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214-186
STATE OF ALASKA • AL,- KA OIL AND GAS CONSERVATION COti,,.,ISSION "r i,&, � A REPORT OF SUNDRY WELL OPERATIONS JUN 2 3 L11_ 1 Operations Abandon r Rug Perforations r Fracture Stimulate r Rill Tubing r Operations shutdown r Performed Suspend r Perforate r Other Stimulate r Alter Casing r Change PApViltellvpr-ogrbm r Rug for Redrill r Perforate New Fbol r Repair Well r Re-enter Susp Well r Other. Prod to WINJ rT0 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number. _ ConocoPhillips Alaska, Inc. Development r Exploratory r 214-186-00 3.Address. 6 API Number Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-20770-60 7. Property Designation(Lease Number). 8.Well Name and Number: ADL 25639 ALK 464 KRU 1 H-04L1 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 10269 feet Plugs(measured) None true vertical 6605 feet Junk(measured) None Effective Depth measured 10269 feet Packer(measured) 0 true vertical 6605 feet (true vertical) 0 Casing Length Size MD TVD Burst Collapse 6605 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Perforation depth Measured depth. 7564-8327,8579-8739,8740-10268 True Vertical Depth. 6601-6599,6629-6648,6648-6605 Tubing(size,grade, MD,and TVD) 3.5, L-80, 7342 MD, 6457 TVD SCANNED ILL 2 8 /nib Packers&SSSV(type,MD,and 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 416 1363 1253 1027 256 Subsequent to operation 0 0 4590 500 1789 14.Attachments(required per 20 AAC 25 070,25 071,&25 283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work. Oil r Gas r VVDSPL r Rinted and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt 315-318 Contact Darrell Humphrey/Bob Christensen Email n1139(a�conocophillips.com Printed Name Darrell Humphrey Title NSK Production Engineering Specialist Signature i/L Phone:659-7535 Date IT � kJ/,5 RBDMSAk JUL - 1 2015 Form 10-404 Revised 5/2015, 7 9 .3---- Submit Original Only 1H-04L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 06/07/15 Well brought on water injection 06/18/15 ISW (CHUCK SCHEVE) MIT-IA PASSED TO 2500 PSI. .. []1. fi KUP PROD 1H-04L1 ConocoPhillips ; Well Attributes Max Angle&MD TD Alaska,Inc. Weubore API/UWI Field Name Wellbore Status Fncl El MD(BKB) Act Btm(ftKB) Crmcd161eps 500292077060 KUPARUK RIVER UNIT PROD I 95.07 8,950.52 10,264.0 --- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1H-04L1,5/20/20153-.3524 PM SSSV:NIPPLE Last WO: 35.00 7/23/1982 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:GLV C/O lehallf 5/28/2015 HANGER;24.1 k lye Casing Strings Casing Description OD(int ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... W7/Len(I...Grade Top Thread �t LINER Li I 2 3/81 1.9921 7,555.41 10,265 0I I 4.601 L-80 IST-L Iii vii Liner Details 111111.MNominal ID Top(ftKB) Top(TVD)(ftKB) Top teal(°) Item Des Corn (in) CONDUCTOR;31.0-110.011_. 7,555.4 6,599.2 80.06 BILLET LINER TOP BILLET 1.900 8,740.2 6,648.6 87.02 DEPLOY SHORTY DEPLOYMENT SLEEVE 1.900 NIPPLE;514.8 Perforations&Slots I Shot Dens I Top(TVD) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 7,564.4 8,327.4 6,600.7 6,599.5 A-4,1H-04L1 1/1/2015 SLOTS SLOTTED LINER SURFACE;20.6-2,191.0 8,579.4 8,739.4 6,629.2 6,648.6 A-4,1H-04L1 1/1/2015 SLOTS SLOTTED LINER ill 8,740.6 10,268.6 6,648.6 A-4,1H-04L1 1/1/2015 SLOTS SLOTTED LINER GAS LIFT;2,523.7 Notes:General&Safety M End Date Annotation 10/21/2014 NOTE:WORKOVER GAS LIFT;3,047.4 1/22015 NOTE:ADD LATERALS L1(off main wellbore),L1-01 BARRIER VW;4,504.5 GAS LIFT;5,087.6 GAS LIFT;6,024.0 1111 GAS LIFT;6,647.6 lam GAS LIFT;7,017.1 SEAL ASSY;7,073.0 " PBR;7,080.7 PACKER;7,103.8 PRODUCTION;7,156.4 IPERF;7,180.07,242.0 SLEEVE-C;7,257.3 ill Blast Joint;7,286.2, - II IPERF;7,291.0-7,324.0 B LOCATOR;7,332.6 PACKER;7,333.5 SEAL ASSY;7,333.4 N z SBE;7,336.8 a a NIPPLE;7,347.4 , Niro rail PRODUCTION;28.5.8,071.0 10..-- SLOTS;7,5644.8,327.4 —; SLOTS;7,370.19,589.8-- i I SLOTS;0.579.45,739.4 Om.— SLOTS;8,740.6-10,268.6 LINER L1-01;7.369.3-9,600.0 LINER L1;7,555.4-10,269,0 ' oF Ty e��\� ��s� THE STATE Alaska Oil and Gas es,;,-s ��, of Conservation Commission A:���•�}�_=== LAsKA 333 West Seventh Avenue e GOVERNOR BILL WALKERAnchorage, Alaska 99501-3572 1:3 Main: 907.279 1433 ALAS*P .\U V �� Fax 907.276 7542 www.aogcc.alaska.goV Darrell Humphrey NSK Production Engineering Specialist ` V I ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1H-04L1 Sundry Number: 315-318 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, i0; Cathy '. Foerster Chair DATED this day of May, 2015 Encl. STATE OF ALASKA ' i 3KA OIL AND GAS CONSERVATION COIL JSION . APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1 Type of Request. Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other.Prod to WINJ 57' 2 Operator Name: 4 Current Well Class. , 5.Permit to Drill Number. ConocoPhillips Alaska, Inc. " Exploratory r Development P. 214-186-00 3.Address Stratigraphic r Service 6.API Number. P 0 Box 100360,Anchorage,Alaska 99510 50-029-20770-60• 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's Yes r No 1. j KRU 1 H-04L1 9.Property Designation(Lease Number). 10.Field/Pool(s). ADL 25639 ALK 164 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). 10269 • 6605 ' 10269' • 6605' None None Casing Length Size MD TVD Burst Collapse Liner L1 2714 2.375 10269' 6605' RECEIVED 4 c5 / ZgJl� MAY 222015 AOGCC Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size• Tubing Grade: Tubing MD(ft): 7564-8327,8579-8739,8740-10268' 6601-6599,6629-6648,6648-6605 3.5 L-80 7342 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKERR 4762 FHL PACKER MD=7104 TVD=6255 TRDP-CAMCO TRDP-1A-NC MD=1798 TVD=1798 ,p 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 14.Estimated Date for Commencing Operations: 15 Well Status after proposed work. 5/30/2015 OIL r WINJ p1 WDSPL r Suspended r 16.Verbal Approval Date' WAG r GSTOR r SPLUG r GAS r Op Shutdown r Commission Representative GINJ r Abandoned r 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Contact Darrell Humphrey/Bob Christensen Email. n1139@conocophillips.com Printed Name Darrell Hum hr Title NSK Production Engineering Specialist Signature Phone.659-7535 Date .5-.20, iS Commission Use Only Sundry Number Conditions of approval. Notify Commission so that a representative may witness -3 k r- ; icd Plug Integrity r BOP Test r Mechanical Integrity Test R Location Clearance Clearance r y Other. inSe- en'‘ OP 6'r‘A ✓‘ c>LCC�O fel QM u2 W I l-% 0 2.0 ti . -tu-fr 1,„-,‘f' r5-$t d /1i1' T-/ --/ td a Fi-r r- s(-R h Jf j.-( d "1-) zc t`"1-I . Spacing Exception Required? Yes ❑ No Er Subsequent Form Required. /Q —4 --- APPROVED BY ) Approved by: COMMISSIONER THE COMMISSION Dates' 7 /'�' Approvepcit' i I' r 2 months from the da_t o#approval. Submit Form and Form 10-403 Revised 5/20150 I` /kL.1fj3y ')6 S' '//S Attachments i Duplicate Vfl- �/Z7-/I S �� c.D,.J 5.126/2o,5 RBDM JUN - 3 2015 1H-04L1 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert Kuparuk Well 1H-04 and its associated laterals from Oil Production service to Water Injection service. Converting well 1 H-04 to injection will provide water injection support to the Kuparuk producers 1G-10B, 1G-12 and 1H-06 in the immature A-Sand patterns. Area of Review: An AOR was completed on the PTD's. The top of the Kuparuk C sand was found at 7178' and /6319'tvd. The top of the Kuparuk A sand was found at 7470' and /6565' tvd. Mechanical Condition of Well to be Converted: The mechanical condition of Kuparuk well 1 H-04 is good and classified as a "Normal Well"with the C Sands currently isolated. A State-witnessed MIT-IA will be performed once well 1 H-04 is converted to water injection, online, and stabilized. The CBL, dated 7/20/1982, identified a cement top of approximately 5800' RKB. The CBL was run to a depth of approximately 8000' RKB and indicated good cement for the interval from 5800' to 8000' RKB. The injection tubing/casing annulus is isolated via a Baker 47B2 FHL packer at 7103.8' RKB and a Baker 85- 40 F-1 Permanent packer at 7333.5' RKB. The 16" Conductor was cemented with 274 sx AS II. The 10.75" Surface casing (2191' and/2191' tvd)was cemented with 1000 sx AS III &250 sx AS II. The 7" Production casing (8071' and/7070'tvd)was cemented with 1145 sx Class"G" &250 sx AS II. CBL and interpretation of the cement quality: . The CBL interpretation was completed on the PTD's. • J cot . —t— (f =� 74 / /,� a r.e�o/ �.al ref e' ICI QJ T ( '?)e Carr l fal Co r4Q )e ► ea,oei7e/ -frv q /re -/2iodic,c94' J e To i 7:5 ��► t eGt led .Sc/v,"c O. ,, KUP PROD 1 H-04L1 ConocoPhiIIips ' , Well Attributes Max Angle&MD TD • T " Wellbore API/UWI Field Name Wellbore Status ncl(^) MD(ftKB) Act Btm(ftKB) Alaska,Inc. 500292077060 KUPARUK RIVER UNIT PROD 95.07 8,950.52 r r.xxd+xwp, -.- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1H-04L1,4/22/20152.03:54 PM SSSV:NIPPLE Last WO: 35.00 7/23/1982 Verncal schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ---- -- ---------- -----Last Tag: Rev Reason:GLV C/O lehallf 4/22/2015 .............. HANGER;24.1 L r Casing Strings Tht1 CaLINsinER g DescriptionL1 OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(WD)... Wt/Len(I...Grade Top Thread x{{51 f� 23/8 1.992 7,555.4 10,269.0 4.60 L-80 ST-L -- NM Liner Details Nominal ID Top(ftKB) Top(WD)(MKB)_Top(Del(') Item Des Com (in) CONDUCTOR;31.0-110.0 7,555.4 6,5992 80.06 BILLET LINER TOP BILLET 1.900 8,740.2 6,648.6 87.02 DEPLOY SHORTY DEPLOYMENT SLEEVE 1.900 NIPPLE;514.8 Perforations&Slots Shot Dens iTop(TVD) Blot(TVD) (shotslf Top(ftKB) Btm(ftKB) MB) (ftKB) Zone Date t) Type Com 7,564.4 8,327.4 6,600.7 6,599.5 A-4,1H-04L1 1/1/2015 SLOTS SLOTTED LINER SURFACE;28.&2,191.0 8,579.4 8,739.4 6,629.2 6,648.6 A-4,1H-04L1 1/1/2015 SLOTS SLOTTED LINER 8.740.6 10,268.6 6.618.6 A-4,1H-04L1 1/1/2015 SLOTS SLOTTED LINER GAS LIFT;2,523.7 - Notes:General&Safety aEnd Date Annotation 10/21/2014 NOTE.WORKOVER GAS LIFT;3,847.4 1/2/2015 NOTE:ADD LATERALS L1(off main wellbore),L1-01 BARRIER VLV;4,504.5 all S S GAS LIFT;5,087.6 g I GAS LIFT;6,024.0 a. I p GAS LIFT;6,647.6 a A GAS LIFT;7,017.1 --- SEAL ASSY;7.073.0 PM;7,080.7 PACKER;7,103.8 - . PRODUCTION;7,156.4 a'. a IPERF;7,180.0.7242.0— 1 r SLEEVE-C;7257.3 ( I A Blast Joint;7,286.2 IPERF,7,291.47,324.0' LOCATOR;7.332.6 PACKER;7,333.5i , SEAL ASSY;7,333.4- i,. SBE;7,336.8 NIPPLE;7,347.4 I III III rail 1irt; WLEG;7,410.6 WHIPSTOCK;7,430.0 WINDOW L1;7,435.47,443.0 PRODUCTION;28.5-8,071.0 SLOTS;7,370.1.9.58961 - UNER L1-01;7,369.3.9,800.0 SLOTS;7,564.4-8,327.4 .. I— SLOTS;8,579.4-8,739.4 - SLOTS;8.740 6-10268 6 .1 F- LINER L7;7655.4.10,269.0 ,y O0 1H-04L1701 7 P �� z vs 1. 1H-07 1+.042 ^� V 2.-1H-12 :12:31Hi10� � �1?31H-10-5-1H 21 e . ���` g1H 21 H B. 1H-13 a,••• 13 (III H-04K °NN l 1 0gt1r,'-Ci4eAl S *47(9ryas o b, %a oe J R 0 1H-04L1 o'. 1�- Legend Well Surface Location Pad Mean Center ConocoPhillips Wells Within 1/4 mile radius Alaska, Inc. 1/4 Mile Injection Radius Q1H-04 Injection Swap Analysis ®1H-04L1 1H-04, 1H-04L1, 1H-04L1-01 M1H-04L1-01 H-04L1-01 1H-04L1-01 N STATUS, WELL_TYPE, FLUID_TYPE n o 025 o.s Prnriu, r. nil L\ Miles 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. al IA- - AS (p Well History File Identifier Organizing (done) ❑ Two-sided ❑ Rescan Needed RES AN: OVERSIZED: NOTES: Co Items: ❑ Maps: Grayscale Items: gs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: ftifBY: AllIDDate: 4 I 15 /s/ Project Proofing I/� BY: Aft Date: I� ) /5— /s/ if Scanning Preparation x 30 = (,), + 3 = TOTAL PAGES (19 3 f (Count does not include cover sheet) 1lb BY: C.;ria Date: /s/ Production Scanning Stage 1 Page Count from Scanned File: (1+" (Count does include cov sheet) Page Count Matches Number in Scanning Preparation: YES yyjfD NOBY: dr° Date: 13 I J /s/ 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 e: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. 