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214-143
, y STATE OF ALASKA AL, . A OIL AND GAS CONSERVATION CON. .3SION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Performed Abandon r Repair w ell r Rug Perforations r Perforate r Other r Prod to WINJ Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r lime Extension r Change Approved Program rOperat Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name 4 Well Class Before Work: 5.Permit to Drill Number ConocoPhillips Alaska, Inc. Development r Exploratory IT 214-143 3.Address 6.API Number. Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-20835-63 7.Property Designation(Lease Number): 8 Well Name and Number. ADL025640 KRU 1G-04L1-03 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 8730 feet Plugs(measured) None true vertical 6724 feet Junk(measured) None Effective Depth measured 8520 feet Packer(measured) 6304,6544,6667 true vertical 6682 feet (true vertical) 6210,6443,6562 Casing Length Size MD TVD Burst Collapse 80 0 0 2222 0 0 6645 0 0 SCS► NE° ',. ` 7280 0 0 6682 0 0 0 0 0 Perforation depth: Measured depth: 6680'-8520' True Vertical Depth: 6756'-6682' RECEIVED Tubing(size,grade,MD,and TVD) 3.5,J-55, 6699 MD,6594 TVD MAR 3 1 2015 Packers&SSSV(type,MD,and TVD) PACKER-BAKE FHL RETRIEVABLE PACKER @ 6304 MD and 6210 TVD - ���� PACKER-BAKER FHL RETRIEVABLE PACKER @ 6544 MD and 6443 TVD ,{� PACKER-BAKER 2-B PACKER @ 6667 MD and 6562 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 0 Subsequent to operation 0 0 1853 320 2048 14 Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r Stratigraphic r 16.Well Status after work. Oil r Gas r WDSPL r Daily Report of Well Operations_X GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt 315-102 Contact Bob Christensen/Darrell Humphrey Email n1139aconocophillips.com Printed Name Darrell Humphrey Title NSK Production Engineering Specialist Signature 3+ 1 ' I.A.,ka Phone:659-7535 Date 3. Z$ . Form 10-404 Revised 10/2012 I( r1- 4 / l 0 l(5 Submitpriginal Only 41417/r— RBDMS. APR - 6 2015 1G-04L1-03 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 03/19/15 Well brought online-water injection service 03/27/15 STATE WITNESSED (CHUCK SCHEVE) MIT-IA(PASSED) TO 2800 PSI. } KUP PROD 1G-04L1-03 ConocoPhillips ro � Well Attributes Max Angle&MD TD Alaska.Inc. Wellbore API/UWI Field Name Wellbore Status 1 ncl('I MD(15(0) Act Btm(ftKB) [nr4144dllipt 500292083563 KUPARUK RIVER UNIT PROD 102.22 7,008.40 8.520.0 ,.•. Comment H2S(ppm) Date Annotation End Date KB-Grd(81) -Rig Release Date 1G-04L1-03,3/9/2015352:17 PM SSSV:NIPPLE Last WO: 34.49 11/2/1982 Vertical schematic(actuap Annotation Depth(NKB) End Date Annotation Last Mod By End Date - ---- - _ •Last Tag: Rev Reason:GLV C/O hipshkf 3/5/2015 HANGER,245 - sT; ., all Casing Strings Casing Description OD(in) ID(in) Top(1KB) Set Depth(1100) Set Depth(TVD)... Wt/Len(I...Grade Top Thread .., .. '� � u ym,LINER Li-03 23/8 1.992 6,679.8 8,520.0 6,682.2 4.60L80 STL 111111 Liner Details CONDUCTOR:29.5.80.0� >• Nominal ID Top(RKB) Top(TVD)(ftKB) Top lnel(') Item Des Com (in) • 6,679.8 6,575.0 12.70 DEPLOY SHORTY DEPLOYMENT SLEEVE 1.000 NIPPLE,505.2 Perforations&Slots • Shot ' Dens Top(TVD) Bim(TVD) (shots!? Top(RKB) Bim(MB) (RKB) (RKB) zone Date t) Type Com SURFACE;29.5-2,222.0-.. 6,680.3 9519.6 6,575.5 6,682.2 A-3,10-04 10/29/2014 SLOTS Slotted Liner • GAS LIFT;6,225.7 Notes:General&Safety End Date Annotation 10/29/2014 NOTE:ADD L1,L1-01,L1-02,L1-03 NIPPLE;6,2716 _ IP SEAL ASSY;6,279.6 PBR:6,281.0 .__ PACKER;6,304.4 -` •` 1111 INJECTION;8349.4 INJECTION;6,429.7 I 11. APERF;6,480.0Q484.0- APERF;6,488.06,516.0- APERF;6,524.06,530.0- a I PACKER:6,543.9 INJECTION;6,557.4 L■■I ■ APERF;6,580.0.6,618.0 INJECTION;6,627.9 - NIPPLE;6,652.4 SEAL ASSY;6,666.1 PACKER;6,666.9 SBE:6,669.4 ) ' APERF;6,682.0$684.0 NIPPLE(Milled to 2.80" 9/25/14);6,687.3 SOS;6,698.8 8J WHIPSTOCK-MONOBORE; T.V 6,750.0 WINDOW L1;6,751.0-6,758.0 IPERF;6,808.66,822.0 IPERF;6,836.0-6,&50.0- I PRODUCTION;28.67399.0 ' SLOTS;6,944.2-0,252.7 SLOTS;6.680.38,519.8 SLOTS;7,141.56,289.6. .,- SLOTS; SLOTS;7,150.2.8,739.6- LINER L1-03;6.679.8-8.520.0 LINER L1-0S 7,141.2-8,740.0 DNER L1-01;6.919.610.100.0 UNER 1.1;7,132.5-10.100.0.1 ("OF ���;_. THE STATE Alaska Oil and Gas s.�='� oConservation Commission fLAS A =:_ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 -ALAS" Fax• 907 276.7542 ppt/s1ED 1Vi�p www.aogcc.alaska.gov Robert D. Christensenl 1,...t3NSK Production Engineering Specialist 1 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1G-04L1-03 Sundry Number: 315-102 Dear Mr. Christensen: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, / ;$.11.4`74"-- Cathy . Foerster Chair, Commissioner DATED this Aday of March, 2015 Encl. RECEIVED STATE OF ALASKA J— SKA OIL AND GAS CONSERVATION COMA,..—JION FEB 2 4 2015 APPLICATION FOR SUNDRY APPROVALS ��GCC 20 AAC 25.280 1.Type of Request Abandon r Rug for Redd! r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp Well r Stimulate r Atter casing r Other: Prod to WINJ . 17 Operator Name 4 Current Well Class 5 Permit to Drill Number ConocoPhillips Alaska, Inc. - Exploratory r Development r 214-143 3 AddressStratigraphic r Service r 6.API Number. P.O. Box 100360,Anchorage,Alaska 99510 50-029-20835-63• 7 If perforating, What 8 Well Name and Number Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No r NK KRU 1G-04L1-03 ' 9 Property Designation(Lease Number) 10 Field/Pool(s) ADL025640 '" Kuparuk River Field/Kuparuk River Oil Pool ' 11 PRESENT WELL CONDITION SUMMARY Total depth MD(ft) Total Depth TVD(ft) Effective Depth MD(ft) Effective Depth TVD(ft) !Plugs(measured). Junk(measured) 8730 " 6724 - 8520' • 6682' - Casing Length Size MD TVD Burst Collapse Conductor 50 16 80' 80' Surface 2192 10.75 2222' 2222' Window L1 10 7 6751' 6645' Production 7371 7 7399' 7280' • Slotted Liner 2050 2 375 8520' 6682' Perforation Depth MD(ft) Perforation Depth TVD(ft) Tubing Size Tubing Grade Tubing MD(ft) 6680'-8520' 6756'-6682' 3.5 J-55 6699 Packers and SSSV Type Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKE FHL RETRIEVABLE PACKER ' MD=6304 TVD=6210 PACKER-BAKER FHL RETRIEVABLE PACKER • MD=6544 TVD=6443 PACKER-BAKER 2-B PACKER , MD=6667 TVD=6562 SSSV-Camco DS Nipple - MD=505 TVD=505 12.Attachments. Description Summary of Proposal r 13 Well Class after proposed work Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service r 14 Estimated Date for Commencing Operations 15 Well Status after proposed work 2/24/2015 Oil r Gas r WDSPL r Suspended r 16 Verbal Approval. Date WINJ r GINJ r WAG r Abandoned r Commission Representative GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Contact Bob Christensen/Darrell Humphrey Email n1139a.conocophillips.com Printed Name/� Robert D Christensen Title NSK Production Engineering Specialist Signature J f Phone 659-7535 Date Z/zZ/ZOi I�L�` Commission Use Only l Sundry Number Conditions of approval Notify Commission so that a representative may witness - ‘5-\OI.. Plug Integrity r BOP Test r Mechanical Integrity Test 174 Location Clearance r Other.c„,,,---1-747-t, W{ fYL-1 5 5 -7'U / T J 14 1--f v l ✓ t U Gt f-9-- -r 1 . Spacing Exception Required? Yes 0 No Li( Subsequent Form Required' f O G T APPROVED BY 3 Approved by. i � COMMISSIONER THE COMMISSION Date: -2 vri— Z/ y0/ AprAdD iGiN ani ftr 12 months fgrpy,the date of approval. p Form 10-403(Revised 10/201 V I H L Pli -`r2 / Submit Form and Attachments Du hcate ,, s1,v �— RBDMS MAR - 5 2015 1G-04L1-03 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert Kuparuk well 1G-04L1-03 (PTD#214-143) from an Oil Producer to a Water Injection Service well. 1G-04L1-03 was completed as a 3-1/2" Oil Producer on October 29, 2014. All attempts to pre-produce this well, post completion, have failed and the well is ready for conversion to its intened purpose. The conversion to water injection service is required to improve sweep effeciency in an immature A sand pattern. Area of Review: The AOR was completed on the PTD's. The top of the Kuparuk A6 sand was found at 8571' and/6687'tvd. Area Map with 1/4 mile radius around target injection zone(see attached): The map attached shows that there are 27 production/injection wells located within a % mile radius of the 1G. 04, 04L1, 04L1-01, L1-02, & L1-03 penetration of the Kuparuk A sands. Mechanical Condition of Well to be Converted: The mechanical condition of Kuparuk well 1G-04L1-03 is good and classified as a "Normal Well". A State- witnessed MIT-IA will be performed once well 1G-04L1-03 is converted to water injection, online, and stabilized. The injection tubing/casing annulus is isolated via a Baker FHL Retrievable Packers located at 6304' and (6210' tvd) and 6544' and (6443' tvd). The 10-3/4" Surface casing was cemented with 1250 sx AS III followed by 250 sx AS I. The 7-5/8" Intermediate casing was cemented with 570 sx Class 'G'followed by 250 bbls AS I. CBL and interpretation of the cement quality: The CBL interpertation was completed on the PTD's. I.,- Al111011 KUP SVC 1G-04L1-03 , ConocoPhillips - Well Attributes Max Angle&MD TD Alaska,Inc, ' j Wellbore APIIUWI Field Name Wellbore Status eel I.) MD(ftKB) Act Btm IftKB) rr re,r,r,Woihp, 500292083563 KUPARUK RIVER UNIT SVC 102.22 7,008.40 8.520.0 .-. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1G-04Lt-03,11/18201411:15 34A SSSV.NIPPLE Last WO. 34.49 11/2/1982 Vertcal schematic(actual) Annotation Depth OMB) End Date Annotation Last Mod By End Date ---- - ----------- -----s:. Last Tag'. Rev Reason GLV C/O hipshkf 11/18/2014 HANGER;24.5 Casing Strings .,^'.Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ttKB) Set Depth(TVD)... Wt/Len II...Grade Top Thread JUMOMUMMIMMIMMIIIIIEdmos LINLI,l 1-03 23/8 1.992 6.679.8 8,520.0 6,682.2 4.60 L-80 STL .--, Liner Details CONDUCTOR.29.580.0 i Nominal ID :_ .„ Top(ftKB( Top(TVD)(ftKB) Top Inel(") Item Des Com (in) 6,679.8 6,575.0 12.70 DEPLOY SHORTY DEPLOYMENT SLEEVE 1.000 NIPPLE;505.2 - Perforations&Slots Shot Dens Top(TVD) Min(TVD) (shotslt Top(ftKB) Btm(ftKB) (ftKB) (ftKB( Zone Date t) Type Coin SURFACE;29.5.2,222.0—a : 6,680.3 8,519.6 6,575.5 6,682.2 A-3,1G-04 10/29/2014 SLOTS Slotted Liner GAS LIFT;6,225.7 -; Notes:General&Safety End Date Annotation 10/29/2014 NOTE:ADD L1,L1-01,L1-02,L1-03 NIPPLE:6,2716 SEAL ASSY;6,279.6 VII FOR.6,281.0 ,— , PACKER,6,304.4 I INJECTION,6.3494 INJECTION,6,429.7 it �I APERF;6,480.06,484.0 APERF;6,488.08,516.0— APERF;6,524.06,530.0- I I PACKER;6,543.9 INJECTION;6,557.4 APERF;6,580.06,618.0 INJECTION,6627.9 - NIPPLE;6,652.4 SEAL ASSY,6,666.1 PACKER,6,666.9 - - SBE,6,669.4 -' i APERF;6,682 06,684.0 NIPPLE(Milled to 280" O II4 9/25/14),6,687.3 11�y SOS;6,698.8 ..141 r„1-Y WHIPSTOCK-MONOBORE; 6750.0 WINDOW L1;6,751.0.6,756.0 i IPERF;6,8080.6,822.0—. '-,.I;1 f IPERF;6,8360.6,850.0— Rill! i'1,411 I L. PRODUCTION;28.0-7,399.0 SLOTS;6,944.28.252.7 SLOTS;6.680.38,519 6 SLOTS;7,141.58,289.6 SLOTS;7.150 2-8.739 6 LINER L7-03;6,679.88,520.0 LINER L1-02;7,141.2-8.7400 UNER L181;6,919.610,109.0 LINER L1;7,132610,100.0a 0. • ri --..ero (41 i i i 05 1 0 Legend o o 0G INJ SWAP WELL OPENINGS ' ' 1G-04 Om— '''' i —1 :=1G-04L1 1 wg 1G-04L1-01 ,` a sim 1G-04L1-02 memo 1G-04L1-03 3C -�I-+ to 1/4 MILE RADIUS ��� 6 , l\ 1_11G-04 qz , Q i G-04 L1 1G-0-8,B1\ 01G-04L1-01 1103 Q1G-04L1-02 ( •-04 0L1 1G-04 -03 \1�/ WELLS IN 1/4 MILE RADIUS ��S Aco. \' O •/ -- 1 G-01 70 ot.G I 11> 1G•1081� `�j - J 1G-02 N -ls d' f 1G-03 ,.. O / • —1G-04L1PB1 •0 —1G-05 —1 G-06 . . .. 1G 77 —1 G-07 0 0 i \, —1G-08 °' r "k, \ 00 -1G-08A \ —1G-08AL1-01 C7 q, \\ -1G-08AL2 Q \ —1 G-08AL2-02 \\ —1G-08AL2PB1 \ —1G-08PB1 —1 G-09 —1G-10 1G-10A !" 1G-10B ----1 G-10 BL 1 —1G-10BL2 —1G-10BPB1 —1 G-11 ---1G-12 -1G-13 1G-15 ConocoPhillips -°----1G-16 Alaska,Inc. 1G-17 —1R-01A Injection Swap Analysis —1R-01B 1G-04, 1G-04L1, 1G-04L1-01, 1G-4L1-02, 1G-04L1-03 y e,2 1/4 MILE RADIUS AROUND ALL WELLS N 0-0 -FIDENTIAL w 35. Drill Site a � .lDo ozs o Primary Road / Miles 1G-02.MXD csv1ono,s • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Tuesday, February 24, 2015 11:50 AM To: n1139@conocophillips.com Subject: KRU 1G-04 Well and Laterals Sundry Applications: Quarter-Mile Area of Review Bob and Darrell, Under 20 AAC 25.402(c)(1), an application for injection must include a plat showing the location of each proposed injection well, abandoned or other unused well, production well, dry hole, and other well within one-quarter mile of each proposed injection well. This plat is required by regulation and must not be stamped confidential. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue . Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. <914 - 11+3 Well History File Identifier Organizing(done) ❑ Two-sided ❑ Rescan Needed RESC N: OVERSIZED: NOTES: olor Items: ❑ Maps: Grayscale Items: ogs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: � BY: Maria Date: 5 // LV /s/ nir Project Proofing BY: 412° Date: 45/15 /s/ IIIP Scanning Preparation _x 30 = + = TOTAL PAGES I!5 (Count does not include cover sheet)yyj BY: C..f2r.........)1a Date: Dig iS I lsl Production Scanning Stage 1 Page Count from Scanned File: (0 4) (Count does include cover sheet) Page Count Matches Number in Scanning Pr paration: VYES NO BY: diSM Date: (4,15 /S 1s/ n/h° Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michal ate: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. 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W W W W W J 3 ? 0 a C7 0 U C O O O O M N cm N lb 0 ri o A co N Z a N C) u La. 9 5 T om 1° a a C qZ J P V Z_ 7 d co co Ncc J u)Q C d O u) D. CL J W = cc a O v W 0z (..) 0 o Z Q o L N N 7 J o aCO NC � o s 15 0 N 17). E C. - Uo en N o 0 o _i Q ore 0. 0 I ' ~ Oz N cNi /y� • O W CC Y n cu CO a o Q 0 c Y a) Q C a 0 E Z E U co Z d 3 a N CD M > m ct H -0 o) N d d Ce D o.. an4 0 16 C.,) a M V ¢ 4ECEIVED JAN 2 9 2b1L, Letter of Transmittal AOGcc Frill r_ _ _ _ __ _ _ _ _- BAKER Date: DATA LOGGED January 29, 2015 nnK.B�o�ER HUGHES ___ To: From: State of Alaska, AOGCC Jesse Salyer 333 West 7th Ave, Suite 100 Baker Hughes INTEQ Anchorage, Alaska 99501 795 East 94th Avenue Anchorage, Alaska 99515 [Please find enclosed the final well data for the following well(s): Wells: 1G-04L1, 214-140 25334 1G-04L1-01, 214-140 25335 { 1G-04L1-02, 214-141 25336 1 -04L1-03. 