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215-003
• • p7-0 21 ,-7-0° 3 Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Wednesday,January 03, 2018 11:05 AM To: 'Plunkett, Ethan T' Subject: RE: [EXTERNAL]RE:ConocoPhillips KRU 30-12 WAG vs.WINJa That will work- From: Plunkett, Ethan T[mailto:Ethan.T.Plunkett@conocophillips.corn] Sent:Tuesday,January 02, 2018 2:50 PM To: Loepp,Victoria T(DOA)<Victoria.loepp@alaska.gov> Cc: Haggerty-Sherrod,Ann(Northland Staffing Services)<Ann.Haggerty-Sherrod@contractor.conocophillips.com> Subject: RE: [EXTERNAL]RE: ConocoPhillips KRU 30-12 WAG vs.WINJ Good morning Victoria, We conducted the WAG on the 30-12 last week to gas. I'm sending over the 10-404 but this will have the same sundry number as the previously submitted 10-403. 30-12 (188-041) 30-1211 (215-003) 30-1211-01(215-047) Will this create an issue? SCANNED Thanks, Ethan Ethan Plunkett I3NIMROQ-Senior Drillsite Petroleum Engineer I ConocoPhillips Alaska I GKA Base I 0: (907)263-4280 C: (918)812-2284 From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday, December 20,2017 9:50 AM To: Plunkett, Ethan T<Ethan.T.Plunkett@conocophillips.corn> Subject: RE: [EXTERNAL]RE: ConocoPhillips KRU 30-12 WAG vs.WINJ You may submit the 10-404 now to correct the status to WAG. Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 1 STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMAION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing H Operations shutdown LJ Performed: Suspend ❑ Perforate ❑ Other Stimulate H Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ 'erforate New Pool H Repair Well ❑ Re-enter Susp Well ❑ Other: WINJ to WAG 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 215-003-0 3.Address: P. 0. Box 100360,Anchorage,Alaska Stratigraphic❑ Service Q 6.API Number: 99510 50-029-21804-60 7.Property Designation(Lease Number): 8.Well Name and Number: ADL025513 KRU 30-12L1 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 9,150 feet Plugs measured None feet true vertical 6,674 feet Junk measured None feet Effective Depth measured 9,130 feet Packer measured 6364 feet true vertical 6,668 feet true vertical 6321 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 74 16 110 110 RECEIVED SURFACE 4,071 12 4,106 4100 WINDOW 8 7 6,636 6590 LINER 517 6 6,876 6827 PRODUCTION 6,924 7 6,957 6909 JAN 0 3 2018 LINER L1 1,530 3 9,130 6668 AOGCC Perforation depth Measured depth Slots:7613-9130 feet True Vertical depth 6597-6669 feet Tubing(size,grade,measured and true vertical depth) 3.5 L-80 6363 6320 Packers and SSSV(type,measured and true vertical depth) Seal ASSY-80-40 GBH-22 SEAL ASSEMBLY 6364 MD 6321 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED JAN 1 6 201$ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 1427 418 3868 Subsequent to operation: 3868 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑ Exploratory❑ Development❑ Service Q Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil H Gas ❑ WDSPL III Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG Q GINJ H SUSP H SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-569 Contact Name: Ethan Plunkett Authorized Name:Ethan Plunkett Contact Email: Ethan.T.Plunkett@conocophillips.com Authorized Title: Petroleum Engineer v� A Contact Phone: (907)263-4280 Authorized Signature: ( Date: �l U Z- Z p l8 Form 10-404 Revised 4/2017 *11 1 1 P +I - (; nf1....1(9 Submit Original Only • • ConocoPhillips ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 January 2, 2018 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, Enclosed you will find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. regarding 30-12L1 (PTD# 215-003). If you have any questions regarding this matter, please contact me at 907-263-4280. Sincerely, L-I/% OrEthan Plunkett Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Sundry Report Description of Work Completed Schematic 1111111M111111111111111111111111=1111111.111111MIIIIMIIIIIIMIL 1 • 30-12L1 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 12/30/17 Convert well from WINJ to WAG service. KUP INJ 110 30-12L1 ConocoPhillips 0.° Well Attributes Max Angle&MD TD Alaska.Inc. Wellbore APl/UWI Field Name Wellbore Status I ncl(°) MD(ftKB) Act Btm(ftKB) Ceine .yips 500292180460 KUPARUK RIVER UNIT INJ 101.32 6,980.84 9,130.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 30-12L1,11/17/20158.04:37 AM SSSV:TRDP 90 5/6/2015 Last WO: 40.00 6/3/1988 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date -- ---- Last Tag' Rev Reason:WAIVERED CANCELLED pproven 10/15/2015 HANGER;33.0 It 1I Casing Strings - Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread iF WINDOW 7 6.276 6,628.0 6,636.0 6,590.3■. Casing Description OD(in) 'ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread LINER L1 2 3/8 1.992 7,600.1 9,129.9 6,668.6 4.60 L-80 STL Ilrlr' Liner Details Nominal ID 1. Top(ftKB) Top(TVD)(ftKB) Top Incl CI Item Des Com (in) CONDUCTOR;36.0.110.0 7,600.1 6,633.0 90.64 BILLET BAKER OPEN HOLE ANCHORED BILLET 1.900 Perforations&Slots SAFETY VLV;1,803.8 5" Shot Dens Top(TVD) Btm(TVD) (shotslf Top(ftKB) Btm(ftKB) (ftK131 (ftKB) Zone Date t) Type Com GAS LIFT;2.4966 7,613.0 8,5776 6,632.8 6,617.8 A-2,30-12 3/9/2015 SLOTS Slotted Liner 8,279.2 9,129.6 6,597.3 6,668.5 A-2,30-12 3/9/2015 SLOTS Slotted Liner Notes:General&Safety End Date Annotation GAS LIFT;3,7170 320/2015 NOTE'ADD LATERALS L1(off main wellbore),L1-01 SURFACE;35.0.4.105.7-A• GAS LIFT;4,603.0 GAS LIFT;5,334 6 GAS LIFT;5,883.8 .. GAS LIFT;6,250.3 NIPPLE;6,310.2 B I LOCATOR;6,362.5 Ali SEAL ASSY;6,363.6 'i.. • • 0.g (PERF;6,611.0-6,621.0- • WHIPSTOCK;6,625.0 - WINDOW;6.628.0.6.636.0 RPERF,6.661.0-6,677.0, IPERF;6,661.0-6,671.0 $. g� RPERF;6.676.0-6695.0 d qNq IPERF;6,676.0-6,700.0 . pAp RPERF;6,695.0-6,700.0 a APERF;6,712.0.6,732.0 it EI. Il. LINER;6,3592-6,876.0 a PRODUCTION;33.0-6,957.1 111 9♦. SLOTS;7,613.0.8,577.6 SLOTS;8.279.25,729.6 LINER LI;7,600.1-9,129.9 Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Wednesday, December 20,2017 9:50 AM To: 'Plunkett, Ethan V Subject: RE: [EXTERNAL]RE:ConocoPhillips KRU 30-12 WAG vs.WINJ You may submit the 10-404 now to correct the status to WAG. Victoria Victoria Loepp Senior Petroleum Engineer SCANNEIJ0 , State of Alaska ' Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepo alaska.gov 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 Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Plunkett, Ethan T[mailto:Ethan.T.Plunkett@conocophillips.com] Sent:Tuesday, December 19, 2017 4:02 PM To:Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]RE: ConocoPhillips KRU 30-12 WAG vs.WINJ Just to confirm:We will conduct the WINJ to WAG and then submit the 10-404 to WAG after the work has been completed? Thanks for the help, Ethan From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday, December 19,2017 11:50 AM To: Plunkett, Ethan T<Ethan.T.Plunkett@conocophillips.com> Subject: [EXTERNAL]RE: ConocoPhillips KRU 30-12 WAG vs.WINJ Ethan, They are currently listed as WINJ. Please submit 10-404 for each of them listed as WAG. Thanx, Victoria 1 • pro (215-003 VT L. From: Plunkett, Ethan T(mailto:Ethan.T.Plunkett@conocophillips.comj Sent: Monday, December 18, 2017 2:02 PM To:Loepp,Victoria T(DOA)<victoria.loeppPalaska.gov> Subject:ConocoPhillips KRU 30-12 WAG vs.WINJ Good afternoon Victoria, I recently transitioned into Yemeli Gozon's vacated role under Michael Braun as petroleum engineer for Kuparuk drillsites 3N,31,3M,3R,30 and 3Q. We are working to find more lean gas injection wells on the north side of Kuparuk. I noticed for 30-12 that we have the 10-403 and 10-407 listed as WAG, but the filed 10-404 were mistakenly filed as WINJ. The wells in question are: 30-12 (188-041) 30-12L1 (215-003) 30-12L1-01(215-047) My question is that are these wells considered WAG or WINJ in AOGCC's opinion? If they are considered WINJ, is it possible to file a 10-404 to WAG? Thanks for your help, Ethan Plunkett Ethan Plunkett I 3NIMROQ-Senior Drilisite Petroleum Engineer I ConocoPhillips Alaska I GKA Base I 0: (907)263-4280 C: (918)812-2284 SCANNED 2 cx 2 STATE OF ALASKA ' AIWA OIL AND GAS CONSERVATION CO*SION ` REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate r Other StimulateAlter Casing pr Change Approved Program Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: Prod to WIND Fi 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: j ConocoPhillips Alaska, Inc. Development Exploratory r 215-003-0 3.Address: 6.API Number: Stratigraphic r Service P. 0. Box 100360,Anchorage,Alaska 99510 50-029-21804-60 7.Property Designation(Lease Number): 8.Well Name and Number: ADL025513 KRU 30-12L1 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 9150 feet Plugs(measured) None true vertical 6674 feet Junk(measured) None Effective Depth measured 9130 feet Packer(measured) 6364 true vertical 6668 feet (true vertical) 6321 Casing Length Size MD TVD Burst Collapse CONDUCTOR 74 16 110 110 SURFACE 4071 12 4106 4100 WINDOW 8 7 6636 6590 LINER 517 5.96 6876 6827 PRODUCTION 6924 7 6957 6909 LINER L1 1530 2.63 9130 6668 RECEIVED Perforation depth: Measured depth: Slots: 7613-9130ANE0 OCT 2 7 201 True Vertical Depth: 6597-6669 AOGCC Tubing(size,grade,MD,and TVD) 3.5, L-80, 6363 MD,6320 TVD Packers&SSSV(type,MD,and TVD) SEAL ASSY-80-40 GBH-22 SEAL ASSEMBLY @ 6364 MD and 6321 TVD SEAL ASSY-80-40 GBH-22 SEAL ASSEMBLY @ 6364 MD and 6321 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 1050 0 Subsequent to operation 2777 338 640 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations P Exploratory r Development r Service 7 Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ 1 WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-569 Contact Darrell Humphrey/Bob Christensen Email n1139(c�conocophillips.com Printed Name Robert D Christensen Title NSK Production Engineering Specialist Signature Phone:659-7535 Date /6/23/ /S' v7-1- 10/277/5" Form 10-404 Revised 5/2015 RBDM jG 1 1 71015 Submit Original Only • 30-12L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/12/15 BRUSH n' FLUSH TBG TO 6400' SLM, SET 2.81 XX PLUG &GAUGES @ 6310' RKB, SET 3 1/2 AVA STYLE CATCHER ON PLUG @ SAME, PULLED OV @ 6250' RKB, PULLED GLV @ 2496' RKB SET DV @ SAME, PULLED GLV's @ 3717', 4603', 5334' &5883' RKB. 10/13/15 SET DV's @ 3717', 4603', 5334', &5883' RKB, LOAD TBG & IA W/INHIBITED SEAWATER W/DSL (U-TUBE) FREEZE PROTECT. SET DV @ 6250' RKB. MITIA(PASS). 