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215-110
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 22, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2S-10 KUPARUK RIV UNIT 2S-10 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2022 2S-10 50-103-20717-00-00 215-110-0 G SPT 6214 2151100 1554 3586 3586 3587 3585 234 242 244 242 4YRTST P Brian Bixby 7/2/2022 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2S-10 Inspection Date: Tubing OA Packer Depth 360 2010 1950 1930IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB220704083641 BBL Pumped:1.8 BBL Returned:1.8 Friday, July 22, 2022 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED JAN 2 3 2020 Anrz 1. Operations Abandon Plug Perforations L1 Fracture Stimulate Pull Tubing ❑ Operations MR= LJ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Prod to WAG ❑� 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development ❑ Straligraphic ❑ Exploratory ❑ Service ❑ 215-110-0 3. Address: p O. Box 100360, Anchorage, Alaska 6. API Number: 99510 50-103-20717-00 7. Property Designation (Lease Number): 8. Well Name and Number: KRU 2S-10 ADL025603; ADI -025604; ADL025608 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 14,896 feet Plugs measured None feet true vertical 6,430 feet Junk measured None feet Effective Depth measured 14,885 feet Packer measured 7375 feet true vertical 6,430 feet true vertical 6215 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80 16 108 108 Surface 2,660 10.75 2,688 2,565 Intermediate 7,465 7.625 7,492 6,246 Slotted Liner 7,539 4.5 14,885 6,431 Perforation depth Measured depth 8102-9024; 9455-11596; 11988-14843 feet True Vertical depth 6336-6344; 6353-6374; 6376-6431 feet Tubing (size, grade, measured and true vertical depth) 3.5 L-80 7404 6223 Packers and SSSV (type, measured and true vertical depth) SSSV = Carrico DS Nipple 500 500 Baker 80-40 GBH Locator Seal Assembly 7375 6215 12. Stimulation or cement squeeze summary: Intervals treated (measured): None Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 480 225 0 740 228 Subsequent to operation: 2200 225 2250 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations ❑ Exploratory ❑ Development ❑ Service ❑Z Straligraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG 2 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: 316-449 Contact Name: Mandy Pogany Authorized Name: Mandy Pogany Contact Email: mandy.w.pogany@cop.com Staff Petroleum Engineer Authorized Title: 9 Date: I a,D aC) Contact Phone: 907-265-4148 Authorized Signature: j A J 2-0 Form 10-404 Revised 4/2017 "�y/�y� RBDMS JAN 2 3 2070 Submit Original Only ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 January 23, 2020 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, Kuparuk River Unit Well 2S-10 was converted from oil production to water-altern ating- gas injection service in 2016 following the approval of 10-403 Sundry Number 316-449 on 9/14/16. This new development rotary horizontal well was produced from 10/18/15 to 10/31/16 and then shut-in and converted to water injection on 11/12/16. Recent review by AOGCC revealed that the required 10-404 had not been previously submitted. Please find enclosed the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. regarding 2S-10 (PTD# 215-110). If you have any questions regarding this matter, please contact me at 907-263-4148. Sincerely, Man y P gany Staff Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Sundry Schematic MIT Reports — 12/1/16 and 7/20/18 �- KUP INJ 2S-10 ConocoPhillips AW5kd Inc,YVellbare Well Attributes BFnpWI Fide Name Wellbore SiMus 501032071700 KUP AR UK RIVER UNIT INI Max Angle IK MD TD nd l•1 MD IXKBI ACI Btm (XRDI 92.13 13,98068 1489].0 CammmlX25 piping SSSV: NIPPLE Ann"Noon Ena Dale AuGxa al) RIp%1 MOale Latl NO: 2]50 9/172015 A7 2510, 1InREST 882SPM ux a e Annotation apIn IXKBI Ena ONe Annotffibn Lsam. By Entl Oah Last Tag'. Rev Reason: GLV C/O 'proven 11/1512016 Casing tstruggs - - - - Casing DesenpOon OO Top lnrcBl gat Oapm (nMel set Dapm lrvDl... WtlLen (L.. Gretle Top mrne HANGER, 25O CONDUCTOR .250 275 1075 10]5 8250 H.4O Welded Casing Oescnption 0O Top TA.N SND,gpKBI Set DepIn IN01_. VYIILen 11... GrMb Top Thread SURFACE .950 283 2688.0 2,564.5 4550 L-00 HYD 563 Casing Oescnpoon GO Top lnKBl SN Capin(MG)Bel DePtM1 IND1... WtlLm 11... GrW Top TM1rmaINTERMEDIATE Fl�o .8]5 2)1 7,492.0 6.245.6 29 )0 LBO Hyd 563 Casing DesaiRuss OO) Top HIRE) SN Wpts HIRE) Bel Naps, P'NN. WXLE, 11... Grate Top TM1roMSLOTTED LINER 5IG 958 ],346.2 14,8850 6430.5 11.60 L -BD IBTM x 5" @7378 x 4 112" @]409 Liner Details Nomhauo Top (XKBI Top(ND)X1KBI Topindr) Item Ass Co. (nl 7.3462 6.205.8 )1.82 PACKER BAKER HRUE ZXP LINER TOP PACKER 5.750 7.3562 6.2119 72.50 NIPPLE BAKER R6 RACKOFF REAL NIPPLE 4.880 7,369.0 6,2128 7260 HANGER BAKER DG FLEX LOCK LINER HANGER 4840 L ],3)89 6.215.7 72.93 XO.NOGO NO GO XO 514" HON 5O3 GOXX 6' Hydri 521 4,390 Dox cON0DCT0R: 27 7.390.2 6.2190 73.32 SBE BAKER SEAL BORE EXTENSION 4.000 0985.7 6,3342 8500 SPELL BAKER SWELL PACKER G' 3.960 PACKER NPPLE,4998 Tubing Strings Tubinq R¢ription Svino Ma...IDlml Top IXKBI Set DepinlX_Set-ph(No)(E WI hlXl Graee Tap CoanMmn TUBING -4112"x3 314 2.992 250 ).404.0 6,2229 9.3O L -BD EUE-M 112"@69.6 Completion Details Nominal to Top(XKB) Tup UNC)RIKB1 Top and V) Ibm Dan, Com Ont suaFACE; xa 32H8U 25.0 250 007 HANGER CW TUBING HANGER 3900 69.5 69.5 O2O XO Reducing NO. 2', 4-1 YY' 128tl L -0O IBTM Sax x 3-112" EV L-80 30M EUE-Mod pin GAS L6T. 3,]825 499.0 4998 0]0 NIPPLE GAMC00.S NIPPLE 2.875 7,2586 6,1763 66.82 SLEEVE BAKER CMU SLIDING SLEEVE WEDS NIPPLE -CLOSED 2.012 7.282.9 SUNS AS NIPPLE CAMOO DNPPLE 2.750 ],300.3 6,19o.g 028 PLUG HES MIRAGE PLUG 2962 7.373.7 62142 72.75 LOCATOR BAKERLOOATOR 2.990 ].3]4.0 1 6214.5 )2)9 1 SEAL ABBY BAKER OO4O GBH LOCATOR SEAL ASSEMBLY 3.000 Perforations & Stats Shot 0ABLIFT;68159 Dens Tap(TVD) B1mnVo1 ahold! Top HH" Blm (flKel MKS) MKS) IDm OMe X Type Co. Omit, 9,024.0 6,335.6 8,343.8 9/142015 SLOTS Slotted Liner 9,454.9 11,595.7 6.352.) 6,3742 9/142015 SLOTS Blolled Liner SLEEVEI7288.6 11,98)] 14.8434 8.3]8.3 6,4305 9/14201 SLOTS 1 BI011. Liner Mandrel Imports BI NIPPLE 7.2329 onl N Tap (TVD) Top (XKB) (hKBI Matr MoaN OO (int Berv' VaFn (Wnh PO(in) Type Tries Ilnl T(Pat) (Pat) Run Gale Com 1 3,)62.5 3,508.6 CAMCO MMG 1112 GAS LIFT Unity RK 0000 0.0 9/1812015 PLUG: 7.3W3 2 6,6159 58673 CAMCO MMG 11/2 GAS LIFT DMY RN 0000 00 11H&2016 Notes: General & Safety 5na Dah Annnlalbn NOTE'. LOCAT0R:7.3737 SEAL ASSY:].3148 INTERMEDNTE.2714,493O SLOTS, 8.101 ]-9,0240- SLOTS', 9 <S4 &11,595.] SL0TS: 11.9877T,180 4- - SL0TTEDLINER.517Ya5• ®7378%410. C74W 7,348 14.0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submitto: iim.reggidalaskanow AOGCClnspectors0alaska.gov. Phoeb brooksC�aia k qo chns wallaw(dalaskagov OPERATOR: ConowPhillips Alaska, Inc FIELD I UNIT I PAD: Kuparuk / KRU / 2S Pad DATE: 12/01/16 OPERATOR REP: Riley/Arend AOGCC REP: Bob Noble Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 25-10 '. W TVD 6215' Tubing 30 2,330 2,330 Interval T e In2,330 2,3 P.T.D.2151100 Type test P Test psi 1554 Casing 7,045 1,800 1,755 7,750 P/F P Notes: MITIA per Sundry #316-449 post conversion to I OA230 285 280 270 Final T/1/0= 2330/960/215 Well Type In'. ND Tubing Interval finjection P.T.D. Type test Tesl si Casing I PIF Notes: I OA Well I Type In-. TVD Tubing Interval P.T.D. Type test Test pail Casing P/F Notes: OA Well I Type In'. TVD Tubing Interval P.T.D. I Type lest I I Test psi I Casing PIF Notes: I OA Well I Type In'. I TVD I I Tubing I I Interval P.T.D. I Type test I I Test psi I Casingi PIF Notes: I OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test Form 10-426 (Revised 11/2012) MIT KRU 25-1012-01-16.As INTERVALCodes I = Initial Test 4 = Four year Cycle V = Required by Variance O = Other (describe in nates) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test b brok Malaslu aov h' II I skagov Submit to: 'm ren I@slaska aov AOGCC I t ®I ska aov h � OPERATOR: FIELD / UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhilli s Alaska, Inc. Ku aruk / KRU / 2S Patl Rile , Sumrell. Hills Well 25.82 PTD 2150700 Tyne Inj Packer ND 6238 BEL Pump Test psi 1560 BBL Retum W 5.8 5.3 Pressures: Tubing IA OA Pretest 2441 350 260 Initial 2457 3200 460 15 Min. 2440 3130 1 420 30 Min. 2462 3120 1 400 45 Min. 60 Min. Type Test Interval Result P 4 P Notes: P•Pess W = Water O. Other (dsscrlba In Notes) 4 • Four Year CYcle F - Fail G=Ges V • Required W Variance I• Incgnduaive s=slam Well PTD Packer TVD Test psi 25.04 2151590 Type Inj 6141 BBLPump 1535 88L Retum W _4.:O:: 2.8 Pressures: Tubing IA 1 OA Pretest 2255 1220 2417 Initial 2253 3100 371 15 Min. 2258 3000 340 30 Min. 2261 2900 325 45 Min. 60 Min. Type Test Interval Result P 1 P Notes: Well PTD Packer ND Test psi 2S-07 2150790 TyPe lnl 6216 BBLPump 1554 BBL Return W 3.3 3.0 Pressures: Tubing IA OA Pretest 2465 550 245 Initial 2465 3280 440 15 Min. 24822474 3210 410 30 Min. 3110 410 45 Min. 60 Min. Type Test Interval Result P 4 P Notes: Well PTD Packer ND Testpsi 2S-08 2151740 Type IN 6104 BBL Pum 1526 BBL Return G 4.6 2.1 Pressures: Tubing IA OA Pretest 3559 0 1 163 Initial 3558 2500 3fi0 15 Min. 3544 2400 320 30 Min. 3535 2370 300 45 Min. 60 Min. Type Test Interval Result P 4 P Netes: Wall TO Packer ND Test psi 2S-18 2151100 Type Inj 6215 BB1-PumPj 1554 BBL ReIum W 3.1 2.8 Pressures: Tubing IA OA Pretest 2469 900 220 Initial 2460 I 3300 375 15 Min. 2480 3180 370 30 Min. 2480 I 3160 300 45 Min. 60 Min. Type Test Interval Result P 4 P Notes: Well PTD Packer ND Test psi 25.13 2161040 TYPe Int 6271 BBLPump 1568 BBL tum W 3.1 2.5 Pressures: Tubing IA OA Pretest 2047 800 1 540 Initial 2047 2800 1 710 15 Min. 2045 2700 1 700 30 Min. 2046 1 2690 700 45 Min. 60 Min. Type t1 Result 4 P Notes: Farm 10-426 (Revised 01/2017) MIT KRU 2S Patl 07-20-18Ah. INTERVAL Codes Reeds Codes TYPE IW Codes TYPETESTCodes P = Pressure Test 1=Initial Tall P•Pess W = Water O. Other (dsscrlba In Notes) 4 • Four Year CYcle F - Fail G=Ges V • Required W Variance I• Incgnduaive s=slam o • OtherNeiin nmec) I•IrAustrel weaewamr N=No' Injecting Farm 10-426 (Revised 01/2017) MIT KRU 2S Patl 07-20-18Ah. Winston, Hugh E (CED) From: Pogany, Mandy W < Mandy.W.Pogany@conocophillips.com > Sent: Thursday, January 23, 2020 10:48 AM To: Winston, Hugh E (CED) Subject: RE: [EXTERNAL] Missing report for KRU 25-10 conversion Hi Huey, The 10-404 for 25-10 conversion to WAG is on its way. I found that we had started a draft but not submitted. I apologize for the oversight. Please let me know if you need any additional information. Thanks, Mandy From: Winston, Hugh E (CED) <hugh.winston@alaska.gov> Sent: Monday, January 13, 2020 9:55 AM To: Pogany, Mandy W <Mandy.W.Pogany@conocophillips.com> Subject: RE: [EXTERNAL] Missing report for KRU 25-10 conversion Great, please let me know if you need additional information. Huey Winston Statistical Technician Alaska Oil and Gas Conservation Commission hugh.winston@alaska.Qov 907-793-1241 From: Pogany, Mandy W <Mandy W PoRany@conocophillips.com> Sent: Friday, January 10, 2020 2:04 PM To: Winston, Hugh E (CED) <hugh winston@alaska.Rov> Cc: Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann.HaRRerty- SherrodC@contractor.conocophillips.com>; Humphrey, Darrell R <Darrell R Humphrey@conocophillips.com>; Germann, Shane <Shane Germann conocophillips.com> Subject: RE: [EXTERNAL]Missing report for KRU 25-10 conversion Hi Hugh, I'm the DPE for 2S. I'll look through the existing 25-10 files and get back to you on the question below so we can get this taken care of as soon as possible. Thanks, Mandy Mandy Pogany Staff Petroleum Engineer ConocoPhillips Alaska, Inc. P:(907)263-4148 mandv w ponanv(a)conocophillips.com From: Humphrey, Darrell R <Darrell R Humphrev@conocophillips.com> Sent: Thursday, January 9, 2020 4:09 PM To: Germann, Shane <Shane.Germann@conocophillips.com> Cc: Winston, Hugh E (CED) <hugh.winston@alaska.gov>; Pogany, Mandy W <Mandv W Poganv@conocophillips.com>; Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann.Haggerty- She rrod @contractor.co noco ph it lips.co_m> Subject: FW: [EXTERNAL] Missing report for KRU 25-10 conversion Shane- I have not been involved with Sundries for over 2 yrs now. This responsibility has been assigned to the DPE's in town. I suggest contacting Mandy Pogany or Ann Haggerty -Sherrod to try to resolve this. Darrell Humphrey/ Doug McMullen Production Engineering Specialist ConocoPhillips Alaska Ph: 907.659.7535 1 Pg: 924 1 Mail: NSK 69 From: Germann, Shane <Shane.Germann@conocophillips.com> Sent: Thursday, January 9, 202011:33 AM To: Humphrey, Darrell R <Darrell R.Humphrev@conocophillips.com> Cc: Winston, Hugh E (CED) <hugh.winston@alaska.gov> Subject: FW: [EXTERNAL]Missing report for KRU 25-10 conversion Darrell, I was contacted by the AOGCC in regards to a 10-404 that wasn't received for the 25-10. It would be a completion report for the 10-403 Sundry (316-449) for converting to WAG that was approved on 9/14/2016. 1 saw that you were the contact on the application so I'm passing this off to you for filing the completion report or finding the right person to complete it. Thanks, Shane Germann Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office: 907-263-4597 Cell: 406-670-1939 700 G St, ATO 664, Anchorage, AK 99501 From: Winston, Hugh E (CED) <hush.winston@alaska.aov> Sent: Thursday, January 9, 2020 9:59 AM To: Germann, Shane <Shane.Germann conocophillips.com> Subject: [EXTERNAL]Missing report for KRU 25-10 conversion Hi Shane, Thanks for helping me solve this issue. Here is the information on the well... KRU 25-10 API# 50-103-20717-00-00 PTD# 215-110 Sundry # for conversion to WAG 316-449 Application was approved 9/14/2016 but no report for the conversion is on file. Huev Winston Statistical Technician Alaska Oil and Gas Conservation Commission h uah.winston @alaska.aov 907-793-1241 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 RECEIVED September 24, 2017 SEP 2 6 2011 AOGCC Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name,top of cement depth prior to filling and volumes used on each conductor. Please call Roger Winter or Roger Mouser at 907-659-7506, if you have any questions. Sin rely, Roger Winter ConocoPhillips Well Integrity Field Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 9/25/2017 2S pad Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 2S-05 501032073900 216-039-0 22" 0.05 11" 6/7/2017 1.7 9/10/2017 2S-06 501032074700 216-085-0 4' 0.25 15" 6/10/2017 3.4 9/10/2017 2S-07 501032071300 215-079-0 22" 0.16 11" 6/7/2017 3.4 9/10/2017 2S-08 501032072200 215-174-0 17" 0.10 13" 6/7/2017 -3.4 9/10/2017 2S-09A 501032074901 216-128-0 39" 0.30 12" 6/10/2017 4.25 9/20/2017 (....- , 2S-10 501032071700 215-110-0 10' 1.50 9" 6/10/2017 1.7 9/10/2017 2S-11 501032073200 215-219-0 20" 0.10 10" 6/7/2017 3.4 9/10/2017 2S-12 501032074300 216-074-0 25" 0.10 13" 6/7/2017 4.8 9/10/2017 2S-13A 501032072001 216-104-0 30" 0.40 9" 6/7/2017 3.4 9/10/2017 2S-14 501032073300 215-220-0 27" 0.24 12" 6/7/2017 3.9 9/10/2017 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission _ DATE: Wednesday,December 07,2016 TO: Jim Regg P.I.Supervisor G �Z SUBJECT: Mechanical Integrity Tests ( CONOCOPHILLIPS ALASKA INC 2S-10 FROM: Bob Noble KUPARUK RIV UNIT 2S-10 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry Nj6(2- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2S-10 API Well Number 50-103-20717-00-00 Inspector Name: Bob Noble Permit Number: 215-110-0 Inspection Date: 12/1/2016 Insp Num: mitRCNl61201150038 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2S-10 (Type Inj W` TVD 6214 - Tubing 1 2330 2330 - 2330- 2330 - PTD 2151100 Type Test SPT Test psi 1554 IA 1045 1800 ' 1755 - 1750- Interval NIT'S- P/F P '' OA 230 285 - 282 - 270 - Notes:---- — -- — SCANNED APR 0 6 2017 Wednesday,December 07,2016 Page 1 of 1 II • voFry4, OAP�1//7,est THE STATE Alaska Oil and Gas F ;, 0f T A Conservation Commission S .it£== 333 West Seventh Avenue � �� c GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 pF�nm;m_ � Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Robert D. Christensen NSK Production Engineering Specialist ConocoPhillips Alaska, Inc. SCAMED FEB 1 5 2017 P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2S-10 Permit to Drill Number: 215-110 Sundry Number: 316-449 Dear Mr. Christensen: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, a// Cathy . Foerster Chair DATED this /¢46-ay of September,2016. RBDMS Li.- SEP 1 6 2016 M STATE OF ALASKA 20 L ALASKA OIL AND GAS CONSERVATION COMMISSION OTS,��,,�_ APPLICATION FOR SUNDRY APPROVALS GCC 20 AAC 25.280 1.Type of Request: Abandon r Plug Perforations r Fracture Stimulate r Repair Well r Operations shutdown r Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Program r Plug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing r Other PROD to WAG lvR 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development 17. 215-110-0 • 3.Address: Stratigraphic r Service 6.API Number: P. O. Box 100360, Anchorage,Alaska 99510 50-103-20717-00 • 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA Will planned perforations require spacing exception? Yes r No '/ KRU 2S-10 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL025603;ADL025604;ADL025608. Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 14896 . 6430 • 14885' • 6430'• 1752 None None Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 16 108' 108' SURFACE 2660' 10 3/4 2688' 2565' INTERMEDIATE 7465' 7 5/8 7492' 6246' SLOTTED LINER 7539' 4 1/2 14885' 6431' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8102-9024;9455-11596; 11988-14843• 6336-6344;6353-6374;6376-6431 3 1/2 L-80 7404 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) SSSV=CAMCO DS NIPPLE • MD=500 TVD=500 PACKER=BAKER 80-40 GBH LOCATOR SEAL ASSEMBLY - MD=7375 TVD=6215 12.Attachments: Proposal Summary r WellBore Schematic r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service 17• 14.Estimated Date for 15. Well Status after proposed work: 10/07/1 6 Commencing Operations: OIL WINJ r t/�/pgpL " Suspended r 16.Verbal Approval: Date: GAS r WAG F • GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdow n r Abandoned r 17. I hereby certify that the foregoing is true Contact: Darrell Humphrey/Bob Christensen Printed Name Robert D. Christensen Phone:659-7535 Email: n1139 conocophillips.com Title: NSK Production Engineering Specialist Signature / / r ("A„......4„4:4-- Date: vas./J (.N Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3' Plug Integrity r BOP Test r Mechanical Integrity Test ocation Clearance r Other: Post Initial Injection MIT Req'd? Yes No r Spacing Exception Required? Yes r No Subsequent Form Required: ' t) ' 4 0 4 RBDMS V/SEP 1 6 2016 APPROVED BY „,./.-e. Approved by: ° /-9 291...„.„.24, COMMISSIONER THE COMMISSION Date:`_/et/../ . 1' ?'('I� IrrL RG `2/lb Q R Q1Ji%siL. .Form 10-403 Revised 11/2015 Approved application ao 1srbm-trdate of approval. Attachments in Duplicate • Robert Christensen/Darrell Humphrey Production Engineering Specialists. Greater Kuparuk Unit,NSK-69 PO Box 196105 ConocóPhillips Anchorage,AK 99519-6105 Phone:(907)659-7535 Fax:659-7314 August 28,2016 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave. Ste. 100 Anchorage, AK 99501 ,V 'y of („15k N1 `TiQr,* fr��Kt Gr► ptiafe. /a' /Pfev/C Dear Commissioner, ,�. ��� ConocoPhillips Alaska, Inc. requests approval to conVerrt'Kup k�Well 2S-10 from (ev,'¢,✓ Production service to Water Alternating_Gas Jnjection servic Enclosed you will find 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 2S-10 (PTD#215-1100). If you have any questions regarding this matter,please contact myself or Darrell Humphrey at 659-7535. Sincerely, Jar V w� Robert D. Christensen Attachments Sundry application Proposal Summary Well schematic Area Map AOR Detail • • 2S-10 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert Kupaurk River Well 2S-10 (PTD# 215-1100) from Oil Production service to Water Alternating Gas Injection service as the pre-production period has been completed. Area of Review: Kuparuk River well 2S-10 was completed as an injector on September 16th 2015 to provide enhanced recovery injection into the reservoir to increase the ultimate recovery of oil. This well will support existing 'A' sand producer 2S-03 and 2S-06 which is currently being drilled. The top of the Kuparuk C4 sand was found at 7855' and /6311' tvd The top of the Kuparuk A4 sand was found at 8061' and/6332' tvd Area Map with 1/4 mile radius around target injection zone (see attached): The map attached shows that there are no additional production/injection wells located within a 1/4 mile radius of the 2S-10 penetrations of the Kuparuk interval. Mechanical Condition of Well to be Converted: The mechanical condition of Kuparuk well 2S-10 is good and is classified as a "Dual Casing - Single"well. The injection tubing/casing annulus is isolated via a BAKER 80-40 GBH LOCATOR SEAL ASSEMBLY located at 7375' and (6215' tvd). A State-witnessed MIT-IA will be performed once well 2S-10 is converted to water injection, online, and stabilized. CBL and interpretation of the cement quality: Attached AOR detail The 16" Conductor was cemented with 412 sx ASI followed by 49 sx ASI. The 10-3/4" Surface casing was cemented with 1288 sx DeepCrete followed by 207 sx DeepCrete. The 7-5/8" Intermediate casing was cemented with 365 sx Class 'G' followed by 130 sx Class 'G'. KUP SVC • 2S-10 ConocoPhillips liti Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) cay.Kowrarg^ 500292354600 KUPARUK RIVER UNIT SVC 14,897.0 •-- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2S-10,10/1520152:49.55 PM SSSV:NIPPLE Last WO: 27.50 9/17/2015 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag. Rev Reason:GLV C/O lehallf 10/15/2015 Casing Strings �� Casing Description OD(in) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WULen(I...Grade Top Thread HANGER,250CONDUCTOR 16 15.250 27.5 107.5 107.5 62.50 H-40 Welded I' •. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(1..Grade Top Thread ... 1 . SURFACE 10 3/4 9.950 28.3 2,688.0 2,564.5 45.50 L-80 HYD 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ......_...__.___..__..�.__.__...___..__.._..._8.. ...._....INTERMEDIATE 7 5/8 6.875 27.1 7,492.0 6,245.6 29.70 L80 Hyd 563 °. Casing Description OD(in) ID(in) Top(ftKB) -Set Depth(ftKB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread SLOTTED LINER-51/2" 41/2 3.958 7,346.2 14,885.0 6,430.5 11.60 L-80 IBTM • • x 5"@7378 x 4 1/2" X7409 Liner Details Nominal ID ' Top(ftKB) Top(TVD)(ftKB) Top Incl F) Item Des Com (in) 7,346.2 6,205.6 71.82 PACKER BAKER HRD-E ZXP LINER TOP PACKER 5.750 I 7,366.2 6,211.9 72.50 NIPPLE BAKER RS PACKOFF SEAL NIPPLE 4.880 7,369.0 6,212.8 72.60 HANGER BAKER DG FLEX-LOCK LINER HANGER 4.840 7,378.9 6,215.7 72.93 XO-NOGO NO GO XO-51/2"Hydril 563 box X 5"Hydril 521 4.390 box _AA,rCONDUCTOR;27.5-107.5 7,390.2 6,219.0 73.32 SBE BAKER SEAL BORE EXTENSION 4.000 I 8,085.7 6,334.2 85.00 SWELL BAKER SWELL PACKER"G" 3.960 PACKER NIPPLE;499.8 I Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(1b/11) Grade Top Connection TUBING-4 1/2"x 3 3 1/2 2.992 25.0 7,404.0 6,222.9 9.30 L-80 EUE-M 1/2"@69.6 Completion Details • Nominal ID • Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) SURFACE;28 3-1008.0 25.0 25.0 0.00 HANGER CIW TUBING HANGER 3.900 i. 69.5 69.5 0.28 XO Reducing XO,2',4-1/2"12.68 L-80 IBTM box x 3-1/2"9.31 L-80 3.000 I EUE-Mod pin GAS LIFT;3,762.5 II 499.8 499.8 0.78 NIPPLE CAMCO DS NIPPLE 2.875 7,258.6 6,176.3 68.82 SLEEVE BAKER CMU SLIDING SLEEVE W/DS NIPPLE-CLOSED 2.812 7,282.9 6,184.9 69.66 NIPPLE CAMCO D NIPPLE 2.750 7,300.3 6,190.9 70.26 PLUG HES MIRAGE PLUG 2.962 7,373.7 6,214.2 72.75 LOCATOR 'BAKER LOCATOR 2.990 GAS LIFT;6,615.9 ( 7,374.8 6,214.5 72.79 SEAL ASSY BAKER 80-40 GBH LOCATOR SEAL ASSEMBLY 3.000 Perforations&Slots Shot Dens Top(NO) Btm(TVD) (shots'? Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com SLEEVE;7,258.6 ' 8,101.8' 9,024.0 6,335.6 6,343.6 9/14/2015 SLOTS Slotted Liner I 9,454.9 11,595.7 6,352.7 6,374.2 9/14/2015 SLOTS Slotted Liner I 11,987.7' 14,843.4 6,376.3 6,430.5 9/14/2015 SLOTS Slotted Liner NIPPLE;7,282.9 Mandrel Inserts I St ati PLUG;7,300.3 _ on Top(ND) Valve Latch Port Size TRO Run I N Top(ftKB) (ftKB) Make Model OD(in) Sew Type Type (in) (psi) Run Date Com 1. 3,762.5 3,508.6 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/16/2015 2 6,615.9 5,867.3 CAMCO MMG . 1 1/2 GAS LIFT OV RK 0.313 0.0 10/14/2015 II Notes:General&Safety End Date Annotation NOTE: i'. LOCATOR;7,373.7 I!. 1 t t SEAL ASSY;7.3748 Ii I INTERMEDIATE;27.1-7,492.0 _R- SLOTS;8,101.7-9,024 0 -I (- SLOTS;9,454.9-11,595.7 I I_ SLOTS;11,987.7-14,843.4I SLOTTED LINER-5 12'x 5' X7378 x 41t2 e7409;7,346.2 -14,885.0 ! 0 • z. } II!: ) - 1E. { -( i(a \\ \\| _ \ \) ° ! E-2.%/ k _ \ [ |} {k k )/ })}\ /j) f / g 2) k)\ $))Li\ `izr\- \;\ k�\k k / \ \ § ;\ jj �\ \ {j } \ f !! - w t |�> oa \} I \\ LLqO , .. .. « |/ - Wq y ` - ° « ` / ` \ /\ y£ \ / 4. \} \ :"°' \ \ !! - si ! -4 }� / 5 z \ , \ \ , ; \ , j j j j j \G \ \ • 29J u 116 ConocoPhillips Alaska, Inc. 2S-10 N 10-403 Sundry 0 0.15 0.3 0.45 0.6 ADL025590 , v 2S-05 17 y t d J ADL025603 1 ! ADL025604 t d NR8 d 20 / 21 d I 1 1 r 2S-10 J w 2S106 29 2S-03 r .,7 • ADL025608 ADL025607 —2S-10 Open Interval: Kuparuk PA —2S-10 Trajectory Q 1/4 Mi. Radius r -- Planned Well —Well Within Radius 0 Well Pad • • , \ 7- I The API number originally assigned to KRU 2S-10 was incorrect. The correct API number is 50-103-20717-00-00. Logs and digital data have been updated with the correct API, and other documents were updated by hand. M. Guhl f l I I(p SCANNED MAR 0 12016 2c0 • S 21 -- 1 ) 0 Schiumberger 22-FEBRUARY-2016 Notice of Revision Please find the enclosed data set for well 2S-10 SONIC Top of Cement to su- persede all previous editions received. Revisions made were isolated to the APIN# for the entire data set. RECEIVED FEB 2 3 2016 AOGCC Stephanie Pacillo Schlumberger Petro Technical Services STEPHANIE PACILLO SCHLUMBERGER A1,ASKA 6411 1 ST1tF,H.T ANCHORAGE,AK 99518 EMAIL:SPACILLO@SLB.COM DIR 907.273.1770 FAX 907.273.4760 • • 2CO2q \ 21S- i io SchivunbergerDrilling & Measurements Transmittal#: 22FEB16-SPO1 MWD/LWD Log Product Delivery Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2S-10 T.O.C. *REVISED** Date Dispatched: 22-Feb-16 Job#: 14AKA0059 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 1 Contents on CD N/A SonicScope Top of Cement x x RECEW FEB--2 3 ct,:o A LAS Digital Data N/A Contents on CD N/A x Directional Data N/A Contents on CD N/A As-Built Survey N/A Contents on CD N/A CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf x Please sign and email a copy to: Please sign and email a copy to: Richard.E.Elgarico(a conocophillips.com AlaskaPTSPrintCenter(a�sib.com Ricky Elgarico Attn:Stephanie Pacillo 907-265-6580 3// it�/ Received By�---�` � � A • 21 S- 110 • 2Co1g2. RECEIVED JAN 25 2016 Scblumberger AOGCC 25-JANUARY-2016 Notice of Revision Please find the enclosed data set for well 2S-10 to supersede all previous editions received. Revisions made were isolated to the corrected APIN# only. Stephanie Pacillo Schlumberger Petro Technical Services STEPHANIE PACILLO SCHLUMBERGER ALASKA 6411 A STREET ANCHORAGE,AK 99518 EMAIL:SPACILLOasix.comj DIR 907.273.1770 FAX 907.273.4760 pis - � �b • REC IVED 2(02:12- JAN (0212JAN 2 5 2016 SchlumbergerDrilling & Measurements /-1^OGko raannsmittal#: 25JAN16-SPO1 MWD/LWD Log Product Delivery Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2S-10 "*REVISED** Date Dispatched: 25-Jan-16 Job#: 14AKA0059 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 4 Contents on CD N/A EcoScope 2" MD x x EcoScope 2"TVD x x EcoScope 5"MD x x EcoScope 5"TVD x x LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 x x As-Built Survey 1 Contents on CD N/A Nad83 x x CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf/tiff _ x Surveys:pdf/txt x Please sign and email a copy to: Please sign and email a copy to: Richard.E.Elqaricoconocophillips.com AlaskaPTSPrintCenter(@,s1b.com Ricky Elgarico Attn:Stephanie Pacillo 90 - :•-6580 .�/ I Received By: A A ` _ • • 215 - 110 2622_612_ RECEIVED JAN 252016 AOGCC FINAL ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad 2S-10 Definitive Survey Report 24 September, 2015 NAD 83 • S Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-10 Project: Kuparuk River Unit TVD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Site: Kuparuk 2S Pad MD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Well: 2S-10 North Reference: True Wellbore: 2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well 2S-10 Well Position +NI-S 0.00 usft Northing: 5,929,729.31 usfl Latitude: 70° 13'10.376 N +E/-W 0.00 usft Easting: 1,621,077.45 usfl Longitude: 150°9'21.677 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 120.00 usft Wellbore 2S-10 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 9/5/2015 18.60 80.87 57,489 Design 2S-10 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.50 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 27.50 0.00 0.00 195.00 Survey Program Date 9/24/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 93.90 462.50 2S-10 Srvy#1 Gyro(2S-10) GYD-GC-MS Gyrodata gyrocompassing m/s 9/4/2015 12:02 506.90 2,627.01 2S-10 Srvy#2 MWD+IFR-AK-CAZ-SC(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/4/2015 12:17 2,725.17 7,429.08 2S-10 Srvy#3 MWD+IFR-AK-CAZ-SC(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/4/2015 12:31 7,519.07 14,834.45 2S-10 Srvy#4 MWD+IFR-AK-CAZ-SC(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/8/2015 11:3£ 14,896.00 14,896.00 2S-10 Srvy#5-Projection to TD(2S-10)BLIND Blind drilling 9/24/2015 2:41 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 27.50 0.00 0.00 27.50 -120.00 0.00 0.00 5,929,729.31 1,621,077.45 0.00 0.00 UNDEFINED 94.40 0.45 73.93 94.40 -53.10 0.07 0.25 5,929,729.38 1,621,077.70 0.67 -0.14 GYD-GC-MS(1) 107.50 0.46 73.22 107.50 -40.00 0.10 0.35 5,929,729.41 1,621,077.80 0.11 -0.19 GYD-GC-MSf1) 16"x 42" NOT an Actual Survey 186.50 0.54 69.67 186.50 39.00 0.32 1.01 5,929,729.63 1,621,078.46 0.11 -0.57 GYD-GC-MS(1) 278.70 0.58 73.72 278.69 131.19 0.61 1.86 5,929,729.91 1,621,079.32 0.06 -1.07 GYD-GC-MS(1) 370.80 0.73 77.64 370.79 223.29 0.86 2.88 5,929,730.16 1,621,080.34 0.17 -1.58 GYD-GC-MS(1) 506.90 0.78 74.23 506.87 359.37 1.30 4.62 5,929,730.59 1,621,082.08 0.05 -2.45 MWD+IFR-AK-CAZ-SC(2) 598.44 0.51 89.00 598.41 450.91 1.48 5.63 5,929,730.77 1,621,083.08 0.34 -2.88 MWD+IFR-AK-CAZ-SC(2) 696.00 1.69 54.94 695.95 548.45 2.31 7.24 5,929,731.60 1,621,084.70 1.33 -4.10 MWD+IFR-AK-CAZ-SC(2) 788.22 2.43 45.82 788.11 640.61 4.45 9.76 5,929,733.73 1,621,087.22 0.88 -6.83 MWD+IFR-AK-CAZ-SC(2) 9/24/2015 2:44:44PM Page 2 COMPASS 5000.1 Build 74 . • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-10 Project: Kuparuk River Unit TVD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Site: Kuparuk 2S Pad MD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Well: 2S-10 North Reference: True Wellbore: 2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°I100') (ft) Survey Tool Name 880.07 3.57 31.30 879.83 732.33 8.25 12.64 5,929,737.53 1,621,090.11 1.48 -11.24 MWD+IFR-AK-CAZ-SC(2) 972.37 5.71 29.21 971.82 824.32 14.72 16.37 5,929,743.98 1,621,093.86 2.33 -18.45 MWD+IFR-AK-CAZ-SC(2) 1,065.00 7.70 32.99 1,063.82 916.32 23.95 22.00 5,929,753.19 1,621,099.51 2.20 -28.82 MWD+IFR-AK-CAZ-SC(2) 1,115.38 9.02 32.68 1,113.66 966.16 30.10 25.97 5,929,759.34 1,621,103.50 2.62 -35.80 MWD+IFR-AK-CAZ-SC(2) 1,158.68 10.08 31.52 1,156.36 1,008.86 36.19 29.78 5,929,765.41 1,621,107.33 2.49 -42.66 MWD+IFR-AK-CAZ-SC(2) 1,216.08 11.15 32.19 1,212.78 1,065.28 45.17 35.37 5,929,774.38 1,621,112.93 1.88 -52.78 MWD+IFR-AK-CAZ-SC(2) 1,251.55 12.84 31.28 1,247.47 1,099.97 51.44 39.24 5,929,780.64 1,621,116.82 4.79 -59.84 MWD+IFR-AK-CAZ-SC(2) 1,345.39 14.91 29.17 1,338.57 1,191.07 70.89 50.54 5,929,800.06 1,621,128.17 2.27 -81.56 MWD+IFR-AK-CAZ-SC(2) 1,438.07 15.95 33.62 1,427.91 1,280.41 91.91 63.40 5,929,821.05 1,621,141.08 1.70 -105.19 MWD+IFR-AK-CAZ-SC(2) 1,531.92 19.06 42.90 1,517.42 1,369.92 113.88 80.98 5,929,842.97 1,621,158.72 4.44 -130.96 MWD+IFR-AK-CAZ-SC(2) 1,626.66 20.25 56.47 1,606.69 1,459.19 134.28 105.19 5,929,863.31 1,621,182.98 4.97 -156.93 MWD+IFR-AK-CAZ-SC(2) 1,719.09 20.73 63.37 1,693.28 1,545.78 150.45 133.15 5,929,879.40 1,621,210.98 2.66 -179.79 MWD+IFR-AK-CAZ-SC(2) 1,814.62 22.50 71.62 1,782.11 1,634.61 163.80 165.62 5,929,892.66 1,621,243.48 3.68 -201.08 MWD+IFR-AK-CAZ-SC(2) 1,909.13 24.42 81.56 1,868.84 1,721.34 172.37 202.13 5,929,901.14 1,621,280.00 4.65 -218.81 MWD+IFR-AK-CAZ-SC(2) 2,002.26 25.90 86.94 1,953.14 1,805.64 176.29 241.49 5,929,904.95 1,621,319.37 2.92 -232.78 MWD+IFR-AK-CAZ-SC(2) 2,094.67 26.33 88.82 2,036.12 1,888.62 177.78 282.13 5,929,906.35 1,621,360.01 1.01 -244.75 MWD+IFR-AK-CAZ-SC(2) 2,187.42 26.80 88.37 2,119.08 1,971.58 178.80 323.60 5,929,907.26 1,621,401.48 0.55 -256.46 MWD+IFR-AK-CAZ-SC(2) 2,280.73 26.91 89.57 2,202.32 2,054.82 179.56 365.74 5,929,907.91 1,621,443.62 0.59 -268.10 MWD+IFR-AK-CAZ-SC(2) 2,373.10 27.01 89.98 2,284.66 2,137.16 179.72 407.62 5,929,907.97 1,621,485.49 0.23 -279.10 MWD+IFR-AK-CAZ-SC(2) 2,465.75 27.03 89.30 2,367.19 2,219.69 179.99 449.71 5,929,908.12 1,621,527.57 0.33 -290.25 MWD+IFR-AK-CAZ-SC(2) 2,558.55 26.95 89.74 2,449.89 2,302.39 180.34 491.82 5,929,908.37 1,621,569.69 0.23 -301.49 MWD+IFR-AK-CAZ-SC(2) 2,627.01 27.67 89.48 2,510.71 2,363.21 180.56 523.23 5,929,908.50 1,621,601.09 1.07 -309.83 MWD+IFR-AK-CAZ-SC(2) 2,688.00 28.50 88.03 2,564.52 2,417.02 181.19 551.93 5,929,909.06 1,621,629.79 1.76 -317.86 MWD+IFR-AV - NOT an Survey 10 3/4"x 13-1/2 2,725.17 29.01 87.18 2,597.11 2,449.61 181.93 569.80 5,929,909.76 1,621,647.66 1.76 -323.21 MWD+IFR-AK-CAZ-SC(3) 2,816.64 28.66 86.99 2,677.24 2,529.74 184.18 613.86 5,929,911.89 1,621,691.72 0.40 -336.78 MWD+IFR-AK-CAZ-SC(3) 2,864.99 28.61 86.53 2,719.68 2,572.18 185.49 636.99 5,929,913.14 1,621,714.85 0.47 -344.03 MWD+IFR-AK-CAZ-SC(3) 2,909.92 28.71 85.72 2,759.10 2,611.60 186.94 658.49 5,929,914.54 1,621,736.35 0.89 -351.00 MWD+IFR-AK-CAZ-SC(3) 3,004.46 28.58 86.65 2,842.07 2,694.57 189.96 703.71 5,929,917.44 1,621,781.57 0.49 -365.62 MWD+IFR-AK-CAZ-SC(3) 3,099.67 28.49 85.34 2,925.72 2,778.22 193.14 749.08 5,929,920.50 1,621,826.94 0.66 -380.43 MWD+IFR-AK-CAZ-SC(3) 3,194.74 28.21 84.10 3,009.38 2,861.88 197.29 794.03 5,929,924.54 1,621,871.90 0.69 -396.07 MWD+IFR-AK-CAZ-SC(3) 3,289.77 28.47 83.37 3,093.02 2,945.52 202.21 838.87 5,929,929.35 1,621,916.75 0.46 -412.44 MWD+IFR-AK-CAZ-SC(3) 3,378.65 28.38 82.95 3,171.19 3,023.69 207.25 880.87 5,929,934.28 1,621,958.77 0.25 -428.17 MWD+IFR-AK-CAZ-SC(3) 3,471.79 28.42 84.19 3,253.12 3,105.62 212.21 924.89 5,929,939.12 1,622,002.79 0.63 -444.36 MWD+IFR-AK-CAZ-SC(3) 3,566.57 28.45 85.54 3,336.47 3,188.97 216.25 969.84 5,929,943.05 1,622,047.75 0.68 -459.89 MWD+IFR-AK-CAZ-SC(3) 3,657.96 28.58 85.71 3,416.77 3,269.27 219.58 1,013.34 5,929,946.26 1,622,091.25 0.17 -474.37 MWD+IFR-AK-CAZ-SC(3) 3,751.66 28.48 87.25 3,499.09 3,351.59 222.33 1,058.01 5,929,948.90 1,622,135.92 0.79 -488.58 MWD+IFR-AK-CAZ-SC(3) 3,843.69 28.54 88.26 3,579.96 3,432.46 224.05 1,101.90 5,929,950.51 1,622,179.81 0.53 -501.60 MWD+IFR-AK-CAZ-SC(3) 3,936.51 28.60 87.63 3,661.48 3,513.98 225.64 1,146.26 5,929,951.98 1,622,224.17 0.33 -514.62 MWD+IFR-AK-CAZ-SC(3) 4,029.03 28.51 86.43 3,742.75 3,595.25 227.93 1,190.42 5,929,954.16 1,622,268.33 0.63 -528.27 MWD+IFR-AK-CAZ-SC(3) 9/24/2015 2:44:44PM Page 3 COMPASS 5000.1 Build 74 • • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-10 Project: Kuparuk River Unit TVD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Site: Kuparuk 2S Pad MD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Well: 2S-10 North Reference: True Wellbore: 2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,123.62 28.53 87.35 3,825.86 3,678.36 230.38 1,235.52 5,929,956.50 1,622,313.43 0.46 -542.30 MWD+IFR-AK-CAZ-SC(3) 4,217.11 28.59 87.17 3,907.97 3,760.47 232.51 1,280.16 5,929,958.52 1,622,358.08 0.11 -555.92 MWD+IFR-AK-CAZ-SC(3) 4,310.04 28.60 88.34 3,989.57 3,842.07 234.26 1,324.60 5,929,960.15 1,622,402.52 0.60 -569.11 MWD+IFR-AK-CAZ-SC(3) 4,404.28 28.51 89.38 4,072.35 3,924.85 235.15 1,369.64 5,929,960.93 1,622,447.55 0.54 -581.63 MWD+IFR-AK-CAZ-SC(3) 4,495.10 28.46 89.55 4,152.17 4,004.67 235.56 1,412.95 5,929,961.22 1,622,490.86 0.10 -593.23 MWD+IFR-AK-CAZ-SC(3) 4,590.23 28.35 88.97 4,235.85 4,088.35 236.14 1,458.20 5,929,961.69 1,622,536.11 0.31 -605.51 MWD+IFR-AK-CAZ-SC(3) 4,682.03 28.23 89.55 4,316.68 4,169.18 236.70 1,501.70 5,929,962.14 1,622,579.61 0.33 -617.31 MWD+IFR-AK-CAZ-SC(3) 4,776.69 28.21 94.78 4,400.11 4,252.61 235.02 1,546.39 5,929,960.34 1,622,624.29 2.61 -627.24 MWD+IFR-AK-CAZ-SC(3) 4,869.45 28.69 99.99 4,481.68 4,334.18 229.33 1,590.18 5,929,954.53 1,622,668.05 2.72 -633.08 MWD+IFR-AK-CAZ-SC(3) 4,961.45 27.81 106.66 4,562.74 4,415.24 219.34 1,632.50 5,929,944.44 1,622,710.34 3.56 -634.39 MWD+IFR-AK-CAZ-SC(3) 5,055.86 26.77 113.98 4,646.66 4,499.16 204.38 1,673.03 5,929,929.38 1,622,750.84 3.72 -630.43 MWD+IFR-AK-CAZ-SC(3) 5,149.51 28.34 121.09 4,729.71 4,582.21 184.32 1,711.35 5,929,909.23 1,622,789.10 3.89 -620.97 MWD+IFR-AK-CAZ-SC(3) 5,242.84 29.66 127.18 4,811.35 4,663.85 158.92 1,748.73 5,929,883.73 1,622,826.41 3.46 -606.11 MWD+IFR-AK-CAZ-SC(3) 5,335.66 29.54 130.70 4,892.07 4,744.57 130.12 1,784.38 5,929,854.84 1,622,861.98 1.88 -587.52 MWD+IFR-AK-CAZSC(3) 5,426.94 29.94 133.79 4,971.33 4,823.83 99.68 1,817.88 5,929,824.32 1,622,895.40 1.74 -566.79 MWD+IFR-AK-CAZ-SC(3) 5,519.21 30.13 138.65 5,051.22 4,903.72 66.36 1,849.81 5,929,790.92 1,622,927.24 2.64 -542.86 MWD+IFR-AK-CAZ-SC(3) 5,611.31 31.24 142.26 5,130.43 4,982.93 30.11 1,879.70 5,929,754.60 1,622,957.04 2.33 -515.59 MWD+IFR-AK-CAZ-SC(3) 5,703.86 32.97 146.14 5,208.83 5,061.33 -9.78 1,908.43 5,929,714.63 1,622,985.66 2.91 -484.49 MWD+IFR-AK-CAZ-SC(3) 5,798.71 34.68 151.60 5,287.64 5,140.14 -54.97 1,935.65 5,929,669.39 1,623,012.76 3.68 -447.89 MWD+IFR-AK-CAZ-SC(3) 5,892.26 36.97 156.04 5,363.50 5,216.00 -104.10 1,959.74 5,929,620.20 1,623,036.72 3.70 -406.67 MWD+IFR-AK-CAZ-SC(3) 5,985.23 39.27 160.70 5,436.66 5,289.16 -157.43 1,980.83 5,929,566.81 1,623,057.67 3.96 -360.61 MWD+IFR-AK-CAZ-SC(3) 6,078.55 40.79 164.67 5,508.12 5,360.62 -214.72 1,998.65 5,929,509.49 1,623,075.35 3.18 -309.89 MWD+IFR-AK-CAZ-SC(3) 6,173.63 43.21 167.37 5,578.78 5,431.28 -276.45 2,013.98 5,929,447.73 1,623,090.52 3.18 -254.23 MWD+IFR-AK-CAZ-SC(3) 6,265.92 45.61 168.60 5,644.70 5,497.20 -339.61 2,027.41 5,929,384.53 1,623,103.78 2.76 -196.69 MWD+IFR-AK-CAZ-SC(3) 6,357.04 48.09 169.16 5,707.02 5,559.52 -404.84 2,040.22 5,929,319.28 1,623,116.43 2.76 -137.01 MWD+IFR-AK-CAZ-SC(3) 6,451.06 50.46 169.97 5,768.35 5,620.85 -474.91 2,053.12 5,929,249.19 1,623,129.14 2.60 -72.66 MWD+IFR-AK-CAZ-SC(3) 6,544.59 53.52 172.52 5,825.95 5,678.45 -547.73 2,064.30 5,929,176.35 1,623,140.14 3.91 -5.22 MWD+IFR-AK-CAZ-SC(3) 6,638.03 56.27 175.01 5,879.68 5,732.18 -623.70 2,072.57 5,929,100.36 1,623,148.21 3.66 66.03 MWD+IFR-AK-CAZ-SC(3) 6,731.17 57.89 176.93 5,930.30 5,782.80 -701.69 2,078.05 5,929,022.37 1,623,153.49 2.45 139.94 MWD+IFR-AK-CAZ-SC(3) 6,825.34 59.14 179.50 5,979.49 5,831.99 -781.94 2,080.54 5,928,942.11 1,623,155.78 2.68 216.82 MWD+IFR-AK-CAZ-SC(3) 6,919.12 60.23 180.98 6,026.83 5,879.33 -862.90 2,080.20 5,928,861.17 1,623,155.22 1.79 295.10 MWD+IFR-AK-CAZSC(3) 7,011.64 61.40 182.28 6,071.95 5,924.45 -943.63 2,077.90 5,928,780.45 1,623,152.72 1.76 373.68 MWD+IFR-AK-CAZ-SC(3) 7,106.70 64.15 184.57 6,115.44 5,967.94 -1,027.99 2,072.83 5,928,696.11 1,623,147.43 3.60 456.48 MWD+IFR-AK-CAZ-SC(3) 7,200.31 66.80 186.14 6,154.29 6,006.79 -1,112.77 2,064.87 5,928,611.36 1,623,139.25 3.22 540.43 MW D+I FR-AK-CAZ-SC(3) 7,293.03 70.01 187.65 6,188.41 6,040.91 -1,198.35 2,054.51 5,928,525.82 1,623,128.68 3.78 625.77 MWD+IFR-AK-CAZ-SC(3) 7,386.50 73.19 189.59 6,217.91 6,070.41 -1,286.02 2,041.20 5,928,438.19 1,623,115.15 3.93 713.90 MWD+IFR-AK-CAZ-SC(3) 7,429.08 74.76 190.75 6,229.67 6,082.17 -1,326.30 2,033.97 5,928,397.93 1,623,107.82 4.52 754.67 MWD+IFR-AK-CAZ-SC(3) 7,492.00 75.95 189.28 6,245.58 6,098.08 -1,386.24 2,023.39 5,928,338.02 1,623,097.08 2.95 815.32 MWD+IFR-A`r'A7 Qr I41 NOT an Actual Survey 7-518"x 9-7/8" 7,519.07 76.47 188.65 6,252.03 6,104.53 -1,412.21 2,019.29 5,928,312.07 1,623,092.92 2.95 841.46 MWD+IFR-AK-CAZ-SC(4) 9/24/2015 2:44:44PM Page 4 COMPASS 5000.1 Build 74 • • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-10 Project: Kuparuk River Unit TVD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Site: Kuparuk 2S Pad MD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Well: 2S-10 North Reference: True Wellbore: 2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,551.02 76.99 190.96 6,259.36 6,111.86 -1,442.85 2,014.00 5,928,281.44 1,623,087.55 7.22 872.43 MWD+IFR-AK-CAZ-SC(4) 7,644.10 79.56 188.84 6,278.28 6,130.78 -1,532.62 1,998.34 5,928,191.72 1,623,071.66 3.55 963.19 MWD+IFR-AK-CAZ-SC(4) 7,741.66 81.29 193.17 6,294.51 6,147.01 -1,627.02 1,979.97 5,928,097.38 1,623,053.05 4.72 1,059.13 MWD+IFR-AK-CAZ-SC(4) 7,836.02 82.12 193.31 6,308.13 6,160.63 -1,717.91 1,958.59 5,928,006.55 1,623,031.43 0.89 1,152.46 MWD+IFR-AK-CAZ-SC(4) 7,929.79 83.68 196.44 6,319.72 6,172.22 -1,807.83 1,934.70 5,927,916.70 1,623,007.32 3.71 1,245.49 MWD+IFR-AK-CAZ-SC(4) 8,024.10 85.16 198.22 6,328.89 6,181.39 -1,897.43 1,906.74 5,927,827.19 1,622,979.13 2.45 1,339.27 MWD+IFR-AK-CAZSC(4) 8,118.25 84.92 198.71 6,337.03 6,189.53 -1,986.40 1,877.03 5,927,738.31 1,622,949.20 0.58 1,432.90 MWD+IFR-AK-CAZSC(4) 8,214.05 87.87 197.66 6,343.05 6,195.55 -2,077.22 1,847.20 5,927,647.57 1,622,919.14 3.27 1,528.35 MWD+IFR-AK-CAZ-SC(4) 8,308.48 89.62 196.11 6,345.12 6,197.62 -2,167.55 1,819.78 5,927,557.32 1,622,891.49 2.48 1,622.70 MWD+IFR-AK-CAZ-SC(4) 8,402.76 89.04 196.58 6,346.22 6,198.72 -2,258.01 1,793.25 5,927,466.93 1,622,864.73 0.79 1,716.95 MWD+IFR-AK-CAZ-SC(4) 8,496.37 89.28 197.01 6,347.60 6,200.10 -2,347.62 1,766.20 5,927,377.40 1,622,837.46 0.53 1,810.50 MWD+IFR-AK-CAZ-SC(4) 8,591.38 90.69 196.27 6,347.62 6,200.12 -2,438.65 1,739.00 5,927,286.45 1,622,810.02 1.68 1,905.47 MWD+IFR-AK-CAZ-SC(4) 8,686.38 90.69 196.85 6,346.48 6,198.98 -2,529.70 1,711.92 5,927,195.48 1,622,782.72 0.61 2,000.43 MWD+IFR-AK-CAZ-SC(4) 8,780.66 90.82 196.21 6,345.23 6,197.73 -2,620.08 1,685.10 5,927,105.18 1,622,755.67 0.69 2,094.66 MWD+IFR-AK-CAZ-SC(4) 8,874.49 90.45 195.66 6,344.19 6,196.69 -2,710.30 1,659.34 5,927,015.04 1,622,729.68 0.71 2,188.48 MWD+IFR-AK-CAZ-SC(4) 8,969.32 90.10 194.75 6,343.74 6,196.24 -2,801.80 1,634.47 5,926,923.60 1,622,704.58 1.03 2,283.30 MWD+IFR-AK-CAZ-SC(4) 9,064.96 90.41 194.56 6,343.31 6,195.81 -2,894.33 1,610.27 5,926,831.15 1,622,680.14 0.38 2,378.94 MWD+IFR-AK-CAZ-SC(4) 9,159.93 89.62 194.95 6,343.29 6,195.79 -2,986.17 1,586.09 5,926,739.38 1,622,655.72 0.93 2,473.91 MWD+IFR-AK-CAZ-SC(4) 9,252.61 88.70 196.17 6,344.65 6,197.15 -3,075.44 1,561.23 5,926,650.18 1,622,630.64 1.65 2,566.57 MWD+IFR-AK-CAZ-SC(4) 9,348.40 87.84 197.16 6,347.54 6,200.04 -3,167.16 1,533.77 5,926,558.54 1,622,602.95 1.37 2,662.27 MWD+IFR-AK-CAZ-SC(4) 9,443.16 86.71 198.40 6,352.04 6,204.54 -3,257.29 1,504.87 5,926,468.49 1,622,573.82 1.77 2,756.81 MWD+IFR-AK-CAZ-SC(4) 9,536.45 87.36 198.72 6,356.87 6,209.37 -3,345.61 1,475.22 5,926,380.26 1,622,543.94 0.78 2,849.80 MWD+IFR-AK-CAZ-SC(4) 9,630.68 89.14 197.21 6,359.75 6,212.25 -3,435.20 1,446.17 5,926,290.76 1,622,514.67 2.48 2,943.85 MWD+IFR-AK-CAZ-SC(4) 9,725.08 88.77 196.00 6,361.47 6,213.97 -3,525.64 1,419.20 5,926,200.39 1,622,487.47 1.34 3,038.20 MWD+IFR-AK-CAZ-SC(4) 9,819.22 89.11 194.88 6,363.21 6,215.71 -3,616.37 1,394.14 5,926,109.74 1,622,462.18 1.24 3,132.32 MWD+IFR-AK-CAZ-SC(4) 9,913.93 90.03 193.93 6,363.92 6,216.42 -3,708.10 1,370.58 5,926,018.08 1,622,438.39 1.40 3,227.02 MWD+IFR-AK-CAZ-SC(4) 10,008.07 90.31 192.73 6,363.64 6,216.14 -3,799.70 1,348.87 5,925,926.54 1,622,416.45 1.31 3,321.11 MWD+IFR-AK-CAZ-SC(4) 10,103.19 90.72 192.81 6,362.79 6,215.29 -3,892.46 1,327.85 5,925,833.84 1,622,395.19 0.44 3,416.16 MWD+IFR-AK-CAZ-SC(4) 10,196.95 90.72 192.38 6,361.61 6,214.11 -3,983.96 1,307.41 5,925,742.41 1,622,374.52 0.46 3,509.83 MWD+IFR-AK-CAZ-SC(4) 10,292.58 90.82 190.65 6,360.32 6,212.82 -4,077.65 1,288.32 5,925,648.77 1,622,355.19 1.81 3,605.27 MWD+IFR-AK-CAZ-SC(4) 10,386.51 90.41 188.75 6,359.32 6,211.82 -4,170.23 1,272.49 5,925,556.25 1,622,339.13 2.07 3,698.79 MWD+IFR-AK-CAZ-SC(4) 10,481.73 90.17 190.15 6,358.83 6,211.33 -4,264.15 1,256.86 5,925,462.37 1,622,323.26 1.49 3,793.56 MWD+IFR-AK-CAZ-SC(4) 10,576.55 90.31 190.20 6,358.44 6,210.94 -4,357.48 1,240.11 5,925,369.10 1,622,306.27 0.16 3,888.04 MWD+IFR-AK-CAZ-SC(4) 10,670.99 90.58 191.18 6,357.70 6,210.20 -4,450.28 1,222.59 5,925,276.35 1,622,288.52 1.08 3,982.21 MWD+IFR-AK-CAZ-SC(4) 10,765.27 90.55 192.16 6,356.77 6,209.27 -4,542.60 1,203.52 5,925,184.09 1,622,269.21 1.04 4,076.32 MWD+IFR-AK-CAZ-SC(4) 10,858.48 89.83 194.08 6,356.46 6,208.96 -4,633.38 1,182.37 5,925,093.38 1,622,247.83 2.20 4,169.48 MWD+IFR-AK-CAZ-SC(4) 10,954.19 90.24 195.93 6,356.41 6,208.91 -4,725.82 1,157.59 5,925,001.01 1,622,222.81 1.98 4,265.18 MWD+IFR-AK-CAZ-SC(4) 11,050.22 89.25 196.73 6,356.83 6,209.33 -4,817.97 1,130.59 5,924,908.93 1,622,195.58 1.33 4,361.18 MWD+IFR-AK-CAZ-SC(4) 11,144.66 85.50 197.93 6,361.16 6,213.66 -4,908.01 1,102.49 5,924,818.97 1,622,167.26 4.17 4,455.43 MWD+IFR-AK-CAZ-SC(4) 11,238.25 86.77 197.87 6,367.47 6,219.97 -4,996.87 1,073.79 5,924,730.20 1,622,138.33 1.36 4,548.68 MWD+IFR-AK-CAZ-SC(4) 9/24/2015 2:44:44PM Page 5 COMPASS 5000.1 Build 74 • • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-10 Project: Kuparuk River Unit TVD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Site: Kuparuk 2S Pad MD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Well: 2S-10 North Reference: True Wellbore: 2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 11,333.47 88.83 196.92 6,371.12 6,223.62 -5,087.66 1,045.35 5,924,639.49 1,622,109.66 2.38 4,643.75 MWD+IFR-AK-CAZ-SC(4) 11,428.31 88.94 196.37 6,372.97 6,225.47 -5,178.51 1,018.19 5,924,548.72 1,622,082.27 0.59 4,738.53 MWD+IFR-AK-CAZ-SC(4) 11,523.26 90.24 195.99 6,373.65 6,226.15 -5,269.69 991.73 5,924,457.61 1,622,055.58 1.43 4,833.45 MWD+IFR-AK-CAZ-SC(4) 11,617.81 88.42 195.85 6,374.75 6,227.25 -5,360.61 965.80 5,924,366.78 1,622,029.42 1.93 4,927.98 MWD+IFR-AK-CAZ-SC(4) 11,712.45 88.25 194.88 6,377.50 6,230.00 -5,451.82 940.74 5,924,275.63 1,622,004.12 1.04 5,022.58 MWD+IFR-AK-CAZ-SC(4) 11,807.67 90.93 193.47 6,378.18 6,230.68 -5,544.13 917.42 5,924,183.39 1,621,980.57 3.18 5,117.77 MWD+IFR-AK-CAZ-SC(4) 11,902.78 90.58 194.67 6,376.93 6,229.43 -5,636.38 894.30 5,924,091.22 1,621,957.22 1.31 5,212.86 MWD+IFR-AK-CAZ-SC(4) 11,997.99 90.21 195.48 6,376.27 6,228.77 -5,728.31 869.54 5,923,999.36 1,621,932.23 0.94 5,308.07 MWD+IFR-AK-CAZ-SC(4) 12,092.97 90.65 195.52 6,375.56 6,228.06 -5,819.83 844.16 5,923,907.91 1,621,906.61 0.47 5,403.04 MWD+IFR-AK-CAZ-SC(4) 12,187.12 90.17 195.41 6,374.89 6,227.39 -5,910.57 819.05 5,923,817.25 1,621,881.28 0.52 5,497.19 MWD+IFR-AK-CAZ-SC(4) 12,281.45 90.45 194.32 6,374.38 6,226.88 -6,001.74 794.86 5,923,726.15 1,621,856.85 1.19 5,591.51 MWD+IFR-AK-CAZ-SC(4) 12,375.72 90.00 196.52 6,374.01 6,226.51 -6,092.61 769.79 5,923,635.35 1,621,831.55 2.38 5,685.77 MWD+IFR-AK-CAZ-SC(4) 12,470.40 88.18 193.33 6,375.51 6,228.01 -6,184.07 745.41 5,923,543.96 1,621,806.94 3.88 5,780.43 MWD+IFR-AK-CAZ-SC(4) 12,564.81 86.47 192.24 6,379.92 6,232.42 -6,276.03 724.54 5,923,452.06 1,621,785.84 2.15 5,874.66 MWD+IFR-AK-CAZ-SC(4) 12,660.18 87.56 191.41 6,384.88 6,237.38 -6,369.25 705.03 5,923,358.90 1,621,766.09 1.44 5,969.75 MWD+IFR-AK-CAZ-SC(4) 12,755.53 87.15 193.11 6,389.28 6,241.78 -6,462.32 684.80 5,923,265.89 1,621,745.63 1.83 6,064.88 MWD+IFR-AK-CAZ-SC(4) 12,850.38 87.36 193.44 6,393.83 6,246.33 -6,554.53 663.05 5,923,173.75 1,621,723.64 0.41 6,159.58 MWD+IFR-AK-CAZ-SC(4) 12,944.88 88.83 192.50 6,396.97 6,249.47 -6,646.57 641.85 5,923,081.78 1,621,702.21 1.85 6,253.97 MWD+IFR-AK-CAZ-SC(4) 13,039.56 88.63 194.11 6,399.07 6,251.57 -6,738.68 620.07 5,922,989.73 1,621,680.19 1.71 6,348.58 MWD+IFR-AK-CAZ-SC(4) 13,133.08 90.00 195.43 6,400.18 6,252.68 -6,829.10 596.23 5,922,899.38 1,621,656.12 2.03 6,442.09 MWD+IFR-AK-CAZ-SC(4) 13,225.82 89.66 197.15 6,400.46 6,252.96 -6,918.11 570.22 5,922,810.44 1,621,629.88 1.89 6,534.80 MWD+IFR-AK-CAZ-SC(4) 13,320.40 89.93 198.83 6,400.80 6,253.30 -7,008.06 541.01 5,922,720.58 1,621,600.45 1.80 6,629.25 MWD+IFR-AK-CAZ-SC(4) 13,414.08 89.66 199.43 6,401.13 6,253.63 -7,096.57 510.31 5,922,632.16 1,621,569.52 0.70 6,722.68 MWD+IFR-AK-CAZ-SC(4) 13,510.10 88.87 200.31 6,402.36 6,254.86 -7,186.86 477.67 5,922,541.96 1,621,536.66 1.23 6,818.35 MWD+IFR-AK-CAZ-SC(4) 13,602.84 89.21 201.55 6,403.92 6,256.42 -7,273.47 444.55 5,922,455.44 1,621,503.32 1.39 6,910.58 MWD+IFR-AK-CAZ-SC(4) 13,697.55 89.73 200.10 6,404.79 6,257.29 -7,361.99 410.88 5,922,367.02 1,621,469.43 1.63 7,004.79 MWD+IFR-AK-CAZ-SC(4) 13,786.78 90.00 197.85 6,405.01 6,257.51 -7,446.36 381.87 5,922,282.73 1,621,440.20 2.54 7,093.80 MWD+IFR-AK-CAZ-SC(4) 13,882.43 91.54 195.90 6,403.72 6,256.22 -7,537.88 354.11 5,922,191.30 1,621,412.21 2.60 7,189.38 MWD+IFR-AK-CAZ-SC(4) 13,980.69 92.13 195.38 6,400.57 6,253.07 -7,632.45 327.63 5,922,096.80 1,621,385.50 0.80 7,287.58 MWD+IFR-AK-CAZ-SC(4) 14,076.36 90.27 196.24 6,398.57 6,251.07 -7,724.48 301.57 5,922,004.85 1,621,359.20 2.14 7,383.22 MWD+IFR-AK-CAZ-SC(4) 14,170.95 88.80 197.85 6,399.34 6,251.84 -7,814.90 273.85 5,921,914.50 1,621,331.25 2.30 7,477.74 MWD+IFR-AK-CAZ-SC(4) 14,265.96 88.49 196.51 6,401.58 6,254.08 -7,905.65 245.80 5,921,823.84 1,621,302.97 1.45 7,572.65 MWD+IFR-AK-CAZ-SC(4) 14,361.22 87.08 196.55 6,405.27 6,257.77 -7,996.90 218.71 5,921,732.67 1,621,275.65 1.48 7,667.80 MWD+IFR-AK-CAZ-SC(4) 14,455.93 87.29 195.88 6,409.92 6,262.42 -8,087.73 192.30 5,921,641.91 1,621,249.01 0.74 7,762.38 MWD+IFR-AK-CAZ-SC(4) 14,549.80 87.91 194.56 6,413.85 6,266.35 -8,178.23 167.68 5,921,551.49 1,621,224.16 1.55 7,856.16 MWD+IFR-AK-CAZ-SC(4) 14,644.65 86.05 194.55 6,418.85 6,271.35 -8,269.90 143.88 5,921,459.89 1,621,200.12 1.96 7,950.87 MWD+IFR-AK-CAZ-SC(4) 14,739.72 85.64 193.74 6,425.73 6,278.23 -8,361.85 120.70 5,921,368.01 1,621,176.72 0.95 8,045.68 MWD+IFR-AK-CAZ-SC(4) 14,834.45 88.80 192.11 6,430.33 6,282.83 -8,454.05 99.55 5,921,275.87 1,621,155.33 3.75 8,140.22 MWD+IFR-AK-CAZ-SC(4) 14,885.00 90.73 192.11 6,430.53 6,283.03 -8,503.48 88.94 5,921,226.48 1,621,144.60 3.82 8,190.71 BLIND(5) NOT an Actual Survey 4 1/2"x 6-3/4" 9/24/2015 2:44:44PM Page 6 COMPASS 5000.1 Build 74 • 1110 Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-10 Project: Kuparuk River Unit TVD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Site: Kuparuk 2S Pad MD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Well: 2S-10 North Reference: True Wellbore: 2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 14,896.00 91.15 192.11 6,430.35 6,282.85 -8,514.23 86.63 5,921,215.73 1,621,142.26 3.82 8,201.69 Projection to TD Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. ❑ Yes ❑ No I have checked to the best of my ability that the following data Is correct: L] Surface Coordinates n Declination & Convergence (] GRS Survey Corrections p Survey Tool Codesch-Ltrtrant Cunt Vincent SLB DE: Osara mar ° Jake Voss 'yn' "� do MAN/sense rsa..-47.1,u.a�w wnw,aw.+rvesrcmiwn Client Representative: Dale xrLIG21. 111 MSC Date: 24-Sep2015 9/24/2015 2:44:44PM Page 7 COMPASS 5000.1 Build 74 2(5- 1t-0 2(oZ9z , , FINAL ., NADConversion RECEIVED Kuparuk River Unit Kuparuk 2S Pad JAN 2 5 2016 2S-10 AOGCC Definitive Survey Report 24 September, 2015 NAD 27 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-10 Project: Kuparuk River Unit TVD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Site: Kuparuk 2S Pad MD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Well: 2S-10 North Reference: True Wellbore: 2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10 Database: OAKEDMP2 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 2S-10 Well Position +N/-S 0.00 usft Northing: 5,929,979.72 usfl Latitude: 70°13'11.496 N +El-W 0.00 usft Easting: 481,044.13 usfl Longitude: 150°9'10.528 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 120.00 usft Wellbore 2S-10 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 9/5/2015 18.60 80.87 57,489 Design 2S-10 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.50 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 27.50 0.00 0.00 195.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 93.90 462.50 2S-10 Srvy#1 Gyro(2S-10) GYD-GC-MS Gyrodata gyrocompassing m/s 9/4/2015 12:02 506.90 2,627.01 25-10 Srvy#2 MWD+IFR-AK-CAZ-SC(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/4/2015 12:17 2,725.17 7,429.08 2S-10 Srvy#3 MWD+IFR-AK-CAZ-SC(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/4/2015 12:31 7,519.07 14,834.45 2S-10 Srvy#4 MWD+IFR-AK-CAZ-SC(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/8/2015 11:3c, 14,896.00 14,896.00 2S-10 Srvy#5-Projection to TD(2S-10)BLIND Blind drilling 9/24/2015 2:4 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 27.50 0.00 0.00 27.50 -120.00 0.00 0.00 5,929,979.72 481,044.13 0.00 0.00 UNDEFINED 94.40 0.45 73.93 94.40 -53.10 0.07 0.25 5,929,979.79 481,044.38 0.67 -0.14 GYD-GC-MS(1) 107.50 0.46 73.22 107.50 -40.00 0.10 0.35 5,929,979.82 481,044.48 0.11 -0.19 GYD-GC-MS(11 NOT an Actual Survey 16"x42" 186.50 0.54 69.67 186.50 39.00 0.32 1.01 5,929,980.04 481,045.14 0.11 -0.57 GYD-GC-MS(1) 278.70 0.58 73.72 278.69 131.19 0.61 1.86 5,929,980.32 481,045.99 0.06 -1.07 GYD-GC-MS(1) 370.80 0.73 77.64 370.79 223.29 0.86 2.88 5,929,980.57 481,047.01 0.17 -1.58 GYD-GC-MS(1) 506.90 0.78 74.23 506.87 359.37 1.30 4.62 5,929,981.01 481,048.75 0.05 -2.45 MWD+IFR-AK-CAZ-SC(2) 598.44 0.51 89.00 598.41 450.91 1.48 5.63 5,929,981.18 481,049.76 0.34 -2.88 MWD+IFR-AK-CAZ-SC(2) 696.00 1.69 54.94 695.95 548.45 2.31 7.24 5,929,982.01 481,051.38 1.33 -4.10 MWD+IFR-AK-CAZ-SC(2) 788.22 2.43 45.82 788.11 640.61 4.45 9.76 5,929,984.15 481,053.90 0.88 -6.83 MWD+IFR-AK-CAZ-SC(2) 9/24/2015 3:14:03PM Page 2 COMPASS 5000.1 Build 74 • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-10 Project: Kuparuk River Unit TVD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Site: Kuparuk 2S Pad MD Reference: Actual:120+27.50 @ 147.5ousft(Doyon-141) Well: 2S-10 North Reference: True Wellbore: 2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 880.07 3.57 31.30 879.83 732.33 8.25 12.64 5,929,987.94 481,056.79 1.48 -11.24 MWD+IFR-AK-CAZ-SC(2) 972.37 5.71 29.21 971.82 824.32 14.72 16.37 5,929,994.40 481,060.54 2.33 -18.45 MWD+IFR-AK-CAZ-SC(2) 1,065.00 7.70 32.99 1,063.82 916.32 23.95 22.00 5,930,003.61 481,066.19 2.20 -28.82 MWD+IFR-AK-CAZ-SC(2) 1,115.38 9.02 32.68 1,113.66 966.16 30.10 25.97 5,930,009.75 481,070.17 2.62 -35.80 MWD+IFR-AK-CAZ-SC(2) 1,158.68 10.08 31.52 1,156.36 1,008.86 36.19 29.78 5,930,015.83 481,074.00 2.49 -42.66 MWD+IFR-AK-CAZ-SC(2) 1,216.08 11.15 32.19 1,212.78 1,065.28 45.17 35.37 5,930,024.79 481,079.61 1.88 -52.78 MWD+IFR-AK-CAZ-SC(2) 1,251.55 12.84 31.28 1,247.47 1,099.97 51.44 39.24 5,930,031.05 481,083.50 4.79 -59.84 MWD+IFR-AK-CAZ-SC(2) 1,345.39 14.91 29.17 1,338.57 1,191.07 70.89 50.54 5,930,050.48 481,094.84 2.27 -81.56 MWD+IFR-AK-CAZ-SC(2) 1,438.07 15.95 33.62 1,427.91 1,280.41 91.91 63.40 5,930,071.46 481,107.76 1.70 -105.19 MWD+IFR-AK-CAZ-SC(2) 1,531.92 19.06 42.90 1,517.42 1,369.92 113.88 80.98 5,930,093.39 481,125.39 4.44 -130.96 MWD+IFR-AK-CAZ-SC(2) 1,626.66 20.25 56.47 1,606.69 1,459.19 134.28 105.19 5,930,113.73 481,149.65 4.97 -156.93 MWD+IFR-AK-CAZ-SC(2) 1,719.09 20.73 63.37 1,693.28 1,545.78 150.45 133.15 5,930,129.82 481,177.65 2.66 -179.79 MWD+IFR-AK-CAZ-SC(2) 1,814.62 22.50 71.62 1,782.11 1,634.61 163.80 165.62 5,930,143.09 481,210.15 3.68 -201.08 MWD+IFR-AK-CAZ-SC(2) 1,909.13 24.42 81.56 1,868.84 1,721.34 172.37 202.13 5,930,151.57 481,246.67 4.65 -218.81 MWD+IFR-AK-CAZ-SC(2) 2,002.26 25.90 86.94 1,953.14 1,805.64 176.29 241.49 5,930,155.38 481,286.04 2.92 -232.78 MWD+IFR-AK-CAZ-SC(2) 2,094.67 26.33 88.82 2,036.12 1,888.62 177.78 282.13 5,930,156.78 481,326.68 1.01 -244.75 MWD+IFR-AK-CAZ-SC(2) 2,187.42 26.80 88.37 2,119.08 1,971.58 178.80 323.60 5,930,157.69 481,368.14 0.55 -256.46 MWD+IFR-AK-CAZ-SC(2) 2,280.73 26.91 89.57 2,202.32 2,054.82 179.56 365.74 5,930,158.34 481,410.28 0.59 -268.10 MWD+IFR-AK-CAZ-SC(2) 2,373.10 27.01 89.98 2,284.66 2,137.16 179.72 407.62 5,930,158.40 481,452.16 0.23 -279.10 MWD+IFR-AK-CAZ-SC(2) 2,465.75 27.03 89.30 2,367.19 2,219.69 179.99 449.71 5,930,158.56 481,494.24 0.33 -290.25 MWD+IFR-AK-CAZ-SC(2) 2,558.55 26.95 89.74 2,449.89 2,302.39 180.34 491.82 5,930,158.81 481,536.35 0.23 -301.49 MWD+IFR-AK-CAZ-SC(2) 2,627.01 27.67 89.48 2,510.71 2,363.21 180.56 523.23 5,930,158.94 481,567.76 1.07 -309.83 MWD+IFR-AK-CAZ-SC(2) 2,688.00 28.50 88.03 2,564.52 2.417.02 181.19 551.93 5,930,159.50 481,596.46 1.76 -317.86 MWD+IFR-4K-(:A7-SC.