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215-031
, STATE OF ALASKA AL 1(A OIL AND GAS CONSERVATION CON,,.,ISSION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redd! r Perforate New Pool Repair Well ," Re enter Susp Well r Other: Prod to WAG 017 2.Operator Name. 4 Well Class Before Work. 5. Permit to Drill Number. ConocoPhillips Alaska, Inc. Development r Exploratory r 215-031-0 -- 3.Address: 6.API Number: Stratigraphic r Service r P. 0. Box 100360,Anchorage,Alaska 99510 50-029-21796-62 7. Property Designation(Lease Number): 8.Well Name and Number. ADL 025513,ADL 025520 KRU 30-16BL2 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 10141 feet Plugs(measured) 7688 true vertical 6463 feet Junk(measured) 6358 Effective Depth measured 10141 feet Packer(measured) 0 true vertical 6463 feet (true vertical) 0 Casing Length Size MD TVD Burst Collapse Conductor 79 16 115 115 Surface 2340 9 625 2375 2215 Tieback 1028 7 1061 1061 Casing Patch 110 6 089 1121 1121 Liner 260 4 7947 6531 BL2 LINER-SLOTTED 2315 2.625 10141 6463 , „ ti rk cD Perforation depth: Measured depth: 7826-10139 i`J l 3 2 i True Vertical Depth: 6468-6519 5 AOGCC O VC Tubing(size,grade, MD,and TVD) 4.5x5, L80, 7695 MD,6364 TVD ° SO* Packers&SSSV(type, MD,and TVD) Baker 2RH ZXP Liner Top Packer 7688 MD 6358 TVD SSSV=Nipple 7636 MD,6316 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 128 39 358 120 90 Subsequent to operation 825 850 1030 14 Attachments(required per 20 AAC 25 070,25 071,&25 283) 15.Well Class after work: Daily Report of Well Operations p Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work• Oil r Gas r WDSPL r Printed and Bectronic Fracture Stimulation Data r GSTOR r WINJ r WAG p 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 315-441 Contact Darrell Humphrey/Bob Christensen Email n1139@_conocophillips.com Printed Name '•.e D Christensen Title NSK Production Engineering Specialist Signature .'/i' ./,/�n hone:659-7535 Date Wstk/ /L/IL/1O ic v-77_ 4/z//, RBD AUG - 2 2015 Form 10-404 Revised 5/2015 y.271)-- Submit Original Only - 30-16BL2 DESCRIPTION OF WORK COMPLETED SUMMARY 07/14/15 (AC EVAL) : MIT-IA(PASSED)TO 2500 PSI. Initial T/I/O = SI 700NACNAC. IA FL @ 36' (600 fps, decimeter), 0.6 bbls fill up volume. Pressured IA to 2500 psi w/3.1 bbls diesel. Starting T/I/O = 725/2500NAC. 15 min T/I/O = 725/2410NAC. (-90) 30 min T/I/O = 725/2400/VAC. (-10). (PASSED). Bled IA to 100 psi (fluid) in 10 min. Final T/I/O = SI 700/100/VAC. 07/27/15 Open well to WAG injection service KUP PROD 30-16BL2 ConocoPhillips ` Well Attributes Max Angle&MD TD Alaska Inc, xltAllke Wellbore API/UWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Btm(ftKB) coarva x 500292179662 KUPARUK RIVER UNIT PROD 97.67 8,285.47 10,141.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 30-16BL2,5/19/20153:1829 PM SSSV:NONE Last WO: 34.98 4/23/1988 Vertcalschematc(aowal) - - Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;33 0 tt•.^I Last Tag: Rev Reason:ADD SIDETRACK B.ADD smsmith - LATERALS L1&L2 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SL2 LINER-SLOTTED 2 3/8 1.992 7,825.6 10,141.0 6,462.5 4.60 L-80 Hyd511 Liner Details Nominal ID MN./1 Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 7,825.6 6,467.4 45.52 BILLET SHORTY DEPLOYMENT SLEEVE 1.000 ALUMINUM BILLET CONDUCTOR;36.0-115.0 Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com__ 7,826.4 8,303.4 6,468.0 6,519.0 A-1,30- 4/19/2015 SLOTS Slotted Liner 16BL2 8,305.2 10,139.0 6,518.8 6,462.4 A-1,30- 409/2015 SLOTS Slotted Liner TIEBACK;33.0-1,060.7 16BL2 Notes:General&Safety CASING PATCH;1,011.4- End Date Annotation 1,121.0 12/11/2014 NOTE WORKOVER 3/12/2015 NOTE:WELL SIDETRACKED TO B,ADD LATERALS L1&L2 SURFACE;35.0-2,3749=� NIPPLE;7,635.8 c 0 XO Enlarging(Tubing);7,683.7 .' LOCATOR;7,684.5 x:. SEAL ASSY;7,8856 • kelk gho 56 WHIPSTOCK;7,775 0 WINDOW;7,775.0-7,788.0 18 j _;- moi V IPERF;7,794.0-7,804.0 ;-S: WHIPSTOCK;7,798.0 I I I1$ All PLUG;7,829.0 !PERF;7,838.0-7,848.0- p�4Vt�"y1IAPERF;7,838.0-7,859.0- WINIPDEORWF;77,8550 -77,80I 5s WHIPSTOCK;7,852.0 - I, !;1 XI • l - APERF;7,867.9-7,872.0is, Ar - \':! 57 IPERF;7,869.0-7,889.0-, WHIPSTOCK;7,875.0 -- ,y WHIPSTOCK 7,900.0 _nr, ✓_ APERF;7,908.0-7,928.0-- ', ; V ,y. .✓ LINER;7,687.5-7,947.3 Si' " I"✓.� SLOTS;7,826.4A-8,303.4 y: B LINER-SOLID;7,726.6- L I 8,900.0 SLOTS;8,305.2-10,139.0 BL2 LINER-SLOTTED;7,825.6 0,141.0 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. r_1,5 - 03_1 Well History File Identifier Organizing (done) Two-sided ❑ Rescan Needed 7RE AN: OVERSIZED: NOTES: C r Items: ❑ M : Grayscale Items: Logs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: Maria Date: q 114115-s /s/ olp Project Proofing R BY: 412. Date: r G /s/ Scanning Preparation 3 x 30 = 61O + 15 = TOTAL PAGES I Os- ( Count does not include cover sheet) BY: Date: I /sl Production Scanning Stage 1 Page Count from Scanned File: l 06 (Count does include cove heet) PageScanning Count Matches Number in Preparation: YES NO BY: CD Date: //til5" /s/ mf Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. 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Z N 0 N Z � C ~ co Z C co O N o O a) 4 0 0 4 O ❑ w C U 0 0 0 0 0 0 0 0 C n •0 •v O) Ja N y •2• 0 E O E o 0 0 E o LL 2 N a M w w W 0 0 w w w 3 F. 0 d 0 0 0 c 0 O O N N CO M 6 O N. Z p N E e) U_ o 01 _ N 1/) O �+ _ Z .----'1 E-- F. Q Z_ 0 Q V SE Z_ 1 7 N (/) i1 To F. ci) G IX a O coa Cl. J LU = Ce V W Z z z V 0 C7 Z V Q « is N 7 J o0. w a. co O c N O M p en V O) N V O J m Q coc H o a I- I Z o E n N W ce N a CI) ca0 Q Y i Q C0. Z A o to z m 3 M co co o p >, e7 > m o Lo d N 0 d D cci OO C C.J w to v E O• CI O ZS 2 c.) L IO-Ub/ 3V-lbti Lbl/3 215-057 30-16BPB1 26174 215-057 30-16BPB2 26175 215-030 30-16BL1 26127 BAKER PRINT DISTRIBUTION LIST >215-0311 30-16BL2 26128 HUGHES Please sign and return one copy of this transmittal form to: COMPANY ConocoPhillips Baker Hughes INTEQ (mandatory) 795 East 94th Avenue DATA LOGGED 9/1, /2015 WELL NAME 30-16B; 16BL1; 16BL2; 16BPB1; 16BPB2 Anchorage,Alaska 99515 M.K.BENDER (mandatory) FIELD Kuparuk River Unit to acknowledge receipt of this data. (mandatory) COUNTY North Slope Borough LOG TYPE LWD-Coil (mandatory) (mandatory) STATE Alaska BH DISTRICT Alaska (mandatory) (mandatory) LOG DATE: April 4,2015 TODAYS DATE: 21-Aug-15 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: Patrick Rider EMAIL: 3trick.rider(c�bakerhughes.co (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? No COMPANY FIELD FINAL CD Final CD ADDRESS(FEDEXWILL NOT DELIVER TO P.O.BOX) LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #01-NNKIN I S #OF COPIES #OF COPIES#OF COPIES v V V V V V 1 ConocoPhillips Alaska Inc. Attn:Ricky Elgaricio ATO 3-344 700 G Street Anchorage,AK 99510 2 BP Exploration(Alaska)Inc. I 1 E I E Wer. Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. AUG2 6 2i s.i Anchorage,Alaska 99508 Attn:Dodie Stinson 3 Chevron/KRU Rep 1 1 Apqcri1 I Attn:Glenn Frederick P.O.Box 196247 Anchorage,AK 99519 4State of Alaska -AOGCC 1 1 I 1 2 1 I Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5IDNR-Division of Oil&Gas *** I I 1 I 1 Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR TOTALS FOR THIS PAGE: 0 3 4 4 4 0 TOTALS FOR ALL PAGES: 0 3 4 4 4 0 r 00M O r- In lD Cal SI SAA_ Q= M Li N Om two c p ■ t as O Q as W W a ,, i z a) ,_• 1 MEI U, — •- — O a = � N = a� a, a to = V O , o 0 V oc CO N L.. ._ c 0 O Y Y J N c N lJ � t0 O aa � o (6 N V Y Y CO D N § Z © ` �0o j § '▪ - ° s _ 0a kk \ ! � CV CV CV 0 u7 LO cr) ,- - � ] ¥ ¥ ¥ ( u. i 00 Dad k � ( \ 4 U) t � � 3 \ § \ \ \ ) ca C CO §0 ° ( ( j co E a \ / ° $ ¥ £ 2 C § $ G E co £ a o 2 - - 2 ~ k co f f k ( ( / / 8 \ ) j ) \ \ / \ ) ® • _ © + 0 2 2 t , _ * 0 / 2 » , { $ f \ 4 06 IX ° $ § 2f E > } a 2DD Lcv O , 2 & 6 A .. o ct 0 _ f i B O . \ / o I K ) A : { J \ k F ° % ! # / 9 E 8 z § ] 2 z a a - . 7 § e _ \ \ \ \ ( — C k { ) a 2 2 • & co c $ to m 0 Lo * 0. ■ & k El • / / A CO e /) / \ ) / 4) 0 0 0 | g [ To 0.\ ( )rCS i 0 0 = iii k / ,-) �{ ( \ \ \» g u ) ) \§ E ry kri / } § a a • i § f 9 # ) ( co Lo ) ) ] e ) ) 2 ) § 7 9 ( 17 § ( '" o co 2 9z7 — — < < CO ) } } ( \ ( 2 i� :c- E o . @ - ] - . 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(mandatory) COUNTY North Slope Borough LOG TYPE LWD-Coil (mandatory) (mandatory) STATE Alaska BH DISTRICT Alaska (mandatory) (mandatory) LOG DATE: April 4,2015 TODAYS DATE: 17-Aug-15 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: Patrick Rider EMAIL: 3trick.rider(cr�bakerhughes.co (mandatory) HAS CLIENT;$EEN INVOICED FOR ADDITIONAL PRINTS? No COMPANY FIELD FINAL CD Final CD ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #01-PKIN I S #OF COPIES #OF COPIES#OF COPIES 2 BP Exploration(Alaska)Inc. Petrotechnical Data Center,LR2-I 900 E.Benson Blvd. Anchorage,Alaska 99508 Attn:Dodie Stinson 3 Chevron/KRU Rep 7 1 1 Attn:Glenn Frederick P.O.Box 196247 Anchorage,AK 99519 4 State of Alaska -AOGCC I 1 1 2 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5,DNR-Division of Oil&Gas *** I 1 j Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR TOTALS FOR THIS PAGE: 0 3 4 4 0 TOTALS FOR ALL PAGES: 0 3 4 4 0 s- ►O CO O CV LC . H Cwt 1111 All�_ `W; sz6 N 0 NNE‘ c :a it. c. tisD iii; o N 0- M W .0 L6 ' co tO 0. Wre a F— ,, t. z 2 •- ._ — s — 0 � _ Q as a `° U O _ ' 0 in+ r v M N .— O C O -NC ,C J Na) N to 0 7 m rl co co IN ._ _ U O as - o RS a V Y Y 0 n I 1 III M Z ® All ...Lila ii \ \ • 2 . e » CO ii / & \ \ E (3 N - � ] ¥ 4 @ \ i \ k � � ( ) Co� 3 3 \ ___1-- 7-1).. 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V d co ci co N Q SOF T� Iy/js THE STATE Alaska Oil and Gas ofAConservation Commission LASKA 333 West Seventh Avenue \Th' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1 433 OFLAS*P' Fax: 907.276.7542 www.aogcc.alaska.gov Darrell Humphrey p Y NSK Production Engineering Specialist ConocoPhillips Alaska, In ( 031 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 30-16BL2 Sundry Number: 315-441 Dear Mr. Humphrey: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this 2 , day f July, 2015 Encl. STATE OF ALASKA RECEIVED A. ,KA OIL AND GAS CONSERVATION CONI SION• IUL 2 1 2015 APPLICATION FOR SUNDRY APPROVALS � 7/z')15 20 AAC 25.280 AOGCC 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Suspend r Perforate E Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Prod to WAG 2 Operator Name. 4.Current Well Class: 5.Permit to Drill Number. ConocoPhillips Alaska, Inc. ' Exploratory r Development r • 215-031-0 t 3.Address. 6.API Number. Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-21796-62 - 7. If perforating, 8 Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception'? Yes r No p 1 KRU 30-16BL2 • 9 Property Designation(Lease Number): 10.Field/Pool(s) ADL 025513,ADL 025520 • 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). 10141 - 6463 • 10141' • 6463' - None None Casing Length Size MD TVD Burst Collapse BL2 LINER-SLOTTED 2315 2 625 10141' 6463' Perforation Depth MD(ft): Perforation Depth TVD(ft). Tubing Size. Tubing Grade Tubing MD(ft). 7826-10139 • 6468-6519 4.5x5 L80 7695 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) Baker 2RH ZXP Liner Top Packer 7688 MD,6358 TVD, SSSV=None 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' 7/21/2015 — OIL r WIND r WDSPL r Suspended r 16.Verbal Approval. Date: GAS r WAG F - GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 1 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact. Darrell Humphrey/Bob Christensen Email. ni'I 39(a�conocophillips.com Printed Name Darrell Humphre Title: NSK Production Engineering Specialist Signature -•�v p 1 Phone:659-7535 Date 1./7, )5. Comm ssion Use Only Sundry Number: Conditions of approval. Notify Commission so that a representative may witness 315" 'f'i,1 I Plug Integrity r BOP Test r Mechanical Integrity Test IF Location Clearance r Other. i ir- d Gr r l`rr = I fib& l!T CI I -t )lG f"I An --71-01-tt 71,1-,-17-55z-G/ N/ Cr— (it re-.3 Spacing Exception Required? Yes ❑ No rr Subsequent Form Required: /6, - 4U 4_ APPROVED BY Approved by' ,1k....4.-1� COMMISSIONER THE COMMISSION Date —2-1F/5 1/'TL 7/7 ) /5 Approve a li ti n isNidAr 12 months fromthe date of approval. Submit Form and Form 10-403 Revised 5/2015 L 712i S AttachmenA Duplicate ,�. 7/kir---- RBDMS. \k AUG - 7 cmc • 30-16BL2 DESCRIPTION SUMMARY OF PROPOSAL ConcoPhillips Alaska Inc. requests approval to convert Kuparuk well 30-16B (PTD#215-057-0)from a Pre- produced >30 days Oil producer back to WAG Injection service.. The conversion to injection service is required to provide reservoir pressure support to offset producers 3N-17 and 30-11. The 9-5/8" Surface casing (2375'md/2215'tvd)was cemented with 900 sx AS III Lite followed by 300 sx ASII and 100 sx AS I. The 7" Production casing (8201'md/6678'tvd)was cemented with 700 sx TLW and 300 sx Class G and 175 sx AS I. The top of the Kuparuk C sand was found at 7775' and/6429' tvd. The top of the Kuparuk A sand was found at 7963' and/6418'tvd. The CBL, dated 12/18/14, identified a cement top of approximately 1060' RKB. The CBL was run to a depth of approximately 7420' RKB and indicated good cement for the entire interval from 1200' to 7420' RKB. 7/14/15: MIT-IA to 2500 psi - Passed KUP PROD 30-16BL2 • ConocoPhillips 41& Well Attributes Max Angle&MD TD Alaska,ipC. Wellbore APIIUWI Field Name Wellbore Status Ind(°) MD(ftKB) Act Btm(658) 500292179662 KUPARUK RIVER UNIT PROD 97.67 8,285.47 10,141.0 • Comment H2S(ppm) Date Annotation End Date KB-God(ft) `Rig Release Date 30-16BL2,5/1920153:18:29 PM SSSV:NONE - Last WO: 34.98 4/23/1988 Verbal sch000tc(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;33.0 VEVA LATERALS Tag: Rev Reason ADD SIDETRACK 8,ADD smsmith LATERALS L1 8 L2 Casing Strings Casing Description OD(in) ID(i n) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread BL2 LINER SLOTTED 2 3/8 1.992 7,825.6 10,141.0 6,462.5 4.60 L-80 Hyd511 Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(') Item Des Com (in) 7,825.6 6,467.4 45.52 BILLET SHORTY DEPLOYMENT SLEEVE 1.000 ALUMINUM BILLET CONDUCTOR,36.0-115.0 .- Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shotslf Top(ftKB) Btm(MKB) (MKB) (ftKB) Zone Date t) Type Com 7,826.4 8,303.4 6,468.0 6519.0 A-1,30- 4/19/2015 SLOTS Slotted Liner 16BL2 8,305.2 10,139.0 6,518.8 6,462.4 A-1,30- 4/19/2015 SLOTS Slotted Liner TIEBACK;33.0-1,0607 16BL2 Notes:General&Safety CASING PATCH;1,011.4- End Date Annotation 1,121.0 12/11/2014 NOTE:WORKOVER 3/12/2015 NOTE:WELL SIDETRACKED TO B,ADD LATERALS L1&L2 SURFACE;35.0-2,3749 NIPPLE;7,635.8 00 Enlarging(Tudrg);7,683.7 LOCATOR;7,684.5 SEAL ASSY;7,685.6 `J ` I ' �9Ev N.:11R v NV'' ',✓ WHIPSTOCK;7,775.0 WINDOW;7,775.0-7,7880 \y' No v, 44 _\ _ (PERF;7,794.0-7,804.0 _ ),y WHIPSTOCK;7,786.0 �� '✓ PLUG;7,829.0 .�.,—-✓, IPERF;7,838.0-7,848.0 APERF;7,838.0-7,859.0 : IPERF;7,850.0-7,860.0 ,. WINDOW;7,852.0-7,857.0 u''. ;A WHIPSTOCK;7,852.0 u., ,4' -- APERF;7,867.0-7,872.0— `.. IPERF;7,869.0-7,889.0-, WHIPSTOCK;7,875.0 WHIPSTOCK;7,900.0 . , APERF;7,905.0-7,928.0— .\`•! ;V LINER;7,687.5-7,947.3 .)' 11.. SLOTS;7,826.4-8,303.4— B LINER-SOLID;7,726.6- 8,900.0, SLOTS;8,305.2-10,139.0— i I BL2 LINER-SLOTTED;7,825.6 -10,141.0 RECEIVED JUL_ 2 2 5 Darrell Humphrey/Robert Christensen Production Engineering Specialists. IIPPV C Greater Kuparuk Unit,NSK-69 ox 19105 :onocoPhilhps ���� Anchoage6AK 99519-6105 Phone:(907)659-7535 Fax:659-7314 July 17, 2015 Dan Seamount AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 33 W. 7th Ave. Ste. 100 Anchorage, AK 99501 Dear Mr. Seamount, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk River Unit well 30- 16B, 30-16BL1, 30-16BL2 from Oil Production to WAG Injection service. Enclosed you will find 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 30-16B and it's associated laterals (PTD#215-057, 215-030, 215- 031). If you have any questions regarding this matter, please contact myself or Robert Christensen at 659-7535. Sincerely, Darrell Humphrey Attachments Sundry applications Well schematics 1/frClf l "e ,rod/ ior COQ ve4/°4 STATE OF ALASKA t-s,rNSKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed Suspend r Perforate r Other StimulateAlter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool rRepair Well r Re-enter Susp Well r Other:WAG to PROD r 2.Operator Name. 4.Well Class Before Work. 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 215-031-0 3.Address' 6.API Number: Stratigraphic r Service pi P. 0. Box 100360,Anchorage,Alaska 99510 50-029-21796-62 7. Property Designation(Lease Number)• 8.Well Name and Number. ADL025513;ADL025520 KRU 30-16BL2 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 10141 feet Plugs(measured) None true vertical 6463 feet Junk(measured) None Effective Depth measured 10141 feet Packer(measured) true vertical 6463 feet (true vertical) Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115 115 SURFACE 2340 9 625 2375 2215 TIEBACK 1028 7 1061 1061 CASING PATCH 110 6 089 1121 1121 RECEIVED LINER 260 4 7947 6531 BL2 LINER-SLOTTED 2315 2.625 10141 6463 JUN 0 8 2 015 Perforation depth. Measured depth: 7826'- 10139' > OGCC True Vertical Depth: 6468'-6519' Tubing(size,grade,MD,and ND) 4-1/2 x 5, L-80, 7695 MD, TVD Packers&SSSV(type,MD,and ND) Packer=BAKER"2RH"ZXP LINER TOP PACKER Packer @ 7688' md, 6358' TVD SSSV=None 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 682 481 2463 900 169 14.Attachments(required per 20 AAC 25 070,25 071,&25 283) 15.Well Class after work. Daily Report of Well Operations r:. Exploratory r Development I- Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work. OiI Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C O.Exempt N/A Contact Darrell Humphrey/Bob Christensen Email n1139conocophillips.com Printed Name Rob= D. Christensen Title NSK Production Engineering Specialist Signature / 41111,&, Iri alone:659-7535 Date LI ib 1/77_ 7/9//5- , / 475---- RBDMS J"N 1 1 2015 Form 10-404 Revised 5/2015 Submit riainal Only 30-16BL2 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 05/03/15 Commence Injector pre-production > 30 days 4 KUP PROD 30-16BL2 • ConocoPhillips 01Well Attributes Max Angle&MD TD ) Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status ncl 7) MD(ftKB) Act Ern If1KB) cc.„ ,ypR 500292179662 KUPARUK RIVER UNIT PROD 97.67 8,285.47 10,141.0 1 --- 4Y Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 30-16BL2,5/19/2015 3.18:29 PM SSSV:NONE Last WO. 34.98 4/23/1988 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date _- -- HANGER:33.0 P..p!§ll - - Last Tag: Rev Reason:ADD SIDETRACK B,ADD smsmith LATERALS L1 8 L2 Casing Strings Casing Description OD(in) 113(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread BL2 LINER-SLOTTED 2 3/8 1.992 7,825.6 10,141.0 6,462.5 4.60 L-80 Hyd511 - Liner Details Nominal ID MA. LT Top(flKB) Top(TVD)(ftKB) Top Incl(..) Item Des Com (In) 7,825.6 6,467.4 45.52 BILLET SHORTY DEPLOYMENT SLEEVE 1.000 ALUMINUM BILLET CONDUCTOR;36.0-115.0- - Perforations&Slots shot Dens Top(TVD) elm(TVD) (shots/f Top(fIKB) Btm(ftKB) (ftKB) (ftKB) Zone Dale t) Type Com 7,826.4 8,303.4 6,468.0 6,519.0 A-1,30- 4/19/2015 SLOTS Slotted Liner 16BL2 8,305.2 10,139.0 6,518.8 6,462.4 A-1,30- 4/19/2015 SLOTS Slotted Liner TIEBACK;33.0-1,060.7it: '..t 16BL2 Notes:General&Safety CASING PATCH;1,011.4- End Date Annotation 1,121.0 12/11/2014 NOTE:WORKOVER 3/12/2015 NOTE:WELL SIDETRACKED TO B,ADD LATERALS Li 8 L2 SURFACE;35.0-2,374.9 - NIPPLE;7,635.8 XO Enlarging(Tubing);7.683.7 ik LOCATOR;7684.5- SEAL ASSY;7,685.6 a 40 !ci i; WHIPSTOCK;7,775.0 si WINDOW;7,776.0-7,788.0At �, 'J Av I A _w; 5 _w .' IPERF;7,794.0-7,804.0-_ WHIPSTOCK;],]960 _`. �% N y.i '41, I VI PLUG;7,829.0 -.Iyl ' i't I (PERF;7,838.0-7,848.0- _1 APERF;7,838.0-7,859.0- . K" V' A IPERF;7,850.-7,860. WINDOW;7,852.00-7,851.00 \ t7t:' WHIPSTOCK;7,8520 At >N4 Ri ZV, :✓ APERF;7,867.0-7,872.0- `. 