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215-154
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 16, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC J-23A MILNE PT UNIT J-23A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/16/2024 J-23A 50-029-22970-01-00 215-154-0 W SPT 3521 2151540 1500 251 267 250 252 4YRTST P Guy Cook 8/24/2024 The testing was completed with a Little Red Services pump truck and calibrated gauges. 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 J-23A Inspection Date: Tubing OA Packer Depth 74 1727 1657 1651IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC240823160254 BBL Pumped:1.3 BBL Returned:1.3 Wednesday, October 16, 2024 Page 1 of 1 9 9 9 9 99 999 9 9 9 9 9 7HVWZDVGXH-$ZDV6,-XQH-XO\DQG$2*&& QRWLILHGWKDWWKHZHOOZDVQRWRSHUDEOH,QMHFWLRQ UHVWDUWHG-5HJJ 8/24/2024 7HVWZDVGXH James B. Regg Digitally signed by James B. Regg Date: 2024.10.16 11:46:47 -08'00' 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: OPERABLE: MPJ-23A (PTD# 2151540) - Return to Injection Date:Monday, August 26, 2024 7:38:05 AM From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Tuesday, August 20, 2024 8:32 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: MPJ-23A (PTD# 2151540) - Return to Injection Mr. Wallace – PWI well MPJ-23A (PTD# 2151540) was made Not Operable in July 2024 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, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Tuesday, July 30, 2024 3:53 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: MPJ-23A (PTD# 2151540) - Shut in for AOGCC MIT-IA Mr. Wallace – PWI well MPJ-23A (PTD# 2151540) is currently shut in and will not be brought online for its scheduled 4 year MIT-IA due this month. The well is now 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 questions. Thank you, 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 delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward 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. 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: MPJ-23A (PTD# 2151540) - Shut in for AOGCC MIT-IA Date:Tuesday, July 30, 2024 4:28:12 PM From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Tuesday, July 30, 2024 3:53 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: MPJ-23A (PTD# 2151540) - Shut in for AOGCC MIT-IA Mr. Wallace – PWI well MPJ-23A (PTD# 2151540) is currently shut in and will not be brought online for its scheduled 4 year MIT-IA due this month. The well is now 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 questions. Thank you, 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 hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward 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. David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt and return one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 07/13/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Date Log Type MPU L-06 50029220030000 190010 5/26/21 Caliper Survey MPU J-23A 50029229700100 215154 7/3/21 Injection Profile MPU E-12 50029232620000 205067 6/26/2021 Coil Flag MPU J-24A 50029229760100 216120 7/4/21 Injection Profile Please include current contact information if different from above. eived By: 07/13/2021 37' (6HW By Abby Bell at 3:30 pm, Jul 13, 2021 MEMORANDUM State of Alaska Packer Alaska Oil and Gas Conservation Commission Pretest DATE: Wednesday, July 29, 2020 To: Jim Regg�/ / SUBJECT: Mechanical Integrity Tests P.I. Supervisor y 3521 Hilcorp Alaska, LLC 744 J-23A FROM: Adam Earl MILNE PT UNIT J-23A Petroleum Inspector SPT Test psi 1 Sre: Inspector IA Reviewed By: 1680 P.I. Supry JRP— NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT J -23A API Well Number 50-029-22970-01-00 Inspector Name: Adam Earl Permit Number: 215-154-0 Inspection Date: 7/22/2020 Insp Num: mitAGE200726113135 Rel Insp Num: Wednesday, July 29, 2020 Page I of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well J -23A Type Inj W jVD �1I 3521 Tubing] 744 748745 74s PTD 2151540 Type Test SPT Test psi 1 1500 IA ss 1680 1610 1601 ' - BBL Pumped: 09 'BBL — Returned: ', 0.9 OA -- Interval 4vRTST P/F P Notes: MITIA/ mono bore well Wednesday, July 29, 2020 Page I of I • ) '1 1 p5 1 5 4 Seth Nolan Hilcorp Alaska, LLC 8 4 0 GeoTech 3800 Centerpoint Drive, Suite 100 RECEIVED Anchorage, AK 99503 Tele: 907 777-8308 Hileorp Mask*,L1C: Fax: 907 777-8510 AUG 0 9 2011 E-mail: snolan@hilcorp.com DATA LOGGED gi%S/2oi't M.K.BENDER DATE 08/09/17 AOGCC To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU ]-23ASCANNED \.1, E 1 Prints: GR/CCL/PRES/TEMP/SPIN CD 1: Hilcorp MP9-23A IPROF 277UL 17 FINAL 7/31/2017 4:32 PM File folder Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: fi) (../, 6.. Date: II 0 o o o CV O 1 • w N • o N •i E a -o > _• • • ,-. • w N r I'1 c m o a) Q Q E E -a a = o .n • Z a)• o o c9 E r U a)I 2 H a1 aI 2 H • 2 1- 2 O $' _ J o co in a2 p 0 P- 0 0 0 0 -o > 0 0 0 0 N R c Z a) E 2I 2I o gI 2I a) 0 gI gI g� gI m = Z 0 c 0 0 O �� C9 U 0 CO E 0 0 ( O H F F. co m ¢ ¢ ¢ Q ¢ ¢ ¢ ¢ E E ¢ ¢ ¢ ¢ () M M M () CO CO () I I M CO CO co Z Q C co LL Q N N N N N N N N C C N N N N D o ' t Ile Z _) -) � -) _) -) -) -) CO -) CO - - - -) F- a)_ a a a a a a a a a I a I a a a a a >z .) 0 �w� 2 2 2 2 2 2 2 2 2 °c) 2 °) 2 2 2 2 w > H p O a) 6 ai 6 a) a) a) a) ai ai 6 a) a) a) Z 'C Np W a it it it it it it it w w w W a it LL coo (a a U¢� U U_ U_ U U U U U U 0 U C U_ U U U_ c N E C C C C C C C C C C a) C a) C C C C c w @ I a) o20 0 0 0 0 0 0 0 0 00 00 0 0 0 0 np I— V '..., J V. N¢' N N N 8 N N N N N¢I .))¢I N N N N lf)i.L1 QJ EO co W N W W W W W W W W W N W N W W W W N 2 0 Y 0 c D co m co (o co co co 0 0 0 0 (o co (o co CL y a) 000000000 0 0000 W J (6N N N N N N N N N N N N N N N Q @ 0 CM O O O O O O O O O CO 01 0)O01 Cf) IX 0. re @ ZE •n ci) it) cn ci) ci) (n (r) O G.. (:),,.. Lli V J 2 z (V 2 2 O V N Z \ o Q r+ \ U G 0 \! 0 C 0 a) cn m N Cn O. @ > O 0I I w m CL (fl C � Z I a C i' M A r a > �+ r O G O a) N ? N E a p N 4. J 0 re 2 N C. co co Z d m o _1 2 0N H rnm CO Z N a a)71) C J N co I- d @ N W T o ICL CC p r • a) 0I ¢ Q o n Z 2 Z Eo 0 E U a co (co @ce co Z D 2 @ CO @ CO @ @ CO CO @ @ @ @ @ @ @ N d co @ CO @ CO @ CO CO CO CO CO io io io Ca -a • (0 C E p 0 0 0 0 0 0 0 0 0 0 0 0 0 0@ co CL aaOaaOaa) o) a) m 0 cs) 'p p p p p p p p p p p a O p p JG p z a • > 0 w a d !0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 F 17 d 13 w 0 ''Iv v v v v a v a a v v v v v v 1l) Q Z C C N 10 7 it N- h. N- N- N- N- N- N- N- N- N- N- N- N- N 2 O 0 0 W o Zi N �N N N N N N N N N N N N N N N N O Q @ ° w E £ E. 2 o 0 0 CD G d v w CI- 2 210 0 0 0 0 0 0 0 0 0 U 0 0 0 0 0 v Z W J o3a w W W W W W W W LU LU w w LU w w 3 • i 0 0 I N N \l G\7 afi } } } › E 7.0 y D .t T I CC @ m m Q % b z E ° 0 a d m H Q 0 2 2 U U CO Z 1 N L (-:0 Q N (((0 1 7 m II as E > >- 1 0 CO co 1 Lf. CJ vs o Uas N -JC. qJ ` 0 lL O Y = Q � aQ U m N = 1 c W Q a7 Z N o) 11 N CD co IX Il E LU oN V Z N N 0) p_ I U = y J N ', Z V c6' 1.12 u) Q COTo O O re cn 15 m 0- 7e. w E 0 n 2 U III v 0. to cN 1 1C N o a) O- EL u� E 1 1 I tko1 a es N a E Ts II"' -) O m o W a) C 1 2 N N @ @ t 9� a) d o m Z N5 C a) E 0 I- E a w m :4 s o) N 0 CO W m m c a) c G Z QJ 0 I— 0 !21 !D_ ''�, Z EE o >, 11 0 £ 0 1 Z a) CO Lo m o 0 C s,L 1 N N O C7) CO tri E O >- C) v et 0 w 1 W O } ',., 1'. m ~ c W as E a O d N a) I W r �0 O t N a) Q a) re 0 C N 1 2 N N o m E O a)Et ai i cts1 W0 m 715 G yr Z Q o c Q o as o w c U a J 0. d Co U 0 Ee a o 0 a a CO $ E 1 a 0 E O E 0 o , E a) y E E Q a 2 3 ? 0 a 0 0 o 10 0 a Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Wednesday,June 22, 2016 7:35 AM To: Wallace, Chris D (DOA) Subject: MPJ-23A(PTD#2151540) Ready For Injection Chris, Water injector MPJ-23A(PTD#2151540)was recently drilled and completed at Milne Point.As previously discussed,the well has a highly deviated horizontal completion with a packer 780' MD/125'TVD from the uppermost injection control device.The well had a passing IA pressure test on the rig to 3000 psi on 4/30/16 and is ready for injection. Hilcorp plans to place the well on injection for stabilization and compliance testing. Plan Forward—Operations 1) Place well on injection. Use caution,annuli are fluid packed. 2) AOGCC MIT-IA when well is on injection and thermally stable. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400Anchorage,AK 99503 pI g Hiln+rp 1.I 1 0.1 i STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 2 5 2016 Status: COMPLETION Gas e OR RECOMPLETION REPORT ANC), la.Well Stat ❑ ❑ Abandoned El Suspended❑ Class: O CC 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑✓ ' WAGE WDSPL❑ No.of Completions: _1 Service ❑Q ' Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: Hilcorp Alaska,LLC • Aband.: 4/29/2016 215-154 • 3.Address: 7. Date Spudded: 15.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 April 18,2016 50-029-22970-01-00 4a.Location of Well(Governmental Section): 8.Date TD Reached: 16.Well Name and Number: Surface: 2685'FSL,3390'FEL,Sec 28,T13N, R10E, UM,AK April 24,2016 MPU J-23A Top of Productive Interval: 9.Ref Elevations: KB: 69.8' 17.Field/Pool(s):Milne Point Unit GL:36.1' BF:36.1' Schrader Bluff Oil Pool . Total Depth: 10. Plug Back Depth MD/TVD: 18.Property Designation: 2083'FNL,738'FWL,Sec 30,T13N, R10E,UM,AK 13,425'MD/3,526'ND (SHL)ADL025906/(BHL)ADL025517. 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19.Land Use Permit: Surface: x- 551926 y- 6015082 Zone- 4 13,430'MD/3,526'ND N/A TPI: x- y- Zone- 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 540247 y- 6015521 Zone- 4 N/A -1,800'MD/1,675'ND 5. Directional or Inclination Survey: Yes Q(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) 7,783'MD/3,552'ND 22. Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper, resistivity, porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary ROP-GM-ADR-HORIZONTAL PRES 21N MD,GM-ADR-INV/REV SECTIONS 2IN ND 23. CASING, LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM - HOLE SIZE CEMENTING RECORD FT PULLED 4-1/2" 13.5 L-80 7,660' 13,430' 3,521' 3,525' 6-1/8" Swell Pkrs w/ICD's 7 " a L-" D ' . ??S3 24.Open to production or injection? Yes 0 No ❑ 25.TUBING RECORD If Yes,list each interval open(MD/ND of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/ND) Size and Number): 4-1/2" 7,670'MD Tieback Assy.@ Please see attached schematic for ICD depth detail. 7,670'MD/3,523'ND 26.ACID,FRACTURE,CEMENT SQUEEZE,ETC. COMPLE±;ON Was hydraulic fracturing used during completion? Yes❑ No Q DATE Per 20 AAC 25.283(i)(2)attach electronic and printed information !1(241(,) DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED VERILIEI, _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: Test Period — Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate . Form 10-407 Revised 11/2015 a ilio- ` _ CONTINUED ivw 2 MAY 3 1 2016 Submit ORIGINIAL oily: y /!r! b`/ ll// RBDMS L� /(-1 28.CORE DATA Conventional CO): Yes ❑ No Q Sidewall Coresfbes ❑ No ❑ If Yes, list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD ND Well tested? Yes El No Q Permafrost-Top If yes,list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1,800' 1,675' Attach separate pages to this form,if needed,and submit detailed test Top of Productive Interval information, including reports,per 20 AAC 25.071. Schrader Bluff NA 7,982' 3,598' Schrader Bluff NB 8,281' 3,637' Formation at total depth: Schrader Bluff NB ' 31. List of Attachments: Wellbore Schematic,Drilling and Completion Composite 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: IkellerQhilcorp.com Printed Name: Luke Keller Title: Drilling Engineer / Signature: Phone: 777-8395 Date: / S ,2 0/4 INSTRUCTIONS /// General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each segregated pool is a completion. Item 1b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,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 II Well: MPU J-23A i SCHEMATIC Last Completed: 4/29/2016 Hilcorp Alaska,LLC PTD: 215-154 KBEIev.:69.8'/GLEIev.:36.1' TREE&WELLHEAD Tree Cameron FL 4 1/16" 5M el FMC 13-5/8"3K x 11"5K,w/horizontal tree tbg.Spool, 20" r deactivated. Added new 11 x 115k spacer spool and 11 x 11 Wellhead 5k attachment spool,One ESP penetration and 2 ea%"NPT control line prep.4"H BPV. 4 OPEN HOLE/CEMENT DETAIL D, 20" Driven 1 7" 1642 sx Cement to Surface 4-1/2" Cementless Injection Liner in 6-1/8"hole CASING DETAIL 9 Size Type Wt/Grade/Conn Drift ID Top Btm BPF ' 20" Conductor 54.5/K-55/Weld N/A Surface 108' N/A 7" Surface 26/L-80/Btrc _ 6.151 Surface 7,783' 0.0383 4-1/2" Liner 13.5/L-80/HTTC 3.833 7,660' 13,430' 0.0152 TUBING DETAIL 4-1/2" Tubing 12.6/L-80/Supermax 3.833 Surf 7,670' 0.0152 WELL INCLINATION DETAIL b KOP @ 325' ;t Max Hole Angle=94.1 deg.@ 10,192'MD JEWELRY DETAIL No. Top MD Item ID Upper Completion 1 2,996' 4.5"x1"w/1"DCK-2 Shear valve w/BEK Latch 3.833" 2 7,536' 4.5"XN Nipple w/RHCP plug,3.725"No-Go,3.813" 3.725" Packing Bore Lower Completion 3 7,660' BOT HRD-E Liner Top Packer 5"x 7" 4.283" 4 Btm@ 7,670' Tieback Assy.(5.75"OD No-Go top @ 7,659') 4.151" 41/ 2„ 5 See Below 4-1/2"13.5#Swell Packers 3.920" PI 6 13,393' 4-1/2"Drillable Packoff Sub 2.400" 7 13,425' WIV Valve LTC BxB(1.5"Ball on Seat/Closed) - 2 fi ICD DETAIL r '� °*�- No Depth ICD Detail i�� 7' 1 3/4 W 1 8,440' 4-1/2"12.6#Hyd 521 BxP,WOT ICD w/(10)1/8"nozzles Tare-7,763' 2 9,124' 4-1/2"12.6#Hyd 521 BxP,WOT ICD w/(10)1/8"nozzles SWELL PACKER DETAIL BOW-7,796 3 9,770' 4-1/2"12.6#Hyd 521 BxP,WOT ICD w/(10)1/8"nozzles• Top(MD) Btm(MD) 4 10,289' 4-1/2"12.6#Hyd 521 BxP,WOT ICD w/(10)1/8"nozzles 5 10,842' 4-1/2"12.6#Hyd 521 BxP,WOT ICD w/(10)1/8"nozzles 8,209' 8,221' 6 11,179' 4-1/2"12.6#Hyd 521 BxP,WOT ICD w/(10)1/8"nozzles 10,987' 10,998' 7 11,700' 4-1/2"12.6#Hyd 521 BxP,WOT ICD w/(10)1/8"nozzles 12,335' 12,347' 8 12,652' 4-1/2"12.6#Hyd 521 BxP,WOT ICD w/(10)1/8"nozzles Se 9 12,932' 4-1/2"12.6#Hyd 521 BxP,WOT ICD w/(10)1/8"nozzles ICOS aill PIT Detail 10 13,333' 4-1/2"12.6#Hyd 521 BxP,WOT ICD w/(10)1/8"nozzles 4-1/2" A GENERAL WELL INFO API:50-029-22970-01-00 Drilled and Completed by Doyon 14 -4/29/2016 6/7 TD=13,430'(MD)/TD=3,526'(TVD) PBTD=13,425'(MD)/PBTD=3,526'(TVD) Revised By:GD 5/23/2016 • • Hilcorp Energy Company Composite Report Well Name: MP J-23A Field: Milne Point County/State: ,Alaska 1(LAT/LONG): evation(RKB): API#: 50-029-22970-01-00 Spud Date: 4/19/2016 Job Name: 1511739D MP-J23A DRILLING Contractor AFE#: 1511739D AFE$: $2,676,786 Activity Date Ops Summary 4/13/2016 Continue to prep for rig move to J-Pad.Dig out snow from around rig.Remove snow berm from Pad entrance for rig clearance.Pull off well,install boosters.Haul support equipment from K-Pad to J-Pad;Notify Security,Start rig move from K-Pad to J-pad.Continue hauling support equipment to J-Pad.Rig arrived @ J-PAD @ 21:00 hrs,9.5 miles total.;Remove rear boosters,remove snow from behind well,set mats around well,place adapter flange and tree behind well,get kill tank f/ B-pad. Mobilize rock washer and equipment f/K-pad to J-pad.;Notify DSO,PJSM,move and spot rig over J-23A,level and set down rig. Note:Rig accepted @ 04:30 hrs.;R/U on J-23A,Skid rig floor into position,lay mats,set cuttings box and rock washer skid,Continue to mobilize equipment from K-pad. 4/14/2016 Rig up floor heat/steam/air and water.Clean out cellar box and prep cellar area,prep mud pits for seawater.load pits with Seawater.Lay mats and spot rock washer skid.;Hook up pump lines on rig floor.Remove BPV and test circulating lines.Blow down circulating lines.Finish setting rock washer skid.Trucks were on hold for weather for about 2 hrs;Line up to kill well pumping down tubing.Both IA and Tubing Pressure @ 0 psi.Pump Seawater down tubing @ 3 bpm/400 psi. Establish returns @ 21 bbls pumped.Mostly Crude returns for first 90 bbls.;Increase pump rate to 4 bpm/500 psi after bottoms up.Continue to circulate a total of 473 bbls with 321 bbls back to surface w/8.5 SW in/out.Lost 152 bbls on circulation.;Monitor well for 30 minutes with tubing and IA on vac.;Shut in well.Blow down circulating lines.R/D lines.Set BPV.R/U fill up line with gauge to IA for monitor and fill during BOP test. Note:Losses to well @ 12 bph.;N/D Tree.Inspect hanger threads,3.625"acme threads,w/2.95"min ID.Exercise Lock Down Screws. Note:Notify Baker fishing that spear needed to pull hanger due to unconventional hanger thread.;N/U 13 5/8"5M BOPE dressed w/2 7/8"x 5"VBR rams in upper and lower,Blind ram in middle BOP.Get stack measurements. Continue to load 4"DP into pipeshed. Note:well continues taking 12 bph.;Pull BPV,install TWC per wellhead rep.;M/U 3 1/2"test jt,flood stack and lines with fresh water.perform body test to 250/3000 psi,good. Note:AOGCC inspector Matt Herrera verbally waived witness to test @ 03:50 hrs.;Test BOP components using 3 1/2"and 4"test joints with doughnut style upset on end,test to 250 psi low and 3000 psi high 5 min.ea.Chart all tests. Cont to monitor and fill annulus @ 12 bph;Hauled 0 bbls to MP G&I for total=0 bbls Hauled 0 bbls to GPB G&I for total=0 bbls Hauled 0 bbls to B-50 for total=0 bbls Hauled 0 bbls from Vern Lake for total=0 bbls;Hauled 0 bbls from L-Pad Lake for total=0 bbls Hauled 120 bbls to ORT,total 120 bbls Daily losses 176 bbls,total=176 bbls 4/15/2016 Cont Test BOP components using 3 1/2"and 4"test joints with oughnut style upset on end,test to 250 psi low and 3000 psi high 5 min.ea.Chart all tests. Cont to monitor and fill annulus©12 bph;Test gas alarms.Perform Accumulator Test:Start 3000 psi/After Close 1600 psi/200 psi build 38 sec/Full recovery 186 sec.N2 bottles 6 @ 2025 ay.Rig down Test Equipment.;Blow down choke and kill lines,clear XO subs ect from floor.Stage Weatherford/Centrilift equipment on floor.;Pull TWC,Fill tubing with Seawater.20 bbls to fill tubing.;M/U 2 13/16"ITECO Spear to stand of DP.Engage spear into tubing hanger.BOLDS.Unseat hanger @ 115K.Pull hanger to floor.PUW 105/SOW 80K.Break down and lay down Hgr and spear.;POOH L/D 3 1/2"Eue 8rd tubing with 1/4"control line from 7888'to 6100',conduct Trip drill,1.56 min response time,Continue POOH to 465',flowing out tbg Note:Fill hole @ 10 bph.;M/U FOSV,circulate out and dump oil cap to rock washer,pump 9 bbls before seeing returns.Blow down top drive.;Continue POH L/D tbg from 465'to surface,continue hole fill @ 10 bph.;Hauled 0 bbls to MP G&I for total=0 bbls Hauled 0 bbls to GPB G&I for total=0 bbls Hauled 190 bbls to B-50 for total=190 bbls Hauled 0 bbls from Vern Lake for total=0 bbls;Hauled 102 bbls from L-Pad Lake for total=102 bbls Hauled 0 bbls to ORT,total 120 bbls Daily losses 385 bbls,total=561 bbls 4/16/2016 ' Continue to POOH L/D 3 1/2"Eue tbg.0own total of248 its/2 GLMl1 Slide Sleeve/Cutjt 2.10'.; and clean rig floor.Stage BHA components on floor, , Load 4 3/4"DC's in pipe shed,tally same.Rig up floor for handling 4"DP.;M/U C/O BHA:6 1/8"Tricone Bit/2ea 4 3/4"Boot Baskets/7"Csg Scraper/Bit Sub/6 1/8"String mill/9 ea 4 3/4"DC's/15 jts 4"HWDP.=754.21'.;TIH with C/O BHA picking up 4"DP from pipe shed 754'to 4850'.PUW 100K/SOW 82K.;Fill pipe @ 4550'.Pumped 46 bbls,catch returns @ 25 bbls.Blow Down Top Drive. Switch Rig to High Line Power.;Cont.TIH with C/O BHA picking up 4"DP from 4850'to 7892'.PUW 140K/SOW 85K.Tag TOF @ 7892'.L/D 1 single DP.MU Top Drive.;Break circulation.Fill Pipe.Catch returns @ 28 bbls.CBU @ 6 bpm/950 psi,working scraper 90'from 7878'to 7788'across cement retainer and whipstock setting depth. Note:loss rate circ @ 130 bph.;Monitor well for 10 minutes,blow down top drive.;POH from 7892'to 750'@ HWDP,rack 5 stds HWDP and 3 stds 4 3/4"drill collars in drk,L/D XO,string mill,bit sub,scraper,2 boot bskts and bit. Note:fill hole @ 20 bph POH.;Fill hole 20 bbls,monitor well,static loss rate @ 108 bph.Load out Tools,clear rig floor.Stage retainer BHA on rig floor.;PJSM, M/U Baker K-1 mech.cement retainer,setting tool and XO=7.39',retainer only=1.89'TIH w/stds 4"DP to 7170'. Note:use 20 bph hole fill TIH.;Single in with 4"DP to 7802'@ retainer setting depth,verify pipe count.;Circulate until hole full,23 bbls,P/U 130K,S/O 80K,set retainer per Baker rep @ 7802'with top retainer @ 7800'(top retainer 7'above casing collar @7807');Unsting,BDTD,M/U head pin on single,stab into retainer setting down 30k,R/U cementers.;Hauled 0 bbls to MP G&I for total=0 bbls Hauled 0 bbls to GPB G&I for total=0 bbls Hauled 85 bbls to B-50 for total=275 bbls Hauled 0 bbls from Vern Lake for total=0 bbls;Hauled 120 bbls from L-Pad Lake for total=222 bbls Hauled 0 bbls to ORT,total 120 bbls Daily losses 625 bbls,total= 1186 bbls seawater 4/17/2016 Continue to RU HES Cementers. Hold PJSM with crew_.Sgueeze CMT Below Retainer @ 7800'as Follows:Pump 10 bbls fresh water.Test lines to 3500 psi. Mix and Pump 295sx/60 bbls 15.8 ppg HALCEM(TM)SYSTEM CMT @ 3.5 bpm/425 psi.;Pump Fresh water displacement @ 4.5 BPM avg/1150 psi,Caught cement @ 18 bbls away.Pumped total of 86 bbls Displacement.2 bbls over calculated.Final pump pressure 700 psi @ 2.8 BPM.;Unsting from ret.Turn over to rig and pump 1 hole vol SW with no CMT returns.Break off head pin,load foam DP wiper.MU Head pin.Circulate DP volume+20 bbls to wipe ID of DP,7.5 bpm/1150 psi.;Close pipe rams,Pressure test 7"cast • •n .1. - • - .*1- n :r r • :I r • • ..e• 1-$ • • u.