( 1 10 314"x 13-1/2 NOT an Actual Survey 2,725.17 29.01 87.18 2,597.11 2,449.61 181.93 569.80 5,930,160.20 481,614.33 1.76 -323.21 MWD+IFR-AK-CAZ-SC(3) 2,816.64 28.66 86.99 2,677.24 2,529.74 184.18 613.86 5,930,162.34 481,658.39 0.40 -336.78 MWD+IFR-AK-CAZ-SC(3) 2,864.99 28.61 86.53 2,719.68 2,572.18 185.49 636.99 5,930,163.59 481,681.52 0.47 -344.03 MWD+IFR-AK-CAZ-SC(3) 2,909.92 28.71 85.72 2,759.10 2,611.60 186.94 658.49 5,930,164.99 481,703.02 0.89 -351.00 MWD+IFR-AK-CAZ-SC(3) 3,004.46 28.58 86.65 2,842.07 2,694.57 189.96 703.71 5,930,167.89 481,748.24 0.49 -365.62 MWD+IFR-AK-CAZ-SC(3) 3,099.67 28.49 85.34 2,925.72 2,778.22 193.14 749.08 5,930,170.95 481,793.61 0.66 -380.43 MWD+IFR-AK-CAZ-SC(3) 3,194.74 28.21 84.10 3,009.38 2,861.88 197.29 794.03 5,930,174.99 481,838.57 0.69 -396.07 MWD+IFR-AK-CAZ-SC(3) 3,289.77 28.47 83.37 3,093.02 2,945.52 202.21 838.87 5,930,179.80 481,883.42 0.46 -412.44 MWD+IFR-AK-CAZ-SC(3) 3,378.65 28.38 82.95 3,171.19 3,023.69 207.25 880.87 5,930,184.74 481,925.43 0.25 -428.17 MWD+IFR-AK-CAZ-SC(3) 3,471.79 28.42 84.19 3,253.12 3,105.62 212.21 924.89 5,930,189.59 481,969.46 0.63 -444.36 MWD+IFR-AK-CAZ-SC(3) 3,566.57 28.45 85.54 3,336.47 3,188.97 216.25 969.84 5,930,193.51 482,014.41 0.68 -459.89 MWD+IFR-AK-CAZ-SC(3) 3,657.96 28.58 85.71 3,416.77 3,269.27 219.58 1,013.34 5,930,196.73 482,057.92 0.17 -474.37 MWD+IFR-AK-CAZ-SC(3) 3,751.66 28.48 87.25 3,499.09 3,351.59 222.33 1,058.01 5,930,199.37 482,102.58 0.79 -488.58 MWD+IFR-AK-CAZ-SC(3) 3,843.69 28.54 88.26 3,579.96 3,432.46 224.05 1,101.90 5,930,200.98 482,146.48 0.53 -501.60 MWD+IFR-AK-CAZ-SC(3) 3,936.51 28.60 87.63 3,661.48 3,513.98 225.64 1,146.26 5,930,202.46 482,190.84 0.33 -514.62 MWD+IFR-AK-CAZ-SC(3) 4,029.03 28.51 86.43 3,742.75 3,595.25 227.93 1,190.42 5,930,204.64 482,235.00 0.63 -528.27 MWD+IFR-AK-CAZ-SC(3) 9/24/2015 3:14:03PM Page 3 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-10 Project: Kuparuk River Unit TVD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Site: Kuparuk 2S Pad MD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Well: 2S-10 North Reference: True Wellbore: 2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,123.62 28.53 87.35 3,825.86 3,678.36 230.38 1,235.52 5,930,206.97 482,280.10 0.46 -542.30 MWD+IFR-AK-CAZ-SC(3) 4,217.11 28.59 87.17 3,907.97 3,760.47 232.51 1,280.16 5,930,209.00 482,324.74 0.11 -555.92 MWD+IFR-AK-CAZ-SC(3) 4,310.04 28.60 88.34 3,989.57 3,842.07 234.26 1,324.60 5,930,210.63 482,369.18 0.60 -569.11 MWD+IFR-AK-CAZ-SC(3) 4,404.28 28.51 89.38 4,072.35 3,924.85 235.15 1,369.64 5,930,211.41 482,414.22 0.54 -581.63 MWD+IFR-AK-CAZ-SC(3) 4,495.10 28.46 89.55 4,152.17 4,004.67 235.56 1,412.95 5,930,211.71 482,457.53 0.10 -593.23 MWD+IFR-AK-CAZ-SC(3) 4,590.23 28.35 88.97 4,235.85 4,088.35 236.14 1,458.20 5,930,212.18 482,502.77 0.31 -605.51 MWD+IFR-AK-CAZ-SC(3) 4,682.03 28.23 89.55 4,316.68 4,169.18 236.70 1,501.70 5,930,212.63 482,546.27 0.33 -617.31 MWD+IFR-AK-CAZ-SC(3) 4,776.69 28.21 94.78 4,400.11 4,252.61 235.02 1,546.39 5,930,210.83 482,590.95 2.61 -627.24 MWD+IFR-AK-CAZ-SC(3) 4,869.45 28.69 99.99 4,481.68 4,334.18 229.33 1,590.18 5,930,205.03 482,634.72 2.72 -633.08 MWD+IFR-AK-CAZ-SC(3) 4,961.45 27.81 106.66 4,562.74 4,415.24 219.34 1,632.50 5,930,194.94 482,677.01 3.56 -634.39 MWD+IFR-AK-CAZ-SC(3) 5,055.86 26.77 113.98 4,646.66 4,499.16 204.38 1,673.03 5,930,179.88 482,717.51 3.72 -630.43 MWD+IFR-AK-CAZ-SC(3) 5,149.51 28.34 121.09 4,729.71 4,582.21 184.32 1,711.35 5,930,159.73 482,755.77 3.89 -620.97 MWD+IFR-AK-CAZ-SC(3) 5,242.84 29.66 127.18 4,811.35 4,663.85 158.92 1,748.73 5,930,134.23 482,793.08 3.46 -606.11 MWD+IFR-AK-CAZ-SC(3) 5,335.66 29.54 130.70 4,892.07 4,744.57 130.12 1,784.38 5,930,105.35 482,828.65 1.88 -587.52 MWD+IFR-AK-CAZ-SC(3) 5,426.94 29.94 133.79 4,971.33 4,823.83 99.68 1,817.88 5,930,074.83 482,862.08 1.74 -566.79 MWD+IFR-AK-CAZ-SC(3) 5,519.21 30.13 138.65 5,051.22 4,903.72 66.36 1,849.81 5,930,041.43 482,893.92 2.64 -542.86 MWD+IFR-AK-CAZ-SC(3) 5,611.31 31.24 142.26 5,130.43 4,982.93 30.11 1,879.70 5,930,005.11 482,923.72 2.33 -515.59 MWD+IFR-AK-CAZ-SC(3) 5,703.86 32.97 146.14 5,208.83 5,061.33 -9.78 1,908.43 5,929,965.15 482,952.34 2.91 -484.49 MWD+IFR-AK-CAZ-SC(3) 5,798.71 34.68 151.60 5,287.64 5,140.14 -54.97 1,935.65 5,929,919.90 482,979.44 3.68 -447.89 MWD+IFR-AK-CAZ-SC(3) 5,892.26 36.97 156.04 5,363.50 5,216.00 -104.10 1,959.74 5,929,870.71 483,003.41 3.70 -406.67 MWD+IFR-AK-CAZ-SC(3) 5,985.23 39.27 160.70 5,436.66 5,289.16 -157.43 1,980.83 5,929,817.33 483,024.36 3.96 -360.61 MWD+IFR-AK-CAZ-SC(3) 6,078.55 40.79 164.67 5,508.12 5,360.62 -214.72 1,998.65 5,929,760.00 483,042.04 3.18 -309.89 MWD+IFR-AK-CAZ-SC(3) 6,173.63 43.21 167.37 5,578.78 5,431.28 -276.45 2,013.98 5,929,698.24 483,057.21 3.18 -254.23 MWD+IFR-AK-CAZ-SC(3) 6,265.92 45.61 168.60 5,644.70 5,497.20 -339.61 2,027.41 5,929,635.05 483,070.48 2.76 -196.69 MWD+IFR-AK-CAZ-SC(3) 6,357.04 48.09 169.16 5,707.02 5,559.52 -404.84 2,040.22 5,929,569.80 483,083.13 2.76 -137.01 MWD+IFR-AK-CAZ-SC(3) 6,451.06 50.46 169.97 5,768.35 5,620.85 -474.91 2,053.12 5,929,499.70 483,095.85 2.60 -72.66 MWD+IFR-AK-CAZ-SC(3) 6,544.59 53.52 172.52 5,825.95 5,678.45 -547.73 2,064.30 5,929,426.86 483,106.84 3.91 -5.22 MWD+IFR-AK-CAZ-SC(3) 6,638.03 56.27 175.01 5,879.68 5,732.18 -623.70 2,072.57 5,929,350.87 483,114.92 3.66 66.03 MWD+IFR-AK-CAZ-SC(3) 6,731.17 57.89 176.93 5,930.30 5,782.80 -701.69 2,078.05 5,929,272.89 483,120.21 2.45 139.94 MWD+IFR-AK-CAZ-SC(3) 6,825.34 59.14 179.50 5,979.49 5,831.99 -781.94 2,080.54 5,929,192.63 483,122.50 2.68 216.82 MWD+IFR-AK-CAZ-SC(3) 6,919.12 60.23 180.98 6,026.83 5,879.33 -862.90 2,080.20 5,929,111.69 483,121.95 1.79 295.10 MWD+IFR-AK-CAZ-SC(3) 7,011.64 61.40 182.28 6,071.95 5,924.45 -943.63 2,077.90 5,929,030.97 483,119.44 1.76 373.68 MWD+IFR-AK-CAZ-SC(3) 7,106.70 64.15 184.57 6,115.44 5,967.94 -1,027.99 2,072.83 5,928,946.63 483,114.16 3.60 456.48 MWD+IFR-AK-CAZ-SC(3) 7,200.31 66.80 186.14 6,154.29 6,006.79 -1,112.77 2,064.87 5,928,861.87 483,105.99 3.22 540.43 MWD+I FR-AK-CAZ-SC(3) 7,293.03 70.01 187.65 6,188.41 6,040.91 -1,198.35 2,054.51 5,928,776.34 483,095.41 3.78 625.77 MWD+IFR-AK-CAZ-SC(3) 7,386.50 73.19 189.59 6,217.91 6,070.41 -1,286.02 2,041.20 5,928,688.71 483,081.89 3.93 713.90 MWD+IFR-AK-CAZ-SC(3) 7,429.08 74.76 190.75 6,229.67 6,082.17 -1,326.30 2,033.97 5,928,648.45 483,074.56 4.52 754.67 MWD+IFR-AK-CAZ-SC(3) 7,492.00 75.95 189.28 6,245.58 6,098.08 -1,386.24 2,023.39 5,928,588.54 483,063.83 2.95 815.32 MWD+IFR-Ak-r02-cr lei NOT an Actual Survey 7-5/8"x 9-7/8" 7,519.07 76.47 188.65 6,252.03 6,104.53 -1,412.21 2,019.29 5,928,562.58 483,059.67 2.95 841.46 MWD+IFR-AK-CAZ-SC(4) 9/24/2015 3:14:03PM Page 4 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-10 Project: Kuparuk River Unit TVD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Site: Kuparuk 2S Pad MD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Well: 2S-10 North Reference: True Wellbore: 2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,551.02 76.99 190.96 6,259.36 6,111.86 -1,442.85 2,014.00 5,928,531.96 483,054.30 7.22 872.43 MWD+IFR-AK-CAZ-SC(4) 7,644.10 79.56 188.84 6,278.28 6,130.78 -1,532.62 1,998.34 5,928,442.24 483,038.41 3.55 963.19 MWD+IFR-AK-CAZ-SC(4) 7,741.66 81.29 193.17 6,294.51 6,147.01 -1,627.02 1,979.97 5,928,347.89 483,019.81 4.72 1,059.13 MWD+IFR-AK-CAZ-SC(4) 7,836.02 82.12 193.31 6,308.13 6,160.63 -1,717.91 1,958.59 5,928,257.06 482,998.20 0.89 1,152.46 MWD+IFR-AK-CAZ-SC(4) 7,929.79 83.68 196.44 6,319.72 6,172.22 -1,807.83 1,934.70 5,928,167.22 482,974.09 3.71 1,245.49 MWD+IFR-AK-CAZ-SC(4) 8,024.10 85.16 198.22 6,328.89 6,181.39 -1,897.43 1,906.74 5,928,077.70 482,945.91 2.45 1,339.27 MWD+IFR-AK-CAZ-SC(4) 8,118.25 84.92 198.71 6,337.03 6,189.53 -1,986.40 1,877.03 5,927,988.81 482,915.98 0.58 1,432.90 MWD+IFR-AK-CAZ-SC(4) 8,214.05 87.87 197.66 6,343.05 6,195.55 -2,077.22 1,847.20 5,927,898.07 482,885.92 3.27 1,528.35 MWD+IFR-AK-CAZ-SC(4) 8,308.48 89.62 196.11 6,345.12 6,197.62 -2,167.55 1,819.78 5,927,807.82 482,858.28 2.48 1,622.70 MWD+IFR-AK-CAZ-SC(4) 8,402.76 89.04 196.58 6,346.22 6,198.72 -2,258.01 1,793.25 5,927,717.43 482,831.52 0.79 1,716.95 MWD+IFR-AK-CAZ-SC(4) 8,496.37 89.28 197.01 6,347.60 6,200.10 -2,347.62 1,766.20 5,927,627.90 482,804.26 0.53 1,810.50 MWD+IFR-AK-CAZ-SC(4) 8,591.38 90.69 196.27 6,347.62 6,200.12 -2,438.65 1,739.00 5,927,536.95 482,776.82 1.68 1,905.47 MWD+IFR-AK-CAZ-SC(4) 8,686.38 90.69 196.85 6,346.48 6,198.98 -2,529.70 1,711.92 5,927,445.98 482,749.52 0.61 2,000.43 MWD+1FR-AK-CAZ-SC(4) 8,780.66 90.82 196.21 6,345.23 6,197.73 -2,620.08 1,685.10 5,927,355.68 482,722.48 0.69 2,094.66 MWD+IFR-AK-CAZ-SC(4) 8,874.49 90.45 195.66 6,344.19 6,196.69 -2,710.30 1,659.34 5,927,265.54 482,696.49 0.71 2,188.48 MWD+IFR-AK-CAZ-SC(4) 8,969.32 90.10 194.75 6,343.74 6,196.24 -2,801.80 1,634.47 5,927,174.10 482,671.40 1.03 2,283.30 MWD+IFR-AK-CAZ-SC(4) 9,064.96 90.41 194.56 6,343.31 6,195.81 -2,894.33 1,610.27 5,927,081.64 482,646.97 0.38 2,378.94 MWD+IFR-AK-CAZ-SC(4) 9,159.93 89.62 194.95 6,343.29 6,195.79 -2,986.17 1,586.09 5,926,989.88 482,622.55 0.93 2,473.91 MWD+IFR-AK-CAZ-SC(4) 9,252.61 88.70 196.17 6,344.65 6,197.15 -3,075.44 1,561.23 5,926,900.68 482,597.48 1.65 2,566.57 MWD+IFR-AK-CAZ-SC(4) 9,348.40 87.84 197.16 6,347.54 6,200.04 -3,167.16 1,533.77 5,926,809.03 482,569.79 1.37 2,662.27 MWD+IFR-AK-CAZ-SC(4) 9,443.16 86.71 198.40 6,352.04 6,204.54 -3,257.29 1,504.87 5,926,718.98 482,540.67 1.77 2,756.81 MWD+IFR-AK-CAZ-SC(4) 9,536.45 87.36 198.72 6,356.87 6,209.37 -3,345.61 1,475.22 5,926,630.75 482,510.79 0.78 2,849.80 MWD+IFR-AK-CAZ-SC(4) 9,630.68 89.14 197.21 6,359.75 6,212.25 -3,435.20 1,446.17 5,926,541.24 482,481.52 2.48 2,943.85 MWD+IFR-AK-CAZ-SC(4) 9,725.08 88.77 196.00 6,361.47 6,213.97 -3,525.64 1,419.20 5,926,450.87 482,454.33 1.34 3,038.20 MWD+IFR-AK-CAZ-SC(4) 9,819.22 89.11 194.88 6,363.21 6,215.71 -3,616.37 1,394.14 5,926,360.22 482,429.04 1.24 3,132.32 MWD+1FR-AK-CAZ-SC(4) 9,913.93 90.03 193.93 6,363.92 6,216.42 -3,708.10 1,370.58 5,926,268.56 482,405.26 1.40 3,227.02 MWD+IFR-AK-CAZ-SC(4) 10,008.07 90.31 192.73 6,363.64 6,216.14 -3,799.70 1,348.87 5,926,177.02 482,383.32 1.31 3,321.11 MWD+IFR-AK-CAZ-SC(4) 10,103.19 90.72 192.81 6,362.79 6,215.29 -3,892.46 1,327.85 5,926,084.32 482,362.07 0.44 3,416.16 MWD+IFR-AK-CAZ-SC(4) 10,196.95 90.72 192.38 6,361.61 6,214.11 -3,983.96 1,307.41 5,925,992.89 482,341.40 0.46 3,509.83 MWD+IFR-AK-CAZ-SC(4) 10,292.58 90.82 190.65 6,360.32 6,212.82 -4,077.65 1,288.32 5,925,899.25 482,322.08 1.81 3,605.27 MWD+IFR-AK-CAZ-SC(4) 10,386.51 90.41 188.75 6,359.32 6,211.82 -4,170.23 1,272.49 5,925,806.72 482,306.02 2.07 3,698.79 MWD+IFR-AK-CAZ-SC(4) 10,481.73 90.17 190.15 6,358.83 6,211.33 -4,264.15 1,256.86 5,925,712.85 482,290.15 1.49 3,793.56 MWD+IFR-AK-CAZ-SC(4) 10,576.55 90.31 190.20 6,358.44 6,210.94 -4,357.48 1,240.11 5,925,619.57 482,273.17 0.16 3,888.04 MWD+IFR-AK-CAZ-SC(4) 10,670.99 90.58 191.18 6,357.70 6,210.20 -4,450.28 1,222.59 5,925,526.83 482,255.42 1.08 3,982.21 MWD+IFR-AK-CAZ-SC(4) 10,765.27 90.55 192.16 6,356.77 6,209.27 -4,542.60 1,203.52 5,925,434.56 482,236.12 1.04 4,076.32 MWD+IFR-AK-CAZ-SC(4) 10,858.48 89.83 194.08 6,356.46 6,208.96 -4,633.38 1,182.37 5,925,343.85 482,214.74 2.20 4,169.48 MWD+IFR-AK-CAZ-SC(4) 10,954.19 90.24 195.93 6,356.41 6,208.91 -4,725.82 1,157.59 5,925,251.48 482,189.73 1.98 4,265.18 MWD+IFR-AK-CAZ-SC(4) 11,050.22 89.25 196.73 6,356.83 6,209.33 -4,817.97 1,130.59 5,925,159.40 482,162.50 1.33 4,361.18 MWD+IFR-AK-CAZ-SC(4) 11,144.66 85.50 197.93 6,361.16 6,213.66 -4,908.01 1,102.49 5,925,069.44 482,134.19 4.17 4,455.43 MWD+IFR-AK-CAZ-SC(4) 11,238.25 86.77 197.87 6,367.47 6,219.97 -4,996.87 1,073.79 5,924,980.67 482,105.27 1.36 4,548.68 MWD+IFR-AK-CAZ-SC(4) 9/24/2015 3:14:03PM Page 5 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-10 Project: Kuparuk River Unit TVD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Site: Kuparuk 2S Pad MD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Well: 2S-10 North Reference: True Wellbore: 2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 11,333.47 88.83 196.92 6,371.12 6,223.62 -5,087.66 1,045.35 5,924,889.96 482,076.60 2.38 4,643.75 MWD+IFR-AK-CAZ-SC(4) 11,428.31 88.94 196.37 6,372.97 6,225.47 -5,178.51 1,018.19 5,924,799.19 482,049.21 0.59 4,738.53 MWD+IFR-AK-CAZ-SC(4) 11,523.26 90.24 195.99 6,373.65 6,226.15 -5,269.69 991.73 5,924,708.08 482,022.53 1.43 4,833.45 MWD+IFR-AK-CAZ-SC(4) 11,617.81 88.42 195.85 6,374.75 6,227.25 -5,360.61 965.80 5,924,617.24 481,996.37 1.93 4,927.98 MWD+IFR-AK-CAZ-SC(4) 11,712.45 88.25 194.88 6,377.50 6,230.00 -5,451.82 940.74 5,924,526.09 481,971.08 1.04 5,022.58 MWD+IFR-AK-CAZ-SC(4) 11,807.67 90.93 193.47 6,378.18 6,230.68 -5,544.13 917.42 5,924,433.85 481,947.53 3.18 5,117.77 MWD+IFR-AK-CAZ-SC(4) 11,902.78 90.58 194.67 6,376.93 6,229.43 -5,636.38 894.30 5,924,341.67 481,924.19 1.31 5,212.86 MWD+IFR-AK-CAZ-SC(4) 11,997.99 90.21 195.48 6,376.27 6,228.77 -5,728.31 869.54 5,924,249.82 481,899.20 0.94 5,308.07 MWD+IFR-AK-CAZ-SC(4) 12,092.97 90.65 195.52 6,375.56 6,228.06 -5,819.83 844.16 5,924,158.37 481,873.59 0.47 5,403.04 MWD+IFR-AK-CAZ-SC(4) 12,187.12 90.17 195.41 6,374.89 6,227.39 -5,910.57 819.05 5,924,067.70 481,848.26 0.52 5,497.19 MWD+IFR-AK-CAZ-SC(4) 12,281.45 90.45 194.32 6,374.38 6,226.88 -6,001.74 794.86 5,923,976.60 481,823.83 1.19 5,591.51 MWD+IFR-AK-CAZ-SC(4) 12,375.72 90.00 196.52 6,374.01 6,226.51 -6,092.61 769.79 5,923,885.80 481,798.54 2.38 5,685.77 MWD+IFR-AK-CAZ-SC(4) 12,470.40 88.18 193.33 6,375.51 6,228.01 -6,184.07 745.41 5,923,794.41 481,773.94 3.88 5,780.43 MWD+IFR-AK-CAZ-SC(4) 12,564.81 86.47 192.24 6,379.92 6,232.42 -6,276.03 724.54 5,923,702.51 481,752.84 2.15 5,874.66 MWD+IFR-AK-CAZ-SC(4) 12,660.18 87.56 191.41 6,384.88 6,237.38 -6,369.25 705.03 5,923,609.35 481,733.09 1.44 5,969.75 MWD+IFR-AK-CAZ-SC(4) 12,755.53 87.15 193.11 6,389.28 6,241.78 -6,462.32 684.80 5,923,516.34 481,712.63 1.83 6,064.88 MWD+IFR-AK-CAZ-SC(4) 12,850.38 87.36 193.44 6,393.83 6,246.33 -6,554.53 663.05 5,923,424.20 481,690.65 0.41 6,159.58 MWD+IFR-AK-CAZ-SC(4) 12,944.88 88.83 192.50 6,396.97 6,249.47 -6,646.57 641.85 5,923,332.22 481,669.22 1.85 6,253.97 MWD+IFR-AK-CAZ-SC(4) 13,039.56 88.63 194.11 6,399.07 6,251.57 -6,738.68 620.07 5,923,240.17 481,647.21 1.71 6,348.58 MWD+IFR-AK-CAZ-SC(4) 13,133.08 90.00 195.43 6,400.18 6,252.68 -6,829.10 596.23 5,923,149.82 481,623.15 2.03 6,442.09 MWD+IFR-AK-CAZ-SC(4) 13,225.82 89.66 197.15 6,400.46 6,252.96 -6,918.11 570.22 5,923,060.89 481,596.91 1.89 6,534.80 MWD+IFR-AK-CAZ-SC(4) 13,320.40 89.93 198.83 6,400.80 6,253.30 -7,008.06 541.01 5,922,971.02 481,567.48 1.80 6,629.25 MWD+IFR-AK-CAZ-SC(4) 13,414.08 89.66 199.43 6,401.13 6,253.63 -7,096.57 510.31 5,922,882.60 481,536.56 0.70 6,722.68 MWD+IFR-AK-CAZ-SC(4) 13,510.10 88.87 200.31 6,402.36 6,254.86 -7,186.86 477.67 5,922,792.39 481,503.71 1.23 6,818.35 MWD+IFR-AK-CAZ-SC(4) 13,602.84 89.21 201.55 6,403.92 6,256.42 -7,273.47 444.55 5,922,705.88 481,470.37 1.39 6,910.58 MWD+IFR-AK-CAZ-SC(4) 13,697.55 89.73 200.10 6,404.79 6,257.29 -7,361.99 410.88 5,922,617.46 481,436.48 1.63 7,004.79 MWD+IFR-AK-CAZ-SC(4) 13,786.78 90.00 197.85 6,405.01 6,257.51 -7,446.36 381.87 5,922,533.16 481,407.26 2.54 7,093.80 MWD+IFR-AK-CAZ-SC(4) 13,882.43 91.54 195.90 6,403.72 6,256.22 -7,537.88 354.11 5,922,441.73 481,379.27 2.60 7,189.38 MWD+IFR-AK-CAZ-SC(4) 13,980.69 92.13 195.38 6,400.57 6,253.07 -7,632.45 327.63 5,922,347.23 481,352.56 0.80 7,287.58 MWD+IFR-AK-CAZ-SC(4) 14,076.36 90.27 196.24 6,398.57 6,251.07 -7,724.48 301.57 5,922,255.28 481,326.28 2.14 7,383.22 MWD+IFR-AK-CAZ-SC(4) 14,170.95 88.80 197.85 6,399.34 6,251.84 -7,814.90 273.85 5,922,164.93 481,298.33 2.30 7,477.74 MWD+IFR-AK-CAZ-SC(4) 14,265.96 88.49 196.51 6,401.58 6,254.08 -7,905.65 245.80 5,922,074.27 481,270.05 1.45 7,572.65 MWD+IFR-AK-CAZ-SC(4) 14,361.22 87.08 196.55 6,405.27 6,257.77 -7,996.90 218.71 5,921,983.09 481,242.74 1.48 7,667.80 MWD+IFR-AK-CAZ-SC(4) 14,455.93 87.29 195.88 6,409.92 6,262.42 -8,087.73 192.30 5,921,892.34 481,216.10 0.74 7,762.38 MWD+IFR-AK-CAZ-SC(4) 14,549.80 87.91 194.56 6,413.85 6,266.35 -8,178.23 167.68 5,921,801.91 481,191.25 1.55 7,856.16 MWD+IFR-AK-CAZ-SC(4) 14,644.65 86.05 194.55 6,418.85 6,271.35 -8,269.90 143.88 5,921,710.31 481,167.22 1.96 7,950.87 MWD+IFR-AK-CAZ-SC(4) 14,739.72 85.64 193.74 6,425.73 6,278.23 -8,361.85 120.70 5,921,618.43 481,143.82 0.95 8,045.68 MWD+IFR-AK-CAZ-SC(4) 14,834.45 88.80 192.11 6,430.33 6,282.83 -8,454.05 99.55 5,921,526.29 481,122.43 3.75 8,140.22 MWD+IFR-AK-CAZ-SC(4) 14,885.00 90.73 192.11 6,430.53 6,283.03 -8,503.48 88.94 5,921,476.89 481,111.71 3.82 8,190.71 BLIND(5 NOT an Actual Survey 4 1/2"x 6-3/4" 9/24/2015 3:14:03PM Page 6 COMPASS 5000.1 Build 74 f Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-10 Project: Kuparuk River Unit TVD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Site: Kuparuk 2S Pad MD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Well: 2S-10 North Reference: True Wellbore: 2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 14,896.00 91.15 192.11 6,430.35 6,282.85 -8,514.23 86.63 5,921,466.15 481,109.37 3.82 8,201.69 Projection to TD Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. ❑ Yes ❑ No I have checked to the best of my ability that the following data is correct: Surface Coordinates [J Declination & Convergence d GRS Survey Corrections O Survey Tool Codes °eP°"arealerDem, Vincent 1,14, SLB DE_ Osara ,. Jake Voss °Olt ltrn^.C.121b "c"': Gent Representative: Dale MOUS Weal ice•" „`°°< Date: 24-Sep20 t 5 9/24/2015 3:14:03PM Page 7 COMPASS 5000.1 Build 74 IVO 24,322_ 2(,322.._. RECEIVED ConocoPhillips JAN 2 0 2016 TRANSMITTAL AOGCC MG- FROM: Sandra D. Lemke, ATO3-0346 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska RE: 2S-10 (permit 215-110-0) DATE: 01/13/2016 Transmitted: Kuparuk River Unit, Alaska 2S-10 1 CD (digital data) and 1 color log print each (redistribution to correct API #error originating at AOGCC) Halliburton-Surface data logging and End of Well report- mud logging data for 2S-10; 09/11/2015; general information, daily summary, days vs. depth, after action review, mud record, bit record, morning reports, survey reports; Digital data: Final Log Files, Final End of well report, Final las export, Halliburton Log Viewer, EMF log viewer color log presentations, 1 color log print Formation Evaluation 2" MD, Gas ratio 2" MD, Drilling Engineering 2" MD Please promptly sign, scan and return electronically to Sandra.D.Lemke(a�Conocophi//ips.com CC: 2S-10 transmittal folder, production well files, eSearch Receipt: Date: q / 1 (o 1.0 GIS-Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph: 907265.6947 STATE OF ALASKA AKA OIL AND GAS CONSERVATION COM SSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Rill Tubing r Operations shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved R-ogram r Rug for Redrill rPerforate New Pool Repair Well r Re-enter Susp Well Other:WAG to PROD 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r _ 215-110-0 • 3.Address: 6.API Number: Stratigraphic r Service 50-103-20717-00 • P. O. Box 100360,Anchorage,Alaska 99510 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25603,25604,25608 KRU 2S-10 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 14896 • feet Plugs(measured) 7300 true vertical 6430 feet Junk(measured) none Effective Depth measured 14885 feet Packer(measured) 7259, 7283, 7300, 7374,7375 true vertical 6430 feet (true vertical) 6176,6185,6191,6214,6215 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 108 0 0 0 SURFACE 2660 11.78 2688 0 0 0 INTERMEDIATE 7465 7.625 7492 0 0 0 SLOTTED LINER 7539 6.06 14885 0 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 8102-14843 ��� JA� �� �� True Vertical Depth: 6336-6431 0� RECEIVED Nov I02015 Tubing(size,grade,MD,and TVD) 3.5, L-80, 7374 MD,6214 TVD AOGCC Packers&SSSV(type,MD,and TVD) SLEEVE-BAKER CMU SLIDING SLEEVE W/DS NIPPLE-CLOSED @ 7259 MD and 6176 TVD NIPPLE-CAMCO D NIPPLE @ 7283 MD and 6185 TVD PLUG-HES MIRAGE PLUG @ 7300 MD and 6191 TVD LOCATOR-BAKER LOCATOR @ 7374 MD and 6214 TVD SEAL ASSY-BAKER 80-40 GBH LOCATOR SEAL ASSEMBLY @ 7375 MD and 6215 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 0 Subsequent to operation 983 1439 1 1188 318 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development 17 Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Darrell Humphrey/Bob Christensen Email n1139(aconocophillips.com Printed Name Darrell Humphrey Title NSK Production Engineering Specialist Signature A.AxtPhone:659-7535 Date i f ` is . ....,...48..4„1.4 Form 10-404 Revised 5/2015 V7L /21-7.J15-- RBDMS N0V 1 3 Z015 Submit Original Only • , , • 2S-10 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/18/15 Open well to production/produce greater than 30 days : KUP SVC • 2S-10 ConocoPhillips .;2 ,5'F'k 5�j WeI Attributes Max Angle&MD Ti) ,j Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Alaska,Ino r 500292354600 KUPARUK RIVER UNIT SVC 14,897.0 --- Comment H2S(ppm) Date Annotation Entl Dale KB-Grtl(fl) Rig Release Date 2S-10,10/15/2015249:55 PM SSSV:NIPPLE Last WO: 27.50 9/17/2015 Vesical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag Rev Reason:GLV 0/0 lehallf 10/15/2015 Casing Strings ..... _......Ir _......... Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread HANGER,250CONDUCTOR 16 15.250 27.5 107.5 107.5 62.50 H-40 Welded i °.i Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 10 3/4 9.950 28.3 2,688.0 2,564.5 45.50 L-80 HYD 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/L¢n(I...Grade Top Thread INTERMEDIATE 7 5/8 6.875 27.1 7,492.0 6,245.6 29.70 L80 Hyd 563 I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...wt/Len(I...Grade Top Thread SLOTTED LINER-51/2" 41/2 3.958 7,346.2 14,885.0 6,430.5 11.60 L-80 )BTM x5"@7378x41/2" @7409 Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com lin) 7,346.2 6,205.8 71.82 PACKER BAKER HRD-E ZXP LINER TOP PACKER 5.750 7,366.2 6,211.9 72.50 NIPPLE BAKER RS PACKOFF SEAL NIPPLE 4.880 7,369.0 6,212.8 72.60 HANGER BAKER DG FLEX-LOCK LINER HANGER 4.840 7,378.9 6,2157 72.93 XO-NOGO NO GO X0-5 1/2"Hydril 563 box X 5"Hydril 521 4.390 box °nAICONDUCTOR;27.5-107.5 /s 7 7,390.2 6,219.0 73.32 SBE BAKER SEAL BORE EXTENSION 4.000 I 8,0857 6,334.2 85.00 SWELL BAKER SWELL PACKER"G" 3.960 Strings PACKER NIPPLE',499.8I l t ng Tubing Description IStnng Ma...I ID(in) 'Top(ftKB) I Set Depth(ft..JSot Depth(TVD)(...I Wt(Ib/ft) (Grade /Top Connection TUBING-41/2'x3 31/2 2.992 25.0 7,404.01 6,222.9 9.30 L-80 EUE-M 1 1/2 @69.6 Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top led(°) Item Des Com tin) SURFACE;28.3-2,688.0 25.0 25.0 0 00 HANGER CIW TUBING HANGER 3.900 a 69.5 69.5 0.28 XO Reducing XO,2',4-1/2"12.6#L-80 IBTM box x 3-1/2"9.3#L-80 3.000 IEUE-Mod pin i GAS LIFT;3,762.5 499.8 499.8 0.78 NIPPLE CAMCO DS NIPPLE 2.875 I 7,258.6 6,176.3 68.82 SLEEVE BAKER CMU SLIDING SLEEVE W/DS NIPPLE-CLOSED 2.812 III 7,282.9 6,184.9 69.66 NIPPLE CAMCO D NIPPLE 2.750 7,300.3 6,190.9 70.26 PLUG HES MIRAGE PLUG 2962 I 7,373.7 6,214.2 72.75 LOCATOR BAKER LOCATOR 2.990 7,374.8 6,214.5 72.79 SEAL ASSY BAKER 80-40 GBH LOCATOR SEAL ASSEMBLY 3.000 GAS LIFT',6,6150 I Perforations&Slots I Shot #f Dens ITop(TVD) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn SLEEVE;7,258.6 ' 8,101.8 9,024.0 6,335.6 6,343.6 9/14/2015 SLOTS Slotted Liner I 9,454.9 11,5957 6,352.7 6,374.2 9/14/2015 SLOTS Slotted Liner I 11,987.7 14,843.4 6,376.3 6,430.5 9/14/2015 SLOTS Slotted Liner NIPPLE,7,282.9 Mandrel Inserts I St ati PLUG;7,300.3 It on Top(TVD) Valve Latch Port Size TRO Run IN Top(ftKB) (ftKB) Make Model OD(in) Sem Type Type lin) (psi) Run Date Corn i■ 1 3,762.5 3,508.6 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/16/2015 2 6,615.9 5,867.3 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.313 0.0.1004/2015 Notes.General&Safety End Date I Annotation NOTE: LOCATOR;7,373.7 II t F L 1 e SEAL ASSY;7,374.8 i t INTERMEDIATE',27.1-7,492.0- ' -R- SLOTS,8,101.7-9,024.0 IL SLOTS;9,454 11,595.7 IL SLOTS',11987.7 14643 4 SLOTTED LINER-51/2"x 5. @7378 x 4 1/2'07409,7,346 2-. -14,885 0 S . PTOziC Loepp, Victoria T (DOA) From: Voss,Jake <Jake.Voss@conocophillips.com> Sent: Wednesday, September 09, 2015 7:19 AM To: Loepp, Victoria T(DOA) Cc: Klem,Adam; Bearden,J Daniel Subject: Injector 2S-10 (PTD#215-110)Topset Kuparuk; Packer placement waiver Attachments: PTD 215-110_2S-10_Cement&Formations.pptx "— ---- Follow Up Flag: Follow up Flag Status: Flagged SCANNED MAR 1 5 201E Good Afternoon Victoria, I just wanted to touch base since I was out of town to ensure you received the information in regards to the intermediate cement job we performed. I know Haibin sent the SonicScope Log and wanted to follow up if you had any further questions. Attached are the logs showing our different formations along with an overview of our cement integrity. Ratty/Strung out cement was found up to 4,350' MD with top of good cement at 5,335' MD. We had quality cement over the Tarn formations(Growler, Cairn,and Bermuda)as well as to the top of our shoe track (plus the "112' behind the bit of the Sonic Scope). All indications lead to quality cement from our shoe at 7,492' MD up to 5,335' MD. We performed our FIT to a 14.5 ppg EMW as well. We lost only 20 bbls of cement during the first stage(believed to be in a weak zone around 6,325' MD) and had full returns on our second stage. Please let me know if you need any additional information. Thanks Jake Voss Sr Drilling Engineer I ConocoPhillips Alaska I Once:(907)265-6935 I Mobile:(832)-499-9085 From: Guo, Haibin Sent: Saturday, September 05, 2015 4:58 PM To: Loepp, Victoria T(DOA) (victoria.loepp@alaska.gov) Cc: Voss, Jake; Klem, Adam; Bearden, 3 Daniel Subject: RE: Injector 2S-10 (PTD# 215-110)Topset Kuparuk; Packer placement waiver Victoria, We just got the sonic log CBL of 25-10.The log shows TOC @5335'MD and good cement bond below that. Please see attached log. The plan is to move forward to drill out the shoe, FIT test and drill the 6-3/4" production hole. Jake is out of office until 9/8. Any question or need anything please let me know. Thanks, 1 • • Haibin From: Voss, Jake Sent: Friday, August 28, 2015 3:53 PM To: Klem, Adam; Bearden, J Daniel Cc: Callahan, Mike S; Guo, Haibin; Brunswick, Scott A Subject: FW: Injector 2S-10 (PTD# 215-110)Topset Kuparuk; Packer placement waiver From: Loepp, Victoria T(DOA) [mailto:victoria.loeppOalaska.gov] Sent: Friday, August 28, 2015 3:46 PM To: Voss, Jake Subject: [EXTERNAL]RE: Injector 2S-10 (PTD# 215-110)Topset Kuparuk; Packer placement waiver Jake, Approval is granted for your plan to topset the Kuparuk sands as described below. The sonic log is required and the results should be reviewed with the AOGCC when obtained. A waiver is granted to allow the packer to be placed^ 480'above the slotted liner/top of Kuparuk(20 AAC 25.412(b)) based on information provided in the waiver request. Please include this information with the approved PTD. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(o.alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Voss, Jake [ nailto:Jake.Voss@conocophillips.com] Sent: Friday, August 28, 2015 2:47 PM To: Loepp, Victoria T(DOA) Cc: Klem, Adam; Bearden, J Daniel Subject: Injector 2S-10 (PTD# 215-110) Victoria, 2 • As we are seeing on the Shark Tooth program,we continue to experience geologic uncertainties in the overburden that require us to top set the over pressured Kuparuk reservoir. I think moving forward we will begin submitting PTD's that include this design. However, before finalizing that decision,we will gladly come over and visit in person. That said,we should hit Intermediate TD on this well over the weekend(including Monday,which our offices will be closed due to the Presidential Visit).Therefore,we have the following Top Set and Packer Depth Waiver Request for well 2S-10(PTD 215-110): ConocoPhillips requests approval of our proposed plan forward to topset the Kuparuk sands per the following Alaska Administrative Codes. 20 AAC 25.030(c) (5) "production casing must be set and cemented through, into, or just above the production interval" 20 AAC 25.030(d) (5) "intermediate and production casing must be cemented with sufficient cement to fill the annular space from the casing shoe to a minimum of 500 feet above all significant hydrocarbon zones and abnormally geo- pressured strata or, if zonal coverage is not required under(a)of this section,from the casing shoe to a minimum of 500 feet above the casing shoe; if indications of improper cementing exist,such as lost returns,or if the formation integrity test shows an inadequate cement job, remedial action must be taken" The drilling plan was to land the intermediate in the higher pressured (^'11.4 ppg) Kuparuk'A'sands. However,we performed the Surface Casing FIT to a 13.8 ppg EMW which is below our minimum requirement for drilling into the Kuparuk Sand.We propose to topset the overpressured Kuparuk'A'sands by landing"'50'TVD above them,setting our 7-5/8" intermediate casing in the Lower Kalubik shale,and cementing with a minimum of 500'above the shoe. The planned cement stage tool will remain in the 7-5/8" casing to also provide an additional 500'of cement above the C-37 (Tarn area) interval. This plan is similar to our successful completion of the previous 2 Shark Tooth wells(2S-02 and 2S- 07) Successful execution of this plan,we would run a real time Sonic log to confirm top of cement and integrity, drill out the shoe track and horizontally into the Kuparuk to planned TD.We would run our planned 4-1/2"slotted liner with swell packers plus an additional Heel swell packer placement; placing the swell packer at the top of the Kuparuk sands to provide pressure isolation for the 7-5/8" casing shoe. Due to this top set design;we request a waiver to the AOGCC regulation (20 AAC 25.412(b))stating that injection packers must be within 200 feet of the upper most perforations on injection wells based on the cement evaluation we get from the SonicScope. Packer placement will be"'480' MD above the slotted liner/top of Kuparuk A-sand. Attached is an updated schematic with this plan. Thank you for your response, Jake Voss Sr Drilling Engineer I ConocoPhillips Alaska I Office:(907)265-6935 I Mobile: (832)-499-9085 3 • 410 .ani, 1Q 31�cr Attempted fieiedpenel9�onavegedmerthe645fl „±!.....: 42i °.t-L u1BikDen* Bob=pme) - ?1.5m](RDP5]Rf 2 cin m 293 D1 dr RV 2nd Stage but °a a . :oededPhone SARIdiiykr16ndt 412Tkr12 02 Spray A2 MHz IPSH_UNC1 d1Aw Si cement GIIIIMI by 0111110120MIERa _ a2 d„un 200 ` - -9111_ Rde6aerl strung out to Real* M°Mei S5Y1fI J 1 Sreedr, Uspray eetPhN7JP*RLsNMffimM3rSIyAe ,leSedmedcied LdkadraPgcyati(sT1hIP; GvWr M r 4,350' MD j h 1D 0 om^za°0-2 atrtm 203 0.6 6M3 0 ' 5269 1 = 1 r• ? C-37L : v-, i t % 1 5267' (MD) Gi "ft _ TOC e I _�% � � 5335' r,5 ,R._ s _ ,� '7.!..F. _ r + ■_. III 1111111 MEAN. `. %4 04 l +� .. utid II ■tE .2i t. 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I i1MMNi &i■ lI11m 1 111 11■�i■■■a ■ --- 1116411111 "u4 641.11 « 11 II II cement to -■ IIIIII I I it 11 NI I1 III 1111111 111111 II :moi r ■ bottom of 1 I rl 11VIII iIl II 11 illi ■ i ■ ■ 11111111 1111111 IIIIII :�1■ SonicSco e- its ■ uw x•11... II I p . �NI Illi i:IIS • •�� ! log , , 111111111 .jtil IIi79.1111M1f111. 1 111111111 k11 ._I■c ■ e spa 11/111111 folidl1 rar3.■`a■ a ___ . ■ ,. 1111 1 11 ■�!�i■ ■■ II ��11 II 111 •aa Norm i .. ■■■C■■ II , II 1111 ■■■■E!i!■■F! • • Loepp, Victoria T (DOA) From: Guo, Haibin <Haibin.Guo@conocophillips.com> Sent: Saturday, September 05, 2015 6:13 PM To: Loepp,Victoria T(DOA) Subject: Re: [EXTERNAL]Re:Injector 2S-10(PTD#215-110)Topset Kuparuk; Packer placement waiver Follow Up Flag: Follow up Flag Status: Flagged Victoria, The intermediate casing shoe is at 7492'MD.The planed packer depth is-150'above the shoe,which is"'7342'MD.TOC is at 5335'. So we will have 2000'cement above the packer depth. Any other questions please let me know. Thanks, Haibin On Sep 5, 2015,at 5:26 PM, Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov<mailto:victoria.loepp@alaska.gov>> wrote: What is the planned depth of the packer?Thanx for the update. Victoria On Sep 5,2015, at 4:57 PM, Guo, Haibin<Haibin.Guo@conocophillips.com<mailto:Haibin.Guo@conocophillips.com>> wrote: Victoria, We just got the sonic log CBL of 2S-10.The log shows TOC @5335'MD and good cement bond below that. Please see attached log. The plan is to move forward to drill out the shoe, FIT test and drill the 6-3/4" production hole. Jake is out of office until 9/8.Any question or need anything please let me know. Thanks, Haibin From:Voss,Jake Sent: Friday,August 28, 2015 3:53 PM To: Klem,Adam; Bearden,J Daniel Cc:Callahan, Mike 5; Guo, Haibin; Brunswick,Scott A 1 • • Loepp, Victoria T (DOA) From: Loepp,Victoria T (DOA) Sent: Friday, August 14, 2015 10:42 AM To: 'Voss,Jake' Cc: Bettis, Patricia K (DOA) Subject: RE:Injector 2S-10 (PTD#215-110) Jake, Please submit as revised PTD to our office as soon as possible. Revisions can be highlighted in red. Thanx, Victoria From: Voss, Jake [mailto:Jake.Voss@conocophillips.com] Sent: Friday, August 14, 2015 10:38 AM To: Loepp, Victoria T(DOA) Cc: Bearden, J Daniel Subject: Injector 2S-10 (PTD# 215-110) Good Morning Victoria, ConocoPhillips requests approval for the amendment to the existing PTD It 215-110,approved 7/13/15. Due to updated Geologic data, formations have shown up shallower than predicted. Adjustments have been made to well KRU 2S-10 (directional plan and casing depths)to reflect these changes. To ensure the state has the most up-to-date data,the following has been attached: • Amended 10-401 • New Directional Plan • Updated 25-10 Wellbore Schematic Estimated spud date for 2S-10 is 8/22/15. Please let me know of any questions or comments Jake Voss Sr Drilling Engineer I ConocoPhillips Alaska I Office: (907)265-6935 I Mobile: (832)-499-9085 1 • • Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Thursday,August 13, 2015 2:42 PM To: 'Rosenbaum,Jesse E' Subject: RE: H-40 Surface Hole PTD#215056 - Update Follow Up Flag: Follow up Flag Status: Completed Thanx for the update. Victoria From: Rosenbaum, Jesse E [mailto:Jesse.RosenbaumCabp.com] Sent: Thursday, August 13, 2015 2:24 PM To: Loepp, Victoria T(DOA) Cc: Endacott, Mary S; Lastufka, Joseph N Subject: RE: H-40 Surface Hole PTD# 215056 - Update Victoria, Shortly after sending my previous e-mail, parker 273 continued drilling to 600 ft MD and losses slowed 25 bbls/hr and no water was observed in H-06 or H-08.The rig continued to drill ahead with no issues. 9-5/8" surface casing was run and cemented per plan and achieved cement to surface. Regards, Jesse Rosenbaum Drilling Engineer I BP Exploration Alaska 0:907-564-5155 I C:406.533.8984 jesse.rosenbaumAbp.com From: Rosenbaum, Jesse E Sent: Saturday, August 08, 2015 2:07 PM To: Loepp, Victoria T(DOA) (victoria.loepp@alaska.gov) Cc: Endacott, Mary S; Lastufka, Joseph N; AK, D&C Rotary Operation Superintendent; AK, D&C Rig 273 Well Site Leader; Schneider, Kenneth J; Romo, Louis A Subject: H-40 Surface Hole PTD# 215056 - Victoria, After spudding H-40 surface hole this morning,the rig encountered losses immediately after drilling out of the conductor(-150 bbls/30 minutes)and continued to drill ahead to' 400 TD.After inspecting surrounding conductors, freshwater was observed on 2 nearby wells. H-04 and H-08.The losses are not bad enough to cease drilling but we are planning on pumping LCM material to cut down the rate of losses. If there is any escalation to the losses or water in other conductors, I will notify you as the events happen. 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M. " o11 I J p LU N N = cri 0, ai I.I@ V LL E IA 0 cn as N V Z @ a ✓ E m Z � c�, N p rn U) u) el:t « O O O) _ co J O. C 3 J a) o E c l O2 0 0 O III r O a 0 O z le I c 0 r a) o J >- £ to Q c . 0 a F— N fa I— )1'),-- O 'l r Z m c 1 I C N N Z' c C• r N E A CO cc rn 0 E E O • N c '6a) as I (6 U a) O Q Q C C O .. Q a c o a) JUc a Z pCI U to Z t a) • O I, M N O IA I— O 0 0 3 N W F —co m Ce 0 5 p = a) m Z N y - a) O Q W N d' �` H W �p 0 O c '' N D H c Z c@ w v p Q 0 0 Qo o 'a co U E O E -'0 —00 2 E 0 w E E C. O. 0 z 0 a`c0 0 0 0 0 RECEIVED • STATE OF ALASKA • OCT 1 6 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LO&CC la.Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended lb.Well Class: 20AAC 25.105 20AAC 25.116 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑✓ WAG❑ WDSPL❑ No.of Completions: Service ❑✓ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. •Aband.: •9/16/2015 •215-110 3.Address: 7. Date Spudded: 15.API Number: P. O. Box 100360,Anchorage,AK 99501 '8/22/2015 . 50-103-20717-00-0° 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 2211'FSL, 1526'FEL, Sec. 17,T1ON, R8E, UM • 9/11/2015 •KRU 2S-10 ' Top of Productive Interval: 9. KB(ft above MSL): 147.5' 17. Field/Pool(s): 279'FSL,364'FWL,Sec. 16,T1ON, R8E, UM GL(ft above MSL): 120' Kuparuk River Field/Kuparuk River Oil Poo- Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1023'FNL, 1465'FEL,Sec.29,T1ON, R8E, UM ' 14885'MD/6430'TVD ADL 25603,25604,25608 4b. Location of 1,S 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 481044 y- 5929980 Zone- 4 14896'MD/6430'TVD 2677,2678,2681 TPI: x- 482935 y- 5928043 Zone- 4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 481109 y- 5921466 Zone- 4 nipple @ 500'MD/500'TVD 1430'MD/1420'TVD 5. Directional or Inclination Survey: Yes ❑✓ (attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 na (ft MSL) not applicable 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, CBL, Density/Neutron 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 16" 62.5# H-40 27.5' 107.5' 27.5' 107.5' 24" pre-installed 10.75" 45.5# L-80 28' 2688' 28' 2565' 13.5" 1288 sx DeepCRETE,207 sx DeepCRETE 7.625" 29.7# L-80 27' 7492' 27' 6246' 9.875" 365 sx Class G, 130 sx Class G 4.5" 11.6# L-80 7346' 14885' 6206' 6431' 6.75" slotted liner 24. Open to production or injection? Yes a No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): ... 3.5" 7404' 7346'MD/6206'TVD slotted liner from 8102-14843'MD 6336-6431'TVD ` • `t(Ib ltr l 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. IqU 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 none 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): waiting on facility hook-up Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period -O. Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API (corr): Press. 24-Hour Rate 3/1 Form 10-407 Revised 5/2015 '/77_ 1 0/2 5 _ CONTINUEI 'PGE 2 RBD ��r� �J OCT 2 0 ZO11 5 Submit ORIGINIAL on y. 28.CORE DATA Conventional Core Yes ❑ No ❑ Sidewall Cores: • ❑ No ❑ If Yes, list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions, core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. none 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No Q Permafrost-Top surface surface If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1430' 1420' Attach separate pages to this form, if needed,and submit detailed test information, including reports,per 20 AAC 25.071. C-80 3094' 2921' C-37 5267' 4832' none Growler 5424' 4969' Top Cairn 6100' 5524' Top Bermuda 6262' 5642' Top HRZ 6857' 5996' Upper Kalubik 7123' 6123' Lower Kalubik 7342' 6205' Kuparuk C4 7855' 6311' A4 8061' 6332' Formation at total depth: Kuparuk A4 31. List of Attachments: Summary of Daily Operations,schematic,final directional survey,cement reports Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. fit, / - Contact: Jacob Voss @ 265-6935 Email: jacob.vosscop.comV-"� Printed Name: Graham L.Alvord� Title: Alaska Drilling Manager // Signature: - `--- C*� Phone: 265-6120 Date: t 0( ( 2 '9 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation, or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and 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 logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection, Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including, but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2015 Submit ORIGINAL Only rw, KUP SVC 2S-10 ConocoPhilips tl i ell Attributes Max Angle&MD TD Alaska Inc Wellbore API/UWI Field Name Wellbore Status ncl 7) MD(ftKB) Act Btm(ftKB) Cormiric:Philnp 500292354600 KUPARUK RIVER UNIT SVC 14,897.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date 2S-10,9/29/2015440.54 PM SSSV:NIPPLE Last WO: 27.50 9/17/2015 Vertical schematic(actual) _ -- ---- Annotation- Depth(ftKB) End Date Annotation Last Mod By End Date ....._,,,._._ Last Tag: Rev Reason:NEW WELL smsmith 9/29/2015 Casing Stnngs ..................................................................................... Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread HANGER;25.0 CONDUCTOR 16 15.250 27.5 107.5 107.5 62.50 H-40 Welded t 1 Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread I■1Cas ', SURFACE 10 3/4 9.950 28.3 2,688.0 2,564.5 45.50 L-80 HYD 563 Il Il 'I ption OD(in) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread .I` INTERMEDmgDescriIATE 7 5/8 6.875' 27.1 7,492.0 6,245.6 29.70 L80 Hyd 563 Casing Description OD(in) to(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WVLen(I...Grade Top Thread SLOTTED LINER-51/2" 41/2 3.958 7,346.2 14,885.0 6,430.5 11.60 L-80 IBTM x 5"@7378 x 4 1/2" @7409 Liner Details Nominal ID 7 Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com BAKER HRD-E ZXP LINER (in) 7,346.2 6,205.8 71.82 PACKER TOP PACKER 5.750 7,366.2 6,211.9 72.50 NIPPLE BAKER RS PACKOFF SEAL NIPPLE 4.880 7,369.0 6,212.8 72.60 HANGER BAKER DG FLEX-LOCK LINER HANGER 4.840 7,378.9 6,215.7, 72.93 XO-NOGO NO GO XO-51/2"Hydril 563 box X 5"Hydril 521 4.390 box CONDUCTOR;27.5-107.5 -- 7,390.2 6,219.0 73.32 SBE BAKER SEAL BORE EXTENSION 4.000 I 8,085.7 6,334.2 85.00 SWELL BAKER SWELL PACKER"G" 3.960 PACKER NIPPLE;499.8 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING-41/2"x3 31/2 2.992 25.0 7,404.0 6,222.9 9.30 L-80 EUE-M 1 1/2"@69.6 I I Completion Details Nominal ID • Top(ftKB) Top(ND)(ftKB) Top Incl 7) Item Des Corn (in) • SURFACE;20.3-2,888.0 25.0 25.0 0.00 HANGER CIW TUBING HANGER 3.900 • 69.5 69.5 0.28 XO Reducing XO,2',4-1/2"12.6#L-80 IBTM box x 3-1/2"9.3#L-80 3.005 EUE-Mod pin GAS LIFT;3,762.5 le 499.8 499.8- 0.78 NIPPLE CAMCO DS NIPPLE 2.875- I 7,258.6 6,176.3 68.82 SLEEVE BAKER CMU SLIDING SLEEVE W/DS NIPPLE-CLOSED 2.812 IE 7,282.9 6,184.9 69.66 NIPPLE CAMCO D NIPPLE 2.750 7,300.3 6,190.9 70.26 PLUG HES MIRAGE PLUG 2.962 I 7,373.7 6,214.2 72.75 LOCATOR BAKER LOCATOR 2.990 GAS LIFT;6,615.9 7,374.8 6,214.5 72.79 SEAL ASSY BAKER 80-40 GBH LOCATOR SEAL ASSEMBLY 3.000 - 1 Perforations&Slots 7 Shot Dens Top(ND) Btm(TVD) (Shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com SLEEVE;7,258.6 ' 8,101.8 9,024.0 6,335.6 6,343.6 9/140015 SLOTS Slotted Liner -I 9,454.9 11,595.7 6,352.7 6,374.2 9/14/2015 SLOTS Slotted Liner 7 11,987.7 14,843.4 6,376.3 6,430.5 9/14/2015 SLOTS Slotted Liner NIPPLE;7,282.9 - Mandrel Inserts I St aft PLUG;7,300.3 M on Top(ND) Valve Latch Port Size TRO Run 1 N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 3,762.5 3,508.6 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/16/2015 2 6,615.9 5,867.3 CAMCO MMG 1 1/2 GAS LIFT SV RKP 0.000 0.0 906/2015 • Notes:General&Safety End Date Annotation NOTE LOCATOR;7,373.7 ,;.. '1 I! a SEAL ASSY;7,374.8 I; 41 INTERMEDIATE:27.1-7,492.0 .. e SLOTS;8,101.7-9,024.0 SLOTS;9,454.9-11,595.7 SLOTS;11,987.7-14,843.4 - _ SLOTTED LINER-5 1/2.0 5" s_i - @7378 x4 12.427409;7,346.2 -14,885.0 • • ConocoPhillips Time Log & Summary Webvieov Web Reporting Report Well Name: 2S-10 Rig Name: DOYON 141 Job Type: DRILLING ORIGINAL Rig Accept: 8/21/2015 9:00:00 PM Rig Release: 9/17/2015 6:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08/21/2015 24 hr Summary Move rig off of 2S-07. Prep pad&lay mats. Spot rig over 2S-10. Complete rig acceptance checklist. Rig accepted at 21:00 hrs. Finish nipple up of diverter system. Change out saver sub on TD to 4-1/2" IF. 09:00 10:00 1.00 0 0 MIRU MOVE RURD P PJSM, prep for rig move. 10:00 10:30 0.50 0 0 MIRU MOVE MOB P PJSM, move pipe sheds&spot rock washer on edge of pad. 10:30 11:00 0.50 0 0 MIRU MOVE MOB P PJSM; move pits, pump, motor, & boiler modules&spot on edge of pad. 11:00 12:00 1.00 0 0 MIRU MOVE MOB P PJSM; pull sub base off of 2S-07. SIMOPS nipple up 1 stick of diverter line on 2S-10. 12:00 14:00 2.00 0 0 MIRU MOVE MOB P PJSM; level pad&lay mats around 2S-10. 14:00 15:00 1.00 0 0 MIRU MOVE MOB P PJSM; move sub base over 2S-10& shim. 15:00 16:30 1.50 0 0 MIRU MOVE MOB P PJSM; level pad&lay mats for remaining modules. SIMOPS nipple up diverter line. 16:30 18:30 2.00 0 0 MIRU MOVE MOB P PJSM; spot pits, pump, motors, & boiler modules. 18:30 19:15 0.75 0 0 MIRU MOVE MOB P PJSM; spot rock washer&pipe sheds. 19:15 21:00 1.75 0 0 MIRU MOVE RURD P PJSM;work on rig acceptance checklist. Rig accepted @ 21:00 hrs. 21:00 23:15 2.25 0 0 MIRU MOVE NUND P PJSM; nipple up annular, install riser, &hook up hydraulic lines to diverter system. 23:15 00:00 0.75 0 0 MIRU MOVE RURD P PJSM; change out saver sub from 4" XT39 to 4-1/2" IF. Diverter Drill CRT 14 min 32 sec. 38/22/2015 Finish dressing TD for 5"DP. Load&strap tubular for surface section. P/U 5"DP, HWDP, &NMFC racking back in derrick. Energize&test seals on diverter adapter spool. Perform diverter test. P/U BHA1 as per SLB. Flood lines&conductor,testing high pressure lines. Drill f/89'-275' MD. Pump out of hole to TIH w/NMFC. Drill f/275'-555'MD. Pump clean survey&CBU. 00:00 02:00 2.00 0 0 MIRU MOVE RURD P PJSM, Cont to C/O saver sub f/4" XT-39 to5"4-1/2"IF. SIMOPS, load pipe shed w/5"DP and 5" HWDP. 02:00 04:15 2.25 0 0 MIRU MOVE RURD P Cont to load and tally 5"DP. SIMOPS, perform derrick inspection. 04:15 07:45 3.50 0 0 MIRU MOVE PULD P PJSM, Pick up and stand back 27 stands of 5"DP and 3 stands of HWDP. 07:45 09:15 1.50 0 0 MIRU MOVE NUND P PJSM; set&test seals on diverter adapter per CIW Rep. Page 1 of 32 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 09:15 10:15 1.00 0 0 MIRU MOVE PULD P PJSM; pick up 3 stands of HWDP& 1 stand of NMFC, racking back in derrick. 10:15 11:15 1.00 0 0 MIRU MOVE BOPE P PJSM; perform diverter test, knife valve open in 11 sec, annular closed in 28 sec.Accumulator test; system pressure 3000 psi, pressure after closure 1850, 200 psi recharge time 44 sec, full recharge time 163 sec. 5 nitrogen bottles averaged 2000 psi. Tested gas&pit level(gain/loss) alarms, good.Witnessed waived by AOGCC Rep Chuck Scheve. SIMOPS mobilize BHA to rig floor. 11:15 11:30 0.25 0 0 MIRU MOVE BHAH P Continue mobilizing BHA to the rig floor. 11:30 12:00 0.50 0 0 MIRU MOVE SVRG P PJSM; service rig. 12:00 12:45 0.75 0 0 MIRU MOVE RURD P PJSM; remove split bushings& install master bushings in rotary table. 12:45 15:00 2.25 0 89 MIRU MOVE BHAH P PJSM; pick up BHA 1 as per SLB 0-89' MD. 15:00 15:15 0.25 89 89 MIRU MOVE SEQP P PJSM; flood lines&conductor checking for leaks. Pressure test surface equipment to 3500 psi. 15:15 18:45 3.50 89 275 SURFA( DRILL DDRL P PJSM;drill f/89'-275' MD, 275'TVD, ADT 2.5, PU 50K, SO 51K, ROT 51K,Tq on/off 1/1K, FO 88%,WOB 5-10K, 40 rpm, 500 gpm,450 psi. 18:45 19:15 0.50 275 93 SURFA( DRILL PMPO P PJSM; POOH f/275'-93' MD, 500 gpm, 475 psi. 19:15 19:45 0.50 93 275 SURFA( DRILL BHAH P PJSM; pick up 3 NMFC&saver sub f/93'-275' MD. 19:45 23:30 3.75 275 555 SURFA( DRILL DDRL P Drill ahead f/275'-555'MD, 555'TVD, ADT 2.94, Bit 5.44,Jars 0.0, PU 64K, SO 66K, ROT 67K, Tq on/off 2/1K, ECD 10.83, FO 75%,WOB 10-15,60 rpm, 577 gpm, 750 psi.. 23:30 00:00 0.50 555 555 SURFA( DRILL CIRC P Survey&CBU @ 575 gpm,685 psi. 08/23/2015 Drop multi-shot survey tool&TOH. Lay down survey tool&UBHO, P/U ADN tool. MADD pass to bottom. Directional drill ahead as per plan f/555'-2075' MD,2014'TVD. 00:00 00:15 0.25 555 555 SURFA( DRILL SRVY P PJSM, drop multi-shot gyro per Gyrodata Rep. 00:15 01:00 0.75 555 155 SURFA( DRILL SRVY P PJSM;TOH f/555'-155' MD,survey shots for each stand. Calculated fill 9.34, actual 8.16 bbls. 01:00 01:45 0.75 155 85 SURFA( DRILL BHAH P PJSM; pull gyro tool&lay down UBHO sub per SLB. 01:45 03:15 1.50 85 180 SURFA( DRILL BHAH P PJSM; make up BHA 2(ADN)&load sources per SLB Rep. 03:15 06:00 2.75 180 555 SURFA( DRILL DLOG P MADD pass f/180'-555'MD, 180 fph, 550 gpm, 525 psi, FO 75%,40 rpm, Tq 1K. Spill Drill CRT 89 sec @ 04:30 hrs. Page 2 of 32 Time Logs 411 • Date From To Dur S. Depth E. DepthPhase Code Subcode T Comment 06:00 12:00 6.00 555 1,138 SURFA( DRILL DDRL P Drill ahead f/555'-1138'MD, 1134' TVD,ADT 3.96,AST 1.97, Bit 9.40, Jars 3.96, PU 85K, SO 83K, ROT 84K, Tq on/off=6/2K, ECD 10.32, FO 87%,WOB 15-20, 60 rpm, 550/650 gpm, 900 psi.. max gas 0 12:00 18:00 6.00 1,138 1,606 SURFA( DRILL DDRL P Drill ahead f/1138'-1606'MD, 1587' TVD,ADT 4.13,AST 2.30, Bit 13.62, Jars 8.18, PU 93K, SO 87K, ROT 91K, Tq on/off=6/3K, ECD 10.64, FO 43%,WOB 25-30,60 rpm, 650 gpm, 1300 psi.. max gas 76 18:00 00:00 6.00 1,606 2,075 SURFA( DRILL DDRL P Drill ahead f/1606'-2075' MD,2014' TVD,ADT 3.91,AST 1.75, Bit 17.53, Jars 12.09, PU 104K, SO 92K, ROT 96K, Tq on/off=6/2K, ECD 10.63, FO 42%,WOB 10-12K, 60 rpm,650 gpm, 1350 psi.. max gas 150 08/24/2015 DDrill ahead to TD—2700' MD. CBU 2X. BROOH to the BHA. Lay down BHA 2 as per SLB. Rig up&run 10-3/4"casing as per detail to 950' MD.Work tight hole at 950' MD. 00:00 07:45 7.75 2,075 2,699 SURFA( DRILL DDRL P Drill ahead f/2075'-2699'MD,2575' TVD,ADT 5.65,AST 0, Bit 23.18, Jars 17.74, PU 120K, SO 100K, ROT 110K,Tq on/off=5/2K, ECD 10.56, FO 44%,WOB 15-25K, 60 rpm, 743 gpm, 1700 psi.. max gas 270 TD @ 2966' MD, 2575'TVD 07:45 08:30 0.75 2,699 2,632 SURFA( CASING CIRC P CBU 2X @ 755 gpm, 1700 psi, FO 44%, 60 rpm, Tq 3K, racking 1 stand back on bottoms up,2699'-2632' MD. 08:30 16:45 8.25 2,632 214 SURFA( CASING BKRM P PJSM, backream out of hole f/ 2632'-214' MD, 750-550 gpm, 750 psi,60 rpm, Tq 3-6K, FO 42%, 700 fph, MADD pass. 16:45 18:45 2.00 214 0 SURFA( CASING BHAH P PJSM, lay down BHA 2 as per SLB. 18:45 19:30 0.75 0 0 SURFA( CASING WWWH P PJSM, rig up&flush stack. 19:30 21:00 1.50 0 0 SURFA( CASING RURD P PJSM; rig up CRT&casing running equipment. 21:00 23:45 2.75 0 950 SURFA( CASING PUTB P PJSM, run 10-3/4",45.5#, L-80, Hyd 563,casing 0-950' MD, as per detail. 23:45 00:00 0.25 950 950 SURFA( CASING PUTB T Work tight spot @ 950', attempt to work through by setting down repeatedly,then wash down with 1.5 bpm,then try turning the pipe in 1/4 turn increments. 08/25/2015 Work thru tight hole&run surface casing as per detail to TD @ 2688'MD. Circulate&condition for cement job. Cement as per SLB CADE with CIP© 19:26 hrs. Rig down casing running equipment. Nipple down diverter equipment. 00:00 03:45 3.75 950 1,015 SURFA( CASING PUTB T PJSM; continue to work pipe thru tight spots f/956'-1015'MD, 5 rpm, Tq 15-20K,2-3 bpm, 75-150 psi. Tight 956'-965'& 1010'-1015'MD. Page 3 of 32 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T 'Comment 03:45 05:15 1.50 1,015 1,015 SURFA( CASING PUTB T Lost prime on mud pumps due to thick mud in suction lines. Clear mud from lines&establish prime to the mud pumps. 05:15 06:00 0.75 1,015 1,045 SURFA( CASING PUTB T Continue working through tight spot f/ 1015'-1045' MD, 5 rpm,Tq 15-20K, 2-3 bpm, 75-150 psi. 06:00 06:30 0.50 1,045 1,224 SURFA( CASING PUTB P PJSM, continue running 10-3/4", 45.5#, L-80, Hyd 563, casing 1045-1224' MD, as per detail. 06:30 07:15 0.75 1,224 1,224 SURFA( CASING PUTB T Lost prime on mud pumps due to thick mud in suction lines. Clear mud from lines&establish prime to the mud pumps. 07:15 08:45 1.50 1,224 1,571 SURFA( CASING PUTB P PJSM, continue running 10-3/4", 45.5#, L-80, Hyd 563, casing 1224'-1571'MD, as per detail.Work thru minor tight spot 1430'-1560' MD, 08:45 09:00 0.25 1,571 1,571 SURFA( CASING CIRC P CBU staging up pumps to 5 bpm, 125 psi, FO 23%. 09:00 09:30 0.50 1,571 1,654 SURFA( CASING PUTB P PJSM, continue running 10-3/4", 45.5#, L-80, Hyd 563, casing 1571'-1654' MD, as per detail. 09:30 10:00 0.50 1,654 1,654 SURFA( CASING PUTB T Lost prime on mud pumps due to thick mud in suction lines. Clear mud from lines&establish prime to the mud pumps. 10:00 12:00 2.00 1,654 2,641 SURFA( CASING PUTB P PJSM, continue running 10-3/4", 45.5#, L-80, Hyd 563, casing 1654'-2641' MD, as per detail, PU 145K, SO 105K, 65 bowspring centrilizers ran. Calculated displacement 29.91, actual 35.54 bbls. 12:00 12:45 0.75 2,641 2,688 SURFA( CASING HOSO P PJSM; make up hanger&landing joint, land hanger f/2641'-2688'MD. 12:45 15:45 3.00 2,688 2,688 SURFA( CEMEN-CIRC P Circulate&condition mud for surface cement job, stage up pump to 7 bpm, 150 psi. 15:45 16:00 0.25 2,688 2,688 SURFA( CEMEN-RURD P PJSM for cement job&rig up cement line. 16:00 19:30 3.50 2,688 0 SURFA( CEMEN-CMNT P PJSM; batch up CW-100, line up to cementers, pump 5 bbls of CW-100, &PT lines to 4000 psi. Pump 73 bbls of CW-100, 99 bbls of Mud Push 2 w/red dye,drop bottom plug. Pump 438 bbls of 11.0ppg lead cement,60bbls of 12.0 ppg tail cement, &drop top plug. Pump 10 bbls of fresh water to kick out plug. Swap over to rig pump&displace cement with 9.6 ppg mud. Bump plug w/2395 strokes.20 bbls of cement to surface. CIP @ 19:26 hrs. 19:30 21:15 1.75 0 0 SURFA( CEMEN-RURD P PJSM; rig down cement equipment, flush lines w/black water, drain stack,&lay down landing joint. Page 4 of 32 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:15 00:00 2.75 0 0 SURFA( CEMEN-NUND P PJSM; nipple down diverter line& annular. remove 1st stick of diverter line&mobilize well head into cellar. 08/26/2015 ND Cameron staring head&20"Hydril-NU Wellhead&test to 5000 psi-NU BOPE-Perform BWM on BOP stack- Clear diverter equipment f/cellar-Set tree&adaptor flange in cellar area w/crane-Shell test BOPE -Test MPDE-Install trip nipple&hoses for MPD-Test MPD choke valves-Test BOPE w/5"test joint- Start changing out failed IBOP 00:00 01:30 1.50 0 0 SURFA( CEMEN-NUND P PJSM-Disengage slips on Cameron starting head-Remove 4"valves f/ conductor&install caps 01:30 02:15 0.75 0 0 SURFA( CEMEN-NUND P ND Cameron diverter adaptor spool& 20"hydril 02:15 03:45 1.50 0 0 SURFA( WHDBO NUND P NU Cameron wellhead&test seals to 5000 psi for 10 mins. 03:45 05:15 1.50 0 0 SURFA( WHDBO NUND P NU BOPE 05:15 12:00 6.75 0 0 SURFA( WHDBO SVRG P PJSM-Perfrom BWM on BOPE- Changed top 3.5"x 6"rubbers- chased threads on btm ram bolt hole SIMOPS-Clean&clear csg tools f/ rig floor-install test plug-Bring MPD test plug to rig floor-chnage out master bushings-remove diverter equipment f/cellar-set tree and adaptor flange in cellar w/crane -weld doors back on from APOD 3 install. 12:00 12:45 0.75 0 0 SURFA( WHDBO RURD P PJSM-rig up&shell test BOPE 250/3500 psi for 5 min each. 12:45 13:45 1.00 0 0 SURFA( WHDBO MPDA P PJSM-install MPD test cap&test to 250 for 5 min& 1200 psi for 10 min, charted. Remove MPD test cap. 13:45 15:15 1.50 0 0 SURFA( WHDBO MPDA P PJSM-install trip nipple&hoses for MPD. 15:15 16:15 1.00 0 0 SURFA( WHDBO MPDA P PJSM-Test MPD choke valves. 16:15 17:15 1.00 0 0 SURFA(WHDBO RURD P PJSM-clear&clean floor, rig up to test BOPE. 17:15 22:45 5.50 0 0 SURFA(WHDBO BOPE P PJSM, test BOPE w/5"test joint to 250/3500 psi for 5 min each.#1: Top pipe rams, CV 1,12,13, 14&manual kill valve.#2: Upper IBOP(Fail), HCR kill, CV 9, & 11.#3: Lower IBOP, CV 5,8&10. #4: Dart„ CV 4,6&7. #5: FOSV and CV 2. #6: HCR choke& 4"kill line Demco valve, #7: Manual choke valve&HCR kill. #8:Annular preventer tested to 250/2500 psi.#9: Lower pipe rams.#10: Blind rams and CV 3. Replace upper IBOP& retest, pass.Accumulator test: system pressure=2900 psi,After closing= 1800 psi,200 psi attained after 44 sec,full pressure attained after 172 sec, Five bottle nitrogen avg=2075 psi. The BOP test witness was waived by AOGCC Rep. Johnnie Hill. Page 5 of 32 Time Logs Date From To ' Dur S. Depth E. Depth Phase Code Subcode T Comment 22:45 23:30 0.75 0 0 SURFA( WHDBO RURD P PJSM-pull test plug&install 10"ID wear bushing, rig down test equipment&blow down lines. 23:30 00:00 0.50 0 0 SURFA( WHDBO BOPE T PJSM-change out upper IBOP. 08/27/2015 Change out upper&lower IBOP-Tested to 250&3500 psi-PU&stand back 38 stds 5"DP-MU BHA#3- Single in the hole to 2521'MD,with shallow test of MWD @ 1587'MD-CBU-Slip&cut drilling line-Trouble shoot&calibrate MPD chokes&software system. 00:00 04:15 4.25 0 0 SURFA( WHDBO BOPE T PJSM-Change out upper&lower IBOP's in TD 04:15 05:15 1.00 0 0 SURFA( WHDBO BOPE T Tested upper&lower IBOP's to 250 &3500 psi(Good Test) 05:15 05:30 0.25 0 0 SURFA( CEMEN-RURD P Blow down TD&Install drilling bails Spill Drill CRT 80 sec @ 06:00 hrs. 05:30 06:00 0.50 0 0 SURFA( CEMEN-RURD P RU to pick up 5"DP 06:00 10:00 4.00 0 0 SURFA( CEMEN PULD P PJSM-PU&stand back 38 stds (114 jts)5"DP-via mouse hole 10:00 10:15 0.25 0 0 SURFA( CEMEN RURD P Clean up rig floor-LD mouse hole& drain water f/stack 10:15 11:00 0.75 0 0 SURFA( CEMEN-BHAH P PU BHA tools to rig flor via beaver slide 11:00 12:00 1.00 0 84 SURFA( CEMEN-BHAH P PJSM-MU BHA#3- 9 7/8"bit-6 3/4"Power Drive X6-Power drive receiver sub-Po2wer flex collar- EdcoScope-TeleScope-to 84' 12:00 13:15 1.25 84 842 SURFA( CEMEN BHAH P PJSM-Cont. MU BHA#3-Float sub-Load RA sources-3 NM Flex DC's-Saver sub/w/float-Well commander- 12 jts 5"HWDP-Jars -8 jts. HWDP to 842.33' 13:15 14:15 1.00 842 1,587 SURFA( CEMEN-PULD P PJSM-single in the hole f/ 842'-1587' MD. Kick w/Tripping Drill CRT 76 sec @ 14:00 hrs. 14:15 14:30 0.25 1,587 1,587 SURFA( CEMEN'DHEQ P Shallow pulse test MWD tools @ 615 gpm, 1700 psi,good. 14:30 15:45 1.25 1,587 2,521 SURFA( CEMEN'PULD P Continue singling in the hole with 5" DP f/1587'-2521' MD,ghost reamer installed at 1960'behind the bit. 15:45 16:00 0.25 2,521 2,521 SURFA( CEMEN CIRC P CBU @ 650 gpm, 1775 psi. 16:00 17:00 1.00 2,521 2,521 SURFA( CEMEN SLPC P PJSM-slip and cut 46'of drill line. 17:00 17:15 0.25 2,521 2,521 SURFA( CEMEN-SVRG P PJSM-service rig. 17:15 18:00 0.75 2,521 2,521 SURFA( CEMEN MPDA T PJSM-remove trip nipple&install MPD bearing. 18:00 23:30 5.50 2,521 2,521 SURFA( CEMEN'MPDA T Trouble shoot&calibrate MPD chokes w/software to fix ramp schedules. 23:30 00:00 0.50 2,521 2,521 SURFA( CEMEN MPDA T PJSM-drain stack&blow down MPD system. 08/28/2015 Pulled MPD bearing-Install trip nipple-Test csg to 3500 psi(Good Test)-Drill out shoe track&20"new hole-Perform LOT to 14.0 ppg EMW-Retest to 13.8 ppg EMW-Decision made to drill ahead-Drilled 9 7/8"hole f/2719'to 3855'MD, 3591'TVD-Total footage for 24 hrs 1260'. 00:00 01:00 1.00 2,521 2,521 SURFA( CEMEN-MPDA P PJSM-Pulled MPD bearing& installed trip nipple Page 6 of 32 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 01:30 0.50 2,521 2,590 SURFA( CEMEN.REAM P Wash&ream f/2521'to 2590'@ 500 gpm @ 1180 psi-w/40 rpm's @ 3/5 k torque 01:30 01:45 0.25 2,590 2,590 SURFA( CEMEN-CIRC P Circ btms up @ 500 gpm @ 1150 psi w/40 rpm's w/3/5 k torque-PU wt 115 SO wt. 94 ROT wt 105 SPR's @ 2590'MD 2478'TVD @ 0145 hrs. #1 30/40 SPM @ 50/110 psi #2 30/40 SPM @ 50/110 psi 01:45 02:00 0.25 2,590 2,521 SURFA( CEMEN-TRIP P POOH f/2950'to 2521' 02:00 03:00 1.00 2,521 2,521 SURFA( CEMEN-PRTS P RU&test 10 3/4'csg to 3500 psi for 30 mins. (Good test) Pumped 3.7 bbls-bled back 3.7 bbls 03:00 03:15 0.25 2,521 2,595 SURFA( CEMEN TRIP P Tirp in hole f/2521'to 2595'(top of cmt.) 03:15 07:00 3.75 2,595 2,699 SURFA( CEMEN DRLG P Drill cmt f/2595'to 2599'-Drilled float collar f/2599'to 2601'-Drilled cmt f/2601'to 2686'-Drilled float shoe f/2686'to 2688'-Cleaned out rat hole f/2688'to 2699'@ 500 gpm @ 1100 psi w/40 rpm's w/5/6 k torque-PU wt 116 SO wt 92 ROT wt. 104 07:00 07:15 0.25 2,699 2,719 SURFA( CEMEN DDRL P Drilled 9 7/8" hole f/2699'to 2719' MD-2592'TVD ADT-.21 hrs. ECD-10.26 ppg Footage-20' WOB 5/10 k RPM 80 GPM 600 @ 1600 psi PU wt 116 SO wt 92 ROT wt 104 Torque on/off btm.-6/5 k torque 07:15 07:45 0.50 2,719 2,703 SURFA( CEMEN"CIRC P Circ hole clean for FIT/LOT @ 600 gpm @ 1600 psi w/80 rpm's w/6 k torque( LD working single of DP to 2703') 07:45 08:00 0.25 2,703 2,610 SURFA( CEMEN'TRIP P POOH f/2703'to 2610' 08:00 09:00 1.00 2,610 2,610 SURFA( CEMEN'FIT P RU&perform FIT-Attempt to achieve 16 ppg EMW-went to leak- off @ 14.0 ppg EMW-Notified Anchorage drilling team(decision made to POOH&perform cmt squeeze job) 09:00 09:30 0.50 2,610 2,610 SURFA( CEMEN"CIRC T Circ btms up @ 600 gpm @ 1650 psi w/40 rpm's w/5 k torque 09:30 10:15 0.75 2,610 2,610 SURFA( CEMEN-FIT T Decision made to perform 2 nd FIT- RU&perform FIT to 13.8 ppg EMW- Decision made to drill ahead-RD test equipment 10:15 11:00 0.75 2,610 2,719 INTRM1 DRILL TRIP P RIH f/2610'to 2719'-Circ @ 650 gpm&send down link to power drive Page 7 of 32 Time Logs i Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 12:00 1.00 2,719 2,796 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/2719'to 2796'MD 2659'TVD ADT-1.00 hr. ECD- 10.69 ppg F000tage-77' WOB 3/5 k RPM's 80 GPM 650 @ 1595 psi w/36%flow out PU wt 117 SO wt 94 ROT wt. 104 Torque on/off btm.-6/6 k torque Total bit hrs. 1.21 hrs..Total jar hrs. 1.21 hrs Max gas 78 units. 12:00 18:00 6.00 2,796 3,266 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/2796'to 3266' MD 3072'TVD ADT-4.15 hr. ECD- 10.69 ppg Footage-470' WOB 4/10 k RPM's 120 GPM 650 @ 1648 psi w/41%flow out PU wt 111 SO wt 98 ROT wt. 111 Torque on/off btm.-9/3 k torque Total bit hrs. 5.36 hrs..Total jar hrs. 5.36 hrs Max gas 46 units. SPR's @ 3173'MD 2989'TVD MW 9.7ppg @ 17:00 hrs. #1 30/40 SPM @ 120/165 psi #2 30/40 SPM @ 120/160 psi 18:00 00:00 6.00 3,266 3,855 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/3266'to 3855'MD 3591'TVD ADT-4.71 hr. ECD- 11.02 ppg Footage-589' WOB 5/8 k RPM's 140 GPM 729 @ 2150 psi w/41%flow out PU wt 135 SO wt 107 ROT wt. 118 Torque on/off btm.-9/3 k torque Total bit hrs. 10.07 hrs..Total jar hrs. 10.07 hrs Max gas 25 units. SPR's @ 3727'MD 3477'TVD MW 9.7ppg @ 22:34 hrs. #1 30/40 SPM @ 130/170 psi #2 30/40 SPM @ 130/170 psi 08/29/2015 Directional drilled 9 7/8"intermediate hole section f/3855'to 5128' MD. CBU&OWFF. Removed trip nipple& installed RCD. Ddrilled f/5128'-5571'MD, 5098'TVD, Total footage drilled for 24hrs, 1716'. Page 8 of 32 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 3,855 4,382 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/3855'to 4382'MD 4053'TVD ADT-5.01 hrs. ECD- 11.4 ppg Footage-527' WOB 5/8 k RPM 140 GPM 730 @ 2400 psi w/41%flow out PU wt 138 SO wt 120 ROT wt 138 Torque on/off btm.-8/5 k Total bit hrs. 15.08 hrs Total jar hrs. 15.08 hrs Max gas 67 units SPR's @ 4195'MD 3888'TVD w/ 9.7 ppg @ 0330 hrs. #1 30/40 SPM @ 130/180 psi #2 30/40 SPM @ 125/180 psi 06:00 12:00 6.00 4,382 4,827 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/4382'to 4827'MD 4444'TVD ADT-4.39 hrs. ECD- 11.54 ppg Footage-445' WOB 5/8 k RPM 140 GPM 730 @ 2650 psi w/42%flow out PUwt142 SOwt125 ROT wt138 Torque on/off btm.-9/6 k Total bit hrs. 19.47 hrs Total jar hrs. 19.47 hrs. Max gas 24 units SPR's @ 4661'MD 4297'TVD w/9.7 ppg mud @ 0930 hrs #1 30/40 SPM @ 140/200 psi #2 30/40 SPM @ 140/200 psi 12:00 16:00 4.00 4,827 5,128 INTRMI DRILL DDRL P Drilled 9 7/8"hole w/RSS f/4827'to 5128'MD 4710'TVD ADT-3.45 hrs. ECD- 11.50 ppg Footage-301' WOB9/13k RPM 140 GPM725 @ 2500 psi w/42%flow out PU wt 150 SO wt 129 ROT wt 137 Torque on/off btm.-9/3 k Total bit hrs.22.92 hrs Total jar hrs. 22.92 hrs. Max gas 57 units 16:00 16:45 0.75 5,128 5,033 INTRM1 DRILL CIRC P CBU racking back 1 stand 5128'-5033' MD @ 725 gpm, 2500 psi, PU 150K, SO 129K, ROT 137K. 16:45 17:00 0.25 5,033 5,033 INTRM1 DRILL OWFF P Monitor well,static. 17:00 17:30 0.50 5,033 5,033 INTRMI DRILL MPDA P PJSM; remove trip nipple&install RCD. 17:30 18:00 0.50 5,033 5,128 INTRM1 DRILL MPDA P PJSM, break in RCD bearing washing back to bottom 5033'-5128' MD @ 10 rpm for 5 min then stage up to 140 rpm, 725 gpm, 1500 psi. Page 9 of 32 Time Logs ! . Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 18:00 00:00 6.00 5,128 5,571 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/5128'to 5571'MD 5098'TVD ADT-4.84 hrs. ECD- 11.54 ppg Footage-443' WOB5/7k RPM 140 GPM711 ©2825 psi w/85%flow out PU wt 157 SO wt 133 ROT wt 144 Torque on/off btm.-9/3 k Total bit hrs. 27.76 hrs Total jar hrs. 27.76 hrs. Max gas 211 units Kick w/Drilling CRT 69 sec @ 22:00 hrs SPR's @ 5220'MD 4792'TVD w/ 10.0 ppg @ 19:30 hrs. #1 30/40 SPM @ 185/250 psi #2 30/40 SPM @ 180/250 psi 08/30/2015 Drilled 9 7/8"hole w/RSS&MPD f/5571'to 6515'MD. Incurred 36 bph losses @ 6515'MD. Spot LCM pill& stage pumps up. Continue to drill f/6515'-7040' MD, 6087'TVD.Total footage for 24 hrs 1469'. 00:00 06:00 6.00 5,571 6,057 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/RSS f/5571'to 6057'MD 5494'TVD ADT-5.22 hrs. ECD- 11.6 ppg Footage-486' WOB 5/13 k RPM 140 GPM 710 @ 2910 psi w/85%flow out PUwt165 SOwt140 ROT wt151 Torque on/off btm.-10/5 k Total bit hrs. -32.98 hrs. Total jar hrs.32.98 hrs. Max gas 124 units Kick w/Drilling CRT 64 sec @ 00:15 hrs SPR's @ 5487'MD 5110'TVD w/ 10.0 ppg @ 0015 hrs. #1 30/40 SPM @ 190/260 psi #2 30/40 SPM @ 190/260 psi Page 10 of 32 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 6,057 6,429 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/6057'to 6429' MD 5755'TVD ADT-4.22 hrs. ECD-11.4 ppg Footage-372' WOB 5/20 k RPM's 140 GPM 710 @ 3075 psi w/77%flow out PU wt 176 SO wt 148 ROT wt. 157 Torque on/off btm.-12/6 k Total bit hrs. -37.20 hrs. Total jar hrs. 37.20 hrs Max gas-752 units SPR's @ 6057'MD 5493'TVD w/ 10.1 ppg @ 0600 hrs. #1 30/40 SPM @ 190/260 psi #2 30/40 SPM @ 190/250 psi Lost 25 bbls last 12 hrs. 12:00 13:00 1.00 6,429 6,515 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/6429'to 6515' MD 5813'TVD ADT-.97 hrs. ECD- 11.63 ppg Footage-86' WOB 7/12 k RPM's 140 GPM 711 @ 3100 psi w/79%flow out PU wt 177 SO wt 145 ROT wt. 158 Torque on/off btm.-11 /4 k Total bit hrs. -38.17 hrs. Total jar hrs. 38.17 hrs Max gas-129 units 13:00 14:00 1.00 6,515 6,515 INTRM1 DRILL CIRC T Circulate due to losses, loss rate @ 36 bph w/705 gpm. Reduce rate to 350 gpm &spot 25bb1; nut plug fine &nut plug meduiml5 ppb each; pill. Stage pumps back up to 650 gpm to drill ahead. SPR's @ 6523'MD 5812'TVD w/ 10.1 ppg @ 14:00 hrs. #1 30/40 SPM @ 200/280 psi #2 30/40 SPM @ 200/285 psi 14:00 18:00 4.00 6,515 6,764 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/6515'to 6764'MD 5947'TVD ADT-3.49 hrs. ECD- 11.73 ppg Footage-249' WOB 5/12 k RPM's 130 GPM 657 @ 2825 psi w/75%flow out PU wt 179 SO wt 144 ROT wt. 155 Torque on/off btm.- 12/5 k Total bit hrs. -41.66 hrs. Total jar hrs.41.66 hrs Max gas-461 units Page 11 of 32 Time Logs • 11110 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 6,764 7,040 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/6764'to 7040'MD 6087'TVD ADT-4.89 hrs. ECD-11.88 ppg Footage-276' WOB7/13k RPM's 130 GPM 631 @ 2715 psi w/81%flow out PU wt 180 SO wt 140 ROT wt. 155 Torque on/off btm.-13/5 k Total bit hrs.