73; Ki IPERF;7,869M-7689.0, _;. '2 WHIPSTOCK;7,875.0 _;:b: WHIPSTOCK 7,900.0 N._N. 5 APERF;7,908.0-7,928.0- V, :✓ �v. �I LINER;7,687.8-7,997.3 �' _ SLOTS;7,826.4-8,303.4- B LINER-SOLID;7,726.6- 2 8,900.0 SLOTS;8,305.2-10,139.0- ' BL2 LINER-SLOTTED;7,825.6 -10,141.0 RECEIVED STATE OF ALASKA MAY 2 0 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND o la.Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAGE WDSPL❑ No.of Completions: Service 0 Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc.• Aband.: .4/20/2015 215-031 3.Address: 7. Date Spudded: 15.API Number: P. O. Box 100360,Anchorage,Alaska 99510 .4/17/2015 50-029-21796-62 . 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 1106'FNL,2060'FWL,Sec.22,T13N, R9E, UM •4/19/2015 02..0 30-16BL2 Top of Productive Interval: 9. KB(ft above MSL): 59' 17. Field/Pool(s): 1505'FSL,2082'FEL,Sec.21,T13N, R9E, UM GL(ft above MSL): 23' Kuparuk River Field/Kuparuk River Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 360'FSL,2323'FEL,Sec.21,T13N, R9E, UM 10141'MD/6463'TVD ADL 25513,25520 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 525698 y- 6021714 Zone-4 .10141'MD/6463'TVD 2554,2556 TPI: x- 521571 y- 6019032 Zone-4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 521336 y- 6017886 Zone-4 none 1636'MD/1612'TVD 5.Directional or Inclination Survey: .Yes Q(attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 na (ft MSL) . 7852'MD/6484'TVD 22. Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper, resistivity,porosity, magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary GR/Res ' 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM . HOLE SIZE CEMENTING RECORD FT. PULLED 16" 62.5# H-40 36' 115' 36' 115' 24" 175 sx AS I 9.625" 36# J-55 35' 2375' 35' 2215' 12.25" 900 sx AS III,300 sx AS II 7" 26# J-55 1062' 8201' 1062' 6778' 8.5" 700 sx TLW,300 sx Class G&175 sx AS I 4.5" 4.6# L-80 7826' 10141' 6471' 6463' 6" 15 bbls of 15.8'G'Neat 3.5" 9.3# L-80 7726' 8900' 6329' 6406' 4.25" 10 bbls 15.8 ppg 2.375" 4.7# L-80 7825' 10141' 6412' 6463' 3" slotted liner 24.Open to production or injection? Yes El No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 4.5" 7695' 7688'MD/6357'TVD slots from 7826-10141'MD 6471'-6463'TVD 26.ACID,FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Yes❑ No Q Per 20 AAC 25.283(i)(2)attach electronic and printed information ..j21-- DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED TED . - 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 5/16/2015 pre-produced injector Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 5/6/2015 15 hours Test Period ....O 410 283 1504 176 658 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 1R4 not available 24-Hour Rate - 762 502 2286 not available Form 10-407 Revised 5/2015 1./71. •//..//5"-- .,q- .//G //$- ONTINUED ON PAG 2 RBDM Submit ORIGINIAL only -"" 9S 7-INI JUL - 1 2015 28.CORE DATA Conventional Cor Yes ❑ No Sidewall Cores: ❑ No ❑✓ If Yes, list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results per 20 AAC 25 071 29 GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑✓ Permafrost-Top surface surface If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1636' 1612' Attach separate pages to this form, if needed,and submit detailed test information, including reports,per 20 AAC 25.071. Top Kuparuk Al 8758' 6474' Kuparuk Al 8956' 6489' Bottom Al 10141' 6463' NA Formation at total depth: Kuparuk Al 31. List of Attachments: Summary of daily operations,schematic,final directional survey,cement reports Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report, production or well test results,per 20 AAC 25.070 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact' Jason Burke @ 265-6097 Email. Jason.Burke@conocophillios.com Printed Name: Dan Venhaus Title: CTD Supervising Engineer Signature. y Phone: 2.6 3 -4/377Z Date. S'—1 V—tS / INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9 The Kelly Bushing 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 15: The API number reported to AOGCC must be 14 digits(ex.50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22. Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25 071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results, including, but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to.core analysis,paleontological report,production or well test results Form 10-407 Revised 5/2015 Submit ORIGINAL Only nu a '0 0 am � C m . N co Q co op Q m 0 (R-2 V N a) co 00 — NON co H m Ln J O c r-I �\ -) O 07 OOm Q >- sP a) N � O a -E 4 ca 0 c N _ 2 N N N y Eo `_ oQ o N c) o Co m N 1011 0Er) V CO Cr) 0 N coL Cn 0 d co r 9 C o ch co co m o _ �, O co C s., a 0as rs. rl O-O 3 N -o � c O c V Q� CO d (��co iii co 12- T 2.- V CO t N C O II �` rn J 0)cD 1.,V O J'. C V (B c Y O Q n. C co Q N __ CO co* -6 Q N = U c L a N a) c •- -" 0 3 LU X N N x h ON- — co 0 N N N m � LL V Lo Lo to DO U (ODN CO00 Nov :© J O N O ) J O a QL Mho A. C� O CO 0©Ha .0 Y N N coED 1 :1-1--• 4.4. 4•t•Y4., • +u •.•4.1.5i•4•t•t•44t 4•t•4`4.t•4.4, li t•ti.ti ti•4:titi.YRt•y1.4 4•t•4. : Q ,,,-...„.„:„..,:„..a.,...,...„:„......„..„:„...,:-.......%-,....-_,-.......-...........-...-...-...-...-...-,.1%. 1.ti ti ti t tiff J4:ti ti•L:S.i�L:4 1.l.f.tztt -az o o I m Zo0 NO a s O Co �2 � � rN CD W - u) 0 CO r co- It ©co a fid. > � :12 m ss 0 � � o = r M Q� is m 0 0 0 0 0 ,- 0 Nv Tzo -(% 1-.0 a i d O � � � � � � CON Lo (` co COLS OL[') N a 0) O L Ur OMoOMO N N- ,— u) , U r 0 - a_N- 0-1,-- N N r F \ U) mII a , , , ' Uv C - I 0 cn co r- CO L � 0. < NNNN 3L ;A PRE-RIG WELL WORK DATE SUMMARY 2/21/2015 Late start due to extended safety meeting, construction equipment blocking access and waiting on hardline rig up. RIH w/venturi to 7,710'Work venturi for a while and POOH. Job in progress. 2/22/2015 RIH with a Venturi w/burn-over shoe and make hole. Returned to surface with just a few pieces of rubber,teflon, but a soild 6' of cement. RIH next with a 3.70 mill and used 9.4 PowerPro Mud from CDR2 and worked down to 7,780'from an initial tag of 7,708'. Job in progress. 2/24/2015 RIH w/3.75"OD 5 Blade Inseted Mill to clean out cement. Mill from 7,752' CTMD down to 7,842'CTMD (7,862' RKB). Could not get past this depth and bit was giving indications we were milling on something other than cement. POOH to inspect bit and found a large chunk of aluminum stuck in center of the concave bit. Confer with town engineer and decision made to RDMO until procedures can be reviewed. Well is ready for E-Line to perform a Jewerly Log. Diesel from 7,842'to surface. 2/28/2015 LOCATED DB NIPPLE @ 7607'SLM, 7636' RKB. DRIFT TBG W/3.45"x 20'1" DUMMY GUN TO 7846'SLM, EST. 7875' RKB. PHASE 3 WX MOVED IN RAPIDLY. R/D EQUIPMENT&SECURED WELL. WAITED OUT STORM @ RIG CDR2. 3/6/2015 (PRE-CTD)TREE VALVE TEST SV,SSV,MV ALL PASSED POSTIVE TESTS. AND DDT TO 0 PSI. TREE SHELL TEST TO 4900 PSI. - PASSED 3/6/2015 PERFORM MULITI FINGER CALIPER SURVEY FROM 7872 TO 7550. PERFORATE FROM 78387859. CCL TO TOP SHOT IS 7.5', CCL STOP AT 7830.5. ATTEMPTED TO PERFORATE THE TOP OF THE A2 SANDS FROM 78687872 BUT WAS UNABLE TO GET THAT DEEP WITH THE SECOND GUN STRING. 3/8/2015 MEASURED BHP @ 7865' RKB (3892 PSI ), RAN 2.5" BAILER WORKED DOWN TO 7881' RKB OBTAINED SAMPLE, DRIFT TO 7830'RKB WITH 12'X 3.63" DUMMY WHIPSTOCK, JOB COMPLETE. 3/10/2015 CORRELATE TO PERF RECORD DATED 6-MAR-2015 AND PERFORATE A2 SANDS FROM 7867'-7872'. WILL BE BACK TO SET WEATHERFORD PACKER TOMORROW. ***IN PROGRESS*** 3/11/2015 CORRELATE TO PERF RECORD DATED 6-MAR-2015 AND SET WEATHERFORD WS-R-BB PACKER MID ELEMENT @ 7829.1'. READY FOR SLICKLINE TO SET WHIPSTOCK TRAY. 3/12/2015 SET WEATHERFORD STARBURST HOLLOW WHIPSTOCK(12.41')(2 RA TAGS 2.2' FROM TOP OF WHIPSTOCK) @ 7815' RKB; RAN 3.5"LIB INDICATED WHIPSTOCK TRAY SET 180 DEGREES. SET BPV. Time Log & Summary Con®c Phillips Weiview Web Reporting Report Well Name: 30-16 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 3/14/2015 12:00:00 PM Rig Release: 4/20/2015 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/12/2015 24 hr summary Lay down gooseneck and install 2 3/8"rollers,reinstall gooseneck. Swap BOP rams. Swap coil tubing reels, install shim hubs, install reel drive motor, install pack-offs. 12:00 18:00 6.00 0 0 MIRU MOVE CTOP P PJSM-Lay down goose neck, change out rollers, install goose neck.change out gripper blocks, stripper,swap BOP rams. 18:00 22:00 4.00 0 0 MIRU MOVE CTOP P PJSM with Peak,lower reel onto Peak truck,swap reel drive motors out,install new reel,shim hubs, install reel drive and motor. 22:00 00:00 2.00 0 0 • MIRU MOVE CTOP P PJSM.Secure coil reel. Install brass and pack-offs,clean-up, X3/13/2015 Stab 2 3/8"coil into injector head. Install new inner reel iron. ND BOP stack,secure wellhead on 30-12. Pull rig modules off well 12,cleanand inspect wellhead/work area.Spot modules over 30-16.Start rigging up CDR. 00:00 02:30 2.50 0 0 MIRU MOVE CTOP P PJSM. P/U stabbing cable, install grapple, pull test.Stab coil in injector, RD stabbing equipment. 02:30 05:00 2.50 0 0 MIRU MOVE CTOP P PJSM. Install new inner reel iron, pre-move checklist. 05:00 10:00 5.00 0 0 MIRU MOVE RURD P Complete RD from 30-12, ND BOP stack,secure stack for move,secure wellhead, load with methanol,check tree flange bolts,two bolts not snug, 40 minutes to complete. 10:00 13:00 3.00 0 0 MIRU MOVE PRLO P Working on pad prep, installing work platform after flow cross swap,work platform will not allow installation of MP valves, MU temp scafolding, install double swabs,double wings off companion,prep site for move. 13:00 18:00 5.00 0 0 MIRU MOVE MOB P Peak on location, PJSM-cold weather ppe, communication. Pull subs off of 30-12, clean and inspect wellhead/work area.Continue working on 30-16 tree configuration. 18:00 22:00 4.00 0 0 MIRU MOVE MOB P PJSM.Spot modules over 30-16. Release Peak crew. 22:00 00:00 2.00 0 0 MIRU MOVE RURD P PJSM.MIRU CDR2, berm cellar, RU PUTZ,steam. 33/14/2015 MIRU CDR2 on 30-16,complete rig up. Rig accept @ 12:00. NU BOP stack. Perform initial BOP test,test PDL's, in progress. 00:00 12:00 12.00 0 0 MIRU MOVE RURD P Continue RU operations, inter connect,TT hardline, pre spud checklist check,tree flange bolts, Page 1 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 14:15 2.25 0 0 MIRU WHDBO RURD P Accept rig @ 12:00 on 03-14-15. NU BOP equipment, MP line,fill stack and shell test, good test. 14:15 23:00 8.75 0 0 MIRU WHDBO BOPE P Perform initial BOPE test,250/4900 psi, annular 2500 psi.Test witnessed by AOGCC(John Hill) 23:00 00:00 1.00 0 0 MIRU WHDBO RURD P PJSM. Lay down test joints and BOP test equipment, blow down. X3/15/2015 Rehead coil connector, Pull BPV. PT PDL's, inner reel iron,TT line. RIH w/BHA#1 to fish whipstock @ 7,815,got two up licks came free. POOH to check BHA, no fish,disconnect sheared. RIH w/BHA#2, in progress. 00:00 03:15 3.25 0 0 MIRU MOVE CTOP P PJSM. Install coil connector, pull test connector 41K. MU E-line, meg test, MU blind sub. 03:15 04:45 1.50 0 0 MIRU MOVE MPSP P PJSM. Pull BPV, LD FMC equipment 04:45 08:45 4.00 0 0 MIRU MOVE PRTS T PJSM. Load coil,attempt to P/T TT line,froze up, hose and first stick of hardline at rig thawed, intake hose to TT thawed. 08:45 12:00 3.25 0 0 MIRU MOVE PRTS P PJSM. PT inner reel iron,stripper and TT and surface lines. Initial Tubing 1275 psi, IA 1657 psi, OA 0 psi,bleed TBG to 0 psi IA to 10 psi. 12:00 12:30 0.50 0 0 SLOT WELLPF OWFF T Monitor well 30 minutes,TBG 0 psi, IA 39 psi, OA 0 psi. Fish is set. 12:30 13:00 0.50 0 0 SLOT WELLPF CTOP T PJSM-Install checks, PT CTC and head 4k. 13:00 14:18 1.30 0 77 SLOT WELLPF FISH T PJSM-MU Weatherford fishing BHA #1, M to CoilTrak,Strip over well. 14:18 15:54 1.60 77 7,776 SLOT WELLPF FISH T TIH with fishing BHA#1, EDC open. Tie in to K1, plus 10-ft correction, continue in hole. 15:54 16:54 1.00 7,776 7,776 SLOT WELLPF FISH T 7,776-ft, Close EDC, swap well over to 11.7 ppg formate KWF 16:54 17:09 0.25 7,776 7,797 SLOT WELLPF FISH T Establish parameters 1 bpm at 530 psi, Diff 178, PUW 40k, RIH per Weatherford rep. RIW 14k, IA 180, OA 0.7796-ft, sat down 10k, PU clean,sat down 10k, hit down jar, PU 4k overpull,sat back down 11k, PU 70k,-21k WOB, Bi-Di jar hit and came free, 17:09 18:45 1.60 7,797 73 SLOT WELLPF FISH T TOOH per Weatherford rep,on surface. 18:45 19:15 0.50 73 73 SLOT WELLPF OWFF T PJSM. Flow check 30 minutes, no flow. 19:15 22:30 3.25 73 66 SLOT WELLPF PULD T PJSM. LD BHA#1.Weatherford disconnect sheared, no fish. Discuss with town,decide to run second fishing string. PJSM. MU BHA#2 with 2.5"Hyd. GS. 22:30 00:00 1.50 66 7,600 SLOT WELLPF TRIP T RIH w/BHA#2 to 7,600' Page 2 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/16/2015 24 hr Summary Made two unsuccessful runs to fish Weatherford whipstock @ 7,792', no fish. Stand by for new marching orders from town.Decide to make one under reamer run. MU BHA#4, RIH w/under remer assembly to 7,610'. 00:00 01:00 1.00 7,600 7,788 SLOT WELLPF FISH T Continue in hole to fish whipstock, tie-in to K1 for+7'correction, close EDC, PUW=42K. RIH @ min rate, engage fish @ 7,788'. Shut down pump,stack 2K down,straight pull 15K over. Hit five up jar licks @ 15K over, hit four more at 20K over,pull free,set back down 2K, pulled free, PUW=44K. 01:00 02:39 1.65 7,788 66 SLOT WELLPF TRIP T POOH to check BHA,open EDC. On surface. 02:39 03:09 0.50 66 66 SLOT WELLPF OWFF T Flow check 30 minutes, no flow. 03:09 05:09 2.00 66 0 SLOT WELLPF PULD T PJSM. LD BHA#2, no fish,brought back lower section of disconnect and box trap. Does not appear that box trap fully engaged fish, pictures on "S"drive. PT above WS to 250 psi, monitor 30 mins. 05:09 09:45 4.60 0 0 SLOT WELLPF WAIT T Waiting on marching orders from town.2nd PT above WS at 05:30 to 320 psi,30 minutes 30 psi,at 07:30- 13 psi,at 09:30-8 psi.maintinence and cleaning on rig, choke B motor, DS counterhead ram. 09:45 10:15 0.50 0 0 SLOT WELLPF OWFF T Flow check 30 minutes, no flow. Note: PJSM-Load out Weatherford equipment 10:15 11:39 1.40 0 57 SLOT WELLPF PULD T PJSM-MU BHA#3, Clean out assembly. 11:39 13:15 1.60 57 7,750 SLOT WELLPF TRIP T TIH with BHA#3, 0°straight motor, 3.80"bald nose crayola mill.Tie in to K1,plus 7-ft correction,close EDC, PUW 40k, continue in hole at min rate. 13:15 14:03 0.80 7,750 7,791 SLOT WELLPF WASH T On line 2.2 bpm, 1708 psi at 7,750-ft, wash down,stall at 7,792.8-ft, pumps off, PUW 40k,wash up/ down 7,760-ft to 7,791-ft while CBU, pump sweep. Note:lateral vibration 3 to 4 during passes after. 14:03 14:36 0.55 7,791 7,700 SLOT WELLPF WASH T PUH and wash up/down 7,700-ft to 7,730-ft per town,open EDC. 14:36 16:00 1.40 7,700 57 SLOT WELLPF TRIP T POOH chasing sweep out of hole. No signifficant cuttings or solids arcoss shaker. 16:00 16:30 0.50 57 57 SLOT WELLPF OWFF T Flow check 30 minutes,no flow. PJSM-laying down BHA 16:30 17:15 0.75 57 0 SLOT WELLPF PULD T LD BHA#3, Page 3 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:15 20:45 3.50 0 0 SLOT WELLPF WAIT T Waiting on under reamer from Prudhoe, Plan forward is to under ream 4 1/2"liner from 7,723-ft to 7,791-ft. 20:45 22:30 1.75 0 70 SLOT WELLPF PULD T PJSM. MU BHA#4, under reamer assembly 22:30 00:00 1.50 70 7,610 SLOT WELLPF TRIP T RIH w/BHA#4 under reamer 03/17/2015 Under ream from 7,724'to 7,791' 00:00 00:45 0.75 7,610 7,724 SLOT WELLPF DLOG T Log K1 for+7.5'correction.Continue in hole. 00:45 02:03 1.30 7,724 7,791 SLOT WELLPF UREM T Start under reaming at 7,724 @ 3 fpm. Pumping at 2 bpm @ 2450 psi, BHP=4025 psi,WOB=0. PUH to 7,724'with same parameters, PUW=40K,no real motor work observed. Open EDC, pump bottoms up. 02:03 03:18 1.25 7,791 71 SLOT WELLPF TRIP T POOH at 50 fpm to 7,600'. Continue OOH @ 100 fpm. 03:18 03:33 0.25 71 71 SLOT WELLPF OWFF T Flow check 03:33 05:51 2.30 71 83 INTRM1 RPEQPI PULD T PJSM. LD BHA#4. PJSM. MU BHA #5 05:51 07:45 1.90 83 7,610 INTRM1 RPEQPI TRIP T RIH w/BHA#5 whipstock assembly, EDC open. 07:45 08:06 0.35 7,610 7,791 INTRM1 RPEQP1DLOG T Tie into K1,plus 5-ft correction, PUW 42k, continue in hole pumps off. 08:06 08:15 0.15 7,791 7,775 INTRM1 RPEQPIWPST T 7,790.73-ft, Bit depth, positioned 0° HS,close EDC,released at 3400 psi,set down 5k, TOWS at 7,775-ft. 08:15 10:09 1.90 7,775 83 INTRM1 RPEQP1 TRIP T 7,775-ft, TOOH for window milling assembly. 10:09 10:39 0.50 83 83 INTRMI RPEQP1 OWFF T Monitor well for flow. PJSM-lay down BHA. 10:39 11:21 0.70 83 0 INTRMI RPEQPI PULD T LD BHA#5 11:21 13:00 1.65 0 0 INTRMI WHPST PULD P PJSM-Add riser for PD/PUD, open top doors to rig to allow gooseneck room to raise. 13:00 16:45 3.75 0 82 INTRMI WHPST PULD P PJSM-MU BHA#6 window milling assembly, 1°AKO motor with string mill and 3.79"string mill and 3.80" DSM, unable to raise injector head high enough to MU to BHA,height of tree a lesson learned,drop 1-ft out of riser assembly. MU to CoilTrak, surface test, P/T riser 1500 psi. 16:45 18:21 1.60 82 7,620 INTRM1 WHPST TRIP P TIH with window milling BHA#6 EDC open. 18:21 18:36 0.25 7,620 7,620 INTRM1 WHPST DLOG P 7620ft,tie into the K1 marker correction of plus 4.5ft. PUW 42.5k 18:36 18:51 0.25 7,620 7,760 INTRM1 WHPST TRIP P 7620ft, continue RIH, RIW 14.3k 18:51 19:36 0.75 7,760 7,760 INTRMI WHPST DISP P 7760ft, Swap well to 9.8ppg drilling mud. Page 4 of 3i Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:36 19:51 0.25 7,760 7,775 INTRMI WHPST WPST P 7775ft, Dry tag TOWS,bring up pump 2.5bpm at 2300psi. IA 650, OA 0 19:51 00:00 4.15 7,775 7,779 INTRM1 WHPST WPST P Mill window as per recommended practice and Baker rep. 03/18/2015 Mill 3.80"Window 7775ft 00:00 04:30 4.50 7,779 7,787 INTRM1 WHPST WPST P Continue milling window as per Baker rep, ROP 1fph, 2.5bpm, 2500psi,3.25k WOB ****Note: Bled down IA from 700psi to 150psi 04:30 10:35 6.09 7,787 7,787 INTRMI WHPST WPST P 7,786.6-ft Decrease in WOB,exited 4 1/2"liner, milling window as per schedule and Baker rep, ROP-.6 fph,2.5 bpm,2500 psi,3.90k WOB 10:35 12:05 1.50 7,787 7,788 INTRM1 WHPST WPST P Milling window as per Baker rep, ROP 1 fph,2.5 bpm,2350 psi,3.90k WOB 12:05 14:35 2.50 7,788 7,791 INTRM1 WHPST WPST P 7,788.2-ft, Decrease in WOB to.5k, milling as per schedule and Baker rep. 1 fph,2.5 bpm at 2300 psi, some cement across shaker 14:35 16:59 2.41 7,791 7,795 INTRM1 WHPST WPST P 7,791-ft, Milling 2.5 bpm at 2350 psi, .5 WOB,WH 17, BHP 3596, EDC 10.9 ppg, call form town,work up to 11.7 EMW at window,2.5 bpm at 2,580 psi, BHP 3,880 psi, EDC 11.7 ppg,WHP 280 psi, ROP 1.7. 16:59 17:59 1.00 7,795 7,800 INTRM1 WHPST WPST P 7,795-ft, Milling rathole 2.5 bpm at 2,580 psi, BHP 3,855 psi,WHP 280, 11.7 ECD 17:59 20:44 2.75 7,800 7,800 INTRM1 WHPST REAM P 7800ft,TD rat hole, Back ream window area as per plan,7770ft- 7798ft, highside,30L,and 30R. 60fph,dry drift window area at 15 fph clean,tag TD at 7800ft. 20:44 22:29 1.75 7,800 82 INTRMI WHPST TRIP P POOH,with Open EDC,pumping 3.0bpm at 2400psi. 22:29 22:59 0.50 82 82 INTRM1 WHPST SFTY P PJSM for undeploying BHA#6 22:59 23:59 1.00 82 82 INTRM1 WHPST PULD P Undeploy milling BHA 03/19/2015 RIH,drilled build section from 7800'to 8090'. POOH, undeployed build BHA, MU and deploy lateral drilling BHA, RIH,drill lateral. 