Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
215-051
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. c IS - 0 Si Well History File Identifier Organizing (done) ❑ Two-sided ❑ Rescan Needed RESCAN: OVERSIZED: NOTES: i)21olor Items: ❑ Maps: payscale Items: ogs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: 4:31bDate: 1115—f IS /s/ 11419 Project Proofing BY: ` Maria Date: 11 G1c isl V14f Scanning Preparation 1 x 30 = 3 0 + I q = TOTAL PAGES (Count does not include cover sh et)BY: Maria Date: / 5/ 5-' /sl Production Scanning r Stage 1 Page Count from Scanned File: J 0 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: 420 Date: 7/15 1/5"-- /s/ yvtp Stage I If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc 0 '^ o r o o .O_ _• N o U E E m C7 0 0 a C a) •� N O U Cr) . C. C. J O b. r p . N @ �. j. <I': J J O O @ O O @ J E O)or p—U N 2 a) @ N V 'O J J C J J C r N a 4 o co p co @ N N @ it it it LL 1- N T cs z D W 0 p @ Q N (n (n N (n (n ()IU m p s Q N J J ~ > J J J J J J = I CI > f"' (O is < < 0 h Q Q Q Q Q Q m I @ — C @ V < < a' V- O V 7 V < < I CO N ce O 2 7 Y __ in c- .- , c I y Z 0 0 Ch p a) N U Ch th C7 C7 C7 C7 c C7 c a p 0 a) O N N N Et N N N N N N N a cNi N @ CE a ai m vhi aui aiii auai iii oiii V p o c •u Z m I.L,� I.L ii D a W 11 it i.i it it i.� I..L i% LL. ;,6 ii — Cr d E v O c) Y cv v v cv NI �I Y(n 7 O E 'E �- c E o W •E Q .E 'E .E 'E E •E .E .c E _I c_I •c 0 w @-. O O O N O N O 70 p O g O O O O p) O O O O O O p Q c4 J V a to ) 0Q i�2 i� i) c) v v v vJ vJ v 0Q N J a)Q a�Q 0 'n W 0 Q 0 CD 0 CD m CD CD m m Q a)Q CD `a W LL Q E W Z W Z W N 2 W 0 W W W W J W W W W ,- W W N I 0 u O a c v in in in L0 L r in in in in in r r 10 a J 0 . > O O O O O O O O O O O O O O W �O N N N N N N N N N N N N N N /� a CO (\) M M ((y L\ (n to LU Ce Q (0 r O (O (O CO cococoCO (O (O CO (D (D (O i� -� LU z Z - Q. C a V 0 < 00 Z To a a O < 0 0 v rn o Ts N J a a 0 N o °' C O O Z O co N O 0 0 a) (.0 co co N a i) ME U a -a Cl)J I— tCO 0. N I` O 0Z N J > d ca To J N Cr) a) re a p ' Q = c g ' I— a) OI QO a Z 0 Z o o w (n d U E J @ (6 -O U U Z C U) U) in c E 0 0 0 0 0 0 0 0 0 0 0 0 0 0 co (73 @ @ I @ @ @ @ @ @ @ @ @ @ @ I ,— co CG Z w. .. w . •. . .. .. ... vr 0) _m •O) co _5 _m O) O) _m O) O) O) O_) O) O) O) co 0 Z O .. 0 0 0 J 0 0 0 0 0 0 0 0 0 0 0 J > 0 J a) d m w ao ao 0 0 0 0 0 0 0 0 0 0 0 0 i F « H -0 h h h N- C) O) C) O) O) O) C) 0) 0) 0) C) O in Q z . c u ra E (Mn LU LU co co (un In LU (Ln (Mn (Mn (Ln (Mn (1n (Mn LO (Ln (Mn N 2 0 0 w w 0 z N N N N N N N N N N N N N N N N Q O EE u. -a °) re Z W c 02 U 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 E m Q w J O d 0 0 Q CL 0 J G !� W WW JW W W W W W W W W W W J o I o o o I t (DC o) o m co a) w O N >- •I o) m } >- } E co 0 o o E co 1 1 I +�� _ jLco a o co _ c_ co a > H i In 0 0 0 rn < VJ v 0 ZO H t 1'I E N In In LO7.......• F- qQ Q a a 0 d Co E E a 1 lM'J 1'a c v U 0_1 03 1 1 o N N NII 0 1 N N a) 113 I Z 1 Iit . d 0 d co U U U �bYl 3+ C E E ` to :o O O O E } } j0 ■ J N N N 0 O. N��VJJ/ 0 Ce < NW W W CO CO Oco) m ._a N U co In In a d a co 3 «° co CL o 0 o E ,EE 12) 0 W = In In In U) Z v; O 1 II, �/ _ 0 CO co CO N N H H0 1'I ii0 it E 1 H W z Z ° o, v; a ) 0) O) p- 1, 0 > E E V 00 a 1 Co° Z m vi .2. co Q o o v) N J a C J 0. E z CL o (J) c 2 0 0 � to � as 1 O � N E co MV Q) U 11 a , No a } 0 E I I a I E N c E ~ to _ co p — Z N Z co C a' 03 CO ch d aa)) E In 5 O E Cl) o w .O. •S 5) I _ coN r+ / ca N a) 0 0 E •E O Q m a H Y o 43 1 CI) ° IE0 0 1 Q Z Eo N v> 0 ZD U 0 2 O la Z m m m to d C Q� N 0) O) Q } c.) Mc 00 0 0 E 0 E InOT m 0 in ~ 'c0 c0 c0 c w E n 0 ai) to Lco co up r N N N d W 0O O ! V~) d N I Q O IX p C ` 1 = 'j CZ • W co I CO 0 O n a) G o co n z Q O E < O 0 co C W C U O d - O - C Y ° U U U o g O U a J _y a) •a m _a U E 0 D a '' 0 n 03 H E °' E E 0 hi 0 0 0 O a) LL O 2 0 0 O 5 d O O a .z w w w 3 z 0 a 0 0 0 c G 0 0 e. 1 50507 21 5051 26 165 - 2 166 BAKER R PRINT DISTRIBUTION LIST HUGHES Please sign and return one copy of this transmittal form to: COMPANY ConocoPhillips Baker Hughes INTEQ DATA LOGGED (mandatory) 795 East 94th Avenue yj /31,/2015 WELL NAME 2G-14A; 14AL1 Anchorage,Alaska 99515 K.BENDER (mandatory) FIELD Kuparuk River Unit to acknowledge receipt of this data. (mandatory) COUNTY North Slope Borough LOG TYPE LWD-Coil (mandatory) (mandatory) STATE Alaska BH DISTRICT Alaska (mandatory) (mandatory) LOG DATE: May 31,2015 TODAYS DATE: 21-Aug-15 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: Patrick Rider EMAIL: itrick.rider bakerhu hes.co (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? No COMPANY FIELD FINAL CD Final CD ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #OI-PRIN I S #OF COPIES #OF COPIES#OF COPIES 4 4 4 4 4 4 4 1 :ConocoPhillips Alaska Inc. !Attn:Ricky Elgaricio ATO 3-344 700 G Street Anchorage,AK 99510 2 'BP Exploration(Alaska)Inc. 1 1 \py9) I \),.. 'Petrotechnical Data Center,1.,R2-11900 E.Benson Blvd. 'Anchorage,Alaska 99508 Attn:Dodie Stinson C 01 . 3 Chevron/KRU Rep ill it 1 I , 1 _ ` 'Attn:Glenn Frederick 111. P.O.Box 196247 1 Anchorage,AK 99519 S °i\VID 42,... ..A 1 41State of Alaska -AOGCC 1 I 1 I VI 1 1 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5'DNR-Division ofOil&Gas *** 1 1 I 1 I Attn:Sean Clifton 1550 West 7th Avenue,Suite 802 'Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR I TOTALS FOR THIS PAGE: 0 3 4 4 4 0 TOTALS FOR ALL PAGES: 0 3 4 4 4 0 RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUL 0 1 2015 Status: COMPLETION OR RECOMPLETION REPORT AND 1a.WeIlStatCC ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 1 b.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAGE , WDSPL❑ No.of Completions: Service 0 • Stratigraphic Test ❑ 2.Operator Name: 6. Date Com usp.,or SJ✓� 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. AbanG15 015•% 215-051 • 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510 •5/29/2015 50-029-21161-60 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 243'FNL,88'FEL,Sec.6,T1ON, R9E, UM •5/30/2015 KRU 2G-14AL1 - Top of Productive Interval: 9. KB(ft above MSL): 140' 17. Field/Pool(s): 1209'FSL, 1191'FWL, Sec.6,T1ON, R9E, UM GL(ft above MSL): 102' Kuparuk River Field/Kuparuk River Oil Poo . Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 106'FNL,448'FWL, Sec.7,T1ON, R9E, UM 8296'MD/5968'TVD ADL 25667• 4b.Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 508610 y- 5943345 Zone- 4 , •9940'MD/6155'TVD ALK 2588 TPI: x- 504874 y- 5939514 Zone- 4 • 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 504132 y- 5938199 Zone- 4 2055'MD/1920'TVD 3410'MD/2814'TVD 5. Directional or Inclination Survey: Yes 0(attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 not applicable (ft MSL) w.8839'MD/6130'TVD • 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to: mud log,spontaneous potential, gamma ray,caliper,resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 38' 110' 38' 110' 24" 202 sx Cold Set II 9.625" 36# L-80 34' 3327' 34' 2760' 12.25" 1060 sx Permafrost E,370 sx PF C 7" 26# J-55 33' 8724' 33' 6278' 8.5" 335 sx Class G,250 sx PF C 2.375" 4.6# L-80 8362' 9940' 6016' 6155' 3" slotted liner 24.Open to production or injection? Yes 0 No El 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3.5" 8374' 8345'MD/6003'ND slotted liner from 8362-9940'MD 6016'-6155'ND •l R-, ) 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. iElig.::1 ts Was hydraulic fracturing used during completion? Yes❑ No 0 e c, Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 8296-8724 15 bbls 16.5 ppg Class G 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 Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate �•► RBDMS Form 10-407 Revised 5/2015 V Ti- 9/Z//_ CONTINUED ON PAGE 2 1�iel Submit ORIGINIAL onl ll}lam LI 28.CORE DATA Conventional Cor. Yes ❑ No Q Sidewall Cores. ❑ No Q If Yes, list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed) Submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results per 20 AAC 25 071. NONE 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD ND Well tested? Yes ❑ No ❑Q Permafrost-Top surface surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 3410' 2814' Attach separate pages to this form,if needed,and submit detailed test information, including reports,per 20 AAC 25.071. Kuparuk A4 8839' 6130' Top Kuparuk A6 9123' 6153' Top Kuparuk A5 9203' 6158' NONE Formation at total depth: Kuparuk A5 - 31. List of Attachments: Summary of Daily Operations,schematic,final directional survey Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and re o t e best of my knowledge. Contact: Jason Burke @ 265-6097 Email: Jason.Burkecop.com Printed Name: Dan Venhaus Title: CTD Engineering Supervisor Signature: �� Phone: 263-4372 Date: G—Lq— /5 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9' The Kelly Bushing and Ground Level elevations in feet above mean sea level Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex 50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and ND for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25 071 and,pursuant to AS 31.05 030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results, including, but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2015 Submit ORIGINAL Only 1. U® KUP INJ 2G-14AL1 ConocoPhiIIIps Well Attributes Max Angle&MD TD Alaska,inc, Wellbore API/UWI Field Name Wellbore Statusnc!(°) MD(ftKB) Act Btm(OKB) 500292116160 KUPARUK RIVER UNIT INJ ' 93.41 8,673.00 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2G-14AL1,6/23/20151:07:49 PM 40.98 10/10/1984 Vesical schematic{actual} Annotation Depth(IIKB) End Date Annotation Last Mod By End Date t Casing Strings Casing Description OD(in) ID(in) Top(OKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(L..Grade Top Thread —I I— Liner AL1 Lateral 23/8 1.992 8,362.5 9,940.0 4.60 L-80 STL HANGER;320k 1111 J 4 Liner Details Nominal ID pr Top(ftKB) Top(TVD)(MB) Top Incl(°) Item Des Corn (in) 'I' 8,362.5 6,016.1 43,84 Deployment Deployment Sleeve Sleeve 1.000 1n.a I -tiN'CONDUCTOR',38 0-110 0 .