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E 1 H FN p III Z N o c coI 2 o 11f6 III CO o F' E Y w (n I, (� 0 a) c m :; A Q p N a) c o 1, c cWO g ICC D I Q ° 0 O I O U L Q ai U N N N IO 1 E m c 0 2 0 Z co In co I I N a w N , r- 1 co -o CD CD ID• com 0 0 m Q I O O O N a) c N N 2 ffl O as E •• C y W F N N _ _ Q d U co = a) a) E Z N co ` W CO re Z c p O d Q O C- O V_ O O C c U «_ r 1U U U U o 2 m . ) J 0 a) .a m cg U 0 a' a 7 0 d a co 0 I E p, C7 — O E O yr m o LL o a o 0 o 0 d E E Q — o — 0 m a ''1° W W i o a` 0 cOi 0 a 0 0 RECEIVE • JAN 2 9 2018 Letter of Transmittal AOGCC BA_ KER i; _n; Date: DATA LOGGED HUGHESJanuary 26, 2018 2/ 1/2DE a GE Company M K.BENDER To: From: Makana Bender Yosha Ragbirsingh I Michael Soper AOGCC Baker Hughes, a GE Company 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-15L1 2 1 7 1 4 6 2 8 9 9 9 2G-1511-01 2 1 7 1 4 7 2 9 .0 0 0 2G-15L1-02 2 1 7 1 4 8 2 9 0 0 1 1D-12L3 2 1 7 1 6 3 2 9 0 0 2 1D-12L3-01 2 1 7 1 6 4 2 9 0 0 3 1D-12L3-02 2 1 7 1 6 5 2 9 0 0 4 1D-12L3-03 2 1 7 1 6 6 2 9 0 0 5 (7) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. 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Tom Osterkamp(WNS Petroleum Technician) WELL NAME 2G-15L1-01 trth 700 G Street. DATA LOGG`ic li, Anchorage,Alaska 99510 M K BENDEF FIELD Greater Kuparuk Area to acknowledge receipt of this data. Ati COUNTY North Slope Borough 119 LOG TYPE GR-RES BHI DISTRICT Alaska --- LOG DATE December 15,2017 AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider@bakerhughes.com TODAYS DATE January 12,2018 Revision STATUS Final Replacement: No Details: Rev. Requested by: COMPANY FIELD/ FINAL CD/DVD FINAL PRELIM (las,dlis,PDF,META, SURVEY REPORT ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS CGM,Final Surveys) (Compass) 1 PERSON ATTENTION #OF PRINTS #OF I'NIN I S - #OF COPIES '#OF COPIES #OF COPIES 1 BP North Slope. 0 0 0 0 0 EOA,PBOC,PRB-20(Office 109) D&G WO Wells Admin Brenda Glassmaker&Peggy O'Neill 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 0 0 I 0 0 Attn:Ricky Elgarico ATO 708 , 700 G Street Anchorage,AK 99510 I 3 ExxonMobil,Alaska 0 0 0 0 0 Attn:Lynda M.Yaskell and/or Leonardo Elias 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC 0 1 1 1 0 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division ofOil&Gas *** 0 0 1 1 0 Attn:Resource Evaluation 550 West 7th Avenue,Suite 1100 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. 0 1 1 I 1 0 Petrotechnical Data Center,LR2-I 900 E.Benson Blvd. Anchorage,Alaska 99508 TOTALS FOR THIS PAGE: 0 2 3 3 0 • i CO S-- CO yU' N W`R "0=s c ___P___211.1% SW m g x 8 N tj A o a I IMI a t co o a CU 0 a) WW a 1-- ,, (/) z a) •� a — — ._ N ._ a) = s 2 ... .c Cl) >°- o 0_ Di_ 7, z; c5) ci) c; a V O _ .- 0 c) ix N O L N C ^, _ 6Y Y r N W a O a 1C N 3 U 0 Y Y N 2 CO 0 0 r • 0 • .!•t:Trfll.„,,I,r,!:„l„"Hl .co8 8 it .,,, ':!' 8"z v, 1 it. 88848; 1 4 ,„ ....,,„,.. a yy # p 6 .N r V C n it { C O O A„,!,,, n $ o L, ( C �J rFs V) T) U LL 444 0 44 444,44444444444 - 44 { U 818,888. a y d V J y r -0 -4,444444 A 47 J J U' 4 4444 N N U) m 2 O L O „ Y O O 01 (0 ,O O Z o) Ov v ,9 jmN Y U %OUV V O N N 2 Q OS {x ` 0) C U N s` FP {o > N N H 2 W 0) U tt€ ` j ,l f N U L t' (0 O N Nttt f o 0 N O N m f (0 > rn U) 0) U .p C OI cc' j V cpo_ 3" Q Q. d 0 07 c ri oo ; co f 0- a { N= . dc U) .. c+ � : 444,,,,4-444:44idV c vm OEa` a ? ,y aC '.— Qasei } o DmL `V UVm T R < x ao W r • Am z w -4 re E ! 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U1- NppCO 0 p_ O O 0 CO CO I\ O 0) UUO UUCO O N O CO 3 7 7 V M (V N M V R V M M (V O U) OD N- Y O OOP ,_ ,_ ,_ ,_ ,_ ,_ ,_ ,_ __ ,_ ,_ ,_ _ O O 0 .O O U Y U) r/ (° co co- (O co- (O (O (° (O (O (O N ID (p UJ (O U) (O (O (° ID C ? .Y N CO (0 7 r N (O N (D (0 O 7 n N U) 7 (p COr CO r N O O I° N (D N O U) N 1- O C) n O M co. O. 0. ,`! O O N r 7 7 CO (V CO n N CO 7 (V .- O CO M (N+) CCO CO 0 CO 00 CO CO M CO 00 CCOO IIS C'' a a > 0 V1 d Y Y Fcrf. y O co co IO N U) O P 7 1- M (NO n Zr; U O U) fp N N O 1� M 7 N- O OD t a a `- `- r O 7 N V r n N N N O O o > > U ^ o ai O 2 2 2 0 0 0 (V c) (V (V O S U Y Y N N N C "' O O O O O a0 O O O O O O O O 0 0 O 0 O 0) O O >a a O O - + OU) M U) N M h. O n O O N f7 O m0 M O` Or ` Mr O OIN O OO O 6 U) 6 O N O UO O O O M O) co (0 Ci (0 C C d t0y 7) r O (O 7 O - r n O M O O 0) O W 0 7 N- OC O d pt TGv0 O O O O O 0 0 0 0 0 0 0 0 0 0 V £ • o d 2 N s « d d 0 vo a` -n 3 3 a 0 o • • V ®F T4 S w\�� �y THE STATE Alaska Oil and Gas N� ► �� ofALASKA Conservation Commission k -2333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF ALAS�� Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Kai Starch CTD Director ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2G-15L1-01 ConocoPhillips Alaska, Inc. Permit to Drill Number: 217-147 Surface Location: 183' FNL, 88' FEL, Sec. 6, T1ON, R9E, UM Bottomhole Location: 2871' FNL, 286' FEL, Sec. 6, T1ON, R9E, UM Dear Mr. Starch: Enclosed is the approved application for permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 184-131, API No. 50-029- 21162-00-00. 0-029- 21162-00-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition,the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Hollis S. French Chair K J DATED this✓ day of November, 2017. • STATE OF ALASKA • RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION la.Well StatuWELOil❑L COMPLETION Gas❑ SPLUG❑ OR rR❑ECOnMnPLed ❑ETIONpeREP❑ORTA a ss: G 20AAC 25.105 20AAC 25.110 Devi - g Exploratory❑ GINJ ❑ WINJ❑ WAGE WDSPL❑ No.of Completions: Se i igraphic Test❑ 2.Operator Name: 6. Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska,Inc. Aband.: 12/16/2017 217-147 • 3.Address: 7.Date Spudded: 15.API Number: P.O.Box 100360 Anchorage,AK 99510-0360 12/5/2017 50-029-21162-61-00 ' 4a.Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 183'FNL,88'FEL,Sec 6,T10N, R9E, UM 12/10/2017 KRU 2G-15L1-01 • Top of Productive Interval: 9. Ref Elevations: KB:140 ' 17. Field/Pool(s): 1377'FNL,929'FEL,Sec 6,T1 ON, R9E, UM GL: 105 . BF: Kuparuk River Field/Kuparuk River Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 2869'FNL,358'FEL,Sec 31,T11 N, R9E, UM N/A ADL 25667,ADL 25656 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 508610 y- 5943405 Zone- 4 11167/6103 - LONS 82-180 TPI: x- 507774 y- 5942210 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 508327 y- 5945998 Zone- 4 N/A 1508/1508 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 N/A (ft MSL) 7158/6160 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper,resistivity,porosity, magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM • HOLE SIZE CEMENTING RECORD PULLED 16 62.5 H-40 35 105 35 105 24 202 sx Cold Set II 9 5/8 36 J-55 34 2727 34 2726 12 1/4 735 sx Permafrost E and 370 sx Permafrost C 7 26 J-55 33 6983 33 6336 8 1/2 340 sx Class G 2 3/8 4.6 L-80 6940 9933 6160 6105 3 1/4 Uncemented Slotted Liner 24.Open to production or injection? Yes 2 No ❑ 25.TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number;Date Perfd): 3 1/2 x 4 1/2 6680 5762/5499,6394/5926 SLOTTED LINER @: 6951 -9933 MD and 6160-6105 TVD 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes❑ No ❑ 12/Melt Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 12/19/2017 GAS LIFT Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 12/27/2017 22 Test Period 526 2176 5221 176/176 4133 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 240 1353 24-Hour Rate — 574 2374 5696 2323 Form 10-407 Revis d 542017 177-1_1– I/2&'/1 CpID�,.T-I�pUED ON PAGE 2 R tE3 L71j 1 ,; Submit ORIGINIAL y • • 28.CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No I If Yes, list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No Permafrost-Top Surface Surface If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1508 1508 Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval 7158 6160 information, including reports,per 20 AAC 25.071. Formation @ TPI-Kuparuk A TD 11167 6103 Formation at total depth: Kuparuk A 31. List of Attachments: Daily Operations Summary,Definitive Survey,Schematics Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report.production or well test results.per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Kai Starck Contact Name: William Long Authorized Title: CTD Director Contact Email: William.R.LongAcop.com AuthorizedContact Phone: 263-4372 Signature: ;_- Date: / / Z 1G 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 1b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 19: Report the Division of Oil&Gas/Division of Mining Land and Water:Plan of Operations(LO/Region YY-123), Land Use Permit(LAS 12345), and/or Easement(ADL 123456)number. 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 5/2017 Submit ORIGINAL Only • i 2G-15 Final CTD Schematic 3-1/2"9.3#L-80 EUE 8rd Tubing to surface 16"62.5#H-40 shoe©105'MD 3-1/2"Camco gas lift mandrels @ 5688',5093',4467', 3653',2492'RKB 9-5/8"360 J-55 shoe Baker PBR @ 5749'MD @ 2727'MD Baker FHL packer @ 5762'MD Baker PBR @ 6381'MD Baker FHL packer @ 6394'MD DS-nipple at 6448'MD(2.813"min ID) .I 4-1/2"Big Tail Pipe 6555'-6680'RKB ......................... C-sand pens 6566' ` , . - -6580'MD — — i• TOWS at6663'MD Q .7_ 2G-15L1-01 A-sand perfs --' TD:11,167'MD 2G-15L1-02 6658'-6738'MD — L - -- Liner Depth: 9833'MD TO:8195'MD 3 TOL:6940'MD Liner Depth:8195' 2G-1ci 1 TD 15L 199'MD -.- Liner Depth:10,154'MD "--- TOL:7157'MD 7"260J-55 shoe 111181...- @ 6983'MD ,..0 t operations Summary (with TimelogSpths) 2G-15 • ConocoPhitlips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(ftKB) 11/22/2017 11/22/2017 2.30 MIRU MOVE RURD P **Rig released from 2Z-13(11-22-17 0.0 0.0 06:00 08:18 at 06:00 hrs) Complete RD CDR3. 11/22/2017 11/22/2017 2.20 MIRU MOVE MOB P Peak sows arrived at 8:15 am,PJSM, 0.0 0.0 08:18 10:30 sub and pits rigged up to sows 11/22/2017 11/22/2017 2.10 MIRU MOVE MOB P Move from 2Z-Pad to 2G-Pad 0.0 0.0 10:30 12:36 11/22/2017 11/22/2017 3.00 MIRU MOVE MOB P Sub&pits spotted over well, 1/2-way 0.0 0.0 12:36 15:36 house&shop spotted at edge of pad 11/22/2017 11/22/2017 5.40 MIRU MOVE RURD P RU CDR3,NU BOP 0.0 0.0 15:36 21:00 11/22/2017 11/23/2017 3.00 MIRU WHDBOP CTOP P Unstab pipe,secure pipe to coil, 0.0 0.0 2.1:00 00:00 remove clamps and hang reel in prep for removal. 11/23/2017 11/23/2017 2.00 MIRU WHDBOP CTOP P Drop off stripper on pole,pull pack off 0.0 0.0 00:00 02:00 and brass.. 11/23/2017 11/23/2017 1.00 MIRU WHDBOP CTOP P PJSM,pick and set old storage reel on 0.0 0.0 02:00 03:00 truck,chain down and remove. 11/23/2017 11/23/2017 0.50 MIRU WHDBOP CTOP P Pick new reel and set in saddles, 0.0 0.0 03:00 03:30 release Peak trucks. 11/23/2017 11/23/2017 2.00 MIRU WHDBOP CTOP P Install new storage reel,saddle 0.0 0.0 03:30 05:30 clamps,begin inner reel iron. 11/23/2017 11/23/2017 5.00 MIRU WHDBOP CTOP P PJSM,clean up reel area,remove ice 0.0 0.0 05:30 10:30 &snow from bottom of inner reel, complete install inner reel iron,grease valves post N2 blow-down&pre BOPE test. 11/23/2017 11/23/2017 2.00 MIRU WHDBOP CTOP P Pressure bulkhead&test e-line 0.0 0.0 10:30 12:30 11/23/2017 11/23/2017 2.50 MIRU WHDBOP CTOP P PJSM,stab coil,inspect rollers,verify 0.0 0.0 12:30 15:00 level wind alignment,RD tugger snatch block assembly,remove grapple. 11/23/2017 11/23/2017 2.00 MIRU WHDBOP CTOP P Dress&re head coil,pull tested CTC, 0.0 0.0 15:00 17:00 re head BHI,test e-line,good,install counters 11/23/2017 11/23/2017 2.00 MIRU WHDBOP CTOP P function upper 2-3/8"rams,install test 0.0 0.0 17:00 19:00 joint,test. 11/23/2017 11/23/2017 1.00 MIRU WHDBOP CTOP P Pressure test DS PDL and tiger tank 0.0 0.0 19:00 20:00 line to 1500 psi,-Good • 11/23/2017 11/23/2017 2.00 MIRU WHDBOP CTOP P Skid cart,inspect pack off post stab,- 0.0 0.0 • 20:00 22:00 good,stab injector,Line up LRS to customer valve,PT,good,pump 10 bbls methanol to the coil,ease in at 0.25 bpm,ramp up to 0.5 bpm after 3.5 bbls away. Push meth plus 10 bbls H2O for 50%dilution to tiger tank. 11/23/2017 11/23/2017 1.50 MIRU WHDBOP CTOP P Pressure up to 4550 psi for initial shell 0.0 0.0 22:00 23:30 test,good, inner reel valve and stripper PT-Good. Un Stab injector, skid back. Install night cap. ***Rig Accept 22:30 11/23/2017 11/24/2017 0.50 MIRU WHDBOP BOPE P PJSM,Flood up&bleed air above C4 0.0 0.0 23:30 00:00 &@ the night cap. Start BOP test- test 1 Page 1/24 Report Printed: 12/27/2017 Iperations Summary (with TimelogSpths) Or 11 ozr 2G-15 ConocoPhiiilFss Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/24/2017 11/24/2017 0.90 MIRU WHDBOP BOPE T BOP test-test 1,struggle to get a 0.0 0.0 00:00 00:54 pass. Cycle swabs,Romeo valves, good test 11/24/2017 11/24/2017 2.20 MIRU WHDBOP BOPE P BOP test-test 2-8 good 0.0 0.0 00:54 03:06 11/24/2017 11/24/2017 1.00 MIRU WHDBOP BOPE T Test 9,issue w R3,bleed down and 0.0 0.0 03:06 04:06 grease,no test,troubleshoot and determine R3 needs to be replaced, 11/24/2017 11/24/2017 2.90 MIRU WHDBOP BOPE P Isolate R3 w/B5 and carry forward 0.0 0.0 04:06 07:00 with test#9 testing Bravo 4&8 and bleeder 3.Continue BOP test,PJSM, change out Romeo 3 valve 11/24/2017 11/24/2017 0.50 MIRU WHDBOP BOPE T Install check in UQC while changing 0.0 0.0 07:00 07:30 out Romeo 3,pressure test UQC 11/24/2017 11/24/2017 0.50 MIRU WHDBOP BOPE P Romeo 3 changed out,complete 0.0 0.0 07:30 08:00 BOPE test 11/24/2017 11/24/2017 1.00 MIRU WHDBOP PRTS P Laydown test jnt,clear floor,pressure 0.0 0.0 08:00 09:00 test ODS PDL 11/24/2017 11/24/2017 1.20 MIRU WHDBOP MPSP P PJSM,MU&pressure test lubricator, 0.0 0.0 09:00 10:12 lubricate out BPV(observe-1420 psi below BPV) 11/24/2017 11/24/2017 0.50 SLOT WHDBOP MPSP P RD lubricator,clear rig floor 0.0 0.0 10:12 10:42 11/24/2017 11/24/2017 2.80 PROD1 WHPST PULD P PJSM,PD BHA#1 Window Milling 0.0 77.0 10:42 13:30 Assembly(WFD 1.0°fixed bend, tapered housing motor,string reamer, &window mill),pause to chain& secure inner reel iron,slide in cart,MU to coil,tag up 11/24/2017 11/24/2017 1.80 PROD1 WHPST TRIP P RIH with BHA#1 77.0 6,478.0 13:30 15:18 11/24/2017 11/24/2017 1.10 PROD1 WHPST DLOG P Log K1,counters dont'agree,do not 6,478.0 6,508.0 15:18 16:24 see K1 on first pass,PUH to 6205' EOP to log HRZ,log HRZ for+103', log K1 for+2'correction 11/24/2017 11/24/2017 0.80 PROD1 WHPST CIRC P Open EDC,flush&circulate well to 6,508.0 6,620.0 16:24 17:12 milling fluid,close EDC,PUW=24K 11/24/2017 11/24/2017 0.10 PROD1 WHPST TRIP P Continue RIH,dry tag TOWS,PUH, 6,620.0 6,663.0 17:12 17:18 set rate at 1.8 bpm&get parameters, RBIH 11/24/2017 11/24/2017 1.30 PROD1 WHPST WPST P Begin milling window @ 330°ROHS, 6,663.0 6,665.0 17:18 18:36 CT Wt 14.8 k lbs,WOB 1.15 k lbs, 1.79 bbpm in 1.79 bpm out,CT on bottom 3973 psi,off bottom diff 640 psi 11/24/2017 11/24/2017 0.90 PROD1 WHPST WPST P CT Wt 14.2 k lbs,WOB 1.04 k lbs, 6,665.0 6,666.0 18:36 19:30 1.78 bbpm in 1.77 bpm out,CT 3936 psi,diff 712 psi annular 3722 psi, 11/24/2017 11/25/2017 4.50 PROD1 WHPST WPST P CT Wt 15.2 k lbs,WOB 1.14 k lbs, 6,666.0 6,670.0 19:30 00:00 1.77 bbpm in 1.76 bpm out,CT 3923 psi,diff 712 psi annular 3722 psi, 6668',WOB 1.98 k lbs,diff 815 psi 6669',WOB 2.43 k lbs,diff 820 psi- 22:15 6670',WOB 2.35k lbs,diff 763 psi, 23:58 Page 2/24 Report Printed: 12/27/2017 Iterations Summary (with TimelogSpths) 2G-15 Ccx,ocaPhtillitlaps Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/25/2017 11/25/2017 4.00 PROD1 WHPST WPST P CT Wt 12.98 k lbs,WOB 2.36 k lbs, 6,670.0 6,673.3 00:00 04:00 1.78 bbpm in 1.77 bpm out,CT 3972 psi,diff 745 psi annular 3734 psi, 6671',WOB 1.54 k lbs,diff 828 psi, 23:58 i 6671.18'Motor work spikes to 928 psi WOB and motor work fall off at 6671.3' BOW Pinch in choke to target 12 ppg. 1.80 bpm in, 1.52 bpm out @ 3812 psi annular Preload DS PDL w build BHA. Formation in returns 11/25/2017 11/25/2017 2.70 PROD1 WHPST WPST P CT Wt 13 k lbs,WOB 2 k lbs, 1.81 6,673.3 6,688.0 04:00 06:42 bbpm in 1.74 bpm out,CT 4293 psi, diff 716 psi annular 3810 psi, Drill rat hole @ 6 fUhr 11/25/2017 11/25/2017 1.10 PROD1 WHPST REAM P Perform back reaming passes down 6,688.0 6,688.0 06:42 07:48 @ 1 ft/min,as milled @ 330°ROHS, turning around at varied depth,back reaming up at 0°,300°,and 150° ROHS,dry drift up&down,clean 11/25/2017 11/25/2017 1.10 PROD1 WHPST TRIP P Open EDC,POOH,tag up,WHP= 6,688.0 77.0 07:48 08:54 1092 psi 11/25/2017 11/25/2017 0.80 PROD1 WHPST PULD P PJSM,PUD BHA#1,window mill 77.0 0.0 08:54 09:42 came out 2.80"no-go,string reamer • came out 2.79"no-go,tools looked good,clean floor 11/25/2017 11/25/2017 1.30 PROD1 DRILL OTHR P Wash down riser,install night cap, 0.0 0.0 09:42 11:00 blow-down choke,remove night cap Post reel swap equipment inspection: hubs,saddle clamps,storage reel, inner reel iron,90,level wind,& injector 11/25/2017 11/25/2017 1.40 PROD1 DRILL PULD P PJSM,PD BHA#2 L1 Build/Turn 0.0 72.0 11:00 12:24 Assembly(2.4°AKO motor,RB Hughes bit),slide in cart,MU to coil, tag up 11/25/2017 11/25/2017 1.60 PROD1 DRILL TRIP P RIH with BHA#2 72.0 6,470.0 12:24 14:00 Driller noticed"thumping"when RIH, hands inspect saddle clamps&hubs while RIH in effort to track down issue, nothing noticable down by reel,will continue to monitor Unload ODS PDL from window milling run 11/25/2017 11/25/2017 0.30 PROD1 DRILL DLOG P log K1 for+4.5'correction,close EDC, 6,470.0 6,495.0 14:00 14:18 PUW=27K 11/25/2017 11/25/2017 0.20 PROD1 DRILL TRIP P Continue RIH 6,495.0 6,688.0 14:18 14:30 • 11/25/2017 11/25/2017 1.20 PROD1 DRILL DRLG P OBD,pumping 1.77 bpm,1.71 bpm 6,688.0 6,780.0 14:30 15:42 out,FS=467 psi,CWT=15K,WOB= 1.8K,annular=3781 psi,WHP=485 psi,circ pressure=4172 psi,average ROP over interval=77 fph 11/25/2017 11/25/2017 0.60 PROD1 DRILL DLOG P PUH, PUW=25 K,log K1 for a+1.5' 6,780.0 6,780.0 15:42 16:18 correction,log RA tag at 6668.5' Page 3/24 Report Printed: 12/27/2017 Aerations Summary (with Timelogpths) 0 .ate A. � ` 2G-15 r y , ConocoPhillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/25/2017 11/25/2017 3.30 PROD1 DRILL DRLG P BOBD pumping 1.8 bpm,FS=441 6,780.0 7,065.0 16:18 19:36 psi,CWT=14K,WOB=1.9K,annular =3841 psi,WHP=477 psi Drilling picked up to 150+ft/hr @ 6927 Up against HOT N stops,PU,28 k lbs, RBIH CT 4206 psi, 1.75 bpm in, 1.70 bpm out,diff 470 psi RIH Wt 14.7 k lbs OBD,CT Wt 10 k lbs,WOB 2.7 k lbs, ROP 128 fUhr,annular 3845 psi Sticky spot around 6974',lost all motor work,PU 31 k,-WOB,draggy,two attempts the get restarted, drilled ahead to Build TD,timed out 5x5 sweeps 11/25/2017 11/25/2017 1.90 PROD1 DRILL TRIP P PU,26 k lbs, POOH,linger to get 7,065.0 80.0 19:36 21:30 sweeps out,Chase out of hole. Pull through window,open EDC,cycle coil up and down looking for potential issue with new storage reel,-mystery noise hear/felt during days. No issue found. Continue out of hole. 11/25/2017 11/25/2017 0.80 PROD1 DRILL PULD P PJSM,bump up,space out,PUD BHA 80.0 0.0 21:30 22:18 #2 11/25/2017 11/25/2017 0.80 PROD1 DRILL PULD P Drop off high bend motor,pick up a 0.0 80.0 22:18 23:06 fresh 0.5°AKO motor topped w agitator and Hycalog B8,PD BHA#2 L1 Lat drilling assembly,stab injector 11/25/2017 11/25/2017 0.20 PROD1 DRILL CTOP P Check pack offs,good. 0.0 80.0 23:06 23:18 11/25/2017 11/25/2017 0.40 PROD1 DRILL PULD P Complet PD,bump up,space out 0.0 80.0 23:18 23:42 11/25/2017 11/26/2017 0.30 PROD1 DRILL TRIP P RIH,Park,close EDC,Shallow test 80.0 1,020.0 23:42 00:00 agitator, 1000 psi+differential and significant vibration felt. Min rate, continue in hole. 11/26/2017 11/26/2017 1.00 PROD1 DRILL TRIP P Continue to RIH in hole. 1,020.0 6,465.0 00:00 01:00 11/26/2017 11/26/2017 0.20 PROD1 DRILL DLOG P Tie into the K1 fora+10'correction. 