10/14/15 PULLED AVA CATCHER &2.81"XX PLUG W/GAUGES @ 6310' RKB. 10/20/15 Well opened to water only injection service ✓ KUP PROD Mr 30-12L1 ConocoPhillips if Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status Ind(") MD ORB) Act Blm(ftKB) CnndP Mpg 500292180460 KUPARUK RIVER UNIT PROD j 101.32 6,980.84 9,130.0 ,.x,. Comment H25(ppm) Date IAnnotation End Date KB-Grd(ft) 'Rig Release Date 30-12L1,10/15/2015 3'25'48 PM SSSV TRDP 90 5/6/2015 Last WO: 40.00 6/3/1988 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date -- ------- --- Last Tag: Rev Reason GLV C/O lehallf 10/15/2015 HANGER;33.0 Pill Casing Strings ` Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread F WINDOW 7 6.276 6,628.0 6,636.0 6,590.3 J Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread LINER LI 23/8 1.992 7,600.1 9,129.9 6,668.6 4.60 L-80 STL �.' Fi,' saa. Liner Details Nominal ID 111 Top(ftKB) Top(TVD)(65613) Top Incl(1 Item Des Com (in) CONDUCTOR;36.0-110.0 s. 7,600.1 6,633.0 90.64 BILLET BAKER OPEN HOLE ANCHORED BILLET 1.900 Perforations&Slots SAFETY VLV;1,803.8 Pqrs.9 III Shot Den I Top(TVD) Btm(TVD) (shots/f Top(ftKB) She(ftKB) (ftKB) (ftKB) Zone Date t) Type Com OAS LIFT;2,49fi.6 7,613.0 8,577.6 6,632.8 6,617.8 A-2,30-12 3/9/20)5 - SLOTS Slotted Liner 8,279.2 9,129.6 6,597.3 6,668.5 A-2,30-12 3/9/2015 SLOTS Slotted Liner Notes:General&Safety End Date Annotation GAS LIFT;3,717.0 In3/20/2015 NOTE.ADD LATERALS L1(off main wellbore),L1-01 SURFACE;35.0-4,105.7-4 GAS LIFT;4,603.0 E GAS LIFT;5,334.6 II I GAS LIFT',5 883 8 GAS LIFT:6,250.3 la a NIPPLE:6,310.2 a LOCATOR;6,362.5 SEAL ASSY;6,363.6 (PERF;6,611.0-6,621.0 WHIPSTOCK;6,625.0 WINDOW;6,628.0-8,636.0 RPERF;6,661P-6,671.0 - • IPERF;6,661.0-6,671.0 • RPERF;6,876.0-6,695.0 IPERF;6,676.0-6,700.0 RPERF;6,695.0.8,700.0- APERF;6,712.0.8,732.0- • li ff rI LINER;6,359.2-6,876.0 Y I PRODUCTION;33.0.6,957.1 40 oc i I SLOTS;7,613.0-8,577.6 on SLOTS;8,279.2-9,129.6 N LINER L1;7,600.1-9,129.9- ti OF Tit 4,w ��\V%iso THE STATTE Alaska Oil and Gas 4. of AsKA Conservation Commission zy 333 West Seventh Avenue 1' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 pit, F` Main: 907.279.1433 ALAS }r, Fax: 907.276.7542 SSEri DE 6.0 www.aogcc.alaska.gov Darrell Humphrey NSK Production Engineering Specialist t 003 ConocoPhillips Alaska, Inc. ai P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 30-12L1 Sundry Number: 315-569 Dear Mr. Humphrey: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, /7/-1,94' Cathy . Foerster Chair DATED this Ig day of September, 2015 RBDMEP 2 , 2015 Encl. 41ECE WED r STATE OF ALASKA ALL OIL AND GAS CONSERVATION COMMON SEP 1 6 2015 APPLICATION FOR SUNDRY APPROVALS �) �( is 20 AAC 25.280 (�0 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown 1— Suspend Suspend r Perforate r Other Stimulate r Alter Casing f— Change Approved Program r Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Prod to WAG IN 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development rj, 215-003-0 3.Address: Stratigraphic r Service r 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-21804-60 I' 7. If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No 17 / KRU 30-12L1 , 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25513 • Kuparuk River Field/Kuparuk River Oil Pool , 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 9150 6674 9130' 6668' None None Casing Length Size MD TVD Burst Collapse LINER L1 1530 2.63 9130' 6668' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Slotted 7613-8577,8279-9129 4 6633-6618,6597-6668 3.5 L-80 6363 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) None 661.4- ASSY (e.Y.0 1` SSSV /RO'3 12.Attachments: Description Summary of Proposal 17 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service rr 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 9/30/2015 OIL r VVINJ r WDSPL r Suspended r 16.Verbal Approval: Date: GAS r WAG GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Darrell Humphrey/Bob Christensen Email: n1139(a),conocophillips.com Printed Name Darrell Humphreyc Title: NSK Production Engineering Specialist Signature ' J �Y4—. �`__„��,( Phone:659-7535 Date 9 . I L , (s Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 31S-rj l Plug Integrity r BOP Test VI Mechanical Integrity Test R. Location Clearance r • Other: 1 nse(...-k-1Qv'N, 0 f cir ch's-AS be i•-k acs_ 0.+.-1 CSL., eAr Ala 2,C(.14V12x3:2 7 .. la,/-c- w/ >SS rof i T — I71- rtt vi d , fit` , ..,-,1--4,1_,r 1,3 d c ,-,j ---c--it Spacing Exception Required? Yes ❑ No Z Subsequent Form Required: jv—44;4 APPROVED BY Approved by: );1•40-4.404.— COMMISSIONER THE COMMISSION Date: 9"if? - /J -A5—Ar li i nIA r 12 months,from th/�a d to of approval. 1n,., it F. aid Form 10-403 Revised 5/2015 PP � � � tJqç �l!«i/eV/6/2z Pp RBLrMSm••+• in_:,'c te4 k13 Ck✓.1 1/16/2-(a1.i 1�i�1J►r� • • 30-12L1 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips requests to convert 30-12 ( PTD 188-041) and it's associated laterals 30-12L1 and 30-12L1- 01 (PTD 215-003,215-047) from oil production to WAG injection service. 30-12 was completed in May of 1988 as a WAG injector, sundry 314-543 10/9/14 approved it for workover as a WAG injector and the 2 laterals were approved for WAG injection 1/13/15. The laterals were completed 3/13/15 were brought on oil production 4/20/15 and have been on production since then. Sundry notifications were submitted 5/17/15 changing the status to oil and pre-produce for greater than 30 days. Converting well 30-12 and it's associated laterals to injection will provide support to the Kuparuk producers 30-08 and 30-13 in the A-Sand patterns. An AOR was completed on the PTD's. Quarter Mile Injection Review(for injection wells only) There are no wells within Y4-mile of the 30-12L1 &30-12L1-0lwell plans. 30-12 (mother bore) Injector • Completed with 7", 26#, J-55 casing on 6/03/1988. • Classified as a "Normal Well"with a recent Rig Work-Over • C-sand perforations: 6611'-6621' MD (behind scab liner and cemented). •A-sand perforations: 6636'-6640' MD, 6661'-6671' MD, 6676'-6700' MD and 6712'-6732' MD (behind scab liner and cemented). • During the Dec. 2014 work over, a variance was granted for setting the packer over 200' away from the uppermost A-sand perforation. Packer is located at 6359' MD. • The cement bond log shows adequate cement as per original injection order. The proposed kick-off point for the CTD sidetrack is in the A-sand perfs and should not compromise existing conformance. The 16" Conductor was cemented with 175sx of AS I. The 9.265" Surface casing was cemented with 1500sx AS III, 300sx Class G, 150sx AS I. 7" Production casing was cemented with 360sx Class G, 175sx AS I. N0 /25erve5 fQ Iir'e 4' CO0 very weld week its Q,,�rove, • • From PTD application 30-12L1 & 30-12L1-01 (approved 1/13/15 215-003, 215-047) 15.Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plan — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire open hole section. — Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 30-12L1 3,397' 30-12L1-01 3,397' — Distance to Nearest Well within Pool Lateral Name Distance Well 30-12L1 1,445' 30-11 30-12L1-01 1,445' 30-11 16. Quarter Mile Injection Review (for injection wells only) II' (Requirements of 20 AAC 25.402) There are no wells within %4-mile of the 30-12L1 & 30-12L1-0lwell plans. 30-12 (mother bore) Injector • Completed with 7", 26#, J-55 casing on 6/03/1988. • Classified as a"Normal Well"with a recent Rig Work-Over • C-sand perforations: 6611'-6621' MD (behind scab liner and cemented). • A-sand perforations: 6636'-6640' MD, 6661'-6671' MD, 6676'-6700' MD and 6712'- 6732' MD (behind scab liner and cemented). • Plan to re-perforate the A-sand perforations pre-rig before drilling the 30-12L1 &30- 12L1-01 laterals. • During the Dec. 2014 work over, a variance was granted for setting the packer over 200' away from the uppermost A-sand perforation. Packer is located at 6359' MD. The cement bond log shows adequate cement as per original injection order. The proposed kick-off point for the CTD sidetrack is in the A-sand perfs and should not compromise existing conformance. • 0 '''.0611.. Oo os , gyp, �� 30-09 30-121 1�� L I\ ,`�O 15 O 3O ,y O P Q( �p O v iso-°- i. I 1 F YP -`-- I' , f 4 r': s ConocoPhilli p Legend Alaska,Inc. 0 Well Surface Location Pad Mean Center Injection Swap Analysis 1/4 Mile Radius 30-12, 30-12L1, 30-12L1-01 30-12 Ni -- 30-12L1 n 5 0.25 0.5 /L\\` Miles 30-12L1-01 V 1 H-04/mjSwap.mxa CSR 5/8/2015 KUP INJ • 30-12L1 ConocoPhiIIips t. = Wen Attributes Max Angle&MD TO Alaska,lnC Wellbore API/OWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) crwxNhnlyn 500292180460 KUPARUK RIVER UNIT INJ 101.32 6,980.84 9,101.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 30-12L1.4/5/20151.18:07 PM SSSV:TRDP Last WO: 40.00 6/3/1988 Vert.alschemanc(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date -- ------ ---- ----- ----Last Tag Rev Reason:GLV 0/0 hipshkf 4/5/2015 HANGER;33.0 i:'. 6j' - Casing Strings Casing 4jt L WINDOW D scri p['on OD tin)lon OD(i n) 7 ID(in) Top(6 276 6 62) Set Depth 28 0 6.63( Set Depth 36 0 5 59) WI/Len(1...Grade Top Thread k I} ) 1 1 (TVD).90.. ■ L N)- I.1 2318 ID(in1 992 Top(7t600.1 Set Depth 9K29 9 Set Depth 5 56) Wt/Len(I.0 L-80e Top Thread P 6,668.6 4.60 L-80 STL Liner Details Nominal ID CONDUCTOR;36.0-110.0 i Top(ftKB) Top(ND)(11KB) Top Incl(1) Item Des Com lin) 7,600.1 6.533-0 00.64 BII-LET BAKER OPEN HOLE ANCHORED BILLET 1.900 SAFETY VLV;1,803.8 alE Perforations&Slots 111 Shot Dens Top(ND) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com GAS LIFT;2,496.6 - 7,613.0 8,577.6 6,632.8 6,617.8 A-2,30-12 3/9/2015 SLOTS Slotted Liner 8,279.2 9,129.6 6,597.3 6,668.5 A-2,30-12 3/9/2015 SLOTS Slotted Liner Notes:General&Safety GAS LIFT;3,717.0 - End Date Annotation 3/20/2015 NOTE:ADD LATERALS L1(off main wellbore),L1-01 SURFACE;35.0-0,105.7-• GAS LIFT;4,603.0 111. GAS LIFT;5,334.6 a GAS LIFT;5,883.8 N GAS LIFT;6,250.3 111 S S NIPPLE;6,310.2 N N LOCATOR;6,362.5 SEAL ASSY;6,363.6 IPERF',6,611 0-6 621 0 WHIPSTOCK;6,625.0 WINDOW;6,628.0-6,636.0 • IPERF;6,661.0.6,671.0 RPERF;6,661.0-6,671.0 • • RPERF;6,676.0-6,7050 IPERF;6,676.0-6,700.0 --- RPERF;6,695.0-6,700.0- APERF;6,712.0-6,732.0 ! t LINER;6,359.2-6,876.0 PRODUCTION;33.0-6,957.11 SLOTS;6.630.4-7578.8- 111 SLOTS;7,613.0.8,577.6 SLOTS;8,279.29,129.6 LINER L1-01;6.620.2-9,101.0 LINER L1;7,600.1-9.129 9 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. t i 5_ 003 Well History File Identifier Organizing (done) ❑ Two-sided ❑ Rescan Needed RESCAN: OVERSIZED: NOTES: Co r Items: ❑ Maps: Grayscale Items: <s: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: ap Date: (0 16 /S /s/ " , Project Proofing BY: art Date: 67//61/5— i 6 ! S /s/ MP Scanning Preparation I x 30 = 30 + a..9 = TOTAL PAGES 57 /6) /5- (Count does not include cover sheet)NBY: aria Date: /s/ Production Scanning Stage 1 Page Count from Scanned File: 0 (Count does include cover eet) Page Count Matches Number in Scanning Preparation: YES NO BY: CP Date: la/ I(Q/l 5T /s/(yip Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc o . c o o a E N N m N 0 . • a -t a N csir o OQ E E °) 6 o as ao Q a _I 0 m �' ° a ° m • =rr c ai • J aJ N Q N NO LLO O LL , i - U }Io >'>. >. >, 8N Oc aa ) 9 co co To To Q o U) U) UM UM C C c c U) co co U) as CJ 2i N p Q j Q Q j Z O O Z E g g 1- 2 g r O O O O F. 0 W W Q CO N l0 (n N (O (0 W W W W a Qa) {p Tito U J J J J J J _J J J J J J C CO N N N LL N N N N N N N N N N 7 -J o O O O p 0 0 0 0 0 0 0 O O O ° N C N M M M Q' M CO CO CO CO CO CO CO CO CO 0 U Ui Q O C N a) a) d co N a) a) N N a) ) a) N a) a) Z 0 N it it,� it p it it LL LL LL LL LL w LL > it LL it - N E ° °a o Y ° cv o oa o o °X 3 N EI.