` SAFETY VLV;2,054.8 GAS LIFT;2,104.2 : 9 SURFACE;340-3,3270 S GAS LIFT;4,4202 GAS LIFT;6,165.8 GAS LIFT;7,473.1 GAS LIFT;8,2892 e r' 11 PBR;8,330.9 03 PACKER;8,344.6 a M SI APERF',8,357.0-8,3590. fi 4 NIPPLE;8.361.6 * F[ 505,8.373.2 ew' �«L/aAb � �a RPERF;8,452.0-8.458.0. PRODUCTION', Liner.A Lateral;8,839 7-9.940.0 Liner AL1 Lateral;82624- 9,9400 • in W — N CO M CDt` n6 z p p Ii () o vsi o 0 rn 4) O p .1- N co L o o tN p Ao' o p it 3 p a = _ u L F- v O `l ppm cop �•3 Q C (V �.©: - Vr ro 0 M (0 EI 0 J '11 th t*I (N�� E 2 O i.nj p Q= N N G F — N —YO co V .@ M (�M a N co M 7 1� U) co OI co o 01 C 0 M N N !0/) 7 I �@ a c y m J u.1 2 O ) =_ >^ N 2 m u tp E t LL a ' 0 d. 0 O U a 0) y # N J — C mN M co 7 m m II of U il U (V (V (V M M ` II 11 11 _ CC3 10 31217.7 1 I nrlf TT I 7 OM N I p s,22 -Nop t o =2 2 m� N o b-cN�cnp 0 N W coa.p fl' co a 2 Yp� co e) c2 -o co;J. I.-- M,C) to C- O N N N v - v d N v-I- r''' f co m ao y YU m <co m LO-C p `n L • co 2 O) N • . 2G-4 -"RE AND POST RIG WELL WORK SUMP" -Y PRE RIG WELL WORK DATE SUMMARY 2/24/2015 (PRE-CTD): MITIA(PASSED TO 3000 PSI), MITOA(PASSED TO 1800 PSI), T POT (PASSED), T PPPOT(PASSED), IC POT(PASSED), IC PPPOT (PASSED), FT LDS (ALL FUNCTIONED PROPERLY). 2/25/2015 (PRE-CTD) : TREE VALVE DDT: SV, MV, SSV(PASSED), TREE VALVE PT: SV, MV (PASSED), SSV(FAILED). 3/23/2015 MEASURED BHP @ 8500' RKB: 3843 PSI. COMPLETE. 4/20/2015 PERFORMED A TUBING PUNCH FROM 8357-8359 WITH A 2"2' 120 PHASE, 3 SPF, BH HSC. LRS PERFORMED SW INJECTIVITY TEST DOWN TUBING 0.43 BPM AT 1180 PSI, 0.5 BPM AT 1190 PSI, 1 BPM AT 1250 PSI, 1.25 BPM AT 1350 PSI, 1.5 BPM AT 1450 PSI. 4/21/2015 PUMP 150BBLS SW FOR INJECTIVITY TEST FOLLWED BY 30BBLS DSL FOR FP (JOB COMPLETE) 5/5/2015 MEASURE BHP @ 8500' RKB (3748 PSI). JOB COMPLETE 5/13/2015 Mill Nipple. Late start due to rig move and wait on hardline to be rigged up. RIH to D Nipple @ 8,362' and painted EOP flag. Milled nipple out with 2.80"tapered mill. Mill gauged 2.80". Will have to jet w/Schmoo-B-Gone in morning. Well freeze protected. Job in progress. 5/14/2015 Pump 25 bbls 16.5 ppg cement and squeeze into A-Sand Perfs. Unsuccessful attempt to to hold requested squeeze pressure (2,200 psi). Contaminate down to 8,400'and wash mandrels and jewerly while POOH. Restart in morning. 5/15/2015 Tag TOC @ 8,526' RKB corrected. Perform FCO to clean any residual contaminated cement from 8,300'down to tag.After initail gel pill returned to surface with slug of cement fluids were clean remaider of FCO.Reciprocated pipe at very slow speeds numerous times through cement area down to TOC. Well freeze protected and ready for cement in morning. Job in progress. 5/16/2015 Second attempt at cement plug unsuccessful. Pushed cement away and washed up 7"casing and tubing jewerly while POOH. Will return in morning and pump cement with Syntec fiber. Job in progress. 5/17/2015 Pump 15 bbls 16.5 ppg cement with middle 8 bbls containing 1 ppb CemNet fiber. Obtained squeeze pressure while squeezing 7.5 bbls behind 7"casing. Washed down to just above target depth of 8,352' RKB corrected. POOH washing tubing jewerly while maintaining overbalance on well. Well freeze protected and ready for Slickline in 72 hrs. 5/19/2015 (PRE CTD)TREE VALVE TEST, JOB POSTPONED DUE TO VALVES LEAKING BY. 5/20/2015 TAGGED CMT WITH 2" BAILER @ 8296'SLM, EST. 8336' RKB. COMPLETE. 5/20/2015 (PRE-CTD): TREE VALVE PPT: MV(PASSED), SSV(PASSED), SV(PASSED). TREE VALVE DDT: MV(PASSED), SSV(PASSED), SV(PASSED). ConocoPhillips Time Log & Summary 4Vel/view Web Reporting Report Well Name: 2G-14 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 5/22/2015 10:00:00 AM Rig Release: 6/1/2015 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 35/21/2015 24 hr Summary Mob to 2G Pad 15:00 18:00 3.00 0 0 MIRU MOVE MOB P MOB to 2G 18:00 00:00 6.00 0 0 MIRU MOVE MOB P Crew change-Continue to 2G pad- hold @ 2A for additional matting21:00 to 23:30 05/22/2015 MIRU,to 2G-14,tested BOPE 00:00 01:00 1.00 0 0 MIRU MOVE MOB P Continue to 2G-14,Arrive on location @ 1:00AM 01:00 02:00 1.00 0 0 MIRU MOVE MOB P Check status on 2G-14, Remove Jeeps, Pull tree cap flange 02:00 06:30 4.50 0 0 MIRU MOVE MOB P Spot sub and pits. Soft pad conditions need cat to move fore and aft 06:30 10:00 3.50 0 0 MIRU MOVE MOB P Rig modules spotted, MIRU 10:00 12:00 2.00 0 0 MIRU WHDBO NUND P Rig Accept @ 10:00, Nipple up stack 12:00 22:45 10.75 0 0 MIRU WHDBO BOPE P Start full BOPE Test,Test witness waived by John Crisp,AOGCC. BOP test pressure low 250/high 4300 psi /Annular 2500 psi 22:45 00:00 1.25 0 0 MIRU WHDBO BOPE P Fluid pack coil,test inner reel valve and pac off.swab valves. 05/23/2015 Completed BOP test, MU, RIH with 0.9°and D331. Mill cement pilot hole. 00:00 00:45 0.75 0 0 MIRU WHDBO CTOP T Replace blind rams, IA 700, OA 0 00:45 01:45 1.00 0 0 MIRU WHDBO BOPE T Retest Lower blind rams, 01:45 02:30 0.75 0 0 MIRU WHDBO CTOP P Test PDL's and kill tank line 02:30 04:00 1.50 0 0 MIRU WHDBO MPSP P PJSM, Load, MU,and PT FMC lubricator. Pull TWC 04:00 06:30 2.50 0 62 PROD1 RPEQP1 PULD P PJSM, PU BHA#1 pilot hole milling assembly,deploy, hole dead. Deploy ' ° Note: coil wall thickness 0.179" good. 06:30 08:54 2.40 62 8,270 PROD1 RPEQPI TRIP P RIH, swap hole to milling fluid(9.34 ppg),flud©the bit 09:25. 08:54 09:06 0.20 8,270 8,325 PROD1 RPEQPI DLOG P Log GR tie in,did not get correlation 09:06 10:00 0.90 8,325 8,230 PROD1 RPEQP CIRC P Circulate well to 9.3 PPG milling fluid while analyzing logs 10:00 10:54 0.90 8,230 8,325 PROD1 RPEQPI DLOG P log GR tie in tagged @ 8325, PUW=30K,-1'correction Pau. 1 of9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:54 13:24 2.50 8,325 8,362 PROD1 RPEQP1MILL P Motored down to 8361. did get samples of green cement. Stalled @ 8361,Assumed milled out D nipple. Stall 4 times to get started 13:24 14:00 0.60 8,362 8,380 PROD1 RPEQP1MILL P 8362 past D nipple Mill down to 8380 and stalled at 7"contact. Found hard cement @ 8365, 2K WOB @ 25FPH 14:00 14:30 0.50 8,380 8,380 PROD1 RPEQP1WPRT P Wipe up hole to 8200', PUW=32K 14:30 16:36 2.10 8,380 8,430 PROD1 RPEQP1MILL P 8380', Mill pilot hole, 1.42 BPM @ 3295 PSI FS, ROP=25 FPM @ 2.1K DHWOB 16:36 17:06 0.50 8,430 8,430 PROD1 RPEQP1WPRT P Wiper trip to 8200, PUW=28K 17:06 19:36 2.50 8,430 8,485 PROD1 RPEQP1MILL P 8430', Mill, 1.43 BPM @ 3360 PSI FS, BHP=3700 19:36 19:51 0.25 8,485 8,280 PROD1 RPEQPI DLOG P 8280ft,tie into the K1 zero ft correction. 19:51 20:06 0.25 8,280 8,485 PROD1 RPEQPI MILL P Dry run through cement pilot hole down to 8396', 1k weight bobble at 8380' looks to be where we contacted the 7 inch. PUH, back ream from 8685'at 1 fph up to 8370' 20:06 22:06 2.00 8,485 8,370 PROD1 RPEQP1 MILL P 8396', PUH, back ream from 8685'to 8370'@ 1 fph,to clean up transition area. Dry run to bottom seeing 300 lbs or motor work. Looks good 22:06 23:36 1.50 8,370 62 PROD1 RPEQP1TRIP P POOH 23:36 00:00 0.40 62 62 PROD1 RPEQP1SFTY P PJSM,simops, Check well for flow 05/24/2015 LD milling BHA#1, MU milling BHA#2 with bi-center bit, RIH milled TOC 8336' to 8512', POOH, LD milling BHA#2, RIH milled from 8485'-8512', POOH,early due to stalling motor. RU HAL caliper, RIH, stacked out on master valve, discussed plan forward., 00:00 00:30 0.50 62 0 PROD1 RPEQP1PULD P LD milling BHA 00:30 01:00 0.50 0 63 PROD1 RPEQPI PULD P MU second milling BHA with 0.6° ako motor and used Reed-Hycalog bi-center bit, 2.7x3.0 01:00 02:30 1.50 63 8,285 PROD1 RPEQPI TRIP P RIH,with BHA#2 02:30 02:45 0.25 8,285 8,285 PROD1 RPEQPI DLOG P 8285',tie into the K1 marker correctiono of minus 1.0' 02:45 03:00 0.25 8,285 8,485 PROD1 RPEQP 1 TRIP P Continue in hole through cement pilot hole pumping min rate. 03:00 05:30 2.50 8,485 8,513 PROD1 RPEQP1MILL P 8485', OBD cement pilot hole 20° ROHS down to 8505',turned tool face down to 180°from 8505'to 8520', 1.4 bpm at 3126 psi, IA 7, OA 0 ****Note:3 stalled getting started, total of 12 stalls,with level 2-3 severity lateral vibration. Max ROP 34 fph with a stall 05:30 07:42 2.20 8,513 76 PROD1 RPEQPI TRIP P POOH, check well for flow, looks good and dead, Painting EOP flag 8200'for tie in on next trip. o;w.j 2 of 9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:42 08:18 0.60 76 76 PROD1 RPEQPI OWFF P At surface, PJSM to lay down BHA #2, perform no flow test 08:18 09:24 1.10 76 0 PROD1 RPEQPI PULD P Lay down BHA#2, Pilot hole bi center test 09:24 10:24 1.00 0 0 PROD1 RPEQPI CIRC P Make up nozzle and jet stack, during stack jetting swabs are closed with tangos open WHP climbed to 630 PSI. Opened up to tiger tank and bled off WHP. Shut back in and pressure began to rise 10:24 10:36 0.20 0 5 PROD1 RPEQP1PULD P Pop off well to double check torque on nozzle, stab on injector 10:36 13:00 2.40 5 8,274 PROD1 RPEQPI TRIP P RIH with Nozzle to kill well 13:00 14:30 1.50 8,274 14 PROD1 RPEQP1TRIP P Trip out pumping 12PPG completion fluid 14:30 15:06 0.60 14 0 PROD1 RPEQPI OWFF P At surface, PJSM, 30 Min no flow, LD BHA#3 15:06 15:18 0.20 0 0 PROD1 RPEQPI PULD P LD BHA#3 Nozzle 15:18 15:36 0.30 0 0 PROD1 RPEQPI PULD P PJSM, P/U HES Caliper, Suspend job and shut master for welding project in pitts 15:36 16:06 0.50 0 25 PROD1 RPEQP1PULD P PJSM, M/U coil to caliper stab on well with master shut. Stabbed on for master opening 16:06 16:12 0.10 25 33 PROD1 RPEQPI TRIP P Trip in hole, tag upon master valve, command given to open, confirmation not received. Lost communication with tool 16:12 17:00 0.80 33 0 PROD1 RPEQPI PULD T PUH and unstab, Caliper parted at knuckle joint.Vac stack out and see caliper at swab valve level 17:00 18:30 1.50 0 0 PROD1 RPEQPI FISH T Group huddle to indentify time line and operational errors, Formulate plan forward. Make notifications 18:30 21:00 2.50 0 0 PROD1 RPEQPI FISH T PJSM, nipple down BOP stack from upper swab to check for tool,tool seemed to be bound up in lower combi cavity, Change of scope, PJSM, remove BOP lower 2"ram doors, Cut centrilizer with sawsaw, hook up steel cable to fish from rig floor, pull to surface. inspection showed that all was returned except one 1/4"keeper from end of bow spring. 