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Home My WebLink About215-120MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, August 16, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC L-48 MILNE PT UNIT L-48 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/16/2024 L-48 50-029-23552-00-00 215-120-0 W SPT 4080 2151200 1500 60 60 60 63 4YRTST P Bob Noble 7/5/2024 Missed 4 year test due to being shut in. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:MILNE PT UNIT L-48 Inspection Date: Tubing OA Packer Depth 944 1712 1672 1662IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN240706091837 BBL Pumped:1.2 BBL Returned:1.2 Friday, August 16, 2024 Page 1 of 1 9 9 9 9 9 9 9 99 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.08.16 15:49:04 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: 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 13,212 feet N/A feet true vertical 4,147 feet N/A feet Effective Depth measured 13,206 feet feet true vertical 4,142 feet feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.2# / L-80 - EUE 8rd 6,136' 4,090' PHL, Liner Top & Packers and SSSV (type, measured and true vertical depth)Swell Packer (5) N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Operations Manager Contact Phone: Structural 6,895' 6,538'Conductor Surface 20" 9-5/8" 5-1/2" 80' 6,507' 13,211' 110' MILNE PT UNIT L-48 Plugs Junk measured Length Burst Collapse measured TVD N/A ADL0025509 / ADL0025515 MILNE POINT / SCHRADER BLUFF OIL Packer MDCasing STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 215-120 50-029-23552-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 1,6010 0 600 193 N/A 4,760psi 6,390psi 6,136, 6,316, 7,668, 8,903, 9,964, 10,867 & 11,843 4,026, 4,078, 4,136, 4,133, 4,102, 4,137 & 4,173 measured true vertical 1,140 6,870psi 7,740psi4,081' N/A 989 Size 110' 4,124' Water-BblOil-Bbl N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 324-237 PL G Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 11:16 am, Jul 30, 2024 Digitally signed by Scott Pessetto (9864) DN: cn=Scott Pessetto (9864) Date: 2024.07.30 10:12:26 - 08'00' Scott Pessetto (9864) RBDMS JSB 073124 WCB 11-7-2024 DSR-8/2/24 _____________________________________________________________________________________ TDF 7/29/2024 SCHEMATIC Milne Point Unit Well: MPU L-48 PTD: 215-120 TD =13,212’ (MD) / TD =4,142’(TVD) 20” RKB: 28.42’ 9-5/8” 1 7 See ICD & Swell Packer Detail PBTD =13,206’ (MD) / PBTD =4,112’(TVD) 9-5/8” ‘ES’ Cementer @ 2,382’ 4 2 3 5 6 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 78.6 / A-53 / Weld 19.25” Surface 80’ N/A 9-5/8" Surface 40 / L-80 / TC-II 8.681” Surface 6,538’ 0.0732 5-1/2” Liner 13.5 / L-80 / DWC/ C-T 4.892” 6,316’ 13,211’ 0.0149 TUBING DETAIL 3-1/2" Tubing 9.2 / L-80 / EUE 8rd 2.992” Surface 6,364’ 0.0087 JEWELRY DETAIL No Depth Item ID 1 2,096’ X Nipple 2.813” 2 3,007’ GLM w/ sheer valve set @ 2500 psi 2.920” 3 6,136’ PHL Packer 3.850” 4 6,363’ Ratcheting Muleshoe 3.500” 5 6,316’ Liner Top Packer 6.150” 6 6,343’ 7” x 5-1/2” XO 4.860” 7 13,206’ WIV Valve (Ball on Seat/Closed) OPEN HOLE / CEMENT DETAIL 20" 60bbls 15.6 ppg 9-5/8”"Stg #1 L- 11.7ppg/ 230bbls ; T- 15.8ppg/ 83bbls Stg #2 L- 10.7ppg/ 287bbls ; T- 15.8ppg/ 54bbls TREE & WELLHEAD Tree Seaboard 3 1/8" 5M Wellhead Seaboard 16 3/4" 3M x 11" 5M Multibowl w/11" x 9 5/8 casing hanger and seal ASSY. tubing hanger 3 1/2" EUE Top and Bottom with 3" CIW "H" BPV profile. Ported for 1ea 3/8" NPT control lines. GENERAL WELL INFO API#: 50-029-23552-00-00 Completed by Doyon 14 11-6-16 ICD DETAIL Top (MD) Btm (MD) 6,585.12’ 6,604.95’ 6,847.85’ 6,867.64’ 7,400.11’ 7,419.92’ 8,002.69’ 8,022.48’ 8,635.22’ 8,655.00’ 9,113.24’ 9,133.07’ 9,734.18’ 9,753.98’ 11,042.97’ 11,062.75’ 11,582.98’ 11,602.77’ 12,055.48’ 12,075.26’ 12,604.17’ 12,623.67’ 13,109.14’ 13,128.94’ SWELL PACKER DETAIL Top (MD) Btm (MD) 7,668.16’ 7,679.04’ 8,903.09’ 8,913.97’ 9,964.09’ 9,974.97’ 10,867.31’ 10,878.19’ 11,842.73’ 11,848.38’ Well Name Rig API Number Well Permit Number Start Date End Date MP L-48 Fullbore 50-029-23552-00-00 215-120 6/20/2024 7/1/2024 No operations to report. 2/0/0 MIT-IA 1825 psi, 5.7 bbls diesel to pressure up, 15 min IA lost 65 psi, 30 min IA lost 23 psi, 3.1 bbls recovered, FWP = 2/25/0. 6/22/2024 - Saturday Injection Test post Equiseal, Pumped 19 bbls diesel down tubing, pressured up to 700 psi. 6/25/2024 - Tuesday 6/23/2024 - Sunday No operations to report. 6/24/2024 - Monday 6/21/2024 - Friday T/I/O = Vac/0/0/. TBG FL = 858'. 6/19/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 6/20/2024 - Thursday T/I/O = 127/100/0. GOING OVER JSA AND JOB CALCULATIONS WITH ALL ESSENTIAL PERSONELL ON LOCATION ARRIval. PUMP 5bbls water down well to fluid pack lines. 1000 PSI LOW TEST/ 3.000 PSI HIGH TEST. PUMP EQUISEAL JOB. PUMP 45bbls of EQUISEAL & SPOT IN PERFS - SUCCESS. FWHP's = T/I/O =126/100/0. Well Name Rig API Number Well Permit Number Start Date End Date MP L-48 Fullbore 50-029-23552-00-00 215-120 6/20/2024 7/1/2024 No operations to report. No operations to report. 6/29/2024 - Saturday T/I/O=0/23/0 Injection test post Equiseal. Pumped 20 bbls diesel down TBG. Final Whps=500/80/0 7/2/2024 - Tuesday 6/30/2024 - Sunday No operations to report. 7/1/2024 - Monday 6/28/2024 - Friday No operations to report. 6/26/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary T/I/O = VAC/100/0. TBG FL SHOT = 650'. 6/27/2024 - Thursday No operations to report. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. You don't often get email from matthew.ross@hilcorp.com. Learn why this is important From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: MPL-48 (PTD# 215120) Return to Injection Date:Monday, June 24, 2024 9:49:16 AM Attachments:image001.png From: Matthew Ross <Matthew.Ross@hilcorp.com> Sent: Monday, June 24, 2024 8:49 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: OPERABLE: MPL-48 (PTD# 215120) Return to Injection To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: OPERABLE: MPF-74A (PTD# 2131890) Return to Injection Mr. Wallace – PWI well MPL-48 (PTD# 215120) was made Not Operable in November 2023 after missing its 4 year MIT-IA due to not being online. We will be bringing this well back on injection. The well will now be re-classified as OPERABLE and an AOGCC witnessed MIT-IA will be scheduled once on stable injection. Please respond with any questions. Thanks, Matthew Ross Sr. Wellsite Supervisor - Milne Point Matthew.ross@hilcorp.com Cell: 907-980-0552 / Office: 907-670-3387 Alternate: Derek Weglin The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 13,212'N/A Casing Collapse Conductor N/A Surface 4,760psi 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 AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng PHL, Liner Top & Swell Packer (5) and N/A Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 6,136MD / 4,026TVD, 6,316MD / 4,078TVD, 7,668MD / 4,136TVD, 8,903MD / 4,133TVD, 9,964MD / 4,102TVD, 10,867MD / 4,137TVD & 11,843MD / 4,173TVD and N/A Perforation Depth MD (ft): See Schematic See Schematic 3-1/2" 80' 20" 9-5/8" 5-1/2" 6,507' 6,895' MD N/A 6,870psi 7,740psi 4,124' 4,081' 6,538' 13,211' Length Size Proposed Pools: 110' 110' 9.2# / L-80 - EUE 8rd TVD Burst 6,364' MILNE POINT STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025509 / ADL0025515 215-120 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23552-00-00 Hilcorp Alaska LLC C.O. 477.05 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): April 29,2024 Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE PT UNIT L-48 SCHRADER BLUFF OIL N/A 4,142' 13,206' 4,142' 1,190 N/A No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:43 am, Apr 22, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.04.19 13:27:10 - 08'00' Taylor Wellman (2143) 324-237 SFD 1,190 10-404 4,147' MGR22APR24 SFD 4/22/2024 DSR-4/23/24*&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.04.25 10:29:59 -08'00'04/25/24 RBDMS JSB 042524 MPL-48 MBE treatment Well Name:MPL-48 API Number: 50-029-23552-00-00 Current Status:Not Operable – Shut in Rig:Cement pump / Coil Estimated Start Date:April 2024 Estimated Duration:1 day each Regulatory Contact:Tom Fouts Permit to Drill Number:215-120 First Call Engineer:Ryan Lewis 303-906-5178 Second Call Engineer:Taylor Wellman 907-777-8449 AFE Number: Job Type:MBE treatment Current Bottom Hole Pressure:1603 psi @ 4130’ TVD 7.5 PPGE | downhole gauge Max. Possible Surface Pressure:1190 psi (Based on 0.1 psi/ft. gas gradient) Min ID:2.813” ID @ 2,096’ MD Max Angle:91 Deg @ 13,113’ MD Brief Well Summary: L-48 is a Schrader Bluff OA injector supporting L-47. The injector experienced an MBE to L-47 on 12/13/2020. A low-pressure alarm shut down the injector, followed by an increased BHP and decrease in intake temperature in the producer L-47. L-47 experienced 100% WC on 12/14/2020 confirming MBE. An MBE treatment using H2Zero was pumped on 12/20/2020 targeting ICD #9 which successfully remediated the MBE. 10/30/21 L-47 has experienced another MBE. Shutting in L-48 resulted in immediate recovery of the WC observed in L-47. 6/15/22 IPROF on CT saw ICDs #1, #5 and #4, taking about 43%, 29% and 18% respectively. Objective: Pump and Equiseal job to heal the MBE. Wellbore Volume to MBE: Pipe Capacity Top Depth Bottom Depth Volume 3-1/2” Tubing .0087 bbl/ft 0 6,365’ 55.4 bbl 5-1/2” liner .0232 bbl/ft 6,365’ 6,585’ 5.1 bbl Wellbore Volume to 6,585’ 60.5 bbl x Frac gradient = 0.65 psi/ft x 6,585’ MD = 4,124’ TVD x Est BHT = 100 deg F x Current fluid level (3/8/24) 2,925’, vol.=25.5 bbls MPL-48 MBE treatment Procedure: Fullbore – Job simulation to verify flush volume (Non-sundried work) 1. MIRU Little Red Services (LRS). 2. Pressure test lines to 3,000 psi. 3. Shoot at Tubing Fluid level. 4. Pump 55 bbls of water followed by 25 bbls diesel, Freeze Protect. 5. RD LRS. 6. Shoot a fluid level at 3 hours and again 6 hours after pumping is complete. 7. Email all fluid level data to Ryan Lewis. Fullbore – (Sundried work) 1. RU Halliburton cementer. Pressure test lines to 3,000 psi. 2. Load well with 200 bbl of 1%KCl or source water at 2 bpm. Watch L-46, L-47 and F-107 BHP gauge looking for an MBE. 3. Prior to pumping gel treatment, ensure MPL-46, L-47 and F-107 are shut in to prevent pumping the gel directly to the producer. 4. Pump the following gel treatment down the tubing at 2bpm keeping pressure below 850psi. Estimated pump time ~1 hr. a. 50 bbl of Equiseal – catch a sample of the gel in a bottle and leave in the wellhouse. b. 5 bbl base brine c. 25 bbl of diesel i. With a bottomhole pressure of 1600psi and a full column of diesel, the fluid level should settle out around 2,925’ (25.5 bbl). The displacement volume is 30 bbl to under-displace by 5bbl and account for the 25.5 bbl of fluid falling out. 5. At 75 bbl away, slow rate to 1.5 bpm. 6. At 80 bbl away, slow rate to 0.75 bpm. 7. Shutdown at 85 bbl away. 8. Leave Halliburton rigged up. 9. RU SL to tag fluid level. 10. 3 hours after pumping is complete, RIH with SL to tag fluid level and Equiseal level. 11. Call Ryan Lewis 303-906-5178 with the results and we will pump additional fluid to place the Equiseal on depth. The goal is to spot the top of the Equiseal at 6,365’ MD (5 bbls short of the top ICD). We have in the range of 3-6 hours before the crosslinker starts to build viscosity. Operations - 12. Prior to RTP L-46, L-47 and F-107 allow gel to set up 12 hours minimum. RTP draw the well down no more than 50-100 psi at a day. 13. Prior to POL of L-48. Let gel set up for 3 days. 14. Put a 1-2 bbl neat methanol spear in the well. a. Methanol will prevent water from slushing up when it touches cold diesel. 15. Attempt to put well on injection at target rate of 1500 bwpd but no more than 700 psi, by walking rate up in 500 bwpd increments for 15 minutes each. a. There is a chance the Equiseal has formed a plug in the liner and will need to be jetted out with coil. b. If well locks up, the diesel displacement from the gel treatment should swap out with any water and leave the well freeze protected. MPL-48 MBE treatment Coil – Cleanout if desired injection rate not achieved. Check out the gel in the sample bottle. It does not have compressive strength and should be removed with jetting action. 16. RIH with JSN and jet through the Equiseal with 1% KCl or source water. Make sure the nozzle has good up jets for getting back through Equiseal. a. Deepest Equiseal depth is 8,525’ if all 50bbl stayed in the wellbore. Attachments: 1.Wellbore Schematic _____________________________________________________________________________________ TDF 3/12/2024 SCHEMATIC Milne Point Unit Well: MPU L-48 PTD: 215-120 TD =13,212’ (MD) / TD =4,142’(TVD) 20” RKB: 28.42’ 9-5/8” 1 7 See ICD & Swell Packer Detail PBTD =13,206’ (MD) / PBTD =4,112’(TVD) 9-5/8” ‘ES’ Cementer @ 2,382’ 4 2 3 5 6 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 78.6 / A-53 / Weld 19.25” Surface 80’ N/A 9-5/8" Surface 40 / L-80 / TC-II 8.681” Surface 6,538’ 0.0732 5-1/2” Liner 13.5 / L-80 / DWC/ C-T 4.892” 6,316’ 13,211’ 0.0149 TUBING DETAIL 3-1/2" Tubing 9.2 / L-80 / EUE 8rd 2.992” Surface 6,364’ 0.0087 JEWELRY DETAIL No Depth Item ID 1 2,096’ X Nipple 2.813” 2 3,007’ GLM w/ sheer valve set @ 2500 psi 2.920” 3 6,136’ PHL Packer 3.850” 4 6,363’ Ratcheting Muleshoe 3.500” 5 6,316’ Liner Top Packer 6.150” 6 6,343’ 7” x 5-1/2” XO 4.860” 7 13,206’ WIV Valve (Ball on Seat/Closed) OPEN HOLE / CEMENT DETAIL 20" 60bbls 15.6 ppg 9-5/8”"Stg #1 L- 11.7ppg/ 230bbls ; T- 15.8ppg/ 83bbls Stg #2 L- 10.7ppg/ 287bbls ; T- 15.8ppg/ 54bbls TREE & WELLHEAD Tree Seaboard 3 1/8" 5M Wellhead Seaboard 16 3/4" 3M x 11" 5M Multibowl w/11" x 9 5/8 casing hanger and seal ASSY. tubing hanger 3 1/2" EUE Top and Bottom with 3" CIW "H" BPV profile. Ported for 1ea 3/8" NPT control lines. GENERAL WELL INFO API#: 50-029-23552-00-00 Completed by Doyon 14 11-6-16 ICD DETAIL Top (MD) Btm (MD) 6,585.12’ 6,604.95’ 6,847.85’ 6,867.64’ 7,400.11’ 7,419.92’ 8,002.69’ 8,022.48’ 8,635.22’ 8,655.00’ 9,113.24’ 9,133.07’ 9,734.18’ 9,753.98’ 11,042.97’ 11,062.75’ 11,582.98’ 11,602.77’ 12,055.48’ 12,075.26’ 12,604.17’ 12,623.67’ 13,109.14’ 13,128.94’ SWELL PACKER DETAIL Top (MD) Btm (MD) 7,668.16’ 7,679.04’ 8,903.09’ 8,913.97’ 9,964.09’ 9,974.97’ 10,867.31’ 10,878.19’ 11,842.73’ 11,848.38’ CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: MPL-48 (PTD# 215120) Missed AOGCC Witnessed MIT-IA Date:Tuesday, November 28, 2023 4:30:42 PM From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Tuesday, November 28, 2023 3:31 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: NOT OPERABLE: MPL-48 (PTD# 215120) Missed AOGCC Witnessed MIT-IA Mr. Wallace – PWI well MPL-48 (PTD# 215120) is currently shut in and will not be brought online for its scheduled 4 year MIT-IA due this month. The well will now be classified as NOT OPERABLE and will remain shut in. A witnessed MIT-IA will be scheduled once the well is returned to injection. Please respond with any comments or concerns. Thanks, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Kaitlyn Barcelona Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564-4422 Received By: Date: Date: 07/18/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL Well API # PTD # Log Date Log Company Log Type Notes AOGCC Eset # MGS D1-06 50733200420000 167052 07/03/2022 Read LEAK + Report MGS D1-18 50733204600000 194098 07/04/2022 Read LEAK + Report MPU L-48 50029235520000 215120 06/27/2022 READ IPROF + Report Please include current contact information if different from above. T36801 T36802 T36803 Kayla Junke Digitally signed by Kayla Junke Date: 2022.07.19 09:05:46 -08'00' Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 06/13/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU L-48 (PTD 215-120) IPROF 06/02/2022 Please include current contact information if different from above. PTD: 215-120 T36696 Kayla Junke Digitally signed by Kayla Junke Date: 2022.06.17 09:18:05 -08'00' 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: 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): 13,212'N/A Casing Collapse Conductor N/A Surface 4,760psi 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 AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE AOGCC Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng 4,142'13,206'4,142'889 N/A 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Operations Manager Taylor Wellman twellman@hilcorp.com 907-777-8449 Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: PHL, Liner Top & Swell Packer (5) and N/A See Schematic See Schematic 11/28/2021 3-1/2" 6,136MD / 4,026TVD, 6,316MD / 4,078TVD, 7,668MD / 4,136TVD, 8,903MD / 4,133TVD, 9,964MD / 4,102TVD, 10,867MD / 4,137TVD & 11,843MD / 4,173TVD and N/A PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025509 / ADL0025515 215-120 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23552-00-00 Hilcorp Alaska LLC MILNE PT UNIT L-48 MILNE POINT / SCHRADER BLUFF OIL C.O. 477.05 110' 9.2# / L-80 - EUE 8rd TVD Burst 6,364' N/A 6,870psi 7,740psi 4,124' 4,081' 6,538' 13,211' Length Size 110' MD 6,895' Perforation Depth MD (ft): 80' 20" 9-5/8" 5-1/2" 6,507' ry Statu Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:44 am, Nov 19, 2021 321-598 Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2021.11.19 09:20:04 -09'00' David Haakinson (3533) DSR-11/22/21SFD 11/19/2021 10-404 MGR21NOV21dts 11/23/2021 11/23/21 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2021.11.23 14:11:16 -09'00' RBDMS HEW 11/24/2021 IPROF/MBE Treatment Well: MPU L-48 Date: 11/15/2021 Well Name:MPU L-48 API Number:50-029-23552-00 Current Status:Shut in – MBE Pad:L-Pad Estimated Start Date:11/28/2021 Rig:CTU Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:215-120 First Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Second Call Engineer:Brian Glasheen (907) 777-564-5277 (O) (907) 545-1144 (M) AFE Number: Job Type:MBE Cement Remediation Current Bottom Hole Pressure: 1,300 psi @ 4,111’ TVD (Based on L-47 producer SBHP on 10/13/21) MPSP:889 psi @ 4,111’ TVD (0.1psi/ft gas gradient) Max Deviation:95° @ 8,966’ MD Max Dogleg:8.61°/100ft @ 1,444’ MD Min ID:2.813” ID @ 2,096’ MD X Nipple Brief Well Summary: L-48 is a Schrader Bluff OA injector supporting L-47. The injector experienced an MBE to L-47 on 12/13/2020. A low-pressure alarm shut down the injector, followed by an increased BHP and decrease in intake temperature in the producer L-47. L-47 experienced 100% WC on 12/14/2020 confirming MBE. An MBE treatment using H2Zero was pumped on 12/20/2020 targeting ICD #9 which successfully remediated the MBE. Recently L-47 has experienced another MBE. Shutting in L-48 resulted in immediate recovery of the WC observed in L-47. Objective: 1) Run IPROF to determine which ICD is taking bulk of injection. 2) Pump H2Zero Conformance Treatment to remediate MBE between L-48i and L-47. 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 H2Zero causing stuck coiled tubing. o The use of a treatment packer should reduce risk of H2Zero 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 (3% KCl and H2Zero) to avoid early release of the treatment packers. x H2Zero Production in producer o Producer L-47 should be shut-in as the H2Zero is in the coiled tubing approaching the formation. Procedure: CTU: IPROF/MBE Treatment Well: MPU L-48 Date: 11/15/2021 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 BOPE test has not been completed in last 7 days, test BOPE to 250 psig low / 2,500 psig high. b. No AOGCC notification required. c. Record BOPE test results on 10-424 form. d. 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 to meet weekly BOPE test requirement. e. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. 3. Ensure Producer L-47 has been online for 48 hours and is ready to be shut in as H2Zero enters the formation. 4. Establish site control and a separate radio channel for crews so that a proper and clear communication can exist through the job. 5. MU CTC, DBCV, carrier and memory spinner (in-line/fullbore/press/temp) IPROF BHA. 6. RIH to deviation. Perform spinner calibration with well SI while RIH. 7. RIH to previous lock-up depth of ~9,800’ MD. Safe-Lube will be needed to reach PBTD. Main objective is to determine which ICD to treat through. a. While pumping Safe-Lube on 12/20/20 a depth of 13,175’ md was achieved. 8. Perform baseline pass, logging up at ±120 FPM to 6,400’ MD. 9. Bring L-48 on injection at 1,200 BWPD rate. DNE 750 psi WHIP. 10. RIH to lock-up depth. No choke changes while POOH 11. Perform up pass at ±120 FPM. 12. RIH to lock up depth. 13. Once at max depth, Increase injection to 1,200 BWPD. No choke changes POOH 14. POOH, obtaining 5 min stations at the following depths (referenced at fullbore spinner). Log at ±120 FPM between stations. a. 13,100’ MD b. 12,500’ MD c. 11,900’ MD d. 11,400’ MD – Flag Pipe at this depth e. 10,900’ MD f. 9,600’ MD g. 9,000’ MD h. 8,500’ MD – Flag Pipe at this depth i. 7,900’ MD j. 7,300’ MD k. 6,700’ MD– Flag Pipe at this depth l. 6,400’ MD 15. POOH and download data to confirm good data. Send data to Chris Gullet and Fanny Haroun for analysis. a. Note: Display CCL track from final Up pass/Flagging Run as main CCL display to be used for correlation. IPROF/MBE Treatment Well: MPU L-48 Date: 11/15/2021 16. MU treatment BHA with CT, CTC, and Baker Hughes dual treatment packer BHA. 17. RIH to below the target ICD and the appropriate flag. POOH to tie into the flagged pipe and correct depth based on the log. 18. Confirm with pumping crew that they are ready to mix H2Zero for pumping. 19. Once on depth, set the lower treatment packer (mid-element) at 5’ below the ICD connection below the target ICD to be treated. 20. Pump 0.5” ball to set the lowermost treatment packer. 21. Slack off weight slightly to confirm the lower packer is set. 22. Continue to pressure up in 500 psig stages until the burst disc pops at ~2,500 psig. The upper treatment packer should be set. 23. Begin injecting 3% KCl water down the CT for baseline injectivity. a. Target 700 psig CT pressure. Inject for a minimum 30 minutes to establish a baseline. b. DNE 895 psig coiled tubing injection pressure. 24. Contact engineering with injectivity results. This testing is meant to confirm that we have injectivity through the ICD. 25. Mix ±30 bbls of 8.6ppg H2Zero and pump to formation. a. Volume assumptions: i. 0.041 bbl/ft annular hole volume for 8.5” hole and 5.5” Liner. ii. Distance between ICD’s ~600’. Annular hole volume ~24.6 bbls. 26. Pump H2Zero as slow as practicable to reduce fracture potential and allow for the cement to take the path of least resistance into the MBE feature.DNE 0.7 BPM. 27. Flush cement with source water spacer. 28. Displace water 1 bbl past ICD into formation to clear the wellbore. a. Discuss w/ engineer contingency plans if screenout/formation lockup occurs for how much H2Zero is placed and if to PU to release packers and jet out or to hesitation squeeze into place. 29. After displacement of the H2Zero, reduce fluid injection into the well as much as possible. 30. PU 5,500 lb-force to release the packers.Allow the elastomers to relax prior to pulling up-hole. 31. POOH to 2,000’ MD. Freeze protect well, circulating fluid in at 1:1 returns while accounting for pipe displacement. 32. Allow L-48’s H2Zero to setup for 18-21 days prior to returning the well to injection. 33. RDMO Coiled Tubing Attachment: 1 Schematic 2 BOPE Schematic ___________________________________________________________________________________ Updated by NLW 0 8/08/21 SCHEMATIC Milne Point Unit Well: MPL-48 PTD: 215-120 API: 50-029-23552-00-00 RKB: 28.42’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 47 L-80 TC II 8.681” Surf 6,538’ 5-1/2" Prod Liner 17 L-80 DWC/C HT 4.892” 6,316’ 13,211’ TUBING DETAIL 3-1/2” Tubing 9.2 L-80 EUE 8rd 2.992” Surf 6,364’ 20” 9-5/8” shoe @ 6,538’ JEWELRY DETAIL No. Item Top MD Btm MD ID OD 1 Tubing Hanger 28.42’ 28.84’ - - 2 X Nipple (X-lock w/ dual gauges, OAL = 83” 8/8/21)2,095.80’ 2,097.42’ 2.813” 4.493” 3 Stage Tool – ES Cementer 2,382’ 2,386’ 8.618” 9.625” 4 GLM w/ sheer valve set @ 2500 psi 3,007’ 3,016’ 2.920” 4.500” 5 PHL Packer 6,136’ 6,144’ 3.850” 8.450” 6 Ratcheting Muleshoe 6,363’ 6,365’ 3.500” 4.688” 7 Liner Top Packer 6,316’ 6,338’ 6.150” 8.290” 8 7” x 5-1/2” XO 6,343’ 6,346’ 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” 11 WIV Valve (Ball on Seat/Closed) 13,206’ 13,209’ - 5.000” SWELL PACKER DETAIL Top (MD) Btm (MD) 7,668.16’ 7,679.04’ 8,903.09’ 8,913.97’ 9,964.09’ 9,974.97’ 10,867.31’ 10,878.19’ 11,842.73’ 11,848.38’ 5-1/2” shoe @ 13,211’ 1 2 3 4 5 6 8 7 9 10 ICD DETAIL Top (MD) Btm (MD) 6,585.12’ 6,604.95’ 6,847.85’ 6,867.64’ 7,400.11’ 7,419.92’ 8,002.69’ 8,022.48’ 8,635.22’ 8,655.00’ 9,113.24’ 9,133.07’ 9,734.18’ 9,753.98’ 11,042.97’ 11,062.75’ 11,582.98’ 11,602.77’ 12,055.48’ 12,075.26’ 12,604.17’ 12,623.67’ 13,109.14’ 13,128.94’ PBTD =13,206’ MD / 4,147’ TVD TD = 13,212’ MD / 4,147’TVD Max Deviation:º94.83 11 MILNE POINT UNIT MP L-48COIL BOPE Valve, Swab, WKM-M, 4 1/16 5M FE Valve, Upper Master, Baker, 4 1/16 5M FE, w/ Hydraulic 20 X 9 з X 7 X 4 ½ Coil Tubing BOP Valve, Lower Master, WKM-M, 4 1/16 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, 4 1/16 5M Pump-In Sub 4 1/16 5M 1502 Union 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 Hilcorp Alaska Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 13,212 feet N/A feet true vertical 4,142 feet N/A feet Effective Depth measured 13,206 feet feet true vertical 4,142 feet feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet PHL, Liner Top & Tubing (size, grade, measured and true vertical depth)Swell Packer (5) N/A See Above N/A Packers and SSSV (type, measured and true vertical depth)3-1/2" 9.2# / L-80 - EUE 8rd 6,364' 4,090' 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: WINJ WAG 0 Water-Bbl MD 110' 6,538' 13,211' TVD 110' 436 Oil-Bbl measured true vertical Packer 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 5301,604 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 215-120 50-029-23552-00-00 Plugs ADL0025509 / ADL0025515 5. Permit to Drill Number: MILNE POINT / SCHRADER BLUFF OIL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 646 Authorized Signature with date: Authorized Name: Abhijeet Tambe Abhijeet.Tambe@hilcorp.com 0 MILNE PT UNIT L-48 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 660 Casing Pressure Tubing Pressure 0 N/A measured N/A Casing Structural Size Junk measured Length 80' 6,507' 6,895' Conductor Surface 6,390psi Burst N/A 6,870psi 7,740psi 20" 9-5/8" 5-1/2" 4,124' 4,081' 4,026, 4,078, 4,136, 4,133, 4,102, 4,137 & 4,173 6,136, 6,316, 7,668, 8,903, 9,964, 10,867 & 11,843 777-8485 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse N/A 4,760psi PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 9:44 am, Jan 27, 2021 Chad A Helgeson 2021.01.27 12:17:30 -06'00'MGR18FEB2021 SFD 1/27/2021RBDMS HEW 1/29/2021 DSR-2/1/21 Well Name Rig API Number Well Permit Number Start Date End Date MP L-48 CTU 50-029-23552-00-00 215-120 12/19/2020 1/6/2021 Set treating packer to straddle ICD #9 and establish injectivity. Continue circulating 2% KCl until H2Zero is batched and ready. Pump 40bbls of H2zero into ICD #9 plus 1bbl KCL. POOH pumping pipe displacement up to ~ 6,000' and then inflatable packers started swabbing. Replace pipe disp w/ 60/40 when at surface. Lay down tools. Wait on winds to lower mast. Job complete. Fluids pumped: 40bbl H2zero, 224bbl slick 2%KCL w/ safelube, 15 bbl 2%KCL. 86.3bbl 60/40. MIRU CTU. Well POI at 1,500 bwpd. Make up 2.75" JSN Drift BHA and RIH. Pump 2% KCl w/ SafeLube and just injection rates for a total injection of ~1500 bwpd. Drift to TD tag at 13,175' down CTMD. Paint white TD flag at 13,133'. POOH. Fluids Pumped: 92 bbls Slick 2 % w/ SafeLube, 15 bbls 60/40 Methanol. 12/19/2020 - Saturday Summary: Change pack offs. Perform weekly BOP test 500psi Low/ 4,300psi High. Standby for IPROF interpretation. Town confirm ICD #9 is taking more injection than normal. Proceed with H2Zero treatment. MU/RIH with BOT dual treating packer BHA. Tie-in at the flag and begin to set the treating packer across ICD #9. Fluids pumped: Slick 2% KCl w/ SafeLube - 52 bbls , 60/40 Methanol - 41bbls. 12/22/2020 - Tuesday 12/20/2020 - Sunday POOH with drift BHA while keeping the well on injection targeting 1,500 bwpd. Make up Memory IPROF BHA and RIH while slipstreaming SafeLube and targeting 1,500 bwpd total injection. Perform spinner calibration passes from 6,400' to 6,500'. Perform station stops from bottom up. Perform dynamic passes up at 30 and 80 fpm. Paint treating packer correlation flag at 10,500' and POOH. Confirm Good data. Prepare for weekly BOP test. Fluids pumped: Slick 2% KCl w/ SafeLube- 504 bbls, 60/40 Methanol- 11 bbls 12/21/2020 - Monday 12/18/2020 - Friday No operations to report. 12/16/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 12/17/2020 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP L-48 LRS 50-029-23552-00-00 215-120 12/19/2020 1/6/2021 1/8/2021 - Friday No operations to report. 1/6/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Freeze Protect (MBE) (Pressure test surface lines 250/3,500psi) Pump 3 bbls 60/40 down Flow Line. Pump 31 bbls 60/40 down Tbg. Bleed Flowline to zero. 1/7/2020 - Thursday No operations to report. No operations to report. No operations to report. 1/9/2021 - Saturday No operations to report. 1/12/2021 - Tuesday 1/10/2021 - Sunday No operations to report. 1/11/2021 - Monday Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 01/11/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU L-48 (PTD 215-120) Injection Profile 12/20/2020 Please include current contact information if different from above. PTD: 2151200 E-Set: 34476 *Resubmittal* Received by the AOGCC 01/11/2021 Abby Bell 01/12/2021 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 12/28/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU L-48 (PTD 215-120) Injection Profile 12/20/2020 Please include current contact information if different from above. 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RWKHU WKLUG SDUW\ VRXUFHV 7KH LQIRUPDWLRQ PD\ QRW EH YDOLG XQGHU DOO FRQGLWLRQV QRU LI WKLV PDWHULDO LV XVHG LQ FRPELQDWLRQ ZLWK RWKHU PDWHULDOV RU LQ DQ\ SURFHVV )LQDO GHWHUPLQDWLRQ RI VXLWDELOLW\ RI DQ\ PDWHULDO LV WKH VROH UHVSRQVLELOLW\ RI WKH XVHU (QG RI 6DIHW\ 'DWD 6KHHW BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB 3DJH MEMORANDUM State of Alaska Permit Number: 215-120-0 Alaska Oil and Gas Conservation Commission TO: Jim Regg IZI DATE: Tuesday, December 3, 2019 P.I. Supervisor�1 3/"-, SUBJECT: Mechanical Integrity Tests Packer Depth Pretest Initial Hilcorp Alaska LLC Well L-48 FROM: Matt Herrera MILNE PT UNIT L-48 Petroleum Inspector 4029 Tubing Src: Inspector 783 Reviewed By: 283 P.J. Supry NON -CONFIDENTIAL Comm Well Name MILNE PT UNIT L-48 API Well Number 50-029-23552-00-00 Inspector Name: Matt Herrera Permit Number: 215-120-0 Inspection Date: 11/302019 ' Insp Num: mitMFH191130165403 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well L-48 Type Inj w TVD 4029 Tubing 784 783 783 283 PTD 2151z00 " Type Test SPT Test psi 1500 IA 518 1829 1774 - 7757 - -- BBL Pumped: 2.4 - BBL Returned: 2.3 OA o 0 0 0 Interval 4YRTST p/F P ✓ Notes: IA Pressure tested to 1800 PSI Per Operator Tuesday, December 3, 2019 Page 1 of l • /20 Hilcorp Alaska,LLC Post Office Box 244027 Anchorage,AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage,AK 99503 J lJ [U N 0 7 2 014 8 Phone: 907/777-8547 SCANNED June 5, 2018 RECEIVED Mr. Guy Schwartz II Alaska Oil and Gas Conservation Commission JUN 0 6 201 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501AOGCC Re: C onductor 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 ` • • 1 1 1 1 N Cl) a) a) a) a) a) a) a) a) a) a) a) a) a) a) a) _ _ C C C C C C CCC C C cc J J J J J J J J J J J J J C C C °- CC C C C C C C C C C C L V V r• o D D D D D D D D M D D 2 2 a) a) a) a) a) a) a) a) a) a) Cl) a) a) Q. Q a ct ce w CLECCta! 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In N d m m m m m m —) Y J J J ' ' a. a a_ a_ a_ a. a. a a_ a_ a_ a. a_ u) u) 2 2 2 2 2 2 2 2 2 2 2 2 2 Z Z • • 215120 Debra Oudean Hilcorp Alaska, LLC 2 8 0 9 GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Hili±nrp 11:erka.1,1.{: RECEIVED Fax: 907 777-8510 E-mail: doudean@hilcorp.com SEP 21 2017 DATE 09/21/2017 AOGCC -,\TA LOGGED 15/2011 BENDER To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SCANNED FEB 2plg MPU L-48 Prints: Memory Production Profile GR/CCL/PRESS/TEMP/SPINNERS CD's HILCORP MPL-48 PPROF 29AUG17 FINAL Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: • or 7,4 •• \�\I j/y��A THE STATE Alaska Oil and Gas ,..11%!, tal OfA Conservation Commission — 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 044'ALnS� Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager Hilcorp Alaska,LLCSCANNED AUG 1 6 x.01 t, 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU L-48 Permit to Drill Number: 215-120 Sundry Number: 317-330 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 S Chair DATED this day of August, 2017. RBDMS �-` AUG 9 2017 • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUL 1 7 017 APPLICATION FOR SUNDRY APPROVALS 071 el ill 7 20 MC 25.280 AOGCC 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: Polymer Injectivity Trial 0 • 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC ' Exploratory ❑ Development ❑ 215-120 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service Q , 6.API Number: Anchorage Alaska 99503 50-029-23552-00-00 • 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-48 , 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025509/ADL0025515 " MILNE POINT/SCHRADER BLUFF OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 13,212'- 4,147' 13,206' 4,147' j 5-6' N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 110' 110' N/A N/A Surface 6,507' 9-5/8" _ 6,538' 4,124' 6,870psi 4,760psi Production 6,895' 5-1/2" 13,211' 4,081' 7,740psi 6,390psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic / See Schematic 3-1/2" 9.2#/L-80-EUE 8rd 6,364' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 6,136MD/4,026TVD,6,316MD/4,078TVD,7,668MD/4,1 6TVD,8,903MD/ 4,133TVD,9,964MD/4,102TVD, 10,867MD/4,173TVD&11,843MD/4,173TVD and PHL,Liner Top&Swell Packer(5)and N/A N/A 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service Q 14.Estimated Date for 15.Well Status after proposed work: 8/2/2017 Commencing Operations: OIL ❑ WINJ ❑✓ - WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and 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: pchant hiIcorp.com Contact Phone: 777-8333 Authorized Signature. Date: i ?' �r.�.7 •11 ,•. COMMISSION USE ONLY Conditions of approval: otify Commission so that a representative may witness Sundry Number: •3 7 33 c Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance �I�^El Other: l 0 V 010.6""2"a-u_.. ,....-t-,_ cxLGG_6:^.32�--h oma_. a.�f A 1 o /0 6 I I Post Initial Injection MIT Req'd? Yes ❑ No ❑ r Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: /0 y 0,1RBDIVI$ .---AUG " 9 2017 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: �i 11-1 — �44)k / o I '4cji Subs in Dup andForm 10-403 Revised 4/2017 113Na valid for 12 months from the date of approval. Attachmentmit Duplicate • • Well Prognosis Well: MPU 1-49 Iiae,,T„aide.,,LL( Date:05/24/2017 Well Name: MPU L-48 API Number: 50-029-23552-00 Current Status: Water Injector Pad: L-Pad Estimated Start Date: September 1, 2017 Rig: n/a Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 215-120 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 Number: Job Type: Polymer lnjectivity Trial Current Bottom Hole Pressure: N/A Maximum Expected BHP: N/A MPSP: 1200— 1500 psi (Estimated polymer injection pressure range) Brief Well Summary: MPU L-48 was drilled and completed in November 2015 as a horizontal Schrader Bluff OA sand injector. Objective: Hilcorp Alaska seeks approval to perform up to "'30 day polymer injection test into the L-48 injector at Milne Point. The purpose of this trial is to test the injectivity of multiple molecular weight polyacrylamide polymers into the Schrader OA sand. The results from the test will support a feasibility study of a 7-injector polymer flood pilot project in the Schrader OA sand at Hilcorp's Moose Pad. Procedure: 1. MIRU polymer injection skid and support equipment. 