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215-099
Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 11/15/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU L-49 (PTD 215-099) Coil Flag 10/21/2021 Please include current contact information if different from above. 37' (6HW Received By: d 11/17/2021 By Abby Bell at 4:00 pm, Nov 15, 2021 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Conformance Treatment Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 12,500'feet N/A feet true vertical 4,197'feet N/A feet Effective Depth measured 12,500'feet 5,780' & 7,080'feet true vertical 4,197'feet 4,182' & 4,221 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 3-1/2" 9.2# / L-80 5,781' 4,182 Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5 / L-80 7,159' 4,222' LTP, PHL & See Packers and SSSV (type, measured and true vertical depth) 8 Swell Packers N/A Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Contact Email: Authorized Title:Operations Manager Contact Phone: 6,390psi N/A 5,750psi 7,740psi Burst Collapse N/A 3,090psi 110' 4,198' 4,197'12,500'5-1/2" measuredPlugs Junk measured N/A Length 80' 5,955' Size Conductor Surface Intermediate 20" 9-5/8" Production Liner 6,720' Casing STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 215-099 50-029-23545-00-00 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025509, ADL0025515, ADl0315848 Milne Point / Schrader Bluff Oil Hilcorp Alaska LLC 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Milne Point Unit L-49 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 000 0 2,936 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 110' 5,955' 0 Structural TVD 321-472 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: Authorized Name and Digital Signature with Date: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 0 2,927 Taylor Wellman twellman@hilcorp.com 907-777-8449 L G Form 10-404 Revised 10/2021 Submit Within 30 days of Operations By Samantha Carlisle at 3:20 pm, Nov 08, 2021 Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2021.11.07 17:00:42 -09'00' David Haakinson (3533) DSR-11/8/21 RBDMS HEW 11/10/2021 SFD 11/9/2021MGR27DEC2021 Well Name Rig API Number Well Permit Number Start Date End Date MP L-49 CTU #6 50-029-23545-00-00 215-099 10/22/2021 10/25/2021 10/22/2021 Mobilize SLB CTU 6 from M pad to L pad. Spot the unit on L-49 and raise the mast. RU CTU 6 on L-49. MU coil connector and MHA. Pull test coil connector and PT MHA to 3,500 psi (good tests), Stab on the well with tools (BHA OAL = 15.20'). Did not have a SSV fusible cap for the Seaboard wellhead. Locate one and install. PT to 300/4,000 psi (good test). RIH with logging BHA to 4,000' CTM, weight check = 17K. Continue to RIH to 7,850' CTM. Flag the CT and wait five minutes for a logging flag. POOH logging at 40 FPM from 7,850' to 7,500'. Flag the CT and wait five minutes for a logging flag. POOH with logging BHA. At surface. SI the well. Undeployed the BHA. LD BHA. Got good data. Install night cap and secure the well. Waiting for the availability of cement pumping unit. Hilcorp Alaska, LLC Weekly Operations Summary Wait for the availability of cement unit. PU and MU BHA: with 2.0X.28 CC / 2.13"X1.56' Disco / 2.11"X.28' X-Over / 2.13"X10.43' Inflatable packer/ 2.13" X6.57' ACC / 2.13" X1.38" IFV / 2.11"X.43' X-Over / 2.13"X10.86' Inflatable packer OAL=33.08', onto the well and PT to 400/3,400 psi. RIH with BHA past flag to 7,532'. PU and stop at flag at 7,501.8. Correct to EOP = 7,522.77' then correct to lower MOE = 7,551.91'. RIH to 7,700'. PU to lower MOE set depth of 7,673' (upper MOE = 7,652.51'), Pump a total of 1 coil volume 31.2 bbls + 20 bbls at 1.2 BPM. Load and launch 1/2" ball. Pump to seat. Set the inflatable packers per Baker. SO 3K to ensure set. Slowly stage pressure up to rupture the burst disk. Pump down CT and WHP tracked. Set down and packer takes weight, Release the packers and POOH with noticeable drag. SI the well. Pop off the well and lay down BHA. Upper inflate packer bag burst. Rupture disk burst. Install nightcap and secure the well. Wait for new inflatable packer BHA. 10/23/2021 10/24/2021 Baker dual inflatable packer BHA on location at 05:30 hours. PU and MU BHA: 2.0X.28 CC / 2.13"X1.56' Disco / 2.11"X.28' X- Over / 2.13"X10.43' Inflatable packer/ 2.13" X6.57' ACC / 2.13" X1.38" IFV / 2.11"X.43' X-Over / 2.13"X10.86' Inflatable packer OAL=33.08', Wait for the availability of HES cement unit. RIH with dual inflatable packer BHA past flag to 7,888'. PU and stop at flag. Correct to EOP = 7,855.29' then correct to upper MOE = 7,863.94'. PU to upper MOE set depth of 7,654' (Lower MOE set at 7674.49'). PU to upper MOE set depth of 7,654' (Lower MOE set at 7674.49'). Pumping 8.6 ppg 3% KCl at 1.2 BPM = 2,563 psi. (20:00 hours L-46 ESP reduced to minimum rate). Total pumped 1 coil volume 31.2 bbls + 18.9 bbls, Load and launch 1/2" ball. Pressure up and inflate the packers per Baker. SO 3K down to ensure set. Slowly stage pressure up to rupture the burst disk (rupture at 2,160 psi), Perform injectivity test. Final injectivity 0.5 BPM = 560 psi. Reduce to minimum rate to keep fluid moving while waiting for HES to prep H2ZERO. HES flood their lines and PT lines to 1,500/4,500 psi. Batch up and pump H2ZERO. Had reduce pump rate to minimum at 0.3 BPM. Kept having to shut down due to hitting pressure limit of 850 psi. Discussed with town engineer about upping pressure limit due to friction and pumping through rupture disk restriction. Continue pumping H2ZERO at 0.3 BPM = 1,275 psi (final treatment pressure). Total H2ZERO pumped = 33 bbls. Displace with 33.2 bbls (2 bbls over coil volume) 3% KCl at 0.3 BPM = 1,090 psi (final displacement pressure), PU to release the inflatable packers. Released at 31K. Allow the elements to relax. POOH with BHA to 4,500'. Well Name Rig API Number Well Permit Number Start Date End Date MP L-49 CTU #6 50-029-23545-00-00 215-099 10/22/2021 10/25/2021 Hilcorp Alaska, LLC Weekly Operations Summary Continue POOH with BHA freeze protecting coil and well, At surface. SI the well. Pop off the well and lay down the dual inflatable packer BHA. Stab back on well, P.T. QTS 4200psi. Stand-by for N2 pumpers to blow down the reel. RU HES N2 unit. HES pump N2 through coil 500scf for 5 minutes / 1500scf for 10 minutes and 500scf for 5 minutes. RDMO to Deadhorse to swap from 1.75" CT to 2" CT. See I-35 report. 10/25/2021 ___________________________________________________________________________________ Revised by DH 11-5-2021 PROPOSED Milne Point Unit Well: MPL-49 PTD: 215-099 API: 50-029-23545-00-00 RKB: 28’CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 20” Conductor 78.6 A-53 Weld 19.25” Surf 110’ 9-5/8" Surf. Csg 40 L-80 TC II 8.835” Surf 5,955’ 5-1/2" Prod Liner 17 L-80 DWC/C HT 4.892” 5,780’ 12,500’ TUBING DETAIL 3-1/2” Tubing 9.2 L-80 EUE 8rd 2.992” Surf 5,781’ 2-7/8” Tubing 6.5 L-80 EUE 8rd 2.441 5,781’ 7,159’ 20” 9-5/8” shoe @ 5,995’ COMPLETION DETAIL No. Item Top MD ID OD 1 Tubing Hanger 28.42’ ” ” 2 X Nipple 2,127’ 2.813” 4.450” 3 3-1/2 GLM w/ 1.5 ”DMY valve 3-22-18 2,990’ 2.920” 4.500” 4 3-1/2” HAL AutoFill sub closed 3-13-18 w/ Rig 5,730’ 2.880” 5.400” 5 Liner Top Packer 5,780’ 5.000” 6.672” 6 Canfield Bushing – 3.5” x 7” x 2-7/8” 5,781’ 2.41” 7.000” 7 7” Seal Stem Assembly (4 Seal Stacks) 5,783’ 2.441” 7.000” 8 Injection Control Device (ICD) (12 Total) See Below 4.675” 6.500” 9 Swell Packer (9 Total – See Detail Below) See Below 4.892” 8.000” 10 5-1/2” x 2-7/8” 13Cr-80 PHL Packer 7,080’ 2.36 4.515” 11 2-7/8” Magnum 10K Ceramic Shear Disk -Btm @ 7,159’-removed disk with coil on 3-25-18 7,158’ 2.5” 3.668” SWELL PACKER DETAIL Top (MD) Btm (MD) 6,146.10’ 6,151.78’ 7,467.23’ 7,472.93’ 7,855.60’ 7,861.29’ 8,336.42’ 8,342.08’ 9,106.81’ 9,112.52’ 9,862.02’ 9,867.72’ 11,053.43’ 11,059.23’ 11,737.00’ 11,742.70’ 12,262.02’ 12.267.78’ 5-1/2” shoe @ 12,500’ 1 2 3 5 6 9 11 ICD DETAIL Top (MD) Btm (MD)Status 5,995.77’ 6,002.63’ Isolated 6,457.55’ 6,464.41’ Isolated 6,912.68’ 6,919.55’ Isolated 7,661.01’ 7,667.87’ Cemented 8,222.94’ 8,229.80’ Open 8,581.47’ 8,588.34’ Open 9,469.75’ 9,476.64’ Open 10,308.68’ 10,315.58’ Open 10,526.22’ 10,533.07’ Open 11,463.84’ 11,470.73’ Open 11,939.57’ 11,946.44’ Open 12.382.70’ 12,389.58’ Open PBTD =12,500’ MD / 4,197’ TVD TD = 12,500’ MD / 4,197’ TVD Max Deviation:94.94º 10 8 6 & 7 4 ES Cementer @ 2,262’ Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 10/18/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU L-49 (PTD 215-099) Injection Profile 09/11/2021 Report Please include current contact information if different from above. 37' (6HW Received By: 10/19/2021 By Abby Bell at 11:31 am, Oct 19, 2021 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Conformance Treatment 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 12,500'N/A Casing Collapse Conductor N/A Surface 3,090psi Production 6,390psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name: Operations Manager Contact Email:dhaakinson@hilcorp.com Contact Phone: 777-8343 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng 3-1/2"9.2# / L-80 / EUE 8rd 5,781' David Haakinson COMMISSION USE ONLY Authorized Name: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025509, ADL0025515 & ADL0315848 50-029-23545-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 215-099 Hilcorp Alaska LLC Length Size 4,197' 12,500' 4,197' 1,226 MILNE POINT / SCHRADER BLUFF OIL 110' 80' 6.5 / L-80 / EUE 8rd TVD Burst 7,159' MD N/A Tubing Grade: 7,740psi 4,198' 4,197' 5,955' 12,500' N/A See Schematic MILNE PT UNIT L-49 See Schematic 80' 20" 9-5/8" 5-1/2" 5,924' 6,720' 5,750psi C.O. 477.05 LTP & PHL and N/A 5,780 MD / 4,182 TVD & 7,080 MD / 4,221 TVD and N/A Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 9/27/2021 2-7/8" Perforation Depth MD (ft): ory Statu Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Meredith Guhl at 9:45 am, Sep 14, 2021 321-472 Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2021.09.14 09:40:51 -08'00' David Haakinson (3533) DSR-9/14/21 DLB 09/14/2021 X 10-404 MGR17SEP2021 dts 9/17/2021 JLC 9/17/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.17 14:48:55 -08'00' RBDMS HEW 9/17/2021 CT Cement Remediation Well: MPU L-49 9-13-2021 Well Name:MPU L-49 API Number: 50-029-23545-00-00 Current Status:Online-WINJ Pad:Milne Point L-Pad Estimated Start Date:September 27, 2021 Rig:Coiled Tubing Unit Reg.Approval Req’std?No Date Reg. Approval Rec’vd:N/A Regulatory Contact:Tom Fouts 777-8398 Permit to Drill Number:215-099 First Call Engineer:David Haakinson (907) 777-8343 (O) (307) 660-4999 (M) Second Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 (M) AFE: Job Scope:CT MBE Remediation Current Bottom Hole Pressure:1,626 psi @ 4,000’ TVD SBHP 02/07/18 |7.82 PPGE Maximum Expected BHP:1,626 psi @ 4,000’ TVD MPSP:1,226 psi (Based on 0.1 psi/ft) MIN ID:2.36” PHL Packer @ 7,080’ MD Max Inclination 90-95° Horizontal Liner Brief Well Summary: MPU L-49 was drilled and completed as a Schrader Bluff OA sand horizontal injector in August 2015. High water saturations were encountered at the heel of the well. The well supports the MP L-46 producer and has been known to have a direct interaction resulting in high water-cut increases. A RWO was completed in 2018 to isolate the high saturation, but it appears that communication exists behind pipe from L-49 to L-46. An IPROF was run on 9/11/21 confirming a significant amount of injection water was entering ICD # 4 at 7,661’ MD. Temperature data indicates that flow behind pipe is likely back up to ICDs #1-3. Well-work Objective: 1. Pump cement conformance treatment to isolate rapid conductivity between L-49 and L-46. Notes Regarding the Well x ICDs # 1-3 are isolated by pipe. However, it is now known that the swell packers installed from 2015 to 2020 were not properly designed for swell time and hole size. x CT IPROF tagged up at 7,137’ MD during IPROF run. A 2.28” bladed junk motor was run to dress the area. Take precaution when drifting through the area. Risks x Exceeding fracture pressure. o Assuming a 0.66 psi/ft fracture gradient, try to reduce surface pressure as much as possible. x Early Setup of cement causing stuck coiled tubing. o The use of a treatment packer should reduce risk of gel setup in coiled tubing annular space. o If the treatment packer becomes stuck, pump a ball to disconnect and leave downhole. x Early Release of Treatment Packers o It is important to maintain consistent temperatures throughout the job (source water, cement) to avoid early release of the treatment packers. x Cement Production in producer o Producer L-46 should be slowed to minimum speed during pumping of cement. YES CT Cement Remediation Well: MPU L-49 9-13-2021 Coiled Tubing & Pumping Unit 1. MIRU Coiled Tubing Unit and spot auxiliary equipment. 2. Pressure test BOPE to 3,500 psi Hi 250 Low, 10 min High, 5 min Low each test. a. If within the standard 7-day test BOPE test period for Milne Point, a full body test and function test of the rams is sufficient. b. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. 3. Reduce producer L-46 ESP speed to minimum during the pumping for the job. 4. RU cement mixing pumping equipment. 5. Establish site control and a separate radio channel for crews so that proper and clear communication can exist throughout the job. 6. MU 1.75” CT with CTC, DBCV, carrier and memory GR/CCL for tie-in with 2” nozzle. 7. RIH to ~2,000’ MD. Displace well freeze protect to tanks. 8. RIH to below ICD #4 to 7,800’ MD. 9. PU to 7,661’ MD at 40 FPM. 10. Flag Pipe. 11. POOH to surface for BHA Change. 12. Review GR/CCL data for tie in. Plan to set the lower treatment packer (mid-element) at 5’ below the ICD connection @ 7,673’ MD 13. MU treatment BHA with 1.75” CT, CTC, and Baker Hughes 2.313” Treatment BHA. 14. RIH to 7,800’ MD. POOH to tie into the flagged pipe and correct depth based on the log. 15. Confirm with pumping crew that they are ready to mix cement for pumping. 16. Once on depth, pump at 0.5” ball to set the lowermost treatment packer. 17. Slack off weight slightly to confirm the lower packer is set. 18. Continue to pressure up in 500 psig stages until the burst disc pops at ~2,500 psig. The upper treatment packer should be set. 19. Begin injecting source water down the CT for baseline injectivity. a. Target 700 psig CT pressure. Inject for a minimum 30 minutes to confirm baseline. b. DNE 700 psig coiled tubing injection pressure. 20. Contact engineering with injectivity results. This testing is meant to confirm that we have injectivity through the ICD. 21. Mix 33 bbls of 12.0 PPG cement and pump cement to formation. a. Volume assumptions: i. 30.5 bbls of annular hole volume back to ICD # 3 @ 6,913’ MD with 8.5” hole size. ii. 16 bbls of annular hole volume between swell packers at 7,467’ and 7,855’ MD. 22.Pump cement as slow as possible to reduce fracture potential and allow for cement to take the path of least resistance.DNE 0.4 BPM. 23. Flush cement with source water spacer. 24. Displace water 2 bbl past ICD into formation to clear wellbore. a. If cement treatment screens out early, PU to release packers and begin contaminating cement. Cement likely cannot be circulated out to surface. CT Cement Remediation Well: MPU L-49 9-13-2021 25. After displacement of the cement, reduce fluid injection into the well as much as possible. 26. PU 5,500 lb-force to release packers.Allow elastomers to relax prior to pulling up-hole. 27. POOH to 2,000’ MD. Freeze protect well, circulating fluid in at 1:1 while account for pipe displacement. 28. Allow L-49 cement product to setup for 3 days prior to returning the well to injection. 29. RDMO Coiled Tubing. Attachment: 1 Schematic 2 Proposed Schematic 3 BOPE Schematic ___________________________________________________________________________________ Revised by DAH 9-14-2021 SCHEMATIC Milne Point Unit Well: MPL-49 PTD: 215-099 API: 50-029-23545-00-00 RKB: 28’CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 20” Conductor 78.6 A-53 Weld 19.25” Surf 110’ 9-5/8" Surf. Csg 40 L-80 TC II 8.835” Surf 5,955’ 5-1/2" Prod Liner 17 L-80 DWC/C HT 4.892” 5,780’ 12,500’ TUBING DETAIL 3-1/2” Tubing 9.2 L-80 EUE 8rd 2.992” Surf 5,781’ 2-7/8” Tubing 6.5 L-80 EUE 8rd 2.441 5,781’ 7,159’ 20” 9-5/8” shoe @ 5,995’ COMPLETION DETAIL No. Item Top MD ID OD 1 Tubing Hanger 28.42’ ” ” 2 X Nipple 2,127’ 2.813” 4.450” 3 3-1/2 GLM w/ 1.5 ”DMY valve 3-22-18 2,990’ 2.920” 4.500” 4 3-1/2” HAL AutoFill sub closed 3-13-18 w/ Rig 5,730’ 2.880” 5.400” 5 Liner Top Packer 5,780’ 5.000” 6.672” 6 Canfield Bushing – 3.5” x 7” x 2-7/8” 5,781’ 2.41” 7.000” 7 7” Seal Stem Assembly (4 Seal Stacks) 5,783’ 2.441” 7.000” 8 Injection Control Device (ICD) (12 Total) See Below 4.675” 6.500” 9 Swell Packer (9 Total – See Detail Below) See Below 4.892” 8.000” 10 5-1/2” x 2-7/8” 13Cr-80 PHL Packer 7,080’ 2.36 4.515” 11 2-7/8” Magnum 10K Ceramic Shear Disk -Btm @ 7,159’-removed disk with coil on 3-25-18 7,158’ 2.5” 3.668” SWELL PACKER DETAIL Top (MD) Btm (MD) 6,146.10’ 6,151.78’ 7,467.23’ 7,472.93’ 7,855.60’ 7,861.29’ 8,336.42’ 8,342.08’ 9,106.81’ 9,112.52’ 9,862.02’ 9,867.72’ 11,053.43’ 11,059.23’ 11,737.00’ 11,742.70’ 12,262.02’ 12.267.78’ 5-1/2” shoe @ 12,500’ 1 2 3 5 6 9 11 ICD DETAIL Top (MD) Btm (MD)Status 5,995.77’ 6,002.63’ Isolated 6,457.55’ 6,464.41’ Isolated 6,912.68’ 6,919.55’ Isolated 7,661.01’ 7,667.87’ Open 8,222.94’ 8,229.80’ Open 8,581.47’ 8,588.34’ Open 9,469.75’ 9,476.64’ Open 10,308.68’ 10,315.58’ Open 10,526.22’ 10,533.07’ Open 11,463.84’ 11,470.73’ Open 11,939.57’ 11,946.44’ Open 12.382.70’ 12,389.58’ Open PBTD =12,500’ MD / 4,197’ TVD TD = 12,500’ MD / 4,197’ TVD Max Deviation:94.94º 10 8 6& 7 4 ES Cementer @ 2,262’ ___________________________________________________________________________________ Revised by DAH 9-14-2021 PROPOSED Milne Point Unit Well: MPL-49 PTD: 215-099 API: 50-029-23545-00-00 RKB: 28’CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 20” Conductor 78.6 A-53 Weld 19.25” Surf 110’ 9-5/8" Surf. Csg 40 L-80 TC II 8.835” Surf 5,955’ 5-1/2" Prod Liner 17 L-80 DWC/C HT 4.892” 5,780’ 12,500’ TUBING DETAIL 3-1/2” Tubing 9.2 L-80 EUE 8rd 2.992” Surf 5,781’ 2-7/8” Tubing 6.5 L-80 EUE 8rd 2.441 5,781’ 7,159’ 20” 9-5/8” shoe @ 5,995’ COMPLETION DETAIL No. Item Top MD ID OD 1 Tubing Hanger 28.42’ ” ” 2 X Nipple 2,127’ 2.813” 4.450” 3 3-1/2 GLM w/ 1.5 ”DMY valve 3-22-18 2,990’ 2.920” 4.500” 4 3-1/2” HAL AutoFill sub closed 3-13-18 w/ Rig 5,730’ 2.880” 5.400” 5 Liner Top Packer 5,780’ 5.000” 6.672” 6 Canfield Bushing – 3.5” x 7” x 2-7/8” 5,781’ 2.41” 7.000” 7 7” Seal Stem Assembly (4 Seal Stacks) 5,783’ 2.441” 7.000” 8 Injection Control Device (ICD) (12 Total) See Below 4.675” 6.500” 9 Swell Packer (9 Total – See Detail Below) See Below 4.892” 8.000” 10 5-1/2” x 2-7/8” 13Cr-80 PHL Packer 7,080’ 2.36 4.515” 11 2-7/8” Magnum 10K Ceramic Shear Disk -Btm @ 7,159’-removed disk with coil on 3-25-18 7,158’ 2.5” 3.668” SWELL PACKER DETAIL Top (MD) Btm (MD) 6,146.10’ 6,151.78’ 7,467.23’ 7,472.93’ 7,855.60’ 7,861.29’ 8,336.42’ 8,342.08’ 9,106.81’ 9,112.52’ 9,862.02’ 9,867.72’ 11,053.43’ 11,059.23’ 11,737.00’ 11,742.70’ 12,262.02’ 12.267.78’ 5-1/2” shoe @ 12,500’ 1 2 3 5 6 9 11 ICD DETAIL Top (MD) Btm (MD)Status 5,995.77’ 6,002.63’ Isolated 6,457.55’ 6,464.41’ Isolated 6,912.68’ 6,919.55’ Isolated 7,661.01’ 7,667.87’Cement 8,222.94’ 8,229.80’ Open 8,581.47’ 8,588.34’ Open 9,469.75’ 9,476.64’ Open 10,308.68’ 10,315.58’ Open 10,526.22’ 10,533.07’ Open 11,463.84’ 11,470.73’ Open 11,939.57’ 11,946.44’ Open 12.382.70’ 12,389.58’ Open PBTD =12,500’ MD / 4,197’ TVD TD = 12,500’ MD / 4,197’ TVD Max Deviation:94.94º 10 8 6& 7 4 ES Cementer @ 2,262’ MILNE POINT UNIT MPU L-49 9/14/2021 COIL BOPE Valve, Swab, WKM-M, 3 1/8 5M FE Valve, Upper Master, Baker, 3 1/8 5M FE, w/ Hydraulic MPU M-10 20 X 9 з X 7 X 3 ½ Coil Tubing BOP Valve, Lower Master, WKM-M, 3 1/8 5M FE Blind/Shear Blind/Shear Lubricator to injection head 4 1/16 10M Slip Slip Blind/Shear Blind/Shear Pipe Pipe Manual Gate 2 1/8 5M 2.00" Single Stripper Crossover spool 4 1/16 10M X 4 1/16 5M Manual Gate 2 1/8 5M Tubing Adapter, 3 1/8 5M Pump-In Sub 4 1/16 5M 1502 Union Crossover spool 4 1/16 5M X 3 1/8 5M (9, 15 -099 • • Hilcorp Alaska,LLC Post Office Box 244027 Anchorage,AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage,AK 99503 Phone: 907/777-8547 SCMHNE) JUN 07202 June 5, 2018 RECEIVED Mr. Guy Schwartz Alaska Oil and Gas Conservation Commission JUN 0 6 2018 333 West 7t''Avenue, Suite 100 Anchorage, Alaska 99501 AOGCC Re: Conductor Annulus Corrosion Inhibitor Treatments 4/20/18-5/12/18 Dear Mr. Schwartz, Enclosed please find multiple copies of a spreadsheet with a list of wells that were treated with corrosion inhibiting casing filler in the surface casing by conductor annulus. The heavier than water "grease-like" filler displaces water to prevent external casing corrosion that could result in a surface casing leak. The attached spreadsheets include the well names, field, PTD and API numbers, treatment volumes and treatment dates. This treatment campaign represents primarily new Milne Point HAK drill wells along with two Northstar wells which previously had excavations and external surface casing leak repairs. If you have any additional questions, please contact me at 777-8547 or wrivard@hilcorp.com. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC i • U U a) a) a) a) a) a) a) a) a) a) o a) a) a) a) 2 2 c c c c c c c c c c c c c J J J J J J J J J J J J J c • C C c C c C C c C C c C c 2 . O L L L L L L L L L L L L L U a) a) a) a) a) a) a) a) a) a) a) a) a) 0- a 5 ccrtccctccccw occcctccC C 7C C c c c c c c c C c c c L L • m a) a) a) a) a) a) a) a) a) a) a) o o 0 Il. E E E E E E E E E E E E E U U a) a) a) m a) a) m a) a) a) a) a) o U 00000000C.) 000 Q Q Q Q Q Q Q Q Q Q Q Q Q U ° c Q Q To col ca V d O OO 0 0 0 Lo LI) Ln O Lo Lf) Lo L o5 U = — N- X- x- N NNc; p 0 �- N � o CO O ao CO 0 O 0 CO O CO ao CO Co CO CO o 0 a) 0 0 0 0 0 0 0 0 0 0 0 0 — 0 0 8f, N N NNNNNNNNNNRNN U Ca 0 O — — '— N N N N M C) Ce') M N N i N N N N N N N N N N N N U 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 U ti LO CO ..Zr O) M N- CO 0 0) N ' Cr) 0 N O LO LC) CO M L) Lo Cr) N a) co �t Ln N O e- 0 — — 0 N C d CO CO CO CO CO CO LO LO CO LO Ln LO N- N N Q N N N N N N N N N N N N N N N L ' 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 U 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 _0 0 0 0 0 0 0 0 0 0 0 0 0 COO CD N- N-O N- CO LL CO C~O LNf) �' LSI CO CO CO a: Lo Ln LI) Lo Lo Ln L() Lf) Lo Ln Lo Lo Lo O r U < M N M M M M M M M M M N M M M M ') N N N N N N N N N N N N N a) a) a) a) 0) 0) 0) 0) a) a) a) a) a) a) a) N N NNNNNNNNNNNNN 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 LO LO LO Ln LO LO LO LO LO LS') LO LO LO LO 1:3 D = D = DDDDDDDDDD a) a. a_ a. a a a a_ a a a a a a_ cn cn ii 2 2 2 2 2 2 2 2 2 2 2 2 Z Z CO 0) O N CO N- CO 't CO 0) 0 CO N N M M M M N N d Lf) Lf) m m m m m m - - Y J J J Ln J a a_ a a a a a a o_ a a a_ a_ u) • STATE OF • OIL AND GAS CON ERVATON C011�IfISSION RA RECEIVED ipsKA ORT OF SUNDRY WELL OPERATIONS MAY 1 1 2018 1.Operations Abandon U Plug Perforations Li Fracture Stimulate 11 Pull Tubing ❑ ❑ Operations shutdown Performed: Suspend ❑ Perforate ❑ Other Stimulate Alter Casing ❑ Cha ,'.',z, - ,+g .gym ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Well❑✓ Re-enter Susp Well ❑ O er:Isolate IC['s ❑I 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska LLC Development ❑ Exploratory ❑ 215-099 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic "Service Q 6.API Number: AK 99503 50-029-23545-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025509,ADL0025575&ADL0315848 MILNE PT UNIT L-49 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL 11.Present Well Condition Summary: Total Depth measured 12,500 feet Plugs measured N/A feet true vertical 4,197 feet Junk measured N/A feet Effective Depth measured 12,500 feet Packer measured See Below feet true vertical 4,197 feet true vertical See Below feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 110' 80' N/A N/A Surface 5,924' 9-5/8" 5,955' 4,198' 5,750psi 3,090psi Production 6,720' 5-1/2" 12,500' 4,197' 7,740psi 6,390psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 3-1/2" 9.2#/L-80 5,781' 4,182' Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80 7,159' 4,222' 5,584'MD/4,156'TVD • Packers and SSSV(type,measured and true vertical depth) PHL<P N/A 5,780'MD/4,180'TVD N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A r JIJN 21 •Z\ '1 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 320 520 702 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑ Exploratory❑ Development p ❑ Service Q Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ Q WAG ❑ GINJ ❑ SUSP❑ SPLOG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 318-083 Authorized Name: Bo York Contact Name: Paul Chan Authorized Title: Operations Manager Contact Email: pchan@hilcorp.c9m Authorized Signature: tom,. - ... -cJ /k.. Date 5/10/2018 Contact Phone: 777-8333 iyic , /. e4vg �� RBDMSd\ Mar 2 5 2018 Form 10-404 Revised 4/2017 A 66✓/` Submit Original Only • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-49 ASR#1 50-029-23545-00-00 215-099 3/7/18 3/25/18 Daily Operations: , qr J 445 3/7/2018-Wednesday Kill Well, Circulate 290 BBIs 8.45#seawater down tubing up annulus, @ 5bpm, 180psi,shut down monitor,tubing went on vac, annulus static, R/D Pump Eq. NRW. Set BPV,test tree void. N/D production tree on well L-49 and move equipment f/F pad to L pad. Spot mud boat into position, spot well house in position over well head, N/U BOPE on well L-49. Roads and Pads on F pad w/crane to R/D rig floor,well house, and BOPE f/well F-87. Move co rep trailer and dog house to L-49 and spot in position. Spot mud pits into position on L-49. Continue to R/U on well L-49. Spot rig floor into position, relocate rig carrier f/F pad to L pad.SIMOPS: Wellhead reps on location at F-87 to N/U production tree. 3/8/2018-'Thursday Cont.R/U, adjust mud boat,spot carrier, prep& raise mast. Run lines, r/u casing jack, pressure up accumulator, r/u gas system &test same good, unload seawater in pits. Continue to R/U in prep for testing BOPE. Function accumulator and find leak in pulsation dampener. Bleed down system and inspect leak.Adjust seal rings and pressure system back up. Contact I- rig for backup seal ring kit. Electricians on location to change out H2S sensor and re-test. (Good test).Wellhead reps on location to pull BPV. Pressure under BPV, attempt to bleed off through BPV. Bleed for 1hr with no success. Decide to bullhead TBG w/52bbls of seawater to clear any gas. R/U pipe handling equipment to 3-1/2", pull jnt of 3-1/2"TBG f/spare TBG on location. P/U and M/U TBG to TBG hanger. R/U to pump. Bullhead kill well through BPV pumping at 3BPM w/ 1,000psi. Pressure stabilized for 30bbls and then dropped off indicating well had gone on a vacuum. Complete the full 52bbls. Blow down fluid system. Wellhead Rep on location to pull BPV and set TWC. Fill BOPE stack and prep for testing BOPE. Shell test BOPE, leaks found on stack. Torque all bolts on stack. (First time stack has been used since getting from Weatherford).Test BOPE as per Sundry and ASR test procedure.Test w/2-7/8" and 3-1/2"test joints to 250psi low, 2,500psi high f/5 charted mins. 3/9/2018-Friday Cont.testing testinfOOPE, AOGCC witness was waived by inspector Lou Laubenstein testesw/3-1/2" &2-7/8" faint 250 low/2,500 high. R/D test eq. warm/test casing jack, install slips, pull TWC, mit fluid from upright tank to pits,. M/U landing jt, P/U t/100k take over w/jack stage up t/shear packer @ 112k, cont. pull wt leveled out @ 50k, do wt 29k, re-land hanger. R/D casing jack, r/u spools,flowline, bird bath. Wrap and heat flowline. Crew changeout. Service equipment. Check IA for pressure prior to opening up blind rams. IA on a consistent blow. R/U jumper hose in the cellar from the IA to the derrick valve, open HCR choke,and allow IA and TBG to U-tube. Open C12 to flowback tank and bleed off any gas trapped in the system. Open blind rams, pull TBG hanger to the floor and L/D. Fill annulus to check fluid level. Fill IA @ 3BPM w/52bbls. No sign of fluid. Shut down pumps, and prep to pump down TBG. Pump down TBG, unable to see pressure spike to indicate catching fluid pressure. Pressures steadily climbed to^'500psi prior to dropping off to^'100psi. Pump 15bbls. Shut down pumps, blow down system. POOH w/3-1/2" x 9-5/8" PHL production PKR on 3-1/2" 9.3#TBG f/"'5,800'md to GLM (-3,000'md). R/U to circulate down TBG to catch pressure and determine what depth the fluid level is at. Pump 25bbls without catching pressure (5-10psi pump pressure). Shut down pump, blow down lines. Continue to POOH w/3-1/2" x 9- 5/8" PHL production PKR on 3-1/2" 9.3#TBG to surface. Load and tally 3-1/2"TBG. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-49 ASR#1 50-029-23545-00-00 215-099 3/7/18 3/25/18 Daily Operations 3/10/2018-Saturday Prep 5-1/2" Cleanout BHA,tally 3-1/2" tubing rack&tally 45 jts 2-7/8"tubing. M/U BHA-4-3/4" bit, 5-1/2" casing scraper, xo's =9.12',.TIH p/u 45 jts 2-7/8" 6.5# EUE 8rd tubing. C/O handling tools t/3-1/2". RIH w/3.5"TBG down to""4,100'md. Rig carrier inverter malfunctioning. 100Kw John Deere generator faulting. R/U back up 100Kw generator but it began showing fault code. Electrician Sean Logan on location to trouble shoot inverter issue. Utilize 100Kw generator from ESP spooler unit. Electrician swap pig tails and plug in generator to breaker panel on TP trailer.System back up and running. Change out kelly cock valve on power swivel quil. Power swivel hydraulics not functioning properly.Trouble shoot. Unable to shut off hydraulic controls without utilizing manual ball valve to kill hydraulic. R/U to pump down TBG and verify fluid depth in wellbore. 9bbls to catch pressure (^'1,000'md). Blow down lines. Continue to RIH w/scraper BHA. Well Control Drill, kick while tripping W/AAR. Issue w/BHA dimensions. Decision made to POOH f/"5,000'md back to surface. POOH t/1,423'. 3/11/2018-Sunday Service Rig, Cont. POOH f/1,423't/surface. C/O BHA t/5 1/2" scraper w/mule shoe.TIH p/u 2-7/8" EUE tubing t/ 1,423'. C/O handling tools t/3-1/2". Cont tih p/u 3-1/2"tubing down to^'6,500'md.Tag up on LNR top @ 5,787'md w/2klbs. See ICD's#1 and#2 on the way in hole. C/O, perform Rig maintenance. Continue to RIH down to 7142'md. R/U and circulate down the TBG to catch pressure. (10bbls) Followed by another 5bbls to push any debris away down hole. Blow down lines, monitor hole. Prepare to POOH w/mule shoe scraper BHA on tapered TBG string. Continue to POOH. Stop at jnt 138 ( 5,787).Verify LNR top by tagging several times w/3-4Klbs. Continue to POOH f/LNR top PKR @ 5,787'md to surface. Perform well control drill, kick while tripping w/AAR. L/D mule shoe/scraper BHA, and prep to M/U polished mill BHA. 3/12/2018'-Monday Service rig, breakdown 5-1/2" c/o BHA, Prep & p/u BHA-7.375 Polish Mill assy,xo, DP xo, DB xxo, xo, pup=36.92'.TIH p/u 3 1/2" tubing t/5,760', up wt 42k, dn wt 28k. Space out&warm swivel. Swivel up,get parameters, have Prostar link up & analyze working swivel. Cont.tih t/5,781', see bobble (L/T) cont to no go on upper mil @ 5,792', up wt 41k dn wt 29k, rot wt 33k, rot 37 rpm, 15k tq off 16.5 on,cleanup liner top&seal bore. POOH t/5,764' break down subs, 6' Pup& l/d same. Blow down. Crew change, rig service. POOH w/ Baker completions polished mill BHA f/5,764'md to surface. Fill hole w/ double metal displacement. Replace 40 joints of 3-1/2" EUE. Strap top row of 3-1/2" EUE TBG. Load and tally 2-7/8" EUE TBG for tail pipe section. PJSM w/Halliburton completions on rig floor, discuss running parameters w/crew. RIH w/ completion as per tally. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-49 ASR#1 50-029-23545-00-00 215-099 3/7/18 3/25/18 Dally Operations: 3/13/2018-Tuesday M/U & rih w/ceramic shear disk Mule shoe, 5-1/2" PHL packer,43 jts 2-7/8" 6.5#L/80 EUE 8 rd tubing. C/O handling tools t/ 3-1/2", P/U 7" seal assembly&auto fill valve as per running tally, cont. in hole p/u 3-1/2" 9.3# L80 EUE tubing t/5,780'. Crew change. Perform rig service. RIH w/completion down to 6,950'md. LRS on location to perform pumping operations. PJSM w/Halliburton, LRS, and rig crews to discuss plan forward. Continue to RIH w/3-1/2" 9.3# EUE completion down to jnt 180. P/U =43.5klbs, S/0 = 28klbs. Start to see 2klbs weight loss 8.5' into jnt 182, continue down 18.5' into jnt 182 and no-go w/7klbs. P/U to 43.5klbs mark the pipe, and then pick up another 2'for a final set depth of 14' into jnt 182 (7,178.09 @ ASR floor). R/U to pump down TBG w/LRS and shift HAL auto fill sub shut. Pressure TBG to 500psi and hold for 1min, no sign of leak, continue up to 1,640psi, hold pressure for 1min. Bleed off pressure from TBG. Blow down system. L/D joints 282, 281, 280. All three joints galled. M/U pups 2.25', 10.25', 10.28'. P/U new joint(30.2') and replace jnt 180. M/U TBG hanger w/ pup joint and lower into BOPE. Shut pipe rams and R/U LRS to pump 160bbls of corrosion inhibition down the IA. PJSM w/ LRS and ASR crew to discuss pumping line up and parameters. Pump 160bbls of corrosion inhibition fluid off of NES vac. Pump @ 3BPM w/400psi. Shut down LRS pump, disconnect NES and send them to B-pad to for 210bbls of diesel. R/U ASR pits to LRS pump and begin displacing corrosion inhibitor w/fresh water from pits. (After 20bbls away leak noticed coming from cam-lock fitting on 3" discharge hose coming from rig pits to LRS. Shut down pump, disconnect cam-lock and note no seal in female cam-lock. Replace seal and continue pumping 210bbls total. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-49 ASR#1 50-029-23545-00-00 215-099 3/7/18 3/25/18 Daily Operations: �) iIvl 3/14/2018-Wednesday Cont. let pressure bleed from well, Land hanger&seals run in LD pin, pressure up t/275 on IA to verify seals engaged @ 5,780' Line up & pressure tubing up t/3500psi t/set packer @ 7,079', hold t/test tubing 30 min good, bled pressure down t/2k Line up conduct MIT, pressure up annulus t/3,110psi, hold f/30 min good, bleed down tubing to shear valve in GLM., valve sheared @ 600psi, cont. bleed off pressure.Start r/d rig eq.while waiting for pump operators to change out. Pump Diesel 205bblsdown annulus f/freeze protect, @ 5 bpm, 1,200psi let U tube to tubing, set BPV Continue to R/D and move rig to A pad. Lower mast, disconnect lines, remove rig carrier from mud boat. Roads and pads on location w/crane to remove floor. Continue to R/D and move rig to A pad. Remove well house and spot on trailer. Remove BOPE in prep for setting production tree.Vac truck suck out remaining diesel from in wellhead as well as the fluids from flow back tank. Roll up herculite containment from under pipe racks. Wellhead reps on location. N/U production tree and test adapter. (Good test) Secure well and continue to R/D M/O L-49. 3/15/2018-Thursday No activity to report. 3/16/2018- Friday No activity to report. 3/17/2018-Saturday No activity to report. 3/18/2018-Sunday No activity to report. 3/19/2018- Monday No activity to report. 3/20/2018-Tuesday No activity to report. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-49 CTU #4 50-029-23545-00-00 215-099 3/7/18 3/25/25018 Daily Operations: 3/21/2018-Wednesday No activity to report. 3/22/2018-Thursday No activity to report. 3/23/2018-Friday No activity to report. 3/24/2018-Saturday No activity to report. 3/25/2018-Sunday MIRU SLB CTU#4 with 20,615' of 1.75" CT. CV=40.7 bbls. PU injector, 11' of lubricator, and BOPE. Run coil down and MU BHA#1- 1.90" OD connector, 2" DFCV, 2x 2.0" Stingers, 2.0"JSN. OAL=9.788'. Stab on well. NU BOPE. Open SSV, install fusible cap. P/T to 250psi low and 3,500psi high. Open well and RIH w/BHA#1 while taking displacement returns to the tank. WHP= 290psi .Tag Shear Disk at 7,137'.Attempt to shear by setting 3k on Disk. No luck. Attempt to shear by setting 5k on Disk. No luck.Attempt to shear by setting 10k down on disk. No luck. Pressure up to 3,400psi and attempt to shear disk again. No luck.Attempted 30 times to shear disk. No luck. POH to surface with nozzle. Order Hipp Tripper and Chisel Bit. M/U BHA#2: 2.1" Dimple Connector, 2.13" Dual Back Pressure Valve, 2.13" G-Force Jar, 2.13"TJ Disconnect (5/8" ball), 2.13" Hipp Tripper, 2.3" Chisel.OAL: 20.41'. M/U to tree and P/T to 250psi low and 3,500 high. RIH w/BHA#2 while taking displacement to the tank. RIH to 7,141'with BHA#2 and tag Shear Disk. Put 10k WOB with no shear. P/U 5', increase WHP to 1000psi. Hipp trip on Disk. No luck. Pressure up to 3,000psi on tubing. RIH at 120 fpm. No luck. Hipp tripp several times. No luck. Bleed pressure to 1000psi. Stack 10k. No luck.POH 50'. RIH at 120 fpm and break shear disk. Pressure drops from 1,000psi to 50psi. Injectivity test=0.8 BPM at 50psi. POH to surface with hipp tripper and chisel. Close swab valve. L/D hipp tripper and chisel. RDMO. 3/26/2018 Monday No activity to report. 3/27/2018 Tuesday No activity to report. Milne Point Unit in • • Well: MPL-49 SCHEMATIC PTD:215-099 API: 5 0-0 0-0229-23 545-00-00 inieorp Alaska.Lit RKB:28' CASING DETAIL , ,1 Size Type Wt Grade Conn. ID Top Btm 20"� ` 20" Conductor 78.6 A-53 Weld 19.25" Surf 110' 3 a "; 9-5/8" Surf. Csg 40 L-80 TC II 8.835" Surf 5,955' ,ivi At 5-1/2" Prod Liner 17 L-80 DWC/C HT 4.892" 5,780' 12,500' ° TUBING DETAIL 3-1/2" Tubing 9.2 L-80 EUE 8rd 2.992" Surf 5,781' 1.01 2-7/8" Tubing 6.5 L-80 EUE 8rd 2.441 5,781' 7,159' i �;ES Cementer @PI COMPLETION DETAIL 2,262' � Na. Item Top MD ID OD 1 Tubing Hanger 28.42' 2 X Nipple 2,127' 2.813" 4.450" '' 3 3-1/2 GLM w/1.5"DMY valve 3-22-18 2,990' 2.920" 4.500" 0*, a 3 4 3-1/2"HAL AutoFill sub closed 3-13-18 w/Rig 5,730' 2.880" 5.400" 5 Liner Top Packer 5,780' 5.000" 6.672" 6 Canfield Bushing—3.5"x 7"x 2-7/8" 5,781' 2.41" 7.000" °I ., 7 7"Seal Stem Assembly(4 Seal Stacks) 5,783' 2.441" 7.000" 114 8 Injection Control Device(ICD)(12 Total) See Below 4.675" 6.500" 9 Swell Packer(9 Total—See Detail Below) See Below 4.892" 8.000" ' • 10 5-1/2"x 2-7/8"13Cr-80 PHL Packer 7,080' 2.36 4.515" 2-7/8"Magnum 10K Ceramic Shear Disk -Btm 11 7,158' 2.5" 3.668" @ 7,159'-removed disk with coil on 3-25-18 ICD DETAIL SWELL PACKER DETAIL " Top(MD) Btm(MD) Top(MD) Btm(MD) 5,995.77' 6,002.63' 6,146.10' 6,151.78' "t. i 6,457.55' 6,464.41' 7,467.23' 7,472.93' r'' 6,912.68' 6,919.55' 7,855.60' 7,861.29' u 7,661.01' 7,667.87' 8,336.42' 8,342.08' 8,222.94' 8,229.80' 9,106.81' 9,112.52' 8 581.47' 8 588.34' OA' 9,862.02' 9,867.72' 9,469.75' 9,476.64' 11,053.43' 11,059.23' 10,308.68' 10,315.58' 11,737.00' 11,742.70' 10,526.22' 10,533.07' 12,262.02' 12.267.78' '� it - 1 11,463.84' 11,470.73' i S 11,939.57' 11,946.44' 6> 12.382.70' 12,389.58' 9-5/8"shoe @ 5 995' i : ."J 8 9 4' 5 A„S I � 10 N I r. , ,, 4 v ett k 5-1/2"shoe yr 6& 7 11 12,500' M * 1:1 A A A A A PBTD=12,500'MD/4,197'TVD TD=12,500'MD/4,197'ND Max Deviation:94.94° Revised by TDF 4/23/2018 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim jtegg p DATE: Wednesday,April 11,2018 P.I.Supervisor I c e i 4 fit(I 5 SUBJECT: Mechanical Integrity Tests l HILCORP ALASKA LLC L-49 FROM: Adam Earl MILNE PT UNIT L-49 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry Tea NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT L-49 API Well Number 50-029-23545-00-00 Inspector Name: Adam Earl Permit Number: 215-099-0 Inspection Date: 4/9/2018 Insp Num: mitAGEI80409144644 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well ; —L-49 T ype Inj W 'ITVD 4182 Tubing l 691 - 692 693 691 PTD L 2150990 -1Type Test SPT Test psi 1500 IA 753 1836 ' 1794 - 1780 BBL Pumped: 1.9 - BBL Returned: 2 OA 0 0 0 0 Interval] INITAL P/F P Notes: SCANNED • Wednesday,April 11,2018 Page 1 of 1 P7ts j 5 o Regg, James B (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Monday, March 19, 2018 10:11 AM To: Regg, James B (DOA);Wallace, Chris D (DOA);Alaska NS - Milne -Wellsite Supervisors Cc: Darci Horner - (C); Brooks, Phoebe L (DOA); Alaska NS - Milne - Field Operator Leads; Harold Soule - (C); Cody Rymut - (C) I\ �1 � ( Subject: RE: MPL-49 (PTD#2150990) Ready for Injection l y ` Attachments: MIT MPU L-49 03-14-18.xlsx All, Please see attached MIT form updated to include pressure test of the tubing following packer set. Thank You, Wyatt Rivard ( Won irate,ritvt Engineer (iliicorp SCANNED 0: (907) 777-8347 I C: (509)670-8001 I wrivardPhilcorp.com 3800 Cella.€rpt:6nt Drive,Suite 1400 I Anchorage,AK 99503 From: Regg,James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, March 16, 2018 2:19 PM To: Wyatt Rivard <wrivard@hilcorp.com>; Wallace, Chris D (DOA) <chris.wallace@alaska.gov>; Alaska NS- Milne - Wellsite Supervisors<AlaskaNS-Milne-WellsiteSupervisors@hilcorp.com> Cc: Darci Horner-(C) <dhorner@hilcorp.com>; Brooks, Phoebe L(DOA) <phoebe.brooks@alaska.gov>; Alaska NS- Milne - Field Operator Leads<AlaskaNS-Milne-FieldOperatorLeads@hilcorp.com> Subject: RE: MPL-49 (PTD#2150990) Ready for Injection Report should show both pre-injection MITT and MITIA Jim Regg Supervisor, Inspections AOGCC 333 W.7ih Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 orjim.regg@alaska.gov. From:Wyatt Rivard <wrivard@hilcorp.com> Sent: Friday, March 16, 2018 10:37 AM To:Wallace, Chris D (DOA) <chris.wallace@alaska.gov>; Alaska NS- Milne -Wellsite Supervisors<AlaskaNS-Milne- WellsiteSupervisors@hilcorp.com> Cc: Darci Horner-(C) <dhorner@hilcorp.com>; Regg,James B (DOA) <jim.regg@alaska.gov>; Brooks, Phoebe L(DOA) <phoebe.brooksPalaska.gov>; Alaska NS- Milne- Field Operator Leads<AlaskaNS-Milne- 1 • • FieldOperatorLeads@hilcorp.com> Subject: MPL-49 (PTD#2150990) Ready for Injection All, Milne point water injector MPL-49 (PTD#2150990)was recently worked over per sundry#318-083.The well had a passing pre injection MIT-IA on the rig to 3000 psi on 3-14-18. MIT form is attached for reference.A schematic is also attached to reflect the new lowermost tubing packer depth of 7,080' MD/4221'TVD.The well is ready to put on injection for stabilization and compliance testing. Plan Forward—Operations 1) Place well on injection. Use caution, annuli are fluid packed. 2) AOGCC MIT-IA when well is on injection and thermally stable. Thank You, Wyatt Rivard ( Well Integrity Engineer Illilcorp Alaska,LLC 0: (907) 777-8547 C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 3.400 I Anchorage,AK 99503 2 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test • r Submit to: jim.redgealaska.dov- AOGCC.Inspectors(Olalaska.dov phoebe.brooks(cdalaska.dov chri�s.waallace(cDalaska.ttov • 'St OPERATOR: Hilcorp Alaska LLC r-."?..ell FIELD I UNIT I PAD: Milne Point/MPU/L-Pad 11 DATE: 03/14/18 OPERATOR REP: Harold Soule AOGCC REP: - Well MPL-49 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2150990 ,• Type Inj N Tubing 0 3610 - 3620 3610 - Type Test P Packer TVD 4221 .. BBL Pump IA 0 0 0 0 Interval 0 Test psi 1500 ' BBL Return OA 0 0 0 0 Result P r/ Notes: Pressure test of tubing following RWO and packer set. -- Well MPL-49 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2150990 Type Inj N Tubing 2016 2368 2368 2368 Type Test P Packer TVD 4221 - BBL Pump 4.8 - IA 0 3110 ' 3110- 3110 ' Interval 0 Test psi 1500 ' BBL Return 5.6 ' OA 0 0 0 0 Result P Notes: Witness wavied by Brian Bixby.Left pressure on tubing during RWO MIT-IA to hold integrity of shear valve,sheared valve after testing by bleeding pressure off tubing. (extra fluid returns from tubing bleed off) Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. • PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type lnj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type lnj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result - Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type lnj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well - Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In) Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W=Water P=Pressure Test I=Initial Test P=Pass G=Gas 0=Other(describe in Notes) 4=Four Year Cycle F=Fail S=Slurry V=Required by Variance I=Inconclusive I=Industrial Wastewater 0=Other(describe in notes) N=Not Injecting Form 10-426(Revised 01/2017) MIT MPU L-49 03-14-10 III • • Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Friday, March 16, 2018 10:37 AM To: Wallace, Chris D (DOA);Alaska NS - Milne -Wellsite Supervisors Cc: Darci Homer- (C); Regg,James B (DOA); Brooks, Phoebe L(DOA);Alaska NS - Milne - Field Operator Leads Subject: MPL-49 (PTD#2150990) Ready for Injection Attachments: MIT MPU L-49 03-14-18.xlsx; MP L-49 Schematic 3-16-18 DRAFT.doc All, Milne point water injector MPL-49(PTD#2150990)was recently worked over per sundry#318-083.The well had a passing pre injection MIT-IA on the rig to 3000 psi on 3-14-18. MIT form is attached for reference.A schematic is also attached to reflect the new lowermost tubing packer depth of 7,080' MD/4221'TVD.The well is ready to put on injection for stabilization and compliance testing. Plan Forward—Operations 1) Place well on injection. Use caution,annuli are fluid packed. 2) AOGCC MIT-IA when well is on injection and thermally stable. Thank You, Wyatt Rivard I Well Integrity Engineer IHilcorp Alaska,LLC 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 SCANNED 1 • • OF Thr . Ools- I//j�'sA THE STATE Alaska Oil and Gas F ."'t 4cf�L�S JL`te1�iC� Conservation Commission l 1 } ` 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 p Q. Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager SCANNED Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU L-49 Permit to Drill Number: 215-099 Sundry Number: 318-083 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this () day of March, 2018. R ► . ` L ? - 2C18 • 0 0 RECEIVED STATE OF ALASKA FEB 28 201 ALASKA OIL AND GAS CONSERVATION COMMISSION S 3 6 � APPLICATION FOR SUNDRY APPROVALS A OGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well Q Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 2 Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing �1 ❑ Other: Isolate ICD's 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: 4- C..-siij j 4Lk.3 Hilcorp Alaska LLC ' Exploratory ❑ Development ❑ 215-099 3.Address: 3800 Centerpoint Dr,Suite 14006.API Number: Stratigraphic ❑ Service D Anchorage Alaska 99503 50-029-23545-00-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 ° Will planned perforations require a spacing exception? Yes ❑ No 0 / MILNE PT UNIT L-49 ' 9.Property Designati ? .Number): .14 10.Field/Pool(s): ADL0025509,AD1 &ADL0315848 MILNE POINT/SCHRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 12,500' • 4,197' ` 12,500' . 4,197' 1,199 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 110' 80' N/A N/A Surface 5,924' 9-5/8" 5,955' 4,198' 5,750psi 3,090psi Production 6,720' 5-1/2" 12,500' 4,197' 7,740psi 6,390psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.2#/L-80/EUE8rd 5,814' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PHL<P and N/A 5,584'MD/4,156'TVD&5,780'MD/4,180'TVD and N/A 12.Attachments: Proposal Summary El Wellbore schematic Q 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: 3/9/2018 Commencing Operations: OIL ❑ WINJ Q '' WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York Contact Name: Paul Chan Authorized Title: Operations Manager Contact Email: pchan(ci)hilcorp.com Contact Phone: 777-8333 Authorized Signature: PL"-------"' Date: 2/26/2018 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: nit tT—I A 1� ' () Plug Integrity ❑ BOP Test VI Mechanical Integrity Test Location Clearance ❑ Other: .e. 2 500 , &P)/° 1 ;> 1— REDIVIS c (-Kit . f+100 2 Post Initial Injection MIT Req'd? Yes ❑ No ❑ r�IJ ��IU Spacing Exception Required? Yes 0 No Zr Subsequent Form Required: IApprAPPROVED BY /1" oved by: COMMISSIONER THE COMMISSION Date: 3 lie e -' /0 /�� -3 —t. 'lb Q v� Submit Form and Form 10-403 Revised 4/2017 Approved applica onRis lir or12 m hs L the date of approval. Attachments in Duplicate • • Well Prognosis Well: MP L-49 Mom)Alaska,LLI Date:2/26/2018 Well Name: MPU L-49 API Number: 50-029-23545-00 Current Status: SI Injector Pad: L-Pad Estimated Start Date: March 9th, 2018 Rig: ASR 1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 215-099 First Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) Second Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) AFE Nurnbet• zjI =20° i t 1af tpl i i0 �i( li'(�r hl i t- .Y. 2:" a9IYIf(q 914#61 Current Bottom Hole Pressure: 1,599 psi @ 4,000'TVDBKB (SBHPS 2/7/2018/7.70 ppg EMW) Maximum Expected BHP: 1,599 psi @ 4,000'TVDBKB (No new perfs being added) MPSP: 1,199 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPU L-49 was drilled and completed as a Schrader Bluff OA sand horizontal injector in August 2015. High water saturations were encountered at the heel of the well. The well supports the MP L-46 producer. Notes Regarding Wellbore Condition • Passing MIT-IA on 9/29/15 to 1750 psi. Objective: Isolate the high water saturation interval with injection control device (ICD)at 5996',6458',and 6912' MD. The ICDs will be isolated with tubing and packer. I Pre-Rig Procedure: 1. Clear and level pad area in front of well.Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 8.5 ppg sea water down tubing,taking returns up casing to 500 bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. vit 7. RD Little Red Services and reverse out skid. 8. RU crane. Set BPV. ND Tree. NU BOPE. RD Crane. 9. NU BOPE house.Spot mud boat. • • . H Well Prognosis Well: MP L-49 Ifilcor')Alaska,LU Date:2/26/2018 Brief RWO Procedure: 10. MIRU Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 11. PU Casing Jacks via the beaver slide and Tugger winches to rig floor. 12. Set Casing Jacks on top of the BOP Annular with Tuggers. Connect Hydraulics and function test same. 13. Check for pressure and if 0 psi pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/8.5 ppg sea water prior to pulling BPV. Set TWC. 14. Test BOPE to 250 psi Low/2,500 psi High, annular to 250 psi Low/2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 2-7/8" and 3-1/2" test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 15. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path,test choke manifold per standard procedure \\ c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor * 9 the surface equipment for leaks to ensure that the fluid is goingdown-hole X o 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. 16. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/8.5 ppg sea water as needed. 17. Casing Jack RU Procedure: cci.ritvL7 a. Yield strength of 3-1/2", 9.3#, EUE-8rd L-80= 207.2K lbs 3 b. 3-1/2" PHL packer released at 175K lbs on August 12, 2015 ;Ac-� c. RU Casing jack Hydraulics to the ASR#1 control panel. Set pressure relief high point to 1,650 psi (90%of yield strength of 3-1/2" 9.2#L-80 EUE-8rd = 186.5 lbs). d. String weight during 2015 completion: PU = 80K lbs/SO =70K lbs. Nordic block weight not noted. e. Cycle jacks up and down to ensure proper function (dry run without being connected to hanger). 18. MU landing joint or spear and PU on the tubing hanger. 19. Set Casing Jack pressure to 1,475 psi (166.7 K lbs). Slowly pressure up on jacks. Hold for 5 min. • • Well Prognosis Well: MP L-49 Ililcora Alaska,LL Date:2/26/2018 a. Increase pressure in 25 psi increments (2800 lbs) and hold for 5 minutes b. Continue increasing pressure in 25 psi increments until packer shears (Packer sheared at 175K lbs previously—equivalent to 1548 psi). 20. Recover the tubing hanger after shearing the PHL packer. Contingency(If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 21. Set tubing in lower slips and retract casing jacks into lowered position. Swap casing jacks to 'Carriage mode'. Resume pulling the completion utilizing upper slips only with rig while laying down the same in singles. 22. POOH and lay down the 3-1/2" tubing string. Number all joints. Tubing will be re-used. Replace tubing as needed. 23. PU cleanout assembly for 7.375" ID PBR on the liner top packer. RIH on 3-1/2"workstring to ^'5,801' MD. Cleanout TBR and circulate the wellbore clean. POOH and LD cleanout assembly. 24. PU 4.75" OD scraper/cleanout assembly for the 5-1/2" 17#/ft lower completion and RIH on 1,432' of 2-7/8" tubing. Continue RIH on 3-1/2" workstring. Reciprocate scraper across packer set depth of 7,092' MD. POOH. _ 25. MU completion assembly as follows: �s4, �✓ a. 2-7/8" Magnum ceramic shear disk EUE-8rd box x 1/2 mule shoe @ ±7,154' MD ,•�� b. 2 joints 2-7/8" 6.5#/ft L-80 tubing C•: c. 5-1/2" x 2-7/8" HAL 13Cr PHL packer with 10' handling pups @ ±7,092' MD d. 2-7/8"tubing 6`) e. 7" x 2-7/8" triple connect sub 1G 92 1. 3-1/2" 9.3#/ft EUE-8rd box up 2. 7" seal steam with 4 seal stacks (Liner top packer @ 5,780' MD) 3. 2-7/8" 6.5#/ft EUE-8rd pin down f. 1 joint 3-1/2" 9.3#/ft L-80 EUE-8rd tubing g. 3-1/2" HAL AutoFill sub h. 3-1/2" 9.3#/ft L-80 EUE-8rd tubing i. 3-1/2" GLM with shear valve and 10' handling pups@ ±2975' MD j. 3-1/2" tubing k. 3-1/2" X nipple @ ±2093' MD I. 3-1/2" tubing m. 3-1/2" Space out pups n. 1 joint 3-1/2" tubing o. 3-1/2" tubing hanger 26. Fill 2-7/8"tubing while RIH. 27. The 3-1/2" tubing will fill through AutoFill sub. 28. RIH with 3-1/2" x 2-7/8" completion. 29. Perform a low pressure tubing test to 500 psi. 30. With annulus open, pressure up on tubing to close Autofill sub. Calculated closer pressure is 1527 psi. Confirm Autofill sub is closed. Bleed pressure off 31. Line up to circulate down the 9-5/8"x 3-1/2" annulus. . • • Well Prognosis Well: MP L-49 Iiileoru Alaska,LLU Date:2/26/2018 32. Slowly lower 7" seal into tie back receptacle and watch for pressure increase when the seal stem enters the TBR. Slack off and confirm seal stem is fully located into the TBR 33. Space out seal assembly 2' above top of TBR. Place space out pups below the first full joint. 34. Line up to circulate down the 9-5/8" x 3-1/2" annulus. 35. Make up tubing hanger. Line up to circulate down the 9-5/8" x 3-1/2" annulus. 36. Slowly lower 7" seal into tie back receptacle and watch for pressure increase when the seal stem enters the TBR. Pick up and pump 180 bbls of 8.5 ppg corrosion inhibited seawater followed by 190 bbls of seawater. 37. Slack off and land tubing hanger. RILDS. Lay down landing joint. Note PU (Pick Up) and SO (Slack Off) weights on tally. is38. Pressure up the tubing to 3500 psi and set the packer. Test the tubing to 3500 psi for 30 minutes. 't � - Bleed off the tubing pressure to 1000 psi. Test the annulus to 3,000 psi for 30 charted minutes. r- a. Notify AOGCC Inspector at least 24 hours prior to conducting pre-injection MIT-IA. b. Record on 10-426 form. c. Email to wrivard@hilcorp.com for submission to AOGCC. 39. Bleed off the tubing pressure and shear the valve in GLM #1. 40. Freeze protect well to 3000'with diesel. 41. Set BPV. Post-Rig Procedure: 42. RD mud boat. RD BOPE house. Move to next well location. 