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216-106
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED FEB 13 2020 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ {,/..�y ��Jrl/'`��,'. i utdown ❑ Performed: Suspend ❑ Perforate ❑ Other ' Stimulate /� Alter Casing ❑ ChgTigQe p v�e Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well Re-enter Susp Well ❑ Other: IC -PO SealTite repair Q 2. Operator Name: ConocoPhlllips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: ment Develo Ex Development ❑ p lorato ry ❑ 216-106-0 3. Address: P. O. BOX 100360, Anchorage, Alaska Stratigraphic ❑ Service ❑ 6. API Number: 99510 50-103-20114-01 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025688 I KRU 2K -11A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Ku aruk River Field / Ku aruk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 9,550 feet Plugs measured None feet true vertical 6,242 feet Junk measured None feet Effective Depth measured 6,511 feet Packer measured 6355, 6369 feet true vertical 6,184 feet true vertical 6030, 6044 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 feet 16 115' MD SURFACE 2,962 feet 9 5/8 " 2,997' MD PRODUCTION 6,479 feet 7 6,510' MD JEWELERY NPI MD =pth MD&TVD feet Composite Tubing (size, grade, measured and true vertical depth) 3.5" J-55 6,441' MD 6,115' TVD Packers and SSSV (type, measured and true vertical depth) PBR - BAKER PBR 6,355' MD 6,030' TVD PACKER - BAKER HB PACKER 6,369' MD 6,044' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mct Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14. Attachments (required per 20 A C 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Q Gas El WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-574 Authorized Name: Jan Byrne Contact Name: Jan Byrne / Dusty Freeborn Authorized Title: Well Integrity Compliance Specialist Contact Email: N1617@conocophilllps.com Authorized Signature: w & Date: 2/10/20 Contact Phone: 907-659-7224 r 7L �/7/W-0 e.'/ o� RBDM5 4FA/ ttG 14 &g Form 30-404 Revised 4/2017 Submit Original Only Date Event Summary 12/15/19 12/19119 12/2011 2K -11A DESCRIPTION OF WORK COMPLETED SUMMARY 2K -11A. SealTite was pumped into the IC -PO and initially appeared to successfully hold IC -PO pressure. Over the monitor period the IC -PO pressure equalized with IA pressure indicating tha the repair was not effective. The OA -FL slowly fell out until it reached the surface casing leak depth which was CPAI stop point for the gas lifted production monitor. CPAI is currently returning the well to natural flow production. Pertinent well work is copied below. Verbal approval was granted for Sundry 319-574 to allow a SealTite repair of the IC -PO on 2K - 11A. (AC EVAL) IC PO SEAL TITE REPAIR (IN PROGRESS) Initial T/l/O = 250/17/5 IA blinded Place heater on IC PO Bled IA to 0 psi 3 minutes fluid Bled OA to 0 psi in 3 minutes gas Assist Seal tite rep to pump —1 liter seal tite Gly-flo into IC PO void per procedure After several pressure cycles and trapping 3000 psi in IC PO the fall off is —10 psi per minute Remove heater and SI catalytic heater in wellhouse DSO is notified Continue with pressure cycles and trap 3000 psi in IC PO for overnight curing Final T/I/O = 250/14/0+ (AC EVAL) IC PO SEAL TITE REPAIR (COMPLETE) Initial T/1/0= 250/3/0+ Rig sealtite manifold to IC PO Apply 3000 psi Gly flo to IC PO 15 min 2900 psi (-100 psi) 6.66 psi per minute fall off Pressure cycle with Gly flo to 3000 psi 15 min 2950 psi (-50 psi) Pressure cycle with Gly flo to 3000 psi with fall off getting better with each pressure cycle Pressure stabilized for 30 minutes Bled IA to 1000 psi and placed heater on IC PO for 2 hours monitoring for thermal response Pressure IC PO with Gly flo to 3000 psi Pressure stabilized for 30 minutes Bled IC PO to 0 psi Final T/I/O = 250/5/0+ Initial T/I/O = 240/SI/0 IC PO 200 psi DSO brought on lift gas Pressured IC PO to 3000 psi with Gly flo monitoring IC PO as well thermals The IC PO pressure flucuations trend the well tempreture Trap 1500 psi of Gly flo in IC PO Rig up manifold with gauge & needle valve to IC PO pressure test manifold to 3000 psi , no leaks OA FL@114' Final T/I/O = 219/1283/6 12/22/19 2K -11A DESCRIPTION OF WORK COMPLETED C 1 111111111 A D V (AC EVAL) LOAD OA (COMPLETE) Initial T/1/0= 250/1310/9. OA FL 114'. Bled OA to 0 psi. Pressured OA to 50 psi w/ 3.5 bbls diesel. Final T/I/0= 250/1310/50. 12122/19- IThe well was brought on gas lift production and monitored throughout this time period. 02/10/20 KUP PROD WELLNAME 2K -11A WELLBORE 2K-11 CUII0CUPIUllipS �a--z Well Attributes Max Angle & MD TD 1" FeIE Name W¢IIEo�e pPWWI W¢IlOare status Incl l') N Vdal� T. Bim lXKe) Alaskanc 2836 40300no RRRSn eat WO: "I, ]/Ip/]11A 3<3'.i]PM Last Tag aticlxtuv% pnnoUlian OepthlhKB End Date Wellbore Isar Moe By Last Tag: RKBLOC) 6,2330 I 10/912016 2K-11 Ipproven Last Rev Reason 1awE6 ni...— A Ell Dino weubore LBy Rev Reason: TAG, GLV CIO, PERFORATFORAT CEMENT ED, PUMPED CEMENT. TAG 10/10/2016 2N,11 ppro,dnven Casing Strings c^upocroR.9eanse Casing Description oD9n1 to (In) roprduSu set Beptl(hKB) — Beptb(NDi...wVLen IT Grade rnpmreaa CONDUCTOR 16 15.06 3fi0 1150 115.0 6250 H-40 WELDED Casing Descopllon UU Gni oUlle) TOPMKe1 Set Depth 114101 Set Death(TVpt... WVten(I._GnJe TDITDI-cl SURFACE 95/6 I 892 350 2,9974 2,949.0 3500 J-55 I BTC SAFEN VLV,t 8150 LaSing Description I.. I..) PRODUCTION 7 ID (Ini Top(XKa) 628 31.2 Set help othe Set F'. ".1 WVLen0 loped 6.877.6 26.00 J-55 Top Thread BTC Perforations & Slots shat . LI"zaw,7 Top(M1N81 Toptrvol atm (hKB) tNKB) ales R'V 1 (f." Laked Zone Date (.ho�m 1 Type Com 5409.0 6,4110 8,083) 6,0851 A-4,21(-01 "1c131201fi 2.0 APERF fi,5)4.0 6600.0 6,24]2 6,2729 A -d, 2K-11 10/2411989 2.0 IPERI- 4.5 HSD Cs9 Guns; 180 deg ph Cement Squeezes SORFACE;sS.azw>,a Top(rvD) Blm(TVDt Top ryKS) Big hKBf (NNB) (%KBr Des Start Dale Lom 6,40>0 6630a 6,118)1 8,302] Cemenl Plug 1011201fi LAV IN 35 B515 OF 1550CEMENT(20 BELS WITH apps LIFT', s,mz4 CEMENT FIBERS) Notes: General & Safety apsuFT.4.6149 End Date oopepi 11/11/2019 NOTE: WAIVERED WELL: Natural Flow only. OMFORM S IAEOA(an gas) 111212010 NOTE: Viev Schematic wl Alaska SChematil0 GAS Ul5.a97 GASLIFT;S.A26 GAS LIFT; 5sedil OAS LIFT; 6.7120 P&9; aWt, F`CKER;6.368.6 Dopey AnwI FJ; 6 sing 41(0 NIPPIE, 6.411.4 APERF: 641906,4110 505;6.4110 .1 A rarer; 8.431.]0.993.1 IPERF; 6.574,09.0J0�� PRODUCTION; 31389P6 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 10, 2020 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7 1 Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 Report of Sundry # 319-574 well operations from ConocoPhillips Alaska, Inc. for KRU 2K -11A (PTD 216-106) IC -PO SealTite repair attempt. Please contact Dusty Freeborn or me at 659-7224 if you have any questions. Sincerely, Jan Byrne Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Jan Byrne Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc, PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2K -I IA Permit to Drill Number: 216-106 Sundry Number: 319-574 Dear Mr. Byrne: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .aogcc.alasko.gov Enclosed is the approved application for the 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, ssie�elowski Commissioner DATED this 2i0 day of December, 2019. 3BDMS *'j.JAN 0 2 2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 280 Etb 111771 IR DEC 18 2013 OSS IgZ011-2 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Weli Operations shutdown LJ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: IC -PO Seal-Tite repair 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilll s Alaska Inc. Exploratory ❑ Development 216-106-0 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: P. O. Bax 100360, Anchorage, Alaska 99510 501032011401 CL2 7. If perforating: 8. Well Name and Number: frI What Regulation or Conservation Order governs well spacing in this pool? (z.. LTJ Will planned perforations require a spacing exception? Yes ❑ No O KRU 2K -11A 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0025588 Kuparuk River Field ! Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD: Effective Depth ND: MPSP (psi): Plugs (MD): Junk (MD): 9,550' 6,242' 6,511' 6,184' Casing Length Size MD ND Burst Collapse Structural Conductor 79' 16" 115' Surface 2,962' 10" 299T Intermediate Production 6,479' 7" 6,510' Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): NA NA 3.500" J-55 6,441' Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft): PACKER - BAKER HB PACKER MD= 6369 ND= 6044 12. Attachments: Proposal Summary O Wellbore schematic ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Service ❑ 14. Estimated Date for 12/17/2019 15. Well Status after proposed work: Commencing Operations: OIL ❑Z + WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG // ❑ SPLUG ❑ 16. Verbal Approval: Date: I//CTORaf/ Commission Representative:4,0Elj%J /z�/�//9 r8,((GSTOR GINJ ❑ t2 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: Jan Byrne Jan Byrne / Dusty Contact Name: y Freeborn Authorized Title: Well Integrity & Compliance Specialist Contact Email: N1617@conocophillips.com Contact Phone: 907-659-7224 Authorized Signature: �. /,2 a•- Date: COMMIS ION 0SE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 319-574 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: IBDMSt Post Initial Injection MIT Req'd?Yes ❑ No JAN 0 2 2020 Spacing Exception Required? Yes ❑ No Subsequent Form Required: ID�gD� �y/ + APPROVED BY Approved by: off-- COMMISSIONER THE COMMISSION Date: 12-12-o L Lj �04*3 �'V!L/1Arm Revised a/2017 Approved application li flr�7Anbrih?yf�i t�a,dateofapproval. AM��� r For an /?Submit Form and Attachments in Duplicate 2K -11A DESCRIPTION SUMMARY OF PROPOSAL 2K -11A is a gas lifted producer that has been waivered for IAxOA (on gas lift) communication since 2003. In October 2019 a surface casing leak at 640' was located during compliance testing. Due to the surface casing leak the gas lift was disconnected and the IA loaded with fluid and a passing MITIA was performed. The well was then waivered for natural production only (no gas lift). The believed source of IAxOA (on gas lift) communication is the inner casing pack off which has failed testing since 2003. COPA intends to repair the i leaking inner casing pack off with Seal-Tite and return the well to gas lift production. Work Steps 1. IA & OA will be bleed to 0 psi. 2. Seal-Tite will be injected into the inner casing pack off until holding pressure. 3. A passing inner casing pack off test will be acquired. 4. Gas lift will be re -connected to the well and gas lift will be circulated through a gas lift valve installed in GLM #1 at 2345'. a. If no IAxOA (on gas lift) communication is observed a full gas lift design will be installed and the well will be returned to gas lift production. b. If IAxOA (on gas lift) communication is observed the IA will be reloaded with fluid and a dummy valve will be reinstalled in GLM#1 at 2345' and the well will be returned to natural flow production. KUP PROD WELLNAME 2K -11A WELLBORE 2K -11A ii I IpsPera uvea nTm.pTes Mex An gIe&II TO Alaska, Inc. nela Name Psu50103211401 wellbore sfaeua 3. MO 999 Ad 0an 0(nNa) KUPARURIVERUNT 103201140 ROD 03.30 6,839.99 9,550.0 Comment H29(ppm) Bah pnnoUllon Entl Oah KBGre(n) RIP Panama Duh "SV. TRDP 10 1,130/2015 Leal WO: 40.09 W2111989 2.11111/1.1981S15 AM Last Tag Verll[elubemtl¢(az1uL) Annotation Beptll(nKB) Entl Data Wellbore Las[Moe By Last Te9: 2K -11A PProven ILwGER. SA- Last Rev Reason Aummadhn Ene Bme w.neore Iasi M^e by Rev Reason: Pulled K-3 Plug Assembly 11/13/2019 2K-1 to EmrTma - CONDUCTOR, 38.01160 cexlnpDeaenpean OD nn) IO6n) IS Peld 6m DePtl Md BI Per meld, ITVDI .. WOLen a.-Oraaa Top I -D! Liner, A Lateral 2318 1.99 6,4367 7,9920 6,258) 4.60 L -BO ST -L Liner Details S"ETt1Vle160 T^p (RKB) Top(ND)(RKB) 1, Incl (°) IRm Des Nommn 10 Lom (Inl 7,991.6 6,258.7 93 i6 Nm-por[etl Bullnose Bullnose -non ponetl 1,000 Tubing Strings Dns uFT; 2.344./ nemy U. curl.. stung ma... m(I^) TO p (nKB) sal Bepm (rt.. sal Bepm (rvD)(... Wt6nm) cn4e Ip ronnec0on TUBING' 3112 2.99 31.1 644te 9,ttfi2 9.30 l55 EUEertlABMOD Completion Details TOP".) TOpina Must P TOp(1KB) (RKB) p) Item Des COM IT pn) 31.1 31.1 000 HANGER FMC GEN IV TUBING HANGER 3.500 1,015.0 1,815.0 0.61 SAFETYVLV CAMCOTRDP-IA-SSASAFEFY VALVE 2.812 suRFACE 36D2914 6,355.1 6,0302 7.80 PBR BAKERPBR 3000 ws uFr', 3,324 6,360.8 6,0438 7.73 PACKER BAKER HE PACKER 2.892 6407.4 6,082.1 1.59 NIPPLE OTIS M NIPPLE W/2.S1- DISH BORE, Milled ODLtO 2.80"on 2.800 1010V16 Ops UMT 4elde 6,4410 6,1154 7.65 SOS BROWN SHEAR OUT SUB 3.015 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) 6p5 UR; 5.S9] T. 1: .1 TOp Incl TOp(RKe) (RKB) (°) Oes CO. Run Daie 6,2330 5,909.3 1.98 Top of semen! Top Or cemen(6233CUS fi191201fi ID (in) 0000 Dns uR; 65rz6 6511.0 6,184.8 T.E0 1 WHIPSTOCK- 3-112"WMpatock, Baker Monabore%L, 10tr LOHS 10130/201 MONOBORE 6 0.000 Mandrel Inserts s1 BAS 11F1: 5.070.8 n O TOIKE) TIP Laisll POrtelze TRO Run N TOp (RNB) DIKE) Make MPD OB (Inl Sery Type Type (Asp Run Data Com 1 2,314.] 2,3412 MIERLA TMPD 1 GAS LIFT DMY BK 0.000 00 1122019 00 2 319324 3.777.4 MERLq TMPD 1 GAS LIFT DMV BK 0,000 00 11IZ2019 3 4,814.9 4,558.1 MERLA TMPD 1 GAS LIFT DMY BK 0000 0.0 1122019 4 5,209] 4,915.8 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 9/3W2016 Ons uFf, 6,312 0- 5 65J2.6 5,261.4 MERLA TMPD i GAS LIFT DMV BK 0000 00 1122019 65,9408 5.620.3 CAM MMG-2 11/2 GAB LIFT DMV RK 0.000 0.0 111312019 1 6,312.0 5,98>.6 CAMCO MMG-2 11/2 GAS LIFT DMV RK 0.000 0.0 1022016 Notes: General & Safety PER; 63E61 End Date Ann^fano^ NOTE: PACKER; 8.360.8 .aper mensm I, 640].0 INS NIPPLE; 6401,4 SPERF', 649.464110- SOS; 6.441.0 PRODUCTION; 3128.8]] 6 WHIPSTOCK-MBNOBORE; 8.5110 Urer.nlpleeal; 6434.]192. Llrcz, nLl lahnl: 6.M01 8.9 0 December 16, 2019 Commissioner Jessie Chmielowski Alaska Oil & Gas Conservation Commission 333 West 7'h Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski: Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well 2K -11A (PTD# 216-106). The request is for approval to repair an inner casing pack off leak with a Seal-Tite application. If you need additional information, please contact us at your convenience. Sincerely, Jan Byrne / usty Freeborn Well Integrity Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 WELLS TEAM ��ps Loepp, Victoria T (CED) From: Loepp, Victoria T (CED) Sent: Monday, December 16, 2019 12:05 PM To: Well Integrity Compliance Specialist CPF1 & 2 Subject: KRU 2K -11A (PTD 216-106) Intent to Seal-Tite repair inner casing pack off Jan, Verbal approval is granted to proceed with the work as outlined. 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. Loeoo(av)alaska. qoy 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 (9071793-1247 or Victoria.Loeop@alaska.aov From: Well Integrity Compliance Specialist CPFl & 2 <n1617@conocophillips.com> Sent: Monday, December 16, 2019 8:59 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: KRU 2K -11A (PTD 216-106) Intent to Seal-Tite repair inner casing pack off Victoria, 2K -11A is a gas lifted producer that has been waivered for IAxOA (on gas lift) communication since 2003. In October 2019 a surface casing leak at 640' was located during compliance testing. Due to the surface casing leak the gas lift was disconnected and the IA loaded with fluid and a passing MITIA was performed. The well was then waivered for natural production only (no gas lift). The believed source of IAxOA (on gas lift) communication is the inner casing pack off which has failed testing since 2003. COPA intends to repair the leaking inner casing pack off with Seal-Tite and return the well to gas lift production. The Seal -rite rep is scheduled to arrive today and the work is planned to begin tomorrow, weather dependent. The 10-403 paper copy is in the mail and a digital copy is attached for your review. Please let us know if the plan is acceptable. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 WELLS TEAM corccoF%Ifip% «kK_ t(4 P 1/, /O6o Regg, James B (DOA) From: Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent: Sunday, November 06, 2016 10:27 AM To: Schwartz, Guy L (DOA) Subject: Re: [EXTERNAL]RE: 2K-11A (PTD#216-106) Nabors CDR-3 BOP Closure Notification Thanks Guy, we will make sure to test the deployment Rams before proceeding. Thanks, Mike Sent from my iPhone SCANNED AUG 1 5 2017 On Nov 6, 2016, at 10:24 AM, Schwartz, Guy L(DOA) <guy.schwartz@alaska.gov>wrote: Mike, You will need to pressure/function test the 2 3/8" deployment rams and any other BOPE equipment used before running in with the production liner again. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at (907-793- 1226) or(Guy.schwartz@alaska.gov). From: Callahan, Mike S [mailto:Mike.Callahan@conocophillips.com] Sent:Sunday, November 06, 2016 9:38 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>; Schwartz, Guy L(DOA) <guy.schwartz@alaska.gov> Cc:Starck, Kai <Kai.Starck@conocophillips.com>; Marti, Marty K <Srinagesh.K.Marti@conocophillips.com>; Robinson, Shon D<Shon.D.Robinson@conocophillips.com>; Nabors CDR3 Company Man <NaborsCDR3CompanyMan@conocophillips.com> Subject: 2K-11A(PTD#216-106) Nabors CDR-3 BOP Closure Notification Victoria/Guy, While picking up slotted liner to complete the 2K-11A lateral last night, Nabors CDR-3 observed a gain of 0.6 bbls of fluid. The rig picked up a blank safety joint and closed the 2-3/8" deployment rams to shut the well in. We had 12.9 ppg potassium-formate completion fluid in the well and observed a "'50 psi pressure buildup. We crossed over to our coil tubing and ran in hole to our window at 6510' MD/6030' TVD while maintaining pressure with our MPD choke. 1 • • We just completed a pressure buildup while at the window indicating a 13.1 ppg bottom hole pressure. Our plan forward is to weight up our mud system to 13.5 ppg to kill the well, then come out and attempt to run liner again. I will keep you informed of any status change or alteration to our plan forward. Date/time of BOPE use: 11/6/2016 @ 02:00 Well location/PTD number: 2K-11A, PTD#216-106 Rig Name: Nabors CDR-3 AC Operator Contact: Mike Callahan, Drilling Engineer(231-2176) Operations Summary: Above BOPE Used: Upper and Lower 2-3/8" deployment rams Reason for BOPE Use: 0.6 bbl pit gain observed Actions Taken/To Be Taken: Described above. Last full BOPE test was 10/29/2016. Full function test performed 11/5/2016. Please let me know what other information you would like provided or any questions you have. Regards, Mike Callahan CTD Engineer ConocoPhillips Alaska ATO 660 Office: (907) 263-4180 Cell: (907) 231-2176 2 • i(rckt 11. fib ?,1(0-106o Regg, James B (DOA) From: Nabors CDR3 Toolpusher <NaborsCDR3Toolpusher@conocophillips.com> Sent: Tuesday, November 08, 2016 11:35 AM \\eft t 1l I ,o(t To: Brooks, Phoebe L (DOA) V Cc: DOA AOGCC Prudhoe Bay; Regg,James B (DOA) Subject: CDR3 2 3/8 PIPE SUPS TEST AFTER WELL CONTROL Attachments: CDR3 2K-11A BOP Test on PSR's TIW 11-7-16.xlsx Thanks Nabors Alaska Drilling CDR 3 ToolPusher Office Ph.- 907.670.6051 Rig Floor Ph.-907.670.6060 Email- ncdr3tpCcoriocophillips.com 1 0 • • STATE OF ALASKA ` OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: jim.regqaalaska.gov AOGCC.Inspectors@alaska.gov phoebe.brooks(u)_alaska.gov Contractor: Nabors 'Rig No.: CDR3AC - DATE: 11/7/16 - Rig Rep.: R. Madson/N. Wheeler Rig Phone: 670-6051 Operator: Conoco Phillips Alaska Op. Phone: 670-6050 Rep.: P. Klein/J. Condio E-Mail ncdr3tp@conocophillips.com Well Name: 2K-11A PTD# 2161060 - Sundry# Operation: Drilling: X _ Workover: Explor.: Test: Initial: Weekly: Bi-Weekly: Test Pressure(psi): Rams: 250/4700 - Annular: 250/2500 - Valves: 250/4700 - MASP: 4170 - MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen. P Well Sign P - Upper Kelly 0 Housekeeping P - Rig P - Lower Kelly 0 PTD On Location P - Hazard Sec. P ' Ball Type 1 P - Standing Order Posted P - Misc. NA Inside BOP 0 FSV Misc 0 BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 1 2" Trip Tank Annular Preventer 1 7 1/16" Pit Level Indicators #1 Rams I Blind/Shear Flow Indicator #2 Rams 1 2"Combi Meth Gas Detector #3 Rams 1 2 3/8"Combi P - H2S Gas Detector #4 Rams 1 2 3/8"Combi P - MS Misc #5 Rams 1 Blind/Shear #6 Rams 1 2"Combi Quantity Test Result Choke Ln.Valves 2 2 1/16" Inside Reel valves HCR Valves 4 2 1/16" Kill Line Valves 7 2 1/16" Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 2 2 1/16" Time/Pressure Test Result System Pressure(psi) 3000 CHOKE MANIFOLD: Pressure After Closure(psi) Quantity Test Result 200 psi Attained(sec) No.Valves 12 Full Pressure Attained(sec) Manual Chokes 1 Blind Switch Covers: All stations Yes - Hydraulic Chokes 1 Nitgn. Bottles#&psi(Avg.): 4 x 1750 CH Misc 0 NA ACC Misc 0 Test Results Number of Failures: 0 Test Time: 0.5 Hours Repair or replacement of equipment will be made within NA days. Notify the AOGCC of repairs with written confirmation to:AOGCC.Inspectors@alaska.gov Remarks: Pressure test Upper and Lower 2 3/8"Pipe Slip Rams and TIW Valve 250 low,4700psi high. This test was after shutting in the well while running 2 3/8"slotted liner after observing slight flow from well on 11/06/2016. AOGCC Inspection 24 hr Notice Yes Date/Time 11/07/2016 Waived By Test Start Date/Time: 11/7/2016 0:00 (date) (time) Witness Test Finish Date/Time: 11/7/2016 0:30 Form 10-424(Revised 11/2015) CDR3 2K-11A BOP Test on PSR's TIW 11-7-16.xlsx DATA SUBMITTAL COMPLIANCE REPORT 2/21/2017 Permit to Drill 2161060 Well Name/No. KUPARUK RIV UNIT 2K -11A ? IF I1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20114-01-00 MD 9550 TVD 6242 Completion Date 11/23/2016 Completion Status 1 -OIL Current Status 1 -OIL UIC No REQUIRED INFORMATION s Mud Log No t/ Samples No✓ Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR/Res (data taken from Logs Portion of Master Well Data Maint) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments Log C 27737 Log Header Scans 0 0 2161060 KUPARUK RIV UNIT 2K -11A PB1 LOG HEADERS ED C 27737 Digital Data 11/14/2016 Electronic File: 2K-11APB1 EOW - NAD27.pdf ED C 27737 Digital Data 11/14/2016 Electronic File: 2K-11APB 1 EOW - NAD27.txt Log C 27795 Log Header Scans 0 0 2161060 KUPARUK RIV UNIT 2K -11A LOG HEADERS ED C 27795 Digital Data 12/6/2016 Electronic File: 2K -11A EOW - NAD27.pdf ED C 27795 Digital Data 12/6/2016 Electronic File: 2K -11A EOW - NAD27.txt ED C 27869 Digital Data 6541 6298 1/9/2017 Electronic Data Set, Filename: 2K- 11A_MFC24_30OCT16.1as NO ED C 27869 Digital Data Q 1/9/2017 Electronic File: 2K-11A_MFC24_30OCT16.pdf 1 ED C 27869 Digital Data 1/9/2017 Electronic File: 2K- 11 A_MFC24_30OCT16_Report.pdf ED C 27869 Digital Data 1/9/2017 Electronic File: 2K- 11A_MFC24_30OCT16_img.tiff ' ED C 27869 Digital Data 1/9/2017 Electronic File: WIVArun.zip ED C 27869 Digital Data 1/9/2017 Electronic File: 2K - 11A MFC24 30OCT16 CENTERED.cmi ED C 27869 Digital Data 1/9/2017 Electronic File: 2K - 11A MFC24 30OCT16 CENTERED.wvd ED C 27869 Digital Data 1/9/2017 Electronic File: 2K- 11A_MFC24_30OCT16_CENTERED.wvf ED C 27869 Digital Data 1/9/2017 Electronic File: 2K- 11A_MFC24_30OCT16_CENTERED.wvp AOGCC Page I of 5 Tuesday, February 21, 2017 DATA SUBMITTAL COMPLIANCE REPORT 2/21/2017 Permit to Drill 2161060 Well Name/No. KUPARUK RIV UNIT 2K -11A Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20114-01-00 MD 9550 TVD 6242 Completion Date 11/23/2016 Completion Status 1 -OIL Current Status 1-0I1- UIC No ED C 27869 Digital Data 1/9/2017 Electronic File: 2K- 11A_MFC24_30OCT16_UNCENTERED.cmi, ED C 27869 Digital Data 1/9/2017 Electronic File: 2K - 11A MFC24 30OCT16 UNCENTERED.wvd , ED C 27869 Digital Data 1/9/2017 Electronic File: 2K - 11A MFC24 30OCT16 UNCENTERED.wvf ' ED C 27869 Digital Data 1/9/2017 Electronic File: 2K- 11A_MFC24_30OCT16_UNCENTERED.wvp Log C 27869 Log Header Scans 0 0 2161060 KUPARUK RIV UNIT 2K -11A LOG HEADERS Log C 27870 Log Header Scans 0 0 2161060 KUPARUK RIV UNIT 2K -11A LOG HEADERS ED C 27870 Digital Data 6644 6374 1/9/2017 Electronic Data Set, Filename: 2K- 11 A_MFC24_12NOV16_CENTERED.las ED C 27870 Digital Data 91/9/2017 Electronic File: 2K-11A_MFC24_12NOV16.pdf , ED C 27870 Digital Data 1/9/2017 Electronic File: 2K- 11A_MFC24_12NOV16_img.tif ' ED C 27870 Digital Data 1/9/2017 Electronic File: 2K- 11_MFC24_12NOV16_Report.pdf - ED C 27870 Digital Data 1/9/2017 Electronic File: 2K - 11A MFC24 12NOV16 CENTERED.cmi ED C 27870 Digital Data 1/9/2017 Electronic File: 2K- 11A_MFC24_12NOV16_CENTERED.wvd ED C 27870 Digital Data 1/9/2017 Electronic File: 2K- 11A_MFC24_12NOV16_CENTERED.wvp ED C 27870 Digital Data 1/9/2017 Electronic File: 2K - 11A MFC24 12NOV16 UNCENTERED.cmi ED C 27870 Digital Data 1/9/2017 Electronic File: 2K- 11A_MFC24_12NOV16_UNCENTERED.wvd - ED C 27870 Digital Data 1/9/2017 Electronic File: 2K- 11A_MFC24_12NOV16_UNCENTERED.wvp Log C 27874 Log Header Scans 0 0 2161060 KUPARUK RIV UNIT 2K -11A LOG HEADERS ED C 27874 Digital Data 6430 9550 1/12/2017 Electronic Data Set, Filename: 2K -11A GAMMA - RES.Ias ED C 27874 Digital Data 1/12/2017 Electronic File: 2K -11A 21VID Final.cgm AOGCC Page 2 of 5 Tuesday, February 21, 2017 DATA SUBMITTAL COMPLIANCE REPORT 2/21/2017 Permit to Drill 2161060 Well Name/No. KUPARUK RIV UNIT 2K -11A Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20114-01-00 MD 9550 TVD 6242 Completion Date 11/23/2016 Completion Status 1-0I1- Current Status 1-0I1- UIC No ED C 27874 Digital Data 1/12/2017 Electronic File: 2K -11A 5MD Final.cgm , ED C 27874 Digital Data 1/12/2017 Electronic File: 2K -11A 5TVDSS Final.cgm ED C 27874 Digital Data P 1/12/2017 Electronic File: 2K -11A 21VID Final.pdf. ED C 27874 Digital Data 1/12/2017 Electronic File: 2K -11A 51VID Final.pdf . ED C 27874 Digital Data Q1/12/2017 Electronic File: 2K -11A 5TVDSS Final.pdf - ED C 27874 Digital Data 1/12/2017 Electronic File: 2K -11A EOW - NAD27.pdf. ED C 27874 Digital Data 1/12/2017 Electronic File: 2K -11A EOW - NAD27.txt- ED C 27874 Digital Data 1/12/2017 Electronic File: 2K -11A Final Survey TD 9550.csv . ED C 27874 Digital Data 1/12/2017 Electronic File: 2K -11A Survey Listing.txt ED C 27874 Digital Data 1/12/2017 Electronic File: 2K -11A Surveys.txt. ED C 27874 Digital Data 1/12/2017 Electronic File: 2K- 11A_25_tapescan_BHI_CTK.txt ' ED C 27874 Digital Data 1/12/2017 Electronic File: 2K -11A_5_ tapescan_BHI_CTK.txt. ED C 27874 Digital Data 1/12/2017 Electronic File: 2K-11A_output.tap ED C 27874 Digital Data 1/12/2017 Electronic File: 2K -11A 21VID Final.tif ED C 27874 Digital Data 1/12/2017 Electronic File: 2K -11A 51VID Final.tif ED C 27874 Digital Data 1/12/2017 Electronic File: 2K -11A 5TVDSS Final.tif ED C 27875 Digital Data 1/12/2017 Electronic File: 2K-11APB 1 21VID Final.cgm ED C 27875 Digital Data 1/12/2017 Electronic File: 2K-11APB1 5MD Final.cgm ED C 27875 Digital Data 1/12/2017 Electronic File: 2K-11APB1 5TVDSS Final.cgm , ED C 27875 Digital Data Q 1/12/2017 Electronic File: 2K-11APB1 2MD Final.pdf ED C 27875 Digital Data ♦? 1/12/2017 Electronic File: 2K-11APB1 51VID Final.pdf, ED C 27875 Digital Data 1/12/2017 Electronic File: 2K-11APB 1 5TVDSS Final.pdf. ED C 27875 Digital Data 1/12/2017 Electronic File: 2K-11APB1 EOW - NAD27.pdf ED C 27875 Digital Data 1/12/2017 Electronic File: 2K-11APB1 EOW - NAD27.txt - ED C 27875 Digital Data 1/12/2017 Electronic File: 2K-11APB1 Final Survey TD , 9058.csv ED C 27875 Digital Data 1/12/2017 Electronic File: 2K-11APB 1 Survey Listing.txt . ED C 27875 Digital Data 1/12/2017 Electronic File: 2K-11APB1 Surveys.txt _ AOGCC Pagc 3 of 5 Tuesday, February 21, 2017 DATA SUBMITTAL COMPLIANCE REPORT 2/21/2017 Permit to Drill 2161060 Well Name/No. KUPARUK RIV UNIT 2K -11A Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20114-01-00 MD 9550 TVD 6242 Completion Date 11/23/2016 Completion Status 1 -OIL ED C 27875 Digital Data ED C 27875 Digital Data ED C 27875 Digital Data ED C 27875 Digital Data ED C 27875 Digital Data ED C 27875 Digital Data ED C 27875 Digital Data Log C 27875 Log Header Scans Well Cores/Samples Information: Name INFORMATION RECEIVED Completion Report GY Production Test Information Y / 10 Geologic Markers/Tops 10 COMPLIANCE HISTORY Completion Date: 11/23/2016 Release Date: 9/7/2016 Description Comments: Interval Start Stop Directional / Inclination Data Y Mechanical Integrity Test Information Y / I Daily Operations Summary 0 Date Comments 6430 9058 0 0 Current Status 1 -OIL UIC No 1/12/2017 Electronic File: 2K- 11APB 1_25_tapescan_BHI_CTK.txt . 