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215-047
• • P r0 /5 — C4-7-- 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.com] 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) 30-12L1 (215-003) 30-12L1-01 (215-047) Will this create an issue? SCANNED w & ' Thanks, Ethan Ethan Plunkett J3NIMROQ-Senior Drilisite 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 RECEIVED ALTA OIL AND GAS CONSERVATION COM•ION REPORT OF SUNDRY WELL OPERATIONS .IAN 0 3 2018 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing UCj �'s?Iwn o Performed: Suspend CI Perforate CI Other Stimulate CI Alter Casing CICh n e pp ve r ram Plug for Redrill ❑ ,erforate New Pool El Repair Well ❑ Re-enter Susp Well ❑ Other: WINJ to WAG❑3 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 215-047-0 3.Address: P. 0. Box 100360,Anchorage,Alaska Stratigraphic❑ Service Q 6.API Number: 99510 50-029-21804-61 7.Property Designation(Lease Number): 8.Well Name and Number: ADL025513 30-12L1-01 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 9,101 feet Plugs measured None feet true vertical 6,608 feet Junk measured None feet Effective Depth measured 9,101 feet Packer measured 6364 feet true vertical 6,608 feet true vertical 6321 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 74 16 110 110 SURFACE 4,071 12 4,106 4,100 LINER 261 6 6,620 6,827 PRODUCTION 6,587 7 6,620 6,909 LINER L1-01 2,481 3 9,101 6,608 Perforation depth Measured depth Slots:6630-9909 feet SCANNED JAN 1 6 2018 True Vertical depth 6585-6633 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 and 6321 TVD TDRP-BAKER'FLVD'@ 1784 MD and 1784 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: 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 ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG Q GINJ ❑ SUSP❑ 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: 315-570 Contact Name: Ethan Plunkett Authorized Name:Ethan Plunkett Contact Email: Ethan.T.Plunkett@conocophillips.com Authorized Title:Petroleum Engineer /'�� ��� Contact Phone: (907)263-4280 Authorized Signature: ✓ — Date: a t-O Z.-ZO f$ en- 175/ie Form 10-404 Revised 4/2017 � r. ;} �� t EDY 1 �! ' ., - (j ., EJ SubmitOriginalOnly • • 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 30-12L1-01 (PTD# 215-047). If you have any questions regarding this matter, please contact me at 907-263-4280. Sincerely, -A(A51 Ethan Plunkett Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Sundry Report Description of Work Completed Schematic 1 • 30-12L1-01 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 12/30/17 Convertt well from WINJ to WAG service. J KUP INJ 30-12L1-01 ConocoPhillips ® • Well Attributes Max Angle&MD TD Alaska,lf1C. Wellbore API/UWI Field Name Wellbore Status Oct(°) MD(CAB) Act Btm(ftKB) 500292180461 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 30-12L1-01.11/1720158:0825 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:WAVERED CANCELLED pproven 10/15/2015 HANGER;33.0 Casing Strings Casing Description GD(in) ID(in) Top(ftKB) Set Depth(11813) Set Depth(TVD)... Wt/Len(I...Grade Top Thread LINER L1-01 23/8 1.992 6,620.2 9,101.0 4.60 L-80 511 Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(0 Item Des Corn (in) -hula tar, , 6,620.2 6,574.7 7.94 DEPLOY BAKER SHORTY DEPLOYMENT SLEEVE 1.900 _. _ ' 7,580.8 6,633.3 91.18 DEPLOY BAKER SHORTY DEPLOYMENT SLEEVE 1.900 Perforations&Slots CONDUCTOR;36.0-110.0 Shot Den Top(ND) Btm(ND) (shots/t Top)ftKB) Btm)ftKB) (ftKB) (ftKB) Zone Date t) Type Com SAFETYVLV;1,803.8 6,630.4 7,578.9 6,584.8 6,633.3 A-3,30-12 3/1 1/201 5 SLOTS Slotted Liner 7,583.5 9,099.0 6,633.2 6,608.1 A-3,30-12 3/11/2015 SLOTS Slotted Liner Notes:General&Safety End Date Annotation GAS LIFT;2,4966 3/20/2015 NOTE:ADD LATERALS L1(off main wellbore),L1-01 GAS LIFT;3,717.0- SURFACE;35.0-4,105.7- GAS LIFT;4,603.0 - GAS LIFT;5,334.6 • • GAS LIFT;5,883 8 GAS LIFT,6.250.3 • NIPPLE 6,3102 -11 LOCATOR;6,362.5 SEAL ASSY;6,363.6 ).IMF • SIL" • IPERF;8,611.0-6,621.0 PRODUCTION;33.06,957.1 LINER;6,359.2-6,876.0 1----' SLOTS;6,630.4-7,578.8 SLOTS;7,583.4-9,099.0 - LINER L1-01;6,620.2-9,101.0 1 • • Loepp, Victoria T (DOA) 0 Lt- From: Loepp,Victoria T(DOA) Sent: Wednesday, December 20,2017 9:50 AM To: 'Plunkett, Ethan T' 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 2 9) iI Senior Petroleum Engineer ��� State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppaalaska.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.Loem@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(a)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 • • prOa /5 -04- From: Plunkett, Ethan T(mailto:Ethan.T.Plunkett@conocophillips.cornj Tt Sent: Monday, December 18, 2017 2:02 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.