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216-056
MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Austin McLeod Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, June 8, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 1L18A KUPARIIK RIV UNIT IL -18A Src: Inspector Reviewed By: P.L Supry T50— Comm Well Name KUPARUK RfV UNIT 1L -18A API Well Number 50-029-22145-01-00 Inspector Name: Austin McLeod Permit Number: 216-056-0 Inspection Date: 6/4/2020 ✓ Iusp Num: mitSAM200605093623 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min IL-18A ' Type In) N - TVD _ 5859 Tubing 1550 - 1550. 1550 " 1550 - rML uws60 'Type Test SPT Test psi 1500 IA 440 2400 - 2300. 2286 mped: z.1 BBL Returned: 1:9 OA 90 - 90. 190 - 90- -------------------- 4YRTST PWP Notes: MIT -IA. S/1 for curtailment Monday, June 8, 2020 Page I of 1 STATE OF ALASKA 411ASKA OIL AND GAS CONSERVATION CO ISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon 0 Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend Li Perforate ❑ Other Stimulate 0 Alter Casing 0 Change Approved Program ❑ Plug for Redrill ❑ .erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other:DAD ACID Stimul0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development❑ Exploratory❑ 216-056 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic❑ Service 0 6.API Number: 99510 50-029-22145-01 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 1 L-18A ADL 25659 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 10,955 feet Plugs measured None feet true vertical 6,071 feet Junk measured None feet Effective Depth measured 10,955 feet Packer measured 7,116 feet true vertical 6,071 feet true vertical 5,859 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 feet 16 122' MD 122' TVD RECEIVED SURFACE 4,079 feet 9 5/8 " 4,121' MD 3566'TVD PRODUCTION 7,751 feet 7II 7,789'MD 5896'TVD LINER 3,110 feet 2 3/8" 10,955'MD 6071'ND APR 1 7 2018 Perforation depth: Measured depth: 7385- 10955 feet I OGCC True Vertical depth: 6055-6071 feet Tubing(size,grade,measured and true vertical depth) 3.5" J-55 7,168' MD 5,896'TVD Packers and SSSV(type,measured and true vertical depth) PACKER-BAKER HB RETRIEVABLE ! 7,116'MD 5,859'ND SAFETY VLV-CAMCO TRDP-4A SAFE 1,799' MD 1,781'ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A SCANNED _ r Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 450 240 780 Subsequent to operation: 0 0 450 460 2541 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ❑ Service [] Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG El GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 318-070 Contact Name: Jason Burke Authorized Name: Jason Burke Contact Email: Jason.Burke@cop.com Authorized Title: Staff Wells Engineer — /7 -18) Contact Phone: (907)265-6097 Authorized Signatetre Date: Form 10-404 Revised 4/2017 �T L _//,2,/I RBDM- Ft t I J iuid Submit Original Only • • 1 L- 1 8A and 1 L- 1 8ALI DAD ACID STIMULATE DTTMSTI JOBTYF SUMMARYOPS 3/13/18 ACID TAG LINER TOP W/2.47"CENT @ 7160' RKB& MEASURE BHP @ 7100' RKB (4,260 psi). ((NOTE: HAD TO HOLD 5000 PSI ON CONTROL LINE TO COME THRU TRSSSV)) JOB COMPLETE& READY FOR CTU. 3/20/18 ACID RIH WITH HELIK NOZZLE TO 9334' RKB. SQUEEZE 100 BBL DAD ACID 9333'-7450' RKB. TURN OVER WELL TO DSO AND RETURN TO INJECTION. JOB COMPLETE. a" '-., KUP INJ 1 L-1 8A ConocoPhillips ( $ Well es Ma &MD TD Wellbore Field Name Wellbore Status ncl(°) D(ftKB) Act Btm(ftKB) AlAt k,-t,I,t 500292214 KUPARUK RIVER UNIT INJ 104.81 9,060.40 10,955.0 C.OrlocaPMg,pe Comment H2S(ppm) Date Annotation End DateKB-Grd(ft) Rig Release Date °•° SSSV:TRDP Last WO: I 42.99 3/24/1991- JI 1L-18A,411 2/201 8 1Z34,55 34:55 PM Last Tag Venccal schematic(actual) Annotation Depth MB) End Date Last Mod By Last Tag: lehallf Last Rev Reason Annotation End Date Last Mod By HANGER;378 WWII Rev Reason: CORRECTED SIDETRACK DONE IN 2016 8 GLV(#1 corn) 4/12/2018 pproven Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread I. CONDUCTOR 16 15.062 43.0 122.0 122.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(1...Grade Top Thread SURFACE 9 5/8 8.921 42.0 4,120.6 3,566.5 36.00 J-55 BTC .�.�CONDUCTOR;43.0.122.0• Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6276 35.4 7,788.6 6,109.2 26.00 J-55 BTC-MOD Casing Description OD(in) ID lin) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread A LATERAL LINER 2 3/8 1.992 7,845.0 10,955.0 4.60 L-80 STL SAFETY VLV;1,789.1 Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Teel C) Item Des Com (in) 7,845.0 6,108.5 91.44 BILLET Anchored Aluminum Billet 1.900 7,899.4 6,106.8 91.81 DEPLOY Shorty Deployment Sleeve 1.900 GAS LIFT;1,938.5 8,812.4 6,129.5 90.07 DEPLOY Shorty Deployment Sleeve 1.900 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..'Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING 31/2 2.992 37.9 7,167.6 5,896.3 9.30 J-55 EUE8rdABMOD Completion Details Top(TVD) Top Inc! Nominal Top(ftKB( (ftKB) CI Item Des Com ID(in) 37.9 37.9 0.00 HANGER FMC GEN IV TUBING HANGER 3.500 SURFACE;42.0<,120.8-.1 1,799.1 1,781.2 20.10 SAFETY VLV CAMCO TRDP-4A SAFETY VALVE 2.812 7,102.6 5,848.9 43.07 PBR BAKER 10'STROKE PBR 3.000 7,116.3 5,858.9 43.10 PACKER BAKER HB RETRIEVABLE PACKER 3.500 GAS LIFT;7,045.7 7,132.7 5,870.8 43.15 NIPPLE CAMCO D NIPPLE NO GO(MILLED TO 2.80"on 5/6/2016) 2.800 7,166.7 5,895.7 43.24 SOS BAKER SHEAR OUT SUB 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 7,385.5 6,055.7 42.78 WHIPSTOCK- 3.5"Baker XL Tray with OH anchor 7/11/2016 0.000 PBR;7,102.6 MONOBORE ,..7 Perforations&Slots PACKER;7,116.3 k Shot ma" Dens k- Top(TVD) Btm(ND) (shots/ft5. Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ) Type Com 7,244.0 7.298.0 5,951.9 5,991.5•C-4,1L-18 8/13/1991 6.0 APERF 2 1/8"EnerJet III.0 degph NIPPLE;7,1327 Cement Squeezes ITop(ND) Btm(TVD) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com . : 7.114.0 7,632.0 5,857.2 6,111.0 Cement 5/8/2016 Lay in 35 bbls of 16.5 ppg Cement(20 bbls with ; Squeeze CemNet Fiber) ) Mandrel Inserts st SOS,7,166.E §• ati VN Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com ` ; \ 1 1,938.5 1,911.5 McMurry FMHO 1 GAS LIFT DMY BK2 0.000 0.0 9/24/1991 FISH NEC KIS i k STRI APERF;7,244.0-7,298.0- ' PPE D • 8/2/2 Cement Squeeze;7,114.08KB $' 2 7,045.7 5,807.3 MACCO SPM-2 11/2 GAS LIFT DMY RK 0.000 0.0 1/25/1992 R1Q) WHIPSTOCK-MONOBORE; 1 S: 7,385.5 ' Notes:General&Safety a End Date Annotation IPERF;7,442.0-7,464.0- 7/27/2016 NOTE:CTD SIDETRACK 7/27/2016 12:00 NOTE: s 5/ 5, IPERF;7,540.0-7,550.0-: Y: i p, PRODUCTION;35.4-7,788.8 - L.I l AL1 LATERAL LINER;7,159.B- 9,340.0 A LATERAL LINER;7,845.0i i 10,955.0 • . KUP INJ 1 L-18AL1 • Conoco'P`hillips 2c1= Iwell es ncI K MD TD • Wellbore Field Name Wellbore Status ncl(1) (ftKB) Act Btm(ftKB) • • 11 Isr.y.lir 50029221 KUPARUK RIVER UNIT INJ 95.50 9,470.51 9,340.0 t_onocoPF9lHps i(' Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) ,Rig Release Date ... SSSV.TRDP Last W0: I 42.99 3/24/1991 1L-18AL1,4/12/201812:36:44 PM Last Tag VerEcal schematic(actual) Annotation Depth(ftKB) End Date Last Mod By Last Tag: lehalit Last Rev Reason Annotation End Date Last Mod By HANGER;378 Rev Reason: CORRECTED SIDETRACK DONE IN 2016 8 GLV(#1 com) 4/12'2018 pproven Casing Strings Casing Description I OD(in) IID(in) I Top(ftKB) Set Depth(ftKB) Set Depth ITVD) Wt/Len(I...I Grade Top Thread IV AL1 LATERAL LINER I 2 3/81 1.9921 7,159.61 9.340 01 6,098.21 4.601L-80 STL .,,,,,,,,,,,,,,,,,,,,r„.a.n.,e..,,,,,,,,,,nil, a.n ,,. Liner Details J Nominal ID Top(ftKB) Top(TVD)(FMB) Top Incl C) Item Des Corn (in) 7,159.6' 5,890.5 43.22 DEPLOY 'Shorty Deployment Sleeve 1.900 i -^-A-CONDUCTOR;43.0-122.0 Notes:General 8 Safety • End Date Annotation • 7/27/2016 NOTE: CTD SIDETRACK 7/27/2016 12:00 NOTE: SAFETY VLV;1,793.1 `i■G /S GAS LIFT;1,938.5 SURFACE;42.04,120.8 GAS LIFT;7,045.7 PBR,7,102.6 C1 PACKER',7,116.3 S 2 i k 2 1 NIPPLE,7,1327 h 5. h • SOS',7.166.7fl , APERF;7,244.0-7.298 III-.4 Cement Squeeze;7,114.0 ftKB C WHIPSTOCK-MONOBO7, S C k. A (PERF;7,442.0-7,464.0 45 !PERF;7,540.0-7,550.0#Z S T PRODUCTION;35.4-7,788.8 - AL1 LATERAL LINER;7,159.6i [ 8,340.0 THE STATE °fALASKA GOVERNOR BILL WALKER Jason Burke Staff Wells Engineer ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1L -18A Permit to Drill Number: 216-056 Sundry Number: 318-070 Dear Mr. Burke: Alaska Oil and Gas Conservation Commission 333 west Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.a laska.gov Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this day of February, 2018. REMOS l`/FED 2 7 2118 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED FEB 21 2018 00-5 z/Z .) h'iaj AOGCC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate Q , Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: DAD ACID Stimulate ❑� , 2. Operator Name: 4. Current Well Class: rmit to Drill Number: ConocoPhilli s Alaska Inc. Exploratory ❑ Development 71216-056-0 Stratigraphic ❑ Service 0 ' 3. Address: L6.APINumber: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22145-01 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1L -18A - Will planned perforations require a spacing exception? Yes ❑ No 0 ✓ 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25659. I Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10,955' 6,071' 10.955' 6,071' 2,657psi NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 79' 16" 122' 122' Surface 4,079' 95/8 4,121' 3,566' Production 7,351' 7" 7,789 6,350' Liner 3,110' 23/8 10,955' 6,071' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7845-169 i 6108 - 6071 3.500" J-55 7,167' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER - BAKER HB RETRIEVABLE PACKER MD= 7116 TVD= 5859 12. Attachments: Proposal Summary ❑, Wellbore schematic O 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigmphic ❑ Development ❑ Service E ' 14. Estimated Date for 316/2018 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG 0 GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Jason Burke Contact Name: Jason Burke Authorized Title: Staff Wells Engineer Contact Email: Jason.burke@cop.00m Z Z/ Contact Phone: (907) 265-6097 Authorized Signatur Date: G COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT RegI Yes ❑ No n REcmJ , Z Spacing Exception Required? Yes ❑ No IA/ Subsequent Form Required: ! Q — f d 4 APPROVED BY Approved by: \— COMMISSIONER THE COMMISSION Date: � `v,z �31RR�S I N A L ^ IN Form 10403 Revised 4/2017 Approved applicatQiS valiII for 12 months from the date of approval. V Submit Form and Attachments in Duplicate -"� KUP INJ 1L-18 1 Well Attributes Max Angle 8 MCcili�D TD OC�)��)�$ rtt venlwre ApW'M FieN wme wenMre slatos nd' MO In., lest nM 1.8) NBs'kB.Ir1D. 5002922145M KUPARUK RIVER UNIT INJ 4479 3,20000 7,800.0 Comment K351ppm) Dale An—b— In.OM 1-111 "a 11-111 SSSV;TBDP Last WO; 42N 32411991 IL -I0. L]INYJI01?A21 PM Last Tag Annohtion DeWM1(IM I Ebd Dab 1 uMed By Last Tag: SLM ],1240 5/11!2016 pproven Last Rev Reason Amnlagon Endada LHaL MIM ay Rev ReasonADD IATERALS 81112016 IeM1alll HFHGER, T e Casing Strings camp Deae,fion oo intto Il TIP Me see DepLn lmcal sed aegn lND)... MLen u... cna. Tepmwd CONDUCTOR 18 15.062 430 1220 122.0 6250 H40 WELDED CampD "Pugn ODllnl ID llnl TIP I—I sM beeM(1Ke1 sM ublen fblb-. Wtllen ll.. Orale Top TM1reW SURFACE 9518 8.921 420 4,120.6 3,566.5 35.00 J-55 BTC ,ring..iguen —gnl 109n, TIp 11Ma1 9N aepN lflNe) SN Depn,IND)... be. fI... Orade apin— 7.el14ad-IJ PRODUCTION 7 6.2]6 354 7,]88.6 6,350.5 26.00 J-55 BTC4MOD Tubing Strings Tubing Descriptio! stung ,,. pol TIp'de" sx owleln.. set Depin lrvol l... wL 0Nn1 cane Topcommarn TUBING Jln 3I1 2.992 3).9 71676 5,896.3 9.30 J-55 EUEBNABMOD 3 Completion Details SAFETY VW, 1,Re 1 mPf1VD1 TePIw Nlmine Top(N(B) ay.) r) wm bea obb ID pn) 37.9 379 0.03 HANGER FMC GEN IV TUBING HANGER 3500 1,]99.1 17812 2009 SAFETY VLV CAMCO TRDPdA SAFETY VALVE 2812 ],1026 5,848.9 430] PBR BAKER IO' STROKE PBR 3000 ],116.3 5,858.9 43.11 PACKER BAKER HB RETRIEVABLE PACKER 3.500 DAs LIM I Das ],132] 58)0.8 43.15 NIPPLE CAMCO D NIPPLE NO GO (MILLED TO 2,80" on 5162016) 2800 7,1667 5,895.6 4324 SOS BAKER SHEAR OUT SUB 29N Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) TIPf1V01 Tepptl(B) IIIKe) TIP mm PI Dea Com sun DDH ID (in) 7,3855 6,055.] 0.]] WHIPSTOCK- 3.5' Baker XL Tray wiN OH ancMr ]/1112016 0.000 MONOBORE Perforations & Slots SURFACE 436a.IN.O-1nb Top 8) au (.) T., MD) me) age IND) fil IDne Dale fsM1OhXI 1 Type Lom 7,244.0 ],298.0 5,951.9 5,991.5 Cd, 1L-18 81IN1991 60 APERF 2118"Enedet III; 0 deg -0b 7,462.0 ],464.0 6,0972 6,113.4 A5, 1L-16 8112/1991 40 PERF 4.5"HSD Gag Gun; 180 deg. ph Dns LIFT; T,OIS.T 7,5400 7,550.0 —6-1 6-9 —2 8,178.5 Ad, 1L-18 6111/1991 4.01PERF 4117HSD Csp Gun;180 pM1asing; Coveretl wl fill fill Cement Squeezes T.IRMS) eMfllKal T"BRA) 61m fN0) gl =1 Dee ad,lwle cIm 1,114.0 7632.0 5.862 6236.5 Cement&&2016 Laya 35DMsof16.5ppg Celnenl(20bubmull p.. 71.n Squeeze CO.Nel Fiber) Mandrel Inserts st PPCKER; ).tla3 on N TapIND) Vales Ishn TIp IIDLaI even Mare Model oD Onl sery Tyw Taw PMaW Tf10 wn Ile) Ipso Run deal com 1.938SI 1,911.5 MCMurry FMHO 1 GAS LIFT DMY BK2 0000 0.019Q41991 1130 21 7,0457 5,807.3 1 MACCO 5PM-2 I 1112 GAS LIFT JDMY IRK 0.000 0.0 12511992 lbUU Notes: General & Safety EM Dad Anncladon NIPPLE:]I]!.7 10142010 NOTE; View Schematic wl All SLbemabc9.0 5057,1!8.] APERF: 73 0. 7, G. Cement Seta; 7.1140 fuS WHIPSTOCK. MONOWRIE ],3955 IPERR 7.A4g,6744fp— IPERF,7,51p07,5`Op— PRCgILTION; S 4-Twfil AD LATERAL LINER: 7, 196 8,3100 J901t, KUP INJ IL -18A -1 �'� Well ttribu Well Attributes Max Angle 8 MD TO r(/r/� cor^owp �`'mps W FINe Name WNIbp¢6Y1u5 n[I I°) M011Na1 ACI BIm Im(01 ' NaS9a.IDC. 500292214501 KUPARUK RIVER UNIT INJ 164.81 9.Ofi040 16,955.0 Canlmm1H1B IpPm1 Oab $SSV: TRDP AIn Wn Ene Oak Last WO: NBG�46L1 4299 RIB Reka' Dab 812411991 1,-I p2 812Swpm Last Tag Annayppl BeINA 18Ka1 Ene Dab Leat MM By Lass Tag: lehallf Last Rev Reason _._............. P ERI ate Annda4on Rev Reason: ADD LATERAL$ Ene Oab Lse Moe ay 81112016 eaall( Casing 3kings cssl.m Wa[nWon oD Unl ID RnI TIP lnxat A LATERALLINER 2818 1.992 ),8450 6NoePb DIKBI sN Mn nvo)... 1Q955.p wuLen ll... Wane 460L-80 toprneeatl STL Liner Details xamLn' m cox0ucroR: a3.a1a0 F rao lnRel rap liVOimNa1 rop Inch C1 lbm 0n cum 0^I) ].845.0 6,1085 9144 BILLET AnchoreO Aluminum Di8e1 1.9011 7,899.4 6,106.8 JUEPLOY IShorly DeDkyment Sleeve 1,900 8,0124 1 6,129.51 90.07 IDEPLOY Shorty Deployment Sleeve 1900 SKEET, IV. I..I Notes: General 8 Safety End mb An�mn NDTE cab UFr; tpms SURFALE;42".IM6� ws uFr'.�oas.] PBR, 7.1028 WI<ER;],f163 NIPPLE, ]1W APERF;],N4.0.],MG9 eennle4uass:7.1140MB W IPSTOLK-MIXIJMls ],3455 WERF;],M24],4G.0_ IPERF ; 7,SW.LLT.5 � PROOUCTION;Y6],]M.6 ALI LATEW LINE R; 6.310.0 f A UTERAL LINER;] a a50J to..0 410 . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday,September 14,2016 Jim Regg P.I.Supervisor zol t 140 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1L-18A FROM: Johnnie Hill KUPARUK RIV UNIT 1L-18A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry ;1 NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1L-18A API Well Number 50-029-22145-01-00 Inspector Name: Johnnie Hill Permit Number: 216-056-0 Inspection Date: 9/11/2016 Insp Num: mitJWH160911195858 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1L-18A Type Inj W TVD 5859 Tubing 2339 _ 2343 . 2318 . 2394 PTD 2160560 Type Test!SPT Test psi! 1500 • IA 1100 1820 - 1740 , 1720 Interval LITAL / PAF C P ✓ OA 630 660 -I 660 . 660 . Notes: SCANNED APR 2 7 2017 Wednesday,September 14,2016 Page 1 of 1 • • S �C� oI I 0 0 - • . 0 • • . 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K.BENDER Anchorage,Alaska 99510 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE GR-RES BHI DISTRICT Alaska LOG DATE July 26,2016 AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider@bakerhughes.com TODAYS DATE August 22,2016 Revision STATUS Final Replacement: No Details: Requested by: COMPANY FIELD FINAL CD CD ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #UI-PHIN IS #OF COPIES #OF COPIES #OF COPIES LL 1 BP North Slope 0 0 0 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 1 0 0 0 Attn:Ricky Elgaricio ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska I 0 I 0 I 0 I Attn:Lynda M.Yaskell and/or Leonardo Elias 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC I 1 I 1 I 1 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 0 1 1 Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. 1 1 1 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 TOTALS FOR THIS PAGE: 0 2 3 3 0 0 TOTALS FOR ALL PAGES: 0 2 3 3 0 0 LP . • to O s J Lc) t47 (NI IIIIH <v allW MW. 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N- N Cr) CO N W N V Cu N m CD to N O N CO Cu m CO M M CO. a 7 7 7 V ^ 0) N O O 4 co 6 co Oi O 0) M N N 4 O CD Oi 0C Oi CO co co S U Y CD J J J C t.. m m m m m m M m Cu CO m m m m m m m m m CD Cu CO Cu CO Cu co O r r 0- m m U) (O U) N U) U1 V M CD N O CO N M O M m C` m V0 V V CO CO N CO N N N C` CO N CO N 0) 0) , CD O CO 7 N CO N CO m O CV MOC C O UUU) U) UO UUUN UUU) O O N co OrO O d OO Ui N % N N N N C]NM 0) V aV oN n N N(O M2n Vn 1: Mg COpmm 0m v O O O O o O O O O O O O O O O O O O O O O O O O O O coUn d .. a ) N E � N• O .+ dd Z • • 21 sols ECI�/ 27510 AUG 2 4 2016 PRINT DISTRIBUTION LIST BAKER HUGHES '''!®GCC Please sign and return one copy of this transmittal form to: COMPANY ConocoPhillips Alaska,Inc. ConocoPhillips Alaska, Inc. Tom Osterkamp DiaTh LOGGED WELL NAME 1L-18APB1 700 G Street. $ /20 ��� K.BENDER Anchorage,Alaska 99510 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE GR-RES BHI DISTRICT Alaska --- LOG DATE July 26,2016 AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider@bakerhughes.com TODAYS DATE August 22,2016 Revision STATUS Final Replacement: No Details: Requested by: COMPANY FIELD FINAL CD CD ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #OF PRIN I S #OF COPIES #OF COPIES #OF COPIES 1 BP North Slope 0 0 I 0 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. I 0 I 0 I 0 Attn:Ricky Elgaricio ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska 0 0 0 Attn:Lynda M.Yaskell and/or Leonardo Elias 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC I 1 1 I 1 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** I 0 I 1 I 1 Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. I 1 1 1 1 1 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 TOTALS FOR THIS PAGE: 0 2 3 3 0 0 TOTALS FOR ALL PAGES: 0 2 3 3 0 0 O in O • Lii O v"- to LO r N N N 0. M I Ci C 2 c 0 LIU ® Q w W Q I- >+ 0 y Z •_ s i ■— N O V R J - ,— ••• N � iii Q El r • c� - L Q , ■= 7 0 L o 2. Q. °° o co w Q i • • • ►�MI VI Z n- = N m o m io M O C N m O O O _ R ` i•- 7 m t 12 (7, O O y ... V) N V N y W r a U. 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O O6 V N M N N N ON -±- 2 -rt v V V } v O CO N- CO N tn C V O 0 O) 0 m 0) o) ,t- ,F5 co co co co co a o 0) N. NN U) Y $v co Ci 0) v 0 0 0 0 0 U v (D c0 O c0 O C (0 Y N _ O c0 CO CD O O N O O O C N cc, co Q_ 6... N CN') N N 2 0- N d > J N d CO 03 Om C Y a 0_ O o CO` `m oo coQro m m rn u(0) u(0) c n o_ u e S U Y Y ,- $ rn m m rn rn �O ClN. O U N NN N- V 0 N. O ,.- roOV h M hi 0 id Ni CC = N NNC) M • a aco- m m CD O U oN m m a 2 o• a ca3 3 o U)) CO II • 0 21 6056 EC IV' � 11 ir 2 7 5 BAIII" AUG 2 4 2016 PRINT DISTRIBUTION LIST HUGHES AOGCC OGC Please sign and return one copy of this transmittal form to: COMPANY ConocoPhillips Alaska,Inc. ConocoPhillips Alaska, Inc. Tom Osterkamp DATA LOGGE=D WELL NAME 1L-18APB2 700 G Street. M.K. BENDER�I. 6ENf�t=R Anchorage,Alaska 99510 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE GR-RES BHI DISTRICT Alaska --- LOG DATE_ July 26,2016 AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider@bakerhu•hes.com TODAYS DATE August 22,2016 Revision STATUS Final Replacement: No Details: Requested by: COMPANY FIELD FINAL CD CD ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #OF PHIN I S #OF COPIES #OF COPIES #OF COPIES 1 BP North Slope 0 0 0 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker , 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. I 0 0 0 Attn:Ricky Elgaricio ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska I 0 I 0 I 0 Attn:Lynda M.Yaskell and/or Leonardo Elias 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC I 1 I 1 I 1 I Attn:Makana Bender 333 W.7th Ave,Suite 100 ,Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 0 1 1 Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. 1 1 1 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 TOTALS FOR THIS PAGE: 0 2 3 3 0 0 TOTALS FOR ALL PAGES: 0 2 3 3 0 0 r to • • r- e-- 0 co in N N 4n IM biWn m N 0- I C) Ci ILL t >II 4 0 O :1 (5,-N g 0 0 tu Q < Q DC 0 z w U—a u) .. /^ v, s — Ov O > Cl- _ > O V � � mN }' N C0 O � � aN al \V W � 1 Q 0 coW 0 4 I. . • • • To mZ o a 4M,we v '3'. 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A (O N V V ) O O _ (0 (0 • O C CJ J V ^ OrC N N O r O0 NC 0 NC N OOONV 2mmmOOONOO S U Y •- r r r Z Oal C O (O C C N 0 V r N N N (D (O 0 N CO 0 N N CO N C V 0 00 V N O 0 0p 0) 0) 000) N pOp ,p-- N .- .