1/12/2017 Electronic File: 2K- 11 AP B 1 _5_tapescan_B H I_CTK.txt 1/12/2017 Electronic File: 2K-11 APB 1_output.tap' 1/12/2017 Electronic File: 2K-11APB1 2MD Final.tif- 1/12/2017 Electronic File: 2K-11APB1 5MD Final.tif - 1/12/2017 Electronic File: 2K-11APB1 5TVDSS Final.tif= 1/12/2017 Electronic Data Set, Filename: 2K-11APB 1.las 2161060 KUPARUK RIV UNIT 2K -11A PB1 LOG HEADERS Sample Set Sent Received Number Comments Mud Logs, Image Files, Digital Data YIn Composite Logs, Image, Data Files0� Cuttings Samples Y N Core Chips Y / Core Photographs Y / N Laboratory Analyses Y / AOGCC Page 4 of 5 Tuesday, February 21, 2017 DATA SUBMITTAL COMPLIANCE REPORT 2/21/2017 Permit to Drill 2161060 Well Name/No. KUPARUK RIV UNIT 2K -11A MD 9550 TVD 6242 Completion Date 11/23/2016 Compliance Reviewed Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20114-01-00 Completion Status 1-0I1- Current Status 1-0I1- UIC No Date: O AOGCC Page 5 of 5 Tuesday, February 21, 2017 RECEIVI BAKE `a JAN 12 2017 PRINT DISTRIBUTION LIST HUGHES COMPANY AQ06iffilWAlaska, Inc. WELL NAME 2K -11A FIELD Prudhoe Bay Unit COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider(cr�.bakerhughes.com STATUS Final Replacement: COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOJ% PERSON ATTENTION 2 1 8 1 0 6 27 87 4 Please sign and return one copy of this transmittal form to: ConocoPhillips Alaska, Inc. Tom Osterkamp DATALp Gc�v 700 G Street. l R=Sg91 ASI.. K, aj-i;i`)flER Anchorage, Alaska 99510 to acknowledge receipt of this data. LOG TYPE GR - RES LOG DATE November 15, 2016 TODAYS DATE January 11, 2017 Revision No Details: Requested by: FIELD FINAL CD CD LOGS LOGS (digital/image) Surveys I# (Final Surveys) 1# # OF PRINTS # OF PKIN I S # OF COPIES OF COPIES OF COPIE 4 4 4 JJ 4 4 1 P 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. Attn: Ricky Elgaricio ATO 3-344 700 G Street Anchorage, AK 99510 3 �ExxonNlobil, Alaska Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4lStateofAlaska -AOGCC Attn: Makana Bender 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5 DNR -Division of Oil & Gas *** Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 *** Stamp "confidential' on all material deliver to DNR 6'i111` Exploration (Alaska) Inc. IPetrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: TOTALS FOR ALL PAGES: 1 1 1 1 1 1 0 2 3 3 0 0 0 2 3 3 0 0 s ConocoPhillip RECEIVED JAN 12 2017 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad 2K -11A 50-103-20114-01 Baker Hughes INTEQ Definitive Survey Report 05 December, 2016 106 27 87 4 WO a I BAKER lIU6NE5 . ConocoPhillips //%S # ConocoPhillips Definitive Survey Report ER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well 2K-11 Project: Kuparuk River Unit TVD Reference: 2K-11 @ 154.00usft (2K-11) Site: Kuparuk 2K Pad MD Reference: 2K-11 @ 154.00usft (2K-11) Well: 2K-11 North Reference: True Wellbore: 2K -11A Survey Calculation Method: Minimum Curvature Design: 2K -11A 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 2K-11 Well Position +N/ -S 0.00 usft Northing: 5,938,350.22usft Latitude: 70° 14' 34.061 N +E/ -W 0.00 usft Easting: 498,310.14usft Longitude: 150° 0'49.133 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 2K -11A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1 (') (nT) BGG M2016 11/1/2016 17.80 80.87 57,536 Design 2K -11A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 6,811.20 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) V) 154.00 0.00 0.00 0.00 Survey Program Date 11/29/2016 From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 200.00 6,500.00 2K-11 (2K-11) BOSS -GYRO Sperry -Sun BOSS gyro multishot 1/12/2001 6,511.00 6,570.98 2K-11APB1 (2K-11AP61) MWD MWD - Standard 10/23/2016 11/5/2016 6,577.00 6,811.20 2K-11AL1 (2K-11AL1) MWD MWD - Standard 11/6/2016 11/15/2016 6,840.00 9,500.02 2K -11A (2K -11A) MWD MWD - Standard 11/16/2016 11/21/2016 12/5/2016 12:27:00PM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips ConocoPhillips Definitive Survey Report Azl F/ h NuGNES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2K-11 Map Project: Kuparuk River Unit TVD Reference: 2K-11 @ 154.00usft (2K-11) Site: Kuparuk 2K Pad MD Reference: 2K-11 @ 154.00usft (2K-11) (waft) Well: 2K-11 North Reference: True Northing Wellbore: 2K -11A Survey Calculation Method: Minimum Curvature Annotation Design: 2K -11A Database: EDM Alaska NSK Sandbox Survey MD Inc Azl TVD TVDSS +NIS +E/ -W Map Map DLS Vertical (waft) (uaR) usit Wait) (usft) Northing Easting (°1100') Section Survey Tool Name Annotation (110 (ft) (ft) 6,811.20 102.81 169.73 6,292.17 6,138.17 -1,517.80 -880.25 5,936,832.77 497,429.64 11.61 -1,517.80 MWD (3) TIP 6,840.00 103.30 167.88 6,285.67 6,131.67 -1,545.32 -874.80 5,936,805.25 497,435.08 6.48 -1,545.32 MWD (4) KOP 6,870.19 88.80 159.72 6,282.49 6,128.49 -1,574.04 566.43 5,936,776.53 497,443.45 55.00 -1,574.04 MWD (4) 6,900.15 83.76 151.79 6,284.44 6,130.44 -1,601.27 -854.17 5,936,749.30 497,455.70 31.31 -1,601.27 MWD (4) 6,930.24 84.56 138.84 6,287.51 6,133.51 -1,625.83 -837.17 5,936,724.74 497,472.69 42.90 -1,625.83 MWD (4) 6,960.01 85.64 127.67 6,290.06 6,136.06 -1,646.12 -815.60 5,936,704.45 497,494.25 37.56 -1,646.12 MWD (4) 6,990.13 89.72 117.34 6,291.28 6,137.28 -1,662.26 -790.26 5,936,688.30 497,519.59 36.84 -1,662.26 MWD (4) 7,019.97 95.22 107.43 6,290.00 6,136.00 -1,673.60 -762.74 5,936,676.96 497,547.10 37.94 -1,673.60 MWD (4) 7,050.08 98.90 96.61 6,286.28 6,132.28 -1,679.83 -733.56 5,936,670.73 497,576.27 37.69 -1,679.83 MWD (4) 7,080.05 98.63 84.20 6,281.70 6,127.70 -1,680.03 -704.01 5,936,670.51 497,605.83 40.93 -1,680.03 MWD (4) 7,110.11 97.76 73.10 6,277.40 6,123.40 -1,674.19 -674.88 5,936,676.35 497,634.95 36.66 -1,674.19 MWD (4) 7,139.89 93.93 61.64 6,274.36 6,120.36 -1,662.80 547.59 5,936,687.73 497,662.24 40.38 -1,662.80 MWD (4) 7,170.77 91.47 50.16 6,272.90 6,118.90 -1,645.53 522.10 5,936,704.99 497,687.73 37.98 -1,645.53 MWD (4) 7,200.45 91.97 39.28 6,272.01 6,118.01 -1,624.49 -601.26 5,936,726.03 497,708.58 36.68 -1,624.49 MWD (4) 7,230.71 92.67 37.15 6,270.78 6,116.78 -1,600.73 -582.55 5,936,749.78 497,727.29 7.40 -1,600.73 MWD (4) 7,259.86 93.53 34.98 6,269.20 6,115.21 -1,577.20 -565.42 5,936,773.30 497,744.43 8.00 -1,577.20 MWD (4) 7,289.96 93.13 33.03 6,267.46 6,113.46 -1,552.30 548.61 5,936,798.20 497,761.23 6.60 -1,552.30 MWD (4) 7,320.34 92.92 31.34 6,265.85 6,111.85 -1,526.62 532.45 5,936,823.87 497,777.40 5.60 -1,526.62 MWD (4) 7,350.09 92.18 30.38 6,264.53 6,110.53 -1,501.11 -517.21 5,936,849.38 497,792.65 4.07 -1,501.11 MWD (4) 7,380.33 92.39 30.48 6,263.32 6,109.32 -1,475.05 -501.91 5,936,875.43 497,807.95 0.77 -1,475.05 MWD (4) 7,410.31 93.13 29.79 6,261.88 6,107.88 -1,449.16 -486.87 5,936,901.32 497,822.99 3.37 -1,449.16 MWD (4) 7,440.58 92.24 28.77 6,260.46 6,106.46 -1,422.78 -472.08 5,936,927.68 497,837.78 4.47 -1,422.78 MWD (4) 7,470.14 90.37 27.47 6,259.79 6,105.79 -1,396.72 -458.16 5,936,953.74 497,851.72 7.70 -1,396.72 MWD (4) 7,500.35 89.79 26.17 6,259.75 6,105.75 -1,369.76 -444.53 5,936,980.70 497,865.35 4.71 -1,369.76 MWD (4) 7,530.67 89.36 25.02 6,259.97 6,105.97 -1,342.42 -431.43 5,937,008.03 497,878.45 4.05 -1,342.42 MWD (4) 7,559.87 89.63 22.82 6,260.23 6,106.23 -1,315.73 -419.59 5,937,034.72 497,890.30 7.59 -1,315.73 MWD (4) 7,590.18 90.71 21.16 6,260.14 6,106.14 -1,287.63 -408.24 5,937,062.82 497,901.65 6.53 -1,287.63 MWD (4) 7,620.15 89.94 18.38 6,259.97 6,105.97 -1,259.43 -398.11 5,937,091.01 497,911.79 9.62 -1,259.43 MWD (4) 7,650.23 91.53 16.76 6,259.58 6,105.58 -1,230.75 -389.03 5,937,119.68 497,920.88 7.55 -1,230.75 MWD (4) 7,675.22 91.44 14.33 6,258.94 6,104.94 -1,206.69 -382.33 5,937,143.74 497,927.57 9.73 -1,206.69 MWD (4) 12/5/2016 12:27:OOPM Page 3 COMPASS 5000.1 Build 74 Survey ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2K-11 Project: Kuparuk River Unit TVD Reference: 2K-11 @ 154.00usft (2K-11) Site: Kuparuk 2K Pad MD Reference: 2K-11 @ 154.00usft (2K-11) Well: 2K-11 North Reference: True Wellbore: 2K -11A Survey Calculation Method: Minimum Curvature Design: 2K -11A Database: EDM Alaska NSK Sandbox Survey Annotation RUN BAKER HUGHES, 12/5/2016 12:27:OOPM Page 4 COMPASS 5000 1 Build 74 Map Map Vertical MD Inc Azl TVD TVDSS +N1 -S +EJ'W Northing Easting DLS Section Survey Tool Name (waft) (1) (1 (usft) (uaft) (usft) (waft) (ft) (ft) ('1100') (ft) 7,704.62 91.10 13.27 6,258.28 6,104.28 -1,178.14 -375.32 5,937,172.28 497,934.59 3.79 -1,178.14 MWD (4) 7,735.35 90.00 12.52 6,257.99 6,103.99 -1,148.19 -368.46 5,937,202.23 497,941.46 4.33 -1,148.19 MWD (4) 7,764.85 88.53 11.13 6,258.37 6,104.37 -1,119.32 -362.42 5,937,231.09 497,947.51 6.86 -1.119.32 MWD (4) 7,795.29 87.61 9.27 6,259.39 6,105.39 -1,089.38 -357.03 5,937,261.03 497,952.90 6.81 -1,089.38 MWD (4) 7,824.65 87.11 7.35 6,260.75 6,106.75 -1,060.36 -352.79 5,937,290.05 497,957.14 6.75 -1,060.36 MWD (4) 7,854.45 88.40 5.40 6,261.91 6,107.91 -1,030.77 -349.49 5,937,319.63 497,960.46 7.84 -1,030.77 MWD (4) 7,885.11 89.66 3.88 6,262.43 6,108.43 -1,000.22 -347.01 5,937,350.18 497,962.94 6.44 -1,000.22 MWD (4) 7,922.15 91.63 2.23 6,262.01 6,108.01 -963.23 -345.03 5,937,387.16 497,964.92 6.94 -963.23 MWD (4) 7,949.33 92.92 0.55 6,260.94 6,106.94 -936.08 -344.38 5,937,414.31 497,965.59 7.79 -936.08 MWD (4) 7,979.99 92.98 358.99 6,259.36 6,105.36 -905.47 -344.50 5,937,444.92 497,965.47 5.09 -905.47 MWD (4) 8,010.01 93.44 356.64 6,257.68 6,103.68 -875.52 -345.64 5,937,474.87 497,964.34 7.96 -875.52 MWD (4) 6,039.67 95.04 354.33 6,255.48 6,101.48 -846.03 -347.97 5,937,504.35 497,962.02 9.46 -846.03 MWD (4) 8,070.49 95.32 352.32 6,252.70 6,098.70 -815.55 -351.54 5,937,534.83 497,958.46 6.56 -815.55 MWD (4) 8,099.70 97.02 351.91 6,249.56 6,095.56 -786.78 -355.52 5,937,563.59 497,954.48 5.98 -786.78 MWD (4) 8,130.89 97.14 349.79 6,245.72 6,091.72 -756.23 -360.44 5,937,594.15 497,949.57 6.76 -756.23 MWD (4) 8,160.58 97.16 347.74 6,242.02 6,088.02 -727.33 -366.18 5,937,623.04 497,943.83 6.85 -727.33 MWD (4) 8,191.19 97.02 345.98 6,238.24 6,084.24 -697.76 -373.09 5,937,652.62 497,936.94 5.72 -697.76 MWD (4) 8,220.77 95.53 347.40 6,235.01 6,081.01 -669.14 -379.85 5,937,661.23 497,930.17 6.94 -669.14 MWD (4) 8,251.04 93.72 349.00 6,232.57 6,078.57 -639.61 -386.02 5,937,710.76 497,924.01 7.97 -639.61 MWD (4) 8,281.10 91.84 349.34 6,231.11 6,077.11 -610.12 -391.66 5,937,740.25 497,918.38 6.36 -610.12 MWD (4) 8,310.77 90.15 350.73 6,230.59 6,076.60 -580.91 -396.80 5,937,769.46 497,913.25 7.37 -580.91 MWD (4) 8,341.46 87.76 348.20 6,231.15 6,077.15 -550.74 -402.41 5,937,799.62 497,907.65 11.34 -550.74 MWD (4) 8,370.69 87.36 351.12 6,232.40 6,078.40 -522.02 -407.65 5.937,828.35 497,902.42 10.07 -522.02 MWD (4) 8,401.14 87.70 353.03 6,233.71 6,079.71 -491.89 411.84 5,937,858.47 497,898.23 6.37 -491.89 MWD (4) 8,429.75 88.10 355.37 6,234.76 6,080.76 -463.45 -414.73 5,937,886.91 497,895.35 8.29 -463.45 MWD (4) 8,461.10 87.63 358.44 6,235.93 6,081.93 -432.17 -416.42 5,937,918.19 497,893.66 9.90 -432.17 MWD (4) 8,489.96 88.19 359.69 6,236.98 6,082.98 -403.33 -416.89 5,937,947.02 497,893.20 4.74 -403.33 MWD (4) 8,520.24 87.76 2.60 6,238.05 6,084.05 -373.08 -416.29 5,937,977.27 497,893.81 9.71 -373.08 MWD (4) 8,549.65 85.98 2.53 6,239.66 6,085.66 -343.74 414.97 5,938,006.60 497,895.13 6.06 -343.74 MWD (4) 8,579.85 84.34 3.92 6,242.21 6,088.21 -313.70 -413.28 5,938,036.64 497,896.83 7.11 -313.70 MWD (4) 8,610.25 84.81 5.91 6,245.08 6,091.08 -283.55 410.69 5,938,066.79 497,899.43 6.70 -283.55 MWD (4) Annotation RUN BAKER HUGHES, 12/5/2016 12:27:OOPM Page 4 COMPASS 5000 1 Build 74 ConocoPhillips p ConocoPhillips Definitive Survey Report W/ j. BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2K-11 Map Project: Kuparuk River Unit TVD Reference: 2K-11 @ 154.00usft (2K-11) Site: Kuparuk 2K Pad MD Reference: 2K-11 @ 154.00usft (2K-11) TVD Well: 2K-11 North Reference: True Wellbore: 2K -11A Survey Calculation Method: Minimum Curvature Design: 2K -11A Database: EDM Alaska NSK Sandbox (usft) Survey 1215/2016 12:27:OOPM Page 5 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +N1 -S +E/ -W DLS _ (usft) O 0 (usft) (usft) (usft) (-ft) Northing Northing EMap 9 (°l100'► Section Section Survey Tool Name Annotation (ft) 8,639,55 86.25 6.88 6,247.36 6,093.36 -254.52 -407.44 5,938,095.82 497,902.69 5.92 -254.52 MWD (4) 8,671.40 88.96 9.20 6,248.69 6,094.69 -223.02 -402.98 5,938,127.32 497,907.15 11.20 -223.02 MWD (4) 8,701.30 90.34 10.34 6,248.88 6,094.88 -193.55 -397.91 5,938,156.78 497,912.23 5.99 -193.55 MWD (4) 8,731.66 92.09 12.54 6,248.23 6,094.23 -163.81 -391.89 5,938,186.52 497,918.25 9.26 -163.81 MWD (4) 8,765.36 92.49 10.94 6,246.89 6,092.89 -130.84 -385.04 5,938,219.48 497,925.11 4.89 -130.84 MWD (4) 8,791.40 94.25 12.01 6,245.36 6,091.36 -105.36 -379.87 5,938,244.95 497,930.29 7.91 -105.36 MWD (4) 8,821.51 95.57 13.25 6,242.78 6,088.78 -76.09 -373.31 5,938,274.22 497,936.85 6.00 -76.09 MWD (4) 8,851.86 93.50 13.82 6,240.38 6,086.38 -46.68 -366.23 5,938,303.63 497,943.94 7.07 -46.68 MWD (4) 8,882.24 93.32 15.41 6,238.57 6,084.57 -17.33 -358.58 5,938,332.97 497,951.59 5.26 -17.33 MWD (4) 8,911.72 94.80 16.68 6,236.48 6,082.48 10.92 -350.45 5,938,361.22 497,959.73 6.61 10.92 MWD (4) 8,941.94 95.38 19.44 6,233.80 6,079.80 39.54 -341.12 5,938,389.83 497,969.06 9.30 39.54 MWD (4) 8,971.57 95.88 21.42 6,230.90 6,076.90 67.17 -330.83 5,938,417.46 497,979.36 6.86 67.17 MWD (4) 9,002.72 94.52 19.78 6,228.07 6,074.07 96.21 -319.91 5,938,446.49 497,990.28 6.82 96.21 MWD (4) 9,031.36 93.01 18.17 6,226.19 6,072.19 123.23 -310.62 5,938,473.51 497,999.58 7.70 123.23 MWD (4) 9,064.28 93.72 16.61 6,224.26 6,070.26 154.59 -300.80 5,938,504.86 498,009.40 5.20 154.59 MWD (4) 9,097.08 94.89 15.46 6,221.80 6,067.80 186.02 -291.77 5,938,536.29 498,018.44 4.99 186.02 MWD (4) 9,121.08 92.36 13.31 6,220.28 6,066.28 209.22 -285.82 5,938,559.49 498,024.40 13.82 209.22 MWD (4) 9,134.63 92.18 13.28 6,219.74 6,065.74 222.40 -282.70 5,938,572.66 498,027.51 1.35 222.40 MWD (4) 9,155.93 90.34 10.12 6,219.27 6,065.27 243.25 -278.39 5,938,593.51 498,031.84 17.16 243.25 MWD (4) 9,188.37 88.50 7.16 6,219.60 6,065.60 275.31 -273.51 5,938,625.57 498,036.71 10.74 275.31 MWD (4) 9,215.63 87.73 6.44 6,220.50 6,066.50 302.37 -270.29 5,938,652.62 498,039.95 3.87 302.37 MWD (4) 9,246.23 86.01 6.19 6,222.17 6,068.17 332.73 -266.93 5,938,682.98 498,043.31 5.68 332.73 MWD (4) 9,278.58 84.49 5.49 6,224.85 6,070.85 364.80 -263.65 5,938,715.05 498,046.60 5.17 364.80 MWD (4) 9,309.77 85.14 1.83 6,227.67 6,073.67 395.80 -261.67 5,938,746.04 498,048.59 11.87 395.80 MWD (4) 9,315.62 85.14 0.59 6,228.16 6,074.16 401.63 -261.54 5,938,751.86 498,048.71 21.12 401.63 MWD (4) 9,345.94 85.27 3.95 6,230.70 6,076.70 431.81 -260.35 5,938,782.05 498,049.92 11.05 431.81 MWD (4) 9,375.16 85.92 358.22 6,232.95 6,078.95 460.93 -259.79 5,938,811.16 498,050.47 19.68 460.93 MWD (4) 9,407.22 86.38 357.78 6,235.10 6,081.10 492.90 -260.91 5,938,843.12 498,049.37 1.98 492.90 MWD (4) 9,435.60 87.39 357.21 6,236.64 6,082.64 521.21 -262.15 5,938,871.43 498,048.13 4.08 521.21 MWD (4) 9,467.88 88.46 356.23 6,237.81 6,083.81 553.41 -264.00 5,938,903.64 498,046.29 4.49 553.41 MWD (4) 9,500.02 86.77 356.70 6,239.15 6,085.15 585.46 -265.98 5,938,935.68 498,044.32 5.46 585.46 MWD (4) 1215/2016 12:27:OOPM Page 5 COMPASS 5000.1 Build 74 Well 2K-11 2K-11 @ 154.00usft (2K-11) 2K-11 @ 154.00usft (2K-11) True Minimum Curvature EDM Alaska NSK Sandbox Map Vertical Easting DLS Section Survey Tool Name (ft) (°/100') (ft) 498,041.46 0.00 635.28 PROJECTED to TD Annotation MAP itI BAKER HUGHES 1215/2016 12.27:OOPM Page 6 COMPASS 5000.1 Build 74 ConocoPhillips ®, ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 2K Pad MD Reference: Well: 2K-11 North Reference: Wellbore: 2K -11A Survey Calculation Method: Design: 2K-1 1 A Database: Survey Map MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing (usft) V) (I (usft) (usft) (usft) (usft) (ft) 9,550.00 86.77 356.70 6,241.96 6,087.96 635.28 -268.85 5,938,985.50 Well 2K-11 2K-11 @ 154.00usft (2K-11) 2K-11 @ 154.00usft (2K-11) True Minimum Curvature EDM Alaska NSK Sandbox Map Vertical Easting DLS Section Survey Tool Name (ft) (°/100') (ft) 498,041.46 0.00 635.28 PROJECTED to TD Annotation MAP itI BAKER HUGHES 1215/2016 12.27:OOPM Page 6 COMPASS 5000.1 Build 74 ncko WWI //F&G JAN 12 2017 BAKER PRINT DISTRIBUTION LIST HUGHES AO G C C COMPANY ConocoPhillips Alaska, Inc. WELL NAME 2K-11APB1 FIELD Prudhoe Bay Unit COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick. Riderp_bakerhughes.com STATUS Final Replacement: COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOJ% PERSON ATTENTION 21 6106 d 75 Please sign and return one copy of this transmittal form to: ConocoPhillips Alaska, Inc. DATA LOGGED Tom Osterkamp \. /73201-1 700 G Street. M. K. BENDER Anchorage, Alaska 99510 to acknowledge receipt of this data. LOG TYPE GR - RES LOG DATE November 15, 2016 TODAYS DATE January 11, 2017 Revision No Details: Requested by: FIELD FINAL CD CD LOGS LOGS (digital/image) Surveys I# (Final Surveys) # OF PRINTS # OF THIN I S # OF COPIES OF COPIES # OF COPIE 4 4 4 4 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. Attn: Ricky Elgaricio ATO 3-344 700 G Street Anchorage, AK 99510 3 ExxonMobil, Alaska Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska - AOGCC Attn: Makana Bender 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 0 0 0 0 0 0 5 DNR - Division of Oil & Gas *** Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 *** Qra.,,.. .... uu ...o+.—i .lm;— fn nNR 61BP Exploration (Alaska) Inc. 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 iN•-' ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad 2K-11APB1 50-103-20114-70 Baker Hughes INTEQ Definitive Survey Report 05 December, 2016 e ,A s x-0-6 27875 Few F1 I BAKER HUGHES ConocoPhillips Real " BAKER ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2K-11 Project: Kuparuk River Unit TVD Reference: 2K-11 @ 154.00usft (2K-11) Site: Kuparuk 2K Pad MD Reference: 2K-11 @ 154.00usft (2K-11) Well: 2K-11 North Reference: True Wellbore: 2K-11APB1 Survey Calculation Method: Minimum Curvature Design: 2K-11APB1 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 2K-11 Well Position +N/-S 0.00 usft Northing: 5,938,350.22usft Latitude: 70° 14' 34.061 N +E/-W 0.00 usft Easting: 498,310.14usft Longitude: 150° 0'49.133 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 2K-11APB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (I V) (nT) BGG M2016 11/11/20116 17.80 80.87 57,536 Design 2K-11APB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 6,500.00 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (I 154.00 0.00 0.00 10.00 Survey Program Date 11/15/2016 From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 200.00 6,500.00 2K-11 (2K-11) BOSS-GYRO Sperry-Sun BOSS gyro multishot 1/12/2001 6,511.00 9,030.65 2K-11APB1 (2K-11APB1) MWD MWD - Standard 10/23/2016 11/5/2016 12/5/2016 12:08:33PM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips r/ k ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 local Coordinate Reference: Well 2K-11 Project: Kuparuk River Unit TVD Reference 2K-11 @ 154.00usft (2K-11) Site: Kuparuk 2K Pad MD Reference: 2K-11 @ 154.00usft (2K-11) Well: 2K-11 North Reference: True Wellbore: 2K-11APB1 Survey Calculation Method: Minimum Curvature Design: 2K-11APB1 Database: EDM Alaska NSK Sandbox Survey A MD Inc Azi TVD TVDSS +NIS *EJ'W Map DLS Vertcal (usft) (°) (°) (usft) NMI (usft) (usft) Northing Eastng (°/100') Section on Survey Tool Name Annotation (ft) (ft) (ft) 6,500.00 7.82 202.20 6,173.86 6,019.86 -1,287.02 -882.30 5,937,063.52 497,427.64 0.70 -1,420.68 MWD (2) TIP 6,511.00 7.80 202.05 6,184.76 6,030.76 -1,288.41 -882.86 5,937,062.14 497,427.08 0.26 -1,422.14 MWD (2) KOP 6,540.04 15.82 201.90 6,213.16 6,059.16 -1,293.92 -885.08 5,937,056.63 497,424.86 27.62 -1,427.95 MWD (2) 6,570.98 29.83 201.90 6,241.61 6,087.61 -1,305.03 -889.54 5,937,045.52 497,420.39 45.28 -1,439.67 MWD (2) 6,590.76 38.45 201.86 6,257.96 6,103.96 -1,315.32 -893.68 5,937,035.24 497,416.26 43.58 -1,450.52 MWD (2) 6,620.38 50.03 200.39 6,279.15 6,125.15 -1,334.57 -901.08 5,937,015.99 497,408.85 39.25 -1,470.77 MWD (2) 6,648.94 60.97 198.18 6,295.30 6,141.30 -1,356.76 -908.82 5,936,993.80 497,401.11 38.83 -1,493.96 MWD (2) 6,675.58 71.70 196.24 6,305.98 6,151.98 -1,380.04 -916.01 5,936,970.53 497,393.91 40.82 -1,518.13 MWD (2) 6,705.35 77.28 188.54 6,313.95 6,159.95 -1,408.02 -922.13 5,936,942.54 497,387.79 31.17 -1,546.76 MWD (2) 6,735.63 77.31 174.07 6,320.64 6,166.64 -1,437.47 -922.80 5,936,913.10 497,387.11 46.61 -1,575.87 MWD (2) 6,760.08 77.21 163.73 6,326.05 6,172.05 -1,460.84 -918.22 5,936,889.74 497,391.69 41.25 -1,598.09 MWD (2) 6,790.43 89.69 162.07 6,329.50 6,175.50 -1,489.60 -909.36 5,936,660.98 497,400.53 41.48 -1,624.88 MWD (2) 6,820.36 102.35 159.65 6,326.37 6,172.37 -1,517.66 -899.63 5,936,832.92 497,410.26 43.05 -1,650.82 MWD (2) 6,850.93 101.41 145.21 6,320.05 6,166.05 -1,544.10 -885.82 5,936,806.48 497,424.06 46.32 -1,674.46 MWD (2) 6,881.10 100.46 131.18 6,314.29 6,160.30 -1,566.12 -866.12 5,936,784.46 497,443.75 45.76 -1,692.72 MWD (2) 6,910.99 99.35 117.72 6,309.13 6,155.13 -1,582.73 -641.90 5,936,767.84 497,467.97 44.51 -1,704.88 MWD (2) 6,940.91 99.40 105.26 6,304.24 6,150.24 -1,593.52 -814.49 5,936,757.04 497,495.38 41.09 -1,710.74 MWD (2) 6,970.57 97.69 92.91 6,299.81 6,145.81 -1,598.13 -785.58 5,936,752.42 497,524.28 41.57 -1,710.27 MWD (2) 7,000.62 101.68 80.90 6,294.74 6,140.74 -1,596.56 -756.07 5,936,753.99 497,553.79 41.56 -1,703.59 MWD (2) 7,030.42 100.15 68.09 6,289.08 6,135.08 -1,588.74 -727.94 5,936,761.80 497,581.92 42.52 -1,691.01 MWD (2) 7,060.66 100.62 55.42 6,283.60 6,129.60 -1,574.70 -701.79 5,936,775.84 497,608.07 41.24 -1,672.64 MWD (2) 7,090.36 100.34 43.03 6,278.18 6,124.18 -1,555.66 679.72 5,936,794.86 497,630.14 41.03 -1,650.06 MWD (2) 7,121.33 93.75 34.08 6,274.38 6,120.38 -1,531.66 -660.61 5,936,818.87 497,649.25 35.70 -1,623.10 MWD (2) 7,149.75 94.09 30.68 6,272.43 6,118.43 -1,507.71 -645.43 5,936,842.80 497,664.44 12.00 -1,596.89 MWD (2) 7,180.58 95.41 27.51 6,269.88 6,115.88 -1,480.87 -630.49 5,936,869.64 497,679.38 11.11 -1,567.86 MWD (2) 7,210.59 95.81 26.28 6,266.95 6,112.95 -1,454.24 -616.98 5,936,896.27 497,692.90 4.29 -1,539.28 MWD (2) 7,239.99 95.81 23.11 6,263.97 6,109.97 -1,427.67 -604.76 5,936,922.83 497,705.12 10.73 -1,510.99 MWD (2) 7,270.91 96.03 20.46 6,260.78 6,106.78 -1,399.11 -593.35 5,936,951.38 497,716.54 8.55 -1,480.89 MWD (2) 7,300.18 96.68 18.67 6,257.54 6,103.54 -1,371.70 -563.61 5,936,978.79 497,726.29 6.47 -1,452.20 MWD (2) 7,330.72 95.25 .,.. 15.72 6,254.37 6,100.37 1,342.69 574.63 _. _ _ 5,.937,007.80 ..,_ 497,735.27 10.69 -1,422.07 MWD (2) 121512016 12:08:33PM Page 3 COMPASS 5000 1 Build 74 Annotation SAM HUGHES 12/5/2016 12:08:33PM Page 4 COMPASS 5000 1 Build 74 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2K-11 Project: Kuparuk River Unit TVD Reference: 2K-11 @ 154.00usft (2K-11) Site: Kuparuk 2K Pad MD Reference: 2K-11 @ 154.00usft (2K-11) Well: 2K-11 North Reference: True Wellbore: 2K-11APB1 Survey Calculation Method: Minimum Curvature Design: 2K-11APB1 Database: EDM Alaska NSK Sandbox Survey Map Map Vertical MD Inc Azi i\/D lypgg +N/ -S +E/.W Northing Eating DLS Section Survey Tool Name (usft) 0 (1 Weft) (rift) (usft) (usft) l(ft)( (ft) ('1100') (ft) 7,359.93 95.26 13.54 6,251.69 6,097.69 -1,314.55 567.28 5,937,035.93 497,742.62 7.43 -1,393.08 MWD (2) 7,390.30 93.07 12.85 6,249.48 6,095.48 -1,285.06 -560.37 5,937.065.42 497,749.54 7.56 -1,362.84 MWD (2) 7,420.45 92.06 12.24 6,248.13 6,094.13 -1,255.66 553.83 5,937.094.81 497,756.09 3.91 -1,332.75 MWD (2) 7,446.53 89.57 12.17 6,247.76 6,093.76 -1,230.17 -548.31 5,937.120.30 497,761.61 9.55 -1,306.70 MWD (2) 7,475.79 88.44 11.70 6,248.27 6,094.27 -1,201.55 -542.26 5,937,148.91 497,767.66 4.18 -1,277.46 MWD (2) 7,501.51 88.10 10.15 6,249.05 6,095.05 -1,176.31 537.39 5,937,174.15 497,772.54 6,17 -1,251.75 MWD (2) 7,531.53 88.16 8.72 6,250.03 6,096.03 -1,146.71 -532.47 5,937,203.74 497,777.46 4.77 -1,221.75 MWD (2) 7,559.75 87.88 6.33 6,251.00 6,097.00 -1,118.75 -528.78 5,937,231.70 497,781.16 8.52 -1,193.58 MWD (2) 7,590.67 90.09 5.51 6,251.55 6,097.55 -1,088.00 525.59 5,937,262.44 497,784.36 7.62 -1,162.74 MWD (2) 7,620.55 93.04 5.26 6,250.73 6,096.74 -1,058.27 -522.79 5,937,292.17 497,787.17 9.91 -1,132.97 MWD (2) 7,650.77 91.17 4.40 6,249.62 6,095.63 -1,028.18 -520.25 5,937,322.26 497.789.72 6.81 -1,102.90 MWD (2) 7,681.23 87.51 2.66 6,249.98 6,095.98 -997.79 -518.37 5,937,352.65 497,791.60 13.30 -1,072.64 MWD (2) 7,710.05 88.46 2.29 6,250.99 6,096.99 -969.01 -517.13 5,937,381.42 497,792.85 3.54 -1,044.09 MWD (2) 7,740.56 89.88 0.65 6,251.43 6,097.43 -938.52 -516.35 5,937,411.91 497,793.64 7.11 -1,013.92 MWD (2) 7,770.20 89.42 358.68 6,251.61 6,097.61 -908.88 -516.52 5,937,441.55 497,793.47 6.83 -984.76 MWD (2) 7,800.35 92.15 2.47 6,251.20 6,097.20 -878.74 -516.22 5,937,471.68 497,793.78 15.49 -955.03 MWD (2) 7,829.83 90.58 3.56 6,250.50 6,096.50 -849.31 -514.67 5,937,501.11 497,795.34 6.48 -925.78 MWD (2) 7,860.26 91.01 5.42 6,250.07 6,096.07 -818.98 -512.28 5,937,531.44 497,797.72 6.27 -895.49 MWD (2) 7,889.87 90.40 6.75 6,249.71 6,095.71 -789.54 -509.15 5,937,560.87 497,800.87 4.94 -865.96 MWD (2) 7,920.39 88.96 9.04 6,249.88 6,095.88 -759.31 -504.95 5,937,591.10 497,805.07 8.86 -835.46 MWD (2) 7,950.30 90.77 9.12 6,249.95 6,095.95 -729.78 -500.23 5,937,620.63 497,809.79 6.06 -805.56 MWD (2) 7,980.25 91.63 7.41 6,249.32 6,095.32 -700.15 495.93 5,937,650.26 497,814.10 6.39 -775.63 MWD (2) 8,010.13 90.52 4.17 6,248.76 6,094.76 -870.43 -492.92 5,937,679.97 497,817.12 11.46 -745.84 MWD (2) 8,040.10 90.25 2.09 6,248.56 6,094.56 -840.51 -491.28 5,937,709.69 497,818.77 7.00 -716.08 MWD (2) 8,070.12 90.55 359.17 6,246.35 6,094.35 -610.49 -490.95 5,937,739.90 497,819.10 9.78 -886.47 MWD (2) 8,100.28 91.69 359.33 6,247.76 6,093.76 -580.34 -491.35 5,937,770.05 497,818.71 3.82 -856.84 MWD (2) 8,130.27 91.87 358.15 6,246.83 6,092.83 -550.37 -492.00 5,937,800.01 497,818.06 3.98 -627.45 MWD (2) 8,160.19 91.93 358.75 6,245.84 6,091.84 -520.48 -492.81 5,937,829.90 497,817.26 2.01 -598.15 MWD (2) 8,190.26 92.00 359.93 6,244.81 6,090.81 490.43 1393.16 5,937,859.95 497,816.92 3.93 -568.62 MWD (2) 8,220.25 92.12 2.18 6,243.73 6,089.73 460.47 492.61 5,937,889.91 497,817.48 7.51 -539.01 MWD (2) 8,250.33 91.44 5.36 6,242.80 6,088.80 1330.47 490.63 5,937,919.90 497,819.46 10.81 -509.13 MWD (2) Annotation SAM HUGHES 12/5/2016 12:08:33PM Page 4 COMPASS 5000 1 Build 74 Survey ConocoPhillips (/%l ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2K-11 MD Project: Kuparuk River Unit TVD Reference: 2K-11 @ 154.00usft (2K-11) TVDSS Site: Kuparuk 2K Pad MD Reference: 2K-11 @ 154.00usft (2K-11) Easting Well: 2K-11 North Reference: True (I Wellbore: 2K-11APB1 Survey Calculation Method: Minimum Curvature (usft) Design: 2K-11AP81 Database: EDM Alaska NSK Sandbox (.1100') Survey 1215/2016 12:08:33PM Page 5 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section Survey Tool Name Annotation (usft) (I (I (usft) (usft) (usft) (usft) (ft) (ft) (.1100') (ft) 8,280.31 91.29 8.49 6,242.08 6,088.08 -400.72 1387.02 5,937,949.65 497,823.08 10.45 -479.20 MWD (2) 8,309.89 91.66 8.57 6,241.32 6,087.32 -371.48 -482.63 5,937,978.89 497,827.47 1.28 -449.64 MWD (2) 8,340.05 92.76 10.25 6,240.16 6,086.16 -341.75 477.70 5,938,008.61 497,832.41 6.65 419.51 MWD (2) 8,370.28 93.62 12.00 6,238.47 6,084.47 -312.13 471.88 5,938,038.22 497,838.24 6.44 -389.33 MWD (2) 8,401.83 93.44 11.62 6,236.53 6,082.53 -281.31 -465.44 5,938,069.04 497,844.69 1.33 -357.86 MWD (2) 8,425.48 93.16 9.57 6,235.17 6,081.17 -258.10 -461.10 5,938,092.25 497,849.03 8.73 -334.25 MWD (2) 8,455.90 93.07 7.93 6,233.52 6,079.52 -228.08 -456.47 5,938,122.26 497,853.66 5.39 -303.88 MWD (2) 8,485.42 89.97 6.88 6,232.73 6,078.73 -198.82 -452.67 5,938,151.52 497,857.47 11.09 -274.41 MWD (2) 8,510.60 88.40 5.57 6,233.09 6,079.09 -173.79 449.94 5,938,176.54 497,860.20 8.12 -249.29 MWD (2) 8,540.36 86.59 4.10 6,234.39 6,080.39 -144.17 -447.44 5,938,206.16 497,862.72 7.83 -219.68 MWD (2) 8,570.27 87.66 3.17 6,235.89 6,081.89 -114.36 -445.54 5,938,235.97 497,864.62 4.74 -189.99 MWD (2) 8,600.15 86.90 1.81 6,237.31 6,083.31 -84.54 -444.25 5,938,265.79 497,865.92 5.21 -160.40 MWD (2) - 8,630.05 87.33 358.52 6,238.82 6,084.82 -54.68 -444.16 5,938,295.64 497,866.01 11.08 -130.98 MWD (2) 8,660.11 87.42 359.55 6,240.19 6,086.19 -24.66 -444.67 5,938,325.66 497,865.51 3.44 -101.50 MWD (2) 8,690.17 88.19 0.93 6,241.34 6,087.34 5.38 444.54 5,938,355.70 497,865.65 5.25 -71.90 MWD (2) 8,720.41 90.15 2.63 6,241.78 6,087.78 35.60 443.60 5,938,385.91 497,866.59 8.58 41.98 MWD (2) 8,750.23 91.29 4.99 6,241.41 6,087.41 65.34 441.62 5,938,415.66 497,868.58 8.79 -12.33 MWD (2) 8,780.15 90.77 6.20 6,240.87 6,086.87 95.12 -438.70 5,938,445.43 497,871.50 4.40 17.49 MWD (2) 8,810.07 91.88 9.94 6,240.18 6,086.18 124.73 -434.50 5,938,475.03 497,875.71 13.04 47.38 MWD (2) 8,834.97 92.70 10.65 6,239.18 6,085.18 149.21 -430.06 5,938,499.51 497,880.16 4.35 72.26 MWD (2) - 8,865.72 93.93 11.10 6,237.40 6,083.40 179.35 -424.27 5,938,529.65 497,885.96 4.26 102.95 MWD (2) 8,896.87 92.73 13.23 6,235.59 6,081.60 209.75 -417.71 5,938,560.04 497,892.52 7.84 134.03 MWD (2) " 8,926.59 93.84 14.20 6,233.89 6,079.89 238.57 410.68 5,938,588.86 497,899.56 4.96 163.64 MWD (2) 8,955.22 95.29 15.38 6,231.61 6,077.61 266.17 403.39 5,938,616.45 497,906.85 6.52 192.07 MWD (2) 8,985.27 94.73 13.21 6,228.99 6,074.99 295.17 -396.00 5,938,645.45 497,914.24 7.43 221.92 MWD (2) 9,010.23 94.46 11.02 6,226.99 6,072.99 319.50 -390.78 5,938,669.77 497,919.47 8.81 246.78 MWD (2) 9,030.65 94.49 9.15 6,225.40 6,071.40 339.54 -387.22 5,938,689.81 497,923.04 9.13 267.14 MWD (2) 9,058.00 94.49 9.15 6,223.25 6,069.25 366.46 -382.88 5,938,716.73 497,927.38 0.00 294.40 PROJECTED to TO 1215/2016 12:08:33PM Page 5 COMPASS 5000.1 Build 74 WELL LOG TRANSMITTAL #903662150 To: Alaska Oil and Gas Conservation Comm. Attn.: Makana Bender 333 West 7th Avenue, Suite 100 RECEIVED Anchorage, Alaska 99501 !AN 0 9 2017 RE: Multi Finger Caliper: 2K -I IA AOGcc Run Date: 11/12/2016 218106 27 87 0 December 13, 2016 DATA LOGGED /2—S2o11 ivi K. BENDER The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS—ANC@halliburton.com 2K -11A Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20114-01 Multi Finger Caliper (Field Log) 1 color log 50-103-20114-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS—ANC@halliburton.com Date: Signed !--!! , STATE OF ALASKA Al AgKA n1l AND GAS CONSERVATION COMMISSION ZSDcc k6 WELL COMPLETION OR RECOMPLETION REPORT AND LOG ta. Well Status: Oil 2 Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended[] 20AAC 25.105 20AAC 25110 GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: «. 1b. Well Class: Development Exploratory ❑ Service ❑ Stratig raph le Test ❑ 2. Operator Name: ConocoPhlllips Alaska, Inc. 6. Date Comp., Susp., or 4 Z3 /b Aband.: VW24l2W 14. Permit to Drill Number I Sundry: 216-106/ 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 11/18/2016 15. API Number: 50-103-20114-01-00 4a. Location of Well (Governmental Section): Surface: 46' FSL, 94' FEL, Sec 2, T1 ON, RBE, UM Top of Productive Interval: 1261' FNL, 986' FEL, Sec 11, T1ON, R8E, UM Total Depth: 4598' FNL, 363' FEL, Sec 2, TION, R8E, UM 8. Date TD Reached: 11/21/2016 16. Well Name and Number: KRU 2K -11A 9. Ref Elevations: KB:154 GL: 118 BF: 17. Field / Pool(s): Kuparuk River Field[Kuparuk River Oil Pool 10. Plug Back Depth MD/TVD: N/A 18. Property Designation: ADL 25588 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 498310 y- 5938350 Zone -4 TPI: x- 497435 y- 5936805 Zone -4 Total Depth: x- 498041 y- 5938986 Zone -4 11. Total Depth MD/TVD: 9550/6242 19. Land Use Permit: ALK 2674 12. SSSV Depth MD/rVD: 1815/1815 20. Thickness of Permafrost MD/TVD: 1496/1463 5. Directional or Inclination Survey: Yes [J (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: NIA (ft MSL) I 21. Re-drill/Lateral Top Window MD/TVD: 1 6510/6184 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16 62.5 H-40 36 115 36 115 24 95/8 36 J-55 35 2997 35 2949 121/4 900 sx AS III, 375 sx Class G 7 26 J-55 31 6854 31 6525 8112 225 sx Class G 23/8 4.6 L-80 6435 7992 6109 6259 Liner 24. Open to production or injection? Yes ❑ No ❑ tt Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number): Slotted Liner @ 6435 - 7992 MD and 6109-6259 TVD COMPLETION DATE 11L-5 I -e VERIFIED 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MDITVD) 3.5 6442 6469/6044 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes L]No ❑ Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Waiting for Hook-up Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Test Period __► Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Casing Press: Calculated 24 -Hour R Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravitv - API (corr): Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 Submit ORIGINIAL only TL Z�l��l RDDMS L STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION DEC 19 2016 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil E] Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: 1b. Well Class: Development 0 Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., S z Zolfo Aband.: 14. Permit to Drill Number/ Sundry: 216-1 C 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 11/18/2016 15. API Number: 50-103-20114 0100 4a. Location of Well (Governmental Section): Surface: 46' FSL, 94' FEL, Sec 2, T1 ON, R8E, UM Top of Productive Interval: 1261' FNL, 986' FEL, Sec 11, T1 ON, R8E, UM Total Depth: 4598' FNL, 363' FEL, Sec 2, T1 ON, R8E, UM 8. Date TD Reached: 11/21/2016 16. Well Name and Number: KRU 2K -11A 9. Ref Elevations: KB: 154 GL: 118 BF: 17. Field / Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 10. Plug Back Depth MD/TVD: N/A 18. Property Designation: ADL 25588 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 498310 y- 5938350 Zone- 4 TPI: x- 497435 y- S93&W_G`1 ,& 805 Zone- 4 Total Depth: x- 498349&t-IctBUy1 y5938-,1'330ISLo Zone -4 11. Total Depth MD/TVD: 9550/6242 19. Land Use Permit: ALK 2674 12. SSSV Depth MD/TVD: 1815/1815 20. Thickness of Permafrost MD/TVD: 1496/1463 5. Directional or Inclination Survey: Yes E] (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 1 1 21. Re-drill/Lateral Top Window MD/TVD: 6510/6184 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 GRADE SETTING DEPTH MD HOLE SIZE CEMENTING RECORD SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM PULLED 16 62.5 H-40 36 115 36 115 24 95/8 36 J-55 35 2997 35 2949 121/4 900 sx AS III, 375 sx Class G 7 26 J-55 31 6854 31 6525 8 1/2 225 sx Class G 23/8 4.6 L-80 6435 7992 16109 6259 Liner 24. Open to production or injection? Yes 0 No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number): Slotted Liner @ 6435 - 7992 MD and 6109-6259 TVD COMPLETION DAT � ) z 5 I V VERIFIED 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3.5 6442 6469/6044 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑ Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Waiting for Hook-up Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casinq Press: Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravitv - API (corr): Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 R13DMS LL, DEC L 1 2016 Submit ORIGINIAL only 28. CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No [21 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 E If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1496 1463 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 6840 6283 information, including reports, per 20 AAC 25.071. TD 9550 6242 2K-11APB1 Total Depth 9058 6223 Formation at total depth: Ku aruk A ZPq 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, le nolo is I report, production or well test results, r 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Callahan 263-4180 c� I % J(%'i' Email: Mike. Callahan co .com Printed Name: G. Eller Title: Lead CTD Engineer Si nature: Phone: 263-4172 Date: Z INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed !ogs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only 2K-11 Final Schematic 1 16'62# H-40 shoe @ 115' MD 10-314" by 9-518" 36# L-80 shoe @ 2997'MD etc -11A (North) A -sand perfs TO @ V -5U MO Liner Bottom @ 7992'ML' 6574' - 6600' MD Liner Top @ 6435'141D 2K-I1h.F'B1 (North) TD@9058'MD Uner Bottom @ 8t 72' Liner Tap @ 7D09' MD Anchored Met @ 6859'ME) 26# J-55 shoe 6878" MD 3-1.12" 9.3# J-55 EUE 8rd Tubing to surface 3-162" Camco TRDP SSSV @ 1815' RKB (locked out???) 3-112" Merla. TMPD gas lift mandrels @ 2345', 3932', 4815', 5210': 5573' RKB 3-112" Gamco MMG GLV @ 5941' RKB 3-962" Carrico MMG OVGLV @ 8312' RKB Baker 3-1/2" P BR @ 6355' RKB (T ID) Baker HB packer @ 6369' RKB (2.892" ID) (6360' PDC) 3-112" Otis XN nipple @ 640T RKB (2.75" min ID) Note- Milled out to 2 80" ID for CTD (6397' PDQ 3-112" tubing tail as 6442* RKB (6431' PDQ _- - - -- - - - - - ---------- 2K-11ALI (SDuth) TO @ SOD' MD Liner Bottom @ 8884' MG, Liner Mile @ 8841' MD ConocoPhillips Alaska, Inc. c.anocovhw,p: KUP Pr - D Well Attribu, Max RIVER UNIT 2K-11 inl 1vnm7ms II ast Wn 1 1 40.091 9/21/1989 erWa emaGe..... Annotation Depth (RKB) Entl Date Last Tag: RKB 6,622.0 9/7/2011 Annotation Rev Reason: TAG, GLV C/O, PERFORATED, Last Mod By pproven End Date 10/10/2016 ............................................................ HANGER: 31.1 PUMPED CEMENT, TA G CEMENT Perforations Slots Shot Dens k Top (TVD) Bt. (TVD) (shots/ Top (RKB) Bt. (RKB) (RKB) (RKB) Zone Date ft) Type Com CONDUCTOR; 3s 0-1150 I 6,409.0 6,411.0 6,083.7 6,085.7 A-4, 2K-11 10/3/2016 2.0 APERF 6,574.0 6,600.0 6,247.2 6,272.9 A-4, 2K-11 10/24/1989 2.0 IPERF 4.5' HSD Csg Guns; 180 deg ph SAFETY VLV; 1,815.0 Cement Squeezes Top (TVD) Bt(, (TVD) Top (RKB) Btm (RKB) (RKB) (RKB) Des Start Date Com 6,407.0 6,630.0 6,081.7 6,302.7 Cement Plug 10/7/2016 LAY IN 35 BBLS OF 16.5# CEMENT (20 BBLS WITH 1 CEMENT FIBERS) GAS LIFT; 2,344.7 Notes: General & Safety End Date Annotation 9/3/2003 NOTE: WAIVERED WELL: IA x OA COMMUNICATION 11/2/2010 NOTE: View Schematic w/ Alaska Schematic9.0 SURFACE; 35.0-2,997.4 GAS LIFT; 3,932.4 GAS LIFT; 4,814.9 GAS LIFT; 5,208.7 GAS LIFT', 5,572 6 GAS LIFT; 5,940.8 GAS LIFT; 6,312.0 PBR; 6,355.1 PACKER; 6,368.8 NIPPLE; 6,407.4 f APERF; 6,409.06,411.0- 1 a M SOS; 6,441 0 WHIPSTOCK - MONOBORE; ✓f' 6,511.0 Y; ff IPERF; 6,574.06,600.0- Display Cement Fill, 6,407.0 ftK8 PRODUCTION; 31 .2-6,877 Liner, ALateral; 6,434.7-7,992.0 Liner, AL1 Lateral; 6,840,3- ,840.38,864.0 8.864.0 KUP P- ')D 2K -11A ,� , tt. COtt©CC)i�"11��1�3S Well AttribL Max Angl D TD ) Alaska Inc. Wellbore APBUWI Field Name Wellbore Status Ll (°)�I MD Rn ) Act Btm (ftKB 501032011401 KUPARUK RIVER UNIT PROD 103.30 6,839.99 9,50 to! lvvnnnl8 II a,1 wn 1 1 40.091 9/21/1989 1K-ilN, l!/le/NlO n1:[a:l/rm -- - eraca s< moat actual Annotation Depth (ftKB) Entl Date Last Tag: Annotation Rev Reason: SIDETRACK, ADD LATERALS, GLV C/O, SET/PULL CATCHER, CORRECTED Last Motl By pproven End Date 12/14/2016 ......_..._ ............................._.._-..__..... ......__ HANGER; 31.1 Casing rings Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen (I... Grade Top Thread CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 HAO WELDED Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... -Len (I... Grade Top Thread SURFACE 95/8 8.921 35.0 2,997.4 2,949.0 36.00 J-55 BTC CONDUCTOR; 36.0-115.0 Casing Description OD (in) ID (in) I Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen (I... Grade Top Thread PRODUCTION 7 6.276 31.2 6,877.6 6,282.7 26.00 J-55 BTC Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen (I... Grade Top Thread Liner, A Lateral 23/8 1.992 6,434.7 7,992.0 6,258.7 4.60 L-80 ST -T Liner Details SAFETY VLV; 1,815.0 '- Nominal ID Nominal Top (ftKB) Top (TVD) (ftKB) Top Incl r) Item Des Com 7,991.6 6,258.7 93.16 Non -ported Bullnose - non ported 1.000 GAS LIFT; 2,344.7 Bullnose I Tubing Strings Tubing Description String Ma... ID (in) Top (ftKB) Set Depth (R.. Set Depth (ND) (... Wt (IbHt) Gratle Top Connection TUBING 31/2 2.992 31.1 6,441.8 6,116.2 9.30 J-55 EUESrdABMOD Completion Details Nominal ID J Top (ftKB) Top (TVD) (ftKB) Top Incl r) Item Des Com (in) SURFACE; 35.0-2,997.4 31.1 31.1 0.00 HANGER FMC GEN IV TUBING HANGER 3.500 1,815.0 1,815.01 0.67 SAFETY VLV CAMCO TRDP-IA-SSA SAFETY VALVE 2.812 GAS LIFT; 3,932.4 6,355.1 6,030.2 7.80 PBR BAKER PBR 3.000 6,368.8 6,043.8 7.73 PACKER BAKER HB PACKER 2.892 GAS LIFT; 4,814.9 6,407.4 6,082.1 7.59 NIPPLE OTIS XN NIPPLE W/2.81" POLISH BORE 2.800 6,441.0 6,115.4 7.65 SOS BROWN SHEAR OUT SUB 3.015 GAS LIFT; 5,209.7 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) GAS LIFT; 5,572.6 6,511.0 6,184.8 7.80 WHIPSTOCK 3-1/2" Whipstock, Baker Monobore XL, 10° LOHS 10/30/2016 0.000 MONOBORE Mandrel Inserts St at GAS LIFT; 5,94l on Top (TVD) Valve Latch Port Size TRO Run N Top (ftKB) I (ftKB) Make Model OD (in) Sery I Type Type (in) (psi) Run Date Com 1 2,344.7 2,341.2 MERLA TMPD 1 GAS LIFT GLV BK 0.156 1,293.0 11/28/2016 2 3,932.4 3,777.4 MERLA TMPD 1 GAS LIFT GLV BK 0.188 1,317.0 11/28/2016 GAS LIFT; 6,312.0 3 4,814.9 4,558.1 MERLA TMPD 1 GAS LIFT OV BK 0.250 0.0 11/28/2016 4 5,209.7 4,915.8 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 9/30/2016 5 5,572.6 5,261.4 1 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 7/202003 6 5,940.8 5,620.3 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/292016 PBR; 6,355.1 7 6,312.0 5,987.6 CAMCO MMG-2 1 12 GAS LIFT DMY RK 0.000 0.0 10/22016 Notes: General & Safety PACKER; 6,368.8 End Dale Annotation NOTE. NIPPLE; 6,407.4 APERF; 6,409.0 -6,411.0 - SOS; 6,441 0 WHIPSTOCK- MONOBORE; 6,511.0 I PERF, 6,574.0&,600.0 Display Cement Fill, 6,407.0 ftKB PRODUCTION; 31.2-6,877.6 Liner, A Lateral; 6,434.7-7,992.0 Liner, AL1 Lateral; 6,840,3- 8,864,0 KUP F- 1D 2K-11AL1 Well AttribL IMaxAng, iD TD Alaska, InC.. Welilwre APVUWI 501032011460 Field Name KUPARUK RIVER UNIT Wellbore Status PROD ncl (-) 103.32 MD (ftKB) 6,841.47 Act Btm (ftKB) 8,900.0 Comment SSSV: TRDP H2S (ppm) Date 10 11/30/2015 Annotation End Date Last WO: KB-Grd (ft) Rig Release Date 40.09 9/21/1989 2K-11AL1, 12/19/201611:23:27 AM Vertical scherni echo Annotation Last Tag: Depth (RKB) End Data AnnofaRon Rev Reason: SIDETRACK Last Mod By pproven End Date 12/14/2016 ........................................................... _. _..._... HANGER; 31.1 Casing rings Casing Description OD (in) ID (in) Top (RKB) Set Depth (RKB) Set Depth (ND)... WVLen Q... Grade Top Thread Liner, AL1 Lateral 2 3/8 1.992 6,840.3 8,864.0 6,293.2 4.60 L-80 ST -L Liner Details CONDUCTOR; 36.0-1150 Top(ftKB) Top (ND) (ftKB) Top Inc] (') Item Des Com Nominal ID (in) 6,852.0 6,282.9 102.91 Deployment Shorty Deployment Sleeve 1.920 Sleeve SAFETY VLV; 1 815.0 8,863.6 6,293.2 94.08 Non -ported Non -Ported Bullnose 1.000 Bullnose Notes: General & Safety End Date Annotation NOTE: GAS LIFT; 2,344.7 SURFACE; 35.0-2,997.4 GAS LIFT; 3,9324 GAS LIFT; 4,614.9 GAS LIFT; 5,209.7 GAS LIFT; 5,5726 GAS LIFT; 5,940.8 GAS LIFT: 6,312.0 PBR; 6,355.1 PACKER; 6,368.6 NIPPLE; 6,407.4 APERF; 6,409.06,411.0 SOS; 6,441 0 WHIPSTOCK - MONOBORE; 6,511.0 (PERF; 6,574.o-6,600.0- Display Cement Fill', 6,407.0 ftKB PRODUCTION; 31.26,877.6 Liner, A Lateral, 6,434.7-7,992.0 Liner, AL1 Lateral; 6,840 3- J 8,864.0 Operations Summary (with Timelog Depths) 2K-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftK8) End Depth (ftKB) 0.0 0.0 10/22/2016 10/22/2016 5.00 MIRU MOVE MOB P Prep rig to move to 2K-11, PEAK 03:00 08:00 trucks arrived 0400. 10/22/2016 10/22/2016 8.50 MIRU MOVE MOB P Moved rig from 1 H-07 to 2K pad. 0.0 0.0 08:00 16:30 10/22/2016 10/22/2016 4.75 MIRU MOVE MOB P Prep wellhead area for rig. Spotted 0.0 0.0 16:30 21:15 drilling sub followed by pits sub. 10/22/2016 2016 2.75 MIRU MOVE RURD P Continue rigging up 0.0 0.0 21:15 10/23/2016 F0123/2016 1.00 MIRU MOVE MOB P Continue MIRU, work post rig move 0.0 0.0 00:00 checklist10/23/2016 2016 3.00 MIRU WHDBOP NUND P Nipple up BOPE, change out risers, 0.0 0.0 01:00 04:00 Measure stack, Grease stack. Check wellhead, 3 loose bolts between Swab 1 and Swab 2. 10/23/2016 10/23/2016 2.00 MIRU WELLPR OTHR P Start filling coil, Bring fluid in pits, Test 0.0 0.0 04:00 06:00 Inner reel iron - Shell test BOPE, Rig Accept @ 06:00 10/23/2016 10/23/2016 10.00 MIRU WHDBOP BOPE T Perform BOPE test to 250/4700 psi D.0 0.0 06:00 16:00 (2500 psi annular). Upper blinds - re- test & pass. `*Witness waived by AOGCC State Inspector, Brian Bixby, on 10/22/2016 @ 1530 via e-mail." 10/23/2016 10/23/2016 2.25 MIRU WHDBOP PRTS P PT surface lines, blowdown TT line. 0.0 D.0 . 16:00 18:15 10/23/2016 10/23/2016 2.25 MIRU WHDBOP MPSP P PJSM, lubricate out BPV. Pressurized 0.0 0.0 18:15 20:30 to 500 psi prior to pulling BPV, immediately depressurized when BPV was pulled. RD lubricator + extension. 10!23/2016 10/23/2016 2.00 SLOT WELLPR OWFF T Install UQC checks. Pre -SPUD w 0.0 0.0 20:30 22:30 focus on well hazards with entire team. Prepare to PU cement milling assembly, BHA #1. Hook up to SSSV control line port, pressure up to 5000 psi to open SSSV. Open MV, 50 psi WHP. Bleed to TT. Fill hole. Monitor well, built back up to 50 psi. 10/23/2016 10/24/2016 1.50 SLOT WELLPR MILL T Prepare for PD of BHA #1. Blow down 0.0 15.0 TT line. PJSM, PD BHA #1. WHP 170 22:30 00:00 psi. 10/24/2016 10/24/2016 1.75 SLOT WELLPR MILL T Cont PD BHA #1 - MU motor/bit assy 15.0 62.5 00:00 01:45 in rotary table to upper tool string. 10/24/2016 10/24/2016 1.65 SLOT WELLPR MILL T RIH BHA #1 pumping 0.65 BPM SW. 62.5 6,135.0 01:45 03:24 10/24/2016 10/24/2016 0.45 SLOT WELLPR DLOG T GR tie in, minus 1' correction. 6,135.0 6,262.0 03:24 03:51 10/24/2016 10/24/2016 0.40 SLOT WELLPR CIRC T Swap to viscosified SW (Power Vis). 6,262.0 6,294.0 03:51 04:15 Close EDC. 10/24/2016 10/24/2016 1.75 SLOT WELLPR MILL T PUW=41k, RIH, tag cement @ 6,306'. 6,294.0 6,306.0 04:15 06:00 PUH, 3 stalls @ 6,306' with HS orientation pumping 1.8 BPM. Try 90° ROHS, 90°LOHS, 180°ROHS with lower pump rate of 1.55 BPM. 10/24/2016 10/24/2016 1.50 SLOT WELLPR MILL T Crew change, Run valve checklist, 6,306.0 6,310.0 06:00 07:30 been at 6310 tough spot, Sample to geo mostly cement little metal, 1.4 BPM @ 2120 PSI FS Page 1129 Report Printed: 11128/2016 Operations Summary (with Timelog Depths) 4-= 2K-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time I our (hr) Phase Op Code Activity Code Time P -T -X T Operation Get 6310 tight spot at 130° (ftKB) 6,310.0 End Depth (ftKB) 6,343.0 10/24/2016 10/24/2016 2.80 SLOT WELLPR MILL past LOHS, ROP up to 13FPH 07:30 10/24/2016 10:18 10/24/2016 0.40 SLOT WELLPR WPRT T pull Stalle on bittuck 6,343.0 6,343.0 cyclea@ 60K,J BHA, Wiperrt 6100cond 10:18 10:42 10/24/2016 10/24/2016 3.30 SLOT WELLPR MILL T 6343', Mill, 1.47 BPM @ 2260PSI FS, 6,343.0 6,363.0 10:42 14:00 Get past 6343 @ 30R 10/24/2016 10/24/2016 0.10 SLOT WELLPR MILL T Milling break, 6363 to 6367 No WOB 6,363.0 6,367.0 of differential pressure, Motor in to 14:00 14:06 6367 @ 30 FPM. Get back to hard cement @ 6367 10/24/2016 10/24!2016 2.60 SLOT WELLPR MILL T 6367, Mill, 1.48 BPM @ 2290 PSI FS, 6,367.0 6,383.0 still getting stalls, try different TF's 14:06 16:42 10/24/2016 10!24/2016 0.20 SLOT WELLPR \PRT T Pull BHA Wiper, PUW=53K 6,383.0 6,383.0 16:42 10/24/2016 16:54 10/24/2016 4.60 SLOT WELLPR MILL T 6383', Mill, 1.5 BPM @ 2305 PSI FS 6,383.0 6,396.0 16:54 10/24/2016 21:30 10/24/2016 0.20 SLOT WELLPR WPRT T Wiper to 6320, PUW=53K 6,396.0 6,396.0 21:30 10/24!2016 21:42 10/25/2016 2.30 SLOT WELLPR MILL T 6396', Mill, 1.45 BPM @ 2295 PSI FS. 6,396.0 6,409.0 21:42 10/25/2016 00:00 10!2512016 3.50 PROD1 RPEQPT MILL P Mill ahead, 1.44 BPM @ 2336 psi FS. 6,409.0r6-,430.0 10:00 03:30 Multiple stalls. Erratic WOB, pressures. 10/25/2016 10/25/2016 040 PROD1 RPEQPT MILL P g break, 6,430 to 6,436. No WOB 6,430.0,436.0 or differential pressure. Found hard 03:30 03:54 cement again @ 6,436'. 10/25/2016 10/25/2016 2.80 PROD, RPEQPT MILL Ti__ Mill ahead to hard spot @ 6,446 (5' 6,436.0 6,448.0 passed TT, likely contacting 7" 03:54 06:42 casing). Numerous stalls, worked through. 10/25/2016 10/25/2016 3.10 PROD1 RPEQPT MILL P Mill ahead, 1.78 BPM @ 3095 psi FS. 6,448.0 6,503.0 06:42 09:48 Rate varied from 2 - 30 FPH. 10/25/2016 10/25/2016 0.15 PROD1 RPEQPT WPRT P BHA wiper, PUW=43k. Swap TF. 6,503.0 6,503.0 09:48 10/25/2016 09:57 10/25/2016 0.95 PROD1 RPEQPT MILL P Mill ahead, 1.8 BPM @ 3125 psi FS. 6,503.0 6,517.0 09:57 10:54 -16 FPH. 10/25/2016 10/25/2016 1.85 PROD1 RPEQPT MILL P Milling break, 6,517'to 6,530'. No 6,517.0 6,531.0 WOB or differential pressure. Found 10:54 12:45 hard cement again @ 6,530'. Work through 6,530' by varying TF & rate. Discuss with town - decision made to run caliper next (instead of under - reamer) to assess the WS setting area for competent cement. 10/25!20,6 10/25/2016 1.00 PROD1 RPEQPT WPRT P PUH, dry drift transition area. 6,531.0 6,435.0 12:45 13:45 Backream through transition area twice @ 1 FPM, 1.8 BPM. 10/25/2016 10/25/2016 0.10 PROD1 RPEQPT DLOG P Tie-in K1 marker for +3' correction. 6,435.0 6,461.0 13:45 10/25/2016 13:51 10/25/2016 0.65 PROD, RPEQPT MILL P RBIH, cont milling to depth of 6,540'. 6,461.0 6,540.0 1.5 BPM @ 2590 psi FS. -26 FPH. 13:51 14:30 CTSW=13.9k. 10/25/2016 10/25/2016 1.25 PR0D1 RPEQPT WPRT P PUH, dry drift transition area. Back 6,540.0 6,440.0 ream transition zone three more times, 14:30 15:45 WOB bobble when RIH -0.5k. 10/25/2016 10/25/2016 0.25 PROD1 RPEQPT OWFF P PUH to 6,292', flow check well. Live 6,440.0 6,292.0 well, plan for PUD BHA #1. 15:45 16:00 Page 2129 Report Printed: 11/2812016 g Operations Summary (with Timelog Depths) 2K-11 r r •' Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log End Time 10/25/2016 17:36 10/25/2016 20:06 Dur (hr) 1.60 2.50 Phase PROD1 PROD1 Op Code RPEQPT RPEQPT Activity Code TRIP RURD Time P -T -X P P Operation POOH BHA #1. Flow Check, Good, Crew Change. Lay down BHA #1. Struggled to remove BHA from tree, uncertain where we were stuck but bit was Start Depth (ftKB) 6,292.0 60.7 End Depth (ftKB) 60.7 0.0 Start Time 10/25/2016 16:00 10!25/2016 17:36 across the master by approx 1'. Worked BHA up, Closed Master. Found cement chunks when vacuuming out the BOP stack. D-331 mill maintained 2.79" NoGo. 10/25/2016 22:24 -2 30 PR0D1 RPEQPT CIRC P MU Nozzle, pop on and jet stack, pop off. 0.0 0.0 10/25/2016 20:06 10/25/2016 22:24 10/26/2016 00:00 1.60 PROD1 RPEQPT _fURD P PJSM, Close swabs, open master, 185 psi on managed pressure line. Bleed pressure, no flow observed. 0.0 62.5 Filled Stack with water, opened swab valves, flow check, good, RU memory caliper, bump up, "Fingers programmed to open 25:10 and close@ 25:34 10/2612016 -1 50 PR0D1 RPEQPT TRIP P RIH w BHA #2 - HES memory caliper. 62.5 6,433.0 10/26/2016 00:00 01:30 10/26/2016 03:36 2.10 PROD1 RPEQPT DLOG P Tie into K1 Marker, -1.5' correction. Wt Ck, 45 k lbs. Park at 6535' wait for fingers to open. Pick up Wt 45k lbs, POOH 50 fpm logging caliper of milled 6,433.0 5,900.0 10/26/2016 01:30 pilot hole. 10/26/2016 10/26/2016 1.00 PROD1 RPEQPT TRIP P POOH with BHA #2 Memory Caliper. 5,900.0 58.6 03:36 04:36 10/26/2016 05:36 1.00 PROD1 RPEQPT OWFF P Flow check, monitor through open whitey valve on injector. 58.6 58.6 10!26/2016 04:36 10/26/2016 07:42 2.10 PROD1 RPEQPT RURD P Crew change. PJSM, PUD BHA #2. Step 50 of PUD checklist -realized spaced out incorrectly, DBV not 58.6 58.6 10/26/2016 05:36 exposed (14 inches too deep). Strip back on, reverse steps. Trouble -shoot injector counter - slipping. 10/26/2016 09:18 10/26/2016 1.60 0.65 PROD1 SLOT RPEQPT WELLPR RURD RURD P T Tag -up, spaceout again watching counter. PUD BHA #2. Inspect EDC, re -configure BHA. 58.6 0. 0 0.0 D.0 10/26/2016 07:42 10/26/2016 09:18 09:57 10/26/2016 11:51 10/26/2016 13:27 1.90 1.60 SLOT SLOT WELLPR WELLPR RURD TRIP T T PJSM, PD BHA #3 (2.25" under- reamer). RIH BHA #3. Troubleshoot counter (RIH was negative value). Cont RIH. 0.0 71.0 71.0 6,450.0 10/26/2016 09:57 10/26/2016 11:51 10/26/2016 0.25 SLOT WELLPR DLOG T Tie-in to K1 for +18.5' correction. 6,450.0 6,470.0 10/26/2016 13:27 13:42 10/26/2016 15:00 1.30 SLOT WELLPR UREM T PUW=46k. PUH to 6,320. Close EDC. Roll pumps on to 1.8 BPM, UR from 6,320' to 6,400'. SD pumps. RIH to 6,470.0 6,490.0 10/26/2016 13:42 6,410'. Roll pumps back to 1.8 BPM. UR from 6,410' to 6,435'. SD pumps. Open EDC. Pump 0.3 BPM, RIH 50', bring pumps up to 1.8 BPM. 10/26/2016 16:42 10/26/2016 18:24 1.70 1.70 SLOT SLOT WELLPR WE TRIP RURD T T POOH w BHA #3 pumping max rate through EDC. Perform jog @ 500'. Pressure undeploy BHA #3 Tubing under reamer. 6,490.0 84.7 84.7 0.0 10/26/2016 15:00 10/26/2016 16:42 Page 3/29 Report Printed: 1 112812 01 6 Operations Summary (with Timelog Depths) 2K-11 Job: DRILLING SIDETRACK Rig: NABORS CDR3-AC Time Log Time 10/26/2016 our (hr) 1.00 Phase PROD1 Op Code RPEQPT Activity Code RURD Time P -T -X T Operation Pick up BHA #4 casing under reamer. Start Depth (ftKB) 0.0 End Depth (ftKB) 0.0 Start TimeEnd 10/26/2016 18:24 10/26/2016 19:24 10/26/2016 1.80 PROM RPEQPT PULD T PJSM, Pressure deploy BHA #4 0.0 66.4 19:24 21:12 casing under reamer. 10/26/2016 1.50 PROD1 RPEQPT TRIP T RIH. Tie into K1 marker for+ 14.5' 6,637.0 6,445.0 10/26/2016 21:12 22:42 correction. Wt Ch 44k lbs. Close EDC, zero WOB, bring pumps to min rate, RIH, tag bottom, 6540' CTMD, PU Wt 44k lbs. PUH to 6445'. 10/27/2016 1.30 PROD1 RPEQPT UREM T Park at 6445', increase pump rate to 6,445.0 6,455.0 10/26/2016 1.52 BPM, CT 2475 psi, differential 22:42 00:00 1048 psi, ease into it with auto drill ,2 f/hr, WOB 160 lbs. Work up to 20 fph averaging -900 lbs WOB with no apparent motor work. 10/27/2016 10/27/2016 4.00 PROM RPEQPT UREM T Under ream to 6455' PU Wt 38k lbs, 6,455.0 6,519.0 back ream to 6447'. RBIH, No WOB 00:00 04:00 seen until 6455'. Reaming ahead at - 20 fph averaging -800- 900 lbs WOB with no apparent motor work. Light cuttings at the shaker. 8 stalls at -6519 - 6516' getting shallower each stall. note previous drilling break when milling was at 6517-6530. 10/27/2016 1.50 PROM UREM T Continuing to stall, 10 total. 6512' PU 6,519.0 6,450.0 10/27/2016 Wt 58.3 k Lbs. back ream up hole to 04:00 05:30 6450'. 10/27/2016 0.80 PROD1 RPEQPT UREM T RBIH, stall multiple times @ 6,509'. 6,450.0 6,509.0 10/27/2016 Decision made to POOH &check UR 05:30 06:18 blades/body. 10/27/2016 1.70 PROD1 RPEQPT TRIP T POOH pumping min rate into tubing, 6,509.0 66.0 10/27/2016 open EDC, POOH pumping max rate. 06:18 08:00 Perform jog @ 500'. 10/27/2016 1.50 PROD1 RPEQPT RURD T PJSM, PUD BHA #4 (7" csg UR). 66.0 0.0 10/27/2016 08:00 09:30 10/27/2016 1.50 PROD1 RPEQPT RURD T Redress UR with new blades, re- 0.0 0.0 10/27/2016 configure BHA w new Weatherford 09:30 11:00 motor. 10/27/2016 10/27/2016 1.75 PROD1 RPEQPT RURD T PJSM, PD BHA #5 (7" csg UR). 0.0 66.0 11:00 12:45 10/27/2016 1.25 PROD1 RPEQPT TRIP T RIH BHA#5. 66.0 6,432.0 10/27/2016 12:45 14:00 10/27/2016 0.20 PROD1 RPEQPT DLOG T Tie-in K1 for +11.5' correction. 6,432.0 6,467.0 10/27/2016 14:00 14:12 PUW=47k. 10/27/2016 10/27/2016 2.00 PR0D1 RPEQPT UREM T RIH to 6,525', close EDC, back -ream 6,467.0 6,525.0 0.5 FPM, 1.5 BPM @ 3685 psi up to 14:12 16:12 6,510'. RIH and repeat. Ream down, stalling at 6,512'. Attempt higher pump rate (1.7 BPM), extreme vibration. 10/27/2016 10/27/2016 1.20 PROD1 RPEQPT UREM T RIH, back -ream trouble section twice 6,525.0 6,520.0 more. Ream down, stall 3 more times. 16:12 17:24 10/27/2016 10/27/2016 2.60 PROD1 RPEQPT UREM T RIH to 6,520' start down ream. Ream 6,520.0 6,540.0 to bottom, frequent stalls, trouble area, 17:24 20:00 6512'. PU Wt 50k lbs, PUH Wt 46k lbs. Page 4/29 Report Printed: 11/2812016 Operations Summary (with Timelog Depths) 2K-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time I Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftK8) End Depth (ftKB) 10/27/2016 10/27/2016 3.00 PROM RPEQPT UREM T Back ream to tubing tail @ 3 fpm. 6,540.0 6,445.0 20:00 23:00 Slight bobble — 6512', Turn around and ream to bottom at 1.5 fpm, 2 stalls at 6505, bypassed w pump down, restart at 6508, clean sailing. Stall at 6516, worked through to TD. Back ream to TT. Saw motor work spike at 6509 taperting off by 6495'. 10/27/2016 10/27/2016 0.30 PROM RPEQPT UREM T Down on the pumps, Pull UR back into 6,445.0 6,540.0 23:00 23:18 the tubing, no weight bobbles, RIH tag TD, dry, 10/27/2016 10/28/2016 0.70 PROM RPEQPT UREM T Open EDC, Pull up hole to TT while 6,540.0 6,429.0 23:18 00:00 pumping 1.8 bpm, CT 2915 psi, Wh 95 psi, PU wt 48 k lbs, PUH wt 46 k lbs. 10/28/2016 10/28/2016 0.30 PROM RPEQPT UREM T Shut down pumps, Close Choke, 6,429.0 6,466.0 00:00 00:18 perform injectivity test to 2500 psi, no leak off. Bleed down. 10/28/2016 10/28/2016 0.30 PROM RPEQPT UREM T RIH tie into K1 +3' correction, PUH, 6,429.0 6,466.0 00:18 00:36 paint white flag @ 6466. (100' from bottom on cement run) 10/28/2016 10/28/2016 1.30 PROM RPEQPT UREM T POOH pumping 1.8 bpm, 1/4-1/2" 6,466.0 77.0 00:36 01:54 pieces of cement and metal cuttings at the shaker. Jog @ 500', increase in cuttings amount and size, up to 1 ". Pictures on S drive 10/28/2016 10/28/2016 3.35 PROD1 RPEQPT UREM T PJSM, PUD BHA # 5, 7" casing under 77.0 0.0 01:54 05:15 reamer #2, clean rig floor. 10/28/2016 10/28/2016 1.30 PROM RPEQPT SQEZ T PJSM, make up BHA # 6, clean out / 0.0 15.0 05:15 06:33 cement nozzle. Change packoffs, MU injector. Tag-up, prep to RIH. 10/28/2016 10/28/2016 1.95 PROM RPEQPT SQEZ T RIH, set depth to painted flag, +14' 15.0 6,542.0 06:33 08:30 correction. Cont RIH. Tag-up early @ 6,519'. Work pipe to bottom, tag bottom. 10/28/2016 10/28/2016 1.25 PROD1 RPEQPT SQEZ T Pump 1 0x1 0 sweeps, chase up to TT 6,542.0 6,436.0 08:30 09:45 pumping 1.8 BPM (picture of sweep returns on S drive). Cement mixed at 0850. 8 hr and 8 min thickening time. 24 hr cure time. 10/28/2016 10/28/2016 1.75 PROM RPEQPT SQEZ T RIH, PU 2' off bottom. SLB pumping 5 6,436.0 6,540.0 09:45 11:30 bbls water, 9 bbls 16.5 ppg cement, 5 bbls water at 0.5 BPM, 1200 psi circ pressure. Rig pumping 20 bbl Hi-Vis spacer until 1.6 bbls of cement out the nozzle. Held back pressure with choke to maintain 1:1 returns. Well IA pressure stayed below 60 psi throughout pumping job. 10/28/2016 10/28/2016 0.75 PROD1 RPEQPT SQEZ T Start PUH while laying in cement at 6,540.0 4,696.0 11:30 12:15 0.5 BPM. Ramp up speed from 15 FPM to 104 FPM to match returns rate. All cement out nozzle @ 5,250'. Cont PUH to 4,700'. Close choke and pressure up to 1300 psi WHP (WHP during pumping —600 psi). Page 5/29 Report Printed: 11128/2016 Operations Summary (with Timelog Depths) 2K-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code RPEQPT Activity Code SQEZ Time P -T -X T Operation RIH pumping 0.5 BPM to contaminate (ftKB) 4,696.0 End Depth (MEI) 15.0 10/28/2016 10/28/2016 2.00 PROD1 cement down to 6,407'. Increase 12:15 14:15 pump rate to 1.8 BPM. Hi -Vis pill out of nozzle, begin PUH (PUW=35k) washing cement out of hole. Returns to TT. 12.3 ppg slug seen on MM with bottoms up. 10/28/2016 10/28/2016 1.75 PROD1 RPEQPT SQEZ T Close master, flow check while PJSM 15.0 0.0 14:15 16:00 for LD BHA #6 (nozzle), replace UQC, test Eline. Test as good as seen previously. 10/28/2016 10/28/2016 2.00 PROD1 RPEQPT CIRC T Pump cement contamination pill 0.0 0.0 16:00 18:00 through surface lines and jet BOP stack follow with SW to prep for BOPE test. 10/28/2016 10/29/2016 6.00 PROD1 RPEQPT CIRC T PJSM, Lock out, Open BOP rams 0.0 0.0 18:00 00:00 inspect / clean same. Replaced upper and lower blind rams. 10/29/2016 10/29/2016 5.50 PROD1 RPEQPT CLEN T Inspect / clean upper and lower 2 3/8" 0.0 0.0 00:00 05:30 rams. Replace 9 of 12 ram door seals. Re -torque BOP bolts. Valve Crew serviced tree. 10/2910/29 /2016 10/29/2016 3.70 PROD1 WHDBOP RURD T Fill stack, shell test to 4,700 psi. Two 0.0 0.0 09:12 door seals leaking on stack. Replace. Total of 11 of 12 door seals replaced. 10/29/2016 10/29/2016 0.80 PROD1 WHDBOP RURD T Shell test to 4,700 psi again. Fail, 0.0 0.0 09:12 10:00 leaking ODS upper blind ram door seal. CO again (had rolled on previous installation). 10/29/2016 10/29/2016 8.50 PROD1 WHDBOP BOPS P Shell test to 25014,700 psi. Pass. 0.0 0.0 10:00 18:30 Start BOP test 25014,700 psi (2,500 psi on annular). No failures. "°AOGCC inspector, Jeff Jones, waived witness at 16:04 on 10/28/2016 via e-mail." 10/29/2016 10/29/2016 2.50 PROD1 RPEQPT MILL T Open master to 200 psi. Bleed 0.0 67.0 18:30 21:00 pressure , monitor, no increase. Open swabs, start no flow test. PJSM, no flow test good. Reinstall quick test sub, install CT nozzle, stab on, PT quick test sub union, good, pop off. Make up BHA #7, cement pilot hole mill. ( Mill 2.79" NG) "'HES crew inspected/tested cable for real time caliper and confirmed camera XO connection. Ready to run real time calipers. 10/29/2016 10/30/2016 3.00 PROD1 RPEQPT MILL T RIH, open EDC, pump 5 bbl pill and 67.0 6,409.0 21:00 00:00 swap from used milling fluid to new milling fluid while tripping in hole. Tie into gamma ray log from 6175-6291' for +15 foot correction. Close EDC, Wt Ck 42k lbs. RIH, 10/30/2016 10/30/2016 0.20 SLOT WELLPR MILL T Dry tag TOC 6409'. POH, PU Wt 42 k 67.0 6,409.0 00:00 00:12 lbs. Bring pumps up to 1.8 bpm, Circ 2766 psi, free spin diff, 406 psi, RBIH, Page 6/29 Report Printed: 11/28/2016 Operations Summary (with Timelog Depths) 2K-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Star/ Depth Start Time End Time Dur (hr) Phase Op Code Activity Code MILL Time P-T-X T Operation Milling pilot hole, 6410' ROP 26 fph, (ftKB) 6,409.0 End Depth (ftKB) 6,438.0 10/30/2016 10/30/2016 2.00 SLOT WELLPR WOB 1.33 klbs, Circ 3095 psi, 760 psi 00:12 02:12 diff. 5 stalls at 6425, 6429, 6437A again at 6437'. Pu Wts at 47 k lbs. Rotated TF to 160 left, ROP 12 f/hr, 626 psi diff, WOB 1.3 k lbs. 10/30/2016 10/30/2016 2.00 SLOT WELLPR MILL T Orient TF back to 20 right. Mill ahead 6,438.0 6,463.0 02:12 04:12 Circ 2700 psi, WOB 1.2k lbs, ROP 12 f/hr, diff 670 psi. ROP picked up to 22 f/hr after 6443', WOB 1.67 k lbs. 10/30/2016 10/30/2016 0.80 SLOT WELLPR MILL T Mill ahead Circ 3000 psi, 1.67 bpm, 6,463.0 6,481.0 04:12 05:00 WOB 1.4 k lbs, ROP 22 f/hr, diff 670 psi. 10/30/2016 10/30/2016 0.25 SLOT WELLPR WPRT T BHAwiper, PUW=51k. 6,481.0 6,481.0 05:00 05:15 10/30/2016 10/30/2016 2.50 PROD1 RPEQPT MILL T Milling ahead, 1.7 BPM @ 2860 psi 6,481.0 6,550.0 05:15 07:45 FS, WOB 2k, ROP 30. Couple stalls @ 6,540', worked through to TD. 10/30/2016 10/30/2016 0.75 PROD1 RPEQPT DLOG T PUH (PUW=50k), tie-in to K1 for +3' 6,550.0 6,460.0 07:45 08:30 correction. RIH, confirm TD @ 6,553'. Pumping 0.3 BPM. PUH, dry drift to TD, WOB 0.9k @ 6,443'. PUH. 10/30/2016 10/30/2016 0.25 PROD1 RPEQPT MILL T Backream up 1 FPM and ream down 5 6,460.0 6,462.0 08:30 08:45 FPM twice w TF LS, once with TF 160°LOHS. Dry drift transition area, WOB 0.9k @ 6,442'. 10/30/2016 10/30/2016 2.60 PROD1 RPEQPT TRIP T POOH. Jog from 237' to 500'. Cont 6,462.0 70.0 08:45 11:21 POOH. Spaceout. 10/30/2016 10/30/2016 0.40 PROD1 RPEQPT OWFF T OWFF - good no flow test. 70.0 70.0 11:21 11:45 10/30/2016 10/30/2016 0.75 PROD1 RPEQPT RURD T PJSM, LD BHA #7 (mill maintained 70.0 0.0 11:45 12:30 2.79" NoGo) 10/30/2016 10/30/2016 0.50 PROD1 RPEQPT CIRC T Jet BOP stack. Small chunks of 0.0 0.0 12:30 13:00 cement in returns. 10/30/2016 10/30/2016 0.70 PROD1 RPEQPT DLOG T PJSM, MU BHA#8 (real-time caliper). 0.0 26.0 13:00 13:42 10/30/2016 10/30/2016 1.60 PROD1 RPEQPT TRIP T RIH W Real time HES caliper. Tie in 26.0 6,433.0 13:42 15:18 W Hal. 10/30/2016 10/30/2016 0.50 PROD1 RPEQPT DLOG T Log cement pilot hole, 3 passes. 6,433.0 6,540.0 15:18 15:48 10/30/2016 10/30/2016 1.30 PROD1 RPEQPT TRIP T POOH W BHA #8 6,540.0 26.0 15:48 17:06 10/30/2016 10/30/2016 1.00 PROD1 RPEQPT PULD T Flow Check, PJSM, Lay down BHA 26.0 0.0 17:06 18:06 #8, HES caliper. 10/30/2016 10/30/2016 2.20 PROD1 RPEQPT PULD P High side whipstock, PJSM, PU BHA 0.0 74.0 18:06 20:18 # 9, Baker 3 112 monobore XL Whipstock, surface test tool, open EDC, tag up. 10/30/2016 10/30/2016 2.00 PROD1 RPEQPT TRIP P RIH W whipstock @ 80 fpm. Wt Ck 74.0 6,520.0 20:18 22:18 46.9 k lbs. Tie into the K1 for a + 13' correction. 10/30/2016 10/30/2016 0.20 PROD1 RPEQPT WPST P Off the pump, Close EDC. RIH wt 13 74.0 6,520.0 22:18 22:30 k lbs in pilot hole. PU 5520.55, Oriented 10 LOHS. Roll the pumps, pressure broke back @ 4700 psi. Stacked weight5.7 k lbs, good. Set Whipstock. Page 7/29 Report Printed: 11/28/2016 Operations Summary (with Timelog Depths) 2K-11 Job: DRILLING SIDETRACK Rig: NABORS CDR3-AC Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) 6,520.0 End Depih (ftKB) 64.0 10/30/2016 10/30/2016 1.20 PROD1 RPEQPT TRIP P POOH 22:30 10/30/2016 23:42 10/31/2016 0.30 PROD1 RPEQPT PULD P @Surface 64.0 64.0 23:42 10/31/2016 00:00 10/31/2016 1.70 PROD1 RPEQPT PULD P PJSM, No flow test, - good, lay down 64.0 0.0 BHA #9, whipstock running BHA. 00:00 10/3110/31 !2016 01:42 10/31/2016 2.00 PROD1 WHPST PULD P PJSM, PU BHA #10, window milling 0.0 74.0 assembly. String mill 2.80" NoGo, 03:42 Window mill 2.80" NoGo. Surface test tool, tag up, open EDC. 10/31/2016 10/31/2016 1.75 PROD1 WHPST TRIP P RIH, EDC open, Tie in at K1 for+13' 74.0 6,459.0 03:42 05:27 correction. 10/31/2016 10/31/2016 0.80 PROD1 WHPST CIRC P Displace wellbore to used FloPro mud 6,459.0 6,436.0 system for milling window. Close EDC. 05:27 06:15 Wt check, PUW=40k, RIH. 10/3110/31 /2016 10!31/2016 8.25 PROD1 WHPST WPST P Dry tag TOWS @ 6,510'. Mill window 6,436.0 6,531.0 10°LOHS, 1.78 BPM @ 4450 psi FS, 14:30 0.7 - 3.Ok WOB, ROP 1 increasing slowly to 6 FPH as worked through casing into formation. 10/31/2016 10/31/2016 1.00 PROD1 WHPST REAM P PUH, PUW=37k. Ream up through 6,531.0 6,501.0 window three times at 1 FPM (10° 14:30 15:30 LOHS, 30°ROHS, 40°LOHS) 10/31/2016 10/31/2016 2.00 PROD1 WHPST TRIP P Dry drift window twice. Slight WOB 6,501.0 74.0 bobble first time. PUH, pump 5x5 15:30 17:30 sweeps. Jog back in hole 40 FPM, stop, open EDC. Resume pumping and POOH. Switch over to hi -line power. Cont POOH. Spaceout. Close EDC. 10/31/2016 10/31/2016 2.00 PROD1 WHPST FTU LD P Flow check, PJSM, LD BHA #10. 74.0 0.0 17:30 19:30 SIM OPS: Blowdown/clean Choke A 10/31/2016 10/31/2016 1.50 PROD1 WHPST CIRC P Jet BOP stack. Open manual valves 0.0 0.0 19:30 21:00 on stack and pump through to clean. 10/31/2016 10/31/2016 1.50 PROD1 DRILL -L D P PJSM, PU BHA#11 (build section, RB 0.0 72.0 21:00 22:30 HCC + 2.4° AKO motor). 11/1/2016 1.50 PROD1 DRILL TRIP P RIH, swap well over to new FLO=PRO 72.0 6,531.0 10!31/2016 SF, Tie in to K1 for +9' correction. 22:30 00:00 Close EDC. 11/1/2016 11/1/2016 4.00 PROD1 DRILL DRLG P bpm, free spin - 420 psi, CT 6,531.0 6,568.0 42121 2 psi OBD, ROP 4, WOB 1.65k 00:00 04:00 lbs. CT wt 11.4 k lbs. 11/1/2016 11/1/2016 2.00 PROD1 DRILL DRLG P DD build section, 1.7 bpm, CT 4300 6,568.0 6,635.0 psi, WH 600 psi, RROP 17 f/hr, WOB 04:00 06:00 1 k lbs, PU to rotate tool, against stops, PU Wt, 41 k lbs. BHA out window, Target WOB 2.5 to 3k lbs. 11!1/2016 11/1/2016 0.50 PROD1 DRILL DRLG P PUH Log /Tie into K1 and RA tag. 6,635.0 6,635.0 06:00 06:30 PU Wt 40 k lbs. 6544 RBIH, 11/1/2016 11/1/2016 1.20 PROD1 DRILL DRLG P BOBD, 1.8 bpm, Ct 4800 psi, Wh 245 6,568.0 6,692.0 psi, CT Wt 11.6 k lbs, WOB 2.4 k lbs, 06:30 07:42 ROP 141 f/hr. 935 psi diff. 11/1/2016 11/1/2016 2.00 PROD1 DRILL TRIP P Unable to make required dog leg 6,692.0 6,692.0 POOH, PU Wt 49 k lbs, Consult W 07:42 09:42 town, evaluate options while circulating. RBI Page 8/29 Report Printed: 1 112 812 01 6 Operations Summary (with Timelog Depths) 2K-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code DRLG Time P -T -X P Operation BOBD, Adjusted landing point, 1.4 (MB) 6,692.0 End Depth (ftKB) 7,048.0 11/1/2016 11!1/2016 / 8.00 PROM DRILL bpm, CT 3774 psi, WH 467, CT Wt 09:42 1I/ 12k lbs, WOB 1.88 k lbs, ROP 30 f/h. Land build section at 6790 ft (6175 ft TVD), invert and drill upward. Surging choke, most likely blockage, swapped from A to B. BHA wipers at 7048 11/1/2016 11/1/2016 0.30 PROD1 DRILL WP P Stacking wt, make short wiper trip to 7,048.0 7,048.0 17:42 18:00 6850', 40K PUW, 11/1/2016 11!1/2016 1.50 PROD1 DRILL DRLG P Drill to 7112', stacking wt, short BHA 7,048.0 7,125.0 18:00 19:30 wiper, continue to drill to 7125 ft, 11/1/2016 11/1/2016 0.50 PROD1 DRILL WPRT P Pull wiper trip while Geologists consult 7,125.0 7,125.0 19:30 20:00 town for EOB decission, 41 K PUW, wiper to 6600' and back to 6970' when decission was made to POOH 11/1/2016 11/1/2016 1.80 PROM DRILL TRIP P EOB called at 7125', Pull back thru 7,125.0 72.6 20:00 21:48 window, open EDC at 6370', Trip for Lateral BHA, jog at surface from 200 to 500', bump up. 11/1/2016 11/2/2016 2.20 PROM DRILL PULD P Hold PJSM, PUD Build section BHA 72.6 0.0 21:48 00:00 #11. 11/2/2016 11/2/2016 2.20 PROD1 DRILL PULD P Hold PJSM, PU & pressure deploy 0.0 72.2 00:00 02:12 BHA #12 with 0.45° AKO motor with New style HCC, 3.0" bi-center bit. Back flush both chokes A & B. 11/2/2016 11/2/2016 2.50 PROD1 DRILL TRIP P Trip in with EDC open, following MP 72.2 6,420.0 02:12 04:42 schedule. 