214-142 25337 1G-04L1PB1 214-143 2533D Enclosed for each well(s): 1 hardcopy print of final logs • 2MD, 5MD & TVDSS 1 compact disk containing final field data • CGM • PDF • SURVEY • TIFF • LAS • PE TA CAN S I RECEIVED STATE OF ALASKA N O V 20 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND SCC la Well Status: Oil ❑ , Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ lb Well Class 20AAC 25.105 20AAC 25.110 Development 0 Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service ❑ StratigraphicTest❑ 2 Operator Name5 Date Comp.,Susp., {k 12 Permit to Drill Number ConocoPhillips Alaska, Inc. , or Aband.: October 26,2014 214-143/ - 3 Address 6 Date Spudded 13.API Number P.O.Box 100360,Anchorage,AK 99510-0360 October 25,2014 50-029-20835-63• 4a Location of Well(Governmental Section): 7.Date TD Reached. 14.Well Name and Number: Surface: 1246'FSL,238'FWL,Sec.29,T12N,R10E, UM October 28,2014 KRU 1G-04L1-03 Top of Productive Horizon 8. KB(ft above MSL): 90'RKB ` 15 Field/Pool(s) 1176'FSL,4221'FEL,Sec.29,T12N, R10E, UM GL(ft above MSL). 61'AMSL. Kuparuk River Field , Total Depth 9 Plug Back Depth(MD+TVD) 570'FNL,4204'FEL,Sec.32,T12N,R10E, UM Kuparuk River Oil Pool , 4b.Location of Well(State Base Plane Coordinates,NAD 27) 10 Total Depth(MD+TVD) 16.Property Designation: Surface' x-540010 y- 5981892 Zone-4 , 8730'MD/6724'TVD • ADL 25640 TPI: x-540831 y- 5981826 Zone-4 11 SSSV Depth(MD+TVD) 17.Land Use Permit Total Depth: x-540864 y- 5980081 Zone-4 nipple @ 505'MD/505'TVD 2571 18.Directional Survey Yes Q✓ No❑ 19.Water Depth,if Offshore 20 Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1539'MD/1539'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25 071) 22 Re-drill/Lateral Top Window MD/TVD GR/Res 7141'MD/6737'ND 23 CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62 58# H-40 30' 80' 30' 80' 24" 250 sx AS II 10.75" 45.5# J-55 30' 2222' 30' 2222' 13.5" 1250 sx AS III,250 sx AS I 7" 26# K-55 28' 7399' 28' 7280' 8.75" 570 sx Class G,250 sx AS I 2.375" 4.6# L-80 6680' 8520' 6575' 6682' 3" slotted liner 24 Open to production or injection? Yes ❑ No ❑ If Yes,list each 25 TUBING RECORD Interval open(MD+TVD of Top&Bottom,Perforation Size and Number). SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 3.5" 6667' 6304'MD/6210',6544'MD/6443'ND, slotted liner from 6680'-8520'MD 6575'-6682'ND 6667'MD/6562'ND r's;;;k•., _ 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC .r Was hydraulic fracturing used during completion? Yes❑ No Q J �, 2 Q 114 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 3 y .. none 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc) waiting on facility hook-up J Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No Q , Sidewall Cores Acquired'? Yes ❑ No Q r If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed) Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25 071. NONE ABC MS NOV 2 4 LUi 16 Form 10-407 Revised 10/2012 v �Z/z y `¢ CONTINUED ON REVERSE -ij 4 Mao/ao/ Submit original only 1 29. GEOLOGIC MARKERS(List all formations and mai ;ncountered): 30 FORMATION TESTS NAME MD TVD Well tested? Yes Q No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1539' 1539' needed,and submit detailed test information per 20 AAC 25.071. Top Kuparuk A3 7157' 6735' Top Kuparuk A6 8571' 6687' Top Kuparuk A6 8638' 6698' Top Kuparuk A5 8665' 6705' Top Kuparuk A4 8706' 6717' N/A Formation at total depth: Kuparuk A4 31. LIST OF ATTACHMENTS Summary of Daily Operations, schematic,final directional surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: James Ohlinger @ 265-1102 Email James J.Ohlingerta'�.conocophillips.com 90 Printed Name D.Venha s Title CTD Engineering Supervisor Q —,9—/y Signature -yi ` �y11y�— Phone 263-4372 Date ////g// L INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20:Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain) Item 27:Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 KUP SVC 1G-04L1-03 ConocoPhillips ; Well Attributes Max Angle&MD TD Alaska Inc WIncl Wellbore API/UWI Field Name Wellbore Status I I') MD(11KB) Act Btm 118/B) ..'I r...xihimps 500292083563 KUPARUK RIVER UNIT SVC 8,520.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1G-04L1-03.11/10201410:09'.24 AM SSSV:NIPPLE Last WO: 34.49 11/2/1982 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date R Rev ,� Last Tag. Reeason.ADD LATERALS LL L1-01.L1-02 haggea 11/7/2014 HANGER;24.5 Rev Re Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread ,111,.yOI•LINER L1-03 2 3/8 1.992 6,679.8 8,520.0 4.60 L-80 OIL Liner Details CONDUCTOR;29.580.0 , Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl 1) Item Des Corn (in) 6,679.8 DEPLOY SHORTY DEPLOYMENT SLEEVE 1.000 NIPPLE;505.2 Perforations&Slots I Shot Dens Top(ND) Btm(ND) (shots/ Top(ItKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com SURFACE:29.5-2.222.0 6,680.3 8,519.6 A-3.1G-04 -10/29/2014 SLOTS Slotted Liner GAS LIFT;6.225.7 Notes:General&Safety End Date Annotation 1.11A1— 10/29/2014 NOTE:ADD L7,L7-01,L7-02,L1-03 NIPPLE;6,271.6 SEAL ASSY;6,279.6irtoi PBR;6,281.0 PACKER;6,304.4 1 INJECTION;6,349.4 INJECTION;6,429.7 at I APERF;6,480.0-6,484.0 APERF;6,488.06,516.0—.1 4_. APERF;6,524.06.5300— a I PACKER;6.543.9 INJECTION;6,557.4 • APERF;6,580.06,618.0 INJECTION;6,627.9 - NIPPLE;6,652.4 ti SEAL ASSY;6,666.1 PACKER',6,666.9 _ _ _ - DOE,6.669.4 i APERF;6,682.0-6,684.0 NIPPLE(Milled to 2.80" 9/26/14);6,687.3 SOS;6,698.8 WHIPSTOCK-MONOBORE; 6,750.0 WINDOW L1;6,751.06,756.0 IPERF;6,808.0.6,822.0 (PERF;6,836.0-6,850.0 I 1 PRODUCTION;28.0-7.399,0 1 I SLOTS;6,944.28.252.7 SLOTS;6,680.38.519.6 SLOTS;7,141.58289.6 SLOTS;7,150.28,739.6 LINER L7-03;6.679.88,520.0 LINER L1-02;7,14128,740.0 LINER L1-01;6,919.610,100.0 LINER L1;7,132.5.10,100.0a 0 ct •-+ o _ co O a) E v css a) E c M it '.- 0' O `>= N US .4 co co E U N in O O O J J sr V N N O) O N CO CO ^ p N co f� V (n N J m c II 15 -0 In N O co Lo a CO CO > a a O N. a -'v_= co m coo -0 m L 2 0 c M iz v Is as _� co N_ J N N L 0 F— N a' 2 N CO - co O t o o a CO C 13 c m CO o d o C6 m CO c N O in" ai m pp E p EY a) (Ln Q o_ g� o o a n 2 a. �N ra ti = c - 'v - zr'- a) c •E o p a) N N M a) ( a)N'� C71 ((DD a Cr)CO• d W m "O co CO .0 co,C N N '.C—O coC N _ O 0 'C (0 O (6 (6 (0 N (0 u) Lis 2 o r- 0 W m co U U O..L :5 O o-o Fso J o 0 d a 0 a O c a) 0 CJ N O a) E 4k E E N J E J E 2rcil E 0-LI.. E E (6 co co (a = CO I co N (0 m m CO .0 `�.�, U Q) 0 0 MLL 0 Lt_0 Q))IQ 0 NO) 0� .2 ' N N N N a) a) N a)N O N E\-1- Q) a)s.- CV- O N 2 i Y Y Y ZY Y Z O ,; CO CO CO Ca CO LO M M M M m m M CO M M CO CO M M 'co ' V .i Y ., A oo O Lto iii Ili I O oH111111 . � , j !!! 'i ' Cl.) O I I L Q!!! 11 0 N N cL2 (nom 000 ON (Mn i o) c2 2 2 c2 -a CO0000D di X03 c ' 'N yOM .M tl0 O3 E T Q CO CO ,I c3 a) -0 0 000 000 N 0003 CO II 'f ,i _� th.c2 m N(CO CCOO COSNCD 0.�p i, '� N th N Vl V V M 3 .. m l- '' CO. O 000 JU- CO __ 'i ,i :1: t a 0 2 0 Q O N .' .: p_M Om '' i r V , II (O i' '' O (O III I 03 p r) II .) ' 0a LL _a ''IH - + 0 + i' Vt ,' J c 0 v•c 1' �0 o r (0\ ,' N N LiJ 1 G-04 WELL WORK SUMMARY DATE SUMMARY 7/25/2014 TAGGED FILL @ 6843' SLM. SET 2.75" CA-2 PLUG & DUAL SPARTEK GAUGES IN D NIPPLE @ 6687' RKB. RETURN IN FIVE DAYS FOR C-SAND BHP. 8/1/2014 MEASURE BHP (C-SAND) © 6610' RKB (2819 PSI); PULLED 2.75" CA-2 PLUG W/GAUGES (A- SAND) © 6687' RKB (3660 PSI). JOB COMPLETE. 8/9/2014 (PRE-CTD) FUNCTION LDS AND GN -T, IC, OC ALL OK. 8/20/2014 TAG FILL © 6838' SLM. SET HOLE FINDER @ 6621' RKB. MITT TO 2300 PSI (PASSED); DEPLOYED CATCHER TO 6687'RKB & PULLED 1.5" HFCV(MODERATE FLOW CUT) © 6628' RKB; PULLED CATCHER © 6687' RKB. READY FOR E-LINE 8/29/2014 LOG ACROSS C-SAND STRADDLE ABOVE BAKER 2B PACKER USING TMD3D FOR SILICON ACTIVATION FROM 6787'-6200'. LOG CORRELATED TO SLB CEMENT BOND LOG DATED 26 OCT 1982. DATA SENT TO ANCHORAGE FOR PROCESSING/INTERPRETATION. IN PROGRESS. 8/30/2014 PERFORATE INTERVAL 6682'-6684' USING 2" HSC, LOADED 6SPF, PHASED 60 DEG, BH CHARGES. SET 2.69" HES FASDRILL COMPOSITE BRIDGE PLUG AT 6646'. LOG CORRELATED TO SLB CEMENT BOND LOG DATED 26 OCT 1982. READY FOR PRESSURE TESTING. 8/31/2014 PUMP AND TEST PLUG TO 3000 PSI. TEST FAILS. PERFORM INJECTIVITY TEST JOB COMPLETE 9/24/2014 TAGGED CBP AT 6646' RKB. PUMPED 25 BBLS TOTAL OF 15.8#CMT, 16 BBLS OUTSIDE THE TUBING THROUGH THE OPEN INJ MANDREL AT 6628' RKB. CLEANED OUT CMT IN TBG TO 6565' RKB. *JOB IN PROGRESS* 9/25/2014 PRESSURE TEST TBG - PASS. TAG CMT AT 6486' CTMD, MILL CMT FOR -2 HRS. PAUSE MILLING ABOVE CBP, PRESSURE TEST, PRESSURE BLEEDING OFF. MILL CBP FOR -1 HR, CHASE CBP PIECES. MILL NIPPLE AT 6687' RKB TO 2.80" FOR -50 MIN. TAG BTM AT 6860' RKB. *JOB IN PROGRESS* 9/26/2014 UNABLE TO REACH BOTTOM AT 6860' RKB; TAGGED AT 6805' RKB. SQUEEZE 26 BBLS 17# CMT INTO A SAND PERFS. UNABLE TO ACHIEVE SQUEEZE PRESSURE HIGHER THAN 348 PSI EVEN AFTER HESITATION SQUEEZES. JET CASING AND TUBING WITH CONTAMINANT DOWN TO TAG AT 6805' RKB AND WASH JEWELRY. *JOB IN PROGRESS* 9/27/2014 PUMP 27 BBLS 17#CMT, SQUEEZE APPROX 7.3 BBLS INTO A SAND PERFS. ACHIEVE 2000 PSI SQUEEZE PRESSURE AFTER HESITATION SQUEEZES. CLEAN OUT CMT IN TUBING TO 6565' RKB, WASH JEWELRY ON WAY OOH. LEAVE 1700 PSI ON WH. *JOB COMPLETE* 9/30/2014 TAGGED CMT TOP © 6550' SLM. TESTED TBG/CMT 2500 PSI, GOOD. COMPLETE. 9/30/2014 (PRE-CTD) PT MV- FAILED; SSV- FAILED; SV- FAILED; DDT MV- PASSED; SSV- FAILED; SV- PASSED 10/1/2014 (PRE-CTD): TREE SWAP. T-POT (PASSED), T-PPPOT (PASSED), T-DDT (PASSED),T-DDT ABOVE BPV(PASSED), IA-DDT (PASSED), OA-DDT (PASSED). 10/2/2014 (Pre-CTD): TREE SHELL TEST PASSED TO 5000 PSI. MV NEGATIVE PASSED. MV PPT PASSED. SSV NEGATIVE . SSV PPT PASSED. SV NEGATIVE PASSED. SV PPT PASSED. ConocoPhillips Time Log & Summary We!Mew Web Reporting Report Well Name: 1G-04 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 10/5/2014 1:00:00 PM Rig Release: 10/30/2014 3:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10/04/2014 24 hr Summary 18:00 23:00 5.00 0 0 MIRU MOVE RURD P Nipple down stack,disconnect PUTZ, MP line, SSSV and SSV from 21-15,continue prepping to move rig. 23:00 00:00 1.00 0 0 MIRU MOVE RURD P Trucks on location, PJSM-load shop onto lowboy, pull rig off well 10/05/2014 Move rig from 2T-Pad to 1 G-Pad 00:00 03:00 3.00 0 0 MIRU MOVE RURD P Move rig off of well. 03:00 09:30 6.50 0 0 MIRU MOVE MOB P Move rig 2T pad to CPF-2,wait at CPF-2 to allow change out in the field to 05:15 to 07:15, continue to move rig towards 1G pad. 09:30 13:00 3.50 0 0 MIRU MOVE MOB P Arrive on location, PJSM. Prep well site for modules,spot modules over 1G-04, berm up cellar, R/U Putz, steam and interconnect, pre-spud checklist. 13:00 14:00 1.00 0 0 MIRU WHDBO NUND P NU BOPE,MP line and cellar lines, check all flange bolts. 14:00 17:00 3.00 0 0 MIRU WHDBO RURD P Grease BOPE stack,fluid pack equipment. MU hardline to tiger tank. 17:00 00:00 7.00 0 0 MIRU WHDBO BOPE P Begin Initial BOPE test,250/3500 psi,2500 psi annular,state test waived by Jeff Jones 10/06/2014 Finish BOP testing, M/U milling BHA, RIH to mill cement from 6566'to 6652'. POOH to P/U D331. 00:00 03:00 3.00 0 0 MIRU WHDBO BOPE P Continue initial BOPE test, 250/3500psi,2500psi annular,state test waived by Jeff Jones 03:00 04:30 1.50 0 0 MIRU WHDBO BOPE P Stab Injector onto well,fill coil, P/T inner reel valve and pac-off. 04:30 06:30 2.00 0 0 MIRU WHDBO MPSP P Pull BPV 06:30 09:00 2.50 0 0 MIRU WHDBO PRTS P Pressure test PDL's and tiger tank line,test gas alarms. 09:00 09:30 0.50 0 0 SLOT WELLPF MILL P Pre spud meeting held with day crew -Nathan Wheeler 09:30 11:42 2.20 0 52 SLOT WELLPF MILL P PJSM-Begin to MU Milling BHA#1, 0°AKO motor with 2.69"x 2.98" Bi-center bit, call from town,confirm procedure addendum and BHA MU, complete MU of BHA#1,surface test tools. Page 1of19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:42 15:00 3.30 52 6,566 SLOT WELLPF MILL P TIH with BHA#1,-5'correction at K1 marker(6,313')open EDC, PUW 27k,swap to 9.6 ppg milling fluid, Close EDC, RBIH. 15:00 18:06 3.10 6,566 6,652 SLOT WELLPF MILL P 6,566', Tag top of cement pumping minimum, PUW 27k, begin milling cement 1.42 bpm at 3114 psi,WOB 1.4k, ROP 54 fph, 1:1 returns to"W' nipple. Note: 2 stalls at 6,630.81'. 18:06 19:42 1.60 6,652 52 SLOT WELLPF MILL P TOOH with BHA#1 19:42 20:03 0.35 52 52 SLOT WELLPF MILL P On surface, monitor well for flow, pre spud with night crew-Mike Vancleve 20:03 20:27 0.40 52 0 SLOT WELLPF MILL P PJSM-LD BHA#1 Hycalog Bi-center bit, 1-1-CT-A-X-I-NO-BHA 20:27 20:51 0.40 0 51 SLOT WELLPF MILL P MU BHA#2, 0°AKO motor with 2.80"go,2.79 no-go D331 mill with side cut(ridgeset) 20:51 22:06 1.25 51 6,305 SLOT WELLPF MILL P RIH with BHA#2 22:06 22:21 0.25 6,305 6,330 SLOT WELLPF DLOG P 6305',Tie into the K1 marker correction of minus 5.5', 22:21 22:36 0.25 6,330 6,630 SLOT WELLPF DLOG P Log CCL down at 1000fpm 22:36 00:00 1.40 6,630 6,653 SLOT WELLPF MILL P Stall motor at 6638', PUW 26k, continue down to 6652',start milling. 10/07/2014 Milled cement pilot hole from 6652'-6716', 00:00 01:00 1.00 6,653 6,655 SLOT WELLPF MILL P Continue milling ahead, 1.43bpm at 2880psi, BHP 3789,WHP 25, IA 15, OA O 01:00 02:15 1.25 6,655 52 SLOT WELLPF TRIP P 6655', POOH 02:15 02:30 0.25 52 52 SLOT WELLPF SFTY P PJSM-Check well for flow, 02:30 03:00 0.50 52 0 SLOT WELLPF PULD P L/D BHA#2 03:00 03:30 0.50 0 52 SLOT WELLPF PULD P M/U BHA#3,with 2.98"bi-center bit, P&C, EDC, DPS, DGS and blind connector. 03:30 04:30 1.00 52 52 SLOT WELLPF TRIP T Surface test of BHI tools, EDC failed, PJSM,swap out EDC, 04:30 05:48 1.30 52 6,338 SLOT WELLPF TRIP P RIH with BHA#3 05:48 06:03 0.25 6,338 6,349 SLOT WELLPF DLOG P 6338',Tie into the K1 marker correction of minus 6.5', 06:03 06:33 0.50 6,349 6,655 SLOT WELLPF TRIP P Continue RIH 06:33 08:33 2.00 6,655 6,688 SLOT WELLPF MILL P Tag cement at 6655', 1.45bpm at 2841psi, BHP 3758',WHP 21, IA 16, OA 0, Mill ahead 6655'to 6688'. 08:33 09:48 1.25 6,688 52 SLOT WELLPF TRIP P POOH 09:48 10:48 1.00 52 0 SLOT WELLPF PULD P PJSM-L/D BHA#3 10:48 11:48 1.00 0 52 SLOT WELLPF PULD P PJSM, Reconfig BHA#4, Straight motor, D331 with side ridge set cutters, and stabilizer. M/U to coil and surface test, Page 2 of 19 0 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:48 13:00 1.20 52 6,310 SLOT WELLPF TRIP P RIH, BHA#4 To mill nipple 13:00 13:12 0.20 6,310 6,330 SLOT WELLPF DLOG P Log K1 tie in for-6.5'correction, PUW=27K, Close EDC 13:12 13:42 0.50 6,330 6,688 SLOT WELLPF TRIP P RIH to mill nipple, Didn't see anything @ mandrel @ 6628 13:42 14:18 0.60 6,688 6,692 SLOT WELLPF MILL P Milling D nipple areaq, 1.46 BPM @ 2832 PSI FS 14:18 15:54 1.60 6,692 50 SLOT WELLPF TRIP P 6692, Let WOB drop off, Trip out, Recip GLM @ 6630, Looks clean. Open EDC @ 6641 15:54 17:42 1.80 50 0 SLOT WELLPF PULD P At surface, PJSM, Flow Check Well, Lay down BHA#4 ****Note: D331 w/sidecut(ridgeset) gauged 2.79"no-go 17:42 18:57 1.25 0 62 PROD1 RPEQP1 PULD P PU milling BHA#5 18:57 20:27 1.50 62 6,325 PROD1 RPEQP1 TRIP P RIH with milling assyembly,0.9° AKO motor and D331 slick gauge. 20:27 20:42 0.25 6,325 6,325 PROD1 RPEQP1 DLOG P 6325',Tie into the K1 marker correction of minus 6.0'. 