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215-178
III • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate p r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: PROD to WAG pr 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratory r 215-178-0 _ 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-20908-62 7.Property Designation(Lease Number): 8.Well Name and Number: ADL025640;ADL024547 KRU 1G-05L1-02 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 10649 feet Plugs(measured) None true vertical 6512 feet Junk(measured) None Effective Depth measured 10649 feet Packer(measured) 8810,9061, 9183 true vertical 6512 feet (true vertical) 6115,6297,6387 Casing Length Size MD TVD Burst Collapse CONDUCTOR 50 16 80' 80' SURFACE 2494 12 2524' 2278' L1-02 WINDOW 7 7 9261' 6445' L1 WINDOW 5 7 9285' 6463' PRODUCTION 10041 7 10071' 7056' ' COVED LINER L1-02 1404 2.375 10649 6512' JAN 20 2016 Perforation depth: Measured depth: Slots: 9246-10643 True Vertical Depth: 6434-6509 .4 OGCC Tubing(size,grade,MD,and TVD) 3.5 x 5.5 @ 9222', L-80/H-40, 9312 MD, TVD Packers&SSSV(type,MD,and TVD) TRDP-CAMCO TRDP-1A SSA @ 1831 MD and 1757 TVD PACKER-BAKER FHL RETRIEVABLE PACKER @ 8810 MD and 6115 TVD PACKER-BAKER FHL RETRIEVABLE PACKER @ 9061 MD and 6297 TVD PACKER-BAKER 85-40 Fl PERMANENT PRODUCTION PACKER @ 9183 MD and 6387 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): t - mak' l iU I Treatment descriptions including volumes used and final pressure: taEft to COT." 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut-in Subsequent to operation 2345 800 1305 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 r 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 p✓ 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: 315-758 Contact Bob Christensen/Darrell Humphrey Email: n1139(u7conocophillips.com Printed Name Robert . C ristensen Title: NSK Production Engineering Specialist Signature Phone:659-7535 Date Y/8y/ 6 Form 10-404 Revised 5/2015 VT1- Z`19 1/G RBDMS c,L. JAN 2 1 2016 Submit Original Only • 1 G-05L1-02 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 12/26/15 BRUSHED & FLUSHED/ DRIFTED TBG 2.80"TO X-NIPPLE @ 9210' RKB. SET 2.81"XX 12/27/15 SET DVs @ 6629' & 7830' RKB (GOOD DDT ON TBG). PULLED OV @ 8722' RKB. 12/28/15 SET DV @ 8722' RKB. MIT-IA 3000 PSI; PASS. PULLED CATCHER, EQUALIZED & 01/15/16 Well put on injection service KUP11. 1G-05L1-02 4 ConocoPhillips ; Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status ncl() MD(ftKB) Act Btm(ftKB) cnrrrr;n,;lhps KUPARUK RIVER UNIT 10,649.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 10-05L1-02,12/3020152:19:28 PM SSSV:NONE Last WO: 29.99 2/17/1983 Vertical schematic(actual) _ Annotation Depth(ft(B) End Date Annotation Last Mod By End Date - - -- Last Tag: Rev Reason:GLV C/O lehallf 12/30/2015 ......................... HANGER,26.4 it)'ll ttf Casing Strings `(� Ir [JCasing Description IOD(in) ID(in) 'Top( ftKB) Iset Depth(ftKB) I Set Depth(TVD)...I Wt/Len II...' Grade I Top Thread L1-02 LINER 2 3/811.992 9,244.7 10.649 0 4 601L-80 ST-L Liner Details • Nominal ID Top(ftKB) I Top(TVD)(ftKB) Top Incl(°)I Item Des ,.hA Com (in) . CONDUCTOR;30.0-800' 9,244.7 DEPLOY BAKER SHORTY DEPLOYMENT SLEEVE 1.000 I Perforations&Slots Shot Den SURFACE;29.7-2,523.9 Top(TVD) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 9,245.5 1,064,303.0 10/8/2015 SLOTS Slotted Liner GAS LIFT;2,843.2 Notes:General&Safety End Date Annotation 10/27/2015 NOTE ADDED LATERALS L1(off main wellbore) L1-01,L1-02(off main wellbore) GAS LIFT;4,963.2 GAS LIFT,6,629.5 GAS LIFT,7,828.9 GAS LIFT;8,722.3 LOCATOR;8,778.9 SEAL ASSY;8,779.3 limis PER;8,809.6 PACKER;8,809.6 NIPPLE;8,831.7 El S GAS LIFT:8,885.3 • GAS LIFT;8,946.8 i'.. 114 I (PERF;8,976.09050.0 1♦;. I a PACKER;9,061.4 GAS LIFT;9,073.0 r IPERF;9.095.09,131.0 — 1 i a GAS LIFT;9,145.9 Ilk a LOCATOR;9,182.3 IML PACKER;9,183.0 SEAL ASSY;9,183.1 9: =' SBE;9,186.3 SE 4 a a NIPPLE;9,210.2 a A PRODUCTION;29.9-10,071.0 — L1-01 LINER;9,700.7-11,451.0 L1-02 LINER,9,244.7-10,649.0 SLOTS;9,245.5-1,064,303.0---, • • o © L1 N W 0 E 0 . CO � I 'N O (T 0) "O -0 n a) ` ''� n • J 0 0 IS 0- • > v N o o \\ N N N N V) • N N 0 • z ! C p O O @ @ y C z LV !! 11 '� Q N N J J C J J C N a) • o) _U NI Z Z ,i m m m m 7J ii: Z Z Z N ti N 1 @ co 7 7 C C C/) C C U) 7 7 3 J O > CO I m U) u) O O LL LL U) LL LL U) U) U) •>. >. > ,on p I a) p p j p p j o a) a) v I >. — f6 O O 2 2 O O c > > C 1 0 i) J W W 6) N 0 L N )n CO W W LL CO U) ^$ Z • > N N Z N N N N N N N N N N N a n o oa) o 0 0 0 0 0 0 0 0 O O Q TO. (0V J J E LL J J J J J J J J J J J C CO Ln Ln Ln 0L Lf) LU LO Ln Ln Ln Ln to Ln 1 o 2 0 O.- O Y - O O O O O O O O O O O E' o 10 O n O D U) m O O O O 0 O O n O O 0 O U > p 0 C1 0 N p 0 d @ U) 0 0 0 0 0 0 0(8 0 0 0 0 Z e° LE LLQ LL p OW LL it it it it it LLQ it it LL it II E' o o o Y� oIX o 0 o f g o 0 o 0 g o 2 3 0 E''c , 0 Q c 0 'C •C 'c w O O. O O 't O N Wp O g O O 0 0 O 0 O 0- O r O N 0 O O Q fA J V1 p, vp 0Q 0M v v rn v v ') 0_ i • • C O O N O •N N • O \ N 01 Z • O O Co 9 >- > >- I m N — J C N cid Cr) 0 I CO Co CO it it) a) n N N O 2 7 C C p L >. ca It) 9 0 0 0it iL u) 6s c 1 i • o 2f ~OI N l0 cZ OQ cLU) C Z Lo E. , v . OO O O F > UO m Q IIVi E Co - 1 in co co i - j020- O O O O 0 0 01 O cl O O O O D >Q iic0i aim ai .2 .2. '13d ! w O > I1 N it V it it I1 lL 2 C C Qco v— ct, 0 o g g v o Y E 'c c Co 'c 'c c 'c p E @ 011 o I o 0 0 ow, wo E > > _ _ J a)NIaa)i NI 11) N _N _N aa)i 00 cOQ O 1 @ O ce < c W O W O W LU W W J N S @ — O °� ) ` 0. J V o 0 0 0 0 0 E y E .� 0 _ N N N N N N ca 7 0 LU = 0 0 CO CD U) Z m O CD f6 O It E W z c co d co 0 o. I E 3 E C.) a) 6s Z11 1o (62co Q m ix o o rn _ N p --I a c ` 7 •o E - 7 - o m 0 0 tC c y O 2 � o a) p I N E f� E / n N U T p U ( l�/� d O J 0 } E N Q �' ° a I— o Lo 1 o E I— � o � 11 0 z N RI Co C Z m re• oo H E f Y Co6s ._ 7 ��//�� •C. C a) V/ p N c o D Y ° I n Q Z o o 'Li v iii O E >., £ U c I 0 2 Co co U z u) ! I Co CO 63 Co C6 06 N ',. 10 10 N 0 0 0 0 0 0 CO C Q 1 N N O O Co To X6 6 CO +a 2 Z N 00m O 0I Q7 O) O •t6 �� (� \ p O c 0 0 0 0 0 0 0 3 £ o t'`' // n ~ 'v v v v v v v C — m CC 1n CO CO CO CO CO CO co — w E a O N N N NNNN N co C.) O C. a) 0 C 2 hi a N N co 0 re H `m Ill al 0 0 ?3 C Ili Tr • p Q O CO Q z o co w C U U U U U U U U I O N v m J N •a c.7 0 0. 7 0 tZ 0. Co U ! E In p d 0 0 0 0 0 0 0 o m so o ° m 0 o a� p 0 a •a w w w w w w _ 3 ! ? •U d 0 0 U Ce I 0 • O O N N t0 N CO N 0 O I Z N , Q rn U ti e49 5 I-8 o in 6 o '$ z 3 I Z 0 a z N w l6 HN a ce Q C ire N pcoa A J li J_ W�/ 0. = LL V W 0Z V 0 C..) Z o Q m J 0. a (0 C 0 N • ti E E V M o U o M J : Q 03 O 0. 1.0 qiZ N 2 ' r /LLI cc O M0 YI, M 416,1 CO '8 ip. Q ' C Y F" fi Tx Q C Z E Q £ Uti is z d • N 0 I ro >m03 1.T •••• I N d 0co coo w o 1 w U ;r 'Q U' EQ c OO a 2 C) OF TI • • I 1/7_;---,,v THE STATE Alaska Oil andGas �w -��.—'� ALASKA.L S Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS— Fax: 907.276.7542 www.aogcc.alaska.gov Robert D. Christensen Engineering Specialist c� ��"�VVQ. ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1G-05L1-02 Sundry Number: 315-758 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, /43 Cathy . Foerster Chair 3 DATED this 21 day of December, 2015 Encl. RBDMSU.DLC 2 4 2015 STATE OF ALASKA /AKA OIL AND GAS CONSERVATION COMMON • APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown 0 Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Oil to WAG Conversion Q' • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. ConocoPhillips Alaska,Inc. Exploratory ❑ Development ❑✓ • 2151780 - 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-029-20908-62 - 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? KRU 1G-05L1-02 - Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL025640;ADL024547 - 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): 10649 6512 10649 6512 Casing Length Size MD ND Burst Collapse CONDUCTOR 50 16 80 80 SURFACE 2494 12 2524 2278 RECEIVED L1-02 WINDOW 7 7 9254 6445 DECL1 WINDOW 5 7 9285 6463 C 16 2015 PRODUCTION 10041 7 10071 7056 LINER L1-02 1404 2.375 10649 6512 i Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Slots:9246-10643 ' 6434-6509 3.5 x 5.5 @ 9222' L-80/H-40 9312 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PKR=BAKER FHL RETRIEVABLE PACKER • MD=8810 TVD=6115 PKR=BAKER FHL RETRIEVABLE PACKER , MD=9061 TVD=6297 PKR=BAKER 85-40 Fl PERMANENT PRODUCTION PACKER • MD=9183 TVD=6387 SSSV=CAMCO X NIPPLE • MD=8832 TVD=6130 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development ❑ Service Q 14.Estimated Date for 15.Well Status after proposed work: 12/20/2015 ❑ ❑ WDSPL ❑ Suspended 0 Commencing Operations: OIL WINJ 16.Verbal Approval: Date: GAS ❑ WAG Q • GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Bob Christensen/Darrell Humphrey Email n1139@conocophillips.com Printed Name Robert D.Christensen Title Engineering Specialist Signature • // / 'IP' /2//41// 1.....1 ii. _.1 Phone:659-7535 Date , COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 i5^/5 Plug Integrity Li BOP BOP Test ❑ Mechanical Integrity Test Location Clearance Other:_5f# -e w, -4""),1 55-r d i i 7 - / 4— .&1c/el Q f?'-rt— i"j.1;)i'Ji i d1 /i.0 r e:tJ i , Post Initial Injection MIT Req'd? Yes o ❑ G G // Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: / `t / / APPROVED BY R,' • Approved by: / P i COMMISSIONER THE COMMISSION Date: /2.—at—/5� 1 1 I5 9I4 `JJ�/N ,j j_" Submit Form and Form 10-403 Revi•ed 11/2015 rivGlINo lid for 12 month>cir�W1Q e gfi�gp (2e7,70.— r`f Attachments in Duplicate • • • • 1 G-05L1-01 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert Kuparuk Well 1G-05L1-02 (PTD# 215-1780) from Oil Production service to Water Alternating Gas Injection service as the well has completed the, post CTD operations, pre-production period. Area of Review: Kuparuk well 1G-05L1-02, CTD operations to added laterals L1, L1-01, & L1-02 were completed in September, 2015. Pre-production began on 10/25/2015 and will continue until the well can be converted back to injection. Wells 1G-05, 1G-05L1, 1G-05L1-01, and 1G-05L1-02 will provide injection support nearby area wells including 1A-03, 1G-12 and 1G-11A. The top of the Kuparuk A4 sand was found at 9698' and /6421'tvd Area Map with 1/4 mile radius around target injection zone (see attached): Tha map attached shows that there are 6 production/injection wells located within a 1/4 mile radiurs of the 1G-05, 05L1, 05L1-01, & 05L1-02 penetrations of the Kuparuk A sands. Mechanical Condition of Well to be Converted: The mechanical condition of Kuparuk well 1G-05 is good and classified as a "Triple Selective Well". A State- witnessed MIT-IA will be performed once well 1 G-05 is converted to water injection, online, and stabilized. The injection tubing/casing annulus is isolated via a Baker FHL Packer located at 8810' and (6115' tvd). The 10-3/4" Surface casing was cemented with 1300 sx AS III, followed by 250 sx AS I, followed by 60 sx AS I (top job). The 7-5/8" Production casing was cemented with 1000 sx Class 'G' followed by 250 sx AS I. CBL and interpretation of the cement quality: The CBL interpretation was completed on the PTD's. KUP • 1G-05L1-02 ConocoPhillips ii Well Attributes Max Angle&MD TD Alaska,Irl(; Wellbore API/UWI Field Name Wellbore Status Incl 7) MD(MB) Act Btm(ftKB) cPreoris KUPARUK RIVER UNIT 10,649.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date t0-05L1-02,11/22/20154:0151 PM SSSV:NONE Last WO: 29.99 2/17/1983 Verncal schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ........ .... ... Last Tag Rev Reason:GLV C/O pproven 11/22/2015 HANGER;26.4 li'_ ,•il ._,,,..,,..,,_.._w__..,.....,. , Casing Strings F] 0 Casing Description OD(in) ID(in) Top(ftKB) Bet Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread J Lt-02 LINER 2 3/8 1.992 9,244.7 10,649.0 4.60 L-80 ST-L Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl 7) Item Des Com (in) -A-AA.CONDUCTOR;30.0-80.0- 9,244.7 - DEPLOY BAKER SHORTY DEPLOYMENT SLEEVE 1.000 Perforations&Slots Shot Dens SURFACE;29.7-2,523.9-4 Top(TVD) Btm(TVD) (shots/f Top(ftKB) Btrn(ftKB) (kKB) (ftKB) Zone Date t) Type Com 9,245.5 1,064,303.0 10/8/2015 SLOTS Slotted Liner GAS LIFT;2,843.2 +;-` Notes:General&Safety End Date Annotation 10/27/2015 NOTE:ADDED LATERALS L1(off main wellbore),L1-01,L1-02(off main wellbore) GAS LIFT;4,963.2 — al U GAS LIFT;6,629.5 ii 11, GAS LIFT;7,828.9 Mr at GAS LIFT;8,722 3 ar, p I LOCATOR;8,778.9 . SEAL ASSY;8,779.3 PBR;8,786.3 PACKER;8,809.6 If NIPPLE;8,831.7 GAS LIFT;8,885.3 GAS LIFT;8,946.8 (PERF;8,976.0-9,050.0 PACKER;9,081.4 - GAS LIFT;9,073.0 (PERF;9,095.0-9,131.0 — it GAS LIFT,9,145.9 LOCATOR;9,182.3 PACKER;9,183.0 "•um�'f'• SEAL ASSY;9,183.1 ">t' SBE;9,186.3 i. �f. T It • NIPPLE;9,210.2 A A PRODUCTION;29.9-10,071.0 _ — M L1-01 LINER;9,700.7-11,451.0 L1-02 LINER;9,244.7-10,649.0 --- SLOTS;9,245.5-1,064,303.0 9 0 \ ConocoPhillips 1 G-05 Well Alaska 14Dec15 ADL025640 ADL025639 n o 1G 11P t C7 4,iiii Fr- 1 iiiiiMI lit\ i1 N O J LO O CD a rX J i to Q C)`b c� ^P S2, NP ADL025647 ADL025648 Well Pad 1G-05 Open Interval 1G-05 Trajectory 1G-05L1 Open Interval -b 1G-05L1-01 Open Interval ®1G-05L1-02 Open Interval Well Within 1G-05L1 Radius Well Within 1G-05L1-01 Radius 1/4 Mi. 1G-05 Open Section Radius References: 1/4 Mi. 1G-05L1 Open Section Radius Well Data: ConocoPhillips Alaska Well Database (ATDB) Surface Facilities:ATDB 1/4 Mi. 1G-05L1-01 Open Section Radius N ❑ 1/4 Mi. 1G-05L1-02 Open Section Radius I Pad Outline 0 0.1 0.2 0.3 0.4 I I CPAI Lease Miles • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil , Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended lb.Well Class: 20AAC 25.105 20AAC 25.11D Development Q ' Exploratory ❑ GINJ fl WINJ Ei WAGE WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6.Date( ,Susp.,or 14.Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 10/12/2015 215-178 " 3.Address: 7. Date Spudded: 15.API Number: P.O.Box 100360 Anchorage,AK 99510 10/9/2015 50-029-20908-62 4a.Location of Well(Governmental Section): 8.Date TD Reached: 16.Well Name and Number: Surface: 971'FSL,666'FWL,Sec.29,T12N, R10E, UM 10/11/2015 1G-05L1-02 • Top of Productive Interval: 9.Ref Elevations: KB: 90' 17. Field/Pool(s): 4984'FNL,3306'FEL,Sec 32,T12N,R10E, UM GL: 60' BF:60' Kuparuk River Field/Oil Pool- Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 972'FNL,3090'FEL,Sec 5,T11N,R10E, UM N/A ADL 25640,25647 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19.Land Use Permit: Surface: x- 540441 y- 5981620 Zone- 4 10,649'MD/6,422'TVD • 2571,465 TPI: x- 541800 y- 5975672 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 542027 y- 5974405 Zone- 4 N/A 1500'MD/1442'TVD 5. Directional or Inclination Survey: Yes Q(attached) No ❑ 13.Water Depth,if Offshore: 21.Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 9,255'MD/6,437'TVD 22.Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper,resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary RECEIVED GR/RES NOV 16 2015 AOGCC 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" 65 H-40 30 80 30 80 24 300 sx ASI I 10-3/4" 45.5 K-55 29.7 2524 29.7 2278 13.5 1300 sx ASIII,250 sx ASI 7" 26 K-55 22.9 10071 22.9 7056 8.5 1000 sx CI G,250 sx AS I 5-1/2" 14 H-40 9103 9312 6390 6438 7 KO joint 2-3/8" 4.6 L-80 9244' 10649' 6335' 6422' 3 Slotted Liner 24.Open to production or injection? Yes Q No ❑ 25.TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3-1/2" 9190' 9183'MD/6387'TVD Slotted Liner from 9244'-10649'MD/6335'-6422'TVD 26.ACID, FRACTURE,CEMENT SQUEEZE,ETC. C;OIMPLETON Was hydraulic fracturing used during completion? Yes❑ No Q✓ DATE to(12 f 15- Per 20 AAC 25.283(i)(2)attach electronic and printed information /ERIF ED DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 10/25/2015 Gas Lift Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 10/28/2015 6 hrs Test Period IN. 115 bbl 57 MCF 371 bbl Open 525 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 229 psi 1117 psi 24-Hour Rate 428 bbl 225 MCF 1471 bbl 21 deg API Fo 0-40 vised 11/2015 ONTINUED ON PAGE 2 Submit ORIGINIAL onlyi'� a/ f�S- r-t_ 1- /z11,5" . / RBDNI OV 18 2015 IV-,�' 128.CORE DATA Conventional CO,: Yes ❑ No El Sidewall Cores:Os ❑ No Q If Yes, list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 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 1500' 1442' Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval 9250' 6437' information, including reports,per 20 AAC 25.071. Top Kuparuk A4 9698' 6421' TD Kuparuk A4 10649' 6422' Formation at total depth: Kuparuk A4 ' 31. List of Attachments: �Zwti Ad` � op Si `w (S devm.oecit Dt_Avvv 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. Contact: Jason Burke @ 265-6097 Email: Jason.Burkecop.com Printed Name: D.Venhaus Title: CTD Engineering Supervisor Signature: Gv.�— Phone: 263-4372 Date: /1-4.—05 —05 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection, Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and 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 11/2015 Submit ORIGINAL Only KUP • 1G-05L1-02 Conoc Phillips ° Well Attributes • Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status -ncl 7) MD(ftKB) Act Btm(ftKB) = yxpc KUPARUK RIVER UNIT 10,649.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Ord(N) Rig Release Date 1G-05L1-02,10/27/20154'.24'.32 PM SSSV;NONE Last WO: 29.99 2/17/1983 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date _...._._......_._...__. Last Tag Rev Reason.ADD LATERALS L1(off main smsmith 10/27/2015 HANGER ra II wellbore),L1-01,L1-02(off main wellbore) Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread '� L1-02 LINER 2 3/8 1.992 9,244.7 10,649.0 4.60 L-80 ST-L Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl 7) Item Des Com (in) .A.AACONDUCTOR;30.0-80.0• ' /van. 9,244.7 DEPLOY BAKER SHORTY DEPLOYMENT SLEEVE 1.000 Perforations&Slots Shot Dens SURFACE;29.7-2,523.9 Top(ND) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 9,245.5 1,064,303.0 10/8/2015 SLOTS 'Slotted Liner GAS LIFT;2.843.2 4 Notes:General&Safety _ End Date Annotation 10/27/2015 NOTE:ADDED LATERALS L1(off main wellbore),L1-01,L1-02(off main wellbore) GAS LIFT;4,983.2 GAS LIFT;6.629.5 GAS LIFT;7,828 9 all GAS LIFT;8,722.3 LOCATOR;8,778.9 SEAL ASSY;8,779.3 •i PER;8,786.3 - PACKER;8,809.8 '- NIPPLE;8,831.7 GAS LIFT;8.885.3 II GAS LIFT;8,946.8 IPERF;8,976.0-9,050.0 • I PACKER;9,061.4. ... GAS LIFT;9,073.0 (PERF;9,095.0-9,131.0 1. I - GAS LIFT;9,145.9 LOCATOR;9,182.3 - PACKER,9,183.0 "'•S.•'' SEAL ASSY;8,183.1 :''.M..'.: SEALMt SEE;9,186.3 ' le I NIPPLE;9,210.2 1' III 4 PRODUCTION;29.9-10,071.0 Is L1-01 LINER;9,700.7-11,451.0 L1-02 LINER;9,244.7-10,649.0 _. SLOTS;9,245.5-1,064.303.0 • 0 � I 'I a) I' L/) ti '1 r-1 'c 'I m m 0 'I o 2 ' p N ❑ ❑ I� N:15 - 0 c_ 0 c I I G6 m 0= E ❑ -❑ p EII Q -a 2-3_ 06 _ . N O Cc NZ\I S`, c I I � iv 'so 2 cco N 00 � LN I m E yr yr 22 u co grn 2 N0, t I' cu Q = 0) w ❑ _-- 05 ❑ , I' N coo Fr) c0M in 2M 0 ' 0 co CO I w rn `� °_°°D m �rn 03 °) ow II I zvo 00 N o IA 2 mY co CO Y U) (j)T- caQ No ' Co• O - �2 N N N U N_ II II cr co u- - a © a to 0 co i M (p N r' C QY W0 @ 10Lc X E IL E LL CO X CO LO o in I I CV CV N N CV N N N Y ,_ N coNN UN 'I -°, I ❑ p T- T.- <6(6 7 co r co - r I (n 2 2 M M 0 mm M co LOM CO m M(f) I1 0 op co i 0 'I I a'M M 5 I a 0) 0) ic N I 03 Csl 00 I co CO M 't ii r� 0�)` I co I < 0) 0) N V 'I as (�) O II V III III a. Y Y SII li E ilit / :.:...._ .... tri // . iiiiiiiuiul■=11 IM�i1 Oil IMS: : _ // : -1 f rI nyii . . L,\ ivvm I— ` 0 I in 1 a III Iii 'I U T II o LC) zi- L ❑❑ 0 I U) YN 2 2 �o // II �❑ � � Igicn �nc) r) // 1' °v� YT u' @� yrnrn �� // I oco irk(0o O I I 1 I II I I o N ❑ Lc.) '2 crorno 0o I' I 0� r` m 4t 0) N2 m co b N .. _N I V' r ) Lir C I' O— O— CO n Ch h r N c-N WSR- Well Service Report . Page 1 of 1 Well Service Report Well Job Scope CPAI Rep 1G-05 DRILLING SUPPORT - CAPITAL FAMA, JAKE Date Daily Work Unit Number 6/14/2015 2266 Network# Company Unit Supervisor 10370448 CPAI FAMA, JAKE Initial& INITIAL AND FINAL T/I/O Final 1200/50/0 Field: KUPARUK RIVER UNIT Pressures: SET 3 1/2" X 5 1/2" BAKER WHIPSTOCK TOP AT 9277', ORIENTATION 5 DEGREES ROHS. 2 RA TAGS AT 9284'. BOTTOM OF WHIPSTOCK AT 9290. 24 hr. Summary CORRELATED TO DRESSER CBL DATED 2/16/83. FOUND 5 1/2" TUBING COLLARS AT 9270'AND 9314'. DEEPER THAN EXPECTED. JOB COMPLETE. STARTTIME OPERATION 07:30 AM DRIVE TO 1G PAD 08:00 AM HOLD PJSM 08:15 AM RIG UP PCE 08:45 AM MAKE UP WHIPSTOCK 09:45 AM PT PCE RUN IN HOLE WITH HEAD/SWIVEL/2 X ANTI ROTATIONAL 10:15 AM CENTRALIZERS /WPP/FIRING HEAD/#10 SETTING TOOL/WHIPSTOCK. TOTAL LENGTH 44'MAX OD 2.7" 12:15 PM CORRELATE TO DRESSER CBL LOG. SET TOP OF WHIPSTOCK AT 9277'. 2 RA TAGS AT 9284'. BOTTOM OF WHIPSTOCK AT 9290'. 12:45 PM POOH 01:45 PM RIG DOWN E-LINE 03:00 PM DRIVE TO KOC Fluid Type To From Non- Note Well Well recoverable http://akapps.conocophillips.net/alaskawelleventquery/worklog.aspx?ID=04CA78099AF... 11/12/2015 a aerations Summary (with Timelog Depths) 1G-05 ConocoPhiitips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/22/2015 9/22/2015 4.00 MIRU MOVE MOB P RD checklist completed on 1G-12. 0.0 0.0 07:00 11:00 9/22/2015 9/22/2015 5.00 MIRU MOVE MOB P PJSM with Peak.RDMO 1G-12 to 1G- 0.0 0.0 11:00 16:00 05 9/22/2015 9/22/2015 2.00 MIRU MOVE RURD P Start rig up,start working post move 0.0 0.0 16:00 18:00 check list. 9/22/2015 9/22/2015 3.50 MIRU WHDBOP NUND P Nipple up BOP, Check tree bolts,40 0.0 0.0 18:00 21:30 minutes,zero loose bolts,hook up Kill Tank to rig, Note:Rig accepted at 18:00 9/22/2015 9/23/2015 2.50 MIRU WHDBOP BOPE P Perform initial BOPE test 250/3,500 0.0 0.0 21:30 00:00 psi,annular 250/2,500 psi.Test waived by(AOGCC)John Crisp. 9/23/2015 9/23/2015 5.00 MIRU WHDBOP BOPE P Continue initial BOPE test 250/3,500 0.0 0.0 00:00 05:00 psi,annular 250/2500 psi.No BOPE failures. 9/23/2015 9/23/2015 4.50 MIRU WHDBOP PRTS T BOPE test completed.Tree serviced 0.0 0.0 05:00 09:30 again,master valve passed,swab#1  leaking by to surface,swabs cycled and serviced,no visible leaks. 9/23/2015 9/23/2015 2.50 MIRU WHDBOP PRTS P Fluid pack coil.Test inner reel iron& 0.0 0.0 09:30 12:00 packoffs. 9/23/2015 9/23/2015 2.00 MIRU WHDBOP MPSP P FMC on location.PJSM,bring 0.0 0.0 12:00 14:00 equipment to rig floor.PJSM,presuere test lubricator,pull TWCV(850 psi on well)PJSM.Offload FMC equipment. 9/23/2015 9/23/2015 1.49 MIRU WHDBOP PRTS P Test PDL&Tiger Tank lines. 0.0 0.0 14:00 15:29 9/23/2015 9/23/2015 0.01 SLOT WHDBOP PRTS P 0.0 15:29 15:30 9/23/2015 9/23/2015 2.50 PROD1 WHPST PULD P Check coil and CTC,install floats, 0.0 0.0 15:30 18:00 inspect injector chains,change out bales while waiting for BOT rep.with vibration pup stuck behind rig in Prudhoe. 9/23/2015 9/23/2015 4.10 PROD1 WHPST PULD P PJSM-MU BHA#1.PJSM PUD BHA 0.0 73.5 18:00 22:06 #1,surface test MWD,tag stripper,set depth. 9/23/2015 9/23/2015 0.85 PROD1 WHPST TRIP P RIH w/milling assembly,while 73.5 9,280.0 22:06 22:57 pumping SW,tie-in to K1 for-3.5' correction,continue in hole.Dry tag whiptock @ 9,280'. 9/23/2015 9/23/2015 0.55 PROD1 WHPST CIRC P PUH.Circulate to used 9.1 ppg mud. 9,280.0 9,260.0 22:57 23:30 9/23/2015 9/24/2015 0.50 PROD1 WHPST WPST P Tag WS with pump on at 9,280.5' 9,260.0 9,280.5 23:30 00:00 9/24/2015 9/24/2015 9.75 PROD1 WHPST WPST P Start milling window exit as per well 9,280.5 9,286.5 00:00 09:45 plan. 1.50 BPM @ 3,610 PSI, BHP=3,982 PSI,CTW=13K, WOB=1K,ROP=1. 9/24/2015 9/24/2015 2.15 PROD1 WHPST WPST P Start drilling rat hole 1.5 bpm at 3,531 9,286.5 9,300.0 09:45 11:54 psi,BHP 3,974 psi,CWT 10.9k, WOB.9k 9/24/2015 9/24/2015 1.10 PROD1 WHPST REAM P 9,300 ft,TD rathole,back ream 9,300.0 9,300.0 11:54 13:00 window area 25L,35R,HS,dry drift window area clean.PUW 30k,pump 5x5 sweep. Page 1/16 Report Printed: 11/12/2015 Operations Summary (with Timelog Depths) 0 1-i . I •}` • 1G-05 ConocoPtt:iliips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/24/2015 9/24/2015 0.55 PROD1 WHPST TRIP P POOH for build assembly 9,300.0 8,570.0 13:00 13:33 9/24/2015 9/24/2015 0.85 PROD1 WHPST DLOG P Log HRZ @ 15 FPM 8,570.0 8,570.0 13:33 14:24 9/24/2015 9/24/2015 1.35 PROD1 WHPST TRIP P Continue OOH for drilling assembly 8,570.0 72.5 14:24 15:45 9/24/2015 9/24/2015 2.65 PROD1 WHPST PULD P PJSM.PUD BHA#1,EDC open,FVS 72.5 0.0 15:45 18:24 and UQC checks leaking,had close annular,bleed off PDL,LD BHA.Load BHA#2 in PDL. 9/24/2015 9/24/2015 0.90 PROD1 DRILL PULD P PJSM.PD BHA#2 0.0 73.5 18:24 19:18 9/24/2015 9/24/2015 2.25 PROD1 DRILL TRIP T BHA became stuck in wellhead, 73.5 73.5 19:18 21:33 several attempts were made to free BHA,working slickline and choke with no success.Decide to close annular and bleed off to check BHA placement.Stripped off PDL and close pipe rams on BHA.However wrong size pipe rams were closed. 9/24/2015 9/25/2015 2.45 PROD1 DRILL PULD T Closed 2 3/8"pipe/slip rams,strip over 0.0 0.0 21:33 00:00 wellhead,equalize,open rams,space out,close deployment rams.PUD BHA#2,LD BHA in mousehole,LD MWD in pipe shed.Load ODS PDL with BHA. 9/25/2015 9/25/2015 4.50 PROD1 DRILL BOPE T Crew chage,PJSM.Change-out 2" 0.0 0.0 00:00 04:30 pipe rams and test.LD Test equipment. 9/25/2015 9/25/2015 1.40 PROD1 DRILL PULD T PJSM.PD BHA#3 0.0 72.6 04:30 05:54 9/25/2015 9/25/2015 1.80 PROD1 DRILL TRIP P RIH with Build BHA#2,2.2+°AKO 72.6 8,840.0 05:54 07:42 motor and RB HYC bi-center bit. 9/25/2015 9/25/2015 0.15 PROD1 DRILL DLOG P Log K1 for minus 3 ft correction,PUW 8,840.0 8,870.0 07:42 07:51 28k. 9/25/2015 9/25/2015 0.45 PROD1 DRILL TRIP P Continue RIH 8,870.0 9,300.0 07:51 08:18 9/25/2015 9/25/2015 14.25 PROD1 DRILL DRLG P 9,300 ft, OBD 1.5 bpm at 3,370 psi, 9,300.0 9,660.0 08:18 22:33 BHP 3,977 psi,CWT 10.8k,WOB 1.4k, IA 170,OA 5,slow drilling thru ankerite from 9,418',hourly BHA wipers,PUW's 30k,broke out of ankerite @ 9,472',ROP=85. 9/25/2015 9/25/2015 0.25 PROD1 DRILL WPRT P Wiper to window,PUW=30K,RBIH. 9,660.0 9,660.0 22:33 22:48 9/25/2015 9/25/2015 0.95 PROD1 DRILL DRLG P Drill ahead:1.55 BPM @ 3,610 PSI, 9,660.0 9,740.0 22:48 23:45 BHP=4,050 PSI,CTW=9K, WOB=2.2K,ROP=90.End of build @ 9,740'.Pump 5 X 5 sweeps. 