11/2/2016 11/2/2016 0.20 PROM DRILL DLOG P Log K1, +8 ft correction 6,420.0 6,464.0 04:42 04:54 11/2/2016 11/2/2016 1.00 PROD1 DRILL TRIP P Close EDC, trip in thru build section at 6,464.0 7,125.0 04:54 05:54 min rate, 50 FPM, SD at 6705', work down to 6737', work pipe, bleed pump pressure off, pull 70K to get free, work tight area, try running in at 1 BPM, 11/2111/2/ 2016 11!2/2016 3.50 PROD1 DRILL DRLG P BOBD, 1.7 bpm, CT 4833 psi, WH 7,125.0 7,434.0 09:24 350 psi, CT Wt 7.8k , WOB 2.25k lbs, ROP 116 f/hr. Sharp drilling break from 7343 - 7351, ROPs 250-300 f/hr. Passed suspected fault@ 7350'. Coil weight falling off starting around 7200', snubbing. Well continues to give up frac sand, Started approx. 7125' bit depth. 11/2/2016 11/2/2016 4.40 PROD1 DRILL DRLG P Drilling ahead, 1.77 bpm, CT 5070 psi, 7,434.0 7,625.0 09:24 13:48 WH 528, holding 12.0 ppg managed pressure, CT wt -5.5 k lbs, WOB 2.57 k lbs, ROP 42 f/hr. Raining carbolite across the shakers. ROP dropped, 7580-90, suspect ankerite. Drilling break, 7590' then suspect ankerite again at 7613 11/2/2016 11/2/2016 0.40 PROM DRILL WPRT P PUH, PU weight, 44 k lbs, Trip #1 7,625.0 6,900.0 13:48 14:12 11/2/2016 11/2/2016 0.20 PROD1 DRILL WPRT P RBIH 6,900.0 7,625.0 14:12 14:24 Page 9/29 ReportPrinted: 11128/2016 F Operations Summary (with Timelog Depths) 2K-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code DRLG Time P -T -X P Operation BOBD, 1.85 bpm, Ct 4186, WH 530, (W) 7,625.0 End Depth (ftKa) 8,125.0 11/2/2016 11/2/2016 6.20 PROD1 DRILL CT Wt -5.0 k lbs, WOB 1.64k lbs, ROP 14:24 20:36 45- 230 f/hr, drill ahead to 8100' 11/2/2016 11/2/2016 0.40 PROD1 DRILL WPRT P Planned wiper#2, 55K PUW 8,125.0 7,125.0 20:36 21:00 11/2/2016 11/2/2016 0.70 PROD1 DRILL WPRT P RBIH to 8050', wiper up per Geo's 7,125.0 8,125.0 21:00 21:42 while awaiting new targets, RBIH 1112/2016 11/3/2016 2.30 PROD1 DRILL DRLG P Drill ahead, 1.56 bpm, 4285 CP, 615 8,125.0 8,260.0 21:42 00:00 WHP, 4200 BHP, 542 dP, 2.6K CWT, 0.9K WOB, AVG ROP 60 FPH, Small drilling breaks at 8165', 8188' and 8231' 11/3/2016 11/3/2016 1.10 PROD1 DRILL DRLG P Drilling ahead to 8310 ft. 8,260.0 8,310.0 00:00 01:06 11/3/2016 11/3/2016 0.40 PROD1 DRILL WPRT -T-Magnetic interference, unable to get 8,310.0 8,310.0 01:06 01:30 survey 11/3/2016 11/3/2016 1.90 PROD1 DRILL DRLG P Drilling, avg ROP 25 ft/hr. 8,310.0 8,359.0 01:30 03:24 11/3/2016 11/3/2016 0.40 PROD1 DRILL WPRT P Wiper up to 8230 ft, 51 K PUW, while 8,359.0 8,359.0 03:24 03:48 Geo's dicuss invert log and targets. RBIH to drill 11/3/2016 11/3/2016 3.00 PROD1 DRILL DRLG P Drill at 1.7 bpm,-1Kwith 1K WOB, 8,359.0 8,464.0 4650 CP, 750 WHP, 4160 BHP, 560 03:48 06:48 dP, 45 ft/hr ROP. Swap to new mud system #2. New mud at bit 11/3/2016 11/3/2016 1.80 PROD1 DRILL DRLG P New off bottom diff, - 370 psi. 1.55 8,464.0 8,475.0 06:48 08:36 bpm, CT 4235 psi, WH 881. Wt -4 k lbs, WOB 1.9 k lbs, ROP 3.4 f/hr. Pump 10/10 sweep, 11/3/2016 11/3/2016 1.00 PROD1 DRILL WPRT P Long wiper PU Wt, 53, dry PU. PUH 8,475.0 6,435.0 08:36 09:36 chasing 10/10 sweep. Sent 5x5 timed for the sump. Lots of frac sand back on the bottoms up sweep. Worked pipe / pumps through 7800-7700. Pulled 60 k lbs, worst of it 6780- 6695'. RBIH, min rate, clean, PUH same issues, pulling negative 4-5k lbs WOB, Motor work (torqueing up), & annular packing off. PUH. 11/3/2016 11/3/2016 1.20 PR651 DRILL DLOG P Open EDC, circulate bottoms up, lots 6,435.0 6,516.0 09:36 10:48 of large shale at the shaker. Close EDC, RBIH min rate to window. Pump up to 12.1 ppg at the window, BHP 3888 psi leaked off to 3868 and stabilized. RIH, tie in W/ RA tag for + 14.5' correction. Reset injector software. 11/3/2016 11/3/2016 1.10 PROD1 DRILL TRIP P RBIH, 6,516.0 8,485.0 10:48 11:54 11/3/2016 11/3/2016 2.30 PROD1 DRILL DRLG P 13013D,Brod, holding 12.1 ppg at the 8,485.0 8,536.0 11:54 14:12 window. off bottom diff 395 psi, 1.50 bpm, CT 3977 psi, WH 992 psi. CT Wt -7.2k lbs, WOB 1.56 k lbs, ROP 23 ft/hr. Page 10129 Report Printed: 1 112812 01 6 Operations Summary (with Timelog Depths) fir...., 2K-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code DRLG Time P-T-X P Operation Packed off the annulus, WOB to zero, (ftKB) 8,536.0 End Depth (ftKB) 8,500.0 11/3/2016 11/3/2016 0.20 PROD1 DRILL pulling heavy to 65k lbs, working pipe 14:12 14:24 while lining up across the top to pump down both coil and the back side. Note' checks do not appear to be holding. Reestablish circulation path and work pipe slowly up hole Ct Wt 45 k lbs. 11/3/2016 11/3/2016 0.40 PROD1 DRILL WPRT P Pulled wiper trip waiting for bottoms 8,500.0 7,800.0 14:24 14:48 up. No influx, fine cuttings comming across the shaker. 11/3/2016 11/3/2016 0.30 PROD1 DRILL WPRT P RBIH 7,800.0 8,536.0 14:48 15:06 11/3/2016 11/3/2016 5.20 PROD1 DRILL DRLG P BOBD, 1.6 bpm, CT 4249 psi, WH 804 8,536.0 8,668.0 15:06 20:18 psi, CT wt 1 k lbs, WOB 0.64, ROP 14 f/hr. Pumped 30 bbl beaded pill, 1 ppb alpine beads, see some improvement in weight transfer, 5.8K SOW, 1 K WOB, 20 to 50 ROP. Continue drilling with short wipers 11/3/2016 11/3/2016 0.40 PROD1 DRILL WPRT P Wiper up to 8470', 51 K PUW, 8,668.0 8,668.0 20:18 20:42 11/3/2016 11/3/2016 1.80 PROD1 DRILL DRLG P BOBD, 1.52 bpm, 3950 CP, 837 WHP, 8,668.0 8,704.0 20:42 22:30 -3.5K CW, 1.0 WOB, 25 ft/hr ROP. 11/3/2016 11/3/2016 0.50 PROD1 DRILL WPRT P Wiper up to 8400', 51K PUW, RBIH 8,704.0 8,704.0 22:30 23:00 11/3/2016 11/4/2016 1.00 PROD1 DRILL DRLG P BOBD, 1.50 bpm, 3987 CP, 813 WHP, 8,704.0 8,734.0 23:00 00:00 4K CW, 1 K WOB, 26 ft/hr ROP 11/4/2016 11/4/2016 1.25 PROD1 DRILL DRLG P BOBD, 1.50 bpm, 3987 CP, 813 WHP, 8,734.0 8,750.0 00:00 01:15 -4K CW, 1 K WOB, 26 ft/hr ROP. 11/4/2016 11/4/2016 0.50 PROD1 DRILL WPRT P PU off bottom, Pumped 10 bbl Alpine 8,750.0 8,750.0 01:15 01:45 beaded pill w/ Lubes (2.5% Lube 776 and 2.5% Lo-Torque), active system has 1 % Lube 776 11/4/2016 11/4/2016 3.25 PROD1 DRILL DRLG P 1.40 bpm, 3890 744 WH, 8,750.0 8,855.0 01:45 05:00 OAKBOBD,C ft/ 0.4K CW, 1.3K WOB, 45 ft/hr, improvment in weight transfer and ROP, see drilling break 8820' cutting down to the top of the lower A4 lobe, pull short wiper at 8829 ft due to vibration, geo steer up for final cross cut to planned TD. 11/4/2016 11/4/2016 1.90 PROD1 DRILL DRLG P Poor weight transfer, ct Wt 4 k lbs, 8,855.0 8,881.0 05:00 06:54 WOB .6k lbs, struggling to RIH. 11/4/2016 11/4/2016 2.20 PROD1 DRILL WPRT P n Pull wiper#2 early. Towrequested 8,881.0 6,385.0 06:54 09:06 wiper to window to clean sump of build section. Send 1 0x1 0 sweeps. POOH wts up to 51 k while pulling through the build, slight motor work and a couple spikes of negative bit weight. Hole appeared relatively clean. Opened EDC, chased cuttings out at 1.85 bpm. Received a good amount of cuttings at the shaker as the hi vis landed. Mostly drill cuttings, very few pieces of shale, (.25 -.4"). Page 11/29 Report Printed: 11/28/2016 - Operations Summary (with Timelog Depths) 2K-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftK8) 11/4/2016 11/4/2016 0.90 PROM DRILL DLOG P Tie into the K1 for a + 12correction. 6,385.0 6,450.0 09:06 10:00 Close EDC. Wt Ck 39.5 k lbs, Calibrate pressure above the window 6450 md, 6124 tvd, 4061 psi 12.75 equivalent MW. 11/4/2016 11/4/2016 1.00 PROD1 DRILL TRIP P RBIH, slight weight bobbles running 6,450.0 8,881.0 10:00 11:00 through the build. Stripper leaking, packing off. 11/4/2016 11/4/2016 0.50 PROM DRILL DRLG P BOBD, struggling to get weight on bit, 8,750.0 8,890.0 11:00 11:30 continuing to have stripper issues, 1000 psi wellhead, holding 2500 psi on stripper to maintain seal. 11/4/2016 11/4/2016 2.70 PROD1 DRILL TRIP T PUH to 6396' to change out stripper 8,890.0 8,883.0 11:30 14:12 pack offs. Down on the pump, monitor BHP, stable, shut 2" pipe rams, shut annular, bleed off at the stump. Replace pack off and extrusion rings. PT, open rams, open annular, RBIH. Tie into the RA tag for a + 3.5 correction. continue to RIH. 11/4/2016 11/4/2016 1.80 PROM DRILL TRIP P Try multiple times to get back on 8,883.0 8,887.0 14:12 16:00 bottom, coil in lock up with drilling pump rate. Prep and pump 10 bbl lube pill, 2.5 x 2 low torque/776. Lubes around, able to slide again, snubbing -3 k lbs, 1 k lbs, WOB 17 f/h r. 11/4/2016 11/4/2016 1.40 PROM DRILL WPRT P 1.45 bpm, CT 4220 psi, WH 874 psi, 8,887.0 8,890.0 16:00 17:24 CT Wt -7.7 k lbs, 1.14 k lbs WOB, ROP 17. Locked up, unable to get back on bottom, pumped another 10 bbl lube pill, add lubes to active system 2.25% L776 x 1.75% LTQ. 11/4/2016 11/4/2016 1.20 PROD1 DRILL DRLG P BOBD, snubbing -2K to -7K CW, 0.8K 8,890.0 8,917.0 17:24 18:36 WOB, struggle to get WOB, 11/4/2016 11/4/2016 0.30 PROM DRILL TRIP P PU for BHA wiper try to get pipe to 8,917.0 8,917.0 18:36 18:54 slide. 11/4/2016 11/4/2016 3.00 PROM DRILL DRLG P OBD w/ -3K to -7K CW, 0.5 - 1 K WOB 8,917.0 8,954.0 18:54 21:54 11/4/2016 11/4/2016 0.40 PROD1 DRILL WPRT P Wiper trip to get weight transfer, 51K 8,954.0 8,954.0 21:54 22:18 PUW, tried to turn around at 8865' and 8837, pulled up to 8700' to get RIH. 11/4/2016 11/4/2016 0.70 PROM DRILL DRLG P BOBD, 1.5 bpm, 4470 psi CP, -7.5K 8,954.0 8,966.0 22:18 23:00 CW, 1 K WOB, 15-25 ft/hr ROP 11/4/2016 11/4/2016 0.50 PROM DRILL WPRT P Wiper trip to get weight transfer, 52K 8,966.0 8,966.0 23:00 23:30 PUW, tried to turn around at 8865' and 8837, pulled up to 8700' to get RIH. 11/4/2016 11/5/2016 0.50 PROD1 DRILL DRLG P BOBD, 1.40 bpm, 4330 psi CP, -8K 8,966.0 8,974.0 23:30 00:00 CW, 0.6K WOB, 10-20 ft/hr ROP 11/5/2016 11/5/2016 1.80 PROM DRILL DRLG P Continue OBD, 1.42 bpm, 4325 psi 8,974.0 9,001.0 00:00 01:48 CP, 925 psi WHP, -7K CW, 0.9K WOB 11/5/2016 11/5/2016 0.50 PROM DRILL WPRT P Wiper trip, weight transfer, 52K PUW, 9,001.0 9,001.0 01:48 02:18 pulled up to 8700', RIH. 11/5/2016 11/5/2016 2.50 PROD1 DRILL DRLG P OBD, 1.45 bpm, 4316 psi CP, 900 psi 9,001.0 9,015.0 02:18 04:48 WHP, -9.5K CW, 1.2K WOB, less than 10 fUhr ROP. Page 12129 ReportPrinted: 11/28/2016 r Operations Summary (with Timelog Depths) 2K-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (MB) End Depth (ftKB) WPRT T Wiper up while BHI troubleshoots lost 9,015.0 9,015.0 11/5/2016 11/5/2016 0.20 PROD1 DRILL 04:48 05:00 comms with RigLink. 11/5/2016 11/5/2016 3.00 PROM DRILL DRLG P OBD, 1.44 bpm, 4315 psi CP, 911 psi 9,015.0 9,035.0 05:00 08:00 WHP, -9K CW, Drilling ankerite, at 1.7 f/hr w low diff pressure and 1.1 k lbs on bit, break out @ 9020'. 1.4 bpm, CT 4317 psi, CT wt -5.88 k lbs, WOB 1 klbs, ROP 23 f/hr. 11/5/2016 11/5/2016 3.00 PROM DRILL DRLG P OBD, 1.44 bpm, 4315 psi CP, 911 psi 9,035.0 9,048.0 08:00 11:00 WHP, -9K CW. Continuing to encounter ankerite stringers and low ROPs. " Town called TD early. 11/5/2016 11/5!2016 0.90 PROM DRILL TRIP P PUH to 8697', start 10 /10 low/ high 9,048.0 9,048.0 11:00 11:54 vis sweeps down coil. RBIH, tag,sweeps at the bit, Pick up, PU Wt 50 k lbs. Chase sweeps out of hole. 11/5/2016 11/5/2016 1.60 PROM DRILL TRIP P PUH to build section. Pull heavy, 53 k 9,048.0 6,523.0 11:54 13:30 lbs @ 6632', turn around, 6720 WOB spike. Work pipe between 6600 and 6800 with diminishing over pulls and motor work. 11/5/2016 11/5/2016 0.60 PROM DRILL DLOG P Tie into the RA maker for a + 19' 6,523.0 2030. 13:30 14:06 correction, pull through window, clean, open EDC 1.9 bpm, CT 4439 psi. Getting lots of cuttings at the shaker, swapped from choke A to B, some smaller pea gravel sized cuttings, -1/4" at the shaker, mosty fine silt. 11/5/2016 11/5/2016 1.60 PROD1 DRILL TRIP P POOH, jog coil 300' silt and some 203.0 74.0 14:06 15:42 gravel at the shaker, POOH, tagged up at surface 11/5/2016 11/5/2016 1.50 PR0D1 DRILL TRIP P Trip in hole 74.0 6,461.0 15:42 17:12 11/5/2016 11/5/2016 0.30 PROD1 DRILL DLOG P Tie in at K1 for+ 1.5' correction, close 6,461.0 6,461.0 17:12 17:30 EDC, pressure calibration at 6461 ft, trap 4100 psi BHP, watch for 10 min, pressure decreased to 4075 psi. 11/5/2016 11/5/2016 1.80 PROM DRILL TRIP P Continue to RIH, sat down worked 6,461.0 9,048.0 17:30 19:18 through tight spots at 6650, 6760 ft, back ream pass to 6600 ft, continue to RIH, tight spot at 7670 ft. Tag at 9058 ft. 11/5/2016 11/5/2016 3.20 PROD1 DRILL TRIP P Trip out, laying in 30 bbls of Hi Vis 9,048.0 83.5 19:18 22:30 13.0 ppg K -Formate with alpine beads, 2% Klaystop, 2% Safe Lube, followed by 13 ppg K -Formate KWF. Perform jog at the tubing tail 6420 to 6480ft. Stops to paint EOP flag at 6602 ft and window flag at 3972 ft, continue to surface, bump up at 83.5 ft. 11/5/2016 11/5/2016 -0 50 FR0D1 DRILL OWFF P Observe well for 30 min. 83.5 83.5 22:30 23:00 11/512016 11/6/2016 1.00 PROD1 DRILL RURD P PJSM, LD BHA #12 over dead well 83.5 0.0 23:00 00:00 11/6/2016 11/6/2016 0.50 PROD1 DRILL BOPE P PJSM, pick up and run safety joint, 0.0 0.0 00:00 00:30 function test BOPE, no failures, lay down test joint Page 13/29 Report Printed: 1 112 8/2 01 6 Operations Summary (with Timelog Depths) x +'_ 2K-1 1 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/6/2016 11/6/2016 0.40 COMPZ1 CASING PUTB P PJSM on PU and run 13 joints of 2- 0.0 387.0 00:30 00:54 3/8" ST -L slotted liner, stop for BOP drill. 11/6/2016 11/6/2016 0.30 COMPZ1 CASING SFTY P BOP Drill "Running Liner", PU safety 387.0 400.0 00:54 01:12 joint, MU, RIH to space out. 3.5 min response. Debrief in doghouse with crew. While preping to pull out safety joint, observed flow from well. 11/6/2016 11/6/2016 0.80 COMPZ1 CASING TRIP T Closed SSSV, consult town engineer, 400.0 208.0 01:12 02:00 decision to pull out with 13 jnts of liner. Pulled and laydown 7 jnts of liner, directed to shut BOP and monitor SITP. 11/6/2016 11/6/2016 1.00 COMPZ1 CASING OWFF T MU test joint, close upper/lower 2-3/8" 208.0 208.0 02:00 03:00 rams, close TIW, open to WC chk 1 and monitor. SITP built 50 psi and stabilized at 30 min. Continue to monitor, consult town. Plan forward to weight up to potassium formate to 13.1 ppg. ***Note WSR time does not accout for 1 hr falling back, daylight savings time. 11/6/2016 11/6/2016 1.50 COMPZ1 CASING PULD T Install new floats in UQC and PU BHA 208.0 208.0 03:00 04:30 #13. 11/6/2016 11/6/2016 1.00 COMPZ1 CASING PULD T PD BHA#13, bump up at surface 208.0 208.0 04:30 05:30 11/6/2016 11/6/2016 1.70 COMPZ1 CASING TRIP T RIH, start weighting up 12.88 K- 208.0 6,601.0 05:30 07:12 formate kill weight to 13.1 ppg. Lost 9.1 bbls to the formation while RIH. 11/6/2016 11/6/2016 2.60 COMPZ1 CASING OWFF T Bleed wellhead to zero and monitor, 6,601.0 6,601.0 07:12 09:48 60 psi gain in 20 minutes, Pressure started decreasing, at 60 min, WHP is at 42 psi gain over starting pressure. Isolate and zero gauge. Open back up to gauge, WH reading zero. Rig up manual gauge to the stump, also reads zero, Open bleeder at the stump, no flow for a minute, 1 teaspoon flow. S/1 gauge still zero. 11/6/2016 11/6/2016 2.50 COMPZ1 CASING OWFF T Continue to build 13.1 kill mud in pit, 6,601.0 6,601.0 09:48 12:18 de inventory process pit, line up to circulate in kill weight fluid. Pump across the top to fill well, no discernable losses. 11/6/2016 11/6/2016 1.70 COMPZ1 CASING CIRC T Line up to pump down coil w/ 13.1 kill 6,601.0 6,601.0 12:18 14:00 weight K -Formate. Start pumping 0.5 bpm, caught fluid pressure and wellhead @ 2.46 bbls away. Adjusting choke and pump rate to maintain returns. lost 8.6 bbls to the formation in 38 pumped. 11/6/2016 11/6/2016 3.50 COMPZ1 CASING CIRC T 13.1 ppg kill weight mud at the nozzle, 6,601.0 6,601.0 14:00 17:30 zero pit G/L (7 bbls past theoretical bottoms up, considering losses at 17:30, 68.28 bbls out 13.00 ppg mw out) 11/6/2016 11/6/2016 2.25 COMPZ1 CASING CIRC T 13.1 ppg kill weight mud at surface, at 6,601.0 6,601.0 17:30 19:45 104 bbls IN MM vol. shut down, G/L= - 19.4 bbls. Page 14129 ReportPrinted: 1 1 /2812 01 6 - Operations Summary (with Timelog Depths) e 2K-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start TimeEnd Time Dur (hr) Phase Op Code Activity Code OWFF Time P -T -X T Operation Closed MP Chk B, Monitor WH (MB) 6,601.0 End Depth (ftKB) 6,601.0 11/6/2016 11/6/2016 1.25 COMPZ1 CASING pressure with Whitey on stump closed 19:45 21:00 for 30 min, 0 psi, Open Whitey to half drum and monitor for 30 min, no flow observed, consult town, stick with plan to POOH 11/6/2016 11/6/2016 1.10 COMPZ1 CASING KLWL T' Formate falling out in pits, down to 13 6,601.0 6,601.0 heavy, weighting up formate back to 21:00 22:06 13.1 ppg 11/6/2016 11/7/2016 1.90 COMPZ1 CASING TRIP Line-up to pump down coil, at 0.5 6,601.0 208.0 bpm, took 3.0 bbls to get returns, start 22:06 00:00 tripping out, stop at 7207.75', paint white window flag, getting 13.1 ppg MW out, continue out, stop at 4103.95 ft, repaint previous window flag that was tied -in at 3972.16 ft (painted blue), stop at 2145 ft to cirulate out 3.8 bbls of 13.0 ppg KWF, let 2 more bbls out at the bit and chase OOH at 50 FPM, saw 13.0 ppg at the shaker, back up to 13.1 ppg, 5.5 bbl loss on trip out. 11/7/2016 11/7/2016 1.00 COMPZI CASING OWFF T Perform 30 min flow check, well on a 208.0 208.0 00:00 01:00 vac, after 30 min no flow observed. 11/7/2016 11/7/2016 0.70 COMPZ1 CASING PUTB T Close U/L pipe rams to hold 208.0 0.0 01:00 01:42 liner while breaking top connection. break Prep rig floor to LD liner assembly. 11/7/2016 11/7/2016 0.80 COMPZ1 CASING PULD T PJSM, opened U/L 2-3/8" pipe rams, 0.0 0.0 LD safety joint and 6 joints of 2-3/8" 01:42 02:30 slotted liner. 11/7/2016 11/7/2016 3.00 COMPZ1 CASING BOPE T PJSM, PU and run safety joint, test 0.0 0.0 U/L 2-3/8" pipe rams and TIW valve to 02:30 05:30 250/4700 psi test pressure. Swab valves not holding. Valve crew serviced tree. 11/7/2016 1.00 COMPZ1 CASING OWFF T Monitor hole for flow. Clean clear rig 0.0 0.0 11/7/2016 05:30 06:30 floor of equipment. 11/7/2016 11/7/2016 1.40 COMPZ1 CASING PUTB T PJSM, Fill hole 3 x, 2, 3.2, and 1.75 0.0 0.0 06:30 07:54 bbls, 6.95 bbls total, prepare liner running equipment. 11/7/2016 11/7/2016 4.10 COMPZ1 CASING PULD P PJSM, Pick up and run 25 joints with a 0.0 1,063.1 07:54 12:00 shorty deployment sleeve. Hole drank 7 bbls of fluid not accounting for liner volume. perform liner running drill, 3.25 minute response time. 11/7/2016 11/7/2016 1.20 COMPZ1 CASING PULD P PJSM, pick up BHA 14, liner running 1,063.0 1,107.0 12:00 13:12 assembly, stab on. 11/7/2016 11/7/2016 -1 80 COMPZI CASING RUNL P Zero pit G/L, RIH, zero pit G/L, zeroed 1,107.0 5,007.3 13:12 15:00 in/out. lined up down the coil @ min rate, WOB -4.73 k lbs. 20 fph, Minimal losses, increase runing speed to 80 f/hr. Tie into previous blue EOP flag for -5' correction, set WOB to 3.8 k lbs. down on pump, Wt Ck 29.5k lbs, pumping min rate. 11/7/2016 11/8/2016 -9 00 COMPZ1 CASING RUNL P Wt ck 43k lbs, RIH, stack weight at 5,073.0 7,910.0 6755, PU neutral wt, - 40k RBIH, 15:00 00:00 broke through, Worked liner slowly from 6700 to 7748' increase in rate of penetration to 7910. Page 15/29 Report Printed: 11/28!2016 operations Summary (with Timelog Depths) 2K-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time 11/8/2016 our (hr) 7.50 Phase COMPZ1 Op Code CASING Activity Code RUNL Time P -T -X P Operation Continue to work lower liner section to (ftKB) 7,910.0 End Depth (ftKB) 8,025.0 11/8/2016 00:00 07:30 bottom, PU to 7990 ft, 58K PUW, worked liner back to 8025 ft. 11/8/2016 11/8/2016 3.75 COMPZ1 CASING RUNL P Start 20 bbl beaded pill at 1/2 ppb 8,025.0 8,040.0 07:30 11:15 concentration, at 0.25 bpm/0.19 bpm rate IN/OUT, 13.1 ppg MW IN/OUT (mud balance), park coil while circulating beads, work coil every 15 min, until weight breaks over. 11/8/2016 11/8/2016 1.75 COMPZ1 CASING CIRC P Liner pill at the BHA, (GS spear w/ 8,040.0 8,048.0 11:15 13:00 0.25" port) 11/8/2016 11/8/2016 1.00 COMPZ1 CASING RUNL P Continue to work liner, unable to push 8,048.0 8,048.0 13:00 14:00 liner any deeper, picking up losses footage. Consult with engineer, pump off liner at 8048, 37K CW, pull up to 7948', no problem turning around and RIH at 40 FPM, 14K CW. 11/8/2016 11/8/2016 1.50 COMPZ1 CASING CIRC P Reciprocate pipe slowly and circulate 8,048.0 8,048.0 14:00 15:30 while building another 20 bbl beaded pill. 11/8/2016 11/8/2016 2.10 COMPZ1 CASING CIRC P Pump 20 bbl liner pill w/ 1% KlayStop 8,048.0 6,963.0 15:30 17:36 and 1 % Safe Lube, and 1 ppb beads. start at 0.25 bpm IN / 0.17 bpm OUT, 730 psi CP, stage rate up to 0.5 bpm IN / 0.3 bpm OUT, 1625 psi CP, 4549 psi BHP, 14.2 ppg ECD. Remove liner length left in hole 11/8/2016 11/8/2016 0.30 COMPZ1 CASING TRIP P Lay in beaded liner running pill to 6,963.0 6,490.0 17:36 17:54 window, Increase pump rate to attempt to push beads down around liner 11/8/2016 11/8/2016 0.10 COMPZ1 CASING DLOG P Log RA marker for +l8' 6,490.0 6,527.0 17:54 18:00 11/8/2016 11/8/2016 0.60 COMPZ1 CASING TRIP P RBIH to push on liner after beaded pill 6,527.0 6,760.0 18:00 18:36 laid in. Clean trip down to set down @ 6760. Work pipe at different speeds and pump rates. Unable to get past. Consult town 11/8/2016 11/8/2016 1.50 COMPZ1 CASING TRIP P Trip out for FCO BHA 6,760.0 62.0 18:36 20:06 11/8/2016 11/8/2016 0.70 COMPZ1 CASING OWFF P Perform No Flow test good 62.0 62.0 20:06 20:48 11/8/2016 11/8/2016 1.50 COMPZ1 CASING PULD P PJSM, Lay down BHA # 14, Shut in 62.0 0.0 20:48 22:18 swabs for ARP HMI software update. Observred 15 PSI increase on MP line, zero on mechanical gauge in 30 min. 11/8/2016 11/9/2016 1.70 COMPZ1 CASING PULD P PJSM, PD BHA #15 with 1.6° AKO 0.0 62.4 22:18 00:00 motor and D-331 slick gauge mill, No pressure on well. Pressure deployed as precaution 11/9/2016 11/9/2016 1.40 COMPZ1 CASING PULD T Continue PD BHA # 15 with 1.6° 62.4 62.4 00:00 01:24 motor and D-331 slick Gauge mill. M/U to coil and surface test. 11/9/2016 11/9/2016 1.30 C0MPZ1 CASING TRIP T Trip in hole with BHA #15, FCO with 62.4 6,435.0 01:24 02:42 1.6° motor and D331 mill, EDC Open 11/9/2016 11/9/2016 0.20 COMPZ1 CASING DLOG T Log K1 for+7' 7,43501-6,46-1 .0 02:42 02:54 Page 16/29 Report Printed: 11/28/2016 Operations Summary (with Timelog Depths) w i �- 2K-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/9/2016 11/9/2016 0.10 COMPZ1 CASING TRIP T Trip into 6500' 6,461.0 6,500.0 02:54 03:00 11/9/2016 11/9/2016 2.25 COMPZ1 CASING CIRC T Park @ 6500 and displace hole to 6,500.0 6,500.0 03:00 05:15 8.6PPG flow pro, closed EDC 11/9/2016 11/9/2016 2.75 COMPZ1 CASING MILL T RIH an tag at 6650', work down to 6,500.0 6,759.0 05:15 08:00 6759', mill/work pipe to get deeper, pull 58K (1 OK overpull) twice. Sample collected at Sam was mostly siltstone cuttings with a little frac sand and a few alpine beads 11/9/2016 11/9/2016 1.20 COMPZ1 WELCTL TRIP T Discovered pin holed pipe while at 6,759.0 6,759.0 08:00 09:12 -6730', pull up looking for pin hole, at counter head with depth at 6620' (-77 ft distance from reel to goose neck), shut down pumps and closed choke to trap WHP, pin hole stopped misting, spooled pin hole on to reel, attempt to verify if checks are holding, bleed pump presssure, checks not holding. Hole is not leaking, consult town, 11/9/2016 11/9/2016 2.30 COMPZ1 WELCTL TRIP T Tripped out, pumping down annulus 6,759.0 62.4 09:12 11:30 on MP schedule, at surface, bump up and space out to 62.8'. 11/9/2016 11/9/2016 2.25 COMPZ1 WELCTL PULD T PJSM, PUD BHA #14, while on MP. 62.4 0.0 11:30 13:45 Laydown BHA. 11/9/2016 11/9/2016 3.00 COMPZ1 CASING CTOP T Clear rig floor, MU nozzel on coil, 0.0 0.0 13:45 16:45 PJSM w/ SLB, RU N2, blow down coil w/ 1500 scf for 15 mins to TT, RD SLB N2. 11/9/2016 11/9/2016 1.25 COMPZ1 CASING CTOP T Bleed off CT N2, PJSM, remove inner 0.0 0.0 16:45 18:00 reel and pressure bulkhead 11/9/2016 11/9/2016 0.50 COMPZ1 CASING CTOP T Crew change, 0.0 0.0 18:00 18:30 11/9/2016 11/9/2016 2.50 COMPZ1 CASING CTOP T PJSM, Remove wash pipe from reel, 0.0 0.0 18:30 21:00 Cut CT connector. Dress coil for grapple connector and install. Rig up pull back cable. Rig up sheive to skate. 11/9/2016 11/10/2016 3.00 COMPZ1 CASING CTOP T PJSM, Pull test grapple connector, 0.0 0.0 21:00 00:00 Pull CT back to storage reel and secure, Pull stripper from injector 11/10/2016 11/10/2016 4.00 COMPZ1 CASING CTOP T- Rig off reel saddle clamps, Pull 0.0 0.0 00:00 04:00 stuffing box brass. rig up to swap reels 11/10/2016 11/10/2016 4.00 COMPZ1 CASING CTOP T PJSM with Peak - Swap CT strings, 0.0 0.0 04:00 08:00 install saddle clamps, rebuild PO assembly with new brass and MU to injector. 11/10/2016 11/10/2016 4.00 COMPZ1 CASING CTOP T PJSM, layout cable and rig up sheive 0.0 0.0 08:00 12:00 to skate 11/10/2016 11/10/2016 2.75 COMPZ1 CASING CTOP T Dress coil for internal grapple 0.0 0.0 12:00 14:45 connector and install, failed pull test, had to cut off a repeat, passed pull test, ready for stabbing pipe. 11/10/2016 11/10/2016 0.25 COMPZ1 CASING CTOP T PJSM, Stab pipe 0.0 14:45 15:00 11/10/2016 11/10/2016 0.25 COMPZ1 CASING RGRP T Stop for ARP to come off Hi Line to 0.0 0.0 15:00 15:15 replace a breaker. Page 17/29 Report Printed: 11/28/2016 Uperations Summary (with Timelog bepths) 2K-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (WEI) 11/10/2016 11/10/2016 1.25 COMPZ1 CASING CTOP T Begin pulling coil to injector, rig went 0.0 0.0 15:15 16:30 black for 5 min, check rig systems before proceeding with stabbing pipe. 11/10/2016 11/10/2016 1.00 C0MPZ1 CASING CTOP T Cut off internal grapple connector. 0.0 0.0 16:30 17:30 MU Baker external connector for chain tension/traction pressure pull test. 11/10/2016 11/10/2016 4.50 COMPZI CASING CTOP T Continue install inner reel iron - wash 0.0 0.0 17:30 22:00 pipe - Make up 10K pressure bulkhead, Work on choke calibration 11/10/2016 11/10/2016 1.00 COMPZI CASING CTOP T PJSM, Rig up LRS and pump 5 BBL 0.0 0.0 22:00 23:00 60/40 methonal spear into coil 11/10/2016 11/10/2016 0.50 COMPZI CASING CTOP T PJSM, Perform pull tests for traction 0.0 0.0 23:00 23:30 pressure vs. tubing loads. All pressures verified at HMI and manual traction pressure gauges. Pulled 50K @ 1260PSI, pulled 70K @ 1800 PSI, pulled 90K @ 2220PSI. RIH 15' between each test looking for marks on CT. 11/10/2016 11/11/2016 0.50 COMPZI CASING CTOP T Skid injector cart back to floor and cut 0.0 23:30 00:00 off BOT grapple connector. Prep for crew change out 11/11/2016 11/11/2016 0.50 COMPZ1 CASING CTOP T Crew change, run valve checklist 0.0 0.0 00:00 00:30 11/11/2016 11/11/2016 1.70 COMPZI CASING CTOP T Trim 25' of coil for pull tests, Prep coil 0.0 0.0 00:30 02:12 for connector. Test wire, 550MOhms, 62.7 Ohmes. Install CTC and pull to 40K 11/11/2016 11/11/2016 1.30 COMPZ1 CASING CTOP T Head up E -line and test connection 0.0 0.0 02:12 03:30 11/11/2016 11/11/2016 3.00 COMPZ1 CASING CTOP T Fill coil with water, pressure test inner 0.0 0.0 03:30 06:30 reel iron, MU test plate and PT coil connector. 11/11/2016 11/11/2016 2.25 COMPZ1 CASING PULD T MU BHA and PD BHA #16, surface 0.0 0.0 06:30 08:45 test tool, voltage not correct. Troublshool BHI tools. 11/11/2016 11/11/2016 1.75 COMPZ1 CASING CTOP T Change out flow sub, retest, still not 0.0 0.0 08:45 10:30 right. BHI called support to trouble shoot, isolated the problem, the polarity was reversed at the collector during the reel swap, reversed the polarity in the MWD office and retest, good test. "" need to get Nabors Electrician to swicth the polarity at the collector at next opportune time 11/11/2016 11/11/2016 0.50 COMPZI CASING PULD T Proceed with PD 0.0 62.4 10:30 11:00 11/11/2016 11/11/2016 1.30 COMPZ1 CASING TRIP T Trip in with EDC open pumping 12.8 62.4 6,430.0 11:00 12:18 ppg MP schedule. 11/11/2016 11/11/2016 0.20 COMPZ1 CASING DLOG T Tie-in to K1, +14 ft, close EDC 6,430.0 6,447.0 12:18 12:30 11/11/2016 11/11/2016 0.20 COMPZI CASING TRIP T RIH at min rate, tag at 6763 ft, come 6,447.0 6,763.0 12:30 12:42 up to 1.37 bpm, 3661 pis CP, 355 dp free spin Page 18/29 ReportPrinted: 11/28/2016 Operations Summary (with Timelog Depths) 3 2K-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (MB) End Depth (ftKB) 11/11/2016 11/11/2016 1.90 COMPZ1 CASING MILL T. Trip in with mill, SD at 6760.8 ft, stall 6,763.0 6,780.0 12:42 14:36 2x, mill for 10 min, to 6763 ft, stall with 5K WOB, PU, resume milling, pump 16 bbls of 2% KCL water, at bit at 14:20, 6765 ft, all 16 bbls out, mill to 6780 ft with 2K WOB, returns are showing 75 - 80 % silt, 10 - 15% frac sand 11/11/2016 11/11/2016 0.20 COMPZ1 CASING MILL T PU clean 43 to 46K, run in at different 6,780.0 6,780.0 14:36 14:48 speeds w/ pumps on & off, sit down same spot, 6780', consult engineer, Plan to resume milling until going far enough to get a survey. 11/11/2016 11/11/2016 4.30 COMPZ1 CASING MILL T Resume milling at 6768 ft, 1.39 bpm, 6,780.0 6,796.0 14:48 19:06 4201 psi CP, 940 psi WHP, 767 psi dP, 2K WOB. At 6778.8 ft take a PUW, 43K, go back to milling 11/11/2016 11/11/2016 1.00 COMPZ1 CASING TRIP T Near bit inclination not matching with 6,796.0 2,055.0 19:06 20:06 drilled hole, Consult town, Trip out for caliper 11/11/2016 11/11/2016 1.80 COMPZ1 CASING TRIP T Trip back to bottom to kill well 2,055.0 6,491.0 20:06 21:54 11/11/2016 11/11/2016 1.20 COMPZ1 CASING TRIP T 5 BBIs 13.0 K Formate out of coil. Trip 6,491.0 66.0 21:54 23:06 1 out following well kill trip sheet 11/11/2016 11/12/2016 0.90 COMPZ1 CASING OWFF T Perform 30 Min flow check - slight 66.0 66.0 23:06 00:00 flow, Shut in and monitor pressure build up, Build 25 PSI, Bleed off and retest 25 PSI. 11/12/2016 11/12/2016 1.80 COMPZ1 CASING PULD T PJSM, PUD BHA and lay down 66.0 0.0 00:00 01:48 11/12/2016 11/12/2016 1.50 COMPZ1 CASING PULD T PJSM, Vac out stack, 20 PSI on MP 0.0 0.0 01:48 03:18 line. Shut master and open swabs. Having issues with camera adapter 11/12/2016 11/12/2016 0.50 COMPZ1 CASING PULD T PJSM, P/U BHA #17 HES 24 arm 0.0 24.7 03:18 03:48 caliper and put in well, Skid injector and M/U to caliper BHA #17 go to surface test caliper junction box is wired backwards. Call out electrician to swap out 11/12/2016 11/12/2016 2.50 COMPZ1 CASING SVRG T Service reel, blow down chokes, swap 24.7 24.7 03:48 06:18 polarity at collector J -box, unlock reel, stab on 11/12/2016 11/12/2016 1.50 COMPZ1 CASING TRIP T Trip in w/ EDC open, pumping 0.25 24.7 6,420.0 06:18 07:48 bpm + 0.3 bpm displacement, getting 0.42 bpm OUT, 8.5 bph loss rate. MW IN= 13.1 ppg, MW OUT= 13.0 ppg, adding sks of K -Formate. 11/12/2016 11/12/2016 0.30 COMPZ1 CASING DLOG T Log K1 marker, +3.9 ft correction to 6,420.0 6,488.0 07:48 08:06 HES depth. 