20:42 21:27 0.75 6,325 6,692 PROD1 RPEQP1TRIP P Continiue RIH RIW 21:27 00:00 2.55 6,692 6,716 PROD1 RPEQP1 MILL P 6692', Mill cement pilot hole, 1.44bpm at 3170psi, BHP 3785, WHP 23, IA 16, OA 0 ****Note: Contact with casing at 6710',30psi difference in bore pressure at 23:12. 10/08/2014 Finished milling 2.80"pilot hole to 6780', POOH, P/U HES memory caliper tool, logged with caliper from 6775' -6586', POOH, UD BHA#7 00:00 02:00 2.00 6,716 6,730 PROD1 RPEQP1 MILL P Continue milling 2.80"cement pilot hole with 0.9°AKO motor and D331 slick gauge. 02:00 02:15 0.25 6,730 6,730 PROD1 RPEQP1 MILL P Pump 5x5 sweep,chase above top of cement 6560', PUW 26k 02:15 05:00 2.75 6,560 6,780 PROD1 RPEQP1 MILL P Continue milling, 1.44bpm at 3100psi, BHP 3835,WHP 20, IA 23, OA 0 05:00 05:15 0.25 6,780 6,325 PROD1 RPEQP1TRIP P 6780',TD cement pilot hole. PUH for tie in. PUW 25k 05:15 05:27 0.20 6,325 6,345 PROD1 RPEQP1 DLOG P Tie into the K1 marker,correction of +.5 05:27 07:09 1.70 6,345 61 PROD1 RPEQP1TRIP P RIH and dry drift transition area 6692 to 6715, Looks good,Trip out for caliper 07:09 09:03 1.90 61 0 PROD1 RPEQP1PULD P On surface, Flow check well, PJSM, Lay down BHA#5, Mill out at 2.79 No Go 09:03 10:57 1.90 0 61 PROD1 RPEQP1 PULD P PJSM w HES memory caliper to P/U caliper, M/U to coiltrack and coil, surface test tool 10:57 12:15 1.30 61 6,320 PROD1 RPEQP1TRIP P RIH, EDC open, BHA#6, Caliper 12:15 12:21 0.10 6,320 6,338 PROD1 RPEQP1 DLOG P Log K1 for-6.5'correction, PUW=26K Page 3 of 19 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:21 12:57 0.60 6,338 6,775 PROD1 RPEQP1TRIP P RIH to logging depth @ 6775 12:57 13:21 0.40 6,775 6,586 PROD1 RPEQP1DLOG P Wait for tool to activate down hole, @ 13:14, Log up at 50 FPM to 6586 13:21 14:51 1.50 6,586 59 PROD1 RPEQPI TRIP P Stop and wait for arms to close on tool,Trip out of well 14:51 16:51 2.00 59 0 PROD1 RPEQP1 PULD P On surface,flow check well, Lay down BHA#6 16:51 19:06 2.25 0 73 PROD1 RPEQP1PULD P PJSM-M/U WS setting BHA#7 19:06 20:36 1.50 73 6,325 PROD1 RPEQP1 TRIP P RIH with Baker Oil Tools 3-1/2" Monobore WS J-Hydraulic setting BHA#7 20:36 20:51 0.25 6,325 6,354 PROD1 RPEQPI DLOG P 6325',Tie into the K1 marker correction of minus 6.5'. __ 20:51 21:21 0.50 6,354 6,761 PROD1 RPEQP1TRIP P Continue RIH to setting depth. 21:21 21:36 0.25 6,761 6,761 PROD1 RPEQPI WPST P 6750'Close EDC,pressure up to set the anchor and released at 3800psi. 21:36 22:51 1.25 6,761 73 PROD1 RPEQP1TRIP P POOH, pumping 0.75bpm. 22:51 23:21 0.50 73 73 PROD1 RPEQPI SFTY P Check well for flow PJSM 23:21 23:36 0.25 73 0 PROD1 RPEQP1 PULD P LID WS setting BHA#7 23:36 00:00 0.40 0 0 PROD1 WHPST PULD P M/U window milling BHA#8,with 0.6°AKO motor,string reamer 2.79" no-go, and new window mill. 10/09/2014 RIH,set TOWS at 6750', POOH, L/D BHA#7,M/U window milling BHA#8, RIH milled 2.80"casing exit, POOH, undeployed the window milling BHA. 00:00 00:15 0.25 0 75 PROD1 WHPST PULD P Continue M/U window milling BHA#8 00:15 01:30 1.25 75 6,335 PROD1 WHPST TRIP P RIH, Baker X-Treme motor w/0.6° AKO,string reamer 2.79"(no-go), new window mill. 01:30 01:45 0.25 6,335 6,348 PROD1 WHPST DLOG P Tie into the K1 marker correction of- 6.5 01:45 02:00 0.25 6,348 6,751 PROD1 WHPST TRIP 15-----Continue CRIH,dry tag WS at 6751', PUW 27k, 02:00 09:12 7.20 6,751 6,756 PROD1 WHPST WPST P_Start time milling window, 1.48bpm at 3080psi, BHP 3813,WHP 27, IA _ 18, OA 0 09:12 10:12 1.00 6,756 6,757 PROD1 WHPST WPST P Call mill exit,WOB down to 250 LBS, ride like this for anoth 1/2 foot to 6756.0 No motor work, No DHWOB(190Lbs). Consult with town speed up in attemp to gain DHWOB _/Motorwork 90-120 FPH 10:12 10:24 0.20 6,757 6,757 PROD1 WHPST WPST P P/U to drift/check for bottom, PUW=29K, RBIH set down weight @ 6757,6K,Very little formation in samples. P/U off bottom to establish pump rates and pressure 10:24 12:42 2.30 6,757 6,771 PROD1 WHPST WPST P Milling, 1.47 BPM @ 2982 PSI FS, Formation picking up in samples 12:42 13:54 1.20 6,771 6,770 PROD1 WHPST WPST P TD Rathole, Make reaming passes per procedure, HS, 30R and 30L 13:54 14:00 0.10 6,770 6,771 PROD1 WHPST WPST P Dry drift window, Looks good Page 4 of 19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 15:30 1.50 6,771 69 PROD1 WHPST TRIP P Trip out of well 15:30 18:00 2.50 69 0 PROD1 WHPST PULD P At surface, PJSM to PUD BHA#8 18:00 18:15 0.25 0 0 PROD1 DRILL SFTY P PJSM-Coil Management 18:15 21:15 3.00 0 0 PROD1 DRILL CTOP P Hand cut 17.5'of coil to remove flat spot, install kenall CTC,pull test 35, head up BHI UQ.service INJH, and inspect choke B. 21:15 21:30 0.25 0 0 PROD1 DRILL PULD P PJSM-M/U build BHA. 21:30 22:15 0.75 0 63 PROD1 DRILL PULD P Pressure deploy build BHA#9 22:15 00:00 1.75 63 6,320 PROD1 DRILL TRIP P RIH,with build BHA#9, Baker X-Treme motor 2.3+AKO, no-res tool as per town, and RB Hughes bi-center bit 10/10/2014 Finished performing CM,deployed build section BHA#9, RIH,drilled build section to TD 7103. 00:00 00:15 0.25 6,320 6,320 PROD1 DRILL DLOG P Tie into the K1 marker correction of minus 7' 00:15 00:33 0.30 6,320 6,770 PROD1 DRILL TRIP P Continue RIHTB 00:33 01:45 1.20 6,770 6,785 PROD1 DRILL DRLG P 6770', OBD 1.48bpm at 3100psi, BHP 4100,WHP 275, IA 24, OA 0, Stacking WOB, no motor work, hanging up on BHA?, PUH,stacked out again,slipped and stalled, PUH, try again,drilling ahead at 6782', 01:45 01:51 0.10 6,785 6,785 PROD1 DRILL DRLG P P/U check ckoke pressures 01:51 04:21 2.50 6,785 6,835 PROD1 DRILL DRLG P Drill, 1.48 BPM @ 3190 PSI FS, BHP=4107 04:21 04:27 0.10 6,835 6,835 PROD1 DRILL WPRT P Mini Wiper, PUH Roll TF around off right stop, PUW=26K 04:27 09:15 4.80 6,835 6,970 PROD1 DRILL DRLG P 6835', Drill, 1.45 BPM @ 3190 PSI FS, BHP=4123 09:15 09:51 0.60 6,970 6,320 PROD1 DRILL WPRT P Wiper to top of cement @ 6320', PUW=26K 09:51 09:57 0.10 6,320 6,345 PROD1 DRILL DLOG P Log K1 for+1 foot correction 09:57 10:21 0.40 6,345 6,770 PROD1 DRILL WPRT P Continue wiper in well good pass through window 10:21 10:27 0.10 6,770 6,785 PROD1 DRILL DLOG P Log RA marker @ 6756,TOW=6750, BOW=6755.5 10:27 10:33 0.10 6,785 6,970 PROD1 DRILL WPRT P Continue wiper to bottom 10:33 12:51 2.30 6,970 6,995 PROD1 DRILL DRLG P 6970', Drill Ahead, 1.46 BPM @ 3150 PSI FS, BHP=4157 12:51 13:03 0.20 6,995 6,995 PROD1 DRILL WPRT P 6995, Stacking, No differential, BHA wiper, PUW=26K. 13:03 15:15 2.20 6,995 7,059 PROD1 DRILL DRLG P Drill, 1.45 BPM @ 3060 PSI FS, BHP=4127,Start new mud down @ 15:03 15:15 15:21 0.10 7,059 7,059 PROD1 DRILL WPRT P BHA Wiper, PUW=29K 15:21 16:39 1.30 7,059 7,103 PROD1 DRILL DRLG P 7059 Drill, NEW MUD @ BIT, 1.45 BPM @ 3404 PSI FS 16:39 18:09 1.50 7,103 63 PROD1 DRILL TRIP P Call end of build @ 7103,Trip out for lateral BHA, PUW=25K Page 5 of 19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:09 18:24 0.25 63 63 PROD1 DRILL SFTY P PJSM-undeploy build BHA. 18:24 19:54 1.50 63 0 PROD1 DRILL PULD P Undeploy BHA#9, L/D 19:54 21:09 1.25 0 0 PROD1 DRILL PULD P M/U L1 Lateral BHA#10 21:09 21:24 0.25 0 0 PROD1 DRILL SFTY P PJSM-Deploy BHA 21:24 22:45 1.35 0 72 PROD1 DRILL PULD P Deploy L1 Lateral drilling BHA#10 22:45 0000 1.25 72 6,325 PROD1 DRILL TRIP P RIH with P&C, EDC, DPS, DGS, USR, HOT, 2-3/8"X-Treme motor 0.5°AKO, rebuild Hycalog bi-center bit. 10/11/2014 Finished POOH, undeployed build BHA, M/U and deployed lateral BHA, RIH, drilled ahead in the L1 Lateral. drilled ahead from 7104'to 8148'. 00:00 00:15 0.25 6,325 6,342 PROD1 DRILL DLOG P Tie into the K1 marker correction of minus 6.5'. 00:15 00:45 0.50 6,342 7,103 PROD1 DRILL TRIP P Continue RIHTB 00:45 03:00 2.25 7,103 7,310 PROD1 DRILL DRLG P 7103', OBD 1.44bpm at3850psi, BHP 4125,WHP 79, IA 24, OA 0 03:00 03:15 0.25 7,310 7,110 PROD1 DRILL WPRT P 7310',Wiper up hole to 6770', PUW 24k 03:15 03:45 0.50 7,110 6,770 PROD1 DRILL DLOG P Madd pass from 7110'-6770', 03:45 04:15 0.50 6,770 7,310 PROD1 DRILL WPRT P Wiper back in hole from 6770'RIW 04:15 07:09 2.90 7,310 7,510 PROD1 DRILL DRLG P 7310', BOBD 1.43 bpm at 3760psi, BHP 4100,WHP 28, IA 32, OA 0 07:09 08:21 1.20 7,510 7,510 PROD1 DRILL WPRT P Wiper trip to window, PUW=26 08:21 11:27 3.10 7,510 7,710 PROD1 DRILL DRLG P 7510', Drilling Aheadm 1.45 BPM @ 3650 PSI FS, BHP=4200 11:27 12:51 1.40 7,710 7,710 PROD1 DRILL WPRT P Wiper trip to window with tie in for +1.5', PUW=29K, Pumped 5 X 5 sweeps 12:51 17:21 4.50 7,710 7,910 PROD1 DRILL DRLG P 7710', Drill, 1.5 BPM @ 3900 PSI FS, BHP=4199 17:21 18:21 1.00 7,910 7,910 PROD1 DRILL WPRT P 7910;,Wiper up hole to 7100', PUW 28k 18:21 22:21 4.00 7,910 8,110 PROD1 DRILL DRLG P 7910', BOBD 1.41 bpm at 3945psi, BHP 4263,WHP 62, IA 45, OA 2 22:21 23:21 1.00 8,110 7,100 PROD1 DRILL WPRT P 8110',Wiper up hole 7100', PUW 28k 23:21 00:00 0.65 7,100 8,148 PROD1 DRILL DRLG P 8110', BOBD 1.45bpm at 3950 psi, BHP 4236,WHP 92, IA 46,OA 0 10/12/2014 Drilled the L1 lateral 8148'to 8230'out of targets. Decide to POOH for anchored aluminum billet, undeployed drilling BHA, M/U,deployed, RIH,and set TOWS at 7250', M/U and deploy L1 lateral BHA#12, 00:00 01:18 1.30 8,148 8,230 PROD1 DRILL DRLG P 8148', OBD 1.45 bpm at 3950 psi, BHP 4246,WHP 90, IA 45, OA 0 """"Note turned up to 111°inc to cross cut for data 01:18 02:18 1.00 8,230 6,770 PROD1 DRILL WPRT T Done cross cutting for data, POOH for billet, pump 5x5 sweep,pulling 5k heavy through build section, PUH to bottom of WS 6770' 02:18 02:45 0.45 6,770 7,125 PROD1 DRILL WPRT T RBIH to 7125'to clean hole. Page 6 of 19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:45 03:03 0.30 7,125 6,780 PROD1 DRILL WPRT T PUH to 6780',still pulling 4k over 03:03 03:21 0.30 6,780 7,000 PROD1 DRILL WPRT T RBIH to 7000', POOH at 35fpm,TF 180°, 03:21 03:39 0.30 7,000 6,740 PROD1 DRILL WPRT T POOH,at 35 fpm,TF180° 03:39 05:09 1.50 6,740 6,772 PROD1 DRILL TRIP T POOH, lost pump,trouble getting charge pressure to the pump,slowly RIH,trouble shooting 05:09 06:09 1.00 6,772 50 PROD1 DRILL TRIP T Get pump going-continue out of well 06:09 08:21 2.20 50 0 PROD1 DRILL PULD T PJSM, PUD BHA#10 08:21 09:51 1.50 0 74 PROD1 STK PULD T PJSM, PD BHA#11,Anchored Aluminum Billet, M/U to coil track and surface test 09:51 11:21 1.50 74 6,338 PROD1 STK TRIP T RIH EDC open 11:21 11:33 0.20 6,338 6,353 PROD1 STK DLOG T Log K1 for-6.5' 11:33 12:21 0.80 6,353 7,263 PROD1 STK TRIP T Continue trip in,stop at 7262, Shut EDC, clean pass through window 12:21 12:27 0.10 7,263 7,264 PROD1 STK WPST T 7262.68'@ 330°set OH anchored billet, See tool shift @ 4200 PSI, Set down 2K 12:27 14:21 1.90 7,264 50 PROD1 STK TRIP T Trip out after setting billet 14:21 15:51 1.50 50 0 PROD1 STK PULD T At surface, PJSM, PUD BHA#11, Anchored billet setting tools 15:51 16:27 0.60 0 0 PROD1 DRILL BOPE P Run bore scope through BOPE,try to identify where rubber came from, Perform Bi Weekly BOPE function test 16:27 18:27 2.00 0 72 PROD1 STK PULD T PJSM, PD BHA#12 with.5°motor and rebuilt hycalog 18:27 19:42 1.25 72 6,335 PROD1 STK TRIP T RIH,with EDC, DPS, DGS, USR, HOT, and RB Hycalog bi-center bit Dura-Force. 19:42 19:57 0.25 6,335 6,348 PROD1 STK DLOG T Tie into the K1 correction of minus 7', PUW 25 19:57 20:27 0.50 6,348 7,250 PROD1 STK TRIP T Continue RIHTB 20:27 20:42 0.25 7,250 7,250 PROD1 STK TRIP T Tag TOB at 7251', PUW 26k, bring pump on 20:42 22:42 2.00 7,250 7,279 PROD1 STK KOST T 7250', pumping 1.48 bpm at 3855psi, BHP 4155,WHP 56, IA 30, OA 0, Start time milling off of billet as per procedure. 22:42 22:57 0.25 7,279 7,279 PROD1 DRILL WPRT T 7279',wiper up hole through kick off area to 7240', clean, RBIH through area clean,continue drilling ahead. _ 22:57 00:00 1.05 7,279 7,327 PROD1 DRILL DRLG T OBD, 1.5 bpm at 3900psi, BHP 4172,WHP 68, IA 37,OA 0 10/13/2014 RIH, kicked off billet at 7250', redrilled L1 lateral in target from 7250'to 8354'. 00:00 02:15 2.25 7,327 7,460 PROD1 DRILL DRLG T OBD, 1.5bpm at 3850psi, BHP 4228, _ WHP 106, IA 40, OA 0 7,460 7,460 PROD1 DRILL WPRT T 7460',Wiper up hole to 6775', PUW 24k 02:15 05:45 3.50 7,460 7,660 PROD1 DRILL DRLG T 7460', BOBD 1.5 bpm at 3840 psi, BHP 4112,WHP 95, IA 43, OA 0 Page 7 of 19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:45 06:45 1.00 7,660 7,660 PROD1 DRILL WPRT T 7660,Wiper to 6780, PUW=26K, Set down on Billet.7256 Went right at 40 FPM 06:45 10:45 4.00 7,660 7,860 PROD1 DRILL DRLG T 7660', Drill, 1.45 BPM @ 3750 PSI FS, BHP=4178, MUD SWAP, new mud @ bit @ 7763 10:45 12:15 1.50 7,860 7,860 PROD1 DRILL WPRT T Wiper to window with tie in for+1.5', PUW=28K. Clean through billet area up and down 12:15 15:27 3.20 7,860 8,060 PROD1 DRILL DRLG T 7860' Drill, 1.4 BPM @ 3970 PSI FS, _ BHP=4249 15:27 16:15 0.80 8,060 8,060 PROD1 DRILL WPRT T 8060',Wiper to 7270, PUW=26K 16:15 16:51 0.60 8,060 8,090 PROD1 DRILL DRLG T 8060',drill ahead, 1.41 BPM @ 3900 PSI FS, BHP=4221 16:51 18:51 2.00 8,090 6,314 PROD1 DRILL WPRT T Retirement Wiper to cased hole 6314', PUW=26K 18:51 19:21 0.50 6,314 6,335 PROD1 DRILL WPRT T 6314',Wiper back in hole. 19:21 19:39 0.30 6,335 6,352 PROD1 DRILL DLOG T Tie into the K1 marker no correction. 19:39 21:27 1.80 8,090 8,230 PROD1 DRILL DRLG T 8090', BOBD 1.41 bpm at 3940 psi, BHP 4290,WHP 57, IA 43, OA 0 21:27 22:15 0.80 8,230 8,290 PROD1 DRILL DRLG P 8230', OBD, 1.9k WOB holding 90.5° at 80 fph 22:15 23:15 1.00 8,290 8,290 PROD1 DRILL WPRT P Wiper up hole to 7290', PUW 25k, RIW 23:15 00:00 0.75 8,290 8,354 PROD1 DRILL DRLG P 8290', BOBD 1.5 bpm at 3940 psi, BHP 4224,WHP 16, IA 45, OA 1 10/14/2014 Drill ahead L1 lateral from 8,354'to 9,364',drilling in progress. 00:00 01:45 1.75 8,354 8,490 PROD1 DRILL DRLG P OBD, 1.41 bpm at 3350 psi, BHP 4278,WHP 20, IA 47, OA 2 01:45 02:45 1.00 8,490 8,490 PROD1 DRILL WPRT P 8490',Wiper up hole to 7500', PUW 26k RIW 11k 02:45 05:27 2.70 8,490 8,690 PROD1 DRILL DRLG P 8490', BOBD 1.40 bpm at 3959 psi, BHP 4300,WHP 33, IA 48, OA 2 05:27 07:21 1.90 8,690 8,690 PROD1 DRILL WPRT P Wiper trip to window with tie in, PUW=26, Correction©RA=+2.5 07:21 10:45 3.40 8,690 8,890 PROD1 DRILL DRLG P 8690', Drill, 1.41 BPM @ 4030 PSI FS, BHP=4315 10:45 11:15 0.50 8,890 8,890 PROD1 DRILL WPRT P Wiper trip to 8000', PUW=25K 11:15 15:57 4.70 8,890 9,090 PROD1 DRILL DRLG P 8890, Drill, 1.4 BPM @ 3930 PSI FS, BHP=4376 15:57 16:57 1.00 9,090 9,090 PROD1 DRILL WPRT P Wiper trip to 8100, PUW=26K 16:57 20:33 3.60 9,090 9,290 PROD1 DRILL DRLG P 9090 Drill, 1.39 BPM @ 4020 PSI FS, BHP=4404 _ 20:33 23:03 2.50 9,290 9,290 PROD1 DRILL WPRT P Wiper trip for tie-in, PUW=25K,tie-in at RA tag for+1'correction, RBIH @ 21:55. 23:03 00:00 0.95 9,290 9,364 PROD1 DRILL DRLG P Drill ahead: 1.36 BPM @ 3,975 PSI, BHP=4455 PSI, CTW=6.5K, WOB=1.6K, ROP=80. Start pumping new mud system. 