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O 5 To To lL O .c >. co , a a ,- m C' O Q 1 m O Q (/',1 c Z H L L V) OI m N u- r!) > 0 a E �� 3 1330. 000Y 999 0 0 J _ '' J = NI p )- r CL V 9 m 8 m m m m d W 1 Z LL a LL LL LL LL D C U :° U c> C) 0 g3 m Yq 7 •c�I c c c c co ld E — _ « N co O I O O O O o Q E } } 1 t �. l4 a0i J PDaa'i m m W V m (,) O Le W O W W W W N 2 1 O y m co 12) • LE d • 'Ln Ln a« o m a -I 0 0 1111 Eve E °' W J N a7 7 QI (/) Z m d a- a- a- � N m ce O 10 V LE E 1 W— o Z vm co • w m V Q Jo m f0 a € J E co Z CL U co ca Qm ° o -� a C •o E H 1 O M 0 0a c p 0 Co� o I a O — 1 E « 1 M U N 0 o J } E gt c E Q O cv 1 0 1 0 a I 0. co C� r I 011 I C Ln _ y O L z N @0 c Z m m co m E OC C O 1— E Y � .f0 w = I m m r c N m //� rn « V/ f0 1, N U m Q Q c c O Qc c g m Y m c c a Q c a °- m O Z Cll:1---) o l y U T U Q 2 Q 1 co V Z v) a7 CO CO CO CO Nif) NI- m /� o O Q Q Q Q LO C r'�\ N N To To :0 Cu :0 I C v NCO tO OI m m 01 © } fl O 0b- 0 0 0 0 J € a c 11', ,, 1} 1 m I— MaMMMMC > m m02 W co a 0 02 N NNNNN W O N 0. m a c w m= I -> E m 11 M co O w H m o 0 m m 0 Z z c p o d Q c 8 Q o a 0 c C.) L) 0 a o a a m v E a 00 d Q a Q Q Q Q o 1— 1 ,..,Ce E 2 as 75 0 o ami a' 0 1 0 a .e Iw w w w W J 3 Z 0 a 0 c.) 0 i 10 0 o "' 0 0 o N o nZ n N o> _o p 9 5 T oco in o C z J_ P V Z C0 3 rN co w C N O N a. = O. J W = cc a 0 0 W z C.) v o Z 8 s 'CC ra J o• co C. U) c T O O 6 O N1- E V Z. o en w No J < oca a C 7 o CO • LN re p 7 N U) < 0 Q a Y o o Y a) Q G z E o Q It 0 E Ivz m 3 in 0 0 m o 0 t0 > o 1- 4 T 4 N G• m w U w C7 E O 0 a • RECEIVED STATE OF ALASKA FEB 02 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AN[AEC la Well Status' Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ 1b Well Class 20AAC 25 105 20AAC 25.110 Development ❑ ' Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service ❑ StratigraphicTest❑ 2.Operator Name. 5 Date Comp,Susp, 12.Permit to Drill Number ConocoPhillips Alaska, Inc. or Aband: •January 2,2015 214-186/ 3.Address. 6 Date Spudded 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 ' December 22,2014 50-029-20770-60• 4a Location of Well(Governmental Section) 7 Date TD Reached 14.Well Name and Number. Surface: 911'FNL, 1140'FEL,Sec.33,T12N, R10E, UM 'December 26,2014 KRU 1H-04L1 • Top of Productive Horizon 8 KB(ft above MSL). 85'RKB 15.Field/Pool(s) 1128'FNL, 1333'FWL,Sec.33,T12N, R10E, UM GL(ft above MSL): 50'AMSL Kuparuk River Field Total Depth: 9 Plug Back Depth(MD+TVD). 1592'FSL, 1295'FWL,Sec.33,T12N, R10E, UM 10264'MD/6605'TVD Kuparuk River Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27). 10 Total Depth(MD+TVD)- 16.Property Designation: Surface. x-549210 y- 5979789 Zone-4 10264'MD/6605'TVD ADL 25639 • TPI. x-546405 y- 5979555 Zone-4 11.SSSV Depth(MD+TVD) 17.Land Use Permit: Total Depth: x-546390 y- 5976996 Zone-4 nipple @ 515'MD/515'TVD 464 18 Directional Survey Yes ✓❑ No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD (Submit electronic and printed information per 20 AAC 25 050) N/A (ft MSL) 2915'MD/2904'TVD 21 Logs Obtained(List all logs here and submit electronic and printed information per 20 MC 25 071): 22 Re-drill/Lateral Top Window MD/TVD GR/Res •7430'MD/6532'TVD 23 CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 65# H-40 31' 110' 31' 110' 24" 274 sx AS II 10.75" 45.5# K-55 29' 2191' 29' 2191' 13.5" 1000 sx AS III,250 sx AS II 7" 26# K-55 29' 8071' 29' 7070' 8.75" 1145 sx Class G,250 sx AS II 2.375" 4.6# L-80 7555' 10264' 6597' 6605' 3" slotted liner 24.Open to production or injection? Yes ❑✓ No ❑ If Yes,list each 25 TUBING RECORD __ Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 5.5 x 3.5 7455' 7104'MD/6255'TVD slots from 7564'-8327'MD 6600'-6600'TVD Ambiiiiimm .ar.t 7334'MD/6451'TVD slots from 8579'-10264'MD 6629'-6605'TVD ' eMP'� 26 ACID,FRACTURE,CEMENT SQUEEZE,ETC 1, lk Was hydraulic fracturing used during completion? Yes❑ No❑ VE //FIE DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED .n_" none 27 PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc) waiting on facility hook-up ✓ Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press 24-Hour Rate-> 28 CORE DATA Conventional Core(s)Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No O If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE Form 10-407 Revised 10/2012 CONTINUED ON REVERSRBDMS- \ FEB - 4 201�ubmit original only V'TL z/G//5- Y , ------ '?Q 2,Itlll`$� G 29 GEOLOGIC MARKERS(List all formations and ma, encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes Q No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 2915' 2904' needed,and submit detailed test information per 20 AAC 25 071. Top Kuparuk A4 7510' 6586' Kuparuk A4 8226' 6594' Kuparuk A4 8616' 6637' Kuparuk A4 9115' 6641' Kuparuk A4 9395' 6628' Kuparuk A4 9631' 6623' Kuparuk A4 9710' 6622' Base Kuparuk A4 10010' 6613' N/A Formation at total depth: Kuparuk A4 31 LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Email. Codv.J.Pohleraconocoohillips.com P Printed Name D.Venhaus ,_���S Title CTD Engineering Supervisor l� ///,� l /940 Signature fji✓/fjffJ/j�-- Phone 263-4372 Date /PO/940/5 -- INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells' Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20:Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27:Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 r-' KUP SVC 1 H-04L1 COME PhiIIip5 r Well Attributes Max Angle&MD TD Alaska.Inc, Wellbore API/OW1 Field Name Wellbore Maths ncl(•) MD(IIKB) Act Wm(859) FrrrinipllMps 500292077060 KUPARUK RIVER UNIT SVC 95.07 8,950.52 -.. Comment 1)25(ppm) Date Annotation End Date KB-Grd(tt) Rig Release Date 11-1-0411,1/2812015 1021 53 AM 5SSV:NIPPLE Last WO: 35.00 7/23/1982 Vertical schematic(actual) Annotation (Depth(ftK8) 'End DateAnnotation Last Mod By i End Date Last Tag: Rev Reason:ADD L ATFRAL S L t L 1-01 smsmitlt 123/2015 RANGER;24.1 1-1,41-I -- -- - - Casing Strings Casing Description OD(In) 10(In) Top(859) Set Depth MKS) Set Depth(TVD)...Wnlen(I...Grade Top Thread LINER L1 2 3/5 1.992 7,555.4 10,269.0 4.60)L-80 ST-L .AjLiner Details Nominal 10 .lam Top(855) Top(TVD)(11KB) Top Incl(°) kern Des Com (In) CONDUCTOR:31.0410.0 i 7,555.4 6.599.2 r 8005 BILLET LINER TOP BILLET 1900 8,740.2 6648.6 87.02 DEPLOY SIIORTY DEPLOYMENT SLEEVE 1.900 NIPPLE.5148 I3 perforations&Slots I Shot Dens Top(ND) Bim(TVD) (shots!( Top MEI) Btm(SKS) NOON (11K8) Zone Dale f) Type Com 7,664.4 8,327.4 6,600.7 6.599.5 A-4,1H-04L( 12.1282015 SLOTS SURFACE:28.6-2,191.0 8.579.4 8,739.4 6,629.2 6,648.6 A-4,IH-04L1 12/28/2015 SLOTS GAS LIFT;2.523.7 . 8.740.6 10,268.6 6,648.6 A-4,11-1-641 1 12,28/2015 SLOTS GAS LIFT.364?.4 Notes:General&Safety End Dale Annotation 10/21/2014 NOTE.WORKOVER 1,2/2015 NOTE:ADD LATERALS L1(o8 main welibofe),L1-01 BARRIER VLV;4.504.5 .. GAS LIFT;5087.6 GAS LIFT;6.024.0 f GAS LIFT;6,617.6_:lill( GAS LIFT.7.017.1 SEAL ASSY;7,073 0 FOR,7.080.7 PACKER;7103 B PRODUCTION;7,168.1 f Fe (PERF,7,180.0-7,212.0 I SLEEVE-C.7,257.3 Blasi Laird.7.286.2 (PERF;7,2910-7,3240 s I I LOCATOR.7,332.8 PACKER.7.333.5., SEAL ASSY;7,333 4— SBE;7,336.8 NIPPLE 7,347.4 1 IC_:I I.s 'y.I Lla�..._ I WLEG:7.410.6 IR1, Al WHIPSTOCK;7,443.0 WINDOW L1,7,135.0-7.4430 PRODUCTION;28.5-B.071.0 SLOTS-7,370.1-9,589.e 1—.. LINER 11-01.7,359.3-9.800.0 8 LI i i Llt:LR 17.515 410,269 0 p o 1---- o o n CD CL v v r a cocv O• aO a) 06 E co p J N co - Op2 M 2 ei j > > C NO VO J O O E ._(0CDpO1:T1 O U O C— O) N VN C ^ ( a) C" o Im opa) E .cocE am na i -2Uoa N flpo U�oN 0 0 0 n a > a- m v i` 0 p I-U o I (a a).c �- -a0 p . , co t,a- p p mFl2 coE° p 03 LO> dac2 �-p EoNo o >@ oco n c rn 0k a) 9 Nor-v o.Eo E2 p') op) N N rg > ° a7E o O m 0 r — c cn rpcc) _ m co cor JVva m )O a p Q t °7M N �a_O0 oc C12p RN O aO W a)— ar >. 2t >,� 2 is a _ U m m W 2 E a2E� aa E co c L.Ucoa r4) O -9- Qc N m 63 'E• 'O L C N 2U x r.4a)••j a> a co eQ- o ° M m o -) oco OCD o_ 0m Q COa) D nN. . • c Yk E YN�� E N a) -- ti N- a) aWE n co a) ca 2 a3a) 2 aJ a) a) a)`-m a) O rn 0 co al I dl 0 U)c�u.. CO U m o V)u-U) 0 N N N N N NI m a) a) N N N (V ca a) a) a) N ,- Z Z O s s s U s s s o C) C) C) C) Q C) m m m C) V A 7 J m m m C) r Ico OM N-r NN- O U)a O 1 TJi i .--- . !1 114.1 _ —� w .I e Wirt c r , C.� p M N -N �r 'IIV Na)�ppp Nro o co �n- p O a. Y� 22 n'S r av \� I N� Lo a 0 aka) vN �Ur I �p ✓ �p �N �rr �� O UN I, �LO N- #� co En _ V QO M o CC N-r N N N N �' ro m 4, co - co O Li) o c N p a)� N- �r = coo m N Nor 2ooa�i ¢r N C r' .-u) UUU moo tiUj .c Opo C r O p ca m a J 0 0 C '—F-J 1 H-04 PRE-RIG WELL WORK DATE SUMMARY 11/10/2014 (PRE-RWO): FUNCTION SEIZED LDS ON OC (WOULD NOT FUNCTION). 11/11/2014 PULLED BALL & ROD @ 7267' SLM; PULLED SOV& SET DV @ 7017' RKB. IN PROGRESS 11/12/2014 3000 PSI MIT-IA (PASS) PULL RHC PLUG @ 7257' RKB &TAGGED TD @ 7610' SLM (EST 106' RATHOLE). JOB COMPLETE 11/15/2014 PRE CTD: MV,SSV,SWAB ALL PASSED POSITIVE AND NEGATIVE PRESSURE TESTS. 11/18/2014 TAGGED @ 7586' SLM. MEASURED BHP @ 7435' RKB (3396 PSI). DRIFT W/ DMY WHIPSTOCK. READY FOR E-LINE. 11/25/2014 SET 5.5" GEN II DELTA WHIPSTOCK. TOP OF WHIPSTOCK AT 7430' RKB. SET AT 0 DEG FROM HIGH SIDE. CCL TO TOP OF WHIPSTOCK= 15'. CCL STOP DEPTH = 7415' RKB. TWO PIP TAGS INSTALLED IN WHIPSTOCK AT 7437.35' RKB. *READY FOR SLICKLINE* 12/16/2014 ASSIST VALVE CREW IN SETTING BPV. ConocoPhiIIips Time Log & Summary Wel(view Web Reporting Report Well Name: 1H-04 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 12/19/2014 10:00:00 AM Rig Release: 1/2/2015 6:00:00 PM Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 12/18/2014 24 hr Summary Complete RD from 1L-04. Inspect worksite,start rig move to 1 H-Pad. 15:00 18:00 3.00 0 0 MIRU MOVE DMOB P Complete RD from 1L-04. Complete rig down checklist. Check tree flange bolts, all bolts were tight, 30 minutes to complete. 18:00 20:30 2.50 0 0 MIRU MOVE DMOB P Prep for Peak truck arrival. PJSM. 20:30 23:00 2.50 0 0 MIRU MOVE MOB P Peak trucks on location, pull subs off 1 L-04, clean&inspect wellhead/jobsite, install jeeps. 23:00 00:00 1.00 0 0 MIRU MOVE MOB P Start rig move to 1H-Pad. 12/19/2014 Complete rig move to 1H-Pad. MIRU CDR2, perform pre-rig checklist, load pits. Perform inital BOPE test, Fill reel. 00:00 01:30 1.50 0 0 MIRU MOVE MOB P Continue rig move to 1H-Pad. 01:30 06:00 4.50 0 0 MIRU MOVE MOB P Arrive on location, inspect wellhead, remove jeeps, spot modules over 1H-04, berm cellar, containment, RU Putz, steam, interconnect. 06:00 10:00 4.00 0 0 MIRU MOVE RURD P Rig move checklist, load pits. Rig Accept: 12/19/14 @ 10:00 10:00 11:00 1.00 0 0 MIRU WHDBO RURD P NU stack, change riser, install TT hardline. 11:00 13:00 2.00 0 0 MIRU WHDBO RURD P PJSM. Grease tree, stack, manifold valves. 13:00 14:30 1.50 0 0 MIRU WHDBO RURD P PJSM. Fluid pack system,shell test. 14:30 22:00 7.50 0 0 MIRU WHDBO BOPE P Perform initial BOPE test,250/4,000 psi, annular 2,500 psi.Test waived by AOGCC(Matt Herrera). 22:00 00:00 2.00 0 0 MIRU WHDBO RURD P PJSM-Lay down BOPE test equipment, RU test pump, fluid pack system for inner reel test. 12/20/2014 Complete initial testing. Pull BPV. Test Orbit valve. MU/RIH with BHA#1. Circulate hole to 9.6 ppg milling fluid, Squeezed 50 bbl 100k LSRV pill into lower formation. Start time milling window exit from 7,435.3'to 7,439.2'. Milling in progress. 00:00 01:30 1.50 0 0 MIRU WHDBO PRTS P Pressure test inner reel iron and chart. 01:30 04:00 2.50 0 0 MIRU WHDBO MPSP P PJSM. Lubricate out BPV,420 psi under BPV, R/D BPV lubricator and load out. 04:00 04:45 0.75 0 0 MIRU WHDBO PRTS P PJSM-Pressure test PDL's, TT line. 04:45 06:00 1.25 0 0 SLOT WELLPF SFTY P Pre spud, PJSM for Orbit valve, crew change. Page 1 of 13 Time Logs _ Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 06:30 0.50 0 0 SLOT WELLPF RURD P Valve checklist 06:30 07:15 0.75 0 0 SLOT WELLPF SFTY P Pre-Spub with day crew 07:15 08:30 1.25 0 0 SLOT WELLPF PRTS P PJSM. Test Baker Orbit valve, close valve, bleed off well, no flow check. 