•C C C O C co •C C C C C C C C C C C V) as a O O O N 2 .- MOD O co O O O O O O or- o.- or- 2 .- O in V 0 t0 0 0 O Q 0 U) 0 0 0 0 0 0 00 t0 t0 0 Q 0 -.- 2 E a) a)Q y Q 'o W a)W a) a) a) a) a) a) m Q a)Q a) Q m Q a) Q N O W W Z W Z NI W d' W W W W LU W W Z W Z W Z W Z W 0 0. 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CL n J N N N N N lE0 co E Q W = N N N N N N Z 0) p) II a a) 03 11 IX O v v v v v iL E O Z a m y W ZO • oil V V < d JI Z m ui m cn Q o o co @ y O J a C J • w Ev O 2 0 0 O. ar C r O O H G O _� O " E I N E T O Z N V _ w (.0 a) J r r H EE a, Q N C H ba O V 0. H` o a r i- r CO E C Z N CO C c ' N 0 0 f6 m rt (h 5 O E Ym j Cl) • a r •c w _I Q 03 0 In C• O O a C - o a� I c c a a o1 ca To 1- as 0 CI Z 8Tis co O Z co CO CO CO CO CO y LC)CO CO CO CO CO Vd 'Tr 0 0 0 0 0 N c t NC m m m m m 2 Q CV rn a a a a o R O } Q _ 51- o D 10 0 0 0 0 3 E p c c > v v v v v v : g � v O ~ � � r� r. r- rS WE a I O I m C71 N N N N N N LO LO W O F N N N d ar re 0 c 2 = ai I > I E E Z a� N x W m p' F. (° ao O m oc p 10 co in aa, Z Q o o Z o O c c v °) 0 0 0 0 0 0 p r 'y .0 Ea - y o .c m (a U 0 E V' o 2 a H E E vo ` 0 D O D D D - LL Oo Q a W W W W W J 3 - 0 0 CD 0 0 c 0 ci 5` STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMiviiSSION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon r Rug Perforations r Fracture Stimulate r Rill Tubing r Operations shutdown r Performed Suspend r Perforate r Other Stimulate r Alter Casing 9 r Change Approved Program r Rug for Redrill r Perforate New Pool rRepair Well r Re-enter Susp Well r Other:WAG to ProdFo 2.Operator Name. 4 Well Class Before Work. 5. Permit to Drill Number ConocoPhillips Alaska, Inc. Development r Exploratory r 215-003-00 3.Address. 6.API Number Stratigraphic r Service ri P. 0. Box 100360,Anchorage,Alaska 99510 50-029-21804-60 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25513 KRU 30-12L1 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10 Field/Pool(s). Kuparuk River Field/Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 9150 feet Plugs(measured) None true vertical 6674 feet Junk(measured) None Effective Depth measured 9130 feet Packer(measured) 0 true vertical 6668 feet (true vertical) 0 Casing Length Size MD TVD Burst Collapse Liner L1 1530 2.375 9150 6674 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Perforation depth: Measured depth• slotted liner 7613-8577, 8279-9129 True Vertical Depth. 6633-6618,6597-6668 RECEIVED MAY 192015 Tubing(size,grade,MD,and ND) 3.5, L-80,6363 MD,6350 TVD rr^ AOGCC Packers&SSSV(type,MD,and ND) SSSV=TRMAXX-CMT-5-SR SCSSSV MD= 1804',ND=1804' 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 0 Subsequent to operation 317 419 2746 1313 154 1 14.Attachments(required per 20 AAC 25.070,25 071,&25 283) 15 Well Class after work: Daily Report of Well Operations r Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt N/A Contact Darrell Humphrey/Bob Christensen Email n1139(c7i conocophillips.com Printed Name Darrell Humphrey Title NSK Production Engineering Specialist Signature 1 1 Phone:659-7535 Date 5 /7, /5- frr X12$//5—, f"3 RBDMSLA MAY 2 9 2015 Form 10-404 Revised 5/2015 • --- Submit Origin al'Only • 30-12L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 04/20/15 Pre produced WAG injector brought online, production to be for greater than 30 days 04/04/15 PULLED DV'S & SET GLV'S @ 5883', 5334', 4603', 3717', &2496' RKB; PULLED CATCHER &2.81" XX PLUG W/GAUGES @ 6310' RKB. JOB COMPLETE. SBHP OF 3597 PSI MEASURED. KUP INJ 30-12L1 ConocoPhillips s Well Attributes Max Angle&MD TD AlaskaInc. Wellbore API/UWI Field Name Wellbore Status eel(°I MD(ftKB) Act Btm(ftKB) Cmcrorhahps 500292180460 KUPARUK RIVER UNIT INJ 101.32 6,980.84 9,101.0 - ... . Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 30-12L1,41520151 1807 PM SSSV:TRDP Last WO: 40.00 6/3/1988 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date -- ----------------- - -- --------Last Tag: Rev Reason:GLV C/O hipshkf 4/5/2015 HANGER:33.0 11141 Casing Strings IJ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I Grade Top Thread WINDOW 7 6.276 6,628.0 6,636.0 6,590.3 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread 2 3/8 1.992 7,600.1 9,129.9 6,668.6 4.60 L-80 STL Ai'"".,-----A-AAT'^.Liner Details Nominal ID CONDUCTOR;36.0-110.0---4. . Top(ftKB) Top(ND)(ftKB) Top not(4) Item Des Corn (in) 7,600.1 6,633.0 90.64 BILLET BAKER OPEN HOLE ANCHORED BILLET 1.900 SAFETY VLV;1,803.8 Perforations&Slots Shot Dens -- Top(TVD) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com GAS LIFT;2,496.6 a, 7,613.0 8,577.6 6,632.8 6,617.8 A-2,30-12 3/9/2015 SLOTS Slotted Liner 8,279.2 9,129.6 6,597.3 6,668.5 A-2,30-12 3/9/2015 SLOTS Slotted Liner Notes:General&Safety GAS LIFT;3.717.0 ' End Date Annotation 3/20/2015 NOTE:ADD LATERALS L1(off main wellbore),L1-01 SURFACE;35.0.4,105.7—. L GAS LIFT;4,603.0 `- GAS LIFT;5,334.6 GAS LIFT,5,883 8 GAS LIFT;6,250.3 NIPPLE;6,310.2 `,A'_ LOCATOR;6,362.5 SEAL ASSY;6,363.6 IPERF;6,611.0.6.621.0 i. WHIPSTOCK;6,625.0 WINDOW;6,628.0-6,636.0 I'.�II (PERF;6,661.0.6,671.0 ■ I. RPERF;6.661.46.671.0 r• • I■ RPERF;6676.0.6,665.0, - II IPERF;6676.0-6700.0 II RPERF;6.695.0-6.700.0 MI a APERF;6,712.06,732.0 ! I[I 1 I ft 4I(1 1I PI II E . LINER;6,359.2-6,876.0 PRODUCTION;33.0.6957.1 SLOTS;6,630.4-7,578.8—- , SLOTS;7,613.08,577.6 SLOTS;8,279.2-9,129.8 I—T LINER L1-01;6,620.2-9,101.0 i f LINER L1;7,600.1-9,129.9 z DU4Y 115003 r. 715 25714 BAKER PRINT DISTRIBUTION LIST HUGHES Please sign and return one copy of this transmittal form to: DATA LOG COMPANY ConocoPhillips Baker Hughes INTEQ g /15/20 E C E I V E (mandatory) 795 East 94th Avenue M.K.BEND v WELL NAME 30-12L1;30-12L1-01 Anchorage,Alaska 99515 APR 2 4 2015 (mandatory) FIELD Kuparuk River Unit to acknowledge receipt of this data. �� (mandatory) COUNTY North Slope Borough LOG TYPE LWD-Coil (mandatory) (mandatory) STATE Alaska BH DISTRICT Alaska (mandatory) (mandatory) LOG DATE: March 9,2015 TODAYS DATE: 22-Apr-15 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: Paula Lacey EMAIL: paula.Iacevbakerhughes.com (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? No COMPANY FIELD ' FINAL CD Final CD ADDRESS f FEDEX WILL NOT DELIVER TO P.O.BOX LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #OF I'IiIN 15 #OF COPIES #OF COPIES#OF COPIES 1 ConocoPhillips Alaska Inc. 1 1 1 1 Attn:Ricky Elgaricio ATO 3-344 1700 G Street Anchorage,AK 99510 2 IBP Exploration(Alaska)Inc. I 1 I 1 1 1 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 Attn:Dodie Stinson j 3 Chevron/KRU Rep I 1 1 1 1 1 Attn:Glenn Frederick 'P.O.Box 196247 'Anchorage,AK 99519 4 tate of Alaska -AOGCC I 1 j 1 I 2 I 1 I Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 995 5 DNR-Division of Oil&Gas *** I I I 1 I 1 I 1 Attn:Sean Clifton 550 West 7th Avenue,Suite 802 I Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR I I I TOTALS FOR THIS PAGE: 0 4 5 5 5 0 TOTALS FOR ALL PAGES: 0 4 5 5 5 0 O _ CD un LC) w A No C� _ cv N w ci 0 . H IN C `W o co N O. I C.) C t to 0 0. 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N I� 10 Oi Oi 8 OD (O 2 (V N O OD 8 7 V U Y Y co co M W W W W W W W W W W W W W W W n n n n Z G U) pp h V O (00 O O N (NO n O(0) 2n M M O N V 7 O R nV V S IiNi O O O O O fVO O Oo o o O C O m o d O O 0 N 0 O 00 , NW W V n O M W n N W W n O M O W N c to O co .. a a T E a co- W OO co- p O co- W co- (O co- co os OD W W OO W of 0) of 07 of U 0 o d m 0 '(7) 7 U a` u) 3 o v) oi xECEIVE''D STATE OF ALASKA ;•M 0 2 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANDMOG la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑✓ * WDSPL ❑ Other ❑ No.of Completions: Service ❑✓ - StratigraphicTest❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: •March 12,2015 215-003/ 3.Address: 6.Date Spudded: 13.API Number: P.0. Box 100360,Anchorage,AK 99510-0360 • March 6,2015 50-029-21804-60-00 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 1019'FNL,2011'FWL,Sec.22,T13N, R9E, UM •March 8,2015 KRU 30-12L1 • Top of Productive Horizon: 8. KB(ft above MSL): 59'RKB 15.Field/Pool(s): 2543'FNL,312'FWL,Sec.22,T13N, R9E,UM GL(ft above MSL): 24'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 2666'FNL,295'FWL,Sec.22,T13N, R9E, UM 9150'MD/6674'TVD Kuparuk Oil Pool . 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-525648 y- 6021801 Zone-4 •9150'MD/6674'TVD ADL 25513 • TPI: x-523958 y- 6020271 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-523941 y- 6020148 Zone-4 1804'MD/1804'TVD 2554 18.Directional Survey: Yes ❑✓ ' No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1662'MD/1662'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/VD GR/Res • 6626'MD/6580'TVD 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.6# H-40 36' 110' 36' 110' 24" 175 sx AS I 9.625" 36# J-55 35' 4106' 35' 4100' 12.25" 1500 sx AS III,300 sx Class G, 150 sx AS 7" 26# J-55 33' 6957' 33' 6909' 8.5" 360 sx Class G, 175 sx AS I 4.5" 11.6# L-80 6359' 6876' 6316' 6827' 6" scab liner 2.375" 4.6# L-80 7600' 9130' 6633' 6669' 3" slotted liner 24.Open to production or injection? Yes ❑ No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 3.5" 6366' no packer slots from 7613'-9129'MD 6633'-6668'TVD j""'° I cor11N 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 3 I l C,r�5 .a Was hydraulic fracturingused duringcompletion? Yes No � Y P VsIEt 1 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED w . �. . 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) waiting on facility hook-up Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No Q . Sidewall Cores Acquired? Yes ❑ No Q . If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE Form 10-407 Revised 10/2012 _ CONTINUEDQN REVERRBDMS 3W APR ' 9 2015Submitoriginal only ,?Ka s�'4/1 S 177-2- 575// 5 y 7/2:5... G 29. GEOLOGIC MARKERS(List all formations and man ncountered) 30. FORMATION TESTS NAME MD TVD Well tested? Yes Q No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results Attach separate sheets to this form,if Permafrost-Bottom 1662' 1662' needed,and submit detailed test information per 20 AAC 25 071 Kuparuk A5 6652' 6606' Kuparuk A3 6658' 6611' Kuparuk A2 6680' 6631' Kuparuk Al 6719' 6660' Kuparuk Al 7030' 6659' Kuparuk Al 7751' 6624' Kuparuk A2 7892' 6602' Kuparuk A2 8615' 6620' Kuparuk Al 9023' 6647' N/A Formation at total depth: Kuparuk Al 31. LIST OF ATTACHMENTS Summary of Daily Operations,schematic Final directional survey 32 I hereby certify that the foregoing is true and correct to the best of my knowledge Contact: Ron Phillips @ 2.--6312 Email: \ Ron.L Phillips@conocophillips.com Printed Name D. nhaus Title: CTD Engineering Supervisor 4110Signature Phone 263-4372 Date 11- t(" (5 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases 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. Item 1a: Classification of Service wells. Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.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 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00) Item 20: Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool Item 23: 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 26: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain) Item 27: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 KUP SVC 30-12L1 ConocoPhillips O° Well Attributes Max Angle&MD TD Alaska.Inc. Wellbore API/UWI Field Name Wellbore Status ncl 7) MD(ftKB) Act Btm(ORB) o>roroarvdR 500292180460 KUPARUK RIVER UNIT SVC 101.32 6,980.84 9,101.0 ..° Comment F125(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 30-12L1,3/25/201512'.00:45 PM SSSV:TRDP Last WO: 40.00 6/3/1988 Vertical stherretlt(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ----- ---- Last Tag. Rev Reason:ADD LATERALS LI,L1-01 smsmith 3/20/2015 HANGER;33.0 (L 1 Casing Strings �1 f Casing Description OD(in) ID(in) Top(ORB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread 1,5 (I, WINDOW 7 6.276 6,628.0 6,636.0 6,590.3 fUd 1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread , 9 LINER LI 23/8 1.992 7,600.1 9,129.9 6,668.6 4.60 L-80 STL Liner Details Nominal ID CONDUCTOR;360-1100 ll a Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com BAKER OPEN HOLE ANCHORED (in) 7,600.1 6,633.0 90.64 BILLET BILLET 1.900 El SAFETY VLV,1.803.8 Perforations&Slots Shot Dens Top(TVD) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com GAS LIFT;2,4966 - 7,613.0 8,577.6 6,632.8 6,617.8 A-2,30-12 3/9/2015 SLOTS Slotted Liner 8,279.2 9,129.6 6,597.3 6,668.5 A-2,30-12 3/9/2015 SLOTS Slotted Liner Notes:General&Safety GAS LIFT',3,717.0End Date Annotation • 3/20/2015 NOTE:ADD LATERALS L1(off main wellbore),L1-01 SURFACE;35.0.4,105.7—A GAS LIFT;4,603.0— GAS LIFT;5,334.6 t i GAS LIFT;5,883.8 • GAS LIFT;6,250.3 NIPPLE'.6.310.2 -X." I LOCATOR;6,362.5 SEAL ASSY;6,363.6 i re Mt IPERF;6,611.0-8,621.0— ;. WHIPSTOCK;6,625.0 16" WINDOW;6,628.0-6,636.0 eU IPERF;6,661.0-6,671.0 I■ RPERF;6,fifi1.0-6.671.0 1. RPERF;6,676.0-6,695.0 `, IPERF;8,878.0-8,700.0 II RPERF;6,695.0-6.700.0— !1! RPERF;6,712.0-6,732.0 — ' — II II it '1i II 1I 9 :II .1 - LINER;6,3592-6,876.0 - .I --47. • PRODUCTION;33.0.8.957.11 SLOTS;6,630.4-7,578.6—__ SLOTS;7,613.0-8,577.6 SLOTS;8,2792-9,129.8 1�'I LINER LOS;8,279.2-9,129.6 LINER L1;7,600.1-9,129.9 30-12 PRE-RIG WELL WORK DATE SUMMARY 1/20/2015 GAUGED TBG WITH 2.60" CENT; TAGGED @ 6570' SLM. SET CATCHER. PULLED SOV& SET DV @ 6250' RKB. MIT IA 2500 PSI, GOOD. PULLED CATCHER. COMPLETE. 1/22/2015 RIH TAG @ 6637' CTMD, START JETTING DOWN AT 10 FT MIN AT 1.8 BPM, MADE IT TO 6658' CTMD. HARD TAG MADE NO HOLE, CAME OUT OF HOLE RESTART IN MORNING ****JOB IN PROGRESS**** 1/23/2015 RIH WITH 2.80" 3 BLADE JUNK MILL, TAG @ 6677' CTMD MILLED FOR 3 HRS MADE NO HOLE, POOH CHANGE OUT MILLS, RIH WITH 2.80" DIAMOND PARABOLIC TAG © 6682', MADE IT TO 6687' CALLED TOWN FOR PLAN FORWARD. ****RESTART IN THE MORNING**** 1/24/2015 THREE VENTURI RUNS, GETTING BACK METAL CHUNKS, RUBBER ELEMENTS, WOOD SCREWS, SET SCREWS, MISC. PIECES OF METAL PICS IN WELLVIEW **** JOB IN PROGRESS**** 1/25/2015 TWO VENTURI RUNS, CAME BACK WITH FULL BASKETS BOTH TIMES, ESTIMATED 15 LBS OF METAL, 3' OF HOLE, TAG @ 6689' CTMD WELL READY FOR SLICK LINE 1/29/2015 TAGGED @ 6690' SLM, EST. 6705' RKB. DRIFTED TBG WITH WHIPSTOCK DUMMY TO BOTTOM. IN PROGRESS. 2/1/2015 LOG GR/CCL CORRELATION PASS AND FOUND TOP OF FILL AT 6710'. PERFORATE INTERVAL 6695'-6700' USING 2.5" HSC LOADED 6 SPF, PHASED 60 DEG, 11.1 GR MILLENIUM II HMX CHARGES. LOG CORRELATED TO SLB CEMENT BOND LOG DATED 17 JUN 1988 AT K1 AND HRZ MARKERS. JOB IN PROGRESS. 2/2/2015 PERFORATED FROM 6676'-6695'AND FROM 6661'-6671'WITH 2.5" POWERJET HSD 6 SPF 60 DEG PHASING CHARGES. JOB IN PROGRESS. 2/3/2015 PUMP 270 BBLS DIESEL DOWN TBG TO ESTABLISH AN INJECTION RATE OF 3.5 BPM AT 2900 PSI (JOB COMPLETE) 2/3/2015 SET BAKER 3.5"x4.5"THRU-TUBING WHIPSTOCK. TOP OF WHIPSTOCK AT 6625' RKB. SET 5 DEG ROHS. CCL TO TOP OF WHIPSTOCK = 15'. CCL STOP DEPTH 6610'. TWO PIP TAGS INSTALLED IN WHIPSTOCK AT 7632.35' RKB. JOB COMPLETE 2/9/2015 MEASURED BHP @ 6620' RKB; PERFORMED CLOSURE TESTED SSSV ( PASS) ASSIST VLV CREW IN SETTING 2-WAY CHECK FOR DHD/RIG. JOB COMPLETE. 2/9/2015 (PRE-CTD): (WC): POSITIVE TREE VALVE TESTS: MV(PASSED), SSV(PASSED), SV(PASSED) DDT'S MV (PASSED), SSV(PASSED), SV(PASSED) ConocoPhillips Time Log & Summary We!lview Web Reporting Report Well Name: 30-12 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 3/4/2015 8:00:00 AM Rig Release: 3/12/2015 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 33/04/2015 24 hr Summary MIRU CDR2 on 30-12. Perform initial BOPE test,test waived by AOGCC. Replaced failed HCR valve(B1)in progress. 00:00 03:15 3.25 0 0 MIRU MOVE MOB P Spot rig modules over 30-12 03:15 08:00 4.75 0 0 MIRU MOVE RURD P MIRU CDR2, berm cellar, Putz, interconnect, steam, and pre-spud checklist. 08:00 21:00 13.00 0 0 MIRU WHDBO NUND P Rig Accept 8:00 am, Nipple up stack /BOPE Test, Test witness waived by Lou Grimaldi,AOGCC 21:00 00:00 3.00 0 0 MIRU WHDBO BOPE T Troubleshoot failed HCR valve(B1). Replaced HCR valve. 3 HRS trouble time: Billable 33/05/2015 Complete initail BOPE test. Pulled TWC. Pumped slack management, cut 1,600'of coil. Rehead CTC, pull test to 31K.TIH w/BHA#1 milling assembly,dry tag whipstock @ 6,628'. Start milling dual string exit window as per well plan, in progress. 00:00 01:00 1.00 0 0 MIRU WHDBO BOPE T Complete HCR change-out. Load and retest B1, good test. BOP test complete. 1 HR trouble time: Billable 01:00 03:30 2.50 0 0 MIRU WHDBO MPSP P PJSM. LD BOP test equipment. PJSM. MU FMC lubricator, pull TWC, LD FMC equipment. 03:30 09:30 6.00 0 0 SLOT WELLPF CTOP P Pump slack management, cut 1,600' coil, Cut 33'pipe to find wire 09:30 11:00 1.50 0 0 SLOT WELLPF CTOP P Prep end of coil and install CTC, pull test to 31K 11:00 11:48 0.80 0 0 SLOT WELLPF CTOP P Test wire and head up UQC, PT CTC &UQC to 4000 PSI 11:48 12:54 1.10 0 0 SLOT WHDBO CTOP P Tighten/Adjust BOPE turnbuckles, Install Elevators 12:54 14:24 1.50 0 78 PROD1 RPEQP1PULD P PJSM, Close and test SSSV, all good, M/U BHA#1. 1.25°fixed bend WFT motor,2.80 window mill, 2.79 String reamer, 3 Magno star magnets.equalize well, OPen SSSV 14:24 17:00 2.60 78 6,628 PROD1 RPEQP1TRIP P RIH, EDC Open.Tie-in to K1 for zero foot correction, close EDC, PUW=27K. RIH,dry tag WS @ 6,628'. 17:00 17:45 0.75 6,628 6,628 PROD1 RPEQP1CIRC P PUH. Swap wellbore fluids to used mud system Page 1 of 6 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:45 00:00 6.25 6,628 6,636 PROD1 WHPST WPST P Start time milling WS as per well plan @ 1 fph. 1.50 BPM @ 3,775 psi, BHP=3920 psi, CTW=14.8K, WOB=2.5K. 33/06/2015 Complete milling operations to 6,646',back ream dual string exit window, clean drift. POOH and LD BHA#1, MU BHA#2. RIH w/build assembly. Drill build section from 6,646'to 6,800'. POOH for lateral assembly. LD BHA#2, MU BHA#3. RIH w/lateral drilling assembly to 6,800'. 00:00 02:00 2.00 6,636 6,638 PROD1 WHPST WPST P Continue window milling operations, 1.50 BPM @ 3,780 psi, BHP=3,915 psi, CTw-14.8K,WOB=.5K, ROP=2 02:00 04:45 2.75 6,638 6,646 PROD1 WHPST WPST P Continue milling rathole to 6,646'at 3 fph. 1.48 BPM @ 3,860 psi, BHP=3,895 psi, CTW=14.7K, WOB=1.2K, dirt across shaker. 04:45 06:15 1.50 6,646 6,646 PROD1 WHPST REAM P Make back reaming passes through window, 5R, 25L, 35R,dry drift 06:15 08:09 1.90 6,646 82 PROD1 WHPST TRIP P Trip out following MP schedule, 08:09 08:39 0.50 82 0 PROD1 WHPST PULD P At surface, PJSM close SSSV Lay down BHA#1 08:39 10:45 2.10 0 72 PROD1 DRILL PULD P Configure Build section BHA, M/U 2.5°motor with RB Huges Bi center with stay sharp cutters, M/U to coil and surface test 10:45 12:39 1.90 72 6,385 PROD1 DRILL TRIP P RIH EDC open 12:39 12:51 0.20 6,385 6,416 PROD1 DRILL DLOG P Log K1 for-.5' 12:51 13:09 0.30 6,416 6,646 PROD1 DRILL TRIP P Continue in hole, Stop at 6600 and close EDC. PUW=26K 13:09 16:15 3.10 6,646 6,720 PROD1 DRILL DRLG P 6646', Drill, 1.53 BPM @ 3570 PSI FS, BHP=3875. Couple stalls getting going. Start new mud down coil @ 14:10 Mud all around 15:30 16:15 16:21 0.10 6,720 6,720 PROD1 DRILL WPRT P BHA Wiper, PUW=26K 16:21 18:36 2.25 6,720 6,800 PROD1 DRILL DRLG P 6720', Drill, 1.53 BPM @ 3610 PSI FS, BHP=3920 18:36 20:45 2.15 6,800 73 PROD1 DRILL TRIP P POOH for lateral drilling assembly, tag up, close SSSV,flow check 30 mins. 20:45 22:15 1.50 73 73 PROD1 DRILL PULD P PJSM. LD BHA#2. PJSM. MU BHA #3,check pack-offs, blow down choke. 22:15 00:00 1.75 73 6,800 PROD1 DRILL TRIP P RIH w/lateral drilling assembly.7 AKO bend,tie-in to K1 for+2' correction,tie-in to RA tag @ 6,633', continue in hole. 33/07/2015 Drill ahead L1 lateral from 6,800'to 8,290',drilling in progress. 00:00 04:00 4.00 6,800 7,040 PROD1 DRILL DRLG P BOBD: 1.50 BPM @ 3,840 psi, BHP=4,010 psi, CTW=11.6K, WOB=1.8K, ROP=65. 04:00 04:30 0.50 7,040 7,040 PROD1 DRILL WPRT P Wiper to window, PUW=23K, RBIH. 04:30 07:12 2.70 7,040 7,290 PROD1 DRILL DRLG P BOBD: 1.50 BPM @ 3,825 psi, BHP=3,955 psi, CTW=12.6K, WOB=1.7K, ROP=70. Page 2of6 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:12 07:54 0.70 7,290 7,290 PROD1 DRILL WPRT P 7290',Wiper trip to 6660', PUW=24K, Clean up and down 07:54 09:42 1.80 7,290 7,540 PROD1 DRILL DRLG P 7290', Drill Ahead, 1.5 BPM @ _3600PS1 FS, BHP=3975 09:42 10:30 0.80 7,540 6,645 PROD1 DRILL WPRT P Wiper trip to TT 6397',Jet 4 1/2", PUW=24K 10:30 10:36 0.10 6,645 6,668 PROD1 DRILL DLOG P Log RA for+.5' 10:36 11:12 0.60 6,668 7,540 PROD1 DRILL WPRT P Continue wiper trip in to drill, Clean trip up and down 11:12 11:54 0.70 7,540 7,657 PROD1 DRILL DRLG P 7540', Drill ahead, 1.49 BPM @ 3570 PSI FS, BHP=3965, Had some high speed drilling intervals to get DLS need to stay in polygon 11:54 12:00 0.10 7,657 7,657 PROD1 DRILL WPRT P BHA Wiper, PUW=25K 12:00 14:36 2.60 7,657 7,790 PROD1 DRILL DRLG P 7657 Drill, 1.48 BPM @ 3570 PSI _FS, BHP=4045 14:36 15:36 1.00 7,790 7,790 PROD1 DRILL WPRT P 7790',Wiper to 6960, PUW=25K 15:36 18:00 2.40 7,790 8,040 PROD1 DRILL DRLG P 7790', Drill, 1.48 BPM @ 3570 PSI FS, BHP=4000, 18:00 19:06 1.10 8,040 8,040 PROD1 DRILL WPRT P Wiper to 6,800', PUW=25K, RBIH. 19:06 21:54 2.80 8,040 8,290 PROD1 DRILL DRLG P BOBD: 1.50 BPM @ 3,840 psi, BHP=4,085 psi, CTW=11.8K, WOB=1.4K, ROP=90. 21:54 00:00 2.10 8,290 8,290 PROD1 DRILL WPRT P Wiper for tie-in, PUW=26K, RA tie-in +1.5'correction. RBIH. 03/08/2015 Drill ahead L1 lateral to called TD @ 9,150'. Pump 10 bbl sweeps and chase to 5,400', pump bottoms up. RBIH for corrected TD @ 9,150'. Pump beaded pill and POOH.Tag up,shut SSSV,bleed off WHP, no flow check. 00:00 04:39 4.65 8,290 8,540 PROD1 DRILL DRLG P BOBD: 1.50 BPM @ 3,830 psi, BHP=4,055 psi, CTW=10.5K, WOB=1.9K, ROP=40. Start mud swap, new mud at bit 8,330'. 