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215-212
1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Temporary flowback > 30 days Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9768 feet None feet true vertical 6575 feet None feet Effective Depth measured feet 7620 feet true vertical feet 6386 feet Perforation depth Measured depth 8512-9649 feet True Vertical depth 6588-6622 feet Tubing (size, grade, measured and true vertical depth) 3.5 L-80 7796 6528 Packers and SSSV (type, measured and true vertical depth) Baker F Packer No SSSV 7620 6386 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name:Devin Kozak Authorized Title:Petroleum Engineer Contact Email:devin.kozak@conocophillips.com Contact Phone:(907) 263-4121 2. Operator Name Name: ConocoPhillips Alaska, Inc. 8. Well Name and Number:KRU 3O-06L1-01 WINJ WAG 47 Water-Bbl MD 115 4,707 0 Oil-Bbl measured true vertical Packer 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf P. O. Box 100360, Anchorage, Alaska 99510 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 1251015 Casing Pressure Tubing Pressure ADL025513 N/A 1369 700 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 215-212-0 50-029-21824-61 None measuredPlugs Junk measured N/A Conductor Surface Intermediate Production 5. Permit to Drill Number: 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 319-085 1400 Size Kuparuk River Field / Kuparuk River Oil Pool Authorized Signature with date: Authorized Name: Devin Kozak Liner Length 79 4,672 8,113 1,140 Casing Structural 16 12 7 2.375 8,146 9,652 TVD 115 4,090 6,588 Burst Senior Engineer: Senior Res. Engineer: Collapse 6,814 Development Service GINJ SUSP SPLUG Gas Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 12:12 pm, Jun 09, 2020 Devin Kozak Digitally signed by Devin Kozak Date: 2020.06.09 10:03:01 -08'00' RBDMS HEW 6/10/2020 VTL 7/27/20 SFD 6/10/2020DSR-6/9/2020 1 ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 June 9th, 2020 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, ConocoPhillips Alaska, Inc. reports the conversion of Kuparuk River Unit Well 3O-06, 3O-06L1, 3O-06L1-01, 3O-06L1-02, 3O-06L1-03, and 3O-06L1-04 from Oil Production to Water Alternating Gas Injection on 5/31/2020. 3O-06 was operating as an injector and had been injecting until 11/2/2018 when it was shut-in and flow back operations started 2/27/2019 for reservoir pressure management ahead of offset CTD drilling. Enclosed you will find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. regarding 3O-06 (PTD# 188-060), 3O-06L1 (PTD# 215-211), 3O-06L1-01 (PTD# 215-212), 3O-06L1- 02 (PTD# 215-213), 3O-06L1-03 (PTD# 215-214), and 3O-06L1-04 (PTD# 215-215). If you have any questions regarding this matter, please contact me at 907-263-4121. Sincerely, Devin R. Kozak Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Sundry application, Well schematic, Well operations report Casing Strings Casing Description CTD L1-01 Slotted Liner OD (in) 2 3/8 ID (in) 1.992 Top (ftKB) 8,500.1 Set Depth (ftKB) 9,652.0 Set Depth (TVD) … 6,587.6 Wt/Len (l… 4.60 Grade L-80 Top Thread ST-L Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Zone Date Shot Dens (shots/f t)Type Com 8,512.0 9,649.0 6,621.9 6,587.8 A-1, 3O-06 12/28/2015 SLOTS Notes: General & Safety End Date Annotation NOTE: Comment SSSV: NONE3O-06L1-01, 1/28/2016 8:44:04 AM Vertical schematic (actual) CTD L1-01 Slotted Liner; 8,500.1-9,652.0 SLOTS; 8,512.0-9,649.0 PRODUCTION; 33.0-8,145.8 IPERF; 7,898.0-7,918.0 APERF; 7,867.0-7,891.0 WHIPSTOCK; 7,855.0 APERF; 7,849.0-7,859.0 Liner; 7,797.4 XO Enlarging (Tubing); 7,796.4 NIPPLE; 7,752.7 PBR; 7,623.5 SEAL ASSY; 7,620.5 PACKER; 7,620.2 Locator; 7,613.0 GAS LIFT; 7,555.9 GAS LIFT; 7,021.4 GAS LIFT; 6,328.6 GAS LIFT; 5,414.9 SURFACE; 35.0-4,707.3 GAS LIFT; 4,217.3 QSTV Tubing Shut Off; 3,495.9 GAS LIFT; 2,708.6 CONDUCTOR; 36.0-115.0 HANGER; 33.0 CTD L1 Window; 0.0 Annotation Last Tag: Depth (ftKB) End Date Annotation Rev Reason: ADD LATERALS, GLV C/O Last Mod By lehallf End Date 1/27/2016 KUP PROD KB-Grd (ft) 34.98 Rig Release Date 6/24/1988 Annotation Last WO: End Date 3O-06L1-01 H2S (ppm) Date ... TD Act Btm (ftKB) 9,652.0 Well Attributes Wellbore API/UWI 500292182461 Field Name KUPARUK RIVER UNIT Wellbore Status PROD Max Angle & MD Incl (°) 99.97 MD (ftKB) 8,740.49 3O-06L1-01 DAILY REPORT WELL OPERATIONS 5/31/2020: 3O-06L1-01 was converted from production to injection to provide injection support at 3O- 04. Flow lines have been bolted back to normal injection and a passing MIT-IA to 3050 psi was complete. I. Operations Performed: .1 STATE OF TI ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Abandon Plug Pertorations- Suspend ❑ PFracture Stimula Pull Tubing ertorate ❑ Other Slimula❑ Operations shutdown Plug for Redrill ❑ ertorate New Pool ❑ Alter Casing ❑ Repair WSJ Re-enter Sus Well Change Approved Program ❑ COnOCOPhiIIIpS Alaska, Inc. 4 Well Class Before Work: P ❑ Other: Temporary Flowback > 30 days Development ❑ Exploratory 5. Permit to Drift Number: P. 0. Bax 100360, Anchorage, Alaska Stratigraphic ❑ p ry ❑ 215-212-0 99510 Service Q 6. API NUmher- and Printed data per 50-029-21824-61 KRU 30-06L1-01 • �� alulc nroer 1=1e1d / Ku aruk River Oil of Total Depth measured g 768 feet true vertical �� Plugs measured X575 feet Junk None feet Effective Depth measured None feet measured feet true vertical— Packer measured _feet 7620 feet Casing true vertical 6386 feet Length Structural Size MD Conductor TVD Burst 79 16 Collapse Surface 16 115 115 Intermediate 12 4,707 Production 4,090 8,113 7 Liner 1,140 8,146 2.375 9,652 6,814 Perforation depth 6,588 P Measured depth 8512-9649 feet True Vertical depth6=feet Tubing (size, grade, measured and true vertical depth) 3.5 L-80 Packers and SSSV (type, measured and true vertical de th 7796 6529 P ) Baker F Packer No SSSV 12. Stimulation or cement squeeze summary: 7620 6386 6 Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-MGf Prior to well operation: 0 0 Water -Bbl Casing pressure Subsequent to operation: 1 950 Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, a 25.283) 20 1080 2649 2269 1450 Daily Report of Well Operations. -Irk 15. Well Class after work: 110 Copies of Logs and Surveys Run ❑ Exploratory ❑ Development Q Service Printed and Electronic Fracture Stimulation Data ❑ GS OR Status after work: ❑ Stratigraphic ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil 0 Gas ❑ WDSPL ❑ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ Sundry Number or N/oA if C.O.empt: Ex Authorized Name: Devin KOZak I ` 085 Contact Name: Devin Kozak Authorized Title: Petroleum En ineer Contact Email: devi Dan.kozak@conocophillips.com luthorized Signature: _Date. 8/16/2019 Contact Phone: (907) 263-4121 Form 10-404 Revised 4/2017 RBDMS U6 2 3 2019 Submit Original Only ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 August 16th, 2019 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, ConocoPhillips Alaska, Inc. reports the conversion of Kuparuk River Unit Well 30-06, 30-061-1, 30-061-1-01, 30-061-3-02, 30-061-1-03, and 30-06L1-04 Water Injection Service to Oil Production. 30-06 was operating as an injector and had been injecting until 11/2/2018 when it was shut-in and flow back operations started 2/27/2019 for reservoir pressure management ahead of offset CTD drilling. A second 10-404 will be submitted after completion of the temporary flowback and conversion from production back to injection. Enclosed you will find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. regarding 30-06 (PTD# 188-060), 30-06L1(PTD# 215-211), 30-06L1-01(PTD# 215-212), 30-06L1- 02 (PTD# 215-213), 30-061-1-03 (PTD# 215-214), and 30-06L1-04 (PTD# 215-215). If you have any questions regarding this matter, please contact me at 907-263-4121. Sincerely, Devin R. Kozak Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Sundry application Well Schematic 30-061-1-01 DAILY REPORT WELL OPERATIONS 2/2712079: 30-061-1-01 was converted from injection to production to reduce the reservoir pressure in the fault block surrounding 30-04. THE STATE °'ALASKA GOVERNOR MIKE DUNLEAVY Devin Kozak Petroleum Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Alaska Oil and Gas Conservation Commission Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 30-06L1-01 Permit to Drill Number: 215-212 Sundry Number: 319-085 Dear Mr. Kozak: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.o[aska.gov Enclosed is the approved application for the 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, Daniel T. Seamount, Jr. Commissioner DATED this day of February, 2019. RB�M A, FEB VA 16 5 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon LJ Plug Perforations LJ Fracture Stimulate Li Repair Well Li Operations shutdown Li Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Temporary Aowback> 30 dayEEI 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocOPhllll s Alaska Inc. Exploratory ❑ Development ❑ Stratigraphic ❑ Service 0 . 215-212-0 3. Address: 6. API Number IF P. O. Box 100360, Anchorage, Alaska 99510 50-029-21824-61-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? , KRU 30-060-01 Will planned perforations require a spacing exception? NA Yes El No 11 9. Property Designation (Lease Number): �ii d s%l 10. Field/Pool(s): ADL025513 Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9,768' 6,575' Casing Length Size MD TVD Buret Collapse Structural Conductor 79' 16" 115' Surface 4,672' 12" 4,707' Intermediate Production 8,113' 7" 8,146' Liner j 1,140' 2.375" 9.652' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3.500" L-80 7,886' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER - BAKER F PACKER, no SSSV MD= 7620 TVD= 6386 12. Attachments: Proposal Summary _�Ij Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigrephic ❑ Development ❑✓ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/25/2019 OIL Q WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Devin Kozak Contact Name: Devin Kozak Authorized Title: Petroleum Engineer Contact Email: devin.kozak@conocophillips.com Contact Phone: (907) 263-4121 Authorized Signature: Date: 2/21/2019 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: ❑ F�8161019 Post Initial Injection MIT Req'd? Yes ❑ No C1 M� Spacing Exception Req fired? Yes ❑ No E�( Subsequent Form Required: l0., yp t' Rgp APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: �l2-S(// / 7 auband 41IL'o,aad 4/201]Approved aPPI a oI1 oALmthe date of approval. M"Atcmen<sin Duplicate ti .0w� -j-:x a- OZ4Z4 ( ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 February 2111, 2019 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, ConocoPhillips Alaska, Inc. requests approval to temporarily flow back Kuparuk River Unit Well 30-06, 30-0611, 30-0611-01, 30-0611-02, 30-061-1-03, and 30-061-1-04 Water Injection Service to Oil Production. The purpose of the temporary flowback, exceeding 30 days is to reduce the reservoir pressure in th-e—fa—u-Ft-6 lock surrounding Kuparuk River Unit Well 30-04 for Coiled Tubing 12r ling development. The flowback will help to reduce the reservoir pressure in the fault block for lower dril ing mud weight for the 30-04 CTD drilling candidate. Initial flowback of 30-06, 30-0611, 30-0611-01, 30-0611-02, 30-061-1-03, and 30-061-1- 04, upon approval, is targeted on February 251h, 2019. Enclosed you will find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 30-06 (PTD# 188-060), 30-0611 (PTD# 215-211), 30-061-1-01 (PTD# 215-212), 30-0611-02 (PTD# 215-213), 30-0611-03 (PTD# 215-214), and 30-06L1-04 (PTD# 215-215). If you have any questions regarding this matter, please contact me at 907-263-4121. Sincerely, Devin Kozak L✓ `� Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Sundry application 1 KUP INJ WELLNAME 30-06 WELLBORE 30-06L1-01 Conoc(� Well Attributes Max AngleB MD TD �'"�"���II''ias FIeM Name WeII Wre APV11Wl WeIICwe SYtua ncl t'1 MO (flNB1 M[BNn tXNB) Alaska, Inc. KUPARUK RIVER UNIT 500292182461 INJ 9.97 874049 9,6520 ast WO'. 30LBL1O1. Y21 Raf91$:10.65 PM Last Tag yxEUl acneme�c(.1) Annotation Depth (MMS) End Dek WNICue L"'Motlay _...... CTD a Winm«. Do __.._....."IATag: 30-061_1-01 1e6a11 NA"GER, a0 Last Rev Reason Anneniion End Do. weNBwa Laat Motley Rev Reason: ADD LATERALS, GLV 01 1/2112016 30-081-1-01 ideadNe Casing Strings caainODascnvNon o00n1 CTO 1_1-01 Slotted Liner 23/8 Io On) 199 Top laKel 8,500.1 3eL Deptn (m(BI fiat Depen lrvD)_. wulen(L_ord. 9,652.0 6,567.6 4.fi0 L -8D Tap Tnrtae ST -L Perforations & Slots caluoucroa: x.an50 6X11 xna T.,JVD) Btm 1rvD1 lsnonm GAS LIFT: 3,]1_8.0 IP tttNBt BM 1"X81 1X681 (NNBt LinkZone caset Type Com 8,5120 9,649.0 6,6219 6,5828 A-1,30-06 12/2812015 SLOTS Notes: General & Safety End Dade I Ann.tion OSNTWry 6MCT.3KiB NDTE'. GASLIET:L3113 ..uaFPLE:35.,7073 .UFra.alae W6 UFT. eme GAS UFT: ].0314 GASUFTL7.555.6 Lemdr.76130 P MR: 6FAL PSSY: 1 170a.3 PMi', ],Ba. . NIPPLE', 7,703.] XO loomp y ITUGp): 7,79dd Ire. 77W.4 A➢ERE7.51067,8500- WXIP8TooN 7.855.0 APERF. 7.W0. 7,891 On- IPERF:7,Mo7G1a0_ PROWOTON:33.08,14ES F�y 81_078: B,51309,WP,0 _ ll. OTD U-01 Mdad B,YO.tA852.0 STATE OF ALASKA AIDA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdow n /— Performed: Suspend r Perforate I— Other Stimulate r Alter Casing rChange Approved Program " Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: PROD to WAG 9- 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratory r 215-212-0 3.Address: 6.API Number: P. 0. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service " 50-029-21824-61 7.Property Designation(Lease Number): 8.Well Name and Number: ADL025513 KRU 30-06L1-01 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 9768 feet Plugs(measured) None true vertical 6575 feet Junk(measured) None Effective Depth measured 9768 feet Packer(measured) 7620 true vertical 6575 feet (true vertical) 6386 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79' 16 115' 115' SURFACE 4668' 9 5/8 4707' 4090' PRODUCTION 8113' 7 8146' 6814' SLOTTED LINER 1140' 2 3/8 9652' 6588' Perforation depth: Measured depth: 8512-9649s 20 7 U6 3 1 2016 True Vertical Depth: 6622-6588 SCAti�,0 JAN tV 3 AOGCC � G Tubing(size,grade,MD,and TVD) 3 1/2 ,L-80, 7886 MD,6529 TVD Packers&SSSV(type,MD,and TVD) SSSV= None PACKER= BAKER F PACKER @ 7620 MD and 6386 ND 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-Bbi Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut-In Subsequent to operation 5848 540 1076 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations I✓ Exploratory r Development r Service 17 Stratigraphic r Copies of Logs and Surveys Run - 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG 17 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: 316-391 Contact Darrell Humphrey/Bob Christensen Email: n1139(p�conocophillips.com Printed Name ►:-rt B. C rstensen Title: NSK Production Engineering Specialist Signature �� ./ Phone:659-7535 Date 5/3 Q f C C7 lam-, vn /z/ l (- d //6 RBDMS (iV SEP - 1 2016 Form 10-404 Revised 5/2015 Submit Original Only • 30-06L1-01 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 08/15/16 PULL GLV @ 2708' RKB, PULL OV @ 7021' RKB. SET DV'S @ 7021, 4217 &2708' RKB. CIRC-OUT 165 BBLS INHIBITIED SEAWATER &90 BBLS DIESEL DOWN TBG UP IA TAKING RETURNS TO PRODUCTION ON 30-08. U-TUBE TO BALANCE FREEZE PROTECT. PERFORM PASSING MIT-IA TO 2500psi, PULL CATCHER @ 7752' RKB, JOB IN PROGRESS 08/16/16 PULLED 2.81"XX PLUG W/GAUGES (2575 PSI) @ 7752' RKB. JOB COMPLETE. 08/18/16 Open well to Injection service 08/28/16 (ISW) INITIAL STATE WITNESSED (Guy Cook) MITIA PASSED TO 3300 PSI • • low' KUP INJ 30-06L1-01 • I ConocoPhillips ;' woa;Att1110ted Max Angle a MD' TD Alaska,Inc, I bornAPPU1M Fled Wane Well6or.Stalin nalc1 MD(fmKtil Act Btu.P663 E. ,0Ft-'i, ',. W0292182401 KUPARI.E RIVER UNIT I84J I 99.97 8,740.49 9,652.0 Cornmeal NII84pplaa fob Annotation End nate KB-GF400 RIO 60(00000010 ••. ...: 3O-06L1m;Iwf?01P 1W46Cornmeal17444 SSSV-NODE 150 1/2112016 Last WO- 34.98 6124119'88 ...VrBol edMns6a taalyalj Annotation Depth 466B) End Dade Annotation Rod By End Date CTD a W dav;oo ..............Last Tap: Rev Reason'ADD LATERALS,GLV COO leB 1/2772016 ... NANf.Fr4;33. 141101't.lir( _ •'' 3 O Gal Top IBK61 ' p Sat Depth(TV(}) i,n rade lop Thnnd i CTD L1-01 Slotted Liner 2 318 1.992 8 5001 9 652.0 6,587.6 4.60 L-80 ST-L Snot'�..k."..---, Tap(1V03 8h0(81(11") W�) N KI Top(AK* &n96(8) (sKB) (nxttl 2006 ante A) Typo Coal 11- 85120 9,649.0 6,621.9 6,587.8 A-1,30-06 12/2812015 SLOTS CON00070R;36.0-115.0 I . L ___ End Dab Annotation GAS IFT;2,706.6 II NOTE: I II I 0S1V TtNSWn2 SO1F,3,4956 1..i ilGAS UFT;4,217.3 I I'iSURFACE:5504,707-3 GAS UFT,SA II 0 I I GAS LIFT;8,3766 ; 1.: a I I GAS LIFT;7,021.4 4 1 a II GAS LIFT,7.565.9. , 1 : I Lawny 7.6133 #I. PACKER;7,620.2 - SEAL ASSY;7,620.5 di--'.1 MR;7,623.5 t'.;r • IF a NIPPLE,7,752.7 I' KO EGnylxg riding),7,700.4 tine,7,767.4 i APERF;7,619.0-7,850 0- WHIPSTOCK 7.855.0 L APERF;7,13WO7,091A-. I MERE;7,68.0770130.--. PROOLICTON;33.0$145.6 I SLOTS;6,512 0-0,049.0 03511-01 LUIGI Uses 6.60.1.4.520 tiOF T4,r • I//7:.• THE STATE Alaska Oil and Gas • of/\ T A S KA Conservation Commission Witt 333 West Seventh Avenue " `— GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 rh,, •• Main: 907.279.1433 �� Fax: 907.276.7542 www.aogcc.alaska.gov Robert D. Christensentub- FEB all, NSK Production Engineering Specialist Salm ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 30-06L1-01 Permit to Drill Number: 215-212 Sundry Number: 316-391 Dear Mr. Christensen: 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. Foerster Chair DATED this 2-ay of August, 2016. RBDMS t,v AUG - 2 2016 • • RECEIVED STATE OF ALASKA JUL 2 7 • ALASKA OIL AND GAS CONSERVATION COMMISSION 07.2 of t /4 APPLICATION FOR SUNDRY APPROVALS AOGC 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Repair Well r Operations shutdow n I-- Suspend r Perforate r Other Stimulate E Pull Tubing r Change Approved Program r Rug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing r Other: PROD to WAG 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r, 215-212-0 • 3.Address: Stratigraphic r Service "' 6.API Number: P. 0. Box 100360,Anchorage, Alaska 99510 50-029-21824-61 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA Will planned perforations require spacing exception? Yes r No / KRU 30-06L1-01 - 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL025513 ' Kuparuk River Field/Kuparuk River Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: ,(f4 MPSP(psi): Plugs(MD): Junk(MD): 9768 6575 94QQ 948' GS'S e' 6Y5' 2075 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79' 16 115' 115' SURFACE 4668' 9 5/8 4707' 4090' PRODUCTION 8113' 7 8146' 6814' SLOTTED LINER 1140' 2 3/8 9652' 6588' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8512-9649 • 6622-6588 3 1/2 L-80 7886 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) SSSV=NONE PACKER=BAKER F PACKER • MD=7620 TVD=6386 12.Attachments: Proposal Summary F7 WellBore Schematic p 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service 17 • 14.Estimated Date for 15. Well Status after proposed work: 08/01/16 OIL r WIND r WDSPL r Suspended r Commencing Operations: 16.Verbal Approval: Date: GAS r WAG F 4 GSTOR E SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact: Darrell Humphrey/Bob Christensen Printed Name Robert D. Christensen Phone:659-7535 Email: n1139t?a conocoohillips.com Title: NSK Production Engineering Specialist Signature ,gic.441:; Date: ��ZS1 ` ` Commission Use Only ` (Q Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3iV-3°14 Rug Integrity r BOP Test r Mechanical Integrity Test cation Clearance r Other: Post Initial Injection MIT Req'd? Yes No r_,_/ Spacing Exception Required? Yes r No I✓ Subsequent Form Required: `0 — Li 0 Li- i.tcF- s4 t APPROVED BY Approved by:ate.(4,71()),L441........_ COMMISSIONERIp THE COMMISSION Date:IJ 2"/6 •Pi`j' ?141c.(I� ‘ 7 ,4 V 7-/2�G / Lrovai. Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 1�n o�ttl Gn1h of Attachments in Duplic to RBDMS �L- AUG - 2016 • 30-06L1-01 • DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert Kuparuk Well 30-06, 06L1, 06L1-01, 06L1-02, 06L1- 03, and 06L1-04 (PTD's# 188-060, 215-211, 215-212, 215-213, 215-214 and 215-215)from Oil Production service to Water Alternating Gas Injection service as the pre-production period has been completed. Area of Review: Kuparuk well 30-06 was completed as an injector on 7/20/15 to provide enhanced recovery injection into the reservoir to increase the ultimate recovery of oil. This well will support existing offset producers 30-08 and 3R- 26. The top of the Kuparuk A3 sand was found at 7833' and/6558' tvd The top of the Kuparuk A2 sand was found at 7860' and/6580'tvd The top of the Kuparuk Al sand was found at 7876' and/6593'tvd Area Map with 1/4 mile radius around target injection zone (see attached): The map attached shows that, with the exception of the offset producers 30-04 &3R-26, there are no additional production/injection wells located within a 1/4 mile radius of the 30-06, 06L1, 06L1-01, 06L1-02, 06L1-03, 06L1-04 penetrations of the Kuparuk interval. Mechanical Condition of Well to be Converted: The mechanical condition of Kuparuk well 30-06 is good and is classified as a "CTD horizontal penta-lateral" well. The injection tubing/casing annulus is isolated via a Baker Packer located at 7620' and (6416' tvd). A State-witnessed MIT-IA will be performed once well 30-06 is converted to water injection, online, and stabilized. CBL and interpretation of the cement quality: See attached AOR Detail The 16" Conductor was cemented with 181 sx AS II. The 9-5/8" Surface casing was cemented with 1650 sx AS Ill &300 sx Class"G". The 7" Production casing was cemented with 300 sx Class "G" & 175 sx AS I. I S \ \\\\ 2 1 I72,,cE \\\ - 1298 { ;) [ );) ! /}}} /11\\} /\[ >© 2, _- 21 E ;/ 22 §( .e : - .& !# r- \ : f&r7A ;k)k . \/ ; : f» .#\ ) ! § )\2 �2\)) )\\ ))§ 8 & ) j\ {- f! { © `¥/ ^2®l2222d!)IiG )/;2¥tr(}�+)¥$ r(/21 '45!= Rt \ \\\�if-\`i- ƒ\\ �\)`� E �{ten a . 23 ' - s - g "3 . e ; y _ 2 } ! \ \ y - \{\ \\ \) a , 2 § . ! ,g ° `4- § - ) \ \ \ ` w • ujII TT; _ -5 _3 3 3b . . . . . O w 2« � \ \ . Q /� //\ : /\ \ \I \ — 2 » !»; _ 20. { \ \ /\ \ 2222/\ �\ \ } } \ / § § § , , , • • ADL355023 Kuparuk River Unit 3R-26 16 0°.-30-06L1-04 30-06L1-03 30-04 30-06%'',.., ADLO �. 30-06L1-02 30-06L-1-01 30-06L11 30 0 21 1/4 Mi. Radius Well Open Interval 1 30-06 30-06 30-06L1 30-06L1 25Jul16 30-06L1-01 30-06L1-01 ConocoPhillips 30-06L1-02 30-06L1-02 30-06L1-03 Alaska, Inc. ❑30-06L1-03 Injection Swap Analysis [\J 30-06L1-04 30-06L1-04 30-06& Laterals Well Pad o 0.08 0.16 0.24 0.32 --- Well Within Radius Miles KUP PROD • 30-06L1-01 ConocoPhillips 0 Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/OW' Field Name Wellbore Status ncl(1 MD(ftKB) Act Btm(ftKB) • m,�yyyp� '' 500292182461 KUPARUK RIVER UNIT PROD I 99.97 8,740.49 9,652.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 30-06L1-01,1/28/2016 8.44.04 AM SSSV:NONE Last WO: 34.98 6/24/1988 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date CTD Lt Window,0.0E Last Tag: Rev Reason:ADD LATERALS,GLV C/O lehallf 1/27/2016 HANGER,33.0 Ire „mala ,,,. ay,,., ,,.W Casing Strings g escription OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WVLen(I...Grade Top Thread Casing CTD L1-D01 Slotted Liner 2 3/8 1.992 8,500.1 9,652.0 6,587.6 4.60 L-80 ST-L Perforations&Slots Shot Dens ti. : Top(TVD) Btm(TVD) (shots lf Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 8,512.0 9,649.0 6,621.9 6,587.8 A-1,30-06 12/28/2015 SLOTS CONDUCTOR;36.0-115.0-4 Notes:General&Safety End Date Annotation GAS LIFT;2,708.6 NOTE: OSTV Tubing Shut Off 3,495.9 r2 GAS LIFT;4,217.3 i SURFACE;35.0-4.707.3 f GAS LIFT;5,414.9 _ GAS LIFT;6,328.6 GAS LIFT;7,021.4 GAS LIFT;7,555.9 Locator;7,613.0 PACKER;7,620.2 ... .t,. SEAL ASSY;7,620.5- n I.1 PBR;7,623.5 jl'�Ii is j NIPPLE:7,752.7 XO Enlarging(Tubing);7,796.4 Liner;7,797.4 APERF;7,849.0-7.859.0— WHIPSTOCK 7,855.0 i APERF;7,867.0-7,891.0 (PERF;7,898.0-7,9180 PRODUCTION;33.0.8,145.8 4 .la SLOTS;8,512.09.649.0 CTD L1-01 Slatted Liner; 8,500.1-9,652.0 0 • o ' O I • N a- 1 - 0 E E •/ •ctJ o) 0) a a • 0 0 Z \�Qi) ,. ':...i O O 17 C co ( O. 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Z 2 U is o 0 CD.o 0 w °) ILI Z W c 02 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 u E = Q W J 0 0 o 0 0 0 wWw 0 Ww Q d re C > 0W o W • 0 +� N m III i)c) C O O J ¢ N J J C Q co as 0 N W Q SII C C (n L T b c7 7 W U O Q M 2 Q Q > r2C �I 2 m 2 2 1- - m Q 1 oOI N u) �n a o Z Z H Y o 0 0 o U a m Q J V I J U J J J J N 2 2 '., O m O I O O O = CO U U J I J O �I O ml O O O O 11 11 V 9 ai 2 hi cu i i ui ui hi Z U. a) IL t/) IL it it it C us ox--.. Q I'I 7 C C a U U U U a) /VI ZO U _N NI _N�I _N N N _N 0 0 . co G LI < N W O W O W W W W O N a) W a cc CD m m CO m Q« a :° ° CL J V o o o o o o Em E �) 0 W J N N N N N N a3 3 Q 2 to )n to in in in N Z a) IX aa @ O iL E c.) N W z v CD N °) 0 J a) as 0) Od V Q E o E m Z13- e vIt)i J co °' NN Q ° m oocJ . I I E ° io 2 0 a co rCD ao N o o ON E et 6w SNI V o0 d o J } } E N Q _ la o E I- 0. ° aco173 H Zco w I o @ @ > a d m _ z O -rn a5 Ca re c 0 1- E Y r ss •. fo d r CO • 0 U) c rn c.„ t~a Co 0 Cl) c ) Q • Co \ C N111 Y co cc6) a) 11 I— a) O C- 0_ a O (6 H Q Z EI'' • U >. O 0 • U o 2 0 I as Z CO CO CO CO CO m m )n • in D 0 as 0 0 CO 0 0 Q o CD o' C Z N N Q Q Q Q Q Q £ D I N o >, - ,- .- A w W g II CO N I— IN- ; N- N- F- 7 c W E a 0 a) N coin co N N N N co co co co 0) W 'C N d O. a) W o E ` 2 N > •7 la R 0 Ce a), 0 0 a) C I O CO co sp . 1 Z II " co- °) 0 0 U U U U O Q O O a) Q O O J .12- C CD C U • , re m E OC7 E c 1 OO O -o NO" NC)g O4 ) Q0 0 QQQQ % 2 0 O U 0 0 O a. IW W W W W WiLi' a 0 c.) 0 0 • STATE OF ALASKA II 2. ALASKA OIL AND GAS CONSERVATION COMMISSION • 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 r Alter Casing 9 r Change Approved Program r Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: WAG to PROD I✓ 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 215-2120 3.Address: 6.API Number: Stratigraphic r Service F P. 0. Box 100360,Anchorage,Alaska 99510 50-029-21824-61 7.Property Designation(Lease Number): 8.Well Name and Number: ADL025513 KRU 30-06L1-01 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 9768 feet Plugs(measured) None true vertical 6575 feet Junk(measured) None Effective Depth measured 9768 feet Packer(measured) 7620 true vertical 6575 feet (true vertical) 6386 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115 115' SURFACE 4672.3 9 5/8 4707.3 4090' PRODUCTION 8112.8 7 8145.8 6814' SLOTTED LINER 1151.9 2 3/8 9652 6588' RECEIVED Perforation depth: Measured depth: 8512-9649 FEB 1 0 2016 True Vertical Depth: 6622-6588 GCC Tubing(size,grade, MD,and ND) 3.5, L-80, 7796 MD,6529 TVD AO Packers&SSSV(type,MD,and ND) SSSV= None PACKER-BAKER F PACKER @ 7620 MD and 6386 ND 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 shut-in Subsequent to operation 265 2733 3454 10 220 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development 1 Service r Stratigraphic r- Copies of Logs and Surveys Run r 16.Well Status after work: Oil ry 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.O.Exempt: N/A Contact Darrell Humphrey/Bob Christensen Email: n1139c conocophillips.com Printed Name Robert D. Christensen Title: NSK Production Engineering Specialist Signature O / Phone:659-7535 Date r '1 a/V111, kTi- zft'/I‘, RBDMS FEB 1 0 2016 n�'/ 0- Form 10-404 Revised 5/2015 /4 iff74 Submit Original Only • • 30-06L1-01 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 12/18/15 CDR2 added 5 Laterals: 30-06L1, L1-01, L1-02, L1-03, & L1-04 01/09/16 SET CATCHER @ 7752' RKB; PULLED DV'S @ 7021', 6328', 5414', &4217' RKB; SET OV 01/10/16 PULLED DV @ 2709' RKB; SET GLV'S @ 4217' &2708' RKB (OBTAIN GOOD IA DDT) 01/11/16 Well turned to production • KUP PROD • 30-06L1-01 ConocoPhillips g Well Attributes Max Angle&MD TD Fi i'1$I(a,Inc. Wellbore APIIUWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Otto(ftKB) cc.