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) 30-1211 (215-003) 30-1211-01 (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 I3NIMROQ-Senior Drillsite Petroleum Engineer I ConocoPhillips Alaska I GKA Base I 0: (907)263-4280 C: (918)812-2284 SCANNED r 2 STATE OF ALASKA AOKA OIL AND GAS CONSERVATION COOSSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate p r Other Stimulate r Alter Casing Change Approved Program Plug for Redrill r Perforate New Pool r Repair Well Re-enter Sus Well r p Other:Prod to WINJ 507 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratory r 215-047-0 3.Address: 6.API Number: Stratigraphic r Service P. 0. Box 100360,Anchorage,Alaska 99510 50-029-21804-61 7. Property Designation(Lease Number): 8.Well Name and Number: ADL025513 KRU 30-12L1-01 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 9101 feet Plugs(measured) None true vertical 6608 feet Junk(measured) None Effective Depth measured 9101 feet Packer(measured) 6364 true vertical 6608 feet (true vertical) 6321 Casing Length Size MD TVD Burst Collapse CONDUCTOR 74 16 110 110 SURFACE 4071 12 4106 4100 LINER 261 5.96 6620 6827 PRODUCTION 6587 7 6620 6909 LINER L1-01 2481 2.63 9101 6608 RECEIVED Perforation depth: Measured depth: Slots:6630-9099 Q C T 7 �Q True Vertical Depth: 6585-6633 SONED 15 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 TRDP-BAKER'FVLD'@ 1784 MD and 1784 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 r7- r Development r Service I✓ 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 I- 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 315-570 Contact Darrell Humphrey/Bob Christensen Email n1139(c�conocophillips.com Printed Name obert D Christensen Title NSK Production Engineering Specialist Signature Phone:659-7535 Date to,'Z 3//5 Vr-i_ l°/2-7/!5" \fi Form 10-404 Revised 5/2015 /4/07A---07A--- RBDMVUI 12 7 206Submit Original Only • 30-12L1-01 • 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 30-12L1-01 ConocoPhillips Well Attributes, " alai Angie&AAD TD A(BS ,Inc ,,. Wellbore API/UWI Field Name Wellbore Status ncl(") MD(ftKB) Act Btm(ftKB) cr_+c.coPivulps. + 500292180461 KUPARUK RIVER UNIT PROD 101.32 6,98084 9,101.0 --, Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 30-12L1-01,10/15/2015 3'2627 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 Data Last Tag: Rev Reason:GLV C/O lehallf 10/15/2015 HANGER:330 1111 II Casing Strings - Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread I LINER L1-01 23/8 1.992 6,6202 9,101.0 4.60 L-80 511 i + Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Inel(') Item Des Com (m) ,,a, 6,620.2 6,574.7 7.94 DEPLOY BAKER SHORN DEPLOYMENT SLEEVE 1.900 "W. �" 7,580.8 6,633.3 91.18 DEPLOY BAKER SHORTY DEPLOYMENT SLEEVE 1.900 1 Perforations&Slots CONDUCTOR;36.0-110.0 Shot Dens ots/f Top(ftKB) elm(ftKB) Top KB)(TVD) Btm )TVD) (ahZone Date o Type Com SAFETY VLVI 1803.8 r' '; 6,630.4 7,578,9 6,584.8 6,633.3 A-3,30-12 3/11/2015 SLOTS Slotted Liner N. 7,583.5 9,099.0 6,633.2 6,608.1 A-3,30-12 3/11/2015 SLOTS Slotted Liner • Notes:General&Safety 11. End Date Annotation GAS LIFT,2496.6 3/20/2015 NOTE:ADD LATERALS L1(off main wellbore),L1-01 I I GAS LIFT;3,717 0 : I • SURFACE;350-4,105.7—* 1 GAS LIFT,4,603.0 it GAS LIFT;5,334 6 I I GAS LIFT,5083.8 I I GAS LIFT;6,250.3 I NIPPLE',6,310.2 I i LOCATOR;6,362 5 jig 0, SEAL ASSY',6,363.6 I ' 11 /,, IPERF',6611.0-6,6210 1. ,t PRODUCTION;33.0-6,957.1 LINER;6,359 2-6,876.0 —11 SLOTS;6,630.4-7,5788 SLOTS;7,583.4-9,099 0 LINER L1-01',6 620.2-9,101 0 • 4,.0",\1%%i ,v THE STATE Alaska Oil and Gas of Conservation Commission x 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 °FALAS*P2.4315 � Fax: 907.276.7542 C���� �v L � www.aogcc.alaska.gov Darrell Humphrey NSK Production Engineering Specialist Q 15- �� ��� ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 30-12L1-01 Sundry Number: 315-570 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, Cathy P. oerster Chair DATED this /g/day of September, 2015 X015 RBDMS Std' 1 Encl. ECEWED r:. . .. A OIL AND GAS CONS RVAT ON COMMOON5E�R 1 6 201' APPLICATION FOR SUNDRY APPROVALS 0.7-s '//vfi 20 AAC 25.280 AOGCC 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Prod to WAG 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development F" 215-047-0 3.Address: Stratigraphic r Service 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-21804-61 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No J 7 KRU 30-12L1-01 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): 9101 * 6608 • 9101' ` 6608' . None None Casing Length Size MD TVD Burst Collapse LINER L1-01 2481 2.63 9101' 6608' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Slotted 6630-7580,7583-9099. 6585-6633,6633-6608 3.5 L-80 6363 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) NIPPLE-"X'NIPPLE MD=6310 TVD=6268, LOCATOR-80-40 GBH-22 LOCATOR(BOTTOM OF LOCATOR SPi MD=6363 TVD=6320 SEAL ASSY-80-40 GBH-22 SEAL ASSEMBLY MD=6364 TVD=6321' SSSV=None Uwe )80-5' 12.Attachments: Description Sunurrary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service P 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 9/30/2015 OIL r WINJ r WDSPL r Suspended r- 16. 16.Verbal Approval: Date: GAS r WAG r GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned F- 17. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Darrell Humphrey/Bob Christensen Email: n1139 anconocophillips.com Printed Name Darrell Humphrey Title: NSK Production Engineering Specialist Signature 'J —4 D�.rai,. Phone:659-7535 Date 4 . f Li. Is A Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 316- 5-7 Plug Integrity r BOP Test 6 Mechanical Integrity Test Pc Location Clearance r Other: QT�1,1, e.(.r1&'\ ye-rajio-n 5 -Hv L7L r f CILC-C..c7-a nCe L'V I " 0 2Lhe"'\`- t747kvom � 2 / i 4- rt- L/,Vf OJ GL F.71-1- ✓ y� �G/ LJ J / `/ 7-25of '!`i/ '7`i.