-46.55 hrs. Total jar hrs.46.55 hrs Max gas-338 units Spill Drill CRT 77 sec @ 23:45 hrs Total Losses for tour 80 bbls SPR's @ 6990' MD 6063'TVD w/ 10.5 ppg @ 22:30 hrs. #1 30/40 SPM @ 220/310 psi #2 30/40 SPM @ 230/305 psi 08/31/2015 Drilled 9 7/8"hole f/7040'to 7500'(TD). CBU 3X w/sweeps, racking back a stand per BU.Wash back to TD. Perform 40%mud dilution.Monitor well,static. TOH 7500'-2559' MD, utilizing MPD. CBU 2X&OWFF. Blow down MPD chokes. 00:00 06:00 6.00 7,040 7,324 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/RSS&MPD f/ 7040'to 7324' MD 6200'TVD ADT-5.38 hrs. ECD- 11.76 ppg Footage-284' WOB 5/10 K RPM 130 GPM 638 @ 2775 psi w/85%flow out PU wt 176 SO wt 138 ROT wt 156 Torque on/off btm.- 14/7 k Total bit hrs. 51.93 hrs. Total jar hrs. 51.93 hrs Max gas 1030 units Spill Drill CRT 60 sec @ 04:15 hrs. 06:00 10:45 4.75 7,324 7,500 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/RSS&MPD f/ 7324'to 7500' MD 6251'TVD ADT-3.96 hrs ECD- 11.74 ppg Footage-176' WOB 5/17 k RPM 130 GPM 638 @ 2725 psi/81%flow out PU wt 175 SO wt 136 ROT wt. 155 Torque on/off btm.-12/8 k Total bit hrs. 55.89 hrs Total jar hrs. 55.89 hrs Max gas- 1351 units 10:45 11:15 0.50 7,500 7,500 INTRM1 CASING SRVY P Survey as per SLB MWD. SPR's @ 7500/MD 6250'TVD w/ 10.5 ppg @ 1100 hrs #1 30/40 SPM @ 205/285 psi #2 30/40 SPM @ 185/285 psi Page12of32 Time Logs 110 Date From To Dur " S. Depth E. Depth Phase Code Subcode T Comment 11:15 14:15 3.00 7,500 7,240 INTRM1 CASING!,CIRC P Pump 30 bbls Hi-Vis sweep&Circ 3 X btms up @ 640 gpm @ 2700 psi w/130 rpms w/5/10 k torque-ECD- 11.75 ppg-Stand back 1 std DP every btm up 14:15 14:45 0.50 7,240 7,500 INTRM1 CASING REAM P PJSM; ream back to bottom 7240'-7500'MD, 500-630 gpm, 1700-2600 psi, 130 rpm, Tq 6K 14:45 16:00 1.25 7,500 7,500 INTRM1 CASING CIRC P PJSM; perform 290 bbl mud dilution 6.5 bpm,650 psi. 16:00 17:00 1.00 7,500 7,500 INTRM1 CASING OWFF P Line up on trip tank to monitor the well for flow. 17:00 22:30 5.50 7,500 2,559 INTRMI CASING TRIP P PJSM;TOH f/7500'-2559' MD, utilizing MPD, holding 200 psi while pulling&60 psi in the slips. Calculated fill 44, actual 52 bbls. 22:30 23:15 0.75 2,559 2,559 INTRMI CASING CIRC P CBU 2X, 550 gpm, 1550 psi, 60 rpm, Tq 2-3K. 23:15 23:30 0.25 2,559 2,559 INTRM1 CASING OWFF P Monitor well, observe very slight flow to static. 23:30 00:00 0.50 2,559 2,559 INTRM1 CASING MPDA P PJSM; blow down MPD choke. 09/01/2015 Remove RCD&install trip nipple.TOH&lay down BHA 3. Flush BOPE. Pull wear ring&install test plug. C/O upper rams from VBR's to 7-5/8"rams&test same. Rig up&run 7-5/8"casing to 2673' MD. CBU. Run 7-5/8"casing to 4349' MD. Encounter tight hole. Circ and cond mud. Run 7-5/8"casing to 4485' MD 00:00 02:00 2.00 2,559 2,559 INTRM1 CASING MPDA P Remove RCD bearing assy. Install trip nipple 02:00 03:30 1.50 2,559 842 INTRM1 CASING TRIP P POOH to 842' MD. PU=105K 03:30 03:45 0.25 842 842 INTRMI CASING OWFF P OWFF. Static. 03:45 04:15 0.50 842 196 INTRM1 CASING TRIP P POOH to 196' MD. Calc disp=30.7 bbls Act disp=32 bbls. 04:15 04:30 0.25 196 196 INTRM1 CASING OWFF P OWFF. Static. Sim-ops/PJSM on removing nuclear sources. 04:30 06:15 1.75 196 0 INTRM1 CASING BHAH P Lay down BHA#3. 06:15 07:15 1.00 0 0 INTRM1 CASING BHAH P Clean and clear rig floor. 07:15 08:15 1.00 0 0 INTRMI CASING WWWH P Rig up and flush BOPE. Function all rams and annular preventer. 08:15 08:45 0.50 0 0 INTRM1 CASING RURD P Rig up and pull wear bushing 08:45 09:00 0.25 0 0 INTRM1 CASING RURD P Change out split master bushing to solid body master bushing. 09:00 10:30 1.50 0 0 INTRM1 CASING BOPE P Change out upper pipe rams to 7 5/8" 10:30 12:45 2.25 0 0 INTRM1 CASING BOPE P Rig up and test 7 5/8"rams to 250/3500 psi 5 mins each. Change out test sub. Rig down test equip. 12:45 14:15 1.50 0 0 INTRM1 CASING RURD P Make up Volant CRT. Rig up to run 7 5/8"casing 14:15 19:00 4.75 0 2,673 INTRM1 CASING PUTB P Pick up 7 5/8" L-80 29.7#Hydril 563 dopeless casing to 2673'MD. 19:00 19:30 0.50 2,673 2,673 INTRM1 CASING CIRC P CBU. Stage pump up to 5 bpm. 175 psi, PU 96K SO 92K. 19:30 22:15 2.75 2,673 4,349 INTRM1 CASING PUTB P Pick up 7 5/8" L-80 29.7#Hydril 563 dopeless casing to 4349'MD. Page 13 of 32 Time Logs 410 Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 22:15 23:30 1.25 4,349 4,349 INTRM1 CASING PUTB T Encounter tight hole @ 4349' MD. Establish circulation staging up pump from 1 bpm,400 psi to 5 bpm, 325 psi. Circ and cond mud. PU 125K SO 111K. 23:30 23:45 0.25 4,349 4,380 INTRM1 CASING PUTB T Wash down from 4349'MD to 4380' MD. 5 bpm, 325 psi 23:45 00:00 0.25 4,380 4,485 INTRMI CASING PUTB P Pick up 7 5/8" L-80 29.7#Hydril 563 dopeless casing to 4485'MD. Calc disp=44 bbls Act disp=38 bbls 39/02/2015 Run 7 5/8"casing to 5104' MD. Circ and cond mud.Run 7 5/8"casing to 5919' MD Break circ.Run 7 5/8" casing to 7462' MD Make up hanger and land csg @ 7492' MD. Circ and cond mud for cement job. Perform two stage cement job as per program. OWFF. Lay down landing jt. Rig down casing equip. Install and test packoffs. 00:00 01:30 1.50 4,485 5,104 INTRM1 CASING PUTB P Pick up 7 5/8" L-80 29.7#Hydril 563 dopeless casing to 5104'MD. 01:30 04:00 2.50 5,104 5,104 INTRM1 CASING CIRC P Circ and cond mud at 5104'MD. Stage pump up from 1 bpm, 200 psi to 5 bpm, 350 psi. PU 150K SO 126K. 04:00 05:45 1.75 5,104 5,919 INTRM1 CASING PUTB P Pick up 7 5/8" L-80 29.7#Hydril 563 dopeless casing to 5919'MD. 05:45 06:15 0.50 5,919 5,919 INTRM1 CASING CIRC P Break circ @ 1/2 bpm,250 psi. Stage up to 1 bpm,300 psi. 06:15 10:30 4.25 5,919 7,462 INTRM1 CASING PUTB P Pick up 7 5/8" L-80 29.7#Hydril 563 dopeless casing to 7462'MD. 10:30 11:15 0.75 7,462 7,492 INTRM1 CASING HOSO P Make up hanger and landing jt. Land 7 5/8" L-80 29.7#Hydril 563 dopeless casing on depth at 7492' MD. PU 220K SO 130K. Calc disp=37.5 bls Act disp=18.5 bbls. 11:15 15:00 3.75 7,492 7,492 INTRMI CEMEN-CIRC P Circ and Gond mud for cement job. Stage pump up from 1/2 bpm, 300 psi to 5 bpm 375 psi. 15:00 15:15 0.25 7,492 7,492 INTRM1 CEMEN-RURD P PJSM on cement job. Install cement line onto Volant swivel. 15:15 15:30 0.25 7,492 7,492 INTRMI CEMEN-CIRC P Con't to circ @ 5 bpm. Batch mix Mudpush. 15:30 18:00 2.50 7,492 7,492 INTRM1 CEMEN-CMNT P Perform first stage of cement job. Pump 5 bbls Mud Push.Test lines to 350/4000 psi. Pump 45 bbls 12 ppg MP2.4.8 bpm, 380 psi.Load btm plug-Batch up cmt. -Pumped 76 bbls 15.8 ppg Class G w/GASBLOK slurry @ 5 bbls/min @ 275 psi- Shut down-Loaded top plug-kicked out w/10 bbls/fresh water-switched over to rig pumps&displaced cmt w/ 10.5 ppg mud @ 5.5 bbls/min @ 200 psi-slow pump&bumped plug w/1450 psi-Bleed off&checked floats-floats held-CIP 17:45 hrs. - Recipcated pipe to just before bumping plug. 18:00 18:45 0.75 7,492 7,492 INTRM1 CEMEN-CIRCP Pressure up to 3550 psi to open stage collar. CBU. 5 bpm, 500 psi. Page 14 of 32 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 18:45 20:30 1.75 7,492 7,492 INTRM1 CEMEN-CMNT P Perform second stage of cement job. Pump 40 bbls 12 ppg MP2 @ 5 bpm, 300 psi. Batch up cmt.-Pumped 27 bbls 15.8 ppg Class G w/GASBLOK slurry @ 5 bbls/min @ 300 psi- Shut down-Loaded closing plug- kicked out w/10 bbls/fresh water- switched over to rig pumps& displaced cmt w/10.5 ppg mud @ 6 bbls/min @ 600 psi-slow pump& land plug w/500 psi. Pressure up to 1900 psi and hold for 5 mins to close stage collar. Bleed off&confirm stage collar closure. CIP 20:15 hrs. 20:30 21:00 0.50 7,492 7,492 INTRM1 CEMEN-OWFFP OWFF. Static. 21:00 21:30 0.50 7,492 0 INTRM1 CEMEN-RURD P Rig down cement equip. Lay down landing jt. 21:30 23:45 2.25 0 0 INTRM1 CEMEN WWSP P Make up packoff running tool and set packoff. RILDS.Test packoff to 5000 psi./10 min. Sim-ops/Con't to lay down casing equip. 23:45 00:00 0.25 0 0 INTRM1 CEMEN-RURD P Change out bails on top drive. 09/03/2015 Lay down 5" DP. Unload pipe shed of 5"DP and load and strap 4"DP. Freeze protect 10 3/4"x 7 5/8" annulus. Change out saver sub and upper pipe rams. PU 390 jts of 4"DP. 00:00 00:45 0.75 0 0 INTRM1 CEMEN-RURD P Install bails, elevators and iron roughneck track 00:45 07:00 6.25 0 0 INTRM1 CEMEN-PULD P Lay down 249 jts of 5"drillpipe and 21 jts 5" HWDP via mousehole. 07:00 13:15 6.25 0 0 INTRMI CEMEN-RURD P Unload pipe shed of 5"drillpipe. Load and strap 465 jts of 4"drillpipe. Sim-ops/Freeze protect 10 3/4"x 7 5/8"annulus. Flush annulus w/118 bbls fresh water followed by 87 bbls diesel. Final OA pressure=800 psi. Change out TD saver sub to XT-39. Blow down and rig down circ lines.Change upper pipe rams to 3 1/2"x 6"VBR's. OA=650 psi @ 12:00 hrs Rig on shore power @ 10:45 hrs. 13:15 15:15 2.00 0 0 INTRM1 CEMEN PULD P Pick up 75 jts of 4"XT-39 drillpipe and stand back in derrick. 15:15 15:45 0.50 0 0 INTRMI CEMEN RURD P Lay down 5" handling tools from rig floor. Sim-ops/Service rig. 15:45 00:00 8.25 0 0 INTRM1 CEMEN-PULD P Pick up 315 jts of 4"DP and stand back in derrick. OA=550 psi 09/04/2015 PU 4"DP. Rig up and test BOPE. Make up BHA#4.TIH to 1562'MD. Perform MWD shallow pulse test. TIH to 4304'MD. Perform Mad pass to 5250'MD to confirm cement placement. 00:00 02:15 2.25 0 0 INTRM1 CEMEN-PULD P Pick up 4"XT-39 drillpipe and stand back in derrick. Picked up total of 155 stds of DP. Page 15 of 32 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:15 03:30 1.25 0 0 INTRM1 CEMEN-RURD P Lay down mouse hole. Clean and clear rig floor. 03:30 04:45 1.25 0 0 INTRM1 WHDBO RURD P Rig up to test BOPE 04:45 11:15 6.50 0 0 INTRMI WHDBO BOPE P Test BOPE w/4"test joint to 250/3500 psi for 5 min each. Test#1: Top pipe rams, CV 1,12,13, 14& manual kill valve. Test#2: Upper IBOP, HCR kill, CV 9, & 11. Test#3: Lower IBOP, CV 5,8& 10. Test#4: Dart„ CV 4,6&7. Test#5: FOSV valve&CV 2. Test#6: HCR choke, 4"kill line Demco valve.. Test#7: Manual choke valve&HCR Kill.Test #8:Annular preventer tested to 250/2500 psi. Test#9: Lower pipe rams. Test#10, Blind rams, CV 3. Test#11 Upper pipe rams with 4'/z' test joint,Test#12. Lower pipe rams with 4'/2'test joint. Test#13 Annular with 4'/z"test joint. Test#14 Upper pipe rams with 3'/z'test joint.Test #15. Lower pipe rams with 3'/z"test joint.Test#16.Annular with 3'/z'test joint.Accumulator test:system pressure=3000 psi,After closing= 1800 psi, 200 psi attained after 41 sec,full pressure attained after 170 sec, Five bottle nitrogen avg= 1975 psi. BOP test witnessed by AOGCC Jeff Jones. 11:15 12:00 0.75 0 0 INTRMI WHDBO RURD P Set 10"ID wear bushing. Blow down and rig down test lines 12:00 12:45 0.75 0 0 INTRM1 CEMEN-BHAH P Bring BHA#4 components to rig floor. 12:45 14:30 1.75 0 137 INTRM1 CEMEN-BHAH P Make up BHA#4. 14:30 15:00 0.50 137 137 INTRM1 CEMEN"BHAH P Load nuclear sources 15:00 16:15 1.25 137 425 INTRM1 CEMEN-BHAH P Continue to make up BHA#4 16:15 17:00 0.75 425 1,562 INTRM1 CEMEN-TRIPP RIH to 1562' MD. 17:00 17:15 0.25 1,562 1,562 INTRM1 CEMEN DHEQ P Shallow pulse test MWD. 17:15 18:45 1.50 1,562 4,304 INTRM1 CEMEN-TRIPP RIH to 4304' MD. 18:45 00:00 5.25 4,304 5,250 INTRMI CEMEN DLOG P MAD pass to confirm cement placement f/4304'MD to 5250'MD. 220 gpm, 1475 psi,450 fph. Calc disp=26.97 bbls Act disp=26.6 OA=400 psi 39/05/2015 Test casing to 3500 psi/10 min. MAD pass to 5280'MD. Drill out cement and stage collar. Con't to MAD pass to 7327'MD. CBU.Test casing to 3500 psi/30min.Cut and slip drilling line. Install RCD bearing assy. Test and fingerprint MPD system. Remove RCD bearing assy.install trip nipple. Repair RCD clamp latch assy. 00:00 00:30 0.50 5,250 5,250 INTRMI CEMEN RURD P Rig up to test casing. Page 16 of 32 Time Logs • Date° From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 00:45 0.25 5,250 5,250 INTRM1 CEMEN-PRTS P Test casing to 3500 psi/10 min. 00:45 01:00 0.25 5,250 5,250 INTRM1 CEMEN-RURD P Rig down test equip. 01:00 01:15 0.25 5,250 5,280 INTRM1 CEMEN-DLOG P MAD pass f/5250 MD t/5280' MD 01:15 03:30 2.25 5,280 5,311 INTRM1 CEMEN-COCF P Drill cement stringers f/5280' MD t/5301' MD.150-220 gpm, 20-60 rpm, 4-5K tq, 5-20K WOB.Wash down to 5311' MD. 03:30 04:45 1.25 5,311 5,314 INTRMI CEMEN-DRLG P Drill out stage collar f/5311' MD t/5314'MD. 220 gpm, 20-60 rpm, 3-20K WOB,Work through and polish x 2. 04:45 12:00 7.25 5,314 7,327 INTRM1 CEMEN'DLOG P MAD pass f/5314' MD t/7327'MD. 220 gpm., 1600 psi, SO 97K.TOC @ 5335' MD. 12:00 13:15 1.25 7,327 7,327 INTRM1 CEMEN-CIRCP CBU. 217 gpm, 1575 psi, FO 17%, 11.24 ECD,60 rpm, 6K tq. 13:15 13:30 0.25 7,327 7,327 INTRM1 CEMEN-RURD P Rig up to test casing. Flood circ lines. 13:30 14:30 1.00 7,327 7,327 INTRM1 CEMEN-PRTS P Test casing to 3500 psi/30 min charted. 14:30 15:00 0.50 7,327 7,327 INTRM1 CEMEN RURD P Rig down test equip. 15:00 15:15 0.25 7,327 7,327 INTRM1 CEMEN SFTY P PJSM on slip and cut drilling line. 15:15 16:15 1.00 7,327 7,327 INTRM1 CEMEN SLPC P Slip and cut 56'drilling line. 16:15 18:00 1.75 7,327 7,327 INTRMI CEMEN MPDA P Remove trip nipple. Install RCD bearing assy. 18:00 18:15 0.25 7,327 7,327 INTRMI CEMEN MPDA P Rig up to test MPD system 18:15 18:45 0.50 7,327 7,327 INTRM1 CEMEN-MPDAP Test MPD air valve, RCD and chokes to 250/1500 psi-5 min each. 18:45 19:00 0.25 7,327 7,327 INTRMI CEMEN-MPDA P Rig down test equip. 19:00 20:30 1.50 7,327 7,327 INTRMI CEMEN-MPDAP Perform MPD finger print procedure. 20:30 21:30 1.00 7,327 7,327 INTRM1 CEMEN-MPDAP Blow down MPD lines. Remove RCD bearing assy and install trip nipple. 21:30 00:00 2.50 7,327 7,327 INTRM1 CEMEN MPDA T RCD clamp latch difficult to open and close. Repair clamp latch assy. 09/06/2015 Con't to repair RCD clamp latch assy.Drill out shoe track and rat hole. CBU x 3. OWFF. Drain BOPE. Install RCD bearing assy. Drill 20' new hole to 7520' MD. Perform draw down test. Perform FIT to 14.5 ppg EMW. DrIg f/7520'MD t/7611°MD. Displace to 10.5 ppg FloThru mud while drilling. MAD pass f/7611' MD t/7490' MD. Obtain SPR's 00:00 00:45 0.75 7,327 7,327 INTRM1 CEMEN MPDA T PJSM. Continue to repair the RCD clamp in the truck shop and re-install on wellhead. 00:45 01:00 0.25 7,327 7,353 INTRM1 CEMEN-COCF P Wash/Ream from 7327 to 7353' MD. Tag up on top of baffle collar on depth. 7353' MD.220 gpm, 52 spm, 20 rpm, 5-6k torque. 1600 psi. 01:00 02:15 1.25 7,353 7,358 INTRM1 CEMEN-DRLG P Drilling baffle collar and hard cement from 7353'to 7358' MD. 220 gpm, 20 rpm, 5 to 15k wob, 5 to 15k torque. 02:15 04:15 2.00 7,358 7,399 INTRM1 CEMEN-DRLG P Drill out the shoe track from 7358 to 7399 to the float collar. Page 17 of 32 1111 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:15 04:30 0.25 7,399 7,399 INTRM1 CEMEN-CIRCP Slow pump rates: Pump 1: 20 spm=395 psi, 30 spm=595 psi Pump 2: 20 spm=400, 30 spm=600 psi. 04:30 05:45 1.25 7,399 7,403 INTRM1 CEMEN-DRLG P Drill float collar from 7399'to 7403'. 220 gpm, 20 rpm, 5 to 20k wob, 5 to 12k torque. 05:45 08:00 2.25 7,403 7,489 INTRM1 CEMEN-DRLG P Drilling cement from 7403'to 7489'. 220 gpm, 50 rpm, 13 to 15k wob,.7 to 9k torque.1600-1800psi. 08:00 08:30 0.50 7,489 7,500 INTRM1 CEMEN-DRLG P Drill out shoe.235 gpm, 2325 psi, 8-11K WOB,20-60 rpm, 8-10K tq, Clean out rat hole to 7500'MD. 08:30 10:15 1.75 7,500 7,500 INTRM1 CEMEN-CIRCP CBU x 3. 235-265 gpm,2325 psi, 60 rpm, 7K tq. 10:15 10:45 0.50 7,500 7,500 INTRM1 CEMEN-OWFFP OWFF. Static. 10:45 12:00 1.25 7,500 7,500 INTRMI CEMEN-MPDA T Attempt to drain BOPE. Draining slowly. Pack off flow path obstructed. Flush IA valve with water multiple times. Connect cellar pump to IA, pumping out slowly to lower VBR's. Flush IA with water. 12:00 13:15 1.25 7,500 7,500 INTRM1 CEMEN-MPDA P Remove trip nipple. Install RCD bearing assy. 13:15 15:30 2.25 7,500 7,520 INTRMI CEMEN'DDRL P Drilled new 6 3/4"hole w/RSS f/ 7500'to 7520' MD 6252'TVD ADT-.86 hrs. ECD-11.6 ppg Footage-20' WOB 12-15 k RPM's 80 GPM 248 @ 2125 psi w/20%flow out PU wt 145 SO wt 85 ROT wt. 110 Torque on 8k. Torque off 6k 15:30 16:30 1.00 7,520 7,520 INTRMI CEMEN-CIRC P CBU.248 gpm, 2050 psi, 80 rpm, 8k tq. 16:30 17:00 0.50 7,520 7,520 INTRM1 CEMEN-OWFF P Perform draw down test to static in 30 psi increments to 0 psi. 17:00 17:15 0.25 7,520 7,329 INTRM1 CEMEN-TRIPP POOH to 7329' MD 17:15 17:30 0.25 7,329 7,329 INTRM1 CEMEN-RURD P Rig up to perform FIT. 17:30 18:00 0.50 7,329 7,329 INTRM1 CEMEN-FIT P Perform FIT to 14.5 ppg EMW 18:00 18:15 0.25 7,329 7,329 PROD1 DRILL RURD P Blow down cement and kill lines. Rig down test equipment. 18:15 18:30 0.25 7,329 7,329 PROD1 DRILL SFTY P PJSM on displacing well to 10.5 ppg FloThru mud. 18:30 19:00 0.50 7,329 7,520 PROD1 DRILL WASH P Wash down f/7329' MD t/7520' MD. Confirm ramp up/down schedule. Page 18 of 32 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 21:45 2.75 7,520 7,611 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS from 7520' to 7611'MD 6272'TVD ADT-2.39 hrs. ECD- 11.8 ppg Footage-91' WOB 10-15 k RPM's 140 GPM 245 @ 2125 psi w/20%flow out PU wt 145 SO wt 85 ROT wt. 110 Torque on/off btm.-8/5 k Total bit hrs. -3.28 hrs. Total jar hrs. 141.28 hrs Max gas- 108 units 21:45 22:45 1.00 7,611 7,490 PROD1 DRILL DLOG P MAD pass from 7611'MD to 7490' MD. 22:45 23:45 1.00 7,490 7,611 PROD1 DRILL WASH P Wash down from 7490'MD to 7611' MD.Take survey @ 7580'MD. 23:45 00:00 0.25 7,611 7,611 PROD1 DRILL CIRC P Obtain SPR's SPR's @ 7611'MD 6272'TVD w/ 10.5 ppg @23:30 hrs. #1 20/30 SPM @ 380/650 psi #2 20/30 SPM @ 380/648 psi 39/07/2015 Directional Drill 6'/4"production hole with SLB rotary steerable assembly from 7611' MD to 8366' MD. CBU. Finger print pore pressure. Directional Drill in 6'/4'production hole with SLB rotary steerable assembly from 8366' MD to 8652' MD. 00:00 06:00 6.00 7,611 7,800 PROD1 DRILL DDRL P Drilled 6 3/4" hole w/RSS from 7520' to 7800' MD 6306'TVD ADT-5.80 hrs. ECD-11.91 ppg Footage-280' WOB 12-15 k RPM's 150 GPM 250 @ 2350 psi w/35%flow out PU wt 145 SO wt 85 ROT wt. 110 Torque on/off btm.-5-12/6 k Total bit hrs. -9.05 hrs. Total jar hrs. 147.08 hrs Max gas-7449 units 06:00 12:00 6.00 7,800 7,944 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS from 7800' to 7944' MD 6323'TVD ADT-4.43 hrs. ECD- 11.92 ppg Footage-144' WOB 5-15k RPM's 150 GPM 250 @ 2350 psi w/35%flow out PUwt150 SOwt86 ROT wt. 112 Torque on/off btm.-5-12/6-8 k Total bit hrs. - 13.48 hrs. Total jar hrs. 151.51 hrs Max gas-786 units SPR's @ 7895'MD 6317'TVD w/ 10.5 ppg @ 10:30 hrs. #1 20/30 SPM @ 440/680 psi #2 20/30 SPM @ 440/690 psi OA=500 psi Page 19 of 32 IDTime Logs • Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 12:00 18:00 6.00 7,944 8,366 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS from 7944' to 8366' MD 6349'TVD ADT-4.04 hrs. ECD- 11.97 ppg Footage-422' WOB 5-10k RPM's 150 GPM 247 @ 2325 psi w/26%flow out PU wt 149 SO wt 83 ROT wt. 108 Torque on/off btm.-9/8 k Total bit hrs. - 17.52 hrs. Total jar hrs. 155.55 hrs Max gas-9898 units 18:00 19:00 1.00 8,366 8,366 PROD1 DRILL CIRC P CBU. 252 gpm, 2300 psi, 11.86 ECD, 24%FO, 150 rpm, 8k tq. 19:00 19:30 0.50 8,366 8,336 PROD1 DRILL OWFF P Perform draw down test to finger print pore pressure as per rig engineer. Determined 11.5 ppg pore pressure. 19:30 00:00 4.50 8,336 8,652 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS from 8366' to 8652'MD 6346'TVD ADT-3.13 hrs. ECD- 12.11 ppg Footage-286' WOB 10-12k RPM's 160 GPM 250 @ 2375 psi w/24%flow out PU wt 149 SO wt 82 ROT wt. 107 Torque on/off btm.-10/7.5 k Total bit hrs.-20.65 hrs. Total jar hrs. 158.68 hrs Max gas-5679 units SPR's @ 8463'MD 6346'TVD w/ 10.6 ppg @ 20:40 hrs. #1 20/30 SPM @ 430/750 psi #2 20/30 SPM @ 430/730 psi OA=450 psi 09/08/2015 Directional Drill 6%"production hole f/8652'MD t/9220'MD. CBU. Change out RCD bearing assy. Directional Drill 6%"production hole f/9220' MD t/10,231' MD. CBU. Change out RCD bearing assy. Directional Drill 6%"production hole f/10231' MD t110302'MD 00:00 06:00 6.00 8,652 9,220 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS from 8652' to 9220' MD 6344'TVD ADT-4.67 hrs. ECD- 12.27 ppg Footage-568' WOB 12-15k RPM's 150 GPM 250 @ 2400 psi w/26%flow out PU wt 153 SO wt 80 ROT wt. 111 Torque on/off btm.-10/8 k Total bit hrs.-25.32 hrs. Total jar hrs. 163.35 hrs Max gas-8305 units 06:00 06:45 0.75 9,220 9,220 PROD1 DRILL CIRC T RCD seal leaking. CBU.250 gpm, 2450 psi,25% FO, 50 rpm, 8k tq, 06:45 08:15 1.50 9,220 9,220 PROD1 DRILL MPDA T Change out RCD bearing assy. Hold 400 to 450 psi back pressure during changeout. Break in new bearing assy. Page 20 of 32 mm, Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:15 12:00 3.75 9,220 9,503 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS from 9220' to 9503' MD 6353'TVD ADT-2.8 hrs. ECD- 12.33 ppg Footage-283' WOB 8-10k RPM's 150 GPM 250 @ 2500 psi w/26%flow out PU wt 165 SO wt 80 ROT wt. 115 Torque on/off btm.-10/8 k Total bit hrs. -28.12 hrs. Total jar hrs. 166.15 hrs Max gas-2679 units SPR's @ 9408'MD 6348'TVD w/ 10.6 ppg @ 10:30 hrs. #1 20/30 SPM @ 560/860 psi #2 20/30 SPM @ 550/850 psi OA=490 psi 12:00 18:00 6.00 9,503 9,975 PROD1 DRILL DDRL P Drilled 6 3/4" hole w/RSS from 9503' to 9975' MD 6365'TVD ADT-4.01 hrs. ECD- 12.23 ppg Footage-472' WOB 10k RPM's 150 GPM 252 @ 2500 psi w/27%flow out PU wt 160 SO wt 73 ROT wt. 104 Torque on/off btm.- 10/9.5 k Total bit hrs. -32.13 hrs. Total jar hrs. 170.16 hrs Max gas-9901 units SPR's @ 9972'MD 6365'TVD w/ 10.6 ppg @ 17:30 hrs. #1 20/30 SPM @ 487/790 psi #2 20/30 SPM @ 514/805 psi 18:00 20:30 2.50 9,975 10,231 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS from 9975' to 10231' MD 6361'TVD ADT-2.09 hrs. ECD- 12.1 ppg Footage-256' WOB 7-10k RPM's 140 GPM 250 @ 2475 psi w/25%flow out PU wt 160 SO wt 70 ROT wt. 112 Torque on/off btm.- 10-12/9-10 k Total bit hrs. -34.22 hrs. Total jar hrs. 172.25 hrs Max gas-9860 units 20:30 21:30 1.00 10,231 10,231 PROD1 DRILL CIRC T RCD seal leaking. CBU.250 gpm, 2450 psi, 26% FO, 90 rpm, 9k tq, 21:30 22:45 1.25 10,231 10,231 PROD1 DRILL MPDA T Change out RCD bearing assy. Hold 400 to 450 psi back pressure during changeout. Break in new bearing assy. Page 21 of 32 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:45 00:00 1.25 10,231 10,302 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS from 10231'to 10302'MD 6360'TVD ADT-.56 hrs. ECD-12.0 ppg Footage-71' WOB 9-11k RPM's 110 GPM 250 ©2450 psi w/24%flow out PUwt160 SOwt70 ROT wt. 112 Torque on/off btm.- 10-11/9-10 k Total bit hrs. -34.78 hrs. Total jar hrs. 172.81 hrs Max gas-6800 units OA=395 psi. 39/09/2015 Directional Drill 6%"production hole with SLB rotary steerable assembly from 10302'MD to 11718'MD. CBU for geologist. Directional Drill 6%"production hole from 11718' MD to 12058' MD. Change out RCD bearing assy. Directional Drill 6%"production hole from 12058'MD to 12085'MD. 00:00 06:00 6.00 10,302 10,920 PROD1 DRILL DDRL P Drilled 6 3/4" hole w/RSS from 10302'to10920'MD 6355'TVD ADT-5.25 hrs. ECD- 12.19 ppg Footage-618' WOB 8-10k RPM's 130 GPM 260 @ 2670 psi w/26%flow out PU wt 160 SOwt70 ROT wt. 108 Torque on/off btm.-12/10 k Total bit hrs. -40.03 hrs. Total jar hrs. 178.06 hrs Max gas-9900 units 06:00 12:00 6.00 10,920 11,300 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS from 10920'to11300'MD 6373'TVD ADT-3.73 hrs. ECD- 12.24 ppg Footage-380' WOB 9-10k RPM's 140 GPM 260 @ 2670 psi w/26%flow out PU wt 160 SO wt 68 ROT wt. 108 Torque on/off btm.-12/10 k Total bit hrs. -43.76 hrs. Total jar hrs. 181.79 hrs Max gas-9876 units SPR's @ 11205'MD 6358'TVD w/ 10.6 ppg @ 10:30 hrs. #1 20/30 SPM @ 570/800 psi #2 20/30 SPM @ 600/830 psi OA=410 psi Page22of32 Timeer Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 17:30 5.50 11,300 11,718 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS from 11300'to11718'MD 6378'TVD ADT-3.61 hrs. ECD-12.32 ppg Footage-418' WOB 8-10k RPM's 150 GPM 260 @ 2800 psi w/24%flow out PU wt 162 SO wt 60 ROT wt. 105 Torque on/off btm.-12/10 k Total bit hrs.-47.37 hrs. Total jar hrs. 185.4 hrs Max gas-8016 units 17:30 18:15 0.75 11,718 11,718 PROD1 DRILL CIRC T CBU for geologic determination. Circulate and analyze cuttings. Consult with town goelogist and periscope engineers. 233 gpm, 2400 psi,23%FO, 130 rpm, 11k tq, 12.18 ECD. 18:15 22:15 4.00 11,718 12,058 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS from 11718'to12058'MD 6375'TVD ADT-2.82 hrs. ECD- 12.32 ppg Footage-340' WOB 10-12k RPM's 150 GPM 253 @ 2725 psi w/27%flow out PU wt 165 SO wt 64 ROT wt. 105 Torque on/off btm.- 12/10 k Total bit hrs. -50.19 hrs. Total jar hrs. 188.42 hrs Max gas-4873 units 22:15 23:00 0.75 12,058 12,058 PROD1 DRILL MPDA T Change out RCD bearing assy. Hold 400 to 450 psi back pressure during changeout. Break in new bearing assy. SPR's @ 12052' MD 6375'TVD w/ 10.5 ppg @ 23:00 hrs. #1 20/30 SPM @ 655/830 psi #2 20/30 SPM @ 630/950 psi 23:00 00:00 1.00 12,058 12,085 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS from 12058'to 12085' MD 6375'TVD ADT-.2 hrs. ECD-12.32 ppg Footage-27' WOB 10-12k RPM's 150 GPM 251 @ 2725 psi w/27%flow out PU wt 165 SO wt 64 ROT wt. 105 Torque on/off btm.-12/10 k Total bit hrs. -50.39 hrs. Total jar hrs. 188.42 hrs Max gas-6892 units OA=410 psi 09/10/2015 Directional Drill 6%"production hole with SLB rotary steerable assembly from 12085'MD to 14363'MD. Page 23 of 32 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 12,085 12,588 PROD1 DRILL DDRL P Drilled 6 3/4" hole w/RSS from 12085'to12588'MD 6379'TVD ADT-4.55 hrs. ECD- 12.46 ppg Footage-503' WOB 8-12k RPM's 150 GPM 260 ©2920 psi w/27%flow out PU wt 165 SO wt 60 ROT wt. 105 Torque on/off btm.- 13/11 k Total bit hrs. -54.94 hrs. Total jar hrs. 192.97 hrs Max gas-8705 units OA=410 psi 06:00 12:00 6.00 12,588 13,100 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS from 12588'to13100' MD 6400'TVD ADT-3.79 hrs. ECD- 12.46 ppg Footage-512' WOB 12-15k RPM's 150 GPM 260 @ 3020 psi w/27%flow out PU wt 166 SO wt 58 ROT wt. 107 Torque on/off btm.- 14/12 k Total bit hrs. -58.73 hrs. Total jar hrs. 196.76 hrs Max gas-9070 units OA=410 psi SPR's, 13100' MD, TVD=6400, MW 10.6 ppg, 11:30 hours MP#1=20 spm@650 psi, 30spm@950 psi MP#2=20 spm@675 psi, 30 spm@ 1000 psi 12:00 18:00 6.00 13,100 13,800 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS from 13100'to13800' MD 6405'TVD ADT-4.52 hrs. ECD- 12.50 ppg Footage-700' WOB 10-13k RPM's 140 GPM 263 @ 3200 psi w/26%flow out PU wt 170 SO wt 50 ROT wt. 105 Torque on/off btm.-15/12-13 k Total bit hrs. -63.25 hrs. Total jar hrs. 201.28 hrs Max gas-9586 units Page 24 of 32 Time Logs 1 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 13,800 14,363 ''PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS from 13800'to14363'MD 6404'TVD ADT-3.72 hrs. ECD- 12.46 ppg Footage-563' WOB 12-15k RPM's 160 GPM 270 @ 3306 psi w/40%flow out PU wt 185 SO wt 0 ROT wt. 106 Torque on/off btm.-15/12-13 k Total bit hrs. -66.97 hrs. Total jar hrs. 205 hrs Max gas-4023 units OA=390 psi 09/11/2015 Directional Drill 6%"production hole with SLB rotary steerable assembly to TD @14897'MD. CBU. Change out RCD bearing assy. Finger print pore pressure. CBU. BROOH to 14708'MD'. Trouble shoot and repair MPD chokes.BROOH from 14708' MD to 10829' MD. 00:00 05:30 5.50 14,363 14,897 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS from 14363'to14897'MD 6430'TVD• ADT-3.93 hrs. ECD- 12.58 ppg Footage-534' WOB 10-12k RPM's 120 GPM 270 @ 3180 psi w/25%flow out PU wt 184 SO wt 0 ROT wt. 105 Torque on/off btm.- 15/12 k Total bit hrs. -70.90 hrs. Total jar hrs.208.93 hrs Max gas-9901 units SPR's, 14897' MD,TVD=6430, MW 10.6 ppg, 05:30 hours MP#1=20 spm@620 psi, 30spm@920 psi MP#2=20 spm@660 psi, 30 spm@ 980 psi 05:30 07:30 2.00 14,897 14,855 PROD1 CASING CIRC P Circulate hole clean @ 120 rpm,270 gpm=3100 psi. P/U= 188K, S/O= 55K, ROT=110K. SIMOPS, hold PJSM on C/O the RCD bearing 07:30 08:15 0.75 14,855 14,855 PROD1 CASING MPDA T Change out leaking RCD bearing. 08:15 09:15 1.00 14,855 14,897 PROD1 CASING OWFF P Perform finger print to establish formation pore pressure as per rig engineer. Rotate @ 20 rpms, Pore pressure= 11.63 ppg. 09:15 10:45 1.50 14,897 14,897 PROD1 CASING CIRC P CBU @ 260 gpm, 120 rpm to ensure no gas was let into the well bore while performing finger print test. 10:45 11:15 0.50 14,897 14,708 PROD1 CASING BKRM P BROOH(/14897'MD t/14708'MD. 250 gpm, 2890 psi,25%FO, 120 rpm, 12k tq. Page 25 of 32 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:15 12:15 1.00 14,708 14,708 PROD1 CASING MPDA T Unable to open MPD chokes. Trouble shoot control system. Reboot operating system and calibrate chokes. OA=310 psi 12:15 00:00 11.75 14,708 10,829 PROD1 CASING BKRM P BROOH f/14708'MD t/10829'MD. 250 gpm,2850 ICP/2550 FCP psi, 25% FO, 120 rpm, 8.5k tq. Calc disp=21.6 bbls Act disp=28.3 bbls. OA=365 psi Finction tested BOPE Conducted safety stand down w/oncoming crew. 39/12/2015 BROOH f/10829'MD t/8087'MD. POOH on elevators f/8087' MD t/7800' MD. Tight hole @7825'MD. Attempt to circ. RIH to 8080'MD Attempt to establish circ. RIH to 8371' MD. Establish circ w/full returns. BROOH to 7790' MD. Pack off. RIH to 7800'MD. Establish circ. BROOH to 7770' MD. Pack off. Establish circ.Attempt to BROOH. Pack off @ 7775' MD. Establish circ. BROOH to 7650'MD. 00:00 07:00 7.00 10,829 8,277 PROD1 CASING BKRM P BROOH from 10829'MD to 8277'MD at 1000 ft/hr, 250 gpm, 110 rpm 07:00 08:15 1.25 8,277 8,087 PROD1 CASING BKRM P Reduced speed to 250 ft/hr to cirulate hole clean while back reaming. BROOH from 8277'MD to 8087' MD. P/U 145k, S/O 88k, ROT 80k 08:15 09:00 0.75 8,087 7,887 PROD1 CASING TRIP T POOH on elevators from 8087'MD to 7800' MD. Maintained constant bottom hole pressure of 11.8 ppg at the shoe with MPD back pressure. Started seeing overpull of 20k at 7830'increasing to 50k overpull at 7825'. Ran stand down and pulled up to 7800'with 50k overpull.ran back down and screwed in to topdrive. Page 26 of 32 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 14:30 5.50 7,887 8,371 PROD1 CASING CIRC T Attempted to establish circulation with full rate and rotation with sporadic flow at surface, continued to RIH and worked sections of flow but lacked full returns. Continued RIH with 3 stands to 8080' MD, looking for stable flow.Worked string and rotated 40 rpm with 3.5 bpm. charged formation up to 500+psi at surface with losses and increased MPD back pressure to 300-400 psi to equalize and initiate flow. Started initiating full returns at 8180'and stepped rate up to 6 bpm before losing circulation again. Continued to run 2 more stands down to 8371' MD(BHA below the shales)and established circulation with full returns. OA=270 psi Total losses for tour=237.74 bbls Conducted safety stand down w/oncoming crew. 14:30 18:15 3.75 8,371 7,800 PROD1 CASING BKRM T BROOH f/8371' MD t/7790' MD. 250 gpm, 2400 psi, 80 rpm, 6k tq,24% FO. Packed off. RIH to 7800' MD. 18:15 20:00 1.75 7,800 7,800 PROD1 CASING CIRC T Establish circulation. Stage pump up to 5 bpm, 20 rpm. 1750 psi, 5-10k tq. 20:00 20:15 0.25 7,800 7,777 PROD1 CASING BKRM T BROOH f/7800 t/7770' MD. Packed off w/minimal returns. RIH to 7777' _ MD. 20:15 22:30 2.25 7,777 7,775 PROD1 CASING CIRC T Establish circulation. Stage pump up to 5 bpm, Stage rotary up to 60 rpm. 1750 psi, 5-10k tq.Attempt to BROOH. Pack off @ 7775' MD. Reestablish circ. 5 bpm,20 rpm, 1750 psi. 22:30 00:00 1.50 7,775 7,650 PROD1 CASING BKRM P Slow pump to 2 bpm. BROOH f/7775'MD t/7650 MD'20 rpm, 800 psi, 18% FO, 5-15K.tq, PU wt=115K OA=230 psi. Total losses for tour=30 bbls 39/13/2015 BROOH to shoe @ 7582'MD. Packed off.Work pipe and establish circ. BROOH to 7490'MD. CBU x 2. Monitor well.Wait on ASRC vac truck.Lay in 12.1 ppg hi-vis pill from 7492'MD to 6760'MD. Displace well to 12.1 ppg brine. OWFF. Remove RCD bearing assy. Install trip nipple. POOH. Lay down BHA. Rig up to run 4 1/2"slotted liner. PU slotted liner to 3497'MD. 00:00 00:45 0.75 7,650 7,582 PROD1 CASING BKRM P BROOH f/7650' MD t/7582' MD.2 bpm, 800 psi, 18%FO, 20 rpm, 5-15K tq. Pack off @ 7582'MD. 00:45 04:00 3.25 7,582 7,614 PROD1 CASING CIRC T Work pipe down to 7614'MD and establish circulation. 1.5 bpm, 700 psi,6-8% FO,20 rpm, 5-6K tq. Page 27 of 32 Time Logs 411 Date From To Dur S. Depth E. Death'.Phase Code Subcode T Comment 04:00 04:45 0.75 7,614 7,490 PROD1 CASING BKRM P BROOH f/7614' MD t/7490' MD. 1.5 bpm, 700 psi,6-8%FO, 20 rpm, 5-6K tq. 04:45 06:30 1.75 7,490 7,490 PROD1 CASING CIRC P Circ hole clean. 240 gpm,2300 psi, 47%FO, 60 rpm, 5K tq, PU 121K, SO 110K, Rot 115K. Reciprocate f/7490'MD t/7421' MD. 06:30 07:00 0.50 7,490 7,490 PROD1 CASING OWFF P Shut in MPD chokes and monitor pressure. Sim-ops/PJSM on fluid displacement. 07:00 08:00 1.00 7,490 7,490 PROD1 CASING WAIT T Wait on ASRC vac truck. Mechanical problem with D-mag pump on truck. 08:00 08:30 0.50 7,490 7,492 PROD1 CASING DISP P Spot 75 bbls 12.1 ppg hi-vis spacer in drill pipe to bit.4 bpm, 1250 psi. 08:30 09:45 1.25 7,492 6,760 PROD1 CASING DISP P POOH f/7492' MD t/6760'MD laying in 33 bbls 12.1 ppg hi-vis spacer. 2000 FPH, 1.5 bpm,450 psi, 60 rpm, 6K tq, 09:45 10:45 1.00 6,760 6,760 PROD1 CASING DISP P Displace well over to 12.1 ppg brine. 5 bpm, 1400 psi, 55% FO, 60 rpm, 5K tq, FCP=1350 psi. PU 135K SO 95K Rot 115K 10:45 11:30 0.75 6,760 6,760 PROD1 CASING OWFF P OWFF. Slight flow to static. 11:30 12:00 0.50 6,760 6,760 PROD1 CASING MPDA P Flush MPD choke skid w/fresh water. Blow down MPD lines and choke skid. OA=220 psi Total losses for tour=52 bbls. 12:00 12:45 0.75 6,760 6,760 PROD1 CASING MPDA P Remove RCD bearing assy. Install trip nipple. Remove and plug MPD return line.Line up for trip nipple operations 12:45 14:00 1.25 6,760 6,760 PROD1 CASING RURD P Blow down kill line. Clean out under shakers and returns trough. Obtain SPR's. Drop 2.25"OD rabbit. SPR's, 6763'MD, TVD=5944, MW 12.1 ppg, 12:55 hours MP#1=20 spm@220 psi, 30spm@510 psi MP#2=20 spm@250 psi, 30 spm@ 520 psi 14:00 16:30 2.50 6,760 520 PROD1 CASING TRIP P POOH on elevators f/6760' MD t/520' MD. OWFF f/5 min. Static. Retrieve rabbit. 16:30 17:15 0.75 520 241 PROD1 CASING BHAH P Lay down HWDP and jars. Change out elevators. 17:15 19:00 1.75 241 0 PROD1 CASING BHAH P Lay down BHA. Remove nuclear sources. Calc disp=41.92 bbls Act disp=51.82 bbls 19:00 19:30 0.50 0 0 PROD1 CASING BHAH P Clean and clear rig floor 19:30 20:30 1.00 0 0 COMPZ CASING RURD P Mobilize liner running equip to rig floor. Rig up to run 4 1/2"IBTM slotted liner. Page 28 of 32 Time Logs I Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:30 00:00 3.50 0 3,497 COMPZ CASING PUTB P PU 4 1/2" 11.6# IBTM slotted/blank liner to 3497'MD. Calc disp=14.25 bbls Act disp=9.69 bbls PU 63K SO 60K OA=210 psi X9/14/2015 PU 4 1/2"slotted liner. RIH w/slotted liner on DP to 14885'MD. Circ DP volumn. Set liner hanger and packer. Test packer to 3000 psi/5 min. Release from packer. CBU x 2. Spot corrosion inhibitor f/7314' MD t/6489' MD. OWFF. POOH w/DP. 00:00 03:30 3.50 3,497 7,273 COMPZ CASING PUTB P PU 4 1/2" 11.6# IBTM slotted/blank liner from 3497' MD to 7273' MD.. Calc disp=19.76 bbls Act disp=11.22 bbls PU 102K SO 80K Rot 90K 03:30 03:45 0.25 7,273 7,273 COMPZ CASING OTHR P Mobilize Baker tools to rig floor. Obtain parameters. PU 102K SO 80K Rot 90K 03:45 04:15 0.50 7,273 7,470 COMPZ CASING PUTB P PU 4 1/2" 11.6# IBTM slotted/blank liner from 7273'MD to 7470' MD. 4 1/2" 11.6#IBTM, 0 rejects/0 remakes 04:15 05:30 1.25 7,470 7,535 COMPZ CASING OTHR P MU SBE and ZXP liner top packer/hanger. Mix and set pal mix. 05:30 07:30 2.00 7,535 7,551 COMPZ CASING OTHR T Pick up one stand DP. RIH to 7643' MD.Attempt to pump through string. Unable to pump. Bleed off pressure and stand back DP.Attempt to pump through packer. Unable to pump. Break out ZXP packer. Break out inner string seal assy. 1.9"OD rabbit found in inner string. Remove rabbit, make up inner string and packer. PU one stand DP. RIH to 7551' MD. 07:30 07:45 0.25 7,551 7,551 COMPZ CASING CIRC P Pump through string. 3 bpm,60 psi, 3% FO. 07:45 12:00 4.25 7,551 12,940 COMPZ CASING RUNL P RIH w/slotted liner on DP from 7551' MD to 12940' MD as per trip schedule. PU 150K SO 80K Calc disp=29.7 bbls Act disp=21.76 bbls. OA=200 psi 12:00 15:15 3.25 12,940 14,885 COMPZ CASING RUNL P Continue to RIH w/slotted liner on DP from 12940'MD to 14890'MD. Tag TD on depth. Lay down single DP. PU to liner setting depth @ 14885' MD,TOL @ 7346'MD. PU 180K SO 70K Calc disp=42.12 bbls Act disp=28.11 bbls. 15:15 16:00 0.75 14,885 14,885 COMPZ CASING CIRC P Circ one DP volume. 3 bpm, 280 psi, 12%FO. Page 29 of 32 Time Logs • Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 16:00 17:00 1.00 14,885 14,885 COMPZ'1 CASING PACK P Set liner top packer/hanger per Baker Rep. drop 1.5"ball&pump down at 2 bpm, 100 psi, ball on seat with 630 strokes. Shoe @ 14885' MD, Liner Top @ 7346' MD. 17:00 17:30 0.50 14,885 14,885 COMPZ CASING PRTS P Rig up&test liner top to 3000 psi for 5 min good. Rig down test equipment. 17:30 20:00 2.50 14,885 7,283 COMPZ WELLPF CIRC P Unsting from liner top 7346'-7283' MD &circulate till 12.1 ppg brine in&out 5 bpm,450 psi, FO 13%. 20:00 20:15 0.25 7,283 7,283 COMPZ WELLPF OWFF P OWFF. Slight decreasing flow. 20:15 20:30 0.25 7,283 7,314 COMPZ WELLPF CIRC P RIH to 7314' MD. Spot 25 bbls 12.1 brine inhibited w/Concor 303A f/7314' MD t/6489'MD. 20:30 21:15 0.75 7,314 7,314 COMPZ WELLPF OWFF P OWFF. Slight flow to static. 21:15 21:45 0.50 7,314 7,219 COMPZ WELLPF RURD P POOH f/7314' MD t/7219'MD. Blow down top drive and kill line. Rig down circ equipment. 21:45 00:00 2.25 7,219 0 COMPZ WELLPF TRIP P POOH f/7219' MD Calc disp=41.04 bbls Act disp=46.07 bbls 09/15/2015 'I Lay down liner running tool. Flush BOPE. Pull wear bushing. Cut drilling line. RU&3 1/2"upper completion as per detail.Test seals. Space out and land hanger.Test hanger seals. ND MPD. 00:00 00:45 0.75 0 0 COMPZ WELLPF BHAH P PJSM; lay down liner running tools as per Baker Rep. 00:45 01:30 0.75 0 0 COMPZ RPCOM WWWH P PJSM; flush out stack&pull wear bushing. 01:30 02:15 0.75 0 0 COMPZ RPCOM RURD P PJSM; clear&clean rig floor. 02:15 03:30 1.25 0 0 COMPZ RPCOM SLPC P PJSM; slip&cut 65'of drill line. 03:30 04:30 1.00 0 0 COMPZ RPCOM RURD P PJSM; rig up to run 3-1/2"tubing. 04:30 05:15 0.75 0 109 COMPZ RPCOM PUTB P PJSM; RIH w/9.3#, L-80, 3-1/2" EUE tubing as per detail from surface to 109' MD. Kick w/Tripping Drill CRT 120 sec @ 05:00 hrs. 05:15 05:30 0.25 109 109 COMPZ RPCOM PRTS P PJSM; pressure test Mirage plug to 1000 psi for 5 min charted. 05:30 06:45 1.25 109 829 COMPZ RPCOM PUTB P PJSM; continue RIH w/9.3#, L-80, 3-1/2"EUE tubing as per detail from109'-829'MD. 06:45 07:00 0.25 829 829 COMPZ RPCOM PRTS P PJSM; pressure test Mirage Plug w/ SOV to 1000 psi for 5 min charted. 07:00 11:00 4.00 829 5,007 COMPZ RPCOM PUTB P PJSM; continue RIH w/9.3#, L-80, 3-1/2"EUE tubing as per detail from829'-5007'MD. 11:00 11:15 0.25 5,007 5,007 'COMPZ RPCOM PRTS P PJSM; pressure test tubing to 3000 psi for 5 min charted. Page 30 of 32 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:15 12:00 0.75 5,007 5,507 COMPZ RPCOM PUTB P PJSM; continue RIH w/9.3#, L-80, 3-1/2"EUE tubing as per detail from 5007'-5507' MD. Started taking weight @ 5500' MD. PU 77K, SO 67K, calculated displacement 17.93, actual 10.54 bbls. Losses for tour 10.79 bbls OA pressure 210 psi. 12:00 12:15 0.25 5,507 5,507 COMPZ RPCOM PRTS P PJSM; pressure test Mirage plug to 3000 psi to verify plug holding. 12:15 12:30 0.25 5,507 5,509 COMPZ RPCOM OTHR T Drain stack to verify there was nothing hanging up in stack, Rotate tubing 3/4 turn for weight to break free. 12:30 14:45 2.25 5,509 7,324 COMPZ RPCOM PUTB P PJSM; continue RIH w/9.3#, L-80, 3-1/2"EUE tubing as per detail from 5509'-7324'MD. Calculated displacement for entire run 25.09, actual 16.2 bbls. PU 90K, SO 69K. 14:45 15:45 1.00 7,324 7,408 COMPZ RPCOM HOSO P PJSM; space out picking up jts 229, 230, &21'of jt 231 to tag no-go @ 7408' MD. Rig up testing equipment then pick up&re-tag no-go. 15:45 16:45 1.00 7,408 7,408 COMPZ RPCOM PRTS P PJSM,test tubing to 3000 psi for 5 min charted. Bleed tubing to 2000 psi test IA to 3500 psi for 30 min charted. Bleed all psi to 0. 16:45 18:00 1.25 7,408 7,378 COMPZ RPCOM HOSO P PJSM, lay down 3 joints, PU 8.16' pup joint,XO, 1 joint of 4-1/2", hanger&landing joint. 18:00 19:30 1.50 7,378 7,378 COMPZ RPCOM THGR P PJSM; land hanger& RILDS. Attempt to test hangers seals. 19:30 21:45 2.25 7,378 7,404 COMPZ RPCOM THGR T PJSM;several attempts to tighten& retest seals. Located torque multiplier to put correct torque on lock down&test for 15 min @ 5000 psi,witnessed by CPAI Rep. 21:45 00:00 2.25 0 0 COMPZ WHDBO MPDA P PJSM; nipple down MPD. SIMOPS C/O saver sub on TD from 4"XT39 to 4-1/2"IF. 09/16/2015 Nipple down BOPE. Nipple up&PT tree. Pull BPV. Test tubing&IA,then shear SOV.Attempt to activate Mirage plug. Freeze protect well.Attempt to set BPV. Lay down 4"DP. 00:00 01:00 1.00 0 0 COMPZ WHDBO NUND P PJSM; nipple down BOPE. 01:00 05:00 4.00 0 0 COMPZ WHDBO NUND P PJSM; nipple up tree adapter flange. 05:00 06:30 1.50 0 0 COMPZ WHDBO PRTS P PJSM;test SRL&neck seals to 5000 psi for 5 min,good. Test void to 250 psi for 5 min&5000 psi for 15 min, good. 06:30 07:00 0.50 0 0 COMPZ WHDBO NUND P PJSM; nipple up tree. 07:00 07:45 0.75 0 0 COMPZ WHDBO RURD P PJSM; set up scaffolding around well head. SIMOPS rig up to circulate& test. 07:45 08:00 0.25 0 0 COMPZ WHDBO NUND P Open actuator valve on tree, per CIW Rep. Page 31 of 32 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 08:30 0.50 0 0 COMPZ WHDBO PRTS P PJSM;test tree to 250&5000 psi, good. 08:30 09:15 0.75 0 0 COMPZ WHDBO MPSP P PJSM; pull test dart&BPV per CIW Rep. 09:15 10:00 0.75 0 0 COMPZ WHDBO SEQP P PJSM; finish rigging up surface lines &test to 2500 psi. 10:00 11:30 1.50 0 0 COMPZ WHDBO PRTS P PJSM;test tubing to 2500 psi for 30 min, charted. Bleed pressure to 2000 psi. Pressure test IA to 3500 psi for 30 min, charted. Dump tubing pressure&observe SOV shear at 2700 psi.All pressure bled to 0 psi. 11:30 13:45 2.25 0 0 COMPZ WHDBO PRTS T PJSM; pressure up tubing to 3700 psi for 5 min,then pressure up to 4150 for 5 min. Did not activate Mirage plug. Pressure bled to 0 psi. Pressure up to 4200 psi holding for 2 min, continue pressuring up to 4900 psi for 2 min.All pressure bled off. Another attempt made to 4900 psi. Three more attempts made to 4200 psi holding 2 min each time with no activation. 13:45 14:00 0.25 0 0 COMPZ WHDBO CIRC P Circulate around tubing to IA to verify communication @ 1.5 bpm,400 psi, 11 bbls pumped. 14:00 17:00 3.00 0 0 COMPZ WHDBO FRZP P PJSM; rig up&test lines to 2500 psi from LRS. Pump freeze protect @ 2 bpm, ICP 850 psi, FCP 2600 psi, total of 272 bbls pumped. Pressured up to 4500 psi to verify Mirage plug had not activated. SIMOPS lay down 47 stands of 4" DP from derrick. 17:00 17:30 0.50 0 0 COMPZ WHDBO PULD P Continue laying down DP, 10 stands. 17:30 19:00 1.50 0 0 COMPZ WHDBO FRZP P PJSM; blow down&rig down lines from freeze protect. 19:00 19:30 0.50 0 0 COMPZ WHDBO PULD P Continue laying down DP,9 stands. 19:30 21:15 1.75 0 0 COMPZ WHDBO MPSP T PJSM; rig up lubricator. Threads would not make up on tree. Rig down lubricator to change out for another from the valve shop. 21:15 00:00 2.75 0 0 COMPZ WHDBO PULD P Continue laying down 4"DP from derrick for a total of 100 stands for the tour. 09/17/2015 Finish laying down 4" DP. Set BPV&secure well. Rig release @ 06:00 hrs. 00:00 03:30 3.50 0 0 COMPZ WHDBO PULD P PJSM; lay down 55 stands of 4" DP. 03:30 05:00 1.50 0 0 COMPZ WHDBO MPSP P PJSM, prep&rig up lubricator. Set type H BPV as per Cameron Rep. 05:00 06:00 1.00 0 0 DEMOB MOVE RURD P PJSM;secure well, install blind flanges, install gauges&suck out cellar. OA pressure 200 psi Tubing pressure 1000 psi Rig Release 06:00 hrs. Page 32 of 32 I • • NADConversion Kuparuk River Unit Kuparuk 2S Pad 2S-10 Definitive Survey Report 24 September, 2015 NAD 27 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-10 Project: Kuparuk River Unit TVD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Site: Kuparuk 2S Pad MD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Well: 2S-10 North Reference: True Wellbore: 2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States ,ws.. ....,o, IhMadW 9ffii CNtlp 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 2S-10 Well Position +N/-S 0.00 usft Northing: 5,929,979.72 usfl Latitude: 70°13'11.496 N +E/-W 0.00 usft Easting: 481,044.13 usfl Longitude: 150°9'10.528 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 120.00 usft Wellbore 2S-10 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 9/5/2015 18.60 80.87 57,489 Design 2S-10 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.50 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 27.50 0.00 0.00 195.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 93.90 462.50 2S-10 Srvy#1 Gyro(2S-10) GYD-GC-MS Gyrodata gyrocompassing m/s 9/4/2015 12:02 506.90 2,627.01 2S-10 Srvy#2 MWD+IFR-AK-CAZ-SC(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/4/2015 12:17 2,725.17 7,429.08 2S-10 Srvy#3 MWD+IFR-AK-CAZ-SC(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/4/2015 12:31 7,519.07 14,834.45 2S-10 Srvy#4 MWD+IFR-AK-CAZ-SC(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/8/2015 11:3. 14,896.00 14,896.00 2S-10 Srvy#5-Projection to TD(2S-10) BLIND Blind drilling 9/24/2015 2:41 Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 27.50 0.00 0.00 27.50 -120.00 0.00 0.00 5,929,979.72 481,044.13 0.00 0.00 UNDEFINED 94.40 0.45 73.93 94.40 -53.10 0.07 0.25 5,929,979.79 481,044.38 0.67 -0.14 GYD-GC-MS(1) 107.50 0.46 73.22 107.50 -40.00 0.10 0.35 5,929,979.82 481,044.48 0.11 -0.19 GYD-GC-MS(11 NOT an Actual Survey 16"x 42" 186.50 0.54 69.67 186.50 39.00 0.32 1.01 5,929,980.04 481,045.14 0.11 -0.57 GYD-GC-MS(1) 278.70 0.58 73.72 278.69 131.19 0.61 1.86 5,929,980.32 481,045.99 0.06 -1.07 GYD-GC-MS(1) 370.80 0.73 77.64 370.79 223.29 0.86 2.88 5,929,980.57 481,047.01 0.17 -1.58 GYD-GC-MS(1) 506.90 0.78 74.23 506.87 359.37 1.30 4.62 5,929,981.01 481,048.75 0.05 -2.45 MWD+IFR-AK-CAZ-SC(2) 598.44 0.51 89.00 598.41 450.91 1.48 5.63 5,929,981.18 481,049.76 0.34 -2.88 MWD+IFR-AK-CAZ-SC(2) 696.00 1.69 54.94 695.95 548.45 2.31 7.24 5,929,982.01 481,051.38 1.33 -4.10 MWD+IFR-AK-CAZ-SC(2) 788.22 2.43 45.82 788.11 640.61 4.45 9.76 5,929,984.15 481,053.90 0.88 -6.83 MWD+IFR-AK-CAZ-SC(2) 9/24/2015 3:14:03PM Page 2 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-10 Project: Kuparuk River Unit TVD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Site: Kuparuk 2S Pad MD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Well: 2S-10 North Reference: True Wellbore: 2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E1-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 880.07 3.57 31.30 879.83 732.33 8.25 12.64 5,929,987.94 481,056.79 1.48 -11.24 MWD+IFR-AK-CAZ-SC(2) 972.37 5.71 29.21 971.82 824.32 14.72 16.37 5,929,994.40 481,060.54 2.33 -18.45 MWD+IFR-AK-CAZ-SC(2) 1,065.00 7.70 32.99 1,063.82 916.32 23.95 22.00 5,930,003.61 481,066.19 2.20 -28.82 MWD+IFR-AK-CAZ-SC(2) 1,115.38 9.02 32.68 1,113.66 966.16 30.10 25.97 5,930,009.75 481,070.17 2.62 -35.80 MWD+IFR-AK-CAZ-SC(2) 1,158.68 10.08 31.52 1,156.36 1,008.86 36.19 29.78 5,930,015.83 481,074.00 2.49 -42.66 MWD+IFR-AK-CAZ-SC(2) 1,216.08 11.15 32.19 1,212.78 1,065.28 45.17 35.37 5,930,024.79 481,079.61 1.88 -52.78 MWD+IFR-AK-CAZ-SC(2) 1,251.55 12.84 31.28 1,247.47 1,099.97 51.44 39.24 5,930,031.05 481,083.50 4.79 -59.84 MWD+IFR-AK-CAZ-SC(2) 1,345.39 14.91 29.17 1,338.57 1,191.07 70.89 50.54 5,930,050.48 481,094.84 2.27 -81.56 MWD+IFR-AK-CAZ-SC(2) 1,438.07 15.95 33.62 1,427.91 1,280.41 91.91 63.40 5,930,071.46 481,107.76 1.70 -105.19 MWD+IFR-AK-CAZ-SC(2) 1,531.92 19.06 42.90 1,517.42 1,369.92 113.88 80.98 5,930,093.39 481,125.39 4.44 -130.96 MWD+IFR-AK-CAZ-SC(2) 1,626.66 20.25 56.47 1,606.69 1,459.19 134.28 105.19 5,930,113.73 481,149.65 4.97 -156.93 MWD+IFR-AK-CAZ-SC(2) 1,719.09 20.73 63.37 1,693.28 1,545.78 150.45 133.15 5,930,129.82 481,177.65 2.66 -179.79 MWD+IFR-AK-CAZ-SC(2) 1,814.62 22.50 71.62 1,782.11 1,634.61 163.80 165.62 5,930,143.09 481,210.15 3.68 -201.08 MWD+IFR-AK-CAZ-SC(2) 1,909.13 24.42 81.56 1,868.84 1,721.34 172.37 202.13 5,930,151.57 481,246.67 4.65 -218.81 MWD+IFR-AK-CAZ-SC(2) 2,002.26 25.90 86.94 1,953.14 1,805.64 176.29 241.49 5,930,155.38 481,286.04 2.92 -232.78 MWD+IFR-AK-CAZ-SC(2) 2,094.67 26.33 88.82 2,036.12 1,888.62 177.78 282.13 5,930,156.78 481,326.68 1.01 -244.75 MWD+IFR-AK-CAZ-SC(2) 2,187.42 26.80 88.37 2,119.08 1,971.58 178.80 323.60 5,930,157.69 481,368.14 0.55 -256.46 MWD+IFR-AK-CAZ-SC(2) 2,280.73 26.91 89.57 2,202.32 2,054.82 179.56 365.74 5,930,158.34 481,410.28 0.59 -268.10 MWD+IFR-AK-CAZ-SC(2) 2,373.10 27.01 89.98 2,284.66 2,137.16 179.72 407.62 5,930,158.40 481,452.16 0.23 -279.10 MWD+IFR-AK-CAZ-SC(2) 2,465.75 27.03 89.30 2,367.19 2,219.69 179.99 449.71 5,930,158.56 481,494.24 0.33 -290.25 MWD+IFR-AK-CAZ-SC(2) 2,558.55 26.95 89.74 2,449.89 2,302.39 180.34 491.82 5,930,158.81 481,536.35 0.23 -301.49 MWD+IFR-AK-CAZ-SC(2) 2,627.01 27.67 89.48 2,510.71 2,363.21 180.56 523.23 5,930,158.94 481,567.76 1.07 -309.83 MWD+IFR-AK-CAZ-SC(2) 2,688.00 28.50 88.03 2,564.52 2,417.02 181.19 551.93 5,930,159.50 481,596.46 1.76 -317.86 MWD+IFR-AK-CA7-SC(31 NOT an Actual Survey 10 3/4"x 13-1/2 2,725.17 29.01 87.18 2,597.11 2,449.61 181.93 569.80 5,930,160.20 481,614.33 1.76 -323.21 MWD+IFR-AK-CAZ-SC(3) 2,816.64 28.66 86.99 2,677.24 2,529.74 184.18 613.86 5,930,162.34 481,658.39 0.40 -336.78 MWD+IFR-AK-CAZ-SC(3) 2,864.99 28.61 86.53 2,719.68 2,572.18 185.49 636.99 5,930,163.59 481,681.52 0.47 -344.03 MWD+IFR-AK-CAZ-SC(3) 2,909.92 28.71 85.72 2,759.10 2,611.60 186.94 658.49 5,930,164.99 481,703.02 0.89 -351.00 MWD+IFR-AK-CAZ-SC(3) 3,004.46 28.58 86.65 2,842.07 2,694.57 189.96 703.71 5,930,167.89 481,748.24 0.49 -365.62 MWD+IFR-AK-CAZ-SC(3) 3,099.67 28.49 85.34 2,925.72 2,778.22 193.14 749.08 5,930,170.95 481,793.61 0.66 -380.43 MWD+IFR-AK-CAZ-SC(3) 3,194.74 28.21 84.10 3,009.38 2,861.88 197.29 794.03 5,930,174.99 481,838.57 0.69 -396.07 MWD+IFR-AK-CAZ-SC(3) 3,289.77 28.47 83.37 3,093.02 2,945.52 202.21 838.87 5,930,179.80 481,883.42 0.46 -412.44 MWD+IFR-AK-CAZ-SC(3) 3,378.65 28.38 82.95 3,171.19 3,023.69 207.25 880.87 5,930,184.74 481,925.43 0.25 -428.17 MWD+IFR-AK-CAZ-SC(3) 3,471.79 28.42 84.19 3,253.12 3,105.62 212.21 924.89 5,930,189.59 481,969.46 0.63 -444.36 MWD+IFR-AK-CAZ-SC(3) 3,566.57 28.45 85.54 3,336.47 3,188.97 216.25 969.84 5,930,193.51 482,014.41 0.68 -459.89 MWD+IFR-AK-CAZ-SC(3) 3,657.96 28.58 85.71 3,416.77 3,269.27 219.58 1,013.34 5,930,196.73 482,057.92 0.17 -474.37 MWD+IFR-AK-CAZ-SC(3) 3,751.66 28.48 87.25 3,499.09 3,351.59 222.33 1,058.01 5,930,199.37 482,102.58 0.79 -488.58 MWD+IFR-AK-CAZ-SC(3) 3,843.69 28.54 88.26 3,579.96 3,432.46 224.05 1,101.90 5,930,200.98 482,146.48 0.53 -501.60 MWD+IFR-AK-CAZ-SC(3) 3,936.51 28.60 87.63 3,661.48 3,513.98 225.64 1,146.26 5,930,202.46 482,190.84 0.33 -514.62 MWD+IFR-AK-CAZ-SC(3) 4,029.03 28.51 86.43 3,742.75 3,595.25 227.93 1,190.42 5,930,204.64 482,235.00 0.63 -528.27 MWD+IFR-AK-CAZ-SC(3) 9/14/1015 3:14:03PM Page 3 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: NADConversionLocal Co-ordinate Reference: Well 2S-10 it Project: Kuparuk River Unit TVD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Site: Kuparuk 2S Pad MD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Well: 2S-10 North Reference: True Wellbore: 2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,123.62 28.53 87.35 3,825.86 3,678.36 230.38 1,235.52 5,930,206.97 482,280.10 0.46 -542.30 MWD+IFR-AK-CAZ-SC(3) 4,217.11 28.59 87.17 3,907.97 3,760.47 232.51 1,280.16 5,930,209.00 482,324.74 0.11 -555.92 MWD+IFR-AK-CAZ-SC(3) 4,310.04 28.60 88.34 3,989.57 3,842.07 234.26 1,324.60 5,930,210.63 482,369.18 0.60 -569.11 MWD+IFR-AK-CAZ-SC(3) 4,404.28 28.51 89.38 4,072.35 3,924.85 235.15 1,369.64 5,930,211.41 482,414.22 0.54 -581.63 MWD+IFR-AK-CAZ-SC(3) 4,495.10 28.46 89.55 4,152.17 4,004.67 235.56 1,412.95 5,930,211.71 482,457.53 0.10 -593.23 MWD+IFR-AK-CAZ-SC(3) 4,590.23 28.35 88.97 4,235.85 4,088.35 236.14 1,458.20 5,930,212.18 482,502.77 0.31 -605.51 MWD+IFR-AK-CAZ-SC(3) 4,682.03 28.23 89.55 4,316.68 4,169.18 236.70 1,501.70 5,930,212.63 482,546.27 0.33 -617.31 MWD+IFR-AK-CAZ-SC(3) 4,776.69 28.21 94.78 4,400.11 4,252.61 235.02 1,546.39 5,930,210.83 482,590.95 2.61 -627.24 MWD+IFR-AK-CAZ-SC(3) 4,869.45 28.69 99.99 4,481.68 4,334.18 229.33 1,590.18 5,930,205.03 482,634.72 2.72 -633.08 MWD+IFR-AK-CAZ-SC(3) 4,961.45 27.81 106.66 4,562.74 4,415.24 219.34 1,632.50 5,930,194.94 482,677.01 3.56 -634.39 MWD+IFR-AK-CAZ-SC(3) 5,055.86 26.77 113.98 4,646.66 4,499.16 204.38 1,673.03 5,930,179.88 482,717.51 3.72 -630.43 MWD+IFR-AK-CAZ-SC(3) 5,149.51 28.34 121.09 4,729.71 4,582.21 184.32 1,711.35 5,930,159.73 482,755.77 3.89 -620.97 MWD+IFR-AK-CAZ-SC(3) 5,242.84 29.66 127.18 4,811.35 4,663.85 158.92 1,748.73 5,930,134.23 482,793.08 3.46 -606.11 MWD+IFR-AK-CAZ-SC(3) 5,335.66 29.54 130.70 4,892.07 4,744.57 130.12 1,784.38 5,930,105.35 482,828.65 1.88 -587.52 MWD+IFR-AK-CAZ-SC(3) 5,426.94 29.94 133.79 4,971.33 4,823.83 99.68 1,817.88 5,930,074.83 482,862.08 1.74 -566.79 MWD+IFR-AK-CAZ-SC(3) 5,519.21 30.13 138.65 5,051.22 4,903.72 66.36 1,849.81 5,930,041.43 482,893.92 2.64 -542.86 MWD+IFR-AK-CAZ-SC(3) 5,611.31 31.24 142.26 5,130.43 4,982.93 30.11 1,879.70 5,930,005.11 482,923.72 2.33 -515.59 MWD+IFR-AK-CAZ-SC(3) 5,703.86 32.97 146.14 5,208.83 5,061.33 -9.78 1,908.43 5,929,965.15 482,952.34 2.91 -484.49 MWD+IFR-AK-CAZ-SC(3) 5,798.71 34.68 151.60 5,287.64 5,140.14 -54.97 1,935.65 5,929,919.90 482,979.44 3.68 -447.89 MWD+IFR-AK-CAZ-SC(3) 5,892.26 36.97 156.04 5,363.50 5,216.00 -104.10 1,959.74 5,929,870.71 483,003.41 3.70 -406.67 MWD+IFR-AK-CAZ-SC(3) 5,985.23 39.27 160.70 5,436.66 5,289.16 -157.43 1,980.83 5,929,817.33 483,024.36 3.96 -360.61 MWD+IFR-AK-CAZ-SC(3) 6,078.55 40.79 164.67 5,508.12 5,360.62 -214.72 1,998.65 5,929,760.00 483,042.04 3.18 -309.89 MWD+IFR-AK-CAZ-SC(3) 6,173.63 43.21 167.37 5,578.78 5,431.28 -276.45 2,013.98 5,929,698.24 483,057.21 3.18 -254.23 MWD+IFR-AK-CAZ-SC(3) 6,265.92 45.61 168.60 5,644.70 5,497.20 -339.61 2,027.41 5,929,635.05 483,070.48 2.76 -196.69 MWD+IFR-AK-CAZ-SC(3) 6,357.04 48.09 169.16 5,707.02 5,559.52 -404.84 2,040.22 5,929,569.80 483,083.13 2.76 -137.01 MWD+IFR-AK-CAZ-SC(3) 6,451.06 50.46 169.97 5,768.35 5,620.85 -474.91 2,053.12 5,929,499.70 483,095.85 2.60 -72.66 MWD+IFR-AK-CAZ-SC(3) 6,544.59 53.52 172.52 5,825.95 5,678.45 -547.73 2,064.30 5,929,426.86 483,106.84 3.91 -5.22 MWD+IFR-AK-CAZ-SC(3) 6,638.03 56.27 175.01 5,879.68 5,732.18 -623.70 2,072.57 5,929,350.87 483,114.92 3.66 66.03 MWD+IFR-AK-CAZ-SC(3) 6,731.17 57.89 176.93 5,930.30 5,782.80 -701.69 2,078.05 5,929,272.89 483,120.21 2.45 139.94 MWD+IFR-AK-CAZ-SC(3) 6,825.34 59.14 179.50 5,979.49 5,831.99 -781.94 2,080.54 5,929,192.63 483,122.50 2.68 216.82 MWD+IFR-AK-CAZ-SC(3) 6,919.12 60.23 180.98 6,026.83 5,879.33 -862.90 2,080.20 5,929,111.69 483,121.95 1.79 295.10 MWD+IFR-AK-CAZ-SC(3) 7,011.64 61.40 182.28 6,071.95 5,924.45 -943.63 2,077.90 5,929,030.97 483,119.44 1.76 373.68 MWD+IFR-AK-CAZ-SC(3) 7,106.70 64.15 184.57 6,115.44 5,967.94 -1,027.99 2,072.83 5,928,946.63 483,114.16 3.60 456.48 MWD+IFR-AK-CAZ-SC(3) 7,200.31 66.80 186.14 6,154.29 6,006.79 -1,112.77 2,064.87 5,928,861.87 483,105.99 3.22 540.43 MWD+IFR-AK-CAZ-SC(3) 7,293.03 70.01 187.65 6,188.41 6,040.91 -1,198.35 2,054.51 5,928,776.34 483,095.41 3.78 625.77 MWD+IFR-AK-CAZ-SC(3) 7,386.50 73.19 189.59 6,217.91 6,070.41 -1,286.02 2,041.20 5,928,688.71 483,081.89 3.93 713.90 MWD+IFR-AK-CAZ-SC(3) 7,429.08 74.76 190.75 6,229.67 6,082.17 -1,326.30 2,033.97 5,928,648.45 483,074.56 4.52 754.67 MWD+IFR-AK-CAZ-SC(3) 7,492.00 75.95 189.28 6,245.58 6,098.08 -1,386.24 2,023.39 5,928,588.54 483,063.83 2.95 815.32 MWD+IFR '• NOT an Actual Survey 7-5/8"x 9-7/8" 7,519.07 76.47 188.65 6,252.03 6,104.53 -1,412.21 2,019.29 5,928,562.58 483,059.67 2.95 841.46 MWD+IFR-AK-CAZ-SC(4) 9/24!2015 3:14:03PM Page 4 COMPASS 5000.1 Build 74 Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-10 Project: Kuparuk River Unit TVD Reference: Actual:120+27.50©147.50usft(Doyon-141) Site: Kuparuk 2S Pad MD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Well: 2S-10 North Reference: True Wellbore: 2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) ( ) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,551.02 76.99 190.96 6,259.36 6,111.86 -1,442.85 2,014.00 5,928,531.96 483,054.30 7.22 872.43 MWD+IFR-AK-CAZ-SC(4) 7,644.10 79.56 188.84 6,278.28 6,130.78 -1,532.62 1,998.34 5,928,442.24 483,038.41 3.55 963.19 MWD+IFR-AK-CAZ-SC(4) 7,741.66 81.29 193.17 6,294.51 6,147.01 -1,627.02 1,979.97 5,928,347.89 483,019.81 4.72 1,059.13 MWD+IFR-AK-CAZ-SC(4) 7,836.02 82.12 193.31 6,308.13 6,160.63 -1,717.91 1,958.59 5,928,257.06 482,998.20 0.89 1,152.46 MWD+IFR-AK-CAZ-SC(4) 7,929.79 83.68 196.44 6,319.72 6,172.22 -1,807.83 1,934.70 5,928,167.22 482,974.09 3.71 1,245.49 MWD+IFR-AK-CAZ-SC(4) 8,024.10 85.16 198.22 6,328.89 6,181.39 -1,897.43 1,906.74 5,928,077.70 482,945.91 2.45 1,339.27 MWD+IFR-AK-CAZ-SC(4) 8,118.25 84.92 198.71 6,337.03 6,189.53 -1,986.40 1,877.03 5,927,988.81 482,915.98 0.58 1,432.90 MWD+IFR-AK-CAZ-SC(4) 8,214.05 87.87 197.66 6,343.05 6,195.55 -2,077.22 1,847.20 5,927,898.07 482,885.92 3.27 1,528.35 MWD+IFR-AK-CAZ-SC(4) 8,308.48 89.62 196.11 6,345.12 6,197.62 -2,167.55 1,819.78 5,927,807.82 482,858.28 2.48 1,622.70 MWD+IFR-AK-CAZ-SC(4) 8,402.76 89.04 196.58 6,346.22 6,198.72 -2,258.01 1,793.25 5,927,717.43 482,831.52 0.79 1,716.95 MWD+IFR-AK-CAZ-SC(4) 8,496.37 89.28 197.01 6,347.60 6,200.10 -2,347.62 1,766.20 5,927,627.90 482,804.26 0.53 1,810.50 MWD+IFR-AK-CAZ-SC(4) 8,591.38 90.69 196.27 6,347.62 6,200.12 -2,438.65 1,739.00 5,927,536.95 482,776.82 1.68 1,905.47 MWD+IFR-AK-CAZ-SC(4) 8,686.38 90.69 196.85 6,346.48 6,198.98 -2,529.70 1,711.92 5,927,445.98 482,749.52 0.61 2,000.43 MWD+IFR-AK-CAZ-SC(4) 8,780.66 90.82 196.21 6,345.23 6,197.73 -2,620.08 1,685.10 5,927,355.68 482,722.48 0.69 2,094.66 MWD+IFR-AK-CAZ-SC(4) 8,874.49 90.45 195.66 6,344.19 6,196.69 -2,710.30 1,659.34 5,927,265.54 482,696.49 0.71 2,188.48 MWD+IFR-AK-CAZ-SC(4) 8,969.32 90.10 194.75 6,343.74 6,196.24 -2,801.80 1,634.47 5,927,174.10 482,671.40 1.03 2,283.30 MWD+IFR-AK-CAZ-SC(4) 9,064.96 90.41 194.56 6,343.31 6,195.81 -2,894.33 1,610.27 5,927,081.64 482,646.97 0.38 2,378.94 MWD+IFR-AK-CAZ-SC(4) 9,159.93 89.62 194.95 6,343.29 6,195.79 -2,986.17 1,586.09 5,926,989.88 482,622.55 0.93 2,473.91 MWD+IFR-AK-CAZ-SC(4) 9,252.61 88.70 196.17 6,344.65 6,197.15 -3,075.44 1,561.23 5,926,900.68 482,597.48 1.65 2,566.57 MWD+IFR-AK-CAZ-SC(4) 9,348.40 87.84 197.16 6,347.54 6,200.04 -3,167.16 1,533.77 5,926,809.03 482,569.79 1.37 2,662.27 MWD+IFR-AK-CAZ-SC(4) 9,443.16 86.71 198.40 6,352.04 6,204.54 -3,257.29 1,504.87 5,926,718.98 482,540.67 1.77 2,756.81 MWD+IFR-AK-CAZ-SC(4) 9,536.45 87.36 198.72 6,356.87 6,209.37 -3,345.61 1,475.22 5,926,630.75 482,510.79 0.78 2,849.80 MWD+IFR-AK-CAZ-SC(4) 9,630.68 89.14 197.21 6,359.75 6,212.25 -3,435.20 1,446.17 5,926,541.24 482,481.52 2.48 2,943.85 MWD+IFR-AK-CAZ-SC(4) 9,725.08 88.77 196.00 6,361.47 6,213.97 -3,525.64 1,419.20 5,926,450.87 482,454.33 1.34 3,038.20 MWD+IFR-AK-CAZ-SC(4) 9,819.22 89.11 194.88 6,363.21 6,215.71 -3,616.37 1,394.14 5,926,360.22 482,429.04 1.24 3,132.32 MWD+IFR-AK-CAZ-SC(4) 9,913.93 90.03 193.93 6,363.92 6,216.42 -3,708.10 1,370.58 5,926,268.56 482,405.26 1.40 3,227.02 MWD+IFR-AK-CAZ-SC(4) 10,008.07 90.31 192.73 6,363.64 6,216.14 -3,799.70 1,348.87 5,926,177.02 482,383.32 1.31 3,321.11 MWD+IFR-AK-CAZ-SC(4) 10,103.19 90.72 192.81 6,362.79 6,215.29 -3,892.46 1,327.85 5,926,084.32 482,362.07 0.44 3,416.16 MWD+IFR-AK-CAZ-SC(4) 10,196.95 90.72 192.38 6,361.61 6,214.11 -3,983.96 1,307.41 5,925,992.89 482,341.40 0.46 3,509.83 MWD+IFR-AK-CAZ-SC(4) 10,292.58 90.82 190.65 6,360.32 6,212.82 -4,077.65 1,288.32 5,925,899.25 482,322.08 1.81 3,605.27 MWD+IFR-AK-CAZ-SC(4) 10,386.51 90.41 188.75 6,359.32 6,211.82 -4,170.23 1,272.49 5,925,806.72 482,306.02 2.07 3,698.79 MWD+IFR-AK-CAZ-SC(4) 10,481.73 90.17 190.15 6,358.83 6,211.33 -4,264.15 1,256.86 5,925,712.85 482,290.15 1.49 3,793.56 MWD+IFR-AK-CAZ-SC(4) 10,576.55 90.31 190.20 6,358.44 6,210.94 -4,357.48 1,240.11 5,925,619.57 482,273.17 0.16 3,888.04 MWD+IFR-AK-CAZ-SC(4) 10,670.99 90.58 191.18 6,357.70 6,210.20 -4,450.28 1,222.59 5,925,526.83 482,255.42 1.08 3,982.21 MWD+IFR-AK-CAZ-SC(4) 10,765.27 90.55 192.16 6,356.77 6,209.27 -4,542.60 1,203.52 5,925,434.56 482,236.12 1.04 4,076.32 MWD+IFR-AK-CAZ-SC(4) 10,858.48 89.83 194.08 6,356.46 6,208.96 -4,633.38 1,182.37 5,925,343.85 482,214.74 2.20 4,169.48 MWD+IFR-AK-CAZ-SC(4) 10,954.19 90.24 195.93 6,356.41 6,208.91 -4,725.82 1,157.59 5,925,251.48 482,189.73 1.98 4,265.18 MWD+IFR-AK-CAZ-SC(4) 11,050.22 89.25 196.73 6,356.83 6,209.33 -4,817.97 1,130.59 5,925,159.40 482,162.50 1.33 4,361.18 MWD+IFR-AK-CAZ-SC(4) 11,144.66 85.50 197.93 6,361.16 6,213.66 -4,908.01 1,102.49 5,925,069.44 482,134.19 4.17 4,455.43 MWD+IFR-AK-CAZ-SC(4) 11,238.25 86.77 197.87 6,367.47 6,219.97 -4,996.87 1,073.79 5,924,980.67 482,105.27 1.36 4,548.68 MWD+IFR-AK-CAZ-SC(4) 9/24/2015 3:14:03PM Page 5 COMPASS 5000.1 Build 74 Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-10 Project: Kuparuk River Unit TVD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Site: Kuparuk 2S Pad MD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Well: 2S-10 North Reference: True Wellbore: 2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +e-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) 0100) (ft) Survey Tool Name 11,333.47 88.83 196.92 6,371.12 6,223.62 -5,087.66 1,045.35 5,924,889.96 482,076.60 2.38 4,643.75 MWD+IFR-AK-CAZ-SC(4) 11,428.31 88.94 196.37 6,372.97 6,225.47 -5,178.51 1,018.19 5,924,799.19 482,049.21 0.59 4,738.53 MWD+IFR-AK-CAZ-SC(4) 11,523.26 90.24 195.99 6,373.65 6,226.15 -5,269.69 991.73 5,924,708.08 482,022.53 1.43 4,833.45 MWD+IFR-AK-CAZ-SC(4) 11,617.81 88.42 195.85 6,374.75 6,227.25 -5,360.61 965.80 5,924,617.24 481,996.37 1.93 4,927.98 MWD+IFR-AK-CAZ-SC(4) 11,712.45 88.25 194.88 6,377.50 6,230.00 -5,451.82 940.74 5,924,526.09 481,971.08 1.04 5,022.58 MWD+IFR-AK-CAZ-SC(4) 11,807.67 90.93 193.47 6,378.18 6,230.68 -5,544.13 917.42 5,924,433.85 481,947.53 3.18 5,117.77 MWD+IFR-AK-CAZ-SC(4) 11,902.78 90.58 194.67 6,376.93 6,229.43 -5,636.38 894.30 5,924,341.67 481,924.19 1.31 5,212.86 MWD+IFR-AK-CAZ-SC(4) 11,997.99 90.21 195.48 6,376.27 6,228.77 -5,728.31 869.54 5,924,249.82 481,899.20 0.94 5,308.07 MWD+IFR-AK-CAZ-SC(4) 12,092.97 90.65 195.52 6,375.56 6,228.06 -5,819.83 844.16 5,924,158.37 481,873.59 0.47 5,403.04 MWD+IFR-AK-CAZ-SC(4) 12,187.12 90.17 195.41 6,374.89 6,227.39 -5,910.57 819.05 5,924,067.70 481,848.26 0.52 5,497.19 MWD+IFR-AK-CAZ-SC(4) 12,281.45 90.45 194.32 6,374.38 6,226.88 -6,001.74 794.86 5,923,976.60 481,823.83 1.19 5,591.51 MWD+IFR-AK-CAZ-SC(4) 12,375.72 90.00 196.52 6,374.01 6,226.51 -6,092.61 769.79 5,923,885.80 481,798.54 2.38 5,685.77 MWD+IFR-AK-CAZ-SC(4) 12,470.40 88.18 193.33 6,375.51 6,228.01 -6,184.07 745.41 5,923,794.41 481,773.94 3.88 5,780.43 MWD+IFR-AK-CAZ-SC(4) 12,564.81 86.47 192.24 6,379.92 6,232.42 -6,276.03 724.54 5,923,702.51 481,752.84 2.15 5,874.66 MWD+IFR-AK-CAZ-SC(4) 12,660.18 87.56 191.41 6,384.88 6,237.38 -6,369.25 705.03 5,923,609.35 481,733.09 1.44 5,969.75 MWD+IFR-AK-CAZ-SC(4) 12,755.53 87.15 193.11 6,389.28 6,241.78 -6,462.32 684.80 5,923,516.34 481,712.63 1.83 6,064.88 MWD+IFR-AK-CAZ-SC(4) 12,850.38 87.36 193.44 6,393.83 6,246.33 -6,554.53 663.05 5,923,424.20 481,690.65 0.41 6,159.58 MWD+IFR-AK-CAZ-SC(4) 12,944.88 88.83 192.50 6,396.97 6,249.47 -6,646.57 641.85 5,923,332.22 481,669.22 1.85 6,253.97 MWD+IFR-AK-CAZ-SC(4) 13,039.56 88.63 194.11 6,399.07 6,251.57 -6,738.68 620.07 5,923,240.17 481,647.21 1.71 6,348.58 MWD+IFR-AK-CAZ-SC(4) 13,133.08 90.00 195.43 6,400.18 6,252.68 -6,829.10 596.23 5,923,149.82 481,623.15 2.03 6,442.09 MWD+IFR-AK-CAZ-SC(4) 13,225.82 89.66 197.15 6,400.46 6,252.96 -6,918.11 570.22 5,923,060.89 481,596.91 1.89 6,534.80 MWD+IFR-AK-CAZ-SC(4) 13,320.40 89.93 198.83 6,400.80 6,253.30 -7,008.06 541.01 5,922,971.02 481,567.48 1.80 6,629.25 MWD+IFR-AK-CAZ-SC(4) 13,414.08 89.66 199.43 6,401.13 6,253.63 -7,096.57 510.31 5,922,882.60 481,536.56 0.70 6,722.68 MWD+IFR-AK-CAZ-SC(4) 13,510.10 88.87 200.31 6,402.36 6,254.86 -7,186.86 477.67 5,922,792.39 481,503.71 1.23 6,818.35 MWD+IFR-AK-CAZ-SC(4) 13,602.84 89.21 201.55 6,403.92 6,256.42 -7,273.47 444.55 5,922,705.88 481,470.37 1.39 6,910.58 MWD+IFR-AK-CAZ-SC(4) 13,697.55 89.73 200.10 6,404.79 6,257.29 -7,361.99 410.88 5,922,617.46 481,436.48 1.63 7,004.79 MWD+IFR-AK-CAZ-SC(4) 13,786.78 90.00 197.85 6,405.01 6,257.51 -7,446.36 381.87 5,922,533.16 481,407.26 2.54 7,093.80 MWD+IFR-AK-CAZ-SC(4) 13,882.43 91.54 195.90 6,403.72 6,256.22 -7,537.88 354.11 5,922,441.73 481,379.27 2.60 7,189.38 MWD+IFR-AK-CAZ-SC(4) 13,980.69 92.13 195.38 6,400.57 6,253.07 -7,632.45 327.63 5,922,347.23 481,352.56 0.80 7,287.58 MWD+IFR-AK-CAZ-SC(4) 14,076.36 90.27 196.24 6,398.57 6,251.07 -7,724.48 301.57 5,922,255.28 481,326.28 2.14 7,383.22 MWD+IFR-AK-CAZ-SC(4) 14,170.95 88.80 197.85 6,399.34 6,251.84 -7,814.90 273.85 5,922,164.93 481,298.33 2.30 7,477.74 MWD+IFR-AK-CAZ-SC(4) 14,265.96 88.49 196.51 6,401.58 6,254.08 -7,905.65 245.80 5,922,074.27 481,270.05 1.45 7,572.65 MWD+IFR-AK-CAZ-SC(4) 14,361.22 87.08 196.55 6,405.27 6,257.77 -7,996.90 218.71 5,921,983.09 481,242.74 1.48 7,667.80 MWD+IFR-AK-CAZ-SC(4) 14,455.93 87.29 195.88 6,409.92 6,262.42 -8,087.73 192.30 5,921,892.34 481,216.10 0.74 7,762.38 MWD+IFR-AK-CAZ-SC(4) 14,549.80 87.91 194.56 6,413.85 6,266.35 -8,178.23 167.68 5,921,801.91 481,191.25 1.55 7,856.16 MWD+IFR-AK-CAZ-SC(4) 14,644.65 86.05 194.55 6,418.85 6,271.35 -8,269.90 143.88 5,921,710.31 481,167.22 1.96 7,950.87 MWD+IFR-AK-CAZ-SC(4) 14,739.72 85.64 193.74 6,425.73 6,278.23 -8,361.85 120.70 5,921,618.43 481,143.82 0.95 8,045.68 MWD+IFR-AK-CAZ-SC(4) 14,834.45 88.80 192.11 6,430.33 6,282.83 -8,454.05 99.55 5,921,526.29 481,122.43 3.75 8,140.22 MWD+IFR-AK-CAZ-SC(4) 14,885.00 90.73 192.11 6,430.53 6,283.03 -8,503.48 88.94 5,921,476.89 481,111.71 3.82 8,190.71 BLIND(5) fl NOT an Actual Survey 4 1/2"x 6-3/4" 9/242015 3:14:03PM Page 6 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-10 Project: Kuparuk River Unit TVD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Site: Kuparuk 2S Pad MD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Well: 2S-10 North Reference: True Wellbore: 2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 14,896.00 91.15 192.11 6,430.35 6,282.85 -8,514.23 86.63 5,921,466.15 481,109.37 3.82 8,201.69 Projection to TD Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. ElYes 0N i have checked to the best of my ability that the following data is correct: d Surface Coordinates ❑ Declination & Convergence ❑ GRS Survey Corrections ,, Survey Tool Codes Vincent Dr*9ytnd bonmeent CAd 124:on-VIIIrant o4chkrntergar, _ Asara �,m ` SLB DE 0rar.K1.5.N.41&S3,[_W Cate.zuv zo-xn 1 as3aa Orm Jake Voss °"'v" .4 14k2 � ' w ortn_nww's csauaurcw.Emilia.:` C hent Representative: oaa.20MUs n1,41MCI} Date: 24-Sep2015 9/242015 3:14:03PM Page 7 COMPASS 5000.1 Build 74 • • �4, Cement Detail Report u10. iH2S-10 GanocoPhillmps String: Intermediate Casing Cement Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 9/2/2015 15:30 9/2/2015 20:15 2S-10 Comment Pump 5 bbls Mud Push.Test lines to 350/4000 psi. Pump 45 bbls 12 ppg MP2.4.8 bpm,380 psi.Load btm plug-Batch up cmt.