2. RU hoses from frac tanks to polymer injection skid. 3. RU hard lines from polymer injection skid to tree. 4. Pressure test hard lines to 3,000 psi. 5. Begin polymer injectivity test with polyacrylamide polymer. 6. Conclude polymer injectivity test. 7. RDMO polymer injection skid and equipment. Attachments: 1. Wellbore Schematic Milne Point Unit H . iil Well: MPL-48 SCHEMATIC PTD: 215-120 A API: 500-029029-2355 2-00-00 Hibor,Alaska,LLA, RKB:28.42' CASING DETAIL 20 � A ' Size Type Wt Grade Conn. ID Top Btm 20" Conductor 78.6 A-53 Weld 19.25" Surf 110' 9-5/8" Surf. Csg 47 L-80 TC II 8.681" Surf 6,538' 5-1/2" Prod Liner 17 L-80 DWC/C HT 4.892" 6,316' 13,211' TUBING DETAIL 6 r � 3-1/2" Tubing 9.2 L-80 EUE 8rd 2.992" Surf 6,364' f ice ' 2 � JEWELRY DETAIL No. Item Top MD Btm MD ID OD 3 Q 1 Tubing Hanger 28.42' 28.84' '4.,b 'J 2 X Nipple 2,095.80' 2,097.42' 2.813" 4.493" o 3 Stage Tool—ES Cementer 2,382' 2,386' 8.618" 9.625" 4 GLM w/sheer valve set @ 2500 psi 3,007' 3,016' 2.920" 4.500" 'Mk 4 5 PHL Packer 6,136' 6,144' 3.850" 8.450" L. 6 Ratcheting Muleshoe 6,363' 6,365' 3.500" 4.688" Asa` , 7 Liner Top Packer 6,316' 6,338' 6.150" 8.290" 8 7"x 5-1/2"XO 6,343' 6,346' 4.860" 7.670" li 0 s9 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" 11 WIV Valve(Ball on Seat/Closed) 13,206' 13,209' 5.000" •'. ICD DETAIL 4. Top(MD) Btm(MD) SWELL PACKER DETAIL 6,585.12' 6,604.95' $, 6,847.85' 6,867.64' Top(MD) Btm(MD) .11^0. " 7,400.11' 7,419.92' 7,668.16' 7,679.04' 8,002.69' 8,022.48' 8,903.09' 8,913.97' s 8,635.22' 8,655.00' 9,964.09' 9,974.97 = 9,113.24' 9,133.07 10,867.31' 10,878.19' {'' i. 9,734.18' 9,753.98' 11,842.73' 11,848.38' 11,042.97' 11,062.75' 11,582.98' 11,602.77 x" 12,055.48' 12,075.26' 12,604.17' 12,623.67' 13,109.14' 13,128.94' s 1 9-5/8"shoe @ t ' M" ,..„4,4' 6,538' . 7 19NINIMININI 1 • 5-1a"shoe 6 13,211' 5 r 11 PBTD=13,206'MD/4,147'TVD TD=13,212'MD/4,147'TVD Max Deviation:'94.83 Updated by CJD 12/11/15 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Monday,December 28,2015 P.L Supervisor ( 2(2 �/c SUBJECT: Mechanical Integrity Tests ( ( HILCORP ALASKA LLC L-48 FROM: Guy Cook MILNE PT UNIT SB L-48 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry UP2 NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT SB L-48 API Well Number 50-029-23552-00-00 Inspector Name: Guy Cook Permit Number: 215-120-0 Inspection Date: 12/21/2015 Insp Num: mitGDC151221205006 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well' [Type In' TVD Tubing _ L-aa � � w un� aoz8 ✓ g 360 367 366 . 366. PTD J 2151200 Type Test SPT Test psi 1795 IA 335 1795 1745 • 1729 Interval INITAL P/F P ✓ OA 0 j 0 0 0 Notes: 2.45 bbls.used to test. MITIA. SCANNED SEP 1 6 2016: Monday,December 28,2015 Page 1 of 1 0 • 0 N • p o .D N o • - > (N N D. 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Q c a ° a) 4 Z EU >, I O Q d 0 0 2 0 (0 Z ISI OS CO CO CO cd CO CO ,n ,n 1 0 ®Q N N III , - a) Co a) Co Co Co Co C O) m O) m O) m CO } ( } JL. 0 0 0 0 0 0 0 E p = �t .� � n o 0 ill O 5` > CO HCo03COCo00c > Co IS Co Co W n O CO N N NN N N N W O Oi CO N a a. p c y = aicu III > 6 co E N CO CO O c' a) 0 0 .O-• C ) iz I— m d O in- Q O O 0 :+ C a) Cca U £ V O n o n H • O Zi D I0 0 0 0 0 0 0 ry Z o 2 a°) 0 o 5 a 0 O 0. LW W W W w w w 0 a 0 0 0 w 1 0 1 0 • 0 0 ,„, O 0 O N O p• N N b coin .a' O. N >- d co U_ T N Co0 w 0 z_ z co m C.) CO Ce J -J 2 0 CL N 0 a w oe O. 111 0 V J z Z Q .r m d m J 0 co 1.1- to co0 O N a Ev V U o J Q ea ct r W O I Ln J r m o 2 co F- N m Z Cl) w al z a Q J O r • 3 Q O a z E Q E 0 m z d • n o 0 o > N I- e- 10 - U,N C N E N o .2_ co U C7 0 • 0 Zr) M • RECEIVED STATE OF ALASKA DEC 2 3 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a.Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 11 b.Well Class: 20AAC 25.105 20AAC 25110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑✓ WAG❑ 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.: 11/21/2015 W 215-120 ' 3.Address: 7. Date Spudded: 15.API Number: 3800 Centerpoint Drive, Suite 1400,Anchorage,AK 99503 October 10, 2015 50-029-23552-00-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 3287'FSL,4759'FEL,Sec 8,T13N, R10E, UM,AK November 15,2015 MPL-48 Top of Productive Interval: 9. Ref Elevations: KB: 47' 17. Field/Pool(s): 193'FNL, 947'FEL,Sec 18,T13N, R10E, UM,AK GL: 17' BF: 17' Milne Point Unit/Schrader Bluff Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1206'FSL,954'FEL, Sec 17,T13N, R10E, UM,AK 13,206'MD/4,147'TVD SHL-ADL025509 TPH/BHL-ADL025515 • 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 545122 y- 6031478 Zone- 4 . 13,212'MD/4,147'TVD N/A TPI: x- 543686 y- 6027989 Zone- 4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 548996 y- 6024142 Zone- 4 N/A 1,970'MD/1,861'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 L-48: ROP-DGR-ADR-EWR-HORIZONTAL PRES 2IN MD, DGR-ADR-EWR-INVERTED/REVERTED INTERVALS 2IN ND L-48PB1: ROP-DGR-EWR 21N MD, DGR-EWR 21N ND L-48PB2: ROP-DGR-EWR 21N MD, DGR-EW$21N TVD L-48PB3: ROP-DGR-ADR-EWR-HORIZONTAL PRES 21N MD, DGR-ADR-EWR 21N ND 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 20" 78.6# A-53 Surface 80' Surface 80' 42" 60 bbls 15.6 ppg Stg 1 L- 11.7 ppg 230 bbls T-15.8 ppg 83 bbls 9-5/8" 47# L-80 Surface 6,538' Surface 4,124' 12-1/4" Stg 2 L- 10.7 ppg 287 bbls T-15.8 ppg 54 bbls 5-1/2" 17# L-80 6,316' 13,211' 4,081' 4,147' 8-1/2" Cementless with Swell Pkrs 24.Open to production or injection? Yes ❑✓ No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3-1/2" 6,364' 6,136'MD/4,027'ND (5)Water Swell Packers C'MIFLt I ON DATE 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. (12)Injection Control Devices 11/21/1i Was hydraulic fracturing used during completion? Yes ❑ No ❑✓ *See attached Wellbore Schematic for further detail* ',/ERIF'E Per 20 AAC 25.283(i)(2)attach electronic and printed information t.t, DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 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 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. N/A N/A 24-Hour Rate N/A N/A N/A N/A 41n(u. VI?) 91AlIC' Form 10-407 Revised 11/2015 (��p�/, CONTINUED ON PAGE 2 RBDMSLLDEC 3 0 201[Submit ORIGINIAL only 4 (Wh 5 1 28. CORE DATA Conventional es): Yes ❑ No ❑ Sidewall Coreibes ❑ No 0 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 El Permafrost-Top If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1,970' 1,861' Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 6,5-851 14,131' LL information, including reports,per 20 AAC 25.071. SV1 2,376' 2,140' Ugnu MA 5,341' 3,698' Schrader Bluff NA 5,885' 3,950' Schrader Bluff OA 6,487' 4,114' Formation at total depth: Schrader Bluff OA 31. List of Attachments: Wellbore Schematic, Daily Drilling and Completion Composite Reports, Casing and Cementing Reports, Definitive Directional Surveys, Days vs Depth, MW vs Depth Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Luke Keller Email: Ikeller(c�hilcorp.com Printed Name: Luke Keller Title: Drilling Engineer ' Signature: � . t Phone: 907-777-8395 Date: /L/2---3/(5-- INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 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,Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 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 11/2015 Submit ORIGINAL Only Milne Point Unit • • Well: MPL-48 PTD:215-120 SCHEMATIC API: 50-029-23552-00-00 Hibor,Alaska,L1.€ RKB:28.42' CASING DETAIL 20 \, A,/1 1 Size Type Wt Grade Conn. ID Top Btm 20" Conductor 78.6 A-53 Weld 19.25" Surf 110' 9-5/8" Surf.Csg 47 L-80 TC II 8.681" Surf 6,538' 5-1/2" Prod Liner 17 L-80 DWC/C HT 4.892" 6,316' 13,211' TUBING DETAIL 3-1/2" Tubing 9.2 L-80 EUE 8rd 2.992" Surf 6,364' 2 JEWELRY DETAIL No. Item Top MD Btm MD ID OD 30. 1 Tubing Hanger 28.42' 28.84' - - 2 X Nipple 2,095.80' 2,097.42' 2.813" 4.493" 3 Stage Tool—ES Cementer 2,382' 2,386' 8.618" 9.625" .. 4 GLM w/sheer valve set @ 2500 psi 3,007' 3,016' 2.920" 4.500" 4 ', 5 PHL Packer 6,136' 6,144' 3.850" 8.450" ". 6 Ratcheting Muleshoe 6,363' 6,365' 3.500" 4.688" 7 Liner Top Packer 6,316' 6,338' 6.150" 8.290" 8 7"x 5-1/2"XO 6,343' 6,346' 4.860" 7.670" 9 Injection Control Device(ICD)(12 Total) See Below See Below 4.675" 6.500" 10 Swell Packer(5 Total—See Detail Below) See Below See Below 4.892" 8.000" 11 WIV Valve(Ball on Seat/Closed) 13,206' 13,209' - 5.000" `a ICD DETAIL Top(MD) Btm(MD) SWELL PACKER DETAIL 6,585.12' 6,604.95' 6,847.85' 6,867.64' Top(MD) Btm(MD) 7,400.11' 7,419.92' 7,668.16' 7,679.04' 8,002.69' 8,022.48' 8,903.09' _ 8,913.97' 8,635.22' 8,655.00' 9,964.09' 9,974.97' 9,113.24' 9,133.07' 10,867.31' 10,878.19' " 9,734.18' 9,753.98' 11,842.73' 11,848.38' 11,042.97' 11,062.75' 11,582.98' 11,602.77' 12,055.48' 12,075.26' 12,604.17' 12,623.67' 13,109.14' 13,128.94' i a' }}A k i. - 9-5/8"shoe @ ``•i6,538' ►� 7 ,19 /I c N N . N ' N \ 5-1/2"shoe 6 13,211' 5 4 1 PBTD=13,206'MD/4,147'TVD TD=13,212'MD/4,147'TVD Max Deviation:94.83° Updated by CJD 12/17/15 • • Hilcorp Energy Company Composite Report Well Name: MP L-48 Field: North Slope County/State: ,Alaska (LAT/LONG): vation(RKB): API#: Spud Date: 10/10/2015 Job Name: 1511126D MP L-48 Drilling Contractor AFE#: 1511126D AFE$: $4,137,342 Activity Date Ops Summary 10/8/2015 Clean cuttings tank;Pull rig off of L-20 and move to L-48,Stop rig in open area on Pad and take spool off floor 10/9/2015 ACCEPT RIG @ 06:00 hrs on L-48.Begin rigging up Nordic 3 on L-48.Berm rig.Set and Berm cuttings tank.Spot and rig up support shacks and associated equipment.N/U Diverter system.;Load pipe shed with BHA;Mobilize crane and remove esp line spooler from rig floor and set GEO steer skid on floor.;Diverter Test:State Rep.John Hill Witness test(Good);Load the pipe shed with 225 Jnts.of 5"DP&Tally;Hauled 0 bbls to G&I Total Hauled 0 bbls Hauled 0 bbls to Pad 3 Total Hauled 0 bbls Hauled 0 bbls to B-50 Total Hauled 0 bbls Hauled 400 bbls H2O F/L-Pad Lake Total Hauled 400 bbls Hauled 10/10/2015 Continue to load the pipe shed with 225 Jnts.of 5"DP&Tally;PU,tourqe and stand back 2 rows of 5"DP from pipe shed.Continue to load the pipe shed with remaining DP.;Set Wear Bushing.;Continue to PU,torque and stand back 7000'5"DS-50 Drill pipe.Rack,Tally,PU and stand back 17 jts HWD with Jars.;Tagged up 54'in; Make up Bit to Motor and wash down to 110';Drill F/110'to 127' pumping @ 300 gpm 40 rpm(dispace well from fresh water to spud mud while drilling);Pull back and rack back stnd.of HWDP;Blow Down and P/U MWD;Drill f/127'to 179'(52') WOB 5-25K,445 gpm- 700 psi,40 RPM,2k ft/lbs torq.P/U 56K,S/O 56K,ROT 56K. MW 8.8 ppg,vis 153.;Pull into the conductor and P/U flex dc's;Drill f/179'to 340'(161') WOB 5-25K,500 gpm- 1050 psi,60 RPM,2k ft/lbs torq.P/U 60K,S/O 60K,ROT 60K. MW 8.8 ppg,vis 135.;Hauled 10 bbls to G&I Total Hauled 10 bbls Hauled 0 bbls to Pad 3 Total Hauled 0 bbls Hauled 0 bbls to B-50 Total Hauled 0 bbls Hauled 120 bbls H2O F/L-Pad Lake Total Hauled 520 bbls Hauled 10/11/2015 Drill f/340'to 1112'(772')AROP=86 FPH WOB 10-24K,508 gpm- 1300 psi,70-80 RPM,2.7k fUlbs torq.P/U 80K,S/O 80K,ROT 86K. MW 9.0 ppg,vis 130/200 Taking MWD Surveys with Gryo standing by;Circulate hole clean.Rig up and run Gyro©1112'.;Drill f/1112'to 1775'(663')AROP=102 FPH. WOB 10-24K,508 gpm- 1300 psi,70-80 RPM,2.7k ft/lbs torq.P/U 90K,S/O 90K,ROT 95K. MW 9.2 ppg,vis 130/200.;Decreased flow in attempt to get better build rates.;Drill f/1775'to 1961 (186')AROP=93FPH. WOB 10-24K,460 gpm- 1100 psi,70-80 RPM,3.5k fUlbs torq.P/U 110K,S/O 100K,ROT 100K. MW 9.2 ppg,vis 130/200.;Survey shot;rack back one stand;CBU 500 gpm 1250 psi 80 rpms.;POOH F/1961'to 175';Rig Service;TIH on elevators from 175'to 655'at report time,with no issues.;Hauled 722 bbls to G&I Total Hauled 732 bbls Hauled 0 bbls to Pad 3 Total Hauled 0 bbls Hauled 0 bbls to B-50 Total Hauled 0 bbls Hauled 900 bbls H2O F/L-Pad Lake Total Hauled 1420 bbls Haulded;Distance to Plan: 63.88'Low 7.34'Right Sliding Last 24 Hours:9.85 Rotating Last 24 hours:4.58 • S 10/12/2015 Continue to TIH on elevators from 655'to 1130'with no issues.;Fill pipe and CBU from 1130'@ 1030'to shear Gel's @ 285 gpm with 540 psi. Rot/Recip pipe.Blow Down Top Drive. MW 9.1+/125 Vis in,MW 9.2+/187 Vis out.;Continue TIH on elevators from 1130'.Tag fill @ 1950'(11'fill)Wash to TD at 1961';Drill f/1961'to 2620 (659')AROP=146.4FPH. WOB 15-27K,535 gpm- 1550 psi,70-80 RPM,5k fUlbs torq.P/U 115K,S/0 95K,ROT 106K. MW 9.3+/9.4+ppg,vis 115/169.;Drill f/2620'to 3374'(754')AROP=125.6 FPH. WOB 15-27K,574 gpm- 1690 psi,70-80 RPM,5.2k ft/lbs torq.P/U 135K,S/O 98K,ROT 111K. MW 9.3+/9.3+ppg,vis 120/200. Pump Sweep @ 3100'60%.;Drill f/3374 to 4508'(1134')AROP= 119 FPH. WOB 15-27K,574 gpm- 2000 psi,(on bottom)70-80 RPM,8k ft/lbs torq.P/U 160K,S/O 103K,ROT 122K. MW 9.3+/9.3+ppg,vis in 100 to 130 vis out 200+.;Circ.hole clean @ 580 rpm.550 gpm 1800 psi.;Monitor well,Blow down top drive Pooh 1/4508 on elev. Max over pull observed was @ 3567'25k over slack off and pulled back through(Good)Continue pooh,pick up weight was increasing.;Dropped one stand and circ.B/U @ 3152'(hole angle 58 deg at this depth poor hole cleaning angle);Hauled 580 bbls to G&I Total Hauled 1312 bbls Hauled 0 bbls to Pad 3 Total Hauled 0 bbls Hauled 0 bbls to 8-50 Total Hauled 0 bbls Hauled 1000 bbls H2O F/L-Pad Lake Total Hauled 2420 bbls;Distance to Plan:0.79'High 10.55'Left Rotating Last 24 hours:10.16 Sliding Last 24 Hours: 2.06 10/13/2015 Continue to CBU from 3100'.Mostly clays @ btms up.Circulate clean.Blow down Top Drive.;Continue to TOH,still encounter tight spots.Back ream tight spots from 2833'-2808', 2373-2337'.TOH on elevators to 1900'with no issues.;Service Rig.TBIH on elevators from 1900'T/2783', Tag,Wash through @ 450 gpm.Trip in on elevators when possible.Wash through tight spots @ 2969',3166',3796',3850',4045'.;Circ&condition while staging up pumps. Mud coming back cold with a 600 vis.ECDs @ 10.2.;Drill ahead F/4505'T/4915'.410'@ 136'FPH. 580 gpm,2000 psi,WOB,7-15, MW 9.3+vis 85.;Drill f/4915'to 5696'(781')AROP= 65 FPH. WOB 15-25K,570 gpm- 2000 psi,(on bottom)80 RPM,10k ft/lbs torq.P/U 180K,S/O 103K,ROT 130K. MW 9.3+/9.3+ppg,vis in 100 to 130 vis out 200+.,Hauled 1276 bbls to G&I Total Hauled 2878 bbls Hauled 0 bbls to Pad 3 Total Hauled 0 bbls Hauled 0 bbls to B-50 Total Hauled 0 bbls Hauled 1250 bbls H2O F/L-Pad Lake Total Hauled 3670 bbls;Distance to Plan: 29.3'High 13.84'Left Sliding Last 24 Hours: 4.51 Rotating Last 24 hours: 4.28 10/14/2015 Drill ahead F/ 5696' T/5950'.(254')AROP= 42 FPH. WOB 15-25K,550 gpm-1900 psi,(on bottom)60 RPM, MW 9.2+/vis 80;Drill ahead F/ 5950' T/6230'.(280')AROP= 56 FPH. WOB 15-25K,550 gpm- 1900 psi,(on bottom)60 RPM, MW 9.2+/vis 80;SIow drilling Fl 6230'T/6235'.Rot&Circ lube sweep @ 500 gpm 10 rpm,6235'.;Drill ahead F/6235' T/6239'. WOB 15-25K,550 gpm- 1950 psi,(on bottom)60 RPM, MW 9.2+/vis 60;Circ.1.5 x B/U @ 560 40 rpm 1750 psi.(Decision was made to pull out of the hole due to low ROP and excessive stick slip, every other time bit touch bottom it would stall the motor).;Monitor Well,Blow down.;POOH on elevators encountered tight spot 6205'thru 5320'pulling 35k 50k over,worked through with no pumps(Good) continued POOH to 4350'periodically pulled tight(35 to 50k over);work through with no pumps .(Good)From 4350'to 732'(BHA)max over pull that was encountered 10k over with no swab.;BHA;Rack back HWDP and Jars in derrick,stand back one stand of flex DC,Pull MWD and Motor through floor and brake off bit.;Hauled 580 bbls to G&I Total Hauled 3458 bbls Hauled 0 bbls to Pad 3 Total Hauled 0 bbls Hauled 0 bbls to B-50 Total Hauled 0 bbls Hauled 450 bbls H2O F/L-Pad Lake Total Hauled 4120 bbls;Hauled 0 bbls of H2O FNern Lake Total Hauled 519 bbls Distance to Plan: 29.25'High 9.31'Left Sliding Last 24 Hours: 6.93 Rotating Last 24 hours: 2.01 10/15/2015 Finish L/D bit.2-4-WT-A-E-3-NO-ROP.Test motor @ 350 gpm..GOOD. M/U used HDBS QHC1GRC.;Slip&Cut drilling line. Inspect brakes.;Service rig,Change saver sub&gripper dies,Pump up TD compensator,Load&tally 5"HWDP,Perform weekly derrick inspection.;RIH with BHA#2. Fill pipe @ 2050'. RIH F/2050'T/4318'.Tag.Work through no pumps. RIH F/4318'T/4508'.Start taking weight.;Break circ&stage up pumps.Pump Condent walnut&circ&condition mud @ 450 max rate due to cold mud. 20 RPM @ 6500 MW in 9.2+Vis 86 MW out 9.4 200 vis.;RIH F/4508'T/4555'.Tag. Try to wash through. Rot 20 rpm 360 gpm. Ream through with 5-10k WOB. RIH F/4611'T/4738'on elevators. Tag.Wash&ream @ 450 gpm 40 rpm.F/4702'T/4796'.;RIH F/4796'to TI 5033'wash and ream @ 450 gpm 40 rpm.;Attempt to wash and ream(no go)stopped rotation and orient tool to the exact position that it was drilled and washed and slid stand down.;Took a survey and showed that we were.3 deg low.5'to the right.Slid an additional 138'(5,171') with the same survey orientation to correlate with a previous survey depth;and still showed.7 deg low but 1.9'to the right of the old hole.Continue slide drilling @ 550 gpm 1400 psi.10 to 15 wob @ 5526'to get back into the old hole.;Hauled 116 bbls to G&I Total Hauled 3574 bbls Hauled 0 bbls to Pad 3 Total Hauled 0 bbls Hauled 0 bbls to B-50 Total Hauled 0 bbls Hauled 425 bbls H2O F/L-Pad Lake Total Hauled 4545 bbls;Hauled 0 bbls of H2O FNern Lake Total Hauled 519 bbls Daily Fluid Loss:83 bbls Total Fluid Loss:83 bbls • • 10/16/2015 Slide drill 110 deg left to try and re enter old hole T/5552'.Take survey.Showing 2.2'high and left of the old hole estimated. Decide circ while discussing with town.;Final decision well was sidetracked @ 5002'.;Circ @ 450 gpm 40 rpm. @ btm up showing 150 increase in vis. Decide to try and slide in to the hole.No go.Taking weight.;Pump out of the hole @ 450 gpm F/5052'T/4900'Clean. Started getting drag after 4900'.Back ream T/ 4885'. RIH on elevators F/4885'T/5552'clean. Circ down last stand tag btm.;Ream/Drill 550 gpm 80 rpm 20k wob @ 300-500 fph F/5552'T/5646'. Circ btm up.Showing 400 vis mud and sand over shakers. Take survey @ 5646'Showing 6.2'left of old hole.;Discuss with drilling engineer to drill to rot F/5646'. Make directional plan now we are away from old hole. Drill ahead @ 80 rpm 10k tq,20k wob.F/5646'T/5716'.Take survey.;Drilling ahead @ 300-500'ROP until 5690'. ROP started to slow back to normal drilling rate.30-100 fph.;Circ Sweep around with sand in returns&no increase in cuttings. Sweep came back 1000 stks early.;Short trip F/5716'T/4900'on elevators.Clean. RIH F/4900'T/5300'.Clean. Make up remaining stands of HWDP&stand back.RIH T/5716'.Wash last stand down&orientate.;Drill ahead F/5716'T/5772'. 56'@ 28 fph Average. Ream full stand.Slide drilling 10-15 WOB 520 gpm,1650 psi,150 dif.;Drill ahead F/ 5772' T/6206'.(434')AROP= 28 FPH. WOB 15-25K,550 gpm- 1650 psi,(on bottom) 80 RPM, ECD 9.7 MW 9.2+/vis 80;Hauled 618 bbl.to G&I Total Hauled 4192 bbl. Hauled 0 bbl.to Pad 3 Total Hauled 0 bbl. Hauled 35 bbl.to B-50 Total Hauled 35 bbl. Hauled 955 bbl.H2O F/L-Pad Lake Total Hauled 5500 bbl.;Hauled 0 bbl.of H2O FNern Lake Total Hauled 519 bbl. Daily Fluid Loss:125 bbl. Total Fluid Loss:208 bbl. Distance to Plan:10.55'Low 19.82'Right Sliding 24 hrs.:13.34 Rotating 24 hrs.2.38 10/17/2015 Drill ahead F/ 6206' T/6627'.(421')AROP= 35 FPH.(TD)Slow ROP from 6590'T/6627'. WOB 15-35K,500-600 gpm- 2025 psi,(on bottom) 80 RPM, ECD 9.8 MW 9.3/vis 75;Circ.hole clean pumping @ 600 gpm 1650 psi.80 rpm.pumped a sweep at TD and the sweep brought back 50%more cutting on the shakers;Monitor well(Static)POOH on elevetors from 6627' to 2100'(no problems)Max over pull seen was 15k over.;At 2163' made up the top drive to circ a B/U pumping @ 520 gpm 950psi,Driller made a 93'stroke up to 2070'.(there was a 15k over pull@ 2100+/-on the up stroke) Kick rotary in @ 50 RPM 3K tq.;On the way down hit a ledge @ 2100' attempt to work through by orienting highside(no go)slow rotation with no pump(no go)slow rotation with low gpm(no go)stacking weight on it(no go);Wash&ream F/2105'TI 2129'@ 10 RPM 280 gpm 500-1500 fph. Shut down pumps&try to make hole.No go.unable to make hole without rot&pumping.;Decision made to come out of the hole and pick up a mill assembly to mill out ledge .;Circ.hole clean 500gpms 10 rpm. Before B/U the hole unloaded with 90%more cutting befor B/U(sand&gravel);POOH F/2070'to 1290'.Washed and reamed from 1290'to 1105'pumpimg @ 400gpms 40 rpms. 800 psi.(cleaned up) Pulled on elevators from 1105'to 173'BHA;Hauled 638 bbls to G&I Total Hauled 4830 bbls Hauled 0 bbls to Pad 3 Total Hauled 0 bbls Hauled 0 bbls to B-50 Total Hauled 35 bbls Hauled 670 bbls H2O F/L-Pad Lake Total Hauled 6170 bbls;Hauled 0 bbls of H2O FNern Lake Total Hauled 519 bbls Daily Fluid Loss:8 bbls Total Fluid Loss:216 bbls Distance to Plan:0.29'High 9.37'Right Sliding time: 8.35 Rot.time:2.53 10/18/2015 Stand back flex collars.Down load MWD. Break off bit.Bit looked good. Stand back MWD&motor.;Clear floor.Strap&tally BHA. M/U 6 1/2 bull nose,7'5"dp pup,8 4 blade two stage 12.1/8 tappered mill,xo,xo,1 jt hwdp,xo,12 1/8 intergal bled stab,5 joints hwdp,jars,20 joints hwdp.;RIH F/ 218'T/2126'. Tag'. Wash down last stand @ 200 gpm.;Try to work through with no pump or rot.No go. Wash down.No go. Ream down @ 20 rpm 200 gpm.TQ 3-6k. Work down with varous perametors up to 40 k down.60 rpm 500 gpm.;Ream F/2126' T/2141'. Ream down @ 10-60 rpm 200 gpm.TO 3-15k. Work down with varous parameters up to 40 k down.60 rpm 500 gpm. Fell through once and got hung up.;Fire jars&100 over 3 times to get free. Continue to ream making hole little by little until 2141'.No go. Blow down TD.P/U working single that was layed down.;POOH F/ 2141'T/46'on elevators (no Problem)BHA was pull above the floor and 8.26'of the BHA was left in the floor.Decision was made to pick up the drilling BHA#4 and side track the well.;L/D milling assembly and the mud motor,MWD and PWD that was racked back in the derrick.;Slip and cut off 34'of drilling line;Pick up BHA#4 Bit,Motor,and MWD.HWDP and Jars;Down load MWD-remove old BHA from pipe shed while down loading MWD.,RIH one stand of HWDP to test MWD-continue RIH to 2100',Pulled back to 2045'to start sidetrack:Hauled 82 bbls to G&I Total Hauled 4912 bbls Hauled 0 bbls to Pad 3 Total Hauled 0 bbls Hauled 0 bbls to B-50 Total Hauled 35 bbls Hauled 80 bbls H2O F/L-Pad Lake Total Hauled 6250 bbls;Hauled 0 bbls of H2O FNern Lake Total Hauled 519 bbls Daily Fluid Loss:41 bbls Total Fluid Loss:257 bbls • • 10/19/2015 RIH to 1970',&tag. Orient High side&slide through no rot down to 2061'.Back ream to clean up slide area for kick off point F/2061'T/1960'. Wash down.Back ream once more and tag on the way;in @ 2010'.Taking wt.Unable to work past. P/U and oreint 160R to start trough. Work trough area F/1980'T/2010'.;Start to time drill as per DD.Start @ 1'per hr.Stage up to 2'per hr by 2020'. Drill F/2010'T 2020'. Continue staging up ROP F/ 2020'T/2027'. 450 gpm,1-3 wob,1064 psi,MW 9.2+,vis 125.;Drilling ahead as per DD, F/2027'T/2274', 247'@ 125 fph average 460-480 GPM,1200-1300 PSI 5-10K WOB, MW,9.3 vis 119;Drilling ahead as per DD, F/2027'T/3165', 1138'@ 126 fph.average. 480 530 GPM,1400-1650 PSI 15-25K WOB, MW,9.3 vis.125;Drilling ahead as per DD, F/3165,to 3476' 311'@ 124 fph.average 530 GPM,1400-1650 PSI 15-25K WOB, MW,9.3 vis.125;Circ.hole clean @ 530 gpm 80 rpms 1500psi;POOH on elevator F 3476'to 3044'consistently pulling 20 to 40k over thru slides.Wash and ream up from/3044'to 2500'.;Hauled 633 bbls to G&I Total Hauled 5545 bbls Hauled 0 bbls to Pad 3 Total Hauled 0 bbls Hauled 0 bbls to B-50 Total Hauled 35 bbls Hauled 570 bbls H2O F/L-Pad Lake Total Hauled 6820 bbls;Hauled 0 bbls of H2O FNern Lake Total Hauled 519 bbls Daily Fluid Loss:10 bbls Total Fluid Loss:267 bbls Distance to Plan:4.91'High 16.83'Right;Sliding Last 24 Hours:9.18 Rotating Last 24 hours:4.90 10/20/2015 RIH on elevators F/2500'T/3476'.Wash last stand down. Clean trip in. Correct displacement on trip in.;Drilling ahead as per DD, F/3476'T/4703' @ 111 fph.average 560 GPM, 2000 PSI 15-25K WOB, MW,9.3 vis.125 Pumped sweep @ 3700'.High vis,condent.Came back with 200%increase on time;Circ sweep&well clean @ 550 gpm,80 RPM,Sweep back on time,200%increase consisting of mostly sand and clay. Pump survey,flowcheck well,static.P/U 170K,S/0 11OK;POH on elevators f/4703'to 4540'with 30k overpull.Wash and backream f/4540'to 4139' pumping 460 gpm,1450 psi.40 rpm.Pull on elevators f/4139'to 3916',backream f/3916'to 3851',;Pull on elevators F/3851'T/3696'. Backream F/3696'T/3666',Pull on elevators to 3355'with no further issues,park @ 3453'.;Install FOSV,monitor well.Service top drive.Clean discharge and suction screens on mud pumps.;TIH on elevators from 3453'to 4610',Work thru tight spots @ 3750'and 4586',wash last stand to bottom,No fill.P/U 155K,S/0 105K,ROT 125K @ 40 RPM,TQ 5300# Note:correct displacement on trip in;Drilling ahead as per DD, F/4703'T/5054', @ 351'64 fph. 532 GPM,1750-1950 PSI 15-20K WOB, MW,9.3+vis.131, No losses. Building our curve @ 6deg DL.;11.67'above the line,2.83'left of the line;Hauled 580 bbls to G&I,Total Hauled 6125 bbls Hauled 0 bbls to Pad 3,Total Hauled 0 bbls Hauled 0 bbls to B-50,Total Hauled 35 bbls Hauled 480 bbls H2O F/L-Pad Lake,Total Hauled 7300 bbls;Hauled 0 bbls of H2O FNern Lake,Total Hauled 519 bbls Daily Fluid Loss:0 bbls Total Fluid Loss:267 bbls 10/21/2015 Drilling ahead as per DD, F/5054'T/5360'. @ 306' 87 fph. 554 GPM,2050PSI 15-20K WOB, MW,9.3+vis.131, No losses. Building our curve @ 6deg DL. Slide 60'per stand.Back ream full stand;Circ&condition.Circ sweep.Two btm up.@ 550 @ 1860 psi Cleaned up good.50%Increase in cuttings.;Drilling ahead as per DD, F/5360'T/5741'. @ 381' 69 fph. 554 GPM,2100PSI 15-20K WOB, MW,9.3+vis.110, No losses. Building our curve @ 6deg DL. Slide 60'per stand.Back ream full stand;Circ sweep&clean.1.5 btm up.Sweep came back @ 100%increase. Rot&Reciprocate @ 80 RPM 550 GPM;Short trip on elevators F/5741'T/4600'. UP/DN 200/110 Had 50K Bobble @ 5320' 15K drag 5320'-5264'. Work pipe&cleaned up.Good. POOH clean F/5200'T/4600'.Good.;Service rig&TD @ 4785'. Clean Suction&discharge screens.;RIH on elevators F/4785'T/5741'. Clean Wash last 30'down. Stage up pumps to 550 gpm.;Drilling ahead as per DD, F/5741'T/5930'. @ 47 fph. 554 GPM,2100PSI 15-20K WOB, MW,9.3+vis.110, No losses. Building our curve @ 6deg DL. Slide 60'per stand.Back ream full stand;Drilling ahead as per DD, F/5930'T/6260'. 55@ fph. 554 GPM,2100PSI 15-20K WOB, MW,9.3+vis 110.ECD 9.9 No losses. Building our curve @ 6deg DL. Slide 60'per stand.Back ream full stand;49.24'above the line,7.51'right of the line. 9.38 slide hrs,3 rotate hrs.;Hauled 464 bbls to G&I,Total Hauled 6589 bbls Hauled 0 bbls to Pad 3,Total Hauled 0 bbls Hauled 0 bbls to B-50,Total Hauled 35 bbls • S 10/22/2015 Drilling ahead as per DD, F/6260'T/6552'@ TD 40@ fph. 80 RPM @ 11k tq 554 GPM,2150PSI 15-20K WOB, MW,9.3+vis 110.ECD 9.9 No losses. Building our curve @ 6deg DL.,Circ&condition @ 80 RPM 600 gpm Circ tandam 18 bbl sweeps. Circ total 2.5 btm up.;Monitor well,L/D single to change breaks. Blow down TD. POOH F/6552'T/3100 Tight spots @ 6200'50K,4475 40k,3830'50k.Pull through or work stab back down and pulls clean.;Started getting lots of clay on tool joints after 2200'out. Filling buckets on the trip out. See pics in 0 Drive.;Continue POOH on elevators from 3100'to 2451'with 50k overpull,attempt to work past several times.Pump out 460 gpm 1200 psi f/2451'to 2420',pull on elevators f/2420'to 2302'w/30k overpull.;Pump out f/2302'to 2220',pull on elevators f/2220'to 2157',50k overpull.;Continue pumping out,mad pass log f/2157'to 1750'pulling 300 fpm. Note:continue to clean clay build up off every tool joint.;Continue POOH on elevators f/1750'to 1490'with 30k overpull,work stand back down,pull to 1385'seeing 15k drag then 50k overpull,pump out f/1385'to 1320'with 45k overpull,;shut down pump when working string down,continue to pump out to 1270', pull on elevators to 1187'w/40k overpull,attempt to pump out,backream f/1187'to 1167'two times;until able to pull thru w/pumps off, pull on elevators f/1167'w/15k drag until 1040',blow down top drive,continue POOH,P/U single before HWDP.Rack HWDP and jars back.;Severe clay packed on HWDP,strip off while POOH and put in buckets,POOH to 354'.;Hauled 923 bbls to G&I,Total Hauled 7512 bbls Hauled 0 bbls to Pad 3,Total Hauled 0 bbls Hauled 0 bbls to B-50,Total Hauled 35 bbls Hauled 550 bbls H2O F/L-Pad Lake,Total Hauled 8390 bbls;Hauled 0 bbls of H2O FNern Lake,Total Hauled 519 bbls Daily Fluid Loss:0 bbls Total Fluid Loss:267 bbls 10/23/2015 Down load MWD,L/D BHA. Grade bit,2-2-WT-A-E-1/8-BU-TD;Clean&Clear floor.Pull 15.375"wear bushing. Wash stack with water hose.Dummy run 9 5/8"casing hanger per well head rep.;R/U 9 5/8"Casing equipment,volant tool,slips,power tongs,elevators,organize rig floor for casing.;PJSM, Inspect,bakerlock and M/U shoe track,install 2 centralizers on shoe jt over stop collars 10'from each end,1 centralizer over stop collar in middle of float collar jt,;lnspect and M/U bypass baffle adaptor and pups and 1 jt,threadlock same per HES rep.Install centralizer in middle over stop collar, Check float operation.;P/U and RIH f/162'to 728'w/9 5/8"TC-II,47#,L-80 surface casing per tally.M/U using optimum torque @ 12500 ft/lbs w/BOL pipe dope.Install 1 centralizer every other jt for 15jts.;Fill every 5 jts using volant tool.Continue RIH w/casing f/728'to 2078'with set down jt#49, attempt to work past,M/U volant tool,stage pump to 5 bpm @ 140 psi,;Rotate slow staying under 10k torque wash f/2078'to 2190'making slow progress finally breaking thru and able to RIH on elevators. Note:full returns while circulating.;RIH on elevators f/2190'to 2677'w/set down,wash and rotate working to 2702'until free.continue RIH on elevators to 3062'with a hard set down.;Attempt to wash 7-12 bpm, 190-360 psi and rotate slow trying to get past obstruction,working pipe f/3062' and pulling tight @ 3024'. Note:no increase in pump pressure setting down @ 3062'.;Mix and pump 20 bbl 5%NXS lube pill and spot outside of shoe,let pill soak for 20 min. Note:no losses while circulating,very little sand and clay seen at returns.;Continue to reciprocate and rotate while circulating trying to work past 3062'.;Hauled 116 bbls to G&I,Total Hauled 7628 bbls Hauled 0 bbls to Pad 3,Total Hauled 0 bbls Hauled 0 bbls to B-50,Total Hauled 35 bbls Hauled 0 bbls H2O F/L-Pad Lake,Total Hauled 8390 bbls;Hauled 0 bbls of H2O FNern Lake,Total Hauled 519 bbls Daily Fluid Loss:0 bbls Total Fluid Loss:267 bbls 10/24/2015 Continue to reciprocate and while circulating trying to work past 3062'@ 500 gpm. Work up to 3025' &Pull 50-75K over. Work down using TD weight. Continue to hammer down.;Pumped lube sweep&worked in. Pumped high vis sweep.Brought back a few rocks&sand. Broke through before HV sweep was out of the pipe. Finish clearing sweep from hole.;CRT broke at the 4 1/2 IF connection while breaking out CRT. Re-torque same.;Hammer casing down 75K down making 1/4 in per 4 hammers. Started making inches and broke through after 4'. Fought every 40'down for 200'.;RIH F/3250'T/4162' Work through on elavators. Push F/4162'T/4300'. Filling pipe every 10 joints. Run casing F/4300'T/6215'.Wash and hammer down 6215';Unable to work past 6215',unable to break over up 370k(80%rig rating)stage pump to 400 gpm CBU.;Work past bridge @ 6215'pumping 400 gpm,work thru on elevators f/6220'to 6500',M/U landing jt and hanger,land on depth @ 6538'.;Stab volant tool,stage pump to 417 gpm 430 psi,circulate and condition mud for cement job lowering YP from 35 to 29,shut down pump after circulating 416 bbls.;R/D volant tool and load out,L/D long bails.DSM witness plug loading,M/U cement head and lines per HES rep.;Continue to circulate and condition mud for cement job pumping 406 gpm,730 psi lowering YP to 29,prep pits,mix two 30 bbl citric contaminate pills,store 1 in pill pit and other on vac truck.;Hold PJSM for cement job w/rig crew,DSM,TP,Rig support,mud man and Cement crew.;Pressure up cement silos,Pump 5 bbls water,PT lines to 4500 psi.Pump 43 bbl 10.5 ppg spacer 3.5 bpm,290 psi,Drop bypass plug,load shut off plug,batch 11.7 ppg lead cmt @ 00:17.;Pump 230 bbls lead cmt 4 bpm 519 psi start,330 psi final,pump 83 bbls 15.8 ppg tail cmt 3.5 bpm 110 psi,drop shut off plug,pump 20 bbls water,w/rig pump displace w/237 bbls 9.3 ppg mud;5.5 bpm,130 psi start,400 psi final,170 bbls away starting to lift cement,pump 80 bbls water w/cementers pump 5 bpm,976 psi final,swap to rig pump,displace w/135 bbls 9.3 ppg mud,;pump 5 bpm,860 psi,at 61 bbls away lost 30%returns,82 bbls away lost full returns,91 bbls away got back 10%of returns then very little returns,109 bbls away slow to 3 bpm,1179 psi,;plug bumped 131 bbls away 5 bbls early 1170 psi.Pressure up to 1750 psi and hold for 5 minutes,bled back 3.3 bbls,float held,Note 52 bbl losses while displacing.Swap to cementers,;increase pressure slowly, stage tool sheared open @ 2750 psi,pump 20 bbls water,swap to rig pump,displace 5 bpm,270 psi,cement back 71 bbls into displacement @ 1000 stks,;Circulate 2-3 bpm and dump cement returns out 4"conducter valves gravity feeding to slop tank,adding citric pill from trip tank fill line contaminating cement returns.;Hauled 174 bbls to G&I,Total Hauled 7802 bbls Hauled 0 bbls to Pad 3,Total Hauled 0 bbls Hauled 0 bbls to B-50,Total Hauled 35 bbls Hauled 170 bbls H2O F/L-Pad Lake,Total Hauled 8560 bbls;Hauled 0 bbls of H2O FNern Lake,Total Hauled 519 bbls Daily Fluid Loss:0 bbls Total Fluid Loss:267 bbls • S 10/25/2015 Circulate 2-3 bpm and dump cement returns out 4"conducter valves gravity feeding to slop tank,adding citric pill from trip tank fill line contaminating cement returns.;60 bbl returned to surface. Started getting mud back.Swap returns back to pits.;Stage up pumps to 6 bpm getting cmt chunks over the shakers.Circ clean&treat mud back to 9.2.Clean all dump hoses and lines.;PJSM,Second stage cmt job.Swap over to HES. Prime pump,Pump 20 bbl water, Mix&pump 10.5 ppg Spacer.(64 bbl) Pump 287 bbl lead.Started to get mud push back @ 250 bbl.;Open dump valves in cellar.Close annular Mix tail.Pump 54.6 bbl 15.8 ppg.Drop closing plug with 3.4 bbl cmt on top.Displace with 20 bbl H2O. Swap to rig.Rig displace with 150 bbl 9.2 ppg mud.;Bump plug.Final circ pressure @ 3 bpm 600 psi,Pressure up to 2000 psi. Felt tool shift @ 1350 psi.Hold pressure for 5 min. Bleed off&check flow.Good. CIP @ 1500. 140 bbls cement returned.;Clean all lines&surface equipment. Offload&clean all pits. Flush stack.R/D halliburton cmt head&lines. Back out landing joint. M/U pack off&running tool.;lnstall packoff per wellhead rep,RILDS.Clear rig floor of remaining cement equipment.Clean cuttings box.;PJSM,R/D riser,N/D diverter system, vac out and clean pits.;N/U Seaboard tbg spool,install packoff P-seals,test void,upper and lower seals to 500/3000 psi 5 min ea per wellhead rep.;N/U 11"5M BOPE;Hauled 1005 bbls to G&I,Total Hauled 8807 bbls Hauled 110 bbls to Pad 3,Total Hauled 110 bbls Hauled 0 bbls to B-50,Total Hauled 35 bbls Hauled 300 bbls H2O F/L-Pad Lake,Total Hauled 8860 bbls;Hauled 0 bbls of H2O FNern Lake,Total Hauled 519 bbls Daily Fluid Loss:58 bbls Total Fluid Loss:325 bbls 10/26/2015 N/U BOPs&perform shell test to 250/3000 psi.;Test ROPE as per AOGCC.Test Witnessed by Mr.Chuck Scheve.Test BOP components w/5"test jt. to 250 low psi and 3000 hi psi 5 min ea.w/water,test annular,upper and lower pipe rams,blind ram,;choke manifold,mud cross valves,FOSV,Dart valve,lower IBOP,Upper hyd IBOP failed low pressure test.Chart record all pressure tests. Perform accumulator draw down test.;R/D test jt and test plug.Blow down top drive and lines.;Load 63 jts 5"DP into pipeshed,C/O upper and lower IBOP.;R/U and re-test upper and lower IBOP to 250 psi low,3000 psi high 5 min ea.charted,good test.R/D test equipment.Blow down top drive.Install 10"ID wear bushing,RI 2 LDS.;M/U BHA#5,8 1/2" VM-3 tricone bit,mud motor,set f/1.22 deg to 0 deg.M/U flt sub,integral stab,4 NM pony collars.;RIH 1 jt 5"HWDP,jars,5 jts HWDP=291.15',RIH with remaining HWDP from derrick,POH,L/D 21 jts of excess HWDP and kickout from pipeshed.;P/U and RIH w/NC50 5"DP from 291'to 2288' taking 10k,cmt stringers.M/U top drive,fill pipe.;Wash and ream cleaning up cmt stringers f/2288'to 2331' Pump 500 gpm,925 psi, P/U105K,S/O 85K,ROT 94K.50 RPM,2500 TQ.off.;Hauled 594 bbls to G&I,Total Hauled 9401 bbls Hauled 0 bbls to Pad 3,Total Hauled 110 bbls Hauled 0 bbls to B-50,Total Hauled 35 bbls Hauled 230 bbls H2O F/L-Pad Lake,Total Hauled 9090 bbls;Hauled 0 bbls of H2O FNern Lake,Total Hauled 519 bbls Daily Fluid Loss:0 bbls Total Fluid Loss:325 bbls 10/27/2015 Continue to wash and ream cleaning up cmt stringers f/2331'.Drill hard CMT @ 2360'.Drill plug @ 2370'.Drill ESCMTR f/2381-2386'.Cont C/O to 2420' Pump 500 gpm,925 psi, P/U105K,S/O 85K,ROT 94K.50 RPM,2500 TQ.off.;RIH picking up NC-50 DP f/2450'to 5125'.Continue TIH with DS-50 DP f/derrick to 6352', encounter occasional hard stringers.