-. Spacing Exception Required? Yes No Subsequent Form Required: / 4l' APPROVED BY Approved by: (1416r ;:a€_* c ____ COMMISSIONER THE COMMISSION Date:9-/e-/• - AppO jpOtLDN v id[ r 12 months fr 01-4.... ,`.2 j Submit Form and Form 10-403 Revise 5/2015 ''vv H L Attachments in Duplicate V77— q//1-// Ail 1 111 -DLJ 'I/1-6/2.o/3 dO 9%//i---- • • 30-12L1-01 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 %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). • 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. No re5e,v e5 lev.'QW fPA'' COhve(7-/n 1( b44l< cinwl-"°° 5:e" e,e, • • 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) (Requirements of 20 AAC 25.402) There are no wells within 1/4-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 --z....iTir-. -." .:: -06,311‘.- � P 300 010 Alp r 'N- 30-09 30-121-1��,14 11M1111111111w,A j\ 00 • M �r to�QiLv 130-0- s ConocoPhillip Legend Alaska,Inc. *Well Surface Location Pad Mean Center Injection Swap Analysis 1/4 Mile Radius 30-12, 30-12L1, 30-12L1-01 11:. 10-12 N — 3012L1 n 0 0.25 o.5 N Miles 30-12L1-01 1 H-04Imj0wap.mxd CSR 5/8/2015 ✓ KUP INJ 0 30-12L1-01 ConocoPhillips ; Well Attributes Max Angle&MD TD - Alaska Inc Wellbore API/DWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Btm(ftKB) ['morn/helm, 500292180461 KUPARUK RIVER UNIT INJ 101.32 6,980.84 9,130.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(R) -Rig Release Date 30-12L1-01,4/5/20151:18:33 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 &k°-V JI -Casing Wings f Casing Description OD(In) ID(in) Top(11KB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread f LINER L1-01 2 318 1.992 6,620.2 9,101.0 4.60 L-80 511 I Liner Details aWL Nominal ID rTIFIr rI '� Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (In) II 6,620.2 6,574.7 7.94 DEPLOY 'BAKER SHORTY DEPLOYMENT SLEEVE 1900 CONDUCTOR;36.0-1100 1 7,580.8 6,633.3 91.18-DEPLOY BAKER SHORTY DEPLOYMENT SLEEVE 1.900 A Perforations&Slots SAFETY VLV;1,803.8 _' Shot all Dens Top(ND) Otto[IVO) (shots/f II Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com GAS LIFT;2,4066 _ 6,630.4 7,578.9 6,584.8 6,633.3 A-3,30-12 3/11/2015 SLOTS Slotted Liner 7,583.5 9,099.0 6,633.2 6,608.1 A-3 30-12 3/11/2015 SLOTS Slotted Liner Notes:General&Safety End Date Annotation GAS LIFT,3,717.0 - 3/20/2015 NOl F'.ADDL ATE RALS L1(off main wellbore),L1-01 • II SURFACE;35.0-4,105.7—. i GAS LIFT;4,603.0 GAS LIFT;5,334.6. GAS LIFT;5.883.t1 GAS LIFT;6,250.3 V NIPPLE;6,310.2 II ' LOCATOR;6,362.5 SEAL ASSY;6,363.6 Mr 1 sw. IPERF;6,611.0-6,621.0— WHIPSTOCK;6,625.0 .,.," WINDOW;6,628.06,636.0 ' RPERF;6,661.06,671.0, —" 1 (PERF;6,661.06,671.0 ■: RPERF;6,676.0-6,695. - IZ ;6,676AQ700.0 1. RPERF;6,695.0-6.700.0 + I, II APERF;6,712.06,732.0—i—•• 11 _ 11 Iti I 11 1I I LINER;6,359.2-6,876.0 U. PRODUCTION;33.06,957.1, SLOTS;6,630.47,578.8- .gam - 16 SLOTS;7,583.4-9,099.0 LINER L1-01;6,620.2-9,101.0 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. ai S- 07 Well History File Identifier Organizing(done) ❑ Two-sided ❑ Rescan Needed RES AN: OVERSIZED: NOTES: o r Items: ❑ Ma s: Grayscale Items: ogs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: Date: (Q/16J/S' /s/ rflf Project Proofing BY: Maria �_ Date: (a/i q 16- /s/ me Scanning Preparation I x 30 = 30 + cg. I = TOTAL PAGES 5' I (Count does not include cover sheet) BY: dIZZIP Date: .9 0 /s/ Production Scanning Stage 1 Page Count from Scanned File: 5(9. (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: 1,/''cES NO BY: Date: 61 f( j'/5 /s/ vviv 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 • v, o , o `° N 00 00 • E E r, nr G Co \ N , ,. 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N\ 4 z_ d CO o J co 0 LI Q y 0 co a v On J W = ce a O v W z z V 0 Q z a o ics o O. ID coC • T2 N • 5"-4 p in E M t. CD U 9 J n a NDA r . O 0. r Cl) H C > N mac\ > N W a' co ,i. D a) CO Q .- cow I a a Y az 0 p E U is z d 3 m o ~ v co m T d 1 N F. r Dm C (� +�+ O) lav .QE E C a) o O Q 0. 2 0 STATE OF ALASKA / ALAor.A OIL AND GAS CONSERVATION COW—SION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed Suspend r Perforate r Other Stimulate Alter Casing r 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 215-047-00 3.Address. 6.API Number. Stratigraphic r Service P. O. Box 100360,Anchorage,Alaska 99510 50-029-21804-61 7. Property Designation(Lease Number): 8.Well Name and Number: ADL 25513 KRU 30-12L1-01 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 9101 feet Plugs(measured) None true vertical 6608 feet Junk(measured) None Effective Depth measured 9101 feet Packer(measured) 0 true vertical 6608 feet (true vertical) 0 Casing Length Size MD ND Burst Collapse Liner L1-01 2480 2.375 9101 6608 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: Slotted Liner 6630-7580,7583-9099 True Vertical Depth: 6585-6633, 6633-6608 RECEIVED MAY 192015 Tubing(size,grade,MD,and ND) 3.5, L-80,6363 MD, 6350 TVD Packers&SSSV(type, MD,and ND) SSSV=TRMAXX-CMT-5-SR SCSSSV MD= 1804',TVD=1804' AOGCC 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-Bbi Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 0 Subsequent to operation 317 419 2746 1313 154 14.Attachments(required per 20 AAC 25 070,25 071,825.283) 15.Well Class after work. Daily Report of Well Operations r Exploratory r Development r Service r Stratigraphic r 1 Copies of Logs and Surveys Run r 16 Well Status after work: Oil Iv 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 n1139C�conocophillips.com Printed Name Darrell Humphrey Title NSK Production Engineering Specialist SignaturePhone:659-7535 Date c 5—•/7.15 1 V 5724 J rs RBDMSji MAY Z 9 2015 Form 10-404 R'ISVrd S/20'f5 - Submit Original Only 30-12L1-01 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 30-12L1-01 ConocoPhillips u Well Attributes Max Angle&MD TD Alaska.Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) r...,x;ft, n 500292180461 KUPARUK RIVER UNIT INJ a 101.32 6,980.84 9,130.0 --- • Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) 'Rig Release Date 30-12L1-01,4520151:18:33 PM SSSV:TRDP Last WO: 40.00 6/3/1988 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ----------- - -- --- r� Last Tag: Rev Reason:GLV C/O hipshkf 4/5/2015 HANGER;33.0 ILi".i I Casing Strings • ' Casing Description IOD(in) IID(in) Top 176280.21 15181 ISet Depth(ftKB) ISet Depth(TVD)... WtlLen II...I Grade I Top Thread LINER L1-01 2 3/8 1.992 6620 2 9,101 0 4 60 L-80 511 J Liner Details Nominal ID �' �� Top(ftKB) Top(ND)(ftKB) Top Ieel(°) Item Des Com (in) 6,620.2 6,574.7 7.94 DEPLOY BAKER SHORTY DEPLOYMENT SLEEVE 1.900 CONDUCTOR;36.0-110.0 7,580.8 6,633.3 91.18 DEPLOY BAKER SHORTY DEPLOYMENT SLEEVE - 1.900 Perforations&Slots SAFETY VLV;1,803.8 TN' ';I Shot Dens Top(NO) Btm(NO) (shotsff Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Dale 1) Type Com • GAS LIFT;2,4966 _ 6.630.4 7,578.9 6,584.8 6,633.3 A-3,30-12 3/11/2015 SLOTS Slotted Liner 7,583.5 9,099.0 6,633.2 6,608.1 A-3,30-12 3/11/2015 SLOTS Slotted Liner • • Notes:General&Safety End Date Annotation GAS LIFT;3,7170 _, 3/20/2015 NO1 E:ADD LATERALS Ll(off main wellbore),L1-01 • SURFACE;35.0-4,105.7—s i. GAS LIFT;4,603.0 GAS LIFT',5,334.6 C GAS LIFT,5,863 8 1. GAS LIFT;6,250.3 a I■ IIII■ NIPPLE;5310.2 j7,:: I 4 LOCATOR;6,362.5— SEAL ASSY;6,363.6 s . Y IPERF;6.611.06,621.0—-� J WHIPSTOCK;8,625.0 WINDOW;6,628.0"6.636.0 ill! sI RPERF;6,661.0.6,671.0 IPERF;6,661.0"6,671.0 RPERF;6,676,0.6,695.0 I IPERF;6,676.06,760.0 RPERF;15695.0-6.700.0— ...1.1. APERF;6,712.06,732.0—�� —48 II Ill 1 tl' LINER;6.359 2-6,876.0 PRODUCTION;33.06,957.11 SLOTS;6530.4-7,5785— stst SLOTS;7583.4-5099.0 I I LINER L1-01;6,620.2-9,101.0—t (215O47 215003 715 25714 BAKER PRINT DISTRIBUTION LIST HUGHES Please sign and return one copy of this transmittal form to: DATA LOGE g COMPANY ConocoPhillips Baker Hughes INTEQ $ it5i2o1 1 E (mandatory) 795 East 94th Avenue M.K.BEND 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. O��� (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.lacev( bakerhuahes.com (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? No COMPANY FIELD FINAL CD Final CD ADDRESS(FEDEXWILL NOT DELIVER TO P.O.BOX) LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #OF I'KIN I S #OF COPIES #OF COPIES#OF COPIES 1 ConocoPhillips Alaska Inc. 1 1 1 1 Attn:Ricky Elgaricio ATO 3-344 700 G Street Anchorage,AK 99510 2 BP Exploration(Alaska)Inc. 1 1 1 1 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 Attn:Dodie Stinson 3 Chevron/KRU Rep 1 1 1 1 Attn:Glenn Frederick P.O.Box 196247 Anchorage,AK 99519 4State of Alaska -AOGCC 1 1 2 1 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 1 1 Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR TOTALS FOR THIS PAGE: 0 4 5 5 5 0 TOTALS FOR ALL PAGES: 0 4 5 5 5 0 0 0 N CI_C 0 H a[ Q < W 1111 Z `W; aZ N O. I — C ca 0 O. U) C3 w W W Q I— >, Q. 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WO o OD co 2 cow' cow o O o M (0 N cti 0 o c o a ` of Of of of of 0) of of ai Of of of of of of of of of o 0 0 0 0 0 .0 U E o m m d ) 0 a co a N 4 RECEIVED STATE OF ALASKA APR 0 2 2015 • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANDIVaCC la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG Q - WDSPL ❑ Other ❑ No.of Completions: Service Ill ' StratigraphicTest❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc.- orAband.: •March 12,2015 215-047/ . 3.Address: 6.Date Spudded: 13.API Number: P.0. Box 100360,Anchorage,AK 99510-0360 • March 9,2015 50-029-21804-61 4a.Location of Weil(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 1019'FNL,2011'FWL,Sec.22,T13N, R9E, UM •March 10,2015 KRU 30-12L1-01 ' Top of Productive Horizon: 8. KB(ft above MSL): 59'RKB 15.Field/Pool(s): 2286'FNL,411'FWL,Sec.22,T13N, R9E,UM GL(ft above MSL): 24'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 2636'FNL,303'FWL,Sec.22,T13N, R9E, UM 9101'MD/6608'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 •9101'MD/6608'TVD ADL 25513• TPI: x-524055 y- 6020528 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-523949 y- 6020178 Zone-4 1804'MD/1804'TVD 2554 18.Directional Survey: Yes El • 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/TVD GR/Res • 7600'MD/6633'TVD " 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD 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 6620' 9101' 6575' 6608' 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 rPE slots from 6630'-9100'MD 6584'-6608'TVD 'nt . 