-Pumped 76 bbls 15.8 ppg Class G w/GASBLOK slurry @ 5 bbls/min @ 275 psi-Shut down-Loaded top plug-kicked out w/10 bbls/fresh water-switched over to rig pumps&displaced cmt WI 10.5 ppg mud @ 5.5 bbls/min @ 200 psi-slow pump&bumped plug w/1450 psi-Bleed off&checked floats-floats held-CIP 17:45 hrs. -Recipcated pipe to just before bumping plug. Pressure up and open stage collar w/3550 psi. CBU @ 5 bpm,500 psi. Pump 40 bbls 12 ppg MP2 @ 5 bpm,300 psi. Batch up cmt.-Pumped 27 bbls 15.8 ppg Class G w/GASBLOK slurry @ 5 bbls/min @ 300 psi-Shut down-Loaded closing plug-kicked out w/10 bbls/fresh water- switched over to rig pumps&displaced cmt w/10.5 ppg mud @ 6 bbls/min @ 600 psi-slow pump&land plug w/500 psi. Pressure up to 1900 psi and hold for 5 mins to close stage collar. Bleed off&confirm stage collar closure.CIP 20:15 hrs. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Casing 5,335.0 7,492.0 No Yes Yes Cement Q Pump[nit(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 5 5 950.0 1,450.0 Yes 15.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 6,100.0 7,492.0 365 G 76.0 Yield(ft5sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.17 3.96 15.80 154.0 4.05 Additives Additive Type Concentration Conc Unit label Antifoam D047 0.1 gal/sx Additive Type Concentration Conc Unit label Dispersant D065 0.4 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.3 %BWOC Additive Type Concentration Conc Unit label Acelerator(Calcium Chloride) D186 0.1 gal/sx Additive Type Concentration Conc Unit label Gas Block D600G 1.0 gal/sx Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Casing 4,767.0 5,311.0 No No No Cement Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 6 6 500.0 1,900.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 4,767.0 5,311.0 130 G 27.0 Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.17 3.96 15.80 142.0 4.05 Additives Additive Type Concentration Conc Unit label Antifoam D047 0.1 gal/sx Additive Type Concentration Conc Unit label Dispersant D065 0.4 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.3 %BWOC Additive Type Concentration Conc Unit label Acelerator(Calcium Chloride) D186 0.1 gal/sx Additive Type Concentration Conc Unit label Gas Block D600G 1.0 gal/sx Page 1/1 Report Printed: 10/6/2015 0 • 7 Cement Detail Report 2S-10 Phillips String: Surface Casing Cement Job: DRILLING ORIGINAL, 8/21/2015 09:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 8/25/2015 16:15 8/25/2015 19:26 2S-10 Comment PJSM; batch up CW-100, line up to cementers, pump 5 bbls of CW-100,&PT lines to 4000 psi. Pump 73 bbls of CW-100,99 bbls of Mud Push 2 w/red dye, drop bottom plug. Pump 438 bbls of 11.0ppg lead cement, 60bbls of 12.0 ppg tail cement, &drop top plug. Pump 10 bbls of fresh water to kick out plug.Swap over to rig pump&displace cement with 9.6 ppg mud. Bump plug w/2395 strokes.20 bbls of cement to surface.CIP @ 19:26 hrs. Cement Stages Stage#<Stage Number?> Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Surface Casing Cement 28.6 2,688.0 Yes 20.0 Yes Yes Q Pump(nit(bbllm...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 7 7 500.0 1,000.0 Yes 26.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 28.6 2,188.0 1,288 DeepCRETE 438.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.91 6.83 11.00 Additives Additive Type Concentration Conc Unit label Retarder D177 gal/sx Additive Type Concentration Conc Unit label Dispersant D185 gal/sx Additive Type Concentration Conc Unit label Antifoam D046 BWOB Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 2,188.0 2,688.0 207 DeepCRETE 60.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.63 5.48 12.00 Additives Additive Type Concentration Conc Unit label Dispersant LT D185 gal/sx Additive Type Concentration Conc Unit label Acelerator D186 gal/sx Additive Type Concentration Conc Unit label Antifoam D046 %BWOB Page 1/1 Report Printed: 10/6/2015 • • Cement Detail Report 2S-10 OxicicoPhiilips String: Conductor Cement Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Conductor Cement 12/1/2014 13:00 12/14/2014 17:00 2S-10 Comment Cement Stages Stage#<Stage Number?> Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Q Pump Mit(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(fVlsack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 10/6/2015 • 215110 26322 Nov ConocoPhillips RECEW E® TRANSMITTAL OCT 082015 CONFIDEAMArDATA ltibr Gt- n FROM; Sandra D. Lemke,ATO3-0346 TO; Makana Bender AOGCC ConocoPhiliips Alaska, Inc. AOGCC P.O. Box 100360 W.7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage,Alaska RE: 25-10(permit 215-110-0) DATA LOGGED /12/2015 DATE: 10/06/2015 K.BENDER Transmitted; Kuparuk River Unit,Alaska 2S-10 1 CD (digital data)and 1 color log print each Halliburton-Surface data logging and End of Well report-mud logging data for 25-10; 09/11/2015: general fll i information, daily summary, days vs. depth, after action review, mud record, bit record, morning reports, survey reports; Digital data: Final Log Files, Final End of well report, Final las export, Halliburton Log Viewer, EMF log viewer color log presentations, ,I 1 color log print 19 Formation Evaluation 2"MD, Gas ratio 2"MD, Drilling Engineering 2"MD Please promptly sign, scan and return electronically to . andra,Q,Lemke0Conocophillios com. CC: 25-10 transmittal folder, production well files, eSearch Receip td/ = ;G 4 ate: GIS-Technical Data Management I ConocoPhillips,I Anchorage, Alaska I Ph: 997.265;6942 215110 1,00C- Schlumberger Drilling & MeasurementsTransmittal#: 30SEP15-SP02 DATA LOGGED MWD/LWD Log Product DeliveryM. BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2S-10 Date Dispatched: 30-Sep-15 Job#: 14AKA0059 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 1 Contents on CD N/A SonicScope Top of Cement x x LAS Digital Data N/A Contents on CD N/A x Directional Data N/A Contents on CD N/A As-Built Survey N/A Contents on CD N/A CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf x Please sign and email a copy to: Please sign and email a copy to: Catherine.RosoAconocophillips.com AlaskaPTSPrintCenterslb.com Catherine Roso Attn:Stephanie Pacillo 907-265-6189 ATO 1707 fi) 1,2 Received By: 0-0—iteget • SSP 30 2, 215110 2 � � y � $cblumherger OG�' Transmittal#: 30SEP15- P1 Drilling & Measurements DATA LOGGED MWD/LWD Log Product Delivery R 30/2015 m.K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2S-10 Date Dispatched: 30-Sep-15 Job#: 14AKA0059 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 4 Contents on CD N/A EcoScope 2" MD x x EcoScope 2'TVD x x EcoScope 5'MD x x EcoScope 5'TVD x x LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 x x As-Built Survey 1 Contents on CD N/A Nad83 x x CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf/tiff x Surveys:pdf/txt x - Please sign and email a copy to: Please sign and email a copy to: Catherine.RosoRconocophillips.com AlaskaPTSPrintCenter(cD,slb.com Catherine Roso Attn:Stephanie Pacillo 907-265-6189 ATO 1707 Received By: i/) ,..g...4,4,..;i7) 6,,,,,„at 26114 92 FINAL RECEIVEr - SEP 3 0 Lii:; NADConversion Aoacc Kuparuk River Unit Kuparuk 2S Pad 2S-10 Definitive Survey Report 24 September, 2015 NAD 27 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-10 Project: Kuparuk River Unit TVD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Site: Kuparuk 2S Pad MD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Well: 2S-10 North Reference: True Wellbore: 2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10 Database: OAKEDMP2 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 2S-10 Well Position +N/-S 0.00 usft Northing: 5,929,979.72 usfi Latitude: 70° 13'11.496 N +E/-W 0.00 usft Easting: 481,044.13 usfi Longitude: 150°9'10.528 W Position Uncertainty 0.00 usft Wellhead Elevation: usfi Ground Level: 120.00 usft 1 Wellbore 2S-10 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 9/5/2015 18.60 80.87 57,489 Design 2S-10 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.50 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 27.50 0.00 0.00 195.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 93.90 462.50 2S-10 Srvy#1 Gyro(2S-10) GYD-GC-MS Gyrodata gyrocompassing m/s 9/4/2015 12:02 506.90 2,627.01 2S-10 Srvy#2 MWD+IFR-AK-CAZ-SC(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/4/2015 12:17 2,725.17 7,429.08 2S-10 Srvy#3 MWD+IFR-AK-CAZ-SC(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/4/2015 12:31 7,519.07 14,834.45 2S-10 Srvy#4 MWD+IFR-AK-CAZ-SC(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/8/2015 11:3c, 14,896.00 14,896.00 2S-10 Srvy#5-Projection to TD(2S-10)BLIND Blind drilling 9/24/2015 2:41 i Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100) (ft) Survey Tool Name 27.50 0.00 0.00 27.50 -120.00 0.00 0.00 5,929,979.72 481,044.13 0.00 0.00 UNDEFINED 94.40 0.45 73.93 94.40 -53.10 0.07 0.25 5,929,979.79 481,044.38 0.67 -0.14 GYD-GC-MS(1) 107.50 0.46 73.22 107.50 -40.00 0.10 0.35 5,929,979.82 481,044.48 0.11 -0.19 GYD-GC-MS(11 NOT an Actual Survey 16"x 42" 186.50 0.54 69.67 186.50 39.00 0.32 1.01 5,929,980.04 481,045.14 0.11 -0.57 GYD-GC-MS(1) 278.70 0.58 73.72 278.69 131.19 0.61 1.86 5,929,980.32 481,045.99 0.06 -1.07 GYD-GC-MS(1) 370.80 0.73 77.64 370.79 223.29 0.86 2.88 5,929,980.57 481,047.01 0.17 -1.58 GYD-GC-MS(1) 506.90 0.78 74.23 506.87 359.37 1.30 4.62 5,929,981.01 481,048.75 0.05 -2.45 MWD+IFR-AK-CAZ-SC(2) 598.44 0.51 89.00 598.41 450.91 1.48 5.63 5,929,981.18 481,049.76 0.34 -2.88 MWD+IFR-AK-CAZ-SC(2) 696.00 1.69 54.94 695.95 548.45 2.31 7.24 5,929,982.01 481,051.38 1.33 -4.10 MWD+IFR-AK-CAZ-SC(2) 788.22 2.43 45.82 788.11 640.61 4.45 9.76 5,929,984.15 481,053.90 0.88 -6.83 MWD+IFR-AK-CAZ-SC(2) 9/24/2015 3:14:03PM Page 2 COMPASS 5000.1 Build 74 1110 Schlumberger . Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-10 Project: Kuparuk River Unit TVD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Site: Kuparuk 2S Pad MD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Well: 2S-10 North Reference: True Wellbore: 2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 880.07 3.57 31.30 879.83 732.33 8.25 12.64 5,929,987.94 481,056.79 1.48 -11.24 MWD+IFR-AK-CAZ-SC(2) 972.37 5.71 29.21 971.82 824.32 14.72 16.37 5,929,994.40 481,060.54 2.33 -18.45 MWD+IFR-AK-CAZ-SC(2) 1,065.00 7.70 32.99 1,063.82 916.32 23.95 22.00 5,930,003.61 481,066.19 2.20 -28.82 MWD+IFR-AK-CAZ-SC(2) 1,115.38 9.02 32.68 1,113.66 966.16 30.10 25.97 5,930,009.75 481,070.17 2.62 -35.80 MWD+IFR-AK-CAZ-SC(2) 1,158.68 10.08 31.52 1,156.36 1,008.86 36.19 29.78 5,930,015.83 481,074.00 2.49 -42.66 MWD+IFR-AK-CAZ-SC(2) 1,216.08 11.15 32.19 1,212.78 1,065.28 45.17 35.37 5,930,024.79 481,079.61 1.88 -52.78 MWD+IFR-AK-CAZ-SC(2) 1,251.55 12.84 31.28 1,247.47 1,099.97 51.44 39.24 5,930,031.05 481,083.50 4.79 -59.84 MWD+IFR-AK-CAZ-SC(2) 1,345.39 14.91 29.17 1,338.57 1,191.07 70.89 50.54 5,930,050.48 481,094.84 2.27 -81.56 MWD+IFR-AK-CAZ-SC(2) 1,438.07 15.95 33.62 1,427.91 1,280.41 91.91 63.40 5,930,071.46 481,107.76 1.70 -105.19 MWD+IFR-AK-CAZ-SC(2) 1,531.92 19.06 42.90 1,517.42 1,369.92 113.88 80.98 5,930,093.39 481,125.39 4.44 -130.96 MWD+IFR-AK-CAZ-SC(2) 1,626.66 20.25 56.47 1,606.69 1,459.19 134.28 105.19 5,930,113.73 481,149.65 4.97 -156.93 MWD+IFR-AK-CAZ-SC(2) 1,719.09 20.73 63.37 1,693.28 1,545.78 150.45 133.15 5,930,129.82 481,177.65 2.66 -179.79 MWD+IFR-AK-CAZ-SC(2) 1,814.62 22.50 71.62 1,782.11 1,634.61 163.80 165.62 5,930,143.09 481,210.15 3.68 -201.08 MWD+IFR-AK-CAZ-SC(2) 1,909.13 24.42 81.56 1,868.84 1,721.34 172.37 202.13 5,930,151.57 481,246.67 4.65 -218.81 MWD+IFR-AK-CAZ-SC(2) 2,002.26 25.90 86.94 1,953.14 1,805.64 176.29 241.49 5,930,155.38 481,286.04 2.92 -232.78 MWD+IFR-AK-CAZ-SC(2) 2,094.67 26.33 88.82 2,036.12 1,888.62 177.78 282.13 5,930,156.78 481,326.68 1.01 -244.75 MWD+IFR-AK-CAZ-SC(2) 2,187.42 26.80 88.37 2,119.08 1,971.58 178.80 323.60 5,930,157.69 481,368.14 0.55 -256.46 MWD+IFR-AK-CAZ-SC(2) 2,280.73 26.91 89.57 2,202.32 2,054.82 179.56 365.74 5,930,158.34 481,410.28 0.59 -268.10 MWD+IFR-AK-CAZ-SC(2) 2,373.10 27.01 89.98 2,284.66 2,137.16 179.72 407.62 5,930,158.40 481,452.16 0.23 -279.10 MWD+IFR-AK-CAZ-SC(2) 2,465.75 27.03 89.30 2,367.19 2,219.69 179.99 449.71 5,930,158.56 481,494.24 0.33 -290.25 MWD+IFR-AK-CAZ-SC(2) 2,558.55 26.95 89.74 2,449.89 2,302.39 180.34 491.82 5,930,158.81 481,536.35 0.23 -301.49 MWD+IFR-AK-CAZ-SC(2) 2,627.01 27.67 89.48 2,510.71 2,363.21 180.56 523.23 5,930,158.94 481,567.76 1.07 -309.83 MWD+IFR-AK-CAZ-SC(2) 2,688.00 28.50 88.03 2,564.52 2,417.02 181.19 551.93 5,930,159.50 481,596.46 1.76 -317.86 MWD+IFR-AK-CA7 SC(11 NOT an Actual Survey 10 3/4"x 13-1/2 2,725.17 29.01 87.18 2,597.11 2,449.61 181.93 569.80 5,930,160.20 481,614.33 1.76 -323.21 MWD+IFR-AK-CAZ-SC(3) 2,816.64 28.66 86.99 2,677.24 2,529.74 184.18 613.86 5,930,162.34 481,658.39 0.40 -336.78 MWD+IFR-AK-CAZ-SC(3) 2,864.99 28.61 86.53 2,719.68 2,572.18 185.49 636.99 5,930,163.59 481,681.52 0.47 -344.03 MWD+IFR-AK-CAZ-SC(3) 2,909.92 28.71 85.72 2,759.10 2,611.60 186.94 658.49 5,930,164.99 481,703.02 0.89 -351.00 MWD+IFR-AK-CAZ-SC(3) 3,004.46 28.58 86.65 2,842.07 2,694.57 189.96 703.71 5,930,167.89 481,748.24 0.49 -365.62 MWD+IFR-AK-CAZ-SC(3) 3,099.67 28.49 85.34 2,925.72 2,778.22 193.14 749.08 5,930,170.95 481,793.61 0.66 -380.43 MWD+IFR-AK-CAZ-SC(3) 3,194.74 28.21 84.10 3,009.38 2,861.88 197.29 794.03 5,930,174.99 481,838.57 0.69 -396.07 MWD+IFR-AK-CAZ-SC(3) 3,289.77 28.47 83.37 3,093.02 2,945.52 202.21 838.87 5,930,179.80 481,883.42 0.46 -412.44 MWD+IFR-AK-CAZ-SC(3) 3,378.65 28.38 82.95 3,171.19 3,023.69 207.25 880.87 5,930,184.74 481,925.43 0.25 -428.17 MWD+IFR-AK-CAZ-SC(3) 3,471.79 28.42 84.19 3,253.12 3,105.62 212.21 924.89 5,930,189.59 481,969.46 0.63 -444.36 MWD+IFR-AK-CAZ-SC(3) 3,566.57 28.45 85.54 3,336.47 3,188.97 216.25 969.84 5,930,193.51 482,014.41 0.68 -459.89 MWD+IFR-AK-CAZ-SC(3) 3,657.96 28.58 85.71 3,416.77 3,269.27 219.58 1,013.34 5,930,196.73 482,057.92 0.17 -474.37 MWD+IFR-AK-CAZ-SC(3) 3,751.66 28.48 87.25 3,499.09 3,351.59 222.33 1,058.01 5,930,199.37 482,102.58 0.79 -488.58 MWD+IFR-AK-CAZ-SC(3) 3,843.69 28.54 88.26 3,579.96 3,432.46 224.05 1,101.90 5,930,200.98 482,146.48 0.53 -501.60 MWD+IFR-AK-CAZ-SC(3) 3,936.51 28.60 87.63 3,661.48 3,513.98 225.64 1,146.26 5,930,202.46 482,190.84 0.33 -514.62 MWD+IFR-AK-CAZ-SC(3) 4,029.03 28.51 86.43 3,742.75 3,595.25 227.93 1,190.42 5,930,204.64 482,235.00 0.63 -528.27 MWD+IFR-AK-CAZ-SC(3) 9/24/2015 3:14:03PM Page 3 COMPASS 5000.1 Build 74 . Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-10 Project: Kuparuk River Unit TVD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Site: Kuparuk 2S Pad MD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Well: 2S-10 North Reference: True Wellbore: 2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,123.62 28.53 87.35 3,825.86 3,678.36 230.38 1,235.52 5,930,206.97 482,280.10 0.46 -542.30 MWD+IFR-AK-CAZ-SC(3) 4,217.11 28.59 87.17 3,907.97 3,760.47 232.51 1,280.16 5,930,209.00 482,324.74 0.11 -555.92 MWD+IFR-AK-CAZ-SC(3) 4,310.04 28.60 88.34 3,989.57 3,842.07 234.26 1,324.60 5,930,210.63 482,369.18 0.60 -569.11 MWD+IFR-AK-CAZ-SC(3) 4,404.28 28.51 89.38 4,072.35 3,924.85 235.15 1,369.64 5,930,211.41 482,414.22 0.54 -581.63 MWD+IFR-AK-CAZ-SC(3) 4,495.10 28.46 89.55 4,152.17 4,004.67 235.56 1,412.95 5,930,211.71 482,457.53 0.10 -593.23 MWD+IFR-AK-CAZ-SC(3) 4,590.23 28.35 88.97 4,235.85 4,088.35 236.14 1,458.20 5,930,212.18 482,502.77 0.31 -605.51 MWD+IFR-AK-CAZ-SC(3) 4,682.03 28.23 89.55 4,316.68 4,169.18 236.70 1,501.70 5,930,212.63 482,546.27 0.33 -617.31 MWD+IFR-AK-CAZ-SC(3) 4,776.69 28.21 94.78 4,400.11 4,252.61 235.02 1,546.39 5,930,210.83 482,590.95 2.61 -627.24 MWD+IFR-AK-CAZ-SC(3) 4,869.45 28.69 99.99 4,481.68 4,334.18 229.33 1,590.18 5,930,205.03 482,634.72 2.72 -633.08 MWD+IFR-AK-CAZ-SC(3) 4,961.45 27.81 106.66 4,562.74 4,415.24 219.34 1,632.50 5,930,194.94 482,677.01 3.56 -634.39 MWD+IFR-AK-CAZ-SC(3) 5,055.86 26.77 113.98 4,646.66 4,499.16 204.38 1,673.03 5,930,179.88 482,717.51 3.72 -630.43 MWD+IFR-AK-CAZ-SC(3) 5,149.51 28.34 121.09 4,729.71 4,582.21 184.32 1,711.35 5,930,159.73 482,755.77 3.89 -620.97 MWD+IFR-AK-CAZ-SC(3) 5,242.84 29.66 127.18 4,811.35 4,663.85 158.92 1,748.73 5,930,134.23 482,793.08 3.46 -606.11 MWD+IFR-AK-CAZ-SC(3) 5,335.66 29.54 130.70 4,892.07 4,744.57 130.12 1,784.38 5,930,105.35 482,828.65 1.88 -587.52 MWD+IFR-AK-CAZ-SC(3) 5,426.94 29.94 133.79 4,971.33 4,823.83 99.68 1,817.88 5,930,074.83 482,862.08 1.74 -566.79 MWD+IFR-AK-CAZ-SC(3) 5,519.21 30.13 138.65 5,051.22 4,903.72 66.36 1,849.81 5,930,041.43 482,893.92 2.64 -542.86 MWD+IFR-AK-CAZ-SC(3) 5,611.31 31.24 142.26 5,130.43 4,982.93 30.11 1,879.70 5,930,005.11 482,923.72 2.33 -515.59 MWD+IFR-AK-CAZ-SC(3) 5,703.86 32.97 146.14 5,208.83 5,061.33 -9.78 1,908.43 5,929,965.15 482,952.34 2.91 -484.49 MWD+IFR-AK-CAZ-SC(3) 5,798.71 34.68 151.60 5,287.64 5,140.14 -54.97 1,935.65 5,929,919.90 482,979.44 3.68 -447.89 MWD+IFR-AK-CAZ-SC(3) 5,892.26 36.97 156.04 5,363.50 5,216.00 -104.10 1,959.74 5,929,870.71 483,003.41 3.70 -406.67 MWD+IFR-AK-CAZ-SC(3) 5,985.23 39.27 160.70 5,436.66 5,289.16 -157.43 1,980.83 5,929,817.33 483,024.36 3.96 -360.61 MWD+IFR-AK-CAZ-SC(3) 6,078.55 40.79 164.67 5,508.12 5,360.62 -214.72 1,998.65 5,929,760.00 483,042.04 3.18 -309.89 MWD+IFR-AK-CAZ-SC(3) 6,173.63 43.21 167.37 5,578.78 5,431.28 -276.45 2,013.98 5,929,698.24 483,057.21 3.18 -254.23 MWD+IFR-AK-CAZ-SC(3) 6,265.92 45.61 168.60 5,644.70 5,497.20 -339.61 2,027.41 5,929,635.05 483,070.48 2.76 -196.69 MWD+IFR-AK-CAZ-SC(3) 6,357.04 48.09 169.16 5,707.02 5,559.52 -404.84 2,040.22 5,929,569.80 483,083.13 2.76 -137.01 MWD+IFR-AK-CAZ-SC(3) 6,451.06 50.46 169.97 5,768.35 5,620.85 -474.91 2,053.12 5,929,499.70 483,095.85 2.60 -72.66 MWD+IFR-AK-CAZ-SC(3) 6,544.59 53.52 172.52 5,825.95 5,678.45 -547.73 2,064.30 5,929,426.86 483,106.84 3.91 -5.22 MWD+IFR-AK-CAZ-SC(3) 6,638.03 56.27 175.01 5,879.68 5,732.18 -623.70 2,072.57 5,929,350.87 483,114.92 3.66 66.03 MWD+IFR-AK-CAZ-SC(3) 6,731.17 57.89 176.93 5,930.30 5,782.80 -701.69 2,078.05 5,929,272.89 483,120.21 2.45 139.94 MWD+IFR-AK-CAZ-SC(3) 6,825.34 59.14 179.50 5,979.49 5,831.99 -781.94 2,080.54 5,929,192.63 483,122.50 2.68 216.82 MWD+IFR-AK-CAZ-SC(3) 6,919.12 60.23 180.98 6,026.83 5,879.33 -862.90 2,080.20 5,929,111.69 483,121.95 1.79 295.10 MWD+IFR-AK-CAZ-SC(3) 7,011.64 61.40 182.28 6,071.95 5,924.45 -943.63 2,077.90 5,929,030.97 483,119.44 1.76 373.68 MWD+IFR-AK-CAZ-SC(3) 7,106.70 64.15 184.57 6,115.44 5,967.94 -1,027.99 2,072.83 5,928,946.63 483,114.16 3.60 456.48 MWD+IFR-AK-CAZ-SC(3) 7,200.31 66.80 186.14 6,154.29 6,006.79 -1,112.77 2,064.87 5,928,861.87 483,105.99 3.22 540.43 MWD+IFR-AK-CAZ-SC(3) 7,293.03 70.01 187.65 6,188.41 6,040.91 -1,198.35 2,054.51 5,928,776.34 483,095.41 3.78 625.77 MWD+IFR-AK-CAZ-SC(3) 7,386.50 73.19 189.59 6,217.91 6,070.41 -1,286.02 2,041.20 5,928,688.71 483,081.89 3.93 713.90 MWD+IFR-AK-CAZ-SC(3) 7,429.08 74.76 190.75 6,229.67 6,082.17 -1,326.30 2,033.97 5,928,648.45 483,074.56 4.52 754.67 MWD+I FR-AK-CAZ-SC(3) 7,492.00 75.95 189.28 6,245.58 6,098.08 -1,386.24 2,023.39 5,928,588.54 483,063.83 2.95 815.32 MWD+IFR;AK_rn7_cr IA) NOT an Actual Survey 7-5/8"x 9-7/8" 7,519.07 76.47 188.65 6,252.03 6,104.53 -1,412.21 2,019.29 5,928,562.58 483,059.67 2.95 841.46 MWD+IFR-AK-CAZ-SC(4) 9/24/2015 3:14:03PM Page 4 COMPASS 5000.1 Build 74 • Schlumberger . Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-10 Project: Kuparuk River Unit TVD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Site: Kuparuk 2S Pad MD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Well: 2S-10 North Reference: True Wellbore: 2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/10(Y) (ft) Survey Tool Name 7,551.02 76.99 190.96 6,259.36 6,111.86 -1,442.85 2,014.00 5,928,531.96 483,054.30 7.22 872.43 MWD+IFR-AK-CAZ-SC(4) 7,644.10 79.56 188.84 6,278.28 6,130.78 -1,532.62 1,998.34 5,928,442.24 483,038.41 3.55 963.19 MWD+IFR-AK-CAZ-SC(4) 7,741.66 81.29 193.17 6,294.51 6,147.01 -1,627.02 1,979.97 5,928,347.89 483,019.81 4.72 1,059.13 MWD+IFR-AK-CAZ-SC(4) 7,836.02 82.12 193.31 6,308.13 6,160.63 -1,717.91 1,958.59 5,928,257.06 482,998.20 0.89 1,152.46 MWD+IFR-AK-CAZ-SC(4) 7,929.79 83.68 196.44 6,319.72 6,172.22 -1,807.83 1,934.70 5,928,167.22 482,974.09 3.71 1,245.49 MWD+IFR-AK-CAZ-SC(4) 8,024.10 85.16 198.22 6,328.89 6,181.39 -1,897.43 1,906.74 5,928,077.70 482,945.91 2.45 1,339.27 MWD+IFR-AK-CAZ-SC(4) 8,118.25 84.92 198.71 6,337.03 6,189.53 -1,986.40 1,877.03 5,927,988.81 482,915.98 0.58 1,432.90 MWD+IFR-AK-CAZ-SC(4) 8,214.05 87.87 197.66 6,343.05 6,195.55 -2,077.22 1,847.20 5,927,898.07 482,885.92 3.27 1,528.35 MWD+IFR-AK-CAZ-SC(4) 8,308.48 89.62 196.11 6,345.12 6,197.62 -2,167.55 1,819.78 5,927,807.82 482,858.28 2.48 1,622.70 MWD+IFR-AK-CAZ-SC(4) 8,402.76 89.04 196.58 6,346.22 6,198.72 -2,258.01 1,793.25 5,927,717.43 482,831.52 0.79 1,716.95 MWD+IFR-AK-CAZ-SC(4) 8,496.37 89.28 197.01 6,347.60 6,200.10 -2,347.62 1,766.20 5,927,627.90 482,804.26 0.53 1,810.50 MWD+IFR-AK-CAZ-SC(4) 8,591.38 90.69 196.27 6,347.62 6,200.12 -2,438.65 1,739.00 5,927,536.95 482,776.82 1.68 1,905.47 MWD+IFR-AK-CAZ-SC(4) 8,686.38 90.69 196.85 6,346.48 6,198.98 -2,529.70 1,711.92 5,927,445.98 482,749.52 0.61 2,000.43 MWD+IFR-AK-CAZ-SC(4) 8,780.66 90.82 196.21 6,345.23 6,197.73 -2,620.08 1,685.10 5,927,355.68 482,722.48 0.69 2,094.66 MWD+IFR-AK-CAZ-SC(4) 8,874.49 90.45 195.66 6,344.19 6,196.69 -2,710.30 1,659.34 5,927,265.54 482,696.49 0.71 2,188.48 MWD+IFR-AK-CAZ-SC(4) 8,969.32 90.10 194.75 6,343.74 6,196.24 -2,801.80 1,634.47 5,927,174.10 482,671.40 1.03 2,283.30 MWD+IFR-AK-CAZ-SC(4) 9,064.96 90.41 194.56 6,343.31 6,195.81 -2,894.33 1,610.27 5,927,081.64 482,646.97 0.38 2,378.94 MWD+IFR-AK-CAZ-SC(4) 9,159.93 89.62 194.95 6,343.29 6,195.79 -2,986.17 1,586.09 5,926,989.88 482,622.55 0.93 2,473.91 MWD+IFR-AK-CAZ-SC(4) 9,252.61 88.70 196.17 6,344.65 6,197.15 -3,075.44 1,561.23 5,926,900.68 482,597.48 1.65 2,566.57 MWD+IFR-AK-CAZ-SC(4) 9,348.40 87.84 197.16 6,347.54 6,200.04 -3,167.16 1,533.77 5,926,809.03 482,569.79 1.37 2,662.27 MWD+IFR-AK-CAZ-SC(4) 9,443.16 86.71 198.40 6,352.04 6,204.54 -3,257.29 1,504.87 5,926,718.98 482,540.67 1.77 2,756.81 MWD+IFR-AK-CAZ-SC(4) 9,536.45 87.36 198.72 6,356.87 6,209.37 -3,345.61 1,475.22 5,926,630.75 482,510.79 0.78 2,849.80 MWD+IFR-AK-CAZ-SC(4) 9,630.68 89.14 197.21 6,359.75 6,212.25 -3,435.20 1,446.17 5,926,541.24 482,481.52 2.48 2,943.85 MWD+IFR-AK-CAZ-SC(4) 9,725.08 88.77 196.00 6,361.47 6,213.97 -3,525.64 1,419.20 5,926,450.87 482,454.33 1.34 3,038.20 MWD+IFR-AK-CAZ-SC(4) 9,819.22 89.11 194.88 6,363.21 6,215.71 -3,616.37 1,394.14 5,926,360.22 482,429.04 1.24 3,132.32 MWD+IFR-AK-CAZ-SC(4) 9,913.93 90.03 193.93 6,363.92 6,216.42 -3,708.10 1,370.58 5,926,268.56 482,405.26 1.40 3,227.02 MWD+IFR-AK-CAZ-SC(4) 10,008.07 90.31 192.73 6,363.64 6,216.14 -3,799.70 1,348.87 5,926,177.02 482,383.32 1.31 3,321.11 MWD+IFR-AK-CAZ-SC(4) 10,103.19 90.72 192.81 6,362.79 6,215.29 -3,892.46 1,327.85 5,926,084.32 482,362.07 0.44 3,416.16 MWD+IFR-AK-CAZ-SC(4) 10,196.95 90.72 192.38 6,361.61 6,214.11 -3,983.96 1,307.41 5,925,992.89 482,341.40 0.46 3,509.83 MWD+IFR-AK-CAZ-SC(4) 10,292.58 90.82 190.65 6,360.32 6,212.82 -4,077.65 1,288.32 5,925,899.25 482,322.08 1.81 3,605.27 MWD+IFR-AK-CAZ-SC(4) 10,386.51 90.41 188.75 6,359.32 6,211.82 -4,170.23 1,272.49 5,925,806.72 482,306.02 2.07 3,698.79 MWD+IFR-AK-CAZ-SC(4) 10,481.73 90.17 190.15 6,358.83 6,211.33 -4,264.15 1,256.86 5,925,712.85 482,290.15 1.49 3,793.56 MWD+IFR-AK-CAZ-SC(4) 10,576.55 90.31 190.20 6,358.44 6,210.94 -4,357.48 1,240.11 5,925,619.57 482,273.17 0.16 3,888.04 MWD+IFR-AK-CAZ-SC(4) 10,670.99 90.58 191.18 6,357.70 6,210.20 -4,450.28 1,222.59 5,925,526.83 482,255.42 1.08 3,982.21 MWD+IFR-AK-CAZ-SC(4) 10,765.27 90.55 192.16 6,356.77 6,209.27 -4,542.60 1,203.52 5,925,434.56 482,236.12 1.04 4,076.32 MWD+IFR-AK-CAZ-SC(4) 10,858.48 89.83 194.08 6,356.46 6,208.96 -4,633.38 1,182.37 5,925,343.85 482,214.74 2.20 4,169.48 MWD+IFR-AK-CAZ-SC(4) 10,954.19 90.24 195.93 6,356.41 6,208.91 -4,725.82 1,157.59 5,925,251.48 482,189.73 1.98 4,265.18 MWD+IFR-AK-CAZ-SC(4) 11,050.22 89.25 196.73 6,356.83 6,209.33 -4,817.97 1,130.59 5,925,159.40 482,162.50 1.33 4,361.18 MWD+IFR-AK-CAZ-SC(4) 11,144.66 85.50 197.93 6,361.16 6,213.66 -4,908.01 1,102.49 5,925,069.44 482,134.19 4.17 4,455.43 MWD+IFR-AK-CAZ-SC(4) 11,238.25 86.77 197.87 6,367.47 6,219.97 -4,996.87 1,073.79 5,924,980.67 482,105.27 1.36 4,548.68 MWD+IFR-AK-CAZ-SC(4) 9/24/2015 3:14:03PM Page 5 COMPASS 5000.1 Build 74 • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-10 Project: Kuparuk River Unit TVD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Site: Kuparuk 2S Pad MD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Well: 2S-10 North Reference: True Wellbore: 2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,333.47 88.83 196.92 6,371.12 6,223.62 -5,087.66 1,045.35 5,924,889.96 482,076.60 2.38 4,643.75 MWD+IFR-AK-CAZ-SC(4) 11,428.31 88.94 196.37 6,372.97 6,225.47 -5,178.51 1,018.19 5,924,799.19 482,049.21 0.59 4,738.53 MWD+IFR-AK-CAZ-SC(4) 11,523.26 90.24 195.99 6,373.65 6,226.15 -5,269.69 991.73 5,924,708.08 482,022.53 1.43 4,833.45 MWD+IFR-AK-CAZ-SC(4) 11,617.81 88.42 195.85 6,374.75 6,227.25 -5,360.61 965.80 5,924,617.24 481,996.37 1.93 4,927.98 MWD+IFR-AK-CAZ-SC(4) 11,712.45 88.25 194.88 6,377.50 6,230.00 -5,451.82 940.74 5,924,526.09 481,971.08 1.04 5,022.58 MWD+IFR-AK-CAZ-SC(4) 11,807.67 90.93 193.47 6,378.18 6,230.68 -5,544.13 917.42 5,924,433.85 481,947.53 3.18 5,117.77 MWD+IFR-AK-CAZ-SC(4) 11,902.78 90.58 194.67 6,376.93 6,229.43 -5,636.38 894.30 5,924,341.67 481,924.19 1.31 5,212.86 MWD+IFR-AK-CAZ-SC(4) 11,997.99 90.21 195.48 6,376.27 6,228.77 -5,728.31 869.54 5,924,249.82 481,899.20 0.94 5,308.07 MWD+IFR-AK-CAZ-SC(4) 12,092.97 90.65 195.52 6,375.56 6,228.06 -5,819.83 844.16 5,924,158.37 481,873.59 0.47 5,403.04 MWD+IFR-AK-CAZ-SC(4) 12,187.12 90.17 195.41 6,374.89 6,227.39 -5,910.57 819.05 5,924,067.70 481,848.26 0.52 5,497.19 MWD+IFR-AK-CAZ-SC(4) 12,281.45 90.45 194.32 6,374.38 6,226.88 -6,001.74 794.86 5,923,976.60 481,823.83 1.19 5,591.51 MWD+IFR-AK-CAZ-SC(4) 12,375.72 90.00 196.52 6,374.01 6,226.51 -6,092.61 769.79 5,923,885.80 481,798.54 2.38 5,685.77 MWD+IFR-AK-CAZ-SC(4) 12,470.40 88.18 193.33 6,375.51 6,228.01 -6,184.07 745.41 5,923,794.41 481,773.94 3.88 5,780.43 MWD+IFR-AK-CAZ-SC(4) 12,564.81 86.47 192.24 6,379.92 6,232.42 -6,276.03 724.54 5,923,702.51 481,752.84 2.15 5,874.66 MWD+IFR-AK-CAZ-SC(4) 12,660.18 87.56 191.41 6,384.88 6,237.38 -6,369.25 705.03 5,923,609.35 481,733.09 1.44 5,969.75 MWD+IFR-AK-CAZ-SC(4) 12,755.53 87.15 193.11 6,389.28 6,241.78 -6,462.32 684.80 5,923,516.34 481,712.63 1.83 6,064.88 MWD+IFR-AK-CAZ-SC(4) 12,850.38 87.36 193.44 6,393.83 6,246.33 -6,554.53 663.05 5,923,424.20 481,690.65 0.41 6,159.58 MWD+IFR-AK-CAZ-SC(4) 12,944.88 88.83 192.50 6,396.97 6,249.47 -6,646.57 641.85 5,923,332.22 481,669.22 1.85 6,253.97 MWD+IFR-AK-CAZ-SC(4) 13,039.56 88.63 194.11 6,399.07 6,251.57 -6,738.68 620.07 5,923,240.17 481,647.21 1.71 6,348.58 MWD+IFR-AK-CAZ-SC(4) 13,133.08 90.00 195.43 6,400.18 6,252.68 -6,829.10 596.23 5,923,149.82 481,623.15 2.03 6,442.09 MWD+IFR-AK-CAZ-SC(4) 13,225.82 89.66 197.15 6,400.46 6,252.96 -6,918.11 570.22 5,923,060.89 481,596.91 1.89 6,534.80 MWD+IFR-AK-CAZ-SC(4) 13,320.40 89.93 198.83 6,400.80 6,253.30 -7,008.06 541.01 5,922,971.02 481,567.48 1.80 6,629.25 MWD+IFR-AK-CAZ-SC(4) 13,414.08 89.66 199.43 6,401.13 6,253.63 -7,096.57 510.31 5,922,882.60 481,536.56 0.70 6,722.68 MWD+IFR-AK-CAZ-SC(4) 13,510.10 88.87 200.31 6,402.36 6,254.86 -7,186.86 477.67 5,922,792.39 481,503.71 1.23 6,818.35 MWD+IFR-AK-CAZ-SC(4) 13,602.84 89.21 201.55 6,403.92 6,256.42 -7,273.47 444.55 5,922,705.88 481,470.37 1.39 6,910.58 MWD+IFR-AK-CAZ-SC(4) 13,697.55 89.73 200.10 6,404.79 6,257.29 -7,361.99 410.88 5,922,617.46 481,436.48 1.63 7,004.79 MWD+IFR-AK-CAZ-SC(4) 13,786.78 90.00 197.85 6,405.01 6,257.51 -7,446.36 381.87 5,922,533.16 481,407.26 2.54 7,093.80 MWD+IFR-AK-CAZ-SC(4) 13,882.43 91.54 195.90 6,403.72 6,256.22 -7,537.88 354.11 5,922,441.73 481,379.27 2.60 7,189.38 MWD+IFR-AK-CAZ-SC(4) 13,980.69 92.13 195.38 6,400.57 6,253.07 -7,632.45 327.63 5,922,347.23 481,352.56 0.80 7,287.58 MWD+IFR-AK-CAZ-SC(4) 14,076.36 90.27 196.24 6,398.57 6,251.07 -7,724.48 301.57 5,922,255.28 481,326.28 2.14 7,383.22 MWD+IFR-AK-CAZ-SC(4) 14,170.95 88.80 197.85 6,399.34 6,251.84 -7,814.90 273.85 5,922,164.93 481,298.33 2.30 7,477.74 MWD+IFR-AK-CAZ-SC(4) 14,265.96 88.49 196.51 6,401.58 6,254.08 -7,905.65 245.80 5,922,074.27 481,270.05 1.45 7,572.65 MWD+IFR-AK-CAZ-SC(4) 14,361.22 87.08 196.55 6,405.27 6,257.77 -7,996.90 218.71 5,921,983.09 481,242.74 1.48 7,667.80 MWD+IFR-AK-CAZ-SC(4) 14,455.93 87.29 195.88 6,409.92 6,262.42 -8,087.73 192.30 5,921,892.34 481,216.10 0.74 7,762.38 MWD+IFR-AK-CAZ-SC(4) 14,549.80 87.91 194.56 6,413.85 6,266.35 -8,178.23 167.68 5,921,801.91 481,191.25 1.55 7,856.16 MWD+IFR-AK-CAZ-SC(4) 14,644.65 86.05 194.55 6,418.85 6,271.35 -8,269.90 143.88 5,921,710.31 481,167.22 1.96 7,950.87 MWD+IFR-AK-CAZ-SC(4) 14,739.72 85.64 193.74 6,425.73 6,278.23 -8,361.85 120.70 5,921,618.43 481,143.82 0.95 8,045.68 MWD+IFR-AK-CAZ-SC(4) 14,834.45 88.80 192.11 6,430.33 6,282.83 -8,454.05 99.55 5,921,526.29 481,122.43 3.75 8,140.22 MWD+IFR-AK-CAZ-SC(4) 14,885.00 90.73 192.11 6,430.53 6,283.03 -8,503.48 88.94 5,921,476.89 481,111.71 3.82 8,190.71 BLIND(5 NOT an Actual Survey 4 1/2"x 6-3/4" 9/24/2015 3:14:03PM Page 6 COMPASS 5000.1 Build 74 Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-10 Project: Kuparuk River Unit TVD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Site: Kuparuk 2S Pad MD Reference: Actual:120+27.50©147.50usft(Doyon-141) Well: 2S-10 North Reference: True Wellbore: 2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 14,896.00 91.15 192.11 6,430.35 6,282.85 -8,514.23 86.63 5,921,466.15 481,109.37 3.82 8,201.69 Projection to TD Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. Yes ❑ No I have checked to the best of my ability that the following data is correct: 1: Surface Coordinates n Declination & Convergence [] GRS Survey Corrections ri Survey Tool Codes Vincent ° "' *Vincent ' `�' SLB DE: Osara atneemnisantensibcanc ` Dema 7913.00.24145334-06OD Jake Voss ° '"�°`�"� Client Representative: WM MOP �� ,s Date: 24-Sep2015 9/24/2015 3:14:03PM Page 7 COMPASS 5000.1 Build 74 215110 26292 FINAL ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad 2S-10 SEP 3 0 2uU Definitive Survey Report 24 September, 2015 NAD 83 • Schlumberger • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-10 Project: Kuparuk River Unit TVD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Site: Kuparuk 2S Pad MD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Well: 2S-10 North Reference: True Wellbore: 2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well 2S-10 Well Position +N/-S 0.00 usft Northing: 5,929,729.31 usfi Latitude: 70° 13' '3.376 N +E/-W 0.00 usft Easting: 1,621,077.45 usft Longitude: 150°9'21.677 W Position Uncertainty 0.00 usft Wellhead Elevation: usfi Ground Level: 120.00 usft Wellbore 2S-10 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (°) (nT) BGGM2015 9/5/2015 18.60 80.87 57,489 Design 2S-10 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.50 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 27.50 0.00 0.00 195.00 Survey Program Date 9/24/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 93.90 462.50 2S-10 Srvy#1 Gyro(2S-10) GYD-GC-MS Gyrodata gyrocompassing m/s 9/4/2015 12:02 506.90 2,627.01 2S-10 Srvy#2 MWD+IFR-AK-CAZ-SC(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/4/2015 12:17 2,725.17 7,429.08 2S-10 Srvy#3 MWD+IFR-AK-CAZ-SC(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/4/2015 12:31 7,519.07 14,834.45 2S-10 Srvy#4 MWD+IFR-AK-CAZ-SC(2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/8/2015 11:3 14,896.00 14,896.00 2S-10 Srvy#5-Projection to TD(2S-10)BLIND Blind drilling 9/24/2015 2:41 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 27.50 0.00 0.00 27.50 -120.00 0.00 0.00 5,929,729.31 1,621,077.45 0.00 0.00 UNDEFINED 94.40 0.45 73.93 94.40 -53.10 0.07 0.25 5,929,729.38 1,621,077.70 0.67 -0.14 GYD-GC-MS(1) 107.50 0.46 73.22 107.50 -40.00 0.10 0.35 5,929,729.41 1,621,077.80 0.11 -0.19 GYD-GC-MS(11 NOT an Actual Survey 16"x 42" 186.50 0.54 69.67 186.50 39.00 0.32 1.01 5,929,729.63 1,621,078.46 0.11 -0.57 GYD-GC-MS(1) 278.70 0.58 73.72 278.69 131.19 0.61 1.86 5,929,729.91 1,621,079.32 0.06 -1.07 GYD-GC-MS(1) 370.80 0.73 77.64 370.79 223.29 0.86 2.88 5,929,730.16 1,621,080.34 0.17 -1.58 GYD-GC-MS(1) 506.90 0.78 74.23 506.87 359.37 1.30 4.62 5,929,730.59 1,621,082.08 0.05 -2.45 MWD+IFR-AK-CAZ-SC(2) 598.44 0.51 89.00 598.41 450.91 1.48 5.63 5,929,730.77 1,621,083.08 0.34 -2.88 MWD+IFR-AK-CAZ-SC(2) 696.00 1.69 54.94 695.95 548.45 2.31 7.24 5,929,731.60 1,621,084.70 1.33 -4.10 MWD+IFR-AK-CAZ-SC(2) 788.22 2.43 45.82 788.11 640.61 4.45 9.76 5,929,733.73 1,621,087.22 0.88 -6.83 MWD+IFR-AK-CAZ-SC(2) 9/24/2015 2:44:44PM Page 2 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-10 Project: Kuparuk River Unit TVD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Site: Kuparuk 2S Pad MD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Well: 2S-10 North Reference: True Wellbore: 2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 880.07 3.57 31.30 879.83 732.33 8.25 12.64 5,929,737.53 1,621,090.11 1.48 -11.24 MWD+IFR-AK-CAZ-SC(2) 972.37 5.71 29.21 971.82 824.32 14.72 16.37 5,929,743.98 1,621,093.86 2.33 -18.45 MWD+IFR-AK-CAZ-SC(2) 1,065.00 7.70 32.99 1,063.82 916.32 23.95 22.00 5,929,753.19 1,621,099.51 2.20 -28.82 MWD+IFR-AK-CAZ-SC(2) 1,115.38 9.02 32.68 1,113.66 966.16 30.10 25.97 5,929,759.34 1,621,103.50 2.62 -35.80 MWD+IFR-AK-CAZ-SC(2) 1,158.68 10.08 31.52 1,156.36 1,008.86 36.19 29.78 5,929,765.41 1,621,107.33 2.49 -42.66 MWD+IFR-AK-CAZ-SC(2) 1,216.08 11.15 32.19 1,212.78 1,065.28 45.17 35.37 5,929,774.38 1,621,112.93 1.88 -52.78 MWD+IFR-AK-CAZ-SC(2) 1,251.55 12.84 31.28 1,247.47 1,099.97 51.44 39.24 5,929,780.64 1,621,116.82 4.79 -59.84 MWD+IFR-AK-CAZ-SC(2) 1,345.39 14.91 29.17 1,338.57 1,191.07 70.89 50.54 5,929,800.06 1,621,128.17 2.27 -81.56 MWD+IFR-AK-CAZ-SC(2) 1,438.07 15.95 33.62 1,427.91 1,280.41 91.91 63.40 5,929,821.05 1,621,141.08 1.70 -105.19 MWD+IFR-AK-CAZ-SC(2) 1,531.92 19.06 42.90 1,517.42 1,369.92 113.88 80.98 5,929,842.97 1,621,158.72 4.44 -130.96 MWD+IFR-AK-CAZ-SC(2) 1,626.66 20.25 56.47 1,606.69 1,459.19 134.28 105.19 5,929,863.31 1,621,182.98 4.97 -156.93 MWD+IFR-AK-CAZ-SC(2) 1,719.09 20.73 63.37 1,693.28 1,545.78 150.45 133.15 5,929,879.40 1,621,210.98 2.66 -179.79 MWD+IFR-AK-CAZ-SC(2) 1,814.62 22.50 71.62 1,782.11 1,634.61 163.80 165.62 5,929,892.66 1,621,243.48 3.68 -201.08 MWD+IFR-AK-CAZ-SC(2) 1,909.13 24.42 81.56 1,868.84 1,721.34 172.37 202.13 5,929,901.14 1,621,280.00 4.65 -218.81 MWD+IFR-AK-CAZ-SC(2) 2,002.26 25.90 86.94 1,953.14 1,805.64 176.29 241.49 5,929,904.95 1,621,319.37 2.92 -232.78 MWD+IFR-AK-CAZ-SC(2) 2,094.67 26.33 88.82 2,036.12 1,888.62 177.78 282.13 5,929,906.35 1,621,360.01 1.01 -244.75 MWD+IFR-AK-CAZ-SC(2) 2,187.42 26.80 88.37 2,119.08 1,971.58 178.80 323.60 5,929,907.26 1,621,401.48 0.55 -256.46 MWD+IFR-AK-CAZ-SC(2) 2,280.73 26.91 89.57 2,202.32 2,054.82 179.56 365.74 5,929,907.91 1,621,443.62 0.59 -268.10 MWD+IFR-AK-CAZ-SC(2) 2,373.10 27.01 89.98 2,284.66 2,137.16 179.72 407.62 5,929,907.97 1,621,485.49 0.23 -279.10 MWD+IFR-AK-CAZ-SC(2) 2,465.75 27.03 89.30 2,367.19 2,219.69 179.99 449.71 5,929,908.12 1,621,527.57 0.33 -290.25 MWD+IFR-AK-CAZ-SC(2) 2,558.55 26.95 89.74 2,449.89 2,302.39 180.34 491.82 5,929,908.37 1,621,569.69 0.23 -301.49 MWD+IFR-AK-CAZ-SC(2) 2,627.01 27.67 89.48 2,510.71 2,363.21 180.56 523.23 5,929,908.50 1,621,601.09 1.07 -309.83 MWD+IFR-AK-CAZ-SC(2) 2,688.00 28.50 88.03 2,564.52 2,417.02 181.19 551.93 5,929,909.06 1,621,629.79 1.76 -317.86 MWD+IFR-AV""" - NOT an Actual Survey 10 3/4"x 13-1/2 2,725.17 29.01 87.18 2,597.11 2,449.61 181.93 569.80 5,929,909.76 1,621,647.66 1.76 -323.21 MWD+IFR-AK-CAZ-SC(3) 2,816.64 28.66 86.99 2,677.24 2,529.74 184.18 613.86 5,929,911.89 1,621,691.72 0.40 -336.78 MWD+IFR-AK-CAZ-SC(3) 2,864.99 28.61 86.53 2,719.68 2,572.18 185.49 636.99 5,929,913.14 1,621,714.85 0.47 -344.03 MWD+IFR-AK-CAZ-SC(3) 2,909.92 28.71 85.72 2,759.10 2,611.60 186.94 658.49 5,929,914.54 1,621,736.35 0.89 -351.00 MWD+IFR-AK-CAZ-SC(3) 3,004.46 28.58 86.65 2,842.07 2,694.57 189.96 703.71 5,929,917.44 1,621,781.57 0.49 -365.62 MWD+IFR-AK-CAZ-SC(3) 3,099.67 28.49 85.34 2,925.72 2,778.22 193.14 749.08 5,929,920.50 1,621,826.94 0.66 -380.43 MWD+IFR-AK-CAZ-SC(3) 3,194.74 28.21 84.10 3,009.38 2,861.88 197.29 794.03 5,929,924.54 1,621,871.90 0.69 -396.07 MWD+IFR-AK-CAZ-SC(3) 3,289.77 28.47 83.37 3,093.02 2,945.52 202.21 838.87 5,929,929.35 1,621,916.75 0.46 -412.44 MWD+IFR-AK-CAZ-SC(3) 3,378.65 28.38 82.95 3,171.19 3,023.69 207.25 880.87 5,929,934.28 1,621,958.77 0.25 -428.17 MWD+IFR-AK-CAZ-SC(3) 3,471.79 28.42 84.19 3,253.12 3,105.62 212.21 924.89 5,929,939.12 1,622,002.79 0.63 -444.36 MWD+IFR-AK-CAZ-SC(3) 3,566.57 28.45 85.54 3,336.47 3,188.97 216.25 969.84 5,929,943.05 1,622,047.75 0.68 -459.89 MWD+IFR-AK-CAZ-SC(3) 3,657.96 28.58 85.71 3,416.77 3,269.27 219.58 1,013.34 5,929,946.26 1,622,091.25 0.17 -474.37 MWD+IFR-AK-CAZ-SC(3) 3,751.66 28.48 87.25 3,499.09 3,351.59 222.33 1,058.01 5,929,948.90 1,622,135.92 0.79 -488.58 MWD+IFR-AK-CAZ-SC(3) 3,843.69 28.54 88.26 3,579.96 3,432.46 224.05 1,101.90 5,929,950.51 1,622,179.81 0.53 -501.60 MWD+IFR-AK-CAZ-SC(3) 3,936.51 28.60 87.63 3,661.48 3,513.98 225.64 1,146.26 5,929,951.98 1,622,224.17 0.33 -514.62 MWD+IFR-AK-CAZ-SC(3) 4,029.03 28.51 86.43 3,742.75 3,595.25 227.93 1,190.42 5,929,954.16 1,622,268.33 0.63 -528.27 MWD+IFR-AK-CAZ-SC(3) 9/24/2015 2:44:44PM Page 3 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-10 Project: Kuparuk River Unit TVD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Site: Kuparuk 2S Pad MD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Well: 2S-10 North Reference: True Wellbore: 2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,123.62 28.53 87.35 3,825.86 3,678.36 230.38 1,235.52 5,929,956.50 1,622,313.43 0.46 -542.30 MWD+IFR-AK-CAZ-SC(3) 4,217.11 28.59 87.17 3,907.97 3,760.47 232.51 1,280.16 5,929,958.52 1,622,358.08 0.11 -555.92 MWD+IFR-AK-CAZ-SC(3) 4,310.04 28.60 88.34 3,989.57 3,842.07 234.26 1,324.60 5,929,960.15 1,622,402.52 0.60 -569.11 MWD+IFR-AK-CAZ-SC(3) 4,404.28 28.51 89.38 4,072.35 3,924.85 235.15 1,369.64 5,929,960.93 1,622,447.55 0.54 -581.63 MWD+IFR-AK-CAZ-SC(3) 4,495.10 28.46 89.55 4,152.17 4,004.67 235.56 1,412.95 5,929,961.22 1,622,490.86 0.10 -593.23 MWD+IFR-AK-CAZ-SC(3) 4,590.23 28.35 88.97 4,235.85 4,088.35 236.14 1,458.20 5,929,961.69 1,622,536.11 0.31 -605.51 MWD+IFR-AK-CAZ-SC(3) 4,682.03 28.23 89.55 4,316.68 4,169.18 236.70 1,501.70 5,929,962.14 1,622,579.61 0.33 -617.31 MWD+IFR-AK-CAZ-SC(3) 4,776.69 28.21 94.78 4,400.11 4,252.61 235.02 1,546.39 5,929,960.34 1,622,624.29 2.61 -627.24 MWD+IFR-AK-CAZ-SC(3) 4,869.45 28.69 99.99 4,481.68 4,334.18 229.33 1,590.18 5,929,954.53 1,622,668.05 2.72 -633.08 MWD+IFR-AK-CAZ-SC(3) 4,961.45 27.81 106.66 4,562.74 4,415.24 219.34 1,632.50 5,929,944.44 1,622,710.34 3.56 -634.39 MWD+IFR-AK-CAZ-SC(3) 5,055.86 26.77 113.98 4,646.66 4,499.16 204.38 1,673.03 5,929,929.38 1,622,750.84 3.72 -630.43 MWD+IFR-AK-CAZ-SC(3) 5,149.51 28.34 121.09 4,729.71 4,582.21 184.32 1,711.35 5,929,909.23 1,622,789.10 3.89 -620.97 MWD+IFR-AK-CAZ-SC(3) 5,242.84 29.66 127.18 4,811.35 4,663.85 158.92 1,748.73 5,929,883.73 1,622,826.41 3.46 -606.11 MWD+IFR-AK-CAZ-SC(3) 5,335.66 29.54 130.70 4,892.07 4,744.57 130.12 1,784.38 5,929,854.84 1,622,861.98 1.88 -587.52 MWD+IFR-AK-CAZ-SC(3) 5,426.94 29.94 133.79 4,971.33 4,823.83 99.68 1,817.88 5,929,824.32 1,622,895.40 1.74 -566.79 MWD+IFR-AK-CAZ-SC(3) 5,519.21 30.13 138.65 5,051.22 4,903.72 66.36 1,849.81 5,929,790.92 1,622,927.24 2.64 -542.86 MWD+IFR-AK-CAZ-SC(3) 5,611.31 31.24 142.26 5,130.43 4,982.93 30.11 1,879.70 5,929,754.60 1,622,957.04 2.33 -515.59 MWD+IFR-AK-CAZ-SC(3) 5,703.86 32.97 146.14 5,208.83 5,061.33 -9.78 1,908.43 5,929,714.63 1,622,985.66 2.91 -484.49 MWD+IFR-AK-CAZ-SC(3) 5,798.71 34.68 151.60 5,287.64 5,140.14 -54.97 1,935.65 5,929,669.39 1,623,012.76 3.68 -447.89 MWD+IFR-AK-CAZ-SC(3) 5,892.26 36.97 156.04 5,363.50 5,216.00 -104.10 1,959.74 5,929,620.20 1,623,036.72 3.70 -406.67 MWD+IFR-AK-CAZ-SC(3) 5,985.23 39.27 160.70 5,436.66 5,289.16 -157.43 1,980.83 5,929,566.81 1,623,057.67 3.96 -360.61 MWD+IFR-AK-CAZ-SC(3) 6,078.55 40.79 164.67 5,508.12 5,360.62 -214.72 1,998.65 5,929,509.49 1,623,075.35 3.18 -309.89 MWD+IFR-AK-CAZ-SC(3) 6,173.63 43.21 167.37 5,578.78 5,431.28 -276.45 2,013.98 5,929,447.73 1,623,090.52 3.18 -254.23 MWD+IFR-AK-CAZ-SC(3) 6,265.92 45.61 168.60 5,644.70 5,497.20 -339.61 2,027.41 5,929,384.53 1,623,103.78 2.76 -196.69 MWD+IFR-AK-CAZ-SC(3) 6,357.04 48.09 169.16 5,707.02 5,559.52 -404.84 2,040.22 5,929,319.28 1,623,116.43 2.76 -137.01 MWD+IFR-AK-CAZ-SC(3) 6,451.06 50.46 169.97 5,768.35 5,620.85 -474.91 2,053.12 5,929,249.19 1,623,129.14 2.60 -72.66 MWD+IFR-AK-CAZ-SC(3) 6,544.59 53.52 172.52 5,825.95 5,678.45 -547.73 2,064.30 5,929,176.35 1,623,140.14 3.91 -5.22 MWD+IFR-AK-CAZ-SC(3) 6,638.03 56.27 175.01 5,879.68 5,732.18 -623.70 2,072.57 5,929,100.36 1,623,148.21 3.66 66.03 MWD+IFR-AK-CAZ-SC(3) 6,731.17 57.89 176.93 5,930.30 5,782.80 -701.69 2,078.05 5,929,022.37 1,623,153.49 2.45 139.94 MWD+IFR-AK-CAZ-SC(3) 6,825.34 59.14 179.50 5,979.49 5,831.99 -781.94 2,080.54 5,928,942.11 1,623,155.78 2.68 216.82 MWD+IFR-AK-CAZ-SC(3) 6,919.12 60.23 180.98 6,026.83 5,879.33 -862.90 2,080.20 5,928,861.17 1,623,155.22 1.79 295.10 MWD+IFR-AK-CAZ-SC(3) 7,011.64 61.40 182.28 6,071.95 5,924.45 -943.63 2,077.90 5,928,780.45 1,623,152.72 1.76 373.68 MWD+IFR-AK-CAZ-SC(3) 7,106.70 64.15 184.57 6,115.44 5,967.94 -1,027.99 2,072.83 5,928,696.11 1,623,147.43 3.60 456.48 MWD+IFR-AK-CAZ-SC(3) 7,200.31 66.80 186.14 6,154.29 6,006.79 -1,112.77 2,064.87 5,928,611.36 1,623,139.25 3.22 540.43 MWD+IFR-AK-CAZ-SC(3) 7,293.03 70.01 187.65 6,188.41 6,040.91 -1,198.35 2,054.51 5,928,525.82 1,623,128.68 3.78 625.77 MWD+IFR-AK-CAZ-SC(3) 7,386.50 73.19 189.59 6,217.91 6,070.41 -1,286.02 2,041.20 5,928,438.19 1,623,115.15 3.93 713.90 MWD+IFR-AK-CAZ-SC(3) 7,429.08 74.76 190.75 6,229.67 6,082.17 -1,326.30 2,033.97 5,928,397.93 1,623,107.82 4.52 754.67 MWD+IFR-AK-CAZ-SC(3) 7,492.00 75.95 189.28 6,245.58 6,098.08 -1,386.24 2,023.39 5,928,338.02 1,623,097.08 2.95 815.32 MWD+IFR-A('rn7 cr.tn\ NOT an Actual Survey 7-5/8"x 9-7/8" 7,519.07 76.47 188.65 6,252.03 6,104.53 -1,412.21 2,019.29 5,928,312.07 1,623,092.92 2.95 841.46 MWD+IFR-AK-CAZ-SC(4) 9/24/2015 2:44:44PM Page 4 COMPASS 5000.1 Build 74 • i Schlumberger • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-10 Project: Kuparuk River Unit TVD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Site: Kuparuk 2S Pad MD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Well: 2S-10 North Reference: True Wellbore: 2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,551.02 76.99 190.96 6,259.36 6,111.86 -1,442.85 2,014.00 5,928,281.44 1,623,087.55 7.22 872.43 MWD+IFR-AK-CAZ-SC(4) 7,644.10 79.56 188.84 6,278.28 6,130.78 -1,532.62 1,998.34 5,928,191.72 1,623,071.66 3.55 963.19 MWD+IFR-AK-CAZ-SC(4) 7,741.66 81.29 193.17 6,294.51 6,147.01 -1,627.02 1,979.97 5,928,097.38 1,623,053.05 4.72 1,059.13 MWD+IFR-AK-CAZ-SC(4) 7,836.02 82.12 193.31 6,308.13 6,160.63 -1,717.91 1,958.59 5,928,006.55 1,623,031.43 0.89 1,152.46 MWD+IFR-AK-CAZ-SC(4) 7,929.79 83.68 196.44 6,319.72 6,172.22 -1,807.83 1,934.70 5,927,916.70 1,623,007.32 3.71 1,245.49 MWD+IFR-AK-CAZ-SC(4) 8,024.10 85.16 198.22 6,328.89 6,181.39 -1,897.43 1,906.74 5,927,827.19 1,622,979.13 2.45 1,339.27 MWD+IFR-AK-CAZ-SC(4) 8,118.25 84.92 198.71 6,337.03 6,189.53 -1,986.40 1,877.03 5,927,738.31 1,622,949.20 0.58 1,432.90 MWD+IFR-AK-CAZ-SC(4) 8,214.05 87.87 197.66 6,343.05 6,195.55 -2,077.22 1,847.20 5,927,647.57 1,622,919.14 3.27 1,528.35 MWD+IFR-AK-CAZ-SC(4) 8,308.48 89.62 196.11 6,345.12 6,197.62 -2,167.55 1,819.78 5,927,557.32 1,622,891.49 2.48 1,622.70 MWD+IFR-AK-CAZ-SC(4) 8,402.76 89.04 196.58 6,346.22 6,198.72 -2,258.01 1,793.25 5,927,466.93 1,622,864.73 0.79 1,716.95 MWD+IFR-AK-CAZ-SC(4) 8,496.37 89.28 197.01 6,347.60 6,200.10 -2,347.62 1,766.20 5,927,377.40 1,622,837.46 0.53 1,810.50 MWD+IFR-AK-CAZ-SC(4) 8,591.38 90.69 196.27 6,347.62 6,200.12 -2,438.65 1,739.00 5,927,286.45 1,622,810.02 1.68 1,905.47 MWD+IFR-AK-CAZ-SC(4) 8,686.38 90.69 196.85 6,346.48 6,198.98 -2,529.70 1,711.92 5,927,195.48 1,622,782.72 0.61 2,000.43 MWD+IFR-AK-CAZ-SC(4) 8,780.66 90.82 196.21 6,345.23 6,197.73 -2,620.08 1,685.10 5,927,105.18 1,622,755.67 0.69 2,094.66 MWD+IFR-AK-CAZ-SC(4) 8,874.49 90.45 195.66 6,344.19 6,196.69 -2,710.30 1,659.34 5,927,015.04 1,622,729.68 0.71 2,188.48 MWD+IFR-AK-CAZ-SC(4) 8,969.32 90.10 194.75 6,343.74 6,196.24 -2,801.80 1,634.47 5,926,923.60 1,622,704.58 1.03 2,283.30 MWD+IFR-AK-CAZ-SC(4) 9,064.96 90.41 194.56 6,343.31 6,195.81 -2,894.33 1,610.27 5,926,831.15 1,622,680.14 0.38 2,378.94 MWD+IFR-AK-CAZ-SC(4) 9,159.93 89.62 194.95 6,343.29 6,195.79 -2,986.17 1,586.09 5,926,739.38 1,622,655.72 0.93 2,473.91 MWD+IFR-AK-CAZ-SC(4) 9,252.61 88.70 196.17 6,344.65 6,197.15 -3,075.44 1,561.23 5,926,650.18 1,622,630.64 1.65 2,566.57 MWD+IFR-AK-CAZ-SC(4) 9,348.40 87.84 197.16 6,347.54 6,200.04 -3,167.16 1,533.77 5,926,558.54 1,622,602.95 1.37 2,662.27 MWD+IFR-AK-CAZ-SC(4) 9,443.16 86.71 198.40 6,352.04 6,204.54 -3,257.29 1,504.87 5,926,468.49 1,622,573.82 1.77 2,756.81 MWD+IFR-AK-CAZ-SC(4) 9,536.45 87.36 198.72 6,356.87 6,209.37 -3,345.61 1,475.22 5,926,380.26 1,622,543.94 0.78 2,849.80 MWD+IFR-AK-CAZ-SC(4) 9,630.68 89.14 197.21 6,359.75 6,212.25 -3,435.20 1,446.17 5,926,290.76 1,622,514.67 2.48 2,943.85 MWD+IFR-AK-CAZ-SC(4) 9,725.08 88.77 196.00 6,361.47 6,213.97 -3,525.64 1,419.20 5,926,200.39 1,622,487.47 1.34 3,038.20 MWD+IFR-AK-CAZ-SC(4) 9,819.22 89.11 194.88 6,363.21 6,215.71 -3,616.37 1,394.14 5,926,109.74 1,622,462.18 1.24 3,132.32 MWD+IFR-AK-CAZ-SC(4) 9,913.93 90.03 193.93 6,363.92 6,216.42 -3,708.10 1,370.58 5,926,018.08 1,622,438.39 1.40 3,227.02 MWD+IFR-AK-CAZ-SC(4) 10,008.07 90.31 192.73 6,363.64 6,216.14 -3,799.70 1,348.87 5,925,926.54 1,622,416.45 1.31 3,321.11 MWD+IFR-AK-CAZ-SC(4) 10,103.19 90.72 192.81 6,362.79 6,215.29 -3,892.46 1,327.85 5,925,833.84 1,622,395.19 0.44 3,416.16 MWD+IFR-AK-CAZ-SC(4) 10,196.95 90.72 192.38 6,361.61 6,214.11 -3,983.96 1,307.41 5,925,742.41 1,622,374.52 0.46 3,509.83 MWD+IFR-AK-CAZ-SC(4) 10,292.58 90.82 190.65 6,360.32 6,212.82 -4,077.65 1,288.32 5,925,648.77 1,622,355.19 1.81 3,605.27 MWD+IFR-AK-CAZ-SC(4) 10,386.51 90.41 188.75 6,359.32 6,211.82 -4,170.23 1,272.49 5,925,556.25 1,622,339.13 2.07 3,698.79 MWD+IFR-AK-CAZ-SC(4) 10,481.73 90.17 190.15 6,358.83 6,211.33 -4,264.15 1,256.86 5,925,462.37 1,622,323.26 1.49 3,793.56 MWD+IFR-AK-CAZ-SC(4) 10,576.55 90.31 190.20 6,358.44 6,210.94 -4,357.48 1,240.11 5,925,369.10 1,622,306.27 0.16 3,888.04 MWD+IFR-AK-CAZ-SC(4) 10,670.99 90.58 191.18 6,357.70 6,210.20 -4,450.28 1,222.59 5,925,276.35 1,622,288.52 1.08 3,982.21 MWD+IFR-AK-CAZ-SC(4) 10,765.27 90.55 192.16 6,356.77 6,209.27 -4,542.60 1,203.52 5,925,184.09 1,622,269.21 1.04 4,076.32 MWD+IFR-AK-CAZ-SC(4) 10,858.48 89.83 194.08 6,356.46 6,208.96 -4,633.38 1,182.37 5,925,093.38 1,622,247.83 2.20 4,169.48 MWD+IFR-AK-CAZ-SC(4) 10,954.19 90.24 195.93 6,356.41 6,208.91 -4,725.82 1,157.59 5,925,001.01 1,622,222.81 1.98 4,265.18 MWD+IFR-AK-CAZ-SC(4) 11,050.22 89.25 196.73 6,356.83 6,209.33 -4,817.97 1,130.59 5,924,908.93 1,622,195.58 1.33 4,361.18 MWD+IFR-AK-CAZ-SC(4) 11,144.66 85.50 197.93 6,361.16 6,213.66 -4,908.01 1,102.49 5,924,818.97 1,622,167.26 4.17 4,455.43 MWD+IFR-AK-CAZ-SC(4) 11,238.25 86.77 197.87 6,367.47 6,219.97 -4,996.87 1,073.79 5,924,730.20 1,622,138.33 1.36 4,548.68 MWD+IFR-AK-CAZ-SC(4) 9/24/2015 2:44:44PM Page 5 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-10 Project: Kuparuk River Unit TVD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Site: Kuparuk 2S Pad MD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Well: 2S-10 North Reference: True Wellbore: 2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,333.47 88.83 196.92 6,371.12 6,223.62 -5,087.66 1,045.35 5,924,639.49 1,622,109.66 2.38 4,643.75 MWD+IFR-AK-CAZ-SC(4) 11,428.31 88.94 196.37 6,372.97 6,225.47 -5,178.51 1,018.19 5,924,548.72 1,622,082.27 0.59 4,738.53 MWD+IFR-AK-CAZ-SC(4) 11,523.26 90.24 195.99 6,373.65 6,226.15 -5,269.69 991.73 5,924,457.61 1,622,055.58 1.43 4,833.45 MWD+IFR-AK-CAZ-SC(4) 11,617.81 88.42 195.85 6,374.75 6,227.25 -5,360.61 965.80 5,924,366.78 1,622,029.42 1.93 4,927.98 MWD+IFR-AK-CAZ-SC(4) 11,712.45 88.25 194.88 6,377.50 6,230.00 -5,451.82 940.74 5,924,275.63 1,622,004.12 1.04 5,022.58 MWD+IFR-AK-CAZ-SC(4) 11,807.67 90.93 193.47 6,378.18 6,230.68 -5,544.13 917.42 5,924,183.39 1,621,980.57 3.18 5,117.77 MWD+IFR-AK-CAZ-SC(4) 11,902.78 90.58 194.67 6,376.93 6,229.43 -5,636.38 894.30 5,924,091.22 1,621,957.22 1.31 5,212.86 MWD+IFR-AK-CAZ-SC(4) 11,997.99 90.21 195.48 6,376.27 6,228.77 -5,728.31 869.54 5,923,999.36 1,621,932.23 0.94 5,308.07 MWD+IFR-AK-CAZ-SC(4) 12,092.97 90.65 195.52 6,375.56 6,228.06 -5,819.83 844.16 5,923,907.91 1,621,906.61 0.47 5,403.04 MWD+IFR-AK-CAZ-SC(4) 12,187.12 90.17 195.41 6,374.89 6,227.39 -5,910.57 819.05 5,923,817.25 1,621,881.28 0.52 5,497.19 MWD+IFR-AK-CAZ-SC(4) 12,281.45 90.45 194.32 6,374.38 6,226.88 -6,001.74 794.86 5,923,726.15 1,621,856.85 1.19 5,591.51 MWD+IFR-AK-CAZ-SC(4) 12,375.72 90.00 196.52 6,374.01 6,226.51 -6,092.61 769.79 5,923,635.35 1,621,831.55 2.38 5,685.77 MWD+IFR-AK-CAZ-SC(4) 12,470.40 88.18 193.33 6,375.51 6,228.01 -6,184.07 745.41 5,923,543.96 1,621,806.94 3.88 5,780.43 MWD+IFR-AK-CAZ-SC(4) 12,564.81 86.47 192.24 6,379.92 6,232.42 -6,276.03 724.54 5,923,452.06 1,621,785.84 2.15 5,874.66 MWD+IFR-AK-CAZ-SC(4) 12,660.18 87.56 191.41 6,384.88 6,237.38 -6,369.25 705.03 5,923,358.90 1,621,766.09 1.44 5,969.75 MWD+IFR-AK-CAZ-SC(4) 12,755.53 87.15 193.11 6,389.28 6,241.78 -6,462.32 684.80 5,923,265.89 1,621,745.63 1.83 6,064.88 MWD+IFR-AK-CAZ-SC(4) 12,850.38 87.36 193.44 6,393.83 6,246.33 -6,554.53 663.05 5,923,173.75 1,621,723.64 0.41 6,159.58 MWD+IFR-AK-CAZ-SC(4) 12,944.88 88.83 192.50 6,396.97 6,249.47 -6,646.57 641.85 5,923,081.78 1,621,702.21 1.85 6,253.97 MWD+IFR-AK-CAZ-SC(4) 13,039.56 88.63 194.11 6,399.07 6,251.57 -6,738.68 620.07 5,922,989.73 1,621,680.19 1.71 6,348.58 MWD+IFR-AK-CAZ-SC(4) 13,133.08 90.00 195.43 6,400.18 6,252.68 -6,829.10 596.23 5,922,899.38 1,621,656.12 2.03 6,442.09 MWD+IFR-AK-CAZ-SC(4) 13,225.82 89.66 197.15 6,400.46 6,252.96 -6,918.11 570.22 5,922,810.44 1,621,629.88 1.89 6,534.80 MWD+IFR-AK-CAZ-SC(4) 13,320.40 89.93 198.83 6,400.80 6,253.30 -7,008.06 541.01 5,922,720.58 1,621,600.45 1.80 6,629.25 MWD+IFR-AK-CAZ-SC(4) 13,414.08 89.66 199.43 6,401.13 6,253.63 -7,096.57 510.31 5,922,632.16 1,621,569.52 0.70 6,722.68 MWD+IFR-AK-CAZ-SC(4) 13,510.10 88.87 200.31 6,402.36 6,254.86 -7,186.86 477.67 5,922,541.96 1,621,536.66 1.23 6,818.35 MWD+IFR-AK-CAZ-SC(4) 13,602.84 89.21 201.55 6,403.92 6,256.42 -7,273.47 444.55 5,922,455.44 1,621,503.32 1.39 6,910.58 MWD+IFR-AK-CAZ-SC(4) 13,697.55 89.73 200.10 6,404.79 6,257.29 -7,361.99 410.88 5,922,367.02 1,621,469.43 1.63 7,004.79 MWD+IFR-AK-CAZ-SC(4) 13,786.78 90.00 197.85 6,405.01 6,257.51 -7,446.36 381.87 5,922,282.73 1,621,440.20 2.54 7,093.80 MWD+IFR-AK-CAZ-SC(4) 13,882.43 91.54 195.90 6,403.72 6,256.22 -7,537.88 354.11 5,922,191.30 1,621,412.21 2.60 7,189.38 MWD+IFR-AK-CAZ-SC(4) 13,980.69 92.13 195.38 6,400.57 6,253.07 -7,632.45 327.63 5,922,096.80 1,621,385.50 0.80 7,287.58 MWD+IFR-AK-CAZ-SC(4) 14,076.36 90.27 196.24 6,398.57 6,251.07 -7,724.48 301.57 5,922,004.85 1,621,359.20 2.14 7,383.22 MWD+IFR-AK-CAZ-SC(4) 14,170.95 88.80 197.85 6,399.34 6,251.84 -7,814.90 273.85 5,921,914.50 1,621,331.25 2.30 7,477.74 MWD+IFR-AK-CAZ-SC(4) 14,265.96 88.49 196.51 6,401.58 6,254.08 -7,905.65 245.80 5,921,823.84 1,621,302.97 1.45 7,572.65 MWD+IFR-AK-CAZ-SC(4) 14,361.22 87.08 196.55 6,405.27 6,257.77 -7,996.90 218.71 5,921,732.67 1,621,275.65 1.48 7,667.80 MWD+IFR-AK-CAZ-SC(4) 14,455.93 87.29 195.88 6,409.92 6,262.42 -8,087.73 192.30 5,921,641.91 1,621,249.01 0.74 7,762.38 MWD+IFR-AK-CAZ-SC(4) 14,549.80 87.91 194.56 6,413.85 6,266.35 -8,178.23 167.68 5,921,551.49 1,621,224.16 1.55 7,856.16 MWD+IFR-AK-CAZ-SC(4) 14,644.65 86.05 194.55 6,418.85 6,271.35 -8,269.90 143.88 5,921,459.89 1,621,200.12 1.96 7,950.87 MWD+IFR-AK-CAZ-SC(4) 14,739.72 85.64 193.74 6,425.73 6,278.23 -8,361.85 120.70 5,921,368.01 1,621,176.72 0.95 8,045.68 MWD+IFR-AK-CAZ-SC(4) 14,834.45 88.80 192.11 6,430.33 6,282.83 -8,454.05 99.55 5,921,275.87 1,621,155.33 3.75 8,140.22 MWD+IFR-AK-CAZ-SC(4) 14,885.00 90.73 192.11 6,430.53 6,283.03 -8,503.48 88.94 5,921,226.48 1,621,144.60 3.82 8,190.71 BLIND(5) NOT an Actual Survey 4 1/2"x 6-3/4" 9/24/2015 2:44:44PM Page 6 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-10 Project: Kuparuk River Unit TVD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Site: Kuparuk 2S Pad MD Reference: Actual:120+27.50 @ 147.50usft(Doyon-141) Well: 2S-10 North Reference: True Wellbore: 2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 14,896.00 91.15 192.11 6,430.35 6,282.85 -8,514.23 86.63 5,921,215.73 1,621,142.26 3.82 8,201.69 Projection to TD Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. E Yes ❑ No 1 have checked to the best of my ability that the following data is correct: El Surface Coordinates [] Declination & Convergence Q GRS Survey Corrections p Survey Tool Codes Vincent ovally iron, ces° Pk -" Osara " �" SLB DE: `�'`�" " wm m7S.D 341.333.-DROP Jake Voss ° �°°°' `""°_ ora.nrovox.°.oiu w-a�w..iw , msam ous Client Representative: SDIZSD A Date: 24-Sep2015 9/24/2015 2:44:44PM Page 7 COMPASS 5000.1 Build 74 •�,of rk �w �\I%%i s? THE STATE Alaska Oil and Gas `v =,•r✓��.+-7,a ftti Conservation Commission „..._ _ „0",„.. :_, it s .- 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 *4" Main: 907.279.1433 o4"ALAS‘''' Fax: 907.276.7542 www.aogoc.alaska.gov Daniel Beardon Supervising Drilling Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2S-10 ConocoPhillips Alaska, Inc. Permit No: 215-110 (Revised) Surface Location: 3068' FNL, 1526' FEL, Sec. 17, T1ON, RO8E, UM Bottomhole Location: 577' FNL, 1309' FEL, Sec. 29, T1ON, RO8E, UM Dear Mr. Beardon: Enclosed is the approved application for permit to drill the above referenced service well. 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. 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, alli Cathy P.7oelprster •- Chair DATED this (7 day of August, 2015. RECEIVED STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMMIIII/ON AUG 17 2015 REVISED PERMIT TO DRILL AOGCC �("1► 20 AAC 25.005 AOGCC 1 a.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service- Winj 0- Single Zonner✓ - lc.Specify if well is proposed for: Drill [ . Lateral ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redril❑ Reentry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ 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 2S-10, 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 14403' ' TVD: 6328' • Kuparuk River Field , 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 3068'FNL, 1526'FEL, Sec 17, T 10N,R008E,UM i ADL 25603,25604,25608 " Kuparuk River Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 4802'FNL,4876'FEL,Sec 16,T10N,R008E,UM ` 2677,2678,2681 8/22/2015 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 577'FNL, 1309'FEL, Sec 29,T1 ON,R008E,UM ' 7632 . 3971 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 148 ' feet 15.Distance to Nearest Well Open Surface: x- 481044 y- 5929980 Zone- 4 GL Elevation above MSL: 120 • feet to Same Pool: 2S-07: 155' 16.Deviated wells: Kickoff depth: 4 600 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: , 90 degrees Downhole: 3751 • Surface: 3113 - 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) 24" 16" 62.5# H-40 Welded 78' 28' 28' 106' 106' pre-driven 13.5" 10.75" 45.5# L-80 Hydril 563 2678' 28' 28' 2706' 2582' 1040 sx DeepCRETE,195sx DeepCRETE 9.875" 7.625" 29.7# L-80 Hydril 563 7817' 28' 28' 7845' 6310' 400 sx GasBLOK,111 sx GasBLOK 6.75" 4.5" 12.6# L-80 IBTM 6758' 7645' 6280' 14403' 6328' 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): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program ❑ Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 AA 25.050 requirements❑ 21. Verbal Approval: Commission Representative: Date /---'-- yl-77,-- 22. I hereby certify that the foregoing is true and correct. acob Voss @ 265-6 Conta jake.voss@cop.com Email Printed Name Daniel Bearden Title Supervising Drilling Engineer Signature 4 R,A„........,- Phone 263-4864 Date ( _Fe/3- Commission Use Only Permit to Drill . API Number: Permit Approval See cover letter for other Number: 215-110 (ev\c e �0 -103-.20?