04:39 05:45 1.10 8,540 8,540 PROD1 DRILL WPRT P Wiper trip, PUW=26.5K, RBIH. 05:45 09:51 4.10 8,540 8,825 PROD1 DRILL DRLG P 8540', Drill, 1.5 BPM @ 3590 PSI FS, BHP=4080 09:51 10:45 0.90 8,825 8,825 PROD1 DRILL WPRT P 8825',Wipe rto 7820, PUW=25K, Clean trip up and down 10:45 12:27 1.70 8,825 8,990 PROD1 DRILL DRLG P 8825', Drill, 1.48 BPM @ 3590 PSI FS, BHP=4015 12:27 13:21 0.90 8,990 8,990 PROD1 DRILL WPRT P 8990',Wiper to 8140, PUW=26K 13:21 16:15 2.90 8,990 9,150 PROD1 DRILL DRLG P 8990', Drill, 1.49 BPM @ 3600 PSI FS, BHP=4055 16:15 16:57 0.70 9,150 9,150 PROD1 DRILL WPRT P Called TD @ 9150, Pump 10 X 10 Sweeps, recip pipe 16:57 18:48 1.85 9,150 5,400 PROD1 DRILL WPRT P Sweeps out, Chase to 5,400', pump btms up. 18:48 21:00 2.20 5,400 9,150 PROD1 DRILL TRIP P Decide to RBIH. Tie-in to K1 for+1' correction,continue in hole,tag corrected TD @ 9,150'. 21:00 23:30 2.50 9,150 72 PROD1 DRILL CIRC P Start pumping beads. POOH, paint EOP flags at 7,500'and 4,900'. Continue OOH,tag up, close SSSV. 23:30 00:00 0.50 72 72 PROD1 DRILL OWFF P No flow check 30 minutes. Page 3 of 6 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/09/2015 24 hr summary MU L1 lateral liner assembly. Set L1 liner assembly©9,130', release from liner. POOH and PUD BHA#4. PD BHA#5. RIH w/drilling assembly, kick-off billet @ 7,601'. Drill ahead L1-01 lateral to 7,884',drilling in progress. 00:00 01:30 1.50 72 0 PROD1 DRILL PULD P PJSM. LD BHA#3. Clear floor, prep to run iner. 01:30 03:15 1.75 0 1,520 COMPZ CASING PUTB P PJSM. MU L1 liner assemby. Bull nose,48 jts slotted, and OH anchored billet. 03:15 04:39 1.40 1,520 1,592 COMPZ CASING PULD P PJSM. MU BHA#4 04:39 06:45 2.10 1,592 6,493 COMPZ CASING RUNL P RIH w/L1 liner assembly, EDC Open Pump min rate 06:45 06:57 0.20 6,493 6,491 COMPZ CASING DLOG P Correct to flag for-1.7', PUW=25K, Shut down pump, close EDC 06:57 07:33 0.60 6,491 8,170 COMPZ CASING RUNL P Continue in hole, clean pass through _ window 07:33 07:45 0.20 8,170 8,191 COMPZ CASING DLOG P Log RA for+1'correction 07:45 08:03 0.30 8,191 9,130 COMPZ CASING RUNL P Continue in hole, Get to set depth 9129.88, PUW=27K, Orient to 150R, See tool shift at 4400PS1, Set down 4K, PUH and reset depth 08:03 09:51 1.80 7,580 65 COMPZ CASING TRIP P Trip out 09:51 12:27 2.60 65 0 COMPZ CASING PULD P At surface, PJSM, PUD BHA#4 Liner running tools, Lay down and load out setting tool 12:27 13:33 1.10 0 72 PROD2 STK PULD P PJSM, PD BHA#5 with .9°motor and RR bit, Check packoffs and UQC floats, M/U to coil and surface test tool. 13:33 14:45 1.20 72 6,390 PROD2 STK TRIP P RIH, BHA#5, EDC open, pumping 14:45 14:51 0.10 6,390 6,415 PROD2 STK DLOG P Log K1 for zero correction, PUW=25K 14:51 17:15 2.40 6,415 6,415 PROD2 STK TRIP T Move pipe,waiting on permit to drill 17:15 17:30 0.25 6,415 7,601 PROD2 STK TRIP P Continue in hole,dry tag billet. 17:30 19:15 1.75 7,601 7,603 PROD2 STK KOST P Time mill off billet as per wellplan, off billet @ 7,603'. 19:15 19:54 0.65 7,603 7,640 PROD2 DRILL DRLG P Drill to establish WOB, 1.50 BPM @ 3,880 psi, BHP=4,010 psi, CTW=12.5K,WOB=.2K. PUW=24K. PUH,dry drift billet, clean. 19:54 22:21 2.45 7,640 7,840 PROD2 DRILL DRLG P DOBD: 1.50 bpm @ 3,890 psi, BHP=4,015 psi, CTW=13K, WOB=1.2K, ROP=80. 22:21 23:30 1.15 7,840 7,840 PROD2 DRILL WPRT P Wiper trip to 6,680', PUW=26K, RBIH. 23:30 00:00 0.50 7,840 7,884 PROD2 DRILL DRLG P DOBD: 1.50 bpm @ 3,880 psi, BHP=4,018 psi, CTW=12.5K, WOB=1.4K, ROP=80. 33/10/2015 Drill ahead L1-01 lateral from 7,884'to called TD @ 9,100'. Pump sweeps and jetted 4.5"liner @ 6,394'. RBIH to 9,100', POOH laying in beaded liner pill, in progress. Page 4 of 6 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:27 2.45 7,884 8,090 PROD2 DRILL DRLG P DOBD: 1.50 bpm @ 3,880 psi, BHP=4,030 psi, CTW=9.5K, WOB=1.9K, ROP=80. 02:27 03:27 1.00 8,090 8,090 PROD2 DRILL WPRT P Wiper trip to 7,000', PUW=26K, RBIH. 03:27 07:18 3.85 8,090 8,340 PROD2 DRILL DRLG P DOBD: 1.49 bpm @ 3,930 psi, BHP=4,040 psi, CTW=9.5K, WOB=1.6K, ROP=85. 07:18 09:27 2.15 8,340 8,340 PROD2 DRILL WPRT P Wiper trip to 6,420', PUW= 25K, Tie into K1 marker for+1.5 correction. RBIH 09:27 11:57 2.50 8,340 8,590 PROD2 DRILL DRLG P Drill @ 8,340', 1.50 bpm @ 3,798 psi, BHP=3,988 psi, CTW=10.8K, WOB=1.02K, ROP=97 fph 11:57 12:45 0.80 8,590 8,590 PROD2 DRILL WPRT P Wiper trip to 7,740-ft, PUW 26k, RBIH. 12:45 15:45 3.00 8,590 8,590 PROD2 DRILL DRLG P 8,590-ft, OBD 1.48 bpm at 3788 psi, BHP 4027 psi, CWT 10.2k,WOB .8k, ROP 100 fph 15:45 16:51 1.10 8,840 8,840 PROD2 DRILL WPRT P Wiper trip to 7,700-ft, PUW 28k, RBIH. 16:51 19:48 2.95 8,840 9,100 PROD2 DRILL DRLG P 8,840-ft, OBD 1.48 bpm at 3757 psi, BHP 4104 psi, CWT 8.7k,WOB .8k, ROP 100 fph. Pump 10 bbl sweeps. 19:48 21:48 2.00 9,100 6,650 PROD2 DRILL TRIP P POOH to 4.5",jet liner max rate. 21:48 23:06 1.30 6,650 9,101 PROD2 DRILL DLOG P Tie-into RA tag for+2'correction. RIH for corrected TD depth @ 9,101'. 23:06 00:00 0.90 9,101 8,000 PROD2 DRILL CIRC P POOH laying in beaded liner pill. 03/11/2015 Continue OOH laying in beaded liner pill. Run L1-01 two segment liner assembly from 6,620'to 9,100'. Swap well over to seawater from 6,585'. POOOH to 2,500'. Freeze protect with diesel from 2,500'. LD BHA#7. Set BPV. 00:00 02:06 2.10 8,000 72 PROD2 DRILL CIRC P Continue OOH laying in beaded liner pill, paint EOP flags @ 7,399'and 5,000', continue OOH. On surface, close SSSV, bleed down WHP. 02:06 02:36 0.50 72 72 PROD2 DRILL OWFF P Monitor well for flow 30 minutes, no flow. 02:36 03:18 0.70 72 0 PROD2 DRILL PULD P PJSM. LD BHA#5, prep floor to run liner. 03:18 06:54 3.60 0 1,564 COMPZ CASING PUTB P PJSM. MU L1-01 lower liner segment: Bullnose,48 jts slotted liner(511),shorty deployment sleeve. MU BHA#6 06:54 08:48 1.90 1,564 7,890 COMPZ CASING RUNL P RIH with L1-01 lower liner assembly, Tie in to EOP flag, minus 2-ft correction, PUW 26k, continue in hole pumps off. 08:48 08:57 0.15 7,890 7,910 COMPZ CASING DLOG P Tie in to K1 marker, plus 1-ft correction. 08:57 09:21 0.40 7,910 9,101 COMPZ CASING RUNL P Continue in hole pumps off to 9,101-ft, PUW 27k, SO 3k, release off liner, PUW 23k, reset counter to BHA depth 09:21 11:15 1.90 9,101 45 COMPZ CASING RUNL P TOOH from 7,580-ft with BHA#6, paint flag at 5,500-ft. Page 5 of 6 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:15 11:45 0.50 45 45 COMPZ CASING OWFF P Close SSSV, monitor well for flow 30 minutes, no flow. 11:45 12:33 0.80 45 0 COMPZ CASING PULD P PJSM. LD BHA#6, prep floor to run liner. 12:33 14:12 1.65 0 961 COMPZ CASING PUTB P PJSM, MU L1-01 upper liner segment, bullnose,XO, 30 jts slotted liner(511),XO, 7.61-ft pup joint, shorty deployment sleeve. 14:12 15:00 0.80 961 1,005 COMPZ CASING PUTB P PJSM, MU BHA#7 to L1-01 upper liner assembly, MU to CoilTrak, surface test. 15:00 16:42 1.70 1,005 7,320 COMPZ CASING RUNL P RIH with L1-01 upper liner assembly, Tie in to EOP flag, minus 2.39-ft correction, PUW 25k, continue in hole. 16:42 17:00 0.30 7,320 7,581 COMPZ CASING DLOG P Tie in to K1 marker, plus 1-ft correction, continue in hole 17:00 17:09 0.15 7,581 7,581 COMPZ CASING RUNL P 7,581-ft,Tag up, PUW 25k, release off upper liner, PUW 23k, reset counters to BHA depth,top of liner at 6,621-ft 17:09 18:00 0.85 7,581 7,581 COMPZ CASING DISP P Swap hole to seawater 18:00 20:30 2.50 7,581 73 COMPZ CASING DISP P POOH to 2,550'. PJSM. Pump 30 bbls diesel,freeze protect from 2,500'. 20:30 22:30 2.00 73 0 COMPZ CASING PULD P PJSM. PUD BHA#7, LD BHA. 22:30 00:00 1.50 0 0 DEMOB WHDBO MPSP P PJSM. RU FMC Lubricator and test. Set PBV. LD FMC equipment. Final WHP @ 995 psi. 03/12/2015 Blow down reel with nitrogen. Start reel swap opeations. Rig released at 12:00 00:00 04:00 4.00 0 0 DEMOB WHDBO RURD P Show orientation video to SLB crew. Hold PJSM with SLB N2 crew,flush stack, prep for N2 purge. Blow down coil reel and surface equipment. RDMO SLB crew. 04:00 08:00 4.00 0 0 DEMOB WHDBO RURD P PJSM. Remove inner reel iron, remove E-Line bulkhead,cut BHI QC, Inj head counter, CTES counter. 08:00 12:00 4.00 0 0 DEMOB WHDBO RURD P PJSM. Unstab coil tubing injector and secure coil spool for shipment, hook up reel bridge crane, remove reel hubs, Page 6 of 6 • ra L•�_ ieg2 N a. I C A.. Cis' O Q co 0 w W ce a 1— ,, a. co Z > •— a i. _ .— cn ...... .— t d. C) w V O > 0 a ,� r 0 v M •- N C O Y � � N 4) C FI, to= L V 0 a a 4 ttf a) a ,. coN j COr Mil O ci F.,. c �O s. T N O F o O O N N LL ' Q. Q. 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V (0 M N- r U) 0) CO N U) O U) U) N- CO M U) (0 o 0 0 0 0 (0 0 U) N 0 r V V co .- .- .- O .- (0 co co NN N co N co r CO CO r r N N N CO CO 11.‘ N N : (0) O O o O 0) O O O O O O O O O O O O O O O o o O O O O O Nj V r 0 N CO 0 N (0 CO V N- 0 M (0 0 N U) CO A- V N- 0 CO CO 0 N U) O C C a; 13 y U1 h U1 U )O o O r r r CO CO CO 0 0 0 0 0 O O N N N N M CO CO V `O O V a) 2 0 N r r r r r r r r r N 00 07 0s 00 N 0 N 00 0 0 CO 00 00 O E o :' m a .� a a` co 3 3 a CO �b _ .- q 1lk co Lci u) O 0 c O 1 Q U 1 d E o ea F- Z o o0 o I— F) • a N N N N N N N N N N N N N N N N N N N N N N N V W Innmmr OWrry N (nmrN (N� (NNUmM rnMMNrnr O i Rcs NN O U) W N (0 O N N (O r W O N M (0 W (0 0) M N U) •` UL N N co OV OO) O co O 0 N N r O NNNNMU)) 1.-- cCsl N ; C CO CO CO ) 0) 0) O O CO7 r r r r CO , Nr N N N N N N N N N (sN N N N N N N C co Q x , tN9NN r r a 0r) M U) O N (M N O N- M N U N UNNN) (0 N-MNO N UO w C ee O 0 Z UJ (- 0 O 7 r CO 7 N V N U) 6 N N U) U) C') N c0 co N U) (O N (O co O Q CV �0`cri (��()\\ U y �. fig[ 0 V G E u CO (N N Q W U) N CO N- O 0 0 N CO M N N N- N 0 U) CO N 7 (O N- 1,-- 7 r O t` CO r r r 0) CO CO OO O 0) r co co M N O] WO O U) 7 O 0 3C OI N0 M OM O0 1'.N NM rM V r‘r-7-. OO) ((N (0 (O(O co': (O( Om ON (OM cod M' LU N N N MM - W QC O OO 0) MO) OO m0O) OO) O) OMW co O armor O O) .. N NN N N N NN N N N N N N co- NNNNNNN(0 U) UUUUUUUUUUUUN) UUUU) U) U) UU) UUUy • • pnp t 0 0. m NU -a (0 U) N LOM r N 0 N O M O N U) N M N U) (0 M N U) O) N` N ` U V (0 - 0) N N U) CO (0 0 N� O] CO N (0 N V r--- U) O V V 1•••• N LL L a) N CO CO O M N N 7 N (V N M W 0) O (O O] 7' w Q ) C m M r r Or ((00 O (NO (00 2 L. OU 7 7 V M M M N N N N O) � � N . O O O O N O= �� O O O N O O O O O O O O N O O O O O _ N c ,, O 0 O O O O O O O O O O O O 0 0 0 0 0 0 0 0 0 O 0 Z (O U) N (O (O N N (O N (O N N (o CO- M. (D CO: N CO: (O co- ( N c0 _ NA .. :. 