08:30 10:09 1.65 0 0 PROD1 WHPST PULD P PJSM. MU BHA#1,window milling assembly with magnets, surface test. 10:09 12:21 2.20 0 7,400 PROD1 WHPST TRIP P RIH w/milling assembly,open EDC, open orbit valve, no issues through Orbit valve, continue in hole, log GR for-2.5'correction, RIH. 12:21 14:00 1.65 7,400 7,400 PROD1 WHPST CIRC P Swap hole to 9.6 ppg mud, experiencing loses, start mixing pill, mud to surface, 1.4 bpm in and returns out.4 bpm. 14:00 15:45 1.75 7,400 7,400 PROD1 WHPST CIRC P Start pumping 20 bbl 100K LSRV pill down coil, circulate to bit,shut in well, squeeze pill into perfs. Monitor pressure bleed off 10 minutes. Open well, continue circulating 1.42 in and .85 out. 15:45 18:15 2.50 7,400 7,400 PROD1 WHPST CIRC P Circulate in additional 30 bbls of pill down coil, pill at bit, shut-in, squeeze remaining pill, let set 30 minutes. 18:15 18:45 0.50 7,400 7,400 PROD1 WHPST CIRC P Circulate in 1.40 bpm, returns 1.26 bpm, 11.6 ECD, confer with town, close EDC. 18:45 19:15 0.50 7,400 7,435 PROD1 WHPST WPST P RIH, pinch point at 7,435.3'(TOWS 7,430')PUW 27k, RBIH 1.40 bpm at 3251 psi, BHP 3870,Two stalls at 7,432', PUW 27k, RBIH and dry tag at 7,435.3', PU to 7,432.3', bring pumps on 1.40 bpm at 3271 psi, BHP 3870,WOB 0, FS 350. 19:15 00:00 4.75 7,435 7,439 PROD1 WHPST WPST P Begin time milling window exit per plan and Baker rep. 1.40 bpm at 3316 psi, BHP 3870, IA 590, OA 0, metal across shaker. Note: Lost 102 bbls 9.6 ppg of PwrPro to formation as of midnight, well is slowly healing. 12/21/2014 Mill window exit(TOW at 7,436', BOW at 7,442')Back ream window area until clean. TOOH. Un-deploy due to still experiencing 7 bph losses. LD BHA#1, MU drilling BHA#2, Deploy and TIH with BHA#2. 00:00 09:24 9.40 7,439 7,446 PROD1 WHPST WPST P Time milling window as per plan, 1.4 bpm at 3321 psi 09:24 11:33 2.15 7,446 7,455 PROD1 WHPST WPST P Drill rathole: 1.40 bpm @ 3,320 psi, BHP=3870 psi, CTW=6.5K, DHWOB=2.3K, ROP=5. PUW=30K. 11:33 14:24 2.85 7,455 7,455 PROD1 WHPST REAM P Make several back-reaming passes, stalled twice on first two down passes. Spent more time dressing top of whipstock @ 7,430'. Dry drift window,window clean. PUW=26K. 14:24 15:09 0.75 7,455 4,400 PROD1 WHPST TRIP P Trip for test just above Orbit valve. Page 2 of 13 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:09 15:27 0.30 4,400 4,400 PROD1 WHPST CIRC P Circulate at 1.45 bpm in place for 15 minutes, monitored losses, returns started at 1.3 bpm. End rates 1.45 bpm in and 1.33 bpm out. 15:27 16:24 0.95 4,400 76 PROD1 WHPST TRIP P Continue OOH for BHA#2. 16:24 18:15 1.85 76 76 PROD1 WHPST PULD P PJSM. PUD BHA#1, LD coil track tools, service injector, crew changeout. 18:15 19:45 1.50 76 0 PROD1 WHPST PULD P PJSM-LD motor and mill, 2.79" no-go on both mills. Inspect reel, service level wind, inspect and test CTC. 19:45 22:18 2.55 0 72 PROD1 DRILL PULD P PJSM-MU BHA#2,2.3-°AKO motor and HCC reconditioned Bi-center bit. Deploy BHA#2. MU to coil track, surface test,failed test sub, replace cut o-ring on test sub, MU to coil track, re-test good. 22:18 00:00 1.70 72 7,040 PROD1 DRILL TRIP P TIH with BHA#2 12/22/2014 Drill build section from 7,455'to 7,550', Opened Baker CMU at 7,257'picking up hole for tie-in at K1, lost returns, pump 100k LSRV pill to control losses.TOOH. RIH with"B"shifting tool BHA#3 and closed CMU. TOOH. RIH with drilling BHA#4. 00:00 00:09 0.15 7,040 7,065 PROD1 DRILL DLOG P Log K1 marker,-2.5'correction. 00:09 00:30 0.35 7,065 7,455 PROD1 DRILL TRIP P Continue in hole to 7,415', close EDC, PUW 27k, RBIH, clean thru window. 00:30 06:54 6.40 7,455 7,550 PROD1 DRILL DRLG P 7,455', OBD 1.42 bpm at 3,367 psi, BHP 3915 psi, ECD 11.65, CTW 13.5k,WOB 1.0k, ROP 15. 06:54 07:42 0.80 7,550 7,257 PROD1 DRILL WPRT P Wiper for K1 tie-in, overpulll Baker CMU @ 7,257', lost returns, opened CMU. 07:42 08:57 1.25 7,257 7,237 PROD1 DRILL OTHR T Made several attempts to re-close CMU was unsuccessful. PUH. 08:57 10:27 1.50 7,237 7,237 PROD1 DRILL CIRC T Mix 100K LSRV pill, pump 20 bbls down coil, pill at bit, close choke and squueeze to formation @ .5 bpm, annular dropping. Circulate 1.42 bpm in&.9 bpm out. 10:27 12:27 2.00 7,237 68 PROD1 DRILL TRIP T POOH laying in remaining 100K LSRV 12:27 14:24 1.95 68 0 PROD1 DRILL PULD T PJSM. PUD BHA#2 while monitoring MP, LD BHA, Bit condition 1-2-BT-A-X-I-PN-HP 14:24 16:00 1.60 0 49 PROD1 DRILL PULD T PJSM. PD BHA#3, surface test tool. 16:00 17:39 1.65 49 7,265 PROD1 DRILL TRIP T RIH w/B-shifting tool assembly, +.5' correction at K1, PUW 25k, RBIH, 17:39 18:00 0.35 7,265 7,281 PROD1 DRILL TRIP T 7,265',-1k CTW seen at Baker CMU SSD, PU and run thru SSD couple of times, CMU closed, circulate, return rate improving to 1.41 bpm in, 1.25 bpm out. 18:00 19:30 1.50 7,281 49 PROD1 DRILL TRIP T TOOH with BHA#3 Page 3 of 13 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 21:27 1.95 49 0 PROD1 DRILL PULD T PJSM. Un-deploy BHA#3 while monitoring MP, LD BHA#3, B shifting tool indicates SSD closed. 21:27 23:06 1.65 0 72 PROD1 DRILL PULD T PJSM-MU BHA#4,2.2°AKO motor and HYC reconditioned Bi-center bit. Deploy BHA#4. MU to coil track, surface test. 23:06 00:00 0.90 72 3,556 PROD1 DRILL TRIP T TIH with BHA#4. Note: Lost 181 bbl of 9.6 PwrPro SF in last 24 hours. 12/23/2014 Drill build section from 7,550 ft to 7,800 ft.TOOH. Drilled L1 Lateral from 7,800 ft to 7,966 ft. Drilling in progress. 00:00 00:48 0.80 3,556 7,040 PROD1 DRILL TRIP T Continue TIH with BHA#4 00:48 01:00 0.20 7,040 7,065 PROD1 DRILL DLOG T Log K1 marker, -4.5 ft correction, PUW 26k. 01:00 01:42 0.70 7,065 7,550 PROD1 DRILL TRIP P Continue in hole, Log RA markers at 7,437.5 ft, clean through window. 01:42 09:42 8.00 7,550 7,740 PROD1 DRILL DRLG P 7,550 ft, OBD 1.44 bpm at 3403 psi, BHP 3927 psi, ECD 11.6, CTW 12.5k,WOB 1.0k,WHP 106, ROP 20. 09:42 10:12 0.50 7,740 7,480 PROD1 DRILL WPRT P 7740 ft,Wiper up hole to 7480 ft, PUW 28k 10:12 10:27 0.25 7,480 7,740 PROD1 DRILL WPRT P 7480 ft,Wiper back in hole. RIW 13k 10:27 11:51 1.40 7,740 7,800 PROD1 DRILL DRLG P 7740 ft, BOBD 1.4 bpm at 3200 psi, WOB 1.5k, ROP 33 fph, BHP 3972, WHP 122, IA 370, OA 123 11:51 12:36 0.75 7,800 7,400 PROD1 DRILL WPRT P 7800 ft, landed the build section, Wiper up hole to the window. 12:36 14:06 1.50 7,400 72 PROD1 DRILL TRIP P 7400 ft, Tripped past CMU clean, Open EDC, POOH 14:06 15:36 1.50 72 0 PROD1 DRILL PULD P At surface, PJSM, Undeploy Build BHA 15:36 16:30 0.90 0 0 PROD1 DRILL SVRG P Inspect top drive, adjuist hose fittings from contacting bails 16:30 18:00 1.50 0 72 PROD1 DRILL PULD P PJSM,deploy lateral BHA 18:00 18:30 0.50 72 72 PROD1 DRILL SFTY P Crew change out,valve check list, PJSM. 18:30 20:03 1.55 72 7,040 PROD1 DRILL TRIP P TIH with BHA#5 20:03 20:15 0.20 7,040 7,075 PROD1 DRILL DLOG P Log K1,-4'correction 20:15 21:00 0.75 7,075 7,800 PROD1 DRILL TRIP P Continue in hole, close EDC at 7,400 ft, PUW 28.5k,clean thru window and build section. 21:00 00:00 3.00 7,800 7,966 PROD1 DRILL DRLG P 7,800 ft, OBD 1.4 bpm at 3473 psi, BHP 3967,WHP 120, ROP 55, WOB 2.0k, IA 0, OA 8. Note: Lost 89 bbl of 9.6 ppg PwrPro in last 24 hours 12/24/2014 Drill L1 lateral from 7,966 ft to 8,859 ft, differentially stuck at 8,859 ft, pump LVT to free up, begin mud swap to 9.6 ppg FloPro. Page 4 of 13 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:21 0.35 7,966 7,990 PROD1 DRILL DRLG P 7,966 ft, OBD 1.4 bpm at 3473 psi, BHP 3967,WHP 120, ROP 70, WOB 2.0k, IA 360, OA 83. 00:21 01:06 0.75 7,990 7,990 PROD1 DRILL WPRT P 7,990 ft,Wiper trip up to 7,480 ft, PUW 27k, RBIH, RIW 13.2k 01:06 .03:21 2.25 7,990 8,190 PROD1 DRILL DRLG P 7,990 ft, OBD 1.41 bpm at 3455 psi, BHP 3996,WHP 127, ROP 90, • WOB 1.3k, IA 365, OA 94. 03:21 04:15 0.90 8,190 8,190 PROD1 DRILL WPRT P 8,190 ft,Wiper trip up to 7,480 ft, PUW 29k, RBIH, RIW 13.3k 04:15 07:30 3.25 8,190 8,390 PROD1 DRILL DRLG P 8,190 ft, OBD 1.42 bpm at 3455 psi, BHP 4001,WHP 126, ROP 90, WOB 1.6k, IA 466, OA 147. • • "*'Note: Magnetic interference, last • 3 survey's are out of parameters, send information to Halliburton for Interpolated Infield Referance(IIFR) 07:30 07:54 0.40 8,390 7,435 PROD1 DRILL WPRT P 8390 ft,Wiper up hole to the window, PUW 27k 07:54 08:39 0.75 7,435 7,300 PROD1 DRILL WPRT P 7435 ft, PUH to 7380 ft, RBIH to above window, open EDC, PUH above tubing tail to 7300 ft, pumping 1.6 bpm cleaning 5 1/2 inch liner. RIH to logging depth 7456 ft. 7,300 7,456 PROD1 DRILL WPRT P RBIH to logging depth 7456 ft. 08:39 08:54 0.25 7,456 7,468 PROD1 DRILL DLOG P 7456 ft, Tie into the RA marker correction of plus 1.5 ft. 08:54 09:24 0.50 7,468 8,390 PROD1 DRILL WPRT P 7468 ft, Continue wiper in hole RIW 14k 09:24 13:00 3.60 8,390 8,590 PROD1 DRILL DRLG P 8390 ft, BOBD 1.5 bpm at 3500 psi, BHP 4050,WHP 120, IA 543, OA 202 13:00 13:45 0.75 8,590 7,409 PROD1 DRILL WPRT P 8590 ft,Wiper up hole to 7460 ft looks like the choke is plugging off, pull up into the liner to clear choke, RBIH through window to bottom. PUW 28k 13:45 14:30 0.75 7,409 8,590 PROD1 DRILL WPRT P 7409 ft,wiper back in hole. RIW 9k 14:30 17:21 2.85 8,590 8,790 PROD1 DRILL DRLG P 8590 ft, BOBD 1.5 bpm at 3500 psi, BHP 4058,WHP 112,WOB 1.4k, ROP 75 fph, IA 214, OA 230 17:21 18:09 0.80 8,790 7,480 PROD1 DRILL WPRT P 8,790 ft,Wiper up hole to 7,480 ft, PUW 29k 18:09 18:57 0.80 7,480 8,790 PROD1 DRILL WPRT P 7,480 ft,Wiper back in hole. RIW 9.2k 18:57 20:15 1.30 8,790 8,859 PROD1 DRILL DRLG P 8,790 ft, OBD 1.5 bpm at 3630 psi, BHP 4093,WHP 108,WOB 1.4k, ROP 75, IA 328, OA 290 20:15 22:51 2.60 8,859 8,859 PROD1 DRILL CIRC T 8,859 ft, Pipe slack, lost diff, no WOB, PU 17k over,work pipe to 29k over,differentially stuck, circulate bottoms up, SD pumps for 15 min, work pipe to 35k over(65k)hold in tension, pump 5x10 Io/hi sweep, clean returns, pump 12 bbl's LVT, 7 bbl's out bit BHA came free. Page 5 of 13 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:51 00:00 1.15 8,859 8,388 PROD1 DRILL CIRC P PUH and begin mud swap to 9.6 ppg FloPro drilling system#1, at 8,550 ft pulled thru heavy,-1.7 WOB, returns to .3 bpm pumping 1.5 bpm in. Note 1,425 ft drilled, .6%solids on milling 9.6 ppg PwrPro system. 12/25/2014 Complete mud swap to 9.6 ppg FloPro, Drill ahead L1 lateral 8,859 ft to 9,660 ft. Drilling in progress. 00:00 02:21 2.35 8,388 7,450 PROD1 DRILL CIRC P Continue PUH and mud swap to 9.6 ppg drilling system#1, returns improving after 8,250 ft, RBIH at 8,050ft, returns diminishing from 8,300 ft to 8,535 ft, 5x5 sweep out, new mud at bit, 1.5 bpm in, .3 bpm out, chase sweep to window, PU into TT, perform jog in BTP, RBIH. 02:21 02:33 0.20 7,450 7,480 PROD1 DRILL DLOG P Log RA marker, +9.5 ft correction 02:33 03:24 0.85 7,480 8,861 PROD1 DRILL WPRT P Wiper back in hole, RIW 13.8k 03:24 04:30 1.10 8,861 8,906 PROD1 DRILL DRLG P 8,861 ft, BOBD 1.4 bpm at 3878 psi, BHP 4118,WHP 149,WOB 1.6k, ROP 50, IA 0, OA 130, losses at -24 bph, confer with town, hold 11.4 ppg at window. 04:30 06:30 2.00 8,906 9,060 PROD1 DRILL DRLG P 8,906 ft, OBD 1.42 bpm at 4033 psi, BHP 4075,WHP 65,WOB 1.6k, ROP 50, IA 0, OA 150, 06:30 07:45 1.25 9,060 9,060 PROD1 DRILL WPRT P 9060 ft wiper up hole to 8060'PUW 32k, RIW 10k 07:45 10:45 3.00 9,060 9,260 PROD1 DRILL DRLG P 9060 ft, BOBD 1.5 bpm at 3800 psi, BHP 4050,WHP 50,WOB 2k, ROP 60 fph 10:45 11:15 0.50 9,260 8,260 PROD1 DRILL WPRT P 9260 ft,Wiper up hole to 8260' chasing 5x5 sweep, PUW 27k, 11:15 11:30 0.25 8,260 8,760 PROD1 DRILL WPRT P 8260 ft,Wiper back in hole. RIW 10k 11:30 12:30 1.00 8,760 7,300 PROD1 DRILL WPRT P 8760 ft, looks like the annular is loaded up with cuttings,decide to pull to the window to clean the hole and 5 1/2 inch. PUW 30k,open EDC to jet 5 1/2. """'Note: Increased cuttings with bottoms up. 12:30 12:45 0.25 7,300 7,456 PROD1 DRILL WPRT P 7300 ft, RIH to tie in depth. 