�r.,co'vreetps 500292182461 KUPARUK RIVER UNIT PROD 99.97 8,740.49 9,652.0 --- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 30-afi1_1-01,1/28/20168:44:04 AM SSSV: NONE Last WO: 34.98 6/24/1988 Vertcal schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date cTD a Wiopos8.00� Last Tag. Rev Reason:ADD LATERALS,GLV C/O lehallf 1/27/2016 HANGER;33.0 la.W Casing Strings Lasing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CTD Li-01 Slotted Liner 2 3/8 1.992 8,500.1 9,652.0 6,587.6 4.60 L-80 ST-L Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shots// Top(ftKB) Bhn(ftKB) (ftKB) )ftKB) Zone Date t) Type Corn 8,512.0 9,649.0 6,621.9 6,587.8 A-1,30-06 12/28/2015 SLOTS CONDUCTOR;36.0-115.0 Notes:General&Safety End Date Annotation GAS LIFT;2,708.8 _ NOTE'. OSTV Tubing Shut Off;3,495.9 I a GAS LIFT;4,217.3 SURFACE;35.0-4,707.3 41 GAS LIFT;5,414.9 err GAS LIFT;6,328.6 GAS LIFT;7,021.4 - GAS LIFT;7,555.9-I Locator;7,613.0 PACKER;7,6202 T' ' SEAL ASSY;7,620.5- s PBR;7,623.5 i e I�I a NIPPLE;7,752 7 I 80 Enlarging(Tubing);7,796.4 Liner;7,797.4 APERF;7,849.0-7,859.0 WHIPSTOCK;7,855.0 APERF;7,867.0-7,891.0- I IPERF;7,898.0-7,918.0-� PRODUCTION;33.0-8,145.8 A SLOTS;8,512.0-9,649.0 --- CTD L1-01 SUIted Liner; I I 8,500.1-9,652.0 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a.Well Status: Oil 0 Gas❑ SPLUG❑ Other ❑ Abandoned ❑ Suspended❑ 1 b.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ❑ WAGE WDSPL❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp., Susp., or�� 14. Permit to Drill Number/ Sundry: 3 ConocoPhillips Alaska, Inc. Abend.: 1/A/2016 215-212 . 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 12/27/201550-029-21824-61-00 - 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 832'FNL, 1904 FWL, Sec 22,T13N, R9E, UM 12/28/2015 KRU 30-06L1-01 Top of Productive Interval: 9. Ref Elevations: KB: 59 17. Field/Pool(s): 3845 FNL,4094 FWL, Sec 16,T13N, R9E, UM GL: 24 BF:24 Kuparuk River Field/Kuparuk Oil Pool• Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4742 FNL,310 FEL,Sec 16,T13N, R9E, UM 9652/6588 ADL 25513 4b. Location of Well(State Base Plane Coordinates, NAD 27). 11.Total Depth MD/TVD-0„ 19. Land Use Permit: Surface: x- 525541 y- 6021987 Zone- 4 6575 'Tilolo/(0c}5 2554 TPI: x- 522439 y- 6024244 Zone- 4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 523319 y- 6023349 Zone- 4 NONE 1967/1840 5. Directional or Inclination Survey: Yes RI (attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 n/a (ft MSL) 8557/6624 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion,suspension, or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to: mud log,spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance,dipmeter,formation tester,temperature, cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary l . ° . FEB 022016 GR/Res �`�' AOGGC 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16 62.5 H-40 36 115 36 115 24 181 sx ASII 9.625 36 J-55 35 4707 35 4090 12.25 1650 sx AS III &300 sx ClassG 7 26 J-55 33 8146 33 6814 8.5 300 sx CIG&175 sx ASI 2 3/8 4.6 L-80 8500 9652 6621 6588 3 Slotted Liner 24.Open to production or injection? Yes 2 No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3.5 X 5.5 7886 7620/6385 Slotted Liner from 8500-9652=MD,6621-6588=TVD COMPLETION 26.ACID, FRACTURE, CEMENT SQUEEZE, ETC. DATE Was hydraulic fracturing used during completion? Yes❑ No 0 1/31201(0 Per 20 AAC 25.283(i)(2)attach electronic and printed information VERIFIED DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED IA- 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing,gas lift,etc.): 1/11/2016 Flowing Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 1/18/2016 21 Test Period 149 1812 3040 176/176 12129 Flow Tubing Casino Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API (corr): Press. 237psiq 480psiq 24-Hour Rate _ 171 2071 3474 25.5 api(1/15/2016) Form 10-407 Revised 11/2015 YT- 2`l 1/ 4 CONTINUED i,ry PAGE 2 �, �' ` Submit ORIGINIAL only1A-RBDMS � FEB 2 2 2016 iic3 .vc' ( • i 28.CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No 0 If Yes, list formations and intervals cored(MD/TVD, From/To), and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No RI Permafrost-Top Surface Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1967 1840 .. Attach separate pages to this form, if needed, and submit detailed test 'FP l %coc Go,to71 information, including reports,per 20 AAC 25.071. A2 8722 6611 Fault 1 (A2 UT/A3 DT) 9650 6588 A3 9650 6588 A5 9731 6580 TD(Kuparuk A3) 9768 6575 Formation at total depth: A4 31. List of Attachments: Summary of Daily Operations, Definitive Survey, Schematic Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey, core analysis, paleontological report,production or well test results,per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. (�(1 Contact: -on Phi .s • 265-6 2 Email: Ron.L.Phillipscop.com K-` Printed Name: Mailif � Title: CTD Engineering Supervisor Signature: Phone: 263-4372 Date: 21 k J k INSTRUCTIONS General: This form a • e required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection, Salt Water Disposal,Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension, or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection, Gas Injection, Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only 0 • 0 0 ID 0 II CI1 m 0 d 2 p 1 1 0 g 2Q- 11 2 f 0) COcor 1 1 -t• 3 a-8 rn 11 � c I--a co N W cu 0 1 1 C E a 0 o-0 1 11 - a) E 2_ B 1 1 I o cc)t. Y W �.:fl LI0 11 (Ca co— 1 O� rCD 3 Oco N I1I 111 MN Y N 0 N. F❑-- C 11 1 v __ 11 N fY co CD a) Y aai r l 1 1 1 11 v m IYal E a Li 0 11 11 11 I� `7 = or N aoo co off' It \ \ 11 > o N°� W��� O\ I I \ \ 1l co ch N CIL- `° (JdY N a) W J 11 \ \ 1 m ID r: m a°r°01MIdJ 11 \\ I 1 >, m EN X `-mnn� \ 1 \\ I I H a m m o -o cur m 1 w Y Y m 1 1 \ CO a 00 E 0j Y r C- Et y \ \ \ a) w a✓Y oCE r urni�NCC \ 1 11 p _y � m 0rrnv W m mr.N a o_ r N-m m \ \1 cO o CD NI r E d m....cs...m 1 \ I ( co iv X m �n cn' \ 1 / / Y Em CC u) H-X`n`n 4 1 t 1/ U � `°Y m CO W co+ in m m rn O/x n0_ S o7 ,tj4� m 11 // N N N in a) a) N N X r_ C I I // �� co co „3- r�in�7-a I I M M C)c[) m 07 (`7 up C7 6 cri H / // / -- '\ 1 / / 1 1 A 1 1 • / • / 1 Y I I gill W L •4+ 41) O i .....r"'"j . U � i I ,,, ', O ® r• N //' tt 2 m 111I o� �o nmm°' rn /// I( rn0 t _� mN. a- -rsZ. ri 0 / / II G,0 ,n❑ #r ch© ma) co / (( _ )nom CV© o Qrrr LO I( t1 0300 m't al ° o a r I 1 1 n m (Ni m 0 co N 0 03 A( 1 1 0 r 1 _ ® o o ilI 11 Q7 L_ i1 11 NL_ rn 3 II I I 03 � C II 11 H- c oa oa a _ 0 J p J O CO N N O= Oi O\ O\ cC N CO N KUP P OD 30-06L1-01 6. Con©coPhillkps Z Well AttribL Max AngD TD Alaska.Inc Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD( ) Act Btm(ftKB) CrxocoPhnptps 500292182461 KUPARUK RIVER UNIT PROD 99.97 8,740.49 9,652.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 30-06L1-01,2w201610'33'.21 AM SSSV: NONE Last WO' 34.98 6/24/1988 Vertical schemanc.(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date CTD a Window;0.0, Last Tag: Rev Reason:ADD LATERALS,GLV C/O lehallf 1/27/2016 HANGER;330-ill t c�Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...I Grade Top Thread CTD L1-01 Slotted Liner 2 3/8 1.992 8,500.1 9.652.0 6,587.6 4.60 L-80 ST-L Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 8,512.0 9,649.0 6,621.9 6,587.8 A-1,30-06 12/28/2015 SLOTS CONDUCTOR,36.0-115.0 ► Notes:General&Safety End Date Annotation GAS LIFT;2,708.6 NOTE OSTV Tubing Shut 011 3,495.9 GAS LIFT;4,2173 . SURFACE;35.0-4,707.3 da L GAS LIFT,5,414.9 GAS LIFT;6,328.6 <- GAS LIFT,7021.4 GAS LIFT,7.555.9 let Locator;7,613.0 PACKER;7,620.2 _ SEAL ASSY,7,620.5-, 1 PBR;7,623.5 4 B NIPPLE;7,752.7. X0 Enlarging(Tubing);7,796.4 i, Liner,7,797.4 APERF;7,849.0-7,859.0 WHIPSTOCK 7,855.0 APERF,7,867.0.7891.0-. (PERF,7,&95.0-7918.0- PRODUCTION;33.0-8,145.8 SLOTS;8,512.0-9,649.0 CTD L1-01 Slotted Leer, I 8,500.1-9,6520 • . of 111Operations Summary (with Timelog Depths) 30-06 Conocc hillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log • Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/20/2015 12/20/2015 4.00 MIRU MOVE MOB T Waiting on Peak SOW.Three Nabors 0.0 0.0 13:00 17:00 rigs moving at same time. 12/20/2015 12/20/2015 2.00 MIRU MOVE MOB P PJSM with Peak crew.Move modules 0.0 0.0 17:00 19:00 off of 30-01 12/20/2015 12/20/2015 3.50 MIRU MOVE MOB P ,Spot rig modules over Well 06.Peak 0.0 0.0 19:00 22:30 change out at 20:00 12/20/2015 12/21/2015 1.50 MIRU MOVE RURD P RU checklist, RU interconnect(Putts). 0.0 0.0 22:30 00:00 berm cellar,clean up around 30-01. 12/21/2015 12/21/2015 3.00 MIRU MOVE RURD P Continue RU checklist,check tree 0.0 0.0 00:00 03:00 flange bolts,none loose,30 mins to check.MU MP and cellar lines. 12/21/2015 12/21/2015 1.00 MIRU WHDBOP NUND P Nipple up BOPE stack,intall fusable 0.0 0.0 03:00 04:00 cap,open IA and OA. Rig accept:04:00 on 12/21/15 12/21/2015 12/21/2015 2.00 MIRU WHDBOP RURD P Continue rig up.swap out riser 0- 0.0 0.0 04:00 06:00 rings,Prep for BOPE test. 12/21/2015 12/21/2015 7.50 MIRU WHDBOP BOPE P Perform initial BOPE test 250/4,300 0.0 0.0 06:00 13:30 psi,annular 250/2,500 psi.Test waived by(AOGCC)Jeff Jones. 12/21/2015 12/21/2015 2.50 SLOT WELLPR PRTS P PJSM.Load coil,test inner reel iron 0.0 0.0 13:30 16:00 and TT line. 12/21/2015 12/21/2015 1.95 SLOT WELLPR MPSP P PJSM with FMC and two valve shop 0.0 0.0 16:00 17:57 crews.Pull TWC,LD FMC equipment. 12/21/2015 12/21/2015 1.40 MIRU WHDBOP PRTS P PJSM-Pressure test PDL's 2,500 psi. 0.0 0.0 17:57 19:21 12/21/2015 12/21/2015 0.50 MIRU WHDBOP RURD P PJSM-Cycle test Orbit valve, Initial 0.0 0.0 19:21 19:51 T/I/O 1300/566/38,unable to bleed tubing down,cycle Orbit valve CLOSED,bleed tubing to 0 psi. 12/21/2015 12/21/2015 0.50 PROD1 WHPST SFTY P Pre spud with Nathan Wheelers crew 0.0 0.0 19:51 20:21 and all third party. 12/21/2015 12/21/2015 0.50 PROD1 WHPST OWFF P WHP 48 psi,bleed to 0 psi,a little gas, 0.0 0.0 20:21 20:51 no flow for 20 minutes,PJSM. 12/21/2015 12/21/2015 1.00 PROD1 WHPST PULD P MU BHA#1,0.6°AKO motor and 0.0 74.3 20:51 21:51 DSM to CoilTrak,surface test, 12/21/2015 12/21/2015 1.65 PROD1 WHPST TRIP P RIH with BHA#1 while circulating, 74.3 7,250.0 21:51 23:30 establishing returns to TT,stop at 164 ft.,pressure WH to 1,000 psi,cycle Orbit valve OPEN,WHP 1,130 psi, continue RIH. 12/21/2015 12/22/2015 0.50 PROD1 WHPST DLOG P 7,250 ft., Begin strip log HRZ to 7,250.0 7,465.0 23:30 00:00 TOWS,Tie in at K1 for minus 6 ft. correction 12/22/2015 12/22/2015 0.65 PROD1 WHPST DLOG P 7,465 ft.Continue strip log HRZ to 7,465.0 7,840.0 00:00 00:39 TOWS,Tie in at K1 for minus 6.5 ft. correction. 12/22/2015 12/22/2015 1.10 PROD1 WHPST DISP P Displace well to milling fluid.Close 7,840.0 7,861.5 00:39 01:45 EDC.No losses during fluid swap, 1:1 returns.Dry tag pinch point at 7,862 ft. PUW 31k, **Note:Bled IA down from 1,000 psi to 200 psi. Page 1/13 Report Printed: 1/20/2016 Operations Summary (with Timelog Depths) 0Lk 30-06 ConocoPhitlips Al,rks Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/22/2015 12/22/2015 5.75 PROD1 WHPST WPST P 7,861.5 ft. Begin milling window per 7,861.5 7,865.7 01:45 07:30 recomended practice 1.52 bpm at 3,654 psi FS,BHP 4,120 psi,WHP 399,IA 220,OA 219 12/22/2015 12/22/2015 0.45 PROD1 WHPST WPST P PUH,to turn TF around stops,pump 7,865.7 7,865.7 07:30 07:57 off,bring pump on,check TF,Good, RBIH 5 fpm,stacked out at the TOWS at 7856 ft,PUH RBIH at 20 fpm clean past TOWS. 12/22/2015 12/22/2015 4.00 PROD1 WHPST WPST P 7865.7 ft,Continue milling window, 1.5 7,865.7 7,868.0 07:57 11:57 bpm at 3680 FS,WHP 380,BHP 4280, IA 761,OA 881 12/22/2015 12/22/2015 1.25 PROD1 WHPST WPST P 7868 ft,milling rathole down to 7876 7,868.0 7,876.0 11:57 13:12 ft. 12/22/2015 12/22/2015 1.50 PROD1 WHPST REAM P 7876 ft,back ream window area,high 7,876.0 7,876.0 13:12 14:42 side TF,30 ROHS,and 30 LOHS, performed dry drift clean. 12/22/2015 12/22/2015 0.55 PROD1 WHPST TRIP P 7850 ft,Perform annular friction test 7,876.0 7,876.0 14:42 15:15 above window,WH 281,Choke 300, Pump rate 1.5 bpm,Annular pressure 4024,ECD 11.96. 12/22/2015 12/22/2015 1.50 PROD1 WHPST TRIP P POOH,following MP schedule. 7,876.0 74.3 15:15 16:45 12/22/2015 12/22/2015 0.75 PROD1 WHPST OWFF P OOH,functioned closed orbit valve, 74.3 74.3 16:45 17:30 PJSM,check well for flow 12/22/2015 12/22/2015 0.75 PROD1 WHPST PULD P LD BHA#1,Mill and String Reamer 74.3 0.0 17:30 18:15 both 2.79"no-go,reconfigure BHA, crew change, PJSM. 12/22/2015 12/22/2015 1.25 PROD1 DRILL PULD P MU BHA#2,2.4°-AKO motor and RB 0.0 72.2 18:15 19:30 HCC Bi-center bit,MU to CoilTrak, surface test.Open EDC,cycle OPEN Orbit valve. 12/22/2015 12/22/2015 0.50 PROD1 DRILL SVRG P Service choke. 