11/12/2016 11/12/2016 0.80 COMPZ1 CASING DLOG T Trip in to 6620 ft, log 2 caliper passes 6,488.0 6,620.0 08:06 08:54 to 6370 ft 11/12/2016 11/12/2016 1.40 COMPZ1 CASING TRIP T Trip out w/ caliper tools 6,620.0 24.7 08:54 10:18 11/12/2016 11/12/2016 0.50 COMPZ1 CASING OWFF T Perform 30 min flow check, no flow 24.7 24.7 10:18 10:48 observed 11/12/2016 11/12/2016 0.70 COMPZ1 CASING PULD T PJSM, close master valve as 24.7 0.0 10:48 11:30 precaution, LD Halliburton caliper tools, reopen MV, close swabs, monitor WHP. 11/12/2016 11/12/2016 0.50 COMPZ1 CASING WAIT T Wait for caliper log results from Town. 0.0 0.0 11:30 12:00 Page 19129 Report Printed: 11/28/2016 - Operations Summary (with Timelog Depths) --- 2K-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time I Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKa) End Depth (WEI) 11/12/2016 11/12/2016 1.00 COMPZ1 CASING PULD T PJSM, WHP = 0 psi, open swabs and 0.0 72.9 12:00 13:00 check for flow, no flow observerd, MU BHA #18, 2.625" aluminum anchored billet to CoilTrak, deploy over dead well. 11/12/2016 11/12/2016 1.80 COMPZ1 CASING TRIP T Trip in with EDC's open 72.9 6,430.0 13:00 14:48 11/12/2016 11/12/2016 0.20 COMPZ1 CASING DLOG T Log K1 marker, +2 ft correction 6,430.0 6,472.0 14:48 15:00 11/12/2016 11/12/2016 0.20 COMPZ1 CASING TRIP T Close EDC, get PUW= 40K, RIW= 6,472.0 6,588.7 15:00 15:12 12.5K at 15 FPM, orient top slip at 30° ROHS, set top of anchored billet at 6577 ft, bottom at 6588.5 ft (center of slips at 6587 ft). Set down and hold 4K WOB, holds solid, PU clean 11/12/2016 11/12/2016 1.40 COMPZ1 CASING TRIP T Trip out with EDC closed, pumping 6,588.7 72.9 15:12 16:36 13.1 ppg trip schedule, 0.51 bpm, 11/12/2016 11/12/2016 0.50 COMPZ1 CASING OWFF T Perform 30 min flow check, 72.9 72.9 16:36 17:06 11/12/2016 11/12/2016 0.90 COMPZ1 CASING PULD T LD BHA #17 Baker #10 setting tool. 72.9 0.0 17:06 18:00 11/12/2016 11/12/2016 1.00 COMPZ1 CASING CTOP T Crew change, Valve checklist, M/U 0.0 0.0 18:00 19:00 nozzle to coil and stab on well, Line up to pump 11/12/2016 11/12/2016 1.00 COMPZ1 CASING CTOP T Jet stack, Test stripper and inner reel 0.0 0.0 19:00 20:00 iron - shell test 11/12/2016 11/12/2016 2.00 COMPZI CASING CTOP T Unstab injector and rack back. prep 0.0 0.0 20:00 22:00 for BOPE test, Jetted with bring - Flush stack with water - service stack, tree and rig valves 11/12/2016 11/13/2016 2.00 PROD1 DRILL BOPE P Perform Full bi weekly BOPE test. 0.0 22:00 00:00 Test witnes waived by Bob Noble, AOGCC 11/13/2016 11/13/2016 4.50 COMPZ1 CASING BOPE P Continue full bi-weekly BOPE Test 00:00 04:30 11/13/2016 11/13/2016 2.50 PROD1 DRILL PULD T Complete BOPE test. Flush stack with 0.0 72.1 04:30 07:00 13PPG KFormate, PJSM P/U BHA # 19 Kick off - build section with 2.6° motor and RB HCC Bi Center. Had to work BHA thru tree. 11/13/2016 11/13/2016 0.25 PROD1 DRILL WAIT T Double check & verify valve allignment 72.1 72.1 07:00 07:15 after BOP test, bofore tripping in. 11/13/2016 11/13/2016 1.60 PROM DRILL TRIP T Trip in with EDC open, pump 10 bbl 72.1 6,440.0 07:15 08:51 spacer (interface) followed by 8.6 ppg FloPro System 2 11/13/2016 11/13/2016 0.20 PROM DRILL DLOG T Log K1 marker, +2.5 ft correction 6,440.0 6,502.0 08:51 09:03 11/13/2016 11/13/2016 1.60 PROD1 DRILL CIRC T Swap hole over to 8.6 ppg FloPro 6,502.0 6,502.0 09:03 10:39 11/13/2016 11/13/2016 0.30 PROD1 DRILL TRIP T Close EDC, trip in and tag billet at 6,502.0 6,577.0 10:39 10:57 6577 ft, 42K PUW, run back in, establish parameters at 1.52 bpm, 3900 psi CP, 690 psi WHP, 385 psi free spin. 11/13/2016 11/13/2016 4.00 PROM DRILL DRLG T Start drilling on billet at 6576.8 ft at 1 6,577.0 6,637.0 10:57 14:57 fph, 30° LOHS, 6578 ft, drill at 2 fph, 6579 ft drill at 3 fph, kicked off at 6581 ft, drilling build section getting 45° DLS. Page 20/29 Report Printed: 11/28/2016 Operations Summary (with Timelog Depths) 2K-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/13/2016 -fl-/ 13/20-16 0.20 PROD1 DRILL WPRT T Pull up to 6550 ft, 39K PUW, dry drift 6,637.0 6,637.0 14:57 15:09 billet, no issues, increase rate to 1.70 bpm, 4368 psi CP, 640 psi WHP, 475 psi free spin 11/13/2016 11/13/2016 1.60 PROD1 DRILL DRLG T Continue drilling build section to 6695 6,637.0 6,695.0 15:09 16:45 ft 11/13/2016 11/13/2016 0.20 PROD1 DRILL WPRT T Wiper to allow DD to restart Wellpath 6,695.0 6,695.0 16:45 16:57 and recalc EOB projection. 11/13/2016 11/13/2016 0.50 PROD1 DRILL DRLG T OBD, 1.70 bpm, 4594 psi CP, 700 psi 6,695.0 6,710.0 16:57 17:27 WHP, 714 dP, 3K WOB 11/13/2016 11/13/2016 2.10 PROD1 DRILL TRIP T 6710', Call EOB, Avg DLS=51.2°, 6,710.0 71.4 17:27 19:33 PUW=41 K, Open EDC above window and circ in KWF 11/13/2016 11/13/2016 1.00 PROD1 DRILL OWFF T At surface, Perform 30 Min No Flow, 71.4 71.4 19:33 20:33 Build 40 PSI in 30 min. Bleed off and retry. Still building. Consult town. Go to PUD mode 11/13/2016 11/13/2016 1.50 PROD1 DRILL PULD T PJSM, PUD BHA# 19 71.4 0.0 20:33 22:03 11/13/2016 11/13/2016 1.80 PROD1 DRILL PULD T PJSM, PD BHA # 20, AL1 lateral BHA 0.0 72.2 22:03 23:51 with .4° AKO motor and RR bi center, M/U to coil and surface test 11/13/2016 11/14/2016 0.15 PROD1 DRILL TRIP T Trip in hole, BHA # 20 72.2 120.0 23:51 00:00 11/14/2016 11/14/2016 1.40 PROD1 DRILL TRIP T Continue running in hole 120.0 6,440.0 00:00 01:24 11/14/2016 11/14/2016 0.10 PROD1 DRILL DLOG T Log K1 for+3' correction 6,440.0 6,459.0 01:24 01:30 11/14/2016 11/14/2016 0.10 PROD1 DRILL TRIP T RIH to 6491 6,459.0 6,491.0 01:30 01:36 11/14/2016 11/14/2016 1.60 PROD1 DRILL CIRC T Displace 13PPG to 8.6 PPG flow pro 6,491.0 6,491.0 01:36 03:12 11/14/2016 11/14/2016 0.20 PROD1 DRILL TRIP T Shut EDC, PUW=38K, RIH to drill, 6,491.0 6,711.0 03:12 03:24 Clean trip through window 11/14/2016 11/14/2016 5.40 PROD1 DRILL DRLG T 6711', Drill, 1.65 BPM @ 4237 PSI 6,711.0 7,125.0 03:24 08:48 FS, BHP=4110, average ROP= 77 ft/hr, up to 140 ft/hr, At 7110 ft, pump 5x5 Lo/Hi vis sweep. 11/14/2016 11/14/2016 0.40 PROD1 DRILL WPRT Planned wiper trip, 39K PUW, pull into 7,125.0 6,440.0 08:48 09:12 window for BHP pressure calibration, perform jog at EO tubing 11/14/2016 11/14/2016 0.30 PROD1 DRILL DLOG Open EDC, tie in to K1 for+2.5 ft 6,440.0 6,510.0 09:12 09:30 correction 11/14/2016 11/14/2016 0.50 PROD1 DRILL TRIP Finish circulating a BU, shut down 6,510.0 6,510.0 09:30 10:00 pumps to take pressure calibration survey at the window with 12.8 ppg EMW, trapped 1158 psi WHP with 9.2 ppg MW. Bled off 50 psi and let pressure build for 20 min to 1219 psi, bled, repeat bled 50 psi and pressure built back to 1220 psi in 10 min, EMW= 13.0 ppg. 11/14/2016 11/14/2016 0.40 PROD1 DRILL TRIP Close EDC, trip in to resume drilling, 6,510.0 7,125.0 10:00 10:24 establish off bottom parameters, 1.65 bpm, 4389 psi CP, 633 psi WHP, 528 psi dP 11/14/2016 11/14/2016 3.10 PROD1 DRILL DRLG Drilling, send 5x5 Lo/Hi vis sweep 7,125.0 7,535.0 10:24 13:30 11/14/2016 11/14/2016 0.50 PROD1 DRILL WPRT Wiper trip, 42K PUW, pull up to 6615 7,535.0 7,535.0 13:30 14:00 j ft, RBIH Page 21/29 Report Printed: 11/28/2016 Uperations Summary (with Timelog Depths) 2K-11 Aw ... 4 io Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 11/14/2016 11/14/2016 2.50 PROD1 DRILL DRLG Drilling, averageing 150 to 180 ft/hr, at 7,535.0 7,954.0 14:00 16:30 7710 ft pumped 5x5 Lo/Hi vis sweep, pumped 5x5 Lo/Hi vis sweep before third wiper 11/14/2016 11/14/2016 1.00 PROD1 DRILL WPRT Wiper trip, 42K PUW clean pick up, 7,954.0 7,954.0 16:30 17:30 pull up to 6600 ft, RBIH 11/14/2016 11/14/2016 3.00 PROD1 DRILL DRLG Drilling ahead, on bottom parameters, 7,954.0 8,325.0 17:30 20:30 1.69 bpm, 4854 psi CP, 677 psi WHP, 819 psi dP w/ 2K WOB, avg ROP 140 ft/hr. 11/14/2016 11/14/2016 1.40 PROD1 DRILL WPRT Wipe trip with a tie-in, 46K PUW, 8,325.0 8,325.0 20:30 21:54 clean pick up, wiper up to 6525 ft, tie into RA tag, +6 ft correction, dry drift past billet at 6577 ft clean, RBIH to drill, establish off bottom parmeters, 1.66 bpm, 4470 psi CP, 680 psi WHP, 524 psi dP, 11/14/2016 11/15/2016 2.10 PROD1 DRILL DRLG Drilling, on bottom parameters, 1.68 8,325.0 8,580.0 21:54 00:00 bpm, 4801 psi CP, 695 psi WHP, 860 psi dP, 2K WOB, 114 ft/hr. 11/15/2016 11/15/2016 1.30 PROD1 DRILL DRLG P 8580', Cont drill ahead, 1.68 BPM @ 8,580.0 8,725.0 00:00 01:18 4450 PSI FS, BHP=4535 11/15/2016 11/15/2016 0.80 PROD1 DRILL WPRT P 8725', Wiper to 7725' with 5 X 5 8,725.0 8,725.0 01:18 02:06 sweeps, PUW=46K. Clean trip up and down 11/15/2016 11/15/2016 1.00 PROD1 DRILL DRLG P 8725', Drill, 1.68 BPM @ 4540 PSi 8,725.0 8,900.0 02:06 03:06 FR, BHP=4525, RIW=3.4K @ 1.98K DHWOB 11/15/2016 11/15/2016 2.70 PROD1 DRILL WPRT P Reach Plan TD, Pump 10 X 10 8,900.0 72.0 03:06 05:48 Sweeps, Pull Swab wiper, PUW=46K 11/15/2016 11/15/2016 1.20 PROD1 DRILL WPRT P Wiper back in hole 72.0 6,440.0 05:48 07:00 11/15/2016 11/15/2016 0.20 PROD1 DRILL DLOG P Log K1 for+2' correction 6,440.0 6,458.0 07:00 07:12 11/15/2016 11/15/2016 0.70 PROD1 DRILL WPRT P Trip into 6504' MD (6178' TVD), above 6,458.0 6,708.0 07:12 07:54 window, static BHP survey, 4231 PSI, 13.15PPG EMW. Shut in EDC 11/15/2016 11/15/2016 0.60 PROD1 DRILL TRIP P Trip into heel of well 6708' MD (6307 6,708.0 6,505.0 07:54 08:30 TVD, 4310 PSI 13.12 EMW, Pull back to cased hole, pump 0.96 BPM with 1:1 returns and ECD=13.6ppg. 11/15/2016 11/16/2016 15.50 PROD1 DRILL WAIT T Wait on 13.4PPG KWF from MI 6,505.0 6,505.0 08:30 00:00 11/16/2016 11/16/2016 4.75 PROD1 DRILL WAIT T Wait on 13.4ppg micronized barite 6,505.0 6,505.0 00:00 04:45 KWF. 11/16/2016 11/16/2016 2.20 PROD1 DRILL OTHR Fluid truck arrives, Mud weight 13.6 6,505.0 6,505.0 04:45 06:57 agitate on truck 30 minutes, still 13.6. Offload to pits, crew change, Mix beads in liner pill 11/16/2016 11/16/2016 1.10 PROD1 DRILL TRIP Close EDC and trip in hole to confirm 6,505.0 8,900.0 06:57 08:03 TD, Tag up @ 8900, clean trip to TD 11/16/2016 11/16/2016 3.80 PROD1 DRILL TRIP Trip out pumping 13.1 beaded liner 8,900.0 66.0 08:03 11:51 running pill followed by 13.6PPG WARP fluid, Paint EOP Flags 6800 & 4400 11/16/2016 11/16/2016 0.60 PROD1 DRILL OWFF At surface, Flow check well - good 66.0 66.0 11:51 12:27 test, lost 0.5 bbl/30 min Page 22/29 Report Printed: 11/28/2016 Operations Summary (with Timelog Depths) 2K-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (MB) End Depth (WEI) 11/16/2016 11/16/2016 1.00 PROD1 DRILL PULD PJSM, Lay down BHA#20 66.0 0.0 12:27 13:27 11/16/2016 11/16/2016 0.50 COMPZI CASING OTHR PJM, Prep floor to run liner 0.0 0.0 13:27 13:57 11/16/2016 11/16/2016 5.40 COMPZ1 CASING PUTB PJSM, P/U BHA #21 with non ported 0.0 2,056.0 13:57 19:21 bullnose, 67 Jts slotted liner and shorty deployment sleeve. MU to running tools. MU running tools to coil. Tag -up. Ready to RIH. 11/16/2016 11/16/2016 1.00 COMPZ1 CASING RUNL RIH. Walk up speed to 40 FPM, 2,056.0 3,460.0 19:21 20:21 pumping min rate (10 SPM=0.22 BPM), walk speed down to 20 FPM to minimize losses. Lost 2.4 bbls in first 1000' of coil RIH. Erratic pumping in pressure/rate, bypass high pressure screen and swap to Mud Pump #2 @ 3,460' MD. 11/16/2016 11/17/2016 3.65 COMPZI CASING RUNL Cont RIH BHA #21. 15-20 FPM 3,460.0 7,283.0 20:21 00:00 pumping min rate. Correct depth @ flag (-5.7 ft). PUW=40k. Cont RIH. 11/17/2016 11/17/2016 1.50 COMPZI CASING RUNL P Cont RIH 15-20 FPM pumping min 7,283.0 8,900.0 00:00 01:30 rate (0.22 BPM). Initially stacked out @ 8,212'. Stacked out @ numerous other depths. PUH each time, RBIH. WOB=5k, PUW=48k to 55k. Cont RIH to tag TD. 11/17/2016 11/17/2016 0.25 COMPZI CASING RUNL P Tagged TD, PUH to 8,859', RBIH to 8,900.0 6,852.0 01:30 01:45 8,864' to put liner in compression prior to pumping to release. Max pump pressure, 5500 psi @ 1.3 BPM with the 13.4 KWF fluid. PUH, liner released. TOL @ 6,852' MD. -40 bbls losses during liner running/setting. 11/17/2016 11/17/2016 4.60 COMPZ1 CASING DISP P PUH to just above window, pump 10 6,852.0 6,506.0 01:45 06:21 bbl hi -vis pill displacing KWF @ min rate (0.22 BPM), losing -4 BPH while pumping. 11/17/2016 11/17/2016 1.20 COMPZI CASING TRIP P POOH following MP schedule, 6,506.0 44.0 06:21 07:33 13.4ppg target @ window. 11/17/2016 11/17/2016 2.00 COMPZ1 CASING PULD P PUD BHA #21 liner running tools. 44.0 0.0 07:33 09:33 Flush and lay down 11/17/2016 11/17/2016 1.00 COMPZ1 CASING PULD P PJSM, PD BHA #22, Open hole 0.0 72.9 09:33 10:33 anchored Billet 11/17/2016 11/17/2016 0.30 COMPZI CASING RGRP P Complete Micro motion swap before 72.9 72.9 10:33 10:51 pressuring up PDL 11/17/2016 11/17/2016 1.00 COMPZI CASING PULD P Pressure up PDL - continue PD BHA 72.9 72.9 10:51 11:51 22, M/U to coil and surface test 11/17/2016 11/17/2016 3.90 COMPZI CASING PULD T Tool did not pass test - DPS. PUD 72.9 72.9 11:51 15:45 BHA #22 to trouble shoot. C/O PDS. PD BHA #23 and surface test tool. Still having issues. Consult town. Move forward with full deployment. Tag up. tool seems normal. *`NOTE: 3.5 Hrs BHI NPT"' 11/17/2016 11/17/2016 1.35 COMPZI CASING TRIP P Trip in hole BHA #23 anchor billet 72.9 6,440.0 15:45 17:06 11/17/2016 11/17/2016 0.20 COMPZI CASING DLOG P Tie-in @ K1 for +5.5' correction. 6,440.0 6,446.0 17:06 17:18 Page 23/29 ReportPrinted: 11/28/2016 - operations Summary (with Timelog Depths) 2K-11 r • ' Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (WEE) End Depth (WEE) 11/17/2016 11/17/2016 0.30 COMPZ1 CASING TRIP P RIH, close EDC @ 6,493'. Cont RIH to 6,446.0 6,852.0 17:18 17:36 billet setting depth. Set TOB @ 6,840' with anchor @ 180°. 11/17/2016 11/17/2016 1.65 COMPZ1 CASING TRIP P POOH BHA#23. Tag, space-out, 6,852.0 75.0 17:36 19:15 open EDC. 11/17/2016 11/17/2016 1.75 COMPZ1 CASING PULD P PJSM, PUD & LD BHA#23. 75.0 0.0 19:15 21:00 11/17/2016 11/17/2016 2.40 PROD2 STK PULD P PJSM, PU & PD BHA #24, A lateral 0.0 72.0 21:00 23:24 KO assembly (2.4° AKO + HCC RR). CO injector packoffs, tag-up. 11/17/2016 11/18/2016 0.60 PROD2 STK TRIP P RIH BHA#24. 72.0 3,003.0 23:24 00:00 11/18/2016 11/18/2016 0.75 PROD2 STK TRIP P Cont RIH BHA #24 (A lateral KO build 3,003.0 6,440.0 00:00 00:45 assembly). Swap chokes due to pressure fluctuations. Cont RIH pumping min rate (0.25 BPM). 11/18/2016 11/18/2016 0.20 PROD2 STK DLOG P Tie-in to K1 for+2' correction. 6,440.0 6,462.0 00:45 00:57 11/18/2016 11/18/2016 0.25 PROD2 STK TRIP P Close EDC. RIH, pumps off @ 6,830'. 6,462.0 6,840.0 00:57 01:12 Dry tag TOB @ 6,840'. 11/18/2016 11/18/2016 1.50 PROD2 STK KOST P PUH, start pumping, RIH, drill, 1.67 6,840.0 6,843.8 01:12 02:42 BPM @ 4466 psi FS, WOB 0.3, CTSW 2.5k. WOB increasing, CTSW decreasing but no motor work. 11/18/2016 11/18/2016 0.35 PROD2 STK KOST P BHA wiper, saw WOB 1 ft higher 6,843.8 6,842.8 02:42 03:03 11/18/2016 11/18/2016 0.40 PROD2 STK KOST P BOBD, 1.68 BPM @ 4333 psi FS, 6,842.8 6,870.0 03:03 03:27 WOB 2.7k, CTSW 3k. Got passed tight area. ROP increased to 70 FPH. . 11/18/2016 11/18/2016 0.10 PROD2 DRILL WPRT P PUH for dry drift. Dry drift passed billet 6,870.0 6,870.0 03:27 03:33 with 1 k WOB bobble. Cont RIH. 11/18/2016 11/18/2016 4.60 PROD2 DRILL DRLG P BOBD, 1.67 BPM @ 4353 psi FS, 6,870.0 7,200.0 03:33 08:09 WOB 2.41k, CTSW 9.1 k, ROP 75 11/18/2016 11/18/2016 1.70 PROD2 DRILL TRIP P 7200', Call end of build, Avg DLS=39', 7,200.0 73.0 08:09 09:51 PUW=49K 11/18/2016 11/18/2016 2.00 PROD2 DRILL PULD P Tag up and space out, PJSM PUD 73.0 0.0 09:51 11:51 BHA #24 build turn BHA 11/18/2016 11/18/2016 1.00 PROD2 DRILL CTOP P Reconfig tool string, run same top half 0.0 0.0 11:51 12:51 run. P/U New hot DGS and Res 11/18/2016 11/18/2016 1.10 PROD2 DRILL PULD P PD BHA #25, A lateral BHA with 0.4+ 0.0 72.0 12:51 13:57 motor and rr bi center, M/U to coil and surface test. Strip on. Tag up and set counters 11/18/2016 11/18/2016 1.60 PROD2 DRILL TRIP P Trip in hole, BHA# 25 72.0 6,435.0 13:57 15:33 11/18/2016 11/18/2016 0.20 PROD2 DRILL DLOG P Log K1 for+4', Close EDC, PUW=42K 6,435.0 6,465.0 15:33 15:45 11/18/2016 11/18/2016 1.10 PROD2 DRILL TRIP P Continue in well, clean trip through 6,465.0 7,200.0 15:45 16:51 window and past billets 11/18/2016 11/18/2016 3.80 PROD2 DRILL DRLG P 7200', Drill, 1.68 BPM @ 4550 PSI 7,200.0 7,610.0 16:51 20:39 FS, BHP=4471. Fault #2 called @ 7,471'. 11/18/2016 11/18/2016 0.70 PROD2 DRILL WPRT P Wiper Trip #1 to 6,870'. PUW=48k. 7,610.0 7,610.0 20:39 21:21 11/18/2016 11/18/2016 2.00 PROD2 DRILL DRLG P BOBD, 1.68 BPM @ 4491 psi FS, 7,610.0 7,746.0 21:21 23:21 WOB 0.9k, CTSW 5.9k, 73 ROP. New FloPro Mud System #3 at bit @ 7,661'. Cont drilling ahead. Page 24129 Report Printed: 11/28/2016 Uperations Summary (with Timelog Depths) 2K-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/18/2016 11/18/2016 0.35 PROD2 DRILL WPRT P Stacking, PUH (PUW=52k), BOBD, 7,746.0 7,746.0 23:21 23:42 PUH to swap chokes, blow down Choke A. 11/18/2016 11/19/2016 0.30 PROD2 DRILL DRLG P BOBD, 1.68 BPM @ 4324 psi FS, 7,746.0 7,773.0 23:42 00:00 WOB 1.5k, CTSW -3.9k, ROP 77. 11/19/2016 11/19/2016 0.25 PROD2 DRILL DRLG P Drilling, 1.68 BPM @ 4368 psi FS, 7,773.0 7,789.0 00:00 00:15 WOB 1k, CTSW 2.7k, ROP 56. 11/19/2016 11/19/2016 0.25 PROD2 DRILL WPRT P Short wiper, PUW=55k. 7,789.0 7,789.0 00:15 00:30 11/19/2016 11/19/2016 1.00 PROD2 DRILL DRLG P BOBD, 1.68 BPM @ 4368 psi FS, 7,789.0 7,820.0 00:30 01:30 WOB 1.7k, CTSW -4.8k, ROP 32. 11/19/2016 11/19/2016 0.35 PROD2 DRILL WPRT P Short wiper, PUW=41 k. Pump 5x5 7,820.0 7,820.0 01:30 01:51 sweeps 11/19/2016 11/19/2016 1.05 PROD2 DRILL DRLG P BOBD, 1.68 BPM @ 4281 psi FS, 7,820.0 7,872.0 01:51 02:54 WOB 1.1 k, CTSW 3k, ROP 40. Drilling through lower A4 sand lobes causing varying ROP. 11/19/2016 11/19/2016 0.60 PROD2 DRILL WPRT P Short wiper to 7,505'. Pump 15 bbl 7,872.0 7,872.0 02:54 03:30 2ppb beaded hi-vis pill. 11/19/2016 11/19/2016 0.20 PROD2 DRILL DRLG P BOBD, 1.68 BPM @ 4281 psi FS, 7,872.0 7,882.0 03:30 03:42 WOB 1.2k, CTSW 1.6k, ROP 65. 11/19/2016 11/19/2016 0.20 PROD2 DRILL WPRT P Short wiper to swap chokes, lower 7,882.0 7,882.0 03:42 03:54 pump rate to 1.5 BPM, RBIH. 11/19/2016 11/19/2016 0.50 PROD2 DRILL DRLG P BOBD, 1.4 BPM @ 3920 psi FS, WOB 7,882.0 7,903.0 03:54 04:24 1.4k, CTSW -2.9k, ROP 36. 11/19/2016 11/19/2016 0.60 PROD2 DRILL WPRT P Pull wiper early, PUW=58K to 6524 7,903.0 6,524.0 04:24 05:00 11/19/2016 11/19/2016 0.10 PROD2 DRILL DLOG P Log RA marker for+6.5' 6,524.0 6,549.0 05:00 05:06 11/19/2016 11/19/2016 0.70 PROD2 DRILL WPRT P Wiper back to bottom 6,549.0 7,906.0 05:06 05:48 11/19/2016 11/19/2016 1.60 PROD2 DRILL DRLG P 7906', Drill ahead, 1.6 BPM @ 4306 7,906.0 7,973.0 05:48 07:24 PSI FS, BHP=4930 11/19/2016 11/19/2016 0.30 PROD2 DRILL WPRT P BHA Wiper, 100', stacking 7,973.0 7,973.0 07:24 07:42 11/19/2016 11/19/2016 4.50 PROD2 DRILL DRLG P 7973', Drill 1.8 BPM @ 4630 PSI FS, 7,973.0 8,310.0 07:42 12:12 BHP=4510, RIW=1 K @ 1.8K DHWOB 11/19/2016 11/19/2016 1.00 PROD2 DRILL WPRT P 8310', 1000' wiper with 5 X 5 sweeps, 8,310.0 8,310.0 12:12 13:12 PUW=51 K, clean trip up and down. 11/19/2016 11/19/2016 1.35 PROD2 DRILL DRLG P 8310', Drill ahead, 1.6 BPM @ 4550 8,310.0 8,460.0 . 13:12 14:33 PSI FS, BHP=4465. CTW=3K, DHWOB=1.3, ROP=150 11/19/2016 11/19/2016 0.20 PROD2 DRILL WPRT P BHA wiper, PUW=51 k. 8,460.0 8,460.0 14:33 14:45 11/19/2016 11/19/2016 0.50 PROD2 DRILL DRLG P BOBD, 1.6 BPM @ 4627 psi FS, WOB 8,460.0 8,519.0 14:45 15:15 1.2k, CTSW -6k, ROP 134 down to 15. 11/19/2016 11/19/2016 0.20 PROD2 DRILL WPRT P 200' wiper trip, PUW=45k. 8,519.0 8,519.0 15:15 15:27 11/19/2016 11/19/2016 2.00 PROD2 DRILL DRLG P BOBD, 1.6 BPM @ 4564 psi FS, 8,519.0 8,633.0 15:27 17:27 WOB1.7k, CTSW -2k, ROP 63. 11/19/2016 11/19/2016 0.20 PROD2 DRILL WPRT P 200'wipertrip, PUW=52k. 8,633.0 8,633.0 17:27 17:39 11/19/2016 11/19/2016 1.20 PROD2 DRILL DRLG P BOBD, 1.62 BPM @ 4795 psi FS, 8,633.0 8,667.0 17:39 18:51 WOB 1.3k, CTSW -5k, ROP 29. Multiple PUS due to weight transfer, Max PUW=62k. Page 25/29 Report Printed: 11/28/2016 Operations Summary (with Timelog Depths) a � ,s 2K-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code . Time P -T -X Operation (MB) End Depth (WB) 11/19/2016 11/19/2016 1.50 PROD2 DRILL TRIP P POOH after consulting w town. Geo's 8,667.0 68.0 18:51 20:21 want planned TD (9,550' MD). Rather than continue to fight weight transfer through the lower A4 sand lobes, decide to trip for agitator. Pump 5x5 sweeps. Open EDC @ 6,391'. Cont POOH BHA #25. Tag -up, space out +1.2'. 11/19/2016 11/20/2016 3.65 PROD2 DRILL PULD P PJSM, PUD BHA #25, Skid injector, 68.0 0.0 20:21 00:00 cont. PUD BHA #25. Blew down MWD/Baker motor and LD bit, motor, lower MWD. (Picking up Weatherford motor w next BHA) 11/20/2016 11/20/2016 PROD2 00:00 00:00 11/20/2016 11/20/2016 0.50 PROD2 DRILL BOPE P Function test BOP w test joint. 0.0 0.0 00:00 00:30 11/20/2016 11/20/2016 1.00 PROD2 DRILL PULD P PU tools, start PD BHA#26 (NOV 0.0 80.8 00:30 01:30 agitator, Weatherford motor, HYC B7 "XD) bi-center bit) 11/20/2016 11/20/2016 1.00 PROD2 DRILL PULD P Cont PD. CO packoffs, CO floats in 80.8 80.8 01:30 02:30 UQC, MU QC. Test MWD. Stab on WH. Equalize, open rams, tag stripper. 11/20/2016 11/20/2016 0.50 PROD2 DRILL TRIP P RIH BHA#26. Close EDC @ 188' MD. 80.8 226.0 02:30 03:00 Test agitator, feel vibration w hand on coil, 1.7 BPM @ 5400 psi FS, differential = 1270 psi within expectations (629 psi for agitator, 750 psi for Weatherford motor). 11/20/2016 11/20/2016 1.15 PROD2 DRILL TRIP P Cont RIH BHA#26. 226.0 6,460.0 03:00 04:09 11/20/2016 11/20/2016 0.10 PROD2 DRILL DLOG P Tie-in to K1 for+3' correction. 6,460.0 6,480.0 04:09 04:15 PUW=40k., Close EDC 11/20/2016 11/20/2016 1.20 PROD2 DRILL TRIP P Cont RIH BHA#26. 6,480.0 8,669.0 04:15 05:27 11/20/2016 11/20/2016 3.30 PROD2 DRILL DRLG P 8669', Drill, 1.72 BPM @ 5566 PSI 8,669.0 8,821.0 05:27 08:45 FS, BHP=4509, CTWt=8.5K @ 1.3 DHWOB, ROP 40-50 FPH 11/20/2016 11/20/2016 0.10 PROD2 DRILL WPRT P 8821', BHA Wiper, PUW=58K 8,821.0 8,821.0 08:45 08:51 11/20/2016 11/20/2016 1.50 PROD2 DRILL DRLG P 8821', Drill, 1.7 BPM @ 5504 PSi FS, 8,821.0 8,880.0 08:51 10:21 BHP=4595 11/20/2016 11/20/2016 0.20 PROD2 DRILL WPRT P 8880', 200' wiper trip, PUW=61 K 8,880.0 8,880.0 10:21 10:33 11/20/2016 11/20/2016 1.90 PROD2 DRILL DRLG P 8880', Drill1.43 BPM (High Vibration) 8,880.0 8,950.0 10:33 12:27 @ 4800 PSI FS, BHP=4554, Multiple pick ups and short BHA wipers, stacking 11/20/2016 11/20/2016 1.20 PROD2 DRILL WPRT P 8950', 1000' wiper, PUW=59K 8,950.0 8,950.0 12:27 13:39 11/20/2016 11/20/2016 1.50 PROD2 DRILL DRLG P 8950', Drill, 1.49 BPM @ 4925 PSI 8,950.0 9,020.0 13:39 15:09 FS, BHP=4575 11/20/2016 11/20/2016 0.60 PROD2 DRILL WPRT P 9020', Stacking, pull 500' wiper, 9,020.0 9,020.0 15:09 15:45 PUW=61 K 11/20/2016 11/20/2016 0.90 PROD2 DRILL DRLG P 9020', Drill, 1.5 BPM @ 4971 PSI FS, 9,020.0 9,080.0 15:45 16:39 BHP=4550, Hard to get started drilling. Couple of short pick ups to get going, RIW=-3.2K, .8K DHWOB Page 26/29 Report Printed: 1 112 8/2 01 6 Operations Summary (with Timelog Depths) 2K-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/20/2016 11/20/2016 0.20 PROD2 DRILL WPRT P PU for surveys, PUW=53k. 9,080.0 9,080.0 16:39 16:51 11/20/2016 11/20/2016 0.80 PROD2 DRILL DRLG P BOBD, 1.49 BPM @ 4945 psi FS, 9,080.0 9,110.0 16:51 17:39 WOB 0.6k, CTSW -5k to -10k, ROP 100 to 60 11/20/2016 11/20/2016 0.20 PROD2 DRILL WPRT P BHA wiper trip, PUW=58k. 9,110.0 9,110.0 17:39 17:51 11/20/2016 11/20/2016 0.70 PROD2 DRILL DRLG P BOBD, 1.50 BPM @ 5300 psi FS, 9,110.0 9,146.0 17:51 18:33 WOB 0.6k, ROP 66. 11/20/2016 11/20/2016 0.80 PROD2 DRILL WPRT P 1000'wiper trip, PUW=51k. 9,146.0 9,146.0 18:33 19:21 11/20/2016 11/21/2016 4.65 PROD2 DRILL DRLG P BOBD, 1.61 - 1.45 BPM varying speed 9,146.0 9,405.0 19:21 00:00 due to vibration. Small wiper @ 9,263'. CTSW -5k to -10k while WOB typically stayed below 1.5k. ROP varied 8 - 115 FPH. 11/21/2016 11/21/2016 1.35 PROD2 DRILL DRLG P Cont drill ahead. 1.45 BPM @ 4708 9,405.0 9,446.0 00:00 01:21 psi FS, WOB 1k, CTSW -8k, ROP 30 11/21/2016 11/21/2016 1.10 PROD2 DRILL WPRT P Long wiper trip up, PUW=58k. 9,446.0 6,525.0 01:21 02:27 11/21/2016 11/21/2016 0.20 PROD2 DRILL DLOG P Tie in @ RA for+10.5' correction. 6,525.0 6,565.0 02:27 02:39 11/21/2016 11/21/2016 1.10 PROD2 DRILL WPRT P Wiper trip in. 6,565.0 9,453.0 02:39 03:45 11/21/2016 11/21/2016 2.45 PROD2 DRILL DRLG P BOBD, 1.52 BPM @ 4916 psi FS, 9,453.0 9,550.0 03:45 06:12 WOB 1.3k, CTSW -5k, ROP 40, 11/21/2016 11/21/2016 3.10 PROD2 DRILL WPRT P At plan TD 9550, Pump 10 X 10 9,550.0 72.0 06:12 09:18 sweeps and chase to surface, Open EDC @ 6494. Get static BHP=13.15 11/21/2016 11/21/2016 1.20 PROD2 DRILL WPRT P Tag up, reset counter, RBIH 72.0 6,460.0 09:18 10:30 11/21/2016 11/21/2016 0.10 PROD2 DRILL DLOG P Log K1 for -1.5', Close EDC, 6,460.0 6,481.0 10:30 10:36 PUW=43K 11/21/2016 11/21/2016 1.30 PROD2 DRILL WPRT P Continue in well to confirm TD 6,481.0 9,550.0 10:36 11:54 11/21/2016 11/21/2016 4.80 PROD2 DRILL TRIP P Tag TD @ 9550', Trip out pumping 9,550.0 72.0 11:54 16:42 13.1 PPG beaded liner running pill followed by 13.5 micronized barite in K formate, Paint EOP flags 6350 and 3300'. 11/21/2016 11/21/2016 0.60 PROD2 DRILL OWFF P At surface, Perform 30 Min No flow 72.0 72.0 16:42 17:18 check 11/21/2016 11/21/2016 1.70 PROD2 DRILL PULD P PJSM, Lay down drilling BHA #26 - 72.0 0.0 17:18 19:00 crew change out - cont laying down BHA #26 11/21/2016 11/21/2016 0.50 COMPZ2 CASING PUTB P Rig up floor to run liner 0.0 0.0 19:00 19:30 11/21/2016 11/21/2016 1.25 COMPZ2 CASING SVRG P Service top drive, De-ice main drilling 0.0 0.0 19:30 20:45 lines. De-ice traveling block shieves 11/21/2016 11/22/2016 3.25 COMPZ2 CASING PUTB P PJSM, P/U A lateral completion with 0.0 1,140.0 20:45 00:00 non -ported bull nose, 102 Jts slotted liner and shorty deployment sleeve. 38 joints in hole at midnight. 11/22/2016 11/22/2016 2.25 COMPZ2 CASING PUTB P Cont PU remaining slotted liner joints. 1,140.0 3,180.0 00:00 02:15 11/22/2016 11/22/2016 0.25 COMPZ2 CASING PUTB P RD tongs, clean up rig floor. 3,180.0 3,180.0 02:15 02:30 I Page 27/29 Report Printed: 11/2812016 Operations Summary (with Timelog Uepths) 2K-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/22/2016 11/22/2016 1.40 COMPZ2 CASING PUTB P PJSM, PU MWD, FVS, shorty 3,180.0 3,180.0 02:30 03:54 deployment sleeve. Strip injector over, CO UQC checks, MU QC. Test MWD. Stab on WH. Tag, set depth. Check inj counter. 11/22/2016 11/22/2016 2.20 COMPZ2 CASING RUNL P RIH BHA#27 (A lateral slotted liner). 3,180.0 6,480.0 03:54 06:06 Pumping min rate, tried 50 FPM, walk back down to 20 FPM to minimize losses. Correct to first flag - 5.3' correction. PUW=60k. 11/22/2016 11/22/2016 3.90 COMPZ2 CASING RUNL P Cont RIH. Stacking @ 7,336'. Working 6,480.0 8,106.0 06:06 10:00 in hole, letting coil relax, stacking, working forward. Discuss path forward with town. Not an option to leave liner high in tubing. Decide to run liner in two separate runs. 11/22/2016 11/22/2016 2.25 COMPZ2 CASING PULL T POOH, paint flag @ 6,300'. Cont. 8,106.0 3,333.0 10:00 12:15 POOH. 11/22/2016 11/22/2016 0.75 COMPZ2 CASING OWFF T Getting too much return rate while 3,333.0 3,333.0 12:15 13:00 POOH, stop, bullhead 3 bbls downhole. Flow check well. Fill well after flow check. — 1.5 BPH losses. 11/22/2016 11/22/2016 0.50 COMPZ2 CASING PULL T Cont POOH, tag -up, space out. Fill 3,333.0 3,167.0 13:00 13:30 hole, flow check while determining path forward. 42.7 bbls of KWF left in active system. 11/22/2016 11/22/2016 2.50 COMPZ2 CASING DISP T PJSM, strip off BHA. Line up coil 3,167.0 3,167.0 13:30 16:00 nozzle on sump, displace KWF from coil into active pit for use while pulling & LD liner joints. 29 bbls KWF added to active system for —72 bbls on surface. Blow down pump lines, clean rig floor and prepare pipe shed for LD liner. 11/22/2016 11/22/2016 5.00 COMPZ2 CASING PULL T PJSM, LD BHA followed by 52 jnts 3,167.0 1,560.0 16:00 21:00 slotted liner. 11/22/2016 11/22/2016 1.00 COMPZ2 CASING PULD T PJSM, MU BHA#28 with agitator 1,560.0 1,607.0 21:00 22:00 abovet he shorty deployment sleeve, Shut in upper / lower 2 3/8" deplotment rams, Shut in dbl ball valves. 11/22/2016 11/22/2016 0.90 COMPZ2 CASING DISP T Turn coil over to kill weight fluid. 1,607.0 1,607.0 22:00 22:54 11/22/2016 11/22/2016 0.40 COMPZ2 CASING PULD T Make up coil to BHA #28, A lateral 1,560.0 1,607.0 22:54 23:18 slotted liner "bottom", open dbl ballvalves, Open upper / lower 2 3/8" rams, bump up, reset. 11/22/2016 11/23/2016 0.70 COMPZ2 CASING RUNL T RIH W BHA# 28, A [at, slotted liner 1,607.0 2,421.0 23:18 00:00 bottom section. 11/23/2016 11/23/2016 4.00 COMPZ2 CASING RUNL T RIH W BHA# 28, A lat, slotted liner 2,421.0 6,450.0 00:00 04:00 bottom section, tie into original EOP flag for -8.5' correction. Park at 6450', Zero G/L & monitor returns at min rate for 20 min. no loss Page 28/29 Report Printed: 11/28/2016 Operations Summary (with Timelog Depths) 2K-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time PJA Operation (ftKB) End Depth (ftKB) 11/23/2016 11/23/2016 1.40 COMPZ2 CASING RUNL T Wt Chk 40k lbs. RIH Wt 13.6 k lbs, 6,450.0 8,886.0 04:00 05:24 set down 8087 PU Wt 45k lbs . RBIH SD 8075'. pumps on line @ 1.2 bpb, 5500 psi CT pressure, no weight slack off. Down on pumps, PUH, RIH while pumping 1.2 bpm, SD hard at 8086'. Consul w/ town engineer. 11/23/2016 11/23/2016 0.70 COMPZ2 CASING RUNL T PUH to 7966', bring pumps to 1.4 6,450.0 7,992.0 05:24 06:06 bpm, attempt to RBIH, stacked at 7980, attempt twice, no go PU Wts 50k lbs. RBIH to 7992' dry, WOB 4.62 k lbs. Bring pumps to 1.3 bpm, pick up, 34 k lbs Set A lat slotted liner, top at 6435' bottom 7992'. 11/23/2016 11/23/2016 3.20 COMPZ2 CASING DISP P Get pits set-up to displace to SW, 7,992.0 6,422.0 06:06 09:18 open EDC, pump hi -vis spacer followed with SW displacing KWF @ 0.3 BPM. 11/23/2016 11/23/2016 1.20 COMPZ2 CASING DISP P POOH BHA #28, pumping 0.9 BPM 6,422.0 2,500.0 09:18 10:30 chasing SW up hole. 11/23/2016 11/23/2016 1.30 COMPZ2 CASING DISP P PJSM, displace upper 2,500' of well to 2,500.0 2,500.0 10:30 11:48 diesel for freeze protect. Prep & test lines. CO customer line plug valve. Pump 30 bbls diesel. Blow down lines, disconnect Little Red Services truck. 11/23/2016 11/23/2016 0.60 COMPZ2 CASING DISP P POOH, laying in diesel. Tag -up, space 2,500.0 42.0 11:48 12:24 out +1.2' CTES counter. 11/23/2016 11/23/2016 2.40 COMM CASING PULD P" PJSM, PUD BHA #28 (liner running 42.0 0.0 12:24 14:48 tools + agitator). 11/23/2016 11/23/2016 1.00 DEMOB WHDBOP CIRC P MU nozzle to coil, stab on WH. Flush 0.0 0.0 14:48 15:48 BOP stack 11/23/2016 11/23/2016 2.80 DEMOB WHDBOP MPSP P PJSM, RU lubricator, set BPV, 0.0 0.0 15:48 18:36 negative test. 11/23/2016 11/24/2016 5.40 DEMOB WHDBOP MPSP P Flush & blow down, RD, Blow down 0.0 0.0 18:36 00:00 hard Iine,empty / clean pits, ND BOPE. Rig Release 12:00 midnight. Page 29129 ReportPrinted: 1112812016 I*-' ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad 2K -11A 50-103-20114-01 Baker Hughes INTEQ Definitive Survey Report 05 December, 2016 WEaI BAKER HUGHES ConocoPhillips ryN ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well 2K-11 Project: Kuparuk River Unit TVD Reference: 2K-11 @ 154.00usft (2K-11) Site: Kuparuk 2K Pad MD Reference: 2K-11@154.00usft(2K-11) Well: 2K-11 North Reference: True Wellbore: 2K -11A Survey Calculation Method: Minimum Curvature Design: 2K -11A 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 2K-11 Well Position -NI-S 0.00 usft Northing: 5,938,350.22usft Latitude: 70° 14' 34.061 N +E/ -W 0.00 usft Easting: 498,310.14usft Longitude: 150" 0'49,133 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 2K -11A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (nT) BGGM2016 11/1/2016 17.80 80.87 57,536 Design 2K -11A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 6,811.20 Vertical Section: Depth From (TVD) +N/ -S +EI -W Direction (usft) (usft) (usft) (°) 154.00 0.00 0.00 0.00 Survey Program Date 11/29/2016 From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 200.00 6,500.00 2K-11 (2K-11) BOSS -GYRO Sperry -Sun BOSS gyro multishot 1/12/2001 6,511.00 6,570.98 2K-11APB1 (2K-11APB1) MWD MWD - Standard 10/23/2016 11/5/2016 6,577.00 6,811.20 2K-11AL1 (2K-11AL1) MWD MWD - Standard 11/6/2016 11/15/2016 6,840.00 9,500.02 2K-1 1A (2K -11A) MWD MWD - Standard 11/16/2016 11/21/2016 1215/2016 12 27 00PM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips ConocoPhillips Definitive Survey Report G Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2K-11 Project: Kuparuk River Unit TVD Reference: 2K-11 @ 154.00usH (2K-11) Site: Kuparuk 2K Pad MD Reference: 2K-11 @ 154,00usfl (2K-11) Well: 2K-11 North Reference: True Wellbore: 2K -11A Survey Calculation Method: Minimum Curvature Design: 2K -11A Database: EDM Alaska NSK Sandbox Survey Map Map Vertical MD Inc Az1 ND TVDSS *NAS +E/ -W Northing Eang DLS Section Survey Tool Name (u�t) (°) (1(usd) (usR) (ustt) (usft) 0sti ftt (ny (°noo•) (ft) 6,811.20 102.81 169.73 6,292.17 6,138.17 -1,517.80 -880.25 5,936,832.77 497,429.64 11.61 -1,517.80 MWD (3) 6,840.00 103.30 167.88 6,285.67 6,131.67 -1,545.32 -874.80 5,936,805.25 497,435.08 6.48 -1,545.32 MWD (4) 6,870.19 88.80 159.72 6,282.49 6,128.49 -1,574.04 -866.43 5,936,776.53 497,443.45 5500 -1,574.04 MWD (4) 6,900.15 83.76 151.79 6,284.44 6,130.44 -1,601.27 -854.17 5,936,749.30 497,455.70 31.31 -1,601.27 MWD (4) 6,930.24 84.56 138.84 6,287.51 6,133.51 -1,625.83 -837.17 5,936,724.74 497,472.69 42.90 -1,625.83 MWD (4) 6,960.01 85.64 127.67 6,290.06 6,136.06 -1,646.12 -815.60 5,936,704.45 497,494.25 37.56 -1,646.12 MWD (4) 6,990.13 89.72 117.34 6,291.28 6,137.28 -1,662.26 -790.26 5,936,688.30 497,519.59 36.84 -1,662.26 MWD (4) 7,019.97 95.22 107.43 6,290.00 6,136.00 -1,673.60 -762.74 5,936,676.96 497,547.10 37.94 -1,673.60 MWD (4) 7,050.08 98.90 96.61 6,286.28 6,132.28 -1,679.83 -733.56 5,936,670.73 497,576.27 37.69 -1,679.83 MWD (4) 7,080.05 9863 84.20 6,281.70 6,127.70 -1,680.03 -704.01 5,936,670.51 497,605.83 40.93 -1,680.03 MWD (4) 7,110.11 97.76 73.10 6,277.40 6,123.40 -1,674.19 -674.88 5,936,676.35 497,634.95 36.66 -1,674.19 MWD (4) 7,139.89 93.93 61.64 6,274.36 6,120.36 -1,662.80 -647.59 5,936,687.73 497,662.24 40.38 -1,662.80 MWD (4) 7,170.77 9147 50.16 6,272.90 6,118.90 -1,645.53 -622.10 5,936,704.99 497,687.73 37.98 -1,645.53 MWD (4) 7,200.45 91.97 39.28 6,272.01 6,118.01 -1,624.49 -601.26 5,936,726.03 497,708.58 36.68 -1,624.49 MWD (4) 7,230.71 92.67 37.15 6,270.78 6,116.78 -1,600.73 -582.55 5,936,749.78 497,727.29 7.40 -1,600.73 MWD (4) 7,259.86 93.53 34.98 6,269.20 6,115.21 -1,577.20 -565.42 5,936,773.30 497,744.43 8.00 -1,577.20 MWD (4) 7,289.96 93.13 33.03 6,267.46 6,113.46 -1,552.30 -548.61 5,936,798.20 497,761.23 6.60 -1,552.30 MWD (4) 7,320.34 92.92 31.34 6,265.85 6,111.85 -1,526.62 -532.45 5,936,823.87 497,77740 5.60 -1,526.62 MWD (4) 7,350.09 92.18 30.38 6,264.53 6,110.53 -1,501.11 -517.21 5,936,849.38 497,792.65 4.07 -1,501.11 MWD (4) 7,380.33 92.39 30.48 6,263.32 6,109.32 -1,475.05 -501.91 5,936,875.43 497,807.95 0.77 -1,475.05 MWD (4) 7,410.31 93.13 29.79 6,261.88 6,107.88 -1,449.16 -486.87 5,936,901.32 497,822.99 3.37 -1,449.16 MWD (4) 7,440.58 92.24 28.77 6,260.46 6,106.46 -1,422.78 A72.08 5,936,927.68 497,837.78 4.47 -1422.78 MWD (4) 7,470.14 90.37 27.47 6,259.79 6,105.79 -1,396.72 A58.16 5,936,953.74 497,851.72 7.70 -1,396.72 MWD (4) 7,500.35 89.79 26.17 6,259.75 6,105.75 -1,369.76 -444.53 5,936,980.70 497,865.35 4.71 -1,369.76 MWD (4) 7,530.67 89.36 25.02 6,259.97 6,105.97 -1,342.42 A31.43 5,937,008.03 497,878.45 4.05 -1,342.42 MWD (4) 7,559.87 89.63 22.82 6,260.23 6,106.23 -1,315.73 A19.59 5,937,034.72 497,890.30 7.59 -1,315.73 MWD (4) 7,590.18 90.71 21.16 6,260.14 6,106.14 -1,287.63 -408.24 5,937,062.82 497,901.65 6.53 -1,287.63 MWD (4) 7,620.15 89.94 18.38 6,259.97 6,105.97 -1,259.43 -398.11 5,937,091.01 497,911.79 9.62 -1,259.43 MWD (4) 7,650.23 91.53 16.76 6,259.58 6,105.58 -1,23075 -389.03 5,937,119.68 497,920.88 7.55 -1,230.75 MWD (4) 7,675.22 91.44 14.33 6,258.94 6,104.94 -1,206.69 -382.33 5,937,143.74 497,927.57 9.73 -1,206.69 MWD (4) Annotation TIP KOP /GTI BAKER HUGHES 12WO16 1227.