(Baffle Adapt @ 6423').;Circulate well from 6352'to 9.1 ppg in/out for casing test.;Blow down TD.R/U 2"HP Hose to Drill Stem. R/U and test 9 5/8"casing to 3000 psi on chart for 30 min.Test good. Note:C/O Grabber dies while testing casing.;Slip and cut drill line.;Continue to wash and ream from 6352'.Drill shut off plug and Baffle Adapter f/6433 to 6436'.w/10-15 WOB,80 RPM,550 GPM. Drill CMT/FE f/6436'to 6552'.Drill 20'new formation to 6572'.;P/U into 9 5/8"casing,@ 6530', reciprocate and rotate,circulate hole clean,pump spacer,Displace to 8.9 ppg BARA-DRILL N mud,condition mud for F.I.T. Tag bttm with new mud @ bit,pull into shoe.;Before displacing,inspect suction rubber gasket in pit 1.Tag bttm with new mud @ bit, then pull into shoe,circ until 8.9 ppg in/out,46 vis.;Park @ 6537'.Perform F.I.T.to 12 ppg EMW with existing MW 8.9 ppg.Close upper pipe ram,flood choke and kill line,shut in choke, pumping down both DP and kill line,apply 654 psi,;1.27 bbls pumped,in 10 seconds pressure bled to 645 psi,in 5 minutes pressure bled to 595 psi,1.1 bbls bled back, open pipe ram.;Get SPR,Blow down top drive,flow check well,static.;POH from 6537'to 5674',flow check well due to improper hole fill,well static.Pump dry job.Blow down top drive.;Continue POH from 5674'to 300',correct fluid displacement on trip out.;Hauled 0 bbls to G&I,Total Hauled 9401 bbls Hauled 0 bbls to Pad 3,Total Hauled 110 bbls Hauled 0 bbls to 8-50,Total Hauled 35 bbls Hauled 0 bbls H2O F/L-Pad Lake,Total Hauled 9090 bbls;Hauled 0 bbls of H2O FNern Lake,Total Hauled 519 bbls Daily Fluid Loss:0 bbls Total Fluid Loss:325 bbls 10/28/2015 Continue to POOH laying down Clean out BHA.;MU BHA#6,8-1/2"Rotary Steerable:W/NOV SK616M-J1D PDC Bit,GEO Pilot w/8.313"stab,Drill DOC,DGR,PWD,DM,ILS,ADR,TM,Stab,3-NMPC,Mtr,Float Sub,1-HWDP,Jar,4-HWDP.Total Length=367.44';Shallow hole test MWD,TIH from 367'to 2092'.;M/U top drive,break in Geo-pilot staging pump up to 500 gpm 1350 psi.;TIH from 2092'to 6544',filling pipe @ 4350',wash and ream last std to bottom @ 6572'w/no fill on bottom. Correct fluid displacement on trip in the hole.;Drill 8 1/2"hole f/6572'to 6814' (243')AROP=37FPH. WOB 11-15K,500 gpm-1650 psi,80 TD RPM,165 Bit RPM,11.5k ft/lbs torq.P/U 220K,S/O 85K,ROT 120K. MW 8.9 ppg,vis 43,ECD 9.85 ppg.;Note:drill concretions per procedure f/6722'to 6724'and 6779'to 6783',@ 1-3 fph.;Drill 8 1/2"hole f/6814'to 7126' (312')AROP=52 FPH. WOB 11-15K,527 gpm-1760 psi,80 TD RPM,170 Bit RPM,12.5k ft/lbs torq.P/U 220K,S/O 85K,ROT 125K. MW 8.9 ppg,vis 38,ECD 9.75 ppg.;Note:drill concretions from 7075'to 7080'@ 2-4 fph. 20.24'above the line,26.70'left of the line.;Hauled 754 bbls to G&I,Total Hauled 10155 bbls Hauled 0 bbls to Pad 3,Total Hauled 110 bbls Hauled 0 bbls to B-50,Total Hauled 35 bbls Hauled 270 bbls H2O F/L-Pad Lake,Total Hauled 9360 bbls;Hauled 0 bbls of H2O FNern Lake,Total Hauled 519 bbls Daily Fluid Loss:0 bbls Total Fluid Loss:325 bbls • • 10/29/2015 Drill 8 1/2"hole f/7126'to 7368' (242')AROP=40.3 FPH. WOB 11-15K,527 gpm-1760 psi,80 TD RPM,170 Bit RPM,12.5k ft/lbs torq.P/U 220K,S/O 85K,ROT 125K. MW 8.9 ppg,vis 38,ECD 9.75 ppg.;Adjust parameters as needed to drill concretions/hard spots. Pumped low vis sweep @ 7368'with 100%increase @ shakers,all fine sands.;Drill 8 1/2"hole f/7368'to 7743' (375')AROP=62.5 FPH. WOB 5-10K,525 gpm-1750 psi,60 TD RPM,150 Bit RPM,12.5k ft/lbs torq.P/U 225K,5/0 80K,ROT 120K. MW 8.9 ppg,vis 38,ECD 10.0 ppg.;Possible fault @ 7575'w/5-12'throw,adjust to 92 deg inc,re-acquire base of OA-3 @ 7815',drop to 90 deg inc to stay @ 4130'TVD.;Drill 8 1/2"hole f/7743'to 8266' (523')AROP=87 FPH. WOB 5-10K,533 gpm-1850 psi,60 TD RPM,150 Bit RPM,13k fUlbs torq.P/U 235K,S/0 80K,ROT 120K. MW 8.9 ppg,vis 38,ECD 10.0 ppg.;Note:@ 7800'Hold ROP back to 160 FPH per Geologist for data.;Drill 8 1/2"hole f/8266'to 8473' (207')AROP= 35 FPH. WOB 10-15K,533 gpm-1850 psi,60 TD RPM,150 Bit RPM,13.5k ft/lbs torq.P/U 240K,5/0 70K,ROT 120K. MW 8.9 ppg,vis 38,ECD 10.0 ppg.;Adjust parameters as needed to drill concretions,har spots Pump 25 bbl to vis sweep @ 8400',sweep back 150 stks early w/20%increase @ shakers,all fine sand. 13.59'above the line,85.72'right;Hauled 623 bbls to G&I,Total Hauled 10778 bbls Hauled 0 bbls to Pad 3,Total Hauled 110 bbls Hauled 0 bbls to B-50,Total Hauled 35 bbls Hauled 450 bbls H2O F/L-Pad Lake,Total Hauled 9810 bbls;Hauled 537 bbls of H2O FNern Lake,Total Hauled 1056 bbls Daily Fluid Loss:0 bbls Total Fluid Loss:325 bbls 10/30/2015 Drilled 8 1/2"hole to 8473'@ report time.Pumped Lo Vis Sweep @ 8400'w/20%cuttings increase and 150 stks early. TOH from 8472'washing 1st stand out to 8382' TOH on elevators from 8382'to 7852';Wash out of hole from 7852'to 7807'@ 450 gpm,1380 psi. Continue on elevators from 7807'to inside shoe @ 6490'.P/U 230k,with 15-20K occassional drag.;Blow down TD.Service Rig.;TIH on elevators from 6490'with no issues or fill on btm.;Drill 8 1/2"hole f/8472'to 8700' (228')AROP=32.6 FPH. WOB 10-15K,542 gpm-1830 psi,60 TD RPM,152 Bit RPM,13.5k ft/lbs torq.P/U 200K,S/O 80K,ROT 120K. MW 8.9 ppg,vis 38,ECD 9.9 ppg.;Adjust parameters as needed to drill concretions/hard spots.;Drill 8 1/2"hole f/8700'to 9039' (339')AROP=61.6 FPH. WOB 8-15K,542 gpm-1830 psi,60 TD RPM,152 Bit RPM,13.5k fUlbs torq.P/U 200K,S/O 80K,ROT 120K. MW 8.9 ppg,vis 38,ECD 9.9 ppg.;Note:encountered OA-4 from 8845'MD/-4085'TVD to 9005'MD/-4083'TVD.Dip increased from 0.1°to the NW to 1° to the NW,adjust inc to 92 deg,regain OA-3.;Swab failed on#1 MP,Circulate w/#2 MP 283 gpm,700 psi and reciprocate pipe while C/O swab and test same.;Drill 8 1/2"hole f/9039'to 9257' (218')AROP=62 FPH. WOB 8-15K,542 gpm-1830 psi,60 TD RPM,152 Bit RPM,13.5k ft/lbs torq.P/U 190K,S/O 75K,ROT 120K. MW 8.9 ppg,vis 37,ECD 10.1 ppg.;Pump lo vis sweep @ 9100',sweep back on time with 25%increase,mostly fine sand. Note:loss 400 psi pump pressure all at once.;25.67'above the line,61.34'right of the Iine.;Check surface equipment for pressure loss,check pump screens,get slow pump rates on both pumps @ 28 spm,260 psi, original SPR 330 psi.;POH on elevators from 9257'to 8700'looking for washout. Blow down top drive.;Hauled 203 bbls to G&I,Total Hauled 10981 bbls Hauled 0 bbls to Pad 3,Total Hauled 110 bbls Hauled 0 bbls to B-50,Total Hauled 35 bbls Hauled xx bbls H2O F/L-Pad Lake,Total Hauled 9810 bbls;Hauled 300 bbls of H2O F/6 mile lake,Total Hauled 300 bbls Hauled 0 bbls of H2O F/Vern Lake,Total Hauled 1056 bbls Daily Fluid Loss:0 bbls Total Fluid Loss:325 bbls 10/31/2015 Continue to POOH on elevators looking for wash outs from 8700'.Stand back HWDP and Jars.POOH with Mud Mtr.;Recovered Mtr Stator housing without the Offset Bent Housing,leaving the Rotor/OffSet Bent housing/Mtr bearing package,MWD/Geo-Pilot in hole.;TD @ 9257.14'. BHA left in hole to top of Offset Bent housing(5.23'mtr left in hole)=155.89' Rotor stick up from top of Mtr=17.75' Estimated TOF=9083';Clear and clean rig floor.Load in and tally 6 1/4 DC's.Load in and tally 6 additional joints HWDP.Change to oversize swabs in MP#1.Change out Liner in MP#1.Load Back up MWD tools in house.;Finish load and tally 5 1/2"liner in house.;Fishing Rep and tools on location. Load fishing tools in pipe shed.Tally same.;MU Fishing BHA#1:Cut Lip Guide,8 1/8"OS w/4.25 Grapple,Dbl pn Bushing, 8 1/8"OS w/4.25 Grapple,OS ext,OS ext,Top Sub,LBS,Hyd Oil Jar,9 jts HWDP,Intensifier,Pump out Sub.Total 331.06'.;TIH from 331'to 6457'just above shoe.:M/U top drive.Test both mud pumps,P/U 180k,S/O 105K.;TIH on elevators from 6457'to 6777'with setdown,P/U and work thru easily, continue TIH to 8567'. Correct displacement on trip in.;M/U top drive,circulate 5 bpm,300 psi,wash to 9002',M/U single,RIH to 9034',set top drive torque @ 15k.M/U std# 93,pump 5 bpm 300 psi.;Per baker rep,Rotate 25 rpm,wash over top of fish @ 9083'to 9095',swallow 12'of fish.Let torque out,set down 15k,P/U to 175k,S/O to 80k 4 times,Pull to 200k,15k over string wt.Fish on.;POOH on elevators slow from 9257'to 2480',slow in and out fo slips.20K overpull @ 8675',40k overpull @ 6788'working thru easily. No other issues pulling into 9 5/8"shoe.Continue POH to 2300';Correct fluid displacement on trip out. Note:daylight savings,clock moves back 1 hr @ 02:00;Hauled 406 bbls to G&I,Total Hauled 11387 bbls Hauled 0 bbls to Pad 3,Total Hauled 110 bbls Hauled 0 bbls to B-50,Total Hauled 35 bbls Hauled 0 bbls H2O F/L-Pad Lake,Total Hauled 9810 bbls;Hauled 560 bbls of H2O F/6 mile lake,Total Hauled 860 bbls Hauled 0 bbls of H2O FNern Lake,Total Hauled 1056 bbls Daily Fluid Loss:0 bbls Total Fluid Loss:325 bbls • 11/1/2015 Continue to POOH on elevators slow from 2480'to 300'.Work BHA.Pull OS to surface with no recovery of fish.Break down and inspect Grapples and Top sub.;lnspected grapples and Top Sub.The grapples are 100%good(Sharp with no Rolled edges on wickers).There is no indication of contact. The top sub does show wear,indicating we were over the fish.;Call for 4 1/8"and 4"Grapples.Clean and clear rig floor.;MU Fishing BHA#2:Cut Lip Guide,8 1/8"OS w/4 1/8"Grapple,Dbl pn Bushing, 8 1/8"OS w/4.00"Grapple,OS ext,OS ext,Top Sub,LBS,Hyd Oil Jar,9jts HWDP,Intesifier, Pump out Sub.Total 331.06;TIH with Fishing BHA#2 from 300'to 6456';M/U TD Circulate well from 6456'while slip and cut drill line,with 80 units max gas @ btms up.;Continue to TIH from 6456'to 9002'with no issues.;M/U single,RIH to 9034', M/U std#93,establish parameters.PU 190K,SO 95K, Tq no pump 8K,Rot 135 no pump 25 RPM,125K w/pump,5 bpm w/325 psi.;Work over TOF @ 9084'with Btm 4 1/8"grapple,No go out on the top 4" Grapple @ 9089'.Work bite on grapple.Attempt to free fish staging up to 180K over multiple times with no movement.;Attempt to fire jars.Grapple kept slipping off.Latch back onto fish,straight pull to 180K over with no movement.Park to fire jars @ 100K over and grapple slips off.;Rotate/Reciprocate pipe while CBU @ 13 bpm w/860 psi.Obtain SPR,Flow check well,static.Pump dry job.;POOH on elevators from 9035'to surface w/40k overpull @ 7558'and 30k overpull @ 6788',able to work thru easily.LID and inspect grapples. Correct hole fill on trip out.;Lower grapple wickers wore flat,also grapple sprung open. Upper 4"grapple trying to slip over top of fish,2 lower wickers scarred,grapple also sprung open.;Redress with new 4 1/8"upper and lower grapples.MU Fishing BHA 3:Cut Lip Guide,8 1/8"OS w/4 1/8"Grapple, Dbl pn Bushing, 8 1/8"OS w/4 1/8"Grapple,OS ext,OS ext,Top Sub,LBS,Hyd Oil Jar,;9 jts HWDP,Intesifier,Pump out Sub.Total=331.06.;TIH with fishing BHA#3 from 331'to 5500'.;Hauled 0 bbls to G&I,Total Hauled 11387 bbls Hauled 0 bbls to Pad 3,Total Hauled 110 bbls Hauled 0 bbls to B-50,Total Hauled 35 bbls Hauled 0 bbls H2O F/L-Pad Lake,Total Hauled 9810 bbls;Hauled 140 bbls of H2O F/6 mile lake,Total Hauled 1000 bbls Hauled 0 bbls of H2O FNern Lake,Total Hauled 1056 bbls Daily Fluid Loss:0 bbls Total Fluid Loss:325 bbls 11/2/2015 Continue to TIH with fishing BHA#3 from 5500'to 9030'with no issues.185K PU,97K S/O.;Est parameters:5 bpm,330 psi,15 rpm,130K Rot,9K free Tq.Engage TOF and work both 4 1/8"grapples over fish @ 9084'and no go @ 9096',set Dn 15-30K.Attempt to work fish free,stage up to 180K.;Fire jars staging up 130K over string weight.On 6th jar hit the grapples let go.Attempt to re-engage grapples with no success.;TOH on elevators from 9084'to 6400'with no issues.Slug pipe @ shoe.Continue to TOH to Surface.Re-covered Rotor and Tie Rod/Stator Adapt.Total length recovered=20.48'.;Break down and remove fish from Over Shots.Clear floor.Lay out and tally fishing BHA#4.New top of fish @ 9102' Correct displacement on trip out;Remove tools and fish from rig floor.MU fishing BHA#4:8 3/8"x 6 3/4"burn shoe,wash pipe ext,drive bushing, bumper sub,oil jar,9 jts 5"HWDP,pumpout sub=313.63;TIH from 313'to 6400'get parameters before exiting shoe. P/U 173K,S/O 110K,ROT 110K,continue TIH to 9079',M/U top drive and last std. Correct displacement on trip in.;P/U 180,S/O 97K with pump off,Pump 5 bpm,350 psi,P/U 157K,5/0 103K,ROT 130K @ 60 RPM 8.5-9K free torq w/pumps on,tag TOF @ 9103.48'2 times,;Rotate 60 rpm,work over fish,top drive stalling,set 1 std back,adjust TD torq f/16k to 18k,M/U std and TD,break circulation.;Mill on fish(mud motor housing pad)f/9103.45'to 9103.62' pumping 221 gpm,350 psi,5k WOBS,55 rpm 12.5-13k tq.;Hauled 0 bbls to G&I,Total Hauled 11387 bbls Hauled 0 bbls to Pad 3,Total Hauled 110 bbls Hauled 0 bbls to B-50,Total Hauled 35 bbls Hauled 0 bbls H2O F/L-Pad Lake,Total Hauled 9810 bbls;Hauled 0 bbls of H2O F/6 mile lake,Total Hauled 1000 bbls Hauled 0 bbls of H2O F/Vern Lake,Total Hauled 1056 bbls Daily Fluid Loss:0 bbls Total Fluid Loss:325 bbls 11/3/2015 Mill on fish(mud motor housing pad)f/9103'.5-6K WOB,with 12-14K Tq.Stage up parameters as needed to mill over fish.Appear to be spinning on top of fish.;Attempt numerous methods to mill over fish.Dry mill staging WOB up to 35K w/10.5-13K Tq,adjusting RPM's from 20-95.;PU off fish and make dry tag,setting Dn 1'High,put 3 rds in DP,Set Back down @ 9103'.Did this 3 times. Continue to Dry mill on fish @ 20-30K,30-50 rpm with no footage.;PU off of fish,set Dn hard several times @ 30-35K on top of fish,attempting friction bite before TOH.;Rotate on top of fish @ 35K-38K WOB while CBU,w/50 units max gas @ Btm Up,and no metals on shaker.Recovered dime size chunk of carbide.Magnets had extra fines metal.Mostly fine sands formation.;Dry mill after Btm Up w/35K WOB 20-80 RPM.Spank top of fish w/35-40k before POOH.Blow down Top Drive.;TOH on elevators from 9103'to the 9 5/8"shoe @ 6538'with no issues,and 1 bbl over calc.hole fill.Cont TOH from 6538'to 300'.Work BHA.;Break down and inspect Burn shoe.ID of shoe shows 3/4"wear inside shoe wear from the leading edge. Face of shoe shows little to no wear.Missing 1 leading edge cutter.;Service Rig.;Slip and cut drill line.;M/U BHA#11;RIH with BHA#11 F/260'T/6709'Break Circ.every 1000 Ft.in open hole,to verify work string is clear.;RIH on elevators,encountered tight spot @ 6,709'attempt to work through with no pumps setting 35k over on down and 35k over up.(No Go) Broke circulation 200 GPM 250 psi.(No rotation)set down 30k;cocked the jars and hit.(String came free),continue RIH to and tagged up @ 6,749' attempt to wash and ream through pumping @ 250 to 400 GPM 200 to 450 psi.45rpm 5-7k TQ(No Go)Pulled two;stands to verify that we were free, went back in the hole to 6749'and continue washing and reaming at 400 gpm.450 psi 45 rpm 7k TQ(No Success)Pulled to the shoe @ 6532'circ. and condition mud;and discussed options.Pulled 30k over coming through the shoe.;RIH in the hole from 6532'to 6749'and attempted to wash and ream through tight spot pumping @ 220 gpm 280 psi.periodically rot.@ 45 rpm 5-7 TQ;Hauled 58 bbls to G&I Total Hauled 11445 bbls Hauled 0 bbls to Pad 3 Total Hauled 110 bbls Hauled 0 bbls to B-50 Total Hauled 35 bbls Hauled 0 bbls H2O F/L-Pad Lake Total Hauled 9810 bbls;Hauled 0 bbls of H2O FNern Lake Total Hauled 1056 bbls Daily Fluid Loss:17 bbls Total Fluid Loss:342 bbls 11/4/2015 RIH in the hole from 6532'to 6749'and attempted to wash and ream through tight spot pumping @ 220 gpm 280 psi.periodically rot.@ 45 rpm 5-7 TQ.;Encounter TD Stalls and had to jar free free to POOH.Work BHA up in to shoe by pulling 20-25K over and ramping pump.Had to hit jars 1 time to get through the float collar.;POOH from 6490'to Surface.Lay down BHA.;Kick out fishing tools from pipe shed.Lay out and prep to PU drilling BHA.;PU RSS BHA.;RIH the hole to 8650'Fill every 1000'in open hole(No Issues);From 8650'To 8720'start trenching pumping @ 470 gpm.98 rpm. 11.5k Torque;Hauled 0 bbls to G&I-Total Hauled 11445 bbls: Hauled 0 bbls to Pad 3-Total Hauled 110 bbls: Hauled 0 bbls to B-50-Total Hauled 35 bbls:Hauled 0 bbls H2O F/L-Pad Lake-Total Hauled 9810 bbls;Hauled 0 bbls H2O F/6 Mile Lake-Total Hauled 1080 bbls: Hauled 0 bbls of H2O FNern-Total Hauled 1056 bbls: Daily Fluid Loss:28 bbls-Total Fluid Loss:370 bbls • • 11/5/2015 Continue troughing from 8697'to 8720'with open hole low side side track.;Drill 8 1/2"hole f/8720'to 8805' (85')AROP=17 FPH. WOB 5-15K,536 gpm-1750 psi,90-95 TD RPM,12-13k ft/lbs torq.P/U 165K,S/O 90K,ROT 123K. MW 9.0 ppg,vis 37,ECD 10.2 ppg.;Drill 8 1/2"hole f/8805'to 8900' (95')AROP=31.6 FPH. WOB 5-15K,536 gpm-1750 psi,90-95 TD RPM,12-13k ft/lbs torq.P/U 165K,S/O 90K,ROT 123K. MW 9.0 ppg,vis 37,ECD 10.2 ppg.;Switch TD to high gear and establish 140 RPM/15-17K Tq Drill 8 1/2"hole f/8900'to 9065' (165')AROP=33 FPH. WOB 5-15K,536 gpm-1750 psi,140 TD RPM,15-17k fUlbs torq.;Drill 8 1/2"hole f/8900'to 9065' (165')AROP=33 FPH. WOB 5-15K,536 gpm-1750 psi,140 TD RPM,15-17k ft/lbs torq;Drill 8 1/2"hole f/9065'to 9086' (21')AROP=7 FPH. WOB 5-15K,536 gpm-1750 psi,140 TD RPM,15-17k fUlbs torq;Not exchanging weight to bit,possible BHA is hanging up on ledge,back ream to 8756'.(No Torque Issues or Tight Spots).;RIH on elevator to 9086'(No Issues);Drill 8 1/2"hole f/9086't/9112(26)AROP=13 FPH WOB 5-15K,505 gpm-1588 psi,140 TD RPM,15-17k ft/lbs torq;Hauled 406 bbls to G&I-Total Hauled 11851 bbls Hauled 0 bbls to Pad 3-Total Hauled 110 bbls Hauled 0 bbls to B-50-Total Hauled 35 bbls Hauled 0 bbls H2O F/L-Pad Lake-Total Hauled 9810 bbls;Hauled 0 bbls H2O F/6 Mile Lake-Total Hauled 1080 bbls Hauled 285 bbls of H2O F/Vern Lake-Total Hauled 1341 bbls Total Hauled 1341 bbls Total Fluid Loss:395 bbls;Distance to Plan: 6.36'High 3.14'Right 11/6/2015 Drill 8 1/2"hole f/9112'U9163(51)AROP=9 FPH WOB 5-25K,540 gpm-1780 psi,140 TD RPM,15-17k ft/lbs tq,P/U 165K,5/O 90K,ROT 123K. MW 8.9 ppg,vis 40,ECD 10.1 ppg.;@ 9112'drilling on what appeared to be a hard concreation.Adjust parameters staging WOB to 10-28K,Rpm's from 40 to 150.PU off btm w/no rotation and encounter 15-20K over pull before breaking over;5'-6'off btm.Wash stand OOH.Position Geo Pilot in 100%Low Side deflection.Wash and ream to btm,taking wt @ 5'from TD.Wash ream to TD w/10-12K WOB and wipe clean,make 1'new of hole.;Repeat process @ High side deflection,Wash to TD with no issues.Started drilling with 100-200 ROP drilling break.;Drill 8 1/2"hole f/9163' t/9281(118)AROP=19.6 FPH WOB 5-25K,540 gpm-1780 psi,140 TD RPM,15-17k ft/lbs tq,P/U 165K,S/0 90K,ROT 123K. MW 8.9 ppg,vis 40,ECD 10.1 ppg.;Adjust parameters as needed to drill hard spots.;Drill 8 1/2"hole (/9281't/9430'(149)ROP=24.8 FPH WOB 5-25K,535 gpm-1750 psi,140 TD RPM,15-16k ft/lbs tq,P/U 165K,5/O 90K,ROT 120K. MW 8.9+ppg,vis 40,ECD 10.ppg.;Drill 8 1/2"hole f/9430'U 9601(171)ROP 28.5 FPH WOB 5-25K,516 gpm-1660 psi,140 TD RPM,12.5k fUlbs tq,P/U 165K,5/O 90K,ROT 120K. MW 8.9+ppg,vis 40,ECD 10.1 ppg.;Adjust parameters as needed to drill hard spots.;Hauled 522 bbls to G&I-Total Hauled 12373 bbls Hauled 0 bbls to Pad 3-Total Hauled 110 bbls Hauled 0 bbls to B-50-Total Hauled 35 bbls Hauled 0 bbls H2O F/L-Pad Lake-Total Hauled 9810 bbls;Hauled 125 bbls H2O F/6 Mile Lake-Total Hauled 1205 bbls Hauled 0 bbls of H2O FNern Lake-Total Hauled 1341 bbls Total Hauled 1341 bbls- Daily Fluid Loss:83 bbls Total Fluid Loss:478 bbls;Distance to Plan: 5.15'High 28'Right Rotating Hrs.=13.86 11/7/2015 Drill 8 1/2"hole f/9601'U 9643' WOB 5-25K,516 gpm-1660 psi,140 TD RPM,12.5k fUlbs tq,P/U 165K,5/O 90K,ROT 120K. MW 8.9+ppg,vis 40,ECD 10.1 ppg.;PU off btm @ 9643'due to no ROP and 20-25 WOB.Could not work past 9639'.Stacking out with no wt transfer to bit.Attempt multiple methods to drill past 9639'with no success.;Pull Short 3 stand BHA wiper with 15K over pull leaving bottom and no issues after. Attempt to drill past 9639'again with same results,stacking weight 4'from TD.;Blow down Top Drive.TOH on elevators from 9639'to the 9 5/8'shoe @ 6538'with no issues.;Continued POOH elevators from 6538'to Bit.;Down load MWD stand back flex DC,break out Bit and L/D Geo-Pilot (BIT GRADE:Inner 2-Outer 1-Dull Char.CT-Location A-Gage I-Reason Pull-BHA);Pick up BOP wash tool and wash out bop's-pull wear ring-drain stack- set test plug and test bop's.;Test BOP:Test annular 250/2500psi. BOP rams,valves& choke components tested to 250/3000psi. (State Rep.Jeff Jones waived to witness test);Hauled 174 bbls to G&-Total Hauled 12547 bbls Hauled 0 bbls to Pad 3-Total Hauled 110 bbls Hauled 0 bbls to B-50- Total Hauled 35 bbls Hauled 0 bbls H2O F/L-Pad Lake-Total Hauled 9810 bbls;Hauled 260 bbls H2O F/6 Mile Lake-Total Hauled 1465 bbls Hauled 0 bbls of H2O FNern Lake-Total Hauled 1341 bbls Daily Fluid Loss:51 bbls-Total Fluid Loss:529 bbls;Distance to Plan: 9.53'High 32.02'Right 11/8/2015 Continue to Test BOP:Test annular 250/2500psi. BOP rams,valves& choke components tested to 250/3000psi. (State Rep.Jeff Jones waived to witness test);Pull Test Plug,Set Wear Bushing.Clear floor of test tools.;Slip and cut drill Iine.;MU BHA#13,8-1/2"Rotary Steerable:W/NOV SK616M- J1 D PDC Bit,GEO Pilot w/8.250"stab,Drill DOC,DGR,PWD,ILS,ADR,DM,TM,Float Sub,3-NMPC,1-HWDP,Jar,1-HWDP.Total Length= 277.53.;Upload MWD,TIH 1 stand DP and shallow test MWD and GEO Pilot.Blow down Top Drive.;TIH from 300'to 8650'with no issues.TIH from 8650'(Side track Depth)slowly past 9101'(Top of fish in old hole)with no issues.Cont TIH to 9620'Est.Parameters and wash/ream to TD w/no issues.;PU off bottom and decrease pump rate and circulate to shear mud.starting @ 250 gpm staging up to minimum drilling rate @ 465 gpm.;Drill 8 1/2"hole f/9644'U9893'(249)AROP= 22.6 FPH WOB 5-25K,536 gpm-1865 psi,140 TD RPM,15-17k ft/lbs tq,P/U 165K,S/0 80K,ROT 123K. MW 8.9 ppg,vis 40,ECD 10.0 ppg.;Hauled 116 bbls to G&I-Total Hauled 12663 bbls Hauled 0 bbls to Pad 3-Total Hauled 110 bbls Hauled 0 bbls to B-50-Total Hauled 35 bbls Hauled 0 bbls H2O F/L-Pad Lake-Total Hauled 9810 bbls;Hauled 170 bbls H2O F/6 Mile Lake-Total Hauled 1635 bbls Hauled 0 bbls of H2O FNern Lake-Total Hauled 1341 bbls Daily Fluid Loss:33 bbls-Total Fluid Loss:562 bbls;Distance to Plan: 13.58'High 32.36'Right Rotating Last 24 hours: 4.95 11/9/2015 Drill 8 1/2"hole f/9893'U10,050'(157')AROP= 26.2 FPH WOB 5-25K,536 gpm-1865 psi,140 TD RPM,15-17k fUlbs tq,P/U 165K,S/0 80K,ROT 123K. MW 8.9 ppg,vis 40,ECO 10.0 ppg.;Drill on hard formation @ 9902'1-2 fph w/80-100fph drilling break @ 9904'.;Drill 8 1/2"hole f/10,050'U10,300' (250')AROP= 41.6FPH WOB 5-25K,536 gpm-1865 psi,140 TD RPM,15-17k fUlbs tq,P/U 165K,S/O 85K,ROT 120K. MW 9.0 ppg,vis 38,ECD 10.1 ppg.;Drilled ahead in OA-3 target sand to 10265'MD,having DD decrease inclination to—90°in anticipation of fault crossing. Once fault is crossed,will proceed down at—85°in order to reenter target sand on other(downthrown)side of fault;Drill 8 1/2"hole f/10,300't/10658' (358')AROP= 59.6FPH WOB 5-25K,536 gpm-1865 psi,140 TD RPM,15-17k fUlbs tq,P/U 165K,5/O 85K,ROT 120K. MW 9.0 ppg,vis 38,ECD 10.1 ppg.;Drill 8 1/2"hole f/10658'U 11055'(397')AROP= 66.1 FPH WOB 5-25K,500 gpm-1907psi,140 TD RPM,15-17k fUlbs tq,P/U 172K,S/O 70K,ROT 120K. MW 9.0 ppg,vis 38,ECD 10.1 ppg.;Hauled 174 bbls to G&I-Total Hauled 12837 bbls Hauled 0 bbls to Pad 3-Total Hauled 110 bbls Hauled 0 bbls to B-50-Total Hauled 35 bbls Hauled 0 bbls H2O F/L-Pad Lake-Total Hauled 9810 bbls;Hauled 180 bbls H2O F/6 Mile Lake-Total Hauled 1815 bbls Hauled 0 bbls of H2O FNern Lake-Total Hauled 1341 bbls Daily Fluid Loss:43 bbls-Total Fluid Loss:605 bbls;Distance to Plan: 53.91'High 57.24'Left Rotating Last 24 hours:13.62 • • 11/10/2015 Continue Drilling 8 1/2"hole F/11055'T/11180' (125)AROP= 56.6 FPH WOB 5-25K,500 gpm-1950psi,120 TD RPM,18-20K ft/lbs tq,P/U 192K,S/O 65K,ROT 120K. MW 9.0 ppg,vis 38,ECD 10.1 ppg.;Pull up and rack back one stand then adjust drilling torque on top drive.Test.GOOD.;Continue Drilling 8 1/2"hole F/11180'T/11391 (211')AROP= 38.3 FPH av WOB 5-25K,500 gpm-1950psi,95 TD RPM,18-20K ft/lbs tq,P/U 192K,S/O 65K,ROT 120K. MW 9.0 ppg,vis 38,ECD 10.1 ppg.;Hard spots @ 11360'-11370';P00H due to traction motor on#2 pump down-Circ B/U with one pump @300 gpms 95 rpms,pull stand rack back,blow down top drive, monitor well(static losses 1.5bph);P00H on Elevators P/U 225k S/O 65k (No Pumps) encountered tight spot @ 10134'pulling 30k wiped through twice.(gone) continue POOH on elevatores F/10,134'to 6552'No Issues;Rigs down due to#2 pump traction motor-Monitor well on trip tank(The well is losing 1.5bph);Crew serviced Top Drive,Crown and Draw works:Hauled 290 bbls to G&I-Total Hauled 13127 bbls Hauled 290 bbls to Pad 3-Total Hauled 400 bbls Hauled 0 bbls to B-50-Total Hauled 35 bbls Hauled 0 bbls H2O F/L- Pad Lake-Total Hauled 9810 bbls;Hauled 270 bbls H2O F/6 Mile Lake-Total Hauled 2085 bbls Hauled 0 bbls of H2O FNern Lake-Total Hauled 1341 bbls Daily Fluid Loss:166 bbls-Total Fluid Loss:771 bbls;Distance to Plan:14.74'High 15.44'Left 11/11/2015 continue working on Traction motor on#2 pump.;Circ.bottoms up 5bpm @ 470 psi.;Continue working on Traction motor on#2 pump-Slip and cut off drilling line.,Continue working on Traction motor on#2 pump-Change out saver sub on top drive-adjuct torque on top drive and adjust compensator on top drive.;Continue working on Traction motor on#2 Circ.bottoms up with#1 5 bpm @ 470 psi.;Continue working on Traction motor on#2-Crew worked on spinners and housekeeping.;Circ.bottoms up with #1 5bpm @ 490 psi.;Continue working on Traction motor on#2-housekeeping-Repair hyd.Cylinder for spinners(static fluid loss 1.5);Cut pedestal guides and align traction motor to pump, terminate wiring harness on traction motor, install bull wheel&traction motor pulley.;Circ.bottoms up with#1 5bpm @ 475 psi.while working on pump(dynamic fluid loss 6 bph).;Continue working on Traction motor on#2-traction motor in place,installing guards.;POOH F/6521' T/5206' so 5"DP can be picked up in casing;Continue working on Traction motor on#2 P/U 48 jnts.of 5"DP out of the pipe shed.;Hauled 0 bbls to G&I-Total Hauled 13127 bbls Hauled 0 bbls to Pad 3- Total Hauled 400 bbls Hauled 0 bbls to B-50-Total Hauled 35 bbls Hauled 0 bbls H2O F/L-Pad Lake-Total Hauled 9810 bbls;Hauled 0 bbls H2O F/6 Mile Lake-Total Hauled 2085 bbls Hauled 0 bbls of H2O FNern Lake-Total Hauled 1341 bbls -Daily Fluid Loss:34 bbls-Total Fluid Loss:805 bbls 11/12/2015 Finish installing guards on MP#2.Test pump to psi Good.;Test pump&circ&condition mud at 300 gpm,721 psi.;RIH F/6493'T/9500'.Clean.;Fill pipe&circ one open hole volume. Stage up pumps to 350 gpm.;RIH F/9500'T/10500'.Started taking wt.Push to 11300'.;Circ&condition.Stage up pumps to 450 gpm. Wash down F/11300 T/11391'.;Drill 8 1/2"hole f/11391'U11,496'(105')AROP= 10.5 FPH WOB 5-25K,443-1575 psi,130 TD RPM,15-17k ft/lbs tq,P/U 210S/0 0 ROT 120k MW 9.1ppg.vis 38,ECD 101ppg.;Drill 8 1/2"hole f/11,496'U11633'(137)AROP=27.4FPH WOB 5-25K,535gpm-2050 psi,130 TD RPM,15-17k ft/lbs tq,P/U 210K,S/00 ROT 120K. MW 9.05 ppg,vis 40 ECD 10.0 ppg.;Valve out on#2 mud pump;rack back one stand and circ.@ 300 gpm.1450 psi while changing valve out;Hauled 116 bbls to G&I-Total Hauled 13243 bbls Hauled 0 bbls to Pad 30-Total Hauled 400 bbls Hauled 0 bbls to B-50-Total Hauled 35 bbls Hauled 0 bbls H2O F/L-Pad Lake-Total Hauled 9810 bbls;Hauled 230 bbls H2O F/6 Mile Lake-Total Hauled 2315 bbls Hauled 562 bbls of H2O FNern Lake- Total Hauled 1903 bbls Daily Fluid Loss:60 bbls-Total Fluid Loss:865 bbls;Distance to Plan:8.34'High 0.25'Right Rotating Last 24 hours: 8.39 11/13/2015 Circ &condition @ 300 gpm while working on#2 MP.;Drill 8 1/2"hole F/11633"T/11690'(57)AROP=11.4FPH WOB 5-25K,535gpm-2650 psi,130 TD RPM,15-17k ft/lbs tq,P/U 215K,S/O 0 ROT 125K. MW 9.0 ppg,vis 42 ECD 10.0 ppg.;Drill 8 1/2"hole F/11690'T/12315'(625)AROP=125FPH WOB 5-20K,535gpm-2650 psi,120 TD RPM,15-17k ft/lbs tq,P/U 215K,S/00 ROT 125K. MW 9.0 ppg,vis 40 ECD 10.0 ppg.;Max gas @ 1100. Drilled in to a fault @ 11777'&in to the OA 4 or 5.Started to build after 11800'. Built INC to 92 deg to build back up in to the OA 3.;Drill 8 1/2"hole F/12315'U12614'(299)AROP=85.4 FPH WOO 5-20K,461 gpm-2060 psi,120 TD RPM,15-17k ft/lbs tq,P/U 215K,S/00 ROT 125K. MW 9.0 ppg,vis 40 ECD 10.2 ppg.;Drill 8 1/2"hole F/12614'T/12645'(31)AROP=15.5 FPH WOB 5-20K,532 gpm-2560 psi,120 TD RPM,15-17k ft/lbs tq,P/U 220K,S/00 ROT 125K. MW 9.0 ppg,vis 40 ECD 10.7 ppg. (0A3 12,420');Adjust parameters as needed to drill hard spots.Most concretions in this time interval 2'to 3'thick average time spent on each 20min;Instantaneous ROP after concretion range 140 to 210 fph.;Drill 8 1/2"hole F/12645'T/12,735 (90)AROP= 25.7 FPH WOO 5-25K,532 gpm-2560 psi,120 TD RPM,15-17k ft/lbs tq,P/U 215K,S/00 ROT 125K. MW 9.15 ppg,vis 40 ECD 10.4 ppg.0A3;Concretions in this time interval 10' thick average time spent on each 1.5hrs;Instantaneous ROP after concretion range 25 to 45 fph. Before drilling into another.;Drill 8 1/2"hole F/12,735 T/12788' (53)AROP= 13.25 FPH WOB 5-30K,410 gpm-1633 psi,120 TD RPM,15-17k ft/lbs tq,P/U 215K,S/00 ROT 125K. MW 9.15 ppg,vis 41 ECD 10.3 ppg.0A3;Adjust parameters as needed to drill hard spots. More of the same from last time interval 5'to 10' thick average time spent on each 2.5hrs;Instantaneous ROP after concretion range 25 to 60 fph.;Hauled 290 bbls to G&I-Total Hauled 13533 bbls Hauled 0 bbls to Pad 3-Total Hauled 400 bbls Hauled 0 bbls to B-50-Total Hauled 35 bbls Hauled 0 bbls H2O F/L-Pad Lake-Total Hauled 9810 bbls;Hauled 245 bbls F/6 Mile Lake-Total Hauled 2560 bbls Hauled 0 bbls of H2O FNern Lake-Total Hauled 1903 bbls Daily Fluid Loss:132 bbls- Total Fluid Loss:997 bbls;Distance to Plan:8.17'High 23.17'Left Drilling Hours Last 24 hours: 11.32 11/14/2015 Drill 8 1/2"hole F/12788'T/12794 (5)AROP= 2 FPH WOB 5-30K,410 gpm-1633 psi,95 TD RPM,15-17k ft/lbs tq,P/U 215K,S/O 0 ROT 125K. MW 9.15 ppg,vis 41 ECD 10.3 ppg. Hard drilling.;Rack a stand back.Ream to btm @ max deflection.Try light wt 5-10&max RPM @ 130.Would not drill. Try more wt&less RPM.No go. Decide to short trip to last wiper.;Monitor well.Good.POOH F/12794'T/12040'up wt 215 off btm Started pulling 240-275 after the first stand pulled. Wipe down and pulls clean @ 240-260.;Continuing to over pull more&more.Wpe down&still 240- 260 up.Pulling up to 300.Decide to circ&ream out to clear cuttings beds.;Wash&backream F/12040'T/11555 @ 540 gpm 100 rpm. No over pulls. Smooth.,Circ btm up @ 540 gpm 100 rpm. Lost MP#2 valves and seats. Lower pump Rate to 300 GPM.Got very little solids back.;Service TD & rig. While working on MP#2.;RIH on elevators F/11555'T/12200'. Unable to RIH floating in elevators.;Wash&ream @ 300 GPM 65 RPM. F/ 12200'T/12794'. Lost#1 pump#1 liner. Change liner while RIH.;Drill ahead with light wt on bit 5-12 300 gpm @ 95 rpm F/12794'. Not making any hole.Play with parameters with wt&RPM. No difference. Put#1 pump back on and ream down&it took off drilling.;Drill 8 1/2"hole F/12794 T/ 12825 (31)AROP= 31 FPH WOB 5-15K,525 gpm-2540 psi,95 TD RPM,8-15k fUlbs tq,P/U 215K,S/00 ROT 125K. MW 9.15 ppg,vis 41 ECD 10.6 ppg. Hard drilling.;Drill 8 1/2"hole F/12825 T/13035 (210)AROP= 52.5 FPH WOB 5-15K,520 gpm-2480 psi,95 TD RPM,8-12k ft/lbs tq,P/U 220K,S/OO ROT 125K. MW 9.05 ppg,vis 41 ECD 10.6 ppg.;Pick up off bottom&flow check well; receiving 500 units of gas and very little flow that stopped after 15min None pressurized scale showed 8.6 coming out 8.7+going in.Pressurized scale 9.05.;ECD's 10.5.Turned the water off in the pits and zero PVT gain loss and strokes.went back to drilling.;Drill 8 1/2"hole F/13035 1/13054' (19')AROP 19 FPH WOB 5-15K,520 gpm-2480 psi,95 TD RPM,8-12k ft/lbs tq,P/U 220K,S/O0 ROT 125K. MW 9.05 ppg,vis 41 ECD 10.6 ppg.;At bottoms up observed 350 units of gas(connection gas).;Drill ahead with one pump light wt on bit 5-12 300 gpm @ 95 rpm while changing out valve and seat on mud pump#1(No footage was made while working on pump).;Drill 8 1/2"hole F/13054'T/13140' (86) AROP= 15.6 WOB 5-20 537pm-266psi,120 RPM,8-12k ft/lbs tq,P/U 220K,S/00 ROT 125K. MW 9.05 ppg,vis 41 ECD 10.8ppg.;Concretions in this time interval 10' thick average time spent on each 2.5hrs;Instantaneous ROP after concretion range 25 to 200 fph. Before drilling into another.;Hauled 290 bbls to G&I-Total Hauled 13823 bbls Hauled 0 bbls to Pad 3-Total Hauled 400 bbls Hauled 0 bbls to B-50-Total Hauled 50 bbls Hauled 0 bbls H2O F/L-Pad Lake-Total Hauled 9810 bbls;Hauled 430 bbls F/6 Mile Lake-Total Hauled 2990 bbls Hauled 0 bbls of H2O FNern Lake-Total Hauled 1903 bbls Daily Fluid Loss:165 bbls-Total Fluid Loss:1162 bbls;Distance to Plan: 4.81' High 16.16'Left Rotating Last 24 hours: 7.13 • . 11/15/2015 Drill 8 1/2"hole F/13140' T/13212'. (72) AROP=9 WOB 5-30 537pm-2660psi,50-120 RPM,18-22k ft/lbs tq,P/U 220K,S/O 0 ROT 125K. MW 9.1 ppg,vis 41 ECD 10.8,ppg.;While drilling at 0 deflection on a hard spot we built 1.94 deg in 8'. Calculated 24 deg dogleg. After reaming& trying to decrease the dogleg TD was called.;Decision made from Town GEO&drilling engineer to call TD @ 13212'do to risk of tool damage or problems during sidetrack.;Ream out dogleg&circ 2.5 btm up @ 550 gpm 120 rpm.MW 9.1;Monitor well.Good. Pump every 3rd stand out of the hole F/13212'T/9653'@ 500 gpm. Clean hole no over pull while pumping.;Blow down TD.Pull out on elevators F/9653' T/6463,(No Issues) Monitor well on trip tank while servicing the rig.;Rig service on top drive,draw works.;Slip and cut off 60'of drilling Iine.;Circ.hole clean at 541 gpm 1960 psi.100 rpms. (No change in the amount of cuttings coming over the shakers);RIH F/6463'T/10815'on elevators(No Issues Going).;Hauled 454 bbls to G&I-Total Hauled 14277 bbls Hauled 0 bbls to Pad 3-Total Hauled 400 bbls Hauled 70 bbls to 6-50-Total Hauled 120 bbls Hauled 0 bbls H2O F/L-Pad Lake-Total Hauled 9810 bbls;Hauled 200 bbls F/6 Mile Lake-Total Hauled 3190 bbls Hauled 0 bbls of H2O FNern Lake-Total Hauled 1903 bbls Daily Fluid Loss:133 bbls-Total Fluid Loss:1295 bbls;Distance to Plan:9.32'High 3.13'Left Drilling Hours Last 24 hours: 3.11 11/16/2015 RIH F/10815'on elevators T/12200'. Tag up. Wash&ream @ 520 gpm, 65 RPM, clean.18K TQ.;Circ hole clean two btm up @ 550 gpm,80 RPM, 15-18K TQ. Thaw out cuttings shoot.;Displace to 8.9 PPG solids free mud system @ 7 BPM.;Monitor well.Good. POOH on elevators F/13212'T/ 6450'on elevators clean. 10-15K bobbles. Hole taking.;Continue POOH on elevators in casing F/6450' T/4855'.;L/D 4,578'of 5"Drill pipe and remove from pipe shed.;BHA:L/D Jars and flex DC;Down load MWD/PWD,break off bit and L/D Geo Pilot.;PJSM on changing rams:Rinse out BOP; Change Lower set of rams to 5.5 solid&change the upper set to 2 7/8 X 5'VBR's.;Hauled 1184 bbls to G&I-Total Hauled 15461 bbls Hauled 0 bbls to Pad 3-Total Hauled 400 bbls Hauled 0 bbls to 6-50-Total Hauled 120 bbls Hauled 0 bbls H2O F/L-Pad Lake-Total Hauled 9810 bbls;Hauled 100 bbls F/6 Mile Lake-Total Hauled 3290 bbls Hauled 0 bbls of H2O FNern Lake-Total Hauled 1903 bbls Daily Fluid Loss:34 bbls-Total Fluid Loss: 1329 bbls • s Hilcorp Energy Company Composite Report Well Name: MP L-48 Field: North Slope County/State: ,Alaska (LAT/LONG): svation(RKB): API#: Spud Date: 10/10/2015 Job Name: 1511126C MP L-48 Completion Contractor AFE#: 1511126C AFE$: $1,093,100 Activity Date Ops Summary 11/17/2015 Pull WB,Set test plug.Wash out stack.,Change lower rams to 5.5.Change upper rams to 2 7/8 X 5"VBRs.,Test bops to 250/3000 psi,Test 5.5 lower rams Test upper VBRs to 2 7/8&5".Test Annular to 5". Test gas alarms.GOOD.Blow down surface equipment.R/D testing equipment. Pull test plug. Set Wearbushing with a 10"ID.,R/U Weatherford casing equipment.Finish loading&strapping ICDs&packers.,PJSM,Run liner. Check pipe count. Set Last two ICDs to 9 port injectors. P/U 4.5 shoe assembly with Packoff. Run 5.5 DWC with Weatherford F/surface T/6528'. Pipe filling through screens. Load 2 7/8 for the inner string. Strap&tally same.,Parked above 9 5/8 csg shoe @ 6528'M/U top drive, XO and FOSV,obtain parameters, P/U 122K,S/O 90K,ROT 105K, rotate 10 rpm @ 3000 ft/lbs,20 rpm @ 3500 ft/lbs,30 rpm @ 4000 ft/lbs.Adjust top drive to 13000#torque.,Kick out 9 jts excess 5 1/2"liner.Load 210 jts 2 7/8" fox tubing (inner string)in pipe shed,strap same.,Continue to P/U and RIH with 5 1/2"liner from 6528'to 6861'(161 jts total 5 1/2"liner),install hand slips and dog collar clamp. Note:18 bbls under calculated displacement on trip in the hole.,Monitor well,Install FOSV and XO,R/U false table,2 7/8"handling equipment and triple connect XO for FOSV.L/D FOSV and XO.drift,P/U and RIH with 2 3/8"slick stick,XO,29 jts 2 7/8"hydril 511 tbg. Static loss rate 1 bph.,Hauled 190 bbls to G&I-Total Hauled 15651 bbls Hauled 0 bbls to Pad 3-Total Hauled 400 bbls Hauled 0 bbls to B-50-Total Hauled 120 bbls Hauled 0 bbls H2O F/L-Pad Lake-Total Hauled 9810 bbls,Hauled 100 bbls F/6 Mile Lake-Total Hauled 3390 bbls. Hauled 1216 bbls of H2O FNern Lake-Total Hauled 3119 bbls. Daily Fluid Loss:28 bbls-Total Fluid Loss:1357 bbls. Rig fuel used 1773 gal,on hand 17497 gal,8323 gal received. 