6,465.0 6,511.0 01:00 01:12 11/26/2017 11/26/2017 0.20 PROD1 DRILL TRIP P Continue to RIH. 6,511.0 7,065.0 01:12 01:24 11/26/2017 11/26/2017 0.20 PROD1 DRILL DRLG P RIH Wt 14.5 k lbs @ min rate,12.9 k 7,065.0 7,080.0 01:24 01:36 @ drilling rate. 1.78 bpm in 1.76 bpm out,diff 918 psi OBD,notice Baker coil trac info • intermitent. PU 27 k lbs,PUH slowly while reboot machines. 11/26/2017 11/26/2017 2.00 PROD1 'DRILL TRIP T Baker coil trac info intermittent, PU 27 7,080.0 78.0 01:36 03:36 k lbs,PUH slowly while reboot machines,decision made to POOH for new tools 11/26/2017 11/26/2017 1.10 PROD1 DRILL PULD T PJSM,Bump up,space out,PUD BHA 78.0 0.0 03:36 04:42 #3 11/26/2017 11/26/2017 1.90 PROD1 DRILL PULD T PU and PD BHA#4,L1 lat drilling 0.0 78.0 04:42 06:36 assembly,crew change,slide in cart, MU to coil,tag up Page 4/24 Report Printed: 12/27/2017 10 iterations Summary (with Timelog•pths) a 2G-15 Ccxt'occiP'hiHips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/26/2017 11/26/2017 0.30 PROD1 DRILL TRIP T RIH with BHA#4,continued to have 78.0 342.0 06:36 06:54 CoilTrak issues due to short at bulkhead,stop to allow BHI time to trouble-shoot 11/26/2017 11/26/2017 1.00 PROD1 DRILL WAIT T Trouble-shoot CoilTrak issues,swap 342.0 78.0 06:54 07:54 out MWD computer,create new data- base,issue not resolved,decison made to come to surface,pop off,and check e-line,PUH,tag up,space out 11/26/2017 11/26/2017 6.00 PROD1 DRILL RGRP T Pop-off,test e-line,no good,cut at e- 78.0 78.0 07:54 13:54 line boot,retest e-line,7000 ohm test, should be 70 ohm,no good,pull pressure bulk-head and test e-line,no good,cut wire at pressure bulk-head • and test e-line,good test. Issue was likely water intrusion related. Pull&rewire pressure bulk-head,MU bulk-head to inner reel iron,grease pack,test a-line,boot a-line,MU to coil,test power to tools,low voltage& high amperage,test from MWD office to junction,good,pop back off,bring ground power to the tools, tools test good,run polarity test,backwards, reverse wiring in junction box,good polarity test,make back up coil with all tests good. 11/26/2017 11/26/2017 1.40 PROD1 DRILL TRIP T RIH with BHA#4,surface test agitator, 78.0 6,453.0 13:54 15:18 good,open EDC 11/26/2017 11/26/2017 0.30 PROD1 DRILL DLOG T Tie into K1 for a+6.5'correction,close 6,453.0 6,494.0 15:18 15:36 EDC,PUW=25K 11/26/2017 11/26/2017 0.40 PROD1 DRILL TRIP T Continue RIH,set down at BOW 6,494.0 7,080.0 15:36 16:00 (-9K),PUH,set down at the BOW a second time,reduced speed to 15 fpm and slipped right through. 11/26/2017 11/26/2017 2.50 PROD1 DRILL DRLG P OBD pumping 1.8 bpm, FS=—1200 7,080.0 7,480.0 16:00 18:30 psi,CWT=12K,WOB=1K,annular= 3797 psi,WHP=319 psi PU 34k lbs,draggy @ 7352 pump 5x5 sweep • PU 31 k lbs,cleaner @ 7436,pull BHA wiper RBIH,CT Wt 9 k lbs,WOB 1.1 k lbs, ROP 180-cuttings ratio 0.73 ROP over interval on bottom, 160 ft/hr 11/26/2017 11/26/2017 0.50 PROD1 DRILL WPRT P PU 30 k lbs,saw some motor work 7,480.06,680.0 18:30 19:00 7190 and shallower. slowed pulling speed chasing sweeps out of hole. 11/26/2017 11/26/2017 0.20 PROD1 DRILL DLOG P Log RA tag for+2'correction 6,680.0 6,705.0 19:00 19:12 11/26/2017 11/26/2017 0.30 PROD1 DRILL WPRT P RBIH,clean hole 6,705.0 7,480.0 19:12 19:30 Page 5/24 Report Printed: 12/27/2017 Iperations Summary (with TimelogSpths) ,ztt ti 0 r;,:, :: '' ' 2G-15 ConocoPhillips i Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/26/2017 11/26/2017 2.90 PROD1 DRILL DRLG P RIH Wt 10 k lbs @ 30 ft/min,CT 5024 7,480.0 7,859.0 19:30 22:24 psi, free spin diff 1180 psi i 1.77 bpm in 1.77 bpm out OBD,CT Wt 4 k lbs,WOB 1.57 k lbs, I ROP 266 ft/hr PU,29 k lbs-7604' PU,32 k lbs-7611'-MWD depth 1 tracking issue,PU,RBIH PU,28 k lbs-7649' Ran into something hard 7735'-7742' Kicked down ROP increased. ROP over interval on bottom, 131 ft/hr 11/26/2017 11/27/2017 1.60 PROD1 DRILL DRLG P Against something hard again,ROP 7,859.0 7,866.0 22:24 00:00 fell to 1.4 ft/hr,bottoms up sample has Ankerite in it. 11/27/2017 11/27/2017 2.00 PROD1 DRILL DRLG P Continue drilling ahead @—1.4 ft/hr in 7,966.0 7,878.0 00:00 02:00 ankerite. ROP increased breifly at 7870,MWD indicates we were thrown down again. 11/27/2017 11/27/2017 3.00 PROD1 DRILL DRLG P OBD,CT 5040 psi, 1.78 bpm in, 1.76 7,878.0 7,892.0 02:00 05:00 bpm out. CT Wt 7.7 k lbs,WOB 2.5 k lbs,ROP 10-1 ft/hr 11/27/2017 11/27/2017 4.60 PROD1 DRILL DRLG P OBD,CWT=10K,WOB=3.3K, 7,892.0 7,912.0 05:00 09:36 annular=3938 psi,WHP=434 psi, circ pressure=4991 psi,continued low ROP through Ankerite,average ROP over interval=4.3 fph 11/27/2017 11/27/2017 0.60 PROD1 DRILL DRLG T Observed bore pressure fall off, 7,912.0 7,912.0 09:36 10:12 walked down reel&observed leak at hammer union on inner reel iron,shut down pumps,hammered up union, leak was controlled,confered with town,continued to drill ahead. 11/27/2017 11/27/2017 4.00 PROD1 DRILL DRLG P Continue drilling from 7912'pumping 7,912.0 7,930.0 10:12 14:12 1.8 bpm,CWT=4K,WOB=2.5K, annular=3920 psi,WHP=420 psi, samples continue to have Ankerite, average ROP over interval=4.5 fph 11/27/2017 11/27/2017 0.60 PROD1 DRILL DRLG P Continue drilling from 7930',CWT= 7,930.0 7,940.0 14:12 14:48 8.4K,WOB=3.9K,annular=3937 psi,WHP=434 psi,drilling break at 7930' 11/27/2017 11/27/2017 0.30 PROD1 DRILL WPRT P Wiper up-hole,PUW=30K 7,940.0 7,120.0 14:48 15:06 11/27/2017 11/27/2017 0.30 PROD1 DRILL WPRT P Wiper in-hole,RIW=7K 7,120.0 7,940.0 15:06 15:24 11/27/2017 11/27/2017 2.90 PROD1 DRILL 'DRLG P BOBD pumping 1.77 bpm,CWT fell 7,940.0 8,041.0 15:24 18:18 off after,WOB= 1.5K,annular=3953, WHP=446 psi,pump 10 x 10 sweeps due to low CWT,observe increased weight transfer with sweeps around, though no increase in ROP, PU to get parameters after crew change,PUW= 43K,turn into BHA wiper Page 6/24 Report Printed: 12/27/2017 perations Summary (with TimelogSpths) `rte 2G-15 ConocoPhiblips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(5KB) 11/27/2017 11/27/2017 3.00 PROD1 DRILL DRLG P OBD pumping 1.8 bpm,CWT=-3.7K, 8,041.0 8,170.0 18:18 21:18 WOB=1.9K,annular=3924 psi, WHP=470 psi,average ROP over interval=43 fph 11/27/2017 11/27/2017 2.50 PROD1 DRILL DRLG P Contiue drilling from 8170',CWT= 8,170.0 8,340.0 21:18 23:48 nuetral,WOB=1.5K,annular-3983 psi,WHP=480 psi,Circ Pressure= 5073 psi,pumped 10 x 10 sweeps, mud System#2(PowerPro),begins to exit bit at 8,235',PU at 8276 to establish values with new mud around,PUW=34K, 11/27/2017 11/28/2017 0.20 PROD1 DRILL WPRT P PU 32 k lbs,long wiper tirip to the 8,340.0 7,773.0 23:48 00:00 window for tie in 11/28/2017 11/28/2017 0.40 PROD1 DRILL WPRT P Continue up hole on long wiper trip for 8,340.0 6,708.0 00:00 00:24 tie in. Spots of decent motor work while PUH Send 5x5 11/28/2017 11/28/2017 0.10 PROD1 DRILL WPRT P RBIH to jog build RBIH 6,708.0 7,081.0 00:24 00:30 11/28/2017 11/28/2017 1.80 PROD1 DRILL WPRT P PU 28 k lbs, 7,081.0 6,470.0 00:30 02:18 CT Wt increased to 25 @ 6719 below the window. Lots of dirt!. RBIH,see a little WOB spike. PU,25 ft/min,motor work started at 6852' Slow pulling rate to allow sweeps out, CT Wt climbed to 35 k 6884' Pull through window clean,CT Wt 35 k.jog 4.5 tailpipe at 1.5 bpm X2 Pump another 5x5 CT Wt fell to our clean value of 27k lbs Lots of cuttings unloaded at the shaker,load another 5x5 sweep S/D Open EDC,on line @ 2.2 bpm, pump bottoms up. 11/28/2017 11/28/2017 0.30 PROD1 DRILL WPRT P Tie into the K1 for+8'correction 6,470.0 6,638.0 02:18 02:36 last sweep out,diminished returns at the shaker 11/28/2017 11/28/2017 0.70 PROD1 DRILL WPRT P Close EDC,RBIH 6,638.0 8,340.0 02:36 03:18 Set down at the bottom of the window twice 1st @ 30 ft/min,6671.66' PU fan pump 2nd,@ 20 ft/min,6673.98'PU fan pump RIH 30 ft/min clean 11/28/2017 11/28/2017 1.20 PROD1 DRILL DRLG P RIH Wt 9.1 k lbs,Ct 4544 psi, 1.77 8,340.0 8,432.0 03:18 04:30 bpm in, 1.74 bpm out,Free spin diff 1080 psi OBD,Ct Wt 1 k lbs,WOB 1.2 k lbs, ROP 90 ft/hr 11/28/2017 11/28/2017 2.00 PROD1 DRILL DRLG P OBD,Ct Wt 2 k lbs,WOB 1 k lbs, 8,432.0 8,564.0 04:30 06:30 ROP 95 ft/hr Pu,31 k lbs 66 fUhr average over interval drilled Page 7/24 Report Printed: 12/27/2017 •perations Summary (with TimelogSpths) 0'6 L.�r 2G-15 Con000Phiiiips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/28/2017 11/28/2017 3.50 PROD1 DRILL DRLG P OBD,Ct Wt 0 k lbs,WOB 1.5 k lbs, 8,564.0 8,722.0 06:30 10:00 ROP 48 ft/hr Pu 37 k lbs , Weight transfer slowly decreasing, ROP dropping. Added 1%low torqu to Hi vis pill pit, total of 1%both 776 and low torque Pumped 15 bbl pill,no increase in weight transfer,pill at the bit @ 8661' 11/28/2017 11/28/2017 2.50 PROD1 DRILL TRIP P Decision made to TOOH to change 8,722.0 78.2 10:00 12:30 out bit.Perform shallow test on agitator @ 273'.No real noticeable vibration on surface.See 2's on Inteq tools lateral&axial. 11/28/2017 11/28/2017 0.25 PROD1 DRILL SFTY P On surface.Perform pre-job for PUD. 78.2 78.2 12:30 12:45 11/28/2017 11/28/2017 1.25 PROD1 DRILL PULD P PUD tools. 78.2 0.0 12:45 14:00 11/28/2017 11/28/2017 0.16 PROD1 DRILL SFTY P Perform pre-job for Pressure Deploy. 0.0 0.0 14:00 14:09 11/28/2017 11/28/2017 1.10 PROD1 DRILL PULD P PD BHA with new agitator(0 hours) 0.0 78.3 14:09 15:15 and a Baker Hughes re-built bit. 11/28/2017 11/28/2017 1.25 PROD1 DRILL TRIP P TIH,stop @ 400',shut EDC.Perform 78.3 6,465.0 15:15 16:30 shallow test on agitator.Still no vibration noted on surface.On Inteq tools,registered a 2 on the Iateral.0 on the Axial.Open EDC continue to TIH 11/28/2017 11/28/2017 0.20 PROD1 DRILL DLOG P Log the K1 correction of plus 3.0', 6,465.0 6,501.0 16:30 16:42 PUW 26 k,close EDC 11/28/2017 11/28/2017 0.50 PROD1 DRILL TRIP P Continue IH 6,501.0 6,650.0 16:42 17:12 11/28/2017 11/28/2017 0.20 PROD1 DRILL TRIP P Close EDC,PUW 26 k 6,650.0 6,650.0 17:12 17:24 11/28/2017 11/28/2017 0.20 PROD1 DRILL TRIP P Continue IH 6,650.0 8,693.0 17:24 17:36 11/28/2017 11/28/2017 0.20 PROD1 DRILL TRIP P Stacking weight,continue IH, 8,693.0 8,722.0 17:36 17:48 increasing pump rate 1.8 bpm at 4,476 psi, 11/28/2017 11/28/2017 2.00 PROD1 DRILL DRLG P BOBD, 1.82 bpm at 4,446 psi,BHP 8,722.0 8,851.0 17:48 19:48 4,044,WHP 519,Diff 199 psi,CTSW 1 k, IA 128,OA 53 11/28/2017 11/28/2017 0.20 PROD1 DRILL WPRT P 100',wiper up hole, PUW 34 k, 8,851.0 8,751.0 19:48 20:00 11/28/2017 11/28/2017 0.20 PROD1 DRILL WPRT P Wiper back in hole,RIW 2 k 8,751.0 8,851.0 20:00 20:12 11/28/2017 11/28/2017 1.25 PROD1 DRILL DRLG P BOBD, 1.78 bpm at 4,495 psi, 8,851.0 8,953.0 20:12 21:27 Diff=816 psi,BHP 3,952,WHP 519,IA 128,OA 52 11/28/2017 11/28/2017 0.20 PROD1 DRILL WPRT P 100',wiper up hole,PUW 41 k 8,953.0 0.0 21:27 21:39 11/28/2017 11/28/2017 0.20 PROD1 DRILL WPRT P Wiper back in hole,RIW 2.5 k 8,853.0 8,953.0 21:39 21:51 11/28/2017 11/28/2017 0.20 PROD1 DRILL DRLG P BOBD,1.80 bpm at 4,467 psi,BHP 8,953.0 8,982.0 21:51 22:03 4,032,WHP 522,Diff=816,BHP 4,055,CTSW=minus 1.5 k,DHWOB= 2k 11/28/2017 11/28/2017 0.20 PROD1 DRILL WPRT P 200'wiper up hole,PUW 35 k 8,982.0 8,782.0 22:03 22:15 Page 8/24 Report Printed: 12/27/2017 •perations Summary (with TimelogQpths) 02 2G-15 ConocoPhillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/28/2017 11/28/2017 0.20 PROD1 DRILL WPRT P Wiper back in hole,RIW 4 k 8,782.0 8,982.0 22:15 22:27 11/28/2017 11/29/2017 1.54 PROD1 'DRILL DRLG P BOBD, 1.8 bpm at 4,467 psi,BHP 8,982.0 9,102.0 22:27 00:00 4,051,WHP 519,IA 152,OA 53, CTSW=4 k,DHWOB=minus 2 k,ROP 130 fph 11/29/2017 11/29/2017 0.20 PROD1 DRILL DRLG P OBD,1.8 bpm at 4,467 psi,BHP 9,102.0 9,114.0 00:00 00:12 11/29/2017 11/29/2017 1.10 PROD1 DRILL WPRT P Wiper up hole,PUW 33 k,performing 9,114.0 6,655.0 00:12 01:18 jog at the EOP with 5x5 sweep 11/29/2017 11/29/2017 0.30 PROD1 DRILL WPRT P Open EDC,perform jog BTP,with 5x5 6,655.0 6,460.0 01:18 01:36 sweep, PUW 25 k 11/29/2017 11/29/2017 0.20 PROD1 DRILL DLOG P PUH,log the K1 marker correction of 6,460.0 6,496.0 01:36 01:48 plus 5.0' 11/29/2017 11/29/2017 0.20 PROD1 DRILL WPRT P RIH,close EDC 6,496.0 6,650.0 01:48 02:00 11/29/2017 11/29/2017 0.85 PROD1 DRILL WPRT P Continue wiper back in hole,RIW 12 6,650.0 9,113.0 02:00 02:51 k, ****Note:Set down 2.5 k BOW,PU • rotate TF HS,RIH no-pump,clean 11/29/2017 11/29/2017 2.98 PROD1 DRILL DRLG P BOBD, 1.80 bpm at 4,406 psi, 9,113.0 9,283.0 02:51 05:49 Diff=713,BHP 4,038,WHP 485, CTSW=0 k,DHWOB= 11/29/2017 11/29/2017 0.18 PROD1 DRILL WPRT P Pull short 200'wiper. 9,283.0 9,283.0 05:49 06:00 11/29/2017 11/29/2017 2.25 PROD1 DRILL DRLG .P Drill ahead. 9,283.0 9,335.0 06:00 08:15 11/29/2017 11/29/2017 0.50 PROD1 DRILL WPRT P Send down 10 x 10 sweep.PUH 8715' 9,335.0 9,335.0 08:15 08:45 to time sweep to bit. 11/29/2017 11/29/2017 5.00 PROD1 DRILL DRLG P Sweep hitting the bit,BOBD:1.80 9,335.0 9,477.0 08:45 13:45 bpm at 4,713 psi,Diff=851,BHP 4,038,WHP 519,CTSW=-1.54 k, DHWOB=.67 ROP 44.4.Had slow drilling&weight transfer issues. Pumped 10 x10 sweep&25X5 sweeps with minimal help.Pump 2 10 bbls hi vis sweeps with beads.Helped for short periods. 11/29/2017 11/29/2017 2.50 PROD1 DRILL DRLG P Break out of slow drilling @ 9477.Drill 9,477.0 9,644.0 13:45 16:15 ahead 1.81 bpm at 4,947 psi, Diff=988,BHP 4,101,WHP 458, CTSW=4.18 k, DHWOB=1.47 ROP 115 11/29/2017 11/29/2017 1.10 PROD1 DRILL WPRT P Pull window wiper 39k off bottom. 9,644.0 6,467.0 16:15 17:21 Pump 5 x 5 sweep to time for tail pipe clean up. • 11/29/2017 11/29/2017 0.45 PROD1 DRILL WPRT P With closed EDC,performed jog in 6,467.0 17:21 17:48 BTP w/sweeps ****Note:perform pressure survey above window,6,650'Bit depth/ 5,919'TVD/12.53 ppg/3852 psi 11/29/2017 11/29/2017 0.20 PROD1 DRILL DLOG P Log the K1 marker correction of plus 6,467.0 6,508.0 17:48 18:00 11.0 ft, 11/29/2017 11/29/2017 1.75 PROD1 DRILL WPST P Wiper back in hole,RIW 0 k, 6,508.0 9,644.0 18:00 19:45 11/29/2017 11/29/2017 1.75 PROD1 DRILL DRLG P BOBD, 1.79 bpm at 4,175 psi,BHP 9,644.0 9,717.0 19:45 21:30 4,102,WHP 612,IA 135,OA 77 Page 9/24 Report Printed: 12/27/2017 •perations Summary (with TimelogSpths) Of 2G-15 .11111 ConocoP'hitlips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/29/2017 11/29/2017 0.20 PROD1 DRILL WPRT P 100'wiper up hole,PUW 35 k 9,717.0 9,617.0 21:30 21:42 11/29/2017 11/29/2017 0.20 PROD1 DRILL WPRT P Wiper back in hole,RIW 1.1 k 9,617.0 9,717.0 21:42 21:54 11/29/2017 11/30/2017 2.10 PROD1 DRILL DRLG 'P BOBD, 1.5 bpm at 4,175 psi,diff=604 9,717.0 9,802.0 I 21:54 00:00 psi,BHP 4,195,WHP 590,IA 132,OA 72,CTSW=minus 4 k,DHWOB=0.8 k,ROP 29-50 fph ****Note:pumping 5x5 lubed sweeps, switching to 3x3 sweeps,increased ROP 29-50 fpm,current mud system— DF 1,500',DS 0.8%,call for trucks for Mud swap. 11/30/2017 11/30/2017 3.75 PROD1 DRILL DRLG P OBD,1.52 bpm at 4,175 psi,DIff=604 9,802.0 .9,914.0 00:00 03:45 psi, BHP 4,178,WHP 537,IA 132, OA 74,CTSW minus 3.3 k, DHWOB=0.85 k,ROP 47 fph ****Note;New mud at the bit 9,914'/ ****System#1 stats: 1,679'DF, 0.82%DS 11/30/2017 11/30/2017 2.50 PROD1 DRILL DRLG P OBD, 1.80 bpm at 4,525 psi,Diff=735 9,914.0 10,040.0 03:45 06:15 psi,BHP 4,146,WHP 572,IA 134,OA 80,CTSW=1.3 k,DHWOB=1.0 k, ROP 70-165 fph 11/30/2017 11/30/2017 0.35 PROD1 DRILL WPRT P Pull 1000'wiper trip,33k off bottom. 10,040.0 9,040.0 06:15 06:36 11/30/2017 11/30/2017 0.40 PROD1 DRILL WPRT P 'Trip back in hole.RIH wt.2-5k 9,040.0 10,040.0 06:36 07:00 11/30/2017 11/30/2017 3.75 PROD1 DRILL DRLG P OBD, 1.80 bpm at psi,Diff 754=psi, 10,040.0 10,115.0 07:00 10:45 BHP 4117,WHP 623,IA 131,OA 68, CTSW=-6 k,DHWOB=.57 k, 20'fph. Have to do multiple pick ups&BHA wipers.Pump several sweeps with minimal success.Run out of hi/lo vis pills.about 45 minutes to mix up more. Decide to set up bead pills. 