43. RU crane. ND BOPE. 44. NU existing 5M tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 45. RD crane. Move 500 bbl returns tank and rig mats to next well location. 46. MIRU SL and PT lubricator to 1500 psi. 47. Pull shear valve from GLM and replace with DGLV. 48. RDMO SL. 49. MIRU CT 50. Pressure test lubricator to 2,500 psi Hi 250 Low. Confirm BOPE have been tested within the last 7 days. 51. RIH w/coil BHA to 2-7/8" ceramic shear disk at±7,154' MD. Set down ±750 lbs and break disk. Confirm disk is broken. 52. Freeze protect well as needed. 53. POOH and RD CT. 54. Replace gauge(s) if removed. 55. Turn well over to production. RU well house and flowlines. 56. Perform AC MIT-IA after well has stabilized. Attachments: 1. As-built Schematic 1111 • • Well Prognosis Well: MP L-49 Ililcorp Alaska.LLI Date:2/26/2018 2. Proposed Schematic 3. BOPE Schematic 4. Existing Tree/Wellhead 5. Blank RWO Sundry Change Form • 0 Milne Point Unit II Well: MPL-49 SCHEMATIC PTD: 215-099 API: 50-029-23545-00-00 !Warp Alaska.Ilk 12K1;'Di' CASING DETAIL 20"A \.__71 Size Type Wt Grade Conn. ID Top Btm 20" Conductor 78.6 A-53 Weld 19.25" Surf 110' 9-5/8" Surf.Csg 40 L-80 TC II 8.835" Surf 5,955' 5-1/2" Prod Liner 17 L-80 DWC/C HT 4.892" 5,780' 12,500' TUBING DETAIL 3-1/2" Tubing 9.2 L-80 EUE 8rd 1 2.992" Surf 5,814' 2 JEWELRY DETAIL No. Item Top MD Btm MD ID OD " 30, 1 Tubing Hanger 28.42' 28.84' " 2 X Nipple 2,093' 2,095' 2.813" 4.493" ' 3 Stage Tool—ES Cementer 2,262' 2,266' 8.618" 9.625" 4 GLM w/sheer valve set @ 2500 psi 2,975' 2,984' 2.920" 4.500" 4 5 PHL Packer 5,584' 5,592' 3.850" 8.450" 6 Ratcheting Muleshoe 5,812' 5,814 3.000" 4.760" 7 Liner Top Packer 5,780' 5,801 5.000" 6.672" 8 7"Pup&7"x 5-1/2"X0 5,801' 5,809' 4.860" 7.670" 9 Injection Control Device(ICD)(12 Total) See Below See Below 4.675" 6.500" ' 10 Swell Packer(9 Total—See Detail Below) See Below See Below 4.892" 8.000" "kr LieICD DETAIL SWELL PACKER DETAIL ", Top(MD) Btm(MD) Top(MD) Btm(MD) 5,995.77' 6,002.63' 6,146.10' 6,151.78' 6,457.55' 6,464.41' 7,467.23' 7,472.93' 6,912.68' 6,919.55' 7,855.60' 7,861.29' 7,661.01' 7,667.87' 8,336.42' 8,342.08' 8,222.94' 8,229.80' 9,106.81' 9,112.52' 8,581.47' 8,588.34' 9,862.02' 9,867.72' 9,469.75' 9,476.64' 11,053.43' 11,059.23' ro 10,308.68' 10,315.58' 11337.00' 11342.70' 10,526.22' 10,533.07' 12,262.02' 12.267.78' ' 11,463.84' 11,470.73' 11,939.57' 11,946.44' 12.382.70' 12,389.58' 4 9-5/8"shoe @ * 4, , : ,,A 5,995' p� (� .-14, 7 91i W .. NININ 5-1/2"shot @_ 6 12,500' R,.. N10 „ N i( N ® X11MM 1 PBTD=12,500'MD/4,197'TVD TD=12,500'MD/4,197'TVD Max Deviation:94.94° Updated by CJD 9/29/15 • 0 Milne Point Unit Well: MPL-49 . iti PTD:215-099 PROPOSED API: 50-029-23545-00-00 Hibor)Alaska,TLC RKB:28' CASING DETAIL /1 Size Type Wt Grade Conn. ID Top Btm 20'� �`0 - r _.41. 20" Conductor 78.6 A-53 Weld 19.25" Surf 110' 1 '' 9-5/8" Surf.Csg 40 L-80 TC II 8.835" Surf 5,955' 5-1/2" Prod Liner 17 L-80 DWC/C HT 4.892" 5,780' 12,500' *,s r TUBING DETAIL t. 3-1/2" Tubing 9.2 L-80 EUE 8rd 2.992" Surf ±5,780' t' • .,, 2-7/8" Tubing 6.5 L-80 EUE 8rd 2.441 ±5,790' ±7,154' N. ie""itt, CASING DETAIL 3� '� No. Item Top MD ID OD 1 Tubing Hanger 28.42' 2 X Nipple ±2,093' 2.813" 4.493" 43 Stage Tool—ES Cementer 2,262' 8.618" 9.625" +r! 1 4 GLM w/sheer valve set @ 2500 psi ±2,975' 2.920" 4.500" 1 5 3-1/2"HALAutoFill sub ±5,750' 2.880" 4.910" 0,' *,f1 6 Liner Top Packer 5,780' 5.000" 6.672" 1 447 7"x 3-1/2"x 2-7/8"Triple connect sub ±5,780' 4.860" 7.670" 8 Tie back seal stem(4 seals) ±5,780' 3.000" 4.760" 9 Injection Control Device(ICD)(12 Total) See Below 4.675" 6.500" 10 Swell Packer(9 Total—See Detail Below) See Below 4.892" 8.000" 11 5-1/2"x 2-7/8"13Cr-80 PHL Packer ±7,092' 3.850" 8.450" aw 12 2-7/8"Magnum 10K Ceramic Shear Disk ±7,154' 2.441" 3.668" ICD DETAIL SWELL PACKER DETAIL ;i kl Top(MD) Btm(MD) Top(MD) Btm(MD) " 5,995.77' 6,002.63' 6,146.10' 6,151.78' 7 6,457.55' 6,464.41' 7,467.23' 7,472.93' 6,912.68' 6,919.55' 7,855.60' 7,861.29' rii 7,661.01' 7,667.87'iii 8,336.42' 8,342.08' 8,222.94' 8,229.80' 9,106.81' 9,112.52' 8,581.47' 8,588.34' i � ,� 9,862.02' 9,867.72' *, 9,469.75' 9,476.64' 11,053.43' 11,059.23' 10,308.68' 10,315.58' 11,737.00' 11,742.70' OA 44 10,526.22' 10,533.07' 12,262.02' 12.267.78' 11,463.84' 11,470.73' 11,939.57' 11,946.44' A.g1 12.382.70' 12,389.58' 9-5/8"shoe @ 1 .'' 1 5 995' :t1"' Ait, Vii_ `,;° 9 10 1 1 1 .. 6 ®� 11 3�Iz 5 7 tom. ♦ 1.11 = 5-1/2"shoe 7814 8 12 12,500' *tams s r /// . v V PBTD=12,500'MD/4,197'TVD TD=12,500'MD/4,197'TVD Max Deviation:94.94° Revised by TDF 2/26/2018 • Milne Point ASR Rig 1 BOPE Ira, r1, ,%lo«an,1.1.4 2018 11 " BOPE Stripping Head ( 1 4.48' ydri• I G 11" - 5000 111 ISI ISI If lel 11111j1111 III III i C I -U .'IE 4.54' o � VBR or Pipe Rams sill 11"- 5000 -�� �� —d Blind • 111 111 111111 111 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves .(61) - 2.00' friTinia-Thrtt 1-4 ; 0 '111011 Manual ' Manual Manual HCR Updated 1/05/2018 . ! • WELL MPL-49 DATE 2-14-18 111 Hilcorp Alaska, LLC Swab valve Seaboard Tree Cap. Otis style, 5%" Model 510, 3 1/8" 5K, FE,DD ACME 3 1/8" 5K, FE,DD L-U I I, L U PN B15753-000 PN 564670-WD1 SN H456279 SN H455723 �0 CO,` 0 ° 0 ' ®G 'i Wing valve Seaboard Model 510, 3 1/8" 5K, FE,DD L-U PN 564670-WD1 SN H455721 ,,J ©� Ui o,,0 00 SSV valve Seaboard Model _ii® 00 510,3 1/8" 5K, FE,DD L-U ®0 00 PN 564670-OM1 SN H455724 E 3 ='i Master valve Seaboard Model 04, -4 510, 31/8" 5K, FE,DDL-U PN 564670-WD1 Tbg Hgr,Seaboard SM- �"' "' SN H455722 E-CL 11 x 3%" EUE BOX WI, _ API 11" 5K top and bottom, 3" "H" BPV,ported for lea 3/ r. il ,,4 � I •• �O. 11 8" Control line,w/3' o� � ` pup L-U,DD-NL, j ��� PN W12231-001 = ii API 16%" 3K Csg Hgr, Seaboard _ SM-B-22 11 x 10.5-4 rii".. - c Stub Acme top x 9 5/8" DWC BOX bottom, w/ I 111 3' pup ini MI LU,DD-NL PN W11840-001 SN • • V = O r d • o • N , '- w v • .. oN p o w- -o > a) Q a w o0 ✓ N W 0 a • �O �O p 0 > O J eq n a) 1 �. 10 M • i, a a 2 2 I- 2 I- 'C N } 'o 2 a) •c c ax) ax) C4 rk CL CL Q_ U 4a rn - 0) aa) 11 'T Q Q cn N1 N1 c c Q Q Q Q Q Q OJ b O Q �- �6 J J t + a) a) c� c� co a a U) v) a) 0) CO I I (n Cl) Cr) Cl) Cr) CO O) � 0 m LL LL .>- co co ix Q LL LL LL LL LL LL v 6 aa) a' ai ai v v E E Q Q T v v v v .7 co Z j N- E J J Q i QCC J J J J J J (1) O. s a s a a a a ') c o c m 2 of rn rn ca ca 2222F--- a) c N X d a o_ d a o. o. o. 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V I— I o E H m 1.0m o 5� N Nes C /G� a) 0 W Z ao c O I— E 7 _ >, 7 L' f0 CO W CO ° N c E'p 0 Z Q J C \ co 1141 I— r2 O U N Q 6a O CO Z Eo ` >, 1 £ 0 o 2 ° II o z 1 0 0 O) C N N O to V 'E } O 11 o a i- D c 5, O m G F- WE a I O in 3 N N W C N N d o C N _ > N F2 1x ti d E Z N ct aA W CO CL 277 0 113 N CI Lcs d Z Q O CO Q O O w c C U '� U J '� O .2- CP N l0 („) w 0 x a 7 o a Q@ E Q °o a - E o O E o E E Q a 3 z 0o a 11)0 0 0 a o 0 0 • Guhl, Meredith D (DOA) From: Maile Sweigart <msweigart@hilcorp.com> Sent: Monday, May 02, 2016 9:10 AM To: Guhl, Meredith D (DOA); Luke Keller Cc: Bettis, Patricia K(DOA); Kevin Eastham Subject: RE: MPU SB L-49, PTD 215-099, PDF Survey Incorrect Attachments: MPL-49 - Definitive Survey.pdf Good morning, Meredith- I have attached the updated survey for MPL-49 that I just received from Halliburton. I spot-checked it to make sure that it matched the text file. Sorry again about the inconvenience. Please let me know if you have any questions, or need anything else. Have a great day! Maile Maile (MY*lei) Sweigart Office: 907.777.8473 I Cell: 907.903.1858 msweigart@hilcorp.com From: Maile Sweigart Sent: Thursday, April 28, 2016 4:00 PM To: 'Guhl, Meredith D (DOA)'; Luke Keller Cc: Bettis, Patricia K (DOA) Subject: RE: MPU SB L-49, PTD 215-099, PDF Survey Incorrect Hi Meredith- Sorry for the inconvenience! I'll contact Halliburton about this now. Have a good evening, Maile Maile (MY*lei) Sweigart Office: 907.777.8473 I Cell: 907.903.1858 msweigart@hilcorp.com From: Guhl, Meredith D (DOA) [mailto:meredith.guhl(aalaska.gov] Sent: Thursday, April 28, 2016 3:40 PM To: Maile Sweigart; Luke Keller Cc: Bettis, Patricia K (DOA) Subject: MPU SB L-49, PTD 215-099, PDF Survey Incorrect Maile, Attached is the PDF version of the directional survey received for MPU SB L-49, PTD 215-099.The same survey in paper format was attached to the 10-407 form. As part of the compliance review I load the survey into a well data program. When I loaded the survey I discovered that the PDF version of the survey provided is incorrect.As you can see,on the text file attached,the N/S offset and�he E/W offset for the BHL location differ AI the text file. My well data program matches the text file. Please have Halliburton re-run the PDF version and email me the corrected version. I will replace the incorrect version. Please send the new survey by May 6, 2016. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W.7th Ave,Suite 100,Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 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 Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 2 . • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Friday,October 09,2015 Jim Regg IG �Il� P.I.Supervisor l' 1 SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC L-49 FROM: Jeff Jones MILNE PT UNIT SB L-49 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J6 -- NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT SB L-49 API Well Number 50-029-23545-00-00 Inspector Name: Jeff Jones Permit Number: 215-099-0 Inspection Date: 9/29/2015 Insp Num: mitJJl51005105215 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well L-49 -.__ Type Inj w-TVD 4156 • Tubing 265 .I 269, j 275 - 278 PTD 2150990 - Type Test SPT Test psi 1500 IA 258 1813 • 1762 , 1747- Interval INITAL _ - 1P/F P V OA 0 1 _ 2 I 2 - Notes: 1 well inspected,no exceptions noted. ��,,�� 4+4G it - (D IJ J W 'V.I.:0-7 C. 0 6irec4-zi i '-t" Friday,October 09,2015 Page 1 of 1 Milne Point Unit . H • • Well: MPL 49 . PTD:215-099 SCHEMATIC API: 50-029-23545-00-00 liacorp:5Ia..1e.LLA RKB:28' CASING DETAIL 10 `°_ l 71i1 Size Type Wt Grade Conn. ID Top Btm 20" Conductor 84 X-56 Weld 15.010 Surf 110' 14 9-5/8" Surf. Csg 40 L-80 IC II 9.625" Surf 5,955' 5-1/2" Prod Liner 29.7 L-80 DWC/C HT 4.892" 5,780' 12,500' g TUBING DETAIL k.y, 3-1/2" Tubing 9.2 L-80 EUE 8rd 2.992" Surf 5,814' At ae JEWELRY DETAIL :', j No. Item Top MD Btm MD ID OD 3 1 Tubing Hanger 28.42' 28.84' " 2 X Nipple 2,093' 2,095' 2.813" 4.493" 3 Stage Tool—ES Cementer 2,262' 2,266' 8.618" 9.625" fr4 GLM w/sheer valve set @ 2500 psi 2,975' 2,984' 2.920" 4.500" 4, lokm .1... _. 5PHL Packer 5,584' 5,592' 3.850" 8.450" °it 16 6 . Ratcheting Muleshoe 5,812' 5,814 3.000" 4.760" za 7 Liner Top Packer 5,780' 5,801 5.000" 6.672" a ' 8 7"Pup&7"x 5-1/2"XO 5,801' 5,809' 4.860" 7.670" 9 Injection Control Device(ICD)(12 Total) See Below See Below 4.675" 6.500" 10 Swell Packer(9 Total—See Detail Below) See Below See Below 4.892" 8.000" . f ICD DETAIL SWELL PACKER DETAIL ; Top(MD) Btm(MD) Top(MD) Btm(MD) 0 5,995.77' 6,002.63' 6,146.10' 6,151.78' 6,457.55' 6,464.41' 7,467.23' 7,472.93' 6,912.68' 6,919.55' 7,855.60' 7,861.29' 7,661.01' 7,667.87' 8,336.42' 8,342.08' '° 8,222.94' 8,229.80' 9,106.81' 9,112.52' 8,588.34' 9,862.02' 9,867.72' 9,469.75' 9,476.64' 11,053.43' 11,059.23' 1410,308.68' 10,315.58' 11,737.00' 11,742.70' 1 10,526.22' 10,533.07' 12,262.02' 12.267.78' 11,463.84' 11,470.73' 11,939.57' 11,946.44' 12.382.70' 12,389.58' ile 9-5/8"shoe @ ` 4' s ',. 5'995' � 4 07.1 7 I 9 1Irl 171 7N N N dpi, 5-1/2"shoe x, 6 12,500' .aC41 1H1 10 1t1 A 46: !t! A1 PBTD=12,500'MD/4,197'TVD TD=12,500'MD/4,197'TVD Max Deviation:'TBD Downhole Proposed Updated by CJD 8/31/15 >J ZIS0�q�W HALL! icJ`'L' DIRECTIONAL SURVEY REPORT Hilcorp Alaska, LLC M P L-49 Milne Point Unit North Slope Borough Alaska USA AK-XX-0902573352 SURVEYS TO 411' MD ARE GYRO SURVEYS. SURVEY AT 789.17' MD HAS AN INTERPOLATED AZIMUTH. ALL MWD SURVEYS ARE SAG, IIFR AND MSA CORRECTED. FINAL SURVEY IS PROJECTED TO TD. niglajM: 17111'': Vertical Vertical 4 Y'. Direction Depth Latitude Departure Section ,1 ��'IDogleg' 14e (degfe11.degrees) (feet) (feet) (feet) f:a .,.,,.degl e 30.00 0.00 0.00 30.00 0.00 N 0.00 E 0.00 TIE-IN 75.00 0.19 153.70 75.00 0.07 S 0.03 E 0.07 0.42 137.00 0.26 117.16 137.00 0.22 S 0.20 E 0.30 0.25 226.00 0.38 71.72 226.00 0.22 S 0.66 E 0.62 0.30 320.00 0.45 62.52 320.00 0.05 N 1.29 E 0.85 0.10 411.00 0.48 54.18 410.99 0.43 N 1.91 E 0.99 0.08 �'4',trt 505.69 0.77 25.57 505.68 1.24 N 2.51 E 0.81 0.44 4 601.55 0.46 42.04 601.54 2.11 N 3.05 E 0.54 0.37 ', 693.12 0.52 44.51 693.10 2.68 N 3.59 E 0.50 0.06 789.17 0.90 155.25 789.15' 2.30 N 4.21 E 1.20 1.24 879.93 4.88 160.57 879.77 1.99 S 5.79 E 5.41 4.39 975.47 5.97 161.88 974.88 10.54 S 8.69 E 13.63 1.15 1071.30 8.22 170.04 1069.97 22.03 S 11.42 E 23.88 2.57 1165.83 10.24 176.49 1163.27 37.08 S 13.11 E 36.01 2.40 1260.38 12.53 194.22 1255.99 55.43 S 11.10 E 48.02 4.40 y 1355.69 17.70 207.95 1347.99 78.28 S 1.76 E 58.29 6.56 ., , 1449.26 20.78 211.80 1436.33 104.96 S 13.66 W 67.20 3.56 1543.07 20.61 212.27 1524.09 133.06 S 31.25 W 75.67 0.25 1638.10 24.63 218.35 1611.80 162.75 S 52.47 W 82.80 4.89 1732.96 30.00 221.16 1696.05 196.14 S80.37 W 88.06 5.81 1825.31 32.22 220.17 1775.12 232.34 S 111.45 W 93.20 2.47 1921.81 34.26 219.05 1855.82 273.10 S 145.16 W 99.86 2.21 2016.13 38.12 217.76 1931.93 316.75 S 179.73 W 108.05 4.17 2109.24 39.45 219.23 2004.51 362.38 S 216.04 W 116.49 1.74 2205.10 42.02 220.59 2077.14 410.35 S 256.19 W 124.01 2.83 F.= 2298.98 41.79 219.30 2147.01 458.42 S 296.44 W 131.52 0.95 2394.22 43.02 217.57 2217.33 508.73 S 336.36 W 140.91 1.78 2489.27 42.45 217.88 2287.14 559.75 S 375.82 W 151.12 0.65 2583.17 41.80 218.43 - 2356.79 609.28 S 414.73 W 160.62 0.79 �' h 2677.03 42.11 218.76 2426.59 658.32 S 453.87 W 169.61 0.40 2771.83 41.88 218.45 2497.05 707.88 S 493.45 W 178.68 0.32 2866.59 40.99 220.11 2568.10 756.42 S 533.14 W 186.93 1.49 2960.40 41.88 217.74 2638.43 804.72 S 572.13 W 195.47 1.93 3054.98 42.26 216.37 2708.64 855.30 S 610.31 W 206.23 1.05 3149.16 42.36 216.14 2778.29 906.42 S 647.81 W 217.87 0.20 ;;--- 3243.21 42.40 215.75 2847.76 957.74 S 685.02 W 229.84 0.28 3338.51 42.35 215.99 2918.16 1009.79 S 722.66 W 242.05 0.18 u 3432.52 42.37 215.70 2987.63 1061.14 S 759.75 W254.12 0.21 3526.80 41.45 214.66 3057.80 1112.61 S 796.03 W 266.83 1.22 1. 3621.10 41.69 208.68 3128.37 1165.81 S 828.85 W 283.19 4.21 3716.29 43.10 201.17 3198.71 1223.95 S 855.80 W 307.15 5.52 3809.90 42.86 197.18 3267.21 1284.20 S 876.76 W 336.75 2.92 3904.63 42.93 190.84 3336.65 1346.69 S 892.35 W 371.66 4.55 3998.24 43.80 183.77 3404.74 1410.37 S 900.48 W 412.54 5.27 4093.42 42.21 176.41 3474.39 1475.19 S 900.64 W 459.71 5.53 4187.22 43.06 168.46 3543.45 1538.06 S 892.26 W 511.30 5.81 s� 4281.79 45.26 163.27 3611.31 1601.88 S 876.13 W 568.88 4.47 4376.25 46.68 158.82 3676.98 1666.07 S 854.05 W 630.80 3.71 4470.87 50.02 153.30 3739.88 1730.60 S 825.30 W 697.53 5.61 1 4563.56 52.17 150.49 3798.09 1794.20 S 791.30 W 767.17 3.31 4659.45 53.49 148.14 3856.03 1859.89 S 752.31 W 841.77 2.39 4754.05 57.47 143.80 3909.65 1924.41 S 708.65 W 918.69 5.65 4i54/.3U OU.4y 14 Luz 3yO/./U '1 yt3t3.Vy J OOU.4U VV yyu.14 3.d/ 4942.42 66.72 87 3999.99 2052.65 S 6 ^ W 1083.19 8.09 5036.09 67.88 .39 4036.14 2114.94 S 5 W 1169.59 1.91 5131.68 71.14 132.88 4069.60 2177.26 S 480.77 W 1259.01 4.20 ' 5225.31 75.59 130.09 4096.41 2236.65 S 413.57-W 1348.30 5.54 5319.98 80.93 128.16- 4115.67 2295.10 S 341.68 W 1440.11 5.99 5413.89 82.12 123.33 4129.51 2349.34 S 266.32 W 1531.23 5.24 5509.90- 80.96 120.60 4143.63 2399.61 S 185.76 W 1623.01 3.06 ��� 5603.43 4 79.76 120.34 4159.30 2446.37 S 106.29 W 1711.48 1.31 5697.63 82.56 119.91 4173.77 2493.08 S 25.79 W 1800.63 3.01 5791.89 85.47 119.52 4183.60 2539.54 S 55.62E 1890.21 3.11 5886.03 84.94 119.77 4191.47 2585.94 S 137.15E 1979.83 0.62 5923.52 83.46 119.57 4195.26 2604.41 S 169.56E 2015.47 3.98 ��� a1C �� � I CU-' D �f ( w""te _ '' ba _ '[e 'I Tr -511V-TWY4,11505 '6 T i i"i 4I �" A .. „,,,,;,..4-14 4144.T..i*Yfitt.4.Q.0 5j:,,e401?..-...::-.7'''i4N11:qi.; �m • ter, P*NT P •T. ;' M , N , :k HORIZON DISPLACEMENT IS RELATIVE'TO TIME'WELL H ar-So -1:41i ViitAijyligraT4Etil.'4;9,V1,1-4'','.-,-,,A., iORIZONTAL DISPLACEMENT(CLOSURE)AT 5923.52 FES f ' IS 2609.92 FEET ALONG 176.28 DEGREES(TRUE riv,,,,,.:,-;.,::..A a�'� % `' SURVEYS TO 411'MD ARE GYRO SURVEYS. ' URVEY AT 789.17'MD HAS AN INTERPOLATED AZIMUTH -_ '� ��� ' '''° �' MWD SURVEYS ARE SAG,IIFR AND MSA CORRECTED, ,�. FINAL SURVEY IS PROJECTED TO TD. Z4 5 66/611) Vrt Date Printed:24 July 2015 Mi L_4- PG qy RECEIVED III 5 OCT 072015 STATE OF ALASKA OG^� ALASKA OIL AND GAS CONSERVATION COMMISSION V WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a.Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ lb.Well Class: 20AAC 25.105 2OAAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ 0 WAGE WDSPL❑ No.of Completions: _1 Service E Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp.,or 14. Permit to Drill Number/ Sundry: Hilcorp Alaska, LLC Aband.: '8/15/2015 • 215-099 3.Address: 7. Date Spudded: 15.API Number: 3800 Centerpoint Drive, Suite 1400 Anchorage,AK 99503 • 7/18/2015 •50-029-23545-00-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 3408'FSL,4695'FEL,Sec 8,T13N, R10E, UM,AK •8/6/2015 • MPL-49 Top of Productive Interval: 9. KB(ft above MSL): •47 17. Field/Pool(s): 773'FSL, 785'FWL, Sec 8,T13N, R10E, UM,AK GL(ft above MSL): .17 Milne Point Field/Schrader Bluff Oil Pool tf Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: $Sfs 3684j' 2624'FNL, 1060'FWL,Sec 16,T13N, R10E, UM,AK .12,500'MD/4,197'TVD ADL 025509(TPH)ADL --(BHL) 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 545185 y- 6031591.2 Zone- 4 .12,500'MD/4,197'TVD N/A TPI: x- 545410.3 y- 6028966.14 Zone- 4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 550997.2 y- 6025605.2 Zone- 4 N/A •1,916'MD/1,851'TVD 5. Directional or Inclination Survey: Yes ❑✓ (attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) • N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to: mud log,spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance,dipmeter,formation tester,temperature, cement evaluation, casing collar locator,jewelry, and perforation record. Acronyms may be used.Attach a separate page if necessary ROP DGR ADR EWR-Phase4 HORIZONAL PRESENTATION DGR ADR EWR-Phase4 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 20" 78.6# A-53 0 80' 0 80' 42" 60 bbls 15.6# None Stg 1 Lead-183 bbls 12# Tail-84 bbls 15.8# 30 bbls 9-5/8" 40# L-80 0 5,955' 0 4,198' 12-1/4" Stg 2 Lead 303 bbls 11.1# Tail-70 bbls 15.8# 240 bbls 5-1/2" 17# L-80 5,780' 12,500' 4,180' 4,197' 8-1/2" Cmntess Linerw Swell Pkrs 24.Open to production or injection? Yes Z No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3-1/2" 5,814' 5,584'MD/4,156'TVD 5,780'- 12,500'MD Cementless Liner 9 Water Swell Packers 26.ACID, FRACTURE, CEMENT SQUEEZE, ETC. (9)Water Swell Packers Was hydraulic fracturing used during completion? Yes ❑ No E (12) Injection Control Devices Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED *See Schematic for further detail* 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: N/A N/A Test Period —4 N/A N/A N/A N/A N/A Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. IN/A N/A 24-Hour Rate . N/A N/A N/A N/A tr.13-Ut 4IVO I1.b 1)14 9I;•7li(' RBDMS OCT 01 2015 cl Form 10-407 Revised 5/2015 CONTINUED ON PAGE Z� Submit ORIGINIAL onl .V// yl� 28.CORE DATA Conventional Os): Yes ❑ No ❑✓ Sidewall CoreSes ❑ No E 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 0 Permafrost-Top Surface Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1,916' 1,851' Attach separate pages to this form, if needed, and submit detailed test SV1 2,295' 2,144' information, including reports, per 20 AAC 25.071. Ugnu MA 4,473' 3,741' Schrader Bluff NA 4,978' 4,014' Schrader Bluff OA 5,878' 4,191' Formation at total depth: Schrader Bluff OA 31. List of Attachments: Wellbore Schematic, Daily Drilling&Completions Reports, Definitive Driectional Surveys, Days vs Depth Graph, MW vs TVD Graph,Casing and Cementing Reports Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Luke Keller Email: Ikeller(a�hilcorp.com Printed Name: Luke Keller / / Title: Drilling Engineer Signature: c_/ Phone: 907-777-8395 Date: I d /7 -2 /_5"--- INSTRUCTIONS S'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 1b: Well Class-Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection, Salt Water Disposal,Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion, suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump, Submersible,Water Injection, Gas Injection,Shut-in, or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs,and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2015 Submit ORIGINAL Only Milne Point Unit • • Well: MPL-49 PTD:215-099 SCHEMATIC API: 50-029-23545-00-00 Hilcorp Alaska,LLC RKB:28' CASING DETAIL \--,/1Size Type Wt Grade Conn. ID Top Btm 20"J 20" Conductor 78.6 A-53 Weld 19.25" Surf 110' ' 9-5/8" Surf.Csg 40 L-80 TC II 8.835" Surf 5,955' 5-1/2" Prod Liner 17 L-80 DWC/C HT 4.892" 5,780' 12,500' TUBING DETAIL vv 3-1/2" Tubing 9.2 L-80 EUE 8rd 2.992" Surf 5,814' 2 JEWELRY DETAIL No. Item Top MD Btm MD ID OD 3 O 1 Tubing Hanger 28.42' 28.84' " 2 X Nipple 2,093' 2,095' 2.813" 4.493" 3 Stage Tool—ES Cementer 2,262' 2,266' 8.618" 9.625" 4 4 GLM w/sheer valve set @ 2500 psi 2,975' 2,984' 2.920" 4.500" . 5 PHL Packer 5,584' 5,592' 3.850" 8.450" 6 Ratcheting Muleshoe 5,812' 5,814 3.000" 4.760" 7 Liner Top Packer 5,780' 5,801 5.000" 6.672" 8 7"Pup&7"x 5-1/2"XO 5,801' 5,809' 4.860" 7.670" 9 Injection Control Device(ICD)(12 Total) See Below See Below 4.675" 6.500" 10 Swell Packer(9 Total—See Detail Below) See Below See Below 4.892" 8.000" ICD DETAIL SWELL PACKER DETAIL Top(MD) Btm(MD) Top(MD) Btm(MD) 5,995.77' 6,002.63' 6,146.10' 6,151.78' 6,457.55' 6,464.41' 7,467.23' 7,472.93' i 4 . 6,912.68' 6,919.55' 7,855.60' 7,861.29' kl 7,661.01' 7,667.87' 8,336.42' 8,342.08' 8,222.94' 8,229.80' 9,106.81' 9,112.52' 8,581.47' 8,588.34' 9,862.02' 9,867.72' 9,469.75' 9,476.64' 11,053.43' 11,059.23' 10,308.68' 10,315.58' 11,737.00' 11,742.70' 10,526.22' 10,533.07' 12,262.02' 12.267.78' 11,463.84' 11,470.73' 11,939.57' 11,946.44' 12.382.70' 12,389.58' • • 9-5/8"shoe @ , 5,995' N -47 9 N c N v P Ii N `�c 5-1/2"shot 6 12,500' r . ® I Nio N I N N I 1 PBTD=12,500'MD/4,197'TVD TD=12,500'MD/4,197'TVD Max Deviation:94.94° Updated by CJD 9/29/15 • Hilcorp Energy Company Composite Report Well Name: MP L-49 Field: North Slope County/State: ,Alaska Location(LAT/LONG): Elevation(RKB): API#: Spud Date: 7/18/2015 Job Name: 1511127D MP L-49 Drilling Contractor AFE#: 1511127D AFE$: $4,137,342 Rpt Date Activity Date Ops Summary 6/28/2015 6/27/2015 Hit Marker pipe for barried cable.Move over 10'from last ettempt for drilling the cellar. Drill 8X8X4'Cellar. Attempt to drill 42"hole for conductor.Unable to drill due to influx of surface;water.Hole filling up with water.R/D Peak drill&crane. Prep to mob out conductor driver.Set up 20 to be delivered on 6-29-15.Set up to born eqiupment out to on 6-30-15.;7-1-15 Drill conductor,Set and level insulated conductor,Pumped 10 bbls cement,WOC,Pumped cement to surface,clean cement equipment&demobe.Pull 5'casing in prep for cellar 7/15/2015 7/14/2015 Continue shaker upgrade.Work on flow trough.GCI installing phones and internet to MWD,Mud&Geo Shacks.Add one more work station in the drilling office.,Move rig Expediter from Milne Point to Nordic camp office.Pre spud meeting with both drilling crews and drilling support.Drilling engineer&Enviromental specialist on location for prespud. 7/16/2015 7/15/2015 Nortic 3 maintenance and shaker installation. 7/17/2015 7/16/2015 Nortic 3 accepted on the MP L-49 @ 12:00 pm 7/16/2015;Move rig over L-49. Spot and level.;Weld 4"casing valves on conductor,set cutting box. Stage Sperry& Geo shack and R/U electrical lines.Rig up vent line on diverter system and reinstall knife valve,install koomey lines.;Continue house keeping,prep location to spot auxiliary tanks(Mud storage)Function test Diverter. Load pipeshed with 5"drill pipe. Spot aux.water tank.;lnstall wear ring;P/U 5"drill pipe. 7/18/2015 7/17/2015 Dress out topdrive for 5"pipe. Re Spot fresh water tank. R/U 3"feed hoses to rig. Run hoses to Aux Mud tanks.Finish berming mud tanks. Cut&weld on well head on L-46.;P/U 24 stand of 5"DP&stand back in the derrick.Not Torqued. State man on location.Perform diverter function test with knife valve opening @ 5 sec&annular closing @ 35 sec.;Attempt draw down measurements. Back up air pumps would not kick on. Test gas alarms. Service air pumps. Pumps working good.;3050 psi starting pressure, 1650 psi after annular shut in, 200 increase,20 sec, Full Pressure,141 sec. Average N2 2050 in 4 bottles.;PJSM- install wear ring.;Diverter Drill and rig Evacuation.Wth all personnel on tour,(All personnel accounted for,drill time was 10 min);Sperry Directional/MWD calibrated block height for the logging tools(MWD).;PJSM; Continue picking up 5"drill pipe out of the pipe shed&rack back in the derrick.;BHA: P/U 5"HWDP with Jars and rack back in derrick.;Slip&cut off drilling line.;Service traveling blocks and drawworks and adjust tq on top drive.;R/U Gyro data for standyby tool face data 7/19/2015 7/18/2015 R/U Haliburton gyro data. Hang sheave and tools in the demck.;PJSM,P/U 12.25 bit,8"Motor,Stab,XO,1 stand of HWDP. RIH&establish circ with fresh water. Good.Tag @ 109'. Drill cmt&shoe T/119'. Pull back into the shoe&circ out sand @ 13 bpm.;Wash sand&drill shoe @ 40 rpm 300-560 gpm. up/dn/rot 50k.;Pull up in to shoe&displace to 8.8 ppg spud mud. Dump all water&cmt. Cuttings showing sheen. Send to G&I.;Diverter drill with all hands on tour. Full muster @ camp shop. All hands accounted for. Discuss lessons learned ways to get better.;M/U drilling BHA#1.12.25 Tricone bit, 8"Motor,12.125 Stab,DM Collar,HOC Collar,EWR Collar,PWD Collar,HCIM Collar,HOC Collar,UBHO Collar, XO&one stand of HWDP.;Drlg.12.25"Surface Section: F/119'to 459' Rot:wob 10K,550 gpm-1045 psi,50/100psi diff,190/250 ft/hr ROP.(Drilling with HWDP until enough hole is made to trip in with the smart tools).;Continue Drlg. 12.25"Surface Section F/459'to 738'Rot:wob 10K,550 gpm-1210 psi,50/200psi diff,190/250 ft/hr ROP.ECD 9.3 ppg.;Circ.hole clean for Gyro and short trip.;After running a gyro log broke circ. to ensure that we are free(no packoff no fill)Started short trip out of the hole on elevators(NO GO SWAB)pumped out of the hole 450 gpms 1050 psi 9.2 ECD.;Tripped back in the hole with no problems,but had a problem with the elevator latching.;Ddg.12.25"Surface Section: F/738' to 927'Sliding:wob 6K,550 gpm-1280 psi,50/100psi diff,125/210fUhr ROP.Rotating:wob 10K,550gpm-psi 1260. RPM 40 TQ 6K ECD 9.55 ppg.;;Hauled 81 bbls cuttings to G&I Total cuttings hauled=81 bbls Hauled 0 bbls Class II fluid to CRP Total Class II fluid hauled=Obbls Hauled Obbls Cement to G&I Cumulative=0 bbls;Distance to Plan @ 4:00am: 4.42'High .68'Right ROT Hrs.4.35 SLD Hrs.0 7/20/2015 7/19/2015 Drilling Ahead F/927'T/1278'. UP/DN 95/92K, 575 GPM @ 1330 psi 15-25 WOB,40 RPM. MW 9.1 ou Slide Depths,970-1005/1041-1116'/1136'-1278'. 3 Good Surveys in a row.R/D Halliburton Gyro.;MW 9.1 in&9.3 out vis 115. 9.6 ECD ppg. Drilling Clay&clay stone.;Drilling Ahead F/1278'T/2061' UP/DN 107/100K, 540 GPM @ 1240 psi 15-25 WOB,40-80 RPM. MW 9.1 ou Slide Depths,.1305'-1355/1373'-14001 1435-1480'/1525-1585/1589'-1637'/1657'-1741;1761'-1778'/1778'-1872'/1872'-18921 1930'-2025/ 2040'- 2061'.,Circ.hole clean @ 470 Gpm 1000psi. Rot.@ 80rpm Tq.5k.;Mad-Pass log from 2059'to 1928 @ 100 to 150 fph.pumping @ 530 gpm.1000psi with 115k up weight.;POH F/1928'T/741'P/U wt.118k(No significant over pull seen throughout trip out);Rig Service on top drive(grease and calibrate rpms).;TIH F/741' T/1270'encountered tight spot 1270'brought pumps up to 450 gpm;orient tool high side;turn pumps off s/o(no problems)continued TIH to 2061'(no problems no fill).,Pump a con-dent sweep with walnut plug as a flag brought back 10%more cuttings.;Drilling Ahead F/2061' T/2343' UP/DN 120/105K, 540 GPM @ 1140 psi 15-25 WOB,80 RPM. MW 9.1+out;;Hauled 0 bbls of Mud to CRP;Total Hauled 0 bbls. Hauled 254 bbls of Cuttings to G&I; Total Hauled 335 bbls Hauled 575 bbls of H2O F/Lake;Total Hauled 1075 bbls.;Distance to Plan: 24.22'Low 11.77'Right Total Rot Hrs.2.67 Total Sliding Hrs.9.05 7/21/2015 7/20/2015 Drilling Ahead F/2343' T/• • 567 @ 95FPH Average UP/DN 120/105K, 550 GPM @ 1200 psi 5-20 WOB,80 RPM. MW 9.3 in 9.4 out Slides-2365-2389', 2627-2652', 2722'-2737',;Drilling Ahead F/2900' T/3574' 672'@ 96 FPH Average UP/DN 120/105K, 550 GPM @ 1400psi 10-20 WOB,80 RPM. MW 9.3 in 9.4 out Slides-2910'-2940', 3005'-3020', 3477'-3492,.;Circ.Sweep @ 530 gpm 80 rpm 1100 psi.Brought back 10%more cuttings(sweep came back @ calculated strokes);POH on elevators F/3,574'to 2,180' encountered tight spot @ 2,180+/-,(30k over)attempted to work through(No Go) made up top drive and brought pumps up to 500 gpm to check orientation of the:motor(Good). Decision was made to back ream and open up the hole pumping @ 500 gpm 40 rpms,after making several passes,shut down pumps and pulled drill string through:with success.Continued POH F/2,180 to 1,210'(No Problems);Rig Service on drawworks and top drive.;TIH F/1,120'to 2,256'encountered tight spot 2,256'+/-,made up top drive;brought pumps up to 500 gpm orient motor to high side,turned pumps off slacked off through tight spot(No Problem).;Continued TIH to 3,479'(No Problems)Kelly up,till pipe and wash last 95'to bottom.;Drilling Ahead F/3574'T/3733' 159'@ 64 FPH Average UP/DN 153/110K, 550 GPM @ 1380psi 10-20 WOB,80 RPM. MW 9.3 in 9.4 out Slides-;;Hauled 555bb1s of Mud to Pad 3;Total Hauled 555 bbls. Hauled 333 bbls of Cuttings to G&I; Total Hauled 668 bbls Hauled 1425 bbls of H2O F/Lake;Total Hauled 2500 bbls.;Distance to Plan:23.35'High 2.31'Left Total Sliding Hrs.1.99 Total Rot.Hrs.8.33 7/22/2015 7/21/2015 Drilling Ahead F/3733' T/4529' 786'@ 65 FPH Average UP/DN ROT 175/116/145k 510-560 GPM @ 1400psi 10-25 WOB,80 RPM.6-8k TQ MW 9.2 in 9.3 out;Pump high vis sweep,circ hole clean, 1.5 BTM UP.No increase in cuttings. Monitor well. Static.;Pooh F/4,519'T/3,470'no problems during the trip to report.;Rig Service-Greased swivel packing and crown cluster. (After service was complete,trip tank showed a half barrel loss which calculated out to be 1 hr.static loss rate);TIH F/3,470'T/4,421'It was calculated that we lost 4 bbl.during the trip in the whole.;;Washed F/4,421 T/4,529'Drilling Ahead F/4529' T/4787' 258'@ 39 FPH Average UP/DN ROT 185/105/135k 510-560 GPM @ 1275psi 10-25 WOB,80 RPM.6-8k TQ MW 9.1+in 9.3 out;;Hauled 0 bbls of Mud to Pad 3;Total Hauled 555 bbls. Hauled 304 bbls of Cuttings to G&I; Total Hauled 972 bbls Hauled 750 bbls of H2O F/L-Pad Lake;Total Hauled 3250 bbls.;Distance to Plan: 36.11'High 10.76'Left Total Rot.Hrs=3.23 Total Sliding Hrs=7.54 7/23/2015 7/22/2015 Drilling Ahead F/4787'T/4958' 171'@ 38 FPH Average UP/DN ROT 180/105/140 550-600 GPM @ 1400psi 10-25 WOB,80 RPM.6-8k TQ MW 9.1+in 9.2 out;Ream F/4892'T/4958'. Slide showing 10 deg dog leg. Ream out&drop to 8 deg.;Drilling Ahead F/4958'T/5250' 292'@ 45 FPH Average UP/DN ROT 180/105/140 550-600 GPM @ 1900psi 10-25 WOB,80 RPM.6-8k TQ MW 9.1+in 9.2 out;At 5250',pull off bottom;shut down#2 mud pump and circ.with#1 pumping @ 300 gpm 720 psi.Wth no rotation;troubleshoot mud pump#2 found out valve in pod#3 was stuck.;Continue Drilling Ahead F/5250'T5625 375 @ 40 FPH Average ROP UP/DN ROT 180/105/135 550-600 GPM @ 1925psi 10-25 WOB,80 RPM.10-12k TQ MW 9.2+in 9.3+out;Hauled 0 bbls of Mud to Pad 3;Total Hauled 555 bbls. Hauled 289 bbls of Cuttings to G&I; Total Hauled 1261 bbls. Hauled 900 bbls of H2O L-Pad Lake; Total Hauled 4150 bbls.,Hauled 0 bbls of H2O FNern Lake; Total Hauled 1160 bbls. Distance to Plan: 8.42'Low 31.08'Right Total Rot.Hrs.=3.46 Total Sliding Hrs.=10.09 7/24/2015 7/23/2015 Continue Drilling Ahead F T/5868' • 120 @ 20 FPH Average ROP UP/DN ROT 180/115/135 550-600 GPM @ 1925psi 10-25 WOB,80 RPM.10-12k TQ MW 9.2+in 9.3+out;Slides:5648/5692-5742/5786-5868/5880;Continue Drilling Ahead F/5868'T/5970' 102 @ 34 FPH Average ROP UP/DN ROT 170/105/135 550-600 GPM @ 1925psi 10-25 WOB,80 RPM.10-12k TQ MW 9.3 in 9.4out;Circ 20 bbl sweep around.Brought back 50%increase in cuttings.Sweep came back on time.Cleaned up after 1.5 btm up. Circ @ 600 gpm,60 rpm, Monitor well.Static.;POOH on elevators F/5970'T/5240'.Over Pulls,5620/25k 5300'/10K, 5260-5240K 30 K. Pulled in to 3 times @ 5240. Kelly up& orient motor to high side. Pump @ 450 gpm F/5260'T/5178'.;POOH on elevators F/5178'T/4014'(No Problems);Monitor Well(No Flow No Losses)TIH F/4014'T/5933'(No Problems)Fill pipe and washed to bottom 5970'(No Fill);Circ.bottoms up X2,@ 595 GPM 1860 psi.80 RPM @ 5840'(30'off bottom).;Monitor well(no flow/no losses)Pooh F/5840' T/4113'(no problems)pumped dry job;continue POOH T/741'.;Trip Drill.5min 10 sec. LD BHA and rack back HWDP and jars,LD Flex DC,MWD,PWD,Motor and Bit.;;-Hauled 0 bbls of Mud to Pad 3;Total Hauled 555 bbls. -Hauled 331 bbls of Cuttings to G&l; Total Hauled 1592 bbls. -Hauled 600 bbls of H2O F/L-Pad Lake; Total Hauled 4750 bbls;-Hauled 0 bbls of H2O FNern Lake; Total Hauled 1160 bbls. Distance to Plan:15.87'Low 14.89'Right Total Rot Hrs.=5.27 Total Sliding Hrs.=2.55 7/25/2015 7/24/2015 L/D BHA,Bit Grade 4-5-LT-A-E-3/16-BALLED-TD Flush out&drain stack, pull wear bushing&send in to get machine work done per Cameron. clean&clear floor.;P/U Weatherford casing equipment. M/U CRT.R/U power tongs&test.Good.Change to long bails. Rig up false boul. Make dummy run with hanger&landing Joint.Verify landing with Cameron hand.;PJSM,P/U float equipment&test.Good. Bakerloc everthing below joint#1. Halliburton hand on floor to verify baffle adaptor running order. M/U Shoe Joint,FC Joint,Baffle adaptor joint.;P/U 9 5/8 40#L-80 Casing T/4050'. Filling every 5 joint with the CRT.;Circ.B/U easing rate up to 6bpm 450 psi.;Continue TIH with 9 5/8 casing F/4050-T/5930'-Pickup landing Jnt.and hanger and land.;Break circ.one B/U with the CRT @ 2bpm easing rate up to 6bpm beg.psi.875 ending 350psi.while reciprocating pipe P/U 230k S/O 75k;Rig down CRT and install cement head.;Reestablish circ. easing rate up to 6bpm @ 480 psi.pick up 225k slack off 85k.;Hauled 0 bbls of Mud to Pad 3;Total Hauled 555 bbls. Hauled 29 bbls of Cuttings to G&I; Total Hauled 1621 bbls. Hauled 670 bbls of H2O F/L-Pad Lake; Total Hauled 4750 bbls.;Hauled 0 bbls of H2O FNern Lake; Total Hauled 1160 bbls. 7/26/2015 7/25/2015 Circ&condition mud while reciprocate casing. 265K up/115K dn. 6 bpm @ 450 psi. YP not coming down after 4 circulations. Decide to land hanger to help with clean up.;Started to clean up good after one circ.Circ until YP was 24 out. Final circ pressure before shutting down 350 psi.;PJSM,Turn over to Halliburton. Pump 10 bbl water&test lines to 5000 psi. Good. Start pumping mud push. Halliburton having trouble pumping mud push. Swap back to rig pumps& continue;circulating @ 6 bpm. Circ 99 bbl. Halliburon ready.Pump 10.5 ppg mud push slow.Still having trouble pumping. Pump 60 bbl total. Drop bypass plug. Pump lead cmt @ 12#ppg. Pump tail cmt.;Drop closing plug. Displace with 220 bbl mud,80 bbl H2O,144 bbl 9.3 ppg mud. Pump 1/2 calculated shoe track @ 3 bbl. Final circ pressure @ 1150 psi. Shut down&discuss options.;Decide to pump 1 more bbl.Did not bump. Shut down.Check floats.Bled back 1.5 bbl.Floats good. Drop stage tool opening plug. Wait 15 minutes.;Bring pumps on. Pressure starts climbing pressure built to 700 psi&dropped to 450. Shut down&discuss. Decide to bleed off&see if the tool opens.U tube 5 bbl back to the unit.;Decide ES cmt tool is open. Start pump @ 3 bpm Monitoring returns for spacer. Divert to cellar @ 40 bbl away. Finish displacing out cmt to cellar. 30 bbl good cmt returned.;Swap returns back to the pits @ 150 bbl away.;Circ&condition mud @ 6bpm while cleaning up cellar&prepping for second stage.;Second stage cement job:Halliburton pumped 60 bbls of mud push @ 10.5 ppg.followed by 300 bbls by volume calculated of 11.1 ppg lead cement followed by 72 bbl tail cement @ 15.8 ppg.;Pumped lead taking mud weights back to back. Got dyed mud back early. Diverted to diverter box. Getting mud push back @ 10PPG. Got lead cmt back.Swap to tail.;Launch top plug Halliburton displaced w/172 bbls of 9.3 PPG mud&bumped plug 10bbI over from calc. Halliburton pressured up U 2200 psi. No indication of tool shifting.;Bleed off pressure and check U tube. No u tube. Pressure back up to 2200 psi for a couple minuets rock hard.Then pressure fell to 980. Tool may have shifted more.;Pressure back up to 2000 psi.Took 1.5 bbl. Pressure now bleeding off slightly.No flow on the annulus. ES Cementer closed. Bleed off pressure.;Pipe was not reciprocated while pumping cement due to sticky hole landed hanger w/95k w/shoe @ 5955'CIP @ 0100 hrs.;Rig down cement equipment and rig up to set pack-off. 1st Stage Total Lead Returned to surface 30 bbl. 2nd stage Total lead cmt returned to surface 240 bbl by calculated volume. 7/27/2015 7/26/2015 R/D halliburton cmt head.R/D halliburton cmt trucks.Clean up after cmt job.Flush diverter&4"dump lines in the cellar. Run swizzle stick in the stack&flush good.;Load tubing spool in to cellar.Flush out top of hanger.;Pull landing joint and M/U pack off and running tool. Set 9 5/8 packoff&RILDS.;N/U tubing spool. N/D diverter&dump lines. Set diverter TEE&annular back on stump. Test pack off to 3000 psi. Load 5"DS-50.drill pipe in shed.;Continue N/U BOP's and cleaning pits.;Full body test check for leaks(good). Test BOP's annular 250/2500 psi rams&valves 250/3000 psi for 5min each.;;Hauled 0 bbls of Mud to Pad 3;Total Hauled 555 bbls. Hauled 20 bbls of Cuttings to G&I; Total Hauled 1670 bbls. Hauled 790 bbls of H2O F/L-Pad Lake; Total Hauled 6590 bbls.;Hauled 0 bbls of H2O FNern Lake; Total Hauled 1160 bbls. 7/28/2015 7/27/2015 Test BOPE as per AOGC . a fail pass on the Top VBR rams. Blew down all testing equipme /D.Test all gas alarms. BOP test waived witness by Mr.John Crisp with AOGCC @ 15:54 7-26-15.;Perform accumulator drawdown test. 3000 psi starting, 1875 after closer 200 psi increase 19 sec Full Pressure 102 sec N2 4 btl @ 2050 psi.;Service rig change gripper dies.;Set WB with and ID of 10". M/U 8 1/2 cleanout BHA#2.RIH HWDP&P/U 5"DS-50 F/656'T/2200'.;Circ. hole clean with 100bbl.of H2O @ 5bpm-800 psi.easing rate up to 7bpm-FCP 340psi 8.8 ppg in and out.,Rig up and test casing to 3000&hold for 5min to verify that ES cementer is closed(good);Continue RIH tagged cement stringer @ 2239'(5k down)washed and reamed f/2239'-t12261'. Pumping @ 400 gpm 500 psi.80 rpm. Drill the ES cementer up sustaining 5/10k on the bit f/2261'- t/2267'.;Started seeing rubber back @ 2263'-after drilling through we washed and reamed to smooth out the es cementer. Turned pumps off and drift the BHA through(good).;Continue P/U 5"Drillpipe out of the pipeshed&RIH f/2267't/4019'.;Circ and conditon mud pumping at 400 gpms 500psi.40 rpms.(Due to unbalanced mud extra circulation was made).;Continue RIH f/4019' T/5000'.Change saver sub on top drive.;-Hauled 58 bbls to G&I Total Hauled 6375 bbls -Hauled 870 bbls to Pad 3 Total Hauled 1550 bbls -Hauled 350 bbls of H2O F/L-Pad Lake Total Hauled 7610 bbls;-Hauled 0 bbls of H2O FNern Lake Total Hauled 1240 bbls 7/29/2015 7/28/2015 RIH out of the derrick T/5100'.Tag 15k.Went through.Pushing plug.;Wash down T/5200'.Clean.RIH F/5200'T/5673'. Tag hard.Start drilling plug @ 5673'.;Drill closing plug 5673'T/5820'.;Lost rig motor.Rig blacked out.;Continue to drill cement from 5820'to 5857'.60 RPM,5-10K WOB,8-9K TQ,575 gpm,1470 psi. Note: Did see aluminum and rubber @ shakers.;Rig up circulating equipment.CBU and condition mud for casing test.;Pull 1 std,park @ 5754',Line up to pump down DP and Annulus.Purge lines.Close bag and attempt to pressure test casing to 3000 psi.(Pumped 4.7 bbls.Lost 500 psi in 5 min.)Bleed to zero.;Pressure up casing to 3000 psi.(Pumped 5.2 bbls.Lost 1900 psi in 15 min.)Bleed to zero. SICP increased from zero to 200 psi in 5 min.Bleed off.;Open bag and monitor well with slight flow,flow stopping after 8 minutes.Pressure up casing to 3000 psi.(Pumped 6.4 bbls.Lost 1350 psi in 12.5 min.)Bleed to zero.;Rig down circulating equipment.CBU with no issues.Monitor well.Well static.;PJSM,Install FOSV,Slip and cut 60'drill line.Reset and test crown saver.;Adjust ng brakes,service draworks,blocks,topdrive and crown sheaves.Flowcheck well,static.;POH from 5754'to HWDP @ 610',flowcheck well,static.Correct displacement on trip out of hole.;L/D 9 jts HWDP,rack jars and 8 jts HWDP in derrick,inspect mud motor,L/D NBS and bit,rack flex collars and mud motor in derrick.Bit grade= 1,1,WT,A,E,I,NO,BHA.Well remains static.;Clear and clean rig floor.;PJSM,R/U Haliburton e-line,P/U CBL logging tools as follows:Bull nose,roller centralizer,R- bond tool,roller centralizer,2-knuckle jts,adaptor,TTCU,knuckle jt and roller wheels,2 wt bars,;roller wheels,head=41.67'.RIH,able to get to 5350',POH making 3 attempts getting to 5383',log up 30 fpm to 3900';Hauled 58 bbls to G&I.Total Hauled 6433 bbls Hauled 0 bbls to Pad 3.Total Hauled 1550 bbls Hauled 130 bbls of H2O F/L-Pad Lake.Total Hauled 7740 bbls;Hauled 809 bbls of H2O FNern Lake.Total Hauled 2049 bbls 7/30/2015 7/29/2015 Continue to log CBL from 3900'to surface.Did not get good log due to centralization. Reconfigure tool string with additional centralizers and RIH to 5270'.Log up from 5270'.Rig down HES Loggers.;PJSM,PU RTTS and TIH to 2370'.,Circulate bottoms up.Test casing to 3000 psi from 2370'to surface.Held flat line for 15 minutes @ 3000 psi.;Release RTTS and TIH from 2370'to 5800'.Had a 15K set down @ 5270'working thru easily.;Circulate BU pumping 230 gpm @ 260 psi.;Set RTTS @ 5800'per Haliburton rep,close annular,test 9 5/8"casing to 3000 psi for 30 min charted,flat line,4 bbls pumped,4 bbls bled back,open annular,release RTTS.Flow check well,static.;POH from 5800'to surface,L/D RTTS tool,correct displacement on trip out.;PJSM,M/U directional BHA#3, 8 1/2"PDC bit,mud motor w/1.5 deg AKO, flt sub,ADR collar,DM collar,scribe motor to MWD w/offset @ 197.95 deg.Download MWD tools,M/U DGR collar,PWD collar,;TM collar,3 NMFC,1 jt HWDP,jars,7 jts HWDP=465.58',test MWD tools.;Drift and P/U 60 jts 5"DP and RIH from 466'to 2362',continue TIH with stands from derrick to 2542';Hauled 0 bbls to G&1.Total Hauled 6433 bbls Hauled 0 bbls to Pad 3.Total Hauled 1550 bbls Hauled 55 bbls of H2O F/L-Pad Lake.Total Hauled 7795 bbls;Hauled 0 bbls of H2O FNern Lake.Total Hauled 2049 bbls 7/31/2015 7/30/2015 Continue to TIH from 2400'to 5748'.PU 192K,SO 98K.;Kelly up and establish parameters and wash down from 5748'Tag FC @ 5915'.No hard cement before FC.;DrI FE&Cmt to 5970'.Dr!20'of new hole to 5990'.FC @ 5917 and Shoe @ 5957'. 10K WOB,30 TD RPM,185 Bit RPM 500 GPM,2080 SPP,Diff 200 PSI,PU 135K,SO 120K,Rot 130K,On Btm TQ 9.5k.;PUH into shoe and circulate hole volume while lowering the PH on mud before fluid swap.;PJSM on displace hole to clean 8.9 mud.Pull down pits to make room for displacment.Pump Spacer and displace spud mud with New 8.9 Mud.;Clean pit 1,Trip tank and under shaker before drilling ahead.:Perform FIT Test to 12.0 ppg EMW. Current MW=8.9. Shoe TVD=4202' Surface pressure applied=680 psi 10 sec drop=660 psi 4 min drop=570 psi 5 min drop=570 psi Total bbl pumped=1.27;Drl f/5990'to 6405'(415')AROP=64 fph.7-15K WOB,60 TD RPM,501 GPM,150 MTR RPM,1670 SPP,100 DIFF,9800 TQ on, 8500 TQ off. Pump tandem sweeps as needed.MW 9.1 ppg,Vis 38,ECD 9.7 ppg.;Drl f/6405'to 6785(380')AROP=63 fph.5-10 K WOB,60 TD RPM,505 GPM,152 MTR RPM,1730 SPP,70 DIFF,9900 TQ on, 8500 TQ off. P/U 175K,S/O 95K,ROT 125K.;Pump tandem sweeps as needed.MW 9.1 ppg,vis 37,ECD 9.7 ppg.No losses.Sweeps back on time averaging 10-15% increase in cuttings @ shaker,mostly sand.;52.25'below the line,20.21'left of the line ADT=6.54 hrs ART=4.01 hrs AST=2.53 hrs;;Hauled 463 bbls to G&I.Total Hauled 6896 bbls Hauled 0 bbls to Pad 3.Total Hauled 1550 bbls Hauled 70 bbls of H2O F/L-Pad Lake.Total Hauled 7865 bbls;Hauled 0 bbls of H2O FNem Lake.Total Hauled 2049 bbls 8/1/2015 7/31/2015 Drl f/6785'to 7319'(535') =89 fph.5-15 K WOB,60-80 TD RPM,520 GPM,161 MTR RPM, SPP,100 DIFF,10K TO on, 8500 TQ off. P/U 172K,S/O 87K,ROT 132K.;Pump tandem sweeps as needed.MW 8.9 ppg,vis 37,ECD 9.7 ppg.No losses.Sweeps back on time averaging 10-15% increase in cuttings @ shaker;DrI f/7319'to 7540'(221')AROP=63 fph.5-15 K WOB,60-80 TD RPM,530 GPM,164 MTR RPM,2230 SPP,350 DIFF,9.5K TQ on, 8.5 TQ off. P/U 175K,S/O 85K,ROT 115K.;Pump tandem sweeps as needed.MW 9.0 ppg,vis 40,ECD 10.05 ppg.No losses.Sweeps back on time averaging 10-15% increase in cuttings @ shaker;Stand Back 1 stand to 7442'.Circulate bottoms up x2 and clean hole up for wiper trip to shoe. Rotate reciprocate pipe @ 528 GPM with 1960 psi. PU 135K,SO 115K Survey from 7472'MD,4216.55 TVD,Inc 92.29,AZI 121.72.Right 30',Low 44';Pull wiper trip to the shoe on elevators.Work through tight spot at 6695'Pu off bottom with 200K.Hole fill took 1 bbl over calculated.;Service rig,top drive,drawworks,blocks and wash pipe.;TIH from 5894'to 7448'with no issues,5 bbls under calc displacement on trip in,safety ream last std to bttm.No fill,P/U 165K,S/O 95K,ROT 125K.;Drl f/7540'to 7828'(288')AROP=72 fph.5-9K WOB,80 TD RPM,510 GPM,153 MTR RPM,1970 SPP,80 DIFF,10,300 TQ on, 9300 TQ off. Pump low vis sweeps as needed.MW 9 ppg,Vis 41,ECD 10.04 ppg.;Note:5028u gas from 7730'with no pit gain.;Dri f/7828'to 8202'(374')AROP=62 fph.8-16K WOB,80 TD RPM,513 GPM,154 MTR RPM,2070 SPP,150 DIFF,10200 TQ on, 9200 TQ off. P/U 160K,S/O 90K,ROT 115K.;Pump low vis sweeps as needed,sweeps back on time with minimal increase. MW 9.2 ppg,Vis 38,ECD 10.09 ppg.No losses.;33.14'below the line,17.68'right of the line ADT=8.18 hrs ART=5.26 hrs AST=2.92 hrs;Hauled 696 bbls to G&I.Total=7592 bbls Hauled 0 bbls to Pad 3.Total=1550 bbls Hauled 750 bbls of H2O F/L-Pad Lake.Total=8615 bbls Hauled 274 bbls of H2O FNern Lake.Total=2323 bbls;We crossed the predicted major,down to the east fault at 7720'(4200'TVD)with a throw of 58'. This was on the high end of the 40-60'throw prediction from the geophysicist. We ended up in the base of the N sands unit at got into the upper OA sand at 8120'(4219'TVD)at 84.5 dais.. 8/2/2015 8/1/2015 Drl f/8202'to 8700'(498')AROP=83 fph.8-10K WOB,80 TD RPM,522 GPM,162 MTR RPM,2080 SPP,230 DIFF,10.5-12 TQ on, 10.5 TQ off. P/U 175K,S/O 75K,ROT 120K.;Pump Lo Vis sweeps as needed.Sweeps coming back on time.;DrIf/8700'to 9050'(350')AROP=100 fph.8-16K WOB,80 TD RPM,520 GPM,162 MTR RPM,2030 SPP,250 DIFF,12.5 TQ on, 11K TQ off. PIU 170K,S/O 80K,ROT 120K.Max gas 3831 u from 8820';Dumped 200 bbls and diluted system with 200 bbls new mud @ 8965'.;Stop drilling and pump 30 bbls to vis sweep to surface with no substantial change in cuttings. Max gas @ 764u.;Drl f/9050'to 9337'(287')AROP=96 fph.8-16K WOB,80 TD RPM,519 GPM,162 MTR RPM,2296 SPP,200 DIFF,12.5 TQ on, 11K TQ off. P/U 175K,S/O 85K,ROT 120K.MW 9.1 ppg,vis 37,ECD 10.12 ppg.;Decision made to pull wiper into 9 5/8"casing instead of previous wiper interval @ 7400'to replace MP#1 leaking swab and cut drilling Iine.;POH from 9337'to 9124',250k off bttm.Flowcheck well,static.Continue POH on elevators into 9 5/8"casing @ 5933'with no issues. Flowcheck well,static.10 bbls over calculated displacement.;Monitor well with trip tank,M/U FOSV and top drive.Slip and cut 48'drag line.Re- set and test crown saver.C/O leaking swab on MP#1 on ODS while cutting drlg line.;Service blocks,topdrive and swivel.Inspect drawworks brakes.;RIH from 5933'to 8908',fill pipe.Drift and P/U 9-6 1/4"drill collars and 2 XOs for push pipe to 9239',M/U last stand,wash to 3'off bottom @ 9334'.TIH 9.8 bbls under calculated disp.;CBU pumping 506 gpm,2190 psi,reciprocate and rotate 70 rpm,TQ 10,000.BU gas 900u;Drl f/9337'to 9390',WOB 5K,83 TD RPM,515 GPM, 150 MTR RPM,2239 SPP,150 DIFF,12.5 TQ on, 11K TQ off. P/U 190K,S/O 85K,ROT 130K.MW 9.1 ppg,vis 38,ECD 10.24 ppg.No losses.;58.56'below the line,3.71'left of the line ADT=8.05 hrs ART=6.35 hrs AST=1.70 hrs;Hauled 1089 bbls to G&I.Total=8681 bbls Hauled 0 bbls to Pad 3.Total=1550 bbls Hauled 750 bbls of H2O F/L-Pad Lake.Total=9365 bbls Hauled 0 bbls of H2O FNern Lake.Total=2323 bbls 8/3/2015 8/2/2015 Drl f/9390'to 9900',WOB 13K,75 TD RPM,527 GPM,163 MTR RPM,2310 SPP,194 DIFF,12.5 TQ on, 11K TQ off. P/U 165K,S/O 115K,ROT 130K.MW 9.1 ppg,vis 38,ECD 9.9 ppg.No losses.;Note:Dump 470 bbls from active and dilute system with 290 new mud 9618'. Last Survey: MD 9830.93 TVD 4243.55 Dist to plan=71.95 ctr to ctr 71.55 low and 7.51 left;DrI f/9900'to 10086',WOB 8K,77 TD RPM,527 GPM,163 MTR RPM,2310 SPP,194 DIFF,12.5 TO on, 11K TQ off. P/U 165K,S/O 115K,ROT 130K.MW 9.1 ppg,vis 38,ECD 10.10 ppg.No losses.;Last Survey:MD 10020.05 TVD 4238.25 Dist to plan =66.92 ctr—ctr 66.25 low and 9.45 left.;Noticed excess oil in the gear box of top drive.Oil appears to be coming from the upper Rainier Hyd Mtr on the Top Drive.Decision made to trip to shoe,trouble shoot and replace mtr.;Stand back one stand to 9995'.Work pipe while circulating hole clean for trip to shoe.;POOH on elevators from 9995'to 6066'. 1 stand outside the shoe.PU off bottom with 250k.PU wt @ the shoe 190K,SO 75K.Work through tight spot @ 9582'to 9552'. 21.7 bbls over calc disp on trip out;CBU at the shoe,prior to making rig repairs.BU gas 115u,Pull 1 std to 5932',park inside 9 5/8"casing.;lnstall FOSV,monitor well with trip tank.Trouble shoot top drive hydraulic motors to determine what is causing excessive oil in topdrive gearbox.Remove upper TDS hyd motor.;lnstall new rainier motor,change gearbox oil.Function test top drive.Note:1.4 bph static loss rate while monitoring well:66.25'below the line,9.45'left of the line ADT=4.98 hrs ART=4.21 hrs AST=.77 hrs Daily fluid lost to well 14 bbls,total 14 bbls;Hauled 590 bbls to G&I.Total=9271 bbls Hauled 0 bbls to Pad 3.Total=1550 bbls Hauled 600 bbls of H2O F/L-Pad Lake.Total=9965 bbls Hauled 550 bbls of H2O FNern Lake.Total=2873 bbls 8/4/2015 8/3/2015 Continue replacing upper Rainier hyd.drive motor on TDS.Test drive mtr.Still leaking oil into gear case.;Reperform lock out tag out and C/O lower hyd top drive motor.Test run TDS @ 40 to 100 RPM for 1 hour.Test good.Reinstall guards on TDS.;Note:1.4 bph static loss rate while monitoring well.Mud engineer and Vac truck support manging fluids and cleaning reserve tanks.;TIH from 5932'.Fill pipe @ 8909',run 3 stds 6 1/4"drill collars from derrick to 9331',continue RIH to 9906'with no issues.Wash last 2 stands to bttm,no fill.;26.5 bbls over calculated displacement on TIH,BU gas 1450u.Note:off NPT @ 00:00 HRS;DrI f/10086'to 10457',WOB 10K,80 TD RPM,506 GPM,152 MTR RPM,2230 SPP,50 DIFF,12 TO on, 11K TQ off. P/U 195K,S/O 90K,ROT 140K.MW 9.1 ppg,vis 39,ECD 10.39 ppg.;Average ROP 64 fph.Note:1523u gas from 10221',2073u gas from 10270',2527u gas from 10287';60.44'below the line,20'left of the line ADT=1.90 hrs ART=.40 hrs AST=1.50 hrs Daily fluid lost to well 34 bbls,total 41 bbls;Hauled 406 bbls to G&I.Total=9909 bbls Hauled 0 bbls to Pad 3.Total=1550 bbls Hauled 100 bbls of H2O F/L-Pad Lake.Total=10065 bbls Hauled 0 bbls of H2O FNern Lake.Total=2873 bbls 8/5/2015 8/4/2015 Dd f/10457'to 11200',AI 12K,85 TD RPM, 506 GPM,152 MTR RPM,2230 SPP,50 DIF , Q on, 11K TQ off. P/U 195K,S/O 90K,ROT 140K.MW 9.1 ppg,vis 39,ECD 10.39 ppg.;707'@ Average ROP 58 fph.;Drl f/11200'to 11368',WOB 10-12K,85 TD RPM, 512 GPM, 154 MTR RPM,2377 SPP,100 DIFF,12.5 TQ on, 11.2K TO off. P/U 190K,S/O 80K,ROT 130K.MW 9.1 ppg,vis 39,ECD 10.41 ppg.;Unable to get weight to bit transfer for slide,Loss rate drilling averaging 2 bph.Average ROP 37 fph,BGG 150u.;Pump 25 bbl low vis sweep @ 507 gpm,2380 psi,rotate 100 rpm and reciprocate pipe.Sweep back 400 stks late with minimal increase in cuttings.;POH from 11368'to 11169, 260k off bottom.Flowcheck well,continues with slight seepage.Continue POH on elevators to 9239'©push pipe drill collars with no issues.;1.4 bbls over calculated displacement on trip out.;Drift and P/U 9 jts HWDP for more push pipe from 9239'to 9518',Continue to TIH from 9518'to 10664',fill pipe and empty trip tank.Continue to TIH,wash last 2 stds to bttm,no fill.;10 bbls under calculated displacement on TIH.;Drtg f/11368'to 11428' WOB 7K,507 GPM,154 MTR RPM,2450 SPP,110 DIFF,12.5 TQ on,11.5K TQ off. P/U 195K,S/O 70K,ROT 130K.MW 9.2 ppg,vis 39,ECD 10.44 ppg.;48.76'below the line,13.5'left of the line ADT=10.53 hrs ART=9.17 hrs AST=1.36 hrs Daily fluid lost to well 35 bbls,total 76 bbls;Hauled 290 bbls to G&l.Total=10199 bbls Hauled 300 bbls to Pad 3.Total=1850 bbls Hauled 540 bbls of H2O F/L-Pad Lake.Total=10605 bbls Hauled 265 bbls of H2O FNem Lake.Total=3138 bbls 8/6/2015 8/5/2015 Dug F/11428'T/12117' WOB 8-12K,507 GPM,2692 SPP 80 RPM, ,13K TQ on,11.5K TO off. P/U 200K,S/O 70K,ROT 130K. MW 9.1+ppg,vis 38,ECD 10.54 ppg. 689'@ 57.4 FPH average.;Hitting hard stringers @ 10-30 FPH.;Drig F/12117'T/12500' WOB 10-16K,512 GPM,2680 SPP 80 RPM, 15.5K TQ on,12K TQ off. P/U 205K,S/0 72K,ROT 135K. MW 9.2 ppg,vis 39,ECD 10.45 ppg. 383'©64 FPH average.;Pump final survey,Pump tandem 25 bbl low vis/25 bbl 9.6 ppg weighted sweep 508 gpm,2650 psi,reciprocate and rotate 100 rpm.BU gas 3402u.;Pump STS and 1 BU,sweep back @ calculated stks with minimal increase in cuttings.;Monitor well,Slight seepage. POOH on elevators F/12500'T/ 12182'.Overpull. Back Ream stand. POOH on elevators F/12182'T/11703'. Pull 30 K over.Pull through.POOH T/10036'.;Pump 25 bbl low vis sweep around, 504 gpm,2430 psi,rotate 100 rpm,reciprocate pipe.;47.86 Low the line,77.88 Left of the line ADT=11.19 hrs ART=9.56 hrs AST=1.63 hrs Daily fluid lost to well 28 bbls,total 104 bbls;Hauled 348 bbls to G&I.Total=10547 bbls Hauled 415 bbls to Pad 3.Total=2265 bbls Hauled 600 bbls of H2O F/L-Pad Lake.Total=11205 bbls Hauled 0 bbls of H2O FNem I ake Total=3138 bbls 8/7/2015 8/6/2015 Pump 25 bbl low vis sweep around @ 10030',500 gpm,2400 psi,rotate 100 rpm and reciprocate,hole unloaded @ BU with 1842u gas,sweep back on time with minimal increase.;POH 5 stands from 10030'to 9565',clean;TIH from 9565'to 11668',seeing 50k drag TIH,wash and ream from 11668'to TD @ 12500',no • fill;CBU @ 12500'pumping 510 gpm,2700 psi.Reciprocate and rotate pipe 100 rpm.Swap wellbore and pits to new 8.9 ppg solids free drilling mud,flowcheck well, seepage continues.;Note:2.5 gallons of drilling mud spilled onto pad,SO1 report submitted.;POOH from 12500'to 9518'@ push pipe.Flowcheck well,seepage continues.Note:with new mud in hole drag reduced from 260k to 220k POOH;UD push pipe-9 jts HWDP and 9-6 1/4"drill collars.Drop 2.8"drift on wire. Continue POOH from 8958'to 5668'inside 9 5/8"csg.SLM drill pipe.7 bbls over calculated displacment on trip out.;Flowcheck well,seepage continues,monitor well with trip tank,Install FOSV,cut and slip 54'drilling line.Re-set and test crown saver.;Continue POOH from 5668'to 2350',Pump 10 bbls fresh water to flush drill pipe,POOH L/D 60 joints of 4 1/2"IF NC-50 drill pipe to 717',flowcheck well,seepage continues.SLM drill pipe.;Fluid lost to well in last 24hrs=42 bbls Total fluid lost to well=146 bbls.;Hauled 348 bbls to G&I.Total=10895 bbls Hauled 1105 bbls to Pad 3.Total=3370 bbls Hauled 450 bbls of H2O F/L-Pad Lake.Total=11655 bbls Hauled 0 bbls of H2O FNem Lake.Total=3138 bbls • Hilcorp Energy Company Composite Report Well Name: MP L-49 Field: North Slope County/State: ,Alaska I(LAT/LONG): ovation(RKB): 47 API#: Spud Date: 7/18/2015 Job Name: 15111270 MP L-49 Completion Contractor AFE#: 1511127C AFE$: $1,093,100 Activity Date I Ops Summary 8/7/2015 L/D 60 joints NC-50 DP.,Monitor well, 1.4 BPH. L/D HWDP&flex collars.,Download MWD data.,L/D BHA,Offload tools&clean floor. Bit Grade 2-3-CT-T-X-3- BT-TD.,Pull wear ring,M/U stack wash tool&wash out BOP stack.,Drain stack,set test plug,close blind ram,remove upper 2 7/8"x 5"VBR,install 5 1/2"pipe ram. Open blind ram.,Monitor annulus,install 5 1/2"test jt, R/U test equipment,close bag.Test 5 1/2"pipe rams to 250/3000 psi 5 min ea.charted.R/D test equipment.,Install wear bushing with 2 LDSRI,load jewelry into pipe shed,R/U Weatherford equipment. Continue to monitor well with trip tank,static loss rate 1.5 bph.,Adjust top drive torque to 10,000 ft/lbs.0/0 grabber dies.,PJSM for running liner with Weatherford, Baker,rig crew and DSM,M/U shoe track,ensure float is operational per Baker rep.P/U and RIH with 5.5"L-80, 17#DWC Injection Liner and jewelry per tally, Baker and Weatherford rep.Use 10,500 ft/lbs optimum M/U torque. Note:ensure auto fill,check fill every 10 jts ran.Monitor fluid displacement with trip tank. RIH to 1007'.,PJSM with oncoming crew,continue to P/U and RIH with 5.5"injection liner and jewelry per tally from 1007'to 4430' Well continues with 1.5 bph loss rate while RIH.Currently 95 jts liner ran,6 swell packers and 8 injection control devices.,Fluid lost to well in last 24hrs=36 bbls Total fluid lost to well= 182 bbls.,Hauled 812 bbls to G&I.Total= 11707 bbls Hauled 0 bbls to Pad 3.Total=3370 bbls Hauled 260 bbls of H2O F/L-Pad Lake.Total=11915 bbls Hauled 979 bbls of H2O F/Vern Lake.Total=4117 bbls 8/8/2015 Continue to P/U and RIH with 5.5"injection liner and jewelry per tally F/4430'T/5934'. Well continues with 1.5 bph loss rate while RIH.Currently 129 jts liner ran. Continue to clean and prep pits for Brine system.,M/U XO to topdrive. Break circulation. Stage up pumps to 8BPM @ 160 PSI. Circ liner volume.GOOD. Establish TQ parameters @ 10,20,30 RPMs. 1800,2200,2500.ROT/UP/DN 105K/118/93. 