00:00 02:00 2.00 82 0 INTRM1 WHPST PULD P Continue Undeploying milling BHA, ****Note:While undeploying found that we had to break the connection above the QTS breaking an o-ring connection that couldn't be tested when deploying build BHA, after discussing this rig team, recommendation from BHI was to remove wear sub from above the P&C to allow,proper break of QTS when deploying the next BHA's. Page 6 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 03:30 1.50 0 0 INTRM1 DRILL PULD P Swap tool around in pipeshed, remove wear sub from BHA, retest tools, ****Note: Mills gauged 3.790D no-go 03:30 04:00 0.50 0 0 INTRM1 DRILL PULD P M/U build BHA 04:00 04:15 0.25 0 0 INTRM1 DRILL PULD P PU,MU, QTS and retest riser connection to 4900psi. 04:15 06:30 2.25 0 82 INTRM1 DRILL PULD P Deploy BHA#7 build assembly,2.0° AKO motor and 3.75"X 4.25"HCC Bi-center bit, MU to CoilTrak,surface test. 06:30 07:54 1.40 82 7,600 INTRM1 DRILL TRIP P TIH with BHA#7, EDC open 07:54 08:12 0.30 7,600 7,800 INTRMI DRILL DLOG P Tie in to K1, plus 5-ft correction, close EDC, PUW 37k. Continue in hole. 08:12 12:12 4.00 7,800 7,953 INTRMI DRILL DRLG P 7,800-ft, OBD 2.52 bpm at 2,949 psi,BHP 3914,WHP 300, IA 300, OA 0,stall at 7,861-ft(6th), 10k overpull, BOBD 2.70 bpm at 3456, BHP 3,947 psi,WHP 243,IA 391, OA 0 12:12 12:33 0.35 7,953 7,600 INTRM1 DRILL WPRT P 7,953-ft, PUH for logging RA markers, PUW 40k, 12:33 13:15 0.70 7,600 7,953 INTRM1 DRILL DLOG P 7,600-ft, Tie in to K1, no correction, Log RA markers on both whipstocks, Top RA marker 7,787.5-ft, Btm RA marker(Weatherford WS)7,796-ft, BOW 7,790-ft. 13:15 15:45 2.50 7,953 8,090 INTRM1 DRILL DRLG P 7,953-ft, BOBD 2.70 bpm at 3,221 psi, BHP 3,990 psi,WHP 259, IA 376,OA 0,pump sweeps, 15:45 18:00 2.25 8,090 82 INTRM1 DRILL TRIP P 8,090-ft, TD build section land in projected Al pay, TOOH chasing sweeps to swab. 18:00 18:30 0.50 82 82 INTRMI DRILL SFTY P PJSM for LD build section BHA#7 18:30 19:45 1.25 82 0 INTRM1 DRILL PULD P Undeploy build BHA 19:45 20:45 1.00 0 0 INTRMI DRILL PULD P Reconfigure MWD tools in pipeshed, installing USMR below DGS. 20:45 22:15 1.50 0 82 INTRM1 DRILL PULD P Deploy BHA#8 22:15 23:51 1.60 82 7,615 INTRM1 DRILL TRIP P RIH with BHA#8,0.9 AKO motor with rebuilt 4.250D bi-center bit. 23:51 00:00 0.15 7,615 7,637 INTRMI DRILL DLOG P 7615ft,tie into the K1 marker correction of plus 6ft, PUW 41k 33/20/2015 Drilled from 8090ft to 8737ft. 00:00 00:15 0.25 7,637 8,090 INTRM1 DRILL TRIP P Continue RIH thorugh window, clean. 00:15 02:33 2.30 8,090 8,290 INTRMI DRILL DRLG P 8090ft, BOBD 2.8bpm at 3100psi, BHP 3949,WHP 235, IA 348, OA 0 02:33 03:00 0.45 8,290 7,836 INTRMI DRILL WPRT P 8290ft,wiper up hole. PUW 38.5k 03:00 03:15 0.25 7,836 8,290 INTRM1 DRILL WPRT P 7,836-ft, Wiper back in hole. Page 6of31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:15 03:33 0.30 8,290 8,358 INTRM1 DRILL DRLG P 8,290-ft, OBD 2.6bpm at 3010psi, BHP 3981,WHP 235, IA 328, OA 0, ROP 215 fpm,pushing on it for turn right, not working. 03:33 07:06 3.55 8,358 82 INTRM1 DRILL TRIP P 8,358-ft, PUH, discuss with town. TOOH for higher AKO motor. 07:06 08:33 1.45 82 0 INTRMI DRILL PULD P PJSM-Un-deploy BHA#8, bit 1-1, looks good. 08:33 09:33 1.00 0 0 INTRM1 DRILL PULD P Adjust motor to 1.5°AKO. 09:33 11:09 1.60 0 82 INTRMI DRILL PULD P PJSM-MU BHA#9, 1.5°AKO Motor and HYC 3 3/4"x 4.25"Bi-center bit, deploy, MU to CoilTrak, surface test. 11:09 12:30 1.35 82 7,610 INTRM1 DRILL TRIP P TIH with BHA#9 EDC open. 12:30 12:45 0.25 7,610 7,640 INTRM1 DRILL DLOG P Log K1, plus 5-ft correction,close EDC, PUW 39k. 12:45 13:15 0.50 7,640 8,358 INTRM1 DRILL TRIP P Continue in hole,clean thru window, 11.8k RIW. 13:15 14:54 1.65 8,358 8,560 INTRM1 DRILL DRLG P 8,358-ft, OBD 2.77 bpm at 3,124 psi, BHP 4,001 psi,WHP 268, IA 472,OA 0,averageing 11 degree DLS, last survey 14°DLS. 14:54 15:24 0.50 8,560 7,850 INTRM1 DRILL WPRT P 8,560-ft,Wiper up hole. PUW 42k 15:24 15:48 0.40 7,850 8,560 INTRM1 DRILL WPRT P 7,850-ft, Wiper back in hole, RIW 11k 15:48 17:48 2.00 8,560 8,684 INTRM1 DRILL DRLG P 8,560-ft, OBD 2.77 bpm at 3,354 psi, BHP 3,987 psi,WHP 224, IA 777, OA 0,WOB 1.8k, ROP 90 from 8,486-ft Note:bleed down IA to 50 psi 17:48 18:03 0.25 8,684 8,684 INTRM1 DRILL WPRT P 8684ft, BHA wiper up to 8590ft, PUW 44k Looks like we transitioned into a different formation,WOB 2.7k, ROP 20 fph 18:03 21:03 3.00 8,684 8,717 INTRM1 DRILL DRLG P 8684ft, BOBD 2.79 bpm at 3354psi, BHP 4064,WHP 300, IA 406,OA 0 21:03 21:18 0.25 8,717 8,717 INTRMI DRILL WPRT P 8717ft, BHA wiper up to 8600ft, PUW 42k 21:18 00:00 2.70 8,717 8,737 INTRM1 DRILL DRLG P 8717ft, BOBD 2.77 bpm at 3244psi, BHP 4079,WHP 325, IA 375,OA 0 33/21/2015 Drilled lateral from 8737ft to TD 8920ft. Performed a swab wiper, RBIH to confirm TD 8922ft, Lay in 11.75ppg liner pill without beads up to the window,and displace well to 11.85ppg to surface,check well for flow, LD drilling BHA, Function test BOPE. 00:00 02:45 2.75 8,737 8,760 INTRM1 DRILL DRLG P 8737ft, OBD 2.77 bpm at 3365psi, BHP 4050 psi,WHP 292, IA 409, OA 0 02:45 03:45 1.00 8,760 8,760 INTRMI DRILL WPRT P 8760ft,Scheduled wiper up hole to 8200ft, PUW 42k ****Note: Pumping drilling rate 2.6bpm,set down at 8630ft, PU, lowered pump rate to 0.75 bpm, pass through without issue. Page 7 of 31 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 03:45 08:51 5.10 8,760 8,850 INTRM1 DRILL DRLG P 8760ft, BOBD 2.76 bpm at 3250 psi, BHP 3998,WHP 277, IA 408,OA 0, WOB 3k, ROP 11fph Looks like we transitioned into a different formation,WOB 1.4k, ROP 20 fph 08:51 09:45 0.90 8,850 8,850 INTRM1 DRILL WPRT P 8,850-ft, Geo wiper to discuss TD in town. 09:45 12:21 2.60 8,850 8,920 INTRM1 DRILL DRLG P 8,850-ft, OBD 2.78 bpm at 3,315 psi, BHP 4,047 psi,WHP 302, IA 490, OA 0,WOB 1.6k, ROP 16. Note: Final ROP 55 fpm,WOB 1.6k. 13 degree DLS on last 70-ft drilled. 12:21 13:21 1.00 8,920 7,820 INTRM1 DRILL WPRT P 8,920-ft, TD called, PUW41k, Chase sweeps to swabs,5k overpull at 8,690-ft, 10k ovrepull at 8,650-ft, reduce pump rate to pull thru,call town. 13:21 14:03 0.70 7,820 8,800 INTRM1 DRILL WPRT P 7,820-ft, Wiper back in hole, PUH at 8,580-ft,choke plugging, BU from 8,650-ft,dime size clay balls, heavy shales across shaker, RBIH, reduce rate.5 bpm at 8,630-ft, RIW 9.0k to 8,760-ft with no problem. 14:03 16:30 2.45 8,800 82 INTRMI DRILL WPRT P 8,800-ft, PUW 42k,TOOH 1.4 bpm at 1,774 psi,max overpull of 2k from 8,760-ft to 8,630-ft,TOOH, EDC open at 7,720-ft,Jog at 200-ft. 16:30 18:00 1.50 82 7,620 INTRM1 DRILL TRIP P At surface, reset depth, RBIH with BHA#9 18:00 18:15 0.25 7,620 7,620 INTRMI DRILL DLOG P 7620ft-7645ft,Tie into K1 correction plus 4.0ft 18:15 18:45 0.50 7,620 7,650 INTRM1 DRILL TRIP P Pressure Survey at window. PUW 40k 1.)0.25 bpm/WHP 425/CHP 340/ANN 3910/ECD 11.93 2.)0.5 bpm/WHP 400/CHP 320/ANN 3911/ECD 11.93 3.) 1.0 bpm/WHP 355/CHP 280/ANN 3911/ECD 11.93 4.)2.0 bpm/WHP 290/CHP 200/ANN 3911/ECD 11.93 Stactic BHP 3865 psi, 11.79 ppg ECD 18:45 20:00 1.25 7,650 8,922 INTRM1 DRILL TRIP P Close EDC,and continue through window to confirm TD. 20:00 20:45 0.75 8,922 7,682 INTRM1 DRILL TRIP P Confirm TD 8922ft, POOH, laying in 11.75 ppg liner running pill without beads up to the window, ****Note: Paint EOP flags at 7600ft and 6400ft. Page 8 of 31 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 20:45 22:15 1.50 7,682 82 INTRM1 DRILL TRIP P POOH,with drilling BHA displacing well to 11.8 ppg complition fluid without beads. 22:15 22:45 0.50 82 82 INTRM1 DRILL SFTY P At surface, PJSM for LD drilling BHA#9,check well for flow. ***'Note: Lost 10 bbls of Nabr to formation during displacement. 22:45 23:30 0.75 82 0 INTRM1 DRILL PULD P LD Drilling BHA 23:30 00:00 0.50 0 0 INTRM1 DRILL CTOP P PU test joint and function test BOPE. 33/22/2015 MU the B lateral 3.5"completion with composite shoe track. POOH and LD liner. MU and RIH with CO BHA. 00:00 00:30 0.50 0 0 INTRM1 CASING SFTY P PJSM,for MU B Lateral completion assembly with compostite shoe. 00:30 03:45 3.25 1,186 1,186 INTRM1 CASING PUTB P MU B lateral completion with 37jts of solid Hyd.511, 9.2#, L-80 with 7 cementrilizers,and shorty deployment sleeve. 03:45 05:00 1.25 1,186 1,230 INTRM1 CASING RUNL P MU BHI and BOT setting tools with GS. 05:00 07:27 2.45 1,230 8,222 INTRM1 CASING RUNL P RIH with 3.5"liner completion with BOT GS. Plus 0.5-ft correction at flag. PUW 45.5k. Continue in hole, RIW 12k. 07:27 08:21 0.90 8,222 7,927 INTRM1 CASING RUNL T 8,222-ft, Sat down 12k,work pipe 4 times,confer with town,pump 1 bpm in tension, PU to 67k to free liner, PUH slowly while discussing with town. 08:21 08:33 0.20 7,927 8,220 INTRM1 CASING RUNL T 7927-ft, RBIH pumping 1 bpm, slow down to 15 fph,start seeing weight swing at 8,145-ft,sat down 5k at 8,220-ft, not moving down,shut down pump, PUW 52k. 08:33 09:12 0.65 8,220 8,000 INTRM1 CASING RUNL T 8,220-ft, PUH slowly while discussing options with town. 09:12 11:30 2.30 8,000 1,230 INTRM1 CASING RUNL T 8,000-ft, POOH for clean out assembly,pumping over the top. 11:30 12:00 0.50 1,230 1,230 INTRM1 CASING OWFF T Flow check. PJSM-laying down BHA. 12:00 12:45 0.75 1,230 1,183 INTRM1 CASING PULD T LD BHA#10 12:45 13:30 0.75 1,183 1,183 INTRM1 CASING PUTB T PJSM-prep floors for laying down liner. 13:30 16:30 3.00 1,183 0 INTRM1 CASING PUTB T PJSM- LD B lateral completion with composite cement retainer, 37 jts of solid Hyd511, 9.2#, L-80 with 7 cementrilizers and deployment sleeve. Clean floors. 16:30 18:30 2.00 0 79 INTRMI CASING PULD T PJSM-MU BHA#11, 1°AKO motor and 3.80"D331 mill(no back cutters) 18:30 20:00 1.50 79 7,620 INTRM1 CASING TRIP T RIH with clean out BHA#11. 20:00 20:15 0.25 0 7,600 INTRM1 CASING DLOG T 7620ft,Tie into the K1 marker correction of plus 5.0ft. 20:15 22:30 2.25 7,600 7,750 INTRM1 CASING DISP T 7750ft,displace well to 9.8ppg drilling fluid. Page 9 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 23:15 0.75 8,625 7,912 INTRM1 CASING WPRT T PUH to 7912ft 23:15 00:00 0.75 7,750 8,625 INTRM1 CASING TRIP T RIH,through window down to 8625ft, Pump 5x5 sweep, and chase up hole above window. 33/23/2015 • RIH with clean out BHA#11. Set down at 8631'. Perform swab wiper trip. Set anchored aluminum billet at 8250'. 00:00 00:15 0.25 7,912 7,730 INTRM1 CASING WPRT T 7912ft, Continue PUH to 7730ft 00:15 00:39 0.40 7,730 8,636 INTRM1 CASING TRIP T 7730ft, RBIH to bottom sat down at 8631', PU heavy,try again and worked pipe down to 8636'. 00:39 01:57 1.30 8,636 7,700 INTRM1 CASING TRIP T PU,pump sweep and wiper to 7700'. 01:57 02:51 0.90 7,700 8,620 INTRM1 CASING TRIP T RBIH to 8620', pump 10 x 10 sweep. 02:51 05:12 2.35 8,620 79 INTRM1 CASING TRIP T Perform swab wiper. 05:12 08:12 3.00 79 8,480 INTRM1 CASING TRIP T At surface, reset counters, RBIH,tie in to K1 with plus 4.5-ft correction, continue in hole, clean thru window, no problem thru build or lateral section 08:12 10:42 2.50 8,480 79 INTRM1 CASING TRIP T 8,480-ft, Chase sweeps to surface, shale across shaker 10:42 13:00 2.30 79 0 INTRM1 CASING PULD T PJSM-Undeploy, replace failed o-ring on PDL, LD BHA#11, blow down BHI tools, Bit 3.78"no-go(in 3.79"no-go) 13:00 14:54 1.90 0 78 INTRM1 STK PULD T PJSM-MU BHA#12, 3 5/8"OD OH anchored billet,deploy, make up to ColiTrak, surface test. 14:54 16:21 1.45 78 7,610 INTRM1 STK TRIP T TIH with BHA#12, EDC open pumping minimum rate. 16:21 16:33 0.20 7,610 7,630 INTRM1 STK DLOG T Tie in to K1, plus 5-ft correction,off on pump, PUW 41k. 16:33 17:03 0.50 7,630 8,262 INTRM1 STK TRIP T Continue in hole pumps off,close EDC at window,slacked off 2k at 7,790-ft, PU, reorientate slips 40 LOHS, RBIH through winndow with slight bobble, continue in hole. 17:03 17:15 0.20 8,262 8,250 INTRM1 STK WPST T 8,262.42-ft, Bit depth, PU neutral, release off Billet at 4,500 psi,set down 5k, OH anchored billet set with top at 8,250-ft. 17:15 19:00 1.75 8,250 78 INTRM1 STK TRIP T TOOH with billet setting BHA for drilling BHA. 19:00 20:42 1.70 78 0 INTRM1 STK PULD T PJSM-Undeploy, replace failed o-ring on PDL, LD BHA#12 Open hole anchored billet. 20:42 21:42 1.00 0 0 INTRM1 STK PULD T Reconfigure MWD tools in pipeshed, installed DGS below USMR. 21:42 23:06 1.40 0 0 INTRM1 STK PULD T PJSM-MU BHA#13, 0.9°AKO . Motor and HCC 3 3/4"x 4.25" . . Bi-center bit and pressure deploy. Surface test. 23:06 00:00 0.90 0 4,290 INTRM1 STK TRIP T RIH with BHA#13. Pagel()of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 33/24/2015 24 hr summary RIH with drilling BHA#13 to sidetrack off anchored billet.Swap well to new 9.8 ppg mud.Tried to time milled off billet, but had several stalls. Displaced well to 11.8 ppg completion fluid and POOH for second anchored billet. RIH with BHA#14 and set second billet at 8183'. 00:00 00:36 0.60 4,290 7,600 INTRMI STK TRIP T RIH with BHA#13. 00:36 01:24 0.80 7,600 7,600 INTRM1 STK DLOG T Tie in to K1,plus 4-ft correction, close EDC, PUW 37k. Continue in hole. 01:24 01:42 0.30 8,250 8,250 INTRM1 STK KOST T Tag up on anchored aluminum billet and start time drilling High Side, stalled PU, restart 01:42 02:42 1.00 8,250 8,255 INTRM1 STK KOST T 8250ft,time milling again,2.7 bpm at 3046psi, BHP 3984,WHP 204, IA 6, OA 0, Stall morning 8253ft 02:42 03:27 0.75 8,255 8,263 INTRM1 STK KOST T 8255ft, Push on it and stall at 8263ft. 03:27 03:42 0.25 8,263 8,263 INTRM1 STK KOST T 8263ft, PUW clean 40k 03:42 07:57 4.25 8,263 8,263 INTRM1 STK KOST T Work pipe down to 8256ft,stalled motor 7 times trying to get back to bottom.Try and RIH dry set down at 8257', PUH, bring up pump RBIH stalled again at 8256ft.PUH and restart pump,stall again at 8256.81'. PUW 44k,minus 4k BHIWOB 07:57 08:27 0.50 8,263 8,263 INTRM1 STK TRIP T 8256ft, PUH,prepair for mud swap, call town about plan forward. 08:27 09:12 0.75 8,263 8,263 INTRM1 STK DISP T 8250ft,swap hole over to new 9.8ppg drilling fluid. 09:12 09:57 0.75 8,263 8,263 INTRM1 STK DISP T RBIH to displace well to 11.8+ppg completion fluid from 8245ft. 09:57 10:57 1.00 8,263 82 INTRM1 STK TRIP T POOH,displacing well with 11.8+ ppg completion fluid. 10:57 12:42 1.75 82 82 INTRM1 STK SFTY T At surface,check well for flow, PJSM for LD tools. 12:42 13:42 1.00 82 0 INTRM1 STK PULD T LD tools 13:42 14:57 1.25 0 0 INTRM1 STK PULD T Reconfigure BHI tools in pipeshed. 14:57 15:27 0.50 0 0 INTRM1 STK SFTY T PJSM,for MU billet setting tools. 15:27 17:27 2.00 0 141 INTRM1 STK PULD T MU 3-5/8"Open Hole Anchored Billet with 2 joints of 2-7/8"ST-L. 17:27 19:21 1.90 141 7,594 INTRMI STK TRIP T Trip in hole with BHA#14. 19:21 19:36 0.25 7,594 7,594 INTRM1 STK DLOG T Tie in at K1 marker at 7594'with a +4.5'correction.Close EDC. PU wt 41K. 19:36 20:21 0.75 7,564 8,258 INTRM1 STK TRIP T RIH at 20 fpm orientated HS sat down at 7857',try 40 L,try HS at 30 fpm,try 30 R and 40L at 30 fpm.Call town and discuss.Tried 20L at 15 fpm then 30R made it through the window. 20:21 20:51 0.50 8,258 8,258 INTRM1 STK WPST T Wt check 42K:Tag up on first aluminum billet at 8260'and picked up to nuetral wt 3 times.All three set downs at 8260'and nuetral wt 8258'. Pumped up to 3800 psi and sheared off billet.Set down on billet with 5K. Page 11 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:51 22:21 1.50 8,183 134 INTRM1 STK TRIP T POOH with BHA#14. 22:21 23:33 1.20 0 0 INTRM1 STK PULD T PJSM-LD BHA#14 Open hole anchored billet. No flow test. 23:33 00:00 0.45 0 82 INTRM1 STK PULD T PJSM-MU BHA#15, 1.1°+AKO Motor and HYC 3 3/4"x 4.25" Bi-center bit. Surface test. 33/25/2015 Drilled off billet at 8186'and drilled to 9076. 00:00 01:15 1.25 82 82 INTRMI STK PULD T PJSM-MU BHA#15, 1.1°+AKO Motor and HYC 3 3/4"x 4.25" Bi-center bit. Surface test. 01:15 04:45 3.50 82 8,186 INTRM1 STK TRIP T RIH with drilling BHA#15 to sidetrack off anchored aluminum billet.Swap well back to drilling mud. Dry tag the billet at 8186'. 04:45 06:15 1.50 8,186 8,200 INTRM1 STK KOST T Start time drilling on billet. 06:15 08:45 2.50 8,200 8,310 INTRM1 DRILL DRLG T Drill ahead at 30 fph,with 1K WOB, 2.75bpm at 2845psi, BHP 3982, WHP 282, IA 8, OA 0 08:45 09:00 0.25 8,310 8,310 INTRM1 DRILL WPRT T 8310ft,Wiper up hole to 8156ft, PUW 40k, Dry drift billet area clean. RBIH to drill ahead. 09:00 10:00 1.00 8,310 8,410 INTRM1 DRILL DRLG T 8310ft, BOBD 2.7 bpm at 2850psi, BHP 4044,WHP 301, IA 16, OA 0 10:00 10:45 0.75 8,410 8,410 INTRM1 DRILL WPRT T 8410ft,Wiper up hole to 7850ft, PUW 40k 10:45 12:45 2.00 8,410 8,600 INTRM1 DRILL DRLG T 8410ft, BOBD 2.75 bpm at 2850psi, BHP 4050,WHP 290, IA 26, OA 0 12:45 13:00 0.25 8,600 8,600 INTRM1 DRILL WPRT T 8600ft,wiper up hole to 8300ft, PUW 41k 13:00 13:30 0.50 8,600 8,666 INTRMI DRILL DRLG T 8600ft, BOBD 2.79bpm at 3000psi, BHP 4024,WHP 254, IA 195,OA 0 13:30 14:30 1.00 8,666 8,666 INTRMI DRILL WPRT T 8666ft,Wiper up hole to 7870ft, PUW 38k 14:30 16:30 2.00 8,666 8,804 INTRMI DRILL DRLG T 8666ft, BOBD 2.8 bpm at 3000 psi, BHP 4019,WHP 273, IA 183,OA 0 16:30 16:39 0.15 8,804 8,804 INTRMI DRILL WPRT T 200'BHA wiper, PUW42K 16:39 17:09 0.50 8,804 8,825 INTRMI DRILL DRLG T 8804 ft, BOBD 2.8 bpm at 3062 psi, BHP 4019,WHP 275, IA 239,OA 0 17:09 17:21 0.20 8,825 8,825 INTRM1 DRILL WPRT T 200'BHA wiper, PUW 41K 17:21 18:06 0.75 8,825 8,894 INTRM1 DRILL DRLG T 8825ft, BOBD 2.75 bpm at 3113 psi, BHP 4019,WHP 270, IA 392, OA 0 18:06 20:24 2.30 8,894 8,894 INTRM1 DRILL DLOG T Log tie-in wiper trip. Plus 7' correction. 20:24 21:09 0.75 8,894 8,922 INTRMI DRILL DRLG T 8894 ft, BOBD 2.77 bpm at 3245 psi, BHP 4000,WHP 264, IA 398,OA 0 21:09 00:00 2.85 8,922 9,029 INTRMI DRILL DRLG P 8922 ft, BOBD 2.77 bpm at 3245 psi, BHP 4000,WHP 264, IA 398,OA 0 03/26/2015 Drilled lateral from 9029' to 9191'. POOH,changed out the motor and cleaned off the bellied up bit. 00:00 00:06 0.10 9,029 9,037 INTRM1 DRILL DRLG P 9029ft, BOBD 2.77 bpm at 3245 psi, BHP 4000,WHP 274, IA 398,OA 0 00:06 01:24 1.30 9,037 9,037 INTRM1 DRILL WPRT P 9037 ft,Wiper up hole to 8260 ft, PUW 44k Page 12 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:24 04:39 3.25 9,037 9,088 INTRM1 DRILL DRLG P 9037 ft, BOBD 2.78 bpm at 3245 psi, BHP 4000,WHP 276, IA 401, OA 0 04:39 05:54 1.25 9,088 7,860 INTRMI DRILL WPRT P 9037 ft, BOBD 2.78 bpm at 3245 psi, BHP 4000,WHP 276, IA 401,0A 0 05:54 06:54 1.00 7,860 9,088 INTRM1 DRILL WPRT P 9037 ft, BOBD 2.78 bpm at 3245 psi, BHP 4000,WHP 276, IA 401, OA 0 06:54 11:24 4.50 9,088 9,137 INTRM1 DRILL DRLG P 9037 ft, BOBD 2.78 bpm at 3245 psi, BHP 4000,WHP 276, IA 401, OA 0 11:24 12:18 0.90 9,137 9,137 INTRM1 DRILL WPRT P 9137ft, BHA wiper, pumping 10 bbls pill of Drill Zone. 12:18 18:36 6.30 9,137 9,178 INTRM1 DRILL DRLG P 9137 ft, BOBD 2.80 bpm at 3245 psi, BHP 4000,WHP 276, IA 450, OA 0 18:36 19:06 0.50 9,178 9,178 INTRM1 DRILL WPRT P 9181 ft, BHA wiper, pumping 10 bbls pill of Drill Zone. 19:06 20:12 1.10 9,178 9,186 INTRM1 DRILL DRLG P 9137 ft, BOBD 2.80 bpm at 3245 psi, BHP 4000,WHP 276, IA 450, OA 0 20:12 20:36 0.40 9,186 9,186 INTRM1 DRILL WPRT P 9181 ft, BHA wiper, pumping 10 bbis pill of Drill Zone mixed with beads. 20:36 22:36 2.00 9,186 9,191 INTRM1 DRILL DRLG P 9186 ft, BOBD 2.80 bpm at 3250 psi. 22:36 00:00 1.40 9,191 9,191 INTRMI DRILL TRIP P POOH with BHA#15 to check bit. PU wt 38K. 03/27/2015 LD drilling BHA#16, MU 37 jts liner and RIH and set it at 8900'. 00:00 00:12 0.20 9,191 82 INTRM1 DRILL TRIP P POOH with BHA#15 to check bit. PU wt 38K. 00:12 01:54 1.70 82 0 INTRM1 DRILL PULD P PJSM-LD BHA#15, 1.1°+AKO Motor and HYC 3 3/4"x 4.25" Bi-center bit. 01:54 03:00 1.10 0 82 INTRM1 DRILL PULD P PJSM-MU BHA#16, 1.0°+AKO Motor and HYC 3 3/4"x 4.25" Bi-center bit. Surface test. 03:00 05:30 2.50 82 7,600 INTRM1 DRILL TRIP P RIH with BHA#16. 05:30 05:45 0.25 7,600 7,600 INTRM1 DRILL DLOG P 7600ft,Tie into the K1 marker correction of plus 14ft. 05:45 06:15 0.50 7,600 9,164 INTRM1 DRILL TRIP P Continue RIH to bottom 06:15 06:30 0.25 9,164 9,164 INTRM1 DRILL TRIP P 9164ft, Stack out, PUW 55k 06:30 07:00 0.50 9,164 9,089 INTRM1 DRILL TRIP P 9164ft, PUH, make call to town on plan forward, 07:00 09:30 2.50 9,089 82 INTRM1 DRILL TRIP P 9098ft, pump 10x10 sweep and perform swab wiper. 