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. l`5Was hydraulic fracturing used during completion? Yes❑ No EDEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 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 For 10-407rp,yps�d 10/2012 'l 5_�/r CONTI E ON REVERSE RBDMS \+ APR - 9 t it original only 294 GEOLOGIC MARKERS(List all formations and man icountered) 30 FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 0 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 A2 7600' 6633' Kuparuk Al 8128' 6628' Kuparuk A3 8734' 6606' N/A Formation at total depth: Kuparuk A3 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 @ 265-6312 Email \ A Ron.L.Phillips@conocophillips.com Printed Name D.V- aus Title CTD Engineering Supervisor [� `C Signature -'' Phone 263-4372 Date /— I5 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 30-12L1-01 ConocoPhillips 1.1 Well Attributes Max Angle&MD TDAPI/UM}Lii>i(A,rlf:. Wellbore API/UM Field Name Wellbore Status n I(°) MD(ftKB) Act Btm(ftKB) Cor,ocrio+eoR 500292180461 I KUPARUK RIVER UNIT SVC 101.32 6,980.84 9,130.0 -.- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 30-120-01,3/25201512:00m7 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:ADD LATERALS L1,L1-01 smsmith 3/20/2015 HANGER:33.0 10;1 Casing Strings T. Casing Description OD(in) ID(in) Top(11KB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread LINER L1-01 2 3/8 1.992 6,620.2 9,101.0 4.60 L-80 511 Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 6.620.2 6,574.7 7.94 DEPLOY BAKER SHORTY DEPLOYMENT SLEEVE 1.900 CONDUCTOR,36.0-110.0-4 ' 7,580.8 6,633.3 91.18 DEPLOY BAKER SHORTY DEPLOYMENT SLEEVE 1.900 Perforations&Slots SAFETY VLV',18030 i_ Shot Dens Top(TVD) Blot(TVD) (shotslf Top(ftKB) Btm(ftKB) (ftKB) (MB) Zane Date t) Type Cam GAS LIFT;3,717.0 GAS LIFT:24988 SLOTS 6,630.4 7,578.9 6,584.8 6,633.3 A-3,30-12 3/11/2015 Slotted Liner 7,583.5 9,099.0 6,633.2 6,608.1 A-3,30-12 3/11/2015 SLOTS Slotted Liner Notes:General&Safety End Date Annotation 3/20/2015 NOTE:ADD LATERALS L1(off main wellbore),Lt-01 SURFACE;35.04,105.7-4 111 GAS LIFT;4,603.0 " S GAS LIFT;5.334.6 GAS LIFT.5,8838 GAS LIFT;6,250.3 NIPPLE:6.3102 LOCATOR;6,362.5 SEAL ASSY;6,363.6 MB IPERF;6,611.0-6,621.0—.~ L. • WHIPSTOCK;6,625.0 WINDOW;6,628.0-6,636.0 ' RPERF;6,661.0-6,671.0 IPERF;6,661.0-6,671.0 RPERF:6,676.0-6,695.0 (PERF:6.676.0-6.700.0 — RPERF;6,695.0-6,700.0 APERF;6,712.0-6,732.0 » �I LINER;6,3592-6,876.0 PRODUCTION;33.0.6,957.1 SLOTS;8.630.4-7,570.8 SLOTS;7.583.4-9,099.0 LINER L7-01;6,6202-9,101.0—J 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/Mew 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. Death E. Depth Phase Code Subcode T Comment 03/04/2015 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 RPEQPITRIP 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 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. 03/06/2015 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 2 of 6 ' 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 into 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 33/09/2015 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. Death 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-in to 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. 33/12/2015 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, In)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 11111 mil 1Loo mil N O I Li C t CU 0 O. W W a ,, a. 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CO 0 CO O N- O N (0 V CO O CO N_ (O O V CO O M V M C- CO C- CO (0 O C- N O V y CO CO O CO CO - N- NCOCO CO CO N- N N CO CO y CO CO CO CO CO v v V VNV V VCv v ° � v V V V V COci CO CO CO CO CO CO CO (O CO (O CO (O CO CO CO (t) (t) CO V CO co- (O CO CO CO CO CO CO (O CO CO CO CO co- CO co- co- CO CO CO 1.-- O O CD CO CO V C• CO 0 CO O C• 0 CO (0 V CO CO CO CO e NiCO O a- a- V CO O COV COC` CO N CO (O ON NOIV a- I 7 O O 7 7 O O O I: o O O r N N n N (O O (O N O Y Q a CO (o CO CO CO O O 88838 83888 O O O O [ a C CO Y N O C- O CO N h V () O V CO V V COCA CO CO O C` N CO M CO (O CO O N 0 CO (O 0 O CO COV C- O (0 COO O C IO v ai N N. o v (d O of O v IO 0i 0 O O O v C) N D aas Q C`^" co CO C- 1� n CO CO CO CO CO CO CO CO CO 0 O 0 0 CO CO O r IAr• E 0co G. 0 t t CO CO N O CO N N CO 0 O (O CO 0 N O CO CO O N N 0 CCI CO d Q .- a- � U CO CO 0 N .- 0 .- V .- CO CO N CO 0 CO CO CO I,- CO 0 0 O = Y OO O O C LE m m m 0) rn rn a, COi m COO oo co m rn rn C) o) CO CO CO OD IE 0 CL co V CO CO CO CO CO CO C CO Cco co co 0O 0 CO CO N 0 CO CO CO CO CO CO 0 (CC) 0 C CO O O O O O O O O O O O O O O O O O O O VN cp M0CO rnCO CD 0 .- V aco (O (O 0 (O (0 COn CO CO 0Nr CO CO 0 (O O0 d1 O C >. 0) CO C 7 O co- CO ( co- o C1 o co- co- CO CO co- co- co- m o0 CO CO CO CO E O U O o r hi m m m a c.) a in 3 3 o 0) 215003 21 5047 RECEIVED MAR 12 2015 Letter of Transmittal r�.■ .__.__ 2 5 5 1 4 2 5 5 1 5 BAKER ( Date. AOGCC DATA LOGGED March 11, 2015 3I V2o15 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. Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BakerHughes.com Yosha Ragbirsingh, Baker Hughes, Survey Manager / Yosha.Ra g g �birsin h BakerHug hes.com �,,�" ,, - ' — ---- __. n LA CO 1` U) tO ,- ii N ' LLI V W > CV 0 ��a_ V O .111 0 M.Q= Ili m C N et I CD 0 Cl. CU WOC a I— ,, Q. U) Z •- O. - ■_ ) = ._ — s - - - Cl) VI' 0) a) o o_ U 0 4 O V it OM O co i ■. 