/1-0 Date: _v3-20As requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales:Fr Other: 50 p ,i-e-„5-f i-e.) ,F506) p5/9 , Samples req'd: Yes❑ o d Mud log req'd:Yes❑ No[ ' /g n n(i/a r p re re - �--r }-o 2 5' 7 p51 H2S measures: Yes[V No❑ Directional svy req'd:YesTeNo❑ 5fa ft t'� f-v� sS d /�6T-14, , Spagin' exception req'd: Yes❑ No LY Inclination-only svy req'd:Yes❑ No[ req�/ ccr t-t -r' af4b 1 If �J«bc/)--, APPROVED BY � Approved by: �'-'" COMMISSIONER THE COMMISSION Date:7 _�) > Y9 is//c O D i, • A ' A ' Submit Form and Form 10-401(Revised 10/2012) T i ri li r 74♦rrtbnths from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate • • Application for Revised Permit to Drill,Well 2S-10 Saved: 14-Aug-15 Post Office Box 100360 Anchorage,Alaska 99510-0360 ConoCo illips Phone(907)265-6935 �,,, Email: jake.vossAconocophillips.com August 14,2015 R C E I V E its, Alaska Oil and Gas Conservation Commission AUG 17 2015 333 West 7`"Avenue, Suite 100 Anchorage,Alaska 99501 q^ Re: Application for Revised Permit to Drill Well 2S-10,A Kuparuk A4 Sand Pre-Produced Injector Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a Revised permit to drill an onshore grassroots pre-produced injector well from the 2S pad. The expected spud date for this well is August 22, 2015. It is planned to use rig Doyon 141. Revisions will be highlighted in Red. 2S-10 is planned to be a horizontal well in the Kuparuk A4 sand. The surface section will be drilled with 13-1/2"bit and run 10-3/4"casing to+/-2,706'MD/2,582'TVD. The intermediate section will be drilled with 9-7/8"bit and run 7-5/8" casing to 7,845'MD/6,310'TVD.The production hole will be drilled with 6-3/4"bit and run 4-1/2"slotted liner to+/- 14,403'MD/6,328'TVD. The upper completion will be run with 3-1/2"tubing. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005(a). 2. Pressure information as required by 20 ACC 25.035 (d)(2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a)and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Jacob Voss at 265-6935 (jake.voss(2 conocophillips.com)or Chip Alvord at 265-6120. Sincerely, Chip Alvord Drilling Manager ORIGINAL • • Application for Revised Permit to Drill Document , Drilling ells Kuparuk Well 2S-10 Conocabillips Well Name Requirements of 20 AAC 25.005(f) The well for which this application is submitted will be designated as 2S-10 Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (2)a plat identdying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth,referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth: Location at Surface 3068'FNL, 1526'FEL, Sec 17, T 1ON,R008E,UM NGS Coordinates RKB Elevation 148'AMSL Northings: 5,929,979.72' Eastings: 481,044.13' Pad Elevation 120'AMSL . Location at Top of 4802'FNL,4876'FEL,Sec 16,T1ON,R008E,UM Productive Interval (Kuparuk A4 Sand) NGS Coordinates Measured Depth, RKB: 7,845' Northings: 5,928,241.42' Eastings:482,974.70' Total Vertical Depth, RKB: 6,310' Total Vertical Depth, SS: 6,162' Location at Total Depth 577' FNL, 1309'FEL, Sec 29,T1ON,R008E,UM NGS Coordinates Measured Depth, RKB: 14,403' Northings: 5,921,911.58' Eastings:481,264.93' Total Vertical Depth, RKB: 6,328' Total Vertical Depth, SS: 6,180' and (D)other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated,the application for a Permit to Drill(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment: Directional Plan And (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells,to the extent that those names are known or discoverable in public records,and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 AAC 25.035,20 AAC 25.036,or 20 AAC 25.037,as applicable; Please reference BOP schematics on file for Doyon 141. I • • Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient; The maximum potential surface pressure (MPSP) while drilling 2S-10 is calculated using an estimated maximum reservoir pressure of 3,751 psi (11.5 ppg,based on Shark Tooth#1 appraisal well), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A4 sand at 6,383' TVD (WP10): A Sand Estimated. BHP = 3,751 psi A Sand estimated depth(WP10) = 6,383' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 638 psi (6,383' TVD * 0.10 psi/ft) MPSP =BHP—gas column =3,113 psi✓ (3,751 psi—638 psi) (B)data on potential gas zones; The well bore is not expected to penetrate any shallow gas zones. And (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; See attached 2S-02 Drilling Hazards Summary Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25.0300; A procedure is on file with the commission for performing LOT's. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted liner,pre perforated liner,or screen to be installed Casing and Cement Program Casing and Cementin_ Program Csg/Tbg Hole Weight Length Top MD/TVD OD(in) Size Grade Conn. ( ) (ft) Btm MD/TVD(ft) Cement Program 16 24 62.5 H-40 Welded 78 Surf 106/106 Existing Hydril Cement to Surface with 10-3/4 13-1/2 45.5 L-80 563 °,678 Surf 2,706/ 2,582 1,040 sx DeepCRETE Lead 11.0 ppg, 195 sx DeepCRETE Tail Slurry 12.0 ppg Stage 1: 400 sx Class G+GASBLOK at Hydril 15.8 ppg w/TOC at 6,043'MD 7-5/8 9-7/8 29.7 L-80 563 7,817 Surf 7,845/ 6,310 Stage 2: 111 sx Class G+GASBLOK at 15.8 ppg w/TOC at 4,659'MD 4 1/2 6-3/4 12.6 L-80 IBTM 6,758 7,645/6,280 14,403/6,328 Slotted liner • • Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (7)a diagram and description of the divetter system as required by 20 AAC25.035,unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please reference diverter schematic on file for Doyon 141. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 AAC 25.033; Mud Program Summary Surface Intermediate Production 13-1/2" Hole 9-7/8" Hole 6-3/4" Hole 10-3/4"Casing 7-5/8" Casing 4-1/2" Liner FLO-PRO NT Mud System Drilplex LSND(WBM) (WBM) Density 9.3- 10 9.2- 11.5 10.5- 11.5 PV 30-50 10-20 10-20 YP 40-80 16-24 16-24 Funnel Viscosity 200-300 N/A N/A Initial Gel 30-50 10- 12 5-8 10 minute Gel 30-50 10- 18 5- 12 API Filtrate NC <6 <6 HTHP Fluid Loss at 160 F N/A < 10 < 10 pH 9.0- 10.0 9.0- 10.0 9.5- 10.0 Diagram of Doyon 141 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) N/A - Application is not for an offshore well. • • Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer to attachment for proposed well schematic. • 411 1. Move in/rig up Doyon Rig 141. Install 21-1/4"Annular with 16"diverter line and function test. 2. Spud and directionally drill 13.5"hole to casing point at+/-2,706 MD/2,582' TVD as per directional plan (wp12). Survey with MWD,Gamma,Resistivity,Gyro,Density/Neutron. 3. Run and cement 10-3/4",45.5#,L80,Hyd-563 casing to surface. Displace cement with mud. Evacuate top 2 feet of cement from annulus for sealant job(post rig.) 4. In the event cement returns are not seen at surface,perform a top job. 5. Remove diverter system,install and test 13-5/8"x 5,000 psi BOP's to 3500 psi(annular preventer to 2500 psi) high and 250 psi low. Notify AOGCC 24 hrs before test. 6. PU 9-7/8"PDC bit and directional drilling assembly,with MWD/LWD(Gamma,resistivity). RIH and clean out to 100' above shoe. Test surface casing to 3500 psi for 30 minutes. 7. Drill out shoe track and 20' of new hole. Perform leak off test to a minimum of 12.5 ppg,maximum of 16 ppg EMW leak off,recording results. 8. Directionally drill to the top of the HRZ at-6,876 MD/6,017 TVD. Install RCD bearing at this time for use of MPD if necessary. 9. Directionally drill to intermediate TD of 7,845'MD/6,310'TVD,landing in the Kuparuk A4 sand. Wellsite geologist will call intermediate TD. Circulate and rotate at maximum rates until shakers are clean,minimum of 3 bottoms up. 10. POOH on elevators. Closely monitor drag and address any problem areas by dropping below and circulating/rotating to clean up. Backream through tights spots only if necessary. If substantial drag was observed through a large part of the trip,consider making a wiper trip back to bottom from the surface casing shoe,otherwise continue pulling out of hole. 11. Laydown intermediate BHA and rack back 5"DP(to lay down after casing run,this will minimize shale exposure time.) 12. Run 7-5/8",29.7#L80,Hydril 563 casing from surface to TD at 7,845 MD. 13. Pump two stage cement job as per Schlumberger proposal. Top of first stage to be 6,113'MD(top of Cairn formation),top of second stage to be 4,783' MD(500' above C37). 14. Flush 10-3/4"x 7-5/8"annulus with water,followed by diesel to freeze protect. 15. Lay down 5"DP. 16. PU 4"DP,6-1/2"bit,and drilling assembly with MWD/LWD(Gamma,resistivity,Periscope,Microscope,and neutron density) 17. RIH and clean out cement to 100' above shoe. Test intermediate casing to 3500 psi for 30 minutes. 18. Drill out shoe track and 20' of new hole. Perform formation integrity test to minimum of 12.5 ppg,maximum of 16 ppg EMW leak off,recording results. 19. Directionally drill 6-1/2"hole geosteering though the Kuparuk A4 sand to TD 14,403' MD as per directional plan(wp12). 20. Circulate hole clean and POOH. 21. Lay down Production BHA. 22. PU and run 4-1/2", 12.6#slotted liner. The top of liner will be placed at 7,645' MD,allowing for 150' of overlap in the 7-5/8"casing. • I 23. Set liner hanger. Slackoff and set liner top packer. 24. Monitor well for flow for 15 minutes 25. Displace to clear brine. PT liner to 3,000 psi at surface for 30 minutes,chart results. 26. Flow check well for 30 minutes to run 3-1/2"upper completion. 27. Nipple down BOPE,nipple up tree and test. 28. Freeze protect well with diesel and install BPV. 29. RDMO. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill music be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authori_ation under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well (1R-18 or new facilities at DS1B). All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well,or stored,tested for hazardous substances,and(if free of hazardous substances)used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: Attachment 1 Well Schematic Attachment 2 Diverter Layout Diagram Attachment 3 Directional Plan Attachment 4 Drilling Hazards Summary Attachment 5 Cement Summaries 0 • 2S-1 0 ConocoPhillips Grassroots Horizontal A-Sand Injector Proposed Wellbore Schematic(wp12) " CAMERON Last Edited: 4-W tree,top joint is 4-W 12.6#IBTM Voss 8-13-15 16"Conductor to-115' Ad 4 3-IA"2.875"DS Landing Nipple 13.5" Surface Hole ' iA GI J 3-1/2"GLM J „,;,i Surface Casing 10-3/4"45.5#L-80 Hydril 563 2,706'MD/2,582'TVD 0. 9-7/8" Intermediate Hole a 3-1/2" 9.3#L-80 EUE 8RD-MOD Tubing m °' Shear out a orifice valve J 2n°Stage TOC:4,783'MD (500'MD above C-37 Formation) �`' WeatherfordStage Collar:5,283'MD/4845'TVD '� �(���(��� C-37:5,283'MD/4,845'TVD il'f'r (Top of C-37 formation) titt Growler(Iceberg):5,435'MD/4,979'TVD '';,::'l, 1.1 Stage TOC:6,113'MD/5,532'TVD ,414 (Top of Cairn formation) Cairn:6,113'MD/5,532'TVD Bermuda:6,257'MD/5,637'TVD — HRZ:6,876'MD/6,017'TVD \\�\� Kalubik:7,128'MD/6,132'TVD i 7-5/8"Flex Lock Liner Hanger/ZXP 6.375"x 4-'/:"Swell Packer Kuparuk A4:7,823'MD/6,308'TVD 11( _ u? ♦ -11.4 ppg i1. Baker 2.812"CMU - - �-;"Silver ewe Sliding Sleeve -. = Shoe N 1. a ` 3_'h„2.75"D Nipple 1. Ill.41111 ■------- ■ TD:14,403'MD/6,328'TVD ND H 0 3-',4"HES Mirage Disappearing Plug Intermediate Casing Production Liner: 6-3/4" Production Hole 7-5/8"29.7#L-80 Hyd563 Casing 4-1/2" 11.6#L-80 IBTM Slotted Liner with Torque Rings 7,845 MD/6,310'TVD (85°) 14,402' MD/6,328'TVD NOTE: Swell Packer will be adjusted as necessary using microscope and periscope data STATE OF ALASKA ALI"OIL AND GAS CONSERVATION COMMI N REVISED PERMIT TO DRILL 20 AAC 25.005 1 a.Type of Work: 1 b.Proposed Well Class: Development-Oil ❑ Service- Winj Q Single Zone Q lc.Specify if well is proposed for: Drill E Lateral ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redril❑ Reentry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket 0 Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska,Inc. Bond No. 59-52-180 KRU 2S-10 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 14403' ND: 6328' K paruk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 3068'FNL, 1526'FEL, Sec 17, T 10N,R008E,UM ADL 25603,25604,25608 uparuk River Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.A,.roximate Spud Date: 4802'FNL,4876'FEL,Sec 16,T10N,R008E,UM 2677,2678,2681 8/22/2015 Total Depth: 9.Acres in Property: 1,.Distance to Nearest Property: 577'FNL, 1309'FEL, Sec 29,T1 ON,R008E,UM 7632 3971 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 148 feet 15.Distance to Nearest Well Open Surface: x- 481044 y- 5929980 Zone- 4 GL Elevation above MSL: 120 feet to Same Pool: 2S-07: 155' 16.Deviated wells: Kickoff depth: 600 feet 17.Maximum Anticipated Pressures in psig .ee 20 AAC 25.035) Maximum Hole Angle: 90 degrees Downhole: 3751 Su :ce: 3113 18.Casing Program: Specifications Top - Setting Depth - Botto' Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 62.5# H-40 Welded 78' 28' 28' 106' 106' pre-driven 13.5" 10.75" 45.5# L-80 Hydril 563 2678' 28' 28' 27.. 2582' 1040 sx DeepCRETE,195sx DeepCRETE 9.875" 7.625" 29.7# L-80 Hydril 563 7817' 28' 28' 7' J 6310' 400 sx GasBLOK,111 sx GasBLOK 6.75" 4.5" 12.6# L-80 IBTM 6758' 7645' 6280' li d? 6328' slotted liner IP 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill-'d 'e-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.De.y' D(ft): Effect.Depth ND(ft): Junk(measured): Casing Length Size Ce ;`"Volume MD TVD Conductor/Structural Surface L Intermediate ' Production Liner Perforation Depth MD(ft): Pe .ration Depth ND(ft): 20. Attachments: Property Plat ❑ BOP Sketch ❑ Dri g Program ❑ Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch ❑ 'eabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 6)70(/..0-- (/ 22. I hereby certify that the foregoing is true and correct. JaVoss @ 265- 35 Contact jake.voss( cop.com Email Printed Name Daniel Bearden Title Supervising Drilling Engineer Signature Phone 263-4864 Date O i aOf l Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: 215-110 Date: requirements. Conditions of approval: If box is chec -d,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales:❑ Other: Samples req'd: Yes❑ No I=1 Mud log req'd:Yes❑ NCI H2S measures: Yes❑ No❑ Directional svy req'd:YesEl No❑ Spacing exception req'd: Yes❑ No❑ Inclination-only svy req'd:Yes❑ No❑ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Submit Form and Form 10-401(Revised 10/2012) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate or t s� THE STATE Alaska Oil and Gas ��`i��iM f oLASI�;A Conservation Commission __- A sif; = 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage,Alaska 99501-3572 ~h' Main:907.279.1433 gt,AS-4 Fax: 907.276.7542 www.aogcc.alaska.gov G. L. Alvord Alaska Drilling Manager ConocoPhillips Alaska,Inc. P.O.Box 100360 Anchorage,AK 99510-0360 Re: Kuparuk River Field,Kuparuk River Oil Pool, KRU 2S-10 ConocoPhillips Alaska, Inc. Permit No: 215-110 Surface Location:2211' FSL, 1526' FEL, SEC. 17,T1ON,R8E,UM Bottomhole Location: 571' FNL, 1309' FEL, SEC. 29, T1ON,R8E,UM Dear Mr.Alvord: Enclosed is the approved application for permit to drill the above referenced service well. 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. 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. oerster Chair DATED this /3 day of July,2015. 0 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 2 3 "coli PERMIT TO DRILL - 20 AAC 25.005 la.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service-Winj ❑J Single Zone Q 1c.Specify if well is proposed for: Drill ❑J Lateral C Stratigraphic Test ❑ Development-Gas ❑ Service-Supply LI Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill ❑ Reentry C Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: [J Blanket U Single Well 11.Well Name and Number: ConocoPhillips Alaska,Inc. Bond No. 59-52-180 KRU 2S-10 3 Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD:14098' TVD: 6383' Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:2211'FSL, 1526'FEL,Sec. 17,T1ON,R8E,UM ADL 25603,25604,25608 Kuparuk River Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 65'FNL,5001'FEL,Sec.21,T1ON,R8E, UM 2677,2678,2681 8/19/2015 Total Depth: 9.Acres in Property: 14.Distance to 571'FNL,1309'FEL,Sec.29,T1 ON,R8E,UM 7632 Nearest Property: 3971 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 148 feet 15.Distance to Nearest Well Open Surface:x- 481044 y- 5929980 Zone- 4 GL Elevation above MSL: 120 feet to Same Pool: Shark Tooth,797' 16.Deviated wells: Kickoff depth: 600 ft. 17.Maximum Anticipated Pressures in psig(see 20 PAC 25.035) Maximum Hole Angle: 92° deg Downhole:3751 psig Surface:3113 psig 18.Casing Program: Specifications J Top - Setting Depth -Bottom Cement Quantity,c f.or sacks Hole Casing Weight Grade Coupling Length MD WO MD TVD (including stage data) 24" 16" 62.5# H-40 Welded 78' 28' 28' 106' 106' pre-installed 13.5" 10,75" 45.5# L-80 Hydril 563 2746' 28' 28' 2774' 2650' 1068 sx DeepCRETE,195 sx DeepCRETE 9.875" 7.625" 29.7# L-80 Hydril 563 8069' 28' 28' 8097 6383' 471 sx GasBLOK, 126 sx GasBLOK 6.75" 4.5" 12.6# L-80 1BTM 6151' r 7947' 6350' 14098' 6383' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): . Effective Depth TVD(ft): Junk(measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Production Scab Liner Perforation Depth MD(11): Perforation Depth TVD(ft): 20.Attachments: Properly Plat❑ BOP Sketch❑ Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 MC 25.050 requirements ❑ 21.Verbal Approval: Commission Representative: Date: .' Z Z-(' // e,%:_----- 22. I hereby certify that the foregoing is true and correct Contact Jacob Voss @ 265-6935 Email JaCOb.VOSSaCOp.COm Printed Name G. L.Alvord skim....4 1� Title Alaska Drilling Manager L-/ Signature ,C./.77/-, ;; ;:;2-- , Nye,-s/ Phone:265-6120 Date .22---/s Commission Use Only Permit to Drill API Number: Permit ApprovalI See cover letter Number: Q/.- I) 50.0),<./-9 36-1/6--cy3-0.0 I Date: 71 1 5 jrIforotherrequirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed m Thane,gas hydrates,or gas contained in shales: ir Other:BOP t-CSf la ,35-00 ,,pp51 Samples req`d: Yes No [ Mud fog req'd: Yes[] No fhnv/ar'.7-c✓Cv11-lP Z5r17'O Z5�(�2 J 5ta,1C tni/ e-Ssra M er iA rr cistwi'rr measures: Yes No Directional svy req'd: Yes Ad No after 5/4,fjili CG/ r i-, eC frc r>pacing exception regdi.. Y klp g knclination-only svy req'd: Yes III No ��� �-I AP o► Approved by: � �fL ; __ COMMI$t(}N�W jJ liit E2 r"i' Date: 7- /3(((YYY�t �� CP7f LUL; Form 10-401 evised 10/2012) This permit Is valid or 24 months r he a a o a p 1(20 AAC 25.005(g)) 14:32,August 13 2015 ANNIIIIkism 2S-lOwpl2 [Itobbegong] 6.642 Plan Summary C-37 Growler Base Bermuda - Top W Sak TopB rmuda Top HRZ(K-2) U Kalubik(Base HRZ) >,5-easePermafrpst `Top C im --' r C-40 • ., A5. aA A4 L Kalubik(.I .1)-_ -5 ..-.. ... m To T-3 andr �� 1 �• „ < 1„ _-KOP C Rase W Sak _- ' 401 K-1: Ma (- - . cn t ( A4 Target Top A4 Target Base En __1r° IC=80050 0 1 r 1 1 I7-5/8" X 9-7/81 -' ..... .. 14,0' ...........r 1 DI, I 1 \ 1 1 1 1 1 1 I I I 1 I ID ` or A 110-314"x 13-1/21' 3500 7000 10500 14000 Measured Depth AVINgagglit0- Geo detic Datum: North American Datum 1983 -0' 110-3/4"x 13-1/21' Depth Reference: Plan:120+28 148.00usft(Doyon 141) 1080 Rig: Doyon 141 o _ I N 30 14 1/2"x 63/41 2 000 I7-5/8"X 9-7/8'1 / 0� / Oo _o 530 e�h 0 la CD 0 4FO Of8 m 0 0. 0 0 0 1 O N M a O of ,- .- D7 a- a- a- O / 1 1 1 I I I I I I I 1 I 1 1 I I a 28 "'" 600 0 1500 3000 4500 6000 7500 9000 d•C1500 Horizontal Departure __p ,a•im�„I 600 - 790 330 O-r tr,e 790 - 970 ��Pilli nSi 30 _ ��.m�,a. �1� I e70 - 1168 II ���a�IY!/%'',..0k/of 1160 - 1300 /® ......... 300 o 1,,p��i i .... -- Cy ♦ �� �%/� •��/�•�I +z 1340 - 1530 �� -_ �1,�►I/EI�i�R�r 4�� •��O/•oas0 1530 - 1710 N ® •�1��1,. �il�., • !p mo - lsoo �� ill��'� �� 8- ,7 Hamrnethea. - �r®i1b1�k,•Jr!,.A.7400���i'R t 1900 - 2430 n I III I ���� , �1�/f�_d���% '•�l� t 2030 zssa CD 30 S•• .•: p.er �tl�d /� • 1 2850 - 34e6 0 2S111wp06[1 rear white] ---. 270 ,,,`,,# ` 3480 - 4000 v sd .:gym. 90 -4000 4530 „1�, I' .-11L wp06[ reat.White] ub - 4530 - 5050 AlU 11, •$-12wp07 jB II]. ....... . * �`s ``s cp�� 40 • ..'� 5050 - 5580 0 w • 3•; �p9R, S 6 5580 - 6100 •*;•- :°:9.4• i. .RtY 6100 - 7140 0 1500 3000 4500 6000 7500 9000 10500 240 `9.b ;www., tliitlish4,,„.-:,,,i,,sioaot/ 120 7140 - 8180 SURVEY PROGRAM // •I' �!rS W� 0 ��,. 0v�i ¢ i�..� 8180 - 9210 Surface Location y • �� ♦ Mt.."' 1Z,1, � ►-._1 rll� 1 9210 - 1025. IIIII Depth From Depth To Survey/Plan Tool /'�V, IA*41 fb,e� 28.00 500.00 2S-10wp12 Wobbegong](Plan:2S-10) INC+TREND Pad Elevation: 120.00 Izs-uree.rOe sr.wwmNll9 • �A�,eO1 ,►��180 Ia9 uS-On] 10250 - 11290 28.00 500.00 2S-10wp12'Wobbegong](Plan 2S-10) GYD-GC-SS Izs-11u.ros[Groat whlrp\ :,r$'1.2 11290 12330 500.00 1500.00 2S-10wp12 Wobbegong] Plan 2S-10) MWD 160 Its-oanvos[n9.r] 12330 ' 13370 500.00 2705.93 2S-10wp12 Wobbegong](Plan MWVOI)IFR-AK-CAZ-SC CASING DETAILS 120-1I.,pos tcrwwmj 13370 - 14403 2705.93 4205.93 2S-10wp12 obbegong (Plan 2S-10) MWD 2705.93 7844.72 2S-10wp12 obbegong(Plan Jr IFR-AK-CAZ-SC TVD MD Name M 7844.72 9344.72 2S-10wp12 obbegong](Plan 25-10 MWD 2582.00 2705.93 10-3/4"x 13-1/2" Magnetic Model: BGGM2015 T 7844.72 14402.75 2S-10wp12 obbegong](Plan ISM in IFR-AK-CAZ-SC 6310.00 7844.72 7-5/8"X 9-7/8" Magnetic Model Date: 05-Sep-15 - 6328.00 14402.75 4 1/2"x 6-3/4" Magnetic Declination: 18.60° To convert a Magnetic Direction to a True Direction,Add 18.60°East SECTION DETAILS -38;',+T-3 Sand Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 0.00 2 800.00 0.00 0.00 800.00 0.00 0.00 0.00 0.00 0.00 KOP:Start 1.5°/100'DLS,30°TF,for 200.09' K-15 Marker 3 800.09 3.00 30.00 800.00 4.54 2.62 1.50 30.00 -5.06 Start 2.5°/103'DLS,0°TF,for 516.08' 4 1316.17 15.90 30.00 1308.00 77.78 44.91 2.50 0.00 -86.76 Hold for 103.98' 5 1420.15 15.90 30.00 1408.00 102.46 59.15 0.00 0.00 -114.28 Start 3°/100'DLS,91.27°TF,for 821.32' -1370.0 6 2241.47 28.75 90.05 2174.82 201.27 316.95 3.00 91.27 -276.45 Hold for 2497.58' 7 4739.05 28.75 90.05 4364.42 200.27 1518.42 0.00 0.00 -586.44 Start 3°/100'DLS,106.4°TF,for 3105.66' Base Permafrost 8 7844.72 85.00 196.00 6310.00 -1733.53 1935.19 3.00 106.40 1173.59 25-Wobbegong 1.Heel 081215 PB_Opt1 Hold for 30' -1849.0 9 7874.72 85.00 196.00 6312.61 -1762.25 1926.95 0.00 0.00 1203.48 Start 1.5"/100'DLS,-12.05°TF,for 340.48' 10 8215.19 90.00 194.93 6327.48 -2089.98 1836.27 1.50 -12.05 1543.51 Hold for 6188.87' Top W Sak 11 14402.06 90.00 194.93 6328.00 -8067.86 241.79 0.00 0.00 7730.37 Start 1'1100'DLS,-44.76°TF,for 0.68' 12 14402.75 90.00 194.93 6328.00 -8068.52 241.62 1.00 -44.76 7731.05 2S-Wobbegong 6.Toe 081215 PB Start 1°/100'DLS,-44.76°TF,for 0.68' -2522.0 Base W Sak -2915.0 C-80 Permit Pack -4256.0 C-50 -4568.0 :Mt 97 t Growler -UN r5ermuda Base Bermuda if(J��, e H- - -- ae Bae 9-By signing this I acknowledge that I have been informed of all risks,checked that the data is correct,ensured it's completeness,and all surrounding wells are assigned to the proper position and I approve the scan and collision avoidance plan as set out in the audit pack.I approve 5 as the basis for the final well Prepared by: ��a••---- --- --w-°-�- Checked by: a..•� ��--- Accepted by: Approved by: Vincent Osara Nate Beck Ifeanyi Ifesie • • 16:09,August 13 2015 Easting(---- -" ■■■■■ Kuparuk 2M Paces g' Kuparuk 2H Pag ;,.,_ .5 d_oy 26-o3 ,. — ..I '. 2B-03A ._ - • I , / • 2M-2. 2M 2H-131-1 .H-1 2H-.• 2H-07 2G-03 V-2.G-04 _ -38wp07 2 a• r-ik�01 — M-31 2M-2' G-o1 -30 2M-17 2H-14 2H-10 2H-01 2H-08� — 2 i-29 2 pyo --2-6- 1 2M-0 2M- 7 O2m_ 2�, _ t2K-03?(- 921 2K-05 2K-01 �ZG-16 2G-15 '�K�4\ \j\ 9L1-01 i- Ti erlinewpl0IMP... _ 2M-33 MBAR oa Kuparuk 2K Pa berlinePB1wp10 2M-32L1P:1 2M-08 2M-0• , r_ _K-10 2K-0 2G-14 2G-13 2S-14w 07 i - 2M-3221"B2 ..151_21K 521 P� ... •10•07.;;;,:i. s P i 3 �A` Vii` " r 2G-1 2 -13AL2 — tv[1t11 � .1cNow ., 2M-35 _ ` /.� 25-1 - - � _<l�=`]A 13A. � 2 _ ` K-2!` 7-StWilliger] _2; i43AL1 ST 2L-03 2S-07wp12.1[Goblin 4A o 44 _ / 2S-05 ,„--,T!1.€„ K-19 , gI s ,l:$2K- 2B C-23 _ s 7 _ 2K- i • • _ 2K-2 • - 5 c K-21• 2K-2�'LI __an n_ Kuparuk 2S Pad 2�_,- R����rP ]-21 2K-22 2K-24 2K-25 _ S c L-308P:1 /PB1 !2wp09 .`w;..., vo anus _ 2L-306P6 9,8[ r••• • ”-gQ10"n] Kuparuk 2L Pa=—_ - i62L- 9 �.�/ � � 2K-22AL1 2K-22AL1-01 -32.-_,.- 2L-308 2 L-308, L �� �.1:-- -L-310 �� �� RU 21-10-8 - 1114111 2L-322 2(._• .S 02 2L-.1.w.r•''' -7wp01) _ L- 2L-3 7 — •L 2L-320 'S2 a u:+ 1 _ [�^� ) 2S-10 .12((WWobbe ong] 2L-322A 2L- ' 03wp01�[Bamboo] - 2>s 2N-322 o Prelim: Kuparuk Cairn PaLY2 2 312wp05 \/ / _ 2N-308 2 -30 2N-3 2 IA -•A'-3� p Prelim: KuparukrlCairn Pad ar 3A « �5-17#11 -t6 b�dgu�sgl u 1c Xl -_ � 2��$4PB1 �S-i5�p�bt�elioprion] _ 1b 2N-310 N-3�. qqq /// _ \R-c 44 W SAK 13 II 11 I ] I I I I I I I I 1 ] I I I I ] I I I I ] I I I I ] I T r f 1 1 1 1 1 1 1 1 I 1 H 1 1 1 1 ] I I I I ] I I I I ] I I I I I I I I I ] I I f l 1 1 1 1 1 1 Easting(5000 usftlin) • . 2S-1 owp12 [Wobbegong] Plan View While drilling production section, stay within 100 feet right and 70feet left of plan, unless notified otherwise. 00 0 0 c� . O $ O fr � 0- r 200• 10-3/4"x 13-1/2" 6000 -1500— 2S-Wobbegong 1. Heel 081215 PB 7-5/8"X 9-7/8" g-3000— 0 LU r 84500— 70ft F Notify office if getting to 15 70ft to the left of plan -6000— 2S.1p4'p 12 fWobbegon -7500— 91 63/4';, �3 _--_ 2S-Wobbegong 6. Toe 081215 PB 41/2"xg I I -4500 -3000 -1500 0 1500 3000 4500 6000 7500 West(-)/East(+) (1500 usft/in) • • 2S-10wp12 [Wobbegong] Section View Top T-3 Sand 0— A K-15 Marker o° Base Permafrost Top W Sak 1,000 1500- Base W Sak 2000.-- 10-3/4"x 13-1/2" — ____C-80 N3 �ud6 X3000— 0 D 29° C-50 a 4000,-- C-40 �' a ---- m a 04500----- x30 Growler m To - o Oa 0� Top Bermuda 7-5/8"X 9-7/8" Co- Base Bermuda o 0 0 0 o E7CI O CI a, iop Caird o, ' 0 0 0 o I-6000— -� — o - M v 0o co rn .- To HRZ K- A4 Target B� se Top ( �) A5 4 1/2"x 6-3/4" a' g U Kalubik(Basel-114Z) P Ku C w 7500— L Kalubik (KJl) ‘ A4 A4 Target Top 2S-Wobbegong 6. Toe 081215 F‘B 2S-Wobbegong 1. Heel 081215 PB I I I 1 0 1000 2000 3000 4000 5000 6000 7000 8000 Vertical Section at 195.00° (1000 usft/in) • • ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-10 Plan: 2S-10 Plan: 2S-10wp12 [Wobbegong] Report - Map Coordinates 13 August, 2015 Permit Pack • Schlumberger 0 Comments apply to Report- Map Coordinates the line before it. Company: ConocoPhillips(Alaska) Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-10 Project: Kuparuk River Unit TVD Reference: Plan: 120+28 @ 148.00usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: Plan: 120+28 @ 148.00usft(Doyon 141) Well: Plan:2S-10 North Reference: True Wellbore: Plan:2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10wp12[Wobbegong] Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 2S Pad Site Position: Northing: usft Latitude: From: Map Easting: usft Longitude: Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.14 ° Well Plan:2S-10 Well Position +N/-S 0.00 usft Northing: usft Latitude: +EI-W 0.00 usft Easting: usft Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 120.110 usft Wellbore Plan:2S-10 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2015 9/5/2015 18.60 80.87 57,489 Design 2S-10wp12[Wobbegong] Audit Notes: Version: Phase: PLAN Tie On Depth: 28.00 Vertical Section: Depth From(TVD) +N/-S +EI-W Direction (usft) (usft) (usft) (°) 28.00 0.00 0.00 195.00 Survey Tool Program Date 8/13/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 28.00 500.00 2S-10wp12[Wobbegong](Plan:2S-10) INC+TREND Inclinometer+known azi trend 28.00 500.00 2S-10wp12[Wobbegong](Plan:2S-10) GYD-GC-SS Gyrodata gyro single shots 500.00 1,500.00 2S-10wp12[Wobbegong](Plan:2S-10) MWD MWD-Standard 500.00 2,705.93 2S-10wp12[Wobbegong](Plan:2S-10) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,705.93 4,205.93 2S-10wp12[Wobbegong](Plan:2S-10) MWD MWD-Standard 2,705.93 7,844.72 2S-10wp12[Wobbegong](Plan:2S-10) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7,844.72 9,344.72 2S-10wp12[Wobbegong](Plan:2S-10) MWD MWD-Standard 7,844.72 14,402.75 2S-10wp12[Wobbegong](Plan:2S-10) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (0) (usft) (usft) (°/100usft) (0) (usft) 28.00 0.00 0.00 28.00 -120.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 -48.00 0.00 0.00 0.48 200.00 0.00 0.00 200.00 52.00 0.00 0.00 1.65 300.00 0.00 0.00 300.00 152.00 0.00 0.00 2.69 400.00 0.00 0.00 400.00 252.00 0.00 0.00 3.71 500.00 0.00 0.00 500.00 352.00 0.00 0.00 4.73 8/1312015 2:33:42PM Page 2 COMPASS 5000.1 Build 74 • Schlumberger • Report- Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-10 Project: Kuparuk River Unit TVD Reference: Plan: 120+28 @ 148.00usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: Plan: 120+28 @ 148.00usft(Doyon 141) Well: Plan:2S-10 North Reference: True Wellbore: Plan:2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10wp12[Wobbegong] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) ND TVDSS DLeg TFace Lat.Error (usft) (°) (0) (usft) (usft) (°/100usft) (0) (usft) 600.00 0.00 0.00 600.00 452.00 0.00 0.00 0.71 KOP:Start 1.5°/100'DLS,30°TF,for 200.09' 700.00 1.50 30.00 699.99 551.99 1.50 30.00 0.72 800.00 3.00 30.00 799.91 651.91 1.50 0.00 0.76 800.09 3.00 30.00 800.00 652.00 1.50 0.00 0.76 Start 2.5°/100'DLS,0°TF,for 516.08' 900.00 5.50 30.00 899.63 751.63 2.50 0.00 0.82 1,000.00 8.00 30.00 998.93 850.93 2.50 0.00 0.93 1,100.00 10.50 30.00 1,097.62 949.62 2.50 0.00 1.09 1,200.00 13.00 30.00 1,195.51 1,047.51 2.50 0.00 1.32 1,300.00 15.50 30.00 1,292.43 1,144.43 2.50 0.00 1.63 1,316.17 15.90 30.00 1,308.00 1,160.00 2.50 0.00 1.68 Hold for 103.98' 1,400.00 15.90 30.00 1,388.62 1,240.62 0.00 0.00 1.99 1,420.15 15.90 30.00 1,408.00 1,260.00 0.00 0.00 2.06 Start 3°/100'DLS,91.27°TF,for 821.32' 1,500.00 16.03 38.71 1,484.78 1,336.78 3.00 91.27 2.32 1,600.00 16.66 49.14 1,580.76 1,432.76 3.00 82.90 1.52 1,700.00 17.77 58.58 1,676.30 1,528.30 3.00 72.88 1.64 1,800.00 19.27 66.76 1,771.13 1,623.13 3.00 63.87 1.78 1,900.00 21.09 73.70 1,865.00 1,717.00 3.00 56.10 1.94 2,000.00 23.14 79.52 1,957.66 1,809.66 3.00 49.59 2.11 2,100.00 25.37 84.40 2,048.83 1,900.83 3.00 44.20 2.31 2,200.00 27.74 88.53 2,138.28 1,990.28 3.00 39.74 2.53 2,241.47 28.75 90.05 2,174.82 2,026.82 3.00 36.05 2.63 Hold for 2497.58' 2,300.00 28.75 90.05 2,226.13 2,078.13 0.00 0.00 2.79 2,400.00 28.75 90.05 2,313.80 2,165.80 0.00 0.00 3.07 2,500.00 28.75 90.05 2,401.47 2,253.47 0.00 0.00 3.36 2,600.00 28.75 90.05 2,489.13 2,341.13 0.00 0.00 3.66 2,700.00 28.75 90.05 2,576.80 2,428.80 0.00 0.00 3.96 2,705.93 28.75 90.05 2,582.00 2,434.00 0.00 0.00 4.26 10-3/4"x 13-1/2" 2,800.00 28.75 90.05 2,664.47 2,516.47 0.00 0.00 4.26 2,900.00 28.75 90.05 2,752.14 2,604.14 0.00 0.00 4.63 3,000.00 28.75 90.05 2,839.81 2,691.81 0.00 0.00 5.10 3,100.00 28.75 90.05 2,927.48 2,779.48 0.00 0.00 5.64 3,200.00 28.75 90.05 3,015.15 2,867.15 0.00 0.00 6.23 3,300.00 28.75 90.05 3,102.82 2,954.82 0.00 0.00 6.86 3,400.00 28.75 90.05 3,190.49 3,042.49 0.00 0.00 7.53 3,500.00 28.75 90.05 3,278.16 3,130.16 0.00 0.00 8.21 3,600.00 28.75 90.05 3,365.83 3,217.83 0.00 0.00 8.91 3,700.00 28.75 90.05 3,453.49 3,305.49 0.00 0.00 9.63 3,800.00 28.75 90.05 3,541.16 3,393.16 0.00 0.00 10.35 3,900.00 28.75 90.05 3,628.83 3,480.83 0.00 0.00 11.09 8/13/2015 2:33:42PM Page 3 COMPASS 5000.1 Build 74 • Schlumberger S Report- Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-10 Project: Kuparuk River Unit TVD Reference: Plan: 120+28 @ 148.00usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: Plan: 120+28 @ 148.00usft(Doyon 141) Well: Plan:2S-10 North Reference: True Wellbore: Plan:2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10wp12[Wobbegong] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (0) (usft) (usft) (°/100usft) (0) (usft) 4,000.00 28.75 90.05 3,716.50 3,568.50 0.00 0.00 11.83 4,100.00 28.75 90.05 3,804.17 3,656.17 0.00 0.00 12.57 4,200.00 28.75 90.05 3,891.84 3,743.84 0.00 0.00 13.32 4,300.00 28.75 90.05 3,979.51 3,831.51 0.00 0.00 7.26 4,400.00 28.75 90.05 4,067.18 3,919.18 0.00 0.00 7.53 4,500.00 28.75 90.05 4,154.85 4,006.85 0.00 0.00 7.82 4,600.00 28.75 90.05 4,242.52 4,094.52 0.00 0.00 8.10 4,700.00 28.75 90.05 4,330.18 4,182.18 0.00 0.00 8.39 4,739.05 28.75 90.05 4,364.42 4,216.42 0.00 0.00 8.50 Start 3°1100'DLS,106.4°TF,for 3105.66' 4,800.00 28.29 93.75 4,417.98 4,269.98 3.00 106.40 8.62 4,900.00 27.75 100.04 4,506.28 4,358.28 3.00 103.15 8.66 5,000.00 27.50 106.49 4,594.90 4,446.90 3.00 97.60 8.62 5,100.00 27.55 112.98 4,683.60 4,535.60 3.00 91.88 8.50 5,200.00 27.90 119.39 4,772.14 4,624.14 3.00 86.12 8.31 5,300.00 28.54 125.59 4,860.27 4,712.27 3.00 80.45 8.06 5,400.00 29.45 131.49 4,947.75 4,799.75 3.00 74.98 7.79 5,500.00 30.60 137.03 5,034.35 4,886.35 3.00 69.82 7.52 5,600.00 31.97 142.17 5,119.82 4,971.82 3.00 65.03 7.27 5,700.00 33.54 146.90 5,203.93 5,055.93 3.00 60.63 7.06 5,800.00 35.26 151.25 5,286.45 5,138.45 3.00 56.65 6.89 5,900.00 37.13 155.22 5,367.16 5,219.16 3.00 53.06 6.77 6,000.00 39.13 158.85 5,445.82 5,297.82 3.00 49.86 6.72 6,100.00 41.22 162.18 5,522.24 5,374.24 3.00 47.00 6.71 6,200.00 43.40 165.24 5,596.19 5,448.19 3.00 44.45 6.76 6,300.00 45.66 168.06 5,667.48 5,519.48 3.00 42.19 6.87 6,400.00 47.98 170.66 5,735.90 5,587.90 3.00 40.18 7.02 6,500.00 50.36 173.08 5,801.28 5,653.28 3.00 38.40 7.21 6,600.00 52.79 175.34 5,863.43 5,715.43 3.00 36.82 7.44 6,700.00 55.25 177.45 5,922.19 5,774.19 3.00 35.41 7.70 6,800.00 57.75 179.45 5,977.38 5,829.38 3.00 34.17 8.00 6,900.00 60.28 181.33 6,028.87 5,880.87 3.00 33.07 8.33 7,000.00 62.83 183.12 6,076.50 5,928.50 3.00 32.10 8.68 7,100.00 65.40 184.83 6,120.16 5,972.16 3.00 31.25 9.05 7,200.00 68.00 186.48 6,159.71 6,011.71 3.00 30.50 9.45 7,300.00 70.61 188.06 6,195.05 6,047.05 3.00 29.85 9.87 7,400.00 73.23 189.59 6,226.08 6,078.08 3.00 29.29 10.30 7,500.00 75.86 191.08 6,252.73 6,104.73 3.00 28.81 10.75 7,600.00 78.51 192.54 6,274.91 6,126.91 3.00 28.42 11.21 7,700.00 81.16 193.97 6,292.56 6,144.56 3.00 28.09 11.68 7,800.00 83.81 195.37 6,305.64 6,157.64 3.00 27.84 12.16 7,844.72 85.00 196.00 6,310.00 6,162.00 3.00 27.66 12.37 Hold for 30'-7-5/8"X 9-7/8" 7,874.72 85.00 196.00 6,312.61 6,164.61 0.00 0.00 12.51 Start 1.5°/100'DLS,-12.05°TF,for 340.48' 8/13/2015 2:33:42PM Page 4 COMPASS 5000.1 Build 74 • Schlumberger S Report- Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-10 Project: Kuparuk River Unit TVD Reference: Plan: 120+28 @ 148.00usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: Plan: 120+28 @ 148.00usft(Doyon 141) Well: Plan:2S-10 North Reference: True Wellbore: Plan:2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10wp12[Wobbegong] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (0) (usft) (usft) (°/100usft) (0) (usft) 7,900.00 85.37 195.92 6,314.74 6,166.74 1.50 -12.05 12.62 8,000.00 86.84 195.61 6,321.53 6,173.53 1.50 -12.05 13.15 8,100.00 88.31 195.29 6,325.77 6,177.77 1.50 -12.03 13.83 8,200.00 89.77 194.98 6,327.45 6,179.45 1.50 -12.01 14.64 8,215.19 90.00 194.93 6,327.48 6,179.48 1.50 -12.01 14.77 Hold for 6186.87' 8,300.00 90.00 194.93 6,327.48 6,179.48 0.00 0.00 15.52 8,400.00 90.00 194.93 6,327.49 6,179.49 0.00 0.00 16.46 8,500.00 90.00 194.93 6,327.50 6,179.50 0.00 0.00 17.48 8,600.00 90.00 194.93 6,327.51 6,179.51 0.00 0.00 18.56 8,700.00 90.00 194.93 6,327.52 6,179.52 0.00 0.00 19.69 8,800.00 90.00 194.93 6,327.53 6,179.53 0.00 0.00 20.87 8,900.00 90.00 194.93 6,327.53 6,179.53 0.00 0.00 22.08 9,000.00 90.00 194.93 6,327.54 6,179.54 0.00 0.00 23.32 9,100.00 90.00 194.93 6,327.55 6,179.55 0.00 0.00 24.58 9,200.00 90.00 194.93 6,327.56 6,179.56 0.00 0.00 25.87 9,300.00 90.00 194.93 6,327.57 6,179.57 0.00 0.00 27.18 9,400.00 90.00 194.93 6,327.58 6,179.58 0.00 0.00 16.70 9,500.00 90.00 194.93 6,327.59 6,179.59 0.00 0.00 17.09 9,600.00 90.00 194.93 6,327.59 6,179.59 0.00 0.00 17.50 9,700.00 90.00 194.93 6,327.60 6,179.60 0.00 0.00 17.91 9,800.00 90.00 194.93 6,327.61 6,179.61 0.00 0.00 18.33 9,900.00 90.00 194.93 6,327.62 6,179.62 0.00 0.00 18.77 10,000.00 90.00 194.93 6,327.63 6,179.63 0.00 0.00 19.21 10,100.00 90.00 194.93 6,327.64 6,179.64 0.00 0.00 19.65 10,200.00 90.00 194.93 6,327.64 6,179.64 0.00 0.00 20.11 10,300.00 90.00 194.93 6,327.65 6,179.65 0.00 0.00 20.57 10,400.00 90.00 194.93 6,327.66 6,179.66 0.00 0.00 21.03 10,500.00 90.00 194.93 6,327.67 6,179.67 0.00 0.00 21.50 10,600.00 90.00 194.93 6,327.68 6,179.68 0.00 0.00 21.98 10,700.00 90.00 194.93 6,327.69 6,179.69 0.00 0.00 22.46 10,800.00 90.00 194.93 6,327.70 6,179.70 0.00 0.00 22.95 10,900.00 90.00 194.93 6,327.70 6,179.70 0.00 0.00 23.44 11,000.00 90.00 194.93 6,327.71 6,179.71 0.00 0.00 23.93 11,100.00 90.00 194.93 6,327.72 6,179.72 0.00 0.00 24.43 11,200.00 90.00 194.93 6,327.73 6,179.73 0.00 0.00 24.93 11,300.00 90.00 194.93 6,327.74 6,179.74 0.00 0.00 25.44 11,400.00 90.00 194.93 6,327.75 6,179.75 0.00 0.00 25.94 11,500.00 90.00 194.93 6,327.75 6,179.75 0.00 0.00 26.45 11,600.00 90.00 194.93 6,327.76 6,179.76 0.00 0.00 26.97 11,700.00 90.00 194.93 6,327.77 6,179.77 0.00 0.00 27.48 11,800.00 90.00 194.93 6,327.78 6,179.78 0.00 0.00 28.00 11,900.00 90.00 194.93 6,327.79 6,179.79 0.00 0.00 28.52 12,000.00 90.00 194.93 6,327.80 6,179.80 0.00 0.00 29.05 8/132015 2:33:42PM Page 5 COMPASS 5000.1 Build 74 • Schlumberger • Report- Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-10 Project: Kuparuk River Unit TVD Reference: Plan: 120+28 @ 148.00usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: Plan: 120+28 @ 148.00usft(Doyon 141) Well: Plan:2S-10 North Reference: True Wellbore: Plan:2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10wp12[Wobbegong] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) ND TVDSS DLeg TFace Lat.Error (usft) (0) (0) (usft) (usft) (°/100usft) (0) (usft) 12,100.00 90.00 194.93 6,327.81 6,179.81 0.00 0.00 29.57 12,200.00 90.00 194.93 6,327.81 6,179.81 0.00 0.00 30.10 12,300.00 90.00 194.93 6,327.82 6,179.82 0.00 0.00 30.63 12,400.00 90.00 194.93 6,327.83 6,179.83 0.00 0.00 31.16 12,500.00 90.00 194.93 6,327.84 6,179.84 0.00 0.00 31.69 12,600.00 90.00 194.93 6,327.85 6,179.85 0.00 0.00 32.22 12,700.00 90.00 194.93 6,327.86 6,179.86 0.00 0.00 32.76 12,800.00 90.00 194.93 6,327.86 6,179.86 0.00 0.00 33.30 12,900.00 90.00 194.93 6,327.87 6,179.87 0.00 0.00 33.84 13,000.00 90.00 194.93 6,327.88 6,179.88 0.00 0.00 34.38 13,100.00 90.00 194.93 6,327.89 6,179.89 0.00 0.00 34.92 13,200.00 90.00 194.93 6,327.90 6,179.90 0.00 0.00 35.46 13,300.00 90.00 194.93 6,327.91 6,179.91 0.00 0.00 36.00 13,400.00 90.00 194.93 6,327.92 6,179.92 0.00 0.00 36.55 13,500.00 90.00 194.93 6,327.92 6,179.92 0.00 0.00 37.09 13,600.00 90.00 194.93 6,327.93 6,179.93 0.00 0.00 37.64 13,700.00 90.00 194.93 6,327.94 6,179.94 0.00 0.00 38.19 13,800.00 90.00 194.93 6,327.95 6,179.95 0.00 0.00 38.73 13,900.00 90.00 194.93 6,327.96 6,179.96 0.00 0.00 39.28 14,000.00 90.00 194.93 6,327.97 6,179.97 0.00 0.00 39.83 14,100.00 90.00 194.93 6,327.97 6,179.97 0.00 0.00 40.38 14,200.00 90.00 194.93 6,327.98 6,179.98 0.00 0.00 40.94 14,300.00 90.00 194.93 6,327.99 6,179.99 0.00 0.00 41.49 14,400.00 90.00 194.93 6,328.00 6,180.00 0.00 0.00 42.04 14,402.06 90.00 194.93 6,328.00 6,180.00 0.00 0.00 42.05 Start 1°/100'DLS,-44.76°TF,for 0.68' 14,402.75 90.00 194.93 6,328.00 6,180.00 1.00 -44.76 42.05 TD:14402.75'MD,6328'ND 8/13/2015 2:33:42PM Page 6 COMPASS 5000.1 Build 74 • Schlumberger S Report- Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-10 Project: Kuparuk River Unit TVD Reference: Plan: 120+28 @ 148.00usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: Plan: 120+28 @ 148.00usft(Doyon 141) Well: Plan:2S-10 North Reference: True Wellbore: Plan:2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10wp12[Wobbegong] Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 2,705.93 2,582.00 10-3/4"x 13-1/2" 10-3/4 13-1/2 14,402.75 6,328.00 4 1/2"x 6-3/4" 4-1/2 6-3/4 7,844.72 6,310.00 7-5/8"X 9-7/8" 7-5/8 9-7/8 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (°) 6,876.28 6,017.00 Top HRZ(K-2) 7,823.01 6,308.00 A4 2,637.49 2,522.00 Base W Sak 5,282.63 4,845.00 C-37 5,435.95 4,979.00 Growler 7,752.49 6,300.00 Kup C 1,380.64 1,370.00 Base Permafrost 4,615.38 4,256.00 C-50 368.00 368.00 K-15 Marker 7,356.11 6,213.00 L Kalubik(K-1) 1,882.87 1,849.00 Top W Sak 7,891.00 6,314.00 A4 Target Top 3,085.76 2,915.00 C-80 6,113.01 5,532.00 Top Cairn 280.00 280.00 Top T-3 Sand 7,128.87 6,132.00 U Kalubik(Base HRZ) 4,969.67 4,568.00 C-40 6,256.77 5,637.00 Top Bermuda 7,785.24 6,304.00 A5 14,402.41 6,328.00 A4 Target Base 6,382.29 5,724.00 Base Bermuda Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 600.00 600.00 0.00 0.00 KOP:Start 1.5°/100'DLS,30°TF,for 200.09' 800.09 800.00 4.54 2.62 Start 2.5°/100'DLS,0°TF,for 516.08' 1,316.17 1,308.00 77.78 44.91 Hold for 103.98' 1,420.15 1,408.00 102.46 59.15 Start 3°/100'DLS,91.27°TF,for 821.32' 2,241.47 2,174.82 201.27 316.95 Hold for 2497.58' 4,739.05 4,364.42 200.27 1,518.42 Start 3°/100'DLS, 106.4°TF,for 3105.66' 7,844.72 6,310.00 -1,733.53 1,935.19 Hold for 30' 7,874.72 6,312.61 -1,762.25 1,926.95 Start 1.5°/100'DLS,-12.05°TF,for 340.48' 8,215.19 6,327.48 -2,089.98 1,836.27 Hold for 6186.87' 14,402.06 6,328.00 -8,067.86 241.79 Start 1°/100'DLS,-44.76°TF,for 0.68' 14,402.75 6,328.00 -8,068.52 241.62 TD: 14402.75'MD,6328'TVD Checked By: Approved By: Date: 8/132015 2:33:42PM Page 7 COMPASS 5000.1 Build 74 • • ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-10 Plan: 2S-10 2S-10wp12 [Wobbegong] Clearance Summary Permit Pack Anticollision Report 13 August, 2015 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 2S Pad-Plan:2S-10-Plan:2S-10-2S-10wp12[Wobbegong] Well Coordinates: Datum Height: Plan:120+28 148.00usft(Doyon 141) Scan Range: 0.00 to 14,402.75 usft.Measured Depth. Scan Radius is 1,637.47 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build: 74 Scan Type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Scan Type: 25.00 • • • ConocoPhillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 2S-10 - 2S-10wp12 [Wobbegong] Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 2S Pad-Plan:2S-10-Plan:2S-10-2S-10wp12[Wobbegong] Scan Range: 0.00 to 14,402.75 usft.Measured Depth. Scan Radius is 1,637.47 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft Kuparuk 2S Pad 25-02-2S-02-2S-02wp08.1[Thresher] 325.00 240.86 325.00 221.72 325.00 12.588 Centre Distance Pass-Major Risk 2S-02-2S-02-2S-02wp08.1[Thresher] 499.94 242.49 499.94 216.87 500.00 9.467 Clearance Factor Pass-Major Risk 2S-02-2S-02-2S-02 250.50 240.16 250.50 228.41 250.00 20.451 Centre Distance Pass-Major Risk 2S-02-2S-02-2S-02 450.19 243.52 450.19 224.39 450.00 12.730 Clearance Factor Pass-Major Risk Plan:2S-03-Plan:2S-03-2S-03wp06[Bamboo] 350.00 210.76 350.00 197.20 350.00 15.538 Centre Distance Pass-Major Risk Plan:2S-03-Plan:2S-03-2S-03wp06[Bamboo] 499.96 212.34 499.96 192.79 500.00 10.861 Clearance Factor Pass-Major Risk Plan:2S-04-Plan:2S-04-2S-04wp09[Lemon] 1,177.45 142.97 1,177.45 124.47 1,175.00 7.731 Centre Distance Pass-Major Risk Plan:2S-04-Plan:2S-04-2S-04wp09[Lemon] 1,200.10 143.14 1,200.10 124.25 1,200.00 7.575 Clearance Factor Pass-Major Risk Plan:2S-05-Plan:2S-05-2S-05wp06[Nurse] 400.00 150.75 400.00 135.19 400.00 9.683 Centre Distance Pass-Major Risk Plan:2S-05-Plan:2S-05-2S-05wp06[Nurse] 499.99 151.08 499.99 131.68 500.00 7.787 Clearance Factor Pass-Major Risk Plan:2S-06-Plan:2S-06-2S-06wp06[Salmon] 1,321.95 109.91 1,321.95 89.83 1,300.00 5.474 Centre Distance Pass-Major Risk Plan:2S-06-Plan:2S-06-2S-06wp06[Salmon] 1,346.44 110.10 1,346.44 89.65 1,325.00 5.385 Clearance Factor Pass-Major Risk Plan:2S-08-Plan 2S-08-2S-08wp07[Hammerhead] 1,053.31 42.19 1,053.31 24.87 1,050.00 2.436 Clearance Factor Pass-Major Risk Plan:2S-09-Plan:2S-09-2S-09wp06[Tiger] 500.00 30.68 500.00 11.25 500.00 1.579 Clearance Factor Pass-Major Risk Plan:2S-09-Plan:2S-09-2S-09wp06[Tiger] 574.96 30.57 574.96 18.09 575.00 2.450 Centre Distance Pass-Major Risk Plan:2S-11-Plan:2S-11-2S-11wp06[Great White] 375.00 29.26 375.00 14.70 375.00 2.009 Centre Distance Pass-Major Risk Plan:2S-11-Plan:2S-11-2S-11wp06[Great White] 499.98 30.13 499.98 10.90 500.00 1.567 Clearance Factor Pass-Major Risk Plan:2S-11-Plan:2S-11L1-2S-11 L1wp06[Great Wh 375.00 29.26 375.00 14.70 375.00 2.009 Centre Distance Pass-Major Risk Plan:2S-11-Plan:2S-11L1-25-11L1wp06[Great Wh 499.98 30.13 499.98 10.90 500.00 1.567 Clearance Factor Pass-Major Risk Plan:2S-12-Plan 2S-12-2S-12wp07[Bull] 350.00 59.27 350.00 45.70 350.00 4.369 Centre Distance Pass-Major Risk Plan:2S-12-Plan:2S-12-25-12wp07[Bull] 499.96 61.32 499.96 41.83 500.00 3.146 Clearance Factor Pass-Major Risk Plan:2S-13-Plan:2S-13L1-2S-13L1wp10[Megalodc 28.00 89.48 28.00 88.47 28.00 88.510 Clearance Factor Pass-Major Risk Plan 2S-13-Plan 2S-13L2-25-13L2wp09[Megalodc 325.00 89.48 325.00 76.92 325.00 7.123 Centre Distance Pass-Major Risk Plan:2S-13-Plan:2S-13L2-2S-13L2wp09[Megalodc 499.94 91.05 499.94 71.87 500.00 4.746 Clearance Factor Pass-Major Risk Plan 2S-13-Plan:2S-13PB1-2S-13PB1wp08[Mega 325.00 89.48 325.00 76.92 325.00 7.123 Centre Distance Pass-Major Risk Plan:2S-13-Plan:2S-13PB1-2S-13PB1wp08[Mega 499.94 91.05 499.94 71.87 500.00 4.746 Clearance Factor Pass-Major Risk Plan:2S-14-Plan:2S-14-25-14wp07[Whale] 300.00 119.27 300.00 107.71 300.00 10.318 Centre Distance Pass-Major Risk Plan:2S-14-Plan:2S-14-2S-14wp07[Whale] 499.91 122.17 499.91 102.99 500.00 6.371 Clearance Factor Pass-Major Risk 13 August,2015- 14:26 Page 2 of 6 COMPASS • III ConocoPhillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 2S-10-2S-10wp12 [Wobbegong] Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 2S Pad-Plan:2S-10-Plan:25-10-2S-10wp12[Wobbegong] Scan Range: 0.00 to 14,402.75 usft.Measured Depth. Scan Radius is 1,637.47 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft Plan:2S-15-Plan:2S-15-2S-15wp06[Helicoprion] 275.00 149.28 275.00 138.73 275.00 14.156 Centre Distance Pass-Major Risk Plan:2S-15-Plan:2S-15-2S-15wp06[Helicoprion] 499.87 153.74 499.87 134.60 500.00 8.030 Clearance Factor Pass-Major Risk Plan:2S-16-Plan:2S-16-2S-16wp06[Squalicorax] 250.00 179.28 250.00 169.75 250.00 18.811 Centre Distance Pass-Major Risk Plan:2S-16-Plan:2S-16-2S-16wp06[Squalicorax] 424.94 182.43 424.94 166.17 425.00 11.218 Clearance Factor Pass-Major Risk Plan:2S-17-Plan:2S-17-2S-17wp06[Hybodus] 225.00 209.28 225.00 200.77 225.00 24.575 Centre Distance Pass-Major Risk Plan:2S-17-Plan:2S-17-2S-17wp06[Hybodus] 399.94 212.47 399.94 197.19 400.00 13.902 Clearance Factor Pass-Major Risk Rig:2S-07-Rig:2S-07-Rig:2S-07 777.00 87.58 777.00 69.71 775.00 4.900 Centre Distance Pass-Major Risk Rig:2S-07-Rig:2S-07-Rig:2S-07 7,305.79 154.48 7,305.79 44.92 7,875.00 1.410 Clearance Factor Pass-Major Risk Rig:2S-07-Rig:2S-07-2S-07wp12.1[Goblin] 801.46 89.70 801.46 67.50 800.00 4.041 Centre Distance Pass-Major Risk Rig:2S-07-Rig:2S-07-2S-07wp12.1[Goblin] 7,290.88 153.36 7,290.88 52.52 7,900.00 1.521 Clearance Factor Pass-Major Risk Non-Pad Shark Tooth#1-Shark Tooth#1-Shark Tooth#1 10,409.94 780.52 10,409.94 663.36 6,325.00 6.662 Clearance Factor Pass-Major Risk Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 28.00 500.00 2S-10wp12[Wobbegong] INC+TREND 28.00 500.00 2S-10wp12[Wobbegong] GYD-GC-SS 500.00 1,500.00 2S-10wp12[Wobbegong] MWD 500.00 2,705.93 2S-10wp12[Wobbegong] MWD+IFR-AK-CAZ-SC 2,705.93 4,205.93 2S-10wp12[Wobbegong] MWD 2,705.93 7,844.72 2S-10wp12[Wobbegong] MWD+IFR-AK-CAZ-SC 7,844.72 9,344.72 2S-10wp12[Wobbegong] MWD 7,844.72 14,402.75 2S-10wp12[Wobbegong] MWD+IFR-AK-CAZ-SC 13 August,2015- 14:26 Page 3 of 6 COMPASS • ConocoPhillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 2S-10-2S-10wp12 (Wobbegong] Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor=Distance Between Profiles/(Distance Between Profiles-Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 13 August,2015- 14:26 Page 4 of 6 COMPASS 111 • ConocoPhillips 2S-10wp12 [Wobbegong] Schlumberger Alaska 3 pE a a EE Ei P !J1t1 ANN = A NN N • 300--__ 11 IIIII'i'I r ', 1III \1H-1-- -E-' ,�d,ii 1tit IIIai �lu�llgllilrrlioll '�"I, IIt if,! II ] 150 41�19"!Il,,d 1!I a)92 ° �gllp,l�a P p , II • allIrdII�Jy��,11.1 iIl�III map.,,IIIIIIIPI, � 1911101i' 11 4 41141.1 r11101110$ue' ifa r 4, q ant Magnetic Distance 0 I 1 I I 1 I I I I I I I I I I I I I I I I I I I I 0 2500 5000 7500 10000 12500 15000 Displayed interval could be less than entire range: Measured DeptI28.O0 To 14402.75 ANTI-COLLISION SETTINGS Interpolation Method: MD, interval:25.00 Depth Range From: 28.00 To 14402.75 Results Limited By: Centre Distance: 1637.47 SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 28.00 500.00 2S-10wp12[Wobbegong](Plan:2S-10) INC+TREND 28.00 500.00 2S-10wp12[Wobbegong](Plan:2S-10) GYD-GC-SS 500.00 1500.00 25-10wp12[Wobbegong](Plan:2S-10) MWD 500.00 2705.93 2S-10wp12[Wobbegong](Plan:2S-10) MWD+IFR-AK-CAZ-SC 2705.93 4205.93 2S-10wp12[Wobbegong](Plan:2S-10) MWD 2705.93 7844.72 25-10wp12[Wobbegong](Plan:2S-10) MWD+IFR-AK-CAZ-SC 7844.72 9344.72 2S-10wp12[Wobbegong](Plan: 2S-10) MWD 7844.72 14402.75 2S-10wp12[Wobbegong](Plan:2S-10) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2582.00 2705.93 10-3/4" x 13-1/2" 10-3/4 6310.00 7844.72 7-5/8"X 9-7/8" 7-5/8 6328.00 14402.75 4 1/2"x 6-3/4" 4-1/2 LEGEND — -- 2S-02,25-02,25-02 VO — Plan:2S-11,Plan:25-11,2S-11wp06[Great White]VO —431— Plan:26-16,Plan:25-16,2S-16wp06[Squalicorax]VO —X— 2S-02,25-02,2S-02wp08.1[Thresher]VO Q Plan:2S-11,Plan:2S-11L1,25-11L1wp06[Great White]VO —e— Plan:2S-17,Plan:2S-17,26-17wp06[Hybodus]V0 —9— Plan:25-03,Plan:26-03,2S-03wp06[Bamboo]VO — Plan:2S-12,Plan:25-12,2S-12wp07[Bull]VO -- Rig:2S-07,Rig:2S-07,26-07wp12.1[Goblin]VO --X— Plan:25-04,Plan:28-04,25-04wp09[Lemon]VO —I— Plan:26-13,Plan:2S-13L1,2S-13L1wp10[Megalodon]V0 $— Rig:20-07,Rig:2S-07,Rig:2S-07 VO —e— Plan:25-05,Plan:2S-05,2S-05wp06[Nurse]VO $ Plan:26-13,Plan:2S-13L2,2S-13L2wp09[Megalodon]VO -0-- Shark Tooth#1,Shark Tooth#1,Shark Tooth#1 VO —X— Plan:25-06,Plan:28-06,25-06wp06[Salmon]VO $— Plan:2S-13,Plan:2S-13PB1,25-13PB1wp08[Megalodon]VO—B-- 2S-10wp12[Wobbegong] -- Plan:25-08,Plan:25-08,2S-08wp07[Hammerhead]VO -16-- Plan:26-14,Plan:2S-14,2S-14wp07[Whale]VO Plan:25-09,Plan:25-09,26-09wp06[Tiger]VO --X— Plan:25.15,Plan:25-15,2S-15wp06[Helicoprion]VO • • Conoco hillips 2S-10wp12 [Wobbegong] Schlumberger Alaska r If , .... 17.• E e .ro u 1 8 6 rs.D., t m VI, J \\ N N vNQi ON N \N I 00 ilimmumilr C 60 �,\111 I• ® ' / ii: co Nit% / 1 2-2 a U 30I Equivelant03 Magnetic Distance ' , U x,41' \\ 0 1 1 1 1 1 I 1 1 I I 1 I I 1 1 1 1 1 I 1 1 I I 1 I 1 1 0 400 800 1200 1600 2000 2400 Displayed interval could be less than entire range: Measured Dept/Q8.O0 To 14402.75 ANTI-COLLISION SETTINGS Interpolation Method: MD, interval: 25.00 Depth Range From: 28.00 To 14402.75 Results Limited By: Centre Distance: 1637.47 SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 28.00 500.00 2S-10wp12[Wobbegong](Plan:2S-10) INC+TREND 28.00 500.00 2S-10wp12[Wobbegong](Plan:2S-10) GYD-GC-SS 500.00 1500.00 2S-10wp12[Wobbegong](Plan:2S-10) MWD 500.00 2705.93 2S-10wp12[Wobbegong](Plan:2S-10) MWD+IFR-AK-CAZ-SC 2705.93 4205.93 2S-10wp12[Wobbegong](Plan:2S-10) MWD 2705.93 7844.72 2S-10wp12[Wobbegong](Plan: 2S-10) MWD+IFR-AK-CAZ-SC 7844.72 9344.72 2S-10wp12[Wobbegong](Plan:2S-10) MWD 7844.72 14402.75 2S-10wp12[Wobbegong](Plan: 2S-10) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2582.00 2705.93 10-3/4"x 13-1/2" 10-3/4 6310.00 7844.72 7-5/8"X 9-7/8" 7-5/8 6328.00 14402.75 4 1/2"x 6-3/4" 4-1/2 LEGEND -e- 2S-02,25-02,25-02 VO —I-- Plan:2S-11,Plan:2S-11,2S-11wp06[Great White]VO -e- Plan:2S-16,Plan:2S-16,2S-16wp06[Squalicorax]V0 -)— 28-02,28-02,25-02wp08.1[Thresher]VO -9- Plan:2S-11,Plan:2S-11L1,2S-11L1wp06[Great White]VO -e- Plan:2S-17,Plan:2S-17,2S-17wp06[Hybodus]V0 -B- Plan:2S-03,Plan:25-03,2S-03wp06[Bamboo]VO -s— Plan:2S-12,Plan:2S-12,2S-12wp07[Bull]VO —0— Rig:2S-07,Rig:2S-07,2S-07wp12.1[Goblin]VO --X-- Plan:2S-04,Plan:2S-04,2S-04wp09[Lemon]VO —i— Plan:28-13,Plan:2S-13L1,2S-13L1wp10[Megalodon]VO -e-- Rig:2S-07,Rig:2S-07,Rig:25-07 VO -e- Plan:25-05,Plan:25-05,2S-05wp06[Nurse]VO -9- Plan:2S-13,Plan:2S-13L2,2S-13L2wp09[Megalodon]VO -0- Shark Tooth#1,Shark Tooth#1,Shark Tooth#1 VO — Plan:2S-06.Plan:25-06,2S-06wp06[Salmon]VO -h- Plan:2S-13,Plan:2S-13PB1,2S-13PB1wp08[Megalodon]Vo--9— 2S-10wp12[Wobbegong] Plan:2S-08,Plan.2S-08,2S-08wp07[Hammerhead]VO —A-- Plan:2S-14.Plan:2S-14,25-14wp07[Whale]VO Plan:2S-09,Plan:2S-09,2S-09wp06[Tiger]VO -,(— Plan:25-15,Plan:25-15,25-15wp06[Helicoprion]VO MDAzi TVD +N/-S +E/-W Dleg TFace V rget Lt{ bUU 28.00 0.00 28.00 0.00 0.00 0.00 0.00 25-10wp12 [Wobbegong]600.00 0.00 600.00 600.09 3.030.00 800.00 0.00 4.54 0.00 2.62 1.50 30.00 -5.06 600 m 790 28.00 To 14402.75 1410.15 15.90 30.00 1408.00 77.78 44.91 2.50 0.00 -86.76 790 970 1420.15 15.90 30.00 1408.00 102.46 59.15 0.00 0.00 -114.28 2241.47 28.75 90.05 2174.82 201.27 316.95 3.00 91.27 -276.45 739.05 28.75 90.05 4364.42 200.27 1518.42 0.00 0.00 -586.44 970 1160 844.72 85.00 196.00 6310.00 -1733.53 1935.19 3.00 106.40 1173.59 2S-Wobbegong 1.Heel 081215 PB_Opt1 14:34.Autiust 13 2015 874.72 85.00 196.00 6312.61 -1762.25 1926.95 0.00 0.00 1203.48 1160 -- 1340 215.19 90.00 194.93 6327.48 -2089.98 1836.27 1.50 -12.05 1543.51 8402.06 90.00 194.93 6328.00 -8067.86 241.79 0.00 0.00 7730.37 1340 - 1530 SURVEY PROGRAM 4402.75 90.00 194.93 6328.00 -8068.52 241.62 1.00 -44.76 7731.05 2S-Wobbegong 6.Toe 081215 PB pib 26.00 ito:o% 2Sr1e0wp12[v..,on9],,,I=,..„. 1530 - 1710 30.00 500.00 25-10wp12 SOsbbegong],PI.Ye $ 500.00 1500.00 25-10wp121W.,1.90n9l,PIA1N97.0. 500.90 4205.93 25.1.02 Mbbbegon9],PIi1NB..09-AK-0PZSC 1710 - --- 1900 2705.93 7844.72 25.10w512 lWobbegong],VIAINB.9-181 7844.72 7844.72 25-100p12[Wobbegon9]07141115:141419-0.14-00.7-SC SG 7844.72 4402.75 25-1021Wobbegongl 0193.11518-10) 1844.72 14402.75 25-10wp12lWabbegong],PIA/N6.111214114C0.2-sC 1900 2430 CASING DETAILS 2430 2950 TVD MD Name Size 2950 3480 2582.00 2705.93 10-3/4"x 13-1/2" 10-3/4 6310.00 7844.72 7-5/8"X 9-7/8" 7-5/8 3480 -- 4000 6328.00 14402.75 4 1/2"x 6-3/4" 4-1/2 4000 ® 4530 4530 5050 Rlg:2S-07I 5050 _ 5580 12S-06wp06[Salmon]I 0 I 360<.- 12S-07wp12.1[Goblin]I 5580 ---`- 6100 ;o.�. �-'•w =`�' 6100 -- 7140 -30/330 'i:: ;4..`.'.111-ti4 ����--.�__``�ul� R,iLr(`fI „�,®�V►,=�gyp``\. �__ w � 30 7140 -- 8180 �2S o8wpO7[Hammerhead] - pr- o-46.-® e'1►• yah ` 8180 - 9210 _I - _'�'4:�� "I '''° -�`' ►�®\tet\i�1►.Z,4-Iwo99- ®0 -. xw!®®oIv * •n,-.-1z �� - l f 9210 10250 , i_®!Ali, `:wO®� ma±b:? ' �`'ai ~moi-���✓ 10250 - 11290 F., ; 1 f '„'°�''sj4-ft1/'� �,®•>`-ay:Aiil/t...el 11290 12330 y � ••ffi6&' ♦O' �', 12330 13370 -60/300 tr •4,ielj0®� ''�`- `waFr tftl ,1 60 13370 -- 14403 140;61! !�4il�®`'® � ��"�-\R1�°i� r�I ®ri4 I2S-03wp06[Bamboo] 12S-12wp07[Bull]I �_%. �A'� +'4U- •¢I®".-0� v.d® .A 1imI�IPFP �YMi°'...4'.6444.3t-,,,,tlrft•i4. . 1 � ® `��''►��j�ev,�,w`�i,\O` �� 5 ®,�j est -1 I.Ir r a ♦ \�� 4s � ♦ ��i o�®+amt ♦ , •®!I�I+���a 6 1 I♦ w444tL .�t. ro r/i : ys• -,...4.0,t71::i7 ; `�� /•... ` '�� s "rove i'1 f�r® • y:� /►� rim-p ♦w♦ +�'w r./ r ' i.: Ojt�r�. .0®II�`..&!It-.r4rereflra ,a' "- -,. 'w� •meq w r1* ���,'` -.'A...V�i�'-' V ..Mini 4866 •�tSt a r , rc�i�B'' 90/270 � ,4 e� ♦ 1 ru x m4,, " . .1t - .-'I 90 V�� r$r" cti v � • ►,5 `!��®4 t ',lii� ff=4, 9r. "k4 t 'Ni4' •A,.>-:S . ' 's®ii /��/ ♦,0 1 ] rg}Y7" _ dye'10,3 fti9,"a -.9- 3 1 4 i D� t^t%III 0,111P,44/4 s A1C, a+q,�i'. ♦t' 0: ,(r��r rI ►j / 0 ��, mw`� 'p!`', + "''-� rltlT,Y♦1 i•���� �i/'►�' �I��1►�r��l _,,,,,Art, ....-_._ m p 'rr,�5 'le.- , � �'">�i`=��� ,♦�Ir� ,i �' ,,�o-i1-ra/ir/1 a , $ , 14,1 A,iik i* els. 40... .le, ( ornuid . �4 t 11* e is ° . ,® • ► r'1 Ar�r ► -. 117►- 1 ^' + ♦�f"r�1e/Y.♦ �ix� rY► ►�.. Fri* ]�►1�1�, a►�,��1,��;�1fr1� -'r] v r,� iVei0#®1141 t ®R (9.A�:�� ��I ht II ��1 ° ♦gt 1 ���� ®err . /►♦ 6 a r 4a�e r Q • 1Y►i ♦a 44..1.1* I'� nrr ♦'��aioa ,,,alr�1 ,l1 A.�+,,to t►641' 4��t!'.�' I��Y�'i ��� rr04��r � DW e1�'� e Y- a1 � .� r VY 1hZ��r te••..� .���� II�I�M,-I ys�1��r� ,•��� 12S-17wp06[Hybodus]I >.f!417 ...at�n.A fis�r 14 4. 44 r M sa34 :ate i1 `�.'r, r �. , ..4.1,41.1t41-114401',143/ Aiw'*� 40 y1t eat. 0$10-,5111,4''411',111 ie �I��w 4 /_�oip��� .��' ►• iii I►�3 � �il ���, �,,ri..�, .� ,.���� ' 8,4,4.944 retiof /:arra.I ►•,�� �1 ' ♦s .'+' v,zo .>;�► ►� ;1►.ext`.1►� / ►Ii is -120/240 114 4,1ida m... I�� �� 7�'� � I�I���I;lrAt;�le PIK*4 120 41'!s►-41 ►601' 0�1� 1 ,4 0 a►� tikir '►f._4 ® � l ► / r I .•.1� Sob 41'7, �i�.4 / 1 tar/ 12S-16wp06[Squallconogl S;• ®.�j •����i1i•� ►�T ipit,•�� -a�rrr!®j�or , --,. , '. �./ ig� ,�e.��.t`♦ice 53 � ,,-. !- _ 2SA5 6[Nurse ]l �►�,, 'i►� l^� <► .-..1•*�.� r 11 12S-15wp06[Helicoprion�� `� b�Olgti��@�``� `ma ►,�,`/, o`0 . ► I2S-14wp07[Whale]I - ►.i��® ` �, ,/ � ��t'+®•' 0:��.4 2S-13L2wp09[Megalodon] ' • ,_ ® I® ?s ' 150/210 �� �.�. '! .a ��IOW O 150 12S-13PB1wp08[Megalodon]1 _- �V `�yr �/p,4,.►® / • 12S-11wp06[Great White]I , "'.►x:11 .- 12S-04wp09[Lemon] I2S-11L1wp06[Great White]I -180/1-8 r2S-09wp06[Tiger]I $ 2502 2542 2.4200 -dr Parc 54812540482719o001.0e621V2 $ n 120049001417044224102 A P.A.,lig 13-071 29-07..12 1(00.1. -?I(- 2542,2042.0242,001111x.4,.11 vo '�- Pow 4.2948,2%wnyos 17q•Ivu 44 n 2re,w)m i.w+won,v0 25-07.510 25-07.49250100 $ n n. 9 4 00904 168 52241 2 0 } n n S1,w{4610ml w105 V0 -� n x0.14,47 whal]vo $ 290Tomo, 1.9n.TMn4100 i(- 84..,0002410441V0 $ n n ,r, io..,wnwlw iE man. n 25-,5.,4812.�P,010 $ 22-10401211.1.2091 $ Plan MOS.Ran 2.05.2s05.4005122erv0 j- Plart n. 20.1z494718u.1V0 -6- Pian 28,Mart s15.yoe p.uaa,..lv0 Pon.2548.004.2800.2948.4,06[Salmi V4 -¢- Pion 25-13 Plan.25-,31,.os4o4t9ptoimeledeonivo Pon.911.004 20 11 20 114048 Mv04�+1 vo • • 14;55,August 13 2015 Easting(3500 usft/in) 111111111111111111111111111I111111111I 111II11111111111111I11rII111111111I1111I1 AC wells ONLY (NOT a Spider) 2S-14wp07[Whale] _ _ 2 -1 11" - � 09wp0�[Tiger] blin] _ /- 2S-05wp06[Nurse] — Kuparuk 2S Pad _2S-02 2wp06.1 [Thresher] 2S-13L ��08[meg-.do 'ig:2S-07 2S-13 /1wp08[M:galodo lf p ' Megalo.on] - Z m j i i o /am/ _ _ o Q_ - S -r Tooth#1 / —� 2S-12w.0 [Bull] 2S-08wprr fi���lmon] 2S-03wp06[Bamboo] _ Prelim: Kuparuk Cairn Pad2 2S-10wp12[Wobbegong] / = Prelim: Kuparuk Cairn Pad - I .. , N,r,it 1','Zw�� - 2S 16wpc[Squalicorax] 2S-15wp06[Helicoprion] 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 111111 1 1 1 1 1 I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 i 1 1 1 I I 1 I I I 1 1 I 1 1 1 1 1 1 1 ] 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Easting(3500 usft/in) AC Flipbook MD Azi TVD +N/-S +E/-W Dleg TFace V rget LS bUU 28.00 0.00 28.00 0.00 0.00 0.00 0.00 2S-10wp12 [Wobbegong]800:00 3.0`" 0 30:00 800:00 °:54 2:62 °:50 30: 0 -5:06 600 790 316.17 15.90 30.00 1308.00 77.78 44.91 2.50 0.00 -86.76 790 970 28.00 To 500.00 420.15 15.90 30.00 1408.00 102.46 59.15 0.00 0.00 -11428 2241.47 28.75 90.05 2174.82 201.27 316.95 3.00 91.27 -276.45 739.05 28.75 90.05 4364.42 200.27 1518.42 0.00 0.00 -586.44 970 1160 844.72 85.00 196.00 6310.00 -1733.53 1935.19 3.00 106.40 1173.59 25-Wobbegong 1.Heel 081215 PB_Opt1 14:36,August 13 2015 874.72 85.00 196.00 6312.61 -1762.25 1926.95 0.00 0.00 1203.48 1160 1340 215.19 90.00 194.93 6327.48 -2089.98 183627 1.50 -12.05 1543.51 1402.06 90.00 194.93 6328.00 -8067.86 241.79 0.00 0.00 7730.37 1340 1530 SURVEY PROGRAM 4402.75 90.00 194.93 6328.00 -8068.52 241.62 1.00 -44,76 7731.05 2S-Wobbegong 6.Toe 081215 PB 000 .To Survey/Plan Tool 28.00 500.00 25-100,12[Wo0be90n4 IP141182E 0 From 1530 1710 28.00 500.00 25-10,,12[Nbbbe9ongl(VlST13.280)SS 500.00 1500.00 25-10,12 R.I.egong](P1.180-10) 500.00 2705.93 25-10,12[Wobbegong](PI41181SHOtAl0.007 C 1710 _ ' 1900 2705.93 420593 25-1021W013begong](P8.1181.-10) 2705.93 7844.72 25.10.0482 tWabbegong]IPIf ICRRIt-AK-CA2-SC 78..72 9344.72 2,10,12(Wobbe9ong](P38181121-10) 1900 2430 7844.72 14402.75 25-10,121Wobbegong](P121W6.W/A8482.SC CASING DETAILS 2430 2950 TVD MD Name Size 2950 3480 2582.00 2705.93 10-3/4"x 13-1/2" 10-3/4 6310.00 7844.72 7-5/8"X 9-7/8" 7-5/8 6328.00 14402.75 4 1/2"x 6-3/4" 4-1/2 3480 4000 4000 4530 4530 5050 0/360 5050 5580 5580 - 6100 75 6100 7140 -30/330 70 30 7140 8180 8180 ' 9210 60 9210 10250 55 10250 11290 50 11290 12330 45 12330 13370 -60/300 40 60 13370 14403 35 Orailikkam -rt@aAl 30 25 1 [2'. un] 1 1 ` 1 14 I 1 / / I 1 ‘ 1 .1 1 I II -90/270 ;----}--� --r--i---t -- ,.�..-_-t ----t-_MIS �_.1--.-J - __t --h-I 90 I 1 1 j 1 i I yY ; 5 i 1 { i� 1 4 1 1 \ v � \, \ \ \� � � vv1 � ` � v`. 1 5-09 .06 Tig.] \ \ 20 t 25 N 2S- iwp0. Great 30 35 -120/240 40 120 45 50 55 60 65 -150/210 70 150 75 -180/180 -0- 2 2. -A- 0=S.0ew07nmm.m.,200 g- P n. :10Lap09[Vg.4nV0 -d- n 2.11000n1V0 4- 5,[01,...]22 -tr P.n 0 5ee„905 rn.,vo -6- P ." ::P9,.ee P.9.e0on 20 ' a 2.0 22 -$. Plan 0&000o21e.mwo v2 -#- s1„�5Gn.,W5.Ve -A- P n , 7P7..VO 5 0 m. Shag roome, VO -X- man a..w9il.ma,v0 $ P." P. 1704X2,22,20 -X- P . 43.404722,2°0 122 $ ZS10017234091 •g• P. 4,06 inn1..rvo -2- P.n.2.2 Plan 2.2 2s1mp0718o•v0 -} Plan n s,e,020(000KongV0 - Pan.2505.P472005.250005[smmonIVO 4- Plan 0s,1.Plan 2s1011.2.301,,n10N.43400"]V0 0' Plan.2st7,Prn2s,7,25-,7.,p0alnveomnjVo MD Azi TVD ON/-S 4-E/-W Dleg TFace V rget lb bUU 28.00 0.00 28.00 0.00 0.00 0.00 0.00 25-10wp12 [Wobbegong]800 09 3 5 30 00 800 00 4 54 262 °50 30 00 -5.0.91F600 - 790 44.500.00 To 1000.001420.15 15.90 30.00 1408.00 102.46 5915 0.00 0.00 -1114.28 1 2.50 0.00 -86.76790 970 2241.47 28.75 90.05 2174.82 201.27 316.95 3.00 91.27 -276.45 ,. 739.05 28.75 90.05 4364.42 200.27 1518.42 0.00 0.00 -586.44 970 1160 844.72 85.00 196.00 6310.00 -1733.53 1935.19 3.00 106.40 1173.59 2S-Wobbegong 1.Heel 081215 PB_Opt1 14:37,August 13 2015 874.72 85.00 196.00 6312.61 -1762.25 1926.95 0.00 0.00 1203.48 1160 1340 215.19 90.00 194.93 6327.48 -2089.98 1836.27 1.50 -12.05 1543.51 9402.06 90.00 194.93 6328.00 -8067.86 241.79 0.00 0.00 7730.37 1340 1530 SURVEY PROGRAM 1402.75 90.00 194.93 6328.00 -8068.52 241.62 1.00 -44.76 7731.05 2S-Wobbegong 6.Toe 081215 PB Tool 01728.00 500.00 25r100,12[Y9,143egong](111 N952484940 1530 1710 28.0 wp 500.00 2S-1012Mob5egong]PIlva )SS ( 500.00 1500.0025-10wp12]Wobbegong]PW9-10 Ia1 -10) 500.00 2705.93 2S-10wp12[Wobbegoeg](00082 ,W9-AK-CAZ-SG 1710 1900 2705.93 4205.93 2S-10wp12[Wobbegon9](P1S1W6-10) 2705.93 7844.72 2S-10wp121Wobbe9782](PIawe-1 9-4KCAZ-SC 7840.72 9344.72 2S.10wp12[W7bbegon9](PISIWn-10) 1900 2430 7844.72 14402.75 2,10.12]Wobbegong](PISIN6.W9-AKCAZ-SG CASING DETAILS 2430 2950 TVD MD Name Size 2950 3480 2582.00 2705.93 10-3/4"x 13-1/2" 10-3/4 6310.00 7844.72 7-5/8"X 9-7/8" 7-5/8 3480 4000 6328.00 14402.75 4 1/2"x 6-3/4" 4-1/2 4000 _ 4530 4530 5050 0/360 5050 5580 5580 " 6100 75 2S-08wp07[Hammerhead]] 6100 7140 -30/330 70 30 7140 8180 44i.,,„ 65 8180 9210 60 9210 10250 55 10250 11290 50 �♦�.' 