6 bbl loss while circulating.,Continue to P/U and RIH with 5.5"injection liner and jewelry per tally F/5934'T/6691'. Well continues with 1.5 bph loss rate while RIH. Currently 145 jts liner ran, 12 ICDs,9 Water Swell Packers. Count pipe in shed&on location. GOOD,Change handling equipment to 5". P/U ZXP Liner top hanger&packer. M/U to Liner. Let slips ride to verify running tools OK. R/D Weatherford casing equipment&clear floor. Baker hand make up Pal Mix&install in running tool.Let set up. Up/ON 130/95K.,RIH on 5"DP from the derrick F/6732 T/9930'.Work past. RIH T/11636'. Stage pumps up to 7BPM 500 psi.Try to rotate.Able to rotatewhen moving pipe but stalling @ 10k TQ as soon as set down.Unable to work past due to Kelly down and no working room.P/U single.31.49. Pump @ 7 bpm working string.Work past setting everything on it. RIH T/11953'. Unable to work past. L/D stand 56 for working singles.,P/U first single from stand 56.Work pipe.Work pipe down F/11953'T/12047'. Rot down @ 30-40 RPM. Picked up 3 singles from stand 56. Circ 3%NXS pill down&work in.,Continue to work 5.5"liner from 12047' to TD @ 12500'pumping 277 gpm,572 PSI,once NSX pill out of shoe we were able to rotate from 10 to 40 rpm as hole allows before top drive stalls working down.,Pump 277 gpm,572 psi.Unable to rotate,Attempt to reciprocate from 12500'to 12490',after reciprocating 3 times difficult getting back to bottom,work pipe to bottom with top drive. Unable to determine S/O wt due to drag,P/U 200k,park in tension @ 200k. (Verify pipe count,ran 61 stds drill pipe and 1 single with 18'stickup on single) Note:losing approx 30 bbls hr while working liner to bottom.,PJSM with mud man,DSM,crew and rig support,review plan to swap well over to KCI, Displace well to 3%8.9 ppg KCI,stage pump slowly from 277 gpm,572 psi to 331 gpm,755 psi. Displace well until good 8.9 ppg 3%KCL returns @ shaker.850 bbls total.Mix and pump 35 bbl 5 ppb SAPP pill,pump 263 gpm @ 420 psi. Loss rate while pumping SAPP pill around @ 2.8 bph. Note:570 bbls of 9.1 ppg BARADRIL-N mud stored @ Baroid,Continue pumping first SAPP pill around,@ 10,000 stks stage pump up to 370 gpm,800 psi, pump STS with additional BU,200%increase of filter cake observed @ shaker,mostly collected in possum belly. Note:loss rate decreasing to 2 bph.,Mix and Pump 35 bbl 10 ppb SAPP pill#2 @ 371 gpm,790 psi, No increase in cake at shakers,pump additional BU. Note:loss rate increasing to 10 bph @ 10,000 stks and decreasing to 6 bph @ 18000 stks.,Fluid lost to well in last 24hrs=64 bbls Total fluid lost to well=246 bbls.,Hauled 174 bbls to G&I.Total=11881 bbls Hauled 0 bbls to Pad 3.Total=3370 bbls Hauled 150 bbls of H2O F/L-Pad Lake.Total= 12065 bbls Hauled 1063 bbls of H2O F/Vern Lake.Total=5180 bbls 8/9/2015 Circ second SAPP pill out. Did not rec any wall cake. Pump tandam 10 ppb sap pill around @ 9 @ 750 psi. No wall cake returned. Displace well to 8.9 ppg clean brine @ 6 bpm 380 psi. Discuss with production engineer&decide to drop MW to 8.6+. Notified AOGCC of upcoming BOP test @ 8/9/2015 @ 0913.,Start diluting brine while pumping @ 6 bpm. Only able to pump 3 bpm while diluting. Displace well to 8.6+@ 3 bpm 100 psi. Hauling diluted brine to B50 in Milne Point. Prep 3 1/2 completion equipment.Strap&Tally.Losses @ 5-8 BPH. Roads and pads leveled pad for L-46,48&50. Prep for rig move.,With 8.6+ppg brine in,8.7 ppg brine out increase pumps to 9.6 bpm,970 psi,CBU,@ BU 75%increase in sand with minimal filter cake,BU gas 520u,circulate until clean. Note:Losses continue @ 7-8 bph. BGG 310u.,Shut down pump,B/O top drive,drop 1 1/2"ball,M/U top drive.Pump 900 stks @ 5 bpm,slow down pump to 2 bpm,Ball on seat @ 1000 stks.Stage up pressure with rig pump to 2000 psi,use test pump and pressure up to 2500 psi, Continue to pressure up,packer set @ 2600 psi,continue to pressure up to 3000 psi,S/0 to 100k string wt.Pressure up to 3500 psi,setting tool released @ 3200 psi.pressure up to 4000 psi.,Bleed pressure to 0 psi,close bag,line up on kill line.Using rig pump,test packer to 1500 psi for 10 charted minutes,solid test. Bleed off pressure thru choke,open bag,pressure up drill pipe to 500 psi,P/U 2'pulling packoff from seal bore,P/U wt 145k. Establish circulation @ 2 1/2 bpm,70 psi. P/U 15'@ tool jt to 5794',continue to circulate for 10 minutes,L/D single„M/U top drive,pump 10 bpm,300 psi to ensure no debris enters TOL when we unsting,Pull running tools out of liner to 5765'.TOL @ 5780'.,Pump 10 bpm,315 psi,Reciprocate and rotate 60 rpm from 5765'to 5735'until clean.Note:significant amount of sand @ BU. Flowcheck well 15 minutes,well flowing 1 bph.,M/U top drive,circulate,increase brine wt from 8.6+ppg to 8.8 ppg.With 8.8 ppg in/out,flowcheck,U-tubing out DP.M/U top drive,pump another pipe volume. B/O top drive,flowcheck well,well is static,fill trip tank.,Fluid lost to well in last 24hrs=132 bbls Total fluid lost to well=378 bbls.,Hauled 1584 bbls to G&I.Total=13465 bbls Hauled 0 bbls to Pad 3.Total=3370 bbls Hauled 1450 bbls of H2O F/L-Pad Lake.Total=13515 bbls Hauled 1073 bbls of H2O F/Vern Lake.Total=6253 bbls 8/10/2015 POOH L/D 5'DP F/5735'to surface.L/D liner running tools. Recovered all tools. Monitor well. Static. RIH remaining 8 stands and lay down same. 6 bbl over calculated displacment for the trip.Well losing 1.5 bph while tripping.,Pull WB. M/U stack wash tool. Wash stack.Set test plug. Change top rams back to 2 7/8 X 5”VBRs rams. M/U test joint. Fill Stack.Perform body test. GOOD.,Test BOPE as per AOGCC.State rep Bob Noble waived witness.Monitor annulus. Using fresh water and 3 1/2"test joint,test annular,upper 2 7/8"x 5"VBR,mud cross valves,upper and lower IBOP,blind ram,2 FOSV, 1 dart valve and choke manifold valves to 250 psi low and 3000 psi hi for 5 min ea.charted. Perform accumulator drawdown test,no failures,R/D test equipment.,R/U to run 3 1/2"completion.Monitor well. Well taking .5 bph.,PJSM with oncoming crew,ensure all components are drifted. P/U first jt,M/U ratcheting mule shoe and XO, P/U Halliburton packer with reps present. RIH 90 fpm max running speed with 3 1/2"L-80,9.3#EUE completion string per tally,use optimum torque @ 3030 ft/lbs,verify auto fill every 10 jts ran.,Utilize dog collar clamp on first 20 jts. Dope pin end only,RIH to 4430'. Note:Hole continues taking.5 bph while running completion. Prep for rig move. Spot rig mats over L-46.,Fluid lost to well in last 24hrs=26 bbls Total fluid lost to well=404 bbls. Daily fuel used=1075 gallons Fuel on hand=12000 gallons,Hauled 0 bbls to G&I.Total=13465 bbls Hauled 0 bbls to Pad 3.Total=3370 bbls Hauled 150 bbls of H2O F/L-Pad Lake.Total=13665 bbls Hauled 0 bbls of H2O FNern Lake.Total=6253 bbls Hauled 530 bbls to B-50.Total=1415 bbls. 8/11/2015 P/U 3.5 tubing T/5805'.Sting shoe in to top of the 5"liner.Good. POOH L/D one joint.M/U Hanger.Dress seals,Drain stack. Land hanger. Pulled threads on landing joint while doing so.Verified landing. Good. Installed TWC and test from above.500 psi.5 min.Good. Pull TWC. R/U circ lines. Reverse circulate corrosion inhibiter down to auto fill tool spot with clean seawater. Close auto fill tool.Verify closed.,Set packer per Halliburton rep. Pressure up tubing to 3500 psi to set packer. Did see bobble @ 2200 psi.Hold 3500 psi on chart for 30 min.Good test. Bleed down T/1000 psi. Pressure up on annulus to 3000 psi. Trouble shoot bleed off. Attempt several methods to obtain casing test with no success.Averaging 100 psi bleed off every 10 minutes.,Consult with Halliburton and receive permission to pressure tubing back up to 4000 psi to ensure setting of packer. Pressure up to 4000 psi.Hold for 15 min w/zero bleed off.Attempt to test casing again with same bleed off.Decision made to shear open GLM and test Csg/Tbg together.Do so with same bleed off results.,Call for Little Red Services to test backside independently.,Rig up Hot Oil to the IA and test Tbg.&IA to 3000 psi.Hold for 30 min. During the test the IA&Tbg.bled off 75 psi every 10 min.,On the rig up we disassembled the choke and kill lines to verify that there would be no leaks going back into the rig circ.system. We filled the stack and tested against the blind rams we had no surface leaks during test.,Filled pits with 500 bbls.of water and weighted up system to 8.8 and installed dutch riser on BOP's while waiting for wireline truck,PJSM-Spot Wireline unit&R/U.,RIH with slick line to retrieve shear valve.,Fluid lost to well in last 24hrs=9 bbls Total fluid lost to well=413 bbls. Daily fuel used=750 gallons Fuel on hand=11250 gallons,Hauled 111 bbls to G&I.Total=13576 bbls Hauled 0 bbls to Pad 3.Total=3370 bbls Hauled 0 bbls of H2O F/L-Pad Lake.Total=13665 bbls Hauled 0 bbls of H2O FNern Lake.Total=6253 bbls Hauled Obbls to B-50.Total= 1415 bbls. 8/12/2015 Finish slick line work pulling Shear out�e and installing dummy valve in GLM.Had to make 3 atte to pull shear out valve. Rig down Slick line. Noted 40 psi on IA. Rig up 2"hose from IA to choke manifold.Open up to choke manifold and bled to zero within minutes and static afterward.,Close blinds,stage up to 4500 psi with test pump.Sheared Mirage plug.Monitor well filling tubing through kill line @ 45 bph loss rate.,Open blinds,sting into hgr with spear. BOLDS, Stage up to 175K(95K over original up wt of 80K)shear PKR free with string wt dropping 90K up wt.Pull hanger to floor.Up Wt 85-90K,Circulate tbg volume.lay down the tbg hanger,spear and 1 joint 3'/z"tubing.Mill TIW and circulating hose.Continue to circulate well to flow back tank,clearing well bore of corrsion inhibitor.Move 5"DP from DS to ODS in Derrick to make room for tubing.and to allow access to DP for the scraper/CIBP run.,Blow down circulating lines. Monitor static loss rate @ 30 BPH with 8.7 MW.Circulated total of 373 bbls by strokes.60 bbls shy on pumping to flow tank,with total losses @ 17:00 hrs of 114 bbls.Average Loss Rate @ 29 bph.,PU 1 single(jt 179)TOH from 5782'standing back 3 1/2"tubing. Up Wt 85K-90K (3 1/2 production packer showed no external damage;all slips were in place an element showed little wear but no tears.the auto fill had some debris in the perforations.),Rlg up and Test VBR rams with 5"test joint.250/3000 hold for 5 min.,Rig down test equpment and set wear ring,PJSM; pick up 9 5/8 scrapper BHA. Bull Nose— 6%'OD 3 1/16"ID 1.58 Length Double Pin—6/" 2 5/16"ID.85 Length Boot Basket—OD 7" ID 2'/;' 3.73 length Boot Basket—OD 7" ID 2 1/4"3.93 Length 9 5/8 Casing scrapper 8"OD 2 V."ID 4.29 Length Bit Sub-6 3/8"OD 2'A ID 3.01 Length Hyd.Oil Jars 6'/.OD 2%,ID 11.87 Length Total Length=29.26,P/U 1000'+/-of 5"DP out of the pipe shed;continue in the hole with remainder out of the derrick.,Fluid lost to well in last 24hrs=227 bbls Total fluid lost to well=640 bbls. Fuel Receive=7305 gallons Daily fuel used=1055 gallons Fuel on hand=17500 gallons,Hauled 111 bbls to G&I.Total=13576 bbls Hauled 0 bbls to Pad 3.Total=3370 bbls Hauled 0 bbls of H2O F/L-Pad Lake.Total=13665 bbls Hauled 0 bbls of H2O FNern Lake.Total=6253 bbls Hauled 525bb1s to B-50.Total=2655 bbls. 8/13/2015 Continue to TIH with 9-5/8"Scraper/Junk basket BHA from 5275'to 5700'.Short trip 3 stands from 5700'. Break circulation and attempt circulate well clean with minimal returns.,TOH with scraper from 5700'. Lay down BHA.Clean junk baskets and recovered 1 lb metal chips recovered.Clear rig floor of scraper BHA.,MU Halliburton Retrievable Bridge plug.TIH to 5583'MU Top Drive.and wash down to 5718'@ 13 bpm,525 psi,PU Wt 175K,SO Wt 115K.Set 9 5/8"RBP @ 5699'EOP and 5695'center of element.,Wash down from 5583'to 5718'@ 13 bpm,525 psi,PU Wt 175K,SO Wt 115K. Set 9 5/8"RBP @ 5699'EOP and 5695'center of element.,Rig up and test 9 5/8",40#L-80 casing to 3000 psi from 5695 to surface.Chart for 30 min.Test Good.,Release drill string from RBP @ 5690'. Reverse circulate well clean @ max rate. 15 bpm,967 psi.Getting a combination of small metals,wall cake and fines back at shakers.,Continue Rev.Circ.@ 13bpm 780psi.(still wall cake and fines back did not stop until well was clean) Total Metal Recoverd 5Ib+/- .,Displace well with clean filterd 8.7 brine @ 5 bpm 330psi(low rate due to trucks rigging up straight to the suction and not being able to keep up),Service Rig; slip and cut drilling line.Have mud plant filter 500 bbls of 8.7 brine and haul to rig. Clean pits. 8/14/2015 Finish Slip and cut drill line.Service Rig.,Release Retrievable Bridge Plug and POOH standing back 40 stands DP.Cont.POOH L/D 22 stands DP and RBP.,Change out pipe handling equipment to 3 14". Pull wear bushing.,Run 3 1/2"Completion as follows: Ratcheting Mule Shoe,XO,6 jts tbg,Mirage Plug/ Auto Fill Sub w/pups,PHL PKR Assembly w/Pups, 81 jts tbg,GLM w/SOV set @ 2500 psi,27 jts tbg, X Nipple w/Pups(2.813 profile),65 jts tbg,Tbg Hgr w/Pup.Total Jts run in hole= 179.,M/U Hanger.Dress seals,Drain stack.Land hanger.(No Problems),R/U circ lines. Reverse circulate 180bb1.corrosion inhibiter down to auto fill tool spot with clean seawater,Set packer per Halliburton rep. Pressure up tubing to 3500 psi to set packer.Did see bobble @ 2000 psi. Hold 3500 psi on chart for 30 min.Good test. Bleed down T/1000 psi. Pressure up on annulus to 3000 psi.in the 30 min IA bled down 125psi,but noticed tubing increased 100 psi.bled pressure down to 0 on the IA&.reconfigured the valves to ensure the surface equipment was not leaking. Retest(Good Test).,Bleed Presure off the IA until GLM#1 shears(good),Rig down Landing Jnt.and Test equipment install TWC and test 1000 psi. N/D BOP's,Hauled 58 bbls to G&I.Total=13692 bbls Hauled 0 bbls to Pad 3.Total=3370 bbls Hauled 0 bbls of H2O F/L-Pad Lake.Total= 15280 bbls Hauled 570 bbls of H2O FNern Lake.Total=7393 bbls Hauled S70bbls to B-50.Total=3525 bbls.,Fluid lost to well in last 24hrs=374 bbls Total fluid lost to well=1284 bbls. Fuel Receive=0 gallons Daily fuel used=600 gallons Fuel on hand= 15,950 gallons 8/15/2015 Continue to N/D BOPs. Cleaning pits and emptying Rain 4 rent tanks.,Land,N/U and test Tree.Pull TWC. Welding in Pit 4 to repair suction line between pit 4 and pill pit.Continue rigging up 20 man camp.,Rig up Little red services.Pump 175 bbls freeze protect down IA. Release little red services.Allow well to U-Tube.Crane Geo Pilot equipment to rig floor.Continue welding in the pits.Continue preping yard for rig move.Lay out rig Mats behind rig.We will mat all the way to L-46.,Allow well to U-Tube.Crane Geo Pilot equipment to rig floor.Continue welding in the pits.Continue preping yard for rig move.Lay out rig Mats behind rig.We will mat all the way to L-46.,Secure L-49 and release Nordic 3 @ 18:00 from MPU L-49 8-15-2015 • • \ \ © { \ . { \ � \ / v } � � \ Hilc o r p Energy Company \ \ \ Mine Point \ / M P L Pad MPL-49 500292354500 \ \ \ 500292354500 \ \ } � } 7 \ } \ \ ƒ \ { f Sperry Drilling \ \ \ Definitive Survey Report \ \ \ \ \ \ 18 September, 2015 \ \ \ \ \ 0 \ \ \ \ \ � { \ \ ¢ , \ \ \ \ ? < Kff \ \ � « « \ 1 \ \ ) \ \ \ \ \ \ HALLJBURTON 6 « » Sperry Drilling 1 \ • Halliburton • Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPL-49 Project: Milne Point TVD Reference: As-Built MPL-49 @ 47.00usft(Nordic 3(30 KB+47 GL)) Site: M Pt L Pad MD Reference: As-Built MPL-49 @ 47.00usft(Nordic 3(30 KB+47 GL)) Well: MPL-49 North Reference: True Wellbore: MPL-49 Survey Calculation Method: Minimum Curvature Design: MPL-49 Database: Sperry EDM-NORTH US+CANADA Project Milne Point,ACT,MILNE POINT Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well MPL-49 Well Position +N/-S 0.00 usft Northing: 6,031,591.23 usft Latitude: 70°29'49.816 N +E/-W 0.00 usft Easting: 545,185.00 usft Longitude: 149°37'49.801 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 17.00 usft Wellbore MPL-49 IMagnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 7/15/2015 19.01 81.08 57,506 Design MPL-49 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 30.00 Vertical Section: Depth From(TVD) +NI-S +E/-W Direction (usft) (usft) (usft) (°) 30.00 0.00 0.00 136.83 Survey Program Date 9/17/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 75.00 411.00 Survey#1 (MPL-49) SRG-SS Surface readout gyro single shot 07/14/2015 505.69 693.12 MPL-49 MWD+SC+SAG(1)(MPL-49) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 07/20/2015 789.17 789.17 MPL-49 Interp Azm+sag(MPL-49) MWD_Interp Azi+sag Fixed:v2.std dec with interpolated azimuth+sag 08/11/2015 879.93 5,923.52 MPL-49 MWD+SC+SAG(2)(MPL-49) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 07/31/2015 6,011.01 12,432.73 MPL-49 MWD+SC+SAG(3)(MPL-49) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 08/11/2015 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 30.00 0.00 0.00 30.00 -17.00 0.00 0.00 6,031,591.23 545,185.00 0.00 0.00 UNDEFINED 75.00 0.19 153.70 75.00 28.00 -0.07 0.03 6,031,591.16 545,185.03 0.42 0.07 SRG-SS(1) 137.00 0.26 117.16 137.00 90.00 -0.22 0.20 6,031,591.01 545,185.21 0.25 0.30 SRG-SS(1) 226.00 0.38 71.72 226.00 179.00 -0.22 0.66 6,031,591.01 545,185.66 0.30 0.62 SRG-SS(1) 320.00 0.45 62.52 320.00 273.00 0.05 1.29 6,031,591.28 545,186.29 0.10 0.85 SRG-SS(1) 411.00 0.48 54.18 410.99 363.99 0.43 1.91 6,031,591.67 545,186.91 0.08 0.99 SRG-SS(1) 505.69 0.77 25.57 505.68 458.68 1.24 2.51 6,031,592.48 545,187.50 0.44 0.81 MWD+IFR2+MS+sag(2) 601.55 0.46 42.04 601.53 554.53 2.11 3.05 6,031,593.35 545,188.03 0.37 0.55 MWD+IFR2+MS+sag(2) 693.12 0.52 44.51 693.10 646.10 2.68 3.58 6,031,593.93 545,188.57 0.07 0.50 MWD+IFR2+MS+sag(2) 789.17 0.90 155.25 789.14 742.14 2.30 4.20 6,031,593.56 545,189.19 1.24 1.20 MWD_InterpAzi+sag(3) 9/18/2015 12:47:31PM Page 2 COMPASS 5000.1 Build 73 • Halliburton • Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPL-49 Project: Milne Point TVD Reference: As-Built MPL-49 @ 47.00usft(Nordic 3(30 KB+47 GL))£' Site: M Pt L Pad MD Reference: As-Built MPL-49©47.00usft(Nordic 3(30 KB+47 GL)) Well: MPL-49 North Reference: True Wellbore: MPL-49 Survey Calculation Method: Minimum Curvature Design: MPL-49 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E1-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (1100') (ft) Survey Tool Name 879.93 4.88 160.57 879.77 832.77 -1.99 5.79 6,031,589.28 545 190.80 4.39 5.41 MWD+IFR2+MS+sag(4) 975.47 5.97 161.88 974.88 927.88 -10.54 8.68 6,031,580.74 545,193.75 1.15 13.63 MWD+IFR2+MS+sag(4) 1,071.30 8.22 170.04 1,069.97 1,022.97 -22.03 11.42. 6,031,569.27 545,196.55 2.57 23.88 MWD+IFR2+MS+sag(4) 1,165.83 10.24 176.49 1,163.28 1,116.28 -37.07 13.10 6,031,554.24 545,198.33 2.40 36.00 MWD+IFR2+MS+sag(4) 1,260.38 12.53 194.22 1,255.99 1,208.99 -55.41 11.10 6,031,535.89 545,196.43 4.40 48.01 MWD+IFR2+MS+sag(4) 1,355.69 17.70 207.95 1,348.00 1,301.00 -78.25 1.76 6,031,512.99 545,187.23 6.56 58.28 MWD+IFR2+MS+sag(4) 1,449.26 20.78 211.80 1,436.34 1,389.34 -104.93 -13.66 6,031,486.22 545,171.98 3.56 67.19 MWD+IFR2+MS+sag(4) 1,543.07 20.61 212.27 1,524.09 1,477.09 -133.04 -31.24 6,031,458.02 545,154.57 0.25 75.65 MWD+IFR2+MS+sag(4) 1,638.10 24.63 218.35 1,611.81 1,564.81 -162.73 -52.47 6,031,428.20 545,133.52 4.89 82.78 MWD+IFR2+MS+sag(4) 1,732.96 30.00 221.16 1,696.06 1,649.06 -196.11 -80.37 6,031,394.66 545,105.83 5.82 88.04 MWD+IFR2+MS+sag(4) 1,825.31 32.22 220.17 1,775.13 1,728.13 -232.31 -111.45 6,031,358.27 545,074.98 2.47 93.18 MWD+IFR2+MS+sag(4) 1,921.81 34.26 219.05 1,855.83 1,808.83 -273.06 -145.16 6,031,317.32 545,041.52 2.21 99.84 MWD+IFR2+MS+sag(4) 2,016.13 38.12 217.76 1,931.94 1,884.94 -316.71 -179.72 6,031,273.46 545,007.22 4.17 108.03 MWD+IFR2+MS+sag(4) 2,109.24 39.45 219.23 2,004.52 1,957.52 -362.35 -216.03 6,031,227.61 544,971.19 1.74 116.47 MWD+IFR2+MS+sag(4) 2,205.10 42.02 220.59 2,077.15 2,030.15 -410.32 -256.18 6,031,179.40 544,931.35 2.84 123.99 MWD+IFR2+MS+sag(4) 2,298.98 41.79 219.30 2,147.03 2,100.03 -458.38 -296.43 6,031,131.10 544,891.39 0.95 131.50 MWD+IFR2+MS+sag(4) 2,394.22 43.02 217.57 2,217.35 2,170.35 -508.70 -336.35 6,031,080.55 544,851.78 1.78 140.89 MWD+IFR2+MS+sag(4) 2,489.27 42.45 217.88 2,287.17 2,240.17 -559.71 -375.81 6,031,029.30 544,812.63 0.64 151.10 MWD+IFR2+MS+sag(4) 2,583.17 41.80 218.43 2,356.81 2,309.81 -609.24 -414.72 6,030,979.54 544,774.03 0.80 160.60 MWD+IFR2+MS+sag(4) 2,677.03 42.11 218.76 2,426.61 2,379.61 -658.28 -453.87 6,030,930.26 544,735.19 0.41 169.59 MWD+IFR2+MS+sag(4) 2,771.83 41.88 218.45 2,497.07 2,450.07 -707.85 -493.44 6,030,880.46 544,695.92 0.33 178.66 MWD+IFR2+MS+sag(4) 2,866.59 40.99 220.11 2,568.11 2,521.11 -756.39 -533.13 6,030,831.69 544,656.53 1.49 186.91 MWD+11R2+MS+sag(4) 2,960.40 41.88 217.74 2,638.44 2,591.44 -804.69 -572.12 6,030,783.16 544,617.83 1.92 195.45 MWD+IFR2+MS+sag(4) 3,054.98 42.26 216.37 2,708.65 2,661.65 -855.26 -610.31 6,030,732.36 544,579.96 1.05 206.22 MWD+IFR2+MS+sag(4) 3,149.16 42.36 216.14 2,778.30 2,731.30 -906.38 -647.80 6,030,681.01 544,542.79 0.20 217.85 MWD+IFR2+MS+sag(4) 3,243.21 42.40 215.75 2,847.78 2,800.78 -957.71 -685.01 6,030,629.47 544,505.89 0.28 229.82 MWD+IFR2+MS+sag(4) 3,338.51 42.35 215.99 2,918.18 2,871.18 -1,009.76 -722.65 6,030,577.20 544,468.58 0.18 242.03 MWD+IFR2+MS+sag(4) 3,432.52 42.37 215.70 2,987.64 2,940.64 -1,061.10 -759.74 6,030,525.63 544,431.80 0.21 254.10 MWD+IFR2+MS+sag(4) 3,526.80 41.45 214.66 3,057.81 3,010.81 -1,112.57 -796.02 6,030,473.95 544,395.83 1.22 266.81 MWD+IFR2+MS+sag(4) 3,621.10 41.69 208.68 3,128.39 3,081.39 -1,165.78 -828.84 6,030,420.55 544,363.34 4.21 283.17 MWD+IFR2+MS+sag(4) 3,716.29 43.10 201.17 3,198.73 3,151.73 -1,223.91 -855.79 6,030,362.26 544,336.75 5.52 307.13 MWD+IFR2+MS+sag(4) 3,809.90 42.86 197.18 3,267.23 3,220.23 -1,284.16 -876.75 6,030,301.89 544,316.16 2.92 336.73 MWD+IFR2+MS+sag(4) 3,904.63 42.93 190.84 3,336.66 3,289.66 -1,346.66 -892.34 6,030,239.30 544,300.95 4.55 371.65 MWD+IFR2+MS+sag(4) 3,998.24 43.80 183.77 3,404.75 3,357.75 -1,410.33 -900.47 6,030,175.59 544,293.21 5.27 412.52 MWD+IFR2+MS+sag(4) 4,093.42 42.21 176.41 3,474.40 3,427.40 -1,475.16 -900.64 6,030,110.77 544,293.44 5.53 459.69 MWD+IFR2+MS+sag(4) 4,187.22 43.06 168.46 3,543.46 3,496.46 -1,538.03 -892.25 6,030,047.96 544,302.20 5.81 511.28 MWD+IFR2+MS+sag(4) 4,281.79 45.26 163.27 3,611.32 3,564.32 -1,601.85 -876.12 6,029,984.24 544,318.72 4.47 568.87 MWD+IFR2+MS+sag(4) 4,376.25 46.68 158.82 3,676.99 3,629.99 -1,666.04 -854.04 6,029,920.19 544,341.19 3.71 630.79 MWD+IFR2+MS+sag(4) 4,470.87 50.02 153.30 3,739.89 3,692.89 -1,730.57 -825.29 6,029,855.85 544,370.32 5.61 697.51 MWD+IFR2+MS+sag(4) 4,563.56 52.17 150.49 3,798.10 3,751.10 -1,794.17 -791.30 6,029,792.46 544,404.70 3.31 767.16 MWD+IFR2+MS+sag(4) 9/18/2015 12:47:31PM Page 3 COMPASS 5000.1 Build 73 • Halli • burton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPL-49 Project: Milne Point TVD Reference: As-Built MPL-49 @ 47.00usft(Nordic 3(30 KB+47 GL)) Site: M Pt L Pad MD Reference: As-Built MPL-49 @ 47.00usft(Nordic 3(30 KB+47 GL)) Well MPL-49 North Reference: True Wellbore MPL-49 Survey Calculation Method: Minimum Curvature Design: MPL-49 Database: Sperry EDM-NORTH US+CANADA Survey lr" ,�...., .{ ,... :. .w Map x. �_ . Map Vertical �.. MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,659.45 53.49 148.14 3,856.04 3,809.04 -1,859.86 -752.30 6,029,727.01 544,444.10 2.39 841.75 MWD+IFR2+MS+sag(4) 4,754.05 57.47 143.80 3,909.66 3,862.66 -1,924.38 -708.65 6,029,662.77 544,488.13 5.65 918.67 MWD+IFR2+MS+sag(4) 4,847.30 60.49 141.92 3,957.71 3,910.71 -1,988.06 -660.39 6,029,599.39 544,536.77 3.67 998.13 MWD+IFR2+MS+sag(4) 4,942.42 66.72 136.87 4,000.00 3,953.00 -2,052.62 -604.91 6,029,535.17 544,592.64 8.09 1,083.17 MWD+IFR2+MS+sag(4) 5,036.09 67.88 135.39 4,036.15 3,989.15 -2,114.91 -545.02 6,029,473.25 54.4,652.90 1.91 1,169.58 MWD+IFR2+MS+sag(4) 5,131.68 71.14 132.88 4,069.61 4,022.61 -2,177.23 -480.76 6,029,411.33 544,717.53 4.20 1,259.00 MWD+IFR2+MS+sag(4) 5,225.31 75.59 130.09 4,096.41 4,049.41 -2,236.62 -413.56 6,029,352.36 544,785.08 5.54 1,348.28 MWD+IFR2+MS+sag(4) 5,319.98 80.93 128.16 4,115.67 4,068.67 -2,295.07 -341.68 6,029,294.35 544,857.32 5.98 1,440.10 MWD+IFR2+MS+sag(4) 5,413.89 82.12 123.33 4,129.52 4,082.52 -2,349.31 -266.31 6,029,240.57 544,933.00 5.24 1,531.22 MWD+IFR2+MS+sag(4) 5,509.90 80.96 120.60 4,143.64 4,096.64 -2,399.58 -185.75 6,029,190.80 545,013.85 3.06 1,622.99 MWD+IFR2+MS+sag(4) 5,603.43 79.76 120.34 4,159.31 4,112.31 -2,446.34 -106.28 6,029,144.53 545,093.60 1.31 1,711.47 MWD+IFR2+MS+sag(4) 5,697.63 82.56 119.91 4,173.78 4,126.78 -2,493.05 -25.78 6,029,098.31 545,174.38 3.01 1,800.61 MWD+IFR2+MS+sag(4) 5,791.89 85.47 119.52 4,183.61 4,136.61 -2,539.51 55.63 6,029,052.35 545,256.06 3.11 1,890.20 MWD+IFR2+MS+sag(4) 5,886.03 84.94 119.77 4,191.48 4,144.48 -2,585.91 137.16 6,029,006.45 545,337.86 0.62 1,979.82 MWD+IFR2+MS+sag(4) 5,923.52 83.46 119.57 4,195.27 4,148.27 -2,604.38 169.57 6,028,988.19 545,370.38 3.98 2,015.46 MWD+IFR2+MS+sag(4) 6,011.01 86.73 117.26 4,202.75 4,155.75 -2,645.84 246.22 6,028,947.19 545,447.28 4.57 2,098.14 MWD+IFR2+MS+sag(5) 6,055.44 87.65 117.65 4,204.92 4,157.92 -2,666.30 285.60 6,028,926.97 545,486.77 2.25 2,140.01 MWD+IFR2+MS+sag(5) 6,149.73 88.21 117.48 4,208.33 4,161.33 -2,709.91 369.13 6,028,883.88 545,570.56 0.62 2,228.96 MWD+IFR2+MS+sag(5) 6,245.55 87.78 118.83 4,211.68 4,164.68 -2,755.09 453.56 6,028,839.21 545,655.25 1.48 2,319.67 MWD+IFR2+MS+sag(5) 6,339.53 87.10 121.64 4,215.88 4,168.88 -2,802.36 534.67 6,028,792.44 545,736.64 3.07 2,409.64 MWD+IFR2+MS+sag(5) 6,434.13 86.54 123.34 4,221.13 4,174.13 -2,853.10 614.33 6,028,742.20 545,816.61 1.89 2,501.15 MWD+IFR2+MS+sag(5) 6,527.46 89.63 125.04 4,224.25 4,177.25 -2,905.51 691.48 6,028,690.26 545,894.06 3.78 2,592.15 MWD+IFR2+MS+sag(5) 6,622.81 90.74 125.59 4,223.94 4,176.94 -2,960.62 769.28 6,028,635.63 545,972.19 1.30 2,665.58 MWD+IFR2+MS+sag(5) 6,717.02 90.86 126.46 4,222.62 4,175.62 -3,016.03 845.47 6,028,580.69 546,048.70 0.93 2,778.11 MWD+IFR2+MS+sag(5) 6,812.17 92.04 125.64 4,220.22 4,173.22 -3,072.00 922.37 6,028,525.19 546,125.94 1.51 2,871.55 MWD+IFR2+MS+sag(5) 6,906.67 89.57 124.31 4,218.89 4,171.89 -3,126.16 999.79 6,028,471.51 546,203.67 2.97 2,964.01 MWD+IFR2+MS+sag(5) 7,001.20 89.14 124.22 4,219.95 4,172.95 -3,179.38 1,077.91 6,028,418.77 546,282.11 0.46 3,056.27 MWD+IFR2+MS+sag(5) 7,095.31 89.51 123.31 4,221.06 4,174.06 -3,231.68 1,156.14 6,028,366.95 546,360.65 1.04 3,147.94 MWD+IFR2+MS+sag(5) 7,189.84 89.32 123.17 4,222.03 4,175.03 -3,283.49 1,235.19 6,028,315.62 546,440.01 0.25 3,239.82 MWD+IFR2+MS+sag(5) 7,283.99 90.80 123.38 4,221.93 4,174.93 -3,335.15 1,313.91 6,028,264.45 546,519.03 1.59 3,331.34 MWD+IFR2+MS+sag(5) 7,378.61 91.73 122.92 4,219.84 4,172.84 -3,386.88 1,393.11 6,028,213.21 546,598.53 1.10 3,423.26 MWD+IFR2+MS+sag(5) 7,472.87 92.29 122.69 4,216.53 4,169.53 -3,437.91 1,472.28 6,028,162.66 546,678.01 0.64 3,514.65 MWD+IFR2+MS+sag(5) 7,566.24 95.32 122.32 4,210.34 4,163.34 -3,487.97 1,550.84 6,028,113.09 546,756.87 3.27 3,604.91 MWD+IFR2+MS+sag(5) 7,661.35 93.27 120.64 4,203.21 4,156.21 -3,537.49 1,631.72 6,028,064.07 546,838.03 2.78 3,696.36 MWD+IFR2+MS+sag(5) 7,755.91 90.86 119.58 4,199.81 4,152.81 -3,584.90 1,713.46 6,028,017.17 546,920.05 2.78 3,786.85 MWD+IFR2+MS+sag(5) 7,850.28 88.33 118.94 4,200.47 4,153.47 -3,631.02 1,795.78 6,027,971.55 547,002.64 2.77 3,876.81 MWD+IFR2+MS+sag(5) 7,945.12 86.04 119.17 4,205.13 4,158.13 -3,677.02 1,878.58 6,027,926.06 547,085.71 2.43 3,967.01 MWD+IFR2+MS+sag(5) 8,039.36 85.86 118.95 4,211.79 4,164.79 -3,722.68 1,960.75 6,027,880.90 547,168.15 0.30 4,056.53 MWD+IFR2+MS+sag(5) 8,133.28 84.50 118.78 4,219.68 4,172.68 -3,767.85 2,042.71 6,027,836.23 547,250.38 1.46 4,145.55 MWD+IFR2+MS+sag(5) 8,228.12 83.69 118.74 4,229.44 4,182.44 -3,813.24 2,125.41 6,027,791.35 547,333.34 0.86 4,235.23 MWD+IFR2+MS+sag(5) 9/18/2015 12:47:31PM Page 4 COMPASS 5000.1 Build 73 • Halliburton • Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPL-49 Project: Milne Point TVD Reference: As-Built MPL-49 @ 47.00usft(Nordic 3(30 KB+47 GL)) Site: M Pt L Pad MD Reference: As-Built MPL-49 @ 47.00usft(Nordic 3(30 KB+47 GL)) Well: MPL-49 North Reference: True Wellbore: MPL-49 Survey Calculation Method: Minimum Curvature Design: MPL-49 Database: Sperry EDM-NORTH US+CANADA Surveyafr a Map A'°" Map Vertical MD Inc Azi TVD TVDSS +N/-S ' +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) ((aft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,322.91 86.54 119.79 4,237.51 4,190.51 -3,859.41 2,207.79 6,027,745.69 547 415.99 3.20 4,325.26 MWD+IFR2+MS+sag(5) 8,417.16 87.10 120.48 4,242.74 4,195.74 -3,906.65 2,289.18 6,027,698.95 547,497.66 0.94 4,415.40 MWD+IFR2+MS+sag(5) 8,512.36 88.71 121.99 4,246.22 4,199.22 -3,955.98 2,370.52 6,027,650.11 547,579.29 2.32 4,507.03 MWD+IFR2+MS+sag(5) 8,605.03 89.38 122.42 4,247.76 4,200.76 -4,005.37 2,448.92 6,027,601.22 547,657.98 0.86 4,596.68 MWD+IFR2+MS+sag(5) 8,698.81 94.94 123.93 4,244.23 4,197.23 -4,056.62 2,527.32 6,027,550.44 547,736.69 6.14 4,687.71 MWD+IFR2+MS+sag(5) 8,793.49 94.08 123.35 4,236.78 4,189.78 -4,108.91 2,605.90 6,027,498.64 547,815.58 1.09 4,779.61 MWD+IFR2+MS+sag(5) 8,888.48 93.70 123.35 4,230.34 4,183.34 -4,161.01 2,685.07 6,027,447.03 547,895.05 0.40 4,871.77 MWD+IFR2+MS+sag(5) 8,982.76 91.17 122.21 4,226.33 4,179.33 -4,212.00 2,764.26 6,027,396.52 547,974.54 2.94 4,963.13 MWD+IFR2+MS+sag(5) 9,075.95 89.51 121.34 4,225.78 4,178.78 -4,261.07 2,843.47 6,027,347.94 548,054.04 2.01 5,053.12 MWD+IFR2+MS+sag(5) 9,172.30 88.02 120.31 4,227.86 4,180.86 -4,310.43 2,926.19 6,027,299.09 548,137.05 1.88 5,145.71 MWD+IFR2+MS+sag(5) 9,266.87 88.70 120.28 4,230.56 4,183.56 -4,358.12 3,007.81 6,027,251.90 548,218.95 0.72 5,236.33 MWD+IFR2+MS+sag(5) 9,357.87 87.16 120.58 4,233.85 4,186.85 -4,404.17 3,086.22 6,027,206.33 548,297.63 1.72 5,323.57 MWD+IFR2+MS+sag(5) 9,452.92 87.78 121.79 4,238.05 4,191.05 -4,453.34 3,167.46 6,027,157.66 548,379.16 1.43 5,415.01 MWD+IFR2+MS+sag(5) 9,547.37 88.33 122.12 4,241.25 4,194.25 -4,503.30 3,247.55 6,027,108.19 548,459.54 0.68 5,506.24 MWD+IFR2+MS+sag(5) 9,642.10 88.09 121.51 4,244.21 4,197.21 -4,553.22 3,328.00 6,027,058.77 548,540.29 0.69 5,597.69 MWD+IFR2+MS+sag(5) 9,736.63 91.23 122.82 4,244.77 4,197.77 -4,603.53 3,408.01 6,027,008.95 548,620.60 3.60 5,689.12 MWD+IFR2+MS+sag(5) 9,830.93 90.25 121.83 4,243.55 4,196.55 -4,653.95 3,487.69 6,026,959.02 548,700.57 1.48 5,780.41 MWD+IFR2+MS+sag(5) 9,925.21 91.91 121.47 4,241.78 4,194.78 -4,703.41 3,567.93 6,026,910.05 548,781.11 1.80 5,871.38 MWD+IFR2+MS+sag(5) 10,020.05 92.35 121.00 4,238.25 4,191.25 -4,752.56 3,648.97 6,026,861.41 548,862.43 0.68 5,962.66 MWD+IFR2+MS+sag(5) 10,111.89 91.42 119.44 4,235.23 4,188.23 -4,798.75 3,728.28 6,026,815.70 548,942.02 1.98 6,050.62 MWD+IFR2+MS+sag(5) 10,208.37 91.05 119.84 4,233.15 4,186.15 -4,846.46 3,812.12 6,026,768.51 549,026.13 0.56 6,142.77 MWD+IFR2+MS+sag(5) 10,303.42 92.29 121.52 4,230.38 4,183.38 -4,894.93 3,893.82 6,026,720.54 549,108.12 2.20 6,234.02 MWD+IFR2+MS+sag(5) 10,396.89 89.51 119.99 4,228.91 4,181.91 -4,942.72 3,974.13 6,026,673.24 549,188.71 3.39 6,323.82 MWD+IFR2+MS+sag(5) 10,490.99 91.42 121.41 4,228.15 4,181.15 -4,990.75 4,055.03 6,026,625.70 549,269.90 2.53 6,414.20 MWD+IFR2+MS+sag(5) 10,585.48 89.75 122.91 4,227.18 4,180.18 -5,041.04 4,135.01 6,026,575.91 549,350.18 2.38 6,505.60 MWD+IFR2+MS+sag(5) 10,679.65 91.61 124.89 4,226.07 4,179.07 -5,093.56 4,213.16 6,026,523.87 549,428.63 2.88 6,597.37 MWD+IFR2+MS+sag(5) 10,774.36 89.26 124.26 4,225.35 4,178.35 -5,147.30 4,291.14 6,026,470.61 549,506.93 2.57 6,689.91 MWD+IFR2+MS+sag(5) 10,868.72 88.39 122.48 4,227.28 4,180.28 -5,199.19 4,369.92 6,026,419.21 549,586.02 2.10 6,781.66 MWD+IFR2+MS+sag(5) 10,963.19 89.38 122.04 4,229.12 4,182.12 -5,249.60 4,449.79 6,026,369.29 549,666.18 1.15 6,873.07 MWD+IFR2+MS+sag(5) 11,058.02 91.48 122.07 4,228.41 4,181.41 -5,299.93 4,530.16 6,026,319.46 549,746.85 2.21 6,964.76 MWD+IFR2+MS+sag(5) 11,151.70 92.90 121.92 4,224.83 4,177.83 -5,349.53 4,609.55 6,026,270.35 549,826.53 1.52 7,055.24 MWD+IFR2+MS+sag(5) 11,246.21 92.04 121.31 4,220.76 4,173.76 -5,399.02 4,689.95 6,026,221.34 549,907.23 1.12 7,146.36 MWD+IFR2+MS+sag(5) 11,336.83 92.78 120.74 4,216.95 4,169.95 -5,445.69 4,767.54 6,026,175.16 549,985.09 1.03 7,233.47 MWD+IFR2+MS+sag(5) 11,431.25 91.24 120.22 4,213.63 4,166.63 -5,493.55 4,848.86 6,026,127.79 550,066.69 1.72 7,324.01 MWD+IFR2+MS+sag(5) 11,524.50 88.70 118.48 4,213.68 4,166.68 -5,539.25 4,930.13 6,026,082.59 550,148.23 3.30 7,412.95 MWD+IFR2+MS+sag(5) 11,619.57 88.27 118.19 4,216.20 4,169.20 -5,584.36 5,013.78 6,026,038.00 550,232.14 0.55 7,503.08 MWD+IFR2+MS+sag(5) 11,713.59 90.37 120.05 4,217.31 4,170.31 -5,630.10 5,095.90 6,025,992.76 550,314.53 2.98 7,592.62 MWD+IFR2+MS+sag(5) 11,807.76 93.34 121.28 4,214.26 4,167.26 -5,678.10 5,176.85 6,025,945.26 550,395.76 3.41 7,683.01 MWD+IFR2+MS+sag(5) 11,902.01 92.22 120.81 4,209.69 4,162.69 -5,726.65 5,257.50 6,025,897.21 550,476.70 1.29 7,773.60 MWD+IFR2+MS+sag(5) 11,995.80 90.68 121.27 4,207.32 4,160.32 -5,774.99 5,337.84 6,025,849.36 550,557.32 1.71 7,863.82 MWD+IFR2+MS+sag(5) 9/18/2015 12:47:31PM Page 5 COMPASS 5000.1 Build 73 • Halliburton • Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPL-49 Project: Milne Point TVD Reference: As-Built MPL-49 @ 47.00usft(Nordic 3(30 KB+47 GL)) Site: M Pt L Pad MD Reference: As-Built MPL-49 @ 47.00usft(Nordic 3(30 KB+47 GL)) Well: MPL-49 North Reference: True Wellbore: MPL-49 Survey Calculation Method: Minimum Curvature Design: MPL-49 Database: Sperry EDM-NORTH US+CANADA Survey . ,,,,:e',.,:nilitis:. +:' ,',1 i,n,..."-,V,illitedr,011,.41,.:16.1':.:',,Cr ,',,to''',',7±tet.fetnitl1/4:St:.v4"4,'' -i-.44117.4;itittiatttg;,';',,',.,-:'.•,.;.;.y. 4",1-'1:,,,./.,44,44,4S,S;,7, Map 44iiiiiiitiaZilii: ';:iiiii#011:',44'i7?,25#31414:4,:.0'::;fiA*Mittlf4:141.thit' 6'14,,14;+.1..$11101%.* :' Vertical .. MD Inc Azi TVD TVDSS ...e.."+N1-S +EI-W Northing Easting DLS Section .:,......:Au (usft) () (°) (usft) (usft) ' (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 12,092.05 88.95 120.67 4,207.63 4,160.63 -5,824.52 5,420.36 6,025,800.34 550,640.14 1.90 7,956.40 MWD+IFR2+MS+sag(5) 12,183.36 89.20 119.15 4,209.11 4,162.11 -5,870.04 5,499.50 6,025,755.30 550,719.54 1.69 8,043.74 MWD+IFR2+MS+sag(5) 12,280.65 92.04 119.61 4,208.05 4,161.05 -5,917.76 5,584.26 6,025,708.10 550,804.58 2.96 8,136.54 MWD+IFR2+MS+sag(5) 12,374.33 93.71 118.75 4203.35 4,156.35 -5,963.38 5,665.94 6,025,662.98 550,886,53 2.00 8,225.69 MWD+IFR2+MS+sag(5) 12,432.73 92.90 117.53 4.199.99 4,152.99 -5,990.87 5,717.35 6,025,635.80 550,938.11 2.50 8,280.92 MWD+IFR2+MS+sag(5) 12,500.00 92.90 117.53 4,196.58 4,149.58 -6,021.93 5,776.93 6,025,605.12 550,997.86 0.00 8,344.33 PROJECTED to TD Checked By: n.com ..,,0=77.,Z7ZrApproved By: cary taylor@hallthurton.com ,,,t:70=,,,,ts=7J:..;.,:;.- Date: 9/18/2015 12:47:31PM Page 6 COMPASS 5000 1 Build 73 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaq(dlalaska.dov: doa.aogcc.prudhoe.bay(dalaska.gov: phoebe.brooks(8talaska.00v OPERATOR: Hilcorp Alaska LLC FIELD/UNIT/PAD: Milne Point/MPU/L DATE: 09/29/15 OPERATOR REP: Matt Linder AOGCC REP: Jeff Jones Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well MPL-49 Type lnj. W ND 4,140' Tubing 265 269 _ 275 278 Interval 1 P.T.D. 2150990 Type test P , Test psi 1500 Casing 258 1,813 1,762 1,747 P/F P Notes: Initial AOGCC MIT-IA for new drill well.2.5 bbls OA 0 1 2 2 dies)to reach test pressure Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing _ Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi, CasingP/F Notes: OA Well Type lnj. ND Tubing_ Interval P.T.D. Type test Test psi Casing P/F • Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 02/2012) MIT MPU L-49 09-29-15 State Witnessed Post rig III 1110 Hilcorp Energy Company CASING&CEMENTING REPORT Lease&Well No. Milne Point Unit,L-49 Date 26-Jul-15 County North Slope Borough State Alaska Supv. Sloan Sunderland/Lenward Toussan CASING RECORD TD 5970.00 Shoe Depth: 5955.16 PBTD: 5,856.53' Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top Shoe 95/8 TC-II DHP 1.85 5,955.16 5,953.31 1 int 9 5/8 40 L-80 TC-II 37.67 5,953.31 5,915.64 Flt Clr 9 5/8 TC-II DHP 1.17 5,915.64 5,914.47 I int 9 5/8 40 L-80 TC-II 39.35 5,914.47 5,875.12 Pup XO 9 5/8 40 L-80 TC-II 16.62 5,875.12 5,858.50 BFL 9 5/8 40 L-80 BTC 1.97 5,858.50 5,856.53 Pup XO 9 5/8 40 L-80 TC-Il 16.56 5,856.53 5,839.97 92 ints 9 5/8 40 L-80 TC-II 3,557.83 2,322.39 2,282.14 Pup XO 9 5/8 40 L-80 TC-II 16.58 2,282.14 2,265.56 ES CMT 9 5/8 40 L-80 BTC 3.12 2,265.56 2,262.44 _ Pup XO 9 5/8 40 L780 TC-II 17.04 2,262.44 2,245.40 57 ints 9 5/8 TC-II 2,212.03 2,245.40 33.37 Hgr w/pup 9 5/8 40 L-80 TC-II Seaboard 2.62 33.37 30.75 RKB 9 5/8 BTC 30.75 30.75 0.00 Totals 149 lots Csg Wt.On Hook: 115 Type Float Collar: _ Model 402 No.Hrs to Run: 12 Csg Wt.On Slips: 85 Type of Shoe: Bull Nose Casing Crew: WFD Fluid Description: 9.3 ppg Spud Mud, YP 24 Liner hanger Info(Make/Model): Liner top Packer?: _Yes X No Liner hanger test pressure: 0 Centralizer Placement: 2 bowspring on shoe jnt,1 centralizer middle FC Joint, 1 centralizers every other jnt to 15, Plus 3 above and below the ES Cmt Tool.17 Total CEMENTING REPORT Preflush(Spacer) Type: Tuned Spacer III Density(ppg) 10.5 Volume pumped(BBLs) 60 Lead Slurry Type: Extended Density(ppg) 12 Volume pumped(BBLs) 183 Mixing/Pumping Rate(bpm): 4 Tail Slurry Type: Swift Chem Stage 1 Density(ppg) 15.8 Volume pumped(BBLs) 84 Mixing/Pumping Rate(bpm): 4 y Post Flush(Spacer) rc Type:Fresh Water Density(ppg) 8.3 Rate(bpm): 5 Volume: 20 LL Displacement: Type: Spud Mud Density(ppg) 9.3 Rate(bpm): 6 Volume(actual/calculated): 447/444 FCP(psi): 1150 Pump used for disp: Halliburton Plug Bumped? Yes x No Bump press Casing Rotated? Yes X No Reciprocated? Yes X No %Returns during job 100 Cement returns to surface? x Yes_No Spacer returns? X Yes No Vol to Surf: 30 Cement In Place At 14:30 Date: 7/25/2015 Estimated TOC: 2,262 Method Used To Determine TOC: ES Cmt tool Preflush(Spacer) Type: Tuned Spacer III Density(ppg) 10.5 Volume pumped(BBLs) _ 60 Lead Slurry Type: Permafrost L Stage 2 Lead Density(ppg) 11.1 Volume pumped(BBLs) 303 Mixing/Pumping Rate(bpm): 4 Tail Slurry w Type: Swift Chem-Stage 2 Lead a Density(ppg) 15.8 Volume pumped(BBLs) 70 Mixing/Pumping Rate(bpm): 4 N Post Flush(Spacer) 0 Type: Density(ppg) Rate(bpm): Volume: iu w Displacement: Type: Spud Mud Density(ppg) 9.3 Rate(bpm): 4 Volume(actual/calculated): 179/174 FCP(psi): 750 Pump used for disp: Halliburton Plug Bumped? X Yes No Bump press 2200 Casing Rotated? Yes _No Reciprocated? _Yes_No %Returns during job 100 Cement returns to surface? x Yes_No Spacer returns? x Yes_No Vol to Surf: 240 Cement In Place At: 4:39 Date: 7/26/2015 Estimated TOC: 0 Method Used To Determine TOC: Returns to surface WELLHEAD Make Seaboard Type 3000 psi Wellhead Serial No. Size W.P. Test Head To PSIG MIN OK Remarks: We finished both stages with cmt returned to surface. • • MPL-49 Days vs Depth 0 500 --MPL-49 Actual — 1000 -1111 .MPL-49 Plan 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 a 0 6500 v a 7000 - 3 Al 7500 2 8000 8500 9000 9500 10000 10500 11000 11500 12000 12500 13000 13500 _ 0 5 10 15 20 25 30 35 Days S MPL-49 MW vs Depth 0 MPL-49 Plan 1000 v- — MPL-49 Actual 2000 3000 4000 1[5000 -• 6000 v -C v n 7000 co ca) C 8000 9000 10000 I 11000 12000 13000 8.0 9.0 10.0 11.0 12.0 13.0 14.0 Mud Density(ppg) • • Brooks, Phoebe L (DOA) PrD 2-1s09/0 From: Regg, James B (DOA) Sent: Thursday, October 01, 2015 10:05 AM To: Wyatt Rivard Cc: Brooks, Phoebe L(DOA) Subject: RE: Milne Point MITs on 9/29/15 Thank you for including the current well schematic and directional survey for MPU L-49 Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 orjim.regg@alaska.gov. From: Wyatt Rivard [mailto:wrivardOhilcorb.com] Sent: Wednesday, September 30, 2015 3:43 PM To: Wallace, Chris D (DOA); Brooks, Phoebe L (DOA); Regg, James B (DOA); DOA AOGCC Prudhoe Bay Cc: Alaska NS - Milne - Wellsite Supervisors; Stan Porhola Subject: Milne Point MITs on 9/29/15 All, Milne Point water injectors MPJ-13 (PTD# 1941260), MPL-49 (PTD#2150990) & MPC-02 (PTD# 1821940) had passing AOGCC witnessed MIT-lAs on 9/29/15.The MIT forms are attached for reference. MPL-49 is a new drill well, schematic and deviation survey are also attached. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 i C: (509)670-8001 wrivardPhilcorp.com 3800 Centerpeint Drive, Suite 1400 1 Anchorage,AK 99503 11 ileorp IAA a. t. 1 S • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regoaalaska.00v doa.aoacc.prudhoe.bay(falaska.00v; phoebe.brooksCa?alaska.gov OPERATOR: Hilcorp Alaska LLC FIELD/UNIT/PAD: Milne Point/MPU/L DATE: 09/29/15 OPERATOR REP: Matt Linder AOGCC REP: Jeff Jones Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well MPL-49 Type Inj. W TVD 4,140' Tubing 265 269 275 278 Interval 1 P.T.D. 2150990 Type test P Test psi 1500 Casing 258 1,813 1,762 1,747 P/F P Notes: Initial AOGCC MIT-IA for new drill well.2.5 bbls OA 0 1 2 2 dies)to reach test pressure Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well _ Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 02/2012) MIT MPU L-49 09-29-15.xls H • SCHEMATIC • PointUnit Well: MP -49 PTD:215-099 API: 50-029-23545-00-00 HiI, ,i,t1.1 .',Li: RKB:28' CASING DETAIL \ /1 Size Type Wt Grade Conn. ID Top Btm 20 A 20" Conductor 84 X-56 Weld 15.010" Surf 110' 9-5/8" Surf. Csg 40 L-80 TC II 9.625" Surf 5,955' ' 5-1/2" Prod Liner 29.7 L-80 DWC/C HT 4.892" 5,780' 12,500' TUBING DETAIL 3-1/2" Tubing 9.2 L-80 EUE 8rd 2.992" Surf 5,814' 2 JEWELRY DETAIL f,M` No. Item Top MD Btm MD ID OD 4 1 Tubing Hanger 28.42' 28.84' 2 X Nipple 2,093' 2,095' 2.813" 4.493" t ` 3 Stage Tool—ES Cementer 2,262' 2,266' 8.618" 9.625" n. P 4 GLM w/sheer valve set @ 2500 psi 2,975' 2,984' 2.920" 4.500" 4 5 PHL Packer 5,584' 5,592' 3.850" 8.450" iA 6 Ratcheting Muleshoe 5,812' 5,814 3.000" 4.760" `, k 7 Liner Top Packer 5,780' 5,801 5.000" 6.672" k 8 7"Pup&7"x 5-1/2"XO 5,801' 5,809' 4.860" 7.670" '"s 9 Injection Control Device(ICD)(12 Total) See Below See Below 4.675" 6.500" t 10 Swell Packer(9 Total—See Detail Below) See Below See Below 4.892" 8.000" ICD DETAIL SWELL PACKER DETAIL o Top(MD) Btm(MD) Top(MD) Btm(MD) t 5,995.77' 6,002.63' 6,146.10' 6,151.78' 6,457.55' 6,464.41' 7,467.23' 7,472.93' 41 6,912.68' 6,919.55' 7,855.60' 7,861.29' 7,661.01' 7,667.87' 8,336.42' 8,342.08' 01 .4 8,222.94' 8,229.80' 9,106.81' 9,112.52' 8,581.47' 8,588.34' 9,862.02' 9,867.72' 9,469.75' 9,476.64' 11,053.43' 11,059.23' 04 10,308.68' 10,315.58' 11,737.00' 11,742.70' 10,526.22' 10,533.07 12,262.02' 12.267.78' 11,463.84' 11,470.73' pi 01 11,939.57' 11,946.44' o 12.382.70' 12,389.58' $1 fir i ii 9-5/8"shoe @ Pa r n. A 5,995, • ►v�7 9 iwi 11 1�1 11 5-1/2"shoe 6 12,500' 0 -t 10 A 1 �i� aI !"..-1141417 qlq:',t.„..-3; "4 PBTD=12,500'MD/4,197'TVD TD=12,500'MD/4,197'TVD Max Deviation:'1131) Downhole Proposed Updated by CJD 8/31/15 • • HALLIBURTON DIRECTIONAL SURVEY REPORT Hilcorp Alaska, LLC MP L-49 Milne Point Unit North Slope Borough Alaska USA AK-XX-0902573352 SURVEYS TO 411' MD ARE GYRO SURVEYS. SURVEY AT 789.17' MD HAS AN INTERPOLATED AZIMUTH. ALL MWD SURVEYS ARE SAG, IIFR AND MSA CORRECTED. FINAL SURVEY IS PROJECTED TO TD. i ! a s a ± 8 a �S 4, See a 0 a a. a Sae s I sE, agI &k IrairatOK ' (degrees re T 30.00 0.00 0.00 30.00 0.00 N 0.00 E 0.00 TIE-IN 75.00 0.19 153.70 75.00 0.07 S 0.03 E 0.07 0.42 137.00 0.26 117.16 137.00 0.22 S 0.20 E 0.30 0.25 226.00 0.38 71.72 226.00 0.22 S 0.66 E 0.62 0.30 320.00 0.45 62.52 320.00 0.05 N 1.29 E 0.85 0.10 411.00 0.48 54.18 410.99 0.43 N 1.91 E 0.99 0.08 f 505.69 0.77 25.57 505.68 1.24 N 2.51 E 0.81 0.44 601.55 0.46 42.04 601.54 2.11 N 3.05 E 0.54 0.37 ' 693.12 0.52 44.51 693.10 2.68 N 3.59 E 0.50 0.06 789.17 0.90 155.25 789.15 2.30 N 4.21 E 1.20 1.24 879.93 4.88 160.57 879.77 1.99 S 5.79 E 5.41 4.39 975.47 5.97 161.88 974.88 10.54 S 8.69 E 13.63 1.15 1071.30 8.22 170.04 1069.97 22.03 S 11.42 E 23.88 2.57 1165.83 10.24 176.49 1163.27 37.08 S 13.11 E 36.01 2.40 1260.38 12.53 194.22 1255.99 55.43 S 11.10 E 48.02 4.40 e .69 17.70 207.95 1347.99 78.28 S 1.76 E 58.29 6,56 •, 6 r 20.78 211.80 1436.33 104.96 S 13.66 W 67.20 3.56 r 20.61, 212.27 1524.09 133.06 S 31.25 W 75.67 0.25 + 24.63 218.35 1611.80 162.75 S 52.47 W 82.80 1 4.89 30.00 221.16 1696.05 196.14 S 80.37 W 88.06 5.81 1825.31 32.22 220.17 1775.12 232.34 S 111.45 W 93.20 2.47 1921.81 34.26 219.05 1855.82 273.10 S 145.16 W 99.86 2.21 2016.13 38.12 217.76 1931.93 316.75 S 179.73 W 108.05 4.17 2109.24 39.45 219.23 2004.51 362.38 S 216.04 W 116.49 1.74 2205.10 42.02 220.59 2077.14 410.35 S 256.19 W 124.01 2.83 2298.98 41.79 219.30 2147.01 458.42 S 296.44 W 131.52 , . `° 2394.22 43.02 217.57 2217.33 508.73 S 336.36 W 140.91 2489.27 42.45 217.88 2287.14 559.75 S 375.82 W 151.12 0.65 2583.17 41.80 218.43 2356.79 609.28 S ' 414.73 W 160.62 0.79 2677.03 42.11 218.76 2426.59 658.32 S 453.87 W 169.61 0.40 r, 2771.83 41.88 218.45 2497.05 707.88 S 493.45 W 178.68 0.32 2866.59 40.99 220.11 2568.10 756.42 S 533.14 W 186.93 1.49 2960.40 41.88 217.74 2638.43 804.72 S 572.13 W 195.47 1.93 3054.98 42.26 216.37 2708.64 855.30 S 610.31 W 206.23 1.05 3149.16 42.36 216.14 2778.29 906.42 S 647.81 W 217.87 0.20 3243.21 42.40 215.75 2847.76 957.74 S 685.02 W 229.84 0.28 3338.51 42.35 215.99 2918.16 1009.79 S 722.66 W 242.05 0.18 3432.52 42.37 215.70 2987.63 1061.14 S 759.75 W 254.12 0.21 .. 3526.80 41.45 214.66 3057.80 1112.61 S 796.03`W 266.83 1.22 =--'''L'",0. 3621.10 41.69 208.68 3128.37 1165.81 S 828.85W 283.19 4.21 3716.29 43.10 201.17 3198.71 1223.95 S 855.80 W 307.15 5.52 3809.90 42.86 197.18 3267.21 1284.20 S 876.76 W 336.75 2.92 3904.63 42.93 190.84 3336.65 1346.69 S 892.35 W 371.66 4.55 3998.24 43.80 183.77 3404.74 1410.37 S 900.48 W 412.54 5.27 4093.42 42.21 176.41 3474.39 1475.19 S 900.64 W 459.71 5.53 4187.22 43.06 168.46 3543.45 1538.06 S 892.26 W 511.30 5.81 4281,79 45.26 163.27 3611.31 1601.88 S 876.13 W 568.88 4.47 4376.25 46.68 158.82 3676.98 1666.07 S 854.05 W 630.80 3.71 v; 4470.87 50.02 153.30 3739.88 1730.60 S 825.30 W 697,53 5.61 4563.56 52.17 150.49 3798.09 1794.20 S 791.30 W 767.17 ,,,,b, . 3.31 4659.45 53.49 148.14 3856.03 1859.89 S 752.31 W 841.77 2.39 4754.05 57.47 143.80 3909.65 1924.41 S 708.65 W 918.69 5.65 404/.3V OV.4y14I.yL 3y�/./V 1Wb5 .Uy J UOV.4 VV yyt3.14 3.d/ 4942.42 66.72 3999.99 2052.65 S 604 1083.19 8.09 5036.09 67.88 4036.14 2114.94 S 54 1169.59 1.91 5131.68 '!. 71.14' 132.88 4069.60 2177.26'S 480.77 W 1259.01 4.20 5225.31 75.59 130.09 4096.41 2236.65 S 413.57 W 1348.30 5.54 5319.98 80.93 128.16 4115.67 2295.10 S 341,68 W 1440.11 5.99 5413.89 82.12 123.33 4129.51 2349.34 S 266.32 W 1531.23 5.24 � 5509.90 �, 80.96 120.60 4143.63 2399.61 S 185.76 W 1623.01 3.06 5603.43 79.76 120.34 4159.30 2446.37 S 106.29 W 1711.48 1.31 5697.63 82.56 119.91 4173.77 2493.08 S 25.79 W 1800.63 3.01 11 5791.89 85.47 119.52 4183.60 2539.54 S 55.62E 1890.21 3.11 5886.03 84.94 119.77 4191.47 2585.94 S 137.15E 1979.83 0.62 5923.52 83.46 119.57 4195.26 2604.41 S 169.56E 2015.47 3.98 r py tb" �j: 44 likAit44n5,Ajr,1,040010,44,10,111*,40',VI fre vili,-,PAII;;;;804ailifif'NI* yill, el C e tm0 S i{ •&5' fi.5 .;-;441(4.;-;;;;.--;;- I fN 11" Ifil ;I.; <� s. , ;.z, � - -Thir 44Viii...4 '.10.,' i;...'..."'.`2,144, 11 1,4314-11.4.4.114..1:ortrtitrek � �t- ii m£.� i qr....., '.11P4Rain41414;414*.n.g gal iro4� "Dij� jxT?4F xrh r Date Printed:24 July 2015 • 21 5099 Maile Sweigart 2 6 4Alaska North Slope Team Hilcorp Alaska, LLC RECEIVED 3800 Centerpoint Drive, Ste 1400 1 Anchorage,Alaska 99503 Ili!carp Alaska.1.1111 Office: 907.777.8473 msweigart@hilcorp.com AUG 2 4 Z015 DATA LOGGED i25/2m15 OGCivl.K.BENDER DATE 08/21/15 a \„/ ,C j To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL MPL-49 E log data Prints: ROP DGR ADR EWR-Phase4 HORIZONAL PRESENTATION DGR ADR EWR-Phase4 CD 1 : Final Well Data Date mcdified (GM 8/21/2015 9:42 AM Definitive Sur.er 8/21/2015 9:42 AM DLIS+L.AS 8,21/2015 9:41 AM EMF 8/21/2015 9:41 AM PDF 8..21/20159:42 AM TIFF 8/21/2015 9:42 AM Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received BMiftgadza.,_,(/) : Date: .v, Or T{f • • 0.),\�y/�'SA THE STATE Alaska Oil and Gas .,,-�r ., of LAsKAL Conservation Commission ttitt 333 West Seventh Avenue " GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 `*'�'' Main: 907.279.1433 OF °�'° Y+Q' Fax: 907.276.7542 ALAS www.aogcc.alaska.gov Luke Keller Drilling Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU L-49 Hilcorp Alaska, LLC Permit No: 215-099 Surface Location: 3399' FSL, 4690' FEL, SEC. 8, T13N, R10E, UM, AK Bottomhole Location: 2605' FNL, 914' FWL, SEC. 16, T13N, R10E, UM, AK Dear Mr. Keller: Enclosed is the approved application for permit to drill the above referenced service well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy P. Foerster Chair DATED this �4- day of July, 2015. RECEIVED STATE OF ALASKA ALTA OIL AND GAS CONSERVATION COMN ' JUL 0 6 2015 PERMIT TO DRILL Revised '.1 ‘'''' \c' _ r, ,rt 20 AAC 25.005 la.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service- Winj Q ' Single Zone El. lc.Specify if well is proposed for: Drill EI Lateral ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket 0,, Single Well ❑ 11.Well Name and Number: Hilcorp Alaska,LLC Bond No. 022035244 MPU L-49 = 3.Address: 6. Proposed Depth: 12. Field/Pool(s): 3800 Centerpoint Drive,Suite 1400,Anchorage AK 99503 MD: 12,374' TVD: 4,172' ' : Milne Point Unit 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): ' Schrader Bluff Oil Pool • Surface: 3408'FSL,4695'FEL,Sec 8,T13N, R10E,UM,AK ADL 025509(TPH) 315-10.6 ADL 025515(BHL) Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 632'FSL, 1034'FWL,Sec 8,T13N,R10E,UM,AK N/A lib 7/15/2015 Total Depth: 9.Acres in Property: ( 337 14. Distance to Nearest Property: 2605'FNL,914'FWL,Sec 16,T13N,R10E,UM,AK 2533 in ADL 025509-t-2544 in Ant-025515 11,730'to Unit Boundry 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: •47 feet 15. Distance to Nearest Well Open Surface: x-545185 y- 6031591.2 Zone-4 ' GL Elevation above MSL: .17 feet to Same Pool: 2,975' 16.Deviated wells: Kickoff depth: .900 feet 17. Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: ' 92 degrees Downhole: 1866 psi • Surface: 1449 psi = 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Stg 1 -Lead-1016 ft3/Tail-468.3 ft3 12-1/4" 9-5/8" 40# L-80 TC-ll 5,856' 0 0 5,856' 4,172' Stg 2-Lead-1756 ft3/Tail-314 ft3 8-1/2" 5-1/2" 17# JJL-80 DWC/C HT 6,718' 5,656' 4,172'4,/ 12,374' 4,172' Cmntless Prod.((Slotted w/Swell Pkrs) 2_.-..' /'�•�. h �, V . v , c' CL:,4 LLQ.^ 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect. Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat ❑ BOP Sketch❑ Drilling Program ❑ Time v. Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch❑✓ Seabed Report ❑ Drilling Fluid Program E 20 AAC 25.050 requirements E 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Luke Keller Email Ikeller@hilcorp.com Printed NameL e Keller / Title Drilling Engineer Signature / Phone 777-8395 Date 7/6/2015 Commission Use Only Permit to Drill ,r._ API Number: Permit Approval (� See cover letter for other Number: ,, 15 - C,( I 50-(}:,1p `< 3 ti y 5 - O --c(.... Date: ? Ii-1 i5 requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane, as hydrates,or gas contained in shales:Z Other: .