9/25/2015 9/26/2015 0.25 PROD1 DRILL TRIP P POOH for RSM assembly 9,740.0 9,304.0 23:45 00:00 9/26/2015 9/26/2015 2.75 PROD1 DRILL TRIP P OOH for RSM assembly,jet 5 1/2" 9,304.0 69.5 00:00 02:45 BTP @ 9,263',continue OOH.Space- out. 9/26/2015 9/26/2015 1.75 PROD1 DRILL PULD P PJSM.PUD BHA#3,LD BHA. Injector 69.5 0.0 02:45 04:30 maintenance,counter repair. 9/26/2015 9/26/2015 1.15 PROD1 DRILL PULD P PJSM.MU/PD BHA#4 0.0 69.5 04:30 05:39 9/26/2015 9/26/2015 1.70 PROD1 DRILL TRIP P RIH with drilling BHA#4,RSM with 69.5 8,840.0 05:39 07:21 RB HCC bi-center bit Page 2/16 Report Printed: 11/12/2015 0 i Operations Summary (with Timelog Depths) f r _ = 1G-05 Conoc°Phitiiips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start lime End lime Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/26/2015 9/26/2015 0.20 PROD1 DRILL DLOG P Tie in to K1 for minus 4 ft correction. 8,840.0 8,872.0 07:21 07:33 9/26/2015 9/26/2015 0.55 PROD1 DRILL TRIP P RIH with BHA#4,PUW above window 8,872.0 9,740.0 07:33 08:06 29k. 9/26/2015 9/26/2015 4.50 PROD1 DRILL DRLG P 9,740 ft, OBD 1.5 bpm at 3,395 psi, 9,740.0 10,090.0 08:06 12:36 BHP 4,031 psi,CWT 8.6k,WOB 1.4k, ROP 60 fpm,IA 223,OA 13 9/26/2015 9/26/2015 0.45 PROD1 DRILL WPRT P Wiper trip up hole to 9,590 ft,PUW 10,090.0 10,090.0 12:36 13:03 29k,RBIH 9/26/2015 9/26/2015 6.30 PROD1 DRILL DRLG P 10,090 ft, OBD 1.55 bpm at 3,608 psi, 10,090.0 10,440.0 13:03 19:21 BHP 4,031 psi,CWT 9.2k,WOB 1.7k, ROP 55 fph, IA 297,OA 16 9/26/2015 9/26/2015 0.80 PROD1 DRILL WPRT P Window to window,PUW=31K,RBIH. 10,440.0 10,440.0 19:21 20:09 9/26/2015 9/27/2015 3.85 PROD1 DRILL DRLG P Drill ahead: 1.51 BPM @ 3,775 PSI, 10,440.0 10,659.0 20:09 00:00 BHP=4,085 PSI,CTW=8K, WOB=2.2K,ROP=55.Ankerite stringer @ 10,582'.BHA wiper @ same depth. 9/27/2015 9/27/2015 7.75 PROD1 DRILL DRLG P Continue drilling:1.50 BPM©3,625 10,659.0 10,742.0 00:00 07:45 PSI,BHP=4,110 PSI,CTW=8.5K, WOB=1.8K,ROP=60.Found ankerite again @ 10,729',ROP=3,start doing hourly pick-ups to 10,742',PUW's 30k, no push,500'wiper,no joy,ribs off, same results,no WOB,no motor work,negative coil weight. 9/27/2015 9/27/2015 2.60 PROD1 DRILL TRIP P POOH for BHA swap,7k over pull at 10,742.0 69.3 07:45 10:21 9,329',jet/jog 5 1/2"BTP from TOWS to 9,225',continue OOH 9/27/2015 9/27/2015 1.65 PROD1 DRILL PULD P PJSM-Pressure undeploy BHA#4, 69.3 0.0 10:21 12:00 LD lower section,using low hour upper section for next BHA,Bit condition-2-1-BT-N-X-I-PN-BHA 9/27/2015 9/27/2015 0.50 PROD1 DRILL SVRG P Service injector and counter on 0.0 0.0 12:00 12:30 horsehead. 9/27/2015 9/27/2015 2.00 PROD1 DRILL PULD P PJSM-MU,Pressure deploy drilling 0.0 72.2 12:30 14:30 BHA#5,.6+°AKO motor and new HYC Bi-center bit,check floats and pack-offs,MU to Coiltrak,surface test. 9/27/2015 9/27/2015 1.70 PROD1 DRILL TRIP P RIH with BHA#5 72.2 8,845.0 14:30 16:12 9/27/2015 9/27/2015 0.20 PROD1 DRILL DLOG P Tie in to K1 for minus 4 ft correction 8,845.0 8,874.0 16:12 16:24 9/27/2015 9/27/2015 0.70 PROD1 DRILL TRIP P RIH,close EDC,PUW above window 8,874.0 10,742.0 16:24 17:06 29k,RIH,clean thru window and A5/6 interface at 9,329'. 9/27/2015 9/28/2015 6.90 PROD1 DRILL DRLG P Drill ahead: 1.52 BPM @ 3,590 PSI, 10,742.0 10,910.0 17:06 00:00 BHP=4140 PSI,CTW=7.5K, WOB=2.7K,ROP=5,Ankerite.Broke free from ankerite @ 10,765'.Found fault @ 10,827',start GEO drop to 78 degrees. 9/28/2015 9/28/2015 4.40 PROD1 DRILL DRLG P Continue drilling ahead:1.55 BPM @ 10,910.0 11,090.0 00:00 04:24 3,440 PSI,BHP=4,140 PSI,CTW=7K, WOB=2.5K,ROP=45.Start pumping new mud system,new mud at bit 10,938'. Page 3/16 Report Printed: 11/12/2015 • • ' Operations Summary (with Timelog Depths) ConocoPhitlips • Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/28/2015 9/28/2015 0.85 PROD1 DRILL WPRT P Wiper trip,PUW=31K,RBIH. 11,090.0 11,090.0 04:24 05:15 9/28/2015 9/28/2015 4.60 PROD1 DRILL DRLG P 11,090 ft,OBD 1.5 bpm at 3,437 psi, 11,090.0 11,230.0 05:15 09:51 BHP 4,206 psi,CWT 6.2k,WOB 2.4k, ROP 40 fpm,heavy lateral vibration at 11,225',stacking weight,couple of BHA wipers,vibration and weight transfer issue,pump sweep 9/28/2015 9/28/2015 1.15 PROD1 DRILL WPRT P Wiper trip up hole 500 ft,PUW 35k, 11,230.0 11,230.0 09:51 11:00 RBIH,stack 7k at 11,088 ft,PUW 40k, a little motor work seen,RBIH reducing pump rate to.95 bpm, running 35 fpm,drilled TF at 75°,no problem through,clean consistent cuttings over shaker. 9/28/2015 9/28/2015 3.50 PROD1 DRILL DRLG P 11,230 ft,OBD 1.5 bpm at 3,418 psi, 11,230.0 11,262.0 11:00 14:30 BHP 4,180 psi,CWT 6.6k,WOB 2.9k, ROP 6-9 fpm,no vibration,losing slide at 11,262 ft. 9/28/2015 9/28/2015 0.45 PROD1 DRILL WPRT P Geo Wiper trip up hole 500 ft,PUW 11,262.0 11,262.0 14:30 14:57 31k,RBIH,no problem through 11,088 ft,.9 bpm,4 fpm,TF 75°. 9/28/2015 9/28/2015 0.85 PROD1 DRILL DRLG P 11,262 ft,OBD 1.5 bpm at 3,400 psi, 11,262.0 11,266.0 14:57 15:48 BHP 4,192 psi,CWT Ok,WOB 2.9k, ROP 3-6 fpm, 9/28/2015 9/28/2015 0.50 PROD1 DRILL DRLG T 11,262 ft, Pull 48k off bottom,coil 11,266.0 11,266.0 15:48 16:18 stuck above BHA,PU to 55k 2 times, coil to neutral,pumps down let relax 5 minutes,pull 55k,no joy,coil back to neutral,let relax 15 minutes pumps down,BHP 3,980 psi,pull 65k coil free on 3rd attempt. 9/28/2015 9/28/2015 2.50 PROD1 DRILL WPRT P Wiper trip to window,pump 5x5,PUW 11,266.0 11,266.0 16:18 18:48 33k,jet 5 1/5"BTP,RBIH.tie-in RA • tag @+7'correction.Tight spot @ 11,256',continue in hole. 9/28/2015 9/29/2015 5.20 PROD1 DRILL DRLG P Drill ahead:1.51 BPM @ 3,380 PSI, 11,266.0 11,320.0 18:48 00:00 BHP=4,210 PSI,CTW=5K, WOB=2.8K,ROP=7.Broke free temporarily,more ankerite @ 11,287', several mini wiper trips to gets going. In&out of ankerite. 9/29/2015 9/29/2015 1.40 PROD1 DRILL DRLG P Drill ahead:1.51 BPM @ 3,380 PSI, 11,320.0 11,326.0 00:00 01:24 BHP=4,150 PSI,CTW=5K, WOB=2.8K,ROP=7.Still drilling ankerite.Several short wipers. 9/29/2015 9/29/2015 0.50 PROD1 DRILL DRLG T 11,326 ft, Pull 42k off bottom,coil 11,326.0 11,326.0 01:24 01:54 stuck above BHA,PU to 47k 2 times, coil to neutral,pumps down let relax 15 mins,pulled 52K,pulled free.Pull 200'wiper. 9/29/2015 9/29/2015 4.15 PROD1 DRILL DRLG P Drill ahead: 1.51 BPM @ 3,380 PSI, 11,326.0 11,341.0 01:54 06:03 BHP=4,150 PSI,CTW=4K, WOB=2.8K,ROP=7.Still drilling ankerite.Several short wipers.PUW's 34,40,42 and 34k Continue drilling 1.60 BPM CTW=4.5K,WOB=2.8K, ROP=4. Page 4/16 Report Printed: 11/12/2015 0 • Operations Summary (with Timelog Depths) ,. 1G-05 ConocoPhiilips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/29/2015 9/29/2015 1.75 PROD1 DRILL DRLG P 11,341 ft, Losing push, PUW 52k, 11,341.0 11,358.0 06:03 07:48 RBIH,continue drilling ahead 1.4 bpm at 3,302 psi,BHP 4,184 psi,CWT 4k, WOB 2.8k,ROP 5,PUW's 35 and 42k,broke out of anchorite at 11,344 ft,to 11,358 ft. 9/29/2015 9/29/2015 0.50 PROD1 DRILL DRLG T 11,358 ft, Pull 45k off bottom,coil 11,358.0 11,358.0 07:48 08:18 stuck above BHA,PU to 50k,coil to neutral,pumps down let relax 20 mins, BHP 4,000 psi,pulled 65K to free.Pull wiper. 9/29/2015 9/29/2015 1.40 PROD1 DRILL WPRT T Wiper trip up hole to 10,000 ft,PUW 11,358.0 11,358.0 08:18 09:42 33k,pull 2-3k heavy at 11,075 and 11,010 ft,RBIH,bobbles at 10,610, 10656 and 11,075 ft,unable to get to bottom 1.4 bpm at 4205 psi,PUW 33k,RBIH 1.5 bpm,no surface weight, WOB or differential,pressure spike annular,suspect packing off. 9/29/2015 9/29/2015 1.35 PROD1 DRILL WPRT T POOH,wiper for bottoms up,PUW 11,358.0 9,329.0 09:42 11:03 34k,pull 50k at 11,025 ft,go back down,PUW 35-39k to 10,920 ft,wiper to window per town. 9/29/2015 9/29/2015 0.15 PROD1 DRILL WPRT T 9,329 ft,pull 40k,RBIH reduce rate, 9,329.0 9,225.0 11:03 11:12 cycle pipe to 40k to free coil,PUH into 5 1/2"BTP. 9/29/2015 9/29/2015 0.60 PROD1 DRILL WPRT T Jet/Jog 5 1/2"BTP while waiting on 9,225.0 9,225.0 11:12 11:48 orders from town 9/29/2015 9/29/2015 1.90 PROD1 DRILL WPRT T Wiper trip up hole to 7,200 ft, RBIH,tie 9,225.0 11,358.0 11:48 13:42 to RA for plus 4.5 ft correction. slacked off 2k at 10,610 ft and 6k at 11,025 ft 9/29/2015 9/29/2015 4.10 PROD1 DRILL DRLG P 11,358 ft, OBD 1.5 bpm at 3,456 psi, 11,358.0 11,559.0 13:42 17:48 BHP 4,205 psi,CWT 6.9k,WOB 2.5k, ROP 60,IA 363,OA 20 9/29/2015 9/29/2015 0.25 PROD1 DRILL WPRT P 11559 ft,Wiper up hole,PUW 32k 11,559.0 11,200.0 17:48 18:03 9/29/2015 9/29/2015 0.25 PROD1 DRILL WPRT P 11200 ft,Wiper in hole, RIW 9k 11,200.0 11,559.0 18:03 18:18 9/29/2015 9/29/2015 5.00 PROD1 DRILL DRLG P 11559 ft,BOBD 1.5 bpm at 3596 psi, 11,559.0 11,731.0 18:18 23:18 BHP 4258,WHP 80,IA 413,OA 25 9/29/2015 9/29/2015 0.60 PROD1 DRILL WPRT P 11731 ft,losing surface weight,work 11,731.0 11,200.0 23:18 23:54 pipe,unable to maintain WOB,pump 5x5 sweep,wiper up hole to 11200 ft, Annular pressure spike 11259 ft- 11241 ft, 9/29/2015 9/30/2015 0.10 PROD1 DRILL WPRT P 11200 ft,Wiper back in hole,RIW 8.5 11,200.0 11,340.0 23:54 00:00 k 9/30/2015 9/30/2015 0.50 PROD1 DRILL WPRT P 11340 ft,Continue wiper in hole,8.5 k 11,340.0 11,731.0 00:00 00:30 9/30/2015 9/30/2015 10.45 PROD1 DRILL DRLG P 11731 ft,BOBD 1.42 at 3385 psi, 11,731.0 11,930.0 00:30 10:57 CTW 6 k,BHP 4240,WHP 124,IA 412,OA 25,0.10 losses at 11734 ft 9/30/2015 9/30/2015 1.50 PROD1 DRILL WPRT P Wiper to window,PUW 31k,Pulled 11,930.0 9,265.0 10:57 12:27 42k at 11052',tight from 11053'- 11030',At 9330'pulled 36k,RBIH,on third attempt was able to PUH into 5 1/2"BTP. 9/30/2015 9/30/2015 0.75 PROD1 DRILL CIRC P Jet/Jog 5 1/2"BTP and 500'of 3 1/2" 9,265.0 8,700.0 12:27 13:12 TBG Page 5/16 Report Printed: 11/12/2015 • 0 Operations Summary (with Timelog Depths) 1G-05 CortocoPhitlips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/30/2015 9/30/2015 0.25 PROD1 DRILL WPRT P Wipe in hole,set down 7k at the BOW 8,700.0 9,290.0 13:12 13:27 9/30/2015 9/30/2015 0.20 PROD1 DRILL DLOG P Tie into RA marker for a plus 3.5 ft 9,290.0 9,321.5 13:27 13:39 correction 9/30/2015 9/30/2015 1.35 PROD1 DRILL WPRT P Wipe in hole,RIW 6k,Set down 6k at 9,321.5 11,930.0 13:39 15:00 11741',PUW 38k,reduce rate to 0.5 bpm and oriented to 90L was able to get coil past tight spot from 11741'to 11764' 9/30/2015 9/30/2015 1.75 PROD1 DRILL DRLG P 11930 ft,BOBD 1.48 bpm at 3278 psi, 11,930.0 11,986.0 15:00 16:45 BHP 4280,WHP 147, IA 393,OA 25, CTW 5k 9/30/2015 9/30/2015 0.25 PROD1 DRILL WPRT P 11986 ft,Wiper up hole to 11800 ft, 11,986.0 11,986.0 16:45 17:00 PUW 31 k 9/30/2015 9/30/2015 3.00 PROD1 DRILL DRLG P 11986 ft,BOBD 1.5 bpm at 3403 psi, 11,986.0 11,996.0 17:00 20:00 BHP 4285,WHP 90, IA 460,OA 25, 9/30/2015 9/30/2015 0.50 PROD1 DRILL WPRT P 11996 ft,Wiper up hole to 11683 ft, 11,996.0 11,996.0 20:00 20:30 pump 26 bbls new mud pill to assist in drilling ahead,RBIH 9/30/2015 10/1/2015 3.50 PROD1 DRILL DRLG P 11996 ft,BOBD 1.5 bpm at 3527 psi, 11,996.0 12,084.0 20:30 00:00 BHP 4317,WHP 92,IA 462,OA 24 10/1/2015 10/1/2015 1.00 PROD1 DRILL DRLG P 12084 ft,OBD 1.5 bpm at 3527 psi, 12,084.0 12,130.0 00:00 01:00 BHP 4296,WHP 95,IA 462,OA 24 10/1/2015 10/1/2015 0.50 PROD1 DRILL WPRT P 12130 ft,Wiper up hole to 11250 ft, 12,130.0 11,250.0 01:00 01:30 PUW 35 k 10/1/2015 10/1/2015 0.50 PROD1 DRILL WPRT P 11250 ft,wiper back in hole RIW 8 k 11,250.0 12,130.0 01:30 02:00 ""Note:Had to steer back in hole from 12069 ft to 12100 ft. 10/1/2015 10/1/2015 8.25 PROD1 DRILL DRLG P 12130 ft,BOBD 1.5 bpm at 3530 psi, 12,130.0 12,330.0 02:00 10:15 BHP 4349,WHP 58,IA 459,OA 24 10/1/2015 10/1/2015 0.50 PROD1 DRILL WPRT P 12330 ft,Wipe up hole,PUW 33k 12,330.0 11,250.0 10:15 10:45 10/1/2015 10/1/2015 0.50 PROD1 DRILL WPRT P 11250 ft,Wipe in hole,RIW 8k 11,250.0 12,330.0 10:45 11:15 10/1/2015 10/1/2015 5.50 PROD1 DRILL DRLG P 12330 ft,BOBD 1.53 bpm at 3557 psi, 12,330.0 12,427.0 11:15 16:45 BHP 4330,WHP 390,IA 464,OA 25 10/1/2015 10/1/2015 2.75 PROD1 DRILL DRLG P 12427 ft,OBD 1.6 bpm at 3600 psi, 12,427.0 12,530.0 16:45 19:30 BHP 4367,WHP 300,IA 472,OA 21 10/1/2015 10/1/2015 1.50 PROD1 DRILL WPRT P 12530 ft,TD L1 lateral,pump 10x10 12,530.0 9,268.0 19:30 21:00 sweep,Wiper up hole,PUW 33k working pipe through 11025 ft and 9320 ft. 10/1/2015 10/1/2015 0.50 PROD1 DRILL WPRT P 9268 ft,Jet the BTP 9,268.0 9,220.0 21:00 21:30 10/1/2015 10/1/2015 2.00 PROD1 DRILL WPRT P Continue wiper to the swab valves. 