- p 00p 07 7 O 'p- pO O O C O a ici O T - 00'1 V Or O 2 0 2 N 8 CO O V Or 8 0 8 0 N 8 CD O R 0 0 0 N V N _' C .. i 0 ,V V V O CO C0 N (O (0 (D r r r CO CO CO CO C CO C O 0 0 0 .- r2 V N CD CD CD CD CD co- CD CD CD CD CD CD N Cf) Cf) Cf) CD CD CD OI OI 0I 0) 0) 0) 0) (p a m .. a o) Co V G O °r' N d N N RECEIVED 0 STATE OF ALASKA • AUG 2 3 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND L OGCC la.Well Status: Oil❑ Gasp SPLUG❑ Other ❑ Abandoned ❑ Suspended❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory❑ GINJ ❑ WINJ❑ WAGE . WDSPL❑ No.of Completions: Service I] 1 Stratigraphic Test❑ 2.Operator Name: 6. Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 7/27/2016 216-056/ 3.Address: 7.Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 7/12/2016 50-029-22145-01 ' 4a.Location of Well(Governmental Section): 8.Date TD Reached: 16.Well Name and Number: Surface: 507'FNL, 143'FEL,Sec 31,T11N, R10E, UM 7/22/2016 a KRU 1 L-18A/1 L-18APB1/1 L-18APB2 Top of Productive Interval: 9. Ref Elevations: KB:130 17. Field/Pool(s): 4383'FNL,4123'FEL,Sec 32,T11N, R10E, UM GL:87 BF:88 Kurparuk River Field/Kupark River Oil Pool • Total Depth: 10.Plug Back Depth MD/TVD: 18. Property Designation: 3361'FNL,83'FEL,Sec 31,T11N,R10E, UM n/a ADL 25659 . 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 539924 y- 5948461 Zone-4 10955/6071 • ALK 2585 TPI: x- 541259 y- 5944593 Zone-4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 540010 y- 5945608 Zone-4 1799/1781 1473/1470 5.Directional or Inclination Survey: Yes El (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)I 7386/6056 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to: mud log,spontaneous potential, gamma ray,caliper,resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT. PULLED 16 62.5 H-40 43 122 43 122 24 235 sx ASI 9 5/8 36 J-55 42 4120 42 3567 12 1/4 800 sx PF Type E,500 sx Premium 7 26 J-55 35 7789 35 6351 8 1/2 250 sx Class G 2 3/8 4.6 L-80 7845 10955 6108 6071 3 slotted liner. 24.Open to production or injection? Yes ❑ 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): 3 1/2 7168 7116/5859 SLOTTED LINER @ 7845-10955 MD and 6108-6071 TVD COMPLETION 1UN 26.ACID, FRACTURE,CEMENT SQUEEZE,ETC. ATFWas hydraulic fracturing used during completion? Yes 111 No 0 - - I v -)i(-P Per 20 AAC 25.283(i)(2)attach electronic and printed information /ERIFIED DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED LV 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 8/4/2016 FLOWING (primary de letion) Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 8/5/2016 12 Test Period 104 156 125 176 Bean 1500 SCF/STB Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 195 psi 364 psi 24-Hour Rate —► 208 312 250 27 Form 10-407 Revised 11/2015STV `t''3i, ,l. CONTINUE ON PAGE 2 RBDMS LV AUG 2 5 2016Submit ORIGINIAL on • I 28.CORE DATA Conventional Core(s): Yes ❑ No D Sidewall Cores: Yes ❑ No 0 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 El Permafrost-Top Surface Surface If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1473 1470 Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval 7447 6093 information, including reports,per 20 AAC 25.071. (Kuparuk A5 Sand) TD(Kuparuk A Sand) 10955 6071 1L-18APB1 9313 6076 TD(Kuparuk A Sand) 1L-18APB2 9184 6028 TD(Kuparuk A Sand) Formation at total depth: Kuparuk A Sand 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, oaleontoloaical report.Production or well test results.per 20 MC 25.070. 32. I hereby certify that the foregoing is true and correp to the best of my knowledge. Contact: Jeff Connelly(a)263-4112 - . - Email: Jeff.S.Connelly(a),conocophillips.com Printed Name: G. Elle• Title: CTD Engineering Supervisor Date: % G 7 IVb Signature: ` Phone: 263-4172 INSTRUCTIONS General: This form and t - -• ired attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,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 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 MC 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 MC 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 11/2015 Submit ORIGINAL Only • • • 1L-18A CTD Schematic m 3-1/2"Camco TRDP-4A SSSV @ 1799'MD(2.812'min ID) 16"62#H-40 shoe @ 122'MD 3-1/2"9.3#J-55 EUE 8rd Tubing to surface 9-5/8"36#J-55 shoe @ 4121'MD 3-1/2"McMurry gas lift mandrel @ 1939' 3-1/2"Macco gas lift mandrel @ 7046' Baker 3-1/2"PBR @ 7102'MD(3.0"ID) Baker HB packer @ 7116'MD(3.5"ID) 3-1/2"Camco D landing nipple @ 7133"MD -yn Baker SOS @ 7167'MD C-sand perfs 7244'-7298'MD 1L-18AL1 wp04(South) KOP @ 7386'MDTD @ 9,504'MD `, Lined from 7160'-9340'MD • 1L-18A wp06(NW) ___ TD@ 10,955'MD Anchor Billet @ 7845'MD A-sand perfs 7442'-7464'MD 7540'-7550'MD A _ _- 1L-18APB1 TD@9313'MD Anchor Billet @ 8441'MD 1 L-18APB2 TD @9184'MD Anchor Billet @ 8410'MD 7"26#J-55 shoe 7789'MD KUP IIS 1 L-18 ConocoPhiflips Well Attribu Max AngIL TD AIANka.Inc, Wellbore API WWI Field Name Wellbore Status ncl(.1 MD(ftK I Act Btm(ftKB) CorK+'caPhigrps ir 500292214500 KUPARUK RIVER UNIT INJ 44.79 3,200.00 7,800.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1L-1e,8x2320168:34:51 AM SSSV.TRDP Last WO: _ 42.99 3/24/1991 Verbs/schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,124.0 5/11/2016 Rev Reason:ADD LATERALS lehallf 8/1/2016 Casing Strings 1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread HANGER,37.8 t al 1 CONDUCTOR _ 16 15.062 43.0 122.0 122.0_ 62.50_H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...-Wt/Len(I.. Grade Top Thread SURFACE 95/8 8.921_ 42.0 4,120.6 3,566.5 36.00 J-55 _BTC - Casing PRODUCTION Description OD(in) 7 ID(in))276 Top(ftKB) 4 Set Depth(ftKB)7,7886'Set Depth(TVD)0.5'Wt/Len(I...'Grade Top Thread 26.00 J-55 BTC MOD :- v. u, F • 'Tubing CTION Strings s L F Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection i ': iii TUBING 31/2 2.992 37.9 7,167.61 5,896.3 9.30 J-55 EUE8rdABMOD .n.".CONDUCTOR;43.0-122.o.L/v^ Completion Details ' Nominal ID Top(ftKB) Top(ND)(ftKB) Top India) Item Des Com (in) III 37.9 37.9 0.03 HANGER FMC GEN IV TUBING HANGER 3.500 1,799.1 1,7812 20.09 SAFETY VLV CAMCO TRDP-4A SAFETY VALVE 2.812 SAFETY VLV;1,7991 6,Y II 7,102.6 5,848.9 43.07 PBR BAKER 10'STROKE PBR 3.000 7,116.3 5,858.9 43.11 PACKER BAKER HB RETRIEVABLE PACKER 3.500 S 7,132.7 5,870.8 43.15 NIPPLE CAMCO D NIPPLE NO GO(MILLED TO 2.80"on 2.800 5/6/2016) 7,166.7 5,895.6 43.24 SOS BAKER SHEAR OUT SUB 2.992 GAS LIFT;1,938.5 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) • 7,385.5 6,055.7' 42.77 WHIPSTOCK 3.5"Baker XL Tray with OH anchor 7/11/2016 0.000 MONOBORE Perforations&Slots Shot • Dens 6 Top(TVD) Btm(TVD) (shots/ SURFACE;42.0-4,120. Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 7,244.0' 7,298.0 5,951.9 5,991.5 C-4,1L-18 8/13/1991 6.0 APERF 2 1/8"EnerJet III;0 deg. ph 7,442.0 7,464.0 6,097.2 6,113.4 A-5,1L-18 6/12/1991 4.0 (PERF 4.5"HSD Csg Gun;180 deg.ph GAS LIFT;7,045.7 ( ` 7,540.0 7,550.0 6,169.2 6,176.5 A-4,1L-18 6/12/1991 4.0 IPERF 4 1/2"HSD Csg Gun; 11 180 deg.phasing; Covered w/fill Cement Squeezes Top(TVD) Btm(ND) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com 7,114.0 7,632.0 5,857.2 6,236.5 Cement 5/8/2016 Lay in 35 bbls of 16.5 ppg Cement(20 bbls with POR,z1n2.0 Squeeze CemNet Fiber) a Mandrel Inserts i ; St iys._elC111 1.; at,, PACKER,7.116.3 A, ,. o Top(TVD) Valve Latch Port Size TRO Run k' Sat', N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com + 1 1,938.5 1,911.5 McMurry FMHO 1 GAS LIFT DMY BK2 0.000 0.0 9/24/1991 1:30 . I ! 2 7,045.7 5,807.3 MACCO SPM-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 1/25/1992 5:00 Notes:General&Safety End Date Annotation NIPPLE:7,132.7 10/4/2010 NOTE:View Schematic w/Alaska Schematic9.0 inSi. L SOS,7,166.7 i °'S + i R i i i + i i APERF;7,244.0-7,298.0 i k. i "z. Cement Squeeze;7,114.0 ftKB �` WHIPSTOCK-MONOBORE; + 7,385.5 k (s. i k i IPERF,7,442.0-7,464.0- i \ i. IPERF;7,540.0-7,550.0--.+ i • • PRODUCTION;35.4-7,788.6 AL1 LATERAL LINER 7,159.6- 9,340.0 KUP P OD 1 L-18A ClonocoPhillips t',g Well Attribut� Max Angle TD Alaska,Inc Wellbore API/UWI Field Name Wellbore Status ncl(") MD(ftK Act Btm(ftKB) Conosli►ptlilli Ps ^' 500292214501 KUPARUK RIVER UNIT PROD 104.81 9,060.40 10,955.0 ., ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1L-I8A,8/18/2016 2 29:32 PM SSSV:TRDP Last WO: 42.99 3/24/1991 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:ADD LATERALS lehallf 8/1/2016 Casing Strings HANGER;37.8 i Casing Description OD lin) ID Be) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread €'''a A LATERAL LINER 2 3/8 1.992 7,845.0 10,955.0 4.60 L-80 STL Liner Details Nominal ID " 4. KUP P OD 1L-18AL1 Well Attrib Max An I TD ConocaPhilll no s Alaska.lnc, Wellbore API/UWI Field Name Wellbore Status ncl(1) MD( Act Btm(kKB) C>no<oPhilhps l 500292214560 KUPARUK RIVER UNIT PROD 95.50 9,470.51 9,340.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(k) Rig Release Date 1L-16AL1,1/22/2016221:31 PM SSSV:TRDP Last WO: 42.99 3/24/1991 Vertical schematic.(actual) Annotation Depth(kKB) End Date Annotation last Mal By End Date Last Tag: Rev Reason:ADD LATERALS lehallf 8/1/2016 using Strings ' i'm=�" Casing Description OD(in) ID(inl Top(kKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread HANGER;37.8 ` � AL1 LATERAL LINER 2 3/8 1.992 7,159.6 9,340.0 6,098.2 4,60 L-80 STL Liner Details Nominal ID Top(568) Top(TVD)(kKB) Top Incl(1) Item Des Com (in) i ;,;: 7,159.6 5,890.5 43.22 DEPLOY Shorty Deployment Sleeve 1.900 1 Notes:General&Safety ` End Date Annotation NOTE' S�CONDUCTOR;43.0-122.0 - SAFETY VLV;1,799.1 nn•II 11 GAS LIFT,1,936.51 1 ( if I SURFACE;420-0,120.6-+ GAS LIFT;7,045.7 AK- PBR;7,102.6 -_ } • - PACKER;7,116.3 ii, , r i I i A NIPPLE,7,132.7 751,5 A A A isis i A SOS.7,1667 Y i A A I i APERF,7,244.0-7,2980 • A Cement Squeeze;7,114.0 kKB t '* WHIPSTOCK-MONOBORE; 0 * 7,385.5 1,, '+ i IPERF,7,442.0-7,4640-- i s• : i i 0. (PERF;7,540.0-7,550.0--.> i t i PRODUCTION;35.4-7,768.6 AL1 LATERAL LINER;7,159.6- l 9,340.0 1111 !0 ! Operations Summary (with Timelog Depths) ' r� 1 L-18 'hilliips t,ia ka Rig: NABORS CDR2-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 MKS) 7/8/2016 7/8/2016 1.50 MIRU MOVE MOB P Complete rig down checklist&secure 0.0 0.0 00:00 01:30 BOPE. 7/8/2016 7/8/2016 3.50 MIRU MOVE MOB P PJSM wl NES,pull pits off to side,pull 0.0 0.0 01:30 05:00 sub off 1L-24A,prep 1L-18 cellar,spot drilling module over 1L-18,set mats. 7/8/2016 7/8/2016 3.00 MIRU MOVE MOB P Spot pit module,mat,set down. 0.0 0.0 05:00 08:00 7/8/2016 7/8/2016 4.00 MIRU MOVE MOB P Complete post rig move checklist. 0.0 0.0 08:00 12:00 SIMOPS-replace isolation valves (Cameron butterfly)on mud line.Rig prep crew fixed leaky valve in manifold and bled 1L-18 gas inj line to 0 psi. DBB in manifold bldg.Scaffolding over gas inj line in cellar for drop protection. 7/8/2016 7/8/2016 4.00 MIRU MOVE RURD P NU BOP,fill rig water tanks,circulate 0.0 0.0 12:00 16:00 surface lines,perform BOP shell test, test inner reel iron and stripper. **Rig Accept at 16:00 on 07/08/2016" 7/8/2016 7/8/2016 4.00 MIRU WHDBOP BOPE P Perform initial BOP test 250/3,600 0.0 0.0 16:00 20:00 psi.Annular 2,500 psi.Witnessed waived by AOGCC Bob Noble at 17:00 on 07/07/2016 over the phone. 7/8/2016 7/8/2016 1.00 MIRU WHDBOP SFTY P CPAI July 1st Safety Awareness 0.0 0.0 20:00 21:00 discussion with day crew and fresh night crew just arriving on slope,1st day back. 7/8/2016 7/9/2016 3.00 MIRU WHDBOP BOPE P Continue Initial BOP test 250/3,600 0.0 0.0 21:00 00:00 psi.Annular 2,500 psi.Failure on C11 valve. . 7/9/2016 7/9/2016 5.00 MIRU WHDBOP BOPE P Continue initial BOP test 250/3,600 0.0 0.0 00:00 05:00 psi.Annular 2,500 psi.Witnessed waived by AOGCC Bob Noble at 17:00 on 07/07/2016 over the phone. Change out C-11 valve,retest good. Fail/pass on B1,grease and retest good.LD test equipment.Draw down test. 7/9/2016 7/9/2016 2.50 MIRU WHDBOP PRTS P Pressure test PDL's and TT lines. 0.0 0.0 05:00 07:30 Move lubricator for BPV retrieval to rig floor. 7/9/2016 7/9/2016 3.00 MIRU WHDBOP MPSP P PJSM.RU lubricator&retrieve BPV. 0.0 0.0 07:30 10:30 Approx. 1200 psi found below BPV. Bled well to 0 psi.RD lubricator. 7/9/2016 7/9/2016 1.00 SLOT WHDBOP SEQP P Micromotion calibration test per Dave 0.0 0.0 10:30 11:30 Smith's procedure. 7/9/2016 7/9/2016 2.50 PROD1 RPEQPT PULD P Flow check.Measure kelly hose 0.0 62.0 11:30 14:00 length(rig workover prep).MU milling BHA#1 (2.8"HCC D331 mill w/slick gauge&Inteq Extreme 0.9°AKO motor). 7/9/2016 7/9/2016 1.25 PROD1 RPEQPT TRIP P RIH milling BHA#1 while pumping 62.0 7,030.0 14:00 15:15 seawater(EDC open). 7/9/2016 7/9/2016 0.25 PROD1 RPEQPT DLOG P Tie-in lower HRZ spikes(+11.5 7,030.0 7,078.0 15:15 15:30 correction). Page 1/17 Report Printed: 7/28/2016 • • 0 Operations Summary (with Timelog Depths) 1 L-18 Conor Phiflips Rig: NABORS CDR2-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) 7/9/2016 7/9/2016 1.50 PROD1 RPEQPT CIRC P Displace wellbore fluid to seawater 7,078.0 7,100.0 15:30 17:00 followed by 8.5ppg PowerVis milling fluid.Close EDC 7/9/2016 7/9/2016 0.40 PROD1 RPEQPT TRIP 'P 7,116 ft.Dry tag,PUW 34k,pumps on, 7,100.0 7,123.0 17:00 17:24 RBIH to 7,123 ft. 7/9/2016 7/9/2016 1.20 PROD1 RPEQPT MILL P 7,123 ft. OBM 1.72 bpm at 2,350 psi 7,123.0 7,128.5 17:24 18:36 FS,20°R,CWT 13.8k,WOB 1.6k,4 stalls and restarts,PUW's 36 to 40k 7/9/2016 7/9/2016 3.40 PROD1 RPEQPT MILL P 7,128.5 ft. OBM 1.6 bpm at 2,060 psi 7,128.5 7,168.5 18:36 22:00 FS,CWT 12.7k,WOB.5 to 1.6k,ROP 8 to 16 fph.to casing contact at 7,168.44 ft,stall,PUW 40k.RBIH 7/9/2016 7/10/2016 2.00 PROD1 RPEQPT MILL P 7,168.4 ft. Stalling,turn TF 220° for 1 7,168.5 7,170.0 22:00 00:00 ft,OBM 1.59 bpm at 2,060 psi FS, CWT 11k,WOB 7/10/2016 7/10/2016 1.25 PROD1 RPEQPT MILL P Continue milling 1.57 bpm at 2,060 psi 7,170.0 7,177.0 00:00 01:15 FS,CWT 11k,WOB 1.2k, ROP 8 to 10 fph 7/10/2016 7/10/2016 1.75 PROD1 RPEQPT WPRT T Pick up above cement,pump at 7,177.0 7,177.0 01:15 03:00 minimum,reboot BHI computers,DD screen in doghouse not showing split screen but enough info to proceed, RBIH 7/10/2016 7/10/2016 7.75 PROD1 RPEQPT MILL P 7,177 ft.BOBM 1.57 bpm at 2,220 psi 7,177.0 7,291.0 03:00 10:45 FS,CWT 12k,WOB 1.0k,ROP 10-25 fph. Stall @ 7226'.PU,CTW 39k.RBIH, resume milling. 7/10/2016 7/10/2016 0.50 PROD1 RPEQPT WPRT P PU heavy,dragging.CTW 45k.Wiper 7,291.0 7,291.0 10:45 11:15 to TOC(7120'), RBIH. 7/10/2016 7/10/2016 0.50 PROD1 RPEQPT WPRT 'P Couple stalls @7,291,not much 7,291.0 7,291.0 11:15 11:45 progress.PUH heavy to 7,078'.CTW up to 45k.Negative WOB @ 7170'(- 1.4k).RBIH,saw WOB spike @ 7170'(0.7k).Maintained 20°ROHS orientation.Stall again. 7/10/2016 7/10/2016 1.25 PROD1 RPEQPT MILL P PU to 7282'and orient toolface to 7,291.0 7,292.3 11:45 13:00 160°LOHS.RBIH,stall.Working pipe through squeezed perfs.CTW 10.6k, WOB 0.5k,ROP 4 FPH, 1.6 BPM. Metal shavings seen in returns. 7/10/2016 7/10/2016 3.50 PROD1 RPEQPT MILL P Change orientation back to 20°ROHS. 7,292.3 7,350.0 13:00 16:30 Continue milling ahead.Milling parameters improved once passed perfs(btm pelf @ 7298').CTW 10.8k, WOB 1.5k,ROP 20-22 FPH. 7/10/2016 7/10/2016 0.40 PROD1 RPEQPT DLOG P PUH.CTW 37k,0 WOB.Tie-in to K1 7,350.0 7,350.0 16:30 16:54 @ 7185'(+1'correction).RBIH,CTW 11.8k,WOB 0.4k,0.38 BPM. 7/10/2016 7/10/2016 3.00 PROD1 RPEQPT DRLG P 7,350 ft. Milling 1.6 bpm at 2,450 psi 7,350.0 7,415.0 16:54 19:54 FS,CWT 11.5k,WOB 1.6k,ROP 20- 22 fph,orient TF 220°at 7,398 ft, orient back to 20°R at 7,401 ft. ' 7/10/2016 7/10/2016 0.30 PROD1 RPEQPT WPRT P TD pilot hole at 7,415 ft,PUW 38k, 7,415.0 7,100.0 19:54 20:12 back ream up 20°R 15 fpm. 7/10/2016 7/10/2016 0.15 PROD1 RPEQPT TRIP P Dry drift pilot hole transition,RBIH 25 7,100.0 7,200.0 20:12 20:21 fpm,TF HS,RIW 14k,zero correction at K1,bobble at 7,173 ft,WOB 0.89. Page 2/17 Report Printed: 7/28/2016 • =' OVi perations Summary (with Timelog Depths) 0 1 L-18 Conocd hiwps Rig: NABORS CDR2-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) 7/10/2016 7/10/2016 1.40 PROD1 RPEQPT REAM P Back ream 5 fpm 180°to 7,160 ft, 7,200.0 7,200.0 20:21 21:45 ream down 5 fpm at 180° to7,180 ft. ream up at 1 fpm at 180°to 7,159 ft ream down 5 fpm at 180°to 7,183 ft. ream up 180°to 7,157 ft,PUH to 7,140 ft.Dry drift pilot hole transition, RBIH 25 fpm,TF HS,RIW 14k,bobble at 7,172 ft,WOB 0.27. 7/10/2016 7/10/2016 0.35 PROD1 RPEQPT OWFF P PUH 39k,Flow check at 7,050 ft.no 7,200.0 7,050.0 21:45 22:06 flow 7/10/2016 7/10/2016 1.30 PROD1 RPEQPT TRIP P POOH for caliper run. 7,050.0 62.0 22:06 23:24 7/10/2016 7/10/2016 0.40 PROD1 RPEQPT OWFF P On surface,flow check,good while 62.0 62.0 23:24 23:48 performing PJSM-LD BHA 7/10/2016 7/11/2016 0.20 PROD1 RPEQPT PULD P Unstab from well,disconnect BHA and 62.0 62.0 23:48 00:00 skid cart. 7/11/2016 7/11/2016 0.75 PROD1 RPEQPT PULD P Continue to lay down BHA#1. 62.0 0.0 00:00 00:45 7/11/2016 7/11/2016 0.50 PROD1 RPEQPT SVRG P Service injector, 0.0 0.0 00:45 01:15 7/11/2016 7/11/2016 0.75 PROD1 RPEQPT CTOP P Install nozzle,jet stack,remove nozzle 7,387.0 01:15 02:00 7/11/2016 7/11/2016 1.50 PROD1 RPEQPT PULD P MU BHA#2(HAL realtime caliper)to 0.0 26.0 02:00 03:30 coil,test caliper. 7/11/2016 7/11/2016 1.30 PROD1 RPEQPT TRIP P RIH with Halliburton caliper. 26.0 7,030.0 03:30 04:48 7/11/2016 7/11/2016 0.25 PROD1 RPEQPT DLOG P Tie in at HRZ(no correction). 7,030.0 7,050.0 04:48 05:03 7/11/2016 7/11/2016 2.50 PROD1 RPEQPT DLOG P POOH logging 1st caliper log run. 7,050.0 7,415.0 05:03 07:33 RBIH to 7410. POOH logging 2nd caliper run. Close caliper. 7/11/2016 7/11/2016 1.75 PROD1 RPEQPT TRIP P POOH BHA#2. On surface. PU and 7,058.0 0.0 07:33 09:18 inspect CT,CTC,and Caliper. 7/11/2016 7/11/2016 0.50 PROD1 RPEQPT PULD P LD BHA#2(caliper). 0.0 0.0 09:18 09:48 7/11/2016 7/11/2016 0.50 PROD1 RPEQPT OWFF P Flow check-good. 0.0 0.0 09:48 10:18 7/11/2016 7/11/2016 0.50 PROD1 RPEQPT SVRG P Perform rig maintenance. Inspect top 0.0 0.0 10:18 10:48 drive/rotating head for upcoming workover. 7/11/2016 7/11/2016 1.20 PROD1 RPEQPT PULD P PJSM.MU BHA#3 in pipe shed. PU 0.0 0.0 10:48 12:00 BHA#3. 7/11/2016 7/11/2016 1.75 PROD1 RPEQPT WPST P RIH with BHA#3(whipstock setting 0.0 12:00 13:45 assembly). EDC open pumping minimum rate while RIH(0.3 BPM). 7/11/2016 7/11/2016 0.25 PROD1 RPEQPT DLOG P Tie in @ K1 (+10.5'correction).Close 7,195.0 7,217.0 13:45 14:00 EDC.PU,CTW 43k. 7/11/2016 7/11/2016 0.25 PROD1 RPEQPT WPST P RIH oriented HS.CTW 11k.Stop @ 7,217.0 7,396.0 14:00 14:15 7396&PU CTW 30k to achieve neutral weight.Set whipstock.Set down weight(WOB 3.9k)to confirm set. 7/11/2016 7/11/2016 1.00 PROD1 RPEQPT TRIP P POOH.CTW 42k. 7,396.0 101.0 14:15 15:15 7/11/2016 7/11/2016 0.75 PROD1 RPEQPT OWFF P Flow check-good. 101.0 101.0 15:15 16:00 7/11/2016 7/11/2016 1.00 PROD1 RPEQPT PULD P LD BHA#3(whipstock setting 101.0 0.0 16:00 17:00 assembly). Page 3/17 Report Printed: 7/28/2016 gii • • Operations Summary (with Timelog Depths) 0. 1L-18 conoc&'himps Rig: NABORS CDR2-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) 7/11/2016 7/11/2016 0.85 PROD1 WHPST PULD P MU BHA#4(2.8"whipstock mill& 0.0 74.3 17:00 17:51 diamond string reamer w/Xtreme motor at 0.6°AKO)MU to CoilTrak, surface test 7/11/2016 7/11/2016 1.50 PROD1 WHPST TRIP P RIH with BHA#4, EDC open 74.3 7,108.0 17:51 19:21 circulating 8.6 used FloPro milling fluid 7/11/2016 7/11/2016 0.35 PROD1 WHPST TRIP P Close EDC,BHI program down again, 7,108.0 7,185.0 19:21 19:42 PU slow, PUW 38k,reboot files.RBIH 7/11/2016 7/11/2016 0.20 PROD1 WHPST DLOG P Tie in to K1 for plus 11 ft correction. 7,185.0 7,221.0 19:42 19:54 7/11/2016 7/11/2016 0.85 PROD1 WHPST TRIP P RIH,dry tag top of whipstock at 7,386 7,221.0 7,386.0 19:54 20:45 ft.PUH,bring up pump 7/11/2016 7/12/2016 3.25 PROD1 WHPST WPST P Begin milling whipstock per 7,386.0 7,387.0 20:45 00:00 recommended practice and Baker rep. from 7,385.2 ft. 1.7 bpm at 3,206 psi FS,CWT 14k, *Top of Whipstock @ 7385.2 ft` 7/12/2016 7/12/2016 7.75 PROD1 WHPST WPST P Continue milling window per RP and 7,386.9 7,390.3 00:00 07:45 Baker rep.1.7 bpm at 3,398 psi,CWT 14k,WOB 2.0 to 2.6k,ROP 0.4-0.6 FPH Note:bled IA down to 175 psi,OA down to 160 psi 7/12/2016 7/12/2016 1.75 PROD1 WHPST WPST P WOB dropped-1k lbs indicating 7,390.3 7,393.2 07:45 09:30 bottom of window @ 7390.3'. Continue milling window per RP.2 FPH to allow string reamer to clean-up window. *Btm of Window @ 7390.3 ft° 7/12/2016 7/12/2016 2.25 PROD1 WHPST WPST P Continue milling with managed 7,393.2 7,406.0 09:30 11:45 pressure system to 21 ft passed TOWS.Gradually increased ROP from 3 to 6 FPM.CTW 11k,WOB 2.3k,1.67 BPM©4310 psi. 7/12/2016 7/12/2016 1.50 PROD1 WHPST REAM P PUH,CTW 32k, 167 BPM.Ream the 7,406.0 7,406.0 11:45 13:15 window area(-7384'-7396')3 times per RP @ 1 FPM.Dry drift window @ 20 FPM-clean pass through window. 7/12/2016 7/12/2016 0.25 PROD1 WHPST DLOG P POOH,tie-in to HRZ @ 7045'(+1 ft 7,406.0 7,045.0 13:15 13:30 correction). 7/12/2016 7/12/2016 0.25 PROD1 WHPST DLOG P RIH,tie-in to K1 @ 7219'(no 7,045.0 7,219.0 13:30 13:45 correction). Note:Original well PDC log only had the K1 logged.Will use HRZ as primary depth correlation due to K1 being located in the cement pilot hole. (Do not want to slow down with bi- centered bit in pilot hole.) 7/12/2016 7/12/2016 1.75 PROD1 WHPST TRIP P POOH BHA#4(whipstock milling 7,219.0 89.8 13:45 15:30 assy).Open EDC.Cont POOH.PJSM -PUD BHA#4. 