11/18/2015 M/U Xo&RIH with fox tubing T/6900'. P/U S/O 88/58K.P/U baker liner top packer assembly.M/U same to inner string&5.5 DWC. P/U/SO. 170/115K Establish circ @ 1 bpm 280 psi. Change handling equipment to 5".,Change handling equipment to 5". R/U spinners. RIH on 5"DP out of derrick. F/6909'work thru tight spot @ 12465' Start taking wt @ 12625',use top drive to work to bottom @13212',Fill pipe every 10 stands to 12625'then fill every 5 stds w/top drive,P/U 255K,unable to get S/O wt.Break circulation on last std pumping 1 bpm 520 psi, pull string in tension to 255k up wt.park string. Note:24 bbls under calculated hole fill on trip in.,Circulate 1 bpm,320 psi,while waiting on last load of brine to arrive, PJSM for fluid displacement.,Displace wellbore to 8.9 ppg 3%KCL pumping 1 bpm 330 psi w/1.5 bph loss rate, 40 bbls pumped increase to 1.5 bpm 350 psi,90 bbls pumped increase to 2 bpm 420 psi w/filter cake @ shakers,200 bbls pumped increase to 3 bpm 810 psi,loss rate 1.5 bph.,321 bbls pumped increase to 3.4 bpm 1020 psi.,Hauled 48 bbls to G&I-Total Hauled 15699 bbls Hauled 0 bbls to Pad 3-Total Hauled 400 bbls Hauled 0 bbls to B-50-Total Hauled 120 bbls Hauled 0 bbls H2O F/L-Pad Lake-Total Hauled 9810 bbls,Hauled 50 bbls F/6 Mile Lake-Total Hauled 3440 bbls. Hauled 0 bbls of H2O FNern Lake-Total Hauled 3119 bbls. Daily Fluid Loss:32 bbls-Total Fluid Loss:1389 bbls. Rig fuel used 2100 gal,on hand 15397 gal. 11/19/2015 Displace well to 8.9 ppg 3%KCL brine. Wall cake cleaned up after displacing to brine.Circ two 40 bbl sap pills @ 4 bpm 1300 psi.Two full circulations. No wall cake was observed after sap pills came back. Displace to clean 8.9 ppg 3%KCL Brine. Shut down.Drop 1.25 OD ball. Pump ball down.Ball on seat @ 90 bbl away.Pressure up to 1400 psi.Shift WIV. Pressure up&set packer @ 3000 psi with mud pumps.,Finish setting packer with test pump to 4000 psi. Bleed down. Test annulus to 1500 psi for 10 minutes,good test.bleed off pressure,P/U TO 195K to confirm release. Note:5 1/2"liner set @ 13211',TOL=6316.08',packer element @ 6329',Breakout top drive,under balanced,flowing out DP,M/U FOSV and head pin,mix and pump dry job.Blow down top drive and lines.,POH from 13155'L/D 72 jts 5"DP and 18 jts HWDP,rack 37 stands 5"DP in derrick to 6810',R/U power tongs,L/D and inspect running tool,L/D 1 jt 2 7/8"fox tbg.,M/U 9 5/8"csg scraper x boot basket assy on top 2 7/8"fox tbg,TIH with 5"stds from 6800'to 7000',Hauled 0 bbls to G&I-Total Hauled 15699 bbls Hauled 1045 bbls to MP G&I-Total 1045 bbls Hauled 0 bbls to Pad 3-Total Hauled 400 bbls Hauled 11120 bbls to B-50-Total Hauled 1240 bbls Hauled 0 bbls H2O F/L-Pad Lake-Total Hauled 9810 bbls,Hauled 100 bbls F/6 Mile Lake-Total Hauled 3540 bbls Hauled 1620 bbls of H2O FNern Lake-Total Hauled 4739 bbls Daily Fluid Loss:27 bbls-Total Fluid Loss:1416 bbls. Rig fuel used 2000 gal,on hand 13397 gal. 11/20/2015 RIH on 5"Dp with 9 5/8 scraper,boot baskets&2 7/8 Cleanout assembly. F/7000'T/13160'. Scraper on depth @ 6300'.Break circ.Close the annular. Reverse circ @ 3 bpm.Displace mud out of 5.5 liner. Dump 187 bbl. During displacement. Shut down.Pump down tubing&displace liner with clean 8.9 ppg 3%KCL. Shut down.POOH L/D 5"DP F/13160'T/9000'.,Continue POH L/D 5"DP from 9000'to 6800'(201 jts total),L/D scraper,boot baskets and XOs,boot baskets clean.,R/U 2 7/8"handling equipment,under balanced,flowing out tbg, pump 3/4 ppg over 12 bbl dry job.POH L/D 190 jts of fox tbg, XO,29 jts 511 tbg, XO and slick stick.,C/O elevators,pull 10"ID wear bushing„PJSM,cut and slip 62'drilling line,re-set and test crown saver.,Hauled 200 bbls to G&I-Total Hauled 15899 bbls Hauled 0 bbls to MP G&I-Total 1045 bbls Hauled 0 bbls to Pad 3-Total Hauled 400 bbls Hauled 65 bbls to B-50-Total Hauled 1305 bbls Hauled 0 bbls H2O F/L-Pad Lake-Total Hauled 9810 bbls,Hauled 140 bbls F/6 Mile Lake-Total Hauled 3680 bbls. Hauled 0 bbls of H2O F/Vern Lake-Total Hauled 4739 bbls. Daily Fluid Loss:33 bbls-Total Fluid Loss:1449 bbls. Rig fuel used 1900 gal,on hand 11497 gal. 11/21/2015 Prep to run 3 1/2 packer completion. Clear floor of baker clean out assembly,Change handling equipment to 3 1/2.,P/U 3 1/2 packer completion,ratcheting Mule shoe, 3 Joints,6.5 OD No GO,3 more joints,Mirage plug assembly,PHL packer assembly, 98 joints, GLM with Sheer valve set @ 2500 psi, 28 more joints, X Nipple, 65 joints, Run in 3 extra joints to NoGo Out.Tag on depth with LT tagged @ 6315'.L/D 3 joints&M/U Pup,Hanger. Run in hanger&Keep off seat 2'.,Reverse circ corrosion inhibitor @ 3 bpm,250 psi,194 bbl,Chase with 189 bbl seawater. Spot 8.6 ppg seawater with Baracor 100 F/3000'T/6161'.,Land hanger,RILD.DN wt 68,Up 85K. Mule shoe stung in to 5.5 liner 22.8'@ 6364', Mirage Plug 6163',PHL Packer 6135', GLM 3007', X Nipple @ 2095.Blow down top drive.,R/U test pump to pump down tbg,R/U mud pump to pump down annulus.Monitor open annulus pump down tbg,pressure up to 500 psi for 5 min, pressure to 3650 psi,auto fill shifted closed @ 1600 psi,packer start to set @ 2100 psi. Test tbg @ 3650 psi for 30 min,charted.Bleed tbg to 1700 psi,With rig pump pressure up annulus to 500 psi,hold for 5 min. Pump 5 bbls and pressure up to 3100 psi and test packer,hold for 30 min charted,good test.Bleed off tbg to shear DCR valve,pump 4 bbls ea way @ 2 bpm to confirm shear.,R/D lines,pull landing jt.Install TWC per wellhead rep,test same to 1000 psi for 5 min charted.Suck out stack,R/D test equipment.,PJSM,N/D BOPE.Set tree in cellar.,N/U tree,test void to 500 psi low for 5 min,5000 psi high for 15 min,test tree with diesel to 500 psi low for 5 min,5000 psi high for 15 min per wellhead rep.R/U lubricator,pull TWC.Secure well.,Rig released from MPU L-48 @ 06:00„Hauled 0 bbls to G&I-Total Hauled 15899 bbls Hauled 0 bbls to MP G&I-Total 1045 bbls Hauled 0 bbls to Pad 3-Total Hauled 400 bbls Hauled 290 bbls to B-50-Total Hauled 1595 bbls Hauled 0 bbls H2O F/L-Pad Lake-Total Hauled 9810 bbls,Hauled 0 bbls F/6 Mile Lake-Total Hauled 3680 bbls. Hauled 0 bbls of H2O FNern Lake-Total Hauled 4739 bbls Daily Fluid Loss:52 bbls-Total Fluid Loss:1501 bbls. Rig fuel used 1833 gal,on hand 14297 gal,received 4633 gal. 11/22/2015 Prep to move rig.R/D containments.Secure cellar.Move rig off well. P/U rig mats around L-48. Spot Little Red.R/U Kill tank&lines.Test same. Pump down tubing taking returns to the kill tank.Pump 220 bbl down the tubing.2 bpm @ 140-170 psi. Got back good diesel to Kill tank.Shut down suck lines clear.R/D kill tank and lines.Turn over to production. • • Hilcorp Energy Company Milne Point M Pt L Pad MPL-48 500292355200 500292355200 Sperry Drilling Definitive Survey Report 02 December, 2015 HALLIBURTON Sperry Drilling • • Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPL-48 Project: Milne Point TVD Reference: As-Built MPL-48 @ 47.50usft Site: M Pt L Pad MD Reference: As-Built MPL-48 @ 47.50usft Well: MPL-48 North Reference: True Wellbore: MPL-48 Survey Calculation Method: Minimum Curvature Design: MPL-48 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-48 Well Position +N/-S 0.00 usft Northing: 6,031,478.37 usft Latitude: 70°29'48.710 N +El-W 0.00 usft Easting: 545,122.81 usft Longitude: 149°37'51.652 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 17.50 usft Wellbore MPL-48 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 9/17/2015 18.91 81.08 57,505 Design MPL-48 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 8,706.70 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 30.00 0.00 0.00 151.04 Survey Program Date 12/2/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 90.00 972.00 MPL-48 Gyro(MPL-48PB1) SRG-MS Surface readout gyro multishot 09/29/2015 1,066.56 1,915.86 MPL-48 MWD(MPL-48PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/13/2015 2,013.79 6,509.01 MPL-48 MWD(MPL-48PB3) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/19/2015 6,630.56 8,706.70 MPL-48 MWD(2)(MPL-48PB3) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/29/2015 8,720.00 13,130.78 MPL-48 MWD(MPL-48) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/05/2015 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100•) (ft) Survey Tool Name 30.00 0.00 0.00 30.00 -17.50 0.00 0.00 6,031,478.37 545,122.81 0.00 0.00 UNDEFINED 90.00 0.63 135.44 90.00 42.50 -0.24 0.23 6,031,478.14 545,123.04 1.05 0.32 SRG-MS(1) 134.00 0.57 129.63 134.00 86.50 -0.55 0.57 6,031,477.83 545,123.38 0.19 0.75 SRG-MS(1) 221.00 0.52 138.84 220.99 173.49 -1.12 1.16 6,031,477.26 545,123.98 0.12 1.54 SRG-MS(1) 316.00 0.65 140.74 315.99 268.49 -1.86 1.79 6,031,476.52 545,124.61 0.14 2.49 SRG-MS(1) 408.00 1.98 145.56 407.96 360.46 -3.58 3.02 6,031,474.81 545,125.85 1.45 4.59 SRG-MS(1) 502.00 3.35 144.47 501.86 454.36 -7.15 5.53 6,031,471.25 545,128.38 1.46 8.94 SRG-MS(1) 596.00 3.75 148.17 595.68 548.18 -12.00 8.75 6,031,466.43 545,131.63 0.49 14.73 SRG-MS(1) 689.00 5.99 144.22 688.34 640.84 -18.52 13.19 6,031,459.93 545,136.11 2.43 22.59 SRG-MS(1) 783.00 7.50 141.21 781.68 734.18 -27.28 19.90 6,031,451.21 545,142.87 1.65 33.51 SRG-MS(1) 12/2/2015 8:10:59PM Page 2 COMPASS 5000.1 Build 73 • • Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPL-48 Project: Mine Point TVD Reference: As-Built MPL-48©47.50usft Site: M Pt L Pad MD Reference: As-Built MPL-48©47.50usf Well: MPL-48 North Reference: True Wellbore: MPL-48 Survey Calculation Method: Minimum Curvature Design: MPL-48 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (g) (ft) (°1100') (ft) Survey Tool Name 878.00 10.77 135.91 875.47 827.97 -38.49 29.96 6,031,440.06 545,153.00 3.55 48.19 SRG-MS(1) 972.00 11.08 137.32 967.76 920.26 -51.44 42.20 6,031,427.19 545,165.32 0.44 65.44 SRG-MS(1) 1,066.56 12.67 154.43 1,060.33 1,012.83 -67.48 52.84 6,031,411.22 545,176.05 4.07 84.63 MWD+IFR2+MS+sag(2) 1,160.89 13.85 169.61 1,152.17 1,104.67 -87.92 59.34 6,031,390.82 545,182.68 3.88 105.66 MWD+IFR2+MS+sag(2) 1,254.60 15.31 185.34 1,242.89 1,195.39 -111.29 60.21 6,031,367.46 545,183.69 4.49 126.53 MWD+IFR2+MS+sag(2) 1,348.91 19.95 197.33 1,332.78 1,285.28 -139.07 54.26 6,031,339.65 545,177.90 6.22 147.95 MWD+IFR2+MS+sag(2) 1,443.95 27.42 205.73 1,419.78 1,372.28 -174.32 39.90 6,031,304.32 545,163.77 8.61 171.84 MWD+IFR2+MS+sag(2) 1,538.05 26.27 206.20 1,503.73 1,456.23 -212.52 21.30 6,031,266.00 545,145.40 1.24 196.26 MWD+IFR2+MS+sag(2) 1,632.41 28.33 209.22 1,587.58 1,540.08 -250.80 1.15 6,031,227.60 545,125.48 2.63 220.00 MWD+IFR2+MS+sag(2) 1,726.67 32.16 214.27 1,669.01 1,621.51 -291.08 -23.91 6,031,187.18 545,100.67 4.87 243.10 MWD+IFR2+MS+sag(2) 1,820.86 36.67 219.85 1,746.71 1,699.21 -333.42 -56.07 6,031,144.65 545,068.77 5.84 264.58 MWD+IFR2+MS+sag(2) 1,915.86 42.43 223.20 1,819.94 1,772.44 -378.60 -96.22 6,031,099.23 545,028.89 6.46 284.67 MWD+IFR2+MS+sag(2) 2,013.79 41.19 224.35 1,892.93 1,845.43 -425.74 -141.38 6,031,051.82 544,984.03 1.49 304.05 MWD+IFR2+MS+sag(3) 2,110.43 44.20 225.11 1,963.95 1,916.45 -472.29 -187.50 6,031,005.00 544,938.19 3.16 322.44 MWD+IFR2+MS+sag(3) 2,204.36 45.23 225.70 2,030.70 1,983.20 -518.68 -234.57 6,030,958.32 544,891.42 1.18 340.25 MWD+IFR2+MS+sag(3) 2,298.13 52.42 227.46 2,092.40 2,044.90 -567.12 -285.83 6,030,909.58 544,840.45 7.80 357.80 MWD+IFR2+MS+sag(3) 2,393.11 53.89 227.08 2,149.35 2,101.85 -618.69 -341.66 6,030,857.68 544,784.94 1.58 375.90 MWD+IFR2+MS+sag(3) 2,488.30 56.96 226.22 2,203.37 2,155.87 -672.50 -398.64 6,030,803.53 544,728.29 3.31 395.38 MWD+IFR2+MS+sag(3) 2,581.81 55.58 225.41 2,255.29 2,207.79 -726.69 -454.41 6,030,749.00 544,672.86 1.64 415.80 MWD+IFR2+MS+sag(3) 2,675.21 56.74 228.88 2,307.31 2,259.81 -779.43 -511.28 6,030,695.93 544,616.32 3.33 434.41 MWD+IFR2+MS+sag(3) 2,768.78 59.09 227.73 2,357.01 2,309.51 -832.17 -570.46 6,030,642.84 544,557.46 2.72 451.89 MWD+IFR2+MS+sag(3) 2,864.92 57.11 228.28 2,407.81 2,360.31 -886.78 -631.12 6,030,587.87 544,497.15 2.12 470.31 MWD+IFR2+MS+sag(3) 2,959.50 60.33 228.21 2,456.91 2,409.41 -940.60 -691.41 6,030,533.68 544,437.19 3.41 488.21 MWD+IFR2+MS+sag(3) 3,052.95 59.58 227.82 2,503.70 2,456.20 -994.71 -751.54 6,030,479.21 544,377.40 0.88 506.44 MWD+IFR2+MS+sag(3) 3,147.34 60.06 226.60 2,551.16 2,503.66 -1,050.14 -811.41 6,030,423.43 544,317.86 1.23 525.94 MWD+IFR2+MS+sag(3) 3,242.51 60.30 224.72 2,598.48 2,550.98 -1,107.85 -870.46 6,030,365.37 544,259.17 1.73 547.84 MWD+IFR2+MS+sag(3) 3,336.40 59.23 224.26 2,645.76 2,598.26 -1,165.71 -927.31 6,030,307.17 544,202.68 1.22 570.95 MWD+IFR2+MS+sag(3) 3,431.74 58.87 224.78 2,694.79 2,647.29 -1,224.01 -984.64 6,030,248.53 544,145.72 0.60 594.20 MWD+IFR2+MS+sag(3) 3,525.06 58.50 224.34 2,743.30 2,695.80 -1,280.81 -1,040.58 6,030,191.39 544,090.13 0.57 616.81 MWD+IFR2+MS+sag(3) 3,619.83 57.94 224.32 2,793.21 2,745.71 -1,338.44 -1,096.87 6,030,133.43 544,034.19 0.59 639.98 MWD+IFR2+MS+sag(3) 3,714.00 57.52 224.20 2,843.49 2,795.99 -1,395.47 -1,152.44 6,030,076.07 543,978.97 0.46 662.96 MWD+IFR2+MS+sag(3) 3,808.53 56.84 224.73 2,894.72 2,847.22 -1,452.16 -1,208.09 6,030,019.04 543,923.68 0.86 685.63 MWD+IFR2+MS+sag(3) 3,903.13 57.21 224.46 2,946.21 2,898.71 -1,508.67 -1,263.81 6,029,962.20 543,868.31 0.46 708.09 MWD+IFR2+MS+sag(3) 3,998.00 56.83 224.23 2,997.85 2,950.35 -1,565.59 -1,319.43 6,029,904.96 543,813.03 0.45 730.95 MWD+IFR2+MS+sag(3) 4,091.73 56.55 223.66 3,049.33 3,001.83 -1,621.99 -1,373.79 6,029,848.23 543,759.02 0.59 753.98 MWD+IFR2+MS+sag(3) 4,185.88 57.47 226.23 3,100.60 3,053.10 -1,677.86 -1,429.58 6,029,792.02 543,703.58 2.49 775.86 MWD+IFR2+MS+sag(3) 4,280.18 57.64 226.67 3,151.19 3,103.69 -1,732.69 -1,487.26 6,029,736.85 543,646.24 0.43 795.91 MWD+IFR2+MS+sag(3) 4,374.65 57.70 225.86 3,201.71 3,154.21 -1,787.88 -1,544.93 6,029,681.32 543,588.91 0.73 816.26 MWD+IFR2+MS+sag(3) 4,469.83 57.88 226.45 3,252.44 3,204.94 -1,843.66 -1,603.01 6,029,625.19 543,531.17 0.56 836.95 MWD+IFR2+MS+sag(3) 4,563.68 57.85 226.57 3,302.36 3,254.86 -1,898.36 -1,660.67 6,029,570.15 543,473.86 0.11 856.89 MWD+IFR2+MS+sag(3) 12/2/2015 8.10:59PM Page 3 COMPASS 5000.1 Build 73 0 ! Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPL-48 Project: Milne Point TVD Reference: As-Built MPL-48 @ 47.50usft Site: M Pt L Pad MD Reference: As-Built MPL-48 @ 47.50usft Well: MPL-48 North Reference: True Wellbore: MPL-48 Survey Calculation Method: Minimum Curvature Design: MPL-48 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi ND TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (h) (k) (°11110) (ft) Survey Tool Name 4,656.75 58.36 224.36 3,351.54 3,304.04 -1,953.77 -1,716.99 6,029,514.40 543,417.88 2.09 878.11 MWD+IFR2+MS+sag(3) 4,751.74 59.42 219.93 3,400.64 3,353.14 -2,014.06 -1,771.52 6,029,453.79 543,363.72 4.15 904.45 MWD+IFR2+MS+sag(3) 4,846.57 60.70 214.18 3,448.00 3,400.50 -2,079.62 -1,820.99 6,029,387.94 543,314.66 5.42 937.86 MWD+IFR2+MS+sag(3) 4,941.15 60.56 208.14 3,494.42 3,446.92 -2,150.10 -1,863.61 6,029,317.21 543,272.47 5.57 978.89 MWD+IFR2+MS+sag(3) 5,035.74 59.07 204.28 3,541.99 3,494.49 -2,223.42 -1,899.73 6,029,243.67 543,236.80 3.86 1,025.56 MWD+IFR2+MS+sag(3) 5,130.07 58.51 199.29 3,590.89 3,543.39 -2,298.30 -1,929.67 6,029,168.62 543,207.32 4.56 1,076.57 MWD+IFR2+MS+sag(3) 5,223.96 59.24 194.27 3,639.44 3,591.94 -2,375.22 -1,952.85 6,029,091.58 543,184.61 4.64 1,132.65 MWD+IFR2+MS+sag(3) 5,318.55 59.60 188.67 3,687.59 3,640.09 -2,454.98 -1,969.02 6,029,011.73 543,168.92 5.11 1,194.60 MWD+IFR2+MS+sag(3) 5,412.73 59.30 183.25 3,735.49 3,687.99 -2,535.60 -1,977.44 6,028,931.06 543,160.99 4.97 1,261.07 MWD+IFR2+MS+sag(3) 5,507.53 58.35 180.69 3,784.57 3,737.07 -2,616.65 -1,980.24 6,028,850.00 543,158.68 2.52 1,330.63 MWD+IFR2+MS+sag(3) 5,601.57 58.76 176.71 3,833.64 3,786.14 -2,696.83 -1,978.42 6,028,769.84 543,160.99 3.64 1,401.67 MWD+IFR2+MS+sag(3) 5,695.84 63.19 171.36 3,879.40 3,831.90 -2,778.74 -1,969.77 6,028,687.99 543,170.13 6.83 1,477.52 MWD+IFR2+MS+sag(3) 5,787.30 67.49 164.44 3,917.59 3,870.09 -2,859.91 -1,952.28 6,028,606.94 543,188.11 8.33 1,557.01 MWD+IFR2+MS+sag(3) 5,884.56 70.63 157.91 3,952.37 3,904.87 -2,945.80 -1,922.95 6,028,521.24 543,217.97 7.05 1,646.37 MWD+IFR2+MS+sag(3) 5,979.01 72.85 152.80 3,981.98 3,934.48 -3,027.28 -1,885.54 6,028,440.00 543,255.87 5.65 1,735.77 MWD+IFR2+MS+sag(3) 6,073.72 73.37 149.33 4,009.51 3,962.01 -3,106.58 -1,841.70 6,028,360.98 543,300.18 3.55 1,826.38 MWD+IFR2+MS+sag(3) 6,168.01 71.89 144.06 4,037.68 3,990.18 -3,181.76 -1,792.32 6,028,286.10 543,350.01 5.56 1,916.07 MWD+IFR2+MS+sag(3) 6,262.05 73.06 138.00 4,066.02 4,018.52 -3,251.43 -1,735.94 6,028,216.78 543,406.81 6.27 2,004.33 MWD+IFR2+MS+sag(3) 6,356.34 75.73 132.52 4,091.40 4,043.90 -3,315.88 -1,672.03 6,028,152.72 543,471.10 6.27 2,091.66 MWD+IFR2+MS+sag(3) 6,450.90 79.89 127.42 4,111.37 4,063.87 -3,375.20 -1,601.22 6,028,093.84 543,542.27 6.87 2,177.85 MWD+IFR2+MS+sag(3) 6,509.01 81.73 126.11 4,120.65 4,073.15 -3,409.53 -1,555.26 6,028,059.80 543,588.42 3.87 2,230.14 MWD+IFR2+MS+sag(3) 6,630.56 84.23 125.38 4,135.51 4,088.01 -3,480.00 -1,457.36 6,027,989.93 543,686.74 2.14 2,339.20 MWD+IFR2+MS+sag(4) 6,725.83 85.96 126.85 4,143.65 4,096.15 -3,535.94 -1,380.68 6,027,934.46 543,763.75 2.38 2,425.28 MWD+IFR2+MS+sag(4) 6,819.20 87.93 128.76 4,148.63 4,101.13 -3,593.09 -1,307.02 6,027,877.76 543,837.75 2.94 2,510.94 MWD+IFR2+MS+sag(4) 6,913.88 89.48 129.79 4,150.77 4,103.27 -3,653.01 -1,233.75 6,027,818.30 543,911.37 1.97 2,598.85 MWD+IFR2+MS+sag(4) 7,007.73 90.29 130.66 4,150.96 4,103.46 -3,713.62 -1,162.10 6,027,758.13 543,983.39 1.27 2,686.57 MWD+IFR2+MS+sag(4) 7,102.46 89.80 130.22 4,150.88 4,103.38 -3,775.06 -1,090.00 6,027,697.13 544,055.85 0.70 2,775.24 MWD+IFR2+MS+sag(4) 7,196.75 89.80 131.12 4,151.21 4,103.71 -3,836.51 -1,018.49 6,027,636.12 544,127.73 0.95 2,863.63 MWD+IFR2+MS+sag(4) 7,291.02 90.78 132.91 4,150.73 4,103.23 -3,899.60 -948.45 6,027,573.46 544,198.14 2.16 2,952.75 MWD+IFR2+MS+sag(4) 7,385.75 92.56 134.77 4,147.97 4,100.47 -3,965.18 -880.16 6,027,508.30 544,266.82 2.72 3,043.20 MWD+IFR2+MS+sag(4) 7,479.73 92.52 133.66 4,143.81 4,096.31 -4,030.65 -812.87 6,027,443.25 544,334.50 1.18 3,133.06 MWD+IFR2+MS+sag(4) 7,574.00 91.28 131.92 4,140.68 4,093.18 -4,094.65 -743.73 6,027,379.68 544,404.02 2.27 3,222.54 MWD+IFR2+MS+sag(4) 7,668.74 90.72 131.79 4,139.03 4,091.53 -4,157.86 -673.18 6,027,316.91 544,474.95 0.61 3,312.00 MWD+IFR2+MS+sag(4) 7,763.40 89.98 131.62 4,138.45 4,090.95 -4,220.83 -602.51 6,027,254.37 544,545.99 0.80 3,401.32 MWD+IFR2+MS+sag(4) 7,857.65 90.97 131.21 4,137.67 4,090.17 -4,283.18 -531.83 6,027,192.46 544,617.04 1.14 3,490.09 MWD+IFR2+MS+sag(4) 7,951.32 90.72 129.95 4,136.29 4,088.79 -4,344.10 -460.69 6,027,131.97 544,688.54 1.37 3,577.84 MWD+IFR2+MS+sag(4) 8,046.11 90.11 129.29 4,135.60 4,088.10 -4,404.55 -387.68 6,027,071.98 544,761.91 0.95 3,666.08 MWD+IFR2+MS+sag(4) 8,139.75 89.49 127.42 4,135.93 4,088.43 -4,462.65 -314.25 6,027,014.33 544,835.68 2.10 3,752.47 MWD+IFR2+MS+sag(4) 8,234.11 90.41 125.15 4,136.01 4,088.51 -4,518.49 -238.20 6,026,958.96 544,912.07 2.60 3,838.15 MWD+IFR2+MS+sag(4) 8,328.34 89.68 124.70 4,135.94 4,088.44 -4,572.44 -160.94 6,026,905.49 544,989.64 0.91 3,922.76 MWD+IFR2+MS+sag(4) 12/2/2015 8:10:59PM Page 4 COMPASS 5000.1 Build 73 III S Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPL-48 Project: Milne Point TVD Reference: As-Built MPL-48 @ 47.50usft Site: M Pt L Pad MD Reference: As-Built MPL-48 @ 47.50usft Well: MPL-48 North Reference: True Wellbore: MPL-48 Survey Calculation Method: Minimum Curvature Design: MPL-48 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) rimy) (ft) Survey Tool Name 8,423.29 90.54 124.24 4,135.76 4,088.26 -4,626.18 -82.66 6,026,852.23 545,068.24 1.03 4,007.68 MWD+IFR2+MS+sag(4) 8,516.82 91.16 126.39 4,134.37 4,086.87 -4,680.23 -6.36 6,026,798.64 545,144.86 2.39 4,091.93 MWD+IFR2+MS+sag(4) 8,612.02 89.31 126.81 4,133.98 4,086.48 -4,736.99 70.07 6,026,742.35 545,221.62 1.99 4,178.59 MWD+IFR2+MS+sag(4) 8,706.65 89.30 126.75 4,135.12 4,087.62 -4,793.65 145.86 6,026,686.17 545,297.75 0.06 4,264.86 MWD+IFR2+MS+sag(4) 8,720.00 89.42 126.68 4,135.27 4,087.77 -4,801.63 156.56 6,026,678.25 545,308.49 1.04 4,277.03 MWD+IFR2+MS+sag(5) 8,777.76 87.84 128.23 4,136.65 4,089.15 -4,836.74 202.39 6,026,643.42 545,354.54 3.83 4,329.94 MWD+IFR2+MS+sag(5) 8,871.88 90.80 129.18 4,137.77 4,090.27 -4,895.58 275.83 6,026,585.03 545,428.32 3.30 4,416.98 MWD+IFR2+MS+sag(5) 8,966.01 94.83 126.77 4,133.15 4,085.65 -4,953.42 349.92 6,026,527.65 545,502.75 4.99 4,503.48 MWD+IFR2+MS+sag(5) 9,060.34 91.05 124.42 4,128.31 4,080.81 -5,008.24 426.50 6,026,473.30 545,579.66 4.72 4,588.51 MWD+IFR2+MS+sag(5) 9,154.44 91.79 125.51 4,125.98 4,078.48 -5,062.14 503.59 6,026,419.87 545,657.07 1.40 4,673.00 MWD+IFR2+MS+sag(5) 9,249.66 91.17 128.32 4,123.52 4,076.02 -5,119.31 579.69 6,026,363.17 545,733.51 3.02 4,759.87 MWD+IFR2+MS+sag(5) 9,343.25 90.43 126.75 4,122.21 4,074.71 -5,176.32 653.89 6,026,306.62 545,808.05 1.85 4,845.68 MWD+IFR2+MS+sag(5) 9,435.78 92.41 124.56 4,119.92 4,072.42 -5,230.24 729.05 6,026,253.17 545,883.52 3.19 4,929.24 MWD+IFR2+MS+sag(5) 9,531.78 91.85 123.00 4,116.35 4,068.85 -5,283.57 808.78 6,026,200.32 545,963.57 1.73 5,014.52 MWD+IFR2+MS+sag(5) 9,624.86 92.10 120.36 4,113.14 4,065.64 -5,332.42 887.94 6,026,151.95 546,043.01 2.85 5,095.59 M1ND+IFR2+MS+sag(5) 9,719.35 91.11 120.16 4,110.50 4,063.00 -5,380.02 969.52 6,026,104.66 546,124.87 1.07 5,176.73 MWD+IFR2+MS+sag(5) 9,814.44 91.54 120.92 4,108.30 4,060.80 -5,428.33 1,051.40 6,026,057.06 546,207.03 0.92 5,258.64 MWD+IFR2+MS+sag(5) 9,908.98 90.12 118.53 4,106.93 4,059.43 5,475.19 1,133.48 6,026,010.69 546,289.39 2.94 5,339.39 MWD+IFR2+MS+sag(5) 10,003.13 92.72 117.94 4,104.59 4,057.09 -5,519.72 1,216.39 6,025,966.68 546,372.57 2.83 5,418.50 MWD+IFR2+MS+sag(5) 10,097.90 91.79 117.94 4,100.87 4,053.37 -5,564.09 1,300.05 6,025,922.82 546,456.49 0.98 5,497.83 MWD+IFR2+MS+sag(5) 10,192.65 90.99 117.28 4,098.57 4,051.07 -5,607.98 1,383.99 6,025,879.44 546,540.68 1.09 5,576.88 MWD+IFR2+MS+sag(5) 10,284.45 90.25 116.25 4,097.57 4,050.07 -5,649.32 1,465.94 6,025,838.60 546,622.88 1.38 5,652.73 MWD+IFR2+MS+sag(5) 10,380.50 87.84 117.14 4,099.18 4,051.68 -5,692.46 1,551.74 6,025,795.99 546,708.92 2.67 5,732.01 MWD+IFR2+MS+sag(5) 10,475.93 84.37 118.69 4,105.66 4,058.16 -5,737.17 1,635.78 6,025,751.79 546,793.22 4.07 5,811.82 MWD+IFR2+MS+sag(5) 10,569.84 84.44 120.78 4,114.81 4,067.31 -5,783.67 1,716.85 6,025,705.80 546,874.57 2.00 5,891.76 MWD+IFR2+MS+sag(5) 10,664.25 85.49 122.52 4,123.10 4,075.60 -5,833.01 1,796.90 6,025,656.94 546,954.91 2.15 5,973.70 MWD+IFR2+MS+sag(5) 10,757.63 84.87 124.67 4,130.95 4,083.45 -5,884.50 1,874.40 6,025,605.94 547,032.72 2.39 6,056.27 MWD+IFR2+MS+sag(5) 10,852.65 85.24 126.62 4,139.14 4,091.64 -5,939.66 1,951.33 6,025,551.24 547,109.97 2.08 6,141.79 MWD+IFR2+MS+sag(5) 10,946.73 85.18 128.75 4,147.00 4,099.50 -5,996.97 2,025.52 6,025,494.39 547,184.50 2.26 6,227.85 MWD+IFR2+MS+sag(5) 11,041.50 85.98 131.10 4,154.30 4,106.80 -6,057.61 2,097,97 6,025,434.20 547,257.31 2.61 6,315.99 MWD+IFR2+MS+sag(5) 11,135.32 85.55 133.51 4,161.23 4,113.73 -6,120.58 2,167.17 6,025,371.66 547,326.88 2.60 6,404.59 MWD+IFR2+MS+sag(5) 11,230.00 86.79 132.58 4,167.55 4,120.05 -6,185.06 2,236.20 6,025,307.61 547,396.30 1.64 6,494.43 MWD+IFR2+MS+sag(5) 11,324.16 88.64 131.58 4,171.31 4,123.81 -6,248.11 2,306.03 6,025,244.99 547,466.50 2.23 6,583.41 MWD+IFR2+MS+sag(5) 11,418.27 89.75 130.66 4,172.63 4,125.13 -6,309.99 2,376.92 6,025,183.54 547,537.75 1.53 6,671.88 MWD+IFR2+MS+sag(5) 11,513.88 88.58 127.73 4,174.02 4,126.52 -6,370.40 2,451.00 6,025,123.59 547,612.19 3.30 6,760.60 MWD+IFR2+MS+sag(5) 11,605.07 89.88 124.86 4,175.25 4,127.75 -6,424.36 2,524.48 6,025,070.08 547,685.99 3.45 6,843.40 MWD+IFR2+MS+sag(5) 11,700.25 89.81 124.11 4,175.51 4,128.01 -6,478.25 2,602.93 6,025,016.67 547,764.77 0.79 6,928.54 MWD+IFR2+MS+sag(5) 11,794.97 89.44 124.40 4,176.13 4,128.63 -6,531.57 2,681.22 6,024,963.84 547,843.37 0.50 7,013.09 MWD+IFR2+MS+sag(5) 11,890.25 91.24 125.78 4,175.56 4,128.06 -6,586.34 2,759.18 6,024,909.55 547,921.65 2.38 7,098.76 M1ND+IFR2+MS+sag(5) 11,984.24 92.29 126.47 4,172.67 4,125.17 -6,641.72 2,835.06 6,024,854.63 547,997.86 1.34 7,183.96 MWD+IFR2+MS+sag(5) 12/212015 8:10:59PM Page 5 COMPASS 5000.1 Build 73 • • . Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPL-48 Project: Milne Point TVD Reference: As-Built MPL-48©47.50usft Site: M Pt L Pad MD Reference: As-Built MPL-48 @ 47.50usft Well: MPL-48 North Reference: True Wellbore: MPL-48 Survey Calculation Method: Minimum Curvature Design: MPL-48 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100) (ft) Survey Tool Name 12,079.04 90.62 123.80 4,170.26 4,122.76 -6,696.25 2,912.55 6,024,800.57 548,075.67 3.32 7,269.19 MWD+IFR2+MS+sag(5) 12,173.19 91.73 123.20 4,168.33 4,120.83 -6,748.21 2,991.05 6,024,749.10 548,154.47 1.34 7,352.66 MWD+IFR2+MS+sag(5) 12,267.98 91.67 123.89 4,165.52 4,118.02 -6,800.56 3,070.01 6,024,697.23 548,233.75 0.73 7,436.70 MWD+IFR2+MS+sag(5) 12,361.94 91.85 123.38 4,162.63 4,115.13 -6,852.58 3,148.21 6,024,645.69 548,312.24 0.58 7,520.08 MWD+IFR2+MS+sag(5) 12,456.25 91.91 124.29 4,159.54 4,112.04 -6,905.07 3,226.50 6,024,593.69 548,390.85 0.97 7,603.91 MWD+IFR2+MS+sag(5) 12,550.11 90.93 124.17 4,157.21 4,109.71 -6,957.85 3,304.08 6,024,541.39 548,468.74 1.05 7,687.65 MWD+IFR2+MS+sag(5) 12,644.47 91.11 125.85 4,155.53 4,108.03 -7,011.97 3,381.35 6,024,487.74 548,546.33 1.79 7,772.43 MWD+IFR2+MS+sag(5) 12,738.76 90.43 128.03 4,154.26 4,106.76 -7,068.63 3,456.70 6,024,431.54 548,622.01 2.42 7,858.48 MWD+IFR2+MS+sag(5) 12,833.28 89.38 127.04 4,154.42 4,106.92 -7,126.21 3,531.65 6,024,374.42 548,697.31 1.53 7,945.16 MWD+IFR2+MS+sag(5) 12,927.65 90.86 127.19 4,154.22 4,106.72 -7,183.16 3,606.90 6,024,317.94 548,772.89 1.58 8,031.42 MWD+IFR2+MS+sag(5) 13,022.23 91.73 128.25 4,152.08 4,104.58 -7,241.00 3,681.69 6,024,260.55 548,848.03 1.45 8,118.25 MWD+IFR2+MS+sag(5) 13,116.57 91.23 129.01 4,149.65 4,102.15 -7,299.88 3,755.37 6,024,202.13 548,922.05 0.96 8,205.43 MWD+IFR2+MS+sag(5) 13,130.78 91.30 128.84 4,149.33 4,101.83 -7,308.81 3,766.42 6,024,193.28 548,933.16 1.29 8,218.59 MWD+IFR2+MS+sag(5) 13,212.00 91.30 128.84 4,147.49 4,099.99 -7,359.73 3,829.66 6,024,142.74 548,996.70 0.00 8,293.77 PROJECTED to TD brian.wheeler@halliburton.,..r.1,9*.............. O,,,,,nun..w.a,w,,.,.,<� Checked By: corn gyp,=,=�,_««m Approved By: cary.taylor@halliburton.com o..7,,,= Date: 12/2/2015 8.10:59PM Page 6 COMPASS 5000.1 Build 73 • • Hilcorp Energy Company Milne Point M Pt L Pad MPL-48PB1 500292355270 500292355270 Sperry Drilling Definitive Survey Report 02 December, 2015 I-IALL.IBUPTON • • Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPL-48 Project: Milne Point TVD Reference: As-Built MPL-48 @ 47.50usft Site: M Pt L Pad MD Reference: As-Built MPL-48 @ 47.50usft Well: MPL-48 North Reference: True Wellbore: MPL-48PB1 Survey Calculation Method: Minimum Curvature Design: MPL-48PB1 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-48 Well Position +NI-S 0.00 usft Northing: 6,031,478.37 usft Latitude: 70°29'48.710 N +E/-W 0.00 usft Easting: 545,122.81 usft Longitude: 149°37'51.652 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 17.50 usft Wellbore MPL-48PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2015 9/17/2015 18.91 81.08 57,505 Design MPL-48PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 30.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 30.00 0.00 0.00 151.04 Survey Program Date 12/2/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 90.00 972.00 MPL-48 Gyro(MPL-48PB1) SRG-MS Surface readout gyro multishot 09/29/2015 1,066.56 6,162.17 MPL-48 MWD(MPL-48PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/13/2015 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +El-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 30.00 0.00 0.00 30.00 -17.50 0.00 0.00 6,031,478.37 545,122.81 0.00 0.00 UNDEFINED 90.00 0.63 135.44 90.00 42.50 -0.24 0.23 6,031,478.14 545,123.04 1.05 0.32 SRG-MS(1) 134.00 0.57 129.63 134.00 86.50 -0.55 0.57 6,031,477.83 545,123.38 0.19 0.75 SRG-MS(1) 221.00 0.52 138.84 220.99 173.49 -1.12 1.16 6,031,477.26 545,123.98 0.12 1.54 SRG-MS(1) 316.00 0.65 140.74 315.99 268.49 -1.86 1.79 6,031,476.52 545,124.61 0.14 2.49 SRG-MS(1) 408.00 1.98 145.56 407.96 360.46 -3.58 3.02 6,031,474.81 545,125.85 1.45 4.59 SRG-MS(1) 502.00 3.35 144.47 501.86 454.36 -7.15 5.53 6,031,471.25 545,128.38 1.46 8.94 SRG-MS(1) 596.00 3.75 148.17 595.68 548.18 -12.00 8.75 6,031,466.43 545,131.63 0.49 14.73 SRG-MS(1) 689.00 5.99 144.22 688.34 640.84 -18.52 13.19 6,031,459.93 545,136.11 2.43 22.59 SRG-MS(1) 783.00 7.50 141.21 781.68 734.18 -27.28 19.90 6,031,451.21 545,142.87 1.65 33.51 SRG-MS(1) 878.00 10.77 135.91 875.47 827.97 -38.49 29.96 6,031,440.06 545,153.00 3.55 48.19 SRG-MS(1) 972.00 11.08 137.32 967.76 920.26 -51.44 42.20 6,031,427.19 545,165.32 0.44 65.44 SRG-MS(1) 1,066.56 12.67 154.43 1,060.33 1,012.83 -67.48 52.84 6,031,411.22 545,176.05 4.07 84.63 MWD+IFR2+MS+sag(2) 12/2/2015 8:05:05PM Page 2 COMPASS 5000.1 Build 73 • • Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPL-48 Project: Milne Point TVD Reference: As-Built MPL-48 @ 47.50usft Site: M Pt L Pad MD Reference: As-Built MPL-48 @ 47.50usft Well: MPL-48 North Reference: True Wellbore: MPL-48PB1 Survey Calculation Method: Minimum Curvature Design: MPL-48PB1 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 1,160.89 13.85 169.61 1,152.17 1,104.67 -87.92 59.34 6,031,390.82 545,182.68 3.88 105.66 MWD+IFR2+MS+sag(2) 1,254.60 15.31 185.34 1,242.89 1,195.39 -111.29 60.21 6,031,367.46 545,183.69 4.49 126.53 MWD+IFR2+MS+sag(2) 1,348.91 19.95 197.33 1,332.78 1,285.28 -139.07 54.26 6,031,339.65 545,177.90 6.22 147.95 MWD+IFR2+MS+sag(2) 1,443.95 27.42 205.73 1,419.78 1,372.28 -174.32 39.90 6,031,304.32 545,163.77 8.61 171.84 MWD+IFR2+MS+sag(2) 1,538.05 26.27 206.20 1,503.73 1,456.23 -212.52 21.30 6,031,266.00 545,145.40 1.24 196.26 MWD+IFR2+MS+sag(2) 1,632.41 28.33 209.22 1,587.58 1,540.08 -250.80 1.15 6,031,227.60 545,125.48 2.63 220.00 MWD+IFR2+MS+sag(2) 1,726.67 32.16 214.27 1,669.01 1,621.51 -291.08 -23.91 6,031,187.18 545,100.67 4.87 243.10 MWD+IFR2+MS+sag(2) 1,820.86 36.67 219.85 1,746.71 1,699.21 -333.42 -56.07 6,031,144.65 545,068.77 5.84 264.58 MWD+IFR2+MS+sag(2) 1,915.86 42.43 223.20 1,819.94 1,772.44 -378.60 -96.22 6,031,099.23 545,028.89 6.46 284.67 MWD+IFR2+MS+sag(2) 2,010.08 48.09 223.58 1,886.24 1,838.74 -427.21 -142.19 6,031,050.35 544,983.23 6.01 304.94 MWD+IFR2+MS+sag(2) 2,104.69 57.87 225.78 1,943.14 1,895.64 -480.78 -195.30 6,030,996.46 544,930.45 10.50 326.10 MWD+IFR2+MS+sag(2) 2,199.10 57.16 225.89 1,993.84 1,946.34 -536.27 -252.43 6,030,940.63 544,873.67 0.76 346.99 M1ND+IFR2+MS+sag(2) 2,293.24 56.30 225.58 2,045.48 1,997.98 -591.21 -308.79 6,030,885.36 544,817.64 0.95 367.76 MWD+IFR2+MS+sag(2) 2,387.63 58.71 225.97 2,096.19 2,048.69 -646.73 -365.84 6,030,829.50 544,760.94 2.58 388.72 MWD+IFR2+MS+sag(2) 2,481.85 57.92 225.75 2,145.68 2,098.18 -702.56 -423.38 6,030,773.32 544,703.74 0.86 409.71 MWD+IFR2+MS+sag(2) 2,575.89 57.89 224.42 2,195.64 2,148.14 -758.81 -479.79 6,030,716.74 544,647.68 1.20 431.61 MWD+IFR2+MS+sag(2) 2,670.90 57.74 225.07 2,246.25 2,198.75 -815.92 -536.40 6,030,659.29 544,591.43 0.60 454.17 MWD+IFR2+MS+sag(2) 2,764.86 57.18 224.62 2,296.79 2,249.29 -872.08 -592.26 6,030,602.80 544,535.92 0.72 476.26 MWD+IFR2+MS+sag(2) 2,859.45 58.69 225.10 2,347.01 2,299.51 -928.90 -648.80 6,030,545.64 544,479.72 1.65 498.60 MWD+IFR2+MS+sag(2) 2,953.61 57.74 224.60 2,396.60 2,349.10 -985.64 -705.25 6,030,488.57 544,423.63 1.11 520.91 MWD+IFR2+MS+sag(2) 3,047.63 57.73 224.51 2,446.80 2,399.30 -1,042.29 -761.03 6,030,431.58 544,368.20 0.08 543.47 MWD+IFR2+MS+sag(2) 3,142.37 59.65 224.44 2,496.03 2,448.53 -1,100.04 -817.73 6,030,373.49 544,311.85 2.03 566.55 MWD+IFR2+MS+sag(2) 3,236.88 58.85 224.18 2,544.35 2,496.85 -1,158.16 -874.47 6,030,315.03 544,255.47 0.88 589.93 MWD+IFR2+MS+sag(2) 3,331.06 58.64 224.06 2,593.21 2,545.71 -1,215.96 -930.52 6,030,256.90 544,199.78 0.25 613.36 MWD+IFR2+MS+sag(2) 3,425.66 58.19 224.03 2,642.76 2,595.26 -1,273.89 -986.54 6,030,198.64 544,144.11 0.48 636.91 MWD+IFR2+MS+sag(2) 3,519.64 58.86 223.16 2,691.83 2,644.33 -1,331.94 -1,041.81 6,030,140.27 544,089.21 1.06 660.94 MWD+IFR2+MS+sag(2) 3,614.59 60.09 225.34 2,740.06 2,692.56 -1,390.51 -1,098.88 6,030,081.35 544,032.49 2.36 684.56 MWD+IFR2+MS+sag(2) 3,708.11 60.56 228.97 2,786.37 2,738.87 -1,445.74 -1,158.45 6,030,025.76 543,973.27 3.41 704.05 MWD+IFR2+MS+sag(2) 3,803.36 60.84 228.89 2,832.99 2,785.49 -1,500.32 -1,221.07 6,029,970.82 543,910.99 0.30 721.47 MWD+IFR2+MS+sag(2) 3,897.16 59.19 229.23 2,879.86 2,832.36 -1,553.55 -1,282.44 6,029,917.21 543,849.95 1.79 738.34 MWD+IFR2+MS+sag(2) 3,991.60 59.75 229.72 2,927.84 2,880.34 -1,606.41 -1,344.27 6,029,863.99 543,788.44 0.74 754.65 MWD+IFR2+MS+sag(2) 4,086.27 58.77 225.73 2,976.24 2,928.74 -1,661.12 -1,404.47 6,029,808.92 543,728.59 3.77 773.37 MWD+IFR2+MS+sag(2) 4,180.23 56.76 222.59 3,026.37 2,978.87 -1,718.10 -1,459.84 6,029,751.60 543,673.56 3.54 796.41 MWD+IFR2+MS+sag(2) 4,274.56 55.71 226.67 3,078.81 3,031.31 -1,773.90 -1,514.90 6,029,695.48 543,618.85 3.76 818.58 MWD+IFR2+MS+sag(2) 4,369.24 56.67 227.29 3,131.49 3,083.99 -1,827.57 -1,572.42 6,029,641.47 543,561.67 1.15 837.69 MWD+IFR2+MS+sag(2) 4,463.10 57.16 226.96 3,182.73 3,135.23 -1,881.08 -1,630.05 6,029,587.61 543,504.37 0.60 856.60 MWD+IFR2+MS+sag(2) 4,558.10 58.11 226.87 3,233.58 3,186.08 -1,935.89 -1,688.65 6,029,532.45 543,446.10 1.00 876.18 MWD+IFR2+MS+sag(2) 4,652.28 57.15 227.06 3,284.00 3,236.50 -1,990.18 -1,746.79 6,029,477.82 543,388.30 1.03 895.53 MWD+IFR2+MS+sag(2) 4,747.06 57.70 227.22 3,335.03 3,287.53 -2,044.51 -1,805.34 6,029,423.14 543,330.09 0.60 914.71 MWD+IFR2+MS+sag(2) 4,840.94 57.38 222.29 3,385.44 3,337.94 -2,100.72 -1,861.09 6,029,366.59 543,274.69 4.44 936.91 MWD+IFR2+MS+sag(2) 12/2/2015 8:05:05PM Page 3 COMPASS 5000.1 Build 73 • • Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPL-48 Project: Milne Point TVD Reference: As-Built MPL-48 @ 47.50usft Site: M Pt L Pad MD Reference: As-Built MPL-48 @ 47.50usft Well: MPL-48 North Reference: True Wellbore: MPL-48PB1 Survey Calculation Method: Minimum Curvature Design: MPL-48PB1 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,935.06 56.89 215.54 3,436.56 3,389.06 -2,162.17 -1,910.71 6,029,304.85 543,225.44 6.05 966.64 MWD+IFR2+MS+sag(2) 5,029.37 58.08 208.22 3,487.30 3,439.80 -2,229.65 -1,952.64 6,029,237.13 543,183.93 6.66 1,005.38 MWD+IFR2+MS+sag(2) 5,124.19 58.24 201.51 3,537.36 3,489.86 -2,302.67 -1,986.48 6,029,163.91 543,150.54 6.01 1,052.89 MWD+IFR2+MS+sag(2) 5,218.45 57.47 195.77 3,587.55 3,540.05 -2,378.24 -2,011.99 6,029,088.20 543,125.49 5.22 1,106.66 MWD+IFR2+MS+sag(2) 5,312.92 58.31 188.46 3,637.81 3,590.31 -2,456.39 -2,028.74 6,029,009.95 543,109.22 6.61 1,166.93 MWD+IFR2+MS+sag(2) 5,407.16 57.77 182.22 3,687.73 3,640.23 -2,535.94 -2,036.19 6,028,930.37 543,102.25 5.65 1,232.92 MWD+IFR2+MS+sag(2) 5,500.66 55.78 177.84 3,738.98 3,691.48 -2,614.12 -2,036.26 6,028,852.19 543,102.65 4.46 1,301.29 MWD+IFR2+MS+sag(2) 5,595.52 58.35 171.57 3,790.58 3,743.08 -2,693.32 -2,028.86 6,028,773.05 543,110.54 6.17 1,374.17 MWD+IFR2+MS+sag(2) 5,690.10 59.36 167.45 3,839.51 3,792.01 -2,772.88 -2,014.11 6,028,693.58 543,125.76 3.88 1,450.93 MWD+1FR2+MS+sag(2) 5,784.40 63.69 162.94 3,884.48 3,836.98 -2,852.96 -1,992.88 6,028,613.65 543,147.48 6.22 1,531.27 MWD+IFR2+MS+sag(2) 5,878.88 70.44 156.89 3,921.31 3,873.81 -2,934.54 -1,962.93 6,028,532.25 543,177.93 9.26 1,617.15 MWD+IFR2+MS+sag(2) 5,973.11 74.38 151.35 3,949.80 3,902.30 -3,015.28 -1,923.70 6,028,451.76 543,217.64 6.99 1,706.79 MWD+IFR2+MS+sag(2) 6,066.83 74.08 147.33 3,975.28 3,927.78 -3,092.85 -1,877.72 6,028,374.48 543,264.08 4.14 1,796.92 MWD+IFR2+MS+sag(2) 6,162.17 74.16 144.67 4,001.37 3,953.87 -3,168.87 -1,826.45 6,028,298.79 543,315.81 2.68 1,888.26 MWD+IFR2+MS+sag(2) 6,232.00 74.16 144.67 4,020.43 3,972.93 -3,223.67 -1,787.60 6,028,244.22 543,354.99 0.00 1,955.02 PROJECTED to TD brian.wheeler@halliburton.co w.an.