11/30/2017 11/30/2017 0.75 PROD1 DRILL WPRT P Pull up 200'.Get bead pill pumped 10,115.0 10,115.0 10:45 11:30 down the coil.Time drilling when pill is at the bit. 11/30/2017 11/30/2017 1.75 PROD1 DRILL DRLG P OBD, 1.81 bpm at 4,774 psi,Diff=745 10,115.0 10,269.0 11:30 13:15 psi,BHP 4,147,WHP 614,IA 132,OA 66,CTSW=1.0k,DHWOB=.68k,ROP 40 fph 11/30/2017 11/30/2017 0.50 PROD1 DRILL WPRT P Pull short 200'wiper. 10,269.0 10,269.0 13:15 13:45 11/30/2017 11/30/2017 1.00 PROD1 DRILL DRLG P OBD, 1.80 bpm at 4,617 psi,Diff=950 10,269.0 10,450.0 13:45 14:45 psi,BHP 4095,WHP 553, IA 131,OA 65,CTSW=-3.6k,DHWOB=.1.88k, ROP 100 fph 11/30/2017 11/30/2017 1.00 PROD1 DRILL WPRT P Pump sweep,pull 1200'wiper 10,450.0 10,450.0 14:45 15:45 (9,250').30k off btm. 11/30/2017 11/30/2017 3.75 PROD1 DRILL DRLG P OBD, 1.83 bpm at 4,915psi,Diff=907 10,450.0 10,850.0 15:45 19:30 psi,BHP 4172,WHP 574,IA 131,OA 67,CTSW=-3.8k,DHWOB=..77k, ROP 153 fph 11/30/2017 11/30/2017 1.50 PROD1 DRILL WPRT P Wiper up hole to window PUW 34K 10,850.0 6,465.0 19:30 21:00 Page 10/24 Report Printed: 12/27/2017 Aerations Summary (with TimelogSpths) f +` -, 2G-15 x ConocoP'hitli fas Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/30/2017 11/30/2017 0.50 PROD1 DRILL WPRT P Jet big BTP w/sweeps(6450-6550) 6,465.0 6,465.0 21:00 21:30 11/30/2017 11/30/2017 0.20 PROD1 DRILL DLOG P Log K1 marker correction of 13ft. 6,465.0 6,499.0 21:30 21:42 11/30/2017 11/30/2017 0.20 PROD1 DRILL WPRT P RBIH,set down twice,roleld pumps, 6,499.0 6,685.0 21:42 21:54 RIH clean 11/30/2017 11/30/2017 1.10 PROD1 DRILL WPRT P conitinue IH 6,685.0 10,850.0 21:54 23:00 11/30/2017 12/1/2017 1.00 PROD1 DRILL DRLG P BOBD,1.76 BPM @ 4,531psi,dif. 10,850.0 10,904.0 23:00 00:00 760psi,BHP 4,141 psi,WHP 631psi, IA 132psi,OA 71 psi,CTSW=-7.62K, DHWOB=.90K,ROP 65 fph 12/1/2017 12/1/2017 8.75 PROD1 DRILL DRLG P OBD, 1.80 bpm at 4,866 psi,Diff=760 10,904.0 11,200.0 00:00 08:45 psi,BHP 4,261,WHP 616, IA 132,OA 71,CTSW=minus 4 k,DHWOB=1.1 k,ROP-pumping beaded pills 12/1/2017 12/1/2017 4.00 PROD1 DRILL WPRT P TD reached.Pump sweeps&pull 11,200.0 78.3 08:45 12:45 wiper.Jog in the 4.5"tail pipe.Log the K-1 for a correction of+5.5'.Wiper to the swabs. 12/1/2017 12/1/2017 1.50 PROD1 DRILL TRIP P TIH,tie in for+2.5'correction. 78.3 6,620.0 12:45 14:15 12/1/2017 12/1/2017 0.25 PROD1 DRILL SRVY P Perform BHP survey 15 minutes.BHP 6,620.0 6,620.0 14:15 14:30 of 3933 PSI @ 6044'TVD. 12.51 ppg. 12/1/2017 12/1/2017 2.75 PROD1 DRILL TRIP P TIH 6,620.0 11,105.0 14:30 17:15 12/1/2017 12/1/2017 0.65 PROD1 DRILL WPRT P Wiper up hole,PUW 31 k 11,105.0 9,000.0 17:15 17:54 12/1/2017 12/1/2017 1.10 PROD1 DRILL TRIP P RBIH 9,000.0 11,198.0 17:54 19:00 12/1/2017 12/1/2017 0.20 PROD1 DRILL WPRT P Unable to get to bottom,PUH 37 k 11,198.0 11,199.0 19:00 19:12 12/1/2017 12/1/2017 0.20 PROD1 DRILL TRIP P Confirm TD,PUH line up to beaded 11,199.0 11,199.0 19:12 19:24 pill. 12/1/2017 12/1/2017 3.00 PROD1 DRILL DISP P POOH,laying in KWF,Paint 10,000' 11,199.0 78.3 19:24 22:24 EOP flag Yellow,continue POOH 12/1/2017 12/1/2017 0.50 PROD1 DRILL OWFF P At surface,PJSM for LD tools on dead 78.3 78.3 22:24 22:54 well,check well for flow,(no-flow) 12/1/2017 12/2/2017 1.10 PROD1 DRILL PULD P LD drilling BHA#5 78.3 0.0 22:54 00:00 12/2/2017 12/2/2017 0.50 PROD1 DRILL CTOP P Perform bi-weekly Funcion test of 0.0 0.0 00:00 00:30 BOPE 12/2/2017 12/2/2017 0.50 PROD1 CASING PUTB P Prep RF for liner 0.0 0.0 00:30 01:00 12/2/2017 12/2/2017 1.50 COMPZ1 CASING PUTB P PU/MU L1 26jts of slotted liner 0.0 1,036.7 01:00 02:30 12/2/2017 12/2/2017 1.00 COMPZ1 CASING PUTB P PJSM,PU CoilTrak tools 1,036.7 1,084.6 02:30 03:30 12/2/2017 12/2/2017 1.35 COMPZ1 CASING RUNL P Tag up,reset counters,RIH pumping 1,084.6 6,475.0 03:30 04:51 min rate. 12/2/2017 12/2/2017 0.16 COMPZ1 CASING RUNL P Log the formation correction of plus 6,475.0 6,497.0 04:51 05:00 1.5' Page 11/24 Report Printed: 12/27/2017 Summa with Timelo therY ( 9 pIperations ) 0 2G-15 )714 Conoccehiiiip Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftK8) End Depth(ftKB) 12/2/2017 12/2/2017 10.25 COMPZ1 CASING RUNL P Continue TIH,Stack out in multiple 6,497.0 9,480.0 05:00 15:15 places starting at 8736'.Work liner down try pumping using various rates and different surface weights on the coil.Eventually get to 9670'where • progress slowed.PUH 100',200',500' trying to get it moving but appears to be worse.Able to pump for several minutes when stack out,cycle the pipe to gain anywhere from 10'to 60'at a cycle.Other times much less. Eventually work the liner down to 9480'.Note:only made 43'in one hour from 14:00 to 15:00.Consult with engineer,decide to TOOH to surface. 12/2/2017 12/2/2017 2.50 COMPZ1 CASING RUNL T TOOH to surface 9,480.0 1,084.6 15:15 17:45 12/2/2017 12/2/2017 0.50 COMPZI CASING OWFF T Check well for flow,PJSM 1,084.6 1,084.6 17:45 18:15 12/2/2017 12/2/2017 0.75 COMPZ1 CASING PULD T LD liner running tools,PJSM 1,084.6 1,084.6 18:15 19:00 """Note:Found Tempress Tool screen to be plugged with debris from vac truck/return tank trash 12/2/2017 12/2/2017 1.00 COMPZ1 CASING PUTB T LD 13 jts of slotted liner. 1,084.6 515.8 19:00 20:00 12/2/2017 12/2/2017 0.50 COMPZ1 CASING PULD T PU/MU Coiltrak tools,surface test 515.8 568.8 20:00 20:30 (good-test),tag up,reset counters. 12/2/2017 12/2/2017 1.80 COMPZI CASING RUNL T RIH 568.8 5,960.0 20:30 22:18 12/2/2017 12/2/2017 0.20 COMPZ1 CASING RUNL T Log the formation marker zero 5,960.0 -5,982.0 22:18 22:30 correction 12/2/2017 12/3/2017 1.50 COMPZ1 CASING RUNL T Continue working pipe to bottom, 5,982.0 9,026.0 22:30 00:00 bringing pump on line at 1.2-1.4 bpm then turning pump off,making 20-100' at a time. 12/3/2017 12/3/2017 6.00 COMPZ1 CASING RUNL T Continue working pipe towards 9,026.0 10,038.0 00:00 06:00 bottom.minipulating pump up to 1.2 bpm at 4,255 psi then shutting pump down making 20-50'at a time. 12/3/2017 12/3/2017 1.75 COMPZ1 CASING RUNL T Unable to make it any deeper.Pull 10,038.0 10,038.0 06:00 07:45 brake&consult town.Decide to pump off&leave liner there.Get beaded liner pill ready. 12/3/2017 12/3/2017 3.00 COMPZ1 CASING RUNL P Pump off liner.Send 25 bbls of 10,038.0 0.0 07:45 10:45 beaded pill down coil.Move coil-1'a minute untill pill arrives at bit.Lay in beaded pill in open hole.Paint flags at the window,TOOH to surface 12/3/2017 12/3/2017 1.25 COMPZ1 CASING PULD P Stop just below surface.Conduct pre- 0.0 0.0 10:45 12:00 job while performing 15 minute no flow test,good no flow,well dead.Lay down coil track&Baker G spear. 12/3/2017 12/3/2017 1.50 COMPZI CASING PULD P Conduct pre-job for running liner. 0.0 800.1 12:00 13:30 Pick/MU 20 jts of slotted liner w/ ported bull nose&shorty deployment sleeve. 12/3/2017 12/3/2017 0.65 COMPZ1 CASING PULD P Conduct pre-job.Pick-up coil track 800.1 850.4 13:30 14:09 BHA, agitator&G spear. 9 Page 12/24 Report Printed: 12/27/2017 s , Operations Summary (with Timelog•pths) - ;; , , 2G-15 ConocoPhillips r'''''.' Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/3/2017 12/3/2017 1.35 COMPZ1 CASING RUNL P TIH w/L-1 Liner section#2(BHA#8) 850.4 6,550.4 14:09 15:30 Tie into EOP flag for a-9.28',tie into K -1 for a+10.5.@ difference of 1.22'. Stack out @ 8737'work down 90' within a few minutes but stack out @ 8833'.Kick on pump w/10k on surface coil weight. 12/3/2017 12/3/2017 0.20 COMPZ1 CASING RUNL P Stop at flag correction of minus 9.28', 6,550.4 6,550.4 15:30 15:42 PUW 28 k 12/3/2017 12/3/2017 0.20 COMPZ1 CASING RUNL P Continue IH 6,550.4 7,255.0 15:42 15:54 12/3/2017 12/3/2017 0.20 COMPZ1 CASING RUNL P Log the K1 marker correction of 10.5' 7,255.0 7,276.4 15:54 16:06 12/3/2017 12/3/2017 1.00 COMPZ1 CASING RUNL P Continue IH 7,276.4 8,833.0 16:06 17:06 12/3/2017 12/3/2017 5.00 COMPZ1 CASING RUNL T Work liner towards bottom,pumping 8,833.0 9,635.0 17:06 22:06 1.0-1.4 bpm at 3,653-4,662 psi, PUW 31 k,stacking out minus 5-10 k.PUW 50 k ****Note:BOL @ 10153.5'/TOL @ 8,835' 12/3/2017 12/3/2017 0.40 COMPZI CASING RUNL P Unable to make forward progress, 9,635.0 9,635.0 22:06 22:30 bring pump up to 1.4 bpm, 1.0 bpm returns,PUW 35 k,reset depth w/o liner,line up to beaded 12.7 ppg liner . running pill 12/3/2017 12/3/2017 0.85 COMPZ1 CASING TRIP P POOH while laying in 12.7 ppg 9,635.0 6,480.0 22:30 23:21 beaded liner pu to 6,480' 12/3/2017 12/3/2017 0.20 COMPZ1 CASING DLOG P Log the K1 marker correction of plus 6,480.0 6,494.0 23:21 23:33 5.5'(unoffical BOL 10,156'/TOL 8,837.5') 12/3/2017 12/4/2017 0.45 COMPZ1 CASING TRIP P Continue POOH 6,494.0 3,807.0 23:33 00:00 12/4/2017 12/4/2017 0.50 COMPZI CASING TRIP P Continue POOH 3,807.0 50.3 00:00 00:30 12/4/2017 12/4/2017 0.50 COMPZI CASING OWFF P At surface,check well for flow,PJSM 50.3 50.3 00:30 01:00 12/4/2017 12/4/2017 0.50 COMPZ1 CASING PULD P LD setting tools 50.3 0.0 01:00 01:30 12/4/2017 12/4/2017 1.50 COMPZ1 CASING PUTB P PJSM,PU/MU 34 jts of slotted liner 0.0 1,357.2 01:30 03:00 12/4/2017 12/4/2017 0.75 COMPZI CASING PULD P PJSM,PU/MU Coiltrak tools,surface 1,357.2 1,438.5 03:00 03:45 test tools(good-test),MU INJH to well, tag up reset counters 12/4/2017 12/4/2017 1.75 COMPZ1 CASING RUNL P RIH,pumping min rate.Correct to flag, 1,438.5 7,636.0 03:45 05:30 0'correction.decided not to log K-1. Stacked out starting @ 7636',work down to 7930',tough to get by.Park at+5k CSW.Pump for a few minutes, RIH&get by. • Page 13124 Report Printed: 12/27/2017 s F ( Aerations Summary (with TimelogSpths) 2G-15 • ConocoPhiliips t: , Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P 7-X Operation (ftKB) End Depth(ftKB) 12/4/2017 12/4/2017 3.75 COMPZ1 CASING RUNL T Stacked out starting @ 7636',work 7,636.0 8,835.0 05:30 09:15 down to 7930',tough to get by.Park at+5k CSW.Pump for a few minutes, RIH&travel down hole.Repeat numerous times until tag middle liner section @ 8825'.Good weight on bit. Pump on and work it to ensure no more movement dow.Coil surface weight @-7 W/7k WOB.Looks good. Pump off,broke over @ 25k,break over with liner on was 31-33k. 12/4/2017 12/4/2017 3.00 COMPZ1 CASING TRIP P Move pipe slightly,circ beads down 8,835.0 50.3 09:15 12:15 coil to lay in.Correct counters to account for the liner length,lay in 25 bbls bead pill up to-5960'. Paint TD &window flags.Tie into K-1 for a+6' 12/4/2017 12/4/2017 0.50 COMPZ1 CASING PULD P Just below surface.Conduct pre job 50.3 0.0 12:15 12:45 while watching well for flow.Well dead.Lay down BHA.pick up upper liner assembly w/OH anchored billet. 12/4/2017 12/4/2017 1.25 COMPZ1 CASING PUTB P Conduct Pre-job.Pick up upper liner 0.0 290.3 12:45 14:00 assembly w/OH anchored billet. 12/4/2017 12/4/2017 1.00 COMPZI STK PULD P Conduct Pre-job.Pick up coil track 290.3 351.9 14:00 15:00 BHA&liner running tools. 12/4/2017 12/4/2017 1.50 COMPZI STK TRIP P RIH w/EDC open,circ min rate, 351.9 6,784.3 15:00 16:30 correct to the EOP flag plus 2.88' 12/4/2017 12/4/2017 0.20 COMPZ1 STK DLOG P Log the K1 marker correction of plus 6,784.3 6,784.3 16:30 16:42 1.5' 12/4/2017 12/4/2017 0.50 COMPZ1 STK TRIP P Continue IH, 6,784.3 7,447.0 16:42 17:12 12/4/2017 12/4/2017 0.20 COMPZ1 STK WPST P PUH to neutral weight,bring pump up 7,447.0 7,434.9 17:12 17:24 to shear 4,000 psi,set down 3.8 k, reset counters by removing liner length 12/4/2017 12/4/2017 1.30 COMPZ1 STK TRIP P POOH 7,434.9 61.7 17:24 18:42 12/4/2017 12/4/2017 0.50 COMPZ1 STK OWFF P Check well for flow,PJSM 61.7 61.7 18:42 19:12 1 %4/2017 12/4/2017 0.50 COMPZ1 STK PULD P LD setting tools,test a-line 69 61.7 0.0 19:12 19:42 megohms/<2000(good-test) 12/4/2017 12/4/2017 1.50 PROD2 STK PULD P MU,drilling BHA#11,MU INJH to 0.0 78.2 19:42 21:12 Coiltrak tools,surface test tools(good- test) 12/4/2017 12/4/2017 1.50 PROD2 STK TRIP P RIH,pumping min rate,EDC closed 78.2 6,470.0 21:12 22:42 12/4/2017 12/4/2017 0.20 PROD2 STK DLOG P Log the K1 marker correction of plus 6,470.0 6,504.0 22:42 22:54 7.0',PUW 32 k 12/4/2017 12/4/2017 0.60 PROD2 STK TRIP P Continue IH, 6,504.0 7,157.0 22:54 23:30 """"Note:Set down @ 6,675', DHWOB=7 k,PUH,rotate motor,shut down pump,RBIH,set down again 7 k,PBUH,rotate TF HS,RIH clean, continue IH 12/4/2017 12/5/2017 0.50 PROD2 STK -DISP P Tag TOB,slowly PUH displacing well 7,157.0 7,157.0 23:30 00:00 to 8.7 ppg drilling fliuid 12/5/2017 12/5/2017 0.50 PROD2 STK DISP P Continue Displacing well to 8.7 ppg 7,157.0 7,158.0 00:00 00:30 drilling fluid,while RIH Page 14124 Report Printed: 12/27/2017 • Miffing Operations Summary (with TimelogSpths) ''`Y &Wells 2G-15 ConocoPhillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/5/2017 12/5/2017 2.00 PROD2 STK KOST P Kickoff billet as per RP, 1.75 bpm at 7,158.0 7,210.0 00:30 02:30 5,235 psi FS,BHP 4,009,WHP 540, IA 127,OA 44,CTSW=14.2 k, DHWOB=0.67 k 12/5/2017 12/5/2017 0.20 PROD2 STK KOST P PUW 29 k,dry drift billet area clean 7,210.0 7,143.0 02:30 02:42 12/5/2017 12/5/2017 3.65 PROD2 DRILL DRLG P RBIH,Drill ahead 1.80 bpm at 5,360 7,210.0 7,610.0 02:42 06:21 psi,BHP 4,070,WHP 546, IA 128,OA 48,CTSW=11.4 k, DHWOB=2.1 k, ROP 80 fph 12/5/2017 12/5/2017 2.00 PROD2 DRILL WPRT P Pull wiper to window,clean PU off 7,610.0 7,610.0 06:21 08:21 bottom,31k.jog 4.5"tail pipe.RBIH 12/5/2017 12/5/2017 1.15 PROD2 DRILL DRLG P Drill ahead 1.80 bpm at 5,535 psi, 7,610.0 7,696.0 08:21 09:30 BHP 4,163,WHP 670, IA 131,OA 54, CTSW=5.71k,DHWOB=1.46 k,ROP 84.6 fph. 12/5/2017 12/5/2017 2.50 PROD2 DRILL DRLG P Pick up,36k off btm.Temporaily 7,696.0 7,924.0 09:30 12:00 adjust pump rate to 1.48 to allow better steering. 1.48 bpm at 4533 psi,BHP 4,105, WHP 667,IA 131,OA 54, CTSW=7.81k,DHWOB=.95 k,ROP 120 fph. 12/5/2017 12/5/2017 0.75 PROD2 DRILL DRLG P Back up to rate, 1.80 bpm at 5,648 7,924.0 8,005.0 12:00 12:45 psi,BHP 4,181,WHP 599, IA 131,OA 54,CTSW=5.71k,DHWOB=1.46 k, ROP 84.6 fph. 12/5/2017 12/5/2017 0.50 PROD2 DRILL WPRT P Wiper trip up to just just below billet @ 8,005.0 8,005.0 12:45 13:15 7157'.RBIH 12/5/2017 12/5/2017 3.25 PROD2 DRILL DRLG P Drill ahead 1.80 bpm at 5,586 psi, 8,005.0 8,405.0 13:15 16:30 BHP 4,155,WHP 650, IA 131,OA 54, CTSW=4.661k,DHWOB=2.16 k, ROP 149' fph. 12/5/2017 12/5/2017 1.00 PROD2 DRILL WPRT P 37k off bottom,perform 1000'wiper 8,405.0 8,405.0 16:30 17:30 trip. 12/5/2017 12/5/2017 2.50 PROD2 DRILL DRLG P Drill ahead 1.78 bpm @ 5,705 psi, 8,405.0 8,645.0 17:30 20:00 BHP 4,201 psi,WHP 597 psi,IA 128, OA41,CTSW=5.1k,DHWOB=1.3k, ROP 133 fph 12/5/2017 12/5/2017 0.50 PROD2 DRILL WPRT P 50k off bottom,perform 800'wiper trip 8,645.0 8,645.0 20:00 20:30 12/5/2017 12/5/2017 0.35 PROD2 DRILL DRLG P Drill ahead 1.80 bpm @ 5,657 psi, 8,645.0 8,670.0 20:30 20:51 BHP 4,136 psi,WHP 604, IA 128,OA 41,CTSW=3.9k,DHWOB=1.9k, ROP109 fph 12/5/2017 12/5/2017 1.10 PROD2 DRILL WPRT P 38k off bottom,perform wiper to 8,670.0 6,470.0 20:51 21:57 window with new mud,clean tail pipe 12/5/2017 12/5/2017 0.20 PROD2 DRILL DLOG P Logged K1 marker,+16.5'correction 6,470.0 6,482.0 21:57 22:09 12/5/2017 12/5/2017 0.75 PROD2 DRILL WPRT P Wiper back in hole 6,482.0 8,670.0 22:09 22:54 12/5/2017 12/6/2017 1.10 PROD2 DRILL DRLG P Drill ahead 1.81 bpm @ 4,981 psi, 8,670.0 8,759.0 22:54 00:00 BHP 4,136 psi,WHP 707, IA 128,OA 41,CTSW=2,99k, DHWOB=1.59k, 12/6/2017 12/6/2017 6.50 PROD2 DRILL DRLG P Conitue drilling ahead 1.77 bpm @ 8,759.0 9,100.0 00:00 06:30 5,165 psi,BHP=4,171 psi,WHP=684 psi,IA=128 psi,OA=41 psi CTSW=-5k DHWOB=1.7k,ROP=170 12/6/2017 12/6/2017 0.75 PROD2 DRILL WPRT P 1000'wiper,44k off btm. 9,100.0 9,100.0 06:30 07:15 Page 15/24 Report Printed: 12/27/2017 ll gperations Summary (with TimelogSpths) rat 2G-15 Conoco`f'hiiliips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/6/2017 12/6/2017 1.00 PROD2 DRILL DRLG P On bottom Drilling. 1.77 bpm @ 5310 9,100.0 9,257.0 07:15 08:15 psi,BHP=4,205 psi,WHP=680 psi, IA=130 psi,OA=41 psi CTSW=-2.9k DHWOB=1.8k,ROP=146 12/6/2017 12/6/2017 3.75 PROD2 DRILL DRLG P Reduce pump rate to 1.56 bpm to 9,257.0 9,265.0 08:15 12:00 reduce lateral vibration. 12/6/2017 12/6/2017 0.10 PROD2 DRILL DRLG P Back up to rate,1.80 bpm @ 5310 psi, 9,265.0 9,265.0 12:00 12:06 BHP=4,205 psi,WHP=680 psi,IA=130 psi,OA=41 psi CTSW=-6k DHWOB=3.33k,ROP=5.1 12/6/2017 12/6/2017 0.10 PROD2 DRILL WPRT P BHA wiper,40k off bottom 9,265.0 9,265.0 12:06 12:12 12/6/2017 12/6/2017 7.00 PROD2 DRILL DRLG P Drill ahead 1.80 bpm @ 5,605 psi, 9,265.0 9,370.0 12:12 19:12 BHP=4,240 psi,WHP=689 psi,IA=132 psi,OA=59psi,CTSW=7k, DHWOB=3.3k,ROP=4.0 12/6/2017 12/6/2017 0.20 PROD2 DRILL WPRT P 1000'wiper,52k off bottom 9,370.0 9,370.0 19:12 19:24 12/6/2017 12/6/2017 0.75 PROD2 DRILL DRLG P Drill ahead 1.79 bpm @ 5,506 psi, 9,370.0 9,401.0 19:24 20:09 BHP=4,242psi,WHP=687psi, IA=132psi,OA=60psi CTSW=-4k, DHWOB=2.1k,ROP=19 12/6/2017 12/6/2017 0.10 PROD2 DRILL WPRT P BHA wiper,56k off bottom 9,401.0 9,401.0 20:09 20:15 12/6/2017 12/6/2017 2.70 PROD2 DRILL DRLG P Drill ahead 1.80 bpm @ 5,506psi, 9,401.0 9,444.0 20:15 22:57 BHP=4,298,WHP=716psi, IA=133psi, OA=6opsi,CTSW=-4.29k, DHWOB=2.1 k,ROP=33 12/6/2017 12/7/2017 1.05 PROD2 DRILL WPRT P Perform wiper to window,45k off 9,444.0 7,167.0 22:57 00:00 bottom 12/7/2017 12/7/2017 0.50 PROD2 DRILL WPRT P Continue wiper run to window,open 7,167.0 6,460.0 00:00 00:30 EDC jet BTP 12/7/2017 12/7/2017 0.20 PROD2 DRILL DLOG P Tie into to K1,+13'correction 6,460.0 6,481.0 00:30 00:42 12/7/2017 12/7/2017 1.20 PROD2 DRILL WPRT P Continue wiper back in hole,RIW=12k 6,481.0 9,444.0 00:42 01:54 12/7/2017 12/7/2017 9.33 PROD2 DRILL DRLG P BOBD 1.81 bpm @ 5,739 psi, 9,444.0 9,769.0 01:54 11:13 BHP=4,249 psi,WHP=658 psi,IA=131 psi,OA=59 psi CTSW=-4.0k DHWOB=2.4K,ROP=37. BHA wiper @ 9521',9564',9702',&9751'.200' wiper @ 9644' 12/7/2017 12/7/2017 2.77 PROD2 DRILL TRIP P Decided to POOH for bit check.Pump 9,769.0 78.2 11:13 14:00 sweep&chase out.Jog 4.5"tail. Called state&got the ok the start BOPE a few hours before the 24 notice. 