7/12/2016 7/12/2016 1.50 PROD1 WHPST PULD P PUD BHA#4. 89.8 0.0 15:30 17:00 7/12/2016 7/12/2016 2.75 PROD1 DRILL PULD P LD milling assembly/MU build section 0.0 72.2 17:00 19:45 BHA,install into PDL Page 4/17 Report Printed: 7/28/2016 itoit, • • Operations Summary (with Timelog Depths) ,a 1 L-18 Conocc:Whillips Rig: NABORS CDR2-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 MKS) 7/12/2016 7/12/2016 1.50 PROD1 DRILL PULD P PJSM,Pressure depoly build section 72.2 72.2 19:45 21:15 BHA 7/12/2016 7/12/2016 1.50 PROD1 DRILL TRIP P RIH,with build section assembly with 72.2 7,030.0 21:15 22:45 1.9°bend motor, RES and RR HCC bi -center bit.IA 165,OA 179 7/12/2016 7/12/2016 0.25 PROD1 DRILL DLOG P 7,030 ft,log the HRZ correction of plus 7,030.0 7,069.0 22:45 23:00 13.0 ft. 7/12/2016 7/12/2016 0.25 PROD1 DRILL TRIP P 7,069 ft,function closed EDC,PUW 7,069.0 7,406.0 23:00 23:15 31 k,continue RIH.Log the K1 correction of negative 2.0 ft. 7/12/2016 7/13/2016 0.75 PROD1 DRILL DRLG P 7,406 ft,OBD 1.6 bpm at 3,650 psi 7,406.0 7,423.0 23:15 00:00 FS,BHP 3,800,WHP 443,IA 289,OA 199 7/13/2016 7/13/2016 6.00 PROD1 DRILL DRLG P 7,423 ft,OBD 1.62 bpm at 3430 psi 7,423.0 7,590.0 00:00 06:00 FS,BHP 3785,WHP 443, IA 289,OA 190. Drilled hard spot @ 7511-7520'.Avg ROP 40-50 FPH after with avg WOB 1.5k. 7/13/2016 7/13/2016 1.75 PROD1 DRILL TRIP P POOH w BHA#5(build assy).Open 7,590.0 85.5 06:00 07:45 EDC above pilot hole,pump max rate. Jog 2159'-2375',saw increased cuttings in returns(unloaded well). 7/13/2016 7/13/2016 2.25 PROD1 DRILL PULD P PJSM,PUD BHA#5.LD motor.Install 85.5 0.0 07:45 10:00 FVS for RSM(RibSteer Motor)while BHA in mouse hole. 7/13/2016 7/13/2016 0.25 PROD1 DRILL SVRG P Rig maintenance,pull RF mats. 0.0 0.0 10:00 10:15 7/13/2016 7/13/2016 1.50 PROD1 DRILL PULD P PJSM,PU/PD BHA#6(HCC 3"bi- 0.0 69.2 10:15 11:45 center bit w RSM,GR,Resistiviity, CCL).Test MWD,strip on WH, equalize,tag stripper. 7/13/2016 7/13/2016 1.50 PROD1 DRILL TRIP P RIH BHA#6(RSM). 69.2 7,025.0 11:45 13:15 7/13/2016 7/13/2016 0.25 PROD1 DRILL DLOG P Tie-in to HRZ(+12 ft correction). 7,025.0 7,082.0 13:15 13:30 Close EDC. 7/13/2016 7/13/2016 0.25 PROD1 DRILL TRIP P Continue RIH.Pumps off to run 7,082.0 7,400.0 13:30 13:45 through window.Stack out @ 7390'(bottom of window).PU,pump @ min rate,pumps off,RIH,took weight but passed through. 7/13/2016 7/13/2016 0.25 PROD1 DRILL DLOG P Log RA in whipstock.Located @ 7,400.0 7,415.0 13:45 14:00 7,392.Corrected TOWS to 7,386'. 7/13/2016 7/13/2016 2.00 PROD1 DRILL DRLG P Continue RIH.OBD 1.63 BPM @ 7,415.0 7,704.0 14:00 16:00 3719 psi FS.WOB 1.6-2.1k,ROP 60 -70 FPH,CTW 10.5-11.5k. New mud at bit @ 7620'.New mud at surface @ 7690'. 7/13/2016 7/13/2016 0.25 PROD1 DRILL DRLG P Loosing pump prime,PU to 7,635', 7,704.0 7,704.0 16:00 16:15 RBIH.CTW 38k. 7/13/2016 7/13/2016 3.50 PROD1 DRILL DRLG P BOBD, 1.7 BPM @ 3727 psi,CTW 7,704.0 7,940.0 16:15 19:45 10.3k,WOB 1.5k,ROP 78 FPH 7/13/2016 7/13/2016 0.50 PROD1 DRILL WPRT P Wiper trip to window.CTW 39k. 1.72 7,940.0 7,400.0 19:45 20:15 BPM @ 3814 psi FS. 7/13/2016 7/13/2016 0.25 PROD1 DRILL WPRT P RBIH from window. 7,400.0 7,940.0 20:15 20:30 7/13/2016 7/14/2016 3.50 PROD1 DRILL DRLG P BOBD,1.7 BPM @ 3777 psi.Avg 7,940.0 8,158.0 20:30 00:00 ROP 69 FPH after wiper.CTW 1.1k- 1.6k. Page 5/17 Report Printed: 7/28/2016 Operations Summary (with Timelog Depths) 1L-18 conochimiips r6rk.o Rig: NABORS CDR2-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) 7/14/2016 7/14/2016 0.75 PROD1 DRILL DRLG P Continue drilling to section TD with 8,158.0 8,200.0 00:00 00:45 RSM. 7/14/2016 7/14/2016 0.50 PROD1 DRILL TRIP P POOH.CTW 36k. 8,200.0 7,400.0 00:45 01:15 Perform annular friction pressure loss calibration @ 7400', 1 FPM coil speed. Rate in=1.62 BPM,Rate out=1.61 BPM, Annular Pres=3705 psi,Choke Pres=450 psi,WHP=426 psi, MW ' in=8.6ppg,MW out=8.7ppg. 7/14/2016 7/14/2016 1.75 PROD1 DRILL TRIP P Cont.POOH,opened EDC @ 7120'. 7,400.0 79.4 01:15 03:00 7/14/2016 7/14/2016 2.00 PROD1 DRILL PULD P PJSM,PUD lateral BHA#6(RSM+ 79.4 0.0 03:00 05:00 used HCC bit) 7/14/2016 7/14/2016 1.75 PROD1 DRILL PULD P PJSM, BOP function test(due 0.0 0.0 05:00 06:45 7/15/2016)-good. 7/14/2016 7/14/2016 0.25 PROD1 DRILL PULD P PJSM,partially PD BHA#7(0.8 AKO 0.0 0.0 06:45 07:00 +RR HYC Duraforce). 7/14/2016 7/14/2016 1.50 PROD1 DRILL PULD P Change UQC(proactive after 250 hrs 0.0 0.0 07:00 08:30 service)&pressure test same to 4000 psi.Change out damaged injector packoffs. 7/14/2016 7/14/2016 0.75 PROD1 DRILL PULD P Skid over,MU QC,open DBVs.Finish 0.0 72.0 08:30 09:15 PD BHA#7. 7/14/2016 7/14/2016 1.75 PROD1 DRILL 'TRIP P RIH.Tie-in HRZ(+11.5'correction). 72.0 8,201.0 09:15 11:00 Close EDC.CTW 34k @ 7622'.Saw WOB spike @ 7890'(BOW). 7/14/2016 7/14/2016 6.25 PROD1 DRILL DRLG P BOBD, 1.6 BPM @ 3820 psi,CTW 8,201.0 8,590.0 11:00 17:15 10.1k,WOB 1.6k,70 FPH. 7/14/2016 7/14/2016 0.50 PROD1 DRILL WPRT P 8,590 ft,wiper up hole PUW 42 8,590.0 7,595.0 17:15 17:45 7/14/2016 7/14/2016 0.25 PROD1 DRILL WPRT P '7,595 ft,wiper back in hole,RIW 12 k 7,595.0 8,590.0 17:45 18:00 ****Bleed down IA 800 psi to 240 psi, OA 800 psi to 270 psi. ,7/14/2016 7/14/2016 2.00 PROD1 DRILL DRLG P 8,590 ft,BOBD 1.68 bpm at 3,500 psi 8,590.0 8,687.0 18:00 20:00 FS, BHP 3823,WHP 372, IA 241,OA 265 7/14/2016 7/14/2016 0.75 PROD1 DRILL WPRT P 8,687 ft,trouble getting weight to bit, 8,687.0 7,593.0 20:00 20:45 PUH,PUW 45 k,packing off around 8,628 ft. ,lowered pump rate,RBIH short distance,PUW still heavy 38 k. slowly PUH,established full returns, performed wiper up to the EOB, circulating a BTMS up.No shale in returns. 7/14/2016 7/14/2016 0.75 PROD1 DRILL WPRT P 7,593 ft,wiper back in hole,stacked 7,593.0 8,687.0 20:45 21:30 out at 7,623 ft,popped thru,continue wiper in hole,RIW 11 k 7/14/2016 7/15/2016 2.50 PROD1 DRILL DRLG P 8,687 ft,BOBD 1.7 bpm at 3,500 psi, 8,687.0 8,796.0 21:30 00:00 BHP 3845,WHP 367,IA 259,OA 266 7/15/2016 7/15/2016 4.50 PROD1 DRILL DRLG P 8,796 ft,OBD 1.58 bpm at 3649 psi, 8,796.0 9,017.0 00:00 04:30 BHP 3890,WHP 427, IA 308,OA 271 7/15/2016 7/15/2016 0.50 PROD1 DRILL WPRT P 200'wiper,CTW 39k.Stack out @ 9,017.0 9,020.0 04:30 05:00 8855', lowered rate&passed by. BOBD, 1.5 BPM @ 3884 psi AP,ROP 40 Page 6/17 Report Printed: 7/28/2016 Operations Summary (with TimelogDepths) ,tes 0' p ) 1 L-18 conoc hu ips xks Rig: NABORS CDR2-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) 7/15/2016 7/15/2016 1.00 PROD1 DRILL WPRT P PUH,wiper to window.Pulled tight 9,020.0 7,400.0 05:00 06:00 (43k)@ 8855',8602'-8575'. 7/15/2016 7/15/2016 0.10 PROD1 DRILL DLOG P Tie-in to RA(+4 ft correction). 7,400.0 7,436.0 06:00 06:06 7/15/2016 7/15/2016 1.40 PROD1 DRILL WPRT P RBIH,stack out @ 8230',8708',8885'. 7,436.0 9,022.0 06:06 07:30 Near bottom,working to get rate up, annular pressure spiking.CTW 47k. Pumped 5x5 sweep.No shale chunks in returns,just individualized particles (silt stone). 7/15/2016 7/15/2016 0.50 PROD1 DRILL DRLG P BOBD, 1.54 BPM @ 3333 psi FS, 9,022.0 9,038.0 07:30 08:00 WOB 1.2k,ROP 51.Geosteer up 95° +.Packing off @ 9038'.Lost WOB. PU,CTW 47k. 7/15/2016 7/15/2016 3.25 PROD1 DRILL DRLG P BOBD, 1.54 BPM @ 3510 psi FS, 9,038.0 9,165.0 08:00 11:15 CTW 7k,WOB 1.3k,ROP 46,IA 349, OA 278. Geosteer up to 100°. 7/15/2016 7/15/2016 0.25 PROD1 DRILL WPRT P PUH 30'to regain CTW,PUW 45k. 9,165.0 9,165.0 11:15 11:30 RBIH. 7/15/2016 7/15/2016 1.50 PROD1 DRILL DRLG P BOBD, 1.55 BPM @ 3560 psi FS, 9,165.0 9,192.0 11:30 13:00 CTW 6k,WOB 1.1k,ROP 24. Lost surface weight(CTW-4.0k)and packing off.PU,CTW 49k. 7/15/2016 7/15/2016 0.50 PROD1 DRILL DRLG P BOBD, 1.5 BPM @ 3534 psi FS,WOB 9,192.0 9,199.0 13:00 13:30 0.8k,ROP 22. PU to regain CTW,PUW 39k. ****Note:New mud to bit @ 9,291 ft 7/15/2016 7/15/2016 5.50 PROD1 DRILL WPRT P 9,303 ft,BHA wiper, BOBD 1.55 bpm 9,199.0 9,313.0 13:30 19:00 at 3,360 psi FS,BHP 3801,WHP 436, IA 141,OA 250 7/15/2016 7/15/2016 1.00 PROD1 DRILL WPRT T 9,313 ft,unable to keep weight on bit, 9,313.0 7,400.0 19:00 20:00 PUW 43 k,work pipe to bottom,and still having trouble keeping weight on bit,perform wiper up hole thru high gamma area,work pipe 40 k to 54 k, up to minus 4k DHWOB, 7/15/2016 7/15/2016 1.75 PROD1 DRILL WPRT T 8,570 ft,discussed with town the 7,400.0 7,400.0 20:00 21:45 trouble pulling up hole,decision was made to clean the hole from 8,570 ft to the window,pumping 5x5 sweep. perform jog before the EOB 7,590 ft, PUH thru build section,pump 5x5 sweep and perform 5 jogs in build section to clean hole, 7/15/2016 7/15/2016 2.00 PROD1 DRILL TRIP T 7,400 ft,POOH,pumping 1.54 bpm at 7,400.0 72.2 21:45 23:45 3,480 psi,following manage pressure. perform jog at 850 ft to 1150 ft. ***Note:Perform choke calibration In rate: 1.51 bpm Out rate: 1.51 Mud wt in:8.60 ppg Mud wt out:8.62 Annular:3749 Choke:500 WHP:511 7/15/2016 7/16/2016 0.25 PROD1 DRILL PULD T PJSM,for undeploying lateral BHA 72.2 23:45 00:00 7/16/2016 7/16/2016 1.50 PROD1 DRILL PULD T Undeploy drilling BHA#7 72.2 0.0 00:00 01:30 7/16/2016 7/16/2016 2.00 PROD1 DRILL PULD T PJSM,reconfigure BHA,PU/MU 0.0 73.6 01:30 03:30 BHA#8 Page 7/17 Report Printed: 7/28/2016 • • Operations Summary (with Timelog Depths) `=' ) 1 L-18 ConocoPhitlips Rig: NABORS CDR2-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) 7/16/2016 7/16/2016 2.00 PROD1 DRILL TRIP T RIH,with OH Anchored Billet BHA#8 73.6 7,025.0 03:30 05:30 7/16/2016 7/16/2016 0.25 PROD1 DRILL DLOG T 7,025 ft,Log the HRZ,correction of 7,025.0 7,077.0 05:30 05:45 +12.5 ft. 7/16/2016 7/16/2016 0.75 PROD1 DRILL TRIP T Close EDC,weight check,RIH. 7,077.0 8,400.0 05:45 06:30 7/16/2016 7/16/2016 0.50 PROD1 DRILL WPST T Wt check.Get on setting depth.PU to 8,400.0 8,451.8 06:30 07:00 neutral wt. Pumps on gradually increasing to set billet.Set down 3k WOB to confirm set. 7/16/2016 7/16/2016 2.00 PROD1 DRILL TRIP T POOH.Open EDC @ 7100'.Cont 8,451.8 82.0 07:00 09:00 POOH. 7/16/2016 7/16/2016 2.00 PROD1 DRILL PULD T Tag up,space out,PJSM,PUD BHA 82.0 0.0 09:00 11:00 #8.Lay down billet setting tool, reconfigure MWD,PU motor. SIMOPS:PDS personnel checked their connection to rig depth counter for real-time caliper 7/16/2016 7/16/2016 1.00 PROD1 DRILL PULD T PJSM,PD BHA#9(0.7°AKO+RR 0.0 72.0 11:00 12:00 HYC Duraforce Edge). 7/16/2016 7/16/2016 1.50 PROD1 DRILL TRIP T RIH BHA#9. 72.0 7,025.0 12:00 13:30 7/16/2016 7/16/2016 0.50 PROD1 DRILL DLOG T Tie-in to HRZ(+27 ft correction). 7,025.0 7,200.0 13:30 14:00 Close EDC.Log K1 marker to verify depth(no correction). 7/16/2016 7/16/2016 0.75 PROD1 DRILL TRIP T Cont RIH.Tag up @ 8237 ft,0.65 7,200.0 8,441.0 14:00 14:45 bpm.Dry tag @ 8441 ft.PU(PUW 37k),pumps up,work down to TOB. 7/16/2016 7/16/2016 1.25 PROD1 DRILL DRLG T Time milling billet @ 1.2 FPH,milled 8,441.0 8,444.0 14:45 16:00 off 8441.44 ft.Drilling off,up to 9 FPH, not much increase WOB. 7/16/2016 7/16/2016 0.25 PROD1 DRILL DRLG T Drilling ahead. 1.53 BPM @ 3340 psi 8,444.0 8,465.0 16:00 16:15 FS,WOB 1.6k,ROP 75, 7/16/2016 7/16/2016 0.50 PROD1 DRILL WPRT T 8,465 ft,PU above billet,dry drift 8,465.0 8,465.0 16:15 16:45 clean, RBIH to bottom. 7/16/2016 7/16/2016 5.75 PROD1 DRILL DRLG T 8,465 ft,BOBD 1.42 bpm at 3155 psi 8,465.0 8,719.0 16:45 22:30 FS,BHP 3842,WHP 382,IA 323,OA 246 7/16/2016 7/16/2016 0.50 PROD1 DRILL WPRT T 8,719 ft,stacking weight,perform 8,719.0 8,470.0 22:30 23:00 wiper up hole to bottom of billet at 8,470 ft 7/16/2016 7/16/2016 0.25 PROD1 DRILL WPRT T 8470 ft,wiper back in hole,RIW 9.5k 8,470.0 8,719.0 23:00 23:15 7/16/2016 7/17/2016 0.75 PROD1 DRILL DRLG T 8,719 ft,BOBD 1.57 bpm at 3510 psi 8,719.0 8,761.0 23:15 00:00 FS,BHP 3803,WHP 442, IA 324,OA 246,CTSW Ok,ROP 50 fph 7/17/2016 7/17/2016 1.75 PROD1 DRILL DRLG T 8,761 ft,OBD 1.55 bpm at 3,637 psi, 8,761.0 8,840.0 00:00 01:45 BHP 3822,WHP 351,IA 356,OA 251, CTSW-0k,DHWOB-1.8k,ROP 50 fph 7/17/2016 7/17/2016 0.50 PROD1 DRILL WPRT T 8,840 ft,wiper up hole PUW 36k 8,840.0 7,840.0 01:45 02:15 7/17/2016 7/17/2016 0.50 PROD1 DRILL WPRT T 7,840 ft,wiper back in hole,RIW 7,840.0 8,840.0 02:15 02:45 7/17/2016 7/17/2016 1.75 PROD1 'DRILL DRLG T 8,840 ft,BOBD 1.55 bpm at 3,550 psi, 8,840.0 8,925.0 02:45 04:30 BHP 3849,WHP 354,IA 371,OA 255 Page 8/17 Report Printed: 7/28/2016 Operations Summary (with Timelog Depths) 01 1L-18 i hp ,tf,rka Rig: NABORS CDR2-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(EKE) 7/17/2016 7/17/2016 3.25 PROD1 DRILL DRLG T 8,925 ft,OBD 1.52 bpm at 3,778 psi, 8,925.0 9,027.0 04:30 07:45 BHP 3,840,WHP 340,IA 371,OA 255,CTSW-0,DHWOB-2k,ROP-40 fph. GEO-target 100°+looking for A5 sand. 7/17/2016 7/17/2016 2.00 PROD1 DRILL DRLG T Drilling ahead,1.54 BPM @ 3735 psi, 9,027.0 9,100.0 07:45 09:45 WOB 1.2k,ROP 33. GEO-target 105°+cross cutting A5 sand. 7/17/2016 7/17/2016 0.25 PROD1 DRILL WPRT T 100'BHA wiper trip,CTSW 36k. 9,100.0 9,100.0 09:45 10:00 7/17/2016 7/17/2016 2.00 PROD1 DRILL DRLG T BOBD, 1.55 BPM @ 3670 psi,CTSW 9,100.0 9,148.0 10:00 12:00 9k,WOB 1k,ROP 20.Drilling parameters ok,continue to cross cut A6 to assist geological interpretation of area. 7/17/2016 7/17/2016 0.50 PROD1 DRILL WPRT T 100'BHA wiper trip.CTSW 39k. 9,148.0 9,148.0 12:00 12:30 7/17/2016 7/17/2016 1.25 PROD1 DRILL TRIP T BOBD,CTSW 6.5k,WOB 1.1k,ROP 9,148.0 9,184.0 12:30 13:45 20 7/17/2016 7/17/2016 1.75 PROD1 DRILL TRIP T POOH,CTSW 39k.Couple tight spots 9,184.0 7,600.0 13:45 15:30 with CTSW and bore pressure increases while PUH from 8970'to 8555'.Pump 5x5 and chase up from 8400'. 7/17/2016 7/17/2016 5.75 PROD1 DRILL TRIP T Pulled heavy(CTSW 48k)@ 7542'. 7,600.0 7,405.0 15:30 21:15 Build section from 7511'to 7542'in bad shape.Pulling heavy,packing off, stacking while trying to clean.Made 5+passes to clean... 7/17/2016 7/17/2016 0.25 PROD1 DRILL DLOG T 7405 ft,tie into the RA correction of 7,405.0 7,418.0 21:15 21:30 plus 4.0ft. 7/17/2016 7/17/2016 0.50 PROD1 DRILL WPRT T 7418 ft,RBIH thru build section clean, 7,418.0 8,410.0 21:30 22:00 pump 10x10 sweep,continue RIH, while circulating sweep down hole to 8,410 ft. 7/17/2016 7/17/2016 0.50 PROD1 DRILL WPRT T 8,410 ft,wiper up hole to window. 8,410.0 7,000.0 22:00 22:30 7/17/2016 7/18/2016 1.50 PROD1 DRILL TRIP T 7000 ft,POOH w/open EDC pumping 7,000.0 1,948.0 22:30 00:00 1.62 bpm at 3031 psi,performing jogs at 5,478 ft. 7/18/2016 7/18/2016 0.50 PROD1 DRILL TRIP T 1,948 ft,continue POOH,performing 1,948.0 72.2 00:00 00:30 jog at1,500 ft down to 2,182 ft. 7/18/2016 7/18/2016 1.25 PROD1 DRILL 'PULD T PJSM,undeploy drilling BHA#9 72.2 0.0 00:30 01:45 7/18/2016 7/18/2016 1.25 PROD1 STK PULD T PU/MU setting tools with open hole. 0.0 0.0 01:45 03:00 anchored billet. inspect choke,clean and inspect INJH chains and counter. 7/18/2016 7/18/2016 1.25 PROD1 STK PULD T Deploy billet#2 setting BHA#10, 0.0 74.0 03:00 04:15 inspect&change pac-off. 7/18/2016 7/18/2016 1.75 PROD1 STK TRIP T RIH with Open Hole Anchored billet. 74.0 7,025.0 04:15 06:00 7/18/2016 7/18/2016 0.25 PROD1 STK DLOG T 7025 ft,tie into the HRZ correction of 7,025.0 7,220.0 06:00 06:15 +25.5 ft.Close EDC.Wt check(CTSW 36k).Verify depth by logging K1 (zero correction). 7/18/2016 7/18/2016 0.75 PROD1 STK TRIP T RIH to setting depth.No issues 7,220.0 8,422.0 06:15 07:00 passing through build section. Page 9/17 Report Printed: 7/28/2016 II • =' Operations Summary (with Timelog Depths) 0 k�l 1L-18 ConocoPhil kps Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Tine Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 7/18/2016 7/18/2016 0.25 PROD1 STK WPST T PU to neutral weight.Set billet.TOB 8,422.0 8,422.0 07:00 07:15 @ 8410'.Verify billet set with 3.5k WOB. 7/18/2016 7/18/2016 2.25 PROD1 STK TRIP T POOH.Open EDC @ 7000'.POOH. 8,422.0 86.8 07:15 09:30 Tag up,space out,PJSM to PUD BHA #10. 7/18/2016 7/18/2016 2.25 PROD1 STK PULD T PUD BHA#10.Reconfigure BHA. 86.8 0.0 09:30 11:45 7/18/2016 7/18/2016 1.00 PROD1 STK PULD T PD BHA#11 (0.9°AKO motor+HYC 0.0 72.2 11:45 12:45 Duraforce Edge,same bit from BHA#9 graded 1-1). 7/18/2016 7/18/2016 1.50 PROD1 STK TRIP T RIH BHA#11. 72.2 7,015.0 12:45 14:15 • 7/18/2016 7/18/2016 0.50 PROD1 STK DLOG T Tie-in to HRZ(+33.5 ft correction). 7,015.0 7,068.0 14:15 14:45 Close EDC. 7/18/2016 7/18/2016 0.75 PROD1 STK TRIP T Wt check(CTSW 35k).RIH.Dry tag 7,068.0 8,410.7 14:45 15:30 billet @ 8410.7 ft. 7/18/2016 7/18/2016 4.00 PROD1 STK DRLG T PU,bring on pumps,RIH,and drill off 8,410.7 8,440.0 15:30 19:30 of billet 5,10,20 fph continue drilling to 8,440 ft,PUH to 8,394 ft,clean dry drift thru billet area.RBIH 7/18/2016 7/18/2016 3.50 PROD1 DRILL DRLG T 8,394 ft,Drill ahead from 8,440 ft to 8,440.0 8,710.0 19:30 23:00 8,710 ft,PUH fora BHA wiper,PUW 33 k 7/18/2016 7/19/2016 1.00 PROD1 DRILL DRLG T 8,710 ft,BOBD 1.5 bpm at 3,652 psi 8,710.0 8,767.0 23:00 00:00 FS,BHP 3,817,WHP 271, IA 360,OA 251 7/19/2016 7/19/2016 0.75 PROD1 DRILL DRLG T 8767 ft,OBD 1.4 bpm at 3866 psi, 8,767.0 8,840.0 00:00 00:45 BHP 3839,WHP 245, IA 360,OA 251 7/19/2016 7/19/2016 0.50 PROD1 DRILL WPRT T 8840 ft,wiper up hole increasing 8,840.0 7,840.0 00:45 01:15 pump rate 1.56 bpm 3600 psi,PUW 38 k. 7/19/2016 7/19/2016 0.50'PROD1 DRILL WPRT T 7840 ft,wiper back in hole,RIW 9 k 7,840.0 8,840.0 01:15 01:45 7/19/2016 7/19/2016 1.50 PROD1 DRILL DRLG T 8840 ft,BOBD 1.5 bpm at 3,629 psi, 8,840.0 8,967.0 01:45 03:15 BHP 3891,WHP 326,IA 361,OA 251 7/19/2016 7/19/2016 0.25 PROD1 DRILL WPRT T Short wiper,CTSW 38k. 8,967.0 8,967.0 03:15 03:30 7/19/2016 7/19/2016 1.50 PROD1 DRILL DRLG T BOBD, 1.4 BPM @ 3645 psi,CTSW- 8,967.0 9,040.0 03:30 05:00 2k,WOB 2.6k,ROP 46. 7/19/2016 7/19/2016 0.25 PROD1 DRILL WPRT T Short wiper,CTSW 36k. 9,040.0 9,040.0 05:00 05:15 7/19/2016 7/19/2016 1.25 PROD1 DRILL DRLG T BOBD. 1.42 BPM @ 3735 psi,CTSW 9,040.0 9,081.0 05:15 06:30 0.2k,WOB 2.1k,ROP 34.Trying to keep 2k+WOB to achieve planned 15°doglegs.Begin taking returns to TT for mud swap to system#3. 7/19/2016 7/19/2016 0.50 PROD1 DRILL WPRT T 300'short wiper,CTSW 40k. 9,081.0 9,081.0 06:30 07:00 7/19/2016 7/19/2016 0.75 PROD1 DRILL DRLG T BOBD. 1.4 BPM @ 3715 psi. 9,081.0 9,129.0 07:00 07:45 7/19/2016 7/19/2016 0.25 PROD1 DRILL WPRT T 100'Short wiper,CTSW 36k. 9,129.0 9,129.0 07:45 08:00 7/19/2016 7/19/2016 2.25 PROD1 DRILL DRLG T BOBD. 9,129.0 9,240.0 08:00 10:15 New mud system#3(added 1%Lo- torq)to bit @ 9178 ft. Page 10/17 Report Printed: 7/28/2016 • • #" Operations Summary (with Timelog Depths) 1L-18 Conor hill ps Rig: NABORS CDR2-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) .7/19/2016 7/19/2016 1.00 PROD1 DRILL WPRT T Wiper to 8,500', PUW=37K,RBIH. 9,240.0 9,240.0 10:15 11:15 7/19/2016 7/19/2016 1.30 PROD1 DRILL DRLG T BOBD: 1.52 BPM @ 3,880 PSI, 9,240.0 9,313.0 11:15 12:33 BHP=3,880 PSI,CTW=9K, WOB=1.8K,ROP=70. 7/19/2016 7/19/2016 3.25 PROD1 DRILL DRLG P BOBD: 1.53 BPM @ 3,920 PSI, 9,313.0 9,590.0 12:33 15:48 BHP=3,910 PSI,CTW=8.5K, WOB=1.5K,ROP=75. Increase KCL and KlaStop to mud system.Per town, POOH for agitator&low bend motor. 7/19/2016 7/19/2016 1.20 PROD1 DRILL TRIP P POOH for agitator.PUW=36KIbs. 9,590.0 7,524.0 15:48 17:00 7/19/2016 7/19/2016 4.50 PROD1 DRILL TRIP P Pulling heavy at 7524 ft.Work BHA to 7,524.0 7,409.0 17:00 21:30 try and pull though tight hole. Occasional packing off. Pump 5x5 bsweep to clear cuttings.No increase in cuttings observed with sweep at surface.Continue to work BHA.Roll to as drilled toolface. Jog down to 8,000 ft.PUH past problem area to 7409 ft.RBIH to 8000 ft,PUH to confirm hole is clean.Slight bobble,but otherwise clean. 7/19/2016 7/19/2016 2.00 PROD1 DRILL TRIP P Continue POOH with BHA#11.Bump 7,409.0 74.0 21:30 23:30 up and space out. 7/19/2016 7/20/2016 0.50 PROD1 DRILL PULD P PUD BHA#11. 74.0 74.0 23:30 00:00 7/20/2016 7/20/2016 1.00 PROD1 DRILL PULD P Continue to PUD and LD BHA#11. 74.0 0.0 00:00 01:00 7/20/2016 7/20/2016 2.00 PROD1 DRILL PULD P MU lateral drilling BHA#12 with 0.0 78.0 01:00 03:00 Agitator,0.4+°AKO motor and RB HYC bit.PD BHA#12. 7/20/2016 7/20/2016 2.75 PROD1 DRILL TRIP P Bump up,reset counters.RIH with, 78.0 9,593.0 03:00 05:45 BHA#12.Shallow test agitator BHA. Good test.Continue running in the hole.Tie in to the HRZ for a plus 11 ft correction,weight check 34K,continue in hole,RIH weight 9K. 7/20/2016 7/20/2016 8.50 PROD1 DRILL DRLG P BOBD:Trouble getting started drilling. 9,593.0 9,890.0 05:45 14:15 Drill ahead 1.46 BPM @ 3,910 PSI, BHP=3,940 PSI,CTW=8K,WOB=1K, ROP=40-50.Only have push for 20-30 minutes,before mini wiper needed, several 100-300 wipers needed to regain weight transfer.Add additional 1/2%lubes to active system. 7/20/2016 7/20/2016 0.90 PROD1 DRILL WPRT P Early wiper to 9,125',PUW=42K, 9,890.0 9,890.0 14:15 15:09 RBIH. 7/20/2016 7/20/2016 1.35 PROD1 DRILL DRLG P BOBD: 1.45 BPM @ 4,145 PSI, 9,890.0 9,938.0 15:09 16:30 BHP=3,915 PSI,CTW=6K,WOB=1, ROP=60.Minimal improvement after wiper,start batching up 50 bbl beaded pill!.Stacking weight.Multiple restarts. Page 11/17 Report Printed: 7/28/2016 0 Operations Summary (with TimelogDepths) foill1 1L-18 Coor hiitllps n Rig: NABORS CDR2-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) 7/20/2016 7/20/2016 1.50 PROD1 DRILL DRLG P Pump 15 bbl beaded pill(at 1 ppb) 9,938.0 9,965.0 16:30 18:00 followed by 30 bbls mud. Continue drilling ahead.1.45 BPM @ 4,100 PSI, BHP=3,930 PSI,CTW=-3 to+8 K, WOB=0.8,ROP=15-40 fph. • Continuing to stack weight. 