11290 12330 � 12330 13370 40 arripiriomix,,, , ®•fir\ 60 13370 14403 60/300 O.�w® � b 30 \OF sA l►�taaara��v >xa� 25-. X, 1 ' 7f0f4.710 ir,V Ni, 2 ,,,,:-.7..-4.2,11. 77/1A110.4sT, if- „',',,,tp,:,':, 2S-12 07[Bull]] : \ -, r(R , , ; wp [ 9] . 511:1d ` tea � / � 1 � _ a 1;'�:.eA n•,t� 1�� -90/2�� I, ___�__ -� I 1 1 f_� -moi 1 /' 44t' 90 rite I 1 ! tmr, --it �-- r , ,_. ,../. 'qS r � ,./ fff \ \ ' y0: \ 1 SSS11Y�� / 4,„Arsi I�FI����' :,,,„,, - -ss , ,, \ ,.'\40,' _-50 _. r, ' 25 30 X44 �l, -120/240 ��: 40 ���� �� I0� 120 50 � 161/1.146-4! 55 � ��1 I2S-11wp06[Great White] 1"4r 60 65 14‘01016.' I, . -150'/210 v4 70 \ WI 150 75 I2S-11L1wp06[Great White]] ]2S-09wp06[Tiger]] -180/180 9 i -�- Pan soew07Memmeme.alvo $ Plan 12,2.rp051M,gab0on]v0 -d- a 0[020002 4t- 2 2.05.02109.1Imr28,04,.. Pn n .2 s„9096,ire•„ri wvo 02 -eo-- P :w P7 08au,vN0aga,007vo -e- 8 .-07a .05 27.,,10257.7 V $ Plan 5.000.109 8. P 02 �810T20 01 VS ,it- P n s0awpg Memm100 -$ P n ,,, o8[0221wnn,Ivo 94. P n xs,en2OSMekopu 02 $, 2s Pan �20n91 m $- P n n. 8u5.p8�M"rsa�vo -}- P n -,. n. 23-12230P28ua�Vo -e- P n. n .05.2008lsa"aa230[02 Pun 22-08.Pun.204827-0.w21082222[V2 Q- Pian.2s,7.P002,11.2517wpmleyemw1Vo MD Azi TVD +N/-S +E/-W Dleg TFace V rget lb bUU 28.00 0.00 28.00 0.00 0.00 0.00 0.00 20.-10wp12 [Wobbegong]800 9 3.030.00 800 454 262 10.50 3000 -5.0 600 790 1316.17 15.90 30.00 1308.00 7728 44. 1 2.50 0.00 1000.00 To 2000.00 1420.15 15.90 30.00 1408.00 102.46 59.15 0.00 0.00 -1184.28 6.76 790 970 2241.47 28.75 90.05 2174.82 201.27 316.95 3.00 91.27 -276.45 739.05 28.75 90.05 4364.42 200.27 1518.42 0.00 0.00 -586.44 970 1160 844.72 85.00 196.00 6310.00 -1733.53 1935.19 3.00 106.40 1173.59 2S-Wobbegong 1.Heel 081215 PB_Opt1 1+1:376 AuaustT3 }15 874.72 85.00 196.00 6312.61 -176225 1926.95 0.00 0.00 203.46 1160 1340 215.19 90.00 194.93 6327.48 -2089.98 1836.27 1.50 -12.05 1543.51 9402.06 90.00 194.93 6326.00 -8067.86 241.79 0.00 000 773037 1340 1530 SURVEY PROGRAM 9402.75 90.00 194.93 6328.00 -8068.52 241.62 1.00 -44.76 7731.05 2S-Wobbegong 6.Toe 081215 PB rpth From Depth To Survey/Plan Tool 28.00 500.00 2510,12 Mokbegong](PIAMZERWID 1530 1710 28.00 500.00 2 0.p 10121'Mbbegong](P188,31320/333500.00 1500.00 2S-5-10wp121Wobbegong](PIl1W9.9-10) 500.00 2705.93 25-10wp121Wobbegong](PIf1W6aMAKCAZ-SC 1710 1900 2705.93 4205.92 25-10wp12 Wobbegong)(PIAWAS-101 2705.93 7844.72 25-1004 ( bb p12 egong](PIAGNISMOKCAZ-SC 7844.72 9344.72 2S-1002p12 rN[Wobbegong](PIA1Wa9-10l 1900 2430 784.72 14402.75 2,10,12]Wob6 begong]0.1.18HC 138-MAZ-SG CASING DETAILS 2430 2950 TVD MD Name Size 2950 3480 2582.00 2705.93 10-3/4"x 13-1/2" 10-3/4 6310.00 7844.72 7-5/8"X 9-7/8" 7-5/8 6328.00 14402.75 41/2"x6-3/4" 4-1/2 3480 4000 4000 4530 4530 5050 0/360 5050 5580 5580 "" "" " 6100 y 75 6100 7140 -30/330 ��►�. 70- 30 7140 8180 12S-08wp07[Hammerhead]I �.`�` �,,�S�i`� 8180 - 9210 �' 0,11110#111k111110.--- * ��:�� =-_` 9210 10250 i�41110411111kalrialleAr, 10250 11290 � 1129012330 P1114111r4iNIOSSIIIIIIIN w 12330 _.___. 13370 ��� i � /I al1Rai -60/300 �_�j� `i �� �, ',1 60 13370 14403 pit.4. - --'--"likaililearlakilliK4W.dik 21 1 1il -90/270 Cir90 10_ ,.,)� 1 20 25 30 35 -120/240 40 120 45 /50 _ 55 %' 60 65 150/210 =7D . ' 150 75 -180/180 -4, Ou0 -� Nan z2.090007000 $ Plan 1153 ae4aamnlvo -y 825510112.1odhv0 Ole. O 0SO4lmnane000 -d- Plan an 5-0000031S2S100 -te P , P915 090.200 00 -+ n $ Nan25-03,06,53.90110 .9.19. Plan n s1,051onvv.,. -f- P n 1,7 nernab1V0 s aTooth al,snam Toon rl vo -X- a4007S(Lemanl0o $ 0506105 704,]7O -j(- n 0-12,0[050070"100 -B.• O0-105010W00030021 $ Plan n aswp0010uia5100 -} Plan n. .0f 2..7071590104 t Plan n .Oslo,.ppookaraxlvo -X- 77506-05.Pun 2,56 25060002[000,100 -g- 7.25-13.Pan Os13li25131.w10loesamo"l V0 ..e- Plan.20.11.van OS-17.25-17,06101oo52w100 MD Azi TVD +N/-S +E/-W Dleg TFace V rget Lo bUU 28.00 0.00 28.00 0.00 0.00 0.00 0.00 2S-10wp12 [Wobbegong]800 00 3°"00 30 00 800:00 4 54 2 62 150 0.00 30.00 -5.06 600 - 790 316.17 15.90 30.00 1308.00 77.78 44. 1 2.50 0.00 -86.76 2000.00 To 7000.00 1420.15 15.90 30.00 1408.00 102.46 59.15 0.00 0.00 -1114.28 790 970 2241.47 28.75 90.05 2174.82 201.27 316.95 3.00 91.27 -276.45 739.05 28.75 90.05 4364.42 200.27 1518.42 0.00 0.00 -586.44 970 1160 844.72 85.00 196.00 6310.00 -1733.53 1935.19 3.00 106.40 1173.59 2S-Wobbegong 1.Heel 081215 PB_Opt1 14:38,August 13 2015 874.72 85.00 196.00 6312.61 -1762.25 1926.95 0.00 0.00 1203.48 1160 1340 215.19 90.00 194.93 6327.48 -2089.98 1836.27 1.50 -12.05 1543.51 $402.06 90.00 194.93 6328.00 -8067.86 241.79 0.00 0.00 7730.37 1340 1530 SURVEY PROGRAM $402.75 90.00 194.93 6328.00 -8068.52 241.62 1.00 -44.76 7731.05 2S-Wobbegong 6.Toe 081215 PB 2From Depth0000 2510,12[Wobbegong]IP1.134#98412 1530 1710 26.00 500.00 2540,12 CMegong](PI 1V 129SS bb 500.00 1500.00 2,10,12[•Nobb gong](PI3IVD-10) 500.00 2705.93 2S-10wp12(Wobbegangl/Pl01V11224.LP2-SC 1710 1900 2705.93 6205.93 2S-10wp121Wobbegong](PI31VA9-10) 2705.93 7844.72 2S- wp 012[Wobbegong]IPI41VB413/-A1,LAZ-SC 7844.72 9344.72 25-l0wp12 @Wbbeg4ng](PI3IVID-10) 7844.72 14402.75 2,10,12[VWbbegong]IPI31Vn.10gAK-CAZ-S4 1900 2430 CASING DETAILS 2430 2950 TVD MD Name Size 2950 3480 2582.00 2705.93 10-3/4"x 13-1/2" 10-3/4 6310.00 7844.72 7-5/8"X 9-7/8" 7-5/8 6328.00 14402.75 4 1/2"x 6-3/4" 4-1/2 3480 4000 4000 4530 4530 5050 0/360 5050 5580 5580 6100 75 6100 7140 -30/330 70 30 7140 8180 65 8180 9210 60 9210 10250 55 10250 11290 50 11290 12330 45 12330 13370 -60/300 40 60 13370 14403 35 30 25 -2 ,,,........s... 1 1� -90/270C-C1°D 90 1 5____"/1::__._.7/7) 1 20 _25 30 35 -120/240 -40 120 :=:: 45 60 55 7 60 65 -150/210 70 150 75 -180/180 2 2,.0 -2S- Plan S40427lwmmem2,124 -a. Plan. 12.051V.9zamnv0 -dw 50.m2110unlv0 -N- z , 22.11Mean.1 v0 $ Pao ,44,20004&Iv4 -a- Plan 201.202 11.42424.41,70 $ 6 43. Plan. 2503no5l9ameaal v0 4- plan n 1w02cre.W..VO -y- P n 427lma.V2 -t shark,. 1n oo 21,00.0o.R 122 - Plan 0 242.9 ^'0120 $ P 2. n ,0 151.04510Wheel VD 41(. Plan - n 7� 25.5.110518e,moolo0 -g- 25.1am12120220227g1 -$ Po. n sa5.m50+me.lv0 $- Pao 2212, 24.12.10716.Rv0 $ Plan n 01..0a(Swaemulvo 44- Pian 2509.Pan 2,00.24.00..72612924o]V0 } Plan 2,12.PMn.25.021,2s23214,7212n<w24221 v4 $ Pian.2517.Pa,24.172S17.y45g17o4,elv0 MD Azi TVD +N/-S +E/-W Dleg TFace V arget Lb bUU 28.00 0.00 28.00 0.00 0.00 0.00 0.00 28-10wp12 [Wobbegong]80009 3.0 30.00 80000 4.00. 0 262 °50 0 00 30.00 506 600 - 790 1316.17 15 90 30.00 1308 00 77.78 44. 1 2.50 0.00 -86.76 7000.00 To 8000.00 1420.15 15.90 30.00 1408.00 102.46 59.15 0.00 0.00 -114.28 790 970 2241.47 28.75 90.05 2174.82 201.27 316.95 3.00 91.27 -276.45 739.05 28.75 90.05 4364.42 200.27 1518.42 0.00 0.00 -586.44 970 1160 844.72 85.00 196.00 6310.00 -1733.53 1935.19 3.00 106.40 1173.59 2S-Wobbegong 1.Heel 081215 PB_Opt1 14:39,August 13 2015 874.72 85.00 196.00 6312.61 -1762.25 1926.95 0.00 0.00 1203.48 1160 1340 215.19 90.00 194.93 6327.48 -2089.98 1836.27 1.50 -12.05 1543.51 4402.06 90.00 194.93 6328.00 -8067.86 241.79 0.00 0.00 7730.37 1340 1530 SURVEY PROGRAM 4402.75 90.00 194.93 6328.00 -8068.52 241 62 1.00 -44.76 7731.05 2S-Wobbegong 6.Toe 081215 PB =Ftb 28.00 500.00 2540,31219110bbegong](P10.151Ag4D 1530 1710 28.00 500.00 25-10,1211111013begong11P11V )S 500.00 1500.00 2540,312[W066egong](PIA1N84-1-10) 500.00 270503 254.4912(Wobbegong]1PI2 AKCA2-SC 2705.93 4205.93 25-1012[Vrbbbegeng](PI1.1V,ID-l0/-10) 1710 ._ 1900 2705.93 7844.72 25-10,7512[Wobbegong](PIAIee-101 KLA2-SC 7844.72 5344.72 25-1012(Wobbegong]1PIA1Vffi.191 7844.72 14402.75 2,10,7512[1,3103eg018](P1041101.RNARLALSC 1900 2430 CASING DETAILS 2430 2950 TVD MD Name Size 2950 3480 2582.00 2705.93 10-3/4"x 13-1/2" 10-3/4 6310.00 7844.72 7-5/8"X 9-7/8" 7-5/8 3480 4000 6328.00 14402.75 4 1/2"x 6-3/4" 4-1/2 4000 -"�- 4530 •I"eren 4530 5050 ''- XV �/ 5050 5580 t Axes Scat 2s o�wp�2.I[Goblin] 0/360 5580 _---' 6100 Rig:2s-071 .___` �_� 6100 7140 -�0J 3301 �`®� _ �+.�"►►• 30 7140 8180 /�®®'♦®�' �_; Off- 8180 ®® 9210 s!® P 4 m,- -0+�Wii7i►� / � 9210 10250 -,_�r_�-� "w1�%� 10250 11290 ��-._ -I 11290 12330 /if.��,�• "`�� -,- _ !`�f 12330 13370 -60/300 . �s8 .�--'=AIF 60 13370 14403 ®�ab�s Ii WO f 4 X80' �wi.r�'®12 j/��� Aft Joir aterimproyr 60 •` AvAre ei I �/�j/ 41 Illiin11.111/.J!�'/� -90/270 ' ._JL11110/ - 40! 90 ,;.1 �- A ®® 40 LISIF I, 50 �i�"ve 60 70 -120/240 80 120 90 100 110 120 : 130 -150/210 140 150 150 -180/180 2 5245327145 453 02120 -$- P ,3L2wp29IM.e3200,IVO a 0110000120 4e- 2 2s02w.7ae.1ITe,.•n.nvo -d- Plan 25.00 Nan 2.9.2so9.000Ir5.rlva a n. wPoe lM.g um020 9 a $ Ran an 2,01 2,03,06,Barn0 4- Plan 2,11.Plan 2,11 25-11rep06,Graat.laIVO P n. e:>2avp�nvnael vo 9 s a e v,,03,473300.vo J(- a n. n. s4<woSO 245102 $ P n. n 221030810.3xw 23120 j(- P n. n 2s-100225�nek0Penive $ 25-100222[05e2e93n91 $ #4n 3 s-os,oSM.,..lvo -I- Pan 2,12 Plan. ,12,0 S2]Ve $- P n. n &125025 1s2023OrulvO -jE- 530 20-02500 20.03 2S400SIS323nl20 Pia3.2210-0 25-12,0,20-1 0310IM203042120 $ Pun 2sn,Pun.2sn.25-nwpe51ef33amlv0 MD Azi TVD +N/-S +E/-W Dleg TFace V arget Lb bUU 28.00 0.00 28.00 0.00 0.00 0.00 0.00 25-10wp12 [Wobbegong]80009 3.00 3000 80000 454 262 850 3000 -5.06 600 - 790 1316.17 15 90 30.00 1308.00 77.78 44 8000.00 To 14402.75 1420.15 15.90 30.00 1408.00 102.46 59.15 0.00 0.00 -11 2.50 0.00 84.28 6.76 790 970 2241.47 28.75 90.05 2174.82 201.27 316.95 3.00 91.27 -276.45 739.05 28.75 90.05 4364.42 200.27 1518.42 0.00 0.00 -586.44 970 1160 844.72 85.00 196.00 6310.00 -1733.53 1935.19 3.00 106.40 1173.59 2S-Wobbegong 1.Heel 081215 PB_Opti 14:40,August 13 2015 874.72 85.00 196.00 6312.61 -1762.25 1926.95 0.00 0.00 1203.48 1160 1340 215.19 90.00 194.93 6327.48 -2089.98 1836.27 1.50 -12.05 1543.51 1402.06 90.00 194.93 6328 00 -8067.86 241.79 0.00 0.00 7730.37 1340 1530 SURVEY PROGRAM 1402.75 90.00 194.93 6328.00 -8068.52 241.62 1.00 -44.76 7731.05 2S-Wobbegong 6.Toe 081215 PB e0l77 00 150000 25r10wp12(YWbbegong]IPI4Nmsamxo 28A0 SOO.00 25-10*P12[W8bbegong]IPI*W -10155 1530 1710 50050 1500.00 25-107,12 IYWbbegong]IPIAINB-101 905.00 2105.92 25-107p121Wobb55052]IPId12B-10) IZ-SD 1710 1900 2705.93 7245.72 2S-107p12[Wobbegong](PIAIWH-10) 2705.93 9544.72 25-107,12[W8bbegong]IPId1V -1011-01(4.AZ-SC 7844.73 4402.72 25-107512 @Wbbegong]IPIAMB-10) 7844.72 14402.75 25-10wp12[Wobbegong]IPIAINBNOp-AKLAZ-SC 1900 2430 CASING DETAILS 2430 2950 TVD MD Name Size 2950 3480 2582.00 2705.93 10-3/4"x 13-1/2' 10-3/4 6310.00 7844.72 7-5/8"X 9-7/8" 7-5/8 6328.00 14402.75 4 1/2 x 6-3/4" 4-1/2 3480 4000 4000 ` 4530 4530 5050 I 14 erent ' 5050 5580 X& 1 Axes Scales, 0/360 5580 ""---------- 6100 6100 7140 -30/330 210 30 7140 8180 195 8180 9210 180 9210 10250 165 10250 11290 11158060 50 11290 12330 12330 13370 -60/r 60 13370 14403 10 ,;411‘69° -90/270 ,� 90 60 90 10 -120/240 120 120 235 t_50 165 180 195 -150/210 210 150 -180/180 -e- 2,02 2..e.,ITnres1411 V0 "�b' P n. . zsoa.µ517gn1v0 $ -$ a 702I[ ...VW, -Q- Plan n. 25-;w13PBISO8[M.420V0 $ 8 .23,01Vo -a- Flan Plan 507525,8am/b.,. -& P n µ7 Mmnklv0 -e- s a oa 22 x,.52901523,4,vo - P n. 242 soawp22[Lam%Ivo $ P n. n 101 2817-140 10224]02 P n. n 2s,s..i0511202Ponl V0 $ 2s,ow22[242040754]m $ P 47 oswµalrv004102 �- P .2S.12.w7000100 -e- P n. n. 23.15..W51302+k3134]V8 - 747.28.13705270022as.0515+205niv4 4. Pun25.15Pu525120125lalwµn04444025]V2 $ PMnz;-n.Penzsn.25v..µa]0l4 81V0 • • ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-10 Plan: 2S-10 Plan: 2S-10wp12 [Wobbegong] Error Ellipse Report 13 August, 2015 To calculate actual errol. ���� ; � F d ter Irkto V y 5, V 4;k2AVM fl • Schlumberger III Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-10 Project: Kuparuk River Unit TVD Reference: Plan: 120+28 @ 148.00usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: Plan: 120+28 @ 148.00usft(Doyon 141) Well: Plan:2S-10 North Reference: True Wellbore: Plan:2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10wp12[Wobbegong] Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States - -- _ -LIZ-. .21. X�~ Multiply by 2.58 Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 2S Pad Site Position: Northing: usft Latitude: From: Map Easting: usft Longitude: Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.14 ° Well Plan:2S-10 Well Position +N/-S 0.00 usft Northing: usfi Latitude: +E/-W 0.00 usft Easting: usfi Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: usfi Ground Level: 120.00 usft Wellbore Plan:2S-10 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 9/5/2015 18.60 80.87 57,489 Design 2S-10wp12[Wobbegong] Audit Notes: Version: Phase: PLAN Tie On Depth: 28.00 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 28.00 0.00 0.00 195.00 Survey Tool Program Date 8/13/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 28.00 500.00 2S-10wp12[Wobbegong](Plan:2S-10) INC+TREND Inclinometer+known azi trend 28.00 500.00 2S-10wp12[Wobbegong](Plan:2S-10) GYD-GC-SS Gyrodata gyro single shots 500.00 1,500.00 2S-10wp12[Wobbegong](Plan:2S-10) MWD MWD-Standard 500.00 2,705.93 2S-10wp12[Wobbegong](Plan:2S-10) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,705.93 4,205.93 2S-10wp12[Wobbegong](Plan:2S-10) MWD MWD-Standard 2,705.93 7,844.72 2S-10wp12[Wobbegong](Plan:2S-10) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7,844.72 9,344.72 2S-10wp12[Wobbegong](Plan:2S-10) MWD MWD-Standard 7,844.72 14,402.75 2S-10wp12[Wobbegong](Plan:2S-10) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 28.00 0.00 0.00 0.00 -120.00 0.00 0.00 0.00 100.00 1.15 0.00 0.00 -48.00 1.15 0.48 0.48 200.00 1.15 0.00 0.00 52.00 1.15 1.65 1.65 300.00 1.15 0.00 0.00 152.00 1.15 2.69 2.69 400.00 1.15 0.00 0.00 252.00 1.15 3.71 3.71 500.00 1.15 0.00 0.00 352.00 1.15 4.73 4.73 8/13/2015 2:55:46PM Page 2 COMPASS 5000.1 Build 74 • Schlumberger • Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-10 Project: Kuparuk River Unit TVD Reference: Plan: 120+28 @ 148.00usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: Plan: 120+28 @ 148.00usft(Doyon 141) Well: Plan:2S-10 North Reference: True Wellbore: Plan:2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10wp12[Wobbegong] Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 600.00 1.15 0.00 0.00 452.00 1.15 0.71 0.71 KOP:Start 1.5°/100'DLS,30°TF,for 200.09' 700.00 1.16 1.50 135.00 551.99 1.16 0.72 0.72 800.00 1.16 3.00 45.00 651.91 1.16 0.76 0.76 800.09 1.16 3.00 45.00 652.00 1.16 0.76 0.76 Start 2.5°/100'DLS,0°TF,for 516.08' 900.00 1.16 5.50 35.93 751.63 1.16 0.82 0.81 1,000.00 1.17 8.00 32.53 850.93 1.16 0.93 0.87 1,100.00 1.18 10.50 31.50 949.62 1.16 1.09 0.94 1,200.00 1.19 13.00 31.04 1,047.51 1.15 1.32 1.02 1,300.00 1.20 15.50 30.79 1,144.43 1.15 1.63 1.12 1,316.17 1.20 15.90 30.77 1,160.00 1.15 1.68 1.13 Hold for 103.98' 1,400.00 1.21 15.90 30.64 1,240.62 1.15 1.99 1.23 1,420.15 1.21 15.90 30.62 1,260.00 1.16 2.06 1.25 Start 3°/100'DLS,91.27°TF,for 821.32' 1,500.00 1.22 16.03 31.04 1,336.78 1.17 2.32 1.36 1,600.00 1.23 16.66 38.13 1,432.76 1.17 1.52 1.36 1,700.00 1.24 17.77 41.13 1,528.30 1.18 1.64 1.46 1,800.00 1.27 19.27 45.80 1,623.13 1.19 1.78 1.56 1,900.00 1.30 21.09 51.25 1,717.00 1.19 1.94 1.66 2,000.00 1.34 23.14 56.90 1,809.66 1.20 2.11 1.77 2,100.00 1.38 25.37 62.35 1,900.83 1.21 2.31 1.87 2,200.00 1.44 27.74 67.39 1,990.28 1.22 2.53 1.96 2,241.47 1.47 28.75 69.17 2,026.82 1.22 2.63 2.00 Hold for 2497.58' 2,300.00 1.47 28.75 71.66 2,078.13 1.23 2.79 2.06 2,400.00 1.48 28.75 74.88 2,165.80 1.26 3.07 2.17 2,500.00 1.49 28.75 77.30 2,253.47 1.30 3.36 2.27 2,600.00 1.50 28.75 79.18 2,341.13 1.34 3.66 2.39 2,700.00 1.51 28.75 80.68 2,428.80 1.38 3.96 2.50 2,705.93 1.53 28.75 81.18 2,434.00 1.39 4.26 2.56 10-3/4"x 13-1/2" 2,800.00 1.53 28.75 81.18 2,516.47 1.39 4.26 2.56 2,900.00 1.54 28.75 81.76 2,604.14 1.40 4.63 2.58 3,000.00 1.55 28.75 82.64 2,691.81 1.42 5.10 2.61 3,100.00 1.56 28.75 83.54 2,779.48 1.45 5.64 2.66 3,200.00 1.57 28.75 84.35 2,867.15 1.49 6.23 2.72 3,300.00 1.59 28.75 85.05 2,954.82 1.53 6.86 2.79 3,400.00 1.60 28.75 85.63 3,042.49 1.58 7.53 2.88 3,500.00 1.61 28.75 86.13 3,130.16 1.63 8.21 2.98 3,600.00 1.62 28.75 86.55 3,217.83 1.68 8.91 3.09 3,700.00 1.63 28.75 86.90 3,305.49 1.74 9.63 3.21 3,800.00 1.65 28.75 87.21 3,393.16 1.81 10.35 3.34 3,900.00 1.66 28.75 87.47 3,480.83 1.87 11.09 3.47 8/13/2015 2:55:46PM Page 3 COMPASS 5000.1 Build 74 • Schlumberger • Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-10 Project: Kuparuk River Unit TVD Reference: Plan: 120+28 @ 148.00usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: Plan: 120+28 @ 148.00usft(Doyon 141) Well: Plan:2S-10 North Reference: True Wellbore: Plan:2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10wp12[Wobbegong] Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 4,000.00 1.67 28.75 87.70 3,568.50 1.94 11.83 3.61 4,100.00 1.69 28.75 87.89 3,656.17 2.01 12.57 3.76 4,200.00 1.70 28.75 88.07 3,743.84 2.09 13.32 3.91 4,300.00 1.71 28.75 87.66 3,831.51 1.84 7.26 3.30 4,400.00 1.73 28.75 87.96 3,919.18 1.88 7.53 3.38 4,500.00 1.74 28.75 88.25 4,006.85 1.93 7.82 3.47 4,600.00 1.76 28.75 88.51 4,094.52 1.98 8.10 3.57 4,700.00 1.77 28.75 88.75 4,182.18 2.03 8.39 3.66 4,739.05 1.78 28.75 88.84 4,216.42 2.05 8.50 3.70 Start 3°/100'DLS,106.4°TF,for 3105.66' 4,800.00 1.84 28.29 88.91 4,269.98 2.08 8.62 3.78 4,900.00 2.02 27.75 89.02 4,358.28 2.13 8.66 4.03 5,000.00 2.28 27.50 89.25 4,446.90 2.17 8.62 4.40 5,100.00 2.59 27.55 89.63 4,535.60 2.22 8.50 4.85 5,200.00 2.93 27.90 90.14 4,624.14 2.27 8.31 5.35 5,300.00 3.30 28.54 90.79 4,712.27 2.31 8.06 5.83 5,400.00 3.69 29.45 91.58 4,799.75 2.36 7.79 6.28 5,500.00 4.10 30.60 92.48 4,886.35 2.41 7.52 6.66 5,600.00 4.51 31.97 93.51 4,971.82 2.46 7.27 6.97 5,700.00 4.93 33.54 94.66 5,055.93 2.51 7.06 7.20 5,800.00 5.34 35.26 95.93 5,138.45 2.56 6.89 7.36 5,900.00 5.76 37.13 97.31 5,219.16 2.61 6.77 7.46 6,000.00 6.17 39.13 98.80 5,297.82 2.67 6.72 7.49 6,100.00 6.58 41.22 100.42 5,374.24 2.73 6.71 7.47 6,200.00 6.99 43.40 102.16 5,448.19 2.80 6.76 7.41 6,300.00 7.38 45.66 104.03 5,519.48 2.87 6.87 7.30 6,400.00 7.77 47.98 106.05 5,587.90 2.94 7.02 7.16 6,500.00 8.15 50.36 108.22 5,653.28 3.02 7.21 7.00 6,600.00 8.52 52.79 110.57 5,715.43 3.11 7.44 6.81 6,700.00 8.87 55.25 113.11 5,774.19 3.20 7.70 6.60 6,800.00 9.21 57.75 115.86 5,829.38 3.30 8.00 6.37 6,900.00 9.54 60.28 118.84 5,880.87 3.41 8.33 6.14 7,000.00 9.85 62.83 122.06 5,928.50 3.52 8.68 5.91 7,100.00 10.14 65.40 125.52 5,972.16 3.64 9.05 5.67 7,200.00 10.42 68.00 129.20 6,011.71 3.76 9.45 5.45 7,300.00 10.69 70.61 133.08 6,047.05 3.89 9.87 5.24 7,400.00 10.93 73.23 137.07 6,078.08 4.02 10.30 5.06 7,500.00 11.16 75.86 141.11 6,104.73 4.16 10.75 4.91 7,600.00 11.37 78.51 145.11 6,126.91 4.30 11.21 4.80 7,700.00 11.56 81.16 148.97 6,144.56 4.44 11.68 4.74 7,800.00 11.74 83.81 152.63 6,157.64 4.59 12.16 4.73 7,844.72 11.81 85.00 154.18 6,162.00 4.66 12.37 4.75 Hold for 30'-7-5/8"X 9-7/8" 7,874.72 12.04 85.00 153.48 6,164.61 4.64 12.51 4.77 Start 1.5°/100'DLS,-12.05°TF,for 340.48' 8/13/2015 2:55:46PM Page 4 COMPASS 5000.1 Build 74 • Schlumberger • Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-10 Project: Kuparuk River Unit TVD Reference: Plan: 120+28 @ 148.00usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: Plan: 120+28 @ 148.00usft(Doyon 141) Well: Plan:2S-10 North Reference: True Wellbore: Plan:2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10wp12[Wobbegong] Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (0) (0) (usft) (usft) (usft) (usft) 7,900.00 12.04 85.37 153.96 6,166.74 4.64 12.62 4.76 8,000.00 12.03 86.84 156.08 6,173.53 4.66 13.15 4.73 8,100.00 12.02 88.31 158.43 6,177.77 4.72 13.83 4.74 8,200.00 11.99 89.77 160.85 6,179.45 4.80 14.64 4.80 8,215.19 11.99 90.00 161.22 6,179.48 4.81 14.77 4.81 Hold for 6186.87' 8,300.00 11.99 90.00 163.21 6,179.48 4.91 15.52 4.91 8,400.00 12.00 90.00 165.43 6,179.49 5.04 16.46 5.04 8,500.00 12.00 90.00 167.52 6,179.50 5.19 17.48 5.19 8,600.00 12.00 90.00 169.47 6,179.51 5.37 18.56 5.37 8,700.00 12.01 90.00 171.26 6,179.52 5.56 19.69 5.56 8,800.00 12.01 90.00 172.88 6,179.53 5.78 20.87 5.78 8,900.00 12.02 90.00 174.35 6,179.53 6.00 22.08 6.00 9,000.00 12.02 90.00 175.69 6,179.54 6.24 23.32 6.24 9,100.00 12.02 90.00 176.89 6,179.55 6.49 24.58 6.49 9,200.00 12.03 90.00 177.97 6,179.56 6.75 25.87 6.75 9,300.00 12.03 90.00 178.95 6,179.57 7.02 27.18 7.02 9,400.00 12.05 90.00 167.00 6,179.58 5.39 16.70 5.39 9,500.00 12.06 90.00 167.93 6,179.59 5.49 17.09 5.49 9,600.00 12.06 90.00 168.82 6,179.59 5.59 17.50 5.59 9,700.00 12.07 90.00 169.69 6,179.60 5.69 17.91 5.69 9,800.00 12.07 90.00 170.53 6,179.61 5.79 18.33 5.79 9,900.00 12.08 90.00 171.33 6,179.62 5.90 18.77 5.90 10,000.00 12.08 90.00 172.11 6,179.63 6.02 19.21 6.02 10,100.00 12.09 90.00 172.85 6,179.64 6.13 19.65 6.13 10,200.00 12.09 90.00 173.57 6,179.64 6.25 20.11 6.25 10,300.00 12.10 90.00 174.25 6,179.65 6.37 20.57 6.37 10,400.00 12.10 90.00 174.91 6,179.66 6.50 21.03 6.50 10,500.00 12.11 90.00 175.53 6,179.67 6.62 21.50 6.62 10,600.00 12.11 90.00 176.13 6,179.68 6.75 21.98 6.75 10,700.00 12.12 90.00 176.70 6,179.69 6.88 22.46 6.88 10,800.00 12.12 90.00 177.24 6,179.70 7.02 22.95 7.02 10,900.00 12.13 90.00 177.76 6,179.70 7.15 23.44 7.15 11,000.00 12.13 90.00 178.26 6,179.71 7.29 23.93 7.29 11,100.00 12.14 90.00 178.74 6,179.72 7.43 24.43 7.43 11,200.00 12.14 90.00 179.19 6,179.73 7.57 24.93 7.57 11,300.00 12.15 90.00 179.62 6,179.74 7.71 25.44 7.71 11,400.00 12.15 90.00 0.04 6,179.75 7.86 25.94 7.86 11,500.00 12.16 90.00 0.43 6,179.75 8.00 26.45 8.00 11,600.00 12.16 90.00 0.81 6,179.76 8.15 26.97 8.15 11,700.00 12.17 90.00 1.17 6,179.77 8.30 27.48 8.30 11,800.00 12.17 90.00 1.52 6,179.78 8.45 28.00 8.45 11,900.00 12.18 90.00 1.85 6,179.79 8.60 28.52 8.60 12,000.00 12.18 90.00 2.17 6,179.80 8.75 29.05 8.75 8/13/2015 2:55:46PM Page 5 COMPASS 5000.1 Build 74 • Schlumberger • Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-10 Project: Kuparuk River Unit TVD Reference: Plan: 120+28 @ 148.00usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: Plan: 120+28 @ 148.00usft(Doyon 141) Well: Plan:2S-10 North Reference: True Wellbore: Plan:2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10wp12[Wobbegong] Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 12,100.00 12.19 90.00 2.47 6,179.81 8.90 29.57 8.90 12,200.00 12.20 90.00 2.77 6,179.81 9.05 30.10 9.05 12,300.00 12.20 90.00 3.05 6,179.82 9.21 30.63 9.21 12,400.00 12.21 90.00 3.32 6,179.83 9.36 31.16 9.36 12,500.00 12.21 90.00 3.57 6,179.84 9.52 31.69 9.52 12,600.00 12.22 90.00 3.82 6,179.85 9.68 32.22 9.68 12,700.00 12.22 90.00 4.06 6,179.86 9.83 32.76 9.83 12,800.00 12.23 90.00 4.29 6,179.86 9.99 33.30 9.99 12,900.00 12.24 90.00 4.51 6,179.87 10.15 33.84 10.15 13,000.00 12.24 90.00 4.73 6,179.88 10.31 34.38 10.31 13,100.00 12.25 90.00 4.93 6,179.89 10.47 34.92 10.47 13,200.00 12.25 90.00 5.13 6,179.90 10.63 35.46 10.63 13,300.00 12.26 90.00 5.32 6,179.91 10.80 36.00 10.80 13,400.00 12.27 90.00 5.50 6,179.92 10.96 36.55 10.96 13,500.00 12.27 90.00 5.68 6,179.92 11.12 37.09 11.12 13,600.00 12.28 90.00 5.85 6,179.93 11.28 37.64 11.28 13,700.00 12.29 90.00 6.02 6,179.94 11.45 38.19 11.45 13,800.00 12.29 90.00 6.18 6,179.95 11.61 38.73 11.61 13,900.00 12.30 90.00 6.33 6,179.96 11.78 39.28 11.78 14,000.00 12.31 90.00 6.48 6,179.97 11.94 39.83 11.94 14,100.00 12.31 90.00 6.63 6,179.97 12.11 40.38 12.11 14,200.00 12.32 90.00 6.77 6,179.98 12.27 40.94 12.27 14,300.00 12.32 90.00 6.91 6,179.99 12.44 41.49 12.44 14,400.00 12.33 90.00 7.04 6,180.00 12.60 42.04 12.60 14,402.06 12.33 90.00 7.04 6,180.00 12.61 42.05 12.61 Start 1°/100'DLS,-44.76°TF,for 0.68' 14,402.75 12.33 90.00 7.04 6,180.00 12.61 42.05 12.61 TD:14402.75'MD,6328'TVD 8/13/2015 2:55:46PM Page 6 COMPASS 5000.1 Build 74 • Schlumberger • Error Ellipse Report Company: ConocoPhillips(Alaska) Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-10 Project: Kuparuk River Unit TVD Reference: Plan: 120+28 @ 148.00usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: Plan: 120+28 @ 148.00usft(Doyon 141) Well: Plan:2S-10 North Reference: True Wellbore: Plan:2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10wp12[Wobbegong] Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") C') 2,705.93 2,582.00 10-3/4"x 13-1/2" 10-3/4 13-1/2 14,402.75 6,328.00 4 1/2"x 6-3/4" 4-1/2 6-3/4 7,844.72 6,310.00 7-5/8"X 9-7/8" 7-5/8 9-7/8 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (0) (0) 6,876.28 6,017.00 Top HRZ(K-2) 7,823.01 6,308.00 A4 2,637.49 2,522.00 Base W Sak 5,282.63 4,845.00 C-37 5,435.95 4,979.00 Growler 7,752.49 6,300.00 Kup C 1,380.64 1,370.00 Base Permafrost 4,615.38 4,256.00 C-50 368.00 368.00 K-15 Marker 7,356.11 6,213.00 L Kalubik(K-1) 1,882.87 1,849.00 Top W Sak 7,891.00 6,314.00 A4 Target Top 3,085.76 2,915.00 C-80 6,113.01 5,532.00 Top Cairn 280.00 280.00 Top T-3 Sand 7,128.87 6,132.00 U Kalubik(Base HRZ) 4,969.67 4,568.00 C-40 6,256.77 5,637.00 Top Bermuda 7,785.24 6,304.00 A5 14,402.41 6,328.00 A4 Target Base 6,382.29 5,724.00 Base Bermuda Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 600.00 600.00 0.00 0.00 KOP:Start 1.5°/100'DLS,30°TF,for 200.09' 800.09 800.00 4.54 2.62 Start 2.5°/100'DLS,0°TF,for 516.08' 1,316.17 1,308.00 77.78 44.91 Hold for 103.98' 1,420.15 1,408.00 102.46 59.15 Start 3°/100'DLS,91.27°TF,for 821.32' 2,241.47 2,174.82 201.27 316.95 Hold for 2497.58' 4,739.05 4,364.42 200.27 1,518.42 Start 3°/100'DLS, 106.4°TF,for 3105.66' 7,844.72 6,310.00 -1,733.53 1,935.19 Hold for 30' 7,874.72 6,312.61 -1,762.25 1,926.95 Start 1.5°/100'DLS,-12.05°TF,for 340.48' 8,215.19 6,327.48 -2,089.98 1,836.27 Hold for 6186.87' 14,402.06 6,328.00 -8,067.86 241.79 Start 1°/100'DLS,-44.76°TF,for 0.68' 14,402.75 6,328.00 -8,068.52 241.62 TD: 14402.75'MD,6328'TVD Checked By: Approved By: Date: 8/13/2015 2:55:46PM Page 7 COMPASS 5000.1 Build 74 Pool Report • 4111 15:36,August 132015 2S 10wp12 [Wobbegong] Name WELLBORE TARGET DETAILS(MAPCO-ORDINATES) TVD Shape 2S-Wobbegong 1.Heel 081215 PB 631000 Circle(Radius:100.00) Quarter Mile View 2S-Wabbegong 1 Heel 081215 PB Circle 631000 Circle(Radius:1320.00) 2S-Wobbegeng 2.T 081215 PB_Cicla 6328.00 Circle(Rados:132000] 2SWabbegorg 8.T 081215 PB 8328.00 Circle(Rados:100.00) 2S.14WP07 --- inn? i., -. . .T.. ........ 254........ 28 'A ............ s'O7Wdf 250SN'PO6 `------ . 2000 o'eJ e`erh. o.l)n INatSel l 'Itej J • 0WPoS.1 • • • • • • • r �hresherJ III 2S-13L2WP08[ / . . `i, • 0 ______. ........ ;' n; ...i 3L1wp1Q-[Me.. ..... _... ...._.-.. _ ........_ -....... 2S•13P61wpI' - ' .. - ������• • �R�• 9 2517 /C1,01 I I 10011 / i i mAd10/1211 A ''': pwr • c\I .•• .•• .•• .•• . .•• 4.2 .• 000 • 1111 -ir •�� •• 1 :_c_4000_ ! ...._.O1 Z • 25.17w \ PO6[11y.., e6000 • • • • O • • I • -0:/000 ..._.__.......... -ZS.17[84/I ..-.-....._ i..... ._.-.-.-. __..._..- ...-.._- -......-- • • 2S'OS 2S 2S.03WP06(garhbo wA07!Hammer -a, 6,,, Wnos[Sa/moryj 28.1 pW p12 nyob oI • 25.16 25.15 I 'Ire be90ngj - I I - R900rualicoraz)4`�f 'elicou,. 2000 0 2000 4001 6000 8000 10000 West(-)/East(+) (2000 usft/in) • A 2S-10wp12 [Wobbegong] 3-D View / F Plan:25-11,Plan'2S-11L1,2$-11 L1wp06[Great Whi' Plan:25-04,Plan:2S-04,25-0' •09[ • PI< Plan:2S-13,Plan:2S-13L2,2$-i3L2wp09[Megalod Plan:2S-13,Plan:2S-13PB1,2$-13PB1wp08[Megalod g 5-07 g 5-07 9 S 0 ... • R 2 Ri:2 RI:2 • ^--., Shark Tooth#1 Shark Tooth#i Shark Tooth .......................-- V _ • Plan:25-03,Plan:2S-03,20-03wp06[Rambo • Plan.2S-10,Plan.25-10,2S-1Owp12[Wobbego • • • • • 2S-10wp12 [Wobbegong] 3-D View J. N ....N / ........................ . , ___„_._ Rig:2S-07,Rig:25-07,R :2S-( 0.4 Shark Tooth#1,Shark Tooth#1,Shark Tooth • • 2S-1 owp12 [Wobbegong] 3-D View Plan:2510,Plan:2S-10,2S-10wp12[Wobbego ...................... • • L..... 2S-10wp12 Surface Location EZI. CPAI Coordinate Converter "`' , From:_ __.___ __ To: Datum: JNAD83 J Region: lalaska J Datum: 1NAD27 J Region: lalaska J C Latitude/Longitude 'Decimal Degrees J C Latitude/Longitude 'Decimal Degrees J C UTM Zone: 1 r South r UTM Zone: (True E South a State Plane Zone: 1.-4---E, Units: Fl—ii—E. C State Plane Zone: 4 ., Units: us-ft C Legal Description(NAD27 only) C Legal Description(NAD27 only) Starting Coordinates: Ending Coordinates: X 11621077.45 X: 1 481044128186967 Y: 15929729.31 Y: 15929979.7234431 E 11 .................Transform._........... Quit I Help I 2S-10wp12 Intermediate Casing .. CPAI Coordinate Converter i ---- X From: To: �{ — Datum: jNAD83 J Region: lalaska j Datum: INAD27 j# Region: lalaska J C Latitude/Lorr ude 'Decimal Degrees J _ C Latitude/Longitude 'Decimal Degrees ±i r UTM Zone: 1 r South C UTM Zone: 'True r South j aState Plane Zone: 14 J Wits: us•ft a State Plane Zone: 14 . Units: jus ft J I C Legal Description(NAD27 only) C Legal Description(NAD27 only) Starting Coordinates: _ _ ._. Ending Coordinates: X 11623008 X: 1482974.695906264 Y: 15927991 ? Y: 15928241.42385364 i I Transform I Quit 1 Heti 1 • • ( 2S-10wpl2 TD rzl- CPAI Coordinate Cony, , — `1 0 X ...From To: _ € Datum: JNAD83 +J Regi: Jalaska .J I Datum: NAD27 Region: Iataska r Latitude/Longitude Decimal Degrees jj r Latitude/Longitude Decimal Degrees • a r UTM Zone: 1 r South C UTM Zone:'True r South C State Plane Zone: 4 J Units: Fit--E a State Plane Zone: 4 Units: us•ft C Legal Description(NAD27 only) r Legal Description(NAD27 only) G i Start�rg Caordines: r-E riling Caxriinates:__.._. _... X: 11621298.37 X: 1 481264.934859187 � I Y: 15921661 Y: 1 5921911.58416229 J Transform i Quit Help • • 2S-10wp12 Surface Location �,. CPAI Coordinate Converter 9 From To: Datum: NAD83 +1 Region: I alaska A Datum: JNAD27 j Region: alaska (- Latitude/Longitude 'Decimal Degrees zi C Latitude/Longitude jDecinal Degrees ? C UTM Zone: r South i C UTM Zone:ITrue r South � s a State Plane Zone:14-73, Units: 1us-ft C State Plane Zone: 4 Units: us-it . C Legal Description 1NAD 27 c,r l'tl t: Legal Description(NA027 only) Starting Coordinates: .___ Legal Description X: 11621077.45 Townshp: 1010 INA Range: 1008 IE Y: 15929729.31 Meridian: tU J section:117 151-L--"E 13068.6061 'FEL A 11526.1734 Transform jl Quit I Help 2S-10wp12 Intermediate Casing Q CPAI Coordinate Converter � � From __ ___ _1 To I Datum: 1NAD83 j Region: 1alaska J ! Datum: JNAD27 _II Region: Ialaska A C Latitude/Longitude Decimal Degrees A. C Latitude/Longitude 'Decimal Degrees C UTM Zone:I r South 1 C UTM Zone: 1True r South E � a State Plane Zone: 4 - units: us.ft C State Plane Zone: 4 Units: us-ft C Legal Description tNA i2 F onlyl t: Legal Description(NAD27 only) Starting Coordinates: — Legal Description X 1623008 Township: 010 IN J Range: 1008 E Y: 5927991 �( i Meridian: lu ,l SectiatJ16 ( FNL14802.4666 FEL 14876.2483 v1--- _Tiansfam __-1) Quit 1 Help I • • 2S-10wp12 TD rfj CPAI Coordinate Con From: ; .. To: Oaten: 'HAD 83 j Region: jalaska J Datum: 1N4027 .j Region: lalaska =.l C Latitude/Longitude 'Decimal Degrees J C`' Latitude/Longitude 'Decimal Degrees .a C UTM Zone: I r South r- UTM Zone: 'True r South I � ( State Plane Zone: IT—E. Units: lus-ft J C State Plane Zone: 14 Units: jus-it • C Legal Description INAD27 or-41 C: Legal Description(NAD27 only) Starting Coordinates: i Legal Description X 1621298.37 Township: 1010 N + Range: 1008 E Y: 15921661 Meridian: lu J Section:123 FNL J 1576.99240 FEL J j1309.2915 a , { I _...Transform..__ _ Quit I Help As - built 411111 REV DATE BY CK APP • DESCRIPTION REV DATEAPP BY DESCRIPTION 1 5/28/15 SZ JAH Created Drawing Per K140173ACS NOTES: 3 10 O ,6 :),5 V)14 i Is le i ,/ , � ce it _ `s DS2A II i...._ _ DS1C i a_y WS 14 71,7l\ — 1. BASIS OF LOCATION AND ELEVATION IS DS2S T4 .'� a'y, i? \22 { 23 _‘�►- 20 MONUMENTATION PER LOUNSBURY & ASSOC. \ r, L '• CPF2 I 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, 24. 30 �� �� �� ��� �� �' �� et; (t5 (( ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES �' V =�szH 4k. 'D t'. ARE NAD 27. 36 } i t1 '',(,34-., �# ,5 Y �s K !,. py �'`�e 'a DS2G tT11N ..3. ELEVATIONS ARE B.P.M.S.L. `' s,,o2 ma, �,, r1oN ,PN i` + e 3 ,� , IX 6jrs. , s 11--3-'''`'°'‘ �'`'°'�.rtp� i ° } m a DS2K . `'? 4. ALL CONDUCTORS ARE LOCATED WITHIN PROTRACTED q 1 SECTION 17, TOWNSHIP 10 NORTH, RANGE 8 EAST, P .7. pea" t1 ° ,, i0 `: It ,Y .1 v°' 10 ' UMIAT MERIDIAN. 19 .0 S2S `Cis 54 13 { u '' C p flS } 5. DATES OF SURVEY: 5-2 THRU 5-27-15 FIELD BOOKS L15-28, L15-29, L15-32, L15-35 ? I. ., .0 r 6. ALL DISTANCES SHOWN ARE TRUE. ' 1 • PROJECT AC TION 111 `I N est `�,:.3° ( �>}�� m. ,{ 27 0. .'12:0--, ss 3s 29 /}3. ' ss '3114, . si`:t• �1k? �,34 f'.3s . ?3, 32 j 33 3. VICINITY MAP NTS 3D. ."P. DS2S --\ r 6 4 ® o 12 ,10 ° ° * * 0 3 21 14 0 � ° 11 9 7 5 13 i LEGEND ® AS—BUILT CONDUCTOR LOCATION \ 17 16 20 21 GRAPHIC SCALE 0100 200 400 I ..,;. LOUNSBURY SEE PAGE 2 OF 2 FOR LOCATIONS & ASSOCIATES, INC. 1 inch = 200 ft. SURVEYORS ENGINEERS PLANNERS 441, *.- , AREA:2S MODULE: XXXX UNIT: D2 ConocoPhillips DS2S WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD FILE NO. DRAWING NO. PART: REV: LK6219d24 5/28/15 CEA—D2SX-6219D24 1 OF 2 1 REV DATE BY CK APP DESCRIPTION REV DATE BY APP DESCRIPTION 1 5/28/15 SZ JAH Created rowing Per K140173ACS CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 17, T. 10 N., R. 8 E., UMIAT MERIDIAN Well NAD 27 NAD 27 Section Elev. No. ASP Coordinates Geographic Coordinates Offset. Y X Lat. Long. F.S.L F.E.L. 0.0. PAD 1 5,930,036.15 481,309.02 70' 13' 12.058" 150' 09' 02.839" 2268' 1261' 112.0' 120.0' 2 5,930,029.92 481,279.68 70' 13' 11.996" 150' 09' 03.690" 2262' 1291' 112.4' 120.0' 3 5,930,023.62 481,250.32 70' 13' 11.933" 150' 09' 04.543" 2255' 1320' 112.1' 120.0' 4 5,930,017.59 481,221.00 70' 13' 11.873" 150' 09' 05.394" 2249' 1349' 112.0' 120.0' 5 5,930,010.88 481,191.79 70' 13' 11.806" 150' 09' 06.242" 2243' 1378' 111.8' 120.0' 6 5,930,004.80 481,162.27 70' 13' 11.746" 150' 09' 07.098" 2236' 1408' 111.5' 120.0' 7 5,929,998.58 481,133.41 70' 13' 11.684" 150' 09' 07.936" 2230' 1437' 111.4' 120.0' 8 5,929,992.42 481,103.50 70' 13' 11.622" 150' 09' 08.804" 2224' 1467' 111.1' 120.0' 9 5,929,986.08 481,074.22 70' 13' 11.559" 150' 09' 09.654" 2217' 1496' 111.0' 120.0' 10 5,929,979.72 481,044.13 70' 13' 11.496" 150' 09' 10.528" 2211' 1526' 111.1' 120.0' 11 5,929,973.68 481,015.40 70' 13' 11.436" 150' 09' 11.362" 2205' 1555' 111.1' 120.0' 12 5,929,968.02 480,986.10 70' 13' 11.380" 150' 09' 12.212" 2199' 1584' 110.9' 120.0' 13 5,929,961.45 480,956.55 70' 13' 11.314" 150' 09' 13.070" 2192' 1614' 110.6' 120.0' 14 5,929,955.02 480,927.39 70' 13' 11.250" 150' 09' 13.920" 2186' 1643' 110.5' 120.0' +.+•PSE OF q.�44. � ••.,��o SURVEYORS CERTIFICATE A.rit '/ 49th # I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND j LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ' , /' ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY A "A �;JEREMIAH F. CORNELL ��/ DONE BY ME OR UNDER MY DIRECT SUPERVISION AND ♦a 's ES-12663 :' �t THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT � Q'•.,,• .°�JQ� AS OF MAY 27, 2015. `. F� 04,c''*;�O ,�� LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS AREA:2S MODULE: XXXX UNIT: D2 ConocoPhillips DS2S WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD FILE NO. DRAWING NO. PART: REV: LK6219d24 5/28/15 CEA-D2SX-6219D24 2 OF 2 1 2S-1 o Schlumberger CemCADE* Preliminary Job Design 10-3/4" Surface Casing (V3) Preliminary Job Design based on limited input data.For estimate purposes only. Volume Calculations and Cement Systems Rig: Doyon 141 Volumes are based on 200% excess in the permafrost and 50% excess below the Location: Kuparuk permafrost. The top of the tail slurry is designed to be at 2206' MD. Client:CPAI Revision Date:August 14, 2015 Prepared by: Jenna Houston Location:Anchorage, AK Lead Slurry Minimum pump time: -230 min. (pump time plus 120 min.) Phone: (907)263-4207 DeepCRETE @ 11 ppg-1.91 ft3/sk Mobile: (907)223-8916 email:jhouston2@slb.com 1.339 ft3/ft x(110') x 1.00 (no excess) = 148 ft3 0.3637 ft3/ft x(1381 -110') x 3.00 (200% excess) = 1387 ft3 < TOC at Surface 0.3637 ft3/ft x(2206-1381)x 1.50(50% excess) = 451 ft3 148 ft3+ 1387 ft3+451 ft3= 1986 ft3 1986 ft3/1.91 ft3/sk= 1040 sks (1050 sks) Please have extra DeepCRETE on location for top out. Tail Slurry Minimum pump time: -180 min. (pump time plus 120 min.) Previous Csg. DeepCRETE @ 12 ppg -1.63 ft3/sk < 20", 106.5#casing at 110'MD 0.3637 ft3/ft x(2706-2206)x 1.50 (50% excess)= 273 ft3 I 0.5400 ft3/ft x 80' (Shoe Joint) = 44 ft3 273 ft3+44 ft3= 317ft3 317 ft3/ 1.63 ft3/sk= 195 sks Round up to 205 sks BHST=64°F, Estimated BHCT= 76°F. (Based on 2.1°F/100 ft. from surface) < Base of Permafrost at PUMP SCHEDULE 1381'MD(-1,370'TVD) Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min Time (bbl) ) (min) C W 100 7.00 100.0 14.3 14.3 MUDPUSH II 7.00 100.0 14.3 28.6 Pause 0.00 0.0 5.0 33.6 < Top of Tail at 2,206'MD 11 ppg DeepCRETE 7.00 353.4 50.5 84.1 Surface Tail 7.00 56.3 8.0 92.1 DeepCRETE Slurry Pause 0.00 0.0 5.0 97.1 Fresh Water 7.00 10.0 1.4 98.5 Pause 0.00 0.0 5.0 103.5 Mud 8.00 232.6 29.1 132.6 Mud 3.00 10.0 3.3 135.9 < 10-3/4",45.5#casing I in 13.5"OH MUD REMOVAL Expected Mud Properties: 9.5 ppg, Pv<20, Tv<20 I TD at 2,706'MD Spacer Properties: 10.5 ppg MudPUSH*II, Pv 17-21, TY 20-25 (2,582'TVD) Centralizers: As per CPAi program. *Mark of Schlumberger s • 2S-10 Schlumberger CemCADE* Preliminary Job Design 7-5/8" Intermediate Casing Rig: Doyon 141 1st Stage (V2) Location: Kuparuk Client: CPAI Revision Date:August 14,2015 Volume Calculations and Cement Systems Prepared by:Jenna Houston Volumes are based on 20% excess. The top of the 1si stage tail slurry is designed to be Location:Anchorage, AK Phone: (907)263-4207 at 6,113' MD. Mobile: (907)223-8916 email:jhouston2@slb.com Tail Slurry Minimum pump time: -240 min. (pump time plus 120 min.) 15.8 ppg GASBLOK* +adds- 1.17 ft3/sk 0.2148 ft3/ft x(7845'-6113')x 1.20 (20% excess) = 447 ft3 0.2578 ft3/ft x 80' (Shoe Joint)= 21 ft3 447 ft3+21 ft3= 468 ft3 468 ft3/1.17 ft3/sk= 400 sks Round up to 410 sks Previous Csg. < 10-3/4",45.5.#casing BHST= 153°F, Estimated BHCT= 106°F. at 2,706'MD (BHST calculated using a gradient of-2.1°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) MUDPUSH II 5.00 50.0 10.0 10.0 Pause 0.00 0.0 5.0 15.0 15.8 ppg GASBLOK* 5.00 83.2 16.6 31.6 < Stage tool at 5,283'MD Slurry Pause 0.00 0.0 5.0 36.6 Fresh Water 5.00 10.0 2.0 38.6 Pause 0.00 0.0 5.0 43.6 Mud 5.00 310.0 62.0 105.6 Mud 2.50 26.5 10.6 116.2 Mud 1.50 10.0 6.7 122.9 < Top of Cement at -6,113 MD MUD REMOVAL Expected Mud Properties:-11.1 ppg, Pv<20, Yield Point<25. Spacer Properties: 12.0 ppg MudPUSH* II, Pv=20-24, Yield Point=20-30 < 7-5/8",29.7#casing in 9-7/8"OH Centralizers: As per program TD at-7,845 MD (6,310'TVD) *Mark of Schlumberger • • 2S-10 Schlumberger CemCADE* Preliminary Job Design 7-5/8" Intermediate Casing Rig: Doyon 141 2nd Stage (V2) Location: Kuparuk Client: CPAI Revision Date: August 14, 2015 Volume Calculations and Cement Systems Prepared by:Jenna Houston Volumes are based on 20% excess. The top of the 2nd stage tail slurry is designed to be Location:Anchorage, AK Phone: (907)263-4207 at-4,783 MD, 500' above the C37. Mobile: (907)223-8916 email:jhouston2@slb.com Tail Slurry Minimum pump time: -200 min. (pump time plus 120 min.) 15.8 ppg Class G +GASBLOK*+ adds- 1.17 ft3/sk 0.2148 ft3/ft x(5283'-4783')x 1.20 (20% excess) = 129 ft3 129 ft3= 129 ft3 129 ft3/ 1.17 ft3/sk = 111 sks Previous Csg. Round up to 121 sks < 10-3/4",45.5.#casing at 2,706'MD BHST= 117°F, Estimated BHCT=79°F. (BHST calculated using a gradient of-2.1°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) MUDPUSH II 5.00 40.0 8.0 8.0 15.8 ppg GASBLOK* 5.00 22.9 4.6 12.6 Slurry Pause 0.00 0.0 5.0 17.6 Fresh Water 5.00 10.0 2.0 19.6 Pause 0.00 0.0 5.0 24.6 Mud 5.00 222.6 44.5 69.1 Mud 3.00 10.0 3.3 72.4 < Top of Cement at MUD REMOVAL 4,783 MD Expected Mud Properties: -11.1 ppg, Pv<20, Yield Point< 25. Spacer Properties: 12.0 ppg MudPUSH* II, Pv=20-24, Yield Point=20-30 Centralizers: As per program < 7-5/8",29.7#casing in 9-7/8"OH Stage tool at 5,283' MD (4,845'TVD) *Mark of Schlumberger • • Bettis, Patricia K (DOA) From: Bettis, Patricia K(DOA) Sent: Monday, August 17, 2015 3:11 PM To: Sandra.D.Lemke@conocophillips.com Subject: API number for 2S-10? Sandra, The Beechey Point quad code (029)for the KRU 2S-10 well was an error. Thank Allison for catching it. With the submittal of the revised application for KRU 2S-10, I have assigned a new API number as follows: 50-103- 20717-00-00. The Permit to Drill Number will remain the same; that is 215-110. Please correct ConocoPhillips database and records to reflect the new API number for KRU 2S-10. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettisCalaska.gov. From: Lemke, Sandra D [mailto:Sandra.D.Lemke@conocophillips.com] Sent: Friday, August 14, 2015 4:00 PM To: Guhl, Meredith D (DOA); Davies, Stephen F (DOA) Cc: Downey, Allison Subject: FW: API number for 2S-10? Can you respond to the request for review of API number assigned to 2S-10 by AOGCC. Thanks Much. 1 ti • • Sandra D. Lemke Alaska IT Staff Associate-Data ConocoPhillips Alaska 700 G Street,AT01412 Anchorage,AK 99501 (907)265-6947 phone, (907)440-4512(cell) Sandra.D.Lemke@COP.com From: Lemke, Sandra D Sent: Monday, August 03, 2015 11:44 AM To: Downey, Allison Subject: RE: API number for 2S-10? Sure—will do From: Downey, Allison Sent: Monday, August 03, 2015 11:18 AM To: Lemke, Sandra D Subject: API number for 2S-10? Hi Sandy, I noticed that the API number for 2S-10 (50-029-23546-00) has the Beechey Point pseudo county code (029)while the other DS-2S wells have the Harrison Bay code (103). Looking at the other Kuparuk wells, it seems like all the DS-2S wells should have the Harrison Bay code (103). Drill sites 2A, 2H, 2K, 2L, 2M, 2N, 2P and 2T all have 103. DS-2S is west of 2A, 2H, 2K, 2M, and 2T so it seems like it should be 103 also. Would you please check if the AOGCC assigned the correct API number for 2S-10? Thanks, Allison Allison Downey Technical Data Management ConocoPhillips Alaska, Inc. 907-263-4299 2 1110 Bettis, Patricia K (DOA) From: Davies, Stephen F (DOA) Sent: Monday, August 17, 2015 3:06 PM To: Bettis, Patricia K (DOA) Subject: FW:API number for 2S-10? From: Lemke, Sandra D [mailto:Sandra.D.Lemke@conocophillips.com] Sent: Friday, August 14, 2015 4:00 PM To: Guhl, Meredith D (DOA); Davies, Stephen F (DOA) Cc: Downey, Allison Subject: FW: API number for 2S-10? Can you respond to the request for review of API number assigned to 2S-10 by AOGCC. Thanks Much. Sandra D. Lemke Alaska IT Staff Associate-Data ConocoPhiuips Alaska 700 G Street,AT01412 Anchorage,AK 99501 (907)265-6947 phone, (907)440-4512(cell) Sandra.D.Lemke@COP.com From: Lemke, Sandra D Sent: Monday, August 03, 2015 11:44 AM To: Downey, Allison Subject: RE: API number for 2S-10? Sure—will do From: Downey, Allison Sent: Monday, August 03, 2015 11:18 AM To: Lemke, Sandra D Subject: API number for 2S-10? Hi Sandy, I noticed that the API number for 2S-10 (50-029-23546-00) has the Beechey Point pseudo county code (029) while the other DS-2S wells have the Harrison Bay code (103). Looking at the other Kuparuk wells, it seems like all the DS-2S wells should have the Harrison Bay code (103). 1 i • Drill sites 2A, 2H, 2K, 2L, 2M, 2N, 2P and 2T all have 103. DS-2S is west of 2A, 2H, 2K, 2M, and 2T so it seems like it should be 103 also. Would you please check if the AOGCC assigned the correct API number for 2S-10? Thanks, Allison Allison Downey Technical Data Management ConocoPhillips Alaska, Inc. 907-263-4299 2 S 0 TRANSMITTAL LETTER CHECKLIST WELL NAME: KFW- Q -/D PTD: c2 15-11 b Development Service Exploratory Stratigraphic Test Non-Conventional FIELD: Kt b.iiir POOL: A.fcilLR Ai'V I / (AA RiVir Oma/ 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 Lname of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are / also required for this well: Well Logging ✓/ Requirements ✓ Per Statute AS 31.05.030 d 2 B and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 • 0 „ , N , , , , , , , ) , . . , , „ . „ as n , N N a) 6 . , 3 a)• O, E, (I) a) cr). O a)' w co �' W Ce W -c O' ° ° ° W a) cN co CrS °j n O 0 c. m. U) a c c a,' ° o a) o o ill ) •. To co >, a O) N. U) 3. . •Q, os o a) 3. as, > a E E 'c a) 0 W O, D: �� O �. �, N' 0. W' c 6 d, c. ' N'. O ° oo' w H�N CZ 0 E' COQ a). a d CO O. 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R.�' •§' c C' co a' ami' °) w ui ° 3' co 2,f0' o �' �' �� 6 '--a J c ,_' w v - as `a). a`) E'. E, c 3 n c. 'tt I-; ►- F 'a aa)j a) > �' d 0. 'o', 0' 0,, ,_ N ra c as Q4 0 0, a0i, c °' °�' °� o •° a a a) a) co ° — ,_' p, o z z' M as v o -d `o c O, O t ° ° a) a) as, a). a). o, � z, a � � � CO�' �' OQa, �, v �' ¢ � v � vvvv ¢ ~ ¢ � om, mv �' �' a' o, � � v -},�. tiiI O t` O ,- N M v ID CO CO 0) 0 N COv U) (0 f` CO 0) 0 N CO v (n CO r` CO 0) v rr 2 E — CV O v (o co n CO O) N N N N N N N N N N M CO M CO M M M M M M U O U H )n n 'n as 2 o c :: No 0 cc,) °: N g o Ix o 0 0 p) 0 co 0 r o UN) J N •2 a)aa)j Et--,_,J Xt • a m c a � o am OZ: . w o E aY a) p_ H O 0. Y as a W Q >c � as OF T4F 0 „w\�����j��s� THE STATE Alaska Oil and Gas ` -;s of Conservation Commission • '-, � LASKA u _-_ 333 West Seventh Avenue tgr \Tti: GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ir Main: 907.279.1433 OA, ALASv. Fax: 907.276.7542 www.aogcc.alaska.gov G. L. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2S-10 ConocoPhillips Alaska, Inc. Permit No: 215-110 Surface Location: 2211' FSL, 1526' FEL, SEC. 17, T1ON, R8E M Bottomhole Location: 571' FNL, 1309' FEL, SEC. 29, T1ON, .' 8E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the abo e referenced service well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 • • ' 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. This permit to drill does not exempt you fro iitaining additional permits or an approval required by law from other governmental agen•' and does not authorize conducting drilling operations until all other required permits an,. approvals have been issued. In addition, the AOGCC reserves the right to withdraw the pviit in the event it was erroneously issued. Operations must be conducted in accore':'' e with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless 'e 44 ' CC specifically authorizes a variance. Failure to comply with an applicable provi 'en/If AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC :.4 er, or the terms and conditions of this permit may result in the revocation or suspension of the.sermit. Sincerely, Cathy P. oerster Chair DATED this /3 day .f July, 2015. STATE OF ALASKA 111 1 I . ALASKA OIL AND GAS CONSERVATION COMMISSION ��)� 3 ZU I PERMIT TO DRILL 20 AAC 25.005 1a.Type of Work: 1 b.Proposed Well Class: Development-Oil ❑ Service-Winj D• Single Zone ❑✓ • 1c.Specify if well is proposed for: Drill ❑•• Lateral C Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill ❑ Reentry L Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: -U Blanket u Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. ' Bond No. 59-52-180 KRU 2S-10 • 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 14098's TVD: 6383'• Kuparuk River Field • 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:2211'FSL, 1526'FEL, Sec. 17,T1ON, R8E, UM • ADL 25603,25604,25608• Kuparuk River Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 65'FNL, 5001'FEL,Sec.21,T1ON, R8E, UM 2677,2678,2681 8/19/2015 Total Depth: 9.Acres in Property: 14.Distance to 571'FNL, 1309'FEL, Sec.29,T1ON, R8E, UM 7632 Nearest Property: 3971 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: • 148 feet 15.Distance to Nearest Well Open Surface:x- 481044 y- 5929980 Zone- 4 . GL Elevation above MSL: , 120 feet to Same Pool: Shark Tooth,797' 16.Deviated wells: Kickoff depth: - 600 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: . 92° deg Downhole:3751 psig • Surface:3113 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) 24" 16" 62.5# H-40 Welded 78' 28' 28' 106' 106' pre-installed 13.5" 10.75" 45.5# L-80 Hydril 563 2746' 28' 28' 2774' 2650' 1068 sx DeepCRETE,195 sx DeepCRETE 9.875" 7.625" 29.7# L-80 Hydril 563 _ 8069' 28' 28' 8097' 6383' 471 sx GasBLOK, 126 sx GasBLOK 6.75" 4.5" 12.6# L-80 IBTM 6151' 7947' 6350' 14098' 6383' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth TVD(ft): Junk(measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Production Scab Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20.Attachments: Property Plat❑ BOP Sketch❑ Drilling Prograrr Q Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements J 21.Verbal Approval: Commission Representative: Date: ( Z 1-15 ,-_j.A--- 22. I hereby certify that the foregoing is true and correct. Contact Jacob Voss @ 26i-6935 Email JaCOb.VOSs(C,Cop.COm Printed Name G. L. Alvord t�s,�jhs�, �'�.- Title Alaska Drilling Manager Signature L. A ins.-.� Phone:265-6120 Date ( --.22-75- Commission ZZ-75-Commission Use Only Permit to Drill API Number Permit Approval I See cover letter Number DVS.- { I 0 50- - -CO •-C,Z� Date: 7 13 15 for other requirements Conditions of approval: If box is checked,xvell may not be used to exploreor• •- •-• thane,gas hydrates,or gas contained in shales: EX Other:8OP f-CS f fa 3�UI,/0S • • Mud log req'd: Yes[] No d ilY "lf- 3nviai- -eve.vitte 00/C -s: Yesr/ No Directional svy req'd: Yesd No❑ 5 ta4''C•W/fn 55rel Al/r= • • _r. ti :y��i.1 tcpr tion-only svy req'd: Yes❑ No[E reepWi-cc a Pre-,-stabs Approved by: 7 t pR„...Wil�t��- • r, ,• . : Date: 7 3----I Form 10-401 (ROised 10/2012) This permit is v i r41,picirAt.ciN. tfapproval(20 AAC 25.005(g)) la (gill-1117 k'7`L //o//5- ,' ,0 .,14aE;, . Application for Permit to Drill,Well 2S-10 Saved: 18-Jun-15 Post Office Box 100360 Anchorage,Alaska 99510-0360 ConocoPhillips Phone(907)265-6935 Email: jake.vossaconocophillips.com June 18,2015 RECEIVED JUN 23 2W Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 AOGCC Anchorage,Alaska 99501 Re: Application for Permit to Drill Well 2S-10,A Kuparuk A4 Sand Pre-Produced Injector ' Dear Commissioner: ConocoPhillips Alaska,Inc.hereby applies for a permit to drill an onshore grassroots pre-produced injector well from the , 2S pad. The expected spud date for this well is August 19,2015.It is planned to use rig Doyon 141/ 2S-10 is planned to be a horizontal well in the Kuparuk A4 sand.The surface section will be drilled with 13-1/2"bit and run 10-3/4"casing to+/-2,774'MD/2,650'TVD.The intermediate section will be drilled with 9-7/8"bit and run 7-5/8" casing to 8,097'MD/6,383'TVD.The production hole will be drilled with 6-3/4"bit and run 4-1/2"slotted liner to+/- 14,098'MD/6,383'TVD.The upper completion will be run with 3-1/2"tubing. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d)(2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a)and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. a/ If you have any questions or require further information, please contact J cob Voss at 265-6935 (jake.vossc conocophillips.com)or Chip Alvord at 265-6120. Sincerely, Chip Alvord • s�h Son Drilling Manager C. 444 • Application for Permit to Drill Document Kuparuk Well 2S-10 Well Name Requirements of 20 AAC 25.005(f) The well for which this application is submitted will be designated as 2S-10 Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (2)a plat identdying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth,referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 3068' FNL, 1526' FEL, Sec 17, T 10N,R008E,UM NGS Coordinates RKB Elevation 148'AMSL Northings: 5,929,979.72' Eastings: 481,044.13' Pad Elevation 120'AMSL Location at Top of 65' FNL,5001' FEL,Sec 21,T1ON,R008E,UM Productive Interval (Kuparuk A4 Sand) NGS Coordinates Measured Depth, RKB: 8,097' Northings: 5,927,698.65' Eastings:482,850.03' Total Vertical Depth, RKB: 6,383' Total Vertical Depth, SS: 6,235' Location at Total Depth 571' FNL, 1309'FEL, Sec 29,T1ON,R008E,UM NGS Coordinates Measured Depth, RKB: 14,098' Northings: 5,921,917.92' Eastings: 481,264.93' Total Vertical Depth, RKB: 6,383' Total Vertical Depth, SS: 6,235' and (D)other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated,the application for a Permit to Drill(Form 10-401)must (I)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well: Please see Attachment: Directional Plan And (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells,to the extent that those names are known or discoverable in public records,and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 AAC 25.035,20 AAC 25.036,or 20 AAC 25.037,as applicable; Please reference BOP schematics on file for Doyon 141. S Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient,' The maximum potential surface pressure (MPSP) while drilling 2S-10 is calculated using an estimated maximum reservoir pressure of 3,751 psi (11.5 ppg; based on Shark Tooth#1 appraisal well), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A4 sand at 6,383' TVD (WP10): A Sand Estimated. BHP = 3,751 psi A Sand estimated depth(WP10) = 6,383' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 638 psi (6,383' TVD * 0.10 psi/ft) MPSP =BHP—gas column =3,113 psi (3,751 psi—638 psi) (B)data on potential gas Hones: The well bore is not expected to penetrate any shallow gas zones. And (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones,and zones that have 7 propensity for differential sticking; See attached 2S-02 Drilling Hazards Summary Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25.0300; A procedure is on file with the commission for performing LOT's. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted liner,pre perforated liner,or screen to be installed Casing and Cement Program Casing and Cementing Program Csg/Tbg Hole Weigh Length Top MD/TVD Btm MD/TVD OD(in) (�)t (lb/ft) Grade Conn. (ft) (ft) (ft) Cement Program 16 24 62.5 H-40 Welded 78 Surf 106/106 Existing Hydril Cement to Surface with 10-3/4 13-1/2 45.5 L-80 563 2,746 Surf 2,774/2,650 1,068 sx DeepCRETE Lead 11.0 ppg, 195 sx DeepCRETE Tail Slurry 12.0 ppg Stage 1: 471 sx Class G+GASBLOK at Hydril 15.8 ppg w/TOC at 6,043'MD 7-5/8 9-7/8 29.7 L-80 563 8,069 Surf 8,097/6,383 Stage 2: 126 sx Class G+GASBLOK at 15.8 ppg w/TOC at 4,659'MD 4 1/2 6-3/4 12.6 L-80 IBTM 6,151 7,947 16,350 14,098/6,383 Slotted liner • Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 AAC 25.035,unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please reference diverter schematic on file for Doyon 141. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 AAC 25.033; Mud Program Summary Surface Intermediate Production 13-1/2" Hole 9-7/8" Hole 6-3/4" Hole 10-3/4" Casing 7-5/8"Casing 4-1/2" Liner FLO-PRO NT Mud System Drilplex LSND(WBM) (WBM) Density 9.3- 10 9.2- 11.5 10.5—11.5 PV 30-50 10-20 10-20 YP 40-80 16-24 16-24 Funnel Viscosity 200-300 N/A N/A Initial Gel 30-50 10- 12 5-8 10 minute Gel 30-50 10- 18 5- 12 API Filtrate NC <6 <6 HTHP Fluid Loss at 160 F N/A < 10 < 10 pH 9.0- 10.0 9.0- 10.0 9.5- 10.0 Diagram of Doyon 141 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) N/A - Application is not for an offshore well. • S Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer to attachment for proposed well schematic. S 1. Move in/rig up Doyon Rig 141. Install 21-1/4"Annular with 16"diverter line and function test. 2. Spud and directionally drill 13.5"hole to casing point at+/-2,774 MD/2,650'TVD as per directional plan (wp 10). Survey with MWD,Gamma,Resistivity,Gyro,Density/Neutron. ✓ 3. Run and cement 10-3/4",45.5#,L80,Hyd-563 casing to surface. Displace cement with mud. Evacuate top 2 feet of cement from annulus for sealant job(post rig.) 4. In the event cement returns are not seen at surface,perform a top job. 5. Remove diverter system,install and test 13-5/8"x 5,000 psi BOP's to 3500 psi(annular preventer to 2500 psi) high and 250 psi low. Notify AOGCC 24 hrs before test. 6. PU 9-7/8"PDC bit and directional drilling assembly,with MWD/LWD(Gamma,resistivity). RIH and clean out to 100' above shoe. Test surface casing to 3500 psi for 30 minutes. 7. Drill out shoe track and 20' of new hole. Perform leak off test to a minimum of 12.5 ppg,maximum of 16 png EMW leak off,recording results. 8. Directionally drill to the top of the HRZ at-6,775' MD/5,948' TVD. Install RCD bearing at this time for use of MPD if necessary. 9. Directionally drill to intermediate TD of 8,097' MD/6,383' TVD,landing in the Kuparuk A4 sand. Wellsite geologist will call intermediate TD. Circulate and rotate at maximum rates until shakers are clean,minimum of 3 bottoms up. 10. POOH on elevators. Closely monitor drag and address any problem areas by dropping below and circulating/rotating to clean up. Backream through tights spots only if necessary. If substantial drag was observed through a large part of the trip,consider making a wiper trip back to bottom from the surface casing shoe,otherwise continue pulling out of hole. 11. Laydown intermediate BHA and rack back 5"DP(to lay down after casing run,this will minimize shale exposure time.) 12. Run 7-5/8",29.7#L80,Hydril 563 casing from surface to TD at 8,097' MD. 13. Pump two stage cement job as per Schlumberger proposal. Top of first stage to be 6,043'MD(top of Cairn v, formation),top of second stage to be 4,954' MD(500' above C37). 14. Flush 10-3/4"x 7-5/8"annulus with water,followed by diesel to freeze protect. 15. Lay down 5"DP. 16. PU 4"DP,6-1/2"bit,and drilling assembly with MWD/LWD(Gamma,resistivity,Periscope,Microscope,and neutron density) 1 17. RIH and clean out cement to 100' above shoe. Test intermediate casing to 3500 psi for 30 minutes. 18. Drill out shoe track and 20' of new hole. Perform formation integrity test to minimum of 12.5 ppg,maximum of 16 ppg EMW leak off,recording results. 19. Directionally drill 6-1/2"hole geosteering though the Kuparuk A4 sand to TD 14,098' MD as per directional plan(wp10). 20. Circulate hole clean and POOH. 21. Lay down Production BHA. 22. PU and run 4-1/2", 12.6#slotted liner. The top of liner will be placed at 7,947' MD,allowing for 150' of overlap in the 7-5/8"casing. 23. Set liner hanger. Slackoff and set liner top packer. 24. Monitor well for flow for 15 minutes 25. Displace to clear brine. PT liner to 3,000 psi at surface for 30 minutes,chart results. 26. Flow check well for 30 minutes to run 3-1/2"upper completion. 27. Nipple down BOPE,nipple up tree and test. 28. Freeze protect well with diesel and install BPV. 29. RDMO. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill music be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authori_ation under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well (1R-18 or new facilities at DS 1B). All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well,or stored,tested for hazardous substances,and(if free of hazardous substances)used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: Attachment 1 Well Schematic Attachment 2 Diverter Layout Diagram Attachment 3 Directional Plan Attachment 4 Drilling Hazards Summary Attachment 5 Cement Summaries 0 • 2S-1 0 ConocoPhillips Grassroots Horizontal A-Sand Injector Proposed Wellbore Schematic(wp10) _ CAMERON Last Edited: 4-%"tree,top Joint is 4-W 12.6#IBTM Voss 6-18-15 a .` 16"Conductor to—115' a O a7 4 3-%"2.875"DS Landing Nipple 13.5" Surface Hole w1114' t: 4 A , GL - 3-1/2"GLM '.:, aL Surface Casing 10-3/4"45.5#L-80 Hydril 563 2,774' MD/2,650'TVD GL 3-V GLM 9-7/8" Intermediate Hole 3-1/2" 9.3#L-80 EUE 8RD-MOD Tubing 0 ---- Shear out GI. orifice valve swt. 2'tl Stage TOC:4,659'MD/4,312'TVD (500'MD above C-37 Formation) 1 1 1 1 1 1 1 1 1 A Weatherford Stage Collar:5,228'MD/4,811'TVD & C-37:5,159'MD/4,751'TVD (Top of C-37 formation) Growler(Iceberg):5,353'MD/4,918'TVD ' _ 1'Stage TOC:6,043'MD/5,471'TVD -6,"11,;', (Top of Bermuda/Cairn formation) Bermuda/Cairn:6,043'MD/5,471'TVD HRZ:9676,J:15' 6,775'MD/5,948'TVD Kalubik:7,291'MD/6,191'TVD . x _n(638" "Swell Packer Iiiilib... ,7-5/8"Flex Lock Liner Hanger I ZXP Kuparuk A4:8,097 MD/6,383'TVD r Baker 2.812"CMU Sliding Sleeve ^11.0 ppg She. ; 3'G"2.75"D Nipple x; -\ 3 3 W'HES Mirage Disappearing TD:14,098'MD/6,383'TVD g Plug i ,,-� Intermediate Casing y 6-3/4" Production Hole 7-5/8"29.7#L-80 Hyd563 Casing Production Liner: 8,097' MD/6,383'TVD(85°) 4-1/2" 11.6#L-80 IBTM Slotted Liner NOTE: Swell Packer will be adjusted as necessary using microscope and periscope data 0 • � w / / I I I I I 1 ›- o ul s --t r-- I z o 0 CI 7i- - _a Z 0 o P U f I F w --C ® m 0 >-- {n U < -< Q ® ^ _C >--- �_ Y ® ^ N i a � < El ® �� ¢ a a L L., o ® r- o , --< " u ® — 0 El ® n0cem N , N N Y C] rya ;:isShh.Nk''..A:\\s\.:\\\\\) N M r - `� ■M •' N M Q ` p N ElO\ mLi N. ,�El O ■m pM pp Q ' N p O , p NY El CD o O U N N =O°0 0 ® = ' ❑ ® _ o . 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O CO (0 CO (O CO (0 c N O N N ci (0 (6 CO e a 222 2 2 2 2 2 2 2 2 2 2 2 2 222 2 2 2 2 2 2 2 2 2 2 2 CU 1 W C C C C C C i C ( ( C C C C ( C C C • Fz+ (n W W W Cl) W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W co W W W W W W W W 00 CO 00 CO 03 CO CO N N N N N CO CO 00 CO @ CO CO CO N 03 00 03 03 00 CO G 0- 0- 0- 0_ a 0- 0- 0- 0- 0- 0- 0- 0- 0- 0- 0- 0- 0- 0- 0- 0- 0- 0- 0- 0- 0- 0- C 0 .G▪ ' a P-1 a) E c� o 0 15, a) 0 0 0 0 0 0 0 `0 0 o 0) o w .:5_, o o 0 0 0 0 o (o = c 0 c cu c co c m c cu c ca co c ca c ca cc Q c 0 0 -60 -6 m cO (o m m c m (n c (0 (0 (0 m (a O .0 N 0 W 0 W a) W NW N W N N N a) W 4) 0CO 0 W 0 N 0 01 a) CO•- D O 6 O 5 O o cO c C C C C C C C C C a) o p 5 0 0 0 50 .150E0 p p 0 O c C C E 2 a) 2 N c26 N N N (` N N CO a) co a) (0 a) (0 a) N a) O N N N N U E ' ca C co C co C R C O C (0 CO C al C as C al C O C 03 C CO C CO 7 a) 0 a) W a) O o a) o 0 o a) 0 o N o o O a) O 0 O a) O 0 O CU Cl) 000000 000000 00000 000000 0000 N r- N O O CO C0 CO 0 N O CO N CO 0) O CO CO CO 0) O 0) CO O O Co O) O O O N r 0 CO I- 0 CO CO 0 ti 0 N- 0 O CO O) 00 0) CO a) C `p N N ,- r O V CO V N ,- CO O N O CO CO V M V M V O O) O O 0 0) @ U V M M N � N N CO CO (O M N M N Ni M 4 M O r O O Cn O (O O R 0 .