• Good Test.;Circulate DP Vol due to unbalanced fluid.Blow down and rig down circ equipment.;POOH with Retainer running tool from 7800'.Lay down Retainer Running tool.PUW 125K/SOW 73K.;Clean and clear rig floor.Stage Whipstock BHA components on rig floor.Prep to N/D and Install tubing spool.;PJSM,Drain stack,de energize Koomey,N/D and Set stack aside.Install new tbg spool on top of existing tbg spool.;N/U BOP stack,re-install kill line,riser and BOP anchors.;PJSM,close blind ram,test spool flanges to 250 psi low/1750 psi high 5 min ea.M/U 4 1/2"test jt,install test plug,test upper and lower 2 7/8"VBR rams;to 250 psi low/3000 psi high 5 min ea. Chart all tests.R/D test equipment.;Record new stack measurements.Install 8.9375"ID wear bushing,;Service rig,drawworks,inspect brake linkage.;PJSM w/ BOT,Sperry,rig crew for P/U Whipstock assembly as follows:M/U 6 1/8"window mill,lower 5 7/8"WM mill,flex jt,upper 6.151"WM mill,1-3 1/2"HWDP,FLT sub,DM and TM collar.;Scribe window mill to MWD D w/offset @ 325 deg,set assy to side,close blind ram,P/U WS with hoist,remove shipping bolt and 3 shear bolts on anchor,leaving3 in w/anchor shear set 10695 ft/Ibs.;set WS in hole,M/U to mill w/25k brass shear bolt installed.open Blind ram.M/U XO,9-4 3/4" @ drill collars from drk and 1 std HWDP, ( Note:very easy in and out of slips w/run speed©50 fpm.;Suface test MWD,good.Blow down top drive. RIH w/remaining 4 stds HWDP=822.93';TIH on C1 elevators 50 fpm from 823'to 3100',slow in/out slips,fill pipe @ 2700';Hauled 114 bbls to MP G&I for total-114 bbls ,, p 3 Hauled 0 bbls to GPB G&I for total=0 bbls ,v ,� Hauled 515 bbls to B-50 for total=790 bbls Hauled 0 bbls from Vern Lake for total=0 bbls;Hauled 312 bbls from L-Pad Lake for total=534 bbls Hauled 0 bbls to ORT,total 120 bbls 1 Daily losses 124 bbls,total=1310 bbls seawater 4/18/2016 TIH on elevators with Whipstock @ 50 fpm from 3100'to 7700',slow in/out slips.;MU Top Drive,bring on pump @ 277 gpm/1380 psi.Orient Whipstock to 35 deg Left.RIH and tag Retainer @ 7801'.yUW 135K/SOW 85K w/no pump.;Set down and shear Anchor Screws©12K. PU to 5K over verify WS set.Set back down 35K and shear Bolt.Anchor Set t"7801'\TOW @ 7783'/BOW 7796'.PUH and lay down single.;Displace well to 8.9 mud system @ 3 bpm/920 psi. Note:ditch magnets in place.;Establish Milling Parameters. Mill window from 7783'to 7796'. 100 rpm/7-10 TQ,250 gpm/1200 psi,3-6K WOM.Pump Hi vis sweep as needed. AROP 3.25 fph milling window.;Drill new formation from 7796'to 7827'making enough footage to get Geo steer BHA out window.Back ream window 2 times,shut , - . 4. off pump and make dry pass,Ream 1 more time 7k smooth torque and no wt.;Park inside 7"casing @ 7772'condition mud for F.I.T.pumping 250 gpm,1200 psi until good 8.9 ppg MW in/out. Note:92 lbs metal recovered from milling window.;Close annular.Perform F.I.T.to 12 ppg EMW with existing mud wt 8.9 ppg,apply 575 psi.Lost 35 psi in 10 sec, 1 min 510 psi,5 min 475 psi, open annular. / Note:pumped.81 bbl,.8 bbl bled back.;Flow check well,static.Mix and Pump dry job,blow down top drive and choke.;POH on elevators from 7772'to 805'@ 4/' HWDP.flow check well before pulling BHA,well static. Note:correct hole fill on trip out.;Rack 4 stds HWDP in derrick,L/D 9-4 3/4"DCs,MWD tools,and window mill assy.Starter mill 1/4"out of gauge,string mill in gauge.;Load out BHA,clear rig floor.Load Geo-steer tools to rig floor. Monitor well with trip tank.;P/U Geo-pilot,M/U 6 1/8"PDC bit;Hauled 213 bbls to MP G&I for total=328 bbls Hauled 0 bbls to GPB G&I for total=0 bbls Hauled 290 bbls to B-50 for total=1080 bbls Hauled 520 bbls from Vern Lake for total=520 bbls;Hauled 200 bbls from L-Pad Lake for total=734 bbls Hauled 0 bbls to ORT,total 120 bbls Daily losses 0 bbls,total=1310 bbls seawater 4/19/2016 Continue to MU BHA#4:Bit,HDBS MM64 PDC/Geo-Pilot w/Stab/ADR/ILS/GM/PWD/DM/TM/Float sub.;Upload MWD.Issues up loading.Circulate through MWD @ 2 bpm/100 psi.Up load MWD with no further issues.;Continue MU BHA:3 NM Flex Collars/XO Sub/1 jt HWDP/Jars/1 jt HWDP.total BHA Length= 275.33.;TIH with Geo-Pilot picking up 4"HT38 DP from 275'to 1217';MU Top Drive/Fill pipe/Test MWD&Geo-Pilot with no issues.Blow down Top Drive.;Continue to single in the hole Picking up 4"DP from 1217'to 5934'. Continue TIH f/5934'to 7726'w/stands from derrick,filling pipe every 20 stands.;Park @ 7726'.Slip and cut Drill line.;Establish parameters©7726'MD. 155k up,89k dn,105k rot,30 rpm,6k tq off. Obtain SPR's @ 7726'MD/3537'TVD(see pump data). TIH F/7726'-T/7827'MD. Clean through window.;Drill 6-1/8" production hole F/7827'-T/8008'MD.Reduced rotating and pumping rate until MWD is off slide. Increase rot F!30 to 130 rpm,Inc pump F!232 to 288 gpm,w/ 1800 psi off,1830 psi on.;181 ft©41 fUhr avg rop. 6k tq off,6.5k tq on,11.0 ECD's.(10.7 clean hole ECD baseline). Build and turn as per WP03.;Cont drilling build and turn F/8008'-T/8288'. 284 gpm,1858 psi on,1800 psi off,28%flow,145 rpm,6.5k tq,8k wob. Pump 25 bbl wt'd sweep w/condet&nut plug due to bit balling @ 8150.;280 ft @ 47 ft/hr avg rop.Last svy @ 8122'-2.3'High,17'Right of plan;Hauled 114 bbls to MP G&I for total=441 bbls Hauled 0 bbls to GPB G&I for total=0 bbls Hauled 0 bbls to B-50 for total=1080 bbls Hauled 0 bbls from Vern Lake for total=520 bbls;Hauled 264 bbls from L-Pad Lake for total=998 bbls Daily losses to formation 0 bbls for total=0 bbls 4/20/2016 Drill 6-1/8"hole F/8280'-8335'(55')A110 FPH, 290 gpm/1960 psi on/1960 psi off, 94 rpm,Alk on/6-7k tq off.PU 150K/SO 60K/Rot94K,MW 8.9+;From 8290'to 8335',ABI showed 17 deg dog leg.Wash and Ream,changing Geo-Pilot tool deflection as needed to wipe out dog leg.;Drill 6-1/8"hole F/ 8335'-8478'(145')AROP 57.2 FPH, 290 gpm/1960 psi on/1960 psi off, 94 rpm,6-7k tq on/6-7k tq off.PU 150K/SO 60K/Rot94K,MW 8.9+;Note:Pump Low vis/Condet/Walnut seep with 200%increase at shakers.;Drill 6-1/8"hole F/8478'-8996'(518')AROP 86 FPH, 184 gpm/1040 psi on/980 psi off, 130 rpm,6.3k tq on/6k tq off.PU 155K/SO 80K/Rot107,MW 8.9.;Drill 6-1/8"hole F/8996'-9484'(488')AROP 81 FPH, 250 gpm/1580 psi on/1540 psi off,100 rpm,8k tq on/7k tq off.PU 163K/SO 58K/Rot95,MW 8.9,ECD=11, 300 bgg.;Drill 6-1/8"hole F/9484'-9830'(346')AROP 58 FPH, 242 gpm/1520 psi on/1500 psi off,145 rpm, 8.2k tq on/7k tq off.PU 163K/SO 58K/Rot95,MW 8.9,ECD=11, 450 bgg.;Pumped 35 bbl low wt,low vis sweep @ 9637'MD. Saw 100%increase in cutting(20 bbls late)fine sands. Currently drilling ahead @ 265°Az to close on plan.;Landed NB sands @ 8266'MD,6580'VS. Drilled in zone 100%thus far. 2'DTE fault @ 9,480'MD. BHA has a very strong right hand walk. Last svy @ 9720'MD, 132'right and 2'TVD from base of NB.;Hauled 461 bbls to MP G&I for total=902 bbls Hauled 0 bbls to 8-50 for total=1080 bbls Hauled 0 bbls from Vern Lake for total=520 bbls Hauled 462 bbls from L-Pad lake for total=1460 bbls;0 bbls daily losses for total=0 bbls. 4/21/2016 Drill 6-1/8"hole F/9830'-10267'(437')AROP 72.8 FPH, 247 gpm/1770 psi on/1760 psi off,150 rpm,9k tq on/7k tq off.PU 164K/SO 55K/Rot95K,MW 9.0, ECD=11.5, 250 bgg.;Drill 6-1/8"hole F/10267'-10763'(496')AROP 99.2 FPH, 250 gpm/1760 psi on/1750 psi off,150 rpm,9k tq on/9.5k tq off.PU 172K/SO 55K/Rot93,WOB 3-5K,MW 9.1,ECD=11.5, 880 bgg.;Pumped 35 bbl low vis sweep @ 10274'MD. Saw 50%increase in cutting mostly fine sands.At 10632' had 6000 units gas.Had increase in oil @ shakers.Increase MW to 9.1 ppg while drill ahead.;Drilled to 10,763',ABI showed 29deg micro DL from 10739'to 10750'.PU to 10,670',wash and ream to reduce DL severity. 250 gpm, 1725 psi, 145 rpm,9.4k tq. L/S orientation.;Drill 6-1/8"hole F/10763'-10835'(72') AROP 36 FPH, 200 gpm/1320 psi on/1290 psi off, 145 rpm,10k tq on/9.5k tq off.PU 172K/SO 55K/Rot96,WOB 3-5K,MW 9.1,ECD=11.2, 280 bgg.;Drill 6-1/8" hole F/10835'-11,115'(280')AROP 47 FPH, 200 gpm/1250 psi on/1210 psi off, 145 rpm,10k tq on/9.5k tq off.PU 172K/SO 55K/Rot96,WOB 3-5K,MW 9.1, ECD=10.9, 240 bgg.;Pump tandem sweep,to/hi vis 20/20 bbl @ 11,030'MD w/no increase in cuttings(on time). 4094 units cuttings gas @ 11,007'MD.;Last svy @ 10948'MD-50'Right and drilling @ base of NB sands(100%in zone).;Hauled 560 bbls to MP G&I for total=1462 bbls Hauled 0 bbls to B-50 for total=1080 bbls Hauled 0 bbls from Vern Lake for total=520 bbls Hauled 610 bbls from L-Pad lake for total=2070 bbls;Daily losses to formation 0 bbls for total=0 bbls 4/22/2016 Drill 6-1/8"hole F/11,115'-11,540'(425')AROP 65.4 FPH, 250 gpm/1820 psi on/11840 psi off, 120 rpm, 10k tq on/10k tq off.PU 177K/SO 55K/Rot96,WOB 3- 5K,MW 9.1,ECD=11.3.;Encounter 15°dog leg.Wash/ream to reduce DLS.;Drill 6-1/8"hole F/11540'-11821'(281')AROP 62.4 FPH, 238 gpm/1820 psi on/11840 psi off,120 rpm,10k tq on/10k tq off.PU 185K/SO 55K/Rot97,WOB 3-5K,MW 9.1,ECD=11.2.;Losses to well at 5-8 bph while drilling w/225 gpm/ECD 11.3.Had 20 bph dynamic loss rate when pumping 250 gpm.MW 9.1.;Drill 6-1/8"hole F/11821'-12026'(205')AROP 41 FPH, 204 gpm/1240 psi on/1180 psi off, 145 rpm,10k tq on/9.7k tq off.PU 185K/SO 55K/Rot97,WOB 3-5K,MW 8.95,ECD=10.9.;Wash and ream 18°micro dogleg. P/U and work pipe F/11,961'- T/11,975'MD @ 30 fph. 204 gpm,1240 psi on,1180 psi off,145 rpm,9.8k tq. 180 BGG, Limit on MWD tools is 14°DLS.;Unable to reduce dogleg on 1st attempt. P/U and begin time drilling again F/11,961'-T/11,975'MD to reduce hi micro dogleg w/same parameters. Orient TF @ L/S(70%deflection).;Last svy @ 11889'MD, 19'Right of plan and 1'below top of zone.;Hauled 746 bbls to MP G&I for total=2208 bbls Hauled 0 bbls to B-50 for total=1080 bbls Hauled 0 bbls from Vern Lake for total=520 bbls Hauled 825 bbls from L-Pad lake for total=2895 bbls;Daily losses to formation 92 bbls for total=92 bbls 4/23/2016 Continue time drilling again F/11,961' to reduce hi micro dogleg @ 30 fph. 204 gpm,1240 psi on, 1180 psi off, 145 rpm,9.8k tq. 180 BGG, Limit on MWD tools is 14°DLS. Orient TF @ L/S(70%deflection). Note:Swivel Packing leaking.Grease Packing.;Drill 6-1/8"hole F/12026'-12090', 204 gpm/1240 psi on/1180 psi off,145 rpm,10k tq on/9.7k tq off.PU 185K/SO 55K/Rot97,WOB 3-5K,MW 8.95,ECD=10.9.;Make connection @ 12090'.swivel packing leaking.Stand back 1 stand.MU head pin and 2"HP Hose.Circulate @ 3 bpm while C/O Swivel Packing and Service Rig.;Drill 6-1/8"hole F/12090'-12115', 250 gpm/1650 psi on/1610 psi off, 120 rpm,11-12k tq on/10k tq off.PU 188K/SO 55K/Rot95,WOB 5-10K,MW 8.95,ECD=11.1.;Drill 6-1/8"hole F/12115'-12367'(252), AROP 56 FPH 250 gpm/1940 psi on/1870 psi off,120 rpm, 12k tq on/12k tq off.PU 196K/SO 55K/Rot95,WOB 10-12K,MW 9.1,ECD=11.7.;Pumped 35 bbl low vis sweep @ 12260'with no increase @ shakers.@ 12,350' ECD increased 320 psi from 11.8 to 12.6 and pump pressure increased 280 psi from 1650 psi to 1970 psi over 30 minutes.;Back ream OOH from 12,367'to 10459'(20Stds)@ 275 gpm/2050 psi/150 rpm/11 K Tq/Rot 90K.;Circulate and condition hole @ 10459'MD. Rot and Recip 10459'to 10553'while conditioning hole. 284 gpm,2030 ICP,29%flow,150 rpm, 10k tq,50 bgg.;Pump 25 bbl Hi vis sweep w/no increase in cuttings. Circulated a total of 3x btm's up. Slight cuttings returned throughout clean up cycle. 11.59 ECD's. 190k up, 105k rot,55k dn w/no pumps.;TIH F/10459'-T/12365'MD. Tripped through sidetrack point with no issue(10763'). Ream and wash dn due to lack of string wt. 30 rpm,3 BPM,910 psi,14%flow. 75k dn while reaming dn.;Drill 6-1/8"hole F/12365'- 12435', 225 gpm/1890 psi on/1850 psi off, 110 rpm, 10.6k tq on/10k tq off.PU 190K/SO 55K/Rot 105k,WOB 5-10K,MW 9.05,ECD=11.78;Drilled out btm of zone @ 12,090'MD. We are currently drilling up in structure trying to find NB Sand to get back in zone. Sand may have pinched out.;Last svy @ 12,227'-1' below base of NB sand and 3.8'left of plan. Daily losses to formation 54 bbls for total=146 bbls;Hauled 397 bbls to MP H&I for total=2605 bbls Hauled 0 bbls to B-50 for total=1080 bbls Hauled 0 bbls from Vern Lake for total=520 bbls Hauled 425 bbls from L-Pad Lake for total=3320 bbls; 4/24/2016 Drill 6-1/8"hole F/12435'-12650', 250 gpm/2210 psi on/2220 psi off, 140 rpm, 11-12k tq on/10-11k tq off.PU 198K/SO 55K/Rot 93k,WOB 4-7K,MW 9.1, ECD=12.0.;Reenter NB Sands @ 12635'.Drilled out of zone for 545'before reentering NB Sand.;Drill 6-1/8"hole F/12650'-12905'(255')42 fph avg rop, 220 gpm/1910 psi on/1820 psi off, 110 rpm,11-12k tq on/10-11k tq off.PU 198K/SO 55K/Rot 93k,WOB 4-7K,MW 9.1,ECD=11.4.;Dropped out of zone @ 12790' and back in zone @ 12860'MD.;Drill 6-1/8"hole F/12905'-13430'(525')70 fph avg rop, 227 gpm/1620 psi on/1550 psi off, 110 rpm, 11.2k tq on/10.5k tq off.PU 210K/SO 55K/Rot 93k,WOB 4-7K,MW 9.1,ECD=11.4;Tighten screens on shakers last 400'and run slightly wet to reduce LGS and sand content for upcoming liner run.;CBU @ 13,430'MD. Rot/Recip pipe. 255 gpm,1870 psi,27%flow, 120 rpm, 11.5k tq,100 units bgg. Pump 30 bbl lo vis/to wt sweep(no increase). Final ECD's @ 11.3.;Obtain SPR's(see pump data). Final svy and monitor well(static). Prep floor fro backreaming operations(Isolate and R/D Geo span).;Backream out of hole F/13,430'-T/11,960'MD. 281 gpm, 2020 psi, 26%flow,100 rpm,12.5k tq, target max pulling speed 15 fpm,avg pulling speed 9.5 fpm.;Extrapolation to bit @ TD(13,430'MD/3525'ND)put us in middle of NB sand as per Geo and.5'left of plan.;Hauled 389 bbls to MP G&I for total= 2994 bbls Hauled 0 bbls to B-50 for total=1080 bbls Hauled 0 bbls from Vern Lake for total=520 bbls Hauled 525 bbls fom L-Pad lake for total=3845 bbls;Daily losses to formation 45 bbls for total=192 bbls 4/25/2016 ' Continue Back Ream out of hole F/11•T/8290'with no issues. 275 gpm/1890 psi/150 rpm,7 tq.;At 8290'Pump pressure increased 400 psi and ECD's 1 • @ 13.5.CBU from 8290'@ max rate and rotation.Hole unloaded 200%on all four shakers for 75 bbls(3500').Circulate clean.Had 1000 units max gas.;Continue to Backream OOH to 8102'kill rotary and pump OOH from 8102'to 8057'(Top of HWDP).Top of BHA hanging and packing off in window.Backream 40 rpm pulling slow from 8057'to 7909'.;Pump OOH from 7909'to 7726'(57'above TOW)with no issues.;Pump and sweep casing from 7726'with 30 bbls hi vis sweep @ 290 gpm/1860 psi/120 rpm/5K Tq. with 10%increase of fine mostly fine sands.Monitor well,well static.;Pump 20 bbls dry job,Drop 2.00"Drift down drill pipe. Blow Down Top Drive.;TOH on elevators from 7726'to 275'(BHA). Retrieved 2.0"drift on wire @ jars. 6 bbl loss over calculated to formation for total trip out.;L/D HWDP and jars. L/D flex DC's then download. B/O and L/D MWD tools. Flush,drain mtr and B/O bit. Bit grade=2,3,CT,A,X,I,BT,TD.;Drain stack and perform weekly function of BOP equipment. Note in IADC report.;Clean and clear rig floor. Bring tools to floor and R/U Weatherford Casing Equipment. Prep pipeshed. 141 total jts in shed. Static losses @ 2 BPH.;PJSM, M/U WIV(2 shear pin/1088 psi)assy. Check float(good). Run 4.5",13.5#,Vam HTTC liner as per detail(approved by Stan Porhola)F/surface-T/2590'MD. 8130 ft/lbs M/U tq.;Hauled 650 bbls to MP G&I for total=3644 bbls Hauled 0 bbls to B-50 for total=1080 bbls Hauled 0 bbls from Vern Lake for total=520 bbls Hauled 392 bbls from L-Pad lake for total=4237 bbls;Daily losses to formation 72 bbls for total=264 bbls HiIci Energy Company Composieport Well Name: MP J-23A Field: Milne Point County/State: ,Alaska (LAT/LONG): evation(RKB): API#: 50-029-22970-01-00 Spud Date: 4/13/2016 Job Name: 1511739C MP J-23A COMPLETION Contractor AFE#: AFE$: Activity Date Ops Summary 4/26/2016 Run 4.5", 13.5#,Vam HTTC liner as per detail. F/2590' T/5721 . 8130 fUlbs M/U TQ. P/U total 10-ICDs&3 swell packers.,R/U 2 3/8 inner string equipment&false table. Change handling equipment to 2 3/8.,P/U slick stick&2 3/8 T/5700'. Drifting 2 3/8 to 1.66.,Cont RIH&tag up @ 5719'MD w/inner string no-go. Set dn 3k(2x). Spaceout inner string 6.23'off no go. Drift all jewelry w/2.1". M/U swivel,"ZXP"packer w/inner string swivel,cup and space out pup assy.Mix and load"Pal Mix"in packer.,RIH w/4.5"F/5721'to 5777'MD. Wait 30 min for"Pal Mix"to setup. L/D Packer"make up swivel".Clear ice from derrick(freezing rain). Circulate 1.5 inner string vol,2 bpm,780 psi,7%flow.,B/D TDS. RIH w/liner on drill pipe out of derrick F/5777'-T/10,552'MD. Obtain parameters prior to exiting window-155k up,77k dn,108k rot, 10 rpm/5k tq,20 rpm/6.5k tq,30 rpm,7k tq. No issues exiting window. RIH @ max rate 1 min/per stand(BOT). Ran 40 stds dp out of derrick,9 DC's out of shed,12 hwdp out of shed,4 stds hwdp out of derrick before unable to trip in on elevators. 2.1"drift,BOP drill while tripping(in casing)w/1 min,26 sec response. Sym ops-Clean pits,load w/ 9.1#brine and prep for upcoming displacement.,Wash and Ream 4.5"liner F/10,552'-T/13,102'MD. 1 bpm,480 psi,10-15 rpm,7-10k tq. 4/27/2016 Wash&ream down @ 7-10 K TQ, 10-15 RPM,Circ @ 1 bpm 510 psi.F/13310'T/13430'.Tag TD on depth.,Attempt to rot while displacing but maxed out @ 12k tq. Stage up pumps to 3 bpm @ 190 psi.Circ 25 bbl spacer followed by 9.1 ppg brine. Circ sts. Getting dirty brine back.,Shut down and drop setting ball. Pump down @ 3 bpm and slow to 2 bpm on the last 50 bbl. Ball on seat @ 780 stks. Pressure up and hold 500 over @ 1700 psi.Good. continue to pressure up to 3500 psi to set hanger. Set down with string wt. Rot&attempt to set packer while setting down. Attempt to test back side to 1500 psi. Unable to get over 150 psi.,Open up and check movement again.Unable to get wt back down to packer. Looks like inner string not going back down. Decide to continue on with operations. P/U&Close PPIT tool.Circ 6 Liner volumes while dumping returns.Still coming back dirty.,Monitor well. POOH L/D 4"dp F/13430'T/10584'MD.,TOH laying down F/10,584'-T/5777'MD. Rack back 4"HWDP and 4-3/4"steel spiral DC's. Continue laying down 4"drill pipe to LRT. LRT confirmed hgr hydraulic set but indicator was not sheared for setting pkr element(Inadequate wt transfer).,M/U safety jt and stage in shed. L/D Baker LRT. R/U Weatherford casing and L/D 2- 3/8"drill pipe F/5,777'-T/surface. 23 bbl loss for total trip. R/D Weatherford casing and safety jt.,M/U BOT seal assy(26.39')w/bumper sub. TIH out of derrick F/26.39'-T/ 1250'MD. .,Hauled 1307 bbls to MP G&I for total=5032 bbls Hauled 0 bbls to B-50 for total=1080 bbls Hauled 0 bbls from Vern Lake for total=520 bbls Hauled 325 bbls from L-Pad lake for total=4612 bbls 4/28/2016 RIH with baker seal assembly&dog sub T/7660'.,Break circ @ 1 bpm.Engage seals.Slack off and no go out on depth. Work wt down on packer.Good indication of packer set. Attempt annulus test to 1500 psi.Bled down 200 psi in 10 min.Steady bleed down.Work pipe&circ back down.Attempt test after checking all surface equipment.Same bleed down. ROT&set down on LT. Decide seals were damaged on trip in.,Circ above liner top&8 bpm working pipe to clean liner top. Finish circulating STS while slipping and cutting drilling line. Dumping all returns.Clean fluid back to surface.,POOH L/D 4"DP F/7660'T/ surface.L/D 9 DC&24 HWDP. Inspect running tools. Good indication of shear on dog sub and showed damaged seals(see"0"drive/photos). 44.6 bbl loss for total trip out.,Drain stack and pull wear ring. Flush load shoulder in wellhead. Bring tools to rig floor. M/U landing jt w/xo's and hanger. Dummy run hanger (29.7'). L/D same,R/U Weatherford casing equipment. PJSM,M/U bullet seal assy and run 4.5"Supermax,12.6#,L-80 tubing as per detail F/surface-T/6790' MD. Check tq first 5(3200 ft/lbs)opt for makeup. Static losses avg 2 bph. Daily losses to formation 86 bbls for total=499 bbls,Hauled 290 bbls MP G&l for total=5322 bbls Hauled 0 bbls to GPB G&I for total=0 bbls Hauled 0 bbls to B-50 for total=1080 bbls Hauled 0 bbls from Vern Lake for total=520 bbls L Hauled 525 bbls from L-Pad Lake for total=5137 bbls 4/29/2016 Run 4.5"Supermax, 12.6#,L-80 tubing as per detail F/6790'T/7600'. Wash down last two stands @ 2 bpm. Engage seals on depth @ 7660'. Set down on no go.Test annulus&packer to 1500 psi for 10 min.Good. Bleed down.,Space out. Lay down two joints and P/U one short joint not in the tally for a total joint count of 233. M/U hanger,pup&XO.,R/U&reverse circ 88 bbl.01 %Baricor 100, 9.1 ppg KCL Brine. Chase with 66 bbl brine. Swap&pump 10 bbl down the tubing to clear the ball seat. Land hanger.RILDS.,Test annulus to 500 psi.5 min,Good. R/U&pressure up on the tubing to 2500 psi. Bump up due to air in the tubing.,Bleed down and check surface equipment.Pump up senators. Re test.Good.2500 psi 30 min.Bleed to 1000 psi.Test annulus to 3000 psi for 30 min. Good. Bleed off annulus and tubing.Monitor.Static.Pressure up and shear out GLM @ 2600 psi.Pump 2 bpm @ 860 psi. Shut down.R/D circ equipment.,lnstall TWC. N/D BOP equipment and secure for rig move.,N/U tree. Test void 500 low/5 min hold, 5000 high/10 min hold(test good). Test internal T/5000(test good). Pull TWC.,R/U little red and freeze protect via IA @ 1.6 BPM,1900 psi fcp w/a total of 105 bbls diesel pumped. B/D lines and R/D same. Secure tree,install gauges and cap flanges. Clean up tree and cellar in prep for turnover to production.,R/D all service lines and prep floor for skid. Prep Rockwasher and demob same. Skid floor and secure for move. Rig released @ 06:00 hrs.,Hauled 125 bbls to MP G&I for total=5447 bbls Hauled 0 bbls to B-50 for total=1080 bbls Hauled 0 bbls from Vern Lake for total=520 bbls Hauled 25 bbls from L-Pad lake for total=5162 bbls Daily losses 132 bbls for total losses to formation=631 bbls • • Hilcorp Energy Company Milne Point M Pt J Pad MPJ-23A 50-029-22970-01 500292297001 I : 1 ! c + rr drilling Definitive Survey Report 29 April, 2016 tis' ,e .,r } iiin f HALLIBURTON Sperry Qrdi n • Halliburton • Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPJ-23 Project: Milne Point TVD Reference: MPJ-23A-Doyon 14 @ 69.80usft(Doyon 14) Site: M Pt J Pad MD Reference: MPJ-23A-Doyon 14 @ 69.80usft(Doyon 14) Well: MPJ-23 North Reference: True Wellbore: MPJ-23A Survey Calculation Method: Minimum Curvature Design: MPJ-23A 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 MPJ-23 Well Position +N/-S 0.00 usft Northing: 6,015,082.24 usft Latitude: 70°27'7.009 N +EI-W 0.00 usft Easting: 551,926.95 usft Longitude: 149°34'34.718 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 36.10 usft Wellbore MPJ-23A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 4/22/2016 18.59 81.06 57,499 L Design MPJ-23A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,749.00 Vertical Section: Depth From(TVD) +NI-S +E/-W Direction (usft) (usft) (usft) (0) 33.70 0.00 0.00 272.55 Survey Program Date 4/29/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 112.76 7,749.00 MPJ-23(MPJ-23) MWD R2 Fixed:v2:standard declination 05/27/2004 7,783.00 13,356.32 MWD+IFR2+MS+sag(MPJ-23A) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 04/11/2016 Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +El-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/700') (ft) Survey Tool Name 33.70 0.00 0.00 33.70 -36.10 0.00 0.00 6,015,082.24 551,926.95 0.00 0.00 UNDEFINED 112.76 0.13 187.79 112.76 42.96 -0.09 -0.01 6,015,082.15 551,926.94 0.16 0.01 MWD R2(1) 235.28 0.30 188.34 235.28 165.48 -0.54 -0.08 6,015,081.70 551,926.88 0.14 0.05 MWD R2(1) 325.17 1.34 270.44 325.16 255.36 -0.77 -1.16 6,015,081.46 551,925.79 1.48 1.13 MWD R2(1) 420.83 3.52 268.81 420.73 350.93 -0.82 -5.22 6,015,081.38 551,921.74 2.28 5.18 MWD R2(1) 511.88 4.64 280.67 511.55 441.75 -0.20 -11.63 6,015,081.96 551,915.32 1.53 11.61 MWD R2(1) 603.88 6.72 272.07 603.09 533.29 