^..�.,..,.wm..,a^ an"^^r ^e^h.n•or.c..i.^.^°^.�^". Checked By: m AteSO,3,=02�� Approved By: cary.taylor@halliburton.com PNmav tor.rurzon Date: Pete:Mlt l}0310:p65]-09Yp' 12/2/2015 8:05:05PM Page 4 COMPASS 5000.1 Build 73 • i Hilcorp Energy Company Milne Point M Pt L Pad MPL-48PB2 500292355271 500292355271 Sperry Drilling Definitive Survey Report 02 December, 2015 minismommiummimimmi HALLIBUPTON Sperry Drilling . 0 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPL-48 Project: Milne Point TVD Reference: As-Built MPL-48 @ 47.50usft Site: M Pt L Pad MD Reference: As-Built MPL-48 @ 47.50usft Well: MPL-48 North Reference: True Wellbore: MPL-48PB2 Survey Calculation Method: Minimum Curvature Design: MPL-48PB2 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-48 Well Position +N/-S 0.00 usft Northing: 6,031,478.37 usft Latitude: 70°29'48.710 N +EI-W 0.00 usft Easting: 545,122.81 usft Longitude: 149°37'51.652 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 17.50 usft Wellbore MPL-48PB2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (°) (nT) BGGM2015 9/17/2015 18.91 81.08 57,505 Design MPL-48PB2 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 4,935.06 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 30.00 0.00 0.00 151.04 Survey Program Date 12/2/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 90.00 972.00 MPL-48 Gyro(MPL-48PB1) SRG-MS Surface readout gyro multishot 09/29/2015 1,066.56 4,935.06 MPL-48 MWD(MPL-48PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/13/2015 5,002.00 6,581.47 MPL-48(MPL-48PB2) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/15/2015 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 30.00 0.00 0.00 30.00 -17.50 0.00 0.00 6,031,478.37 545,122.81 0.00 0.00 UNDEFINED 90.00 0.63 135.44 90.00 42.50 -0.24 0.23 6,031,478.14 545,123.04 1.05 0.32 SRG-MS(1) 134.00 0.57 129.63 134.00 86.50 -0.55 0.57 6,031,477.83 545,123.38 0.19 0.75 SRG-MS(1) 221.00 0.52 138.84 220.99 173.49 -1.12 1.16 6,031,477.26 545,123.98 0.12 1.54 SRG-MS(1) 316.00 0.65 140.74 315.99 268.49 -1.86 1.79 6,031,476.52 545,124.61 0.14 2.49 SRG-MS(1) 408.00 1.98 145.56 407.96 360.46 -3.58 3.02 6,031,474.81 545,125.85 1.45 4.59 SRG-MS(1) 502.00 3.35 144.47 501.86 454.36 -7.15 5.53 6,031,471.25 545,128.38 1.46 8.94 SRG-MS(1) 596.00 3.75 148.17 595.68 548.18 -12.00 8.75 6,031,466.43 545,131.63 0.49 14.73 SRG-MS(1) 689.00 5.99 144.22 688.34 640.84 -18.52 13.19 6,031,459.93 545,136.11 2.43 22.59 SRG-MS(1) 783.00 7.50 141.21 781.68 734.18 -27.28 19.90 6,031,451.21 545,142.87 1.65 33.51 SRG-MS(1) 878.00 10.77 135.91 875.47 827.97 -38.49 29.96 6,031,440.06 545,153.00 3.55 48.19 SRG-MS(1) 972.00 11.08 137.32 967.76 920.26 -51.44 42.20 6,031,427.19 545,165.32 0.44 65.44 SRG-MS(1) 12/2/2015 8:06:17PM Page 2 COMPASS 5000.1 Build 73 • • Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPL-48 Project: Milne Point TVD Reference: As-Built MPL-48©47.50usft Site: M Pt L Pad MD Reference: As-Built MPL-48 @ 47.50usft Well: MPL-48 North Reference: True Wellbore: MPL-48P82 Survey Calculation Method: Minimum Curvature Design: MPL-48PB2 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVD8S +N/-8 +E/-W Northing Easting DLS Section (waft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 1,066.56 12.67 154.43 1,060.33 1,012.83 -67.48 52.84 6,031,411.22 545,176.05 4.07 84.63 MWD+IFR2+MS+sag(2) 1,160.89 13.85 169.61 1,152.17 1,104.67 -87.92 59.34 6,031,390.82 545,182.68 3.88 105.66 MWD+IFR2+MS+sag(2) 1,254.60 15.31 185.34 1,242.89 1,195.39 -111.29 60.21 6,031,367.46 545,183.69 4.49 126.53 MWD+IFR2+MS+sag(2) 1,348.91 19.95 197.33 1,332.78 1,285.28 -139.07 54.26 6,031,339.65 545,177.90 6.22 147.95 MWD+IFR2+MS+sag(2) 1,443.95 27.42 205.73 1,419.78 1,372.28 -174.32 39.90 6,031,304.32 545,163.77 8.61 171.84 MWD+IFR2+MS+sag(2) 1,538.05 26.27 206.20 1,503.73 1,456.23 -212.52 21.30 6,031,266.00 545,145.40 1.24 196.26 MWD+IFR2+MS+sag(2) 1,632.41 28.33 209.22 1,587.58 1,540.08 -250.80 1.15 6,031,227.60 545,125.48 2.63 220.00 MWD+IFR2+MS+sag(2) 1,726.67 32.16 214.27 1,669.01 1,621.51 -291.08 -23.91 6,031,187.18 545,100.67 4.87 243.10 MWD+IFR2+MS+sag(2) 1,820.86 36.67 219.85 1,746.71 1,699.21 -333.42 -56.07 6,031,144.65 545,068.77 5.84 264.58 MWD+IFR2+MS+sag(2) 1,915.86 42.43 223.20 1,819.94 1,772.44 -378.60 -96.22 6,031,099.23 545,028.89. 6.46 284.67 MWD+IFR2+MS+sag(2) 2,010.08 48.09 223.58 1,886.24 1,838.74 -427.21 -142.19 6,031,050.35 544,983.23 6.01 304.94 MWD+IFR2+MS+sag(2) 2,104.69 57.87 225.78 1,943.14 1,895.64 -480.78 -195.30 6,030,996.46 544,930.45 10.50 326.10 MWD+IFR2+MS+sag(2) 2,199.10 57.16 225.89 1,993.84 1,946.34 -536.27 -252.43 6,030,940.63 544,873.67 0.76 346.99 MWD+IFR2+MS+sag(2) 2,293.24 56.30 225.58 2,045.48 1,997.98 -591.21 -308.79 6,030,885.36 544,817.64 0.95 367.76 MWD+IFR2+MS+sag(2) 2,387.63 58.71 225.97 2,096.19 2,048.69 -646.73 -365.84 6,030,829.50 544,760.94 2.58 388.72 MWD+IFR2+MS+sag(2) 2,481.85 57.92 225.75 2,145.68 2,098.18 -702.56 -423.38 6,030,773.32 544,703.74 0.86 409.71 MWD+IFR2+MS+sag(2) 2,575.89 57.89 224.42 2,195.64 2,148.14 -758.81 -479.79 6,030,716.74 544,647.68 1.20 431.61 MWD+IFR2+MS+sag(2) 2,670.90 57.74 225.07 2,246.25 2,198.75 -815.92 -536.40 6,030,859.29 544,591.43 0.60 454.17 MWD+IFR2+MS+sag(2) 2,764.86 57.18 224.62 2,296.79 2,249.29 -872.08 -592.26 6,030,602.80 544,535.92 0.72 476.26 MWD+IFR2+MS+sag(2) 2,859.45 58.69 225.10 2,347.01 2,299.51 -928.90 -648.80 6,030,545.64 544,479.72 1.65 498.60 MWD+IFR2+MS+sag(2) 2,953.61 57.74 224.60 2,396.60 2,349.10 -985.64 -705.25 6,030,488.57 544,423.63 1.11 520.91 MWD+IFR2+MS+sag(2) 3,047.63 57.73 224.51 2,446.80 2,399.30 -1,042.29 -761.03 6,030,431.58 544,368.20 0.08 543.47 MWD+IFR2+MS+sag(2) 3,142.37 59.65 224.44 2,496.03 2,448.53 -1,100.04 -817.73 6,030,373.49 544,311.85 2.03 566.55 MWD+IFR2+MS+sag(2) 3,236.88 58.85 224.18 2,544.35 2,496.85 -1,158.16 -874.47 6,030,315.03 544,255.47 0.88 589.93 MWD+IFR2+MS+sag(2) 3,331.06 58.64 224.06 2,593.21 2,545.71 -1,215.96 -930.52 6,030,256.90 544,199.78 0.25 613.36 MWD+IFR2+MS+sag(2) 3,425.66 58.19 224.03 2,642.76 2,595.26 -1,273.89 -986.54 6,030,198.64 544,144.11 0.48 636.91 MWD+IFR2+MS+sag(2) 3,519.64 58.86 223.16 2,691.83 2,644.33 -1,331.94 -1,041.81 6,030,140.27 544,089.21 1.06 660.94 MWD+IFR2+MS+sag(2) 3,614.59 60.09 225.34 2,740.06 2,692.56 -1,390.51 -1,098.88 6,030,081.35 544,032.49 2.36 684.56 MWD+IFR2+MS+sag(2) 3,708.11 60.56 228.97 2,786.37 2,738.87 -1,445.74 -1,158.45 6,030,025.76 543,973.27 3.41 704.05 MWD+IFR2+MS+sag(2) 3,803.36 60.84 228.89 2,832.99 2,785.49 -1,500.32 -1,221.07 6,029,970.82 543,910.99 0.30 721.47 MWD+IFR2+MS+sag(2) 3,897.16 59.19 229.23 2,879.86 2,832.36 -1,553.55 -1,282.44 6,029,917.21 543,849.95 1.79 738.34 MWD+IFR2+MS+sag(2) 3,991.60 59.75 229.72 2,927.84 2,880.34 -1,606.41 -1,344.27 6,029,863.99 543,788.44 0.74 754.65 MWD+IFR2+MS+sag(2) 4,086.27 58.77 225.73 2,976.24 2,928.74 -1,661.12 -1,404.47 6,029,808.92 543,728.59 3.77 773.37 MWD+IFR2+MS+sag(2) 4,180.23 56.76 222.59 3,026.37 2,978.87 -1,718.10 -1,459.84 6,029,751.60 543,673.56 3.54 796.41 MWD+IFR2+MS+sag(2) 4,274.56 55.71 226.67 3,078.81 3,031.31 -1,773.90 -1,514.90 6,029,695.48 543,618.85 3.76 818.58 MWD+IFR2+MS+sag(2) 4,369.24 56.67 227.29 3,131.49 3,083.99 -1,827.57 -1,572.42 6,029,641.47 543,561.67 1.15 837.69 MWD+IFR2+MS+sag(2) 4,463.10 57.16 226.96 3,182.73 3,135.23 -1,881.08 -1,630.05 6,029,587.61 543,504.37 0.60 856.60 MWD+IFR2+MS+sag(2) 4,558.10 58.11 226.87 3,233.58 3,186.08 -1,935.89 -1,688.65 6,029,532.45 543,446.10 1.00 876.18 MWD+IFR2+MS+sag(2) 4,652.28 57.15 227.06 3,284.00 3,236.50 -1,990.18 -1,746.79 6,029,477.82 543,388.30 1.03 895.53 MWD+IFR2+MS+sag(2) 4,747.06 57.70 227.22 3,335.03 3,287.53 -2,044.51 -1,805.34 6,029,423.14 543,330.09 0.60 914.71 MWD+IFR2+MS+sag(2) 12/2/2015 8.06:17PM Page 3 COMPASS 5000.1 Build 73 • • Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPL-48 Project: Milne Point TVD Reference: As-Built MPL-48 @ 47.50usft Site: M Pt L Pad MD Reference: As-Built MPL-48 CO47.50usft Well: MPL-48 North Reference: True Wellbore: MPL-48PB2 Survey Calculation Method: Minimum Curvature Design: MPL-48PB2 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc MI TVD TVDSS +NI-8 +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100) (ft) Survey Tool Name 4,840.94 57.38 222.29 3,385.44 3,337.94 -2,100.72 -1,861.09 6,029,366.59 543,274.69 4.44 936.91 MWD+IFR2+MS+sag(2) 4,935.06 56.89 215.54 3,436.56 3,389.06 -2,162.17 -1,910.71 6,029,304.85 543,225.44 6.05 966.64 MWD+IFR2+MS+sag(2) 5,002.00 57.69 210.32 3,472.75 3,425.25 -2,209.43 -1,941.31 6,029,257.42 543,195.14 6.67 993.18 MWD+IFR2+MS+sag(3) 5,033.25 58.27 209.77 3,489.32 3,441.82 -2,232.36 -1,954.57 6,029,234.40 543,182.02 2.38 1,006.82 MWD+IFR2+MS+sag(3) 5,128.92 57.41 203.26 3,540.28 3,492.78 -2,304.76 -1,990.72 6,029,161.79 543,146.31 5.83 1,052.67 MWD+IFR2+MS+sag(3) 5,224.07 58.33 197.21 3,590.92 3,543.42 -2,380.32 -2,018.55 6,029,086.08 543,118.95 5.47 1,105.30 MWD+IFR2+MS+sag(3) 5,318.36 60.12 188.13 3,639.24 3,591.74 -2,459.24 -2,036.23 6,029,007.05 543,101.75 8.49 1,165.79 MWD+IFR2+MS+sag(3) 5,415.53 57.80 179.35 3,689.41 3,641.91 -2,542.19 -2,041.73 6,028,924.09 543,096.75 8.10 1,235.70 MWD+IFR2+MS+sag(3) 5,507.52 56.06 170.40 3,739.68 3,692.18 -2,618.84 -2,034.91 6,028,847.48 543,104.03 8.37 1,306.08 MWD+IFR2+MS+sag(3) 5,577.41 56.27 169.67 3,778.59 3,731.09 -2,676.02 -2,024.87 6,028,790.37 543,114.42 0.92 1,360.97 MWD+IFR2+MS+sag(3) 5,600.35 56.36 169.60 3,791.31 3,743.81 -2,694.80 -2,021.43 6,028,771.62 543,117.97 0.47 1,379.06 MWD+IFR2+MS+sag(3) 5,663.94 56.89 169.33 3,826.30 3,778.80 -2,747.00 -2,011.72 6,028,719.47 543,128.00 0.91 1,429.44 MWD+IFR2+MS+sag(3) 5,691.50 57.13 169.31 3,841.30 3,793.80 -2,769.72 -2,007.44 6,028,696.79 543,132.42 0.87 1,451.39 MWD+IFR2+MS+sag(3) 5,785.21 59.99 165.72 3,890.19 3,842.69 -2,847.75 -1,990.12 6,028,618.87 543,150.20 4.47 1,528.04 MWD+IFR2+MS+sag(3) 5,879.62 61.97 161.87 3,936.00 3,888.50 -2,926.99 -1,967.06 6,028,539.78 543,173.74 4.14 1,608.54 MWD+IFR2+MS+sag(3) 5,972.82 64.21 157.24 3,978.20 3,930.70 -3,004.82 -1,938.02 6,028,462.14 543,203.26 5.04 1,690.70 MWD+IFR2+MS+sag(3) 6,066.17 68.92 151.35 4,015.34 3,967.84 -3,081.89 -1,900.83 6,028,385.30 543,240.91 7.68 1,776.14 MWD+IFR2+MS+sag(3) 6,158.90 72.84 145.17 4,045.73 3,998.23 -3,156.31 -1,854.73 6,028,311.17 543,287.46 7.58 1,863.58 MWD+IFR2+MS+sag(3) 6,253.61 75.91 138.35 4,071.27 4,023.77 -3,227.87 -1,798.28 6,028,239.96 543,344.33 7.65 1,953.52 MWD+IFR2+MS+sag(3) 6,347.64 78.92 132.23 4,091.77 4,044.27 -3,293.03 -1,733.74 6,028,175.20 543,409.26 7.11 2,041.78 MWD+IFR2+MS+sag(3) 6,441.07 79.65 129.43 4,109.15 4,061.65 -3,353.04 -1,664.29 6,028,115.62 543,479.07 3.05 2,127.92 MWD+IFR2+MS+sag(3) 6,536.09 81.75 126.61 4,124.50 4,077.00 -3,410.78 -1,590.42 6,028,058.33 543,553.28 3.67 2,214.21 MWD+IFR2+MS+sag(3) 6,581.47 83.25 125.51 4,130.43 4,082.93 -3,437.26 -1,554.05 6,028,032.07 543,589.80 4.09 2,254.99 MWD+IFR2+MS+sag(3) 6,627.00 83.25 125.51 4,135.78 4,088.28 -3,463.53 -1,517.25 6,028,006.04 543,626.76 0.00 2,295.79 PROJECTED to TD .....,,,.a.,...,.+....,.,....,.. cary.taylor@halliburton.c a*+v+waa.r � Checked By: brlanwheeIer@haIIiburtoncom ,,,,,,,..A Approved By: "`°"'"� Date: om Om mrs.rmar<oxnMOO 12/2/2015 8.06:17PM Page 4 COMPASS 5000.1 Build 73 Hilcorp Energy Company Milne Point M Pt L Pad MPL-48PB3 500292355272 Sperry Drilling Definitive Survey Report 02 December, 2015 HALLIBURTON Sperry Drilling • • Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPL-48 Project: Milne Point TVD Reference: As-Built MPL-48 @ 47.50usft Site: M Pt L Pad MD Reference: As-Built MPL-48 @ 47.50usft Well: MPL-48 North Reference: True Wellbore: MPL-48PB3 Survey Calculation Method: Minimum Curvature Design: MPL-48 PB3 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-48 Well Position +Nl-S 0.00 usft Northing: 6,031,478.37 usft Latitude: 70°29'48.710 N +E/-W 0.00 usft Easting: 545,122.81 usft Longitude: 149°37'51.652 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 17.50 usft Wellbore MPL-48PB3 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 9/17/2015 18.91 81.08 57,505 Design MPL-48 PB3 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 1,915.86 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 30.00 0.00 0.00 151.04 Survey Program Date 12/2/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 90.00 972.00 MPL-48 Gyro(MPL-48PB1) SRG-MS Surface readout gyro multishot 09/29/2015 1,066.56 1,915.86 MPL-48 MWD(MPL-48PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/13/2015 2,013.79 6,509.01 MPL-48 MWD(MPL-48PB3) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/19/2015 6,630.56 9,177.86 MPL-48 MWD(2)(MPL-48PB3) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/29/2015 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°M00') (ft) Survey Tool Name 30.00 0.00 0.00 30.00 -17.50 0.00 0.00 6,031,478.37 545,122.81 0.00 0.00 UNDEFINED 90.00 0.63 135.44 90.00 42.50 -0.24 0.23 6,031,478.14 545,123.04 1.05 0.32 SRG-MS(1) 134.00 0.57 129.63 134.00 86.50 -0.55 0.57 6,031,477.83 545,123.38 0.19 0.75 SRG-MS(1) 221.00 0.52 138.84 220.99 173.49 -1.12 1.16 6,031,477.26 545,123.98 0.12 1.54 SRG-MS(1) 316.00 0.65 140.74 315.99 268.49 -1.86 1.79 6,031,476.52 545,124.61 0.14 2.49 SRG-MS(1) 408.00 1.98 145.56 407.96 360.46 -3.58 3.02 6,031,474.81 545,125.85 1.45 4.59 SRG-MS(1) 502.00 3.35 144.47 501.86 454.36 -7.15 5.53 6,031,471.25 545,128.38 1.46 8.94 SRG-MS(1) 596.00 3.75 148.17 595.68 548.18 -12.00 8.75 6,031,466.43 545,131.63 0.49 14.73 SRG-MS(1) 689.00 5.99 144.22 688.34 640.84 -18.52 13.19 6,031,459.93 545,136.11 2.43 22.59 SRG-MS(1) 783.00 7.50 141.21 781.68 734.18 -27.28 19.90 6,031,451.21 545,142.87 1.65 33.51 SRG-MS(1) 878.00 10.77 135.91 875.47 827.97 -38.49 29.96 6,031,440.06 545,153.00 3.55 48.19 SRG-MS(1) 12/2/2015 8:07:24PM Page 2 COMPASS 5000.1 Build 73 • • Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPL-48 Project: Milne Point TVD Reference: As-Built MPL-48 @ 47.50usft Site: M Pt L Pad MD Reference: As-Built MPL-48 @ 47.50usft Well: MPL-48 North Reference: True Wellbore: MPL-48PB3 Survey Calculation Method: Minimum Curvature Design: MPL-48 PB3 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E!-W Northing Easting DLS Section (uaft) (°) (°) (usft) (waft) (usft) (uaft) (ft) (ft) (°1100') (ft) Survey Tool Name 972.00 11.08 137.32 967.76 920.26 -51.44 42.20 6,031,427.19 545,165.32 0.44 65.44 SRG-MS(1) 1,066.56 12.67 154.43 1,060.33 1,012.83 -67.48 52.84 6,031,411.22 545,176.05 4.07 84.63 MWD+IFR2+MS+sag(2) 1,160.89 13.85 169.61 1,152.17 1,104.67 -87.92 59.34 6,031,390.82 545,182.68 3.88 105.66 MWD+IFR2+MS+sag(2) 1,254.60 15.31 185.34 1,242.89 1,195.39 -111.29 60.21 6,031,367.46 545,183.69 4.49 126.53 MWD+IFR2+MS+sag(2) 1,348.91 19.95 197.33 1,332.78 1,285.28 -139.07 54.26 6,031,339.65 545,177.90 6.22 147.95 MWD+IFR2+MS+sag(2) 1,443.95 27.42 205.73 1,419.78 1,372.28 -174.32 39.90 6,031,304.32 545,163.77 8.61 171.84 MWD+IFR2+MS+sag(2) 1,538.05 26.27 206.20 1,503.73 1,456.23 -212.52 21.30 6,031,266.00 545,145.40 1.24 196.26 MWD+IFR2+MS+sag(2) 1,632.41 28.33 209.22 1,587.58 1,540.08 -250.80 1.15 6,031,227.60 545,125.48 2.63 220.00 MWD+IFR2+MS+sag(2) 1,726.67 32.16 214.27 1,669.01 1,621.51 -291.08 -23.91 6,031,187.18 545,100.67 4.87 243.10 MWD+IFR2+MS+sag(2) 1,820.86 36.67 219.85 1,746.71 1,699.21 -333.42 -56.07 6,031,144.65 545,068.77 5.84 264.58 MWD+IFR2+MS+sag(2) 1,915.86 42.43 223.20 1,819.94 1,772.44 -378.60 -96.22 6,031,099.23 545,028.89 6.46 284.67 MWD+IFR2+MS+sag(2) 2,013.79 41.19 224.35 1,892.93 1,845.43 -425.74 -141.38 6,031,051.82 544,984.03 1.49 304.05 MWD+IFR2+MS+sag(3) 2,110.43 44.20 225.11 1,963.95 1,916.45 -472.29 -187.50 6,031,005.00 544,938.19 3.16 322.44 MWD+IFR2+MS+sag(3) 2,204.36 45.23 225.70 2,030.70 1,983.20 -518.68 -234.57 6,030,958.32 544,891.42 1.18 340.25 MWD+IFR2+MS+sag(3) 2,298.13 52.42 227.46 2,092,40 2,044.90 -567.12 -285.83 6,030,909.58 544,840.45 7.80 357.80 MWD+IFR2+MS+sag(3) 2,393.11 53.89 227.08 2,149.35 2,101.85 -618.69 -341.66 6,030,857.68 544,784.94 1.58 375.90 MWD+IFR2+MS+sag(3) 2,488.30 56.96 226.22 2,203.37 2,155.87 -672.50 -398.64 6,030,803.53 544,728.29 3.31 395.38 MWD+IFR2+MS+sag(3) 2,581.81 55.58 225.41 2,255.29 2,207.79 -726.69 -454.41 6,030,749.00 544,672.86 1.64 415.80 MWD+IFR2+MS+sag(3) 2,675.21 56.74 228.88 2,307.31 2,259.81 -779.43 -511.28 6,030,695.93 544,616.32 3.33 434.41 MWD+IFR2+MS+sag(3) 2,768.78 59.09 227.73 2,357.01 2,309.51 -832.17 -570.46 6,030,642.84 544,557.46 2.72 451.89 MWD+IFR2+MS+sag(3) 2,864.92 57.11 228.28 2,407.81 2,360.31 -886.78 -631,12 6,030,587.87 544,497.15 2.12 470.31 MWD+IFR2+MS+sag(3) 2,959.50 60.33 228.21 2,456.91 2,409.41 -940.60 -691.41 6,030,533.68 544,437.19 3.41 488.21 MWD+IFR2+MS+sag(3) 3,052.95 59.58 227.82 2,503.70 2,456.20 -994.71 -751.54 6,030,479.21 544,377.40 0.88 506.44 MWD+IFR2+MS+sag(3) 3,147.34 60.06 226.60 2,551.16 2,503.66 -1,050.14 -811.41 6,030,423.43 544,317.86 1.23 525.94 MWD+IFR2+MS+sag(3) 3,242.51 60.30 224.72 2,598.48 2,550.98 -1,107.85 -870.46 6,030,365.37 544,259.17 1.73 547.84 MWD+IFR2+MS+sag(3) 3,336.40 59.23 224.26 2,645.76 2,598.26 -1,165.71 -927.31 6,030,307.17 544,202.68 1.22 570.95 MWD+IFR2+MS+sag(3) 3,431.74 58.87 224.78 2,694.79 2,647.29 -1,224.01 -984.64 6,030,248.53 544,145.72 0.60 594.20 MWD+IFR2+MS+sag(3) 3,525.06 58.50 224.34 2,743.30 2,695.80 -1,280.81 -1,040.58 6,030,191.39 544,090.13 0.57 616.81 MWD+IFR2+MS+sag(3) 3,619.83 57.94 224.32 2,793.21 2,745.71 -1,338.44 -1,096.87 6,030,133.43 544,034.19 0.59 639.98 MWD+IFR2+MS+sag(3) 3,714.00 57,52 224.20 2,843.49 2,795.99 -1,395.47 -1,152.44 6,030,076.07 543,978.97 0.46 662.96 MWD+IFR2+MS+sag(3) 3,808.53 56.84 224.73 2,894.72 2,847.22 -1,452.16 -1,208.09 6,030,019.04 543,923.68 0.86 685.63 MWD+IFR2+MS+sag(3) 3,903.13 57.21 224.46 2,946.21 2,898.71 -1,508.67 -1,263.81 6,029,962.20 543,868.31 0.46 708.09 MWD+IFR2+MS+sag(3) 3,998.00 56.83 224.23 2,997.85 2,950.35 -1,565.59 -1,319.43 6,029,904.96 543,813.03 0.45 730.95 MWD+IFR2+MS+sag(3) 4,091.73 56.55 223.66 3,049.33 3,001.83 -1,621.99 -1,373.79 6,029,848.23 543,759.02 0.59 753.98 MWD+IFR2+MS+sag(3) 4,185.88 57.47 226.23 3,100.60 3,053.10 -1,677.86 -1,429.58 6,029,792.02 543,703.58 2.49 775.86 MWD+IFR2+MS+sag(3) 4,280.18 57.64 226.67 3,151.19 3,103.69 -1,732.69 -1,487.26 6,029,736.85 543,646.24 0.43 795.91 MWD+IFR2+MS+sag(3) 4,374.65 57.70 225.86 3,201.71 3,154.21 -1,787.88 -1,544.93 6,029,681.32 543,588.91 0.73 816.26 MWD+IFR2+MS+sag(3) 4,469.83 57.88 226.45 3,252.44 3,204.94 -1,843.66 -1,603.01 6,029,625.19 543,531.17 0.56 836.95 MWD+IFR2+MS+sag(3) 4,563.68 57.85 226.57 3,302.38 3,254.86 -1,898.36 -1,660.67 6,029,570.15 543,473.86 0.11 856.89 MWD+IFR2+MS+sag(3) 4,656.75 58.36 224.36 3,351.54 3,304.04 -1,953.77 -1,716.99 6,029,514.40 543,417.88 2.09 878.11 MWD+IFR2+MS+sag(3) 1222015 8:07:24PM Page 3 COMPASS 5000.1 Build 73 • • Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPL-48 Project: Milne Point TVD Reference: As-Built MPL-48 @ 47.50usft Site: M Pt L Pad MD Reference: As-Built MP L-48 @ 47.50usft Well: MPL-48 North Reference: True Wellbore: MPL-48PB3 Survey Calculation Method: Minimum Curvature Design: MPL-48 PB3 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi ND TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (weft) (ft) (ft) (°Hop') (ft) Survey Tool Name 4,751.74 59.42 219.93 3,400.64 3,353.14 -2,014.06 -1,771.52 6,029,453.79 543,363.72 4.15 904.45 MWD+IFR2+MS+sag(3) 4,846.57 60.70 214.18 3,448.00 3,400.50 -2,079.62 -1,820.99 6,029,387.94 543,314.66 5.42 937.86 MWD+IFR2+MS+sag(3) 4,941.15 60.56 208.14 3,494.42 3,446.92 -2,150.10 -1,863.61 6,029,317.21 543,272.47 5.57 978.89 MWD+IFR2+MS+sag(3) 5,035.74 59.07 204.28 3,541.99 3,494.49 -2,223.42 -1,899.73 6,029,243.67 543,236.80 3.86 1,025.56 MWD+IFR2+MS+sag(3) 5,130.07 58.51 199.29 3,590.89 3,543.39 -2,298.30 -1,929.67 6,029,168.62 543,207.32 4.56 1,076.57 MWD+IFR2+MS+sag(3) 5,223.96 59.24 194.27 3,639.44 3,591.94 -2,375.22 -1,952.85 6,029,091.58 543,184.61 4.64 1,132.65 MWD+IFR2+MS+sag(3) 5,318.55 59.60 188.67 3,687.59 3,640.09 -2,454.98 -1,969.02 6,029,011.73 543,168.92 5.11 1,194.60 MWD+IFR2+MS+sag(3) 5,412.73 59.30 183.25 3,735.49 3,687.99 -2,535.60 -1,977.44 6,028,931.06 543,160.99 4.97 1,261.07 MWD+IFR2+MS+sag(3) 5,507.53 58.35 180.69 3,784.57 3,737.07 -2,616.65 -1,980.24 6,028,850.00 543,158.68 2.52 1,330.63 MWD+IFR2+MS+sag(3) 5,601.57 58.76 176.71 3,833.64 3,786.14 -2,696.83 -1,978.42 6,028,769.84 543,160.99 3.64 1,401.67 MWD+IFR2+MS+sag(3) 5,695.84 63.19 171.36 3,879.40 3,831.90 -2,778.74 -1,969.77 6,028,687.99 543,170.13 6.83 1,477.52 MWD+IFR2+MS+sag(3) 5,787.30 67.49 164.44 3,917.59 3,870.09 -2,859.91 -1,952.28 6,028,606.94 543,188.11 8.33 1,557.01 MWD+IFR2+MS+sag(3) 5,884.56 70.63 157.91 3,952.37 3,904.87 -2,945.80 -1,922.95 6,028,521.24 543,217.97 7.05 1,646.37 MWD+IFR2+MS+sag(3) 5,979.01 72.85 152.80 3,981.98 3,934.48 -3,027.28 -1,885.54 6,028,440.00 543,255.87 5.65 1,735.77 M1ND+IFR2+MS+sag(3) 6,073.72 73.37 149.33 4,009.51 3,962.01 -3,106.58 -1,841.70 6,028,360.98 543,300.18 3.55 1,826.38 MWD+IFR2+MS+sag(3) 6,168.01 71.89 144.06 4,037.68 3,990.18 -3,181.76 -1,792.32 6,028,286.10 543,350.01 5.56 1,916.07 MWD+IFR2+MS+sag(3) 6,262.05 73.06 138.00 4,066.02 4,018.52 -3,251.43 -1,735.94 6,028,216.78 543,406.81 6.27 2,004.33 MWD+IFR2+MS+sag(3) 6,356.34 75.73 132.52 4,091.40 4,043.90 -3,315.88 -1,672.03 6,028,152.72 543,471.10 6.27 2,091.66 MWD+IFR2+MS+sag(3) 6,450.90 79.89 127.42 4,111.37 4,063.87 -3,375.20 -1,601.22 6,028,093.84 543,542.27 6.87 2,177.85 MWD+IFR2+MS+sag(3) 6,509.01 81.73 126.11 4,120.65 4,073.15 -3,409.53 -1,555.26 6,028,059.80 543,588.42 3.87 2,230.14 MWD+IFR2+MS+sag(3) 6,630.56 84.23 125.38 4,135.51 4,088.01 -3,480.00 -1,457.36 6,027,989.93 543,686.74 2.14 2,339.20 MWD+IFR2+MS+sag(4) 6,725.83 85.96 126.85 4,143.65 4,096.15 -3,535.94 -1,380.68 6,027,934.46 543,763.75 2.38 2,425.28 MWD+IFR2+MS+sag(4) 6,819.20 87.93 128.76 4,148.63 4,101.13 -3,593.09 -1,307.02 6,027,877.76 543,837.75 2.94 2,510.94 MWD+IFR2+MS+sag(4) 6,913.88 89.48 129.79 4,150.77 4,103.27 -3,653.01 -1,233.75 6,027,818.30 543,911.37 1.97 2,598.85 MWD+IFR2+MS+sag(4) 7,007.73 90.29 130.66 4,150.96 4,103.46 -3,713.62 -1,162.10 6,027,758.13 543,983.39 1.27 2,686.57 MWD+IFR2+MS+sag(4) 7,102.46 89.80 130.22 4,150.88 4,103.38 -3,775.06 -1,090.00 6,027,697.13 544,055.85 0.70 2,775.24 MWD+IFR2+MS+sag(4) 7,196.75 89.80 131.12 4,151.21 4,103.71 -3,836.51 -1,018.49 6,027,636.12 544,127.73 0.95 2,863.63 MWD+IFR2+MS+sag(4) 7,291.02 90.78 132.91 4,150.73 4,103.23 -3,899.60 -948.45 6,027,573.46 544,198.14 2.16 2,952.75 MWD+IFR2+MS+sag(4) 7,385.75 92.56 134.77 4,147.97 4,100.47 -3,965.18 -880.16 6,027,508.30 544,266.82 2.72 3,043.20 MWD+IFR2+MS+sag(4) 7,479.73 92.52 133.66 4,143.81 4,096.31 -4,030.65 -812.87 6,027,443.25 544,334.50 1.18 3,133.06 MWD+IFR2+MS+sag(4) 7,574.00 91.28 131.92 4,140.68 4,093.18 -4,094.65 -743.73 6,027,379.68 544,404.02 2.27 3,222.54 MWD+IFR2+MS+sag(4) 7,668.74 90.72 131.79 4,139.03 4,091.53 -4,157.86 -673.18 6,027,316.91 544,474.95 0.61 3,312.00 MWD+IFR2+MS+sag(4) 7,763.40 89.98 131.62 4,138.45 4,090.95 -4,220.83 -602.51 6,027,254.37 544,545.99 0.80 3,401.32 MWD+IFR2+MS+sag(4) 7,857.65 90.97 131.21 4,137.67 4,090.17 -4,283.18 -531.83 6,027,192.46 544,617.04 1.14 3,490.09 MWD+IFR2+MS+sag(4) 7,951.32 90.72 129.95 4,136.29 4,088.79 -4,344.10 -460.69 6,027,131.97 544,688.54 1.37 3,577.84 MWD+IFR2+MS+sag(4) 8,046.11 90.11 129.29 4,135.60 4,088.10 -4,404.55 -387.68 6,027,071.98 544,761.91 0.95 3,666.08 MWD+IFR2+MS+sag(4) 8,139.75 89.49 127.42 4,135.93 4,088.43 -4,462.65 -314.25 6,027,014.33 544,835.68 2.10 3,752.47 MWD+IFR2+MS+sag(4) 8,234.11 90.41 125.15 4,136.01 4,088.51 -4,518.49 -238.20 6,026,958.96 544,912.07 2.60 3,838.15 MWD+IFR2+MS+sag(4) 8,328.34 89.68 124.70 4,135.94 4,088.44 -4,572.44 -160.94 6,026,905.49 544,989.64 0.91 3,922.76 MWD+IFR2+MS+sag(4) 8,423.29 90.54 124.24 4,135.76 4,088.26 -4,626.18 -82.66 6,026,852.23 545,068.24 1.03 4,007.68 MWD+IFR2+MS+sag(4) 12222015 8:07:24PM Page 4 COMPASS 5000.1 Build 73 • ! Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPL-48 Project: Milne Point TVD Reference: As-Built MPL-48 @ 47.50usft Site: M Pt L Pad MD Reference: As-Built MPL-48 @ 47.50usft Well: MPL-48 North Reference: True Wellbore: MPL-48PB3 Survey Calculation Method: Minimum Curvature Design: MPL-48 PB3 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 8,516.82 91.16 126.39 4,134.37 4,086.87 -4,680.23 -6.36 6,026,798.64 545,144.86 2.39 4,091.93 MWD+IFR2+MS+sag(4) 8,612.02 89.31 126.81 4,133.98 4,086.48 -4,736.99 70.07 6,026,742.35 545,221.62 1.99 4,178.59 MWD+IFR2+MS+sag(4) 8,706.65 89.30 126.75 4,135.12 4,087.62 -4,793.65 145.86 6,026,686.17 545,297.75 0.06 4,264.86 MWD+IFR2+MS+sag(4) 8,800.42 90.17 126.27 4,135.56 4,088.06 -4,849.43 221.22 6,026,630.84 545,373.44 1.06 4,350.17 MWD+IFR2+MS+sag(4) 8,894.43 90.35 123.56 4,135.13 4,087.63 -4,903.24 298.30 6,026,577.51 545,450.84 2.89 4,434.56 MWD+IFR2+MS+sag(4) 8,988.49 91.65 122.48 4,133.49 4,085.99 -4,954.48 377.15 6,026,526.75 545,529.99 1.80 4,517.58 MWD+IFR2+MS+sag(4) 9,083.78 91.59 121.29 4,130.80 4,083.30 -5,004.80 458.03 6,026,476.94 545,611.17 1.25 4,600.76 MWD+IFR2+MS+sag(4) 9,177.86 91.77 121.58 4,128.04 4,080.54 -5,053.84 538.27 6,026,428.38 545,691.69 0.36 4,682.53 MWD+IFR2+MS+sag(4) 9,257.00 91.77 121.58 4,125.59 4,078.09 -5,095.26 605.66 6,026,387.37 545,759.33 0.00 4,751.40 PROJECTED to TD brian.wheeler@halliburton.com n ...... .,� rY Y w�wrow wc..°w°.+.w,�<, Checked By: Ep,=,ror,„ f Approved By: ca .ta for halliburton.como«= •:=7, Date: 12/2/2015 8:07:24PM Page 5 COMPASS 5000.1 Build 73 i • Hilcorp Energy Company CASING&CEMENTING REPORT Lease&Well No. Milne Point Unit,L-48 Date 25-Oct-15 County North Slope Borough State Alaska Supv. Sloan Sunderland/Doug Yessak CASING RECORD TD 6552.00 Shoe Depth: 6538.21 PBTD: Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top Shoe 95/8 TC-II DHP 2.92 6,538.21 6,535.29 1 int 9 5/8 47 L-80 TC-II 40.16 6,535.29 6,495.13 Flt Or 9 5/8 TC-II DHP 1.94 6,495.13 6,493.19 1 int 9 5/8 47 L-80 TC-II 41.08 6,493.19 6,452.11 Pup XO 9 5/8 47 L-80 TC-II 15.61 6,452.11 6,436.50 BEL 9 5/8 47 L-80 _ BTC 2.74 6,436.50 6,433.76 Pup XO 9 5/8 47 L-80 TC-II 17.52 6,433.76 6,416.24 100 Jnts 9 5/8 47 _ L-80 TC-II 4,014.32 6,416.24 2,401.92 Pup XO 9 5/8 47 L-80 TC-II 15.60 2,401.92 2,386.32 ES CMT 9 5/8 47 L-80 BTC 4.01 2,386.32 2,382.31 Pup XO 9 5/8 47 L-80 TC-II 16.54 2,382.31 2,365.77 58 into 9 5/8 47 _ L-80 TC-II 2,332.42 _ 2,365.77 33.35 Hgr w/pup 9 5/8 47 L-80 TC-II Seaboard _ 2.60 33.35 30.75 RKB 9 5/8 BTC 30.75 30.75 0.00 Totals 162 into Csg Wt.On Hook: 115 Type Float Collar: Model 402 No.Hrs to Run: 29 Csg Wt.On Slips: 85 Type of Shoe: Bull Nose Casing Crew: WFD Fluid Description: 9.3 ppg Spud Mud, YP 17 Liner hanger Info(Make/Model): Liner top Packer?: _Yes X No Liner hanger test pressure: Centralizer Placement: 2 bowspring on shoe jnt,1 centralizer middle FC Joint, 1 centralizers every other jnt to jt 15, Plus 3 above and below the ES Cmt Tool.18 Total CEMENTING REPORT Preflush(Spacer) Type: Tuned Spacer III Density(ppg) 10.5 Volume pumped(BBLs) 43 Lead Slurry Type: Extended Density(ppg) 11.7 Volume pumped(BBLs) 230 Mixing/Pumping Rate(bpm): 4 Tail Slurry Type: Swift Chem Stage 1 lej Density(ppg) 15.8 Volume pumped(BBLs) 83 Mixing/Pumping Rate(bpm): 4 m Post Flush(Spacer) )( Type:Fresh Water Density(ppg) 8.3 Rate(bpm): 4 Volume: 20 IX LL Displacement: Type: Spud Mud Density(ppg) 9.3 Rate(bpm): 4 Volume(actual/calculated): 448/452 FCP(psi): 1179 Pump used for disp: Halliburton Plug Bumped? x Yes No Bump press 1750 Casing Rotated? Yes X No Reciprocated? Yes X No %Returns during job 90 Cement returns to surface'? x Yes No Spacer returns? X Yes No Vol to Surf: 103 i/ Cement In Place At: 4:24 Date: 10/25/2015 Estimated TOC: 2,382 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) 10.7 Volume pumped(BBLs) 287 Mixing/Pumping Rate(bpm): 4 Tail Slurry ui Type: Swift Chem-Stage 2 Lead Density(ppg) 15.8 Volume pumped(BBLs) 54 Mixing/Pumping Rate(bpm): 4 N Post Flush(Spacer) 0 0 z Type: Density(ppg) Rate(bpm): Volume: E Displacement: 0 Type: Spud Mud Density(ppg) 9.3 Rate(bpm): 5 Volume(actual/calculated): 173/175 FCP(psi): 600 Pump used for disp: Halliburton Plug Bumped? X Yes No Bump press 2000 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: 140 Cement In Place At: 15:00 Date: 10/25/2015 Estimated TOC: 0 Method Used To Determine TOC: Returns to surface WELLHEAD Make Seaboard Type 3000 psi Wellhead Serial No. Size W.P. Test Head To PSIG MIN OK Remarks: We finished both stages with cement returned to surface. 0 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reagc alaska.00v: doa.aogcc.prudhoe.bay@alaska.gov; phoebe.brooksCrilalaska.aov OPERATOR: Hilcorp Alaska LLC FIELD/UNIT/PAD: Milne Point/MPU/L DATE: 12/21/15 OPERATOR REP: Matthew Linder AOGCC REP: Guy Cook Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well MPL-48 Type Inj. W TVD 4,028' Tubing_ 360 367 _ 366 366 Interval I P.T.D. 215120 Type test P Test psi 1500 Casing 335 1,795 1,745 1,729 P/F P Notes: Initial AOGCC MIT-IA for new drill well. OA 0 0 0 0 2.45 bbls diesel to pressure up,2.2 bbls bled back. Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type In). TVD TubingInterval 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 0=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-48 12-21-15 • • MPL-48 FINAL Days vs Depth 0 500 1111 — MPL 48 Actual 1000 — -- MPL-48 Plan 1500 2000 2500 "_-- 3000 3500 1111111111 -- 400011111 4500 5000 5500 6000 6500 a 0 7000 -o v 7500 3I(� CafO, 8000 8500 9000 9500 10000 10500 11000 11500 12000 ' 1 12500 13000 - - 13500 - - 14000 - 14500 0 5 10 15 20 25 30 35 40 45 50 Days 12/18/2015 9:49 AM MPL-48 MW vs Depth 0 MPL-48 Plan �._ 1000 , -MPL-48 Actual 2000 3000 4000 5000 F r aa)i 6000 ai ca a) 7000 8000 9000 - 10000 11000 12000 8.0 9.0 10.0 11.0 12.0 13.0 14.0 Mud Density(ppg) 1110 • 21 51 20 II Maile Sweigart Alaska North Slope Team Hilcorp Alaska, LLC 3800 Centerpoint Drive, Ste 1400 1 Anchorage,Alaska 99503 Hll•erp w LLC Office: 907.777.8473 msweigart@hilcorp.com DATA LOGGED /?-n/201Co M.K.BENDER Date: 12/17/15 To: Alaska Oil & Gas Conservation Commission Makana Bender • Natural Resource Technician 333 W 7th Ave Ste 100 RECEIVFD Anchorage, AK 99501 iL E C 18 LI,; AOGCC DATA TRANSMITTAL z • : 6583 26584 MP L-48, L-48PB1, L-48PB2, L-48PB3 L-48 Prints: ROP-DGR-ADR-EWR-HORIZONTAL PRES 2IN MD,DGR-ADR-EWR-INVERTED/REVERTED INTERVALS 2IN TVD L-48PB 1 Prints:ROP-DGR-EWR 2IN MD,DGR-EWR 2IN TVD L-48PB2 Prints: ROP-DGR-EWR 21N MD,DGR-EW$2IN TVD r L-48PB3 Prints: ROP-DGR-ADR-EWR-HORIZONTAL PRES 2IN MD,DGR-ADR-EWR 2IN TVD E log data CD 1 : Final Well Data Name Date modified Type a. MPL-48 12/9/2015 5;01 PM File folder .46 MPL-48 PB1 12/9/2015 5:02 PM File folder MPL-48 PB2 12/9/2015 5:02 PM File folder li MPL-48 PB3 12/9/2015 5:02 PM File folder Each folder contains subfolders: Name Date modified Type 1 CGM 12/9,12015 5:01 PM File folder Definitive Survey 12/9/2015 5:01 PM File folder 1 DLIS+LAS 12/9/2015 5:01 PM File folder A EMF 12/9/2015 5:01 PM File folder PDF 12/9/2015 5:01 PM File folder ` TIFF 12/9/2015 5:01 PM File folder Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received ByD�/A:daV Date: • • Brooks, Phoebe L (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Tuesday, December 29, 2015 12:44 PM To: Regg,James B (DOA) Cc: Brooks, Phoebe L (DOA) Subject: RE: MIT MPU L-48 (PTD # 215120) Attachments: MPL-48 - Definitive Survey.pdf Jim, Sorry for the broken file.The attached deviation survey should be good. Thank You, Wyatt Rivard Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 ( wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, December 29, 2015 12:15 PM To: Wyatt Rivard Cc: Brooks, Phoebe L (DOA) Subject: RE: MIT MPU L-48 (PTD # 215120) Can you send us the deviation survey? Could not open one of the attachments—may have been the survey. Thank you. 