-OOPM Page 3 COMPASS 5000.1 Build 74 Survey ConocoPhillips r?Aiir ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well 2K-11 MD Project: Kuparuk River Unit TVD Reference 2K-11 @ 154.00usft (2K-11) TVDSS Site: Kuparuk 2K Pad MD Reference: 2K-11 @ 154.00usft (2K-11) Eating Well: 2K-11 North Reference. True (°) Wellbore: 2K -11A Survey Calculation Method: Minimum Curvature (waft) Design: 2K -11A Database: EDM Alaska NSK Sandbox (-now) Survey 12/5/2016 12 27 Page 4 COMPASS 5000.1 Build 74 Map Map e MD Inc AN TVD TVDSS +N/ -S +E/ -W Northing Eating DLS Section Sectisurvey Name Annotation (ustt) (°) l°) (ush) (usn) (waft) tu�l E�1 (it) (-now) (ft)IHI 7,704.62 91.10 13.27 6,258.28 6,104.28 -1,178.14 -375.32 5,937,172.28 497,934.59 3.79 -1,178.14 MWD (4) 7,735.35 90.00 12.52 6,257.99 6,103.99 -1,148.19 -368.46 5,937,202.23 497,941.46 4.33 -1,148.19 MWD (4) 7,764.85 88.53 11.13 6,258.37 6,104.37 -1,119.32 -362.42 5,937,231.09 497,947.51 6.86 -1,119.32 MWD (4) 7,795.29 87.61 9.27 6,259.39 6,105.39 -1,089.38 -357.03 5,937,261.03 497,952.90 6.81 -1,089.38 MWD (4) 7,824.65 87.11 7.35 6,260.75 6,106.75 -1,060.36 -352.79 5,937,29005 497,957.14 6.75 -1,060.36 MWD (4) 7,854.45 88.40 5.40 6,261.91 6,107.91 -1,030.77 -349.49 5,937,319.63 497,960.46 7.84 -1,030.77 MWD (4) 7,885.11 89.66 3.88 6,262.43 6,108.43 -1,000.22 -347.01 5,937,350.18 497,962.94 6.44 -1,000.22 MWD (4) 7,922.15 91.63 2.23 6,262.01 6,108.01 -963.23 -345.03 5,937,387.16 497,964.92 6.94 -963.23 MWD (4) 7,949.33 92.92 0.55 6,260.94 6,106.94 -936.08 -344.38 5,937,414.31 497,965.59 7.79 -936.08 MWD (4) 7,979.99 92.98 358.99 6,259.36 6,105.36 -905.47 -344.50 5,937,444.92 497,965.47 5.09 -905.47 MWD (4) 8,010.01 93.44 356.64 6,257.68 6,103.68 -875.52 -345.64 5,937,474.87 497,964.34 7.96 -875.52 MWD (4) 8,039.67 95.04 354.33 6,255.48 6,10148 $96.03 -347.97 5,937,504.35 497,962.02 9.46 -846.03 MWD (4) 8,070.49 95.32 352.32 6,252.70 6,098.70 -815.55 -351.54 5,937,534.83 497,958.46 6.56 -815.55 MWD (4) 8,099.70 97.02 351.91 6,249.56 6,095.56 -786.78 -355.52 5,937,563.59 497,954.48 5.98 -786.78 MWD (4) 8,130.89 97.14 349.79 6,245.72 6,091.72 -756.23 -360.44 5,937,594.15 497,949.57 6.76 -756.23 MWD (4) 8,160.58 97.16 347.74 6,242.02 6,088.02 -727.33 -366.18 5,937,623.04 497,943.83 6.85 -727.33 MWD (4) " 8,191.19 97.02 345.98 6,238.24 6,084.24 -697.76 -373.09 5,937,652.62 497,936.94 5.72 -697.76 MWD (4) 8,220.77 95.53 347.40 6,235.01 6,081.01 -669.14 -379.85 5,937,681.23 497,930.17 6.94 -669.14 MWD (4) 8,251.04 93.72 349.00 6,232.57 6,078.57 -639.61 -386.02 5,937,710.76 497,924.01 7.97 -639.61 MWD (4) 8,281.10 91.84 349.34 6,231.11 6,077.11 -610.12 -391.66 5,937,740.25 497,918.38 6.36 -610.12 MWD (4) 8,310.77 90.15 350.73 6,230.59 6,076.60 -580.91 -396.80 5,937,769.46 497,913.25 7.37 -580.91 MWD(4) 8,341.46 87.76 348.20 6,231.15 6,077.15 -550.74 -402.41 5,937,799.62 497,907.65 11.34 -550.74 MWD (4) 8,370.69 87.36 351.12 6,232.40 6,078.40 -522.02 -007.65 5,937,828.35 497,902.42 10.07 -522.02 MWD (4) 8,401.14 87.70 353.03 6,233.71 6,079.71 491.89 411.84 5,937,858.47 497,898.23 6.37 -491.89 MWD (4) 8,429.75 88.10 355.37 6,234.76 6,080.76 -463.45 414.73 5,937,886.91 497,895.35 8.29 -46345 MWD(4) 8,461.10 87.63 358.44 6,235.93 6,081.93 432.17 416.42 5,937,918.19 497,893.66 9.90 432.17 MWD (4) 8,489.96 88.19 359.69 6,236.98 6,082.98 403.33 416.89 5,937,947.02 497,893.20 4.74 403.33 MWD (4) 8,520.24 87.76 2.60 6,238.05 6,084.05 -373.08 416.29 5,937,977.27 497,893.81 9.71 -373.08 MWD (4) 8,549.65 85.98 2.53 6,239.66 6,085.66 -343.74 414.97 5,938,006.60 497,895.13 6.06 343.74 MWD (4) 8,579.85 84.34 3.92 6,242.21 6,088.21 -313.70 413.28 5,938,036.64 497,896.83 7.11 -313.70 MWD (4) 8,610.25 84.81 5.91 6,245.08 6,091.08 -283.55 410.69 5,938,066.79 497,899.43 6.70 -283.55 MWD (4) 12/5/2016 12 27 Page 4 COMPASS 5000.1 Build 74 ConocoPhillips V1,09 it it ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well 2K-11 Project: Kuparuk River Unit TVD Reference: 2K-11 @ 154.00usft (2K-11) Site: Kuparuk 2K Pad MD Reference: 2K-11 @ 154.00usft (2K-11) Well: 2K-11 North Reference: True Wellbore: 2K -11A Survey Calculation Method: Minimum Curvature Design: 2K -11A Database: EDM Alaska NSK Sandbox Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E1 -W Northing Easting DLS Section Survey Tool Name Annotation (usft) (1 (1) (USM Waft) Nan) (esft) (ft) (ft) ("1100') (ft) 8,639.55 86.25 6.88 6,247.36 6,09336 -254.52 -407.44 5,938,095.82 497,902.69 5.92 -254.52 MWD (4) 8,671.40 88.96 9.20 6,248.69 6,094.69 -223.02 -402.98 5,938,127.32 497,907.15 11.20 -223.02 MWD (4) 8,701.30 90.34 10.34 6,248.88 6,094.88 -193.55 -397.91 5,938,156.78 497,912.23 5.99 -193.55 MWD (4) 8,73166 92.09 12.54 6,248.23 6,094.23 -163.81 -391.89 5,938,186.52 497,918.25 9.26 -163.81 MWD (4) 8,765.36 92.49 10.94 6,246.89 6,092.89 -130.84 -385.04 5,938,219.48 497,925.11 4.89 -130.84 MWD (4) 8,791.40 94.25 1201 6,245.36 6,091.36 -105.36 -379.87 5,938,244.95 497,930.29 7.91 -105.36 MWD (4) 8,821.51 95.57 13.25 6,242.78 6,088.78 -76.09 -373.31 5,938,274.22 497,936.85 6.00 -76.09 MWD (4) y 8,851.86 93.50 13.82 6,240.38 6,086.38 -46.68 -366.23 5,938,303.63 497,943.94 7.07 -46.68 MAD (4) 8,882.24 93.32 15.41 6,238.57 6,084.57 -17.33 -358.58 5,938,332.97 497,951.59 5.26 -1733 MAD (4) 8,91172 94.80 16.68 6,236.48 6,082.48 10.92 -350.45 5,938,361.22 497,959.73 6.61 10.92 MWD (4) ' 8,941.94 95.38 19.44 6,233.80 6,079.80 39.54 -341.12 5,938,389.83 497,969.06 9.30 39.54 MWD (4) 8,971.57 95.88 21.42 6,230.90 6,076.90 67.17 -330.83 5,938,417.46 497,979.36 6.86 67.17 MWD (4) 9,002.72 94.52 19.78 6,228.07 6,074.07 96.21 -319.91 5,938,446.49 497,990.28 6.82 96.21 MWD (4) 9,031.36 93.01 18.17 6,226.19 6,072.19 123.23 -310.62 5,938,473.51 497,999.58 7.70 123.23 MWD (4) 9,064.28 93.72 16.61 6,224.26 6,070.26 154.59 -300.80 5,938,504.86 498,009.40 5.20 154.59 MWD (4) j 9,097.08 94.89 15.46 6,221.80 6,067.80 186.02 -291.77 5,938,536.29 498,018.44 4.99 186.02 MWD (4) 9,121.08 92.36 13.31 6,220.28 6,066.28 209.22 -285.82 5,938,559.49 498,024.40 13.82 209.22 MWD (4) 9,134.63 92.18 13.28 6,219.74 6,065.74 222.40 -282.70 5,938,572.66 498,027.51 1.35 222.40 MWD(4) 9,155.93 90.34 10.12 6,219.27 6,065.27 243.25 -278.39 5,938,593.51 498,031.84 17.16 243.25 MWD (4) 9,188.37 88.50 7.16 6,219.60 6,065.60 275.31 -273.51 5,938,625.57 498,036.71 10.74 275.31 MWD (4) , 9,215.63 87.73 6.44 6,220.50 6,066.50 302.37 -270.29 5,938,652.62 498,039.95 3.87 302.37 MWD (4) 9,246.23 86.01 6.19 6,222.17 6,068.17 332.73 -266.93 5,938,682.98 498,043.31 5.68 332.73 MWD (4) 9,278.58 84.49 5.49 6,224.85 6,070.85 364.80 -263.65 5,938,715.05 498,046.60 5.17 364.80 MWD (4) 9,309.77 85.14 1.83 6,227.67 6,073.67 395.80 -261,67 5,938,746.04 498,048.59 11.87 395.80 MWD (4) 9,315.62 85.14 0.59 6,228.16 6,074.16 401.63 -261.54 5,938,751.86 498,048.71 21.12 401.63 MWD (4) 9,345.94 85.27 3.95 6,230.70 6,076.70 431.81 -260.35 5,938,782.05 498,049.92 11.05 431.81 MWD (4) 9,375.16 85.92 358.22 6,232,95 6,078.95 460.93 -259.79 5,938,811.16 498,05047 19.68 460.93 MWD (4) 9,407.22 86.38 357.78 6,235.10 6,081.10 492.90 -260.91 5,938,843.12 498,049.37 1.98 492.90 MWD (4) 9,435.60 87.39 357.21 6,236.64 6,082-64 521.21 -262.15 5,938,871.43 498,048.13 4.08 521.21 MWD (4) - 9,467.88 88.46 356.23 6,237.81 6,083.81 553.41 -264.00 5,938,903.64 498,046.29 449 553.41 MWD (4) 9,500.02 86.77 356.70 6,239.15 6,085.15 585.46 -265.98 5,938,935.68 498,044.32 5.46 585.46 MWD (4) 12WO16 12: 27.00PM Page 6 COMPASS 5000.1 Build 74 ConocoPhillips FAN ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well 2K-11 Project: Kuparuk River Unit TVD Reference: 2K-11 @ 154.00usft (2K-11) Site: Kuparuk 2K Pad MD Reference: 2K-11 @ 154.00usft (2K-11) Well: 2K-11 North Reference: True Wellbore: 2K -11A Survey Calculation Method: Minimum Curvature Design: 2K -11A Database: EDM Alaska NSK Sandbox Survey MD Inc Azl TVD TVDSS +NIS +EI -W Map Map DLS Vertical (usft) (I (°) (usft) (usft) (usft) (usft) Northing East) (°M00') Section Survey Tool Name (ft) (ft) Iftl 9,550.00 86.77 356.70 6,241.96 6,08796 635.28 -268.85 5,938,985.50 498,041.46 0.00 635.28 PROJECTEDto TD Annotation 1215,12016 12: 27.00PM Page 6 COMPASS 5000 1 Build 74 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad 2K-11APB1 50-103-20114-70 Baker Hughes INTEQ Definitive Survey Report 05 December, 2016 WEaI BAKER HUGHES 12/52016 12 08 33P Page 2 COMPASS 5000.1 Build 74 ConocoPhillips RUN �, ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2K-11 Project: Kuparuk River Unit TVD Reference: 2K-11 @ 154.00usft (2K-11) Site: Kuparuk 2K Pad MD Reference: 2K-11@154.00usft(2K-11) Well: 2K-11 North Reference: True Wellbore: 2K-11APB1 Survey Calculation Method: Minimum Curvature Design: 2K-11APBi 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 2K-11 Well Position -NI-S 0.00 usft Northing: 5,938,350.22usft Latitude: 70° 14' 34.061 N +E/ -W 0.00 usft Easting: 498,310.14usft Longitude: 150° 0'49.133 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 2K-11AP81 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (nT) BGGM2016 11/112016 17.80 80.87 57,536 Design 2K-11APB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 6,500.00 Vertical Section: Depth From (TVD) +NIS +El -W Direction (usft) (usft) (usft) (°) 154.00 0.00 0.00 10.00 Survey Program Date 11/15/2016 From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 200.00 6,500.00 2K-11 (2K-11) BOSS -GYRO Sperry -Sun BOSS gyro multishot 1/12/2001 6,511.00 9,030.65 2K-11APB1 (2K-11AP81) MWD MWD - Standard 10/23/2016 11/5/2016 12/52016 12 08 33P Page 2 COMPASS 5000.1 Build 74 ConocoPhillips //id ConocoPhillips Definitive Survey Report KER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2K-11 Project: Kupamk River Unit TVD Reference: 2K-11 @ 154.00usft (2K-11) Site: Kuparuk 2K Pad MD Reference: 2K-11 @ 154.00usft (2K-11) Well: 2K-11 North Reference: True Wellbore: 2K-11APB1 Survey Calculation Method: Minimum Curvature Design. 2K-11 APB1 Database: EDM Alaska NSK Sandbox Survey Vertical MD Inc Aid TVD 7VDSS +NIS +E/ -W Northingrt Easting DLS Section Survey Tool Name Annotation (usm 11 (1 Welt) (usft) (us") (usft) (ft) (n ("1100') ft)) ( 6,500.00 7.82 202.20 6,173.86 6,019.86 -1,287.02 -882.30 5,937,063.52 497,427.64 0.70 -1,420.68 MWD (2) TIP 6,511.00 7.80 202.05 6,184.76 6,030.76 -1,288.41 -882.86 5,937,062.14 497,427.08 0.26 -1,422.14 MWD (2) KOP 6,540.04 15.82 201.90 6,213.16 6,059.16 -1,293.92 -885.08 5,937,056.63. 497,424.86 27.62 -1,42295 MWD (2) 6,570.98 29.83 201.90 6.24161 6,087.61 -1,305.03 -889.54 5,937,045.52 497,420.39 45.28 -1,439.67 MWD (2) 6,590.76 38.45 201.86 6,257.96 6,103.96 -1,315.32 -893.68 5,937,035.24 497,416.26 43.58 -1,450.52 MWD(2) 6,620.38 50.03 200.39 6,279.15 6,125.15 -1,334.57 -901.08 5,937,015.99 497,408.85 39.25 -1,470.77 MWD (2) 6,648.94 60.97 198.18 6,295.30 6,141.30 -1,356.76 -908.82 5,936,993.80 497,401.11 38.83 -1,493.96 MWD (2) 6,675.58 71.70 196.24 6,305.98 6,151.98 -1,380.04 -916.01 5,936,970.53 497,393.91 40.82 -1,518.13 MWD(2) 6,705.35 77.28 188.54 6,313.95 6,159.95 -1,408.02 -922.13 5,936,942.54 497,387.79 31.17 -1,546.76 MWD (2) 1 6,735.63 77.31 174.07 6,320.64 6,166.64 -1,437.47 -922.80 5,936,913.10 497,387.11 46.61 -1,575.87 WD (2) 6,760.08 77.21 163.73 6,326.05 6,172.05 -1,460.84 -918.22 5,936,889.74 497,391.69 41.25 -1,598.09 MWD (2) 6,790.43 89.69 162.07 6,329.50 6,175.50 -1,489.60 -909.36 5,936,860.98 497,400.53 41.48 -1,624.88 MWD (2) 6,820.36 102.35 159.65 6,326.37 6,172.37 -1,517.66 -899.63 5,936,832.92 497,410.26 43.05 -1,650.82 MWD (2) - 6,850.93 101.41 145.21 6,320.05 6,166.05 -1,544.10 -885.82 5,936,806.48 497,42406 46.32 -1,674.46 MWD (2) 6,881.10 100.46 131.18 6,314.29 6,160.30 -1,566.12 -866.12 5,936,784.46 497,443.75 45.76 -1,692.72 MWD (2) 6,910.99 99.35 117.72 6,309.13 6,155.13 -1,582.73 -841.90 5,936,767.84 497,467.97 44.51 -1,704.88 MWD (2) 6,940.91 99.40 105.26 6,304.24 6,150.24 -1,593.52 -814.49 5,936,757.04 497,495.38 41.09 -1,710.74 MWD (2) 6,970.57 97.69 92.91 6,299.81 6,145.81 -1,598.13 -785.58 5,936,752.42 497,524.28 41.57 -1,710.27 MWD (2) 7,000.62 101.68 80.90 6,294.74 6,140.74 -1,596.56 -756.07 5,936,753.99 497,553.79 41.56 -1,703.59 MWD (2) 7,030.42 100.15 68.09 6,289.08 6,135.08 -1,588.74 -727.94 5,936,761.80 497,581.92 42.52 -1,691.01 MWD (2) 7,060.66 100.62 55.42 6,283.60 6,129.60 -1,574.70 -701.79 5,936,775.84 497,608.07 41.24 -1,672.64 MWD (2) 7,090.36 100.34 43.03 6,278.18 6,124.18 -1,555.66 -679.72 5,936,794.86 497630.14 41.03 -1,650.06 MWD (2) 7,121.33 93.75 34.08 6,274.38 6,120.38 -1,531.66 -660.61 5,936,818.87 497,649.25 35.70 -1,623.10 MWD (2) 7,149.75 94.09 30.68 6,272.43 6,118.43 -1,507.71 -645.43 5,936,842.80 497,664.44 12.00 -1,596.89 MWD (2) 7,180.58 95.41 27.51 6,269.88 6,115.88 -1,480.87 -630.49 5,936,869.64 497,679.38 11.11 -1,567.86 MWD (2) 7,210.59 95.81 26.28 6,266.95 6,112.95 -1,454.24 -616.98 5,936,896.27 497,692.90 4.29 -1,539.28 MWD (2) 7,239.99 95.81 23.11 6,263.97 6,109.97 -1,427.67 -604.76 5,936,922.83 497,705.12 10.73 -1,510.99 MWD(2) 7,270.91 96.03 20.46 6,260.78 6,106.78 -1,399.11 -593.35 5,936,951.38 497,716.54 8.55 -1,480.89 MWD (2) 7,300.18 96.68 18.67 6,257.54 6,103.54 -1,371.70 -583.61 5,936,978.79 497,726.29 6.47 -1,452.20 MWD (2) 7,330.72 95.25 15.72 6,254.37 6,100.37 -1,342.69 -574.63 5,937,007.80 497,735.27 10.69 -1422.07 MWD (2) " 12WO16 12.108.33PM Page 3 COMPASS 5000.1 Build 74 Survey ConocoPhillips ON ConocoPhillips Definitive Survey Report HKUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well 2K-11 MD Project: Kupamk River Unit TVD Reference: 2K-11 @ 154.00usft (2K-11) TVDSS Site: Kupamk 2K Pad MD Reference: 2K-11 @ 154.00usft (2K-11) Easting Well: 2K-11 North Reference: True (1) Wellbore: 2K-11APB1 Survey Calculation Method: Minimum Curvature Waft) Design: 2K-11APB1 Database: EDM Alaska NSK Sandbox (°1100') Survey 121512016 12:05:33PM Page 4 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E1-WDLS Notthing Easting Section Survey Tool Name Annotation Wait) (1) M Nan) (usft) Waft) Nom) (ft) If) (°1100') (ft) 7,359.93 95.26 13.54 6,251.69 6,097.69 -1,314.55 -567.28 5,937,035.93 497,742.62 7.43 -1,393.08 MWD (2) 7,390.30 93.07 12.85 6,249.48 6,095.48 -1,285.06 -560.37 5,937,065.42 497,749.54 7.56 -1,362.84 MWD (2) 7,420.45 92.06 12.24 6,248.13 6,094.13 -1,255.66 -553.83 5,937,094.81 497,756.09 3.91 -1,332.75 MWD (2) 7,446.53 89.57 12.17 6,247.76 6,093.76 -1,230.17 -548.31 5,937,120.30 497,761.61 9.55 -1,306.70 MWD (2) 7,475.79 88.44 11.70 6,248.27 6,094.27 -1,201.55 -542.26 5,937,148.91 497,767.66 4.18 -1,277.46 MWD (2) 7,501.51 88.10 10.15 6,249.05 6,095.05 -1,176.31 -537.39 5,937,174.15 497,772.54 6.17 -1,251.75 MWD (2) 7,531.53 88.16 8.72 6,250.03 6,096.03 -1,146.71 -532.47 5,937,203.74 497,777,46 4.77 -1,221.75 MWD (2) 7,559.75 87.88 6.33 6,251.00 6,097.00 -1,118.75 -528.78 5,937,231.70 497,781.16 8.52 -1,193.58 MWD (2) 7,590.67 90.09 5.51 6,251.55 6,097.55 -1,088.00 -525.59 5,937,262.44 497,784.36 7.62 -1,162.74 MWD (2) 7,620.55 93.04 5.26 6,250.73 6,096.74 -1,058.27 -522.79 5,937,292.17 497,787.17 9.91 -1,132.97 MWD (2) 7,650.77 91.17 4.40 6,249.62 6,095.63 -1,028.18 -520.25 5,937,322.26 497,789.72 6.81 -1,102.90 MWD (2) 7,681.23 87.51 2.66 6,249.98 6,095.98 -997.79 -518.37 5,937,352.65 497,791.60 13.30 -1,072.64 MWD (2) 7,710.05 88.46 2.29 6,250.99 6,096.99 -969.01 -517.13 5,937,381.42 497,792.85 3.54 -1,044.09 MWD (2) 7,740.56 89.88 0.65 6,251.43 6,097.43 -938.52 -516.35 5,937,411.91 497,793.64 7.11 -1,013.92 MWD (2) g 7,770.20 89.42 358.68 6,251.61 6,097.61 -908.88 -516.52 5,937,441.55 497,793.47 6.83 -984.76 MWD (2) 7,800.35 92.15 2.47 6,251.20 6,097.20 -878.74 -516.22 5,937,471.68 497,793.78 15.49 -955.03 MWD (2) - 7,829.83 90.58 3.56 6,250.50 6,096.50 -849.31 -514.67 5,937,501.11 497,795.34 6.48 -925.78 MWD (2) 7,860.26 91.01 542 6,250.07 6,096.07 -818.98 -512.28 5,937,531.44 497797.72 6.27 -895.49 MWD (2) 7,889.87 90.40 6,75 6,249.71 6,095.71 -789.54 -509.15 5,937,560.87 497,800.87 4.94 -865.96 MWD (2) 7,920.39 88.96 9.04 6,249.88 6,095.88 -759.31 -504.95 5,937,591.10 497,805.07 8.86 -835.46 MWD (2) 7,950.30 90.77 9.12 6,249.95 6,095.95 -729.78 -500.23 5,937,620.63 497,809.79 6.06 -805.56 MWD (2) 7,980.25 91.63 741 6,249.32 6,095.32 -700.15 -495.93 5,937,650.26 497,814.10 6.39 -775.63 MWD(2) 8,010.13 90.52 4.17 6,248.76 6,094.76 -670.43 -492.92 5,937,679.97 497,817.12 11.46 -745.84 MWD (2) 8,040.10 90.25 2.09 6,248.56 6,094.56 -640.51 -491.28 5,937,709.89 497,818.77 7.00 -716.08 MWD (2) 8,070.12 90.55 359.17 6,248.35 6,094.35 -610.49 -490.95 5,937,739.90 497,819.10 9.78 -686.47 MWD (2) 8,100.28 91.69 359.33 6,247.76 6,093.76 -580.34 A91.35 5,937,770.05 497,818.71 3.82 -656.84 MWD (2) 8,130.27 91.87 358.15 6,246.83 6,092.83 -550.37 492.00 5,937,800.01 497,818.06 3.98 -627.45 MWD (2) 8,160.19 91.93 358.75 6,245.84 6,091.84 -520.48 -492.81 5,937,829.90 497,817.26 2.01 -598.15 MWD (2) 8,190.26 92.00 359.93 6,244.81 6,090.81 -490.43 -493.16 5,937,859.95 497,816.92 3.93 -568.62 MWD (2) 8,220.25 92.12 2.18 6,243.73 6,089.73 -460.47 A92.61 5,937,889.91 497,817.48 7.51 -539.01 MWD (2) 8,250.33 91.44 5.36 6,242.80 6,088.80 A30.47 490.63 5,937,919.90 497,819.46 10.81 -509.13 MWD (2) 121512016 12:05:33PM Page 4 COMPASS 5000.1 Build 74 ConocoPhillips BAKER ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2K Pad Well: 2K-11 Wellbore: 2K-11APB1 Design: 2K-11 APB1 Survey MD Inc AN TVD TVDSS +NIS NMI (°I i°► (usft) lustt) (ush) 8,280.31 91.29 8.49 6,242.08 6,088.08 -400.72 8,309.89 9166 8.57 6,241.32 6,087.32 -371.48 8,340.05 92.76 10.25 6,240.16 6,086.16 -341,75 8,370.28 9362 12.00 6,238.47 6,084.47 -312.13 8,401.83 93.44 11.62 6,236.53 6,082.53 -281.31 8,425.48 93.16 957 6,235.17 6,081.17 -258.10 8,455.90 93.07 7.93 6,233.52 6,079.52 -228.08 8,485.42 89.97 6.88 6,232.73 6,078.73 -198.82 8,510.60 88.40 5.57 6,233.09 6,079.09 -173.79 8,540.36 86.59 4.10 6,234.39 6,080.39 -144.17 8,570.27 87.66 3.17 6,235.89 6,081.89 -114.36 8,600.15 86.90 1.81 6,237.31 6,083.31 -84.54 8,630.05 87.33 358.52 6,238.82 6,084.82 -54.68 8,660.11 87.42 359.55 6,240.19 6,086.19 -24.66 8,690.17 88.19 0.93 6,241.34 6,087.34 5.38 8,720.41 90.15 263 6,241.78 6,087.78 35.60 8,750.23 91.29 4.99 6,241.41 6,087.41 65.34 8,780.15 90.77 6.20 6,240.87 6,086.87 95.12 8,810.07 91.88 9.94 6,240.18 6,086.18 124.73 8,834.97 92.70 10.65 6,239.18 6,085.18 149.21 8,865.72 93.93 11.10 6,237.40 6,063.40 179.35 8,896.87 92.73 13.23 6,235.59 6,081.60 209.75 z 8,926.59 93.84 14.20 6,233.89 6,079.89 238.57 8,955.22 95.29 15.38 6,231.61 6,077.61 266.17 8,985.27 94.73 13.21 6,228.99 6,074.99 295.17 9,010.23 9446 11.02 6,226.99 6,072.99 319.50 9,030.65 94.49 9.15 6,225.40 6,071.40 339.54 9,058.00 94.49 9.15 6,223.25 6,069.25 366.46 Local Co-ordinate Reference: Well 2K-11 TVD Reference: 2K-11 @ 154.00usft (2K-11) MD Reference: 2K-11 @ 154.00usft (2K-11) North Reference: True Survey Calculation Method: Minimum Curvature Database. EDM Alaska NSK Sandbox Map Map vertical +PJ -W Northing Easting OLS Seaton Survey Tool Name (usft) (ft) (ft) (°Moo.) (ft) 487.02 5,937,949.65 497,823.08 10.45 479.20 MWD (2) 482.63 5,937,978.89 497,827.47 1.28 -449.64 MWD (2) -477.70 5,938,008.61 497,832.41 6.65 A19.51 MWD (2) 471.88 5,938,038.22 497,838.24 6.44 -389.33 MWD (2) -465.44 5,938,069.04 497,844.69 1.33 -357.86 MWD (2) -061.10 5,938,092.25 497,849.03 8.73 -334.25 MWD (2) 456.47 5,938,122.26 497,853.66 5.39 -303.88 MWD (2) A52.67 5,938,151.52 497,857.47 11.09 -274.41 MWD(2) -449.94 5,938,176.54 497,860.20 8.12 -249.29 MWD (2) -447.44 5,938,206.16 497,862.72 7.83 -219.68 MWD (2) 1145.54 5,938,235.97 497,864.62 4.74 -189.99 MWD (2) -444.25 5,938,265.79 497,865.92 5.21 -160.40 MWD (2) -444.16 5,938,295.64 497,866.01 11.08 -130.98 MWD (2) -444.67 5,938,325.66 497,865.51 3.44 -101.50 MWD (2) -444.54 5,938,355.70 497,865.65 5.25 -71.90 MWD (2) -443.60 5,938,385.91 497,866.59 8.58 41.98 MWD (2) -441.62 5,938,415.66 497,868.58 8.79 -12.33 MWD (2) 1138.70 5,938,445.43 497,871.50 4.40 17.49 MWD (2) 434.50 5,938,475.03 497,875.71 13.04 47.38 MWD (2) 430.06 5,938,499.51 497,880.16 4.35 72.26 MWD(2) 1124.27 5,938,529.65 497,885.96 4.26 102.95 MWD (2) -417.71 5,938,560.04 497,892.52 7.84 134.03 MWD (2) 410.68 5,938,588.86 497,899.56 4.96 163.64 MWD (2) 403.39 5,938,616.45 497,906.85 6.52 192.07 MWD (2) -396.00 5,938,645.45 497,914.24 7.43 221.92 MWD(2) -390.78 5,938,669.77 497,919.47 8.81 246.78 MWD (2) -387.22 5,938,689.81 497,923.04 9.13 267.14 MWD (2) -382.88 5,938,716.73 497,927.38 0.00 294.40 PROJECTED to TD Annotation IZWO16 12.,08:33PM Page 5 COMPASS 50001 Build 74 FrA as BAKER HUGHES To IVSD pEC 06 2016 ���� Letter of Transmittal Date: December 5 2016 DATA LOGGED L'L/9 /201G iw! K BENDER Makana Bender AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 From: Yosha Ragbirsingh / Michael Soper Baker Hughes INTEQ 795 East 94th Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 2K-11APB1 2 1 6 1 0 6 27 73 7 2K-11AL1 2 1 6 1 0 7 27 7 3 8 2k -11A2 1 6 1 0 6 2-n—tc 5 (4) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files I Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Project Engineer Michael. Soper@BakerHughes.com Yosha Ragbirsingh, Baker Hughes, Survey Manager Yosha.Ragbirsingh@BakerHughes.com ConocoPhilli s p EVV E pEC 0 6 2016 nor � ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad 2K -11A 50-103-20114-01 Baker Hughes INTEQ Definitive Survey Report 05 December, 2016 21 61 06 -234-- 2n11�5 MA as BAKER HUGHES ConocoPhillips FeAal ConocoPhillips Definitive Survey Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2K-11 Project: Kuparuk River Unit TVD Reference: 2K-11 @ 154.00usft (2K-11) Site: Kuparuk 2K Pad MD Reference: 2K-11 @ 154.00usft (2K-11) j Well: 2K-11 North Reference: True Wellbore: 2K -11A Survey Calculation Method: Minimum Curvature Design: 2K -11A 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 v Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2K-11 ) Well Position +N/ -S 0.00 usft Northing: 5,938,350.22 usft Latitude: 70° 14'34.061 N +E/ -W 0.00 usft Easting: 498,310.14 usft Longitude: 150° 0'49.133 W ( Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 2K -11A d Magnetics Model Name Sample Date Declination Dip Angle Field Strength (nT) BGGM2016 11/1/2016 17.8D 80.87 57,536 z _ Design 2K -11A .. Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 6,811.20 M a Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction — (usft) (usft) (usft) (_) g I 154.00 0.00 0.00 0.00 ... ., ,. Survey Program Date 11/29/2016 From To Survey a Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 200.00 6,500.00 2K-11 (2K-11) BOSS -GYRO Sperry -Sun BOSS gyro multishot 1/12/2001 6,511.00 6,570.98 2K-11APB1 (2K-11APB1) MWD MWD- Standard 10/23/2016 11/5/2016 6,577.00 6,811.20 2K-11AL1 (2K -11A1_1) MWD MWD- Standard 11/6/2016 11/15/2016 6,840.00 9,500.02 2K -11A (2K -11A) MWD MWD - Standard 11/16/2016 11/21/2016 12/5/2016 12:27:OOPM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips [/rs ConocoPhillips Definitive Survey Report BHUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2K-11 Project: Kuparuk River Unit TVD Reference: 2K-11 @ 154.00usft (2K-11) Site: Kuparuk 2K Pad MD Reference: 2K-11 @ 154.00usft (2K-11) Well: 2K-11 North Reference: True Wellbore: 2K -11A Survey Calculation Method: Minimum Curvature Design: 2K -11A Database: EDM Alaska NSK Sandbox Survey -1,673.60 MWD (4) 6,811.20 Vertical DLS Section (°/1001) Survey Tool Name Annotation (ft) 11.61 -1,517.80 MWD (3) 6.48 Map Map MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing East) ng (usft) (°) (I (usft) (usft) (usft) usft -1,673.60 MWD (4) 6,811.20 102.81 169.73 6,292.17 6,138.17 -1,517.80 -880.25 5,936,832.77 497,429.64 6,840.00 103.30 167.88 6,285.67 6,131.67 -1,545.32 -874.80 5,936,805.25 497,435.08 6,870.19 88.80 159.72 6,282.49 6,128.49 -1,574.04 -866.43 5,936,776.53 497,443.45 6,900.15 83.76 151.79 6,284.44 6,130.44 -1,601.27 -854.17 5,936,749.30 497,455.70 6,930.24 84.56 138.84 6,287.51 6,133.51 -1,625.83 -837.17 5,936,724.74 497,472.69 6,960.01 85.64 127.67 6,290.06 6,136.06 -1,646.12 -815.60 5,936,704.45 497,494.25 6,990.13 89.72 117.34 6,291.28 6,137.28 -1,662.26 -790.26 5,936,688.30 497,519.59 7,019.97 95.22 107.43 6,290.00 6,136.00 -1,673.60 -762.74 5,936,676.96 497,547.10 7,050.08 98.90 96.61 6,286.28 6,132.28 -1,679.83 -733.56 5,936,670.73 497,576.27 7,080.05 98.63 84.20 6,281.70 6,127.70 -1,680.03 -704.01 5,936,670.51 497,605.83 7,110.11 97.76 73.10 6,277.40 6,123.40 -1,674.19 -674.88 5,936,676.35 497,634.95 7,139.89 93.93 61.64 6,274.36 6,120.36 -1,662.80 -647.59 5,936,687.73 497,662.24 7,170.77 91.47 50.16 6,272.90 6,118.90 -1,645.53 -622.10 5,936,704.99 497,687.73 7,200.45 91.97 39.28 6,272.01 6,118.01 -1,624.49 -601.26 5,936,726.03 497,708.58 7,230.71 92.67 37.15 6,270.78 6,116.78 -1,600.73 -582.55 5,936,749.78 497,727.29 7,259.86 93.53 34.98 6,269.20 6,115.21 -1,577.20 -565.42 5,936,773.30 497,744.43 7,289.96 93.13 33.03 6,267.46 6,113.46 -1,552.30 -548.61 5,936,798.20 497,761.23 7,320.34 92.92 31.34 6,265.85 6,111.85 -1,526.62 -532.45 5,936,823.87 497,777.40 7,350.09 92.18 30.38 6,264.53 6,110.53 -1,501.11 -517.21 5,936,849.38 497,792.65 7,380.33 92.39 30.48 6,263.32 6,109.32 -1,475.05 -501.91 5,936,875.43 497,807.95 7,410.31 93.13 29.79 6,261.88 6,107.88 -1,449.16 -486.87 5,936,901.32 497,822.99 7,440.58 92.24 28.77 6,260.46 6,106.46 -1,422.78 472.08 5,936,927.68 497,837.78 7,470.14 90.37 27.47 6,259.79 6,105.79 -1,396.72 -458.16 5,936,953.74 497,851.72 7,500.35 89.79 26.17 6,259.75 6,105.75 -1,369.76 -444.53 5,936,980.70 497,865.35 7,530.67 89.36 25.02 6,259.97 6,105.97 -1,342.42 -431.43 5,937,008.03 497,878.45 7,559.87 89.63 22.82 6,260.23 6,106.23 -1,315.73 -419.59 5,937,034.72 497,890.30 7,590.18 90.71 21.16 6,260.14 6,106.14 -1,287.63 -408.24 5,937,062.82 497,901.65 7,620.15 89.94 18.38 6,259.97 6,105.97 -1,259.43 -398.11 5,937,091.01 497,911.79 7,650.23 91.53 16.76 6,259.58 6,105.58 -1,230.75 -389.03 5,937,119.68 497,920.88 7,67522 91.44 14.33 6,258.94 6,104.94 -1,206.69 -382.33 5,937,143.74 497,927.57 Vertical DLS Section (°/1001) Survey Tool Name Annotation TIP KOP 12/5/2016 12:27:OOPM Page 3 COMPASS 5000.1 Build 74 (ft) 11.61 -1,517.80 MWD (3) 6.48 -1,545.32 MWD (4) 55.00 -1,574.04 MWD (4) 31.31 -1,601.27 MWD (4) 42.90 -1,625.83 MWD (4) 37.56 -1,646.12 MWD (4) 36.84 -1,662.26 MWD (4) 37.94 -1,673.60 MWD (4) 37.69 -1,679.83 MWD (4) 40.93 -1,680.03 MWD (4) 36.66 -1,674.19 MWD (4) 40.38 -1,662.80 MWD (4) 37.98 -1,645.53 MWD (4) 36.68 -1,624.49 MWD (4) 7.40 -1,600.73 MWD (4) 8.00 -1,577.20 MWD (4) 6.60 -1,552.30 MWD (4) 5.60 -1,526.62 MWD (4) 4.07 -1,501.11 MWD (4) 0.77 -1,475.05 MWD (4) 3.37 -1,449.16 MWD (4) 4.47 -1,422.78 MWD (4) 7.70 -1,396.72 MWD (4) 4.71 -1,369.76 MWD (4) 4.05 -1,342.42 MWD (4) 7.59 -1,315.73 MWD (4) 6.53 -1,287.63 MWD (4) 9.62 -1,259.43 MWD (4) 7.55 -1,230.75 MWD (4) 9.73 -1,206.69 MWD (4) TIP KOP 12/5/2016 12:27:OOPM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips F/AG ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2K-11 Project: Kuparuk River Unit TVD Reference: 2K-11 @ 154.00usft (2K-11) Site: Kuparuk 2K Pad MD Reference: 2K-11 @ 154.00usft (2K-11) Well: 2K-11 North Reference: True Wellbore: 2K -11A Survey Calculation Method: Minimum Curvature Design: 2K -11A Database: EDM Alaska NSK Sandbox Survey 1215/2016 12:27:OOPM Page 4 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +EI -W Northing Easting DLS Section Survey Tool Name Annotation (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) 7,704.62 91.10 13.27 6,258.28 6,104.28 -1,178.14 -375.32 5,937,172.28 497,934.59 3.79 -1,178.14 MWD (4) 7,735.35 90.00 12.52 6,257.99 6,103.99 -1,148.19 -368.46 5,937,2D2.23 497,941.46 4.33 -1,148.19 MWD (4) 7,764.85 88.53 11.13 6,258.37 6,104.37 -1,119.32 -362.42 5,937,231.09 497,947.51 6.86 -1,119.32 MWD (4) 7,795.29 87.61 9.27 6,259.39 6,105.39 -1,089.38 -357.03 5,937,261.03 497,952.90 6.81 -1,089.38 MWD (4) 7,824.65 87.11 7.35 6,260.75 6,106.75 -1,060.36 -352.79 5,937,290.05 497,957.14 6.75 -1,060.36 MWD (4) 7,854.45 88.40 5.40 6,261.91 6,107.91 -1,030.77 -349.49 5,937,319.63 497,960.46 7.B4 -1,030.77 MWD (4) 7,885.11 89.66 3.88 6,262.43 6,108.43 -1,000.22 -347.01 5,937,350.18 497,962.94 6.44 -1,000.22 MWD (4) 7,922.15 91.63 2.23 6,262.01 6,108.01 -963.23 -345.03 5,937,387.16 497,964.92 6.94 -963.23 MWD (4) 7,949.33 92.92 0.55 6,260.94 6,106.94 -936.08 -344.38 5,937,414.31 497,965.59 7.79 -936.08 MWD (4) 7,979.99 92.98 358.99 6,259.36 6,105.36 -905.47 -344.50 5,937,444.92 497,965.47 5.09 -905.47 MWD (4) 8,010.01 93.44 356.64 6,257.68 6,103.68 -875.52 -345.64 5,937,474.87 497,964.34 7.96 -875.52 MWD (4) 8,039.67 95.04 354.33 6,255.48 6,101.48 -846.03 -347.97 5,937,504.35 497,962.02 9.46 -846.03 MWD (4) 8,070.49 95.32 352.32 6,252.70 6,098.70 -815.55 -351.54 5,937,534.83 497,958.46 6.56 -815.55 MWD (4) 8,099.70 97.02 351.91 6,249.56 6,095.56 -786.78 -355.52 5,937,563.59 497,954.48 5.98 -786.78 MWD (4) 8,130.89 97.14 349.79 6,245.72 6,091.72 -756.23 -360.44 5,937,594.15 497,949.57 6.76 -756.23 MWD (4) 8,160.58 97.16 347.74 6,242.02 6,088.02 -727.33 -366.18 5,937,623.04 497,943.83 6.85 -727.33 MWD (4) 8,191.19 97.02 345.98 6,238.24 6,084.24 -697.76 -373.09 5,937,652.62 497,936.94 5.72 -697.76 MWD (4) 8,220.77 95.53 347.40 6,235.01 6,081.01 -669.14 -379.85 5,937,681.23 497,930.17 6.94 -669.14 MWD (4) 8,251.04 93.72 349.00 6,232.57 6,078.57 -639.61 -386.02 5,937,710.76 497,924.01 7.97 -639.61 MWD (4) 8,281.10 91.84 349.34 6,231.11 6,077.11 -610.12 -391.66 5,937,740.25 497,918.38 6.36 -610.12 MWD (4) 8,310.77 90.15 350.73 6,230.59 6,076.60 -580.91 -396.80 5,937,769.46 497,913.25 7.37 -580.91 MWD (4) 8,341.46 87.76 348.20 6,231.15 6,077.15 -550.74 -4D2.41 5,937,799.62 497,907.65 11.34 -550.74 MWD (4) 8,370.69 87.36 351.12 6,232.40 6,078.40 -522.02 -407.65 5,937,828.35 497,9D2.42 10.07 -522.02 MWD (4) 8,401.14 87.70 353.03 6,233.71 6,079.71 -491.89 411.84 5,937,858.47 497,898.23 6.37 -491.89 MWD (4) 8,429.75 88.10 355.37 6,234.76 6,080.76 -463.45 414.73 5,937,886.91 497,895.35 8.29 -463.45 MWD (4) 8,461.10 87.63 358.44 6,235.93 6,081.93 -432.17 -416.42 5,937,918.19 497,893.66 9.90 -432.17 MWD (4) 8,489.96 88.19 359.69 6,236.98 6,082.98 -403.33 -416.89 5,937,947.02 497,893.20 4.74 403.33 MWD (4) 8,520.24 87.76 2.60 6,238.05 6,084.05 -373.08 416.29 5,937,977.27 497,893.81 9.71 -373.08 MWD (4) 8,549.65 85.98 2.53 6,239.66 6,085.66 -343.74 414.97 5,938,006.60 497,895.13 6.06 -343.74 MWD (4) 8,579.85 84.34 3.92 6,242.21 6,088.21 -313.70 -413.28 5,938,036.64 497,896.83 7.11 -313.70 MWD (4) 8,610.25 84.81 5.91 61245.08 6,091.08 -283.55 1410.69 5,938,066.79 497,899.43 6.70 -283.55 MWD (4) 1215/2016 12:27:OOPM Page 4 COMPASS 5000.1 Build 74 ConocoPhillips //itI ConocoPhillips Definitive Survey Report BHUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2K Pad Well: 2K-11 Wellbore: 2K -11A Design: 2K -11A Survey Local Co-ordinate Reference: Well 2K-11 TVD Reference: 2K-11 @ 154.00usft (2K-11) MD Reference: 2K-11 @ 154.00usft (2K-11) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM Alaska NSK Sandbox MD Inc Annotation 12/5/2016 12:27-OOPM Page 5 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi ND TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) Survey Tool Name (ft) (ft) (ft) 8,639.55 86.25 6.88 6,247.36 6,093.36 -254.52 -407.44 5,938,095.82 497,902.69 5.92 -254.52 MWD (4) 8,671.40 88.96 9.20 6,248.69 6,094.69 -223.02 -402.98 