21:00 23:00 2.00 0 0 PROD1 RPEQPI FISH T PJSM, nipple up stack, inspect and install lower combi's, install doors, fluid pac stack and surface lines for testing Combi rams 23:00 00:00 1.00 0 0 PROD1 RPEQPI BOPE T Test lower 2"combi's 250 psi low/ 4300 psi high J5/25/2015 RIH, caliper cement pilot hole, crossover broke leaving caliper in hole, RU SL- fish caliper, RU SL attemp dummy WS down to 8355', RD SL, RU and RIH w/coil and dummy WS,tie into the K1 00:00 00:45 0.75 0 0 PROD1 RPEQP1PULD T Finish testing lower 2-3/8"combi's, RD testing equipment. �____ _________ Page 3 of 9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:45 01:45 1.00 0 0 PROD1 RPEQP1PULD T PJSM,with Haliburton a-line.for making up caliper to calibrate.Then make up tools to BHI upper quick. 01:45 02:00 0.25 0 26 PROD1 RPEQP1PULD T MU caliper tools in hole,stab INJH "`*"*Note: 10 hrs downtime for Nabors damaged caliper 02:00 05:06 3.10 26 8,228 PROD1 RPEQP1TRIP P RIH with caliper at 60 fpm 05:06 05:30 0.40 8,228 8,226 PROD1 RPEQP1DLOG P Tie into flag for-1.4', Log GR tie in with HAL GR log for-1'correction 05:30 05:42 0.20 8,226 8,502 PROD1 RPEQP1TRIP P RIH to log cement pilot hole 05:42 05:54 0.20 8,502 8,250 PROD1 RPEQP1 DLOG P Caliper cement pilot hole, 8502 to 8250 05:54 06:00 0.10 8,250 8,502 PROD1 RPEQP1TRIP P Close fingers, RIH to make second pass 06:00 06:12 0.20 8,502 8,246 PROD1 RPEQPI DLOG P Make second caliper pass 8502 to 8246, Close fingers 06:12 07:36 1.40 8,246 31 PROD1 RPEQP1TRIP P POOH 07:36 08:06 0.50 31 31 PROD1 RPEQP1 OWFF P At surface,30 Min flow check, PJSM to lay down caliper 08:06 08:30 0.40 31 0 PROD1 RPEQP1PULD P Break off injector,caliper tool not on. Camera adapter failed 08:30 11:30 3.00 0 0 PROD1 RPEQP1WAIT T Make notifications, Plan forward to rig up slick line to fish caliper 11:30 12:00 0.50 0 0 PROD1 RPEQP1SFTY T PJSM with HAL S/L Rig up to fish caliper 12:00 15:00 3.00 0 0 PROD1 RPEQP1PULD T Rig up slick line 15:00 17:06 2.10 0 0 PROD1 RPEQP1TRIP T RIH with slick line 17:06 17:36 0.50 0 0 PROD1 RPEQP1PULD T At surface with fish, LD tools 17:36 18:21 0.75 0 0 PROD1 RPEQP1PULD P MU Dummy WS on Haliburton slick line, 18:21 20:21 2.00 0 0 PROD1 RPEQP1TRIP P RIH, set down at 8355'SLMD, jarred down 2 times, PU 1k heavy, POOH 20:21 21:21 1.00 0 0 PROD1 RPEQPI PULD P RD slickline 21:21 21:36 0.25 0 0 PROD1 RPEQPI SFTY P PJSM for MU dummy WS to coil. 21:36 22:21 0.75 0 71 PROD1 RPEQP1 PULD P MU, BHI tools and dummy WS. 22:21 23:51 1.50 71 8,295 PROD1 RPEQP1TRIP P RIH,with coil 23:51 00:00 0.15 8,295 8,295 PROD1 RPEQPI DLOG P 8295',tie into the K1 marker no correction of 0.0 ft 35/26/2015 LD BHA#6, P/U BHA#7,set whipstock @ 8,455'. POOH for milling assembly. LD BHA#7, P/U BHA#8. Mill exit window @ 8,457'to 8,463', mill rathole to 8,478', back ream window,window clean. Start OOH, in progress. 00:00 00:45 0.75 8,295 8,485 PROD1 RPEQP1TRIP P Continue RIH with dummy down to 8485', 00:45 02:03 1.30 8,485 71 PROD1 RPEQP1TRIP P POOH 02:03 02:33 0.50 71 0 PROD1 RPEQPI PULD P PJSM, check well for flow, LD dummy WS 02:33 03:18 0.75 0 74 PROD1 RPEQPI PULD P MU BOT WS setting tools L 019 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:18 05:30 2.20 74 8,295 PROD1 RPEQPi TRIP P RIH with Open hole anchored WS EDC Open 05:30 05:36 0.10 8,295 8,305 PROD1 RPEQPI DLOG P Log tie in for-1, PUW=31K, Shut EDC 05:36 06:00 0.40 8,305 8,465 PROD1 RPEQP1TRIP P Continue in with whipstock, Slight stacking 1200-1500LBS DHWOB, Get to setting depth, Orient to 5° LOHS, See tool shift @ 3800, Set down 2K after set,TOWS=8455 06:00 07:36 1.60 8,465 74 PROD1 RPEQP1TRIP P Trip out after setting whipstock 07:36 08:06 0.50 74 74 PROD1 RPEQPI OWFF P On surface, 30 min flow check, PJSM lay down BHA#7 08:06 09:00 0.90 74 0 PROD1 RPEQPI PULD P Break off injector and reconfig BHA 09:00 09:18 0.30 0 73 PROD1 WHPST PULD P Make up injector to BHA#8 with.6° motor,2.80"DSM and 2.79"string reamer 09:18 10:54 1.60 73 8,295 PROD1 WHPST TRIP P RIH EDC open 10:54 11:00 0.10 8,295 8,322 PROD1 WHPST DLOG P Log K1 for no correction 11:00 12:12 1.20 8,322 8,318 PROD1 WHPST CIRC P Roll well to 9.3PPG used milling fluid, close EDC 12:12 12:48 0.60 8,318 8,457 PROD1 WHPST TRIP P RIH and dry tag TOWS @ 8457, 12:48 13:48 1.00 8,457 8,457 PROD1 WHPST WPST P Start milling window following revised procedure, 1.41 BPM @ 3270 PSI FS, BHP=3685. Did not stall contacting whipstock @ 10 FPH call pinch point @ 8456.9' 13:48 14:48 1.00 8,457 8,458 PROD1 WHPST WPST P Made one foot, Increase Diff pressure and WOB per procedure, Good metal on ditch magnets 14:48 18:39 3.85 8,458 8,462 PROD1 WHPST WPST P Continue as per well plan @ 1 fph, good metal in return, mill off casing, not much WOB. 18:39 22:27 3.80 8,462 8,478 PROD1 WHPST WPST P Mill @ 2-3 fph,dress BOW with string mill,good pressure and WOB, continue milling @ 6 fph to rathole TD. 22:27 23:27 1.00 8,478 8,478 PROD1 WHPST REAM P Make several back reaming passes @ 5L, 35L, and 25R. Dry drift window,window clean. 23:27 00:00 0.55 8,478 8,300 PROD1 WHPST TRIP P Start OOH,saw small overpull @ 8,415'. RBIH with no issue,continue OOH. J5/27/2015 Trouble getting high bend motor through tree, able to free BHA. RIH w/nozzle to 8,440', POOH laying KWF. LD BHA#9, MU BHA#10, displace fluid to used mud system,drill build section from 8,477'to EOB @ 8,556',displace back to KWF. POOH, LD BHA#10, PU BHA#11. RIH w/drilling assembly, displace fluid to new mud system. Start drilling A lateral from 8,556'to 8,640',drilling in progress. 00:00 01:00 1.00 8,300 77 PROD1 WHPST TRIP P Continue OOH with BHA#8 01:00 02:30 1.50 77 0 PROD1 WHPST PULD P PJSM. PUD BHA#8 Page5of9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 04:30 2.00 0 76 PROD1 DRILL PULD T PJSM. PD BHA#9, made several attempts get 2.3 AKO motor through tree, all the normal tricks, unable to move BHA, can not close master. Call town, prep to bullhead KWF annulus. 04:30 05:30 1.00 76 0 PROD1 DRILL PULD T Got tool free. Pull into PDL, Bleed off and inspect 05:30 07:30 2.00 15 8,440 PROD1 DRILL TRIP T Tool look good, M/U BHA#9 Nozzle trip in to displace to 12.0PPG completion fluid 07:30 09:12 1.70 8,440 14 PROD1 DRILL TRIP T POOH on 12 PPG Fluid 09:12 09:48 0.60 14 14 PROD1 DRILL OWFF T At surface,30 Min flow check, PJSM to P/U Build section BHA in PDL 09:48 10:42 0.90 14 63 PROD1 DRILL PULD P Unstab injector and break off nozzle. Run BHA#10 in well. Inspect motor/ AKO setting,All good, M/U to coil and surface test. 10:42 12:54 2.20 63 8,285 PROD1 DRILL TRIP P Trip in hole with BHA#10,2.3°AKO and RR Hughes bi center 12:54 13:00 0.10 8,285 8,314 PROD1 DRILL DLOG P Log K1 for-1.5'correction 13:00 13:36 0.60 8,314 8,422 PROD1 DRILL CIRC P Trip to 8420 and circulate well to 9.3PPG used flo pro 13:36 13:54 0.30 8,422 8,477 PROD1 DRILL TRIP P Close EDC and trip in to drill, Clean pass through window 13:54 14:54 1.00 8,477 8,557 PROD1 DRILL DRLG P 8477', Drill ahead, 1.41 BPM ©3300 PSI FS, BHP=3705 14:54 17:12 2.30 8,557 73 PROD1 DRILL TRIP P Call EOB, PUW=31K, PUH to 8315 open EDC and swap well to 12PPG fluid 17:12 17:42 0.50 73 73 PROD1 DRILL OWFF P At surface,start 30 Min no flo check 17:42 19:27 1.75 73 73 PROD1 DRILL PULD P PJSM. LD BHA#10, motor AKO 2.3. PJSM. PU/MU BHA#11. 19:27 22:27 3.00 73 8,557 PROD1 DRILL TRIP P RIH w/lateral drilling assembly,while displace well over to new mud system 9.3 ppg Pow Vis. No correction at K1 marker, log RA tag ©8,464', continue in hole. 22:27 23:36 1.15 8,557 8,640 PROD1 DRILL DRLG P BOBD: 1.42 bpm @ 3,150 psi, BHP=3,610 psi, CTW=8.5K, WOB=2.3K, ROP=80. 23:36 00:00 0.40 8,640 8,470 PROD1 DRILL DLOG P Trip for Mad pass, Mad pass @ 6 fpm. Start back in hole. 35/28/2015 Complete mad pass, continue drilling A lateral from 8,640'to TD @ 9,940'.Wiper trip to swab at max rate. RBIH for corrected TD @ 9,940'.Start OOH laying in beaded liner pill. 00:00 00:09 0.15 8,470 8,640 PROD1 DRILL DLOG P Complete mad pass, RBIH. 00:09 02:24 2.25 8,640 8,890 PROD1 DRILL DRLG P BOBD: 1.52 bpm @ 3,480 psi, BHP=3,740 psi, CTW=8.2K, WOB=1.6K, ROP=120. 02:24 02:39 0.25 8,890 8,890 PROD1 DRILL WPRT P Wiper to window, PUW=27K, RBIH. 02:39 05:36 2.95 8,890 9,140 PROD1 DRILL DRLG P BOBD: 1.45 bpm @ 3,420 psi, BHP=3,710 psi, CTW=7.2K, WOB=2.4K, ROP=115. Found fault @ 9,125',slowed progress. Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:36 06:12 0.60 9,140 9,140 PROD1 DRILL WPRT P Wiper trip to 8480, PUW=29K 06:12 12:54 6.70 9,140 9,440 PROD1 DRILL DRLG P 9140', Drill, 1.4 BPM @ 3025 PSI FS, BHP=3710 12:54 13:54 1.00 9,440 9,440 PROD1 DRILL WPRT P 9440 Wiper to window with tie in, PUW=29K,Tie in to RA marker for +2'correction. 13:54 17:00 3.10 9,440 9,740 PROD1 DRILL DRLG P 9440', Drill ahead, 1.45BPM @ 3060 PSI FS, BHP=3830 17:00 17:54 0.90 9,740 9,740 PROD1 DRILL WPRT P 9740 Wiper trip to 8940. PUW=30K 17:54 19:48 1.90 9,740 9,940 PROD1 DRILL DRLG P BOBD: 1.43 BPM @ 3,320 PSI, BHP=3,785 PSI, CTW=7.5K, WOB=2.8K, ROP=105. Called TD @ 9,940'. Pump 10 bbl to/hi vis sweeps. 19:48 21:48 2.00 9,940 76 PROD1 DRILL WPRT P Chase sweeps to swab at max rate, tag up, reset depth. 21:48 23:51 2.05 76 9,440 PROD1 DRILL DLOG P RBIH for corrected TD,tie-in to K1 for -1'correction, continue in hole,tag TD @ 9,440'. 23:51 00:00 0.15 9,440 9,420 PROD1 DRILL CIRC P POOH laying in beaded liner pill. 05/29/2015 POOH laying in completion fluid. LD BHA#11. MU A liner assemby. RIH w/BHA#12, release from liner© 9,940',TOL @ 8,439'. POOH. LD BHA#12. Function test BOP. MU BHA#13. RIH w/drilling assembly, dry tag billet @ 8,439'. Kick-off billet, drill ahead AL1 lateral, drilling in progress. 00:00 02:15 2.25 9,420 83 PROD1 DRILL CIRC P Continue OOH, laying in beaded liner pill/completion fluid. Paint EOP flags @ 8,600'and 7,200'. 02:15 02:45 0.50 83 83 PROD1 DRILL OWFF P Monitor well for flow. 02:45 03:45 1.00 0 0 PROD1 DRILL PULD P PJSM. LD BHA#11. Prep rig floor to run liner. 03:45 06:15 2.50 0 1,185 COMPZ CASING PUTB P PJSM. PU/MU A lateral liner assembly: Bull nose, 36 jts slotted, two solid pups, anchored billet. MU BHA#13. 