7/20/2016 7/20/2016 3.00 PROD1 DRILL DRLG P PU and restart.PUW=48 Klbs. 9,965.0 10,139.0 18:00 21:00 Continue drilling ahead. 1.40 BPM @ 4,010 PSI,BHP=3,940 PSI,CTW=3- 6K,WOB=1.2,ROP=50-80 fph.Begin stacking weight again. 7/20/2016 7/20/2016 2.25 PROD1 DRILL WPRT P Start wiper trip to the tubing tail to 10,139.0 7,057.0 21:00 23:15 clean up build section.No issues pulling up through the open hole. Jog down at 7600 ft.PUH through build and into the tubing tail. 7/20/2016 7/20/2016 0.50 PROD1 DRILL CIRC P Open EDC.Increase pump rate to 1.8 7,057.0 6,995.0 23:15 23:45 BPM to flush tubing.No increase in cuttings over the shakers at BU. 7/20/2016 7/21/2016 0.25 PROD1 DRILL WPRT P Close EDC. RBIH.Stack weight at the 6,995.0 7,395.0 23:45 00:00 window.Roll TF from HS to 10° ROHS.Clean pass through window. 7/21/2016 7/21/2016 0.25 PROD1 DRILL WPRT P Continue to RIH. 7,395.0 7,410.0 00:00 00:15 7/21/2016 7/21/2016 0.25 PROD1 DRILL DLOG P Tie in to RA for a+5.5 ft correction. 7,410.0 7,427.0 00:15 00:30 7/21/2016 7/21/2016 1.00 PROD1 DRILL WPRT P Continue into open hole.Stacked 7,427.0 10,139.0 00:30 01:30 weight at 7505 ft,7550 ft,8890 ft. Stacked weight again at 9,100 ft.Had to slow pump rate to get past this section.Continue in the hole to bottom. 7/21/2016 7/21/2016 2.85 PROD1 DRILL DRLG P BOBD. 1.45 BPM at 4167 PSI.CTW= 10,139.0 10,340.0 01:30 04:21 2.3 Klbs,WOB=1.7 Klbs.ROP=90 FPH. 7/21/2016 7/21/2016 0.95 PROD1 DRILL WPRT P Wiper trip to 9,500',PUW=40K,RBIH. 10,340.0 10,340.0 04:21 05:18 7/21/2016 7/21/2016 6.25 PROD1 DRILL DRLG P BOBD.1.43 BPM at 3995 PSI.CTW= 10,340.0 10,540.0 05:18 11:33 4 Klbs,WOB=1.2 Klbs.ROP=50 FPH.BHA wiper @ 10441'.Start losing WT,pump 15 bbl beaded pill, waiting on beads,PUW=50K,minimal impact from beads,start pumping new mud system,mud at bit 10,475'.Able to maintain ROP of 55. 7/21/2016 7/21/2016 1.20 PROD1 DRILL WPRT P Wiper to 9,500',PUW=42K.RBIH was 10,540.0 10,540.0 11:33 12:45 10,060',continue in hole. 7/21/2016 7/21/2016 5.75 PROD1 DRILL DRLG P BOBD. 1.43 BPM at 4075 PSI.CTW= 10,540.0 10,740.0 12:45 18:30 3 Klbs,WOB=1 Klbs.ROP=40. 7/21/2016 7/21/2016 2.00 PROD1 DRILL WPRT P . Start PUH for tie in wiper trip.PUW= 10,740.0 7,410.0 18:30 20:30 45Klbs. Pull into tight hole at 8990 ft.PUW 52 Klbs.Work pipe to get free. Poor hole conditions in the build section.Jog down from 7,450 ft to 7650 ft. 7/21/2016 7/21/2016 2.00 PROD1 DRILL WPRT P RBIH.Tie in to RA for a+7 ft 7,410.0 10,740.0 20:30 22:30 correction.Continue in the hole.Stack weight at 7550 ft,7555 ft,7635 ft,and 10,065 ft. Page 12/17 Report Printed: 7/28/2016 • r, • •rations Summary (with Timelog Depths) 0►s4 1 L-18 conocc chimps Rig: NABORS CDR2-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(EKE) 7/21/2016 7/22/2016 1.50 PROD1 DRILL DRLG P BOBD. 1.45 BPM at 4060 psi.CTW= 10,740.0 10,790.0 22:30 00:00 -1.8 Klbs,WOB=1 Klbs.ROP=20- 40. Stack weight at 10787 ft.PU and restart.PUW 52Klbs. 7/22/2016 7/22/2016 1.50 PROD1 DRILL DRLG P Continue drilling ahead. 1.45 BPM at 10,790.0 10,842.0 00:00 01:30 4060 psi.CTW=-1.8 Klbs,WOB=1 Klbs.ROP=20-40. Stack weight at 10842 ft.PU and restart.PUW 53KIbs. 7/22/2016 7/22/2016 2.00 PROD1 DRILL DRLG P Continue drilling ahead.Start pumping 10,842.0 10,861.0 01:30 03:30 15 bbl beaded pills(1 ppb Alpine Beads) followed by 30 bbls of mud. Little to no improvement in weight transfer.Still stacking weight. 7/22/2016 7/22/2016 0.50 PROD1 DRILL WPRT P Start early wiper trip.PUW=48 Klbs. 10,861.0 10,100.0 03:30 04:00 PUH to 10,100 ft. 7/22/2016 7/22/2016 0.50 PROD1 DRILL WPRT P RBIH.RIW=7-9 Klbs. 10,100.0 10,861.0 04:00 04:30 7/22/2016 7/22/2016 3.25 PROD1 DRILL DRLG P Continue drilling ahead.1.42 BPM at 10,861.0 10,950.0 04:30 07:45 4161 psi.CTW=1.0 Klbs,WOB=1.4 Klbs.ROP=90.BHA wiper @ 10,912',200'wiper @ 10,992',and BHA wiper @ 10,946'to regain WT. Town called TD @ 10,950'.Pump 10 x 10 to/hi vis sweeps. 7/22/2016 7/22/2016 1.75 PROD1 DRILL WPRT P Chase sweeps to swab,jog @ 7;60.0' 10,950.0 80.0 07:45 09:30 to 8,000',continue OOH,hole clean. 7/22/2016 7/22/2016 4.75 PROD1 DRILL TRIP P Tag up,reset counters.RBIH for 80.0 10,955.0 09:30 14:15 corrected TD,tie-in at HRZ for+11.5' correction,PUW=34K,continue in hole,saw 7,555',9,137',and 10,262'. Tag corrected TD @ 10,955'. 7/22/2016 7/22/2016 3.75 PROD1 DRILL CIRC P POOH laying in beaded liner 10,955.0 80.0 14:15 18:00 pill/completion fluid,paint EOP flags @ 8,700'&5,100',continue OOH. 7/22/2016 7/22/2016 0.50 PROD1 DRILL OWFF P 30 minute flow check.Static. 80.0 80.0 18:00 18:30 7/22/2016 7/22/2016 1.00 PROD1 DRILL PULD P LD agitator BHA#12.BHA in good 80.0 0.0 18:30 19:30 condition. Bit graded 1-1-TD. 7/22/2016 7/22/2016 0.50 COMPZ1 CASING PULD P PJSM.Prepare to run liner.Stage 0.0 3.0 19:30 20:00 safety joint on rig floor. PU liner running tools. 7/22/2016 7/22/2016 3.00 COMPZ1 CASING PUTB P Plck up first liner segment.Non ported 3.0 2,187.0 20:00 23:00bull nose,54 joints 2-3/8"slotted liner and shorty deployment sleeve.MU Coiltrak tools.Stab on injector.Bump up and set depth. 7/22/2016 7/23/2016 1.00 COMPZ1 CASING RUNL P Begin RIH with first segment of liner to 2,187.0 5,838.0 23:00 00:00 midnight depth of 5838 ft. Page 13117 Report Printed: 7/28/2016 a. 'Ill10 tz Operations Summary (with Timelog Depths) 0 1L-18 conocc 'hitlips krks Rig: NABORS CDR2-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) 7/23/2016 7/23/2016 3.00 COMPZ1 CASING RUNL P Continue running in the hole with the 5,838.0 10,951.0 00:00 03:00 first segment of liner,NP bull nose,54 joints 2-3/8"SLT Slotted Liner,and shorty deployment sleeve. Poor hole conditions at 8215 ft. Reciprocate liner working through tight hole to 9700 ft. Continue RIH with liner,SOW=5-7 Klbs. +3ft correction at the flag.Liner set down at 10951 ft.PUH and retag bottom 3 times at the same depth.Will tie in on the way out of the hole to confirm liner top depth. Bring up pumps and release liner with 3800 psi.PUH and confirm free. 7/23/2016 7/23/2016 2.50 COMPZ1 CASING TRIP P POOH with liner running tools.Paint 10,951.0 55.5 03:00 05:30 EOP flags at 6300 and 7700 ft. Relog HRZ to confirm liner top depth of 8813 ft. Continue out of the hole. 7/23/2016 7/23/2016 0.50 COMPZ1 CASING OWFF P Monitor well for flow,no flow. 55.5 55.5 05:30 06:00 7/23/2016 7/23/2016 1.00 COMPZI CASING PULD P PJSM.LD BHA#13 55.5 0.0 06:00 07:00 7/23/2016 7/23/2016 3.00 COMPZ1 CASING PUTB P PJSM.PU/MU upper assembly,BN, 0.0 957.2 07:00 10:00 23 jts slotted,shorty deployment sleeve.MU BHA#14. 7/23/2016 7/23/2016 2.25 COMPZ1 CASING RUNL P RIH w/liner assembly,tie-in EOP flag 957.2 8,812.0 10:00 12:15 for+8.5'correction,continue in hole to set depth,tag @ 8,812',PUW=40K, RBIH,stack 3K down,release from liner,TOL @ 7,900',PUW=34K.PUH, reset depth. 7/23/2016 7/23/2016 1.75 COMPZ1 CASING TRIP P POOH for OH anchored billet,tie-in to 8,812.0 57.5 12:15 14:00 HRZ to confirm top of liner depth,+1' correction.POOH. 7/23/2016 7/23/2016 0.50 COMPZI CASING OWFF P Monitor well for flow,no flow. 57.5 57.5 14:00 14:30 7/23/2016 7/23/2016 0.75 COMPZ1 CASING PULD P PJSM.LD BHA#14 57.5 0.0 14:30 15:15 7/23/2016 7/23/2016 1.00 PROD2 STK PUTB P PJSM.PU/MU OH anchor billet 0.0 113.4 15:15 16:15 assembl:BN,one jts slotted liner,OH anchored billet.MU BHA#15. 7/23/2016 7/23/2016 2.25 PROD2 STK RUNL P RIH w/OH anchored billet assembly, 113.4 7,898.0 16:15 18:30 tie-in to the HRZ for a+8.5 ft correction.Close EDC,weight check, PUW=36 Klbs.RIH to set depth,tag top of liner at 7898 ft.Bring up pumps, set anchors with 4200 psi.Single slip oriented 30°LOHS. 7/23/2016 7/23/2016 1.50 PROD2 STK TRIP P POOH with running tools. 7,898.0 61.0 18:30 20:00 7/23/2016 7/23/2016 0.50 PROD2 STK OWFF P Flow check well at surface.Static 61.0 61.0 20:00 20:30 7/23/2016 7/23/2016 1.00 PROD2 STK PULD P Lay down BHA#15.Remove UQC 61.0 0.0 20:30 21:30 checks. 7/23/2016 7/24/2016 2.50 PROD2 WHDBOP BOPE P RU and start bi-weekly BOP test. 0.0 0.0 21:30 00:00 Witness waived by Chuck Shieve. Test BOPE per checklist and procedures. Page 14/17 Report Printed: 7/28/2016 t' • •• 0 Operations Summary (with Timelog Depths) 1 L-18 k .. ConocoPhiiiipss Rig: NABORS CDR2-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) 7/24/2016 7/24/2016 6.25 PROD2 WHDBOP BOPE P Continue bi-weekly testing of BOPE 0.0 0.0 00:00 06:15 per procedure.BOPE test complete, no failures. 7/24/2016 7/24/2016 2.00 PROD2 WHDBOP SVRG P Grease stack and choke manifold. 0.0 0.0 06:15 08:15 Maintenance on injector&top drive. 7/24/2016 7/24/2016 4.75 PROD2 STK CTOP P Cut 18'coil,removing two flats spots, 0.0 0.0 08:15 13:00 test E-Line.Stall coil connector,pull test to 35K,install UQC,test line. Pressure test 4,200 psi.MU nozzle, swap reel back to KWF. 7/24/2016 7/24/2016 1.40 PROD2 STK PULD P PJSM. MU BHA#16,check pack-offs, 0.0 72.5 13:00 14:24 surface test. , 7/24/2016 7/24/2016 4.10 PROD2 STK TRIP P RIH w/drilling assembly:0.7 AKO 72.5 7,846.0 14:24 18:30 motor&RB HCC bit,tie-in for+9' correction,continue in hole.Weight check,35 Klbs.Finish rolling hole to FloPro drilling fluid.Dry tag billet at 7846 ft. 7/24/2016 7/24/2016 3.50 PROD2 STK KOST P Begin time drilling off of billet per 7,846.0 7,881.0 18:30 22:00 procedure.PU and restart at 7848 ft after losing pump pressure.Drill off billet and rathole to 7881 ft.Dry drift clean. 7/24/2016 7/25/2016 2.00 PROD2 DRILL DRLG P Continue drilling ahead,pumping 1.6 7,881.0 8,036.0 22:00 00:00 bpm at 4160 psi.CTW=11.5 Klbs, WOB=1.8 Klbs, BHP=4000 psi,FS =410 psi. 7/25/2016 7/25/2016 1.25 PROD2 DRILL DRLG P Continue drilling ahead,pumping 1.6 8,036.0 8,165.0 00:00 01:15 bpm at 4200 psi.CTW=10.5 Klbs, WOB=1.8 Klbs,BHP=3820 psi, 7/25/2016 7/25/2016 0.75 PROD2 DRILL DRLG T PUH and troubleshoot survey.Survey 8,165.0 8,165.0 01:15 02:00 out of spec due to magnetic interference.Survey cleaned up over time.RBIH. 7/25/2016 7/25/2016 1.25 PROD2 DRILL DRLG P Continue drilling ahead,pumping 1.5 8,165.0 8,240.0 02:00 03:15 bpm at 4105 psi.CTW=10.5 Klbs, WOB=1.8 Klbs,BHP=3800 psi, 7/25/2016 7/25/2016 1.85 PROD2 'DRILL WPRT P Pull wiper trip. Tight hole at 7605 ft. 8,240.0 8,240.0 03:15 05:06 Continuing to work tight hole on wiper trip,steady cuttings returns across shaker,RBIH. 7/25/2016 7/25/2016 4.35 PROD2 DRILL DRLG P Continue drilling ahead,pumping 1.6 8,240.0 8,540.0 05:06 09:27 bpm at 4070 psi.CTW=10.9 Klbs, WOB=1.7 Klbs,BHP=3825 psi, ROP=100.Continue to battle magnetic interference,call Sperry to correct surveys,got OK from town to continue drilling. 7/25/2016 7/25/2016 2.00 PROD2 DRILL WPRT T Wiper to 7,620',PUW=36K,RBIH. 8,540.0 8,540.0 09:27 11:27 Town questioning surveys.PUH,re- survey,send surveys to town.High magnetic interference.. 7/25/2016 7/25/2016 3.35 PROD2 DRILL DRLG P Continue drilling ahead,pumping 1.58 8,540.0 8,840.0 11:27 14:48 bpm at 4075 psi.CTW=10.2 Klbs, WOB=1.6 Klbs,BHP=3830 psi, ROP=95. 7/25/2016 7/25/2016 1.50 PROD2 DRILL WPRT P Wiper for tie-in, PUW=35K,make jog 8,840.0 8,840.0 14:48 16:18 before FOB,tight spot @ 7,607',make 200'jog,no issue.Tie-in for+6.5' correction.RBIH,clean. Page 15/17 Report Printed: 7/28/2016 • • Of 1111111 Operations Summary (with Timelog Depths) ex 1 L-18 Cs naocoPhillips Rig: NABORS CDR2-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) 7/25/2016 7/25/2016 3.70 PROD2 DRILL DRLG P Continue drilling ahead,pumping 1.62 8,840.0 9,130.0 16:18 20:00 bpm at 4,005 psi.CTW=10 Klbs,WOB =1.5 Klbs,BHP=3,920 psi,ROP=90. 7/25/2016 7/25/2016 0.75 PROD2 DRILL TRIP T PUH to resurvey. Decrease survey 9,130.0 9,130.0 20:00 20:45 stations from 45 ft to 30 ft.PUW=33 Klbs. 7/25/2016 7/25/2016 0.25 PROD2 DRILL DRLG P BOBD.Pumping 1.66 bpm at 4,020 9,130.0 9,140.0 20:45 21:00 psi.CTW=4.9 Klbs,WOB=1.5 Klbs, BHP=3,920 psi,ROP=75. 7/25/2016 7/25/2016 0.50 PROD2 DRILL WPRT P PUH for planned wiper trip.PUW=33 9,140.0 7,940.0 21:00 21:30 Klbs. 7/25/2016 7/25/2016 0.50 PROD2 DRILL WPRT P RBIH.Clean trip.SOW= 12 Klbs. 7,940.0 9,140.0 21:30 22:00 7/25/2016 7/26/2016 2.00 PROD2 DRILL DRLG P BOBD.Pumping 1.7 bpm at 4,070 psi. 9,140.0 9,325.0 22:00 00:00 CTW=7.5 Klbs,WOB=1.8 Klbs,BHP =3,835 psi,ROP=80-100 fph. ***New mud at the bit at 9176 ft. 7/26/2016 7/26/2016 1.00 PROD2 DRILL DRLG P Drilling ahead.Pumping 1.7 bpm at 9,325.0 9,392.0 00:00 01:00 4,120 psi.CTW=5 Klbs decreasing to negative weight,WOB=1.5 Klbs, BHP=3,830 psi, ROP=100 fph decreasing to 20 fph.. 7/26/2016 7/26/2016 0.13 PROD2 'DRILL WPRT P PUH for short wiper to help improve 9,392.0 9,290.0 01:00 01:07 weight transfer.80 7/26/2016 7/26/2016 0.13 PROD2 DRILL WPRT P RBIH.Clean trip.SOW=9.5 Klbs. 9,290.0 9,392.0 01:07 01:15 7/26/2016 7/26/2016 0.75 PROD2 DRILL DRLG P BOBD.Pumping 1.7 bpm at 4,057 psi. 9,392.0 9,440.0 01:15 02:00 CTW=8.4 Klbs,WOB=1.2 Klbs,BHP =3,895 psi,ROP=35. 7/26/2016 7/26/2016 2.00 PROD2 DRILL WPRT P PUH for long wiper trip.PUW=37Klbs. 9,440.0 7,118.0 02:00 04:00 Tight hole at 8240 ft and 7505 ft.Pull into tubing tail for mud friction factor measurement. 7/26/2016 7/26/2016 0.25 PROD2 DRILL CIRC P Circulate at 1.5 bpm holding 3700 psi 7,118.0 7,118.0 04:00 04:15 annular pressure. Rate out=1.49 BPM Density in=8.63 PPG Density out=8.68 PPG WHP=520 PSI 7/26/2016 7/26/2016 0.75 PROD2 DRILL WPRT P RBIH.Tie-in RA tag for+3.5' 7,118.0 9,440.0 04:15 05:00 correction,continue in hole,no issues. 7/26/2016 7/26/2016 1.75 PROD2 DRILL DRLG P BOBD.Pumping 1.7 bpm at 4,080 psi. 9,440.0 9,505.0 05:00 06:45 CTW=6 Klbs,WOB=1.4 Klbs,BHP= 3,895 psi,ROP=60.PU GEO wiper, off target,wait on town.Town called TD.Pump 10 x 10 to/hi vis sweeps. 7/26/2016 7/26/2016 2.50 PROD2 DRILL WPRT P Chase sweep to swab max rate,jog @ 9,505.0 72.0 06:45 09:15 7,750',continue long wiper trip.Tag up,reset counters. 7/26/2016 7/26/2016 2.50-PROD2 DRILL TRIP P RBIH to lay in completion fluid,log 72.0 9,340.0 09:15 11:45 HRZ for+15'correction,PUW=32K, continue in hole.Saw 7,505'&8,256'. 7/26/2016 7/26/2016 3.25 PROD2 DRILL CIRC P POOH laying in beaded liner 9,340.0 72.0 11:45 15:00 pill/completion fluid,paint EOP flags @ 7,000'&5,100'.POOH. 7/26/2016 7/26/2016 0.50 PROD2 DRILL OWFF P Monitor well for flow,no flow. 72.0 72.0 15:00 15:30 Page 16/17 Report Printed: 7/28/2016 • • . ' Operations Summary (with Timelog Depths) 0 1 L-18 ConacdPhiilips Rig: NABORS CDR2-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) 7/26/2016 7/26/2016 1.00 PROD2 DRILL PULD P PJSM.LD BHA#16 72.0 0.0 15:30 16:30 7/26/2016 7/26/2016 0.50 COMPZ2 CASING PUTB P Prep rig floor for liner run. 0.0 0.0 16:30 17:00 7/26/2016 7/26/2016 3.00 COMPZ2 CASING PUTB P PJSM.MU AL1 liner assembly:BN,68 0.0 2,180.4 17:00 20:00 jts slotted,shorty deployment sleeve. 7/26/2016 7/26/2016 0.90 COMPZ2 CASING PULD P PJSM-MU BHA#17 to AL1 liner 2,180.4 2,224.6 20:00 20:54 assembly,MU to CoilTrak,surface test. 7/26/2016 7/26/2016 2.00 COMPZ2 CASING RUNL P RIH with BHA#17,tie in at flag for 2,224.6 8,730.0 20:54 22:54 plus 5 ft correction,PUW 44k, continue RIH,Stack at 7,535 ft,PU 40k,continue RIH. 7/26/2016 7/27/2016 1.10 COMPZ2 CASING RUNL P 8,730 ft.Stacking,reciprocate liner 8,730.0 9,335.0 22:54 00:00 working through tight hole to 9,335 ft. 7/27/2016 7/27/2016 0.15 COMPZ2 CASING RUNL P At depth,PUW 47k,RBIH to 9,335 ft, 9,335.0 7,155.0 00:00 00:09 release off liner,PUW 30k,reset counters. 7/27/2016 7/27/2016 0.20 COMPZ2 CASING DLOG P PUH to 7,020 ft,log HRZ for plus 5.5 ft 7,155.0 7,160.0 00:09 00:21 correction,bottom of liner at 9,340 ft, top of liner at 7,160 ft corrected. 7/27/2016 7/27/2016 0.75 COMPZ2 CASING DISP P Displace out KWF to seawater.PJSM- 7,160.0 7,130.0 00:21 01:06 MIRU LRS. 7/27/2016 7/27/2016 1.00 COMPZ2 CASING DISP P POOH while pumping seawater.LRS 7,130.0 2,500.0 01:06 02:06 PT Lines and equipment,pump 30 bbl diesel,RDMO LRS. 7/27/2016 7/27/2016 1.15 DEMOB WHDBOP FRZP P Pump freeze protect from 2,500'to 2,500.0 44.2 02:06 03:15 surface.POOH 7/27/2016 7/27/2016 2.50 DEMOB WHDBOP PULD P PJSM-PUD BHA#17,LD liner 44.2 0.0 03:15 05:45 running tools,pull checks.Displace coil,flush lines. 7/27/2016 7/27/2016 1.50 DEMOB WHDBOP MPSP P Bring in BPV equipment,PJSM, RU 0.0 0.0 05:45 07:15 BPV equipment,lubricate in BPV,test from below,RD,off load BPV equipment. 7/27/2016 7/27/2016 4.25 DEMOB WHDBOP RURD P Blow down surface line.Complete RD 0.0 0.0 07:15 11:30 checklist.Off load pits. 7/27/2016 7/27/2016 0.50 DEMOB WHDBOP NUND P ND BOP stack,load tree with 0.0 0.0 11:30 12:00 methanol,check tree bolts torque, found 5 to be less than tight,30 minutes to tighten. Rig released:@ 12.00 on 07/27/16 Page 17117 Report Printed: 7/28/2016 • • • ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 1L Pad 1L-18A 50-029-22145-01 Baker Hughes INTEQ BAKER Definitive Survey Report HUGHES • 01 August,2016 • • ConocoPhillipssurveyct BAKERHUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Coordinate Reference: Well 1L-18 Project Kuparuk River Unit TVD Reference: 1L-18 @ 130.00usft(1L-18) Site: Kuparuk 1L Pad MD Reference: 1L-18)l 130.00usft(1 L-18) Well: 1L-18 North Reference: True Wellbore: 1L-18A Survey Calculation Method: Minimum Curvature Design: 1L-18A Database: EDM Alaska NSK Sandbox 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 Well 1L18 Well Position +N/-S 0.00 usft Northing: 5,948,461.17usft Latitude: 70`16'12.472 N +E/-W 0.00 usft Easting: 539,924.15 usft Longitude: 149°40'37.662 W j Position Uncertainty 000 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1 Li-)BA z Magnetic; , 141,77A741..1.1..,1,:,,,, Declination Dip Angle Field Strength ) BGGM2015 7/1/2016 18.40 80.93 57,492 I Design 1L-18A .. • ':Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 8,401.01 VerticalSectiotl: . Depth From(TVD) +Nl-5 +El-W Direction (usft) (usft) (usft) r) 130.00 0.00 0.00 300.00 Survey Program Date 7/22/2016 From To Survey Survey (usft). (usft) Survey(Wellbore) .:Tool Name Description Start Date End Date . 200.00 7,300.00 1L-18(1L-18) GCT-MS Schlumberger GCT multishot 1/8/2001 1 8 7,386.00 8,401.01 1L-18APB1(1L-18APB1) MWD MWD-Standard 7/8/2016 7/15/2016 8,410.00 10,916.94 1L-18A(1L-18A) MWD MWD-Standard 7/18/2016 7/22/2016 V50016:2:87 11Siiiiid. • . C°notNob illi ps Mil ConocoPhillips zerrellvesuiveyiktpcot HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 1L-18 Project: Kuparuk River Unit TVD Reference: 1L-18 130.00usft(1L-18) Site: Kuparuk 1L Pad MD Reference: 1L-18 1130.00usft(1L-18) Well: 1L-18 North Reference: True Wellbore: 1L-18A Survey Calculation Method: Minimum Curvature Design: 1 L-18A Database: EDM Alaska NOK Sandbox t, Survey Map MaP MD Inc Aol TVD NDSS +Nf-S +8.,/-W Vertical NI:ANN basting DLg Seat on Survey Tool Name Annotati0p (usft) (°) f°) (usft) (usft) (usft) (usft) Itt (ft) (°/100-1) (ft) 8,401 01 88.56 225.20 6,107.84 5,97784 438797 1,121 44 5,944,079.64 541,068 74 1516 -3165.19 MWD(2) TIP 6,410.00 88.41 226.45 6,108.08 5,978 08 -4,394.24 1,115.00 5,944,073.34 541,062.33 14.00 -3,16274 MWD(3) KOP S 8,440.53 84.68 226.71 6,109.92 5,979.92 -4,41518 1,092.87 5,944,052.28 541,040.31 1225 -3,154.04 MWD(3) 8,470.60 81.03 228.14 6,113.66 5,983.66 -4,43536 1,070.90 5,944,031.99 541,018.46 13.02 -3,145.11 MWD(3) I 8,488.18 79.10 228.94 6,116.69 5,986.69 -4,446.83 1,057.93 5,944,020.45 541,005.54 11.86 -3,139.60 MWD(3) 8,51526 81.59 230.78 6,121.23 5,991.23 -4,464.03 1,037.52 5,944,003.14 540,98523 11.38 -3,130.53 MWD(3) 8,54536 85.18 231.65 6,124.70 5,994.70 -4,482.76 1,014.22 5,943,98A 29 540,962.03 1227 -3,119.72 MWD(3) 8,575.48 88.62 231.64 6,126.33 5,996.33 -4,501.42 990.63 5,943,96551 540,938.55 11.42 -3,108.62 MWD(31 8,60550 89.72 235.48 6,126.76 5,996.76 4,519.24 966.49 5,943,947.56 540,914.50 13.30 -3,096.63 MWD(3) 8,635.94 89.17 238.92 6,127.06 5,997.06 4,535.73 940.91 5,943,930.94 540,889.01 11.44 -3,08272 MWD(31 8,665.64 88.71 243.72 6,127.61 5,997.61 4,549.98 914.87 5,943,916.55 540,863.05 16.23 -3,067.29 MWD(3) 8,69577 89.57 247.91 6,128.06 5,998.06 -4,562.32 887.39 5,943,904.07 540,835.64 14.19 -3,049.66 MWD(3) il 8,725.84 88.90 251.69 6,128.46 5,998.46 -4,572.70 859.18 5,943,893.54 540,807.48 1277 -3,030.42 MWD(3) F 8,755.74 89.60 255.09 6,128.85 5,998.85 4,58124 830.53 5,943,884.85 540,778.89 11.61 -3,009.88 MWD(3) 8,785.39 88.77 258.31 6,129.27 5,999.27 -4,588.06 801.68 5,943,877.87 540,750.08 11.21 -2988.31 MWD(3) 8,820.54 90.46 261.59 6,129.51 5,999.51 4,594.19 767.08 5,943,871.56 540,715.51 10.50 -2,96141 MWD(3) 8,849.96 91.53 265.62 6,129.00 5,999.00 -4,597.47 737.85 5,943,868.13 540,686.31 14.17 -2,937.74 MWD(3) 8,880.17 93.01 269.38 6,127.80 5,997.80 4,598.79 707.70 5,943,866.65 540,656.16 13.37 -2,912.28 MWD(3) 8,910.49 93.81 273.12 6,126.00 5,996 00 -4,598.13 677.45 5,941867.15 540,62591 1259 -2,885.75 MWD(3) 8,940.10 9526 276.77 6,123.66 5,993.66 -4,595.58 648.05 5,943,869.54 540,596.50 13.23 -2,859.02 MWD(3) , 8,970.55 97.70 27480 6,120.22 5,990.22 -4,591.23 618.11 5,94187174 540,566.55 1273 -2,83092 MWD(3) 9,000.23 100.43 282.32 6,115.54 5,985.54 -4,585.61 589.35 5,941879.20 540,537.76 1245 -2,803.20 MWD(3) 1 9,030.17 103.13 285.12 6,109.43 5,979.43 -4,578.66 560.88 5,941886.00 540,509.26 1285 -2,77507 MWD(3) s 9,060 41 104.81 288.21 6,102.13 5,972.13 -4,570.25 532.78 5,941894.26 540,481.11 11.37 -2,746.52 MWD(3) il 9,090.30 104.52 291.82 6,094.56 5,964.56 -4,560.35 505.61 5,94190A 01 540,453.89 11.72 -2,718.05 MWD(3) I Ill 9,120.34 102.42 295.77 6,087.56 5,957.56 -4,548.57 478.89 5,941915.65 540,427.11 14.57 -2,689.01 MWD(3) II 9,150.16 100.31 298.70 6,081.68 5,951.68 -4,535.19 452.90 5,941928.89 540,401.06 11.95 -2,659.82 MWD(3) 9,180.38 9659 301.46 6,077.24 5,947.24 -4,520.21 427.04 5,943,943.74 540,37512 15.27 -2,629.93 MWD(3) 9,210.50 9252 302.39 6,074.85 5,944.85 -4,504.33 401.57 5,943,959.47 540,349.56 13.86 -2,599.93 MWD(3) 9,240.26 89.26 305.26 6,074.39 5,944.39 -4,487.77 376.85 5,943,975.90 540,324.76 14.59 -2,570.25 MWD(3) 1rk11'8'#b 111.1`a B COMPASS Mtati 3 eakil74 • • ConocaPhtAys Still ConocoPhillips ,iwe BAKER HUMES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 1L-18 Project: Kuparuk River Unit TVD Reference: 1L-18 @ 130.00usft(1 L-18) Site: Kuparuk 1L Pad MD Reference: 1 L-18(t1 130.00usft(1L-18) Well: 1L-18 North Reference: True Wellbore: 1 L-18A Survey Calculation Method: Minimum Curvature Design: 1L-18A Database: EDM Alaska NSK Sandbox Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +Ef-W DLS Northing Easting Section Survey Tool Name 8YfOt1 v (usn) (°I (°) loot) twat) (usn) {ustty !ft). (fry (°n00) {n) ,.,I '.. 