72.2 72.2 19:30 20:00 12/22/2015 12/22/2015 1.90 PROD1 DRILL TRIP P RIH with BHA#2 72.2 7,560.0 20:00 21:54 12/22/2015 12/22/2015 0.25 PROD1 DRILL DLOG P Log K1 for minus 8 ft.correction, 7,560.0 7,840.0 21:54 22:09 Continue in hole. 12/22/2015 12/22/2015 0.75 PROD1 DRILL DISP P Displace well to 9.3 ppg FloPro drilling 7,840.0 7,840.0 22:09 22:54 mud,Close EDC,PUW XXk,RBIH, clean thru window. 12/22/2015 12/23/2015 1.10 PROD1 DRILL DRLG P 7,876 ft. OBD 1.5 bpm at 3,368 FS, 7,876.0 7,940.0 22:54 00:00 BHP 4,087 psi,WHP 390,IA 160,OA 130 12/23/2015 12/23/2015 3.40 PROD1 DRILL DRLG P 7,940 ft. OBD 1.51 bpm at 3,587 psi, 7,940.0 8,155.0 00:00 03:24 BHP 4,121 psi,WHP 397,IA 280,OA 235 12/23/2015 12/23/2015 0.25 PROD1 DRILL DRLG P 8,155 ft.ROP picked up to 100 fph at 8,155.0 8,155.0 03:24 03:39 8,140 ft,WOB 0.8k,—20 bph losses, pick up hole,PUW 31k,clean,RBIH 12/23/2015 12/23/2015 1.00 PROD1 DRILL DRLG P 8,155 ft. BOBD 1.69 bpm at 4,126 8,155.0 8,280.0 03:39 04:39 psi,BHP 4,214 psi,WHP 404,IA 365, OA 351,WOB 1.5k,ROP 150,slowly healing,adjust choke gradually for gas cut mud,little crude in returns 12/23/2015 12/23/2015 0.35 PROD1 DRILL WPRT P Wiper trip to window,PUW 28k 8,280.0 7,900.0 04:39 05:00 Page 2/13 Report Printed: 1/20/2016 'la 0 Operations Summary (with Timelog Depths) 30-06 ConoccP'hiilip*s Asks Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/23/2015 12/23/2015 0.20 PROD1 DRILL WPRT P Wiper back in hole. 7,900.0 8,280.0 05:00 05:12 12/23/2015 12/23/2015 1.25 PROD1 DRILL DRLG P 8,280 ft. OBD 1.64 bpm at 4140 psi, 8,280.0 8,410.0 05:12 06:27 BHP 4,250 psi,WHP 426,IA 310,OA 345 12/23/2015 12/23/2015 0.50 PROD1 DRILL TRIP P 8410 ft,TD build section,PUH through 8,410.0 7,890.0 06:27 06:57 window. PUW 32k 12/23/2015 12/23/2015 0.25 PROD1 DRILL TRIP P 7890 ft,perform jog in hole to 7970 ft 7,890.0 7,890.0 06:57 07:12 12/23/2015 12/23/2015 1.50 PROD1 DRILL TRIP P 7890 ft,continue POOH,jetting 5.5". 7,890.0 72.2 07:12 08:42 12/23/2015 12/23/2015 0.50 PROD1 DRILL OWFF P At surface,function closed orbit valve, 72.2 72.2 08:42 09:12 1000 psi WHP,check well for flow, PJSM with rig crew for LD build BHA on a dead well. 12/23/2015 12/23/2015 0.75 PROD1 DRILL PULD P LD build section BHA#2 72.2 0.0 09:12 09:57 12/23/2015 12/23/2015 0.75 PROD1 DRILL PULD P PU/MU lateral section BHA#3, 0.0 72.2 09:57 10:42 surface test coiltrak tools 12/23/2015 12/23/2015 1.50 PROD1 DRILL TRIP P RIH with ultra low bend motor 0.4 ako, 72.2 7,565.0 10:42 12:12 lateral BHA#3 with new hycalog bi- center bit.Function open orbit valve. 12/23/2015 12/23/2015 0.25 PROD1 DRILL DLOG P 7565 ft,Log K1 down to 7607' 7,565.0 7,607.0 12:12 12:27 correction of minus 8.0 ft, 12/23/2015 12/23/2015 0.50 PROD1 DRILL TRIP P 7607 ft,Continue RIH to bottom, 7,607.0 8,410.0 12:27 12:57 12/23/2015 12/23/2015 5.55 PROD1 DRILL DRLG P 8410 ft,BOBD 1.60 bpm at 3800 psi, 8,410.0 8,810.0 12:57 18:30 BHP 4130,WHP 240,IA 27,OA 118 12/23/2015 12/23/2015 0.35 PROD1 DRILL WPRT P Wiper trip up hole,PUW 32k. 8,810.0 8,000.0 18:30 18:51 12/23/2015 12/23/2015 0.35 PROD1 DRILL WPRT P Wiper back in hole 8,000.0 8,810.0 18:51 19:12 12/23/2015 12/24/2015 4.80 PROD1 DRILL DRLG P 8,810 ft.OBD 1.58 bpm at 4,107 psi, 8,810.0 9,090.0 19:12 00:00 BHP 4,194 psi,WHP 292,IA 391,OA 375 12/24/2015 12/24/2015 1.45 PROD1 DRILL DRLG P 9,090 ft.OBD 1.57 bpm at 4,053 psi, 9,090.0 9,210.0 00:00 01:27 BHP 4,228 psi,WHP 500,IA 473,OA 375 12/24/2015 12/24/2015 1.00 PROD1 DRILL WPRT P Wiper to window,PUW 34k,jet/jog 9,210.0 7,840.0 01:27 02:27 BTP,sat down at top of window at 7,864 ft twice, PU and run thru at 25 fpm turning the bit slightly with no problem. 12/24/2015 12/24/2015 0.20 PROD1 DRILL DLOG P Log RA for a plus 2.5 ft correction. 7,840.0 7,900.0 02:27 02:39 12/24/2015 12/24/2015 0.50 PROD1 DRILL 'WPRT P Wiper trip back in hole. 7,900.0 9,210.0 02:39 03:09 12/24/2015 12/24/2015 4.75 PROD1 DRILL DRLG P 9,210 ft.OBD 1.56 bpm at 3,962 psi, 9,210.0 9,610.0 03:09 07:54 BHP 4,270 psi,WHP 356,IA 482,OA 471 12/24/2015 12/24/2015 0.50 PROD1 DRILL WPRT P 9610 ft,Wiper up hole to 8450 ft,PUW 9,610.0 8,450.0 07:54 08:24 32k 12/24/2015 12/24/2015 0.50 PROD1 DRILL WPRT P 8450 ft,Wiper back in hole.RIW 8k, 8,450.0 9,610.0 08:24 08:54 stacking between 9000 ft to 9200 ft. 12/24/2015 12/24/2015 6.00 PROD1 DRILL DRLG P 9610 ft,BOBD 1.6 bpm at 3750 psi 9,610.0 9,893.0 08:54 14:54 FS,BHP 4327,WHP 345,IA 556,OA 525 Page 3/13 Report Printed: 1/20/2016 ,:40 Operations Summary (with Timelog Depths) 30-06 ConocoPhillips , Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/24/2015 12/24/2015 3.00 PROD1 DRILL TRIP P 9893 ft,POOH for agitator,PUW 33k, 9,893.0 72.2 14:54 17:54 pump 5x5 sweep ****Note: Per Cerbrus perdiction-due to low ROP,loss of surface weight, and unable to geo steer. 12/24/2015 12/24/2015 0.25 PROD1 DRILL OWFF P On surface,cycle Orbit valve 72.2 72.2 17:54 18:09 CLOSED,monitor for flow.PJSM-LD BHA 12/24/2015 12/24/2015 0.70 PROD1 DRILL PULD P LD BHA#3,bit condition 1-1-NO-A-X-I 72.2 0.0 18:09 18:51 -NO-BHA 12/24/2015 12/24/2015 0.80 PROD1 DRILL PULD P PJSM- MU BHA#4,Agitator 0.0 78.5 18:51 19:39 #W973692-1,0.6°AKO motor and RR 1-1 HCC Bi-center bit.MU to CoilTrak, surface test. 12/24/2015 12/24/2015 1.50 PROD1 DRILL TRIP P RIH with BHA#4 to 200 ft.surface test 78.5 7,570.0 19:39 21:09 agitatror at 1.4 bpm,agitator working, cycle Orbit Valve OPEN,continue in hole. 12/24/2015 12/24/2015 0.20 PROD1 DRILL DLOG P Tie in at K1 for minus 7.5 ft. 7,570.0 7,600.0 21:09 21:21 correction. 12/24/2015 12/24/2015 0.95 PROD1 DRILL TRIP P Continue RIH 7,600.0 9,893.0 21:21 22:18 12/24/2015 12/25/2015 1.70 PROD1 DRILL DRLG P 9,893 ft. OBD 1.47 bpm at 3,869 psi 9,893.0 10,018.0 22:18 00:00 FS,BHP 4,296 psi,WHP 444,IA 315, OA 310. 12/25/2015 12/25/2015 1.20 PROD1 DRILL DRLG P 10,018 ft. OBD 1.47 bpm at 3,869 psi 10,018.0 10,067.0 00:00 01:12 FS,BHP 4,296 psi,WHP 444, IA 315, OA 310 12/25/2015 12/25/2015 1.00 PROD1 DRILL DRLG T 10,067 ft.Diferentially stuck,PU 48k 10,067.0 10,067.0 01:12 02:12 to 54k,no movement,shut down pumps 15 minutes,BHP 4,040 psi down to 4,000 psi,stack-10k,PU 80 fpm to 64k,pipe free on second attempt. 12/25/2015 12/25/2015 1.00 PROD1 DRILL WPRT P Wiper to window,make up 20 bbl of 10,067.0 7,880.0 02:12 03:12 5%lube pill 12/25/2015 12/25/2015 0.15 PROD1 DRILL DLOG P Tie in to RA for plus 4.5 ft.correction. 7,880.0 7,900.0 03:12 03:21 12/25/2015 12/25/2015 1.00 PROD1 DRILL WPRT P Wiper back in hole,pump 20 bbl of 7,900.0 10,067.0 03:21 04:21 5%lube pill. 12/25/2015 12/25/2015 2.50 PROD1 DRILL DRLG P 10,067 ft..OBD 1.46 bpm at 4,020 psi 10,067.0 10,146.0 04:21 06:51 FS,BHP 4,300 psi,WHP354,IA 405, OA 395.Pill to bit.still seing poor weight transfer until 8 bbls of pill around bit,CWT-1.5k to 4k,WOB.8k to 1.5k,confer with town,up system to 2%lubes 12/25/2015 12/25/2015 6.00 PROD1 DRILL DRLG P 10,146 ft,Bring mud system up to 10,146.0 10,400.0 06:51 12:51 2.5%lubes(1.25%Lotorq, 1.25% 776),Drilled ahead 1.5 bpm at 4043 psi,3850 psi FS,BPH 4310,WHP 352, IA 465,OA 400 12/25/2015 12/25/2015 1.75 PROD1 DRILL WPRT P 10,400 ft,TD L1 lateral,pump 10x10 10,400.0 7,800.0 12:51 14:36 sweep,wiper up hole to the window, Pull through window,jet 5.5"7,800 ft, RBIH to log RA marker 12/25/2015 12/25/2015 0.25 PROD1 DRILL TRIP P 7,800 ft,RBIH to log RA marker 7,800.0 7,885.0 14:36 14:51 12/25/2015 12/25/2015 0.25 PROD1 DRILL DLOG P RBIH,tie into RA marker correction of 7,885.0 7,925.0 14:51 15:06 plus 3.0 ft, Page 4/13 Report Printed: 1/20/2016 • • 0'... ,, Operations Summary (with Timelog Depths) r 30-06 cmifr� Atar;k, Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/25/2015 12/25/2015 1.00 PROD1 DRILL TRIP P 7,925 ft,RBIH to confirm TD. 7,925.0 10,402.0 15:06 16:06 12/25/2015 12/25/2015 0.50 PROD1 DRILL TRIP P Confirm TD 10,402 ft,PUH,by-pass 10,402.0 10,402.0 16:06 16:36 high pressure screens,line up to circulate liner running pill.PUW 35k 12/25/2015 12/25/2015 1.15 PROD1 DRILL TRIP P 10,402 ft,POOH laying in 9.3 ppg liner 10,402.0 7,865.0 16:36 17:45 running pill with beads 12/25/2015 12/25/2015 1.00 PROD1 DRILL CTOP T 7,865 ft.slight bobble,motor stall,bit 7,865.0 7,865.0 17:45 18:45 stuck in bottom of window,TF rolled to 228°,PU heavy-8k,attempt to orientate, RBIH stack 3k,go to neutral,try to orientate,stack no more than 7k,PU-6k to-12k,no joy,BHP 3,980 psi. NOTE:8 cycles,max pull 31k. 12/25/2015 12/25/2015 2.40 PROD1 DRILL CTOP T Discuss options with town,PUH/RIH 7,865.0 7,865.0 18:45 21:09 incrementaly stacking 8k to 12k, pulling-10k to-14k,pressuring backside up to 1,000 psi WHP,slight movement noticed,TF 220°stacking, moves to 150°pulling -14k,BHP 3,980 to 4,080 psi. NOTE:30 cycles toal,Max pull 40k. 12/25/2015 12/25/2015 1.70 PROD1 DRILL CTOP T Discuss with town our findings,OK to 7,865.0 7,640.0 21:09 22:51 stack/pull max limits,line up to pump down backside,pressure backside (WHP)up incrementaly 735 psi to 1,700 psi,BHP 3,980 to 4,500 psi, stacking 8k to 13k while pulling to-18 (43k CWT)BHA frees up on 4th cycle at max pressure 1700 psi WHP. NOTE:38 cycles total with pipe at this point.A gain of 8%coil life,Max pull 43k 12/25/2015 12/26/2015 1.15 PROD1 DRILL CTOP T 7,640 ft.bleed pressures,realign 7,640.0 4,800.0 22:51 00:00 pumps.POOH finish laying in beaded pill,Paint EOP flag 5,900 ft. 12/26/2015 12/26/2015 0.90 PROD1 DRILL TRIP T Continue POOH,laying in completion 4,800.0 78.5 00:00 00:54 fluids. 12/26/2015 12/26/2015 0.25 PROD1 DRILL OWFF T On surface,cycle Orbit vale CLOSED, 78.5 78.5 00:54 01:09 monitor for flow. PJSM-LD BHA 12/26/2015 12/26/2015 1.10 PROD1 DRILL PULD T LD BHA#4,Bit condition(pics in 78.5 0.0 01:09 02:15 folder)scar on motor body from bit box to bend wear pad,wear pad gouged. 12/26/2015 12/26/2015 1.70 PROD1 DRILL PULD T PJSM-MU BHA#5,0.6°motor and 0.0 63.4 02:15 03:57 DSM and string reamer,both 2.79"no- go,no vibration pup in BHA,change out checks,MU to CoilTrak,surface test. 12/26/2015 12/26/2015 1.55 PROD1 DRILL TRIP T RIH with BHA#5. 63.4 7,570.0 03:57 05:30 12/26/2015 12/26/2015 0.20 PROD1 DRILL DLOG T Tie in to K1 for minus 7.5 ft. 7,570.0 7,590.0 05:30 05:42 correction. Page 5/13 Report Printed: 1/20/2016 • • 0 Operations Summary (with Timelog Depths) 30-06 ConocoPhillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/26/2015 12/26/2015 0.65 PROD1 DRILL TRIP T Continue in hole,ease thru window 1 7,590.0 7,870.0 05:42 06:21 fpm,1.6 bpm at 3,736 psi FS,BHP 4,084 psi,WHP 241,IA 106,OA 83, seen a little motor work at 7,863.4 ft. 12/26/2015 12/26/2015 1.50 PROD1 DRILL REAM T Back ream window area HS,30 L/R 7,870.0 7,870.0 06:21 07:51 and 45 L/R,little to no motor work seen,dry drift window,clean 12/26/2015 12/26/2015 0.50 PROD1 DRILL TRIP T Line up and circulate 9.3ppg liner 7,870.0 7,870.0 07:51 08:21 running pill down hole. 12/26/2015 12/26/2015 2.15 PROD1 DRILL TRIP P 7870 ft,POOH,laying in beaded 9.3 7,870.0 63.4 08:21 10:30 ppg liner running pill up to 6300 ft, ' painting EOP flag at 5900 ft, 12/26/2015 12/26/2015 1.00 PROD1 DRILL PULD P PJSM,LD window milling BHA#5 63.4 0.0 10:30 11:30 12/26/2015 12/26/2015 0.50 COMPZ1 CASING PUTB P PJSM,prep rig floor,liner ops 0.0 0.0 11:30 12:00 12/26/2015 12/26/2015 3.50 COMPZ1 CASING PUTB P PU/MU L1 slotted liner assembly 0.0 1,829.6 12:00 15:30 12/26/2015 12/26/2015 1.75 COMPZ1 CASING RUNL P RIH,with L1 liner assembly with 62 1,829.6 7,792.1 15:30 17:15 joints of slotted liner,Liner Top Billet, and coiltrak tools. 12/26/2015 12/26/2015 1.20 COMPZ1 CASING RUNL P 7792 ft,correct to the EOP flag 7,792.1 10,400.0 17:15 18:27 correction of minus 8.5 ft.PUW 32k, continue RIH,no problem with liner, billet or BHA down thru window, 10k RIW to bottom at 10,400 ft. PUW 33k, stack minus 5k,release off liner 1.5 bpm at 3,800 psi,PUW 27.5k,lost 4k WOB,reset counters,TOL at 8,560 ft. 12/26/2015 12/26/2015 2.00 COMPZ1 CASING TRIP P POOH for kick off/drilling BHA,no 8,560.0 44.2 18:27 20:27 problems back thru window area, clean. 12/26/2015 12/26/2015 0.30 COMPZ1 CASING OWFF P At surface,CLOSE Orbit valve,PJSM 44.2 44.2 20:27 20:45 LD BHA 12/26/2015 12/26/2015 0.75 COMPZ1 CASING PULD P LD liner running BHA#6,flat spot 13 ft 44.2 0.0 20:45 21:30 above CTC 12/26/2015 12/27/2015 2.50 PROD2 STK CTOP P Cut 17 ft pipe,re-head,pull test 35k, 0.0 0.0 21:30 00:00 MU Upper Quick Connect,MEG line, good,P/T CTC 4,000 psi, 12/27/2015 12/27/2015 1.50 PROD2 STK PULD P PJSM-MU BHA#7,0.5°motor and 0.0 72.2 00:00 01:30 RR 1-1 HYC bi-center bit,MU to CoilTrak,surface test,change out pack-offs.OPEN Orbit valve,EDC open,pump 1.5 bpm for 15 minutes. 12/27/2015 12/27/2015 1.55 PROD2 STK TRIP P RIH with BHA#7 72.2 7,565.0 01:30 03:03 12/27/2015 12/27/2015 0.20 PROD2 STK DLOG P Tie in to K1 for minus 8.0 ft. 7,565.0 7,592.0 03:03 03:15 correction. 12/27/2015 12/27/2015 0.65 PROD2 STK TRIP P Continue RIH,Close EDC,PUW 7,592.0 8,557.0 03:15 03:54 above window 31k,RBIH,clean thru window.Dry tag top of billet at 8,557.71 ft 12/27/2015 12/27/2015 1.35 PROD2 STK KOST P 8,557 ft. Kick off billet per 8,557.0 8,560.0 03:54 05:15 recomended practice 1.5 bpm at 3,810 psi,BHP 4,170 psi,WHP 244, IA 30, OA 70. 