0.69 -20.67 6,015,082.78 551,906.28 2.44 20.68 MWD R2(1) 697.73 10.76 276.00 695.83 626.03 1.80 -34.87 6,015,083.80 551,892.07 4.35 34.92 MWD R2(1) 791.38 12.68 275.10 787.53 717.73 3.63 -53.81 6,015,085.49 551,873.12 2.06 53.92 MWD R2(1) 881.05 14.26 274.00 874.73 804.93 5.27 -74.63 6,015,086.99 551,852.29 1.78 74.79 MWD R2(1) 974.58 16.54 272.97 964.89 895.09 6.77 -99.42 6,015,088.31 551,827.50 2.46 99.62 MWD R2(1) 1,063.61 19.12 276.44 1,049.64 979.84 9.06 -126.57 6,015,090.42 551,800.33 3.13 126.85 MWD R2(1) 1,160.77 21.70 277.20 1,140.70 1,070.90 13.10 -160.21 6,015,094.22 551,766.67 2.67 160.63 MWD R2(1) 4/29/2016 7:57:09PM Page 2 COMPASS 5000.1 Build 73 • Halliburton 0 Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPJ-23 Project: Milne Point TVD Reference: MPJ-23A-Doyon 14 @ 69.80usft(Doyon 14) Site: M Pt J Pad MD Reference: MPJ-23A-Doyon 14 @ 69.80usft(Doyon 14) Well: MPJ-23 North Reference: True Wellbore: MPJ-23A Survey Calculation Method: Minimum Curvature Design: MPJ-23A Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (') (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 1,253.11 25.19 277.11 1,225.40 1,155.60 17.67 -196.66 6,015,098.54 551,730.20 3.78 197.25 MIND R2(1) 1,346.19 28.86 273.88 1,308.31 1,238.51 21.64 -238.74 6,015,102.22 551,688.09 4.25 239.47 MWD R2(1) 1,440.41 32.24 273.67 1,389.44 1,319.64 24.79 -286.52 6,015,105.03 551,640.29 3.59 287.34 MIND R2(1) 1,533.77 34.55 272.25 1,467.38 1,397.58 27.43 -337.83 6,015,107.31 551,588.97 2.61 338.72 MWD R2(1) 1,625.61 38.10 274.03 1,541.36 1,471.56 30.44 -392.14 6,015,109.94 551,534.65 4.03 393.10 MIND R2(1) 1,719.42 41.61 276.08 1,613.37 1,543.57 35.77 -452.00 6,015,114.86 551,474.75 3.99 453.15 MWD R2(1) 1,812.03 46.90 275.75 1,679.68 1,609.88 42.42 -516.26 6,015,121.06 551,410.45 5.72 517.64 MWD R2(1) 1,906.22 49.33 276.67 1,742.56 1,672.76 50.02 -585.97 6,015,128.17 551,340.70 2.68 587.61 MWD R2(1) 1,999.05 48.92 276.72 1,803.31 1,733.51 58.20 -655.68 6,015,135.87 551,270.94 0.44 657.62 MWD R2(1) 2,092.27 49.84 276.83 1,863.99 1,794.19 66.55 -725.94 6,015,143.72 551,200.63 0.99 728.19 MWD R2(1) 2,183.09 45.61 277.68 1,925.07 1,855.27 75.02 -792.59 6,015,151.73 551,133.93 4.71 795.15 MWD R2(1) 2,276.87 47.60 277.01 1,989.50 1,919.70 83.72 -860.17 6,015,159.96 551,066.30 2.18 863.05 MWD R2(1) 2,369.91 51.43 276.66 2,049.90 1,980.10 92.14 -930.42 6,015,167.88 550,996.00 4.13 933.60 MWD R2(1) 2,462.75 56.46 275.71 2,104.52 2,034.72 100.20 -1,005.02 6,015,175.43 550,921.35 5.48 1,008.48 MWD R2(1) 2,555.55 60.76 273.71 2,152.85 2,083.05 106.67 -1,083.95 6,015,181.35 550,842.39 4.99 1,087.62 MWD R2(1) 2,648.97 62.20 271.43 2,197.46 2,127.66 110.34 -1,165.94 6,015,184.44 550,760.38 2.64 1,169.69 MWD R2(1) 2,742.79 68.92 273.64 2,236.26 2,166.46 114.16 -1,251.21 6,015,187.67 550,675.10 7.48 1,255.05 MWD R2(1) 2,834.50 71.98 274.08 2,266.94 2,197.14 119.98 -1,337.43 6,015,192.89 550,588.85 3.37 1,341.44 MIND R2(1) 2,926.98 73.86 274.39 2,294.10 2,224.30 126.51 -1,425.58 6,015,198.80 550,500.66 2.06 1,429.80 MWD R2(1) 3,019.04 73.95 270.04 2,319.64 2,249.84 129.93 -1,513.94 6,015,201.60 550,412.29 4.54 1,518.22 MWD R2(1) 3,110.28 74.75 271.28 2,344.25 2,274.45 130.94 -1,601.79 6,015,202.00 550,324.44 1.58 1,606.03 MWD R2(1) 3,204.16 73.73 270.64 2,369.75 2,299.95 132.46 -1,692.13 6,015,202.89 550,234.10 1.27 1,696.35 MWD R2(1) 3,269.45 73.30 271.05 2,388.27 2,318.47 133.38 -1,754.73 6,015,203.38 550,171.51 0.89 1,758.92 MWD R2(1) 3,296.34 69.92 271.69 2,396.76 2,326.96 133.99 -1,780.23 6,015,203.81 550,146.00 12.77 1,784.43 MWD R2(1) 3,388.91 69.84 271.37 2,428.60 2,358.80 136.31 -1,867.12 6,015,205.52 550,059.10 0.34 1,871.34 MWD R2(1) 3,481.75 73.52 270.68 2,457.78 2,387.98 137.88 -1,955.23 6,015,206.48 549,971.00 4.03 1,959.43 MWD R2(1) 3,574.42 77.07 270.65 2,481.30 2,411.50 138.92 -2,044.84 6,015,206.89 549,881.39 3.83 2,049.00 MWD R2(1) 3,667.23 77.80 270.59 2,501.49 2,431.69 139.90 -2,135.42 6,015,207.24 549,790.81 0.79 2,139.53 MWD R2(1) 3,753.36 76.16 270.85 2,520.89 2,451.09 140.95 -2,219.33 6,015,207.71 549,706.91 1.93 2,223.40 MWD R2(1) 3,850.76 73.89 270.22 2,546.06 2,476.26 141.83 -2,313.41 6,015,207.94 549,612.83 2.41 2,317.43 MIND R2(1) 3,943.21 71.68 271.85 2,573.42 2,503.62 143.42 -2,401.70 6,015,208.91 549,524.55 2.92 2,405.70 MIND R2(1) 4,035.79 74.66 272.28 2,600.22 2,530.42 146.62 -2,490.24 6,015,211.49 549,435.99 3.25 2,494.30 MWD R2(1) 4,129.38 75.21 271.58 2,624.55 2,554.75 149.66 -2,580.56 6,015,213.90 549,345.66 0.93 2,584.67 MWD R2(1) 4,222.00 73.83 273.38 2,649.27 2,579.47 153.52 -2,669.73 6,015,217.14 549,256.47 2.39 2,673.92 MWD R2(1) 4,314.71 73.98 274.38 2,674.97 2,605.17 159.54 -2,758.60 6,015,222.54 549,167.57 1.05 2,762.97 MWD R2(1) 4,408.13 74.89 273.96 2,700.04 2,630.24 166.09 -2,848.36 6,015,228.46 549,077.78 1.07 2,852.93 MWD R2(1) 4,501.04 73.13 272.80 2,725.63 2,655.83 171.36 -2,937.51 6,015,233.11 548,988.60 2.24 2,942.23 MWD R2(1) 4,593.85 72.69 271.82 2,752.91 2,683.11 174.93 -3,026.15 6,015,236.07 548,899.95 1.12 3,030.94 MWD R2(1) 4,686.29 73.69 270.00 2,779.64 2,709.84 176.34 -3,114.63 6,015,236.85 548,811.47 2.17 3,119.39 MWD R2(1) 4,779.51 70.91 269.38 2,807.98 2,738.18 175.86 -3,203.42 6,015,235.76 548,722.69 3,05 3,208.07 MWD R2(1) 4/29/2016 7:57:09PM Page 3 COMPASS 5000.1 Build 73 0 Halliburton • Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPJ-23 Project: Milne Point TVD Reference: MPJ-23A-Doyon 14 @ 69.80usft(Doyon 14) Site: M Pt J Pad MD Reference: MPJ-23A-Doyon 14 @ 69.80usft(Doyon 14) Well: MPJ-23 North Reference: True Wellbore: MPJ-23A Survey Calculation Method: Minimum Curvature Design: MPJ-23A Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) 0100') (ft) Survey Tool Name 4,872.15 73.18 270.82 2,836.54 2,766.74 176.02 -3,291.54 6,015,235.30 548,634.58 2.86 3,296.11 MWD R2(1) 4,964.70 75.61 269.68 2,861.43 2,791.63 176.40 -3,380.67 6,015,235.07 548,545.46 2.88 3,385.17 MWD R2(1) 5,057.97 76.34 270.61 2,884.04 2,814.24 176.63 -3,471.16 6,015,234.66 548,454.98 1.24 3,475.58 MWD R2(1) 5,152.99 77.38 271.02 2,905.64 2,835.84 177.95 -3,563.68 6,015,235.34 548,362.46 1.17 3,568.07 MWD R2(1) 5,244.21 78.23 272.64 2,924.91 2,855.11 180.80 -3,652.79 6,015,237.56 548,273.34 1.97 3,657.22 MWD R2(1) 5,336.30 77.09 271.82 2,944.59 2,874.79 184.30 -3,742.68 6,015,240.44 548,183.44 1.51 3,747.18 MWD R2(1) 5,429.68 78.25 270.70 2,964.53 2,894.73 186.30 -3,833.88 6,015,241.81 548,092.23 1.71 3,838.38 MWD R2(1) 5,521.50 77.10 271.52 2,984.13 2,914.33 188.04 -3,923.57 6,015,242.92 548,002.55 1.53 3,928.05 MWD R2(1) 5,614.26 75.98 270.95 3,005.72 2,935.92 189,99 -4,013.76 6,015,244.24 547,912.35 1.35 4,018.24 MWD R2(1) 5,706.75 76.78 270.05 3,027.50 2,957.70 190.77 -4,103.64 6,015,244.39 547,822.48 1.28 4,108.07 MWD R2(1) 5,799.88 75.62 270.09 3,049.72 2,979.92 190.88 -4,194.08 6,015,243.87 547,732.05 1.25 4,198.42 MWD R2(1) 5,891.59 76.16 269.38 3,072.07 3,002.27 190.47 -4,283.02 6,015,242.84 547,643.12 0.95 4,287.26 MWD R2(1) 5,983.86 77.14 269.86 3,093.38 3,023.58 189.87 -4,372.80 6,015,241.62 547,553.36 1.18 4,376.91 MWD R2(1) 6,077.32 76.25 270.20 3,114.89 3,045.09 189.92 -4,463.75 6,015,241.03 547,462.42 1.02 4,467.78 MWD R2(1) 6,170.50 73.23 268.86 3,139.41 3,069.61 189.19 -4,553.63 6,015,239.68 547,372.56 3.53 4,557.53 MWD R2(1) 6,262.62 73.50 269.53 3,165.78 3,095.98 187.95 -4,641.88 6,015,237.82 547,284.32 0.76 4,645.65 MWD R2(1) 6,357.70 73.57 268.87 3,192.73 3,122.93 186.68 -4,733.05 6,015,235.92 547,193.17 0.67 4,736.67 MWD R2(1) 6,449.14 77.28 269.39 3,215.74 3,145.94 185.34 -4,821.52 6,015,233.96 547,104.72 4.09 4,825.00 MWD R2(1) 6,543.26 77.64 267.63 3,236.17 3,166.37 182.95 -4,913.36 6,015,230.93 547,012.91 1.86 4,916.64 MWD R2(1) 6,636.17 75.80 269.24 3,257.52 3,187.72 180.47 -5,003.75 6,015,227.83 546,922.55 2.60 5,006.82 MWD R2(1) 6,728.99 76.90 269.37 3,279.42 3,209.62 179.38 -5,093.94 6,015,226.10 546,832.38 1.19 5,096.88 MWD R2(1) 6,822.22 76.75 269.56 3,300.67 3,230.87 178.53 -5,184.71 6,015,224.62 546,741.62 0.26 5,187.52 MWD R2(1) 6,913.20 75.46 270.74 3,322.52 3,252.72 178.76 -5,273.02 6,015,224.24 546,653.32 1.90 5,275.76 MWD R2(1) 7,007.33 74.04 271.96 3,347.28 3,277.48 180.90 -5,363.81 6,015,225.74 546,562.53 1.96 5,366.55 MWD R2(1) 7,100.32 73.98 272.40 3,372.89 3,303.09 184.30 -5,453.14 6,015,228.52 546,473.19 0.46 5,455.94 MWD R2(1) 7,194.55 74.39 272.64 3,398.58 3,328.78 188.28 -5,543.71 6,015,231.87 546,382.60 0.50 5,546.60 MWD R2(1) 7,285.92 73.93 272.24 3,423.52 3,353.72 192.03 -5,631.53 6,015,235.00 546,294.76 0.66 5,634.50 MWD R2(1) 7,378.97 74.86 272.85 3,448.55 3,378.75 196.01 -5,721.06 6,015,238.36 546,205.21 1.18 5,724.12 MWD R2(1) 7,471.84 74.91 272.46 3,472.76 3,402.96 200.16 -5,810.62 6,015,241.89 546,115.64 0.41 5,813.78 MWD R2(1) 7,564.85 75.11 272.10 3,496.82 3,427.02 203.73 -5,900.40 6,015,244.84 546,025.85 0.43 5,903.62 MWD R2(1) 7,657.48 75.51 272.65 3,520.31 3,450.51 207.45 -5,989.92 6,015,247.93 545,936.31 0.72 5,993.22 MWD R2(1) 7,749.25 75.11 272.04 3,543.58 3,473.78 211.08 -6,078.62 6,015,250.94 545,847.60 0.78 6,081.99 MWD R2(1) 7,783.00 75.00 272.33 3,552.29 3,482.49 212.32 -6,111.20 6,015,251.96 545,815.01 0.89 6,114.60 MWD+IFR2+MS+sag(2) 7,840.75 76.10 274.79 3,566.70 3,496.90 215.80 -6,167.01 6,015,255.04 545,759.18 4.54 6,170.51 MWD+IFR2+MS+sag(2) 7,934.54 77.30 278.85 3,588.28 3,518.48 226.64 -6,257.62 6,015,265.25 545,668.51 4.40 6,261.50 MWD+IFR2+MS+sag(2) 8,027.71 79.76 282.84 3,606.82 3,537.02 243.83 -6,347.27 6,015,281.81 545,578.75 4.96 6,351.83 MWD+IFR2+MS+sag(2) 8,122.18 81.89 287.00 3,621.88 3,552.08 267.85 -6,437.35 6,015,305.20 545,488.51 4.90 6,442.90 MWD+IFR2+MS+sag(2) 8,215.68 85.62 287.44 3,632.05 3,562.25 295.36 -6,526.12 6,015,332.09 545,399.57 4.02 6,532.80 MWD+IFR2+MS+sag(2) 8,308.58 86.23 287.25 3,638.66 3,568.86 322.98 -6,614.57 6,015,359.09 545,310.93 0.69 6,622.39 MWD+IFR2+MS+sag(2) 8,402.75 87.28 288.01 3,643.99 3,574.19 351.46 -6,704.17 6,015,386.94 545,221.14 1.38 6,713.17 MWD+IFR2+MS+sag(2) 4/29/2016 7:57:09PM Page 4 COMPASS 5000.1 Build 73 • Halliburton • Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPJ-23 Project: Milne Point TVD Reference: MPJ-23A-Doyon 14 @ 69.80usft(Doyon 14) Site: M Pt J Pad MD Reference: MPJ-23A-Doyon 14 @ 69.80usft(Doyon 14) Well: MPJ-23 North Reference: True Wellbore: MPJ-23A Survey Calculation Method: Minimum Curvature Design: MPJ-23A Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (1100') (ft) Survey Tool Name 8,496.67 89.08 289.53 3,646.97 3,577.17 381.66 -6,793.04 6,015,416.52 545,132.07 2.51 6,803.30 MWD+IFR2+MS+sag(2) 8,587.03 90.43 291.21 3,647.36 3,577.56 413.11 -6,877.75 6,015,447.38 545,047.16 2.39 6,889.32 MWD+IFR2+MS+sag(2) 8,678.94 90.74 288.95 3,646.42 3,576.62 444.67 -6,964.06 6,015,478.33 544,960.64 2.48 6,976.95 MWD+IFR2+MS+sag(2) 8,777.55 92.41 288.88 3,643.71 3,573.91 476.62 -7,057.31 6,015,509.63 544,867.18 1.70 7,071.52 MWD+IFR2+MS+sag(2) 8,871.17 89.63 287.40 3,642.04 3,572.24 505.76 -7,146.25 6,015,538.14 544,778.04 3.36 7,161.67 MWD+IFR2+MS+sag(2) 8,968.05 90.06 286.63 3,642.30 3,572.50 534.11 -7,238.89 6,015,565.84 544,685.22 0.91 7,255.48 MWD+IFR2+MS+sag(2) 9,060.50 88.76 287.27 3,643.25 3,573.45 561.06 -7,327.31 6,015,592.17 544,596.62 1.57 7,345.02 MWD+IFR2+MS+sag(2) 9,156.95 86.54 285.75 3,647.21 3,577.41 588.44 -7,419.70 6,015,618.91 544,504.05 2.79 7,438.53 MWD+IFR2+MS+sag(2) 9,251.71 90.19 283.81 3,649.91 3,580.11 612.60 -7,511.27 6,015,642.43 544,412.32 4.36 7,531.09 MWD+IFR2+MS+sag(2) 9,344.99 91.73 278.50 3,648.35 3,578.55 630.64 -7,602.74 6,015,659.82 544,320.74 5.93 7,623.27 MWD+IFR2+MS+sag(2) 9,439.13 91.73 270.77 3,645.50 3,575.70 638.23 -7,696.45 6,015,666.77 544,226.98 8.21 7,717.23 MWD+IFR2+MS+sag(2) 9,533.39 93.21 264.78 3,641.44 3,571.64 634.58 -7,790.51 6,015,662.46 544,132.96 6.54 7,811.03 MWD+IFR2+MS+sag(2) 9,627.46 88.39 264.54 3,640.12 3,570.32 625.83 -7,884.14 6,015,653.06 544,039.41 5.13 7,904.17 MWD+IFR2+MS+sag(2) 9,720.45 88.03 264.98 3,643.03 3,573.23 617.34 -7,976.69 6,015,643.93 543,946.92 0.61 7,996.26 MWD+IFR2+MS+sag(2) 9,813.68 91.05 267.17 3,643.78 3,573.98 610.96 -8,069.68 6,015,636.90 543,853.99 4.00 8,088.88 MWD+IFR2+MS+sag(2) 9,908.70 92.16 267.14 3,641.12 3,571.32 606.25 -8,164.55 6,015,631.52 543,759.17 1.17 8,183.44 MWD+IFR2+MS+sag(2) 10,002.90 91.36 267.44 3,638.22 3,568.42 601.80 -8,258.60 6,015,626.42 543,665.16 0.91 8,277.19 MWD+IFR2+MS+sag(2) 10,097.55 91.30 263.55 3,636.02 3,566.22 594.37 -8,352.91 6,015,618.33 543,570.91 4.11 8,371.08 MWD+IFR2+MS+sag(2) 10,192.44 94.14 264.26 3,631.52 3,561.72 584.30 -8,447.15 6,015,607.61 543,476.75 3.08 8,464.78 MWD+IFR2+MS+sag(2) 10,286.90 91.97 264.33 3,626.49 3,556.69 574.93 -8,541.00 6,015,597.58 543,382.98 2.30 8,558.12 MWD+IFR2+MS+sag(2) 10,383.04 91.60 266.09 3,623.49 3,553.69 566.90 -8,636.75 6,015,588.89 543,287.29 1.87 8,653.42 MWD+IFR2+MS+sag(2) 10,476.77 91.30 268.42 3,621.12 3,551.32 562.42 -8,730.34 6,015,583.76 543,193.75 2.51 8,746.72 MWD+IFR2+MS+sag(2) 10,570,26 90.62 268.93 3,619.55 3,549.75 560.25 -8,823.79 6,015,580.94 543,100.32 0.91 8,839.98 MWD+IFR2+MS+sag(2) 10,663.89 91.61 271.15 3,617.73 3,547.93 560.32 -8,917.40 6,015,580.36 543,006.73 2.60 8,933.50 MWD+IFR2+MS+sag(2) 10,673.00 91.61 271.15 3,617.48 3,547.68 560.50 -8,926.50 6,015,580.47 542,997.62 0.00 8,942.60 MWD+IFR2+MS+sag(2) 10,759,25 91.91 267.24 3,614.83 3,545.03 559.29 -9,012.69 6,015,578.66 542,911.46 4.54 9,028.64 MWD+IFR2+MS+sag(2) 10,852.42 91.97 266.59 3,611.67 3,541.87 554.28 -9,105.67 6,015,573.01 542,818.52 0.70 9,121.31 MWD+IFR2+MS+sag(2) 10,948.06 88.89 266.03 3,610.95 3,541.15 548.13 -9,201.09 6,015,566.19 542,723.15 3.27 9,216.37 MWD+IFR2+MS+sag(2) 11,041.72 92.04 267.35 3,610.19 3,540.39 542.72 -9,294.58 6,015,560.13 542,629.71 3.65 9,309.52 MWD+IFR2+MS+sag(2) 11,134.41 92.78 264.17 3,606.30 3,536.50 535.87 -9,386.92 6,015,552.64 542,537.43 3.52 9,401.47 MWD+IFR2+MS+sag(2) 11,229.94 92.65 265.64 3,601.77 3,531.97 527.40 -9,481.97 6,015,543.51 542,442.46 1.54 9,496.04 MWD+IFR2+MS+sag(2) 11,326.20 91.54 265.74 3,598.25 3,528.45 520.17 -9,577.89 6,015,535.61 542,346.60 1.16 9,591.55 MWD+IFR2+MS+sag(2) 11,419.77 91.11 267.21 3,596.09 3,526.29 514.42 -9,671.25 6,015,529.21 542,253.28 1.64 9,684.56 MWD+IFR2+MS+sag(2) 11,513.99 93.34 269.70 3,592.43 3,522.63 511.88 -9,765.35 6,015,526.01 542,159.21 3.55 9,778.46 MWD+IFR2+MS+sag(2) 11,609.41 92.78 271.33 3,587.34 3,517.54 512.74 -9,860.63 6,015,526.21 542,063.94 1.80 9,873.68 MWD+IFR2+MS+sag(2) 11,702.69 92.35 272.57 3,583.16 3,513.36 515.91 -9,953.76 6,015,528.73 541,970.80 1.41 9,966.86 MWD+IFR2+MS+sag(2) 11,797.09 92.66 273.41 3,579.03 3,509.23 520.83 -10,047.94 6,015,532.99 541,876.60 0.95 10,061.16 MWD+IFR2+MS+sag(2) 11,889.23 92.34 272.87 3,575.02 3,505.22 525.87 -10,139.86 6,015,537.39 541,784.66 0.68 10,153.21 MWD+IFR2+MS+sag(2) 11,983.35 89.38 269.00 3,573.60 3,503.80 527.40 -10,233.92 62015,538.27 541,690.59 5.18 10,247.25 MWD+IFR2+MS+sag(2) 12,078.79 86.17 265.27 3,577.31 3,507.51 522.64 -10,329.14 6,015,532.84 541,595.42 5.15 10,342.17 MWD+IFR2+MS+sag(2) 4/29/2016 7:57:09PM Page 5 COMPASS 5000.1 Build 73 • Halliburton • Definitive Survey Report .... .. ....... .. . Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPJ-23 Project: Milne Point TVD Reference: MPJ-23A-Doyon 14 @ 69.80usft(Doyon 14) Site: M Pt J Pad MD Reference: MPJ-23A-Doyon 14 @ 69.80usft(Doyon 14) Well: MPJ-23 North Reference: True Wellbore: MPJ-23A Survey Calculation Method: Minimum Curvature Design: MPJ-23A Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Ml TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 12,173.20 89.63 265.21 3,580.77 3,510.97 514.81 -10,423.15 6,015,524.36 541,501.48 3.67 10,435.73 MWD+IFR2+MS+sag(2) 12,267.84 93.40 265.73 3,578.27 3,508.47 507.34 -10,517.44 6,015,516.24 541,407.25 4.02 10,529.60 MWD+IFR2+MS+sag(2) 12,361.47 90.68 266.84 3,574.93 3,505.13 501.28 -10,610.81 6,015,509.52 541,313.93 3.14 10,622.60 MWD+IFR2+MS+sag(2) 12,455.77 93.21 269.50 3,571.73 3,501.93 498.27 -10,704.99 6,015,505.86 541,219.79 3.89 10,716.56 MWD+IFR2+MS+sag(2) 12,551.17 94.88 271.93 3,565.00 3,495.20 499.45 -10,800.13 6,015,506.38 541,124.64 3.09 10,811.66 MWD+IFR2+MS+sag(2) 12,645.15 94.88 272.97 3,557.01 3,487.21 503.46 -10,893.69 6,015,509.73 541,031.08 1.10 10,905.30 MWD+IFR2+MS+sag(2) 12,740.17 91.05 271.69 3,552.09 3,482.29 507.31 -10,988.48 6,015,512.92 540,936.27 4.25 11,000.17 MWD+IFR2+MS+sag(2) 12,834.22 93.03 268.14 3,548.74 3,478.94 507.18 -11,082.45 6,015,512.13 540,842.31 4.32 11,094.04 MWD+IFR2+MS+sag(2) 12,928.68 92.10 269.59 3,544.52 3,474.72 505.31 -11,176.80 6,015,509.61 540,747.99 1.82 11,188.21 MWD+IFR2+MS+sag(2) 13,023.37 92.53 271.01 3,540.69 3,470.89 505.80 -11,271.40 6,015,509.44 540,653.39 1.57 11,282.75 MWD+IFR2+MS+sag(2) 13,117.25 91.85 271.92 3,537.10 3,467.30 508.20 -11,365.18 6,015,511.19 540,559.60 1.21 11,376.54 MWD+IFR2+MS+sag(2) 13,211.07 92.04 272.29 3,533.92 3,464.12 511.64 -11,458.89 6,015,513.98 540,465.89 0.44 11,470.30 MWD+IFR2+MS+sag(2) 13,305.45 92.22 272.50 3,530.41 3,460.61 515.59 -11,553.12 6,015,517.26 540,371.64 0.29 11,564.62 MWD+IFR2+MS+sag(2) 13,356.32 92.04 272.37 3,528.52 3,458.72 517.75 -11,603.91 6,015,519.07 540,320.84 0.44 11,615.45 MWD+IFR2+MS+sag(2) 13,430.00 92.04 272.37 3,525.90 3,456.10 520.79 -11,677.48 6,015,521.60 540,247.26 0.00 11,689.08 PROJECTED to TD brian.rrheeier2haniburton.cr......................... Checked rw.w.nd.... .-'-- Checked By: corn Pt R..m,w.r� Approved By: Date: 4/29/2016 7:57:09PM Page 6 COMPASS 5000.1 Build 73 • • MPJ-23A FINAL Days vs Depth 0 500 MPJ-23A Actual 1000 1500 MPJ-23A Plan . . — � 2000 11 2500 .. MPJ-23A Stretch . .�3000 Goal — 3500II 4000 - — 4500 - 5000 5500 6000 F 6500 w 7000 -a I) 7500 3 a, 8000 2 8500 9000 9500 10000 10500 11000 11500 12000 12500 13000 13500 14000 - 14500 1111 , 0 5 10 15 20 25 Days 5/24/2016 1:30 PM • A MPJ-23A MW vs Depth 0 -- - -MP1-23A Plan 1000 -MPJ-23A Actual - 2000 3000 4000 5000 L u 6000 v co co w 7000 8000 9000 10000 11000 12000 8 9 10 11 12 13 14 Mud Density(ppg) • • 215154 RECEIVED® Maile Sweigart 2 7 1 4 0 Alaska North Slope Team Hilcorp Alaska, LLC MAY 09 Lfi i6 3800 Centerpoint Drive, Ste 1400 Anchorage,Alaska 99503 lbh urp:Uliac..IJA Office: 907.777.8473 AndJl�n CC msweigart@hilcorp.com DATA LOGGED 5/14/201(y K.BENDER Date: 5/9/2016 To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL MP J-23A J-23A Prints: ROP-GM-ADR-HORIZONTAL PRES 2IN MD,GM-ADR- INV/REV SECTIONS 2IN TVD E log data CD 1 : Final Well Data r Name Date modified Type :files Currently on the Disc (7) CGM 5/2/2016 10:24 AM File folder Definitive Survey 5/2/2016 10:24 AM File folder DLIS+LAS 5/2/201610:24 AM File folder , . EMF 5/2/201610:24 AM File folder y ,. Geosteering Data 5/2/2016 10:24 AM File folder ,. PDF 5/2/201610:24 AM File folder j.. TIFF 5/2/2016 10:24 AM File folder Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Receivefil Date: • S Schwartz, Guy L (DOA) From: Schwartz,Guy L(DOA) Sent: Thursday,April 14,2016 2:18 PM To: 'Luke Keller;Quick, Michael J (DOA) Cc: James Lott- (C); Stan Porhola;Cody Dinger- (C); Paul Mazzolini; Doug Yessak- (C);Tim Barnhart- (C) Subject: RE:J-23A(PTD:215-154)Change to Wellhead Luke, Per our discussion you have approval to install the new tubing as outlined below. Casing will have been tested and isolated from the reservoir. Send a new wellhead diagram with the update as soon as possible and update the MOC form on both the P&A sundry (#315-537) and the drilling PTD. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Luke Keller [mailto:lkeller@hilcorp.com] Sent:Thursday, April 14, 2016 1:59 PM To: Schwartz, Guy L(DOA); Quick, Michael J (DOA) Cc: James Lott-(C); Stan Porhola; Cody Dinger- (C); Paul Mazzolini; Doug Yessak- (C);Tim Barnhart- (C) Subject: J-23A(PTD: 215-154) Change to Wellhead Guy/Mike, After we began work on J-23A,we identified that the tubing hanger we built for this well will not work in the existing tubing spool (lock down grooves on hanger will not reach the lock down screws on spool). It is an older style tubing spool and dimensions from load shoulder to lock down screws could not be ascertained from OEM or original BP files. We would like to install a new tubing spool on top of the existing,with 11"x 5M API flanges on both ends. Then install a vertical tree(horizontal tree equipment will be removed). The 4-1/2" injection tubing will be hung off in the new tubing spool as per attached revised BOP drawing. Subject to AOGCC review and approval,our plan for installing and testing the new spool is as follows: 1. Squeeze cmt through the cmt retainer at 7880' MD to P&A well,clean up well. (per approved Sundry 315-537& 315-538) 2. Tag plug with 10k set down. Pressure test plug and casing to 1750 psi/30 min(charted).TOH. (per approved Sundry 315-537&315-538) 3. N/D BOP (no storm packer b/c well hydraulically isolated via plug and tested). 4. Remove 24"spacer spool, Install new tubing spool. N/U BOP. Test both flanges and new tubing spool to 250/1750 psi (charted). 1 5. Continue with well drillingikrations. Please let us know if this path forward is acceptable to the AOGCC. Thank you, Luke Keller Drilling Engineer Hilcorp Alaska, LLC 907-777-8395 2 • 0 s — r v \. mrm,mm - , r� 0 = Q Cl F • s :00 C E 9 OOO OOO W C N o o 0• TAe CB e�� O00 O00 X@mn E It i) /7 I I/ 0 / • 111I WI I. o "./ m m N N l .4 -6). W YY t� � k x en W .•] Vt fll 9 K x X 0, 2 ( ____ L__- N W — d n ? X O 01 m r S mm n c X m 101 . . w ,..„ �0 ill - a0 1 10 '4cO ��c N - a M z - Z3/k ao 4— H N N Z $ _ a tna r • V. V. - - Cr -‹_JNd o s s V) ¢wW w`L — W W Y>Z0 O Y -- ,'°,a,. O SNQODN0 F2 " coca>Z�aC�F-- . '0A,034 � �I a cn N Z H a J-z 0 Ucro(..)Co Wcrd 0 ti © _ / '� S-1 Z —NMVLfI(A 1-oo I1 S� t 5 • QNI"iii Z 4 Lil N a_ 0 w z0W- —J N F--CL I— QvW c)WOJ 0 1 11 0 (n(3H- `° O .. ..-.11.111) 0 o � Tm ._l aQa cc Ili... ), © 1�1L ��a m a ' .