12/7/2017 12/7/2017 2.00 PROD2 DRILL PULD P Conduct pre-job for PUD.Perform 78.2 0.0 14:00 16:00 pressure undeploy per check list.Lay down BHA. 12/7/2017 12/7/2017 2.00 PROD2 DRILL BOPE P Prep for BOPE test.Swap the coil 0.0 0.0 16:00 18:00 over to water,flush the stack.Get valve crew to service the tree. 12/7/2017 12/8/2017 6.00 PROD2 DRILL BOPE P Test BOPE,state witness waived by 0.0 0.0 18:00 00:00 Guy Cook. test pressures:250 psi/2,500 psi/4500 psi 12/8/2017 12/8/2017 2.00 PROD2 WHDBOP BOPE P Continue w/BOP bi-weekly test,on 0.0 0.0 00:00 02:00 test#15 '*"'Note:Test time 8.0 hrs Page 16/24 Report Printed: 12/27/2017 qPperations Summary (with TimelogSpths) ;; 8 •w 2G-15 ConacoPhilli ps Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/8/2017 12/8/2017 1.00 PROD2 WHDBOP CTOP P RD Testing equipment 0.0 0.0 02:00 03:00 12/8/2017 12/8/2017 0.75 PROD2 DRILL CTOP P Trim 19'of coiled tubing,flat spot 0.0 0.0 03:00 03:45 (0.13 in 12'from EOP)and 1/4 in gap observed,rehead CTC,pull test to 35 k 12/8/2017 12/8/2017 0.75 PROD2 DRILL CTOP P Re-head BHI upper quick,test e-line 0.0 0.0 03:45 04:30 (good-test),PT assembly to 4,000 psi (good-test) 12/8/2017 12/8/2017 3.75 PROD2 DRILL PULD P PU/MU L1-01 lateral drilling BHA#12 0.0 78.3 04:30 08:15 12/8/2017 12/8/2017 2.75 PROD2 DRILL TRIP P RIH w/drilling BHA.(BHA#12)EDC 78.3 9,769.0 08:15 11:00 open,circulating @ min.rate.Tie inti the K-1 marker for a+3.5'correction. Density out is up&see some cuttings over the shakers.Back on BTM 12/8/2017 12/8/2017 5.00 PROD2 DRILL DRLG P Drill ahead 1.79 bpm,cir pres 5665 9,769.0 10,104.0 11:00 16:00 psi,BHP 4230 psi, 1439 DP,ROP 130',WOB 1.35k CSW.64k.Have some wt.transfer issues.Pump a 10 X 10 w/1.5%to torque.See better weight transfer&ROP picked when sweep at the bit.Add Lo-torque to the system to 1%. 12/8/2017 12/8/2017 0.50 PROD2 DRILL WPRT P Pull short wiper&log a short section 10,104.0 10,104.0 16:00 16:30 of missed res. 12/8/2017 12/8/2017 1.50 PROD2 DRILL DRLG P Drill ahead 1.79 bpm,cir pres 5724 10,104.0 10,195.0 16:30 18:00 psi,BHP 4191 psi, 1492 DP, ROP 68', WOB 1.47 CSW-6k 12/8/2017 12/8/2017 0.70 PROD2 DRILL WPRT P Wiper up hole to 9,000',PUW 40 k 10,195.0 9,000.0 18:00 18:42 12/8/2017 12/8/2017 0.50 PROD2 DRILL WPRT P Wiper back in hole,RIW 3 k 9,000.0 10,195.0 18:42 19:12 12/8/2017 12/9/2017 4.80 PROD2 DRILL DRLG P BOBD, 1.8 bpm at 5,434 psi, BHP 10,195.0 10,410.0 19:12 00:00 4,285,WHP 630,IA 130,OA 61, CTSW=minus 6 k,DHWOB=1 k,ROP 55 fph 12/9/2017 12/9/2017 4.00 PROD2 DRILL DRLG P OBD,1.79 bpm at 5,480 psi OB,BHP 10,410.0 10,557.0 00:00 04:00 4,305,WHP 640,IA 131,OA 64, CTSW=minus 7 k,DHWOB=0.5 k, ROP 20 fph,send 5x5 sweep 12/9/2017 12/9/2017 1.25 PROD2 DRILL DRLG P OBD.1.79 bpm at 5,430 psi,BHP 10,557.0 10,595.0 04:00 05:15 4,299,WHP 643,IA 131,OA 66, CTSW=minus 5.5 k,DHWOB=0.7 k, ROP=45 fph,vac trucks on location to begin mud swap. 12/9/2017 12/9/2017 2.00 PROD2 DRILL WPRT P Wiper to window,clean BTP,jogged 10,595.0 6,664.0 05:15 07:15 tail pipe with ECD closed.Jog build section. 12/9/2017 12/9/2017 0.75 PROD2 DRILLDLOG P Tie into RA marker.+14'correction& 6,664.0 6,702.0 07:15 08:00 jog 4.5"tail pipe one more time. 12/9/2017 12/9/2017 1.50 PROD2 DRILL WPRT P RBIH 6,702.0 10,604.0 08:00 09:30 12/9/2017 12/9/2017 3.00 PROD2 DRILL DRLG P OBD. 1.79 bpm at 5,450 psi,BHP 10,604.0 10,682.0 09:30 12:30 4,960,WHP 643, IA 131,OA 66, CTSW=minus 8 k,DHWOB=1 k, ROP=45 fph,vac trucks on location to • begin mud swap.Had to pull several BHA wipers. Page 17/24 Report Printed: 12/27/2017 , , iterations Summary (with Timelog pths) 2G-15 CortocoPhitiips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log I Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) I 12/9/2017 12/9/2017 1.00 PROD2 DRILL DRLG P Pull off btm,having weight transfer 10,682.0 10,682.0 12:30 13:30 issues.Pump a 5 x 5 will no help.Get bead pill made up,and send down the coil.stay off btm until pill arrives. 12/9/2017 12/9/2017 5.50 PROD2 DRILL DRLG 'P Beads at the bit©10,682.Drill ahead 10,682.0 10,873.0 13:30 19:00 @ rop of 42,-6.7 k on surface.85k WOB. 12/9/2017 12/9/2017 1.90 PROD2 DRILL 'WPRT P Wiper up hole 6,465',PUW 43 k 10,873.0 6,465.0 19:00 20:54 12/9/2017 12/9/2017 0.20 PROD2 DRILL DLOG P Log the K1 marker correction of plus 6,465.0 6,488.0 20:54 21:06 7.0' 12/9/2017 12/9/2017 0.25 PROD2 DRILL WPRT P Jet the 4.5"BTP 6640'-6,490', 6,488.0 6,488.0 21:06 21:21 pumping thru the bit @ 1.8 bpm at 5,053 psi, 12/9/2017 12/9/2017 1.70 PROD2 DRILL WPRT P Wiper back in hole,RIW 11 k 6,488.0 10,873.0 21:21 23:03 ****Note:Set down @ 6,675',PUH, roll pump,RBIH,clean 12/9/2017 12/10/2017 0.95 PROD2 DRILL DRLG P BOBD, 1.78 bpm at 5,180 psi, 10,873.0 10,895.0 23:03 00:00 Diff=970 psi, BHP 4,383,WHP 694, IA 133,OA 62,CTSW=minus 6, DHWOB=1.2 k,ROP 50 fph 12/10/2017 12/10/2017 3.75 PROD2 DRILL DRLG P Continue drilling ahead, 1.78 bpm at 10,895.0 11,001.0 00:00 03:45 5,186 psi,Diff=971 psi,BHP 4,367, WHP 747, IA 133,OA 65,CTSW= minus 5 k,DHWOB=0.4,ROP=30fph 12/10/2017 12/10/2017 PROD2 DRILL DRLG P OBD, 1.76 bpm at 5,186 FS,Diff=910 11,001.0 11,141.0 03:45 03:45 psi,BHP 4,434,WHP 720, IA 133,OA 67,CTSW=0 k,DHWOB=Pump frequent bead pills. 12/10/2017 12/10/2017 6.25 PROD2 DRILL WPRT P Pull 1000'wiper.RBIH,have to work 11,141.0 11,041.0 03:45 10:00 pump rates to get back to bottom. 12/10/2017 12/10/2017 2.50 PROD2 DRILL DRLG P Drill ahead, 1.79 bpm© BHP 4,385, 11,041.0 11,164.0 10:00 12:30 WHP 648,IA 131,OA 67,CTSW=0- 6k,DHWOB= .9kPump frequent bead pills. Increasing getting more difficult to drill. 12/10/2017 12/10/2017 3.50 PROD2 DRILL WPRT P Consult with town GEO,decision 11,164.0 6,460.0 12:30 16:00 made to call TD @ 11164'.Perform wiper per 2G-15L1-01 Liner data sheet. *pump 2 ea. 10 x10 sweeps prior to chasing out @ 40 FPM. *Pump 10 x10 sweep to have out of the bit @ EOB(7065') *Pump 10 x10 sweep to have at the bit @ window(6671') *Jog big tail pipe. 12/10/2017 12/10/2017 1.00 PROD2 DRILL WPRT P Continue wiper to swab in @ 80 fpm 6,460.0 .1,500.0 16:00 17:00 12/10/2017 12/10/2017 0.50 PROD2 DRILL WPRT P Jog in hole,from 1,500'to 1,750'.test 1,500.0 78.0 17:00 17:30 agitator(good-test) 12/10/2017 12/10/2017 1.25 PROD2 DRILL TRIP P Tag up,re-set depth,RIH 78.0 6,465.0 17:30 18:45 12/10/2017 12/10/2017 0.25 PROD2 DRILL DLOG P Lot the K1 marker correction of plus 6,465.0 6,656.0 18:45 19:00 1.0',continue IH Page 18/24 Report Printed: 12/27/2017 Milling operations Summary (with Timeloglpths) y-: &Wells. 20-15 ConocoPhillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(HKB) 12/10/2017 12/10/2017 0.25 PROD2 DRILL TRIP P Perform Pressure Survey above 6,656.0 6,656.0 19:00 19:15 window for 15 mins, MWIN=8.6 ppg Sensor Depth(TVD)=6072' Annular Press=3,983 psi BHP EMW=12.62 ppg 12/10/2017 12/10/2017 2.15 PROD2 DRILL TRIP P Continue IH clean thru window, 6,656.0 11,167.0 19:15 21:24 confirm TD 11,167' - 12/10/2017 12/10/2017 0.50 PROD2 DRILL DISP P Lineup and pump 12.8 ppg completion 11,167.0 11,167.0 21:24 21:54 fluid, 12/10/2017 12/11/2017 2.10 PROD2 DRILL TRIP P Displace well to completion fluid while 11,167.0 5,860.0 21:54 00:00 POOH 12/11/2017 12/11/2017 0.75 PROD2 DRILL TRIP P Continue POOH,displacing well to 5,860.0 78.0 00:00 00:45 12.8 ppg completion fluid 12/11/2017 12/11/2017 0.50 PROD2 DRILL OWFF P At surface,check well for flow, PSJM 78.0 78.0 00:45 01:15 12/11/2017 12/11/2017 1.25 PROD2 DRILL PULD P LD drilling BHA on a dead well. 78.0 0.0 01:15 02:30 12/11/2017 12/11/2017 0.50 COMPZ2 CASING PUTB P Prep RF for liner operations 0.0 0.0 02:30 03:00 12/11/2017 12/11/2017 2.50 COMPZ2 CASING PUTB P PU/MU L1-01 liner segment#1,w/15 0.0 601.8 03:00 05:30 jts of slotted liner. 12/11/2017 12/11/2017 2.00 COMPZ2 CASING RUNL P RIH L1-01 liner segment#1,Tie in for 601.8 8,200.0 05:30 07:30 0'correction. 12/11/2017 12/11/2017 6.00 COMPZ2 CASING RUNL T Stack out©8200'work to 8245'dry. 8,200.0 9,093.0 07:30 13:30 Use pump @ various rates.Have very little success gaining depth while pumping.Seem to make hole better w/ pumps off while RIH.But Make a good stretch from 8750'to 9219'with pump @ 1.15 BPM.Unable to repeat the success with RIH while pumping. Cycle coil&pumps to eventually get down to 9248'.PUH some to try to get momentum&lose ground.Stopped @ 9093'. 12/11/2017 12/11/2017 1.00 COMPZ2 CASING RUNL T Get call from town,working up a plan 9,093.0 9,093.0 13:30 14:30 to pump LVT. 12/11/2017 12/11/2017 1.50 COMPZ2 CASING RUNL T Continue to load up LVT in the pits. 9,093.0 9,093.0 14:30 16:00 12/11/2017 12/11/2017 0.75 COMPZ2 CASING RUNL T Begin pumping LVT down the the coil, 9,093.0 9,098.0 16:00 16:45 18.6 bbls,push LVT down coil with 12.8 formate, Spot in 9 bbls of LVT around BHA& coil to stay below build©7065'. • Capture sample of mud coming back for testing,per engineer.After 9 bbls of LVT spotted,had to pull 65k to get free.Started losing ground. 12/11/2017 12/11/2017 2.00 COMPZ2 CASING RUNL T Continue working pipe down hole 9,098.0 9,327.0 16:45 18:45 12/11/2017 12/11/2017 3.00 COMPZ2 CASING RUNL T 'Continue working pipe down hole 9,327.0 9,402.0 18:45 21:45 12/11/2017 12/12/2017 2.25 COMPZ2 CASING RUNL T Plan forward circulate out LVT,while 9,402.0 9,428.0 21:45 00:00 attempting to work pipe to bottom 12/12/2017 12/12/2017 1.20 COMPZ2 CASING CIRC T Continue circulating 12.8 ppg 9,428.0 9,428.0 00:00 01:12 completion fluid around displacing the LVT out of the hole. Page 19/24 Report Printed: 12/27/2017 .. inniterations Summary (with TimelogSpths) &Wells 2G-15 ConocoPhillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/12/2017 12/12/2017 0.50 COMPZ2 CASING CIRC T POOH 9,428.0 7,255.0 01:12 01:42 12/12/2017 12/12/2017 0.10 COMPZ2 CASING RUNL T Perform no-flow above window(no- 7,255.0 7,255.0 01:42 01:48 flow) 12/12/2017 12/12/2017 0.80 COMPZ2 CASING RUNL T POOH,pumping across the top 7,255.0 4,000.0 01:48 02:36 12/12/2017 12/12/2017 0.10 COMPZ2 CASING RUNL T Perform no-flow at 4,000',(no-flow) 4,000.0 4,000.0 02:36 02:42 12/12/2017 12/12/2017 0.70 COMPZ2 CASING RUNL T Continue POOH 4,000.0 653.3 02:42 03:24 12/12/2017 12/12/2017 0.50 COMPZ2 CASING OWFF T Check well for flow,PJSM 653.3 653.3 03:24 03:54 12/12/2017 12/12/2017 1.50 COMPZ2 CASING PUTB T LD Liner BHA#13 w/15 jts of liner 653.3 0.0 03:54 05:24 12/12/2017 12/12/2017 1.20 COMPZ2 CASING PULD T Conduct pre-job.Pick-up Clean out 0.0 • 68.5 05:24 06:36 BHA#14 12/12/2017 12/12/2017 1.30 COMPZ2 CASING TRIP T RIH w/Clean out BHA(#14)Test 68.5 6,463.0 06:36 07:54 Agitaor-Good 12/12/2017 12/12/2017 0.20 COMPZ2 CASING DLOG T Log K1 for+3'correction 6,463.0 6,506.0 07:54 08:06 12/12/2017 12/12/2017 3.50 COMPZ2 CASING TRIP T Continue in hole,Clean pass through 6,506.0 9,472.0 08:06 11:36 window,Low surface weight,no observed DHWOB.No motor work.No material coming over shaker.Unable to get past 9472'.Start working pipe. Loose ground on pick ups 12/12/2017 12/12/2017 0.80 COMPZ2 CASING TRIP T Not making headway.PUH to jet 4 9,472.0 6,681.0 11:36 12:24 1/2"tail pipe. 12/12/2017 12/12/2017 0.10 COMPZ2 CASING DLOG T Log RA marker for+5'correction 6,681.0 6,702.0 12:24 12:30 12/12/2017 12/12/2017 0.40 COMPZ2 CASING TRIP T PUH and jet 4 1/2"interval 6582 6,702.0 6,582.0 12:30 12:54 12/12/2017 12/12/2017 2.80 COMPZ2 CASING TRIP T Trip in hole.Observe RA for no 6,582.0 9,432.0 12:54 15:42 corraction.Continue in pumping drilling system#4 Pwr Pro with 1% 776&1%Lo tork.Working pipe down Mud at bit @ 9432.Continue working down until open hole above is mud packed 12/12/2017 12/12/2017 0.60 COMPZ2 CASING TRIP T PUH 100',PUW=32K down from-45K 9,432.0 10,627.0 15:42 16:18 with formate,Turn around and RIH 50 FPM clean to 10416'.working pipe down 12/12/2017 12/12/2017 1.00 COMPZ2 CASING TRIP T Working hard spot,PUH to 10,500 go 10,627.0 11,167.0 16:18 17:18 to full drilling rate @ 1.8 BPM work down past 10627.Continue in hole, tag bottom 12/12/2017 12/12/2017 3.20 COMPZ2 CASING DISP T Laying liner running pill to EOB(tubed 11,167.0 69.0 17:18 20:30 &beaded FloPro),KWF from EOB to surface,paint flags,tag up, flow check well,good,PJSM 12/12/2017 12/12/2017 1.40 COMPZ2 CASING PULD T LD BHA#14 over a dead well,mill 69.0 0.0 20:30 21:54 came out a 2.79"no-go(same as going in-hole) Page 20/24 Report Printed: 12/27/2017 ', iterations Summary (with Timelog•pths) 0 II r 2G-15 • Ccnoc hiiiips Rl.r,k.a Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/12/2017 12/12/2017 0.80 COMPZ2 CASING PUTB T PJSM, PU liner(Non-ported BN, 15 0.0 600.0 21:54 22:42 jnts slotted liner,shorty deployment sleeve) **Drill:Kick while running liner,LD saftey jnt 12/12/2017 12/13/2017 1.30 COMPZ2 CASING PULD T PJSM, PU BHA#15(liner running 600.0 653.0 22:42 00:00 tools w/agitator),change out checks, slide in cart,MU to coil,tag up,set counters 12/13/2017 12/13/2017 0.90 COMPZ2 CASING RUNL T Begin RIH with BHA#15 liner section 653.0 6,045.0 00:00 00:54 #1 12/13/2017 12/13/2017 0.20 COMPZ2 CASING DLOG T Tie into formation for 0'correction 6,045.0 6,070.0 00:54 01:06 12/13/2017 12/13/2017 0.90 COMPZ2 CASING RUNL T Continue RIH,tie into EOP flag for+8' 6,070.0 8,200.0 01:06 02:00 correction,30K PUW at window, pumps off in OH,off trouble time once past 8200' 12/13/2017 12/13/2017 1.50 COMPZ2 CASING RUNL T Continue RIH,stack weight at 9400', 8,200.0 9,920.0 02:00 03:30 PUW=35K,continue in-hole,work pipe at 9614',9642',9663',9732', 9763',9773',9781',9786',9815', 9825',9865,9888',9900' Confer with town,decison made to work pipe to 9920'and release off liner,leaving TOL at—9317'(above fault#1) 12/13/2017 12/13/2017 1.00 COMPZ2 CASING TRIP T Lost communication with BHA,reboot, 9,920.0 6,628.0 03:30 04:30 no good,PUH to 6628 12/13/2017 12/13/2017 1.60 COMPZ2 CASING CIRC T 'Stop and circ 12.8 into hole 6,628.0 6,628.0 04:30 06:06 12/13/2017 12/13/2017 1.20 COMPZ2 CASING TRIP T Trip out,Paint EOP flag @ 5100' 6,628.0 67.0 06:06 07:18 12/13/2017 12/13/2017 0.30 COMPZ2 CASING OWFF T At surface,flow check well.PJSM to 67.0 67.0 07:18 07:36 lay down BHA#15 liner running tools 12/13/2017 12/13/2017 1.20 COMPZ2 CASING PULD T Break off injector,test E-line,bad.Pull 67.0 0.0 07:36 08:48 BHA from dead well 12/13/2017 12/13/2017 4.20 COMPZ2 CASING PUTB P PJSM,Run liner and inspect pressure 0.0 1,600.6 08:48 13:00 bulkhead,R/U floor and make up AL1- 01 intermediate liner segment with ported bullnose,40 Jts slotted liner, and shorty deployment sleeve,RID tongs and R/U little jerks.M/U coiltrak to liner and set in slips. 12/13/2017 12/13/2017 0.40 COMPZ2 CASING PULD P Skid injector to floor and test E-line- 1,600.6 1,651.0 13:00 13:24 Good,M/U coil to coiltrack and surface test tool 12/13/2017 12/13/2017 0.90 COMPZ2 CASING RUNL P RIH BHA#16,EDC shut 1,651.0 5,990.0 13:24 14:18 12/13/2017 12/13/2017 0.20 COMPZ2 CASING -DLOG P Log K1 for+1.5' 5,990.0 6,057.0 14:18 14:30 12/13/2017 12/13/2017 4.60 COMPZ2 CASING RUNL P Continue in hole.Weight check @ 6,057.0 9,063.0 14:30 19:06 6590 31K,clean trip through window, initial setdown @ 8116',PUW=48K Page 21/24 Report Printed: 12/27/2017 •Peratuons Summary (with TimelogIpths) 0 2G-15 Cona�cdP'huhps Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/13/2017 12/13/2017 2.40 COMPZ2 CASING RUNL P Work pipe to 9063',difficulty working 9,063.0 8,936.0 19:06 21:30 past 9063'with multiple PU's,confer with town,decision made to stop working coil,begin pumping PowerPro down coil,once at the bit begin working liner to bottom 12/13/2017 12/13/2017 2.00 COMPZ2 CASING CIRC P Begin pumping PowerPro down coil 8,936.0 8,861.0 21:30 23:30 at.5 bpm to minimize KWF losses, occasionally shut down pump and work pipe to ensure not getting stuck. 12/13/2017 12/13/2017 0.30 COMPZ2 CASING RUNL P Begin running liner with PowerPro 8,861.0 9,325.0 23:30 23:48 coming out the bit,with 5 bbl out gained CWT(-10K CWT),slid liner to 9271',PU and RIH to setting depth, stop at 9325',believe at TOL for run #1,stop with 3.25K WOB,attempting to avoid pushing run#1 down-hole, bring up pumps,release off liner,TOL -7725' 12/13/2017 12/14/2017 0.20 COMPZ2 CASING CIRC P Continue displacing well to PowerPro 9,325.0' 9,300.0 23:48 00:00 in OH&KWF from EOB to surface 12/14/2017 12/14/2017 2.30 COMPZ2 CASING CIRC P Continue displacing well to KWF(EOB 9,300.0 6,650.0 00:00 02:18 to surface),PUH to log formation for +6.5'correction,return to window& complete KWF displacement,flow check well at the window,good 12/14/2017 12/14/2017 1.40 COMPZ2 CASING TRIP P POOH,paint EOP flag at 5750', 6,650.0 64.0 02:18 03:42 PJSM,flow check 12/14/2017 12/14/2017 0.90 COMPZ2 CASING PULD P LD BHA#16,PJSM for PU liner 64.0 0.0 03:42 04:36 • 12/14/2017 12/14/2017 1.50 COMPZ2 CASING PUTB P PU liner run#3(ported BN,3 pups, 19 0.0 778.0 04:36 06:06 jnts slotted liner,OH anchor&billet), MU safety jnt for crew change. 