09:30 11:00 1.50 82 7,600 INTRM1 DRILL TRIP P At surface,reset counters, RBIH 11:00 11:15 0.25 7,600 7,600 INTRM1 DRILL DLOG P 7600ft,Tie into the K1 marker correction of plus 5.5ft. 11:15 12:36 1.35 7,600 9,120 INTRM1 DRILL TRIP P 7600ft,continue RIH """"Note:Set down at the bottom of the window 8k, PUH, Run back through window at 18 fpm clean, continue RIH. 12:36 14:36 2.00 9,120 85 INTRMI DRILL DISP P 9120ft, Lay in liner running pill with bead up to the window. Displacing well to 12.0 ppg completion fliud without beads to surface, Painting EOP flags at 6500ft, and 7600ft. LPage13of31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:36 15:06 0.50 85 85 INTRM1 DRILL SFTY P At surface, check well for flow, PJSM for LD drilling BHA 15:06 16:06 1.00 85 0 INTRM1 DRILL PULD P LD drilling BHA#16 16:06 16:36 0.50 0 0 INTRM1 CASING SFTY P PJSM for MU liner assembly 16:36 18:36 2.00 0 1,173 INTRM1 CASING PULD P MU 37 jts of 3-1/2"solid liner with a composite cement retainer/ shoetrack and aluminum bullnose. The top 3 jts have cementralizers installed. 18:36 20:06 1.50 1,173 1,221 INTRM1 CASING PULD P PJSM and MU BHA. Surface test. 20:06 21:48 1.70 1,221 6,500 INTRM1 CASING RUNL P RIH with BHA#17 21:48 22:00 0.20 6,500 6,500 INTRM1 CASING RUNL P 6500'EOP flag,zero correction. Up wt 46K. 22:00 00:00 2.00 8,494 8,560 INTRM1 CASING RUNL P Tag up at 8494 and start working pipe in hole at various speed,pumps on and off. 03/28/2015 Finish running liner in to hole. Perform a full BOPE test. 00:00 02:36 2.60 8,560 8,900 INTRM1 CASING RUNL P Working pipe in hole at various speed,pumps on and off from 8560' to 8900'. PU to neutral wt and pressure up to 3000 psi to release liner. 02:36 04:06 1.50 8,900 48 INTRMI CASING RUNL P Pooh with liner setting BHA#17. 04:06 04:36 0.50 48 48 INTRM1 CASING PULD P At surface, check well for flow. 04:36 05:36 1.00 48 0 INTRM1 CASING PULD P LD liner setting BHA#17. 05:36 06:51 1.25 0 0 INTRM1 CASING PULD P MU nozzle and jet BOPE. 06:51 07:21 0.50 0 0 INTRM1 CASING PULD P Unstab INJH, RD nozzle and BHI checks. 07:21 09:36 2.25 0 0 INTRM1 CASING PULD P Flush surface lines, Grease BOP's and service tree. 09:36 21:36 12.00 0 0 INTRM1 WHDBO BOPE P BOPE test.Test waived by Matthew Herrera 9:25pm 3/26/15 21:36 22:36 1.00 0 0 INTRM1 CEMEN'CTOP P RD BOPE testing equipment, 22:36 00:00 1.40 0 INTRM1 CEMEN"PULD P Cut CTC off and boot end of a-line. 03/29/2015 M/U Cement BHA with stinger and RIH, Displace well to 8.6PPG fluid, Sting into retainer. Pump 10 BBIs 15.8PPG cement. Pump 8 BBIs then unsting from retainer, Pump remainder of cement. POOH filling coil voidage 00:00 00:18 0.30 0 0 INTRM1 CEMEN-PULD P PJSM about pumping slack forward. 00:18 02:33 2.25 0 0 INTRM1 CEMEN-PULD P Pumping slack forward.Cut 90'off. 02:33 03:33 1.00 0 0 INTRMI CEMEN-PULD P Change of plan. Pump slack back into reel. Cut coil to find e-line. Rehead and pump slack forward. 03:33 06:33 3.00 0 0 INTRM1 CEMEN-PULD P PJSM, Install CTC, pull test to 35k, install UQC, PT 4300psi, 06:33 08:33 2.00 0 0 INTRM1 CEMEN'PULD P MU nozzle,stab on INJH and displace coil to 12.0 ppg NaBr. 08:33 10:03 1.50 0 11 INTRM1 CEMEN-PULD P MU cementing BHA#18,pump one coil volume forward Page 14 of 31, Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:03 12:33 2.50 11 7,600 INTRM1 CEMEN-TRIPP RIH,with cementing BHA#18 with Fixed bladed Centralizer,weight bar, and snap-latch cementing stinger, 100 fpm circulating 0.3 bpm. 12:33 14:33 2.00 7,600 8,840 INTRMI CEMEN-TRIPP 7600ft,weight check 38k,slow down at the top of liner, 15 fpm,continue RIH to 8840ft 50'above CMT retainer. ****Note:Started stacking weight at 8823ft,stop coil, looks like we are in the high dog area of the hole,push on it, got weight back,continued in hole to 8400ft. 14:33 18:03 3.50 8,840 8,887 INTRM1 CEMEN"DISP P Displace liner to 9.8 ppg while POOH at 30 fpm, park at 7600ft and displace with 9.8". RBIH to 8886.57ft sting into the retainer,seen an pressure increase of 200 lbs. Set down 5k 8886.57ft.bring pump up to 1.0 bpm at 1259 psi, IA 0, OA 0 18:03 18:57 0.90 8,887 8,887 INTRM1 CEMEN-DISP P Crew change, run valave checklist, check SLB R/U to rig, PJSM with SLB cementers, Batch up cement @ weight 15.8© 18:55 18:57 19:27 0.50 8,887 8,887 INTRM1 CEMEN-DISP P Line up on pill pit and pump 4.3 BBIs 8.6 PPG mud to MM 19:27 19:51 0.40 8,887 8,887 INTRM1 CEMEN-DISPP S/D pump and line up to cement unit,WHP=579, IA=0, OA=0, Pump 5 BBIs Fresh water. S/D for cementers PT,4K, Line back up to coil 19:51 20:09 0.30 8,887 8,887 INTRM1 CEMEN-CMNT P Cementers on line with 15.8PPG cement, 1 BPM,2.34 BBIs between cemeters and rig MM, Pump 10 BBIs Cement,followed by 3 BBIs fresh, S/D and swap to rig pump 20:09 20:45 0.60 8,887 8,865 INTRM1 CEMEN-CMNT P Swap to rig pump and line up on 8.6PPG fluid,Vol in 12.9,34.9 BBIs in goto 9.8PPG Power vis, 20:45 20:51 0.10 8,865 8,879 INTRM1 CEMEN-CMNT P 41.7BBIs in, reset out micro motion, 49.7 BBIs, all cement pumped at one for one. S/D pump and unsting from cement retainer, PUW=38K, Pump one more BBI 20:51 23:45 2.90 8,879 50 INTRMI CEMEN-TRIPP POOH replace coil voidage, PUW=34K, Discuss WHP with Jason. Unable to get below—600 PSI,Continue out 23:45 00:00 0.25 50 0 INTRM1 CEMEN-TRIPP 50'from surface, Continue out following slimhole procedure 33/30/2015 Flush coil and pump inhibitor.Test wire-good. PT Cement-Fail. Blow down CT with N2. Remove coil from injector and secure to spool. Rig up to swap out Page 15 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:30 0.50 0 0 INTRM1 CEMENT PULD P Master shut, bleed off WHP and remove tools,Shut swabs. Open master and monitir MP line.Trip sheets out at one to one.WHP @ 620. Bleed off 100 psi pressure came right back up 00:30 06:00 5.50 0 0 INTRM1 CEMEN-WOC P WOC 06:00 11:00 5.00 0 0 INTRM1 CEMEN-WOC P Line up, mix inhibitor, and flush surface lines,Stage 2 inch parts for reel swap. 11:00 14:30 3.50 0 0 INTRM1 CEMEN-WOC P Call out SLB N2 pumpers from Deadhorse, Remove CTS counter, stage new brass, and pac-offs. Unboot wire and test cable>2kMeg/38 Ohmes 14:30 17:00 2.50 0 0 INTRM1 CEMEN-WOC P PJSM with SLB N2 Pumpers, R/U and blow down coil to TT.Shut down Rig down N2 17:00 18:00 1.00 0 INTRM1 CEMEN-PRTS P Pressure test cement, Pump up 200 PSI pressure bled right back down 18:00 00:00 6.00 INTRM1 CEMEN-CTOP P R/D inner reel iron, Dress coil and install internal grapple connector. Unstab coil from injector and secure to storage reel. Rig up spool to lifting rams 03/31/2015 Reel swap from 2 3/8"to 2"coil.Change out BOP rams and gooseneck rollers. Stab coil in injector head, MU inner reel iron,test bulkhead. Rehead coil connector and UQC,test. Load coil and test inner reel iron and pack-offs. Prep for BOP test. 00:00 06:00 6.00 0 0 INTRM1 CEMEN"CTOP P PJSM with Peak-Load out 2 3/8" coil to truck, P/U 2"CT string. Swap out brass in stuffing box, C/O injector gripper blocks, C/O horsehead rollers,Torque reel saddle clamps 06:00 19:15 13.25 0 0 INTRM1 CEMEN CTOP P PJSM, C/O BOP Rams and gooseneck rollers, Install stripper on injector and install packoff. Prep coil and install grapple, Stab coil in injector.M/U inner reel iron and pressure bulkhead. Meg test E-Line, good test. 19:15 23:30 4.25 0 0 INTRM1 CEMEN"CTOP P Rehead coil connector,and pull test. Rehead upper quick connect, meg test good. Load coil,pressure test inner reel iron,pack-offs. 23:30 00:00 0.50 0 0 PROD1 DRILL BOPE P Prep rig floor for BOP test. 34/01/2015 Finish prep for BOP test.Complete bi-weekly BOP test. PD BHA#19, RIH w/4.5"clean-out assembly to 7,590', in progress. 00:00 01:00 1.00 0 0 PROD1 DRILL BOPE P Continue prepping for BOP test,shell test to 4,900 psi. 01:00 13:00 12.00 0 0 PROD1 DRILL BOPE P Perform full BOP test 250/4900 psi, annular 2,500 psi. Test waived by AOGCC(Johnnie Hill)at 16:45 on 03-31-15. Page 16 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:00 18:00 5.00 0 0 PROD1 DRILL BOPE T Troubleshoot choke leaks. Change-out valves C5, C8,and C16. Retest. BOP test complete.Stab on wellhead,test inner iron and pack-offs. Start NAD NPT 5 Hrs 18:00 19:30 1.50 0 0 PROD1 DRILL RURD P PJSM. LD BOP test equipment,prep floor for pressure deployment. 19:30 22:00 2.50 0 0 PROD1 DRILL PULD P PJSM. MU/PU BHA#19 clean-out assembly. Pressure deployment BHA. 22:00 00:00 2.00 0 7,590 PROD1 DRILL TRIP P RIH w/4.5"clean-out assembly 34/02/2015 Make 4.5"liner clean-out run to 7,732'. Make 3.5"liner clean-out run to 8,700',milled continual cement from 8,500'to 8,700'. POOH for whipstock assembly. PUD BHA#20, PD BHA#21. RIH w/whipstock,whipstock became stuck @ 7,950',work pipe, in progress. 00:00 01:21 1.35 7,590 7,732 PROD1 DRILL TRIP P Continue in hole with clean-out assembly,tie-in K1 for+7' correction,close EDC. RIH watching for cement stringers,saw nothing. Shut down pump,dry tag TOL @ 7,732'.Open EDC,pump sweeps. 01:21 02:45 1.40 7,732 53 PROD1 DRILL TRIP P Chase sweeps to surface at max rate. 02:45 04:48 2.05 53 0 PROD1 DRILL PULD P PJSM. PUD BHA#19, LD BHA. 04:48 06:15 1.45 0 52 PROD1 DRILL PULD P PJSM. PD BHA#20 06:15 07:39 1.40 52 7,590 PROD1 DRILL TRIP P RIH w/3.5"clean-out assembly, EDC Open 07:39 07:45 0.10 7,590 7,618 PROD1 DRILL DLOG P Log K1 for+9' 07:45 07:57 0.20 7,618 7,700 PROD1 DRILL TRIP P Continue in 07:57 10:27 2.50 7,700 8,700 PROD1 DRILL MILL P Stop and shut EDC, PUW=34K, clean trip past liner top,first set down at 8024, stringers down to 8500 then constant milling to 8700' 10:27 11:03 0.60 8,700 8,700 PROD1 DRILL MILL P Recip across whipstock setting depth 8660 to 8700 while waiting for 10 X 10 sweeps 11:03 13:27 2.40 8,700 60 PROD1 DRILL TRIP P Chase sweeps to surface 13:27 14:57 1.50 60 0 PROD1 DRILL PULD P At surface, PJSM PUD BHA#20 3.5"liner clean out 14:57 16:15 1.30 0 0 PROD1 RPEQP1PULD P M/U Whipstock BHA#21 16:15 17:30 1.25 0 73 PROD1 RPEQPI PULD P PD BHA#21 Set Whipstock Page 17 of 31 d Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 00:00 6.50 73 7,950 PROD1 RPEQP1TRIP T RIH w/WS assembly,tie-in K1 for +8'correction,weight check above TOL @ 7,635'34K. Continue in hole, stack out @ 7,899'. PUW=37K. Make four more attempts,work WS to 7,926'. Call town,decide to POOH check BHA.Town change minds, decide to pump more lubes, RBIH. pump lubes around, start stacking and getting weight back @ 7,930', Work down to 7,950', not getting weight back,stuck @ 7,950',work pipe, pump on/off and different orientation, no luck. Discuss with town. 34/03/2015 Pull free from stuck whipstock @ 7,950'.POOH LD BHA#21,whipstock left in hole. RIH w/nozzle,jet above fish @ 7,940'max rate. POOH, LD BHA. RIH w/dummy whipstock assembly,drift to top of fish @ 7,940', no issues. POOH, LD BHA.RIH w/new whipstock assembly,set whipstock @ 7,911',TOWS 7,900'40 ROHS. 00:00 00:15 0.25 7,950 7,950 PROD1 RPEQPI TRIP T Start pulling on stuck BHA with pump off,eight cycles to 65K,pump on at 1 bpm, pull 70K, pull free, HOT tool still working. 00:15 01:30 1.25 7,950 80 PROD1 RPEQP1TRIP T POOH to check BHA. 01:30 02:45 1.25 80 0 PROD1 RPEQPI PULD T PJSM. PUD BHA#21, Check BHA, no whipstock, hard cemment in collars of setting tool, pictures of setting tool in folder on"S"drive. LD BHA. 02:45 03:45 1.00 0 0 PROD1 RPEQPI PULD T Wait on Baker fishing tools.Town decided to run nozzle first. 03:45 05:00 1.25 0 26 PROD1 RPEQPI PULD T PJSM. PU/MU nozzle assembly. 05:00 06:48 1.80 26 7,941 PROD1 RPEQPI TRIP T RIH w/nozzle assembly 06:48 07:48 1.00 7,941 7,941 PROD1 RPEQPI TRIP T On top of fishpump 2.07 BPM @ 3780,Pump 10 X 10 sweep, recip on top of fish 07:48 09:24 1.60 7,941 25 PROD1 RPEQP1TRIP T Trip out 09:24 09:42 0.30 25 0 PROD1 RPEQPI PULD T On Surface, PJSM, Lay down FCO BHA 09:42 11:00 1.30 0 0 PROD1 RPEQPI SVRG T Service/inspect injector&reel.Pull choke b apart 11:00 12:00 1.00 0 0 PROD1 RPEQP1WAIT T Conference call with town-explore options decide to prep hole and run second whipstock 12:00 13:30 1.50 0 71 PROD1 RPEQP1PULD T Crew change, PJSM, Make up BHA #23 with Dummy whipstock and Deploy 13:30 15:12 1.70 71 7,939 PROD1 RPEQP1TRIP T Trip in hole with BHA#23 Dummy Whipstock tie into K1 @ 7610 to 7637 for+11 15:12 16:24 1.20 7,939 7,700 PROD1 RPEQP1CIRC T Tag pinchpoint,Jet and recip to 7880 with sweeps, pumped second set of sweeps jetted 7939 to 7700'.2.1 BPM @ 4500 PSI 16:24 18:00 1.60 7,700 71 PROD1 RPEQP1TRIP T POOH at 2.09 BBIs/Min Page 18 of 31 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 19:30 1.50 71 0 PROD1 RPEQP1PULD T PJSM. PUD BHA#23, LD BHA 19:30 21:00 1.50 0 74 PROD1 RPEQP1PULD T PJSM. PD BHA#24 21:00 00:00 3.00 74 7,911 PROD1 RPEQP1TRIP T RIH w/whipstock assembly,tie-in K1 for+7.5'correction, continue in hole to set septh @ 7,910'. PUW=34K. RBIH to set depth, close EDC, pressure up to release from WS @ 4,100 psi,stack 4K down. TOWS @ 7,900'40 ROHS. 34/04/2015 POOH, LD BHA#24. PD BHA#25. RIH w/window milling assembly. Mill window from 7,900'to 7,905',milling in progress. 00:00 01:30 1.50 7,911 74 PROD1 RPEQP1TRIP P POOH for milling assembly. 01:30 04:00 2.50 74 72 PROD1 RPEQPIPULD P PJSM.PUD BHA#24, LD BHA. PJSM.PD BHA#25. 04:00 05:18 1.30 72 7,600 PROD1 WHPST TRIP P RIH w/window milling assembly, tie-in 05:18 05:36 0.30 7,600 7,643 PROD1 WHPST DLOG P Log K1 tie in for+5.5'correction 05:36 06:00 0.40 7,643 7,901 PROD1 WHPST TRIP P RIH to dry tag whipstock 06:00 15:00 9.00 7,901 7,904 PROD1 WHPST WPST P 7800, bring pumps on, 1.7 BPM @ 4000 PSI FS, BHP=3905, Call pinch point @ 7899.9 with motor work and DHWOB 15:00 16:48 1.80 7,904 7,905 PROD1 WHPST WPST P Confer with town,window going slowly,double check liner tally,way away from connection. Keep on, Pump up sample looking for dirt, Good supply of metal on magnets, 150 PSI motorwork 16:48 00:00 7.20 7,905 7,905 PROD1 WHPST WPST P P/U and restart, 1.52 BPM @ 3890 PSI FS, See DHWOB @ 7904.2. Only metal in sample. Slow going, several pick-ups, clean pick-ups, mainly metal across shakers. 34/05/2015 Continue milling window to 7,906'.POOH to check BHA. PUD BHA#25, PD BHA#26. Mill on window exit @ 7,906', no progress made.POOH.Wait on new orders from town, make clean-out run to 7,890'with dummy drift.Start out hole with BHA#27. 00:00 04:54 4.90 7,905 7,906 PROD1 WHPST WPST P Continue milling whiptock @ 7,905'. Cut pump rate to 1.53 BPM @ 3,650 PSI, BHP=3950 PSI, CTW=10K, WOB=4K. Restart several times, metal across shaker. 04:54 06:12 1.30 7,906 77 PROD1 WHPST TRIP T Forward progress stopped,Trip out to inspect BHA 06:12 08:12 2.00 77 0 PROD1 WHPST PULD T At surface, PUD BHA#25. Bit shows little evidence of crossing centerline. Motor tight and holding fluid. Check scribe down tool string good. Mill out @ 2.79 No Go 08:12 09:24 1.20 0 73 PROD1 WHPST PULD T M/U BHA#26 with 0°motor,new 2.80 window mill,new string reamer and pressure deploy 09:24 10:48 1.40 73 7,610 PROD1 WHPST TRIP T Trip in hole, EDC open Page 19 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:48 11:00 0.20 7,610 7,640 PROD1 WHPST DLOG T Log K1 for+4.5'correction,close EDC 11:00 11:18 0.30 7,640 7,905 PROD1 WHPST TRIP T Continue in well,dry tag @ 7905.81 11:18 15:18 4.00 7,905 7,906 PROD1 WHPST MILL T Bring pumps on 1.53 BPM @ 3450 PSI FS, BHP=3900, Getting DHWOB with no motorwork, Run at it to get motor work-150 PSI 15:18 16:36 1.30 7,906 80 PROD1 WHPST TRIP T Making no progress, no metal coming out, POOH 16:36 18:00 1.40 80 81 PROD1 WHPST PULD T At Surface, PJSM, PUD BHA#26, service injector and reel. 18:00 20:00 2.00 81 0 PROD1 WHPST PULD T Waiting new marching orders from town. 20:00 21:00 1.00 0 72 PROD1 WHPST PULD T PJSM. MU BHA#27, PD BHA. 21:00 23:30 2.50 72 7,890 PROD1 WHPST TRIP T RIH w/Dummy drift/nozzle,tie-in to K1 for+4.5'correction, continue in hole, no issues. Pump bottoms up at max rate 1.9 bpm @ 4,300 psi, clean 3.5"liner. 23:30 00:00 0.50 7,890 6,370 PROD1 WHPST TRIP T Start out of hole. 34/06/2015 POOH w/BHA#27, PUD BHA. PD BHA#28,Set 3.5"Monobore whipstock @ 7,875'. POOH and PUB BHA#28. PD BHA#29, RIH w/magnets and LIB,tag whipstock @ 7,877', POOH, PUD BHA#29. PD BHA #30, RIH w/milling assembly,dry tag whipstock 7,876',start milling window exit, in progress. 00:00 01:15 1.25 6,370 78 PROD1 WHPST TRIP T Continue out of hole with BHA#27. 01:15 02:30 1.25 78 0 PROD1 WHPST PULD T PJSM. PUD BHA#27 02:30 03:30 1.00 0 73 PROD1 RPEQP1 PULD T PJSM. MU BHA#28, PD BHA. 03:30 05:36 2.10 73 7,613 PROD1 RPEQP1 TRIP T RIH w/Whipstock assembly,tie-in 05:36 05:42 0.10 7,613 7,641 PROD1 RPEQP1 DLOG T Log K1 for+5'correction 05:42 06:24 0.70 7,641 7,886 PROD1 RPEQPI TRIP T Continue in to set depth @ 7885.5, TOWS=7875 @ 20L,see tool shift @ 4200PSI,Set down 4K Looks good 06:24 07:42 1.30 7,886 78 PROD1 RPEQP1TRIP T Trip out after setting whipstock 07:42 08:30 0.80 78 0 PROD1 RPEQP1 PULD T At surface, PJSM PUD BHA#29 Whipstock setting tools 08:30 10:00 1.50 0 0 PROD1 WHPST WAIT T Waiting on Magnets from Deadhorse 10:00 11:06 1.10 0 67 PROD1 WHPST PULD T PJSM, P/U BHA#29, Magnets and 2.50 LIB 11:06 12:30 1.40 67 7,600 PROD1 WHPST TRIP T Trip in hole, EDC open 12:30 12:36 0.10 7,600 7,633 PROD1 WHPST DLOG T Tie into K1 for+5.5 12:36 12:48 0.20 7,633 7,878 PROD1 WHPST TRIP T Continue in with LIB,Tag @ 7877.87, see 2.6K DHWOB 12:48 14:00 1.20 7,878 75 PROD1 WHPST TRIP T Trip out of well 14:00 15:12 1.20 75 0 PROD1 WHPST TRIP T At surface,Tag up and space out, PJSM PUD BHA#29 15:12 16:00 0.80 0 0 PROD1 WHPST WAIT T Pics on LIB to S Drive,clean magnets, formulate plan forward 16:00 17:15 1.25 0 71 PROD1 WHPST PULD T PJSM, M/U and deploy BHA#30.6° motor and 2.80 window mill Page 20 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:15 19:21 2.10 71 7,877 PROD1 WHPST TRIP T RIH w/millinf assembly,tie-in to K1 for+5'correction,continue in hole. PUW=34K. Dry tag whipstock @ 7,876.7'. 19:21 00:00 4.65 7,877 7,879 PROD1 WHPST WPST T Start stick milling window: 1.50 bpm @ 3,775 psi, BHP=3,960 psi, CTW=12.4K,WOB=2.5K. 04/07/2015 Mill window exit from 7,876'to 7,880'. Progress not being made on window. POOH, PD BHA#30, LD BHA. Rig maintenance. PD BHA#31, RIH w/caliper assembly, log CCL from 7,600'to 7,865'. Log caliper survey from 7,880'to 6,980'. POOH and PUD BHA#31, LD BHA. Download caliper data, send for processing. Waiting on orders. 00:00 03:00 3.00 7,879 7,880 PROD1 WHPST WPST T Continue milling window exit. 1.52 bpm @ 3,740', BHP=3,924 psi, CTW=11 K,WOB=2.7K. have motor work, but progress is slowing down. 03:00 07:06 4.10 7,880 7,880 PROD1 WHPST WPST T Continue milling window: 1.53 bpm @ 3,725 psi, BHP=3,920 psi. CT1N=11.5K,WOB=3K. Progress is slowing down, made about 4'total: 07:06 08:42 1.60 7,880 71 PROD1 WHPST WPST T 7880,Trip out for something else, PUW=33.5K 08:42 12:00 3.30 71 0 PROD1 WHPST PULD T PJSM-Un-deploy and LD 2.6BHA #30, P/T BHA and CTC,good, mill gauge 2.79"no-go,good shape, no damage or indication of wear to BHA, wait on PDS tools. 12:00 12:30 0.50 0 0 PROD1 WHPST SFTY T PDS tools on site, rig orientation for new to rig hand. 12:30 13:30 1.00 0 0 PROD1 WHPST PULD T Confirm plan forward caliper BHA set up, program tools,set timer for tool to open. 13:30 14:54 1.40 0 59 PROD1 WHPST PULD T PJSM-MU/Deploy BHA#31,tool set to open at 19:12. 14:54 16:00 1.10 59 7,595 PROD1 WHPST TRIP T RIH with caliper BHA#31. 16:00 16:45 0.75 7,595 7,865 PROD1 WHPST DLOG T Log K1 marker,plus 5-ft correction, PUW 32k, RBIH,CCL log from 7,600' to 7,865'@ 20 fpm..75 16:45 19:30 2.75 7,865 7,880 PROD1 WHPST TRIP T RBIH to 7,870'.Waiting on caliper to engage. RIH to 7,880'. 19:30 21:00 1.50 7,880 63 PROD1 WHPST DLOG T TOOH logging caliper survey @ 50 fpm to 6,980'. Caliper arms released, POOH at normal spped. 21:00 22:30 1.50 63 0 PROD1 WHPST PULD T PJSM. PUD BHA#31, LD Caliper BHA. 22:30 00:00 1.50 0 0 PROD1 WHPST WAIT T Waiting on orders. Download caliper data,send for processing, rig maintenance. 34/08/2015 Waiting on caliper survey.Waiting on orders,decide to run another whipstock,wait on whipstock assembly. RIH w/BHA#32 whipstock with OH anchor assembly, in progress. 