5,938,127.32 497,907.15 11.20 -223.02 MWD (4) 8,701.30 90.34 10.34 6,248.88 6,094.88 -193.55 -397.91 5,938,156.78 497,912.23 5.99 -193.55 MWD (4) 8,731.66 92.09 12.54 6,248.23 6,094.23 -163.81 -391.89 5,938,186.52 497,918.25 9.26 -163.81 MWD (4) 8,765.36 92.49 10.94 6,246.89 6,092.89 -130..84 -385.04 5,938,219.48 497,925.11 4.89 -130.84 MWD (4) 8,791.40 94.25 12.01 6,245.36 6,091.36 -105.36 -379.87 5,938,244.95 497,930.29 7.91 -105.36 MWD (4) 8,821.51 95.57 13.25 6,242.78 6,088.78 -76.09 -373.31 5,938,274.22 497,936.85 6.00 -76.09 MWD (4) 8,851.86 93.50 13.82 6,240.38 6,086.38 -46.68 -366.23 5,938,303.63 497,943.94 7.07 -46.68 MWD (4) 8,882.24 93.32 15.41 6,238.57 6,084.57 -17.33 -358.58 5,938,332.97 497,951.59 5.26 -17.33 MWD (4) 8,911.72 94.80 16.68 6,236.48 6,082.48 10.92 -350.45 5,938,361.22 497,959.73 6.61 10.92 MWD (4) 8,941.94 95.38 19.44 6,233.80 6,079.80 39.54 -341.12 5,938,389.83 497,969.06 9.30 39.54 MWD (4) 8,971.57 95.88 21.42 6,230.90 6,076.90 67.17 -330.83 5,938,417.46 497,979.36 6.86 67.17 MWD (4) 9,002.72 94.52 19.78 6,228.07 6,074.07 96.21 -319.91 5,938,446.49 497,990.28 6.82 96.21 MWD (4) 9,D31.36 93.01 18.17 6,226.19 6,072.19 123.23 -310.62 5,938,473.51 497,999.58 7.70 123.23 MWD (4) 9,064.28 93.72 16.61 6,224.26 6,070.26 154.59 -300.80 5,938,504.86 498,009.40 5.20 154.59 MWD (4) 9,097.08 94.89 15.46 6,221.80 6,067.80 186.02 -291.77 5,938,536.29 498,018.44 4.99 186.02 MWD (4) 9,121.08 92.36 13.31 6,220.28 6,066.28 209.22 -285.82 5,938,559.49 498,024.40 13.82 209.22 MWD (4) 9,134.63 92.18 13.28 6,219.74 6,065.74 222.40 -282.70 5,938,572.66 498,027.51 1.35 222.40 MWD (4) 9,155.93 90.34 10.12 6,219.27 6,065.27 243.25 -278.39 5,938,593.51 498,031.84 17.16 243.25 MWD (4) 9,188.37 88.50 7.16 6,219.6D 6,065.60 275.31 -273.51 5,938,625.57 498,036.71 10.74 275.31 MWD (4) 9,215.63 87.73 6.44 6,220.50 6,066.50 302.37 -270.29 5,938,652.62 498,039.95 3.87 302.37 MWD (4) 9,246.23 86.D1 6.19 6,222.17 6,068.17 332.73 -266.93 5,938,682.98 498,043.31 5.68 332.73 MWD (4) 9,278.58 84.49 5.49 6,224.85 6,070.85 364.80 -263.65 5,938,715.05 498,046.60 5.17 364.80 MWD (4) 9,309.77 85.14 1.83 6,227.67 6,073.67 395.80 -261.67 5,938,746.04 498,046.59 11.87 395.80 MWD (4) 9,315.62 85.14 0.59 6,228.16 6,074.16 401.63 -261.54 5,938,751.86 498,048.71 21.12 401.63 MWD (4) 9,345.94 85.27 3.95 6,230.70 6,076.70 431.81 -260.35 5,938,782.05 498,049.92 11.05 431.81 MWD (4) 9,375.16 85.92 358.22 6,232.95 6,078.95 460.93 -259.79 5,938,811.16 498,050.47 19.68 460.93 MWD (4) 9,407.22 86.38 357.78 6,235.10 6,081.10 492.90 -260.91 5,938,843.12 498,D49.37 1.98 492.90 MWD (4) 9,435.60 87.39 357.21 6,236.64 6,082.64 521.21 -262.15 5,938,871.43 498,048.13 4.08 521.21 MWD (4) 9,467.88 88.46 356.23 6,237.81 6,083.81 553.41 -264.00 5,938,903.64 498,046.29 4.49 553.41 MWD (4) 9,500.02 86.77 356.70 6,239.15 6,085.15 585.46 -265.98 5,938,935.68 498,044.32 5.46 585.46 MWD (4) Annotation 12/5/2016 12:27-OOPM Page 5 COMPASS 5000.1 Build 74 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: HIM ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2K Pad Well: 2K-11 Wellbore: 2K-11 A Design: 2K -11A ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section Survey Tool Name Annotation (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) 9,550.00 86.77 356.70 6,241.96 6,087.96 635.28 -268.85 5,938,985.50 498,041.46 0.00 635.28 PROJECTED to TD 12/5/2016 12:27:OOPM Page 6 COMPASS 5000.1 Build 74 HIM BAKER HUGHES Well 2K-11 2K-11 @ 154.00usft (2K-11) 2K-11 @ 154.00usft (2K-11) True Minimum Curvature EDM Alaska NSK Sandbox Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section Survey Tool Name Annotation (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) 9,550.00 86.77 356.70 6,241.96 6,087.96 635.28 -268.85 5,938,985.50 498,041.46 0.00 635.28 PROJECTED to TD 12/5/2016 12:27:OOPM Page 6 COMPASS 5000.1 Build 74 216106 % 27 7 3 7 ConocoPhillips DEC 0 6 2�ia AOr ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad 2K-11APB1 50-103-20114-70 Baker Hughes INTEQ WMA R I BAKER Definitive Survey Report HUGHES 05 December, 2016 1215/2016 12.08:33PM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips //&'I ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2K-11 Project: Kuparuk River Unit TVD Reference: 2K-11 @ 154.00usft (2K-11) Site: Kuparuk 2K Pad MD Reference: 2K-11 @ 154.00usft (2K-11) Well: 2K-11 North Reference: True Wellbore: 2K-11APB1 Survey Calculation Method: Minimum Curvature Design: 2K-11APB1 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 2K-11 s Well Position +N/ -S 0.00 usft Northing: 5,938,350.22usft Latitude: 70° 14' 34.061 N +E/ -W 0.00 usft Easting: 498,310.14usft Longitude: 150° 0'49.133 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 2K-11APB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (nT) BGGM2016 11/1/2016 17.80 80.87 57,536 Design 2K-11APB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 6,500.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (°) 154.00 0.00 _ 0.00 10.00 Survey Program Date 11/15/2016 z From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 200.00 6,500.00 2K-11 (2K-11) BOSS -GYRO Sperry -Sun BOSS gyro multishot 1/12/2001 6,511.00 9,030 65 2K 11APB1 (2K 11APB1) MWD MWD - Standard 10/23/2016 11/5/2016 1215/2016 12.08:33PM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 2K Pad MD Reference: Well: 2K-11 North Reference: Wellbore: 2K-11APB1 Survey Calculation Method: Design: 2K-11APB1 Database: Survey FS fit HUGHES Annotation TIP KOP 12/6/2016 12:08:33PM Page 3 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Fasting DLS Section (usft) (°) (1 (usft) (usft) (usft) usft usft (usft) (°1100') Survey Tool Name (ft) (ft) (ft) 6,500.00 7.82 202.20 6,173.86 6,019.86 -1,287.02 -882.30 5,937,063.52 497,427.64 0.70 -1,420.68 MWD (2) 6,511.00 7.80 202.05 6,184.76 6,030.76 -1,288.41 -882.86 5,937,062.14 497,427.08 0.26 -1,422.14 MWD (2) 6,540.04 15.82 201.90 6,213.16 6,059.16 -1,293.92 -885.08 5,937,056.63 497,424.86 27.62 -1,427.95 MWD (2) 6,570.98 29.83 201.90 6,241.61 6,087.61 -1,305.03 -889.54 5,937,045.52 497,420.39 45.28 -1,439.67 MWD (2) 6,590.76 38.45 201.86 6,257.96 6,103.96 -1,315.32 -893.68 5,937,035.24 497,416.26 43.58 -1,450.52 MWD (2) 6,620.38 50.03 200.39 6,279.15 6,125.15 -1,334.57 -901.08 5,937,015.99 497,408.85 39.25 -1,470.77 MWD (2) 6,648.94 60.97 198.18 6,295.30 6,141.30 -1,356.76 -908.82 5,936,993.80 497,401.11 38.83 -1,493.96 MWD (2) 6,675.56 71.70 196.24 6,305.98 6,151.98 -1,380.04 -916.01 5,936,970.53 497,393.91 40.82 -1,518.13 MWD (2) 6,705.35 77.28 186.54 6,313.95 6,159.95 -1,408.02 -922.13 5,936,942.54 497,387.79 31.17 -1,546.76 MWD (2) 6,735.63 77.31 174.07 6,320.64 6,166.64 -1,437.47 -922.80 5,936,913.10 497,387.11 46.61 -1,575.87 MWD (2) 6,760.08 77.21 163.73 6,326.05 6,172.05 -1,460.84 -918.22 5,936,889.74 497,391.69 41.25 -1,598.09 MWD (2) 6,790.43 89.69 162.07 6,329.50 6,175.50 -1,489.60 -909.36 5,936,860.98 497,400.53 41.48 -1,624.88 MWD (2) 6,820.36 102.35 159.65 6,326.37 6,172.37 -1,517.66 -899.63 5,936,832.92 497,410.26 43.05 -1,650.82 MWD (2) 6,850.93 101.41 145.21 6,320.05 6,166.05 -1,544.10 -885.82 5,936,806.48 497,424.06 46.32 -1,674.46 MWD (2) 6,881.10 100.46 131.18 6,314.29 6,160.30 -1,566.12 -866.12 5,936,784.46 497,443.75 45.76 -1,692.72 MWD (2) 6,910.99 99.35 117.72 6,309.13 6,155.13 -1,582.73 -841.90 5,936,767.84 497,467.97 44.51 -1,704.88 MWD (2) 6,940.91 99.40 105.26 6,304.24 6,150.24 -1,593.52 -814.49 5,936,757.04 497,495.38 41.09 -1,710.74 MWD (2) 6,970.57 97.69 92.91 6,299.81 6,145.81 -1,598.13 -785.58 5,936,752.42 497,524.28 41.57 -1,710.27 MWD (2) 7,DD0.62 1D1.68 80.90 6,294.74 6,140.74 -1,596.56 -756.07 5,936,753.99 497,553.79 41.56 -1,703.59 MWD (2) 7,030.42 100.15 68.09 6,289.08 6,135.08 -1,588.74 -727.94 5,936,761.80 497,581.92 42.52 -1,691.01 MWD (2) 7,060.66 100.62 55.42 6,283.60 6,129.60 -1,574.70 -701.79 5,936,775.84 497,608.07 41.24 -1,672.64 MWD (2) 7,090.36 100.34 43.03 6,278.18 6,124.18 -1,555.66 -679.72 5,936,794.86 497,630.14 41.03 -1,650.06 MWD (2) 7,121.33 93.75 34.08 6,274.38 6,120.38 -1,531.66 £60.61 5,936,818.87 497,649.25 35.70 -1,623.10 MWD (2) 7,149.75 94.09 30.68 6,272.43 6,118.43 -1,507.71 -645.43 5,936,842.80 497,664.44 12.00 -1,596.89 MWD (2) 7,180.58 95.41 27.51 6,269.88 6,115.88 -1,480.87 -630.49 5,936,869.64 497,679.38 11.11 -1,567.86 MWD (2) 7,210.59 95.81 26.28 6,266.95 6,112.95 -1,454.24 -616.98 5,936,896.27 497,692.90 4.29 -1,539.28 MWD (2) 7,239.99 95.81 23.11 6,263.97 6,109.97 -1,427.67 -604.76 5,936,922.83 497,705.12 10.73 -1,510.99 MWD (2) 7,270.91 96.03 20.46 6,260.78 6,106.78 -1,399.11 -593.35 5,936,951.38 497,716.54 8.55 -1,480.89 MWD (2) 7,300.18 96.68 18.67 6,257.54 6,103.54 -1,371.70 -583.61 5,936,978.79 497,726.29 6.47 -1,452.20 MWD (2) 7,330.72 95.25 15.72 6,254.37 6,100.37 -1,342.69 -574.63 5,937,007.80 497,735.27 10.69 -1,422.07 MWD (2) Annotation TIP KOP 12/6/2016 12:08:33PM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips W/FAI ER ConocoPhillips Definitive Survey Report SHUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2K-11 Project: Kuparuk River Unit TVD Reference: 2K-11 @ 154.00usft (2K-11) Site: Kuparuk 2K Pad MD Reference: 2K-11 @ 154.00usft (2K-11) Well: 2K-11 North Reference: True Wellbore: 2K-11APB1 Survey Calculation Method: Minimum Curvature Design: 2K-11APB1 Database: EDM Alaska NSK Sandbox Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +El -W Northing Easting DLS Section (usft) (1) (1) (usft) (usft) (usft) (usft) (11100.) Survey Tool Name Annotation (ft) (ft) (ft) 7,359.93 95.26 13.54 6,251.69 6,097.69 -1,314.55 -567.28 5,937,035.93 497,742.62 7.43 -1,393.08 MVVD (2) 7,390.30 93.07 12.85 6,249.48 6,095.48 -1,285.06 -560.37 5,937,065.42 497,749.54 7.56 -1,362.84 MWD (2) 7,420.45 92.06 12.24 6,248.13 6,094.13 -1,255.66 -553.83 5,937,094.81 497,756.09 3.91 -1,332.75 MWD (2) 7,446.53 89.57 12.17 6,247.76 6,093.76 -1,230.17 -548.31 5,937,120.30 497,761.61 9.55 -1,306.70 MWD (2) 7,475.79 88.44 11.70 6,248.27 6,094.27 -1,201.55 -542.26 5,937,148.91 497,767.66 4.18 -1,277.46 MWD (2) 7,501.51 88.10 10.15 6,249.05 6,095.05 -1,176.31 -537.39 5,937,174.15 497,772.54 6.17 -1,251.75 MVVD (2) 7,531.53 88.16 8.72 6,250.03 6,096.03 -1,146.71 -532.47 5,937,203.74 497,777.46 4.77 -1,221.75 MWD (2) a 7,559.75 87.88 6.33 6,251.00 6,097.00 -1,118.75 -528.78 5,937,231.70 497,781.16 8.52 -1,193.58 MWD (2) 7,590.67 90.09 5.51 6,251.55 6,097.55 -1,088.00 -525.59 5,937,262.44 497,784.36 7.62 -1,162.74 MWD (2) 7,620.55 93.04 5.26 6,250.73 6,096.74 -1,058.27 -522.79 5,937,292.17 497,787.17 9.91 -1,132.97 MWD (2) 7,650.77 91.17 4.40 6,249.62 6,095.63 -1,028.18 -520.25 5,937,322.26 497,789.72 6.81 -1,102.90 MWD (2) 7,681.23 87.51 2.66 6,249.98 6,095.98 -997.79 -518.37 5,937,352.65 497,791.60 13.30 -1,072.64 MWD (2) 7,710.05 88.46 2.29 6,250.99 6,096.99 -969.01 -517.13 5,937,381.42 497,792.85 3.54 -1,044.09 MWD (2) 7,740.56 89.88 0.65 6,251.43 6,097.43 -938.52 -516.35 5,937,411.91 497,793.64 7.11 -1,013.92 MWD (2) 7,770.20 89.42 358.68 6,251.61 6,097.61 -908.88 -516.52 5,937,441.55 497,793.47 6.83 -984.76 MWD (2) 7,800.35 92.15 2.47 6,251.20 6,097.20 -878.74 -516.22 5,937,471.68 497,793.78 15.49 -955.03 MWD (2) 7,829.83 90.58 3.56 6,250.50 6,096.50 -849.31 -514.67 5,937,501.11 497,795.34 6.48 -925.78 MWD (2) 7,860.26 91.01 5.42 6,250.07 6,096.07 -818.98 -512.28 5,937,531.44 497,797.72 6.27 -895.49 MWD (2) 7,889.87 90.40 6.75 6,249.71 6,095.71 -789.54 -509.15 5,937,560.87 497,800.87 4.94 -865.96 MWD (2) 7,920.39 88.96 9.04 6,249.88 6,095.88 -759.31 -504.95 5,937,591.10 497,805.07 8.86 -835.46 MWD (2) 7,950.30 90.77 9.12 6,249.95 6,095.95 -729.78 -500.23 5,937,620.63 497,809.79 6.06 -805.56 MWD (2) 7,980.25 91.63 7.41 6,249.32 6,095.32 -700.15 -495.93 5,937,650.26 497,814.10 6.39 -775.63 MWD (2) 8,010.13 90.52 4.17 6,248.76 6,094.76 -670.43 -492.92 5,937,679.97 497,817.12 11.46 -745.84 MWD (2) 8,040.10 90.25 2.09 6,248.56 6,094.56 -640.51 -491.28 5,937,709.89 497,818.77 7.00 -716.08 MWD (2) 6,070.12 90.55 359.17 6,248.35 6,094.35 -610.49 -490.95 5,937,739.90 497,819.10 9.78 -686.47 MWD (2) 8,100.28 91.69 359.33 6,247.76 6,093.76 -580.34 -491.35 5,937,770.05 497,818.71 3.82 -656.84 MWD (2) 8,130.27 91.87 358.15 6,246.83 6,092.83 -550.37 -492.00 5,937,800.01 497,818.06 3.98 -627.45 MWD (2) 8,160.19 91.93 358.75 6,245.84 6,091.84 -520.48 -492.81 5,937,829.90 497,817.26 2.01 -598.15 MWD (2) 8,190.26 92.00 359.93 6,244.81 6,090.81 -490.43 -493.16 5,937,859.95 497,816.92 3.93 -568.62 MWD (2) 8,220.25 92.12 2.18 6,243.73 6,089.73 -460.47 -492.61 5,937,889.91 497,817.48 7.51 -539.01 MWD (2) 8,250.33 91.44 5.36 6,242.80 61088.80 -430.47 -490.63 5,937,919.90 497,819.46 10.81 -509.13 MWD (2) 12/5/2016 12 08:33PM Page 4 COMPASS 5000.1 Build 74 ConocoPhillips [/FAI ConocoPhillips Definitive Survey Report BHUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2K-11 Project: Kuparuk River Unit TVD Reference: 2K-11 @ 154.00usft (2K-11) Site: Kuparuk 2K Pad MD Reference: 2K-11 @ 154.00usft (2K-11) Well: 2K-11 North Reference: True Wellbore: 2K-11APB1 Survey Calculation Method: Minimum Curvature Design: 2K-11AP61 Database: EDM Alaska NSK Sandbox Survey 12/5/2016 12:08:33PM Page 5 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Fasting DLS Section Survey Tool Name Annotation (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (111001) (ft) 8,280.31 91.29 8.49 6,242.08 6,088.08 -400.72 -487.02 5,937,949.65 497,823.08 10.45 -479.20 MWD (2) 8,309.89 91.66 8.57 6,241.32 6,087.32 -371.48 -482.63 5,937,978.89 497,827.47 1.28 -449.64 MWD (2) 8,340.05 92.76 10.25 6,240.16 6,OB6.16 -341.75 477.70 5,938,008.61 497,832.41 6.65 419.51 MWD (2) 8,370.28 93.62 12.00 6,238.47 6,064.47 -312.13 471.88 5,938,038.22 497,838.24 6.44 -389.33 MWD (2) 8,401.83 93.44 11.62 6,236.53 6,082.53 -281.31 -465.44 5,938,069.04 497,844.69 1.33 -357.86 MWD (2) B,425.4B 93.16 9.57 6,235.17 6,081.17 -258.10 -461.10 5,938,092.25 497,849.03 8.73 -334.25 MWD (2) 8,455.90 93.07 7.93 6,233.52 6,079.52 -228.08 -456.47 5,938,122.26 497,853.66 5.39 -303.88 MWD (2) 8,485.42 89.97 6.8B 6,232.73 6,078.73 -198.82 452.67 5,938,151.52 497,857.47 11.09 -274.41 MWD (2) 8,510.60 88.40 5.57 6,233.09 6,079.09 -173.79 -449.94 5,938,176.54 497,860.20 8.12 -249.29 MWD (2) 8,540.36 86.59 4.1D 6,234.39 6,080.39 -144.17 -447.44 5,938,206.16 497,862.72 7.83 -219.68 MWD (2) 8,570.27 B7.66 3.17 6,235.89 6,081.89 -114.36 -445.54 5,938,235.97 497,864.62 4.74 -189.99 MWD (2) 8,600.15 86.90 1.81 6,237.31 6,083.31 -84.54 444.25 5,938,265.79 497,865.92 5.21 -160.40 MWD (2) 8,630.05 87.33 358.52 6,238.82 6,084.82 -54.68 444.16 5,938,295.64 497,866.01 11.08 -130.98 MWD (2) 8,660.11 87.42 359.55 6,240.19 6,086.19 -24.66 -444.67 5,938,325.66 497,865.51 3.44 -101.50 MWD (2) 8,690.17 88.19 0.93 6,241.34 6,087.34 5.38 -444.54 5,938,355.70 497,865.65 5.25 -71.90 MWD (2) 8,720.41 90.15 2.63 6,241.78 6,087.78 35.60 -443.60 5,938,385.91 497,866.59 8.58 41.98 MWD (2) 8,750.23 91.29 4.99 6,241.41 6,087.41 65.34 -441.62 5,938,415.66 497,868.58 8.79 -12.33 MWD (2) 8,7BO.15 9D.77 6.20 6,240.87 6,086.87 95.12 438.70 5,938,445.43 497,871.50 4.40 17.49 MWD (2) 8,810.07 91.88 9.94 6,240.18 6,086.18 124.73 434.50 5,938,475.03 497,875.71 13.04 47.38 MWD (2) 8,834.97 92.70 10.65 6,239.18 6,085.18 149.21 430.06 5,938,499.51 497,880.16 4.35 72.26 MWD (2) 8,865.72 93.93 11.10 6,237.40 6,083.40 179.35 424.27 5,938,529.65 497,885.96 4.26 102.95 MWD (2) 8,896.87 92.73 13.23 6,235.59 6,081.60 209.75 417.71 5,938,56D.04 497,892.52 7.84 134.03 MWD (2) 8,926.59 93.84 14.20 6,233.89 6,079.89 238.57 410.68 5,938,588.86 497,899.56 4.96 163.64 MWD (2) 8,955.22 95.29 15.38 6,231.61 6,077.61 266.17 403.39 5,938,616.45 497,906.85 6.52 192.07 MWD (2) 8,985.27 94.73 13.21 6,228.99 6,074.99 295.17 -396.00 5,938,645.45 497,914.24 7.43 221.92 MWD (2) 9,D10.23 94.46 11.02 6,226.99 6,072.99 319.50 -390.78 5,938,669.77 497,919.47 8.81 246.78 MWD (2) 9,030.65 94.49 9.15 6,225.40 6,071.40 339.54 -387.22 5,938,689.81 497,923.04 9.13 267.14 MWD (2) 9,058.00 94.49 9.15 6,223.25 6,069.25 366.46 -382.88 5,938,716.73 497,927.38 0.00 294.40 PROJECTED to TD 12/5/2016 12:08:33PM Page 5 COMPASS 5000.1 Build 74 THE STATE o1I-I LASK-A GOVERNOR BILL WALKER G. Eller CTD Team Lead ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2K -I IA ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-106 Surface Location: 46' FSL, 94' FEL, Sec. 2, T10N, R8E, UM Bottomhole Location: 691' FSL, 442' FEL, Sec. 2, T10N, R8E, UM Dear Mr. Eller: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for permit to re -drill the above referenced development 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 P Foerster F Chair DATED this 7 day of September, 2016. STATE OF ALASKA AL + OIL AND GAS CONSERVATION COMM )N PERMIT TO DRILL 9n AAr. *?- nm 1 a. Type of Work: 1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ 1 c. Specify if well is proposed for: Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development - Oil Qe Service - Winj ❑ Single Zone 0 ° Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑� L 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 2K -11A 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 9,300' - TVD: 6,225' ` Kuparuk River Field Kuparuk Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 46' FSL, 94' FEL, Sec. 2, T10N, R8E, UM ADL 25588, Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 3804' FSL, 1017 FEL, Sec. 11, T1 ON, R8E, UM ALK 2674 10/1/2016 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 691 FSL, 442 FEL, Sec. 2, T1 ON, R8E, UM 2560 9700' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 154 - 15. Distance to Nearest Well Open Surface: x- 498308 y- 5943537 Zone- 4 • GL Elevation above MSL (ft): 118 to Same Pool: 2K-09, 1025' 16. Deviated wells: Kickoff depth: 6,510 feet • 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 98° degrees Downhole: 4,2ri6 psig 11�9 ( Surface: 4,170 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 2,475' 6,825' 6,298' 9,300' 6,225' 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): 6870' 6,541' None 6,776' 6446' None Casing Length Size Cement Volume MD TVD Conductor/Structural 115 16" 115' 115' Surface 2,997 9-5/8" 900 sx AS 111 & 375 sx Class G 2,997' 2,949' Production 6,877 7" 225 sx Class G 6,877' 6,540' Perforation Depth MD (ft): 6,574'- 6,600' Perforation Depth TVD (ft): 6,247'- 6,273' 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program 0 Time v. Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not Jeff Connelly @ 263-4112 be deviated from without prior written approval. Contact Email Ieff.s.Connelly(C cop.com Printed Name `. G. Eller } Title CTD Team Lead Signature Phone 263-4172 Date Commission Use Only Permit to Drill API Number: Permit Approval 1 See cover letter for other Number: 50 3 —In I 1—Q --00 Date: q requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methan , gas hydrates, or gas contained in shales: Other: 50P f-rs f Ito .lt BUD F",i Samples req'd: YesNom Mud log req'd: Yes ❑ No measures: Yes � No❑ Directional svy req'd: Yes [V No❑ vYt/t r n C �G,� �--t�J d Spacing exception req'd: Yes ❑ Nod Inclination -only svy req'd: Yes ❑ No Post initial injection MIT req'd: Yes ❑ No P APPROVED BY / THE COMMISSION Date: q — 7 "(/ b Approved by: COMMISSIONER VTL W6 /& Submit Form and Form 10-401 (Revised 11/2015)G,RItis va�it� � nths from at�Of�a��Oval (20 AAC 25.005(8)) Attachments in Duplicate ConocoPs philli Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 24, 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 2K-11 using the coiled tubing drilling rig, Nabors CDR2-AC or CDR3-AC. ✓ The work is scheduled to begin October 2016. The objective will be to drill laterals KRU 2K -11A and 2K-11AL1 targeting the Kuparuk A4 -sands. A separate sundry application was submitted to plug the KRU 2K-11 (PTD 189- 093) 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 A -sand perfs in 2K-11. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. Attached to this application are the following documents: — 10-401 Applications for 2K -11A and 2K-11AL1 — Detailed Summary of Operations — Directional Plans for 2K -11A and 2K-11AL1 — Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-263-4112. Sincerely, Jeff Connelly ConocoPhillips Alaska Coiled Tubing Drilling Engineer Kuparuk CTD Laterals NABOBS ALASKA 2K -11A & 2K-11AL1 Application for Permit to Drill Document 2RC 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b))................................................................................................................... 2 2. Location Summary.......................................................................................................................... 2 (Requirements of 20 AAC 25.005(c)(2)).................................................................................................................................................. 2 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005(c)(3))................................................................................................................................................. 2 4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005(c)(4))................................................................................................................................................. 2 5. Procedure for Conducting Formation Integrity tests................................................................... 2 (Requirements of 20 AAC 25.005(c)(5)).................................................................................................................................................. 2 6. Casing and Cementing Program.................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(6)).................................................................................................................................................. 3 7. Diverter System Information.......................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(7)).................................................................................................................................................. 3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(8)).................................................................................................................................................. 3 9. Abnormally Pressured Formation Information............................................................................. 4 (Requirements of 20 AAC 25.005(c)(9)).................................................................................................................................................. 4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10))................................................................................................................................................ 4 11. Seabed Condition Analysis............................................................................................................ 4 (Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................ 4 12. Evidence of Bonding...................................................................................................................... 4 (Requirements of 20 AAC 25.005(c)(12))................................................................................................................................................ 4 13. Proposed Drilling Program.............................................................................................................4 (Requirements of 20 AAC 25.005(c)(13))................................................................................................................................................ 4 Summaryof Operations...................................................................................................................................................4 LinerRunning...................................................................................................................................................................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 2K -11A and 2K -AL1 laterals....................................................................................7 Attachment 2: Current Well Schematic for 2K-11............................................................................................................7 Attachment 3: Proposed Well Schematic for 2K -11A and 2K-11AL1 laterals..................................................................7 Page 1 of 7 August 29, 2016 PTD A►..Aication: 2K -11A & 2K-11AL1 1. Well Name and Classification (Requirements of 20 AAC 25.005(0 and 20 AAC 25.005(b)) The proposed laterals described in this document are 2K -11A & 2K-11AL1. All laterals will be classified as "Development -Oil" wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 2K -11A & 2K-11AL1. 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 or Nabors CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4,700psi. Using the maximum formation pressure in the area of 4,791 psi in 2K-28 (i.e. 14.9 ppg EMW), the maximum potential surface pressure in 2K-11, assuming a gas gradient of 0.1 psi/ft, would be 4,170 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 2K-11 was measured to be 3,063 psi (9.4 ppg EMW) on 8/8/2016. All of the wells in the 2K-11 vicinity are between 9.8 ppg and 14.9 ppg. The A sand SBHP readings suggest pressures will be close to 12.8 ppg. The maximum downhole pressure in the 2K-11 vicinity is the injector 2K -28A at 4,791 psi or 14.9 ppg EMW, which is currently shut-in and expected to come down in pressure. 2K-11 CTD will be drilling towards 9.8 ppg to the north in 2K-09 and 12.8 ppg to the south in 2K-16. It is expected that the pressure range seen while drilling 2K-11 CTD will be in the 9.4 ppg-12.8 ppg range. It is anticipated that the maximum pressure seen while drilling will be that of 2K-16, which is currently shut-in, at 12.8 ppg. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) Offset injection wells have in the past injected gas, thus there is the potential of encountering free gas while drilling the 2K-11 CTD laterals. However, if significant gas is detected in the returns to surface, contaminated mud will 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 potential cause of hole problems in the 2K-11 laterals may be the potential for siltstone instability in the lower A4. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with any fault crossings. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 2K-11 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 August 29, 2016 PTD Al,Nlication: 2K -11A & 2K-11AL1 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Name LinerTop Liner Btm Liner Top Liner Btm Liner Details Btm MD MD MD TVD TVD Conductor 2K -11A 6,825' 9,300' 6,298' 6,225' 2%", 4.7#, L-80, ST -L slotted liner; 36' 115' 1,640 670 Surface aluminum billet on top 2K-11AL1 6,440' 8,900' 6,114' 6,320' 2%", 4.7#, L-80, ST -L slotted liner; 2,949' 3,520 2,020 Production 7" deployment sleeve on top Existing Casing/Liner Information Category OD Weight (ppf) Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 62.5 H-40 Welded 36' 115' 36' 115' 1,640 670 Surface 9-5/8" 36 J-55 BTC 35' 2,997' 35' 2,949' 3,520 2,020 Production 7" 26 J-55 BTC 31' 6,878' 31' 6,549' 4,980 4,320 Tubing 3-1/2" 9.3 J-55 EUE/AB-MOD 31' 6,442' 31 6,116' 4,980 4,320 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR2-AC & CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR2-AC and CDR3-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 12.8 ppg Potassium Formate completion fluid in order to provide formation over -balance and well bore stability while running completions based on current down -hole conditions. Should pressures continue to decrease through pressure management practices prior to start CTD drilling, 11.8 ppg NaBr may be utilized. 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 2K-11 laterals we will target a constant BHP of 12.8 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 August 29, 2016 PTD Application: 2K -11A & 2K-11AL1 Pressure at the 2K-11 Window (6,510' MD, 6,184' TVD) Using MPD 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 2K-1 I was originally drilled and completed in 1989 with 3'/z" tubing and 7" production casing as an A -sand, Kuparuk producer. Prior to CTD operations, the 3-1/2" tubing tail will be perforated and the XN nipple at 6,407' MD will be milled out to a 2.80" ID. The existing A -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 or CDR3-AC will drill a pilot hole to 6,550' MD and set a mechanical whipstock in the 2.80" pilot hole to kick off at 6,510' MD. Two laterals will be drilled: one to the north and one to the south of the parent well with the laterals targeting the Kuparuk A4 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 August 29, 2016 Pumps On 1.5 bpm) Pum s Off A -sand Formation Pressure 9.4 3023 psi 3023 psi Mud Hydrostatic 8.6 2765 psi 2765 psi Annular friction i.e. ECD, 0.080 psi/ft 521 psi 0 psi Mud + ECD Combined no chokepressure) 3286 psi overbalanced —263psi) 2765 psi underbalanced —258psi) Target BHP at Window 12.8 4116 psi 4116 psi Choke Pressure Required to Maintain Target BHP 830 psi 1351 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is 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 2K-1 I was originally drilled and completed in 1989 with 3'/z" tubing and 7" production casing as an A -sand, Kuparuk producer. Prior to CTD operations, the 3-1/2" tubing tail will be perforated and the XN nipple at 6,407' MD will be milled out to a 2.80" ID. The existing A -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 or CDR3-AC will drill a pilot hole to 6,550' MD and set a mechanical whipstock in the 2.80" pilot hole to kick off at 6,510' MD. Two laterals will be drilled: one to the north and one to the south of the parent well with the laterals targeting the Kuparuk A4 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 August 29, 2016 PTD Auulication: 2K -11A & 2K-11AU Pre -CTD Work 1. RU Slickline: Dummy off gas lift mandrels; obtain a SBHP 2. RU E -line: Punch tubing at 6409' MD. 3. RU Pumping: Swap hole over to diesel and perform injectivity test 4. RU Service Coil: Mill out nipple set at 6407' MD, and lay in cement plug and squeeze off the A -sand perforations. 5. RU Slick -line: Tag top of cement and pressure test cement. 6. Prep site for Nabors CDR2-AC or CDR3-AC and set BPV. Rig Work 1. MIRU Nabors CDR2-AC or CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 2K -11A Sidetrack (A4 sand - North) a. Drill 2.80" high -side pilot hole through cement to 6550' MD b. Caliper pilot hole c. Set top of whip -stock at 6510' MD d. Mill 2.80" window at 6510' MD. e. Drill 3" bi-center lateral to TD of 9300' MD. f. Run 2%" slotted liner with an aluminum billet from TD up to 6825' MD. 3. 2K-11AL1 Lateral (A4 sand - South) a. Kick off of the aluminum billet at 6825' MD. b. Drill 3" bi-center lateral to TD of 8900' MD. c. Run 23/" slotted liner with a deployment sleeve from TD up to 6435' MD. 4. Freeze protect, set BPV, ND BOPE, and RDMO Nabors CDR2-AC or CDR3-AC. Post -Rig Work 1. Pull BPV 2. Obtain SBHP 3. Install gas lift design 4. Return to production Page 5 of 7 August 29, 2016 PTD Auulication: 2K -11A & 2K-11AL1 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 2K-11 laterals will be displaced to an overbalancing fluid (12.8ppg Potassium Formate) prior to running liner. See "Drilling Fluids" section for more details. — While running 2%" slotted liner, a joint of 23/" 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 23/" 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 (1 R-18 or 1 B 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 August 29, 2016 PTD Application: 2K -11A & 2K-11AL1 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) Lateral Name Distance 2K -11A 9,700' 2K-11 AL1 7,900' - Distance to Nearest Well within Pool Lateral NameDistance Well 2K -11A 1,025' 2K-09 2K-11AL1 400' 2K-16 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) N/A - Application is for a production well. 17. Attachments Attachment 1: Directional Plans for 2K -11A and 2K -AL1 laterals Attachment 2: Current Well Schematic for 2K-11 Attachment 3. Proposed Well Schematic for 2K -11A and 2K-11AL1 laterals Page 7 of 7 August 29, 2016 GAS LIFT, 6,441.0 6,115.4 7.62 SOS BROWN SHEAR OUT SUB ^. -. Perforations & Slots "-'-- Shoe Top(TVD) Bt.