10/15/2014 Drill ahead L1 lateral to called TD @ 10,100'. Chase sweeps to swab. RBIH for corrected TD depth, in progress. Page 8 of 19 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 00:00 01:45 1.75 9,364 9,490 PROD1 DRILL DRLG P Drill ahead: 1.43 BPM @ 4,005 PSI, BHP=4380 PSI,CTW=5.8K, WOB=2K, ROP=90. New mud around @ 9,416'. 01:45 02:45 1.00 9,490 9,490 PROD1 DRILL WPRT P Wiper to 8,000', PUW=26K, RBIH @ 02:20. 02:45 06:21 3.60 9,490 9,690 PROD1 DRILL DRLG P BOBD: 1.49 BPM @ 4,040 PSI, BHP=4330 PSI, CTW=7.2K, WOB=1.8K, ROP=65. 06:21 07:21 1.00 9,690 9,690 PROD1 DRILL WPRT P 9690,Wiper to 8740', PUW=24K 07:21 10:39 3.30 9,690 9,890 PROD1 DRILL DRLG P 9690', Drill ahead, 1.43 BPM ©3933 PSI FS, BHP=4403, RIW=5.7, DHWOB=1.7k 10:39 13:39 3.00 9,890 9,890 PROD1 DRILL WPRT P Wiper trip to window with tie in, PUW=24K, RA Tie in for+2.5, Clean trip up and down 13:39 17:33 3.90 9,890 10,100 PROD1 DRILL DRLG P 9890, Drilling, 1.44 BPM @ 3950 PSI FS, BHP=4394, RIW=7K, DHWOB=1.5K called TD @ 10,100'. Pump 10/10 sweeps. 17:33 20:48 3.25 10,100 72 PROD1 DRILL WPRT P Chase sweeps to swab 20:48 21:33 0.75 72 6,315 PROD1 DRILL TRIP P RBIH for corrected TD, tie-in to K1 for -7'correction. 21:33 22:33 1.00 6,315 6,315 PROD1 DRILL TRIP T Troubleshoot reel surging issues, troubleshoot encoder, issues resolved. Note: 1 hour non-billable 22:33 00:00 1.45 6,315 8,467 PROD1 DRILL TRIP P Continue in hole for corrected TD. 10/16/2014 Run L1 lateral liner in two segments from 7,132'to 10,100'. POOH LD BHA#14, in progress. 00:00 01:24 1.40 8,467 10,100 PROD1 DRILL TRIP P Continue in hole for corrected TD,tag TD @ 10,100'. 01:24 04:12 2.80 10,100 72 PROD1 DRILL DISP P POOH laying in beaded liner pill/completion fluid. Paint EOP flags @ 8,100'&4,800'. Continue OOH. 04:12 04:42 0.50 72 72 PROD1 DRILL OWFF P At surface,perform flow check. 04:42 05:30 0.80 72 0 PROD1 DRILL PULD P PJSM. LD BHA#12 05:30 06:12 0.70 0 0 COMPZ CASING PUTB P Prep floor for tubing P/U, Crew change, 06:12 09:30 3.30 0 1,854 COMPZ CASING PUTB P PJSM. PU/MU lower liner assembly, Non Ported bullnose, 57 Jts slotted 2 3/8"liner,shorty deployment sleeve, M/U to coil track,surface test 09:30 10:48 1.30 1,854 6,553 COMPZ CASING TRIP P Trip in hole, EDC closed 10:48 10:54 0.10 6,553 6,553 COMPZ CASING DLOG P Tie into 4800'EOP flag for-9.9, PUW =29K, Looking back correction was on but should be 6453', Explains why we missed K1 10:54 11:30 0.60 6,553 8,119 COMPZ CASING TRIP P Continue trip in hole 11:30 11:48 0.30 8,119 8,166 COMPZ CASING DLOG P Log K1, Missed it RIH Page 9 of 19 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:48 13:00 1.20 8,166 10,000 COMPZ CASING TRIP P Continue in with liner,set down looks like bottom, Numbers work out with CTES EOP counter. Release from liner, PUH to 8100'EOP flag and correct to 9954, + 101',putting liner @ 10,100' 13:00 13:42 0.70 10,000 8,510 COMPZ CASING TRIP P Above window @ 8510, Remove liner left in hole, 1810'to 6700.17, Continue up hole to tie into K1 13:42 13:54 0.20 8,510 6,303 COMPZ CASING TRIP P Continue up hole to K1 13:54 14:00 0.10 6,303 6,324 COMPZ CASING DLOG P Log K1,for+1.5, TOL lower segment=8289 14:00 15:30 1.50 6,324 48 COMPZ CASING TRIP P Continue out of well, Paint EOP flag 5400' 15:30 16:00 0.50 48 48 COMPZ CASING SFTY P Flow check, PJSM Lay down liner running tools 16:00 16:30 0.50 48 0 COMPZ CASING PULD P Lay down BHA#13 Liner running tools 16:30 17:00 0.50 0 0 COMPZ CASING SVRG P R/U floor for liner ops, Inspect- service top drive. Inspect liner running equipment 17:00 18:57 1.95 0 1,150 COMPZ CASING PUTB P PJSM, P/U L1 Liner upper section 18:57 19:45 0.80 1,150 1,210 COMPZ CASING PULD P PJSM. MU BHA#14 19:45 21:57 2.20 1,210 8,290 COMPZ CASING RUNL P TIH w/upper liner segment,tie-in to EOP flag for-1.5'correction, continue hole to liner set depth, weight check above window 26K. Release from liner,TOL depth @ 7,132'. 21:57 23:09 1.20 8,290 55 COMPZ CASING TRIP P Reset depth. POOH for drilling assembly. 23:09 23:39 0.50 55 55 COMPZ CASING OWFF P At surface,flow check, PJSM. 23:39 00:00 0.35 55 0 COMPZ CASING PULD P LD BHA#14 10/17/2014 TIH w/kick-off drilling assembly,tag billet @ 7,128'.Swap hole back to drilling mud. Kick-off billet as per well plan,dry drift billet, billet clean. Drill ahead L1-01 lateral to 7,909',drilling in progress. 00:00 01:15 1.25 0 73 PROD2 STK PULD P Finish LD Of BHA#14. Check pack-off and UQC checks. PJSM. MU BHA#15. 01:15 03:15 2.00 73 6,550 PROD2 STK TRIP P TIH w/kick-off drilling assembly, tie-in to K1 for-5.5'correction, continue in hole. 03:15 03:45 0.50 6,550 6,550 PROD2 STK CIRC P Circulate hole back to drilling mud. 03:45 04:30 0.75 6,550 7,128 PROD2 STK TRIP P TIH to TOL depth @ 7,128' 04:30 06:54 2.40 7,128 7,131 PROD2 STK KOST P Start time milling off billet as per well plan: 1,2, and 3 fph, Stall @ 7128.8 06:54 08:06 1.20 7,131 7,175 PROD2 DRILL DRLG P 7131 Drill, 1.39 BPM @ 3700 PSI FS, BHP=4160 08:06 08:12 0.10 7,175 7,175 PROD2 DRILL WPRT P 7175, PUH to drift billet area, PUW=26K.All clean up and down 08:12 11:42 3.50 7,175 7,360 PROD2 DRILL DRLG P 7175', Drill, 1.44 BPM @ 3930 PSI FS, BHP=4212, RIW=11.5K 11:42 12:24 0.70 7,360 7,360 PROD2 DRILL WPRT P 7360',Wipe trip 6780', PUW=27K, Clean trip up and down Page 10 of 19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:24 15:12 2.80 7,360 7,560 PROD2 DRILL DRLG P 7360'Drill, 1.43 BPM @ 3920 PSI FS, BHP=4215 15:12 16:00 0.80 7,560 7,560 PROD2 DRILL WPRT P 7560',Wiper to 6785, PUW=27K 16:00 19:54 3.90 7,560 7,760 PROD2 DRILL DRLG P Drill ahead: 1.44 BPM @ 4080 PSI, BHP=4240 PSI, CTW=9.5K, WOB=2K, ROP=50 19:54 21:00 1.10 7,760 7,760 PROD2 DRILL WPRT P Wiper trip for tie-in,PUW=26K,tie-in at RA for-1'correction, RBIH. 21:00 00:00 3.00 7,760 7,909 PROD2 DRILL DRLG P Drill ahead: 1.44 BPM @ 4120 PSI, BHP=4260 PSI, CTW=10K, WOB=1.5K, ROP=50. Slower going encountering several ankerite stringers. 10/18/2014 Drill ahead L1-01 lateral from 7,909'to 8,960',drilling in progress. 00:00 02:09 2.15 7,909 7,960 PROD2 DRILL DRLG P Drill ahead: 1.44 BPM @ 4120 PSI, BHP=4260 PSI, CTW=10K, WOB=1.5K, ROP=20.Still battling ankerite. 02:09 03:18 1.15 7,960 7,960 PROD2 DRILL WPRT P Wiper to window, PUW=26.5K, RBIH. 03:18 07:18 4.00 7,960 8,160 PROD2 DRILL DRLG P Drill ahead: 1.41 BPM @ 4115 PSI, BHP=4260 PSI, CTW=11 K, WOB=1.4K, ROP=85. NEW MUD @ Bit 8020, System 3 1685', .8%Drill solids 07:18 08:30 1.20 8,160 8,160 PROD2 DRILL WPRT P Wiper to 7180', PUW=25K 08:30 11:18 2.80 8,160 8,360 PROD2 DRILL DRLG P 8160', Drill, 1.45 BPM @ 3936 PSI FS, BHP=4216, RIW=9.6K 11:18 12:06 0.80 8,360 6,775 PROD2 DRILL WPRT P 8360',Wiper to window with tie in. PUW=25K 12:06 12:18 0.20 6,775 6,799 PROD2 DRILL DLOG P Log RA marker for+.5'correction 12:18 12:54 0.60 6,799 8,619 PROD2 DRILL WPRT P RBIH to drill 12:54 13:54 1.00 8,619 8,163 PROD2 DRILL WPRT T CT storage reel out of sync.Trouble shoot injector and reel encoder, Tighten loose injector encoder solve problem 13:54 14:30 0.60 8,163 8,360 PROD2 DRILL WPRT P Continue in hole to drill 14:30 16:42 2.20 8,360 8,560 PROD2 DRILL DRLG P 8360', Drill 1.43 BPM @ 3926 PSI FS, BHP=4293, RIW=8K 16:42 17:27 0.75 8,560 8,560 PROD2 DRILL WPRT P Wiper trip to 7560, PUW=26K, RBIH. 17:27 19:27 2.00 8,560 8,760 PROD2 DRILL DRLG P Drill ahead: 1.43 BPM @ 4,210 PSI, BHP=4,315 PSI, CTW=8.4K, WOB-1.5K, ROP=100 19:27 20:36 1.15 8,760 8,760 PROD2 DRILL WPRT P Wiper to window, PUW=26K, RBIH. 20:36 23:30 2.90 8,760 8,960 PROD2 DRILL DRLG P Drill ahead: 1.43 BPM @ 4,150 PSI, BHP=4,365 PSI, CTW=9K, WOB-1.4K, ROP=70 23:30 00:00 0.50 8,960 8,960 PROD2 DRILL WPRT P Start wiper trip for tie-in, PUW=23K. 10/19/2014 Drill ahead L1-01 lateral from 8,960'to 9,950',drilling in progress. 00:00 01:42 ` 1.70 8,960 8,960 PROD2 DRILL WPRT P Continue wiper for tie-in,tie-in for-2' correction, RBIH @ 01:20. Page 11 of 19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:42 05:00 3.30 8,960 9,160 PROD2 DRILL DRLG P Drill ahead: 1.43 BPM @ 4,250 PSI, BHP=4,370 PSI, CTW=7.2K, WOB-2.2K, ROP=65 05:00 06:12 1.20 9,160 9,160 PROD2 DRILL WPRT P Wiper trip to 7960, PUW=26K 06:12 07:54 1.70 9,160 9,360 PROD2 DRILL DRLG P 9160 Drill, 1.42 BPM @ 3988 PSI FS, BHP=4333, RIW=8.7K, DHWOB=1.3K 07:54 08:36 0.70 9,360 9,360 PROD2 DRILL WPRT P Wiper to 8560, PUW=26K 08:36 13:00 4.40 9,360 9,560 PROD2 DRILL DRLG P 9360 Drill, 1.4 BPM @ 3960 PSI FS, BHP=4378, RIW=9.3K, 13:00 14:18 1.30 9,560 6,775 PROD2 DRILL WPRT P 9560 Wiper to window with tie in, PUW=24K, Pumped 5 X 5 sweepd 14:18 14:30 0.20 6,775 6,799 PROD2 DRILL DLOG P Log RA marker for+2.5'correction 14:30 15:42 1.20 6,799 9,560 PROD2 DRILL WPRT P continue wiper back in hole to drill, RIW=10K 15:42 20:27 4.75 9,560 9,760 PROD2 DRILL DRLG P 9560', Drill, 1.4 BPM @ 3990 PSI FS, BHP=4349, NEW MUD @ Bit 9600' 20:27 21:39 1.20 9,760 9,760 PROD2 DRILL WPRT P Wiper to window, PUW=24K, RBIH. 21:39 00:00 2.35 9,760 9,950 PROD2 DRILL DRLG P Drill ahead: 1.42 BPM @ 4,090 PSI, BHP=4,450 PSI, CTW=6K, WOB-1.3K, ROP=65 10/20/2014 Drill ahead L1-01 lateral to called TD @ 10,100', pumped sweeps and chase to swab. RBIH for corrected TD @ 10,100'. POOH laying in liner pill/completion fluid. Flow check, LD BHA#15. Prep for BOP test, start bi-weekly BOP test, in progress. 00:00 00:15 0.25 9,950 9,960 PROD2 DRILL DRLG P Drill ahead: 1.42 BPM @ 4,090 PSI, BHP=4,450 PSI, CTW=6K, WOB-1.3K, ROP=65 00:15 01:36 1.35 9,960 9,960 PROD2 DRILL WPRT P Wiper trip to window, PUW=24K, RBIH. 01:36 03:15 1.65 9,960 10,100 PROD2 DRILL DRLG P Drill ahead to TD: 1.41 BPM @ 4,115 PSI, BHP=4,445 PSI, CTW=6K, WOB-1.3K, ROP=90. Pumped 10 bbl to/hi vis sweeps. 03:15 06:27 3.20 10,100 63 PROD2 DRILL TRIP P Chase sweeps to swab 06:27 07:27 1.00 63 6,332 PROD2 DRILL TRIP P Tag up at surface, Reset counters, RIH 07:27 09:51 2.40 6,332 6,352 PROD2 DRILL DLOG P Log gamma tie in at K1 for+4.5' correction 09:51 10:21 0.50 6,352 10,100 PROD2 DRILL TRIP P continue in hole,confirm TD @ 10,100',pump beaded liner pill 10:21 13:15 2.90 10,100 71 PROD2 DRILL TRIP P POOH pumping 12.0PPG beaded liner running pill followed by 12.0PPG completion fluid, Paint EOP flags @ 9100&4800'EOP 13:15 13:45 0.50 71 71 PROD2 DRILL PULD P At surface,perform 30 min no flo, PJSM to lay down tools on dead well, 13:45 14:30 0.75 71 71 PROD2 DRILL PULD T Unable to move top drive,severe derrick ice. Mechanical anti crown frozen. Get Top drive to work, Lower to floor and de ice 14:30 16:00 1.50 71 0 PROD2 DRILL PULD P Lay down BHA#15 Page 12 of 19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 17:30 1.50 0 0 PROD2 DRILL CTOP P Install nozzel,jet stack, Grease crew here to service tree 17:30 00:00 6.50 0 0 PROD2 WHDBO BOPE P Start bi-weekly BOP test 250/3500 psi,annular 2500 psi.Test waived by Bob Noble(AOGCC). 10/21/2014 Finished BOPE test. Prep floor to run liner segments, MU and RIH with lower liner assembly, release from liner @ 10,100'. POOH for upper liner, MU and RIH with upper liner segment to 4,863'. 00:00 02:00 2.00 0 0 PROD2 WHDBO BOPE P Complete bi-weekly BOP test 250/3500 psi,annular 2500 psi.Test waived by Bob Noble(AOGCC). 02:00 05:30 3.50 0 0 PROD2 WHDBO BOPE P Upper pipe rams failed, replace pipe rams, load stack and retest. Complete BOPE Test 5:30 05:30 08:00 2.50 0 0 PROD2 DRILL OTHR T Remove Ice from Derrick/Traveling equipment 08:00 11:15 3.25 0 1,847 COMPZ CASING PUTB P PJSM, Rig up floor to run L1-01 Lower liner segment with non ported bullnose,58 Jts slotted liner, Shorty deployment sleeve. 11:15 12:06 0.85 1,847 1,891 COMPZ CASING PULD P MU BHA#16 to coil track, surface test. 12:06 13:15 1.15 1,891 6,691 COMPZ CASING RUNL P TIH with EDC closed. 13:15 13:21 0.10 6,691 6,691 COMPZ CASING DLOG P Tie into 4800'EOP flag for-7.4', PUW=28K. 13:21 15:06 1.75 6,691 10,100 COMPZ CASING RUNL P Continue TIH with L1-01 lower liner segment,weight getiing erratic at 7,382',sat down at 8,145',work liner at 10 to 20 fpm,-2 to 6k CWT to 9,045', BHA past billet, no problems to 10,100', RIW 8k, 1.25 bpm release off liner, PUW 26k, correct to BHA depth. 15:06 16:03 0.95 10,100 6,300 COMPZ CASING TRIP P TOOH with BHA#16. 16:03 16:12 0.15 6,300 6,350 COMPZ CASING DLOG P Log K1 marker, +6'correction 16:12 16:57 0.75 6,350 44 COMPZ CASING TRIP P TOOH, paint EOP flag at 5,300'. 16:57 17:39 0.70 44 44 COMPZ CASING OWFF P At surface,flow check, PJSM. 17:39 18:48 1.15 44 0 COMPZ CASING PULD P PJSM. LD BHA#16 18:48 19:00 0.20 0 65 COMPZ CASING PUTB P PJSM. Start MU upper liner segment 19:00 20:00 1.00 65 66 COMPZ CASING PUTB T Large chuck of ice fell from derrick. Clear ice from derrick before continuing. 20:00 22:30 2.50 66 1,810 COMPZ CASING PUTB P Continue MU of upper liner segment: Bull nose,41 jts slotted,two solid pups, and billet. 22:30 23:12 0.70 1,810 1,855 COMPZ CASING PULD P PJSM. PU/MU BHA#17 23:12 00:00 0.80 1,855 4,863 COMPZ CASING RUNL P RIH w/Upper liner segment 10/22/2014 Run upper liner segment to 8,253', release from liner. POOH and LD BHA#17. MU BHA#18, RIH w/drilling assembly,swap hole to mud, drill build/turn section to TD @ 7,080'. POOH and PUD BHA#18. Page 13 of 19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:30 1.50 4,863 8,253 COMPZ CASING RUNL P Continue in hole with upper liner segment,tie-in to EOP flag for-6' correction,weight above window 27K,tag lower liner @ 8,253', PUW=32K, had to work pipe down, two attempts before releasing from liner, PUW=23K. 01:30 03:00 1.50 8,253 61 COMPZ CASING TRIP P Reset depth counter. POOH for drilling assembly. 03:00 03:30 0.50 61 61 COMPZ CASING OWFF P At surface,flow check, no flow. 03:30 04:00 0.50 61 0 COMPZ CASING PULD P PJSM. LD BHA#17 04:00 05:06 1.10 0 72 PROD3 STK PULD P PJSM. MU BHA#18, kick-off drilling assembly 05:06 06:27 1.35 72 6,400 PROD3 STK TRIP P TIH w/kick-off drilling assembly, tie-in to K1 for-6.5'correction, continue in hole. 06:27 07:27 1.00 6,400 6,400 PROD3 STK CIRC P Circulate hole back to drilling mud. 07:27 08:18 0.85 6,400 6,916 PROD3 STK TRIP P TIH to TOL depth @ 6,916' 08:18 11:18 3.00 6,916 6,919 PROD3 STK KOST P 6,916', Start time milling off billet as per well plan: 1,2 and 3 fph.stall at 6,916.51' 11:18 13:06 1.80 6,919 6,960 PROD3 DRILL DRLG P 6,919', Drill, 1.40 bpm @ 3775 psi, BHP 4104, 10 and 20 fph 13:06 13:15 0.15 6,960 6,960 PROD3 DRILL WPRT P 6,960', PUH to drift billet area, PUW 25k.All clean up and down. 13:15 16:42 3.45 6,960 7,080 PROD3 DRILL DRLG P 6,960', BOBD 139 bpm at 3857 psi, BHP 4141,CWT 11.4k,WOB 1.5k, ROP 36 16:42 18:27 1.75 7,080 72 PROD3 DRILL TRIP P 7,080', TD build section, TOOH for lateral drilling assembly, PUW 24k. 18:27 20:57 2.50 72 0 PROD3 DRILL PULD P At surface. PJSM. PUD BHA#18 20:57 22:57 2.00 0 0 PROD3 DRILL PULD T Had to switch loaded PDL,due to ice build-up on PDL crown. Send crew member up to de-ice derrick. 