# 30c),:,76 P"p S„ jj o,' %e_S f'' Samples req'd: Yes❑ Nog' Mud log req'd:Ye f NO/ f' z/`-�{Pt#J,t TF j H2S measures: Yes[d ❑� �NoDirectional svy req'd:Yeo N . G * Spacing exception req'd: Yes❑ Nog Inclination-only svy req'd:YeI NCI] v bt.I+1 °I,12-""4 4-1-.. C'6' APPROVED BY Approved by: = �' y COMMISSI1ONER . THE COMMISSION Date: 7-7 �-7 -i-- `7-[5 fS e R j�'t � m >date o Submit Form and Form 10-41iRevised 10/2012) h t a i 21n nths from the date of ap royal(20 AAC 25.005(g)) Attachments in Duplicate 111 • Luke Keller • Hilcorp Alaska, LLC Drilling Engineer • P.O. Box 244027 Anchorage,AK 99524-4027 Tel 907 777 8395 Email Ikeller@hilcorp.com H il,ori,.tla ka,Ii.c July 6th, 2015 Commissioner RECEIVED Alaska Oil &Gas Conservation Commission 333 W. 7th Avenue JUL 0 6 2015 Anchorage, Alaska 99501 AOGCC AOGCC Re: MPL-49 Permit to Drill Dear Commissioner, Enclosed for review and approval is a revision to the Permit to Drill for MPL-49. The"as-built" surface location plat is attached and differs from the"as-staked"surface plat by<10 ft. .A revised directional plan is included that reflects this slight change of surface location. The directional plan was also slightly modified to reduce anti-collision concerns of previous plan. The most recent version (WP 4.0) is attached. There is no change to TPH or BHL. The surface casing changed from 47#/ft to 40#/ft due to rail car delays. Injection string tubing changed to 3-1/2". If you have any questions, please don't hesitate to contact myself at 777-8395 or Paul Mazzolini at 777-8369. Sincerely, Luke Keller Drilling Engineer Hilcorp Alaska, LLC Page 1 of 1 • Hilcorp Alaska, LLC Milne Point Unit (MPU) L-49 Drilling Program Version 1 June 6th, 2015 • • Milne Point Drilling Procedure Hilcorp Energy Company Contents 1.0 Well Summary 2 2.0 Management of Change Information 3 3.0 Tubular Program: 4 4.0 Drill Pipe Information: 4 5.0 Internal Reporting Requirements 5 6.0 Planned Wellbore Schematic 6 7.0 Drilling/Completion Summary 7 8.0 Mandatory Regulatory Compliance/Notifications 8 9.0 R/U and Preparatory Work 10 10.0 N/U 21-1/4"2M Diverter System 10 11.0 Drill 12-1/4"Hole Section 13 12.0 Run 9-5/8"Surface Casing 17 13.0 Cement 9-5/8"Surface Casing 23 14.0 BOP N/U and Test 28 15.0 Drill 8-1/2"Hole Section 29 16.0 Run 5-1/2"Production Liner 33 17.0 Run ESP assy. 36 18.0 RDMO 36 19.0 Diverter Schematic 37 20.0 BOP Schematic 38 21.0 Wellhead Schematic 39 22.0 Days Vs Depth 40 23.0 Formation Tops 41 24.0 Anticipated Drilling Hazards 42 25.0 Nordic#3 Rig Layout(Drillers Side) 44 26.0 Nordic#3 Rig Layout(Well End&Top View) 45 27.0 FIT Procedure 46 28.0 Choke Manifold Schematic 47 29.0 Casing Design Information 48 30.0 8-1/2"Hole Section MASP 49 31.0 Spider Plot(NAD 27)(Governmental Sections) 50 32.0 Surface Plat(As Built)(NAD 27) 51 33.0 Offset MW vs TVD Chart 52 34.0 Drill Pipe Information 5" 19.5#S-135 DS-50 53 • • Milne Point Unit L-49 Drilling Procedure Hilcorp EnerSY Company 1.0 Well Summary Well MPU L-49 Pad Milne Point"L"Pad Planned Completion Type 3-1/2" Injection string Target Reservoir(s) Schrader Bluff OA Sand Planned Well TD, MD/TVD 12,374' MD/4,172' TVD PBTD, MD/TVD 12,364' MD/4,172' TVD Surface Location(Governmental) 3,408' FSL,4,695' FEL, Sec 8, T13N, R10E, UM,AK Surface Location(NAD 27—Zone 4) Y=6,031,591.23,X=545,185.0 Surface Location(NAD 83) Top of Productive Horizon (Governmental) 632'FSL, 1034'FWL, Sec 8, T13N, R10E,UM,AK TPH Location(NAD 27) Y=6028826.55,X=545660.33 TPH Location(NAD 83) BHL(Governmental) 2605' FNL, 914'FWL, Sec 16, T13N, R10E, UM,AK BHL(NAD 27) Y=6025623.15,X= 550850.8 BHL(NAD 83) AFE Number 1511127 AFE Drilling Days 15 days AFE Completion Days 4 days AFE Drilling Amount $4,137,342.00 AFE Completion Amount $1,093,100 AFE Facility Amount $431,000.00 Maximum Anticipated Pressure (Surface) 1449 psig Maximum Anticipated Pressure (Downhole/Reservoir) 1866 psig Work String 5" 19.5# S-135 DS-50(Weatherford Rental) KB Elevation above MSL: 30 ft+ 17 ft=47 ft GL Elevation above MSL: 17 ft BOP Equipment 11"x 5M Annular,(3)ea 11"x 5M Rams Page 2 Version 1 May, 2015 • Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 2.0 Management of Change Information Hilcorp Alaska, LLC Hilcorp tangy Company Changes to Approved Permit to Drill Date: 7-2-2015 Subject: Changes to Approved Permit to Drill for MPU L-49 File#: MPU L-49 Drilling and Completion Program Any modifications to MPU L-49 Drilling& Completion Program will be documented and approved below. Changes to an approved APD must be approved by the AOGCC. Sec Page Date Procedure Change Approved Approved BY By 7-2-2015 Surface casing changed from 47#to 40# due to rail car LK PM delay. 7-2-2015 Injection string changed to 3-1/2" by Paul Chan LK PM 7-2-2015 Surface location moved 5'West due to complications LK PM setting conductor at staked location Approval Paul Mazzolini 7-2-2015 Drilling Manager Date Prepared: Luke Keller 7-2-2015 Drilling Engineer Date Page 3 Version 1 May, 2015 • • Milne Point Unit L-49 111 Drilling Procedure Hilcorp Comp.n7 3.0 Tubular Program: Hole OD (in) ID (in) Drift Conn Wt Grade Conn Burst Collapse Tension Section (in) OD (in) (#/ft) (psi) (psi) (k-lbs) Cond 20" 19.25" - - 78.6 A-53 Weld 12-1/4" 9-5/8" 8.835" 8.75" 10.235" 40 L-80 TC-II 5,750 3,090 916 8-1/2" 5-1/2" 4.892" 4.767" 6.05" 17 L-80 DWC/C 7,740 7,100 397 HT 4.0 Drill Pipe Information: Hole OD (in) ID(in) TJ ID TJ OD Wt Grade Conn M/U M/U Tension Section (in) (in) (#/ft) (Min) (Max) (k-lbs) All 5" 4.276" 3.25" 6.625" 19.5 S-135 GPDS50 36,100 43,100 560k All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Version 1 May, 2015 • • Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 5.0 Internal Reporting Requirements 17.1 Fill out daily drilling report and cost report on Wellez. • Report covers operations from 6am to 6am • Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area—this will not save the data entered, and will navigate to another data entry tab. • Ensure time entry adds up to 24 hours total. • Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. • Enter the MD and TVD depths EVERY DAY whether you are making hole or not. 17.2 Afternoon Updates • Submit a short operations update each work day to pmazzolini@hilcorp.com , lkeller@hilcorp.com and cdinger@hilcorp.com 17.3 Intranet Home Page Morning Update • Submit a short operations update each morning by 7am on the company intranet homepage. On weekend and holidays, ensure to have this update in before 5am. 17.4 EHS Incident Reporting • Health and safety: Notify EHS field coordinator. • Environmental: Drilling Environmental coordinator • Notify Drlg Manager&Drlg Engineer • Submit Hilcorp Incident report to contacts above within 24 hrs 17.5 Casing Tally • Send final"As-Run"Casing tally to Ikeller@hilcorp.com and cdinger@hilcorp.com 17.6 Casing and Cmt report • Send casing and cement report for each string of casing to Ikeller@hilcorp.com and cdinger@hilcorp.com 17.7 Hilcorp Milne Point Contact List: Title Name Work Phone Cell Phone Email Drilling Manager Paul Mazzolini 907.777.8369 907.317.1275 pmazzolini@hilcorp.com Drilling Engineer Luke Keller 907.777.8395 832.247.3785 Ikeller@hilcorp.com Geologist Kevin Eastham 907.777.8316 907.360.5087 keastham@hilcorp.com Reservoir Engineer Keith Elliot 907.777.8355 832.233.5855 kelliott@hilcorp.com Drlg Environmental Coord Julieanna Orczewska 907.777.8444 907.715.7060 iorczewska@hilcorp.com EHS Manager Carl Jones 907.777.8327 907.382.4336 caiones@hilcorp.com EHS Field Coordinator Jimmy Watson 907.777.8450 907.744.7376 iiwatson@hilcorp.com Drilling Tech Cody Dinger 907.777.8389 509.768.8196 cdinger@hilcorp.com Page 5 Version 1 May, 2015 • • II Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 6.0 Planned Wellbore Schematic AFE No. Well Name: KB: 30 ft AGL 1511127 Milne Point Unit(MPU)L-49 GL a RKB 17 ft+30 ft=47 ft API d -BD AFE WELLBORE DESIGN Proposed TD: 12,374' Permit No. TOD Proposed TVD: 4,172' Geologic Information Wellbore Infcrmanon Casing Info r Mud Irdo/Hole Size/Cement Specs Mud Provam SS TVD FM Lithology Conductor RKB-Tubing Hanger 34'•x 20"Insulated conductor(Pre-set)to 80'BGL(110'RKB) interval: e ' ' Inner sleeve:20"x 0.375"Wail 78.6%.A-53.ERW.PE Surface hole § a, Exterior Jacket:34"x 0.344'Wall,123#,A-139.Grade B spiral.Pb Mud Type; j0 � Fresh Water/Native 2 M 4 Surface Casing Weight Range: o E "- 9.518"40%L-80 TC-8 set at 5856'MD 14172'TVD 8$-9.2 m •- F Surface Casing Cement E u °u 1st Stage: o « n 60 bbts 10.5 ppg Tuned spacer III - a`a Lead:(50%0H Excess)ARCTICCEM fgq 10.7 ppg c E Tail:(50%OH Excess)SWIFTCEM 15.8 ppg • pVe D 5 2nd stage: 1750' 60 bbls 10.5 ppg Tuned spacer III A r Lead:(Until returns at surface)ARCTICCEM 10.7 ppg ;, °a Stage Tail:SWIFTCEM 15.8 ppg c O 51 c Collar a Y Production Liner v o « 5.1)2"17%L-80 DWCIC HT liner a 12.374'MDI 4,172'TVD ac C 0 v Y ..- m c Injection Tubing C '- m 3-112"9.28 L-80 8RD EUE ,s is ry N rroo ° ran vi o 3 r -o o o r✓ .r _ � :L q C C Q v e, C C C] 3500' v y O p 3 O M K-sands Coarse sand,silty Top Pkr:5656 ft Injection Control Devices shale,better Interna: UGNU developed 'k. Production Hole L-sands intervening shales Mud Two: r -4000' M-sands in the L and M .� m g _ _ MEM .11111 Ili' _ Bgedry-N .N-sands Continued layering as \ 0 0 D I-0 cra' 0 Wei Ramp; Schrader in U nu,more \ _ O0 O ^ QO 8.9-9.2 pp g condensed with occ � `- IO `7ti, Imo. OO-sands ��coat 4300 �`L ..... Injection Packer Tr Swell Pkrs 5-1/2"Injection Liner Page 6 Version 1 May, 2015 • • Milne Point Unit L-49 Drilling Procedure Hilcorp Enmity ComPanY 7.0 Drilling / Completion Summary MPU L-49 is a grassroots water injector planned to be drilled in the Schrader Bluff OA sand. L-49 is part of a(5)well pilot program targeting the OA sand. Each producing lateral will have water injection support on either side. The directional plan is a catenary wellpath build with 9-5/8"surface casing set into the top of the Schrader Bluff OA sand. A lateral section will then be drilled in the OA sand. An injection liner will then be run with ICDs placed along the wellbore to optimize water injection strategy. Drilling operations are expected to commence approximately July 15th,2015. Nordic Calista Rig#3 will be used to drill and complete the wellbore. Surface casing will be run to 5,856' MD/4,172' TVD and cemented to surface via a 2 stage primary cement . job. Cement returns to surface will confirm.TOC at surface. If cmt returns to surface are not observed, a Temp log will be run between 6 — 18 hrs after CIP to determine TOC. Necessary remedial action will then be discussed with AOGCC authorities. All waste & mud generated during drilling operations above the UGNU formation (3500' TVD) will be hauled to the Milne Point"A"pad temporary disposal site for storage until the Milne Point G&I facility is up and running. Waste and mud generated after penetrating the UGNU formation will be hauled to the BP G&I facility at Prudhoe Bay. General sequence of operations: 1. MOB Nordic Rig #3 to well site 2. N/U 21-1/4" conductor and 16"diverter line. 3. Drill 12-1/4"hole to TD of surface hole section. Run and cmt 9-5/8" surface casing. 4. N/D diverter,N/U &test 11" x 5M BOP. 5. Drill 8-1/2" lateral to well TD. Run 5-1/2" liner. 6. Run Injection string. 7. N/D BOP,N/U temp abandonment cap, RDMO. Reservoir Evaluation Plan: 1. Surface hole: No mud logging. On Site geologist. LWD: GR+Res 2. Production Hole: No mud logging. On site geologist. LWD: GR+ADR(For geo-steering) Page 7 Version 1 May, 2015 • • Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Cornneny 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the below AOGCC regulations. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. • BOPs shall be tested at(2)week intervals during the drilling and completion of MPU L-49. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. • The initial test of BOP equipment will be to 250/3000 psi & subsequent tests of the BOP equipment will be to 250/3000 psi for 5/5 min(annular to 50%rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. • If the BOP is used to shut.in on the well in a well control situation, we must test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system". • All AOGCC regulations within 20 AAC 25.035 "Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements". • Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office. AOGCC Regulation Variance Requests: • There are no variance requests at this time. Page 8 Version 1 May, 2015 • • II Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure(psi) 12-1/4" • 21-1/4"2M diverter w/16"diverter line Function Test Only • 11"x 5M Hydril Annular BOP • 11"x 5M Shaffer Double Ram Initial Test:250/3000 o Blind ram in btm cavity (Annular 2500 psi) • Mud cross w/3"x 5M side outlets 8-1/2" • 11"x 5M Hydril Single Ram • 3"x 5M Choke Line Subsequent Tests: • 3"x 5M Kill line 250/3000 • 3"x 5M Choke manifold(10M Hydraulic remote Choke (Annular 2500 psi) • Standpipe,floor valves,etc • Primary closing unit: Hydril, 165 gal, 6 station accumulator w/dual electric and air pumps, w/ 1 (ea) electric over hydraulic remote control panel at the driller station.' • Primary closing hydraulic pressure is provided by an electrically driven triplex pump. Emergency pressure is provided by bottled nitrogen. Tertiary pressure is provided by air pumps. Required AOGCC Notifications: • Well control event(BOPS utilized to shut in the well to control influx of formation fluids). • 24 hours notice prior to spud. • 24 hours notice prior to testing BOPs. • 24 hours notice prior to casing running & cement operations. • Any other notifications required in APD. Regulatory Contact Information: AOGCC Jim Regg/AOGCC Inspector/(0): 907-793-1236/Email:jim.reggAalaska.gov Guy Schwartz/Petroleum Engineer/(0): 907-793-1226/(C): 907-301-4533 /Email:guy.schwartzc alaska.gov Victoria Loepp/Petroleum Engineer/(0): 907-793-1247/Email: Victoria.loeppcll alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectorscl alaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html Notification/Emergency Phone: 907-793-1236(During normal Business Hours) Notification/Emergency Phone: 907-659-2714(Outside normal Business Hours) Page 9 Version 1 May,2015 • • Milne Point Unit L-49 Drilling Procedure Hilcorp Energy ConPM 9.0 R/U and Preparatory Work 9.1 Set insulated 34"x 20" conductor at 80' below ground level (110' RKB) 9.2 Dig out and set impermeable cellar. 9.3 Ensure PTD and drilling program are posted in the rig office and on the rig floor. 9.4 Install Seaboard slip-on 16-3/4" 3M "A" section. Ensure to orient wellhead so that tree will line up with flowline later. 9.5 Insure (2) 3"threaded nipples are installed on opposite sides of the conductor with ball valves on each nipple. These will be used to take cement returns to the cellar during the surface cmt job, and also to wash out the diverter and hanger in preparation for running the pack-off. 9.6 Level pad and ensure enough room for layout of rig footprint and R/U, 9.7 Confirm that the rig is over the appropriate well slot. 9.8 MIRU Nordic #3. 9.9 Mud loggers WILL NOT be used on either hole section. 9.10 Mix spud mud for 12-1/4" surface hole section. Keep mud cool. 9.11 Set test plug in wellhead prior to N/U diverter to ensure nothing can fall into the wellbore if it is accidentally dropped. 9.12 Install 5-1/2" liners in mud pumps. • Continental EMSCO F-1000 mud pumps are rated at 3500 psi (100%)/354 gpm(120 spm @ 95% eff) with 5-1/2" liners. 10.0 N/U 21-1/4" 2M Diverter System 10.1 N/U 21-1/4"Hydril MSP 2M diverter System (Diverter Schematic at Sec 19 at back of program). • N/U 16-3/4" 3M x 21-1/4" 2M DSA on 16-3/4" 3M wellhead. • N/U 21-1/4" diverter"T". • Knife gate, 16" diverter line. • Ensure diverter R/U complies with AOGCC reg 20.AAC.25.035(C). • Diverter line must be 75 ft from nearest ignition source • Place drip berm at the end of diverter line. Page 10 Version 1 May, 2015 • • Milne Point Unit L-49 Drilling Procedure Hilcorp Enemy Company 10.2 Function test diverter. Ensure that the knife gate and annular are operated on the same circuit so that knife gate opens prior to annular closure. 10.3 Ensure to set up a clearly marked"warning zone" is established on each side and ahead of the vent line tip. "Warning Zone" must include: • A prohibition on vehicle parking • A prohibition on ignition sources or running equipment • A prohibition on staged equipment or materials • Restriction of traffic to essential foot or vehicle traffic only. 10.4 Set 15.375" ID wearbushing in wellhead. 10.5 Pad Drawing ■ ■ ■ r • riI 1 1 a ■ t^t C4.r^r Lx a a , 1 L-99 a -41 a a aa ■ ■ ■ ■ 11 Page 11 Version 1 May, 2015 • 11 Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 10.6 Rig& Diverter Orientation on"L"pad: i1 - _ - , 1 r -- -------- __— _.-• 'i 11 YS , i- 1L I i. riancur I I I I I L-47 •, L-48 FL-46 , .�n '6 ; - �-- 1 - , 77��ii � ���� II I —'L4 -lGlii'�am�Wrf� vOIiN II T I Page 12 Version 1 May, 2015 • ► • Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 11.0 Drill 12-1/4" Hole Section 11.1 P/U 12-1/4" directional drilling assy: • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Ensure Gyro MWD is R/U and operational. Be sure to run a UBHO sub so that wireline orientation is possible if necessary. • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. • Workstring will be 5" 19.5# S-135 • Run a solid float in the surface hole section. 11.2 12-1/4" BHA (GR+ Res LWD and PWD planned in surface hole): COMPONENT DATA ;' Item OD ID Gauge Weight Top Length Cumulative Description Serial Number # (in) (in) (in) °bpf) Connection (ft) Length (ft)','; ME PDC 8-000 3.000 12.250 147-22 P 6-5/8"REG 1.10 1.10 © 8"SperryDrill Lobe 415-5.3 stg ® 8.000 5.000 103.09 B 6-5/B"REG 31.47 32.57 - Stabilizer -__ 12.125 © Float Sub 8.000 2.880 149.10 B 6-518"REG 2.40 34.97 O Stabilizer 8.000 3.000 10.250 147.22 B 6-5+8"REG 6.00 40.97 © 8"DM Collar 8.000 3.500 147.40 B 6-518"REG 9.20 50.17 0 8"DGR Collar 8.000 1.920 142.70 B 6-518"REG 4.55 54.72 1111 8"EWR-P4 Collar 8.000 1.985 151.00 B 6-5+8"REG 12.19 66.91 O 8"HCIM Collar 8.000 1.920 149.90 B 6-5/8"REG 4.97 71.88 0 8"POS PULSER 8.000 4.000 145.20 B 6-5/8"REG 15.44 87.32 10 Orienting Sub UBHO 8.000 2.875 149.18 B 6-518"REG 2.50 89.82 ® NM Flex Collar 8.000 2.813 MI 150.13 B 6-5/8"REG 31.00 120.82 ® NM Flex Collar 8.000 2.813 150.13 8 6-518"REG 31.00 151.82 ® NM Flex Collar 8.000 2.813 150.12 B 6-518"REG 31.00 182.82 • 8jts x 5"X 3'HWDP#49.3-NC50(IF)- 5.000 3.000 49.30 240.00 422.82 ® Jar 7.500 2.813 129.38 B 4-1/2"IF 35.00 457.82 ® 12js x 5"X 3"HVFDP#49.3-NC50 5.000 3.000 49 30 360.00 817.82 O 817.82 Page 13 Version 1 May, 2015 • • Milne Point Unit L-49 Drilling Procedure Hi1COlp Enemy Company 11.3 Primary Bit: 12-1/4" (311mm) QHCIGRC PRODUCT SPECIFICATIONS t IADC Code 117W Total Tooth Count 67 Gage Row Tooth Count 39 . Journal Angle 33° `. 44 Offset(1 r 16") 6 "fir Jet Nozzle Types Standard 83244 Extended 302417111 `' Center Jet (lfCenterJetted)SO1813 T.J.Connection 6-5/8"(API Reg.) ., Recommended Make-Up Torque* 28000132000 Ft lbs. Bit Weight(Boxed) 250 Lbs.(113 Kg.) yrs Bit Breaker (Mat.#[Legacy#) 5153531506463 • PRODUCT FEATURES 41414401 • New patented Diamond."Claw R tooth bit design_ " * i • Tungsten carbide'surf inserts in gage teeth for added gage protection. ."b • Newly formulated,proprietary hardfacing on cutting structure and ":• 4 +° gage maximizes carbide and diamond volume for ultimate wearAP resistance. . Raised tungsten carbide inserts and proprietary hardfacing _° +r provides maximum arm protection in abrasive and directional applications while minimizing drill string torque. •• . QuadPackk Plus Series incorporates its successful"longevity" features and patented engineered hydraulics system for optimal cleaning efficiency. . Center jet feature to prevent bit balling problems . Dual seal dual compensation bearing system containing dual seals. dual independent pressure compensators.and a dual grease formulation. • The latest OCP seal technology designed with the highest contact pressures on the outside edges of the seal where it is needed most. Material#740990 helps keep contaminants out extending bearing life. "Calculations based on recommendations from API and tool-joint manufacturers. '2014 Halliburton.All rights reserved.Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. 11.4 5" Workstring, HWDP, and Jars will come from Weatherford. 11.5 Begin drilling out from 20" conductor at reduced flow rates to avoid broaching the conductor. 11.6 Drill 12-1/4"hole section to 5,856' MD/4,172' TVD. Confirm this setting depth with the geologist and Drilling Engineer while drilling the well. Page 14 Version 1 May, 2015 • • Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company • Monitor the area around the conductor for any signs of broaching. If broaching is observed, Stop drilling(or circulating) immediately notify Drilling Engineer. • Efforts should be made to minimize dog legs in the surface hole. ESP equipment can be damaged if run through high dog legs. Keep DLS <6 deg/ 100. • Hold a safety meeting with rig crews to discuss: • Conductor broaching ops and mitigation procedures. • Well control procedures and rig evacuation • Flow rates, hole cleaning, mud cooling, etc. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Keep mud as cool as possible to keep from washing out permafrost. • Pump at 600 - 650 gpm. Ensure shaker screens are set up to handle this flowrate. • Keep swab and surge pressures low when tripping. • Ensure to leave a"Pump Tangent" section that is approx. 300' long in the directional plan. The ESP will need a straight section to sit. This will occur very near TD of the hole section. • Make wiper trips every 2000' unless hole conditions dictate otherwise. • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability. • TD the hole section just into the Schrader Bluff OA sand. Geologists and Drilling Engineers will help adjust well path to ensure well is landed correctly. • Take MWD surveys every stand drilled (60' intervals). • Watch returns closely for signs of gas when near the base of the permafrost and circulate out all gas cut mud before continuing to drill. There have been no indications of hydrates on any of the "L"pad wells to date. • Have the flowline jets hooked up and be ready to jet the flowline at the first sign of clay balling. Page 15 Version 1 May,2015 Milne Point Unit L-49 Drilling Procedure Hilcorp Energy CompmY 11.7 12-1/4"hole mud program summary: • Density: Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system (1) ppg above highest anticipated MW. We will start with a simple gel + FW spud mud at 8.8 ppg. • PVT System: MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. • Rheology: Aquagel and Barazan D+ should be used to maintain rheology. Begin system with a 75 YP but reduce this once clays are encountered. Maintain a minimum 25 YP at all times while drilling. Be prepared to increase the YP if hole cleaning becomes an issue. • Fluid Loss: DEXTRID and/or PAC L should be used for filtrate control. Background LCM(10 ppb total)BARACARBs/BAROFIBRE/STEELSEALs can be used in the system while drilling the surface interval to prevent losses and strengthen the wellbore. • Wellbore and mud stability: Additions of CON DET PRE-MIX/DRIL N SLIDE are recommended to reduce the incidence of bit balling and shaker blinding when penetrating the high-clay content sections of the Sagavanirktok and the heavy oil sections of the UGNU 4A. Maintain the pH in the 8.5—9.0 range with caustic soda. Daily additions of ALDACIDE G/X- CIDE 207 MUST be made to control bacterial action. • Casing Running: Reduce system YP with DESCO as required for running casing as allowed (do not jeopardize hole conditions). Run casing carefully to minimize surge and swab pressures. Reduce the system rheology once the casing is landed to a YP<20(check with the cementers to see what YP value they have targeted). System Type: 8.8—9.2 ppg Pre-Hydrated Aquagel/freshwater spud mud Properties: Depths Density Viscosity Plastic Viscosity Yield Point API FL pH 80-5856' 8.8—9.2 85-250 20-40 25-75 <10 8.5—9.0 System Formulation: Gel + FW spud mud Product Concentration Fresh Water 0.905 bbl soda Ash 0.5 ppb AQUAGEL 15 -20 ppb caustic soda 0.1 ppb(8.5 —9.0 pH) BARAZAN D+ as needed BAROID 41 as required for 8.8—9.2 ppg PAC-L/DEXTRID LT if required for<10 FL ALDACIDE G 0.1 ppb Page 16 Version 1 May, 2015 S Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 11.8 At TD; pump sweeps, CBU, and pull a wiper trip back to the 20" conductor shoe. 11.9 Should backreaming be necessary to get out of the hole: • Prior to initiating backreaming, ensure at least 3 —4 B/U have been circulated to get hole as clean as possible. • Pump at full drill rate (600—700 gpm), and maximize rotation. • Pull slowly, 5— 10 ft/minute. • Monitor well for any signs of packing off or losses. • Have the flowline jets hooked up and be ready to jet the flowline at the first sign of clay balling. • If flow rates are reduced to combat overloaded shakers/flowline, stop back reaming until parameters are restored. 11.10 TOH with the drilling assy, handle BHA as appropriate. • 11.11 No open hole logging program planned. 12.0 Run 9-5/8" Surface Casing 12.1 R/U and pull 15.375"wearbushing. 12.2 Make a dummy run with the 9-5/8" casing hanger. 12.3 R/U Weatherford 9-5/8" casing running equipment. • Ensure 9-5/8" TC-II x DS50 XO on rig floor and M/U to FOSV. • Consider R/U of CRT if hole conditions require. • R/U a fill up tool to fill casing while running if the CRT is not used. • Ensure all casing has been drifted to 8.525" on the location prior to running. • Be sure to count the total # of joints on the location before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/vendor& model info. 12.4 P/U shoe joint, visually verify no debris inside joint. 12.5 Continue M/U & thread locking shoe track assy consisting of: • (1) Shoe joint w/float shoe bucked on (thread locked). Install (2) centralizers on shoe joint over stop collars 10' from each end. • (1) Joint with float collar bucked on pin end &thread locked. Install (1) centralizer mid tube over a stop collar. • Ensure bypass baffle is correctly installed on top of float collar. Page 17 Version 1 May, 2015 • S Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company Bypass Baffle This end up. 101110 kis or • (1) Joint with Halliburton bypass baffle adapter bucked on pin&threadlocked. Install (1) centralizer mid tube over a stop collar. • Ensure proper operation of float equipment while picking up. • Ensure to record S/N's of all float equipment and stage tool components. Page 18 Version 1 May, 2015 s • Til Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 12.6 Float equipment and Stage tool equipment drawings: "A a Overall Length —i Type H ES Cementer B iia Part No. M .ID Ager orflout SO No. C Max.'col CD art 1 Wimp D p ESN Rural Order Open,. ._____ ..Sea. C A x Closing Sleeve __ !1 No.Shear Pins IIIIIIIIIIIIII111 E t Cloning Seat ID II ( i Opening Sleeve No.Shear Pins plug Set ES-II Cementer .1111111111.1111 ES Cementer Part No. B�� Depth 6 SO No. . \ /. Closing Plug . = Ba`'e Adapter(if used) OD Shut ORPlug El 1 Baffle Adapter ■ iDng P III Depth OD OD Bypass or Shut-off Baffle ,IBI ID By-Pass Plug Depth Shut-off Plug 3 . Float Collar C) 1 _—I Depth By Pass Baffle + OD Rost Calfor li Float Shoe Depth Bypass Plug (if used) Hole TO Float Shoe "Reference ea;ra OD Sales Ma-gal Sect c-5- Page Page 19 Version 1 May,2015 • • 11 Milne Point Unit L-49 Drilling Procedure Hilcorp Energy ColnPY7 12.7 Continue running 9-5/8" surface casing • Fill casing while running using fill up line on rig floor. • Use Jet Lube Seal or BOL 72733 thread compound. Dope pin end only w/paint brush. • Install (1) centralizer every other joint for the first 15 joints. • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Break circulation prior to reaching the base of the permafrost if casing run indicates poor hole conditions. • Any packing off while running casing should be treated as a major problem. It is preferable to POH with casing and condition hole than to risk not getting cmt returns to surface. 12.8 Install the Halliburton Type H ES-II Stage tool so that it is positioned at 2300' MD /2137' TVD. This will position the stage collar comfortably below the permafrost. • Install centralizers over couplings on 3 joints below and above stage tool. • Do not place tongs on ES cementer, this can cause damaged to the tool. • Ensure tool is pinned with 6 opening shear pins. There are 6 holes,the tool is normally sent with only 4 pins installed. This will allow the tool to open at 3300 psi. 9-5/8" 40#L-80 TC-II Make Up Torques: Casing OD Min M/U Torque Max M/U Torque 9-5/8" 11,600 ft-lbs 13,600 ft-lbs Page 20 Version 1 May, 2015 • Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company Technical Specifications Connection Type: Sixe(O.D.): Weight(Wall): Grade: TC-Il Casing 9-5/8 in 40.00 lb/ft (0.395 in) L-80 stands rd Material L-80 Grade 80.000 Minimum Yield Strength (psi) U A 95.000 Minimum Ultimate Strength (psi) VAM USA Pipe Dimensions 4424 W.Sam Houston Pkwy.Suite 150 Houston, TX 77041 9.625 Nominal Pipe Body O.D. (in) Phone:713-azo-32 713-479-3200 8.835 Nominal Pipe Body I.D.(in) Fax:713-479-3234 0.395 Nominal Wall Thickness(in) E-mail:VAMUSAsalesvam-usa.com 40.00 Nominal Weight 0)s/ft) 38.97 Plain End Weight (lbs!ft) 11.454 Nominal Pipe Body Area (sq in) Pipe Body Performance Properties 916.000 Minimum Pipe Body Yield Strength (lbs) 3.090 Minimum Collapse Pressure (psi) 5.750 Minimum Internal Yield Pressure (psi) 5,300 Hydrostatic Test Pressure (psi) Connection Dimensions 10.235 Connection O.D. (in) 8.835 Connection I.D. (in) 8.750 Connection Drift Diameter (in) 5.23 Make-up Loss (in) Connection Performance Properties 916.000 (1) Joint Strength (lbs) 16.360 Reference String Length (ft) 1.4 Design Factor 916.000 Compression Rating (lbs) 3,090 Collapse Pressure Rating (psi) 5.750 Internal Pressure Rating (psi) 38.1 Maximum uniaxial bend rating [degrees/100 ftj Recommended Torque Values 11,600 (2) Minimum Final Torque (ft-lbs) 13.600 (2) Maximum Final Torque (ft-lbs) Page 21 Version 1 May, 2015 • • Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 12.9 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 12.10 Slow in and out of slips. 12.11 P/U casing hanger joint and M/U to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe as close to TD as possible. Strap the landing joint while it is on the deck and mark the joint at(1) ft intervals to use as a reference when landing the hanger. 12.12 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. 12.13 Have emergency slips ready to go in the event we cannot land the hanger. 12.14 R/U circulating equipment and circulate B/U. Reduce YP to <20 to help ensure success of cement job. Ensure adequate amounts of cold M/U water are available to achieve this. Elevate hanger slightly above hang off point while circulating to avoid plugging the flutes. 12.15 After circulating, lower string and land hanger in wellhead again. Page 22 Version 1 May, 2015 • • Milne Point Unit L-49 11 Drilling Procedure Hilcorp Enemy Company 13.0 Cement 9-5/8" Surface Casing 13.1 Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud& water can be delivered to the cmt unit at acceptable rates. • How to handle cmt returns at surface. Ensure vac trucks are on standby and ready to assist. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Ensure adequate amounts of water for mix fluid is heated and available in the water tanks. • Positions and expectations of personnel involved with the cmt operation. • Review test reports and ensure pump times are acceptable. • Conduct visual inspection of all iron used to route slurry to rig floor. 13.2 Document efficiency of all possible displacement pumps prior to cement job • 13.3 Flush through cement pump and•treating iron from pump to rig floor to the shakers. This will • help ensure any debris left in the cmt pump or treating iron will not be pumped downhole. 13.4 R/U cmt head (if not already done so). Ensure top and bottom plugs have been loaded correctly. 13.5 Pump 5 bbls 10.5 ppg tuned spacer. Test surface cmt lines. 13.6 Pump remaining 55 bbls 10.5 ppg tuned spacer. 13.7 Drop bottom plug(flexible bypass plug). Mix and pump cmt per below calculations for the 1st stage. 13.8 Cement volume based on annular volume+ 30% open hole excess. Job will consist of lead& tail, TOC brought to stage tool. Estimated Total Cement Volume: Section: Calculation: Vol(BBLS) Vol(ft3) 12-1/4" OH x 9-5/8" Casing (4800'- 2300') x .0558 bpf x 1.3 = 181 bbls 1016 ft3 annulus: Total LEAD: 181 bbls 1016 ft3 12-1/4" OH x 9-5/8" Casing (5854'- 4800') x .0558 bpf x 1.3 = 76.5 bbls 430 ft3 annulus: 9-5/8" Shoe track: 90 x .0758 bpf = 6.8 38.3 Total TAIL: 83.3 bbl 468.3 ft3 • • II Milne Point Unit L-49 Drilling Procedure Hilcorp Emma Canna). Cement Slurry Design: Lead Slurry Tail Slurry System ArcticCEM TM System SwiftCEM TM System Density 10.7 lb/gal 15.8 lb/gal Yield 4.298 ft3/sk 1.16 ft3/sk Mixed 21.13 gal/sk 5.04 gal/sk Water 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Keep the hanger elevated above the wellhead while working. If the hole gets "sticky", land the hanger on seat and continue with the cement job. 13.9 After pumping cement, drop top plug (Shutoff plug) and displace cement with spud mud out of mud pits. 13.10 Ensure cement unit is used to displace cmt so that volume tracking is more accurate. To operate the stage tool hydraulically, the plug must be bumped. 13.11 Displacement calculation: 5700' x .0758 bpf=218 bbls mud, 80 bbls water, 134 bbls mud The 80 bbls of water must be left across stage tool to ensure proper operation once opened. 13.12 Monitor returns closely while displacing cement. Adjust pump rate if necessary. If hanger flutes become plugged, open wellhead side outlet in cellar and take returns to cellar. Be prepared to pump out fluid from cellar. Have some sx of sugar available to retard setting of cement. 13.13 Do not overdisplace by more than 1/2 shoe track volume. Total volume in shoe track is 8.7 bbls. Page 24 Version 1 May, 2015 • • li Milne Point Unit L-49 Drilling Procedure Hilcorp Energy company 13.14 If plug is not bumped consult with drilling engineer. Ensure the free fall stage tool opening plug is available if needed. This is the back-up option to open the stage tool if the plugs are not bumped. 13.15 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held. 13.16 Increase pressure to 3300 psi to open circulating ports in stage collar. Slightly higher pressure may be necessary if TOC is above the stage tool. CBU and record any spacer or cement returns to surface. Circulate until YP <20 again in preparation for the 2nd stage of the cement job. 13.17 Be prepared for cement returns to surface. Dump cmt returns in the cellar or open the shaker bypass line to the cuttings tank. Have sacks of sugar available and vac trucks ready to assist. Ensure to flush out any rig components used to route cmt. Page 25 Version 1 May, 2015 • • Milne Point Unit L-49 Drilling Procedure Hilcorp Erma CoalPla7 Second Stage: 13.18 Prepare for the 2nd stage as necessary. Hold another pre job meeting if crew change has occurred. 13.19 Load ES cementer closing plug in cmt head. 13.20 Pump 5 bbls 10.5 ppg tuned spacer. Test surface cmt lines. 13.21 Pump remaining 55 bbls 10.5 ppg tuned spacer. 13.22 Mix and pump cmt per below recipe for the 2nd stage. 13.23 Cement volume based on annular volume +200% open hole excess. Job will consist of lead& tail, TOC brought to surface. However cmt will continue to be pumped until clean spacer is observed at surface. Estimated Total Cement Volume: Section: Calculation: Vol(BBLS) Vol(ft3) 20" Conductor x 9-5/8" (110') x .27 bpf x 1 = 29.7 bbls 167 ft3 casing annulus: 12-1/4" OH x 9-5/8" Casing (1800'- 110') x .0558 bpf x 3 = 283 bbls 1589 ft3 annulus: Total LEAD: 312.7 bbls 1756 ft3 12-1/4" OH x 9-5/8" Casing (2300'- 1800')x .0558 bpf x 2 = 56 314 ft3 annulus: Total TAIL: 56 bbls 314 ft3 13.24 Continue pumping lead until uncontaminated spacer is seen at surface,then switch to tail. 13.25 After pumping cement, drop ES Cementer closing plug and displace cement with spud mud out of mud pits. 13.26 Displacement calculation: 2300' x .0758 bpf= 174 bbls mud Page 26 Version 1 May, 2015 • • II Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 13.27 Monitor returns closely while displacing cement. Adjust pump rate if necessary. If hanger flutes become plugged, open wellhead side outlet in cellar and take returns to cellar. Be prepared to pump out fluid from cellar. Have some sx of sugar available to retard setting of cement. 13.28 Decide ahead of time what will be done with cmt returns once they are at surface. We should get back approx. 150 bbls of cmt slurry. 13.29 Land closing plug on stage collar and pressure up to 1000— 1500 psi to ensure stage tool closes. Follow instructions of Halliburton personnel. Bleed off pressure and check to ensure stage tool has closed. Back out and L/D landing joint. Flush out wellhead with FW. 13.30 M/U pack-off running tool and pack-off to bottom of Landing joint. Set casing hanger packoff. Run in lock downs and inject plastic packing element. 13.31 Lay down landing joint and pack-off running tool. Ensure to report the following on wellez: • Pre flush type, volume(bbls)&weight(ppg) • Cement slurry type, lead or tail,volume&weight • Pump rate while mixing,bpm,note any shutdown during mixing operations with a duration a. Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid b. Note if casing is reciprocated or rotated during the job c. Calculated volume of displacement, actual displacement volume, whether plug bumped&bump pressure, do floats hold d. Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure e. Note if pre flush or cement returns at surface&volume f. Note time cement in place g. Note calculated top of cement h. Add any comments which would describe the success or problems during the cement job Send final "As-Run" casing tally & casing and cement report to lkeller@hilcorp.corn and cdinger@hilcorp.com This will be included with the EOW documentation that goes to the AOGCC. Page 27 Version 1 May, 2015 • • Milne Point Unit L-49 Drilling Procedure Hilcorp Enemy compimY 14.0 BOP N/U and Test 14.1 N/D the diverter. 14.2 N/U Seaboard tubing spool. Install pack-off 9-5/8"P-seals. Test to 3000 psi. 14.3 N/U 11"x 5M BOP as follows: • BOP configuration from Top down: 11"x 5M Hydril annular BOP/11" x 5M Shaffer double ram/11"x 5M mud cross/11"x 5M Hydril single ram • Double ram should be dressed with 2-7/8" x 5" VBRs in top cavity, blind ram in btm cavity. • Single ram should be dressed with 2-7/8" x 5" VBRs. • N/U bell nipple, install flowline. • Install (1) manual valve & (1) HCR valve on kill side of mud cross. (manual valve closest to mud cross). ' • Install (1)manual valve on choke side of mud cross. Install an HCR outside of the manual valve. 14.4 Run 5" BOP test assy, land out test plug (if not installed previously). • Test BOP to 250/3000 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. • Ensure to leave "B" section side outlet valves open during BOP testing so pressure does not build up beneath the test plug. 14.5 R/D BOP test assy. 14.6 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.7 Mix 8.9 ppg Baradrill-N fluid for production hole. 14.8 Set 10" ID wearbushing in wellhead. 14.9 Rack back as much 5"DP in derrick as possible to be used while drilling the hole section. 14.10 Keep 5-1/2" liners in mud pumps. Page 28 Version 1 May, 2015 • • II Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 15.0 Drill 8-1/2" Hole Section 15.1 P/U 8-1/2" directional BHA. • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Ensure MWD is R/U and operational. • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. • Workstring will be 5" 19.5# S-135 • Install ported float above motor. 15.2 8-1/2"BHA Includes GR+Res+ADR LWD corn sonents & PWD : COMPONENT DATA Item Description Serial Number OD ID Gauge Weight Top Length Cumulative # (in) (in) (in) (Ibpf) Connection (ft) Length (ft) 1 PDC 6.750 2.500 8.500 105.23 P 4-1/2"REG 0.80 0.80 2 7"SperryDrill Lobe 7/8-6.0 stg 7.000 4.952 93.13 B 4-1/2"IF 27.38 28.18 Stabilizer -__ 8.375 _--- 3 Float Sub 6.750 2.813 100.77 P 4-112"IF 2.00 30.18 4 6 3/4"DM Collar(Directional) 6750 3.125 103.40 P 4-112"IF 9.20 39.38 5 imine Stabilizer(ILS) 6.750 1.920 8.375 112.09 B 4-112"IF 2 00 41.38 6 6 3/4"ADR Collar(Resistivity) 6.750 1.920 109.40 B NC 50 24.34 65.72 7 6 314"DGR Collar(Gamma) 6.750 1.920 97.80 B 4-1/2"IF 4.46 70.18 8 6 314"PWD(Pressure ECDs) 6.750 1.905 112.24 B 4-112"IF 4.44 74.62 9 6 3/4"HCIM(Processor) ® 6.750 1.920 112.09 B 4-112"IF 4.97 79.59 10 6 314'TM Pulser(Telemetry) 6.750 3.250 99.16 B 4-112"IF 15.26 94,85 11 NM Flex Collar 6.750 2.813 100.77 B 4-112"IF 31.00 125.85 12 NM Flex Collar 6.750 2.813 100.77 B 4-1/2"IF 31.00 156.85 13 NM Flex Collar 6.750 2.813 100.77 B 4-112"IF 31.00 187.85 14 3xJts 5"X 3"HWDP-4.51F 5.000 3.000 42.83 93.00 280.85 15 Jar 6.250 2.250 91.01 B 4-1/2"IF 33.00 313.85 16 14Jts 5"X 3"HWDP-4.51F 5.000 3.000 42.83 420.00 733.85 733.85 Page 29 Version 1 May, 2015 0 Milne Point Unit L-49 II Drilling Procedure Hilcoor Emily 15.3 Primary Bit: 8-1/2" (216mm) SFE56 PRODUCT SPECIFICATIONS Cutter Type X2-Tough Drilling IADC Code S42441111 li Body Type STEEL I Total Cutter Count 29 Cutter Distribution 13mm 91 mm Face 0 19 1 Ir N Gauge 10 0 Number of Large Nozzles 5 °` Number of Medium Nozzles 0 ' Number of Small Nozzles 0 Number of Micro Nozzles 0 , ` Number of Ports(Size) 0 Number of Replaceable Ports(Size) 0 '. #s Junk Slot Area(sq in) 20.81 > > Ir. Normalized Face Volume 73.86% API Connection 4-1/2 I.F.PIN 11 Recommended Make-Up Torque' 23,743 Ft•lbs. Nominal Dimensions** Make-Up Face to Nose 8.31 in-211 mm 00 Gauge Length 3 in-76 mm r J Sleeve Length 0 in-0 mm Shank Diameter 6.688 in-170 mm Break Out Plate(Mat.#!Legacy#) 181960144073 Approximate Shipping Weight 120Lbs.-54Kg. SPECIAL FEATURES Anti-Balling Coating,Short Shank,EDL Tool Specific Gage,.084"Dia Step,.126"Dia Step Material#761417 Page 30 Version 1 May,2015 • • Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Conway 15.4 8-1/2"hole section mud program summary: • Density: Weighting material to be used for the hole section will be calcium carbonate. Additional calcium carbonate will be on location to weight up the active system (1) ppg above highest anticipated MW. • Solids Concentration: It is imperative that the solids concentration be kept low while drilling the production hole section. Keep the shaker screen size optimized and fluid running to near the end of the shakers. It is okay if the shakers run slightly wet to ensure we are running the finest screens possible. • Rheology: Keep viscosifier additions to an absolute minimum(N-VIS). Data suggests excessive viscosifier concentrations can decrease return permeability. Do not pump high vis sweeps, instead use water or low vis sweeps. • • Run the centrifuge continuously while drilling the pro.duction hole, this will help with solids removal. • Dump and dilute as necessary to keep drilled solids to an absolute minimum. • MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, & Toolpusher office. System Type: 8.9—9.2 ppg Baradrill-N drilling fluid Properties: Depths Density Plastic Viscosity Yield Point Total Solids MBT HPHT pH 5856- 12374 8.9-9.2 15-25 15-25 <10% <7 <11.0 8.5-9.5 System Formulation: Baradrill-N Product Concentration Water 0.955 bbl KCL 11 ppb KOH 0.1 ppb N-VIS 1.0— 1.5 ppb N-DRIL HT PLUS 5 ppb BARACARB 5 11.5 ppb BARACARB 25 16.8 ppb BARACOR 700 1.0 ppb BARASCAV D 0.5 ppb X-CIDE 207 0.015 ppb EZ-GLIDE 2.0% Page 31 Version 1 May, 2015 • Milne Point Unit L-49 II Drilling Procedure Hilcorp Enemy Company 15.5 TIH w/ 8-1/2" directional assy to stage tool. Shallow test MWD and LWD on trip in. Note depth TOC tagged on AM report. Drill out stage tool as follows: • Do not exceed 75 rev/min rotation speed. A good range is 40 to 75 rpm. • Because of aggressive nature of PDC bits, drilling with minimal WOB is recommended. Approx 2-5 k is enough. • Apply weight and allow it to drill off before applying more. • After drilling out, chase any remaining debris to bottom with the drill bit. 15.6 TIH to TOC above the baffle adapter. Note depth TOC tagged on morning report. 15.7 R/U and test casing to 3000 psi/30 min. Ensure to record volume/pressure and plot on FIT graph. AOGCC reg is 50% of burst= 6870/2 =—3500 psi, but maximum test pressure on L-49 is 3000 psi. 15.8 Drill out shoe track and 20' of new formation. 15.9 CBU and condition mud for FIT. 15.10 Conduct FIT to 12 ppg EMW. 15.11 Drill 8-1/2"hole section to section TD per Geologist and Drilling Engineer. • Pump at 500 - 550 gpm. • Ensure shaker screens are set up to handle this flowrate. Ensure shakers are running slightly wet to maximize solids removal efficiency. Check for holes in screens on every connection. • Pump water or other low vis sweeps to aid in hole cleaning. • Keep swab and surge pressures low when tripping. • Make wiper trips every 1500—2000 ft if necessary. • Take MWD surveys every stand drld. Surveys can be taken more frequently if deemed necessary. • Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. • Use ADR to stay in section. Ideally, we would like to stay in section 100% of the time and DO NOT want to serpentine between the upper and lower lobes. 15.12 Open hole sidetracking practice: • If a known fault is coming up, put a slight"kick-off ramp" in wellbore ahead of the fault so we have a nice place to low side. • Attempt to lowside in a fast drilling interval where the wellbore is headed up. • Orient TF to low side and dig a trough with high flowrates for the first 10 ft, working string back and forth. Trough for approx. 30 min. Page 32 Version 1 May, 2015 • • Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Consw■r • Time drill at 4 to 6 feet per hour with high flow rates. Gradually increase ROP as the openhole sidetrack is achieved. 15.13 At TD; pump low vis sweeps, CBU at least 3 times at maximum circulation and rotation, and pull a wiper trip back to the 9-5/8" shoe. If backreaming is necessary: • Circulate at full drill rate (500—550 gpm). • Rotate at maximum rpm that can be sustained. • Limit pulling speed to 5 — 10 min/std (slip to slip time, not including connections). • If backreaming operations are commenced, continue backreaming to the shoe and circ at least a b/u once at the shoe. 15.14 TOH with the drilling assy, stand back BHA if possible. Rabbit DP on TOH. 15.15 No open hole logs are planned for the production hole section. • 16.0 Run 5-1/2" Injection Liner 16.1. Install and test 5-1/2" casing ram in top ram cavity. Test to 250/3000 psi. 16.2. Re-install wear bushing in wellhead after test. 16.3. R/U 5-1/2" casing running equipment. • Ensure 5-1/2"DWC/C x DS-50 crossover is on rig floor and M/U to FOSV. • Ensure all casing has been drifted on the deck prior to running. • Be sure to count the total # of joints on the deck before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/vendor& model info. 16.4. Run 5-1/2"production liner per completion tally. • Use "Best 0 Life 2000"thread compound. Dope pin end only w/paint brush. • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Install swell packers & ICDs as per Operations Engineer guidance. • Ensure all plastic packing is removed from swell pkr elements. • Do not place tongs or slips on pkr elements or ICDs. 5-1/2" DWC/C HT M/U torques Casing OD Minimum Maximum Yield Torque 5.5" 9,800 ft-lbs 11,000 ft-lbs 14,800 ft-lbs Page 33 Version 1 May,2015 S Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company Technical Specifications Connection Type: Size(O.D.): Weight(Wall): Grade: DWC/C-HT Casing 5-1/2 in 17.00 lb/ft(0.304 in) L-80 standard Material L-80 Grade 80.000 Minimum Yield Strength(psi) 1111111111111111111111111.USA 95.000 Minimum Ultimate Strength(psi) VAM USA 4424 W-Sam Houston Pkwy.Suite 150 Pipe Dimensions Houston.TX 77041 Phone:713-479-3200 5.500 Nominal Pipe Body O.D. (in) Fax:713-479-3234 4.892 Nominal Pipe Body I.D.(in) E-mai VAMUSAsales vam-usa.com 0.304 Nominal Wall Thickness (in) 17.00 Nominal Weight (lbs/ft) 16.89 Plain End Weight(lbs/ft) 4.962 Nominal Pipe Body Area (sq in) Pipe Body Performance Properties 397.000 Minimum Pipe Body Yield Strength(lbs) 6,290 Minimum Collapse Pressure(psi) 7,740 Minimum Internal Yield Pressure(psi) 7.100 Hydrostatic Test Pressure (psi) Connection Dimensions 6.050 Connection O.D. (in) 4.892 Connection I.D.(in) 4.767 Connection Drift Diameter(in) 4.13 Make-up Loss (in) <' 4.962 Critical Area (sq in) 100.0 Joint Efficiency(%) d,] Connection Performance Properties 397,000 Joint Strength (lbs) 16.680 Reference String Length (ft) 1.4 Design Factor 428.000 API Joint Strength (lbs) 397.000 Compression Rating (lbs) 6,290 API Collapse Pressure Rating (psi) 7.740 API Internal Pressure Resistance (psi) t. 66.7 Maximum Uniaxial Bend Rating[degrees/100 ft] Appoximated Field End Torque Values 9.800 Minimum Final Torque(ft-lbs) 11.000 Maximum Final Torque(ft-lbs) 14.800 Connection Yield Torque(ft-lbs) Page 34 Version 1 May, 2015 • • Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 16.6. Ensure to run enough liner to provide for approx 200' overlap inside 9-5/8" casing. Ensure hanger/pkr will not be set in a 9-5/8" connection. 16.7. Before picking up Baker ZXP liner hanger/packer assy, count the # of joints on the pipe deck to make sure it coincides with the pipe tally. 16.8. M/U Baker ZXP liner top packer. Fill liner tieback sleeve with"Pal mix", ensure mixture is thin enough to travel past the HRD tool and down to the packoff. Wait 30 min for mixture to set up. 16.9. Note weight of liner. Run liner in the hole one stand and pump through liner hanger to ensure a clear flow path exists. 16.10. RIH w/liner on DP no faster than 1-1/2 min/ stand. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 16.11. DP should autofill. 16.12. Slow in and out of slips. Ensure accurate slack off data is gathered during RIH. Record shoe depth+ S/O depth every stand. Record torque value if it becomes necessary to rotate the string to bottom. 16.13. Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10, 20, & 30 rpm. 16.14. If any open hole sidetracks have been drilled, monitor sidetrack depths during run in and ensure shoe enters correct hole. 16.15. TIH deeper than planned setting depth. Last motion of the liner should be up to ensure it is set in tension. 16.16. Prior to setting the hanger and packer, double check all pipe tallies and record amount of drill pipe left on location. Ensure all numbers coincide with proper setting depth of liner hanger. 16.17. Rig up to pump down the work string with the rig pumps. 16.18. Displace entire wellbore to completion fluid (8.9 ppg KCl). Pump at 10-12 bpm. Catch mud for future use if feasible. Once KC1 observed at surface shut down pumps. 16.19. Drop setting ball down the workstring and pump slowly (1-2 bpm). Slow pump before the ball seats. Do not allow ball to slam into ball seat. 16.20. Pressure up to 3000 psi and hold for 5-15 minutes to set SLZXP hanger packer. Continue pressuring up in 500 psi increments holding for 5 min each up to 4000 psi. Page 35 Version 1 May, 2015 • Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 16.21. Bleed DP pressure to zero, close BOP and test annulus to 1500 psi for 10 min and chart record same. 16.22. Bleed off pressure and pickup to verify that the HRD setting tool has released. If packer did not test, rotating dob sub can be used to set packer. If running tool cannot be hydraulically released, apply LH torque to mechanically release the setting tool. 16.23. POOH, L/D and inspect running tools. If setting of liner hanger/packer proceeded as planned, LDDP on the TOH. 16.24. L/D remaining DP out of derrick. 17.0 Run Injection Assembly 17.1 Remove 5-1/2" ram, re-install VBR and test on 3-1/2"test joint to 250/3000 psi. 17.2 M/U injection assy and RIH to setting depth. • Ensure appropriate well control crossovers on rig floor and ready. • Monitor displacement from wellbore while RIH. 17.3 Land hanger, RILDs and test hanger. 17.4 Circulate freeze protect down IA, allow freeze protect to U-tube down tubing. 17.5 Set packer. Test annulus to 3000 psi f/30 min. 17.6 Install BPV and N/D BOP. 17.7 N/U tree adapter and tree. Conduct pressure tests of same to 250/3000 psi. 17.8 Shut in well. 18.0 RDMO Page 36 Version 1 May, 2015 • Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 19.0 Diverter Schematic =maul 1 Schaffer ,0 VV 21-114" VV 2M Annular Q en mlR WIN RN 11.v 21-114"2M Riser 16"Full Opening Knife Valve nnn nMIM f�O�Q 21-114'2M------ Diverter Diverter Line VLY Y UMI lilt , 21-1/4"2M----_.... Spacer Spool daa asa 16-314"3M x---.. 21-114"2M DSA {� r r r' Seaboard Casinghead,522-AP-8 16*SOW x 16-3/4"3M; (2)ea 2-1116"5M studded outlets t_____20"Casing Page 37 Version 1 May,2015 • II Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 20.0 BOP Schematic / l \ 5 1 6 0 Hydril Annular \\\ BOP 11"x5M E * Kann Lo r... aa a:rj 0 ri Shaffer 11" x 5MU D o ❑ :0 ❑ DF:- VI' Diii _ to. I I neN o.11 n �3"x5MHCf2 U al& u uv � � Ii I i`':.:'l ll 11\11,11)l [ ' ' —ChokeLine Kilo Line 3"x 5M Manual Gate Valve - _I Hydril 11"x 5M 1®1— I € E 1 3 1 ----_ a0a �o YY Y4iY ff of of ES �'`�-11"x5M 9-518"DBL 0 Seal r'�[,f1 11. 2-1116"x 5M Casing Hanger _�1 II d� , /i 16-314"x 3M SMB-22 i , 'w' ``r 16-314"MOM f 9-5/8"BTC Bim x 2-1116"x 5M 10.5"-4 SA Pin Top I. W/Primary Sea 20"Casing 9-5/8"Casing Page 38 Version 1 May,2015 s • Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 21.0 Wellhead Schematic HILCORP ALASKA. LLC SCHRADER BLUFF WELLS NORTH SLOPE HO-34863 !Ira, IP Amnia,.GIOtE S-1/O Si (*---ii 4g,1 E,.1 1441;0‘. � Amnia,.±-trg -IO, r5-1/g SIA i Ir On 13 a 1 A TI EST _ '� ... a./ �J ___ , r- 1 I I ACTUATED i 0 1 '.-118 V S IOL maLii 52,2 EST 11111111111ES- MlII v . . 114.2 3-1/0 514 /`�. EST fAOAP GER.9N-E-CIN It 511 x 3-,/8 514 iit ' RIR TED; o. '1.0 .61; •.N RAMC MANGER E=11i t1 SY-E-Q It X 3-1/2— li r API NOO tom ... A EU Ono TOP IRI j 'I EST i �� 9-j,/E 00E 0 SEAL 1■. ,. e/t F. :a/ it 574 tl" EST CASIG MANGER. SMO-77 IRI IRI I O-3/!NOTA, II 0-5/0 OC OEM■ Jt,6 '0.500-4 SA.AAV TCPEFA 'I . 1.•. W/PgIMARY SEK RI 11111rI• 1. EST SWAGE ADAPTER. ` 20 SOW■14 SUP ON PN\ ' '` \ `•2-1/14 5M 11 70 CASING 1 I I-5/4 CASINO-- WM 3-1/7 WONG--- 5.000 PSI MEWU4EAD&111E ASSDRO'V K 20 X 9-5/4 x 3-1/2 E INSCNS SPINN CN LRS ORMANC ME FSIMANS OLT AMO CAN MAX 9GIIKM0.Y RESTRICTED CONE DENTIAI. DOCUMENT CWEMCCH IN RAM PAVAN LDIGTNS r rr....+u�r�r�ww�s.wi ww..K Ir. RPI 1:12 j vnJ LI S six NO MANATEE OF STAOLP INGOT IS/N1� �Rr:..A.iL' 7� �• � GR REFER SHORN slam e<C01SECIED P—20547 FOR REFERENCE SH N SNOE3 G&Y. +. w'�r're°".r�'r'la .w'1��' 5 Page 39 Version 1 May, 2015 • • II Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 22.0 Days Vs Depth Days Vs Depth 0 'Schrader Bluff Well -MPI.1912CCL M P1-1812011) �' v -MPI-17(2004) 2000 -MPI-15(2002) _ 1� ‘. .