\ �� W O O O "' 1i11�1 1 11► . --p o x x x 2 ♦�� W Q x V ao �r ! ,= oa �r S. (� N S 0 0 ¢ N x x - C Swj )rj _i3 •'m v :::::18:11::;:%•:;‘, le• • �: * i og0a o z--w:::!:! :::: A OI _C *! i4 N...),,,,,,j 0 mliit OW .. co ° 1 N 11'�'� W F —Q u. mu Q 2 Q -Y. G W N Q JW _ W a I m I I o I w 1 , —cc OF TFf • P-‘'\ I�%�sA THE STATES Alaska. Oil and Gas ti� ill�n of Conservation Commission u x = "' 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ALA91�P- Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Luke Keller Drilling Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPJ-23A Hilcorp Alaska, LLC Permit No: 215-154 Surface Location: 2685' FSL, 3390' FEL, SEC. 28, T13N, R10E, UM, AK Bottomhole Location: 2082' FNL, 699' FWL, SEC. 30, T13N, R10E, UM, AK Dear Mr. Keller: Enclosed is the approved application for permit to redrill the above referenced service 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 '. Foerster Chair DATED this (0 day of October, 2015. STATE OF ALASKA i -#iw, A .A OIL AND GAS CONSERVATION COMMIIN PERMIT TO DRILL ( � 20 AAC 25.005 '' C"" la.Type of Work: 1 b.Proposed Well Class: Development-Oil ❑ Service- Winj ❑., Single Zone ❑✓ 1c.Specify if well is,proposed for: Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development-Ga: ❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑I Reentry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket E Single Wel ❑ 11.Well Name and Number: Hilcorp Alaska,LLC Bond No. 022035244 MPJ-23A 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive,Suite 1400,Anchorage AK 99503 MD: 13,433' TVD: 3,555' Milne Point Unit 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Schrader Bluff Oil Pool Surface: 2685'FSL,3390'FEL,Sec 28,T13N,R10E,UM,AK ADL 025906(SHL)/ADL 025517(TPH/BHL) NZ '5A ti'fl Pilo f Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2384'FNL,1039'FWL,Sec 29,T13N,R10E,UM,AK N/A 10/17/2015 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 2082'FNL,699'FWL,Sec 30,T13N,R10E,UM,AK 5115 Acres 6,277'to nearest unit boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): *6 10.KB Elevation above MSL: 66.1 feet 15.Distance to Nearest Well Open Surface: x-5 8.8 y- 61:11(751-1-8 Zone-4 GL Elevation above MSL: 36.1feet to Same Pool: 1060'from J-26 SS 946.95 Golsog2, 16.Deviated wells: Kickoff depth:tg)1 feet ?Kb 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 91 degrees Downhole: 1599 psi - Surface: 1242 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) 6-1/8" 4-1/2" 13.5# L-80 VAM HTTC 4,554' 7,680' 3,520' 13,433' 3,555' Cementless Liner ICDs&Swell PKRS WPM;pcw ' ? `Atlfr 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): 12,126' 3,783 N/A 12,126' 3,783 N/A Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 20" 260 sx Arctic Set 108' 108' Surface 8,663' 7" 1100 sx Arctic Set,542 sx Class G 8,892' 3,838' Intermediate Liner L1 3,536' 4-1/2" Uncemented Slotted Liner 12,126' 3,719' Liner 3,265' 4-1/2" Uncemented Slotted Liner 12,062' 3,783' Perforation Depth MD(ft): Slotted Liner 8,590'-12,126'MD L1 Perforation Depth ND(ft): Slotted Liner 3,788'-3,719'ND L1 Slotted Liner 8,798'-12,062'MD Slotted Liner 3.840'-3,781'ND 20. Attachments: Property Plat ❑✓ BOP Sketch Q Drilling Program Q Time v.Depth Plot Q Shallow Hazard Analyss❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program Q 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 Ikeliera.hilcorp.com Printed Name Luke Keller Title Drilling Engineer Signature ZZ / Phone 907-777-8395 Date 74/ -:"?/.2c)/3 - Commission Use Only Permit to Drill ,, API Number: Permit Approval See cover letter for other Number: '5-.- /SI 50-Oa- ,2,,,z? O-01-aQ Date: Pi (.14 I t requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in oh:[� 3000 log req'd: � Other: fs >c (cs'r Samples req'd: Ye: ❑ N4.[� Mud Y IvoLe ik I'I' - n oCMJ) b e- (C\ H2S measures: Yet [7�Nd'❑ Directional svy req'd:Ye NO❑ CR. w/it �0 'O n Spacing exception req'd: Ye ❑ Nisi l Re Inclination-only svy req'd:Y, Na[� IA yr-- 1 A b l� APPROVED BY Approved by: a e t__?,, ,,,,,,,,,Z.,,,,_ COMMISSIONERTHE COMMISSION Date/D-6_( -c.L3•l s fle 42$IIS- MW '0/Jr Submit Form and Form 10-401(Revised 10/2012) Oh1�D(�einGs[aNck4 nonths fr the da a of approval(20 AAC 25.005(g1) Attachments in Duplicate 11 \x` ?/ /)-- RECEIVED AUG 2 8 2015 Hilcorp Luke Keller Hilcorp Alaska, LLC p� Energy Company Drilling Engineer P.O. Box 244027 "`�,O` CC Anchorage,AK 99524-4027 8/27/2015 Tel 907 777 8395 Email Ikeller@hilcorp.com Commissioner Alaska Oil &Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Re: MPJ-23A Permit to Drill Dear Commissioner, MPU J-23A is part of a (4) well pilot program and will be used as a horizontal water injector in the Schrader Bluff NB sand. It is planned as a sidetrack out of the parent well, J-23 which is currently a shut-in producer with an MBE to J-20A in the OA Sand. It has been shut in since June 2010. The parent well will be P&A'd, and sidetracked at —7780' MD. The base plan is a lateral well in Schrader NB sand. Drilling operations are expected to commence approximately Oct 17th, 2015. Nordic Calista Rig#3 will be used to drill and complete the wellbore. The existing 7"surface casing will be used and a pressure test conducted prior to drilling the sidetrack. �Ne eo OL0 i"` All waste & mud generated during drilling operations will be hauled to the Milne Point G&I facility on "B" pad. This facility is expected to be up and running by then. If it is not, the back-up option is to haul all mud and cuttings to the BP G&I facility at Prudhoe Bay. A separate sundry notice will be submitted to cover P&A and wellbore preparation for the sidetrack and will be included with the PTD submittal to the AOGCC. The P&A sundry will cover the following operations: 1. Circ kill weight fluid in well. 2. MOB Nordic#3 to the well site. 3. N/D tree, N/U & test BOP. Install 2-7/8" x 5" VBRs in upper and lower ram, blind rams in middle ram cavity. Test on 3-1/2", 4", &4-1/2" test joints to 250/3000 psi (annular to 250/2500 psi). 4. Cut 3-1/2"tubing above pkr at 7900', POOH and UD tubing. 5. RIH w/cmt retainer, set at 7800', bullhead cmt down well to P&A. If you have any questions, please don't hesitate to contact myself at 777-8395 or Paul Mazzolini at 777-8369. Sincerely, // (/ Luke Keller Drilling Engineer Hilcorp Alaska, LLC Page 1 of 1 • Hilcorp Alaska, LLC Milne Point Unit (MPU) J-23A Drilling Program Version 1 August 20th, 2015 • Milne Point Drilling Procedure IIihorp;Ua•ka. 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 Rig Orientation on "J"Pad. 11 11.0 6-1/8"Hole Section Mud Program 12 12.0 Whipstock Running Procedure 13 13.0 Whipstock Setting Procedure• 15 14.0 Drill 6-1/8"Hole Section 17 15.0 Run 4-1/2"Injection Liner 20 16.0 Run Injection Assembly 23 17.0 RDMO 23 18.0 BOP Schematic 24 19.0 Wellhead Schematic 25 20.0 Days vs Depth 26 21.0 Formation Tops 27 22.0 Anticipated Drilling Hazards 28 23.0 Nordic#3 Rig Layout(Drillers Side) 29 24.0 Nordic#3 Rig Layout(Well End & Top View) 30 25.0 FIT Procedure 31 26.0 Choke Manifold Schematic 32 27.0 Casing Design Information 33 28.0 6-1/8"Hole Section MASP 34 29.0 Spider Plot(NAD 27)(Governmental Sections) 35 30.0 Surface Plat(As Built)(NAD 27) 36 31.0 Drill Pipe Specifications 37 • • Milne Point Drilling & Completion Procedure I lih orp:11a.ka.LL1: 1.0 Well Summary Well MPU J-23A Pad Milne Point"J"Pad Planned Completion Type 4-1/2"Injection String Target Reservoir(s) Schrader Bluff NB Sand Planned Well TD, MD/TVD 13,433' MD/3,555' TVD PBTD, MD/TVD 13,430' MD/3,555' TVD Surface Location(Governmental) 2685' FSL,3390' FEL, Sec 28,T13N, R10E, UM,AK Surface Location(NAD 27—Zone 4) X=551926.95,Y=6015082.24 Surface Location(NAD 83) Top of Productive Horizon (Governmental) 2384' FNL, 1039'FWL, Sec 29,T13N, RIDE, UM,AK TPH Location(NAD 27) X= 545794.9,Y=6015252.6 TPH Location(NAD 83) BHL(Governmental) 2082' FNL,699' FWL, Sec 30, T13N,R10E,UM,AK BHL(NAD 27) X=541408.8,Y=6015518.8 BHL(NAD 83) AFE Number 1511739 AFE Drilling Days 10 AFE Completion Days 4 AFE Drilling Amount $2,676,786 AFE Completion Amount $1,166,800 AFE Facility Amount $100,000 Maximum Anticipated Pressure (Surface) 1242 psig Maximum Anticipated Pressure - (Downhole/Reservoir) 1599 psig Work String 4" 14# S-135 XT-39(Nordic Rental) KB Elevation above MSL: 30+36.1 ft=66.1 ft AMSL GL Elevation above MSL: 36.1 ft AMSL BOP Equipment 11"x 5M Annular,(3)ea 11"x 5M Rams Page 2 Version 1 August, 2015 • Milne Point Drilling & Completion Procedure Ililrorp:Ua.ka. 2.0 Management of Change Information Hilcorp Alaska, LLC Hilcorp,agy ompaq Changes to Approved Permit to Drill Date: July 22nd,2015 Subject Changes to Approved Permit to Drill for J-23A File#: J-23A Drilling and Completion Program Any modifications to J-23A Drilling&Completion Program will be documented and approved below. Changes to an approved APD will be communicated to and approved by the AOGCC. Sec Page Date Procedure Change Approved Approved By By Approval Drilling Manager Date Prepared Drilling Engineer Date Page 3 Version 1 August, 2015 • S Milne Point Drilling& Completion Procedure Ililrorp Ala.ko.1.1A. 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) VAM 6-1/8" 4-1/2" 3.849 3.75 4.93 13.5 L-80 HTTC 9020 8540 307 4.0 Drill Pipe Information: Hole OD (in) ID(in) TJ ID TJ OD Wt Grade Conn Burst Collapse Tension Section (in) (in) (#/ft) (psi) (psi) (k-lbs) 6-1/8" 4" 3.34" 2.813" 5" 14 S-135 XT-39 18,428 13,836 403 All casing will be new, PSL 1 (100%mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Version 1 August, 2015 • Milne Point Drilling& Completion Procedure Ilil•orp:\la.ka,1.1.1: 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on Wellez. i. Report covers operations from 6am to 6am ii. Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area—this will not save the data entered, and will navigate to another data entry tab. iii. Ensure time entry adds up to 24 hours total. iv. Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. v. Enter the MD and TVD depths EVERY DAY whether you are making hole or not. 5.2 Afternoon Updates i. Submit a short operations update each work day to pmazzolini@hilcorp.com, Ikeller@hilcorp.com and cdinger@hilcorp.com 5.3 Intranet Home Page Morning Update i. 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. 5.4 EHS Incident Reporting i. Health and safety: Notify EHS field coordinator. ii. Environmental: Drilling Environmental coordinator iii. Notify Drlg Manager&Drlg Engineer iv. Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally i. Send final"As-Run"Casing tally to Ikeller@hilcorp.com and cdinger@hilcorp.com 5.6 Casing and Cmt report i. Send casing and cement report for each string of casing to lkeller@hilcorp.com and cdinger@hilcorp.com 5.7 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 DrIg Environmental Coord Julieanna Orczewska 907.777.8444 907.715.7060 jorczewska@hilcorp.com EHS Manager Carl Jones 907.777.8327 907.382.4336 cajones@hilcorp.com EHS Field Coordinator Jimmy Watson 907.777.8450 907.744.7376 iiwatson@hilcorp.com Drilling Tech Cody Dinger 907.777.8389 509.768.8196 cdinger@hilcorp.com Page 5 Version 1 August,2015 0 • Milne Point Drilling & Completion Procedure Ililrurp ‘la,ka.I.1,1: 6.0 Planned Wellbore Schematic AFE No. Well Name: KB: 36.1 ft AGL 1511739 Milne Point Unit(MPU)J-23A GL+RKB 36.1 ft+30 ft=66.1 ft API S AFE WELLBORE DESIGN Proposed TO: 13.433° Permit No. Proposed TVD: 3,555' Get ogic Information V'd&I ore Information Casing Info I Mud Info]Hole Size I Cement Specs S5 TVD FM Lithology Existing Strings(J-23 Original Borehole) RKB-Tuomg Hanger 20"Driven to 110'RKB v +. Surface/Production Casing ° " 7"26#L-80 BTC t r �' Originally set at 8892 VI E g Planned plug and abandon of lower(2)laterals o ° E Baker S-3 Packer left at 7900'MD E « Cmt Retainer set at-7800'MD a '(f1/4 a a 1 -�' Whipstock no i{ i,°- Top at 7780'MD a - c Btm at 7800'MD c £ 2 Planned Strings(J-23A) 2150' r Production Liner 4-112"13.5#L-80 VAM HTTC set at 13,433'MD Z 22 Injection Tubing C. ,. 4-112"11.6#L-80 IBT-M set at 7,700'MD Y A H C N u . ,1 Ao eo > q O 8 e8 + if; m N •a 9 v o m n s 5 o c Liner top Packer& c4- bullet seal assy - ° 8: 3335' 1 u 3 ;n -5 4-1I2"Injection Liner K-sands Coarse sand,silty Wh shale,better _--------c---„, Interval: UGNU developed 4*- l Injection Control Devices ' Production Hole L-Sands intervening shales A \ �.-. Mud Twe: 3590' M-sans in the L and M \- \\ Bara�fl-N N-sands `Continued layering as 1 ■ r ■ . Wepht,RAMC Schrader in Ugnu,more p 0 O b o g.9-92 ppg 0-sands condensed with acc. Q c> 00 6 bit ti. n 3640' .coal \ ii4 ■ 0 ■ a o V O i o.. Vih pstcck -*_-e iSwell Plies Cmt Retainer '. Baker 5-3 Packer Page 6 Version 1 August, 2015 S s Milne Point Drilling & Completion Procedure I lilrorp:1la.ka.. 7.0 Drilling / Completion Summary MPU J-23A is part of a(4)well pilot program and will be used as a horizontal water injector in the Schrader Bluff NB-sand. It is planned as a sidetrack out of the parent well,J-23 which is currently a shut-in producer with an MBE to J-20A in the OA Sand. It has been shut in since June 2010. The parent well will be P&A'd, and sidetracked at 7780' MD. The base plan is a lateral well in Schrader NB sand. Drilling operations are expected to commence approximately Oct 17th, 2015. Nordic Calista Rig#3 will be used to drill and complete the wellbore. The existing 7"surface casing will be used and a pressure test conducted prior to drilling the sidetrack. All waste & mud generated during drilling operations will be hauled to the Milne Point G&I facility on "B" pad. This facility is expected to be up and running by then. If it is not, the back-up option is to haul all mud and cuttings to the BP G&I facility at Prudhoe Bay. A separate sundry notice will be submitted to cover P&A and wellbore preparation for the sidetrack and will be included with the PTD submittal to the AOGCC. The P&A sundry will cover the following operations: 1. Circ kill weight fluid in well. 2. MOB Nordic#3 to the well site. 3. N/D tree,N/U & test BOP. Install 2-7/8"x 5" VBRs in upper and lower ram, blind rams in middle ram cavity. Test on 3-1/2", 4", & 4-1/2"test joints to 250/3000 psi (annular to 250/2500 psi). 4. Cut 3-1/2"tubing above pkr at 7900', POOH and L/D tubing. 5. RIH w/cmt retainer, set at 7800', bullhead cmt down well to P&A. General sequence of operations pertaining to this approved drilling procedure: 1. Run whipstock, mill window in 7"26# casing. 2. Drill 6-1/8"production hole section to TD. 3. Run 4-1/2" injection liner. 4. Run 4-1/2" injection tubing 5. N/D BOP,N/U tree, RDMO Page 7 Version 1 August,2015 • Milne Point Drilling & Completion Procedure I lilrorp:Ua,ka. 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 J-23A. 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 10/10 min(annular to 50%rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. • If the BOP is used to shut in on the well in a well control situation, we must test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system". • All AOGCC regulations within 20 AAC 25.035 "Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements". • Ensure both AOGCC approved drilling permit is posted on the rig floor and in Co Man office. Variance Requests: • There are no variance requests at this time. Page 8 Version 1 August, 2015 • Milne Point Drilling& Completion Procedure nacorp Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure(psi) • 11"x 5M Hydril Annular BOP • 11"x 5M Hydril Double Ram Initial Test:250/3000 o Blind ram in btm cavity (Annular 2500 psi) • Mud cross w/3"x 5M side outlets 6-1/8" • 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. Additional requirements may be stipulated on APD. Regulatory Contact Information: AOGCC Jim Regg/AOGCC Inspector/(0): 907-793-1236/Email:jim.regg@alaska.gov Guy Schwartz/Petroleum Engineer/(0): 907-793-1226/(C): 907-301-4533 /Email:guy.schwartz@alaska.gov Victoria Loepp/Petroleum Engineer/(0): 907-793-1247/Email: Victoria.loepp@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format:http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html Notification/Emergency Phone: 907-793-1236(During normal Business Hours) Notification/Emergency Phone: 907-659-2714 (Outside normal Business Hours) Page 9 Version 1 August, 2015 • • 14Milne Point Drilling & Completion Procedure !Mewl).Ua.ka.1,1.1: 9.0 R/U and Preparatory Work 9.1 Level pad and layout rig mats for footprint of rig. 9.2 Drive rig over well and ensure rotary centered over wellhead. Confirm that rig is over appropriate well—J-23. 9.3 Spot& tie in service company shacks and water/displacement tanks. 9.4 Layout herculite and spot cuttings tank, berm up for 100% containment. 9.5 Ensure PTD and drilling program are posted in the rig office and on the rig floor. 9.6 After rig equipment has been spotted, R/U handi-berm containment system around footprint of rig. 9.7 Mud Loggers WILL NOT be used for J-23A. 9.8 Mix mud for 6-1/8"hole section. 9.9 Set test Plug in wellhead prior to N/U BOP to ensure nothing can fall into the wellbore if it is accidentally dropped. 9.10 Install 5" liners in mud pumps. • Continental EMSCO F-1000 mud pumps are rated at 4,000 psi (100%)/290 gpm(120 spm @ 95%eff)with 5" liners. • According to Hilcorp/Nordic contract, pumps can be operated continuously at 80% of above pressure rating (3200 psi), and 126 spm continuous maximum. 9.11 Conduct P&A operations which include: • Circ kill weight fluid in well. • N/D tree,N/U &test BOP. Install 2-7/8"VBRs in upper and lower ram, blind rams in middle ram cavity. Test on 3-1/2", 4", & 4-1/2"test joints to 250/3000 psi (annular to 250/2500 psi). • Cut 3-1/2"tubing above ph at 7900', POOH and L/D tubing. • RIH w/cmt retainer, set at 7800', bullhead cmt down well to P&A. NOTE:A separate sundry will be submitted to the AOGCC that covers P&A operations, and will accompany the PTD application. 3i5-- j Page 10 Version 1 August,2015 • Milne Point Drilling & Completion Procedure Ililcorp Alaska,LI I' 10.0 Rig Orientation on "J" Pad. t216:71 af swi � I � I t , El —I- t A 3rl�n i =MMAMIIIMUU 16121471M ImPT- JNr..111 =MIMImm MN MN=MI 1 � - I EL a I _ I � I 4. R� a Page 11 Version 1 August, 2015 • • Milne Point Drilling & Completion Procedure !lilt orp u:,.k:,.1.1.1 11.0 6-1/8f9 Hole Section Mud Program • Density: Weighting material to be used for the hole section will be calcium carbonate. Additional calcium carbonate will be on location to weight up the active system (1)ppg above highest anticipated MW. • Solids Concentration: It is imperative that the solids concentration be kept low while drilling the production hole section. Keep the shaker screen size optimized and fluid running to near the end of the shakers. It is okay if the shakers run slightly wet to ensure we are running the finest screens possible. • Rheology: Keep viscosifier additions to an absolute minimum(N-VIS). Data suggests excessive viscosifier concentrations can decrease return permeability. Do not pump high vis sweeps, instead use water or low vis sweeps. • Run the centrifuge continuously while drilling the production hole, this will help with solids removal. • Dump and dilute as necessary to keep drilled solids to an absolute minimum. • MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, & Toolpusher office. System Type: 8.9—9.2 ppg Baradrill-N drilling fluid Properties: Depths IIensity Pla is Viscosity Yield Point Total Solids MBT HPHT pH 7,780- 8.9-9.2 15-25 15-25 <10% <7 <11.0 8.5-9.5 13,433' System • ulation: Baradrill-N Product Concentration Water 0.955 bbl KCL 11 ppb KOH 0.1 ppb N-VIS 1.0- 1.5 ppb N-DRIL HT PLUS 5 ppb BARACARB 5 11.5 ppb BARACARB 25 16.8 ppb BARACOR 700 1.0 ppb BARASCAV D 0.5 ppb X-CIDE 207 0.015 ppb EZ-GLIDE 2.0% Page 12 Version 1 August, 2015 • • Milne Point Drilling & Completion Procedure I liIrorp.11a.ka.1.1.1: 12.0 Whipstock Running Procedure 12.1 M/U window milling assembly and TIH w/4" DP • Use a 6-1/8"Upper String mill and a 6-1/8" string mill above to ensure CIBP &whipstock assy will pass freely. • Ensure BHA components have been inspected previously. • Caliper and drift all BHA components before running them in the hole. 12.2 Make up mills on a joint of HWDP. 12.3 RIH& set in slips. 12.4 Make up float sub, install float. 12.5 Install MWD for orientation. 12.6 Make up UBHO sub. 12.7 Orient UBHO to starter mill. 12.8 TIH to cmt retainer(7800' MD). Verify proper operation of MWD. 12.9 CBU & circ at least(1)hi-vis sweep to remove any debris created by the clean out run. Anything left in the wellbore could affect the setting of the Whipstock. 12.10 Drop drift and TOH. 12.11 Leave assembly hanging in the elevators, and stand back on floor. 12.12 Bring Whipstock to rig floor on the pipe skate. Do not slam into bottom of Whipstock with pipe skate. 12.13 Pick up Whipstock per Baker rep using the Baker Whipstock handling system using air hoist. Allow assy to hang while Baker Rep inspects and removes shear screws as needed and any safety screws. Note: Anchor should be pinned with 6 shear screws initially. Shear screws are rated for 6,630 lbs each. REMOVE 3 screws for a set down shear of 6,630 x 3=19,890 lbs. Note: Attach mills to Whipstock with (1) 35k mill shear bolt. 12.14 If needed, open BOP Blinds. Page 13 Version 1 August,2015 • • Milne Point Drilling& Completion Procedure Ilih orp.Um,ku.1.11. 12.15 Run the Whipstock in the hole, install safety clamp as per Baker Rep, and install hole cover wrap. 12.16 Release pick up system at this point, Make up mills. 12.17 With the top drive,pick the assembly and position the starting mill to align with the hole in the slide. The Baker Rep will instruct the driller when the slot is lined up, the shear bolt then can be made up by the Baker Rep. 12.18 The assembly can now be picked up to ensure that the shear bolt is tight. 12.19 Remove the handling system. 12.20 Slowly run in the hole as per Baker Rep. run extremely slow through the BOP & wear bushing. 12.21 Run in hole at 1 %2 to 2 minutes per stand. 12.22 Fill every 30 stands or as needed, do not rotate or work the string unnecessarily. 12.23 Call for Baker Rep. 15 — 10 stands before being to bottom. 