12:45 13:00 0.25 7,456 7,476 PROD1 DRILL DLOG P 7456 ft,tie into the RA marker correction of plus 3.5 ft. 13:00 14:00 1.00 7,476 9,260 PROD1 DRILL WPRT P 7476 ft,Wiper back in hole. RIW 10 14:00 17:00 3.00 9,260 9,460 PROD1 DRILL DRLG P 9260 ft, BOBD 1.5 bpm at 3700 psi, BHP 4073,WHP 20,WOB 1.5k, ROP 72 fph, IA 248, OA 276 17:00 18:00 1.00 9,460 7,800 PROD1 DRILL WPRT P 9460 ft,Wiper up hole. PUW 30k 18:00 18:54 0.90 7,800 9,460 PROD1 DRILL WPRT P 7,800 ft,Wiper back in hole, RIW 10.7k Page 6 of 13 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:54 22:36 3.70 9,460 9,660 PROD1 DRILL DRLG P 9,460 ft, OBD 1.5 bpm at 4058 psi, BHP 4083,WHP 22,WOB 1.5k, ROP 55, IA 420, OA 365 22:36 23:27 0.85 9,660 7,800 PROD1 DRILL WPRT P 9,660 ft,Wiper up hole. PUW 29k 23:27 00:00 0.55 7,800 8,650 PROD1 DRILL WPRT P 7,800 ft,Wiper back in hole, RIW 10.7k Note: Lost 182 bbls of 9.6 ppg FloPro in last 24 hours. 12/26/2014 Drill ahead L1 Lateral 9,660 ft to called TD at 10,264 ft.. Pump sweep. Begin swab wiper. 00:00 00:33 0.55 8,650 9,660 PROD1 DRILL WPRT P 8,650 ft, Continue wiper in hole, RIW 11k 00:33 04:09 3.60 9,660 9,860 PROD1 DRILL DRLG P 9,660 ft, OBD 1.5 bpm at 4090 psi, BHP 4120,WHP 22,WOB 1.5k, ROP 55, IA 484, OA 413 04:09 05:24 1.25 9,860 7,300 PROD1 DRILL WPRT P 9,860 ft,Wiper up hole for tie-in. PUW 30k, PU thru window to clean 5-1/2" BTP. __ 05:24 05:39 0.25 7,300 7,456 PROD1 DRILL WPRT P RBIH to tie in depth 05:39 05:54 0.25 7,456 7,478 PROD1 DRILL DLOG P 7456 ft,Tie into the RA marker correction of plus 4.5 ft. 05:54 06:54 1.00 7,478 9,860 PROD1 DRILL WPRT P 7478 ft,Wiper back in hole. RIW 9k 06:54 10:24 3.50 9,860 10,060 PROD1 DRILL DRLG P 9860 ft, BOBD 1.5 bpm at 3800 psi, BHP 4118,WHP 20,WOB 1.6k, ROP 72 bph, IA 563, OA 440 10:24 11:24 1.00 10,060 10,060 PROD1 DRILL WPRT P 10060 ft,Wiper up hole to 9060 ft, PUW 26k, RIW 11:24 12:54 1.50 10,060 10,076 PROD1 DRILL DRLG P 10060 ft, BOBD 1.5 bpm at 3800 psi, BHP 4119,WHP 0,WOB 1.5k, ROP 80 fph, IA 562, OA 444 12:54 14:54 2.00 10,076 10,076 PROD1 DRILL DRLG P 10076 ft, Stall motor, PUH,work to get drilling, pump 20 bbls of new mud, 14:54 15:24 0.50 10,076 10,163 PROD1 DRILL DRLG P 10076 ft, BOBD 1.5 bpm at 3800 psi, BHP 4119,WHP 0, IA 459, OA 441 15:24 15:39 0.25 10,163 10,163 PROD1 DRILL DRLG P 10163 ft, started losing 42 bph, PUH PUW 32k, RBIH to drill ahead 15:39 17:09 1.50 10,163 10,260 PROD1 DRILL DRLG P 10163 ft, BOBD 1.5 bpm at 3850 psi, BHP 3900,WHP 0,WOB 2k, ROP 75 fph, IA 455, OA 440 17:09 18:09 1.00 10,260 10,105 PROD1 DRILL WPRT P 10260 ft,wiper up hole to 9,200 ft, PUW 28k, RBIH, RIW 4.5k, SO CTW-3k, .03k WOB at 10,078 ft,work down to 10,105 ft, DHWOB .5k, CTW-3.5k, PUW 29k, attempt to RBIH and SO at 10,048 ft, .03k WOB, 30 bph losses pumping 1.5 bpm. 18:09 20:09 2.00 10,105 7,350 PROD1 DRILL WPRT P 10,105 ft,wiper to TT, pull up into BTP, perform jog,open EDC,jet 5-1/2"x 3-1/2"to 7,350 ft,Jet back down to 7,415 ft, Close EDC. Page 7 of 13 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:09 22:15 2.10 7,350 10,264 PROD1 DRILL WPRT P Wiper back in hole, log RA+4.5 ft correction, RIW 11 k at 8,200 ft, RIW -4k CWT bobble at 8,528 ft, RIW 0 to -2k at 9,270 ft, RIH 20 fpm, pump 20 bbl new mud, SO-10k at 9,800 ft PUW 29k, RBIH, RIW+4k after stripper lube applied, SO-10k at 10,080 ft, no WOB change, PUW 30k,pumps down to minimum, SO at 10,068 ft, 10,080 ft, 10,098 ft and 10,109 ft, PUW each time 30k, continue in hole. 22:15 23:15 1.00 10,264 10,264 PROD1 DRILL DRLG P 10,260 ft, BOBD, 1.36 bpm at 3580 psi,several attempts to get started drilling, new mud at bit at 19:30,-14k CWT, no WOB change, no motor work seen, confer with town,TD • called, pump 10x10 to/hi sweep. 23:15 00:00 0.75 10,264 9,980 PROD1 DRILL WPRT P TOOH chasing sweeps to swab 12/27/2014 Wiper to swab. RBIH,tie-in for corrected TD at 10,264 ft. Lay in 11.4 ppg beaded liner pill to surface.Well dead. LD BHA#5, Function test BOPE. MU BHA#6 on L1 lower liner assembly. RIH and release off liner. TOOH. 00:00 03:00 3.00 9,980 72 PROD1 DRILL WPRT P Continue wiper up hole to swab.tag up, reset counters. 03:00 04:27 1.45 72 7,040 PROD1 DRILL WPRT P RBIH with BHA#5 for tie-in and corrected TD. 04:27 04:42 0.25 7,040 7,075 PROD1 DRILL DLOG P Log K1, -4.5 ft correction, close EDC. 04:42 06:27 1.75 7,075 10,082 PROD1 DRILL WPRT P Continue RIH, PUW 27k in 5-1/2" BTP, clean thru window. 06:27 07:57 1.50 10,082 10,264 PROD1 DRILL WPRT P 10082', Trouble getting to bottom, work pipe,TF, pump with no success, PUH, pump 20 bbls of new mud, attemp to run through trouble spot. 07:57 08:57 1.00 10,264 10,264 PROD1 DRILL DISP P 10264', Made it to bottom, line up to pump beads down hole. 08:57 10:12 1.25 10,264 7,420 PROD1 DRILL DISP P POOH laying in 11.4 ppg completion fluid with beads *"" Paint EOP flag at 8600 ft(Yellow) 10:12 11:42 1.50 7,420 72 PROD1 DRILL DISP P 7420', Continue POOH ****Paint EOP flag at 5800 ft 11:42 12:12 0.50 72 72 PROD1 DRILL OWFF P Check well for flow, PJSM,for laying down drilling BHA ****Note: Losing 3 bph 12:12 13:27 1.25 72 0 PROD1 DRILL PULD P L/D drilling BHA#5 13:27 13:57 0.50 0 0 PROD1 WHDBO BOPE P Function test BOPE. 13:57 14:27 0.50 0 0 COMPZ CASING PUTB P PJSM, Prep rig floor for M/U lower AL liner assembly. Page 8 of 13 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:27 18:00 3.55 0 1,529 COMPZ CASING PUTB P M/U AL lateral assembly with 48 joints of slotted liner *"*"Note: Current losses 3 bph 18:00 19:09 1.15 1,529 1,573 COMPZ CASING PULD P PJSM-MU BHA#6, MU to coil track,surface test. 19:09 23:21 4.20 1,573 10,270 COMPZ CASING RUNL P RIH with BHA#6 on L1 lower liner assembly,tie-in to flag, +1.86 ft correction, PUW 29k, continue in hole, 23:21 23:30 0.15 10,270 8,741 COMPZ CASING RUNL P 10,270 ft, Slack off-5k, PUW 30k, SO-5k, pump off liner, PUW 27k, re-set depth to BHA. Note: lost 20 bbl 11.4 ppg during trip in hole. 23:30 00:00 0.50 8,741 7,550 COMPZ CASING TRIP P 8,741 ft,TOOH pumping over the top. Note: Lost 82 bbl 9.6 ppg FloPro and 77 bbls of 11.4 ppg completion fluid in last 24 hrs 12/28/2014 TOOH. MU BHA#7 on L1 upper liner assembly. RIH and release off liner at 8,741 ft.TOOH. LD BHA#7. MU BHA#8 and RIH. Displace well to drilling fluid. Kick off billet at 7,555 ft. Drill build to 7,595 ft. Dry drift billet clean. Drilling in progress. 00:00 00:15 0.25 7,550 7,010 COMPZ CASING TRIP P TOOH pumping over the top. 00:15 00:30 0.25 7,010 7,040 COMPZ CASING DLOG P Tie-in at K1, +2.5 ft correction. 00:30 02:00 1.50 7,040 44 COMPZ CASING TRIP P TOOH with BHA#6, paint EOP flag at 6,100 ft. 02:00 02:30 0.50 44 44 COMPZ CASING OWFF P Monitor well for flow, PJSM-laying down BHA. Note: lost 3 bbl triping out of hole. 02:30 03:00 0.50 44 0 COMPZ CASING PULD P LD BHA#6 03:00 03:42 0.70 0 0 COMPZ CASING PUTB P PJSM, Prep rig floor for M/U of upper L1 liner assembly. 03:42 07:21 3.65 0 1,184 COMPZ CASING PUTB P M/U L1 upper lateral assembly with bullnaos, 5 jts slotted, pup,XO, 8 jts solids,XO,24 jts slotted, liner top billet. Note: Current losses 3 bph 07:21 09:51 2.50 1,184 7,338 COMPZ CASING RUNL P RIH,with AL lateral upper liner assembly with liner top billet. 09:51 10:06 0.25 7,338 7,338 COMPZ CASING RUNL P Correct to the EOP flag 5800', minus 7.6 ft, PUW 33k 10:06 11:06 1.00 7,338 8,741 COMPZ CASING RUNL P 7338 ft, Continue RIH with liner, 11:06 11:21 0.25 8,741 8,741 COMPZ CASING RUNL P 8741 ft,Work pipe down to bottom, RIW 10k to-12k. Picking up to 30k, RIH 45 fpm making hole every cycle. 11:21 12:51 1.50 8,741 45 COMPZ CASING TRIP P Remove liner length from CT counters, POOH ****Note: Lost 4 bbls on trip out of hole. Page 9 of 13 Time Logs _ Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:51 13:21 0.50 45 45 COMPZ CASING OWFF P At surface, no flow, PJSM for L/D setting tools 13:21 13:51 0.50 45 0 COMPZ CASING PULD P L/D liner setting tools BHA#7 13:51 15:21 1.50 0 72 PROD2 STK PULD P PJSM, M/U kickoff/drilling BHA#8 15:21 17:51 2.50 72 7,040 PROD2 STK TRIP P RIH,with kickoff/drilling BHA#8 with 1.7 AKO motor and RR Hycalog bit (A178854) 17:51 18:06 0.25 7,040 7,065 PROD2 STK DLOG P Log K1,-6 ft. correction. 18:06 18:24 0.30 7,065 7,420 PROD2 STK TRIP P Continue in hole to BTP. 18:24 19:57 1.55 7,420 7,555 PROD2 STK DISP P Displace out 11.4 ppg completion fluid to 9.6 ppg drilling fluid, close EDC, PUW 28k, RBIH, clean thru window,dry tag top of biilet at 7,555.89 ft, PUW 27k. 19:57 23:09 3.20 7,555 7,565 PROD2 STK KOST P 7,554.63 ft. begin time milling off billet per plan 1.43 bpm at 3970 psi, BHP 3953, IA 0, OA 0. 23:09 23:45 0.60 7,565 7,595 PROD2 DRILL DRLG P 7,565 ft. begin drilling L1-01 build section 1.45 bpm at 3978 psi,WOB 1.5k, ROP 50 fph, BHP 3970,WHP 0, IA 0, OA 35 Note: loses at—7 bph. 23:45 00:00 0.25 7,595 7,595 PROD2 DRILL WPRT P 7,595 ft, Pull up hole for drift, PUW 26k, clean thru billet out and in. Note: Lost 68 bbl of 11.4 NaBr and 46 bbl of 9.6 ppg FloPro in last 24 hrs. 12/29/2014 Drill L1-01 build section from 7,595 ft to TD at 7,796 ft.TOOH. LD BHA#8. MU BHA drilling#9. RIH and drill L1-01 lateral to 8,295 ft. Drilling in progress 00:00 05:00 5.00 7,595 7,795 PROD2 DRILL DRLG P 7,595 ft, OBD 1.45 bpm at 3989 psi, BHP 3977,WHP 0,WOB 1.6k, ROP 40, IA 0, OA 40, pump 5x5 sweep. 05:00 07:00 2.00 7,795 72 PROD2 DRILL TRIP P 7,795 ft, Build section TD, PU to TT, PUW 26k,Jet 5 1/2"BTP, POOH for lateral drilling BHA 07:00 07:30 0.50 72 72 PROD2 DRILL SFTY P At surface, PJSM for undeploying Build BHA 07:30 09:15 1.75 72 0 PROD2 DRILL PULD P Undeploy build BHA#8, BHI checks are not holding, notice scope change, call for PJSM for undeploying with out using checks in the upper quick 09:15 10:45 1.50 0 72 PROD2 DRILL PULD P M/U AL1-01 lateral BHA 10:45 11:15 0.50 72 72 PROD2 DRILL SVRG P Replace checks in UQ,tighten saddle bolts and injector pac-off 11:15 13:15 2.00 72 7,040 PROD2 DRILL TRIP P RIH,with lateral BHA#9 13:15 13:30 0.25 7,040 7,069 PROD2 DRILL DLOG P 7040',Tie into the K1 marker correction of minus 8.5 ft. 13:30 14:00 0.50 7,069 7,796 PROD2 DRILL TRIP P 7069 ft, continue RIHTB Page 10 of 13 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 17:15 3.25 7,796 7,990 PROD2 DRILL DRLG P 7796 ft, OBD 1.42 bpm at 3650 psi, BHP 3996,WHP 8,WOB 1.4k, ROP 55 fph, IA 0,OA 0 ""Note:7816 ft new mud at the bit 17:15 17:33 0.30 7,990 7,590 PROD2 DRILL WPRT P Wiper up hole, PUW 26k 17:33 17:48 0.25 7,590 7,990 PROD2 DRILL WPRT P Wiper back in hole, RIW 13k. 17:48 20:36 2.80 7,990 8,190 PROD2 DRILL DRLG P 7,990 ft, OBD 1.50 bpm at 3910 psi, BHP 3913,WHP 9,WOB 1.4k, ROP 70, IA 82, OA 136 20:36 21:00 0.40 8,190 7,580 PROD2 DRILL WPRT P Wiper up hole, PUW 26k 21:00 21:24 0.40 7,580 8,190 PROD2 DRILL WPRT P Wiper back in hole, RIW 12.5k. 21:24 00:00 2.60 8,190 8,295 PROD2 DRILL DRLG P 8,190 ft, OBD 1.50 bpm at 3910 psi, BHP 3940,WHP 9,WOB 1.5k, ROP 40, IA 245, OA 242 Note: Lost 12 bbls 9.6 ppg mud since mud swap. 12/30/2014 Drill L1-01 lateral 8,295 ft to 9272 00:00 01:42 1.70 8,295 8,390 PROD2 DRILL DRLG P 8,295 ft, OBD 1.50 bpm at 3900 psi, BHP 3967,WHP 9,WOB 1.5k, ROP 55, IA 333, OA 300 01:42 02:42 1.00 8,390 7,385 PROD2 DRILL WPRT P Wiper up hole for tie-in, PUW 28k, PU into TT,jog in 5-1/2"BTP to clean up. RBIH. 02:42 02:54 0.20 7,385 7,485 PROD2 DRILL DLOG P Log RA marker, +1 ft correction. 