\\\\\ . • .1 ti • 8000 1p ill 101300 12000 14000 0 5 10 15 20 25 30 Days Page 40 Version 1 May,2015 • • 11 Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 23.0 Formation Tops Formation TVD (Top) TVD (Bottom) Anticipated Pressure (Psi) SV1 2175 3545 973 Ugnu LA1 3544 3767 1585 Ugnu MB 3768 4011 1685 SB NB Sand Top 4012 4149 1794 SB OA Sand Top 4150 4172 1866 Page 41 Version 1 May, 2015 • • Milne Point Unit L-49 111 Drilling Procedure Hilcorp Energy ConigenY 24.0 Anticipated Drilling Hazards 12-1/4" Hole Section: Lost Circulation Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Gas Hydrates Remember that hydrate gas behave differently from a gas sand. Additional fluid density will not prevent influx of gas hydrates. Once a gas hydrate has been disturbed the gas will come out of the hole. Drill through the hydrate section as quickly as possible while minimizing gas belching. Minimize circulation time while drilling through the hydrate zone. Excessive circulation will accelerate formation thawing which can increase the amount of hydrates released into the wellbore. Keep the mud circulation temperature as cold as possible. Weigh mud with both a pressurized and non-pressurized mud scale. The non-pressurized scale will reflect the actual mud cut weight. Add 1.0—2.0 ppb DRILTREAT to the system to help thin the mud and release the gas. Isolate/dump contaminated fluid to remove hydrates from the system. Hole Cleaning: Maintain rheology of mud system. Sweep hole with high viscosity sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Monitor ECDs to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out a particular section of the hole. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Anti-Collison: There are a number of wells in the vicinity of L-49. Take directional surveys every stand,take additional surveys if necessary. Continuously monitor proximity to offset wellbores and record any close approaches on AM report. Discuss offset wellbores with production foreman and consider shutting in adjacent wells if necessary. Monitor drilling parameters for signs of collision with another well. Wellbore stability (Permafrost, running sands and gravel, conductor broaching): Washouts in the permafrost can be severe if the string is left circulating across it for extended periods of time. Keep mud as cool as possible by taking on cold water and diluting often. High TOH and RIH speeds can aggravate fragile shale/coal formations due to the pressure variations btwn surge and swab. Bring the pumps on slowly after connections. Monitor conductor for any signs of broaching. Maintain mud parameters and increase MW to combat running sands and gravel formations. H2S: Treat every hole section as though it has the potential for H2S. No H2S events have been documented on drill wells on 'L"pad. 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. Page 42 Version 1 May, 2015 • • 11 Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. 3. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. 8-1/2" Hole Section: Hole Cleaning: Maintain rheology of mud system. Sweep hole with low-vis water sweeps. Ensure shakers are set up with appropriate screens to maximize solids removal efficiency. Run centrifuge continuously. Monitor ECDs to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out a particular section of the wellbore. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Maintain circulation rate of> 500 gpm. Lost Circulation: Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Faulting: There is at least (1)fault that will be crossed while drilling the well. There could be others and the throw of these faults is not well understood at this point in time. When a known fault is coming up, ensure to put a"ramp" in the wellbore to aid in kicking off(low siding) later. Once a fault is crossed, we'll need to either drill up or down to get a look at the LWD log and determine the throw and then replan the wellbore. H2S: Treat every hole section as though it has the potential for 112S. No H2S events have been documented on drill wells on `L"pad. 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. 3. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Abnormal Pressures and Temperatures: There are no abnormal pressures or temperatures observed on"L" pad. Page 43 Version 1 May, 2015 •11 • Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 25.0 Nordic #3 Rig Layout (Drillers Side) o kill ..�r p ' r -+Galista 0,11 I.. '4 Services R1G NO. 3 ot:ato>t,,, 1 VA The Dnepr.orrlydinp apeer(zaeaaanr drawing sat three comma.1,The drapwl M reel:rove patter y mf\i f d.r Calms and n pnrmeel he Madarerruaiwl rrprryln I...The Designee ken 4 Iwo on a f.d.r.r,boon w n :he tepree.aEmrorrm:h:.vol on In add,rranrE.rmd.apiplird traced.ehor overt-se&to rrp:.Jra eel-n AnT roannor what weft,in whole m tan.net any nem her.m hr Leah.oussfarewred.m 3.1erriotesi ft-ieh the aru.4 I,dr eign wirbaar rhr wzolen ayr.emerr of Nn di—Cahn&Me Demiyn may net be&.e k«.3.o arn:thee Furor cerepr for:he erred-lc power-for which a het',ern provided Al ; . . . till' 1f olio. illo 4411,,„,. 0.„,,,,, 1� LI l '•Nh, I. 104 1lf�Rl V1" II�y1'—.—r II WOgK ' — �IL' OWL UK If! '77 l WIl` WS OW I t 111 ( t __ l L_ _ t . \ t,\,,, t ,,I 7Y.e W-I' 'p--wyr !NW 1 Drillers Side Page 44 Version 1 May, 2015 • • II Milne Point Unit L-49 Drilling Procedure Hilcorpy Energy CmEy 26.0 Nordic #3 Rig Layout (Well End & Top View) u.-0 llII IIII III I...„,.. Iil ,, • t al II .. A$ 1 IIIlkl) r;th� r..\\,, ,r.,...., I , q ... , IIII III MEI MN i p nom r''�i •iii TA/4 =, i��rl #A,..:: ~ "�r I ■■ ^ 000US tO *CCM FLOW WES • Well End 9"-2,12*- 1.--v-Ptf I az-i —,,-r—. i# ry IJ1 I I I 111 I I I I( vwzve'WPM Pm gummy n �• — �I � F/[OWN //--�� L Of-]f9 `—� 0 R�, COGNd17F Ora ' ipiA NR HFA1tjR e } .� r: : ' till .WED PPE We WNW ._O 1 ;7'1'5' -I__ 4t M!` AMA . o� i s r1111[111 ( U MS OM= UPOI WA I TOP VIEW Page 45 Version 1 May,2015 • • Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 27.0 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. 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Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 29.0 Casing Design Information Calculation & Casing Design Factors DATE: 6/212015 WELL: MPU L-49 DESIGN BY:Luke Keller Design Criteria: Hole Size 12-1/4" Mud Density: 9.5 ppg Hole Size 8-1/2" Mud Density: 9.5 ppg Hole Size Mud Density: Drilling Mode MASP: 1449 psi (see attached MASP determination& calculation) MASP: Production Mode MASP: 1449 psi (see attached MASP determination&calculation) Collapse Calculation: Section Calculation 1 Normal gradient external stress(0.494 psi/ft)and the casing evacuated for the internal stress Casing Section Calculation/Specification 1 2 3 4 Casing OD 9-5/8" 5-112" Top(MD) 0 5,656 Top (TVD) 0 4,172 Bottom (MD) 5,856 12,374 Bottom (TVD) 4,172 4,172 _ Length 5,856 8,202 Weight(ppf) 40 17 Grade L-80 L-80 Connection TC-Il DWC=C HT Weight w/o Bouyancy Factor(lbs) 234,240 139.434 Tension at Top of Section (lbs) 234,240 139.434 Min strength Tension(1000 lbs) 916 347 Worst Case Safety Factor(Tension) 3.91 2.49 Collapse Pressure at bottom (Psi) 2,061 2,061 Collapse Resistance who tension (Psi) 3,090 7,100 Worst Case Safety Factor(Collapse) 1.50 3.44 MASP (psi) 1,449 1,449 Minimum Yield (psi) 5,750 7,740 Worst case safety factor(Burst) 3.97 5.34 Page 48 Version 1 May, 2015 • • 11 Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 30.0 8-1/2" Hole Section MASP Maximum Anticipated Surface Pressure Calculation 84/2"Hole Section II Hen.p MPU L-49 Milne Point Unit MD TVD Planned Top: 5856 4172 Planned TD: 12374 4172 Anticipated Formations and Pressures: Formation ND Est Pressure Oil/Gas/Wet PPG Grad Schrader Bluff OA Sand 4,172 1866 Oil/Wet 8.6 I 0.447 Offset Well Mud Densities Well MW range Top(ND) Bottom(ND) Date L-37(1998) 8.9-9.3 Surface 7,050 1998 L-35(1997) 8.4-9.2 Surface 5,687 1997 L-341(1997) 8.4-9.4 Surface 5,842 1997 Assumptions: 1. Field test data suggests the Fracture Gradient in the Schrader Bluff is btwn 11.5 and 15 ppg EMW. 2. Maximum planned mud density for the 8-1/2"hole section is 9.5 ppg. 3. Calculations assume full evacuation of wellbore to gas Fracture Pressure at 9-5/8"shoe considering a full column of gas from shoe to surface: 4172(ft)x 0.78(psi/ft)= 3254 psi 3254(psi)-[0.1(psi/ft)*4172(ft)]= 2837 psi MASP from pore pressure(complete evacuation of wellbore to gas from Schrader Bluff OA sand) 4172(ft)x 0.447(psi/ft)= 1866 psi 1866(psi)-0.1(psi/ft)*4172(ft)= 1449 psi Summary: 1. MASP while drilling 8-1/2"production hole is governed by pore pressure and evacuation of entire wellbore to gas at 0.1 psi/ft. Page 49 Version 1 May, 2015 • • Milne Point Unit L-49 II Drilling Procedure Hilcorp Energy Company 31.0Spider Plot (NAD 27) (Governmental Sections) t r,\ r� , 1 as o bi}/fi 4,rr ,/ l 1 . J t f I , ! ¢' r.1PL_CT 5� , l •)! r INr �, J f f.. J f r rwc..10 %♦t♦��:�\� 1tI .ljIlfrl,/i ,�/ r l y, r f ii / r / // 'r ♦r ;�,11;k / >}rl//!�;aLJ F5 s F-..:i r I 1 r { J { / r / //' 'r1 r; r. F 10 S. r tr N��i , i V t f r r ! I / / / / , r t� .. Ir t/l t1 o'yl ! rJ II / I / / : /. r ♦�'ty♦��KA A� .. r4,/i r l f t , f I I r f r r / y,/ '• t 1,Vrr+,,�4% FI 4,,, ,„/r v,,,t t,, 1 1 11 J r Jr rr // ,, /�P /� `Q�♦♦ r r�,} , ttv„., r tf rJ {J/l5IF /f ,;f / / ,it JJ I! 'Va • Sec.4 fIr4rr' f // ,: .'f 41FCA9 --FIF,'ti-v ♦ r , a I', 1) l II r ,tr'L.',779 , Jr dr 44 ,/o r!I{/r /r // ', /�� •` Y ✓>` ,r+♦ * ♦ '. i 1 !I I r / ,' /1 • Lrpo r r •moi/ r\♦' rrr t 04,:t tt t♦ JJ Ilrr{1 ' / .' f • / s?......,.:;,, : • Y+ r \1 It�� 111 17# f! / '+! f • ♦ ? � , . r \‘‘\\ t .� IF! a/f/N /�/ /, I/ •-,•_3.„..„. 2......:".:\ 1 r"....,......wi__o2c\ :.:Alai,i41,:i41:611:::;(::;.,i'n.141.:5L:1„, 5 / ,;' ADL047434 `r.•FC-ca + w _ IPHL +` ^( • 3 raac_• 3+Sec ? "erly t5♦ \ r 3 `�'` .... '`—• . Sec.9 `�: �' MPL-49 TPH /p' /"A UO13i�N10E ¢ z' . •++ .ou //,ltd - .„ 43.1 1Q rt "*" 1 r `r „. • .. i '"• 1 ' MPL-49 BHL // Sec.18 3 I it7' ' sec:is ' /f <C Legend ADL315848 MPL-49 SHL t, mo MPL-49 TPH ' MPL-49 BHL 4 PP Other Surface Holes(SHL) enc.'s) • Other Bottom Holes(BHL) `` - _rte^ 4 CNC -- - - Other Well Paths <C * + C ^sC764:0 ntoDOnt? t' �_ {/1� a, Page 50 Version 1 May, 2015 • • II Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 32.0 Surface Plat (As Built) (NAD 27) / 36 31 I 37 ill 33 es:/4, I f 4 T t.N �l T 13 N 1 );" 1 M a_r F-P (/ ' AD r 32 ■ 33 ■ L-PAD I ' ,7' 26 ■ 29 ■ t3 7 s I -s` 41 II43 IN „ . .» I 45 • 1,---^ pi--, pi t3 18 17 1 ,1! I 1 r II I 39 ■ ■ 42 VICINITY MAP t II ■ 9 N.Y.., 34 ■ • 14 ' 3 • ■ 10 ' 15 • ■ 47 2 • 7 .`r 0'1%%111 pg. 12 • L-49 ��.� �� OF A� fry 6 35 436 5 37 11 5Od v 4;$§ '* •4921 /N ':A I t 8018 , .rte' ) !r ' •i i 40 4•R d F. Mison il 1 -4'0,,_#' " 10608 ` 1 L-PAD ' "'-"it Illitsm.V0V4% 11 I SURVEYOR'S CERTIFICATE NOTES: LEGEND I HEREBY CERTIFY THAT 1 AM 1SEO . ALASKA STATE PLANE COORDINATES ARE + AS-DUCT CONDUCTOR TTODPRACTICE LAG SURVEYINGC LY REGISTERED AM) N ZONE 4,NAD27. • Emma CONDUCTOR THE STATE OF ALASKA AND THAT 2. BASIS Cf LOCATION IS L-PAD MONUMENTS THIS AS-BUILT REPRESENTS A SURVEY MADE BY ME OR LA L-1 NORTH AG L-2 SOUTH. GER MY DIRECT SUPERVISION AND 3. ELEVATION DATUM IS MSL. THATENS10N5 AND ALL OTHERMANSIONS DETAILS ARE 4. GEODETIC P0611TCNS ARE NAD27. GRAPHIC SCALE CORRECT AS OF JULY 4, 2015. 5. PAD MEAN SCALE FACTOR IS: 0.9999023 0 100 200 400 6. DATE Cf SURVEY. JULY 4, 2015. R )_ 1 7. REFERENCE FI 1O BOOK: HC75-02 PGS. (IN FEET ) 50-58 t Toth -200 ft. LOCATED WITHIN PROTRACTED SEC. 8, T. 13 N., R. 10 E., UMIAT MERIDIAN, AK. WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD)BOX ELEV. OFFSETS Y-6,031,494.52 N= 1110.03 70'29'48.865" 70.4969071' 3,303'FSL L- X= 545.148.08 E= 1422.61 149'37'50.919" 149.6308099' 17.5' 4.733'FEL Y=6,031,478.37 N= 1110.21 70'29'48.710" 70.4968639' 3,287'FSL L-48 X= 545,122.81 E= 1392.18 14937'51.681" 149.6310225' 175' 4.759'FEL Y=6,031,591.23 N= 1179.23 70'29'48.865" 70.4971930' 3, 408'FSL L-49 X= 545,185.00 E= 1509.82 149'37'50.916" 149.6304998' 17'0' 4.695'FEL DRAM WPM Hilcorp Alaska . "nil JA03123 fl °"' i11 MUX,al MPU L-PAD 9NF1: mNO __- nill sulk AS-BUILT CONDUCTOR 04 000404 INGLOP y gi_...._..._.__., . ALAI. r-200' WELLS L-46. L-48, L--49 1 or; 44 D>T .e1ea111 ■Y 114t Page 51 Version 1 May,2015 • • Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 33.0 Offset MW vs TVD Chart MW vsN'D Offsets 0 L-37 —L-35 1000 - -L-34i 2000 • \\( 3000 - — - a 4000 44‘NAI 5000 11\116000 7000 8000 8.0 9.0 10.0 11.0 12.0 13.0 14.0 15.0 Mud weight(PPG) Page 52 Version 1 May, 2015 • • Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 34.0 Drill Pipe Information 5" 19.5# S-135 DS-50 Drill Pipe Configuration Pipe Body OD 5.000 80%Inspection Class Pipe Body Wall Thickness in 0.362 Nominal Weight Designation 19.50 Pipe Body Grade 5-135 Drill Pipe Approximate Length 31 5 (,, Drill Pipe Length Range2 3moothEdge Height m)�3f32 Raised 1 Connection GPDS50 Tool Joint SMYS p;++120.000 Tool Joint OD 6.625 Upset Type IEU Tool Joint ID o.3.250 Max Upset OD (DTE) ,.. 5 125 Pin Tong 9 Friction Factor �1.0 Box Tong un 12 Note 1000 space slay Intrude nar00ebin Drill Pipe Performance Drill-Pipe Length Range2 f Performance of Drill Pipe with Pipe Body at I Best Estimates Nominal Il 80%InS ectlon Class ^Ix t'u' vrn coaurq e.z.accuralei Drill Pipe Ad usted Weight b n+ Apptntfaake-,p -` Operational Max Tension p 1 9 24.11 23.29 ta5le utas Torque in-lbs) nos-� Fluid Displacement .,t+�0.37 0.36 Tension Only ()Torque 560.800 Fluid Dliglacemenl eb--m 0 0088 0.0085T 43,100 ccmbl xd t a3mm Fluid Capacity 1gap111 0.71 0.70 0.72 39.600 410.500 Fluid Capacity ceolz+ni 0.0169 0.0167 0.0172 36,100 Tension Only0 560,800 : III karr„km Mur Drift Size tont 3.125 convince Lowing 32.100 467.400 Note:.OS field barrel equals 42 US gallons. !Wile.Dell pipe assembly values are best estimates and may vary due to{ripe body rill tolerance,Internal 014010 coating and other factors Connection Performance GPDS5O ( 6.625 i:n) OD X 3.250 ion) ID ) 120.000 (-pso Appled Make:lp Terz;on at ShoulderTertalon at eorerecbon TOoool Joint Dimensions Torque Separation. Yell n e:) Ibot Ansi Balanced nft ot 6.435 Maximum Make-up Torque 43,100 Tensile Limited 1.046.900 su mum Toolyard 00 or API 5.930 wnum Mike-up Torque 36,100 1.202,500 1,250.000 Pmm um Class un; ""' Note The maximum make-op torque shouid be aciated when posslnk karwlltan Tool Joint 00 for 5.93 Note To ma xi,41 canned o-oae,a`un al lens 11 a M T 1141-37,500 tIJbs)should be applied. I [ToolJoint Torsional Strength ..n-iest 71,840 Tool Joint Tensile Strength it. 1250,000 Counterborc iln Elevator Shoulder InformationElevator OD 3/32 Raised 6.812 [ SmoothEdge Height Nominal Tool Joint Worn to Bevel worn to Min TJ OD for 3132 Raised OD Diameter API Premium Class Box OD n-.6.812 6.625 6.063 5.930 Elevator Capacity Ib: 1,658,000 1,440,200 823,600 685,600 -n;5.219 ""'-"'1 Note Elevator capacity based on assumed Elevator Bore,no wear factor,and contact stress;'t I'0 J:4 - Assumed Elevator Bore Diameter Note A raised e'evator 00 Increases elevator capac,ly wNlcul affecting+rake-up toque Pipe Body Slip Crushing Capacity Pipe Body Configuration( 5 iBri OD 0.362 Wall S-135) Nominal 80%Inspection Class API Premium Class /irt7 Slip Crushing Capacity m-?498, m)16-5 300 396,500 396.500 Note:Sip Cnrleendfeding.Sip meting bad Is oak waled +to Spin-nenbold equation horn Goes.OYi:.P Fe Assumed Slip Length Fat In me Stp Anes'.50010 00,inns Oor the sip length and eansFerbe load!odor shovel and Is to reference Transverse Load Factor(K) 4.2 1 ps.teeSip 00 and 001 50505,511 1000on roe,. otheer x�Comet +iellt`err,nuta�rfored a rberf q" rfonnalbm. Pipe Body Performance Pipe Body Configuration( 5(W OD 0.362 c° Wail S-135) Nominal 80%Inspection Class API Premium Class Pipe Tensile Strength +Im:z,i 712100 560,800 560,800 Pipe Torsional Strengthn-IC= 74,100 58.100 58,100 TJiPipeBody Torsional Ratio 0.97 1.24 124 80%Pipe Torsional Strength n Ib.+59 309 46.500 46.500 Burst (poi 17.105 15.638 15,638 Note:Noo final Burst Colapse pal 15,672 10.029 10.029 calculated a,07 a Raw per API. Pipe OD on)5.000 4.855 4.855 Wall Thickness n+0.362 0.290 0.290 Nominal Pipe ID on"4276 4.276 4.276 Cross Sectional Area of Pipe Body 'nn2+5.275 4.154 4.154 Cross Sectional Area of OD nn"I1)9.635 18.514 _18.514 Cross Sectional Area of ID ,'0' 14.360 14.360 14.360 SectionS Modulus ,"31+5. 48 _4-476 4.476 din Polar Section Modulus ,.,^3+ 11.415 8.953 8.953 Page 53 Version 1 May, 2015 •II • Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company Operational Limits of Drill Pipe Connection ',GPDS50 Tool Joint OD 4.825 I Tool Joint ID ,n43.250 Tool Joint Specified Minimum 120,000 Yield Strength ipAl Pipe Body 1-710%Inspection Class Pipe Body OD ,.,,5 J(Wall Thickness 1,.]0.362 Pipe Body Grade 1S-135 Combined Loading for Drill Pipe at Combined Loading for Drill Pipe at Maximum Make-up Torque= 43,100 ,n-„„ Minimum Make-up Torque= 36,100 in.iosy Operations AssemblyPipe Body CR:median Operational AssTensiony Max Body T..II.,nNdna I Torque Max Ten:aan Maa Tenalan Torque MaxMeX 'MTension rq Max Tension Mins; Ilbsy (lert ;Mei E•!absy iIbsl Rlbcl (Ibsi 0 560,800 560,800 1.046.900 0 560,800 '560,800 1.202,500 2,100 560,400 560.400 1.046.900 1,700 560,500 560.500 1,202.500 4.200 559.300 559,300 1,046.900 3.400 559.800 559.800 1,202,500 6,300 557.500 557.500 1,046.900 5.100 558.600 558.600 1,202.500 8,300 555.000 555,000 1.046.900 6.800 556.900 556.900 1,202,500 10,400 551,700 551,700 1.046.900 8,400 554,900 554.900 1,202,500 12,500 547,600 547.600 1,046.900 )0100 552.200 552.200 1.202.500 ' 14,600 542.800 ' 542,800 1.046.900 11.800 549.100 • 549,100 1.202.500 16.700 537.100 537.100 1.046.900 13.500 545.400 545.400 1.202,500 18,800 530,600 530,600 1.046.900 15.200 541,200 541,200 1.202.500 20.800 523,600 523,600 1.046.900 16.900 536.500 536.500 1.202.500 22,900 515,400 515,400 1,046.900 18.600 531,300 531,300 1.202,500 25.000 506.200 506,200 1.046.900 20.300 525,400 525.400 1.202.500 27.100 496,100496.100 1.046.900 22.000 519,000 519.000 1.202,500 29,200 484,800 484.800 1,046.900 23.700 512.000 512.000 1.202.500 31,300 472,500 472,500 1.046.900 25.300 504,800 504.800 1,202.500 33.300 459,600 459.600 1.046.900 27 000 496.600 496.600 1.202.500 35.400 444,700 444,700 1,046.900 28.700 487.600 487.600 1.202,500 37.500 428.400 428,400 1.046.900 30.400 477.900 477.900 1.202.506' 39,600 410,500 410,500 1.046.900 32.100 467,400 .467.400 1,202,500 Operational drilling torque is limited by the Make-up Torque. Operational drilling torque is limited by the Make-up Torque. Connection Make-up Torque Range Make-up Torque Connection Max In b.,Tension ,r;, Min MUT 36,100 1,202,500 36,900 1,229,200 37.700 1,243,600 :... 38.400 1,218,100 39.200 1,189,000 40,000 1,159,800 40.800 1,130,700 41.500 1,105,200 42,300 1,076,100 Max MUT 43,100 1,046,900 Page 54 Version 1 May, 2015 • • Milne Point Unit L-49 II Drilling Procedure Hilcorp Energy Company Connection Wear Table Connection GPDS50 Tool Joint 00 0,16.625 Tool Joint ID ,,,,.13.250 Tool Joint Specified Minimum 120,000 Yield Strength urn. Connection Wear Tool Connection Max Connection Max Min MUT Connection Max Joint OD Torsional MUT Tension Tension New OD Strength ,. ill-,bsl :bib: ubst m.mst 11e5} . 1 A,`t � � l�� � 6.625 71,800 43,100 1,046,900 35,900 11,195,900 6.562 71,800 43,100 1,034,900 35,900 1.208.700 6.499 71,800 43.100 1,022,600 35,900 1,222.400 6.435 71,800 43,100 1,009,800 35.900 1.237.500 6.372 71,200 42,700 1,008,100 35,600 1.245,200 6.309 68,000 40,800 1,057,300 34.000 1.207.700 6.246 64,800 38,900 1,104,800 32.400 1.169.800 / 6.183 61,700 37,000 1,150,400 30.800 1.131.300 6.12 58,600 35,200 1,190,900 29,300 1.096,100 6.056 55,500 33,300 1,232,300 27.800 1.060.800 Worn OD 5.993 52,600 31,500 1,227,200 26.300 1,024.600 5.93 49,600 29,800 1,187,100 24.800 987.900 Pipe Body Combined Loading Table(Torque-Tension) Pipe Body 80%Inspection Class Pipe Body OD .1,15 Wall Thickness ,.;10.362 Pipe Body Grade S-135 ray V tiPipe Body Torque � 0 5.330 10.600 15.600 21.100 26.400 31.700 37.000 42.300 47.500 52.800 58.100 A-ms} i Pipe Body Max Tension 558,400 551.400 534.600 522.500 499.600 470.000 432.400 384.500 323 100 234.300 12.200 lx7s? D Page 55 Version 1 May, 2015 • • Hilcorp Energy Company Milne Point M Pt L Pad Plan MPL-49 MPL-49 (Well #1) Plan: MPL-49 wp4 Standard Proposal Report 06 July, 2015 a. / HALLIBURTON Sperry Drilling Services • • NALLIBURTON Project: Milne Point WELL DETAILS:Plan MPL-49 NAD 1927(NADCONCONt1S) Alaska Zone 04 Site: M Pt L Pad GaundLeva: 17.00 an.mv Drilling Well: Plan MPL-49 +N/-S OEO.W Northing Easling tatittude Longitude Slot Wellbore: MPL-49(Well#1) 0.00 0.00 6031591.23 545185.00 70"2949.816N 149°3749.801 W -20007 Design: MPL-49 wp4 FORMATION TOP DETAILS No formation data is available -1500- -1000- -500- _ ,-` o-_ CASING DETAILS 500- 500 TVD TVDSS MD Size Name -_ Start Build 3.00 • 4172.60 4125.60 5$56.42 9-5/8 9 5/8" 4171.99 4124.99 12374.00 5-1/2 51/2" 10007 1000 Start OLS 4.00 TFO 58.18 c_ 0 1500- 1500 N _Start 1610.16 hold at 1965.42 MD c 2000- 2000__ al 2500 2500- Start DLS 5.00 TFO-0.72 3000 Start DLS 5.00 TFO-99.46 .Start 199.56 hold at 8032.13 MD 2 3000y35 0_ Start 500.00 hold at 5351.37 Mei Start DLS 5.00 TFO-179.25 000 3500- O • - Start 5100.00 hold at 8272.43 MD %'$ Start 1001.57 hold at 11372.43 MD 4000- I •' - TD at 12374.00 0 o o ut 8 N o o' o of�S MPL-49 wp4 g g o 8 S o b o 4500- 95/8", o 0 o a 5 1/2" 5000- Well 1 Heel Well 1 Toe 5500- 6000- 11111111111111liiill++lil+1+l 1111111111111111111rIr l ilirlilir11111111111I Ir Ir 1111111r111111111111lliiiliiirIr1111111111i -2000 -1500 -1000 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 8000 6500 7000 7500 8000 8500 9000 9500 10000 Vertical Section at 136.83°(1250 ustt/in) • I • HALLIBURTON Project: Milne Point WELL DETAILS:Plan MPL-49 Site: M Pt L Pad GmundLovd: 1700 miaerre Orratne +N/-6+F/-W No Well: Plan MPL-49 0.00 0.00 6031599123 5451 70°29'49.816 N 149e 3749801W Slot 2000— Wellbore: MPL-49(Well#1) Plan: MPL-49 wp4 REFERENCE INFORMATION 1500— Co-ordinate(NtE)Reference:Well Plan MPL-49.True North Vertical(TVD)Reference'.As-Staked MPL-49 @ 4]oousn Measured Depth Reference:As-Staked MPL-49 @ 4700use Calculation Method:Minimum Curvature 1000- - CASING DETAILS 500— ND TVDSS MD Size Name 4172.60 4125.60 5856.42 9-5/8 95/8" _ I�4 __Start Build 3.00 ' 4171.99 4124.99 12374.00 5-1/2 51/2" 0— p_ Sort DIS 4.00 TFO 58.18 a__ ? o Start 1610.16 hold at 1955.42 MD -500— _ 't0 -10007 lid. -Stmt DLS 5.001TO-99.46 • -1500— r r 3150 Start 500.00 hold at 5351.37 MD C -2000— StaTIDLS 5.00 TFO-0.72 g -25007 Web 1 Fkd F__ a ___ Start 199.56 hold at 6032.13 MD _ _Stet-0LS 5.00 TFO-179.25 9 5/8" Start 5630.00 hold at 6272.43 MD -3000 -3500— M) 4000 -4500— -50007 Steel 1031.57 hold d 11372.43 MD -5500— 6.6d1 1 Toe I ,� _ F -6000- 512""% TD at 12374.00 s -6500— T M Azimuths to True North -7000— Magnetic North:19.00' Magneto Field 7500 Strength:57506.1snT Dip Angle'81.08' Date:7/28/2015 Model:BGGM2615 -8000- 1111I1I11l111LI1I11l111111111111I11llll1llrl1rl111111111IIIlII1111t1111111111III 111111111111111111111111111111111111111111111111111111111111111111 -4500 -4000 -3500 -3000 -2500 -2000 -1500 -1000 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 West(-)/East(+)(1500 usn) liiltiu•j1 • • • Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan MPL-49 Company: Hilcorp Energy Company ND Reference: As-Staked MPL-49 @ 47.00usft Project: Milne Point MD Reference: As-Staked MPL-49 @ 47.00usft Site: M Pt L Pad North Reference: True Well: Plan MPL-49 Survey Calculation Method: Minimum Curvature Wellbore: MPL-49(Well#1) Design: MPL-49 wp4 Project Milne Point,ACT,MILNE POINT Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site M Pt L Pad,TR-13-10 Site Position: Northing: 6,029,799.28usft Latitude: 70°29'32.230 N From: Map Easting: 544,529.55 usft Longitude: 149°38'9.412 W Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.34 ° Well Plan MPL-49 Well Position +N/-S 0.00 usft Northing: 6,031,591.23 usft Latitude: 70°29'49.816 N +E/-W 0.00 usft Easting: 545,185.00 usft Longitude: 149°37'49.801 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 17.00 usft Wellbore MPL-49(Well#1) Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°l Cl (nT) BGGM2015 7/26/2015 19.00 81.08 57,506 Design MPL-49 wp4 Audit Notes: Version: Phase: PLAN Tie On Depth: 30.00 Vertical Section: Depth From(ND) +NI-S +E/-W Direction (usft) (usft) (usft) (°) 30.00 0.00 0.00 136.83 Plan Sections Measured Vertical ND Dogleg Build Turn Depth Inclination Azimuth Depth System +NI-S +El-W Rate Rate Rate Tool Face (usft) (°) (°) (usft) usft (usft) (usft) (1100usft) (1100usft) (1100usft) (°) 30.00 0.00 0.00 30.00 -17.00 0.00 0.00 0.00 0.00 0.00 0.00 800.00 0.00 0.00 800.00 753.00 0.00 0.00 0.00 0.00 0.00 0.00 1,100.00 9.00 170.00 1,098.77 1,051.77 -23.16 4.08 3.00 3.00 0.00 170.00 1,965.42 40.01 218.67 1,881.56 1,834.56 -315.97 -163.09 4.00 3.58 5.62 58.18 3,575.58 40.01 218.67 3,114.92 3,067.92 -1,124.14 -809.84 0.00 0.00 0.00 0.00 5,351.37 83.00 122.17 4,111.06 4,064.06 -2,280.18 -317.88 5.00 2.42 -5.43 -99.46 5,851.37 83.00 122.17 4,171.99 4,124.99 -2,544.42 102.21 0.00 0.00 0.00 0.00 6,032.13 92.04 122.06 4,179.81 4,132.81 -2,640.32 255.00 5.00 5.00 -0.06 -0.72 6,231.69 92.04 122.06 4,172.72 4,125.72 -2,746.17 424.03 0.00 0.00 0.00 0.00 6,272.43 90.00 122.03 4,171.99 4,124.99 -2,767.78 458.56 5.00 -5.00 -0.07 -179.25 11,372.43 90.00 122.03 4,171.99 4,124.99 -5,472.63 4,782.19 0.00 0.00 0.00 0.00 12,374.00 90.00 122.03 4,171.99 4,124.99 -6,003.83 5,631.29 0.00 0.00 0.00 0.00 7/6/2015 12:45:38PM Page 2 COMPASS 5000.1 Build 73 110 • Halliburton HALLIBLiRTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan MPL-49 Company: Hilcorp Energy Company TVD Reference: As-Staked MPL-49 @ 47.00usft Project: Milne Point MD Reference: As-Staked MPL-49 @ 47.00usft Site: M Pt L Pad North Reference: True Well: Plan MPL-49 Survey Calculation Method: Minimum Curvature Wellbore: MPL-49(Well#1) Design: MPL-49 wp4 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N1-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) -17.00 30.00 0.00 0.00 30.00 -17.00 0.00 0.00 6,031,591.23 545,185.00 0.00 0.00 100.00 0.00 0.00 100.00 53.00 0.00 0.00 6,031,591.23 545,185.00 0.00 0.00 200.00 0.00 0.00 200.00 153.00 0.00 0.00 6,031,591.23 545,185.00 0.00 0.00 300.00 0.00 0.00 300.00 253.00 0.00 0.00 6,031,591.23 545,185.00 0.00 0.00 400.00 0.00 0.00 400.00 353.00 0.00 0.00 6,031,591.23 545,185.00 0.00 0.00 500.00 0.00 0.00 500.00 453.00 0.00 0.00 6,031,591.23 545,185.00 0.00 0.00 600.00 0.00 0.00 600.00 553.00 0.00 0.00 6,031,591.23 545,185.00 0.00 0.00 700.00 0.00 0.00 700.00 653.00 0.00 0.00 6,031,591.23 545,185.00 0.00 0.00 800.00 0.00 0.00 800.00 753.00 0.00 0.00 6,031,591.23 545,185.00 0.00 0.00 900.00 3.00 170.00 899.95 852.95 -2.58 0.45 6,031,588.66 545,185.47 3.00 2.19 1,000.00 6.00 170.00 999.63 , 952.63 -10.30 1.82, 6,031,580.94 545,186.88 3.00 8.76 , 1,100.00 9.00 170.00 1,098.77 1,051.77 -23.16 4.08 6,031,568.10 545,189.22 3.00 19.68 1,200.00 11.61 187.13 1,197.17 1,150.17 -40.85 4.19 6,031,550.41 545,189.44 4.00 32.67 1,300.00 14.85 197.48 1,294.51 1,247.51 -63.07 -0.91 6,031,528.16 545,184.48 4.00 45.38 1,400.00 18.39 204.07 1,390.33 1,343.33 -89.71 -11.19 6,031,501.47 545,174.36 4.00 57.77 1,500.00 22.07 208.55 1,484.15 1,437.15 -120.62 -26.61 6,031,470.46 545,159.13 4.00 69.78 1,600.00 25.85 211.80 1,575.52 1,528.52 -155.67 -47.09 6,031,435.29 545,138.86 4.00 81.33 1,700.00 29.69 214.26 1,663.99 1,616.99 -194.69 -72.52 6,031,396.12 545,113.67 4.00 92.38 1,800.00 33.55 216.20 1,749.13 1,702.13 -237.47 -102.80 6,031,353.16 545,083.66 4.00 102.88 1,900.00 37.45 217.78 1,830.53 1,783.53 -283.82 -137.76 6,031,306.60 545,048.98 4.00 112.77 1,965.42 40.01 218.67 1,881.56 1,834.56 -315.97 -163.09 6,031,274.31 545,023.85 4.00 118.89 2,000.00 40.01 218.67 1,908.05 1,861.05 -333.32 -176.98 6,031,256.87 545,010.07 0.00 122.04 2,100.00 40.01 218.67 1,984.65 1,937.65 -383.51 -217.14 6,031,206.44 544,970.21 0.00 131.17 2,200.00 40.01 218.67 2,061.24 2,014.24 -433.71 -257.31 6,031,156.01 544,930.36 0.00 140.30 2,300.00 40.01 218.67 2,137.84 2,090.84 -483.90 -297.48 6,031,105.58 544,890.50 0.00 149.43 2,400.00 40.01 218.67 2,214.44 2,167.44 -534.09 -337.64 6,031,055.15 544,850.64 0.00 158.56 2,500.00 40.01 218.67 2,291.04 2,244.04 -584.28 -377.81 6,031,004.72 544,810.78 0.00 167.69 2,600.00 40.01 218.67 2,367.64 2,320.64 -634.47 -417.98 6,030,954.29 544,770.93 0.00 176.82 2,700.00 40.01 218.67 2,444.24 2,397.24 -684.67 -458.15 6,030,903.86 544,731.07 0.00 185.95 2,800.00 40.01 218.67 2,520.84 2,473.84 -734.86 -498.31 6,030,853.43 544,691.21 0.00 195.08 2,900.00 40.01 218.67 2,597.43 2,550.43 -785.05 -538.48 6,030,803.00 544,651.35 0.00 204.21 3,000.00 40.01 218.67 2,674.03 2,627.03 -835.24 -578.65 6,030,752.57 544,611.50 0.00 213.34 3,100.00 40.01 218.67 2,750.63 2,703.63 -885.43 -618.81 6,030,702.14 544,571.64 0.00 222.47 3,200.00 40.01 218.67 2,827.23 2,780.23 -935.63 -658.98 6,030,651.71 544,531.78 0.00 231.60 3,300.00 40.01 218.67 2,903.83 2,856.83 -985.82 -699.15 6,030,601.28 544,491.92 0.00 240.73 3,400.00 40.01 218.67 2,980.43 2,933.43 -1,036.01 -739.32 6,030,550.85 544,452.07 0.00 249.86 3,500.00 40.01 218.67 3,057.03 3,010.03 -1,086.20 -779.48 6,030,500.42 544,412.21 0.00 258.99 3,575.58 40.01 218.67 3,114.92 3,067.92 -1,124.14 -809.84 6,030,462.30 544,382.08 0.00 265.89 3,600.00 39.82 216.79 3,133.65 3,086.65 -1,136.53 -819.43 6,030,449.85 544,372.57 5.00 268.37 3,700.00 39.38 208.97 3,210.75 3,163.75 -1,189.96 -853.99 6,030,396.22 544,338.34 5.00 283.70 3,800.00 39.47 201.10 3,288.04 3,241.04 -1,247.41 -880.82 6,030,338.61 544,311.87 5.00 307.25 3,900.00 40.09 193.34 3,364.94 3,317.94 -1,308.43 -899.70 6,030,277.48 544,293.36 5.00 338.84 4,000.00 41.21 185.85 3,440.85 3,393.85 -1,372.57 -910.49 6,030,213.28 544,282.96 5.00 378.24 4,100.00 42.79 178.76 3,515.21 3,468.21 -1,439.34 -913.12 6,030,146.51 544,280.74 5.00 425.14 4,200.00 44.78 172.13 3,587.44 3,540.44 -1,508.23 -907.55 6,030,077.66 544,286.72 5.00 479.19 7/6/2015 12:45:38PM Page 3 COMPASS 5000.1 Build 73 110 • Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan MPL-49 Company: Hilcorp Energy Company TVD Reference: As-Staked MPL-49 @ 47.00usft Project: Milne Point MD Reference: As-Staked MPL-49 @ 47.00usft Site: M Pt L Pad North Reference: True Well: Plan MPL-49 Survey Calculation Method: Minimum Curvature Wellbore: MPL-49(Well#1) Design: MPL-49 wp4 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (0) (0) (usft) usft (usft) (usft) (usft) (usft) 3,610.00 4,300.00 47.12 165.98 3,657.00 3,610.00 -1,578.71 -893.84 6,030,007.27 544,300.86 5.00 539.97 4,400.00 49.77 160.31 3,723.35 3,676.35 -1,650.25 -872.09 6,029,935.88 544,323.04 5.00 607.03 4,500.00 52.68 155.09 3,786.00 3,739.00 -1,722.30 -842.46 6,029,864.01 544,353.10 5.00 679.85 4,600.00 55.79 150.27 3,844.46 3,797.46 -1,794.31 -805.19 6,029,792.23 544,390.82 5.00 757.88 4,700.00 59.09 145.80 3,898.29 3,851.29 -1,865.75 -760.54 6,029,721.08 544,435.89 5.00 840.53 4,800.00 62.52 141.64 3,947.08 3,900.08 -1,936.05 -708.86 6,029,651.09 544,487.99 5.00 927.16 4,900.00 66.07 137.73 3,990.45 3,943.45 -2,004.70 -650.56 6,029,582.81 544,546.71 5.00 1,017.12 5,000.00 69.72 134.03 4,028.09 3,981.09 -2,071.16 -586.06 6,029,516.75 544,611.60 5.00 1,109.72 5,100.00 73.43 130.51 4,059.70 4,012.70 -2,134.93 -515.86 6,029,453.41 544,682.18 5.00 1,204.25 5,200.00 77.21 127.12 4,085.04 4,038.04 -2,195.52 -440.49 6,029,393.28 544,757.90 5.00 1,300.01 5,300.00 81.03 123.83, 4,103.92 4,056.92 -2,252.48 -360.54 6,029,336.82 , 544,838.20 5.00 ,1,396.25 5,351.37 83.00 122.17 4,111.06 4,064.06 -2,280.18 -317.88 6,029,309.38 544,881.02 5.00 1,445.64 5,400.00 83.00 122.17 4,116.98 4,069.98 -2,305.88 -277.02 6,029,283.93 544,922.03 0.00 1,492.34 5,500.00 83.00 122.17 4,129.17 4,082.17 -2,358.73 -193.00 6,029,231.60 545,006.36 0.00 1,588.36 5,600.00 83.00 122.17 4,141.36 4,094.36 -2,411.58 -108.99 6,029,179.27 545,090.69 0.00 1,684.38 5,700.00 83.00 122.17 4,153.54 4,106.54 -2,464.42 -24.97 6,029,126.94 545,175.01 0.00 1,780.40 5,800.00 83.00 122.17 4,165.73 4,118.73 -2,517.27 59.05 6,029,074.61 545,259.34 0.00 1,876.42 5,851.37 83.00 122.17 4,171.99 4,124.99 -2,544.42 102.21 6,029,047.73 545,302.66 0.00 1,925.75 5,856.42 83.25 122.17 4,172.60 4,125.60 -2,547.09 106.45 6,029,045.09 545,306.92 5.00 1,930.60 9 5/8" 5,900.00 85.43 122.14 4,176.89 4,129.89 -2,570.16 143.16 6,029,022.23 545,343.77 5.00 1,972.55 6,000.00 90.43 122.08 4,180.50 4,133.50 -2,623.26 227.79 6,028,969.65 545,428.71 5.00 2,069.17 6,032.13 92.04 122.06 4,179.81 4,132.81 -2,640.32 255.00 6,028,952.77 545,456.02 5.00 2,100.23 6,100.00 92.04 122.06 4,177.40 4,130.40 -2,676.32 312.49 6,028,917.12 545,513.72 0.00 2,165.82 6,200.00 92.04 122.06 4,173.84 4,126.84 -2,729.36 397.19 6,028,864.60 545,598.74 0.00 2,262.45 6,231.69 92.04 122.06 4,172.72 4,125.72 -2,746.17 424.03 6,028,847.96 545,625.67 0.00 2,293.07 6,272.43 90.00 122.03 4,171.99 4,124.99 -2,767.78 458.56 6,028,826.56 545,660.33 5.00 2,332.46 6,300.00 90.00 122.03 4,171.99 4,124.99 -2,782.40 481.93 6,028,812.08 545,683.79 0.00 2,359.11 6,400.00 90.00 122.03 4,171.99 4,124.99 -2,835.44 566.71 6,028,759.57 545,768.88 0.00 2,455.79 6,500.00 90.00 122.03 4,171.99 4,124.99 -2,888.47 651.49 6,028,707.05 545,853.97 0.00 2,552.47 6,600.00 90.00 122.03 4,171.99 4,124.99 -2,941.51 736.26 6,028,654.54 545,939.06 0.00 2,649.15 6,700.00 90.00 122.03 4,171.99 4,124.99 -2,994.55 821.04 6,028,602.02 546,024.15 0.00 2,745.83 6,800.00 90.00 122.03 4,171.99 4,124.99 -3,047.58 ' 905.82 6,028,549.51 546,109.24 0.00 2,842.51 6,900.00 90.00 122.03 4,171.99 4,124.99 -3,100.62 990.59 6,028,496.99 546,194.33 0.00 2,939.19 7,000.00 90.00 122.03 4,171.99 4,124.99 -3,153.66 1,075.37 6,028,444.48 546,279.41 0.00 3,035.87 7,100.00 90.00 122.03 4,171.99 4,124.99 -3,206.69 1,160.15 6,028,391.96 546,364.50 0.00 3,132.55 7,200.00 90.00 122.03 4,171.99 4,124.99 -3,259.73 1,244.92 6,028,339.45 546,449.59 0.00 3,229.23 7,300.00 90.00 122.03 4,171.99 4,124.99 -3,312.77 1,329.70 6,028,286.93 546,534.68 0.00 3,325.91 7,400.00 90.00 122.03 4,171.99 4,124.99 -3,365.80 1,414.48 6,028,234.42 546,619.77 0.00 3,422.59 7,500.00 90.00 122.03 4,171.99 4,124.99 -3,418.84 1,499.26 6,028,181.90 546,704.86 0.00 3,519.27 7,600.00 90.00 122.03 4,171.99 4,124.99 -3,471.87 1,584.03 6,028,129.39 546,789.95 0.00 3,615.95 7,700.00 90.00 122.03 4,171.99 4,124.99 -3,524.91 1,668.81 6,028,076.87 546,875.04 0.00 3,712.64 7,800.00 90.00 122.03 4,171.99 4,124.99 -3,577.95 1,753.59 6,028,024.36 546,960.13 0.00 3,809.32 7,900.00 90.00 122.03 4,171.99 4,124.99 -3,630.98 1,838.36 6,027,971.84 547,045.22 0.00 3,906.00 8,000.00 90.00 122.03 4,171.99 4,124.99 -3,684.02 1,923.14 6,027,919.33 547,130.31 0.00 4,002.68 7/6/2015 12:45:38PM Page 4 COMPASS 5000.1 Build 73 • • Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan MPL-49 Company: Hilcorp Energy Company TVD Reference: As-Staked MPL-49 @ 47.00usft Project: Milne Point MD Reference: As-Staked MPL-49 @ 47.00usft Site: M Pt L Pad North Reference: True Well: Plan MPL-49 Survey Calculation Method: Minimum Curvature Wellbore: MPL-49(Well#1) Design: MPL-49 wp4 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) 4,124.99 8,100.00 90.00 122.03 4,171.99 4,124.99 -3,737.06 2,007.92 6,027,866.81 547,215.40 0.00 4,099.36 8,200.00 90.00 122.03 4,171.99 4,124.99 -3,790.09 2,092.70 6,027,814.30 547,300.49 0.00 4,196.04 8,300.00 90.00 122.03 4,171.99 4,124.99 -3,843.13 2,177.47 6,027,761.78 547,385.58 0.00 4,292.72 8,400.00 90.00 122.03 4,171.99 4,124.99 -3,896.16 2,262.25 6,027,709.27 547,470.67 0.00 4,389.40 8,500.00 90.00 122.03 4,171.99 4,124.99 -3,949.20 2,347.03 6,027,656.75 547,555.76 0.00 4,486.08 8,600.00 90.00 122.03 4,171.99 4,124.99 -4,002.24 2,431.80 6,027,604.24 547,640.85 0.00 4,582.76 8,700.00 90.00 122.03 4,171.99 4,124.99 -4,055.27 2,516.58 6,027,551.72 547,725.94 0.00 4,679.44 8,800.00 90.00 122.03 4,171.99 4,124.99 -4,108.31 2,601.36 6,027,499.21 547,811.03 0.00 4,776.12 8,900.00 90.00 122.03 4,171.99 4,124.99 -4,161.35 2,686.13 6,027,446.69 547,896.12 0.00 4,872.80 9,000.00 90.00 122.03 4,171.99 4,124.99 -4,214.38 2,770.91 6,027,394.18 547,981.21 0.00 4,969.48 9,100.00 • 90.00 122.03 4,171.99 . 4,124.99 -4,267.42 2,855.69. 6,027,341.66 548,066.30 0.00 5,066.16 9,200.00 90.00 122.03 4,171.99 4,124.99 -4,320.46 2,940.47 6,027,289.15 548,151.39 0.00 5,162.84 9,300.00 90.00 122.03 4,171.99 4,124.99 -4,373.49 3,025.24 6,027,236.64 548,236.48 0.00 5,259.52 9,400.00 90.00 122.03 4,171.99 4,124.99 -4,426.53 3,110.02 6,027,184.12 548,321.56 0.00 5,356.21 9,500.00 90.00 122.03 4,171.99 4,124.99 -4,479.56 3,194.80 6,027,131.61 548,406.65 0.00 5,452.89 9,600.00 90.00 122.03 4,171.99 4,124.99 -4,532.60 3,279.57 6,027,079.09 548,491.74 0.00 5,549.57 9,700.00 90.00 122.03 4,171.99 4,124.99 -4,585.64 3,364.35 6,027,026.58 548,576.83 0.00 5,646.25 9,800.00 90.00 122.03 4,171.99 4,124.99 -4,638.67 3,449.13 6,026,974.06 548,661.92 0.00 5,742.93 9,900.00 90.00 122.03 4,171.99 4,124.99 -4,691.71 3,533.90 6,026,921.55 548,747.01 0.00 5,839.61 10,000.00 90.00 122.03 4,171.99 4,124.99 -4,744.75 3,618.68 6,026,869.03 548,832.10 0.00 5,936.29 10,100.00 90.00 122.03 4,171.99 4,124.99 -4,797.78 3,703.46 6,026,816.52 548,917.19 0.00 6,032.97 10,200.00 90.00 122.03 4,171.99 4,124.99 -4,850.82 3,788.24 6,026,764.00 549,002.28 0.00 6,129.65 10,300.00 90.00 122.03 4,171.99 4,124.99 -4,903.85 3,873.01 6,026,711.49 549,087.37 0.00 6,226.33 10,400.00 90.00 122.03 4,171.99 4,124.99 -4,956.89 3,957.79 6,026,658.97 549,172.46 0.00 6,323.01 10,500.00 90.00 122.03 4,171.99 4,124.99 -5,009.93 4,042.57 6,026,606.46 549,257.55 0.00 6,419.69 10,600.00 90.00 122.03 4,171.99 4,124.99 -5,062.96 4,127.34 6,026,553.94 549,342.64 0.00 6,516.37 10,700.00 90.00 122.03 4,171.99 4,124.99 -5,116.00 4,212.12 6,026,501.43 549,427.73 0.00 6,613.05 10,800.00 90.00 122.03 4,171.99 4,124.99 -5,169.04 4,296.90 6,026,448.91 549,512.82 0.00 6,709.73 10,900.00 90.00 122.03 4,171.99 4,124.99 -5,222.07 4,381.68 6,026,396.40 549,597.91 0.00 6,806.41 11,000.00 90.00 122.03 4,171.99 4,124.99 -5,275.11 4,466.45 6,026,343.88 549,683.00 0.00 6,903.10 11,100.00 90.00 122.03 4,171.99 4,124.99 -5,328.15 4,551.23 6,026,291.37 549,768.09 0.00 6,999.78 11,200.00 90.00 122.03 4,171.99 4,124.99 -5,381.18 4,636.01 6,026,238.85 549,853.18 0.00 7,096.46 11,300.00 90.00 122.03 4,171.99 4,124.99 -5,434.22 4,720.78 6,026,186.34 549,938.27 0.00 7,193.14 11,372.43 90.00 122.03 4,171.99 4,124.99 -5,472.63 4,782.19 6,026,148.30 549,999.90 0.00 7,263.17 11,400.00 90.00 122.03 4,171.99 4,124.99 -5,487.25 4,805.56 6,026,133.82 550,023.36 0.00 7,289.82 11,500.00 90.00 122.03 4,171.99 4,124.99 -5,540.29 4,890.34 6,026,081.31 550,108.45 0.00 7,386.50 11,600.00 90.00 122.03 4,171.99 4,124.99 -5,593.33 4,975.11 6,026,028.79 550,193.54 0.00 7,483.18 11,700.00 90.00 122.03 4,171.99 4,124.99 -5,646.36 5,059.89 6,025,976.28 550,278.63 0.00 7,579.86 11,800.00 90.00 122.03 4,171.99 4,124.99 -5,699.40 5,144.67 6,025,923.76 550,363.71 0.00 7,676.54 11,900.00 90.00 122.03 4,171.99 4,124.99 -5,752.44 5,229.45 6,025,871.25 550,448.80 0.00 7,773.22 12,000.00 90.00 122.03 4,171.99 4,124.99 -5,805.47 5,314.22 6,025,818.73 550,533.89 0.00 7,869.90 12,100.00 90.00 122.03 4,171.99 4,124.99 -5,858.51 5,399.00 6,025,766.22 550,618.98 0.00 7,966.58 12,200.00 90.00 122.03 4,171.99 4,124.99 -5,911.55 5,483.78 6,025,713.70 550,704.07 0.00 8,063.26 12,300.00 90.00 122.03 4,171.99 4,124.99 -5,964.58 5,568.55 6,025,661.19 550,789.16 0.00 8,159.94 12,374.00 90.00 122.03 4,171.99 4,124.99 -6,003.83 5,631.29 6,025,622.33 550,852.13 0.00 8,231.49 7/6/2015 12:45:38PM Page 5 COMPASS 5000.1 Build 73 • 0 Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan MPL-49 Company: Hilcorp Energy Company TVD Reference: As-Staked MPL-49 @ 47.00usft Project: Milne Point MD Reference: As-Staked MPL-49 @ 47.00usft Site: M Pt L Pad North Reference: True Well: Plan MPL-49 Survey Calculation Method: Minimum Curvature Wellbore: MPL-49(Well#1) Design: MPL-49 wp4 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +NI-S +E/-W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) Well 1 Toe 0.00 0.35 4,171.99 -5,472.63 4,782.19 6,026,148.30 549,999.90 -plan hits target center -Circle(radius 100.00) Well 2 Heel 0.00 0.35 4,147.00 -3,278.18 -425.92 6,028,310.84 544,779.06 -plan misses target center by 902.48usft at 5792.38usft MD(4164.80 TVD,-2513.25 N,52.65 E) -Circle(radius 100.00) MPL-50 wp3 Toe 0.00 0.35 4,027.00 -8,566.17 1,998.56 6,023,038.20 547,235.40 -plan misses target center by 4101.51 usft at 10653.26usft MD(4171.99 TVD,-5091.21 N,4172.49 E) -Circle(radius 100.00) MPL-50 wp3 Heel 0.00 0.35 4,027.00 -5,748.32 -1,987.57 6,025,831.50 543,232.60 -plan misses target center by 3827.10usft at 5771.09usft MD(4162.21 TVD,-2501.99 N,34.76 E) • -Circle(radius 100.00) • Well 2 Toe 0.00 0.35 4,147.00 -6,419.68 4,229.27 6,025,198.00 549,452.80 -plan misses target center by 1096.41usft at 11405.96usft MD(4171.99 TVD,-5490.42 N,4810.62 E) -Circle(radius 100.00) Well 3 Toe 0.00 0.35 4,127.00 -7,177.94 3,418.17 6,024,434.90 548,646.40 -plan misses target center by 2169.60usft at 11120.49usft MD(4171.99 TVD,-5339.01 N,4568.60 E) -Circle(radius 100.00) Well 1 Heel 0.00 0.35 4,171.99 -2,544.42 102.21 6,029,047.73 545,302.66 -plan hits target center -Circle(radius 100.00) Well 4 Toe 0.00 0.35 4,067.00 -8,067.56 2,894.40 6,023,542.20 548,128.10 -plan misses target center by 3202.84usft at 11148.27usft MD(4171.99 TVD,-5353.75 N,4592.15 E) -Circle(radius 100.00) Well 3 Heel 0.00 0.35 4,127.00 -3,968.46 -1,040.74 6,027,616.90 544,168.50 -plan misses target center by 1814.06usft at 5638.18usft MD(4146.01 TVD,-2431.75 N,-76.91 E) -Circle(radius 100.00) Well 4 Heel 0.00 0.35 4,067.00 -4,887.06 -1,535.88 6,026,695.40 543,679.00 -plan misses target center by 2856.49usft at 5700.32usft MD(4153.58 TVD,-2464.59 N,-24.70 E) -Circle(radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (') (") 5,856.42 4,172.60 95/8" 9-5/8 12-1/4 12,374.30 5 1/2" 5-1/2 8-1/2 7/6/2015 12:45:38PM Page 6 COMPASS 5000.1 Build 73 • Hilcorp Energy Company Milne Point M Pt L Pad Plan MPL-49 MPL-49(Well#1) MPL-49 wp4 Sperry Drilling Services Clearance Summary Anticollision Report 06 July,2015 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: M Pt L Pad-Plan MPL-49-MPL-49(Well#1)-MPL-49 wp4 Well Coordinates:6,031,591.23 N,545,185.00 E(70°29'49.82"N,149'37'49.80"W) Datum Height:As-Staked MPL-49 @ 47.00usft Scan Range: 0.00 to 12,374.00 usft.Measured Depth. Scan Radius is 1,434.40 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build: 73 Scan Type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Scan Type: 25.00 HA! 1.l1 IJ�lT["t�! Sperry Drilling Services • • Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan MPL-49-MPL-49 wp4 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design:M Pt L Pad-Plan MPL-49-MPL-49(Well WO-MPL-49 wp4 Scan Range:0.00 to 12,374.00 usft.Measured Depth. Scan Radius is 1,434.40 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft M Pt L Pad MPL-01-MPL-01-MPL-01 1,300.00 424.81 1,300.00 395.84 1,303.66 14.561 Clearance Factor Pass- MPL-01-MPL-01-MPL-01 1,944.75 346.32 1,944.75 328.73 1,876.01 ' 19.683 Ellipse Separation Pass- ' MPL-01-MPL-01-MPL-01 1,944.75 346.32 1,944.75 337.34 1,876.01 38.557 Centre Distance Pass- MPL-01-MPL-01-MPL-01 1,950.00 346.34 1,95000 337.32 1,880.05 38.409 Ellipse Separation Pass- MPL-01-MPL-01-MPL-01 2,225.00 389.94 2,22500 378.26 2,091.03 33.389 Clearance Factor Pass- MPL-01-MPL-01A-Plan#3 1,300.00 424.81 1,300.00 395.64 1,303.66 14.561 Clearance Factor Pass- MPL-01-MPL-01A-Plan#3 1,944.75 346.32 1,944.75 328.73 1,876.01 19.683 Ellipse Separation Pass- MPL-01-MPL-OIA-MPL-01A 1,944.75 346.32 1,944.75 337.34 1,876.01 38.557 Centre Distance Pass- MPL-01-MPL-OIA-MPL-01A 1,950.00 346.34 1,950.00 337.32 1,880.05 38.409 Ellipse Separation Pass- MPL-01-MPL-01A-MPL-01A 2,225.00 389.94 2,225.00 378.26 2,091.03 33.389 Clearance Factor Pass- MPL-01-MPL-01A-MPL-01A 1,300.00 424.81 1,300.00 395.64 1,303.66 14.561 Clearance Factor Pass- MPL-01-MPL-01A-MPL-01A 1,944.75 346.32 1,944.75 328.73 1,876.01 19.683 Ellipse Separation Pass- MPL-01-MPL-01A-Plan#3 1,944.75 346.32 1,944.75 337.34 1,876.01 38.557 Centre Distance Pass- MPL-01-MPL-01A-Plan#3 1,950.00 346.34 1,950.00 337.32 1,880.05 38.409 Ellipse Separation Pass- MPL-01-MPL-01A-Plan#3 2,225.00 389.94 2,225.00 378.26 2,091.03 33.389 Clearance Factor Pass- MPL-02-MPL-02-MPL-02 2,004.04 230.08 2,004.04 212.77 1,920.48 13.294 Ellipse Separation Pass- MPL-02-MPL-02-MPL-02 2,075.00 234.50 2,075.00 216.51 1,975.29 13.032 Clearance Factor Pass- MPL-02-MPL-02-MPL-02 2,004.04 230.08 2,004.04 220.19 1,920.48 23.257 Ellipse Separation Pass- MPL-02-MPL-02-MPL-02 2,125.00 242.69 2,125.00 231.73 2,013.90 22.137 Clearance Factor Pass- MPL-02-MPL-02A-MPL-02A 2,004.04 230.08 2,004.04 213.06 1,920.48 13.514 Ellipse Separation Pass- MPL-02-MPL-02A-MPL-02A 2,075.00 234.50 2,075.00 216.79 1,975.29 13.239 Clearance Factor Pass- MPL-02-MPL-02AL1-MPL-02AL1 2,004.04 230.08 2,004.04 213.08 1,920.48 13.531 Ellipse Separation Pass- MPL-02-MPL-02AL1-MPL-02AL1 2,075.00 234.50 2,075.00 216.81 1,975.29 13.255 Clearance Factor Pass- MPL-02-MPL-02AL2-MPL-02AL2 2,004.04 230.08 2,004.04 212.77 1,920.48 13.294 Ellipse Separation Pass- MPL-02-MPL-02AL2-MPL-02AL2 2,075.00 234.50 2,075.00 216.51 1,975.29 13.032 Clearance Factor Pass- MPL-02-MPL-02APB1-MPL-02APB1 2,004.04 230.08 2,004.04 212.77 1,920.48 13.294 Ellipse Separation Pass- MPL-02-MPL-02APB1-MPL-02APB1 2,075.00 234.50 2,075.00 216.51 1,97529 13032 Clearance Factor Pass- MPL-02-MPL-02APB2-MPL-02APB2 2,004.04 230.08 2,004.04 212.77 1,920.48 13294 Ellipse Separation Pass- 06 July,2015-12:49 Page 2 of 10 COMPASS I • Hilcorp Energy Company HALLI BURTON Milne Point Anticollision Report for Plan MPL-49-MPL-49 wp4 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design:M Pt L Pad-Plan MPL-49-MPL-49(Well#1)-MPL-49 wp4 Scan Range: 0.00 to 12,374.00 usft.Measured Depth. Scan Radius Is 1,434.40 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft MPL-02-MPL-02APB2-MPL-02APB2 2,075.00 234.50 2,075.00 216.51 1,975.29 13.032 Clearance Factor Pass- MPL-04-MPL-04-MPL-04 1,031.54 291.34 1,031.54 282.49 1,020.96 32.928 Centre Distance Pass- MPL-04-MPL-04-MPL-04 1,050.00 291.41 1,050.00 282.46 1,037.91 32.545 Ellipse Separation Pass- MPL-04-MPL-04-MPL-04 1,375.00 317.91 1,375.00 307.01 1,300.46 29.161 Clearance Factor Pass- MPL-04-MPL-04-MPL-04 . 1,031.54. 291.34 1,031.54 279.97 1,020.96 25.639 Centre Distance Pass- MPL-04-MPL-04-MPL-04 1,050.00 291.41 1,050.00 279.88 1,037.91 25.272 Ellipse Separation Pass- MPL-04-MPL-04-MPL-04 1,375.00 317.91 1,375.00 303.51 1,300.46 22.075 Clearance Factor Pass- MPL-05-MPL-05-MPL-05 1,356.14 190.06 1,356.14 175.72 1,353.98 13.250 Ellipse Separation Pass- MPL-05-MPL-05-MPL-05 1,450.00 195.26 1,450.00 180.02 1,430.64 12.814 Clearance Factor Pass- MPL-05-MPL-05-MPL-05 1,356.14 190.06 1,356.14 179.11 1,353.98 17.358 Ellipse Separation Pass- MPL-05-MPL-05-MPL-05 1,450.00 19526 1,450.00 183.62 1,430.64 16.766 Clearance Factor Pass- MPL-06-MPL-06-MPL-06 1,600.50 80.38 1,600.50 67.33 1,620.32 6.158 Clearance Factor Pass- MPL-06-MPL-06-MPL-06 1,600.50 80.38 1,600.50 65.58 1,606.12 5.431 Clearance Factor Pass- MPL-07-MPL-07-MPL-07 30.00 26.75 30.00 25.84 39.00 29.337 Centre Distance Pass- MPL-07-MPL-07-MPL-07 425.00 29.03 425.00 23.53 433.59 5.283 Ellipse Separation Pass- MPL-07-MPL-07-MPL-07 575.00 33.78 575.00 26.30 582.28 4.519 Clearance Factor Pass- MPL-07-MPL-07-MPL-07 30.00 26.75 30.00 25.84 39.00 29.337 Centre Distance Pass- MPL-07-MPL-07-MPL-07 400.00 28.70 400.00 24.46 408.70 6.766 Ellipse Separation Pass- MPL-07-MPL-07-MPL-07 575.00 33.78 575.00 27.80 582.28 5.654 Clearance Factor Pass- MPL-08-MPL-08-MPL-08 30.00 207.46 30.00 206.55 32.00 227.517 Centre Distance Pass- MPL-08-MPL-08-MPL-08 75.00 207.61 75.00 206.40 75.68 171.350 Ellipse Separation Pass- MPL-08-MPL-08-MPL-08 1,075.00 242.28 1,075.00 234.65 1,058.34 31.747 Clearance Factor Pass- MPL-08-MPL-08-MPL-08 30.00 207.46 30.00 206.55 32.00 227.517 Centre Distance Pass- MPL-08-MPL-08-MPL-08 475.00 211.17 475.00 206.21 474.94 42.522 Ellipse Separation Pass- MPL-08-MPL-08-MPL-08 1,000.00 229.43 1,000.00 220.86 993.62 26.785 Clearance Factor Pass- MPL-09-MPL-09-MPL-09 700.00 146.11 700.00 140.15 703.50 24.504 Clearance Factor Pass- MPL-09-MPL-09-MPL-09 805.62 145.76 805.62 140.24 808.93 26.434 Centre Distance Pass- MPL-09-MPL-09-MPL-09 805.62 145.76 805.62 138.20 815.03 19.297 Centre Distance Pass- MPL-09-MPL-09-MPL-09 825.00 145.85 825.00 138.19 834.38 19.039 Ellipse Separation Pass- MPL-09-MPL-09-MPL-09 1,000.00 155.29 1,000.00 146.68 1,008.88 18.027 Clearance Factor Pass- 06 July,2015. 12:49 Page 3 of 10 COMPASS • • Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan MPL-49-MPL-49 wp4 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design:M Pt L Pad-Plan MPL-49-MPL-49(Well#1).MPL-49 wp4 Scan Range:0.00 to 12,374.00 usft.Measured Depth. Scan Radius is 1,434.40 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 Wall Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft MPL-09-MPL-09A-MPL-09A 805.62 145.76 805.62 138.51 815.03 20.101 Centre Distance Pass- MPL-09-MPL-09A-MPL-09A 825.00 145.85 825.00 138.49 834.38 19.821 Ellipse Separation Pass- MPL-09-MPL-09A-MPL-09A 1,000.00 155.29 1,000.00 146.98 1,008.88 18.682 Clearance Factor Pass- MPL-09-MPL-09APB1-MPL-09APB1 805.62 145.76 805.62 138.20 815.03 19.297 Centre Distance Pass- MPL-09-MPL-09APB1-MPL-09APB1 825.00 145.85 825.00 138.19 834.38 19.039 Ellipse Separation Pass- MPL-09-MPL-09APB1-MPL-09APB1 1,000.00 155.29 1,000.00 146.68 1,008.88 18.027 Clearance Factor Pass- MPL-10-MPL-10-MPL-10 119.74 88.34 119.74 86.86 128.74 59.860 Centre Distance Pass- MPL-10-MPL-10-MPL-10 800.00 88.77 800.00 81.25 808.85 11.805 Ellipse Separation Pass- MPL-10-MPL-10-MPL-10 925.00 92.87 925.00 84.66 933.72 11.317 Clearance Factor Pass- MPL-10-MPL-10-MPL-10 119.74 88.34 119.74 86.77 128.74 56.338 Centre Distance Pass- MPL-10-MPL-10-MPL-10 825.00 88.96 825.00 82.01 833.84 12.795 Ellipse Separation Pass- MPL-10-MPL-10-MPL-10 975.00 96.70 975.00 88.49 983.55 11.780 Clearance Factor Pass- MPL-11-MPL-11-MPL-11 1,183.42 49.33 1,183.42 32.21 1,205.39 2.881 Clearance Factor Pass- MPL-11-MPL-11-MPL-11 1,183.42 49.33 1,183.42 32.23 1,205.39 2.884 Clearance Factor Pass- MPL-12-MPL-12-MPL-12 1,969.01 87.19 1,969.01 67.97 1,893.55 4.536 Centre Distance Pass- MPL-12-MPL-12-MPL-12 1,975.00 87.27 1,975.00 67.94 1,897.53 4.514 Clearance Factor Pass- MPL-12-MPL-12-MPL-12 1,969.01 87.19 1,969.01 67.90 1,893.55 4.519 Centre Distance Pass- MPL-12-MPL-12-MPL-12 1,975.00 87.27 1,975.00 67.85 1,897.53 4.494 Clearance Factor Pass- MPL-14-MPL-14-MPL-14 249.55 118.39 249.55 116.51 248.55 62.960 Centre Distance Pass- MPL-14-MPL-14-MPL-14 300.00 118.52 300.00 116,38 298.24 55.232 Ellipse Separation Pass- MPL-14-MPL-14-MPL-14 700.00 140.04 700.00 135,28 687.68 29.370 Clearance Factor Pass- MPL-270P1 Plan-MPL-270P1 Plan-MPL-270P1 Wp 514.23 155.54 514.23 150.35 518.90 29.979 Centre Distance Pass- MPL-270P1 Plan-MPL-270P1 Plan-MPL-270P1 Wp 600.00 155.76 600.00 149.90 604.15 26.585 Ellipse Separation Pass- MPL-270P1 Plan-MPL-270P1 Plan-MPL-270P1 Wp 800.00 159.93 800.00 153.01 801.51 23.109 Clearance Factor Pass- MPL-34-MPL-34-MPL-34 2,143.67 336.73 2,143.67 324.65 1,998.10 27.872 Centre Distance Pass- MPL-34-MPL-34-MPL-34 2,150.00 336.75 2,150.00 324.59 2,003.11 27.701 Ellipse Separation Pass- MPL-34-MPL-34-MPL-34 3,625.00 498.21 3,625.00 461.93 3,466.15 13.733 Clearance Factor Pass- MPL-34-MPL-34-MPL-34 2,143.67 336.73 2,143.67 317.67 1,998.10 17.664 Centre Distance Pass- MPL-34-MPL-34-MPL-34 2,150,00 336.75 2,150.00 317.60 2,003.11 17.587 Ellipse Separation Pass- MPL-34-MPL-34-MPL-34 3,600.00 494.60 3,600.00 453.43 3,443.42 12.013 Clearance Factor Pass- 06 July,2015- 12:49 Page 4 of 10 COMPASS I • Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan MPL-49-MPL-49 wp4 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design:M Pt L Pad-Plan MPL-49-MPL-49(Well#1)-MPL-49 wp4 Scan Range: 0.00 to 12,374.00 usft.Measured Depth. Scan Radius is 1,434.40 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft MPL-35-MPL-35-MPL-35 2521.33 234.37 2,521.33 217.73 2,280.97 14.084 Centre Distance Pass- MPL-35-MPL-35-MPL-35 2,525.00 234.37 2,525.00 217.71 2,284.11 14.063 Ellipse Separation Pass- MPL-35-MPL-35-MPL-35 2,750.00 246.43 2,750.00 228.20 2,487.00 13.518 Clearance Factor Pass- MPL-35-MPL-35-MPL-35 2,521.33 234.37 2,521.33 223.41 2,280.97 21.390 Centre Distance Pass- MPL-35-MPL-35-MPL-35 2,525.00 234.37 2,525.00 223.40 2,284.11 21.358 Ellipse Separation Pass- MPL-35-MPL-35-MPL-35 2,775.00 248.87 2,775.00 236.64 2,510.14 20.348 Clearance Factor Pass- MPL-35-MPL-35A-MPL-35A 2,521.33 234.37 2,521.33 217.73 2,281.77 14.084 Centre Distance Pass- MPL-35-MPL-35A-MPL-35A 2,525.00 234.37 2,525.00 217.71 2,284.91 14.063 Ellipse Separation Pass- MPL-35-MPL-35A-MPL-35A 2,750.00 246.43 2,750.00 228.20 2,487.80 13.518 Clearance Factor Pass- MPL-35-MPL-35A-Plan#7 2,521.33 234.37 2,521.33 223.41 2,281.77 21.392 Centre Distance Pass- MPL-35-MPL-35A-Plan#7 2,525.00 234.37 2,525.00 223.40 2,284.91 21.359 Ellipse Separation Pass- MPL-35-MPL-35A-Plan#7 2,775.00 248.87 2,775.00 236.64 2,510.94 20.349 Clearance Factor Pass- MPL-35-MPL-35A-MPL-35A 2,521.33 234.37 2,521.33 223.41 2,281.77 21.392 Centre Distance Pass- MPL-35-MPL-35A-MPL-35A 2,525.00 234.37 2,525.00 223.40 2,284.91 21.359 Ellipse Separation Pass- MPL-35-MPL-35A-MPL-35A 2,775.00 248.87 2,775.00 236.64 2,510.94 20.349 Clearance Factor Pass- MPL-35-MPL-35APB1-MPL-35APB1 2,521.33 234.37 2,521.33 223.41 2,281.77 21.392 Centre Distance Pass- MPL-35-MPL-35APB1-MPL-35APB1 2,525.00 234.37 2,525.00 223.40 2,284.91 21.359 Ellipse Separation Pass- MPL-35-MPL-35APB1-MPL-35APB1 2,775.00 248.87 2,775.00 236.64 2,510.94 20.349 Clearance Factor Pass- MPL-35-MPL-35APB1-MPL-35APB1 2,521.33 234.37 2,521.33 217.73 2,281.77 14.084 Centre Distance Pass- MPL-35-MPL-35APB1-MPL-35APB1 2,525.00 234.37 2,525.00 217.71 2,284.91 14.063 Ellipse Separation Pass- MPL-35-MPL-35APB1-MPL-35APB1 2,750.00 246.43 2,750.00 228.20 2,487.80 13.518 Clearance Factor Pass- MPL-35-MPL-35APB2-MPL-35APB2 2,521.33 234.37 2,521.33 217.73 2,281.77 14.084 Centre Distance Pass- MPL-35-MPL-35APB2-MPL-35APB2 2,525.00 234.37 2,525.00 217.71 2,284.91 14.063 Ellipse Separation Pass- MPL-35-MPL-35APB2-MPL-35APB2 2,750.00 246.43 2,750.00 22820 2,487.80 13.518 Clearance Factor Pass- MPL-35-MPL-35APB2-MPL-35APB2 2,521.33 234.37 2,521.33 223.41 2,281.77 21.392 Centre Distance Pass- MPL-35-MPL-35APB2-MPL-35APB2 2,525.00 234.37 2,525.00 223.40 2,284.91 21.359 Ellipse Separation Pass- MPL-35-MPL-35APB2-MPL-35APB2 2,775.00 248.87 2,775.00 236.64 2,510.94 20.349 Clearance Factor Pass- MPL-35-MPL-35APB3-MPL-35APB3 2,521.33 234.37 2,521.33 223.41 2,281.77 21.392 Centre Distance Pass- MPL-35-MPL-35APB3-MPL-35APB3 2,525.00 234.37 2,525.00 223.40 2,284.91 21.359 Ellipse Separation Pass- MPL-35-MPL-35APB3-MPL-35APB3 2,775.00 248.87 2,775.00 236.64 2,510.94 20.349 Clearance Factor Pass- 06 July,2015- 12:49 Page 5 of 10 COMPASS I • Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan MPL-49-MPL-49 wp4 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design:M Pt L Pad-Plan MPL-49-MPL-49(Well#1)-MPL-49 wp4 Scan Range: 0.00 to 12,374.00 usft.Measured Depth. Scan Radius is 1,434.40 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft MPL-35-MPL-35APB3-MPL-35APB3 2,521.33 234.37 2,521.33 217.73 2,281.77 14.084 Centre Distance Pass- MPL-35-MPL-35APB3-MPL-35APB3 2,525,00 234.37 2,525.00 217.71 2,284.91 14.063 Ellipse Separation Pass- MPL-35-MPL-35APB3-MPL-35APB3 2,750.00 246.43 2,750.00 228.20 2,487.80 13.518 Clearance Factor Pass- MPL-36-MPL-36-MPL-36 2„286.55 250.71 2,286.55 . 