0 -• v a) 0 a. b Nu > a i v _ Las 4 C G ) W y C_1 24 0) U) N N N 00 03 U) 00 M m M M N W O V N O N (O Q NN` 0 V MCC/ COMM N U) r 0 N r U) r M N 07070 U cll d L d S ? N M co. (() N (OO r N- N O W W O W O r.: O O O Or) O u-5 O M Q t0 0 a Z @ ''�, • ,�' (0 co (0 co co co (O co co co co co (O (O (O co_ co (O co (0 1- r r r JU > 0 0 o co F- E 2 0) 0 W V , , , , , , , , , , , , , , , , , , , , , , , , S •, - 0) N M O) M 0) N N- O N- O M MCDMCVLO M (O O) (O r II 0107 M M O) (O (O U) (0 N M O7 0 N 0) n V (O M (O r M W •-• O co n: U) (0 ni N) (h M N U) N N N M N N N N0 N N (O (n LON- 7 NI- 037 .0- N- O M (O M N U) O V N- O M M O) V • ( V Cr., Cr., 0 0 0 _ _ N N N N CO CO CO V N V U) U) U) U) CO (O I O O r N N- 7 0 O N- M V N- N (O CO CO CO O) N CO 7 CO V M , O V CO V r Cr) CO O] 7 N N V CO r CO U) (O N N CO r O 0 CO (n r 0) NU) m6 N M co N6 O) O O M N O V 0) V r V (n ,0 V V U) U) U) (O U) M co co co co O r N` r r co co co 0) O O O U) U) U) U) U) U) U) U) U) U) U) U) U) U) U) U) U) U) U) U) U) CO CO CO 0O CO- O CO- CO- CO- CO- N (O CO- CO' CO- Co' N (0 CO- 0 (0 CO- M CO- CO- CO- (O (V O O N- N N- O O 1- M N N V (0 ro M (0 O N N M N M i d O N (O V r co M co r N N V CO 7 M U) U) N N CO r O O CO S Y & Q (O N r N N 0) N <6 N- N N N6 O N U) O M N M O (O M O O N N N N N N N N CO CO M CO N N O O CO N ` ✓ , COCOc0 COCOCOco (0 cococo (0 COCO (0 (O ` CO 5/ (O (0 (O U 0 (O CO- (0 (O (O (O (O (O (O (O (O (O (O co O co- co- co- co- co- M co- co- (O C (0 Y N � co co N- 0 0) M CO (O N r M 0 0 (O CO CO CO V U) U) Q ''-c � CO r U) CO CO M N- N U) U) V 0 U) CO co. O U) r N co N 0) 0) ------ -p Qi (0 M O 6 n ti U) M (V Nd N) V (0 n r N N (O Q ^ O 0) 0) O m W O W OO 0 00 O r 00 O W O] 0 W N O M M CO CO Q N d — N Ha i52 01 0� U 01, :-_-e _ _ U N N N (O 00 p N- U 0 N- 0 M N 0) V U) m (O N U) 0 0 0 t 0 N N N O M 00 CO c- N 0) N 0) N U) N CO U) r V CO N- O O) O (0 O) Qi 0) 0• 0 ^ U) U) Ui V U) M ( (O U) N (0 V Ni N N6 N (O V V i.S U Y Y 0 0 C :.. ro (0 M (O M 00 M 00 0 00 00 00 m 00 W 00 00 M W W N N- N- N co no Q. oco NU (0 co O N O 0) CO N UN 00 CO 7 0) UCO (O W U 0 h- Ur 0 = V r CO O r r N Ur 01 CO r CO CO O UV V O V V V r O (n 0 OO O O N O O O O O O O O O OO O O O UUUO O V r V CO V r O M 0 m N UV f` 0 CO M O N UNj >•• DyVVUUUCO CO CO r r r r N O N m O) O O O O O r r O A 4-..Q OD) d co-V O] co- co- N N N co- co- N co- N N N co- co- co- co- m O V Ead •Nwa o a in o (n ' 0 215003 RECEIVED 2 1 5 0 4 7 Letter of Transmittal MAR 12 2015 VPUC 25 5 1 4 25 5 1 5 Date: AOGCC DATA LOGGED March 11, 2015 3i►ti2o►5 HUGHES M.K.BENDER To: From: Makana Bender Yosha Ragbirsingh/Michael Soper AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 30-12L1 30-12L1-01 (2) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. 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CID CO CO Oi O N CCOD O) M m CM 0p CCpp M O �Qp N N N N N N N N M M Ch M V V U) (D (2 N- (A M (O (O U) CO CO CO CO CO CO U) CD CO CO CO CO CO CO CO CO CO CO CO CO ✓ 7 co- 0 CO U) CO (O (O CO- CO (O CD CO- CO CO U) (O (O co- (O CO CO U) CO CO C Y co N �. M m nU) C) O M (O M n NU) N- O O M C U) O M) aV U) V W OQ C v of C(Dp a) o O) N: n C1 a) N m o ct (+) (d n 0 0 C() (u N O N ^ O fA m O) !n m lD m m m m W n m m OD m l2 m m m m CD a `m a C e� 2 /� a E cn i! 8 2 Y J N N N "' 2 ' 8882 O O M N O) U) O) (� 0 co N N CA N m V U) 8 O Cn /_. C 0. a U 6 U) U) U) U) CO h ((pp U) CO O) O) O) CO COM N N CJ ND (O R N y o 0 0 0 0 0 C °`.. CO CO OD GO CD CO CO CO CO CO CO CO CO CD CO GO (O CO CO CO N- N. N- N� VI CO GO Z CL in CD _ _ _ tisi o V V m 10 N CO CO CO CO N Om) co. CO M M O N V CO O 0 N- 7 0 Ill O 0 0 0 o N o 0 0 p 0 0 . 0 Ci o u) u) o o iV V 14 V 2) n O M CO N- N U) W 8 0) O M (O N • C .. d .. y V V CO U) U) (O U) f� r f� t` (D m m W O O O O oU U _ 2 vCO- CO CO- CO- CO- CO- CO- CO- CO- W [ CO- CO- m CO- O1 ¢� m A O of co •y = i j N E• O y N N N o a u) o to �- S I1/j THE STATE Alaska Oil and Gas (�-s����, of LASI�:A Conservation Commission __=_ A 333 West Seventh Avenue Anchorage, Alaska 99501-3572 �*h GOVERNOR BILL WALKER 9 o . Main: 907.279.1433 ALAS1 Fax: 907.276.7542 www.aogcc.alaska.gov D. Venhaus CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 30-12L1 ConocoPhillips Alaska, Inc. Permit No: 215-003 Surface Location: 1019' FNL, 2011' FWL, SEC. 22, T13N, R9E, UM Bottomhole Location: 2622' FSL, 294' FWL, SEC. 22, T13N, R9E, UM Dear Mr. Venhaus: Enclosed is the approved application for permit to redrill the above referenced service well. The permit is for a new wellbore segment of existing well Permit No. 188-041, API No. 50-029- 21804-00-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter '25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy P. oerster Chair DATED this 3 day of January, 2015. RECEIVED STATE OF ALASKA 1 A N 0 2 ?015 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL AOGCC 20 AAC 25.005 la Type of Work 1 b Proposed Well Class Development-Oil ❑ Service-Winj ❑ Single Zone 0 .1c Specify if well is proposed for Drill ❑ *Lateral C Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone El Coalbed Gas ❑ Gas Hydrates❑ Redrill El Reentry❑ Exploratory ❑ Service-WAG ❑✓ • Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name 5 Bond: U Blanket U Single Well 11 Well Name and Number ConocoPhillips Alaska, Inc. , Bond No. 59-52-180 - KRU 30-12L1 3.Address 6.Proposed Depth 12. Field/Pool(s)' P.O. Box 100360 Anchorage,AK 99510-0360 MD:9125 - TVD: 6629' ' Kuparuk River Field ' 4a Location of Well(Governmental Section) 7 Property Designation(Lease Number): Surface: 1019'FNL,2011'FWL,Sec.22,T13N, R9E, UM , ADL 25513 • Kuparuk Oil Pool Top of Productive Horizon 8 Land Use Permit 13 Approximate Spud Date. 1235'FNL, 1858'FWL,Sec 22,T13N, R9E,UM 2554 1/19/2015 Total Depth 9.Acres in Property 14.Distance to 2622'FSL,294'FWL,Sec.22,T13N, R9E,UM 2560 . Nearest Property 3397 4b.Location of Well(State Base Plane Coordinates-NAD 27) 10.KB Elevation above MSL: 59 feet 15.Distance to Nearest Well Open Surface:x- 525648 ' y- 6021801 • Zone- 4 i GL Elevation above MSL 24 feet to Same Pool: 30-11 ,1445 16 Deviated wells Kickoff depth' , 6625 ft. 17 Maximum Anticipated Pressures in psig(see 20 AAC 25 035) 3 y k ?11.3 Maximum Hole Angle 103° deg Downhole:4095 psig • Surface:3850 psig 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) 3" 2.375" 4.7# L-80 ST-L 2505' 6620' 6579' 9125' 6629' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft) Total Depth TVD(ft) Plugs(measured) Effective Depth MD(ft) Effective Depth TVD(ft) Junk(measured) 7005' 6956 none 6875 6827 none Casing Length Size Cement Volume MD TVD Conductor/Structural 74' 16" 175 sx AS I 110' 110' Surface 4071' 9.625" 1500 sx AS III,300 sx CI G, 4106' 4100' 150 sx AS I Liner 517' 4 5" scab liner 6876' 6827' Production 6924' 7" 360 sx Class G, 175 sx AS I 6957' 6909' Perforation Depth MD(ft): Perforation Depth TVD(ft). perfs cemented off perfs cemented off 20.Attachments. Property Plat❑ BOP Sketch❑ Drilling Progran- Q Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25 050 requirements 0 21.Verbal Approval Commission Representative. Date: 22 I hereby certify that the foregoing is true and correct. Contact Ron Phillips @ 265-6312 Email on.L.PhillipsCo�cop corn Printed Name D. nhau Title CTD Engineering Supervisor Signature ,t`ice Phone:265-6120 Date 12-3/--/ Commission Use Only Permit to Drill API Number Permit Approv // See cover letter Number c215—o0 3 50-o aq- a) go-6 0 —oti Date' ( I ) I r✓ ) for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed m thane,gas hydrates,or gas contained in shales d Other: 3)p --�,5 f to 4 000 175 ) o� SSamples req'd: Yes ❑ No L Mud log req'd: Yes❑ No[v]� s-r i- v/4 r pre-vev,try fryt to zS H2S measures: Yes [✓r No ,❑ Directional svy req'd: Yes Di No❑ �1`a 1-i wr tots 5Z- /M l T 7_1• Spac�in exc tion req'd: Yes L� Inclination-only svy req'd. Yes❑ No 2 rectviy-c64 c,e..,5 5Z- tido r 1r3rI'etc)ecrc� _q ❑ No Approved by: CO M N SiON Date: /� /3 /.5 Form 10-401 ( vised 10/2012) This permit is va id or 2 months rom the a e of approval(20 AAC 25.005(g)) -1144 I��IS �7/ ,767/s7- , ConocoPhilli s p Alaska RECEIVED P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 JAN 0 2 2015 December 31, 2014 AOGCC Commissioner- State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an application for perr9it to drill a single-lateral out of the Kuparuk Well 30-12 using the coiled tubing drilling rig, Nabors CDR2-AC. The work is scheduled to begin late January 2015. The CTD objective will be to drill one lateral (30-12L1), targeting the A sand intervals. Note the current A sand perforations will be open below the whipstock. / Attached to this application are the following documents: - Sundry application to re-perforate the A-sand - Permit to Drill Application Form 10-401 for 30-12L1 - Detailed Summary of Operations - Directional Plan - Proposed Schematic If you have any questions or require additional information please contact me at 907-265-6312. Sincerely, 64' Ron Phillips Coiled Tubing Drilling Engineer ASALASKA o.,�DrillingKuparuk CTD Lateral NABO,�CIJ` &Wells 30-12L1 Application for Permit to Drill Document AC 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(1)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 5 (Requirements of 20 AAC 25.005(c)(13)) 5 Summary of Operations 5 Pressure Deployment of BHA 6 Liner Running 6 14. Disposal of Drilling Mud and Cuttings 6 (Requirements of 20 AAC 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 7 (Requirements of 20 AAC 25.050(b)) 7 16. Quarter Mile Injection Review (for injection wells only) 7 (Requirements of 20 AAC 25.402) 7 17. Attachments 7 Attachment 1: Directional Plan for 30-12L1 7 Attachment 2: Current Well Schematic for 30-12 7 Attachment 3: Proposed Well Schematic for 30-12L1 7 Page 1 of 7 iU R 1 GINA ! 12/31/2014 PTD Application: 30-12L1 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed lateral described in this document is 30-12L1. This lateral will be classified as a "Service — Water Alternating Gas Injection"well. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This lateral will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 30-12L1. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036, for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 40.00 psi. Using the maximum formation pressure in the area of 4,095 psi in the 30-16A, the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 3,443 psi. See the "Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005(c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005(c)(4)(a)) The last pressure survey from October 18, 2014 for 30-12 was a combined Kuparuk A & C sand, and measured 3950 psi (11.4 ppg EMW). The final mud weight used during the 30-12 rig work over in November 2014 was 11.8 ppg and the well was on a slight vac. An updated pressure survey will be obtained on the Kuparuk A-sand only before Coiled Tubing Drilling operations begin. The C-sand is isolated via a cemented scab liner. The maximum downhole pressure in the 30-12 pattern is to the southwest with the 30-16A injector at 4095 psi V (12.1 ppg EMW). It is unlikely we will see this pressure because it is on the other side of a large sealing fault. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) No specific gas zones will be drilled, but 30-07, 30-12, 30-14 and 30-17 have injected gas into this area so there is a risk of encountering gas. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The largest, expected risk of hole problems in the 30-12L1 lateral will be shale instability across the faults, managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossing. Close approaches The 30-12L1 lateral has no close approach issues. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) N/A for this thru-tubing drilling operation. According to 20 AAC 25.030(t), thru-tubing drilling operations need not perform additional formation integrity tests. Page 2 of 7 ORIGINAL 12/31/2014 PTD Application: 30-12L1 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Liner Top Liner Btm Liner Top Liner Btm Lateral Name Liner Details MD MD TVDSS TVDSS 2%", 4.7#, L-80, ST-L slotted liner; 30-12L1 6,620' 9,125' 6,515' 6,570' contingency blank liner across belly section, deployment sleeve on top Existing Casing/Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (ppf) MD MD TVD TVD psi psi Conductor 16" 62.5 H-40 Welded 36' 110' 36' 110' 1,640 630 Surface 9-5/8" 36.0 J-55 BTC 35' 4,106' 35' 4,100' 3,520 2,020 Casing 7" 26.0 J-55 BTC 33' 6,957' 33' 6,852' 4,980 4,320 Scab Liner 4-1/2" 12.6 L-80 BTC 6,359' 6,876' 6,258' 6,771' 8,430 7,500 Tubing 3-W 9.3 L-80 EUE 33' 6,393' 33' 6,292' 10,160 10,530 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) N/A for this thru-tubing drilling operation. Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System Diagram of Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System - Window milling operations: Chloride-based FloVis mud (9.6 ppg) - Drilling operations: Chloride-based FloVis mud (9.6 ppg).' While this mud weight may not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. - Completion operations: Well 30-12 does contain a subsurface safety valve (SSSV). The subsurface safety valve will be used for isolation and if the valve fails the well will be loaded with 11.8 ppg NaBr completion fluid in order to provide formation over-balance while running completions. - Emergency Kill Weight fluid: Two well bore volumes (-162 bbl) of 12.2 ppg NaBr emergency kill weight fluid will be within a short drive to the rig during drilling operations. Page 3 of 7 0RIGINAL 12/31/2014 PTD Application: 30-12L1 Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the openhole formation throughout the coiled tubing drilling (CTD) process. Maintaining a constant BHP promotes wellbore stability, particularly in shale sections, while at the same time providing an overbalance on the reservoir. Through experience with drilling CTD laterals in the Kuparuk sands, 11.8 ppg has been identified as the minimum EMW to ensure stability of shale sections. Since this well is kicking out into the B2 shale turning south-west and building inclination to land in the Al and crosscut up into the A3, we plan to hold 11.8 ppg at the window for stability. The constant BHP target will be adjusted to maintain overbalanced conditions if increased reservoir pressure is encountered during drilling. The constant BHP target will be maintained utilizing the surface choke. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Pressure at the 30-12 Window(6625' MD, 6520' TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A+C-sand Formation Pressure (11.4 ppg) 3865 psi 3865 psi Mud Hydrostatic (9.6 ppg) 3255 psi 3255 psi Annular friction (i.e. ECD, 0.090 psi/ft) 596 psi 0 psi Mud + ECD Combined 3851 psi 3255 psi (no choke pressure) (underbalanced (underbalanced —14 psi) —610 psi) Target BHP at Window(11.8 ppg) 4001 psi 4001 psi Choke Pressure Required to Maintain 150 psi 746 psi Target BHP 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an exploratory or stratigraphic test well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Page 4 of 7 ORIGINAL 12/31/2014 PTD Application: 30-12L1 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well 30-12 was a Kuparuk A-C sand injection well. A rig work-over was recently performed. A 4-1/2" scab liner was cemented in place across all A-C sand perforations.They also replaced the existing tubing and packers with a new 3-1/2"tubing completion. During that workover, a variance was granted for setting the packer over 200' away from the uppermost A-sand perforation. One lateral will be drilled to the southwest of the parent well. These laterals will access reserves in the Al,A2 and A3 sands. , » - whip-stockkickof A Baker Hughes Thru-Tubing will be set inside the 4 /Z liner at theplannedoff point g g 6625' MD. The 30-12 lateral will exit through the 4-1/2" scab liner by 7"casing at 6625'MD and TD at 9125' MD. The 2 3/8"slotted liner completion will be run from TD up to 6620' MD,five feet above the whipstock. Pre-CTD Work 1. RU Slickline: RIR and tag fill. 2. RU Service Coil: Perform a FCO down to 6811' MD to remove drilling mud. Swap well to diesel. 3. RU E-line: Re-perforate A-sands at 6661'-6671', 6676'-6700' &6712'-6732'. 4. RU E-line: Set Baker Hughes 4-1/2"Thru-Tubing Whipstock at 6625' MD. 5. Prep site for Nabors CDR2-AC, including setting BPV. Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 30-12L1 Lateral(Al,2&3 sands) a. Mill 2.80"window at 6,625' MD. b. Drill 3"bi-center lateral to TD of 9,125' MD. c. Run 2%"slotted liner from TD up to 6,625' MD,just above top of whipstock. 3. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV. 2. Install GLV's(if needed). 3. One month flowback for cleanup,then return to injection. Page5of7 0 R I G 1 NIA L 12/31/2014 PTD Application: 30-12L1 Pressure Deployment of BHA The planned bottomhole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. Because of this, MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slickline lubricator. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running — The subsurface safety valve will be used for isolation and if the valve fails the well will be loaded with 11.8 ppg NaBr completion fluid in order to provide formation over-balance while running completions. — While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal.✓ • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18 or 1B disposal facilities) or Prudhoe DS-4 if a Kuparuk facility is unavailable. / • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). Page 6of7 l L 12/31/2014 PTD Application: 30-12L1 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plan — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire open hole section./ — Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 30-12L1 3,397' — Distance to Nearest Well within Pool Lateral Name Distance Well 30-12L1 1,445' 30-11 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) There are no wells within 1/4-mile of the 30-12L1 well plan. 30-12 (mother bore) Injector • Completed with 7", 26#, J-55 casing on 6/03/1988. • Classified as a "Normal Well"with a recent Rig Work-Over • C-sand perforations: 6611'-6621' MD (behind scab liner and cemented). • A-sand perforations: 6636'-6640' MD, 6661'-6671' MD, 6676'-6700' MD and 6712'-6732' MD (behind scab liner and cemented). • Plan to re-perforate the A-sand perforations pre-rig before drilling the 30-12L1 lateral. • During the Dec. 2014 workover, a variance was granted for setting the packer over 200' away from the uppermost A-sand perforation. Packer is located at 6359' MD. • The cement bond log shows adequate cement as per original injection order. The proposed kick-off point for the CTD sidetrack is in the A-sand perfs and should not compromise existing conformance. 17. Attachments Attachment 1: Directional Plan for 30-12L1 Attachment 2: Current Well Schematic for 30-12 Attachment 3: Proposed Well Schematic for 30-12L1 Page 7 of 7 ORIGINAL 12/31/2014 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 30 Pad 30-12 30-12L1 Plan: 30-12L1_wp07 Standard Planning Report 23 December, 2014 BAKER HUGHES ORIGINAL Conocor Phillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 30-12 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 30-12 @ 59.00usft(30-12) Site: Kuparuk 30 Pad North Reference: True Well: 30-12 Survey Calculation Method: Minimum Curvature Wellbore: 30-12L1 Design: 30-12L1_wp07 Project Kuparuk River Unit,North Slope Alaska,United States 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 Kuparuk 30 Pad Site Position: Northing: 6,022,094.67 usft Latitude: 70°28'17.333 N From: Map Easting: 525,478.25 usft Longitude: 149°47'30.897 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.20 ° Well 30-12 Well Position +N/-S 0.00 usft Northing: 6,021,800.87 usft Latitude: 70°28'14.437 N +E/-W 0.00 usft Easting: 525,648.48 usft Longitude: 149°47'25.922 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 30-12L1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (°) (nT) BGGM2014 2/1/2015 19.01 81.01 57,582 Design 30-12L1_wp07 Audit Notes: Version: Phase: PLAN Tie On Depth: 6,600.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 0.00 0.00 0.00 225.00 12/23/2014 8:23:13AM Page 2 COMPASS 5000.1 Build 61 ORIGINAL id,- ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 30-12 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 30-12 @ 59.00usft(30-12) Site: Kuparuk 30 Pad North Reference: True Well: 30-12 Survey Calculation Method: Minimum Curvature Wellbore: 30-12L1 Design: 30-12L1_wp07 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (usft) (0) (0) (usft) (usft) (usft) (°/100ft) (°/100ft) (°/100ft) (0) Target 6,600.00 7.97 247.81 6,495.72 -215.53 -149.36 0.00 0.00 0.00 0.00 6,625.00 7.93 247.52 6,520.48 -216.85 -152.56 0.23 -0.16 -1.16 -135.07 6,650.00 12.43 247.52 6,545.08 -218.54 -156.64 18.00 18.00 0.00 0.00 6,835.71 96.00 247.52 6,644.30 -271.17 -283.83 45.00 45.00 0.00 0.00 6,905.71 103.00 247.52 6,632.75 -297.55 -347.59 10.00 10.00 0.00 0.00 7,105.71 102.20 268.00 6,588.67 -338.63 -537.23 10.00 -0.40 10.24 90.00 7,250.71 91.31 277.65 6,571.60 -331.41 -680.65 10.00 -7.52 6.65 138.00 7,705.00 90.92 232.21 6,562.30 -446.43 -1,107.82 10.00 -0.09 -10.00 270.00 7,835.00 100.83 223.75 6,548.99 -532.74 -1,203.75 10.00 7.63 -6.51 320.00 7,960.00 100.57 211.03 6,525.69 -630.12 -1,278.16 10.00 -0.21 -10.18 270.00 8,140.00 91.29 226.56 6,507.00 -768.95 -1,390.01 10.00 -5.15 8.63 120.00 8,220.00 88.55 234.07 6,507.10 -820.00 -1,451.53 10.00 -3.42 9.40 110.00 8,375.00 83.36 219.43 6,518.09 -925.56 -1,563.84 10.00 -3.35 -9.45 250.00 8,555.00 90.28 202.78 6,528.14 -1,078.86 -1,656.22 10.00 3.85 -9.25 292.00 8,705.00 90.02 187.78 6,527.75 -1,223.14 -1,695.63 10.00 -0.18 -10.00 269.00 8,830.00 82.88 177.49 6,535.51 -1,347.52 -1,701.40 10.00 -5.71 -8.23 235.00 8,955.00 82.84 190.09 6,551.11 -1,471.02 -1,709.57 10.00 -0.04 10.08 91.00 9,125.00 84.61 173.08 6,569.83 -1,639.30 -1,714.17 10.00 1.04 -10.01 275.00 12/23/2014 8:23:13AM Page 3 COMPASS 5000.1 Build 61 .jRIGINAL ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 30-12 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 30-12 @ 59.00usft(30-12) Site: Kuparuk 30 Pad North Reference: True Well: 30-12 Survey Calculation Method: Minimum Curvature Wellbore: 30-12L1 Design: 30-12L1_wp07 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting I (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100ft) (°) (usft) (usft) 6,600.00 7.97 247.81 6,495.72 -215.53 -149.36 258.02 0.00 0.00 6,021,584.85 525,499.87 TIP 6,625.00 7.93 247.52 6,520.48 -216.85 -152.56 261.21 0.23 -135.07 6,021,583.52 525,496.68 KOP 6,650.00 12.43 247.52 6,545.08 -218.54 -156.64 265.29 18.00 0.00 6,021,581.82 525,492.61 End 18 dls,Start 45 dls 6,700.00 34.93 247.52 6,590.57 -226.17 -175.08 283.72 45.00 0.00 6,021,574.13 525,474.20 6,800.00 79.93 247.52 6,643.03 -257.57 -250.96 359.59 45.00 0.00 6,021,542.47 525,398.43 6,835.71 96.00 247.52 6,644.30 -271.17 -283.83 392.45 45.00 0.00 6,021,528.75 525,365.61 End 45 dls,Start 10 die 6,900.00 102.43 247.52 6,634.01 -295.42 -342.44 451.03 10.00 0.00 6,021,504.30 525,307.09 6,905.71 103.00 . 