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'a 2 2 U) m N 2 2 (D 8 8 ro m 2 8 CO m cD (D r J > F 2 Z U) 0 w N i i i • W N- CO CO 00)) 0) CO''7 co r co 0 CO O COCCO N N O) CO C N _ 7 U) U) C m C C C O) m r m r C r m (n r 0 C) m 0 N U) m 7 r 0 v (0 0) N 7 N O �' O_ O O N N N C) C) CO CO t N- 0 0 m N CO 7 N- CO O m 0) r O N 0 7 CO 0) CO N COI CO 0 7 CO O 0 7 CO r CO r m U) O r r CA 7 7 (o CO m co- co- m m (0- CD- m m m m m CO co- co- co" m co- co- -_, CV ( C O (0 N7 CO ? r C) O m C r O N U) 7 C) C C) N 2 CD O C+) 7 C) r th r m Cl) o r r O) 7 Y 0 yC o 0 0 0 0 0 0 0 6: 181 '81 0 0 818: g (q CD CO m m m m m m m m CO CO CO m CO m m CD m m m O v m CO CO CO m CO CO CO CO m CO CO CO CO CO CO CO 0 CO CO CO C (U Y e� CCpp N w (CO 0 N N CO O r O N CCD O 00)) CO77 r m N (C'C) Ori Ort Q C N r O) CO N O WcoU) CO O) J )` CV N M CD V W Cm00 rrrm m m m0) CD C NNNO) P 0,N Ns- ,-- ,- 0_ CL VI/� a(B O co _ _ CL Y J J 1 0 l6 l6 N (sl $ p N N r O " C7 O m) I� m O N m m N N O 8 Cda V ^ lV Cn CJ CV M UU a, O) U) U) O) O O) O) O) O) S U Y Y 0 0 0 c ;� m Si m rn m m m rn Zi- m m m m rn g o S m m m m Qcn ea ea. co O N- U CO 0) 0)) CO. 0 v CO O N 0 W 0 00)) O) Om) r r m o CC) O d O d O CO CO U) U) (() ,,,o; (O O O O p O p N O CJ § O) (NO CO N. r 7 r O o (D O C C `) ❑ y CO coC] (00 m (((000 m r r r aD m m W co m O O O co O co Ua E v c6 N OD co- co- co- co- m (O co- Ui CQ co- co- co- co- co- co- co- C C) 0 C T U o •l d a, 0 y O 0 0) i 0 co f T�, Alaska Oil and Gas (c0 \�� I�j,�s� THE STATE., �d���, of Conservation Commission 'anti ALASI�:A T:.-;:t,_-_-5k--,- 333 West Seventh Avenue 2 _ Anchorage, Alaska 99501-3572 �� GOVERNOR BILL WALKER g OF 1"° P Main: 907.279.1433 ALASY+ 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 30-12L1-01 ConocoPhillips Alaska, Inc. Permit No: 215-047 Surface Location: 1019' FNL, 2011' FWL, SEC. 22, T13N, R9E, UM Bottomhole Location: 2570' FNL, 308' 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, f) (t/r Cathy P. oerster Chair DATED this ay of March, 2015. r RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 0 9 2015 PERMIT TO DRILL ���� 20 AAC 25.005 la Type of Work 1 b Proposed Well Class: Development-Oil ❑ Service-Winj ❑ Single Zone 0- lc Specify if well is proposed for: Drill ❑ , Lateral ❑✓ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill ❑ Reentry El Exploratory ❑ Service-WAG ❑✓ , Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name 5. Bond - L_J Blanket U Single Well 11 Well Name and Number ConocoPhillips Alaska, Inc. Bond No. 59-52-180 4 KRU 30-12L1-01 3 Address. 6 Proposed Depth 12. Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD.9100' - TVD: 6610'• 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: 1404'FNL,972'FWL,Sec.22,T13N, R9E, UM 2554 3/9/2015 Total Depth. 9 Acres in Property. 14 Distance to 2570'FNL,308'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• GL Elevation above MSL; . 24 feet to Same Pool 30-11 ,1445 16 Deviated wells: Kickoff depth •7600 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25 035) Maximum Hole Angle , 96° deg( Downhole:4095 psig . Surface:3443 prig- 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 2480 6620' 6574' 9100' 6610' 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 1 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): 6661-6671, 6676-6700 6615-6625, 6630-6654 20 Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Prograrr ❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements ❑✓ 21 Verbal Approval: Commission Representative. Date 22 I hereby certify that the foregoing is true and correct Contact Ron Phillips @ 265-6312 Email 0Ron.L.Phillips(a�cop.com Printed N e D. haus Title CTD Engineering Supervisor?-t' { Signature ,e- �� Phone:265-6120 Date I \ IZ!::'t5 Commission Use Only Permit to Drill API Number Permit Approval See cover letter Number J1-5- 1 50-Qm ^ `a/ '( y—(aI—o0 I Date 3Iq 15 Ifor other requirements 111 Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed m hane,gas hydrates,or gas contained in shales d Other: •*yCre)ps;, ij 0( 1.Z....%F-- Samples req'd: Yes ❑ No Mud log req'd: Yes❑ No V J o H2S measures: Yes M No I❑,f Directional svy req'd: Yes" No❑ 7K'Al IT-44 ei m.+9. Spacing exception req'd: Yes ❑ No L✓J Inclination-only svy req'd: Yes El No APPROVED BY THE Approved by /% COMMISSIONER COMMISSION Dai d 3 -q- /s,'cf' 5, Form 10-401 (Re • ed 1W 1 I` h �eR lit ti1ttm the date of approval(20 AAC 25.005(g)) _3/'j)/ S 0,,,,er RECEIVED ConocoPhillips MAR 09 2015 p Alaska P.O. BOX 100360 AOGCC ANCHORAGE,ALASKA 99510-0360 March 09, 2015 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 permit to drill a dual-lateral out of the Kuparuk Well 30-12 using the coiled tubing drilling rig, Nabors CDR2-AC. The work is scheduled to begin late March 09, 2015. The CTD objective will be to drill two laterals (30-12L1 & 30-12L1-01), targeting the A sand intervals. Note the current A sand perforations will be open below the whipstock. The second lateral 30-12L l-01 will kick-off the 30-12L1 lateral at 7,600' and TD at 9,100' MD. The second ic lateral is to recover A l & A2 pay in the middle of the well and A3 pay at the end of the well. The second lateral will remain in the same polygon, but TVD in the middle of the well should be up to 55' TVD deeper and at the end of the well TVD should be up to 55' TVD shallower. Attached to this application are the following documents: — Permit to Drill Application Form for 30-12L1-01 — Detailed Summary of Operations — Directional Plan — Current Schematic — Proposed Schematic If you have any questions or require additional information please contact me at 907-265-6312. Sincerely, 621/4 Ron Phillips Coiled Tubing Drilling Engineer Kuparuk CTD Lateral NABORS ALASKA 30-12L1 & 30-12L1 -01 CD9 ConocoPhilips Application for Permit to Drill Document RC 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(f)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 30-12L1-01 7 Attachment 2: Current Well Schematic for 30-12L1 7 Attachment 3: Proposed Well Schematic for 30-12L1-01 7 Page 1 of 7 3/9/2015 PTD Application: 30-12L1 &30-12L1-01 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document is 30-12L1 & 30-12L1-01. These laterals 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 & 30-12L1-01. 