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 or iim.regg@alaska.gov. From: Wyatt Rivard [mailto:wrivard©hilcorp.com] Sent: Tuesday, December 22, 2015 2:43 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; Cody Dinger - (C) Subject: MIT MPU L-48 (PTD # 215120) All, 1 Milne Point water injector L-48 (PTD#215120) had a passing AOGCC witnessed MIT-IA on 12/21/15.The MIT form is attached for reference. MPL-48 is a new drill well, schematic and deviation survey are also attached. Thank You, Wyatt Rivard I Well Integrity Fngineer 0: (907) 777'8547 | C: (509)670'8001 | vvrhard@biicorp.cncu ]O0UCent cr in1Drke. Sukel400 | &ucboroge,/lK99S03 Ifiteorp Atato �.V�� 2 • • i ro HilcorpEnergyCompany p Y Milne Point M Pt L Pad MPL-48 500292355200 ; 500292355200 Sperry Drilling fe Definitive Survey Report 02 December, 2015 N 40 2 ri �R ''II 41 11111111 , N mem etasr ggOlr9 • • Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPL-48 Project: Milne Point TVD Reference: As-Built MPL-48 @ 47.50usft Site: M Pt L Pad MD Reference: As-Built MPL-48 @ 47.50usft Well: MPL-48 North Reference: True Wellbore: MPL-48 Survey Calculation Method: Minimum Curvature Design: MPL-48 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-48 Well Position +N/-S 0.00 usft Northing: 6,031,478.37 usft Latitude: 70°29'48.710 N +E/-W 0.00 usft Easting: 545,122.81 usft Longitude: 149°3T 51.652 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 17.50 usft Wellbore MPL-48 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2015 9/17/2015 18.91 81.08 57,505 Design MPL-48 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 8,706.70 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 30.00 0.00 0.00 151.04 Survey Program Date 12/2/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 90.00 972.00 MPL-48 Gyro(MPL-48PB1) SRG-MS Surface readout gyro multishot 09/29/2015 1,066.56 1,915.86 MPL-48 MWD(MPL-48PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/13/2015 2,013.79 6,509.01 MPL-48 MWD(MPL-48PB3) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/19/2015 6,630.56 8,706.70 MPL-48 MWD(2)(MPL-48PB3) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/29/2015 8,720.00 13,130.78 MPL-48 MWD(MPL-48) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/05/2015 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100) (ft) Survey Tool Name 30.00 0.00 0.00 30.00 -17,50 0.00 0.00 6,031,478.37 545,122.81 0.00 0.00 UNDEFINED 90.00 0.63 135.44 90.00 42.50 -0.24 0.23 6,031,478.14 545,123.04 1.05 0.32 SRG-MS(1) 134.00 0.57 129.63 134.00 86.50 -0.55 0.57 6,031,477.83 545,123.38 0.19 0.75 SRG-MS(1) 221.00 0.52 138.84 220.99 173.49 -1.12 1.16 6,031,477.26 545,123.98 0,12 1.54 SRG-MS(1) 316.00 0.65 140.74 315.99 268.49 -1.86 1.79 6,031,476.52 545,124.61 0.14 2.49 SRG-MS(1) 408.00 1.98 145.56 407.96 360.46 -3.58 3.02 6,031,474.81 545,125.85 1.45 4.59 SRG-MS(1) 502.00 3.35 144.47 501.86 454.36 -7.15 5.53 6,031,471.25 545,128.38 1.46 8.94 SRG-MS(1) 596.00 3.75 148.17 595.68 548.18 -12.00 8.75 6,031,466.43 545,131.63 0.49 14.73 SRG-MS(1) 689.00 5.99 144.22 688.34 640.84 -18.52 13.19 6,031,459.93 545,136.11 2.43 22.59 SRG-MS(1) 783.00 7,50 141.21 781.68 734.18 -27.28 19.90 6,031,451.21 545,142.87 1.65 33.51 SRG-MS(1) 12/2/2015 8:10:59PM Page 2 COMPASS 5000.1 Build 73 IIII • Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPL-48 Project: Milne Point TVD Reference: As-Built MPL-48©47.50usft Site: M Pt L Pad MD Reference: As-Built MPL-48 @ 47.50usft Well: MPL-48 North Reference: True Wellbore: MPL-48 Survey Calculation Method: Minimum Curvature Design: MPL-48 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 878.00 10.77 135.91 875.47 827,97 -38.49 29.96 6,031,440.06 545,153.00 3,55 48.19 SRG-MS(1) 972.00 11.08 137.32 967.76 920.26 -51.44 42.20 6,031,427.19 545,165.32 0.44 65.44 SRG-MS(1) 1,066.56 12,67 154.43 1,060.33 1,012.83 -67.48 52.84 6,031,411.22 545,176.05 4.07 84.63 MWD+IFR2+MS+sag(2) 1,160.89 13.85 169.61 1,152.17 1,104.67 -87.92 59.34 6,031,390.82 545,182.68 3.88 105.66 MWD+IFR2+MS+sag(2) 1,254.60 15.31 185.34 1,242.89 1,195.39 -111.29 60.21 6,031,367.46 545,183.69 4.49 126.53 MWD+IFR2+MS+sag(2) 1,348.91 19,95 197.33 1,332.78 1,285.28 -139.07 54.26 6,031,339.65 545,177.90 6.22 147.95 MWD+IFR2+MS+sag(2) 1,443.95 27.42 205.73 1,419.78 1,372.28 -174.32 39.90 6,031,304.32 545,163.77 8.61 171.84 MWD+IFR2+MS+sag(2) 1,538.05 26.27 206.20 1,503.73 1,456.23 -212.52 21.30 6,031,266.00 545,145.40 1.24 196.26 MWD+IFR2+MS+sag(2) 1,632,41 28.33 209.22 1,587.58 1,540.08 -250.80 1.15 6,031,227.60 545,125.48 2.63 220.00 MWD+IFR2+MS+sag(2) 1,726.67 32.16 214.27 1,669.01 1,621.51 -291.08 -23.91 6,031,187.18 545,100.67 4.87 243.10 MWD+IFR2+MS+sag(2) 1,820.86 36.67 219.85 1,746.71 1,699.21 -333.42 -56.07 6,031,144.65 545,068.77 5.84 264.58 MWD+IFR2+MS+sag(2) 1,915.86 42.43 223.20 1,819.94 1,772.44 -378.60 -96.22 6,031,099.23 545,028.89 6.46 284.67 MWD+IFR2+MS+sag(2) 2,013.79 41.19 224.35 1,892.93 1,845.43 -425.74 -141.38 6,031,051.82 544,984.03 1.49 304.05 MWD+IFR2+MS+sag(3) 2,110.43 44,20 225.11 1,963.95 1,916.45 -472.29 -187.50 6,031,005.00 544,938.19 3.16 322.44 MWD+IFR2+MS+sag(3) 2,204.36 45.23 225.70 2,030.70 1,983.20 -518.68 -234.57 6,030,958.32 544,891.42 1.18 340.25 MWD+IFR2+MS+sag(3) 2,298.13 52.42 227.46 2,092.40 2,044.90 -567.12 -285.83 6,030,909.58 544,840.45 7.80 357.80 MWD+IFR2+MS+sag(3) 2,393.11 53.89 227.08 2,149.35 2,101.65 -618.69 -341.66 6,030,857.68 544,784.94 1.58 375.90 MWD+IFR2+MS+sag(3) 2,488.30 56.96 226.22 2,203.37 2,155.87 -672.50 -398.64 6,030,803.53 544,728.29 3.31 395.38 MWD+IFR2+MS+sag(3) 2,581.81 55.58 225.41 2,255.29 2,207.79 -726.69 -454.41 6,030,749.00 544,672.86 1.64 415.80 MWD+IFR2+MS+sag(3) 2,675.21 56.74 228.88 2,307.31 2,259.81 -779.43 -511.28 6,030,695.93 544,616.32 3.33 434.41 MWD+IFR2+MS+sag(3) 2,768.78 59.09 227.73 2,357.01 2,309.51 -832.17 -570.46 6,030,642.84 544,557.46 2.72 451.89 MWD+IFR2+MS+sag(3) 2,864.92 57,11 228.28 2,407.81 2,360.31 -886.78 -631.12 6,030,587.87 544,497.15 2.12 470.31 MWD+IFR2+MS+sag(3) 2,959.50 60.33 228.21 2,456.91 2,409.41 -940.60 -691.41 6,030,533.68 544,437.19 3.41 488.21 MWD+IFR2+MS+sag(3) 3,052.95 59.58 227.82 2,503.70 2,456.20 -994.71 -751.54 6,030,479.21 544,377.40 0.88 506.44 MWD+IFR2+MS+sag(3) 3,147.34 60.06 226.60 2,551.16 2,503.66 -1,050.14 -811.41 6,030,423.43 544,317.86 1.23 525.94 MWD+IFR2+MS+sag(3) 3,242.51 60.30 224.72 2,598.48 2,550.98 -1,107.85 -870.46 6,030,365.37 544,259.17 1.73 547.84 MWD+IFR2+MS+sag(3) 3,336.40 59.23 224.26 2,645.76 2,598.26 -1,165.71 -927.31 6,030,307.17 544,202.68 1.22 570.95 MWD+IFR2+MS+sag(3) 3,431.74 58.87 224.78 2,694.79 2,647.29 -1,224.01 -984.64 6,030,248.53 544,145.72 0.60 594.20 MWD+IFR2+MS+sag(3) 3,525.06 58.50 224.34 2,743.30 2,695.80 -1,280.81 -1,040.58 6,030,191.39 544,090.13 0.57 616.81 MWD+IFR2+MS+sag(3) 3,619.83 57,94 224.32 2,793.21 2,745.71 -1,338.44 -1,096.87 6,030,133.43 544,034.19 0.59 639.98 MWD+IFR2+MS+sag(3) 3,714.00 57.52 224.20 2,843.49 2,795.99 -1,395.47 -1,152.44 6,030,076.07 543,978.97 0.46 662.96 MWD+IFR2+MS+sag(3) 3,808.53 56.84 224.73 2,894.72 2,847.22 -1,452.16 -1,208.09 6,030,019.04 543,923.68 0.86 685.63 MWD+IFR2+MS+sag(3) 3,903.13 57.21 224.46 2,946.21 2,898.71 -1,508.67 -1,263.81 6,029,962.20 543,868.31 0.46 708.09 MWD+IFR2+MS+sag(3) 3,998.00 56.83 224.23 2,997.85 2,950.35 -1,565.59 -1,319.43 6,029,904.96 543,813.03 0.45 730.95 MWD+IFR2+MS+sag(3) 4,091.73 56.55 223.66 3,049.33 3,001.83 -1,621.99 -1,373.79 6,029,848.23 543,759.02 0.59 753.98 MWD+IFR2+MS+sag(3) - 4,185.88 57.47 226.23 3,100.60 3,053.10 -1,677.86 -1,429.58 6,029,792.02 543,703.58 2.49 775.86 MWD+IFR2+MS+sag(3) 4,280.18 57.64 226.67 3,151.19 3,103.69 -1,732.69 -1,487.26 6,029,736.85 543,646.24 0.43 795.91 MWD+IFR2+MS+sag(3) 4,374.65 57.70 225.86 3,201.71 3,154.21 -1,787.88 -1,544.93 6,029,681.32 543,588.91 0.73 816.26 MWD+IFR2+MS+sag(3) 4,469.83 57.88 226.45 3,252.44 3,204.94 -1,843.66 -1,603.01 6,029,625.19 543,531.17 0.56 836.95 MWD+IFR2+MS+sag(3) 4,563.68 57.85 226.57 3,302.36 3,254.86 -1,898.36 -1,660.67 6,029,570.15 543,473.86 0.11 856.89 MWD+IFR2+MS+sag(3) 12/2/2015 8:10:59PM Page 3 COMPASS 5000.1 Build 73 el • Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPL-48 Project: Milne Point TVD Reference: As-Built MPL-48 @ 47.50usft Site: M Pt L Pad MD Reference: As-Built MPL-48©47.50usft . Well: MPL-48 North Reference: True Wellbore: MPL-48 Survey Calculation Method: Minimum Curvature Design: MPL-48 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/1001 (ft) Survey Tool Name 4,656.75 58.36 224.36 3,351.54 3,304.04 -1,953.77 -1,716.99 6,029,514.40 543,417.88 2.09 878.11 MWD+IFR2+MS+sag(3) 4,751.74 59.42 219.93 3,400.64 3,353.14 -2,014.06 -1,771.52 6,029,453.79 543,363.72 4.15 904.45 MWD+IFR2+MS+sag(3) 4,846.57 60.70 214.18 3,448.00 3,400.50 -2,079.62 -1,820.99 6,029,387.94 543,314.66 5.42 937.86 MWD+IFR2+MS+sag(3) 4,941.15 60.56 208.14 3,494.42 3,446.92 -2,150.10 -1,863.61 6,029,317.21 543,272.47 5.57 978.89 MWD+IFR2+MS+sag(3) 5,035.74 59.07 204.28 3,541.99 3,494.49 -2,223.42 -1,899.73 6,029,243.67 543,236.80 3.86 1,025.56 MWD+IFR2+MS+sag(3) 5,130.07 58.51 199.29 3,590.89 3,543.39 -2,298.30 -1,929.67 6,029,168.62 543,207.32 4.56 1,076.57 MWD+IFR2+MS+sag(3) 5,223.96 59.24 194.27 3,639.44 3,591.94 -2,375.22 -1,952.85 6,029,091.58 543,184.61 4.64 1,132.65 MWD+IFR2+MS+sag(3) 5,318.55 59.60 188.67 3,687.59 3,640.09 -2,454.98 -1,969.02 6,029,011.73 543,168.92 5.11 1,194.60 MWD+IFR2+MS+sag(3) 5,412.73 59.30 183.25 3,735.49 3,687.99 -2,535.60 -1,977.44 6,028,931.06 543,160.99 4.97 1,261.07 MWD+IFR2+MS+sag(3) 5,507.53 58.35 180.69 3,784.57 3,737.07 -2,616.65 -1,980.24 6,028,850.00 543,158.68 2.52 1,330.63 MWD+IFR2+MS+sag(3) 5,601.57 58.76 176.71 3,833.64 3,786.14 -2,696.83 -1,978.42 6,028,769.84 543,160.99 3.64 1,401.67 MWD+IFR2+MS+sag(3) 5,695.84 63.19 171.36 3,879.40 3,831.90 -2,778.74 -1,969.77 6,028,687.99 543,170,13 6.83 1,477.52 MWD+IFR2+MS+sag(3) 5,787.30 67.49 164.44 3,917.59 3,870.09 -2,859.91 -1,952.28 6,028,606.94 543,188.11 8.33 1,557.01 MWD+IFR2+MS+sag(3) 5,884.56 70.63 157.91 3,952.37 3,904.87 -2,945.80 -1,922.95 6,028,521.24 543,217.97 7.05 1,646.37 MWD+IFR2+MS+sag(3) 5,979.01 72.85 152.80 3,981.98 3,934.48 -3,027.28 -1,885.54 6,028,440.00 543,255.87 5.65 1,735.77 MWD+IFR2+MS+sag(3) 6,073.72 73.37 149.33 4,009.51 3,962.01 -3,106.58 -1,841.70 6,028,360.98 543,300.18 3.55 1,826.38 MWD+IFR2+MS+sag(3) 6,168.01 71.89 144.06 4,037.68 3,990.18 -3,181.76 -1,792.32 6,028,286.10 543,350.01 5.56 1,916.07 MWD+IFR2+MS+sag(3) 6,262.05 73.06 138.00 4,066.02 4,018.52 -3,251.43 -1,735.94 6,028,216.78 543,406.81 6.27 2,004.33 MWD+IFR2+MS+sag(3) 6,356.34 75.73 132.52 4,091.40 4,043.90 -3,315.88 -1,672.03 6,028,152.72 543,471.10 6.27 2,091.66 MWD+IFR2+MS+sag(3) 6,450.90 79.89 127.42 4,111.37 4,063.87 -3,375.20 -1,601.22 6,028,093.84 543,542.27 6.87 2,177.85 MWD+IFR2+MS+sag(3) 6,509.01 81.73 126.11 4,120.65 4,073.15 -3,409.53 -1,555.26 6,028,059.80 543,588.42 3.87 2,230.14 MWD+IFR2+MS+sag(3) 6,630.56 84.23 125.38 4,135.51 4,088.01 -3,480.00 -1,457.36 6,027,989.93 543,686.74 2.14 2,339.20 MWD+IFR2+MS+sag(4) 6,725.83 85.96 126.85 4,143.65 4,096.15 -3,535.94 -1,380.68 6,027,934.46 543,763.75 2.38 2,425.28 MWD+IFR2+MS+sag(4) 6,819.20 87.93 128.76 4,148.63 4,101.13 -3,593.09 -1,307.02 6,027,877.76 543,837.75 2.94 2,510.94 MWD+IFR2+MS+sag(4) 6,913.88 89.48 129.79 4,150.77 4,103.27 -3,653.01 -1,233.75 6,027,818.30 543,911.37 1.97 2,598.85 MWD+IFR2+MS+sag(4) 7,007.73 90.29 130.66 4,150.96 4,103.46 -3,713.62 -1,162.10 6,027,758.13 543,983.39 1.27 2,686.57 MWD+IFR2+MS+sag(4) 7,102.46 89.80 130.22 4,150.88 4,103.38 -3,775.06 -1,090.00 6,027,697.13 544,055.85 0.70 2,775.24 MWD+IFR2+MS+sag(4) 7,196.75 89.80 131.12 4,151.21 4,103.71 -3,836.51 -1,018.49 6,027,636.12 544,127.73 0.95 2,863.63 MWD+IFR2+MS+sag(4) 7,291.02 90.78 132.91 4,150.73 4,103.23 -3,899.60 -948.45 6,027,573.46 544,198.14 2.16 2,952.75 MWD+IFR2+MS+sag(4) 7,385.75 92.56 134.77 4,147.97 4,100.47 -3,965.18 -880.16 6,027,508.30 544,266.82 2.72 3,043.20 MWD+IFR2+MS+sag(4) 7,479.73 92.52 133.66 4,143.81 4,096.31 -4,030.65 -812.87 6,027,443.25 544,334.50 1.18 3,133.06 MWD+IFR2+MS+sag(4) 7,574.00 91.28 131.92 4,140.68 4,093.18 -4,094.65 -743.73 6,027,379.68 544,404.02 2.27 3,222.54 MWD+IFR2+MS+sag(4) 7,668.74 90.72 131.79 4,139.03 4,091.53 -4,157.86 -673.18 6,027,316.91 544,474.95 0.61 3,312.00 MWD+IFR2+MS+sag(4) 7,763.40 89.98 131.62 4,138.45 4,090.95 -4,220.83 -602.51 6,027,254.37 544,545.99 0.80 3,401.32 MWD+IFR2+MS+sag(4) 7,857.65 90.97 131.21 4,137.67 4,090.17 -4,283.18 -531.83 6,027,192.46 544,617.04 1.14 3,490.09 MWD+IFR2+MS+sag(4) 7,951.32 90.72 129.95 4,136.29 4,088.79 -4,344.10 -460.69 6,027,131.97 544,688.54 1.37 3,577.84 MWD+IFR2+MS+sag(4) 8,046.11 90.11 129.29 4,135.60 4,088.10 -4,404.55 -387.68 6,027,071.98 544,761.91 0.95 3,666.08 MWD+IFR2+MS+sag(4) 8,139.75 89.49 127.42 4,135.93 4,088.43 -4,462.65 -314.25 6,027,014.33 544,835.68 2.10 3,752.47 MWD+IFR2+MS+sag(4) 8,234.11 90.41 125.15 4,136.01 4,088.51 -4,518.49 -238.20 6,026,958.96 544,912.07 2.60 3,838.15 MWD+IFR2+MS+sag(4) 8,328.34 89.68 124.70 4,135.94 4,088.44 -4,572.44 -160.94 6,026,905.49 544,989.64 0.91 3,922.76 MWD+IFR2+MS+sag(4) 12/2/2015 8.10:59PM Page 4 COMPASS 5000.1 Build 73 • • Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPL-48 Project: Milne Point TVD Reference: As-Built MPL-48 @ 47.50usft Site: M Pt L Pad MD Reference: As-Built MPL-48©47.5ousft Well: MPL-48 North Reference: True Wellbore: MPL-48 Survey Calculation Method: Minimum Curvature Design: MPL-48 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 8,423.29 90.54 124.24 4,135.76 4,088.26 -4,626.18 -82.66 6,026,852.23 545,068.24 1.03 4,007.68 MWD+IFR2+MS+sag(4) 8,516.82 91.16 126.39 4,134.37 4,086.87 -4,680.23 -6.36 6,026,798.64 545,144.86 2.39 4,091.93 MWD+IFR2+MS+sag(4) 8,612.02 89.31 126.81 4,133.98 4,086.48 -4,736.99 70.07 6,026,742.35 545,221.62 1.99 4,178.59 MWD+IFR2+MS+sag(4) 8,706.65 89.30 126.75 4,135.12 4,087.62 -4,793.65 145.86 6,026,686.17 545,297.75 0.06 4,264.86 MWD+IFR2+MS+sag(4) 8,720.00 89.42 126.68 4,135.27 4,087.77 -4,801.63 156.56 6,026,678.25 545,308.49 1.04 4,277.03 MWD+IFR2+MS+sag(5) 8,777.76 87.84 128.23 4,136.65 4,089.15 -4,836.74 202.39 6,026,643.42 545,354.54 3.83 4,329.94 MWD+IFR2+MS+sag(5) 8,871.88 90,80 129.18 4,137.77 4,090.27 -4,895.58 275.83 6,026,585.03 545,428.32 3.30 4,416.98 MWD+IFR2+MS+sag(5) 8,966.01 94.83 126.77 4,133.15 4,085.65 -4,953.42 349.92 6,026,527.65 545,502.75 4.99 4,503.46 MWD+IFR2+MS+sag(5) 9,060.34 91.05 124.42 4,128.31 4,080.81 -5,008.24 426.50 6,026,473.30 545,579.66 4.72 4,588.51 MWD+IFR2+MS+sag(5) 9,154.44 91.79 125.51 4,125.98 4,078.48 -5,062.14 503.59 6,026,419.87 545,657.07 1.40 4,673.00 MWD+IFR2+MS+sag(5) 9,249.66 91.17 128.32 4,123.52 4,076.02 -5,119.31 579.69 6,026,363.17 545,733.51 3.02 4,759.87 MWD+IFR2+MS+sag(5) 9,343.25 90.43 126.75 4,122.21 4,074.71 -5,176.32 653.89 6,026,306.62 545,808.05 1.85 4,845.68 MWD+IFR2+MS+sag(5) 9,435.78 92,41 124.56 4,119.92 4,072.42 -5,230.24 729.05 6,026,253.17 545,883.52 3.19 4,929.24 MWD+IFR2+MS+sag(5) 9,531.78 91.85 123.00 4,116.35 4,068.85 -5,283.57 808.78 6,026,200.32 545,963.57 1.73 5,014.52 MWD+IFR2+MS+sag(5) 9,624.86 92.10 120.36 4,113.14 4,065.64 -5,332.42 887.94 6,026,151.95 546,043.01 2.85 5,095.59 MWD+IFR2+MS+sag(5) 9,719.35 91.11 120.16 4,110.50 4,063.00 -5,380.02 969.52 6,026,104.86 546,124.87 1.07 5,176.73 MWD+IFR2+MS+sag(5) 9,814.44 91.54 120.92 4,108.30 4,060.80 -5,428.33 1,051.40 6,026,057.06 546,207.03 0.92 5,258.64 MWD+IFR2+MS+sag(5) 9,908.98 90.12 118.53 4,106.93 4,059.43 -5,475.19 1,133.48 6,026,010.69 546,289.39 2.94 5,339.39 MWD+IFR2+MS+sag(5) 10,003.13 92.72 117.94 4,104.59 4,057.09 -5,519.72 1,216.39 6,025,966.68 546,372.57 2.83 5,418.50 MWD+IFR2+MS+sag(5) 10,097.90 91.79 117.94 4,100.87 4,053.37 -5,564.09 1,300.05 6,025,922.82 546,456.49 0.98 5,497.83 MWD+IFR2+MS+sag(5) 10,192.65 90.99 117.28 4,098.57 4,051.07 -5,607.98 1,383.99 6,025,879.44 546,540.68 1.09 5,576.88 MWD+IFR2+MS+sag(5) 10,284.45 90.25 116.25 4,097.57 4,050.07 -5,649.32 1,465.94 6,025,838.60 546,622.88 1.38 5,652.73 MWD+IFR2+MS+sag(5) 10,380.50 87.84 117.14 4,099.18 4,051.68 -5,692.46 1,551.74 6,025,795.99 546,708.92 2.67 5,732.01 MWD+IFR2+MS+sag(5) 10,475.93 84.37 118.89 4,105.66 4,058.16 -5,737.17 1,635.78 6,025,751.79 546,793.22 4.07 5,811.82 MWD+IFR2+MS+sag(5) 10,569.84 84.44 120.78 4,114.81 4,067.31 -5,783.67 1,716.85 6,025,705.80 546,874.57 2.00 5,891.76 MWD+IFR2+MS+sag(5) 10,664.25 85.49 122.52 4,123.10 4,075.60 -5,833.01 1,796.90 6,025,656.94 546,954.91 2.15 5,973.70 MWD+IFR2+MS+sag(5) 10,757.63 84.87 124.67 4,130.95 4,083.45 -5,884.50 1,874.40 6,025,605.94 547,032.72 2.39 6,056.27 MWD+IFR2+MS+sag(5) 10,852.65 85.24 126.62 4,139.14 4,091.64 -5,939.66 1,951.33 6,025,551.24 547,109.97 2.08 6,141.79 MWD+IFR2+MS+sag(5) 10,946.73 85.18 128.75 4,147.00 4,099.50 -5,998.97 2,025.52 6,025,494.39 547,184.50 2.26 6,227.85 MWD+IFR2+MS+sag(5) 11,041.50 85.98 131.10 4,154.30 4,106.80 -6,057.61 2,097.97 6,025,434.20 547,257.31 2.61 6,315.99 MWD+IFR2+MS+sag(5) 11,135.32 85.55 133.51 4,161.23 4,113.73 -6,120.58 2,167.17 6,025,371.66 547,326.88 2.60 6,404,59 MWD+IFR2+MS+sag(5) 11,230.00 86.79 132.58 4,167.55 4,120.05 -6,185.06 2,236.20 6,025,307.61 547,396.30 1.64 6,494.43 MWD+IFR2+MS+sag(5) 11,324.16 88.64 131.58 4,171.31 4,123.81 -6,248.11 2,306.03 6,025,244.99 547,466.50 2.23 6,583.41 MWD+IFR2+MS+sag(5) 11,418.27 89.75 130.66 4,172.63 4,125.13 -6,309.99 2,376.92 6,025,183.54 547,537.75 1.53 6,671.88 MWD+IFR2+MS+sag(5) 11,513.88 88.58 127.73 4,174.02 4,126.52 -6,370.40 2,451.00 6,025,123.59 547,612.19 3.30 6,760.60 MWD+IFR2+MS+sag(5) 11,605.07 89.88 124.86 4,175.25 4,127.75 -6,424.36 2,524.48 6,025,070.08 547,685.99 3.45 6,843.40 MWD+IFR2+MS+sag(5) 11,700.25 89.81 124.11 4,175.51 4,128.01 -6,478.25 2,602.93 6,025,016.67 547,764.77 0.79 6,928.54 MWD+IFR2+MS+sag(5) 11,794.97 89.44 124.40 4,176.13 4,128.63 -6,531.57 2,681.22 6,024,963.84 547,843.37 0.50 7,013.09 MWD+IFR2+MS+sag(5) 11,890.25 91.24 125.78 4,175.56 4,128.06 -6,586.34 2,759.18 6,024,909.55 547,921.65 2.38 7,098.76 MWD+IFR2+MS+sag(5) 11,984.24 92.29 126.47 4,172.67 4,125.17 -6,641.72 2,835.06 6,024,854.63 547,997.86 1.34 7,183.96 MWD+IFR2+MS+sag(5) 12/2/2015 8:10:59PM Page 5 COMPASS 5000.1 Build 73 • Halliburton • Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPL-48 Project: Milne Point TVD Reference: As-Built MPL-48 @ 47.50usft Site: M Pt L Pad MD Reference: As-Built MPL-48©47.50usft Well: MPL-48 North Reference: True Wellbore: MPL-48 Survey Calculation Method: Minimum Curvature Design: MPL-48 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 12,079.04 90,62 123.80 4.170.26 4,122.76 -6,696.25 2,912.55 6,024,800.57 548,075.67 3.32 7,269.19 MWD+IFR2+MS+sag(5) 12,173.19 91.73 123.20 4,168.33 4,120.83 -6,748.21 2,991.05 6,024,749.10 548,154.47 1.34 7,352.66 MWD+IFR2+MS+sag(5) 12,267.98 91.67 123.89 4,165.52 4,118.02 -6,800.56 3,070.01 6,024,697.23 548,233.75 0.73 7,436.70 MWD+IFR2+MS+sag(5) 12,361.94 91.85 123.38 4,162.63 4,115.13 -6,852.58 3,148.21 6,024,645.69 548,312.24 0.58 7,520.08 MWD+IFR2+MS+sag(5) 12,456.25 91.91 124.29 4,159.54 4,112.04 -6,905.07 3,226.50 6,024,593.69 548,390.85 0.97 7,603.91 MWD+IFR2+MS+sag(5) 12,550.11 90.93 124.17 4,157.21 4,109.71 -6,957.85 3,304.08 6,024,541.39 548,468.74 1.05 7,687.65 MWD+IFR2+MS+sag(5) 12,644.47 91.11 125.85 4,155.53 4,108.03 -7,011.97 3,381.35 6,024,487.74 548,546.33 1.79 7,772.43 MWD+IFR2+MS+sag(5) 12,738.76 90.43 128.03 4,154.28 4,106.76 -7,088.63 3,456.70 6,024,431.54 548,622.01 2.42 7,858.48 MWD+IFR2+MS+sag(5) 12,833.28 89.38 127.04 4,154.42 4,106.92 -7,126.21 3,531.65 6,024,374.42 548,697.31 1.53 7,945.16 MWD+IFR2+MS+sag(5) 12,927.65 90.86 127.19 4,154.22 4,106.72 -7,183.16 3,606.90 6,024,317.94 548,772.89 1.58 8,031.42 MWD+IFR2+MS+sag(5) 13,022.23 91,73 128.25 4,152.08 4,104.58 -7,241.00 3,681.69 6,024,260.55 548,848.03 1.45 8,118.25 MWD+IFR2+MS+sag(5) 13,116.57 91.23 129.01 4,149.65 4,102.15 -7,299.88 3,755.37 6,024,202.13 548,922.05 0.96 8,205.43 MWD+IFR2+MS+sag(5) 13,130.78 91.30 128.84 4,149.33 4,101.83 -7,308.81 3,766.42 6,024,193.28 548,933.16 1.29 8,218.59 MWD+IFR2+MS+sag(5) 13,212.00 91.30 128.84 4,147.49 4,099.99 -7,359.73 3,829.66 6,024,142.74 548,996.70 0.00 8,293.77 PROJECTED to TD brian.wheeler@halliburton...wme..,...,..,we..m„ Checked By: com °.,-=71,1:1==aa,m Approved By: Date: 12/2/2015 8.10:59PM Page 6 COMPASS 5000.1 Build 73 H • SCHEMATIC • PointUnitit Well: MP48 PTD:215-10 API: 50-029-23552-00-00 Hih orp:11u.»k.,1.,1A.. RKB:28.42' CASING DETAIL 20' `; t 1 Size Type Wt Grade Conn. ID Top Btm -t. .7:4,7, 20" Conductor 78.6 A-53 Weld 19.25" Surf 110' 9-5/8" Surf.Csg 47 L-80 TC II 8.681" Surf 6,538' I i: 5-1/2" Prod Liner 17 L-80 DWC/C HT 4.892" 6,316' 13,211' TUBING DETAIL 3-1/2" Tubing 9.2 L-80 EUE 8rd 2.992" Surf 6,364' kil ®�� 2 JEWELRY DETAIL No. Item Top MD Btm MD ID OD L:,,,4t 3 , 1 Tubing Hanger 28.42' 28.84' - - d 2 X Nipple 2,095.80' 2,097.42' 2.813" 4.493" I GE 3 Stage Tool—ES Cementer 2,382' 2,386' 8.618" 9.625" av .114 4 GLM w/sheer valve set @ 2500 psi 3,007' 3,016' 2.920" 4.500" ��® 4 5 PHL Packer 6,136' 6,144' 3.850" 8.450" 41 A 74 6 Ratcheting Muleshoe 6,363' 6,365' 3.500" 4.688" 4 7 Liner Top Packer 6,316' 6,338' 6.150" 8.290" 11 0 8 7"x 5-1/2"XO 6,343' 6,346' 4.860" 7.670" gtfil 1 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" 11 WIV Valve(Ball on Seat/Closed) 13,206' 13,209' - 5.000" ICD DETAIL Top(MD) Btm(MD) SWELL PACKER DETAIL 6,585.12' 6,604.95'11:41;i: Top(MD) Btm(MD) 6,847.85' 6,867.64' 7,400.11' 7,419.92' 7,668.16' 7,679.04' 4 8,002.69' 8,022.48' 8,903.09' 8,913.97' rFe 8,635.22' 8,655.00' 9,964.09' 9,974.97' low 9,113.24' 9,133.07' 10,867.31' 10,878.19' Ali it 9,734.18' 9,753.98' 11,842.73' 11,848.38' 11,042.97' 11,062.75' ' 11,582.98' 11,602.77' 12,055.48' 12,075.26' 12,604.17' 12,623.67' :11:,'. r 13,109.14' 13,128.94' ,t li 1,.: 9-5/8"shoe @ ' 6,538' ,,rCA �; 9 1ra1 1�1 11 1�1 ►�1 5-1/2"shoe ....,:tiN 13,211' M 5 02 A . N 1 0 ® IJ1 j1 N [1 11 PBTD=13,206'MD/4,147'TVD TD=13,212'MD/4,147'TVD Max Deviation:°94.83 Updated by CJD 12/11/15 ti OF Ty • THE STATEAlaska Oil and Gas of /\ SKA. Conservation Commission t. x 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALASI' Fax: 907.276.7542 www.aogcc.alaska.gov Luke Keller Drilling Engineer Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU L-48 Hilcorp Alaska, LLC Permit No: 215-120 Surface Location: 3287' FSL, 4759' FEL, Sec. 8, T13N,R10E,UM Bottomhole Location: 916' FSL, 492' FEL, Sec. 17, T13N, R10E, UM 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 2/- day of July, 2015. STATE OF ALASKA AIDA OIL AND GAS CONSERVATION COMMON JUL 13 2015 PERMIT TO DRILLr,r,f.., 20 AAC 25.005 t(1) 1 a.Type of Work: 1 b.Proposed Well Class: Development-Oil ❑ Service- Winj 0 • Single Zone y lc.Specify if well is,proposed for: Drill 1:11, Lateral ❑ Stratigraphic Test ❑ Development-Gay ❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redril ❑ Reentry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blantet ❑✓ . Single Well ❑ 11.Well Name and Number: Hilcorp Alaska,LLC ' Bond No. 022035244 , MPU L-48 3.Address: 6.Proposed Depth: 12. Field/Pool(s): 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 MD: 13,154' TVD: 4,127' ' Milne Point Unit . 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): r'4121 Schrader Bluff Oil Pool Surface: 3287'FSL,4759'FEL,Sec 8,T13N, R10E,UM,AK ADL 025515 SS Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 569'FNL,469'FEL,Sec 18,T13N,R10E, UM,AK N/A 9/7/2015 Total Depth: 9.Acres in Property: ,�; 14.Distance to Nearest Property: 2 916'FSL,492'FEL,Sec 17,T13N, R10E,UM,AK -264+— cu.?? 10,018'from 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-545122 y- 6031478 . Zone-4 GL Elevation above MSL: • 17 feet to Same Pool: --1,000'from L-46/47 16. Deviated wells: Kickoff depth: , 680 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 91 degrees Downhole: 1845 psi ' Surface: 1433 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) 42" 20" 78.6# A-53 Weld 80' 0 0 80' 80' 60 bbls of 15.6 ppg permafrost-C 12-1/4" 9-5/8" 40# L-80 TC-II 6,662' 0 0 6,662' 4,127' Stg 1 Lead-1302 ft3/Tail 470.3 ft3 Stg 2 Lead-1851 ft3/Tail 314 ft3 8-1/2" 5-1/2" 17# L-80 DWC/C HT 6,692' 6,462' 4,127 13,154' 4,127' u,/ jc,v . ,.(( ,A.c i(., 11:. Ctn+tr✓* . 7-rS-la" 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 TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat 0 BOP Sketch ❑ Drilling Program Li Time v.Depth Plot 0 Shallow Hazard Analyss❑ Diverter Sketch 0 Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requiremens0 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Luke Keller Email Ikeller(ahilcorp.com Printed Name Luk:y J ler / Title Drilling Engineer Signature Phone 777-8395 Date folly Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: ,6 I,) 50- L.,,Li — 351 --t, C c Date: -7 I ai I i 6 requirements. J 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 sr:❑ Other: 105� $,, cS .i Samples req'd: Ye;❑ Nv[ Mud log req'd:Y?L1 N 1h H2S measures: Ye;MI Mb❑ Directional svy req'd:Y*YrN� LS`Z' /`1 S` r-i it K..._ I '_-5 f Spacing exception req'd: Ye❑ M)7. Inclination-only svy req'd:hilj NG( +" C (SL M i 1-- 4 ✓s.c- 1 4 .,w,. o ter, ,� ❑�.�:v i �/ 14 icy f 013 ct APPROVED BY Approved by: r,// ! �L�— COMMISSIONER THE COMMISSION Date: 7 2...7—/5- , 1 (,S f f /Li i ) Submit Form and Form 10-401(Revised 10/2012) h' e s dor 4 onths from the date o appy val(20 AAC 25.005(9)) 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 Hilcorp Alaska,ld.f. July 8th, 2015 RECEIVED Commissioner JUL 13 2015 Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue AOGCC Anchorage, Alaska 99501 Re: MPL-48 Dear Commissioner, MPU L-48 is a grassroots water injector planned to be drilled in the Schrader Bluff OA sand. L-48 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 the water injection strategy. Drilling operations are expected to commence approximately Sept 7th, 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 Area of øiew — Proposed MPL-48 Injlion Well Prior to completion of the MPL-48 Schrader Bluff OA injection well, an Area of Review (AOR) must be conducted. This AOR found one other well, MPL-45, that enters the SB OA within1/4 mile of MPL-48's proposed lateral. 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-48 TBD 0' 9-5/8 casing to be cemented from injection zone to surface per drilling program page 22-26. MIT-IA of 3- 1/2" by 9-5/8" annulus to be completed to 1500 psi. " MPL-45 198-169 1025' Packerless monobore ESP. 5.5" casing cemented to surface. No known integrity issues. MPL-46 TBD TBD Will submit post completion MPL-47 TBD TBD Will submit post completion Table 2: Completion Detail Well Name Casing Size Hole Size Vol Cement(bbls) Schrader Bluff OA Depth (MD) MPL-48 9-5/8" 12-1/4" ^'701.5 6,661' MPL-45 5-1/2" 7-7/8" 352 7808' MPL-46 9-5/8" 12-1/4" ^'686.3 6,578' MPL-47 9-5/8" 12-1/4" 780.3 7,700' MPL-48 AFE No. Well Nance: KB: 30 ft ADA. 1511125 Milne Point Unit(MPU)L-41 GL a RK9 lift*30 R—47 tt API* IPI, AFE WELLBORE DESIGN Proposed TO: 13,154' Penne No. T7T Proposed TMG: 4,12T G.ologw Information Wenbure Information Casing info.,Mud Into/Hole Size I Camant Specs bYd.Pgatam SS TVD FM LKlwlogy Conductor a RKB-Tubing Hanger 34"a 20"Insulated conductor(Pm-set)to SD BOL(110'RKB) Interval: 1 Inner slave'20"x 0.375-Wall 78.6*.A-53.ERA.PE SwtSa!role Exterior Jacket.34".O 344'Wall.1231.A-139.Gretle B.pital.PE MW Twa: L Fresh Water/News Surface Cooing Weigh.Ralg.: ;.,_,I n g 93/8"400 L-80 TC-II set at 6602'MO i 412T TVD 8.8-9.2 & E E B 1 Surface Casing Cement TS 101 Stage: 3'i 60 bels 10.5 ppg Tuned spacer 111 IS 2 Lead:0016 ON Excess)ARCTICCEM @ 10.7 ppg I3 Tail:(30%ON Excess)SWIFTCEM 15.8 prig j A 2nd stave :750' tr ted LO N 10.5 pa Tuned spacer 10 a .- Lead:(Unf(.rums et surface)ARCTICCEM 10 7 PF9 IP'.— Stage Tail:SWIFTCEM 15.8 ppg 0 1 Collar t A Production Liner -o$ S-12-170 LAO DWC/C HT liner A 11.1541 MD r 4.127'TVD c0 Yr Y`'5 i Injection Tubing B.t' 3-12-9.3*L-80 81,415 EUE .1`S a i m IlL jr 35001 t-sane, Coarse sand,silty shale better Liner Top Pkr:6462)1 Injection Control Devices Inter V GN V developed nin " P T/ lion Hoie t-sands intervening of a shales Mud Trp PA-sands the L d M ------- -- - 78'0:::::N -b00 M �J -_ " — N sands C e ae ring as o a LV g ft Se. Schrader Ue o 0 0 0 ? 0 $ `��pc9 o.and. condensed with our o Num cos armsT� Injection Packer Swell Pkrs 5-1/2"Injection Uner • 0 . MPL-45 • Tree: 2 1/16"5M Gray MPU L-45 Orig. DF Elev.= 56.61' (N 27E) Wellhead:7 1/16"5M Gray Orig. GL Elev. = 16.70' Tbq. Hilo: 2 3/8"x 7" Gray w/2 3/8" i[ 1 DF csg. hng.=39.91'(N 27E) eue 8rd T&B/ 2" CIW H BPV profilei I . 7"26#/ft L-80 i a 37' 7"x 5.5"X-Over 20" 91.1 ppf, H-40 115' 4 Camco 2 3/8"x 1" KOP @ 600' sidepocket KBMM GLM 170' Max. hole angle=98 deg.@ 9,140' (ID.1.945") Hole angle thru perfs 1 O 5.5" Port Collar Cementer 1,009' and 2 3/8"4.70"ppf,J-55, 8 rd EUE tbg.. i i Camco 2 3/8"x 1" (drift ID =1.995",cap. =0.00387 bpf) 1 3,446' 4 sidepocket KBMM GLM } i (ID.1.945") 5.5" 15.5 ppf, J-55, Btrc. prod.casing 1'; (drift ID =4.950",cap. =0.0238 bpf; 4 I2-3/8"HES XN-Nipple(1.791"id) 3,461' Centrilift heat trace 3,500' f 1 KUDU 100TP1800 PCP, 7,115' IP Centrilift flex shaft intake tvd 3,985' Centrilift seal section fstbdbilpfsaflashsni7,151' Centrilift FMH series, 54 hp motor, 1020 v./35 7,163' l amps.[9:01 Gear Box I Centrilift PHD 7,174' 5.5"float collar 7,261' and 1')p //� Baker 5.5"x 3.5"C-2 setting sleeve 7,212' 5.5'float shoe 7,343'and h. Liner Hanger Top TVD=3982' 3.5"9.3#/ft slotted liner 7,789'-9,301' Mid-pert MD=8545' 90 deg.+ at various places from 7,656'to pbtd Mid-pert TVD=4074' 4053'TVD .1411. Baker Float shoe 9,363' DATE REV.BY COMMENTS MILNE POINT UNIT 09/28/98 KJW Drilled and ESP Completion Nabors 27 WELL L-45 API NO: 50-029-22913 MPL-46 • III AFE No. Well Name: KB: 30 ft AGL 1511124 Milne Point Unit(MPU)L-46 GL RKB 17 ft+30 ft=47 ft API# AFE WELLBORE DESIGN Proposed TD: 13,193' Permit No. Proposed ND: 4.148' Geologic Information Weft=Information Casing Info I Mud Into/Hole Size/Cement Specs Mud Program SS TVD FM LlUwlogy Conductor a«e-ru sH,"eH 34"x 20"Insulated conductor(Pre-set)to 80'BGL(110'RKB) Inaerrat: 1 tic Inner sleeve:20"x 0375'Wall 78.68,A-53,ERW,PE Surface hate • m Exterior Jacket:34"x 0.344"Wall,123#.A-139.Grade 8 spiral.PE Mand Type. E 2 Fresh WetertNaae a= Surface Casing We�tttRange: • E `a 9.58"40#L80TC 11 set at 6585'MD14148'ND 8.8-82 q o c E E `- ✓ Surface Casing Cement 3 1st Stage a. d n 60 bbls 10.5 ppg Tuned spacer III 4 mirl Lead:(50%OH Excess)ARCTICCEM©10.7 ppg N a Tail:(50%OH Excess)SWIFTCEM 15.8 ppg c 3 a O a 2nd stage: 1750' • 60 bbls 10.5 ppg Tuned spacer III • Lead:(Until rehtms at surface)ARCTICCEM 10.7 ppg s If Tail:SWIFTCEM 15.8 ppg o2� a} ` Production Liner v o« 5.112"1781-80 DWGC HT Slotted liner TS 13.193'MD/4.148'TVD 2 A L t Y i % Tieback E z .w 7.5/8"29.7#L-80 SLIJ-II 4�6385'MD/4148'TVD re> jog re N w c o M Production Tubing `^ o � 2-718"6.4#L-80 8RD EUE 1,4 N n 5oc v C p p M 6 t, . . O -3500` uo 3 T d K-sands Coarse sand,silty shale,better ESP !parva: UGNU developed Bullet Scat tibProduction.Hole L-Sands intervening shales Slotted liner Mud Type .4004m-sands in the l and M J Baradril-N N-sands Continued layering as g/ -- Weiam Rance: S[hrcdet in Ugnu,more L9-92 pop 0-sandscondensed with ac 1111 _4300' coal Liner Top Packer 6385'MD • III MPL-47 AFE No. Well Name: KB: 30 ft AGL 1511125 Milne Point Unit(MPU)L-47 GL+RKB 17 ft 1.30 ft=47 ft API* T00 AFE WELLBORE DESIGN Proposed TO: 13.002 Permit No. TOD Proposed TVD: 4,06T Geologic Information Wellbore Information Casing Info i Mud Info!Hole Sae:Cement Specs Mut frOKIIM SS TVD FM Lithology Conductor 13-3/8"conductor(Pre-set)to BO'BGL(110'RKB) Interval' 1 Surface hate Tc' Surface Casing Mud Type: E $ 9-5r8 400 L-89 TC-II set at 7.941'MD!4,088'TVD Fresh WateRNative H .d Weight Range. E g Surface Casing Cement 8.8-92 1st Stage: E `> ' - r': ;} 60 bbls 10.5 ppg Tuned spacer III a 3 ' '4 Lead:)30%0H Excess)ARCTICCEM @ 10.7 ppg a y• 5 Tail:(30%OH Excess)SW IFTCEM 15.8 ppg M 2nd stage: ck.'7 : 60 bbls 10.5 ppg Tuned spacer III v y • a ) Lead:i0n1a returns at surface)ARCTICCEM 10 7 ppg 1750' w TdIF.SWIFTCEM 15.8 ppg a r 2 Stale.; ... 2500' Production Liner E B' 5-U2-178 L-80 DWC1C HT Slotted liner'35 13.002'MD,'4,007'TVD ra • a' v o.� '4 Tieback ri I.:3 0 2 7-5'8-29.70 L-90 SLIJ-ll fEp 7741'MD 1 4,088'TVD 0-3 c 'c• .a~ S Production Tubing i 8h, 2-7'8-640 L-60895 EOE m o a a it c a Liner Top Packer fp i — - ' 7741'MD 053. $4 u '3500' 3 K-sands Coarse sand,silty shale,better ESP Interval. UGNU developed gullet Seal Assy Slotted finer Production Hole t-Sands Intervening shales Mud Type. -4DC0' M-sands in the Land M &.ore e-N N-sands Continued layering as /,It _ � Weight Range: Schrader in Ugnu,more s — — � � � J a 89-5.2 p,g 0-sands condensed with oce. -4300' coal i 0 • L-(1 L-12 L-42 • Prop L-49 n 0000, 4116 / Prop LA Prop L. -37 i_ \ Prop L-47 l 37A PropL- .\114• NINIlb` 111411444,4 0000 ,malms.' 1441. r i 1 LIHILCORP ALASKA LLC , _ - NS. \ MILNE POINT FIELD - / AOR MAP N.44..Proposed MPL-48 Irjeclor 0 1,139 2,270 1 FEET WELL SYMBOLS A• Active aY CSA A ,N.,WO I'Naler Flaodi I PCACt ryelt,Localon P'odaer Lacaton REMARKS Wall Symbol dl top ol SCtlratler OA Sand Ealsllno perR In OA SAM hlphllphled pots Mac*Dash Circle-132P radius Irani proposed OA lop(heel)and TO Itoel In MM.-15 Jdy 9.:0'.3 Schrader Bluff OA Map Illustrating AOR • Hilcorp Alaska, LLC Milne Point Unit (MPU) L-48 Drilling Program Version 1 June 30th, 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 22 14.0 BOP N/U and Test 27 15.0 Drill 8-1/2" Hole Section 28 16.0 Run 5-1/2"Production Liner 32 17.0 Run ESP assy. 35 18.0 RDMO 35 19.0 Diverter Schematic 36 20.0 BOP Schematic 37 21.0 Wellhead Schematic 38 22.0 Days Vs Depth 39 23.0 Formation Tops 40 24.0 Anticipated Drilling Hazards 41 25.0 Nordic#3 Rig Layout(Drillers Side) 43 26.0 Nordic#3 Rig Layout(Well End&Top View) 44 27.0 FIT Procedure 45 28.0 Choke Manifold Schematic 46 29.0 Casing Design Information 47 4-6 ,3i.0 8-1/2"Hole Section MASP 48 31.0 Spider Plot(NAD 27)(Governmental Sections) 49 32.0 Surface Plat(As Built)(NAD 27) 50 33.0 Offset MW vs TVD Chart 51 34.0 Drill Pipe Information 5" 19.5#S-135 DS-50 52 • • Milne Point Unit L-48 Drilling Procedure Hilcorp Energy Company 1.0 Well Summary Well MPU L-48 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 13,154' MD/4,127' TVD PBTD, MD/TVD 13,144' MD/4,127' TVD Surface Location(Governmental) 3,287' FSL,4,759' FEL, Sec 8, T13N, R10E, UM,AK Surface Location(NAD 27—Zone 4) X=545,122, Y=6,031,478 Surface Location(NAD 83) Top of Productive Horizon (Governmental) 569'FNL, 469' FEL, Sec 18, T13N, R10E, UM,AK TPH Location(NAD 27) X=544168.5,Y=6027616.9 TPH Location(NAD 83) BHL(Governmental) 916' FSL,492' FEL, Sec 17, T13N, R10E, UM,AK BHL(NAD 27) X=549461.43,Y=6023855.64 BHL(NAD 83) AFE Number 1511126 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) 1433 psig Maximum Anticipated Pressure (Downhole/Reservoir) 1845 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 July, 2015 ! ! Milne Point Unit L-48 Drilling Procedure Hilcorp Energy Company 2.0 Management of Change Information Hilcorp Alaska, LLC Hilcorp Emma Company Changes to Approved Permit to Drill Date: Subject: Changes to Approved Permit to Drill for MPU L-48 File#: MPU L-48 Drilling and Completion Program Any modifications to MPU L-48 Drilling& Completion Program will be documented and approved below. Changes to an approved APD will be communicated to the BLM and AOGCC. Sec Page . Date Procedure Change Approved Approved By By Approval: Drilling Manager Date Prepared: Drilling Engineer Date Page 3 Version 1 July, 2015 • • Milne Point Unit L-48 Drilling Procedure Hilcorp Energy Company 3.0 Tubular Program: Hole OD (in) ID (in) Drift Conn Wt Grade Conn Burst Collapse Tension Section (in) OD (in) (#/ft) (psi) (psi) (k-lbs) Cond 20" 19.25" - - 78.6 A-53 Weld 12-1/4" 9-5/8" 8.835" 8.75" 10.235" 40 L-80 TC-II 5,750 3,090 916 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 July,2015 • . Milne Point Unit L-48 Drilling Procedure Hilcorp Enwgy 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 lkeller@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 jiwatson@hilcorp.com Drilling Tech Cody Dinger 907.777.8389 509.768.8196 cdinger@hilcorr.com Page 5 Version 1 July,2015 • Milne II Drilling ProcedurePointUnitL-48 HIlcorp Energy Company 6.0 Planned Wellbore Schematic AFE No. Well Name: KB: 30 ft AGL 1511128 Milne Point Unit(MPU)L-48 GL+RKB 17 ft+30 ft=47 ft API8 AFE WELLBORE DESIGN Proposed TD: 13,154' Permit No. Proposed TVD: 4,127' Geolog;c Information '.Je lbore Infc•maticn Casing Info i Mud Info 1 Hole Size I Cement Specs Mud Program SS TVD FM Lithology Conductor RKB-Tubing Flange' 34"x 20"Insulated conductor(Pre-set)to B0'BGL(110'RKB) Interval: 1 'e .-_- Inner sleeve:20"x 0.375'Wall 786 1.A-53.ERW,PE Surface hole c '� Exterior Jacket:34"x 0.344'Wall.1238.A-139,Grade B spiral.PE Mud Type: 1 Fresh Wateo'Nab''e N L . Surface Casing Weight Range: 9-518"408 L-80 TC-ll set at 6662'MD 14127'TVD 8.8-9.2 o og NE R . S Surface Casing Cement $ tat Sage: ci a it ' 60 bbls 10.5 ppg Tuned spacer III '9 o `a Lead:(30%OH Excess)ARCTICCEM @ 10.7 ppg c q Tail:(30%OH Excess)SWIFTCEM 15.8 ppg c E S /3 q 2nd stage: 1750' V 60 bbls 10.5 ppg Tuned spacer III a Lead:(Until returns at surface)ARCTICCEM 10.7 ppg L o n m le._ Stage Tail:SWIFTCEM 15.8 ppg e a, I:: Collar 0 n 1," roduction Liner a o 5-112-178 L-80 DWC1C HT liner;@ 13,154'MD 14,127'TVD x c 6 y: ac FL', c Injection Tubing c • g 3-112-9.38 L-80 8RD EUE r- ti m.1= - c u g k,r▪ o3 a o m 4/ L p ' 2 4, a E O 'E- -0 o 7^ — yuy C O 8 3500 c .u 3 ,O._ tsands Coarse sand,siltyLiner Top Pkr:6462ft Injection Control Devices shale,better Interval: UGNU developed .-^-,�" Production Hole 1-Sands intervening shales - r, Adak Mud TWe: -4000' M-sands in the L and M Baradril.N N-sands Continued layering as -. o 0 o 0 a o Weight Range: scMader in Ugnu,more ... o V q G c7 8.9-9-2 ppg 0-sands condensed with occ. - r' .. coal `-, 4300' ,.��._-� _. Injection Packer Swell Pkrs 5-1/2"Injection Liner Page 6 Version 1 July, 2015 • • Milne Point Unit L-48 Drilling Procedure Hilcorp Energy Company 7.0 Drilling / Completion Summary MPU L-48 is a grassroots water injector planned to be drilled in the Schrader Bluff OA sand. L-48 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 the water injection strategy. Drilling operations are expected to commence approximately Sept 7th,2015. Nordic Calista Rig#3 will be used to drill and complete the wellbore. Surface casing will be run to 6,662' MD/4,127' 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 will be hauled to the Milne Point G&I facility located on"B"pad. / 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 July, 2015 Milne Point Unit L-48 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-48. 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 July,2015 • • Milne Point Unit L-48 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: iim.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 July, 2015 • •Milne Point Unit L-48 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 July,2015 ID •Milne Point Unit L-48 Drilling Procedure Hilcorp Energy 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 Drawin: 1 •-4---)..__-'_:•1.--Z--) _ _ -- — —— , �.,} 1 i _t . I _ N II i ir_�J 1 ii __ -f in --L —I a— I LA, 111-- 1L. rL-59 rt-40 FL-0 L— -_ ' I� — ' `�� I ' l ,h inter� a /IC-- ii — I I II MI., i .,, ..uIl i II- -- Page 11 Version 1 July, 2015 . Milne Point Unit L-48 Drilling Procedure Hilcorp Energy Company 10.6 Ri: &Diverter Orientation on"L" sad: 1 1 L-49 1i� 1I-L-SU 1 L 4$ L.