235.37 2,130.45 16.346 Centre Distance Pass- . MPL-36-MPL-36-MPL-36 2,325.00 251.10 2,325.00 235.14 2,164.73 15.730 Ellipse Separation Pass- MPL-36-MPL-36-MPL-36 2,850.00 300.82 2,850.00 276.27 2,645.26 12.254 Clearance Factor Pass- MPL-36-MPL-36PB1-MPL-36PB1 2,292.89 251.09 2,292.89 235.61 2,136.79 16.220 Centre Distance Pass- MPL-36-MPL-36PB1-MPL-36PB1 2,325.00 251.33 2,325.00 235.33 2,165.55 15.702 Ellipse Separation Pass- MPL-36-MPL-36PB1-MPL-36PB1 2,875.00 304.95 2,875.00 279.97 2,667.74 12.208 Clearance Factor Pass- MPL-36-Plan MPL-36A-Plan#7 2,286.55 250.71 2,286.55 235.37 2,130.60 16.346 Centre Distance Pass- MPL-36-Plan MPL-36A-Plan#7 2,325.00 251.10 2,325.00 235.14 2,164.88 15.730 Ellipse Separation Pass- MPL-36-Plan MPL-36A-Plan#7 2,850.00 300.82 2,850.00 276.27 2,645.41 12.254 Clearance Factor Pass- MPL-37-MPL-37-MPL-37 2,363.34 123.69 2,363.34 105.63 2,219,32 6.849 Centre Distance Pass- MPL-37-MPL-37-MPL-37 2,425.00 124.54 2,425.00 104.00 2,279,03 6.064 Ellipse Separation Pass- MPL-37-MPL-37-MPL-37 3,075.00 185.11 3,075.00 144.91 2,922.83 4.604 Clearance Factor Pass- MPL-37-MPL-37-MPL-37 2,363.34 123.69 2,363.34 106.16 2,219.32 7.058 Centre Distance Pass- MPL-37-MPL-37-MPL-37 2,450.00 125.52 2,450.00 104.48 2,302.47 5.965 Ellipse Separation Pass- MPL-37-MPL-37-MPL-37 3,075.00 185.11 3,075.00 145.28 2,922.83 4,648 Clearance Factor Pass- MPL-37-MPL-37A-MPL-37A 2,363.34 123.69 2,363.34 105.63 2,228.52 6.848 Centre Distance Pass- MPL-37-MPL-37A-MPL-37A 2,425.00 124.54 2,425.00 104.00 2,288.23 6.063 Ellipse Separation Pass- MPL-37-MPL-37A-MPL-37A 3,075.00 185.11 3,075.00 144.88 2,932.03 4.601 Clearance Factor Pass- MPL-37-MPL-37A-MPL-37A 2,363.34 123.69 2,363.34 106.17 2,228.52 7.059 Centre Distance Pass- MPL-37-MPL-37A-MPL-37A 2,450.00 125.52 2,450.00 104.48 2,311.67 5.966 Ellipse Separation Pass- MPL-37-MPL-37A-MPL-37A 3,100.00 187.56 3,100.00 147.19 2,955.94 4.646 Clearance Factor Pass- MPL-37-Plan MPL-37B-MPL-37B WP 6.0 2,363.34 123.69 2,363.34 106.27 2,219.32 7.103 Centre Distance Pass- MPL-37-Plan MPL-37B-MPL-37B WP 6.0 2,450.00 125.52 2,450.00 104.59 2,302.47 5.997 Ellipse Separation Pass- MPL-37-Plan MPL-37B-MPL-37B WP 6.0 3,075.00 185.11 3,075.00 145.39 2,922.83 4.660 Clearance Factor Pass- MPL-42-MPL-42-MPL-42 1,452.16 151.76 1,452.16 143.37 1,474.86 18.080 Ellipse Separation Pass- MPL-42-MPL-42-MPL-42 6,900.00 540.73 6,900.00 437.93 6,174.46 5.260 Clearance Factor Pass- MPL-42-MPL-42-MPL-42. 1,452.16 151.76 1,452.16 144.20 1,474.86 20.072 Ellipse Separation Pass- 06 July,2015-12:49 Page 6 of 10 COMPASS I • Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan MPL-49-MPL-49 wp4 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design:M Pt L Pad-Plan MPL-49-MPL-49(Well#1)-MPL-49 wp4 Scan Range: 0.00 to 12,374.00 usft.Measured Depth. Scan Radius is 1,434.40 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft MPL-42-MPL-42-MPL-42 6,900.00 540.73 6,900.00 430.32 6,174.46 4.897 Clearance Factor Pass- MPL-45-MPL-45-MPL-45 3,144.26 70.94 3,144.26 40.18 3,175.43 2.306 Centre Distance Pass- MPL-45-MPL-45-MPL-45 3,200.00 76.37 3,200.00 35.32 3,223.32 1.861 Ellipse Separation Pass- MPL-45-MPL-45-MPL-45 3,225.00 82.12 3,225.00 37.52 3,244.36 1.841 Clearance Factor Pass- • MPL45-MPL-45-MPL-45 3,144.26 70.94 3,144.26 40.17 3,175.43 2.305 Centre Distance Pass- MPL45-MPL-45-MPL-45 3,200.00 76.37 3,200.00 3506 3,223.32 1.849 Ellipse Separation Pass- MPL45-MPL-45-MPL-45 3,225.00 82.12 3,225.00 37.17 3,244.36 1.827 Clearance Factor Pass- MPL-45-Plan MPL-45A-MPL-45a wp01 3,131.87 69.78 3,131.87 39.25 3,165.79 2.286 Centre Distance Pass- MPL-45-Plan MPL-45A-MPL-45a wp01 3,175.00 74.34 3,175.00 35.37 3,200.00 1.908 Ellipse Separation Pass- MPL-45-Plan MPL-45A-MPL-45a wp01 3,200.00 80.96 3,200.00 38.20 3,219.16 1.893 Clearance Factor Pass- MPL-Carvey Plan-MPL-Carvey Plan-MPL-Carvey W 30.00 65.17 3000 64.22 34.30 67.980 Centre Distance Pass- MPL-Carvey Plan-MPL-Carvey Plan-MPL-Carvey W 125.00 65.75 12500 64.01 128.50 37.827 Ellipse Separation Pass- MPL-Carvey Plan-MPL-Carvey Plan-MPL-Carvey W 550.00 91.40 550.00 85.84 543.18 16.440 Clearance Factor Pass- MPL-Vinchi Plan-MPL-Vinchi Plan-MPL-Vinchi WP 2 239.89 59.28 239.89 56.43 244.29 20.782 Centre Distance Pass- MPL-Vinchi Plan-MPL-Vinchi Plan-MPL-Vinchi WP 2 300.00 59.55 300.00 56.24 303.81 17.985 Ellipse Separation Pass- MPL-Vinchi Plan-MPL-Vinchi Plan-MPL-Vinchi WP 2 600.00 71.63 600.00 65.84 599.44 12.375 Clearance Factor Pass- Plan MPL-46-MPL-46(Well#2)-MPL-46 wp4 3,025.00 90.09 3,025.00 58.28 3,104.33 2.832 Clearance Factor Pass- Plan MPL-46-MPL-46(Well#2)-MPL-46 wp4 3,048.67 89.85 3,048.67 58.14 3,127.05 2.834 Ellipse Separation Pass- Plan MPL-47-MPL-47(Well#4)-MPL-47 wp3 708.71 5523 708.71 48.81 709.12 8.605 Centre Distance Pass- Plan MPL-47-MPL-47(Well#4)-MPL-47 wp3 725.00 55.26 725.00 48.76 725.30 8.496 Ellipse Separation Pass- Plan MPL-47-MPL-47(Well#4)-MPL-47 wp3 825.00 57.65 825.00 50.61 823.83 8.184 Clearance Factor Pass- Plan MPL-48-MPL-48(Well#3)-MPL-48 wp4 675.00 128.87 675.00 122.47 675.50 20.123 Centre Distance Pass- Plan MPL-48-MPL-48(Well#3)-MPL-48 wp4 700.00 128.93 700.00 122.37 700.00 19.655 Ellipse Separation Pass- Plan MPL-48-MPL-48(Well#3)-MPL-48 wp4 1,100.00 138.57 1,100.00 130.66 1,078.89 17.519 Clearance Factor Pass- Plan MPL-50-MPL-50(well#5)-MPL-50 wp3 325.00 154.92 325.00 151.59 325.80 46.537 Centre Distance Pass- Plan MPL-50-MPL-50(well#5)-MPL-50 wp3 375.00 155.12 375.00 151.37 374.42 41.333 Ellipse Separation Pass- Plan MPL-50-MPL-50(well#5)-MPL-50 wp3 72500 172.79 72500 166.40 705.91 27.054 Clearance Factor Pass- 06 July,2015- 12:49 Page 7 of 10 COMPASS • • Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan MPL-49-MPL-49 wp4 Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 30.00 700.00 MPL-49 wp4 SRG-SS 700.00 5,856.42 MPL-49 wp4 MWD+IFR2+MS+sag 5,856.42 12,374.00 MPL-49 wp4 MWD+IFR2+MS+sag Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor=Distance Between Profiles/(Distance Between Profiles-Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 06 July,2015-12..49 Page 8 of 10 COMPASS • III Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan MPL-49-MPL-49 wp4 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to As-Staked MPL-49 @ 47.00usft. Northing and Easting are relative to Plan MPL-49. Coordinate System is US State Plane 1927(Exact solution),Alaska Zone 04. Central Meridian is-150,00°,Grid Convergence at Surface is:0.35°. -o-MPL-TL,MYL-TL,MF'L-12VI LaddeLadder. Plot S. MPL-34,MPL-34,MPL-34V10 r $ MPL-35,MPL-35,MPL-35 V6 t- i I -4- MPL35,MPL-35A,MPL35AV12 i i i MPL-35,MPL-35APB1,MPL35APB1V5 . ee i �- MPL35,MPL35APB2,MPL35AP82V3 ii 13 I !.1',,fr ii, Nil, '4; r: ,,.i i / /, �' -4- NPL35,NPL35APB3,MPL35APB3V5 f /.•__________ � NPL-37,MPL37,MPL37V3 1;ifR n I I r 1 $MPL37,MPL37A,MPL-37AV1 Lo ' it , ai p -f NPL42,MPL42,MPL-42V4 C il' ' 4. ■■■G A _ p MPL45,MPL45,MPL45V7 ' C F 1' Plan MPL46,MPL46(Well#2),MPL46 wp4 VO i, hr•r... .m 9� iI';� �" �'"�•�=,�.•_ Plan ell#4,MPL47 3V0 0. im in . �.c (� ) wp '4,1r ,ir t 7 '''7i j',; tic o,or Plan MPL48,MPL48(Well#3),MPL48 wp4 VO u) Iii . �A7 Iii;' _ Plan MPL-50,MPL-50(well#5),NPL-50wp3V0 22 ,qt (r� ',!� MPL-01,MPL-01,MPL-01 V1 ��j��yrrIIa / !�f !G MPL-01,MPL-01A,NPL-01AV4 U , .�..5,r ,/,/I II ,._ MPL-01,MPL-01A, o 4 ! ` /4 MPL-02,MPL-02,MPL-02 V1 �/ �y,•' MPL-04,MPL-04,MPL-04 V1 L MPL-05,MPL-05,MPL-05 V1 CD U _ ;r fl ',)k MPL-06,MPL-06,MPL-06 V1 MPL-07,MPL-07,MPL-07 V1 0 MPL-08,MPL-08,MPL-08 V1 0 2500 5000 7500 10000 12500 MPL-09,MPL-09,MPL-09 V1 Measured Depth usfUin) MPL-10,MPL-10,MPL-10 V1 '-'�F' (2500MPL-11,MPL-11,MPL-11 V1 06 July,2015- 12:49 Page 9 of 10 COMPASS • • Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan MPL-49-MPL-49 wp4 Clearance Factor Plot: Measured Depth versus Separation(Clearance)Factor Y :',��, ".�� IEE 6MPL34,MPL-34,MPL34V10 10.00 • Y -- '. -- -- - - MPL35,MPL35,MPL-35V6 /, I II// 3-MPL35,MPL35A,NPL35AV12 i 6 , i\ $MPL35,MPL35APB1,MPL35APB1V5 8.75- 1 43 - ' A -- $MPL35,MPL-35, A' .� -X-MPL-35,MPL35APB3,MPL35APB3V5 ' II ' -0-MPL-37,MPL37,MPL-37 V3 7.50 4.1U . c = \ .,; i $MPL-37,MPL37A,MPL-37AV1 I -\ -N- MPL42,MPL42,MPL42V4 6.25 i�'r - . MPL-45,MPL-45,MPL-45WO Plan (Well wp4(Well wp4 500— A. - -B-Plan MPL-50,MPL-50(well#5),MPL50wp3VO 1 m ' �C a Al, 4 $MPL-01,MPL-01,MPL-01 V1 U)) 3.75 ' $MPL-AP -01A,MPL-01AV4 l•1p $MPL-01,MPL-01A,Plan#3 V4 .11- i- I -0-MPL-02,MPL-02,MPL-02 V1 2.50----__- - $ MPL-04,MPL-04,MPL-04V1 _ NoCollisionAvoidance Req $MPL-05,MPL-05,MPL-05 V1 125 f . -e-MPL-06,MPL-06,MPL-06V1 $MPL-07,MPL-07,MPL-07V1 -9-MPL-08,MPL-08,MPL-08 V1 0.00 i i i i l i 1 1 1 1 1 1 1 11 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I I I i I '6'MPL-09,MPL-09,MPL-09 V1 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 '4)"MPL-10,MPL-10,MPL-10 V1 MeasuedDepth(2(00usft(n) $MPL-11,MPL-11,MPL-11 V1 06 July,2015- 12:49 Page 10 of 10 COMPASS • • TRANSMITTAL LETTER CHECKLIST WELL NAME: "P() 4-145 PTD: _Development /Service _Exploratory _Stratigraphic Test _Non-Conventional FIELD: /)91/111:-. POOL: /)1 /r t Aid') J, a/ 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. hi 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(dX2XB) 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 • • IIC 0 N 'p iT p a) _ Q E a) O a) O0 5 N N C , , N cL Co 4 m D7 w N U) J O, m. a) v a ) r-- o a �. `t, . y. L, N• N. •y. , ao. 22 2 O. p. 0) O. , W, V1. O)• C• a a) 0) 'C U) a . U. .... N U O a. t, 'O E •E, a0. N. . )V. , N ' 0 a) (4. U. y. •O. �' o N' N' -� �. c. Z, N LO. c. E. m. 0 a W. a) O' ui; co; � o m co ❑' o, N. as, O -O' 10• • N. U. Oi t, O• E C' W. U J Q, J, •V. �� C, `� w, •G >, p. '�, a F•, M. m. t 0) m U m N. O' 7) D7 . w . . , E, y. co, N; 0` ") �� (D p' �; � a O H �' J' 0) N. . 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Ea. a 4 4 a) m, as. o. a, ; � mv. v, 0OO ; a); m, a), a, p, o U cz a J, D., (n, wo, o, a, a, U ; ¢; a; U, v), U. U. U. U. Q. "—: Q. "—'. 0', m, , " 2 a ❑. cn. co, U, W O N M V (0 (0 a, O) O N M C' to co N- co 0) O N CO d' t0 CO N- CO O) r E N CO V (O h a0 O e- N N N N N N N N N N M M M M M M M M M M U am_ to to ,- N G Y O w ON y cN V O ce co 0 ❑ M 0) ❑ M ro ❑ co O co LLJ O as r a1i E ti'\ J N N a) O U O -,, W 1.- a E Y p) a -I o c. YU ,ia Q a w Q 0 0 Q Cl_ HL CElVED STATE OF ALASKA • JUN 0 9 2015 AL&OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL � �i� 20 AAC 25.005 la.Type of Work: 1 b.Proposed Well Class: Development-Oil ❑ Service- Winj ❑., • Single Zone 0 . lc.Specify if well is proposed for: Drill • ❑., Lateral ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas LI Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ _Geothermal ElShale Gas CI 2.Operator Name: 5. Bond: Blanket ❑. Single Well ❑ 11.Well Name and Number: Hilcorp Alaska,LLC . Bond No. 022035244• MPU L-49 3.Address: 6. Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive,Suite 1400,Anchorage AK 99503 MD: 12,374' , TVD: 4,172' . Milne P nt Unit - 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): a41 Schrade tuff Oil Pool .. Surface: 3399'FSL,4690'FEL,Sec 8,T13N,R'OE,UM,AK • ADL 025509(TPH) 315 ,..03 ADL 025515(BHL) Top of Productive Horizon: 8. Land Use Permit: 13.Approgimate Spud Date: 632'FSL, 1034'FWL,Sec 8,T13N, R10E, UM,AK N/A 7/15/2015 Total Depth: 9.Acres in Property: (0 3S? I'f's 14. Distance to Nearest Property: 2605'FNL,914'FWL,Sec 16,T13N, R10E, UM,AK 2_.. .• •.- 1 1• .. •• •. • -- 11,730'to Unit Boundry 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: k. 47 feet 15. Distance to Nearest Well Open Surface: x-545189.6 y- 6031591.2 Zone-4 GL Elevation above MSL: • 17 feet to Same Pool: 2,975' 16.Deviated wells: Kickoff depth: - 900 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: - 92 degrees Downhole: 1866 psi . Surface: 1449 psi - 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Stg 1 -Lead-1016 ft3/Tail-468.3 ft3 12-1/4" 9-5/8" 47# L-80 TC-II 5,856' 0 0 5,856' 4,172' Stg 2-Lead-1756 ft3/Tail-314 ft3 8-1/2" 5-1/2" 17# L-80 DWC/C HT 6,718' 5,656' 4,17 /12,374' 4,172' Cmntless Prod.(Slotted w/Swell Pkrs) r U ,)c A to / 's)), _ ,w,w3n - 1 19. PRESENT WELL CONDITION SUMMARY(To be completed .,'',drill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): • E ct. Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): • Casing Length Size / Ce ent Volume MD TVD Conductor/Structural Surface \yj. Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat ❑ OP Sk--: i ❑ Drilling Program ❑ Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Dt 0 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 cor ct. / Contact Luke Keller Email Ikellerhilcorp.com Printed Name . Luke Keller Title Drilling Engineer Signature --.L. / Phone 777-8395 Date 6/9/2015 Commission Use Only Permit to Drill '/ API Number: _ Permit Approval See cover letter for other Number: 02/5- Q 5 50-) -,�?-35`-J a3 --Go Date: requirements. Conditions of approval:/, If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales:[ Other: k 3„�11) '5. se.,f I e I,'7 Samples req'd: Yes❑ No[, Mud log req'd:YeJ NU/ n•, ""L411 ) HZS measures: Yes®' No[ Directional svy req'd:Ye" Nk /�/J j f� Spacing exception req'd: Yes❑ No[X Inclination-only svy req'd:Ye/j Nav - !',. 1 l —1A • t Cal. te-1) �+-i •,�Y --- UL.r ill--4. .- Dr,e--,,,,,....4-;C r. , f-. Ll/ At /CD6 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 74-- (5 i k Ca/24115' Submit Form and Form 10- (Revised 10/2012) OsRlitOviliR 2 nths from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate Luke Keller • Hilcorp Alaska, LLC Drilling Engineer P.O. Box 244027 Anchorage, AK 99524-4027 Tel 907 777 8395 Email Ikeller@hilcorp.com IliIcorp:1fo.Aa.l,LC June 9th, 2015 Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Re: MPL-49 Dear Commissioner, Enclosed for review and approval is the Permit to Drill for MPL-49 water injection well. MPU L-49 is a grassroots water injector planned to be drilled in the Schrader Bluff OA sand. L-49 is part of a(5)well pilot program targeting the OA sand. Each producing lateral will have water injection support on either side. The directional plan is a catenary wellpath build with 9-5/8"surface casing set into the top of the Schrader Bluff OA sand. A lateral section will then be drilled in the OA sand. An injection liner will then be run with ICDs placed along the wellbore to optimize water injection strategy. '^f s. Gt dot-lam« S Drilling operations are expected to commence approximately July 15th, 2015. Nordic Calista Rig#3 will be used to drill and complete the wellbore. If you have any questions, please don't hesitate to contact myself at 777-8395 or Paul Mazzolini at 777-8369. Sincerely, Luke Keller Drilling Engineer Hilcorp Alaska, LLC Page 1 of 1 • • Hilcorp Alaska, LLC Milne Point Unit (MPU) L-49 Drilling Program Version 1 June 6th, 2015 • S Milne Point Drilling Procedure Hilcorp Energy Company Contents 1.0 Well Summary 2 2.0 Management of Change Information 3 3.0 Tubular Program: 4 4.0 Drill Pipe Information: 4 5.0 Internal Reporting Requirements 5 6.0 Planned Wellbore Schematic 6 7.0 Drilling/Completion Summary 7 8.0 Mandatory Regulatory Compliance/Notifications 8 9.0 R/U and Preparatory Work 10 10.0 N/U 21-1/4"2M Diverter System 10 11.0 Drill 12-1/4"Hole Section 13 12.0 Run 9-5/8"Surface Casing 17 13.0 Cement 9-5/8"Surface Casing 23 14.0 BOP N/U and Test 28 15.0 Drill 8-1/2"Hole Section 29 16.0 Run 5-1/2"Production Liner 33 17.0 Run ESP assy. 36 18.0 RDMO 36 19.0 Diverter Schematic 37 20.0 BOP Schematic 38 21.0 Wellhead Schematic 39 22.0 Days Vs Depth 40 23.0 Formation Tops 41 v44.0 Anticipated Drilling Hazards 42 25.0 Nordic#3 Rig Layout(Drillers Side) 44 26.0 Nordic#3 Rig Layout(Well End&Top View) 45 27.0 FIT Procedure 46 28.0 Choke Manifold Schematic 47 29.0 Casing Design Information 48 30.0 8-1/2"Hole Section MASP 49 31.0 Spider Plot(NAD 27)(Governmental Sections) 50 32.0 Surface Plat(As Built)(NAD 27) 51 33.0 Offset MW vs TVD Chart 52 34.0 Drill Pipe Information 5" 19.5#S-135 DS-50 53 ! • Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 1.0 Well Summary Well MPU L-49 Pad Milne Point"L"Pad Planned Completion Type 2-7/8"Injection string Target Reservoir(s) Schrader Bluff OA Sand ' Planned Well TD, MD/TVD 12,374' MD/4,172' TVD PBTD, MD/TVD 12,364' MD/4,172' TVD Surface Location(Governmental) 3,399' FSL,4,690' FEL, Sec 8, T13N, R10E, UM,AK Surface Location(NAD 27—Zone 4) Y=6,031,591.24,X=545,189.65 Surface Location(NAD 83) Top of Productive Horizon (Governmental) 632'FSL, 1034'FWL, Sec 8, T13N, R10E, UM, AK TPH Location(NAD 27) Y=6028826.55,X=545660.33 TPH Location(NAD 83) BHL(Governmental) 2605' FNL, 914' FWL, Sec 16, T13N, R10E,UM,AK BHL(NAD 27) Y=6025623.15, X= 550850.8 BHL(NAD 83) AFE Number 1511127 AFE Drilling Days 15 days AFE Completion Days 4 days AFE Drilling Amount $4,137,342.00 AFE Completion Amount $1,093,100 AFE Facility Amount $431,000.00 Maximum Anticipated Pressure (Surface) 1449 psig Maximum Anticipated Pressure (Downhole/Reservoir) 1866 psig Work String 5" 19.5# S-135 DS-50 (Weatherford Rental) KB Elevation above MSL: 30 ft+ 17 ft=47 ft GL Elevation above MSL: 17 ft BOP Equipment 11"x 5M Annular,(3)ea 11"x 5M Rams ' Page 2 Version 1 May, 2015 • S Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 2.0 Management of Change Information Hilcorp Alaska, LLC Hilcorp roma Conway Changes to Approved Permit to Drill Date: 6-2-2015 Subject: Changes to Approved Permit to Drill for MPU L49 File#: MPU L-49 Drilling and Completion Program Any modifications to MPU L49 Drilling&Completion Program will be documented and approved below. Changes to an approved APD must be approved by the AOGCC. Sec Page Date Procedure Change Approved Approved By By Approval Drilling Manager Date Prepared: Drilling Engineer Date Page 3 Version 1 May, 2015 • • Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 3.0 Tubular Program: Hole OD(in) ID (in) Drift Conn Wt Grade Conn Burst Collapse Tension Section (in) OD (in) (#/ft) (psi) (psi) (k-lbs) Cond 20" 19.25" - - 78.6 A-53 Weld 12-1/4" 9-5/8" 8.681" 8.525" 10.235" 47 L-80 TC-II 6,870 4,760 1086 8-1/2" 5-1/2" 4.892" 4.767" 6.05" 17 L-80 DWC/C 7,740 7,100 397 HT 4.0 Drill Pipe Information: Hole OD(in) ID (in) TJ ID TJ OD Wt Grade Conn M/U M/U Tension Section (in) (in) (#/ft) (Min) (Max) (k-lbs) All 5" 4.276" 3.25" 6.625" 19.5 S-135 GPDS50 36,100 43,100 560k All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Version 1 May, 2015 I • Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 5.0 Internal Reporting Requirements 17.1 Fill out daily drilling report and cost report on Wellez. • Report covers operations from 6am to 6am • Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area—this will not save the data entered, and will navigate to another data entry tab. • Ensure time entry adds up to 24 hours total. • Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. • Enter the MD and TVD depths EVERY DAY whether you are making hole or not. 17.2 Afternoon Updates • Submit a short operations update each work day to pmazzolini@hilcorp.com , Ikeller@hilcorp.com and cdinger@hilcorp.com 17.3 Intranet Home Page Morning Update • Submit a short operations update each morning by 7am on the company intranet homepage. On weekend and holidays, ensure to have this update in before 5am. 17.4 EHS Incident Reporting • Health and safety:Notify EHS field coordinator. • Environmental: Drilling Environmental coordinator • Notify Drlg Manager&Drlg Engineer • Submit Hilcorp Incident report to contacts above within 24 hrs 17.5 Casing Tally • Send final"As-Run"Casing tally to Ikeller@hilcorp.com and cdinger@hilcorp.com 17.6 Casing and Cmt report • Send casing and cement report for each string of casing to Ikeller@hilcorp.com and cdinger@hilcorp.com 17.7 Hilcorp Milne Point Contact List: Title Name Work Phone Cell Phone Email Drilling Manager Paul Mazzolini 907.777.8369 907.317.1275 pmazzolini@hilcorp.com Drilling Engineer Luke Keller 907.777.8395 832.247.3785 Ikeller@hilcorp.com Geologist Kevin Eastham 907.777.8316 907.360.5087 keastham@hilcorp.com Reservoir Engineer Keith Elliot 907.777.8355 832.233.5855 kelliott@hilcorp.com Drlg Environmental Coord Julieanna Orczewska 907.777.8444 907.715.7060 jorczewska@hilcorp.com EHS Manager Carl Jones 907.777.8327 907.382.4336 cajones@hilcorp.com EHS Field Coordinator Jimmy Watson 907.777.8450 907.744.7376 jiwatson@hilcorp.com Drilling Tech Cody Dinger 907.777.8389 509.768.8196 cdinger@hilcorp.com Page 5 Version 1 May, 2015 V • • 11 Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 6.0 Planned Wellbore Schematic AFE No. Well Name: KB: 30 ft AGL 1511127 Milne Point Unit(MPU)L-49 GL+RKB 17 ft*30 ft=47 ft API# AFE WELLBORE DESIGN Proposed TD: 12,374' Permit No. Proposed TVO: 4,172" Geologic Information Wellbore Information Casing Info!Mud Info 1 Hole Size 1 Cement Specs Mud Program SS ND FM Lithology Conductor RKB-Tubing Hanger 34"lc 20"Insulated conductor(Pre-set)to 80'BGL(110'RKB) interval: tsuInner sleeve:20"x 0.375"Wall 78.6#.A-53.ERW.PE Surface hole Exterior Jacket:34"x 0.344"Wall,1234,A-139.Grade 8 spiral.PE Mud Type: Fresh Water/Native 2 Surface Casing Watalt.Range H £ o` 9-518"474L-80 TC-Il set at 5856'MD!4172'TVD B.8-9.2 O 2 -5- E E f0L Surface Casing Cement 8 let Stage: a a ti 60 bbis 10.5 ppg Tuned spacer III v m Lead:(50%OH Excess)ARCTICCEM q+10.7 ppg c 18 Tail:(50%OH Excess)SWIFTCEM 15.8 ppg o c v D m 2nd stage: 1750' • 60 bbls 10.5 ppg Tuned spacer III A Lead:(Until returns at surface)ARCTICCEM 10.7 ppg m Te a Irt.. Stage Tail:SWIFTCEM 15.8 ppg o Collar it 131 a m Y 2$-- Production Liner v 0 5-112"174 L-80 DWC1C HT liner ig 12,374'MD 14,172'TVD a m 2 -Y m c Injection Tubing r ro E " u 2-718"6.44 L-80 BRD EUE ro N ea ro 4-'0 M V7 G ; i 'n g n a » 2 21 2 d S o c A c' gx c = 4 \\\\'' '35DD' 3 ' rrn ,_ K-sands Coarse sand,silty Liner Top Pkr.5656 ft Injection Control Devices shale,better r(I Interval: UGvNU developed ) Production Hole 1-Sands intervening shales ' 1' Mu T -4000' M-sands in the L and M ■ . , ■ ■ ■ Bared:VS N-sands Continued layering as ---- 0 o o m P 0 Weight Range' Schrader in Ugnu,more \` 0 0 o ° c' 0O c7 n p 0 8.9-92 ppg 0-sands condensed with occ. 0 0 0 0 0 0 4300' coal k.k. r VP Injection Packer 7>,' tl Swell Pkrs 5-1/2"Injection Liner Page 6 Version 1 May, 2015 i • 1 Fl Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 7.0 Drilling / Completion Summary MPU L-49 is a grassroots water injector planned to be drilled in the Schrader Bluff OA sand. L-49 is part of a(5)well pilot program targeting the OA sand. Each producing lateral will have water injection support on either side. The directional plan is a catenary wellpath build with 9-5/8" surface casing set into the top of the Schrader Bluff OA sand. A lateral section will then be drilled in the OA sand. An injection liner will then be run with ICDs placed along the wellbore to optimize water injection strategy. Drilling operations are expected to commence approximately July 15th, 2015. Nordic Calista Rig#3 will be used to drill and complete the wellbore. Surface casing will be run to 5,856' MD/4,172' TVD and cemented to surface via a 2 stage primary cement job. Cement returns to surface will confirm TOC at surface. If cmt returns to surface are not observed, a Temp log will be run between 6— 18 hrs after CIP to determine TOC. Necessary remedial action will then be discussed with AOGCC authorities. All waste & mud generated during drilling operations above the UGNU formation (3500' TVD) will be hauled to the Milne Point"A"pad temporary disposal site for storage until the Milne Point G&I facility is up' and running. Waste and mud generated after penetrating the UGNU formation will be hauled to the BP G&I facility at Prudhoe Bay. , General sequence of operations: 1. MOB Nordic Rig #3 to well site 2. N/U 21-1/4" conductor and 16" diverter line. 3. Drill 12-1/4"hole to TD of surface hole section. Run and cmt 9-5/8" surface casing. 4. N/D diverter,N/U & test 11"x 5M BOP. / 5. Drill 8-1/2" lateral to well TD. Run 5-1/2" liner. 6. Run Injection string. 7. N/D BOP,N/U temp abandonment cap, RDMO. Reservoir Evaluation Plan: 1. Surface hole: No mud logging. On Site geologist. LWD: GR+Res 2. Production Hole: No mud logging. On site geologist. LWD: GR+ADR(For geo-steering) Page 7 Version 1 May, 2015 • Milne Point Unit L-49 11 Drilling Procedure Hilcorp Energy Company 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the below AOGCC regulations. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. • BOPs shall be tested at(2)week intervals during the drilling and completion of MPU L-49. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. • The initial test of BOP equipment will be to 250/3000 psi & subsequent tests of the BOP equipment will be to 250/3000 psi for 5/5 min(annular to 50% rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. • If the BOP is used to shut in on the well in a well control situation, we must test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system". • All AOGCC regulations within 20 AAC 25.035 "Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements". • Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office. AOGCC Regulation Variance Requests: • There are no variance requests at this time. / Page 8 Version 1 May, 2015 Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure(psi) 12-1/4" • 21-1/4"2M diverter w/16"diverter line Function Test Only • 11"x 5M Hydril Annular BOP • 11"x 5M Shaffer Double Ram Initial Test:250/3000 o Blind ram in btm cavity (Annular 2500 psi) • Mud cross w/3"x 5M side outlets 8-1/2" • 11"x 5M Hydril Single Ram • 3"x 5M Choke Line Subsequent Tests: • 3"x 5M Kill line 250/3000 • 3"x 5M Choke manifold(10M Hydraulic remote Choke (Annular 2500 psi) • Standpipe,floor valves,etc • Primary closing unit: Hydril, 165 gal, 6 station accumulator w/dual electric and air pumps, w/ 1 (ea) electric over hydraulic remote control panel at the driller station. • Primary closing hydraulic pressure is provided by an electrically driven triplex pump. Emergency pressure is provided by bottled nitrogen. Tertiary pressure is provided by air pumps. Required AOGCC Notifications: • Well control event (BOPS utilized to shut in the well to control influx of formation fluids). • 24 hours notice prior to spud. • 24 hours notice prior to testing BOPs. • 24 hours notice prior to casing running & cement operations. • Any other notifications required in APD. Regulatory Contact Information: AOGCC Jim Regg/AOGCC Inspector/(0): 907-793-1236/Email:jim.regg@alaska.gov Guy Schwartz/Petroleum Engineer/(0): 907-793-1226/(C): 907-301-4533 /Email:guy.schwartz@alaska.gov Victoria Loepp/Petroleum Engineer/(0): 907-793-1247/Email: Victoria.loepp@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html Notification/Emergency Phone: 907-793-1236 (During normal Business Hours) Notification/Emergency Phone: 907-659-2714 (Outside normal Business Hours) Page 9 Version 1 May,2015 Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 9.0 R/U and Preparatory Work 9.1 Set insulated 34" x 20" conductor at 80' below ground level (110' RKB) 9.2 Dig out and set impermeable cellar. 9.3 Ensure PTD and drilling program are posted in the rig office and on the rig floor. 9.4 Install Seaboard slip-on 16-3/4" 3M "A" section. Ensure to orient wellhead so that tree will line up with flowline later. 9.5 Insure (2) 3"threaded nipples are installed on opposite sides of the conductor with ball valves on each nipple. These will be used to take cement returns to the cellar during the surface cmt job, and also to wash out the diverter and hanger in preparation for running the pack-off. 9.6 Level pad and ensure enough room for layout of rig footprint and R/U. 9.7 Confirm that the rig is over the appropriate well slot. 9.8 MIRU Nordic #3. 9.9 Mud loggers WILL NOT be used on either hole section. 9.10 Mix spud mud for 12-1/4" surface hole section. Keep mud cool. 9.11 Set test plug in wellhead prior to N/U diverter to ensure nothing can fall into the wellbore if it is accidentally dropped. 9.12 Install 5-1/2" liners in mud pumps. • Continental EMSCO F-1000 mud pumps are rated at 3500 psi (100%)/354 gpm (120 spm @ 95%eff) with 5-1/2" liners. 10.0 N/U 21-1/4" 2M Diverter System 10.1 N/U 21-1/4" Hydril MSP 2M diverter System (Diverter Schematic at Sec 19 at back of program). • N/U 16-3/4" 3M x 21-1/4" 2M DSA on 16-3/4" 3M wellhead. • N/U 21-1/4" diverter"T". • Knife gate, 16" diverter line/ • Ensure diverter R/U complies with AOGCC reg 20.AAC.25.035(C). • Diverter line must be 75 ft from nearest ignition source • Place drip berm at the end of diverter line. Page 10 Version 1 May,2015 • 0 II Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Compaiy 10.2 Function test diverter. Ensure that the knife gate and annular are operated on the same circuit so that knife gate opens prior to annular closure. 10.3 Ensure to set up a clearly marked "warning zone" is established on each side and ahead of the vent line tip. "Warning Zone" must include: • A prohibition on vehicle parking • A prohibition on ignition sources or running equipment • A prohibition on staged equipment or materials • Restriction of traffic to essential foot or vehicle traffic only. 10.4 Set 15.375" ID wearbushing in wellhead. 10.5 Pad Drawing I I in 1111 fl _i LL I r_ I 11 al II is i ii I1 16 t CY.r^er Lx ■ i , I — l 19 I 111 ii ii Page 11 Version 1 May, 2015 • 0 Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 10.6 Rig& Diverter Orientation on"L"pad: ` — yl ------ i __-- —— (iI) I — , U --, 1 ill 11111 r-15 h rIverter L lmtr. I I i i ! —_ L-47 i 1 ti I 1 —ao H.,-48 F-L-4AlF4:::::" I i L ti . — r1 ....- —I-1...... i U u u MUD L 0 I II I I PI 1 Page 12 Version 1 May, 2015 • • Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 11.0 Drill 12-1/4" Hole Section 11.1 P/U 12-1/4" directional drilling assy: • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Ensure Gyro MWD is R/U and operational. Be sure to run a UBHO sub so that wireline orientation is possible if necessary. • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. • Workstring will be 5" 19.5# S-135 • Run a solid float in the surface hole section. 11.2 12-1/4" BHA(GR+Res LWD and PWD planned in surface hole): COMPONENT DATA illiffieffilh sil Description Serial ember OD ttem # tin) on)`, i On „ ME PDC 8.000 3.000 12 250 147.22 P 6-518"REG 1.10 ' '0 © 8"SperryOrii Lobe 415-5.3 stg 8.000 5.000 103.09 B 6-518"REG 31.47 32.57 IIII Stabilizer 12.125 © Float Sub 8.000 2.880 149.10 B 6-5i8"REG 2.40 34.97 ® Stabilizer 8.000 3.000 10.250 147.22 B 6-518"REG 6.00 40.97 © 8'DM Collar 11111111111 8.000 3.500 147 40 B 6-518"REG 9 20 50.17 Q 8"DGR Collar 8.000 1.920 142.70 B 6-518"REG 4.55 54.72 Ell 8"EWR-P4 Collar 8.000 1.985 151.00 B 6-5/8"REG 12.19 66.91 0 8"HCIM Collar 8.000 1.920 149.90 B 6-5/8"REG 4.97 71.88 9 8"POS PULSER 8.000 4.000 _ 145.20 B 6-518"REG MilEl= 87.32 10 Orienting Sub UBHO 8.000 2.875 149.18 B 6-518"REG 2.50 89.82 ® NM Flex Collar 8.000 2.813 150.13 8 6-518"REG 31.00 120.82 NM Flex Collar 8000 2.813 150.13 8 6-5/8"REG 31.00 151.82 ® NM Flex Collar 8.000 2.813 150.12 B 6-518"REG 31.00 182.82 8jts x 5"X 3'HWDP#49.3-NC50(IF)- 5.000 3.000 49.30 240.00 422.82 ® Jar 7.500 2.813 111.1. 129.38 B 4-112"IF 35.00 457.82 ® 12jts x 5"X 3"H FDP#49.3-NC50 5.000 3.000 49.30 360.00 817.82 :. # 817 82 Page 13 Version 1 May, 2015 • • II Milne Point Unit L-49 Drilling Procedure Hikor Ensily 11.3 Primary Bit: 12-1/4" (311mm) QHCIGRC PRODUCT SPECIFICATIONS # ` IADC Code l I7W Total Tooth Count 67 w . Gage Row Tooth Count 39 ' Journal Angle 33° 1 Offset(11161 6 ,, ,/,.... 010, .4.. Jet Nozzle Types V Standard 83244 Extended 302447 Center Jet (If Center Jetted)501813 le T.J.Connection 6-5/8"(API Reg.) `' Recommended Make-Up Torque' 28000132000 Ft•lbs. Bit Weight(Boxed) 250 Lbs.(1 13 Kg.) Bit Breaker (Mat.#/LegacyH) 5153531506463 PRODUCT FEATURES "�°"" ► • New patented Diamond"ClawR tooth bit design. " �z s,t. • Tungsten carbide'surf inserts in gage teeth for added gage +t protection. • Newly formulated,proprietary hardfacing on cutting structure and ,� i> gage maximizes carbide and diamond volume for ultimate wear - i resistance. wt • Raised tungsten carbide inserts and proprietary hardfacing * 4111k provides maximum arm protection in abrasive and directional applications while minimizing drill string torque. ` • QuadPaek41 Plus Series incorporates its successful"longevity" features and patented engineered hydraulics system for optimal cleaning efficiency. • Center jet feature to prevent hit balling problems • Dual seal;dual compensation bearing system containing dual seals, dual independent pressure compensators,and a dual grease formulation. • The latest OCP seal technology designed with the highest contact pressures on the outside edges of the seal where it is needed most. Material#740990 helps keep contaminants out extending bearing life. *Calculations based on recommendations from AM and took-joint manufacturers. 2014 Halliburton.All rights reserved.Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. www,hatli Burton.corn 11.4 5" Workstring, HWDP, and Jars will come from Weatherford. 11.5 Begin drilling out from 20" conductor at reduced flow rates to avoid broaching the conductor. 11.6 Drill 12-1/4"hole section to 5,856' MD/4,172' TVD. Confirm this setting depth with the geologist and Drilling Engineer while drilling the well. / Page 14 Version 1 May,2015 • Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company • Monitor the area around the conductor for any signs of broaching. If broaching is observed, Stop drilling (or circulating) immediately notify Drilling Engineer. • Efforts should be made to minimize dog legs in the surface hole. ESP equipment can be damaged if run through high dog legs. Keep DLS <6 deg/ 100. • Hold a safety meeting with rig crews to discuss: • Conductor broaching ops and mitigation procedures. • Well control procedures and rig evacuation • Flow rates, hole cleaning, mud cooling, etc. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Keep mud as cool as possible to keep from washing out permafrost. • Pump at 600 - 650 gpm. Ensure shaker screens are set up to handle this flowrate. • Keep swab and surge pressures low when tripping. • Ensure to leave a"Pump Tangent" section that is approx. 300' long in the directional plan. The ESP will need a straight section to sit. This will occur very near TD of the hole section. • Make wiper trips every 2000' unless hole conditions dictate otherwise. • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability. • TD the hole section just into the Schrader Bluff OA sand. Geologists and Drilling Engineers will help adjust well path to ensure well is landed correctly. • Take MWD surveys every stand drilled (60' intervals). " • Watch returns closely for signs of gas when near the base of the permafrost and circulate out all gas cut mud before continuing to drill. There have been no indications of hydrates on any of the "L" pad wells to date. • Have the flowline jets hooked up and be ready to jet the flowline at the first sign of clay balling. Page 15 Version 1 May, 2015 • • Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 11.7 12-1/4"hole mud program summary: • Density: Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system (1) ppg above highest anticipated MW. We will start with a simple gel + FW spud mud at 8.8 ppg. • PVT System: MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. • Rheology: Aquagel and Barazan D+ should be used to maintain rheology. Begin system with a 75 YP but reduce this once clays are encountered. Maintain a minimum 25 YP at all times while drilling. Be prepared to increase the YP if hole cleaning becomes an issue. • Fluid Loss: DEXTRID and/or PAC L should be used for filtrate control. Background LCM(10 ppb total) BARACARBs/BAROFIBRE/STEELSEALs can be used in the system while drilling the surface interval to prevent losses and strengthen the wellbore. • Wellbore and mud stability: Additions of CON DET PRE-MIX/DRIL N SLIDE are recommended to reduce the incidence of bit balling and shaker blinding when penetrating the high-clay content sections of the Sagavanirktok and the heavy oil sections of the UGNU 4A. Maintain the pH in the 8.5—9.0 range with caustic soda. Daily additions of ALDACIDE G/X- CIDE 207 MUST be made to control bacterial action. • Casing Running: Reduce system YP with DESCO as required for running casing as allowed (do not jeopardize hole conditions). Run casing carefully to minimize surge and swab pressures. Reduce the system rheology once the casing is landed to a YP<20 (check with the cementers to see what YP value they have targeted). System Type: 8.8—9.2 ppg Pre-Hydrated Aquagel/freshwater spud mud Properties: _ Depths DensityViscosity Plastic Viscosity Yield Point API FL pH 80-5856' 8—9.2 85-250 20 40 25 75 <10 8.5—9.0 System Formulation: M-1 Gel + FW spud mud Product Concentration Fresh Water 0.905 bbl soda Ash 0.5 ppb AQUAGEL 15 -20 ppb caustic soda 0.1 ppb(8.5—9.0 pH) BARAZAN D+ as needed BAROID 41 as required for 8.8—9.2 ppg PAC-L/DEXTRID LT if required for<10 FL ALDACIDE G 0.1 ppb Page 16 Version 1 May, 2015 • Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 11.8 At TD; pump sweeps, CBU, and pull a wiper trip back to the 20" conductor shoe. 11.9 Should backreaming be necessary to get out of the hole: • Prior to initiating backreaming, ensure at least 3 —4 B/U have been circulated to get hole as clean as possible. • Pump at full drill rate (600—700 gpm), and maximize rotation. • Pull slowly, 5— 10 ft/minute. • Monitor well for any signs of packing off or losses. • Have the flowline jets hooked up and be ready to jet the flowline at the first sign of clay balling. • If flow rates are reduced to combat overloaded shakers/flowline, stop back reaming until parameters are restored. 11.10 TOH with the drilling assy, handle BHA as appropriate. 11.11 No open hole logging program planned. 12.0 Run 9-5/8" Surface Casing 12.1 R/U and pull 15.375" wearbushing. 12.2 Make a dummy run with the 9-5/8" casing hanger. 12.3 R/U Weatherford 9-5/8" casing running equipment. • Ensure 9-5/8" TC-II x DS50 XO on rig floor and M/U to FOSV. • Consider R/U of CRT if hole conditions require. • R/U a fill up tool to fill casing while running if the CRT is not used. • Ensure all casing has been drifted to 8.525" on the location prior to running. • Be sure to count the total # of joints on the location before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/vendor& model info. 12.4 P/U shoe joint, visually verify no debris inside joint. 12.5 Continue M/U &thread locking shoe track assy consisting of: • (1) Shoe joint w/float shoe bucked on (thread locked). Install (2) centralizers on shoe joint over stop collars 10' from each end. • (1)Joint with float collar bucked on pin end &thread locked. Install (1) centralizer mid tube over a stop collar. • Ensure bypass baffle is correctly installed on top of float collar. Page 17 Version 1 May, 2015 I • Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company Bypass Baffle This end up. SION 11 I • (1) Joint with Halliburton bypass baffle adapter bucked on pin&threadlocked. Install (1) centralizer mid tube over a stop collar. • Ensure proper operation of float equipment while picking up. • Ensure to record S/N's of all float equipment and stage tool components. Page 18 Version 1 May,2015 • • II Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 12.6 Float equipment and Stage tool equipment drawings: "A Overall Length ! iluir Type H ES Cementer B Part No. Mer.ID After Drilloul SO No. C 3: E Max.Teel OD Opening Seat ID 111 D Hawn)ES-Il Running Order A Closing Sleeve P No.Shear Pins el Cloning Seat ID i-"1)=-Ii . Opening Sleeve . FLi ` No.Shear Pins Plug Set I 9� C I! ES-II Cementer ES Cementer Part No. B A i Depth SO No. -_---- \ ) Closing Plug .1 Ir • 1 r 1 r' io r Baffle Adapter(If used) OD Shut Off Plug ID A Opening Plug Depth OD �(�i1� Baffle Adapter OD LJ 1 f Bypass or Shut-off Baffle ID By-Pass Plug 11Depth Shut-off Plug Float Collar _ Depth By Pass Baffle OD Float Collar b clii__----- Float Shoe Depth Bypass Plug (if used) )\-...11k Hole TD Float Shoe "Reference Casing OD Sales Manual Section 5 Page 19 Version 1 May, 2015 • • Milne Point Unit L-49 11 Drilling Procedure Hilcorp Energy Company 12.7 Continue running 9-5/8" surface casing • Fill casing while running using fill up line on rig floor. • Use Jet Lube Seal or BOL 72733 thread compound. Dope pin end only w/paint brush. • Install (1) centralizer every other joint for the first 15 joints. • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Break circulation prior to reaching the base of the permafrost if casing run indicates poor hole conditions. • Any packing off while running casing should be treated as a major problem. It is preferable to POH with casing and condition hole than to risk not getting cmt returns to surface. 12.8 Install the Halliburton Type H ES-II Stage tool so that it is positioned at 2300' MD/2137' TVD. This will position the stage collar comfortably below the permafrost. • Install centralizers over couplings on 3 joints below and above stage tool. • Do not place tongs on ES cementer, this can cause damaged to the tool. • Ensure tool is pinned with 6 opening shear pins. There are 6 holes, the tool is normally sent with only 4 pins installed. This will allow the tool to open at 3300 psi. 9-5/8" 47#L-80 TC-II Make Up Torques: Casing OD Min M/U Torque Max M/U Torque 9-5/8" 16,100 ft-lbs 18,900 ft-lbs Page 20 Version 1 May,2015 . • Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company Technical Specifications Connection Type: size(O.D.): Weight (Wall): Grade: TC-ll Casing 9-5/8 in 47.00 Ib/ft (0.472 in) L-80 standard Material L-80 Grade 1114Pg 80,000 Minimum Yield Strength (psi) 1111111111.11111111111,USA 95.000 Minimum Ultimate Strength (psi) VAM USA Pipe Dimensions 4424 W.Sam Houston Pkwy.Suite 150 9.625 Nominal PipeBodyO.D. in House: 77041031 � ) Phone:X133--479-3200 8.681 Nominal Pipe Body I.D.(in) Fax:713-479-3234 0.472 Nominal Wall Thickness (in) E-mail:VAMUSAsalesvam-usa.com 47.00 Nominal Weight (lbs/ft) 46.18 Plain End Weight (lbs /ft) 13.572 Nominal Pipe Body Area (sq in) Pipe Body Performance Properties 1.086.000 Minimum Pipe Body Yield Strength (lbs) 4.750 Minimum Collapse Pressure (psi) 6,870 Minimum Internal Yield Pressure (psi) /, 6.300 Hydrostatic Test Pressure (psi) Connection Dimensions 10.366 Connection O.D. (in) 8.681 Connection 1.D. (in) 8.525 Connection Drift Diameter (in) 5.23 Make-up Loss (in) Connection Performance Properties 1.086,000 (1) Joint Strength (lbs) 16.500 Reference String Length (ft) 1.4 Design Factor 1,086.000 Compression Rating (lbs) 4.750 Collapse Pressure Rating (psi) 6.870 Internal Pressure Rating (psi) 38.1 Maximum uniaxial bend rating [degrees/100 ft] Recommended Torque Values 16.100 (2) Minimum Final Torque (ft-lbs) 18.900 (2) Maximum Final Torque (ft-lbs) Page 21 Version 1 May, 2015 • • II Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 12.9 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 12.10 Slow in and out of slips. 12.11 P/U casing hanger joint and M/U to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe as close to TD as possible. Strap the landing joint while it is on the deck and mark the joint at(1) ft intervals to use as a reference when landing the hanger. 12.12 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. 12.13 Have emergency slips ready to go in the event we cannot land the hanger. 12.14 R/U circulating equipment and circulate B/U. Reduce YP to <20 to help ensure success of cement job. Ensure adequate amounts of cold M/U water are available to achieve this. Elevate hanger slightly above hang off point while circulating to avoid plugging the flutes. 12.15 After circulating, lower string and land hanger in wellhead again. Page 22 Version 1 May, 2015 • • Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 13.0 Cement 9-5/8" Surface Casing 13.1 Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud& water can be delivered to the cmt unit at acceptable rates. • How to handle cmt returns at surface. Ensure vac trucks are on standby and ready to assist. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Ensure adequate amounts of water for mix fluid is heated and available in the water tanks. • Positions and expectations of personnel involved with the cmt operation. • Review test reports and ensure pump times are acceptable. • Conduct visual inspection of all iron used to route slurry to rig floor. 13.2 Document efficiency of all possible displacement pumps prior to cement job 13.3 Flush through cement pump and treating iron from pump to rig floor to the shakers. This will help ensure any debris left in the cmt pump or treating iron will not be pumped downhole. 13.4 R/U cmt head (if not already done so). Ensure top and bottom plugs have been loaded correctly. 13.5 Pump 5 bbls 10.5 ppg tuned spacer. Test surface cmt lines. 13.6 Pump remaining 55 bbls 10.5 ppg tuned spacer. 13.7 Drop bottom plug(flexible bypass plug). Mix and pump cmt per below calculations for the 1st stage. 13.8 Cement volume based on annular volume+ 30% open hole excess. Job will consist of lead& tail, TOC brought to stage tool. Estimated Total Cement Volume: 4 6- Section: Calculation: Vol(BBLS) Vol(ft3) 12-1/4" OH x 9-5/8" Casing (4800'- 2300') x .0558 bpf x 1.3 = 181 bbls 1016 ft3 annulus: Total LEAD: 181 bbls 1016 ft3 2.34 Ssc 12-1/4" OH x 9-5/8" Casing (5854'- 4800') x .0558 bpf x 1.3 = 76.5 bbls 430 ft3 annulus: 9-5/8" Shoe track: 90 x .0758 bpf = 6.8 38.3 Total TAIL: 83.3 bbl 468.3 ft3 `(63 56- • II Milne Point Unit L-49 Drilling Procedure Hilcorp Energy ComPenY Cement Slurry Design: Lead Slurry Tail Slurry System ArcticCEM TM System SwiftCEM TM System Density 10.7 lb/gal 15.8 lb/gal Yield 4.298 ft3/sk V 1.16 ft3/sk Mixed 21.13 gal/sk 5.04 gal/sk Water 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Keep the hanger elevated above the wellhead while working. If the hole gets "sticky", land the hanger on seat and continue with the cement job. 13.9 After pumping cement, drop top plug (Shutoff plug) and displace cement with spud mud out of mud pits. 13.10 Ensure cement unit is used to displace cmt so that volume tracking is more accurate. To operate the stage tool hydraulically, the plug must be bumped. 13.11 Displacement calculation: 5700' x .0722 bpf=200 bbls mud, 80 bbls water, 131 bbls mud The 80 bbls of water must be left across stage tool to ensure proper operation once opened. 13.12 Monitor returns closely while displacing cement. Adjust pump rate if necessary. If hanger flutes become plugged, open wellhead side outlet in cellar and take returns to cellar. Be prepared to pump out fluid from cellar. Have some sx of sugar available to retard setting of cement. 13.13 Do not overdisplace by more than '/2 shoe track volume. Total volume in shoe track is 8.7 bbls. Page 24 Version 1 May, 2015 • • Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Coinpeny 13.14 If plug is not bumped consult with drilling engineer. Ensure the free fall stage tool opening plug is available if needed. This is the back-up option to open the stage tool if the plugs are not bumped. 13.15 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held. 13.16 Increase pressure to 3300 psi to open circulating ports in stage collar. Slightly higher pressure may be necessary if TOC is above the stage tool. CBU and record any spacer or cement returns V to surface. Circulate until YP <20 again in preparation for the 2nd stage of the cement job. 13.17 Be prepared for cement returns to surface. Dump cmt returns in the cellar or open the shaker bypass line to the cuttings tank. Have sacks of sugar available and vac trucks ready to assist. Ensure to flush out any rig components used to route cmt. Page 25 Version 1 May, 2015 • S Milne Point Unit L-49 11 Drilling Procedure Hilcorp Enemy Company Second Stage: 13.18 Prepare for the 2nd stage as necessary. Hold another pre job meeting if crew change has occurred. 13.19 Load ES cementer closing plug in cmt head. 13.20 Pump 5 bbls 10.5 ppg tuned spacer. Test surface cmt lines. 13.21 Pump remaining 55 bbls 10.5 ppg tuned spacer. 13.22 Mix and pump cmt per below recipe for the 2nd stage. 13.23 Cement volume based on annular volume+200% open hole excess. Job will consist of lead& tail, TOC brought to surface. However cmt will continue to be pumped until clean spacer is observed at surface. Estimated Total Cement Volume: 2 N S Section: Calculation: Vol(BBLS) Vol (ft3) 20" Conductor x 9-5/8" (110') x .27 bpf x 1 = 29.7 bbls 167 ft3 casing annulus: 12-1/4" OH x 9-5/8" Casing annulus: (1800'- 110')x .0558 bpf x 3 = 283 bbls 1589 ft3 Total LEAD: 312.7 bbls 1756 ft3 12-1/4" OH x 9-5/8" Casing (2300' 1800')x .0558 bpf x 2 = 56 314 ft3 annulus: Total TAIL: qi,rtfr" 56 bbls 314 ft3 2'10s)C 13.24 Continue pumping lead until uncontaminated spacer is seen at surface, then switch to tail. 13.25 After pumping cement, drop ES Cementer closing plug and displace cement with spud mud out of mud pits. 13.26 Displacement calculation: 2300' x .0722 bpf= 166 bbls mud Page 26 Version 1 May,2015 • • Milne Point Unit L-49 Drilling Procedure Hilcorp Ems Company 13.27 Monitor returns closely while displacing cement. Adjust pump rate if necessary. If hanger flutes become plugged, open wellhead side outlet in cellar and take returns to cellar. Be prepared to pump out fluid from cellar. Have some sx of sugar available to retard setting of cement. 13.28 Decide ahead of time what will be done with cmt returns once they are at surface. We should get back approx. 150 bbls of cmt slurry. 13.29 Back out and L/D landing joint. Flush out wellhead with FW. 13.30 M/U pack-off running tool and pack-off to bottom of Landing joint. Set casing hanger packoff. Run in lock downs and inject plastic packing element. 13.31 Lay down landing joint and pack-off running tool. Ensure to report the following on wellez: • Pre flush type,volume(bbls)&weight(ppg) • Cement slurry type, lead or tail, volume&weight • Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration a. Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid b. Note if casing is reciprocated or rotated during the job c. Calculated volume of displacement, actual displacement volume,whether plug bumped&bump pressure, do floats hold d. Percent mud returns during job, if intermittent note timing during pumping ofjob. Final circulating pressure e. Note if pre flush or cement returns at surface&volume f. Note time cement in place g. Note calculated top of cement h. Add any comments which would describe the success or problems during the cement job Send final "As-Run" casing tally & casing and cement report to lkeller@hilcorp.com and cdinger@hilcorp.com This will be included with the EOW documentation that goes to the AOGCC. Page 27 Version 1 May, 2015 • • Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 14.0 BOP N/U and Test 14.1 N/D the diverter. 14.2 N/U Seaboard tubing spool. Install pack-off 9-5/8"P-seals. Test to 3000 psi. 14.3 N/U 11" x 5M BOP as follows: • BOP configuration from Top down: 11" x 5M Hydril annular BOP/11" x 5M Shaffer double ram/11" x 5M mud cross/11"x 5M Hydril single ram • Double ram should be dressed with 2-7/8" x 5" VBRs in top cavity, blind ram in btm cavity. • Single ram should be dressed with 2-7/8" x 5" VBRs. • N/U bell nipple, install flowline. • Install (1) manual valve & (1) HCR valve on kill side of mud cross. (manual valve closest to mud cross). • Install (1) manual valve on choke side of mud cross. Install an HCR outside of the manual valve. 14.4 Run 5" BOP test assy, land out test plug(if not installed previously). • Test BOP to 250/3000 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. • Ensure to leave "B" section side outlet valves open during BOP testing so pressure does not build up beneath the test plug. ✓ 14.5 R/D BOP test assy. 14.6 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.7 Mix 8.9 ppg Baradrill-N fluid for production hole. 14.8 Set 10" ID wearbushing in wellhead. 14.9 Rack back as much 5"DP in derrick as possible to be used while drilling the hole section. 14.10 Keep 5-1/2" liners in mud pumps. Page 28 Version 1 May, 2015 . Milne Point Unit L-49 11111 Drilling Procedure Hilcorp Energy Company 15.0 Drill 8-1/2" Hole Section 15.1 P/U 8-1/2" directional BHA. • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Ensure MWD is R/U and operational. • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. • Workstring will be 5" 19.5# S-135 • Install ported float above motor. 15.2 8-1/2"BHA(Includes GR+Res+ADR LWD components & PWD): ✓ COMPONENT DATA IIIIIIIIIIIIIIIIIIIIMIIIIIIIIIIIIMIIMIIIIIIIIIIII ri ttem ODsuge w Top ; °a Lengt . Cumulative Description Serial Number AI (in) i,ln} (in) (Rip Connec tit Length (ft) EN HOBS-FX6513 8.400 2.500 8.500 172-13 P 4-12'REG 1.00 1.00 © T'SperryDrill Lobe 7,8-6.0 stg 7.000 4.952 93.13 B 4-1/2"IF 27 38 28 38 - Stabilizer -__ 7.750 __- ® Non Mag Float Sub 6.750 2.750 101 71 B 4-112"IF 3 I ME Integral Blade Stabilizer(NM) 6.750 2.813gam 100.77 B 4-1/2"IF 5.00 36 38 © 6 3/4"DM(Directional) 6.750 3.125 103 40 B 4-112"IF 9.20 101 6 314"DGR(Gamma) 6.750 1.920 97.80 B 4-112"IF 4.55 50 14 11311 6 3,4'EWR-P4 (Resistivity) IIIIIIIIIIII 6.750 2.000 104.30 B 4-112"IF 12.10 Eig 6 314"HCIM (Processor) 6.750 1.920 101.70 B 4-112"IF 4.97 Milill ® 6 314"ALD Collar 175C 30KSI 6.750 1.920 8.250 104 30 P NC 50 14.54 81 75 - Stabilizer -__ 8.250 _--- 10 6 3/4"CTN Collar 175C 30KSI 6.750 1.905 102.30 B NC 50 11.84 9359 IIIII 6 314"TM-HOC(Pulser) 6.900 3.250 103.60 B 4-112"IF 15 59 109 18 ® 6-314"Non Mag Flex Drill Collar 6.750 2.813 100.77 8 4-112"IF 30.00 139 18 ® 6-314"Non Mag Flex Drill Collar ® 6.750 2.813 100.77 B 4-112"IF 30.00 169.18 ® X-O 4-112"CDS 40 Box X 4-112"IF Pin 6.500 2.750 92.85 B 4.5"COS 40 2.75 171.93 ® 6 Joints 4-112'CDS 40 HWOP 4.500 2.500 37.47 180.00 351.93 Es X-O 4-1/2"IF Box X 4-1,2"COS 40 Pir 6.500 2.750 92.85 B 4-112"IF 2.75 354.68 Ell Weatherford 6-1/4"Jars 6.250 2.250 91.01 B 4-1i2"IF 30.00 384.6B MIEM X-O 4-112"IF Pin X 4-1!2"CDS 40 Box 6.500 2.750 92.85 B 4.5"CDS 40 2.75 387.43 NEI 19 Joints 4-112°CDS 40 HWOP 4.500 2.500 37 47 570.00 957.43 Tatat ,,. 