12/27/2015 12/27/2015 0.75 PROD2 DRILL DRLG P 8,560 ft,Drill ahead 10 fph,20 fph, 8,560.0 8,610.0 05:15 06:00 Page 6/13 Report Printed: 1/20/2016 • • t 0..;.t'_' Operations Summary (with Timelog Depths) ..t 30-06 ConocoPhilliips dlxks Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(ftKB) 12/27/2015 12/27/2015 0.50 PROD2 DRILL WPRT P 8,610 ft,PUH to 8,530 ft,PUW 28k, 8,610.0 8,610.0 06:00 06:30 dry drift kickoff point,2k bobble at 8,559 ft 12/27/2015 12/27/2015 5.00 PROD2 DRILL DRLG P 8,610 ft,BOBD 1.5 bpm at 3400 psi 8,610.0 8,960.0 06:30 11:30 FS,BHP 4710,WHP 228,IA 422,OA 404 12/27/2015 12/27/2015 0.50 PROD2 DRILL WPRT P 8,960 ft,Wiper up hole to 8,000 ft 8,960.0 8,000.0 11:30 12:00 PUW 32k 12/27/2015 12/27/2015 0.50 PROD2 DRILL WPRT P 8,000 ft,Wiper back in hole,RIW 8,000.0 8,960.0 12:00 12:30 12/27/2015 12/27/2015 5.00 PROD2 DRILL DRLG P 8,960 ft,BOBD 1.5 bpm at 3578 psi 8,960.0 9,380.0 12:30 17:30 FS,BHP 4293,WHP 281, IA 539,OA 497 12/27/2015 12/27/2015 0.80 PROD2 DRILL WPRT P 9,360 ft,Wiper up hole to cased hole, 9,380.0 8,600.0 17:30 18:18 ft.PUW 32k 12/27/2015 12/27/2015 0.40 PROD2 DRILL WPRT P Wiper back in hole. 8,600.0 9,380.0 18:18 18:42 12/27/2015 12/28/2015 5.30 PROD2 DRILL DRLG P 9,380 ft. OBD 1.5 bpm at 3,841, BHP 9,380.0 9,670.0 18:42 00:00 4,247 psi,WHP 190,IA 592,OA 540, several BHA wipers 12/28/2015 12/28/2015 3.15 PROD2 DRILL DRLG P 9,670 ft. OBD 1.5 bpm at 4,027,BHP 9,670.0 9,766.0 00:00 03:09 4,320 psi,WHP 237,IA 680,OA 620, TD called at 9,766 ft.PUW 33k,Pump 10x10 Lo/hi sweeps Note:Bled IA/OA to 200/200 12/28/2015 12/28/2015 1.15 PROD2 DRILL WPRT P 9,768 ft.Chase sweeps to window,2k 9,766.0 7,845.0 03:09 04:18 bobble at billet 8,559 ft,clean thru window,Jet BTP. 12/28/2015 12/28/2015 0.20 PROD2 DRILL DLOG P Tie in to RA for a plus 4 ft.correction. 7,845.0 7,900.0 04:18 04:30 12/28/2015 12/28/2015 1.25 PROD2 DRILL WPRT P Wiper back in hole,clean passing 7,900.0 9,650.0 04:30 05:45 billet at 8,557 ft. 12/28/2015 12/28/2015 1.00 PROD2 DRILL TRIP P 9650 ft,lay in 9.3 ppg beaded liner pill 9,650.0 7,000.0 05:45 06:45 up into cased hole. 12/28/2015 12/28/2015 1.50 PROD2 DRILL TRIP P 7,000 ft,POOH pumping full rate. 7,000.0 72.2 06:45 08:15 12/28/2015 12/28/2015 0.50 PROD2 DRILL OWFF P At surface,function closed orbit valve, 72.2 72.2 08:15 08:45 check well for flow, PJSM-LD BHA on dead well. 12/28/2015 12/28/2015 0.50 PROD2 DRILL PULD P LD drilling BHA, BHA#7 72.2 0.0 08:45 09:15 12/28/2015 12/28/2015 0.50 PROD2 DRILL PULD P Function test BOPE 0.0 0.0 09:15 09:45 12/28/2015 12/28/2015 1.00 COMPZ2 CASING PUTB P PJSM,prep rig floor for MU L1-01 liner 0.0 0.0 09:45 10:45 assembly,inspect Top Drive,perform. 12/28/2015 12/28/2015 2.25 COMPZ2 CASING PUTB P PU/MU L1-01 liner assembly with 37 0.0 1,139.1 10:45 13:00 jts. 12/28/2015 12/28/2015 1.25 COMPZ2 CASING PUTB P 1,139 ft,MU coiltrak tools,and surface 1,139.1 1,212.0 13:00 14:15 test. 12/28/2015 12/28/2015 1.75 COMPZ2 CASING RUNL P RIH,with L1-01 liner assembly with 1,212.0 7,812.0 14:15 16:00 non-port,37 jts of slotted liner and open hole anchored billet. 12/28/2015 12/28/2015 0.25 COMPZ2 CASING RUNL P 7812 ft,correct to the EOP 6600 ft, 7,812.0 7,812.0 16:00 16:15 minus 10.56 ft. 12/28/2015 12/28/2015 0.45 COMPZ2 CASING RUNL P 7812 ft,continue RIH through window 7,812.0 8,710.0 16:15 16:42 Page 7/13 Report Printed: 1/20/2016 Operations Summary (with Timelog Depths) 0 -1 30-06 Conoco'hitlips Antis Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/28/2015 12/28/2015 0.25 COMPZ2 CASING RUNL P 8710 ft,Tie into the K1 marker 3,710.0 8,744.3 16:42 16:57 correction of plus 2.0 ft. 12/28/2015 12/28/2015 0.25 COMPZ2 CASING RUNL P 8744.3 ft,Continue RIH 8,744.3 9,651.0 16:57 17:12 12/28/2015 12/28/2015 0.25 COMPZ2 CASING RUNL P 9651 ft,PUW 35k,minus 1.9 k 9,651.0 9,651.0 17:12 17:27 DHWOB,RBIH to 9651 ft,pressure up 4130 psi,release liner on bottom,set down 3.6k, TOB at 8500 ft. 12/28/2015 12/28/2015 1.45 COMPZ2 CASING TRIP P 9651 ft,POOH 9,651.0 61.2 17:27 18:54 12/28/2015 12/28/2015 0.35 COMPZ2 CASING 'OWFF P On surface,cycle Orbit valve 61.2 61.2 18:54 19:15 CLOSED,monitor,PJSM-LD BHA 12/28/2015 12/28/2015 0.75 COMPZ2 CASING PULD P LD liner running BHA#8 on dead well. 61.2 0.0 19:15 20:00 12/28/2015 12/28/2015 1.15 PROD3 STK PULD P PJSM-MU BHA#9,0.5°AKO motor 0.0 72.2 20:00 21:09 and RB HCC bi-center bit,MU to CoilTrak,surface test. 12/28/2015 12/28/2015 1.75 PROD3 STK TRIP P RIH with BHA#9,cycle OPEN Orbit 72.2. 7,565.0 21:09 22:54 valve. 12/28/2015 12/28/2015 0.20 PROD3 STK DLOG P Tie in to K1 for minus 8.5 ft. 7,565.0 7,595.0 22:54 23:06 correction. 12/28/2015 12/28/2015 0.50 PROD3 STK TRIP P Continue RIH,PUW above window 7,595.0 8,500.3 23:06 23:36 30k,RBIH,dry tag billet at 8,500.3 ft, PUW 31k. 12/28/2015 12/29/2015 0.40 PROD3 STK KOST P 8,500.3 ft.Time drill off billet per 8,500.3 8,500.5 23:36 00:00 recomended practice 1.5 bpm at 3,597 psi FS,BHP 4,150 psi,WHP 164, IA 0,OA 25 12/29/2015 12/29/2015 2.40 PROD3 STK KOST P 8,500.5 ft. Time drill off billet per 8,500.5 8,512.0 00:00 02:24 recomended practice 1.5 bpm at 3,597 psi FS,BHP 4,150 psi,WHP 164, IA 0,OA 33 12/29/2015 12/29/2015 0.45 PROD3 DRILL DRLG P 8,512 ft. Drill to 8,530 ft, PUW 30K, 8,512.0 8,530.0 02:24 02:51 dry drift billet clean,RBIH,clean past billet. 12/29/2015 12/29/2015 4.40 PROD3 DRILL DRLG P 8,530 ft. OBD 1.52 bpm at 3,773 psi 8,530.0 8,930.0 02:51 07:15 FS,BHP 4,168 psi,WHP 150, IA 0, OA 80 "'Note:Begin mud swap,new mud to bit at 8,627 ft. 12/29/2015 12/29/2015 0.50 PROD3 DRILL WPRT 'P 8,930 ft.Wiper up hole to 8,000 ft. 8,930.0 8,000.0 07:15 07:45 PUW 29k 12/29/2015 12/29/2015 0.50 PROD3 DRILL WPRT P 8,000 ft.Wiper back in hole.RIW 12k. 8,000.0 8,930.0 07:45 08:15 12/29/2015 12/29/2015 3.00 PROD3 DRILL DRLG P 8,930 ft.BOBD 1.5 bpm at 3500 psi 8,930.0 9,330.0 08:15 11:15 FS,BHP 4194,WHP 347, IA 0,OA 42, 12/29/2015 12/29/2015 0.50 PROD3 DRILL WPRT P 9,330 ft,Wiper up hole to 8,550 9,330.0 8,550.0 11:15 11:45 ft.PUW 30k 12/29/2015 12/29/2015 0.50 PROD3 DRILL WPRT P 8,550 ft.Wiper back in hole,RIW 9k 8,550.0 9,330.0 11:45 12:15 12/29/2015 12/29/2015 4.00 PROD3 DRILL DRLG P 9,330 ft.BOBD 1.5 bpm at 3680 psi 9,330.0 9,642.0 12:15 16:15 FS,BHP 4268,WHP 350, IA 0,OA 71 12/29/2015 12/29/2015 0.90 PROD3 DRILL WPRT P 9,642 ft,TD lateral,pump 10x10 9,642.0 7,808.0 16:15 17:09 sweep,PUH to cased hole.Clean up 5 1/2",RBIH to 7880 12/29/2015 12/29/2015 0.10 PROD3 DRILL DLOG P Log RA marker for+2.5'correction 7,808.0 7,903.0 17:09 17:15 7880 to 7903 Page 8/13 Report Printed: 1/20/2016 • 0 0°' Operations Summary (with Timelog Depths) 30-06 Conocohil!lips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/29/2015 12/29/2015 1.40 PROD3 DRILL WPRT P Continue back to hole,clean trip to 7,903.0 9,644.0 17:15 18:39 corrected TD @ 9644',Start beaded liner running pill down coil 12/29/2015 12/29/2015 2.50 PROD3 DRILL TRIP P Trip out pumping 9.3 PPG beaded 9,644.0 66.6 18:39 21:09 liner running pill,Paint EOP flags @ 8134&6300'.At surface cycle orbit valve shut and test-Good 12/29/2015 12/29/2015 0.90 PROD3 DRILL PULD P PJSM,Lay down BHA#9 lateral 66.6 0.0 21:09 22:03 drilling BHA 12/29/2015 12/29/2015 0.50 COMPZ3 CASING RURD P Prep floor to run liner 0.0 0.0 22:03 22:33 12/29/2015 12/30/2015 1.45 COMPZ3 CASING PUTB P M/U BHA#10,Solid bullnose,49 Jts 2 0.0 0.0 22:33 00:00 3/8"slotted liner,OH anchor and aluminum Billet.25 Jts picked up @ midnight 12/30/2015 12/30/2015 1.20 COMPZ3 CASING PUTB P Continue to M/U L1-02 liner 0.0 1,419.5 00:00 01:12 12/30/2015 12/30/2015 2.20 COMPZ3 CASING RUNL P PJSM,M/U anchored billet to liner, 1,419.5 1,492.3 01:12 03:24 Inspect and replace check valves in UQC, M/U Coiltrak to liner,Strip on injector and surface test 12/30/2015 12/30/2015 1.25 COMPZ3 CASING RUNL P RIH to 1567 to pressure up well bore 1,492.3 5,101.0 03:24 04:39 to 900 PSI,Pump open Orbit valve, Continue in hole.EDC Open 12/30/2015 12/30/2015 0.75 COMPZ3 CASING RUNL P 5,101 ft.Flush beads from EDC,by 5,101.0 5,101.0 04:39 05:24 pumping 5 bbls of drilling fluid without beads,then PUH 30 ft,function closed EDC, 12/30/2015 12/30/2015 1.50 COMPZ3 CASING RUNL P 5,101 ft.Continue RIH,without 5,101.0 7,802.4 05:24 06:54 pumping 12/30/2015 12/30/2015 0.25 COMPZ3 CASING RUNL P 7,802 ft.Correct to the EOP flag 6,300 7,802.4 7,782.0 06:54 07:09 ft.minus 10.0 ft.PUW 33.5k. 12/30/2015 12/30/2015 0.50 COMPZ3 CASING RUNL P 7,782 ft,RIH to 9,631 ft. 7,782.0 8,980.0 07:09 07:39 12/30/2015 12/30/2015 0.25 COMPZ3 CASING RUNL P 8,980 ft. Log the RA marker correction 8,980.0 8,980.0 07:39 07:54 of plus 2.5 ft. 12/30/2015 12/30/2015 0.25 COMPZ3 CASING RUNL P Continue RIH to setting depth.RIW 8,980.0 9,631.0 07:54 08:09 10k 12/30/2015 12/30/2015 0.25 COMPZ3 CASING RUNL P 9,631 ft.PUW 33k,RBIH to setting 9,631.0 8,200.0 08:09 08:24 depth,PUH to break over,bring pump up to shear setting tool at 4565 psi, set down 3k DHWOB, 12/30/2015 12/30/2015 1.50 COMPZ3 CASING TRIP P 8,200 ft.POOH 8,200.0 61.4 08:24 09:54 12/30/2015 12/30/2015 0.50 COMPZ3 CASING OWFF P At surface,function closed Orbit 61.4 61.4 09:54 10:24 Valve,check well for flow,PJSM 12/30/2015 12/30/2015 1.00 COMPZ3 CASING PULD P LD L1-02 liner setting tools 61.4 0.0 10:24 11:24 12/30/2015 12/30/2015 0.75 PROD4 STK PULD P PU/MU L1-03 lateral BHA, BHA#11 0.0 72.2 11:24 12:09 12/30/2015 12/30/2015 1.50 PROD4 STK TRIP P RIH,with L1-03 lateral BHA with 1.0° 72.2 7,580.0 12:09 13:39 bend motor. 12/30/2015 12/30/2015 0.25 PROD4 STK DLOG P 7,580 ft,Tie into the K1 marker 7,580.0 7,580.0 13:39 13:54 correction of minus 7.0 ft. 12/30/2015 12/30/2015 0.25 PROD4 STK TRIP P 7580 ft,Continue RIH through 7,580.0 8,200.0 13:54 14:09 window. 12/30/2015 12/30/2015 1.75 PROD4 STK KOST P 8200 ft.,Dry tag TOB at 8200 ft,PUH, 8,200.0 8,203.0 14:09 15:54 bring pump up 1.5 bpm at 3600 psi FS,BHP 4118,WHP 251, IA 0,OA 25,begin time milling Page 9/13 Report Printed: 1/20/2016 11 6.4 Operations Summary (with Timelog Depths) 0 30-06 ConocoPhilslips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/30/2015 12/30/2015 0.80 PROD4 DRILL DRLG P 8,203 ft.5, 10,and 20 fph 8,203.0 8,230.0 15:54 16:42 12/30/2015 12/30/2015 0.20 PROD4 STK REAM P 8,230 ft,PUH,dry drift kick off point, 8,230.0 8,230.0 16:42 16:54 slight bobble 500 lbs, 12/30/2015 12/30/2015 3.00 PROD4 DRILL DRLG P 8,230 ft,OBD 1.55 bpm at 3600 psi 8,230.0 8,630.0 16:54 19:54 FS,BHP 4193,WHP 277,IA 0,OA 102 12/30/2015 12/30/2015 0.50 PROD4 DRILL WPRT P Wiper trip to 8250',PUW=31 K 8,630.0 8,630.0 19:54 20:24 12/30/2015 12/31/2015 3.60 PROD4 DRILL DRLG P 8630',Drill, 1.55 BPM @ 3830 PSI 8,630.0 9,008.0 20:24 00:00 FS,BHP=4212,Swap Mud,new mud @ bit 8956'.Old mud out @ 1773' drilled,.85%Drill solids 12/31/2015 12/31/2015 0.80 PROD4 DRILL DRLG P 9008',Drill, 1.56 BPM @ 3670 PSI 9,008.0 9,030.0 00:00 00:48 FS,BHP=4211 12/31/2015 12/31/2015 1.00 PROD4 DRILL WPRT P Wiper to 7885,PUW=29K 9,030.0 9,030.0 00:48 01:48 12/31/2015 12/31/2015 5.50 PROD4 DRILL DRLG P 9030',Drill. 1.53 BPM @ 3361 PSI 9,030.0 9,320.0 01:48 07:18 FS, BHP=4185 12/31/2015 12/31/2015 1.00 PROD4 DRILL WPRT P 9320 ft,TD was called early due to 9,320.0 7,907.0 07:18 08:18 opening the Miluveach shale,pump 10x10 sweep,wiper up into cased hole.Seeing 9014 ft and 9061 ft, pulling minus 1k-1.5k DHWOB. 12/31/2015 12/31/2015 0.50 PROD4 DRILL WPRT P 7,907 ft,recip in 5.5",pumping a 7,907.0 7,880.0 08:18 08:48 bottoms up.7,907 ft-7,846 ft.RIH to logging depth. 12/31/2015 12/31/2015 0.25 PROD4 DRILL DLOG P 7880 ft,Logged RA marker correction 7,880.0 7,896.0 08:48 09:03 of plus 2.0 ft, 12/31/2015 12/31/2015 0.80 PROD4 DRILL WPRT P 7896 ft.Wiper back in hole.RIW 11.4k 7,896.0 9,000.0 09:03 09:51 12/31/2015 12/31/2015 2.00 PROD4 DRILL DISP P POOH,PUW 31k,Laying in 9.3 ppg 9,000.0 72.2 09:51 11:51 beaded completion fluid up to 6,350 ft..Painting EOP flag at 7,100 ft.and 8333.8 ft. 12/31/2015 12/31/2015 0.50 PROD4 DRILL OWFF P At surface, 1000 psi WHP,function 72.2 72.2 11:51 12:21 closed Orbit Valve,checked well for flow,PJSM 12/31/2015 12/31/2015 0.75 PROD4 DRILL PULD P LD Drilling BHA 72.2 0.0 12:21 13:06 12/31/2015 12/31/2015 0.75 COMPZ4 CASING PUTB P Prep Rig floor for liner,PJSM 0.0 0.0 13:06 13:51 12/31/2015 12/31/2015 1.15 COMPZ4 CASING PUTB P PU/MU L1-03 slotted liner completion 0.0 586.2 13:51 15:00 12/31/2015 12/31/2015 1.10 COMPZ4 CASING PUTB P PU/MU coiltrak tools and billet, 586.2 659.1 15:00 16:06 surface test tools 12/31/2015 12/31/2015 2.00 COMPZ4 CASING RUNL P 659 ft,RIH with L1-03 slotted liner 659.1 6,097.0 16:06 18:06 completion with 20 jts of slotted liner, non-ported bull nose,and Open Hole Anchored Billet.EDC Open. Pressure up to balance orbit valve and pump open valve. 12/31/2015 12/31/2015 0.30 COMPZ4 CASING CIRC P Pump 4 BBIs to flush open EDC,PUH 6,097.0 6,046.0 18:06 18:24 50'and shut EDC 12/31/2015 12/31/2015 0.60 COMPZ4 CASING RUNL P Continue in well 6,046.0 7,767.0 18:24 19:00 12/31/2015 12/31/2015 0.10 COMPZ4 CASING DLOG P Stop and correct to 7100'EOP flag for 7,767.0 7,759.0 19:00 19:06 -7.5',PUW=31K Page 10/13 Report Printed: 1/20/2016 • • 0;1 ,-, Operations Summary (with Timelog Depths) oiz at 30-06 ConocOehittips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/31/2015 12/31/2015 0.20 COMPZ4 CASING RUNL P Continue in hole,Clean pass through 7,759.0 8,155.0 19:06 19:18 window 12/31/2015 12/31/2015 0.20 COMPZ4 CASING DLOG P Log K1 marker for no correction 8,155.0 8,200.0 19:18 19:30 12/31/2015 12/31/2015 0.50 COMPZ4 CASING RUNL P Continue in hole to set depth©8998', 8,200.0 8,998.0 19:30 20:00 PUW=33.5K,DHWOB=-1.9K,RBIH to set depth.Orient to 10R.Pumps on see tool shift©3900 PSI,Set down 4K.Lift off liner. PUW=30K, DHWOB=4K.Subtract liner length left in hole 12/31/2015 12/31/2015 1.70 COMPZ4 CASING TRIP P Trip out after setting L1-03 liner 3,998.0 84.0 20:00 21:42 12/31/2015 12/31/2015 1.00 COMPZ4 CASING PULD P At surface,Cycle orbit valve shut and 84.0 0.0 21:42 22:42 test.LD BHA#12 Liner running tools 12/31/2015 12/31/2015 1.00 PROD5 STK PULD P M/U BHA#13 with 1°AKO motor and 0.0 72.2 22:42 23:42 RR Bi-center,M/U to coil and surface test tools.Tag stripper and set counters,Pressure up well to equalize orbit valve.Open orbit. 