- x- CU CL 0 13 000000 000000 00000 000000 0000 N o 0 0 0 0 O O O O O o O O O O O o 0 o 0 0 0 o 0 o O O . . m L o CO O LriN- O 0 O CO Cn O 0 (O O O o In O O 0 O O Cn O CO O CO O W O N CO r ,- O O N N CO O N O If) O O CO O CO O N t` N r N r R a,N M V CO V N V f- M CO CO CO O (O COM O CO CO CO V CO V M M 'Cr V CO M ON- 0 CO 0Cj MfC N M M 01 03 O CO CO CO CO N. CO V V V 0) ,- CCo L CM N- C) VV M M M M .- O O CO O M 0 0 N N .- N N C) N M N M N Q 0y NNN N V V O CO r r N N <- N N N N O CO CO CO CO Ca CO CO ✓...1 I y NN ITIa— O 1) (1) I,- d O E a O CO O O U) 0 O V (0 (O M (0 CO o CO 0 0 0 0) 0 CO 0 (O 0 CO (.) 0 .- 0 0) 0 0) V ,- O (O 0) O v V CO 0) 0 O O) 0 0) 0 0) 0 01 0 03 0 0) C i ovovr' o 6N- rri (O r) vai (ri6 (rio) 6C) (r) <i La4C() v .Q • N='� O N CO ti r o O N V N- 0 N O I"- 0) r 0) r O O V N r N r N r 0 W Q N co V CO V V CO CO O (O CO CO V CO V CO CO V CO M V C o U O) R C O CESCU r N CO CO 0) V O N O 0 CO O 11 0) O CO CO CO r ,- CO N O N CO N d d a E o r O r b t` O CO O N V O O N N N - V CO V CO v CO O _O ,- N M o Ch a) 0 0 0) N O O O O 0 0 CA 0 0) O d) O CA o r d co 7 C 0- N- V V' CO CO 0 - CO O V CO M N co N CO U (0 0) O CO O CO O Q O o E N N N N N ,- ,- 3 d• � Q ` W= o � s W o ✓ F, O. x I 3 co 0 O 0 CO CO 0 O V CO CO CO V CO CO 0 Co 0 03 O 0) 0 CO 0 (O 0 CO O 0 O) O O V ,- O (O O (0 V V M Cr) 0 0 O 0 0 0 0) 0 0 0 0 0 0) w o v o v r o 0 1r l� ri (0 ri .4 a) (ri a) Cri a) o (r (C) v Cri v u) v N Lam''I N d 7 O N (O N- ti 0 0 N V 0 N O I"- O ti O N- O CO V N r N r N r Cl)W y W CO V CO V ,- N V 1- CO COM CO CO O (O CO CO V M V M V (M 4. M V' co V O _ N O V a Z O E 2 T (o c m N CO O 0 T C V V V V N o CO = C a a 0 CO CO a t . rn (D a) 0 0 0 o N a°7i 7 a 7 'y ` N N a f0 (6 a0 O O O a) O d O O C C a) c m Y o o s 9 0 o a) a� 0 0 c c E r.., 0 0 2 2 2 2 r 8 0 0 ` (A a E E E E K N E E .o a E t 0-`s d H11i n RS 0 Q• (a m o as Z I- I- CO (0 0 0 m (0 (O CO 0 0 I- CO CO CO (O - 1- N- - N0_ O 0 0- a) 0 0 0 0 0 0 0 0 0 0 0 O O O O O J J O o J J J J CO CO 4- 0 C rL Ct Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q — Q Q M M M M c a 0 3 - 5� 3 3 .0 CO 3 3 3 - 3 co co • i. .0 (6 .0 Co co V V O O (0 O N- N- CO 0) 0) N N 66N ,N O N a y N 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N N N N N C C 7 o (/) 0) 0) C0 0) C0 (/) (n C0 0) C0 0) CO Cn (A C/) CO C C (� Cl") a. z,N O N N N N N N N N N N N N N N N N N N N ( C (V (u CO Co CA 0 • � L. ' ' J J J J 0- 0- CO £ i O) N CU C C CO M V V CO CO CO (O N- I- CO O O ,- .- ,- N N CO M CO CO CO CO Ce X 'a 0 7 E 0 0 0 0 0 0 O O O O O.O O O O ,- ,- ,- <- .,'- r o 0 as (nu) (hu) u) c o (hoSo0) ch rnu) u) (h (h (n (i) d) chd ch chd) � (h o 4 ,- Z N N N N N N N N N N N N N N N N N N N N N N N N N N N C 0- Y . 0 Q. C C C C C C C C C C C C C C C C C C C C C C C C C C C ) CO in O .0 O N (0 (0 (0 (0 (0 (0 (0 (6 (0 (0 (6 CO (0 (6 CO CO (0 (0 (6 (6 (6 (0 (0 ca N (0 (0 N •N o c oo m Cl) 0_ 0_ 0_ 0._ 0. 0._ 0. 0. 0. 0. 0. 0. 0. 0_ 0. d 0._ 0_ 0. 0_ 0_ 0_ 0. 0. 0. 0_ 0_ ti Z 'W 0 CA d 0 Y C C M M V V CO CO O M r N- O O O .- N N M M M M M M 0 y o W = 0 E. 0 0 0 0 0 0 0 0 0 0 0 0 0 Q a O G7 E V CO (n CO CO CO CO N Ch (h (i) CO (l) v) CO Ch Ch Ci) (1) Cn Ci) Ch CO 0) Ch (h (h CO N. E C'a co Q- (O N N N N N N N N N N N N N N N N N N N N N N N N N N N ,- .T C CO CO w E 0. C C C C C C C C C C C C C EE C C C C C C C C C {j 0 o Q' o (0 CO C0 CO (0 CO (0 (0 CO (0 (0 (0 (0 CO (0 (0 (0 (0 (0 (0 (0 0 (0 (0 (0 (0 (0 c i1)) (.) Y 0- 0- 0- 0- 0- 0- 0- 0- 0- 0- 0- 0- 0. 0-. 0. 0- 0_ 0. 0- 0- 0- 0- 0- 0- 0- 0- 0- Q1- CC w m • a. 'a Co xC a 1 C U 0 = PG Y Y Y Y Y Y Y Y Y Y ISI U) U) U) U) N 0 U) U) CO N (A CO U) U) CO EEEEEE EEEEEE EE Is = E 0 0 0 0 0 0 0 0 0 0 0 0 O O r/) a. @ .0 @ (0 (0 CO CO @ (0 (0 (0 (0 CO (0 (0 CC O a 2 2 2 2 2 2 2 2 2 2 2 2 2 2 cu N U) u) u) u) u) m 4747 m (17 U) U) U) U) CO RS RI a a a CO CO CO a a a CO a a c 0 = -a Po o f a) 0 0 0 0 O 0 0 a) O a) O N O U U U U U U ori U U U U U ) @ C @ C @ C @ C @ C @ C @ U m E (a (L o LL (13LL @ LL U) u_ as u_ as LL G c w a) N a) o a) a) m a) w 0 ii cD 0 0 0 E- N @ 2 @ a) @ N @ N @ N @ N @ O U (6 @ (6 C (6 @ C (6 (6 r a s = a) a) U) a) a) a) a) a) a) a) a) a) a) a) 0 U 0 Co 000000 U U U U U U o Y Y Y �_ CO 6) co V 0-- W CO (O CC) N M M N U) Q Q Q CU CO O N- N V (0 O W CO N = CC (Y cL C r 6) CO CO 6) O 6) N W O M MM CO (� LL LL LL @ O W 61 V a0 O O W CA CO O Ni CO (O C) + f -F @ R N N N CO CO (O CO V CO Q' 0 0 0 0 0 0 ULL CCO22222 -a0 0 0 0 0 0 0 0 0 0 0 0 00 y6 0 0 0 0 0 0 0 0 0 0 0 0 0 . . jt y O O Ln O O . ui O (n O O O 0 (n V) O O N CO (C) N N co, N (O C6 Lc) C6 r') @ 3.-N CO V' N M N M N CO CO V N M co co a) = ca co V N O N (O CO CO O W (fl O N CO N CC N 6) N LU CO O V M C) (O r N a) ^ M N r M V V (C) V W r C' M N N N ,- OONNMM WW 1:1:-.4 O ,7) .- -- ,- NNNNNN CO (O C) — w Ma-0 O a Cl) m 4— O Q) O O O O O O O W O r moo C •— O Cf) 0 0 0 0 0 0 0 6) CO V . . C N 1:1 C ^ O O CO O O CO (O O Cn 6 O O O 0) r (6 (O N N O N VLc C6 6 W O O Co a)@ /1 NNp•y MMNMNM N CO CO VN CO CO s- d (L O C 0 OO COp > U) O co N CO W CO CO W CO r- CO CO -Cr r N V' O a) O• E N Cn N r— N W N W W W CO N N V"' _ U Cn (A C31 Cf) Cf) 6i Qi (7i O O r r O ZP rT O O CP O mc ,;7 s- V' V N. O O V V V V' mm C C C C C C C Q p al N N N N N N N r r 0 0 0 0 0 0 0 Ti) = N = 0) 0) 0) 0) 0) 0) 0)) •- Q _0 9 0 _0 9 9 ` W mmmmmmm 0 0 0 0 0 0 Il °) 3 m 06) 0000000 W o r- CO o &I' '2 om0000 000 (n (6v C6 co 0000000 t ^ a 6i Cn O 6 ((i LC O LCi 6i O O 6i CO �.Q Q�.Q Q N .o t -0 = a w O co r CO LU N N O N V C6 co O O 1••' N r 0 0 N CO M N CO N CO N CO CO V N CO A- O . @ p - O O 0000000 O Z O •£ 2 ‘- x- 6c/566c/5c:06 T.. a@+ N N N N N N N I Co N = Cl) 0 N N ate) m EL o cC c x X oCNNO 0o ) ) (6m C Co O 0 U O O0 (a Cl C 0) O N O O - - -O "O .0 C f" / O O r N O C) O N N VW CAp .0 .0 U elO � d N ` U 4) L .0 . N N O O H H _ E = LL R > 2 2 CO U) 2 2 N co 0 CD Y L () @ CU N N Z IN r M (fl CO CO W CO N (6 O a, E C i 0_ 0_ 0_ 0_ 0_ 0_0 a Q F H co co L O O O Cn Cn N N ++ C .a • " 0 3 3 3 3 3 3 3 3 0 0 0 0 0 (0 (0 CO Ja v v Lo Lo co co N- r-- 7 O .�ca 664 v r L CO CO y _ r cCi a0 L e +' N 0 0 N- r co 6) O (i m U 666666 (J5 C n o_ .0 .0 o. O o , , o o cL T N O N N N N N N NN ? 3 0 —O L.L — N N CO-W �L, N N N N 0 0 O (O W E 7 O N a) V' V' co co 0 0 0 0 O W O Y Y Ce p C a3 U) W U) U) U) U) U) U) N N N N CO @ C = Z N N N N N N N N L L 0 (() O c1. 7 ,- 1- • C31'-: C C C C C C C C 0 0 0 0 CO (0 r c0 a) @ @ @ @ @ @ @ @ ,I7-) 0 = o _ zi d d d a d d a s N N N N # 4 VI •N O C= C C 1 i i I C a) Z 'y O Ul O O V V' CO (O CO co r r .a L L C '"33 cl'a 0 a) N N c- . . . 0 0 0 0 I 0 0 O C o C Z O. CO N N N N N N N w co N N N N N 0- Y Y j. C@@ y E C C C C C C C C 0 @ U 0 Ce .-, 0 @ @ @ @ CO @ @ @ 0 0) 2) 0 O L L C > G1 C C CO 0 0- 0_ 0_ 0_ 0_ 0_ E a it CC Z U) CO < @ 0 0 • • N o) = Q ;- - I (L) 0 • _ 0 ft a. ':4 O v 0 0 U 11-1 0) C O o a) Lo d c. -13 a O c 0 m O m n r N a) a 2 w COI U a ) L_ N a) o a) .o EI2c 713 ai 3 0 is 1 c c w CO n a) m U d) _o c E az V U C ^� p O N E li T N N \ y a) o- 'O N L N O D ° a) c c u) c = o 'in t� N aa) r d D aoNN .ct c NLON N 3Q N ^. a) N U a) a) U a) c w m tON @ (E Ti N Ce N '( N N U a) O O a 2 2 v a 3a) Lo O m ° o •'^ N V1 N c II m v—I - .a .0 U U -O 7 _ U 0 8O a mNC a) N 2 U O_ n) m 0C . C a m cU :suan -• (O ) Q = m a) Na) – W 0 U) 0 0 Q 41 10 • ConocoPhillips 2S-10wp10 [Wobbegong] Schlumberger Alaska -c i.. c E oo •c • EE EE a -'k= 3 3 33 3 V m vn4 on 4 44 4 4O N NN N 300 Iil ' 7 11 1 II 1 AP i I �4 � ipp ..,.,.„ l ,10, I c � U l�0 Q N®0IIII:IIk /lI I 0 ���t Ie CZ I Ia u • a., " .gIlsl1 llI�wE.• 150 'd 1t � I U S � 11111 L W0111111'If I - ... ...... .. IJ i 1 0,/,,,, °u,!II , �.,Equivelant Magnetic Distance _tee 0 I I I I I I I I I I I I I I I I I I I I I I I 1 I I i I I 0 2000 4000 6000 8000 10000 12000 14000 Displayed interval could be less than entire range: Measured Deptt28.0O To 14099.10 ANTI-COLLISION SETTINGS Interpolation Method: MD, interval: 25.00 Depth Range From: 28.00 To 14099.10 Results Limited By: Centre Distance: 1607.11 SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 28.00 1000.00 2S-10wp10[Wobbegong](Plan:2S-10) GYD-GC-SS 1000.00 2000.00 2S-10wp10[Wobbegong](Plan:2S-10) MWD 1000.00 2774.05 2S-10wp10[Wobbegong](Plan:2S-10) MWD+IFR-AK-CAZ-SC 2774.05 4274.05 2S-10wp10[Wobbegong](Plan:2S-10) MWD 2774.05 8097.62 2S-10wp10[Wobbegong](Plan:2S-10) MWD+I FR-AK-CAZ-SC 8097.62 9597.62 2S-10wp10[Wobbegong](Plan:2S-10) MWD 8097.62 14099.10 2S-10wp10[Wobbegong](Plan:2S-10) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2650.00 2774.05 10-3/4"x 13-1/2" 10-3/4 6383.00 8097.62 7-5/8"X 9-7/8" 7-5/8 6383.00 14099.10 4 1/2"x 6-3/4" 4-1/2 LEGEND -e- Plan:2S-01,Plan.2S-01,2S-01wp07[Mako]VO -8- Plan:2S-11,Plan:2S-11,2S-11wp06[Great White]VO —X— Plan:2S-16,Plan:2S-16,2S-16wp06[Squalicorax]VO -e- Plan:2S-03,Plan:2S-03,2S-03wp06[Bamboo]VO —g— Plan.25-11,Plan:2S-11L1,2S-11L1wp06[Great White]VO -9- Plan.2S-17,Plan:2S-17,2S-17wp06[Hybodus]VO —X— Plan:2S-04,Plan:25-04,2S-04wp09[Lemon]VO —1— Plan:2S-12,Plan:2S-12,2S-12wp07[Bull]VO -0- Rig:2S-02,2S-02,2S-02 VO —g— Plan:2S-05,Plan:25-05,2S-05wp06[Nurse]VO —1— Plan:2S-13,Plan:2S-13L1,2S-13L1wp07[Megalodon]VO --X— Rig:25-02,2S-02,2S-02wp08.1[Thresher]VO —X— Plan:2S-06,Plan:2S-06,2S-06wp06[Salmon]VO -9- Plan:2S-13,Plan:2S-13L2,2S-13L2wp07[Megalodon]VO -0-- Shark Tooth#1,Shark Tooth#1,Shark Tooth#1 VO —0,— Plan:2S-07,Plan:2S-07,25-07wp10[Goblin]VO -a- Plan:2S-13,Plan:2S-13PBt,2S-13PB1wp07[Megalodon]VO--9— 2S-10wp10[Wobbegong] --A— Plan:2S-08,Plan:2S-08,2S-08wp07[Hammerhead]VO —A— Plan:2S-14,Plan:2S-14,2S-14wp07[Whale]VO --1-- Plan:2S-09,Plan:2S-09,25-09wp06[Tiger]VO -h- Plan:2S-15,Plan:2S-15,2S-15wp06[Helicoprion]VO i • ConocoPhillips 2S-10wp10 [Wobbegong] Schlumberger Alaska A L 3 3 E E H 3 3 3 1 Ni It' r r , 4 _ 1 / , / 60 1111 -.4111111 @ _ 'r „a ,dlifrk ri, , N _am."' Equivelalt Magnetic Distance ' 0 0 I I I 1 I I I I I I I I I I I I I I I I I I I I I I I 1 0 400 800 1200 1600 2000 2400 Displayed interval could be less than entire range: Measured DeptI28.00 To 14099.10 ANTI-COLLISION SETTINGS Interpolation Method: MD, interval:25.00 Depth Range From: 28.00 To 14099.10 Results Limited By: Centre Distance: 1607.11 SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 28.00 1000.00 2S-10wp10[Wobbegong](Plan:2S-10) GYD-GC-SS 1000.00 2000.00 2S-10wp10[Wobbegong](Plan:2S-10) MWD 1000.00 2774.05 2S-10wp10[Wobbegong](Plan:2S-10) MWD+IFR-AK-CAZ-SC 2774.05 4274.05 2S-10wp10[Wobbegong](Plan:2S-10) MWD 2774.05 8097.62 2S-10wp10[Wobbegong](Plan:2S-10) MWD+IFR-AK-CAZ-SC 8097.62 9597.62 2S-10wp10[Wobbegong](Plan:2S-10) MWD 8097.62 14099.10 2S-10wp10[Wobbegong](Plan:2S-10) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2650.00 2774.05 10-3/4"x 13-1/2" 10-3/4 6383.00 8097.62 7-5/8"X 9-7/8" 7-5/8 6383.00 14099.10 4 1/2"x 6-3/4" 4-1/2 LEGEND -8-- Plan:2S-01,Plan:25-01,2S-01wp07[Mako]V0 -8- Plan:25-11,Plan:2S-11,2S-11wp06[Great White]VO —X— Plan:25-16,Plan:2S-16,20-16wp06[Squalicorax]VO -8- Plan:2S-03,Plan:2S-03,2S-03wp06[Bamboo]V0 -e- Plan:25-11,Plan:2S-11L1,2S-11L1wp06[Great White]VO -e- Plan:2S-17,Plan:2S-17,2S-17wp06[Hybodus]V0 - Plan:2S-04,Plan:2S-04,2S-04wp09[Lemon]VO --1— Plan:25-12,Plan:25-12,25-12wp07[Bull]VO -0- Rig:2S-02,2S-02,2S-02 VO -9-- Plan:2S-05,Plan:2S-05,2S-05wp06[Nurse]VO -1— Plan:25-13,Plan:2S-13L1,2S-13L1wp07[Megalodon]VO -1- Rig:2S-02,25-02,2S-02wp08.1[Thresher]VO - Plan:2S-06,Plan:2S-06,2S-06wp06[Salmon]VO -8- Plan:25-13,Plan:2S-1312,2S-13L2wp07[Megalodon]VO -0- Shark Tooth#1,Shark Tooth#1,Shark Tooth#1 VO -9-- Plan:2S-07,Plan:2S-07,2S-07wp10[Goblin]VO -6- Plan:2S-13,Plan:2S-13PB1,2S-13PB1wp07[Megalodon]V0-B- 2S-10wp10[Wobbegong] —A- Plan:2S-08,Plan:2S-08,2S-08wp07[Hammerhead]VO -h- Plan:2S-14,Plan:2S-14,2S-14wp07[Whale]VO - Plan:2S-09,Plan:2S-09,2S-09wp06[Tiger]VO -h-- Plan:2S-15,Plan:2S-15,25-15wp06[Helicoprion]VO MD c Azi ND SN/-S +E/-W Dleg TFace VS Target 28.00 0.00 28.00 0.00 0.00 0.00 0.00 28 600 ?S�a 600.00 0.00 600.00 0.00 0.00 0.00 0.00 -1029510 [WObbegong 600.09 0 30.00 800.00 4.54 2.62 1.50 36.00 -5. 1485.52 20.14 30.00 1469.00 123.14 71.10 2.50 0.00 -137.35 600 790 28.00 To 14099.10 12404.97 208.15 10.54 12324.59 12534914°5 352.74 '31'0 110.04 322.58 790 970 4606.08 28.15 101.54 4265.26 31.61 1370.33 0.00 0.00 -385.20 8097.62 85.00 195.15 6383.00 -2276.69 1811.91 2.50 95.53 1730.16 2S-Wobbegong 1.Heel061214 BP 970 1160 1y.yfes,� aAir 8127.62 85.00 195.15 6385.61 -2305.54 1804.10 0.00 0.00 1760.04 «�:Aidrh Orf. 4 9f 1(14 8299.74 91.88 195.10 6390.29 -2471.53 1759.23 4.00 -0.36 1931.99 8977.55 91.88 195.10 6368.00 -3125.57 1582.72 0.00 0.00 2609.43 25-Wobbegong 3.T2 050714 PB 1160 1340 SURVEY PROGRAM 9051.85 90.40 195.21 6366.52 -319728 1563.30 2.00 176.07 2683.72 0958.47 90.40 195.21 6353.14 -5037.10 1063.25 0.00 0.00 459028 1340 1530 D-on From Depth 7o 0.0 Dolmen 0998.91 90.00 195.16 6353.00 -5076.13 1052.66 1.00 -173.67 4630.72 2S-Wobbegong 4.T3 050714 PB 26.00 1000.00 2,108000 5ob959095](5.05006996 1480.02 90.00 195.16 6353.00 -5540.50 926.84 0.00 0.00 5111.83 25-Wobbegong 5.T4 050714 PB 1530 1710 1000.00 2000.00 26-1095001Wobbeg0ng]I50000 -101 1513.05 89.34 195.17 6353.19 -5572.38 918.20 2.00 179.38 5144.85 1000.00 2774.05 25-10,10[Wobbegong](P APAIDSIRRAISGAE-SC2004099.10 89.34 195.17 6383.00 -8068.18 241.62 0.00 0.00 7730.73 25-Wobbegong 6.Toe 061214 BP 2774.05 4274.05 25-100510(0obbegangl(P IS08 9U] 1710 -- 1900 2774.06 6097.62 25-124510(Wobbegong1(P 22600-10) RCAZSC 0097.62 9597.62 26-10.p10]Wbbbegong]IP 4.ATS1U] 0097.62 1409910 26-1001510(4Wbbego7g](14 YW9BI10(-41CAZSC 1900 2410 CASING DETAILS 2410 2930 ND MD Name Size 2930 3440 2650.00 2774.05 10-3/4"x 13-1/2" 10-3/4 6383.00 8097.62 7-5/8"X 9-7/8" 7-5/8 6383.00 14099.10 4 1/2"x 63/4" 4-1/2 3440 3950 3950 -_-- 4460 4460 4970 4970 5490 I2S-07wp10[Gobi-in]._ 0/360 5490 6000 2S-06wp06[Salmon] ��� 1 6000 7010 -30/330 ., A�0 a`!� , 4 �� '_� 30 7010 8020 ��►I!,i:�� ' R ®101.! 8020 9040 0,#t 01� I I.��0,% V 9� •� 9040 10050 ��r �'� ° � � jP .. 1� 4. 10050 ---- 11060 At :wA '�%�/'W,1jr� �; 11060 12070 , � " il�/y-v // ® „�` 12070 13090 -60/300 ��® I 1 x!.,61 1. f 1��fa A� ' ,; 60 �►�?��"o ' �.® I r'i'f( b/s'�@ra \v``v 13090 14099 v p [ ,S'i 6.1.040:446; r ®®�� "11108(91 r 5il e S-08 07[Ha .y I / , Dry,0 ff T r ��' �� 4e Ia Qr eia4g4t'7/2;p2*:y�1�����y��,� ,'r 90 `Tiley%�j4ySC}4e Ib��'®•5®�� rYi����Y� � �71 �►�''�: rropP�Fit. \` wpb � 1 A arli7i i r4 t(, r ./,0�� 7� orr,� r �wa�a�,4iVp�'71 • 167/rE 66/Fr�0�T �� �0/ \ �� \ X441 Q4 j�����4"400I$7f, *:ver. rg P \ :f4 \ \ i ' 12S-03wp06[Bamboo] 1 1.11.14,114k4da'%.4..t! I, / f;. � 111'�f♦tea v .�j, i �� \' 0 A\ -.-1111. �.`�� ®�®��������pp///N 1 J .=...yea .,�I�1r�a�,it������.��� �\\\ ',,, 2S-12wp07[Bull,������� ®�( / ' . 44105.9 P 4t 8 v10 --�,•� • tittAsipAtt.'f,,,i►�I-' v-®� trl !r/1 J, . �/j ♦ ..a s'» rt' 'Irli.4.g be:1:g'nivismalivimin r�ui ]iVi�1 "�.F it (l s tte 0.''M��s11 90 -90/270 vpp,v,ov-®v�Yo@ivaefe'lliip a ‘'"'k ��yr�/�+/ 3 4 11' /e' it.,4������ �q1..M�bQ,.► ♦4LJe f 14I''� -� v �-%' e.kii$1 (i1. yr��"' 4 I(I I oq/ .* r3r� �_ li r, 1 14�P,tio 1l-i.a 5 o4i i)I I I p� -ATI �� d 49�w.v � 9�'�Pl•♦ A � ♦ al\\\ \'iwi ' fr... .. ;001.-0(9 - O y'w s ////,A1i0:, /01"0'.;44..#401 y yK., 1.a+�1 `� +ys.iys ref 1i�i�I! �c�i003 t s ,�1 , ;.�, .t .. ✓ ¢,*-111 �..l.�/ % r Ili+v ' T .i.aL ,r•`0. ov,,Ats �s�� �' / )oto-i0, iej4 1401/1Awfi +; ¢'�tc "1. ft v ate. As f'. I{9 rie4 ,��.$.1 /1.4..,,,,`ia'v i[ 4% e�, t v . P soot' �1e4. 1 �A4 t..4 i 25-17 06 H odus A.'�,W 'is rt>\�6v� 1`q.� t��}�o�, !s �1 �' 1 1 j P:r/� 1. wp [ w 4� r �� wD �y o ����rU L��4w��►,i���►A�i R.. w���� 2m. 1►a .400A .o..# �L��itizt �•- -*,1 mil/ 4#070/A, ,Vtil �A�T n.'101e s P AIS v� / '�Vli110172;,%4 1�► iliv**wr� �{ �'$ &VA'it O�Q n '6- PNt '" 4'DlaA'.t IS11174'�� f D a M S i 4�i ,...._4.4,,...,440iQ��' .s ,St11))6,1c.q\®e, 11.' 1►. ,Z . r �� �. s ! v��ja�.'� l I2S-1629506[Squalicorax] =KNOW!i1 ig bi.r�Nn,4.Ors wsiNo /S ra � s..�..di�.1 :I4:�'.;`�/ I�H' � 1 zo/240 * 0$:.:`" �11� �V"04 �!r �:1�'e.10 +•=•�i•I4 � 1g��` 14 120 /.4.,4_,,,v. 2S-15wp06[Helicoprion]�,, -111/ `�. I�'�/ 1' =I, �``NrJ?4�• 62.414 Y 40 �e.� ��"� ',PAT i,/��--W 6'y` ' 125-05wp06[Nurse] r \� P�►;jb� !►,g,�' / il ��'1 � �i� 125-1429507[Whale]. ��� ��� .4,�a� ,,ss-n4I.' 1 �I - op-- r I2S-13L1wp07[Megalodon]��, eft *Ito �re �rm v t .20.-13 07 lodon]�50/210 46731110-4� ( �� �°.' it4 150 L2wp [Mega :� r is ,r„ ►,� ►films a6 .�__I2S-0429509[Lemon]. I2S-1388129507[Megalodon]�, - �_ I2S-11wp06[Great White \\ -180/180 -129-09wpos[nger]I 2S-11L1wp06[Great White] $ Plan 20000p0104em)00 41- Plin MOB,nal x9012%06+907 IIlammemeed,05 $ Rm...Ren.00.,8(2,20-1200000520069105 $ 09 00 9 P. 0.x 26002(990 menter -n•0 -i- Plan 1.0005 2900.909(799,)00 4- P.00 291,P.0 29-,380 .0.,9 ,,26, 0107[Mag..,w •jt- 6 002.0..108--n w -34- Pe 00.08.42290519..mmiv0 $ Plan 2.11 Plan 2.1t 20.112906 prep mostvo -6- Plan 231,Plan 2,14 29-45947(wham vo -i^ s 5.415.40, I.showroom A vo $ a 90 (Awp .20c50eae(00 e- P n. 1L0wm -4 8(coat vv.)v0 - Pm 6.,5..(94016.000 2 .0I VO $ 25lva 162510mearg, 9t- Fun 2.806.Pert 2940.20008(08102mm1 w } P 902.0000(0(20 jt'- P. 0.15i0(9.9060a.100 ♦ P.n 2.7.Ren 294725.0210)0020)00 ♦ Plan Ma Plan 28-13,28031.1,01 pnagalacion)00 $ P.n 20,7 Pen 20,720170528Myman(v0 • • Northing (3500 usft/in) 11 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I 1 1 1 i 1 1 1 1 i 1 i i i i I i i 1 1 I i i i i 1 1 - o - I - _ Q) am - cr., - Q z N — - O O C O. N C - - Ta3 co _ O N E O_ (O N 1 m O - - 9 0 3 n , o _ ,__40 N 3 CO CO - _ OO O m E3 4 N - O o5 — �I� N _ - N r�. 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0.00 -137.35 600 790 8000.00 To 14099.1089A3 0.00 0.00 -172.76 1254041'9; 28.15 1010.54 12324.59 1239.45 352.74 3.50 110.04 -322.58 790 970 4606.08 28.15 101.54 4265.26 31.61 1370.33 0.00 0.00 -385.20 8097.62 85.00 195.15 6383.00 -2276.69 1811.91 2.50 95.53 1730.16 2S-Wobbegong 1.Heel 061214 BP 970 1160 ems. 8127.62 85.00 195.15 6385.61 -2305.54 1804.10 0.00 0.00 1760.04 �36a June 17 2015 8299.74 91.88 195.10 639029 -2471.53 1759.23 4.00 -0.36 1931.99 " 8977.55 91.88 195.10 6368.00 -3125.57 1582.72 0.00 0.00 2609.43 2S-Wobbegong 332 050714 PB 1160 1340 SURVEY PROGRAM9051.85 90.40 195.21 6366.52 -3197.28 1563.30 2.00 176.07 2683.72 10958.47 90.40 195.21 6353.14 -5037.10 1063.25 0.00 0.00 4590.28 1340 1530 Dan From Depth To 407048 000 0 77 tool 0998.91 90.00 195.16 6353.00 -5076.13 1052.66 1.00 -173.67 4630.72 25-Wobbegong 433 050714 PB 2000 100000 26-1040710 pNobbegongl 17I2700980E0 11480.02 90.00 195.16 6353.00 -5540.50 926.84 0.00 0.00 5111.83 2S-Wobbegong 5.T4 050714 PB 1530 1710 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\. 75 7•/- i \\\' ),, , „ W 1,11, 90/270 (� 1„ "" 90 �\":"._- , /::/::::"//'''/'/'> `'/ l ' Ili IT)i lit, iii 1 1 ff ll 4 ��' ; �/ 1 \\\ \i;, 75 \ ;;'`\,,\N, - f\1• 11\ / \� �. 105 ci .� \' 121 - 120 -120/240 `;�� A� 135 150 165 180 - 195 -150/210 210 150 225 -180/180 $ n n0m.m0774010O - Pan 9024 sol(Harm*00 $ ro 28-1312.,7Mgme9amm100 $ x02002,6626.230226 9 A a3m2smws16-00126 -f Rim 2.6 Ran 23.09.2s-02*I1 Iw 4, PI. x6,262626.-261077)26 * x2623022626.1802,081m� 100 -X- p". n a.42wp128609100 $ Pa 49n.m0.40worv0 -ir w 461«267718704 $ 6 ,.sloxlmm.1w Pa sas.46-007770)rvumlvo $ Pan 121..20 pat vara)v0 -� Pn 013..44 I0.*Pm)00 $ 20_0 904*019� -x- w 2000.2309ww0)6.m9")w 8+ Pan 2010n.m(OA V. 83- Mare 2310,Plan.16 20,s.m0)9wlbna.)w -} DVrt 2307.77077.2407,20 2626010 16 9 0."I v0 } Pan 2513 P.2.031x125122109011980.2649)40 ♦ Pan 25,Pan MA,2017an101#9048100 • ConocoPhillips ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-10 Plan: 2S-10 Plan: 2S-10wp10 [Wobbegong] Error Ellipse Survey Report To calculate actual errors: 17 June, 2015 I Multip y by 58 • Schlumberger • ConocoPhillips Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-10 Project: Kuparuk River Unit TVD Reference: Plan:120+28 @ 148.00usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: Plan:120+28 @ 148.00usft(Doyon 141) Well: Plan:2S-10 North Reference: True Wellbore: Plan:2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10wp10[Wobbegong] Output errors are at 1.00 sigma To calcul,-,,,actual errors: Database: OAKEDMP2 IP y Project Kuparuk River Unit,North Slope Alaska,United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 2S Pad Site Position: Northing: usft Latitude: From: Map Easting: usft Longitude: Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.14 ° Well Plan:2S-10 Well Position +N/-S 0.00 usft Northing: usft Latitude: +E/-W 0.00 usft Easting: usft Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 120.00 usft r I Wellbore Plan:2S-10 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2015 9/5/2015 18.60 80.87 57,489 Design 2S-10wp10[Wobbegong] Audit Notes: Version: Phase: PLAN Tie On Depth: 28.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 28.00 0.00 0.00 195.00 Survey Tool Program Date 6/17/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 28.00 1,000.00 2S-10wp10[Wobbegong](Plan:2S-10) GYD-GC-SS Gyrodata gyro single shots 1,000.00 2,000.00 2S-10wp10[Wobbegong](Plan:2S-10) MWD MWD-Standard 1,000.00 2,774.05 2S-10wp10[Wobbegong](Plan:2S-10) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,774.05 4,274.05 2S-10wp10[Wobbegong](Plan:2S-10) MWD MWD-Standard 2,774.05 8,097.62 2S-10wp10[Wobbegong](Plan:2S-10) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8,097.62 9,597.62 2S-10wp10[Wobbegong](Plan:2S-10) MWD MWD-Standard 8,097.62 14,099.10 2S-10wp10[Wobbegong](Plan:2S-10) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Position uncertainty and bias at survey station Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi-major Semi-minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (°1 el (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (°I 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 UNDEFINED 100.00 0.00 0.00 100.00 0.05 0.00 0.05 0.00 1.15 0.00 0.00 0.05 0.05 0.00 GYD-GC-SS(1,1) 200.00 0.00 0.00 200.00 0.20 0.00 0.20 0.00 1.15 0.01 0.01 0.20 0.20 0.00 GYD-GC-SS(1,1) 300.00 0.00 0.00 300.00 0.34 0.00 0.34 0.00 1.15 0.01 0.01 0.34 0.34 0.00 GYD-GC-SS(1,1) 6/17/2015 9:42:23AM Page 2 COMPASS 5000.1 Build 65 • • ),, Schlumberger ConocoPhillips Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-10 Project: Kuparuk River Unit TVD Reference: Plan:120+28 @ 148.00usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: Plan:120+28 @ 148.00usft(Doyon 141) Well: Plan:2S-10 North Reference: True Wellbore: Plan:2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10wp10[Wobbegong] Output errors are at 1.00 sigma Database: OAKEDMP2 Position uncertainty and bias at survey station Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi-major Semi-minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (°) (°1 (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usC) (°) 400.00 0.00 0.00 400.00 0.49 0.00 0.49 0.00 1.15 0.02 0.02 0.49 0.49 0.00 GYD-GC-SS(1,1) 500.00 0.00 0.00 500.00 0.63 0.00 0.63 0.00 1.15 0.03 0.03 0.63 0.63 0.00 GYD-GC-SS(1,1) 600.00 0.00 0.00 600.00 0.78 0.00 0.78 0.00 1.16 0.05 0.05 0.78 0.78 0.00 GYD-GC-SS(1,1) 700.00 1.50 30.00 699.99 0.92 0.00 0.92 0.00 1.16 0.07 0.07 0.92 0.92 135.00 GYD-GC-SS(1,1) 800.00 3.00 30.00 799.91 1.05 0.00 1.06 0.00 1.16 0.09 0.09 1.06 1.06 120.81 GYD-GC-SS(1,1) 800.09 3.00 30.00 800.00 1.05 0.00 1.06 0.00 1.16 0.09 0.09 1.06 1.06 120.81 45Y0-GC-SS(1,1) 900.00 5.50 30.00 899.63 1.19 -0.01 1.20 0.00 1.17 0.11 0.11 1.20 1.20 121.54 GYD-GC-SS(1,1) 1,000.00 8.00 30.00 998.93 1.33 -0.01 1.34 0.00 1.17 0.13 0.13 1.34 1.34 125.60 GYD-GC-SS(1,1) 1,100.00 10.50 30.00 1,097.62 1.40 -0.02 1.43 0.00 1.16 0.16 0.16 1.43 1.42 25.02 MWD(1,2) 1,200.00 13.00 30.00 1,195.51 1.40 -0.03 1.49 0.01 1.16 0.19 0.19 1.49 1.44 30.22 MWD(1,2) 1,300.00 15.50 30.00 1,292.43 1.41 -0.04 1.64 0.01 1.16 0.22 0.22 1.64 1.48 30.29 MWD(1,2) 1,400.00 18.00 30.00 1,388.18 1.44 -0.05 1.89 0.02 1.16 0.26 0,26 1.89 1.53 30.28 MIND(1,2) 1,485.52 20.14 30.00 1,469.00 1.48 -0.06 2.19 0.03 1.15 0.29 0.29 2.19 1.58 30.27 MIND(1,2) 1,500.00 20.14 30.00 1,482.60 1.49 -0.06 2.25 0.04 1,15 0.29 0.30 2.25 1,60 30.27 MIND(1,2) 1,592.03 20.14 30.00 1,569.00 1.56 -0.06 2.63 0,05 1.16 0.33 0.34 2.63 1.66 30.25 MWD(1,2) 1,600.00 20.04 30.76 1,576.49 1.57 -0.06 2.66 0.05 1.17 0.33 0.34 2.66 1.66 30.24 MIND(1,2) 1,700.00 19.16 40.87 1,670.72 1.70 -0.04 2.93 0.05 1.19 0,37 0.38 2.96 1.73 30.92 MWD(1,2) 1,800.00 18.87 51.59 1,765.29 1.94 -0.03 3.17 0.06 1.21 0.41 0.43 3.29 1.81 32.93 MWD(1,2) 1,900.00 19.20 62.29 1,859.85 2.26 -0.02 3.38 0.08 1.23 0.46 0.48 3.64 1.91 36.05 MWD(1,2) 2,000.00 20.12 72.34 1,954.05 2.62 -0.01 3.56 0.10 1.25 0.51 0.54 4.01 2.02 40.01 MIND(1,2) 2,100.00 21.56 81.33 2,047.53 1.90 -0.10 2.12 -0.08 1.24 0.55 0.57 2.22 1.90 46.58 MWD+IFR-AK-CAZ-SC(2,2) 2,200.00 23.41 89.10 2,139.94 1.99 -0.13 2.25 -0.09 1.25 0.60 0.62 2.37 1.99 53.55 MWD+IFR-AK-CAZ-SC(2,2) 2,300.00 25.59 95.71 2,230.95 2.08 -0.17 2.40 -0.11 1.26 0.66 0.68 2.54 2.09 60.94 MWD+IFR-AK-CAZ-SC(2,2) 2,400.00 28.03 101.29 2,320.21 2.15 -0.20 2.58 -0.12 1.27 0.71 0.73 2.73 2.19 68.35 MWD+IFR-AK-CAZ-SC(2,2) 2,404.97 28.15 101.54 2,324.59 2.16 -0.21 2.59 -0.12 1.27 0.71 0.74 2.74 2.19 68.65 MWD+IFR-AK-CAZ-SC(2,2) 2,500.00 28.15 101.54 2,408.38 2.23 -0.21 2.82 -0.12 1.29 0.76 0.79 2.95 2.27 74.41 MWD+IFR-AK-CA2-SC(2,2) 2,600.00 28.15 101.54 2,496.55 2.32 -0.21 3.08 -0.12 1.32 0.82 0.85 3.19 2.35 78.88 MWD+IFR-AK-CAZ-SC(2,2) 2,700.00 28.15 101.54 2,584.71 2.40 -0.21 3.35 -0.12 1.36 0.88 0.91 3.44 2.43 82.29 MWD+IFR-AK-CAZ-SC(2,2) 2,774.05 28.15 101.54 2,650.00 2.45 -0.21 3.62 -0.06 1.37 0.94 0.97 3.72 2.49 83.82 MIND(2,3) 2,800.00 28.15 101.54 2,672.88 2.45 -0.21 3.62 -0.06 1.37 0.94 0.97 3.72 2.49 83.82 MWD(2,3) 2,900.00 28.15 101.54 2,761.05 2.47 -0.21 3.99 0.07 1.38 1.00 1.04 4.09 2.49 86.06 MWD(2,3) 3,000.00 28.15 101.54 2,849.22 2.50 -0.21 4.47 0.20 1.40 1.06 1.13 4.56 2.52 88.47 MIND(2,3) 3,100.00 28.15 101.54 2,937.39 2.55 -021 5.03 0.32 1.43 1.13 1.23 5.10 2.57 90.56 MWD(2,3) 3,200.00 28.15 101.54 3,025.55 2.61 -0.21 5.64 0.45 1,47 1.20 1.34 5.70 2.62 92.25 MWD(2,3) 3,300.00 28.15 101.54 3,113.72 2.69 -0.21 6.29 0.58 1.51 1.27 1.46 6.34 2.69 93.58 MWD(2,3) 3,400.00 28.15 101.54 3,201.89 2.78 -0.21 6.96 0.71 1.55 1.34 1.59 7.00 2.77 94.65 MWD(2,3) 3,500.00 28.15 101.54 3,290.06 2.88 -0.21 7.65 0.83 1.60 1.41 1.72 7.69 2.85 95.50 MIND(2,3) 3,600.00 28.15 101.54 3,378.23 2.99 -0.21 8.36 0.96 1.66 1.49 1.86 8.40 2.95 96.19 MWD(2,3) 3,700.00 28.15 101.54 3,466.39 3.11 -0.21 9.09 1.09 1.71 1.57 2.00 9.11 3.05 96.77 MWD(2,3) 3,800.00 28.15 101.54 3,554.56 3.24 -0.21 9.82 1.21 1.78 1.65 2.15 9.84 3.15 97.25 MIND(2,3) 3,900.00 28.15 101.54 3,642.73 3.37 -0.21 10.55 1.34 1.84 1.73 2.30 10.57 3.27 97.65 MWD(2,3) 4,000.00 28.15 101.54 3,730.90 3.51 -0.21 11.30 1.47 1.91 1.82 2.45 11.32 3.39 98.00 MWD(2,3) 4,100.00 28.15 101.54 3,819.06 3.66 -0.21 12.04 1.60 1.98 1.90 2.60 12.06 3.51 98.30 MWD(2,3) 4,200.00 28.15 101.54 3,907.23 3.81 -0.21 12.79 1.72 2.05 1.99 2.76 12.81 3.64 98.56 MWD(2,3) 4,300.00 28.15 101.54 3,995.40 3.21 -0.21 6.77 -0.12 1.81 2.08 2.26 6.79 3.18 97.26 MWD+IFR-AK-CAZ-SC(3,3) 4,400.00 28.15 101.54 4,083.57 3.29 -0.21 7.06 -0.12 1.86 2.18 2.37 7.07 3.26 97.73 MWD+IFR-AK-CAZ-SC(3,3) 4,500.00 28.15 101.54 4,171.74 3.39 -0.21 7.35 -0.12 1.91 2.27 2A8 7.36 3.34 98.16 MWD+IFR-AK-CAZ-SC(3,3) 4,600.00 28.15 101.54 4,259.90 3.48 -0.21 7.65 -0.12 1.95 2.37 2.59 7.65 3.42 98.54 MWD+IFR-AK-CAZ-SC(3,3) 4,606.08 28.15 101.54 4,265.26 3.49 -0.21 7.66 -0.12 1.96 2.37 2.59 7.67 3.42 98.56 MWD+IFR-AK-CAZ-SC(3,3) 4,700.00 28.02 106.52 4,348.14 3.63 -0.21 7.83 -0.21 2.00 2.47 2.70 7.89 3.49 98.79 MWD+IFR-AK-CAZ-SC(3,3) 4,800.00 28.07 111.84 4,436.1 3.86 -0.24 7.90 -0.31 2.05 2.57 2.81 8.06 3.56 98.99 MWD+IFR-AK-CAZ-SC(3,3) 4,900.00 28.33 117.11 4,524.55 4.15 -0.28 7.92 -0.42 2.09 2.67 2.93 8.24 3.63 99.34 MWD+IFR-AK-CAZ-SC(3,3) 5,000.00 28.78 122.25 4,612.40 4.48 -0.34 7.91 -0.52 2.14 2.78 3.05 8.42 3.71 99.84 MWD+IFR-AK-CAZ-SC(3,3) 5,001.32 28.79 122.32 4,613.56 4.82 -0.42 7.86 -0.62 2.19 2.88 3.16 8.60 3.79 100.48 MWD+IFR-AK-CAZ-SC(3,3) 6/17/2015 9:42:23AM Page 3 COMPASS 5000.1 Build 65 • Schlumberger • ConocoPhillips Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-10 Project: Kuparuk River Unit TVD Reference: Plan:120+28 @ 148.00usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: Plan:120+28 @ 148.00usft(Doyon 141) Well: Plan:2S-10 North Reference: True Wellbore: Plan:2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10wp10[Wobbegong] Output errors are at 1.00 sigma Database: OAKEDMP2 Position uncertainty and bias at survey station Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi-major Semi-minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) ri (') (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (°) 5,081.25 29.29 126.30 4,683.45 4.82 -0.42 7.86 -0.62 2.19 2.88 3.16 8.60 3.79 100.48 MWD+IFR-AK-CAZ-SC(3,3) 5,100.00 29.42 127.22 4,699.79 4.82 -0.42 7.86 -0.62 2.19 2.88 3.16 8.60 3.79 100.48 MWD+IFR-AK-CAZ-SC(3,3) 5200.00 30.24 131.97 4,786,55 5.16 -0.51 7.80 -0.71 2.24 2.99 3.28 8.78 3.88 101.26 MWD+IFR-AK-CAZ-SC(3,3) 5,300.00 31.22 136.47 4,872,52 5.47 -0.62 7.74 -0.80 2.29 3.10 3.40 8.96 3.97 102.18 MWD+IFR-AK-CAZ-SC(3,3) 5,400.00 32.35 140.70 4,957.52 5.75 -0.73 7.67 -0.89 2.34 3.21 3.52 9.15 4.08 103.22 MWD+IFR-AK-CAZ-SC(3,3) 5,500.00 33.62 144.67 5,041.41 6.00 -0.86 7.62 -0.97 2.39 3.31 3.65 9.33 4.19 104.39 MWD+IFR-AK-CAZ-SC(3,3) 5,600.00 35.00 148.37 5,124.02 6.21 -1.00 7.58 -1.05 2.45 3.42 3.77 9.52 4.31 105.67 MW3+IFR-AK-CAZ-SC(3,3) 5,700.00 36.48 151.81 5,205.20 6.38 -1.14 7.57 -1.12 2.50 3.53 3.89 9.71 4.44 107.06 MWD+IFR-AK-CAZ-SC(3,3) 5,800.00 38.06 155.02 5,284.78 6.52 -1.29 7.58 -1.18 2.56 3.63 4.00 9.90 4.58 108.56 MWD+IFR-AK-CAZ-SC(3,3) 5,900.00 39.72 158.00 5,362.62 6.62 -1.45 7.63 -1.25 2.63 3.73 4.12 10.09 4.73 110.16 MW0+1FR-AK-CAZ-SC(3,3) 6,000.00 41.45 160.77 5,438.57 6.68 -1.60 7.70 -1.31 2.70 3.84 4.24 10.28 4.89 111.87 MWD+IFR-AK-CAZ-SC(3,3) 6,017.24 41.75 161.23 5,451.46 6.72 -1.76 7.80 -1.36 2.77 3.93 4.36 10.48 5.06 113.67 MWD+IFR-AK-CAZ-SC(3,3) 6,100.00 43.24 163.38 5,512.49 6.72 -1.76 7.80 -1.36 2.77 3.93 4.36 10.48 5.06 113.67 MWD+IFR-AK-CAZ-SC(3,3) 6,200.00 45.08 165.78 5,584.23 6.73 -1.93 7.93 -1.42 2.84 4.03 4.47 10.69 5.23 115.57 MWD+IFR-AK-CAZ-SC(3,3) 6,300.00 46.98 168.05 5,653.65 6.72 -2.09 8.10 -1.47 2.92 4.12 4.58 10.90 5.42 117.56 MWD+IFR-AK-CAZ-SC(3,3) 6,400.00 48.91 170.18 5,720.64 6.68 -2.26 8.29 -1.52 3.01 4.21 4.69 11.12 5.61 119.64 MWD+IFR-AK-CAZ-SC(3,3) 6,500.00 50.89 172.19 5,785.05 6.62 -2.43 8.50 -1.57 3.10 4.30 4.80 11.35 5.80 121.81 MWD+IFR-AK-CAZ-SC(3,3) 6,600.00 52.89 174.08 5,846.76 6.54 -2.59 8.75 -1.62 3.19 4.38 4.90 11.58 6.00 124.06 MW0+1FR-AK-CAZ-SC(3,3) 6,700.00 54.93 175.88 5,905.67 6.45 -2.76 9.02 -1.67 3.29 4.46 5.00 11.83 6.21 126.37 MWD+IFR-AK-CAZ-SC(3,3) 6,775.12 56.47 177.18 5,948.00 6.35 -2.92 9.31 -1.71 3.39 4.53 5.10 12.09 6.41 128.76 MWD+IFR-AK-CAZ-SC(3,3) 6,800.00 56.99 177.59 5,961.65 6.35 -2.92 9.31 -1.71 3.39 4.53 5.10 12.09 6.41 128.76 MWD+IFR-AK-CAZ-SC(3,3) 6,900.00 59.07 179.23 6,014.60 6.24 -3.09 9.62 -1.76 3.50 4.60 5.20 12.36 6.61 131.19 MWD+IFR-AK-CAZ-SC(3,3) 7,000.00 61.17 180.79 6,064,42 6.12 -3.25 9.95 -1.81 3.62 4.66 5.29 12.65 6.82 133.66 MWD+IFR-AK-CAZ-SC(3,3) 7,100.00 63.29 182.29 6,111.01 6.00 -3.41 10.30 -1.85 3.74 4.72 5.38 12.95 7.02 136.16 MWD+IFR-AK-CAZ-SC(3,3) 7,200.00 65.42 183.73 6,154.29 5.87 -3.57 10.67 -1.90 3.86 4.77 5.46 13.27 7.21 138.66 MW0+IFR-AK-CAZ-SC(3,3) 7,300.00 67.57 185.13 6,194.16 5.75 -3.73 11.06 -1.95 3.99 4.82 5.54 13.61 7.40 141.16 MW1D+IFR-AK-CAZ-SC(3,3) 7,400.00 69.73 186.48 6,230.57 5.63 -3.88 11.46 -1.99 4.12 4.87 5.62 13.96 7.58 143.64 MWD+IFR-AK-CAZ-SC(3,3) 7,500.00 71.90 187.80 6,263.44 5.52 -4.03 11.88 -2.04 4.25 4.90 5.69 14.33 7.76 146.07 MWD+IFR-AK-CAZ-SC(3,3) 7,600.00 74.08 189.08 6,292.69 5.42 -4.17 12.31 -2.08 4.39 4.94 5.76 14.72 7.93 148.45 MWD+IFR-AK-CAZ-SC(3,3) 7,700.00 76.26 190.3.4 6,318.29 5.34 -4.31 12.74 -2.13 4.54 4.97 5.82 15.12 8.09 150.76 MWD+IFR-AK-CAZ-SC(3,3) 7,800.00 78.45 191.57 6,340.18 5.29 -4.44 13.19 -2.18 4.68 4.99 5.88 15.54 8.24 152.99 MWD+IFR-AK-CA2-SC(3,3) 7,900.00 80.65 192.79 6,358.32 5.25 -4.57 13.65 -2.23 4.83 5.01 5.94 15.98 8.38 155.14 MWD+IFR-AK-CAZ-SC(3,3) 8,000.00 82.85 193.99 6,372.67 5.25 -4.69 14.11 -2.27 4.98 5.02 5.99 16.43 8.51 157.19 MWD+IFR-AK-CAZ-SC(3,3) 8,097.62 85.00 195.15 6,383.00 5.20 -4.81 14.51 -2.31 5.01 5.03 6.03 17.01 8.61 157.90 MIND(3,4) 8,100.00 85.00 195.15 6,383.21 5.20 -4.81 14.52 -2.30 5.01 5.03 6.03 17.02 8.60 157.93 MIND(3,4) 8,127.62 85.00 195.15 6,385.61 5.20 -4.81 14.67 -2.30 5.01 5.03 6.04 17.17 8.56 158.30 MWD(3,4) 8,20400 87.90 195.13 6,390.10 5.09 -4.94 15.11 -2.27 5.03 5.04 6.06 17.59 8.46 159.35 MWD(3,4) 8,299.74 91.88 195.10 6,390.29 5.06 -5.12 15.81 -2.23 5.09 5.04 6.08 18.23 8.39 160.97 MWD(3,4) 8,300.00 91.88 195.10 6,390.28 5.06 -5.12 15.81 -2.23 5.09 5.04 6.08 18.23 8.39 160.97 MWD(3,4) 8,400.00 91.88 195.10 6,386.99 5.14 -5.12 16.61 -2.20 5.17 5.04 6.10 18.95 8.37 162.71 MIND(3,4) 8,500.00 91.88 195.10 6,383.70 5.24 -5.12 17.50 -2.16 5.27 5.03 6.12 19.72 8.39 164.48 MWD(3,4) 8,509.15 91.88 195.10 6,383.40 5.37 -5.12 18.47 -2.13 5.39 5.03 6.14 20.57 8.45 166.26 MWD(3,4) 8,600.00 91.88 195.10 6,380.42 5.37 -5.12 18.47 -2.13 5.39 5.03 6.14 20.57 8.45 166.26 MWD(3,4) 8,700.00 91.88 195.10 6,377,13 5.52 -5.12 19.50 -2.09 5.54 5.03 6.17 21.47 8.52 167.98 MWD(3,4) 8,800.00 91.88 195.10 6,373.84 5.69 -5.12 20.58 -2.06 5.71 5.03 6.19 22.42 8.61 169.62 MIND(3,4) 8,900.00 91.88 195,10 6,370.55 5.87 -5.12 21.71 -2.02 5.89 5.02 6.22 23.43 8.70 171.18 MIND(3,4) 8.977.55 91.88 195.10 6,368.00 6.03 -5.12 22.61 -2.00 6.05 5.02 6.24 24.24 8.77 172.31 MWD(3,4) 9,000.00 91.44 195.13 6,367.35 6.08 -5.10 22.81 -1.99 6.10 5.02 6.25 24.44 8.77 172.53 MIND(3,4) 9,051.85 90.40 195.21 6,366.52 6.20 -5.04 23.15 -1.98 6.21 5.02 6.26 24.78 8.72 172.78 MIND(3,4) 9,100.00 90.40 195.21 6,366.18 6.31 -5.04 23.60 -1.96 6.31 5.02 628 25.21 8.72 173.24 MWD(3,4) 9,200.00 90.40 195.21 6,365.48 6.54 -5.04 24.81 -1.92 6.54 5.02 6.31 26.31 8.82 174.52 MIND(3,4) 9,300.00 90.40 195.21 6,364.78 6.78 -5.04 26.04 -1.89 6.78 5.02 6.34 27.45 8.91 175.70 MWD(3,4) 9,400.00 90.40 195.21 6,364.08 7.03 -5.04 27.30 -1.86 7.04 5.02 6.38 28.62 9.01 176.80 MIND(3,4) 9,500.00 90.40 195.21 6,363.37 7.29 -5.04 28.58 -1.82 7.30 5.02 6.41 29.82 9.09 177.80 MWD(3,4) 6/17/2015 9:42:23AM Page 4 COMPASS 5000.1 Build 65 • 1.-- Schlumberger • ConocoPhillips Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-10 Project: Kuparuk River Unit TVD Reference: Plan:120+28 @ 148.00usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: Plan:120+28 @ 148.00usft(Doyon 141) Well: Plan:2S-10 North Reference: True Wellbore: Plan:2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10wp10(Wobbegong] Output errors are at 1.00 sigma Database: OAKEDMP2 Position uncertainty and bias at survey station Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi-major Semi-minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (°) r) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (°) 9,800.00 90.40 195.21 6,362.67 5.72 -5.04 18.24 -2.33 5.72 5.02 6.62 20.25 8.81 166.39 MWD+IFR-AK-CAZ-SC(4,4) 9,700.00 90.40 195.21 6,361.97 5.80 -5.04 18.61 -2.33 5.81 5.02 6.67 20.56 8.86 167.12 MWD+IFR-AK-CAZ-SC(4,4) 9,800.00 90.40 195.21 6,361.27 5.90 -5.04 19.00 -2.33 5.90 5.02 6.71 20.89 8.92 167.85 MWD+IFR-AK-CAZ-SC(4,4) 9,900.00 90.40 195.21 6,360.57 6.00 -5.04 19.40 -2.33 6.00 5.01 6,76 21.23 8.98 168.56 MWD+IFR-AK-CAZ-SC(4,4) 10,000,00 90.40 195.21 6,359.87 6.10 -5.04 19.80 -2.33 6.10 5.01 6.81 21.57 9.04 169.27 MWD+IFR-AK-CAZ-SC(4,4) 10,100.00 90.40 195.21 6,359.16 6.20 -5.04 20.21 -2.33 6.21 5.01 6.86 21.93 9.10 169.96 MWD+IFR-AK-CAZ-SC(4,4) 10,200.00 90.40 195.21 6,358.46 6.31 -5.04 20.63 -2.33 6.31 5.01 6.91 22.30 9.17 170.64 MWD+IFR-AK-CAZ-SC(4,4) 10,300.00 90.40 195.21 6,357,76 6.42 -5.04 21.06 -2.33 6.43 5.01 6.96 22.67 9.23 171.31 MWD+IFR-AK-CAZ-SC(4,4) 10,400.00 90.40 195.21 6,357.06 6.53 -5.04 21.50 -2.33 6.54 5.01 7.01 23.05 9.29 171.96 MWD+IFR-AK-CAZ-SC(4,4) 10,500.00 90.40 195.21 6,356.36 6.65 -5.04 21.94 -2.33 6.66 5.01 7.06 23.45 9.35 172.59 MWD+IFR-AK-CAZ-SC(4,4) 10,600.00 90.40 195.21 6,355.66 6.77 -5.04 22.39 -2.33 6.78 5.01 7.12 23.84 9.41 173.21 MWD+IFR-AK-CAZ-SC(4,4) 10,700.00 90.40 195.21 6,354.96 6.89 -5.04 22.84 -2.33 6.90 5.01 7,17 24.25 9.47 173.80 MWD+IFR-AK-CAZ-SC(4,4) 10,800.00 90.40 195.21 6,354.25 7.02 -5.04 23.30 -2.33 7.02 5.01 7.22 24.67 9.52 174.38 MWD+IFR-AK-CAZ-SC(4,4) 10,900.00 90.40 195.21 6,353.55 7.14 -5.04 23.77 -2.33 7.15 5.01 7.28 25.09 9.58 174.94 MWD+IFR-AK-CAZ-SC(4,4) 10,958.47 90.40 195.21 6,353.14 7.22 -5.04 24.04 -2.33 7.22 5.01 7.31 25.33 9.61 175.26 MWD+IFR-AK-CAZ-SC(4,4) 10,998.91 90.00 195.16 6,353.00 7.28 -5.01 24.14 -2.32 7.28 5.01 7.33 25.43 9.61 175.32 MWD+IFR-AK-CAZ-SC(4,4) 11,000.00 90.00 195.16 6,353.00 7.28 -5.01 24.14 -2.32 7.28 5.01 7.33 25.43 9.60 175.33 MWD+IFR-AK-CAZ-SC(4,4) 11,100.00 90.00 195.16 6,353.00 7.41 -5.01 24.61 -2.32 7.41 5.01 7.39 25.86 9.66 175.85 MWD+IFR-AK-CAZ-SC(4,4) 11,200.00 90.00 195.16 6,353.00 7.54 -5.01 25.09 -2.32 7.54 5.01 7.44 26.30 9.71 176.36 MWD+IFR-AK-CAZ-SC(4,4) 11,300.00 90.00 195.16 6,353.00 7.68 -5.01 25.57 -2.32 7.68 5.01 7.50 26.74 9.76 176.85 MWD+IFR-AK-CAZ-SC(4,4) 11,400.00 90.00 195.16 6,353.00 7.81 -5.01 26.06 -2.32 7.81 5.01 7.56 27.19 9.81 177.33 MWD+IFR-AK-CAZ-SC(4,4) 11,480.02 90.00 195.16 6,353.00 7.93 -5.01 26.45 -2.32 7.93 5.01 7.61 27.55 9.85 177,69 MWD+IFR-AK-CAZ-SC(4,4) 11,500.00 89.60 195.16 6,353.07 7.96 -4.97 26.50 -2.32 7.95 5.01 7.62 27.60 9.85 177.72 MWD+IFR-AK-CAZ-SC(4,4) 11,513.05 89.34 195.17 6,353.19 7.98 -4.95 26.49 -2.32 7.97 5.01 7.63 27.60 9.84 177.69 MWD+IFR-AK-CAZ-SC(4,4) 11,600.00 89.34 195.17 6,354.19 8.10 -4.95 26.70 -2.32 8.09 5.01 7.68 27.81 9.83 177.79 MWD+IFR-AK-CAZ-SC(4,4) 11,700.00 89.34 195.17 6,355.35 8,24 -4.95 27.19 -2.32 8.23 5.01 7.74 28.26 9.88 178.23 MWD+IFR-AK-CAZ-SC(4,4) 11,800.00 89.34 195.17 6,356.50 8.39 -4.95 27.69 -2.32 8.38 5.01 7.80 28.73 9.92 178.65 MWD+IFR-AK-CAZ-SC(4,4) 11,900.00 89.34 195.17 6,357.65 8.53 -4.95 28.19 -2.32 8.52 5.01 7.86 29.20 9.97 179.06 MWD+IFR-AK-CAZ-SC(4,4) 12,000.00 89.34 195.17 6,358.80 8.68 -4.95 28.69 -2.32 8.67 5.01 7.93 29.67 10.01 179.45 MWD+IFR-AK-CAZ-SC(4,4) 12,100.00 89.34 195.17 6,359.96 8.82 -4.95 29.19 -2.32 8.81 5.01 7.99 30.14 10.05 179.83 MWD+IFR-AK-CAZ-SC(4,4) 12,200.00 89.34 195.17 6,361.11 8.97 -4.95 29.70 -2.32 8.96 5.02 8.05 30.62 10.10 0.20 MWD+IFR-AK-CAZ-SC(4,4) 12,300.00 89.34 195.17 6,362.26 9.12 -4.95 30.21 -2.32 9.11 5.02 8.12 31.11 10.14 0.55 MWD+IFR-AK-CAZ-SC(4,4) 12,400.00 89.34 195.17 6,363.41 9.27 -4.95 30.72 -2.32 9.26 5.02 8.18 31.60 10.18 0.89 MWD+IFR-AK-CAZ-SC(4,4) 12,500.00 89.34 195.17 6,364.57 9.42 -4.95 31.24 -2.32 9.41 5.02 8.25 32.09 10.22 1.21 M9'D+IFR-AK-CAZ-SC(4,4) 12,600.00 89.34 195.17 6,365.72 9.57 -4.95 31.75 -2.32 9.57 5.02 8.31 32.58 10.25 1.53 MWD+IFR-AK-CAZ-SC(4,4) 12,700.00 89.34 195.17 6,366.87 9.73 -4.95 32.27 -2.32 9.72 5.02 8.38 33.08 10.29 1.83 MWD+IFR-AK-CAZ-SC(4,4) 12,800.00 89.34 195.17 6,368.03 9.88 -4.95 32.79 -2.32 9.87 5.02 8.45 33.58 10.33 2.13 MWD+IFR-AK-CAZ-SC(4,4) 12,900.00 89.34 195.17 6,369.18 10.04 -4.95 33.32 -2.32 10.03 5.02 8.51 34.08 10.36 2.41 MWD+IFR-AK-CAZ-SC(4,4) 13,000.00 89.34 195.17 6,370.33 10.19 -4.95 33.84 -2.32 10.18 5.02 8.58 34.58 10.39 2.68 MWD+IFR-AK-CAZ-SC(4,4) 13,100.00 89.34 195.17 6,371.48 10.35 -4.95 34.37 -2.32 10.34 5.02 8.65 35.09 10.43 2.94 MVVD+IFR-AK-CAZ-SC(4,4) 13,200.00 89.34 195.17 6,372.64 10.50 -4.95 34.90 -2.32 10.50 5.03 8.72 35.60 10.46 3.20 MWD+IFR-AK-CAZ-SC(4,4) 13,300.00 89.34 195.17 6,373.79 10.66 -4.95 35.43 -2.32 10.66 5.03 8.78 36.11 10.49 3.44 MWD+IFR-AK-CAZ-SC(4,4) 13,400.00 89.34 195.17 6,374.94 10.82 -4.95 35.96 -2.32 10.81 5.03 8.85 36.63 10.52 3.68 MWD+IFR-AK-CAZ-SC(4,4) 13,500.00 89.34 195.17 6,376.09 10.98 -4.95 36.49 -2.32 10.97 5.03 8.92 37.15 10.55 3.91 MWD+IFR-AK-CAZ-SC(4,4) 13,600.00 89.34 195.17 6,377.25 11.14 -4.95 37.02 -2.32 11.13 5.03 8.99 37.66 10.58 4.13 MWD+IFR-AK-CAZ-SC(4,4) 13,700.00 89.34 195.17 6,378.40 11.30 -4.95 37.56 -2.32 11.29 5.03 9.06 38.19 10.61 4.35 MWD+IFR-AK-CA2-SC(4,4) 13,800.00 89.34 195.17 6,379.55 11.46 -4.95 38.10 -2.32 11.45 5.03 9.13 38.71 10.64 4.55 M1MD+IFR-AK-CAZ-SC(4,4) 13,900.00 89.34 195.17 6,380.70 11.62 -4.95 38.63 -2.32 11.62 5.03 9.20 39.23 10.66 4.76 MWD+IFR-AK-CAZ-SC(4,4) 14,000.00 89.34 195.17 6,381.86 11.78 -4.95 39.17 -2.32 11.78 5.03 9.27 39.76 10.69 4.95 MWD+IFR-AK-CAZ-SC(4,4) 14,099.10 89.34 195.17 6,383.00 11.94 -4.95 39.71 -2.32 11.94 5.03 9.34 40.28 10.72 5.14 MWD+IFR-AK-CAZ-SC(4,4) 6/17/2015 9:42:23AM Page 5 COMPASS 5000.1 Build 65 • • Schlumberger ConocoPhillips Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-10 Project: Kuparuk River Unit TVD Reference: Plan:120+28 @ 148.00usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: Plan:120+28 @ 148.00usft(Doyon 141) Well: Plan:2S-10 North Reference: True Wellbore: Plan:2S-10 Survey Calculation Method: Minimum Curvature Design: 2S-10wp10[Wobbegongj Output errors are at 1.00 sigma Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name ("I C') 2,774.05 2,650.00 10-3/4"x 13-1/2" 10-3/4 13-1/2 8,097.62 6,383.00 7-5/8"X 9-7/8" 7-5/8 9-7/8 14,099.10 6,383.00 4 1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (1 (1 6,775.12 5,948.00 HRZ(top) 0.00 8,097.62 6,383.00 A4 0.00 [-I:Ian Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 600.00 600.00 0.00 0.00 KOP:Start 1.5°/100'DLS,30°TF,for 200.09' 800.09 800.00 4.54 2.62 Start 2.5°/100'DLS,0"TF,for 685,43' 1,485.52 1,469.00 123.14 71.10 Hold for 106.51' 1,592.03 1,569.00 154.90 89.43 Start 3.5°/100'DLS,110.04°TF,for 812.94' 2,404.97 2,324.59 239.45 352.74 Hold for 2201.11' 4,606.08 4,265.26 31.61 1,370.33 Start 2.5°/100'DLS,95.53°IF,for 3491.54' 8,097.62 6,383.00 -2,276.69 1,811.91 Hold for 30' 8,127.62 6,385.61 -2,305.54 1,804.10 Start 4°/100'DLS,-0.36°TF,for 172.12' 8,299.74 6,390.29 -2,471.53 1,759.23 Hold for 677.81' 8,977.55 6,368.00 -3,125.57 1,582.72 Start 2°1100'DLS,176.07°TF,for 74.31' 9,051.85 6,366.52 -3,197.28 1,563.30 Hold for 1906.61' 10,958.47 6,353.14 -5,037.10 1,063.25 Start 1°/100'DLS,-173.67°TF,for 40.44' 10,998.91 6,353.00 -5,076.13 1,052.66 Hold for 481.11' 11,480.02 6,353.00 -5,540.50 926.84 Start 2°1100'DLS,179.38°TF,for 33.03' 11,513.05 6,353.19 -5,572.38 918.20 Hold for 2586.05' 14,099.10 6,383.00 -8,068.18 241.62 TD:14099.1'MD,6383'TVD Checked By: Approved By: Date: 6/17/2015 9:42:23AM Page 6 COMPASS 5000.1 Build 65 • • Pool Report Permit Pack • • 0 •m 3QO O ooaooss O ql Uhl w rcarezrcceEMI I Qfja NU UU 88 U 8-4)2 G p 34 1 _o 0 d N ' CO .08'0, $ 1 0 �12elelnm wmw � M a o 4 W o O m .� T__. 3 O W CO a �� aaaaa.g , / ry 1 V Ye V�p F,H_�p04/ 3 C)G�i�00o' .� 0000=] yi �'Mry O i O O �` ama xwww U O E.dn1-12d O Om Od00000 004 c)NNrN��N oI o 'C N...,... ...„..,,,......, N oO N c O t O Na_ o ++ wN��7 N '_ .Y .. 33CmC 1*._____!....z.--.,...:1! /' • m .. + . co t alW O _�, 3 CO E I w w 1 1 , --N‘ .*, (0,-- c:, O W 1 : VIIII 00.„3 ' a o a O m al C To 0 ug- • \ o N et7 7,- di 4 0 O iv - m N N N d ►0 IM - 2 n illik1 m ro CO)V♦ O 1 ‘)11,1111 n J 3� c 76,4 m o a N , w o 1 3� 0 v co ;i — —' o_ m 3a p.., ^3 CijNNN Nw c O OE O O O O O N (u!/14% 0002) (+7y}aoN/(-)u}dos CO • 0 il • • • • • • • • • • •4 1 .1111 ill , iCi I M • lr, $y:41 • • • fi ligi a • / i0 0 I '► • • 0 r O T". N • I } • °' • • . • M - • �► a) C 0 Cr) •• $ .O •• ••CO • CO • T"' CO • • . • • •• • • • lks5 • e M • • \ . t . ►e® . - ►• • O 4) • 0 •• O h r • O14--.' r N • • 011 5 C3 1 I M O ; 0 N O 6 N a d jCh N I a A I 0)C 0) CD O P P 1 N • • I 2S-10wp10 Surface Location ____ ,...______________________________........._____J Qz, CPAI Coordinate Con �� > .0 From: To: Datum: NAD83 Region: alaska Datum: 1NAD27 z.1 Region: f alaska C Latitude/Longitude !Decimal Degrees _I C Latitude/Longitude !Decimal Degrees 2.11 r UTM Zone: 1 E South I r" UTM Zone:r---- IT rue 1 South r: State Plane Zone: q Units: Fri—.-;i,. a State Plane Zone: q . Units: us-ft . C Legal Description(NAD27 only) C Legal Description(NAD27 only) Starting Coordinates: Ending Coordinates: X: 11621077.45 X: 1 481044.128186967 Y: 15929729.31 Y: 1 5929979.7234431 i i Transform Quit I Help F 2S-10wp10 Intermediate Casing E. CPAi Coordinate Converter From: To: Datum: INAD83 Region: Ialaska ± Datum: 1NAD27 j Region: alaska C Latitude/Longitude [Decimal Degrees +i ' C Latitude/Longitude [Decimal Degrees C UTM Zone: r- E South 1 C UTM Zone: True 1- South C. State Plane Zone: q Units: us-11 . a State Plane Zone: q . Units: us ft . C Legal Description(NAD27 only) l Legal Description(NAD27 only) Starting Coordinates: ..•-,i Ending Coordinates: X 11622883.34 X: 1482850.025509912 i i Y: 15927448.21 Y: 15927698.64744913 I i ....,.... ._....Transform...._...,. ... Quit I Help — — -- -... .. _ ani • • F 2S-10wp10 TD r f3 CPL: Coordinate Ccni.err.er ' a From: T Datum: INAD83 .. .1 Region: lalaska Datum: jN,4D27 j Region: Ialaska C Latitude/Longitude !Decimal Degrees +� C Latitude/Longitude !Decimal Degrees C UTM Zone: r South r UTM Zone: True r South C: State Plane Zone: 4 Units: , us ft I State Plane Zone: 4 Units: us-rt I C Legal Description(NAD27 only) C Legal Description(NAD27 only) Starting Coordinates: Ending Coordinates: X: 11621298.37 X: 1 481264.934952431 V: 15921667.34 Y: 15921917.92482555 I i Transform 1 Quit Help i I • 2S-10wp10 Surface Location t!ti, CPA)Coordinate Converter From: To: Datum: 1NAD83 A Region: Jalaska A 1 Datum: [NAD27 A Region: lalaska A ( Latitude/Longitude !Decimal Degrees A. i r. Latitude/Longitude 'Decimal Degrees zi (... UTM Zone: 1 r South C UTM Zone: ITUT r South 4' State Plane Zone: ri—D, Units: 1-7: us-ft ... c. State Plane Zone: F----2.] Units: 1171;:it r. t, t tt ,t,, ., .., „,,,,,,1 , 4. Legal Description(NAD27 only) ,.,. Starting Coordinates: Legal Description X: 11621077.45 Township: r"-— iciio [Nj Range: r im ii -Ar 1 1 Y: 15929729.31 Meridian: lu .,,,J Section:117 i ! A / r---. , i 15F. . 13068.6061 'FEL aml 11526.1734 i/ . Transform 1 Quit I Help I i 2S-10wp10 Intermediate Casing .,,i I tn. CPA!Coordinate Convertet ''',',------'-'--ll'''L -iP-4-34-0,1 From: . To: Datum: 1NAD83 .J Region: lalaskaI Datum: 1NAD 27 A Region: lalaska ..7....1 C Latitude/Longitude 'Decimal DegreesI , C Latitude/Longitude !Decimal Degrees :..7..1 ii r UTM Zone:F.-- r South , r UTM Zone: I 'True r South 4* State Plane Zone:ri--_:,],.. Units: ijiTt3 c State Plane Zone: ri--- J Units: 17;;T:,.] 4' Legal Description(NAD27 only) Starting Coordinates: Legal Description X: 11622883.34 Township: 1010 [N . Range: 15)-(i— Ir .• Y: 15927448.21 Meridian: lu I S ection:r2., via:- .---A, 165.601798 FEi.----j 15001.2042 i ... . . .... . . : . i Transform Quit I Help 1 • 0 F 2S-1 Owp1 0 TD tf) CPA1 Coordinate Con ,,verter , 44,M.;;e0irl.w. 4 v From i To: 1 Datum: INAD 83 _7:1 Region: Jalaska ...m.1 ' 1 Datum: INAD27 ,I Region: Ialaska oml C Latitude/Longitude [Decimal Degrees 2d, , C Latitude/Longitude 'Decimal Degrees 2:1 C UTM Zone: E r- South C UTM Zone: True r South (41.111 State Plane Zone: ii----ii. Units: Fir id C State Plane Zone: rit .11, Units: rj;1TE1.i.1 4' Legal Description(NAD27 onbq Starting Coordinates: Legal Description X: 11621298.37 Township: I— I ai o 11471, Range: r---- 008 i-E---...A. Y: 15921667.34 Meridian: lu ..:1 Section:129 P iFiz-.A. 1570.63776 ITEE:vi 11309.2869 Transform I Quit I Help As - built REV DATE BY CK APP DESCRIPTION REV DATE BY APP DESCRIPTION 1 5/28/15 SZ JAH Created Drawing Per K140173ACS i t 3 W W 19 17. 16 16 li/} {\1 13 1/ 16 i 17 f ;Ft6 0. NOTES: DS2A i 1.1..!>2. cc cc bSiC• 1. BASIS OF LOCATION AND ELEVATION IS DS2S ` V15 26 '1'' 22 ' 23,:WS� ,l 11 26 ,CPF2t, MONUMENTATION PER LOUNSBURY & ASSOC. 2a i• 27 1,20•1 '2s ,Sgi \a 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, 23 23 \ 0 ern —I I 9L, ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES a DUN � . D ,' ARE NAD 27. • y� ! pc,,:-.A $ •[t DS20 / T11N 3. ELEVATIONS ARE B.P.M.S.L pa,` a Kc:- 3 °�ti=,M 1 T it 6.. )3 v 4 3 4. ALL CONDUCTORS ARE LOCATED WITHIN PROTRACTED • € .� i ' 2 7 c16 �{ 9 19S 71 r1'l 7 9. G 9 }\10 SECTION 17, TOWNSHIP 10 NORTH, RANGE 8 EAST, /� t, \ f ,, � ,l '\� , UMIAT MERIDIAN. r` ,11/. '3 ' S26S i'c�3 V 3 13 16'' Y,11 ‘11(15 1711 5. DATES OF SURVEY: 5-2 THRU 5-27-15 FIELD BOOKS — ,= L15-28, L15-29, L15-32, L15-35 ' i �� ';' '� 2211 �' r t3 :.w\ x, 2 .� '023 24(_ 19 ;ti) '41 2$ 6. ALL DISTANCES SHOWN ARE TRUE. PROJECT ' i T , LOCATION \ � I 1 3 ,739 1v`' z: I 27 fi---�, 2s �39 23 as 21 N ,° i a' 11 t Y---- 6 31 I 31 347`Y35 36 .131 32 33 3 l ` ` VICINITY MAP NTS 1 \\------..I I 3� -c,(P. DS2S --1 6 40 ® 0 14 12 ,10 ® ® ® ® ® 3 21 , o3 7 5 i ® 13 11 9 I 1 LEGEND 1 AS—BUILT 17 16 ILT CONDUCTOR LOCATION 20+21 GRAPHIC SCALE 0 100 200 400 LOUNSBURY SEE PAGE 2 OF 2 FOR LOCATIONS — & ASSOCIATES, INC. 1 inch = 200 ft. SURVEYORS ENGINEERS PLANNERS AREA:2S MODULE: XXXX UNIT: D2 06-nocoPhillips DS2S WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD FILE NO. DRAWING NO. PART: REV: LK6219d24 5/28/15 CEA—D2SX-6219D24 1 OF 2 1 REV DATE BY CK APP ,DESCRIPTION REV DATE BY APP DESCRIPTION 1 5/28/15 SZ JAH Created Drawing Per K140173ACS CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 17, T. 10 N., R. 8 E., UMIAT MERIDIAN Well NAD 27 NAD 27 Section Elev. No. ASP Coordinates Geographic Coordinates Offset. Y X Lat. Long. F.S.L F.E.L. O.G. PAD 1 5,930,036.15 481,309.02 70' 13' 12.058" 150' 09' 02.839" 2268' 1261' 112.0' 120.0' 2 5,930,029.92 481,279.68 70' 13' 11.996" 150' 09' 03.690" 2262' 1291' 112.4' 120.0' 3 5,930,023.62 481,250.32 70' 13' 11.933" 150' 09' 04.543" 2255' 1320' 112.1' 120.0' 4 5,930,017.59 481,221.00 70' 13' 11.873" 150' 09' 05.394" 2249' 1349' 112.0' 120.0' 5 5,930,010.88 481,191.79 70' 13' 11.806" 150' 09' 06.242" 2243' 1378' 111.8' 120.0' 6 5,930,004.80 481,162.27 70' 13' 11.746" 150' 09' 07.098" 2236' 1408' 111.5' 120.0' 7 5,929,998.58 481,133.41 70' 13' 11.684" 150' 09' 07.936" 2230' 1437' 111.4' 120.0' 8 5,929,992.42 481,103.50 70' 13' 11.622" 150' 09' 08.804" 2224' 1467' 111.1' 120.0' 9 5,929,986.08 481,074.22 70' 13' 11.559" 150' 09' 09.654" 2217' 1496' 111.0' 120.0' 10 5,929,979.72 481,044.13 70' 13' 11.496" 150' 09' 10.528" 2211' 1526' 111.1' 120.0' 11 5,929,973.68 481,015.40 70' 13' 11.436" 150' 09' 11.362" 2205' 1555' 111.1' 120.0' 12 5,929,968.02 480,986.10 70' 13' 11.380" 150' 09' 12.212" 2199' 1584' 110.9' 120.0' 13 5,929,961.45 480,956.55 70' 13' 11.314" 150' 09' 13.070" 2192' 1614' 110.6' 120.0' 14 5,929,955.02 480,927.39 70' 13' 11.250" 150' 09' 13.920" 2186' 1643' 110.5' 120.0' '. SURVEYOR'S CERTIFICATE s Gj•,• ~ �•• 49th `,O\ T. I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND 0 ° 1LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND 1040t# JEREMIAH F. CORNELLViir 'O��" LS-12663 ••• THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT F,s AS OF MAY 27, 2015. PESSIONN- LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS AREA:2S MODULE: XXXX UNIT: D2 .. o P illips DS2S WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD FILE NO. DRAWING NO. PART: REV: LK6219d24 5/28/15 CEA-D2SX-6219D24 2 OF 2 1 • 2S-10 Drilling Hazards Summary 13-1/2" Hole/ 10-3/4" Casing Interval Event Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Low If observed-control drill,reduce pump rates,reduce drilling fluid temperatures,Additions of Lecithin. Anti-collision Low Run Gyro as needed for magnetic interference.Third well on pad,so no real anti-collision risk,only with future plans. Gravel/Sand Sloughing Low Increase mud weight/viscosity,High viscosity sweeps. Monitor fill on connections. Hole Swabbing/Tight Hole on Moderate Circulate hole clean prior to trip. Proper hole fill(use of Trips trip sheets),Pumping out of hole as needed. Lost circulation Low Prevent by keeping hole clean. If losses occur-reduce pump rates and mud rheology,use LCM Unsuccessful cement job Moderate Use lower density cement slurry.Adjust the mud properties prior pump cement.Use proper pump rate. 9-7/8" Hole/7-5/8" Casing Interval Event Risk Level Mitigation Strategy Shale stability Moderate For the unstable HRZ and Kalubik shales with high inclination control with higher MW and proper tripping practices to avoid surging or swabbing. Minimize pressure cycling by stripping out using MPD to eliminate swab. High ECD and swabbing with Low Condition mud prior to trips. Monitor ECD's with PWD higher MW's required tool while drilling across pay interval. Backream out on trips as a last resort. Strip out with MPD to eliminate swab. Lost circulation Low Use PWD and TAD to monitor hole cleaning. Reduced pump rates,adjust mud rheology,add LCM. Use GKA LC decision tree. Keep ECD below known frac gradient of—13.0 ppg in Tarn formations crossed in intermediate. Hole cleaning Low Use PWD and TAD to monitor hole cleaning.Control the ROP and use the best hole cleaning practice. Stuck pipe Low Good hole cleaning,stabilized BHA,proper mud weight, PWD monitor ECD. Abnormal Reservoir Pressure Moderate Follow mud weight schedule and do not fall behind. Adjust mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Utilize MPD to contain any pressure and prevent allowing an influx in the event pressure is higher than expected. 6-3/4" Hole/4-1/2" Liner Interval Event Risk Level Mitigation Strategy High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with PWD higher MW's required tool while drilling across pay interval. Backream out on trips as a last resort. Strip out with MPD to eliminate swab. Abnormal Reservoir Pressure Moderate Follow mud weight schedule and do not fall behind. Adjust mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Utilize MPD to contain any pressure and prevent allowing an influx in • • the event pressure is higher than expected. Lost Circulation Moderate Use PWD and TAD to monitor hole cleaning. Reduced pump rates,adjust mud rheology,add LCM. Use GKA LC decision tree. Use of MPD will allow lower mud weights to reduce ECD while shutting on connections to prevent any potential influx. Stuck pipe Moderate Good hole cleaning,stabilized BHA,proper mud weight to minimize differential stuck,PWD monitor ECD. Hole swabbing on trips Moderate Monitor proper hole fill while tripping,good hole cleaning.Backream out to intermediate shoe,then utilize MPD to strip out and eliminate swab. 2S-10 Schlumberger CemCADE Preliminary Job Design 10-3/4" Surface Casing (V1) Preliminary Job Design based on limited input data.For estimate purposes only. Volume Calculations and Cement Systems Rig: Doyon 141 Volumes are based on 200% excess in the permafrost and 50% excess below the Location: Kuparuk permafrost. The top of the tail slurry is designed to be at 2274' MD. Client: CPAI Revision Date: June 15, 2015 Prepared by: Jenna Houston Location:Anchorage, AK Lead Slurry Minimum pump time: -230 min. (pump time plus 120 min.) Phone: (907)263-4207 DeepCRETE @ 11 ppg-1.91 ft3/sk Mobile: (907)223-8916 email:jhouston2@slb.com 1.339 ft3/ft x(110') x 1.00 (no excess) = 148 ft3 0.3637 ft3/ft x(1373- 110') x 3.00 (200% excess) = 1379 ft3 < TOC at Surface 0.3637 ft3/ft x(2274- 1373) x 1.50 (50% excess) = 492 ft3 148 ft3+ 1379 ft3+492 ft3= 2019 ft3 2019 ft3/1.91 ft3/sk = 1058 sks (-1068 sks) Please have extra DeepCRETE on location for top out. Tail Slurry Minimum pump time: -180 min. (pump time plus 120 min.) Previous Csg. DeepCRETE @ 12 ppg - 1.63 ft3/sk < 20", 106.5#casing at 110'MD 0.3637 ft3/ft x(2774-2274)x 1.50 (50% excess) = 273 ft3 0.5400 ft3/ft x 80' (Shoe Joint) = 44 ft3 273 ft3+44 ft3 = 317 ft3 317 ft3/1.63 ft3/sk = 195 sks Round up to 205 sks BHST=67°F, Estimated BHCT=75°F. (Based on 2.1°F/100 ft. from surface) < Base of Permafrost at PUMP SCHEDULE 1373'MD(-1,363'ND) Stage Cumulative Stage Pump Rate Volume Stage Time Time (bpm) (bbl) (min) (min) CW 100 7.00 100.0 14.3 14.3 MUDPUSH II 7.00 100.0 14.3 28.6 Pause 0.00 0.0 5.0 33.6 < Top of Tail at 11 ppg DeepCRETE 7.00 359.2 51.3 84.9 2,274'MD Surface Tail 7.00 56.3 8.0 92.9 DeepCRETE Slurry Pause 0.00 0.0 5.0 97.9 Fresh Water 7.00 10.0 1.4 99.3 Pause 0.00 0.0 5.0 104.3 Mud 8.00 239.1 29.9 134.2 Mud 3.00 10.0 3.3 137.5 < 10-3/4",45.5#casing in 13.5"OH MUD REMOVAL Expected Mud Properties:9.5 ppg, Pv<20, Ty<20 TD at 2,774'MD Spacer Properties: 10.5 ppg MudPUSH* II, Pv 17-21, Ty 20-25 (2,650'TVD) Centralizers: As per CPAi program. *Mark of Schlumberger • • 2S-10 Schlumberger CemCADE Preliminary Job Design 7-5/8" Intermediate Casing Rig: Doyon 141 1St Stage (V1) Location: Kuparuk Client: CPAI Revision Date: June 15, 2015 Volume Calculations and Cement Systems Prepared by:Jenna Houston Volumes are based on 20% excess. The topof the 1st stage tail slurrydesigned to be Location:Anchorage, AKg is g Phone: (907)263-4207 at-6,043' MD. Mobile: (907)223-8916 email:jhouston2@slb.com Tail Slurry Minimum pump time: -240 min. (pump time plus 120 min.) 15.8 ppg GASBLOK*+ adds- 1.17 ft3/sk 0.2148 ft3/ft x(8097'-6043')x 1.20 (20% excess) = 530 ft3 0.2578 ft3/ft x 80' (Shoe Joint) = 21 ft3 530 ft3+21 ft3= 551 ft3 551 ft3/1.17 ft3/sk = 471 sks Round up to 481 sks Previous Csg. < 10-3/4",45.5.#casing BHST= 154°F, Estimated BHCT= 110°F. at 2,774'MD (BHST calculated using a gradient of-2.1°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) MUDPUSH II 5.00 50.0 10.0 10.0 Pause 0.00 0.0 5.0 15.0 15.8 ppg GASBLOK* 5.00 98.0 19.6 34.6 < Stage tool at 5,228'MD Slurry Pause 0.00 0.0 5.0 39.6 Fresh Water 5.00 10.0 2.0 41.6 Pause 0.00 0.0 5.0 46.6 Mud 5.00 320.0 64.0 110.6 Mud 3.00 20.0 6.7 117.3 Mud 1.40 18.1 12.9 130.2 < Top of Cement at -6,043 MD MUD REMOVAL Expected Mud Properties:-11.1 ppg, Pv<20, Yield Point<25. Spacer Properties: 12.0 ppg MudPUSH* II, Pv=20-24, Yield Point=20-30 < 7-5/8",29.7#casing in 9-7/8"OH Centralizers: As per program TD at-8,097 MD (6,383'TVD) Mark of Schlumberger • 2S-02 Schlumberger CemCADE Preliminary Job Design 7-5/8" Intermediate Casing Rig: Doyon 141 2nd Stage (V1) Location: Kuparuk Client: CPAI Revision Date: June 15, 2015 Volume Calculations and Cement Systems Prepared by: Jenna Houston Volumes are based on 20% excess. The top of the 2nd stage tail slurry is designed to be Location: Anchorage, AK Phone: (907)263-4207 at-4,659 MD, 500' above the C37. Mobile: (907)223-8916 email:jhouston2@slb.com Tail Slurry Minimum pump time: -190 min. (pump time plus 120 min.) 15.8 ppg Class G + GASBLOK*+adds- 1.17 ft3/sk 0.2148 ft3/ft x(5228'-4659')x 1.20 (20% excess) = 147 ft3 147 ft3= 147 ft3 147 ft3/ 1.17 ft3/sk = 126 sks Previous Csg. Round up to 136 sks < 10-3/4",45.5.#casing at 2,774'MD BHST= 116°F, Estimated BHCT= 79°F. (BHST calculated using a gradient of-2.1°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Cumulative Stage Time Stage Volume Time (bpm) (bbl) (min) (min) MUDPUSH II 5.00 40.0 8.0 8.0 Pause 0.00 0.0 5.0 13.0 15.8 ppg GASBLOK* 5.00 26.1 5.2 18.2 Slurry Pause 0.00 0.0 5.0 23.2 Fresh Water 5.00 10.0 2.0 25.2 Pause 0.00 0.0 5.0 30.2 Mud 5.00 220.0 44.0 74,2 Mud 3.00 10.0 3.3 77.5 < Top of Cement at -4,659 MD MUD REMOVAL Expected Mud Properties:-11.1 ppg, Pv< 20, Yield Point < 25. Spacer Properties: 12.0 ppg MudPUSH* II, Pv= 20-24, Yield Point= 20-30 < 7-5/8",29.7#casing Centralizers: As per program in 9-7/8"OH Stage tool at-5,228' MD (4,811'11/D) Mark of Schlumberger i • Bettis, Patricia K (DOA) From: Voss, Jake <Jake.Voss@conocophillips.com> Sent: Wednesday, June 24, 2015 12:34 PM To: Bettis, Patricia K (DOA) Subject: Re: [EXTERNAL]KRU 2S-10: Permit to Drill Application Good afternoon Patricia, The well will be produced for roughly 6 months depending on production rates and pressures. Thanks, Jake Voss On Jun 24, 2015, at 12:28 PM, Bettis, Patricia K(DOA) <patricia.bettis@alaska.gov<mailto:patricia.bettis@alaska.gov» wrote: Good afternoon Jake, The permit to drill application states that the well will be pre-produced. Will this be for a duration of less than 3 months or more? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907) 793- 1238 or patricia.bettis@alaska.gov<mailto:patricia.bettis@alaska.gov>. 1 • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. r` • • TRANSMITTAL LETTER CHECKLIST WELL NAME: K R(,A, .2S - /O PTD: Q16- - 110 Development /Service Exploratory Stratigraphic Test Non-Conventional FIELD: KVI/.k./ A,k Al'Ue4r POOL: 14l1 A R11/641 / k yAIWc RI11&r al Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion,suspension or abandonment of this well. Revised 2/2015 0 0 U) , co co ° a o, 1 a) o `. OS N a), C. O Ct N C N. co, C -c ay , co a. 0 C a' o . �' O o; co, E O m a 0 °z. M. °, a °, a - Us'3. °' ' °' c, °, o j co (N„ E. o 'c 0,f > 0 a C � a3). u0)). . 3; • pa Q o. a � a , o .0o _ c� wcil 1 II, . . .c. :LI)• o' r vi E' U) a Y W' N ~' J g. N. o. , ca 3, o, co, u.). 4 I- ca O. .is , E., x' °, d E ' O' O 0a O •y. • CN„ c• N C �. , a , o, CO C. p, co Q. lic OL Q O. Qy' a• --, H, W CO • Q, I, d CD m D'. O' 8 . n a . 3'. ; v'. a N . y. o .a N aa> = o nQ rn , Y'. c °..., >. 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Technical Report Title Date Client: ConocoPhillips Alaska, Inc Field: Kuparuk River Unit Rig: Doyon 141 Date: September 11, 2015 Surface Data Logging End of Well Report 2S-10 TABLE OF CONTENTS 1.General Information 2.Daily Summary 3.Days vs. Depth 4.After Action Review 5.Mud Record 6.Bit Record 7.Morning Reports 8.Survey Report Digital Data to include: Final Log Files Final End of Well Report Final LAS Exports Halliburton Log Viewer EMF Log Viewer GENERAL WELL INFORMATION Company: ConocoPhillips Alaska Inc. Rig: Doyon 141 Well: 2S-10 Field: Kuparuk River Unit Borough: North Slope Borough State: Alaska Country: United States API Number: 50-103-20717-00-00 Sperry Job Number: AK-AM-902703435 Job Start Date: 25 August 2015 Spud Date: 22 August 2015 Total Depth: 14896’ MD, 6431’ TVD North Reference: True Declination: 18.60° Dip Angle: 80.870° Total Field Strength: 57488.760 nT Date Of Magnetic Data: 05 September 2015 Wellhead Coordinates N: North 70° 13’ 10.37873” Wellhead Coordinates W: West 150° 9’ 21.65699“ Drill Floor Elevation 147.50’ Ground Elevation: 120.00’ Permanent Datum: Mean Sea Level SDL Engineers: Kyle Wiseman, Connor Murray SDL Sample Catchers: Chris Woolley, Will Halliburton Company Geologist: Brett Harvey, Matthew Smith Company Representatives: Robert Wall, Any Lundale, Bob Finkbiner, SSDS Unit Number: 125 DAILY SUMMARY 08/25/2015 SDL rigged up unit and setup computers. 