12.24 Orient at least 30' —45' above the CIBP using the MWD. Consider having gyro personnel on standby in the event the MWD is not working. WindowMaster G2 System on TorqueMaster BTA BHA #1 Connection Length O.D. BOTTOM TRIP ANCHOR 3 %2" IF-B X Anchor 3.21' 5.680 WINDOWMASTER G2 WHIPSTOCK 3 1/2 IF-P X 35K Shear bolt 18.5 5.500 WINDOW MILL 3 % REG-P X MILL 1.38 6.125"" NEW LOWER WATERMELON MILL 3 % IF-B X 3 % IF-P 5.50 6.125" FLEX JOINT 3 '/ IF-B X 3 % IF-P 6.55 4.750 UPPER WATERMELON MILL 3 '/" IF-B X 3 '/2" IF-P 5.83 6.125" 1jt - HWDP 3 %" IF-B X 3 '/" IF-P 30 4.750 MWD collar 3 %2" IF-B X 3 %" IF-P 18 4.750 FLOAT SUB 3 %2" IF-B X 3 %2' IF-P 3 4.750 UBHO 3 '/2' IF-B X 3 '/" IF-P 4 4.750 X-O sub+ 30 jts-HWDP 4" HT-38 4" HT-38 B X 4" HT-38-P 900' 4.750 CONNECTIONS ON TUBULARS ARE SUBJECT TO CHANGE. BHA'S SHOW SPECIFIC CONNECTIONS AS AN EXAMPLE ONLY Page 14 Version 1 August, 2015 • • Milne Point Drilling& Completion Procedure na• �, %laska.ii.c 13.0 Whipstock Setting Procedure: 13.1 With the bottom of the Whipstock 30—45' above the CIBP, measure and record P/U and S/O weights. Run gyro survey to orient Whipstock face. 13.2 Orient Whipstock to desired direction by turning DP in 1/4 round increments. P/U and S/O on DP to work all torque out(Being careful not to set BTA). Whipstock Orientation Diagram: 30L 60Ljok ‘111P' Desired orientation of the Whipstock face is 30L to 60L Hole Angle at window interval (7,800 MD) is -75 deg. 13.3 Once Whipstock is in desired orientation, slack off and tag CIBP to set Bottom Trip Anchor. 13.4 Set down 15-20K on anchor to trip, P/U 5-7K maximum overpull to verify anchor is set. The window mill can then be sheared off by slacking off weight on the Whipstock shear bolt. (35k fr:fr shear value). 13.5 P/U 5-10' above top of Whipstock. 13.6 Displace to Baradrill-N fluid system. 13.7 Record P/U, 5/0 weights, and free rotation. Slack off to top of Whipstock and with light weight and low torque. Mill window. Utilize 4 ditch magnets on the surface to catch metal cuttings. - 13.8 Install catch trays in shaker underflow chute to help catch iron. ,i' 13.9 Keep iron in separate bbls. Record weight of iron recovered on ditch magnets. Page 15 Version 1 August,2015 • • Milne Point Drilling& Completion Procedure Ilileorp 1.1.1: •"•" 13.10 Estimated metal cuttings volume from cutting window: 7" 26# L-80 Cuttings Weight Window Length Casing Weight Min(lbs) Avg(lbs) Max(lbs) 16 26# 60 85 115 13.11 Drill approx. 20' rat hole to accommodate the drilling assembly. Ream window as needed to assure there is little or no drag. After reaming, shut off pumps and rotary (if hole conditions allow) and pass through window checking for drag. 13.12 Circulate Bottoms Up until MW in=MW out. 13.13 Conduct FIT to 12 ppg EMW. 13.14 Slug pipe and POOH. Gauge Mills for wear. 13.15 Should a second run be required pick up the following BHA. Back Up Mills Connection Length O.D. WINDOW MILL 3 % REG-P X MILL 1.38 6.125" NEW LOWER WATERMELON MILL 3 1/2 IF-B X 3 % IF-P 5.50 6.125" FLEX JOINT 3 '/ IF-B X 3 % IF-P 6.55 4.750 UPPER WATERMELON MILL 3 '/" IF-B X 3 %2" IF-P 5.83 6.125" FLOAT SUB 3 '/2" IF-B X 3 '/2' IF-P 3 4.750 X-O sub 30 jts-HWDP 4" HT-38 4" HT-38 B X 4" HT-38-P 900' 4.750 CONNECTIONS ON TUBULARS ARE SUBJECT TO CHANGE. BHA'S SHOW SPECIFIC CONNECTIONS AS AN EXAMPLE ONLY! Page 16 Version 1 August, 2015 • • 11 Milne Point Drilling & Completion Procedure IIiIrur1, ‘1,..h...1.1( 14.0 Drill 6-1/8" Hole Section 12.1 P/U 6-1/8" 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 4" 14# S-135 XT-39 • Install ported float above motor. 12.2 6-1/8"BHA(Includes GR+Res+ADR LWD components & PWD): COMPONENT DATA Item OD ID Gauge Weight Top Length Cumulative Description Serial Number (in) (in) (in) (Ibpf) Connection (ft) Length (ft) 1 6 1/8"HDBS MM64 PDC 4.500 1.500 6.125 48.18 P 3-1/2"REG 0.83 0.83 2 4 3/4'SperryDrill Lobe 7/8-2.9 stg 475-997 4.750 2.901 44.52 B 3-1/2"IF 38.27 39.10 Stabilizer 5.750 3 4 314"NM ILS 4.750 1.250 6.000 56.21 B 3-1/2"IF 6.30 45.40 4 4 3`4'GM Collar 4.750 2.610 47.00 B 3-112"IF 8.56 53.96 5 4 34"PWD P8903$4 768WJ 4.730 1.250 47.90 B 3-1/2"IF 10.84 64.80 6 4 3/4"NM ILS 119946593 4.750 2.313 6.000 46.08 B 3-1/2"IF 3.59 68.39 7 4 3/4"ADR Collar 4.750 1.250 53.70 B NC 38 25.28 93.67 8 4 3'4"DM Collar 4.720 1.500 47.00 B 3-1;2"IF 9.19 102.86 9 4 14"SHORT HOC 4.710 1.500 46.10 B 3-1/2"IF 11.28 114.14 10 4 3'4"NM Float sub 4.750 2.250 46.84 B 3-1/2"IF 3.00 117.14 11 4 3,4"NM Flex Collar 4.750 2.313 46.08 B 3-1/2"IF 30.21 147.35 12 4 3/4"NM Flex Collar 4.750 2.313 46.08 B 3-1/2"IF 31.02 178.37 13 4 14"Steel Float Sub 4.750 2.250 46.84 B 3-112"IF 2.49 180.86 14 X-Over Sub 3-1/2"IFP x XT39B 4.750 2.563 42.81 B 4"XT39 1.67 182.53 15 lit x 4"HWDP XT39 4.000 2.563 29.70 31.50 214.03 16 4 3/4"Dailey Hyd Jar 4.630 2.250 43.83 B 4"XT39 30.00 244.03 17 2jts x 4-HWDP XT39 4.000 2.563 29.70 63.00 307.03 18 4 3/4"Hypulse Slinger 4.750 2.250 46.84 B 4"XT39 32.00 339.03 19 2jts x 4"HW DP XT39 4.000 2.563 29.70 63.00 402.03 20 33 its 4'DP XT39 11 stands 4.000 3.240 18.03 1039.50 1441.53 21 X-Over Sub 4 XT39 P x 3.5 IF B 4.750 2.500 43.66 B 3-1 2"IF 1.60 1443.13 22 NOV Agitator 4.750 2.000 49.69 B 3-12"IF 26.00 1469.13 23 X-Over Sub 3.5 IF B x 4 XT39 P 4.750 2.500 43.66 B 4"XT39 1.55 1470.68 Total: 1470.68 Page 17 Version 1 August, 2015 • S Milne Point Drilling& Completion Procedure Ililcorp Alaska,LII 12.3 Primary Bit: HALLIBURTON 6-118" (156mm) MM64 PRODUCT SPECIFICATIONS ihn. - Cutter Type SelectCutter IADC Code M434 I Body Type MATRIX 411 Total Cutter Count 43 Nc Cutter Distribution 13mm Face 25 1►. R Gauge 12 Up Drill 6 Number of Large Nozzles 0 Number of Medium Nozzles 0 Number of Small Nozzles 0 Number of Micro Nozzles 6 Number of Ports(Size) 0 ar Number of Replaceable Ports(Size) 0 Junk Slot Area(sq in) 537 1 11 Normalized Face Volume 25.99% API Connection 3-1/2 REG.PIN • Recommended Make-Up Torque* 5,173—705 Ft•lbs. ► Nominal Dimensions** Make-Up Face to Nose 935 in-237 mm Gauge Length 2 in-51 mm Sleeve Length Din-0 mm Shank Diameter 4.5 in-114 mm Break Out Plate(Mat.#/Legacy#) 181953/44030 Approximate Shipping Weight 86Lbs.-39Kg. SPECIAL FEATURES 1132"Relieved Gage,Optimized Dual Row-"D"Feature Material#791888 *Bit specific recommended make-up torque is a function of the bit I.D.and actual bit sub O.D_utilized as specified in API RP7C Section A.X.'-. "•Design dimensions arc nominal and may vary slightly on manufactured product.Halliburton Drill Biu and Services models arc continuously reviewed and refined. Product specifications may change without notice. 1. 2014 Halliburton.All rights reserved.Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. www.halliburton.corn • Page 18 Version 1 August,2015 • Milne Point Drilling & Completion Procedure IliIcorp.‘la.ka.1.1.1: 12.4 TIH w/6-1/8" directional assy to one stand above window. Shallow test MWD and LWD on trip in. 12.5 Orient motor and continue lowering assy through window. 12.6 Drill 6-1/8"hole section to section TD per Geologist and Drilling Engineer. • Pump at 250-290 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. 12.7 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. 12.8 At TD; pump low vis sweeps, CBU at least 3 times at maximum circulation and rotation, and pull a wiper trip back to the window. If backreaming is necessary: • Circulate at full drill rate (250-290 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. I. 12.9 TOH with the drilling assy, stand back BHA if possible. Rabbit DP on TOH. 12.10 No additional logs are planned for the 6-1/8"hole section. Page 19 Version 1 August, 2015 • • Milne Point 14Drilling& Completion Procedure I likorp Alaska.1.1.1: 15.0 Run 4-1/2" Injection Liner 15.1 Ensure rams have been tested on 4-1/2"test joint prior to running liner. 15.2 Ensure wear bushing is installed in wellhead. 15.3 R/U 4-1/2" casing running equipment. • Ensure 4-1/2" HTTC x XT-39 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. 15.4 Run 4-1/2" injection liner per completion tally. • Use "API Modified"or"BOL 4010 NM"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 completion liner tally. • Ensure all plastic packing is removed from swell pkr elements. • Do not place tongs or slips on pkr elements or ICDs. 4-1/2" VAM HTTC M/U torques Casing OD Minimum Maximum Yield Torque 4.5" 6,910 ft-lbs 9,350 ft-lbs 14,400 ft-lbs Page 20 Version 1 August, 2015 • • Milne Point Drilling& Completion Procedure Ililirorp Alaska,LLC Issued on:0S Jun.2015 by Jean-Guillaume Besse , D TA RE NFORMATIVE BASED ON SI-PD ONLY. Connection Data Sheet BASED ON SI-PD 101156 OD Weight Wall Th. Grade API Drift Connection 4 1/2 in. 13.50 lb/ft 0.290 In. L80 3.795 In. VAM®HTTC PIPE PROPERTIES CONNECTION PROPERTIES !Nominal OD 4.500 in. Connection Type Premium T&C' Nominal ID 3.920 in. Connection OD(nom) 4.930 in. Nominal Cross Section Area 3.836 sqin. Connection ID(nom) 3.849 in. Grade Type API SCT Make-Up Loss 4.380 in. Min.Yield Strength 80 ksi Coupling Length 9.917 in. Max.Yield Strength 95 ksi Critical Cross Section 3.836 sqin. 'Min.Ultimate Tensile Strength 95 ksi Tension Efficiency 100%of pipe Tensile Yield Strength 307 klb Compression Efficiency 100%of pipe Compressive Yield Strength 307 klb Compression Efficiency with Sealability 80%of pipe Internal Yield Pressure 9,020 psi Internal Pressure Efficiency 100%of pipe ,Collapse pressure 8,540 psi External Pressure Efficiency 100%of pipe [Tensile Yield Strength 307 klb Min.Make-up torque 6,910 ft.lb Compression Resistance 307 klb Opti.Make-up torque 8,130 ft.lb Compression with Sealability 246 klb Max.Make-up torque 9,350 ft.lb Internal Yield Pressure 9,020 psi Max.Torque with Sealability 12,350 ft.lb External Pressure Resistance 8,540 psi Max.Torsional Value 14,400 ft.lb Max.Bending 77°/100ft Max.Bending with Sealability 33°/100ft Max.Load on Coupling Face 158 klb Do you need help on this product?-Remember no one knows VAM''like VAM canada5avamneldservice.com uk®vamlleidser'ce.com chinaevamfieldservice.com usa5hvemfieldservice.com dubelevamfeidservice.com bakuivamrieldservice.com nlexicoLdlvemrleldservice,com Oigeriac vamfieldserv1Ce.com singaporwpvomfieldsennce.com braziit5vemfieldservice.com Angola@vamfieldservice.com australia@vamfieldservice.com Over 140 YAM®Specialists available worldwide 24/7 for Rig Site Assistance Other Connection Data Sheets are available at www.vamservices.ccm 15.7 Ensure to run enough liner to provide for approx 100' overlap inside 7" casing. Ensure hanger/pkr will not be set in a 7" connection. 15.8 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. 15.9 M/U Baker ZXP liner top packer. Fill liner tieback sleeve with "Pal mix", ensure mixture is thin enough to travel past the HRD tool and down to the packoff. Wait 30 min for mixture to set up. 15.10 Note weight of liner. Run liner in the hole one stand and pump through liner hanger to ensure a clear flow path exists. 15.11 RIH w/liner on DP no faster than 1-1/2 min/ stand. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. Page 21 Version 1 August, 2015 Milne Point Drilling & Completion Procedure IIil•orp 1.1.1: 15.12 DP should autofill. 15.13 Slow in and out of slips. Ensure accurate slack off data is gathered during RIH. Record shoe depth+ S/O depth every stand. Record torque value if it becomes necessary to rotate the string to bottom. 15.14 Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10, 20, & 30 rpm. 15.15 If any open hole sidetracks have been drilled, monitor sidetrack depths during run in and ensure shoe enters correct hole. 15.16 TIH deeper than planned setting depth. Last motion of the liner should be up to ensure it is set in tension. 15.17 Prior to setting the hanger and packer, double check all pipe tallies and record amount of drill pipe left on location. Ensure all numbers coincide with proper setting depth of liner hanger. 15.18 Rig up to pump down the work string with the rig pumps. 15.19 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. 15.20 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. 15.21 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. 15.22 Bleed DP pressure to zero, close BOP and test annulus to 1500 psi for 10 min and chart record same. 15.23 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. 15.24 POOH, L/D and inspect running tools. If setting of liner hanger/packer proceeded as planned, LDDP on the TOH. 15.25 L/D remaining DP out of derrick. Page 22 Version 1 August, 2015 • 0 14Milne Point Drilling & Completion Procedure Ilil"•orp %laka,LIA: 16.0 Run Injection Assembly . .4 12 -- 16.1 M/U injection assy and RIH to setting depth. i. Ensure appropriate well control crossovers on rig floor and ready. ii. Monitor displacement from wellbore while RIH. 16.2 __, . . _ . ., : . 16.3 Circulate freeze protect down IA, allow freeze protect to U-tube down tubing. _ SP4-6.ca,..—*- c (e..-•-.9 S ,fdt-<., , 16.4 /.;Y::,r�- . Test annulus to 3000 psi f/30 min. 16.5 Install BPV and N/D BOP. 16.6 N/U tree adapter and tree. Conduct pressure tests of same to 250/3000 psi. 16.7 Shut in well. 17.0 RDMO �, 9 * wA ` Page 23 Version 1 August,2015 • Milne Point Drilling & Completion Procedure iri,.." u:,a.8.11.1 18.0 BOP Schematic / I \ 1 1 Hydril Annular BOP 11"x 5M II MI AM • 1 v v v „a! Hydril 11"x 5M 1�... -- _m NM -. p 1i immi aim I -NM Il ► � / I r 7_3"x 5M HCR • ��� • f • I I■I I[`• }ll/I 11 l J/' ----Choke Line Kill Line — 3"x 5M Manual Gate Valve = Hydric 11"x 5M = — _ .j DO Mi Y 5f11e-fII- MI in ns , ~-~�11"x 5M 4' "" rfl,: Ig il T S 2-1116"x5M II20"Casing 7"Casing Page 24 Version 1 August, 2015 s 0 Milne Point Drilling& Completion Procedure lid,orp:tIaska,1.1.1. 19.0 Wellhead Schematic AFIIIN 1 Wellhead,, quipment Division Tobasco II System Date: /0/7/00 Rig: Vo-Vo/ti l'YI Well Number: 1b P'S—2-23 - i` .17 , mom 40 Tree: f c. Me.( I [1Q_n, A" .o o (S Bore: 3' —'.r rit" R I�; n- /.G8/ Im, 11" 5000 FLG. ,--or.- ■ 0=1 t O ,.11.' a®ILI11.11 _ if: FMC • 2o3' IF * :1 ) 6 e 1 1 _. 1' i f-C-- 0 Page 25 Version 1 August, 2015 S S Milne Point Drilling & Completion Procedure ili) urp ua,ka.I I I 20.0 Days vs Depth J-23A Days Vs Depth 7000 8000 • 9000 10004 2 N IQ 91 nom 12000 13300 14;04 0 2 4 6 8 10 12 14 16 18 20 Days Page 26 Version 1 August,2015 4 • Milne Point Drilling& Completion Procedure I lih orp. Ia.ka.I.IC 21.0 Formation Tops Formation TVD (Top) TVD (Bottom) Anticipated Pressure (Psi) SV1 2150 3334 1491 Ugnu LA3 3335 3549 1587 SB NA Top 3550 3630 1623 SB OA Sand Top 3631 3640 1628 Page 27 Version 1 August,2015 • • Milne Point Drilling& Completion Procedure I Mein p.4.IaSI(a.LI.I 22.0 Anticipated Drilling Hazards 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"J"pad. encountered 1. The AOGCC will be notified within 24 hours if H2 S i s e ncou to ed 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"J"pad. Page 28 Version 1 August, 2015 • ! II Milne Point Drilling & Completion Procedure Ililrorp 11a.ka.1.1.1 23.0 Nordic #3 Rig Layout (Drillers Side) CI r R � ' , C - €alista l 0 Services ' Ovc)ott...., 1R/G NO. 3 Tilam,":n iuling pe ilsat•..ru.arawa aaadsM raevaxe The dcogn! eiaa ef.•.prvprrtr op!rlmdir• Cabot and u potsei d Ler US and-ca.aneiauI copyright tram The Design i.(r Mei in at rwd&anial hnint wih rhe e.pe.a apt-cram thats it rut br eo d.r.andeu.d.applied.around-phrrograshnl,or rrp dnerd in sera'mann whataoe rr.in wink as par..rra any nem Iwrmt he huih.marrai'aurcd,.n mar rtiski with ter alt of the as.ign wuiom the',norm agreemcr.of Nsudr-Calvn'a..The Design may nsa In darkerto amx raker platy strap for the apaipr purpose for%hire it hor hero poridrt i 40 Jo. 44 1. 1, ,..40. rrr wr >ItI r r •-•vt r-ora Vt.—,-.6+y, � OR WOt arA nrsae. AL 1 MEL eV-.. 41_,_ Nor •11., ` f IMO Pei UM VI ii. \` ' €1: aWzj ._—___ r-r r; t 41"-r r-r r-r rr EY at-dr r Ir-r • Dr llers Side Page 29 Version 1 August, 2015 • • 11 Milne Point Drilling & Completion Procedure I Glrnrp.Ua'ka•1.1A, 24.0 Nordic #3 Rig Layout (Well End & Top View) [---- u-o' MO g� W . ct ti, .1 •' 1 1 '. I I I -- •fit n •I - �p __„./-- 1 LN µ M■ ENCLG•31YrL ®s b IH1iii1V1 r oc. '0 4C0EPT FLGW UI€5 Well End ,w-r .S-, _. ._——N- Y-t+,,- —,r-rcr - xf-Y —+r-r--1 fl 1 r Ni I n Ne amity ,'. COON minim��minimwm.aeMo = ti , i M — 114,- ``.fi= == , 116 1 pMIK �y�pTry�p y .��. 1 PP(POOP 11111111j U PPE acva,rw u --,r-ra— 141'-7• _ TOP VIEW Page 30 Version 1 August, 2015 S Milne Point Drilling& Completion Procedure IIII.orp:1Ia,'ka,1,1.1: 25.0 FIT Procedure Formation Integrity Test (FIT) and Leak-Off Test (LOT) Procedures Procedure for FIT: 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer(ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Page 31 Version 1 August,2015 0 Milne Point Drilling & Completion Procedure Ilil(•orp:tiW4I a,Lii: 26.0 Choke Manifold Schematic 3`>'sf 'S t<<t`>iiSa<'�,•.•:,t`s'iar<ifl'>eac`.sr><!<``iY'}1<<�fii'/1tf><i`f i)•t`<`` >ta'i'>•>'tf t <t>ss' sfYf. i`rsDsf f `t<tf�t1 f'))>'<<<tf< <s'}t`'A<i<a <a<r:f •—>`s)i<•'a>s 1>>Y'<f<a>r f>•�:t ts'�< f `s` <i ia>'1 at< f ifA#<3 > >`K..,..'.ti i<•>ft`<l'>'tsfiS tff i`<t>''. fe< x)<s .a: >'>Yi `sfSE<a r)f)>y i[i 3>>>°;;�t Ya>ft.>'>f'i<R<,aa' ,,x iSff > SiY`<Si>ilAifit)iftl[Ytay`st>fTtff3i'iTe3 3 >tiY ><i > IF< !d1Yn�[ 4Sf3i3`}ff<<,`> >` ) aiT'ff<>f :>iSft> iiYifii1i<f< `YSiS>fif)> i<)if )i}iiay<. � � :: j IL vits. t = it ° ` 'f < i f'' ' ' < ' , • yfif3 >0>03 > Ys !fia:)fofS ` f3ai < `sYi> •;• f >} >fa sat >fJ > )<s'<i -(:: : ' tl <>•'<>:...,,xf '<t 111 3 '<3St't'it <'1'<'<:t's<:i <! s < 4 <i'< ir 'iY :1 atfa <: t'ttttt i'tJc <te> a'>S' '<'i'< 'I' f3f• • f Y > f3 Tsf a > >tY > ' > ) •if < <> i< •Y>YDeft)S><)t'3'a>i ;at <!i'{)Kf<><><31'S < i)t <'S'(S> [ Sw,awt�t .::::::::::::::::::::::::::::::::::i::::::11.,,, . )[)t}<>i ( >t>S)ft>t ( ('<', < <::YSaf>1ytr ( <<>t>t>i/3<Y [>t'1aYs<)< if>t<a['3tt i:r<i< si ' S < :ff3f>`}R}ffys ip. �1 . >f } tf) > f } <3aY > a } 3a > ' tii'S ! r ' ' ' ' ' ' ' s ° a`>°}`fS!e>iri!f>fst> s ,,,,,„:.:.:.,,,,,.x.,,,,,..:. .\-`feit�>e>t><•t>t>°Ye><fi><rt>< `a<r<> > ):)i}<>< <se> aS:<aiai>fa '`afss>c>tYtrY)cs<'t': < a ' 'f' ' ' ' a' s < a't'<'S'<'t'<'<'aa('i'<'<:t'<'+ { <y<' ><' ]o'<'<da't>i','< < 1't'S'i'1'i <i'fIa0 ('t'<'c'i',a< t':'1'< i:ii {'c't'< i <'+' Iri><'e><':':'fJ t>t>t)tf<atair<If :°Yi>iJa> ria<><)t>i,t) �.� � '>:::: :'/..:::,:,X.:,;,: t: efY> � ,'..Xe <Ja)O i >a> i:=',, t'1}'`t `t3`>:}`iSfSf3`) i::::::::,]::::::::::::::::::::::::::).*]*. :tfife>a ii'i ' :f>Sa'i' ft1St � ;::.N::::::::::::::,:::::::::: t' ✓}sfSs`>' s`>`iiT >t 'tif1Si>i sifArt <)iS3 ) }e . 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R't3 > }< i [ ,,,,� i> Jf):'<' r`)f.ftl}f' > Dfi'`Y'`> fSf):a•'ff ' 'ffD:`f'i>af<>'f3',>'>tf< f}', >ff'i�fi>f♦fffY:>(•f/f1fYYY3fSf> 3a >`>iTf>f ) xiftlesY<>f9 L }t3tff>eit! ifs'itifi<i{i1iffiti<it[;< <atat•a'<'<'<i< t <�a <Ie 1 , �1.� f ..*4: _1i}<}i>aai} >iiya}at ` a` f `Ji)t1 )f) }� Y) (firr_ `� r �cif' �� >` >fa > f .fJy J 7<a<><>t,<)f) i>`Sf>i>,>t)<)<° '><> t>'<}'Y DtStYT<eaTf]i ` f>f lf TR f< TDtIs '><'a Y<> a: D<>1}<>t t)tI+ti<3i]< 4 <fta 'f <1ts`i ',Cf > )t >f) fSaf<3'`ti +:RtY .a:Yi'atr'a. ae9[. <1t aS<T •<. aD{> . t<•.> tr'. iar)i• > >e'r:.'.>:afi)<• >.> )<1R) T r!<Ti :'> m'<T;a> ).<,ro a rr afiaY >t>at:e't': 't Y< iti° Page 32 Version 1 August, 2015 • • Milne Point Drilling & Completion Procedure 27.0 Casing Design Information Calculation & Casing Design Factors DATE: 8/5/2015 WELL: MPU J-23A DESIGN BY:Luke Keller Design Criteria: Hole Size 6-118" Mud Density: 9.5 ppg Hole Size Mud Density: Hole Size Mud Density: Drilling Mode MASP: 1242 psi(see attached MASP determination&calculation) MASP: Production Mode MASP: 1242 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 4-1/2" Top(MD) 7,700 , Top(TVD) 3554 Bottom(MD) 13.433 • Bottom(TVD) 3,555 Length 9,879 Weight(ppf) 13.5 Grade L-80 Connection VAM HTTC Weight wlo Bouyancy Factor(lbs) 133,367 Tension at Top of Section(lbs) 133,367 Min strength Tension(1000 lbs) 307 Worst Case Safety Factor(Tension) 2.30 • Collapse Pressure at bottom(Psi) 1.756 Collapse Resistance wlo tension(Psi) 8,540 Worst Case Safety Factor(Collapse) 4.86 MASP psi 1,242 Minimum Yield(psi) 9,020 Worst case safety factor(Burst) 7.26 • Page 33 Version 1 August, 2015 I II Milne Point Drilling & Completion Procedure irirorp %Ia.La.HA: 28.0 6-1/8" Hole Section MASP ,,-_,_ f--A Maximum Anticipated Surface Pressure Calculation 6-1/8" Hole Section 11ilcorn MPU 1-23A Milne Point Unit MD ND Planned Top: 7780 3554 Planned TD: 13433 3555 Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad Schrader Bluff NBSand 3,576 1599 Oil/Wet 8.6 I 0.447 Offset Well Mud Densities Well MW range Top(TVD) Bottom (TVD) Date MPI -19 9-9.3 ppg Surface 4,079 2004 MPI-18 9- 10 ppg Surface 3,848 2011 MPI-17 9-9.5 ppg Surface 3,864 2004 MPI-16 9-9.3 ppg Surface 4,101 2004 MPI- 15 9- 10.8 ppg Surface 4,042 2002 MPI - 14 9.1-9.3 ppg Surface 3,979 2004 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 6-1/8" hole section is 9.5 ppg. 3, Calculations assume full evacuation of wellbore to gas Fracture Pressure at 7"window considering a full column of gas from shoe to surface: 3576(ft)x 0.78(psi/ft)= 2789 psi 2789(psi)-[0.1(psi/ft)*3576(ft)j= 2432 psi MASP from pore pressure(complete evacuation of wellbore to gas from Schrader Bluff OA sand) \ 3576(ft)x 0.447(psi/ft)= 1599 psi A." SP (.--.-599(psi) -0.1(psi/ft)*3576(ft)= 1242 psi / Summary: — 1. MASP while drilling 6-1/84 production hole is governed by pore pressure and evacuation of entire wellbore to gas at 0.1 psi/ft. Page 34 Version 1 August, 2015 I Milne Point Drilling & Completion Procedure iul'•"'I' %111.1,:'.1.1.1: 29.0 Spider Plot (NAD 27) (Governmental Sections) • ADL025515 ', ci .:- l Sec.24 Sec. 19 -'' Sec.20� % Sec.121 ` •\ '. - , ADL315848 • a \ I ,, ♦ 1 a , i.'.r 7 l, }.1�NE SITE E v r , , 1 t 0• AA 7T 1 _ - 4 Qj}'FJn,Pe. • , , n l , _tea _ ,� _, ,, ,, a< \lP.l ?.A Ulli. . MPJ-23A TPH ` •?,� v u •• rN ��__Sec 29 R' !,-7,77—,..„ , ,�} tt_°!_ Sec. 30 ,�N .� .- J ,,4,_, ,i U013N010E.._ vc--- ,23 .+' U013N009E , , ,\ • , • MPJ-23A SHL I a _..�:.t' , •may. rn. �. _. ' ; , / , a a ' 1 y I I IADL025906 AD1025519 .i ADL025517 .� , .5 I VISA?...25 c'i J i S' � L' S• 25 s, ..,-� us__ 2 ` r. Sec.3r6 Sec.31 Sec. 3: "-------- -- ---- •Src..33.2 _- _ ..�_ -'^'` 4 t iiia ea+ ��-- M. �� �`-'-"'` Pyr, s r Legend - --- -------- 4> cJ< }h C f ::�f.�- MPJ-23A SHL i MPJ-23A TPH a KUPARUK RIVER UNIT MPJ-23A BHL Al AC11025627 Sec.4 Other Surface Holes(SHL) Sec.6; '.;,U012N010E Sec 3 • Other Bottom Holes(BHL) - - -- Other Well Paths , IIMilne Point Unit 0 1,000 2.000 3.000 MPJ 23A Well Feet Page 35 Version 1 August, 2015 0 • Milne Point Drilling& Completion Procedure ih'orp.Ua.+ka.I.I.1: 30.0 Surface Plat (As Built) (NAD 27) N 1800+ 20 J—I NOR fl' PROJECT AREA 21 2z W o, 27 MPU J—PAD �g �Q ' P, UPAD 1 PAG —tV— me 3.3 4 34 I H PAD II e .F 23 VICINITY MAP 1 • NOTES N.T.S. 11 • 2 • 1_ DATE OF SURVEY: JULY 26, 2000. 8 IN 2. REFERENCE FIELD BOOKS: MP00-01 (POS. 28--29). 