247.52 6,632.75 -297.55 -347.59 456.18 10.00 0.00 6,021,502.15 525,301.95 5 7,000.00 102.82 257.19 6,611.64 -325.37 -435.06 537.70 10.00 90.00 6,021,474.04 525,214.59 7,100.00 102.25 267.42 6,589.88 -338.41 -531.65 615.23 10.00 92.17 6,021,460.67 525,118.05 7,105.71 102.20 268.00 6,588.67 -338.63 -537.23 619.33 10.00 94.39 6,021,460.43 525,112.47 6 I 7,200.00 95.14 274.32 6,574.45 -336.69 -630.31 683.78 10.00 138.00 6,021,462.04 525,019.39 7,250.71 91.31 277.65 6,571.60 -331.41 -680.65 715.64 10.00 138.96 6,021,467.15 524,969.04 7 7,300.00 91.30 272.72 6,570.48 -326.96 -729.71 747.18 10.00 -90.00 6,021,471.43 524,919.97 7,400.00 91.26 262.72 6,568.24 -330.93 -829.48 820.54 10.00 -90.11 6,021,467.11 524,820.23 7,500.00 91.18 252.72 6,566.10 -352.18 -927.04 904.55 10.00 -90.34 6,021,445.54 524,722.75 7,600.00 91.07 242.71 6,564.12 -390.04 -1,019.44 996.66 10.00 -90.55 6,021,407.35 524,630.49 7,700.00 90.92 232.71 6,562.38 -443.38 -1,103.86 1,094.07 10.00 -90.75 6,021,353.73 524,546.27 7,705.00 90.92 232.21 6,562.30 -446.43 -1,107.82 1,099.02 10.00 -90.92 6,021,350.67 524,542.31 8 7,800.00 98.17 226.06 6,554.77 -508.30 -1,179.38 1,193.37 10.00 -40.00 6,021,288.56 524,470.98 7,835.00 100.83 223.75 6,548.99 -532.74 -1,203.75 1,227.88 10.00 -40.49 6,021,264.04 524,446.70 9 7,900.00 100.76 217.13 6,536.80 -581.31 -1,245.14 1,291.49 10.00 -90.00 6,021,215.33 524,405.48 7,960.00 100.57 211.03 6,525.69 -630.12 -1,278.16 1,349.36 10.00 -91.24 6,021,166.41 524,372.63 10 8,000.00 98.55 214.53 6,519.04 -663.27 -1,299.51 1,387.90 10.00 120.00 6,021,133.19 524,351.39 8,100.00 93.39 223.14 6,508.63 -740.62 -1,361.83 1,486.66 10.00 120.58 6,021,055.63 524,289.35 8,140.00 91.29 226.56 6,507.00 -768.95 -1,390.01 1,526.62 10.00 121.48 6,021,027.21 524,261.26 11 8,200.00 89.24 232.19 6,506.72 -808.00 -1,435.53 1,586.41 10.00 110.00 6,020,988.01 524,215.89 8,220.00 88.55 234.07 6,507.10 -820.00 -1,451.53 1,606.21 10.00 110.03 6,020,975.96 524,199.93 12 8,300.00 85.84 226.54 6,511.02 -870.98 -1,512.96 1,685.70 10.00 -110.00 6,020,924.76 524,138.68 8,375.00 83.36 219.43 6,518.09 -925.56 -1,563.84 1,760.27 10.00 -109.63 6,020,870.02 524,088.00 13 8,400.00 84.30 217.10 6,520.78 -945.08 -1,579.23 1,784.95 10.00 -68.00 6,020,850.45 524,072.68 8,500.00 88.14 207.84 6,527.39 -1,029.16 -1,632.72 1,882.23 10.00 -67.75 6,020,766.19 524,019.48 8,555.00 90.28 202.78 6,528.14 -1,078.86 -1,656.22 1,933.99 10.00 -67.14 6,020,716.42 523,996.15 14 8,600.00 90.20 198.28 6,527.95 -1,120.99 -1,671.99 1,974.94 10.00 -91.00 6,020,674.24 523,980.52 8,700.00 90.02 188.28 6,527.75 -1,218.19 -1,694.94 2,059.89 10.00 -91.02 6,020,576.97 523,957.92 8,705.00 90.02 187.78 6,527.75 -1,223.14 -1,695.63 2,063.89 10.00 -91.04 6,020,572.02 523,957.24 15 8,800.00 84.58 179.98 6,532.23 -1,317.71 -1,702.06 2,135.30 10.00 -125.00 6,020,477.44 523,951.14 12/23/2014 8:23:13AM Page 4 COMPASS 5000.1 Build 61 ORIGINAL ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 30-12 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 30-12 @ 59.00usft(30-12) Site: Kuparuk 30 Pad North Reference: True Well: 30-12 Survey Calculation Method: Minimum Curvature Wellbore: 30-12L1 Design: 30-12L1_wp07 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +EI-W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°1100ft) (°) (usft) (usft) 8,830.00 82.88 177.49 6,535.51 -1,347.52 -1,701.40 2,155.91 10.00 -124.63 6,020,447.63 523,951.90 16 8,900.00 82.81 184.54 6,544.23 -1,416.92 -1,702.63 2,205.85 10.00 91.00 6,020,378.24 523,950.91 8,955.00 82.84 190.09 6,551.11 -1,471.02 -1,709.57 2,249.02 10.00 90.12 6,020,324.11 523,944.15 17 9,000.00 83.25 185.57 6,556.56 -1,515.26 -1,715.66 2,284.60 10.00 -85.00 6,020,279.86 523,938.23 9,100.00 84.31 175.57 6,567.42 -1,614.54 -1,716.64 2,355.50 10.00 -84.45 6,020,180.59 523,937.59 9,125.00 84.61 173.08 6,569.83 -1,639.30 -1,714.17 2,371.26 10.00 -83.37 6,020,155.84 523,940.13 Planned TD at 9125.00 12/23/2014 8:23:13AM Page 5 COMPASS 5000.1 Build 61 ORIGINAL ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 30 Pad 30-12 30-12L1 30-12L1_wp07 Travelling Cylinder Report 22 December, 2014 BAKER HUGHES ORIGINAL Baker Hughes INTEQ Fa" ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 30-12 Project: Kuparuk River Unit TVD Reference: 30-12 @ 59.00usft(30-12) Reference Site: Kuparuk 30 Pad MD Reference: 30-12 @ 59.00usft(30-12) Site Error: 0.00usft North Reference: True Reference Well: 30-12 Survey Calculation Method: Minimum Curvature Well Error: O.O0usft Output errors are at 1.00 sigma Reference Wellbore 30-12L1 Database: OAKEDMP2 Reference Design: 30-12L1_wp07 Offset TVD Reference: Offset Datum Reference 30-12L1_wp07 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 6,600.00 to 9,125.Oousft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,106.60usft Error Surface: Elliptical Conic Survey Tool Program Date 12/22/2014 From To (usft) (usft) Survey(Wellbore) Tool Name Description 100.00 6,600.00 30-12(30-12) GCT-MS Schlumberger GCT multishot 6,600.00 9,125.00 30-12L1_wp07(3O-12L1) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 9,125.00 6,628.83 2-3/8" 2-3/8 3 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) Kuparuk 30 Pad 30-01-30-01-30-01 Out of range 30-02-30-02-30-02 Out of range 30-02-3O-02A-3O-02A Out of range 30-02-30-02AL1-30-02AL1 Out of range 30-02-30-02AL1 PB1-30-02AL1 PB1 Out of range 30-02-30-02AL2-30-02AL2 Out of range 30-02-30-02AL2-01-30-02AL2-01 Out of range 30-04-30-04-30-04 Out of range 30-05-30-05-30-05 Out of range 30-06-30-06-30-06 Out of range 30-08-30-08-30-08 Out of range 30-09-30-09-30-09 Out of range 30-10-30-10-30-10 Out of range 30-11-30-11-30-11 Out of range 30-12-30-12-30-12 6,649.95 6,650.00 0.99 1.93 -0.94 FAIL-Major Risk 30-13-30-13-30-13 Out of range 30-14-30-14-30-14 Out of range 30-15-30-15-30-15 Out of range 30-16-30-16-30-16 Out of range 30-16A-30-16A-30-16A Out of range 30-17-30-17-30-17 Out of range 30 19 30 19 30 19 Out of range Plan:DHH-02-Plan:DHH-02-DHH-02wp01 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 12/22/2014 3:17:13PM Page 2 of 4 COMPASS 5000.1 Build 65 x) RIGINAL a 1A o s N W 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I lul.i it I I, ti{{y (-A" �{{ ••..6.....6.4.........:•t•t•t•t•t•t•t•. 1.1.1.1.1.1.1.1 1?L{L nr-e?L?1?L{1{ti U L{L{� 1{L{1{1{1{1{1 } }}}}}}} }}}} i , } ,} t•t•t•t•{w•t•. }•1.1 1.1.1.1 1.1.1.1.1 L•L•L w �?�•r�?����a?�r.r.±.r.ra?.f i r r r.r.r.t.r rr r }t.t.t.t.t.t.t.. i I - -IP III Iillll III II 11111 O I (n m m 0 0 _� 0 L co 0 -0000 oN 0)Er) a (n N at ) 0 opsin o � � � � _o (0 n � (n0 000 * rn (N og (no .wri000 -o m � ,m 'Cg � 22 � a) � OO CA (La � � I� (�O � COO co � c o �� UrOM I� V O o 0_(s) r r M � � � 2 �o a (O (O (U No_ OED ( (0r N L V• a (o < (O (fl (O 1 ORIGINAL 4 Bettis, Patricia K (DOA) From: Phillips, Ron L <Ron.L.Phillips@conocophillips.com> Sent: Tuesday, January 06, 2015 2:38 PM To: Bettis, Patricia K (DOA) Subject: RE: KRU 30-12L1: Permit to Drill Application Patricia, On the spider plot all of the wells that are shown in the 1/4 mile radii are at much shallower depth. Along each wellbore are small numbers showing TVD (True Vertical Depth) every 1,000'. The TVD of the 30-12L1 lateral varies between 6,507' and 6,644'. Personally I look at each well bore that crosses the 1/4 mile radii and check the TVD depth to verify that wellbore is not in the Kuparuk reservoir. Since this well is nearly vertical down to the kickoff point, every well on the pad crosses over the top of the 30-12L1 lateral above the top of the Kuparuk Reservoir. Another place to look is on the Travelling Cylinder Report Summary Page which states that all the wells on the 30 pad are out of range at the reservoir depth except the 30-12 parent wellbore that we plan to kick out of. Please let me know if I can be of further help. Thanks, Ron L. Phillips Senior CTD Engineer ConocoPhillips Alaska Phone 265-6312 Cell 317-5092 From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Tuesday, January 06, 2015 11:40 AM To: Phillips, Ron L Subject: [EXTERNAL]KRU 30-12L1: Permit to Drill Application Good morning Ron, In the permit to drill application, page 7 Quarter Mile Injection Review, it states that there are no wells within%-mile of the 30-12L1 well. On the spider map that provides%-mile radii,there appears to be numerous wells that are within a %- mile radius of the planned 30-12L1 wellbore. Please explain. Under 20 AAC 25.402, all wells, abandoned, or other unused well, production well, dry hole, and other wells within one- luarter mile of each proposed injection well must be identified. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 1 • Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Tuesday, January 06, 2015 11:40 AM To: Ron.L.Phillips@conocophillips.com Subject: KRU 30-12L1: Permit to Drill Application Good morning Ron, In the permit to drill application, page 7 Quarter Mile Injection Review, it states that there are no wells within 'A-mile of the 30-12L1 well. On the spider map that provides%-mile radii,there appears to be numerous wells that are within a 1/4- mile radius of the planned 30-12L1 wellbore. Please explain. Under 20 AAC 25.402, all wells, abandoned, or other unused well, production well, dry hole, and other wells within one- luarter mile of each proposed injection well must be identified. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME: 1<ftu . PTD: 0,/5- 003 _Development ✓ Service Exploratory Stratigraphic Test Non-Conventional FIELD: I�`�� �J�,,r— POOL: k(,�t!ti i J t `,/4. Ri,/ 0,7 I 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. 1 V- O y I , API No. 50-429 - 30 -Oo - 00 (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 Well Logging also required for this well: 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 5/2013 N ,, p. . 0) o a , a) o- , , , , 2. co N as o , , vi� , 3. , Q o' , , � , MtcO: ; M U f0' 7' 00• V, , 3, , ' m D. ' c c. a. , W (n H y'. ,,. W' a E O as a o , m Z' .. 4 , ca. p r u ; u ai c , , cu �i, C car W , 3 �' _ 0) 3. O c, a o, g OII J O a) > t e O • N, 0 W 3 m w' .p, 3 a ca . o. , , , , 2 � , O, U Y, a' o rn, ZI > �. 2 c o E �, �, 4 Y D.,,, a'' a 2 w, O0. �:', , , • �' Y 16, N N N, : y. � 0) C' a) mUy CC' 8.? ' .a a E, a o G)' 0a> YV ' Cd CdU pQ? OO L 2 - N , N, . D. 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