9,220.0 750.0 21:30 23:30 10/1/2015 10/1/2015 0.25 PROD1 DRILL WPRT P 750 ft,choke plugging off,RBIH to 750.0 72.1 23:30 23:45 1000 ft,continue POOH 10/1/2015 10/2/2015 0.25 PROD1 DRILL TRIP P Reset depth,blow down choke,RBIH 72.1 1,083.0 23:45 00:00 10/2/2015 10/2/2015 1.50 PROD1 DRILL TRIP P 1083 ft,continue tripping in hole,RIW 1,083.0 8,845.0 00:00 01:30 13k 10/2/2015 10/2/2015 0.25 PROD1 DRILL DLOG P 8845 ft,tie into the K1 marker 8,845.0 8,875.0 01:30 01:45 correction of minus 3.0 ft 10/2/2015 10/2/2015 1.75 PROD1 DRILL TRIP P Continue RIH through window 8,875.0 12,534.0 01:45 03:30 Page 6/16 Report Printed: 11/12/2015 Operations Summary (with Timelog Depths) 1G-05 ConocoPhitlips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/2/2015 10/2/2015 1.25 PROD1 DRILL CIRC P 12534 ft,Confirmed TD,pump 5x5 12,534.0 12,534.0 03:30 04:45 sweep, 10/2/2015 10/2/2015 3.25 PROD1 DRILL DISP P 12534 ft,POOH laying in 11.8 ppg 12,534.0 72.2 04:45 08:00 beaded liner running completion fluid. Paint EOP flags at 10,300'and 7,000' 10/2/2015 10/2/2015 1.50 PROD1 DRILL PULD P At surface,30 minute flow check, 72.2 0.0 08:00 09:30 Inspect coil,flat spot at 0.133 14'up, PJSM,LD BHA#5 **Note:Bit Grade 4-3-BT-A-X-I-BU-TD 10/2/2015 10/2/2015 0.25 PROD1 DRILL BOPE P Function test BOP 0.0 0.0 09:30 09:45 10/2/2015 10/2/2015 0.25 COMPZ1 CASING PUTB P Prep rig floor to run liner,PJSM to P/U 0.0 0.0 09:45 10:00 liner 10/2/2015 10/2/2015 3.00 COMPZ1 CASING PUTB P P/U non-ported bull nose,58 joints of 0.0 1,787.3 10:00 13:00 2 3/8"slotted liner,shorty deployment sleeve 10/2/2015 10/2/2015 1.50 COMPZ1 CASING PULD P PJSM,R/D floor from liner running, 1,787.3 1,831.5 13:00 14:30 P/U Coil Trak BHA#6,change out floats in UQC,M/U,and surface test 10/2/2015 10/2/2015 1.65 COMPZ1 CASING RUNL P RIH with L1 lower liner section 1,831.5 8,840.2 14:30 16:09 10/2/2015 10/2/2015 0.10 COMPZI CASING DLOG P Correct at EOP flag,minus 8.68 ft 8,840.2 8,831.5 16:09 16:15 correction,PUW 33.5k 10/2/2015 10/2/2015 1.65 COMPZ1 CASING RUNL P RIH with L1 lower liner section,Sat 8,831.5 12,534.0 16:15 17:54 down 4k at 11,071 ft,shorty at 9,284 ft bottom of window,PU 42k,broke over,RBIH faster and fell through slowly to 11,170 ft,continue RIH with lower L1 liner section. 10/2/2015 10/2/2015 1.00 COMPZ1 CASING TRIP P Reset depth removing liner 10729 ft, 12,534.0 8,825.0 17:54 18:54 liner up pumping across the top,PUH for tie in 10/2/2015 10/2/2015 0.25 COMPZ1 CASING DLOG P 8825 ft,Tie into the RA marker 8,825.0 8,849.5 18:54 19:09 correction of plus 5.0 ft. 10/2/2015 10/2/2015 1.85 COMPZ1 CASING TRIP P 8849.5 ft,POOH,pumping across the 8,849.5 44.2 19:09 21:00 top.Painting EOP flag at 7700 ft 10/2/2015 10/2/2015 0.50 COMPZ1 CASING OWFF P At surface,perform no flow check, 44.2 44.2 21:00 21:30 inspect injector chains,PJSM for LD down setting tools. 10/2/2015 10/2/2015 0.25 COMPZI CASING PULD P LD L1 liner setting tools,BHA#6 44.2 0.0 21:30 21:45 10/2/2015 10/2/2015 0.50 COMPZI CASING PUTB P Prep rig floor and PJSM for running 0.0 0.0 21:45 22:15 upper section of liner, 10/2/2015 10/3/2015 1.75 COMPZ1 CASING PUTB P MU L1 liner assembly with 47 jts of 0.0 1,176.1 22:15 00:00 slotted liner. 10/3/2015 10/3/2015 0.50 COMPZ1 CASING PUTB P Continue MU upper liner section 1,176.1 1,459.2 00:00 00:30 w/slotted liner. 10/3/2015 10/3/2015 0.75 COMPZ1 CASING PUTB P PJSM,MU coiltrak tools,inspect 1,459.2 1,515.2 00:30 01:15 checks in upper quick,swapped out checks 10/3/2015 10/3/2015 2.50 COMPZ1 CASING RUNL P Zero depth,RIH w/L1 upper liner 1,515.2 9,221.0 01:15 03:45 section 47 jts of slotted liner,shorty deployment sleeve,and ported bull nose. 10/3/2015 10/3/2015 0.25 COMPZ1 CASING DLOG P Correct to EOP at 7700 ft,minus 6.0 9,221.0 9,221.0 03:45 04:00 ft. Page 7/16 Report Printed: 11/12/2015 • • Operations Summary (with Timelog Depths) 1 G-05 ConocoPhiilips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/3/2015 10/3/2015 0.50 COMPZ1 CASING TRIP P 9221 ft,Continue RIH 9,221.0 10,746.8 04:00 04:30 10/3/2015 10/3/2015 0.25 COMPZ1 CASING TRIP P Tag top of Liner at 10746.7 ft,TOL 10,746.8 10,746.8 04:30 04:45 9275.8 ft 10/3/2015 10/3/2015 1.50 COMPZ1 CASING TRIP P Remove liner from BHA,POOH 10,746.8 44.2 04:45 06:15 10/3/2015 10/3/2015 0.50 COMPZ1 CASING OWFF P At surface,perform a no flow check, 44.2 44.2 06:15 06:45 PJSM for LD setting tools 10/3/2015 10/3/2015 0.50 COMPZ1 CASING PULD P LD L1 liner setting tools 44.2 0.0 06:45 07:15 10/3/2015 10/3/2015 1.00 PROD2 RPEQPT PULD P PU Whipstock setting BHA#8,MU 0.0 75.5 07:15 08:15 coiltrak tools,stab on,and surface test MWD 10/3/2015 10/3/2015 2.20 PROD2 RPEQPT TRIP P Reset counters, RIH with Gen II 3 1/2" 75.5 8,850.0 08:15 10:27 X 5 1/2"whipstock,EDC open 10/3/2015 10/3/2015 0.30 PROD2 RPEQPT DLOG P Tie into K1 marker for-4.5 ft. 8,850.0 8,881.4 10:27 10:45 correction 10/3/2015 10/3/2015 0.25 PROD2 RPEQPT TRIP P Continue RIH with Gen II 3 1/2"X 5 8,881.4 9,263.0 10:45 11:00 1/2"whipstock, EDC closed,PUW 32.5k 10/3/2015 10/3/2015 0.25 PROD2 RPEQPT WPST P On depth,orient to 30°ROHS,release 9,263.0 9,263.0 11:00 11:15 from whipstock at 3,200 psi,stack 4k, TOWS at 9,250 ft. 10/3/2015 10/3/2015 1.75 PROD2 RPEQPT TRIP P POOH 9,263.0 62.6 11:15 13:00 10/3/2015 10/3/2015 0.50 PROD2 RPEQPT OWFF P At surface,perform a no flow check, 62.6 62.6 13:00 13:30 PJSM for LD setting tools 10/3/2015 10/3/2015 0.50 PROD2 RPEQPT PULD P LD whipstock setting tools 62.6 0.0 13:30 14:00 10/3/2015 10/3/2015 1.00 PROD2 WHDBOP RURD P Remove checks,valve crew grease 0.0 0.0 14:00 15:00 and function tree valves,install swizzle stick and stab INJH onto well, displace coil to water and jet BOP stack. 10/3/2015 10/3/2015 0.75 PROD2 WHDBOP BOPE P Test inner reel iron,stripper,and 0.0 0.0 15:00 15:45 alarm system 10/3/2015 10/3/2015 6.25 PROD2 WHDBOP BOPE P PJSM-BOPE testing,BOPE test 0.0 0.0 15:45 22:00 250/3500 psi,Annular 250/2500 psi **Note: Test witnessed by Chuck Scheve ****Note:7 hr BOPE test time 10/3/2015 10/3/2015 1.00 PROD2 DRILL DISP P MU nozzle,stab on injecter head and 0.0 0.0 22:00 23:00 displace coil to completion fluid, installed BHI checks in upper quick, tested e-line,replaced flow sub 10/3/2015 10/4/2015 1.00 PROD2 WHPST PULD P PJSM,MU Milling BHA,BHA#8 0.0 23:00 00:00 10/4/2015 10/4/2015 0.70 PROD2 WHPST PULD P Continue PU/MU window milling BHA# 0.0 74.3 00:00 00:42 9 10/4/2015 10/4/2015 1.50 PROD2 WHPST TRIP P RIH,BHA#9 w/0.6 ako motor,string 74.3 8,850.0 00:42 02:12 reamer,and window mill 10/4/2015 10/4/2015 0.25 PROD2 WHPST DLOG P 8850 ft,tie into the K1 marker 8,850.0 8,850.0 02:12 02:27 correction of minus 5.0 ft. 10/4/2015 10/4/2015 0.25 PROD2 WHPST TRIP P Continue RIH to 9200 ft 8,850.0 9,200.0 02:27 02:42 10/4/2015 10/4/2015 1.80 PROD2 WHPST DISP P 9200 ft,displace well to 8.9 ppg 9,200.0 9,254.0 02:42 04:30 FloPro Page 8/16 Report Printed: 11/12/2015 • • .._ Operations Summary (with Timelog Depths) r it t.. . 1 G-05 ConocoPhillips f Al.rk.3 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/4/2015 10/4/2015 8.85 PROD2 WHPST WPST P 9,254 ft, Tagged pinch point 9254 ft, 9,254.0 9,261.3 04:30 13:21 PU,bring on pump,begin milling window 30°ROHS per recomended practice,1.5 bpm at 3,390 psi,BHP 3.979 psi,IA 189,OA 5,bottom of window 9,260.4 ft. 10/4/2015 10/4/2015 2.10 PROD2 WHPST WPST P 9,262 ft,drill rat hole 1.5 bpm at 3,440 9,261.3 9,275.0 13:21 15:27 psi,BHP 3,981 psi,CWT 10.1k,WOB 2.9k,IA 277,OA 13 10/4/2015 10/4/2015 3.00 PROD2 WHPST REAM P 9,275 ft, Rathole TD,PUW 31k,back 9,275.0 9,275.0 15:27 18:27 ream window HS,30°R and 60°R 10/4/2015 10/4/2015 0.25 PROD2 WHPST REAM P 9275 ft,Dry drift window area clean 9,275.0 9,275.0 18:27 18:42 10/4/2015 10/4/2015 1.65 PROD2 WHPST TRIP P '9275 ft,POOH 9,275.0 74.3 18:42 20:21 10/4/2015 10/4/2015 0.25 PROD2 WHPST SFTY P At surface,PJSM for undeploying 74.3 74.3 20:21 20:36 milling BHA. 10/4/2015 10/4/2015 1.75 PROD2 WHPST PULD P Start undeploying milling BHA#9 74.3 0.0 20:36 22:21 10/4/2015 10/4/2015 1.00 PROD2 DRILL PULD P PJSM,Deploy Build BHA#10 0.0 72.2 22:21 23:21 10/4/2015 10/5/2015 0.65 PROD2 DRILL TRIP P RIH build BHA#10 w/2.2°ako motor 72.2 1,913.0 23:21 00:00 10/5/2015 10/5/2015 1.20 PROD2 DRILL TRIP P 1913 ft,continue RIH with the build 1,913.0 8,850.0 00:00 01:12 BHA 10/5/2015 10/5/2015 0.25 PROD2 DRILL DLOG P 8850 ft,tie into the K1 marker 8,850.0 8,865.0 01:12 01:27 correction of minus 4.0 ft. 10/5/2015 10/5/2015 0.25 PROD2 DRILL TRIP P Continue RIH 8,865.0 9,275.0 01:27 01:42 10/5/2015 10/5/2015 1.25 PROD2 DRILL DRLG P 9275 ft,OBD 1.6 bpm at 3700 psi, 9,275.0 9,346.0 01:42 02:57 BHP 3935,WHP 100, IA 256,OA 16 10/5/2015 10/5/2015 0.25 PROD2 DRILL WPRT P 9346 ft,PUH for confirming WS 9,346.0 8,850.0 02:57 03:12 depths.PUW 30k 10/5/2015 10/5/2015 0.25 PROD2 DRILL DLOG P 8850 ft,Tie into the K1 marker plus 8,850.0 8,868.0 03:12 03:27 1.0 ft, 10/5/2015 10/5/2015 0.25 PROD2 DRILL TRIP P 8868 ft,RIH 8,868.0 9,270.0 03:27 03:42 10/5/2015 10/5/2015 0.25 PROD2 DRILL DLOG P 9270 ft,Log RA for window depths. 9,270.0 9,346.0 03:42 03:57 ****Note:TOW 9255 ft RA 9257.5 ft BOW 9261 ft 10/5/2015 10/5/2015 9.40 PROD2 DRILL DRLG P 9346 ft,BOBD 1.6 bpm at 3700 psi, 9,346.0 9,630.0 03:57 13:21 BHP 3893,WHP 85,IA 261,OA 16, pump sweeps. 10/5/2015 10/5/2015 2.65 PROD2 DRILL TRIP P 9,630 ft,TD L1-01 build,PUW 31k, 9,630.0 72.2 13:21 16:00 POOH for lateral drilling assembly. 10/5/2015 10/5/2015 1.75.PROD2 DRILL PULD P PJSM,Pressure un-deploy build BHA 72.2 0.0 16:00 17:45 #10 **Note: Bit grade 2-2-bt-a-x-i-bu-bha 10/5/2015 10/5/2015 2.00 PROD2 DRILL PULD P PJSM,Pressure deploy L1-01 lateral 0.0 72.2 17:45 19:45 drilling BHA#11 10/5/2015 10/5/2015 1.75 PROD2 DRILL TRIP P RIH,with L1-01 lateral BHA,0.6+ 72.2 8,850.0 19:45 21:30 motor bend 10/5/2015 10/5/2015 0.25 PROD2 DRILL DLOG P 8850 ft,tie into the K1 marker 8,850.0 8,877.1 21:30 21:45 correction of minus 4.0 ft. Page 9/16 Report Printed: 11/12/2015 '° Operations Summary (with Timelog Depths) r y : 1G-05 ConocoPhillips , Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/5/2015 10/5/2015 0.75 PROD2 DRILL TRIP P 8877 ft,Continue RIH 8,877.1 9,630.0 21:45 22:30 10/5/2015 10/6/2015 1.50 PROD2 DRILL DRLG P 9630 ft,BOBD 1.6 bpm at 3630 psi, 9,630.0 9,648.0 22:30 00:00 BHP 3971,WHP 211, IA 258,OA 16 10/6/2015 10/6/2015 5.65 PROD2 DRILL DRLG P 9648 ft,OBD 1.6 bpm at 3800 psi, 9,648.0 9,980.0 00:00 05:39 BHP 4001,WHP 209,IA 276,OA 15 10/6/2015 10/6/2015 0.55 PROD2 DRILL WPRT P Wiper trip to 9,500 ft.,PUW 29k,RBIH 9,980.0 9,980.0 05:39 06:12 10/6/2015 10/6/2015 4.00 PROD2 DRILL DRLG P 9,980 ft,OBD 1.6 bpm at 3900 psi, 9,980.0 10,330.0 06:12 10:12 BHP 4019,WHP 123,IA 351,OA 19 10/6/2015 10/6/2015 0.35 PROD2 DRILL WPRT P 10330 ft,Wiper up hole,PUW 30k 10,330.0 9,630.0 10:12 10:33 10/6/2015 10/6/2015 0.30 PROD2 DRILL WPRT P 9630 ft,Wipe in hole,RIW 11k 9,630.0 10,330.0 10:33 10:51 10/6/2015 10/6/2015 4.65 PROD2 DRILL DRLG P 10330 ft,BOBD 1.58 bpm at 3800 psi, 10,330.0 10,640.0 10:51 15:30 BHP 4009,WHP 85, IA 388,OA 20 10/6/2015 10/6/2015 1.00 PROD2 DRILL WPRT P 10640 ft,Wiper up hole,PUW 29k, 10,640.0 9,245.0 15:30 16:30 pump 5x5 sweep 10/6/2015 10/6/2015 0.25 PROD2 DRILL CIRC P 9245 ft,Jet big tailpipe 9,245.0 9,245.0 16:30 16:45 10/6/2015 10/6/2015 0.10 PROD2 DRILL WPRT P 9245 ft,Wiper in hole 9,245.0 9,280.0 16:45 16:51 10/6/2015 10/6/2015 0.10 PROD2 DRILL DLOG P 9280 ft,Tie into RA marker fora+2.0 9,280.0 9,295.0 16:51 16:57 ft.correction 10/6/2015 10/6/2015 0.55 PROD2 DRILL WPRT P 9295 ft,Continue wiper in hole, RIW 9,295.0 10,640.0 16:57 17:30 11.5k 10/6/2015 10/6/2015 4.00 PROD2 DRILL DRLG P 10640 ft,BOBD 1.60 bpm at 3930 psi, 10,640.0 10,890.0 17:30 21:30 BHP 4045,WHP 55, IA 403,OA 21 10/6/2015 10/6/2015 1.00 PROD2 DRILL WPRT P 10890 ft,wiper up hole,slowing down 10,890.0 9,650.0 21:30 22:30 to 10 fpm through tight spot. PUW 30k **""Note: 10281 ft-10371 ft Packing off,over pulls 1 -4k DHWOB 10/6/2015 10/6/2015 0.50 PROD2 DRILL WPRT P 9650ft,wiper back in hole,RIW 11k 9,650.0 10,890.0 22:30 23:00 """"Note: 10400 ft stacking weight 2.5 k DHWOB,6 k CSW 10/6/2015 10/7/2015 1.00 PROD2 DRILL DRLG P 10890 ft,BOBD 1.6 bpm at 3800 psi, 10,890.0 10,940.0 23:00 00:00 BHP 4150,WHP 70,I A 417,OA 29 """"Note:New mud at the bit 10890 ft. 10/7/2015 10/7/2015 4.50 PROD2 DRILL DRLG P 10940 ft,OBD 1.57 bpm at 3726 psi, 10,940.0 11,140.0 00:00 04:30 BHP 3993,WHP 279,IA 413,OA 19 10/7/2015 10/7/2015 0.50 PROD2 DRILL WPRT P 11140 ft,wiper up hole PUW 30k 11,140.0 10,400.0 04:30 05:00 10/7/2015 10/7/2015 0.50 PROD2 DRILL WPRT P 10400 ft,wiper back in hole, RIW 9.7k 10,400.0 11,140.0 05:00 05:30 10/7/2015 10/7/2015 4.25 PROD2 DRILL DRLG P 11140 ft,BOBD 1.59 bmp at 3844 psi, 11,140.0 11,292.0 05:30 09:45 BHP 4050,WHP 183,IA 455,OA 23 10/7/2015 10/7/2015 1.75 PROD2 DRILL DRLG P 11292 ft,OBD 1.30 bpm at 3243 psi, 11,292.0 11,360.0 09:45 11:30 BHP 4095,WHP 307, IA 440,OA 24 Page 10/16 Report Printed: 11/12/2015 ,, ,,,--,--,:y.