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 4000 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. r The maximum downhole pressure in the 30-12 pattern is to the southwest with the 30-16A injector at 4095 psi (12.1 ppg EMW).4 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 & 30-12L1-01 laterals 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 & 30-12L1-01 laterals have 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 3/9/2015 PTD Application: 30-12L1 & 30-12L1-01 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 MD MD TVDSS TVDSS Liner Details 2%", 4.7#, L-80, ST-L slotted liner; 30-12L1 7,600' 9,125' 6,574' 6,570' contingency blank liner across belly section, anchored aluminum billet on top 2%", 4.7#, L-80, ST-L slotted liner; 30-12L1-01 6,620' 9,100' 6,515' 6,551' 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 1 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 3/9/2015 • PTD Application: 30-12L1 & 30-12L1-01 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 Target BHP 150 psi 746 psi 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 3/9/2015 PTD Application: 30-12L1 & 30-12L1-01 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 work over, 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. The second lateral 30-12L 1-01 will kick-off the 30-12L1 lateral at 7,600' and TD at 9,100' MD. The second lateral is to recover A l & A2 pay in the middle of the well and A3 pay at the end of the well. The second lateral will remain in the same polygon, but TVD in the middle of the well should be up to 55' TVD deeper and at the end of the well TVD should be up to 55' TVD shallower. A Baker Hughes Thru-Tubing whip-stock will be set inside the 4 '/2" liner at the planned kick off point of 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 7600' MD where an anchored aluminum billet will be set to kick off and drill a second lateral to TD at 9100' 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: RIH 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 with an anchored aluminum billet from TD up to 7600' MD. 3. 30-12L1-01 Lateral(A l, 2 & 3 sands) a. Kick off the aluminum billet at 7600' MD. b. Drill 3" bi-center lateral to TD of 9,100' MD. c. Run 2%" slotted liner from TD upto 6 620' MD,just above topof whipstock. p 4. 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. Page 5 of 7 3/9/2015 PTD Application: 30-12L1 & 30-12L1-01 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 6 of 7 3/9/2015 PTD Application: 30-12L1 & 30-12L1-01 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) (Requirements of 20 AAC 25.402) 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). • 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. 17. Attachments Attachment 1: Directional Plan for 30-12L1-01 Attachment 2: Current Well Schematic for 30-12L1 Attachment 3: Proposed Well Schematic for 30-12L1-01 Page 7 of 7 3/9/2015 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 30 Pad 30-12 30-12L1-01 Plan: 30-12L1-01_wp01 Standard Planning Report 08 March, 2015 r' 1 BAKER HUGHES 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: 30-12L1-01 Design: 30-12L1-01_wp01 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 +EI-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 30-12L1-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2014 2/1/2015 19.01 81.01 57,582 Design 30-12L1-01 wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,570.41 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 0.00 0.00 0.00 225.00 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 7,570.41 91.47 256.28 6,574.53 -377.45 -1,009.74 0.00 0.00 0.00 0.00 7,600.00 90.64 252.47 6,573.99 -385.42 -1,038.23 13.18 -2.80 -12.88 -102.25 7,670.00 83.64 252.47 6,577.48 -406.46 -1,104.85 10.00 -10.00 0.00 180.00 8,020.00 95.98 219.65 6,578.66 -598.87 -1,390.71 10.00 3.53 -9.38 290.00 8,120.00 96.41 229.70 6,567.84 -669.47 -1,460.52 10.00 0.43 10.05 87.00 8,270.00 95.16 214.68 6,552.63 -779.73 -1,560.44 10.00 -0.83 -10.02 266.00 8,340.00 94.63 221.69 6,546.65 -834.51 -1,603.52 10.00 -0.75 10.01 94.00 8,510.00 89.27 205.54 6,540.82 -975.51 -1,697.20 10.00 -3.16 -9.50 252.00 8,590.00 89.27 197.54 6,541.84 -1,049.86 -1,726.54 10.00 0.01 -10.00 270.00 8,740.00 88.78 182.54 6,544.40 -1,197.12 -1,752.62 10.00 -0.33 -10.00 268.00 8,940.00 89.03 162.54 6,548.27 -1,394.38 -1,726.80 10.00 0.12 -10.00 270.50 9,100.00 89.06 178.54 6,550.95 -1,551.67 -1,700.60 10.00 0.02 10.00 90.00 3/8/2015 8:01:37PM Page 2 COMPASS 5000.1 Build 61 • 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: 30-12L1-01 Design: 30-12L1-01_wp01 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +NI-S +E/-W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100ft) (°) (usft) (usft) 7,570.41 91.47 256.28 6,574.53 -377.45 -1,009.74 980.89 