12/31/2015 1/1/2016 0.30 PROD5 STK TRIP P RIH BHA#13 L1-04 lateral section 72.2 927.0 23:42 00:00 1/1/2016 1/1/2016 1.30 PROD5 STK TRIP P Continue in well 927.0 7,570.0 00:00 01:18 1/1/2016 1/1/2016 0.30 PRODS STK DLOG P Log K1 for-8',PUW=28K,Shut EDC 7,570.0 7,602.0 01:18 01:36 1/1/2016 1/1/2016 0.50 PRODS STK TRIP P Continue in well,clean pass through 7,602.0 8,401.0 01:36 02:06 window 1/1/2016 1/1/2016 2.50 PRODS STK KOST P PUH,Pumps on 1.48 BPM @ 3340 8,401.0 8,406.0 02:06 04:36 PSI FS,See WOB/Moro work @ 8401.2.Mill off billet per procedure 1/1/2016 1/1/2016 1.00 PRODS DRILL DRLG P 8,406 ft.Drill ahead 1.5 bpm at 3750 8,406.0 8,470.0 04:36 05:36 psi on bottom,BHP 4165,WHP 300, IA 129,OA 193 1/1/2016 1/1/2016 0.25 PROD5 DRILL WPRT P 8,470 ft.,Wiper up hole to drift kickoff 8,470.0 8,470.0 05:36 05:51 point,look clean,RBIH 1/1/2016 1/1/2016 5.75 PRODS DRILL DRLG P 8,470 ft,.OBD 1.45 bpm at 3700 psi, 8,470.0 8,840.0 05:51 11:36 BHP 4170,WHP 300, IA 132,OA 192 1/1/2016 1/1/2016 0.50 PRODS DRILL WPRT P 8,840 ft,Wiper up hole to 8,470ft PUW 8,840.0 8,470.0 11:36 12:06 31 1/1/2016 1/1/2016 0.50 PRODS DRILL WPRT P 8,470ft,Wiper back in hole RIW 9 k 8,470.0 8,840.0 12:06 12:36 1/1/2016 1/1/2016 4.80 PRODS DRILL DRLG P 8,840ft,BOBD 1.5 bpm at 3500psi, 8,840.0 9,215.0 12:36 17:24 BHP 4217,WHP 256, IA 289,OA 305 1/1/2016 1/1/2016 0.90 PRODS DRILL WPRT P Wiper to 8485',PUW=28K 9,215.0 9,215.0 17:24 18:18 1/1/2016 1/1/2016 4.60 PROD5 DRILL DRLG P 9215 Drill,1.46 BPM @ 3550 PSI FS, 9,215.0 9,490.0 18:18 22:54 BHP=4210 1/1/2016 1/1/2016 0.90 PRODS DRILL WPRT P 9490',At plan TD,Pump 10 X 10 9,490.0 7,850.0 22:54 23:48 sweeps and chase to window 1/1/2016 1/2/2016 0.20 PRODS DRILL WPRT P Cleanout 5 1/2"to Tubing tail 7,850.0 7,800.0 23:48 00:00 1/2/2016 1/2/2016 0.30 PRODS DRILL WPRT P Recip 5 1/2 liner 7,800.0 7,885.0 00:00 00:18 1/2/2016 1/2/2016 0.20 PROD5 DRILL DLOG P Tie into RA for+2.5' 7,885.0 7,908.0 00:18 00:30 Page 11/13 Report Printed: 1/20/2016 0 >21t Operations Summary (with Timelog Depths) r'+i 30-06 ConocoPhillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/2/2016 1/2/2016 1.00 PROD5 DRILL WPRT P RIH to confirm TD 7,908.0 9,490.0 00:30 01:30 1/2/2016 1/2/2016 3.00 PROD5 DRILL TRIP P Trip out pumping 9.3PPG beaded 9,490.0 64.0 01:30 04:30 liner running pill.Come up through window.RBIH to paint flag tagged/ stuck up in window©7862.Oriented to left stop and pulled free.Continue OOH.Paint EOP flags @ 7780 and 6100 1/2/2016 1/2/2016 1.00 PROD5 DRILL PULD P At surface,Shut orbit valve,bleed off 64.0 0.0 04:30 05:30 well and observe for flow 1/2/2016 1/2/2016 0.50 COMPZ5 CASING PUTB P Prep Rig Floor for MU L1-04 liner 0.0 0.0 05:30 06:00 completion. 1/2/2016 1/2/2016 0.50 COMPZ5 CASING PUTB P ' Crew change, PJSM for MU liner 0.0 0.0 06:00 06:30 1/2/2016 1/2/2016 3.75 COMPZ5 CASING PUTB P MU L1-04 liner completion with 56 jts 0.0 1,637.9 06:30 10:15 of slotted liner. 1/2/2016 1/2/2016 1.50 COMPZ5 CASING PUTB P PJSM,PU/MU Coiltrak tools,inspect 1,637.9 1,683.1 10:15 11:45 checks in upper quick,replace cracked lower quick,surface test tools 1/2/2016 1/2/2016 3.50 COMPZ5 CASING RUNL T Coiltrak tools failed,LD failed tool 1,683.1 1,683.1 11:45 15:15 section,MU new tools,still have tool problem,trouble shoot,looks like updating issue,tools up and running. BHI-3.5 hrs downtime for tool failure. 1/2/2016 1/2/2016 0.50 COMPZ5 CASING RUNL T High line killed power to rig 1,683.1 15:15 15:45 prematurley HighLine-0.5 downtime. 1/2/2016 1/2/2016 1.70 COMPZ5 CASING RUNL P RIH,L1-04 liner completion with 56 jts 1,683.1 7,793.0 15:45 17:27 of slotted liner,shorty deployment sleeve,and non-ported bull noze.@ 1783 equialize orbit valve and open 1/2/2016 1/2/2016 0.10 COMPZ5 CASING DLOG P Stop and correct-10'to 6100'EOP 7,793.0 7,783.0 17:27 17:33 flag,PUW=30K 1/2/2016 1/2/2016 0.50 COMPZ5 CASING RUNL P Continue in well,Clean pass through 7,783.0 9,180.0 17:33 18:03 window 1/2/2016 1/2/2016 0.10 COMPZ5 CASING DLOG P Log K1 for+1 foot,Did not stop and 9,180.0 9,197.0 18:03 18:09 correct 1/2/2016 1/2/2016 0.40 COMPZ5 CASING RUNL P Continue into hole,Tag TD @ 9489 9,197.0 7,844.0 18:09 18:33 (+1'9490).PUW=31K,Set back dowm.Pump off liner,PUW=26K, PUH to 9480',Start seawater displacement.Remove liner lenght 1638.88'. 1/2/2016 1/2/2016 0.40 DEMOB WHDBOP DISP P Displace well to seawater 7,844.0 7,844.0 18:33 18:57 1/2/2016 1/2/2016 0.80 DEMOB WHDBOP DISP P Trip out pumping seawater 7,844.0 2,522.0 18:57 19:45 1/2/2016 1/2/2016 1.30 DEMOB WHDBOP FRZP P Stop,shut and test orbit valve.1, 2,522.0 33.0 19:45 21:03 Pump 30 BBIs F/P diesel 1/2/2016 1/2/2016 1.70 DEMOB WHDBOP PULD P PJSM,Pull BHA#14 liner running 33.0 0.0 21:03 22:45 tools.B/O UQC and install Nozzle. 1/2/2016 1/3/2016 1.25 DEMOB WHDBOP MPSP P PJSM,R/U lubricator and set BPV 0.0 0.0 22:45 00:00 1/3/2016 1/3/2016 0.70 DEMOB WHDBOP MPSP P Complete BPV set.Lay down and load 0.0 0.0 00:00 00:42 out equipment Page 12/13 Report Printed: 1/20/2016 • • :.. .. 'K.-41 I 11 I 0 1 0 Operations Summary (with Timelog Depths) 30-06 ConocaPhiIrps Anti Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/3/2016 1/3/2016 1.00 DEMOB WHDBOP CIRC P ' Stab back on well and flush rig,30 0.0 0.0 00:42 01:42 BBLs fresh water,30 BBIs inhibitor,30 BBIs flush 1/3/2016 1/3/2016 0.80 DEMOB WHDBOP CIRC P PJSM,Prep and blow down CT string 0.0 0.0 01:42 02:30 with N2 1/3/2016 1/3/2016 1.00 DEMOB WHDBOP CTOP P N2 Rigged down,Bleed off N2 0.0 0.0 02:30 03:30 1/3/2016 1/3/2016 1.00 DEMOB WHDBOP CTOP P Blow down rig,Prep for CT unstab. 0.0 0.0 03:30 04:30 Install grapple and rig cables 1/3/2016 1/3/2016 1.50 DEMOB WHDBOP CTOP P PJSM, Pull test grapple and rigging. 0.0 0.0 04:30 06:00 RTemove CT from injector and secure to spool 1/3/2016 1/3/2016 3.00 DEMOB WHDBOP CTOP P PJSM,Blow down reverse line, 0.0 0.0 06:00 09:00 remove inner reel iron,prep to open bombay doors,remove king pin. 1/3/2016 1/3/2016 3.50 DEMOB WHDBOP CTOP P PJSM,with rig crew and Peak crew. 0.0 0.0 09:00 12:30 Swap reels to Reel#42807-15,590 ft. 1/3/2016 1/3/2016 2.50 DEMOB WHDBOP CTOP P PJSM,clean stripper,change out 0.0 0.0 12:30 15:00 brass,unwrap reel,install saddle clamps and shims in reel hubs. 1/3/2016 1/3/2016 3.00 DEMOB WHDBOP CTOP P PJSM,Install inner reel iron and 0.0 0.0 15:00 18:00 bulkhead,dress downhole end of coil for grapple. 1/3/2016 1/3/2016 1.50 DEMOB WHDBOP CTOP P Continue with pressure bulkhead, 0.0 0.0 18:00 19:30 Install stabbing grapple,R/D PUTZ. 1/3/2016 1/3/2016 1.00 DEMOB MOVE CTOP P PJSM,Stab coil in injector 0.0 0.0 19:30 20:30 1/3/2016 1/3/2016 1.00 DEMOB WHDBOP CTOP P Test wire,Good continuity and Meg 0.0 0.0 20:30 21:30 test,Hook up jumper and test polarity through J box and collector 1/3/2016 1/4/2016 2.50 DEMOB WHDBOP RURD P R/D cellar-BOPE Equipment Check 0.0 0.0 21:30 00:00 trr studs,3 loose on swab one and two flange,2 on flow cross to SSV,and 2 between tango one and two,45 Minutes. 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ConocoPhillips Alaska, Inc. Ricky Elgarico.ATO 3-334. DATA LOGGED 2-/10/2016 WELL NAME 30-06L1;-01;-02;-03;-04 700 G Street. K BENDER Anchorage,Alaska 99510 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE GR-RES BHI DISTRICT Alaska --- LOG DATE January 2,2016 AUTHORIZED BY Patrick Rider EMAIL Patrick.Ridera,bakerhughes.com TODAYS DATE January 22,2016 Revision STATUS Final Replacement: No Details: Requested by: --- COMPANY FIELD ' FINAL CD CD ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #OF NRIN I S #OF COPIES #OF COPIES #OF COPIES 4 4 4 4 4 4 1 BP North Slope I 0 0 0 EOA,PBOC,PRB-20(Office 109) i D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker '900 E.Benson Blvd. �/ Anchorage,Alaska 99508 30-06L1 215-211 26710 30-06L1-01 215-212 26711 2 ConocoPhillips Alaska Inc. I 30-06L1-02 215-213 26712 Attn:Ricky Elgaricio AT03-344 30-06L1-03 215-214 26713 700 G Street4_30-06L1-04 215-215 26714 Anchorage,AK 99510 3 ExxonMobil,Alaska 0 I 0 0 Attn:Lynda M.Yaskell and/or Leonardo Elias 3201 C Street,Suite 505 Anchorage,AK 99503 4''State of Alaska -AOGCC I 1 I 1 I 1 'Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 0 I 1 1 Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR 6'BP Exploration(Alaska)Inc. 1 1 1 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 TOTALS FOR THIS PAGE: 0 2 3 3 0 0 TOTALS FOR ALL PAGES: 0 2 3 3 0 0 N • • N ,-- Lf) Lf) r- LO N N - W 1IN_ w. `go g Z Ci L1! U 0 X N Q I C i RS Y SD- ca 0 au W ce 6. cis Z > 2g . •— y t!) sE CL w u a = > `fl N N 2 c.) , M O � L � T 0 _0 W � R O N � iA�A+ LO 0 Q a Oi C W 7 C) el o ., 0 0 • IP M '1/ 10 0 „; 8 c t 8 cr.) , C 0 .0 0 a (0 S. 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GO a Co 1 • • ..• 'RECEIVED • JAN 19 2,016 Letter of Transmittal rani AOGCC BAKER Date: DATA LOGGED January 12, 2016 1-13 /201Ci HUGHES 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): 30-06L1 21 5 2 1 1 2 6 6 6 2 30-06L1-01 5 2 1 3 2 666 6 3 30-06L1-02 2 1 1 6 6 4 30-06L1-03 30-06L1-04 2 1 5 2 1 4 2 6 6 6 5 21 52 15 26 66 6 (5) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. 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CCco CO CO CO CO O 7, cO CO CO CD CD COO (O CO CO CD CO (O C R Y N CO t„ O 0) O Co CO O I.-- (O CO O O Q C i c0 co co co 7 N- N N O 7 M CO 1:1„., V O) N CO aD O) N V N V N a v M M N N 8 8 N N N N N Ca CC O- 4/1s 0 C a Y Y OO i CO OCCO ) 1 a ti , :---;__--,-4-g;,[0 -4-g;�._ CC 0) O) o CocoM O N N- r 0 R R O O O M r 7 CO3 co co 0) co O O C O_ d V .. m r r CO O N 7 N co (o (o c0 U Y Y 0 0 0 c P..... co co co co m m a, a) a) rn m m u W O CO r .7 CO O 7 03 N M o N V N (0 M N CO (o CO N M O O o O O O O O O CJ O O O O (U co C . d ❑ 5, CO Co 7 N N) (COO 0 7 r n fN Co R .<. p C >, 2 V 0 n O0OO) 0) O) 0) 0) 0) m cov O ) CC EO O 6. r m a) co = • • OF 77 • e,'\�\1//7 , ,v,s, THE STATES Alaska Oil and Gas ��,,,Z����M ®f LAs KA Conservation Comissio 1 1- - = = 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 �T4 Main: 907.279.1433 ALAS 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 30-06L1-01 ConocoPhillips Alaska, Inc. Permit No: 215-212 Surface Location: 832' FNL, 1904' FWL, Sec. 22, T13N, R9E, UM Bottomhole Location: 4689' FNL, 5117' FWL, Sec. 16, T13N, R9E, UM Dear Mr. Venhaus: Enclosed is the approved application for permit to drill the above referenced service well. The permit is for a new wellbore segment of existing well Permit No. 188-060, API No. 50-029- 21824-00-00. 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, gd4 Cathy . Foerster Chair DATED this /v y of December,2015. STATE OF ALASKA RECEIVED P4111,OIL AND GAS CONSERVATION COMi iN DEC 09 2015 PERMIT TO DRILL 20 AAC 25.005 la.Type of Work: lb.Proposed Well Class: Exploratory-Gas ❑ Service- WAG ❑ . Service-Disp ❑ 1 c.gQoposed for: Drill ❑ .Lateral 0 Stratigraphic Test ❑ Development-Oil ❑ Service- Winj ❑ Single Zone 0 Coalbed Gas ❑ Gas Hydrates E Redril ❑ Reentry ❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket 0. Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska Inc. Bond No. 59-52-180 . KRU 30-06L1-01 v 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 9,900' . TVD: 6,562' ' Kuparuk River Field ' 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): - Kuparuk Oil Pool . Surface: 832'FNL, 1904'FWL,Sec.22,T13N, R9E, UM ` ADL 25513 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 3835'FNL,4094'FWL,Sec. 16,T13N,R9E, UM 2554 1/1/2016 Total Depth: 9.Acres in Property: 14. Distance to Nearest Property: 4689'FNL,5117'FWL,Sec. 16,T13N,R9E,UM 2560 5443' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10. KB Elevation above MSL(ft): , 59 15. Distance to Nearest Well Open Surface:x- 525541 y- 6,021,987 Zone- 4 . GL Elevation above MSL(ft): 124 to Same Pool: 30-11,2168' 16. Deviated wells: Kickoff depth: • 8,550' feet 17. Maximum Potential Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: . 98° degrees Downhole: 4,386 psig . Surface: 3,733 psig , 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2.375" 4.7# L-80 ST-L 1,425' 8,475' 6,557' 9,900' 6,562' 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): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): 8172' 6836' none 8063' 6746' none Casing Length Size Cement Volume MD TVD Conductor/Structural 79' 16" 181 Sx AS II 115' 115' Surface 4672' 9.625" 1650 Sx AS III&300 G 4707' 4090' Production 8113' 7" 300 Sx CI G&175 AS I 8146' 6814' Perforation Depth MD(ft): 7849-7,859,7867-7891,7898-7918 Perforation Depth TVD(ft): 6571-6579,6586-6605,6611-6627 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program Q Time v. Depth Plot ❑ Shallow Hazard Analysis Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements0 21. Verbal Approval: Commission Representative: Date .lee._. 1 pS 22. I hereby certify that the foregoing is true and the procedure approved herein will not R. Phillips @265-63/2 t_..--. be deviated from without prior written approval. Contact Email ron.l.phillips(a),cop.com Printed Name D.Venhaus Title CTD Engineering Supervisor / Signature Phone 263-4372 Date /'Z— — /5 Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number:, p1/5- p2/1 50-4c/q-p21O a•1/41—0 -ac3 Date: N2-\cif' 2 O\5 requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: Z Other: fj p r ey t to 4 3 U O ,17$)=n. Samples req'd: Yes ❑ No 1Mud log req'd:Yes❑ No IZ A 0 n v/ar pre v tn. trr 1t5 f fd Z 5 °h 5)�HZS measures: Yes VI No❑ Directional svy req'd:Yes Q No 5t4 ft- 140 t-t'i t SSeld /1I (1.--11-' 1' 4"Y t pacing exception req'd: Yes ❑ No[i Inclination-only svy req'd:Yes❑ No of/- 'r s tt 4t b '1)? r-cl b -f r c 77 . Post initial injection MIT req'd:Yes❑ No C APPROVED BY //L Approved by: P l�r COMMISSIONER/ / }� THE COMMISSION Date:/2.