22:57 00:00 1.05 0 73 PROD3 DRILL PULD P Finish MU BHA. PJSM. PD BHA#19 10/23/2014 Drill ahead L1-02 lateral from 7,080'to M80',drilling in progress. 00:00 00:09 0.15 73 73 PROD3 DRILL PULD P Finish PD of BHA#19. Change pack-offs. 00:09 02:00 1.85 73 7,080 PROD3 DRILL TRIP P RIH w/lateral drilling assembly,tie-in for-6.5'correction,continue in hole. 02:00 04:18 2.30 7,080 7,280 PROD3 DRILL DRLG P Drill ahead: 1.43 BPM @ 4,025 PSI, BHP=4,210 PSI, CTW=11.5K, WOB=1.4K, ROP=85. 04:18 05:00 0.70 7,280 7,280 PROD3 DRILL WPRT P Wiper to window, PUW=23K, RBIH. 05:00 07:06 2.10 7,280 7,480 PROD3 DRILL DRLG P Drill ahead: 1.43 BPM @ 4,063 PSI, BHP=4,205 PSI, CTW=10.5K, WOB=1.6K, ROP=95. 07:06 08:00 0.90 7,480 7,480 PROD3 DRILL WPRT P Wiper to window, PUW=24K, RBIH. 08:00 09:42 1.70 7,480 7,680 PROD3 DRILL DRLG P 7,480', BOBD 1.43 bpm at 4059 psi, BHP 4210 psi, CWT 10.4k,WOB 1.9k, ROP 115. Page 14 of 19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:42 10:12 0.50 7,680 6,820 PROD3 DRILL WPRT P Wiper trip for tie in, PUW 27k.• 10:12 10:24 0.20 6,820 6,790 PROD3 DRILL DLOG P Log RA markers,+1.5'correction. 10:24 10:51 0.45 6,790 7,680 PROD3 DRILL WPRT P Wiper back in hole. 10:51 12:33 1.70 7,680 7,880 PROD3 DRILL DRLG P 7,680', BOBD 1.40 bpm at 4019 psi, BHP 4207 psi, CWT 10.4k,WOB 1.6k, ROP 145. 12:33 13:24 0.85 7,880 7,880 PROD3 DRILL WPRT P Wiper up hole, PUW 27k,at 7,030' wiper in hole. 13:24 15:45 2.35 7,880 8,080 PROD3 DRILL DRLG P 7,880', BOBD 1.43 bpm at 4070 psi, BHP 4262 psi, CWT 10.2k,WOB 1.9k, ROP 85. Note:begin mud swap,at 8,017'new 9.8 ppg mud at bit. 15:45 16:39 0.90 8,080 8,080 PROD3 DRILL WPRT P Wiper up hole, PUW 25k,at 7,230' wiper in hole. 16:39 18:39 2.00 8,080 8,280 PROD3 DRILL DRLG P 8,080', BOBD 1.47 bpm at 4090 psi, BHP 4281 psi, CWT 10.6k,WOB 1.9k, ROP 100. 18:39 19:45 1.10 8,280 8,280 PROD3 DRILL DLOG P Wiper for tie-in, PUW=23K,tie-in-1' correction, RBIH. 19:45 23:06 3.35 8,280 8,480 PROD3 DRILL DRLG P Drill ahead: 1.45 BPM @ 4020 PSI, BHP=4280 PSI, CTW=10K, WOB=1.4K, ROP=60. 23:06 00:00 0.90 8,480 8,480 PROD3 DRILL WPRT P Wiper to window, PUW=25K. 10/24/2014 Drill L1-02 lateral to called TD @ 8,740', pump 10 bbl sweeps, chase to swab. RBIH for corrected TD @ 8,740'. POOH laying in liner pill/completion fluid. LD BHA#19. MU liner assembly, RIH w/L1-02 liner assembly to 7,224'. 00:00 00:30 0.50 8,480 8,480 PROD3 DRILL WPRT P Continue wiper trip 00:30 05:00 4.50 8,480 8,680 PROD3 DRILL DRLG P Drill ahead: 1.45 BPM @ 3975 PSI, BHP=4310 PSI, CTW=10K, WOB=1K, ROP=45. 05:00 06:06 1.10 8,680 8,680 PROD3 DRILL WPRT P Wiper to 7,480', PUW=24K, RBIH. 06:06 07:24 1.30 8,680 8,740 PROD3 DRILL DRLG P 8,680', BOBD 1.43 bpm at 3940 psi, BHP 4300 psi, CWT 10k,WOB 1.7k, ROP 55. Pumped 10 bbl to/hi vis sweeps. 07:24 10:06 2.70 8,740 63 PROD3 DRILL WPRT P 8,740', TD reached,chase sweep to swab, PUW 25k 10:06 11:12 1.10 73 6,320 PROD3 DRILL TRIP P Tag up at surface,reset counters, TIH 11:12 11:21 0.15 6,320 6,355 PROD3 DRILL DLOG P Log K1 marker for-7.5'correction 11:21 12:30 1.15 6,355 8,740 PROD3 DRILL TRIP P Continue in hole, sat down 5k at TOW, PU and pass through clean, confirm TD @ 8,740.7',pump beaded liner pill. 12:30 15:36 3.10 8,740 74 PROD3 DRILL DISP P POOH pumping 12 ppg beaded liner running pill followed by 12 ppg completion fluid, Paint EOP flags @ 7,000'&5,000'EOP. 15:36 16:06 0.50 74 74 PROD3 DRILL OWFF P At surface,monitor well for flow, PJSM to lay down tools on dead well. Page 15 of 19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:06 17:00 0.90 74 0 PROD3 DRILL PULD P LD BHA#19 17:00 21:00 4.00 0 1,599 COMPZ CASING PUTB P PJSM, Rig up floor to run L1-02 Liner assembly with non ported bullnose, 50 Jts slotted liner, liner top billet. 21:00 22:09 1.15 1,599 1,643 COMPZ CASING PULD P PJSM. Injector maintenance. MU BHA#20 22:09 00:00 1.85 1,643 7,224 COMPZ CASING RUNL P RIH w/L1-02 liner assembly,tie-in to EOP flag for-8.5'correction,weight check above window 28K, continue in hole. 10/25/2014 Run L1-02 liner assembly to 8,740'. Kick-off billet @ 7,141',dry drift clean. Drill ahead L1-03 lateral from 7,180'to 7,580',drilling in progress. 00:00 01:00 1.00 7,224 8,741 COMPZ CASING RUNL P Continue in hole,tag bottom 8,740', PUW=32K. RBIH,set down 8,741', release from liner, PUW=26K. 01:00 02:30 1.50 8,741 72 COMPZ CASING TRIP P POOH for drilling assembly 02:30 03:00 0.50 72 72 COMPZ CASING OWFF P At surface,no flow check. 03:00 03:30 0.50 72 0 COMPZ CASING PULD P PJSM. LD BHA#20 03:30 04:12 0.70 0 73 PROD4 STK PULD P PJSM. MU BHA#21 Kick-off drilling assembly 04:12 05:42 1.50 73 6,330 PROD4 STK TRIP P RIH w/drilling assembly. 05:42 05:54 0.20 6,330 6,360 PROD4 STK DLOG P Log K1 marker for-6.5'correction. 05:54 06:27 0.55 6,360 7,125 PROD4 STK TRIP P Continue in hole, begin circulating hole back to drilling mud 06:27 07:54 1.45 7,125 7,141 PROD4 STK CIRC P Circulate hole back to drilling mud, Tag TOL at 7,141' 07:54 11:24 3.50 7,141 7,146 PROD4 STK KOST P 7,141', Start time milling off billet as per well plan: 1,2 and 3 fph. _ _ 11:24 12:06 0.70 7,146 7,180 PROD4 DRILL DRLG P 7,145', Drill, 1.42 bpm @ 3985 psi, BHP 4215, 10 and 20 fph 12:06 12:15 0.15 7,180 7,180 PROD4 DRILL WPRT P 7,180', PUH to drift billet area, PUW 24k.All clean up and down. 12:15 19:51 7.60 7,180 7,380 PROD4 DRILL DRLG P 7,180', BOBD 1.42 bpm at 3985 psi, BHP 4228 psi, CWT 11k,WOB 1.9k, ROP=25,found several ankerite stringers. 19:51 20:45 0.90 7,380 7,380 PROD4 DRILL WPRT P Wiper to window, PUW=27K, RBIH. 20:45 23:30 2.75 7,380 7,580 PROD4 DRILL DRLG P Drill ahead: 1.40 BPM @ 3,920 PSI, BHP=4,225 PSI, CTW=9.6K. WOB=1.9K, ROP=70. 23:30 00:00 0.50 7,580 7,180 PROD4 DRILL WPRT P Start wiper to window, PUW=25K. 10/26/2014 Drill ahead L1-03 lateral 7,580'to 7,793', unable to make hole, swap to new mud system, no progress. POOH to check BHA, PUD BHA#21,PD BHA#22. RIH drilling assembly with new bit. Drill ahead 7,793'to 7,925', drilling in progress. 00:00 00:15 0.25 7,180 7,580 PROD4 DRILL WPRT P Finish wiper from window 00:15 04:36 4.35 7,580 7,780 PROD4 DRILL DRLG P Drill ahead: 1.39 BPM @ 3,970 PSI, BHP=4,260 PSI, CTW=9.7K. WOB=1.85K, ROP=45. Page 16 of 19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:36 06:09 1.55 7,780 7,780 PROD4 DRILL WPRT P Pumped to/hi vis sweeps,wiper trip for tie-in, PUW=25K, +1.5' _ correction, RBIH. 06:09 11:15 5.10 7,780 7,792 PROD4 DRILL DRLG P 7,780', BOBD 1.42 bpm at 3855 psi, BHP 4250 psi, CWT 10.5k,WOB 2.1k, ROP=25,Ankerite at 7,789', stacking coil to 2k,WOB 3.8k,very little motor work,begin mud swap (New mud at bit at 7,792')attempt to drill ahead, no change, no motor work, confer with town. Note: 1,374'drilled with 0.7%solids on old system 11:15 13:09 1.90 7,792 72 PROD4 DRILL TRIP T TOOH with BHA#21 13:09 15:21 2.20 72 0 PROD4 DRILL PULD T PJSM-Pressure Un-deploy BHA #21, HYC Razor edge bit grade 5-1-RO-N-X-I-LT-PR,6 buttons missing from inner, pics in folder. 15:21 16:51 1.50 0 72 PROD4 DRILL PULD T PJSM-Pressure Deploy BHA#22, .5 AKO motor and new HYC bi-center bit(Helios edge), 16:51 19:03 2.20 72 7,790 PROD4 DRILL TRIP T TIH with drilling assembly.Tie-in for -7.5'correction,continue in hole. 19:03 00:00 4.95 7,790 7,925 PROD4 DRILL DRLG P Drill ahead: 1.40 BPM @ 4.065 PSI, BHP=4,270 PSI, CTW=10.8K, WOB=2K, ROP=30. Slow drilling, found ankerite several times. 10/27/2014 Drill ahead L1-03 lateral from 7,925'to 8,390', encountered ankerite numerous times,slow drilling, drilling in progress. 00:00 01:18 1.30 7,925 7,990 PROD4 DRILL DRLG P Drill ahead: 1.40 BPM @ 4.065 PSI, BHP=4,270 PSI, CTW=10.8K, WOB=2K, ROP=50. 01:18 02:48 1.50 7,990 7,990 PROD4 DRILL WPRT P Wiper to window, PUW=25K, RBIH. 02:48 10:27 7.65 7,990 8,190 PROD4 DRILL DRLG P Drill ahead: 1.42 BPM @ 4.265 PSI, BHP=4,260 PSI, CTW=10K, WOB=2.1K, ROP=70. slow drilling through ankerite. 10:27 11:27 1.00 8,190 8,190 PROD4 DRILL WPRT P Wiper up hole, PUW 26k,wiper in hole at 7,190'. 11:27 22:54 11.45 8,190 8,390 PROD4 DRILL DRLG P 8,190', BOBD 1.42 bpm at 4250 psi, BHP 4270 psi, CWT 8k,WOB 2.1k, ROP 15, lots of ankerite. 22:54 00:00 1.10 8,390 6,880 PROD4 DRILL WPRT P Wiper for tie-in, PUW=24K,tie-in for _ _ +2'correction, RBIH. 10/28/2014 Drill ahead L1-03 lateral, TD well 8730', pumped 10x10 sweep and chased to surface. 00:00 00:45 0.75 6,880 8,390 PROD4 DRILL WPRT P Continue RBIH 00:45 04:30 3.75 8,390 8,530 PROD4 DRILL DRLG P Drill ahead: 1.36 BPM @ 4,040 PSI, BHP=4,295 PSI, CTW=7.5K, WOB=2.2K, ROP=40.Started having mud pump issues, pull wiper trip early. 04:30 06:09 1.65 8,530 8,530 PROD4 DRILL WPRT T Wiper trip, PUW=24K,troubleshoot pump issues,wiper in hole at 6,945'. Page 17 of 19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:09 14:27 8.30 8,530 8,730 PROD4 DRILL DRLG P 8,530', BOBD 1.36 bpm at 3975 psi, BHP 4300 psi, CWT 9.3k,WOB 2.4k, ROP 25, pump 5x5 sweeps. 14:27 15:12 0.75 8,730 7,745 PROD4 DRILL WPRT P 8,730', TD called, chase sweeps to swab, PUW 26k,well unloading, pump 10x10 sweep. 15:12 15:48 0.60 7,745 8,500 PROD4 DRILL WPRT P TBIH to 8,500'. 15:48 18:18 2.50 8,500 73 PROD4 DRILL WPRT P 8,500', POOH chasing sweep to swab, PUW 18:18 19:30 1.20 73 6,340 PROD4 DRILL TRIP P Tag up at surface, reset counters, RBIH 19:30 19:45 0.25 6,340 8,520 PROD4 DRILL DLOG P Tie into the K1 marker correction of minus 7.5ft, 19:45 21:30 1.75 8,520 8,520 PROD4 DRILL TRIP P Continue RIH,circulate completion fluid with Alipine Beads, 21:30 00:00 2.50 8,520 PROD4 DRILL DISP P POOH, laying in liner running pill. Paint 6500' EOP flag(Yellow) 4800' EOP flag(White) 10/29/2014 Finished wiper to the swab valves chasing 10x10 sweep, RBIH, POOH, laying in liner pill/completion fluid. L/D BHA#22, M/U liner assyembly BHA#23, RIH w/L1-03 liner assembly to 8520', Displaced well to seawater, freeze protected well from 2900', set BPV valve. 00:00 00:30 0.50 0 0 PROD4 DRILL OWFF P At surface,check well for flow, PJSM for UD BHA#22 00:30 01:30 1.00 0 0 PROD4 DRILL PULD P L/D Drilling BHA#22 ****Note: HYC bit grade: 4-1-bt-n-x-i-bu-td,pictures on S:Drive, (Retrieved a cutter from previous bit run). 01:30 02:00 0.50 0 0 PROD4 DRILL BOPE P Function test BOPE 02:00 02:45 0.75 0 0 COMPZ DRILL SVRG P Inspect Top Drive as per Nabors Policy. 02:45 06:15 3.50 0 1,834 COMPZ CASING PUTB P PJSM, Rig up floor to run L1-03 liner assembly with non-ported bullnose, 58 Jts of slotted liner,shorty deployment sleeve. 06:15 07:15 1.00 1,834 1,896 COMPZ CASING SVRG P PJSM, inspect INJH, inspect upper float valves in UQ,swap out lower float valves(Stuck in the open position with beads), M/U BHA#23 ****Note: Lower float valves stuck in the open position with beads. 07:15 09:30 2.25 1,896 8,520 COMPZ CASING RUNL P RIH,w/L1-03 liner assembly,tie into the EOP flag at 4800'plus 11' correction,weight check above window 26k, continue RIHTB, PUW 30k, liner on depth, 1.2 bpm and release off liner at 8,520', PUW 24k, reset counters to BHA depth. 09:30 09:54 0.40 6,680 6,500 COMPZ CASING DLOG P PUH to tie in, plus 3'correction at K1 marker,TBIH 09:54 11:42 1.80 6,500 6,500 COMPZ CASING DISP P Displace well to seawater. PJSM with LRS crew 11:42 12:42 1.00 6,500 2,900 COMPZ CASING TRIP P TOOH displacing with seawater, LRS pump 30 bbl diesel, RDMO LRS. Page 18 of 19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:42 13:36 0.90 2,900 56 DEMOB WHDBO FRZP P Freeze protect from 2,900'to surface with diesel. 13:36 15:21 1.75 56 0 DEMOB WHDBO PULD P PJSM-Pressure un-deploy, LD BHA #23. 15:21 18:00 2.65 0 0 DEMOB WHDBO MPSP P PJSM-RU, P/T FMC lubricator,set type"H"BPV, SITP 872 psi, LD FMC equipment. 18:00 21:30 3.50 0 0 DEMOB WHDBO CIRC P PJSM-valve check list, line up to circulate inhibitor through surface lines and stack. 21:30 23:30 2.00 0 0 DEMOB WHDBO CTOP P PJSM-remove BHI upper quick, secure eline with eline boot and epoxy, perform slack management pumping 1.7bpm at 4200psi, start up big air compresser, blow down coil. 23:30 00:00 0.50 0 0 DEMOB WHDBO CTOP P PJSM-Prep floor for trimming coil, install tubing cutter,set up eline cutter,stage basket on beaver slide, spot metal dumpster 10/30/2014 Cut 5000'of 2"coil from reel, ND BOPE. Rig released at 15:00. 00:00 06:00 6.00 0 0 DEMOB WHDBO CTOP P Continue trimming 5000ft from coiled tubing reel. Loading basket lowering to dumpster. 06:00 08:30 2.50 0 0 DEMOB WHDBO CTOP T Repairs to damaged pipe cutter. pipe trirmmed so far 2,461' 08:30 13:00 4.50 0 0 DEMOB WHDBO CTOP P PJSM-Continue trimming 5000'from coiled tubing reel. Loading basket lowering to dumpster.3'sample taken every 1,000'cut. Rig down pipe cutting equipment. 13:00 15:00 2.00 0 0 DEMOB WHDBO NUND P PJSM-Blow down stack, ND BOPE and secure, install coil connector, **** Rig Released at 15:00. Note:Torqueing flange bolts post rig took 45 minutes to torque with sweeny wrench Page 19 of 19 IN W II zMS. Sz T— o_ I a co 0 .. 0. co C3 w W W a H ,, Q C, z •- %.. .- 2 .- - - Cl))41- o a � 73 = _ V O tga = . N ON T Q L .Q C O c £.. O = L L J O a a 9 fa W z° (.) 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I� V O CO 0 N CO O I- ,- M uu C d O. U ". OCCN N N rnCuN O V' CO O ) N N V N Oi I` VN N0 0 C7 0 c 2. co o) a, a, 0) 0) a, a, m m m m rn mO mcoOmm I-- r` `S Y Y Q CI. o 0 rn co O O 0 CO CO O N V N V V O O O O V M O V O10 VO V V V N 0 .- M N O O N N CO N N M N N N N .- N N M O N 6666 O M O 6 O C)66666 6666 66666 66 a & co V N- O CO O 0) N u) O V N- 0 CO O O) N (O O V C- CO CO Q• C C N o y CD 0 0 0 .- .- .- •- N N N CO CO CO 'Cr V V V v) u) O O CO O CO N. O O V cG r N a6 co co- m c co co co- co O] m m O O] co- co co 0) OO N a0 Co N co- - p p C CD CC V osvvd o a w o co Letter of Transmittal r�`■ — — - - Date: RECEIVED 1G1G-04L1PBI04L1214214-140140 BAKER November 12, 2014 NOV 13 2014 1G-04L1-01 214-141 HUGHES 1G-04L1-02 214-142 AOGCC 1G-04L1-03 214-143 To: From: Makana Bender Yosha Ragbirsingh/Michael Soper AOGCC Baker Hughes INTEQ DATA LOGGED 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 M.K.BENDER Please find enclosed the directional survey data for the following well(s): 1G-04L1PB1 214140 25063 1G-04L1 214-140 25064 1G-04L1-01 214-141 25065 1G-04L1-02 214-142 25066 G-04L13 214-143 25067) (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 inp lace of return mail. 