02:54 03:24 0.50 7,485 8,390 PROD2 DRILL WPRT P Wiper back in hole, RIW 14k 03:24 06:24 3.00 8,390 8,590 PROD2 DRILL DRLG P 8,390 ft, OBD 1.48 bpm at 3952 psi, BHP 3985,WHP 17,WOB 1.5k, ROP 70, IA 291, OA 307 Note: Losses at-4.5 bph. 06:24 07:24 1.00 8,590 8,590 PROD2 DRILL WPRT P 8590 ft,Wiper up hole to 7583 ft, PUW 28k 07:24 10:54 3.50 8,590 8,790 PROD2 DRILL DRLG P 8590 ft, BOBD 1.5 bpm at 3750 psi, BHP 4029,WHP 14,WOB 1.8k, ROP 50 fph, IA 466, OA 400 10:54 11:54 1.00 8,790 8,790 PROD2 DRILL WPRT P 8790 ft,Wiper up hole up to 7593 ft, PUW 28k 11:54 15:24 3.50 8,790 8,990 PROD2 DRILL DRLG P 8790 ft, BOBD 1.5 bpm at 3750 psi, BHP 4067,WHP 14,WOB 2.5k, ROP 53, IA 515, OA 439 15:24 16:24 1.00 8,990 7,420 PROD2 DRILL WPRT P 8990 ft,wiper to the window. PUW 27k 16:24 16:39 0.25 7,420 7,380 PROD2 DRILL WPRT P Open EDC and jet 5-1/2'from 7420 ft to 7380 ft, 16:39 16:51 0.20 7,380 7,456 PROD2 DRILL WPRT P RBIH to tie in depth 7456 ft. 16:51 16:57 0.10 7,456 7,475 PROD2 DRILL DLOG P 7456 ft,tie into the RA marker correction of+1' 16:57 17:45 0.80 7,475 8,990 PROD2 DRILL WPRT P 7475 continue wiper trip in hole to drill 17:45 21:15 3.50 8,990 9,190 PROD2 DRILL DRLG P 8990', Drill ahead 1.47 BPM @ 3920PS1 FS, BHP=4085 Page 11 of 13 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/30/2014 24 hr Summary Drill L1-01 lateral 8,295 ft to 9272 21:15 22:15 1.00 9,190 9,190 PROD2 DRILL WPRT P 9190',Wiperto8400', PUW=31K Clean trip up and down 22:15 00:00 1.75 9,190 9,272 PROD2 DRILL DRLG P 9190', Drill 1.47 BPM @ 3920 PSI FS, BHP=4133, 12/31/2014 Drill ahead to 9390, PUH to casing @ 7420 stand by for Phase 3 weather 00:00 02:00 2.00 9,272 9,390 PROD2 DRILL DRLG P Continue drill ahead, 1.47 BPM @ 3920 PSI FS, BHP=4152 02:00 03:42 1.70 9,390 7,420 PROD2 DRILL WPRT P Wiper trip to 8300, PUW=29K, RBIH Field went to Phase 3 @ 3:00 Pull up to cased hole from 8800' 03:42 00:00 20.30 7,420 7,420 PROD2 DRILL WPRT T PHASE 3, Pull into cased hole, Open EDC circ at min rate 01/01/2015 TD L1-01 lateral @ 9600',Wiper trip to swab,Trip to bottom and lay in liner running pill and completion fluid. M/U completion and start in well. 00:00 00:45 0.75 7,420 7,420 PROD2 DRILL WPRT T Stand by for Phase 3 00:45 01:00 0.25 7,420 7,460 PROD2 DRILL SFTY P Received verbal from Tim, Roads and pads forman road to 1H now Phase two, PJSM to resume operations 01:00 01:06 0.10 7,460 7,477 PROD2 DRILL DLOG P Shut EDC,trip into 7460 and log K1 for+1'correction 01:06 02:06 1.00 7,477 9,390 PROD2 DRILL WPRT P Continue wiper trip to bottom to drill. Observed surface weight loss 8400'. Reduce pump rate to 3/4BPM and slow RIS 35 FPM to 25FPM. Did not set down. Got surface weight back @-8640' 02:06 07:06 5.00 9,390 9,600 PROD2 DRILL DRLG P 9390', Drill, 1.4 BPM @ 3990 PSI FS, BHP=4190,WHP=0, RIW=12.9, DP=445 07:06 09:48 2.70 9,600 72 PROD2 DRILL WPRT P 9600ft TD AL-01 lateral, PUH chasing 10x10 sweep up to the suface. PUW 27k 09:48 11:33 1.75 72 7,040 PROD2 DRILL WPRT P At surface, reset counters, RBIH 11:33 11:48 0.25 7,040 7,068 PROD2 DRILL DLOG P 7040ft,tie into the K1 marker correction of minus 7.5ft. 11:48 13:03 1.25 7,068 9,600 PROD2 DRILL WPRT P Continue RIHTB 13:03 14:03 1.00 9,600 7,420 PROD2 DRILL DISP P 9600ft confirmed TD, PUH, line up 11.4ppg completion beaded liner pill. 14:03 16:03 2.00 7,420 72 PROD2 DRILL DISP P 7420 ft, countinue POOH,displacing well to 11.4ppg completion fluid with beads to surface 16:03 16:33 0.50 72 72 PROD2 DRILL OWFF P At surface,check well for flow, PJSM -for L/D drilling tools. 16:33 18:03 1.50 72 0 PROD2 DRILL PULD P Lay down drilling BHA#9/Prep floor to run liner 18:03 23:27 5.40 0 2,275 COMPZ CASING PUTB P PJSM, M/U BHA#10, Non ported bullnose, 10'pup,70 jts slotted liner shorty deployment sleeve, Perform safety joint drill, M/U to coiltrack and coil. Surface test tool 23:27 00:00 0.55 2,275 4,150 COMPZ CASING RUNL P Trip in hole with completion, EDC shut Page 12 of 13 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 31/02/2015 24 hr Summary Run completion to bottom, Swap well to seawater. F/P to 2500', RDMO 00:00 01:00 1.00 4,150 7,374 COMPZ CASING RUNL P Continue in well with liner 01:00 01:06 0.10 7,374 7,374 COMPZ CASING DLOG P Tie into 5100' EOP flag for-10.66', PUW=28K 01:06 02:18 1.20 7,374 9,602 COMPZ CASING RUNL P Continue in hole 02:18 02:24 0.10 9,602 9,585 COMPZ CASING RUNL P Tag TD, PUW=34K, DHWOB=-9K, Set back down, Pumps on @ 1.47 BPM, PUW=24K, DHWOB=1.54K 02:24 04:00 1.60 9,585 7,350 COMPZ CASING CIRC P Pump viscisified space followed by seawater Subtract liner length from counters 04:00 07:00 3.00 7,350 45 COMPZ CASING TRIP P Trip out of well, freeze protecting well from 2500ft. 07:00 07:15 0.25 45 45 COMPZ CASING SFTY P At surface, PJSM for undeploying without MP. 07:15 09:00 1.75 45 0 COMPZ CASING PULD P Undeploy BHA#10 09:00 12:00 3.00 0 0 DEMOB WHDBO RURD P Pick up nozzle,jet stack and pump corrosion inhibitor through surface lines. 12:00 14:00 2.00 0 0 DEMOB WHDBO RURD P PJSM, R/U and set BPV, R/D and load out equipment 14:00 16:00 2.00 0 0 DEMOB WHDBO RURD P Stab on tree and blow down coil 16:00 18:00 2.00 0 0 DEMOB WHDBO NUND P Nipple down stack. 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C '"(a e O O N V O O O O (/J J O Cn N r (O O 0 o Z o 0 0 0 N o . @ © E m — o o E 2 rn m (v rn m x x 2 c a' ccoo N ro O 0m ll) a Y CD co (0 co CO a: V(O N f0 co- CO I W t 0 0 3 d N i C Q 0 0 0 0 00) 4L .L co '- CO(0 C') 00)) w d C .- 0 0 O 0 IX c gg 2 C 0 l 0 Ori 0 �_ Z cn ai ui vi vi co c uco > i'' a c :c2i : c6i o) Q .°1. 2 ` w m @' p 4 Li=C O •~ � d 7. R 8 O m v2i 0 = N 9Q W > - A ' W 2 W w2 p gZ 7 O ' W N (V (V (V NV v) (0 (0 N- 0 to CV Y) 0) Cu ri r V 9 E ,T 0 N N- n ":4 ` N N (V (i. N { CV 0 coCV N O0)CVCVco 'd1 (O cc cc o 0 OW CV(dei N CV 06 CV LO 7 (O (O m (O (O p_ C CO N CV CVO CV = o r ro ui ui Y pe0 coo coo coo 1 ti =. (o m m m (o c Y 0 r C cn M )0O N N a of 0 o a a, a Q " m m r IA /� a Y U a C d O. O O O V .-. V co ON 0) rn.- _ c rnmm ,C UYY cn Po OV V (rO CO O C C i 0 co - - N N CV LOiCi 0 /0 U O Lcr, T 2 c O O o 0 0 V G O N W y a c) a. in 3 3 o Co e 214186 25301 Letter of Transmittal BAKER Date: DATA LOGGED t Bra January 22, 2015 K BENDER HUGHES To: From: State of Alaska, AOGCC Jesse Salyer 333 West 7th Ave, Suite 100 Baker Hughes INTEQ Anchorage, Alaska 99501 795 East 94th Avenue Anchorage, Alaska 99515 Please find enclosed the final well data for the following well(s): RECEIVED ���EI R L C Well: 1H 04L1 tVE i Enclosed for each well(s): �AN 2 2 2015 1 hardcopy print of final logs AOGGC AOGCC • 2MD, 5MD & TVDSS 1 compact disk containing final field data • CGM • PDF • SURVEY • TIFF • LAS • TAPESCAN 6_,,„„at 0 C o _ _ _ o r) L (p o c -a _ /fx� (N° r = c = 0 c1 = 0 N " 7c 7- o N , _ ; 1 n 0 o —■ o a fD o 0 (D (Q o 0- C CD — D- F ( l (I) -. - cD Z u) '3 X m D CD 0 SU o a) IMMINE0 IX C 13 21 1; > D _rw7 0 a m "' N 1\1IA 111D ci, CO i ' O Op IN cl z { a _ yO. 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Letter of Transmittal FARM RECEIVED BAKER Date: JAN 1 6 2015 DATA LOGGED January 15, 2015 /t6/2015 HUGHES AOGOC M.K.BENDER To: From: Makana Bender Yosha Ragbirsingh/Michael Soper AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 1H-04L1 211A- C' 2-b213 1H-04L1-01 2\1-VIC-A '2-5 21 di 1E-14L1 21�' 202- 252-1 ' (3) 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 mommiNimmummommEmmisummommimmomillillimimiliii 4 ' ' or r� Alaska Oil and Gas Conservation Commission LS :Amac...- 333 West Seventh Avenue � ;_�=r�,:=-` — —— Anchorage,Alaska 99501-3572 �, '� ( ,�iVILPN+ IR 1}lI-I `\ ,;[I:FI: Main 907.279.1433 p0,i— " "p Fax:907.276 7542 ALAS'' www aogcc.alaska.gov D. Venhaus CTD Engineering Supervisor ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage,AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1H-04L1 ConocoPhillips Alaska, Inc. Permit No: 214-186 Surface Location: 911' FNL, 1140' FEL, Sec. 33, T12N, R10E,UM Bottomhole Location: 1474' FSL, 1308' FWL, Sec. 33, T12N, R10E,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. 182-103, API No. 50-029- 20770-00-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, cli- Cathy P. oerster Chair DATED this U day of December, 2014. . r RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION NOV 2 0 2014 PERMIT TO DRILL 20 AAC 25.005 AOGCC la Type of Work 1 b Proposed Well Class Development-Oil ❑ Service-Winj ❑ Single Zone ❑✓ • lc Specify if well is proposed for Drill ❑ .Lateral Stratigraphic Test ElDevelopment-Gas ❑ Service-Supply ❑ Multiple Zone ElCoalbed Gas CIGas Hydrates❑ Redrill ❑ Reentry[j Exploratory ❑ Service-WAG ❑., ' Service-Disp ❑ r Geothermal ❑ Shale Gas ❑ 2 Operator Name' 5 Bond -u U Blanket Single Well 11 Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 . .1'jZ j4 1H-04L1 r 3 Address. 6 Proposed Depth 12 Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD. 10400' 4 TVD: 6617'. Kuparuk River Field , 4a Location of Well(Governmental Section) 7 Property Designation(Lease Number). Surface:911'FNL, 1140'FEL,Sec.33,T12N,R10E, UM ' ADL 25639 • Kuparuk River Oil Pool Top of Productive Horizon 8.Land Use Permit 13 Approximate Spud Date: 1131'FNL, 1318'FWL, Sec. 33,T12N,R10E, UM 464 12/19/2014 Total Depth. 9.Acres in Property. 14 Distance to 1474'FSL, 1308'FWL,Sec.33,T12N, R10E, UM 2560 • Nearest Property 17750 4b Location of Well(State Base Plane Coordinates-NAD 27): 10 KB Elevation above MSL. • 85 feet 15 Distance to Nearest Well Open Surface:x- 549210 y- 5979789 Zone- 4. GL Elevation above MSL 50 feet to Same Pool 1H-08,265 16 Deviated wells Kickoff depth . 7435 ft. 17 Maximum Anticipated Pressures in psig(see 20 MC 25 035) g3/i 7/46 Maximum Hole Angle: , 95° deg Downhole'3968 psig. Surface:28.74 psig 18 Casing Program. Specifications Top - Setting Depth -Bottom Cement Quantity,c f or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2.375" 4.7# L-80 ST-L 2850' 7550' 6602' 10400' 6617' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft) Total Depth TVD(ft) Plugs(measured) Effective Depth MD(ft) Effective Depth TVD(ft).' Junk(measured) 8086' 7082' none none Casing Length Size Cement Volume MD TVD Conductor/Structural 79' 16" 274 sx AS II 110' 110' Surface 2162' 10.75" 1000 sx AS III,250 sx AS II 2191' 2191' 1 Production 8043' 7" 1145 sx CI G,250 sx AS II 8071' 7070' Perforation Depth MD(ft): Perforation Depth TVD(ft): 7180-7242,7291-7324,7482-7486,7496-7520 6320-6373,6414-6442,6575-6579,6587-6607 20 Attachments Property Plat❑ BOP Sketch ❑ Drilling Program ❑✓ Time v Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements ❑., 21 Verbal Approval Commission Representative Date 22. I hereby certify that the foregoing is true and correct Contact Cody Poh/er @ 265-6435 Email Cody.J.Pohler@cop corn Printed Name ..,, D-Venhaus Title CTD Engineering Supervisor ��r Signature ryst.`� �/� Phone:263-4372 Date //-/7- iL/ Commission Use Only Permit to Drill API Number Permit Approval 1See cover letter Number d/�` — /8Ib 50-p�9 - (2p ?7.0_fop —pc� Date: \ ,I4 for other requirements Conditions of a roval: If box is checked well ma not be used to ex lore for test,or roduce coalbed \c-tt) hane as h drates or as contained in shales: IApP � Y P � P � .9 hydrates, 9 Other: Bop ft5 7- fa 4 00 0/�s ; Samples req'd: Yes No Mud log req'd: YestJ No[Z i9 v,n v lar p rr v -•- tc r�. H2S measures: Yes No Directional svy req'd: Yes No re S t fo Z ---6c.-1 p 5 i Spacing exception req'd: Yes ❑ No Inclination-only svy req'd: Yes❑ No �-/-a/- - Vv/PJ-,r55cd /lair r4 re-11.Jicof uf?Ler" Sfre6, 1r'3,1tJ ,%IJ�ec1-r�vi . Form 10-401 (Revid 10/2012) Thispermit is vao�r 24�months theEa of aE rRval 0 C 5.005 �� - / Approved by' COM I E i SON Date��!�i K1J ) 7 1'I` (9)) _ f$ y .11/7::://10/1114t- � RECEIVED ConocoPhillips NOV 2 0 2014 Alaska P.O. BOX 100360 AOGCC ANCHORAGE,ALASKA 99510-0360 November 19, 2014 Commissioner-State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an application for permits to drill a dual-lateral out of the Kuparuk Well 1H-04 using the coiled tubing drilling rig, Nabors CDR2-AC. The work is scheduled to begin late December 2014. The CTD objective will be to drill dual-laterals (1 H-04L1 and 1H-04L1-01), targeting the A sand intervals. Note the current A sand perforations are still open below the •� whipstock. / Attached to this application are the following documents: - Permit to Drill Application Form 10-401 for 1H-04L1 and 1H-04L1-01 - Detailed Summary of Operations - Directional Plans - Proposed Schematic If you have any questions or require additional information please contact me at 907-265-6435. Sincerely, C )CAPP(2/- Cody Pohler Coiled Tubing Drilling Engineer 0 2 0- i--. o 2 C0 0 O N a'S E O O .403 0 0 O 0 N 0 - 0 0 0 _ ° N O O "6 U E I — m N V y C O� a) a) N a) i-I .0 c t N N p 0 0 @ Cl a E V) 0000 N NO O 2 N N a) 9'00 0 r o -`o aa)ca V0 OFha 0 ` ,i w 2 O 0 Y 2 2 CO g c >n d o c� 2"0 2 in N o 2 2 c oo� v m E cn °7c E- h0� co _� a ih0 N cO N`rti we d r m N co V @ O a 0 < E O E $0 O_ O n a X N- co co o. - J ""' 2 a — >.c rn —N. N-c) N m >m Nih N m o .a 'p O N p u7 O r a) CO M + a M O@ZiO w rnd. 0 n a �a >,03� t N x >.