„._ • Operations Summary (with Timelog Depths) xsF 1G-05 +ConocoPhillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/7/2015 10/7/2015 0.75 PROD2 DRILL WPRT P 11360 ft,Wiper up hole,PUW 31k, 11,360.0 9,245.0 11:30 12:15 pump 5x5 sweep **Note: Tight hole 10,281'to 10,370', packing off,overpull 1-8k DHWOB 10/7/2015 10/7/2015 0.50 PROD2 DRILL CIRC P 9245 ft,Jet big tailpipe 9,245.0 9,245.0 12:15 12:45 10/7/2015 10/7/2015 3.25 PROD2 DRILL CIRC T Repair 3 rubber gaskets on#1 mud 9,245.0 8,900.0 12:45 16:00 pump suction manifold 10/7/2015 10/7/2015 0.35 PROD2 DRILL WPRT P 8900 ft,Wiper in hole 8,900.0 9,280.0 16:00 16:21 10/7/2015 10/7/2015 0.15 PROD2 DRILL DLOG P Tie into RA marker for a+2.5 ft 9,280.0 9,297.0 16:21 16:30 correction 10/7/2015 10/7/2015 1.00 PROD2 DRILL WPRT P 9297 ft,Wiper in hole,RIW 9k 9,297.0 11,360.0 16:30 17:30 **Note: 10,374'and 10705'stacking wt.4k DHWOB 10/7/2015 10/7/2015 1.50 PROD2 DRILL DRLG P 11360 ft,BOBD 1.48 bpm at 3727 psi, 11,360.0 11,394.0 17:30 19:00 BHP 4094,WHP 226,IA 371,OA 22 10/7/2015 10/7/2015 0.25 PROD2 DRILL WPRT P 11394 ft,trouble with weight transfer, 11,394.0 11,394.0 19:00 19:15 pump 5x5 sweep,BHA wiper 10/7/2015 10/8/2015 4.75 PROD2 DRILL DRLG P 11394 ft,BOBD 1.0 bpm at 2786 psi, 11,394.0 11,451.0 19:15 00:00 48 fph, 11435 ft encountered ankerite, 10/8/2015 10/8/2015 0.75 PROD2 DRILL DRLG P 11451 ft,OBD 1.1 bpm at 2800 psi, 11,451.0 11,454.0 00:00 00:45 BHP 3937,WHP 225,IA 371,OA 22 10/8/2015 10/8/2015 1.25 PROD2 DRILL WPRT P 11454 ft,TD L1-01 lateral,pump 11,454.0 10,500.0 00:45 02:00 10x10 sweep,clean hole from 10500 ft to 11454 ft, 10/8/2015 10/8/2015 1.25 PROD2 DRILL WPRT P 10500 ft,PUH and work thru trouble 10,500.0 10,200.0 02:00 03:15 spots 10367, 10344, 10303,and 10313 ft pulled 44k,continued pulling up to 10200 ft,RBIH,having to lower pump rate and speed to 15 fph to pass thru down to 10520 ft,Pulled up hole at 1.5 bpm at 25 fpm,pulled 49 k at 10305 ft,pumped another 5x5 sweep, 10/8/2015 10/8/2015 0.50 PROD2 DRILL WPRT P 10200 ft,Continued pulling up to 9400 10,200.0 9,199.0 03:15 03:45 ft,jogged back in hole to 9500 ft,PUH to 9199 ft,opened the EDC,continued performing swab wiper 10/8/2015 10/8/2015 2.00 PROD2 DRILL WPRT P 9199 ft,continued swab wiper, 9,199.0 72.2 03:45 05:45 pumping 1.62 bpm at 3500 psi,tag up, reset counters 10/8/2015 10/8/2015 1.75 PROD2 DRILL WPRT P 72.21 ft,RIH to confirm TD 72.2 8,850.0 05:45 07:30 10/8/2015 10/8/2015 0.25 PROD2 DRILL DLOG P 8850 ft,Tie into K1 marker for a-3.0 ft 8,850.0 8,871.0 07:30 07:45 correction 10/8/2015 10/8/2015 1.25 PROD2 DRILL WPRT P 8871 ft,Continue RIH to confirm TD, 8,871.0 11,451.0 07:45 09:00 stacked 2-3k at 10149 ft, 11090 ft, PUH reduced pump rate and went through. **Note: Confirmed TD at 11,451 ft. 10/8/2015 10/8/2015 3.00 PROD2 DRILL DISP P 11451 ft,POOH laying in 11.8 ppg 11,451.0 72.2 09:00 12:00 beaded liner running completion fluid. Paint EOP flags at 7400 ft and 9600 ft. Page 11/16 Report Printed: 11/12/2015 • • Operations Summary (with Timelog Depths) 1G-05 ComocoPhiNaps Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/8/2015 10/8/2015 1.00 PROD2 DRILL PULD P At surface,30 minute flow check, 72.2 0.0 12:00 13:00 PJSM,LD BHA#11 **Note:Bit Grade 2-1-WT-N-X-I-PN- TD 10/8/2015 10/8/2015 0.75 COMPZ2 CASING PUTB -P Prep rig floor to run liner,PJSM to P/U 0.0 0.0 13:00 13:45 liner 10/8/2015 10/8/2015 3.50 COMPZ2 CASING PUTB P P/U non-ported bull nose,56 joints of 0.0 1,727.1 13:45 17:15 2 3/8"slotted liner,shorty deployment sleeve 10/8/2015 10/8/2015 1.25 COMPZ2 CASING PUTB P PJSM,R/D floor from liner running, 1,727.1 1,772.6 17:15 18:30 P/U Coil Trak BHA#12,change out floats in UQC,M/U,and surface test 10/8/2015 10/8/2015 3.00 COMPZ2 CASING RGRP T 0-ring failure on lower 2-3/8",bonnet, 1,772.6 1,772.6 18:30 21:30 PJSM,perform lock out and tag out, repair damaged o-ring,good,PIT hydraulic system. *"**Note:Spilled 5 gals into secondary containment. "*"*Note:Nabors 3.0 hrs downtime 10/8/2015 10/8/2015 2.00 COMPZ2 CASING RUNL P Function 2-3/8"rams,tag up and reset 1,772.6 9,180.7 21:30 23:30 depth,RIH with L1-01 liner completion with 56 jts. 10/8/2015 10/8/2015 0.25 COMPZ2 CASING RUNL P 9180.7 ft,correction at EOP flag 9,180.7 9,180.7 23:30 23:45 minus 8.2 ft.PUW 33.5 k 10/8/2015 10/9/2015 0.25 COMPZ2 CASING RUNL P 9180.7 ft,Run in hole thru window 9,180.7 9,869.0 23:45 00:00 10/9/2015 10/9/2015 0.85 COMPZ2 CASING RUNL P 9855 ft,continue RIH with L1-01 liner. 9,869.0 11,451.0 00:00 00:5110179 ft stacking,work pipe thru 11163 ft to 11200 ft,continue RIH 10/9/2015 10/9/2015 0.60 COMPZ2 CASING TRIP P Tag bottom,11451 ft,release from 11,451.0 8,820.0 00:51 01:27 liner,PUH,remove liner from counters, PUH for tie in 10/9/2015 10/9/2015 0.25 COMPZ2 CASING TRIP , P 8820 ft,tie into the K1 correction of 8,820.0 8,820.0 01:27 01:42 plus 4.0 ft. 10/9/2015 10/9/2015 1.50 COMPZ2 CASING TRIP P 8820 ft,POOH,pumping across the 8,820.0 45.0 01:42 03:12 top,starting a trip sheet. 10/9/2015 10/9/2015 0.50 COMPZ2 CASING OWFF P At surface,check well for flow,PJSM 45.0 45.0 03:12 03:42 for LD liner setting tools. 10/9/2015 10/9/2015 2.00 COMPZ2 CASING PULD P LD BHA#12,MU BHA#13,surface 45.0 83.7 03:42 05:42 test 10/9/2015 10/9/2015 1.80 COMPZ2 CASING TRIP P 83 ft,RIH with BHA#13,OH anchored 83.7 8,860.0 05:42 07:30 aluminum billet 10/9/2015 10/9/2015 0.25 COMPZ2 CASING DLOG P 8860 ft,Tie into K1 for a-3.5 ft 8,860.0 8,883.0 07:30 07:45 correction 10/9/2015 10/9/2015 0.50 COMPZ2 CASING TRIP P 8883 ft,Continue RIH with OH 8,883.0 9,720.5 07:45 08:15 anchored aluminum billet,PUW 32.5k, tagged at 9720.45 ft. 10/9/2015 10/9/2015 0.25 COMPZ2 CASING RUNL P 9720.45 ft,Orient to 150°LOHS,see 9,720.5 9,720.5 08:15 08:30 tool shift at 4100 psi,set down 2k, reset depth 10/9/2015 10/9/2015 1.75 COMPZ2 CASING TRIP P 9720 ft,POOH with setting tool 9,720.5 61.6 08:30 10:15 Page 12/16 Report Printed: 11/12/2015 • • '' Operations Summary (with Timelog Depths) 1G-05 ConocoPhiiti � _, Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/9/2015 10/9/2015 0.50 COMPZ2 CASING OWFF P At surface,conducted no flow check, 61.6 61.6 10:15 10:45 PJSM-LD BHA#13 10/9/2015 10/9/2015 0.75 COMPZ2 CASING PULD P LD BHA#13 61.6 0.0 10:45 11:30 10/9/2015 10/9/2015 2.00 PROD3 DRILL RGRP T Check/torque hydraulic actuator bolts 0.0 0.0 11:30 13:30 on stack to manufacture specifications **Note: Nabors 2 hrs.downtime 10/9/2015 10/9/2015 0.25 PROD3 DRILL BOPE P Fuction test BOP 0.0 0.0 13:30 13:45 10/9/2015 10/9/2015 1.25 PROD3 DRILL PULD P PJSM,P/U L1-02 lateral drilling BHA 0.0 72.2 13:45 15:00 #14.0.8°AKO,Hycalog duraforce bi- center bit,replace checks,stab on, surface test 10/9/2015 10/9/2015 1.50 PROD3 DRILL TRIP P RIH with L1-02 lateral drilling BHA 72.2 8,850.0 15:00 16:30 10/9/2015 10/9/2015 0.25 PROD3 DRILL DLOG P 8850 ft,Tie into K1 marker for a-4.0 ft 8,850.0 8,870.8 16:30 16:45 correction 10/9/2015 10/9/2015 0.25 PROD3 DRILL TRIP P 8870 ft,Continue RIH with L1-02 8,870.8 9,200.0 16:45 17:00 lateral drilling BHA 10/9/2015 10/9/2015 1.00 PROD3 DRILL DISP P 9200 ft,Diplace well to 8.9 ppg FloPro 9,200.0 9,200.0 17:00 18:00 10/9/2015 10/9/2015 0.25 PROD3 DRILL TRIP P RIH,dry tag TOB at 9699 ft. 9,200.0 9,699.0 18:00 18:15 10/9/2015 10/9/2015 1.00 PROD3 STK KOST P Kick off billet,time milling,1.41 bpm at 9,699.0 9,705.0 18:15 19:15 3630 ft, 10/9/2015 10/9/2015 0.50 PROD3 DRILL 'DRLG P Drilling ahead,79 fph, 1.44 bpm at 9,705.0 9,740.0 19:15 19:45 3760 psi,BHP 3997,WHP 111, IA 262,OA 10 10/9/2015 10/9/2015 0.25 PROD3 DRILL WPRT P 9740 ft,Wiper up hole,dry drift billet, 9,740.0 9,740.0 19:45 20:00 clean 10/9/2015 10/10/2015 4.00 PROD3 DRILL DRLG P 9740 ft,drilling ahead 1.41 bpm at 9,740.0 9,901.0 20:00 00:00 3655 psi,BHP 3920,WHP 80,IA 262, OA 10 10/10/2015 10/10/2015 4.50 PROD3 DRILL DRLG P 9901 ft,OBD, 1.43 bpm at 3760 psi, 9,901.0 9,972.0 00:00 04:30 BHP 3993,WHP 110,IA 264,OA 10 10/10/2015 10/10/2015 2.50 PROD3 DRILL DRLG P 9972 ft,OBD 1.43 at 3703 psi,BHP 9,972.0 10,010.0 04:30 07:00 3972,WHP 114, IA 289,OA 12 10/10/2015 10/10/2015 0.50 PROD3 DRILL WPRT P 10010 ft,Wiper up hole,PUW 31k 10,010.0 9,750.0 07:00 07:30 10/10/2015 10/10/2015 0.25 PROD3 DRILL WPRT P 9750 ft,Wiper in hole,RIW 12k 9,750.0 10,010.0 07:30 07:45 10/10/2015 10/10/2015 4.25 PROD3 DRILL DRLG P 10010 ft,BOBD 1.40 bpm at 3504 psi, 10,010.0 10,260.0 07:45 12:00 BHP 4000,WHP 109, IA 324,OA 16 **Note: New mud at the bit at 10,200 ft. 10/10/2015 10/10/2015 0.75 PROD3 DRILL WPRT P 10260 ft,Wiper up hole,PUW 31k, 10,260.0 9,230.0 12:00 12:45 Jog 5 1/2" 10/10/2015 10/10/2015 0.20 PROD3 DRILL WPRT P 9230 ft,Wiper in hole 9,230.0 9,250.0 12:45 12:57 10/10/2015 10/10/2015 0.20 PROD3 DRILL DLOG P Tie into RA marker for a+1.5 ft 9,250.0 9,294.9 12:57 13:09 correction 10/10/2015 10/10/2015 0.50 PROD3 DRILL WPRT P 9294 ft,Wiper in hole, RIW 12.5k 9,294.9 10,260.0 13:09 13:39 Page 13/16 Report Printed: 11/12/2015 • • a Operations Summary (with Timelog Depths) 1G-05 ConocoPhiilips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/10/2015 10/10/2015 8.50 PROD3 DRILL DRLG P 10260 ft,BOBD 1.48 bpm at 3490 psi, 10,260.0 10,359.0 13:39 22:09 BHP 3990,WHP 273,IA 322,OA 17 10/10/2015 10/10/2015 1.35 PROD3 DRILL WPRT P 10359 ft,BHA wiper up hole,PUW 30 10,359.0 10,359.0 22:09 23:30 k, 10/10/2015 10/11/2015 0.50 PROD3 DRILL DRLG P 10359 ft,BOBD 1.54 bpm at 3900 psi, 10,359.0 10,372.0 23:30 00:00 BHP 4413,WHP 249,IA 424,OA 22 10/11/2015 10/11/2015 1.00 PROD3 DRILL DRLG P 10372 ft,OBD in ankerite @ 5-8 fph, 10,372.0 10,378.0 00:00 01:00 1.53 bpm at 4034,BHP 4037,WHP 249,IA 423,OA 21 10/11/2015 10/11/2015 0.25 PROD3 DRILL DRLG P 10375 ft,PUW 31 k,BOBD 1.55 bpm 10,378.0 10,384.0 01:00 01:15 at 3500 psi,BHP 4004,WHP 205,IA 430,OA 22 10/11/2015 10/11/2015 0.75 PROD3 DRILL DRLG P 10385ft,PUW 35 k,BOBD 1.55 bpm 10,384.0 10,384.0 01:15 02:00 at 3500 psi, BHP 4003,WHP 204,IA 430,OA 22 10/11/2015 10/11/2015 2.00 PROD3 DRILL DRLG P 10384 ft,Broke thru Ankerite,Drilling 10,384.0 10,452.0 02:00 04:00 Ahead at 60 fph, 1.55 bpm at 3500 psi,BHP 406,WHP 204, IA 431,OA 22 10/11/2015 10/11/2015 2.75 PROD3 DRILL TRIP T 10452 ft,POOH for HOT failure,PUW 10,452.0 72.2 04:00 06:45 31k 10/11/2015 10/11/2015 1.25 PROD3 DRILL PULD T PJSM,Pressure un-deploy BHA#14 72.2 0.0 06:45 08:00 **Note: Bit Grade 1-1-BT N-X-I BU DTF 10/11/2015 10/11/2015 1.50 PROD3 DRILL PULD T P/U 1.5°AKO motor,HCC RR bi- 0.0 72.2 08:00 09:30 center bit,MU Coil Trak,PJSM, Pressure deploy BHA#15,surface test 10/11/2015 10/11/2015 1.65 PROD3 DRILL TRIP T RIH with L1-02 lateral drilling BHA#15 72.2 8,850.0 09:30 11:09 10/11/2015 10/11/2015 0.10 PROD3 DRILL DLOG 'T 8850 ft,Tie into K1 marker for a-4.0 ft 8,850.0 8,869.0 11:09 11:15 correction 10/11/2015 10/11/2015 1.00 PROD3 DRILL TRIP T 8869 ft,Continue RIH with L1-02 8,869.0 10,455.0 11:15 12:15 lateral drilling BHA#15 **Note: Baker Hughes 8 hrs. downtime 10/11/2015 10/11/2015 6.00 PROD3 DRILL DRLG P 10455 ft,BOBD 1.52 bpm at 3706 psi, 10,455.0 10,650.5 12:15 18:15 BHP 3974,WHP 104,IA 305,OA 15 10/11/2015 10/11/2015 0.50 PROD3 DRILL WPRT P 10650 ft,TD L1-02 lateral,pump 10 x 10,650.5 10,650.5 18:15 18:45 10 sweep 10/11/2015 10/11/2015 2.25 PROD3 DRILL WPRT P 10650 ft,Wiper to the swab valves 10,650.5 72.2 18:45 21:00 10/11/2015 10/11/2015 1.50 PROD3 DRILL TRIP P At surface,reset counters,RBIH 72.2 8,850.0 21:00 22:30 10/11/2015 10/11/2015 0.25 PROD3 DRILL DLOG P 8850 ft,Tie into the K1 marker 8,850.0 8,871.0 22:30 22:45 correction of minus 4.0 ft. 10/11/2015 10/11/2015 0.75 PROD3 DRILL TRIP P 8871 ft,Continue wiper in hole,RIW 8,871.0 10,649.0 22:45 23:30 10 k 10/11/2015 10/11/2015 0.25 PROD3 DRILL TRIP P 10649 ft,confirmed TD,line up 10,649.0 10,649.0 23:30 23:45 completion fluid 10/11/2015 10/12/2015 0.25 PROD3 DRILL DISP P 10649 ft,POOH laying in 11.8 ppg 10,649.0 10,430.0 23:45 00:00 completion fluid with beads. 10/12/2015 10/12/2015 0.50 PROD3 DRILL DISP P 10430 ft,Continue laying in 11.8 ppg 10,430.0 9,100.0 00:00 00:30 liner running pill Page 14/16 Report Printed: 11/12/2015 „ ,,,, ,., • • . . ‘,. . , , Operations Summary (with Timelog Depths) 1- . .,_µ 1G-05 {ConocoPhitl9ps.0 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/12/2015 10/12/2015 2.00 PROD3 DRILL DISP P 9100 ft,continue POOH while 9,100.0 72.2 00:30 02:30 displacing well Painting EOP flags at 9100 ft and 7700 ft. 10/12/2015 10/12/2015 0.50 PROD3 DRILL OWFF P PJSM,perform no flow check 72.2 72.2 02:30 03:00 10/12/2015 10/12/2015 0.75 PROD3 DRILL PULD P LD drilling BHA#15 72.2 0.0 03:00 03:45 10/12/2015 10/12/2015 0.25 COMPZ3 CASING PUTB P PJSM,prep rig floor for MU liner 0.0 0.0 03:45 04:00 10/12/2015 10/12/2015 3.50 COMPZ3 CASING PUTB P MU BHA#16 w/45 jts of slotted liner 0.0 1,448.5 04:00 07:30 5.55 ft pup joint and non-ported bull nose,replaced checks 10/12/2015 10/12/2015 1.60 COMPZ3 CASING RUNL P RIH with L1-02 slotted liner completion 1,448.5 9,156.0 07:30 09:06 10/12/2015 10/12/2015 0.15 COMPZ3 CASING DLOG P 9156 ft,correction at EOP flag-8.0 ft. 9,156.0 9,149.0 09:06 09:15 PUW 35k 10/12/2015 10/12/2015 0.75 COMPZ3 'CASING RUNL P 9149 ft,Continue RIH with L1-02 9,149.0 10,649.0 09:15 10:00 slotted liner completion,RIW 12.5k 10/12/2015 10/12/2015 0.25 COMPZ3 CASING RUNL P Tag bottom at 10649 ft,release from 10,649.0 9,234.0 10:00 10:15 liner,PUH,remove liner from counters,open EDC 10/12/2015 10/12/2015 0.80 COMPZ3 CASING DISP P 9234 ft, Displace well to seawater 9,234.0 9,234.0 10:15 11:03 10/12/2015 10/12/2015 3.00 COMPZ3 CASING TRIP P Trip out,Freeze protect tubing from 9,234.0 41.5 11:03 14:03 2500'with diesel 10/12/2015 10/12/2015 1.40 COMPZ3 CASING PULD P At surface,PJSM,PUD BHA#16 and 41.5 0.0 14:03 15:27 lay down,FSITP=1005,IA=182,OA=9 10/12/2015 10/12/2015 2.00 DEMOB WHDBOP MPSP P PJSM,Set BPV in tubing hanger, 0.0 0.0 15:27 17:27 Load out FMC lubricator 10/12/2015 10/12/2015 2.00 DEMOB WHDBOP CIRC P PJSM,Pump Corrosion Inhibitor and 0.0 0.0 17:27 19:27 post flush and jet BOPE 10/12/2015 10/12/2015 1.75 DEMOB WHDBOP CTOP P PJSM,RU and pump N2,RD SLB N2, 0.0 0.0 19:27 21:12 bleed off coil 10/12/2015 10/12/2015 1.00 DEMOB WHDBOP CTOP P PJSM,RU to blow down rig surface 0.0 0.0 21:12 22:12 lines with HO air compressor. 