06:15 07:51 1.60 1,185 8,366 COMPZ CASING RUNL P RIH w/BHA#12 Liner assembly 07:51 07:57 0.10 8,366 8,363 COMPZ CASING DLOG P Tie into upper pipe flag @ 7200 EOP for-3" 07:57 08:51 0.90 8,363 9,940 COMPZ CASING RUNL P Weight check 30K, Close EDC, Trip in hole. Clean pass through window and trip to bottom ©9940 08:51 08:57 0.10 9,940 9,475 COMPZ CASING RUNL P Tag up @ 9940, PUW=32.5K,set back down oriented to 150R, Pumps on see tool shift @ 4100PSI 08:57 10:33 1.60 9,475 71 COMPZ CASING TRIP P PUH to 9475 take liner length out of counters, 8374',Trip out 10:33 11:09 0.60 71 71 COMPZ CASING OWFF P At surface, 30 min flow check 11:09 11:39 0.50 71 0 COMPZ CASING PULD P Break off injector, Lay down liner running tools 11:39 12:09 0.50 0 0 PROD2 DRILL BOPE P Vac out stack and perform BOPE function test Page oir0 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:09 13:15 1.10 0 72 PROD2 DRILL PULD P M/U BHA#13, Drill by AL1 lateral with.8°AKO motor and RR Bi Center. Change out pack offs. Change out floats in UQC, service floats in lower FVS. Stab on injector and surface test 13:15 14:45 1.50 72 8,305 PROD2 DRILL TRIP P RIH, EDC open 14:45 15:45 1.00 8,305 8,320 PROD2 DRILL DLOG P Log K1 for-1'correction 15:45 16:09 0.40 8,320 8,350 PROD2 STK CIRC P RIH to 8350 and displace 12.0 to 9.3 PPG fluid 16:09 16:15 0.10 8,350 8,839 PROD2 STK TRIP P Trip in and dry tag liner top billet @8839 • 16:15 17:09 0.90 8,839 8,840 PROD2 STK KOST P Mill off liner top billet, 1.53 BPM @ 3200 PSI FS, BHP=3745,TF=180° 17:09 17:48 0.65 8,840 8,842 PROD2 STK KOST P Milled 1'speed up to 2 FPH, WOB=1.35,Aluminum in samples 17:48 22:03 4.25 8,842 9,090 PROD2 DRILL DRLG P Drill ahead: 1.54 BPM @ 3,545 PSI, BHP=3,790 PSI, CTW=9K, WOB=1.8K, ROP=35. PUH for dry drift, clean both directions. Continue drilling, start pumping new mud system, new mud around©9,027'. 22:03 22:48 0.75 9,090 9,090 PROD2 DRILL WPRT P Wiper to window, PUW=29K, RBIH. 22:48 00:00 1.20 9,090 9,139 PROD2 DRILL DRLG P Drill ahead: 1.51 BPM @ 3,480 PSI, BHP=3,830 PSI, CTW=7.8K, WOB=1.65K, ROP=35. 05/30/2015 Drill ahead AL1 lateral from 9,139'to called TD @ 9,940'. Pumped sweeps, chase to swab. RBIH for corrected TD @ 9,940'. POOH laying in liner pill/completion fluid. LD BHA#13. Prep rig floor for liner run. 00:00 03:45 3.75 9,139 9,340 PROD2 DRILL DRLG P Drill ahead: 1.51 BPM @ 3,560 PSI, BHP=3,840 PSI, CTW=7.5K, WOB=1.95K, ROP=50. 03:45 04:30 0.75 9,340 9,340 PROD2 DRILL WPRT P Wiper to window, PUW=29K, RBIH. 04:30 07:54 3.40 9,340 9,640 PROD2 DRILL DRLG P Drill ahead: 1.50 BPM @ 3,650 PSI, BHP=3,825 PSI, CTW=8.5K, WOB=1.45K, ROP=75. 07:54 08:54 1.00 9,640 9,640 PROD2 DRILL WPRT P 9640, Wiper trip to window with tie in for+1.5'correction, PUW=30K, Clean trip up and down 08:54 13:12 4.30 9,640 9,877 PROD2 DRILL DRLG P 9640', Drill, 1.5 BPM @ 3385PSI FS, BHP=3875 13:12 13:18 0.10 9,877 9,877 PROD2 DRILL WPRT P BHA Wiper, PUW=29K 13:18 14:12 0.90 9,877 9,940 PROD2 DRILL DRLG P 9877', Drill 1.5 BPM @ 3358 PSI FS, BHP=3885 14:12 16:30 2.30 9,940 72 PROD2 DRILL WPRT P 9940', Call TD'Pump 10 X 10 • sweeps, Chase to swab, PUW=29K 16:30 18:27 1.95 72 72 PROD2 DRILL WPRT P Tag up and reset counters. 18:27 19:51 1.40 72 9,940 PROD2 DRILL DLOG P RBIH,tie-in to K1, no correction.Tag corrected TD©9,940'. 19:51 22:39 2.80 9,940 72 PROD2 DRILL CIRC P Pump beads, POOH laying in liner pill/completion fluids. Paint EOP flags @ 8,200'&6,700',continue 00H. 22:39 23:09 0.50 72 72 PROD2 DRILL OWFF P Monitor well for flow, no flow. ._.__.._.._ Pa -,8car Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:09 00:00 0.85 72 0 PROD2 DRILL PULD P PJSM. LD BHA#13. Prep floor for liner run. 05/31/2015 Run AU liner assembly to 9,940', release from liner,TOL @ 8,362'. Circulate well to seawater,freeze protect with diesel from 2,500'. PUD BHA#14, Set BPV. Inhibit/Flush/blow down coil. Cut 2,500'of coil. ND BOP stack. 00:00 00:45 0.75 0 0 COMPZ CASING PUTB P Finish rig floor prep. PJSM. 00:45 04:48 4.05 0 1,622 COMPZ CASING PUTB P MU AL1 liner assembly: bull nose, 51 jts slotted, 3 solid pups,shorty deployment sleeve. MU BHA#14. 04:48 06:06 1.30 1,622 8,324 COMPZ CASING RUNL P RIH w/AL1 liner assembly,tie-in for 06:06 06:12 0.10 8,324 8,321 COMPZ CASING DLOG P Tie into flag for-.3, PUW=30K, DHWOB=-5K 06:12 06:54 0.70 8,321 9,940 COMPZ CASING RUNL P Continue in with AL-1 Liner, Tag bottom @ 9940, PUW=30K, DHWOB=-1.5K Pumps on 1.3 BPM ©4100 PSI, PUH, PUW=27K, DHWOB=3.4K 06:54 07:30 0.60 9,940 8,350 COMPZ CASING DISP P PUH to 9928, Subtract liner length, 8350, Start seawater down coil 07:30 10:06 2.60 8,350 8,350 COMPZ CASING FRZP P Trip out, Lay in Diesel from 2500' 10:06 11:30 1.40 8,350 0 COMPZ CASING PULD P PJSM.Tag up and space out, PUD BHA#14 11:30 13:12 1.70 0 0 DEMOB WHDBO MPSP P PJSM, Set BPV 13:12 15:00 1.80 0 0 DEMOB WHDBO RURD P Pump flush, inhibitor,amd flush through CT 15:00 16:00 1.00 0 0 DEMOB WHDBO RURD P PJSM, R/U and blow down coil string. Bleed off 16:00 22:30 6.50 0 0 DEMOB WHDBO CTOP P PJSM, R/U to trim 2500'CT and discard, prep floor for move. 22:30 00:00 1.50 0 0 DEMOB WHDBO NUND P PJSM. Start ND BOP stack/cellar., RIG Release Midnight Pao 9 or 9 II 2G-14 PRE AND POST RIG WELL WORK SUMMARY DATE SUMMARY POST RIG WELL WORK 6/5/2015 (STANDBY FOR VALVE CREW TO PULL BPV) MAKE SEVERAL MAGNET RUNS TO LINER TOP @ 8362' RKB; MEASURED BHP © 8362' RKB (3634 PSI) IN PROGRESS. 6/6/2015 SET CATCHER ON LINER TOP @ 8362' RKB; PULLED DV'S @ 4420' &2104' RKB; SET OV© 4420' RKB & GLV @ 2104' RKB (GOOD IA DDT); PULLED CATCHER @ 8362' RKB. JOB COMPLETE. • W Igo`W; szN a c i RS O - O. CU 0 CD Q W ce F— A in Z cu_ . = t .... • = E , co ,,1cle., V O °- r = > c; C 0 Y _c J z.-,i- E N O c V O a a - c C6 V Y Y N 2 CO 0 0 CO IP "Omz a VS _ p 3 �W� 6 O L Q1 8` - in C a� L. (0 Ci O O O g O ` a CO C C In 7 L LO N M 0) r id W Ci') (sn Q ) l.c.. a. 0 C O °) (I V ; O d In iA li,▪ — N Z o c, 0 c, N N N N Nw M N s ii 1 N (n .- ( N gg 'd8 J I O 2 u co 7 1' C O d J J (.9 C a O a m - _ ii z Cr) V .- .- 03 U Y ! ?1 b F U © © q m co , P, W 2 O C7 ca m N- ct E a a w + O C -0 ? d C O d 1 C 0I > N N H 2 wW d U O u) u) w a T'a) d U 7 3I a) 7 > > J CC a) 0 0 = a) U — a O ' o u) 2 N a? I a. d (') > tP to (A a CCV. (6 M CO- 41. 0 O >, r y 2 » rn m • m CO o 2 ,r) � `.. O N CC C d a. C V G)4) 'O C d 0' C71 to (°>> c ° w a. o wd E w + Vw C a 0.d Vd ; T N O pad •C d 9 'idE (n10 0 � C a c coN & o� O A z . 2 Z co ' d + V i= $ U C En H ( 2 2 m c rn y , y d Z W r N T [ CO (0a) I (6 to 0 _ U N C. O C EN IL < pN ULo 8� � Q �' O O d V' (7 7 ' u) U co N co d O W O N 6 N Y Z 7 7 7 LL „7. Jp O b d L N OO # -aI i dZ OO OV. V VC d• Z▪ O L a r i a 7 U CD CD W 0 Cl) N N N :-.L.' Q- C a > 46 Z 4.. O E v _ O- Zr. a a a .- 0 J M O J - d N N Z N < O O V L 'a. N 7 N (A N V h V V O a .- Z O la O 2 N V V d' Y u) Q N N + W N r° m (Ni 0 7 V W (n (l a Z Q m co rn O 7 7 >s^ UYYNNN C i c 6 O R I a. cD N UU .CC C H U E, o 40 d d O O O d L C .. i y ? C .� 7 i U O N a E O O O N co CD LO a N .. _a D7 ... fn 0 N a C Of ? U W li 3 0 m U E m = — 'w Q- O a = = w — n o C c0 CO o i CC d R d d O d C d 3 d d 7 N O d d O 0 a` 0) 3 3 0 a 2 (7 2 3 3 a 3 5 o a > > , u) a co W0 II 0 o m La C U) U) RI a o Q r= Y g a 0) P E R Z O F T N M M M M M M M M M M M M M M M M M M Cl M M M M M M M M M M 0) CO X222 22222 22222 22222 22222 22222 2 0 °N34 M r (0 0) r r M S S f^O N U) S r N V C) W N 00) 8 N- r N 3 N 0) N 0 0) I 17, s ,...: 6 0 (O UV C) N 6 O 6 C) 6 O 0 6 OOG O O O OO 0) D 7 U F r r S S D S NS S S O O C) WN N N M M M V V 0V aa 0 y "U) UUUUUUUUO co- (O co- (O co- O O 0 O O co- O O O co- O O co- O ON N X (0 0) N 3 3 'O — 0 ',-). ) C- 7 N. M U) (p 0 M T U) 0 M - N M O 0 N O O .a C n r 0 0 N N W 0 0 M 0 7 7 41 0 h N S O O N O R 7. 7. M U) d 0 O Z UJ J O Ol CO V 6� (V (O O O O) O O CD O CO 4) O (V C] (`! 01 'V' CO "e0 ' N V Y 03 N 7 7 Q M CO 0 M 7 0 N N 7 7 0 0) 7 N. LilN CO N 0 M N 0 CO 0 O E 2 6 N U) (D 0 Cl 0 N. N co (Op M (hp fQ� co. d1 N N CO (yW0 R V M O (O 1� 00 C7 C(I O O . , (0 4 N 71 S 000 P (m0 (NO 10 (0 Q R Q V 17'4 97 R R M M a (M+) M (O+) N N N N .) N N F- i W O_C 0 N 0 h 0 0 (q 0 7 7 7 7 7 7 7 ms -7 7 U) U) g g g g g g g g g g g g U) U) U) U) U) U) U) U) U) 2 8 U) N O O O O l2 ,,3 -8 ,98 ,2 U) N U) U) N U) 0 0 N N 0 U) N 0 0 N 0 0 a 0) a) U ip 7 N (O 0 Cr) CO M N 7 N 0 N CO N 0) r CO 00 0 (O U) M V 0) sl. 0) M U) C 0 (0 r` 0 N 0) N Q 0 n O N M M r.... 5- 5- 00 O N l0 N 0 00 5- N M N N. i r 07 r N 0 N C- M C- O 6 U) 6 f.: m m 00 d) O M 0 7 0 M 0 7 O 7 0 m O 0 U) M O 0 U) M O N 7 0 U) N 0) N. 7 OD U) N 0 N. N CO O N. U) w d _ 0 0 0 0 Q1 0) 0) 0 CO 0 C` N. C` r (O 0 0 CO U) N U) Cl) 7 7 7 m 2 n3 L co O0M M N M 0 M 0 M CO 0 0 0 2 0 M 0 cc C ro `_0 0 2 O0 N O 2 M M O 0 0) 0 6 0 0 OSi 6 0 0 2 M M M co- 0) M D O z () N co- UU) U) U) UUUN 1.6 UUU) N UUUUUUUco- co- U) UUUU W N d - N M dC) a C U m . la _ m O U) N w N 4 C O w w Cl U N 0 0 0 O O O O) N.0 0) 0 M 0) 7 Oh- V. 00 h CO N. CO 0 CC 0) 7 7 CO CO 0 N M 0 4---- U .H4 M N. 0 7 0 0 .- M U) h I� N M M 0 0 ¢) M M 0 7 0 M N O O M O CO 0 O _ " M 0 < 0 0 ' 0 6 O N N 7 0 8 0 (7 N A M MQ 0 z° n(CO w v t 'Ti' ? 't 'Ti' Y t v i' 'Ti' Y 'T 'T 'T 'T v V 'T 'T Y ? Y g Y Y Y r. N i 7 N O) 7 M C0 0 0 0 0 N M 7 N 0 0 7 U) 0) CO Q) 0 CO U) CO 7 O CO N N r 0) 0 7 CO CO 0 U) N. 0 O 0 CO N 1` O N 0 0) 0 iO 0 N 7 0'- _ CM (a 4 N (V 1� M O R) (0(p M C•1 N CJ p• Ci 6) 1- (O (V N- U) O U) CJ Oi • �' (CO FN.-42 M M M C V V V N 7 U) S (NO ((O S C• r N. N. a0 m S S ON) V▪ v 4 Y V Y Y Y i v Y v v V Y Y Y v i 4 Y y V v Y Y Y Y Y Y O N CD 5- N CO S COOS R 0 (N n OO (MO CO CO 0) . 00) n V V N5- 5- 00 n 0) - - M U O 6 U) 0) (M co O Os- (Y M U7 N.: OG 6 N.: r--: f: 1: 1: co Oi 6 0) OD r--: 1: (O4 0 N 6) 60) 00) 00) OM) S 00 O O 0000000000 0000000000 O z N U) U) U) U) 0 0 0 co- 0 (O 0 (O 0 (O (O 0 0 (O 0 (O co- 0 0 0 0 (is 0 0 0 N 0 O O U) N OD 0 M 0 O N 7 M M ((pp 0 0 7 CO C- C` 0 N O O M a O N 0 5- N M 0) 0 0) V 0 U) N. CO 0 co 0 7 U) m r 7 7 .- N- 0) 5- 5- M Y 0 E O O U) Oi C) (O 0) O (V C) U) I- 0 m n C` h C- (- 0 0) 0) 0) 0 1- 1` N V M_ _M C') M_ M_ 7 7 7 U) U) U) U) U) ^ U) U) U) ^ ^ U) U) U) b N_ U) U) U) N_ U) U) 6 .y3.. 0 0 0 0 U) (O U) 0 0 (O (O N N (O (O t0 (O 0 0 0 U) (O (O (0 (O (O ,Ti. (O (O (O C -Ci 6 u 5 W ) M 7 7 U) M N O O 0 0) 0) N O 7 f0 1- O O co co 1- O) O U) CO 0 0 " X W M M W 0 P M M O 0 O) N p 0 0 M 0 N 8 W 0 N O 0 N 0 M .- M Q -, E _ U) 4 V 4 U) O n Ui 6 OD Ui 6 O m 000 S co S O 4 O 4 r U) 6 O O O S g D. d Q N N N N 010.18C91 N 0 0 0 N N N N N N N N N N N N j V1 -C OE N 1 O- C CO 7 77 7.4- CO U ^ V M 3 M S M (� (0O 7 r S N a8D " N N 0 S 0 8 OOD sr N (N+) n M V M • (� 0 0 N N N C :••- S S 07D ONO OD OND S m 000 S S 000 000 S 00) S W OO) S W S 000 m 0) 00) O) 0) 0) N OM) a a o, O O O N CO 7 N N el N 6 0 O 7 r-- N O 0 0 N CO N N CO O 0) O N V 0 O 0 0 7 CO O U) O O N N 7 7 M 7 7 7 7 7 U) U) 0 U) U) 0 0 QS O � O O) O 6 O O O O po O O6 C Ci O O O O O U) V) U) U) U) U) U) U) U) 0 d' �-' N M N- O M 0 m N N CO N. S CO CO CO N U) CO 7 N. 0 M 0 0) N U) O1 n( C• . ` D N 0 0 0 O) O) 0) 0) O O O 5- N N N N M M M 7 7 7 U) U) U) U) 0 0 0 . (O fl y O E >. m E 0.. 