12/14/2017 12/14/2017 1.50 COMPZ2 CASING PULD P PU liner running tools,BHA#17,M/U 778.0 851.1 06:06 07:36 to coil and surface test,Check pack offs 12/14/2017 12/14/2017 1.20 COMPZ2 CASING TRIP P Trip in hole,EDC open.Test HOT 851.1 6,240.0 07:36 08:48 12/14/2017 12/14/2017 0.10 COMPZ2 CASING DLOG P Log GR tie in for-1'correction 6,240.0 6,268.0 08:48 08:54 12/14/2017 12/14/2017 0.70 COMPZ2 CASING TRIP P Continue in,close EDC @ 6268', 6,268.0 7,729.0 08:54 09:36 PUW=28K,clean pass through window down to TOL @ 7729 12/14/2017 12/14/2017 1.20 COMPZ2 CASING TRIP P 7729,Orient to 330°ROHS,Set OH 7,729.0 50.0 09:36 10:48 Anchor,See tool shift with increased DHWOB,Trip out 12/14/2017 12/14/2017 1.00 COMPZ2 CASING PULD P Surface,Flow check,PJSM,Lay down 50.0 0.0 10:48 11:48 anchor setting tools 12/14/2017 12/14/2017 0.90 PROD3 STK PULD P M/U Drilling BHA#18 with.5°AKO 0.0 78.3 11:48 12:42 motor,Agitator,and Halliburton M144 Bi Center bit.Make up to coil and surface test 12/14/2017 12/14/2017 1.20 PROD3 STK TRIP P RIH BHA#18,shallow test agitator- 78.3 6,465.0 12:42 13:54 good 12/14/2017 12/14/2017 0.20 PROD3 STK DLOG P Tie in to K1,+4'correction 6,465.0 6,495.0 13:54 14:06 12/14/2017 12/14/2017 0.20 PROD3 STK TRIP P continue in hole,tag billet @ 6939' 6,495.0 6,939.0 14:06 14:18 Page 22/24 Report Printed: 12/27/2017 e of Iperations Summary (with TimeloglIpths) 2G-15 +Ccsmmehiiiips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/14/2017 12/14/2017 1.00 PROD3 STK CIRC P PUH 6,644',displace well to PowerPro 6,939.0 6,644.0 14:18 15:18 system 4 12/14/2017 12/14/2017 0.101 PRODS STK TRIP P RIH and to begin milling off billet 6,644.0 6,940.0 15:18 15:24 12/14/2017 12/14/2017 3.00 PROD3 STK KOST P Milling billet @ 6,939'1.80 BPM @ 6,940.0 6,949.0 15:24 18:24 5,587 psi free spin BHP=4,055psi,KO billet w/o issue. 12/14/2017 12/14/2017 3.10 PROD3 DRILL DRLG P Off billet drilling in formation,pumping 6,949.0 7,303.0 18:24 21:30 1.75 bpm,CWT=11K,WOB=2.3K, annular=4036 psi,WHP=612 psi, dry drift billet up&down,clean,drop rate to 1.5 bpm to help in building angle,ROP decreased beginning at 7288',average ROP over interval= 114 fph 12/14/2017 12/14/2017 0.90 PROD3 DRILL DRLG P Continue drilliing ahead,CWT=12K, 7,303.0 7,350.0 21:30 22:24 WOB=3K,annular=4064 psi, average ROP over interval=52 fph, ankerite observed in samples over shakers. 12/14/2017 12/14/2017 0.60 PROD3 DRILL WPRT P Wiper up-hole,PUW=31K,tie into 7,350.0 6,593.0 22:24 23:00 RA tag for+2'correction, jog BTP, stack-7.5k WOB at bottom of window,PU,roll pumps,clean through 12/14/2017 12/14/2017 0.50 PROD3 DRILL WPRT P Wiper in-hole,RIW=13.5K 6,593.0 7,350.0 23:00 23:30 12/14/2017 12/15/2017 0.50-PROD3 DRILL DRLG P BOBD,1.8 bpm,FS=1050 psi,CWT 7,350.0 7,469.0 23:30 00:00 =11K,WOB=1.2K,annular=4100 psi,WHP=580 psi,average ROP over interval=238 fph 12/15/2017 12/15/2017 3.10 PROD3 DRILL DRLG P Continue drilling from 7469,pumping 7,469.0 7,750.0 00:00 03:06 1.8 bpm,CWT=9.5K,WOB=1.5K, annular=4100 psi,WHP 577 psi, encountered reduced ROP beginning at 7590'-7612',average ROP over interval=91 fph 12/15/2017 12/15/2017 0.30 PROD3 DRILL WPRT P Wiper up-hole,PUW=33K 7,750.0 7,008.0 03:06 03:24 12/15/2017 12/15/2017 0.30 PROD3 DRILL WPRT P Wiper in-hole,RIW=10K 7,008.0 7,750.0 03:24 03:42 12/15/2017 12/15/2017 2.00 PROD3 DRILL DRLG P BOBD,pumping, 1.8 bpm,CWT= 7,750.0 8,076.0 03:42 05:42 8.7K,WOB=1.4K,annular=4182, WPH-619 psi 12/15/2017 12/15/2017 0.20 PROD3 DRILL WPRT P BHA Wiper,PUW=35K 8,076.0 8,076.0 05:42 05:54 12/15/2017 12/15/2017 1.00 PROD3 DRILL DRLG P 8076',Drill, 1.8 BPM @ 5390 PSI FS, 8,076.0 8,190.0 05:54 06:54 BHP=4160 12/15/2017 12/15/2017 2.20 PROD3 DRILL WPRT P At Plan TD,Pump 10 X 10 Sweeps 8,190.0 78.0 06:54 09:06 and chase to swab,AVG DLS for lateral=9.06°vs.planned 7°with HES bi center,Jog at 500'from surface 12/15/2017 12/15/2017 1.30'PROD3 DRILL WPRT P At surface,reset counters,RBIH 78.0 6,465.0 09:06 10:24 12/15/2017 12/15/2017 0.20 PROD3 DRILL DLOG P Log K1 for+2'correction 6,465.0 6,501.0 10:24 10:36 12/15/2017 12/15/2017 1.10 PROD3 DRILL WPRT P Continue in well.WT.check @ 6633 6,501.0 8,195.0 10:36 11:42 @ 31K.Stack in bottom of window, PUH and orient go through.Clean to corrected TD @ 8195',wait on pill Page 23/24 Report Printed: 12/27/2017 ', Pte, _ operations Summary (with TimelogSpths) 2G-15 conocoPhits' .> Hr 51.r.r.s Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End lime Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/15/2017 12/15/2017 2.00 PROD3 DRILL TRIP P Trip out of hole pumping 12.8 beaded 8,195.0 87.0 11:42 13:42 liner running pill,Paint EOP flags @ 7400&5900' 12/15/2017 12/15/2017 0.80 PROD3 DRILL PULD P At surface,Flow check well,PJSM lay 87.0 0.0 13:42 14:30 down BHA on dead well 12/15/2017 12/15/2017 1.50 COMPZ3 CASING PUTB P PJSM,Rig up floor to run liner.P/U L2 0.0 597.5 14:30 16:00 -01 lower segment with non ported bullnose, 15 Jts slotted liner,shorty deployment sleeve 12/15/2017 12/15/2017 1.00 COMPZ3 CASING PULD P Make up coil to coil tral and surface 597.5 643.7 16:00 17:00 test tool,Check pack offs 12/15/2017 12/15/2017 2.20 COMPZ3 CASING RUNL P Trip in hole,EDC closed,Min rate,tie 643.7 8,194.0 17:00 19:12 in for 0'correction,arrive at TD,PUW =37K,RBIH,release off lower liner segment,PUW=27K,good release, TOL-7597' 12/15/2017 12/15/2017 1.80 COMPZ3 CASING TRIP P POOH,flow check well,good,PJSM 8,195.0 46.0 19:12 21:00 12/15/2017 12/15/2017 0.60 COMPZ3 CASING PULD P LD BHA#19 liner running tools 46.0 0.0 21:00 21:36 12/15/2017 12/15/2017 1.10 COMPZ3 CASING PUTB P PU upper liner section(ported BN,27 0.0 •1,080.0 21:36 22:42 jnts slotted liner,shorty deployment sleeve) 12/15/2017 12/15/2017 0.90 COMPZ3 CASING PULD P PJSM,PU BHA#20 upper liner 1,080.0 1,122.0 22:42 23:36 running tools,slide in cart,check pack -offs,good,MU to coil,tag up 12/15/2017 12/16/2017 0.40 COMPZ3 CASING RUNL P Begin RIH with BHA#20 upper liner 1,122.0 3,153.0 23:36 00:00 section 12/16/2017 12/16/2017 1.40 COMPZ3 CASING RUNL P Continue RIH with upper liner section, 3,153.0 7,597.0 00:00 01:24 tie-in for 0'correction,PUW at window =29K,set down 9K WOB at 7404',- 12K WOB on PU,stack multiple more times at same depth,continue working pipe at various speeds&get by, again stack out at 7481',work pipe, arrive at setting depth,release off liner,PUW=27K,TOL-6519' 12/16/2017 12/16/2017 0.30 COMPZ3 CASING DLOG P PUH to 6509 MD&obtain SBHP, 7,597.0 6,509.0 01:24 01:42 pressure sensor TVD=5995', annular=4006 psi,calculated EMW =12.85 ppg 12/16/2017 12/16/2017 3.30 COMPZ3 CASING DISP P Circulate well to seawater,POOH& 6,509.0 42.0 01:42 05:00 freeze protect from 2500'up,WHP= 1185 psi 12/16/2017 12/16/2017 3.30 COMPZ3 CASING PULD P PJSM,PUD BHA#20,Lay down tools 42.0 0.0 05:00 08:18 and pull check valve from UQC 12/16/2017 12/16/2017 0.40 COMPZ3 WHDBOP CIRC P MU nozzle&jet stack 0.0 . 0.0 08:18 08:42 12/16/2017 12/16/2017 1.00 COMPZ3 WHDBOP MPSP P PJSM,R/U BPV lubricator,set BPV, 0.0 0.0 08:42 09:42 lay down BPV lubricator 12/16/2017 12/16/2017 1.30 COMPZ3 WHDBOP CIRC P Flush rig surface lines,Blow down 0.0 0.0 09:42 11:00 lines and drilling choke 12/16/2017 12/16/2017 0.70 COMPZ3 WHDBOP CTOP P Rig up bore scope,scope BOPE 0.0 0.0 11:00 11:42 equipment 12/16/2017 12/16/2017 0.30 COMPZ3 WHDBOP OTHR P Freeze protect tree 0.0 0.0 11:42 12:00 12/16/2017 12/16/2017 3.00 DEMOB MOVE MOB P Run rig down check list-Release Rig 0.0 0.0 12:00 15:00 @ 15:00 Page 24/24 Report Printed: 12/27/2017 • S ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2G Pad 2G-15L1-01 50-029-21162-61 Baker Hughes INTEQ Blau = e`T 1aGEmpany Definitive Survey Report 10 January,2018 • S ConocoPhillips EGNF&0 ConocoPhillips p Definitive Survey Report ,„ Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2G-15 Project: Kuparuk River Unit TVD Reference: 2G-15 ll 140.00usft(2G-15) Site: Kuparuk 2G Pad MD Reference: 2G-15 li 140.00usft(20-15) Well: 2G-15 North Reference: True Wellbore: 2G-15 Survey Calculation Method: Minimum Curvature Design: 2G-15 Database: EDT Alaska Sandbox ' :l... ,. . Project Kuparuk River Unit,North Slope Alaska,United States k Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level 3 `Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point °°Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2G-15 Well Position +N/-S 0.00 usft Northing: 5,943,405.25usft Latitude: 70°15'23.735 N +E/-W 0.00 usft Easting: 508,609.95usft Longitude: 149°55'49.499 W I Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wettbore 2G-15L1-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°): (nT) BGGM2017 11/1/2017 17.28 80.85 57,474 Design2G-15L1-01 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,150.29 Vertical Section: Depth From(TVD) +Nt-S +El-W Direction (usft) (usft) (usft) r) 140.00 0.00 0 00 0.00 • 1/102018 6:29:07PM Page 2 COMPASS 5000.14 Build 85 • • ConocoPhillips . t;ties 0 ConocoPhillips Definitive Survey Report " Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2G-15 Project: :Kupamk River Unit TYD Reference: 2G-15(Y)140.00usft(2G-15) Site: Kuparuk 2G Pad MD Reference: 2G-15 I§140.00usft(2G-15) Well: 2G-15 North Reference: True Wellbore: 2G-15 Survey Calculation Method: Minimum Curvature Design: 2G-15 Database: EDT Alaska Sandbox Survey Program Date 1/8/2018 FromTo Survey Survey (usft( (usft) Survey(Weilbore) Tool Name Description Start Date End Date 200.00 6,600.00 2G-15(2G-15) GCT-MS Schlumberger GCT multishot 1/12/2001 1 $ 6,661.00 6,721.77 2G-15L1 MWD-INC(2G-15L1) MWD-INC_ONLY MWD-INC_ONLY_FILLER 11/25/2017 11/25/2017 E $ 6,750.73 7,150.29 2G-15L1 MWD(2G-15L1) MWD MWD-Standard 11/25/2017 12/1/2017 - 7,158.00 7,190.24 2G-15L1-01 MWD-INC(2G-15L1-01) MWD-INC ONLY MWD-INC ONLY FILLER 12/2/2017 12/4/2017 7,224.75 11,130.13 2G-15L1-01(2G-15L1-01) MWD MWD-Standard 12/4/2017 12/13/2017 Survey Map Map Vertical - ) MD Inc Azi TVD TVDSS 1-NIS *E/-W NorthingEastingDLS Sectiont. survey Told Name Annotation I (waft), (°l r) (usft) (usft) (usft) (usft( (ft) (ft) ('/1001 (ft) 7,150.29 90.31 44.29 6,160.25 6,020.25 -1,199.31 -842.26 5,942,205.10 507,769.15 9.49 -1,199.31 MWD(3) TIP 1. 7,158.00 90.47 43.38 6,160.20 6,020.20 -1,193.75 -836.92 5,942,210.67 507,774.48 11.88 -1,193.75 MWD-INC_ONLY(4) KOP a 7,190.24 91.04 43.60 6,159.77 6,019.77 -1,170.36 -814.73 5,942,234.08 507,796.64 1.90 -1,170.36 MWD-INC_ONLY(4) Interpolated Azimuth Y 7,224.75 92.43 43.65 6,158.73 6,018.73 -1,145.39 -790.93 5,942,259.07 507,820.41 4.03 -1,145.39 MWD(5) 7,254.83 94.61 39.76 6,156.88 6,016.88 -1,122.98 -770.96 5,942,281.50 507,840.35 14.80 -1,122.98 MWD(5) 7,290.49 94.46 38.67 6,154.06 6,014.06 -1,095.44 -748.49 5,942,309.06 507,862.79 3.08 -1,095.44 MWD(5) 7,320.04 92.49 37.85 6,152.27 6,012.27 -1,072.28 -730.22 5,942,332.24 507,881.03 7.22 -1,072.28 MWD(5) 7,350.93 89.20 35.23 6,151.82 6,011.82 -1,047.47 -711.84 5,942,357.07 507,899.38 13.61 -1,047.47 MWD(5) 7,380.17 87.42 3412 6,152.68 6,012.68 -1,023.44 -695.21 5,942,381.12 507,915.98 7.17 -1,023.44 MWD(5) 7,410.17 88.16 33.66 6,153.83 6,013.83 -998.55 -678.50 5,942,406.02 507,932.66 2.90 -998.55 MWD(5) g 7,440.21 88.89 32.67 6,154.61 6,014.61 -973.41 -662.07 5,942,431.18 507,949.06 4.09 -973.41 MWD(5) 7,471.45 90.37 34.66 6,154.81 6,014.81 -947.42 -644.75 5,942,457.19 507,966.34 7.94 -947.42 MWD(5) 7,500.40 91.01 38.46 6,154.46 6,014.46 -924.17 -627.51 5,942,480.46 507,983.56 13.31 -924.17 MWD(5) 7,524.99 90.61 40.02 6,154.11 6,014.11 -905.13 -611.96 5,942,499.52 507,999.09 6.55 -905.13 MWD(5) 1 7,556.53 89.14 40.36 6,154.18 6,014.18 -881.03 -591.61 5,942,523.63 508,019.41 4.78 -881.03 MWD(5) 7,585.53 88.80 40.58 6,154.70 6,014.70 -858.98 -572.79 5,942,545.71 508,038.20 1.40 -858.98 MWD(5) 7,616.23 87.79 41.20 6,155.62 6,015.62 -835.78 -552.70 5,942,568.92 508,058.26 3.86 -835.78 MWD(5) 7,646.10 87.79 39.73 6,156.77 6,016.77 -813.07 533.33 5,942,591.65 508,077.60 4.92 -813.07 MWD(5) 7,676.32 88.31 38.18 6,157.80 6,017.80 -789.58 -514.34 5,942,615.16 508,096.56 5.41 -789.58 MWD(5) 1/102018 6:29:07PM Page 3 COMPASS 5000.14 Build 85 • S ConocoPhillips BA4Eates 48 ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2G-15 Project: Kupamk River Unit TVD Reference: 2G-15 i 140.00usft(2G-15) Site: Kuparuk 2G Pad MD Reference: 2G-15 @ 140.00usft(2G-15) Well: 2G-15 North Reference: True Wellbore: 2G-15 Survey Calculation Method: Minimum Curvature Design: 2G-15 Database: EDT Alaska Sandbox Survey Map Map Vertical MD Inc AN TVD TVDSS +N/-S +EI-W DLS Northing Easting Section Survey Tool Name Annotation (usft) (') PP ) Omni (usft) (usft). (ft) (ft) plow) (ft) 7,705.73 88.74 36.17 6,158.55 6,018.55 -766.16 -496.58 6942 638 60 558,114.30 6.99 -766.16 MWD(5) 7,735.59 90.22 3227 6,158.83 6,018.83 -741.48 479.79 5,942,663.30 508,131.06 13.97 -741.48 MWD(5) 1 ( 7,765.71 90.74 29.23 6,158.57 6,018.57 -715.59 -464.39 5,942,689.20 508,146.42 10.24 -715.59 MWD(5) 7,795.58 91.41 26.94 6,158.01 6,018.01 -689.25 -450.33 5,942,715.56 508,160.45 7.99 -689.25 MWD(5) 7,825.91 9264 25.01 6,156.94 6,016.94 -662.00 -437.06 5,942,742.82 508,173.69 7.54 -662.00 MWD(5) 7,858.17 91.91 22.83 6,155.66 6,015.66 -632.54 -423.99 5,942,772.29 508,186.73 7.12 -632.54 MWD(5) 7,887.43 90.18 21.03 6,155.13 6,015.13 -605.40 -413.06 5,942,799.44 508,197.62 8.53 -605.40 MWD(5) 7,917.56 91.08 17.93 6,154.79 6,014.79 -577.00 -403.02 5,942,827.85 508,207.63 10.71 -577.00 MWD(5) 7,948.29 91.04 17.86 6,154.23 6,014.23 -547.76 -393.58 5,942,857.09 508,217.04 0.26 -547.76 MWD(5) 7,978.45 91.10 15.36 6,153.66 6,013.66 -518.87 -384.96 5,942,885.99 508,225.62 8.29 -518.87 MWD(5) 8,006.69 90.46 14.58 6,153.28 6,013.28 491.59 -377.66 5,942,913.28 508,232.88 3.57 491.59 MWD(5) 8,036.73 88.99 10.60 6,153.42 6,013.42 462.28 -371.12 5,942,942.59 508,239.40 14.12 462.28 MWD(5) 8,066.84 90.25 6.91 6,153.62 6,013.62 432.53 -366.54 5,942,972.35 508,243.94 12.95 -432.53 MWD(5) 8,098.01 90.18 5.60 6,153.51 6,013.51 -401.54 -363.14 5,943,003.33 508,247.30 4.21 401.54 MWD(5) , 8,128.07 88.80 2.13 6,153.77 6,013.77 -371.56 -361.11 5,943,033.32 508,249.30 12.42 -371.56 MWD(5) 8,157.58 89.54 359.17 6,154.20 6,014.20 -342.06 -360.78 5,943,062.82 508,249.60 10.34 -342.06 MWD(5) 8,186.41 90.98 357.82 6,154.07 6,014.07 -313.24 -361.54 5,943,091.63 508,248.81 6.85 -313.24 MWD(5) 8,221.45 90.80 353.94 6,153.53 6,013.53 -278.30 -364.05 5,943,126.56 508,246.25 11.08 -278.30 MWD(5) 8,248.46 92.70 353.58 6,152.70 6,012.70 -251.46 -366.99 5,943,153.39 508,243.29 7.16 -251.46 MWD(5) 8,277.48 92.61 352.02 6,151.36 6,011.36 -222.70 -370.62 5,943,182.15 508,239.62 5.38 -22270 MWD(5) 8,307.61 91.41 350.64 6,150.30 6,010.30 -192.94 -375.16 5,943,211.90 508,235.05 6.07 -192.94 MWD(51 8,337.81 91.44 349.76 6,149.55 6,009.55 -163.19 -380.30 5,943,241.64 508,229.88 2.91 -163.19 MWD(5) 8,367.69 89.91 348.31 6,149.20 6,009.20 -133.86 -385.98 5,943,270.97 508,224.16 7.05 -133.86 MWD(5) 8,397.99 89.02 346.67 6,149.48 6,009.48 -104.28 -392.54 5,943,300.53 508,217.56 6.16 -104.28 MWD(5) 8,427.20 86.80 342.34 6,150.54 6,010.55 -76.16 -400.34 5,943,328.64 508,209.74 16.65 -76.16 MWD(5) 8,457.47 89.11 34203 6,151.63 6,011.63 -47.36 -409.59 5,943,357.43 508,200.45 7.70 -47.36 MWD(5) 8,487.77 90.18 341.16 6,151.81 6,011.81 -18.61 419.16 5,943,386.16 508,190.85 4.55 -18.61 MWD(5) 8,52277 90.37 339.94 6,151.64 6,011.65 14.39 -430.81 5,943,419.15 508,179.16 3.53 14.39 MWD(5) 8,548.25 88.59 337.70 6,151.88 6,011.88 38.15 -440.02 5,943,442.89 508,169.93 11.23 38.15 MWD(5) S 8,577.23 89.42 337.16 6,152.38 6,012.38 64.90 -451.14 5,943,469.63 508,158.78 3.42 64.90 MWD(5) 8,609.60 89.91 339.03 6,15257 6,01257 94.93 -463.22 5,943,499.65 508,146.67 5.97 94.93 MWD(5) 1/10!2018 6:29:07PM Page 4 COMPASS 5000.14 Build 85 1 • • ConocoPhillips 641,,r, CI ConocoPhillips Definitive Survey Report liGt+ Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 20-15 Project: Kuparuk River Unit TVD Reference: 2G-15 c 140.00usft(20-15) Site: Kuparuk 2G Pad MD Reference: 2G-15©140.00usft(20-15) Well: 2G-15 North Reference: True Wellbore: 20-15 Survey Calculation Method: Minimum Curvature Design: 2G-15 Database: EDT Alaska Sandbox Survey Map MD Inc Azi 'NG -N +NI-S +EW-W Noitill� EMap st ng DLS Vertical Section Survey Tool Name Annotation (usft( (°) 19: ttrsih (moi to ) iUS1t and et) (°110x) (ft) 1 8,637.33 91.29 337.74 6,152.28 6,012.28 120.71 -473.43 5,943,525.41 508,136.43 6.81 120.71 MWD(5) 8,668.30 92.15 340.79 6,151.35 6,011.35 149.66 -484.39 5,943.554.34 508,125.44 10.23 149.66 MWD(5) 8,698.58 93.47 342.09 6,149.86 6,009.86 178.33 -494.01 5,943,583.00 508,115.78 6.11 178.33 MWD(5) 8,728.25 93.69 343.55 6,148.01 6,008.01 206.62 -502.76 5,943,611.27 508,107.00 4.97 206.62 MWD(5) 8,761.23 92.66 343.97 6,146.13 6,006.13 238.23 -511.97 5,943,642.87 508,097.76 2.82 238.23 MWD(5) 8,795.46 93.57 347.01 6,144.21 6,004.21 271.31 -520.53 5,943,675.94 508,089.16 9.11 271.31 MWD(5) 8,828.81 90.83 348.14 6,142.93 6,002.93 303.85 -527.70 5,943,708.47 508,081.96 8.89 303.85 MWD(5) 8,860.91 89.54 348.37 6,142.82 6,002.82 335.28 -534.23 5,943,739.89 508,075.39 4.08 335.28 MWD(5) l. 8,890.78 88.65 349.49 6,143.29 6,003.30 364.59 -539.97 5,943,769.19 508,069.62 4.79 364.59 MWD(5) 8,926.19 89.08 351.15 6,144.00 6,004.00 399.49 -545.92 5,943,804.07 508,063.63 4.84 399.49 MWD(5) 8,958.33 90.92 354.05 6,144.00 6,004.00 431.36 -550.06 5,943,835.93 508,059.45 10.69 431.36 MWD(5) 8,986.11 92.70 355.01 6,143.12 6,003.12 456.99 -552.71 5,843,663.57 508,056.77 7.28 458.99 MWD(5) 9,018.19 90.68 356.33 6,142.17 6,002.17 490.97 -555.13 5,943,895.53 508,054.32 7.52 490.97 MWD(5) 9,055.88 90.49 358.26 6,141.79 6,001.79 528.61 -556.91 5,943,933.17 508,052.50 5.15 528.61 MWD(5) l 9,084.85 90.12 359.65 6,141.63 6,001 63 557.57 -557.43 5,943,962.13 508,051.93 4.97 557.57 MWD(5) 3 9,109.81 91.04 0.92 6,141.38 6,001.38 582.53 -557.31 5,943,987.09 508,052.03 6.28 582.53 MWD(5) 9,140.44 91.07 359.77 6,140.82 6,000.82 613.16 -557.13 5,944,017.71 508,052.18 3.76 613.16 MWD(5) 9,173.06 89.69 3.29 6,140.60 6,000.60 645.76 -556.25 5,944,050.31 508,053.01 11.59 645.76 MWD(5) i I 9,205.23 90.31 5.94 6,140.60 6,000.60 677.82 -553.67 5,944,082.37 508,055.56 8.46 677.82 MWD(5) j 9,235.43 90.40 7.41 6,140.41 6,000.41 707.81 -550.16 5,944,112.36 508,059.04 4.88 707.81 MWD(5) 9,264.93 89.94 7.84 6,140.33 6,000.33 737.05 -546.24 5,944,141.60 508,062.92 2.13 737.05 MWD(5) 9,299.63 90.74 7.76 6,140.12 6,000.12 