957.43 Bit Number • Nozzles : 5x13 Bit Size (in) 8.500 TFA (int) : 0.6481 Manufacturer Dull Grade In Model • Dull Grade Out • Serial Number . Page 29 Version 1 May, 2015 • • Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 15.3 Primary Bit: 8-1/2" (216mm) SFE56 PRODUCT SPECIFICATIONS Cutter Type X2-Tough Drilling 1ADC Code S424 Body Type STEEL # Total Cutter Count 29 Cutter Distribution31 t ern 19� w+ Face 0 19 1 Ir Gauge 10 0 Number of Large Nozzles 5 46. k SP Number of Medium Nozzles 0 Number of Small Nozzles 0 Number of Micro Nozzles 0 Number of Ports(Size) 0 Number of Replaceable Ports(Size) 0 1 Junk Slot Area(sq in) 20.81 1 Normalized Face Volume 73.86% " API Connection 4-1/2 I.F.PIN 1010 Recommended Make-Up Torque* 23,743 FNlbs. 0 Nominal Dimensions** Make-Up Face to Nose 8.31 in-211 mm 1 Gauge Length 3 in-76 mm Sleeve Length 0 in-0 mm Shank Diameter 6.688 in-170 mm Break Out Plate(Mat.#/Legacy#) 181960 44073 Approximate Shipping Weight I20Lbs.-54Kg. SPECIAL FEATURES Anti-Balling Coating.Short Shank.EDL Tool Specific Gage..084"Dia Step,.126"Dia Step Material#761417 15.4 8-1/2"hole section mud program summary: • Density: Weighting material to be used for the hole section will be calcium carbonate. Additional calcium carbonate will be on location to weight up the active system(1)ppg above highest anticipated MW. • Solids Concentration: It is imperative that the solids concentration be kept low while drilling the production hole section. Keep the shaker screen size optimized and fluid running to near the end of the shakers. It is okay if the shakers run slightly wet to ensure we are running the finest screens possible. Page 30 Version 1 May, 2015 i Milne Point Unit L-49 Drilling Procedure Hilcorp EnergY Cowwoy • Rheology: Keep viscosifier additions to an absolute minimum (N-VIS). Data suggests excessive viscosifier concentrations can decrease return permeability. Do not pump high vis sweeps, instead use water or low vis sweeps. • Run the centrifuge continuously while drilling the production hole, this will help with solids removal. • Dump and dilute as necessary to keep drilled solids to an absolute minimum. • MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, & Toolpusher office. System Type: 8.9—9.2 ppg Baradrill-N drilling fluid Properties: Depths Density '1 Plastic Viscosity Yield Point Total Solids MBT HPHT pH 5856- 12374 8.9-9.2 15-25 15-25 <10% <7 <11.0 8.5-9.5 System rmulation: Baradrill-N Product Concentration Water 0.955 bbl KCL 11 ppb KOH 0.1 ppb N-VIS 1.0— 1.5 ppb N-DRIL HT PLUS 5 ppb BARACARB 5 11.5 ppb BARACARB 25 16.8 ppb BARACOR 700 1.0 ppb BARASCAV D 0.5 ppb X-CIDE 207 0.015 ppb EZ-GLIDE 2.0% 15.5 TIH w/ 8-1/2" directional assy to stage tool. Shallow test MWD and LWD on trip in. Note depth TOC tagged on AM report. Drill out stage tool as follows: • Do not exceed 75 rev/min rotation speed. A good range is 40 to 75 rpm. • Because of aggressive nature of PDC bits, drilling with minimal WOB is recommended. Approx 2-5 k is enough. • Apply weight and allow it to drill off before applying more. • After drilling out, chase any remaining debris to bottom with the drill bit. Page 31 Version 1 May, 2015 • • Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 15.6 TIH to TOC above the baffle adapter. Note depth TOC tagged on morning report. 15.7 R/U and test casing to 3000 psi/ 30 min. Ensure to record volume/pressure and plot on FIT graph. AOGCC reg is 50% of burst= 6870/2 =—3500 psi, but maximum test pressure on L-49 is 3000 psi. Z;.�� 15.8 Drill out shoe track and 20' of new formation. 15.9 CBU and condition mud for FIT. 15.10 Conduct FIT to 121„...2.2ELIAW. 15.11 Drill 8-1/2"hole section to section TD per Geologist and Drilling Engineer. • Pump at 500 - 550 gpm. • Ensure shaker screens are set up to handle this flowrate. Ensure shakers are running slightly wet to maximize solids removal efficiency. Check for holes in screens on every connection. • Pump water or other low vis sweeps to aid in hole cleaning. • Keep swab and surge pressures low when tripping. • Make wiper trips every 1500—2000 ft if necessary. • Take MWD surveys every stand drld.v Surveys can be taken more frequently if deemed necessary. • Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. • Use ADR to stay in section. Ideally, we would like to stay in section 100% of the time and DO NOT want to serpentine between the upper and lower lobes. 15.12 Open hole sidetracking practice: • If a known fault is coming up,put a slight"kick-off ramp" in wellbore ahead of the fault so we have a nice place to low side. • Attempt to lowside in a fast drilling interval where the wellbore is headed up. • Orient TF to low side and dig a trough with high flowrates for the first 10 ft, working string back and forth. Trough for approx. 30 min. • Time drill at 4 to 6 feet per hour with high flow rates. Gradually increase ROP as the openhole sidetrack is achieved. 15.13 At TD; pump low vis sweeps, CBU at least 3 times at maximum circulation and rotation, and pull a wiper trip back to the 9-5/8" shoe. If backreaming is necessary: • Circulate at full drill rate (500—550 gpm). • Rotate at maximum rpm that can be sustained. • Limit pulling speed to 5 — 10 min/std (slip to slip time, not including connections). • If backreaming operations are commenced, continue backreaming to the shoe and circ at least a b/u once at the shoe. Page 32 Version 1 May,2015 • Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 15.14 TOH with the drilling assy, stand back BHA if possible. Rabbit DP on TOH. 15.15 No open hole logs are planned for the production hole section. 16.0 Run 5-1/2" Injection Liner 16.1. Install and test 5-1/2"casing ram in top ram cavity. Test to 250/3000 psi. 16.2. Re-install wear bushing in wellhead after test. 16.3. R/U 5-1/2" casing running equipment. • Ensure 5-1/2" DWC/C x DS-50 crossover is on rig floor and M/U to FOSV. • Ensure all casing has been drifted on the deck prior to running. • Be sure to count the total #of joints on the deck before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/vendor& model info. 16.4. Run 5-1/2"production liner per completion tally. • Use "Best 0 Life 2000"thread compound. Dope pin end only w/paint brush. • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Install swell packers & ICDs as per Operations Engineer guidance. • Ensure all plastic packing is removed from swell pkr elements. • Do not place tongs or slips on ph elements or ICDs. 5-1/2" DWC/C HT M/U torques Casing OD Minimum Maximum Yield Torque 5.5" 9,800 ft-lbs 11,000 ft-lbs 14,800 ft-lbs Page 33 Version 1 May, 2015 • Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company Technical Specifications Connection Type: Size(O.D.): Weight (Wail): Grade: DWCIC-HT Casing 5-112 in 17.00 Ibift(0.304 in) L-80 standard Material L-80 Grade 80.000 Minimum Yield Strength (psi) USA 95.000 Minimum Ultimate Strength (psi) VAM USA 4424 W.Sam Houston Pkwy.Suite 150 Pipe Dimensions Houston.TX 77041 Phare:713-479-3200 5.500 Nominal Pipe Body O.D. (in) Fax:713-479-3234 4.892 Nominal Pipe Body I.D.(in) E-mail:VAMUSAsalesvam-usa.com 0.304 Nominal Wall Thickness (in) 17.00 Nominal Weight (Ibslft) 16.89 Plain End Weight(lbs/ft) 4.962 Nominal Pipe Body Area (sq in) Pipe Body Performance Properties 397.000 Minimum Pipe Body Yield Strength (lbs) 6.290 Minimum Collapse Pressure(psi) 7.740 Minimum Internal Yield Pressure(psi) 7.100 Hydrostatic Test Pressure(psi) Connection Dimensions 6.050 Connection O.D. (in) 4.892 Connection I.D. (in) 4.767 Connection Drift Diameter(in) 4.13 Make-up Loss(in) 4.962 Critical Area(sq in) 100.0 Joint Efficiency(%) Connection Performance Properties 397.000 Joint Strength (lbs) 16.680 Reference String Length(ft) 1.4 Design Factor 428.000 API Joint Strength (ibs) 397.000 Compression Rating(lbs) 6.290 API Collapse Pressure Rating (psi) 7.740 API Internal Pressure Resistance (psi) 66.7 Maximum Uniaxial Bend Rating [degrees/100 ft] Appoximated Field End Torque Values 9.800 Minimum Final Torque (ft-lbs) 11.000 Maximum Final Torque (ft-lbs) 14.800 Connection Yield Torque (ft-lbs) Page 34 Version 1 May, 2015 • • Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 16.6. Ensure to run enough liner to provide for approx 200' overlap inside 9-5/8" casing. Ensure hanger/pkr will not be set in a 9-5/8" connection. 16.7. Before picking up Baker ZXP liner hanger/packer assy, count the # of joints on the pipe deck to make sure it coincides with the pipe tally. 16.8. M/U Baker ZXP liner top packer. Fill liner tieback sleeve with"Pal mix", ensure mixture is thin enough to travel past the HRD tool and down to the packoff. Wait 30 min for mixture to set up. 16.9. Note weight of liner. Run liner in the hole one stand and pump through liner hanger to ensure a clear flow path exists. 16.10. RIH w/liner on DP no faster than 1-1/2 min/ stand. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 16.11. DP should autofill. 16.12. Slow in and out of slips. Ensure accurate slack off data is gathered during RIH. Record shoe depth+ S/O depth every stand. Record torque value if it becomes necessary to rotate the string to bottom. 16.13. Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10, 20, & 30 rpm. 16.14. If any open hole sidetracks have been drilled, monitor sidetrack depths during run in and ensure shoe enters correct hole. 16.15. TIH deeper than planned setting depth. Last motion of the liner should be up to ensure it is set in tension. 16.16. Prior to setting the hanger and packer, double check all pipe tallies and record amount of drill pipe left on location. Ensure all numbers coincide with proper setting depth of liner hanger. 16.17. Rig up to pump down the work string with the rig pumps. 16.18. Displace entire wellbore to completion fluid (8.9 ppg KC1). Pump at 10-12 bpm. Catch mud for future use if feasible. Once KC1 observed at surface shut down pumps. 16.19. Drop setting ball down the workstring and pump slowly(1-2 bpm). Slow pump before the ball seats. Do not allow ball to slam into ball seat. 16.20. Pressure up to 3000 psi and hold for 5-15 minutes to set SLZXP hanger packer. Continue pressuring up in 500 psi increments holding for 5 min each up to 4000 psi. Page 35 Version 1 May, 2015 • i Milne Point Unit L-49 14 Drilling Procedure Hilcorp Energy Company 16.21. Bleed DP pressure to zero, close BOP and test annulus to 1500 psi for 10 min and chart record same. 16.22. Bleed off pressure and pickup to verify that the HRD setting tool has released. If packer did not test, rotating dob sub can be used to set packer. If running tool cannot be hydraulically released, apply LH torque to mechanically release the setting tool. 16.23. POOH, L/D and inspect running tools. If setting of liner hanger/packer proceeded as planned, LDDP on the TOH. 16.24. L/D remaining DP out of derrick. 17.0 Run Injection Assembly 17.1 M/U injection assy and RIH to setting depth. • Ensure appropriate well control crossovers on rig floor and ready. • Monitor displacement from wellbore while RIH. 17.2 Land hanger, RILDs and test hanger. 17.3 Circulate freeze protect down IA, allow freeze protect to U-tube down tubing. 17.4 Set packer. Test annulus to 3000 psi f/30 min. /ck4I 17.5 Install BPV and N/D BOP. 17.6 N/U tree adapter and tree. Conduct pressure tests of same to 250/3000 psi. 17.7 Shut in well. 18.0 RDMO Page 36 Version 1 May, 2015 • II Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 19.0 Diverter Schematic rp NI III PI rem 411 / \ 1 1 G Schaffer 21-1r4" fr 2M Annular \\\\ / CM El lik J. 21-1r4"2M Riser---_ ji16"Full Opening Knife Valve If M.. ns .,-, I-)L� �� amu. -) 111 8-.......N.,_ 21-1/4"2M-- R Diverter"T' g 16"Diverter Line ill II fe of elf if i an Y Si LLB UP{! 21-1/4"2M--_--,- Spacer Spool am a-.TM 1111 16-314"3M x 21-114"2M DSA flb ilb el'r L„no JL Imoli Seaboard Casinghead,S-22-AP-8 '4 16"SOW x 16-34"3M; (2)ea 2.1116"5M studded outlets 20"Casing Page 37 Version 1 May, 2015 • • II Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 20.0 BOP Schematic / I \ I I 6 0 Z Hydril Annular BOP 711"x5M clip et mill �m a,9r' +r 1 7,.. Shaffer 11" x 5M1111„ �1 1 `eft. '— _ 0 000 III t i I 0 0 0 50 0 't-111� ' ] t IN") � . 0 i I .... .... I 7-3"xSMHCR ■ f 1��� II 9/ L ark II I MEI(s'.11 ��l i i`... �'1■f -------Choke Line r Kill Line mil L3"x 5M Manual Gate Valve Y Y —1—_E Hydril 11"x 5M r___r1 _ . A - :t YY YY , Rn nam , , --------------11"x 5M -I— — el l[;if-N] Seal----„N, ` g-5i8"DBL D Sea , . 1 `I' 2-1/16"x 5M Casing Hanger _'1� III di���r 16-314"x 3M SMB-22 � • 'V' !`V 16-314"NOM 9-5/8"BTC Btrn x AI 2-1116"x SM 10.5"-4 SA Pin Top W1 Primary Sea ON 20"Casing 9-518"Casing Page 38 Version 1 May, 2015 I • II Milne Point Unit 1-49 Drilling Procedure Hilcorp Energy Company 21.0 Wellhead Schematic ADAPTER, ESP-C2L TOADSTOOL 35.8 11 5M HOLD-DOWN SHOULDER EST x 2-9/16 5M ROTATING FLG I-5- U LI ti 7 EST di 11i11111 lIcl}!1 M m 11.1n - 11111 rIL1!Li , . TUBING HANGER, S—BB—ESP Mil Irl 11 NOM, 2-7/8 8RD BOX TOP x 2-7/8 IBT-M BOX BTM ; •� , 'O 9 •ins • EST ! EMI 11111111111 E11• - a'. -I EST 9-5/8 DAL D SEAL JIMII VI lil . � = .11 ...... 2-1/16 5M _ � :ate - 16-314 3M 4 ..,1 ir g 7. CASING HANGER, SMR-22 mi1111 16-3/4 NOM, l. __,..._,. „, 9-5/8 BC BTM x _ 10,500-4 SA PIN TOP ! m.::_i - AT IA f1-IN/PRIMARY SEAL ' 1111 1■Ii7.1, ri o ! Niro •1 31.6 ft s�j EST g SWAGE ADAPTER, 20 SOW x 16 SLIP ON PIN 2-1/16 SM All =- ---' MIL UWE 1_f011&GAS r 3.000 PSI WELLHEAD ASSEMBLY 20 CASING- 20 x 9-5/8 x 2-7/8 rr" Arc .�"T:Tz °'"z/12/15 . 9-5/8 CASING 1 LM° °"'"'6 ND' 1r P-20547 2-7/6 TUBING Page 39 Version 1 May, 2015 ! Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 22.0 Days Vs Depth Days Vs Depth 0 �Schrade r B luff Well -M PI-19 12004) MPI-18[2011) -MP4-1712004) 2000 M P1-15 12002) \\\\\\ 4000 6000 �i. 8 7 1 N iI m CI 8000 10000 12000 14000 0 5 10 15 20 25 30 Days Page 40 Version 1 May,2015 0 Milne Point Unit L-49 11 Drilling Procedure Hilcorp Energy Company 23.0 Formation Tops Formation TVD (Top) TVD (Bottom) Anticipated Pressure (Psi) SV1 2175 3545 973 Ugnu LA1 3546 3773 1586 Ugnu MB 3774 4023 1688 SB NB Sand Top 4024 4160 1800 SB OA Sand Top 4161 4196 1861 Page 41 Version 1 May, 2015 • • Milne Point Unit L-49 11 Drilling Procedure Hilcorp Energy Company 24.0 Anticipated Drilling Hazards 12-1/4" Hole Section: Lost Circulation Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Gas Hydrates Remember that hydrate gas behave differently from a gas sand. Additional fluid density will not prevent influx of gas hydrates. Once a gas hydrate has been disturbed the gas will come out of the hole. Drill through the hydrate section as quickly as possible while minimizing gas belching. Minimize circulation time while drilling through the hydrate zone. Excessive circulation will accelerate formation thawing which can increase the amount of hydrates released into the wellbore. Keep the mud circulation temperature as cold as possible. Weigh mud with both a pressurized and non-pressurized mud scale. The non-pressurized scale will reflect the actual mud cut weight. Add 1.0—2.0 ppb DRILTREAT to the system to help thin the mud and release the gas. Isolate/dump contaminated fluid to remove hydrates from the system. Hole Cleaning: Maintain rheology of mud system. Sweep hole with high viscosity sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Monitor ECDs to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out a particular section of the hole. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. /Anti-Collison: There are a number of wells in the vicinity of L-49. Take directional surveys every stand, take additional surveys if necessary. Continuously monitor proximity to offset wellbores and record any close approaches on AM report. Discuss offset wellbores with production foreman and consider shutting in adjacent wells if necessary. Monitor drilling parameters for signs of collision with another well. Wellbore stability (Permafrost, running sands and gravel, conductor broaching): Washouts in the permafrost can be severe if the string is left circulating across it for extended periods of time. Keep mud as cool as possible by taking on cold water and diluting often. High TOH and RIH speeds can aggravate fragile shale/coal formations due to the pressure variations btwn surge and swab. Bring the pumps on slowly after connections. Monitor conductor for any signs of broaching. Maintain mud parameters and increase MW to combat running sands and gravel formations. H2S: Treat every hole section as though it has the potential for H2S. No H2S events have been documented on drill wells on `L"pad. / t 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during v drilling operations. Page 42 Version 1 May,2015 • • Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. 3. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. 8-1/2" Hole Section: Hole Cleaning: Maintain rheology of mud system. Sweep hole with low-vis water sweeps. Ensure shakers are set up with appropriate screens to maximize solids removal efficiency. Run centrifuge continuously. Monitor ECDs to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out a particular section of the wellbore. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Maintain circulation rate of> 500 gpm. Lost Circulation: Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Faulting: There is at least(1) fault that will be crossed while drilling the well. There could be others and the throw of these faults is not well understood at this point in time. When a known fault is coming up, ensure to put a"ramp" in the wellbore to aid in kicking off(low siding) later. Once a fault is crossed, we'll need to either drill up or down to get a look at the LWD log and determine the throw and then replan the wellbore. H2S: Treat every hole section as though it has the potential for H2S. No H2S events have been documented on drill wells on `L"pad. 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. 3. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Abnormal Pressures and Temperatures: There are no abnormal pressures or temperatures observed on"L"pad. Page 43 Version 1 May, 2015 • II Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 25.0 Nordic #3 Rig Layout (Drillers Side) • kvi Atiro -6alista Services RJG NO. 3 0,--\14)--6.00(?).0 1 2 Thr Drop.eorhnding.pr.dxnvm eIrrottor and slot corona..imhr&o nl the rre-harm parent of Notes- Cal tot a oedirr-Calms And o prcarrs d br US rod ortennernri rr trn¢ho lets.The I>c.ip"ea ferntrh.1 on..rm6dnei.l huu.reh the r.pnu.y.mem she n nail not br esti.c:amSmmd.aprlird srx.d.phorngrep ode or reproduced In say mune 'Aunee r,in wink spm not ant nem heron hr h+ih.sumferrvmd,or awr'kd snit rite aid d'rhr align .vim the written velment of Nerd:-[.hats rot D.iyc may net Is dick rd to any ether pant.inept for 1hr einci(cpeper Gm which n ha been panda i Ni lir441 .. ,.,I 400,.. .0 • i ..... AP gr.,-._._-__—., ' + }rif riC 2rX IRf—�I�Vf'.w—Ifs y7'-.r.� I ' D amain 1 .'J� owa as r . .... �..__.d� Mt MN et 4An mama PrA4N °fd14:.r-ma k '..-..Nk. - I IMI 218 NO ........ 4...\/: 011 .......______ RBI i `' �� w !CAT d ,1:; _tea r i. err ,I wimpms rr,sar-r- - {—�i--�-r _gpt-e Iwo Drillers Side Page 44 Version 1 May, 2015 0 • II Milne Point Unit L-49 Drilling Procedure Hilcorp Enemy Comcpoy 26.0 Nordic #3 Rig Layout (Well End & Top View) • u.- i -11= 1111111 lin- �—t- � ' NINO ri, � i - . , ...„, C MI Err - - —f -- -' ENGL•:liLpKL ■ MEMO ID I iv Hoops'o ACCEWT FLOW WIES Well End Y.t+J,'-J 6---t1-m- — ___-_ M-r —w-Y— f I- I ii ref[ntwo p n =I SHAKO!OUILONG C MT COON lar%iAMA* ooawC ones - —r 2-r _ 4 w Ile! .w•}Ep PPE r>•ED. MAICII %;/lnJ,lJ w...1 5 .. 'L+ .. b , , ...:-.----------- I_i!•11 _. _.�. 1 i' .ARA+.J V A ., ,A 17 oil 41 b wap lMF ! :Li_ TAIII 4ppGl. Pet DOOM I I I I II I I I I U Pm nswoom U I TOP VIEW Page 45 Version 1 May, 2015 • Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 27.0 FIT Procedure Formation Integrity Test (FIT) and Leak-Off Test (LOT) Procedures Procedure for FIT: 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer(ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. 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• Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 29.0 Casing Design Information Calculation & Casing Design Factors DATE: 6/2/2015 WELL: MPU L-49 DESIGN BY:Luke Keller Design Criteria: Hole Size 12-114" Mud Density: 9.5 PP9 Hole Size 8-112" Mud Density: 9.5 ppg Hole Size Mud Density: Drilling Mode MASP: 1449 psi (see attached MASP determination& calculation) MASP: Production Mode MASP: 1449 psi(see attached MASP determination&calculation) Collapse Calculation: Section Calculation 1 Normal gradient external stress (0.494 psi/ft)and the casing evacuated for the internal stress Casing Section Calculation/Specification 1 2 3 4 Casing OD 9-5/8" 5-1/2" Top(MD) 0 5,656 Top (TVD) 0 4,172 Bottom (MD) 5,856 12,374 Bottom (TVD) 4,172 4,172 Length 5,856 8,202 Weight(ppf) 47 17 Grade L-80 L-80 Connection TC-II DWC/C HT Weight who Bouyancy Factor(lbs) 275,232 139.434 Tension at Top of Section (lbs) 275,232 139.434 Min strength Tension(1000 lbs) 1086 347 Worst Case Safety Factor(Tension) 3.95 2.49 Collapse Pressure at bottom (Psi) 2,061 2,061 Collapse Resistance w/o tension (Psi) 4,760 7,100 Worst Case Safety Factor(Collapse) 2.31 3.44 MASP(psi) 1,449 1,449 Minimum Yield (psi) 6,870 7,740 Worst case safety factor(Burst) 4.74 5.34 Page 48 Version 1 May,2015 • • 11 Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 30.0 8-1/2" Hole Section MASP Maximum Anticipated Surface Pressure Calculation ti�i�orh 8-1/2"Hole Section MPU L-49 Milne Point Unit MD TVD Planned Top: 5856 4172 Planned TD: 12374 4172 Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad Schrader Bluff OA Sand 4,172 1866 Oil/Wet 8.6 I 0,447 Offset Well Mud Densities Well MW range Top(TVD) Bottom(TVD) Date L-37(1998) 8.9-9.3 Surface 7,050 1998 L-35(1997) 8.4-9.2 Surface 5,687 1997 L-341(1997) 8.4-9.4 Surface 5,842 1997 Assumptions: 1. Field test data suggests the Fracture Gradient in the Schrader Bluff is btwn 11.5 and 15 ppg EMW. 2. Maximum planned mud density for the 8-1/2"hole section is 9.5 ppg. 3. Calculations assume full evacuation of wellbore to gas Fracture Pressure at 9-5/8"shoe considering a full column of gas from shoe to surface: 4172(ft)x 0.78(psi/ft)= 3254 psi 3254(psi)-[0.1(psi/ft)*4172(ft)]= 2837 psi MASP from pore pressure(complete evacuation of wellbore to gas from Schrader Bluff OA sand) V,< 4172(ft)x 0.447(psi/ft)= 1866 psi 1866(psi)-0.1(psi/ft)*4172(ft)= 1449 psi Summary: 1. MASP while drilling 8-1/2 production hole is governed by pore pressure and evacuation of entire wellbore to gas at 0.1 psi/ft. Page 49 Version 1 May, 2015 • s II Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 31.0 Spider Plot (NAD 27) (Governmental Sections) tit% ,i alt,', %?.�+ +++ +.,t r . ''F--': r + + + 1, ' \��Z ;yrNl r. tt 410, 0, , ... v r � +,fr-. 1111 �$ 11 / + // �/. =c.13 • \\,V�,i\ ! + M+1.+/rtaraF y.•F--, 'r t r 1 1 ' / + �// // \l'‘41 � ,�� Fl r J + \� �t1 I r r tr rr11 ' ++ +1 / /r+ .. \ ♦ \ r� r,f/M+,+ + a h 1 II r r 1 1 1 + !/ '/ +\ i. . ♦v rl'V, x4.')- „�1''Ff h r ,, it tr r1// 1+ /f ,i' #` . 2r t �a•.�f� .:.,,,,,..,,,f Sec 6 7'- 4 1 Ni 1' 1 r_ _IL r '/Sec 5 / ,:' ,' 0' :Vr+.i7V ;6251__,- -f it It it 1111 + ! /� ` •FIF, :-'\ '• ' k t 1 rr tr rr 10,.1 , ff nlFcas ` \ %\ + N rt 1i f r� Ya,F✓J r.,, , t 1 tr 1 tt Iti + /! r` ' F.- r 'i ., \ e� \\ %• A\ Irr I I tFtl_ f r, `• \ j ♦ ir. • ., \ •• 11�� Its 4111• ! ,rte \ .\ • •1 ',\‘1 g4t1Nf / \a ` '•``• �' •• •S,ADL025509/' /;' r ADL047434 F . ""� i \ ♦\ 4T 1 + r 1� \ `,u4�t I /i/r r f + r r ', w - V tax ' -....c........\.: F �1 i ,MPL-49 SHL '. , •� • ..•a ,, 1,l \♦♦♦1Z F (2:30 Sec 9 ~zx' i t f /r M ntA .. N.N. �f/r ri`r 4 /f '•II A, ..,x,•'r f ;MPL-49 TPH - S' "V'U013N010E • rV '„ 1, ! //i �""� _• • !� ffI // , ,_. • 1� �1 r- `.Y , .. ••F�-1 - /!/ // 1 ` • //// 1 \ f I \ / \` MPL-49 SHL fc3 , CZ®' -ec 16 Legend ADL315848 • MPL-49 SHL X �^ MPL-49 TPH 4 i MPL-49 BHL 4 Aii "re Surface Holes(SHL) ,r xi, ` ti 21 v47• 1 • Other Bottom Holes(BHL) �±� -- - - v,Other Well Paths . , "IP•`t Page 50 Version 1 M,ay, 2015 • • II Milne Point Unit L-49 Drilling Procedure Hilcorp Energy ComWny 32.0 Surface Plat (As Built) (NAD 27) • I �, 3i 31 1 32 I 33 o� b Q 1 lls V 1 11l N 1 1e;;115'. _ _ h.W T 13N\\\\\ f' \1 1 =s 1 / 1 t` S ( 4 } } I / 32 • 33 ■ , \•6 `�lg. `. av I } I i 2B • 29 • 1 7 ! ,\I 1 I 24 • 25 ■ -IV- I 20 • 21 • I h-y t6 • » ■ 41 • 43 ■ I ��( / 4Si • L----1 13 II I ` 17 i 16 1 1 13 ■ ■ B _14 to I zo I 7t I 39 ■ ■ 42 VICINITY MAP • ■ 9 MAL 34• • 14 3 • • 10 15 ■ ■ 47 LEGEND 2 • ■ 7 ■ +L-49 4 AS-STAKED CONDUCTOR 12 12 • ■ EXISTING CONDUCTOR 40 ■•■■■■ ■•+-4- 6 35 4 Je 5 37 11 50 J J _ ) NOTES: k\\ �� 1. ALASKA STATE PLANE COORDINATES ARE ZONE 4.N4027. I 2 BASIS O•LOCATION IS L-PAO MONUMENTS 1-1 NORTH At40 L-2 SOUTH. \ I L-PAD 3. BASIS OF ELEVATION IS MLLW. } I 4. GEODETIC POSITIONS ARE NAO27. 5. PAD MEAN SCALE FACTOR It 0.9999023 I I 6. DATE OF SURVEY: MAY 10,2015. I 7. REFERENCE FIELD BOOK: HC15-01 POS.58-64 GRAPHIC SCALE 0 100 200 400 1 1 (IN FEET) t ircN -200 M. LOCATED WITHIN PROTRACTED SEC. 8. T. 13 N., R. 10 E., UMIAT MERIDIAN, AK, WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(O.DD)BOX ELEV. OFFSETS Y=6,031,494.52 N= 1109.99 70'29'48.867') 70.4969076' 3,303'FSI. L-� X= 545,148.08 E= 1423.02 149'37'50.905" 149.6308069' NA 4,733'FEL Y=6,031,478.63 N= 1110.00 70'29'48.712' 70.498864' 3,287'FSL I.- X= 545,122.85 E= 1393.00 149'37'51.656' 149,6310156' NA 4,758'FEL Y=6,031,591.24 N= 1169.99 70'29'49.816' 70.4971711' 3,399'FSL 1-49 X= 545.189.65 E= 1509.53 149'37'49,665 149.63046216' NA 4.690'FEL mak a Mr+ w,o N0 -HUMAN 11HilwlrpAlaska S/11/18 la3 Net 6t MPV L-PAD 1 C AMP, NS 449414110N _.NSdV AS-STAKED CONDUCTOR NM ME MINION IN 1St moi-.aov WELLS 1-46, L-48, 1-49 1 a 1 Page 51 Version 1 May, 2015 i 11 Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 33.0 Offset MW vs TVD Chart MW vs ND Offsets 0 1 L-37 —L35 1000 — — L-341 2000 3000 e 4000 5000 ) 4111 5000 7000 5000 8.0 9.0 10.0 11.0 12.0 13.0 14.0 15.0 Mud Weight(PPG) Page 52 Version 1 May,2015 i i 11 Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company 34.0 Drill Pipe Information 5" 19.5# S-135 DS-50 Drill Pipe Configuration Pipe Body OD it;5.000 80 c Inspection Class Pipe Body Wall Thickness ,n,0.362 Nominal Weight Designation 19.50 Pipe Body Grade S-135 Drill Pipe Approximate Length -.. 31 5 I Drill Pipe Length RangelSrnoothEdge Height m,13132 Raised Connection GPOS50 Tool Joint SMYS i',,120-000 f Tod Joint 00 6.625pset Type IEU ' Tool Joint ID Pay 3.250 Max Upset OD (DTE) ,,:5.125 Pin Tong 9 Friction Factor 11.0 Box Tong 1411 12 Node-Tong space may Include ha eacing. Drill Pipe Performance Drill-Pipe Length Rangel Performance of Drill Pipe with Pipe Body at i Best Estimates Nominal 80 X Inspection Class f `W1 a.t Coatji l*v4J1 Coanrgt ,least accurate) Ap:ied Mike•+o Operational Max Tension Drill Pipe Adjusted Weight ;ibanl 24.11 23.29 1�01G inubsl Torque in-os, :b:, Fluid Displacement �'n 0 37 0.36 43,100 Tension Only ()Torque 560.800 Fluid Displacement en: 11,40 0088 0.0085 MaaFnum MUT Fluid Capacity .�.._... �" Gemmed e���39,600 410.500 P til -:aenl 0.71 0.70 0.72 Fluid Capacity abls•n1 0.0169 0.0167 0.0172 36,100 Tension Only0 560,800 IArMetan Mur Gp„p 1ed d n0 32,100 467.400 Drift Size 3.125 Note.Oilfield barrel equals 42 US Qa6pas. tole Doll ppe assemtlY values are best esbmabes and may vary due to pre body mll tolerance,Infernal p1as00 00015,0and other rac:ors. Connection Performance GPDS50 ( 6.6251n) OD X 3.250(If ID ) 120,000 ias1l Applied make-up Terson a1 sa1oW6et Tenslcn at Carnector Tool Joint Dimensions Torque SNara:von Yeld in-en) bs; os1 Balanced 00 (Mi 6.435 I idmum Make-up Torque 43,100 Tensile Circled 1,046,900 Mlnm an Tow Jong CO far AFI 5,930 ttliinimum Make-up Torque 36.100 1.202.500 1,250.000 PrcmMm Cass ons "--- N0M:The m nio.1Rt make-up Wove should be acpled risen Kase.0 Mlnmurn Tod Joint 00 far on)5.93 Counterbarc Note-To masbwab cannechon operational tensile.a MUT 1,141-37.4C0�;nJbsl should be applied. Tool Joint Torsional Strength in lbat 71,800 ja Tool Joint Tensile Strength r 11250,000 Elevator Shoulder Information Elevator OD 3/32 Raised 6.812 - 7SmoothEdge Height Nominal Tool Joint Worn to Bevel Worn to Min TJ o0 for 3132 Raised OD Diameter API Premium Class Box OD 6.812 6.625 6.063 5.930 Elevator Capacity t! 1,658.000 1.440,200 823,600 685,600 . "�15.219 'l a El4vals2 canaaty bas0tl an assumes Eleya3-- e e 7 '.era , 1,7 t stress Or 1'0.15.051. Assumed Elevator Bore Diameter v e A raised eeva10,CC lrcreases elevator cad., . ,_at,100113 1.100 103.:0 Pipe Body Slip Crushing Capacity Pipe Body Confguration( 5 icl OD 0.362 rn; Wall S-135) Nominal 80%Inspection Class API Premium Class Slip Crushing Capacity _! 498.300 396,500 396.500 __.-.._�._::.r .._ NO*sty G,ennq sic.mating l rskuakc edn fe`-p'r.9,a ots;Po equation ton'Ally Coes DII Pee // Assumed Slip Length ,n�16.5 Fal In le 5$p Area"Akre Of 1545 acr lhcsp latom a•lb bansua',e lo43'a pr!OWS and is for reference Transverse Load Factor 1K1 4.2 only 'tee austro scexnderl a resp desQ.s and co'dlu'tooTkkni c4 l'icion loadrg candscre n+en OM bill ppe_A an]Nat.aWL4kT,aW other 5sOors CanJt 5110 the sip nr'cbcteor fir wow.' swnuUon. Pipe Body Performance Pipe Body Configuration( 5 oro OD 0.362 on) Wall S-135) Nominal 80%Inspection Class API Premium Class Pipe Tensile Strength otsi 712,100 560,800 560,800 Pipe Torsional Strengthn_.rl. 74.100 58.100 58,1G0 TJ/PipeBody Torsional Ratio 0.97 1.24 1.24 80%Pipe Torsional Strength n-h; 59.300 46.500 46.500 Burst p4t1 17.105 15.638 15,638 Nola Nom41v1 Burst Colapse p:,, 15.672 10.029 10.029 saa�/ed a1 e7s A Raw Pipe OD 1n,5.00() 4.855 4.855 per API. Wall Thickness n1 0.362 0.290 0.290 Nominal Pipe ID (mi 4276 4.276 4276 Cross Sectional Area of Pipe Body yl" 5.275 4.154 4.154 Cross Sectional Area of OD iln^21 19.635 18.514 18.514 Cross Sectional Area of ID 11'2, 14.360 14.360 14.360 Section Modulus i1,,,^35.708 4.476 4.476 glighPolar Section Modulus r003, 11.415 8-953 8.953 Page 53 Version 1 May, 2015 • • Milne Point Unit L-49 II Drilling Procedure Hilcorp Energy Company Operational Limits of Drill Pipe Connection ,GPDS50 Tool Joint OD ;,,,,.16.625 Tool Joint ID t„13.250 Tool Joint Specified 61^irri URI 120.000 Yield Strength G51 Pipe Body 80%Inspection Class Pipe Body OD ,,,,5 Wall Thickness ,„.10.362 Pipe Body Grade 1S-135 Combined Loading for Drill Pipe at Combined Loading for Drill Pipe at Maximum Make-up Torque= 43,100 in-it6, Minimum Make-up Torque= 36,100 inrbsr Operational Assembly ape Body Connecnen Man Operatorra Assembly P1pe Body Corner/ion Tor ue Max Tension Tension I Torque Max Tension mem Tension Ma+tenamn q Max Tension In-INS) II055 (Iba) (Ibtl ^l-,b, Inst :1061 (10s1 0 560,800 560,800 1.046.900 0 560.800 560.800 1,202,500 2,100 560,400 560.400 1,046.900 t700 560,500 560.500 1,202.500 4,200 559,300 559,300 1.046.900 3.400 559.800 559.800 1202.500 6,300 557.500 557,500 1,046,900 5,100 558.600 558.600 1.202.500 8.300 555.000 555.000 1.046.900 6.800 556.900 556.900 1.202.500 10,400 551.700 551,700 1.046.900 8.400 554.900 554.900 1,202.500 12,500 547.600 547,600 1.046.900 10.100 552.200 552200 1,202.500 14,600 542.800 542,800 1.046.900 11,800 549.100 549.100 1.202,500 16.700 537.100 537.100 1.046.900 13.500 545.400 545.400 1.202,500 18.800 530,600 530,600 1.046.900 15.200 541.200 541.200 1.202,500 20.800 523.600 523,600 1.046.900 16.900 536.500 536.500 1202.5000 22,900 515,400 515,400 1,046.900 18.600 531.300 531.300 1,202,500 25.000 506.200 506,200 1.046.900 20.300 525.400 525.400 1202,500 27,100 496.100 496,100 1.046.900 22.000 519,000 519.000 1.202,500 29.200 484,800 484,800 1.046.900 23.700 512.000 512.000 1,202,500 31,300 472.500 472,500 1,046.900 25,300 504,800 504.800 1.202,500 33.300 459.600 459.600 1.046.900 27.000 496.600 496.600 1.202.500 35,400 444,700 444,700 1,046.900 ' 28.700 487.600 487.600 1.202,500 37.500 428.400 428.400 1.046.90 30.400 477.900 477:230 1202.500 39,600 410.500 410,500 1.046.900 32.100 467,400 467.400 1.202,500 Operational drilling torque is limited by the Make-up Torque. Operational drilling torque is limited by the Make-up Torque. Connection Make-up Torque Range Make-up Torque Connection Max ,,.pn,Tension ,r,. Min MUT 36.100 1,202,500 36.900 1,229.200 37.700 1,243,600 4... 38.400 1,218,100 39.200 1,189,000 140.000 1,159,800 40.800 1,130,700 41.500 1,105,200 42,300 1,076,100 Max PAW 43,100 1,046,900 Page 54 Version 1 May, 2015 s Milne Point Unit L-49 Drilling Procedure Hilcorp Energy Company Connection Wear Table Connection GPDS50 Tool Joint GD ,,,,16.625 Tool Joint iD ,,,, 3.250 -cni Jo-t Specified Rt-ir,.r- 120.009 Yield Strength Connection Wear Tool Connection Max Ca-eche-Max Min MUT Connection Max Joint OD Torsional MUT Tersia Tension New OD Strength 6.625 71,800 43,100 1,046,900 35.900 1,195.900 6.562 71,800 43.100 1,034,900 35.900 1.208.700 ; , 6.499 71,800 43,100 1,022,600 35.900 1,222.400 6.435 71,800 43.100 1,009,800 35.900 1.237.500 6.372 71,200 42,700 1,008,100 35.600 1.245,200 6.309 68,000 40.800 1,057.300 34.000 1.207.700 6.246 64,800 38.900 1,104,800 32.400 1.169.800 6.183 61,700 37.000 1,150.400 30.800 1.131.300 6.12 58,600 35,200 1,190,900 29,300 1.096.100 6.056 55,500 33.300 1,232,300 27.800 1.060.800 Worn CO 5.993 52,800 31,500 1,227,200 26.300 1,024,600 5.93 49,600 29,800 1,187,100 24,800 987,900 Pipe Body Combined Loading Table (Torque-Tension) Plpe Bodi 80%Inspection Class Pipe Body OD ,h 15 Wall TNaness ,,,,0.362 Pipe Body Grade S-135 Pipe Body Torque 0 5.300 10,000 15800 21.100 26A00 31,700 37.000 42.300 47.500 52.800 58.100 two _ Pipe Body Max Tension 560800 558,400 551,400 539.600 522.500 .600 470,000 432.400 384,500 323,100 234.300 12.200 �,� Page 55 Version 1 May,2015 s a Hilcorp Energy Company Milne Point M Pt L Pad Plan MPL-49 MPL-49 (Well #1) Plan: MPL-49 wp3 Standard Proposal Report 08 June, 2015 MEM HALLIBURTON Sperry Drilling Services • • HALLIBURTON Project: Milne Point W®l DUALS:Pla°MPL-49 NAD 1927(NADCONCONOS) Alaska Zone 04 Site: M Pt L Pad G1mmdLevel: 17.00 1 011 9 Well: Plan MPL-49 ow-s *DAV Noting Fueling >atitmae Longitude slot Wellbore: MPL-49(Well#1) 0.00 0.00 6031591.24 545189.65 70129 49816 N 14913749664W -2000- Design: MPL-49 wp3 FORMATION TOP DETAILS _ No formation data is available -1500- -1000- -500- - it 0� - Start Build 3.00 CASING DETAILS 500- 500 TVD TVDSS MD Size Name ---- Start OLS 4.00 TFO 58.35 4172.38 4125.38 5856.42 9-5/8 9 5/8" 4171.99 4124.99 12374.30 5-1/2 5 1/2" 1000- 1090--" TE - - Start 1607_.72 hold at 1967.39 MD o, 1500- 1500 -_--N --- u't 5000 t 2000- EL _ Start DLS 5.00 TFO-99.59 0 - 2500 -- - 1 2500-_ 3000 - Start 500.00 hold at 5353.23 MD Start 199.58 hold at 6033.99 MD Start 1000.00 hold at 11374.30 MD m 3000- a6 I- - ob , - r Start DLS 5.00 TFO-0.72 Start DLS 5.00 TFO-179.23 - d0°p 3500- TD at 12374.30 bh� o - Start 5100.00 hold at 6274.30 MD h i Ni i ouff V 4000_ `fl' _.-- ---- 4500- o $ o g c ° $ 0 0 o c o a 9 5/8" • i 5 1/2" 5000- Well 1 Heel Well Toe 5500 6000 1111111111111111111111111111111111111111111111111111111111111111l111111111111111111111111111111111111111I1111HI1 111111I1I -2000 -1500 -1000 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 8000 8500 7000 7500 8000 8500 9000 9500 10000 Vertical Section at 136.86°(1250 usft/in) 11 Uncoil) I • • • HALLIBURTON Project: Milne Point WELL DETAILS:Plat MPL49 SAW',,1,creamsSite: M Pt L Pad Gto ad Lend: 17.00 Well: Plan MPL-49 +N/s+E-W Northing Fasting Letittde Longitude Slot 2000- Wellbore: MPL-49(Well#1) 0.00 0.00 6031591.24 545189.65 70°2849.816 N 149°3749.664W Plan. MPL-49 wp3 REFERENCE INFORMATION 1500- Co-ordinate(WE)Reference:Well Plan MPL-49,True Noon Vertical(TVD)Reference:As-Staked MPL-49 @ 47.Wusit Measured Depth Reference:As-Staked MPL-49®47.Wusfl Calculation Method:Minimum Curvature 1000- _ CASING DETAILS 500- ND TVDSS MD Size Name 4172.38 4125.38 5858.42 9-5/8 95/8" tiS _ _Start Build 3.00 4171.99 4124.99 12374.30 5-1/2 5 1/2" __ /so, _-StatDLS 4.0018059.35 -500_ 2� ltd Stat 1607.72 hold at 1967.39 MD -1000- Start DL45.00 TFO-99.59 -1500- _ )15°�p Start 500.00 hold at 5353.23 MD •2000- 1TT Start DIS 5.00 TFO-0.72 • Start 199.56 hold at 6033.99 MD • •2500- !Well l Heel F-- .c - --__________StatDIS 5.00 LPO-179.23 1h - 9 5/8" Start 5100.00 hold at 6274.30 MD +-3000- -3500 X5011- Start 000 CO hold at 11374.30 MD 5000- - TD at 12374.30 5500- ' Vi IWdl l Toe -6000- 5117^ 5as •6500- 9 T M Azimuths to True North -7000- Magnetic North:19.00' Magnetic Field 7500- Strength:57506.lenT Dip Angle:81.08' Date:7/26/2015 Model:BGGM2015 -8000- III1(1111(11 IMI 1111111 1111 111111111111111111 11i 111 1111111111111111111111111111111111 I I111111 11(1111111 I111I 11(1111(11 I 1(1111111111111111 111(1 -4500 -4000 -3500 -3000 -2500 -2000 -1500 -1000 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 West(-)/East(+)(1500 ld3Win) ) 411 i.ri'{r I • Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan MPL-49 Company: Hilcorp Energy Company TVD Reference: As-Staked MPL-49 @ 47.00usft Project: Milne Point MD Reference: As-Staked MPL-49 @ 47.00usft Site: M Pt L Pad North Reference: True Well: Plan MPL-49 Survey Calculation Method: Minimum Curvature Wellbore: MPL-49(Well#1) Design: MPL-49 wp3 Project Milne Point,ACT,MILNE POINT Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site M Pt L Pad,TR-13-10 Site Position: Northing: 6,029,799.28 usft Latitude: 70°29'32.230 N From: Map Easting: 544,529.55 usft Longitude: 149°38'9.412 W Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.34 ° Well Plan MPL-49 Well Position +NI-S 0.00 usft Northing: 6,031,591.24 usft Latitude: 70°29'49.816 N +E/-W 0.00 usft Easting: 545,189.65 usft Longitude: 149°37'49.664 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 17.00 usft Wellbore MPL-49(Well#1) Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (') (nT) BGGM2015 7/26/2015 19.00 81.08 57,506 Design MPL-49 wp3 Audit Notes: Version: Phase: PLAN Tie On Depth: 30.00 Vertical Section: Depth From(TVD) +N/-S +El-W Direction (usft) (usft) (usft) (°) 30.00 0.00 0.00 136.86 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (usft) (") (°) (usft) usft (usft) (usft) (1100usft) (°/100usft) (1100usft) (°) 30.00 0.00 0.00 30.00 -17.00 0.00 0.00 0.00 0.00 0.00 0.00 800.00 0.00 0.00 800.00 753.00 0.00 0.00 0.00 0.00 0.00 0.00 1,100.00 9.00 170.00 1,098.77 1,051.77 -23.16 4.08 3.00 3.00 0.00 170.00 1,967.39 40.06 218.84 1,883.17 1,836.17 -316.41 -164.37 4.00 3.58 5.63 58.35 3,575.12 40.06 218.84 3,113.62 3,066.62 -1,122.42 -813.29 0.00 0.00 0.00 0.00 5,353.23 83.00 122.17 4,111.06 4,064.06 -2,280.17 -322.53 5.00 2.41 -5.44 -99.59 5,853.23 83.00 122.17 4,171.99 4,124.99 -2,544.40 97.55 0.00 0.00 0.00 0.00 6,033.99 92.04 122.06 4,179.81 4,132.81 -2,640.30 250.35 5.00 5.00 -0.06 -0.72 6,233.55 92.04 122.06 4,172.72 4,125.72 -2,746.15 419.38 0.00 0.00 0.00 0.00 6,274.30 90.00 122.03 4,171.99 4,124.99 -2,767.77 453.91 5.00 -5.00 -0.07 -179.23 11,374.30 90.00 122.03 4,171.99 4,124.99 -5,472.62 4,777.54 0.00 0.00 0.00 0.00 12,374.30 90.00 122.03 4,171.99 4,124.99 -6,002.98 5,625.31 0.00 0.00 0.00 0.00 6/8/2015 7:24:51PM Page 2 COMPASS 5000.1 Build 73 s s Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan MPL-49 Company: Hilcorp Energy Company TVD Reference: As-Staked MPL-49 @ 47.00usft Project: Mine Point MD Reference: As-Staked MPL-49 @ 47.00usft Site: M Pt L Pad North Reference: True Well: Plan MPL-49 Survey Calculation Method: Minimum Curvature Wellbore: MPL-49(Well#1) Design: MPL-49 wp3 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (^) (*) (usft) usft (usft) (usft) (usft) (usft) -17.00 30.00 0.00 0.00 30.00 -17.00 0.00 0.00 6,031,591.24 545,189.65 0.00 0.00 100.00 0.00 0.00 100.00 53.00 0.00 0.00 6,031,591.24 545,189.65 0.00 0.00 200.00 0.00 0.00 200.00 153.00 0.00 0.00 6,031,591.24 545,189.65 0.00 0.00 300.00 0.00 0.00 300.00 253.00 0.00 0.00 6,031,591.24 545,189.65 0.00 0.00 400.00 0.00 0.00 400.00 353.00 0.00 0.00 6,031,591.24 545,189.65 0.00 0.00 500.00 0.00 0.00 500.00 453.00 0.00 0.00 6,031,591.24 545,189.65 0.00 0.00 600.00 0.00 0.00 600.00 553.00 0.00 0.00 6,031,591.24 545,189.65 0.00 0.00 700.00 0.00 0.00 700.00 653.00 0.00 0.00 6,031,591.24 545,189.65 0.00 0.00 800.00 0.00 0.00 800.00 753.00 0.00 0.00 6,031,591.24 545,189.65 0.00 0.00 900.00 3.00 170.00 899.95 852.95 -2.58 0.45 6,031,588.67 545,190.12 3.00 2.19 1,000.00 6.00 170.00 999.63 952.63 -10.30 1.82 6,031,580.95 545,191.53 3.00 8.76 1,100.00 9.00 170.00 1,098.77 1,051.77 -23.16 4.08 6,031,568.11 545,193.87 3.00 19.69 1,200.00 11.61 187.17 1,197.17 1,150.17 -40.85 4.19 6,031,550.42 545,194.08 4.00 32.67 1,300.00 14.84 197.56 1,294.52 1,247.52 -63.04 -0.93 6,031,528.20 545,189.10 4.00 45.36 1,400.00 18.37 204.17 1,390.34 1,343.34 -89.64 -11.25 6,031,501.54 545,178.95 4.00 57.72 1,500.00 22.06 208.67 1,484.17 1,437.17 -120.51 -26.72 6,031,470.59 545,163.67 4.00 69.66 1,600.00 25.84 211.92 1,575.55 1,528.55 -155.49 -47.25 6,031,435.48 545,143.35 4.00 81.15 1,700.00 29.67 214.39 1,664.04 1,617.04 -194.42 -72.76 6,031,396.40 545,118.08 4.00 92.12 1,800.00 33.54 216.34 1,749.19 1,702.19 -237.12 -103.12 6,031,353.52 545,087.98 4.00 102.51 1,900.00 37.43 217.92 1,830.61 1,783.61 -283.36 -138.18 6,031,307.07 545,053.21 4.00 112.28 1,967.39 40.06 218.84 1,883.17 1,836.17 -316.41 -164.37 6,031,273.86 545,027.22 4.00 118.49 2,000.00 40.06 218.84 1,908.12 1,861.12 -332.76 -177.53 6,031,257.44 545,014.16 0.00 121.42 2,100.00 40.06 218.84 1,984.66 1,937.66 -382.90 -217.89 6,031,207.06 544,974.11 0.00 130.40 2,200.00 40.06 218.84 2,061.19 2,014.19 -433.03 -258.26 6,031,156.69 544,934.06 0.00 139.39 2,300.00 40.06 218.84 2,137.72 2,090.72 -483.16 -298.62 6,031,106.32 544,894.00 0.00 148.37 2,400.00 40.06 218.84 2,214.26 2,167.26 -533.30 -338.98 6,031,055.94 544,853.95 0.00 157.35 2,500.00 40.06 218.84 2,290.79 2,243.79 -583.43 -379.35 6,031,005.57 544,813.90 0.00 166.33 2,600.00 40.06 218.84 2,367.33 2,320.33 -633.56 -419.71 6,030,955.20 544,773.84 0.00 175.32 2,700.00 40.06 218.84 2,443.86 2,396.86 -683.70 -460.07 6,030,904.83 544,733.79 0.00 184.30 2,800.00 40.06 218.84 2,520.39 2,473.39 -733.83 -500.43 6,030,854.45 544,693.73 0.00 193.28 2,900.00 40.06 218.84 2,596.93 2,549.93 -783.96 -540.80 6,030,804.08 544,653.68 0.00 202.26 3,000.00 40.06 218.84 2,673.46 2,626.46 -834.10 -581.16 6,030,753.71 544,613.63 0.00 211.25 3,100.00 40.06 218.84 2,750.00 2,703.00 -884.23 -621.52 6,030,703.33 544,573.57 0.00 220.23 3,200.00 40.06 218.84 2,826.53 2,779.53 -934.37 -661.89 6,030,652.96 544,533.52 0.00 229.21 3,300.00 40.06 218.84 2,903.06 2,856.06 -984.50 -702.25 6,030,602.59 544,493.47 0.00 238.19 3,400.00 40.06 218.84 2,979.60 2,932.60 -1,034.63 -742.61 6,030,552.21 544,453.41 0.00 247.18 3,500.00 40.06 218.84 3,056.13 3,009.13 -1,084.77 -782.98 6,030,501.84 544,413.36 0.00 256.16 3,575.12 40.06 218.84 3,113.62 3,066.62 -1,122.42 -813.29 6,030,464.00 544,383.27 0.00 262.90 3,600.00 39.87 216.92 3,132.69 3,085.69 -1,135.04 -823.11 6,030,451.33 544,373.54 5.00 265.40 3,700.00 39.42 209.12 3,209.74 3,162.74 -1,188.44 -857.84 6,030,397.73 544,339.14 5.00 280.62 3,800.00 39.51 201.25 3,286.99 3,239.99 -1,245.86 -884.83 6,030,340.15 544,312.50 5.00 304.06 3,900.00 40.11 193.49 3,363.86 3,316.86 -1,306.87 -903.88 6,030,279.03 544,293.82 5.00 335.55 4,000.00 41.22 186.00 3,439.76 3,392.76 -1,371.00 -914.85 6,030,214.84 544,283.24 5.00 374.85 4,100.00 42.79 178.91 3,514.11 3,467.11 -1,437.77 -917.65 6,030,148.06 544,280.85 5.00 421.65 4,200.00 44.77 172.27 3,586.35 3,539.35 -1,506.66 -912.26 6,030,079.21 544,286.65 5.00 475.61 6/8/2015 7:24:51PM Page 3 COMPASS 5000.1 Build 73 • • Halliburton HOLLI B U R TO N Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan MPL-49 Company: Hilcorp Energy Company TVD Reference: As-Staked MPL-49 @ 47.00usft Project: Milne Point MD Reference: As-Staked MPL-49 @ 47.00usft Site: M Pt L Pad North Reference: True Well: Plan MPL-49 Survey Calculation Method: Minimum Curvature Wellbore: MPL-49(Well#1) Design: MPL-49 wp3 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (^) (usft) usft (usft) (usft) (usft) (usft) 3,608.92 4,300.00 47.10 166.11 3,655.92 3,608.92 -1,577.15 -898.72 6,030,008.81 544,300.62 5.00 536.30 4,400.00 49.75 160.43 3,722.31 3,675.31 -1,648.71 -877.14 6,029,937.39 544,322.64 5.00 603.28 4,500.00 52.64 155.20 3,785.00 3,738.00 -1,720.79 -847.67 6,029,865.50 544,352.54 5.00 676.02 4,600.00 55.75 150.37 3,843.51 3,796.51 -1,792.84 -810.54 6,029,793.68 544,390.10 5.00 753.98 4,700.00 59.04 145.90 3,897.41 3,850.41 -1,864.32 -766.05 6,029,722.48 544,435.03 5.00 836.57 4,800.00 62.47 141.73 3,946.27 3,899.27 -1,934.68 -714.51 6,029,652.44 544,486.98 5.00 923.14 4,900.00 66.02 137.81 3,989.74 3,942.74 -2,003.38 -656.33 6,029,584.11 544,545.57 5.00 1,013.05 5,000.00 69.66 134.11 4,027.47 3,980.47 -2,069.90 -591.95 6,029,517.98 544,610.35 5.00 1,105.62 5,100.00 73.37 130.58 4,059.18 4,012.18 -2,133.74 -521.86 6,029,454.58 544,680.82 5.00 1,200.12 5,200.00 77.14 127.19 4,084.63 4,037.63 -2,194.40 -446.59 6,029,394.38 544,756.45 5.00 1,295.86 5,300.00 80.96 123.89 4,103.63 4,056.63 -2,251.44 -366.72 6,029,337.84 544,836.66 5.00 1,392.09 5,353.23 83.00 122.17 4,111.06 4,064.06 -2,280.17 -322.53 6,029,309.38 544,881.02 5.00 1,443.27 5,400.00 83.00 122.17 4,116.76 4,069.76 -2,304.88 -283.24 6,029,284.91 544,920.46 0.00 1,488.17 5,500.00 83.00 122.17 4,128.94 4,081.94 -2,357.73 -199.22 6,029,232.58 545,004.79 0.00 1,584.18 5,600.00 83.00 122.17 4,141.13 4,094.13 -2,410.57 -115.20 6,029,180.25 545,089.11 0.00 1,680.19 5,700.00 83.00 122.17 4,153.32 4,106.32 -2,463.42 -31.19 6,029,127.92 545,173.44 0.00 1,776.20 5,800.00 83.00 122.17 4,165.50 4,118.50 -2,516.27 52.83 6,029,075.59 545,257.77 0.00 1,872.21 5,853.23 83.00 122.17 4,171.99 4,124.99 -2,544.40 97.55 6,029,047.73 545,302.66 0.00 1,923.32 5,856.42 83.16 122.17 4,172.38 4,125.38 -2,546.08 100.23 6,029,046.06 545,305.35 5.00 1,926.38 9 5/8" 5,900.00 85.34 122.14 4,176.74 4,129.74 -2,569.16 136.94 6,029,023.21 545,342.19 5.00 1,968.32 6,000.00 90.34 122.08 4,180.51 4,133.51 -2,622.26 221.55 6,028,970.63 545,427.12 5.00 2,064.92 6,033.99 92.04 122.06 4,179.81 4,132.81 -2,640.30 250.35 6,028,952.77 545,456.02 5.00 2,097.78 6,100.00 92.04 122.06 4,177.46 4,130.46 -2,675.31 306.26 6,028,918.10 545,512.14 0.00 2,161.56 6,200.00 92.04 122.06 4,173.91 4,126.91 -2,728.36 390.96 6,028,865.58 545,597.15 0.00 2,258.18 6,233.55 92.04 122.06 4,172.72 4,125.72 -2,746.15 419.38 6,028,847.96 545,625.67 0.00 2,290.60 6,274.30 90.00 122.03 4,171.99 4,124.99 -2,767.77 453.91 6,028,826.55 545,660.33 5.00 2,329.98 6,300.00 90.00 122.03 4,171.99 4,124.99 -2,781.40 475.70 6,028,813.06 545,682.20 0.00 2,354.83 6,400.00 90.00 122.03 4,171.99 4,124.99 -2,834.43 560.47 6,028,760.54 545,767.29 0.00 2,451.49 6,500.00 90.00 122.03 4,171.99 4,124.99 -2,887.47 645.25 6,028,708.03 545,852.38 0.00 2,548.16 6,600.00 90.00 122.03 4,171.99 4,124.99 -2,940.51 730.03 6,028,655.51 545,937.47 0.00 2,644.83 6,700.00 90.00 122.03 4,171.99 4,124.99 -2,993.54 814.81 6,028,603.00 546,022.56 0.00 2,741.50 6,800.00 90.00 122.03 4,171.99 4,124.99 -3,046.58 899.58 6,028,550.48 546,107.65 0.00 2,838.17 6,900.00 90.00 122.03 4,171.99 4,124.99 -3,099.62 984.36 6,028,497.97 546,192.74 0.00 2,934.84 7,000.00 90.00 122.03 4,171.99 4,124.99 -3,152.65 1,069.14 6,028,445.45 546,277.83 0.00 3,031.51 7,100.00 90.00 122.03 4,171.99 4,124.99 -3,205.69 1,153.91 6,028,392.94 546,362.92 0.00 3,128.18 7,200.00 90.00 122.03 4,171.99 4,124.99 -3,258.73 1,238.69 6,028,340.42 546,448.01 0.00 3,224.84 7,300.00 90.00 122.03 4,171.99 4,124.99 -3,311.76 1,323.47 6,028,287.91 546,533.10 0.00 3,321.51 7,400.00 90.00 122.03 4,171.99 4,124.99 -3,364.80 1,408.24 6,028,235.39 546,618.19 0.00 3,418.18 7,500.00 90.00 122.03 4,171.99 4,124.99 -3,417.83 1,493.02 6,028,182.88 546,703.28 0.00 3,514.85 7,600.00 90.00 122.03 4,171.99 4,124.99 -3,470.87 1,577.80 6,028,130.36 546,788.37 0.00 3,611.52 7,700.00 90.00 122.03 4,171.99 4,124.99 -3,523.91 1,662.58 6,028,077.85 546,873.45 0.00 3,708.19 7,800.00 90.00 122.03 4,171.99 4,124.99 -3,576.94 1,747.35 6,028,025.33 546,958.54 0.00 3,804.86 7,900.00 90.00 122.03 4,171.99 4,124.99 -3,629.98 1,832.13 6,027,972.82 547,043.63 0.00 3,901.53 8,000.00 90.00 122.03 4,171.99 4,124.99 -3,683.02 1,916.91 6,027,920.31 547,128.72 0.00 3,998.20 6/8/2015 7:24:51PM Page 4 COMPASS 5000.1 Build 73 0 • Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan MPL-49 Company: Hilcorp Energy Company TVD Reference: As-Staked MPL-49 @ 47.00usft Project: Milne Point MD Reference: As-Staked MPL-49 @ 47.00usft Site: M Pt L Pad North Reference: True Well: Plan MPL-49 Survey Calculation Method: Minimum Curvature Wellbore: MPL-49(Well#1) Design: MPL-49 wp3 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 4,124.99 8,100.00 90.00 122.03 4,171.99 4,124.99 -3,736.05 2,001.68 6,027,867.79 547,213.81 0.00 4,094.86 8,200.00 90.00 122.03 4,171.99 4,124.99 -3,789.09 2,086.46 6,027,815.28 547,298.90 0.00 4,191.53 8,300.00 90.00 122.03 4,171.99 4,124.99 -3,842.12 2,171.24 6,027,762.76 547,383.99 0.00 4,288.20 8,400.00 90.00 122.03 4,171.99 4,124.99 -3,895.16 2,256.02 6,027,710.25 547,469.08 0.00 4,384.87 8,500.00 90.00 122.03 4,171.99 4,124.99 -3,948.20 2,340.79 6,027,657.73 547,554.17 0.00 4,481.54 8,600.00 90.00 122.03 4,171.99 4,124.99 -4,001.23 2,425.57 6,027,605.22 547,639.26 0.00 4,578.21 8,700.00 90.00 122.03 4,171.99 4,124.99 -4,054.27 2,510.35 6,027,552.70 547,724.35 0.00 4,674.88 8,800.00 90.00 122.03 4,171.99 4,124.99 -4,107.31 2,595.12 6,027,500.19 547,809.44 0.00 4,771.55 8,900.00 90.00 122.03 4,171.99 4,124.99 -4,160.34 2,679.90 6,027,447.67 547,894.53 0.00 4,868.22 9,000.00 90.00 122.03 4,171.99 4,124.99 -4,213.38 2,764.68 6,027,395.16 547,979.62 0.00 4,964.88 9,100.00 90.00 122.03 4,171.99 4,124.99 -4,266.42 2,849.45 6,027,342.64 548,064.71 0.00 5,061.55 9,200.00 90.00 122.03 4,171.99 4,124.99 -4,319.45 2,934.23 6,027,290.13 548,149.80 0.00 5,158.22 9,300.00 90.00 122.03 4,171.99 4,124.99 -4,372.49 3,019.01 6,027,237.61 548,234.89 0.00 5,254.89 9,400.00 90.00 122.03 4,171.99 4,124.99 -4,425.52 3,103.79 6,027,185.10 548,319.98 0.00 5,351.56 9,500.00 90.00 122.03 4,171.99 4,124.99 -4,478.56 3,188.56 6,027,132.58 548,405.07 0.00 5,448.23 9,600.00 90.00 122.03 4,171.99 4,124.99 -4,531.60 3,273.34 6,027,080.07 548,490.16 0.00 5,544.90 9,700.00 90.00 122.03 4,171.99 4,124.99 -4,584.63 3,358.12 6,027,027.55 548,575.25 0.00 5,641.57 9,800.00 90.00 122.03 4,171.99 4,124.99 -4,637.67 3,442.89 6,026,975.04 548,660.34 0.00 5,738.23 9,900.00 90.00 122.03 4,171.99 4,124.99 -4,690.71 3,527.67 6,026,922.52 548,745.43 0.00 5,834.90 10,000.00 90.00 122.03 4,171.99 4,124.99 -4,743.74 3,612.45 6,026,870.01 548,830.52 0.00 5,931.57 10,100.00 90.00 122.03 4,171.99 4,124.99 -4,796.78 3,697.22 6,026,817.49 548,915.61 0.00 6,028.24 10,200.00 90.00 122.03 4,171.99 4,124.99 -4,849.81 3,782.00 6,026,764.98 549,000.70 0.00 6,124.91 10,300.00 90.00 122.03 4,171.99 4,124.99 -4,902.85 3,866.78 6,026,712.46 549,085.78 0.00 6,221.58 10,400.00 90.00 122.03 4,171.99 4,124.99 -4,955.89 3,951.56 6,026,659.95 549,170.87 0.00 6,318.25 10,500.00 90.00 122.03 4,171.99 4,124.99 -5,008.92 4,036.33 6,026,607.44 549,255.96 0.00 6,414.92 10,600.00 90.00 122.03 4,171.99 4,124.99 -5,061.96 4,121.11 6,026,554.92 549,341.05 0.00 6,511.59 10,700.00 90.00 122.03 4,171.99 4,124.99 -5,115.00 4,205.89 6,026,502.41 549,426.14 0.00 6,608.25 10,800.00 90.00 122.03 4,171.99 4,124.99 -5,168.03 4,290.66 6,026,449.89 549,511.23 0.00 6,704.92 10,900.00 90.00 122.03 4,171.99 4,124.99 -5,221.07 4,375.44 6,026,397.38 549,596.32 0.00 6,801.59 11,000.00 90.00 122.03 4,171.99 4,124.99 -5,274.11 4,460.22 6,026,344.86 549,681.41 0.00 6,898.26 11,100.00 90.00 122.03 4,171.99 4,124.99 -5,327.14 4,545.00 6,026,292.35 549,766.50 0.00 6,994.93 11,200.00 90.00 122.03 4,171.99 4,124.99 -5,380.18 4,629.77 6,026,239.83 549,851.59 0.00 7,091.60 11,300.00 90.00 122.03 4,171.99 4,124.99 -5,433.21 4,714.55 6,026,187.32 549,936.68 0.00 7,188.27 11,374.30 90.00 122.03 4,171.99 4,124.99 -5,472.62 4,777.54 6,026,148.30 549,999.90 0.00 7,260.09 11,400.00 90.00 122.03 4,171.99 4,124.99 -5,486.25 4,799.33 6,026,134.80 550,021.77 0.00 7,284.94 11,500.00 90.00 122.03 4,171.99 4,124.99 -5,539.29 4,884.10 6,026,082.29 550,106.86 0.00 7,381.60 11,600.00 90.00 122.03 4,171.99 4,124.99 -5,592.32 4,968.88 6,026,029.77 550,191.95 0.00 7,478.27 11,700.00 90.00 122.03 4,171.99 4,124.99 -5,645.36 5,053.66 6,025,977.26 550,277.04 0.00 7,574.94 11,800.00 90.00 122.03 4,171.99 4,124.99 -5,698.40 5,138.43 6,025,924.74 550,362.13 0.00 7,671.61 11,900.00 90.00 122.03 4,171.99 4,124.99 -5,751.43 5,223.21 6,025,872.23 550,447.22 0.00 7,768.28 12,000.00 90.00 122.03 4,171.99 4,124.99 -5,804.47 5,307.99 6,025,819.71 550,532.31 0.00 7,864.95 12,100.00 90.00 122.03 4,171.99 4,124.99 -5,857.50 5,392.77 6,025,767.20 550,617.40 0.00 7,961.62 12,200.00 90.00 122.03 4,171.99 4,124.99 -5,910.54 5,477.54 6,025,714.68 550,702.49 0.00 8,058.29 12,300.00 90.00 122.03 4,171.99 4,124.99 -5,963.58 5,562.32 6,025,662.17 550,787.58 0.00 8,154.96 12,374.30 90.00 122.03 4,171.99 4,124.99 -6,002.98 5,625.31 6,025,623.15 550,850.80 0.00 8,226.78 6/8/2015 7:24:51 PM Page 5 COMPASS 5000.1 Build 73 a • Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan MPL-49 Company: Hilcorp Energy Company TVD Reference: As-Staked MPL-49 @ 47.00usft Project: Milne Point MD Reference: As-Staked MPL-49 @ 47.00usft Site: M Pt L Pad North Reference: True Well: Plan MPL-49 Survey Calculation Method: Minimum Curvature Wellbore: MPL-49(Well#1) Design: MPL-49 wp3 Targets Target Name •hit/miss target Dip Angle Dip Dir. ND +N/-S +El-W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) Well 1 Toe 0.00 0.35 4,171.99 -5,472.62 4,777.54 6,026,148.30 549,999.90 -plan hits target center -Circle(radius 100.00) Well 2 Heel 0.00 0.35 4,147.00 -3,278.16 -430.57 6,028,310.84 544,779.06 -plan misses target center by 902.48usft at 5794.25usft MD(4164.80 TVD,-2513.23 N,48.00 E) -Circle(radius 100.00) MPL-50 wp3 Toe 0.00 0.35 4,027.00 -8,566.16 1,993.91 6,023,038.20 547,235.40 -plan misses target center by 4101.51 usft at 10655.12usft MD(4171.99 TVD,-5091.19 N,4167.84 E) -Circle(radius 100.00) MPL-50 wp3 Heel 0.00 0.35 4,027.00 -5,748.30 -1,992.23 6,025,831.50 543,232.60 -plan misses target center by 3827.10usft at 5772.96usft MD(4162.21 TVD,-2501.97 N,30.11 E) -Circle(radius 100.00) Well 2 Toe 0.00 0.35 4,147.00 -6,419.67 4,224.62 6,025,198.00 549,452.80 -plan misses target center by 1096.41 usft at 11407.83usft MD(4171.99 TVD,-5490.40 N,4805.96 E) -Circle(radius 100.00) Well 3 Toe 0.00 0.35 4,127.00 -7,177.92 3,413.51 6,024,434.90 548,646.40 -plan misses target center by 2169.60usft at 11122.35usft MD(4171.99 TVD,-5338.99 N,4563.94 E) -Circle(radius 100.00) Well 1 Heel 0.00 0.35 4,171.99 -2,544.40 97.55 6,029,047.73 545,302.66 -plan hits target center -Circle(radius 100.00) Well 4 Toe 0.00 0.35 4,067.00 -8,067.54 2,889.74 6,023,542.20 548,128.10 -plan misses target center by 3202.84usft at 11150.13usft MD(4171.99 TVD,-5353.73 N,4587.50 E) -Circle(radius 100.00) Well 3 Heel 0.00 0.35 4,127.00 -3,968.45 -1,045.40 6,027,616.90 544,168.50 -plan misses target center by 1814.06usft at 5640.05usft MD(4146.01 TVD,-2431.74 N,-81.56 E) -Circle(radius 100.00) Well 4 Heel 0.00 0.35 4,067.00 -4,887.04 -1,540.54 6,026,695.40 543,679.00 -plan misses target center by 2856.49usft at 5702.18usft MD(4153.58 TVD,-2464.57 N,-29.36 E) -Circle(radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (') P9 5,856.42 4,172.38 95/8" 9-5/8 12-1/4 12,374.30 4,171.99 51/2" 5-1/2 8-1/2 6/8/2015 7:24:51PM Page 6 COMPASS 5000.1 Build 73 ! • Hilcorp Energy Company Milne Point M Pt L Pad Plan MPL-49 MPL-49(Well#1) MPL-49 wp3 Sperry Drilling Services Clearance Summary Anticollision Report 08 June,2015 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: M Pt L Pad-Plan MPL-49-MPL-49(Well#1)-MPL-49 wp3 Well Coordinates: 6,031,591.24 N,545,189.65 E(70°29'49.82"N,149°37'49.66"W) Datum Height:As-Staked MPL-49 @ 47.00usft Scan Range: 0.00 to 12,374.30 usft.Measured Depth. Scan Radius is 1,434.43 usft. Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build: 73 Scan Type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Scan Type: 25.00 d'r HALLIBURTON Sperry Drilling Services • Hilcorp Energy Company HALLIBURTON Mine Point Anticollision Report for Plan MPL-49-MPL-49 wp3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design:M Pt L Pad-Plan MPL-49-MPL-49(Well#1)-MPL-49 wp3 Scan Range:0.00 to 12,374.30 usft.Measured Depth. Scan Radius is 1,434.43 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation Is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft M Pt L Pad MPL-01-MPL-01-MPL-01 1,300.00 429.43 1,300.00 400.26 1,303.66 14.720 Clearance Factor Pass- MPL-01-MPL-01-MPL-01 1,950.00 349.27 1,950.00 331.69 1,880.15 19.867 Ellipse Separation Pass- MPL-01-MPL-01-MPL-01 1,951.59 349.27 1,951.59 331.69 1,881.37 19.873 Centre Distance Pass- MPL-01-MPL-01A-MPL-01A 1,300.00 429.43 1,300.00 400.26 1,303.66 14.720 Clearance Factor Pass- MPL-01-MPL-01A-MPL-01A 1,950.00 349.27 1,950.00 331.69 1,880.15 19.867 Ellipse Separation Pass- MPL-01-MPL-01A-MPL-01A 1,951.59 349.27 1,951.59 331.69 1,881.37 19.873 Centre Distance Pass- MPL-01-MPL-01A-Plan#3 1,300.00 429.43 1,300.00 400.26 1,303.66 14.720 Clearance Factor Pass- MPL-01-MPL-01A-Plan#3 1,950.00 349.27 1,950.00 331.69 1,880.15 19.867 Ellipse Separation Pass- MPL-01-MPL-01A-Plan#3 1,951.59 349.27 1,951.59 331.69 1,881.37 19.873 Centre Distance Pass- MPL-02-MPL-02-MPL-02 2,009.80 232.92 2,009.80 215.54 1,924.99 13.404 Ellipse Separation Pass- MPL-02-MPL-02-MPL-02 2,075.00 236.62 2,075.00 218.60 1,975.32 13.132 Clearance Factor Pass- MPL-02-MPL-02A-MPL-02A 2,009.80 232.92 2,009.80 215.82 1,924.99 13.624 Ellipse Separation Pass- MPL-02-MPL-02A-MPL-02A 2,075.00 236.62 2,075.00 218.88 1,975.32 13.340 Clearance Factor Pass- MPL-02-MPL-02AL1-MPL-02AL1 2,009.80 232.92 2,009.80 215.84 1,924.99 13.641 Ellipse Separation Pass- MPL-02-MPL-02AL1-MPL-02AL1 2,075.00 236.62 2,075.00 218.90 1,975.32 13.356 Clearance Factor Pass- MPL-02-MPL-02AL2-MPL-02AL2 2,009.80 232.92 2,009.80 215.54 1,924.99 13.404 Ellipse Separation Pass- MPL-02-MPL-02AL2-MPL-02AL2 2,075.00 236.62 2,075.00 218.60 1,975.32 13.132 Clearance Factor Pass- MPL-02-MPL-02APB1-MPL-02APB1 2,009.80 232.92 2,009.80 215.54 1,924.99 13.404 Ellipse Separation Pass- MPL-02-MPL-02APB1-MPL-02APB1 2,075.00 236.62 2,075.00 218.60 1,975.32 13.132 Clearance Factor Pass- MPL-02-MPL-02APB2-MPL-02APB2 2,009.80 232.92 2,009.80 215.54 1,924.99 13.404 Ellipse Separation Pass- MPL-02-MPL-02APB2-MPL-02APB2 2,075.00 236.62 2,075.00 218.60 1,975.32 13.132 Clearance Factor Pass- MPL-04-MPL-04-MPL-04 1,025.52 295.60 1,02552 286.79 1,014.70 33.553 Centre Distance Pass- MPL-04-MPL-04-MPL-04 1,050.00 295.73 1,050.00 286.77 1,037.21 33.039 Ellipse Separation Pass- MPL-04-MPL-04-MPL-04 1,375.00 322.30 1,375.00 311.40 1,299.71 29.577 Clearance Factor Pass- MPL-05-MPL-05-MPL-05 1,358.29 194.62 1,358.29 183.66 1,355.62 17.753 Ellipse Separation Pass- MPL-05-MPL-05-MPL-05 1,450.00 199.44 1,450.00 187.80 1,430.49 17.128 Clearance Factor Pass- MPL-06-MPL-06-MPL-06 1,604.40 83.64 1,604.40 70.55 1,624.36 6.388 Clearance Factor Pass- MPL-07-MPL-07-MPL-07 30.00 28.98 30.00 28.07 39.00 31.779 Centre Distance Pass- 08 June,2015- 19:05 Page 2 of 7 COMPASS / • • Hilcorp Energy Company HALLIBURTON Mune Point Anticollision Report for Plan MPL-49-MPL-49 wp3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design:M Pt L Pad-Plan MPL-49-MPL-49(Well 41)-MPL-49 wp3 Scan Range: 0.00 to 12,374.30 usft.Measured Depth. Scan Radius Is 1,434.43 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft MPL-07-MPL-07-MPL-07 400.00 30.56 400.00 26.31 408.74 7.202 Ellipse Separation Pass- MPL-07-MPL-07-MPL-07 600.00 36.32 600.00 30.10 607.11 5.839 Clearance Factor Pass- MPL-08-MPL-08-MPL-08 30.00 209.89 30.00 208.98 32.00 230.177 Centre Distance Pass- MPL-08-MPL-08-MPL-08 475.00 213.58 475.00 208.61 474.94 43.006 Ellipse Separation Pass- MPL-08-MPL-08-MPL-08 1,000.00 231.71 1,000.00 223.15 993.57 27.052 Clearance Factor Pass- MPL-09-MPL-09-MPL-09 805.84 148.11 805.84 140.55 81528 19.605 Centre Distance Pass- MPL-09-MPL-09-MPL-09 825.00 14820 825.00 140.54 834.40 19.345 Ellipse Separation Pass- MPL-09-MPL-09-MPL-09 1,000.00 157.54 1,000.00 148.92 1,008.89 18.286 Clearance Factor Pass- MPL-09-MPL-09A-MPL-09A 805.84 148.11 805.84 140.86 815.28 20.422 Centre Distance Pass- MPL-09-MPL-09A-MPL-09A 825.00 148.20 825.00 140.84 834.40 20.140 Ellipse Separation Pass- MPL-09-MPL-09A-MPL-09A 1,025.00 160.12 1,025.00 151.67 1,033.69 18.948 Clearance Factor Pass- MPL-09-MPL-09APB1-MPL-09APB1 805.84 148.11 805.84 140.55 815.28 19.605 Centre Distance Pass- MPL-09-MPL-09APB1-MPL-09APB1 825.00 148.20 825.00 140.54 834.40 19.345 Ellipse Separation Pass- MPL-09-MPL-09APB1-MPL-09APB1 1,000.00 157.54 1,000.00 148.92 1,008.89 18.286 Clearance Factor Pass- MPL-10-MPL-10-MPL-10 113.78 90.72 113.78 89.30 122.78 64.029 Centre Distance Pass- MPL-10-MPL-10-MPL-10 800.00 91.15 800.00 83.63 808.85 12.123 Ellipse Separation Pass- MPL-10-MPL-10-MPL-10 925.00 95.19 925.00 86.98 933.72 11.600 Clearance Factor Pass- MPL-11-MPL-11-MPL-11 1,186.28 53.67 1,186.28 36.49 1,208.63 3.124 Ellipse Separation Pass- MPL-11-MPL-11-MPL-11 1,200.00 54.16 1,200.00 36.75 1,220.15 3.111 Clearance Factor Pass- MPL-12-MPL-12-MPL-12 1,975.00 86.24 1,975.00 66.85 1,898.71 4.447 Ellipse Separation Pass- MPL-12-MPL-12-MPL-12 2,000.00 88.26 2500.00 68.34 1,915.35 4.430 Clearance Factor Pass- MPL-34-MPL-34-MPL-34 2,150.16 339.53 2,150.16 320.39 2,002.40 17.737 Centre Distance Pass- MPL-34-MPL-34-MPL-34 2,175.00 339.78 2,175.00 320.31 2,022.10 17.452 Ellipse Separation Pass- MPL-34-MPL-34-MPL-34 3,600.00 494.20 3,600.00 453.01 3,441.48 11.998 Clearance Factor Pass- MPL-35-MPL-35-MPL-35 2525.47 236.21 2,525.47 219.55 2,283.00 14.176 Ellipse Separation Pass- MPL-35-MPL-35-MPL-35 2,775.00 250.20 2,775.00 231.81 2,508.33 13.602 Clearance Factor Pass- MPL-35-MPL-35A-MPL-35A 2,525.47 236.21 2,525.47 219.55 2,283.80 14.176 Ellipse Separation Pass- MPL-35-MPL-35A-MPL-35A 2,775.00 250.20 2,775.00 231.81 2,509.13 13.602 Clearance Factor Pass- MPL-35-MPL-35APB1-MPL-35APB1 2,525.47 236.21 2,525.47 219.55 2,283.80 14.176 Ellipse Separation Pass- MPL-35-MPL-35APB1-MPL-35APB1 2,775.00 250.20 2,775.00 231.81 2,509.13 13.602 Clearance Factor Pass- 08 June,2015- 19:05 Page 3 of 7 COMPASS • . Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan MPL-49-MPL-49 wp3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design:M Pt L Pad-Plan MPL-49-MPL-49(Well#1)-MPL-49 wp3 Scan Range: 0.00 to 12,374.30 usft.Measured Depth. Scan Radius is 1,434.43 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft MPL-35-MPL-35APB2-MPL-35APB2 2,525.47 23621 2,525.47 219.55 2,283.80 14.176 Ellipse Separation Pass- MPL-35-MPL-35APB2-MPL-35APB2 2,775.00 250.20 2,775.00 231.81 2,509.13 13.602 Clearance Factor Pass- MPL-35-MPL-35APB3-MPL-35APB3 2,525.47 236.21 2,525.47 219.55 2,283.80 14.176 Ellipse Separation Pass- MPL-35-MPL-35APB3-MPL-35APB3 2,775.00 250.20 2,775.00 231.81 2,509.13 13.602 Clearance Factor Pass- MPL-35-Plan MPL-358-MPL-35B wpi 2,525.47 236.21 2,525.47 219.72 2,283.00 14.323 Ellipse Separation Pass- MPL-35-Plan MPL-35B-MPL-35B wpi 2,775.00 250.20 2,775.00 231.98 2,508.33 13.730 Clearance Factor Pass- MPL-37-MPL-37-MPL-37 2,375.37 123.06 2,375.37 104.83 2,229.95 6.749 Centre Distance Pass- MPL-37-MPL-37-MPL-37 2,450.00 124.49 2,450.00 103.26 2,301.32 5.865 Ellipse Separation Pass- MPL-37-MPL-37-MPL-37 3,075.00 184.35 3,075.00 144.25 2,920.88 4.597 Clearance Factor Pass- MPL-37-MPL-37A-MPL-37A 2,375.37 123.06 2,375.37 104.82 2,239.15 6.747 Centre Distance Pass- MPL-37-MPL-37A-MPL-37A 2,450.00 124.49 2,450.00 103.26 2,310.52 5.863 Ellipse Separation Pass- MPL-37-MPL-37A-MPL-37A 3,075.00 184.35 3,075.00 144.22 2,930.08 4.594 Clearance Factor Pass- MPL-37-Plan MPL-37B-MPL-37B WP2 2,375.37 123.06 2,375.37 105.04 2,229.95 6.828 Centre Distance Pass- MPL-37-Plan MPL-378-MPL-37B WP2 2,450.00 124.49 2,450.00 103.47 2,301.32 5.923 Ellipse Separation Pass- MPL-37-Plan MPL-37B-MPL-37B WP2 3,075.00 184.35 3,075.00 144.45 2,920.88 4.620 Clearance Factor Pass- MPL-42-MPL-42-MPL-42 1,468.88 154.43 1,468.88 145.93 1,491.22 18.179 Centre Distance Pass- MPL-42-MPL-42-MPL-42 1,475.00 154.44 1,475.00 145.92 1,497.19 18.142 Ellipse Separation Pass- MPL-42-MPL-42-MPL-42 6,900.00 541.04 6,900.00 438.18 6,173.06 5.260 Clearance Factor Pass- MPL-45-MPL-45-MPL-45 3,146.17 69.60 3,146.17 38.94 3,175.61 2.270 Centre Distance Pass- MPL-45-MPL-45-MPL-45 3,200.00 74.79 3,200.00 33.97 3,221.84 1.832 Ellipse Separation Pass- MPL-45-MPL-45-MPL-45 3,225.00 80.51 3,225.00 36.05 3,242.87 1.811 Clearance Factor Pass- Plan MPL-46-MPL-46(Well#2)-MPL-46 wp3 3,025.00 93.27 3,025.00 61.82 3,096,18 2.966 Clearance Factor Pass- Plan MPL-46-MPL-46(Well#2)-MPL-46 wp3 3,040.13 93.17 3,040.13 61.80 3,110.70 2.970 Ellipse Separation Pass- Plan MPL-47-MPL-47(Well#4)-MPL-47 wp3 676.28 58.53 676.28 52.32 676.62 9.428 Centre Distance Pass- Plan MPL-47-MPL-47(Well#4)-MPL-47 wp3 700.00 58.58 700.00 52.21 700.21 9.193 Ellipse Separation Pass- Plan MPL-47-MPL-47(Well#4)-MPL-47 wp3 800.00 60.51 800.00 53.62 798.91 8.773 Clearance Factor Pass- Plan MPL-48-MPL-48(Well#3)-MPL-48 wp3 675.00 131.05 675.00 124.65 675.00 20.469 Centre Distance Pass- Plan MPL-48-MPL-48(Well#3)-MPL-48 wp3 700.00 131.10 700.00 124.54 699.29 19.994 Ellipse Separation Pass- Plan MPL-48-MPL-48(Well#3)-MPL-48 wp3 1,100.00 140.55 1,100.00 132.63 1,078.56 17.761 Clearance Factor Pass- Plan MPL-50-MPL-50(well#5)-MPL-50 wp3 325.00 157.63 325.00 154.30 325.80 47.351 Centre Distance Pass- 08 June,2015- 19:05 Page 4 of 7 COMPASS • • Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan MPL-49-MPL-49 wp3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design:M Pt L Pad-Plan MPL-49-MPL-49(Well#1)-MPL-49 wp3 Scan Range: 0.00 to 12,374.30 usft.Measured Depth. Scan Radius is 1,434.43 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft Plan MPL-50-MPL-50(well#5)-MPL-50 wp3 375.00 157.82 375.00 154.07 374.45 42.053 Ellipse Separation Pass- Plan MPL-50-MPL-50(well#5)-MPL-50 wp3 725.00 175.04 725.00 168.65 705.93 27.397 Clearance Factor Pass- Survey tool prourafn From To Survey/Plan Survey Tool (usft) (usft) 30.00 700.00 MPL-49 wp3 SRG-SS 700.00 5,856.42 MPL-49 wp3 MWD+IFR2+MS+sag 5,856.42 12,374.30 MPL-49 wp3 MWD+IFR2+MS+sag Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor=Distance Between Profiles/(Distance Between Profiles-Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 08 June,2015- 19:05 Page 5 of 7 COMPASS • s Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan MPL-49-MPL-49 wp3 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to As-Staked MPL-49 @ 47.00usft. Northing and Easting are relative to Plan MPL-49. Coordinate System is US State Plane 1927(Exact solution),Alaska Zone 04. Central Meridian is-150.00°,Grid Convergence at Surface is:0.35°. -I- MPL-02 MPL-02 MPL-02V1 Ladder Plot PMP L-02, L-02AL1,lvPL-02AL1V0 $ NPL-02,FPL-02AL2,MPL-02AL2V0 r r I- i $ MPL-02,1VPL-02APB1,MPL-02APB1V0 i i i c i i °• MPL-02,MPL-02APB2,MPL-02APB2V0 1350 11f1 OA `t i „ $ MPL-04,MPL-04,MPL-04V1 !! ' ,.moi - q '. ^ MPL-05,MPL-05,MPL-05 V1 fill /`, I P', •S MPL-06,MPL-06,MPL-06V1 LO � l�„i ri h ,M- MPL-07,MPL-07,MPL-07 V1 ILi!ic hr 214 !' /i 4� $ MPL-0S,MPL-0B,MPL-08 V1 O �1.'I 1� ,' } MPL-09,MPL-09,MPL-09 V1 illi r A,.,.',14 '1'-- 4 $ MPL-09,MPL-09A,MPL-09AV0 CL 11 .1fr !' fra $ MPL-09,MPL-09APB1,MPL-09APBI VO N 6/1:,. L`•� 4hr 4 (/) ;1 .'i $ MPL-10,MPL-10,MPL-10 V1 �� "4 /'�/ ��'` :‘ �' $MPL-11,MPL-11,MPL-11 V1 2 el ;07 A a ,«71 '' E' p A i iir ,%.`-� -0-MPL-12,MPL-12,MPL-12 V1 ry /�, /� PA -0- MPL-34,MPL-34,MPL-34 V10 U > t r if 0 450 �,04 I �� ,1 � - MPL35,MPL35,MPL35V6 r ��w 14UA $ MPL35,MPL35A,MPL-35, ,.;; ',;"2,.::,..,3 c.w % L -e-MPL-35,MPL35APB1,MPL35APB1 V5 .rlplrA:s r,,�.1:f. $ MPL35,MPL35APB2,MPL35APB2V3 -A-MPL35,MPL35APB3,MPL35APB3V5 r -11•-fl/PL-35,Plan MPL35B,NFL-3513,W VO 0 2500 5000 7500 10000 12500 -4- IvP137,MPL-37,MPL37 V3 -9- MPL-37,NPL-37A,MPL-37AV1 Measured Depth(25OOusft/in) -e- MPL37,Plan MPL37B,MPL-37BWP2V19 4'- Mt'L4L,MYL4L,MrL4L V 4 08 June,2015- 19:05 Page 6 of 7 COMPASS • • Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan MPL-49-MPL-49 wp3 Clearance Factor Plot: Measured Depth versus Separation(Clearance)Factor MPC-02-,MPL-0Z,MPL-02VT II I --- 111:' o $ MPL-02,MPL-02A,MPL-02AVO 10.00- �I, -6- MPL-02,MPL-02ALI,MPL-02AL1V0 $ MPL-02,MPL-02AL2,MPL-0ZAL2 V0 $ MPL-02,MPL-02APB1,MPL-02APB1VO r875- - -� -)I4- MPL-02,MPL-02APB2,MPL-02AP62 V0 A\ $ MPL-04,MPL-04,MPL-04 V1- �\ - MPL-0S,MPL-05,MPL-05V17,50 A, -N- MPL-06,MPL-06,MPL-06V1S o 9r' �f MPL-07,MPL-07,MPL-07V1�� $ MPL-0B,MPL-08,MPL-08V16.25 o _ -j- MPL-09,MPL-09,MPL-09V1 ti G $ MPL-09,MPL-09A,MPL-09AVO m - 11 �� e. co 5.00-- -'71:, .rf _______ C-.+ $ MPL-09,MPL-09AP61,MPL-09AP61 VO `p ♦• MPL-10,MPL-10,MPL-10 V1 IA _ $ MPL-11,MPL-11,MPL-11 V1 CO 3.75------ I ,. -a' MPL-12,MPL-12,MPL-12 V1 {, fk $ MPL-34,MPL-34,MPL-34 V10 IJ �\ -X- MPL-35,MPL-35,MPL-35 V6 2.50--- - - --. _. --. $ MPL-35,MPL-35A,MPL-35A V12 Collision Avoida Ice Reg -0- MPL35,MPL35APB1,MPL-35APB1 V5 Zone-Stop Chilling -d• MPL-35,MPL-35APB2,MPL-35AP82 V3 1.25-____---- _.... _ ----- -6-MPL-35,MPL-35APB3,MPL-35AP63V5 - -2- MPL-35,Plan MPL35B,MPL-35Bwp1VO $ MPL-37,MPL-37,MPL-37 V3 0.00 , , , 1 1 , , 1 + 1 1111 ' 1111 1111 1111 1111 1111 1 $-MPL-37,MPL-37A,MPL-37AV1 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 _e. MPL-37,PIan MPL-37B,MPL37BWP2V19 Measued Depin(2t/JG usffln) -4- MP L-42,MPL-42,MPL-42 V4 08 June,2015- 19:05 Page 7 of 7 COMPASS • • Hilcorp Energy Company Milne Point M Pt L Pad Plan MPL-49 MPL-49(Well#1) MPL-49 wp3 Sperry Drilling Services Anticollision Report 08 June,2015 Closest Approach 3D Proximity Scan on Current Survey Data(Highside Reference) Reference Design: M Pt L Pad-Plan MPL-49-MPL-49(Well#1)-MPL-49 wp3 Well Coordinates: 6,031,591.24 N,545,189.65 E(70°29'49.82"N,149°37'49.66"W) Datum Height: As-Staked MPL-49 @ 47.00usft Scan Range: 0.00 to 12,374.30 usft.Measured Depth. Scan Radius is 1,434.43 usft. Clearance Factor cutoff Is Unlimited. Max Ellipse Separation Is Unlimited Geodetic Scale Factor Applied Version:5000.1 Build: 73 Scan Type: NO GLOBAL FILTER:Using user defined selection&filtering criteria Interpolation Interval: 25.00 HALLIBURTON • • Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan MPL-49/MPL-49 wp3 Closest Approach 3D Proximity Scan on Current Survey Data(Highside Reference) Offset Design:M Pt L Pad-MPL-45-MPL-45 Scan Range:0.00 to 12,374.30 usft.Measured Depth. Scan Radius is 1,434.43 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (soft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 30.00 30.00 0.00 34.50 30.60 0.00 455.15 0.91 454.24 -70.36 289.64 499.150 Pass- 50.00 50.00 0.05 53.51 49.61 0.02 455.16 0.98 454.18 -70.36 289.64 464.608 Pass- 75.00 75.00 0.10 78.01 74.10 0.05 455.20 1.07 454.13 -70.35 289.65 427.310 Pass- 100.00 100.00 0.16 102.50 98.60 0.08 455.26 1.15 454.11 -70.34 289.66 395.584 Pass- 125.00 125.00 028 127.00 123.09 0.11 455.35 1.29 454.06 -70.32 289.68 351.747 Pass- 150.00 150.00 0.39 151.49 147.59 0.13 455.47 1.44 454.03 -70.29 289.71 316.689 Pass- 175.00 175.00 0.51 175.98 172.08 0.16 455.62 1.58 454.03 -70.26 289.74 288.017 Pass- 200.00 200.00 0.63 200.47 196.57 0.19 455.79 1.73 454.06 -70.23 289.77 264.136 Pass- 225.00 225.00 0.74 225.14 221.23 0.23 455.99 1.88 454.11 -70.18 289.82 241.980 Pass- 250.00 250.00 0.86 249.95 246.04 0.29 456.20 2.06 454.14 -70.14 289.86 221.813 Pass- 275.00 275.00 0.97 274.76 270.85 0.35 456.42 2.23 454.19 -70.09 289.91 204.768 Pass- 300.00 300.00 1.09 299.57 295.65 0.40 456.66 2.40 454.26 -70.04 289.96 190.174 Pass- 325.00 325.00 1.21 324.59 320.67 0.45 456.90 2.57 454.33 -69.99 290.01 177.832 Pass- 350.00 350.00 1.32 349.68 345.75 0.51 457.13 2.74 454.39 -69.95 290.05 167.075 Pass- 375.00 375.00 1.44 374.76 370.83 0.56 457.36 2.90 454.46 -69.93 290.07 157,554 Pass- 400.00 400.00 1.55 399.96 396.02 0.61 457.59 3.07 454.52 -69.91 290.09 149.068 Pass- 425.00 425.00 1.67 426.02 422.09 0.66 457.77 3.24 454.54 -69.91 290.09 141.467 Pass- 450.00 450.00 1.79 452.09 448.16 0.71 457.90 3.40 454.50 -69.92 290.08 134.592 Pass- 475.00 475.00 1.90 478.16 474.23 0.76 457.97 3.57 454.41 -69.95 290.05 128.341 Pass- 500.00 500.00 2.02 504.13 500.19 0.81 457.99 3.74 454.25 -69.99 290.01 122.572 Pass- 525.00 525.00 2.14 530.02 526.08 0.86 457.95 3.91 454.05 -70.05 289.95 117.248 Pass- 550.00 550.00 2.25 555.91 551.97 0.91 457.87 4.08 453.80 -70.12 289.88 112.359 Pass- 575.00 575.00 2.37 581.78 577.83 0.97 457.74 4.24 453.50 -70.20 289.80 107.841 Pass- 600.00 600.00 2.48 607.52 603.55 1.02 457.57 4.42 453.15 -70.29 289.71 103.593 Pass- 625.00 625.00 2.54 63325 629.26 1.08 457.35 4.53 452.82 -70.40 289.60 100.919 Pass- 650.00 650.00 2.60 658.96 654.96 1.14 457.10 4.65 452.45 -70.53 289.47 98.354 Pass- 675.00 675.00 2.66 684.01 679.98 1.19 456.82 4.76 452.05 -70.68 289.32 95.893 Pass- 700.00 700.00 2.72 708.17 704.10 1.25 456.57 4.88 451.69 -70.84 289.16 93.546 Pass- 725.00 725.00 2.72 732.32 728.20 1.31 456.37 4.94 451.43 -71.02 288.98 92.313 Pass- 750.00 750.00 2.73 756.44 752.28 1.37 456.22 5.01 451.21 -71.22 288.78 91.120 Pass- 08 June,2015-21:39 Page 2 of 12 COMPASS • • Hilcorp Energy Company HALLIBURTON Mine Point Anticollision Report for Plan MPL-49/MPL-49 wp3 Closest Approach 3D Proximity Scan on Current Survey Data(Highside Reference) Offset Design:M Pt L Pad-MPL-45-MPL45 Scan Range:0.00 to 12,374.30 usft.Measured Depth. Scan Radius Is 1,434.43 unit.Clearance Factor cutoff is Unlimited.Max Ellipse Separation Is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 775.00 775.00 2.73 781.09 776.85 1.43 456.11 5.08 451.03 -71.45 288.55 89.844 Pass- 800.00 800.00 2.74 806.01 801.69 1.50 456.01 5.15 450.86 -71.70 288.30 88.536 Pass- 814.10 814.10 2.74 820.05 815.69 1.54 455.99 5.20 450.79 118.16 308.16 87.758 Pass- 825.00 825.00 2.74 830.91 826.50 1.57 456.00 5.23 450.77 118.05 308.05 87.191 Pass- 850.00 849.99 2.75 855.81 851.30 1.64 456.16 5.31 450.85 117.81 307.81 85.938 Pass- 875.00 874.98 2.76 881.09 876.45 1.72 456.46 5.39 451.07 117.59 307.59 84.643 Pass- 900.00 899.95 2.77 906.58 901.82 1.80 456.90 5.48 451.42 117.38 307.38 83.354 Pass- 925.00 924.91 2.78 932.08 927.18 1.88 457.46 5.57 451.89 117.21 307.21 82.064 Pass- 950.00 949.85 2.80 955.49 950.47 1.96 458.15 5.66 452.49 117.07 307.07 80.934 Pass- 975.00 974.76 2.81 981.31 976.13 2.05 459.01 5.76 453.25 116.94 306.94 79.635 Pass- 1,000.00 999.63 2.82 1,005.17 999.83 2.13 460.08 5.86 454.22 116.83 306.83 78.513 Pass- 1,025.00 1,024.48 2.84 1,029.01 1,023.49 2.22 461.36 5.96 455.39 116.72 306.72 77.367 Pass- 1,050.00 1,049.29 2.86 1,052.86 1,047.15 2.31 462.84 6.07 456.78 116.63 306.63 76.275 Pass- 1,075.00 1,074.05 2.88 1,076.91 1,070.98 2.41 464.53 6.19 458.34 116.55 306.55 75.062 Pass- 1,100.00 1,098.77 2.90 1,100.94 1,094.75 2.51 466.41 6.31 460.10 116.46 306.46 73.927 Pass- 1,125.00 1,123.44 2.92 1,124.97 1,118.49 2.61 468.30 6.44 461.85 111.31 296.18 72.707 Pass- 1,150.00 1,148.07 2.95 1,149.68 1,142.85 2.72 470.00 6.58 463.42 106.78 287.11 71.460 Pass- 1,175.00 1,172.65 2.98 1,178.71. 1,171.45 2.86 471.35 6.75 464.60 102.82 279.16 69.877 Pass- 1,200.00 1,197.17 3.01 1,207.77 1,200.04 3.00 472.26 6.91 465.34 99.38 272.22 68.307 Pass- 1,225.00 1,221.62 3.05 1,236.86 1,228.60 3.15 472.71 7.10 465.62 96.41 266.15 66.624 Pass- 1,250.00 1,246.01 3.09 1,262.78 1,254.02 3.28 472.79 7.27 465.52 93.83 260.84 65.003 Pass- 1,275.00 1,270.31 3.13 1,287.94 1,278.69 3.42 472.63 7.45 465.18 91.60 256.20 63.435 Pass- 1,300.00 1,294.52 3.17 1,313.09 1,303.34 3.56 472.23 7.63 464.60 89.69 252.14 61.914 Pass- 1,325.00 1,318.64 3.22 1,338.35 1,328.08 3.70 471.59 7.82 463.77 88.06 248.58 60.280 Pass- 1,350.00 1,342.65 3.28 1,366.45 1,355.58 3.87 470.64 8.05 462.59 86.69 245.49 58.484 Pass- 1,375.00 1,366.56 3.33 1,394.52 1,382.99 4.04 469.30 8.27 461.03 85.53 242.78 56.740 Pass- 1,400.00 1,390.34 3.39 1,422.54 1,410.32 4.21 467.58 8.50 459.09 84.57 240.40 55.037 Pass- 1,425.00 1,414.01 3.47 1,448.35 1,435.45 4.35 465.52 8.71 456.81 83.75 238.31 53.467 Pass- 1,450.00 1,437.54 3.54 1,472.64 1,459.10 4.47 463.26 8.90 454.37 83.08 236.47 52.070 Pass- 1,475.00 1,460.93 3.62 1,496.86 1,482.70 4.59 460.84 9.09 451.75 82.57 234.89 50.714 Pass- 1,500.00 1,484.17 3.70 1,521.01 1,506.22 4.71 458.25 9.28 448.97 82.21 233.54 49.398 Pass- 08 June,2015-21:39 Page 3 of 12 COMPASS • • Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan MPL-49/MPL-49 wp3 Closest Approach 30 Proximity Scan on Current Survey Data(Highside Reference) Offset Design:M Pt L Pad-MPL-45-MPL-45 Scan Range:0.00 to 12,374.30 usft.Measured Depth. Scan Radius is 1,434.43 usft.Clearance Factor cutoff Is Unlimited.Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 1,525.00 1,507.27 3.80 1,544.91 1,529.50 4.83 455.52 9.49 446.02 81.96 232.39 47.976 Pass- 1,550.00 1,530.20 3.90 1,568.72 1,552.63 4.97 452.65 9.72 442.93 81.81 231.40 46.578 Pass- 1,575.00 1,552.96 4.00 1,592.55 1,575.72 5.10 449.67 9.94 439.72 81.74 230.55 45.231 Pass- 1,600.00 1,575.55 4.10 1,616.40 1,598.76 5.24 446.56 10.16 436.39 81.75 229.83 43.932 Pass- 1,625.00 1,597.96 4.22 1,641.08 1,622.53 5.41 443.32 10.45 432.87 81.86 229.26 42.428 Pass- 1,650.00 1,620.18 4.35 1,666.38 1,646.80 5.62 439.91 10.76 429.14 82.05 228.82 40.874 Pass- 1,675.00 1,642.21 4.48 1,691.68 1,670.99 5.82 436.31 11.08 425.23 82.32 228.49 39.395 Pass- 1,700.00 1,664.04 4.60 1,716.96 1,695.08 6.03 432.53 11.39 421.14 82.65 228.27 37.988 Pass- 1,725.00 1,685.65 4.75 1,742.02 1,718.86 6.26 428.59 11.74 416.85 83.06 228.14 36.509 Pass- 1,750.00 1,707.06 4.91 1,767.01 1,742.50 6.50 424.50 12.09 412.40 83.53 228.11 35.101 Pass- 1,775.00 1,728.24 5.06 1,791.96 1,766.03 6.73 420.27 12.44 407.83 84.07 228.18 33.771 Pass- 1,800.00 1,749.19 5.22 1,816.88 1,789.45 6.97 415.92 12.79 403.12 84.69 228.35 32.513 Pass- 1,825.00 1,769.91 5.39 1,841.74 1,812.74 7.22 411.45 13.18 398.27 85.38 228.61 31.218 Pass- 1,850.00 1,790.39 5.57 1,866.56 1,835.91 7.48 406.88 13.56 393.32 86.14 228.97 30.002 Pass- 1,875.00 1,810.63 5.75 1,891.32 1,858.94 7.74 402.23 13.94 388.29 86.97 229.42 28.859 Pass- 1,900.00 1,830.61 5.93 1,916.43 1,88223 8.00 397.50 14.31 383.19 87.90 229.98 27.774 Pass- 1,925.00 1,850.33 6.14 1,943.80 1,907.50 8.32 392.62 14.73 377.89 89.00 230.73 26.651 Pass- 1,950.00 1,869.79 6.34 1,971.05 1,932.52 8.63 387.54 15.14 372.40 90.19 231.58 25.600 Pass- 1,975.00 1,888.99 6.54 1,998.17 1,957.29 8.94 382.29 15.54 366.75 91.47 232.63 24.605 Pass- 2,000.00 1,908.12 6.75 2,024.78 1,981.46 9.26 376.95 15.95 361.00 92.77 233.93 23.632 Pass- 2,025.00 1,927.26 6.96 2,051.14 2,005.27 9.59 371.57 16.36 355.21 94.07 235.23 22.712 Pass- 2,050.00 1,946.39 7.17 2,077.56 2,028,98 9.93 366.14 16,76 349.38 95.36 236.53 21.850 Pass- 2,075.00 1,965.52 7.38 2,104.03 2,052.60 10.26 360.66 17.14 343.52 96.67 237.83 21.040 Pass- 2,100.00 1,984.66 7.59 2,129.85 2,075.48 10.62 355.15 17.53 337.62 97.94 239.10 20.256 Pass- 2,125.00 2,003.79 7.81 2,155.77 2,098.28 10.99 349.62 17.92 331.70 99.20 240.36 19.514 Pass- 2,150.00 2,022.92 8.02 2,181.78 2,120.98 11.35 344.05 18.28 325.76 100.46 241,62 18.816 Pass- 2,175.00 2,042.06 8.24 2,207.75 2,143.47 11.73 338.44 18.65 319.79 101.71 242.87 18.148 Pass- 2,200.00 2,061.19 8.46 2,233.61 2,165.67 12.12 332.79 19.01 313.77 102.94 244.11 17.503 Pass- 2,225.00 2,080.32 8.68 2,259.56 2,187.75 12,52 327.09 19.37 307.73 104.17 245.33 16.889 Pass- 2,250.00 2,099.46 8.90 2,285.59 2,209.69 12.91 321.34 19.71 301.64 105.38 246.54 16.308 Pass- 2,275.00 2,118.59 9.12 2,311.31 2,231.18 13.33 315.54 20.04 295.49 106.56 247.72 15.742 Pass- 08 June,2015-21:39 Page 4 of 12 COMPASS • • Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan MPL-49/MPL-49 wp3 Closest Approach 3D Proximity Scan on Current Survey Data(Highside Reference) Offset Design:M Pt L Pad-MPL-45-MPL-45 Scan Range:0.00 to 12,374.30 usft.Measured Depth. Scan Radius Is 1,434.43 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highslde Clearance (usft) (usft) Axis/2 (usft) (usft) Axlsl2 (usft) (usft) (usft) Bearing Bearing Factor Warning 2,300.00 2,137.72 9.35 2,336.96 2,252.40 13.75 309.69 20.37 289.31 107.73 248.89 15.201 Pass- 2,325.00 2,156.86 9.57 2,362.67 2,273.48 14.17 303.79 20.69 283.10 108.89 250.05 14.683 Pass- 2,350.00 2,175.99 9.80 2,388.44 2,294.41 14.59 297.83 20.99 276.84 110.04 251.20 14.189 Pass- 2,375.00 2,195.12 10.02 2,414.73 2,315.55 15.06 291.78 21.30 270.48 111.21 252.37 13.699 Pass- 2,400.00 2,214.26 10.25 2,441.00 2,336.47 15.53 285.61 21.59 264.03 112.38 253.54 13.231 Pass- 2,425.00 2,233.39 10.48 2,467.25 2,357.17 15.99 279.33 21.85 257.47 113.55 254.72 12.781 Pass- 2,450.00 2,252.53 10.71 2,493.58 2,377.72 16.47 272.91 22.11 250.80 114.74 255.90 12.345 Pass- 2,475.00 2,271.66 10.94 2,520.05 2,398.16 16.98 266.35 22.35 244.00 115.95 257.11 11.918 Pass- 2,500.00 2,290.79 11.17 2,546.45 2,418.32 17.49 259.62 22.56 237.06 117.17 258.33 11.508 Pass- 2,525.00 2,309.93 11.40 2,572.77 2,438.19 17.99 252.73 22.74 229.98 118.41 259.57 11.112 Pass- 2,550.00 2,329.06 11.63 2,598.59 2,457.45 18.50 245.69 22.91 222.78 119.65 260.82 10.726 Pass- 2,575.00 2,348.19 11.86 2,624.18 2,476.32 19.01 238.54 23.05 215.49 120.89 262.06 10.351 Pass- 2,600.00 2,367.33 12.09 2,649.75 2,494.93 19.52 231.27 23.16 208.11 122.14 263.31 9.987 Pass- 2,625.00 2,386.46 12.32 2,675.27 2,513.27 20.03 223.88 23.24 200.64 123.41 264.57 9.634 Pass- 2,650.00 2,405.59 12.56 2,700.90 2,531.45 20.57 216.35 23.30 193.05 124.70 265.86 9.285 Pass- 2,675.00 2,424.73 12.79 2,726.45 2,549.33 21.10 208.68 23.33 185.35 126.03 267.19 8.946 Pass- 2,700.00 2,443.86 13.02 2,751.91 2,566.90 21.64 200.85 23.31 177.55 127.39 268.55 8.617 Pass- 2,725.00 2,462.99 13.25 2,777.30 2,584.19 22.18 192.88 23.25 169.64 128.81 269.97 8.297 Pass- 2,750.00 2,482.13 13.49 2,802.67 2,601.24 22.74 184.75 23.13 161.62 130.32 271.48 7.987 Pass- 2,775.00 2,501.26 13.72 2,827.86 2,617.96 23.30 176.46 22.94 153.52 131.94 273.10 7.692 Pass- 2,800.00 2,520.39 13.96 2,852.88 2,634.35 23.86 168.03 2267 145.36 133.68 274.85 7.412 Pass- 2,825.00 2,539.53 14.19 2,877.65 2,650.37 24.42 159.48 22.31 137.17 135.58 276.75 7.149 Pass- 2,850.00 2,558.66 14.43 2,902.20 2,666.03 24.99 150.84 21.85 128.98 137.64 278.81 6.902 Pass- 2,875.00 2,577.79 14.66 2,926.59 2,681.37 25.56 142.12 21.30 120.83 139.90 281,06 6.674 Pass- 2,900.00 2,596.93 14.90 2,950.84 2,696.41 26.12 133.37 20.63 112.74 142.39 283.55 6.465 Pass- 2,925.00 2,616.06 15.13 2,974.93 2,711.14 26.69 124.60 19.86 104.74 145.19 286.35 6.274 Pass- 2,950.00 2,635.20 15.37 2,998.79 2,725.55 27.25 115.88 18.99 96.89 148.42 289.58 6.103 Pass- 2,975.00 2,654.33 15.61 3,022.38 2,739.64 27.81 107.29 18,10 89.19 152.19 293.35 5.928 Pass- 3,000.00 2,673.46 15.84 3,045.70 2,753.40 28.37 98.97 17.37 81.59 156.60 297.76 5.697 Pass- 3,025.00 2,692.60 16.08 3,068.59 2,766.74 28.90 91.09 17.11 73.98 161.73 302.89 5.324 Pass- 3,050.00 2,711.73 16.32 3,091.04 2,779.73 29.43 83.95 17.66 66.29 167.68 308.84 4.754 Pass- 08 June,2015-21:39 Page 5 of 12 COMPASS • • Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan MPL-49/MPL-49 wp3 Closest Approach 3D Proximity Scan on Current Survey Data(Highside Reference) Offset Design:M Pt L Pad-MPL-45-MPL-45 Scan Range:0.00 to 12,374.30 usft.Measured Depth. Scan Radius is 1,434.43 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.x Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axist2 (usft) (usft) Axlsl2 (usft) (usft) (usft) Bearing Bearing Factor Warning 3,075.00 2,730.86 16.55 3,11326 2,792.51 29.94 77.87 19.33 58.54 174.54 315.71 4.028 Pass- 3,100.00 2,750.00 16.79 3,135.25 2,805.07 30.46 73.22 22.31 50.91 -177.71 -401.13 3.282 Pass- 3,125.00 2,769.13 17.03 3,157.07 2,817.44 30.97 70.38 26.49 43.89 -169.23 -409.61 2.657 Pass- 3,146.17 2,785.33 17.23 3,175.61 2,827.85 31.42 69.60 30.66 38.94 -161.62 -417.21 2.270 Pass- 3,150.00 2,788.26 17.27 3,178.94 2,829.70 31.50 69.62 31.44 38.19 -160.24 -418.60 2.215 Pass- 3,175.00 2,807.40 17.50 3,200.53 2,841.64 32.03 71.10 36.39 34.71 -151.26 -427.58 1.954 Pass- 3,200.00 2,826.53 17.74 3,221.84 2,853.25 32.55 74.79 40.82 33.97 -142.89 -436.14 1.832 Pass- 3,225.00 2,845.66 17.98 3,242.87 2,864.55 33.06 80.51 44.46 36.05 -134.86 6.31 1.811 Pass- 3,250.00 2,864.80 18.22 3,264.01 2,875.73 33.59 87.92 47.34 40.59 -127.77 13.39 1.857 Pass- 3,275.00 2,883.93 18.45 3,285.14 2,886.75 34.14 96,64 49.51 47.12 -121.54 19.62 1.952 Pass- 3,300.00 2,903.06 18.69 3,306.10 2,897.49 34.68 106.37 51.11 55.26 -116.14 25.02 2.081 Pass- 3,325.00 2,922.20 18.93 3,326.89 2,907.98 35.22 116.92 5229 64.63 -111.48 29.68 2.236 Pass- 3,350.00 2,941.33 19.17 3,345.66 2,917,31 35.71 128.14 53.11 75.03 -107.78 33.38 2.413 Pass- 3,375.00 2,960.46 19.41 3,367.17 2,927.79 36.28 139.93 53.81 86.12 -104.04 37.12 2.601 Pass- 3,400.00 2,979.60 19.65 3,386.60 2,937.04 36.80 152.28 54.31 97.97 -101.05 40.11 2.804 Pass- 3,425.00 2,998.73 19.89 3,405.72 2,945.95 37.32 165.12 54.72 110.41 -98.42 42.75 3.018 Pass- 3,450.00 3,017.87 20.12 3,424.54 2,954.51 37.82 178.40 55.05 123.35 -96.08 45.08 3.241 Pass- 3,475.00 3,037.00 20.36 3,441.46 2,962.05 38.27 192.07 55.33 136.74 -94.17 46.99 3.471 Pass- 3,500.00 3,056.13 20.60 3,461.75 2,970.85 38.83 206.06 55.59 150.47 -92.08 49.09 3.707 Pass- 3,525.00 3,075.27 20.84 3,480.11 2,978.58 39.34 220.35 55.82 164.54 -90.32 50.84 3.948 Pass- 3,550.00 3,094.40 21.08 3,498.18 2,985.96 39.84 234.92 56.02 178.90 -88.72 52.44 4.194 Pass- 3,575.00 3,113.53 21.32 3,515.95 2,992.99 40.33 249.75 56.20 193.54 -87.24 53.92 4.444 Pass- 3,600.00 3,132.69 21.50 3,537.29 3,001.16 40.92 264.64 56.64 208.00 -84.32 58.76 4.672 Pass- 3,625,00 3,151.90 21.61 3,551.56 3,006.45 41.31 279.29 57.02 222.27 -81.99 63.02 4.898 Pass- 3,650.00 3,171.15 21.72 3,569.69 3,013.00 41.81 293.76 57.36 236.40 -79.43 67.53 5.121 Pass- 3,675.00 3,190.44 21.83 3,587.79 3,019.34 42.30 308.02 57.67 250.34 -76.92 72.00 5.341 Pass- 3,700.00 3,209.74 21.94 3,605.86 3,025.47 42.80 322.07 57.96 264.11 -74.46 76.42 5.557 Pass- 3,725.00 3,229.06 22.05 3,623.88 3,031.38 43.29 335.92 5821 277.70 -72.04 80.82 5.770 Pass- 3,750.00 3,248.38 22.15 3,641.28 3,036.91 43.78 349.58 58.45 291.13 -69.69 85.13 5.981 Pass- 3,775.00 3,267.69 22.26 3,658.07 3,042.11 44.26 363.10 58.68 304.42 -67.42 89.37 6.188 Pass- 3,800.00 3,286.99 22.37 3,674.80 3,047.15 44.74 376.49 58.88 317.61 -65.20 93.56 6.394 Pass- 08 June,2015-21:39 Page 6 of 12 COMPASS • • Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan MPL-49/MPL-49 wp3 Closest Approach 3D Proximity Scan on Current Survey Data(Highside Reference) Offset Design:M Pt L Pad-MPL-45-MPL-45 Scan Range:0.00 to 12,374.30 usft.Measured Depth. Scan Radius Is 1,434.43 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 3,825.00 3,306.27 22.47 3,691.45 3,052.04 45.22 389.75 59.06 330.69 -63.02 97.69 6.600 Pass- 3,850.00 3,325.51 22.57 3,708.03 3,056.77 45.69 402.88 59.21 343.67 -60.89 101.77 6.804 Pass- 3,875.00 3,344.71 22.67 3,728.16 3,062.33 46.27 415.90 59.31 356.59 -58.60 105.99 7.012 Pass- 3,900.00 3,363.86 22.78 3,743.65 3,066.54 46.73 428.70 59.43 369.27 -56.61 109.90 7.213 Pass- 3,925.00 3,382.95 22.87 3,763.66 3,071.96 47.32 441.24 59.50 381.74 -54.42 113.99 7.416 Pass- 3,950.00 3,401.96 22.97 3,783.81 3,077.40 47.92 453.48 59.53 393.94 -52.28 118.01 7.617 Pass- 3,975.00 3,420.90 23.07 3,804.08 3,082.87 48.53 465.42 59.54 405.88 -50.19 121.97 7.817 Pass- 4,000.00 3,439.76 23.17 3,824.63 3,088.40 49.13 477.07 59.51 417.56 -48.12 125.87 8.016 Pass- 4,025.00 3,458.51 23.26 3,849.30 3,095.11 49.72 488.33 59.33 429.01 -45.92 129.89 8.231 Pass- 4,050.00 3,477.16 23.35 3,874.30 3,102.05 50.32 499.11 59.10 440.02 -43.74 133.85 8.445 Pass- 4,075.00 3,495.70 23.45 3,899.61 3,109.21 50.92 509.42 58.83 450.59 -41.60 137.76 8.659 Pass- 4,100.00 3,514.11 23.54 3,924.35 3,116.35 51.49 519.25 58.52 460.73 -39.52 141.57 8.873 Pass- 4,125.00 3,532.39 23.63 3,946.42 3,122.74 51.93 528.71 58.16 470.54 -37.59 145.21 9.090 Pass- 4,150.00 3,550.53 23.72 3,968.53 3,129.13 52.37 537.84 57.76 480.08 -35.69 148.79 9.311 Pass- 4,175.00 3,568.51 23.81 3,990.66 3,135.51 52.81 546.66 57.32 489.34 -33.81 152.31 9.537 Pass- 4,200.00 3,586.35 23.89 4,012.81 3,141.88 53.25 555.18 56.84 498.34 -31.95 155.78 9.768 Pass- 4,225.00 3,604.01 23.98 4,035.41 3,148.38 53.70 563.38 56.31 507.08 -30.11 159.21 10.006 Pass- 4,250.00 3,621.50 24.07 4,058.09 3,154.94 54.16 571.27 55.74 515.54 -28.29 162.59 10.250 Pass- 4,275.00 3,638.81 24.15 4,080.81 3,161.54 54.62 578.86 55.13 523.74 -26.49 165.91 10.501 Pass- 4,300.00 3,655.92 24.24 4,103.54 3,168.18 55.07 586.15 54.48 531.67 -24.72 169.17 10.760 Pass- 4,325.00 3,672.84 24.32 4,125.78 3,174.70 55.50 593.15 53.78 539.36 -23.00 172.36 11.029 Pass- 4,350.00 3,689.55 24.40 4,147.72 3,181.14 55.91 599.89 53.05 546.84 -21.31 175.48 11.307 Pass- 4,375.00 3,706.04 24.49 4,169.65 3,187.60 56.31 606.39 52.29 554.09 -19.65 178.54 11,596 Pass- 4,400.00 3,722.31 24.57 4,191.56 3,194.07 56.72 612.64 51.50 561.15 -18.01 181.56 11.897 Pass- 4,425.00 3,738.35 24.65 4,213.44 3,200.55 57.13 618.67 50.66 568.00 -1639 184.52 12.211 Pass- 4,450.00 3,754.15 24.73 4,222.08 3,203.11 57.29 624.60 50.13 574.48 -15.38 186.86 12.461 Pass- 4,475.00 3,769.70 24.82 4,248.32 3,210.72 57.90 630.29 49.18 581.11 -13.60 189.93 12.816 Pass- 4,500.00 3,785.00 24.90 4,264.42 3,215.20 58.28 636.07 48.44 587.64 -12.29 192.51 13.132 Pass- 4,525.00 3,800.03 24.98 4,280.31 3,219.50 58.65 641.85 47.66 594.18 -11.01 195.03 13.466 Pass- 4,550.00 3,814.80 25.06 4,296.00 3,223.60 59.02 647.63 46.87 600.76 -9.75 197.51 13.817 Pass- 4,575.00 3,829.30 25.14 4,319.24 3,229.44 59.57 653.49 45.86 607.63 -8.15 200.30 14.249 Pass- 08 June,2015-21:39 Page 7 of 12 COMPASS 0 . Hilcorp Energy Company HALLIBURTONMilne Point Anticollision Report for Plan MPL-49/MPL-49 wp3 Closest Approach 3D Proximity Scan on Current Survey Data(Highside Reference) Offset Design:M Pt L Pad-MPL-45-MPL-45 Scan Range: 0.00 to 12,374.30 usft.Measured Depth. Scan Radius is 1,434.43 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (uaft) Axis/2 (usft) (usft) Axis/2 (usft) (waft) (usft) Bearing Bearing Factor Warning 4,600.00 3,843.51 25.22 4,329.79 3,232.03 59.83 659.23 45.17 614.06 -7.17 202.45 14.595 Pass- 4,625.00 3,857.43 25.30 4,351.06 3,237.27 60.37 664.90 44.18 620.72 -5.70 205.08 15.050 Pass- 4,650.00 3,871.06 25.38 4,372.19 3,242.49 60.90 670.44 43.18 627.26 -4.24 207.66 15.527 Pass- 4,675.00 3,884.39 25.47 4,393.15 3,247.69 61.43 675.85 42.17 633.68 -2.81 210.20 16.026 Pass- 4,700.00 3,897.41 25.55 4,413.93 3,252.87 61.95 681.15 41.17 639.99 -1.40 212.70 16.547 Pass- 4,725.00 3,910.11 25,63 4,434.53 3,258.02 62.47 686.36 40.16 646.20 -0.01 215.16 17.091 Pass- 4,750.00 3,922.49 25.71 4,454.92 3,263.15 62.98 691.50 39.17 652.33 1.36 217.58 17.656 Pass- 4,775.00 3,934.55 25.80 4,475.10 3,268.23 63.49 696.57 38.19 658.38 2.71 219.96 18.239 Pass- 4,800.00 3,946.27 25.88 4,495.06 3,273.28 63.99 701.59 37.24 664.35 4.03 222.30 18.839 Pass- 4,825.00 3,957.66 25.96 4,514.77 3,278.29 64.46 706.59 36.32 670.27 5.33 224.60 19.456 Pass- 4,850.00 3,968.70 26.05 4,534.25 3,283.26 64.87 711.57 35.43 676.14 6.60 226.86 20.084 Pass- 4,875.00 3,979.39 26.14 4,553.56 3,288.21 65.27 716.56 34.60 681.96 7.85 229.08 20.713 Pass- 4,900.00 3,989.74 26.23 4,572.69 3,293.13 65.67 721.56 33.82 687.74 9.07 231.26 21.335 Pass- 4,925.00 3,999.72 26.31 4,591.62 3,298.03 66.07 726.59 33.11 693.48 10.27 233.40 21.943 Pass- 4,950.00 4,009.34 26,40 4,610.35 3,302.89 66.46 731.66 32.48 699.18 11.44 235.51 22.527 Pass- 4,975.00 4,018.59 26.49 4,628.87 3,307.72 66.85 736.79 31.93 704.86 12.59 237.57 23.076 Pass- 5,000.00 4,027.47 26.59 4,647.17 3,312.51 67.23 741.99 31.47 710.53 13.71 239.60 23.580 Pass- 5,025.00 4,035.97 26.68 4,665.23 3,317.26 67.61 747.28 31.10 716.18 14.80 241.58 24.029 Pass- 5,050.00 4,044.09 26.77 4,683.06 3,321.96 67.98 752.67 30.83 721.84 15.86 243.53 24.416 Pass- 5,075.00 4,051.83 26.87 4,699.37 3,326.29 68.32 758.17 30.65 727.52 16.82 245.37 24.736 Pass- 5,100.00 4,059.18 26.98 4,716.28 3,330.77 68.70 763.81 30.57 733.24 17.79 247.21 24.989 Pass- 5,125.00 4,066.14 27.07 4,731.69 3,334.84 69.04 769.63 30.57 739.06 18.66 248.94 25.175 Pass- 5,150.00 4,072.70 27.18 4,746.76 3,338.82 69.38 775.63 30.66 744.97 19.49 250.63 25.300 Pass- 5,175.00 4,078.87 2729 4,761.49 3,342.69 69.71 781.83 30.82 751.01 20.29 252.26 25.369 Pass- 5,200.00 4,084.63 2741 4,775.86 3,346.46 70.03 788.25 31.05 757.20 21.04 253.85 25.387 Pass- 5,225.00 4,089.99 27.52 4,789.86 3,350.13 70.34 794.88 31.36 763.52 21.75 255.40 25.348 Pass- 5,250.00 4,094.95 27.63 4,803.50 3,353.70 70.65 801.75 31.72 770.03 22.42 256.89 25.273 Pass- 5,275.00 4,099.49 27.76 4,816.77 3,357.16 70.95 808.86 32.14 776.72 23.04 258.33 25.168 Pass- 5,300.00 4,103.63 27.90 4,829.66 3,360.52 71.23 816.22 32.59 783.63 23.61 259.72 25.043 Pass- 5,325.00 4,107.35 28.03 4,842.17 3,363.77 71.51 823.84 33.10 790.74 24.14 261.06 24.890 Pass- 5,350.00 4,110.66 28.17 4,854.30 3,366.91 71.78 831.72 33.63 798.09 24.62 262.34 24.730 Pass- 08 June,2015-21:39 Page 8 of 12 COMPASS • • Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan MPL-49/MPL-49 wp3 Closest Approach 3D Proximity Scan on Current Survey Data(Highside Reference) Offset Design:M Pt L Pad-MPL-45-MPL-45 Sean Range:0.00 to 12,374.30 usft.Measured Depth. Scan Radius is 1,434.43 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 5,375.00 4,113.71 28.32 4,866.17 3,369.98 72.05 839.95 34.17 805.78 25.31 263.14 24.582 Pass- 5,400.00 4,116.76 28.48 4,878.00 3,373.04 72.31 848.67 34.71 813.96 26.04 263.87 24.449 Pass- 5,425.00 4.119.80 28.65 4,892.26 3,376.71 72.63 857.86 35.39 822.47 26.90 264.73 24.242 Pass- 5,450.00 4,122.85 28.83 4,902.06 3,379.24 72.90 867.49 35.87 831.61 27.50 265.33 24.182 Pass- 5,475.00 4,125.90 29.02 4,914.46 3,382.43 73.23 877.55 36.46 841.09 28.24 266.07 24.072 Pass- 5,500.00 4,128.94 29.23 4,926.85 3,385.61 73.57 888.03 37.11 850.92 28.98 266.81 23.930 Pass- 5,525.00 4,131.99 29.44 .4,939.26 3,388.80 73.90 898.91 37.75 861.17 29.72 267.55 23.815 Pass- 5,550.00 4,135.04 29.66 4,951.66 3,391.99 74.24 910.18 38.40 871.78 30.45 268.28 23.700 Pass- 5,575.00 4,138.08 29.91 4,964.08 3,395.17 74.57 921.82 39.08 882.74 31.17 269.00 23.586 Pass- 5,600.00 4,141.13 30.17 4,976.50 3,398.35 74.91 933.82 39.78 894.04 31.89 269.72 23.473 Pass- 5,625.00 4,144.18 30.43 4,988.92 3,401.54 75.24 946.16 40.48 905.68 32.60 27043 23.372 Pass- 5,650.00 4,147.22 30.70 5,001.35 3,404.72 75.58 958.84 41.20 917.64 33.31 271.14 23.274 Pass- 5,675.00 4,150.27 30.99 5,013.78 3,407.90 75.92 971.83 41.93 929.90 34.01 271.84 23.178 Pass- 5,700.00 4,153.32 31.30 5,026.22 3,411.09 76.25 985.13 42.67 942.45 34.71 272.54 23.085 Pass- • 5,725.00 4,156.36 31.61 5,038.67 3,414.27 76.59 998.72 43.42 955.30 35.39 273.22 23.000 Pass- 5,750.00 4,159.41 31.93 5,051.12 3,417.45 76.93 1,012.59 44,18 968.41 36.07 273.90 22.917 Pass- 5,775.00 4,162.46 32.27 5,063.57 3,420.63 77.26 1,026.73 44.96 981.77 36.75 274.58 22.838 Pass- 5,800.00 4,165.50 32.61 5,076.03 3,423.81 77.60 1,041.13 45.74 995.39 37.42 275.25 22.761 Pass- 5,825.00 4,168.55 32.97 5,083.32 3,425.66 77.80 1,055.79 46.32 1,009.48 37.80 275.63 22.795 Pass- 5,850.00 4,171.60 33.33 5,098.14 3,429.45 78.18 1,070.69 47.21 1,023.48 38.59 276.42 22.679 Pass- 5,875.00 4,174.44 33.82 5,108.42 3,432.09 78.45 1,085.72 47.80 1,037.92 38.61 276.45 22.713 Pass- 5,900.00 4,176.74 34.33 5,118.47 3,434.68 78.72 1,100.68 48.88 1,051.80 38.54 276.40 22.520 Pass- 5,925.00 4,178.50 34.42 5,128.28 3,437.21 78.97 1,115.55 49.82 1,065.73 38.47 276.34 22.391 Pass- 5,950.00 4,179.72 34.50 5,137.87 3,439.70 79.23 1,130.34 50.80 1,079.54 38.38 276.27 22.252 Pass- 5,975.00 4,180.39 34.58 5,147.22 3,442.13 79.47 1,145.05 51.80 1,093.25 38.29 276.19 22.103 Pass- 6,000.00 4,180.51 34.66 5,156.33 3,444.50 79.71 1,159.69 52.84 1,106.85 38.18 276.11 21.947 Pass- 6,025.00 4,180.09 34.76 5,165.21 3,446.82 79.94 1,174.25 53.91 1,120.33 38.07 276.01 21.780 Pass- 6,050.00 4,179.24 34.86 5.179.14 3,450.47 80.31 1,188.82 54.83 1,133.99 38.57 276.52 21.683 Pass- 6,075.00 4,178.35 34.97 5.183.50 3,451.62 80.40 1,203.60 55.08 1,148.51 38.79 276.73 21.850 Pass- 6,100.00 4,177.46 35.08 5,194.82 3,454.60 80.65 1,218.63 55.64 1,163.00 39.36 277.30 21.904 Pass- 6,125.00 4,176.57 35.20 5,206.13 3,457.59 80.90 1,233.89 56.20 1,177.69 39.92 277.86 21.955 Pass- 08 June,2015-21:39 Page 9 of 12 COMPASS • ! Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan MPL-49/MPL-49 wp3 Closest Approach 3D Proximity Scan on Current Survey Data(Highside Reference) Offset Design:M Pt L Pad-MPL-45-MPL-45 Scan Range: 0.00 to 12,374.30 usft.Measured Depth. Scan Radius is 1,434.43 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation(Ref.>Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No-Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (usft) (usft) Axis/2 (usft) (usft) Axis/2 (usft) (usft) (usft) Bearing Bearing Factor Warning 6,150.00 4,175.69 35.32 5,217.43 3,460.58 81.15 1,249.37 56.76 1,192.60 40.47 278.41 22.010 Pass- 6,175.00 4,174.80 35.45 5,228.73 3,463.58 81.40 1,265.05 57.32 1,207.73 41.02 278.96 22.068 Pass- 6,200.00 4,173.91 35.57 5,240.03 3,466.59 81.65 1,280.94 57.88 1,223.06 41.57 279.51 22.130 Pass- 6,225.00 4,173.02 35.71 5,251.32 3,469.60 81.90 1,297.02 58.45 1,238.57 42.11 280.05 22.190 Pass- 6,250.00 4,172.25 35.86 5,262.64 3,472.62 82.15 1,313.35 58.64 1,254.70 43.13 281.08 22.395 Pass- 6,275.00 4,171.99 36.00 5,274.10 3,475.70 82.40 1,330.14 58.71 1,271.43 44.42 282.39 22.655 Pass- 6,300.00 4,171.99 36.16 5,285.62 3,478.79 82.65 1,347.22 59.29 1,287.93 44.96 282.93 22.722 Pass- 6,325.00 4,171.99 36.32 5,297.15 3,481.90 82.91 1,364.46 59.88 1,304.58 45.49 283.46 22.786 Pass- 6,350.00 4,171.99 36.49 5,308.67 3,485.01 83.16 1,381.84 60.47 1,321.37 46.02 283.99 22.852 Pass- 6,375.00 4,171.99 36.66 5,320.19 3,488.13 83.42 1,399.37 61.06 1,338.31 46.55 284.52 22.919 Pass- 6,400.00 4,171.99 36.83 5,331.70 3,491.25 83.67 1,417.02 61.64 1,355.38 47.06 285.03 22.989 Pass- Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 30.00 700.00 MPL-49wp3 SRG-SS 700.00 5,856.42 MPL-49wp3 MWD+IFR2+MS+sag 5,856.42 12,374.30 MPL49wp3 MWD+IFR2+MS+sag Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor=Distance Between Profiles/(Distance Between Profiles-Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 08 June,2015-21:39 Page 10 of 12 COMPASS i I Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan MPL-49/MPL-49 wp3 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to As-Staked MPL-49 @ 47.00usft. Northing and Easting are relative to Plan MPL-49. Coordinate System is US State Plane 1927(Exact solution),Alaska Zone 04. Central Meridian is-150.00°,Grid Convergence at Surface is: 0.35°. Ladder Plot I I I 1 1 T T , 1 1 1 1 1 17) 150 0 Lo 0 — Q 10 0LEGEND N MPL-05,MPL-05,MPL-05 V7 MPL-09 wp3 C U B 50 1 22 1 1 1 U 1 I 1 0 1 0 1500 3000 4500 6000 7500 Measured Depth(1500 usft/in) 08 June,2015-21:39 Page 11 of 12 COMPASS 11 • Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan MPL-49/MPL-49 wp3 Clearance Factor Plot: Measured Depth versus Separation(Clearance)Factor 11.00---' - - -- --- ------- ----..- 10.00- -_ ----- _ . _ 6 9.00— 8.00— c 7.00—-- N 0 6.00— - U _ c 5.00— -- LEGEND La MPL-45,MPL-45,MPL-45 V7 4.00—__ —.. V) _ 3.00—..- 2.00_ Collision Avoidance Req =�IZone-Stop Drilling ----. 1.00 0.00 iiiiiii , 1111111111111111+1 iii 1111 1111 1111 1111 iiia iiia 111 /11111 1111 `111 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 MessUBd Depth(150018tVi1) 08 June,2015-21:39 Page 12 of 12 COMPASS • • Bettis, Patricia K (DOA) From: Keith Elliott <kelliott@hilcorp.com> Sent: Tuesday, June 23, 2015 4:52 PM To: Luke Keller Cc: Bettis, Patricia K (DOA) Subject: RE: MPU L-49: Permit to Drill Application No, we will not pre-produce. From: Luke Keller Sent: Tuesday, June 23, 2015 1:58 PM To: Keith Elliott Cc: 'Bettis, Patricia K (DOA)' Subject: FW: MPU L-49: Permit to Drill Application Keith, Are you planning on pre-producing MPU L-49 prior to injecting water? Luke From: Bettis, Patricia K (DOA) [mailto:patricia.bettisftalaska.gov] Sent: Tuesday, June 23, 2015 1:57 PM To: Luke Keller Subject: MPU L-49: Permit to Drill Application Good afternoon Luke, Does Hilcorp plan to pre-produce MPU L-49, and if so,for what duration? 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: Bettis, Patricia K (DOA) Sent: Tuesday,June 23, 2015 1:57 PM To: Luke Keller(Ikeller@hilcorp.com) Subject: MPU L-49: Permit to Drill Application Good afternoon Luke, Does Hilcorp plan to pre-produce MPU L-49, and if so,for what duration? 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: Wyatt Rivard <wrivard@hilcorp.com> Sent: Tuesday,June 23, 2015 10:44 AM To: Bettis, Patricia K(DOA) Subject: MPU L-49 (PTD#215-099): PTD Area Of Review Attachments: MPL-49 AOR_6-22-15.docx Hello Patricia, I have included an Area Of Review to supplement the PTD application for the proposed grass roots injector, MPL-49.The attached AOR should address any questions regarding the cement and casing integrity of MPL-49 in addition to the single existing well found within the 1/4 mile radius of MPL-49's entry into the Schrader Bluff OA. Future injector PTD applications will include an AOR with the application. Please call with any questions. Thank You, Wyatt Rivard I WeII Integrity Engineer 0: (907) 777-8547 ( C: (509)670-8001 i wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 14100 I Am;ho age,AK 9950:3 ,k Loktt 11,1 1 AfEJJ (/43// Area of I . Proposedview — MPL-49 Injection Well Prior to completion of the MPL-49 Schrader Bluff OA injection well, an Area of Review (AOR) must be conducted. This AOR found one other well, MPL-42, within 1/4 mile of MPL-49's entry into the SB OA formation. The tables below illustrate the wells within the AOR, the distance from MPL-49, completion details and integrity conditions based on in-depth review of each well. Table 1: Wells within AOR Well Name PTD Distance, Ft. Annulus Integrity MPL-49 2150990 0' 9-5/8 casing to be cemented from injection zone to surface as per drilling program page 23. MIT-IA of 2- 3/8" by 9-5/8" Annulus to be completed to 1500 psi. MPL-42 1980180 950' Long term SI injector with slow TBGxIA communication but good cement isolation of 9-5/8" from SB OA to surface. Table 2: Completion Detail Well Name Casing Size Hole Size Vol Cement Schrader Bluff OA Depth MPL-49 9-5/8" 12-1/4" "'632 5819' MPL-42 9-5/8" 12-1/4" 715 bbls 5416' MPL-49 (Figure 2) is designed to meet all requirements for injector construction per 20 AAC 25.412. 9-5/8" surface casing will be run to 5856' and cemented to surface as per "Milne Point Unit (MPU) L-49 Drilling Program"pages 23-27. Cementing will be conducted in two stages with the first stage circulating 264 bbls of cement up from the shoe at "5856'. A second stage of ^'368 bbls of cement will be circulated through a cementer at "2300' with roughly 150 bbls excess cement expected at surface. With the casing cemented to surface,the 9-5/8" provides cement isolation of the Schrader Bluff OA from the well's entry into the formation at 5819' to surface. The well may pass through a single known fault at roughly 7900' MD that terminates vertically at approximately 2000' TVD. If encountered, the production liner will be isolated across the fault with swell packers. An MIT-IA to 1500 psi will be completed as per "Milne Point Unit (MPU) L-49 Drilling Program"page 36. Additional AOGCC witnessed MIT-lAs, monitoring and mechanical integrity notifications will be performed as per the requirements of Area Injection Order 10-B. L-42 MPL-42 (Figure 3) is a Kuparuk River water injector shut-in since October, 2007. The well had a OA passing AOGCC witnessed MIT-IA on 10/12/07 but was subsequently SI for slow TBGxIA pressurization. The well has a 9-5/8" surface casing run to 5928' MD and cemented to surface. 5-0(.; The completion enters the Schrader bluff OA at 5416'. Cementing was performed in two stages with an initial 283 bbls circulated up from the shoe at 5928ft followed by an additional 432 bbl 2nd stage circulated through a cementer at 2130'. The plugs were bumped in both stages and the rig maintained good returns to surface throughout the entire job. Approximately 140 bbls of excess cement were circulated back to surface. 7" production casing was then run and cemented by circulating 51 bbls of class G cement up from the shoe at 11,493. The estimated TOC of 9235' provides over 1600' of isolation above the well's entry into the Kuparuk River formation at 10840'. L-zi w 3 L-05 •-29 ��\ -09 F- • 9999 L-04 L-09A 1-06 N 3 10 L- • -— --T L-03 • I .-28 � I 141, 1 lir ' i Lala" L-12 ' /� L / S Pro , p L-49.1/•s-, ) ``\ , / I -- . HIL - �.• �,�r/ CORP ALASKA LLC .-37A MILNE POINT FIELD AOR MAP L-37 L-45 Proposed L-49 miecca Wel 1 123 2218 FEET WELL SYMBOLS _ • AaMa D&A A W Wel(WSW Flood) Pana 011,4 Jmareor.e ti.m. — REMARKS .......— WellSymbd=Tap Sc t a OA Sm0 8 ack bny Uash e'de-.,.31y Padua rmm L 490A lop Jur 19.2016 Figure 1:Schrader Bluff OA Map Illustrating AOR • • AFE No. Well Name: KB: 30 ft AGL 1511127 Milne Point Unit(MPU)L-49 GL*RKB 17 ft•30 ft=47 ft API C AFE WELLBORE DESIGN Proposed TO: 12,374' Permit No. Proposed TVD: 4,172' Geologic Information .,e,rare-'c'mat_r Casing Into/Mud Into i Hole Sae/Cement Specs Mud Program SS TVD FM Llthology Conductor PKe-Tubing.,anfe' 34"x 20"Insulated conductor(Pre-set)to 80'BGL(110'RKB) interval. I 9 E Irrer sleeve 20-x 0.375"Wan 78.6x.A-53.ERW,PE Soda.rwle c Exterior Jacket:34'x 0.344"Wan.123x.A-139.Grade 8 spiral PE Mg :Apr S O Fresh Watet/Native = Surface Casing weight Rave. v .. E g 9-518"470 1.80 TC-II set at 5856'MD,4172'TVD E P•9 2 0 • w E Ew Surface Casing Cement let Stage a13 lii 60 obis 70 5 ppg Tuned spacer III eo Lead:(50%OH Excess)ARCTICCEM Q 10.7 ppg 9 Tail.(50%OH Excess)SWIFTCEM 15.8 ppg c E o 0 7 n 2nd stage 1750' a 60 ibis 10.5 ppg Tuned spacer III 4 Lead:(Until returns at surface)ARCTICCEM 10.7 ppg Stage Tad SWIFTCEM 15.0 ppg gCo for Production Liner `a.‘4‘.. 5-12-170 L-80 DWC/C HT liner g 12,374'MD 14.172'TVD 4 g Injection Tubing Gu 9 2-7 "6.401.80 8RD EUE > cu 1= 1 W U 31 4 c c' g r r '-3500' • u 3/ K-sands Coarse sand,silty Liner Top Pkr.5656 ft Injection Control Ge.:e: shale,better mal. UGNU developed t i, Pioducaon 0100 L-Sands intervening shales ` rill .^ud Tjpe. -4000' M-sands in the L and M �_ S 81000.8 � � � uc>• � N-sands continued layering as - o t' o ,:e�4ltarge- Schnder In Ugnu,more ? o cr C j 8.9-9.1 dDP O-sands condensed with oc< MEM. - MI-4 coal .. N., Tr Swell Kiss 0.3/2'Injector L ne' Figure 2:MPL-49 Proposed Well Schematic • • Tree: 3 118"-5M CIW w Orig.KB Elev.= 45.7'(N 22E) Wellhead:11" 5M FMC Gen.5a wt MPU L-42 Orig.GL Elev,= 17.20' FMC Tbg.Hng.,threads top and RT To Tbg.Spool=26.9'(N 22E) bottom,3" CIW "H"BPV profile 20" 91.1 ppf.H-40 112 KOP @ 500' L 5"HES X-Nipple(2.813"id) 2,151' Max,hole angle=68 deg.@ 6,100' la& 60 deg.to 68 deg.(4,100'-9,100') �-- Hole angle thru'perfs=>31 deg. QA S A N 9 518 40 ppf.L-80 Btrc. 5928' , • 7"26 ppf,L-80,NSCC production casing (drift ID=6.151",cap.=0.0383bpf) 3.5'9.3 ppf,L-80 NSCT tubing (cap.=0.0087 bpf,drift=2.867') 4 ,3 5"HES X-Nipple t 2 813',d} 10,947' soft 7"x 3.5"Baker S-3 Perm pkr. 10.982' Stimulation Summary j3.5'HES XN-Nipple(2.750'id) 10.996' II WLEG 11,004' Perforation Summary Ref log: LWD 2121198 Size SPF Interval (TVD) KM�_B 4.5' 5 11,048'-11,068 7,081'-7,092' -- Kun A 4.5' 5 11,098'-11,158' 7,123'-7,174' !� Deep penetrating charges @ 60/120 deg.phasing a A 7"float collar(PBTD) 11,407' 7"float shoe 11,493' DATE REV.BY COMMENTS MILNE POINT UNIT 03/06/98 MDO Drilled and cased&completed 22E WELL L-42i API No: 50-029-22862 BP EXPLORATION (AK) Figure 3:MPL-42 Well Schematic • • • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent Tuesday,June 30, 2015 1:27 PM To: Luke Keller Cc: Bettis, Patricia K(DOA) Subject: L-49 PTD 215-099 Luke, I had a question regarding the 2nd stage cement on the 9 5/8" . There is no cement type listed for either the lead or tail. Why not just ArticCem for entire 2nd stage?Can you specify those cement types and ropertie-M-0%-&-- , !/Z Sr s r4q I was thinking about a CBL but the use of 10.7 ppg in the first stage would make it hard to verify that set t on with any conventional CBL tools. Although the bottom 1000'will have 15.8 ppg which should show up. I am inclined to require the CBL and just log the bottom part of the casing to verify good shoe integrity. • / Please supply a diagram of the planned wellhead also. Regards, r 'l-5 Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226)or(Guv.schwartz@alaska.aov). 1 • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Friday,June 12, 2015 2:06 PM To: Luke Keller(Ikeller@hilcorp.com) Subject: MPU L-49: Permit to Drill Application (215-099) Good afternoon Luke, Hilcorp needs to provide information that demonstrates compliance with all sections of 20 AAC 25.402. 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. t • TRANSMITTAL LETTER CHECKLIST WELL NAME: L- 1-1 `j PTD: °2)s-O/ Development /Service _Exploratory _Stratigraphic Test _Non-Conventional FIELD: / l i/l L Ain]_ POOL: 4/1L/ j/1 L �dI�1 G J'eAc ! •/JaC. ad) 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 er 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 0 • C ❑ To N O) o a) 0- us 6 a) D _• _ ' , ' ' , ci: o. ' O uy z, ' ' , , , ,, ' , ; z' W• v) , p. O, m. a) a a7. O' E O Z. d 1--,� , J O2 o op 0 ac ' O O7 ` o -1 c: CO o > 3. �: �. c' t o: y -a: c m, a a), o' -o: 0 c. I. o, N 07 0. �: 0. U. �: 3, W ti' �, _ a) j 1.0 v, •� c , , , (IY c; m. o 73, 3 a , ' _' (, , 3, , , 5 C1-' CD 2 O -0' a). o. m. o N. E, a `° o' °� N• a, N C' , 0, E. U. v): 0' a .N' N (O' $ V' a)' (O, • c LL, ' .� • , ' 8' m O' E, C ; d Cil 00 ' w' C. 2'. ; : ate)'. 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