9,27048 8908 308.46 6,074.82 5,94482 -046965 352.68 5,943,993 89 540,300.50 1060 2,540.25 MWD(3) 1 9,300.42 89.54 312.22 6,075 19 5,945.19 -4,450.27 329.86 5,944,013 15 540,277.58 12.65 -2,510.81 MWD(3) 9,330.44 8954 315.07 6,075.43 5,94543 -4,429.56 308.14 5,944,033.75 540,255.75 9.49 -2,481.64 MWD(3) s 9,360.42 8997 318.26 6,075.55 5,945.55 -4,407.75 287.57 5,944,055.44 540,235.07 10.74 -2,45292 MWD(3) 9,390.41 90.64 321.55 6,075.39 5,94539 -4,38481 268.26 5,944,078.27 540,215.64 11.20 -2,42473 MWD(3) 9,420.41 91.11 325.35 6,074.94 5,94494 -4,36072 250.40 5,944,102.27 540,197.65 1276 -2,397.21 MWD(3) 9,450.57 90.21 329.61 6,07459 5,94459 -4,335.30 234.19 5,944,127.60 540,181.31 1444 -2,370.46 MWD(3) 9,480.50 8994 332.42 6,07455 5,944.55 4,309.12 219.69 5,944,153.70 540,166.67 9.43 -2,34482 MWD(3) 9,510.47 89.75 336.22 6,07463 5,94463 -4,282.12 206.70 5,944,180.63 540,153.54 12.70 -2,320.07 MWD(3) 9,540.48 90.18 339.56 6,07465 5,944.65 -4,25432 195.41 5,944,208.37 540,142.10 11.22 -2,296.39 MWD(3) 9,570.36 90.55 341.66 6,074.46 5,944.46 4,226.13 185.49 5,944,236.49 540,132.04 7.14 -2,273.71 MWD(3) 9,600.45 90.77 345.36 6,07411 5,944.11 -4,19729 176.95 5,944,265.29 540,123.34 1232 -2,251.89 MWD(3) 9,630.43 91.26 34621 6,073.58 5,943.58 4,168.23 169.59 5,944,294.31 540,115.83 3.27 -2,230.99 MWD(3) I9,662.09 91.04 348.75 6,072.95 5,94295 -4,137.33 162.73 5,944,325.16 540,108.81 8.05 -2,209.59 MWD(3) 1. 9,690.33 90.77 351.38 6,072.50 5,942.50 4,109.52 157.86 5,944,352.95 540.103.79 9.36 -2,191.47 MWD(3) 1 9,720.45 90.40 353.37 6,07219 5,942.19 4,079.67 153.86 5,944,382.77 540,09963 6.72 -2,173.08 MWD(3) 1 9,750.29 89.48 355.77 6,072.22 5,942.22 -4,04997 151.04 5,944,412.46 540,096.65 8.61 -2,155.79 MWD(3) 9,780.35 90.12 358.87 6,072.33 5,94233 -4,01994 149.63 5,944,442.47 540,095.09 10.53 -2,139.56 MWD(3) 9,810.23 90.09 0.63 6,072.27 5,942.27 -3,990.07 149.50 5,944,472.34 540,094.80 5.89 -2,124.51 MWD(3) t 9,840.34 9040 1.14 6,07214 5,942.14 -3,959.96 149.97 5,944,502.45 540,095.11 1.98 -2,109.86 MWD(3) 1 9,870.33 89.57 0.41 6,07215 5,942.15 -3,929.97 150.37 5,944,532.44 540,095.35 3.69 -2,095.21 MWD(3) 9,900.27 88.59 357.70 6,07263 5,94263 -3,900.04 149.88 5,944,562.36 540,09470 9.62 -2,079.82 MWD(3) 9,935.51 85.82 355.12 6,07435 5,94435 -3,86492 147.68 5,944,597.47 540692 31 10.74 -2,060.35 MWD(3) 9,96544 84.62 35227 6,076.85 5,946.85 -3,835.28 144.40 5,944,627.09 540,088.88 10.30 -2,042.70 MWD(3) 2 9,995.55 85.55 350.53 6,079.43 5,94943 -3,805.62 139.92 5,944,656.72 540,084.24 6.53 -2,023.98 MWD(3) t 10,025.13 86.56 34966 6,081.46 5,951.46 -3,776.55 134.84 5,944,685.76 540,07901 4.50 -2,005.05 MWD(3) e 10,055.37 87.85 347.44 6,082.94 5,952.94 -3,746.95 128.85 5,944,715.32 540,07286 8.48 -1,985.06 MWD(3) I 10,085.43 8939 34642 6,083.66 5,953.66 -3,717.68 122.05 5,944,744.56 540,065.91 6.14 -1,964.54 MWD(3) r 10,115.50 91.07 347.11 6,083.54 5,953.54 -3,688.41 115.17 ' 5,944,773.79 540,058.87 6.04 -1,943.94 MWD(3) 10,145.43 9273 347.07 6,082.55 5,952.55 -3,65925 108.48 5,944,802.90 540,052.03 5.55 -1,923.58 MWD(3) S 10,17149 49 94 45 348.41 6,080.66 5,95166 -3,62994 102.11 5,944,832.18 540,045.50 725 -1,903.40 MWD(3) t 4061V t 2.4r. f Awfie 4 CDSORCSS sow 1 X 74 • • ConotoPtulUps igai ConocoPhillips HUGHES Company: ConocoPhillips(Alaska)Inc.-Ku p2 Local Co-ordinate Reference: Well 1L-18 '..Project: Kuparuk River Unit TVD Reference: 1L-18 @ 130.00usft(1L-18) Site: Kuparuk 1 L Pad MD Reference 1 L-18 @ 130.00usft(1L-18) Well: 1L-18 North Reference: True Wellbore: 1L-18A Survey Calculation Method: Minimum Curvature Design' 1L 18A Database: EDM Alaska NSK Sandbox SurveyIl `r i Map Map Vertical '... MD Inc At{ 1110 'NDS 41,41.S +E1-W Northing Fasting OLS iSfetWn Survey Tool Name Annotation itis(t) (°) .. (1 .. (Usft) (Al* • ^.. . (usff) (t tit) ;(M00" C 10,205 49 93.93 350.53 6,078.47 5,948.47 -3,600.52 96.65 5,944,861.56 540,039.88 7.26 -1,883.96 MWD(3) 10,235 39 9273 35291 6,076.74 5,946.74 -3,570.99 9235 5,944,891.07 540,035.43 8.90 -1,86547 MWD(3) i 10,265.35 91.20 35478 6,075.71 5,945.71 -3,54122 89.14 5,944,920.82 540,032.06 8.06 -1,847.80 MWD(3) 10,295.26 90.34 357.14 6075.31 5,945.31 -3,511.39 87.03 5,944,950.64 540,029.80 8.40 -1,831.07 MWD(3) r �; 10,325.35 90.80 358.53 6,075.01 5,945.01 -3,481.32 8589 5,944,980.69 540,028.50 487 -1,815.05 MWD(3) 10,355.27 91.78 0.02 6,07433 5,94433 3,451.41 85.52 5,945,010.60 540,027.96 5.96 -1,799.77 MWD(3) i 10,390.25 88.96 359.09 6,07411 5,94411 3,416.44 8524 5,945,045.57 540,027.51 8.49 -1,782.04 MWD(3) 10,415.25 87.73 35744 6,074.83 5,94483 -3,39146 8449 5,945,070.54 540,026.62 8.23 -1,76690 MWD(3) y 10,44574 88.40 355.68 6,075.86 5,945.86 -3,361.05 8266 5,945,100.94 540,024.63 6.17 -1,752.11 MWD(3) l 10,475.31 89.85 355.32 6,076.31 5,946.31 -3,331.57 80.34 5,945,130.40 540,022.15 5.05 -1,735.36 MWD(3) I, 10,505.28 91.29 354.69 6,076.01 5,946.01 -3,301.72 77.73 5,945,160.23 540,019.38 5.24 -1,718.18 MWD(3) 10,535.31 90.34 351.74 6,075.58 5,945.59 -3,271.90 74.18 5,945,190.03 540,015.68 10.32 -1,700.20 MWD(3) . g. 10,565.28 91.99 350.19 6,074.98 5,944.98 -3,24231 69.48 5,945,219.59 540,010.82 7.55 -1,681.33 MWD(3) g @ 10,595.97 93.66 351.88 6,073.46 5,943.46 -3,21204 64.70 5,945,249.83 540,005.88 7.74 -1,662.05 MWD(3) B 10,620.30 93.35 353.84 6,071.98 5,941.98 -3,187.94 61.68 5,945,27391 540,002.73 8.14 -1,647.39 MWD(3) 10,650.18 9227 355.54 6,070.51 5,940.51 -3,158.23 58.92 5,945,303.61 539,999.82 6.73 -1,630.14 MWD(3) 10,682.97 9202 356.85 6,069.28 5,939.28 -3,125.54 56.75 5,945,336.29 539,997.47 4.06 -1,611.91 MWD(3) 10,706.03 91.23 358.42 6,068.63 5,938.63 -3,102.50 55.80 5,945,359.31 539,996.40 7.62 -1,599.57 MWD(3) 10,740.30 90.80 359.12 6,068.02 5,938.02 -3,068.25 55.06 5,945,393.56 539,99548 240 -1,581.81 MWD(3) l 10,771.13 98.80 3.10 6,068.13 5,938.13 -3,037.43 55.66 5,945,42437 539,995.91 14.45 -1,566.92 MWD(3) • I 10,810.29 89.17 4.31 6,068.82 5,938.82 -2,998.36 58.19 5,945,463.45 539,998.23 3.23 -1,549.57 MWD(3) l f 10,840.61 89.97 691 6,069.05 5,939.05 -2968.19 61.15 5,945,493.64 540,001.04 8.97 -1,537.05 MWD(3) 3 10,870.27 89.17 620 6.069.27 5,939.27 -2938.73 64.54 5,945,523.12 540,004.27 361 -1,525.25 MWD(3) t 10,900.39 88.62 4.82 6,069.85 5,939.85 -2908.75 67.43 5,945,553.10 540,007.00 4.93 -1,512.77 MWD(3) 10,916.94 88.31 292 6,070.30 5,940.30 -2,892.25 68.54 5,945,569.61 540,008.03 11.63 -1,505.48 MWD(3) 10,955.00 68.31 2.92 6.07142 5,94142 -2854.25 70.48 5,945,607.61 540,009.76 0.00 -1,488.17 PROJECTED to TD 44.&41/6 1.47Ati,e3 CCOMSS 5209 9 itd,34r • • w-' ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 1L Pad 1 L-18APB1 50-029-22145-70 Baker Hughes I1TE 11 BAKER Definitive Survey Report HUGHES 01 August,2016 • • ConcxoPtiiilips ConocoPhillips ':',..eitnitYve Stftvey R HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 1L-18 Project: Kuparuk River Unit ND Reference: 1L-18 @ 130.00usft(1L-18) Site: Kuparuk 1L Pad MD Reference: I1L-18@ 130.00usft(1L-18) Well' 1L-18 North Reference: '.True Wellbore: 1L-18APB1 Survey Calculation Method: Minimum Curvature 'l.Design: 1L-18APB1 Database: EDM Alaska NSK Sandbox 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 Well 1L-18 Well Position +N/-S 0.00 usft Northing: 5,948,461 17 usft Latitude: 70°16'12.472 N• 't +EI-W 0.00 usft Easting: 539,924.15usft Longitude: 149°40'37.662 W Position Uncertainty 0.00 usft Wellhead Elevation: ask Ground Level: 0.00 usft .... ,,,. .... _ -.. .. ..... ..........�,...�.._..... ,......_._.... ....... ,,,,,,, .....,...,,,....,,,,.,,,.E »"" Wellbore '. 1L-18APB1 s Magnetics Model Name Sample Date Win:- Dip Angle Field Strength i . (°) (nil BGGM2015 7/1/2016 18.40 80.93 57,492 Design 1L 18APB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,300 00 `' 1 Vertical Section: Depth From(ND) +N!-$ •Idtiliii�, mt� (use( (usft) Luft `" (*$ . 5 % 130 00 0 00 O00 300 00 Survey Program Date 7/17/2016 From ToStr> y SinitBy (usft) (usft) Survey(Wellbore) Teet:Ahfne Des8riptott '-Saaft.Date . 200.00 7,300.00 1L-18(1L-18) GCT-MS Schlumberger GCT multishot 1/8/2001 1 7,386.00 927147 1L-18APB1(1L-18APB1) MWD MWD Standard 7/8/2016 7/15/2016 j $r,';-;.2.;" i-?:Sa'M-14s1 Z C124144,ASS S 70.^I Strad 741 • • conocaphifts ,,,,,,,.. ConocoPhillips -..,-,7.3,,e Sulam Rep= HUGHES Company: ConocoPhillips(Alaska)Inc.-Ku p2 Local Co-ordinate Reference: Well 1L-18 Project: <Kuparuk River Unit TVD Reference: ``1L-18 @ 130.00usft(1L-18) _ Site: `Kuparuk 1L Pad MD Reference: 1 L-18(g 130.00usft(1 L-18) Well: 1 L-18 North Reference: True Wellbore: 1L-18APB1 Survey Calculation Method: Minimum Curvature Design: 1 L-18APB1 Database: EDM Alaska NSK Sandbox Survey • Map Map Vertical. MD Inc Azi i+: TVD TVDSS +N!-S (us W Northing Easting DLS Section) Survey Tool Name Annotatitln (usft) (°) (°) ..(usft) (usft) (usff) (usft) ) Ift) (°/100') (ft) 7,300.00 42.75 151.97 5,992.96 5,862.96 -3,397.33 1,251.20 5,945,070.86 541,193.22 0.60 -2,782.23 MWD(2) TIP 7,386.00 42.78 151.80 6,056.10 5,926.10 -3,448.83 1,278.71 5,945,019.51 541,221.01 0.14 -2,831.81 MWD(2) KOP 7,415.36 51.62 152.00 6,076.03 5,946.03 -3,467.82 1,288.85 5,945,000.58 541,231.25 30.13 -2,850.08 MWD(2) 7,445.49 62.57 152.50 6,092.37 5,962.37 -3,490.17 1,300.60 5,944,978.29 541,243.12 36.37 -2,871.44 MWD(2) 1 ggg t 7,475.40 72.41 153.00 6,103.81 5,973.81 -3,514.71 1,313.23 5,944,953.82 541,255.88 32.93 -2,894.65 MWD(21 7,505.49 83.97 153.72 6,109.96 5,979.96 -3,540.99 1,326.41 5,944,927.61 541,269.20 38.49 -2,919.20 MWD(2) lrill 7,535.56 89.94 162.09 6,111.56 5,981.56 -3,568.78 1,337.69- 5,944,899.89 541,280.62 34.15 -2,942.86 MWD(2) 7,560.57 89.97 171.82 6,111.57 5,981.58 -3,593.11 1,343.33 5,944,875.58 541,286.38 38.90 -2,959.91 MWD(2) - 7,590.89 90.40 181.70 6,111.48 5,981.48 -3,623.35 1,345.04 5,944,845.36 541,288.26 32.62 -2,976.51 MWD(2) 7,620.88 90.89 184.14 6,111.14 5,981.14 -3,653.30 1,343.51 5,944,815.41 541,286.89 8.30 -2,990.16 MWD(2) 7,650.82 90.83 185.95 6,110.69 5,980.69 -3,683.11 1,340.88 5,944,785.58 541,284.41 6.05 -3,002.79 MWD(2) 7,680 99 90.98 186.80 6,110.21 5,980 21 -3,713.09 1,337.53 5,944,755.59 541,281.22 2.86 -3,014.88 MWD(2) 7,710.99 90.43 187.92 6,109.84 5,979.84 -3,742.84 1,333.69 5,944,725.82 541,277.54 4.16 -3,026.43 MWD(2) 7,740.64 90.00 188.21 6,109.73 5,979.73 -3,772.20 1,329.53 5,944,696.44 541,273.53 1.75 -3,037.50 MWD(2) 7,770.51 91.01 188.65 6,109.47 5,979.47' -3,801.75 1,325.15 ‘ 5,944,666.88 541,269.31 3.69 -3,048.48 MWD(2) ) g 7,800.57 90.21 188.37 6,109.15 5,979.15 -3,831.47 1,320.70 5,944,637.13 541,265.02 2.82 -3,059.50 MWD(2) y 7,830.49 91.17 188.59 6,108.79 5,978.79 -3,861.06 1,316.29 5,944,607.52 541,260.77 3.29 -3,070.47 MWD(2) • 7,860.53 91.72 189.12 6,108.03 5,978.03 -3,890.74 1,311.66 5,944,577.83 541,256.30 2.54 3,081.30 MWD(2) 7,890.53 91.84 189.55 6,107.10 5,977.10 -3,920.32 1,306.80 5,944,548.22 541,251.60 1.49 -3,091.89 MWD(2) 7,920.29 91.75 191.13 6,106.17 5,976.17 -3,949.59 1,301.46 5,944,518.93 541,246.41 5.32 -3,101.89 MWD(2) 7,950.37 91.38 192.89 6,105.35 5,975.35 -3,979.00 1,295.21 5,944,489.49 541,240.31 5.98 -3,111.18 MWD(2) 7,980.39 91.10 193.58 6,104.70 5,974.70 -4,008.21 1,288.33 5,944,460.24 541,233.60 2.48 -3,119.84 MWD(2) 18,010.43 91.38 194.69 6,104.05 5,974.05 -4,037.33 1,281.00 5,944,431.08 541,226.42 3.81 -3,128.05 MWD(2) 8,040.47 91.32 195.57 6,103.34 5,973.34 -4,066.32 1,273.16 5,944,402.05 541,218.74 2.94 -3,135.75 MWD(2) li 8,070.51 90.64 195.34 6,102.82 5,972.82 -4,095.27 1,265.16 5,944,373.07 541,210.89 2.39 -3,143.30 MWD(2) 8,100.47 90.83 195.99 6,102.44 5,972.44 -4,124.12 1,257.07 5,944,344 18 541,202.95 2.26 -3,150.71 MWD(2) 8,130.37 90.37 197.00 6,102.13 5,972.13 -4,152.79 1,248.58 5,944,315.47 541,194.62 3.71 -3,157.69 MWD(2) 8,160.49 90.03 197.96 6,102.02 5,972.02 -4,181.51 1,239.53 5,944,286.70 541,185.72 3.38 -3,164.22 MWD(2) • 8,190.95 89.72 198.91 6,102.09 5,972.09 -4,210.41 1,229.90 5,944,257.75 541,176.24 3.28 -3,170.33 MWD(2) • 8,220.79 89.57 202.09 6,102.27 5,972.27 -4,238.36 1,219.45 5,944,229.76 541,165.95 10.67 -3,175.26 MWD(2) ? Ellett 8S:4tl B 8 Rage 9SI3DEJ`1 saw.74 0 C onoc-GPt'8i11ips MI ConocoPhillips -; ;F,,= sump/Rev= _ Bain Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 1L-18 Project Kuparuk River Unit TVD Reference: 1 L-18@ 130.00usft(1 L-18) Site: Kuparuk 1L Pad MD Reference: 1 L-18 @ 130.00usft(1L-18) • Welt 1L-18 North Reference: True • Wellbore: '1L-16APB1 Survey Calculation Method: Minimum Curvature Design: 1 L-18APB1 Database: EDM Alaska NSK Sandbox Survey...... Map 'Map Vertical MD Inc Azi ND. TVDSS +NIS +EI-W OLS (ustt).. O (°) .' (ustt usft usft u Northing Easting > iSectSurvey Tool Name Annotation g;: ) ( ) ( ) (usft) (k)i ',' on t 10(4 tin , 8,250.69 88.43 205.12 6,102.80 5,972.80 -4,265.75 1,207.48 5,944,202.31 541,154.12 10.83 -3,178.58 MWD(2) 8,280.89 8862 208.78 6,10357 5,973.57 -4,292.65 1,193.80 5,944,175.33 541,140.59 12.13 -3,180.19 MWD(2) 8,310.83 87.42 21162 6,104.61 5,974.61 -4,318.24 1,178.31 5,944,149.66 541,125.23 16.65 .3,179.56 MWD(2) 8,340.95 87.42 217.54 6,105.96 5,975.96 -4,342.71 1,160.80 5,944,125.11 541,107.86 13.00 -3,176.64 MWD(2) 8,370.79 88.43 220.62 6,107.05 5,977.05 -4,365.85 1,142.01 5,944,101.86 541,089.19 10.86 -3,171.93 MWD(2) 8,401.01 88.56 225.20 6,107 84 5,977.84 -4,387.97 1,121.44 5,944,079.64 541,068.74 15.16 -3,165.19 MWD(2) g 8,430.59 88.06 229.32 6,108.71 5,978.71 -4,408.04 1,099.73 5,944,059.46 541,047.14 14.02 -3,156.42 MWD(2) a 6,465.57 86.87 233.19 6,110.26 5,980.26 -4,429.90 1,072.48 5,944,037.45 541,020.01 11.56 -3,143.75 MWD(2) 6,490.65 86.43 235.51 6,111.73 5,981.73 -4,44449 1,05214 5,944,022.75 540,999.75 9.40 -3,133.43 MWD(2) I 8,520.53 87.45 239.20 6,11132 5,983.32 -4,460.59 1,027.02 , 5,944,006.53 540,974.72 12.80 -3,119.72 MWD(2) • 8,550.54 87.94 244.35 6,114.53 5,984.53 -4,474.76 1,000.61 5,943,992.22 540,948.38 17.22 -3,10193 MWD(2) 8,580.32 88.83 248.18 6,115.37 5,985.37 -4,486.74 97136 5,943,980.09 540,921.20 13.20 -3,086.33 MWD(2) • 8,610.31 89.63 252.19 6,115.77 5,985.77 -4,496.90 945.16 5,943,969.78 540,893.05 13.63 -3,066.98 MWD(2) • • 8,640.49 90.22 255.74 6,115.81 5,985.81 -4,505.24 916.16 5,943,961.30 540,864.10 11.92 -3,046.04 MWD(2) I 8,670.37 89.26 260.12 6,115.95 5,985.95 -4,511.49 886.95 5,943,954.89 540,834.93 ' 15.01 -3,023.86 MWD(2) I 8,700.39 90.83 263.96 6,115.92 5,985.92 -4,515.64 857.22 5,943,950.58 540,805.23 13.82 -3,000.20 MWD(2) 8,730.38 90.61 268.15 6,115.55 5,985.55 -4,517.70 827.31 5,943,948.36 540,775.33 13.99 -2,975.33 MWD(2) - 8,760.42 90.68 272.28 6,115.21 5,985.21 -4,517.59 797.28 5,943,948.31 540,745.30 13.75 -2,949.26 MWD(2) 8,790.37 90.40 275.99 6,114.93 5,984.93 -4,515.43 767.42 5,943,950.31 540,715.43 12.42 -2,922.32 MWD(2) I • 8,820.41 90.12 280.02 6,114.79 5,984.79 -4,511.25 737.67 5,943,954.34 540,685.67 13.45 -2,894.47 MWD(2) • S 8,850.33 90.22 285.61 6,114.70 5,984.70 -4,504.62 708.51 5,943,960.82 540,656.47 18.69 -2,865.90 MWD(2) • 8,880.40 89.69 288.64 6,114.72 5,984.72 -4,495.76 679.78 5,943,969.52 540,627.70 10.23 -2,836.59 MWD(2) •• 8,910.44 90.03 293.01 6,114.80 5,984.80 4,485.09 651.71 5,943,980.04 540,599.57 14.59 -2,806.94 MWD(2) 8,940.43 90.49 296.83 6,11466 5,984.66 -4,47245 624.52 5,943,992.53 540,572.32 1283 -2,777.07 MWD(2) 8,970.48 90.34 301.38 6,114.44 5,984.44 -4,457.84 598.27 5,944,007.00 540,545.99 15.15 -2,747.03 MWD(2) • 9,000.37 90.00 304.90 6,114.35 5,984.35 -4,441.50 57124 5,944,023.21 540,520.89 11.83 -2,717.19 MWD(2) 9,030,34 9129 307.73 6,11402 5,984.02 4,423.76 549.10 5,944,040.82 540,496.65 10.38 -2,687.41 MWD(2) I 9,060.72 95.33 308.78 6,112.26 5,982.26 -4,404.98 525.29 5,944,059.47 540,472.74 1174 -2,657.40 MWD(2) I, 9,090.31 98.60 311.15 6,108.68 5,978.68 -4,386.12 502.78 5,944,078.21 540,450.14 1361 -2,628.48 MWD(2) • • 9,120.27 99.09 315.86 6,104.07 5,974.07 -4,365.75 481.31 5,944,098.46 540,428.56 15.62 -2,599.70 MWD(2) • g 9,150 25 99.80 319.55 6,099 14 5969 14 -4,343.88 461.41 5,944,120.23 540,408.55 12.37 2 571 54 MWD(2) I 'S..�,U,..,.M,,,..._.H............�..,,�A ..... ,,,,M.,...»...,.....,..,.....,,.w,....,..,,...,.W.....,,�.,......,,„...»� .,......,....w. ,,,,,,,�.,..»»....,...,._ .,. ,,,___ »»...�,�w.,A,,,»,m, t f f0lb V.5.540141 `F4p'e4 COVIAMS SEW:7 .7q • • CorwcoPhitlips ConocoPhillips oeffroeve survey feeport HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 1 L-18 Project: Kuparuk River Unit $NO Reference: 1L-18@ 130.00usft(1 L-18) Site: Kuparuk 1L Pad MD Reference: 1 L-18 @ 130.00usft(1L-18) Well: 1L-18 North Reference: True Wellbore:''. 1L-18APB1 Survey Calculation Method: Minimum Curvature Design: 1 L-18APB1 -Database: EDM Alaska NSK Sandbox Survey i MD Inc Azi TVD TVDSS +N/-5 +EI-W Map Map DLS Vertical Northing Eastmg Section Survey Tool Name Annotation. (usft) (°) (°) (usft) (usft) (usft) lusft 1 (ft) (ft) (°1100.1 (ft) 9,180.29 9969 324.80 6,094.06 5,964.06 -4,320.50 443.27 5,944,143.50 540,390.28 17.23 -2,54413 MWD(2) t. 9,210.20 99.94 329.26 6,088.96 5,958.96 -4,295.78 427.23 5,944,168.14 540,374.12 14.72 -2,517.88 MWD(2) ) 9,240.27 99.91 333.68 6,083.77 5,953.77 -4,269.77 413.09 5,944,194.07 540,359.84 14.48 -2,492.63 MWD(2) ) 9,271.47 96.56 335.06 6,079.30 5,949.30 -0,241.93 399.73 5,944,221.84 540,346.34 11.59 -2,467.14 MWD(2) • 9,313.00 96.56 335.06 6,074.56 5,944.56 -4,204.52 382.34 5,944,259 15 540,328.74 0.00 -2,433.37 PROJECTED to TD .8/526"X6:2=3`5.ffld=.11I iqlgeS .1 74 s • • ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 1L Pad 1 L-18APB2 50-029-22145-71 Baker Hughes INTEQ411 BAKER Definitive Survey Report HUGHES 01 August,2016 • • ConocoPhillips ;, ,lot Company: ConocoPhillips(Alaska)Inc-Ku p2 Local Co-ordinate Reference: Well1L-18 Project: Kuparuk River Unit TVD Reference: 1L-18(§130.00usft(1L-18) Site: Kuparuk 1L Pad MD Reference: 1 L-18(t�130.00usft(1 L-18) Well: 1L-18 North Reference: True Wellbore: 1 L-18APB2 Survey Calculation Method: Minimum Curvature Design: IL-18APB2 Database EDM Alaska NSK Sandbox Project Kuparuk River Unit,North Slope Alaska,United States j Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level j Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point _ ji • Map Zone: Alaska Zone 04 Using geodetic scale factor t Well 1L-18 Well Position 1-NLS 0.00 usft Northing. 5,948461 17 usft Latitude: 70 16 12.472 N { +E/-W 0.00 usft Fasting: 539,924.15usft Longitude: 149°40'37.662 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1L 18APB2 Magnetics Model Name SanipteDate'. DectiMNdd DipAnyle _ , FreftlStfength „,1 (°) {nT} BGGM2015 7/1/2016 18.40 80.93 57,492 • Design 1 L 18APB2 Audit Notes: ig Version: 1.0 Phase: ACTUAL lie On Depth: 8,430.59 Vertical Section: Depth From(TVD) +N/-$ l 1.W i on.. t (usft) „(uaftk (thgt) F 130.00 0.00 0.00 300.00 , Survey Program Date 7/17/2016 7t From To ,SdsiYVey rk (usft( (usft) Survey(Wellbore) Tool Name ' Description - ':%°Sti.7tDate ,f 1➢ 200.00 7,300 00 1L-18(1 L-18) GCT-MS Schlumberger GCT multishot 1/8/2001 3 7,386.00 8,430.59 1L-18APB1(1L-18APB1) MWD MWD-Standard 7/8/2016 7/15/2016 8,441.00 9,155.91 1L-18APB2(1L-18APB2) MWD MWD-Standard 7/16/2016 7/17/2016 FSS'S tZ.