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O (Op O Q 0 D £ Pj p�^� Oro m W O Of ami N N N O (> O O O O O O O O O O O O O fl. d a N N N N N N N N N N N N N N N E 1E— ' VI i a_ Y Y�. i O ca la V V V A p N S M c0 2 p p N W n N oo O c0 W 0 OS r M O OO a a U gg S U Y Y o u u C `. co m m rn m rn rn rn m co cn �i co co co co corco `co .9 co r- r Ti n r 9 Q CL. r o O >0 O O O �p OD O N V N V V O U) O O V M O 0 10 V V V V N pO c'D pM pNo O cr- pO N N M pN N M N N N ONp ° (0, N U) oO 10 C ., d G 0 co O Oig ° O_ M O W N N N c) co • OV vr O 47 c0 c0 co CD n O co Uca. 8 p C >, V N- co os N co- N CO !b U) OD l41 !b co- co- QS OD OD OD co.- c0 co- OD OD OC l0 O U E o 6 cu 0 = Z 2 c.) a u) o co 1VTHE STATEf -` ..s _- _%,_ � L.),_J,1� Y,L_,t L� \J `_, S t ±- ,1- 333 West Seventh Avenue e GOVFRNOR Si \N PARNH !. Anchorage, Alaska 99501-3572 ET J! ';`*'- H Man 907 27c) i'3 ALAS r' cn7 ''7' 75^: 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 1G-04L1-03 ConocoPhillips Alaska, Inc. Permit No: 214-143 Surface Location: 1246' FSL, 238' FWL, SEC. 29, T12N, R10E, UM Bottomhole Location: 568' FNL, 1130' FWL, SEC. 32, T12N, R10E, UM Dear Mr. Venhaus: Enclosed is the approved application for permit to redrill the above referenced service well. The permit is for a new wellbore segment of existing well Permit No. 182-161, API No. 50-029- 20835-00-00. 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 a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, A ' pli.isz Cathy ". Foerster Chair DATED this 0*--< day of September, 2014. • RECEWED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 1 8 2014 PERMIT TO DRILL 20 AAC 25.005 AOGCC 1 a Type of Work 1 b Proposed Well Class Development-Oil ❑ Service-Win) ❑, Single Zone ❑, 1 c Specify if well is proposed for Drill ❑ + Lateral E Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates Cl Redrill ❑ Reentry[I Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2 Operator Name: 5 Bond ,U Blanket Li Single Well 11 Well Name and Number. ConocoPhillips Alaska, Inc. . Bond No. 59-52-180. 1G-04L1-03 • 3 Address 6 Proposed Depth 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD:8675' . TVD: 6698' ' Kuparuk River Field 4a Location of Well(Governmental Section) 7 Property Designation(Lease Number). Surface. 1246'FSL,238'FWL,Sec.29,T12N, R10E, UM • ADL 25640 . Kuparuk River Oil Pool Top of Productive Horizon 8.Land Use Permit 13 Approximate Spud Date 1172'FSL, 1062'FWL,Sec.29,T12N, R10E, UM 2571 10/1/2014 Total Depth 9 Acres in Property. 14.Distance to 568'FNL, 1130'FWL,Sec.32,T12N,R10E, UM 2459 r Nearest Property 16900 4b Location of Well(State Base Plane Coordinates-NAD 27) 10.KB Elevation above MSL 90 feet, 15 Distance to Nearest Well Open Surface.x- 540010 y- 5981892 Zone- 4 • GL Elevation above MSL: 61 feet - to Same Pool 1G-10BL2,1840' 16.Deviated wells -?K-6 Kickoff depth - 664 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25 035) Maximum Hole AnglitiVtea° deg Downhole 3660 psig. Surface:3002 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 1991' 6684' 6579' 8675' 6698' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redd!and Re-Entry Operations) Total Depth MD(ft) Total Depth TVD(ft) Plugs(measured) Effective Depth MD(ft) Effective Depth TVD(ft) Junk(measured) 7415' 7295' none 7365' 7246' none Casing Length Size Cement Volume MD TVD Conductor/Structural 51' 16" 250 sx AS II 80' 80' Surface 2193' 10.75" 1250 sx AS III,250 sx AS I 2222' 2222' Production 7371' 7" 570 sx Class G,250 sx AS I 7399' 7280' Perforation Depth MD(ft). Perforation Depth TVD(ft): 6480-6484,6488-6516,6524-6530,6580-6618,6682-6684,6808-6822,6836-6850 6381-6384,6388-6416,6423-6429,6478-6515,6577-6579,6700-6714,6728-6741 20 Attachments Property Plat❑ BOP Sketch ❑ Drilling Progran- ❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch.❑ Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25 050 requirements 0 21.Verbal Approval Commission Representative Date C7//t/ 22 I hereby certify that the foregoing is true and correct Contact James Ohlinger @ 265-1102,0, Email James.J.Ohlinger@cop.com Printed Name ..-.D. Venhyus Title CTD Engineering Supervisor Signature4 !f f.GO✓12' Phone:263-4372 Date T-/7- Commission Use Only Permit to Drill API Number p Permit Approo I See cover letter Number 0.19 — 14 3 50- 0.2.9-c2.0p 3S (3 -00 Date. l� '1 I4 for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed m thane,gas hydrates,or gas contained in shales. d Other: 0c p tt5 t 35-o o ps; Samples req'd: Yes ❑ No [1 Mud log req'd: Yes❑ No 2/ 5"-a /-c- kr r,fn -s s -d An IT-!.4- H2S measures: Yes Ni No Directional svy req'd: Yes d No❑ rt cL v r i—e c1 4F1-r,-S i,---4 br 1 r 3 Spacing exception req'd: Yes ❑ No Inclination-only svy req'd: Yes❑ No Ff r---, 'ccf1c" / Approved by `�-- CQ,QSf'�(NEF I 1\ PAVHE Date 9-, -1j,,,, Form 10-401 (R ed 10/2012)��`�is permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) y�i 9/i/ .7 „/� ConocoPhillips' RECEIVED Alaska SEP 1 8 2014 P.O.BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC September 10,2014 Commissioner-State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an application for permits to drill a quadri-lateral out of the Kuparuk Well 1G-04 using the coiled tubing drilling rig, Nabors CDR2-AC. The work is scheduled to begin in October 2014. The CTD objective will be to drill quadri-laterals (1G-04L1 and 1G-04L1-01, 1G-04L1-02, &1G-04L1-03), targeting the A sand intervals. Attached to this application are the following documents: — Permit to Drill Application Form for 1G-04L1 and 1G-04L1-01, 1G-04L1-02, & 1G-04L1-03 — Detailed Summary of Operations — Directional Plans — Proposed Schematic If you have any questions or require additional information please contact me at 907-265-1102. Sincerely, James Ohlinger Coiled Tubing Drilling Engineer A • 4 , Kuparuk CTD Laterals NAHOR,A X D CI Pi 1G-04L1 , L1-01, L1-02, & L1-03 Application for Permit to Drill Document 2RC 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(1)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 MC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 MC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 MC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 MC 25.005(c)(5)) 2 6. Casing and Cementing Program 3 (Requirements of 20 MC 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 MC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 5 (Requirements of 20 AAC 25.005(c)(13)) 5 Summary of Operations 5 Pressure Deployment of BHA 6 Liner Running 7 14. Disposal of Drilling Mud and Cuttings 7 (Requirements of 20 AAC 25.005(c)(14)) 7 15. Directional Plans for Intentionally Deviated Wells 7 (Requirements of 20 MC 25.050(b)) 7 16. Quarter Mile Injection Review(for injection wells only) 8 (Requirements of 20 AAC 25.402) 8 KRU 1G-04(motherbore injector) 8 KRU Surrounding Wells 8 KRU 1G-09(injector) 8 17. Attachments 8 Attachment 1: Directional Plans for 1G-04L1, L1-01, L1-02,&L1-03 8 Attachment 2: Current Well Schematic for 1G-04 8 Attachment 3: Proposed Well Schematic for 1G-04L1,L1-01, L1-02,&L1-03 8 Page 1 of 8 ORIGINAL 9/15/2014 PTD Application: 1G-04L1, L1-01, L1-02, & L1-03 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 1G-04L1, L1-01, L1-02, & L1-03. All laterals will be classified as"Service—Water Injection"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 the attached 10-401 form for surface and subsurface coordinates of the 1G-04L1, L1-01, L1-02, & L1-03. 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 3500 psi. Using the maximum formation pressure in the area of 3660 psi in the 1G-04(the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 3002 psi. See the"Drilling Hazards Information and Reservoir Pressure"section for more details. — The annular preventer will be tested to 250 psi and 2500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005(c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005(c)(4)(a)) A static bottom hole pressure in 1G-p4 of the A-sand in August 2014 indicated a reservoir pressure of 3660 psi or 10.7 ppg equivalent mud weight. The maximum down hole pressure in the 1G-04 pattern is at 1G-04. The highest pressure in an offset well is at 1G-09 with 3434 psi, or 10.0 ppg EMW. Using the 1G-04 pressure as the maximum possible, the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 3002 psi.' Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) No specific gas zones will be drilled; gas injection was last performed April/May 2010, so there's a low probability of encountering gas. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) An expected risk of 1G-04 is the hole stability through the lower A3 sand/silt. There are backup kick-off locations and room for plugback sidetrack options. There are also paralleling large N-S faults that are perpendicular to another fault that would result into watering out the lateral prematurely. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) N/A for this thru-tubing drilling operation. According to 20 AAC 25.030(f), thru-tubing drilling operations need not perform additional formation integrity tests. Page 2 of 8 ORIGINAL 9/15/2014 { PTD Application: 1G-04L1, L1-01, L1-02, & L1-03 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 1G-04L1 7225' 10,100' 6662' 6671' 2%", 4.7#, L 80, ST-L slotted liner; with aluminum billet on top. 1G-04L1-01 6920' 10,100' 6666' 6647' 2%", 4.7#, L 80, ST-L slotted liner; with aluminum billet on top. 1G-04L1-02 7004' 8675' 6663' 6634' 2%", 4.7#, L-80, ST-L slotted liner; with aluminum billet on top. 1G-04L1-03 6684' 8675' 6489' 6608' 2%", 4.7#, L-80, ST-L slotted liner Existing Casing/Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (ppf) MD MD TVD TVD psi psi Conductor 16" 62.50 H-40 Welded 29.5' 80' 0' 80' 1640 630 Surface 10-3/4" 45.5 J-55 BTC 29.5' 2222' 0' 2222' 4980 4330 Casing 7" 26 K-55 BTC 28' 7399' 0' 7280' 7240 5410 Tubing 31/2" 9.2 L-80 EUE-MOD 24.5' 6667' 0' 6562' 10160 10540 7. Diverter System Information (Requirements of 20 AA C 25.005(c)(7)) N/A for this thru-tubing drilling operation. Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AA C 25.005(c)(8)) Diagram of Drilling System Diagram of Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System - Window milling operations: Chloride-based Flo-Pro mud (9.8 ppg) - Drilling operations: Chloride-based Flo-Pro mud (9.8 ppg). While this mud weight may not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. - Completion operations: 1G-04 does not contain a subsurface safety valve (SSSV). The well will be loaded with 12.0 ppg NaBr completion fluid in order to provide formation over-balance while running completions. - Emergency Kill Weight fluid: Two well bore volumes (-285 bbl) of at least 13.1 ppg emergency kill weight fluid will be within a short drive to the rig during drilling operations. ORIGINAL Page 3 of 8 9/16/2014 PTD Application: 1G-04L1, L1-01, L1-02, & L1-03 Managed Pressure Drilling Practice Managed pressure drilling (MPD)techniques will be employed to maintain a constant overbalanced pressure on the openhole formation throughout the coiled tubing drilling (CTD) process. Maintaining a constant BHP promotes wellbore stability, particularly in shale sections, while at the same time providing an overbalance on the reservoir. Through experience with drilling CTD laterals in the Kuparuk sands, 11.8 ppg has been identified as the minimum EMW to ensure stability of shale sections. The constant BHP target will be adjusted to maintain overbalanced conditions if increased reservoir pressure is encountered during drilling. The constant BHP target will be maintained utilizing the surface choke. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Pressure at the 1G-04 Window(6750' MD,6644'TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure(10.7 ppg) 3660 psi 3660 psi Mud Hydrostatic(9.8 ppg) 3386 psi 3386 psi Annular friction (i.e. ECD, 0.090 psi/ft) 608 psi 0 psi Mud+ ECD Combined 4073 psi 3386 psi (no choke pressure) (overbalanced (underbalanced —417 psi) —274 psi) Target BHP at Window(11.8 ppg) 4077 psi 4077 psi Choke Pressure Required to Maintain Target BHP 0 psi 691 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AA C 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AA C 25.005(c)(11)) N/A-Application is not for an exploratory or stratigraphic test well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Page 4 of 8 O R I G ( NAL 9/15/2014 PTD Application: 1G-04L1, L1-01, L1-02, & L1-03 r 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well 1G-04 is a Kuparuk A-sand injection(service)well equipped with 31/2"tubing and 7"production casing. Four laterals from well 1G-04 will be drilled,two to the North(1G-04L1 &L1-01)and two to the South(1G-04L1-02&L1-03)side of parent well 1G-04 to improve sweep in an immature A sand pattern while supporting 1G-08A. Operations will be targeting the A4 and A3 sand intervals. The C-sand perforations in the Cl,6580'-6618' MD will be cemented off to seal the leaking mandrel at 6628' MD. The C3/C4 will remain accessible with the selective completion. The D-Nipple located at 6688' MD will have the ID milled out to a 2.80"to allow the drilling assemblies access through the tubing tall. The tubing tail will also be perforated prior to cementing to allow cement between the 3-1/2"tubing tail and 7"casing. Sunday 314-456 has been approved for the preparation work. Prior to drilling,the existing A-sand perfs in 1 G-04 will be squeezed with cement to provide a means to kick out of the 7"casing. After plugging off the existing A-sand perfs with cement, a mechanical whipstock will be placed in the 7"casing at the planned kickoff point. All sidetracks will exit through the 7"casing at 6750' MD and will target the A3 &A4 sands north and south of the existing well. The laterals will be completed with 2-%" slotted liner from TD with the liner top located inside the 3'/2"tubing at 6684' MD. Pre-CTD Work 1. Positive pressure and drawdown tests on MV and SV. 2. Test Packoffs—T&IC 3. Slickline: Pull the Dummy GLVs at 6557' and 6628' MD 4. E-line: Shoot 2' of holes in the 3%2"tubing tail at 6684' MD. 5. E-line: Set a composite bridge plug(CBP)in the 3%2"tubing at 6647' 6. Coil: Cement squeeze the C-sand straddle to seal off the leaking mandrel at 6628' MD 7. Coil: Drill out cement and CBP plug. 8. Coil: Mill out Camco D-nipple at 6688' MD to 2.80" 9. Coil: Lay in cement plug(A-sand squeeze) in the 7"casing - 10. Slickline: Drift tubing,tag top of cement(TOC). PT to 2500 psi. 11. Prep site for Nabors CDR2-AC, including setting BPV Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 1G-04L1 Lateral(A3 sand North) a. Drill 2.80"high-side pilot hole through cement to 6800' MD b. Drift pilot hole with whip-stock dummy c. RU Slickline—caliper pilot hole d. Set whip-stock at 6750' MD e. Mill 2.80"window at 6750' MD f. Drill 2.74"x 3.0"bi-center lateral to TD of 10,100' MD g. Run 2%"slotted liner with an aluminum billet from TD up to 7225' MD Page5of8 RIGINA 9/17/2014 PTD Application: 1G-04L1, L1-01, L1-02, & L1-03 3. 