-4,. ../5- VEL 1 ///o//5 P,hA 11i�N Submit Form and Form 10-401(Revised 11/2015) (h),Rine,fiNrAmLiths from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate iG, /"/D�� i • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 December 7, 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 applications for permits to drill a penta-lateral out of the KRU 30-06 (188-060) using the coiled tubing drilling rig, Nabors CDR2-AC. The work is scheduled to begin December 28, 2015. The CTD objective will be to drill five laterals (30-06L1, 30-06L1-01, 30-06L1-02, 30-06L1-03 & 30- 06L1-04), targeting the Kuparuk A-sand intervals. Note the current A sand perforations will be open below the whipstock. Attached to this application are the following documents: — Permit to Drill Application Forms (10-401) for 30-06L1, 30-06L1-01, 30-06L1-02, 30-06L1-03 & 30- 06L1-04 — Detailed Summary of Operations = Directional Plans for 30-06L1, 30-06L1-01, 30-06L1-02, 30-06L1-03 & 30-06L1-04 — Current wellbore schematic — Proposed wellbore schematic If you have any questions or require additional information please contact me at 907-265-6312. Sincerely, Ron Phillips Coiled Tubing Drilling Engineer • • NABOAS ALASKA Kuparuk CTD Laterals �, 30-06L1, 30-06L1-01, 30-06L1-02, 3®-06L1-03 & 3®-06L1-04 a)9 ConocoP,dP Application for Permit to Drill Document 2n 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(f)and 20 AA C 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 4 (Requirements of 20 AAC 25.005(c)(13)) 4 Summary of Operations 4 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 6 (Requirements of 20 AAC 25.050(b)) 6 16. Quarter Mile Injection Review (for injection wells only) 7 (Requirements of 20 AAC 25.402) 7 17. Attachments 7 Attachment 1: Directional Plans for 30-06 laterals 7 Attachment 2: Current Well Schematic for 30-06 7 Attachment 3: Proposed Well Schematic for 30-06 laterals 7 Page 1 of 7 December 7, 2015 PTD App lic on: 30-06L1, 30-06L1-01, 30-06L 2, 30-06L1-03 & 30-06L1-04 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 are 30-06L1, 30-06L1-01, 30-06L1-02, 30-06L1-03 & 30- 06L1-04. All laterals will be classified as "Service—WAG"wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 30-06L1, 30-06L1-01, 30-06L1-02, 30-06L1-03 & 30-06L1-04. 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 4,300 psi. Using the maximum formation pressure in the area of 4,386 psi in 30-10 (i.e. 12.9 ppg EMW), the maximum potential surface pressure in 30-06, assuming a gas gradient of 0.1 psi/ft, would be 3,733 psi. See the "Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2,500 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 formation pressure in KRU 30-06 was measured to be 4630 psi (13.5 ppg EMW) on 7/19/2015, 4399 psi (12.8 ppg EMW) on 8/30/2015 and 4193 psi (12.2 ppg EMW) on 10/11/2015 following the workover. From this trend we expect the formation pressure to be 12.0 ppg EMW while drilling. The maximum downhole pressure in the 30-06 vicinity is to the southwest in the 30-10 shut-in injector at 4,386 psi (12.9 ppg EMW) from Sept 2015. Producers to the north and south have recorded the lowest downhole pressures of 9.5 ppg EMW. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) None of the offset injection wells to 30-06 have ever injected gas, so there is a low probability of encountering free gas while drilling the 30-06 laterals. Nevertheless, if significant gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected risk of hole problems in the 30-06 laterals will be shale instability across faults. Managed pressure drilling (MPD)will be used to reduce the risk of shale instability associated with fault crossing. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 30-06 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 7 December 7,2015 PTD Application: 3O-06L1, 30-06L1-01, 30-06102, 30-06L1-03 & 30-06L1-04 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Liner Top Liner Btm Liner Top Liner Btm Liner Details Name MD MD TVDSS TVDSS 30-06L1 8,550' 10,400' 6,557' 6,515` 2%', 4.7#, L 80, ST-L slotted liner; aluminum billet on top 30-06L1-01 8,475' 9,900' 6,557' 6,562' 2%", 4.7#, L 80, ST-L slotted liner; aluminum billet on top 30-06L1-02 8,200' 9,550' 6,566' 6,524' 2%", 4.7#, L 80, ST-L slotted liner; aluminum billet on top 30-06L1-03 8,525' 9,500' 6,570' 6,501' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 30-06L1-04 7,840' 9,000' 6,440' 6,530' 2%", 4.7#, L-80, ST-L slotted liner; 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 0' 79' 0' 79' 1,640 670 Surface 9-5/8" 36 J-55 BTC 0' 4,707' 0' 4,090' 3,520 2,020 Production 7" 26.0 J-55 BTC 0' 8,146' 0' 6,814' 4,980 4,320 Tubing 3-1/2" 9.3 L-80 EUE 0' 7,886' 0' 6,542' 10,160 10,540 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) 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 A diagram of the Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System - Window milling operations: Chloride-based FloVis mud (9f7 ppg) - Drilling operations: Chloride-based FloVis mud (9.7 ppg). While this mud weight will not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. - Completion operations: Well 30-06 contains a downhole deployment valve allowing deployment of tool strings and liner without pumping kill weight fluid. If the valve does not hold, BHA's will be deployed using standard pressure deployments and the well will be loaded with 12.2 ppg NaBr completion fluid in order to provide formation over-balance and well bore stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5,000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". Page 3 of 7 December 7, 2015 PTD Application: 30-06L1, 30-06L1-01, 30-06L -02, 30-06L1-03 & 30-06L1-04 In the 30-06 laterals we will target a constant BHP of 12.2 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. 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 30-06 Window(7,850' MD, 6513' TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure (12.0 ppg) 4064 psi 4064 psi Mud Hydrostatic(9.7 ppg) 3285 psi 3285 psi Annular friction (i.e. ECD, 0.085 psi/ft) 667 psi 0 psi Mud + ECD Combined 3952 psi 3285 psi (no choke pressure) (underbalanced —112 (underbalanced psi) —779 psi) Target BHP at Window(12.2 ppg) 4132 psi 4132 psi Choke Pressure Required to Maintain 180 psi 847 psi Target BHP 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is for a land based 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. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well 30-06 is a Kuparuk A-sand service well equipped with 31/2"tubing and 7"production casing. A rig work-over was recently performed, replacing the existing tubing and packers with new 31/2"tubing with a 51/2""Big Tail Pipe" completion. Five laterals will be drilled three to the east and two to the west of the parent well with the laterals targeting the Kuparuk Al,A2 and A3 sands. A thru-tubing whip-stock will be set pre-rig inside the 51/2"tail pipe at the planned kick off point of 7,850' MD. The 30-06L1 eastern lateral will exit through the 51/2"tailpipe and 7"casing at 7,850'MD and TD at 10,400' MD, targeting the Kuparuk Al,A2 and A3 sands. It will be completed with 2%" slotted liner from TD up to 8,550' MD with an aluminum billet for kicking off the 30-06L1-01 lateral. The 30-06L1-01 will drill east to a TD of 9,900' MD targeting the A2 and A3 sands. It will be completed with 2%" slotted liner from TD up to 8,475' MD with an aluminum billet for kicking off the 30-06L1-02 lateral. Page 4 of 7 December 7, 2015 PTD App(icon: 30-06L1, 30-06L1-01, 30-06L02, 30-06L1-03 30-06L1-04 The 30-06L1-02 will drill east to a TD of 9,550' MD targeting the A3 sand. It will be completed with 23/8" slotted liner from TD up to 8,200' MD with an aluminum billet for kicking off the 30-06L1-03 lateral. The 30-06L1-03 will turn north then west and drill to a TD of 9,500' MD targeting the Al,A2 and A3 sands. It will be completed with 2%"slotted liner from TD up to 8,525' MD with an aluminum billet for kicking off the 30-06L1-04 lateral. The 30-06L1-04 will drill west to a TD of 9,000' MD targeting the Al,A2 and A3 sands. It will be completed with 2%"slotted liner from TD up to 7,760' MD with the liner top inside the 3-1/2"tubing and below the X-nipple. Pre-CTD Work 1. Pull the BPV,pull the XX plug from the X nipple, pump in test to confirm perfs are open and drift for a whipstock. 2. Set a whipstock, conduct a formation integrity test,pump a degradable plug and set a BPV. 3. Prep site for Nabors CDR2-AC. Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 30-06L1 Lateral(Al,A2 and A3 sands east) a. Mill 2.80"window at 7,850' MD. b. Drill 3"bi-center lateral to TD of 10,400' MD. c. Run 2%" slotted liner with an aluminum billet from TD up to 8,550' MD. 3. 30-06L1-01 Lateral(A2 and A3 sands east) a. Kick off of the aluminum billet at 8,550' MD. b. Drill 3"bi-center lateral to TD of 9,900' MD. • c. Run 23/8" slotted liner from TD up to 8,475' MD. 4. 30-06L1-02 Lateral(A3 sand east) a. Kick off of the aluminum billet at 8,475' MD. b. Drill 3"bi-center lateral to TD of 9,550' MD. c. Run 2%" slotted liner from TD up to 8,200' MD. 5. 30-06L1-03 Lateral(Al,A2 and A3 sands west) a. Kick off of the aluminum billet at 8,200' MD. b. Drill 3"bi-center lateral to TD of 9,500' MD. c. Run 2%" slotted liner from TD up to 8,525' MD. 6. 30-06L1-03 Lateral(Al,A2 and A3 sands west) a. Kick off of the aluminum billet at 8,525' MD. b. Drill 3"bi-center lateral to TD of 9,000' MD. c. Run 2%" slotted liner from TD up to 7,840' MD,just above the whipstock 7. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV. 2. Install GLV's 3. One month flowback for cleanup,then return to injection. Page 5 of 7 December 7, 2015 PTD App licton: 30-06L1, 30-06L1-01, 30-0611_1.1002, 30-06L1-03 & 30-061_1-04 Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure, so installed in this well is a down hole deployment valve. This valve, when closed using hydraulic control lines from surface, isolates the well pressure and allows long BHA's to be deployed/un-deployed without killing the well. If the deployment valve fails, operations will continue using the standard pressure deployment process. 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 slick-line lubricator can be used. 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 30-06 well has a deployment valve installed. It will serve to deploy liners into the newly drilled laterals. If the valve fails the laterals will be displaced to an overbalance completion fluid (12.2 ppg NaBr) prior to running liner. See "Drilling Fluids" section for more details. — 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 (1 R-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). 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. Page 6 of 7 December 7, 2015 PTD Application: 30-06L1, 30-06L1-01, 30-061110-02, 30-06L1-03 & 30-06L1-04 — Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 30-06L1 5,180' 30-06L1-01 5,443' 30-06L1-02 5,770' 30-06L1-03 7,407' 30-06L1-04 6,861' — Distance to Nearest Well within Pool Lateral Name Distance Well 30-06L1 1115' 30-04 30-06L1-01 2,168' 30-11 30-06L1-02 2,223' 30-11 30-06L1-03 1,225' 3R-26 30-06L1-04 1,660' 3R-26 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AA C 25.402) There are 2 wells within 1/4-mile of the 30-06 laterals. 30-06 (mother bore) Injector • Completed with 7", 26#, J-55 casing on 6/22/1988. • Classified as a "Normal Well"with a recent 2015 Rig Work-Over • A-sand perforations: 7849'-7859' MD, 7867'-7891' MD and 7898'-7918' MD • During the Oct. 2015 work over, a variance was granted for setting the packer over 200' away from the uppermost A-sand perforation. Packer is located at 7634' 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. 30-04(producer),—1115' away from 30-06L1 lateral to the southwest • 30-04 has been shut-in since June 2014 • Classified as a"waivered well"for IAxOA communication • Well can operate with gas lift • Well is completed with 7" 26#J-55 csg w/4.5" 12.6# L-80 cemented scab liner and a 3.5" 9.3# L-80 tbg • A, C and Unit B perforations isolated with cemented liner during 2013 RWO: C4/C1/Unit B: 8622' —8640' MD, A3: 8653'—8669' MD, A2: 8675' —8698' MD &Al: 8710'—8730' MD • A-sand add perfs after 2013 RWO cemented liner: Al/A2: 8675' —8695' MD • Good cement across the A-sand perfs and atleast 200' above that. 3R-26 (producer), —1225' away from 30-06L1-03 lateral to the northwest • 3R-26 has been shut-in since June 2015 • Classified as a "normal well"with a recent Nov 2013 Rig Work-Over • Well can operate with gas lift • Well is completed with 5.5x4.4" 17# L-80 csg and a 2-7/8"6.5# L-80 tbg • A-sand perforations: A3: 8540'—8550' MD, A2: 8560'—8580' MD &Al: 8592' —8622' MD • Good cement across the A-sand perfs and atleast up to the production tubing. The top of cement is above the production tubing and could not be determined with the logging tool. 17. Attachments Attachment 1: Directional Plans for 30-06 laterals Attachment 2: Current Well Schematic for 30-06 Attachment 3: Proposed Well Schematic for 30-06 laterals Page 7 of 7 December 7, 2015 0 I W W �W0 `w_ Qifii!....ii..... zamealuiii g tr $ roots 2 Oit, ''-;-,":"Ie _ NEE, 1 - 3: y foo a - j-- .. /, _ c.: o0 $ 3$ gi _ oo w �s �9 �.e— d f.-...,2-,,-.;. 1.-.'ill,...i..J.:Ir'jj_li.fL',. .,JII:J.,T.J.:-_.:I.. ..:,-:.i.1-:;:tt.,;':./r.i.lidgd:.+-tt. Ar :i.t:,,,,:',--,;.,::,i- , Aria. m, on 7 1.-:-.,'Hr--•'.÷:.41:-'-..!..'.-:•Aill - MAIni ;., 1 9! 0 6j M n Elbh v0 8 o m>o '�- I - - .,, ,_ _ i Dour o m N _ f m — • '••. • • — • •' — •killiFiriii&Oki ii —- o 4 �. "> i : �kNZ.; IlF - ?, w om. _ E i ._in m0t te-e- ITtere• e I, -1 1 e:. V r f le-4e:-44--e-i-;:-1--i--te4:1- Ti:,::: . . . . •'44--....I44--444.;---4--i--4-'-4 4.