-:8 99pAf P410e 2 'SS BODO 1 Strad 14 • • conocoPhimps EMI ConocoPhillips Dthirtitte _,;_ = ESKERHUGHEs Company: ConocoPhilllps(Alaska)Inc-Ku p2 Local Co-ordinate Reference: Well 1L-18 Project: Kuparuk River Unit TVD Reference: 1 L-18 @ 130.00usft(1 L-18) Site: Kuparuk 1 L Pad MD Reference: 1L-1 8 @ 130.00usft(1 L-18) Well: 1 L-18 North Reference: - True Wellbore: 1L-18APB2 Survey Calculation Method: Minimum Curvature Design: 1 L-18APB2 Database: EDM Alaska NSK Sandbox Survey MD Inc Azl ND TVDSS -1-NI-S +8/W Map Map OLS Vertical" Northing basting Section Survey Tool Name A14104t1011 Nett) - r) (°I (usft) (usft) (usft) (usft) (h) _ (ft) (°1100') Ift1 8,430.59 88.06 229.32 6,108.71 5,978.71 -4,408.04 1,099.73 5,944,059.46 541,047 14 14.02 -3,156.42 MWD(2) TIP 8,441.00 87.71 230.47 6,109.10 5,979.10 -4,414.74 1,091.78 5,944,052.72 541,039.22 11.54 -3,152.88 MWD(3) KOP 8,470.35 91.78 233.71 6,109.23 5,979.23 -0,432.76 1,068.63 5,944,034.57 541,016.17 17.72 3,141.84 MWD(3) 8,500.89 92.67 237.78 6,108.04 5,978.04 -4,449.94 1,043.41 5,944,017.27 540,991.05 13.63 -3,128.59 MWD(3) 8,530.09 9230 240.49 6,106.77 5,976.77 -4,464.90 1,018.37 5,944,002.17 540,966.09 9.36 -3,11439 MWD(3) 8,560.05 90.34 24301 6,106 08 5,976.08 -4,479.08 991.99 5,943,987.86 540,939.79 10.65 3,098.63 MWD(3) 8,590.21 87.36 243.64 6,106.69 5,976.69 -4,492.61 965.05 5,943,974.18 540,912.92 10.10 3,082.06 MWD(3) t 8,620.23 88.68 245.62 6,107.73 5,977.73 -4,505.47 937.94 5,943,961.18 540,885.88 7.92 -3,065.02 MWD(3) 8,650.04 92.37 249.06 6,107 45 5,977.45 -4,516.95 910.44 5,943,949.56 540,858.45 16.92 3,046.94 MWD(3) 8,680.17 93.47 251.44 6,105.92 5,975.92 -4,527.11 882.13 5,943,939.24 540,830.19 8.69 -3,027.50 MWD(3) 1 8,710.22 92.12 254.30 6,104.45 5,974.45 -4,535.95 85345 5,943,930.25 540,801.56 10.51 -3,007.08 MWD(3) 8,740.15 92.03 258.89 6,10337 5,973.37 -4,542.89 824.36 5,943,923.17 540,772.51 15.33 -2,985.36 MWD(3) 6,770.12 90.71 262.16 6,102.65 5,972.65 -4,547.82 794.81 5,943,918.08 540,742.99 11.76 -2,962.23 MWD(3) ' 8,800.16 90.06 266.45 6,102.45 5,972.45 -4,550.80 764.93 5,943,914.94 540,713.13 14.44 -2,937.84 MWD(3) 1 8,830.35 90.31 270.27 6,102.35 5,972.35 -4,551.66 734.76 5,943,913.92 540,682.96 12.68 -2,912.15 MWD(3) jjt E 8,860.10 92.61 27360 6,101.59 5,971.59 4,550.66 705.04 5,943,914.76 540,653.25 1160 -2,885.91 MWD(3) 8,890.12 94.18 276.96 6,099 82 5,969.82 -4,547.90 675.20 5,943,917.36 540,623.40 12.34 -2,858.69 MWD(3) } 1 8,920.06 96.34 280.11 6,097.07 5,967.07 -4,543.48 645.72 5,943,921.63 540,593.90 12.72 -2,830.95 MWD(3) 6,950.10 97.64 28367 6,093.41 5,963.41 -4,537.34 616.55 5,943,927.61 540,564.70 12.53 -2,802.62 MWD(3) 8,980.05 98.75 287.17 6,089.14 5,959.14 -4,529.46 587.98 5,943,935.34 540,536.09 1215 -2,773.93 MWD(3) 9,010.15 99.20 290.50 6,084 45 5,954.45 -4,519.86 559.85 5,943,944.79 540,507.91 11.03 -2,744.77 MWD(3) 1g 9,040.08 100.40 292.58 6,079.35 5,949.35 -4,509.03 532.41 5,943,955.47 540,480.42 7.94 -2,715.60 MWD(3) 9 9,070.02 104.40 29344 6,072.92 5,942.92 -4,497.61 505.50 5,943,966.75 540,453.45 13.65 -2,686.58 MWD(3) 19,099.99 108.52 294.57 6,064.43 5,934.43 -4,485.92 479.25 5,943,978.29 540,427.14 14.21 -2,658.01 MWD(3) 9,130.04 112.97 295.83 6,053.79 5,923.79 -4,473.96 453.83 5,943,990.12 540,401.66 15.32 -2,630.01 MWD(3) 9,155.91 116.61 297.04 6,042.95 5,912.95 -4,463.51 432.80 5,944,000.45 540,380.58 14.70 -2,606.57 MWD(3) 9,184.00 116.61 297.04 6,030.36 5,900.36 -4,452.10 410.43 5,944,011.75 540,358.15 0.00 -2,581.49 PROJECTED to TD 410101,1*146411140 Akira ZerAIIMSS 7&Al 74 1REC IVED S AUG 0 2 2010 Letter of Transmittal Mal AOGCC BAKER Date: DATA LOGGED August 1' 2016 /242016 HUGHES M.K.BENDER To: From: Makana Bender Yosha Ragbirsingh/Michael Soper AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 1L-24APB1 21 6 0 4 9 27 4 3 9 1L-24A 2 1 6 0 4 9 27 4 4 0 1L-24AL1-02PB1 2 1 6 0 8 0 1L-24AL1-02 21 6 0 8 0 7 4 4 1 1L-24AL1 21 6 0 5 0 1443 1L-18APB1 1L-18APB2 21 21 6056 64 4 5 1L-18A 21 60 7 4 4 6 1L-18AL1 21 64 27 447 (9) 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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J J J f IF 3 p Oro W ON) S''', 8rm ON) OM) ON) ON) 00) m 8 A N 4, O O O N (O (O N O M m O O N N O N M O O O O O) O OO) o, (O O O O O O O O O O O O O O O O O O O O O 0p O O O (O 03 T o i 0 M Q r O M m mN m N m Lr. Q rr O M m m N 0 m O Q r O N OQ 41 .o 0 t E 0 co- co- co- W c6 W W O] W OO co- co- co- co- OO OO co- co- W CJ 0) 0) 0DOD6 (0 O U o o :: w a y 7 O a w o co • 0 • • ..°F T�� Alaska Oil and Gas �\�����j,�s� THE STATE F •,. o f Conservation Commission ALASI�:A 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 k, r+ � Main: 907.279.1433 • fie, Fax: 907.276.7542 ALAS www.aogcc.alaska.gov K. Starck CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1L-18A ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-056 Surface Location: 507' FNL, 143' FEL, SEC. 31, Ti 1N, R10E,UM Bottomhole Location: 2695' FNL, 23' FEL, SEC. 31,Ti 1N, R10E, UM Dear Mr. Starck: Enclosed is the approved application for permit to redrill the above referenced service well. 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, Cathy . Foerster Chair DATED this a y of April, 2016. STATE OF ALASKA RECEIVED A4PA OIL AND GAS CONSERVATION COM4ON APR 14 2016 PERMIT TO DRILL 20 AAC 25.005 , la.Type of Work: 1 b.Proposed Well Class: Exploratory-Gas ciService- WAG c]f Service-Disp ❑ 1 c.S ci sed for: Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development-Oil ❑ Service- Winj Cl Single Zone CI % Coalbed Gas ❑ Gas Hydrates ❑ Redrill L i Reentry❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket ❑� , Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska Inc Bond No. 59-52-180 KRU 1L-18A 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 11,400' • TVD: 6,077' • Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Kuparuk Oil Pool Surface: 507'FNL,143'FEL,Sec.31,T11 N,R10E,UM ' ADL 25659 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 4533'FNL,4131'FEL,Sec.32,T11 N,R10E,UM ALK 2585 8/7/2016 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 2695'FNL,23'FEL,Sec.31,T11 N,R10E,UM 2560 - 12,720' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): 130• 15.Distance to Nearest Well Open Surface:x- 539924 y- 5,948,461 Zone- 4 , GL Elevation above MSL(ft): 87, to Same Pool: 1L-13AL1,610' 16.Deviated wells: Kickoff depth: 7,385 feet • 17.Maximum Potential Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 95° degrees. Downhole: 3,702 psig • Surface: 3,097 psig . 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2.375" 4.7# L-80 ST-L 3,400' 8,000' 6,104' 11,400' 6,077' slotted liner 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): 7,800' 6,359' none 7,700' 6,285' 7,626' Casing Length Size Cement Volume MD TVD Conductor/Structural 122' 16" 235 sx AS I 122' 122' Surface 3,991' 9-5/8" 800 sx PF E&500 sx Premium 4,121' 3,567' Production 7,659' 7" 250 sx Class G 7,789' 6,351' Perforation Depth MD(ft): 7244'-7298',7442'-7464', Perforation Depth TVD(ft): 5952'-5992',6097'-6113', 7540'-7550' 6169'-6177' 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program 0 Time v.Depth Plot ❑ Shallow Hazard Analysis El Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements2 21. Verbal Approval: Commission Representative: Date q//3/02°I b 22.I hereby certify that the foregoing is true and the procedure approved herein will not R.Phillips @265-6312 6P be deviated from without prior written approval. Contact Email ron.l.phillipsacop.com Printed Name K.Starck Title CTD Engineer Signature / 41-N . Phone 263-4093 Date 7 Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: Q./(0 of cD 50-O a3 ^oZ a 116-_61 -0l3 Date: 4 Iau t 1 p 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: 171 Other: 8 d p '-c 5 t to j(,1,0 p 5 j q 5�q Samples req'd: Yes❑ Nod Mud log req'd:Yes❑ No[ ' e n n vJ a p re V e ,' r-5 t t 5-e)° U U J HZS measures: Yes]I?J No❑ Directional svy req'd:Yes['No❑ Spacing exception req'd: Yes❑ No V Inclination-only svy req'd:Yes❑ No g Post initial injection MIT req'd:Yes No❑ APPROVED BY Approved by:OCOMMISSIONER THE COMMISSION Date: f -1 Vii 4/zi/I4, Submit Form and Form 10-401(Revised 11/2015) T iRr i1tll �f 2 monthsCOI* from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate • • . ConocoPhillips ECE ED Alaska APR 14 2016 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 OGCC April 6, 2016 Commissioner-State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill a dual-lateral out of the Kuparuk Well 1L-18 using the coiled tubing drilling rig, Nabors CDR2-AC. The work is scheduled to begin August 2016. The objective will be to drill laterals KRU 1L-18A and 1 L-18AL1 targeting the Kuparuk A5-sands. A separate sundry application was submitted to plug the KRU 1L-18 (PTD 191- 035) perfs to allow these laterals to be drilled. As detailed in the Summary for plugging Sundry, ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1)to plug the NC-sand perfs in 1L-18. Attached to this application are the following documents: — 10-401 Applications for 1L-18A and 1 L-18AL1 — Detailed Summary of Operations — Directional Plans for 1L-18A and 1 L-18AL1 — Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-265-6312. Sincerely, a.,, 3. 2z/.4.„ Ron Phillips ConocoPhillips Alaska Coiled Tubing Drilling Engineer • • Kuparuk CTD Laterals NAe0A5 ALASKA di; 1L®18A & 1L-18AL1CIJs CanomPhill^ps Application for Permit to Drill Document 2fC 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(1)and 20 MC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 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 6 14. Disposal of Drilling Mud and Cuttings 6 (Requirements of 20 AAC 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 7 (Requirements of 20 AAC 25.050(b)) 7 16. Quarter Mile Injection Review(for injection wells only) 7 (Requirements of 20 AAC 25.402) 7 17. Attachments 7 Attachment 1: Directional Plans for 1 L-18A and AL1 laterals 7 Attachment 2: Current Well Schematic for 1L-18 7 Attachment 3: Proposed Well Schematic for 1L-18A and AL1 laterals 7 Page 1 of 7 April 6, 2016 • • PTD Application: 1 L-18A & 1 L-18AL1 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document are 1L-18A& 1 L-18AL1. All laterals will be classified as "Service-Wag"wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 1L-18A & 1 L-18AL1. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,600 psi. Using the maximum formation pressure in the area of 3 70 i in 1L-16 (i.e. 12.0 ppg EMW), the maximum potential surface pressure in 1L-18, assuming a gas gradient of 0.1 psi/ft, would be 3,097 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 1L-18 was measured to be 3,143 psi (10.0 ppg EMW) on 5/10/2014. All of the wells in the 1L-18 vicinity are between 9.3 ppg and 10.6 ppg. The combined A and C sand SBHP readings suggest pressures will be close to 10 ppg. The maximum downhole pressure in the 1L-18 vicinity, is the 1L-16 injector at 3702 psi or 12.0 ppg EMW. The 1L-16 injector is on the other side of the 1L-15 and 1L-13 producers, which are at a 9.4 ppg and 9.8 ppg. There is also a large sealing fault between the 1L-16 injector and the 1L-18 well, so we do not expect to see pressures over 10.6 ppg EMW. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) None of the offset injection wells to 1 L-18 have ever injected gas, so there is a low probability of encountering free gas while drilling the 1L-18 laterals. Nevertheless, 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 AA C 25.005(c)(4)(c)) The major expected risk of hole problems in the 1L-18 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 1L-18 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 7 April 6, 2016 • • PTD Application: 1L-18A & 1 L-18AL1 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Name Liner Top Liner Btm Liner Top Liner Btm Liner Details MD MD TVD TVD IL-18A 8,000' 11,400' 6,104' 6,077' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 1L-18AL1 7,157' 10,200' 5,889' 6,096' 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 (ppb TVD TVD psi psi Conductor 16" 62.5 H-40 Welded 0' 122' 0' 122' 1,640 670 Surface 9-5/8" 36 J-55 BTC 0' 4121' 0' 3,567' 3,520 2,020 Production 7" 26 J-55 BTC-MOD 0' 7789' 0' 6,351' 4,980 4,320 Tubing 3-1/2" 9.3 J-55 EUE 0' 7168' 0 5,897' 6,980 7,400 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride-based FloVis mud (8.6 ppg) — Drilling operations: Chloride-based FloVis mud (8.6 ppg)./While 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 11.8 ppg NaBr completion fluid in order to 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 1L-18 laterals we will target a constant BHP of 11.8 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 7 April 6,2016 • i PTD Application: 1L-18A & 1 L-18AL1 Pressure at the 1 L-18 Window(7,385' MD, 6055' TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure (9.9 ppg) 3117 psi 3117 psi Mud Hydrostatic (8.6 ppg) 2708 psi 2708 psi Annular friction (i.e. ECD, 0.080 psi/ft) 591 psi 0 psi Mud + ECD Combined 3299 psi 2708 psi (no choke pressure) (overbalanced -182 psi) (underbalanced -409 psi) Target BHP at Window(11.8 ppg) 3715 psi 3715 psi Choke Pressure Required to Maintain 417 psi 1008 psi Target BHP 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is 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 AA C 25.005(c)(13)) Summary of Operations Background Well 1L-18 was originally drilled and completed in 1991 with 3'/2"tubing and 7"production casing as an A-sand and C-sand,Kuparuk injector. Prior to CTD operations,the 3-1/2"tubing tail will be perforated and the D nipple at 7,133' MD will be milled out to a 2.80"ID. The existing A/C-sand perfs will be squeezed with cement to provide a means to kick out of the 7" casing. Following the cement squeeze Nabors CDR2-AC will drill a pilot hole to 7,415' MD and set a mechanical whipstock in the 2.80"pilot hole to kick off at 7,385' MD. Two laterals will be drilled: one to the northwest and one to the south of the parent well with the laterals targeting the Kuparuk A5 sand. Both laterals will be completed with 2-3/8" slotted liner from TD with the last lateral liner top located inside the 3-1/2"tubing tail. Page 4 of 7 April 6, 2016 4110 PTD Application: 1 L-18A & 1 L-1 8AL1 Pre-CTD Work 1. RU Slickline: dummy off gas lift mandrels and pressure test. 2. RU E-line: Shoot 2' of holes in the 3W tubing tail at 7128' MD. 3. RU Pumping Unit: perform injectivity test down the tubing. 4. RU Service Coil: Mill out D nipple and cement squeeze the NC-sand perforations up to the perforations in the tubing tail. 5. RU Slickline: Tag top of cement and log. 6. Prep site for Nabors CDR2-AC and set BPV. Rig Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 1 L-18A Sidetrack (A5 sand - Northwest) J a. Drill 2.80" high-side pilot hole through cement to 7,415' MD b. Caliper pilot hole c. Set top of whipstock at 7,385' MD d. Mill 2.80"window at 7,385' MD. e. Drill 3" bi-center lateral to TD of 11,400' MD. f. Run 2%" slotted liner with an aluminum billet from TD up to 8,000' MD. 3. 1L-18AL1 Lateral (A5 sand - South) a. Kick off of the aluminum billet at 8,000' MD. b. Drill 3" bi-center lateral to TD of 10,200' MD. c. Run 2%" slotted liner with deployment sleeve from TD up to 7,157' MD. 4. Freeze protect, set BPV, ND BOPE, and RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain SBHP 3. Return to injection Page 5 of 7 April 6, 2016 • • PTD Application: 1L-18A & 1 L-18AL1 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 undeployment, the steps listed above are observed, only in reverse. Liner Running — The 1L-18A laterals will be displaced to an overbalancing fluid (11.8ppg NaBr) prior to running liner. See "Drilling Fluids" section for more details. — While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AA C 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18 or 1B disposal facilities) or Prudhoe DS-4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). Page 6 of 7 April 6,2016 • • PTD Application: 1L-18A & 1 L-18AL1 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.'s 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) Lateral Name Distance 1L-18A 12,720' 1 L-18AL1 10,800' — Distance to Nearest Well within Pool Lateral Name Distance Well 1L-18A 610' 1L-13AL1 1 L-18AL1 670' 1L-25AL1-02 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) There are two wells within %4-mile of the 1L-18A and 1 L-18AL1 laterals. Well 1L-18A will be a Kuparuk A-sand injector and both wells within a quarter mile are Kuparuk C-sand producers. 1L-18 (mother bore) Injector • Classified as a "Normal Well" • The well is completed with 3.5" 9.3#J-55 tubing and 7" 26#J-55 production casing. • Packer located at 7116' MD which is located less than 200' from the top of the perforations. • A-sand perforations: C: 7244' - 7298' MD, A: 7442' -7464' MD, and A: 7540' -7550' MD • Well is currently SI for Pre-CTD well work to Plug and abandoned the A and C sand perfs to allow the well to be sidetracked. This well will be a A5-sand injector only. • Production casing was cemented with 250 sx of Class "G" cement. The proposed kick off point for the CTD sidetrack is between the perforations and should not compromise existing conformance. 1 L-13AL1 (producer), —610' away from 1L-18A lateral to the southwest • Classified as a "Normal Well" • The well is completed with 3.5" 9.3#J-55 tubing and 7" 26#J-55 production casing. • Packer located at 7277' MD which is located less than 200' from the top of the perforations. • NC-sand perforations: C4: 7417' -7485' MD, A5: 7612' -7638' MD, and A5: 7719' -7729' MD • Well is currently SI for Pre-CTD well work to Plug and abandoned the A and C sand perfs to allow the well to be sidetracked. This well will be a C-sand producer only. • Production casing was cemented with 250 sx Class `G' 1 L-25AL1-02 (producer), —670' away from 1 L-18AL1 lateral to the south • Classified as a "Normal Well" • Well is completed with 3.5" 9.3#J-55 tubing and 7" 26#J-55 production casing. • Packers located at 8692' MD which is located less than 200' from the top of the perforations. • This well is a C-sand producer only. • 2-3/8" Slotted liner form 8838' MD to 10,374' MD. • Production casing was cemented with 250 sx Class 'G' 17. Attachments Attachment 1: Directional Plans for 1L-18A and AL1 laterals Attachment 2: Current Well Schematic for 1L-18 Attachment 3: Proposed Well Schematic for 1L-18A and AL1 laterals Page 7 of 7 April 6,2016 • S $ ( \` 2 M { \� ) } § {E \ 7g 72 - \ a /} {k }) @ | } \} !7 !7 ! 1 \ %/! \ \� ! � ? 2k !! \) /( j\ :-.2; \} \{ \ - m ! f_- '-z• | 3 Q ;; }! ) 2 !! 7 Al § 0 !! 0 , \ /ƒ ] ) § )k § § § \k % "6! ! E U # - ! : E } t f j ) - - ® § £ )41 § ) § ) , ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 1L Pad IL-18 1L-18A Plan: 1 L-18A wp03 Standard Planning Report 18 March, 2016 r' 1 BAKER HUGHES • • ✓ ConocoPhillips Ird.11 ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 1 L-18 Company: ConocoPhillips(Alaska)Inc.-Kup2 ND Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 L-18 @ 130.00usft(1 L-18) Site: Kuparuk'IL Pad North Reference: True Well: 1 L-18 Survey Calculation Method: Minimum Curvature Wellbore: 1L-18A Design: 1 L-1 8A_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 1L Pad Site Position: Northing: 5,949,190.90 usft Latitude: 70°16'19.650 N From: Map Easting: 539,916.78 usft Longitude: 149°40'37.763 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.30 ° Well 1L-18 Well Position +NI-S 0.00 usft Northing: 5,948,461.17 usft Latitude: 70°16'12.472 N +E/-W 0.00 usft Easting: 539,924.15 usft Longitude: 149°40'37.662 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1 L-18A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (`) (nT) BGGM2015 7/1/2016 18.40 80.93 57,492 Design 1 L-1 8A_wp03 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,300.00 Vertical Section: Depth From(ND) +N/-S +EI-W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 300.00 3/18/2016 9:10:21AM Page 2 COMPASS 5000.1 Build 74 • • 1.. ConocoPhillips EMI ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 1L-18 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1L-18 @ 130.00usft(1L-113) Site: Kuparuk 1L Pad North Reference: True Well: 1L-18 Survey Calculation Method: Minimum Curvature Wellbore: 1L-18A Design: 1L-18A 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) (°/100ft) (°/100ft) (1 Target 7,300.00 42.75 151.97 5,862.96 -3,397.33 1,251.20 0.00 0.00 0.00 0.00 7,385.00 42.78 151.80 5,925.36 -3,448.24 1,278.39 0.14 0.04 -0.20 -75.49 7,406.00 46.98 151.80 5,940.24 -3,461.29 1,285.39 20.00 20.00 0.00 0.00 7,519.21 90.00 151.80 5,980.78 -3,551.95 1,334.01 38.00 38.00 0.00 0.00 7,589.21 90.00 178.40 5,980.78 -3,618.99 1,351.84 38.00 0.00 38.00 90.00 7,675.00 90.30 181.82 5,980.56 -3,704.77 1,351.68 4.00 0.35 3.98 85.00 7,775.00 91.67 185.58 5,978.84 -3,804.52 1,345.23 4.00 1.37 3.76 70.00 8,100.00 90.50 198.53 5,972.68 -4,121.62 1,277.51 4.00 -0.36 3.98 95.00 8,200.00 89.80 202.47 5,972.41 -4,215.27 1,242.50 4.00 -0.70 3.94 100.00 8,375,00 86.25 223.18 5,978.50 -4,361.43 1,148.26 12.00 -2.03 11.84 100.00 8,550.00 87.21 244.19 5,988.59 -4,464.30 1,008.26 12.00 0.55 12.01 88.00 8,750.00 90.29 268.00 5,993.00 -4,511.97 815.58 12.00 1.54 11.91 83.00 8,900.00 90.28 286.00 5,992.25 -4,493.76 667.31 12.00 -0.01 12.00 90.00 9,000.00 95.31 296.91 5,987.36 -4,457.30 574.51 12.00 5.04 10.91 65.00 9,175.00 94.96 318.00 5,971.51 -4,351.91 436.95 12.00 -0.20 12.05 90.00 9,290.00 92.45 331.59 5,964.04 -4,258.36 370.96 12.00 -2.19 11.83 100.00 9,390.00 90.33 343.41 5,961.61 -4,166.16 332.78 12.00 -2.12 11.82 100.00 9,500.00 89.18 356.56 5,962.09 -4,058.08 313.70 12.00 -1.04 11.95 95.00 9,700.00 89.66 332.56 5,964.15 -3,866.71 260.84 12.00 0.24 -12.00 271.00 9,950.00 90.20 2.56 5,964.47 -3,625.36 207.61 12.00 0.22 12.00 89.00 10,150.00 90.18 338.56 5,963.79 -3,429.51 175.04 12.00 -0.01 -12.00 270.00 10,400.00 . 