00:00 06:30 6.50 0 0 PROD1 WHPST WAIT T Continue waiting on orders,process Caliper data, monitored MP. 06:30 07:00 0.50 0 0 PROD1 WHPST BOPE T PJSM-Function test BOPE 07:00 15:00 8.00 0 0 PROD1 WHPST WAIT T Continue waiting on orders, rig maintenance,monitor MP. Page 21 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 16:15 1.25 0 0 PROD1 RPEQP1PULD T PJSM-Un load and reconfigure BHI tools, pre load DS PDL for whistock run. 16:15 20:00 3.75 0 0 PROD1 RPEQPI WAIT T Waiting on whipstock from Prudhoe, rig maintenance, monitor MP. 20:00 21:54 1.90 0 74 PROD1 RPEQPI PULD T PJSM. PU/MU/PD BHA#32 Whipstock assembly 21:54 00:00 2.10 74 7,610 PROD1 RPEQP1TRIP T RIH w/Whipstock OH anchor assembly 04/09/2015 Set whipstock @ 7,862.5,TOWS @ 7,852'. POOH. PUD BHA#32, PD BHA#33. RIH w/milling assembly, dry tag whipstock @ 7,851', mill window exit from 7,851'to 7,857'. Drill rahole from 7,857'to 7,866', back ream window,dry drift clean. POOH. PUD BHA#33, PD BHA#34, RIH w/build section drilling assembly, in progress. 00:00 00:39 0.65 7,610 7,862 PROD1 RPEQP1TRIP T Continue in hole with whipstock, tie-in to K1 for+6'correction. RBIH to set depth, PUW=35K,set depth 7,862.3'TOWS @ 7,852', release from WS @ 4,200 psi,stack 4K down. 00:39 02:00 1.35 7,862 74 PROD1 RPEQPI TRIP T POOH for milling assembly 02:00 04:15 2.25 74 72 PROD1 RPEQP1PULD T PJSM. PUD BHA#32, LD BHA. PJSM. PD BHA#33. 04:15 06:09 1.90 72 7,851 PROD1 WHPST TRIP T RIH w/milling assembly,tie-in for plus 5-ft correction, continue in hole. 06:09 12:18 6.15 7,851 7,854 PROD1 WHPST WPST T 7,851.2-ft, Dry tag top of whipstock, PUW 34k, bring up pump 1.54 bpm at 3,712 psi, begin time milling window 1.54 bpm at 4,010 psi, BHP 3,934 psi, CWT 12.4k,WOB 1.2k 12:18 13:39 1.35 7,854 7,855 PROD1 WHPST WPST T 7,854.2-ft,time milling 1.54 bpm at 4,046 psi, BHP 3,957 psi, CWT 12.4k,WOB 3.4k, IA 0, OA 0, lots of metal across shaker. 13:39 15:33 1.90 7,855 7,857 PROD1 WHPST WPST T 7,855-ft, decrease of WOB, continue milling 1 fph, 1.55 bpm at 3,850 psi, BHP 3,956 psi, CWT 13.5k,WOB 0.8k for 2-ft 15:33 16:57 1.40 7,857 7,866 PROD1 DRILL DRLG T 7,857-ft, Drill rathole 1.55 bpm at 3,880 psi, BHP 3,958 psi, CWT 11k, WOB 2.4k. 16:57 18:06 1.15 7,866 7,866 PROD1 DRILL REAM T 7,866-ft, TD rat hole, Back ream window area as per plan, highside, 30L,and 30R.60fph,dry drift window area at 15 fph clean,tag TD at 7,866-ft. 18:06 19:33 1.45 7,866 78 PROD1 DRILL TRIP T POOH w/BHA#33 19:33 23:12 3.65 78 72 PROD1 DRILL PULD T PJSM. PUD BHA#33, LD BHA, string&window mill both mic'd at 2.79" NO-GO. PJSM. PD BHA#34 23:12 00:00 0.80 72 4,150 PROD1 DRILL TRIP T Start in hole with build asembly 04/10/2015 Drill build section to TD @ 7,995'. POOH. PUD BHA#34. PD BHA#35. Drill B lateral from 7,995'to 8,545', in progress. __ Page 22 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:15 2.25 4,150 7,866 PROD1 DRILL TRIP T Continue in hole with build section assembly,start pumping new 10 ppg mud system @ 4,300'.Tie-in to K1 for+5.5'correction,tag up @ 7,866'. New mud around, 02:15 08:39 6.40 7,866 7,995 PROD1 DRILL DRLG T BOBD: 1.35 BPM @ 4,160 PSI, BHP=4,060 PSI, CTW=11.8K, WOB=1.85K, ROP=40. bit balling at 7,950-ft, pump 30 bbl 5%DrillZone pill 08:39 09:30 0.85 7,995 7,885 PROD1 DRILL DLOG T 7,995-ft, Build TD'd, PUW 33k,Tie in to K1, 0-ft correction, RBIH Log RA tag,TOW 7,851-ft, BOW 7,855-ft, RA 7,858-ft 09:30 11:00 1.50 7,885 72 PROD1 DRILL TRIP T TOOH with BHA#34 11:00 13:00 2.00 72 0 PROD1 DRILL PULD T PJSM-Un-deploy/Crew changeout, PJSM- LD BHA#34, bit 2-1-BF-N-X-I-PN-BHA,change out check valves. 13:00 14:12 1.20 0 72 PROD1 DRILL PULD T PJSM-MU/Deploy BHA#35, .8° AKO motor and HYC Bi-center bit, surface test. 14:12 16:00 1.80 72 7,995 PROD1 DRILL TRIP T RIH with BHA#35, EDC open, plus 5-ft correction at K1, PUW 33k, continue in hole. 16:00 18:15 2.25 7,995 8,190 PROD1 DRILL DRLG T 7,995-ft, OBD 1.36 bpm at 4,320 psi, BHP 4,106 psi, CWT 12.6k, WOB 1.6k, ROP 80, IA 0,OA 0. 18:15 18:45 0.50 8,190 8,190 PROD1 DRILL WPRT T Wiper to window, PUW=34K, RBIH. 18:45 21:15 2.50 8,190 8,390 PROD1 DRILL DRLG T DOBD: 1.38 BPM @ 4,430 PSI, BHP=4,135 PSI, CTW=12K, WOB=1.3K, ROP=80. 21:15 22:00 0.75 8,390 8,390 PROD1 DRILL WPRT T Wiper to window, PUW=35K, RBIH. 22:00 00:00 2.00 8,390 8,545 PROD1 DRILL DRLG T DOBD: 1.38 BPM @ 4,330 PSI, BHP=4,135 PSI, CTW=11.8K, WOB=1.1K, ROP=70. 34/11/2015 Drill ahead B lateral from 8,545'to 9,790',drilling in progress. 00:00 00:36 0.60 8,545 8,590 PROD1 DRILL DRLG T Continue drilling: 1.38 BPM @ 4,410 PSI, BHP=4,145 PSI, CTW=10.6K, WOB=1.5K, ROP=90. 00:36 02:06 1.50 8,590 8,590 PROD1 DRILL WPRT T Pump sweeps, PUW=35K,wiper trip for tie-in, +1'correction,jet liner max rate, RBIH. 02:06 04:21 2.25 8,590 8,790 PROD1 DRILL DRLG T DOBD: 1.39 BPM @ 4,480 PSI, BHP=4,165 PSI, CTW=11.5K, WOB=1.2K, ROP=80. Note: Off trouble time at 8,670-ft/ 03:00 am. 04:21 05:00 0.65 8,790 8,790 PROD1 DRILL WPRT P Wiper to window, PUW=34K, RBIH. 05:00 07:48 2.80 8,790 8,990 PROD1 DRILL DRLG P DOBD: 1.40 BPM @ 4,430 PSI, BHP=4,180 PSI, CTW=11K, WOB=1.4K, ROP=95. Page 23 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:48 08:45 0.95 8,990 8,990 PROD1 DRILL WPRT P 8,990-ft, Wiper up hole to 8,000-ft, PUW=35K. RBIH 08:45 11:15 2.50 8,990 9,190 PROD1 DRILL DRLG P 8,990-ft OBD 1.4 bpm at 4,404 psi, BHP 4,202 psi, CWT 10.2k,WOB 1.6k, ROP 90, IA 174, OA 0 11:15 13:15 2.00 9,190 9,190 PROD1 DRILL WPRT P Wiper up hole for tie in, pump sweeps, PUW 35k,jet liner, RBIH, plus 3-ft correction at RA. 13:15 16:03 2.80 9,190 9,390 PROD1 DRILL DRLG P 9,190-ft OBD 1.37 bpm at 4,410 psi, BHP 4,206 psi, CWT 9.0k,WOB 1.6k, ROP 85, IA 220, OA 0 16:03 17:00 0.95 9,390 9,390 PROD1 DRILL WPRT P Wiper up hole, PUW 35k, RBIH. 17:00 19:27 2.45 9,390 9,590 PROD1 DRILL DRLG P DOBD: 1.38 BPM @ 4,480 PSI, BHP=4,220 PSI, CTW=8.5K, WOB=1.4K, ROP=80. 19:27 20:30 1.05 9,590 9,590 PROD1 DRILL WPRT P Wiper to window, PUW=35K, RBIH. 20:30 22:30 2.00 9,590 9,790 PROD1 DRILL DRLG P DOBD: 1.37 BPM @ 4,505 PSI, BHP=4,250 PSI, CTW=7.5K, WOB=1.0K, ROP=100. 22:30 00:00 1.50 9,790 9,450 PROD1 DRILL WPRT P Wiper up hole for tie in, pump sweeps, PUW 36k,jet liner, RBIH, plus 4-ft correction. Start pumping new mud system. 04/12/2015 Drill ahead B lateral from 9,790'to called early TD @ 10,327'.Wiper trip to swab,jet 4.5"tubing at 30 fpm. Reset depth, start RBIH corrected TD. 00:00 00:21 0.35 9,450 9,790 PROD1 DRILL WPRT P Continue RBIH after tie-in wiper. New mud around. 00:21 02:30 2.15 9,790 9,990 PROD1 DRILL DRLG P DOBD: 1.40 BPM @ 4,420 PSI, BHP=4,280 PSI, CTW=6.2K, WOB=1.3K, ROP=95. 02:30 03:39 1.15 9,990 9,990 PROD1 DRILL WPRT P Wiper to window, PUW=36.5K, RBIH. 03:39 06:48 3.15 9,990 10,119 PROD1 DRILL DRLG P DOBD: 1.40 BPM @ 4,380 PSI, BHP=4,250 PSI, CTW=5.5K, WOB=1.4K, ROP=90,weight transfer problems starting at 10,060-ft,work to 10,119-ft after a couple BHA wipers,several pick ups, all PUW's 34k and clean. 06:48 07:21 0.55 10,119 9,000 PROD1 DRILL WPRT P 10,119-ft, Wiper up hole, PUW 34k. 07:21 07:51 0.50 9,000 10,119 PROD1 DRILL WPRT P 9,000-ft, Wiper back in hole, RIW 10k. 07:51 09:39 1.80 10,119 10,221 PROD1 DRILL DRLG P 10,119-ft OBD 1.4 bpm at 4,364 psi, BHP 4,295 psi, CWT 3.0k,WOB 1.6k, ROP 70, IA 413, OA 0, negitive 5k CWT,WOB.3k, no motor work 09:39 13:06 3.45 10,221 10,221 PROD1 DRILL WPRT P Early wiper up hole for tie in, pump sweeps, PUW 34k,jet liner at full rate, RBIH,plus 3.5-ft correction at RA, RIW 10k. _ Page 24 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:06 16:21 3.25 10,221 10,321 PROD1 DRILL DRLG P 10,221-ft, OBD 1.36 bpm at4,401 psi, BHP 4,326 psi, CWT 7.2k,WOB 1.4k, ROP 70, IA 362, OA 0. Lost push, retry six times, loosing WOB. Continue drilling, restart several times. 16:21 16:51 0.50 10,321 10,321 PROD1 DRILL WPRT P 500'wiper trip, PUW=35K, RBIH. 16:51 17:06 0.25 10,321 10,327 PROD1 DRILL DRLG P Drill ahead same parameters, no string weight or WOB. 17:06 17:42 0.60 10,327 9,050 PROD1 DRILL WPRT P Another wiper to window, PUW=35K. Town decided to call TD @ 10,327'. 17:42 22:57 5.25 9,050 76 PROD1 DRILL WPRT P Wiper to top 3.5"liner @ 7,732'.Jet 4.5"tubing max rate at 30 fpm to swab. 22:57 00:00 1.05 76 4,895 PROD1 DRILL TRIP P Reset depth. RBIH for corrected TD. 04/13/2015 Tag corrected TD @ 10,328'. POOH laying in completion fluids,flow check. LD BHA#35. PU/MU liner assembly,MU BHA. RIH w/BHA#36 B lateral liner assembly,set liner @ 10,327',TOL @ 8,770'. POOH, LD BHA#36. Start BOP test, in progress. 00:00 02:30 2.50 4,895 10,328 PROD1 DRILL TRIP P Continue in hole for corrected TD, tie-in to K1 for+5'correction,tag TD @ 10,328'. PUH,start pumping beaded pill. 02:30 05:39 3.15 10,328 73 PROD1 DRILL DISP P POOH laying in liner pill/completion fluid 05:39 06:15 0.60 73 73 PROD1 DRILL OWFF P Monitor well for flow. 06:15 07:00 0.75 73 0 PROD1 DRILL PULD P PJSM-LD BHA#35, bit 2-1-BT-N-X-I-BU-TD 07:00 10:15 3.25 0 1,456 COMPZ CASING PUTB P PJSM-Prep floors for running liner, MU bullnose,XO,45 jts of 2 3/8" slotted,XO, 3 pup jts, aluminum liner top billet, LD liner running equipment. 10:15 11:33 1.30 1,456 1,501 COMPZ CASING PULD P PJSM-MU Liner assembly to BHA #36, CoilTrak, surface test. 11:33 14:27 2.90 1,501 10,327 COMPZ CASING RUNL P RIH with 2 3/8"slotted liner assembly on BHA#36 pumping minimum rate, plus 1.3-ft at flag, PUW 36k,continue in hole pumps off. 14:27 14:39 0.20 10,327 8,870 COMPZ CASING RUNL P On depth, PUW 39k, stack 5k,on line 1.4 bpm, PUW 36k, no difference in WOB wieght, on line 1.4 bpm, RBIH and stack 5k at at 10,224-ft, PUW 36k, 2k WOB change, liner released,correct counter to BHA depth. 14:39 16:48 2.15 8,870 44 COMPZ CASING TRIP P TOOH, Tie into RA, plus 2-ft correction,top of liner at 8,870-ft, continue out of hole. 16:48 17:18 0.50 44 44 COMPZ CASING OWFF P Monitor well for flow, PJSM-LD of BHA. 17:18 18:18 1.00 44 0 COMPZ CASING PULD P LD BHA#36 Page 25 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:18 22:00 3.70 0 0 PROD2 WHDBO RURD P PJSM-Prep for BOPE test. Flush stack, PT inner reel valve and pack-offs. Grease tree valves and stack. 22:00 00:00 2.00 0 0 PROD2 WHDBO BOPE P Start BOP test, 250/4,900 psi, annular 2,500 psi. Test waived by AOGCC(Jeff Jones)@ 05:40 on 04-13-15. 04/14/2015 Complete BOP test, Kick off of billet at 8865ft, and drill ahead to 9233ft. 00:00 05:30 5.50 0 0 PROD2 WHDBO BOPE P Complete BOP test 250/4,900 psi, annular 2,500 psi.Teat waived by AOGCC(Jeff Jones)at 05:40 on 04-13-15. 05:30 06:15 0.75 0 0 PROD2 STK DISP P Displace coil back to KWF. 06:15 07:30 1.25 0 72 PROD2 STK PULD P PJSM. MU BHA#37, MU to Coil Trak, surface test. 07:30 08:51 1.35 72 7,610 PROD2 STK TRIP P RIH with BHA#37, 0.8 AKO motor and HYC Bi-center bit pumping drilling fluid minimum rate. 08:51 09:30 0.65 7,610 7,630 PROD2 STK DLOG P Tie in to K1, plus 4-ft correction, PUW 35k,continue up to prime pump#2. RBIH 09:30 11:12 1.70 8,867 7,720 PROD2 STK DISP P 8,867-ft, Dry tag billet, PUH displaceing out completion fluid to 10 ppg drilling fluid, PUW 32k. 11:12 11:21 0.15 7,720 7,710 PROD2 STK CIRC P Perform choke calibration, 1.45 bpm at 4,075 psi,WH 340 psi, BHP 3,880 psi, EDC 11.9. 11:21 11:54 0.55 7,710 8,866 PROD2 STK TRIP P Continue in hole 11:54 14:51 2.95 8,866 8,895 PROD2 STK KOST P 8,866.4-ft,Tag top of billet, PUW 37k, begin time milling off billet 1.44 bpm at 4,167 psi, BHP 4,025, CWT 11.4k,WOB 1.8k, IA 10, OA O. 14:51 15:15 0.40 8,895 8,895 PROD2 STK KOST P 8,895-ft, Pick up hole to drift billet, PUW 36k to 8,855-ft, RBIH,dry drift, clean down through billet. 15:15 20:00 4.75 8,895 9,090 PROD2 DRILL DRLG P 8„895-ft, OBD 1.44 bpm at 4,180 psi, BHP 4,048 psi, CWT 10.4k, WOB 1.6k, ROP 40, IA 51, OA 0. 20:00 21:00 1.00 9,090 9,090 PROD2 DRILL WPRT P 9090ft,Wiper up hole 8050ft, PUW 35k 21:00 23:00 2.00 9,090 9,290 PROD2 DRILL DRLG P 9090ft, BOBD 1.45 bpm at 4140 psi, BHP 4057,WHP 319, IA 211, OA 0 23:00 23:30 0.50 9,290 9,290 PROD2 DRILL WPRT P 9290ft,Wiper up hole to 8290ft, PUW 35k 23:30 00:00 0.50 9,290 9,322 PROD2 DRILL DRLG P 9290ft, BOBD 1.45 bpm at 4000 psi, BHP 4043,WHP 300, IA 205, OA 0 34/15/2015 Drilled ahead from 9233ft to 10220ft 00:00 02:00 2.00 9,322 9,490 PROD2 DRILL DRLG P 9233ft, OBD 1.40 bpm at 4291 psi, BHP 4079,WHP 305, IA 249,OA 0, 1.7k WOB, ROP 77 fph. 02:00 02:48 0.80 9,490 7,880 PROD2 DRILL WPRT P 9490ft,Wiper up hole to 7875ft, PUW 34k 02:48 03:03 0.25 7,880 7,895 PROD2 DRILL DLOG P 7880ft,tie into the RA marker correction of plus 5.0ft. Page 26 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:03 03:48 0.75 7,895 9,490 PROD2 DRILL WPRT P 7895ft,Wiper back in hole to bottom. RIW 14k 03:48 05:57 2.15 9,490 9,690 PROD2 DRILL DRLG P 9490ft, BOBD 1.4 bpm at 4030 psi, BHP 4030,WHP 248, IA 249,OA 0 05:57 07:06 1.15 9,690 9,690 PROD2 DRILL WPRT P 9,690-ft,Wiper up hole to 8,490ft, PUW 34k, RBIH. 07:06 09:36 2.50 9,690 9,890 PROD2 DRILL DRLG P 9,690-ft, OBD 1.43 bpm at 4,226 psi, BHP 4,088 psi,WHP 257,CWT 8.2k,WOB 1.6k, ROP 80, IA 339, OA 0. Note: Mud swap with new mud at bit at 9,800-ft. 09:36 10:33 0.95 9,890 9,890 PROD2 DRILL WPRT P 9,890-ft,Wiper up hole to 8,990ft, PUW 34k, RBIH. 10:33 12:18 1.75 9,890 10,021 PROD2 DRILL DRLG P 9,890-ft, OBD 1.42 bpm at 4,144 psi, BHP 4,085 psi,WHP 361,CWT 8.1k,WOB 1.4k, ROP 60, IA 374, OA 0.attempt to get more WOB for drillers directional help, CWT Ok, WOB 2k, pull early wiper,getting a lot of aluminum in cuttings samples from 9,500-ft. 12:18 14:39 2.35 10,021 3,952 PROD2 DRILL WPRT P 10,021-ft, Early wiper for tie in and hole cleaning, PUW 33k, pull up into liner, open EDC,wiper up 1.74 bpm at 4,175 psi,60 fpm,2 bottoms up, more sand than aluminum in cuttings. 14:39 16:36 1.95 3,952 10,021 PROD2 DRILL WPRT P 3,952-ft, Wiper back in hole, close EDC,weight check 34k, sat down at 7,854-ft, PU 35k, RBIH 20 fph, clean thru billet, tie in to RA, plus 5-ft correction,continue in hole RIW 12k 16:36 20:06 3.50 10,021 10,220 PROD2 DRILL DRLG P 10,021-ft, OBD 1.43 bpm at 4,363 psi, BHP 4,098 psi,WHP 338, CWT 3.2k,WOB 1.8k, ROP 100, IA 302, _ _OA O. 20:06 21:06 1.00 10,220 7,955 PROD2 DRILL WPRT P 10220ft,Wiper up hole to 7955ft, PUW 33k 21:06 21:36 0.50 7,955 8,700 PROD2 DRILL WPRT P 7955ft, RBIH to TOB, pump 10x10 sweep """"Note:TD was called per JB and Geo's. 10220ftMD unconfirmed. 21:36 00:00 2.40 8,700 4,896 PROD2 DRILL WPRT P 8700ft, Continue wiper up hole, POOH at 30 fpm pump max rate 1.47 bpm at 4212 psi _ 34/16/2015 Drilled BL1 lateral to TD 10220ft,performed swab wiper, confirmed TD, POOH, MU slotted liner completion with 46 jts of slotted liner with Open Hole Anchored Billet. 00:00 01:00 1.00 4,896 244 PROD2 DRILL WPRT P Continue swab wiper up hole 01:00 01:15 0.25 244 550 PROD2 DRILL WPRT P Perform Jog RIH at 120 fpm 244ft- 550ft -- - _ Page 27 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:15 01:30 0.25 550 72 PROD2 DRILL WPRT P Continue swab wiper up hole to tag up. ****Note: Seen increase in cuttings/MW out at shaker after performing jog. 01:30 02:51 1.35 72 7,610 PROD2 DRILL TRIP P Reset counters, RBIH 02:51 03:06 0.25 7,610 7,629 PROD2 DRILL DLOG P 7610ft,tie into the K1 marker correction of plus 4.5ft 03:06 04:06 1.00 7,629 10,220 PROD2 DRILL TRIP P Continue RIH to confirm TD 10220ft. 04:06 07:51 3.75 10,220 71 PROD2 DRILL DISP P POOH laying in 12.0 ppg completion fluid with beads up to the window. 07:51 08:21 0.50 71 71 PROD2 DRILL OWFF P Monitor well for flow. PJSM-LD BHA 08:21 09:00 0.65 71 0 PROD2 DRILL PULD P LD BHA#37, bit 1-1-BU-G-X-I-NO-TD 09:00 11:30 2.50 0 1,459 COMPZ CASING PUTB P PJSM-prep floors, MU bull nose, XO,45 jts slotted,XO, 3 pup jts, OH anchored billet, LD liner equipment. 11:30 12:30 1.00 1,459 1,520 COMPZ CASING PULD P PJSM-MU BL1 liner assembly to BHA#38, MU to CoilTrak,surface test. 12:30 15:18 2.80 1,520 10,217 COMPZ CASING RUNL P RIH with BL1 liner assembly on BHA #38, EDC open,tie in at flag plus .7-ft, continue in hole 15:18 15:30 0.20 10,217 8,757 COMPZ CASING RUNL P 10,217-ft, Tag up, PUW 39k, on depth, release off liner at 3,400 psi, PUW 36k, reset counters to BHA depth 15:30 17:15 1.75 8,757 61 COMPZ CASING TRIP P 8,757-ft, POOH for kick off assembly. 17:15 18:00 0.75 61 61 COMPZ CASING OWFF P Monitor well for flow, crew change out. 18:00 19:00 1.00 61 0 COMPZ CASING PULD P LD Liner setting tools, load out BOT tools. 19:00 20:00 1.00 0 72 PROD3 STK PULD P MU kickoff/drilling BHA#39 20:00 21:15 1.25 72 7,610 PROD3 STK TRIP P RIH, BHA#39 with rebuilt Hughes bi-center bit 21:15 21:30 0.25 7,610 7,629 PROD3 STK DLOG P 7610ft,tie into the K1 marker correction of plus 4.0ft,WC 21:30 22:00 0.50 7,629 8,740 PROD3 STK TRIP P 7629ft, Continue RIH through window to TOB, 22:00 00:00 2.00 8,740 8,740 PROD3 STK DISP P Displace well to drilling fluid J4/17/2015 MU kickoff/drilling BHA#39, kickoff at 8758ft, drilled ahead BL2 lateral to 9672ft 00:00 00:30 0.50 8,740 8,758 PROD3 STK TRIP P Finished displacing well to drilling fluid, continue tripping in hole to tag billet. ****Note:Tag TOB at 8758ft 00:30 02:30 2.00 8,758 8,761 PROD3 STK KOST P Start time milling off billet, 1.41 bpm at 4100 psi, BHP 4043,WHP 350, IA 134, OA 0 02:30 04:00 1.50 8,761 8,800 PROD3 DRILL DRLG P Drill ahead 1.4 bpm at 4252 psi, BHP 4044,WHP 351, IA 134, OA 0 Page 28 of 31 + I Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 04:15 0.25 8,800 8,800 PROD3 DRILL WPRT P 8800ft,Wiper up past billet to 8670ft clean, PUW 33k 04:15 06:45 2.50 8,800 8,970 PROD3 DRILL DRLG P BOBD 1.4 bpm at 4130 psi, BHP 4047,WHP 337, IA 155, OA 0 06:45 08:15 1.50 8,970 8,970 PROD3 DRILL WPRT P Wiper trip from 8970'to 7880' 08:15 11:50 3.59 8,970 9,170 PROD3 DRILL DRLG P BOBD 1.4 bpm at 4434 psi, BHP 4028,WHP 297, IA 213, OA 0. Averaging approximately 2k lbs WOB&40 ft/hr ROP. 11:50 12:54 1.08 9,170 9,170 PROD3 DRILL WPRT P Wiper trip from 9170'to 8168'. PUW at 9170'=35k lb. 12:54 15:43 2.83 9,170 9,370 PROD3 DRILL DRLG P BOBD 1.4 bpm at 4240 psi, BHP 4045,WHP 290, IA 280, OA 0. 15:43 17:18 1.59 9,370 9,370 PROD3 DRILL WPRT P Wiper trip from 9370'to 7896'.Tie in to RA tag in whipstock. +3.5'. PUW at 9370'=35k lb. 17:18 20:51 3.56 9,370 9,570 PROD3 DRILL DRLG P BOBD 1.4 bpm at 4294 psi, BHP 4052,WHP 265, IA 306, OA 0. 20:51 22:06 1.25 9,570 9,570 PROD3 DRILL WPRT P 9570ft,wiper up hole to 8840ft, PUW 36k -- 22:06 23:57 1.85 9,570 9,672 PROD3 DRILL DRLG P BOBD 1.4 bpm at 4170 psi, BHP _ 4081,WHP 270, IA 386, OA 0 04/18/2015 Drilled ahead BL2 lateral, from 9672ft to 10138ft. 00:00 00:45 0.75 9,672 9,770 PROD3 DRILL DRLG P OBD 1.40 bpm at 4112 psi, BHP 4084,WHP 278, IA 407, OA 0 00:45 02:00 1.25 9,770 9,770 PROD3 DRILL WPRT P 9770ft,Wiper up hole to 8875ft, PUW 35k 02:00 09:00 7.00 9,770 9,916 PROD3 DRILL DRLG P BOBD 1.40 bpm at 4100 psi, BHP 4090,WHP 279, IA 409, OA 0, Mud swap, new mud at the bit at 9907'.Wait until-5 bbls of new mud is around the bit and PU for short wiper trip to 9824'. PUW=33k lb. Then BOBD. Experiencing some low ROPs. 09:00 12:00 3.00 9,916 9,916 PROD3 DRILL WPRT P Pump-10 bbls high vis sweep. When it reaches bit,start wiper trip from 9916'to surface. PUW at 9916'=33k lb. 12:00 15:19 3.33 9,916 9,916 PROD3 DRILL WPRT P At approx 150',jog back down to 500'. Saw an increase in the cuttings return-aluminum and rock. Tie in to K1 marker on way back to bottom: +4.5'correction. 15:19 21:34 6.25 9,916 10,120 PROD3 DRILL DRLG P BOBD 1.4 bpm at 4200 psi, BHP 4095,WHP 328, IA 214, OA 0. 21:34 22:34 1.00 10,120 10,120 PROD3 DRILL WPRT P 10120ft,wiper up hole to 8855ft, PUW31k 22:34 23:59 1.42 10,120 10,138 PROD3 DRILL DRLG P BOBD 1.4 bpm at 4120 psi, BHP 4116,WHP 373, IA 408, OA 0 04/19/2015 Drilled ahead BL2 lateral from 10138ft to TD 10141ft, perform swab wiper, confirm TD 10141, POOH, MU BL2 liner completion with 73 jts of slotted liner,displace well to seawater Page 29 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 10,138 10,141 PROD3 DRILL DRLG P 10138ft, OBD 1.41 bpm at4224, BHP 4116,WHP 371, IA 406, OA 0, ROP 3-15 fph, DHWOB 750 lbs, CSW-10k 01:00 04:30 3.50 10,141 72 PROD3 DRILL WPRT P 10140ft, TD was called due to lockup. Pump 10x10 sweep, pull swab wiper. 