0.00 0.00 6,021,419.98 524,640.15 TIP 7,600.00 90.64 252.47 6,573.99 -385.42 -1,038.23 1,006.67 13.18 -102.25 6,021,411.92 524,611.69 KOP 7,670.00 83.64 252.47 6,577.48 -406.46 -1,104.85 1,068.66 10.00 -180.00 6,021,390.65 524,545.15 Start 10 dls 7,700.00 84.67 249.64 6,580.53 -416.15 -1,133.07 1,095.47 10.00 -70.00 6,021,380.86 524,516.96 7,800.00 88.20 240.26 6,586.76 -458.37 -1,223.37 1,189.17 10.00 -69.71 6,021,338.33 524,426.82 7,900.00 91.77 230.92 6,586.79 -514.81 -1,305.77 1,287.34 10.00 -69.13 6,021,281.62 524,344.63 8,000.00 95.29 221.54 6,580.63 -583.76 -1,377.76 1,387.00 10.00 -69.12 6,021,212.43 524,272.88 8,020.00 95.98 219.65 6,578.66 -598.87 -1,390.71 1,406.84 10.00 -69.70 6,021,197.27 524,259.98 4 8,100.00 96.34 227.69 6,570.06 -656.35 -1,445.59 1,486.29 10.00 87.00 6,021,139.61 524,205.31 8,120.00 96.41 229.70 6,567.84 -669.47 -1,460.52 1,506.13 10.00 87.86 6,021,126.44 524,190.42 5 8,200.00 95.79 221.68 6,559.32 -724.99 -1,517.39 1,585.60 10.00 -94.00 6,021,070.73 524,133.74 8,270.00 95.16 214.68 6,552.63 -779.73 -1,560.44 1,654.75 10.00 -94.85 6,021,015.85 524,090.89 6 8,300.00 94.94 217.68 6,549.99 -803.84 -1,578.08 1,684.27 10.00 94.00 6,020,991.67 524,073.34 8,340.00 94.63 221.69 6,546.65 -834.51 -1,603.52 1,723.95 10.00 94.26 6,020,960.92 524,048.00 7 8,400.00 92.76 215.97 6,542.77 -881.14 -1,641.05 1,783.45 10.00 -108.00 6,020,914.17 524,010.64 8,500.00 89.59 206.49 6,540.72 -966.52 -1,692.81 1,880.43 10.00 -108.37 6,020,828.62 523,959.18 8,510.00 89.27 205.54 6,540.82 -975.51 -1,697.20 1,889.89 10.00 -108.56 6,020,819.62 523,954.82 8 8,590.00 89.27 197.54 6,541.84 -1,049.86 -1,726.54 1,963.21 10.00 -90.00 6,020,745.18 523,925.74 9 8,600.00 89.24 196.54 6,541.97 -1,059.42 -1,729.47 1,972.04 10.00 -92.00 6,020,735.61 523,922.84 8,700.00 88.91 186.54 6,543.59 -1,157.26 -1,749.45 2,055.35 10.00 -91.99 6,020,637.71 523,903.20 8,740.00 88.78 182.54 6,544.40 -1,197.12 -1,752.62 2,085.78 10.00 -91.82 6,020,597.84 523,900.17 10 8,800.00 88.84 176.54 6,545.65 -1,257.07 -1,752.14 2,127.84 10.00 -89.50 6,020,537.89 523,900.85 8,900.00 88.97 166.54 6,547.57 -1,355.84 -1,737.46 2,187.29 10.00 -89.38 6,020,439.19 523,915.88 8,940.00 89.03 162.54 6,548.27 -1,394.38 -1,726.80 2,207.01 10.00 -89.18 6,020,400.69 523,926.67 11 9,000.00 89.03 168.54 6,549.28 -1,452.45 -1,711.83 2,237.48 10.00 90.00 6,020,342.68 523,941.84 9,100.00 89.06 178.54 6,550.95 -1,551.67 -1,700.60 2,299.70 10.00 89.90 6,020,243.50 523,953.41 Planned TD at 9100.00 3/8/2015 8.01:37PM Page 3 COMPASS 5000.1 Build 61 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 30 Pad 30-12 30-12L1-01 30-12L1-01_wp01 Travelling Cylinder Report 08 March, 2015 r' 1 BAKER HUGHES Baker Hughes INTEQ Iffr 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: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 30-12L1-01 Database: OAKEDMP2 Reference Design: 30-12L1-01_wp01 Offset TVD Reference: Offset Datum Reference 30-12L1-01_wp01 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 7,570.41 to 9,100.0ousft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,104.10usft Error Surface: Elliptical Conic Survey Tool Program Date 3/8/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 100.00 6,600.00 30-12(30-12) GCT-MS Schlumberger GCT multishot 6,626.00 7,570.41 30-12L1 (30-12L1) MWD MWD-Standard 7,570.41 9,100.00 30-12L1-01_wp01 (30-12L1-01) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 9,100.00 6,609.95 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 30-02-30-02A-30-02A 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 30-06-30-06-30-06 Out of range 30-10-30-10-30-10 Out of range 30-11-30-11-30-11 Out of range 30-12-30-12L1-30-12L1 7,600.00 7,600.00 0.01 0.86 -0.86 FAIL-Minor 1/10 30 15 30 15 30 15 Out of range 30-16-30-16-30-16 Out of range 30-16-30-16A-30-16A Out of range 30-16-30-16AL1-30-16AL1_wp07 Out of range 30-16-30-16AL1-01-30-16AL1-01_wp02 Out of range 30-16-30-16AL1-02-30-16AL1-02_wp02 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 3/8/2015 7:32:07PM Page 2 of 5 COMPASS 5000.1 Build 65 o ,., {A O N W 0 1 = O _- N .0 h N ,...... 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TRANSMITTAL LETTER CHECKLIST WELL NAME: KA U. 3 O - /3/.I -6 PTD: c213--O`I-7- Development ✓ ervice _Exploratory _Stratigraphic Test _Non-Conventional FIELD: iUE,r— POOL: 14, a Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit V LATERAL No. ;•i- 0`-j I , API No. 50-`O.2 - a 2011 - 130 - o (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name)in the attached application,the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(dX2XB) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion,suspension or abandonment of this well. Revised 2/2015 L 1i 1. N 0) O a) Q , � C a). , , C a, . . . Z. ; , , s, ; . , , . ; . . . . m; a' �, N N o, N To' a 4 :a . , . >. .6, . a 4 y w, �, vco 3' a ' ' a oi' a E, a ca O . . ' c. ) . O' ; . c; t, c y, r d' a D . . ' t' in. O? . , . 1Q0, N a, j� .d . C. , N rq v, 'C3 CI CL a). , a N t .t„ _. N' o. N, N, 3. N. N, O, pdj, y, N 0. 0, O, 0 o O' > c, c a) m. 3 c ., c . Q cTy " 4 N' . Q , , W a. P_'' o ai �, �, U, U, . , , Y. , c a . . iy a, , , , co, , C N 0, . N, CV, ,' D, N, N, i , 0 V, .. 0. o J, a) g 11, O a O' N, is Z ' 00, (•') Q. M (? , N, M, E =, , N, l0, iv O) (1), ,O, , a, C. 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