92.16 8.50 5,958.55 -3,183.99 147.17 12.00 . 0.79 11.98 86.00 10,750.00 92.09 354.49 5,945.50 -2,835.22 156.27 4.00 -0.02 -4.00 270.00 11,000.00 90.00 4.27 5,940.93 -2,585.60 153.58 4.00 -0.84 3.91 102.00 11,400.00 88.34 348.35 5,946.77 -2,187.76 127.96 4.00 -0.41 -3.98 264.00 3/1812016 9:10:21AM Page 3 COMPASS 5000.1 Build 74 • • ConocoPhillips ,, }s>: ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 1L-18 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 L-18©130.00usft(1L-18) Site: Kuparuk 1L Pad North Reference: True Well: 1L-18 Survey Calculation Method: Minimum Curvature Wellbore: 1L-18A Design: 1L-18A 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) (°1100ft) (°) (usft) (usft) 7,300.00 42.75 151.97 5,862.96 -3,397.33 1,251.20 -2,782.23 0.00 0.00 5,945,070.86 541,193.22 TIP 7,385.00 42.78 151.80 5,925.36 -3,448.24 1,278.39 -2,831.24 0.14 -75.49 5,945,020.10 541,220.69 KOP 7,400.00 45.78 151.80 5,936.10 -3,457.46 1,283.34 -2,840.14 20.00 0.00 5,945,010.90 541,225.69 7,406.00 46.98 151.80 5,940.24 -3,461.29 1,285.39 -2,843.83 20.00 0.00 5,945,007.08 541,227.76 End 20 dls,Start 38 dls 7,500.00 82.70 151.80 5,979.56 -3,535.07 1,324.95 -2,914.97 38.00 0.00 5,944,933.53 541,267.70 7,519.21 90.00 151.80 5,980.78 -3,551.95 1,334.01 -2,931.26 38.00 0.00 5,944,916.69 541,276.84 4 7,589.21 90.00 178.40 5,980.78 -3,618.99 1,351.84 -2,980.23 38.00 90.00 5,944,849.75 541,295.04 End 38 dls,Start RSM 7,600.00 90.04 178.83 5,980.78 -3,629.78 1,352.10 -2,985.85 4.00 85.00 5,944,838.97 541,295.35 7,675.00 90.30 181.82 5,980.56 -3,704.77 1,351.68 -3,022.97 4.00 85.00 5,944,763.99 541,295.33 6 7,700.00 90.64 182.76 5,980.35 -3,729.75 1,350.68 -3,034.60 4.00 70.00 5,944,739.01 541,294.46 7,775.00 91.67 185.58 5,978.84 -3,804.52 1,345.23 -3,067.27 4.00 70.01 5,944,664.21 541,289.41 7 7,800.00 91.58 186.58 5,978.14 -3,829.37 1,342.59 -3,077.40 4.00 95.00 5,944,639.35 541,286.90 7,900.00 91.22 190.56 5,975.69 -3,928.21 1,327.70 -3,113.92 4.00 95.03 5,944,540.44 541,272.53 8,000.00 90.86 194.55 5,973.87 -4,025.78 1,305.97 -3,143.89 4.00 95.13 5,944,442.77 541,251.33 8,100.00 90.50 198.53 5,972.68 -4,121.62 1,277.51 -3,167.17 4.00 95.20 5,944,346.79 541,223.38 8 8,200.00 89.80 202.47 5,972.41 -4,215.27 1,242.50 -3,183.67 4.00 100.00 5,944,252.96 541,188.87 End RSM,Start 12 dls 8,300.00 87.74 214.29 5,974.56 -4,303.07 1,195.07 -3,186.50 12.00 100.00 5,944,164.92 541,141.91 8,375.00 86.25 223.18 5,978.50 -4,361.43 1,148.26 -3,175.14 12.00 99.75 5,944,106.32 541,095.41 10 8,400.00 86.36 226.18 5,980.11 -4,379.17 1,130.72 -3,168.82 12.00 88.00 5,944,088.49 541,077.97 8,500.00 86.89 238.19 5,986.02 -4,440.25 1,051.99 -3,131.18 12.00 87.81 5,944,026.99 540,999.58 8,550.00 87.21 244.19 5,988.59 -4,464.30 1,008.26 -3,105.33 12.00 87.10 5,944,002.71 540,955.97 11 8,600.00 87.96 250.15 5,990.70 -4,483.67 962.24 -3,075.16 12.00 83.00 5,943,983.10 540,910.06 8,700.00 89.51 262.06 5,992.92 -4,507.64 865.36 -3,003.25 12.00 82.75 5,943,958.63 540,813.33 8,750.00 90.29 268.00 5,993.00 -4,511.97 815.58 -2,962.29 12.00 82.48 5,943,954.03 540,763.57 12 8,800.00 90.29 274.00 5,992.75 -4,511.09 765.61 -2,918.58 12.00 90.00 5,943,954.64 540,713.60 8,900.00 90.28 286.00 5,992.25 -4,493.76 667.31 -2,824.78 12.00 90.03 5,943,971.46 540,615.22 13 9,000.00 95.31 296.91 5,987.36 -4,457.30 574.51 -2,726.19 12.00 65.00 5,944,007.41 540,522.24 14 9,100.00 95.20 308.96 5,978.16 -4,403.26 491.10 -2,626.93 12.00 90.00 5,944,061.01 540,438.55 9,175.00 94.96 318.00 5,971.51 -4,351.91 436.95 -2,554.36 12.00 91.11 5,944,112.07 540,384.13 15 9,200.00 94.43 320.96 5,969.46 -4,332.97 420.76 -2,530.87 12.00 100.00 5,944,130.92 540,367.84 9,290.00 92.45 331.59 5,964.04 -4,258.36 370.96 -2,450.44 12.00 100.24 5,944,205.26 540,317.66 16 9,300.00 92.24 332.78 5,963.63 -4,249.52 366.30 -2,441.99 12.00 100.00 5,944,214.07 540,312.95 9,390.00 90.33 343.41 5,961.61 -4,166.16 332.78 -2,371.28 12.00 100.05 5,944,297.24 540,278.99 17 9,400.00 90.22 344.60 5,961.56 -4,156.55 330.03 -2,364.09 12.00 95.00 5,944,306.84 540,276.19 9,500.00 89.18 356.56 5,962.09 -4,058.08 313.70 -2,300.71 12.00 95.01 5,944,405.21 540,259.33 3/18/2016 9:10:21AM Page 4 COMPASS 5000.1 Build 74 0 • NI,' ConocoPhillipsk`F-71.--3,-.71,7-.1 ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 1L-18 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1L-18 @ 130.00usft(1L-18) Site: Kuparuk 1L Pad North Reference: True Well: 1L-18 Survey Calculation Method: Minimum Curvature Wellbore: 1L-18A Design: 1 L-18A_wp03 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +Ni-S +EI-W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°M00ft) (°) (usft) (usft) 18 9,600.00 89.40 344.56 5,963.33 -3,959.62 297.33 -2,237.30 12.00 -89.00 5,944,503.57 540,242.44 9,700.00 89.66 332.56 5,964.15 -3,866.71 260.84 -2,159.25 12.00 -88.85 5,944,596.27 540,205.47 19 9,800.00 89.87 344.56 5,964.57 -3,773.80 224.36 -2,081.20 12.00 89.00 5,944,688.98 540,168.50 9,900.00 90.09 356.56 5,964.60 -3,675.34 207.99 -2,017.79 12.00 88.95 5,944,787.35 540,151.61 9,950.00 90.20 2.56 5,964.47 -3,625.36 207.61 -1,992.47 12.00 88.95 5,944,837.32 540,150.96 20 10,000.00 90.20 356.56 5,964.29 -3,575.39 207.22 -1,967.15 12.00 -90.00 5,944,887.28 540,150.31 10,100.00 90.19 344.56 5,963.95 -3,476.92 190.85 -1,903.74 12.00 -90.02 5,944,985.65 540,133.42 10,150.00 90.18 338.56 5,963.79 -3,429.51 175.04 -1,866.34 12.00 -90.06 5,945,032.97 540,117.36 21 10,200.00 90.60 344.54 5,963.44 -3,382.11 159.22 -1,828.94 12.00 86.00 5,945,080.29 540,101.29 10,300.00 91.41 356.52 5,961.68 -3,283.66 142.80 -1,765.50 12.00 86.04 5,945,178.63 540,084.35 10,400.00 92.16 8.50 5,958.55 -3,183.99 147.17 -1,719.44 12.00 86.25 5,945,278.32 540,088.19 End 12 dls,Start 4 dls 10,500.00 92.15 4.50 5,954.79 -3,084.72 158.48 -1,679.61 4.00 -90.00 5,945,377.63 540,098.97 10,600.00 92.14 0.50 5,951.05 -2,984.91 162.83 -1,633.47 4.00 -90.15 5,945,477.46 540,102.79 10,700.00 92.11 356.49 5,947.34 -2,885.03 160.20 -1,581.26 4.00 -90.30 5,945,577.31 540,099.64 10,750.00 92.09 354.49 5,945.50 -2,835.22 156.27 -1,552.95 4.00 -90.45 5,945,627.09 540,095.45 23 10,800.00 91.68 356.45 5,943.86 -2,785.41 152.33 -1,524.62 4.00 102.00 5,945,676.88 540,091.23 10,900.00 90.84 0.36 5,941.66 -2,685.49 149.55 -1,472.26 4.00 102.06 5,945,776.77 540,087.92 11,000.00 90.00 4.27 5,940.93 -2,585.60 153.58 -1,425.81 4.00 102.15 5,945,876.68 540,091.43 24 11,100.00 89.58 0.29 5,941.31 -2,485.70 157.57 -1,379.30 4.00 -96.00 5,945,976.59 540,094.88 11,200.00 89.16 356.31 5,942.41 -2,385.77 154.61 -1,326.78 4.00 -95.99 5,946,076.49 540,091.39 11,300.00 88.75 352.33 5,944.23 -2,286.29 144.72 -1,268.48 4.00 -95.94 5,946,175.90 540,080.98 11,400.00 88.34 348.35 5,946.77 -2,187.76 127.96 -1,204.69 4.00 -95.87 5,946,274.33 540,063.70 Planned TD at 11400.00 3/18/2016 9:10:21AM Page 5 COMPASS 5000.1 Build 74 • • ConocoPhillips ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 1L Pad 1L-18 1L-18A 1 L-18A_wp03 Travelling Cylinder Report 17 March, 2016 BAKER HUGHES • 0 ✓ Baker Hughes INTEQ Fail ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 1L-18 Project: Kuparuk River Unit TVD Reference: 1L-18©130.00usft(1L-18) Reference Site: Kuparuk 1L Pad MD Reference: 1L-18©130.00usft(1L-18) Site Error: 0.00 usft North Reference: True Reference Well: 1L-18 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 1L-18A Database: OAKEDMP2 Reference Design: 1 L-18A_wp03 Offset TVD Reference: Offset Datum Reference 1 L-18A_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: 7,300.00 to 11,400.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,327.00 usft Error Surface: Elliptical Conic Survey Tool Program Date 3/17/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description 200.00 7,300.00 1 L-18(1 L-18) GCT-MS Schlumberger GCT multishot 7,300.00 11,400.00 1 L-18A_wp03(1L-18A) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 11,400.00 6,076.77 23/8" 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 1L Pad 1L-13-1L-13-1L-13 Out of range 1L-13-1L-13A-1 L-13A_wp04 Out of range 1L-13-1 L-13AL1-1 L-13AL1 wp04 9,390.00 9,050.00 613.22 264.02 353.24 Pass-Major Risk 1L-17-1L-17-1L-17 Out of range 1L-17-1L-17A-1 L-17A_wp05 Out of range 1L-17-1L-17AL1-1 L-17AL1_wp04 Out of range 1L-18-1L-18-1L-18 7,399.99 7,400.00 0.40 3.80 -3.07 FAIL-Major Risk 1L-18-1 L-18AL1-1 L-18AL1_wp02 8,024.97 8,025.00 0.87 0.55 0.34 Pass-Minor 1/10 1L-23-1L-23-1L-23 Out of range 1L-24-1L-24-1L-24 Out of range 1L-24-1 L-24A-1 L-24A_wp03 Out of range 1L-24-1 L-24AL1-1 L-24AL1_wp01 Out of range 1L-25-1L-25-1L-25 8,625.00 7,675.00 1,138.29 240.90 900.88 Pass-Major Risk 1L-25-1 L-25A-1 L-25A 8,625.00 7,675.00 1,138.29 240.90 900.88 Pass-Major Risk 1L-25-1 L-25AL1-01-1 L-25AL1-01 8,625.00 7,675.00 1,138.29 240.90 900.88 Pass-Major Risk 1 L-25-1 L-25AL1-01 PB1-1 L-25AL1-01 PB1 8,625.00 7,675.00 1,138.29 240.90 900.88 Pass-Major Risk 1 L-25-1 L-25AL1-02-1 L-25AL1-02 8,625.00 7,675.00 1,138.29 240.90 900.88 Pass-Major Risk 1L-25-1 L-25AL1-02PB2-1 L-25AL1-02PB2 8,625.00 7,675.00 1,138.29 240.90 900.88 Pass-Major Risk 1L-25-1 L-25APB1-1 L-25APB1 8,625.00 7,675.00 1,138.29 240.90 900.88 Pass-Major Risk Offset Design Kuparuk 1L Pad- 1L-13-1 L-13AL1-1 L-13AL1_wp04 Offset Site Error: 0.00 usft Survey Program: 200-GCT-MS,7400-MWD,7480-MWD Rule Assigned:Major Risk Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface a Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +E/-w Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) ('I (usft) (usft) f7 (usft) (usft) (usft) 9,11468 6,106.83 9,725.00 6,010.71 40.94 45.44 -131.81 -4,958.16 5.47 2-11/16 743.44 270.36 481.12 Pass-Major Risk 9,125.00 6,105.91 9,675.00 6,005.58 40.93 45.02 -130.02 -4,909.48 -4.70 2-11/16 714.38 270.03 452.02 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 3/17/2016 2:07:39PM Page 2 COMPASS 5000.1 Build 74 h ea e,1 h O ,.�� 3. 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Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1L-18,5112/20153:27:48 PM SSSV:TRDP Last WO: 42.99 3/24/1991 Vemcal schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,487.0 5/8/2015 Rev Reason:TAG,MANDREL ORIENTATION hipshkf 5/12/2015 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread HANGER',3i.9 A :lilt' CONDUCTOR 16 15.062 43.0 122.0 122.0 62.50 H-40 WELDED agl, Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(L..Grade Top Thread SURFACE 95/8 8.921 42.0 4,120.6 3,566.5, 36.00 J-55 BTC Casing Description 00(in) 'ID(in) Top(ftKB) Set Depth(ftKB) 'Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6276 35.4 7,788.6 6,350.5 26.00 J-55 BTC-MOD Tubing Strings 161111412.21 • X.U0IghIMUMIMULAMILMIIILISSi Tubing Description String Ma...ID(in) Top(ftI40) Set Depth(ft. Depth(ND)(...Wt(Ibllt) Grade Top Connection TUBING 31/2 2.992 37.9 7,167.6 5,896.3 9.30 J-55 EUESrdABMOD Completion Details Nominal ID Top(ftKB) Top(ND)(ft5B)_Top Incl I") Item Des Corn (in) .AA/CONDUCTOR;43.0-122.0- 37.9 37.9 0.03 HANGER • 'FMC GEN IV TUBING HANGER 3.500 1,799.1 1,7812 20.09 SAFETY VLV CAMCO TRDP-4A SAFETY VALVE 2.812 7,102.6 5,848.9 43.07 PBR BAKER 10'STROKE PBR 3.000 7,116.3 5,858.9 43.11 PACKER BAKER HB RETRIEVABLE PACKER . 3.500' SAFEIYVLV:1,799.1 Fel _. 7,132.7 5,870.8 43.15 NIPPLE CAMCO D NIPPLE NO GO 2.750 7,166.7 5,895.6 43.24 SOS BAKER SHEAR OUT SUB 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(MB) (ftKB) 01 Des Corn Run Date ID(in) 7,626.0 6,232.1 43.09 FISH 1.5"OV w/RK Latch Lost Downhole 10/7/1991 10/7/1991 GAS LIFT:1,938.5 '111 Perforations&Slots Shot Den Top(TVD) Btm(TVD) (shots/( Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 7,244.0 7,298.0 5,951.9 5,991.5 C-4,1L-18 8/13/1991 6.0 APERF 2 1/8"EnerJet III;0 deg. ph 7,442.0 7,464.0 6,097.2 6,113.4 A-5,1L-18 6/12/1991 4.0 (PERF 4.5"HSO Csg Gun;180 deg.ph 7,540.0 7,550.0 6,169.2 6,176.5 A-4,1L-18 6/12/1991 4.0 IPERF 41/2"HSD Csg Gun; • 180 deg.phasing; SURFACE;420.4,12(1.6-+ - Covered W/fill Mandrel Inserts St ati on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn GAS LIFT;7,045.7 il 1 1,938.5 1,911.5 McMurry FMHO l 1 GAS LIFT DMY BK2 0.000 0.0 9/24/1991 1:30 -• 2 7,045.7 5,807.3 MACCO SPM-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 1/25/1992 5:00 Notes:General&Safety End Date Annotation 10/4/2010 NOTE:View Schematic w/Alaska Schematic9.0 PBR;7,102.6 MN.411n ., PACKER;7,118.3 ambit NIPPLE;7,132.7 I SOS;7.166.7 APERF;7,244.0.7.298.0 .-- (PERF;7,442.0.7,464.0 .- IPERF;7.540.0-7.550.0 FISH;7,626.0 PRODUCTION;35.4-7,768.6 110 S 1L-18 Proposed CTD Schematic Modified by RLP 4-1-16 3-1/2"Camco TRDP-4A SSSV @ 1799'MD(2.812'min ID) 16"62#H-40 shoe @ 122'MD 3-1/2"9.3#J-55 EUE 8rd Tubing to surface 9-5/8"36#J-55 shoe @ 4121'MD 3-1/2"McMurry gas lift mandrel @ 1939' 3-1/2"Macco gas lift mandrel @ 7046' Baker 3-1/2"PBR @ 7102'MD(3.0"ID) Baker HB packer @ 7116'MD(3.5"ID) 3-1/2"Camco D landing nipple @ 7133"MD(2.75"min ID,No-Go) 1J rte! Baker SOS @ 7167'MD 3-1/2"tubing tail @ 7162'PDC C-sand perfs 7244'-7298'MD 1 L-18AL1 wp02(South) TD©10,200'MD KOP @ 7385'MD ILat#2 I L-18A wp03(NW) TD @ 11,400'MD ........... Liner Billet©8000'MD A-sand perfs 7442'-7464'MD I Lat#1 7540'-7550'MD 7"26#J-55 shoe @ 7789'MD RECEWED STATE OF ALASKA ALAIL OIL AND GAS CONSERVATION COMM N APR 0 7 2016 PERMIT TO DRILL 20 AAC 25.005 AOGCC la.Type of Work: 1 b.Proposed Well Class: Exploratory-Gas ❑ Service- WAG ❑✓ . Service-Disp ❑ lc.Specify if well is proposed for: Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development-Oil ❑ Service- Winj ❑ Single Zone ❑., - Coalbed Gas ❑ Gas Hydrates ❑ Redrill 24 Reentry❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska Inc • Bond No. 59-52-180 KRU 1L-18A 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 11,400' TVD: 6,07 ' Kuparuk River Field . 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number Kuparuk Oil Pool Surface: 507'FNL,143'FEL,Sec.31,T11N,R10E,UM ADL 25659 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 4533'FNL,4131'FEL,Sec.32,T11N,R10E,UM ALK 2585 8/7/2016 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 2695'FNL,23'FEL,Sec.31,T11N,R10E,UM 2560 12,720' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MS (ft): 130 15.Distance to Nearest Well Open Surface:x- 539924 y- 5,948,461 Zone- 4 GL Elevation above M'.L(ft): 87 to Same Pool: 1L-13AL1,610' 16.Deviated wells: Kickoff depth: 7,385 feet 17.Maximum Potential r essures in psig(see 20 AAC 25.035) Maximum Hole Angle: 950 degrees Downhole: 3,702 psi. . Surface: 3,097 psig 18.Casing Program: Specifications Top eking Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD • MD TVD (including stage data) i 3" 2.375" 4.7# L-80 ST-L 3,400' 8, A0' . 104' 11,400' 6,077' slotted liner 19. PRESENT WELL CONDITION SUMMARY(To be comp e -d . Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): t.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): 7,800' 6,359' none 7,700' 6,285' 7,626' - Casing Length Size v\ Cement Volume MD TVD Conductor/Structural 122' 16" , 235 sx AS I 122' _ 122' Surface 3,991' 9-5/8" ' 800 sx PF E&500 sx Premium 4,121' 3,567' Production 7,659' 7",// 250 sx Class G 7,789' 6,351' 1 - I Perforation Depth MD(ft): 7244'-7298',744 '-7464', Perforation Depth TVD(ft): 5952'-5992',6097'-6113', 7540'-7550' 6169'-6177' 20. Attachments: Property Plat ❑ Be' Sk`.# ❑ Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis Diverter - etch ❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date C ///1/ 22. I hereby certify that the foregoing is true and the . ocedure approved herein will not R.Phillips @265-6312 be deviated from without prior written approval. Contact Email ron.I.phillipsc cop.com ce Printed Name K.Starck Title CTD Engineer / Signature �� Phone 263-4093 Date VA 40 /`� 1, "_"' Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: a'G— QSe 50- 019—clUIS `01 —O(0 Date: requirements. Conditions of approval: If,ox is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: ❑ Other: Samples req'd: Yes❑ No❑ Mud log req'd:Yes❑ No❑ H2S measures: Yes❑ No❑ Directional svy req'd:Yes❑ No❑ Spacing exception req'd: Yes❑ No❑ Inclination-only svy req'd:Yes❑ No❑ Post initial injection MIT req'd:Yes El No❑ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: U J rA Submit Form and Oiprtirailf4rnEths Form 10-401(Revised 11/2015) from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate licate • • ConocoPhillips p Alaska / P.O. BOX 100360 RECEIVED !� ANCHORAGE,ALASKA 99510-0360 APR 0 7 2016 April 6, 2016 AOGGC Commissioner-State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill a dual-lateral out of the Kuparuk Well 1L-18 using the coiled tubing drilling rig, Nabors CDR2-AC. The work is scheduled to begin August 2016. The objective will be to drill laterals KRU 1L-18A and 1 L-18AL1 targeting the Kuparuk A5-sands. A separate sundry application was submitted to plug the KRU 1 L-18 (PTD 191- 035) perfs to allow these laterals to be drilled. As detailed in the Summary for plugging Sundry, ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the NC-sand perfs in 1L-18. Attached to this application are the following documents: — 10-401 Applications for 1 L-18A and 1 L-18AL1 — Detailed Summary of Operations — Directional Plans for 1 L-18A and 1 L-18AL1 — Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-265-6312. Sincerely, der' eg4 Ron Phillips ConocoPhillips Alaska Coiled Tubing Drilling Engineer i 11110 Kuparuk CTD Laterals NABOAS ALASKA k 0 1 L-1 8A & 1 L-1 8AL1 CDR ConocePhillips 4. Application for Permit to Drill Document 2I1t 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(f)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AA C 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 6 14. Disposal of Drilling Mud and Cuttings 6 (Requirements of 20 AAC 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 7 (Requirements of 20 AAC 25.050(b)) 7 16. Quarter Mile Injection Review (for injection wells only) 7 (Requirements of 20 AAC 25.402) 7 17. Attachments 7 Attachment 1: Directional Plans for 1L-18A and AL1 laterals 7 Attachment 2: Current Well Schematic for 1L-18 7 Attachment 3: Proposed Well Schematic for 1L-18A and AL1 laterals 7 Page 1 of 7 April 6, 2016 • PTD Application: 1L-18A & 1 L-18AL1 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document are 1L-18A& 1L-18AL1. All laterals will be classified as "Service-Wag"wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 1 L-18A & 1 L-18AL1. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,600 psi. Using the maximum formation pressure in the area of 3,702 psi in 1L-16 (i.e. 12.0 ppg EMW), the maximum potential surface pressure in 1 L-18, assuming a gas gradient of 0.1 psi/ft, would be 3,097 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 1L-18 was measured to be 3,143 psi (10.0 ppg EMW) on 5/10/2014. All of the wells in the 1 L-18 vicinity are between 9.3 ppg and 10.6 ppg. The combined A and C sand SBHP readings suggest pressures will be close to 10 ppg. The maximum downhole pressure in the 1L-18 vicinity, is the 1L-16 injector at 3702 psi or 12.0 ppg EMW. The 1L-16 injector is on the other side of the 1L-15 and 1L-13 producers, which are ata 9.4 ppg and 9.8 ppg. There is also a large sealing fault between the 1L-16 injector and the 1L-18 well, so we do not expect to see pressures over 10.6 ppg EMW. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) None of the offset injection wells to 1 L-18 have ever injected gas, so there is a low probability of encountering free gas while drilling the 1 L-18 laterals. Nevertheless, 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 1 L-18 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 1L-18 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 7 April 6, 2016 • PTD Application: 1 L-1 8A & 1 L-1 8AL1 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 TVD TVD Liner Details IL-18A 8,000' 11,400' 6,104' 6,077' 23/", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 1 L-1 8AL1 7,157' 10,200' 5,889' 6,096' 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 (ppf) TVD TVD psi psi Conductor 16" 62.5 H-40 Welded 0' 122' 0' 122' 1,640 670 Surface 9-5/8" 36 J-55 BTC 0' 4121' 0' 3,567' 3,520 2,020 Production 7" 26 J-55 BTC-MOD 0' 7789' 0' 6,351' 4,980 4,320 Tubing 3-1/2" 9.3 J-55 EUE 0' 7168' 0 5,897' 6,980 7,400 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride-based FloVis mud (8.6 ppg) — Drilling operations: Chloride-based FloVis mud (8.6 ppg). While 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 11.8 ppg NaBr completion fluid in order to 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 1 L-18 laterals we will target a constant BHP of 11.8 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 7 April 6, 2016 • PTD Application: 1L-18A & 1 L-18AL1 Pressure at the 1L-18 Window (7,385' MD, 6055' TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure (9.9 ppg) 3117 psi 3117 psi Mud Hydrostatic (8.6 ppg) 2708 psi 2708 psi Annular friction (i.e. ECD, 0.080 psi/ft) 591 psi 0 psi Mud + ECD Combined 3299 psi 2708 psi (no choke pressure) (overbalanced —182 psi) (underbalanced —409 psi) Target BHP at Window(11.8 ppg) 3715 psi 3715 psi Choke Pressure Required to Maintain 417 psi 1008 psi Target BHP 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is 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 1L-18 was originally drilled and completed in 1991 with 3'/2"tubing and 7"production casing as an A-sand and C-sand, Kuparuk injector. Prior to CTD operations,the 3-1/2"tubing tail will be perforated and the D nipple at 7,133' MD will be milled out to a 2.80" ID. The existing A/C-sand perfs will be squeezed with cement to provide a means to kick out of the 7"casing. Following the cement squeeze Nabors CDR2-AC will drill a pilot hole to 7,415' MD and set a mechanical whipstock in the 2.80"pilot hole to kick off at 7,385' MD. Two laterals will be drilled: one to the northwest and one to the south of the parent well with the laterals targeting the Kuparuk A5 sand. Both laterals will be completed with 2-3/8" slotted liner from TD with the last lateral liner top located inside the 3-1/2"tubing tail. Page 4 of 7 April 6, 2016 PTD Application: 1 L-18A & 1 L-1 8AL1 Pre-CTD Work 1. RU Slickline: dummy off gas lift mandrels and pressure test. 2. RU E-line: Shoot 2' of holes in the 3W tubing tail at 7128' MD. 3. RU Pumping Unit: perform injectivity test down the tubing. 4. RU Service Coil: Mill out D nipple and cement squeeze the NC-sand perforations up to the perforations in the tubing tail. 5. RU Slickline: Tag top of cement and log. 6. Prep site for Nabors CDR2-AC and set BPV. Rig Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 1L-18A Sidetrack (A5 sand - Northwest) a. Drill 2.80" high-side pilot hole through cement to 7,415' MD b. Caliper pilot hole c. Set top of whipstock at 7,385' MD d. Mill 2.80" window at 7,385' MD. e. Drill 3" bi-center lateral to TD of 11,400' MD. f. Run 2%" slotted liner with an aluminum billet from TD up to 8,000' MD. 3. 1L-18AL1 Lateral (A5 sand - South) a. Kick off of the aluminum billet at 8,000' MD. b. Drill 3" bi-center lateral to TD of 10,200' MD. c. Run 2%" slotted liner with deployment sleeve from TD up to 7,157' MD. 4. Freeze protect, set BPV, ND BOPE, and RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain SBHP 3. Return to injection Page 5 of 7 April 6, 2016 • PTD Application: 1 L-18A & 1 L-18AL1 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 undeployment, the steps listed above are observed, only in reverse. Liner Running — The 1 L-18A laterals will be displaced to an overbalancing fluid (11.8ppg NaBr) prior to running liner. See "Drilling Fluids" section for more details. — While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18 or 1B disposal facilities) or Prudhoe DS-4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). Page 6 of 7 April 6, 2016 PTD Application: 1L-18A & 1 L-18AL1 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) Laterestall� IL-18A 12,720' 1 L-18AL1 10,800' — Distance to Nearest Well within Pool Lateral larre- 81is:e Well 1L-18A 610' 1L-13AL1 1 L-18AL1 670' 1L-25AL1-02 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) There are two wells within '/4-mile of the 1 L-18A and 1 L-18AL1 laterals. Well 1L-18A will be a Kuparuk A-sand injector and both wells within a quarter mile are Kuparuk C-sand producers. 1L-18 (mother bore) Injector • Classified as a "Normal Well" • The well is completed with 3.5" 9.3#J-55 tubing and 7" 26#J-55 production casing. • Packer located at 7116' MD which is located less than 200' from the top of the perforations. • A-sand perforations: C: 7244' - 7298' MD, A: 7442' -7464' MD, and A: 7540' - 7550' MD • Well is currently SI for Pre-CTD well work t Plug and abandoned the A and C sand perfs to allow the well to be sidetracked. This well will be a A5-sand injector only. • Production casing was cemented with 250 sx of Class "G" cement. The proposed kick off point for the CTD sidetrack is between the perforations and should not compromise existing conformance. 1 L-13AL1 (producer), —610' away from 1L-18A lateral to the southwest • Classified as a "Normal Well" • The well is completed with 3.5" 9.3#J-55 tubing and 7" 26#J-55 production casing. • Packer located at 7277' MD which is located less than 200' from the top of the perforations. • A/C-sand perforations: C4: 7417' -7485' MD, A5: 7612' -7638' MD, and A5: 7719' -7729' MD • Well is currently SI for Pre-CTD well work to Plug and abandoned the A and C sand perfs to allow the well to be sidetracked. This well will be a C-sand producer only. • Production casing was cemented with 250 sx Class 'G' 1L-25AL1-02 (producer), —670' away from 1L-18AL1 lateral to the south • Classified as a "Normal Well" • Well is completed with 3.5" 9.3#J-55 tubing and 7" 26#J-55 production casing. • Packers located at 8692' MD which is located less than 200' from the top of the perforations. • This well is a C-sand producer only. • 2-3/8" Slotted liner form 8838' MD to 10,374' MD. • Production casing was cemented with 250 sx Class 'G' 17. Attachments Attachment 1: Directional Plans for 1L-18A and AL1 laterals Attachment 2: Current Well Schematic for 1L-18 Attachment 3: Proposed Well Schematic for 1L-18A and AL1 laterals Page 7 of 7 April 6, 2016 • • ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 1L Pad 1 L-18 1 L-18AL1 Plan: 1 L-18AL1 wp02 Standard Planning Report 18 March, 2016 Irta BAKER HUGHES y ConocoPhillips • Fail ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 1L-18 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 L-18 @ 130.00usft(1L-18) Site: Kuparuk 1L Pad North Reference: True Well: 1L-18 Survey Calculation Method: Minimum Curvature Wellbore: 1 L-18AL1 Design: 1 L-18AL1_wp02 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 1L Pad Site Position: Northing: 5,949,190.90usft Latitude: 70°16'19.650 N From: Map Easting: 539,916.78 usft Longitude: 149°40'37.763 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.30 ° Well 1L-18 Well Position +N/-S 0.00 usft Northing: 5,948,461.17 usft Latitude: 70°16'12.472 N +El-W 0.00 usft Easting: 539,924.15 usft Longitude: 149°40'37.662 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1L-18AL1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BGGM2015 7/1/2016 18.40 80.93 57,492 Design 1L-18AL1_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,000.00 Vertical Section: Depth From(TVD) +N/-S +El-W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 151.81 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) (°/100ft) (°/100ft) (°) Target 8,000.00 90.86 194.55 5,973.87 -4,025.78 1,305.97 0.00 0.00 0.00 0.00 8,500.00 90.86 134.54 5,966.33 -4,485.92 1,433.22 12.00 0.00 -12.00 -90.00 8,875.00 90.08 89.54 5,963.26 -4,623.04 1,771.93 12.00 -0.21 -12.00 -91.00 9,075.00 89.66 113.54 5,963.72 -4,662.76 1,966.46 12.00 -0.21 12.00 91.00 9,275.00 87.15 137.42 5,969.29 -4,777.94 2,128.08 12.00 -1.25 11.95 96.00 9,475.00 89.24 113.50 5,975.58 -4,893.05 2,289.73 12.00 1.05 -11.96 -85.00 9,775.00 89.87 149.49 5,977.90 -5,088.56 2,510.74 12.00 0.21 12.00 89.00 10,200.00 93.43 98.59 5,965.67 -5,318.68 2,851.19 12.00 0.84 -11.99 -86.00 3/18/2016 9:11:55AM Page 2 COMPASS 5000.1 Build 74 • ConocoPhillips1,13 dTV ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 1 L-18 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1L-18 @ 130.00usft(1L-18) Site: Kuparuk 1L Pad North Reference: True Well: 1 L-18 Survey Calculation Method: Minimum Curvature Wellbore: 1 L-18AL1 Design: 1 L-18AL1_wp02 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (0) (0) (usft) (usft) (usft) (usft) (°/100ft) (°) (usft) (usft) 8,000.00 90.86 194.55 5,973.87 -4,025.78 1,305.97 4,165.14 0.00 0.00 5,944,442.77 541,251.33 TIP/KOP 8,100.00 90.86 182.54 5,972.36 -4,124.48 1,291.14 4,245.13 12.00 -89.91 5,944,344.00 541,237.02 8,200.00 90.86 170.54 5,970.85 -4,224.10 1,297.16 4,335.77 12.00 -89.91 5,944,244.42 541,243.57 8,300.00 90.86 158.54 5,969.35 -4,320.30 1,323.76 4,433.12 12.00 -89.91 5,944,148.38 541,270.68 8,400.00 90.86 146.54 5,967.84 -4,408.86 1,369.78 4,532.92 12.00 -89.91 5,944,060.07 541,317.16 8,500.00 90.86 134.54 5,966.33 -4,485.92 1,433.22 4,630.80 12.00 -89.91 5,943,983.36 541,381.00 Start 12 dls 8,600.00 90.65 122.54 5,965.01 -4,548.10 1,511.28 4,722.49 12.00 -90.92 5,943,921.60 541,459.39 8,700.00 90.44 110.54 5,964.05 -4,592.70 1,600.58 4,803.99 12.00 -90.94 5,943,877.48 541,548.91 8,800.00 90.23 98.54 5,963.46 -4,617.76 1,697.20 4,871.73 12.00 -90.96 5,943,852.93 541,645.65 8,875.00 90.08 89.54 5,963.26 -4,623.04 1,771.93 4,911.69 12.00 -90.99 5,943,848.05 541,720.40 3 8,900.00 90.02 92.54 5,963.24 -4,623.50 1,796.93 4,923.90 12.00 91.00 5,943,847.72 541,745.40 9,000.00 89.82 104.54 5,963.37 -4,638.32 1,895.64 4,983.60 12.00 91.00 5,943,833.42 541,844.17 9,075.00 89.66 113.54 5,963.72 -4,662.76 1,966.46 5,038.61 12.00 91.02 5,943,809.36 541,915.12 4 9,100.00 89.34 116.52 5,963.94 -4,673.34 1,989.11 5,058.63 12.00 96.01 5,943,798.90 541,937.82 9,200.00 88.09 128.46 5,966.17 -4,726.95 2,073.28 5,145.64 12.00 96.11 5,943,745.75 542,022.27 9,275.00 87.15 137.42 5,969.29 -4,777.94 2,128.08 5,216.48 12.00 96.17 5,943,695.05 542,077.33 5 9,300.00 87.41 134.43 5,970.47 -4,795.88 2,145.45 5,240.49 12.00 -85.07 5,943,677.21 542,094.80 9,400.00 88.46 122.47 5,974.08 -4,857.90 2,223.58 5,332.07 12.00 -85.23 5,943,615.61 542,173.24 9,475.00 89.24 113.50 5,975.58 -4,893.05 2,289.73 5,394.30 12.00 -85.10 5,943,580.82 542,239.57 6 9,500.00 89.30 116.50 5,975.90 -4,903.61 2,312.38 5,414.31 12.00 89.02 5,943,570.38 542,262.28 9,600.00 89.50 128.50 5,976.95 -4,957.23 2,396.56 5,501.35 12.00 89.07 5,943,517.20 542,346.74 9,700.00 89.71 140.49 5,977.63 -5,027.19 2,467.76 5,596.64 12.00 89.04 5,943,447.63 542,418.30 9,775.00 89.87 149.49 5,977.90 -5,088.56 2,510.74 5,671.03 12.00 89.02 5,943,386.50 542,461.60 7 9,800.00 90.08 146.50 5,977.91 -5,109.75 2,523.99 5,695.98 12.00 -86.00 5,943,365.38 542,474.96 9,900.00 90.92 134.53 5,977.04 -5,186.79 2,587.46 5,793.86 12.00 -85.96 5,943,288.69 542,538.83 10,000.00 91.75 122.56 5,974.71 -5,248.97 2,665.51 5,885.54 12.00 -85.88 5,943,226.93 542,617.20 10,100.00 92.59 110.58 5,970.92 -5,293.58 2,754.72 5,967.00 12.00 -85.79 5,943,182.79 542,706.64 10,200.00 93.43 98.59 5,965.67 -5,318.68 2,851.19 6,034.70 12.00 -85.70 5,943,158.21 542,803.23 Planned TD at 10200.00 3/18/2016 9.11:55AM Page 3 COMPASS 5000.1 Build 74 • ConocoPhillips ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 1L Pad 1L-18 1 L-18AL1 1 L-18AL1_wp02 Travelling Cylinder Report 17 March, 2016 r' 1 BAKER HUGHES • Baker Hughes INTEQ • Vial ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 1 L-18 Project: Kuparuk River Unit ND Reference: 1L-18 @ 130.00usft(1L-18) Reference Site: Kuparuk 1L Pad MD Reference: 1L-18 @ 130.00usft(1L-18) Site Error: 0.00 usft North Reference: True Reference Well: 1 L-18 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 1L-18AL1 Database: OAKEDMP2 Reference Design: 1L-18AL1_wp02 Offset TVD Reference: Offset Datum Reference 1L-18AL1_wp02 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 8,000.00 to 10,200.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,207.00 usft Error Surface: Elliptical Conic Survey Tool Program Date 3/17/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description 200.00 7,300.00 1L-18(1L-18) GCT-MS Schlumberger GCT multishot 7,300.00 8,000.00 1 L-18A_wp03(1L-18A) MWD MWD-Standard 8,000.00 10,200.00 1 L-18AL1_wp02(1L-18AL1) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name C') (") 10,200.00 6,095.67 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 1L Pad 1L-13-IL-13-1L-13 Out of range 1L-13-1L-13A-1 L-13A_wp04 Out of range 1L-13-1 L-13AL1-1 L-13AL1_wp04 Out of range 1 L 17 1 L 17 1L 17 Out of range 1L-17-1L-17A-1 L-17A_wp05 Out of range 1L-17-1 L-17AL1-1 L-17AL1_wp04 Out of range 1L-18-1L-18A-1 L-18A_wp03 8,000.00 8,000.00 0.00 0.34 -0.22 FAIL-Minor 1/10 1L-23-1 L-23-1 L-23 Out of range 1 L-24-1L-24-1 L-24 Out of range 1L-24-1 L-24A-1 L-24A_wp03 Out of range 1L-24-1 L-24AL1-1 L-24AL1_wp01 Out of range 1 L-25-1L-25-1L-25 8,658.93 7,875.00 1,121.36 258.93 867.49 Pass-Major Risk 1 L-25-1 L-25A-1 L-25A 8,658.93 7,875.00 1,121.36 258.93 867.49 Pass-Major Risk 1 L-25-1 L-25AL1-01-1 L-25AL1-01 10,050.00 9,855.00 1,079.78 304.93 780.85 Pass-Major Risk 1 L-25-1 L-25AL1-01 PB1-1 L-25AL1-01 PB1 8,658.93 7,875.00 1,121.36 258.93 867.49 Pass-Major Risk 1L-25-1 L-25AL1-02-1 L-25AL1-02 10,150.00 10,374.00 678.28 295.18 390.67 Pass-Major Risk 1 L-25-1 L-25AL1-02PB2-1 L-25AL1-02PB2 10,185.75 10,397.00 667.41 292.18 385.65 Pass-Major Risk 1 L-25-1 L-25APB1-1 L-25APB1 8,658.93 7,875.00 1,121.36 258.93 867.49 Pass-Major Risk 1 L-26-1 L-26-1 L-26 Out of range 1 L-26-1 L-26A-1 L-26A Out of range Offset Design Kuparuk 1L Pad- 1L-18-1L-18A-1 L-18A_wp03 Offset Site Error: 0.00 usft Survey Program: 200-GCT-MS,7300-MWD 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 +N/-S +E/-W Hole Size Centre Distance Deviation (usft) (usft) (usft) (tisk) (usft) (usft) Fl (usft) (usft) CI (usft) (usft) (usft) CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 3/17/2016 11:48:16AM Page 2 COMPASS 5000.1 Build 74 S Ii M 8 m N _I `11. e o N * ` -"8 SO l'NA I-'n-- o ^ N 0 Q O E'1 N ��• O 0 .N 'N O 0 0 O i'1 0 a a. 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O a Fe J N Am WJ >9 lN10 h '. _ - _ a u = o m .3.. .<_� oo ca3- F.. _ _ .., . > r, O ... i„,-,:,,,t., ... ; .•ter t( p r I Jpr 1 0 > - 1 o i • 7FS J fu i v C. d � r `, I o • C 'itL c 0 � / -o U i _ / 0 ' 0 0 o 0 o O o >o 0 0 0 0 0 0 0 0 0 0 0 o a o 0 8 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 00 0 0 0 001 C '� , N N N N N N b b r r U 0 (u!jgsn OOb)(+)u oN/(-)ginos A.' KUP INJ . 1 L-18 ConocoPhillips I -ti Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status ncl(') MD(0813) Act atm(ftKB) ,,,,,,,,,IRIl,p, 500292214500 KUPARUK RIVER UNIT INJ 44.79 3,200.00 7,800.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft( Rig Release Date 1L-18,5/12/2015327:48 PM SSSV:TRDP Last WO: 42.991 3/24/1991 Vortical schematic(actual) Annotation Depth(ftKB) End Date .Annotation Last Mod By End Date Last Tag.SLM 7,487.0 5/8/2015 Rev Reason:TAG,MANDREL ORIENTATION hipshkf 5/12/2015 ............................................................................................................. Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...Grade Top Thread ''''i CONDUCTOR 16 15.062 43.0 122.0 122.0 62.50 H-40 WELDED HANGER 37.8 I . Casing Description OD g p (in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread SURFACE 9 5/8 8.921 42.0 4,120.6 3,566.5 36.00 J-55 BTC Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread PRODUCTION 7 6.276 35.4 7,788.6 6,350.5 26.00 1-55 BTC-MOD Tubing Strings •i I ^• - ii Tubing Description String Ma...ID(in) Top(080) Set Depth(1t..Set Depth(ND)(.,.Wt(113/ft) Grade Top Connection TUBING 3112 2.992 37.9 7,167.6 5,896.3 9.30 J-55 EUEBrdABMOD Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) AM CONDUCTOR;43.0-122.0' ' I II 37.9 37.9 0.03 HANGER FMC GEN IV TUBING HANGER 3.500 1,799.1 1,781.2 20.09 SAFETY VLV CAMCO TRDP-4A SAFETY VALVE 2.812 7,102.6 5,848.9 43.07 PBR BAKER 10'STROKE PBR 3.000 7,116.3 5,858.9 43.11 PACKER BAKER HB RETRIEVABLE PACKER 3.500 SAFETY VLV;1,799.1 1 Il ,; 7,132.7 5,870.8 43.15 NIPPLE CAMCO D NIPPLE NO GO 2.750 7,166.7 5,895.6 4324 SOS BAKER SHEAR OUT SUB 2.992 Other in Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(EKG) (ftKB) (°) Des Cam Run Date 1018)92' 7,626.0 6,232.1 43.09 FISH 1 5"OV w/RK Latch Lost Downhole 10/7/1991 10/7/1991 GAS LIFT,1,938.5111 Perforations&Slots Shot Dens Top(ND) Btm(TVG) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 7,244.0 7,298.0 5,951.9 5,991.5 C-4,1L-18 8/13/1991 6.0 APERF 2 1/8"EnerJet 18;0 deg. ph 7,442.0 7,464.0 6,097.2 6,113.4 A-5,1L-18 6/12/1991 4.0 IPERF 4.5"HSD Csg Gun;180 deg.ph 7,540.0 7,550.0 6,169.2 6,176.5 A-4,1L-18 6/12/1991 4.0 (PERF 41/2"HSD Csg Gun; 180 deg.phasing; SURFACE;42.0-4,120.6--e Covered wl fill Mandrel Inserts St atl on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD In) Sate Type Type (in) (psi( Run Date Com GAS LIFT;7,045.7 j' 1,938.5 1,911.5 McMurry FMHO 1 GAS LIFT DMY BK2 0.000 0.0 9/24/1991 1:30 2 7,045.7 5,807.3 MACCO SPM-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 1/25/1992 5:00 Notes:General 8 Safety End Date Annotation 10/4/2010 NOTE:View Schematic w/Alaska Schematic9.0 IMI PBR:7,1026 in PACKER;7.116.3 NIPPLE;21327 . t, I SOS;7,166.7 APERF;7,244.07,298.0 —a (PERF;7,442.0-7,464.0 IPERF;7,540.0-7,550.0 —. FISH;7,626.3 PRODUCTION;35.47,788.6 • • 1L-18 Proposed CTD Schematic Modified by RLP 4-1-16 3-1/2"Camco TRDP-4A SSSV @ 1799'MD(2.812'min ID) 16"62#H-40 shoe ©122'MD 3-1/2"9.3#J-55 EUE 8rd Tubing to surface 9-5/8"36#J-55 shoe @ 4121'MD ` 3-1/2"McMurry gas lift mandrel @ 1939' 3-1/2"Macco gas lift mandrel @ 7046' Baker 3-1/2"PBR @ 7102'MD(3.0"ID) Baker HB packer @ 7116'MD(3.5"ID) 3-1/2"Camco D landing nipple @ 7133"MD(2.75"min ID,No-Go) mar Baker SOS @ 7167'MD 3-1/2"tubing tail @ 7162°PDC C-sand perfs 7244'-7298'MD 1 L-18AL1 wp02(South) TD @ 10,200'MD KOP @ 7385'MD ILat#2 I 1L-18Awp03(NW) TD 11,400'MD _______r= Liner Billet@ 8000'MD A-sand perfs - T __ 7442'-7464'MD 1Lat#1 7540'-7550'MD N~ 7"26#J-55 shoe @ 7789'MD • • • loepp, Victoria T (DOA) From: Phillips, Ron L <Ron.L.Phillips@conocophillips.com> Sent: Tuesday,April 19, 2016 3:21 PM To: Loepp,Victoria T(DOA) Subject: RE: KRU 1L-18A(PTD 216-056)& KRU 1L-25AL(PTD 216-064) Attachments: 1L-18 injector area of review.xlsx Follow Up Flag: Follow up Flag Status: Flagged Victoria, Please let me know if you need anything else. Thanks, Ron L. Phillips Senior CTD Engineer ConocoPhillips Alaska Phone 265-6312 Cell 317-5092 From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Monday,April 18,2016 9:23 AM To: Phillips, Ron L<Ron.L.Phillips@conocophillips.com> Subject: [EXTERNAL]KRU 1L-18A(PTD 216-056)& KRU 1L-25AL(PTD 216-064) Ron, For wells within the%mile AOR please provide information as outlined in the attached table.You may email the completed table to me when finished. 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.Loecle alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.gov 1 I • Bettis, Patricia K (DOA) From: Phillips, Ron L <Ron.L.Phillips@conocophillips.com> Sent: Friday, April 15, 2016 11:32 AM To: Bettis, Patricia K (DOA) Cc: Eller,J Gary Subject: RE: KRU 1L-18A and KRU 1L-18AL1: Permit to Drill Application Patricia, We do not plan to pre-produce past the normal flowback to clean up the KRU 1L-18A well, but if we find oil in an upswept area we may elect to pre-produce it and submit the appropriate paperwork. Thanks, Ron L. Phillips Senior CTD Engineer ConocoPhillips Alaska Phone 265-6312 Cell 317-5092 From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Friday,April 15, 2016 10:38 AM To: Phillips, Ron L<Ron.L.Phillips@conocophillips.com> Subject: [EXTERNAL]KRU 1L-18A and KRU 1L-18AL1: Permit to Drill Application Good morning Ron, Does ConocoPhillips plan to pre-produce the wells; and, if so,for what duration? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Friday, April 15, 2016 10:38 AM To: Ron.L.Phillips@conocophillips.com Subject: KRU 1L-18A and KRU 1L-18AL1: Permit to Drill Application Good morning Ron, Does ConocoPhillips plan to pre-produce the wells; and, if so,for what duration? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Wednesday, April 13, 2016 9:29 AM To: Ron.L.Phillips@conocophillips.com Subject: KRU 1L-18A (PTD 216-056): Permit to Drill Application Good morning Ron, For the application, the Baker Hughes Standard Planning Report submitted was for KRU 1L-18AL1, not KRU 1L-18A. The AOGCC has not received the permit to drill application for KRU 1L-18AL1 as of yet. Please submit the correct Baker Hughes proposed wellbore directional survey for KRU 1L-18A. This may be sent to me via email. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • I TRANSMITTAL LETTER CHECKLIST WELL NAME: JA k) , I L- )a fr PTD: .21(o -OSc Development /Service Exploratory Stratigraphic Test Non-Conventional FIELD: ZW,j'- POOL: 211/kkr 4 K c bk ir(ftr ate' 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. , API No. 50- - - - (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 C- m N a) 0 y. Q Ci' 0. ▪ C o. a aj, Q .0 0. � a' v C a) o c o. ; : : p ; a; O Z -o c, . E o • L 0, _ , uJ U) co p -a • n. 'c c E O Z: .0 3. ; c. E: �, W. �, coo c; p C ; N 3 a), ,_ 3; : o) a o . v n ' c o N 0 E, o . 3. of a 3, , V) •-. ca , p " ' 7' �� 2' o L, a) 4 a- Uy 'V p. .c" V '- W o. N ✓ O. 1".'). N E a a E. a 2. �- N, C. Ol > Y, 0' o co co' a p o h� 0 < C �: , N: D, C o. LO O, CO �: O' p , .N.' N' N •y 0]. N y; -o: 1 Y' 0 Q' ' N. c .0 a-. �: 7 O. a 0. �. O, a au co • �' �, Y' c o >, -I a. ,, c o; 3. o a N. M. 3. o a � L — �' E' N • N . N > RI. C�. : : N. 3 y. :� U) c a a N: `.+� N. 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