-4c, - it 1 I Idly ! I 1 , I 1C in Diverter Line I yilw �ti — g 1 i E It. i/ I■ 41-11 1 -i1 i Page 12 Version 1 July, 2015 • Mime Point Unit L-48 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. • 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 DATA4111111111 411==1.11111110 Item ID Stiff ID Gauge Weigh Top erigth Total Location Description , (in) ) (in) (in) (Ibpf) nneeti {ft) (ft) (ft) Tricone 8.000 3.000 12.250 147.22 P 6-5/8"REG 1.10 ©8"SperryDrill Lobe 4/5-5.3 stg 8.000 5.000 5.000 103.09 B 6-5/8"REG 31.47 32.57 Stabilizer 12.125 4.28 ©Float Sub 8.000 2.880 2.880 149.10 B 6-5/8"REG 2.40 34.97 0 Stabilizer 8.000 3.000 3.000 10.250 147.22 B 6-5/8"REG 6.00 40.97 35.97 ©8"DM Collar(Directional) 8.000 3.500 3.544 147.40 B 6-5/8"REG 9.20 50.17 6 8"DGR Collar(Gamma) 8.000 1.920 4.997 142.70 B 6-5/8"REG 4.55 54.72 Q 8"EWR-P4 Collar(Resistivity) 8.000 1.985 5.205 151.00 B 6-5/8"REG 12.19 66.91 8 8"PWD(Pressure ECDs) 8.000 1.920 4.760 143.40 B 6-5/8"REG 4.44 71.35 9 8"HCIM Collar(Processor) 8.000 1.920 4.309 149.90 B 6-5/8"REG 4.97 76.32 10 8"POS PULSER(Telemetry) 8.000 4.000 4.257 145.20 B 6-5/8"REG 15.44 91.76 III Orienting Sub UBHO 8.000 2.875 3.000 149.18 B 6-5/8"REG 2.50 94.26 ®NM Flex Collar 8.000 2.813 150.13 B 6-5/8"REG 31.00 125.26 ®NM Flex Collar 8.000 2.813 150.13 B 6-5/8"REG 31.00 156.26 m NM Flex Collar 8.000 2.813 150.12 B 6-5/8"REG 31.00 187.26 8jts x 5"X 3"HWDP#49.3-NC50(IF) 5.000 3.000 49.30 240.00 427.26 16 Jar 7.500 2.813 2.813 129.38 B 4-1/2"IF 35.00 462.26 12jts x 5"X 3" HWDP#49.3-NC50(IF) 5.000 3.000 49.30 360.00 822.26 822.26 Page 13 Version 1 July,2015 • Milne Point Unit L-48 Drilling Procedure Hilcorp , Energy Company 11.3 Primary Bit: 12-1/4" (311mm) QHC1GRC ry PRODUCT SPECIFICATIONS . ., IADC Code 117W Total Tooth Count 67 Gage Row Tooth Count 39 e. V711, Journal Angle 33° Offset(1116") 6 Jet Nozzle Types Standard 83244 Extended 302447 Center Jet (If Center Jetted)501813 T.J.Connection 6-5/8"(API Reg.) Recommended Make-Up Torque' 28000132000 Felbs. Bit Weight(Boxed) 250 Lbs.(113 Kg.) Bit Breaker (Mat.#/Le ac #) 515353/506463 PRODUCT FEATURES '�' ',y' ▪ New patented Diamond'Claws tooth bit design. • Tungsten carbide'surf inserts in gage teeth for added gage X4. 4 protection. • Newly formulated,proprietary hardfacing on cutting structure and gage maximizes carbide and diamond volume for ultimate wear .. resistance. ▪ Raised tungsten carbide inserts and proprietary hardfacing provides maximum arm protection in abrasive and directional applications while minimizing drill string torque. . QuadPacklt 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. C 2014 Halliburton.All rights reserved.Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. 11.4 5" Workstring, HWDP, and Jars will come from Weatherford. 11.5 Begin drilling out from 20" conductor at reduced flow rates to avoid broaching the conductor. 11.6 Drill 12-1/4" hole section to 6,662' MD/4,127' TVD. Confirm this setting depth with the geologist and Drilling Engineer while drilling the well. ✓ Page 14 Version 1 July,2015 • Milne Point Unit L-48 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. i crit_ • Efforts should be made to minimize dog legs in the surface hole. ES�uipment 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 July, 2015 j • • Milne Point Unit L-48 Drilling Procedure Hilcorp Energy Company 11.7 12-1/4"hole mud program summary: • Density: Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system(1)ppg above highest anticipated MW. We will start with a simple gel + FW spud mud at 8.8 ppg. • PVT System: MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. • Rheology: Aquagel and Barazan D+ should be used to maintain rheology. Begin system with a 75 YP but reduce this once clays are encountered. Maintain a minimum 25 YP at all times while drilling. Be prepared to increase the YP if hole cleaning becomes an issue. • Fluid Loss: DEXTRID and/or PAC L should be used for filtrate control. Background LCM(10 ppb total)BARACARBs/BAROFIBRE/STEELSEALs can be used in the system while drilling the surface interval to prevent losses and strengthen the wellbore. • Wellbore and mud stability: Additions of CON DET PRE-MIX/DRIL N SLIDE are recommended to reduce the incidence of bit balling and shaker blinding when penetrating the high-clay content sections of the Sagavanirktok and the heavy oil sections of the UGNU 4A. Maintain the pH in the 8.5—9.0 range with caustic soda. Daily additions of ALDACIDE G/X- CIDE 207 MUST be made to control bacterial action. • Casing Running: Reduce system YP with DESCO as required for running casing as allowed (do not jeopardize hole conditions). Run casing carefully to minimize surge and swab pressures. Reduce the system rheology once the casing is landed to a YP<20 (check with the cementers to see what YP value they have targeted). System Type: 8.8—9.2 ppg Pre-Hydrated Aquagel/freshwater spud mud Properties: Depths Density / Viscosity Plastic Viscosity Yield Point API FL pH 80-6662' 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 July, 2015 S fl Mime Point Unit L-48 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 July, 2015 "° • SMilne Point Unit L-48 Drilling Procedure Hilcorp Energy Company Bypass Baffle This end up. NON 1(� • (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 July, 2015 ,� • • II Milne Point Unit L-48 Drilling Procedure Hilcorp Energy Company 12.6 Float equipment and Stage tool equipment drawings: "A Ove*all Length 1 1 Type H ES Cementer B Part Na. M n.ID After 0-,Bout SO No. C Mao.`col CD e o i' D Hilcorp ES-II Running Order E'a" iOpeni:^+a Sear C _ A - Closing Sleeve No.Shear Pins E , ^: Closing Seat'D '� D 11 Opening Sleeve No.Shear Pins Plug Set ES-II Cementer ES Cementer Part No. 3 Depth I SO No. ____---- — 11 t J Closing Plug 1 i ,1 l r Baffle Adapter(if used) ��.1 OD Snot orf Plug ID Doering 9 Pl t+9 ■ D�� ^ OD Baffle Adapter - OD I 11 Bypass or Shut-off Baffle -°! ! By-Pass Plug -. Depth Shut-off Plug Float Collar -- ir .41 Depth By Pass Baffle fl 1 OD Float Collar n Float Shoe Depth Bypass Plug (if used) Hole TD Float Shoe "Reference Casing WOD Sales Manual Section 5 Page 19 Version 1 July, 2015 •Milne Point Unit L-48 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 2400' MD/2080' 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 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. Page 20 Version 1 July, 2015 • Milne Point Unit L-48 Drilling Procedure Hilcorp Energy Company Technical Specifications Connection Type: Slze(O.D.): Weight (Wall): Grade: TC-II Casing 9-5/8 in 40.00 lb/ft(0.395 in) L-80 standard Material L-80 Grade 80.000 Minimum Yield Strength (psi) 4011MINIMMIWUSA 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:713-479-3200 8.835 Nominal Pipe Body I.D.(in) Fax:713-479-3234 0.395 Nominal Wall Thickness (in) E-mail.VAMUSAsalescii2vam-usa.com 40.00 Nominal Weight (lbs/ft) 38.97 Plain End Weight (lbs /ft) 11.454 Nominal Pipe Body Area (sq in) Pipe Body Performance Properties 916.000 Minimum Pipe Body Yield Strength (lbs) 3.090 Minimum Collapse Pressure (psi) 5.750 Minimum Internal Yield Pressure (psi) 5.300 Hydrostatic Test Pressure (psi) Connection Dimensions 10.235 Connection O.D. (in) 8.835 Connection I.D. (in) 8.750 Connection Drift Diameter(in) 5.23 Make-up Loss (in) Connection Performance Properties 916.000 (1) Joint Strength (lbs) 16.360 Reference String Length (ft) 1.4 Design Factor 916.000 Compression Rating (lbs) 3.090 Collapse Pressure Rating (psi) 5.750 Internal Pressure Rating (psi) 38.1 Maximum uniaxial bend rating [degrees/100 ft] Recommended Torque Values 11.600 (2) Minimum Final Torque (ft-lbs) 13.600 (2) Maximum Final Torque (ft-lbs) 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 21 Version 1 July, 2015 • Milne Point Unit L-48 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: ;t rl ` 3 I.<<: Section: Calculation: Vol(BBLS) Vol(ft3) 12-1/4" OH x 9-5/8" Casing (5600'- 2400') x .0558 bpf x 1.3 = 232 bbls 1302 ft3 annulus: Total LEAD: 232 bbls 1302 ft3 } `y 12-1/4" OH x 9-5/8" Casing (6662'- 5600')x .0558 bpf x 1.3 = 77 bbls 432 ft3 annulus: 9-5/8" Shoe track: 90 x .0758 bpf = 6.8 38.3 Total TAIL: 83.8 bbl 470.3 ft3 • • Milne Point Unit L-48 Drilling Procedure Hilcorp Energy Company Cement Slurry Design (both rt and 2"a stage cement jobs): 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: . 4 130'- 6572' x .0758 bpf=268.7 bbls mud, 80 bbls water, 142 bbls mud The 80 bbls of water must be left across stage ool 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. 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. Page 23 Version 1 July, 2015 • • Milne Point Unit L-48 Drilling Procedure Hilcorp Energy Company 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 24 Version 1 July, 2015 • Milne Point Unit L-48 Drilling Procedure Hilcorp Encs 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: ksisA i.t( 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 (1900'- 110')x .0558 bpf x 3 = 300 bbls 1684 ft3 annulus: Total LEAD: 329.7 bbls 1851 ft3 143` 12-1/4" OH x 9-5/8" Casing (2400'- 1900') x .0558 bpf x 2 = 56 314 ft3 annulus: Total TAIL: 56 bbls 314 ft3 Y 7� 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: 2400' x .0758 bpf= 182 bbls mud/ Page 25 Version 1 July, 2015 • Milne Point Unit L-48 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 26 Version 1 July,2015 rMilne Point Unit L-48 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 27 Version 1 July, 2015 • Milne Point Unit L-48 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. ,i 15.2 8-1/2"BHA (Includes GR+Res+ADR LWD components & PWD): COMPONENT DATA Item OD Stift ID Gauge Weight Top Length Total Location Description Connection (in) (in) (in) (Ibpf) (ft) (ft) (fk) 11111 PDC 6.750 2.500 8.500 105.23 CM= 0.80 ©7'SperryDnll Lobe 718-6.0 stg 7.000 On 4.952 NMI 93.13 B 4-1/2"IF 27.38 28.18 11111.1 IIII Stabilizer III. 8.375 3.47 El Float Sub 6.750 2.813 2.813 100.77 n 2.00 30.18 ®6 314"DM Collar(Directional) 6.750 3.'25 3.155 103.40 P 4-112"IF 9.20 39.38 Inline Stabilizer{ILS) 6.750 1.920 1.920 8.375 112.09 B 4-112"IF 2.00 41.38 40.03 0 6 314"ADR Collar(Resistivity) 6.750 1.920 i�•'•'� 109.40 B NC 50 I= 65.72 ©6 314"DGR Collar(Gamma) 6.750 1.920 4.430 97.80 B 4-112"IF 4.46 70.18 ICI 6 3/4"PWD(Pressure ECDs) 6.750 1.905 IT= 112.24 c ► 4.44silo En 9 6 314"HCIM(Processor) 6.750 1 920 3.667 112.09 4.97 79.59 10 CISMICEINIII - 6.750 3.250 3.551 99.16 =Mg= 94.85 ®NM Flex Collar 6.750 2.813 100.77 B 4-112"IF 31.00 125.85 ®NM flex Collar 6.750 2.813 100.77 B 4-112"IF 31.00 156.85 ®NM Flex Collar 6.750 2.813 100.77 B 4-112"IF 31.00 187.85 3xJts 5"X 3'HWDP-4.51F 5.000 3.000 42.83 ® 93.00 280.85 ®Jar 6.250 2.250 2.250 91.01 B 4-1/2"IF 33.00 313.85 14Jts 5"X 3" HWDP-4.51F 5.000 3.000 42.83 420.00 g_ 733.85 Page 28 Version 1 July, 2015 • Milne Point Unit L-48 Drilling Procedure Hilcorp Energy Company 15.3 Primary Bit: 8-112" (216mm) SFE56 PRODUCT SPECIFICATIONS Cutter Type X2-Tough Drilling IADC Code S424 Body Type STEEL Total Cutter Count 29 le 111116 4f4Cutter Distribution mm 19mmi I3 Face 0 19 Gauge 10 0 Number of Large Nozzles 5 s dr 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 Junk Slot Area(sq in) 20.81 t alb' Normalized Face Volume 73.86% API Connection 4-1/2 I.F.PIN Recommended Make-Up Torque' 23.743 Ft'Ibs. Nominal Dimensions" Make-Up Face to Nose 8.31 in-211 mm 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 120Lbs.-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 29 Version 1 July, 2015 • SMilne Point Unit L-48 Drilling Procedure Hilcorp Energy Company • Rheology: Keep viscosifier additions to an absolute minimum (N-VIS). Data suggests excessive viscosifier concentrations can decrease return permeability. Do not pump high vis sweeps, instead use water or low vis sweeps. • Run the centrifuge continuously while drilling the production hole, this will help with solids removal. • Dump and dilute as necessary to keep drilled solids to an absolute minimum. • MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, & Toolpusher office. System Type: 8.9—9.2 ppg Baradrill-N drilling fluid Properties: Depths Density Plastic Viscosity Yield Point Total Solids MBT HPHT pH 6662- 13154 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% 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 30 Version 1 July, 2015 • • Milne Point Unit L-48 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. 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. • 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 31 Version 1 July,2015 r •i Milne Point Unit L-48 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 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 32 Version 1 July, 2015 i Milne Point Unit L-48 Drilling Procedure Hilcorp Energy Company Technical Specifications Connection Type: Size(O.D.): Weight(Wail): ©rads: DWCIC-HT Casing 5-112 in 17.00 lb/ft(0.304 in) L-80 standard Material L-80 Grade 80.000 Minimum Yield Strength (psi) 11111111111111MMIIMVUSA 95.000 Minimum Ultimate Strength (psi) VAM USA 4424 W.Sam Houston Pkwy.Suite 150 Pipe Dimensions Houston.TX 77041 0Q 5.500 Nominal Pipe BodyO.D. (1n) Fax:713-479-3234 4.892 Nominal Pipe Body I.D.(in) E-mat:VAMUSAsalesvam-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(%) 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) 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 33 Version 1 July, 2015 Milne Point Unit L-48 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 34 Version 1 July, 2015 • • Milne Point Unit L-48 Drilling Procedure Hilcorp Energy Company 16.21. Bleed DP pressure to zero, close BOP and test annulus to 1500 psi for 30 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. 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 35 Version 1 July, 2015 • • Milne Point Unit L-48 Drilling Procedure Hilcorp Energy Company 19.0 Diverter Schematic ruu-111 4131.01 If \ 1 Schaffer 21-114" �J 2M Annular O Y IIt. 21-1.4"2M Riser--- [I _ 18"Full Opening Knife Valve ii". RI 1111 fgatti aqua WI LW / Diverter"T' 3 16"Diverter Line I nae WI 1111 ni YIBM Y r{a YM 21-1/4" Spacer Spool ix III an as fr■at 16-314"3M x 21.1/4"2M DSA i\ i\ Seaboard Casinghead,S-22-AP-8 16"SOW x 16-314"3M; (2)ea 2.1116"5M studded outlets 20"C:avii y Page 36 Version 1 July, 2015 • • II Milne Point Unit L-48 Drilling Procedure Hilcorp Energy Company 20.0 BOP Schematic / I \ J 1 & 0 Hydril Annular \\\ BOP 11"x5M mica nirmork 1 41121..m am alum r-, ��Shaffer 11" x 5ti1U'HIT' ip 4-n ; , t')0�.' +-- ❑ ❑ ani — LI1 c I WM NV iv iv n 7-3"x 5M HCR 111 41#1.4k II r I �. .'' 'AOr It t:. : iii [ —Choke Line Kill Line 1110,,n a� i Y 3"x 5M Manual Gate Valve L.rY Y _€ t Hydril 11"x 5M a — -----€ 0'L 0 1 1. LYY YYY AA AtiA �`�"-"11"x5M ,n ,_i 9-518"DBL D Seal A ,i.►.��,` . iiri i 2-1116"x5M Casing Hanger .11 al 1E e�1 16-314"x 3M SMB-22 ''1110. 16-314"MOM - 9-5/B"BTC Btm x 2-1116"x 5M 10.5"-4 SA Pin Top W1 Primary Sea 20"Casing 9-518"Casing Page 37 Version 1 July, 2015 • • 11 Milne Point Unit L-48 Drilling Procedure Hilcorp Energy Company 21.0 Wellhead Schematic HILCORP ALASKA. LLC SCHRADER BLUFF WELLS NORTH SLOPE HO-34863 0 ISI Ir© ,:im�T, AD,MSUIBLE,CHOK 10.3 � 3-1/8 SN. EST .. r 3-1/E 581— ou/ r''1 i r 3-1.'8 SN 111 CIIII AB:LI! ANA? dil ND E 70 LW EF.T _._... _ _ `N. �'+ I 1-1/8 SM 1 (} 1 ',-1/8 SNJ� NM �■ 1 $ 1 Sz.z —R, 434 ` _... ._.ES- EST a. r 14..2 EST �®]-1/Ei SN—i (2)1c�O��Q��_Ij� U.I..4u7-1AIIAYIf• :A� K P.,±-t�n'1 8 ..:;.I.h am Jr �E,,. :12.; TUBING MANGER 4 L ' • 11 x 3-1/2 API NCO ON ... 1 EU[AO TOP t 26.0 • 9-7/e 081. 0 SEA. In! - In 11 .L i '%I6'Al'6 1J4 :1W 57.6 EST CASING i-ANEER, SEAR-22 riot ( r ionI6-S/4 NW, 9--'+/H HC ATN.-^'`-- : 0 10.:x:0 4S PN TOP iiir iC(I ]I ,.EST SWAGE ADAPTER. IIP 1 7 20 SOW a 16 SUP ON PMI\ ''-2-1/14 51.4 • 7 CASING— A-5/8 CASING--- 3 1/2 1URNG „,,L,WLEAS 5.000 PSI WELLHEAD&TREE ASSEMBLY '1GII 70 x 9-5/8% 3-1/2 ESI1 ALES Sl•5 Citi INS ORAYNIG IAF fSMMIES act An CIl1 V4.4T 9GNfICJJf R.Y I RESTRICTED CONE DENTIA 3(k:UNfN7 ---- CTfEAOW'CA RAN NA11:881 LD42115. re se........-rwa**de war.a se S'," 4P1 4» 1:12 I"*01JUL.15 la rRl CJulAx to a VAMP KW 154puEA ®f•»"'••••»••••�•• »,• mein o1Is SAC4N 946,D 8E OCNSE.•ERED ' °�°"••• +tti t.`t;}" ...••�,li. 7d`•• w�.r 22.0 ^al 4EFERDA1 NAMES Q$Y. I ", og XrPirk:xe ;ow P-20547 5 Page 38 Version 1 July, 2015 1111 • Milne Point Unit L-48 Drilling Procedure Hilcorp Energy Company 23.0 Days Vs Depth Days Vs Depth o I --- l (S chrader Bluff Well -M PI-19 Rom)MPF 18(2411) I -M PI-1712004) 2.x'3 -MPI-15(2002} r 1 =OC�r 6000 r 5. 8 m: N 10 8000 1 10000 12000 14000 1 I 0 5 10 15 20 25 30 Days Page 39 Version 1 July,2015 • • li Milne Point Unit L-48 Drilling Procedure Hilcorp Energy Company 24.0 Formation Tops Formation TVD (Top) TVD (Bottom) Anticipated Pressure (Psi) SV1 2175 3545 973 Ugnu LA1 3487 3726 1559 Ugnu MB 3727 3976 1667 SB NB Sand Top 3977 4097 1779 SB OA Sand'' Top 4098 4127 1845 J Page 40 Version 1 July, 2015 Milne Point Unit L-48 Drilling Procedure Hilcorp Energy Company 25.0 Anticipated Drilling Hazards 12-1/4" Hole Section: Lost Circulation Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Gas Hydrates Remember that hydrate gas behave differently from a gas sand. Additional fluid density will not prevent influx of gas hydrates. Once a gas hydrate has been disturbed the gas will come out of the hole. Drill through the hydrate section as quickly as possible while minimizing gas belching. Minimize circulation time while drilling through the hydrate zone. Excessive circulation will accelerate formation thawing which can increase the amount of hydrates released into the wellbore. Keep the mud circulation temperature as cold as possible. Weigh mud with both a pressurized and non-pressurized mud scale. The non-pressurized scale will reflect the actual mud cut weight. Add 1.0—2.0 ppb DRILTREAT to the system to help thin the mud and release the gas. Isolate/dump contaminated fluid to remove hydrates from the system. Hole Cleaning: Maintain rheology of mud system. Sweep hole with high viscosity sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Monitor ECDs to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out a particular section of the hole. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Anti-Collison: There are a number of adjacent wells in the vicinity. 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 41 Version 1 July, 2015 • •Milne Point Unit L-48 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 42 Version 1 July, 2015 • •II Milne Point Unit L-48 Drilling Procedure Hilcorp Energy Company 26.0 Nordic #3 Rig Layout (Drillers Side) •1 IA .1446/t;r r‘ii. --Nr -\io 1 r aiiSta Services RJG NO. 3 111 A. The lip,iashdiagap.i6e.mfu..&romp ani hrr aan.rna Mrs drogr.l hreuduuw propos*,of Narita• Calve.ad:resoled by US ad Orono acral oyssrphr lams.Tar!drop is funtrimi on a rmfulerel,E haecowl:h she Cliff..ap..arm abo ie wd1 on?.add.II"n.0 rd.apclirii curdphreopaMd.or repvWood m.any manner whosoever.M rink a pam no;any lean heron le toil,memrarared..n aearrr&kd..irh r"tr aid of the aroyls wuhow;he wooer;agmnrm of Nordirt_abos.to Drop may roe hr akar Lod.am orhrr purr Creep,for rhe Truro purpuv for which it hm kern lnvvri lu:I Pr Ali i 1414 It4 a„„„,,, ___ ' � Kd K� N-f Ra Vis I7-aVr--+r Twr1 1!K ....M rifler - _ lit ii:iI • MI UMW :li .iii a — � ,f' f-. drd ltd Wolf Kd and Drillers Side Page 43 Version 1 July,2015 • •Milne Point Unit L-48 Drilling Procedure I1 Hilcorp Energy Company 27.0 Nordic #3 Rig Layout (Well End & Top View) I 111 op II 1111111 i 1 1 .1111 " } a MI .ct'r Hillis i tilt' - w a 11 ir,... I ., , 11, IN=11 Il MN ',-/„..... is f 44442 . 1111.I IFi r`i 71NK as,..... r. o00w$ 'o 400022 FLdM LRCS w'-0. Well End -. (1 I n n INI111111111 � 1 =OWN IarmTag;IWriatt4 _____. +._.:,,,� 7 . t e a. , ( � i r1 r— t �r 4 t 3b3 6d, ASA swap uwatta win TNM A. T PP(POM '""I'« s 'FHA L., °"C '°' U I TOP VIEW Page 44 Version 1 July, 2015 • • Milne Point Unit L-48 11 Drilling Procedure Hilcorp Energy Company 28.0 FIT Procedure Formation Integrity Test (FIT) and Leak-Off Test (LOT) Procedures Procedure for FIT: 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer(ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Page 45 Version 1 July,2015 • • Milne Point Unit L-48 Drilling Procedure Hilcorp Energy Company 29.0 Choke Manifold Schematic s , f 3 . 44'44 1 < i x 44 t i i [ >=:=<a:44>=:`r ,:< :: t Y`> < ><>>1< >-a' >:`>'^ <p t :< t<>44a`>\S44x<i>,`<Ya< 44,t > =pi<� yl>`{.:44x[,t44<>444<)<={,. :<:,t<'t't�'<';(y:>:):><'S ><S rYYt<..:Y.44<�>a44t`>cr<r[>).<<`44` p >a`>t=a> a><:> 44<{::St i:>: >:a c<[)>;t, =t a r :x[ : 44` ') < <,,,,,,,,:,:,:,:,:,:,:„ e> ><<:`:e:t,:,:,::f„ < t'tt < < < 4437U<,tS' = t 44'S 4'1'<.1 S t4' :S:<44t'[ ::i:S ='<:SS,t< [ t e > s >e><YscYY[Yex' � �� _ Ckt:e elt:>`,<ae>_>_ :.':':':':':::::::::.4"141711.111111 MIL `� ` tiro`li /11111.',11111111 Y34.� k.:,', 't't'<44' ' i :'='44'44 tY.>= =r`a><<>4444>44>::::: 44#`a :::::=>`>_> >°>_r44a44>`a o>i>=: ,,,=:=:=;=;:::::::',=:,;=',=;:',1 a :44>,44:`>1 °,:'r >44>44Y=a >°r`> :: rrx > t,<,:;::::t`'S'< S'i't <'S'+'tt'<,tf,<':',< S)t'3'1'< < t'S'<,=:: ww <'i'1 : 3,: :1:i: {'i'i'3'< :,i< < +',:'Sa< <:<<:{'(':<'<'3'44<'< ::<:t:<<,a<':i'3'f t' >Sar<>Y<>a`>:=>,`: =',=',=:=',;;`=',=;=;`,:::::;',=',=;=''' =>=>Y=><Y,<>+><Y . _ '4r :>4`:44>Y[ :::< ;:::::::::::::::=',=',=',=;=';',:;`=':=C=',::::=',=',* • !_ < s'!tYtt i Sst:`'<`:<:l:`:=:< i< e'< :'<t'< 1 ` ,44:4t'<, '4 [ tS :,< '<'^.1' rS: ' :s 'S4:4 :<< � ::3S'<1'<< < :< s 'X' '< 't>:;:a:>(D`<atstat> :;::::`:':`:`:':':':!:`:':`;`:':`:`:`:`:`'s >`>`> >`)`> a=r > r:r , a t'`:`'`'=,`> �� < < < r:'Vt`)r`> r':`>`> > >`> rr`>`>`r`r >r rr ` 44444't's:4:4:4'=44'< t<'<' )iYat t 21tY44tii < <a`1YcSla<! :'44'44'4<':'44'X'44'44'44 144'<44's4 < if 1Y ':'44'44'4<'44'44'44'44'4 S3Yi t <154'4'4'4'44'X': Y=Y=> Yaa`>1> (>[ 44>44! > Yr<#`> Y }`S<,`> �> r`1`> :Y4#4>=>=r=> > 'S >Y < 44:!: t 4Y :_t ` `a 4S44tr;'44'Xa44 :44 1.1 44:4;44:44:44'44'44'44'44'4'''4'4'4i < > a ` tSt > " > > . r >t ♦'>`>''. <',',' a ! a > s NW 1111 ir tea. 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Milne Point Unit L-48 Drilling Procedure Hilcorp Energy Company 30.0 Casing Design Information Calculation & Casing Design Factors DATE: 7/1/2015 WELL: MPU L-48 DESIGN BY:Luke Keller Design Criteria: Hole Size 12-1;4" Mud Density: 9.5 ppg Hole Size 8-112" Mud Density: 9.5 ppg Hole Size Mud Density: Drilling Mode MASP: 1433 psi (see attached MASP determination & calculation) MASP: Production Mode MASP: 1433 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 9-518" 5-112" Top (MD) 0 6,462 Top(TVD) 0 4,127 Bottom (MD) 6.662 13,154 Bottom (TVD) 4,127 4,127 Length 6,662 9,027 Weight(ppf) 40 17 Grade L-80 L-80 Connection TC-Il DWC/C HT Weight w/o Bouyancy Factor(lbs) 266,480 153.459 Tension at Top of Section (lbs) 266,480 153.459 Min strength Tension(1000 lbs) 916 347 Worst Case Safety Factor(Tension) 3.44 2.26 Collapse Pressure at bottom (Psi) 2,039 2,039 Collapse Resistance wlo tension (Psi) 3,090 7,100 Worst Case Safety Factor(Collapse) 1.52 3.48 MASP (psi) 1,433 1,433 Minimum Yield (psi) 5,750 7,740 Worst case safety factor(Burst) 4.01 5.40 Page 47 Version 1 July, 2015 • * II Milne Point Unit L-48 Drilling Procedure Hilcorp Energy Company 31.0 8-1/2" Hole Section MASP Maximum Anticipated Surface Pressure Calculation d 44 8-1/2" Hole Section I l i Icnrp MPU L-48 Milne Point Unit MD TVD Planned Top: 6662 4127 Planned TD: 13154 4127 Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad Schrader Bluff OA Sand 4,127 1846 Oil/Wet 8.6 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-34i(1997) 8.4-9.4 Surface 5,842 1997 Assumptions: 1. Field test data suggests the Fracture Gradient in the Schrader Bluff is btwn 11.5 and 15 ppg EMW. 2. Maximum planned mud density for the 8-1/2" hole section is 9.5 ppg. 3. Calculations assume full evacuation of wellbore to gas Fracture Pressure at 9-5/8" shoe considering a full column of gas from shoe to surface: 4127(ft)x 0.78(psi/ft)= 3220 psi 3220(psi)-[0.1(psi/ft)"4127(ft)]= 2808 psi MASP from pore pressure(complete evacuation of wellbore to gas from Schrader Bluff OA sand) 4127(ft)x 0.447(psi/ft)= 1845 psi, 1845(psi)-0.1(psi/ft)*4127(ft)= 1433 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 48 Version 1 July, 2015 • • r Milne Point Unit 1-48 h :- Drilling Procedure :le. Hilcorp Energy Company 32.0 Spider Plot (NAD 27) (Governmental Sections) As +is �:„ V ,! 1 ,!� ,,,F,f ' y 11 i r ! , / , Sec 1 rc. fT3=�- SeLS�. ti, ++S.+1 ,f r 111 ecf :�, 17 \,L� r.,•.„ • -' ♦ , / 1, F...._-87 1 9,1 ' 1 s r / ,' , a4�� se , �'♦ .� 1 ,1t!1 ,r r ,L. / / a� L ._ ,Y\, `'•* ',1•% 1� 1114 f, ,'� 1,, "--""_ \ ♦w\'' 111 ,r ! ' • ADL388�3J 11 ' `. `s:`14.,,DL�12 54 ,' ADL047434 - �r- MPL 48 SHL r r .Y ♦..iry ec 7 -'4 1" _ Sec.12 o,28t 'If ' , `R,' S - Sec 9 ,.0' I� // II v `* /1 Ir * +` .", ,S // a \ I/ • /f/// �F s // , T I V \ 1 , r ;, rY ' ' r I,!� / /v MPL-48 TPH ti ss /I ,. ((''EPOIN UV— `� 1i s` A�DI3NOD9�'.0 , 4.'i Terril •013N010 '4 // / tag. / // ,a. �t Sec. �+i �. .-. i uti \I PL 48 BHL`. ADL025514 ADL025515 ADL315848 ;'1 • Legend � MPL-48 SHL a MPL-48 TPH 1 r.. ` S__ =a Q-ec.21't ♦ MPL-48 BHL * v w t J-a, Other Surface Holes(SHL) ' \ # 1 , 1 ', M \ESITE E *v 1 Other Bottom Holes(BHL) ' t " r '� t r t r ' ' 1 1 • 1 7 , N t 9., • Other Well Paths `, *V 11 ., 't; ,� 1 1 !1 ec.c 638 _ '_S ^El Milne Point Unit MPL-48 Well 0 1.000 2.000 3.000 Feet Page 49 Version 1 July, 2015 • •11 Milne Point Unit L-48 Drilling Procedure Hilcorp Energy Company 33.0 Surface Plat (As Built) (NAD 27) 18 31 1 .32 1 33 n/� 1 1 \ \ ( / ;) ii, \ \ r,F-PAD I I I \ I r 32 ■ 33 • L.-PAD 1 _�41_- , e I � I ,/ 26 ■ 29 • ,2 7 n I fir% I 'I. 1 20 ■ n • I 1}118 PROJECT f t(f�\Ls:Lt._ / / 45 ■ I,_.....---., r3 18 I 17144 1 I ,. 13 ■ • 6 2i I la I 20 21 g I 3e ■ • 42 VICINITY +A 1 ■ II 9 M.T.S. 34 II • 14 3 • ■ 13 15 ■ ■ 47 2 • q 7 ,`00,t1‘1U11,1 1.-49 %.1..."Ri.9 F..Iq.�C4's!1'1iQ..,c a • • ■• ■ • ■ ■-40.4-■ ` � ' , .. B 35436 537 1150 E • ...*w 1. ao 'r , A, 1 '/ 3 Ri ••rd.F. Allison' I ��ii ','•• . 10608 . 4.- ` I L-PAD S "'fSS1GN�1- 41- I I 1 t mom I SURVEYOR'S CERTIFICATE NOTES: LEGEND f HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED 1. ALASKA STATE PLANE COORDINATES ARE AS-BUILT CONCUC TOR TO PRACTICE LAND SURVEYING IN ZONE 4. NA027. • EXISTING CONDUCTOR THE STATE Cf ALASKA AND THAT 2. BASIS OF LOCATION IS L-PAD MONUMENTS THIS A5= 3URT REPRESENTS A SURVEY L-4 NORTH AND L-2 SOUTH. MADE 9Y ME CR UNDER MY DIRECT SL4ERVISICN ANO THAT ALL 3. ELEVATION DATUM tS MSL. DIMENSICNS AND OTHER DETAILS ARE 4. GEODETIC POSITIONS ARE NAD27. GRAPHIC SCALE CORRECT AS OF AJLY 4, 2015. 5. PAD MEAN SCALE FACTOR+S: 0.9999023 0 103 240 400 8. DATE OF SURVEY: JULY 4, 2015. 1 1 7. REFERENCE MELD BOOK: HC15-02 POS. ( IN FEET) 50-56 1 kWh .200 N. LOCATED IMTHIN PROTRACTED SEC. 8. T. 13 N., R. 10 E., UMIAT MERIDIAN, AK. WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSIT1ON(DMS) POS'T1ON(D,DD)80X ELEV. OFFSETS Y=6,031.494.52 N= 1110 03 70'29'48.865" 70.4969071' 3.303'FSL L-46 X= 545.148.08 E. 1422.61 149'37'50.919" 149.6308099' 1T5' 4,733'FEL Y=8.031,478.37 N= 1110.21 70'29'48.710' 70.4968639' 3,287'FSL i"-48 X= 54,122.81 _c- 1392.18 149'37'51,68°' 149.6310225' 17.5' 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 OAANA VUGN 11 Hilcorp Alaska r II iii 'Gale: 7/0/2flAg0.0 .11 t. - 5 R!l 91,....„ AIPU L PAD mut AS-BUILT CONDUCTOR katAil NO a tialwiiNVOLM_ararrawu ----- NT JI. 1'.200' 0•ELLS L-46, L-48, 1-49 1 n 1 w n..1' 41.91. o' Page 50 Version 1 July,2015 • MilL Drillingne ProcedurePointUnit -48 Hilcorp Energy Company 34.0 Offset MW vs TVD Chart MW vs TVD Offsets L-37 L-35 1000 . L-341 2000 - 3000 j t x a 4000 5000 6000 • 7000 I • 8000 8.0 9.0 10.0 11.0 12.0 13.0 14.0 15.0 Mud Weight(PPG) Page 51 Version 1 July, 2015 • • Mime Point Unit L-48 Drilling Procedure Hilcorp Energy Company 35.0 Drill Pipe Information 5" 19.5# S-135 DS-50 Drill Pipe Configuration Pie Body OD ,n;5.000 80%Inspection Class Pipe Body Wall Thickness in0 0.362 Nominal Weight Designation 19.50 Pipe Body Grade S-135 Drill Pipe Approximate Length °. 31.5 I Drill Pipe Length Rangel SmaotiEdge Height •ii„13132 Raised Connection GPOS50 Tool Joint SPAYS r,l, 120.000 Tool Joint OD 6.625Upset Type IEU Tool Joint ID rrt'3.250 Max Upset OD (DTE) Int 5.125 Pin Tong 9 !Friction Factor 11.0 Box Tong Drill Pipe Performance Drill-Pipe Length Rangel Performance of Drill Pipe with Pipe Body atBest Estimates Nominal 80%Inspection Class ! ` ' `�` 'C�ittrd.j .east"`il nal°' J .,..,,,,,,Y3,-,P' Operatonal Max Tension Drill Pipe Adjusted Weight nynt 24.11 23.29 .ndb°t Torque in-ibsi „c,.. Fluid Displacement ;.,a ll 0.37 0.36 �'43,1 OD Tension Only 0 560.800 Fluid Disclacement eb:ni 00088 0.0085 Fluid Capacity 0.71 0.70 0.72 ccrnaned L.,,,,,.39,600 410,500 P tY rgm'nI Fluid Capacity ,Bbls'l 0.0169 0.0167 0.0172 36,100 Tension Only 0 560,800 Drift Size <Irl 3.125 MUT Ce.elnec I-0.0.2 32.100 467,400 ---- Note:00 told barrel equals 42 US gallons. 0 hole D,II ppe assembly vol.,are best estma'xs and may vs.,dine to tape Ixtdy moll toleranceinternal plastic mating and other factors. Connection Performance GPDS50 ( 6.625 OD X 3.250 tot ID ) 120,000 apsq Appled Make-up Tension al SnouWe! Tesl.n ae Connector Tool Joint Dimensions Torque Separatbn Yckf ii-bo) ibm •:aril Balanced OU Stn:6.435 Maximum Make up Torque 43,100 Tensile Limited 1,046,900 t.to m m T�Joint 00 for API 5.930 Aanimum Make-up Torque 36,100 1.202,500 1,250.000 Premium Class n' ------ - Note The maximum makeup moire shatld be applied when ponoBle.... Women Tod Joint 00 tor .5.93 Note To maxlm.YTe cpnnectm operational lensge.a NUT,T4f-37.580 tndtrsl should be applied Tool Joint Torsional Strength te-ami 71,800 Tool Joint Tensile Strength Mt 1.250.000 Caunlerbpre Om Elevator Shoulder Information Elevator OD 3/32 Raised 6.812 e , SmoothEdge Height Nominal Tool Joint Worn to Bevel Worn to Min TJ OD for 3/'32 Raised OD Diameter API Premium Class Box OD In.6.812 6.625 6.063 5.930 Elevator Capacity it°!1.658.000 1.440.200 823,600 685.600 Note Ele,3:_r capacty based on assumed Elevator Bore.no wear factor.and conlxt stress sr I'0'02.os - !•Assumed Elevator Bore Diameter 5.219 I N:x A rained ee,ator OD Increases elevator capac ty h-enrut air cCng O'akebp iotm, Pipe Body Slip Crushing Capacity Pipe Body Confguration( 5 lilll OD 0.362 in' Wall S-135) Nominal I %Inspection Class I API Premium Class Slip Crushing capacity 1498.300 396.5C J`396.500 _. -._. - - .-- ---...: NNe.Ttp 'rni do rx load calcuated Mb p Rerinld Maallor trrn'Any Coes DSI;Floe ,: ! Assumed Slip Length ' Ing 16.5 rat in Ye 1p Area ione CR 1959 Yr the alp and tramrerse bad actor sheen and ts'or rete•e'tCe Transverse Load Factor MI4.2 I t, p ,mrd seam-dent sr on entInnrapdesonan,c,rdwroncoemcientarr-kta',k�ng`�on ,n :time rips i p'.o tri 7...3 o•Jl s in Nh .ctnr. CaroJI Mt the sip marNactsef for adorsonT Pipe Body Performance Pipe Body Configuration( 5 i OD 0.36200 Wall S-135) Nominal 80%Inspection Class API Premium Class Pipe Tensile Strength imsi 712,100 560.800 560.800 111 Pipe Torsional Strengthn incl 74.100 58.100 58.104 TJ/PipeBody Torsional Ratio 0.97 124 1.24 80%Pipe Torsional Strength .n.Ibsi 59.300 46.500 46.500 :iprii - Burst tptt 17,105 15.638 15,638 Note:Nominal Borst Collapse q psis 15.672 10.029 10.029 calculated at 0757;,RBW per API. Pipe OD (lot 5.000 4.855 4.855 Wall Thickness an I 0.362 0.290 0.290 Nominal Pipe ID sot 4.276 4.276 4.276 Cross Sectional Area of Pipe Body .m^2i 5.275 4-154 4.154 Cross Sectional Area of OD .W021'19.635 18.514 18.514 Cross Sectional Area of ID 02) 14.360 14.360 14.360 Section Modulus ,"Io°31 5.708 4.476 4.476 Polar Section Modulus 31 11.415 8.953 8.953 AIM Page 52 Version 1 July, 2015 • 11 Milne L Drilling ProcedurePointUnit -48 Hilcorp Energy Company Operational Limits of Drill Pipe Connection GPDS50 Tool Joint OD ;,16.625 Tool Joint ID In,3.250 Tool Joist Specified Minimum 120,000 Yield Strength tr11 Pipe Body 80%Inspection Class Pipe Body OD ,,,,5 Wall Thickness 0.362 Pipe Body Grade IS-135 Combined Loading for Drill Pipe at Combined Loading for Drill Pipe at Maximum Make-up Torque= 43.100 in-m . Minimum Make-up Torque= 36,100 (nabs) Operational Assembly Pipe Body Connecuan Max Operation Assembly Pipe Body Cc i{eroon Torque Max Tension Tensicr, I Torque Max Tension max Torsion q Max Tension In-Ibsi pb:. 055 .lost irtibs, -::irs 1 its 11551 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 1 4,200 559.300 559,300 1.046.900 3.400 559.800 559.800 1.202,500 6,300 557.500 557.500 1,046,900 5.100 558.600 558.600 1,202,500 8,300 555.000 555.000 1.046.900 6.800 556.900 556.900 1.202.500 10,400 551.700 551,700 1.046.900 8.400 554.900 554,900 1,202,500 12,500 547,600 547,600 1.046.900 . 10.100 552.200 552.200 1.202.500 14,600 542,800 542,800 1,046.900 11.800 549.100 549,100 1,202,500 16.700 537.100 537,100 1.046.900 13.500 545.400 545.400 1.202.500 18,800 530.600 530,600 1.046.900 15.200 541.200 541.200 1,202.500 20.800 523.600 523,600 1.046.90C 16.900 536.500 538.500 1,202,500 22,900 515.400 515,400 1.046.900 18.600 531.300 531.300 1202,500 25.000 506.200 506,200 1.046.900 20.300 525.400 525.400 1,202,500 27.100 496.100 496,100 1.046.900 .. 22.000 519.000 519.000 1,202,500 29,200 484.800 484,800 1.046.900 23.700 512.000 512.000 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 1202.500 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 30.400 477 900 477.930 1.202.500 39.600 410.500 410.500 1,046.900 32.100 467.400 457.400 1,202.500 V 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 ,h-b_,Tension IN' Min MUT 136.100 1,202,500 036.900 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 53 Version 1 July,2015 0 . Milne Point Unit L-48 Drilling Procedure Hilcorp Energy Company Connection Wear Table Connection GPDS50 Tool.,oint OD .16.625 Tool,ioint 1D 3.250 _ I c:I Jc-1 Epe_1'ed M--r-_r 120.000 t iec o rer,h Connection Wear Tool Connection Max Connection Max Min MUT Connection Max Joint OD Torsional MUT Tension Tension New OD Strength ,n it: n:; IIT 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 r : _-___-...:.:. 6.435 71,800 43,100 1,009,800 35.900 1237.500 6.372 71,200 42,700 1,003,100 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 YYornOO 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 0,015 Wall Thickness (n;10.362 Pipe Body Grade _IS-135 Pipe Body Torque 0 5,300 10.800 15.800 21.100 26.400 31.700 37.000 42.300 47.500 52.800 58.100 Lion) Pipe Body Max Tension 560,800 558,400 551,400 539,800 522.500 499.800 470.000 432.400 384.500 323.100 234,300 12,200 ob.) Page 54 Version 1 July, 2015 • • Hilcorp Energy Company Milne Point M Pt L Pad Plan MPL-48 MPL-48 (Well #3) Plan: MPL-48 wp3 Standard Proposal Report 26 June, 2015 HALLIBURTON tut Sperry Drilling Services • 0 HALLISLIRTON Project: Milne Point WELL DETAILS:Plan MPI.,-48 NAD 1927(NADDONCONDS) Alaska Zone 04 Site: M Pt L Pad GrnwdLevel: 1700 „enY Orating Well: Plan MPL-48 +5450 +55W Nortling basting latitude Lon®tude Slot Wellbore: MPL-48(Well#3) 0.00 0.00 6031475.63 545122.65 70.2948.712N 149'3751.656 W -2000- Design: MPL-48 wp3 FORMATION TOP DETAILS - No formation data is available -1500- -1000- -500- - fr 0- Start Build 2.00-- CASING DETAILS 500- 500 _-' TVD TVDSS MD Size Name Start Build 4.00 4127.15 4080.15 6662.38 9-5/8 9 5/8" __ -- 4127.00 4080.00 13154.60 5-1/2 5 1/2" 1000- 1000 Stag DLS 5.00 TFO 45.73 _ 1Ep0 Start 2972.18 hold at 2097.15 MD p 1500- /3 ryp00 N 2000- tiy�� Start DLS 5.00 TFO-0.39 • - .50''0 Start 200.00 hold at 6480.59 MD Start 828.27 hold at 8788.44 MD 5)• 2500- _ '54'° Start DLS 6.00 TFO-91.67; Start 1000.00 hold at 12154.60 MD _ ' d - tOp ' Start DLS 5.00 TFO 174.71 I TD at 13154.60 23000- F _ 6,,,G`' - i Start 4750.00 hold at 7404.80 MD 3500- 0, oo ,_-' i1 e - 4000- .y _-'' 11 • Q QQ ---MPL-48 wp3 0 0 0 0 0 0 o a o o $ 3 S Vol ` 4500- _ 95B" 5 1/2" 5000- 5500- 6000- 111111111111 ,1 , 1111111 ,1 ,11 ,1 [11 ,1 , 1111 ,1111 ,11,1 ,1, 1111111 [ 1 ,111iiiliirilriiiliiiiliiiiliiii [ -1500 -1000 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 8000 8500 7000 7500 8000 8500 9000 9500 10000 10501 Vertical Section at 150.70°(1250 usfUin) tiJlileor11 • • 1110 HALLl6URTON Project: Milne Point WELL DETAHS:Plat MPL-48 Site: M Pt L Pad GmundLevel: 17.00 Well: Plan MPL-48 -4N/-S 46/-V/ Notting Eanang Latmude Longitude Slot Wellbore: MPL-48(Well#3) 0.00 0.00 6031479.63 545122.65 70°29'48.712N 149'3751.656W 1000- Plan: MPL-48 wp3 REFERENCE INFORMATION Co-ordure,.(N/E)Reference:WeN Plan MPL-48.True North Vert cal(TVD)Reference:As-Stake MPL-Sa 500 Measured Depth Reference:As-Stake MPL B e 41.00055 Calculation Method:Minimum MPL-08 0- fg.iStarIBNld 2.00 C-21°::.: 2S0------- CASING DETAILS StartBmld 4.00 _ D DSS MD Size Name - '500 17$0 `` NN StartDLS 5.007F045.73 4127,15 4080.15 8662.38 9-5/8 95/8" 4127.00 4080.00 13154.60 5-1/2 51/2' 1000 Z'k/ Start 2972,18 hold at 2037.15 MD 1500- 2 4'jJ0 2000 3°00 3 -Start DES 6.007FO-91.67 -2500- C - Start 240.00 hold at 6460.59 MD _3000_ 3750 - Start DLS5.007FO-0.39 g -3500- ''Start 628.27 hold at 6768.44 MD + - -4000_ 95/8" ]n Start D135.007F0174.71 o --_Sue aTo.09rome 7404.60 MD IMPL48 Heel .L.