� a� m Lq• I 10.�2 u) 0 C'.) a.c ya CD2 9m�° a N rnm o 0 .flm n cv( N F [0a) O 9 ac 2� $0Y c5 c a_.0 c N N °)`h c VAa�)oVU Y i� X « u0 >o O� > > °� Q� n U ° U3 ° M Qmm `* nmoC 7k E Y N 'O E @ N J N N : N a w E 0 Ou) M @ @ E @ a)'T= @ @ m a m @ 24. Uc O of 0 m ili l 0 coc u_ - m 0 m o Utim U �� 0�N N (V NzZ y N YYY NNNN@ .YYY NVN "OL M M M M 0. M mmm M V M V J m m m M inN NCw �a>i� �m rN « I ill 11 11 11 I\ 11ii ' W ,...:. _ '47-, t • N.- t ti 1 >_ t I I J I MA VA� T__ O 11 Wf 1 0 co m nm @ �0 -- 0� avo 2 r �._ a\UN �� IIa CI aI 1- Nv O 2 it m NM �O d N'Zp I dN L90 L O� CON w r N N'O O UN II O-N Y� d = cl YN-N c cob �1 _ a13� M O 10 N N O cm L V p N O N n. I N I`1` 1 zo O 0,N N I\ I\ 8-8 I Q 1\ nU� L N. I 0 0 c—N I 0-876 I co n J O O 1 OU(, I0J 1 Kuparuk CTD Laterals MA • ALASKA &We°s 111-04L1 & 1 H®04L1®01 Application for Permit to Drill Document AC 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(f)and 20 MC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 3 (Requirements of 20 AAC 25.005(c)(5)) 3 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 3 (Requirements of 20 MC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 • 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 5 (Requirements of 20 AAC 25.005(c)(13)) 5 Summary of Operations 5 Pressure Deployment of BHA 5 Liner Running 6 14. Disposal of Drilling Mud and Cuttings 6 (Requirements of 20 MC 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 6 (Requirements of 20 AAC 25.050(b)) 6 16. Quarter Mile Injection Review(for injection wells only) 7 (Requirements of 20 AAC 25.402) 7 17. Attachments 7 Attachment 1: Directional Plans for 1H-04L1 &1H-04L1-01 7 Attachment 2: Current Well Schematic for 1H-04 7 Attachment 3: Proposed Well Schematic for 1H-04L1 & 1H-04L1-01 7 Page 1 of 7 0 1 0 I N A L 11/19/2014 PTD Application: 1 H-04L1 & 1H-04L1-01 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document are 1H-04L1 & 1H-04L1-01. Both laterals will be classified as "Service— Water Alternating Gas Injection"wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 1H-04L1 & 1H-04L1-01. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036, for thru-tubing drilling operations. 12141 — Pipe rams, blind rams and the CT pack off will be pr ss tested to 250 psi and to 4000 psi. Using the maximum formation pressure in the area of 3; * the 1 H-03, the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft, would be-3-3-2?-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. 3 31+ 1, —� 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005(c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005(c)(4)(a)) The last pressure survey from September 2, 2014 for 1H-04 was a combined Kuparuk A & C sand, and measured 2874 psi (10.5 ppg EMW). The final mud weight used during the 1H-04 rig work over in November 2014 was 10.2 ppg and was experiencing losses. An updated pressure survey will be obtained on the Kuparuk A-sand only before Coiled Tubing Drilling operations begin, the C-sand will be isolated via a straddle completion. The maximum downhole pressure in the 1H-04 pattern is to the north with the 1H-03 injector at 3968 psi (11.9 ppg EMW). We are unable to get a static formation pressure measurement in the A-sand in well 1H-08 to the south, but the A-sand has been isolated from injection since 2007. It is likely that the A-sand pressure in 1H-08 has diminished since 2007 so the maximum pressure in the vicinity will still be from 1 H-03. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) No specific gas zones will be drilled; no gas injection has been performed in this area, so low probability of encountering gas. Potential Causes of Hole Problems(Requirements of 20 AAC 25.005(c)(4)(c)) The largest, expected risk of hole problems in the 1H-04 laterals will be pressure differentials across the faults, managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossing. Page 2 of 7 RI G I N A L 11/19/2014 PTD Application: 1H-04L1 & 1H-04L1-01 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 25.0300, thru-tubing drilling operations need not perform additional formation integrity tests. 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 1H-04L1 7,550' 10,400' 6,516' 6,532' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top. IH-04L1-01 7,370' 9,600' 6,396' 6,545' 2%", 4.7#, L 80, ST-L slotted liner; deployment sleeve on top Existing Casing/Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (ppf) MD MD TVD TVD psi psi Conductor 16" 65 H-40 Welded 31' 110' 31' 110' 1,640 630 Surface 10-3/4" 45.5 K-55 BTC 29' 2,191 29' 2191' 3,580 2,090 Casing 7" 26.0 K-55 BTC 29' 8,071' 29' 7,070' 4,980 4330 Tubing 3-1/2" 9.3 L-80 EUE 24' 7,375' 24' 6,400' 10,160 10,530 Tubing Tail 5'/" 14 J-55 STC 7,375' 7,455' 6,400' 6,468' 4,270 3,120 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) N/A for this thru-tubing drilling operation. Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System Diagram of Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride-based FloVis mud (9.7 ppg) — Drilling operations: Chloride-based FloVis mud (9.7 ppg). / While this mud weight may not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: Well 1H-04 contains a new style deployment valve allowing deployment of tool strings and liner without pumping kill weight fluid. If the valve does not hold, BHA's will be deployed using standard pressure deployments and the well will be loaded with 12.0 ppg NaBr completion fluid in order to provide formation over-balance while running completions. Page 3 of 7 0 ' I G I N A L 11/19/2014 PTD Application: 1H-04L1 & 1H-04L1-01 — Emergency Kill Weight fluid: Two well bore volumes (-182 bbl) of 12.0 ppg NaBr emergency kill weight fluid will be within a short drive to the rig during drilling 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 kicking out into the B2 shale turning south and building inclination to land in the A4,we plan to hold 11.8 ppg at the window for stability. The constant BHP target will be adjusted to maintain overbalanced conditions if increased reservoir pressure is encountered during drilling. The constant BHP target will be maintained utilizing the surface choke. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Pressure at the 1H-04 Window(7435' MD, 6451'TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A+C-sand Formation Pressure(10.5 ppg) 2874 psi 2874 psi Mud Hydrostatic(9.7 ppg) 3251 psi 3251 psi Annular friction (i.e. ECD, 0.095 psi/ft) 706 psi 0 psi Mud+ECD Combined 3957 psi 3251 psi (no choke pressure) (overbalanced (overbalanced —1083 psi) —377 psi) Target BHP at Window(11.8 ppg) 3958 psi 3958 psi Choke Pressure Required to Maintain 0 psi 708 psi Target BHP 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an exploratory or stratigraphic test well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Page 4 of 7 ORIGINAL 11/19/2014 PTD Application: 11-1-04L1 & 1H-04L1-01 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well 1H-04 is a Kuparuk A-sand injection well equipped with 3'/2"tubing and 7"production casing. A rig work-over was recently performed,replacing the existing tubing and packers with new 3-1/2"tubing, a C- sand straddle,and a 5-1/2""Big Tail Pipe"completion. Two laterals will be drilled;one to the south of the parent well and the other to the north.These laterals will access reserves in the adjacent fault blocks targeting the A4 sand. A Baker Hughes Thru-Tubing whip-stock will be set inside the 5 '/2"big tail pipe at the planned kick off point of 7,435' MD. The 1H-04L1 lateral will exit through the big tail pipe at 7435'MD and TD at 10,400' MD. 2 3/8"slotted liner will be run from TD up to 7,550' MD with an aluminum billet for kicking off the 1H-04L1-01 lateral. The 1H-04L1-01 will drill to a TD of 9,600' MD,with the liner top at 7,370 MD; located inside the 3 %2"tubing. Pre-CTD Work 1. RU Slickline:Dummy all gas lift valves and obtain a KRU A-sand SBHP. 2. RU Slickline: Install downhole pressure gauge in the lowest mandrel and Dummy Whipstock Drift 3. RU E-line:Set Baker Hughes 3-1/2"x 5-1/2"Thru-Tubing Whipstock. 4. Prep site for Nabors CDR2-AC,including setting BPV. Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 1H-04L1Lateral(A4 sand to south) a. Mill 2.80"window at 7,435' MD. b. Drill 3"bi-center lateral to TD of 10,400' MD. c. Run 2%"slotted liner with an aluminum billet from TD up to 7,550' MD. 3. 1H-04L1-01Lateral(A4 sand to north) a Kick off of the aluminum billet at 7,550'MD. b. Drill 3" bi-center lateral to TD of 9,600' MD. c. Run 2%"slotted liner from TD up to 7,370' MD,inside the tubing tail. 4. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV. 2. Install GLV's(if needed). 3. Pre-produce for several months,then return to injection(via Sundry submittal) Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure, so installed in this well is a down hole deployment valve. This valve, when closed using hydraulic control lines from surface, isolates the well pressure and allows long BHA's to be deployed/un-deployed without killing the well. If the deployment valve fails, operations will continue using the standard pressure deployment process. A system of double swab valves on the Christmas tree,double deployment rams, double check valves and double ORIGINAL Page 5 of 7 11/19/2014 4111/ PTD Application: 1H-04L1 & 1 H-04L1-01 ball valves in the BHA, and a slick-line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running — The 1H-04 well has a new down hole deployment valve installed. It will serve to deploy liners into the newly drilled laterals. If the valve fails the laterals will be displaced to an overbalancing fluid (12 ppg NaBr) prior to running liner. See"Drilling Fluids"section for more details. — While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%"liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (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). 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. Page 6 of 7 ORIGINAL 11/19/2014 PT® Application: 1H-04L1 & 1H-04L1-01 — Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 1H-04L1 17,750' 1H-04L1-01 17,700' — Distance to Nearest Well within Pool Lateral Name Distance Well 1H-04L1 265' 1H-08 1H-04L1-01 560' 1H-03 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) 1H-04L1 is within %-mile of the 1H-08 well 1H-04L1-01 is within %4-mile of the 1H-03 well 1H-04(mother bore) Injector • Completed with 7", 26#, K-55 casing on 7/23/1982. • Classified as a "Normal Well"with a recent Rig Work-Over • C-sand perforations: C4: 7180'-7242' MD, Cl: 7291'-7324' MD • A-sand perforations: A5:7482'-7486' MD,A4: 7496'-7520' MD • Packers are located at 7103'and 7333' as a C-sand straddle completion • 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. 1H-08 (injector), -265' away from L1 lateral to south • The 1 H-08 injector is currently on line for injection into the Kuparuk C-sand interval. • Completed with 7", 26#, K-55 casing on 7/7/82 • C-sand perforations: C4: 8092'-8152' MD, Cl: 8224'-8252' MD • A-sand perforations: A5: 8426'-8432' MD,A4: 8442'-8472' MD • Packers at 7985', 8213', and 8323' MD • 1 H-08 was converted to a water injector in 1993. The cement bond logs of 1982 show generally poor cement throughout the Kuparuk sands, so remedial cement squeeze operations were conducted. The post squeeze bond log of December 1985 shows improved cement quality above the C-sand perfs. Sundry for injection was approved thereafter. • Passed MIT-IA on 8/11/13 1H-03 (injector), —560' away from L1-01 lateral to north • The 1 H-03 injector is currently on line for injection into the Kuparuk A&C-sand intervals. • Completed with 7", 26#, K-55 casing on 8/8/82 • C-sand perforations: C4: 7184'-7220' MD, Cl: 7276'-7305' MD • A-sand perforations:A5: 7476'-7481' MD,A4: 7490'-7513' MD • Packers at 7022', and 7381' MD, for a C-sand Straddle • Classified as a"Normal Well"and passed the last MIT-IA on 10/08/13 • The cement bond log shows adequate cement as per original injection order 17. Attachments Attachment 1: Directional Plans for 1H-04L1 & 1H-04L1-01 Attachment 2: Current Well Schematic for 1H-04 Attachment 3: Proposed Well Schematic for 1H-04L1 & 1H-04L1-01 Page 7 of 7 VRI h A L 11/19/2014 I 1 _ . `� _ ,, 1 I I- ' 1 7 + o os r i !