771.43 -541.53 5,944,175.98 508,067.59 2.32 771.43 MWD(5) S g 9,330.56 91.69 11.10 6,139.46 5,999.46 801.93 -536.47 5,944,206.49 508,072.62 11.22 801.93 MWD(5) d 9,360.37 91.32 14.00 6,138.68 5,998.88 831.02 -529.99 5,944,235.58 508,079.06 9.80 831.02 MWD(5) 9,390.41 94.00 15.27 6,137.29 5,997.29 860.05 -522.41 5,944,264.61 508,086.61 9.87 860.05 MWD(5) i 9,420.55 95.04 15.69 6,134.91 5,994.91 889.00 -514.39 5,944,293.58 508,094.59 3.72 889.00 MWD(5) 9,450.85 95.41 18.90 6,132.15 5,992.15 917.81 -505.42 5,944,322.39 508,103.53 10.62 917.81 MWD(5) 9,480.60 96.07 20.55 6,129.18 5,989.18 945.67 -495.43 5,944,350.26 508,113.48 5.95 945.67 MWD(5) I 9,511.69 95.10 23.97 6,126.15 5,986.15 974.30 -483.71 5,944,378.90 508,125.17 11.38 974.30 MWD(5) 9,541.17 95.73 25.47 6,123.37 5,983.37 1,000.96 -471.44 5,944,405.57 508,137.41 5.50 1,000.96 MWD(5) 9 571 09 95.35 2fi 49 6,120 48 5 980 48 1,027 73 -458.40 5,944 432 35 508 150.42 3 62 1 027 73 MWD(5) 1/10/2018 6:29:07PM Page 5 COMPASS 5000.14 Build 85 • ConocoPhillips EIA4bErAl vs 42 ConocoPhillips p Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2G-15 Project: Kuparuk River Unit TVD Reference: 2G-15 Q 140.00usft(2G-15) I Site: Kuparuk 2G Pad MD Reference: 20-15(g 140.00usft(2G-15) Well: 2G-15 North Reference: True Wellbore: 2G-15 Survey Calculation Method: Minimum Curvature Design: 2G-15 Database: EDT Alaska Sandbox survey I. Map MD Inc Azi TVD TVDSS ate-S +E/-W Map DLS Vertical Mamba% Fasting Section Survey Tool Name Annotation (set) (°) 17/ (usft) (usft) tush tus t) ', (ft) (h) (°1100) (n) 9,600.52 92.27 24.82 6,118 52 5,978.52 1,054.20 445.69 5,944,458.83 508,163.10 11.90 1,054.20 MWD(5) 9,630.63 91.60 20.73 6,117.51 5,977.51 1,081.94 434.04 5,944,486.58 508,174.72 13.76 1,081.94 MWD(5) 9,660.85 92.21 18.98 6,116.50 5,976.50 1,110.34 423.78 5,944,515.00 508,184.94 6.13 1,110.34 MWD(5) 9,691.04 93.81 16.08 6114.92 5,974.92 1,139.09 -414.70 5,944,543.75 508,193.99 10.96 1,139.09 MWD(5) 1 9,721.44 92.06 14.10 6,113.36 5,973.36 1,168.40 406.80 5,944,573.07 508,201.86 8.69 1,168.40 MWD(5) 9,750.75 91.53 11.30 6,112.44 5,972.44 1,196.98 400.36 5,944,601.65 508,208.26 9.72 1,196.98 MWD(5) 9,780.27 92.55 9.17 6,111.39 5,971.39 1,226.01 -395.12 5,944,630.68 508,213.47 8.00 1,226.01 MWD(5) 9,810.47 95.22 9.26 6,109.34 5,969.34 1,255.74 -390.29 5,944,660.42 508,218.26 8.85 1,255.74 MWD(5) 9,840.03 94.61 6.95 6,106.81 5,966.81 1,284.90 -386.14 5,944,689.58 508,222.38 8.05 1,284.90 MWD(5) 9,870.45 92.45 7.06 6,104.94 5,964.94 1,315.03 -382.44 5,944,719.71 508,226.05 7.11 1,315.03 MWD(5) E 9,900.13 89.82 5.53 6,104.35 5,964.35 1,344.53 -379.18 5,944,749.21 508,229.27 10.25 1,344.53 MWD(5) 9,930.79 89.26 3.82 6,104.60 5,964.60 1,375.08 -376.69 5,944,779.76 508,231.73 5.87 1,375.08 MWD(5) 9,960.21 88.25 2.46 6,105.24 5,965.24 1,404.45 -375.07 5,944,809.13 508,233.31 5.76 1,404.45 MWD(5) 9,990.19 87.72 0.85 6,106.29 5,966.29 1,434.40 -374.21 5,944,839.07 508,234.14 5.65 1,434.40 MWD(5) 10,020.19 87.23 359.95 6,107.61 5,967.61 1,464.37 -374.00 5,944,869.04 508,234.31 3.41 1,464.37 MWD(5) 10,050.32 86.25 358.90 6,109.33 5,969.33 1,494.45 -374.30 5,944,899.12 508,233.98 4.76 1,494.45 MWD(5) 10,084.90 85.88 359.48 6,111.70 5,971.70 1,528.94 -374.79 5,944,933.61 508,233.45 1.99 1,528.94 MWD(5) • 10,118.50 86.99 1.58 6,113.79 5,973.79 1,562.47 -374.48 5,944,967.14 508,233.72 7.06 1,562.47 MWD(5) 10,146.81 86.53 2.38 6,115.39 5,975.39 1,590.72 -373.50 5,944,995.38 508,234.67 3.26 1,590.72 MWD(5) 10,179.02 85.67 3.19 6,117.58 5,977.58 1,622.82 -371.94 5,945,027.48 508,236.19 3.66 1,622.82 MWD(5) i 10,208.54 86.37 5.23 6,119.63 5,979.63 1,652.18 -369.78 5,945,056,84 508,238.32 7.29 1,652.18 MWD(5) 10,238.57 88.15 7.73 6,121.06 5,981.06 1,681.98 -366.39 5,945,086.65 508,241.67 10.21 1,681.98 MWD(5) 10,265.65 89.32 10.11 6,121.66 5,981.66 1,708.73 -362.20 5,945,113.39 508,245.84 9.79 1,708.73 MWD(5) 10,298.64 90.18 10.84 6,121.81 5,981.81 1,741.17 -356.20 5,945,145.83 508,251.80 3.42 1,741.17 MWD(5) 10,328.07 90.71 12.24 6,121.58 5,981.58 1,770.00 -350.31 5,945,174.67 508,257.65 5.09 1,770.00 MWD(5) 10,358.63 91.63 11.95 6,120.95 5,980.95 1,799.88 -343.91 5,945,204.55 508,264.02 3.16 1,799.88 MWD(5) I. 10,388.59 91.07 13.54 6,120.25 5,980.25 1,829.09 -337.30 5,945,233.77 508,270.59 5.63 1,829.09 MWD(5) 10,418.71 92.46 14.61 6,119.32 5,979.32 1,858.29 -329.98 5,945,262.97 508,277.88 5.82 1,858.29 MWD(5) 10,448.59 93.35 16.85 6,117.80 5,977.80 1,887.01 -321.89 5,945,291.70 508,285.93 8.06 1,887.01 MWD(5) 10,480.81 93.07 18.13 6,116.00 5,976.00 1,917.69 -312.22 5,945,322.39 508,295.57 4.06 1,917.69 MWD(5) 10,508.60 91.96 19.09 6,114.78 5,974.78 1,944.00 -303.36 5,945,348.71 508,304.39 5.28 1,944.00 MWD(5) s 1/10/2018 6:29:07PM Page 6 COMPASS 5000.14 Build 85 -. • 0 Iv' ConocoPhillips SAAR$$ ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2G-15 Project: Ku paruk River Unit IVO Reference: 12G-15 @ 140.00usft(2G-15) Site: Kupamk 2G Pad MD Reference: '.2G-15 @ 140.00usft(2G-15) Well: 20-15 North Reference: True Wellbore: 2G-15 Survey Calculation Method: (Minimum Curvature Design: 20-15 Database: '.EDT Alaska Sandbox Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-5 +E!-SI DLS tt) (°J (°) (usft) (usft) (usft Northing Fasting Section Survey Tool Name Annotation (us ;usft) (rt) t►t) (°/1001 (ft) 10,540.13 90.40 17.23 6,114.13 5,974.13 1,973.95 -293.54 5,945,378.67 508,314.18 7.70 1,973.95 MWD(5) 10,570.85 89.79 14.01 6,114.08 5,974.08 2,003.54 -285.27 5,945,408.26 508,322.42 10.67 2,003.54 MWD(5) 10,590.43 90.34 14.08 6,114.06 5,974.06 2,022.53 -280.52 5,945,427.26 508,327.15 2.83 2,022.53 MWD(5) 10,618.15 91.17 13.61 6,113.69 5,973.69 2,049.44 -273.88 5,945,454.17 508,333.75 3.44 2,049.44 MWD(5) 10,649.95 91.38 12.24 6,112.99 5,972.99 2,080.43 -266.77 5,945,485.16 508,340.82 4.36 2,080.43 MWD(5) 10,685.13 88.62 8.67 6,112.99 5,972.99 2,115.01 -260.39 5,945,519.75 508,347.17 12.83 2115.01 MWD(5) i 10,719.17 88.77 7.22 6,113.76 5,973.76 2,148.72 -255.69 5,945,553.46 508,351.83 4.28 2148.72 MWD(5) 10,750.00 89.91 5.96 6,114.12 5,974.12 2179.34 -252.15 5,945,584.08 508,355.33 5.51 2,179.34 MWD(5) S 10,775.11 90.12 3.57 6,114.11 5,974.11 2,204.36 -250.06 5,945,609.11 508,357.39 9.55 2,204.36 MWD(5) 10,809.89 90.09 4.26 6,114.05 5,974.05 2,239.06 -247.69 5,945,643.80 508,359.73 1.99 Z239.06 MWD(5) 10,835.19 90.49 2.75 6,113.92 5,973.92 2,264.31 -246.14 5,945,669.05 508,361.24 6.17 2,264.31 MWD(5) 10,860.34 91.26 1.99 6,113.53 5,973.53 2289.44 -245.10 5,945,694.18 508,362.25 4.30 2,289.44 MWD(5) 10,890.52 92.46 0.34 6,112.55 5,972.55 2319.59 -244.49 5,945,724.33 508,362.83 6.76 2,319.59 MWD(5) 10,919.74 93.75 356.77 6,110.97 5,970.97 2348.76 -245.22 5,945,753.49 508,362.06 12.97 2,348.76 MWD(5) I 10,950.39 91.72 356.92 6,109.51 5,969.51 2,379.32 -246.91 5,945,784.05 508,360.35 6.64 2,379.32 MWD(5) I10,981.98 91.69 355.35 6,108.57 5,968.57 2410.83 -249.04 5,945,815.55 508,358.18 4.97 2,410.83 MWD(5) I11,013.36 92.77 353.84 6,107.35 5,967.35 2,442.04 -251.99 5,945,846.76 508,355.19 5.91 2,442.04 MWD(5) 11,049.79 91.23 348.06 6,106.07 5,966.07 2,477.98 -257.72 5,945,882.69 508.349.43 16.41 2,477.98 MWD(5) 11,078.10 92.24 350.63 6,105.22 5,965.22 2,505.79 -262.95 5,945,910.48 508,344.16 9.75 2,505.79 MWD(5) p 11,106.76 91.17 349.27 6,104.36 5,964.36 2,533.99 -267.95 5,945,938.68 508,339.13 6.04 2533.99 MWD(5) 3333333 11,130.13 90.98 348.01 6,103.93 5,963.93 2,556.90 -272.55 5,945,961.58 508,334.51 5.45 2,556.90 MWD(5) i 11,167.00 90.98 348.01 6,103.30 5,963.30 2,592.96 -280.21 5,945,997.63 508,326.81 0.00 2,592.96 PROJECTED to TD 1. 1/10/2018 6:29:07PM Page 7 COMPASS 5000.14 Sulk!85 i STATE OF ALASKA IL AND GAS CONSERVATION COM All/KAO •,ION RECEIVED PERMIT TO DRILL 20 AAC 25.005 77 la.Type of Work: lb.Proposed Well Class: Exploratory-Gas ❑ Service- WAG ❑ Service-Disp El1 c Tify2f hell�(�4�'�roposed for: Drill ❑ Lateral• ❑� Stratigraphic Test ❑ Development-Oil ❑✓ •Service- Winj ❑ Single Zone ❑., - Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Ge G e0jGas CI2.Operator Name: 5. Bond: Blanket ❑� - Single Well ❑ 11. I ame and Number: ConocoPhillips Alaska Inc Bond No. 5952180 , KRU 2G-15L1-01 N 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 11200' ' TVD: 5976' 4a. Location of Well(Governmental Section): 7.Property Designation: Kuparuk River Pool/• rr//.�f Kuparuk River Oil Pool, Surface: 183'FNL,88'FEL,Sec 6,T10N,R9E,UM ADL 25667 i 9.5.65(2., Top of Productive Horizon: 8.DNR Approval Number: 13.Approximate Spud Date: 1414'FNL,941'FEL,Sec 6,T10N,R9E,UM LONS 82-180 11/3/2017 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 2871'FNL,286'FEL,Sec 31,T11N,R9E,UM 2501 ' 7r(1 '9i13136' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): 140' • 15.Distance to Nearest Well Open Surface: x- 508610 y- 5943405 Zone- 4 ' GL/BF Elevation above MSL(ft): 105' , to Same Pool: 303' (2G-02) 16.Deviated wells: Kickoff depth: 7200 feet ' 17.Maximum Potential Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 97 degrees- Downhole: 4379 • Surface: 3768 • 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2-3/8" 4.7# L-80 ST-L 4250' 6950' 6019' 11200' 5976' Slotted 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): 6997' 6346' N/A 6900' 6277' N/A Casing Length Size Cement Volume MD TVD Conductor/Structural 70' 16" 202 sx Cold Set II 105' 105' Surface 2693' 9-5/8" 735 sx Permafrost E&370 sx Permafrost C 2727' 2726' Production 6950' 7" 340 sx Class G 6983' 6336' Perforation Depth MD(ft): 6566'-6580' Perforation Depth TVD(ft): 6044'-6054' 6658'-6728' 6107'-6156' Hydraulic Fracture planned? Yes❑ No ❑., 20. Attachments: Property Plat ❑ BOP Sketch — Drilling Program 7 Time v.Depth Plot — Shallow Hazard Analysis— Diverter Sketch Seabed Report = Drilling Fluid Program ✓ 20 AAC 25.050 requirements 7 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: William Long Authorized Name: Kai Starck Contact Email: WilIiam.R.Lonq(c�COP.com Authorized Title: CTD Director Contact Phone: 263-4372 Authorized Signature: o /AA. NDate:` - Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: Q,7- t y 7' 50- OL — .1 16 a - i -- Date: 1/ 1 11 requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: IX Other: 0.6p y-e�t -to 4-S,o Q p 4 Samples req'd: Yes❑ No Zi Mud log req'd:Yes❑ No Wr f- -to 25-00 easures: Yes I No Directional svy req'd:Yes �nvrvlcl� pf�<�f�tf✓ 5 \ d �z� L1J ❑ Y q' No El A Va ria Y)C C 1 D a O 4,4-c 2 5. 615(b) Spacing exception req'd: Yes❑ No Zf Inclination-only svy req'd:Yes❑ No Q,,,, i5r?v)--fd 'f O a 1 I D - tk c k i`c ICG if pc))k t be 4 vi l� Post initial injection MIT req'd:Yes❑ No pd�'v- fialon1 fl/7t pareKO- I4-Fr ra- I (LaDcr BY t i I \1 Approved by: C�RICW I NAL ISSION Date: �(�, ��/�`0� //ddb Submit Form and GIS L�\l F rm 10-�11 via /5 17 /1 14 rdhit is valid for 24 months from the date of approval per 20 AAC 25.005(g) Attachments in Duplicate ( T f7 • • ConocoPhillis p Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 October 23, 2017 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 four laterals out of the newly worked over KRU 2G-15 (PTD# 184-131)well using the coiled tubing drilling rig, Nabors CDR3-AC. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. The work is scheduled to begin early November 2017. The objective will be to drill four laterals KRU 2G-15L1, 2G-15L1-01, 2G-15L1-02, and 2G-15L1-03 targeting the Kuparuk A-sands. Attached to this application are the following documents: — Permit to Drill Application Forms (10-401) for 2G-15L1, 2G-15L1-01, 2G-15L1-02, and 2G-15L1-03 — Detailed Summary of Operations — Directional Plans for 2G-15L1, 2G-15L1-01, 2G-15L1-02, and 2G-15L1-03 — Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-263-4372. Sincerely, 4// William R. Long Coiled Tubing Drilling Engineer ConocoPhillips Alaska • ll. Kuparuk CTD Laterals Osy2G-15L1, 2G-15L1-01, 2G-15L1-02, & 2G-15L1-03 ConocoPhOps Application for Permit to Drill Document 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 AA C 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 4 (Requirements of 20 AAC 25.005(c)(13)) 4 Summary of Operations 4 Liner Running 5 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. Attachments 6 Attachment 1: Directional Plans for2G-15L1, 2G-15L1-01,2G-15L1-02, and 2G-15L1-03 laterals 6 Attachment 2: Current Well Schematic for 2G-15 6 Attachment 3: Proposed Well Schematic for 2G-15L1, 2G-15L1-01,2G-15L1-02, and 2G-15L1-03 laterals. 6 Page 1 of 6 October 23,2017 • PTD Application: 2G-15L1, 2L1-01, 2G-15L1-02, and 2G-15L1-03 1. Well Name and Classification (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b)) The proposed laterals described in this document are 2G-15L1, 2G-15L1-01, 2G-15L1-02, and 2G-15L1-03. All laterals will be classified as"Development-Oil" wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 forms for surface and subsurface coordinates of the 2G-15L1, 2G-15L1-01, 2G-15L1-02, and 2G-15L1-03 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 CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4,500 psi. Using the maximum formation pressure in the area of 4,379 psi in 2G-12A(i.e. 13.9 ppg EMW), the maximum potential surface pressure in 2G-15, assuming a gas gradient of 0.1 psi/ft, would be 3,768 psi. See the "Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005(c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005(c)(4)(a)) The formation pressure in KRU 2G-15 was measured to be 3,786 psi (11.8 ppg EMW) on 10/17/2017. The maximum downhole pressure in the 2G-15 vicinity, is the 2G-12A at 4,379 psi (13.9 ppg EMW)from July 2017. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) The offset injection wells to 2G-15 have injected gas, so there is a chance of encountering free gas while drilling the 2G-15 laterals. If significant gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected risk of hole problems in the 2G-15 laterals will be shale instability across faults. Managed pressure drilling (MPD)will be used to reduce the risk of shale instability associated with fault crossings. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 2G-15 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 6 October 23,2017 • PTD Application: 2G-15L1, 2G-15L1-01, 2G-15L1-02, and 2G-15L1-03 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Liner Top Liner Btm Liner Top Liner Btm Lateral Name MD MD TVDSS TVDSS Liner Details 2G-15L1 7,200' 11,200' 6,019' 6,001' 2% , 4.7#, L-80, ST-L slotted liner, aluminum billet on top 2G-15L1-01 6,950' 11,200' 6,019' 5,976' 2%", 4.7#, L 80, ST-L slotted liner; aluminum billet on top 2G-15L1-02 7,100' 9,500' 6,009' 6,047' 2%', 4.7#, L-80, ST-L slotted liner, aluminum billet on top 2K-04L1-03 6,658' 9,500' 5,967' 6,025' 2%", 4.7#, L-80, ST-L slotted liner, deployment sleeve on top Existing Casing/Liner Information Category OD Weight Grade Connection Top MD Btm MD Top Btm Burst Collapse (PO TVD TVD psi psi Conductor 16" 62.5 H-40 Welded 35' 105' 36' 105' 1,640 670 Surface 9-5/8" 36 J-55 BTC 34' 2,727' 34' 2,726' 3,520 2,020 Production 7" 26 J-55 BTC 33' 6,983' 33' 6,336' 4,980 4,320 Tubing 3-1/2" 9.3 L-80 EUE 32' 6,680' 32' 6,123' 10,160 10,540 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride-based FloVis mud (8.7 ppg) — Drilling operations: Chloride-based FloVis mud (8.7 ppg)./This mud weight will not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: The well will be loaded with 12.0 ppgNaBr completion fl id topr provide formation over-balance and well bore stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5,000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". In the 2G-15 laterals we will target a constant BHP of 12.0 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Page 3 of 6 October 23,2017 • PTD Application: 2G-15L1, 2•L1-01, 2G-15L1-02, and 2G-15L1-03 Pressure at the 2G-15 Window(6,663' MD, 6111' TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure (11.8 ppg) 3786 psi 3786 psi Mud Hydrostatic (8.7 ppg) 2765 psi 2765 psi Annular friction (i.e. ECD, 0.080 psi/ft) 533 psi 0 psi Mud + ECD Combined 3298 psi 2765 psi (no choke pressure) (underbalanced —488 psi) (underbalanced —1021 psi) Target BHP at Window(12.0 ppg) 3813 psi 3813 psi Choke Pressure Required to Maintain 515 psi 1048 psi Target BHP 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AA C 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well 2G-15 is a Kuparuk A-sand and C-sand producer equipped with 3-1/2"tubing and 7"production casing. A recent rig workover installed new 3-1/2"tubing, and a big tail pipe to facilitate CTD laterals. The laterals will target the A-sands to the north and south of the 2G-15 parent wellbore. The project will improve the ultimate recovery in the parent pattern as well as provide offtake from the patterns to the north and the south. Pre-CTD Work 1. Perform RWO to install new 3-1/2"tubing and big tail pipe. 2. RU Slickline: Perform a dummy whipstock drift. 3. RU E-line: Obtain jewelry log and set 3-1/2"x 4-1/2"whipstock at 6,663' MD. 4. Prep site for Nabors CDR3-AC. Rig Work 1. MIRU Nabors CDR3-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 2G-15L1 Lateral(A4 sand-North) a. Mill 2.80"window at 6,663' MD. Page 4 of 6 October 23,2017 • PTD Application: 2G-15L1, 2G-15L1-01, 2G-15L1-02, and 2G-15L1-03 b. Drill 3"bi-center lateral to TD of 11,200' MD. c. Run 2-3/8" slotted liner with an aluminum billet from TD up to 7,200' MD. 3. 2G-15L1-01 Lateral(A4 sand-North) I a. Kick off the aluminum billet at 7,200' MD. b. Drill 3"bi-center lateral to TD of 11,200' MD. c. Run 2-3/8" slotted liner with an aluminum billet from TD up to 6,950' MD. 4. 