04:30 06:00 1.51 72 7,610 PROD3 DRILL TRIP P Rezero counters, RBIH 06:00 06:09 0.15 7,610 7,610 PROD3 DRILL DLOG P Tie into the K1 marker correction of plus 3.5 06:09 07:18 1.15 7,610 10,141 PROD3 DRILL DLOG P RIH to tag bottom at 10,141' 07:18 11:27 4.15 10,141 72 PROD3 DRILL DISP P POOH laying in liner running pill(12 ppg NaBr with beads)and completion fluid(12 ppg NaBr). PUW @ 10,130'=29k lb. Paint EOP flags at 7772'bit depth/7670'EOP and at 5072'bit depth/5000'EOP. 11:27 11:57 0.50 72 72 PROD3 DRILL OWFF P At surface. Perform no flow test. 11:57 13:44 1.79 72 0 PROD3 DRILL PULD P Lay down drilling BHA#39. Bit condition:3-1-BT-N-X-I-PN-TD 13:44 19:44 6.00 0 2,315 COMPZ CASING PUTB P PJSM for running liner. MU and run non-ported bull nose, Hyd511 x STL XO,58 jts 2 3/8"4.6#L-80, Hyd511 slotted liner, STL x Hyd511 XO, 15 jts 2 3/8"4.6#L-80 STL slotted liner, and shorty deployment sleeve. 19:44 20:59 1.25 2,315 5,000 COMPZ CASING RUNL P RIH,with BL2 liner assembly 20:59 21:59 1.00 5,000 10,141 COMPZ CASING RUNL P No correction at the flag, Continue RIHTB 21:59 22:14 0.25 10,141 10,141 COMPZ CASING RUNL P 10141ft, set down on bottom, PUW 35.5k, Set back down 5k,bring pump up, release from liner, PUW 29k 22:14 22:59 0.75 10,141 10,141 COMPZ CASING TRIP P 10141ft, reset counters to BOT GS, line up sea water down the coil. 22:59 23:59 1.00 10,141 4,006 COMPZ CASING DISP P POOH, displacing well to sea water 04/20/2015 Freeze protect well from 2500ft, set BPV, FTP 1135psi, RDMO to 2K-pad Well 15 00:00 00:45 0.75 4,006 2,500 COMPZ CASING DISP P 4006ft,continue POOH while displacing well to sea water. 00:45 01:45 1.00 2,500 2,500 COMPZ CASING SFTY P PJSM,with Little Red, RU, PT line to 3500 psi,freeze protect well from 2500ft. 01:45 02:30 0.75 2,500 44 COMPZ CASING TRIP P POOH,puming pipe displacemet 02:30 04:00 1.50 44 0 COMPZ CASING PULD P PJSM, undeploy and LD liner running tools ****Note: FTP 1140 psi 04:00 07:30 3.50 0 0 DEMOB WHDBO NUND P PJSM, MU nozzle to circulate inhibitor through surface equipment. Pumped 37 bbls freshwater followed corrosion inhibitor. Blow down surface lines and reel. —_____-_. Page 30 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:30 09:30 2.00 0 0 DEMOB WHDBO MPSP P PJSM-Lubricate in BPV,off load FMC equipment. 09:30 12:00 2.50 0 0 DEMOB WHDBO NUND P Nipple down BOPE. Trucks on location PJSM for RDMO of well. """"Note Rig Released 1200 noon Page 31 of 31 Cement Detail Report 30-16 ConocoPhillips String: 4 112" liner Job: RECOMPLETION, 12/11/2014 09:30 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name 4 1/2"liner 1/10/2015 00:00 1/11/2015 00:00 30-16A Comment Cement 4 1/2"liner assembly for upcoming CTD from 7947'-7707'. Pumped 5bbls fresh,mud flush 15 bbls.pumped 15 bbls of 15.8#G neat cement,5 bbls fresh,dropped plug displaced with 60 bbls of 12.2#mud.Set packer and hanger assembly @ 4300 psi against cement plug. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? 4.5 liner Cement in Liner 7,707.0 7,947.0 No No No Q Pump'nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(fP/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 5/13/2015 0114 Cement Detail Report 30-16 ConocoPtliillp String: CMT SQUEEZE Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name CMT SQUEEZE 7/9/2013 00:00 30-16A Comment CEMENT SQUEEZE PLUG INTO THE PERFS. PUMPED/BULLHEADED THE FOLLOWING DOWN THE TBG. 10.5#PPG INHIBITED BRINE,68 BBLS FOR WELL KILL&STEP RATE INJECTION,5 BBLS WATER SPACER, 17 BBLS OF 15.8 CLASS G CEMENT Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? CMT PLUG 7,790.0 8,200.0 Q Pump Mit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment CEMENT SQUEEZE PLUG INTO THE PERFS. PUMPED/BULLHEADED THE FOLLOWING DOWN THE TBG. 10.5#PPG INHIBITED BRINE,68 BBLS FOR WELL KILL&STEP RATE INJECTION,5 BBLS WATER SPACER, 17 BBLS OF 15.8 CLASS G CEMENT Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa-s) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 5/13/2015 Cement Detail Report 0!:4 011 30-16 ConocoPhillips AtsA:. String: Production Casing Cement Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Production Casing Cement 30-16A Comment Cement Stages Stage#<Stage Number?> Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Production Casing 0.0 8,201.0 Cement Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 5/13/2015 Cement Detail Report 30-16 ConocoPhilliips String: Surface Casing Cement Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 30-16A Comment Cement Stages Stage#<Stage Number?> Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Surface Casing Cement 0.0 2,375.0 Q Pump mit(bbllm...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) 'Rotated? Pipe RPM(rpm) Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(ft'Isack) Mix H2O Ratio(gal/sa... 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N n N co (O (O u) co co 0 CO N 01 u) 2F O M N N O O O O O Oi O) O O O M 0 QQ Q Q Q Q Q Q Q CO CO CO CO M Q QQQ (O (D N O (O (O N (0 (O (O (O (O N (fl (0 (O (O (O 1 S N a Q O O a7 co N M tO N (O CO Q N r•- coma i O (O CO CO u) n N (0 u) (0 u) O (14) CO CO N O (0 7 I- C) '7 M N O 0i a) CO N aD a0 of 0 0 N >> N v W W v v v v v v v v v v 4) (4 %'- `4 F v (o co co (o (o ro E6m c Y W co Q h M M Q M � h O N u) O] (O O N <7_, •� N O O co O N a) CO N CO O co Q O O u) N N -Q (-- O R n V m CO 0 (� or O) co M N N ^ n co N a0 m O co N N 0 O co O) co a0 op a0 op � L• OM N N YL d Y Y J J ^ 8 2 ,t (O (0 (0 n co op co aO N aO CO N O n 0 CV OJ co aJ (0 0 i O 00 5 CO (0 O 1.... n n CO n N O Q a0 (0 0 0 00 O a0 co c O. Q U r. (.j (V O N O O) O O (i) ¢� r n S U Y Y 0 0 0 5 0) m m rn rn m rn m rn o) m o) O (0 m m m a) OC) O Q N 0 N 0 n N O (0 (0 N N (0 O O 0 O Oo (O h n CO CO 0 N N 0 N N N N N N N u) 0 O CJ O O O CJ O O O CJ Mp80; (CJ O O QL d w M O O N Nh hm 0-0' CQD dno 0 O O O O O (O OO• y d .. al ' Oi a,- Oi Oi OO Oi O Oi 0) 0,- 4) Oi O O O O c` r r r c r O U o wdd c Letter of Transmittal VP U RECEIVED Date: E� DATA LOGGED BAKER Aril 27, 2015 5,,201$ HUGHES p APR 2 8 2015 �� K BENDER AOGCC To: From: Makana Bender Yosha Ragbirsingh/Michael Soper AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 30-16BPB1 30-16B 215-057 25729 30-16BPB2 30-16B PB1 215-057 25730 30-16B 30-16B PB2 215-057 25731 30-16BL1 30-16BL1 215-030 25732 30-16BL2 30-16BL2 215-031 25733 (5) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BakerHughes.com Yosha Ragbirsingh, Baker Hughes, Survey Manager Yosha.Ragbirsingh@BakerHughes.com _ — 1-- M M oto 0 t,[) L- I L Nrst - 0 ll ll git W I 1 Q ® hi go �Wce CCgl N 0- I i•. t CU O th CU 0 a) WOC a I- ,, co •- u,.- — _ s •- 4_, _c v) P'' CI- -a N GJ kJ 0 > •- O 0 "e O13- Q,M N r — o N ./ C NO = = m O aLw C `� V a r � 1:1) Q 0 YYg2 CO 0 N I Ili 03 11 • i' N O C ro N N 11.4,1111716 Pfli Ti O n ` L,-) 14 >+'�' p - RN W c • ❑ ( CO o CO `00 - O 3333 - r - a _ • C N r N G W ch V C LL Cl.. CO % r O i O co• p O O O O q� ` N N N N N • s { 2 ❑ O �,„ in ,- N e U) V) M m V 71;>" s 6) J ; II w C O « C O 41 J J U ' N • 0 E CS) o Q m ti/1 O O , x el p Il 3c , . —00 O O Cu i • 1 1 'O U)'O 'OO O , 1Om 0 0 O 7 C fi ' w 0 IIO II II� 4 n3 N i } 3p V E N o ° o CO UCl)m a am Q 01_01 I-77. W ❑,@ h ; .r r 'm O t 00 4tC/J O 7 T r ?O oQ d c mc CDo t'11i 41 4 „-s1/1111111•11,11111./I• OD a 7 2 ,• .8. 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S U Y Y 0 0 0 c Eco co co .,. m m a) rn m 0) 0) rn rn 0) 0 0) 0) 0 0 0 0 co g C. a O o m Sr CO 0 N CO N- N 0 (D (O CO N 0 0 O 0 0 OV c0 N- Nps O (D () N N O N N N pN N CU pN (p0 O ^ OM (00 O) N v0) O 0 V N O CO0CO00) (0U U) 00 O (V Y C .. 0) 0 N M O CO N- N- N` CO 00 CO O 0) O CO O O O h O C v y0 C `L C) o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 s Nn m 0 E •o }? m m 76 Z 0 a` in 0 in ,ii,, — . ' Bettis, Patricia K (DOA) -?Ti al5 - 03 I From: Eller, J Gary <J.Gary.Eller@conocophillips.com> Sent: Friday, March 20, 2015 1:53 PM To: Bettis, Patricia K (DOA) Cc: Soper, Michael K (Baker Hughes INTEQ); Starck, Kai; Burke,Jason Subject: RE: Change in Completion Configuration, KRU 30-16AL1 (215-029) Patricia—Yes, it was pointed out to me later that I had inverted a couple those numbers. Thanks for clarifying the API numbers of the two 30-16B laterals. -Gary From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Thursday, March 19, 2015 2:01 PM To: Eller, J Gary Subject: [EXTERNAL]RE: Change in Completion Configuration, KRU 30-16AL1 (215-029) Good afternoon Gary, In putting the name change for the wells into the AOGCC database, I notice that there was a typo in your email for the API numbers. The APIs should be as follows: 30-16BL1 API 50-029-21796-61 30-16BL2 API 50-029-21796-62. The name changes are now reflected in the AOGCC database. Thank you, Patricia From: Eller, J Gary [mailto:J.Gary.Eller@conocophillips.com] Sent: Wednesday, March 18, 2015 9:38 AM To: Loepp, Victoria T (DOA) Cc: Bettis, Patricia K (DOA); Schwartz, Guy L (DOA); Starck, Kai; Venhaus, Dan E Subject: RE: Change in Completion Configuration, KRU 30-16AL1 (215-029) Victoria— ConocoPhillips just signed a new 10-401 for KRU 30-16B and a 10-403 for the plugging of KRU 30-16A, as outlined below. Those documents should arrive at the AOGCC later today. As you requested, I am furthermore requesting that the names of the subsequent proposed laterals be changed as follows: • 30-16AL1-01 (215-030) will be renamed to 30-16BL1. API number shall remain as 50-029-21769-61. • 30-16AL1-02 (215-031) will be renamed to 30-16BL2. API number shall remain as 50-029-21769-62. Please let me know if there are any questions about this. Thanks for your patience in working through this. -Gary Eller ConocoPhillips Alaska From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Tuesday, March 17, 2015 9:39 AM To: Eller, 3 Gary 1 Cc: Bettis, Patricia K (DOA); Schwartz, Guy L (DOA) Subject: [EXTERNAL]RE: Change in Completion Configuration, KRU 30-16AL1 (215-029) Gary, Please see comments in red. Let me know if there is any confusion. Thank, Victoria Proposed Renaming Lateral PTD API Proposed Proposed API Comments Name Lateral Name Submit 407 for abandon 30-16A to close out. Email. 30-16AL1 215- 50-029- 30-16B 50-029- request for alternate plug placement variance. 029 21769-60 21769-02 Resubmit 401 PTD for 30-16B w/out PTD# or API♦ Change all 30-16AL1 references to 30-16B. 30- 215- 50-029- 50-02930-16BL1 - Email to change name from 3O-16AL1-01 to 30-161 21769- 16AL1-01 030 21769-61 21769-60 ? 30- 215- 50-029- 30-16BL2 20-029- Email to change name from 30-16AL1-02 to 30-161 16AL 1-02 031 21769-62 21769-61 ? From: Schwartz, Guy L (DOA) Sent: Tuesday, March 17, 2015 9:24 AM To: Loepp, Victoria T (DOA) Subject: FW: Change in Completion Configuration, KRU 30-16AL1 (215-029) Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226)or(Guy.schwartz@alaska.gov). From: Eller, J Gary [mailto:J.Gary.Eller@conocophillips.com] Sent: Monday, March 16, 2015 12:27 PM To: Schwartz, Guy L (DOA) Cc: Venhaus, Dan E; Starck, Kai; Burke, Jason Subject: Change in Completion Configuration, KRU 30-16AL1 (215-029) Guy—As I briefly indicated over the phone, we've had some complications early in the planned CTD lateral from KRU 30- 16A. As the attached proposed schematic of 10-7-14 shows, 30-16AL1 (215-029) has been planned as a sidetrack off of a Starburst packer/whipstock at 7815' MD. The Starburst has a hollow tray, so the Starburst in combination with a packer 2 provides isolation from the 30-16A motherbore during drilling but hydraulic communication can be restored by perforating into the hollow tray post-CTD. All of that has gone awry. The packer is set at the correct depth, but we've been unable to latch the Starburst tray into the packer. We've reached the point where we need to move uphole by setting another whipstock, the top of which will be 7780' MD. Once we sidetrack and run our 3W liner and cement it in place, we'll permanently lose communication to the 30-16A motherbore. I've attached a second schematic that attempts to communicate what the completion will look like now. So we have two issues we need to address: (1) wellbore naming &API numbering since this will now be a sidetrack instead of a lateral, and (2) abandonment of the 30-16A completion. Regarding naming, the table below shows the current approved lateral naming and assigned API numbers as well as ConocoPhillips' recommendation for revised naming. If it is possible to do so, it would be simplest to rename the planned/approved laterals and assign new API numbers. Hopefully that can be accomplished without submitting replacements 10-401's. Approved Drilling Permits Proposed Renaming Lateral Proposed Lateral PTD APIe sed API Comments Name • F���'�� W �� �� 'dtlVr az` ev..«w,. airlk-.. fP rods i u .IiIri�if 30-16AL1 215- 50-029-21769- 30-16B 50-029-21769-02 Change from lateral to sidetrack 029 60 30-16AL1- 215- 50-029-21769- 50-029-21769-60 Has same API number as old 30- 01 030 61 30-16BL1 ? 16AL1? 30-16AL1- 215- 50-029-21769- 50-029-21769-61 Has same API number as old 30- 02 031 62 30-16BL2 16AL1-01? Regarding abandonment of the KRU 30-16A completion, there's no way we can meet the plugging requirements of 20 AAC 25.112(c)(1) while still sidetracking at 7780' MD, so a variance will clearly be needed. ConocoPhillips proposes that we accomplish the abandonment of 30-16A following drilling, lining, and cementing the 3W hole section in 30-16B. That is, after cementing the 3W liner in place, we'll perform a pressure test of the 3W liner lap. If cement integrity is adequate around the 3W liner lap then that will have effectively isolated 30-16A. If the liner lap fails the integrity test, then 30-16A can be isolated via a liner lap squeeze and/or a liner top packer(post-CTD). Either of these solutions will serve to confine the hydrocarbons to their respective strata, as is intended by 20 AAC 25.112(c)(1). On the attached updated schematic diagram, I have left the original lateral names to minimize confusion (I hope). If you approve of both the renaming and the abandonment plan then I'll issue a new proposed schematic reflecting the revised naming. I realize that this is a lot to throw at you at once, and I apologize for that. Please call to discuss when you have opportunity. J. Gary Eller Wells Engineer ConocoPhillips - Alaska work: 907-263-4172 cell: 907-529-1979 3 Bettis, Patricia K (DOA) / J-) (-)3 From: Bettis, Patricia K (DOA) Sent: Thursday, March 19, 2015 2:01 PM To: 'Eller,J Gary' Subject: RE: Change in Completion Configuration, KRU 30-16AL1 (215-029) Good afternoon Gary, In putting the name change for the wells into the AOGCC database, I notice that there was a typo in your email for the API numbers. The APIs should be as follows: 30-16BL1 API 50-029-21796-61 30-168L2 API 50-029-21796-62. The name changes are now reflected in the AOGCC database. Thank you, Patricia From: Eller, J Gary [mailto:J.Gary.Eller@conocophillips.com] Sent: Wednesday, March 18, 2015 9:38 AM To: Loepp, Victoria T(DOA) Cc: Bettis, Patricia K (DOA); Schwartz, Guy L (DOA); Starck, Kai; Venhaus, Dan E Subject: RE: Change in Completion Configuration, KRU 30-16AL1 (215-029) Victoria— ConocoPhillips just signed a new 10-401 for KRU 30-16B and a 10-403 for the plugging of KRU 30-16A, as outlined below. Those documents should arrive at the AOGCC later today. As you requested, I am furthermore requesting that the names of the subsequent proposed laterals be changed as follows: • 30-16AL1-01 (215-030) will be renamed to 30-16BL1. API number shall remain as 50-029-21769-61. • 30-16AL1-02 (215-031) will be renamed to 30-16BL2. API number shall remain as 50-029-21769-62. Please let me know if there are any questions about this. Thanks for your patience in working through this. -Gary Eller ConocoPhillips Alaska From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Tuesday, March 17, 2015 9:39 AM To: Eller, J Gary Cc: Bettis, Patricia K (DOA); Schwartz, Guy L (DOA) Subject: [EXTERNAL]RE: Change in Completion Configuration, KRU 30-16AL1 (215-029) Gary, Please see comments in red. Let me know if there is any confusion. Thanx, Victoria 1 ,.._ t4 : �.: Proposed Renaming twer.vrt7.1, d,.�'n r wtovµm n,rt-. Lateral Proposed PTD API Proposed API Comments e Lateral Name 44, Submit 407 for abandon 30-16A to close out. Email 215- 50-029- 50-029- request for alternate plug placement variance. 30-16AL1 30-16B 029 21769-60 21769-02 Resubmit 401 PTD for 30-16B w/out PTD# or APIh Change all 30-16AL1 references to 30-16B. 30- 215- 50-029- 50-02930-16BL1 - Email to change name from 30-16AL1-01 to 30-161 21769- 16AL1-01 030 21769-61 21769-60 .? 30- 215- 50-029- 30-16BL2 20-029- Email to change name from 30-1.6AL1-02 to 30-16] 16AL 1-02 031 21769-62 21769-61 ? From: Schwartz, Guy L (DOA) Sent: Tuesday, March 17, 2015 9:24 AM To: Loepp, Victoria T(DOA) Subject: FW: Change in Completion Configuration, KRU 30-16AL1 (215-029) Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226)or(Guv.schwartz@alaska.gov). From: Eller, J Gary [mailto:J.Gary.Eller@conocophillips.com] Sent: Monday, March 16, 2015 12:27 PM To: Schwartz, Guy L (DOA) Cc: Venhaus, Dan E; Starck, Kai; Burke, Jason Subject: Change in Completion Configuration, KRU 30-16AL1 (215-029) Guy-As I briefly indicated over the phone, we've had some complications early in the planned CTD lateral from KRU 30- 16A. As the attached proposed schematic of 10-7-14 shows, 30-16AL1 (215-029) has been planned as a sidetrack off of a Starburst packer/whipstock at 7815' MD. The Starburst has a hollow tray, so the Starburst in combination with a packer provides isolation from the 30-16A motherbore during drilling but hydraulic communication can be restored by perforating into the hollow tray post-CTD. All of that has gone awry. The packer is set at the correct depth, but we've been unable to latch the Starburst tray into the packer. We've reached the point where we need to move uphole by setting another whipstock, the top of which will be -7780' MD. Once we sidetrack and run our 3W liner and cement it in place, we'll permanently lose communication to the 30-16A motherbore. I've attached a second schematic that attempts to communicate what the completion will look like now. So we have two issues we need to address: (1) wellbore naming &API numbering since this will now be a sidetrack instead of a lateral, and (2) abandonment of the 30-16A completion. 2 Regarding naming, the table below shows the current approved lateral naming and assigned API numbers as well as ConocoPhillips' recommendation for revised naming. If it is possible to do so, it would be simplest to rename the planned/approved laterals and assign new API numbers. Hopefully that can be accomplished without submitting replacements 10-401's. Approved Drilling Permits Proposed Renaming Lateral Proposed Lateral PTD API �� Proposed API i Comments y Name , g 's1ame q u� 30-16AL1 215- 50-029-21769- 30-16B 50-029-21769-02 Change from lateral to sidetrack 029 60 30-16AL1- 215- 50-029-21769- 50-029-21769-60 Has same API number as old 30- 01 030 61 30-16BL1 16AL1? 