-4500- 0 40 -5000- -5500- -6000- -6500- stmt 104030 raid at 12154.60 MD -7000- ae ' 7D at 13154.60 _ v: �N' -7500- T IMPL-0e Toe' -�' - M Azimuths to True North - Magnetic North:18,93° -8000 - Magneto Field 5 16. MPI,-08,p3 _ Strength:57505,0snT Dip Angle:81.08° -8500-: Data:90/2015 Model:BGGM2015 -9"-'ttttItlllltttt1111iltlltltllllllltltttrlllttlltltlttltlttttltltiiilltltltllttttlttttlttllllltlllttrl 11:1111 I11i,ltltltlltlttlttlrltlltllttrlttltllr -5500 -5000 -4500 -4000 -3500 -3000 -2500 -2000 -1500 -1000 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 West(-)/East(+)(1500 usn) iii IIIt'I11'p • • Halliburton I-IALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan MPL-48 Company: Hilcorp Energy Company TVD Reference: As-Stake MPL-48 @ 47.00usft Project: Mine Point MD Reference: As-Stake MPL-48 @ 47.00usft Site: M Pt L Pad North Reference: True Well: Plan MPL-48 Survey Calculation Method: Minimum Curvature Wellbore: MPL-48(Well#3) Design: MPL-48 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-48 Well Position +N/-S 0.00 usft Northing: 6,031,478.63 usft Latitude: 70°29'48.712 N +El-W 0.00 usft Easting: 545,122.65 usft Longitude: 149°37'51.656 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 17.00 usft Wellbore MPL-48(Well#3) Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 9/3/2015 18.93 81.08 57,505 Design MPL-48 wp3 Audit Notes: Version: Phase: PLAN Tie On Depth: 30.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 30.00 0.00 0.00 150.70 Plan Sections Measured Vertical ND Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +El-W Rate Rate Rate Tool Face (usft) (°) (°) (usft) usft (usft) (usft) (°/100usft) (°/100usft) (1100usft) (°) 30.00 0.00 0.00 30.00 -17.00 0.00 0.00 0.00 0.00 0.00 0.00 680.00 0.00 0.00 680.00 633.00 0.00 0.00 0.00 0.00 0.00 0.00 930.00 5.00 175.00 929.68 882.68 -10.86 0.95 2.00 2.00 0.00 175.00 1,230.00 17.00 175.00 1,223.63 1,176.63 -67.78 5.93 4.00 4.00 0.00 0.00 2,097.15 56.28 211.23 1,912.16 1,865.16 -524.41 -178.92 5.00 4.53 4.18 45.73 5,069.33 56.28 211.23 3,562.32 3,515.32 -2,638.12 -1,460.73 0.00 0.00 0.00 0.00 6,460.59 85.00 125.75 4,109.57 4,062.57 -3,739.84 -1,139.37 6.00 2.06 -6.14 -91.67 6,660.59 85.00 125.75 4,127.00 4,080.00 -3,856.24 -977.67 0.00 0.00 0.00 0.00 6,768.44 90.39 125.71 4,131.33 4,084.33 -3,919.16 -890.22 5.00 5.00 -0.03 -0.39 7,396.71 90.39 125.71 4,127.03 4,080.03 -4,285.89 -380.11 0.00 0.00 0.00 0.00 7,404.60 90.00 125.75 4,127.00 4,080.00 -4,290.50 -373.71 5.00 -4.98 0.46 174.71 12,154.60 90.00 125.75 4,127.00 4,080.00 -7,065.68 3,481.27 0.00 0.00 0.00 0.00 13,154.60 90.00 125.75 4,127.00 4,080.00 -7,649.93 4,292.84 0.00 0.00 0.00 0.00 6/26/2015 5:54:37PM Page 2 COMPASS 5000.1 Build 73 • • Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan MPL-48 Company: Hilcorp Energy Company TVD Reference: As-Stake MPL-48 @ 47.00usft Project: Milne Point MD Reference: As-Stake MPL-48 @ 47.00usft Site: M Pt L Pad North Reference: True Well: Plan MPL-48 Survey Calculation Method: Minimum Curvature Weilbore: MPL-48(Well#3) Design: MPL-48 wp3 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) -17.00 30.00 0.00 0.00 30.00 -17.00 0.00 0.00 6,031,478.63 545,122.65 0.00 0.00 100.00 0.00 0.00 100.00 53.00 0.00 0.00 6,031,478.63 545,122.65 0.00 0.00 200.00 0.00 0.00 200.00 153.00 0.00 0.00 6,031,478.63 545,122.65 0.00 0.00 300.00 0.00 0.00 300.00 253.00 0.00 0.00 6,031,478.63 545,122.65 0.00 0.00 400.00 0.00 0.00 400.00 353.00 0.00 0.00 6,031,478.63 545,122.65 0.00 0.00 500.00 0.00 0.00 500.00 453.00 0.00 0.00 6,031,478.63 545,122.65 0.00 0.00 600.00 0.00 0.00 600.00 553.00 0.00 0.00 6,031,478.63 545,122.65 0.00 0.00 680.00 0.00 0.00 680.00 633.00 0.00 0.00 6,031,478.63 545,122.65 0.00 0.00 700.00 0.40 175.00 700.00 653.00 -0.07 0.01 6,031,478.56 545,122.66 2.00 0.06 800.00 2.40 175.00 799.96 752.96 -2.50 0.22 6,031,476.13 545,122.88 2.00 2.29 900.00 4.40 175.00 899.78 852.78 -8.41 0.74 6,031,470.22 545,123.44 2.00 7.70 930.00 5.00 175.00 929.68 882.68 -10.86 0.95 6,031,467.78 545,123.67 2.00 9.94 1,000.00 7.80 175.00 999.24 952.24 -18.63 1.63 6,031,460.01 545,124.39 4.00 17.05 1,100.00 11.80 175.00 1,097.76 1,050.76 -35.59 3.11 6,031,443.07 545,125.98 4.00 32.56 1,200.00 15.80 175.00 1,194.85 1,147.85 -59.34 5.19 6,031,419.33 545,128.20 4.00 54.29 1,230.00 17.00 175.00 1,223.63 1,176.63 -67.78 5.93 6,031,410.89 545,128.99 4.00 62.01 1,300.00 19.60 182.49 1,290.10 1,243.10 -89.71 6.31 6,031,388.97 545,129.51 5.00 81.32 1,400.00 23.70 190.26 1,383.04 1,336.04 -126.27 2.00 6,031,352.39 545,125.42 5.00 111.09 1,500.00 28.09 195.80 1,472.99 1,425.99 -168.73 -8.00 6,031,309.88 545,115.68 5.00 143.23 1,600.00 32.63 199.92 1,559.26 1,512.26 -216.76 -23.60 6,031,261.75 545,100.37 5.00 177.48 1,700.00 37.29 203.12 1,641.20 1,594.20 -270.00 -44.69 6,031,208.39 545,079.60 5.00 213.59 1,800.00 42.01 205.70 1,718.18 1,671.18 -328.05 -71.12 6,031,150.19 545,053.53 5.00 251.28 1,900.00 46.78 207.84 1,789.62 1,742.62 -390.46 -102.67 6,031,087.60 545,022.37 5.00 290.27 2,000.00 51.58 209.68 1,854.97 1,807.97 -456.75 -139.10 6,031,021.08 544,986.34 5.00 330.25 2,097.15 56.28 211.23 1,912.16 1,865.16 -524.41 -178.92 6,030,953.20 544,946.94 5.00 369.76 2,100.00 56.28 211.23 1,913.74 1,866.74 -526.44 -180.15 6,030,951.16 544,945.72 0.00 370.93 2,200.00 56.28 211.23 1,969.26 1,922.26 -597.55 -223.27 6,030,879.79 544,903.03 0.00 411.85 2,300.00 56.28 211.23 2,024.78 1,977.78 -668.67 -266.40 6,030,808.42 544,860.34 0.00 452.76 2,400.00 56.28 211.23 2,080.30 2,033.30 -739.78 -309.53 6,030,737.05 544,817.65 0.00 493.67 2,500.00 56.28 211.23 2,135.82 2,088.82 -810.90 -352.65 6,030,665.68 544,774.96 0.00 534.59 2,600.00 56.28 211.23 2,191.34 2,144.34 -882.02 -395.78 6,030,594.31 544,732.27 0.00 575.50 2,700.00 56.28 211.23 2,246.86 2,199.86 -953.13 -438.91 6,030,522.94 544,689.58 0.00 616.41 2,800.00 56.28 211.23 2,302.38 2,255.38 -1,024.25 -482.04 6,030,451.57 544,646.89 0.00 657.33 2,900.00 56.28 211.23 2,357.90 2,310.90 -1,095.37 -525.16 6,030,380.20 544,604.20 0.00 698.24 3,000.00 56.28 211.23 2,413.42 2,366.42 -1,166.48 -568.29 6,030,308.83 544,561.51 0.00 739.15 3,100.00 56.28 211.23 2,468.94 2,421.94 -1,237.60 -611.42 6,030,237.46 544,518.82 0.00 780.07 3,200.00 56.28 211.23 2,524.46 2,477.46 -1,308.72 -654.54 6,030,166.09 544,476.13 0.00 820.98 3,300.00 56.28 211.23 2,579.98 2,532.98 -1,379.83 -697.67 6,030,094.72 544,433.43 0.00 861.89 3,400.00 56.28 211.23 2,635.50 2,588.50 -1,450.95 -740.80 6,030,023.35 544,390.74 0.00 902.81 3,500.00 56.28 211.23 2,691.02 2,644.02 -1,522.07 -783.93 6,029,951.98 544,348.05 0.00 943.72 3,600.00 56.28 211.23 2,746.54 2,699.54 -1,593.18 -827.05 6,029,880.61 544,305.36 0.00 984.64 3,700.00 56.28 211.23 2,802.06 2,755.06 -1,664.30 -870.18 6,029,809.24 544,262.67 0.00 1,025.55 3,800.00 56.28 211.23 2,857.58 2,810.58 -1,735.42 -913.31 6,029,737.87 544,219.98 0.00 1,066.46 3,900.00 56.28 211.23 2,913.10 2,866.10 -1,806.53 -956.43 6,029,666.50 544,177.29 0.00 1,107.38 4,000.00 56.28 211.23 2,968.62 2,921.62 -1,877.65 -999.56 6,029,595.13 544,134.60 0.00 1,148.29 6/26/2015 5:54:37PM Page 3 COMPASS 5000.1 Build 73 • • Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan MPL-48 Company: Hilcorp Energy Company TVD Reference: As-Stake MPL-48 @ 47.00usft Project: Mine Point MD Reference: As-Stake MPL-48 @ 47.00usft Site: M Pt L Pad North Reference: True Well: Plan MPL-48 Survey Calculation Method: Minimum Curvature Wellbore: MPL-48(Well#3) Design: MPL-48 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) 2,977.15 4,100.00 56.28 211.23 3,024.15 2,977.15 -1,948.76 -1,042.69 6,029,523.76 544,091.91 0.00 1,189.20 4,200.00 56.28 211.23 3,079.67 3,032.67 -2,019.88 -1,085.82 6,029,452.39 544,049.22 0.00 1,230.12 4,300.00 56.28 211.23 3,135.19 3,088.19 -2,091.00 -1,128.94 6,029,381.02 544,006.53 0.00 1,271.03 4,400.00 56.28 211.23 3,190.71 3,143.71 -2,162.11 -1,172.07 6,029,309.65 543,963.84 0.00 1,311.94 4,500.00 56.28 211.23 3,246.23 3,199.23 -2,233.23 -1,215.20 6,029,238.28 543,921.15 0.00 1,352.86 4,600.00 56.28 211.23 3,301.75 3,254.75 -2,304.35 -1,258.32 6,029,166.91 543,878.46 0.00 1,393.77 4,700.00 56.28 211.23 3,357.27 3,310.27 -2,375.46 -1,301.45 6,029,095.54 543,835.77 0.00 1,434.68 4,800.00 56.28 211.23 3,412.79 3,365.79 -2,446.58 -1,344.58 6,029,024.17 543,793.08 0.00 1,475.60 4,900.00 56.28 211.23 3,468.31 3,421.31 -2,517.70 -1,387.71 6,028,952.80 543,750.39 0.00 1,516.51 5,000.00 56.28 211.23 3,523.83 3,476.83 -2,588.81 -1,430.83 6,028,881.43 543,707.70 0.00 1,557.43 5,069.33 56.28 211.23 3,562.32 3,515.32 -2,638.12 -1,460.73 6,028,831.95 543,678.10 0.00 1,585.79 5,100.00 56.24 209.02 3,579.36 3,532.36 -2,660.17 -1,473.53 6,028,809.82 543,665.44 6.00 1,598.76 5,150.00 56.27 205.41 3,607.14 3,560.14 -2,697.14 -1,492.54 6,028,772.75 543,646.65 6.00 1,621.69 5,200.00 56.41 201.81 3,634.86 3,587.86 -2,735.26 -1,509.21 6,028,734.53 543,630.22 6.00 1,646.78 5,250.00 56.64 198.23 3,662.44 3,615.44 -2,774.44 -1,523.48 6,028,695.27 543,616.19 6.00 1,673.96 5,300.00 56.98 194.67 3,689.82 3,642.82 -2,814.56 -1,535.32 6,028,655.08 543,604.59 6.00 1,703.16 5,350.00 57.42 191.13 3,716.91 3,669.91 -2,855.52 -1,544.70 6,028,614.07 543,595.46 6.00 1,734.29 5,400.00 57.96 187.64 3,743.63 3,696.63 -2,897.20 -1,551.59 6,028,572.35 543,588.83 6.00 1,767.27 5,450.00 58.60 184.20 3,769.93 3,722.93 -2,939.50 -1,555.97 6,028,530.03 543,584.71 6.00 1,802.01 5,500.00 59.32 180.80 3,795.72 3,748.72 -2,982.29 -1,557.83 6,028,487.23 543,583.11 6.00 1,838.42 5,550.00 60.13 177.45 3,820.93 3,773.93 -3,025.45 -1,557.16 6,028,444.08 543,584.03 6.00 1,876.38 5,600.00 61.02 174.16 3,845.50 3,798.50 -3,068.88 -1,553.97 6,028,400.68 543,587.48 6.00 1,915.81 5,650.00 62.00 170.94 3,869.35 3,822.35 -3,112.44 -1,548.27 6,028,357.15 543,593.45 6.00 1,956.60 5,700.00 63.04 167.77 3,892.43 3,845.43 -3,156.03 -1,540.07 6,028,313.62 543,601.92 6.00 1,998.62 5,750.00 64.16 164.66 3,914.66 3,867.66 -3,199.51 -1,529.39 6,028,270.20 543,612.86 6.00 2,041.77 5,800.00 65.34 161.61 3,936.00 3,889.00 -3,242.78 -1,516.27 6,028,227.02 543,626.24 6.00 2,085.92 5,850.00 66.58 158.62 3,956.37 3,909.37 -3,285.71 -1,500.73 6,028,184.19 543,642.04 6.00 2,130.97 5,900.00 67.88 155.68 3,975.72 3,928.72 -3,328.19 -1,482.83 6,028,141.83 543,660.20 6.00 2,176.77 5,950.00 69.23 152.80 3,994.01 3,947.01 -3,370.09 -1,462.60 6,028,100.05 543,680.68 6.00 2,223.21 6,000.00 70.62 149.98 4,011.17 3,964.17 -3,411.31 -1,440.11 6,028,058.97 543,703.41 6.00 2,270.16 6,050.00 72.06 147.20 4,027.17 3,980.17 -3,451.73 -1,415.42 6,028,018.71 543,728.35 6.00 2,317.50 6,100.00 73.54 144.46 4,041.96 3,994.96 -3,491.24 -1,388.59 6,027,979.36 543,755.41 6.00 2,365.08 6,150.00 75.05 141.77 4,055.50 4,008.50 -3,529.74 -1,359.71 6,027,941.05 543,784.53 6.00 2,412.79 6,200.00 76.59 139.12 4,067.74 4,020.74 -3,567.11 -1,328.84 6,027,903.87 543,815.62 6.00 2,460.48 6,250.00 78.16 136.50 4,078.67 4,031.67 -3,603.25 -1,296.07 6,027,867.93 543,848.60 6.00 2,508.04 6,300.00 79.76 133.91 4,088.25 4,041.25 -3,638.07 -1,261.50 6,027,833.33 543,883.38 6.00 2,555.32 6,350.00 81.37 131.35 4,096.44 4,049.44 -3,671.47 -1,225.21 6,027,800.15 543,919.87 6.00 2,602.21 6,400.00 83.01 128.81 4,103.24 4,056.24 -3,703.35 -1,187.31 6,027,768.50 543,957.96 6.00 2,648.56 6,450.00 84.65 126.28 4,108.61 4,061.61 -3,733.64 -1,147.90 6,027,738.46 543,997.55 6.00 2,694.26 6,460.59 85.00 125.75 4,109.57 4,062.57 -3,739.84 -1,139.37 6,027,732.31 544,006.12 6.00 2,703.84 6,500.00 85.00 125.75 4,113.00 4,066.00 -3,762.78 -1,107.50 6,027,709.57 544,038.12 0.00 2,739.44 6,600.00 85.00 125.75 4,121.72 4,074.72 -3,820.98 -1,026.65 6,027,651.86 544,119.31 0.00 2,829.76 6,660.59 85.00 125.75 4,127.00 4,080.00 -3,856.24 -977.67 6,027,616.90 544,168.50 0.00 2,884.48 MPL-48 Heel-Well 3 Heel 6/26/2015 5:54:37PM Page 4 COMPASS 5000.1 Build 73 • 0 Halliburton HALL I B U R TO N Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan MPL-48 Company: Hilcorp Energy Company TVD Reference: As-Stake MPL-48 @ 47.00usft Project: Milne Point MD Reference: As-Stake MPL-48 @ 47.00usft Site: M Pt L Pad North Reference: True Well: Plan MPL-48 Survey Calculation Method: Minimum Curvature Wellbore: MPL-48(Well#3) Design: MPL-48 wp3 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) 4,080.15 6,662.38 85.09 125.75 4,127.15 4,080.15 -3,857.29 -976.22 6,027,615.86 544,169.96 5.00 2,886.10 95/8" 6,700.00 86.97 125.74 4,129.76 4,082.76 -3,879.21 -945.76 6,027,594.13 544,200.55 5.00 2,920.13 6,768.44 90.39 125.71 4,131.33 4,084.33 -3,919.16 -890.22 6,027,554.52 544,256.32 5.00 2,982.15 6,800.00 90.39 125.71 4,131.12 4,084.12 -3,937.58 -864.60 6,027,536.26 544,282.05 0.00 3,010.75 6,900.00 90.39 125.71 4,130.43 4,083.43 -3,995.95 -783.41 6,027,478.39 544,363.59 0.00 3,101.39 7,000.00 90.39 125.71 4,129.75 4,082.75 -4,054.32 -702.21 6,027,420.52 544,445.13 0.00 3,192.02 7,100.00 90.39 125.71 4,129.06 4,082.06 -4,112.69 -621.02 6,027,362.64 544,526.67 0.00 3,282.66 7,200.00 90.39 125.71 4,128.38 4,081.38 -4,171.07 -539.83 6,027,304.77 544,608.20 0.00 3,373.30 7,300.00 90.39 125.71 4,127.69 4,080.69 -4,229.44 -458.63 6,027,246.90 544,689.74 0.00 3,463.94 7,396.71 90.39 125.71 4,127.03 4,080.03 -4,285.89 -380.11 6,027,190.93 544,768.59 0.00 3,551.60 7,404.60 90.00 125.75 4,127.00 4,080.00 -4,290.50 -373.71 6,027,186.36 544,775.03 5.00 3,558.75 7,500.00 90.00 125.75 4,127.00 4,080.00 -4,346.23 -296.28 6,027,131.10 544,852.78 0.00 3,645.25 7,600.00 90.00 125.75 4,127.00 4,080.00 -4,404.66 -215.13 6,027,073.18 544,934.28 0.00 3,735.91 7,700.00 90.00 125.75 4,127.00 4,080.00 -4,463.08 -133.97 6,027,015.25 545,015.79 0.00 3,826.58 7,800.00 90.00 125.75 4,127.00 4,080.00 -4,521.51 -52.81 6,026,957.33 545,097.29 0.00 3,917.25 7,900.00 90.00 125.75 4,127.00 4,080.00 -4,579.93 28.34 6,026,899.40 545,178.79 0.00 4,007.91 8,000.00 90.00 125.75 4,127.00 4,080.00 -4,638.36 109.50 6,026,841.47 545,260.29 0.00 4,098.58 8,100.00 90.00 125.75 4,127.00 4,080.00 -4,696.78 190.66 6,026,783.55 545,341.80 0.00 4,189.25 8,200.00 90.00 125.75 4,127.00 4,080.00 -4,755.21 271.82 6,026,725.62 545,423.30 0.00 4,279.92 8,300.00 90.00 125.75 4,127.00 4,080.00 -4,813.63 352.97 6,026,667.70 545,504.80 0.00 4,370.58 8,400.00 90.00 125.75 4,127.00 4,080.00 -4,872.06 434.13 6,026,609.77 545,586.30 0.00 4,461.25 8,500.00 90.00 125.75 4,127.00 4,080.00 -4,930.48 515.29 6,026,551.85 545,667.81 0.00 4,551.92 8,600.00 90.00 125.75 4,127.00 4,080.00 -4,988.91 596.45 6,026,493.92 545,749.31 0.00 4,642.58 8,700.00 90.00 125.75 4,127.00 4,080.00 -5,047.33 677.60 6,026,436.00 545,830.81 0.00 4,733.25 8,800.00 90.00 125.75 4,127.00 4,080.00 -5,105.76 758.76 6,026,378.07 545,912.32 0.00 4,823.92 8,900.00 90.00 125.75 4,127.00 4,080.00 -5,164.18 839.92 6,026,320.14 545,993.82 0.00 4,914.59 9,000.00 90.00 125.75 4,127.00 4,080.00 -5,222.61 921.08 6,026,262.22 546,075.32 0.00 5,005.25 9,100.00 90.00 125.75 4,127.00 4,080.00 -5,281.03 1,002.23 6,026,204.29 546,156.82 0.00 5,095.92 9,200.00 90.00 125.75 4,127.00 4,080.00 -5,339.46 1,083.39 6,026,146.37 546,238.33 0.00 5,186.59 9,300.00 90.00 125.75 4,127.00 4,080.00 -5,397.88 1,164.55 6,026,088.44 546,319.83 0.00 5,277.25 9,400.00 90.00 125.75 4,127.00 4,080.00 -5,456.31 1,245.71 6,026,030.52 546,401.33 0.00 5,367.92 9,500.00 90.00 125.75 4,127.00 4,080.00 -5,514.73 1,326.86 6,025,972.59 546,482.83 0.00 5,458.59 9,600.00 90.00 125.75 4,127.00 4,080.00 -5,573.16 1,408.02 6,025,914.67 546,564.34 0.00 5,549.26 9,700.00 90.00 125.75 4,127.00 4,080.00 -5,631.58 1,489.18 6,025,856.74 546,645.84 0.00 5,639.92 9,800.00 90.00 125.75 4,127.00 4,080.00 -5,690.01 1,570.34 6,025,798.81 546,727.34 0.00 5,730.59 9,900.00 90.00 125.75 4,127.00 4,080.00 -5,748.43 1,651.49 6,025,740.89 546,808.84 0.00 5,821.26 10,000.00 90.00 125.75 4,127.00 4,080.00 -5,806.86 1,732.65 6,025,682.96 546,890.35 0.00 5,911.93 10,100.00 90.00 125.75 4,127.00 4,080.00 -5,865.28 1,813.81 6,025,625.04 546,971.85 0.00 6,002.59 10,200.00 90.00 125.75 4,127.00 4,080.00 -5,923.71 1,894.97 6,025,567.11 547,053.35 0.00 6,093.26 10,300.00 90.00 125.75 4,127.00 4,080.00 -5,982.13 1,976.12 6,025,509.19 547,134.85 0.00 6,183.93 10,400.00 90.00 125.75 4,127.00 4,080.00 -6,040.56 2,057.28 6,025,451.26 547,216.36 0.00 6,274.59 10,500.00 90.00 125.75 4,127.00 4,080.00 -6,098.98 2,138.44 6,025,393.33 547,297.86 0.00 6,365.26 10,600.00 90.00 125.75 4,127.00 4,080.00 -6,157.41 2,219.59 6,025,335.41 547,379.36 0.00 6,455.93 10,700.00 90.00 125.75 4,127.00 4,080.00 -6,215.83 2,300.75 6,025,277.48 547,460.86 0.00 6,546.60 6/26/2015 5:54:37PM Page 5 COMPASS 5000.1 Build 73 • • Halliburton H A L L I B U R TO N Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan MPL-48 Company: Hilcorp Energy Company TVD Reference: As-Stake MPL-48 @ 47.00usft Project: Milne Point MD Reference: As-Stake MPL-48 @ 47.00usft Site: M Pt L Pad North Reference: True Well: Plan MPL-48 Survey Calculation Method: Minimum Curvature Wellbore: MPL-48(Well#3) Design: MPL-48 wp3 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +El-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 4,080.00 10 800.00 90.00 125.75 4,127.00 4,080.00 -6,274.26 2,381.91 6,025,219.56 547,542.37 0.00 6,637.26 12 7 4,080.00 -6 332.68 2 463.07 6,025,161.63 547 623.87 0.00 10,900.00 90.00 5. 5 4,127.00 6,727.93 11,000.00 90.00 125.75 4,127.00 4,080.00 -6,391.11 2,544.22 6,025,103.71 547,705.37 0.00 6,818.60 11,100.00 90.00 125.75 4,127.00 4,080.00 -6,449.53 2,625.38 6,025,045.78 547,786.88 0.00 6,909.26 11,200.00 90.00 125.75 4,127.00 4,080.00 -6,507.96 2,706.54 6,024,987.86 547,868.38 0.00 6,999.93 11,300.00 90.00 125.75 4,127.00 4,080.00 -6,566.38 2,787.70 6,024,929.93 547,949.88 0.00 7,090.60 11,400.00 90.00 125.75 4,127.00 4,080.00 -6,624.81 2,868.85 6,024,872.00 548,031.38 0.00 7,181.27 11,500.00 90.00 125.75 4,127.00 4,080.00 -6,683.23 2,950.01 6,024,814.08 548,112.89 0.00 7,271.93 11,600.00 90.00 125.75 4,127.00 4,080.00 -6,741.66 3,031.17 6,024,756.15 548,194.39 0.00 7,362.60 11,700.00 90.00 125.75 4,127.00 4,080.00 -6,800.08 3,112.33 6,024,698.23 548,275.89 0.00 7,453.27 11,800.00 90.00 125.75 4,127.00 4,080.00 -6,858.51 3,193.48 6,024,640.30 548,357.39 0.00 7,543.93 11,900.00 90.00 125.75 4,127.00 4,080.00 -6,916.93 3,274.64 6,024,582.38 548,438.90 0.00 7,634.60 12,000.00 90.00 125.75 4,127.00 4,080.00 -6,975.36 3,355.80 6,024,524.45 548,520.40 0.00 7,725.27 12,100.00 90.00 125.75 4,127.00 4,080.00 -7,033.78 3,436.96 6,024,466.53 548,601.90 0.00 7,815.94 12,154.60 90.00 125.75 4,127.00 4,080.00 -7,065.68 3,481.27 6,024,434.90 548,646.40 0.00 7,865.44 MPL-48 Toe-Well 3 Toe 12,200.00 90.00 125.75 4,127.00 4,080.00 -7,092.21 3,518.11 6,024,408.60 548,683.40 0.00 7,906.60 12,300.00 90.00 125.75 4,127.00 4,080.00 -7,150.63 3,599.27 6,024,350.67 548,764.91 0.00 7,997.27 12,400.00 90.00 125.75 4,127.00 4,080.00 -7,209.06 3,680.43 6,024,292.75 548,846.41 0.00 8,087.94 12,500.00 90.00 125.75 4,127.00 4,080.00 -7,267.48 3,761.59 6,024,234.82 548,927.91 0.00 8,178.60 12,600.00 90.00 125.75 4,127.00 4,080.00 -7,325.91 3,842.74 6,024,176.90 549,009.41 0.00 8,269.27 12,700.00 90.00 125.75 4,127.00 4,080.00 -7,384.33 3,923.90 6,024,118.97 549,090.92 0.00 8,359.94 12,800.00 90.00 125.75 4,127.00 4,080.00 -7,442.76 4,005.06 6,024,061.05 549,172.42 0.00 8,450.61 12,900.00 90.00 125.75 4,127.00 4,080.00 -7,501.18 4,086.21 6,024,003.12 549,253.92 0.00 8,541.27 13,000.00 90.00 125.75 4,127.00 4,080.00 -7,559.61 4,167.37 6,023,945.20 549,335.42 0.00 8,631.94 13,100.00 90.00 125.75 4,127.00 4,080.00 -7,618.03 4,248.53 6,023,887.27 549,416.93 0.00 8,722.61 13,154.60 90.00 125.75 4,127.00 4,080.00 -7,649.93 4,292.84 6,023,855.64 549,461.43 0.00 8,772.11 Targets Target Name -hit/miss target Dip Angle Dip Dlr. TVD +NIS +E/-W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) MPL-48 Toe 0.00 0.00 4,127.00 -7,065.68 3,481.27 6,024,434.90 548,646.40 -plan hits target center -Circle(radius 100.00) Well 3 Toe 0.00 0.35 4,127.00 -7,065.68 3,481.27 6,024,434.90 548,646.40 -plan hits target center -Circle(radius 100.00) MPL-48 Heel 0.00 0.00 4,127.00 -3,856.24 -977.67 6,027,616.90 544,168.50 -plan hits target center -Circle(radius 100.00) Well 3 Heel 0.00 0.35 4,127.00 -3,856.24 -977.67 6,027,616.90 544,168.50 -plan hits target center -Circle(radius 100.00) 6/26/2015 5:54:37PM Page 6 COMPASS 5000.1 Build 73 • • Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan MPL-48 Company: Hilcorp Energy Company TVD Reference: As-Stake MPL-48 @ 47.00usft Project: Milne Point MD Reference: As-Stake MPL-48 @ 47.00usft Site: M Pt L Pad North Reference: True Well: Plan MPL-48 Survey Calculation Method: Minimum Curvature Wellbore: MPL-48(Well#3) Design: MPL-48 wp3 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 6,662.38 4,127.15 9 5/8" 9-5/8 12-1/4 13,154.60 4,127.00 51/2" 5-1/2 8-1/2 6/26/2015 5:54:37PM Page 7 COMPASS 5000.1 Build 73 i • Hilcorp Energy Company Milne Point M Pt L Pad Plan MPL-48 MPL-48(Well#3) MPL-48 wp3 Sperry Drilling Services Clearance Summary Anticollision Report 26 June,2015 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: M Pt L Pad-Plan MPL-48-MPL-48(Well#3)-MPL-48 wp3 Well Coordinates:6,031,478.63 N,545,122.65 E(70°29'48.71"N,149°37'51.66"W) Datum Height: As-Stake MPL-48 La147.00usft Scan Range:0.00 to 13,154.60 usft.Measured Depth. Scan Radius is 1,512.46 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 r. HALLIBURTON Sperry Drilling Services S ! SURVEY PROGRAM Hilcorp Energy Company ANTI-COLLISION SETTINGS Date:2015-06-08T00:00:00 Validated:Yes Version: Calculation Method:Minimum Curvature Interpolation Method:MD,interval:25.00 Error System:ISCWSA Depth Range From:30.00 To 13154.60 Depth From Depth To Survey/Plan Tool Scan Method:Closest Approach 3D Centre Distance:1512.46 30.00 1000.00 MPL-48 wp3(MPL-48(Well 8812-SS Error Surface:Elliptical Conic Reference: Plan:MPL-48 wp3(Plan MPL-48/MPL48(Well#3)) 1000.00 6662.46 MPL-48 wp3(MPL-48(Well itif))/D+IFR2+MS+sa0 Warning Method:Error Ratio 6662.46 13154.60 MPL48 wp3(MPL-48(Well iti(7/D+IFR2+MS+sag MPL-421-I MPL-10I I= I MP6491Mp4 �,,w� 7= IMPL-11 IMPL.O2P i - I �'..;;',i;''.� ___--IMPL-0�.J IMPL-111 • 330,1��, . (( ti. 30 IMPL-46 wp7 IMPL-371 0 IMPL-041 b"L i.�4 A - 330,1 t8�0/``30 IMPL37AI ♦4 i ;14'...'N°:".,‘-ii,,-` --MPL-1 �:iii �e 1MPLJ7I A, .3 ,4,@+'�4 , r".��; moo% MPL45 IMPL35A9 aoo A .'s,rt Alet4 'a fio 300 jr��,�� j • • Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan MPL-48-MPL-48 wp3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: M Pt L Pad-Plan MPL-48-MPL-48(Well#3)-MPL-48 wp3 Scan Range:0.00 to 13,154.60 usft.Measured Depth. Scan Radius is 1,512.46 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation Is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft M Pt L Pad MPL-02-MPL-02-MPL-02 1,476.56 301.88 1,476.56 288.94 1,462.39 23.337 Centre Distance Pass- MPL-02-MPL-02-MPL-02 1,500.00 301.96 1,500.00 288.86 1,483.16 23.052 Ellipse Separation Pass- MPL-02-MPL-02-MPL-02 1,725.00 319.28 1,725.00 304.41 1,670.43 21.474 Clearance Factor Pass- MPL-02-MPL-02A-MPL-02A 1,476.56 301.88 1,476.56 289.22 1,462.39 23.856 Centre Distance Pass- MPL-02-MPL-02A-MPL-02A 1,500.00 301.96 1,500.00 289.15 1,483.16 23.558 Ellipse Separation Pass- MPL-02-MPL-02A-MPL-02A 1,725.00 319.28 1,725.00 304.69 1,670.43 21.888 Clearance Factor Pass- MPL-02-MPL-02AL1-MPL-02AL1 1,476.56 301.88 1,476.56 289.24 1,462.39 23.895 Centre Distance Pass- MPL-02-MPL-02AL1-MPL-02AL1 1,500.00 301.96 1,500.00 289.17 1,483.16 23.596 Ellipse Separation Pass- MPL-02-MPL-02AL1-MPL-02AL1 1,725.00 319.28 1,725.00 304.71 1,670.43 21.920 Clearance Factor Pass- MPL-02-MPL-02AL2-MPL-02AL2 1,476.56 301.88 1,476.56 288.94 1,462.39 23.337 Centre Distance Pass- MPL-02-MPL-02AL2-MPL-02AL2 1,500.00 301.96 1,500.00 288.86 1,483.16 23.052 Ellipse Separation Pass- MPL-02-MPL-02AL2-MPL-02AL2 1,725.00 319.28 1,725.00 304.41 1,670.43 21.474 Clearance Factor Pass- MPL-02-MPL-02APB1-MPL-02APB1 1,476.56 301.88 1,476.56 288.94 1,462.39 23.337 Centre Distance Pass- MPL-02-MPL-02APB1-MPL-02APB1 1,500.00 301.96 1,500.00 288.86 1,483.16 23.052 Ellipse Separation Pass- MPL-02-MPL-02AP61-MPL-02APB1 1,725.00 319.28 1,725.00 304.41 1,670.43 21.474 Clearance Factor Pass- MPL-02-MPL-02APB2-MPL-02APB2 1,476.56 301.88 1,476.56 288.94 1,462.39 23.337 Centre Distance Pass- MPL-02-MPL-02APB2-MPL-02APB2 1,500.00 301.96 1,500.00 288.86 1,483.16 23.052 Ellipse Separation Pass- MPL-02-MPL-02AP82-MPL-02APB2 1,725.00 319.28 1,725.00 304.41 1,670.43 21.474 Clearance Factor Pass- MPL-04-MPL-04-MPL-04 30.00 179.26 30.00 178.35 19.00 196.592 Centre Distance Pass- MPL-04-MPL-04-MPL-04 675.00 183.17 675.00 176.21 662.72 26.312 Ellipse Separation Pass- MPL-04-MPL-04-MPL-04 1,025.00 201.83 1,025.00 191.87 992.05 20.265 Clearance Factor Pass- MPL-05-MPL-05-MPL-05 938.50 118.79 938.50 109.51 948.40 12.805 Centre Distance Pass- MPL-05-MPL-05-MPL-05 950.00 118.82 950.00 109.43 959.66 12.661 Ellipse Separation Pass- MPL-05-MPL-05-MPL-05 1,050.00 122.77 1,050.00 112.55 1,054.52 12.018 Clearance Factor Pass- MPL-06-MPL-06-MPL-06 1,347.64 134.64 1,347.64 122.55 1,375.35 11.132 Centre Distance Pass- MPL-06-MPL-06-MPL-06 1,350.00 134.65 1,350.00 122.54 1,377.32 11.125 Clearance Factor Pass- MPL-07-MPL-07-MPL-07 30.00 14625 30.00 145.34 39.00 160.387 Centre Distance Pass- MPL-07-MPL-07-MPL-07 300.00 148.10 300.00 144.85 307.57 45.585 Ellipse Separation Pass- 26 June,2015-17:58 Page 2 of 7 COMPASS S • Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan MPL-48-MPL-48 wp3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design:M Pt L Pad-Plan MPL-48-MPL-48(Well#3)-MPL-48 wp3 Scan Range:0.00 to 13,154.60 usft.Measured Depth. Scan Radius is 1,512.46 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-07 825.00 187.61 825.00 179.47 807.01 23.030 Clearance Factor Pass- MPL-09-MPL-09-MPL-09 681.00 239.58 681.00 232.56 690.40 34.139 Centre Distance Pass- MPL-09-MPL-09-MPL-09 700.00 239.61 700.00 232.42 709.40 33.314 Ellipse Separation Pass- MPL-09-MPL-09-MPL-09 1,060.00 265.62 1,050.00 255.56 1,057.67 26.421 Clearance Factor Pass- MPL-09-MPL-09A-MPL-09A 681.00 239.58 681.00 232.86 690.40 35.674 Centre Distance Pass- MPL-09-MPL-09A-MPL-09A 700.00 239.61 700.00 232.72 709.40 34.775 Ellipse Separation Pass- MPL-09-MPL-09A-MPL-09A 1,050.00 265.62 1,050.00 255.87 1,057.67 27.239 Clearance Factor Pass- MPL-09-MPL-09APB1-MPL-09APB1 681.00 239.58 681.00 232.56 690.40 34.139 Centre Distance Pass- MPL-09-MPL-09APB1-MPL-09AP61 700.00 239.61 700.00 232.42 709.40 33.314 Ellipse Separation Pass- MPL-09-MPL-09APB1-MPL-09AP81 1,050.00 265.62 1,050.00 255.56 1,057.67 26.421 Clearance Factor Pass- MPL-10-MPL-10-MPL-10 323.62 190.23 323.62 186.74 332.62 54.514 Centre Distance Pass- MPL-10-MPL-10-MPL-10 700.00 190.48 700.00 183.29 708.77 26.496 Ellipse Separation Pass- MPL-10-MPL-10-MPL-10 1,000.00 209.36 1,000.00 199.63 1,007.80 21.514 Clearance Factor Pass- MPL-11-MPL-11-MPL-11 859.70 31.10 859.70 18.36 867.16 2.441 Ellipse Separation Pass- MPL-11-MPL-11-MPL-11 875.00 31.37 875.00 18.39 881.93 2.417 Clearance Factor Pass- MPL-12-MPL-12-MPL-12 1,771,92 87.53 1,771.92 70.30 1,761.85 5.079 Clearance Factor Pass- MPL-35-MPL-35-MPL-35 2,169.09 166.23 2,169.09 145.32 2,019.46 7.950 Centre Distance Pass- MPL-35-MPL-35-MPL-35 2,175.00 166.25 2,175.00 14524 2,024.76 7.915 Ellipse Separation Pass- MPL-35-MPL-35-MPL-35 3,825.00 285.24 3,825.00 233.61 3,695.98 5.524 Clearance Factor Pass- MPL-35-MPL-35A-MPL-35A 2,169.09 166.23 2,169.09 145.32 2,020.26 7.950 Centre Distance Pass- MPL-35-MPL-35A-MPL-35A 2,175.00 166.25 2,175.00 145.24 2,025.56 7.915 Ellipse Separation Pass- MPL-35-MPL-35A-MPL-35A 3,825.00 285.24 3,825.00 233.61 3,696.78 5.524 Clearance Factor Pass- MPL-35-MPL-35APB1-MPL-35APB1 2,169.09 166.23 2,169.09 145.32 2,020.26 7.950 Centre Distance Pass- MPL-35-MPL-35APB1-MPL-35APB1 2,175.00 166.25 2,175.00 145.24 2,025.56 7.915 Ellipse Separation Pass- MPL-35-MPL-35APB1-MPL-35AP61 3,825.00 285.24 3,825.00 233.61 3,696.78 5.524 Clearance Factor Pass- MPL-35-MPL-35APB2-MPL-35APB2 2,169.09 166.23 2,169.09 145.32 2,020.26 7.950 Centre Distance Pass- MPL-35-MPL-35APB2-MPL-35APB2 2,175.00 166.25 2,175.00 145.24 2,025.56 7.915 Ellipse Separation Pass- MPL-35-MPL-35APB2-MPL-35APB2 3,825.00 28524 3,825.00 233.61 3,696.78 5.524 Clearance Factor Pass- MPL-35-MPL-35APB3-MPL-35APB3 2,169.09 166.23 2,169.09 145.32 2,020.26 7.950 Centre Distance Pass- MPL-35-MPL-35APB3-MPL-35APB3 2,175.00 166.25 2,175.00 145.24 2,025.56 7.915 Ellipse Separation Pass- MPL-35-MPL-35APB3-MPL-35APB3 3,825.00 285.24 3,825.00 233.61 3,696.78 5.524 Clearance Factor Pass- 26 June,2015-17:58 Page 3 of 7 COMPASS S • Hilcorp Energy Company i HALLIBURTON Milne Point Anticollision Report for Plan MPL-48-MPL-48 wp3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design:M Pt L Pad-Plan MPL-48-MPL-48(Well#3)-MPL-48 wp3 Scan Range: 0.00 to 13,154.60 usft.Measured Depth. Scan Radius is 1,512.46 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-Plan MPL-35B-MPL-3513 wp1 2,169.09 166.23 2,169.09 145.49 2,019.46 8.016 Centre Distance Pass- MPL-35-Plan MPL-35B-MPL-35B wp1 2,175.00 166.25 2,175.00 145.42 2,024.76 7.980 Ellipse Separation Pass- MPL-35-Plan MPL-35B-MPL-35B wp1 3,825.00 285.24 3,825.00 233.78 3,695.98 5.542 Clearance Factor Pass- MPL-37-MPL-37-MPL-37 1,898.28 70.53 1,898.28 53.80 1,836.58 4.215 Ellipse Separation Pass- MPL-37-MPL-37-MPL-37 4,675.00 204.55 4,675.00 97.78 4,758.69 1.916 Clearance Factor Pass- MPL-37-MPL-37A-MPL-37A 1,898.28 70.53 1,898.28 53.79 1,845.78 4.213 Ellipse Separation Pass- MPL-37-MPL-37A-MPL-37A 4,675.00 204,55 4,675.00 97.60 4,767.89 1.913 Clearance Factor Pass- MPL-37-Plan MPL-378-MPL-37B WP2 1,898.28 70.53 1,898.28 54.01 1,836.58 4.268 Ellipse Separation Pass- MPL-37-Plan MPL-37B-MPL-37B WP2 4,675.00 204.55 4,675.00 97.90 4,758.69 1.918 Clearance Factor Pass- MPL-42-MPL-42-MPL-42 1,011.87 234.60 1,011.87 227.49 1,047.51 32.983 Centre Distance Pass- MPL-42-MPL-42-MPL-42 1,025.00 234.63 1,025.00 227.46 1,061.56 32.702 Ellipse Separation Pass- MPL-42-MPL-42-MPL-42 1,175.00 239.92 1,175.00 232.22 1,222.01 31.164 Clearance Factor Pass- / ."'�.. MPL-45-MPL-45-MPL-45 J 7,009.70 280.20 7,009.70 226.53 6,703.72 5.221 Centre Distance Pass- MPL-45-MPL-45-MPL-45 7,025.00 280.52 7,025.00 225.81 6,710.91 5.127 Ellipse Separation Pass- MPL-45-MPL-45-MPL-45 7,150.00 306.16 7,150.00 242.0 6,771.20 4.777 Clearance Factor Pass- Plan MPL-46-MPL-46(Well#2)-MPL-46 wp3 250.00 29.99 250.00 .36 250.00 11.407 Centre Distance Pass- Plan MPL-46-MPL-46(Well#2)-MPL-46 wp3 300.00 30.14 300.00 27.07 299.81 9.818 Ellipse Separation Pass- Plan MPL-46-MPL46(Well#2)-MPL-46 wp3 13,154.60 1,112.78 13,154.60 827.63 12,951.86 3.902 Clearance Factor Pass- Plan MPL-47-MPL-47(Well#4)-MPL-47 wp3 1,036.93 129.77 1,036.93 119.89 1,064.67 13.132 Centre Distance Pass- Plan MPL-47-MPL-47(Well#4)-MPL-47 wp3 1,050.00 129.84 1,050.00 119.81 1,077.88 12.947 Ellipse Separation Pass- Plan MPL-47-MPL-47(Well#4)-MPL-47 wp3 12,125.00 1,033.17 12,125.00 774.61 13,002.29 3.996 Clearance Factor Pass- Plan MPL-49-MPL-49(Well#1)-MPL-49 wp3 675.00 131.05 675.00 124.65 675.00 20.469 Centre Distance Pass- Plan MPL-49-MPL-49(Well#1)-MPL-49 wp3 700.00 131.10 700.00 124.54 700.00 19.986 Ellipse Separation Pass- Plan MPL-49-MPL-49(Well#1)-MPL-49 wp3 1,100.00 141.27 1,100.00 133.33 1,118.02 17.812 Clearance Factor Pass- Plan MPL-50-MPL-50(well#5)-MPL-50 wp3 325.00 29.92 325.00 26.59 325.80 8.988 Centre Distance Pass- Plan MPL-50-MPL-50(well#5)-MPL-50 wp3 450.00 30.41 450.00 26.03 450.54 6.939 Ellipse Separation Pass- Plan MPL-50-MPL-50(well#5)-MPL-50 wp3 625.00 35.56 625.00 29.66 624.29 6.036 Clearance Factor Pass- 26 June.2015- 17:58 Page 4 of 7 COMPASS • S Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan MPL-48 -MPL-48 wp3 Survey tool program From To Survey/Plan Survey Tool (usf) (usf) 30.00 1,000.00 MPL-48 wp3 SRG-SS 1,000.00 6,662.46 MPL-48 wp3 MWD+IFR2+MS+sag 6,662.46 13,154.60 MPL-48 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. 26 June,2015- 17:58 Page 5 of 7 COMPASS • • Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan MPL-48-MPL-48 wp3 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to As-Stake MPL-48 @ 47.00usft.Northing and Easting are relative to Plan MPL-48. Coordinate System is US State Plane 1927(Exact solution),Alaska Zone 04. Central Meridian is-150.00°,Grid Convergence at Surface is:0.35°. -.Pt MF'L-U1,IVF'L-ULA,MF'L-ULA VU Ladder Plot - MPL-02,NPL-02AL1,MPL-02AL1V0 $• MPL-02,NPL-02AL2,NPL-02AL2V0 - r r r I I -e-NPL-02,NPL-02APB1,NPL-02APB1V0 A -air NPL-02,MPL-02APB2,NPL-02APB2VO c D. ;. 11. I /1 1' (p i I I -I- MPL-04,MPL-04,MPL-04 V1 N 13 I I II;I J I I A $ MPL-05,MPL-05,MPL-05 V1 Iil. F. I $ MPL-06,MPL-06,MPL-06V1 O0 lit /A -8- MPL-07,MPL-07,MPL-07 V1 F t, $ MPL-09,MPL-09,MPL-09V1 (i h v Tai:S ♦- MPL-09,MPL-09A,MPL-09AV0 • ��l • ice_....ca Itilli6-' i $ NPL-09,IVPL-09APB1,MPL-09APB1V0 f0 hift l"'` 7 $ MPL-10,MPL-10,MPL-10 V1 / 1.N G'r� -- MPL-11,MPL-11,MPL-11V1 A..(I) / n dI,,f:�,.', __ •1 it ! _ } MPL-12,MPL-12,MPL-12 V1 r, N l�/� I. `A' /� -� MPL35,MPL35,MPL-35 V6 -e- MPL35,MPL35A,NPL35AV12 o 450 AAA lilt iK $ MPL35,MPL35APB1,MPL35APB1V5 o '1,,rAI1/- 1~.'- A\ -N- MPL35,MPL35APB2,MPL35APB2V3 vm,'r., '+-• _h } NPL35,1VPL35APB3,MPL35APB3V5 CL a) .Yw`��:,'.��..� i ... - ---- -- $ MPL35,PIan IVPL35B,MPL35B`.vp1 V0 U =;:;- , i4 -X- MPL37,NPL37,IvPL37V3 0 n�'N� 1 -e- MPL37,MPL37A,MPL37AV1 $ MPL37,Plan MPL37B,NPL37BWP2V19 0 2500 5000 7500 10000 12500 $ MPL42,MPL42,MPL42V4 Measured Depth(2500 usft/in) -6- MPL45,MPL-45,MPL-45 V7 Plan MPL46,MPL46(Well#2),MPL-46 v n3 VO 28 June,2015-17:58 Page 6 of 7 COMPASS 41111 • Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan MPL-48-MPL-48 wp3 Clearance Factor Plot: Measured Depth versus Separation(Clearance)Factor i -;,. - $ MPL-02,MPL-02A,MPL-02AVO Qi �\ i � Iii 4A -6-MPL-02,MPL-02ALI,MPL-02AL1V0 10.00 I % -- --- $MPL-02,MPL-02AL2,MPL-02A1.2 Ae \\At A \ -e-MPL-02,MPL-02APB1,MPL-02APB1 VO ll �" -6- MPL-02,WL-02APB2,MPL-02APB2V0 8.75 •- I .. $ MPL-04,MPL-04,MPL-04 V1 A A -4- MPL-05,MPL-05,MPL-05 V1 d\ -A-MPL-06,MPL-06,MPL-06 V1 7.50- �\ '!(A __._ � : -$MPL-07,MPL-07,MPL-07 V1 i7m ,;4 y� ` I AA\ $ MPL-09,MPL-09 ,MPL-09V1 6.25 „,. _ $ MPL-09,MPL-09A.MPL-09AV0 o _ •\ $ MPL-09,MPL-09APB1,MPL-09APB1 VO m - •� ' $ MPL-10,MPL-10,MPL-10 V1 co 5.00 Al -_.-_ -6-MPL-11,MPL-11,MPL-11 V1 m - /• $MPL-12,MPL-12,MPL-12 V1 a _ �` .:: -at-MPL-35,MPL-35,MPL-35 V6 AL 3,75 ` r -e- MPL35,MPL-35A,MPL-35AV12 $ MPL-35,MPL-35APB1,MPL35APB1V5 2.50 _."_,__ -N- MPL35,MPL35APB2,MPL35APB2V3 _ -I-MPL35,MPL35APB3,MPL35APB3V5 - NoCollision Avoidance Req -9- MPL-35,Plan MPL3KO 1 V0 1 25- ' -1E-MPL-37,MPL37,MPL-37 V3 $ MPL37,MPL37A,MPL37AV1 - ♦- MPL-37,Plan MPL37B,NPL37BWP2V19 0.00- I I I 1111 11111 1 i rill 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I $ MPL-42,MPL-42.MPL-42V4 0 1250 2500 3750 5000 6250 7500 8750 10000 11250 12500 13750 15000 6-MPL-45,MPL-45,MPL45 V7 MeasuadDepth(2500usftfin) -I-Plan MPL46,MPL46(Well#2),MPL46wp3 V0 26 June,2015- 17:58 Page 7 of 7 COMPASS • • Bettis, Patricia K (DOA — From: Keith Elliott <kelliott@hilcorp.com> Sent: Wednesday,June 24, 2015 10:18 AM To: Bettis, Patricia K (DOA) Subject: Re: MPU L-49: Permit to Drill Application Sure thing. Economically, pre-production does not work for us b/c of our completion design and added cost of associated workovers. Have a great day as well! Keith Elliott Cell: 832-233-5855 Office: 907-777-8355 Sent from my iPhone On Jun 24, 2015, at 9:07 AM, Bettis, Patricia K (DOA)<patricia.bettis@alaska.gov<mailto:patricia.bettis@alaska.gov» wrote: Thank you and have a great day. From: Keith Elliott [mailto: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.bettis@alaska.gov] Sent:Tuesday,June 23, 2015 1:57 PM To: Luke Keller Subject: MPU L-49: Permit to Drill Application Good afternoon Luke, 1 • • 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<mailto:patricia.bettis@alaska.gov>. 2 • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • TRANSMITTAL LETTER CHECKLIST WELL NAME: fiP L- L g PTD: c /.5- Development V Service Exploratory Stratigraphic Test Non-Conventional FIELD: 1)1:ink_ 01.'111— POOL: ir)& '20i rt cc_Au LT.* Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements / Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 • • El El U) , , , , , , , , O) 0 (1) a , , U) N N b Ui. Oa) �_ C Co � , o _I L 0 cn a). L P. a c. ' , 4 a , , a w CL cn O, t y �, 0 , a o o a, c' ( ° ami' Q;' a 0' 3; o y, N. 0' , , 0 co fi5 a) cc m 7 � � � � �� . � � � N, � � � N, C, N �� as , a U. c. 3' Q. E. c. 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