0 0 m OD a0 N co- Oi 0) Oi Oi Oi O) 0) 6) 6) 0) O) 0) Oi O) O) O) 0) 0i O) 0 0i 0) 0) U) U .. - T EO N N w N O O 0 o co 11 N o IM 'Cs W meg_ Ci C CO O CO 0 4 Ii g C 0 Q U d E 0 m 1- z O O ❑ O W I- I- >N NMO MO (S Coo CO CO CO CO W CC 0 O O O N N Co 0 (0 0 0 O 0 0 N Co N 'C V Cl coo N <`',3 (0) r r W W N . E y ""N N co- (O co- co- (D co N• N > u X 0 N N Cl) 7 J c .. M O 2 M r Cl Co O O O 7 O O Z U) J O (!i - 6i W O 0 ci(7 v j N N V V Q Co, co 0 co co Co N CO > 7 7 0 M ,- (O V N V nl > N N F W G C N N N 0 CO N SO 2 w —O 0 0 O O O O O W .141 U1 lD Ln lD 0 Q N CC N c N V 0sr co 0) 0) N CO. 0 7' w d C M M Co 0 N N Co 0) N N 2 .3 .c ,e+ co co- coN cocoN N rec .g C) N N M C) N M 2m d ii O z co- cN (D (o co- N N coi O N ` d i0 0(z_ w C O w d U a 0 M CO 0 CO m N. T m 0 R 0 - L N 2 ... M M V ',Ti- Co V V O >> 2 O 7 (Cl W 3 v v v v v c v v J F- z COO + O LU Co 0) N CO 0 (n O N (o CO N V 0 O N o N 7k'_ C) (O of N 0 0 O O O O O� Z 2 Y Y `? .ii LU ui vi (n mSOLLoo o LU CO N N V Q N O O O O 0 0 0 0 V 0 N (D N N N co- N N 2NV M° D M ( W M d Y >>> ir3 o CO CO LU co LU U U ~ 7 (0 '-co- co c0 c0 cD co CO c (u N ?c DC N W 4 CO cD Co V V' -CU O c‘i0 0 co O Co O Q O. D d < ..-. N O O N N N N N i .0. N E IX N a. -N Y_ OU .1- V V N N 0 a) V (D 0 (0 (00 N N N C730) ,- ,- C O. °. C ° S U Y Y N N N a rn co m co co m co CO CL O o0 0 o o .NN 0 v 0 cci N O c o LU n n uo 0 • w01 r- r- roromrn NC co 0 w ° T .. .0 m ` o m o o D D co- ac 5-U £ - it; = = 7, co 15050 215051 Waite z5 889 25 890 BAKER PRINT DISTRIBUTION LIST HUGHES Please sign and return one copy of this transmittal form to: COMPANY ConocoPhillips Baker Hughes INTEQ EC E I Y E D (mandatory) 795 East 94th Avenue DATA LOGGED 5 I WELL NAME 2G-14A,12G-14AL1\ Anchorage,Alaska 99515 45 K/‘'t BEN/201DEW UN 0 5 2015 (mandatory) FIELD Kuparuk River Unit to acknowledge receipt of this data. AOGCC (mandatory) COUNTY North Slope Borough LOG TYPE LWD-Coil (mandatory) (mandatory) STATE Alaska BH DISTRICT Alaska (mandatory) (mandatory) LOG DATE: May 29,2015 TODAYS DATE: 4-Jun-16 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: Paula Lacey EMAIL: pauia.lacev(abakerhuohes.com (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? No COMPANY cD FIELD FINAL (digital/image) Final inal ADDRESS f FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS Survey/Logs Surveys PERSON ATTENTION #OF PRINTS #OF PRINTS It OF COPIES #OF PRINTS 4 U U U U U 1 ConocoPhillips Alaska Inc. 1 1 Karen Hipsher/Lynn Hallford NSK 69 700 G Street Anchorage,AK 99510 2 BP Exploration(Alaska)Inc. 1 1 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 'Attn:Analisa Steger 3 Chevron/KRU Rep 1 1 Attn:Glenn Frederick P.O.Box 196247 'Anchorage,AK 99519 4iState of Alaska -AOGCC 1 1 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5DNR-Division of Oil&Gas *** 1 Attn:James Hvun 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR TOTALS FOR THIS PAGE: 0 4 5 0 0 0 TOTALS FOR ALL PAGES: 0 4 5 0 0 0 .......... ....... 15051 ( 15050 15 878 15 877 Letter o Transmittal Milli IFCFIVED BAKE Date: DATA LOGGED U N 0 3 2015 June 2, 2015 6 K%BENDER /2015 HUGHES AOGCC To: From: Makana Bender Yosha Ragbirsingh/Michael Soper AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 2G-14A - ->. 2G-14AL1 1 tt (2) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BakerHughes.com Yosha Ragbirsingh, Baker Hughes, Survey Manager /.(/) / Yosha.Ragbirsingh@BakerHughes.com v ' LC) co O C` LC) op V CNI 0 IP y vz LU 4z, 0 MI x_ ir N a i c co O co a. 0 au — W Ce a I— ,, in Z C) co .. a , - .— a) .E .— .., - (/) I:1. .2 o 0 V O °' a _ >_ 0 4 in O v � Nr � ■— c O Y : N = N 0 = c`c cLa N `^� ^++ _ U O Cl. a r c CZ W U Y Y N 2 m 0 0 0 I in W €g Z w a v `W k o m N O Ci n O o V' 'tl�,. y G.. N M �' U iI_ cn o m o w Ln N 4 v N mm N N N 11 c--.`..1 P7 „ iWfi �s k iii y yIn Ul 01 3 "�r g" � M ...1l> tlN lr -' Ct , RE JJ (D ( =4 `, ' OD 6 6 N N x E' 3 f'�- O O Y O O O C O O O N O O O Ul C ,,ii.:- O 98 E m o P �� o N Q a w ',,,,b,,,,,,;,,, ,�,� .... O -44 N U U U j 'c Q C N ih icy i' ,,Vo,%?--,zap: m t(7) N N F- W N U ( q P�11 o. n J m 7 7 O t1 V m U > > ro T., rn o 1i gi o CC aU° o m °c c M ro c ,,, , 2 n a0 . ❑ $2. c m :..,,,,,i-----=- 1,,,,,, - c ' n. c � UC O m m m � o A', 4:447 z t mcNo Z0 ❑ Oj 1 ' +r 1 ,; Z t J i 2 t I m ? " ooA9 c rn 8 r - �� _ t E m 2 z w 3 ` w N 1-74 co o ( 0 : a O E N = N N n Y O Q s' _ LIQ H ',.,_r 41- ; QI o C U. 7-7 o� oiUQ E o o a N2a N NN o Ndx ` 3 NJa U = . mc O m Y OUi 1 0 O O N a V VVU W U IO O O L Q m r r t0 = D 7 (DC ZNo ' a o NNNN__ O) U YN = ❑.. iii I C O l6 E E v r O Q 7 m J C md d N N t- > -(TJ. co 4"' (n V' mo6 o mvN~ � CO a'NI L dN a ❑ NC7 +Z W , CO `.. ODW m C_ 2V V V S) Q QNN + N C OOC �s i p cms� O O C NS UYNNN VG maO N o 0 O VV j a O a E o m 3 w c m ?yc ° c m m m iNo Wv aDro Nm U) O N °- § En N L ic. m . n y AdACI N N d D ¢ >V p O «' ddd i (7 _ 3 U ao 0 a. 1 r CO o 0 0 LO O a o g c a p OU Q 1- Y k E co z 0 0 T N en M M M M M M co M M M M M M M M M M M M M M M M M M M M M QQ 4 CO co co.Mr co. ON) N- r n coM coc co00o N CO CO coN V O CO N 001 m CO N- N N 01 N r P 8 �Cp g1 p) N 8 CD C CO O U) P') 4 GO 0 pp Of CO V '.. U C u) r O N (O co N CO m O M t0 CO0 V CO C) N N r V 1,‘° g V V fD V m ;C U ^r r 0 0 W co O 01 O) O O 000 O .- .- '- N N N M M V O 77 R N N �(1 th t C) " C 'N CO CO N N N CD V) i0 u) CD CD CD CD f0 CD (D CO CD CD CD CD CD CD CD (O CO CD co-. CO N N CC N fes/) N 3 o o o 3 "OC --- C-O N-C) .r CO r N M W N M M p y W p 0 0 N O M '- N M VO 0 M N O 0 JCm7 (Or0O O . N O CO N coCD (V N N 0 0 0) 0 en 0 O) 0 CO 0) N 0 N CO ^ 0) V COZ V sr 7 mi • cc -,e,„ 6 © @ E Fes I- moktio,6iir— c, V , CC Q rM NO COO COM CO MCD COO r CON CD 1 O O rm rV Or CD NN CD CO NO M• N CO M O O N- >.-6" 7 7 W CO CO cc; CD V O CD N D) N CD (O O C) CO C) = U) 7 N- A N DN 0) co O (r r N O CO r CO CO V V M N 0 CO N. CO M 0 CO r CO V > N N H 2 W d i=+ 0 CO CO p CO CO CO "_ "_ st Q Q V V V' V V M M Co) Co) 01 CO N C') N N A y -V V V V O O O O O 0 0 0 0 0 0 0 .:i sr- 0 O O O O O epi 0 O O sr- 2 'L co N 228 CO u) O N CO CO u) u) u) u) N u) 0 u) u) CO u) N CO CO CI') CO CO CO CO W t 0 a 6 V 'L1 ,„sof g V u) co O M co co N V N O_ N 0 u) O) r co 0 O co co co 0) a 0) M to eL C O 1"" CO N CD N W N V 10 I� O CON M CO M 1,- CD 0 CO CO CC Opp 1� tO N CO U CO N>` d C ONrD r O al pip pCD p000pD CO O pN- n CD pCO pCO CCOp m� 7 CO7 > d 2 N L .O> O) CA CA O) 0) M P0] M P0') en C7 8 8 M 8 M en C07 C07 0 PO0 000 CeO M M CO 8 C00 M x N C _ 'L C OM) N N OM) co C0)) O1 W O) 0) 01 W co O) 0) m rn W W O) W O) 0) O1 0) 0) 0) 0) 0) 0) O Z co' ui u) vi 1ci CO CO ui u) 0 tri vi vi u) ui 0 ui tri CO CO CO (D CO t0 CO ui CO ui t0 CO C C) t0 a) `<!)' C imp > a C C C v -': .kms: - CL - C . V CC _ CO CD CO 0 0 0 CD N- 0 0 M CD V CD N- CO I,- CD CCO.) rN CD CVO CVD VI CCOO CO CONM N .— N C`) r CO V CD co 7 M CO r r N M CO r CO co _ C) CC R r _ CO CD (O M O (O 0 (N CD V N N V. O) 7 O CO {CD f`') O) (`') (O O) 0 CC 0 Q' L N R a+ O 0 0 0 0 0 O— N- e- '- ,- 0 1- CD Cn N N N CO N N N M CI A (88) 8 lbeAti "'T V N N Vr M m V M u) p N M rV N m D NO M OO 0 N 0 V O _ NrONuOICDu (ONV 0) Co V CO N h C7 O CD CD V Ch of N N O O) 1U V co Y n O d D csi O) Cl) _ 0O COO M N0 M M fM M N COV COV CO CO 2 W ON CO D r erCO COr CO M Cm CO N ? ? 4 v Y 4 Y 4 v Y 4 4 Y v Y 4 Y Y 4 Y 4 g Y Y v mih i3 OO O CO ,nO NN M O)D 0O M COO OO CN rV COM CDM MO COO VV COM CO 0Nr f-V CO c.:! r O 0 rO M k. � a) 0NN M 0 O N (D CO � N aD f� h h � � m aO) W CD � r.... CO V 0) CD O CC O) 0 0) O 0 O 0O OO OO O OOO OO O O coo OOOOO O C CO CO O O co- CD CD CO CO (0 (D co' CD CO CO CO (D co- CO co- co- CO CO CO co- co co- CO co- CO •N O N COC- N M O O M O O NCOCO (MM W CO °41 CO CO it R CO N r 01 0 O MO_ C ^ O O co O) /'n co 0) O N n r CC ClD cd n r N. N. N. CD CC Oi 0) N t` y - 1=1 " M M CC M M V V V CO Cn COO CO CCO CO CO CO CO CO CO CO CO CO 0 CO CO 0 0 0 N U v CO CO 0 CO 0 0 0 CO CO 0 0 0 0 0 CO CO 0 0 CO co- co- co. 0 co" co- CO co" co co- co" C CO co N •„ M V V CO M CO O O O) m CDN O V CD (- 0 0 M N 0) 0 CO M 0 -,11Q C 0) M M O) CD r CO M O CO 0) N U) CO CO Co) N N M 0) CO C N O CO N CO CO C" M .O t() V 44 CO O r CO N CD CO M O n O) (7 (D m N 7 N- V N- CO C) O CD C) O N O O O 0) W O M 0 CO O) O) M O O O O O O a a Q .°� N N N N N N N N N N N N N N N N N N N N N j Q. L 12 N �) _ Yl d , , = OOd' V V V N N V Cp W pp Cn pp V N p W W p O O m pp O O pp O V N N Nr N VM 0 Cda ,- C S O Y NNN O ` Cm 0T g CN CCV 0 N N O) O N ON O OMO N O C0 m CDDW Nm mN M CL a O CD COO0 CND p0. CO01 p 00p7 pOp .- CLO Op .- CO pN N CO pOp M pRp V V V CO U)) VN) CDMC0O 0 CO u0') CO O T �^' N C00 O C) CO OI N CO CO ci O N 0 (O') CCD O) N CO COD 0 7 n O m (NO 00) N 5,5 Oi N C C CC 0 fA CO co co 01 O 0 CA O O O N N N (V M M M V V V O O Y) O f0 (D O O CO -;-.' O C T Z C CD co 0 0 CO CO CO 0) m W O) W 0) W co W 01 W 0) CA CA O) CD CP CA O) CP 0) m C) U oo O r d d d 7 f O a u) i 0 u) � ` p a) m gin ' o "hi 0 0) O m 15 a. Q Biu „ c o H Z o O D o 1.- H : Iie T1 M M M co M M Co W i z o �g ,111 . ' ogre - 0) vm O. U 01 co pm� p� pp N p Oi O O) N (() a) (V ems., . U - �'• c.0 (70 ((00 (0 r N- W W Ny —co" (0 c0 co co- f0 t0 (O C7 C7 > a) N X fC 2 2 N > > C m o ((a aa) n r (8+) o 0 0 O 0 eu (CO DI (O CO N 0, CO O B ,_ v m�-\\ b y L. .: V V 7 N co N 7. Q 1- co a7 a) CO 4) N CO E M U) co n (`') 7 j - 0 coan N — co co cc0 Lo • N N H W p,w N N N t aJ O .. 0_ m a) U .a 7 a0 a) N CO CD r 0 IX C d p 0 7 ca) O) N co u) L D C0Or ( • w d C c62) COCM 8 N (N) N+ 0) 2 0, r e co- co c0 m c co cp ( P C 2 p m el rn m co m m CO co co O z ui ..6 vi ui ui ui ui vi • 'O• C U g U $ @ ` C a0 C p w " N u) Ng N- ‘,2 Q. .- V wd O N 0)CO 0) M CO a) N n T N p a U 0 -s i Z (E x M M a 7 a 4 7 '4 • F z ('n o w V ? Y ..,f Y 4 V 4 R i i ) o CO( CO <O Co) (CO (00 v 0 (ten m o (`9) CO m 0 v 0) m o o 0 o 2 2 v v vi .? vi u u? ul CCO m CO() Cr, CO CO c°)D co CD N •• •• .1- N 7 N .u' 0 0 0 0 0 0 0 0 Oj v cO (O (0 (O N co- co- f0 N I� N c0 0) 01 a) CO a c0 aD (O 7 9 m (D (D F Y 0 y Lo a ' 3 C co COvi COtlJ c0 CO(.c CO(o CO CO €}E c N CO C N a0) (No c0 CO 00 V 7 7 Q C _ O N $ 8 O (al V Q cn d 4 L. ON N N N N N N N N 0 a Q N 0 ^ Y Y p (D cp •iii O co co 7 7 7 m 8 N 8 m C 0. 