- 7 I I - o ` t / i • LL &¢¢¢ +a-T t f-_ k 1 t ._- '�� ,di ,-,,, I+7 .-}r T'1 } tit rt�t i I f- i ++ri-1. o ¢ iag il, 4- c t't "Tit! 1t '�' t _ i 1f__ tl 11 . � .1._,.—m _—__-_ - rti ii I, i f �8� � - 1- ;H _'ij ;: :{ 1 1 11'1 : ' ..i. . 4 n r }{ 1 ± ++1711 t � :, t !1 I t++I_. o d - '• ':i'�_Hitt iib -'t+:�iiiiaadiiai� ?i�ui S' _- 8 C ix 3 m ®.. '��. + gamma imuMn $ � 8 Ar •,---- .410 :wcw„. I 1 , 2-----t--ftt qt ---;• ,. s F„'N -8.V. iymil allit"-V-. . egg i ..tiio�� '.fie� �.'d'r � iilo � �� a _ 44 8 iIy Lin.�.• ..-...■..." �I!> 1.��•-�.2 I.I. iilin � 6Ai iii�ii 7 I ; H Low nil" igi 9. 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I t t= f2�$ EsaWv O ^' � PI g W N N .D tSN .8, r O pR �n N N N [KG (1,_N. � 0 _ nos a d,R, ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad 1H-04 1H-04L1 Plan: 1H-04L1_wp01 Standard Planning Report 03 November, 2014 r' 1 BAKER HUGHES ORIGINAL ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 1 H-04 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 H-04 @ 85.00usft(1 H-04) Site: Kuparuk 1H Pad North Reference: True Well: 1 H-04 Survey Calculation Method: Minimum Curvature Wellbore: 1 H-04L1 Design: 1H-04L1_wp01 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 1H Pad Site Position: Northing: 5,979,968.84 usft Latitude: 70°21'21.831 N From: Map Easting: 549,197.16 usft Longitude: 149°36'1.675 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.38° Well 1 H-04 Well Position +N/-S 0.00 usft Northing: 5,979,789.20 usft Latitude: 70°21'20.064 N +E/-W 0.00 usft Easting: 549,210.20 usft Longitude: 149°36'1.328 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1 H-04L1 ," , Model Name Sample Date Declination Dip Angle Field Strength NiOra `' l f* ^ a (') (°) (nT) BGG M2014 1/1/2015 19.12 80.95 57,578 Design 1 H-04L1_wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,400.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 224.31 11/3/2014 9.59:16AM Page 2 COMPASS 5000.1 Build 61 ORIGINAL ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 1H-04 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 H-04 @ 85.0ousft(1 H-04) Site: Kuparuk 1H Pad North Reference: True Well: 1 H-04 Survey Calculation Method: Minimum Curvature Wellbore: 1H-04L1 Design: 1 H-04L1_wp01 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System i-NI-S +E/-W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°/100ft) (°/100ft) (°1100ft) (°) Target 7,400.00 32.58 287.11 6,421.29 -249.94 -2,694.49 0.00 0.00 0.00 0.00 7,435.00 32.74 287.25 6,450.75 -244.36 -2,712.54 0.51 0.46 0.40 25.34 7,450.00 34.54 287.25 6,463.24 -241.90 -2,720.47 12.00 12.00 0.00 0.00 7,562.13 85.00 287.25 6,517.89 -214.09 -2,810.04 45.00 45.00 0.00 0.00 7,687.13 90.87 231.24 6,522.79 -236.58 -2,927.85 45.00 4.69 -44.81 274.40 7,812.13 90.48 174.99 6,521.19 -346.98 -2,974.97 45.00 -0.31 -45.00 270.00 8,112.13 90.45 153.99 6,518.72 -634.43 -2,895.19 7.00 -0.01 -7.00 270.00 8,262.13 90.08 164.48 6,518.03 -774.49 -2,842.09 7.00 -0.25 7.00 92.00 8,612.13 85.12 188.51 6,532.90 -1,120.85 -2,820.73 7.00 -1.42 6.86 102.00 8,747.13 77.61 182.70 6,553.16 -1,253.52 -2,833.81 7.00 -5.56 -4.30 217.00 8,882.13 81.88 174.13 6,577.22 -1,386.15 -2,830.07 7.00 3.16 -6.35 296.00 8,982.13 86.31 179.57 6,587.52 -1,485.41 -2,824.62 7.00 4.44 5.45 51.00 9,082.13 90.73 174.14 6,590.10 -1,585.16 -2,819.14 7.00 4.42 -5.44 309.00 9,332.13 94.87 191.16 6,577.80 -1,833.62 -2,830.57 7.00 1.66 6.81 76.00 9,482.13 94.79 180.63 6,565.14 -1,982.09 -2,845.90 7.00 -0.05 -7.02 270.00 9,632.13 93.80 170.14 6,553.89 -2,130.97 -2,833.88 7.00 -0.66 -6.99 265.00 9,782.13 93.73 180.67 6,544.01 -2,279.95 -2,821.91 7.00 -0.04 7.02 90.00 9,932.13 90.80 190.76 6,538.06 -2,428.88 -2,836.82 7.00 -1.96 6.73 106.00 10,232.13 90.74 169.75 6,533.99 -2,727.18 -2,838.15 7.00 -0.02 -7.00 270.00 10,400.00 90.73 181.51 6,531.82 -2,894.25 -2,825.38 7.00 -0.01 7.00 90.00 11/3/2014 9:59:16AM Page 3 COMPASS 5000.1 Build 61 O ! G ( NAL ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 1 H-04 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 H-04 @ 85.00usft(1 H-04) Site: Kuparuk 1H Pad North Reference: True Well: 1 H-04 Survey Calculation Method: Minimum Curvature Wellbore: 1H-04L1 Design: 1H-04L1_wp01 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (o) (o) (usft) (usft) (usft) (usft) (°/100ft) (°) (usft) (usft) 7,400.00 32.58 287.11 6,421.29 -249.94 -2,694.49 2,061.07 0.00 0.00 5,979,521.59 546,517.67 TIP 7,435.00 32.74 287.25 6,450.75 -244.36 -2,712.54 2,069.68 0.51 25.34 5,979,527.05 546,499.59 KOP 7,450.00 34.54 287.25 6,463.24 -241.90 -2,720.47 2,073.46 12.00 0.00 5,979,529.46 546,491.64 End 12 dls,Start 45 dls 7,500.00 57.04 287.25 6,497.88 -231.34 -2,754.48 2,089.66 45.00 0.00 5,979,539.80 546,457.57 7,562.13 85.00 287.25 6,517.89 -214.09 -2,810.04 2,116.13 45.00 0.00 5,979,556.68 546,401.90 4 7,600.00 86.51 270.23 6,520.71 -208.38 -2,847.22 2,138.01 45.00 -85.60 5,979,562.15 546,364.68 7,687.13 90.87 231.24 6,522.79 -236.58 -2,927.85 2,214.52 45.00 -84.33 5,979,533.41 546,284.25 5 7,700.00 90.86 225.45 6,522.60 -245.13 -2,937.46 2,227.35 45.00 -90.00 5,979,524.80 546,274.70 7,800.00 90.55 180.45 6,521.30 -334.86 -2,975.45 2,318.09 45.00 -90.09 5,979,434.84 546,237.30 7,812.13 90.48 174.99 6,521.19 -346.98 -2,974.97 2,326.43 45.00 -90.67 5,979,422.72 546,237.86 End 45 dls,Start 7 dls 7,900.00 90.48 168.84 6,520.45 -433.93 -2,962.62 2,380.02 7.00 -90.00 5,979,335.87 546,250.79 8,000.00 90.47 161.84 6,519.62 -530.61 -2,937.32 2,431.53 7.00 -90.05 5,979,239.36 546,276.71 8,100.00 90.45 154.84 6,518.82 -623.48 -2,900.43 2,472.22 7.00 -90.11 5,979,146.74 546,314.21 8,112.13 90.45 153.99 6,518.72 -634.43 -2,895.19 2,476.39 7.00 -90.17 5,979,135.83 546,319.52 7 8,200.00 90.23 160.14 6,518.20 -715.30 -2,860.96 2,510.35 7.00 92.00 5,979,055.19 546,354.27 8,262.13 90.08 164.48 6,518.03 -774.49 -2,842.09 2,539.52 7.00 92.04 5,978,996.14 546,373.54 8 8,300.00 89.53 167.07 6,518.16 -811.19 -2,832.79 2,559.28 7.00 102.00 5,978,959.50 546,383.08 8,400.00 88.08 173.93 6,520.26 -909.73 -2,816.29 2,618.28 7.00 101.99 5,978,861.08 546,400.22 8,500.00 86.66 180.79 6,524.85 -1,009.46 -2,811.68 2,686.42 7.00 101.85 5,978,761.39 546,405.48 8,600.00 85.29 187.67 6,531.88 -1,108.88 -2,819.03 2,762.69 7.00 101.53 5,978,661.94 546,398.79 8,612.13 85.12 188.51 6,532.90 -1,120.85 -2,820.73 2,772.44 7.00 101.05 5,978,649.96 546,397.17 9 8,700.00 80.23 184.75 6,544.10 -1,207.37 -2,830.80 2,841.39 7.00 -143.00 5,978,563.38 546,387.67 8,747.13 77.61 182.70 6,553.16 -1,253.52 -2,833.81 2,876.52 7.00 -142.52 5,978,517.21 546,384.96 10 8,800.00 79.26 179.31 6,563.76 -1,305.30 -2,834.72 2,914.20 7.00 -64.00 5,978,465.44 546,384.40 8,882.13 81.88 174.13 6,577.22 -1,386.15 -2,830.07 2,968.81 7.00 -63.32 5,978,384.63 546,389.57 11 8,900.00 82.67 175.11 6,579.63 -1,403.78 -2,828.41 2,980.26 7.00 51.00 5,978,367.01 546,391.35 8,982.13 86.31 179.57 6,587.52 -1,485.41 -2,824.62 3,036.03 7.00 50.87 5,978,285.42 546,395.67 12 9,000.00 87.10 178.60 6,588.54 -1,503.24 -2,824.34 3,048.59 7.00 -51.00 5,978,267.58 546,396.07 9,082.13 90.73 174.14 6,590.10 -1,585.16 -2,819.14 3,103.58 7.00 -50.94 5,978,185.71 546,401.81 13 9,100.00 91.03 175.35 6,589.82 -1,602.95 -2,817.50 3,115.16 7.00 76.00 5,978,167.93 546,403.56 9,200.00 92.71 182.15 6,586.55 -1,702.81 -2,815.32 3,185.10 7.00 76.02 5,978,068.10 546,406.40 9,300.00 94.35 188.97 6,580.39 -1,802.09 -2,824.98 3,262.88 7.00 76.24 5,977,968.77 546,397.40 9,332.13 94.87 191.16 6,577.80 -1,833.62 -2,830.57 3,289.36 7.00 76.66 5,977,937.20 546,392.01 14 9,400.00 94.85 186.40 6,572.05 -1,900.43 -2,840.89 3,344.38 7.00 -90.00 5,977,870.33 546,382.13 9,482.13 94.79 180.63 6,565.14 -1,982.09 -2,845.90 3,406.30 7.00 -90.40 5,977,788.65 546,377.65 15 9,500.00 94.68 179.38 6,563.67 -1,999.89 -2,845.90 3,419.05 7.00 -95.00 5,977,770.85 546,377.77 9,600.00 94.02 172.39 6,556.08 -2,099.29 -2,838.75 3,485.17 7.00 -95.10 5,977,671.52 546,385.58 11/3/2014 9:59:16AM ORItNAL a4e 4COMPASS 5000.1 Build 61 • ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 11-1-04 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 H-04 @ 85.00usft(1 H-04) Site: Kuparuk 1H Pad North Reference: True Well: 1H-04 Survey Calculation Method: Minimum Curvature Wellbore: 1H-04L1 Design: 1 H-04L1_wp01 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100ft) (°) (usft) (usft) 9,632.13 93.80 170.14 6,553.89 -2,130.97 -2,833.88 3,504.44 7.00 -95.63 5,977,639.87 546,390.66 16 9,700.00 93,78 174.91 6,549.40 -2,198.09 -2,825.07 3,546.32 7.00 90.00 5,977,572.81 546,399.90 9,782.13 93.73 180.67 6,544.01 -2,279.95 -2,821.91 3,602.69 7.00 90.31 5,977,490.98 546,403.60 17 9,800.00 93.39 181.87 6,542.90 -2,297.78 -2,822.30 3,615.72 7.00 106.00 5,977,473.15 546,403.33 9,900.00 91.43 188.60 6,538.69 -2,397.21 -2,831.42 3,693.24 7.00 106.07 5,977,373.67 546,394.87 9,932.13 90.80 190.76 6,538.06 -2,428.88 -2,836.82 3,719.67 7.00 106.36 5,977,341.97 546,389.67 18 10,000.00 90.79 186.01 6,537.12 -2,496.00 -2,846.70 3,774.60 7.00 -90.00 5,977,274.80 546,380.23 10,100.00 90.78 179.01 6,535.75 -2,595.83 -2,851.07 3,849.09 7.00 -90.07 5,977,174.95 546,376.52 10,200.00 90.75 172.00 6,534.41 -2,695.45 -2,843.24 3,914.91 7.00 -90.16 5,977,075.39 546,385.00 10,232.13 90.74 169.75 6,533.99 -2,727.18 -2,838.15 3,934.05 7.00 -90.26 5,977,043.71 546,390.30 19 10,300.00 90.74 174.51 6,533.11 -2,794.38 -2,828.86 3,975.65 7.00 90.00 5,976,976.57 546,400.03 10,400.00 90.73 181.51 6,531.82 -2,894.25 -2,825.38 4,044.68 7.00 90.06 5,976,876.74 546,404.16 Planned TD at 10400.00 11/3/2014 9:59:16AM Page 5 COMPASS 5000.1 Build 61 ORIGINAL ri- ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 1 H-04 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 H-04 @ 85.00usft(1 H-04) Site: Kuparuk 1H Pad North Reference: True Well: 1 H-04 Survey Calculation Method: Minimum Curvature Wellbore: 1H-04L1 Design: 1H-04L1_wp01 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +EI-W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 1H-04 CTD Polygon Sot. 0.00 0.00 0.00 -240.06 -2,723.69 5,979,531.28 546,488.42 70°21'17.698 N 149°37'20.945 W -plan misses target center by 6421.36usft at 7400.00usft MD(6421.29 TVD,-249.94 N,-2694.49 E) -Polygon Point 1 0.00 0.00 0.00 5,979,531.28 546,488.42 Point2 0.00 181.97 -144.83 5,979,712.28 546,342.41 Point 3 0.00 92.16 -329.44 5,979,621.26 546,158.41 Point 4 0.00 -28.34 -409.23 5,979,500.25 546,079.42 Points 0.00 -278.60 -372.86 5,979,250.26 546,117.43 Point 6 0.00 -672.47 -247.41 5,978,857.26 546,245.45 Point? 