1G-04L1-01 Lateral(A4 sand North) a. Kick off of the aluminum billet at 7225' MD b. Drill 2.74"x 3.0"bi-center lateral to TD of 10,100' MD c. Run 2%"slotted liner with an aluminum billet from TD up to 6920' MD 4. 1G-04L1-02 Lateral(A3 sand South) a. Kick off of the aluminum billet at 6920' MD b. Drill 2.74"x 3.0"bi-center lateral to TD of 8675' MD c. Run 2%"slotted liner with an aluminum billet from TD up to 7150' MD 5. 1G-04L1-03 Lateral(A4 sand South) a. Kick off of the aluminum billet at 7150' MD b. Drill 2.74"x 3.0"bi-center lateral to TD of 8675' MD c. Run 2%"slotted liner from TD up to 6684' MD, inside the 3'/Z"tubing tail 6. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain static BHP. Install GLV(if needed). 3. Turn over to pre-production(several months) 4. Return well to injection Pressure Deployment of BHA The planned bottomhole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. Because of this, MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slickline lubricator. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment,the steps listed above are observed, only in reverse. Page 6 of 8 O I ^ I N A L 9/15/2014 PTD Application: 1G-04L1, L1-01, L1-02, & L1-03 Liner Running — The 1G-04 CTD laterals will be displaced to an overbalancing fluid (12.0 ppg NaBr) prior to running liner. See the"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 openhole section. — Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 1G-04L1 14,420' 1G-04L1-01 14,460' 1G-04L1-02 16,960' 1G-04L1-03 16,900' — Distance to Nearest Well within Pool (heel measured to offset well) Lateral Name Distance Well 1G-04L1 1730' 1 G-10BL2 1G-04L1-01 1730' 1G-10BL2 1G-04L1-02 1850' 1 G-10BL2 1G-04L1-03 1840' 1G-10BL2 Page 7 of 8 ORIGINAL 9/15/2014 Bettis, Patricia K (DOA) From: Ohlinger,James J <James.J.Ohlinger@conocophillips.com> Sent: Friday, September 19, 2014 2:04 PM To: Bettis, Patricia K (DOA) Subject: RE: KRU 1G-04L1-02 and 1G-04L1-03: Permit to Drill Applications Under the '/ Mile review for the 1G-04 CTD laterals: Wells 1G-09 and 1R-01 are within theY4 mile for the 1G-04L1 and 1G-04L1-01 laterals. There are no wells within the1/4 mile for the 1G-04L1-02 and 1G-04L1-03 laterals. From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Friday, September 19, 2014 1:50 PM To: Ohlinger, James J Subject: [EXTERNAL]KRU 1G-04L1-02 and 1G-04L1-03: Permit to Drill Applications Good afternoon James, The quarter mile injection review submitted with the application applied to KRU 1G-04L1 and KRU 1G-04L1-01. As KRU 1G-04L1-02 and 1G-04L1-03 will be drilled to the south, a new quarter mile review along with a spider map showing all wells within a quarter miles of KRU 1G-04L1-02 and 1G-04L1-03 needs to be submitted. This information may be sent to me via e-mail. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 PTD Application: 1G-04L1, L1-01, L1-02, & L1-03 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) o KRU 1G-04 (motherbore injector) � \� . CN • Completed with 7", 26#, K-55 casing on 10/17/82. • C-sand perforations: C4: 6480'-6484' MD, C4: 6488'-6516' MD, C3: 6524'X530' MD, Cl: 6580'-6618' MD • A-sand perforations: A4: 6808'-6822' MD, A3: 6836'-6850' MD • The tubing tail is at 6701' MD with the packers at 6304', 6544', and 664D • 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. KRU Surrounding Wells SS KRU 1G-09 (injector) • t<% • Completed with 7", 26#, K-55 casing on 8128'183. • C-sand perforations: C4: 7770'-7814' MD/t1: 7864'-7914' MD • A-sand perforations: A4: 8105'-8117' MD, A3: 8130'-8146' MD • The tubing tail is at 8017' MD with the'packers at 7609', 7822', and 8005' MD • 1G-09 will be a C-sand only injector with the 1G-04 CTD laterals supporting A-sand. • The cement bond log shows excellent cement between the A and C sand intervals. KRU 1R-01 (producer) • Completed with 7", 26#,;`J-55 casing and is a CTD multilateral from 2008 • Sidetracked at 8053',v.'ith 2 laterals and 2 plugbacks • The A-sand CTD extension in 2000 was to the south which is 1R-01B. The 2008 laterals kicked off above the CTD7extension and turned north to A-sand targets. • 1R-01 is separefied from the 1G-04 CTD laterals by a large sealing fault. • 1R-01 has been shut in since August 2013, and is planned to be so for the foreseeable future. i 17. Attachments Attachment 1: Directional Plans for 1G-04L1, L1-01, L1-02, & L1-03 Attachment 2: Current Well Schematic for 1G-04 Attachment 3: Proposed Well Schematic for 1G-04L1, L1-01, L1-02, & L1-03 (7? P\ IGIN AL Page 8 of 8 9/17/2014 ca 0 o b 0 o o 0 0 o g _ 11 N n I—N ON c m (0 am I-n t-1 CO CO a)co -0 174 Ull m II II c C N c N r2.- 0- m d c= I-0 Q.= CO -a -o c. a + W" a)c, �� o + U� Cm c m W -- c (O co a1 v c o= -fl 0-m a 9 0 'O M 8- O + U0` o N CU 0 Q_ _Q N m -ty C b Co C O J c V c I 0 E (N E c o= 0- I E^ N (V CO co (OE - •E (�„ �^ I (V N N I as as $ E v v co a' •N v in csi• co 0 ccoo ccoo > 0 0 ro c 0 m mt 2 2 _ yy 13 N F-- @ N 0- ) N 7 c0 - (00 .O `1 (0 -0 -0 U O O (0- 1 — 11 _ ch _ N 0 C a1 �� a7 a7 a3 v N O 8 0 # 11 in 2 m a1 00 E 0 E:x a) a)c•o 1\ m LOO Q E a 22 o 2 0 N _n g allo J J co▪ ti C ;_,Cr U Pli a) - N O) NM 0 N: W O m0 C 'O m2 i3U 1 \ 11 '6 N N (a a) C p— C a1 \\� 1 1 C CD W N a3 N CO -p- \ I m U 0 -0-C °'co D E I' co• © U 4.�. U 4U a) 0 0(1 0 •\� E xt E E NJ E J E g a0i E cW EF /, a1 co co a1 •-I ca I co a) (o mm (0.. //// o oi 0 0 (�)(L 0 ti.C)OI0 0 NV) C)al \I //// (V (V (V N Y) N Y(V Z N (V YY NZ T- 7 a1 a) a1 s- ,- a1 co I A A M M mm M m A M mm M ' / I I 1 1 I M I I 7 1 O 1 • 'X N O al a) cvf r ci O - •a, o I113-0w ✓ r c c a 9,6111 PlIFO*1 // NN ' t• ofi "" 1 h., , 1 A " . I, 1 v cu M , :. ▪ a o a) .c --I Q 4-• o ((a t i I I I U III III III m a III III m N O LQ 0 a) o00 0 b L O to c�2� c� n L -V t0N V c00 �a0 (O 00 �� d �N N N oD.—c'1 N N2 )0 •' L u N `C—V to In 0(<103 �` 't(V O Y O) 0 y V/�, O E(0 CO(O EV CD tO Ykm 1 - v 00 00 V 00 O a0 N •O 0 CO CO N 0 00 n- C(O(O co co r O I ID t0 UD c �oo� /1)(0 YO 000m i�m CCoo N� V SUV V JC.) QcO0 _ co ORIGINAL KUP INJ 1G-04 ConocoPhillips " & Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/Utit Field Name Wellbore Status nc1(1 MD(ftKB) Act Stm(ftKB) r,.„,,,,,„ii,p, 500292083500 KUPAR UK RIVER UNIT INJ 14.10 3,900.00 7,415.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date 10-04.9/120141.40:53 PM SSSV:NIPPLE Last WO: 2/1/2000 3449 11/2/1982 Wiliest schematic tactual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ................................................................... __..Last Tag:SLM 6,838.0 8/20/2014 Rev Reason:TAG,PERF,SET PLUG hipshki 9/1/2014 HANGER;24.5 ( - Casing Strings Casing Description OD(In) ID(in) Top(ftKB) Set Depth(11661 Set Depth(ND)...WtlLen(I...Grade Top Thread CONDUCTOR 16 15.060 29.5 80.0 80.0 62.58 H-40 WELDED , , J Casing Description 00(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread tl�. SURFACE 103/4 9.950 29.5 2,222.0 2,221.9 45.50 J-55 BTC Ii Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR;29.5-60.0 . PRODUCTION 7 6.276 28.0 7,399.0 7,279.7 26.00 K-55 BTC Tubing Strings IITubing Description String Ma...10(in) Top(ftKB) Set Depth(ft..1Set Depth(ND)(...Wt(lb/ft) Grade Top Connection NIPPLE;505.2 TUBING WO 312 2.992 24.5 6,666.91 6,562.4 9.30 L-80 EUE8RDABM r Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 24.5 24.5 0.07 HANGER MCEVOY GEN III HANGER 3.500 505.2 505.2 0.38 NIPPLE CAMCO DS NIPPLE 2.875 SURFACE;29.5-2,222.0- 6,271.6 6,178.1 14.01 NIPPLE CAMCO W LANDING NIPPLE w/2.812 SELECTIVE 2.812 PROFILE GAS LIFT;6225.7 C 6,279.6 6,185.9 14.03 SEAL ASSY BAKER NO GO SEAL ASSEMBLY 2.992 6,281.0 6,187.2 14.03 PBR BAKER 80-40 PBR 3.000 6,304.4 6,209.9 14.05 PACKER BAKE FHL RETRIEVABLE PACKER 2.992 NIPPLE;6,271.6 6,473.9 6,374.5 13.60 BLASTJT BLAST JOINTS(2) 2.992 6,543.9 6,442.6 13.33 PACKER BAKER FHL RETRIEVABLE PACKER 3.000 sEALAsst;e.z7s.s 6,571.8 6,469.8 13.17 BLASTJTS BLAST JOINTS(2) 2.992 6,652.4 6,548.3 12.81 NIPPLE CAMCO W LANDING NIPPLE w/2.813 SELECTIVE 2.813 PBR;6,281.0 ti PROFILE 6,666.1 6,561.6 12.76 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 2.812 PACKER;6,304.4 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(NO)(...Wt(Ib/ft) Grade Top Connection -LL TUBING Original 3 1/2 2.992 6,665.9 6,699.7 6,594.4 9.30 J-55 IPC BTC Completion Details Nominal ID INJECTION;6,349.4 Top(ftKB) Top(TVD)(ftKB) Top Incl Pt Item Des Com (in) 6,666.9 6,562.4 12.75 PACKER BAKER 2-B PACKER 4.000 6,669.4 6,564.9 12.74 SBE BAKER SEAL BORE EXTENSION 4.000 6,687.3 6,582.3 12.67 NIPPLE CAMCO D NIPPLE 2.750 INJECTION,sAzs� 6,698.8 6,593.5 12.62 SOS BAKER SHEAR OUT SUB,ELMD TTL @ 6701'during 3.015 IPROF on 08/24/2007 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) 1°) Des Com Run Date ID/44 APERF;6.480.0.6,484.0-. - 6,646.0 6,542.1 12.84 PLUG 2.69"HALLIBURTON FASDRILL PLUG 8/30/2014 0 000 Perforations&Slots APERF;6,488.0-6,516.0- Shot Top(ND) Btm(ND) (shotsa APERF;6,524.0-6,530.0 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date Dens t) Type Com _ 6,480.0 6,484.0 6,380.5 6,384.4 C-4,1G-04 8/1/1984 12.0 APERF Bakers DPCP 6,488.0 6,576.0 6,388.2 6,475.5 C-4,1G-04 8/1/1984 12.0 APERF Baker DPCP U 6,524.0 6,530.0 6,423.2 6,429.1 C-3,1G-04 8/1/1984 12.0 APERF Baker 5 DPCP PACKER;6,543.9 _' 6,580.0 6,618.0 6,477.7 6,514.8 C-1,UNIT B, '8/1/1984 12.0 APERF Baker 5 DPCP 1G-04 INJECTION;6,557.4 6,682.0 6,684.0 6,577.2' 6,579.1 A-3,1G-04 8/30/2014 6.0 APERF HES HMX BIGHOLE CHARGES,60 DEG PHASE APERF;6,580.0-6,618.0- - 6,808.0 6,822.0 6,700.2 6,713.9 A-4,10-04 11/3/1982 12.0 IPERF GeoVann TCP _ 6,836.0 6,850.0 6,727.5 6,741.2 A-3,1G-04 11/3/1982 12.0 IPERF GeoVann TCP Mandrel Inserts INJECTION;6,627.9 - St ati C on Top(TVD) Valve Latch Port Size TRO Run o q� No Top(ftKB) (ftKB) Make Model _OD(in) Sery Type Type (in) (psi) Run Date PLUG;6,648.0 IA 1 6,225.7 6,133.6 CAMCO MMM 11/2 GAS LIFT DMY RK 0.000 0.0 3/2/2000 7 NIPPLE;6,652,4- 3 0 1 2 6,349.4 6,253.5 CAMCO MMM ' 112 INJ DMY RK 0.000 0.0 6/10/2001 8 3 SEAL ASSY;6,666.1 0 PACKER;6,666.9t N. : 3 6,429.7 6,331.6 CAMCO MMM 11/2 INJ DMY RK 0.000 0.0 5/25/2007 1 SBE;6,669.4p O t 0 ..-"-- 4 6,557.4 6,455.7 CAMCO MMM 1 1/2 INJ DMY RK 0.000 00 2/6/2000 1 APERF;6.6620-5,684,- 1 0 NIPPLE;6,687.3 D 11 5 6,627.9 6,524.4 CAMCO MMM 1 1,2 INJ OPEN RK 0.000 0.0 8/20/2014 1 0 SOS;8,698.8 iii 3 IPERF;6,eoe.o fi,a22o- Notes:General&Safety End Date Annotation IPERF;6,836.0.6,850.0- 8/15/2010 NOTE:View Schematic w/Alaska Schematic9.0 3/27/2014 NOTE:CSM©6628'APPARENTLY LEAKING.PULLED SEVERELY ERODED CV 10/23/2011 PRODUCTION;28.0-7,399.0- ORIGINIAL , y W Mjsr we Elmo zz' { .�xx■xx■ T gxg■g■g■■g■g■g■■■x�■■g■■- _ _■■■■■■■■■■■■ex■■.x.■� _ 18 a uu : e IOHH11l1iiim !H!!IENff H ! , _: x gg i C �' / r ALE■ 11i a .1 11111111111"" ggg� !i■ ' oo !!!■!! ! ■ a iEi•l tL o I : i.! : i o ° - !llml! lla..a LS' ! ! ll!!l !!sLg C • -- 1` 1II:Iii!!�!_!so � E. `i'' I!!I!!!g!g■■■ o y !� !! l l iElEgi i!!j ■■■ . $• °04-, e::::::a:!!!!l!!■ = G E !•!■ • •. y q :egg ° •' c �a $ !!�! !! ! !ea lli!! y � !g� E•.' . .. 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V r M, ' r--: C — V 'A OVV V rn rn rn N NN - - . , 1 . 40Jsn OCE)/+ u 0N/ u1nos _ ConocoPhilli ps ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1G Pad 1G-04 1G-04L1-03 Plan: 1 G-04L1-03_wp02 Standard Planning Report 11 September, 2014 BAKER HUGHES CRIGIAL • , `- IE ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Prod Local Co-ordinate Reference: Well 1G-04 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1G-04 @ 90.Oousft(1G-04) Site: Kuparuk 1G Pad North Reference: True Well: 1G-04 Survey Calculation Method: Minimum Curvature Wellbore: 1G-04L1-03 Design: 1G-04L1-03_wp02 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 1G Pad Site Position: Northing: 5,981,540.78 usft Latitude: 70°21'37.826 N From: Map Easting: 540,089.12 usft Longitude: 149°40'27.705 W Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.31 ° Well 1 G-04 Well Position +N/-S 0.00 usft Northing: 5,981,891.82 usft Latitude: 70°21'41.283 N +E/-W 0.00 usft Easting: 540,010.13 usft Longitude: 149°40'29.960 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1G-04L1-03 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1 (°) (nT) BG GM 2014 11/1/2014 19.18 80.95 57,582 Design 1G-04L1-03_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,150.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 153.65 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +NI-S +E/-W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (°j Target 7,150.00 94.81 150.81 6,640.04 -354.24 1,029.62 0.00 0.00 0.00 0.00 7,250.00 97.17 157.44 6,629.60 -443.65 1,073.01 7.00 2.36 6.63 70.00 7,320.00 97.14 162.38 6,620.87 -508.86 1,096.86 7.00 -0.04 7.05 90.00 7,520.00 92.21 175.53 6,604.51 -704.02 1,134.89 7.00 -2.47 6.57 110.00 7,600.00 91.42 169.98 6,601.97 -783.31 1,144.98 7.00 -0.99 -6.93 262.00 7,750.00 91.40 180.48 6,598.28 -932.54 1,157.43 7.00 -0.02 7.00 90.00 7,900.00 90.10 190.90 6,596.32 -1,081.58 1,142.57 7.00 -0.86 6.95 97.00 8,030.00 89.47 199.98 6,596.81 -1,206.75 1,107.99 7.00 -0.49 6.98 94.00 8,160.00 90.11 209.06 6,597.30 -1,324.90 1,054.10 7.00 0.49 6.98 86.00 8,260.00 90.83 202.10 6,596.47 -1,415.04 1,010.96 7.00 0.73 -6.96 276.00 8,360.00 89.98 195.15 6,595.76 -1,509.75 979.05 7.00 -0.86 -6.95 263.00 8,430.00 85.08 195.15 6,598.78 -1,577.23 960.78 7.00 -7.00 0.00 180.00 8,500.00 86.93 199.70 6,603.67 -1,643.84 939.87 7.00 2.64 6.50 68.00 8,675.00 90.14 187.87 6,608.16 -1,813.42 898.28 7.00 1.84 -6.76 285.00 9/11/2014 1:47:47PM Page 2 COMPASS 5000.1 Build 61 . . FE" ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Prod Local Co-ordinate Reference: Well 1G-04 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1G-04 @ 90.00usft(1G-04) Site: Kuparuk 1G Pad North Reference: True Well: 1 G-04 Survey Calculation Method: Minimum Curvature Wellbore: 1G-04L1-03 Design: 1 G-04L1-03_wp02 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) (1100usft) (°) (usft) (usft) 7,150.00 94.81 150.81 6,640.04 -354.24 1,029.62 774.45 0.00 0.00 5,981,543.13 541,041.53 TIP/KOP 7,200.00 96.00 154.12 6,635.33 -398.37 1,052.63 824.21 7.00 70.00 5,981,499.12 541,064.77 7,250.00 97.17 157.44 6,629.60 -443.65 1,073.01 873.84 7.00 70.31 5,981,453.95 541,085.39 Start 7 dls 7,300.00 97.15 160.96 6,623.36 -490.02 1,090.62 923.21 7.00 90.00 5,981,407.68 541,103.25 7,320.00 97.14 162.38 6,620.87 -508.86 1,096.86 942.86 7.00 90.44 5,981,388.88 541,109.59 3 7,400.00 95.20 167.66 6,612.27 -585.66 1,117.41 1,020.80 7.00 110.00 5,981,312.19 541,130.54 7,500.00 92.71 174.22 6,605.36 -684.12 1,133.10 1,115.99 7.00 110.57 5,981,213.83 541,146.76 7,520.00 92.21 175.53 6,604.51 -704.02 1,134.89 1,134.62 7.00 111.02 5,981,193.94 541,148.65 4 7,600.00 91.42 169.98 6,601.97 -783.31 1,144.98 1,210.14 7.00 -98.00 5,981,114.71 541,159.16 5 7,700.00 91.41 176.98 6,599.50 -882.57 1,156.32 1,304.13 7.00 90.00 5,981,015.53 541,171.04 7,750.00 91.40 180.48 6,598.28 -932.54 1,157.43 1,349.39 7.00 90.17 5,980,965.57 541,172.41 6 7,800.00 90.97 183.96 6,597.25 -982.48 1,155.49 1,393.29 7.00 97.00 5,980,915.62 541,170.74 7,900.00 90.10 190.90 6,596.32 -1,081.58 1,142.57 1,476.35 7.00 97.07 5,980,816.47 541,158.35 7 8,000.00 89.61 197.89 6,596.57 -1,178.38 1,117.73 1,552.06 7.00 94.00 5,980,719.55 541,134.03 8,030.00 89.47 199.98 6,596.81 -1,206.75 1,107.99 1,573.17 7.00 93.98 5,980,691.12 541,124.45 8 8,100.00 89.81 204.87 6,597.25 -1,271.44 1,081.30 1,619.28 7.00 86.00 5,980,626.30 541,098.10 8,160.00 90.11 209.06 6,597.30 -1,324.90 1,054.10 1,655.12 7.00 85.97 5,980,572.70 541,071.19 9 8,200.00 90.40 206.27 6,597.12 -1,360.32 1,035.53 1,678.62 7.00 -84.00 5,980,537.18 541,052.81 8,260.00 90.83 202.10 6,596.47 -1,415.04 1,010.96 1,716.74 7.00 -84.01 5,980,482.34 541,028.53 10 8,300.00 90.49 199.32 6,596.01 -1,452.45 996.82 1,743.99 7.00 -97.00 5,980,444.86 541,014.59 8,360.00 89.98 195.15 6,595.76 -1,509.75 979.05 1,787.44 7.00 -97.03 5,980,387.47 540,997.13 11 8,400.00 87.18 195.15 6,596.76 -1,548.34 968.60 1,817.39 7.00 -180.00 5,980,348.83 540,986.89 8,430.00 85.08 195.15 6,598.78 -1,577.23 960.78 1,839.80 7.00 -180.00 5,980,319.90 540,979.22 12 8,500.00 86.93 199.70 6,603.67 -1,643.84 939.87 1,890.21 7.00 68.00 5,980,253.19 540,958.68 13 8,600.00 88.76 192.94 6,607.44 -1,739.68 911.82 1,963.64 7.00 -75.00 5,980,157.21 540,931.14 8,675.00 90.14 187.87 6,608.16 -1,813.42 898.28 2,023.71 7.00 -74.74 5,980,083.40 540,918.00 Planned TD at 8675.00 9/11/2014 1:47:47PM Page 3 COMPASS 5000.1 Build 61 R ! G1NAL • . , y ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Prod Local Co-ordinate Reference: Well 1G-04 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1G-04 @ 90.00usft(1G-04) Site: Kuparuk 1G Pad North Reference: True Well: 1G-04 Survey Calculation Method: Minimum Curvature Wellbore: 1G-04L1-03 Design: 1 G-04L1-03_wp02 Targets Target Name : -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 1G-04L1-03_T03 0.00 0.00 6,597.00 -982.76 1,155.15 5,980,915.34 541,170.40 70°21'31.617 N 149°39'56.187 W -plan misses target center by 0.40usft at 7800.32usft MD(6597.24 TVD,-982.80 N,1155.47 E) -Point 1G-04L1-03_T05 0.00 0.00 6,596.00 -1,509.87 979.31 5,980,387.36 540,997.40 70°21'26.433 N 149°40'1.330 W -plan misses target center by 0.37usft at 8360.05usft MD(6595.76 TVD,-1509.80 N,979.03 E) -Point 1G-04 CTD Polygon Nor 0.00 0.00 0.00 -154.32 713.53 5,981,741.33 540,724.41 70°21'39.765 N 149°40'9.096 W -plan misses target center by 6638.62usft at 7400.O0usft MD(6612.27 TVD,-585.66 N,1117.41 E) -Polygon Point 1 0.00 0.00 0.00 5,981,741.33 540,724.41 Point2 0.00 -163.84 156.15 5,981,578.34 540,881.41 Point 3 0.00 -191.95 364.03 5,981,551.35 541,089.42 Point4 0.00 77.57 650.48 5,981,822.37 541,374.40 Point5 0.00 614.64 837.35 5,982,360.37 541,558.38 Point6 0.00 1,437.45 889.71 5,983,183.37 541,606.34 Point7 0.00 1,898.22 944.15 5,983,644.38 541,658.31 Point8 0.00 2,370.80 1,033.66 5,984,117.38 541,745.28 Point 9 0.00 2,877.05 1,186.36 5,984,624.39 541,895.26 Point 10 0.00 2,954.75 866.73 5,984,700.38 541,575.25 Point 11 0.00 2,434.36 738.96 5,984,179.36 541,450.28 Point 12 0.00 1,958.76 653.44 5,983,703.36 541,367.31 Point 13 0.00 1,525.37 529.13 5,983,269.35 541,245.33 Point 14 0.00 900.80 435.81 5,982,644.36 541,155.35 Point 15 0.00 616.59 469.31 5,982,360.36 541,190.37 Point 16 0.00 223.96 390.23 5,981,967.35 541,113.40 Point 17 0.00 106.32 320.60 5,981,849.35 541,044.40 Point 18 0.00 124.72 243.69 5,981,867.34 540,967.40 Point 19 0.00 0.00 0.00 5,981,741.33 540,724.41 1G-04L1-03_T01 0.00 0.00 6,615.00 -560.49 1,111.41 5,981,337.33 541,124.41 70°21'35.770 N 149°39'57.464 W -plan misses target center by 0.25usft at 7373.97usft MD(6614.77 TVD,-560.44 N,1111.50 E) -Point 1G-04L1-03_T07 0.00 0.00 6,608.00 -1,813.46 898.68 5,980,083.36 540,918.40 70°21'23.447 N 149°40'3.688 W -plan misses target center by 0.43usft at 8674.97usft MD(6608.16 TVD,-1813.39 N,898.29 E) -Point 1G-04L1-03_T02 0.00 0.00 6,604.00 -711.63 1,135.60 5,981,186.33 541,149.41 70°21'34.283 N 149°39'56.758 W -plan misses target center by 0.23usft at 7527.66usft MD(6604.22 TVD,-711.64 N,1135.52 E) -Point 1G-04 CTD Polygon Sot 0.00 0.00 0.00 -154.30 710.53 5,981,741.33 540,721.41 70°21'39.765 N 149°40'9.184 W -plan misses target center by 6638.80usft at 7400.O0usft MD(6612.27 TVD,-585.66 N,1117.41 E) -Polygon Point 1 0.00 0.00 0.00 5,981,741.33 540,721.41 Point2 0.00 -180.80 148.06 5,981,561.34 540,870.42 Point3 0.00 -361.35 248.12 5,981,381.35 540,971.43 Point4 0.00 -698.69 305.34 5,981,044.35 541,030.44 Point 5 0.00 -966.49 261.92 5,980,776.35 540,988.46 Point 6 0.00 -1,232.89 142.49 5,980,509.34 540,870.47 Point7 0.00 -1,637.27 16.34 5,980,104.33 540,746.49 Point8 0.00 -1,723.86 315.91 5,980,019.35 541,046.49 Point9 0.00 -1,166.02 545.89 5,980,578.36 541,273.46 Point 10 0.00 -683.25 600.45 5,981,061.36 541,325.44 Point 11 0.00 -276.74 512.59 5,981,467.36 541,235.42 Point 12 0.00 -53.10 395.76 5,981,690.35 541,117.41 Point 13 0.00 124.69 250.69 5,981,867.34 540,971.40 Point 14 0.00 0.00 0.00 5,981,741.33 540,721.41 9/11/2014 1:47:47PM Page 4 COMPASS 5000.1 Build 61 FA ConocoPhillips Planning Report s HUGHES Database: EDM Alaska Prod Local Co-ordinate Reference: Well 1G-04 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1G-04 @ 90.00usft(1 G-04) Site: Kuparuk 1G Pad North Reference: True Well: 1G-04 Survey Calculation Method: Minimum Curvature Wellbore: 1G-04L1-03 Design: 1 G-04 L 1-03_wp02 1G-04L1-03_T06 0.00 0.00 6,602.00 -1,617.71 948.73 5,980,279.36 540,967.40 70°21'25.373 N 149°40'2.225 W -plan misses target center by 0.03usft at 8472.36usft MD(6602.01 ND,-1617.72 N,948.76 E) -Point 1G-04L1-02_Faultl 0.00 0.00 0.00 -1,518.96 996.27 5,980,378.36 541,014.40 70°21'26.344 N 149°40'0.835 W -plan misses target center by 6595.79usft at 8360.00usft MD(6595.76 TVD,-1509.75 N,979.05 E) -Rectangle(sides W345.00 H1.00 D0.00) 1G-04L1-03_T04 0.00 0.00 6,595.00 -1,335.22 1,048.26 5,980,562.35 541,065.40 70°21'28.151 N 149°39'59.314 W -plan misses target center by 2.27usft at 8171.86usft MD(6597.26 ND,-1335.31 N,1048.41 E) -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 8,675.00 6,608.16 2-3/8" 2-3/8 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 7,150.00 6,640.04 -354.24 1,029.62 TIP/KOP 7,250.00 6,629.60 -443.65 1,073.01 Start 7 dls 7,320.00 6,620.87 -508.86 1,096.86 3 7,520.00 6,604.51 -704.02 1,134.89 4 7,600.00 6,601.97 -783.31 1,144.98 5 7,750.00 6,598.28 -932.54 1,157.43 6 7,900.00 6,596.32 -1,081.58 1,142.57 7 8,030.00 6,596.81 -1,206.75 1,107.99 8 8,160.00 6,597.30 -1,324.90 1,054.10 9 8,260.00 6,596.47 -1,415.04 1,010.96 10 8,360.00 6,595.76 -1,509.75 979.05 11 8,430.00 6,598.78 -1,577.23 960.78 12 8,500.00 6,603.67 -1,643.84 939.87 13 8,675.00 6,608.16 -1,813.42 898.28 Planned TD at 8675.00 9/11/2014 1:47:47PM Page 5 COMPASS 5000.1 Build 61 0 N IV vl ,.. N N 8 S p ooN r N O hol MN O t N F• _GoI ch V c J I g NO N lz l "f4Q c co I m oQ � 4 I h .N$ - Y g , CFV � . - - /, I 1 I V . Q / O ,, L O .N o- " 1 v E-, 5O 'O rl I o . eo 0. I 1 I p �./ Q .a 7 C 1 O 2 d g N of _ •.. m .. O f!:1 1 0 �� O / 4 A .. 0.I O �N�� 1 siiiit N ;i:4, .'1�^ II, ate+ C7 y c'ill y F `Y O w� O I - .N dad - 3 4 o V 11,&i1 4 _ , CI>=Q'� yUy Gr.r/ I III 8 l -a .b g�V O II �D 9 :O 1 b> 0 -Co g Q 'o - ,t ghO \ - / I 1 , IMc X9O MpOI o -N 7,_ • N , ¢o C .O_ a V C ' O ,J 0 0 b 00 S M O C7`r C7 U o '� r.....n N •O O F mop p p o UJ n C h O o 8 0 8 0 o 8 o 8 O O o f) 0 O eC^ q �O ,- O. O N en 'O 00 Oa O .o en F - (ui/lJsn oc i)(+)t{uoN/(-)�noS ___ - tel O] 0 - -Q .N Cd d ,I :o .0 0 - - h o tm t^p ..t .o 0 z°m N2 M O '� �° vu�iQ am 10 -Cl .p, U v 4gi c ,n 0 I u •O fi s 'mom ga'o v c •o, a) E cap iaOr 0 _n a O O Y .- C J C Q. .�.. O r CV 01 A • N O N .2 r- C,nOrNo r 0- b y . O y o v a F o}f U to Co N C Co,i l r N C C0 - O O N- O C CO N 0 r M M r r r C N N r V 'r C M N Q O o CD M CA CD r CO 0 M r r V N v r r CO N M o N ' A O •D Z r CO CO N M C,O Co r r CO Co 0 co 6e M C D Co COi 0000 Co 000000000 I ,O O J N _O O O O N O r C t D C O M O CO G n ]9 J H r o-N o CO oNNN co CO Va ,0 0 0 Q r -cr • O �O O O O 0 0 0 0 0 0 0 0 0 0 Y Ce a- o- N al o 0 0 0 0 0 0 0 0 0 0 0 0 0 s.. ,-4 or 1N-r-rrrrrrrrN o ` ` Oa Q O Q'Q N Co Co co M r Co co Co,n CO r co YY• �e-N , CD O CO C,CIO o O r CO N Co O LU Co M CoC C r CV r C6 Co Co 6N ei .d. d 3 01 M +O ro c.OMC,t)C Co Co 0 o o o Co en aN3A°cr N O O. d 0/1. 1 W I- N C...n c..0 N r C N Lo C0 M C N N J 0 _N CD NOM to 0 r N O r N N C o C < 0 2 C M co C M N r 6C Co Co r M M - ± on C O O co M co Co N r Co r C r LU 7r M V Co r r Co Co N M V Co Co Co Co N a In C J o J 0 C Co r r co N O r co Co r Co O E 1.L1 a CO CPI 0 N M co M c r r co - On N >j Coo-CoN Co o o Co Co Co m Co Co Co o Co 0 L CO -a?,Co CND CCoo CND Co tC0 Co Co Co Co Co Co Co ,- s= r 0 O) '- e-co M co co 0 Co Co Co Co CO Co r z 00 aCo C MCal o C o CO O rrrr NO o r N Cfl T Co Co Co Co N Co,f1 6 r Oi 00 DtDNooON000CoCo � . ._ VI CY) O o CO r r C r N Co 0 r r M Co Co M C 0 0 LL C N r r NCC r C r CO O)O 0,r C r r N QOO Co 0 Co Co Co Co Co Q 0 o010,0 l )o Noo N CO No OC - J \ o W a000000ooooooo0 O + 00000000000000 o Co Co 0 o Co Co 0 o o o 0 o Co 0en oC 00C r C C o Co CAN N Co CoLo M Co Co M Or rN M CO Co N-Co Co mN N-.Cr Co CO en V 0 YO N N e U r r r r r r CO Co Co CO CO CO (O 0 C N c O U,-N M c-C as r N o 0 r N M C O zz o , (u►/ijsn oL)g1daQ lua[uan anij ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1G Pad 1G-04 1G-04L1-03 1 G-04L1-03_wp02 Travelling Cylinder Report 10 September, 2014 FAIN BAKER HUGHES 1 p • ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1G-04 Project: Kuparuk River Unit TVD Reference: 1G-04 @ 90.00usft(1G-04) Reference Site: Kuparuk 1G Pad MD Reference: 1G-04 @ 90.O0usft(1G-04) Site Error: 0.00usft North Reference: True Reference Well: 1G-04 Survey Calculation Method: Minimum Curvature Well Error: 0.O0usft Output errors are at 1.00 sigma Reference Wellbore 1G-04L1-03 Database: EDM Alaska Prod Reference Design: 1G-04L1-03_wp02 Offset TVD Reference: Offset Datum 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 3S Pad 3S-08C Doyon 141-3S-08C-3S-08C-to delete in Out of range Kuparuk 1G Pad 1G-01-1G-01-1G-01 Out of range 1G-02-1G-02-1G-02 Out of range 1G-03-1G-03-1G-03 Out of range 1G-04-1G-04L1-02-1G-04L1-02_wp04 7,150.00 7,150.00 0.00 0.22 -0.22 FAIL-Minor 1/10 1G-05-1G-05-1 G-05 Out of range 1G-06-1G-06-1G-06 Out of range 1G-07-1G-07-1G-07 Out of range 1G-08-1G-08-1G-08 Out of range 1G-08-1G-08A-1G-08A Out of range 1G-08-1G-08PB1-1G-08PB1 Out of range 1G-09-1G-09-1G-09 Out of range 1G-10-1G-10-1G-10 Out of range 1G-10-1G-10A-1G-10A Out of range 1G-10-1G-10B-10-10B Out of range 1G-10-1G-1OBL1-1G-1OBL1 Out of range 1G-10-1G-1OBL2-1G-10BL2 Out of range 1G-10-1G-1OBPB1-1G-10BPB1 Out of range 1G-11-1G-11-1G-11 Out of range 1G-12-IG-12-1G-12 Out of range 1G-13-1G-13-1G-13 Out of range 10-14-10-14-10-14 Out of range 10-15-10-15-10-15 Out of range 1G-16-1G-16-1G-16 Out of range 1G-17-1G-17-1G-17 Out of range Plan:1G-18-Plan 1G-18-1G-18(wp02) Out of range Plan:1G-19-1G-19-1G-19(wp02) Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 9/10/2014 4:51:12PM Page 3 of 6 COMPASS 5000.1 Build 61 OR Bettis, Patricia K (DOA) PTD 91'7' -/413 From: Ohlinger, James J <James.J.Ohlinger@conocophillips.com> Sent: Friday, September 19, 2014 2:04 PM To: Bettis, Patricia K (DOA) - — Subject: RE: KRU 1G-04L1-02 ander-04L1-03: Pe it to Drill Applications Under the1/4 Mile review for the 1G-04 CTD laterals: Wells 1G-09 and 1R-01 are within the 1/4 mile for the 1G-04L1 and 1G-04L1-01 laterals. There are no wells within the1/4 mile for the 1G-04L1-02 and 1G-04L1-03 laterals. From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Friday, September 19, 2014 1:50 PM To: Ohlinger, James J Subject: [EXTERNAL]KRU 1G-04L1-02 and 1G-04L1-03: Permit to Drill Applications Good afternoon James, The quarter mile injection review submitted with the application applied to KRU 1G-04L1 and KRU 1G-04L1-01. As KRU 1G-04L1-02 and 1G-04L1-03 will be drilled to the south, a new quarter mile review along with a spider map showing all wells within a quarter miles of KRU 1G-04L1-02 and 1G-04L1-03 needs to be submitted. This information may be sent to me via e-mail. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettisCc@alaska.gov. 1 Bettis, Patricia K (DOA) From: Bettis, Patricia K(DOA) Sent: Friday, September 19, 2014 1:50 PM To: Ohlinger,James J (James.J.Ohlinger@conocophillips.com) Subject: KRU 1G-04L1-02 and 1G-04L1-03: Permit to Drill Applications Good afternoon James, The quarter mile injection review submitted with the application applied to KRU 1G-04L1 and KRU 1G-04L1-01. As KRU 1G-04L1-02 and 1G-04L1-03 will be drilled to the south, a new quarter mile review along with a spider map showing all wells within a quarter miles of KRU 1G-04L1-02 and 1G-04L1-03 needs to be submitted. This information may be sent to me via e-mail. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME: l�j�(J�, I G -O`1 L. I - o3 PTD: oC ) L — P-13 _Development Service Exploratory _Stratigraphic Test Non-Conventional FIELD: 11 1/4.k Z\J&r- POOL: I 4 &I �.u- I 4 "JL 0j, I Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit / (If last two digits No. IS Z— I(Q ( , API No. 50- O -c,203,5- _ 06- QO. ✓ in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. 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 name Pilot Hole ( 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 Spacing Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are Well Lo ,n also required for this well: gg g 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 4/2014 (a N a) 0 u) N N E u 0 _o m ma) d c 2 Q0 ,--7-.a c_) L C oo N m O) N C_ C m C N "00 0 (O/) co v Coc m o o - o u 0 m O .'`D o co E a W L pco a c m Co o c o m o a o. E OQo o ao X co ai c 'C 4) O co W "0 0 us O L J 0) C) c0 C CL ° 3 v Coa N m 4 '� O O a a O Co 00 N -0 — c U -0 a o 0 0 0 = m 0 2 a) (0 c o r D N3 °d •5 .- — Q a a) o -r.) o Y o 3 m — ac) '- Q W O) a a) c _0 a) co — M N o_ _c = (0 c = 3 a) Co O D o L N c o 0 a Y 3 m 3 o c o 0 c Too c n 0 2 v o a 3 o N a J C C C Co cu E 4- 0. 'C a) 0 N- O N c LA N H 0 o a Co o ate) .3 o Co o M U (N n E Z > o C ate) n o .N B o • h. 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