30-16AL1- 215- 50-029-21769- 50-029-21769-61 Has same API number as old 30- 02 031 62 30-16BL2 16AL 1-01? Regarding abandonment of the KRU 30-16A completion, there's no way we can meet the plugging requirements of 20 AAC 25.112(c)(1) while still sidetracking at 7780' MD, so a variance will clearly be needed. ConocoPhillips proposes that we accomplish the abandonment of 30-16A following drilling, lining, and cementing the 3W hole section in 30-16B. That is, after cementing the 3'/2" liner in place, we'll perform a pressure test of the 3W liner lap. If cement integrity is adequate around the 3W liner lap then that will have effectively isolated 30-16A. If the liner lap fails the integrity test, then 30-16A can be isolated via a liner lap squeeze and/or a liner top packer(post-CTD). Either of these solutions will serve to confine the hydrocarbons to their respective strata, as is intended by 20 AAC 25.112(c)(1). On the attached updated schematic diagram, I have left the original lateral names to minimize confusion (I hope). If you approve of both the renaming and the abandonment plan then I'll issue a new proposed schematic reflecting the revised naming. I realize that this is a lot to throw at you at once, and I apologize for that. Please call to discuss when you have opportunity. J. Gary Eller Wells Engineer ConocoPhillips - Alaska work: 907-263-4172 cell: 907-529-1979 3 Prr7 7_I s—o3 / Loepp, Victoria T (DOA) From: Eller,J Gary <J.Gary.Eller@conocophillips.com> Sent: Wednesday, March 18, 2015 9:38 AM To: Loepp,Victoria T(DOA) Cc: Bettis, Patricia K(DOA); Schwartz, Guy L(DOA);Starck, Kai;Venhaus, Dan E Subject: RE:Change in Completion Configuration, KRU 30-16AL1 (215-029) Victoria—ConocoPhillips just signed a new 10-401 for KRU 30-16B and a 10-403 for the plugging of KRU 30-16A, as outlined below. Those documents should arrive at the AOGCC later today. As you requested, I am furthermore requesting that the names of the subsequent proposed laterals be changed as follows: • 30-16AL1-01 (215-030)will be renamed to 30-16BL1. API number shall remain as 50-029-21769-61. • 30-16AL1-02 (215-031)will be renamed to 30-16BL2. API number shall remain as 50-029-21769-62. Please let me know if there are any questions about this. Thanks for your patience in working through this. -Gary Eller ConocoPhillips Alaska From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Tuesday, March 17, 2015 9:39 AM To: Eller, 3 Gary Cc: Bettis, Patricia K(DOA); Schwartz, Guy L(DOA) Subject: [EXTERNAL]RE: Change in Completion Configuration, KRU 30-16AL1 (215-029) Gary, Please see comments in red. Let me know if there is any confusion. Thanx, Victoria Proposed Renaming Lateral PTD API Proposed Proposed API Comments Name Lateral Name Submit 407 for abandon 30-16A to close out. Email 30-16AL1 215- 50-029- 30-16B 50-029- request for alternate plug placement variance. 029 21769-60 21769-02 Resubmit 401 PTD for 30-16B w/out PTD#or API#. Change all 30-16AL1 references to 30-16B. 30- 215- 50-029- 50-02930-16BL1 - Email to change name from 30-16AL1-01 to 30-16E 16AL 1-01 030 21769-61 21769-21769-60 ? 30- 215- 50-029- 30-16BL2 20-029- Email to change name from 30-16AL1-02 to 30-16E 16AL 1-02 031 21769-62 21769-61 From: Schwartz, Guy L(DOA) Sent: Tuesday, March 17, 2015 9:24 AM To: Loepp, Victoria T(DOA) Subject: FW: Change in Completion Configuration, KRU 30-16AL1 (215-029) 1 Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226)or(Guv.schwartz@alaska.gov). From: Eller, 3 Gary [mailto:J.Gary.Eller@conocophillips.com] Sent: Monday, March 16, 2015 12:27 PM To: Schwartz, Guy L(DOA) Cc: Venhaus, Dan E; Starck, Kai; Burke, Jason Subject: Change in Completion Configuration, KRU 30-16AL1 (215-029) Guy—As I briefly indicated over the phone, we've had some complications early in the planned CTD lateral from KRU 30- 16A. As the attached proposed schematic of 10-7-14 shows, 30-16AL1 (215-029) has been planned as a sidetrack off of a Starburst packer/whipstock at 7815' MD. The Starburst has a hollow tray, so the Starburst in combination with a packer provides isolation from the 30-16A motherbore during drilling but hydraulic communication can be restored by perforating into the hollow tray post-CTD. All of that has gone awry. The packer is set at the correct depth, but we've been unable to latch the Starburst tray into the packer. We've reached the point where we need to move uphole by setting another whipstock, the top of which will be —7780' MD. Once we sidetrack and run our 3W liner and cement it in place, we'll permanently lose communication to the 30-16A motherbore. I've attached a second schematic that attempts to communicate what the completion will look like now. So we have two issues we need to address: (1)wellbore naming &API numbering since this will now be a sidetrack instead of a lateral, and (2) abandonment of the 30-16A completion. Regarding naming, the table below shows the current approved lateral naming and assigned API numbers as well as ConocoPhillips' recommendation for revised naming. If it is possible to do so, it would be simplest to rename the planned/approved laterals and assign new API numbers. Hopefully that can be accomplished without submitting replacements 10-401's. Approved Drilling Permits Proposed Renaming Lateral PTDj.PI Proposed Lateral Proposed API Comments NameName • 30-16AL1 215- 50-029-21769- 30-16B 50-029-21769-02 Change from lateral to sidetrack 029 60 30-16AL1- 215- 50-029-21769- 50-029-21769-60 Has same API number as old 30- 01 030 61 30-16BL1 ? 16AL1? 30-16AL1- 215- 50-029-21769- 50-029-21769-61 Has same API number as old 30- 02 031 62 30-16BL2 16AL 1-01? Regarding abandonment of the KRU 30-16A completion, there's no way we can meet the plugging requirements of 20 AAC 25.112(c)(1) while still sidetracking at 7780' MD, so a variance will clearly be needed. ConocoPhillips proposes that 2 we accomplish the abandonment of 30-16A following drilling, lining, and cementing the 3W hole section in 30-16B. That is, after cementing the 3W liner in place, we'll perform a pressure test of the 3W liner lap. If cement integrity is adequate around the 3'/2" liner lap then that will have effectively isolated 30-16A. If the liner lap fails the integrity test, then 30-16A can be isolated via a liner lap squeeze and/or a liner top packer(post-CTD). Either of these solutions will serve to confine the hydrocarbons to their respective strata, as is intended by 20 AAC 25.112(c)(1). On the attached updated schematic diagram, I have left the original lateral names to minimize confusion (I hope). If you approve of both the renaming and the abandonment plan then I'll issue a new proposed schematic reflecting the revised naming. I realize that this is a lot to throw at you at once, and I apologize for that. Please call to discuss when you have opportunity. J. Gary Eller Wells Engineer ConocoPhillips - Alaska work: 907-263-4172 cell: 907-529-1979 3 14.‘, OF T4 0, \\I�j,,,s,, THE STATE Alaska Oil and Gas mw �s��—'� of Conservation Commission -- _M ALASI�;A `•Iit.�_ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 0.0., Main: 907.279.1433 ALASI Fax 907.276 7542 www.aogcc.alaska.gov D. Venhaus CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 30-16AL1-02 ConocoPhillips Alaska, Inc. Permit No: 215-031 Surface Location: 1106' FNL,2060' FWL, Sec. 22, T13N, R9E, UM Bottomhole Location: 302' FNL, 2432' FEL, Sec. 28, T13N, R9E, UM Dear Mr. Venhaus: Enclosed is the approved application for permit to drill the above referenced service well. The permit is for a new wellbore segment of existing well Permit No. 188-043, API No. 50-029- 21796-01-00. 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 I Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, . P- 4.X.-4.4V------- Cathy P oerster Chair / DATED this v day of March, 2015. r9 RECEIVED ` ` STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 13 2015 PERMIT TO DRILL //��►► 20 AAC 25.005 AOGCC la Type of Work: 1 b Proposed Well Class Development-Oil ❑ Service-Winj ❑ Single Zone Q- 1 c Specify if well is proposed for: Drill ❑ •Lateral C Stratigraphic Test❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill ❑ Reentry E Exploratory ❑ Service-WAG • Q Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name 5. Bond •U Blanket u Single Well 11 Well Name and Number ConocoPhillips Alaska, Inc. r Bond No. 59-52-180- KRU 30-16AL1-02 3.Address 6.Proposed Depth (Py3p >, 12. Field/Pool(s): 1 P.O. Box 100360 Anchorage,AK 99510-0360 MD. 10650' - TVD: §.46 Kuparuk River Field 4a Location of Well(Governmental Section). 7 Property Designation(Lease Number) /Q;•le( Surface: 1106'FNL,2060'FWL,Sec.22,T13N,R9E,UM ADL 25513,25520 Kuparuk Oil Pool Top of Productive Horizon. 8 Land Use Permit 13 Approximate Spud Date: 1879'FSL, 1075'FEL,Sec.21,T13N, R9E, UM 2554,2556 3/1/2015 Total Depth 9.Acres in Property gt 14 Distance to 302'FNL,2432'FEL,Sec.28,T13N, R9E, UM .2.666-519,0 Nearest Property 7100 4b.Location of Well(State Base Plane Coordinates-NAD 27). 10 KB Elevation above MSL. • 59 feet 15 Distance to Nearest Well Open Surface:x- 525698 y- 6021714 Zone- 4 • GL Elevation above MSL 24 feet to Same Pool: 3N-13,1253 16 Deviated wells: Kickoff depth: • 8885 ft. 17.Maximum Anticipated Pressures in psig(see 20 MC 25 035) Maximum Hole Angle: , 99° deg Downhole:5300 psig , Surface:4651 psig • 18.Casing Program Specifications Top - Setting Depth -Bottom Cement Quantity,c f.or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 3" 2.375" 4.7# L-80 ST-L 2845' 7805' 6449' 10650' 6462' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redd!and Re-Entry Operations) Total Depth MD(ft) Total Depth ND(ft): Plugs(measured) Effective Depth MD(ft) Effective Depth ND(ft): Junk(measured) 8351' 6901' none 8115 6709' none Casing Length Size Cement Volume MD TVD Conductor/Structural 79' 16" 175 sx AS I 115' 115' Surface 2340' 9.625" 900 sx AS III,300 sx AS II, 2375' 2215' 100 sx AS I Liner 8168' 7" 700 sx TLW,300 sx Class G,175 sx 8201' 6778' Liner 238' 4 5" liner 7945' 6571' Perforation Depth MD(ft): Perforation Depth TVD(ft) 7794-7804,7838-7848,7850-7860,7869-7889,7908-7928 6444-6452,6480-6488,6489-6498,6505-6522,6537-6553 20 Attachments: Property Plat❑ BOP Sketch❑ Drilling Prograrr ❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements Q 21 Verbal Approval: Commission Representative. Date 22 I hereby certify that the foregoing is true and correct Contact Jason Burke @ 265-6097 Email Jason.B Printed Name D. Venh S Title CTD Engineering Supervisor =' Signature l ../,� — Phone:263-4372 Date Z— /z- 15 Commission Use Only Permit to Drill API Number: 1 Permit Approval / See cover letter Number. 215— 0 3l 50-0 29- 7_q __6 a_.oLD Date. .I40(16" ( ✓ for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed. methane,gas hydrates,or gas contained in shales Er�-,( Other: O J) /CS 71 to 9,1 O 1 /3 5 r Samples req'd: Yes 1=I [✓]� u No Mud log req'd: YesE No fin Yl v la r p r-c V rve,tri- rc-5I- H2S measures: Yes E?J No ❑ Directional svy req'd: Yes[✓7 No❑ to 2 5-C,C)P5 ' Spacing req'd: Yes •57e4-f6 wi fit-,e•Sara n4 i T/r� p g exce tion p G' CI No [ Inclination-only svy req'd: Yes❑ No Z tri`�r a fttr�l cab%l/3 rd "`j.c cfrw, // (�APPPROVED BY THE Approved by � / ?*244,/(iL=MATI .I AAA MlsloN Date'31 -6 l Cr..m 7A AI11 /�.. in...l 1nl7ft{•fl Th'�. 4 li A !�� 4441.1114 nF onn.n...�l/7A AA!`7G flflGln\1 A�11 J I'V 1\ Ii ConocoPhillips RECEIVED Alska FEB 13 2015 P.O.BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC February 11, 2015 Commissioner-State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an application for a permit to drill a lateral from the existing well bore on KRU 30-16A using the coiled tubing drilling rig, Nabors CDR2-AC. The work is scheduled to begin on March 1, 2015. The CTD objective will be to drill 3 laterals (30-16AL1, L1-01 & L1-02), targeting the Al,A2 &A3 sands. This well will be classified as an injection well. Attached to this application are the following documents: — Permit to Drill Application Form 10-401 for 30-16AL1, L1-01 &L1-02 — Detailed Summary of Operations — Directional Plans — Current Schematic — Proposed Schematic If you have any questions or require additional information please contact me at 907-265-6097. Sincerely, r it t'�� ---- ason Burke Coiled Tubing Drilling Engineer 907-231-4568 Kuparuk CTD Laterals to..ALAfi. 0111) 30-16AL1, L1-01 & L1-02 '♦/ConocoFt � va~ Application for Permit to Drill Document ac 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(t)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 AAC 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 AAC 25.005(c)(6)) 3 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 MC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 MC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 4 (Requirements of 20 AAC 25.005(c)(13)) 4 Summary of Operations 5 Pressure Deployment of BHA 6 Liner Running 6 14. Disposal of Drilling Mud and Cuttings 6 (Requirements of 20 AAC 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 7 (Requirements of 20 AAC 25.050(b)) 7 16. Attachments 8 Attachment 1: Directional Plans for 30-16AL1, L1-01 & L1-02 8 Attachment 2: Current Well Schematic for 30-16A 8 Attachment 3: Proposed Well Schematic for 30-16AL1, L1-01 &L1-02 8 Page 1 of 8 2/11/2015 CRIG1I\ AL PTD Application: 30-16AL1, L1-01 & L1-02 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 30-16AL1, L1-01 & L1-02. This lateral will be classified as "Service—WAG Injection"well. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This lateral will target the Al, A2 &A3 sand packages in the Kuparuk reservoir. See the attached 10-401 form for surface and subsurface coordinates of the 30-16AL1, L1-01 & L1-02. 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. 4,9 0C^/754 — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 50b0 psi. Using the maximum formation pressure in the area of 5300 psi in the 30-10, the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft,would be 4646 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 of 30-16A in June 2013 indicated a reservoir pressure of 4095 psi or 12.1 ppg equivalent mud weight. The recent work over done on this well was done with a 12.2 ppg NaBr. The maximum down hole pressure in the 30-16A pattern is at 30-10 with 5300 psi. It is not expected that reservoir pressure as high as 30-10 will be encountered while drilling the 30-16AL1, L1-01 & L1-02 because we are drilling away from the 30-10 and the two wells are separated by 2 separate faults. Using the 30-10 pressure as the maximum possible, the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 4651 psi. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) No specific gas zones will be drilled; gas injection has been performed on the 30 pad, so cuttings will be monitored for entrained gas. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) The largest, expected risk of hole problems in the 30-16A laterals will be drilling into a highly faulted zone directly outside of the mother bore. Managed pressure drilling will be used to reduce this risk. 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 2/11/2015 JRIGINAL PTD Application: 30-16AL1, L1-01 & L1-02 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 3'/2", 9.2#, L-80, Hydril 511 solid 30-16AL17815' 8815' 6461' 6495' liner; cemented in place with a 6' (first stage) seal bore deployment sleeve on top. 30-16AL1 2%", 4.7#, L-80, ST-L slotted liner; (second 8925' 10650' 6478' 6429' stage) with an aluminum billet on top. 30-16AL1-01 8885' 10650' 6486' 6413' 2%", 4.7#, L-80, ST-L slotted liner; with an aluminum billet on top. 2%", 4.7#, L-80, ST-L slotted liner; 30-16AL1-02 7805' 10650' 6449' 6462' with a shorty deployment sleeve on top. Existing Casing/Liner Information Category OD Weight Grade Conn. Top MD Btm Top Btm Burst Collapse (PPOMD TVD TVD psi psi Conductor 16" 62.5 H-40 Welded 36' 115' 0' 115' 1640 630 Surface 9-5/8" 36 J-55 BTC 35' 2375' 0' 2214' 3520 2020 Casing 7" 26 L-80 TCII 35' 1056' 0' 1056' 7240 5410 Casing 7" 26 J-55 BTC 1800' 8201' 1756' 6778' 4980 4330 Liner 4'/" 11.6 L-80 EUE 7707' 7945' 6309' 6448' 7780 6360 Tubing 4 %" 12.6 L-80 IBT-Mod 35' 7707' 0' 6309' 8430 7500 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) N/A for this thru-tubing drilling operation. Nabors CDR2-AC will be operating under 20 AA C 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(10.0 ppg) — Drilling operations: Chloride-based Flo-Pro mud (10.0 ppg). This mud weight will not hydrostatically overbalance the reservoir pressure. — Completion operations: BHA's will be deployed using standard pressure deployments and the well will be loaded with 12.5 ppg K-Formate completion fluid in order to provide formation over-balance while running completions. Page 3 of 8 G R I G I N A 1. 2/11/2015 PTD Application: 30-16AL1, L1-01 & L1-02 iZ,a�p — Kill Weight fluid: Two wellbores offkill weight fluid`vGill be stored at a central location in the Kuparuk field and accessible for trucking to the rig during CTD operations. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the openhole formation throughout the coiled tubing drilling (CTD) process. Maintaining a constant BHP promotes wellbore stability, particularly in shale sections, while at the same time providing an overbalance on the reservoir. Through experience with drilling CTD laterals in the Kuparuk sands, 11.8 ppg has been identified as the minimum EMW to ensure stability of shale sections. Since this well is proposed as an infield development candidate in an actively water flooded field, expected reservoir pressures can be difficult to estimate. In this case, however, a constant BHP of 12.5 ppg will be initially targeted at the window based on the recent static bottom-hole pressure and the fault blocks being drilled into. The constant BHP target will be adjusted to maintain overbalanced conditions if increased reservoir pressure is encountered during drilling. The constant BHP target will be maintained utilizing the surface choke. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Pressure at the 30-16A Window(7815' MD, 6461' TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure (12.1 ppg) 4066 psi 4066 psi Mud Hydrostatic(10.0 ppg) 3360 psi 3360 psi Annular friction (i.e. ECD, 0.050 psi/ft) 391 psi 0 psi Mud + ECD Combined 3751 psi 3360 psi (no choke pressure) (underbalanced (underbalanced —315 psi) —706 psi) Target BHP at Window(12.5 ppg) 4200 psi 4200 psi Choke Pressure Required to Maintain Target BHP 449 psi 840 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 AAC 25.005(c)(11)) N/A-Application is not for an exploratory or stratigraphic test well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Page 4 of 8 ORIGINAL 2/12/2015 PTD Application: 30-16AL1, L1-01 & L1-02 Summary of Operations Background Well 30-16A is a Kuparuk A-sand service well equipped with 4%2"tubing and a 4 'h"liner. Three laterals will be drilled from the mother bore in order to provide injection support to the area. A mechanical whip-stock will be placed in the 4 'A"liner at the planned kickoff point of 7815'MD. A protection hole(4.125")will be drilled from the mother bore for 1000',then 3 'A"tubing will be cemented in place. From there we will pick up 3"tools and drill the AL1 to a depth of 10650' in the A2 sand. We will run 2-3/8"slotted liner with an aluminum billet back up to 8925'. We will kick off the AL1-01 and drill to a depth of 10650' in the A3 sand. We will run 2-3/8"slotted liner with an aluminum billet back up to 8885'. We will kick off the AL1-02 and drill to a depth of 10650' in the Al sand. We will run 2-3/8" slotted liner with 6' deployment sleeve back up to 7815'. Pre-CTD Work • Coil:Perform FCO of old mud left over from RWO • E-line:Perform jewelry log from 7900'—7550' MD. Perforate the A sand from 7908`—7928', 7869'- 7889`&7838`—7860'MD. • Pump: Perform breakdown at 2 BPM. • Slick-line:Run a dummy whip-stock down to 7830'MD,and obtain a SBHP • E-line: Set a 4'A"starburst packer-whip-stock at 7815' MD and 0°HS Rig Work 1. MIRU Nabors CDR2-AC rig using 2%"coil tubing. NU 7-1/16"BOPE,test. 2. 30-16AL1 Lateral(A2 sand-Southwest) i. Mill 3.80"window at 7815'MD ii. Drill 3.74"x 4.13"bi-center lateral to TD of 8815'MD iii. Run 3 'h"solid liner and cement in place iv. Swap over to 2"CT v. Drill 2.74"x 3.00"bi-center lateral to TD of 10650' MD vi. Run 2%"slotted liner with an aluminum billet from TD up to 8925' MD 3. 