0.00 -1,001.43 -259.56 5,978,528.26 546,235.46 Point8 0.00 -1,501.48 -259.82 5,978,028.27 546,238.49 Point 9 0.00 -2,008.43 -277.12 5,977,521.27 546,224.52 Point 10 0.00 -2,279.45 -278.89 5,977,250.27 546,224.53 Point 11 0.00 -2,658.71 -246.36 5,976,871.27 546,259.55 Point 12 0.00 -2,758.83 -230.01 5,976,771.27 546,276.55 Point 13 0.00 -2,726.75 66.24 5,976,805.29 546,572.56 Point 14 0.00 -2,611.63 48.99 5,976,920.28 546,554.55 Point 15 0.00 -2,271.47 30.20 5,977,260.28 546,533.53 Point 16 0.00 -2,007.56 49.92 5,977,524.28 546,551.52 Point 17 0.00 -1,503.50 49.21 5,978,028.28 546,547.50 Point 18 0.00 -1,010.35 35.42 5,978,521.28 546,530.47 Point 19 0.00 -670.44 54.64 5,978,861.28 546,547.45 Point 20 0.00 -507.22 24.70 5,979,024.28 546,516.44 Point 21 0.00 -266.62 -63.75 5,979,264.27 546,426.42 Point22 0.00 0.00 0.00 5,979,531.28 546,488.42 1H-04L1_T02 0.00 0.00 6,519.00 -8,425.331,137,289.60 5,978,835.00 1,686,420.00 70°5'55.246 N 140°27'2.062 W -plan misses target center by 1140013.41 usft at 7400.00usft MD(6421.29 TVD,-249.94 N,-2694.49 E) -Point 1H-04L1_T08 0.00 0.00 6,544.00 -10,017.491,137,285.14 5,977,243.00 1,686,426.00 70°5'39.794 N 140°27'9.060 W -plan misses target center by 1140021.48usft at 7400.00usft MD(6421.29 TVD,-249.94 N,-2694.49 E) -Point 1H-04 CTD Polygon Nor 0.00 0.00 0.00 -7,950.471,137,319.72 5,979,310.00 1,686,447.00 70°5'59.812 N 140°26'59.154 W -plan misses target center by 1140058.30usft at 7400.00usft MD(6421.29 TVD,-249.94 N,-2694.49 E) -Polygon Point 1 0.00 0.00 0.00 5,979,310.00 1,686,447.00 Point 2 0.00 280.02 1.83 5,979,590.00 1,686,446.99 Point3 0.00 882.22 -17.25 5,980,192.00 1,686,423.96 Point4 0.00 1,257.89 -113.82 5,980,566.99 1,686,324.93 Point5 0.00 1,689.90 -107.00 5,980,999.00 1,686,328.91 Point 6 0.00 1,992.54 -200.04 5,981,300.99 1,686,233.90 Point 7 0.00 2,157.72 -224.96 5,981,465.99 1,686,207.89 Point8 0.00 2,112.79 -543.30 5,981,418.97 1,685,889.89 Point 9 0.00 1,916.37 -482.57 5,981,222.97 1,685,951.90 Point 10 0.00 1,616.77 -395.51 5,980,923.98 1,686,040.92 Point 11 0.00 1,229.81 -409.03 5,980,536.98 1,686,029.94 Point 12 0.00 865.22 -325.40 5,980,172.98 1,686,115.96 Point 13 0.00 255.92 -290.37 5,979,563.98 1,686,154.98 Point 14 0.00 55.77 -270.67 5,979,363.99 1,686,176.00 Point 15 0.00 -126.42 -90.83 5,979,183.00 1,686,357.01 Point 16 0.00 0.00 0.00 5,979,310.00 1,686,447.00 1H-04L1_T05 0.00 0.00 6,577.00 -9,132.271,137,267.95 5,978,128.00 1,686,403.00 70°5'48.414 N 140°27'5.730 W -plan misses target center by 1139997.06usft at 7400.00usft MD(6421.29 TVD,-249.94 N,-2694.49 E) -Point 1H-04L1_T09 0.00 0.00 6,532.00 -10,604.671,137,301.28 5,976,656.00 1,686,446.00 70°5'34.070 N 140°27'11.133 W -•Ian misses tar•et center b 1140042.80usft at 7400.00usft MD 6421.29 TVD -249.94 N -2694.49 E 11/3/2014 9:59:16AM Page 6 COMPASS 5000.1 Build 61 ORIGINAL IA' ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 1 H-04 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 H-04 @ 85.00usft(1 H-04) Site: Kuparuk 1H Pad North Reference: True Well: 1 H-04 Survey Calculation Method: Minimum Curvature Wellbore: 1 H-04L1 Design: 1 H-04L1_wp01 -Point 1H-04L1_T01 0.00 0.00 6,523.00 -7,964.701,137,202.61 5,979,295.00 1,686,330.00 70°5'59.846 N 140°27 2.553 W -plan misses target center by 1139923.21 usft at 7400.00usft MD(6421.29 TVD,-249.94 N,-2694.49 E) -Point 1H-04L1_T03 0.00 0.00 6,518.00 -8,508.31 1,137,285.05 5,978,752.00 1,686,416.00 70°5'54.447 N 140°27'2.550 W -plan misses target center by 1140009.46usft at 7400.00usft MD(6421.29 TVD,-249.94 N,-2694.49 E) -Point 1H-04L1_Fault2 0.00 0.00 0.00 -9,658.371,137,273.49 5,977,602.00 1,686,412.00 70°5'43.298 N 140°27'7.842 W -plan misses target center by 1140024.89usft at 7400.00usft MD(6421.29 TVD,-249.94 N,-2694.49 E) -Rectangle(sides W315.00 H1.00 D0.00) 1H-04L1_Faultl 0.00 0.00 0.00 -8,759.471,137,304.40 5,978,501.00 1,686,437.00 70°5'51.980 N 140°27'3.082 W -plan misses target center by 1140048.74usft at 7400.00usft MD(6421.29 TVD,-249.94 N,-2694.49 E) -Rectangle(sides W300.00 H1.00 D0.00) 1 H-04L1_T06 0.00 0.00 6,590.00 -9,314.351,137,276.75 5,977,946.00 1,686,413.00 70°5'46.633 N 140°27'6.265 W -plan misses target center by 1140007.3ousft at 7400.00usft MD(6421.29 TVD,-249.94 N,-2694.49 E) -Point 1H-04L1_T07 0.00 0.00 6,565.00 -9,728.451,137,284.04 5,977,532.00 1,686,423.00 70°5'42.602 N 140°27'7.844 W -plan misses target center by 1140017.94usft at 7400.00usft MD(6421.29 TVD,-249.94 N,-2694.49 E) -Point 1H-04L1_T04 0.00 0.00 6,533.00 -8,833.231,137,266.91 5,978,427.00 1,686,400.00 70°5'51.319 N 140°27'4.469 W -plan misses target center by 1139993.72usft at 7400.00usft MD(6421.29 TVD,-249.94 N,-2694.49 E) -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 10,400.00 6,531.82 2-3/8" 2.375 3.000 Plan Annotationst,,,..... � ' , ve \ 11klg,a ` oty ' � "Measured Vertical Local Coordinates , tia ����m +� 0 , I Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 7,400.00 6,421.29 -249.94 -2,694.49 TIP 7,435.00 6,450.75 -244.36 -2,712.54 KOP 7,450.00 6,463.24 -241.90 -2,720.47 End 12 dls,Start 45 dls 7,562.13 6,517.89 -214.09 -2,810.04 4 7,687.13 6,522.79 -236.58 -2,927.85 5 7,812.13 6,521.19 -346.98 -2,974.97 End 45 dls,Start 7 dls 8,112.13 6,518.72 -634.43 -2,895.19 7 8,262.13 6,518.03 -774.49 -2,842.09 8 8,612.13 6,532.90 -1,120.85 -2,820.73 9 8,747.13 6,553.16 -1,253.52 -2,833.81 10 8,882.13 6,577.22 -1,386.15 -2,830.07 11 8,982.13 6,587.52 -1,485.41 -2,824.62 12 9,082.13 6,590.10 -1,585.16 -2,819.14 13 9,332.13 6,577.80 -1,833.62 -2,830.57 14 9,482.13 6,565.14 -1,982.09 -2,845.90 15 9,632.13 6,553.89 -2,130.97 -2,833.88 16 9,782.13 6,544.01 -2,279.95 -2,821.91 17 9,932.13 6,538.06 -2,428.88 -2,836.82 18 10,232.13 6,533.99 -2,727.18 -2,838.15 19 10,400.00 6,531.82 -2,894.25 -2,825.38 Planned TD at 10400.00 11/3/2014 9:59:16AM Page 7CC a COMPASS 5000.1 Build 61 J S. Iri S L We g ` 8 8 Tr N X S O 3 F[. y OC O8Y 2 s o yq o y I roii a v' P. - I I a W, 9 P, - I I I I I O i� @l� u// I I 1 N o =1P1 \I / I 1 I 1 ' 3s s I qE�d , '^ I i I 81 ,'T O .7 4 N `+ `+ M y� J P. L 89 I I $ ' - jc J 8 2S O (- M N 4 yo Y 3 M X 1 CO 8 , N O '1 .0 M (IJ n Y - _ O N b O E Eo 8 4 8 8 $ 8 8 8 8 8 8 8 8 8 $ 4 0 la 3~ O /8 OOZ) +)gpoN/(-)glnos 4I - Y m 2 J,__ - N Ca Jw5 0. 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L1�JQ MMM OJ co coon CO C5 u5 h.co comon o.OV)0,010,CP i�4 on O l-f_ + O 0 0 0 0 M M M M M M M CO M CO M M M M M CO 8 O ^ o ' TTTO O P Jr CDU ER(CV rs CV CV CV((VV D-CV CV CV CV CV((04 CV Ceel CV C; n a O eP 2 b 0 F.F.? m k,g g OmD E g g A O) OJ O O �O V �D �G �0 �c �G b N C (0 n0 NM V(Am r-0O)O'NM V(nm D-co m0 0 o (� (u►/gsn S9)1.11d30 teotyraA anal V ORIGINAL ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad 1H-04 1H-04L1 1 H-04L1_wp01 Travelling Cylinder Report 03 November, 2014 BAKER HUGHES n3IGINAL Baker Hughes INTEQ rd" ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1H-04 Project: Kuparuk River Unit TVD Reference: 1 H-04 @ 85.00usft(1 H-04) Reference Site: Kuparuk 11-1 Pad MD Reference: 1 H-04 @ 85.00usft(1 H-04) Site Error: 0.00usft North Reference: True Reference Well: 1H-04 Survey Calculation Method: Minimum Curvature Well Error: 0.O0usft Output errors are at 1.00 sigma Reference Wellbore 1H-04L1 Database: OAKEDMP2 Reference Design: 1 H-04L1_wp01 Offset TVD Reference: Offset Datum Reference 1H-04L1_wp01 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 7,400.00 to 10,400.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,231.50usft Error Surface: Elliptical Conic Survey Tool Program Date 10/28/2014 From To (usft) (usft) Survey(Wellbore) Tool Name Description 100.00 7,400.00 1H-04(1H-04) BOSS-GYRO Sperry-Sun BOSS gyro multishot 7,400.00 10,400.00 1 H-04L1_wp01 (1H-04L1) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 10,400.00 6,616.82 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 1H Pad 1H-01-1H-01-1H-01 Out of range 11-1-02-1 H-02-1 H-02 Out of range 1 H-03-1 H-03-1 H-03 Out of range 1 H-04-1 H-04-1 H-04 7,450.00 7,450.00 0.23 1.85 -1.27 FAIL-Major Risk 1 H-04-1 H-04L1-01-1 H-04L1-01_wp02 7,550.00 7,550.00 0.00 0.29 -0.22 FAIL-Major Risk 1H-08-1H-08-1H-08 10,400.00 7,500.00 947.87 265.02 780.49 Pass-Major Risk 1 H-09-1 H-09-1 H-09 Out of range 1H-18-1H-18-1H-18 Out of range 1H-19-1H-19-1H-19 Out of range 1H-19-1H-19A-1 H-19A Out of range 1H-19-1 H-19AL1-1 H-19AL1 Out of range 1H-19-1 H-19AL1-01-1 H-19AL1-01 Out of range 1H-19-1 H-19AL1-01 PB1-1 H-19AL1-01 PB1 Out of range 1H-19-1 H-19AL1 PB1-1 H-19AL1 PB1 Out of range 1H-19-1 H-19AL2-1 H-19AL2 Out of range 1H-19-1 H-19APB1-1 H-19APB1 Out of range 1H-20-1 H-20-1 H-20 Out of range 1H-22-1 H-22-1 H-22 Out of range Plan:1H-107(formerly 108 and 30E)-Plan:1H-10 Out of range Plan:1H-112(formerly 106 and 28E)-Plan:1H-11 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 11/3/2014 8:20:55AM C R I ,paged of 7� L COMPASS 5000.1 Build 65 1 Milli i as tTtt:r o_ T-t- _,,,i, „: o p NIU : ""+ - ry 1 • •, o o t t I, q 0 :�� : Ui,O � + NNMPIIIIITIH ¢ ..._ zkm 'ITT l : S _ G,; :Lill- :I;i 14 fit+tI �? + - t LL anti § f�m�{ .A. oIN } , t ±1,t , ++ _S �' l Baa i + } } 1 t .II I r T” — ... + ,,t +++4-4--4+1-: 71 J g 7 C Q ,- } 1 ti:itt tea—' , I+} o S ..: „. i: _ n N ,:r '1 A l s. _ . 1,: rr i g o (( /i pgpl� ---°111.4,±1...; ., - Q C Y,r4." A h tom- T .''':FJ "INN I(•.IOMMEN' 1 S • W O O ce 3 F a t.+ y-,+-.. ■. i • ora' r ., ■�r;_ �., .. - misi , +} �� aO}.}.-t-i----1-7-4-rt I .1_ .1E-oinTmt !#i} 1 ;t11 _;;; ped �`� k E „ „, E m 11. iI t . 'rte n _�,� 1Nifilmantor km MidSi`M..}�+ tl -o � ,1'' # r t yI 'a� iS�puts4 .��# 1- . ;y t. In its „ o v, ,i -�>� #.1 2 'T9 -,, = at' 11 IDsso ft _ +, :-: } } rfi rt1 <t „..in,; ,:, _ r ilgrAL 1."--1-i-4 -= MEIJI--H' ; I � i 1 ®�@$ - ,- its_ lb ,, -- F+ r2 �! �{� tt tri 1.i } �..t.;.. }:..,. • ..iG$ 1:1:1 t.,-r+ riLii3 }f- # f s I ---: —:-::—:1-:7:1::— ” 1 ..dgigallitimuli11111 iiiiiimiiiiiiiiii ---t.---.- '.:.----4',---,-i- . J ,-1 t N,.. , .+t1. 7 1 #IINI� �'"_ �1t�4 ht .}�4. 1 t'10 0 >a SI.R 1 12 2+7T CO1 i + ac44x = - I--:: I :+ 4 .,1 t-' }. 1 +{--14111-4 -� ' .::� --Q xxxz ..�;KIM t T` -'s o fi •• • t+ 72,74a4t BEM S x • iMniIli °p� 4-1i:Eil 6 911 E !MENU � 'Via_ +_ . a ±4 . # # t±7 +---- + -lir4 so ' "y+ r i* o +_ dim,w3illpiffi }--Uzi_ + ag + , ,ile 6 •„ \\\\ - _- - �_W.Yffin � I M ?' '}' 17 11*"+ ,- ++ .hi4-- 1.� + r-tP! H !if4à0 1� 1T...� ..iia ° ,.tea tt+ Ti ,. 4 S --8 = A i $i ies" :' - +r �I+_ { �;. o - GGCNO SOOOOO OO 0 O O 0 0 0 0 0 0 O O '1 t91 N CN M N 0 ( LKA-)ulno3nRIspp Bettis, Patricia K (DOA) From: Pohler, Cody J <Cody.J.Pohler@conocophillips.com> Sent: Friday, November 21, 2014 2:00 PM To: Bettis, Patricia K (DOA) Subject: RE: KRU 1H-04L1: Permit to Drill Application Hi Patricia, The maximum pressure in the 1H-04 pattern is 3968 psig to the north, in well 1H-03. Using a 0.1 psi/ft gas gradient the max potential surface pressure is 3314.4 psig, as stated in the permit under Section 3. Blowout Prevention Equipment Information (typo 3986 psi is meant to be 3968 psi).The information was left out of Section 4. Drilling Hazards Information and Reservoir Pressure, I can amend the permit to reflect this if necessary. Please let me know if you need anything further. Thank you, Cody Pohler I CTD Engineer Office: 907-265-6435 I Cell: 281-409-7869 cody.j.pohler@conocophillips.com ConocoPhillips Alaska From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Friday, November 21, 2014 11:44 AM To: Pohler, Cody.3 Subject: [EXTERNAL]KRU 1H-04L1: Permit to Drill Application Good morning Cody, What is the maximum anticipate surface pressure in psig that ConocoPhillips expects while drilling the KRU 1H-04L1? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission(AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907) 793-1238 or patricia.bettis@alaska.gov. 1 Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Friday, November 21, 2014 11:44 AM To: 'Cody.J.Pohler@cop.com' Subject: KRU 1H-04L1: Permit to Drill Application Good morning Cody, What is the maximum anticipate surface pressure in psig that ConocoPhillips expects while drilling the KRU 1H-04L1? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME: P\(.. 1 I+ - 0,11,) PTD: Qiq _A'( Development ✓ Service Exploratory Stratigraphic Test Non-Conventional FIELD: X(Afc.i4-- gAV POOL: 4AftAllAg gukirOc rc /21AJ Q� Check Box for Appropriate Letter/ Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. / ' - )'03 , API No. 50- 8aq - a,O 7.?0 - 00 - 00. in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name Pilot Hole ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. 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