2G-15L1-02 Lateral (A4 sand - South) a. Kick off the aluminum billet at 6,950' MD. b. Drill 3"bi-center lateral to TD of 9,500' MD. c. Run 2-3/8" slotted liner from TD up into the tubing tail at 7,100' MD. 5. 2G-15L1-03 Lateral(A4 sand - South) a. Kick off the aluminum billet at 7,100' MD. b. Drill 3"bi-center lateral to TD of 9,500' MD. c. Run 2-3/8" slotted liner from TD up into the tubing tail at 6,658' MD. 6. Obtain SBHP, freeze protect,ND BOPE, and RDMO Nabors CDR3-AC. Post-Rig Work 1. Return to production. Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure 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 slick-line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA un-deployment, the steps listed above are observed, only in reverse. Liner Running — The 2G-15 laterals will be displaced to an overbalancing completion fluid prior to running liner. See "Drilling Fluids" section for more details. — While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. Page 5 of 6 October 23, 2017 • PTD Application: 2G-15L1, 2G-15L1-01, 2G-15L1-02, and 2G-15L1-03 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18 or 1B disposal facilities) or Prudhoe DS-4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plans — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire open hole section. — Distance to Nearest Property Line (measured to KPA boundary at closest point) *Z bistalik* 2G-15L1 13,136' 2G-15L1-01 13,136' 2G-15L1-02 6,820' 2G-15L1-03 6,820' — Distance to Nearest Well within Pool Lata1 Name Distance Well 2G-15L1 303' 2G-02 2G-15L1-01 303' 2G-02 2G-15L1-02 537' 2G-13 2G-15L1-03 537' 2G-13 16. Attachments Attachment 1: Directional Plans for 2G-15L1, 2G-15L1-01, 2G-15L1-02, and 2G-15L1-03 laterals. Attachment 2: Current Well Schematic for 2G-15 Attachment 3: Proposed Well Schematic for 2G-15L1, 2G-15L1-01, 2G-15L1-02, and 2G-15L1-03 laterals. Page 6 of 6 October 23, 2017 S ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2G Pad 2G-15 2G-15L1-01 Plan: 2G-15L1-01_wp03 Standard Planning Report 20 October, 2017 BA:4(ER UGHES a GE company 0 • ✓ ConocoPhillips BA ER1 ConocoPhillips Planning Report FlUGHES a GE company Database: EDT Alaska Sandbox Local Co-ordinate Reference: Well 2G-15 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2G-15 @ 140.00usft(2G-15) Site: Kuparuk 2G Pad North Reference: True Well: 2G-15 Survey Calculation Method: Minimum Curvature Wellbore: 2G-15L1-01 Design: 2G-15L1-01_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-15 Well Position +N/-S 0.00 usft Northing: 5,943,405.25 usft Latitude: 70°15'23.735 N +EI-W 0.00 usft Easting: 508,609.95 usft Longitude: 149°55'49.499 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 2G-15L1-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGG M2017 11/1/2017 17.28 80.85 57,474 Design 2G-150-01 wp03 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,200.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 0.00 10/20/2017 6:05:50PM Page 2 COMPASS 5000.14 Build 85 SConocoPhillips 0 AER ConocoPhillips Planning Report BUGHES d6) a GE company Database: EDT Alaska Sandbox Local Co-ordinate Reference: Well 2G-15 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2G-15 @ 140.00usft(2G-15) Site: Kuparuk 2G Pad North Reference: True Well: 2G-15 Survey Calculation Method: Minimum Curvature Wellbore: 2G-15L1-01 Design: 2G-15L1-01_wp03 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°/100ft) (°/10Oft) (°/100ft) (°) Target 7,200.00 90.00 52.09 6,019.10 -1,231.68 -849.26 0.00 0.00 0.00 0.00 7,270.00 94.24 49.63 6,016.51 -1,187.54 -795.02 7.00 6.06 -3.51 330.00 7,400.00 94.19 40.51 6,006.94 -1,096.07 -703.33 7.00 -0.04 -7.02 270.00 7,500.00 94.16 33.49 5,999.65 -1,016.47 -643.35 7.00 -0.03 -7.02 270.00 7,750.00 82.90 20.07 6,006.09 -794.25 -531.13 7.00 -4.50 -5.37 230.00 7,950.00 90.00 7.97 6,018.51 -601.05 -482.97 7.00 3.55 -6.05 300.00 8,300.00 91.66 343.53 6,013.35 -254.70 -508.70 7.00 0.47 -6.98 274.00 8,550.00 91.58 1.03 6,006.21 -8.03 -542.14 7.00 -0.03 7.00 90.00 8,700.00 89.75 11.37 6,004.47 140.87 -525.96 7.00 -1.23 6.89 100.00 8,800.00 86.25 17.44 6,007.96 237.61 -501.12 7.00 -3.49 6.07 120.00 9,000.00 86.36 3.41 6,020.90 433.40 -465.08 7.00 0.06 -7.01 270.00 9,200.00 89.59 349.78 6,028.00 632.43 -476.94 7.00 1.61 -6.82 283.00 9,400.00 96.54 1.95 6,017.27 831.12 -491.37 7.00 3.48 6.09 60.00 9,625.00 96.30 17.80 5,991.95 1,050.67 -453.14 7.00 -0.11 7.04 90.00 9,725.00 96.86 24.83 5,980.49 1,143.16 -417.06 7.00 0.56 7.02 85.00 9,925.00 90.82 12.16 5,967.04 1,331.96 -354.00 7.00 -3.02 -6.33 245.00 10,125.00 86.74 358.76 5,971.30 1,530.51 -335.01 7.00 -2.04 -6.70 253.00 10,375.00 86.90 16.29 5,985.28 1,777.00 -302.45 7.00 0.06 7.01 90.00 10,625.00 90.03 359.06 5,992.04 2,023.72 -269.24 7.00 1.25 -6.89 280.00 10,875.00 92.13 16.44 5,987.31 2,270.43 -235.68 7.00 0.84 6.95 83.00 11,200.00 91.96 353.67 5,975.56 2,591.83 -207.24 7.00 -0.05 -7.00 270.00 10/20/2017 6:05:50PM Page 3 COMPASS 5000.14 Build 85 S Conoco0 Phillips BA ER 'A' ConocoPhillips Planning Report I UGHES `" a GE company Database: EDT Alaska Sandbox Local Co-ordinate Reference: Well 2G-15 Company: ConocoPhillips(Alaska)Inc.-Kup2 ND Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2G-15 @ 140.00usft(2G-15) Site: Kuparuk 2G Pad North Reference: True Well: 2G-15 Survey Calculation Method: Minimum Curvature Wellbore: 2G-15L1-01 Design: 2G-15 L 1-01_w p03 Planned Survey Measured ND Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +EI-W Section Rate Azimuth Northing Easting (usft) (o) (o) (usft) (usft) (usft) (usft) (°/100ft) (0) (usft) (usft) 7,200.00 90.00 52.09 6,019.10 -1,231.68 -849.26 -1,231.68 0.00 0.00 5,942,172.72 507,762.18 TIP/KOP 7,270.00 94.24 49.63 6,016.51 -1,187.54 -795.02 -1,187.54 7.00 -30.00 5,942,216.92 507,816.36 Start 7 dls 7,300.00 94.24 47.53 6,014.29 -1,167.75 -772.59 -1,167.75 7.00 -90.00 5,942,236.74 507,838.77 7,400.00 94.19 40.51 6,006.94 -1,096.07 -703.33 -1,096.07 7.00 -90.16 5,942,308.48 507,907.94 3 7,500.00 94.16 33.49 5,999.65 -1,016.47 -643.35 1,016.47 7.00 -90.00 5,942,388.15 507,967.82 4 7,600.00 89.65 28.13 5,996.33 -930.68 -592.20 -930.68 7.00 -130.00 5,942,473.99 508,018.88 7,700.00 85.14 22.77 6,000.88 -840.54 -549.29 -840.54 7.00 -130.18 5,942,564.17 508,061.68 7,750.00 82.90 20.07 6,006.09 -794.25 -531.13 -794.25 7.00 -129.93 5,942,610.47 508,079.78 5 7,800.00 84.66 17.02 6,011.51 -747.14 -515.32 -747.14 7.00 -60.00 5,942,657.60 508,095.53 7,900.00 88.21 10.98 6,017.73 -650.35 -491.20 -650.35 7.00 -59.67 5,942,754.40 508,119.54 7,950.00 90.00 7.97 6,018.51 -601.05 -482.97 -601.05 7.00 -59.29 5,942,803.71 508,127.71 6 8,000.00 90.25 4.48 6,018.40 -551.35 -477.55 -551.35 7.00 -86.00 5,942,853.41 508,133.08 8,100.00 90.73 357.50 6,017.55 -451.43 -475.82 -451.43 7.00 -86.01 5,942,953.32 508,134.69 8,200.00 91.21 350.51 6,015.85 -352.06 -486.26 -352.06 7.00 -86.07 5,943,052.67 508,124.14 8,300.00 91.66 343.53 6,013.35 -254.70 -508.70 -254.70 7.00 -86.19 5,943,149.99 508,101.59 7 8,400.00 91.65 350.53 6,010.46 -157.36 -531.13 -157.36 7.00 90.00 5,943,247.30 508,079.06 8,500.00 91.61 357.53 6,007.61 -58.00 -541.52 -58.00 7.00 90.20 5,943,346.64 508,068.55 8,550.00 91.58 1.03 6,006.21 -8.03 -542.14 -8.03 7.00 90.40 5,943,396.60 508,067.87 8 8,600.00 90.97 4.48 6,005.10 41.89 -539.74 41.89 7.00 100.00 5,943,446.52 508,070.22 8,700.00 89.75 11.37 6,004.47 140.87 -525.96 140.87 7.00 100.08 5,943,545.51 508,083.88 9 8,800.00 86.25 17.44 6,007.96 237.61 -501.12 237.61 7.00 120.00 5,943,642.26 508,108.61 10 8,900.00 86.28 10.43 6,014.48 334.40 -477.10 334.40 7.00 -90.00 5,943,739.07 508,132.51 9,000.00 86.36 3.41 6,020.90 433.40 -465.08 433.40 7.00 -89.54 5,943,838.08 508,144.42 11 9,100.00 87.96 356.59 6,025.86 533.22 -465.09 533.22 7.00 -77.00 5,943,937.88 508,144.30 9,200.00 89.59 349.78 6,028.00 632.43 -476.94 632.43 7.00 -76.66 5,944,037.07 508,132.33 12 9,300.00 93.08 355.85 6,025.67 731.55 -489.45 731.55 7.00 60.00 5,944,136.17 508,119.71 9,400.00 96.54 1.95 6,017.27 831.12 -491.37 831.12 7.00 60.14 5,944,235.72 508,117.67 13 9,500.00 96.49 9.00 6,005.91 929.95 -481.90 929.95 7.00 90.00 5,944,334.56 508,127.04 9,600.00 96.35 16.04 5,994.71 1,026.90 -460.37 1,026.90 7.00 90.80 5,944,431.52 508,148.45 9,625.00 96.30 17.80 5,991.95 1,050.67 -453.14 1,050.67 7.00 91.59 5,944,455.30 508,155.66 14 9,700.00 96.73 23.07 5,983.44 1,120.47 -427.13 1,120.47 7.00 85.00 5,944,525.12 508,181.58 9,725.00 96.86 24.83 5,980.49 1,143.16 -417.06 1,143.16 7.00 85.60 5,944,547.82 508,191.63 15 9,800.00 94.62 20.05 5,972.98 1,212.11 -388.59 1,212.11 7.00 -115.00 5,944,616.80 508,220.01 9,900.00 91.59 13.73 5,967.57 1,307.60 -359.60 1,307.60 7.00 -115.48 5,944,712.31 508,248.89 9,925.00 90.82 12.16 5,967.04 1,331.96 -354.00 1,331.96 7.00 -115.82 5,944,736.67 508,254.46 16 10,000.00 89.29 7.14 5,966.97 1,405.87 -341.43 1,405.87 7.00 -107.00 5,944,810.59 508,266.94 10/20/2017 6:05:50PM Page 4 COMPASS 5000.14 Build 85 0 0 ✓ ConocoPhillips Bp ER r ConocoPhillips Planning Report I UGHES a GE company Database: EDT Alaska Sandbox Local Co-ordinate Reference: Well 2G-15 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2G-15 @ 140.00usft(2G-15) Site: Kuparuk 2G Pad North Reference: True Well: 2G-15 Survey Calculation Method: Minimum Curvature Wellbore: 2G-15L1-01 Design: 2G-15L1-01_wp03 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100ft) (°) (usft) (usft) 10,100.00 87.25 0.44 5,969.99 1,505.54 -334.83 1,505.54 7.00 -107.00 5,944,910.26 508,273.43 10,125.00 86.74 358.76 5,971.30 1,530.51 -335.01 1,530.51 7.00 -106.80 5,944,935.22 508,273.23 17 10,200.00 86.76 4.02 5,975.56 1,605.34 -333.19 1,605.34 7.00 90.00 5,945,010.05 508,274.96 10,300.00 86.82 11.03 5,981.17 1,704.26 -320.13 1,704.26 7.00 89.70 5,945,108.97 508,287.91 10,375.00 86.90 16.29 5,985.28 1,777.00 -302.45 1,777.00 7.00 89.31 5,945,181.73 508,305.50 18 10,400.00 87.20 14.56 5,986.57 1,801.07 -295.81 1,801.07 7.00 -80.00 5,945,205.80 508,312.11 10,500.00 88.44 7.67 5,990.37 1,899.06 -276.56 1,899.06 7.00 -79.91 5,945,303.81 508,331.24 10,600.00 89.71 0.78 5,991.99 1,998.72 -269.20 1,998.72 7.00 -79.65 5,945,403.46 508,338.49 10,625.00 90.03 359.06 5,992.04 2,023.72 -269.24 2,023.72 7.00 -79.54 5,945,428.46 508,338.43 19 10,700.00 90.67 4.27 5,991.59 2,098.66 -267.06 2,098.66 7.00 83.00 5,945,503.39 508,340.52 10,800.00 91.51 11.22 5,989.69 2,197.67 -253.59 2,197.67 7.00 83.03 5,945,602.40 508,353.87 10,875.00 92.13 16.44 5,987.31 2,270.43 -235.68 2,270.43 7.00 83.16 5,945,675.18 508,371.70 20 10,900.00 92.13 14.69 5,986.38 2,294.50 -228.97 2,294.50 7.00 -90.00 5,945,699.25 508,378.38 11,000.00 92.10 7.68 5,982.68 2,392.47 -209.60 2,392.47 7.00 -90.06 5,945,797.24 508,397.63 11,100.00 92.05 0.68 5,979.06 2,492.07 -202.32 2,492.07 7.00 -90.32 5,945,896.84 508,404.80 11,200.00 91.96 353.67 5,975.56 2,591.83 -207.24 2,591.83 7.00 -90.58 5,945,996.58 508,399.76 Planned TD at 11200.00 10/20/2017 6:05:50PM Page 5 COMPASS 5000.14 Build 85 410 0 ConocoPhillips BA ER ' J ConocoPhillips Planning Report F�UGHES a GE company Database: EDT Alaska Sandbox Local Co-ordinate Reference: Well 2G-15 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2G-15 @ 140.00usft(2G-15) Site: Kuparuk 2G Pad North Reference: True Well: 2G-15 Survey Calculation Method: Minimum Curvature Wellbore: 2G-15L1-01 Design: 2G-15L1-01_wp03 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +El-W Northing Easting -Shape (0) (0) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 2G-15L1-01_T03 0.00 0.00 6,028.00 -869.091,138,908.60 5,943,838.00 1,647,405.00 70°1'14.363 N 140°48'5.838 W -plan misses target center by 1139115.88usft at 11100.00usft MD(5979.06 TVD,2492.07 N,-202.32 E) -Point 2G-15 CTD Polygon Sol. 0.00 0.00 0.00 -5,633.471,138,828.14 5,939,074.00 1,647,330.00 70°0'28.216 N 140°48'28.540 W -plan misses target center by 1139075.14usft at 11100.00usft MD(5979.06 TVD,2492.07 N,-202.32 E) -Polygon Point 1 0.00 0.00 0.00 5,939,074.00 1,647,330.00 Point 2 0.00 -430.42 346.56 5,938,644.02 1,647,677.02 Point 3 0.00 -69.75 680.99 5,939,005.04 1,648,011.00 Point4 0.00 402.16 806.52 5,939,477.04 1,648,135.98 Point 5 0.00 972.31 723.13 5,940,047.04 1,648,051.95 Point6 0.00 1,291.22 835.49 5,940,366.05 1,648,163.93 Point7 0.00 1,819.30 808.07 5,940,894.04 1,648,135.91 Point8 0.00 2,249.18 961.55 5,941,324.05 1,648,288.88 Point9 0.00 2,666.20 975.01 5,941,741.05 1,648,301.86 Point 10 0.00 3,819.14 1,143.29 5,942,894.06 1,648,468.81 Point 11 0.00 3,902.80 546.32 5,942,977.03 1,647,871.80 Point 12 0.00 2,388.90 308.64 5,941,463.01 1,647,635.88 Point 13 0.00 1,472.84 279.64 5,940,547.01 1,647,607.93 Point 14 0.00 1,110.91 182.23 5,940,185.01 1,647,510.94 Point 15 0.00 347.78 236.40 5,939,422.02 1,647,565.98 Point 16 0.00 0.00 0.00 5,939,074.00 1,647,330.00 2G-15L1-01_T04 0.00 0.00 5,994.00 -495.101,138,951.03 5,944,212.00 1,647,447.00 70°1'17.932 N 140°48'3.029 W -plan misses target center by 1139157.27usft at 11100.00usft MD(5979.06 TVD,2492.07 N,-202.32 E) -Point 2G-15L1-01 T3.6 0.00 0.00 5,993.00 478.041,139,793.22 5,945,186.00 1,648,288.00 70°1'26.146 N 140°47'34.935 W -plan misses target center by 1139997.33usft at 11100.00usft MD(5979.06 TVD,2492.07 N,-202.32 E) -Point 2G-15L1-01 T3.5 0.00 0.00 5,962.00 -229.861,139,644.40 5,944,478.00 1,648,140.00 70°1'19.491 N 140°47'42.201 W -plan misses target center by 1139849.97usft at 11100.00usft MD(5979.06 TVD,2492.07 N,-202.32 E) -Point 2G-15L1-01_T06 0.00 0.00 5,994.00 471.781,139,145.15 5,945,179.00 1,647,640.00 70°1'27.036 N 140°47'53.368 W -plan misses target center by 1139349.27usft at 11100.00usft MD(5979.06 TVD,2492.07 N,-202.32 E) -Point 2G-15L1-01 T3.1 0.00 0.00 6,018.00 -2,182.851,139,460.15 5,942,525.00 1,647,958.00 70°1'0.797 N 140°47'55.812 W -plan misses target center by 1139672.06usft at 11100.00usft MD(5979.06 TVD,2492.07 N,-202.32 E) -Point 2G-15L1-01 T3.2 0.00 0.00 6,003.00 -1,395.831,139,512.05 5,943,312.00 1,648,009.00 70°1'8.363 N 140°47'50.962 W -plan misses target center by 1139721.01 usft at 11100.00usft MD(5979.06 TVD,2492.07 N,-202.32 E) -Point 2G-15L1-01 T3.4 0.00 0.00 5,995.00 -492.831,139,592.09 5,944,215.00 1,648,088.00 70°1'17.014 N 140°47'44.815 W -plan misses target center by 1139798.33usft at 11100.00usft MD(5979.06 TVD,2492.07 N,-202.32 E) -Point 2G-15L1-01 T3.3 0.00 0.00 6,028.00 -875.841,139,566.65 5,943,832.00 1,648,063.00 70°1'13.332 N 140°47'47.181 W -plan misses target center by 1139773.95usft at 11100.00usft MD(5979.06 TVD,2492.07 N,-202.32 E) -Point 2G-15L1-01_T01 0.00 0.00 6,018.00 -2,125.041,138,755.15 5,942,582.00 1,647,253.00 70°1'2.392 N 140°48'15.580 W -plan misses target center by 1138966.83usft at 11100.00usft MD(5979.06 TVD,2492.07 N,-202.32 E) -Point 2G-15L1_Fault1_M 0.00 0.00 0.00 -501.161,139,004.03 5,944,206.00 1,647,500.00 70°1'17.796 N 140°48'1.550 W -plan misses target center by 1139225.97usft at 11100.00usft MD(5979.06 TVD,2492.07 N,-202.32 E) -Rectangle(sides W1.00 H2,000.00 D0.00) 10/20/2017 6:05:50PM Page 6 COMPASS 5000.14 Build 85 0 ConocoPhillips • A E ConocoPhillips Planning Report F tJGji HES a GE company Database: EDT Alaska Sandbox Local Co-ordinate Reference: Well 2G-15 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2G-15 @ 140.00usft(2G-15) Site: Kuparuk 2G Pad North Reference: True Well: 2G-15 Survey Calculation Method: Minimum Curvature Wellbore: 2G-15L1-01 Design: 2G-15L1-01_wp03 2G-15L1-02 Polygon 0.00 0.00 0.00 -3,065.271,138,880.08 5,941,642.00 1,647,379.00 70°0'53.079 N 140°48'16.063 W -plan misses target center by 1139111.65usft at 11100.00usft MD(5979.06 TVD,2492.07 N,-202.32 E) -Polygon Point 1 0.00 0.00 0.00 5,941,642.00 1,647,379.00 Point2 0.00 444.65 361.52 5,942,087.02 1,647,739.98 Point3 0.00 249.36 611.33 5,941,892.03 1,647,989.98 Point4 0.00 -236.96 860.83 5,941,406.05 1,648,240.01 Point5 0.00 -723.12 958.31 5,940,920.05 1,648,338.04 Point6 0.00 -1,306.13 915.67 5,940,337.05 1,648,296.07 Point7 0.00 -1,737.25 984.20 5,939,906.05 1,648,365.09 Point 8 0.00 -2,279.29 969.61 5,939,364.05 1,648,351.12 Point 9 0.00 -2,361.61 344.46 5,939,281.02 1,647,726.12 Point 10 0.00 -1,736.60 387.14 5,939,906.02 1,647,768.09 Point 11 0.00 -1,444.51 332.46 5,940,198.02 1,647,713.08 Point 12 0.00 -986.52 387.96 5,940,656.02 1,647,768.05 Point 13 0.00 -541.36 277.44 5,941,101.01 1,647,657.03 Point 14 0.00 -222.25 208.78 5,941,420.01 1,647,588.01 Point 15 0.00 0.00 0.00 5,941,642.00 1,647,379.00 2G-15L1-01_T02 0.00 0.00 6,002.00 -1,432.041,138,820.94 5,943,275.00 1,647,318.00 70°1'9.025 N 140°48'10.741 W -plan misses target center by 1139030.03usft at 11100.00usft MD(5979.06 TVD,2492.07 N,-202.32 E) -Point 2G-15 CTD Polygon Nor 0.00 0.00 0.00 1,341.741,139,256.16 5,946,049.00 1,647,750.00 70°1'35.321 N 140°47'46.482 W -plan misses target center by 1139474.75usft at 11100.00usft MD(5979.06 TVD,2492.07 N,-202.32 E) -Polygon Point 1 0.00 0.00 0.00 5,946,049.00 1,647,750.00 Point2 0.00 -28.69 625.03 5,946,021.03 1,648,375.00 Point 3 0.00 -750.58 458.23 5,945,299.02 1,648,209.04 Point4 0.00 -1,736.46 262.13 5,944,313.01 1,648,014.09 Point 5 0.00 -2,292.49 233.52 5,943,757.01 1,647,986.12 Point6 0.00 -2,792.48 177.97 5,943,257.00 1,647,931.14 Point 7 0.00 -3,195.58 232.53 5,942,854.01 1,647,986.16 Point8 0.00 -3,792.60 204.88 5,942,257.02 1,647,959.19 Point 9 0.00 -4,320.31 -115.73 5,941,728.99 1,647,639.22 Point 10 0.00 -4,347.72 -657.81 5,941,700.97 1,647,097.23 Point 11 0.00 -4,055.42 -907.52 5,941,992.95 1,646,847.21 Point 12 0.00 -3,597.43 -851.01 5,942,450.96 1,646,903.19 Point 13 0.00 -3,819.76 -573.23 5,942,228.97 