10 II . ALASKA STATE PLANE COORDINATES ARE ZONE 4, ALASKA, NAC/ 27. 4 • 4. GEODETIC COORDINATES ARE NAD 27. 5. PAD SCALE FACTOR IS 0.9999031. 6. HORIZONTAL 1 VERTICAL CONTROL IS BASED ON J PAO WELLS J-1 AND J-2. 7. ELEVATIONS ARE BPX MILNE POINT I9 • • 6 DATUM M.S-L. 16 • •12 17 ■ •13 �% %*4E‘‘10%%11111,, O F 14 C141Ii 19 • • 5 _moi I?�,.• • '•.;�,5 �/ 20 ■ •14 r 67 .' ` ,••"T 2' IN • 7 7te:49m i'' ' , .�► 22 • r,�; ( i ` _---, ; Jeffrey J. Cotton/ ' LS 8306 +` (IINW ANS J-2 SOUTH SURVEYOR'S CERTIFICATE LEGEND I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN D THAT +N 400 AS—BUILT CONDUCTOR THE STATE OF ALASKA THIS PLAT REPRESENTS A�SURVEY ■ EXISTING CONDUCTOR MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF AUGUST 8, 2000. LOCATED WITHIN PROTRACTED SEC. 28, T. 13 N., R. 10 E., UMIAT MERIDIAN, ALASKA WELL A-SP PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DO) BOX ELEV. OFFSETS Y= 6,015,082.24 N= 1,329.77 70'27'07.009" 70,4519469'^ 2685'FSL J-23 X= 551,926.95 E. 1,119.45 149'34'34.718' 149,5763106' 36.1' 3390'FEL Y= 6,015,110.45 N. 1,360.69 70'27'07.288" 70.4520244' 2713'FSL J-24 X= 551,914.26 E= 1,119.14 _14:34'35.085" 149.5764125' 3fi.3' 3402'FEL JACOBS I4 ® BP EXPLORATION a/2!0a It.l l.l., , PJ M23J24 IP MPU J—PAD —' ' I I`,,., AS—BUILT CONDUCTOR 011/2/OJJSSUED FOR WF0RMA110K JJ ok, ITPpis,�,fflrns tt�a[ 1 Or 1 w, q,.a mu ,,,OL ;. ,w MT I'.200 WELL MP J-23 & J-24 Page 36 Version 1 August, 2015 • Milne Point Drilling & Completion Procedure IliIcorp Alaska.1.1.1: 31.0 Drill Pipe Specifications Drill Pipe Performance Characteristics U Pipe line and Weight:4"14.00 IU Pipe Grade: 5-135 Range: 2._ _ Tool Joint: &mix ZI IIs Pipe -- - __... _ .. New Premium Nein Premium OD(in) 4.000 3.868 Torsional strength(ft-lbs) 41,900 32,800 Wall thickness(in) 0.330 0.264 Tensile strength (lbs) 513,600 403,500 ID(in) 3.340 3.340 Calculated plain end weight(Ins/ft) 12.921 10.151 80%Torsional strength(ft-lbs) 33,500 26,200 Note:Premium properties are calculated based on uniform 00 and wall thickness. Cross sectional area pipe body(In') 3.805 2.989 Pressure capacity(psi) 19,491 18,428 Cross sectional area OD(In2) 12.586 11.751 Collapse capacity(psi) 20,141 13,836 Cross secbonai area ID(Ing) 8.762 8.762 Section modulus(in') 3.229 2.523 Polar section modulus(in3) 6.458 5.046 Tool Joint Drill pipe assembly with Grant Prideco XT39 OD(in) 5.000 XT39 uXtremeTM Torque Connection ID ON 2.813 Pin tong length(in) 10.0 Adjusted weight(Ibslft) 15.66 Box tong length(in) 15.0 Approximate length(ft) 31.64 Torsional Strength(ft-Rrs) 32,900 Fluid displacement(gallft) 0,240 Max Recommended Make-up Torque(ft-lbs) 19,700 Fluid capacity{gatift) 0.446 Min Recommended Make-up Torque(ft-lbs) 12,000 Drift size(in) 2.688 Balance OD(in) 4.852 Tensile strength(lbs) 599,500 Tool joinUDrill pipe torsional ratio(New pipe) 0.79 Tool joint/Drill pipe torsional ratio(Prem pipe) 1.00 Min OD for premium class(in) 4.656 Minimum make-up is based on shoulder sezaraaon caused by bending. Page 37 Version 1 August,2015 i • Milne Point Drilling & Completion Procedure Ililrorp:tla ka.1.1.1: Torque Tension Curve: 4" 14.00 IU S-135 Premium Class Drill Pipe with 5.000 X ,,. -` 2.813 XT39 eXtreme TPA Torque Tool Joint. Curve Based on Calculation Method in I. API RP7G. Safety Factor=1.0 G'rfi:111TPR1DF.CYJ 700,000 - i 600,000 - _ - '° 500,000 - — v 1 16 • \ 0 J a 400,000 _ op C F v 300,000 -- __. Ti..._• 4 200,000 100,000 - I L_.,, 1 f / 0 1 r f I 0 5,000 10,000 15,000 20,000 25,000 30,000 35,000 Applied Torsional Load(ft-lbs) w.1.....lJ..W..., - Page 38 Version 1 August, 2015 S Area of Review — Proposed MPJ-23A Injection Well Prior to completion of the MPJ-23A Schrader Bluff NB injection well, an Area of Review (AOR) must be conducted. This AOR found MPJ-23, MPJ-23L1, MPJ-20A, MPJ-26, MPJ-26L1, MPJ-26L2, MPN-01, MPN-01A, MPN-01B, MPJ-27(future): within % mile of MPJ-23A's entry into the SB OA formation. The tables below illustrate the wells within the AOR, the distance from MPL-49, completion details and integrity conditions based on in-depth review of each well. Table 1: Wells within AOR Well Name PTD Distance, Ft. Annulus Integrity MPJ-27 TBD TBD Will submit post completion — MPJ-23/L1 200- 316' J-23 L-1 slotted liner lateral and mother bore below 7800'to 120/200-121 be P&A'd. 3.5"tubing to be cut/pulled above packer at 7900'. Cement retainer will be set at 7800' and cement bullheaded to P&A. Cement plug to be tested to 1750 psi MPJ-23A TBD 0' 4.5" injection tubing will be completed with production packer at 7,700'4.5"by 7" Inner Annulus will be tested to ✓ 3000 psi to verify integrity. 7" casing was cemented with 1187 bbls cement, 20 bbls excess to surface. MPJ-20A 200-185 760' Long Term Shut-In produced water injector with an MBE to J-23. Had a passing MIT-IA on 6/3/2006. 7" casing was cemented to surface with 618 bbls cement, 84 bbls excess to surface. 4.5" Liner cemented with 126 bbls cement. MPJ- 204- 1,550'/1,560' Active Jet Pump Producer with two slotted liner laterals had 26/L1/L2 064/204- /1,555' passing MIT-IA to 3500 psi on 2/26/14. 10-3/4" Surface 066/204-067 casing cemented with 406 bbls cement, 166 bbls excess to surface. 7-5/8" Production casing cemented with 157 bbls cement. Good circulation through cement job and bumped plug. Estimated TOC of 7-5/8" at -2300 MD. /'- MPN-01 183-178 520' P&A'd on 1/5/1984. 9-5/8" Surface casing cemented with 478 bbls cement, 68 bbls excess to surface. Wellbore plugged back at 6776', 3600', 3150' and 2400' MPN-01A 184-006 845' P&A'd on 1/18/1984. 9-5/8" Surface casing cemented with 478 bbls cement, 68 bbls excess to surface. Wellbore plugged back at 7900', 3600', 3050' and 2350'/ MPN-01B 184-013 760' P&A'd 3/29/2002. 9-5/8" Surface casing cemented with 478 bbls cement, 68 bbls excess to surface. 7" Production casing cemented with 1100 sks cement with TOC @ "'2000' MD bbls. 3.5" tubing pulled from 320'. Cement plug of 7" casing and 7"x 9-5/8" annulus from 274' to surface. 0 • 4i Ef ,74 1119 J�27 / 19 ems ismsiii;11 J•24L1 e ' h r����� y*` ayN Il f,' � / ,__, . J-23 Prop ,1•20Ath •2OA \ J.17 ` J-29 \ h •a4``,, e149A 4 , , --- ��� - Jen ` �N -r l \ I ,,,, V \ ci-23L1 \‘ , I 41A N c'' --- 1_ 1 1 ; l 1 1 HILCORP ALASKA LLC 1 VthE PObi1FEL /CAW1 ,p .. 1.No..Ja4 tor / 1 Z ` � FEET I 1. Q i 1 PO5TEDWELL DATA /` // , Web Number i I ,,,t ‘ 0 112 1 a1/L1 \ WEAK 25 WELL SYMBOLS -.1 ----- / I Active°, ` / 1 ¢ GSA I.12L1 __ - A NJWell i 4 Flocdl h 07PIA 01 �. Abandard lgeda M3 I-0 -- = hjecta Laatlrn -_-_ - .�_a�: Reducerlcmlm -. -,!___— - ------- - 141 xrpm.a 3 L. --14f.. gk b. ." j August 21 20'5 (sr.-a J • • AFE No. Well Nana: KB: I:D'I AC'L 0017626 Milne Point Unit IMPtl)J-27 GI.4 RKB 35 ft-K ft=65 ft API C -BD AFE WELLBORE DESIGN Proposed TD: 13.701 Permit No. TBD Proposed TVD: 3,5,99' Geologic VdamsadorWeilbcre irn rnolsen Casing int,:btsd int;Hole Size Cement Specs 1RKB-Tubing Hanger a' °1O' 55 TVD FM Lithology Conductor 20"conductor(Pre-set)to 80'BGL(110'RKB) line: Sutace IKin $ Surface Casing MI�Iyce; 39-518"40#L 80 TC-II set at 8.247 MD 13.665'ND Fresh WowIb.,r ix A 1 Welg`t Ringo Surface Casing Cement 0.042. 2. $I 1st Stage: E 60 bbls 10.5 ppg Tuned spacer III a V °# Lead:(30%OH Excess)ARCTICCEM @ 10.7 ppg E m Tail:(30%OH Excess)SWIFTCEM 15.8 ppg a e�E 2nd stage: 60 bbls 10.5 ppg Tuned spacer III Lead:(Until returns at surface)ARCTICCEM 10.7 ppg 1.750' T Tail:SWIFTCEM 15.8 ppg i 5'a -n. . Production Liner i . 4-112"Screens c1w base pipe: w q C 9 11.6#L-80 Hydril 521screens©13.701'MD 13,589'TVD is 't < Tieback N it c °` 7.518"29.7#L-80 VAM STL 8100'MD/3,665'TVD 2 ,J 4 ,,sa in c"; Production Tubing rd iin F..1., i ^ ; 2-718"6.4#L-80 8RD EUE z IIL 35 • 0. o i,M= ESP Liner Top Packer Wire wrapped screen production liner A-Hrids Coarse sand,silty shale,better kidIniervat Sed saw U6NU developed Fradxace Hoe Liards ntervenlrs shales • Mud Type: -yugo wordy n the L and M 'f g c_y -, N ssrds Continued layering as alig' 'I/ WW1 RAP'Schrader ss TEAL mare ll a9-92ppg 0-s20ds condensed nods ecc 47D7' coal --- s-sir shoe • • MUM 3-1.8-FMC horizortal woes MP -spry KR Plav i. 1 Y'x.11-15941 tb4.apocf.. FMC Horbornal Irsa Motto,1213 OF olov.-A9?:.1' 1 3'14 3-5'8111 Et1E(I88 A=Morn) GE_olov.-35 130,. FMC TBC3 HMCi at 3.5-1-1'WV prattle 20' ( 110? Al Tam poll collar Lifland 3.5'31.301 pat,1-80 EtIE N6 tubing, l: m om 3.5"x 1' p 8122.9.36 (dr81 ID a 2.8 '.cap...0.0087 opr1 sldaryrlckar'(Bi..3 GLM 7"28 lag1,L-80,Btrc.prop l<cLI oolong (18141 ID•6.181'.cap ..0 fl383 bp,1 KCP es' 9 Maa...tabors,Ar.pb 79'AD'MO RWM amain 11-vouch parrs-110 Clot} I . .. Con-co 3.6'x 1- I 27312 z Ok opacat KUUI3 OIM i ;I e.ewnr r tar 111 1 ®Amato-0MLI-1 9 shawl jt J wr 2.91-X Matta molds I 71.110' I B 1 ae"ar t'nanlry gauger(3667-twit r 7854' 1 1 t I _ - — • Ramo S-3 Pecker(3.97'ID) 7CK1' , I - Yr'1 3.5'-HES XMNlp7M —� ' 7976 T.9Y3'pwchwrY;lr 2 76'No� _ E %IDLER E-79;777 nes amt Rakes 1ir+U.:"hoe RA tap at 6858' Salmi torn 8539"(29.73) lAMsd wrnoow horn asocr asa..".. 1p W Mon..$leer 1:393 13902'31940' Rake.-4 5'/taw,al.lda MOM vRt1376' I 8573' 781u.at slatted mot s 1naa"1 imam,-11e81 1 to nohow HR erflbrrj atoatixr 8580" Kr—f----_,--'n7.7".'''.1r_ Raker 7-ML tongue rnasla.pew 800-47 _ �� - AILED I 8814` r>F // 411 M 4.5'12.8/..1-90 IBT Luang. o M'/ Fir r Float shoe at 12082' nkar MR 3r8ava w oataneirlo 1�--79n 4 0 Baker 1110 Ins.Manger ' r 8947'i Ha/fbvlory Allam=Aar L now li � �' }p�- HaIthvrn itoad atlgo baa, -" .1111•01111• -ill L 4.6-12 41,L-B0 1191 tubing Raker Frost shoo al 1217$' 97Its.ot S810011 lelar 434023(88+Er3..12082'1 �� ._....rl.4.7.3Rh,Q'LLE77 INTERVALS ... OA 111402'43.340-IWO(3W) OA-B881'-t`9111r IMO(30037 OR-6Et90'-120132`PAD r/ATE REV.FEY COf. .4EMT8 , MILNE POINT UNIT 1+7.0000 M.Lindkv tr11t01 comptefal by Oowtn+141 WELL J-23 00'1.5+C21 B.Haaatm Aadttkm of,tat PUmp now acrtameisc API NO: 50-029-22970 BP EXPLORATION (AK) • III IjrniK 2 9116"- 5M ( WeIneart 11'SM FMC Gen 6 -MO. Hno: 2 7/6"x11' FMC wi 2 706" rPr SCT TAB and .5 N 2 ' CIW H ESPV 011ile _. . MPU J-20 Or1®_ 04—.0.----= 54-22-{ht 22E) Ong,GL Blair., a 35.10' OF to T.'cag- hno, .,30,13' (N 22E) 20r 91,1 ppot. H-40 115 Koaa a 400' 11111 11ES X-Nipple 2,313"id 2041' Max. hole angle=79 to1151.4 ciao. U 3,300'to 10.512 Hole angle elmparts=43 deg. 0 7 Howe°'''ES"Cementer 2194- .111M= 27i8"6.5 cpf. L-50. SUE Sa•cl.lbg. (dnit.,..2.441" .cap.= ( .0055 lope) gamins 7"26 pcif IL-615 Mod. Btac_prod_casing ( drift ID=6_151 .cap_=o.ctsaa bpi) JLIoac 4.5'12,6 ppf.L-60 1ST drift=3_056"id (cap= .0152 bp0) 2-706"HES x-Nippie 2 313-Id Exuai Min. id ir 2,205" 1 ...,,,... 7ir2-7.43"Bakerl,kr.S-.3 Peon pkr. 50,39' a• Wirkitaw cut 6202'-6,216 v5.0463, MIS 2 7.4r HES XN.NIppie 2204-id 5065.6 WLEG .G77- Baker 6"lie back shrew 4_6 Baker landing cellar MEM Baker 2:141P rxxrip.liner lop packer 6,007 41,15*has float color MOM Baker 5 x 7"flax lock lunar hanger SAW- .,%\..............„...______. - 4.O'has float shoe NM Poriorutkai SIIIIIIIIIIry arar . I-IEEI 7"EZEini Liner Size SPF larval tirvm Pk( a 6,213' 45" 126Th L-80 IB.T 3.958-Ici ( .0152 003 2" 4 10,900'-10,920r 3.7,02'- 3..796' 7 ... 2' 4 10,020.-10040 3.796-3.000f ':,3'14 2' 4 10.006%11.016 3.8515.- 3.670 • -.„ , •-•1•";"' ; :.11.64P; 2...POWORIell gums .40 apt so degree Phasing ., . :. o4TE IFiEV.ErY CCeillialEtfra .. MILNE POINT UNIT 01/2=1 MDO Sidetrack 1n4 or completion Nabors 22e Amillhei 02/16.,01 MDC - Initial perforations vat clu a-line Ifirg , API NO: 50-029-22832-01 - BP EXPLORATION (AK) • • -Trpp. Cameron 4-1116" - SMO.'Cr Poo = 69 r90r{Doyon 141 vVelhead, 11'x 4.6 Alias Brat, M PJ-`6/ 1/L Ung.rrgr Eder- 30-27'(Doyon 14) ford Wr2{3'8) I wire poll h 4.5' r TC-I-A EMS T&B Tub,Hang r -I cm BPV 4 5-H'Type i FI 20'x 34' insulatBl.215.k.i A-53 11 a^°lid Camco 4.6-x I"Ns.'EYG latch I .492 10 31'4"4S S par yip 9 FFiC- asidepaa:►.et KGB-2 w-,DCK-2 nheare valva CiLh1 {E7Ptt ID=9 794-cap = 0061 Dat} 10 314-HiowC°F'loal Shoe I 'gtpgi KOP lI 30C' 611•dogma!►c'1 25511 .. Max bole angle-74 degree a 3736- . 61 n.*green(I[.Hsi) '1 ft / 1.' 1 cei 11 po,i Dhoe,nrx DiacFargie gamma l`J 133-id} I 4.947' 400! 11 1*, it i "J I�I 1 e 5'FiES-M@'Dom sliding sleeve � •,960"•, f patent.gauge 13.85 .d 5 4 570" 4.5"HES X Mkpple 13.513 ID-) L_S-y,Cb41 798'x 4.5'HES TNT 1.. 50 Ptlt ar. 5.0667' I I 4.5'tiES X Nipple{3.1313 10.'I 5.10T' I 4.6'HES*N-1�Upp4e{3.725-VIt7 2 C-A1 plug 5.1 79":, 7 5.'8"29 7 MCL-84.®TAC415 [duringaYLEr3 w ITC-11 and 5.0000. 15.231 Mil 10.15ID.8.750-.cap=0045900 17 518-X 2 7.'8-Cep = 0379 001 I(IBC.4.5 L.-a0 T+:,„„-11 12 6 1 PEI (T8G 4 5 flfl ad=3 956-cap= 01522 bp11 OA Sands. 5270 -8535'MD Bare Plo KOP 504` •*_ 3$L-I -3907'7\43 5G- degree from 4250 1' '°•-4e x es 053`5 aa. a s r35'. Mci .hole sevla In lbg■ 64' .48.50' :. I.r.. �- � 76 re. 4 1.7-Slanrd hnrr F.511=1 Win.1ow in 7518'Casng @ 5270'-5287• 12 Fix L-th1 1BT..5134'-g440 1 27 Weil Angle ISE window 75` Baker T Bac..SWva 5228 - Baker 22r5'Law Tap Packer 5239' taker H..d.Har ar LEM 5255 -5290 ,near>lodaa•M a Harlow ams.LSrS Window'u•SCb' wak.1*took WM OS Sande 5558 -8670'MG 'rt.-v++.W .-,toff(Madam 5298 4014'-4843 TVD 'ir ndow n 7-514'casino a 5868'-557.9" rill 1.�ieiy1 4 1.7-5:b11v0 Liner ww:lasM '.W5 Taw Br.. window 78' 92.SO L-a1C1 101 t4<d1'45011 Br...*7r�rsrw.a 55ut 93 8,..,p.ZAP'L mr Torr Packs,7.46 e 7 n: M eooka manger LEY 1543'-VON 1 i Jr . . . . . . 1l' t :e ..r 1-1mk wall a 1J '1444e see a870 1Yn Illskir-V-rem(:ir+o.e.I1- ',n.pyr Ae.de r 7.4 whMpaa 5563' Hak M'Mask.WWI ---.--.. Ha..!laer aae.ael 7.5atr Vehma r.557111.- 148 Sands. 6406'-8760'MO . 3515'-3694'TVD Baker LIP Liner Top P.eosar seas Laker 64 Paeewl►Sol Sipple d T I 4 tl 14.8-40,-.e4:1147 a Igor ar..ttakw-a..�-'v•ra-.a.!:err..117rr1 Baker 7-5AS-a 5.5"Flex Loch Lry Har 5717` Req Ir_N Laker 19847 Seal L'.-r+Lane neon 5?3I5 h _ale-al ra Sa �(I IR'RInrkx drK1 u 7-6.9"Wer lerinrd foal Coder 6318' 7fi IIS Raker 1v1rr1 recle.aipr Sin•._..3f{yy% 8796'1 7-5.9-Waal-earinrd Foal Shoe 6404' 4• DATE RF ?Y CC7MMFNT'S MILNE POINT UNIT 617104 Lea I lulme Drilled&Completed Doyen 14 2.25114 B.K ,skte Ooycr 16 ranged from ESI'10 JP WELL MTPJ-26 r. API NO. 5O-O2943205-OO . BP EXPLORATION (AKI • • X Final P&A'd Condition Milne Point N-01 B MUno Point Field, North Slope Alaska Nixed and camped 11.5 hbli Arcda5atI Csmeni pluyr tonurlasa.Gingham!dumped pumpr d dmxa 9.1:9'x 7'annulus.UMP retinas at 4urtaea GM satins at$'haluea angina l-tundra grade Irva1 Mblded au Wirt .... In nrar►4r Platt iml covtrtd. `;Ii-e M. {id* Thrd Depth S1ta/Cent nnermwevni x°par,arahad;ri 27i'r ;.oRauicraR -.I IF /2# LSD 13t)' aradn Putt Mtcw _ 18a'1•720 ,nwIfl abhC4Ir. SUKFAGE 9MSI' 478 KIM 2496' ° . 139'10D Nebo �Ir14'Yf5 +' 'Wimp 9avarad 321' lrtE4fmM1! .....y' Ppm ! _ .• ,oa*-i666`Ma it LINER i 105 t..z' a rn•x r annMus bat Plum ire lulus ,PRODUCTION r 2s# L-80 Mr 9193' 11 UG"sks 9 W1°,tx. TuLtibing : 1'LtBI 310- 9.24 L-80 8 RL 3325' 2t66arw #48`rub) 1 ' tI47'vei ad' 15 T_1Zfr phru. ki.tii 3,t 4 C.2 se Destrl 'ien CD I D ,h �- Placed 1 bbi es r p F! Depth 'uhuni Packer 323•.1'WO t - PO ..._......�...._....__ Arcteavl l balansad ping YMdU Tax as P�t1.'d wan iYelvxiPO «..., PBI'kill'Mt II'r.p;r'ullvdl r t 3 t,2"1..IX Lod 1ND 1uharq 9720' Iftrdirtlt tr,Paula ...IN • •+► QSV Ce en Retainer �` 9020' EZSV Cement Retainer r 8800' ° t 31.3 hh1 ._._.. .,. I°i°tt EZSV Cement Retainer 7" 3964' plug 2161'•3325 — 19aker FH.Rind Ret.Pecker 7" 3258' •. • P&A�IDescription Start Depth End Dept ^•••-% €2S\'l:rtttr1Httifaar R Plug Location Sgwtt ai Pr+h 4 apt Tw4a'SIC!IMF ria! ..° J . S9a9.296'5' ,1 Rcfcrcnc.4itp ••• 4+ ,,I ' 253 It(17.5 bbp Cm!Plug Surface 279 a 7'Bridge P9 285' 8 b>h1 Cmlt Plug Balanced 2159' 254r 63911,31,3 Uhl) Plug 3103' 964' d ATTACHMENT I PTD: 184-013 API 50-029-21083 — t SpL$Dote- Dec.17,1983 EFS,/Camint ararartini' =••,•� ., ® Date Suspended:Apra 27,1984 ,• Data P&A'd: March 30,2002 E1e+r,(RNE9 54,50 AM SL purr,IS ar016121/49ALIC '' 1.1— F All depths are RtCB measured depths. P0Os 1 S 4p!til S*OiS - Kguri1rd Perp;d$pI YUTS'AUSu' ha Lt$ 91 1 MOD DRAWING NIT TQ E._ MILhE Pt.N-018 1)9261'MU FAIRWEATHER E&P Final P&A i DHE '/ SZRVICJr'S'LW.. Os-Apr.8.02 s • Hilcorp Energy Company Milne Point M Pt J Pad MPJ-23 Plan: MPJ-23A Plan: MPJ-23A wp3 Standard Proposal Report 19 August, 2015 4 1 w ... .:: .z,.. .._: .. ,. 4., . ,..r, .. Y9 :.,n .. HALLIBURTON Sperry Drilling Services • • • HALLIBURTON Project: Milne Point • WELL DETAILS:0151-23 NAD 1927(NADCCNCI'NUS) Alaska Zone 04 ea.r.y DrillingSite: M Pt J Pad comdLe°a: 35.70 Well: MPJ-23 +N/-S +E/.W Northing Easn,g Lamado Longitude Slot Wellbore: Plan: MPJ-23A 0.00 0.00 6015082.24 551926.95 70°277.009 N 149°34.34.718W loon— Design: MPJ-23A wp3 FORMATION TOP DETAILS - No formation data is available 1500- - 2000— CASING DETAILS - TVD TVDSS MD Size Name - 3553.89 3487.89 7800.02 7 7"TOW - 3555.69 3489.69 13433.11 4-1/2 4 1/2"x6 1/8" • 2500— Start Dir 15.24°/100':7800'MD,3553.88'TVD:30°LT TF ‘, End Dir:7812.6 MD,3556.98'TVD - Start Dir 51/100':7832.8'MD,3561.62'7VD c 3000 - o ''End Dir:8359.67'MD,3629.31'ND o - o Total Depth:13433.11'MD,3555.69'TVD - '"Start Dir 51/100':8440.47'MD,3630.97'ND h X3500— ^ ,'' ,,,, --- _ End Dir :8933.11'MD,3631.87 TVD 'A To -��--� � ra' — - y N ri WO S� - 8 8 N O N O �� O w 1 ,- MPJ-23A Heel MPJ-23L1MPJ-23A wp3 2 4000— MPJ-23 MPJ-23A Toe I- - MPJ-23A NB - 4500— 5000— 5500— I I I I I I I I I I r I I I I I ; I I I 1 I I I I I I I I I I I I 1 I I I I l I I I I I I I I 1 I I I 1 I I I I I I I I I I I I 1 1 I 1 l 1 1 1 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 10500 11000 11500 12000 Vertical Section at 272.55°(750 usft/iin) In I liltvlrll 41) • HALLIEURTON Project: Milne Point WELL DETAILS:MPJ-23 g,,,,, Site: M Pt J Pad GmundLevel: 35.70 Well: MPJ-23 42,1/-S+E/-W Northing &sting Lamade Longitude Slot Wellbore. Plan:MPJ-23A 0.00 0.00 6015082.24 551926.95. 70°2T 7.039N 149°34'34.718W - Plan: MPJ-23A wp3 _ REFERENCE INFORMATION 2500— Ceordlmte(N/E)Reference:Well MPJ-23,True North Vertical(TVD)Reference:MPJ-236066.I0uafl(NORDIC 3) - Masured Depth Reference:MPJ-236 fa 66.COus?(NORDIC 3) Calculation Method:Minimum Curvatura CASING DETAILS 2000— ND TVOSS MD Size Name _ 3553.89 3487.89 7800.02 7 7'TOW 3555.69 3489.69 13433.11 4-1/2 41/2 z 61/8" 1500— - _ StartDir 15.24°/100:7800 MD,3553.S8TVD:347'LT IF StartDir 55100:8440.47 MID,3630.9TTVD 1000— Start Dr 5°/100':7832.6'MD,3561.62'TVD TotalDepth:13433.11'MD,3555.69 TVD - `.End Dir:8359.67 MD,3629.31'TVD`\ Ed Du:7812.6'MD,3556.98'TVD S - End Dir:8933.11'MD,3631.87 TVD • - 3 R _ • v' 500— i'' 'I' ` - ` � I rs, .-. MPS-23A wp3 IMP1-23A To# s I + _ MPI-23L1 MP1-23 I IMP1-23A Nil 0— IMPJ-23A Heel O - rn -500— -1000— -1500— _ T M Azimuths to True North Magnetic North:18.93° _ Magnetic Field Strength:57574.5snT -2000— Dip Angle:81.02° Data 5/28/2015 Model:BGGM2014 l I 1 j I I r I l r i l l l I I I I I I I I I I i i I I I I I I I I I I 1 111111111111111111 / I I I I I 1 l I I I I I I l l I ' -12000 -11500 -11000 -10500 -10000 -9500 -9000 -8500 -8000 -7500 -7000 -6500 -6000 -5500 -5000 West(-)/East(+)(750 ustVin) 1III(orp • • MALLIiURTON Project: Milne Point Sperry o,.IN, Site: M Pt J Pad Well: MPJ-23 Wellbore: Plan:MPJ-23A Plan: MPJ-23A wp3 MPJ-24A WP2 MPJ-24 a0 MPJ-224 Wp5_ NV1-24L MPJ24LIPB2 MPJ-24LIPB1 2167— MPI-Switch wp01 1733— MPI-20A Wpb hVJ-27 WP3 MPJ-20A 1300— a 867- - 41/2"x61/8" /Va 54-AID o ▪ 433— O - MPJ-23A wp3 „ + 7"TOW - - MP1-23L1 0A- 6g MPJ-23 o \ ▪ 0 _ gnQo - MO-b1 5110 -433— w 4000 -867- 007 )07 _ M Azimuths to True North Magnetic North:18.93° -1300— Magnetic Field _ Strength:57574.5snT Dip Angle:81.07 Date:5/262015 Model:BGGM2014 MPN-01B 7000 _ 'Uy,. MPN-OL_ 2 I I I I I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I` fel I I I 1 1 I 1 1 1 1 I 1 171451 r I I I J i I I i i I I 1 1 I 1 1 1 1 1 1 1 1 1 1 1 1 1 -11700 -11267 -10833 -10400 -9967 -9533 -9100 -8667 -8233 -7800 -7367 -6933 -6500 -6067 • West(-yEast(+)(650 usft/in) II I IIIIY1rp • • Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well MPJ-23 Company: Hilcorp Energy Company TVD Reference: MPJ-23A @ 66.00usft(NORDIC 3) Project: Milne Point MD Reference: MPJ-23A @ 66.O0usft(NORDIC 3) Site: M Pt J Pad North Reference: True Well: MPJ-23 Survey Calculation Method: Minimum Curvature Wellbore: Plan:MPJ-23A Design: MPJ-23Awp3 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 J Pad,TR-13-10 Site Position: Northing: 6,013,415.23 usft Latitude: 70°26'50.647 N From: Map Easting: 551,435.10 usft Longitude: 149°34'49.503 W Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.40 ° Well MPJ-23 Well Position +N/-S 0.00 usft Northing: 6,015,082.24 usft Latitude: 70°27'7.009 N +E/-W 0.00 usft Easting: 551,926.95 usft Longitude: 149°34'34.718 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 35.70 usft Wellbore Plan:MPJ-23A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) e) (nT) BGGM2014 5/26/2015 18.92 81.02 57,574 Design MPJ-23Awp3 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,800.00 Vertical Section: Depth From(TVD) +N1S +EJ-W Direction (usft) (usft) (usft) (°) 66.00 0.00 0.00 272.55 Plan Sections Measured Vertical ND Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (usft) (°) (°) (usft) usft (usft) (usft) (1100usft) 0100usft) 0100usft) (°) 7,800.00 74.93 272.50 3,553.88 3,487.88 213.21 -6,131.27 0.00 0.00 0.00 0.00 7,812.60 76.60 271.52 3,556.98 3,490.98 213.64 -6,143.47 15.24 13.21 -7.83 -30.00 7,832.60 76.60 271.52 3,561.62 3,495.62 214.15 -6,162.92 0.00 0.00 0.00 0.00 8,359.67 88.82 295.10 3,629.31 3,563.31 334.83 -6,666.70 5.00 2.32 4.47 64.31 8,440.47 88.82 295.10 3,630.97 3,564.97 369.10 -6,739.86 0.00 0.00 0.00 0.00 8,933.11 90.97 270.56 3,631.87 3,565.87 477.65 -7,216.50 5.00 0.44 -4.98 -85.10 12,233.11 90.97 270.56 3,576.00 3,510.00 509.90 -10,515.87 0.00 0.00 0.00 0.00 13,433.11 90.97 270.56 3,555.69 3,489.69 521.62 -11,715.64 0.00 0.00 0.00 0.00 8/19/2015 6:32:17PM Page 2 COMPASS 5000.1 Build 73 I • Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well MPJ-23 Company: Hilcorp Energy Company TVD Reference: MPJ-23A @ 66.00usft(NORDIC 3) Project: Milne Point MD Reference: MPJ-23A @ 66.00usft(NORDIC 3) Site: M Pt J Pad North Reference: True Well: MPJ-23 Survey Calculation Method: Minimum Curvature Wellbore: Plan:MPJ-23A Design: MPJ-23Awp3 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 3,487.88 7,800.00 74.93 272.50 3,553.88 3,487.88 213.21 -6,131.27 6,015,252.70 545,794.94 0.00 6,134.68 Start Dir 15.24°1100':7800'MD,3553.88'TVD:30°LT TF 7,800.02 74.93 272.50 3,553.89 3,487.89 213.21 -6,131.29 6,015,252.70 545,794.92 0.00 6,134.70 7"TOW 7,812.60 76.60 271.52 3,556.98 3,490.98 213.64 -6,143.47 6,015,253.04 545,782.73 15.26 6,146.89 End Dir :7812.6'MD,3556.98'TVD 7,832.60 76.60 271.52 3,561.62 3,495.62 214.15 -6,162.92 6,015,253.42 545,763.28 0.00 6,166.35 Start Dir 5°/100':7832.6'MD,3561.62'TVD 7,900.00 78.08 274.62 3,576.40 3,510.40 217.67 -6,228.58 6,015,256.49 545,697.61 5.00 6,232.09 8,000.00 80.33 279.16 3,595.14 3,529.14 229.47 -6,326.06 6,015,267.60 545,600.06 5.00 6,330.01 8,100.00 82.65 283.64 3,609.95 3,543.95 249.03 -6,422.97 6,015,286.48 545,503.02 5.00 6,427.69 8,200.00 85.00 288.08 3,620.71 3,554.71 276.20 -6,518.57 6,015,312.98 545,407.24 5.00 6,524.41 8,300.00 87.39 292.48 3,627.34 3,561.34 310.77 -6,612.14 6,015,346.90 545,313.45 5.00 6,619.41 8,359.67 88.82 295.10 3,629.31 3,563.31 334.83 -6,666.70 6,015,370.58 545,258.72 5.00 6,675.00 End Dir :8359.67'MD,3629.31'TVD 8,400.00 88.82 295.10 3,630.14 3,564.14 351.93 -6,703.21 6,015,387.42 545,222.10 0.00 6,712.23 8,440.47 88.82 295.10 3,630.97 3,564.97 369.10 -6,739.86 6,015,404.33 545,185.34 0.00 6,749.60 Start Dir 5°/100':8440.47'MD,3630.97'TVD 8,500.00 89.08 292.13 3,632.06 3,566.06 392.94 -6,794.38 6,015,427.79 545,130.65 5.00 6,805.14 8,600.00 89.51 287.15 3,633.28 3,567.28 426.54 -6,888.53 6,015,460.73 545,036.29 5.00 6,900.68 8,700.00 89.95 282.17 3,633.75 3,567.75 451.85 -6,985.24 6,015,485.36 544,939.41 5.00 6,998.42 8,800.00 90.39 277.19 3,633.45 3,567.45 468.66 -7,083.78 6,015,501.48 544,840.76 5.00 7,097.62 8,900.00 90.83 272.21 3,632.38 3,566.38 476.85 -7,183.41 6,015,508.98 544,741.09 5.00 7,197.51 8,933.11 90.97 270.56 3,631.87 3,565.87 477.65 -7,216.50 6,015,509.55 544,707.99 5.00 7,230.61 End Dir :8933.11'MD,3631.87'TVD 9,000.00 90.97 270.56 3,630.73 3,564.73 478.30 -7,283.38 6,015,509.73 544,641.12 0.00 7,297.45 9,100.00 90.97 270.56 3,629.04 3,563.04 479.28 -7,383.36 6,015,510.01 544,541.14 0.00 7,397.37 9,200.00 90.97 270.56 3,627.35 3,561.35 480.26 -7,483.34 6,015,510.29 544,441.17 0.00 7,497.30 9,300.00 90.97 270.56 3,625.65 3,559.65 481.23 -7,583.32 6,015,510.57 544,341.19 0.00 7,597.22 9,400.00 90.97 270.56 3,623.96 3,557.96 482.21 -7,683.30 6,015,510.85 544,241.22 0.00 7,697.15 9,500.00 90.97 270.56 3,622.27 3,556.27 483.19 -7,783.29 6,015,511.14 544,141.24 0.00 7,797.07 9,600.00 90.97 270.56 3,620.58 3,554.58 484.16 -7,883.27 6,015,511.42 544,041.27 0.00 7,897.00 9,700.00 90.97 270.56 3,618.88 3,552.88 485.14 -7,983.25 6,015,511.70 543,941.29 0.00 7,996.93 9,800.00 90.97 270.56 3,617.19 3,551.19 486.12 -8,083.23 6,015,511.98 543,841.31 0.00 8,096.85 9,900.00 90.97 270.56 3,615.50 3,549.50 487.10 -8,183.21 6,015,512.26 543,741.34 0.00 8,196.78 10,000.00 90.97 270.56 3,613.80 3,547.80 488.07 -8,283.19 6,015,512.54 543,641.36 0.00 8,296.70 10,100.00 90.97 270.56 3,612.11 3,546.11 489.05 -8,383.17 6,015,512.82 543,541.39 0.00 8,396.63 10,200.00 90.97 270.56 3,610.42 3,544.42 490.03 -8,483.15 6,015,513.10 543,441.41 0.00 8,496.55 10,300.00 90.97 270.56 3,608.73 3,542.73 491.01 -8,583.13 6,015,513.38 543,341.44 0.00 8,596.48 10,400.00 90.97 270.56 3,607.03 3,541.03 491.98 -8,683.11 6,015,513.66 543,241.46 0.00 8,696.40 10,500.00 90.97 270.56 3,605.34 3,539.34 492.96 -8,783.09 6,015,513.94 543,141.49 0.00 8,796.33 10,600.00 90.97 270.56 3,603.65 3,537.65 493.94 -8,883.08 6,015,514.22 543,041.51 0.00 8,896.25 10,700.00 90.97 270.56 3,601.95 3,535.95 494.91 -8,983.06 6,015,514.50 542,941.53 0.00 8,996.18 10,800.00 90.97 270.56 3,600.26 3,534.26 495.89 -9,083.04 6,015,514.78 542,841.56 0.00 9,096.10 10,900.00 90.97 270.56 3,598.57 3,532.57 496.87 -9,183.02 6,015,515.06 542,741.58 0.00 9,196.03 8/19/2015 6:32:17PM Page 3 COMPASS 5000.1 Build 73 • 0 Halliburton I-IALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well MPJ-23 Company: Hilcorp Energy Company TVD Reference: MPJ-23A @ 66.00usft(NORDIC 3) Project: Milne Point MD Reference: MPJ-23A @ 66.00usft(NORDIC 3) Site: M Pt J Pad North Reference: True Well: MPJ-23 Survey Calculation Method: Minimum Curvature Wellbore: Plan:MPJ-23A Design: MPJ-23Awp3 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 3,530.88 11,000.00 90.97 270.56 3,596.88 3,530.88 497.85 -9,283.00 6,015,515.34 542,641.61 0.00 9,295.96 11,100.00 90.97 270.56 3,595.18 3,529.18 498.82 -9,382.98 6,015,515.62 542,541.63 0.00 9,395.88 11,200.00 90.97 270.56 3,593.49 3,527.49 499.80 -9,482.96 6,015,515.90 542,441.66 0.00 9,495.81 11,300.00 90.97 270.56 3,591.80 3,525.80 500.78 -9,582.94 6,015,516.18 542,341.68 0.00 9,595.73 11,400.00 90.97 270.56 3,590.10 3,524.10 501.75 -9,682.92 6,015,516.46 542,241.70 0.00 9,695.66 11,500.00 90.97 270.56 3,588.41 3,522.41 502.73 -9,782.90 6,015,516.74 542,141.73 0.00 9,795.58 11,600.00 90.97 270.56 3,586.72 3,520.72 503.71 -9,882.88 6,015,517.02 542,041.75 0.00 9,895.51 11,700.00 90.97 270.56 3,585.02 3,519.02 504.69 -9,982.87 6,015,517.30 541,941.78 0.00 9,995.43 11,800.00 90.97 270.56 3,583.33 3,517.33 505.66 -10,082.85 6,015,517.59 541,841.80 0.00 10,095.36 11,900.00 90.97 270.56 3,581.64 3,515.64 506.64 -10,182.83 6,015,517.87 541,741.83 0.00 10,195.28 12,000.00 90.97 270.56 3,579.95 3,513.95 507.62 -10,282.81 6,015,518.15 541,641.85 0.00 10,295.21 ' 12,100.00 90.97 270.56 3,578.25 3,512.25 508.60 -10,382.79 6,015,518.43 541,541.88 0.00 10,395.14 12,200.00 90.97 270.56 3,576.56 3,510.56 509.57 -10,482.77 6,015,518.71 541,441.90 0.00 10,495.06 12,233.11 90.97 270.56 3,576.00 3,510.00 509.90 -10,515.87 6,015,518.80 541,408.80 0.00 10,528.14 12,300.00 90.97 270.56 3,574.87 3,508.87 510.55 -10,582.75 6,015,518.99 541,341.92 0.00 10,594.99 12,400.00 90.97 270.56 3,573.17 3,507.17 511.53 -10,682.73 6,015,519.27 541,241.95 0.00 10,694.91 12,500.00 90.97 270.56 3,571.48 3,505.48 512.50 -10,782.71 6,015,519.55 541,141.97 0.00 10,794.84 12,600.00 90.97 270.56 3,569.79 3,503.79 513.48 -10,882.69 6,015,519.83 541,042.00 0.00 10,894.76 12,700.00 90.97 270.56 3,568.10 3,502.10 514.46 -10,982.67 6,015,520.11 540,942.02 0.00 10,994.69 12,800.00 90.97 270.56 3,566.40 3,500.40 515.44 -11,082.66 6,015,520.39 540,842.05 0.00 11,094.61 12,900.00 90.97 270.56 3,564.71 3,498.71 516.41 -11,182.64 6,015,520.67 540,742.07 0.00 11,194.54 13,000.00 90.97 270.56 3,563.02 3,497.02 517.39 -11,282.62 6,015,520.95 540,642.10 0.00 11,294.46 13,100.00 90.97 270.56 3,561.32 3,495.32 518.37 -11,382.60 6,015,521.23 540,542.12 0.00 11,394.39 13,200.00 90.97 270.56 3,559.63 3,493.63 519.34 -11,482.58 6,015,521.51 540,442.14 0.00 11,494.31 13,300.00 90.97 270.56 3,557.94 3,491.94 520.32 -11,582.56 6,015,521.79 540,342.17 0.00 11,594.24 13,400.00 90.97 270.56 3,556.25 3,490.25 521.30 -11,682.54 6,015,522.07 540,242.19 0.00 11,694.17 13,433.11 90.97 270.56 3,555.69 3,489.69 521.62 -11,715.64 6,015,522.17 540,209.09 0.00 11,727.25 Total Depth:13433.11'MD,3555.69'TVD Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) MPJ-23A Heel 0.00 0.00 3,631.00 377.35 -6,463.90 6,015,414.50 545,461.20 -plan misses target center by 113.63usft at 8176.31 usft MD(3618.53 TVD,269.08 N,-6496.08 E) -Circle(radius 20.00) MPJ-23AToe 0.00 0.00 3,576.00 509.90 -10,515.87 6,015,518.80 541,408.80 -plan hits target center -Circle(radius 20.00) MPJ-23A NB 0.00 0.00 3,641.00 472.72 -6,688.47 6,015,508.30 545,236.00 -plan misses target center by 116.08usft at 8438.10usft MD(3630.92 TVD,368.09 N,-6737.71 E) -Circle(radius 50.00) 8/19/2015 6:32:17PM Page 4 COMPASS 5000.1 Build 73 • • Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well MPJ-23 Company: Hilcorp Energy Company TVD Reference: MPJ-23A @ 66.00usft(NORDIC 3) Project: Milne Point MD Reference: MPJ-23A@ 66.00usft(NORDIC 3) Site: M Pt J Pad North Reference: True Well: MPJ-23 Survey Calculation Method: Minimum Curvature Wellbore: Plan:MPJ-23A Design: MPJ-23A wp3 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (') (") 7,800.02 3,553.89 7"TOW 7 8-1/2 13,433.11 3,555.69 4 1/2"x 6 1/8" 4-1/2 6-1/8 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 7,800.00 3,553.88 213.21 -6,131.27 Start Dir 15.24°/100':7800'MD,3553.88'TVD:30°LT TF 7,812.60 3,556.98 213.64 -6,143.47 End Dir :7812.6'MD,3556.98'TVD 7,832.60 3,561.62 214.15 -6,162.92 Start Dir 5°/100':7832.6'MD,3561.62'TVD 8,359.67 3,629.31 334.83 -6,666.70 End Dir :8359.67'MD,3629.31'TVD 8,440.47 3,630.97 369.10 -6,739.86 Start Dir 5°/100':8440.47'MD,3630.97'TVD 8,933.11 3,631.87 477.65 -7,216.50 End Dir :8933.11'MD,3631.87'TVD 13,433.11 3,555.69 509.90 -10,515.87 Total Depth:13433.11'MD,3555.69'TVD 8/19/2015 6:32:17PM Page 5 COMPASS 5000.1 Build 73 • • Hilcorp Energy Company Milne Point M Pt J Pad MPJ-23 Plan: MPJ-23A 500292297000 MPJ-23A wp3 Sperry Drilling Services Clearance Summary Anticollision Report 19 August,2015 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: M Pt J Pad-MPJ-23-Plan:MPJ-23A-MPJ-23A wp3 Well Coordinates:6,015,082.24 N,551,926.95 E(70'27'07.01"N,149.34'34.72"W) Datum Height: MPJ-23A 88.00usft(NORDIC 3) Scan Range:0.00 to 13,433.11 usft.Measured Depth. Scan Radius Is 1,536.71 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation Is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build: 73 Scan Type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Scan Type: 25.00 �.« HALLIBURTON Sperry Drilling Services • s Hilcorp Energy Company HALLI B U RTO N Milne Point Anticollision Report for MPJ-23-MPJ-23A wp3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: M Pt J Pad-MPJ-23-Plan:MPJ-23A-MPJ-23A wp3 Scan Range:0.00 to 13,433.11 usft.Measured Depth. Scan Radius is 1,536.71 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 MPtJPad MPJ-01-MPJ-01-MPJ-01 100.00 30.17 100.00 27.36 99.84 10.726 Ellipse Separation Pass- MPJ-01-MPJ-01-MPJ-01 258.51 29.74 258.51 27.69 258.15 14.513 Centre Distance Pass- MPJ-01-MPJ-01-MPJ-01 550.00 39.02 550.00 34.77 549.16 9.175 Clearance Factor Pass- MPJ-01-MPJ-01-MPJ-01 100.00 30.17 100.00 27.26 99.64 10.339 Clearance Factor Pass- MPJ-01-MPJ-01-MPJ-01 258.51 29.74 258.51 28.13 258.15 18.511 Centre Distance Pass- MPJ-01-MPJ-01A-MPJ-01A 100.00 30.17 100.00 27.90 99.64 13.277 Ellipse Separation Pass- MPJ-01-MPJ-01A-MPJ-01A 258.51 29.74 258.51 28.23 258.15 19.795 Centre Distance Pass- MPJ-01-MPJ-01A-MPJ-01A 450.00 33.17 450.00 30.34 449.47 11.717 Clearance Factor Pass- MPJ-01-MPJ-01A-MPJ-01A 258.51 29.74 258.51 27.79 258.15 15.291 Centre Distance Pass- MPJ-01-MPJ-01A-MPJ-01A 300.00 29.88 300.00 27.63 299.63 13.277 Ellipse Separation Pass- MPJ-01-MPJ-01A-MPJ-01A 550.00 39.02 550.00 34.87 549.16 9.406 Clearance Factor Pass- MPJ-01-MPJ-01AL1-Plan#5 100.00 30.17 100.00 27.36 99.64 10.726 Ellipse Separation Pass- MPJ-01-MPJ-01AL1-Plan#5 258.51 29.74 258.51 27.69 258.15 14.513 Centre Distance Pass- MPJ-01-MPJ-01AL1-Plan#5 550.00 39.02 550.00 34.77 549.16 9.175 Clearance Factor Pass- MPJ-01-MPJ-01AL1-MPJ-01AL1 258.51 29.74 258.51 27.88 258.15 16.020 Centre Distance Pass- MPJ-01-MPJ-01AL1-MPJ-01AL1 300.00 29.88 300.00 27.71 299.63 13.821 Ellipse Separation Pass- MPJ-01-MPJ-01AL1-MPJ-01AL1 550.00 39.02 550.00 34.96 549.16 9.611 Clearance Factor Pass- MPJ-01-MPJ-01AL1-MPJ-01AL1 100.00 30.17 100.00 27.26 99.64 10.339 Clearance Factor Pass- MPJ-01-MPJ-01AL1-MPJ-01AL1 258.51 29.74 258.51 28.13 258.15 18.511 Centre Distance Pass- MPJ-01-MPJ-01AL1-Plan#5 100.00 30.17 100.00 27.26 99.64 10.339 Clearance Factor Pass- MPJ-01-MPJ-01AL1-Plan#5 258.51 29.74 258.51 28.13 258.15 18.511 Centre Distance Pass- MPJ-02-MPJ-02-MPJ-02 66.00 90.28 66.00 87.82 70.04 36.646 Centre Distance Pass- MPJ-02-MPJ-02-MPJ-02 100.00 90.34 100.00 87.67 103.90 33.831 Ellipse Separation Pass- MPJ-02-MPJ-02-MPJ-02 775.00 133.91 775.00 128.78 765.51 26.107 Clearance Factor Pass- MPJ-02-MPJ-02-MPJ-02 66.00 90.28 66.00 87.88 70.04 37.635 Centre Distance Pass- MPJ-02-MPJ-02-MPJ-02 100.00 90.34 100.00 87.81 103.90 35.629 Ellipse Separation Pass- MPJ-02-MPJ-02-MPJ-02 675.00 111.49 675.00 106.13 673.11 20.785 Clearance Factor Pass- MPJ-03-MPJ-03-MPJ-03 100.00 150.00 100.00 147.07 103.77 51.130 Ellipse Separation Pass- 19 August,2015-18:27 Page 2 of 13 COMPASS 0 0 Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for MPJ-23-MPJ-23A wp3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: M Pt J Pad-MPJ-23-Plan:MPJ-23A-MPJ-23A wp3 Scan Range:0.00 to 13,433.11 usft.Measured Depth. Scan Radius is 1,536.71 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 MPJ-03-MPJ-03-MPJ-03 233.92 149.94 233.92 147.84 237.62 71.562 Centre Distance Pass- MPJ-03-MPJ-03-MPJ-03 950.00 248.48 950.00 238.23 914.16 24.243 Clearance Factor Pass- MPJ-03-MPJ-03-MPJ-03 100.00 150.00 100.00 147.19 103.77 53.362 Ellipse Separation Pass- MPJ-03-MPJ-03-MPJ-03 233.92 149.94 233.92 148.07 237.62 80.402 Centre Distance Pass- MPJ-03-MPJ-03-MPJ-03 2,750.00 1,518.46 2,750.00 1,466.57 1,973.48 29.266 Clearance Factor Pass- I MPJ-04-MPJ-04-MPJ-04 100.00 209.98 100.00 207.43 104.22 82.291 Ellipse Separation Pass- MPJ-04-MPJ-04-MPJ-04 262.02 209.40 262.02 207.50 266.29 110.203 Centre Distance Pass- MPJ-04-MPJ-04-MPJ-04 950.00 308.15 950.00 299.45 896.32 35.388 Clearance Factor Pass- MPJ-04-MPJ-04-MPJ-04 262.02 209.40 262.02 207.14 266.29 92.556 Centre Distance Pass- MPJ-04-MPJ-04-MPJ-04 300.00 209.52 300.00 206.98 304.17 82.439 Ellipse Separation Pass- MPJ-04-MPJ-04-MPJ-04 2,475.00 1,532.18 2,475.00 1,491.95 1,401.74 38.086 Clearance Factor Pass- MPJ-08-MPJ-08-MPJ-08 100.00 119.47 100.00 117.20 87.85 52.705 Ellipse Separation Pass- MPJ-08-MPJ-08-MPJ-08 264.31 119.26 264.31 117.76 252.41 79.634 Centre Distance Pass- MPJ-08-MPJ-08-MPJ-08 925.00 181.85 925.00 176.87 905.60 36.519 Clearance Factor Pass- MPJ-08-MPJ-08-MPJ-08 100.00 119.47 100.00 117.41 87.85 57.893 Ellipse Separation Pass- MPJ-08-MPJ-08-MPJ-08 264.31 119.26 264.31 118.02 252.41 96.066 Centre Distance Pass- MPJ-08-MPJ-08-MPJ-08 1,000.00 199.45 1,000.00 195.36 977.49 48.736 Clearance Factor Pass- MPJ-08-MPJ-08A-MPJ-08A 100.00 119.47 100.00 117.20 87.85 52.705 Ellipse Separation Pass- MPJ-08-MPJ-08A-MPJ-08A 264.31 119.26 264.31 117.76 252.41 79.634 Centre Distance Pass- MPJ-08-MPJ-08A-MPJ-08A 925.00 181.85 925.00 176.87 905.60 36.519 Clearance Factor Pass- MPJ-08A-MPJ-08A-MPJ-08A 100.00 119.47 100.00 117.20 87.85 52.705 Ellipse Separation Pass- MPJ-08A-MPJ-08A-MPJ-08A 264.31 119.26 264.31 117.81 252.41 82.558 Centre Distance Pass- MPJ-08A-MPJ-08A-MPJ-08A 1,000.00 199.45 1,000.00 195.16 977.49 46.431 Clearance Factor Pass- MPJ-10-MPJ-10-MPJ-10 289.63 179.11 289.63 177.49 278.66 111.025 Centre Distance Pass- MPJ-10-MPJ-10-MPJ-10 325.00 179.20 325.00 177.43 314.10 101.402 Ellipse Separation Pass- MPJ-10-MPJ-10-MPJ-10 1,025.00 252.38 1,025.00 246.46 1,001.56 42.595 Clearance Factor Pass- MPJ-10-MPJ-10-MPJ-10 289.63 179.11 289.63 177.54 278.66 114.066 Centre Distance Pass- MPJ-10-MPJ-10-MPJ-10 325.00 179.20 325.00 177.48 314.10 104.579 Ellipse Separation Pass- MPJ-10-MPJ-10-MPJ-10 1,050.00 259.93 1,050.00 254.26 1,021.66 45.826 Clearance Factor Pass- MPJ-11-MPJ-11-MPJ-11 100.00 60.08 100.00 57.93 88.10 27.844 Clearance Factor Pass- 19 August,2015-18:27 Page 3.013 COMPASS • • Hilcorp Energy Company H ALL I B U RTO N Milne Point Anticollision Report for MPJ-23-MPJ-23A wp3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: M Pt J Pad-MPJ-23-Plan:MPJ-23A-MPJ-23A wp3 Scan Range: 0.00 to 13,433.11 usft.Measured Depth. Scan Radius is 1,536.71 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 MPJ-11-MPJ-11-MPJ-11 250.00 59.39 250.00 58.16 237.83 48.103 Centre Distance Pass- MPJ-11-MPJ-11-MPJ-11 100.00 60.08 100.00 57.93 88.10 27.844 Ellipse Separation Pass- MPJ-11-MPJ-11-MPJ-11 250.00 59.39 250.00 58.07 237.83 44.884 Centre Distance Pass- MPJ-11-MPJ-11-MPJ-11 700.00 81.61 700.00 78.14 687.62 23.554 Clearance Factor Pass- MPJ-15-MPJ-15-MPJ-15 1587.28 152.43 1,387.28 139.40 1,520.99 11.701 Centre Distance Pass- MPJ-15-MPJ-15-MPJ-15 1,400.00 152.64 1,400.00 13921 1,532.05 11.365 Ellipse Separation Pass- MPJ-15-MPJ-15-MPJ-15 1,575.00 196.06 1,575.00 174.71 1,670.95 9.184 Clearance Factor Pass- MPJ-15-MPJ-15-MPJ-15 1,387.28 152.43 1,387.28 139.01 1,520.99 11.357 Centre Distance Pass- MPJ-15-MPJ-15-MPJ-15 1,400.00 152.64 1,400.00 138.79 1,532.05 11.021 Ellipse Separation Pass- MPJ-15-MPJ-15-MPJ-15 1,550.00 185.53 1,550.00 164.66 1,653.54 8.890 Clearance Factor Pass- MPJ-16-MPJ-16-MPJ-16 1556.94 326.64 1,356.94 317.29 1,487.25 34.935 Centre Distance Pass- MPJ-16-MPJ-16-MPJ-16 1,375.00 326.80 1,375.00 317.27 1,504.24 34.287 Ellipse Separation Pass- MPJ-16-MPJ-16-MPJ-16 2,925.00 1,217.91 2,925.00 1,163.58 2593.13 22.418 Clearance Factor Pass- MPJ-16-MPJ-16-MPJ-16 1,356.94 326.64 1,356.94 316.64 1,487.25 32.678 Centre Distance Pass- MPJ-16-MPJ-16-MPJ-16 1,375.00 326.80 1,375.00 316.64 1,504.24 32.137 Ellipse Separation Pass- MPJ-16-MPJ-16-MPJ-16 2,925.00 1,217.91 2,925.00 1,163.50 2,593.13 22.387 Clearance Factor Pass- MPJ-16-MPJ-16A Plan-MPJ-16A Wp 3.0 1,356.94 326.64 1,356.94 317.40 1,492.85 35.356 Centre Distance Pass- MPJ-16-MPJ-16A Plan-MPJ-16A Wp 3.0 1,375.00 326.80 1,375.00 317.39 1,509.84 34.695 Ellipse Separation Pass- MPJ-16-MPJ-16A Plan-MPJ-16A Wp 3.0 5,600.00 1,353.28 5,600.00 1,275.14 6,100.00 17.318 Clearance Factor Pass- MPJ-16-MPJ-16A Plan-MPJ-16A Wp 3.0 1556.94 326.64 1556.94 316.75 1,492.85 33.026 Centre Distance Pass- MPJ-16-MPJ-16A Plan-MPJ-16A Wp 3.0 1,375.00 326.80 1,375.00 316.74 1,509.84 32.474 Ellipse Separation Pass- MPJ-16-MPJ-16A Plan-MPJ-16A Wp 3.0 5,375.00 1,255.57 5,375.00 1,030.05 6,000.00 5.568 Clearance Factor Pass- MPJ-17-MPJ-17-MPJ-17 2,900.00 296.37 2,900.00 232.51 3,128.51 4.641 Ellipse Separation Pass- MPJ-17-MPJ-17-MPJ-17 2,925.00 296.61 2,925.00 232.67 3,152.45 4.639 Clearance Factor Pass- MPJ-17-MPJ-17-MPJ-17 3,053.01 296.30 3,053.01 234.60 3,277.50 4.802 Centre Distance Pass- MPJ-17-MPJ-17-MPJ-17 2,900.00 296.37 2,900.00 231.68 3,128.51 4.581 Ellipse Separation Pass- MPJ-17-MPJ-17-MPJ-17 2,925.00 296.61 2,925.00 231.83 3,152.45 4.578 Clearance Factor Pass- MPJ-17-MPJ-17-MPJ-17 3,053.01 296.30 3,053.01 233.73 3,277.50 4.735 Centre Distance Pass- MPJ-18-MPJ-18-MPJ-18 1,533.85 349.38 1,533.85 337.65 1,678.13 29.789 Centre Distance Pass- MPJ-18-MPJ-18-MPJ-18 1,550.00 349.46 1,550.00 337.61 1,695.02 29.486 Ellipse Separation Pass- MPJ-18-MPJ-18-MPJ-18 2,900.00 839.45 2,900.00 777.68 2,955.98 13.590 Clearance Factor Pass- 19 August,2015-18:27 Page 4 of 13 COMPASS 0 0 Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for MPJ-23-MPJ-23A wp3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: M Pt J Pad-MPJ-23-Plan:MPJ-23A-MPJ-23A wp3 Scan Range: 0.00 to 13,433.11 usft.Measured Depth. Scan Radius is 1,536.71 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 MPJ-18-MPJ-18-MPJ-18 1533.85 349.38 1,533.85 338.06 1578.13 30.873 Centre Distance Pass- MPJ-18-MPJ-18-MPJ-18 1,550.00 349.46 1,550.00 338.01 1,695.02 30.528 Ellipse Separation Pass- MPJ-18-MPJ-18-MPJ-18 4900.00 839.45 2,900.00 776.50 2,955.98 13.337 Clearance Factor Pass- MPJ-19-MPJ-19-MPJ-19 2,725.00 411.06 2,725.00 379.63 4095.10 13.080 Ellipse Separation Pass- MPJ-19-MPJ-19-MPJ-19 2,787.13 409.82 2,787.13 380.50 3,164.14 13.978 Centre Distance Pass- MPJ-19-MPJ-19-MPJ-19 5,225.00 1,408.99 5,225.00 1283.24 5,260.20 11.205 Clearance Factor Pass- MPJ-19-MPJ-19-MPJ-19 2,725.00 410.65 2225.00 383.71 3,095.44 15.247 Ellipse Separation Pass- MPJ-19-MPJ-19-MPJ-19 2,787.38 409.39 2,787.38 384.79 3,164.74 16.638 Centre Distance Pass- MPJ-19-MPJ-19-MPJ-19 5,225.00 1,408.82 5,225.00 1,273.26 5,260.43 10.393 Clearance Factor Pass- MPJ-19-MPJ-19A-MPJ-19A 2,600.00 426.54 2,600.00 392.09 2,965.63 12.382 Clearance Factor Pass- MPJ-19-MPJ-19A-MPJ-19A 2,725.00 411.06 2,725.00 379.63 3,095.10 13.080 Ellipse Separation Pass- MPJ-19-MPJ-19A-MPJ-19A 2,787.13 409.82 2,787.13 380.50 3,164.14 13.978 Centre Distance Pass- MPJ-19A-MPJ-19A-MPJ-19A 2,525.00 440.06 2,525.00 408.64 2,892.67 14.006 Clearance Factor Pass- MPJ-19A-MPJ-19A-MPJ-19A 2,725.00 411.08 2,725.00 384.15 3,095.67 15.267 Ellipse Separation Pass- MPJ-19A-MPJ-19A-MPJ-19A 2,787.11 409.84 2,787.11 385.23 3,164.68 16.651 Centre Distance Pass- MPJ-20-MPJ-20-MPJ-20 8,657.16 487.40 6,657.16 144.56 6,858.76 1.422 Centre Distance Pass- MPJ-20-MPJ-20-MPJ-20 6,725.00 488.58 6,72500 143.06 6,914.65 1.414 Clearance Factor Pass- MPJ-20-MPJ-20-MPJ-20 6,657.69 487.39 6,657.69 151.93 6,958.47 1.453 Centre Distance Pass- MPJ-20-MPJ-20-MPJ-20 6,725.00 488.55 6,725.00 150.46 7,013.88 1.445 Clearance Factor Pass- MPJ-20-MPJ-20A-MPJ-20A Wpb 8,798.11 211.58 8,798.11 56.61 9,243.90 1.365 Centre Distance Pass- MPJ-20-MPJ-20A-MPJ-20A Wp6 MIMI - - MIMIClearance Factor FAIL- MPJ-20-MPJ-20A-MPJ-20A Wp6 - - ,12$# MIMI MI= Ellipse Separation FAIL- MPJ-20-MPJ-20A-MPJ-20A 8,793.98 206.33 8,793.98 67.82 9,231.37 1.490 Centre Distance Pass- MPJ-20-MPJ-20A-MPJ-20A Illi 9,0764 - - la. 0.826 Clearance Factor FAIL- MPJ-20-MPJ-20A-MPJ-20A - Ilk 9,1004 II=M ir{ 0.829 Ellipse Separation FAIL- MPJ-20-MPJ-20A-MPJ-20A 8,024.07 200.65 8,824.07 59.91 9,265.21 1.426 Centre Distance Pass- MPJ-20-MPJ-20A-MPJ-20A - - - - - I;; 0.761 Clearance Factor FAIL- MPJ-20-MPJ-20A-MPJ-20A IMO= - I' 0.765 Ellipse Separation FAIL- MPJ-23-MPJ-23-MPJ-23 - - - - - Il,. 