10/12/2015 10/12/2015 1.25 DEMOB WHDBOP CTOP P PJSM,RD pressure bulkhead and 0.0 0.0- 22:12 23:27 inner reel iron 10/12/2015 10/13/2015 0.55 DEMOB WHDBOP CTOP P PJSM,RU,unstab off of well,secure 0.0 0.0 23:27 00:00 injector cart,unstab coil from injector and secure coil to reel spool,hook up lifting slings,remove horses head. 10/13/2015 10/13/2015 3.50 DEMOB MOVE CTOP P Continue reel swap,RU and spot 0.0 0.0 00:00 03:30 empty rig truck, lower reel to trailer, and secure coil reel to trailer.Spot new reel under rig,hook up slings, unsecure reel,PU and secure in rig saddle clamps and hubs. 10/13/2015 10/13/2015 2.50 DEMOB MOVE CTOP P PJSM,remove protective covering 0.0 0.0 03:30 06:00 from coil reel,and tighten reel hubs, remove stripper from injector,uninstall old brass,install new brass. 10/13/2015 10/13/2015 2.50 DEMOB MOVE CTOP P PJSM,tighten saddle clamp bolts. 0.0 0.0 06:00 08:30 Install grapple and pull test.Re torque grapple.Position spool and remove banding securing CT.Stab coil into injector. Page 15/16 Report Printed: 11/12/2015 Operations Summary (with Timelog Depths) 1G-05 ConocoPhittips • Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(ftKB) 10/13/2015 10/13/2015 4.00 DEMOB MOVE CTOP P PJSM,Install inner reel iron-pressure 0.0 0.0 08:30 12:30 bulkhead 10/13/2015 10/13/2015 1.00 DEMOB MOVE CTOP P PJSM,Move cart,install lifting cable 0.0 0.0 12:30 13:30 on BOPE 10/13/2015 10/13/2015 1.50 DEMOB WHDBOP NUND P PJSM,Nipple down stack. 0.0 0.0 13:30 15:00 RIG RELEASE 15:00 Page 16/16 Report Printed: 11/12/2015 I • • • W KI W= mQ= r M 1 • C t CtS O Q. RS 0 O 0 w W C a ,, w z > 6 Mils MOM •- in Sim mmIIIVIIIIiMEM ili MIN N zg •- =_ Cn s 0) 0 ^ m m N O > o = •— r 0 0 O /\ (,7 No g •- N VO L C Y Y • N = sod 8 C L L 0 0 C C•1 `V a O O Q Q. 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DATA LOGGED WELL NAME 1C-05L1;05L1-01;05L1-02 700 G Street. /°t/ 201 M..K.BENDND R Anchorage,Alaska 99510 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE CR-RES BHI DISTRICT Alaska --- LOG DATE October 15,2015 AUTHORIZED BY Patrick Rider EMAIL Patrick.Riderbakerhuqhes.com TODAYS DATE November 4,2015 Revision STATUS Final Replacement: No Details: Requested by: COMPANY FIELD FINAL CD CD ADDRESS(FEDEXWILL NOT DELIVER TO P.O.BOX) LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #01-1-1-(IN I S #OF COPIES #OF COPIES #OF COPIES 1 BP North Slope 0 0 0 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 0 0 Attn:Ricky Elgaricio ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska 0 0 0 Attn:Lynda M.Yaskell and/or Leonardo Elias 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC 1 1 1 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5'DNR-Division of Oil&Gas *** 0 1 1 Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. 1 1 1 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 TOTALS FOR THIS PAGE: 0 2 3 3 0 0 TOTALS FOR ALL PAGES: 0 2 3 3 0 0 CO • • N"' M e.-- (0 c... 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Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BakerHughes.com Yosha Ragbirsingh, Baker Hughes, Survey Manager Yosha.Ragbirsingh • BakerHughes.com °Or.... o • • rn M Ln toN Ely W 1® ,_ MN `M2 g Z a z I a asL CU 0 a) Q W W i tn 0. (./) Z 0 ENE O. IMMO Cf) ,, E MN= • E CO a N z O d m ; • N.-- '—' rt:t.'''',4,bitttli,h373t.43-ft'33-3,1,31, 11 �WliNu�+ v • .-.- ca �. � .N ` � r _ d N O N CD O LIO to' c Ln o W 3 ' a a c•. ° o ��� �� �� w ( m O o 0 0 _. _ .. , i . . O N N > .. , , , �� NaN�q v� a cc CI -L.,' J (� s UV{UI'i ta� O ' I,. ,, d •r p ,....... 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CL C• m2 2 = 2 = � ) a - . ) qq SO LOo ~ g / ` / } } \ \ \ ° ` k 2 *1gEri 2 / � » k \ \ , 0 CO | LOo U ( / / t ( . » ! o a k ; 3 § / S / i 0 • Pti\\I/OF T{i, • • �w)" 774, THE STATE Alaska Oil and Gas 7A OfA Conservation Commission N..„,...._ _ =___-_-.._ �l'rl •. TAsKA t. €,,,,__ 333 West Seventh Avenue 2-- .. _ GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 --7,i Main: 907.279.1433 oFALAS'''� Fax: 907.276.7542 www.aogcc.alaska.gov D. Venhaus CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1G-05L1-02 ConocoPhillips Alaska, Inc. Permit No: 215-178 Surface Location: 1323' FSL, 590' FWL, SEC. 29, T12N, R10E, UM Bottomhole Location: 925' FNL, 3065' FEL, SEC. 5, Ti 1N, R10E, UM Dear Mr. Venhaus: Enclosed is the approved application for permit to redrill the above referenced service well. The permit is for a new wellbore segment of existing well Permit No. 183-020, API No. 50-029- 20908-00-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy P. oerster Chair DATED this nay of October, 2015. • 0 RECEIVED . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION OCT 0 7 2015 PERMIT TO DRILL AOGCC 20 AAC 25.005 la.Type of Work: 1 b.Proposed Well Class: Development-Oil ❑ Service-Winj ❑ . Single Zone O. 1c.Specify if well is proposed for: Drill ❑ i Lateral C Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill ❑ Reentry[, Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: •Lti Blanket ❑Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc.' Bond No. 59-52-180 % KRU 1G-05L1-02 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 10600' - TVD: 6401' . Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 1323'FSL,590'FWL,Sec.29,T12N, R10E, UM , ADL 25640,24547 . Kuparuk River Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 49'FNL,3117'FEL,Sec.5,T11N, R10E,UM ' 2571,465 10/8/2015 Total Depth: 9.Acres in Property: 14.Distance to 925'FNL,3065'FEL,Sec.5,T11N, R10E, UM ` 4928 , Nearest Property: 22950 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: • 90 feet 15.Distance to Nearest Well Open Surface:x- 540441 y- 5981620 Zone- 4 , GL Elevation above MSL- 63 feet to Same Pool: 1A-16,590' 16.Deviated wells: Kickoff depth: . 9700 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: , 98.1* deg Downhole:3820 psig + Surface:3175 psig - 18.Casing Program: Specifications Top - Selling Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2.375" 4.7# L-80 ST-L 1355' 9245' 6340' 10600' 6401' 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) 10086 7068 none 9975 6982 9509', 9520' Casing Length Size Cement Volume MD TVD Conductor/Structural 50' 16" 300 sx AS II 80' 80' Surface 2248' 10.75" 1300 sx AS III,250 sx AS I 2524' 2278' Production 10041' 7" 1000 sx CI G,250 sx ASI 10071 7056' Perforation Depth MD(ft): Perforation Depth TVD(ft): 8976-9050,9095-9131,9332-9336,9348-9378 6234-6288,6322-6349,6498-6501,6509-6532 20.Attachments: Property Plat❑ BOP Sketch❑ Drilling Program 0 Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements ❑ 21.Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Jason Burke @ 265--6737------------ Email Jason.Burkecop.com Printed Name D. Ve haus Title CTD Engineering Supervisor Signature A"-- , Phone:263-4372 Date /t 7—/5 Commission Use Only Permit to Drill API Number: Permit Approval 1 �7f�n See cover letter Number: Q i s-- I n-? 50-01.9 - f�O G3 og_P z_40Date: 10 XIII for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed m thane,gas hydrates,or gas contained in shales: d Other: Bt P tc5f f0 3.5-60p5 i Samples req'd: Yes ❑ No Mud log req'd: Yes No[' /1-�V7 u/a p rev Lvt-tt✓ fs$-1 fo 25 A(4 measures: Yes [A No Directional svy req'd: Yes RI No❑ •S f a 7't wr fn x 5 5-r 1 " 1 T 1 s acin exception req'd: Yes r q, lYtC/ Cc f¢G�StGr b i l rU p g p q ❑ No Inclination-only svy req'd: Yes❑ No[V / Irc'f1OYL ✓✓ APPROVED BY THE /D--6)..—[ S Approved by: P 7 fi CIV(]p�`IS' I COMMISSION Date:Form 10-401 (Re ised 10/2012) T . t f1o1AhEom the date of approval(20 AAC 25.005(g)) /5,4/,s • s ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 October 7, 2015 Commissioner-State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for an additional permit to drill a tri-lateral out of the KRU 1G-05 (183-020) using the coiled tubing drilling rig, Nabors CDR2-AC.'The work is currently in progress. The CTD objective will be to drill laterals the 1G-05L1 (215-147), 1G-05L1-01 (215-148' & 1G-05L1-02, targeting the Kuparuk A-sand intervals. Note the current A sand perforations will be open below the whipstock. Attached to this application are the following documents: — Permit to Drill Application Forms (10-401)for 1G-05L1-02 — Detailed Summary of Operations(revised) — Directional Plans for 1G-05L1-02 — Current wellbore schematic — Proposed wellbore schematic If you have any questions or require additional information please contact me at 907-265-6097. Sincerely, 411111111PAIr 'Jason Burke Coiled Tubing Drilling Engineer • Kuparuk CTD Laterals NABORSS ALASKA rl, 1G-05L1 L1 -01 & L1 -02 cu ConocoPhillips Application for Permit to Drill Document 211C 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(f)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 5 (Requirements of 20 AAC 25.005(c)(13)) 5 Summary of Operations 5 Pressure Deployment of BHA 6 Liner Running 6 14. Disposal of Drilling Mud and Cuttings 6 (Requirements of 20 AAC 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 7 (Requirements of 20 AAC 25.050(b)) 7 16. Quarter Mile Injection Review (for injection wells only) 7 (Requirements of 20 AAC 25.402) 7 17. Attachments 8 Attachment 1: Directional Plans for 1G-05L1 & L1-01 8 Attachment 2: Current Well Schematic for 1 G-05 8 Attachment 3: Proposed Well Schematic for 1G-05L1 & L1-01 8 Page 1 of 8 10/7/2015 • • PTD Application: 1G-05L1, L1-01 & L1-02 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document are 1G-05L1, L1-01 & L1-02. Laterals will be classified as "Service- WINJ"well. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A4 sand package in the Kuparuk reservoir. See the attached 10-401 form for surface and subsurface coordinates of the 1G-05L1, L1-01 & L1-02. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036, for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. Using the maximum formation pressure in the area of 3820 psi in this well the 1G-05,the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft,would be 3175 psi. See the "Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Expected Downhole Pressure (Requirements of 20 AAC 25.005(c)(4)(a)) A static bottom hole pressure of 1G-05 in August 2015 indicated a reservoir pressure of 3820 psi or 11.4 ppg equivalent mud weight. The maximum down hole pressure in the 1G-05 pattern is the 1G-05 with 3820 psi. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) No specific gas zones will be drilled. Gas injection has been performed on 1G pad, so cuttings will be monitored for entrained gas. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) Exposed shale while drilling the 1G-05 laterals, especially at fault crossings, has the potential to cause hole problems. Managed pressure drilling equipment will be used to keep pressure on the well bore to minimum of 11.8 ppg, which has historically kept shale sections stabilized at Kuparuk. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) N/A for this thru-tubing drilling operation. According to 20 AAC 25.030(f), thru-tubing drilling operations need not perform additional formation integrity tests. Page 2 of 8 10/7/2015 PTD Application: 1G-05L1, L1-01 & L1-02 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Liner Top Liner Btm Liner Top Liner Btm Liner Details Name MD MD TVDSS TVDSS 1G-05L1 9275' 12534' 6365' 6599' 23/", 4.7#, L 80, ST-L slotted liner; with a shorty deployment sleeve 1G-05L1-01 9700' 11600' 6420' 6395' 23/8', 4.7#, L 80, ST L slotted liner; with a liner top billet. 1G-05L1-02 9245' 10600' 6340' 6410' 2%", 4.7#, L-80, ST-L slotted liner, with a shorty deployment sleeve Existing Casing/Liner Information Category OD Weight Grade Conn. Top Btm Top Btm Burst Collapse (POMD MD TVD TVD psi psi Conductor 16" 65 H-40 Welded 30' 80' 0' 80' 1640 630 Surface 10-3/4" 45.5 K-55 BTC 30' 2,523' 0' 2,278' 3580 2090 Casing 7" 26 K-55 BTC 30' 10,071' 0' 7,056' 7240 5410 Tubing 3 '/2" 9.3 L-80 EUE8Rd mod 26' 9,189' 0' 6,392' 6990 7400 Liner 51/" 14 H-40 STC 9,183' 9,312' 6,387' 6,482' 3110 2620 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) N/A for this thru-tubing drilling operation. Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System Diagram of Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride weighted FloVis water based mud (9.1 ppg) — Drilling operations: Chloride weighted PowerVis water based mud (9.5 ppg)./This mud weight will not hydrostatically overbalance the reservoir pressure. — Completion operations: Liner running operations will be done with 11.8 ppg Bromide weighted completion fluid to maintain overbalance and well bore stability during completion operations. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". The targeted MPD BHP will be 11.8 ppg'EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Page 3 of 8 10/7/2015 • PTD Application: 1G-05L1, L1-01 & L1-02 Pressure at the 1G-05 Window (9277' MD, 6459' TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure (11.4 ppg) 3794 psi 3794 psi Mud Hydrostatic (9.5 ppg) 3162 psi 3162 psi Annular friction (i.e. ECD, 0.070 psi/ft) 649 psi 0 psi Mud + ECD Combined 3811 psi 3162 psi (no choke pressure) (over balanced (under balanced —17 psi) —632 psi) Target BHP at Window(11.8 ppg) 3927 psi 3927 psi Choke Pressure Required to Maintain 116 psi 765 psi Target BHP 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AA C 25.005(c)(11)) N/A—Application is for a land-based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Page 4 of 8 10/7/2015 • PTD Application: 1G-05L1, L1-01 & L1-02 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background KRU 1 G-05 will be a dual lateral injector. A recent RWO was performed to replace the 3.5"tubing and a 5.5"big tail pipe to allow for CTD operations. The objective of this well is to drill 2 laterals one to the north and one to the south. 1G-05L1 will kick off in the B2 shale at 9277' MD and turn to the north, landing in the A4 sand. The lateral will be drilled to the north and cross the first fault(55' DTN) into the B-shale. From there drop down to reacquire the A4 sand and drill to 13000' MD 1G-05L1-01 will kick off the billet at 9490' MD and turn to the south in the A4 sand. Drill in the A4 sand until a planned TD of 11,600' MD. l 1G-05L1-02 will kick off the billet at 9700' MD and drop down to drill in the A4 until 10600'just before the large fault Pre-CTD Work ■ E-line: Set a 31/2"x 5 1/2"thru-tubing whip-stock at 9,277' MD and 0°HS Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 1G-05L1 Lateral(A4 sand-North) i. Mill 2.80"window at 9,277' MD ii. Drill 2.70"x 3.00"bi-center lateral to TD of 12,534 MD iii. Run 23/8" slotted liner with deployment sleeve from TD up to 9275' MD 3. 1G-05L1-01 Lateral(A4 sand- South) i. Mill off aluminum billet at 9,490' MD ii. Drill 2.70"x 3.00"bi-center lateral to TD of 11,600' MD iii. Run 2%" slotted liner with aluminum billet from TD up to 9700' MD 4. 1G-05L1-02 Lateral(A4 sand- South) i. Mill off aluminum billet at 9700' MD ii. Drill 2.70"x 3.00"bi-center lateral to TD of 10600' MD x iii. Run 2%" slotted liner with deployment sleeve from TD up to 9245' MD 5. Freeze protect the well. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull I3PV Page 5 of 8 10/7/2015 S • PTD Application: 1G-05L1, L1-01 & L1-02 2. Obtain static BHP. 3. Pre-produce for more than 1 month / 4. Convert back to injection Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. Because of this, MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick line lubricator. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slick line. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA un-deployment, the steps listed above are observed, only in reverse. Liner Running — While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. — The 1G-05 CTD laterals will be displaced to an overbalance completion fluid (as detailed in Section 8 "Drilling Fluids Program") prior to running liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AA C 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18 or 1B disposal facilities) or Prudhoe DS-4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). Page 6 of 8 10/7/2015 • • PTD Application: 1G-05L1, L1-01 & L1-02 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plan — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire openhole section. — Distance to Nearest Property Line (measured to KPA boundary at closest point) teral Name Distar ce 1G-05L1 21,500' 1G-05L1-01 22,950' 1G-05L1-02 22,950' — Distance to Nearest Well within Pool (measured to offset well) Lateral Name 1G-05L1 230' 1G-11A 1G-05L1-01 590' 1A-16 1G-05L1-02 590' 1A-16 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) 1G-11A, 1G-14, 1A-16, 1A-18, 1A-03 & 1A-16RD are within 1/4-mile of the 1G-05L1, L1-01 & L1-02 wells 1G-05 (mother bore) Injector • The well is completed with 3.5" 9.3# L-80 tubing, 5.5" 14.0# H-40 liner and 7" 26# K-55 production casing. The last MIT-IA was completed on 5/08/15 and passed at 3030 psi. • Classified as a "Normal Well" • C-sand perforations (open, isolated between packers at 9061', 9183' & 8809'): 8976' —9050' MD & 9095' —9131' MD • A-sand perforations (open): A5: 9332'—9336' MD &A4: 9348' —9378' MD • Well was recently worked over on 4-11-15, the selective across the C-sand was replaced as well as the tubing pack-offs which were tested to 5000 psi 10-11A (producer),—230' away from 1G-05L1 & L1-02 lateral to northwest • Well has currently not been drilled • This lateral will be drilled —1 month prior to CDR-2 arriving on 1G-05 • CTD lateral completed with 2-3/8" slotted liner • Will be completed in the C-sand • C-sand and A-sand are separated by at least 140' TVD of impermeable B-shale 1G-14(injector), —1040' away from 1G-05L1 & L1-02 lateral to northwest • 1G-14 currently injecting into the Kuparuk A&C sand intervals • Classified as a normal well • State witnessed MIT-IA last performed 7-7-15 passed to 2400 psi • Well is completed with 7" 26# K-55 production casing and 3 %Z" 9.3#J-55 tubing • C-sand perforations (isolated with a straddle): C4: 7097' —7168' MD & Cl: 7240' —7296' MD • A-sand perforations: A4: 7564' —7590' & 7560' —7590' MD &A3: 7610'—7630' MD • Packer at 6928' MD, which is less than 200' from the perforations • The cement bond log shows adequate cement more than 200' above the top perforation 1A-16 (abandoned injector), -590' away from 1G-05L1-01 lateral to southwest Page 7 of 8 10/7/2015 • PTD Application: 1G-05L1, L1-01 & L1-02 • 1A-16 is an abandoned injection well, that was abandoned in 1982 • It was originally drilled to a depth of 7722' MD out of the 10.75" surface casing set at 2456' MD • When abandoned a balanced plug of 125 sxs of class 'G' cement was laid in from 7200' —6900' • A second balanced plug of 225 sxs of class 'G' cement was laid in from 4800' —4400' MD • Hard cement was tagged and then drilled from 4285' —4400' MD (tag was state witnessed) • 1A-16RD was sidetracked from 4500' MD 1A-18 (producer), —1140' away from 1G-05L1-01 lateral to south • 1A-18 currently producing from the Kuparuk A&C sand intervals • Classified as a waivered well for OAxFormation communication • Well can operate with gas lift • Well is completed with 7" 26#J-55 production casing and a 4" x 3.5" x 2.875" tubing string • C-sand perforations (isolated with a straddle): C4: 6822'—6850' MD &6850' —6870' MD & Cl: 6915'— 6932' MD • A-sand perforations: A5: 7076' —7080' MD &A4: 7091' —7118' MD • The original cement bond log shows poor cement, a remedial squeeze job was performed in 1991 • The job consisted of shooting perforations from 6908' —6910' MD &6668'—6670' MD then pumping 30 bbl of cement and squeezing away 26.5 bbl • A balanced plug was then set and an additional 1.4 bbl of cement was squeezed when applying 3000 psi pressure • A CBL was not run post squeeze job 1A-03 (producer), —1150' away from 1G-05L1-01 lateral to east • 1A-03 currently producing from the Kuparuk A&C sand intervals • Classified as a waivered well for IAxOA communication • Well can operate with gas lift • Well is completed with 7"26# K-55 production casing and a 3.5" 9.3# L-80 tubing • C-sand perforations (isolated with a straddle): C2/C4/C3: 7820' —7888' MD C2: 7920' —7922' MD Cl: 7948' —7972' MD • Unit B perforations (squeezed with cement): 8108' —8110' MD • A-sand perforations (isolated with a plug and sand): A5: 8166' —8172' MD &A4: 8178'—8210' &8180'— 8214' MD • Good cement across the C-sand perfs, the cement above the perfs is marginal 1A-16RD (injector), —1260' away from 1G-05L1-01 lateral to southwest • 1A-16RD currently injecting into the Kuparuk A&C sand intervals • Classified as a waivered well for IAxOA communication • MIT-IA last performed 3-22-15 passed to 3384 psi • Well is completed with 7" 26# K-55 casing and 3 1/2" 9.3# L-80 tubing • C-sand perforations (isolated with a straddle): C4: 6771' —6832' MD & Cl: 6870' —6883' MD • A-sand perforations: A5: 7014' —7022' MD &A4: 7032' —7054' MD • Packer at 6699' MD, which is less than 200' from the perforations • The cement bond log shows adequate cement more than 200' above the top perforation 17. Attachments Attachment 1: Directional Plans for 1G-05L1, L 1-01 & L1-02 Attachment 2: Current Well Schematic for 1G-05 Attachment 3: Proposed Well Schematic for 1G-05L1, L1-01 & L1-02 Page 8 of 8 10/7/2015 • • mi H LII E L MO `M2 a= xm4. i. 1.4 kip a t g � � r /I t••• 1 s=3 a z 2§6.s m m;• h p O ,nmmU L': _ E } . LL d/2d-8 :; Eagm i 1 o�aaWvitt _ 0 0 S ry, J4 I 4 w ' _ nJ �. . i . o~ - . H . x S 0 e E `'�-- C + 9 N M H^nn tan I n pi \ - OO �J E. �C _.... .-11--'•---''-- S <�4v, -. ;. fir.,.;:_...rae_ _ .. qv fit,nob .7 _ I -1 + _ [�] m En Lamm, i1 it T .if,,-,,, _ICE amegrior ..,.......„,.,.., ,Hlt.„, .11,,,,,,,I, ..„. . . . ..: _ , . , _,.,...„.„, , , ,. . , .i_: .," , .. : .e-'-',----,'-- - 4 t. '' _.-__ _ --_ - of 7 O r , Y `w a c 4 �� iir.._. IC 22 �4 U N 4644 N q`� • _ Y Jc, o Y Y N moi.. c 11: 4 i EM t_ EliH: :-111111W7.,_._.,_,%_,.. E L - , '42o m lN tom a}: :_:, FA +MIIMINENCI, MIN: ,4 ko M . . ` . f -_ _ - N 0 ' i c r u o -o c c o c o 0 o f c o ' o 0 0 + Y Oo o o 0 0 0 0 e. o v r ,-: N g e q •4 h ,°? `4 o a n 0 M(u!Aisn oc£)(+)quoN1(-)u;nos • • ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1G Pad 1G-05 1G-05L1-02 Plan: 1 G-05L1-02_wp02 Standard Planning Report 07 October, 2015 BAKER HUGHES `, • Baker Hughes INTEQ Vail COfOCOPl1IhhpS Planning Report BAKER HUGHES Database: OAKEDMP2 Local Co-ordinate Reference: Well 1G-05 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1G-05 @ 90.00usft(1G-05) Site: Kuparuk 1G Pad North Reference: True Well: 1G-05 Survey Calculation Method: Minimum Curvature Wellbore: 1G-05L1-02 Design: 1 G-05L1-02_wp02 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 1G Pad Site Position: Northing: 5,981,540.78 usft Latitude: 70°21'37.826 N From: Map Easting: 540,089.12 usft Longitude: 149°40'27.705 W Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.31 ° Well 1G-05 Well Position +N/-S 0.00 usft Northing: 5,981,619.82 usft Latitude: 70°21'38.585 N +EI-W 0.00 usft Easting: 540,440.61 usft Longitude: 149°40'17.414 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1G-05L1-02 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BGGM2015 10/1/2015 18.85 81.00 57,501 Design 1G-05L1-02_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 9,695.81 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 180.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (usft) (0) (°) (usft) (usft) (usft) (°/100usft) (°/100usft) (°1100usft) (0) Target 9,695.81 90.68 155.73 6,420.87 -6,300.78 1,518.30 0.00 0.00 0.00 0.00 9,700.00 90.66 156.15 6,420.82 -6,304.61 1,520.01 10.03 -0.48 10.02 92.72 9,790.00 81.66 156.15 6,426.84 -6,386.65 1,556.28 10.00 -10.00 0.00 180.00 9,990.00 91.89 173.39 6,438.17 -6,578.38 1,608.32 10.00 5.11 8.62 60.00 10,070.00 91.87 165.38 6,435.55 -6,656.90 1,623.04 10.00 -0.02 -10.01 270.00 10,380.00 91.60 196.40 6,425.93 -6,962.95 1,618.27 10.00 -0.09 10.00 90.00 10,495.00 98.14 186.90 6,416.15 -7,074.97 1,595.12 10.00 5.69 -8.26 305.00 10,600.00 98.01 197.51 6,401.35 -7,176.43 1,573.18 10.00 -0.13 10.10 90.00 10/7/2015 9:38:11AM Page 2 COMPASS 5000.1 Build 74 y,. • Baker •Hughes INTEQ • EMI Conoconilips Planning Report BAKER HUGHES x r Database: OAKEDMP2 Local Co-ordinate Reference: Well 1G-05 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1G-05 @ 90.00usft(1G-05) Site: Kuparuk 1G Pad North Reference: True Well: 1G-05 Survey Calculation Method: Minimum Curvature Wellbore: 1 G-05L1-02 Design: 1 G-05 L 1-02_wp02 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100usft) (°) (usft) (usft) 9,695.81 90.68 155.73 6,420.87 -6,300.78 1,518.30 6,300.78 0.00 0.00 5,975,327.95 541,992.76 TIP 9,700.00 90.66 156.15 6,420.82 -6,304.61 1,520.01 6,304.61 10.03 92.72 5,975,324.13 541,994.49 KOP 9,790.00 81.66 156.15 6,426.84 -6,386.65 1,556.28 6,386.65 10.00 -180.00 5,975,242.29 542,031.20 Start 10 dls 9,800.00 82.16 157.02 6,428.25 -6,395.74 1,560.21 6,395.74 10.00 60.00 5,975,233.23 542,035.18 9,900.00 87.25 165.67 6,437.49 -6,489.97 1,591.99 6,489.97 10.00 59.88 5,975,139.18 542,067.46 9,990.00 91.89 173.39 6,438.17 -6,578.38 1,608.32 6,578.38 10.00 59.08 5,975,050.87 542,084.27 4 10,000.00 91.89 172.39 6,437.84 -6,588.29 1,609.56 6,588.29 10.00 -90.00 5,975,040.96 542,085.56 10,070.00 91.87 165.38 6,435.55 -6,656.90 1,623.04 6,656.90 10.00 -90.03 5,974,972.43 542,099.41 5 10,100.00 91.86 168.39 6,434.57 -6,686.10 1,629.84 6,686.10 10.00 90.00 5,974,943.27 542,106.37 10,200.00 91.82 178.39 6,431.35 -6,785.26 1,641.33 6,785.26 10.00 90.10 5,974,844.19 542,118.39 10,300.00 91.72 188.40 6,428.25 -6,884.91 1,635.42 6,884.91 10.00 90.42 5,974,744.52 542,113.02 10,380.00 91.60 196.40 6,425.93 -6,962.95 1,618.27 6,962.95 10.00 90.73 5,974,666.40 542,096.29 6 10,400.00 92.75 194.76 6,425.17 -6,982.20 1,612.90 6,982.20 10.00 -55.00 5,974,647.12 542,091.03 10,495.00 98.14 186.90 6,416.15 -7,074.97 1,595.12 7,074.97 10.00 -55.06 5,974,554.26 542,073.76 7 10,500.00 98.14 187.41 6,415.44 -7,079.88 1,594.51 7,079.88 10.00 90.00 5,974,549.35 542,073.17 10,600.00 98.01 197.51 6,401.35 -7,176.43 1,573.18 7,176.43 10.00 90.07 5,974,452.69 542,052.36 Planned TD at 10600.00 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 10,600.00 6,401.35 2 3/8" 2-3/8 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 9,695.81 6,420.87 -6,300.78 1,518.30 TIP 9,700.00 6,420.82 -6,304.61 1,520.01 KOP 9,790.00 6,426.84 -6,386.65 1,556.28 Start 10 dls 9,990.00 6,438.17 -6,578.38 1,608.32 4 10,070.00 6,435.55 -6,656.90 1,623.04 5 10,380.00 6,425.93 -6,962.95 1,618.27 6 10,495.00 6,416.15 -7,074.97 1,595.12 7 10,600.00 6,401.35 -7,176.43 1,573.18 Planned TD at 10600.00 10/7/2015 9:38:11AM Page 3 COMPASS 5000.1 Build 74 1 • ConocoPhillips edr ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kupt Local Co-ordinate Reference: Well 1 G-05 Project: Kuparuk River Unit TVD Reference: 1G-05 @ 90.00usft(1G-05) Reference Site: Kuparuk 1G Pad MD Reference: 1G-05 @ 90.00usft(1G-05) Site Error: 0.00 usft North Reference: True Reference Well: 1G-05 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 1G-05L1-02 Database: EDM Alaska ANC Prod Reference Design: 1G-05L1-02_wp02 Offset TVD Reference: Offset Datum Reference 1G-05L1-02_wp02 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 9,695.81 to 10,600.