(TVD Dens 2.345 Too MKBI Btm I.KBI (ftKB) (ftKB) Zone Date (sh... Tvpe Comment F End Data Annotation X9/3/2003 NOTE: WAIVERED WELL: IA x OA COMMUNICATION GAS LI Fr, 4,815 GAS UFT, 5.210 GAS LIFT, 5,573 GAS LIFT, 5,941 GAS LI Fr. 6,312 PER, 6,355 PACKER, 6,369 NIPPLE, 6,407 SOS, 6,441 IPERF 5,209.7 5,572.6 5,940.8 TD, ,'TVD, D, th Inc OD Valve Latch Size TRO Run (ftKB) (°) Make Model (in) S¢ry Type Type (in) (psi) Run Date Com... KUP 2K-11 Conoco fillips Well Attributes Max An le & MD ;TD --- FU25k8 InC .... .- _ Wellbore API/UWI Field Name 501032011400 KUPARUK RIVER UNIT _ - - Well Status PROD - Incl (°) 28.36 MD IftKB) 4,300.00 Act Bt (kK8) 6,885.0 _ _ Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date '' SSSV: TRDP 15 10/28/2011 Last WO: 40.09 9/21/1989 Visit Config: -2K-i 1.7/202012102254 AM Schematcnul Annotation Last Tag: RKB Depth (ftKB) Entl Date 6,622.0 9!7/2011 Annotation Rev Reason: GLV C/O Last Mod ninam — ... End Data 7/20/2012 - Casinq_Strin s — - -- -- -- HANGER, 31 ( Casing Description String 0... String ID ... 16 15.062 Tap (ftKB) 36.0 Set Depth (f... 115.0 Set Depth (TVD) ... 115.0 String Wt... String... 62.50 H-40 String Top ThirdCONDUCTOR WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Third SURFACE 9 518 8.921 35.0 2,997.4 2,949.0 36.00 J-55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (C.. Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 31.2 6,877.6 26.00 J-55 BTC _ TubingStrings _ CONDUCTOR, 36-115 Tubing Description String 0... String ID ... TUBING 31/2 2.992 Top (ftKB) 31.1_ Set Depth (1... Set Depth (TVD) ... 6,116.2 String Wt... String... 9.30 J-55 String Top Thrd EUE8TdABMOD Completion DetaEls _6,441.8 Top Depth (TVD) Top In Nomi... Top (ftKB) (ftKB) (°) Item Description Comment ID (in) 31.1 31.1 0.38 HANGER IFMC GEN IV TUBING HANGER 1 3500 SAFETY VLV. GAS LIFT, 6,441.0 6,115.4 7.62 SOS BROWN SHEAR OUT SUB ^. -. Perforations & Slots "-'-- Shoe Top(TVD) Bt.(TVD Dens 2.345 Too MKBI Btm I.KBI (ftKB) (ftKB) Zone Date (sh... Tvpe Comment F End Data Annotation X9/3/2003 NOTE: WAIVERED WELL: IA x OA COMMUNICATION GAS LI Fr, 4,815 GAS UFT, 5.210 GAS LIFT, 5,573 GAS LIFT, 5,941 GAS LI Fr. 6,312 PER, 6,355 PACKER, 6,369 NIPPLE, 6,407 SOS, 6,441 IPERF 5,209.7 5,572.6 5,940.8 TD, ,'TVD, D, th Inc OD Valve Latch Size TRO Run (ftKB) (°) Make Model (in) S¢ry Type Type (in) (psi) Run Date Com... 2K-11 Proposed CTD Schematic 16" 62# H-40 shoe @ 115' 10-3/4" by 9-5/8" 36# L-80 shoe @ 2997' MD IKOP @ —6510' MD A -sand perfs 6574' - 6600' MD Lat #2 -South 2K-11AL1 wp04 TD @ 8900' MD Liner Top @ 6440' MD 7" 26# J-55 shoe @ 6878' MD Modified by JJO 5/25/16 � 3-1/2" 9.3# J-55 EUE 8rd Tubing to surface 3-1/2" Carrico TRDP SSSV @ 1815' RKB (locked out???) 3-1/2" Merla TMPD gas lift mandrels @ 2345', 3932', 4815', 5210', 5573' RKB 3-1/2" Carrico MMG GLV @ 5941' RKB 3-1/2" Camco MMG OV GLV @ 6312' RKB Baker 3-1/2" PBR @ 6355' RKB (3" ID) Baker HB packer @ 6369' RKB (2.892" ID) 3-1/2" Otis XN nipple @ 6407' RKB (2.75" min ID) Note: Milled out to 2.80" ID for CTD 3-1/2" tubing tail @ 6442' RKB Lat #1 - North 2K -11A wp06 TD @ 9300' MD Liner Billet @ 6825' MD ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad 2K-11 2K -11A Plan: 2K -11A wp06 Standard Planning Report 02 August, 2016 FfAA & I BAKER HUGHES ConocoPhillips Kuparuk 2K Pad ConocoPhillips Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2K Pad Well: 2K-11 Wellbore: 2K -11A Design: 2K-11A_wp06 ConocoPhillips Kuparuk 2K Pad Planning Report Site Position: Local Co-ordinate Reference: Well 2K-11 TVD Reference: Mean Sea Level MD Reference: 2K-11 @ 154.00usft (2K-11) North Reference: True Survey Calculation Method: Minimum Curvature 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 2K Pad Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 usft Slot Radius: Well i 2K-11 Well Position +N/ -S 0.00 usft Northing: +E/ -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore 2K -11A Magnetics Model Name Sample Date BGGM2016 11/1/2016 Design 2K-11A_wp06 Audit Notes: Version: Phase: Vertical Section: Depth From (TVD) (usft) 0.00 r/Rt BAKER HUGHES 5,938,600.18 usft Latitude: 700 14' 36.519 N 498,310.17 usft Longitude: 1500 0'49.133 W 0.000in Grid Convergence: -0.01 ° 5,938,350.22 usft Latitude: 70° 14' 34.061 N 498,310.14 usft Longitude: 150° 0'49.133 W usft Ground Level: 0.00 usft Declination (°) 17.80 PLAN +N/ -S (usft) 0.00 Dip Angle Field Strength (°) (nT) 80.87 57,536 Tie On Depth: +E/ -W (usft) 0.00 6,500.00 Direction (°) 10.00 8/2/2096 3:00:49PM Page 2 COMPASS 5000.9 Build 74 i ConocoPhillips HAN ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 2K-11 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-11 @ 154.00usft (2K-11) Site: Kuparuk 2K Pad North Reference: True Well: 2K-11 Survey Calculation Method: Minimum Curvature Wellbore: 2K -11A (°) (usft) Design: 2K-11A_wp06 (°/100ft) (°/100ft) 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) (°1100ft) (°) Target 6,500.00 7.82 202.20 6,019.86 -1,287.02 -882.30 0.00 0.00 0.00 0.00 6,510.00 7.81 202.06 6,029.77 -1,288.28 -882.81 0.22 -0.10 -1.40 -117.78 6,531.00 12.01 202.06 6,050.45 -1,291.63 -884.16 20.00 20.00 0.00 0.00 6,704.31 90.00 202.06 6,151.28 -1,407.05 -930.94 45.00 45.00 0.00 0.00 6,975.00 96.79 80.00 6,124.22 -1,579.65 -793.13 45.00 2.51 -45.09 -82.00 7,075.00 94.80 34.80 6,113.57 -1,527.39 -711.56 45.00 -2.00 -45.20 -90.00 7,400.00 94.42 11.97 6,087.10 -1,232.04 -583.86 7.00 -0.12 -7.02 -90.00 7,625.00 90.24 356.77 6,077.90 -1,008.58 -566.81 7.00 -1.86 -6.76 -105.00 7,925.00 90.22 17.77 6,076.67 -712.66 -529.04 7.00 -0.01 7.00 90.00 8,200.00 95.11 359.13 6,063.77 -442.24 -488.77 7.00 1.78 -6.78 -75.00 8,270.00 95.09 4.05 6,057.55 -372.57 -486.84 7.00 -0.03 7.03 90.00 8,390.00 89.67 10.47 6,052.57 -253.74 -471.68 7.00 -4.52 5.35 130.00 8,560.00 84.67 359.65 6,060.98 -84.92 -456.69 7.00 -2.94 -6.36 -115.00 8,810.00 89.37 16.54 6,074.06 161.28 -421.58 7.00 1.88 6.75 75.00 9,010.00 90.60 2.59 6,074.12 358.01 -388.42 7.00 0.61 -6.97 -85.00 9,160.00 90.59 13.10 6,072.57 506.39 -367.98 7.00 -0.01 7.00 90.00 9,300.00 90.58 3.29 6,071.15 644.78 -348.05 7.00 -0.01 -7.00 -90.00 8/2/2016 3:00,49PM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips r��■ ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 2K-11 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-11 @ 154.00usft (2K-11) Site: Kuparuk 2K Pad North Reference: True Well: 2K-11 Survey Calculation Method: Minimum Curvature Wellbore: 2K -11A Design: 2K-11 A_wp06 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/ -S +E/ -W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100ft) (°) (usft) (usft) 6,500.00 7.82 202.20 6,019.86 -1,287.02 -882.30 -1,420.68 0.00 0.00 5,937,063.52 497,427.64 TIP 6,510.00 7.81 202.06 6,029.77 -1,288.28 -882.81 -1,422.01 0.22 -117.78 5,937,062.26 497,427.13 KOP 6,531.00 12.01 202.06 6,050.45 -1,291.63 -884.16 -1,425.54 20.00 0.00 5,937,058.92 497,425.77 End 20 dls, Start 45 dis 6,600.00 43.06 202.06 6,110.89 -1,320.84 -896.00 -1,456.36 45.00 0.00 5,937,029.72 497,413.94 6,700.00 88.06 202.06 6,151.21 -1,403.06 -929.32 -1,543.12 45.00 0.00 5,936,947.51 497,380.60 6,704.31 90.00 202.06 6,151.28 -1,407.05 -930.94 -1,547.33 45.00 0.00 5,936,943.52 497,378.98 4 6,800.00 95.45 159.28 6,146.51 -1,500.38 -932.11 -1,639.44 45.00 -82.00 5,936,850.20 497,377.79 6,900.00 98.00 • 114.02 6,134.16 -1,570.74 -665.83 -1,697.23 45.00 -84.14 5,936,779.83 497,444.04 6,975.00 96.79 80.00 6,124.22 -1,579.65 -793.13 -1,693.37 45.00 -89.73 5,936,770.91 497,516.74 5 7,000.00 96.66 68.67 6,121.28 -1,572.95 -769.26 -1,682.64 45.00 -90.00 5,936,777.60 497,540.60 7,075.00 94.80 34.80 6,113.57 -1,527.39 -711.56 -1,627.75 45.00 -91.33 5,936,823.14 497,598.31 End 45 dis, Start 7 dis 7,100.00 94.79 33.04 6,111.48 -1,506.72 -697.66 -1,604.98 7.00 -90.00 5,936,843.81 497,612.21 7,200.00 94.74 26.02 6,103.16 -1,420.07 -648.58 -1,511.12 7.00 -90.15 5,936,930.44 497,661.31 7,300.00 94.62 18.99 6,094.99 -1,328.05 -610.45 -1,413.88 7.00 -90.73 5,937,022.44 497,699.45 7,400.00 94.42 11.97 6,087.10 -1,232.04 -583.86 -1,314.71 7.00 -91.30 5,937,118.44 497,726.06 7 7,500.00 92.58 5.21 6,080.98 -1,133.41 -568.96 -1,214.99 7.00 -105.00 5,937,217.06 497,740.98 7,600.00 90.71 358.46 6,078.10 -1,033.56 -565.77 -1,116.10 7.00 -105.41 5,937,316.89 497,744.20 7,625.00 90.24 356.77 6,077.90 -1,008.58 -566.81 -1,091.69 7.00 -105.61 5,937,341.87 497,743.16 8 7,700.00 90.24 2.02 6,077.58 -933.62 -567.60 -1,017.99 7.00 90.00 5,937,416.83 497,742.39 7,800.00 90.23 9.02 6,077.17 -834.14 -557.98 -918.36 7.00 90.02 5,937,516.29 497,752.03 7,900.00 90.23 16.02 6,076.77 -736.58 -536.30 -818.52 7.00 90.05 5,937,613.83 497,773.73 7,925.00 90.22 17.77 6,076.67 -712.66 -529.04 -793.70 7.00 90.08 5,937,637.75 497,781.00 9 8,000.00 91.58 12.70 6,075.49 -640.34 -509.33 -719.05 7.00 -75.00 5,937,710.06 497,800.71 8,100.00 93.37 5.93 6,071.17 -541.81 -493.17 -619.21 7.00 -75.08 5,937,808.58 497,816.90 8,200.00 95.11 359.13 6,063.77 -442.24 -488.77 -520.40 7.00 -75.37 5,937,908.13 497,821.32 10 8,270.00 95.09 4.05 6,057.55 -372.57 -486.84 -451.44 7.00 90.00 5,937,977.80 497,823.27 11 8,300.00 93.74 5.66 6,055.24 -342.76 -484.31 -421.66 7.00 130.00 5,938,007.60 497,825.81 6,390.00 89.67 10.47 6,052.57 -253.74 -471.68 -331.79 7.00 130.12 5,938,096.61 497,838.45 12 8,400.00 89.37 9.84 6,052.65 -243.90 -469.92 -321.79 7.00 -115.00 5,938,106.45 497,840.21 8,500.00 86.42 3.48 6,056.32 -144.70 -458.33 -222.09 7.00 -114.99 5,938,205.64 497,851.82 8,560.00 84.67 359.65 6,060.98 -84.92 -456.69 -162.93 7.00 -114.76 5,938,265.41 497,853.48 13 8,600.00 85.40 2.37 6,064.44 -45.08 -455.99 -123.58 7.00 75.00 5,938,305.25 497,854.19 8,700.00 87.27 9.13 6,070.83 54.15 -445.99 -24.12 7.00 74.77 5,938,404.47 497,864.20 8,800.00 89.18 15.87 6,073.93 151.67 -424.37 75.68 7.00 74.33 5,938,501.97 497,885.84 8,810.00 89.37 16.54 6,074.06 161.28 -421.58 85.62 7.00 74.12 5,938,511.58 497,888.64 14 8,900.00 89.92 10.27 6,074.62 248.78 -400.73 175.41 7.00 -85.00 5,938,599.06 497,909.50 9,000.00 90.53 3.29 6,074.22 348.02 -388.94 275.19 7.00 -84.96 5,938,698.29 497,921.32 9,010.00 90.60 2.59 6,074.12 358.01 -388.42 285.12 7.00 -84.99 5,938,708.28 497,921.84 81212016 3:00:49PM Page 4 COMPASS 5000.1 Build 74 �.- ConocoPhillips F&A.' ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit +N/ -S Site: Kuparuk 2K Pad Rate Well: 2K-11 Easting Wellbore: 2K -11A (usft) Design: 2K-11A_wp06 (usft) [13Planned Survey 447.50 -379.42 374.82 7.00 Measured 5,938,797.76 TVD Below Depth Inclination Azimuth System (usft)(°) (°) (usft) 15 545.55 -359.87 9,100.00 90.59 8.89 6,073.19 9,160.00 90.59 13.10 6,072.57 16 574.55 7.00 9,200.00 90.58 10.30 6,072.16 9,300.00 90.58 3.29 6,071.15 Planned TD at 9300.00 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 2K-11 Mean Sea Level 2K-11 @ 154.00usft (2K-11) True Minimum Curvature 8/2/2016 3:00:49PM Page 5 COMPASS 5000.1 Build 74 Vertical Dogleg Toolface Map Map +N/ -S +E/ -W Section Rate Azimuth Northing Easting (usft) (usft) (usft) (°/100ft) (°) (usft) (usft) 447.50 -379.42 374.82 7.00 90.00 5,938,797.76 497,930.86 506.39 -367.98 434.79 7.00 90.07 5,938,856.64 497,942.31 545.55 -359.87 474.77 7.00 -90.00 5,938,895.79 497,950.43 644.78 -348.05 574.55 7.00 -90.03 5,938,995.01 497,962.27 8/2/2016 3:00:49PM Page 5 COMPASS 5000.1 Build 74 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad 2K-11 2K -11A 2K-11 A_wp06 Travelling Cylinder Report 02 August, 2016 we P P �_- 'A Fag BAKER HUGHES ✓ ConocoPhillips .eA.. ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 2K Pad Site Error: 0 00 usft Reference Well: 2K-11 Well Error: 0.00 usft Reference Wellbore 2K -11A Reference Design: 2K-11A_wp06 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 2K-11 2K-11 @ 154 00usft (2K-11) 2K-11 @ 154 00usft (2K-11) True Minimum Curvature 1.00 sigma EDM Alaska ANC Prod Offset Datum Reference 2K-11A_wp06 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 6,500.00 to 9,300.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,114.60 usft Error Surface: Elliptical Conic Survey Tool Program Date 8/2/2016 From To (usft) (usft) Survey (Wellbore) Tool Name Description 200.00 6,500.00 2K-11 (2K-11) BOSS -GYRO Sperry -Sun BOSS gyro multishot 6,500.00 9,300.00 2K-11A_wp06(2K-11A) MWD MWD -Standard Casing Points Measured Vertical Depth Depth (usft) (usft) 9,300.00— 6,225.15 2 3/8" Reference — Casing Hole Diameter Diameter Name () 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 2K Pad 2K-02 - 2K-02 - 2K-02 Out of range 2K-03 - 2K-03 - 2K-03 Out of range 2K-04 - 2K-04 - 2K-04 Out of range 2K-05 - 2K-05 - 2K-05 Out of range 2K-06 - 2K-06 - 2K-06 Out of range 2K-07 - 2K-07 - 2K-07 Out of range 2K-08 - 2K-08 - 2K-08 Out of range 2K-08 - 2K -08A - 2K -08A Out of range 2K-08 - 2K-08APB1 - 2K-08APB1 Out of range 2K-08 - 2K-08APB2 - 2K-08AP82 Out of range 2K-08 - 2K-08APB3 - 2K-08APB3 Out of range 2K-08 - 2K-08BPB1 - 2K-08BPB1 Out of range 2K-08 - 2K-08BPB2 - 2K-08BPB2 Out of range 2K-08 - 2K-08BPB3 - 2K-08BPB3 Out of range 2K-09 - 2K-09 - 2K-09 Out of range 2K-09 - 2K -09L1 - 2K -09L1 Out of range 2K -09 -2K -09L1-01 -2K-091-1-01 Out of range 2K-10 - 2K-10 - 2K-10 Out of range 2K-11 - 2K-11 - 2K-11 6,524.99 6,525.00 0.40 1.02 -0.62 FAIL - Major Risk 2K-11-2K-11AL1-2K-11AL1_wp04 6,849.64 6,850.00 2.67 0.64 2.25 Pass - Minor 1/10 2K-12 - 2K-12 - 2K-12 Out of range 2K-13 - 2K-13 - 2K-13 Out of range 2K-13 - 2K -13A - 2K -13A Out of range 2K-13 - 2K-13AL1 - 2K-13AL1 Out of range 2K-13 - 2K-13AL2 - 2K-13AL2 Out of range 2K-14 - 2K-14 - 2K-14 Out of range 2K-14 - 2K -14A - 2K -14A Out of range 2K-14 - 2K-14AL1 - 2K-14AL1 Out of range 2K-15 - 2K-15 - 2K-15 Out of range CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 8/212016 11.20.46AM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips FeC.. ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 2K Pad Site Error: 0.00 usft Reference Well: 2K-11 Well Error: 0.00 usft Reference Wellbore 2K -11A Reference Design: 2K-11A_wp06 Summary Site Name Offset Well - Wellbore - Design Kuparuk 2K Pad 2K-15 - 2K-151-1 - 2K-151-1 2K-15 - 2K-151-1-01 - 2K-151-1-01 2K-15 - 2K-151-1-02 - 2K-151-1-02 2K-16 - 2K-16 - 2K-16 2K-17 - 2K-17 - 2K-17 2K-18 - 2K-18 - 2K-18 2K-19 - 2K-19 - 2K-19 2K-19 - 2K -19A - 2K -19A 2K-19 - 2K-19AL1 - 2K-19AL1 2K-26 - 2K-26 - 2K-26 2K-28 - 2K-28 - 2K-28 2K-28 - 2K -28A - 2K -28A 2K-28 - 2K-28AL1 - 2K-28AL1 2K-28 - 2K-28AL1 PB1 - 2K-28AL1 PB1 2K-28 - 2K-28AL1 PB2 - 2K-28AL1 P82 2K-28 - 2K-28APB1 - 2K-28APB1 2K-29 - 2K-29 - 2K-29 2K-34 - 2K-34 - 2K-34 2K-34 - 2K -34L1 - 2K-341_1 2K-34 - 2K-34PB1 - 2K-34PB1 Plan: 2K-30 - Plan: 2K-30 - 2K-30wp05 Plan: 2K-31 - Plan: 2K-31 - 2K-31wp05 Plan: 2K-32 - Plan: 2K-32 - 2K-32wp06 Plan: 2K -Timberline - Plan 2K-TimberlinePB1 - 2K Plan: 2K -Timberline - Plan: 2K -Timberline - 2K -Tim Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 2K-11 2K-11 @ 154.00usft (2K-11) 2K-11 @ 154.00usft (2K-11) True Minimum Curvature 1.00 sigma EDM Alaska ANC Prod Offset Datum Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Depth Depth Distance (usft) from Plan (usft) (usft) (usft) (usft) Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Offset Design Kuparuk 2K Pad - 2K-11 - 2K-11 - 2K-11 offset Site Error: 0 00 usft Survey Program: 200 -BOSS -GYRO Rule Assigned: Major Risk 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) (usft) (usft) (usft) (°) (usft) (usft) (") (usft) (usft) (usft) 6,524.99 6,198.56 6,525.00 6,198.63 0.01 0.06 22.58 -1,290.17 -883.57 2-11/16 0.40 1.02 -0.62 FAIL- Major Risk, CC, ES, SF 6,549.46 6,222.17 6,550.00 6,223.40 0.01 0.12 22.48 -1,293.31 -884.82 2-11/16 3.56 2.35 1.20 Pass - Major Risk 6,572.01 6,242.51 6,575.00 6,248.17 0.02 0.19 22.41 -1,296.44 -886.04 2-11/16 11.17 3.67 7.50 Pass - Major Risk 6,591.66 6,258.61 6,600.00 6,272.95 0.02 0.25 22.39 -1,299.57 -887.24 2-11/16 22.63 4.75 17.87 Pass - Major Risk 6,608.18 6,270.68 6,625.00 6,297.73 0.03 0.31 22.39 -1,302.67 -888.40 2-11/16 37.14 5.60 31.54 Pass - Major Risk 6,621.80 6,279.47 6,650.00 6,322.51 0.03 0.37 22.41 -1,305.74 -889.53 2-11/16 54.00 6.25 47.74 Pass - Major Risk 6,632.97 6,285.81 6,675.00 6,347.31 0.04 0.43 22.42 -1,308.76 -890.61 2-11/16 72.60 6.76 65.84 Pass - Major Risk 6,642.16 6,290.41 6,700.00 6,372.11 0.04 0.49 22.44 -1,311.74 -891.65 2-11/16 92.50 7.15 85.35 Pass - Major Risk 6,650.00 6,293.87 6,725.00 6,396.91 0.05 0.55 22.45 -1,314.69 -892.67 2-11/16 113.37 7.46 105.91 Pass - Major Risk 6,656.15 6,296.28 6,750.00 6,421.72 0.05 0.61 22.45 -1,317.63 -893.70 2-11/16 134.98 7.70 127.28 Pass - Major Risk 6,660.00 6,297.65 6,775.00 6,446.52 0.05 0.67 22.45 -1,320.55 -894.73 2-11/16 157.16 7.87 149.29 Pass - Major Risk 6,666.14 6,299.60 6,800.00 6,471.33 0.06 0.74 22.45 -1,323.47 -895.76 2-11/16 179.75 8.08 171.67 Pass - Major Risk 6,670.00 6,300.69 6,825.00 6,496.14 0.06 0.80 22.44 -1,326.40 -896.79 2-11/16 202.69 8.23 194.47 Pass - Major Risk 6,673.56 6,301.59 6,850.00 6,520.95 0.07 0.86 22.44 -1,329.32 -897.82 2-11/16 225.92 8.36 217.56 Pass - Major Risk 6,676.01 6,302.15 6,870.00 6,540.79 0.07 0.90 22.44 -1,331.66 -898.64 2-11/16 244.67 8.45 236.22 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 8/2/2016 11.20.46AM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips 660 600 540 480 320 360 300 240 ISO 120 C Co G=. O O -60 -120 p-180 _-240 ..0 -300 0601 _420 -4801 401 6001 -6601 -7201 -7801 -840(( -900( 2K-11 -960( ire �■ BAKER HUGHES — �\ 51 1I Project: Kuparuk River Unit AzimumsmTrue Norm Magnetic N1hh::7,80° WELLBORE DETAILS: 2K -11A \ REFERENCE INFORMATION Site: Kuparuk 2K Pad auzc o1 .o i 2f)ut Well: 2K-11 14 �N�q Magnetic Field Parent Wellbore: 2K-11 �© Co-ordinate (N/E) Reference: Well2K-11, True North Wellbore: 2K -11A b` 65f 2K -2/^K 2yj1— Strength. 6/63513-T Dip Angle: 80.87° Tie on MD: 6500.00 K-05 Vertical (TVD) Reference: 2K-11 @ 154.00usft (2K-11) Plan: 2K -11A w O6 2K -11/2K -11A P ( Kd11/. AI 247 Dale: 11/1/2016 16 o Section (VS) Reference: Slot -(O.00N, 0.00E) Measured Depth Reference. 2K-11 @ 154.00usft (2K-11) - M�del BGGM2016 { Calculation Method: Minimum Curvature ire �■ BAKER HUGHES — �\ 51 1I 0 11,U1P 1:01 \ °` z tr II-gB 11 DK auzc o1 .o i 2f)ut i�cD_/..G 14 �N�q ISI 2K 07/2K4>ji ) � �x-� (A �© - b` 65f 2K -2/^K 2yj1— 6 C3.0�2K-OS/ K-05 Kd11/. AI 247 { 12c 16 o [i -I/'(7 GO J r ) { K -09f' 091.1 _— 4(10. -0RA11° 2K G88A/'K)I'HK^'A%ZoPK�= _6869/2K/2K. EI - 8/2K:II.h � 4C 1 7/2f -2I2 2.'. K.. 00 0 !. C , (,-1_.>_ 211Ld2LiL 2K4,8111'112 ... 2K -3472K 141 I '41 /2K. )81 PB3 2K-34/ rk34Z_TnK-I.-. 0 M _ 1000 (..., - - 2Y,15/2K- I 'cL-I �.0 -1 6y<0J00 • c r 1 I ;'� o �• ^n s E 1412 20-11/20-14, ;-14AL 6 (}-132 G i 13AI. o- I ^ M2K-13 - 17rK-27 4K-13/-IiAl,l 2K-1 2K-13 1.' 2 dK�k 90 1 I7 K o e2 2K -IS/2I o � b K Z6 K -w i aK a000 o eta° 21!^7-2N W uA -p1 W AK 1'2C1-11/ 0-I9h i. -214/2K-`4A 2K-19/2K-IDA .. 2K-19/ K IIAI . H - -, ^K-1 t/ - �paK-IIAI 1 - 0 j i ^RJ K2ftAT7 � - . 2Y-1, 'N/2K-#8Al.I 7. l K-16 P) - 0 4 1 2K-IR/ $ 1., - �K 18 r.:. (+X - -1�7 _ K-17CI lafh-H ,b 2K7/2x-1 ; y 2K-23/ :-23 i]{ K 0 2K -21d 51 00 2 C-22/21( 22A d -50p0 1_ {_-.. 6 2K-2& K-2RALi mop -2112K 212"-2512K 65 25 _ 2K-?'172K-21�6100 1 . ' s 6000 - 2K -]2/2x-2 2K -2 /2K-24 50 - I ^K- 472K-2 1.2{7I ^-2d/2K 2K , 2"/2K- 21A ...134 3AI1 6360 _. 1 54 Ol1Sff �.. � � Q Ji2K 11 j 6169 �2K-24/221I ':. 2V. 2>nK Til 2K 22/PK-2 2AL1 rya C-24AL2 61 K-25/21,-2>Lt -l'000-11,100-10900-WOO-porno _9n0n _Kann _Tann _7>nr) SFnn rnnn conn noon -- •-�� _,cam ���� ,ow v<uv vauv wuu uuuu 0000 /2Uu -/800 8400 9000 9600 10200 West( -)/East(+) (600 usft/in) ConocoPhillips flits BAKER HUGHES K D ,TNt 2 -K10. _IK ` K1 1.nl n 3 -SFkBn132 J/ l KOKIr�1 :K-0 /2zx oszK osn�D09 000 _ - — - T Bao-• ,1I _ + 21 u>/ Kt�r I a {�- — -- -- --`--I --- _ _ klF/2h-117111 ,b 1 ' 21..I18'F2KSA -... i -d � i 600 - 2K -4/2R ORBIB1 ! ' 2K-0R/2K-(�NRpF12� 2Kat8/2K1813P133 - - I 2K -01/21i-071 n � _ x-14AL1 h I , K-34 K-341,1 li $ ., 14/ K 11111, -. 1 2K -28/2K-2' A�- -2001 -400 I -boo - -- I W-I000-� - _ _ i�_ :: 2K 2812K-28APR1� 5 1200 N I ZK 33/2K f Al _- - o -- ;OITN -. --- _. - 2IG IS/ 7 r71 n, - 2K-15Y2K-151,14fy K 1sr2K-13nt1 ,rte 6s -=2 -IV K�i1.. b. l 2K-IStr_K.75 + 2K -27/2K 7 I o s O 3K -12K -14/2K-141800 o - -- -- - ',i - fi- - L I 490 - n I -2200-�00 I jopT—. j o 00 -2400—+ ::-I' -2600 t I �- -lsoo .> .. , 2K-11i2K 191: - -3000 - 2k 9)2K -19a - -- - hK 19nL.1. 2K IMIC-1 ._ 32001 zK-II 1 - 12K-14/ K-1417 1 6283 I - -34007 �_. rt--•—� _ - ._ _ _ I r — O` - 2K-1 f2K7LI -3600 0001 28ALI'62 2K -282K- 3800 ' - 2K -2812K-2 L113I 1 l >Opp -4000 III _ 2' s2K tt/4K-IG 2 E zo/_x�2D � — r- � 2K -21/2K -T K-21 ' - _ 2K-'k7L'��.t9.Tft -'(.2 4 _ _ -- __ In ..'2K 28/,K 2RR1 I _ _.._ 2K 2 %KS7).gl}-0I_ _. 2K 22/ K 22A -4600 -4400 -4200 -4000 -3800 - 600 -3400 -3200 -3000 -2800 -2600 -2400 -2200 2000 -1800 -1600 -1400 -1200 - _ - 1000 -800 -600 -400 200 0 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 West( -)/East(+) (200 usft/in) Project: Kuparuk River Unit Site: Kuparuk 2K Pad AMi hsm Tme Norm Ma9nelm Nnnh 17.80° WELLBORE DETAILS: 2K -11A REFERENCE INFORMATION Well: 2K-11 Magnetic Field Parent Wellbore: 2K-11 Co-ordinate (N/E) Reference. Well 2K-11, True North Wellbore: 2K -11A Strenpill, 57535.8snT Dip Angle: 80.87° Tie on MD: 6500.00 Verbcal (TVD) Reference: 2K-11 @ 154.o0usfl (2K-11) Plan: 2K-11A_wp06 (21<41/21<41A) Date: 1111J201e Section (VS) Reference: Slot -(O.00N, O,OOE) Measured De th Reference 2K-11@154.00ucf(2K-11) ModelBGGM2016 Calculation Method. Minimum Curvature flits BAKER HUGHES K D ,TNt 2 -K10. _IK ` K1 1.nl n 3 -SFkBn132 J/ l KOKIr�1 :K-0 /2zx oszK osn�D09 000 _ - — - T Bao-• ,1I _ + 21 u>/ Kt�r I a {�- — -- -- --`--I --- _ _ klF/2h-117111 ,b 1 ' 21..I18'F2KSA -... i -d � i 600 - 2K -4/2R ORBIB1 ! ' 2K-0R/2K-(�NRpF12� 2Kat8/2K1813P133 - - I 2K -01/21i-071 n � _ x-14AL1 h I , K-34 K-341,1 li $ ., 14/ K 11111, -. 1 2K -28/2K-2' A�- -2001 -400 I -boo - -- I W-I000-� - _ _ i�_ :: 2K 2812K-28APR1� 5 1200 N I ZK 33/2K f Al _- - o -- ;OITN -. --- _. - 2IG IS/ 7 r71 n, - 2K-15Y2K-151,14fy K 1sr2K-13nt1 ,rte 6s -=2 -IV K�i1.. b. l 2K-IStr_K.75 + 2K -27/2K 7 I o s O 3K -12K -14/2K-141800 o - -- -- - ',i - fi- - L I 490 - n I -2200-�00 I jopT—. j o 00 -2400—+ ::-I' -2600 t I �- -lsoo .> .. , 2K-11i2K 191: - -3000 - 2k 9)2K -19a - -- - hK 19nL.1. 2K IMIC-1 ._ 32001 zK-II 1 - 12K-14/ K-1417 1 6283 I - -34007 �_. rt--•—� _ - ._ _ _ I r — O` - 2K-1 f2K7LI -3600 0001 28ALI'62 2K -282K- 3800 ' - 2K -2812K-2 L113I 1 l >Opp -4000 III _ 2' s2K tt/4K-IG 2 E zo/_x�2D � — r- � 2K -21/2K -T K-21 ' - _ 2K-'k7L'��.t9.Tft -'(.2 4 _ _ -- __ In ..'2K 28/,K 2RR1 I _ _.._ 2K 2 %KS7).gl}-0I_ _. 2K 22/ K 22A -4600 -4400 -4200 -4000 -3800 - 600 -3400 -3200 -3000 -2800 -2600 -2400 -2200 2000 -1800 -1600 -1400 -1200 - _ - 1000 -800 -600 -400 200 0 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 West( -)/East(+) (200 usft/in) ConocoPhillips Project: Kuparuk River Unit Site: Kuparuk 2K Pad Well: 2K-11 n uroths to True North Magnetic North: 17.80' Magnetic Field WELLBORE DETAILS: 2K -11A REFERENCE INFORMATION _ .�.. Parent Wellbore: 2K-11 Co-ordinate (NrE) Reference: Well 2K-11, True North Wellbore: 2K -11A Strength: 57535.8anT Dip Angle: 60.87' Tie on MD: 6500.00 Vertinl (ND) Reference: Mean Seg Level Sect- Reference: MeanSlot - Sea Level BAKER Plan: 2K-11A_wpOf, (2K -11/2K -11A) Model BGG 2018 Longitude Measured Depth Reference: 2K-11 @ 154.00usf1(2K-11) 0.00 5938350.22 498310.14 70° 14' 34.061 N 150° 0'49.133 W Calculation Method: Minimum Curvature HUGHES Mean 125( 100( 75( 50( 25( +, a5( too( Z-125(Z-125( 0 V) -150C -175C -200( -225C WELL DETAILS: 2K-11 +N/ -S +E/ -W Northing Easting Latitude Longitude 0.00 0.00 5938350.22 498310.14 70° 14' 34.061 N 150° 0'49.133 W Sec MD Inc Azi TVDSS +N/ -S +E/ -W Dleg TFace VSect Annotation 1 6500.00 7.82 202.20 6019.86 -1287.02 -882.30 0.00 0.00-1420.68 TIP 2 6510.00 7.81 202.06 6029.77 -1288.28 -882.81 0.22 -117.78-1422.01 KOP 3 6531.00 12.01 202.06 6050.45 -1291.63 -884.16 20.00 0.00 -1425.54 End 20 d1s, Start 45 dls 4 6704.31 90.00 202.06 6151.28 -1407.05 -930.94 45.00 0.00 -1547.33 4 5 6975.00 96.79 80.00 6124.22 -1579.65 -793.13 45.00 -82.00 -1693.37 5 6 7075.00 94.80 34.80 6113.57 -1527.39 -711.56 45.00 -90.00 -1627.75 End 45 d1s, Start 7 dls 7 7400.00 94.42 11.97 6087.10 -1232.04 -583.86 7.00 -90.00-1314.71 7 8 7625.00 90.24 356.77 6077.90 -1008.58 -566.81 7.00 -105.00 -1091.69 8 9 7925.00 90.22 17.77 6076.67 -712.66 -529.04 7.00 90.00 -793.70 9 10 8200.00 95.11 359.13 6063.77 -442.24 -488.77 7.00 -75.00 -520.40 10 11 8270.00 95.09 4.05 6057.55 -372.57 -486.84 7.00 90.00 -451.44 11 12 8390.00 89.67 10.47 6052.57 -253.74 -471.68 7.00 130.00 -331.79 12 13 8560.00 84.67 359.65 6060.98 -84.92 -456.69 7.00 -115.00 -162.93 13 14 8810.00 89.37 16.54 6074.06 161.28 -421.58 7.00 75.00 85.62 14 15 9010.00 90.60 2.59 6074.12 358.01 -388.42 7.00 -85.00 285.12 15 16 9160.00 90.59 13.10 6072.57 506.39 -367.98 7.00 90.00 434.79 16 17 9300.00 90.58 3.29 6071.15 644.78 -348.05 7.00 -90.00 574.55 Planned TD at 9300.00 Mean 125( 100( 75( 50( 25( +, a5( too( Z-125(Z-125( 0 V) -150C -175C -200( -225C - -111 -r - - 'w -t -w -nU -5UU -25U 0 250 500 750 1000 1250 1500 1750 Vertical Section at 10.00° (70 usft/in) 2X -IIA 06----- -----Plat - ned T at 930).00 - -"-2C-11/2 .11A 15 2K• I IAT 5------- 14 13 o K-11 T03- -- --- 2 -11A 02 Kfl 2K-1 12K-11 E ad 20 Is, Star 45 dls - End 4 dls, S art 7 d 2K -IIA Ol 2K - 16 12 K- 16 AL1 - -111 -r - - 'w -t -w -nU -5UU -25U 0 250 500 750 1000 1250 1500 1750 Vertical Section at 10.00° (70 usft/in) TRANSMITTAL LETTER CHECKLIST WELL NAME: K PTD: iG -- J�o /Development Service _ Exploratory Stratigraphic Test _ Non -Conventional FIELD: tiU POOL: "f 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 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 Well Name: KUPARUK RIV UNIT _2K -11A Program DEV _ Well bore seg ❑ PTD#: 2161060 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type DEV / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal Administration 17 Nonconven. gas -conforms toAS31.05.030(j1.A),(j,2.A-D) _ - - - - _ _ _ - - _ - - - - - - - - NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - 1 Permit fee attached-------------------------- -------- - NA ---------- --------------- ------ ---------- 2 Lease number appropriate- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - ADL0025588, entire wellbore. - _ _ - - - - - - - - - - - - - - 3 Unique well name and number - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - KRU 2K -11A - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 4 Well located in_a_defined -pool - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - KUPARUK RIVER,_KUPARUK-RIV OIL - 490100,_governed_by Conservation -Order No. 432D_ _ _ _ 5 Well -located proper distance from drilling unit -boundary ------------------------ Yes - - - - - - _ CO 432D contains no spacing restrictions with respect to drilling unit boundaries. - - - - _ _ _ _ _ 6 Well located proper distance from other wells- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - _ - _ _ _ _ CO 432D has no interwell spacing restrictions._ - 7 Sufficient acreage available in -drilling unit - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - _ _ _ _ _ _ _ _ _ - - - - - _ _ _ _ _ _ _ _ - - - _ _ - - - - - - _ 8 -if deviated, is wellbore plat -included - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 9 Operator only affected party- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - Wellbore will be more than 50V from an external property line where ownership or landownership- changes ._ _ _ _ 10 Operator has -appropriate bond in force - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 11 Permit can be issued without conservation order- -- - - - - - - - - - - - - Yes- - - - - - - - - _ _ _ _ - - - _ - - - - - - - - - - _ - - - - _ - - - - - - - - - - -- - 12 Permit can be issued without administrativ_e_appr-oval - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - _ - _ - - - - - - - _ _ _ - _ - - - _ _ - - - - - - - _ _ - - _ - - - - - - - - - - - - - - PKB 9/1/2016 13 Can permit be approved before 15 -day wait- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - -- ----------------------------------------- - - _ - - - - - - - - - - - - - - - - - - - _ - - - - 14 Well -located within area and -strata authorized by Injection Order # (put 10# in -comments) -(For NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 15 All wells -within 1/4_mile-area-of review identified (For service well only)_ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ - - - - - - - - _ _ - - - - - - - - - - - _ _ _ _ - - - - _ _ - - - - - - - - - - _ - - - - - - - - - - - - 16 Pre -produced injector: duration of pre production Less than 3 months -(For Service well only) - N_A- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 18 Conductor string_p_rovided - - - NA_ - - - - - _ -Conductor set-in KRU - - -11 - - - _ _ Engineering 19 Surface casing_protects a11_known USDWs NA_ Surface casing set in KRU 2K-11 20 CMT_ vol adequate to circulate on conductor & surf_csg - - - - - - - -- - - - - - _ _ - - - NA_ - - - - - - - Surface casing set and fully cemented - - - - - - - - - - - - - 21 CMT_ vol adequate to tie-inlongstring tosurfcsg------------ ----------------NA -------------------------------- ------------------------- 22 CMT_will coverall known -productive horizons- - - - - - - - - - - - - - - - - - - - - - - - - - - - No_ - _ - - - - - Productive interval wilt be completed with -uncemented slotted liner 23 Casing designs adequate for C,_T, B &_ permafrost ----------- - _ _ _ - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 24 Adequate -tankage or reserve pit - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - _ _ _ Rig has steel tanks; all waste -to approved disposal wells_ - - - - - - - - - - - - 25 -if _a_ re -drill, has_a 10-403 for abandonment been approved - - - - - - - - - - - - - - - - - - - - - NA_ - - _ _ _ _ _ _ _ _ _ _ - - - - _ _ _ _ _ _ _ _ _ - _ _ _ _ _ - - _ _ _ _ _ _ - - - - - - - - - - - - - - - - - _ _ 26 Adequate wellbore separation_proposed - - - - - - - - - - - - - - - - - - - _ - _ - - - - - - - Yes _ _ _ - _ _ - Anti -collision_ analysis complete; no major risk failures - - - - _ _ - _ - _ _ _ _ . 27 -if _diverterrequired, does -it -meet regulations -------------------------------- A_-______________--------------------------------------- Appr Date 28 Dulling fluid -program schematic &equip -list-adequate _ _ Yes Max formation_ pressure is_4791 psig(14.9 ppg_EMW); will drill w/ 8.6_ppg EMW and -maintain ov-erbalw/ MPD _ _ - VTL 9/6/2016 29 BOPEs,_do they meet regulation - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 30 BOPS -press rating appropriate; test to -(put psig in comments)- - - - - - - - - - - - - - - - - - - - Yes _ _ _ - _ _ - MPSP Is 4170 psig; will test SOPs_to 4700-psig - - - - - - - _ _ _ - _ _ - - _ - - - - - _ _ - - - - - - - - - - _ _ _ _ _ _ 31 Choke_ manifold complies w/API_ RP -53 (May 84) - -- ------------ - - - - -- - --- Yes______________________________ --------------------- 32 Work will occur without operation shutdown- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - _ - _ - _ - _ _ _ _ - - - - - - - _ _ _ _ _ _ _ - - _ _ _ - - - - - - - - _ _ - - - - - - - - - - - - - - - - 33 lspresence ofH2Sgasprobable -------------------------------------- es--_____H2S measures required _______-__________-____________-___________________- 34 Mechanical condition of wells within AOR verified (For service well only) - _ - - - - - _ _ _ - - NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 35 Permit can be issued w/o hydrogen_ sulfide measures - - - - - - - - - - - - - - - - - - - - - - - - No_ - - _ - _ _ _ Wells _on 2K -Pad are_H2S-bearing. H2S measures -required -- - - _ _ _ _ _ _ _ _ - _ _ _ _ _ _ _ - _ - - - - - - -- -Geology Geology 36 _Data -presented on potential overpressure zones_ - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - Max. potential_ reservoir pressure is 14.9 ppg-EMW4will be drilled using 8.6_ppg mud and MPD technique._ Appr Date 37 Seismic_analysis of shallow gas_zones------------------------ - - - - - - - - - -NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - PKB 9/1/2016 38 Seabed conditionsurvey-Of off_ -shore)- - - - - - -- - - - - - - - - - - - - - - - - - - - - - - NA- - - - - - - - - --- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - --- _ 39 Contact-name/phone for weekly -progress reports [exploratory only] - - - - - - - - - - - - NA - - - - - - - Onshore development well to_be drilled- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Geologic Engineering Public Commissioner: Date: Commissioner: Date C er Date ,� � / 5;-.7_,r � � 11