0.000 Clearance Factor FAIL- MPJ-23-MPJ-23-MPJ-23 - - - - - IIIIII FAIL- 19 August,2015-18:27 Page 5 of 13 COMPASS • • Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for MPJ-23-MPJ-23A wp3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: M Pt J Pad-MPJ-23-Plan:MPJ-23A-MPJ-23A wp3 Scan Range: 0.00 to 13,433.11 usft.Measured Depth. Scan Radius is 1,536.71 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 MPJ-23-MPJ-23-MPJ-23 - - ll - - MPJ-23-MPJ-23-MPJ-23 - - MEM - MPJ-23-MPJ-23L1-MPJ-23L1 _ - MEM - - MPJ-23-MPJ-23L1-MPJ-23L1 MEM III MIIIM - - MPJ-23-MPJ-23L1-MPJ-23L1 - - 11. - - MPJ-23-MPJ-23L1-MPJ-23L1 MIMI 11111 E - - MPJ-24-MPJ-24-MPJ-24 388.11 30.44 388.11 28.86 387.63 19.184 Centre Distance Pass- MPJ-24-MPJ-24-MPJ-24 525.00 30.82 525.00 28.59 523.49 13.794 Ellipse Separation Pass- MPJ-24-MPJ-24-MPJ-24 2,300.00 260.48 2,300.00 209.97 2,236.05 5.157 Clearance Factor Pass- MPJ-24-MPJ-24-MPJ-24 388.11 30.44 388.11 28.64 387.63 16.870 Centre Distance Pass- MPJ-24-MPJ-24-MPJ-24 525.00 30.82 525.00 28.31 523.49 12.277 Ellipse Separation Pass- MPJ-24-MPJ-24-MPJ-24 2,300.00 260.48 2,300.00 202.61 2,236.05 4.502 Clearance Factor Pass- MPJ-24-MPJ-24-MPJ-224 Wp5 66.00 30.94 66.00 28.89 66.05 15.149 Centre Distance Pass- MPJ-24-MPJ-24-MPJ-224 Wp5 525,00 31.09 525.00 28.43 523.78 11.711 Ellipse Separation Pass- MPJ-24-MPJ-24-MPJ-224 Wp5 2,325.00 265.41 2,325,00 212.76 2,277.63 5.041 Clearance Factor Pass- MPJ-24-MPJ-24L1-MPJ-24L1 388.11 30.44 388.11 28.96 387.63 20.532 Centre Distance Pass- MPJ-24-MPJ-24L1-MPJ-24L1 525.00 30.82 525.00 28.69 523.49 14.468 Ellipse Separation Pass- MPJ-24-MPJ-24L1-MPJ-24L1 2,300.00 260.48 2,300.00 210.07 2,236.05 5.168 Clearance Factor Pass- MPJ-24-MPJ-24L1-MPJ-24L1 388.11 30.44 388.11 28.74 387.63 17.903 Centre Distance Pass- MPJ-24-MPJ-24L1-MPJ-24L1 525.00 30.82 525.00 28.42 523.49 12.808 Ellipse Separation Pass- MPJ-24-MPJ-24L1-MPJ-24L1 2,300.00 260.48 2,300.00 202.72 2,236.05 4.510 Clearance Factor Pass- MPJ-24-MPJ-24L1PB1-MPJ-24L1PB1 388.11 30.44 388.11 28.64 387.63 16.870 Centre Distance Pass- MPJ-24-MPJ-24L1PB1-MPJ-24L1PB1 525.00 30.82 525.00 28,31 523.49 12.277 Ellipse Separation Pass- MPJ-24-MPJ-24Lt PB1-MPJ-24L1PB1 2,300.00 260.48 2,300.00 202.58 2,236.05 4.499 Clearance Factor Pass- MPJ-24-MPJ-24L1PB1-MPJ-24L1PB1 388.11 30.44 388.11 28.86 387.63 19.184 Centre Distance Pass- MPJ-24-MPJ-24L1PB1-MPJ-24L1PB1 525.00 30.82 525.00 28.59 523.49 13.794 Ellipse Separation Pass- MPJ-24-MPJ-24L1PB1-MPJ-24L1PB1 2,300.00 260.48 2,300.00 209.94 2,236.05 5.154 Clearance Factor Pass- MPJ-24-MPJ24L1PB2-MPJ24L1PB2 388.11 30.44 388.11 28.86 387.63 19.184 Centre Distance Pass- MPJ-24-MPJ24L1PB2-MPJ24L1PB2 525.00 30.82 525.00 28.59 523.49 13.794 Ellipse Separation Pass- MPJ-24-MPJ24L1PB2-MPJ24L1PB2 2,300.00 260.48 2,300.00 209.97 2,236.05 5.157 Clearance Factor Pass- 19 August,2015-18:27 Page 6 of 13 COMPASS I • Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for MPJ-23-MPJ-23A wp3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: M Pt J Pad-MPJ-23-Plan:MPJ-23A-MPJ-23A wp3 Scan Range:0.00 to 13,433.11 usft.Measured Depth. Scan Radius is 1,536.71 ash.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) (ash) usft MPJ-24-MPJ-24L1PB2-MPJ-24L1 PB2 388.11 30.44 388.11 28.64 387.63 16.870 Centre Distance Pass- MPJ-24-MPJ-24L1PB2-MPJ-24L1PB2 525.00 30.82 525.00 28.31 523.49 12.277 Ellipse Separation Pass- MPJ-24-MPJ-24L1 P82-MPJ-24L1PB2 2,300.00 260.48 2,300.00 202.61 2,236.05 4.502 Clearance Factor Pass- MPJ-24-Plan:MPJ-24A-MPJ-24A WP2 388.11 30.44 388.11 28.64 387.63 16.871 Centre Distance Pass- MPJ-24-Plan:MPJ-24A-MPJ-24A WP2 525.00 30.82 525.00 28.31 523.49 12.275 Ellipse Separation Pass- MPJ-24-Plan:MPJ-24A-MPJ-24A WP2 2,300.00 260.48 2,300.00 202.22 2,236.05 4.471 Clearance Factor Pass- MPJ-25-MPJ-25-MPJ-25 WP16 397.98 57.41 397.98 54.77 401.16 21.716 Centre Distance Pass- MPJ-25-MPJ-25-MPJ-25 WP16 425.00 57.48 425.00 54,67 427.77 20.468 Ellipse Separation Pass- MPJ-25-MPJ-25-MPJ-25 WP16 575.00 61.61 575.00 58.00 573.75 17.047 Clearance Factor Pass- MPJ-25-MPJ-25-MPJ-25 397.98 57.41 397.98 54.77 401.16 21.716 Centre Distance Pass- MPJ-25-MPJ-25-MPJ-25 425.00 57.48 425.00 54.67 427.77 20.468 Ellipse Separation Pass- MPJ-25-MPJ-25-MPJ-25 575.00 61.61 575.00 58.00 573.75 17.047 Clearance Factor Pass- MPJ-25-MPJ-25-MPJ-25 WP16 397.98 57.41 397.98 54.63 401.16 20.659 Centre Distance Pass- MPJ-25-MPJ-25-MPJ-25 WP16 425.00 57.48 425.00 54.53 427.77 19.500 Ellipse Separation Pass- MPJ-25-MPJ-25-MPJ-25 WP16 575.00 61.61 575.00 57.84 573.75 16.311 Clearance Factor Pass- MPJ-25-MPJ-25-MPJ-25 397.98 57.41 397.98 54.63 401.16 20.659 Centre Distance Pass- MPJ-25-MPJ-25-MPJ-25 425.00 57.48 425.00 54.53 427.77 19.500 Ellipse Separation Pass- MPJ-25-MPJ-25-MPJ-25 575.00 61.61 575.00 57.84 573.75 16.311 Clearance Factor Pass- MPJ-25-MPJ-25PB1-MPJ-25PB1 397.98 57.41 397.98 54.63 401.16 20.659 Centre Distance Pass- MPJ-25-MPJ-25PB1-MPJ-25PB1 425.00 57.48 425,00 54.53 427.77 19.500 Ellipse Separation Pass- MPJ-25-MPJ-25PB1-MPJ-25PB1 575.00 61.61 575.00 57.84 573.75 16.311 Clearance Factor Pass- MPJ-25-MPJ-25PB1-MPJ-25PB1 WP06 66.00 59.79 66.00 57.43 70.14 25.355 Centre Distance Pass- MPJ-25-MPJ-25PB1-MPJ-25PB1 WP06 500.00 60.19 500.00 56.28 501.76 15.383 Ellipse Separation Pass- MPJ-25-MPJ-25PB1-MPJ-25PB1 WP06 725.00 69.57 725.00 64.60 722.15 14.003 Clearance Factor Pass- MPJ-25-MPJ-25PB1-MPJ-25PB1 WP06 66.00 59.79 66.00 57.43 70.14 25,355 Centre Distance Pass- MPJ-25-MPJ-25P81-MPJ-25PB1 WP06 500.00 60.19 500.00 56.28 501.76 15.378 Ellipse Separation Pass- MPJ-25-MPJ-25PB1-MPJ-25P81 WP06 725.00 69.57 725.00 64.60 722.15 13.991 Clearance Factor Pass- MPJ-25-MPJ-25PB1-MPJ-25P81 397.98 57.41 397.98 54.77 401.16 21.716 Centre Distance Pass- MPJ-25-MPJ-25PB1-MPJ-25PB1 425.00 57.48 425.00 54.67 427.77 20.468 Ellipse Separation Pass- MPJ-25-MPJ-25PB1-MPJ-25PB1 575.00 61.61 575.00 58.00 573.75 17.047 Clearance Factor Pass- 19 August,2015-18:27 Pays 7 o113 COMPASS III • Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for MPJ-23-MPJ-23A wp3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: M Pt J Pad-MPJ-23-Plan:MPJ-23A-MPJ-23A wp3 Scan Range: 0.00 to 13,433.11 usft.Measured Depth. Scan Radius is 1,536.71 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 MPJ-26-MPJ-26-MPJ-26 7,065.77 478.74 7,065.77 402.96 8,253.74 6.317 Centre Distance Pass- MPJ-26-MPJ-26-MPJ-26 7,150.00 485.07 7,150.00 400.32 8,287.86 5.724 Ellipse Separation Pass- MPJ-26-MPJ-26-MPJ-26 8,175.00 1,171.58 8,175.00 847.01 8,596.13 3.610 Clearance Factor Pass- MPJ-26-MPJ-26-MPJ-26 7,065.77 478.74 7,065.77 424.61 8,253.74 8.844 Centre Distance Pass- MPJ-26-MPJ-26-MPJ-26 7,100.00 479.73 7,100.00 423.98 8,266.49 8.605 Ellipse Separation Pass- MPJ-26-MPJ-26-MPJ-26 8,175.00 1,171.58 8,175.00 939.99 8,596.13 5.059 Clearance Factor Pass- MPJ-26-MPJ-26-MPJ-26 wp08 6,978.67 506.16 6,978.67 445.42 8,135.50 8.333 Centre Distance Pass- MPJ-26-MPJ-26-MPJ-26 wp08 7,000.00 506.51 7,000.00 444.76 8,141.88 8.202 Ellipse Separation Pass- MPJ-26-MPJ-26-MPJ-26 wp08 8,125.00 1,202.89 8,125.00 961.97 8,518.14 4.993 Clearance Factor Pass- MPJ-26-MPJ-26-MPJ-26 wp08 6,978.67 506.16 6,978.67 446.85 8,135.50 8.533 Centre Distance Pass- MPJ-26-MPJ-26-MPJ-26 wp08 7,025.00 507.85 7,025.00 446.17 8,149.45 8.233 Ellipse Separation Pass- MPJ-26-MPJ-26-MPJ-26 wp08 8,125.00 1,202.89 8,125.00 962.37 8,518.14 5.001 Clearance Factor Pass- MPJ-26-MPJ-26L1-MPJ-26L1 wp06 298.66 541.92 298.66 540.12 302.97 301.150 Centre Distance Pass- MPJ-26-MPJ-26L1-MPJ-26L1 wp06 350.00 542.13 350.00 540.00 352.64 254.183 Ellipse Separation Pass- MPJ-26-MPJ-26L1-MPJ-26L1 wp06 8,300.00 1,366.89 8,300.00 1,147.22 8,610.78 6.222 Clearance Factor Pass- MPJ-26-MPJ-26L1-MPJ-26L1 wp06 298.66 541.92 298.66 539.34 302.97 210.416 Centre Distance Pass- MPJ-26-MPJ-26L1-MPJ-26L1 wp06 350.00 542.13 350.00 539.22 352.64 185.888 Ellipse Separation Pass- MPJ-26-MPJ-26L1-MPJ-26L1 wp06 8,300.00 1,366.89 8,300.00 1,061.31 8,610.78 4.473 Clearance Factor Pass- MPJ-26-MPJ-26L1-MPJ-26L1 298.66 541.92 298.66 539.34 302.97 210.416 Centre Distance Pass- MPJ-26-MPJ-26L1-MPJ-26L1 350.00 542.13 350.00 539.22 352.64 185.888 Ellipse Separation Pass- MPJ-26-MPJ-26L1-MPJ-26L1 8,350.00 1,407.10 8,350.00 1,103.58 8,587.04 4.636 Clearance Factor Pass- MPJ-26-MPJ-26L1-MPJ-26L1 298.66 541.92 ' 298.66 540.12 302.97 301.150 Centre Distance Pass- MPJ-26-MPJ-2611-MPJ-26L1 350.00 542.13 350.00 540.00 352.64 254.183 Ellipse Separation Pass- MPJ-26-MPJ-26L1-MPJ-26L1 8,350.00 1,407.10 8,350.00 1,188.96 8,587.04 6.451 Clearance Factor Pass- MPJ-26-MPJ-26L2-MPJ-26L2 298.66 541.92 298.66 539.34 302.97 210.416 Centre Distance Pass- MPJ-26-MPJ-26L2-MPJ-26L2 350.00 542.13 350.00 539.22 352.64 185.888 Ellipse Separation Pass- MPJ-26-MPJ-26L2-MPJ-2612 8,275.00 1,364.83 8,275.00 1,054.26 8,517.84 4.395 Clearance Factor Pass- MPJ-26-MPJ-26L2-MPJ-2612 wp05 298.66 541.92 298.66 540.12 302.97 301.150 Centre Distance Pass- MPJ-26-MPJ-26L2-MPJ-26L2 wp05 350.00 542.13 350.00 540.00 352.64 254.183 Ellipse Separation Pass- MPJ-26-MPJ-26L2-MPJ-26L2 wp05 8,250.00 1,312.76 8,250.00 1,089.30 8,620.46 5.875 Clearance Factor Pass- 19 August,2015- 18:27 Page 8 of 13 COMPASS I • Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for MPJ-23 -MPJ-23A wp3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: M Pt J Pad-MPJ-23-Plan:MPJ-23A-MPJ-23A wp3 Scan Range: 0.00 to 13,433.11 usft.Measured Depth. Scan Radius is 1,536.71 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 MPJ-26-MPJ-26L2-MPJ-26L2 298.66 541.92 298.66 540.12 302.97 301.150 Centre Distance Pass- MPJ-26-MPJ-26L2-MPJ-26L2 350.00 542.13 350.00 540.00 352.64 254.183 Ellipse Separation Pass- MPJ-26-MPJ-26L2-MPJ-26L2 8,300.00 1,384.21 8,300.00 1,155.63 8,532.46 6.056 Clearance Factor Pass- MPJ-26-MPJ-26L2-MPJ-26L2 wp05 298.66 541.92 298.66 539.34 302.97 210.416 Centre Distance Pass- MPJ-26-MPJ-26L2-MPJ-26L2 wp05 350.00 542.13 350.00 539.22 352.64 185.888 Ellipse Separation Pass- MPJ-26-MPJ-26L2-MPJ-26L2 wp05 8,250.00 1,312.76 8,250.00 1,002.08 8,620.46 4.225 Clearance Factor Pass- MPJ-26-MPJ-26PB1-MPJ-26PB1 6,914.49 508.75 6,914.49 439.31 8,074.00 7.326 Ellipse Separation Pass- MPJ-26-MPJ-26PB1-MPJ-26PB1 8,350.00 1,534.99 8,350.00 1,304.22 8,074.00 6.652 Clearance Factor Pass- MPJ-26-MPJ-26PB1-MPJ-26P01 6,914.49 508.75 6,914.49 411.37 8,074.00 5.224 Ellipse Separation Pass- MPJ-26-MPJ-26PB1-MPJ-26PB1 8,350.00 1,534.99 8,350.00 1,215.70 8,074.00 4.808 Clearance Factor Pass- MPJ-26-MPJ-26PB2-MPJ-26PB2 7,065.77 478.74 7,065.77 424.51 8,253.74 8.827 Centre Distance Pass- MPJ-26-MPJ-26PB2-MPJ-26PB2 7,100.00 479.73 7,100.00 423.87 8,266.49 8.589 Ellipse Separation Pass- MPJ-26-MPJ-26PB2-MPJ-26PB2 8,200.00 1,195.97 8,200.00 957.37 8,562.00 5.012 Clearance Factor Pass- MPJ-26-MPJ-26PB2-MPJ-26PB2 7,065.77 478.74 7,065.77 402.29 8,253.74 6.262 Centre Distance Pass- MPJ-26-MPJ-26PB2-MPJ-26PB2 7,150.00 485.07 7,150.00 399.66 8,287.86 5.679 Ellipse Separation Pass- MPJ-26-MPJ-26PB2-MPJ-26PB2 8,175.00 1,174.79 8,175.00 849.45 8,552.60 3.611 Clearance Factor Pass- Plan MPJ-Cipher-Plan MPJ-Cipher-MPJ-Cipher wp0 1,750.00 101.89 1,750.00 87.90 1,834.51 7.283 Ellipse Separation Pass- Plan MPJ-Cipher-Plan MPJ-Cipher-MPJ-Cipher wp0 1,754.61 101.88 1,754.61 87.96 1,839.22 7.320 Centre Distance Pass- Plan MPJ-Cipher-Plan MPJ-Cipher-MPJ-Cipher wp0 2,450.00 207.69 2,450.00 173.89 2,507.95 6.145 Clearance Factor Pass- Plan MPJJax-Plan MPJ-Jax-MPJ-Jax wp01 2,625.00 198.88 2,625.00 157.43 2,777.14 4.798 Clearance Factor Pass- Plan MPJ-Jax-Plan MPJ-Jax-MPJ-Jax wp01 2,725.00 181.98 2,725.00 148.23 2,876.28 5.393 Ellipse Separation Pass- Plan MPJJax-Plan MPJ-Jax-MPJ-Jax wp01 2,766.72 180.47 2,766.72 151.21 2,915.83 6.168 Centre Distance Pass- Plan MPJ-Kali-Plan MPJ-Kali-MPJ-Kali wp01 1,550.00 105.90 1,550.00 96.32 1,63123 11.051 Ellipse Separation Pass- Plan MPJ-Kali-Plan MPJ-Kali-MPJ-Kali wp01 1,553.57 105.89 1,553.57 96.32 1,634.80 11.062 Centre Distance Pass- Plan MPJ-Kali-Plan MPJ-Kali-MPJ-Kali wp01 2,525.00 312.95 2,525.00 265.66 2,611.51 6.617 Clearance Factor Pass- Plan MPJ-L-Plan MPJ-L-MPJ-L wp03 726.44 90.05 726.44 85.64 719.56 20.429 Centre Distance Pass- Plan MPJ-L-Plan MPJ-L-MPJ-L wp03 750.00 90.12 750.00 85.56 742.55 19.738 Ellipse Separation Pass- Plan MPJ-L-Plan MPJ-L-MPJ-L wp03 2,925.00 547.49 2,925.00 480.97 2,883.28 8.230 Clearance Factor Pass- Plan MPJ-L-Plan MPJ-LL1-MPJ-LL1 wp03 726.44 90.05 726.44 85.74 719.56 20.924 Centre Distance Pass- Plan MPJ-L-Plan MPJ-LL1-MPJ-LL1 wp03 750.00 90.12 750.00 85.66 742.55 20.198 Ellipse Separation Pass- Plan MPJ-L-Plan MPJ-LL1-MPJ-LL1 wp03 2,925.00 547.49 2,925.00 481.07 2,883.28 8.243 Clearance Factor Pass- 19 August,2015-18:27 Page 9 0113 COMPASS • 0 Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for MPJ-23-MPJ-23A wp3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: M Pt J Pad-MPJ-23-Plan:MPJ-23A-MPJ-23A wp3 Scan Range:0.00 to 13,433.11 usft.Measured Depth. Scan Radius Is 1,536.71 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse ©Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft Plan MPJ-N6-Plan MPJ-N6-MPJ-N6 wp04 563.05 44.33 563.05 40.37 560.58 11.182 Centre Distance Pass- Plan MPJ-N6-Plan MPJ-N6-MPJ-N6 wp04 575.00 44.35 575.00 40.32 572.37 10.995 Ellipse Separation Pass- Plan MPJ-N6-Plan MPJ-N6-MPJ-N6 wp04 1,300.00 108.81 1,300.00 94.30 1,287.03 7.498 Clearance Factor Pass- Plan MPJ-N6-Plan MPJ-N6L1-MPJ-6NL1 wp01 563.05 44.33 563.05 40.37 560.58 11.182 Centre Distance Pass- Plan MPJ-N6-Plan MPJ-N6L1-MPJ-6NL1 wp01 575.00 44.35 575.00 40.32 572.37 10.995 Ellipse Separation Pass- Plan MPJ-N6-Plan MPJ-N6L1-MPJ-6NL1 wp01 1,300.00 108.81 1,300.00 94.30 1,287.03 7.498 Clearance Factor Pass- Plan MPJ-Persphone-Plan MPJ-Persphone-MPJ-Pe 260.16 209.61 260.16 207.20 263.16 86.825 Centre Distance Pass- Plan MPJ-Persphone-Plan MPJ-Persphone-MPJ-Pe 300.00 209.73 300.00 207.06 302.99 78.488 Ellipse Separation Pass- Plan MPJ-Persphone-Plan MPJ-Persphone-MPJ-Pe 1,000.00 284.95 1,000.00 277.52 981.73 38.351 Clearance Factor Pass- Plan MPJ-Switch-Plan MPJ-Switch-MPJ-Switch wp0 7,575.00 286.79 7,575.00 104.43 8,117.63 1.573 Clearance Factor Pass- Plan MPJ-Switch-Plan MPJ-Switch-MPJ-Switch wp0 7,675.00 232.89 7,675.00 92.62 8,172.99 1.660 Ellipse Separation Pass- Plan MPJ-Switch-Plan MPJ-Switch-MPJ-Switch wp0 7,806.30 200.82 7,806.30 115.25 8,234.98 2.347 Centre Distance Pass- Plan MPJ-Y-Plan MPJ-Y-MPJ-Y wp02 472.10 61.76 472.10 58.38 470.08 18.248 Centre Distance Pass- Plan MPJ-Y-Plan MPJ-Y-MPJ-Y wp02 500.00 61.77 500.00 58.28 497,61 17.685 Ellipse Separation Pass- Plan MPJ-Y-Plan MPJ-Y-MPJ-Y wp02 725.00 73.43 725.00 68.93 715.56 16.331 Clearance Factor Pass- Plan MPJ-Y-Plan MPJ-YL1-MPJ-YL1 wp02 472.10 61.76 472.10 58.38 470.08 18.248 Centre Distance Pass- Plan MPJ-Y-Plan MPJ-YL1-MPJ-YL1 wp02 500.00 61.77 500.00 58.28 497.61 17.685 Ellipse Separation Pass- Plan MPJ-Y-Plan MPJ-YL1-MPJ-YL1 wp02 725.00 73.43 725.00 68.93 715.56 16.331 Clearance Factor Pass- Plan:MPJ-27-MPJ-27-MPJ-27 WP3 3,282.96 135.47 3,282.96 113.28 3,500.56 6.106 Centre Distance Pass- Plan:MPJ-27-MPJ-27-MPJ-27 WP3 3,800.00 160.29 3,800.00 60.51 4,002.99 1.606 Ellipse Separation Pass- Plan:MPJ-27-MPJ-27-MPJ-27 WP3 3,925.00 179.35 3,925.00 64.44 4,124.61 1.561 Clearance Factor Pass- M Pt N Pad MPN-01-MPN-01-MPN-01 10,297.78 526.20 10,297.78 292.87 3,595.92 2.255 Centre Distance Pass- MPN-01-MPN-01-MPN-01 10,300.00 526.21 10,300.00 292.86 3,595.88 2.255 Clearance Factor Pass- MPN-01-MPN-01-MPN-01 10,297.78 526.20 10,297.78 279.56 3,595.92 2.133 Centre Distance Pass- MPN-01-MPN-01-MPN-01 10,300.00 526.21 10,300.00 279.54 3,595.88 2.133 Clearance Factor Pass- MPN-01-MPN-01A-MPN-01A 10,267.09 756.30 10,267.09 543.11 3,309.69 3.547 Clearance Factor Pass- MPN-01-MPN-0IA-MPN-01A 10,267.09 756.30 10,267.09 531.85 3,309.69 3.370 Clearance Factor Pass- MPN-01-MPN-01B-MPN-01B 10,425.76 698.52 10,425.76 470.37 3,379.31 3.062 Centre Distance Pass- MPN-01-MPN-01B-MPN-01B 10,450.00 698.93 10,450.00 470.17 3,382.76 3.055 Ellipse Separation Pass- 19 August,2015-18:27 Page 10 of 13 COMPASS ! ! Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for MPJ-23-MPJ-23A wp3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: M Pt J Pad-MPJ-23-Plan:MPJ-23A-MPJ-23A wp3 Scan Range: 0.00 to 13,433.11 usk.Measured Depth. Scan Radius is 1,536.71 usk.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 (usk) (tisk) (usk) (usk) usft MPN-01-MPN-01B-MPN-01B 10,500.00 702.44 10,500.00 471.29 3,400.00 3.039 Clearance Factor Pass- MPN-01-MPN-01B-MPN-01B 10,425.76 698.52 10,425.76 458.93 3,379.31 2.916 Centre Distance Pass- MPN-01-MPN-01B-MPN-01B 10,450.00 698.93 10,450.00 458.70 3,382.76 2.909 Ellipse Separation Pass- MPN-01-MPN-01B-MPN-01B 10,500.00 702.44 10,500.00 459.70 3,400.00 2.894 Clearance Factor Pass- Survey tool program From To Survey/Plan Survey Tool (usk) (usk) 108.96 7,800.00 MWD R2 7,800.00 13,433.11 MPJ-23Awp3 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. 19 August,2015- 18:27 Page 11 of 13 COMPASS • • Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for MPJ-23-MPJ-23A wp3 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to MPJ-23A©66.00usft(NORDIC 3). Northing and Easting are relative to MPJ-23. Coordinate System is US State Plane 1927(Exact solution),Alaska Zone 04. Central Meridian is-150.00°,Grid Convergence at Surface is:0.40". -X- J1PJ-2b,MPJ-2b,MPJ-2b VS Ladder Plot 4 APJ-26,MPJ-26,MPJ-26 wp08 V30 -e- APJ-26,MPJ-26PB1,MPJ-26PB1 V3 -9- APJ-26,MPJ-26L1,MPJ-26L1wp06V21 Ifi�� t Q k,i �` APJ-26,MPJ-26L1,MPJ-26L1 V3 is 7.�r,� - i� iyrlr: w r ��liP "1 '104.14./ A li: i 1CA, APJ-11, -11,MPJ-11 V1 1350 APJ-10,MPJ-10,MPJ-10 V1 1n c 91i; I 1 11 �� nl.): %1, ,, �/, Ii�„1� , . /r' i it IIS $ APJ-24,Plan:MPJ-24A,MPJ-24A WP2 VO d, '��� v v1,11 !'�� /• 1'" :/e•--- tfi i1 ,�Y 'Ian:MPJ-27,MPJ-27,MPJ-27VM3V0 - ,���� /a 1i - .j+t _ 11 !'4: 10 CI, -� APJ-01, -01,MPJ-01 V3 d ❑l, rl. i e�7. :1,\,,,,- r, ,� all C j ,tift f y�/ �f�.✓r If _ 1 AP,L01,MPJ-01A,MPJ-01AV2 �� t �!► u�I��u �'r�it 'e`./'+iA IrQ x,df ,1�i /�� $ APJ-01,MPJ-01ALI,MPJ-01AL1V6 TV-5 ,)� fit 1,' t./ 'I •Vl X11 4i.fl ' •' - APJ-01,MPJ-01AL 1,Plan#5 V1 /�.� , �_ '�, � 1� 1 (. :.,...1......v,,, .r► -� APJ-02,MPJ-02,MPJ-02 V1 cq it a / ,I,i, �� yi.• ,"�` . ___ � " -t- APJ-03,MPJ-03,MPJ-03 V1 !�� ..1. :A._ i���Y /i /� IR r, 11 i )F APJ-04,MPJ-04,MRL04V1 c %d Ifs •• �` 1i 4qt. ii:. r 1 ./rY -� APJ 08,MPJ OS,MPJ OS Vi U 45t) �' !if.,I! I 'r=A 11 ' -X- APJ-08A MPJ-08A,MPJ-08AV7 O ���r- I I .�� iy�., ;/�� .` -4- AP110,MPJ10 MP 110 V1 1 it►�"1/ ....: M it } APJ-11,MPJ-11,MPJ-11 V1 c � :A �� ' $ APJ-15,MPJ-15,MRL15V5 C.) "M-e =�" �r 1 1 APJ-16,MPJ-16,MPJ-16 V1 I Iy'' I $ APJ-16,MPJ-16APlan,MPJ-16AWp3.0V12 0 ,ht/p,43 ',',3,,QlA,3,r14.MA\A\,'JF,31r1.,rYri,tva,P..o°.• -A- APJ I7.MPJ-1 7.MP-17V1 0 2500 5000 7500 10000 12500 $ APJ-18,MPJ-18,MPJ-18 V2 Measured Depth(2500 usft/In) -' APJ-19,MPJ-19,MPJ-19 V1 APJ-19A,MPJ-19A,MPJ-19A V1 l9 August.2016- 1827 Page 12 of 13 COMPASS • • Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for MPJ-23-MPJ-23A wp3 Clearance Factor Plot: Measured Depth versus Separation(Clearance)Factor t l ri � %.^ ♦ II,LT III. `I 11j Itl - MPJ-26,MPJ-26,MPJ-26 V5 Ilt MPJ-26,MPJ-26,MPJ-26 08V30 10.00 Il i Igi!I Ik ,ai All j�l ,tik4�a �i iki 1�1 1Eva 11 11 = MPJ-26,MPJ-26P61,MP 6PB1V3 leill ri•ll r L `r■" II 1II , 's Iii 1,/1 IF V Ill II !I MPJ -26L11 vpO6V21 w\ 11�I+�us10 ,,1I�,.,l ii /1 i1 FM• i� ____ MPJ26,MPl26L1,MPY26L1V3 875 311 till,Tintili•S7VI:t101 �� i {'1 • 1 - - MPJII,MPJ-11,MPJ-11 V1 �� I, ; 1 w 1! I� MPJ-10,MPJ-10,MPJ-10V1 �- 1p ) •, i1 �,'\�I'11 JI ii I'1 = MPJ-24, -24A,MPJ-24AWP2V0 7.50 1 I �i, , , �� A- 1itN,l lr(�1/►�J!'e/,.vr 1 t �S•, Plan:MPJ-27,MPJ-27,MPJ-27 WP3 V0 �1 1 �l� .. �`I,./ `I���III �\ �4 = MPJ-01,MPJ-01,MPJ-01 V3 A`� 111 �,)IA, ♦,♦ `� a,, s •'111;1:: 1 1.I,l\ _.__.-_r/ !i - MPJ-01,MPJ-01A,MPJ-01AV2 6.25 _-.-- �... l :. ; - U ,1�� • ,Ir- ♦yr.A 1 1! `` , ,` I/ /• = MPJ-O01 -01AL1V6 -4 �4$ ...... /!111* `17.' A\�'1' 111 '/I 1 - MPJ-01,MPJ-01AL1,Plan 45V1 0 5.00 ----- � t>�it�` I�AI� lial J,l��1 `I\,��,1, /I _ MPJ-02,MPJ-02,MPJ-02V1 .T , k'4,1 I �\r\,1♦ VA i'l 11 MPJ-03,MPJ-03,MRY03V1 I� ,,��Ipliii ���+, \;\,i ♦♦��� i 1 fir'. MPJ-04,MPJ04,MPJ-04 V1 W 3.75 �F` A a ��, ♦fir �. 0I / - MPJ-08,MPJ-08,MPJ08V1 \ 1 r �r/ I 6: MPJ-08A,MPJ-08A,MPJ-08AV7 2.50_ { !I SII Olire. "' ",;T:c"Fr". A\\ �"{,`�y�. �1�11 /� MPJ-10,MPJ-10,MPJ-10 V1 • �ft'.i iL ,,...AMPJ-11,MPJ-11,MPJ-11 V1 CollisionAvoidanceReg � - ,. 'JIl�10 .te7MPJ-15,MPJ-15,MPJ-15V5 oZone-Stop Dolling -- I MPJ-16,MPJ-16,MPJ-16 V1 1.25 -- - -•'s-�..:w6,,....' G,141 - MPJI6,MPJ-16APlan,MPJ-16AWp3.0V12 MPJ-17,MPJ-17,MPJ-17 V1 _ /A 0.00 A:1[kAAikikAAA!\!1A!\AAAA!►AA'►Ae►AAlie1l\AA41 1 i i 1 1 ` r I I S 1 1 F 1 1 11 i MPJ-18,MPJ-18,MPJ-18 V2 0 1250 2500 3750 5000 6250 7500 8750 10000 11250 12500 13750 15000 MPJ-19,MPJ-19,MPJ-19 V1 MeasaDepth(2500In) —111—MPJ-19A,MPJ-19A,MPJ-19A V1 ..—.---- IS August,2015• 18:27 Page 13 of 13 COMPASS • , Tree:3-1/8"FMC horizontal tree MP J-23 Post-Work KB elev.=63.20' Wellhead:11"x 11'5M tbg.spool, DF elev.=62.20' FMC Horizontal tree Model 120 11'x 3.5"8 rd EUE(top&bottom) GL elev.=35.80' FMC TBG HNG w/3.5"'H'BPV profile. , 20" 110' Pv Tam port collar 1005' 0 ` `' , �' 3.5"9.3#ppf,L-80 EUE 8rd tubing S�, / JJJ (drift ID=2.992",cap.=0.0087 bpf) /I , 7"26 ppf,L-80,Btrc.production casing `� (drift ID=6.151",cap.=0.0383bpf) KOP 0' , � Max wellbore Angle:79"(81'MD �, , � Hole angle through perfs=90 deg. eO'4/j/ • Cement Retainer @-7,800'i I \. Tubing - 891' f /‘-)13 "�`�• • Baker S-3 packer(3.97'ID) 7900' 3.5"HES"XN"Nipple 7925' 2.813"packing/2.75"No- WLEG 7937' Baker guide shoe' RA tag at 8456' 3v Short joint 8539'(29.73') 1:7rp c Uf' Milled window from 8569'-8581' lit of slotted liner(39')8902'-8940' Baker 4.5"flow guide stock w/2.375" 8573' 75jts.of slotted liner(3000')(8981'-11981') /E id 4 D I Baker HR setting sleeve 8590' �� _� - - �� _J — _/ MUM Baker T ML torque master pkr 600-47 8595' .`7 -y _ WLEG 8614' 1 ^' 4.5'12.6#,L-80 IBT tubing 4 4 Baker Float shoe at 12062' Baker HR sleeve w extension 8798' Baker HMC liner hanger BBOT MIMIIIIIMMI 111•1111i IM=E 1111 ANIMMI U! M - M Halliburton float collar 8809' UMW MN= MUM Halliburton float shoe 8892' 4.5'12.6#,L-80 IBT tubing. Baker Float shoe at 12126' 87jts.of Slotted liner(3402')(8680'-12082') 4-112"SLOTTED INTERVALS OA-8902'-8940'MD(39') OA-8981'-11981'MD(3000') OB-8680'-12082'MD DATE REV.BY COMMENTS MILNE POINT UNIT 10/08/00 M.Linder Initial completion by Doyon 141 WELL J-23 09/15/01 B.Hasebe Addition of Jet Pump flow schematic API NO: 50-029-22970 BP EXPLORATION (AK) • 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: P U LT- A- PTD: o2IS —/S / Development ✓ Service Exploratory Stratigraphic Test Non-Conventional FIELD: ifil int- I a��, _ POOL: i'/j1E / 7c I n4 X.r' j,r\Z1t1 Cly) 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 ! 0 El II Q III o Q o m m a > co o, a ct p g, �. a� m, �, m, of c o' E a) � Z. y, ai, v, 2 a) o 0 p U. rn 3 O. y. 0 L, $ p Je 2i, o �' �, w, > m L . . c o. , o c �, a a N, v+• m', - E' o . y N , Y 0 v. L aC3 O, �, y. c�. �, g. , 3, y. 0 ,J� o ¢ , . 0, in. c. � (0ui, oga` aON cNi W' o to o N N. . J, 0) N. . -' . 4 -0 n, `O a) m m a) 0, a, W fa, a co, a DOJ . cc, 'a u), . Cl., , N . X C, 5, c', •g. (U c, v' 3, 0, m pap, o, m . a) . u o F.' ' f'. W, a )' . C, ' a), E, V, 3' .t. y m, 0. W, . ' . 0, 'O. . 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