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,251.00 usft Error Surface: Elliptical Conic Survey Tool Program Date 10/7/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 100.00 9,200.00 1G-05(1G-05) FINDER-MS SDC Finder multishot 9,250.00 9,695.81 1G-05L1-01(1G-05L1-01) MWD MWD-Standard 9,695.81 10,600.00 1G-05L1-02_wp02(1G-05L1-02) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (') 10,600.00 6,491.35 2 3/8" 2-3/8 3 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) Kuparuk 1G Pad 1G-05-1G-05-1G-05 9,706.78 9,875.00 413.83 18.28 401.29 Pass-Major Risk 1G-05-1G-05L1-01-1G-05L1-01 9,700.00 9,700.00 0.00 0.53 -0.44 FAIL-Minor 1/10 Offset Design Kuparuk 1G Pad- 1G-05-1 G-05-1 G-05 Offset Site Error. 0.00 usft Survey Program: ISO-FINDER-MS Rule Assigned:Major Risk Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +E/-W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) 11 (soft) (usft) C.) (usft) (usft) (usft) 9,706.78 6,510.78 9,875.00 6,905.25 0.67 3.58 -41.45 -6,361.29 1,408.26 2-11/16 413.83 18.28 401.29 Pass-Major Risk,CC,ES,SF 9,763.04 6,513.56 9,900.00 6,924.39 0.75 3.70 -41.16 -6,377.06 1,411.39 2-11/16 432.41 19.55 419.17 Pass-Major Risk 9,799.13 6,518.13 9,925.00 6,943.56 0.82 3.83 -40.25 -6,392.80 1,414.48 2-11/16 449.60 20.48 435.88 Pass-Major Risk 9,814.41 6,520.12 9,950.00 6,962.79 0.84 3.96 -38.85 -6,408.49 1,417.49 2-11/16 466.80 21.03 452.82 Pass-Major Risk 9,829.39 6,521.88 9,975,00 6,982.03 0.87 4.09 -37.42 -6,424.17 1,420.46 2-11/16 484.15 21.57 469.92 Pass-Major Risk 9,844.10 6,523.41 10,000.00 7,001.27 0.90 4.22 -35.96 -6,439.85 1,423.44 2-11/16 501.62 22.10 487.16 Pass-Major Risk 9,858.52 6,524.73 10,025.00 7,020.52 0.93 4.35 -34.49 -6,455.53 1,426.41 2-11/16 519.21 22.63 504.52 Pass-Major Risk 9,872.63 6,525.84 10,050.00 7,039.76 0.96 4.48 -33.01 -6,471.22 1,429.38 2-11/16 536.93 23.16 522.02 Pass-Major Risk 9,886.43 6,526.76 10,075.00 7,059.00 0.99 4.61 -31.52 -6,486.90 1,432.35 2-11/16 554.77 23.67 539.66 Pass-Major Risk 9,892.41 6,527.10 10,086.00 7,067.47 1.00 4.66 -30.86 -6,493.79 1,433.66 2-11/16 562.66 23.89 547.46 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 10/7/2015 8:12:48AM Page 2 COMPASS 5000.1 Build 74 • • •kli g 4 II< co ad w g 4 a r _ M.1 s 1 .-9 ,n 4. g o �sN — `-' NN s s Z- , 4 a 8 , o 7. th e c 6 - 3 m a o $o a s s s s s s s a g g s a a ca''' 4 � o 3 w $ w `, �o o (u!/gsn 00z)(+)9uoN/(-)41nos __ U LT., ao o O o U o t 2Fh y g .$ �a o 11, m i y t .4 a b c J d o c Q H Y UJ v.n c O r d O V cn b `cF ""m c.r cm O.n r _N g d r mmM Q>00 V V]oV tO,-LONV c0 -moo z >oo m CO co CO LO.n co o,- N COO,-CD CD CD 0 CD C0 4 n N ., 000000 g J C 7 J M ,O O C O CD 0 0 =9 _ c,--,.. M >a 4 N m a'.- Q N 000 0 0 0 0 0 0 b 22 N— or CI o o o 0000 .1- YYf7 t7= �o�mNvrNm 9.�N OfV MON ci {y� Q. O,-- mN Loo NmO�i `+ O 11.3oi co .n LOCOCOCO� b Y N -O 1 Y j J W V co m—.o m O.n r M o r co cn vq rnmrnv, 4 H ; :: OJmoo�{{ , ZS ZS ZS ZS ZS ,- "-M.A.lJ 0 m00•- Co ¢.�--M MV O7.n v8 8. U m m m Or O V ... _ 4 C CO CO CO CO co co,-O 0 - - . ,_.9 0 o m m Q J 6i cm m g 33 CD + O m O o 0 0 0 0 C. r h b b b b b h b b O h3N .r j 0 0 0 p O..'1 O c 0 O O,O,1,--CO 0,CD r r O O CO V CO 1 .(%I p�0>O)O>o o 0 OO W NM LO mrm o (ut/gsn S9)ty.do F3R.13A 3tu1 V F KUP INJ • 1G-05 ConocoPhillips 3 Well Attributes Max Angle&MD TD Alaska,inc. Wellbore API/UWI Field Name Wellbore Status ncl V) MD(ftKB) Act Btm(ttKB) con,,..., ,,,,, 500292090800 KUPARUK RIVER UNIT INJ 56.37 4,600.00 10,086.0 .-. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 10-05,6/162015 3:18:24 PM SSSV:Flapper Locked Out Last WO: 3/24/2015 29.99 2/17/1983 Vertical schematic(actual) Annotation Depth(RKB) End Date Annotation Last Mod By End Date ___ ...... _.. _ Last Tag:SLM 9,412.0 6/6/2015 Rev Reason:TAG,SET WHIPSTOCK lehallf 6/16/2015 HANGER 26.4 At d' }} , f. Casing Strings `r7 II �B Casing Description OD(in) ID(in) Top(RKB) Set Depth(RKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread ii ii CONDUCTOR 16 15.060 30.0 80.0 80.0 65.00 H-40 WELDED Casing Description OD(in) ID(in) Top(ttKB) Set Depth(ttKB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread SURFACE 103/4 9.950 29.7 2,523.9 2,278.4 45.50 K-55 BTC Casing Description OD(in) ID(in) Top(RKB) Set Depth(MB) Set Depth(TVD)...WtlLen(I...Grade Top Thread CONDUCTOR;30.0-80.0- I PRODUCTION 7 6.276 29.9 10,071.0 7,055.9 26.00 K-55 BTC 1 I Tubing Strings Tubing Description String Ma...ID(in) Top(ttKB) Set Depth(ft...Set Depth(ND)(...Wt(Ib/f0 Grade Top Connection TUBING-2015 WO- 31/2 2.992 26.4 9,189.3 6,392.1 9.30 L-80 EUE 8rd AB Mod UPPER SURFACE;29.7-2,523.9 Completion Details Nominal ID GAS LIFT;2,843.2 Top(ttKB) Top(TVD)(RKB) Top Incl(") Item Des Corn (in) 26.4 26.4 0.10 HANGER McENVOY TUBING HANGER 2.992 I 8,778.9 6,093.3 45.96 LOCATOR LOCATOR 2.970 8,779.3 6,093.6 45.96 SEAL BAKER 80-40 SEAL ASSEMBLY 3.000 GAS LIFT;4,963.2 ASSEMBLY 1111 8,786.3 6,098.4 45.81 PBR BAKER 80-40 PBR 4.000 8,809.6 6,114.8 45.40 PACKER BAKER FHL RETRIEVABLE PACKER 2.900 8,831.8 6,130.4 45.13 NIPPLE CAMCO X NIPPLE W/PXX PLUG 2.812 GAS LIFT;6,629.5 la 8,966.6 6,227.0 43.34 BLAST JTS Crossover 4-1/2 OD Blast Joints 3-1/2 8rd x 3-1/2 TCII 2.992 8,971-ft El 8,986.3 6,241.3 43.06 BLAST JTS 4-1/2 OD Blast Joints 3-1/2 TCII x 3-1/2 TCII 2.992 GAS LIFT,7.8289 9,045.5 6,284.8 42.27 BLAST JTS Crossover 4-1/2 OD Blast Joints 3-1/2 TCII x 3-1/2 8rd 2.992 9,055-ft 11 9,061.4 6,296.6 42.06 PACKER BAKER FHL RETRIEVABLE PACKER 2.900 9,086.8 6,315.6 41.72 BLAST JTS Crossover 4-1/2 OD Blast Joints 3-1/2 8rd x 31/2 TCII 2.992 GAS LIFT;8,722.3 - 9,090-ft 9,106.6 6,330.3 41.58 BLAST JTS 4-1/2 OD Blast Joints 3-1/2 TCII x 3-1/2 TCII 2.992 9,182.3 6,386.8 41.90 LOCATOR LOCATOR 2.990 LOCATOR;8,778.9 9,183.1 6,387.4 41.90 SEAL BAKER 80-40 SEAL ASSEMBLY 2.990 ASSEMBLY SEAL ASSEMBLY;8,779.3 PBR;8,786.3 Tubing Description String Ma...ID 5n) Top(ttKB) Set Depth(ft..,Set Depth(ND)(...Wt(1h/ft) Grade Top Connection TUBING-2015 W0- 51/2 4.950 9,183.0 9,312.0 6,482.9 14.00 H-40 STC PACKER;8,8096 - LOWER-31/2"x5 1/2"@9222 NIPPLE;8,831.7 Completion Details at Nominal ID Top(RKB) Top(TVD)(ttKB) Top Incl 13 Item Des Com (in) IF 9,183.0 6,387.3 41.90 PACKER BAKER 85-40 Fl PERMANENT PRODUCTION PACKER 4.000 GAS LIFT;8,885.3 r 9,186.3 6,389.8 41.91 SBE 80-40 SEAL BORE EXTENSION 4.000 9,191.3 6,393.5 41.93 XO Reducing Crossover sub 2.990 9,210.2 6,407.6 42.03 NIPPLE CAMCO X NIPPLE W/PXX PLUG 2.812 GAS LIFT;0,946eII 9,222.1 6,416.4 42.09 XO Enlarging Vented/Ported Cross-over 3-1/2 EUE 8rd x 5-1/2"STC 2.990 BxP - 1 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) 0.9.050.0 Top(ND) Top Incl (PERF;8,976. I Top(1160) (RKB) r) Des Com Run Date _ ID(in) 9.277.0 6,457.0 42.40 WHIPSTOCK 3 1/2"X 5 1/2"GEN II WHIPSTOCK 6/6/2015 9.509.0 6,628.6 41.65 FISH 1.5"CV Empty Pocket;Fell to Rathole 8/7/1987 8/7/1997 9,520.0 6,636.8 41.62 FISH 1 5"OV Lost in Hole 1/25/1994 1/25/1994 PACKER;9,061.4 ''-""._; Illar Perforations&Slots GAS LIFT;9.073.0 Shot Dens Top(TVD) Blot(TVD) (shotsff Top(RKB) Btm(ttKB) (ttKB) (ttKB) Zone Date t) Type Com 8,976.0 9,050.0 6,233.8 6,288.2 C-3,C-4,1G- 2/17/1983 12.0 (PERF 120 deg Ph;GeoVann IPERF;9,095.0-9,131.0 I 05 TCP 9,095.0 9,131.0 6,321.7 6,348.6 C-1,1G-05 2/17/1983 12.0 IPERF 120 deg Ph;GeoVann li TCP GAS LIFT;9,145.9 9,332.0 9,336.0 6,497.6 6,500.5 A-5,10-05 2/17/1983 12.0 (PERF 120 deg Ph;GeoVann f TCP LOCATOR,9,182.3 9,348.0 9,378.0 6,509.4 6,531.5 A-4,1G-05 2/17/1983 12.0 (PERF 120 deg Ph;GeoVann PACKER;9,183.0 I "`• TCP SEAL ASSEMBLY,9,183.1 I" SBE;9,186.3 I = Mandrel Inserts St ati on Top(ND) Valve Latch Port Size TRO Run N Top((MB) (RKB) Make Model OD fin) Sero Type Type (in) (psi) Run Date Coo III:1 1 2,843.2 2,490.3 CAMCO MMG 5.968 GAS LIFT DMY RK 1.500 0.0 4/10/2015 NIPPLE;9,210.2 1J26 2 4,963.2 3,737.0 CAMCO MMG 5.968 GAS LIFT DMY RK 1.500 0.0 4/10/2015 IIIIIIE 3 6,629.5 4,739.9 CAMCO MMG 5.968 GAS LIFT DMY RK 1.500 0.0 4/10/2015 4 7,828.9 5,496.1 CAMCO MMG 5.968 GAS LIFT DMY RK 1.500 0.0 4/102015 - - 11 5 8,722.3 6,054.4 CAMCO MMG 5.968 GAS LIFT DMY RKP 1.500 0.0 4/16/2015 OCR 1 WHIPSTOCK 9.277.0 oir 6 8,885.3 6,168.4 CAMCO MMG 5.968 GAS LIFT 'DMY RK 1.500 0.0 4/10/2015 7 8,946.8 6,212.5 CAMCO MMG 5.968 GAS LIFT DMY RK 1.500 0.0 4/10/2015 IPERF;9,332.0.9,336.0 8 9,073.0 6,305.2 CAMCO MMG 5.968 GAS LIFT DMY RK ' 1.500 0.0 3/8/2015 9 9,146.0 6,359.7 CAMCO MMG 5.968 GAS LIFT DMY RK 1.500 0.0 4/10/2015 IPERF;9,3/8.0.9.378.0 Notes:General&Safety End Date Annotation FISH;9,509.0 - 9/16/2010 NOTE:Mandrel @ 8924-Leak found 6/21/2006 @ C-sand;tbg test failed 2/9/08 confirmed C3/C4 leak 9/16/2010 NOTE:View Schematic w/Alaska Schematic9.0 FISH;9,5200 a PRODUCTION;29.9-10.071.0 . • • II II o) II () II as t!) 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J I m J to S o- N (5 M N • • Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Wednesday, October 07, 2015 10:28 AM To: Burke,Jason; Schwartz, Guy L(DOA); Regg,James B (DOA) Subject: Re:Authorization to continue drilling, KRU 1G-05 Please submit the PTD today for review and approval. Thanx, Victoria Sent from my iPhone On Oct 7, 2015, at 9:29 AM, Burke,Jason<Jason.Burke@conocophillips.com>wrote: ConocoPhillips requests written authorization via email from the Commission to proceed with drilling operations without interruption as per 20 AAC 25.015(b)(2). Due to geologic complexity while drilling the KRU 1G-05L1-01 (PTD 215-148): we anticipate needing to drill an additional lateral to achieve objectives of the well. This 1G-05L1-02 lateral will kick off from the 1G-05L1-01 lateral at 9700' MD and will be drilled to a planned TD of 10600' MD in the Kuparuk A4 In map-view this proposed lateral will look very similar to what the AOGCC has already authorized, and formation pressures are expected to be similar to what has already been drilled and to what was submitted in the original drilling permit. A written drilling V v permit will be submitted to the AOGCC within 3 calendar days. Nabors CDR2-AC expects to spud the 1G-05L1-02 lateral on 10/8/15 Thanks much for your help. Please contact me if you have any questions or concerns. <image001.png> Jason Burke CID Engineer- Greater.%uparuk Area 700 G St#1210 anchorage,ax 99501 (n):(907)-265-6097 (M):(907)-231-4568 Jason.Burke@conocophillips.com fb OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME: i<11A)- 1 G -oS1.j -02 PTD: SIS - /n Development , Service Exploratory Stratigraphic Test _Non-Conventional FIELD: 47364 R ULJ POOL: fG.rJ. 4�/E tI /441't ICU 0/ Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER ULTI The permit is for a new wellbore segment of existing well Permit i/VALATERAL No. / 3—Q O , API No. 50-OM -2 a 9 0 -00 - 00. (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 • • N CO N o;12 a), „ „ t, , , „ a , N C 0 U ' o � �� a) - Co C, O z c,C E' a a) 4 �. W Oc 'co o c. m O o v as co 0) C, p O) a 3 a, p v C, 0) -I, a) 'O, 3, � o 0 0 E, O , N a), co a O, c 7, -, W, o _ gyE o v, a N', , '-, p, (a , 0 J c .�, a) . C' �, , O, t>, a CO c, 3, >o' E 8' L''' y, SIcv I ' N, > N, • °? 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