30-16AL1-01 Lateral(A3 sand-Southwest) i. Kick off the billet at 8925' ii. Drill 2.74"x 3.00"bi-center lateral to TD of 10650' MD iii. Run 2%"slotted liner with an aluminum billet from TD up to 8885' MD 4. 30-16AL1-02 Lateral(A3 sand-Southwest) i. Kick off the billet at 8885' ii. Drill 2.74"x 3.00"bi-center lateral to TD of 10650' MD iii. Run 2%"slotted liner with 6' deployment sleeve from TD up to 7805' MD Page 5 of 8 OR I G t N n L 2/11/2015 PTD Application: 30-16AL1, L1-01 & L1-02 5. Freeze protect the well. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pu11 BPV 2. Obtain static BHP. 3. MIRU CT and N2 lift well for flow back(less than 30 days) 4. Return to operations 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, so we will use the standard pressure deployment process. A system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick-line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running — All the laterals will be displaced to an overbalancing fluid (12.5 ppg K-Formate) 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 (1R-18 or 1B disposal facilities) or Prudhoe DS-4 if a Kuparuk facility is unavailable. • • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). Page 6 of 8 ORIGINAL 2/11/2015 PTD Application: 30-16AL1, L1-01 & L1-02 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 30-16AL1 7100' 30-16AL1-01 7100' 30-16AL1-02 7100' — Distance to Nearest Well within Pool (measured to offset well) Lateral Name Distance Well 30-16AL1 728' 30-16 30-16AL1-01 1253' 3N-13 30-16AL1-02 1253' 3N-13 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) 30-16AL1 is within 1/4-mile of the 30-16 well 30-16AL1, L1-01 & L1-02 is within 1/4-mile of the 3N-13 well 30-16A (mother bore) Injector • Recently worked over and new 7"26#casing was run from 1056'to surface and cemented in place with 15 bbl G neat cement • Classified as a"Normal Well" • C-sand perforations (cemented): 7794'-7804'MD • A-sand perforations:Al: 7908`—7928',A2: 7869'—7889`&A3: 7838'—7860'MD • Packer is located at 7687' and 4 '/" liner below is cemented in place • MetalSkin patch was installed during RWO from 1015'—1128' and pressure tested to 3500 psi • The cement bond log shows adequate cement as per original injection order. The proposed kick-off point for the CTD sidetrack is in the A-sand perfs and should not compromise existing conformance. 30-16 (abandoned well bore),—728' away from AL1 lateral to south • 9-5/8"casing was cemented down to 2375', 900 sks ASIII © 12.1 ppg and 300 sks ASII @ 15.2 ppg • Set a balanced cement plug of 183 sks 15.8 ppg "G"cement from TD of 7980'—7680' MD • Set a balanced cement plug of 194 sks 16.5 ppg "G"cement from 5195'—4900' MD • Well was sidetracked in 1988 from 5100' MD. 3N-13(injector),—1253' away from 30-16AL1, L1-01 & L1-02 lateral to southwest • The 3N-13 is currently injecting into the Kuparuk A&C-sand intervals. • Recently received RWO to fix communication problem, original waiver cancelled • Completed with 7", 26#, J-55 casing • C-sand perforations: Cl: 7485'-7505' MD • A-sand perforations:A3: 7557'-7571' MD,A2: 7580'-7607' MD &A1: 7621'-7654' MD • Packers at 7333', and 7253' MD, for a C-sand Straddle • Classified as a"Normal Well" and passed the last MIT-IA on 9/08/13 • The cement bond log shows adequate cement as per original injection order Page7of8 ORIGIN L 2/11/2015 PTD Application: 30-16AL1, L1-01 & L1-02 17. Attachments Attachment 1: Directional Plans for 30-16AL1, L1-01 & L1-02 Attachment 2: Current Well Schematic for 30-16A Attachment 3: Proposed Well Schematic for 30-16AL1, L1-01 & L1-02 Page 8 of 8 O R I G I N A L 2/11/2015 e. aO N 2 0 b ¢ 2 N 2 In Q 2 n acnes t tow on w O `w b ;a O O a 8 i - @1a' o@ `w JmJCJ m H :J I II 1 I I 0 I y I0 a) - , 2 _ _ ~ U I = La L a a) Co a a O O 0 t ba O d U N N i t c 6 I a s c0 5 a) I N U ..,N _ •N H O 1 _�., ZT O CO N N- E v 0.0 c 0 E a Cx c � COca. N I- 2 Ual U H st 0 .fl v = .o W \ I C \ Z N -fl Y J uUi o `o N \1 I n• •c a LL (0 / • c v O" c Q = 3 `) m a \ To o av Co pN o 1 c in O m It (0 O- fn O co Y 0 c O Y v) co c y+ LL J U I- O OE, a 1 E d a Iaif r N X `- a Yr, '•c / u 0 3 cap a N N N m (� N O.s E a ' "C m - CO m V (n V � tA � V 273 O Q� / c co ..ccu' p ¢) C) El- n c_ / O Q 3 r� E Y L O L N▪ N aa+ a I a) O C O.O u..y u DQE moff 3a �_ a 3 t m :a CO a f l a) cc !f ' f i 1 4:4:M: Wi, GL -. O O J y::v O ▪ -.....i:: L•L'Y`.... 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Kuparuk River Unit Kuparuk 30 Pad 30-16 30-16AL1-02 Plan: 30-16AL1-02_wp02 Standard Planning Report 23 January, 2015 r' 1 BAKER HUGHES \ ILIAL ' ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 30-16 Company: ConocoPhillips(Alaska)Inc.NAD83-NAD27 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 30-16A @ 59.00usft(30-16A) Site: Kuparuk 30 Pad North Reference: True Well: 30-16 Survey Calculation Method: Minimum Curvature Wellbore: 30-16AL1-02 I Design: 30-16AL 1-02_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 30 Pad Site Position: Northing: 6,022,094.67 usft Latitude: 70°28'17.333 N From: Map Easting: 525,478.25 usft Longitude: 149°47'30.897 W Position Uncertainty: 0.00 usft Slot Radius: 13.200 in Grid Convergence: 0.20 ° Well 30-16 Well Position +N/-S 0.00 usft Northing: 6,021,714.15 usft Latitude: 70°28'13.583 N +EI-W 0.00 usft Easting: 525,698.17 usft Longitude: 149°47'24.470 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 30-16AL1-02 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (°) (nT) BGGM2014 2/1/2015 19.01 81.01 57,582 Design 30-16AL1-02_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,885.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 225.06 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (usft) (0) (°) (usft) (usft) (usft) (°/100ft) 0100ft) (°/100ft) (°) Target i 8,885.00 99.41 213.69 6,421.01 -2,798.06 -4,016.70 0.00 0.00 0.00 0.00 I 8,965.00 91.41 213.69 6,413.48 -2,864.28 -4,060.84 10.00 -10.00 0.00 180.00 9,315.00 90.29 178.70 6,408.11 -3,195.15 -4,156.92 10.00 -0.32 -10.00 268.50 9,465.00 90.02 193.70 6,407.69 -3,343.85 -4,173.08 10.00 -0.18 10.00 91.00 9,615.00 89.76 178.70 6,407.97 -3,492.54 -4,189.23 10.00 -0.17 -10.00 269.00 9,835.00 89.41 200.70 6,409.58 -3,708.06 -4,226.07 10.00 -0.16 10.00 91.00 9,970.00 89.42 187.20 6,410.96 -3,838.77 -4,258.54 10.00 0.01 -10.00 270.00 10,120.00 94.03 201.48 6,406.42 -3,983.62 -4,295.55 10.00 3.07 9.52 72.00 10,220.00 93.97 211.51 6,399.43 -4,072.79 -4,340.00 10.00 -0.06 10.02 90.00 10,390.00 93.79 194.47 6,387.84 -4,228.35 -4,405.99 10.00 -0.10 -10.02 270.00 10,490.00 93.74 204.49 6,381.26 -4,322.30 -4,439.22 10.00 -0.06 10.02 90.00 10,650.00 93.59 188.46 6,370.96 -4,474.91 -4,484.36 10.00 -0.09 -10.02 270.00 1/23/2015 12:28:59PM Page 2 COMPASS 5000.1 Build 61 ORIGINAL • • Irr- ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 30-16 Company: ConocoPhillips(Alaska)Inc.NAD83-NAD27 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 30-16A @ 59.00usft(30-16A) Site: Kuparuk 30 Pad North Reference: True Well: 30-16 Survey Calculation Method: Minimum Curvature Wellbore: 30-16AL1-02 Design: 30-16AL1-02_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) (0) (o) (usft) (usft) (usft) (usft) (°/100ft) (0) (usft) (usft) 8,885.00 99.41 213.69 6,421.01 -2,798.06 -4,016.70 4,819.67 0.00 0.00 6,018,902.52 521,691.55 TIP/KOP 8,900.00 97.91 213.69 6,418.75 -2,810.40 -4,024.93 4,834.21 10.00 -180.00 6,018,890.15 521,683.37 8,965.00 91.41 213.69 6,413.48 -2,864.28 -4,060.84 4,897.69 10.00 -180.00 6,018,836.16 521,647.64 Start 10 dls 9,000.00 91.31 210.19 6,412.65 -2,893.97 -4,079.35 4,931.76 10.00 -91.50 6,018,806.41 521,629.24 9,100.00 91.02 200.19 6,410.60 -2,984.32 -4,121.85 5,025.67 10.00 -91.58 6,018,715.91 521,587.06 9,200.00 90.69 190.19 6,409.11 -3,080.69 -4,148.02 5,112.27 10.00 -91.79 6,018,619.46 521,561.22 9,300.00 90.35 180.20 6,408.20 -3,180.15 -4,157.07 5,188.92 10.00 -91.94 6,018,519.98 521,552.52 9,315.00 90.29 178.70 6,408.11 -3,195.15 -4,156.92 5,199.42 10.00 -92.03 6,018,504.99 521,552.71 3 9,400.00 90.14 187.20 6,407.79 -3,279.96 -4,161.30 5,262.42 10.00 91.00 6,018,420.17 521,548.63 9,465.00 90.02 193.70 6,407.69 -3,343.85 -4,173.08 5,315.88 10.00 91.03 6,018,356.25 521,537.07 4 9,500.00 89.96 190.20 6,407.70 -3,378.08 -4,180.32 5,345.20 10.00 -91.00 6,018,321.99 521,529.95 9,600.00 89.79 180.20 6,407.91 -3,477.55 -4,189.38 5,421.86 10.00 -91.00 6,018,222.51 521,521.24 9,615.00 89.76 178.70 6,407.97 -3,492.54 -4,189.23 5,432.35 10.00 -90.98 6,018,207.51 521,521.43 5 9,700.00 89.62 187.20 6,408.43 -3,577.35 -4,193.60 5,495.35 10.00 91.00 6,018,122.70 521,517.36 9,800.00 89.46 197.20 6,409.23 -3,674.97 -4,214.71 5,579.24 10.00 90.95 6,018,025.02 521,496.59 9,835.00 89.41 200.70 6,409.58 -3,708.06 -4,226.07 5,610.66 10.00 90.87 6,017,991.89 521,485.34 6 9,900.00 89.41 194.20 6,410.25 -3,770.04 -4,245.55 5,668.23 10.00 -90.00 6,017,929.86 521,466.08 9,970.00 89.42 187.20 6,410.96 -3,838.77 -4,258.54 5,725.97 10.00 -89.93 6,017,861.08 521,453.33 7 10,000.00 90.35 190.05 6,411.02 -3,868.43 -4,263.04 5,750.11 10.00 72.00 6,017,831.41 521,448.94 10,100.00 93.42 199.57 6,407.72 -3,964.93 -4,288.55 5,836.33 10.00 71.99 6,017,734.83 521,423.76 10,120.00 94.03 201.48 6,406.42 -3,983.62 -4,295.55 5,854.49 10.00 72.31 6,017,716.12 521,416.83 8 10,200.00 93.99 209.50 6,400.82 -4,055.60 -4,329.87 5,929.62 10.00 90.00 6,017,644.03 521,382.76 10,220.00 93.97 211.51 6,399.43 -4,072.79 -4,340.00 5,948.93 10.00 90.56 6,017,626.81 521,372.69 9 10,300.00 93.93 203.49 6,393.91 -4,143.52 -4,376.82 6,024.96 10.00 -90.00 6,017,555.96 521,336.12 10,390.00 93.79 194.47 6,387.84 -4,228.35 -4,405.99 6,105.53 10.00 -90.55 6,017,471.04 521,307.24 10 10,400.00 93.79 195.47 6,387.18 -4,237.99 -4,408.57 6,114.16 10.00 90.00 6,017,461.39 521,304.70 10,490.00 93.74 204.49 6,381.26 -4,322.30 -4,439.22 6,195.42 10.00 90.07 6,017,376.98 521,274.33 11 10,500.00 93.74 203.49 6,380.60 -4,331.41 -4,443.28 6,204.73 10.00 -90.00 6,017,367.85 521,270.31 10,600.00 93.67 193.47 6,374.13 -4,425.94 -4,474.87 6,293.86 10.00 -90.07 6,017,273.23 521,239.05 10,650.00 93.59 188.46 6,370.96 -4,474.91 -4,484.36 6,335.16 10.00 -90.71 6,017,224.23 521,229.73 Planned TD at 10650.00 1/23/2015 12:28:59PM Page 3 COMPASS 5000.1 Build 61 ORIGINAL ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 30-16 Company: ConocoPhillips(Alaska)Inc.NAD83-NAD27 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 30-16A @ 59.00usft(30-16A) Site: Kuparuk 30 Pad North Reference: True Well: 30-16 Survey Calculation Method: Minimum Curvature Wellbore: 30-16AL1-02 Design: 30-16AL1-02_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 30-16AL1_Fault4 0.00 351.30 0.00 -4,595.82 -4,539.06 6,017,103.14 521,175.45 70°27'28.370 N 149°49'37.823 W -plan misses target center by 6372.35usft at 10650.00usft MD(6370.96 TVD,-4474.91 N,-4484.36 E) -Rectangle(sides W500.00 H1.00 D0.00) 30-16AL1_Fault1 0.00 351.30 0.00 -2,417.42 -3,450.36 6,019,285.08 522,256.51 70°27'49.800 N 149°49'5.868 W -plan misses target center by 6456.39usft at 8900.00usft MD(6418.75 TVD,-2810.40 N,-4024.93 E) -Rectangle(sides W220.00 H1.00 D0.00) 30-16AL1-02_T01 0.00 351.30 6,433.00 -2,691.75 -3,936.38 6,019,009.10 521,771.49 70°27'47.100 N 149°49'20.147 W -plan misses target center by 133.78usft at 8885.00usft MD(6421.01 TVD,-2798.06 N,-4016.70 E) -Point 30-16AL1_Fault2 0.00 351.30 0.00 -2,666.83 -3,913.29 6,019,034.10 521,794.49 70°27'47.345 N 149°49'19.468 W -plan misses target center by 6418.21 usft at 8965.00usft MD(6413.48 TVD,-2864.28 N,-4060.84 E) -Rectangle(sides W280.00 H1.00 D0.00) 30-16A CTD Polygon 0.00 351.30 0.00 -2,192.24 -3,208.55 6,019,511.07 522,497.52 70°27'52.016 N 149°48'58.764 W -plan misses target center by 6499.92usft at 8900.00usft MD(6418.75 TVD,-2810.40 N,-4024.93 E) -Polygon Point 1 0.00 0.00 0.00 6,019,511.07 522,497.52 Point 2 0.00 -137.88 -334.50 6,019,323.12 522,188.41 Point 3 0.00 -434.77 -963.58 6,018,932.52 521,612.89 Point4 0.00 -903.10 -1,174.19 6,018,437.29 521,477.29 Point 5 0.00 -1,403.02 -1,213.90 6,017,937.30 521,515.39 Point6 0.00 -1,794.60 -1,350.24 6,017,529.38 521,441.28 Point? 0.00 -2,214.26 -1,462.68 6,017,097.42 521,395.12 Point8 0.00 -2,316.26 -1,172.00 6,017,041.63 521,698.05 Point 0.00 -1,875.75 -1,013.48 6,017,501.31 521,786.51 Point 10 0.00 -1,477.09 -901.12 6,017,912.51 521,835.83 Point 11 0.00 -991.25 -840.46 6,018,401.84 521,820.60 Point 12 0.00 -616.68 -700.17 6,018,793.56 521,901.25 Point 13 0.00 -343.13 -265.19 6,019,131.08 522,288.63 Point 14 0.00 -202.35 96.32 6,019,326.08 522,623.98 Point 15 0.00 0.00 0.00 6,019,511.07 522,497.52 30-16AL1_Fault3 0.00 351.30 0.00 -4,120.35 -4,374.39 6,017,579.13 521,338.46 70°27'33.047 N 149°49'32.993 W -plan misses target center by 6381.77usft at 10650.00usft MD(6370.96 TVD,-4474.91 N,-4484.36 E) -Rectangle(sides W340.00 H1.00 D0.00) 30-16AL1-02_T02 0.00 351.30 6,403.00 -4,471.99 -4,488.63 6,017,227.14 521,225.45 70°27'29.588 N 149°49'36.344 W -plan misses target center by 32.17usft at 10645.92usft MD(6371.22 TVD,-4470.88 N,-4483.74 E) -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 10,650.00 6,370.96 2 3/8" 2.375 3.000 1/23/2015 12:28:59PM Page 4 COMPASS 5000.1 Build 61 031GINAL ` r/" ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 30-16 Company: ConocoPhillips(Alaska)Inc.NAD83-NAD27 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 30-16A @ 59.00usft(30-16A) Site: Kuparuk 30 Pad North Reference: True Well: 30-16 Survey Calculation Method: Minimum Curvature Wellbore: 30-16AL1-02 Design: 30-16A L 1-02_wp02 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 8,885.00 6,421.01 -2,798.06 -4,016.70 TIP/KOP 8,965.00 6,413.48 -2,864.28 -4,060.84 Start 10 dls 9,315.00 6,408.11 -3,195.15 -4,156.92 3 9,465.00 6,407.69 -3,343.85 -4,173.08 4 9,615.00 6,407.97 -3,492.54 -4,189.23 5 9,835.00 6,409.58 -3,708.06 -4,226.07 6 9,970.00 6,410.96 -3,838.77 -4,258.54 7 10,120.00 6,406.42 -3,983.62 -4,295.55 8 10,220.00 6,399.43 -4,072.79 -4,340.00 9 10,390.00 6,387.84 -4,228.35 -4,405.99 10 10,490.00 6,381.26 -4,322.30 -4,439.22 11 10,650.00 6,370.96 -4,474.91 -4,484.36 Planned TD at 10650.00 1/23/2015 12:28:59PM Page 5 COMPASS 5000.1 Build 61 ConocoPhillips ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 30 Pad 30-16 30-16AL1-02 30-16AL1-02_wp02 Travelling Cylinder Report 21 January, 2015 BAKER HUGHES O1GJNAL IP • • ,. Baker Hughes INTEQ Ire(-- ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 30-16 Project: Kuparuk River Unit TVD Reference: 30-16A @ 59.00usft(30-16A) Reference Site: Kuparuk 30 Pad MD Reference: 30-16A @ 59.00usft(30-16A) Site Error: 0.00usft North Reference: True Reference Well: 30-16 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 30-16AL1-02 Database: OAKEDMP2 Reference Design: 30-16AL1-02_wp02 Offset TVD Reference: Offset Datum Reference 30-16AL1-02_wp02 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 2004-100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 8,885.00 to 10,650.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,259.10usft Error Surface: Elliptical Conic Survey Tool Program Date 1/21/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 100.00 7,800.00 30-16A(30-16A) GCT-MS Schlumberger GCT multishot 7,800.00 8,885.00 30-16AL1_wp07(30-16AL1) MWD MWD-Standard 8,885.00 10,650.00 30-16AL1-02_wp02(30-16AL1-02) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (•') (") 10,650.00 6,429.96 2 3/8" 2-3/8 3 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) Kuparuk 30 Pad 30-15-30-15-30-15 Out of range 30-16-30-16AL1-30-16AL1_wp07 8,900.00 8,900.00 0.08 0.48 -0.27 FAIL-Minor 1/10 30-16-30-16AL1-01-30-16AL1-01_wp02 8,900.00 8,900.00 0.08 0.48 -0.27 FAIL-Minor 1/10 30-17-30-17-30-17 Out of range 30-18-30-18-30-18 Out of range 30-19-30-19-30-19 Out of range 30-20-30-20-30-20 Out of range Kuparuk UGNU Plan:UGNU SAGD-UGNU SAGD-UGNU SAGD Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 1/21/2015 5:20:58PM Page 2 of 7 COMPASS 5000.1 Build 65 i rt 1 o .O [g 8 d V 4 keel b S d w, o�y + N en el ii 8 d E Vi 4 1",11 s. ..5. -8 111111: 3m$s1 Phi 1 .. -1 b _6 o M 3 'V 1 ,-, 0. o i yy o O :m lb o P M c h N b .O 5 '8 g j Y :N 3 g _ S DA d u' g ^ . •rJ' Q J oo SN , b - m o N r h dm § J _a o oo iii G (.4 J es i'l CD Bo § 8 8 8 8 8 8 8 § 8 § 8 8 § 8 § •g 3d 13 r e b M M M 4 4 : el me (uNsn 00Z)( )gNoN/(-)ipnos e _. a L h SS O o O '� At 8 a o c ti O _ q V $a �� '300 � '7 J- C d W c,,— t 0I F V o :<-'-- CO ce /1 Q F-(n M V 41 00 N- O� d S� a eeO co o Gp p O ((y//]CroCOOaa0`ACCOOrinOMi,Mn4 UP b =$ o Z O CD m,-M CO N p OO O O 0 0 •.0 N �� �R u to CO to up to CO CO CMD .y O O O O O O O O O 0 O O < _ R 4 03 r, a O O u A O O O O O O O O O LI -- - - LL OO GO.-ai O(V 0000 '8 '0 Q CO H m N m COV O CrV r M CCVV O CV 1:-' VV a M N ~ -C2 o _92 °Q 0,00 0000 00000 O d .N r 4 0 0 0 0 0 0 0 0 0 0 0 0 'V . 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X888888888888 _ c g g 0 8e c�v e b 8 �� U GOO at g 00 008Q bu0 140 140 u0 U0 U1 CD CD CD CD cp s V b .O O D b ,O GOO O coO CJ N M,r C]CO r•03 at 0.-0 O o <NnN (ur/gsn Os)I(;daa ino!paA an.1J V IflIGINAL Bettis, Patricia K (DOA) P c2LS---03 I From: Burke, Jason <Jason.Burke@conocophillips.com> Sent: Monday, February 23, 2015 4:03 PM To: Bettis, Patricia K (DOA) Subject: RE: KRU 30-16AL1, 30-16AL1-01, 30-16-AL1-02: Permit to Drill Application Patricia Sorry for the delayed response, I was out of the office quite sporadically last week. This well will not be pre-produced and the KWF will be at least 12.2 ppg. Jason ConocoPhillips Jason Burke C'T1) Engineer - yreclt er:Kupw'uk 'Arent 700 cj St #1210 Anchoraqe, .AJC 90501 (0): (907)-265-6097 (:11): (907)-231-4568 Jason.Burke@conocophillips.com From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Monday, February 23, 2015 1:43 PM To: Burke, Jason Subject: [EXTERNAL]FW: KRU 30-16AL1, 30-16AL1-01, 30-16-AL1-02: Permit to Drill Application Good afternoon Jason, Did you receive my email of last Wednesday? Thanks, Patricia From: Bettis, Patricia K(DOA) Sent: Wednesday, February 18, 2015 4:39 PM To: Burke, Jason (Jason.Burke@conocophillios.com) Subject: KRU 30-16AL1, 30-16AL1-01, 30-16-AL1-02: Permit to Drill Application Good afternoon Jason, Does ConocoPhillips plan to pre-produce any of the KRU 30-16A laterals? On page 4 of the "Application for Permit to drill Document" it states that "two wellbores of kill weight fluid will be available". What would be the weight of the available KWF? Thank you, 1 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. 2 Loepp, Victoria T (DOA) From: Burke,Jason <Jason.Burke@conocophillips.com> Sent: Tuesday, February 17, 2015 9:05 AM To: Loepp,Victoria T(DOA) Cc: Venhaus, Dan E Subject: 30-16A Permit Follow Up Flag: Follow up Flag Status: Flagged Victoria As you are processing the 30-16A drilling permit you'll notice it recommends a 5000 psi pressure test. I was wondering if we could bump that down to 4900 psi on the approved permit. It will give us a little cushion for pressure testing, so if we bump a little high (say 4920 psi)we aren't exceed the working pressure of our BOP stack. Thanks Jason ConochiIIi ps Jason Burke CTD Engineer- Greater Xuyaruk.Area 70oGSt#1210 .Anchorage,.AX 99501 (0):(9o7)-265-6o97 (14):(907)-231-4568 Jason.Burke@conocophillips.com 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: I.CR k 30 -- /G AL..) - o2- PTD: ZPTD: c2)S -O3 Development /Service _Exploratory _Stratigraphic Test _Non-Conventional FIELD: KuilatuC I Au-- POOL: Xtkpc ��J�ar / kApJ1( 2v U,/ Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit „/r- LATERAL No. /8'8- O j3 , API No. 50-C - 77 -01 - o . (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name)in the attached application,the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(dX2XB) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion,suspension or abandonment of this well. 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