08/26/2015 The gas gear was calibrated, the diverter was nippled down, and the Blow-Out prevention equipment was rigged up and tested. Managed-Pressure drilling equipment was then rigged up and tested. Fluids: 0 barrels of water-based mud was lost downhole. 08/27/2015 The Total Hydrocarbon Analyzer was calibrated with 10, 20, and 99% Methane. The Gas Chromatograph was calibrated with C1-C5 blend gas. The internal blow-out preventer was tested, and Bottom-Hole Assembly #3 was picked up. The Bottom-Hole Assembly was tripped in on 5” drill-pipe singles to 1587’ MD and a shallow hole test was performed. Tripping in hole continued with drill-pipe joints to 1959’ MD. The ghost reamer was then installed in the drill string before tripping in continued to 2521’ MD. A slip and cut was then performed and the Managed-Pressure Drilling bearing was installed and tested. Gas: The max gas was 13 units and the average background gas was 0 units. Fluids: 0 barrels of water-based mud was lost downhole. 08/28/2015 The trip nipple was installed and the mud was circulated and conditioned. The casing was then tested to 3500 PSI. The cement and float equipment were then drilled through and drilled ahead to 2719’MD. A FIT was performed before drilling ahead to 3863’MD. Background gas has been between 40-70 units for the extent drilled with a high connection gas of 284 units. The Gas Chromatograph was re-calibrated at a connection to confirm accuracy. Gas: The max gas was 284 units and the average background gas was 32 units. Fluids: 0 barrels of water-based mud was lost downhole. Geology: The samples have been 90% Claystone that is grey, soft, amorphous, non-swelling, non-calcareous, and slightly hydrophilic. The other 10% has been Siltstone that is dark grey, fine crystalline, moderately hard, and blocky 08/29/2015 The Rig drilled ahead to 5128’MD and circulated a bottoms-up before monitoring the well for 15 minutes. The trip nipple was then pulled and the Managed-Pressure drilling bearing was installed. The rig then drilled ahead to 5582’MD. A formation gas peak of 599 units was seen at 5368’MD which correlates with increased sandstone present in cuttings samples at that depth. Background gas has been between 80-150 units with occasional connection gas peaks of approximately 140-160 units. Gas: The max gas was 599 units and the average background gas was 59 units. Fluids: 0 barrels of water-based mud was lost downhole. Geology: The samples have been predominantly siltstone that is white, light grey to dark grey, medium to coarse grain, sub angular to angular, poorly sorted, unconsolidated, with trace amounts of pyrite. 08/30/2015 The rig drilled ahead to 6515’MD and began experiencing fluid losses. The pumps were slowed to 350 gallons-per-minute and lost-circulation material was added to the mud. The rig then drilled ahead to 7051’MD. Background gas has been between 200-500 units with gas peaks above 600 units. Gas: The max gas was 848 units and the average background gas was 175 units. Fluids: 105 barrels of water-based mud was lost downhole. Geology: The samples have been predominantly shale that is dark grey to black, silty, friable, splintery, non-swelling, and non-calcareous. 08/31/2015 The rig drilled ahead from 7051’MD to the TD of the intermediate section at 7500’MD. A gas peak of 1352 units at 1352’MD was observed. Background gas was between 150-300 units with a high connection gas of 596 units @ 7270’MD. Lithology was 100% shale by TD depth. The rig pumped a high viscosity sweep and circulated 3 bottoms-up. The drillstring was tripped out to 7240’MD and then washed back to bottom before displacing the well with 290 bbls new low- solids non-damaging mud. The well was monitored and then the drillstring was stripped out of hole from 7500’MD to 2559’MD. Two bottoms-ups were circulated then and the well was monitored and was static. Gas: The max gas was 1352 units and the average background gas was 237 units. Fluids: 0 barrels of water-based mud was lost downhole. Geology: The samples have been predominantly shale that is dark grey to black, silty, friable, splintery, non-swelling, and non-calcareous. 09/01/2015 The Managed-Pressure Drilling bearing was taken out and the trip nipple was installed. The drillstring was tripped out of the hole and the bottom-hole assembly was laid down. The pipe rams were changed out to 7 5/8” rams and tested to 3500 PSI. The casing equipment was then rigged up and the 7 5/8” casing was run in hole. The mud was circulated at surface casing shoe at 2673’MD with no rise in gas seen. A tight spot was encountered at 4349’MD, so the mud was circulated and a peak gas of 255 units was seen. The casing was then washed down to 4380’MD. Gas: The max gas was 255 units and the average background gas was 24 units. Fluids: 0 barrels of water-based mud was lost downhole. 09/02/2015 The rig continued to run in hole with the casing to bottom while stopping to circulate a bottoms- up at 5104’MD and 5919’MD. The mud was circulated on bottom and lagged up a gas peak of 2824 units before landing casing at 7492’MD. Cement equipment was rigged up and a 2 stage cement job was performed. The well was monitored post-cement job and was static. The cement equipment was then rigged down and the pack-off was set and tested to 5000 psi. Gas: The max gas was 2824 units and the average background gas was 174 units. Fluids: 99 barrels of water-based mud was lost downhole. 09/03/2015 The 5” drill-pipe was laid down and unloaded from the pipe shed. The 4” DP was then loaded and strapped. The upper annulus was then freeze protected with diesel and the 4” drill-pipe was picked up. Gas: The max gas was 8 units and the average background gas was 0 units. Fluids: 0 barrels of water-based mud was lost downhole. 09/04/2015 The Total Hydrocarbon Analyzer and Gas Chromatograph were calibrated in preparation for the production section. The 4” drill-pipe was racked back and the blow-out prevention equipment was rigged up and tested to 250 and 3500 PSI for 5 m inutes each. Bottom-hole assembly #4 was then picked up and run in hole to 1562’MD. A shallow hole pulse test was then conducted before continuing to RIH to 4303’MD. A cement bond log was then taken from 4304’ to 5240’MD. Gas: The max gas was 32 units and the average background gas was 14 units. Fluids: 0 barrels of water-based mud was lost downhole. 09/05/2015 The casing was tested at 5250’MD to 3500 PSI. The cement bond log was continued to 7327’MD while pausing to drill the cement stringer and stage collar. The casing was tested again to 3500 PSI for 30 minutes. A slip and cut was then performed, the trip nipple was removed and the Managed-Pressure drilling bearing was installed. A Managed-Pressure drilling fingerprint was performed before switching back to the trip nipple. Gas: The max gas was 46 units and the average background gas was 6 units. Fluids: 0 barrels of water-based mud was lost downhole. 09/06/2015 The cement and shoe track were drilled and 3 bottoms-ups were circulated. The trip nipple was then swapped out for the Managed-Pressure drilling bearing. The rig then drilled to 7520’MD and performed a Formation Integrity test to 14.5 ppg equivalent mud weight. The well was displaced to new FLOTHRU water-based mud and then drilled ahead to 7613’MD. Background gas has been between 40-90 units. Gas: The max gas was 108 units and the average background gas was 61 units. Fluids: 0 barrels of water-based mud was lost downhole. Geology: The samples have been predominantly shale that is dark grey to black, silty, friable, splintery, non-swelling, and non-calcareous. 09/07/2015 The rig drilled ahead in the production section to 8366’MD before taking a formation fingerprint. A gas peak of 7451 units at 7672’MD was encountered before entering the Kuparuk formation. Gas rose around 7880’MD as Kuparuk sands were exposed to a background gas of 2000-3000 units. Larger gas peaks upwards of 9000 units were encountered between 8150’-8300’MD and gas has been at background levels of 3000-6000 units with peaks of 7000+ units since that depth. The rig drilled ahead to 8685’MD. Gas: The max gas was 9899 units and the average background gas was 3367 units. Fluids: 0 barrels of water-based mud was lost downhole. Geology: The samples have been sandstone that is light grey to dark grey, coarse to very coarse grain, sub spherical, sub rounded, moderately sorted, friable to moderately hard, moderately well cemented, with glauconite and trace pyrite. The samples also have a strong odor, slight stain, fluorescence of 80% dull yellow, and a cut of blooming blue to white color. 09/08/2015 The rig drilled ahead in the production hole to 10233’MD and stopped to change-out a leaking Managed-Pressure drilling bearing. Drilling continued to 10324’MD with background gas levels between 6000-9000 units. Gas: The max gas was 9904 units and the average background gas was 5362 units. Fluids: 0 barrels of water-based mud was lost downhole. Geology: The samples have been sandstone that is light grey to dark grey, medium grain, sub spherical, sub rounded, well sorted, friable to moderately hard, moderately well cemented. The samples also have a strong odor, slight stain, fluorescence of 80% dull yellow, and a cut of blooming blue to white color. 09/09/2015 The rig drilled ahead to 11718’MD and stopped to circulate a bottoms-up for the Geologist. Drilling then continued to 12058’MD where the RCD bearing was changed out. Drilling ahead then continued. Background gas through the extent drilled has been between 3000-7500 units. Gas: The max gas was 9901 units and the average background gas was 5952 units. Fluids: 0 barrels of water-based mud was lost downhole. Geology: The samples have been sandstone that is light grey to dark grey, medium grain, sub spherical, sub rounded, well sorted, friable to moderately hard, moderately well cemented. The samples also have a strong odor, slight stain, fluorescence of 60% dull yellow, and a slow cut of blooming blue to white color. 09/10/2015 The rig drilled ahead from 12104’MD to 14382’MD. Background gas through the extent drilled has been between 2500-8000 units. Gas: The max gas was 9902 units and the average background gas was 6263 units. Fluids: 0 barrels of water-based mud was lost downhole. Geology: The samples have been sandstone that is light grey to dark grey, medium grain, sub spherical, sub rounded, well sorted, friable to moderately hard, moderately well cemented. The samples also have a strong odor, slight stain, fluorescence of 60% dull yellow, and a slow cut of blooming blue to white color. 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 0 5 10 15 20 Me a s u r e d D e p t h Rig Days Prognosed Actual Days vs. Depth WELL NAME: 2S-10 OPERATOR: ConocoPhillips Alaska, Inc. MUD CO: MI-Swaco RIG: Doyon 141 SPERRY JOB: AK-XX-902703435 LOCATION: Kuparuk River Unit AREA: North Slope Borough STATE: Alaska SPUD: 22-Aug-2015 TD: 11-Sep-2015 25 August 2015 Sperry SDL Arrived on Location 11 September 2015 SDL released from location Commenced 9.875" Intermediate Hole Section On Bot: 06:58 28 Aug 2015 TD Intermediate Hole Section 7500' MD, 6247' TVD Off Bot: 10:50 31 Aug 2015 Landed 7.625" Casing 7492' MD, 6245' TVD 03 Sep 2015 Commenced 6.75" Production Hole Section On Bot: 14:32 06 Sep 2015 TD Production Hole Section 14896' MD, 6431' TVD Off Bot: 05:24 11 Sept 2015 WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Difficulties experienced: We were receiving MWD data once per day in LAS format and importing the data to our logs. This daily import meant that we could not record fully informed lithology interpretations each day until we received our gamma and resistivity import. Recommendations: In the future, ideally we would setup a WITS connection either directly with the MWD or through TOTCO so that we can have real-time gamma and resitivity plotting on our FEL log to assist us in making more informed real-time lithology interprations. Innovations and/or cost savings: N/A Doyon 141 Intermediate Connor Murray 31-Aug-2015 What went as, or better than, planned: Depth Tracking was excellent with very few minor depth corrections which resulted in very accurate lag calculations. Our gas equipment also performed well without interruptions. Communication between parties in regards to mud losses/gains was prompt and productive. 2S-10 Kuparuk River Unit ConocoPhillips Alaska Inc.North Slope 902703435 Alaska Surface Data Logging After Action Review Surface Data Logging WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Difficulties experienced: Rig pump #2 experienced several malfunction instances during this hole section and the resulting erroneous stroke data caused our lag depth calculation to "skip" footage. This lead to several gaps in the gas data plotted on our Formation Evaluation Log. Recommendations: I'm not sure if the erroneous pump data is a result of the pump itself malfunctioning or an error in how TOTCO reads the pump data but it should be addressed or the mudloggers should consider installing their own pump counter sensors. Innovations and/or cost savings: N/A Doyon 141 Production Connor Murray 11-Sep-2015 What went as, or better than, planned: Our communication and collaboration with the well-site geologists created an environment where information about lithology, MWD data, and hydrocarbon gas levels was shared quickly and often between the two parties leading to an improvement in both services. 2S-10 Kuparuk River Unit ConocoPhillips Alaska Inc.North Slope Borough 902703435 Alaska Surface Data Logging After Action Review Surface Data Logging 2S-10 ConocoPhillips Alaska Inc. MI-Swaco Doyon 141 AK-XX-902703435 Date Depth Wt Vis PV YP Gels Filt R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Sd Pm pH MBT Pf/Mf Chlor Hard ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%%ppb Eqv mg/l Ca++ 26-Aug 2699 9.60 N/A 17 16 7/14/28 NC 50/33/25/17/7/6 NC/NA 9.0 /91 1.75 1.80 10.6 16.3 1.60/2.20 1900 140 BOP test 27-Aug 2699 9.60 N/A 17 14 6/14/26 NC 48/31/26/17/7/6 NC/NA 9.0 /91 1.75 1.80 10.7 16.3 1.60/2.20 1900 140 Trip in to shoe, test MPD 28-Aug 3603 9.70 49 12 27 10/13/15 7.1 51/39/33/26/11/9 1/-7.5 2/91 0.25 0.45 10.2 4.0 0.20/1.45 260 40 Drill out of Shoe, FIT, Drill Ahead 29-Aug 5350 10.00 45 14 26 10/12/15 4.1 54/40/35/27/12/10 1/-10.0 3/87 0.25 0.50 9.8 18.0 0.40/1.40 500 20 Installed MPD bearing, drilled ahead 30-Aug 6931 10.50 56 16 24 10/14/18 3.4 56/40/34/25/10/9 1/2 12.0 3/86 0.50 0.40 9.5 21.0 0.25/1.20 450 400 Drilled Ahead to 7051'MD 31-Aug 7500 10.50 49 12 25 10/13/15 2.9 49/37/32/25/11/10 1/2 12.0 3/85 0.50 0.40 9.6 15.5 0.20/2.20 2000 40 TD'd Intermediate Section 1-Sep 7500 10.50 58 14 26 11/14/16 3.0 54/40/35/27/12/10 1/2 12.0 3/85 0.75 0.40 9.5 15.0 0.20/2.10 1500 40 POOH, RIH w/ Casing 2-Sep 7500 10.50 58 12 23 9/11/13 3.1 47/35/30/24/11/9 1/-12.0 3/85 0.75 0.40 9.7 15.0 0.20/2.10 1400 40 Land Casing, 2 stage Cement Job 3-Sep 7500 10.50 61 12 23 9/12/14 3.1 47/35/30/23/11/9 1/-12.0 3/85 0.50 0.40 9.6 15.0 0.20/2.00 1200 60 LD 5" DP, R/B 4" DP 4-Sep 7500 10.50 61 17 24 11/16/18 3.3 58/41/34/25/12/11 1/-12.0 3/85 0.50 0.40 9.4 15.0 0.20/2.40 1200 80 P/U BHA, RIH 5-Sep 7500 10.50 50 13 22 9/11/13 3.1 48/35/31/22/9/8 1/-12.0 3/85 0.50 0.40 10.3 15.0 0.20/2.40 1200 80 Drill Out Stage Collar, TIH 6-Sep 7592 10.50 60 9 37 6/7/7 2.4 55/46/31/22/8/7 1/2 16.0 2/82 0.00 6.50 10.0 0.25 5.40/9.60 164000 200 Drilled Shoe, FIT, Dispalced to Flothru 7-Sep 8458 10.60 56 18 28 7/8/9 3.0 64/46/36/26/8/7 1/2 16.0 1/83 tr 5.70 9.7 1.6 5.50/9.40 135000 100 Drilled Ahead 8-Sep 10321 10.65 58 19 25 7/8/10 2.6 63/44/36/26/8/7 1/2 16.0 2/83 tr 4.70 9.7 1.5 4.50/8.60 142000 40 Drilled Ahead 9-Sep 11992 10.50 60 21 30 9/11/13 2.4 72/51/42/31/10/9 1/2 16.0 2/83 tr 5.60 10.1 2.0 5.50/9.90 151000 20 Drilled Ahead 10-Sep 14133 10.70 55 20 25 8/10/11 2.0 65/45/37/26/8/7 1/2 16.5 2/82 tr 6.30 10.1 2.0 6.20/11.50 161000 20 Drilled Ahead Casing Record Remarks 16" Conductor @ 106' MD, 106'TVD 10.6" Casing @ 2688' MD, 2566'TVD 7.625" Casing @ 7492' MD, 6245'TVD WELL NAME:LOCATION:Kuparuk River Unit OPERATOR:AREA:North Slope Borough MUD CO:STATE:Alaska RIG:SPUD:22-Aug-2015 SPERRY JOB:TD:11-Sep-2015 W a t e r a n d O i l B a s e d M u d R e c o r d BHA#SDL RUN #Bit #Bit Type Bit Size Depth In Depth Out Footage Bit Hours TFA AVG ROP WOB (max) RPM (max) SPP (max) FLOW GPM (max)Bit Grade Comments 1 N/A 1 Milled Tooth Bit 13.50 89 556 467 7.84 0.994 85.8 -60 725 570 0-0-No-A-X-In-No-BHA Surface #1 2 N/A 2 Milled Tooth Bit 13.50 556 2699 1368 36.76 0.994 117.8 -60 1950 745 1-2-FC-2-E-1/8-WT-TD Surface TD 3 300 3 PDC 9 .875 2699 7500 4801 93.60 1.282 85.9 -1400 3050 725 O-1-BT-N-X-I-CT-TD Intermediate TD 4 400 4 PDC 6.75 7500 14896 7396 70.90 0.464 104.0 -160 3300 270 4-4-BT-A-X-I-CT-TD Production TD Alaska RIG:Doyon 141 SPUD:22-Aug-2015 WELL NAME:2S-10 LOCATION:Kuparuk River Unit OPERATOR:ConocoPhillips Alaska Inc.AREA:North Slope Borough MUD CO: SPERRY JOB:AK-XX-902703435 TD:11-Sep-2015 MI Swaco STATE: B i t R e c o r d . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 180 0 213226037 Pumps Off (max)(current) Surface 13 0 Cly 2132 Size 62.5 HW Grade 16" 907-670-4906Unit Phone: 0 Connor Murray Maximum Report By:Logging Engineers:Kyle Wiseman, Connor Murray 87 0 10.75'' 0 0 Units* Casing Summary Lithology (%) 1 - pH 0 13 0 Siltst Set At SPP (psi) Gallons/stroke TFABit Type Depth 16.3N/A Depth C-5n N/A - C-2 0 N/AMinimum 13 blend gas. Tested IBOP, and began making up BHA #3. Tripped in on 5” DP singles to 1587’ MD and performed a shallow hole 0 2699' 2699' 0' Max @ ft Current -- Date: Avg to- Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Time: Gas Summary 0 0 12 (current) TuffGvlCoal cP 17 L-80 - 2143' R. Wall / D. Mickey ShClyst MBT Ss (ppb Eq) C-1 C-5i AK-AM-0902703435 Testing MPD Equipment PV Footage 24 hr Max 45.5 Weight 0 Hours C-3 - CementChtSilt C-4i C-4n 10.70 000 00 DRILPLEX NC2699'14 Depth in / out YP (lb/100ft2)in Mud Type Lst Type Average 130Background (max)Trip -- Avg Min Comments RPM ECD (ppg) ml/30min 4 Tools - API FL Chromatograph (ppm) WOB Conductor and cut, installed MPD bearing, and performed MPD test. test. Singled in hole to 1959’ MD, installed ghost reamer in string, and continued singling in hole to 2521’ MD. Performed a slip 2659' 106' 100% Gas In Air=10,000 UnitsN/AConnection Bit # 9.09.609.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Morning Report Report # 1 Customer: Well: Area: Location: Rig: 2S-10 ConocoPhillips Alaska, Inc. Kuparuk North Slope ROP ROP (ft/hr) 4.23 @ Mud Data Depth Condition 28-Aug-2015 12:00 AM Current Pump & Flow Data: 0 Max 0 Chlorides mg/l 1900.00 Calibrated Total Hyrdrocarbon Analyzer with 10, 20, and 99% Methane, Calibrated Gas Chromatograph with C1-C5 rig Density (ppg) out (sec/qt) Viscosity Cor Solids % 556' -60 1-2-FC-2-E-1/8-WT-TD 3 PDC 9 7/8"1.282 -2699' 556' --- 1 Milled Tooth Bit 13 1/2"0.994 7.84 89' 2699' 467'-40-60 0-0-No-A-X-In-No-BHA 2 Milled Tooth Bit 13 1/2"0.994 36.76 . . * 24 hr Recap: 40-60 0-0-No-A-X-In-No-BHA 2 Milled Tooth Bit 13 1/2"0.994 36.76 1 Milled Tooth Bit 13 1/2"0.994 7.84 89' 9 7/8"1.282 -2699' 556' - 2699' Installed trip nipple, Circulated and Conditioned Mud and tested casing to 3500 PSI. Drilled out cement and float rig Density (ppg) out (sec/qt) Viscosity Cor Solids %mg/l 260.00 556' -60 1 Chlorides 1-2-FC-2-E-1/8-WT-TD 3 PDC 29-Aug-2015 12:00 AM Current Pump & Flow Data: 2240 Max -- 467'- Depth Condition ROP ROP (ft/hr) 4.23 @ Mud Data Morning Report Report # 2 Customer: Well: Area: Location: Rig: 2S-10 ConocoPhillips Alaska, Inc. Kuparuk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: 9.70 Size Fluid Losses: 0 bbls connection to confirm accuracy. 40-70 units for the extent drilled with a high connection gas of 284 units. The Gas Chromatograph was re-calibrated at a 2659' 106' 100% Gas In Air=10,000 Units284Connection 90% Tools EcoScope, Telescope API FL Chromatograph (ppm) WOB Conductor 7.5 -- Avg Min Comments RPM ECD (ppg) ml/30min 58Background (max)Trip Average N/A Mud Type Lst Type DRILPLEX 7.13603'27 Depth in / out YP (lb/100ft2)in Bit # 9.70 10.20 001 00 CementChtSilt C-4i C-4n 35 Hours C-3 - 10 Ss (ppb Eq) C-1 C-5i AK-AM-0902703435 Drilling Ahead PV Footage 2143' R. Wall, D. Mickey, A. Lundale ShClyst MBT 24 hr Max 45.5 Weight TuffGvlCoal cP 12 L-80 - Gas Summary 0 7 0 (current) Avg to2699' Yesterday's Depth: Current Depth: 24 Hour Progress: 157.8 Flow In (gpm) Flow In (spm) Time: 2699' 3863' 1164' Max @ ft Current 3228'91.7 Date: equipment and drilled ahead to 2719’MD. Performed FIT before drilling ahead to 3863’MD. Background gas has been between 57 3522'Minimum 157 C-5n 2940' 100.6 C-2 4 SPP (psi) Gallons/stroke TFABit Type Depth 4.049 3863' pH 0 19 0 Siltst Set At Depth 10.75'' 732 173 Units* Casing Summary Lithology (%) 4 10% 8405 1170 907-670-4906Unit Phone: 0 Connor Murray Maximum Report By:Logging Engineers:Kyle Wiseman, Connor Murray Size 62.5 HW Grade 16" (max)(current) Surface 124 7 Cly 20342 Bottoms Up Time 273 0 271033259 16 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Bottoms Up Strokes Bottoms Up Time 394 0 398448389 24 min Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) (current) Surface 2092 0 Cly 60052 Volumes Size 62.5 HW Grade 16" 907-670-4906Unit Phone: 34 Connor Murray Maximum Report By:Logging Engineers:Kyle Wiseman, Connor Murray 20% 7414 95 10.75'' 711 168 Units* Casing Summary Lithology (%) 20 112 0 Siltst Set At Depth Lag Correction (bbls) SPP (psi) Gallons/stroke TFABit Type Depth 18.045 5582' C-5n 5368' 84.5 C-2 2 4658'Minimum 599 bearing. Drilled ahead to 5582’MD. Formation Gas peak of 599 units at 5368’MD correlates with increased sandstone present 59 3863' 5582' 1719' Max @ ft Current 4491'99.6 Date: to3863' Yesterday's Depth: Current Depth: 24 Hour Progress: 134.5 Flow In (gpm) Flow In (spm) Time: Gas Summary 0 189 40 (current) TuffGvlCoal cP 14 L-80 - R. Wall, D. Mickey, A. Lundale ShClyst MBT 24 hr Max 45.5 Weight Ss (ppb Eq) C-1 C-5i AK-AM-0902703435 Drilling Ahead PV Footage 225 Hours C-3 - 860 2143' 0 CementChtSilt C-4i C-4n 7338 00 5350'26 Depth in / out YP (lb/100ft2)in Bit # 10.00 Mud Type Lst 70% Type Average N/ABackground (max)Trip (max) RPM ECD (ppg) ml/30min 70 DRILPLEX 4.1 9.80 Conductor 10.0 -- Avg Min Comments pH 100% Gas In Air=10,000 Units151Connection 10% Chromatograph (ppm) Fluid Losses: 0 bbls approximately 140-160 units. in cuttings samples at that depth. Background gas has been between 80-150 units with occasional connection gas peaks of Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Morning Report Report # 3 Customer: Well: Area: Location: Rig: 2S-10 ConocoPhillips Alaska, Inc. Kuparuk North Slope ROP ROP (ft/hr) 4.23 @ Mud Data Tools EcoScope, Telescope API FL Avg Condition 10.00 30-Aug-2015 12:00 AM Current Pump & Flow Data: 2800 Max -- 467'- 101 Chlorides 1-2-FC-2-E-1/8-WT-TD 3 PDC Depth Size 2659' 500.00 556' -60 106' WOB Density (ppg) out (sec/qt) Viscosity Cor Solids %mg/l - 2699' Drilled ahead to 5128’MD, circulated BU and then monitored well for 15 mins. Pulled trip nipple and installed RCD rig 0.994 7.84 89' 9 7/8"1.282 -2699' 556' 40-60 0-0-No-A-X-In-No-BHA 2 Milled Tooth Bit 13 1/2"0.994 36.76 1 Milled Tooth Bit 13 1/2" . . * 24 hr Recap: Milled Tooth Bit 13 1/2" 2699' 556' 40-60 0-0-No-A-X-In-No-BHA 2 Milled Tooth Bit 13 1/2"0.994 36.76 1 Cor Solids %mg/l - 2699' Drilled ahead to 6515’MD and began experiencing fluid losses. Slowed pumps to 350 gpm and began using LCM. rig 0.994 7.84 89' 556' -60 106' 9 7/8"1.282 - Chlorides 1-2-FC-2-E-1/8-WT-TD 3 PDC Depth Size 2659' 450.00 31-Aug-2015 12:00 AM Current Pump & Flow Data: 2800 Max -- 467'- Condition 582 ROP ROP (ft/hr) 4.23 @ Mud Data Tools EcoScope, Telescope API FL Avg Morning Report Report # 4 Customer: Well: Area: Location: Rig: 2S-10 ConocoPhillips Alaska, Inc. Kuparuk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Fluid Losses: 105 bbls 100% Gas In Air=10,000 Units646Connection Chromatograph (ppm) Conductor 12.0 -- Avg Min Comments pH ECD (ppg) ml/30min 298 DRILPLEX 3.4 9.5010.50 WOB Density (ppg) out Background (max)Trip (max) Average N/A Mud Type Lst Type 6931'24 Depth in / out YP (lb/100ft2)in Bit # 10.50 (sec/qt) Viscosity 7226460 03 CementChtSilt C-4i C-4n 1014 Hours C-3 90% - 2390 2143' 4 (ppb Eq) C-1 C-5i AK-AM-0902703435 Drilling Ahead PV Footage L-80 - R. Wall, D. Mickey, A. Lundale ShClyst MBT 24 hr Max 45.5 TuffGvlCoal cP 16 Weight RPM Gas Summary 0 1044 193 (current) to5582' Yesterday's Depth: Current Depth: 24 Hour Progress: 165.0 Flow In (gpm) Flow In (spm) Time: 5582' 7051' 1469' Max @ ft Current 5964'83.5 Date: Drilled ahead to 7051’MD. Background gas has been between 200-500 units with gas peaks above 600 units. 175 6401'Minimum 848 C-5n 6897' 45.0 C-2 2 SPP (psi) Gallons/stroke TFABit Type Depth 21.056 7051' 263 0 Siltst Set At Depth Lag Correction (bbls) 10.75'' 639 151 Units* Casing Summary Lithology (%) 7718233 134 907-670-4906Unit Phone: 215 Connor Murray Maximum Report By:Logging Engineers:Kyle Wiseman, Connor Murray Volumes Size 62.5 HW Grade 16" Ss Annular Volume (bbls) (current) Surface 3994 7 Cly 63495 10% Bottoms Up Strokes Bottoms Up Time 498 0 4944613115 33 Hole Capacity (bbls) Drillstring Capacity (bbls) . . * 24 hr Recap: Milled Tooth Bit 13 1/2" 2699' 556' 40-60 0-0-No-A-X-In-No-BHA Fluid Losses: 0 bbls mg/l - 2699' Drill ahead from 7051’MD to TD of intermediate section at 7500’MD. A gas peak of 1352 units at 1352’MD was rig 0.994 7.84 89' Milled Tooth Bit 13 1/2" 556' -60 106' 9 7/8"1.282 - 2 0.994 1-2-FC-2-E-1/8-WT-TD 3 PDC Depth Size 2659' 2000.00 1-Sep-2015 12:00 AM Current Pump & Flow Data: 0 Max -- 467'- 711 ROP ROP (ft/hr) 4.23 @ Mud Data Tools EcoScope, Telescope API FL Avg Morning Report Report # 5 Customer: Well: Area: Location: Rig: 2S-10 ConocoPhillips Alaska, Inc. Kuparuk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: monitored well and it was static. displaced well with 290 bbls new LSND. Monitored well and then stripped out of hole from 7500’MD to 2559’MD. Circulated 2xBU, shale by TD depth. Pumped a Hi-Vis sweep and circulated 3xBU. Racked back to 7240’MD and washed back to bottom and 100% Gas In Air=10,000 Units596 ECD (ppg) Connection Chromatograph (ppm) -- Avg Min Comments pH Condition Chlorides Cor Solids % WOB N/A Conductor 12.0 102 36.76 1 Background (max)Trip0 (max) Average Mud Type Lst Type 7500' in Bit # 10.50 (sec/qt) Viscosity (ppb Eq) Density (ppg) out DRILPLEX 10.50 343 83 61165 CementChtSilt C-4i C-4n C-1 C-5i Bottoms Up Time 1472 Hours C-3 100% - 1904 2143' 202 AK-AM-0902703435 OWFF at Casing Shoe PV Footage 25 Depth in / out YP (lb/100ft2) L-80 - R. Wall, D. Mickey, A. Lundale ShClyst MBT 24 hr Max ml/30min Coal cP 12 Weight 2.9 9.60 RPM Gas Summary 46 628 140 (current) to7051' Yesterday's Depth: Current Depth: 24 Hour Progress: 66.0 Flow In (gpm) Flow In (spm) Time: 7051' 7500' 449' Max @ ft Current 7453'51.2 Date: observed. Background gas was between 150-300 units with a high connection gas of 596 units @ 7270’MD. Lithology was 100% 237 7155'Minimum 1352 C-5n 7293' 23 219 39 N/A C-2 Volumes Size 0 SPP (psi) Gallons/stroke TFABit Type Depth 15.549 7500' Siltst Set At Depth Lag Correction (bbls) 62.5 HW Grade 10.75'' 0 0 Units* Casing Summary Lithology (%) 8923395 1326 907-670-4906Unit Phone: 154 Connor Murray Maximum Report By:Logging Engineers:Kyle Wiseman, Connor Murray 16" Ss Annular Volume (bbls) Bottoms Up Strokes 45.5 TuffGvl (current) Surface 5371 200 Cly 131168 185 183668538 Pumps Off Hole Capacity (bbls) Drillstring Capacity (bbls) . . * 24 hr Recap: 1826674206 Pumps Off Hole Capacity (bbls) Drillstring Capacity (bbls) Gvl (current) Surface 597 0 Cly 31714 16" Ss Annular Volume (bbls) Bottoms Up Strokes 45.5 Tuff 907-670-4906Unit Phone: 33 Connor Murray Maximum Report By:Logging Engineers:Kyle Wiseman, Connor Murray 10.75'' 0 0 Units* Casing Summary Lithology (%) 184 62.5 HW Grade 9 Depth 15.058 - Siltst Set At Depth Lag Correction (bbls)Volumes Size 0 SPP (psi) Gallons/stroke TFABit Type C-5n N/A 0 49 0 - C-2 N/AMinimum 255 0 3500 PSI. R/U and RIH with 7 5/8” casing. Circulated at shoe at 2673’MD with no rise in gas. Encountered tight spot at 4349’MD, 24 2940 7500' 7500' 0' Max @ ft Current -- Date: to- Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Time: Gas Summary 0 126 32 (current) cP 14 Weight 3.0 9.50 RPM L-80 - R. Wall, D. Mickey, A. Lundale ShClyst MBT 24 hr Max ml/30min Coal AK-AM-0902703435 RIH w/ Casing PV Footage 26 Depth in / out YP (lb/100ft2) 71 Hours C-3 - 308 2143' 0 Silt C-4i C-4n C-1 C-5i Bottoms Up Time 29 4 00 Cement 7500' in Bit # 10.50 (sec/qt) Viscosity Density (ppg) out DRILPLEX 10.50 Mud Type Lst Type (ppb Eq) Cht (max) Average Background (max)Trip25 WOB 255 Conductor 12.0 4 36.76 1 -- Avg Min Comments pH Condition Chlorides Cor Solids % ECD (ppg) Connection Chromatograph (ppm) circulated and observed peak gas of 255 units. Washed down to 4380’MD. Continued to RIH to 4485’MD. 100% Gas In Air=10,000 UnitsN/A Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Morning Report Report # 6 Customer: Well: Area: Location: Rig: 2S-10 ConocoPhillips Alaska, Inc. Kuparuk North Slope ROP ROP (ft/hr) 4.23 @ Mud Data Tools - API FL Avg 46 2-Sep-2015 12:00 AM Current Pump & Flow Data: 0 Max -- 467'- 1-2-FC-2-E-1/8-WT-TD 3 PDC Depth Size 2659' 1500.00 556' -60 106' 9 7/8"1.282 - 2 0.994 mg/l - 2699' Removed RCD bearing and installed trip nipple. POOH and L/D BHA. C/O pipe rams to 7 5/8” and tested rams to rig 0.994 7.84 89' Milled Tooth Bit 13 1/2" Fluid Losses: 0 bbls Milled Tooth Bit 13 1/2" 2699' 556' 40-60 0-0-No-A-X-In-No-BHA . . * 24 hr Recap: 0-0-No-A-X-In-No-BHA Fluid Losses: 99 bbls Continued to RIH with casing to bottom while stopping to circulate a BU at 5104’MD and 5919’MD. Circulated on rig 0.994 7.84 89' Milled Tooth Bit 13 1/2" Milled Tooth Bit 13 1/2" 2699' 9 7/8"1.282 - 2 0.994 mg/l - 2699' 556' 40-60 Size 2659' 1400.00 556' -60 106' 3-Sep-2015 12:00 AM Current Pump & Flow Data: 0 Max -- 467'- 1-2-FC-2-E-1/8-WT-TD 435 ROP ROP (ft/hr) 4.23 @ Mud Data Tools - API FL Avg Morning Report Report # 7 Customer: Well: Area: Location: Rig: 2S-10 ConocoPhillips Alaska, Inc. Kuparuk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Monitored well post-cement job and well was static. R/D cement equipment, set pack-off, and tested pack-off to 5000 psi. 100% Gas In Air=10,000 UnitsN/A ECD (ppg) Connection Chromatograph (ppm) -- Avg Min Comments pH Condition Chlorides Cor Solids % 2824 Conductor 12.0 30 36.76 1 Background (max)Trip0 (max) Average Mud Type Lst Intermediate Type (ppb Eq) Cht in Bit # 10.50 (sec/qt) Viscosity Density (ppg) out DRILPLEX 10.50 Depth Cement 7500' WOB 3 PDC 162 32 1438 2143' 47 Silt C-4i C-4n C-1 C-5iC-3 - 5597 AK-AM-0902703435 C/O topdrive bails PV Footage 23 Depth in / out YP (lb/100ft2) - R. Wall, D. Mickey, A. Lundale ShClyst MBT 24 hr Max ml/30min Coal Hours cP 12 29.7 Weight 3.1 9.70 RPM Gas Summary 0 1754 283 (current) to- Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Time: 7500' 7500' 0' Max @ ft Current -- Date: bottom and lagged up a gas peak of 2824 units before landing casing at 7492’MD. R/U and performed a 2 stage cement job. 174 18399 N/AMinimum 2824 602 C-5n N/A 3 570 11 - C-2 Volumes Size 0 SPP (psi) Gallons/stroke TFABit Type Depth 15.058 - Siltst Set At Depth Lag Correction (bbls) Grade 53 L-80 904 10.75'' 0 0 Units* Casing Summary Lithology (%) N/A 62.5 HW 907-670-4906Unit Phone: 265 Connor Murray Maximum Report By:Logging Engineers:Kyle Wiseman, Connor Murray L-807492' 16" 7.63'' Ss Annular Volume (bbls) Bottoms Up Strokes 45.5 TuffGvl (current) Surface 12839 44 Cly 268199 N/A345N/A N/A Hole Capacity (bbls) Drillstring Capacity (bbls) Bottoms Up Time . . * 24 hr Recap: N/A345N/A N/A Hole Capacity (bbls) Drillstring Capacity (bbls) Bottoms Up Time Gvl (current) Surface - - Cly - L-807492' 16" 7.63'' Ss Annular Volume (bbls) Bottoms Up Strokes 45.5 Tuff 907-670-4906Unit Phone: - Connor Murray Maximum Report By:Logging Engineers:Kyle Wiseman, Connor Murray 10.75'' 0 0 Units* Casing Summary Lithology (%) N/A 62.5 HW -- Depth 15.061 - Siltst Set At Depth Lag Correction (bbls)Volumes Size 0 SPP (psi) Gallons/stroke TFABit Type C-5n N/A 0 - - - C-2 N/AMinimum 8 - P/U 4” DP. 0 - 7500' 7500' 0' Max @ ft Current -- Date: to- Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Time: Gas Summary - -- (current) 29.7 Weight 3.1 9.60 RPM Grade L-80 YP (lb/100ft2) - R. Wall, D. Mickey, A. Lundale ShClyst MBT 24 hr Max Hours cP - - AK-AM-0902703435 Racking Back 4" DP PV Footage 23 Silt C-4i C-4n C-1 C-5iC-3 -- -- 2143' - Coal Cement 7500' WOB 3 PDC in Bit # 10.50 (sec/qt) Viscosity Density (ppg) out LSND 10.50 Depth Mud Type Lst Intermediate Type (ppb Eq) Cht (max) Average Background (max)Trip0 N/A Conductor 12.0 - 36.76 1 -- Avg Min Comments pH Condition Chlorides Cor Solids % ECD (ppg) Connection Chromatograph (ppm) 100% Gas In Air=10,000 UnitsN/A Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Morning Report Report # 8 Customer: Well: Area: Location: Rig: 2S-10 ConocoPhillips Alaska, Inc. Kuparuk North Slope ROP ROP (ft/hr) 4.23 @ Mud Data Tools - API FL Avg - 4-Sep-2015 12:00 AM Current Pump & Flow Data: 0 Max -- 467'- 1-2-FC-2-E-1/8-WT-TD 2659' 1200.00 556' -60 106' mg/l - 2699' 556' 40-60 Size Depth in / out ml/30min 12 2699' 9 7/8"1.282 - 2 0.994 L/D 5” DP and unload 5” DP from shed. Loaded and strapped 4” DP. Freeze protect upper annulus with diesel. rig 0.994 7.84 89' Milled Tooth Bit 13 1/2" Milled Tooth Bit 13 1/2"0-0-No-A-X-In-No-BHA Fluid Losses: 0 bbls . . * 24 hr Recap: --7500' ---- Fluid Losses: 0 bbls rig 0.994 7.84 89' Milled Tooth Bit 13 1/2" Milled Tooth Bit 13 1/2"0-0-No-A-X-In-No-BHA PDC 9 7/8"1.282 93.61 2 0.994 The Total Hydrocarbon Analyzer and Gas Chromatograph were calibrated in preparation for the production section. 4 6.75 0.464 mg/l - 2699' 556' 40-60 Size Depth in / out ml/30min 17 2699' 2659' 1200.00 556' -60 106' 5-Sep-2015 12:00 AM Current Pump & Flow Data: 0 Max 120-1400 0-1-BT-N-X-I-CT-TD 467'- 1-2-FC-2-E-1/8-WT-TD - ROP ROP (ft/hr) 4.23 @ Mud Data Tools - API FL Avg Morning Report Report # 9 Customer: Well: Area: Location: Rig: 2S-10 ConocoPhillips Alaska, Inc. Kuparuk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: - pulse test. Continue to RIH to 4303’MD. MAD PASS from 4304’ to 5240’MD. 100% Gas In Air=10,000 UnitsN/A ECD (ppg) Connection Chromatograph (ppm) -- Avg Min Comments pH Condition Chlorides Cor Solids % 32 Conductor 12.0 - 36.76 1 Background (max) Trip4 (max) Average Mud Type Lst Intermediate Type (ppb Eq) Cht in Bit # 10.50 (sec/qt) Viscosity Density (ppg) out LSND 10.50 Depth Cement 7500' WOB 3 PDC -- -- 2143' - CoalSilt C-4i C-4nC-1 C-5iC-3 7500' - AK-AM-0902703435 MAD Pass in Casing PV Footage 24 YP (lb/100ft2) 4801' R. Wall, D. Mickey, A. Lundale ShClyst MBT 24 hr Max Hours cP 29.7 Weight - - 3.3 9.40 RPM Grade L-80 Gas Summary - -- (current) to- Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Time: 7500' 7500' 0' Max @ ft Current -- Date: Racked back 4” DP, R/U BOPE, and tested BOPE to 250/3500 psi for 5 minutes each. P/U BHA #4, RIH to 1562’MD, and shallow 14 - N/AMinimum 32 - C-5n N/A 0 - - - C-2 Volumes Size 0 SPP (psi) Gallons/stroke TFABit Type Depth 15.061 - Siltst Set At Depth Lag Correction (bbls) -- 10.75'' 0 0 Units* Casing Summary Lithology (%) N/A 62.5 HW 907-670-4906Unit Phone: - Connor Murray Maximum Report By:Logging Engineers:Kyle Wiseman, Connor Murray L-807492' 16" 7.63'' Ss Annular Volume (bbls) Bottoms Up Strokes 45.5 TuffGvl (current) Surface - - Cly - N/A345N/A N/A Hole Capacity (bbls) Drillstring Capacity (bbls) Bottoms Up Time . . * 24 hr Recap: 291 74 Pumps Off Hole Capacity (bbls) Drillstring Capacity (bbls) Bottoms Up Time Gvl (current) Surface - - Cly - L-807492' 16" 7.63'' Ss Annular Volume (bbls) Bottoms Up Strokes 45.5 Tuff 907-670-4906Unit Phone: - Connor Murray Maximum Report By:Logging Engineers:Kyle Wiseman, Connor Murray 0 0 Units* Casing Summary Lithology (%) 217 62.5 HW 2157 -- Depth 15.050 - Siltst Set At Depth Lag Correction (bbls)Volumes Size 0 SPP (psi) Gallons/stroke TFABit Type C-5n N/A 0 - - - C-2 N/AMinimum 46 - MAD PASSing to 7327’MD. Tested Casing to 3500 PSI for 30 minutes. Slip and Cut Drill line, remove trip nipple, installed RCD 6 - 7500' 7500' 0' Max @ ft Current -- Date: to- Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Time: Gas Summary - -- (current) 29.7 Weight - - 3.1 10.30 RPM Grade L-80 YP (lb/100ft2) 4801' R. Wall, D. Mickey, A. Lundale ShClyst MBT 24 hr Max Hours cP 7500' - AK-AM-0902703435 Repari RCD Clamp PV Footage 22 Silt C-4i C-4n C-1 C-5iC-3 -- -- 2143' - Coal Cement 7500' WOB 3 PDC Viscosity Density (ppg) out LSND 10.50 Depth Mud Type Lst Intermediate Type (ppb Eq) Cht (max) Average Background (max) Trip1 46 Conductor 12.0 - 36.76 1 -- Avg Min Comments pH Condition Chlorides Cor Solids % ECD (ppg) Connection Chromatograph (ppm) - bearing. MPD fingerprint performed, RCD bearing removed, trip nipple installed. 100% Gas In Air=10,000 UnitsN/A Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Morning Report Report # 10 Customer: Well: Area: Location: Rig: 2S-10 ConocoPhillips Alaska, Inc. Kuparuk North Slope ROP ROP (ft/hr) 4.23 @ Mud Data Tools - API FL Avg - 6-Sep-2015 12:00 AM Current Pump & Flow Data: 0 Max 120-1400 0-1-BT-N-X-I-CT-TD 467'- 1-2-FC-2-E-1/8-WT-TD 1200.00 556' -60 106' Bit #Size Depth in / out ml/30min 13 2699' 2659' in 10.50 (sec/qt) 10.75'' Tested casing @ 5250’MD to 3500 PSI. MAD PASS to 5260’MD and drilled cement stringer and stage collar before 4 6.75 0.464 mg/l - 2699' 556' 40-60 0-0-No-A-X-In-No-BHA PDC 9 7/8"1.282 93.61 2 0.994 0.994 7.84 89' Milled Tooth Bit 13 1/2" Milled Tooth Bit 13 1/2" Fluid Losses: 0 bbls rig --7500' ---- . . * 24 hr Recap: - Fluid Losses: 0 bbls rig --7500' --- Milled Tooth Bit 13 1/2" Milled Tooth Bit 13 1/2"0-0-No-A-X-In-No-BHA PDC 9 7/8"1.282 93.61 2 0.994 0.994 7.84 89' Repaired RCD clamp, drilled cement and shoe track and circulated BUx3. Removed trip nipple and installed RCD 4 6.75 0.464 mg/l - 2699' 556' 40-60 Size Depth in / out ml/30min 9 2699' 2659' in 10.50 (sec/qt) 10.75'' 164000 556' -60 106' Bit # 7-Sep-2015 12:00 AM Current Pump & Flow Data: 2270 Max 120-1400 0-1-BT-N-X-I-CT-TD 467'- 1-2-FC-2-E-1/8-WT-TD 135 ROP ROP (ft/hr) 4.23 @ Mud Data Tools Periscope, ImPulse, SonicScope, adnVISION API FL Avg Morning Report Report # 11 Customer: Well: Area: Location: Rig: 2S-10 ConocoPhillips Alaska, Inc. Kuparuk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: - 7613’MD. Background gas has been between 40-90 units. 100% Gas In Air=10,000 UnitsN/A ECD (ppg) Connection Chromatograph (ppm) -- Avg Min Comments pH Condition Chlorides Cor Solids % N/A Conductor 16.0 1 36.76 1 Background (max) Trip27 (max) Average Mud Type Lst Intermediate Type (ppb Eq) Cht Viscosity Density (ppg) out FLOTHRU 10.50 Depth Cement 7592' WOB 3 PDC 29 0 08 2143' 23 CoalSilt C-4i C-4nC-1 C-5iC-3 100% 7500' 217 AK-AM-0902703435 Drilling Ahead PV Footage 37 YP (lb/100ft2) 4801' R. Wall, D. Mickey, A. Lundale ShClyst MBT 24 hr Max Hours cP 29.7 Weight - - 2.4 10.00 RPM Grade L-80 Gas Summary 0 43 0 (current) to7500' Yesterday's Depth: Current Depth: 24 Hour Progress: 121.7 Flow In (gpm) Flow In (spm) Time: 7500' 7613' 113' Max @ ft Current 7522'17.3 Date: bearing. Drilled to 7520’MD and performed FIT to 14.5 ppg EMW. Displaced well to new FLOTHRU mud and then drilled ahead to 61 7795 7606'Minimum 108 488 C-5n 7560' 6 17 3 17.6 C-2 Volumes Size 0 SPP (psi) Gallons/stroke TFABit Type Depth 0.2560 7613' Siltst Set At Depth Lag Correction (bbls) 10466 242 60 Units* Casing Summary Lithology (%) 226 62.5 HW 2248 907-670-4906Unit Phone: 5 Connor Murray Maximum Report By:Logging Engineers:Kyle Wiseman, Connor Murray L-807492' 16" 7.63'' Ss Annular Volume (bbls) Bottoms Up Strokes 45.5 TuffGvl (current) Surface 778 47 Cly 13109 303 77 38 Hole Capacity (bbls) Drillstring Capacity (bbls) Bottoms Up Time . . * 24 hr Recap: Cly 794903 344 88 Hole Capacity (bbls) Drillstring Capacity (bbls) 7492' 16" 7.63'' Ss Annular Volume (bbls) Bottoms Up Strokes 45.5 TuffGvl Surface 907-670-4906Unit Phone: 1918 Connor Murray Maximum Report By:Logging Engineers:Kyle Wiseman, Connor Murray 254 60 Units* Casing Summary Lithology (%) 256 62.5 HW 2548 113521968 328 1.6056 8685' Siltst Set At Depth Lag Correction (bbls) Size 0 SPP (psi) Gallons/stroke TFABit Type Depth C-5n 8230' 36 3836 12 139.1 C-2 7617'Minimum 9899 4726 87186 7672’MD before entering Kuparuk. Gas rose around 7880’MD as Kuparuk sands were exposed to a background gas of 2000-3000 3367 203214 7613' 8685' 1072' Max @ ft Current 8208'87.6 Date: to7613' Yesterday's Depth: Current Depth: 24 Hour Progress: 195.1 Flow In (gpm) Flow In (spm) Time: Gas Summary 2 8278 1877 (current) - - 3.0 9.70 RPM Grade L-80 L-80 (lb/100ft2) 4801' B.Finkbiner, R. Wall ShClyst MBT 24 hr Max Hours cP 29.7 7500' 374632 AK-AM-0902703435 Drilling Ahead PV Footage 28 YP C-4nC-1 C-5iC-3 43 Bottoms Up Time 638 030 2143' 117 Coal 8458' WOB 3 PDC Silt C-4i Viscosity Density (ppg) out FLOTHRU 10.60 Depth Lst 100% Intermediate Type Cht Weight Volumes Average 2556 (max)Trip5200 (max)(current) Conductor 16.0 684 36.76 1 -- Avg Min Comments pH Condition Chlorides Cor Solids % ECD (ppg) Connection Chromatograph (ppm) levels of 3000-6000 units with peaks of 7000+ units since that depth. Drilled ahead to 8685’MD. units. Larger gas peaks upwards of 9000 units were encountered between 8150’-8300’MD and gas has been at background 100% Gas In Air=10,000 UnitsN/AN/ABackground Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Morning Report Report # 12 Customer: Well: Area: Location: Rig: 2S-10 ConocoPhillips Alaska, Inc. Kuparuk North Slope ROP ROP (ft/hr) 4.23 @ Mud Data Tools Periscope, ImPulse, SonicScope, adnVISION API FL Avg 32659 8-Sep-2015 12:00 AM Current Pump & Flow Data: 2400 Max 120-1400 0-1-BT-N-X-I-CT-TD 467'- 1-2-FC-2-E-1/8-WT-TD 556' -60 106'- Cement in 10.60 (sec/qt) 10.75'' 135000 Bit # Mud Type (ppb Eq)mg/l - 2699' 556' 40-60 Size Depth in / out ml/30min 18 2699' 2 0.994 0.994 7.84 89' Drilled in production section to 8366’MD before taking formation fingerprint. Encountered gas peak of 7451 units at 4 6.75 0.464 0-0-No-A-X-In-No-BHA PDC 9 7/8"1.282 93.61 - Milled Tooth Bit 13 1/2" Milled Tooth Bit 13 1/2" 2659' - Fluid Losses: 0 bbls rig --7500' -- . . * 24 hr Recap: --7500' -- 2659' - Fluid Losses: 0 bbls rig 0-0-No-A-X-In-No-BHA PDC 9 7/8"1.282 93.61 - Milled Tooth Bit 13 1/2" Milled Tooth Bit 13 1/2" The rig drilled ahead in the production hole to 10233’MD and stopped to change-out a leaking MPD bearing. Drilling 4 6.75 0.464 2699' 2 0.994 0.994 7.84 89' 556' 40-60 Size Depth in / out ml/30min 19 10.75'' 142000 Bit # Mud Type (ppb Eq)mg/l - 2699' 556' -60 106'- Cement 9-Sep-2015 12:00 AM Current Pump & Flow Data: 2200 Max 120-1400 0-1-BT-N-X-I-CT-TD 467'- 1-2-FC-2-E-1/8-WT-TD 31242 ROP ROP (ft/hr) 4.23 @ Mud Data Tools Periscope, ImPulse, SonicScope, adnVISION API FL Avg Morning Report Report # 13 Customer: Well: Area: Location: Rig: 2S-10 ConocoPhillips Alaska, Inc. Kuparuk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: 100% Gas In Air=10,000 UnitsN/AN/ABackground ECD (ppg) Connection Chromatograph (ppm) (sec/qt) -- Avg Min Comments pH Condition Chlorides Cor Solids % Conductor 16.0 2249 36.76 1 (max)Trip1510 (max)(current) Average 9390 Lst 100% Intermediate Type Cht Weight Volumes Viscosity Density (ppg) out FLOTHRU 10.65 Depth in 10.6510321' WOB 3 PDC Silt C-4i 2169 3171064 2143' 3236 Coal C-4nC-1 C-5iC-3 52 Bottoms Up Time 38714 AK-AM-0902703435 Drilling Ahead PV Footage 25 YP 4801' R. Wall, B. Finkbiner ShClyst MBT 24 hr Max Hours cP 29.7 7500' - - 2.6 9.70 RPM Grade L-80 L-80 (lb/100ft2) Gas Summary 322 9185 2118 (current) to8685' Yesterday's Depth: Current Depth: 24 Hour Progress: 166.3 Flow In (gpm) Flow In (spm) Time: 8685' 10324' 1639' Max @ ft Current 9698'118.8 Date: continued to 10324’MD with background gas levels between 6000-9000 units. 5362 713430 10081'Minimum 9904 36711 81680 C-5n 10206' 154 4036 438 122.4 C-2 Size 0 SPP (psi) Gallons/stroke TFABit Type Depth 1.5058 10324' Siltst Set At Depth Lag Correction (bbls) 408681729 5412 216 51 Units* Casing Summary Lithology (%) 303 62.5 HW 3007 907-670-4906Unit Phone: 2199 Connor Murray Maximum Report By:Logging Engineers:Kyle Wiseman, Connor Murray 7492' 16" 7.63'' Ss Annular Volume (bbls) Bottoms Up Strokes 45.5 TuffGvl Surface Cly 713430 408 105 Hole Capacity (bbls) Drillstring Capacity (bbls) . . * 24 hr Recap: Cly 648541 476 123 Hole Capacity (bbls) Drillstring Capacity (bbls) 7492' 16" 7.63'' Ss Annular Volume (bbls) Bottoms Up Strokes 45.5 TuffGvl Surface 907-670-4906Unit Phone: 1887 Connor Murray Maximum Report By:Logging Engineers:Kyle Wiseman, Connor Murray 250 59 Units* Casing Summary Lithology (%) 353 62.5 HW 3506 228639880 15108 2.0060 12104' Siltst Set At Depth Lag Correction (bbls) Size 0 SPP (psi) Gallons/stroke TFABit Type Depth C-5n 10329' 2413 3523 1171 116.9 C-2 11694'Minimum 9901 165540 71051 12058’MD where the RCD bearing was changed out. Drilling ahead then continued. Background gas through the extent drilled has 5952 372362 10324' 12104' 1780' Max @ ft Current 12063'117.1 Date: to10324' Yesterday's Depth: Current Depth: 24 Hour Progress: 154.9 Flow In (gpm) Flow In (spm) Time: Gas Summary 884 7978 1823 (current) - - 2.4 10.10 RPM Grade L-80 L-80 (lb/100ft2) 4801' D. Coates, R. Finkbiner ShClyst MBT 24 hr Max Hours cP 29.7 7500' 33152 AK-AM-0902703435 Drilling Ahead PV Footage 30 YP C-4nC-1 C-5iC-3 62 Bottoms Up Time 1328 9402906 2143' 8230 Coal 11992' WOB 3 PDC Silt C-4i Viscosity Density (ppg) out FLOTHRU 10.60 Depth in 10.50 Lst 100% Intermediate Type Cht Weight Volumes Average 5309 (max)Trip2308 (max)(current) Conductor 16.0 1391 36.76 1 -- Avg Min Comments pH Condition Chlorides Cor Solids % ECD (ppg) Connection Chromatograph (ppm) (sec/qt) been between 3000-7500 units. 100% Gas In Air=10,000 UnitsN/AN/ABackground Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Morning Report Report # 14 Customer: Well: Area: Location: Rig: 2S-10 ConocoPhillips Alaska, Inc. Kuparuk North Slope ROP ROP (ft/hr) 4.23 @ Mud Data Tools Periscope, ImPulse, SonicScope, adnVISION API FL Avg 1-2-FC-2-E-1/8-WT-TD 26468 10-Sep-2015 12:00 AM Current Pump & Flow Data: 2700 Max 120-1400 0-1-BT-N-X-I-CT-TD 467'- 151000 Bit # Mud Type (ppb Eq)mg/l - 2699' 556' 40-60 Size Depth in / out ml/30min 21 10.75'' -60 106'- 2699' 2 0.994 0.994 7.84 89' 556' 4 6.75 0.464 0-0-No-A-X-In-No-BHA PDC 9 7/8"1.282 93.61 - Milled Tooth Bit 13 1/2" Milled Tooth Bit 13 1/2" 2659' - Fluid Losses: 0 bbls rig --7500' -- The rig drilled ahead to 11718’MD and stopped to circulate a bottoms-up for the Geologist. Drilling then continued to Cement . . * 24 hr Recap: --7500' -- The rig drilled ahead from 12104’MD to 14382’MD. Background gas through the extent drilled has been between Cement 2659' - Fluid Losses: 0 bbls rig 0-0-No-A-X-In-No-BHA PDC 9 7/8"1.282 93.61 - Milled Tooth Bit 13 1/2" Milled Tooth Bit 13 1/2" 4 6.75 0.464 2699' 2 0.994 0.994 7.84 89' 556' 40-60 Size Depth in / out ml/30min 20 10.75'' -60 106'- 161000 Bit # Mud Type (ppb Eq)mg/l - 2699' 556' 11-Sep-2015 12:00 AM Current Pump & Flow Data: 3200 Max 120-1400 0-1-BT-N-X-I-CT-TD 467'- 1-2-FC-2-E-1/8-WT-TD 22351 ROP ROP (ft/hr) 4.23 @ Mud Data Tools Periscope, ImPulse, SonicScope, adnVISION API FL Avg Morning Report Report # 15 Customer: Well: Area: Location: Rig: 2S-10 ConocoPhillips Alaska, Inc. Kuparuk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: 100% Gas In Air=10,000 UnitsN/AN/ABackground ECD (ppg) Connection Chromatograph (ppm) (sec/qt) -- Avg Min Comments pH Condition Chlorides Cor Solids % Conductor 16.5 1504 36.76 1 (max)Trip2393 (max)(current) Average 6066 Lst 100% Intermediate Type Cht Weight Volumes Viscosity Density (ppg) out FLOTHRU 10.70 Depth in 10.7014133' WOB 3 PDC Silt C-4i 1495 9732752 2143' 6375 Coal C-4nC-1 C-5iC-3 69 Bottoms Up Time (min) 36435 AK-AM-0902703435 Drilling Ahead PV Footage 25 YP 4801' D. Coates, R. Finkbiner ShClyst MBT 24 hr Max Hours cP 29.7 7500' - - 2.0 10.10 RPM Grade L-80 L-80 (lb/100ft2) Gas Summary 865 8841 2051 (current) to12104' Yesterday's Depth: Current Depth: 24 Hour Progress: 193.5 Flow In (gpm) Flow In (spm) Time: 12104' 14382' 2278' Max @ ft Current 13382'144.9 Date: 2500-8000 units. 6263 386813 14238'Minimum 9902 96033 75520 C-5n 13277' 1535 4044 1083 153.8 C-2 Size 0 SPP (psi) Gallons/stroke TFABit Type Depth 2.0055 14382' Siltst Set At Depth Lag Correction (bbls) 270643470 9539 266 63 Units* Casing Summary Lithology (%) 417 62.5 HW 4144 907-670-4906Unit Phone: 2028 Connor Murray Maximum Report By:Logging Engineers:Kyle Wiseman, Connor Murray 7492' 16" 7.63'' Ss Annular Volume (bbls) Bottoms Up Strokes 45.5 TuffGvl Surface Cly 621148 564 147 Hole Capacity (bbls) Drillstring Capacity (bbls) WELL INFORMATION Created On : Sep 12 2015 Customer :ConocoPhillips Alaska Inc. Well Name :2S-10 Job Number :AK-XX-0902703435 Rig Name :Doyon 141 Field Name : Kuparuk River Unit Country :USA Survey Report SURVEY HEADER Survey data provided by Schlumberger. DIRECTIONAL SURVEY DATA Tie-in 0.00 0.00 0.00 0.00 0.00 N 0.00 E (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 27.50 0.00 0.00 27.50 0.00 N 0.00 E 0.00 0.00 94.40 0.45 73.93 94.40 0.07 N 0.25 E -0.14 0.67 186.50 0.54 69.67 186.50 0.32 N 1.01 E -0.57 0.11 278.70 0.58 73.72 278.69 0.61 N 1.86 E -1.07 0.06 370.80 0.73 77.64 370.79 0.86 N 2.88 E -1.58 0.17 463.00 0.88 78.02 462.98 1.13 N 4.15 E -2.17 0.16 506.90 0.78 74.23 506.87 1.29 N 4.77 E -2.48 0.26 598.44 0.51 89.00 598.41 1.46 N 5.77 E -2.91 0.34 696.00 1.69 54.94 695.95 2.30 N 7.39 E -4.13 1.33 788.22 2.43 45.82 788.11 4.44 N 9.90 E -6.85 0.88 880.07 3.57 31.30 879.83 8.24 N 12.78 E -11.27 1.48 972.37 5.71 29.21 971.82 14.70 N 16.52 E -18.48 2.33 1065.00 7.70 32.99 1,063.82 23.93 N 22.15 E -28.85 2.20 1115.38 9.02 32.68 1,113.66 30.09 N 26.12 E -35.82 2.62 1158.68 10.08 31.52 1,156.36 36.17 N 29.93 E -42.69 2.49 1216.08 11.15 32.19 1,212.78 45.15 N 35.51 E -52.81 1.88 1251.55 12.84 31.28 1,247.47 51.43 N 39.39 E -59.87 4.79 1345.39 14.91 29.17 1,338.57 70.88 N 50.69 E -81.58 2.27 1438.07 15.95 33.62 1,427.91 91.90 N 63.55 E -105.21 1.70 1531.92 19.06 42.90 1,517.42 113.87 N 81.13 E -130.99 4.44 1626.66 20.25 56.47 1,606.68 134.27 N 105.34 E -156.96 4.97 1719.09 20.73 63.37 1,693.28 150.44 N 133.30 E -179.81 2.66 1814.62 22.50 71.62 1,782.11 163.79 N 165.77 E -201.11 3.68 1909.13 24.42 81.56 1,868.84 172.36 N 202.27 E -218.84 4.65 2002.26 25.90 86.94 1,953.14 176.27 N 241.63 E -232.80 2.92 2094.67 26.33 88.82 2,036.12 177.77 N 282.28 E -244.77 1.01 2187.42 26.80 88.37 2,119.07 178.79 N 323.74 E -256.49 0.55 2280.73 26.91 89.57 2,202.32 179.55 N 365.89 E -268.13 0.59 2373.10 27.01 89.98 2,284.65 179.71 N 407.76 E -279.12 0.23 2465.75 27.03 89.30 2,367.19 179.98 N 449.85 E -290.27 0.33 INSITE V8.3.0 Page 1Job No:AK-XX-0902703435 Well Name:2S-10 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2558.55 26.95 89.74 2,449.88 180.33 N 491.97 E -301.51 0.23 2627.01 27.67 89.48 2,510.71 180.54 N 523.38 E -309.85 1.07 2725.17 29.01 87.18 2,597.11 181.92 N 569.94 E -323.23 1.76 2816.64 28.66 86.99 2,677.24 184.16 N 614.00 E -336.80 0.40 2864.99 28.61 86.53 2,719.67 185.47 N 637.13 E -344.06 0.47 2909.92 28.71 85.72 2,759.10 186.93 N 658.63 E -351.03 0.89 3004.46 28.58 86.65 2,842.07 189.95 N 703.85 E -365.64 0.49 3099.67 28.49 85.34 2,925.71 193.12 N 749.22 E -380.45 0.66 3194.74 28.21 84.10 3,009.38 197.27 N 794.17 E -396.10 0.69 3289.77 28.47 83.37 3,093.02 202.20 N 839.01 E -412.46 0.46 3378.65 28.38 82.95 3,171.19 207.24 N 881.02 E -428.20 0.25 3471.79 28.42 84.19 3,253.12 212.20 N 925.04 E -444.38 0.63 3566.57 28.45 85.54 3,336.46 216.24 N 969.98 E -459.92 0.68 3657.96 28.58 85.71 3,416.77 219.56 N 1,013.49 E -474.39 0.17 3751.66 28.48 87.25 3,499.09 222.31 N 1,058.15 E -488.61 0.79 3843.69 28.54 88.26 3,579.96 224.03 N 1,102.04 E -501.63 0.53 3936.51 28.60 87.63 3,661.48 225.62 N 1,146.40 E -514.65 0.33 4029.03 28.51 86.43 3,742.75 227.91 N 1,190.57 E -528.29 0.63 4123.62 28.53 87.35 3,825.86 230.37 N 1,235.66 E -542.33 0.46 4217.11 28.59 87.17 3,907.97 232.50 N 1,280.31 E -555.95 0.11 4310.04 28.60 88.34 3,989.57 234.24 N 1,324.75 E -569.13 0.60 4404.28 28.51 89.38 4,072.34 235.14 N 1,369.78 E -581.65 0.54 4495.10 28.46 89.55 4,152.17 235.55 N 1,413.10 E -593.25 0.10 4590.23 28.35 88.97 4,235.85 236.13 N 1,458.35 E -605.53 0.31 4682.03 28.23 89.55 4,316.68 236.69 N 1,501.85 E -617.33 0.33 4776.69 28.21 94.78 4,400.10 235.00 N 1,546.54 E -627.27 2.61 4869.45 28.69 99.99 4,481.67 229.31 N 1,590.32 E -633.10 2.72 4961.45 27.81 106.66 4,562.74 219.33 N 1,632.64 E -634.41 3.56 5055.86 26.77 113.98 4,646.66 204.37 N 1,673.18 E -630.45 3.72 5149.51 28.34 121.09 4,729.71 184.31 N 1,711.50 E -621.00 3.89 5242.84 29.66 127.18 4,811.35 158.91 N 1,748.88 E -606.14 3.46 5335.66 29.54 130.70 4,892.06 130.11 N 1,784.52 E -587.54 1.88 5426.94 29.94 133.79 4,971.33 99.67 N 1,818.03 E -566.81 1.74 5519.21 30.13 138.65 5,051.22 66.34 N 1,849.95 E -542.89 2.64 5611.31 31.24 142.26 5,130.43 30.10 N 1,879.85 E -515.62 2.33 5703.86 32.97 146.14 5,208.83 9.80 S 1,908.57 E -484.51 2.91 5798.71 34.68 151.60 5,287.64 54.98 S 1,935.80 E -447.92 3.68 5892.26 36.97 156.04 5,363.50 104.11 S 1,959.89 E -406.69 3.70 5985.23 39.27 160.70 5,436.65 157.45 S 1,980.97 E -360.63 3.96 6078.55 40.79 164.67 5,508.12 214.73 S 1,998.80 E -309.91 3.18 6173.63 43.21 167.37 5,578.78 276.46 S 2,014.13 E -254.25 3.18 6265.92 45.61 168.60 5,644.70 339.63 S 2,027.56 E -196.72 2.76 6357.04 48.09 169.16 5,707.02 404.85 S 2,040.37 E -137.03 2.76 6451.06 50.46 169.97 5,768.35 474.92 S 2,053.26 E -72.68 2.60 6544.59 53.52 172.52 5,825.95 547.74 S 2,064.44 E -5.24 3.91 INSITE V8.3.0 Page 2Job No:AK-XX-0902703435 Well Name:2S-10 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 6638.03 56.27 175.01 5,879.68 623.72 S 2,072.72 E 66.01 3.66 6731.17 57.89 176.93 5,930.30 701.70 S 2,078.20 E 139.91 2.45 6825.34 59.14 179.50 5,979.49 781.96 S 2,080.69 E 216.79 2.68 6919.12 60.23 180.98 6,026.83 862.91 S 2,080.34 E 295.07 1.79 7011.64 61.40 182.28 6,071.94 943.65 S 2,078.04 E 373.66 1.76 7106.70 64.15 184.57 6,115.43 1,028.01 S 2,072.97 E 456.45 3.60 7200.31 66.80 186.14 6,154.29 1,112.79 S 2,065.01 E 540.41 3.22 7293.03 70.01 187.65 6,188.41 1,198.36 S 2,054.65 E 625.74 3.78 7386.50 73.19 189.59 6,217.91 1,286.03 S 2,041.35 E 713.87 3.93 7429.08 74.76 190.75 6,229.67 1,326.31 S 2,034.12 E 754.65 4.52 7519.07 76.47 188.66 6,252.03 1,412.22 S 2,019.43 E 841.44 2.94 7551.02 76.99 190.97 6,259.36 1,442.86 S 2,014.13 E 872.40 7.22 7644.10 79.56 188.84 6,278.28 1,532.63 S 1,998.46 E 963.17 3.56 7741.66 81.29 193.19 6,294.51 1,627.03 S 1,980.08 E 1059.11 4.74 7836.02 82.12 193.31 6,308.12 1,717.92 S 1,958.68 E 1152.44 0.89 7929.79 83.68 196.46 6,319.72 1,807.83 S 1,934.78 E 1245.47 3.73 8024.10 85.16 198.23 6,328.89 1,897.42 S 1,906.79 E 1339.25 2.44 8118.25 84.92 198.72 6,337.03 1,986.38 S 1,877.07 E 1432.88 0.58 8214.05 87.87 197.65 6,343.05 2,077.21 S 1,847.24 E 1528.33 3.27 8308.48 89.62 196.13 6,345.12 2,167.53 S 1,819.81 E 1622.68 2.45 8402.76 89.04 196.59 6,346.22 2,257.99 S 1,793.26 E 1716.92 0.79 8496.37 89.28 197.02 6,347.59 2,347.59 S 1,766.19 E 1810.48 0.53 8591.38 90.69 196.25 6,347.62 2,438.62 S 1,739.00 E 1905.44 1.69 8686.38 90.69 196.87 6,346.48 2,529.68 S 1,711.92 E 2000.40 0.65 8780.66 90.82 196.20 6,345.23 2,620.05 S 1,685.09 E 2094.64 0.72 8874.49 90.45 195.66 6,344.19 2,710.27 S 1,659.34 E 2188.45 0.70 8969.32 90.10 194.75 6,343.74 2,801.78 S 1,634.47 E 2283.28 1.03 9064.96 90.41 194.56 6,343.31 2,894.30 S 1,610.27 E 2378.92 0.38 9159.93 89.62 194.95 6,343.29 2,986.14 S 1,586.09 E 2473.88 0.93 9252.61 88.70 196.18 6,344.65 3,075.41 S 1,561.22 E 2566.55 1.66 9348.40 87.84 197.17 6,347.54 3,167.13 S 1,533.75 E 2662.25 1.37 9443.16 86.71 198.42 6,352.04 3,257.25 S 1,504.82 E 2756.79 1.78 9536.45 87.36 198.72 6,356.87 3,345.56 S 1,475.15 E 2849.77 0.77 9630.68 89.14 197.19 6,359.75 3,435.16 S 1,446.12 E 2943.82 2.49 9725.08 88.77 196.01 6,361.47 3,525.61 S 1,419.16 E 3038.17 1.31 9819.22 89.11 194.88 6,363.21 3,616.33 S 1,394.09 E 3132.29 1.25 9913.93 90.03 193.95 6,363.92 3,708.05 S 1,370.52 E 3226.99 1.38 10008.07 90.31 192.72 6,363.64 3,799.65 S 1,348.80 E 3321.09 1.34 10103.19 90.72 192.82 6,362.79 3,892.42 S 1,327.78 E 3416.13 0.44 10196.95 90.72 192.38 6,361.61 3,983.91 S 1,307.33 E 3509.80 0.47 10292.58 90.82 190.63 6,360.32 4,077.61 S 1,288.26 E 3605.24 1.83 10386.51 90.41 188.73 6,359.32 4,170.19 S 1,272.46 E 3698.76 2.07 10481.73 90.17 190.16 6,358.83 4,264.12 S 1,256.84 E 3793.53 1.52 10576.55 90.31 190.21 6,358.44 4,357.44 S 1,240.07 E 3888.01 0.16 10670.99 90.58 191.19 6,357.70 4,450.23 S 1,222.54 E 3982.18 1.08 INSITE V8.3.0 Page 3Job No:AK-XX-0902703435 Well Name:2S-10 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 10765.27 90.55 192.15 6,356.77 4,542.56 S 1,203.47 E 4076.30 1.02 10858.48 89.83 194.07 6,356.46 4,633.34 S 1,182.33 E 4169.45 2.20 10954.19 90.24 195.91 6,356.41 4,725.78 S 1,157.57 E 4265.16 1.97 11050.22 89.25 196.71 6,356.83 4,817.95 S 1,130.61 E 4361.16 1.33 11144.66 85.50 197.95 6,361.16 4,907.99 S 1,102.51 E 4455.40 4.18 11238.25 86.77 197.88 6,367.47 4,996.84 S 1,073.79 E 4548.66 1.36 11333.47 88.83 196.90 6,371.12 5,087.63 S 1,045.35 E 4643.72 2.40 11428.31 88.94 196.37 6,372.97 5,178.48 S 1,018.21 E 4738.50 0.57 11523.26 90.24 196.00 6,373.65 5,269.67 S 991.74 E 4833.43 1.42 11617.81 88.42 195.84 6,374.75 5,360.58 S 965.81 E 4927.95 1.93 11712.45 88.25 194.90 6,377.50 5,451.79 S 940.74 E 5022.55 1.01 11807.67 90.93 193.49 6,378.18 5,544.09 S 917.39 E 5117.75 3.18 11902.78 90.58 194.66 6,376.93 5,636.34 S 894.27 E 5212.83 1.28 11997.99 90.21 195.48 6,376.27 5,728.27 S 869.51 E 5308.04 0.94 12092.97 90.65 195.51 6,375.56 5,819.80 S 844.14 E 5403.01 0.46 12187.12 90.17 195.43 6,374.89 5,910.53 S 819.03 E 5497.16 0.52 12281.45 90.45 194.34 6,374.38 6,001.70 S 794.80 E 5591.49 1.19 12375.72 90.00 196.52 6,374.01 6,092.56 S 769.72 E 5685.75 2.36 12470.40 88.18 193.33 6,375.51 6,184.02 S 745.34 E 5780.40 3.88 12564.81 86.47 192.23 6,379.92 6,275.99 S 724.48 E 5874.63 2.15 12660.18 87.56 191.39 6,384.88 6,369.21 S 704.98 E 5969.72 1.44 12755.53 87.15 193.10 6,389.28 6,462.29 S 684.78 E 6064.85 1.84 12850.38 87.36 193.44 6,393.83 6,554.50 S 663.04 E 6159.55 0.42 12944.88 88.83 192.50 6,396.97 6,646.53 S 641.84 E 6253.94 1.85 13039.56 88.63 194.13 6,399.07 6,738.64 S 620.04 E 6348.55 1.73 13133.08 90.00 195.43 6,400.18 6,829.06 S 596.19 E 6442.06 2.02 13225.82 89.66 197.16 6,400.46 6,918.07 S 570.17 E 6534.77 1.90 13320.40 89.93 198.82 6,400.80 7,008.02 S 540.96 E 6629.22 1.78 13414.08 89.66 199.42 6,401.13 7,096.53 S 510.27 E 6722.65 0.70 13510.10 88.87 200.31 6,402.36 7,186.83 S 477.65 E 6818.32 1.24 13602.84 89.21 201.53 6,403.92 7,273.44 S 444.54 E 6910.55 1.37 13697.55 89.73 200.11 6,404.79 7,361.96 S 410.88 E 7004.76 1.60 13786.78 90.00 197.85 6,405.00 7,446.33 S 381.86 E 7093.77 2.55 13882.43 91.54 195.91 6,403.72 7,537.85 S 354.09 E 7189.36 2.59 13980.69 92.13 195.38 6,400.57 7,632.42 S 327.60 E 7287.56 0.81 14076.36 90.27 196.21 6,398.57 7,724.45 S 301.57 E 7383.19 2.13 14170.95 88.80 197.85 6,399.34 7,814.88 S 273.87 E 7477.71 2.33 14265.96 88.49 196.48 6,401.58 7,905.63 S 245.84 E 7572.63 1.48 14361.22 87.08 196.55 6,405.27 7,996.89 S 218.78 E 7667.78 1.48 14455.93 87.29 195.88 6,409.92 8,087.72 S 192.37 E 7762.35 0.74 14549.80 87.91 194.54 6,413.85 8,178.22 S 167.76 E 7856.14 1.57 14644.65 86.05 194.54 6,418.85 8,269.91 S 143.98 E 7950.85 1.96 14739.72 85.64 193.74 6,425.73 8,361.85 S 120.82 E 8045.66 0.94 14834.45 88.80 192.11 6,430.33 8,454.06 S 99.66 E 8140.20 3.75 14896.00 88.80 192.11 6,431.62 8,514.23 S 86.75 E 8201.66 0.00 INSITE V8.3.0 Page 4Job No:AK-XX-0902703435 Well Name:2S-10 Survey Report DIRECTIONAL SURVEY DATA NOTES - Calculation based on minimum curvature method. - Survey coordinates relative to well system reference point. - TVD values given relative to drilling measurement point. - Vertical section relative to well head. - Vertical section is computed along a direction of 195.00 degrees (True) - A total correction of 18.60 deg from Magnetic north to True north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 14,896.00 feet is 8,514.67 feet along 179.42 degrees (True) WARRANTY HALLIBURTON ENERGY SERVICES, INC. WILL USE ITS BEST EFFORTS TO FURNISH CUSTOMERS WITH ACCURATE INFORMATION AND INTERPRETATIONS THAT ARE PART OF, AND INCIDENT TO, THE SERVICES PROVIDED. HOWEVER, HALLIBURTON ENERGY SERVICES, INC. CANNOT AND DOES NOT WARRANT THE ACCURACY OR CORRECTNESS OF SUCH INFORMATION AND INTERPRETATIONS. UNDER NO CIRCUMSTANCES SHOULD ANY SUCH INFORMATION OR INTERPRETATION BE RELIED UPON AS THE SOLE BASIS FOR ANY DRILLING, COMPLETION, PRODUCTION, OR FINANCIAL DECISION OR ANY PROCEDURE INVOLVING ANY RISK TO THE SAFETY OF ANY DRILLING VENTURE, DRILLING RIG OR ITS CREW OR ANY THIRD PARTY. THE CUSTOMER HAS FULL RESPONSIBILITY FOR ALL DRILLING, COMPLETION, AND PRODUCTION OPERATION. HALLIBURTON ENERGY SERVICES, INC. MAKES NO REPRESENTATIONS OR WARRANTIES, EITHER EXPRESSED OR IMPLIED, INCLUDING, BUT NOT LIMITED TO, THE IMPLIED WARRANTIES OF MERCHANTABILITY OR FITNESS FOR A PARTICULAR PURPOSE, WITH RESPECT TO THE SERVICES RENDERED. IN NO EVENT WILL HALLIBURTON ENERGY SERVICES, INC. SERVICES BE LIABLE FOR FAILURE TO OBTAIN ANY PARTICULAR RESULTS OR FOR ANY DAMAGES, INCLUDING, BUT NOT LIMITED TO, INDIRECT, SPECIAL OR CONSEQUENTIAL DAMAGES, RESULTING FROM THE USE OF ANY INFORMATION OR INTERPRETATION PROVIDED BY HALLIBURTON ENERGY SERVICES, INC. INSITE V8.3.0 Page 5Job No:AK-XX-0902703435 Well Name:2S-10 Survey Report