1,647,181.19 Point 14 0.00 -3,097.88 -392.42 5,942,950.98 1,647,361.16 Point 15 0.00 -2,360.82 -377.62 5,943,687.99 1,647,375.12 Point 16 0.00 -1,722.82 -320.91 5,944,325.99 1,647,431.09 Point 17 0.00 -1,374.86 -251.53 5,944,673.99 1,647,500.07 Point 18 0.00 0.00 0.00 5,946,049.00 1,647,750.00 2G-15L1-03 Polygon 0.00 0.00 0.00 -3,162.361,138,949.98 5,941,545.00 1,647,449.00 70°0'52.033 N 140°48'14.495 W -plan misses target center by 1139182.03usft at 11100.00usft MD(5979.06 TVD,2492.07 N,-202.32 E) -Polygon Point 1 0.00 0.00 0.00 5,941,545.00 1,647,449.00 Point2 0.00 430.56 444.51 5,941,976.02 1,647,892.97 Point3 0.00 223.29 666.31 5,941,769.03 1,648,114.99 Point4 0.00 -236.95 846.83 5,941,309.04 1,648,296.02 Point5 0.00 -807.20 1,026.22 5,940,739.05 1,648,476.04 Point6 0.00 -1,432.17 942.53 5,940,114.05 1,648,393.07 Point7 0.00 -2,112.33 1,024.80 5,939,434.05 1,648,476.11 Point 8 0.00 -2,292.71 441.54 5,939,253.03 1,647,893.12 Point9 0.00 -1,917.63 399.95 5,939,628.02 1,647,851.10 Point 10 0.00 -1,361.57 400.55 5,940,184.02 1,647,851.07 Point 11 0.00 -903.47 346.05 5,940,642.02 1,647,796.05 Point 12 0.00 -389.37 304.61 5,941,156.02 1,647,754.02 Point 13 0.00 0.00 0.00 5,941,545.00 1,647,449.00 2G-15L1_Faultl 0.00 0.00 6,000.00 -501.161,139,004.03 5,944,206.00 1,647,500.00 70°1'17.796 N 140°48'1.550 W -plan misses target center by 1139210.28usft at 11100.00usft MD(5979.06 TVD,2492.07 N,-202.32 E) -Polygon 10/20/2017 6.05:50PM Page 7 COMPASS 5000.14 Build 85 ✓ S ConocoPhillips 0 BITER ( ) ConocoPhillips Planning Report GHES GE company Database: EDT Alaska Sandbox Local Co-ordinate Reference: Well 2G-15 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2G-15 @ 140.00usft(2G-15) Site: Kuparuk 2G Pad North Reference: True Well: 2G-15 Survey Calculation Method: Minimum Curvature Wellbore: 2G-15L1-01 Design: 2G-15L1-01_wp03 Point 1 6,000.00 0.00 0.00 5,944,206.00 1,647,500.00 Point2 6,000.00 1.00 1.00 5,944,207.00 1,647,501.00 2G-15L1-01_T05 0.00 0.00 5,963 00 -233.121,138,997.33 5,944,474.00 1,647,493.00 70°1'20.408 N 140°48'0.591 W -plan misses target center by 1139202.91 usft at 11100.00usft MD(5979.06 TVD,2492.07 N,-202.32 E) -Point 2G-15L1-01 T3.7 0.00 0.00 5,975.00 1,020.001,139,876.85 5,945,728.00 1,648,371.00 70°1'31.286 N 140°47'30.233 W -plan misses target center by 1140080.13usft at 11100.00usft MD(5979.06 TVD,2492.07 N,-202.32 E) -Point 2G-15L1-01_T07 0.00 0.00 5,972.00 1,011.731,139,231.78 5,945,719.00 1,647,726.00 70°1'32.152 N 140°47'48.591 W -plan misses target center by 1139435.06usft at 11100.00usft MD(5979.06 TVD,2492.07 N,-202.32 E) -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 11,200.00 5,975.56 2 3/8" 2.375 3.000 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 7,200.00 6,019.10 -1,231.68 -849.26 TIP/KOP 7,270.00 6,016.51 -1,187.54 -795.02 Start 7 dls 7,400.00 6,006.94 -1,096.07 -703.33 3 7,500.00 5,999.65 -1,016.47 -643.35 4 7,750.00 6,006.09 -794.25 -531.13 5 7,950.00 6,018.51 -601.05 -482.97 6 8,300.00 6,013.35 -254.70 -508.70 7 8,550.00 6,006.21 -8.03 -542.14 8 8,700.00 6,004.47 140.87 -525.96 9 8,800.00 6,007.96 237.61 -501.12 10 9,000.00 6,020.90 433.40 -465.08 11 9,200.00 6,028.00 632.43 -476.94 12 9,400.00 6,017.27 831.12 -491.37 13 9,625.00 5,991.95 1,050.67 -453.14 14 9,725.00 5,980.49 1,143.16 -417.06 15 9,925.00 5,967.04 1,331.96 -354.00 16 10,125.00 5,971 30 1,530.51 -335.01 17 10,375.00 5,985.28 1,777.00 -302.45 18 10,625.00 5,992.04 2,023.72 -269.24 19 10,875.00 5,987.31 2,270.43 -235.68 20 11,200.00 5,975.56 2,591.83 -207.24 Planned TD at 11200.00 10/20/2017 6.05:50PM Page 8 COMPASS 5000.14 Build 85 0 • I Baker Hughes INTEQ B ER ConocoPhillips Travelling Cylinder Report IrUGHES a GE company Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2G-15 Project: Kuparuk River Unit TVD Reference: 2G-15 @ 140.00usft(2G-15) Reference Site: Kuparuk 2G Pad MD Reference: 2G-15 @ 140.00usft(2G-15) Site Error: 0.00 usft North Reference: True Reference Well: 2G-15 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 2G-15L1-01 Database: OAKEDMP2 Reference Design: 2G-15L1-01_wp03 Offset TVD Reference: Offset Datum Reference 2G-15L1-01_wp03 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 7,200.00 to 11,200.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,306.00 usft Error Surface: Pedal Curve Survey Tool Program Date 10/17/2017 From To (usft) (usft) Survey(Wellbore) Tool Name Description 200.00 6,600.00 2G-15(2G-15) GCT-MS Schlumberger GCT multishot 6,600.00 7,200.00 2G-15L1_wp06(2G-15L1) MWD MWD-Standard 7,200.00 11,200.00 2G-15L1-01_wp03(2G-15L1-01) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 11,200.00 6,115.56 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-02-2G-02-2G-02 9,763.06 6,100.00 360.74 4.55 360.49 Pass-Minor 1/10 c 2G-10-2G-10-2G-10 Out of range 2G-13-2G-13-2G-13 Out of range 2G-13-2G-13A-2G-13A Out of range 2G-13-2G-13AL1-2G-13AL1 Out of range 2G-13-2G-13AL2-2G-13AL2 Out of range 20-14-2G-14-20-14 Out of range 20-14-2G-14A-2G-14A Out of range 2G-14-2G-14AL1-2G-14AL1 Out of range 2G-15-2G-15-2G-15 7,219.92 6,575.00 305.76 11.28 299.21 Pass-Major Risk 2G-15-2G-15L1-2G-15L1_wp06 7,500.97 7,500.00 20.75 1.37 19.56 Pass-Minor 1/10 2G-15-2G-15L1-02-2G-15L1-02_wp03 7,274.93 6,525.00 321.65 8.28 316.81 Pass-Major Risk 20-15-2G-15L1-03-2G-15L1-03_wp03 7,274.93 6,525.00 321.65 8.28 316.81 Pass-Major Risk 20-16-2G-16-2G-16 Out of range Plan:2G-19-Plan:2G-19-2G-19wp02 Out of range Plan:2G-20A-Plan:2G-20A-2G-20Awp02 Out of range Offset Design Kuparuk 2G Pad- 2G 02 2G 02 2G 02 Offset Site Error: 0.00 usft Survey Program: 200-GCT-MS Rule Assigned:Minor 1/10 Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth ON/-S +E/-w Hole Size Centre Distance Deviation (usft) Iusft) (usft) (usft) (usft) (usft) (°) (usft) (usft) (") (usft) (usft) (usft) 9,73765 6,119.02 5,525.00 5,417.67 39.88 23.52 30.13 1,051.17 -375.31 3 70868 442 708.63 Pass-Minor 1/10 9,737.66 6,119.01 5,550.00 5,438.56 39.88 23.63 29.19 1,058.87 -386.70 3 686.63 4.42 686.38 Pass-Minor 1/10 9,737.70 6,119.01 5,500.00 5,396.69 39.88 23.41 30.99 1,043.61 -364.02 3 731.38 4.42 731.13 Pass-Minor 1/10 9,737.74 6,119.01 5,575.00 5,459.35 39.88 23.74 28.18 1,066.69 -398.17 3 664.65 4.42 664.40 Pass-Minor 1/10 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 10/17/2017 3:25:10AM Page 2 COMPASS 5000.14 Build 85 410 . .4200 . 4050 W .3600 3900 ,3000 Ilit -, Y -3750 yr .2400 �•1 w1 .... -3600 V N N a H _1800 —, -3450 -1200 N 1 • 63300 lI o a •i 0 0. .600 N y b ch w -mss.��;•"oa m �O ln9 9�Y - o .3150 z '_ y- ,r,-52 _ ^n_e I -o 8 - LEI m --.... 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N CO N M 10 M r•O V'O N O V r-V O O —CO O YYNNM N OM2 o r• 0c'oa7M 000 V'NON O LL O)U)M CCS NON QS a-IO CO,-M r•a IO NC)IA r- -b 52 613 c)rn + 0c0w0 v�IL9 CV Ino 1-ava MONN CD -600 .:1,4.. y3 a`I -N _-oCD d d,- J N 0,CO_COO IvO V N o�O CO CO4 00 CV Y-o 100 CV 4 00 ...---•n -750 In < W ao 'ZOZ IJ-[ZSI-'Jz.-- O Z r•CO COV O Ut O O r-M 0cm.i0 C0 o M o r-M O.- • W l.0 + N OO CO 140 1 MMMMOV'MMr-Nr0) -.-. T Ur 1 .-N V CID 00,-M r-ON CO -9OO c-y a-N N N IO.L 10-DISI m W cnoc-a lO O),-In,-r.o o O r-In rn a o Ov,-cn _.----- -0 � ... n - "-1050 N,-CO CD MN V'06)O NO V'O M N OM CO r is un >0O C6of CO Cori Ci)00N-N-r-0)O r•N-ai CO0 r•N. S. 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C O N c-c-O)O CD I O 1--N M C O I O M CO CO 1-O)O c-C n I n - • Q O,i 44NO.--c-C)OCOO)COCOCOOCOCOONVJ ., • o 0)C)C)CCO0CCOCOCOCO) )o) ) CO00 0)0)0)o) 000)C)0) N ;`C, .-1650 7= w O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0O o 0 o ON o 0 o 04 CS o o O 000000000tototo'4 Uri'4to o 1°la O r•O O CO CO O CO o 0 0 0 o N N N N r•N N-O N vri 0 b b 1 b ItN V N N V' r•O)M LO f-O O N V'CO I O)r-M C O CO N i q I.-r N`r-r-r-co CO CO co co,0)0)0)0 0)co o 0 0,- 0 O 0 N Ma'10 CO 1-coC)o,-CV 00 V I0001-OC)O.- C c N N z o (uisn OSi)g�daQ IeoiaA awl U 0 0 w uM CO02 -'4 11 o =C 4 {t _ '7T o0 : z t z z 1 i. o �<gd� �h iTITTT i. + yi a }a sz �} s -4-;,..- • a 1 !1 zw w -1-1197171 + i C� :: Gf. —moo i'+-� t __. ��� 4t'; MO hof. M rn 0 , t_. o CYd s . 1- • Q `'.f / # r., R J O J S ri ... /co CC J v O Q N F- 0W a .� , l.l �\ L ce J co 02 " - i--. -' u -may � i1 �'_ ��_.-". ` ...P + Tjt 1+ O '. y T i '�F onr „v im000, ,n J I` o E e O '� /it, - - 13 __ _ - MOV `O + ,°Goy ?+ .. + ,{. v.'.3 .... r _ , b V ----••,..,,'?q" O ff -V 3 ='0 J - i t r o aua d r Y �1 N 7 J r , Y YNNwo rN�� .." + _. - X �' ai o di 0' - i.. yam. o y a w I, - I_j• . aJ 4 ' yY + 1 t72,22 a u t. I - ry'X , _ nrr(h I - 1. 1 �, a ': C b 0 0 0 O 0 O O O O O O O 0O O OO OO O OO OO OO ,OO OO OO 8,,,,,:,/ ,0,OOhOOO00Ns O oo Nv en o ;, N V " q o0- (ul/gsn 005)(+)41,10N/(-)q3nos U COU Y�uis a7 ii 7 KUP PROD • 2G-15 ConocoPhitlips t Well Attributes Max Angle Sr MD TD Alaska Inc. Wellbore API/UWI Field Name Wel!bore Status ncl('I MD(ftKB) Act Btm(ftKB) (ftKB), 500292116200 KUPARUK RIVER UNIT PROD 47.88 6,000.00 6,997.0 ..- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date DEVIATED-2C-15,9/5/201711.03.02 AM SSSV:NONE 150 11/1/2014 Last WO: 7/20/2017 35.00 10/16/1984 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date - - - Last Tag:RKB 6,835.0 8/13/2017 Rev Reason:W/O,SET WRP&CATCHER,GLV jennalt 9/5/2017 Hanger;32.0 11._W`l. 0/0,PULL WRP&CATCHER,TAG Casing Strings ""•' '•'""""' l Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread J CONDUCTOR 16 15.062 35.0 105.0 105.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Tap(ftKB) Set Depth(ftKB) Set Depth(TVD)... WI/Len(I...Grade Top Thread __...._..._...._....._....�_.._...__...�....... ........ -- --SURFACE 95/8 8.921 34.0 2,726.5 2,726.1 36.00 J-55 BUTT Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I.. Grade Top Thread PRODUCTION 7 6.276 33.1 6,983.0 6,336.3 26.00 J-55 BUTT ✓AA/CONDUCTOR;35.6-105.0I1Ln.AI Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection 3-1/2 Upper Gas lift 3 1/2 2.992 0.0 5,757.2 5.495.6 9.30 L-80 EUE 8rd Mod completion 2017 GAS LIFT;2,491.5 RWO Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(') Item Des Com (in) 32.0 32.0 0.23 Hanger Tubing Hanger,McEvoy,MSDP,7-1/16"x 3-1/2"EUE 8rd 2.992 Top x Bottom with 3"H BPVG SURFACE:34.0-2,726.5-', 5,745.1 5,487.2 46.21 Locator Locator,Baker,GBH-22(bottom of locator spaced out 3') 2.990 GAS LIFT;3,852.9 5,748.4 5,489.5 46.24 Seal Assembly Seal Assembly,Baker,80-40(total seal assembly= 2.990 11.79') • Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) I Grade Top Connection Straddle Completion 3 1/2 2.992 5,748.7 6,390.9 5,924.2 9.30 L-80 EUE 8rd Mod 2017 RWO OAS UFT;4,466.9 - Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl I') Item Des Com (in) 5,748.7 5,489.8 46.24 PBR PBR,Baker,10'80-40 4.000 5,761.7 5,498,8 46.36 FHL Packer Packer,Baker,47B2 FHL(shear release=60K) 2.940 6,378.8 5,915.9 47.03 Locator Locator,Baker,GBH-22(bottom of locator spaced out 3') 2.990 GAS LIFT;5,003.1 6,381.1 5,917.5 47.02 Seal Assembly Seal Assembly,Baker,80-40(total seal assembly= 2.990 GAS LIFT;5,688.3 - 11.80') Tubing Description !String Ma...I ID(in) !Top(ftKB) Set Depth(ft..1Sot Depth(ND)(...1Wt(Ib/ft) Grade !Tap Connection Lower Completion 41/2 3.958 6,381.1 6,680.1 6,122.5 12.60 L-80 IBTM 2017 RWO Completion Details Locator;5,745.1 Nominal ID Seal Asaembty;5,746.4_ Top(ftKB) Top(ND)(ftKB) Top Incl(") Item Des Com (in) PBR;5,7a8.7 6,381.1 5,917.5 47.02 PBR PBR,Baker,10'80-40 4.000 6,394.1 5,926.4 46,99 FHL Packer Packer,Baker,47B2 FHL(shear release=60K) 2.940 FHL Packer;5,761.7 - 6,447.6 5,962.9 46.87 Nipple-2.813" Nipple,Camco,2.813"DS profile,SN:3651-18 2.813 DS 6,553.5 6,035.5 46.72 Crossover Crossover,3-1/2"EUE 8rd Mod Box x 4-1/2"IBT Pin 2.992 6,555.0 6,036.5 46.72 Wearsox Wearsox,Northern Solutions,4-1/2",12.6#,L-80,)BTM 3.958 Locator;6,378.8 Box x Pin Seal Assembly;6,381.1, s,'.) Perforations&Slots PBR 8,381.1 i.W. Shot FHL Packer;6,394.1 Dens Top(ND) Blot(ND) (shota/f Top(ftKB) Blot(ftKB) (ftKB) (ftKB) Zone Date i) Type Com 6,566.0 6,580.0 6,044.0 6,053.6 C-4,2G-15 '2/23/2005 6.0 APERF 2.5"HSD,60 deg.ph 6,658.0 6,674.0 6,107.3 6,118.3-A-5,2G-15 '9/30/1985 4.0 RPERF 2 1/8"Dresser;0 Ph 6,660.0 6,662.0 6,108.6 6,110.0 A-5,2G-15 11/8/1984 1.0 IPERF 4"DAJJ;90 deg. Phasing Nipple-2.813'DS;6,447.6 • - 6,666.0 6,667.0 6,112.8 6,113.5 A-5,2G-15 11/8/1984 ' 1.0'IPERF 4"DAJJ;90 deg. Phasing 6,668.0 6,669.0` 6,114.2 6,114.9.A-5,2G-15 11/8/1984 ' 1.0'IPERF 4"DAJJ;90 deg. Phasing 6,694.0 6,738.0 6,132.2 6,162.8 A-4,2G-15 9/30/1985 4.0-RPERF 21/8"Dresser,0 Ph 6,697.0 6,698.0' 6,134.3 6,135.0 A-4,2G-15 11/8/1984 1.0 IPERF 4"DAJJ;90 deg. Phasing 6,700.0 6,702.0 6,136.4 6,137.7 A-4,2G-15 11/8/1984 1.0 IPERF 4"DA JJ;90 deg. Phasing Crossover;6,553.5 6,705.0 6,706.0 6,139.8 6,140.5 A-4,2G-15 11/8/1984 1.0 IPERF 4"DA JJ;90 deg. Phasing 6,710.0 6,712.0 6,143.3 6,144.7 A-4,2G-15 11/8/1984 1.0 IPERF 4"DAJJ;90 deg. APERF;6,566.0-6,580.0-� Phasing 6,716.0 6,718.0' 6,147.5 6,148.9'A-4,2G-15 11/8/1984 1.0 IPERF 4"DA JJ;90 deg. Weersoz;6,555.0 Phasing IPERF;6,660.0-6,662.0RPERF;6,658.0-6,574.0, ac 6,724.0 6,725.0 6,153.1 6,153.8 A-4,2G-15 11/8/1984 1.0 IPERF 4"DAJJ;90 deg. IPERF;6,666.0-6,667.0 _ Phasing IPERF;6,668.0-6,669.0 0 6,727.0 6,728.0 6,155.1 6,155.8 A-4,2G-15 11/8/1984 1. IPERF 4"DAJJ;90 deg. Phasing _ Mandrel Inserts IPERF;6,697.0-6,698.0 - St 2 ati (PERF;8,700.0-6,702.0- . on Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(In) Sery Type Type (in) (psi) Run Date Com a= -1 2,491.5 2,491.2 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,257.0 8/12/2017 IPERF;6,705.0-6,]06.0- a • _� 2 3,652.9 3,652.1 Cameo MMG 11/2 GAS LIFT GLV RK 0.188 1,245.0 8/12/2017 ac - IPERF;6,710.043,712.0- 3 4,466.8 4,444.6 Cameo MMG 11/2 GAS LIFT GLV RK 0.188 1,244.0'8/12/2017 RPERF;6,694.0-6,738.0, - iG IPERF;6,716.0-6,718.0---. 4 5,093.1 4,990.8 Cameo MMG 11/2 GAS LIFT GLV RK 0.188 i 1,240.0 8/12/2017 IPERF;6,724.0-6,725.0 - C 5 5,688.3 5,447.8 Ca mco MMG 11/2 GAS LIFT OV RK 0.250 0.0 8/12/2017 IPERF;6,727.0-6,728.0� Notes:General6,727.0-6,728.0 ' .-- End Date Annotation .-- 10/21/2010 NOTE:View Schematic w/Alaska Schematic9.0 1/19/2016 NOTE:100'balanced 11#WellLock Resin plug into both the Tubing and IA-0/0 on 2017 RWO PRODUCTION;33.16,983.0 KUP PROD 0 2G-15 ConocoPhillips Pa Alaska,Inc. coaoPH�lps ••• DEVIATED-2G-15,9/52017 11:03'.03 AM Vertical ache matic(actual) .................... Hanger',32 0 1a_11P . Notes:General&Safety • ". - Ed Date Annotation 9/5/2017 Note .A.AJ CONDUCTOR;35.0-105.0 GAB LIFT;2,491.5 I0 SURFACE;34.0-2,726.5—A A GAS LIFT;3,652.9 - GAS LIFT;4,466.8 GAS LIFT;5,093.1 GAS LIFT;5,688.3 Locator;5,745.1 Seal Assembly;5,748.41 PBR;5,748.7 FHL Packer;5,761.7 Locator;6,378.8 Seal Assembly;6,381.1, - PBR;6,381.1 FHL Packer;6,394.1 Nipple-2813-DS,64476 Crossover;6,553.5 Li APERF;6,566.0-6,580.0— Wearsox;6,555.0 —_ IPERF;6,660.0-6,662.0+ lc RPERF;6,658.0-6,674.01 IPERF;6,666.0-6,667.0—� _ IPERF;6,668.0-6,669.0 IPERF;6,697.0-6,698.0 IPERF;6,700.0-6,702.0— ' IPERF;8,705.0-6,706.0—. . lac IPERF;6,710.0-6,712.0 RPERF;6,694.0-6,738.01 IPERF;6,716.0-6,718.0,, s IPERF;6,724.0-6,725.0 IPERF;6,727.0-6,728.0— ' PRODUCTION;33.1-6,983.0 0 \§§ m§§ ;;:.;.. \s-Li \\/ \§) Q// \ » FtIR C CO / / S \ { _ co o 0 c a •E \ / ƒ § § - co = 0 w 4 v , = CO c % - 2 \ CO \@) \ / \ /$ \� \\ / f °� ©� @0_\ \ / E § ± u ± \ ( / /\ / / cp / mr /2 2W 0 m \ \\ 22 22 § \ Iil W. , c 9 i4\ F,:- ,, , a a ` / / "l•U.I 1ci) S ? ^ e !!! „ _ :. !fly!!! o . _ _ \ _ ° = ^ c ) 2 2 ¥2 «_ «% C e% \c m— 22 co 2b - \/ 1.0 wg F {# 7J , _ % { 0 \\ o� } ƒ§ \/ h- _ \ \ / ƒ CO \ \\� EA a Cl)\\ (/) 000 • • Loepp, Victoria T (DOA) From: Long,William R <William.R.Long@conocophillips.com> Sent: Tuesday, October 31, 2017 2:40 PM To: Loepp,Victoria T(DOA) Subject: RE: [EXTERNAL]KRU 2G-15L1-01(PTD 217-147)Anti-collision Victoria, 2G-02 was plugged and abandoned last year. Plugging was completed on October 17,2016. Please let me know if you would like any additional information. Thanks, William R. Long Staff CTD Engineer ConocoPhillips 907-263-4372(office) 281-723-6000(cell) William.R.Long@ConocoPhillips.com From:Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday,October 31,2017 2:11 PM To: Long,William R<William.R.Long@conocophillips.com> Subject: [EXTERNAL]KRU 2G-15L1-01(PTD 217-147)Anti-collision William, KRU 2G-15L1-01 fails major risk with KRU 2G-02 in the anti-collision analysis. What is the status of 2G-02 and what Y mitigating measures will be in place during drilling such as setting a deep plugor shut in at surface? g Thanx Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.LoeppCa alaska.ciov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first savingor forwardingit,and,so that the AOGCC is aware of the mistake in sendingit to p you,contact Victoria Loepp at(907)793-1247 or Victorialoem@alaska.gov 1 • i TRANSMITTAL LETTER CHECKLIST WELL NAME: f'C I� �. ,1 G - /\s 41 — I PTD: /Development Service _Exploratory Stratigraphic Test Non-Conventional FIELD: �tWkr POOL: J1crJ( A4 &, gl7d4AR RI V4.43— 017 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. /81-/,3 , API No. 50-'0Z3 -02,//6 Z -QC) - OO (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion,suspension or abandonment of this well. Revised 2/2015 0 0 0❑ N . . ; ; . . . . W o ° c' Q . ; 0' . ; . . . . . a, w 0 , r y g co c. O o a a ' c' 1--' O' C' y, a , Y w , f/> d co ;, ° 3, a o E' vi. NZ :, 0, > + ' a cN, , Qa c? Ce ,-, a' (a , Q a, 0, , .toE; a 0 , - , o, ' O ' ' ' , a° co Y co ' E Y, a> N ip, y' �, a' y �, m' 4 ai p r, J, a'' c' (a h, y N' C , 0> , C O' , co • ' 7 L9, a , N, cis z O' N, rN) rNs , o' 7 a, ° , a 0. 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