‘kr4417 A A -,---,--4---;-;-;--4- i:;-+--4--,-4-- a : 4 A .' El 3 p EiiiilingliENEW j N J r A AG M - YYnoa p _ .. 3 _ -- Al 'to -_'-f F' a 4 - - - g12'. F ----44-44-!-4-44-i--,4-4-'f- -47---44-1-1-4-i-1-1- 10 0 aa '4:-.. p O NI. - co o y o • o C v, V y V 4 V m m M r, Am N N N N N m b V N O m b V N O N 9 U (ui/gsn OOZ)(+)twuN/(')u3noS o KUP INJ • 30-06 ConocoPhillips =` , ,m;.: Well Attributes Max Angle&MD TD Aaska,Inc. Wellbore APIIUWI Field Name Wellbore Status ncl(') MD(ftKB) Act Btm(ftKB) C,omarampc"'' .500292182400 KUPARUK RIVER UNIT INJ 40.43 5,500.00 8,172.0 - Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3D-06,11/17/201510:18:31 AM SSSV:NONE Last WO: 10/25/2015 34.98 6/24/1988 Vertcal schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date .. .____._.. ................... .............. ..._..........Last Tag:SLM 7,923.0 7/19/2015 Rev Reason:WORKOVER lehallf 11/17/2015 HANGER;33.0 Y,'•I Ir y 111 f Casing Strings " "' -"t Casing Description OD(in) ID Top(ftKB) Set Depth ftKB Set Depth (in) ( ) p (ftKB) (TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED { Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.921 35.0 4,707.3 4,090.3 36.00 J-55 BTC • Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 33.0 8,145.8 6,814.2 26.00 J-55 BTC J Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING-2015 WO- 31/2 2.990 33.0 7,634.6 6,397.2 9.30 L-60 EUE 8rd UPPER COMPLETION CONDUCTOR;36.0-115.0 Completion Details 'i Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl 7) Item Des Corn (in) GAS LIFT;2,708.6111 33.0 33.0 0.09 HANGER Tubing Hanger 3.500 7,613.0 6,379.8 36.39 Locator Locator Sub 3.000 7,620.5 6,385.6 36.35 SEAL ASSY Baker GHB-22 locating seal assembly 3.000 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING-2015 WO- 31/2 2.992 7,620.2 7,886.0 6,601.2 9.30 L-80 EUE Brd OSTV Tubing Slwt Off;3,495.9 sit J'! LOWER COMPLETION I Completion Details Nominal ID Top(ftKB) Top(NO)(ftKB) Top Incl(") Item Des Corn (In) 7,620.2 6,385.6 36.36 PACKER Baker F packer 4.000 GAS LIFT;4,217.3 7,623.5 6,388.2 36.34 PBR -80-40 PBR 4.000 7,752.7 6,492.8 35.75 NIPPLE HES 3.5 X 2.82 X nipple W/XX plug 2.182 7,797.4 6,529.1 35.56 Liner 5.5 X 14#J-55 STC Wear sox 5 15/16"OD on Wear 5.000 rings Perforations&Slots Shot SURFACE;35.0-4,707.3 Dens Top Top(ftKB) Blm(ftKB) (ftKB)(TVD) Btm(TVD) (shots/f (ftKB) Zone Date t) Type Com 7,849.0 7,859.0 6,571.1 6,579.2 A-3,30-06 6/5/1989 12.0 APERF 60 deg.phasing(Strips GAS LIFT;5,414.9 I is Kinked @ 35 deg.);2 1/8"EnerJet 7,867.0 7,891.0 6,585.7 6,605.3 A-2,30-06 6/5/1989 12.0 APERF 60 deg.phasing;21/8" EnerJet 7,898.0 7,918.0 6,611.0 6,627.4 A-1,30-06 9/23/1988 8.0 IPERF 45 deg.phasing;4 1/2" GAS LIFT;6,328.6 Ultrapak Csg Mandrel Inserts St ati N Top(TVD) Valve Latch Port Sine TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (In) (psi) Run Date Corn GAS LIFT;7,021.4 IC1 2,708.6 2,494.7 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/24/2015 2 4,217.3 3,705.9 Camoc MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/24/2015 3 5,414.9 4,642.4 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/24/2015 GAS LIFT;7,555.9 a 4 6,328.6 5,355.4 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/24/2015 - 5 7,021.4 5,908.2 Camco MMG 1 1/2 GAS LIFT SOV RKP 0.000 0.0 10/24/2015 6 7,555.9 6,333.9 Camco MMG 11/2 GAS LIFT DMY RK 0.000 0.0 10/24/2015 Locator,7,613.0 _, Notes:General&Safety PACKER;7,620.2 Ti SEAL ASSY;7,020.5 End Date Annotation �l 12 /1/2010 NOTE:View Schematic w/Alaska Schematic9.0 FOR;7,623.5 II i I, 7/7/2015 NOTE: WAIVERED WELL,T x IA COMMUNICATION,WATER INJECTION ONLY. I I 10/25/2015 NOTE:Orbit Valve Control lines/system at Wellhead marked Open/Close. 10/25/2015 NOTE:Orbit Valve is NOT a safety valve,it does not fall to closed position. HI NIPPLE;7,752.7 17/ XO Enlarging(Tubing);7,796.4 ' Liner;7,797.4 APERF;7,849.0-7,859.0- I I APERF;7,867.0-7,891.0 ' (PERF;7,898.0-7818.U- PRODUCTION;33.0-8,145.8 - Li i I C E p M ij W 1 c0 CG v is) CO nW' Eiio a) c_a)v co p p p aj j O r•-• 00 WJJm o" 73 (0 �1 m (Ni W W N V I m O W O to W �L- +- C f Y tn � coa) oc I— 'ONO m =Ymmh v (0 2 o ao c ~ � Y ��� � m ai � W a) o0 rnvcc SL 0• 0 W to ON Q- Qrl� 00 (0 C 0)N _1 12 O NO t` O Q eL O) r rco co N 0 E _ C. C O Co co (0 Ci (0 N ti •— (0 OS o.. 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N o N OM N Q O N< • • ConocoPhillips NADConversion Kuparuk River Unit Kuparuk 30 Pad 30-06 30-06L1-01 Plan: 30-06 L 1-01_wp01 Standard Planning Report 16 October, 2015 BAKER HUGHES 'Ir'' Baker Hughes INTEQ 1 ISM COnocoPhilhhp5 Planning Report BAKER HUGHES Database: OAKEDMP2 Local Co-ordinate Reference: Well 30-06 Company: NADConversion TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 30-06 @ 59.00usft(30-06) Site: Kuparuk 30 Pad North Reference: True Well: 30-06 Survey Calculation Method: Minimum Curvature Wellbore: 30-06L1-01 Design: 30-06L 1-01_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" Grid Convergence: 0.20° Well 30-06 Well Position +N/-S 0.00 usft Northing: 6,021,987.12 usft Latitude: 70°28'16.273 N +EI-W 0.00 usft Easting: 525,540.73 usft Longitude: 149°47'29.071 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 30-06L1-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2015 1/1/2016 18.65 81.05 57,496 Design 30-06L1-01_wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,550.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 0.00 0.00 0.00 135.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (°) Target 8,550.00 89.70 131.51 6,557.03 2,277.53 -3,094.57 0.00 0.00 0.00 0.00 8,675.00 98.45 131.51 6,548.15 2,194.98 -3,001.29 7.00 7.00 0.00 0.00 8,795.00 90.05 131.51 6,539.26 2,115.75 -2,911.75 7.00 -7.00 0.00 180.00 8,935.00 89.88 141.30 6,539.35 2,014.48 -2,815.32 7.00 -0.12 7.00 91.00 9,135.00 89.64 127.31 6,540.19 1,875.14 -2,672.56 7.00 -0.12 -7.00 269.00 9,335.00 89.41 141.30 6,541.85 1,735.79 -2,529.79 7.00 -0.12 7.00 91.00 9,435.00 90.02 134.33 6,542.34 1,661.74 -2,462.68 7.00 0.61 -6.97 275.00 9,535.00 94.03 128.59 6,538.80 1,595.61 -2,387.84 7.00 4.01 -5.74 305.00 9,635.00 89.07 123.64 6,536.09 1,536.73 -2,307.13 7.00 -4.96 -4.94 225.00 9,735.00 85.58 117.57 6,540.76 1,485.90 -2,221.21 7.00 -3.49 -6.08 240.00 9,900.00 79.91 107.42 6,561.64 1,423.30 -2,070.29 7.00 -3.44 -6.15 240.00 10/16/2015 2:52:25PM Page 2 COMPASS 5000.1 Build 74 • I.-- Baker Hughes INTEQ • FAIN Planning Report BAKER HUGHES Database: OAKEDMP2 Local Co-ordinate Reference: Well 30-06 Company: NADConversion TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 30-06 @ 59.00usft(30-06) Site: Kuparuk 30 Pad North Reference: True Well: 30-06 Survey Calculation Method: Minimum Curvature Wellbore: 30-06L1-01 Design: 30-06L1-01_wp01 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100usft) (°) (usft) (usft) 8,550.00 89.70 131.51 6,557.03 2,277.53 -3,094.57 -3,798.65 0.00 0.00 6,024,253.79 522,438.67 TIP/KOP 8,600.00 93.20 131.51 6,555.76 2,244.41 -3,057.14 -3,748.77 7.00 0.00 6,024,220.81 522,476.21 8,675.00 98.45 f 131.51 6,548.15 2,194.98 -3,001.29 -3,674.32 7.00 0.00 6,024,171.58 522,532.23 Start 7 dls 8,700.00 96.70 131.51 6,544.85 2,178.56 -2,982.73 -3,649.58 7.00 -180.00 6,024,155.22 522,550.84 8,795.00 90.05 131.51 6,539.26 2,115.75 -2,911.75 -3,554.98 7.00 -180.00 6,024,092.66 522,622.03 3 8,800.00 90.04 131.86 6,539.26 2,112.43 -2,908.01 -3,549.99 7.00 91.00 6,024,089.35 522,625.78 8,900.00 89.92 138.85 6,539.29 2,041.32 -2,837.78 -3,450.05 7.00 91.00 6,024,018.49 522,696.24 8,935.00 89.88 141.30 6,539.35 2,014.48 -2,815.32 -3,415.19 7.00 91.00 6,023,991.73 522,718.79 4 9,000.00 89.80 136.75 6,539.53 1,965.42 -2,772.72 -3,350.37 7.00 -91.00 6,023,942.82 522,761.56 9,100.00 89.68 129.76 6,539.98 1,896.94 -2,699.93 -3,250.48 7.00 -90.99 6,023,874.59 522,834.57 9,135.00 89.64 127.31 6,540.19 1,875.14 -2,672.56 -3,215.70 7.00 -90.96 6,023,852.89 522,862.02 5 9,200.00 89.56 131.86 6,540.64 1,833.73 -2,622.47 -3,151.01 7.00 91.00 6,023,811.66 522,912.24 9,300.00 89.45 138.85 6,541.50 1,762.63 -2,552.25 -3,051.08 7.00 90.97 6,023,740.81 522,982.70 9,335.00 89.41 141.30 6,541.85 1,735.79 -2,529.79 -3,016.22 7.00 90.91 6,023,714.05 523,005.25 6 9,400.00 89.81 136.77 6,542.29 1,686.72 -2,487.19 -2,951.40 7.00 -85.00 6,023,665.13 523,048.01 9,435.00 90.02 134.33 6,542.34 1,661.74 -2,462.68 -2,916.41 7.00 -84.97 6,023,640.23 523,072.60 7 9,500.00 92.63 130.60 6,540.84 1,617.88 -2,414.76 -2,851.50 7.00 -55.00 6,023,596.54 523,120.67 9,535.00 94.03 128.59 6,538.80 1,595.61 -2,387.84 -2,816.72 7.00 -55.09 6,023,574.37 523,147.67 8 9,600.00 90.81 125.37 6,536.06 1,556.56 -2,335.97 -2,752.43 7.00 -135.00 6,023,535.50 523,199.66 9,635.00 89.07 123.64 6,536.09 1,536.73 -2,307.13 -2,718.02 7.00 -135.14 6,023,515.77 523,228.57 9 9,700.00 86.80 119.70 6,538.43 1,502.63 -2,251.86 -2,654.83 7.00 -120.00 6,023,481.87 523,283.95 9,735.00 85.58 117.57 6,540.76 1,485.90 -2,221.21 -2,621.32 7.00 -119.86 6,023,465.24 523,314.65 10 9,800.00 83.32 113.60 6,547.04 1,457.96 -2,162.88 -2,560.32 7.00 -120.00 6,023,437.51 523,373.08 9,900.00 79.91 107.42 6,561.64 1,423.30 -2,070.29 -2,470.34 7.00 -119.62 6,023,403.17 523,465.78 Planned TD at 9900.00 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 9,900.00 6,561.64 2 3/8" 2-3/8 3 10/16/2015 2:52:25PM Page 3 COMPASS 5000.1 Build 74 • e .• , Baker Hughes INTEQ VEIN ConocoPhillips Planning Report BAKER HUGHES Database: OAKEDMP2 Local Co-ordinate Reference: Well 30-06 Company: NADConversion TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 30-06 @ 59.00usft(30-06) Site: Kuparuk 30 Pad North Reference: True Well: 30-06 Survey Calculation Method: Minimum Curvature Wellbore: 30-06L1-01 Design: 30-06L 1-01_wp01 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 8,550.00 6,557.03 2,277.53 -3,094.57 TIP/KOP 8,675.00 6,548.15 2,194.98 -3,001.29 Start 7 dls 8,795.00 6,539.26 2,115.75 -2,911.75 3 8,935.00 6,539.35 2,014.48 -2,815.32 4 9,135.00 6,540.19 1,875.14 -2,672.56 5 9,335.00 6,541.85 1,735.79 -2,529.79 6 9,435.00 6,542.34 1,661.74 -2,462.68 7 9,535.00 6,538.80 1,595.61 -2,387.84 8 9,635.00 6,536.09 1,536.73 -2,307.13 9 9,735.00 6,540.76 1,485.90 -2,221.21 10 9,900.00 6,561.64 1,423.30 -2,070.29 Planned TD at 9900.00 10/16/2015 2:52:25PM Page 4 COMPASS 5000.1 Build 74 I • I ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 30 Pad 30-06 30-06L1-01 30-06L1-01_wp01 Travelling Cylinder Report 20 October, 2015 r' 1 BAKER HUGHES I,- • ConocoPhillips • 'dill ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 30-06 Project: Kuparuk River Unit TVD Reference: 30-06 @ 59.00usft(30-06) Reference Site: Kuparuk 30 Pad MD Reference: 30-06 @ 59.00usft(30-06) Site Error: 0.00 usft North Reference: True Reference Well: 30-06 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 30-06L1-01 Database: EDM Alaska ANC Prod Reference Design: 30-06L1-01_wp01 Offset TVD Reference: Offset Datum Reference 30-06L1-01_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: 8,550.00 to 9,900.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,184.10 usft Error Surface: Elliptical Conic Survey Tool Program Date 10/20/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 100.00 7,800.00 30-06(30-06) BOSS-GYRO Sperry-Sun BOSS gyro multishot 7,800.00 8,550.00 30-06L1_wp02(30-06L1) BOSS-GYRO Sperry-Sun BOSS gyro multishot 8,550.00 9,900.00 30-06L1-01_wp01 (30-06L1-01) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (1 9,900.00 6,620.64 2 3/8" 2-3/8 3 j 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 30-01-30-01A-30-01A_wp03 Out of range 30-01-30-01AL1-30-01AL1_wp03 Out of range 30-01-30-01AL2-30-01AL2_wp03 Out of range 30-01-30-01AL3-30-01AL3_wp03 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 30-05-30-05-30-05 Out of range 30-06-30-06-30-06 8,559.41 7,850.00 230.03 16.09 217.73 Pass-Major Risk 30-06-30-06L1-30-06L1_wp02 8,550.00 8,550.00 0.00 0.28 -0.22 FAIL-Minor 1/10 30-06-30-06L1-02-30-06L1-02_wp01 8,550.00 8,550.00 3.96 7.24 3.73 Pass-Minor 1/10 30-06-30-06L1-03-30-06L1-03_wp03 8,559.41 7,850.00 230.03 3.00 227.10 Pass-Minor 1/10 30-06-30-06L1-04-30-06L1-04_wp01 8,559.41 7,850.00 230.03 3.00 227.10 Pass-Minor 1/10 30-08-30-08L1-30-08L1 Out of range 30-08-30-08L1-03-30-08L1-03 Out of range 30-08-30-08L1-04-30-08L1-04 Out of range 30-10-30-10-30-10 Out of range 30-11-30-11-30-11 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 10/20/2015 4:17:46PM Page 2 COMPASS 5000.1 Build 74 • • :$ • V! 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(uvusn OL)A3daa IeotuaA anis U • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • • TRANSMITTAL LETTER CHECKLIST WELL NAME: 1(�. ��� — © i1,1-0I PTD: a)s- - ;2) Development /Service Exploratory Stratigraphic Test Non-Conventional FIELD: X(f./¼ . 'RA UL1 POOL: / fi.fk R)i_Ar P1uPAA4tr. Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit / LATERAL No. /gg- 060 , API No. 50-0 Z9 - `02,I g�1 -co - oC V (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 • • SI P N m ° N a 0 o a as ai CD 23 Z CO c. as' CC O a os U) O C CO g o `, m. a Z, o' 3 of E O N .o o 0 0: a), a a co E ° - o j.5 a' > U n v. a> N. _ a> 6 a o c : 3 -o N •- o To o CD o , rn ai 0.' I- 0, •U ai a> ami �o, ° E o). o o, 2, N m �� 5 (0. N. N N C (N: N � � m U) a) rt o D, o a gyp, a cfl p �, E m N 1 D _a�, a, a aco y _c c 0 p, ct w 3 U', V) ?3 ; L; N O. o Q o 3. 2' o �' o, p'. �' 2 Y c = m . N. '3. �, 3, a) 2' E, �� may, a)• Y. a) N' Ti: Y• —t y� O? � O' 0,, 03, a>, CO Y @ c w, c o _Na a, c. CO. N. c m. �, 3 v- to, co co c <• . ri f Fc, c. ) CO. 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