0. co. C. U C °^.. N a) O O) a) W r r co co s U Y Y N N N W m a k a Di uu o 0 0 0 EA V 4 S ^O .. O (O (O u) u) (N O O i 7 C C .. 0 N r r 8 t5 01 a71 Nj Q (a 0 c T C 0) m of of of of of of Q as U 0 o0 „ 0 0 a) o O O U) 0 co 4w�'�\�j/`7-s THE STATE Alaska Oil and Gas ti� ��� o Conservation Commission : _ __• fALASI�:A lift =.�y== 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 04t, Main: 907.279.1 433 ALAS*P.- Fax: 907.276 7542 www aogcc.alaska.gov D. Venhaus CTD Supervising Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2G-14AL1 ConocoPhillips Alaska, Inc. Permit No: 215-051 Surface Location: 243' FNL, 88' FEL, SEC. 6, T1ON, R9E, UM Bottomhole Location: 98' FNL, 444' FWL, SEC. 7, T1ON, R9E, UM Dear Mr. Venhaus: Enclosed is the approved application for permit to redrill the above referenced service well. The permit is for a new wellbore segment of existing well Permit No. 215-050, API No. 50-029- 21161-01-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, /6 / Cathy . Foerster Chair DATED this i3 day of March, 2015. STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 1 2 2015 PERMIT TO DRILL 20 AAC 25.005 ,BOG CC 1a.Type of Work 1 b Proposed Well Class Development-Oil ❑ Service-Winj ❑ Single Zone D. 1c.Specify if well is proposed for: Drill ❑ . Lateral Q Stratigraphic Test❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill ❑ Reentry LI Exploratory ❑ Service-WAG ❑✓ k Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name 5 Bond. • LJ Blanket U Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc.- Bond No. 59-52-180 • KRU 2G-14AL1 • 3 Address 6 Proposed Depth 12. Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 9940'• TVD: 6156'• 4a Location of Well(Governmental Section): 7 Property Designation(Lease Number) Kuparuk River Field - Surface 243'FNL,88'FEL,Sec 6,T1ON, R9E, UM • ADL 25667 • Kupruk River Pool • Top of Productive Horizon 8 Land Use Permit. 13 Approximate Spud Date' 1190'FSL, 1173'FWL, Sec 6,T1ON, R9E, UM 2588 5/7/2015 Total Depth: 9 Acres in Property 14.Distance to 98'FNL,444'FWL,Sec 7,T1ON, R9E, UM 2501 . Nearest Property: 11122 4b Location of Well(State Base Plane Coordinates-NAD 27). 10.KB Elevation above MSL • 140 feet 15.Distance to Nearest Well Open Surface:x- 508610 y- 5943345 Zone- 4 - GL Elevation above MSL . 102 feet to Same Pool: 2K-07,1930' 16.Deviated wells: Kickoff depth: •9150 ft. 17.Maximum Anticipated Pressures in psig(see 20 MC 25 035) Maximum Hole Angle. . 95° deg Downhole:4349 psig • Surface:3820 psig• 18 Casing Program Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 3" 2.375" 4.7# L-80 ST-L 1572' 8368 6043' 9940 6156 slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft) Total Depth ND(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth ND(ft) Junk(measured) 8750 6297 none 8645 6220 none Casing Length Size Cement Volume MD TVD Conductor/Structural 72' 16" 202 sx CS II 110' 110' Surface 3293' 9.625" 1060 PF E,370 sx PF C 3327' 2760' Intermediate Production 8691' 8724' 335 sx CI G, 175 sx PF C 8724' 6278' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 8452-8470, 8490-8532 6081-6094, 6109-6139 20.Attachments: Property Plat D BOP Sketch❑ Drilling Program ❑ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25 050 requirements Q 21 Verbal Approval Commission Representative. Date: '_\\_.\5 22 I hereby certify that the foregoing is true and correct Contact Gary Eller @ 263-4172 Email J.Garv.Eller(o)cop. Printed Name D. V haus Title CTD Supervising Engineer Signature -�yy. 4,-�fk_ Phone 263-4372 Date 3-1 1 - 15 Commission Use Only Permit to Drill API Number. Permit Approva See cover letter Number p2)5-0 51 50-0Q?-a)I (Q I-60 _00 Date. 3 I ') ) Ifor other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed m thane,gas hydrates,or gas contained in shales: d Other:go tCSf- 71-0q3 ❑7 pS; Samples req'd: Yes No [J Mud log req'd: Yes❑ No E f1#11'W lCL r<Ve - /cr 1 -t H2S measures: Yes d No ❑ Directional svy req'd: Yes[,7r No❑ tr 2�f��J5 , / pacing exception req'd: Yes ❑ No [ Inclination-only svy req'd: Yes❑ No RI" e tc w� r1 -55 -c . 117 l 1 y� *<c�l a� i ��� �I SGL kji �� APPROVED BY THE 2 Approved by: MMISSIONER COMMISSION Date 3 —,2-3 —/S— Form /S— Form 10-401 (Re sed 10/2012) T Oe it nl '�4'noilths)from the date of approval(20 AAC 25.005(g)) f k . /i211 - K.2 /�r� //3//5U 1 ` I �1��� ConocoPhillips p RECEIVED Alaska P.O. BOX 100360 MAR 1 2 2015 ANCHORAGE,ALASKA 99510-0360 AOGCC March 10, 2015 Commissioner- State of Alaska Alaska Oil &Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill a dual-lateral out of the Kuparuk Well 2G-14 using the coiled tubing drilling rig, Nabors CDR2-AC. CTD operations are scheduled to begin in May 2015. The objective will be to drill laterals KRU 2G-14A and 2G-14AL1 targeting the Kuparuk A-sand. A separate sundry application is attached to plug the KRU 2G-14 (184-130) perfs to allow these laterals to be drilled. As detailed in the attachments, ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1)to plug the A-sand perfs in 2G-14. Attached to this application are the following documents: — 10-401 Applications for 2G-14A&2G-14AL1 — Detailed Summary of Operations — Directional Plans for 2G-14A&2G-14AL1 — Proposed CTD Schematic — 10-403 Sundry Application to Abandon KRU 2G-14(184-130) — Operations Summary in support of the 10-403 sundry application If you have any questions or require additional information please contact me at 907-263-4172. Sincerely, Gary Eller- ConocoPhillips ConocoPhillips ska Coiled Tubing Drilling Engineer 0. Kuparuk CTD Laterals 111111) 2G-14AL°I NA80N5 ALASKA CDR °°`°'Ph" Application for Permit to Drill Document 2110 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(f)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 4 (Requirements of 20 AAC 25.005(c)(13)) 4 Summary of Operations 4 Pressure Deployment of BHA 5 Liner Running 6 14. Disposal of Drilling Mud and Cuttings 6 (Requirements of 20 AAC 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 6 (Requirements of 20 AAC 25.050(b)) 6 16. Quarter Mile Injection Review (for injection wells only) 7 (Requirements of 20 AAC 25.402) 7 17. Attachments 7 Attachment 1: Directional Plans for 2G-14A&2G-14AL1 7 Attachment 2: Current Well Schematic for 2G-14 7 Attachment 3: Proposed Well Schematic for 2G-14 CTD Laterals 7 Page 1 of 7 March 12, 2015 PTD Application: 2G-14A & 2G-14AL1 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 2G-14A & 2G-14AL1. All laterals will be classified as "Service- WAG"wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See the attached 10-401 forms for surface and subsurface coordinates of the 2G-14A & 2G-14AL1 laterals. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036, for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and 4300 psi. Using the maximum formation pressure in the area of 14.0 ppg EMW in well 2G-15 (4349 psi at 5995' TVD, 7/10/2012), the maximum potential surface pressure in 2G-14, assuming a gas gradient of 0.1 psi/ft, would be 3820 psi.7 See the"Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005(c)(4)(a)) Well 2G-14 has been shut in almost a year, which has allowed the formation pressure to drop to 12.4 ppg EMW as of 3/5/15 (3935 psi at 6116' TVD). The maximum down hole pressure in the vicinity is at well 2G-15 to the northeast, which measured 14.0 ppg EMW in July 2012 (4349 psi at 5995' TVD). The 2G-14 laterals will be drilled away from 2G-15, so it is believed that there is no way we can encounter formation pressure in the magnitude of 2G-15. The highest pressure that we expect to encounter is in 2G-14 itself. The most recent pressure measurement in 2G-14 indicated a formation pressure of 3910 psi at 6116' TVD or 12.3 ppg EMW (3/10/15) but w expect formation pressure to decline to approximately 12.0 ppg EMW by the time we spud. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) No specific gas zones will be drilled but 2G-14 has had gas injection as recently as 2009. There is a distinct potential that free gas could be associated with any formation influx. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) A major objective in drilling the 2G-14 laterals is to cross a large DTS fault south of 2G-14 into an area of lower pressure, believed to be in the range of 8.0 ppg EMW. The major drilling risk in 2G-14 then is lost circulation from these lower pressure intervals. We have mitigated that risk by reducing the differential pressure between fault blocks by keeping 2G-14 shut-in for almost a year. We hope that the formation pressure in 2G-14 will have declined to 12.0 ppg EMW by the time we spud in May 2015. Another risk in 2G-14 is hole stability through the A6 shale and A5 basal shales. We expect to encounter these intervals in the build section and after crossing the DTS fault south of 2G-14. We will use MPD techniques to target a constant formation pressure while drilling and completing all laterals. There is a risk of differential sticking since we're drilling into areas of reduced formation pressure. There are some backup window exit locations available in 2G-14 if needed. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) N/A for this thru-tubing drilling operation. PTD Application: 2G-14A & 2G-14AL1 According to 20 AAC 25.030(f), 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 2G-14A 9150' 9940' 6010' 6036' 2%", 4.7#, L-80, ST-L slotted liner; with aluminum billet 2G-14AL2 8368' 9940' 5880' 6016' 2%", 4.7#, L-80, ST-L slotted liner with deployment sleeve Existing Casing/Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (ppf) MD MD TVD TVD psi psi Conductor 16" 62.50 H-40 Welded 0' 110' 0' 110' 1640 630 Surface 9%" 36.0 J-55 BTC 0' 3327' 0' 2759' 3520 2020 Casing 7" 26 J-55 BTC 0' 8727' 0' 6278' 4980 4320 Tubing 3W' 9.3 J-55 EUE 8rd 0' 8374' 0' 6024' 6990 7400 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 Flo-Pro mud (10.0 ppg) — Drilling operations: Chloride-based Flo-Pro mud (10.0 ppg). This mud weight will not hydrostatically overbalance reservoir pressure. However, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: 2G-14 does not contain a subsurface safety valve (SSSV). The well will be loaded with 12.2 ppg (or greater) completion fluid in order to provide formation over-balance while running completions. — Emergency Kill Weight fluid: Two wellbore volumes of 12.9 ppg kill weight fluid will be stored at drillsite 1B in the Kuparuk field, and is accessible for trucking to the rig during CTD operations. Managed Pressure Drilling Practice I 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 n......0 ..t7 RA---L An nnec PTD Application: 2G-14A & 2G-14AL1 promotes wellbore stability, particularly in shale sections, while at the same time providing an overbalance on the reservoir. Because of the expected 12.0 ppg EMW formation pressure in 2G-14, it is our plan to hold 12.2 ppg EMW at the window to maintain overbalance and promote shale 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 2G-14A Window(8455' MD, 6083' TVD 1 Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure (12.0 ppg) 3796 psi 3796 psi Mud Hydrostatic(10.0 ppg) 3163 psi 3163 psi Annular friction (i.e. ECD, 0.060 psi/ft) 507 psi 0 psi Mud + ECD Combined 3670 psi 3163 psi (no choke pressure) (underbalanced (underbalanced —130 psi) —630 psi) Target BHP at Window(12.2 ppg) 3859 psi 3859 psi Choke Pressure Required to Maintain Target BHP 190 psi 700 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an exploratory or stratigraphic test well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well 2G-14 is a Kuparuk A-sand injection(service)well equipped with 31/2"tubing and 7"production casing. Two laterals from well 2G-14 will be drilled,both to the south to support A sand production from 2K-07, 2K-15,and 2K-26. Operations will target the A4 and A5 sand intervals. Prior to CTD operations,the existing A-sand perfs in will be squeezed with cement to provide a means to kick out of the 7"casing. ConocoPhillips has submitted at 10-403 sundry application for a variance Page 4 of 7 March 12,2015 PTD Application: 2G-14A & 2G-' -FAL 1 from the requirements of 20 AAC 25.112(c)(1) to plug the A-sand perfs in this manner. Immediately prior to cementing the A-sand perfs,the D-nipple at 8362' MD will be milled out to a 2.80"ID and the tubing tail will be perforated. Both of these operations are needed to prepare the well for CTD operations. After plugging off the existing A-sand perfs with cement pre-rig,the Nabors CDR2-AC drilling rig will drill a pilot hole to 8475' and set a whipstock in the 2.80"pilot hole at the planned kickoff point at 8455' MD Both laterals will be completed with 23/8" slotted liner from TD with the final liner top located inside the 31/2"tubing tail. Pre-CTD Work 1. E-line: Shoot 2' of holes in the 3'/2"tubing tail at 8357' MD. 2. Coil: Mill out Cameo D-nipple at 8362' MD to 2.80" 3. Coil: Cement squeeze the A-sand perfs bringing cement up into the tubing tail. 4. Slickline: Drift tubing,tag top of cement and pressure test. 5. Prep site for Nabors CDR2-AC, including setting BPV Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 2G-14A Sidetrack(A4 sand -south) a. Drill 2.80"high-side pilot hole through cement to 8475' MD b. Caliper pilot hole c. Set whipstock at 8455' MD d. Mill 2.80"window at 8455' MD e. Drill 3"bi-center lateral to TD of 9940' MD f. Run 2%" slotted liner with an aluminum billet from TD up to 9150' MD 3. 2G-14AL1 Lateral(A5 sand-south) / a. Kick off of the aluminum billet at 9150' MD b. Drill 3"bi-center lateral to TD of 9940' MD c. Run 2%" slotted liner from TD up to 8368' MD, inside the 3'/2"tubing tail 4. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain static BHP. 3. Backflow well to clean up CTD laterals 4. Conduct MIT-IA 5. Return to injection Pressure Deployment of BHA The planned bottomhole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. Because of this, MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slickline lubricator. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate Page 5 of 7 March 12,2015 PTD Application: 2G-14A & 2G- --AL1 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 2G-14 CTD laterals will be displaced to an overbalancing fluid (12.2 ppg NaBr) prior to running liner. See the"Drilling Fluids" section for more details. — While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (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./ — Distance to Nearest Property Line and nearest well in the same pool. Sidetrack Directional Distance to Distance to Name Plan Unit Boundary Nearest Well Nearest Well 2G-14A 06 11,122' 1930' 2K-07 (existing) 1830' 2K-15L1 (proposed) 2G-14AL1 03 11,122' 1930' 2K-07 (existing) 1830' 2K-15L1 (proposed) Page 6 of 7 March 12,2015 PTD Application: 2G-14A & 2G-14AL1 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) There are no wells within 1/4-mile of either 2G-14A or 2G-14AL1 that penetrate the same strata. 2G-14 (mother bore) Injector • Completed with 7", 26#, K-55 casing in October 1982. It was cemented with 335 sacks of Class "G" cement. • 2G-14 is classified as a "Normal Well" in the ConocoPhillips AnnCom database. It passed a non- AOGCC witnessed MIT-IA to 3000 psi on 2/24/15. The last state-witnessed MIT-IA was 5/1/12. • Current A-sand perforations as follows. These perfs will be squeezed as part of the pre-CTD prep. • A5: 8452'-8472' MD • A4: 8490'-8532' MD • The CTD sidetrack will exit within the current perforated interval at 8455' MD • The packer is located at 8345' MD, placing it well within the 200' of the window as required by 20 AAC 25.412(b). • The cement bond log of 10/22/1984 shows good quality cement as per the original injection order. The proposed kick-off point for the CTD sidetrack is in the A-sand perfs and should not compromise existing conformance. 2G-14A&AL1 CTD Injectors • The window for the 2G-14A CTD lateral will be milled at 8455' MD which is within the existing perforated interval for 2G-14. The window exit here will not compromise the cement integrity of 2G-14 in any way. 17. Attachments Attachment 1: Directional Plans for 2G-14A & 2G-14AL1 Attachment 2: Current Well Schematic for 2G-14 Attachment 3: Proposed Well Schematic for 2G-14 CTD Laterals Page 7 of 7 March 12,2015 2G-14 Proposed CTD Sidetrack Modified by JGE 3-12-15 3-1/2"Baker FVL SSSV @ 2055 MD(locked out) (ID=2.8131 3-1/2"9.3#J-55 EUE 8rd Tubing to surface 16"62#H-40 shoe @ 110' MD 9-5/8""36#L-80 shoe @ 3327'MD 3-1/2"Camco MMH gas lift mandrel @ 2104',4420',6165',7473',8289' Baker 3-1/2"PBR @ 8331 MD(2.81"ID) Baker FHL packer @ 8345'MD(3.0"ID) + ***Will pert tubing tail at 8357'MD 3-1/2"Camco D landing nipple @ 8362'MD(2.75"min ID,No-Go) ***Will be milled out to 2.80"ID 3-1/2"tubing tail @ 8373'MD KOP @ 8455'MD Cement pilot hole drilled to-8475'MD 2G-14AL1,Proposed TD=9,940'MD 2-3/8"liner with top at 8368'MD A-sand perfs(sgz'd) 8452'-8470'MD 2G-14A,Proposed TD=9,940'MD 2-3/8"liner with billet at 9150'MD 7"26#J-55 shoe @ ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2G Pad 2G-14 2G-14AL1 Plan: 2G-14AL1 wp03 Standard Planning Report 10 March, 2015 BAKER HUGHES ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 2G-14 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2G-14 @ 140.00usft(2G-14) Site: Kuparuk 2G Pad North Reference: True Well: 2G-14 Survey Calculation Method: Minimum Curvature Wellbore: 2G-14AL1 Design: 2G-14AL1_wp03 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 2G Pad Site Position: Northing: 5,944,015.12 usft Latitude: 70°15'29.733 N From: Map Easting: 508,649.96 usft Longitude: 149°55'48.314 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.07° Well 2G-14 Well Position +N/-S 0.00 usft Northing: 5,943,345.15 usft Latitude: 70°15'23.144 N +E/-W 0.00 usft Easting: 508,609.90 usft Longitude: 149°55'49.502 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 2G-14AL1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2014 7/1/2015 18.68 80.85 57,545 Design 2G-14AL1_wp03 Audit Notes: Version: Phase: PLAN Tie On Depth: 9,150.00 Vertical Section: Depth From(TVD) +N/-S +EI-W Direction (usft) (usft) (usft) (0) 0.00 0.00 0.00 221.16 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (usft) (°) (0) (usft) (usft) (usft) (°/100ft) (1100ft) (°/100ft) (°) Target 9,150.00 80.02 199.98 6,009.62 -4,459.20 -4,092.03 0.00 0.00 0.00 0.00 9,274.85 95.00 199.98 6,015.03 -4,576.10 -4,134.52 12.00 12.00 0.00 0.00 9,474.85 90.01 223.48 6,006.30 -4,744.77 -4,238.87 12.00 -2.49 11.74 102.00 9,674.85 88.46 199.53 6,008.97 -4,914.03 -4,342.62 12.00 -0.77 -11.98 -93.70 9,874.85 88.46 223.54 6,014.34 -5,083.20 -4,446.41 12.00 0.00 12.00 90.00 9,940.00 88.46 215.72 6,016.09 -5,133.32 -4,487.92 12.00 0.00 -12.00 -90.00 3/10/2015 12:40:39PM Page 2 COMPASS 5000.1 Build 61 rd- ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 2G-14 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2G-14 @ 140.00usft(2G-14) Site: Kuparuk 2G Pad North Reference: True Well: 2G-14 Survey Calculation Method: Minimum Curvature Wellbore: 2G-14AL1 Design: 2 G-14A L 1_wp 03 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) 9,150.00 80.02 199.98 6,009.62 -4,459.20 -4,092.03 6,050.45 0.00 0.00 5,938,881.72 504,523.38 TIP/KOP 9,200.00 86.02 199.98 6,015.70 -4,505.82 -4,108.98 6,096.70 12.00 0.00 5,938,835.09 504,506.49 9,274.85 95.00 199.98 6,015.03 -4,576.10 -4,134.52 6,166.42 12.00 0.00 5,938,764.79 504,481.03 Start 12 dls 9,300.00 94.37 202.94 6,012.98 -4,599.42 -4,143.69 6,190.01 12.00 101.88 5,938,741.46 504,471.89 9,400.00 91.88 214.69 6,007.53 -4,686.74 -4,191.73 6,287.38 12.00 101.64 5,938,654.09 504,423.95 9,474.85 90.01 223.48 6,006.30 -4,744.77 -4,238.87 6,362.10 12.00 101.90 5,938,596.01 504,376.88 3 9,500.00 89.81 220.47 6,006.34 -4,763.47 -4,255.69 6,387.24 12.00 -93.70 5,938,577.30 504,360.08 9,600.00 89.04 208.49 6,007.34 -4,845.74 -4,312.20 6,486.37 12.00 -93.75 5,938,494.97 504,303.67 9,674.85 88.46 199.53 6,008.97 -4,914.03 -4,342.62 6,557.81 12.00 -93.79 5,938,426.65 504,273.33 4 9,700.00 88.46 202.55 6,009.64 -4,937.49 -4,351.64 6,581.41 12.00 90.04 5,938,403.18 504,264.34 9,800.00 88.46 214.55 6,012.33 -5,025.14 -4,399.33 6,678.78 12.00 90.16 5,938,315.49 504,216.76 9,874.85 88.46 223.54 6,014.34 -5,083.20 -4,446.41 6,753.48 12.00 90.12 5,938,257.38 504,169.74 5 9,900.00 88.46 220.52 6,015.02 -5,101.87 -4,463.24 6,778.61 12.00 -90.04 5,938,238.70 504,152.94 9,940.00 88.46 215.72 6,016.09 -5,133.32 -4,487.92 6,818.53 12.00 -90.06 5,938,207.22 504,128.30 Planned TD at 9940.00 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +EI-W Northing Easting -Shape (°) (1 (usft) (usft) (usft) (usft) (usft) Latitude Longitude 2G-14A_Fault1 0.00 0.00 0.00 -5,849.251,136,091.67 5,938,795.00 1,644,594.00 70°0'29.542 N 140°49'47.388 W -plan misses target center by 1140200.39usft at 9150.00usft MD(6009.62 TVD,-4459.20 N,-4092.03 E) -Rectangle(sides W470.00 H1.00 D0.00) 2G-14AL1_T02 0.00 0.00 6,007.00 -6,298.081,135,906.14 5,938,346.00 1,644,409.00 70°0'25.455 N 140°49'54.571 W -plan misses target center by 1139999.65usft at 9150.00usft MD(6009.62 TVD,-4459.20 N,-4092.03 E) -Point 2G-14AL1_T03 0.00 0.00 6,016.00 -6,685.841,135,657.67 5,937,958.00 1,644,161.00 70°0'22.052 N 140°50'3.279 W -plan misses target center by 1139751.88usft at 9150.00usft MD(6009.62 TVD,-4459.20 N,-4092.03 E) -Point 2G-14AL1_T01 0.00 0.00 6,010.00 -6,012.221,136,053.48 5,938,632.00 1,644,556.00 70°0'28.015 N 140°49'49.168 W -plan misses target center by 1140146.57usft at 9150.00usft MD(6009.62 TVD,-4459.20 N,-4092.03 E) -Point 2G-14 CTD Polygon 0.00 0.00 0.00 -5,342.191,136,084.25 5,939,302.00 1,644,586.00 70°0'34.477 N 140°49'45.432 W -plan misses target center by 1140192.46usft at 9150.00usft MD(6009.62 TVD,-4459.20 N,-4092.03 E) -Polygon Point 1 0.00 0.00 0.00 5,939,302.00 1,644,586.00 Point2 0.00 -1,299.40 -666.49 5,938,001.97 1,643,921.06 Point 3 0.00 -1,533.83 -300.71 5,937,767.98 1,644,287.07 Point4 0.00 -164.48 427.86 5,939,138.03 1,645,014.00 Point5 0.00 0.00 0.00 5,939,302.00 1,644,586.00 3/10/2015 12:40:39PM Page 3 COMPASS 5000.1 Build 61 ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 2G-14 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2G-14 @ 140.00usft(2G-14) Site: Kuparuk 2G Pad North Reference: True Well: 2G-14 Survey Calculation Method: Minimum Curvature Wellbore: 2G-14AL1 Design: 2G-14AL1_wp03 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 9,940.00 6,016.09 2 3/8" 2.375 3.000 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 9,150.00 6,009.62 -4,459.20 -4,092.03 TIP/KOP 9,274.85 6,015.03 -4,576.10 -4,134.52 Start 12 dls 9,474.85 6,006.30 -4,744.77 -4,238.87 3 9,674.85 6,008.97 -4,914.03 -4,342.62 4 9,874.85 6,014.34 -5,083.20 -4,446.41 5 9,940.00 6,016.09 -5,133.32 -4,487.92 Planned TD at 9940.00 3/10/2015 12:40:39PM Page 4 COMPASS 5000.1 Build 61 ConocoPhillips ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 2G Pad 2G-14 2G-14AL1 2G-14AL1_wp03 Travelling Cylinder Report 10 March, 2015 BAKER HUGHES • -t,- Baker Hughes INTEQ �� ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2G-14 Project Kuparuk River Unit TVD Reference: 2G-14 @ 140.00usft(2G-14) Reference Site: Kuparuk 2G Pad MD Reference: 2G-14 @ 140.O0usft(2G-14) Site Error: 0.O0usft North Reference: True Reference Well: 2G-14 Survey Calculation Method: Minimum Curvature Well Error: 0.O0usft Output errors are at 1.00 sigma Reference Wellbore 2G-14AL1 Database: OAKEDMP2 Reference Design: 2G-14AL1_wp03 Offset TVD Reference: Offset Datum Reference 2G-14AL1_wp03 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.O0usft Error Model: ISCWSA Depth Range: 9,150.00 to 9,940.O0usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,180.00usft Error Surface: Elliptical Conic Survey Tool Program Date 3/10/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 200.00 8,400.00 2G-14(2G-14) GCT-MS Schlumberger GCT multishot 8,400.00 9,150.00 2G-14A_wp06(2G-14A) MWD MWD-Standard 9,150.00 9,940.00 2G-14AL1_wp03(2G-14AL1) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (') (") 9,940.00 6,156.09 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 2G Pad 2G-13-2G-13A-2G-13A Out of range 2G-13-2G-13AL1-2G-13AL1 Out of range 2G-14-2G-14A-2G-14A_wp06 9,150.00 9,150.00 0.00 0.33 -0.22 FAIL-Minor 1/10 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 3/10/2015 11:49:27AM Page 2 of 4 COMPASS 5000.1 Build 65 O 8 O r en c n kV 1/ M e _ o a. ' en - m g m � 1 I- 0 ,< o F - I - ,' I r 5 P. C a V 0.8 e N M CS a _1 II 0. 1 1 FI a. 1 . 11111 `t !.4111111411111 .1 1 q a e na 1 �. & g i Q o e a I [P c�5 d i ---__ M e O O q JO S �y Q O O CA R < O Y CnN Cn q `� J_ N Q O O ❑ d O 8 C S O 8 O O S b O S O O O N O w ?) r r v Y V I 'T Y Y Y yy QY r r r r , 'O N cc i=o (111/(111/1011r/ 000(+)uoN/t-)4;noS w co :o CI J CO _ N ▪ a Lu 1 a G o r- V cr OD CD 0 Cil • fig _ e V N�j is azfnov 7 N C '�ca 0' rr�) O c CO eel N h co Z LO N 0 COM an co CD N >MI CO0(NOu0 rM CO Q fO CO CMD�CCOO COS '^ II 77 yy 0 0 C.0 0 0 O V CO .• 0 0 0 C.1 0 0 L J t J N I-C C C\I MOO h 7 a a F OD 0;3 e_ ea ,_CD . >y N .(7 rN p N N O N O O O O O O 2 r-- QONNNNN2 so a d N an Y Y r N M N I N N .. O lO CO CO O) R N ,. O CV eO N ca 0- r «y-�i tT O) M•7�CO /J °1N3n 1 CCT OD 1-ggq / O 0. 3y J LL co (n O C I-MON Q N I-ONM rn ch o 't 1. C �]' A P a re, 0(C) ppn O)(000 CO'Q CO C r COCDOOCD ,/ -_____ h F CO 0 0 0 0 CO -C V CO CO COOCO CO ZM 'N 03 C O CO M N v CC) pan Ojcn N 00))N I �- c-N c-N N h 0.. U N O CO CO CO IIMM C 0 0 < O O CCCJ 00000 00 r 0 cocoC n W c O c 0 s o PPI� a + p CD()la.1 40 C3 - - - - O CO CO W OD O N O O J O O'7 lT iF'a0 `- O CT O W en p Cp0p N .O La C-f� 'cF N N N r h h h V ,O ,O cc. N V O)0)04 m OO)00)C C I O CO 4. O O,_N M C O L O 0 • co (uojsn Sb)tpdau ieopian arui V 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 ., PTD: 0V S — G 5 Development Service _Exploratory _Stratigraphic Test _Non-Conventional FIELD: gyAtui< k\JEs POOL: /2 �i�✓�J ktyx,d-L.,K RC vLit- 0I Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. US- O o , API No. 50- - 91/,`, -E I - G't . (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements Per Statute AS and 31.05.030(dX2XB) Regulation 20 AAC 25.071, x composite curves for well logs run must be submitted to the AOGCC within 90 days after completion,suspension or abandonment of this well. Revised 2/2015 iii TO , , N , , m o o Q , , N N p a) E . . . vi a ; ; . ; ; ; ; . o m `a) ca3 . , ; � c as , Q � L. N , U To • a N > `� (L' M; C C -0 C c CO' z c' E .O, da j E, IL - ; : 0 m a O . m t : o. c. a`) , w, p E O �� �� p a c m 5 0) a) o ,co c 3' �, 3 v a). y 3 a a). . °o) a o. �' 3 3' _1 Do, r c a w co W u-, . Q p, U) U. V)• Y. N CO. , H . Q V, ,_ E. a) . . a E v E I. �, w, O, O, o R CA, m : —, a) , wy a, o G, U) V C - co,0 a) , �, > Y', m UT UT a)' C7 8 , E 'a M O IMI 7-7`o. . 1, a .. co, T 6' ° a m mE ' f6' E' y $. 0 cc , ah , �- Un) N 'c. n: 7. N. d 3 U' N. 0' .�2� N p, a_ CD CD . �; : ' c «)' �' >, C7 0 c' m'. .§ CO 0' a' 3 &-. 3 Z i°. a D ` C O' N' N' U) W g Y a) , t.a W' co C a) . : . Y �� �/l, Vx �� , co n n C a. 2, O, ay Zrea) O , CO, sa Q „ 8. l0 , a a)' N N 'y , c' . a) c O aD (7, �� ~, a) coa) CO -' .0 3 7 3 , as CO ai a) O 1 M N n N 0 . U �. D, O' U , N , y. o U ° . Y U) •N • Ui E c co Z O. N d' N N O. U U O U a) a) ' 'V N, •° € E O' 0 X Q �� of d' V, v. .0 N, �, Y "6. U U 7, = V O. d' E C� N a) 'c L Z . 0 a D O O a) O. c' co a . o 0) •�, CD a N', p ai m' 8. 0 Z Q Y Y U 0 .' Q. Y. m. U U) co a ., Q . 2' 2. < �; 2' 0 w a CC w , , , . , ) �//' ' ) ) 0 ) ) ) 1 ) ) ) , l . . UUUU) UO UUUUvUUUCO UUUCl)UCl) U 0 0 UUCl) . ; \QQ ), a), a, aa) a) a) a) N, a) mm. aa, a) Q Q Q Qoaa < a) Qaaa) Naaaoa, QQo0, < < <z, z > }, � } } > } � � >- � r rr r .z z z z z >- >•, z, - z � }, ›- >•, > > } z >- zz z, M , . . . . . , . . : : : .2. , . . . . . : . . , : . . . , . C m . . . c . . : . . : p a E k , , a) 3. E' . . . . . . . 3, o >0 . . . . . . . . . , . . . p. �, �. . . . C . . Z . a Cf a . . , . z . , , o. �: w . . E. '. . . o a 7 2' T c, 7' v), co ° Q, .8 a) n o, or ce o, c a) rn v' 0, U) -c' o Y c �. . ; o' co w 0' ' c. . 00' ,t c E' ' o y c, a o E, o w in, � n 3. .� o �' ;� o� °' N' a o o, �, v. a)� . v), lr1 N' 7 N' E U C• � .2.' t, CA ` O• H /0 7 3' N cia C, t7 L. °�, C• y� �, 7 O. �, Q 7, co co �, • z � •o o c "O , 0 0 'C V CO. ? n D U c N• aLl, O O 0) N N d N, C. C N• C N • Q-Q M, E� E _ 'O •C� C,co, E �� N O, C C; o > I- C, Q N. e, d': 0 a) L a) 2- N' . a C C a Y Q k .c v cg c°o d, c o . rn o. j, 'Q a, fl o 6 d ° - 3 0 > m T a)N d to ° C C G O. �. � �,' 4: 7 90 N O C 3� .0 •@ N' Q¢ N. N '0 O. 0� O y a) CO D g y, 0 E on c c a m -c -0 t_ L_, a c a) `` - �' c a °' Z o' = E 7 3 °' o a, t co 3°' 3 a E Q 0, 7, •0 a). N. • N, 4 n E, . m o :° 12, as n a :: m, v a), f0 c, . m, co oy r y o O n 3 —O' c Eo N •c �)' m tic') m . 3. g, 1°' d, v w' dr 3 0' m p a§' U' c a;' m' ET `o' w TD a o n v' , m .c. d ° 7. ani O ° a 'a 3@ 0 3. o r V ao J c o' o m .- v. 03 �°. c"°) o a) °' o). E' U. o, °' g Y ° v. a) m o. rn c a) n w. �' o Q ci' o' `o' o E E E' « o o' w c, KS - "� _c a O, •° C, a „,co n f7/)� fps n C N °• 2 4') .0+. - •° a) a, •p E p 0 U 7. c 0 O ° 2 U). .)) m, E f6 0. o, f d' -' n 0, v�, N w' 'E m a m 00 f6 `°' 0 co' o c _co T C' 3' 2 -0 co CO. o )' o. a a) d f0 m a) c. n n aa) 3' m as a) a) a) § c. C °? 7' T tr,_ c' Y, Ui a' '9. o a) m 3 0. w, o ai, •- LL` C. m -0' c •' ami ami, 0 m • , 07 �� a, �� •° w ate) . •(' .v '- '' .- 0, -C 3� ,0. 0 w N •C U. �, �U,, C, m cc E E aY ..r 'p O t. c D. . s •§ 3 0 l0' f6' 8 a)' a) = N 7 O N' m °' C7 zs N N. @ U, C F.' c> c 3' ccg c8. ca a 1'2, 6`o o 8' 8' €' a vi —, •0, ., m q E -, a, .c U' m, tA; c. w+ 0 ° O' O' -. .- .. d O o 7 c°i > > 3. rn o .' a a) j 0 §, y' CO' n .0 c, 0 a). D. o > m, ,_, n m. a a a) c ° a a) c W. w. ,� O, -c m ui J: o' a0. af6) C a) d' m c, V n n a5', a5: cca, ar 3', 22' o . 2', 2' M, m; v. m V v. O' O', .0 ° n a 0 m: 0. 0 o, o • '� z a _1 � s > >, v), —, 0, O' aaU, 3' Q, a' U, V) C.) 0C.) C.), < Qw gmmUs' � � a' ocncn0, Vd m W. n n o '- N M In (0 CO 0) 0 ‘- N M V UT CO n CO CA 0 ..,--• N r) v UT (O r a0 0) E - - N F) in CO h co o) . . N N N N N N N N N N C7 CI C•) M a) M M V) 01 Cr) # O — -. V. 0 t Ln �, o ,_ to .C2' p C a) Ni 22 o ao 0 O � O _N O M 03 - En--- 0 O N NUT O U-II' o az M C M ) a) E 0. ,_ N a, T CD E J,, N •C a) CA O C O ...1,, ii • Q m 'a —i am U LU E n a c n > y na >:: d Q Q W Q (7 Q
