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215-223
• tilkii STATE OF ALASKA ALADA OIL AND GAS CONSERVATION COMOION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate E Pull Tubing r Operations shutdown r Performed. Suspend r Perforate r Other StimulateAlter Casing 9 r Change Approved Program r Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: PROD to WAG f;,•- 2. ✓2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r 215-223-0 3.Address: g p r Service 6.API Number: P. O. Box 100360, Anchorage, Alaska 99510 strati ra hic50-029-21664-61 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25512 _ KRU 3Q-13L1-01 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 10457 feet Plugs(measured) None true vertical 6287 feet Junk(measured) None Effective Depth measured 10457 feet Packer(measured) 7566 true vertical 6287 feet (true vertical) 6114 Casing Length Size MD TVD Burst Collapse L1-01 SLOTTED LINER 1702' 2 3/8 10457' 6291' Perforation depth: Measured depth: 8755-10457 SEP 13 2016 True Vertical Depth: 6291-6287 AOGCC Tubing(size,grade,MD,and TVD) 3 1/2 ,L-80, 7681 MD, 6200 TVD Packers&SSSV(type,MD,and TVD) SSSV=None PACKER=BAKER 7"26#F-1 PACKER @ 7566 MD and 6114 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 156 1221 694 1050 185 Subsequent to operation 0 0 4514 550 1096 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 1 Exploratory r Development r Service 170 Stratigraphic r Copies of Logs and Surveys Run 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG ' 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: 316-419 Contact Darrell Humphrey/Bob Christensen Email: n1139@Conocophillips.Com Printed Name Darrell Humphrey Title: NSK Production Engineering Specialist Signature Phone:659-7535 Date VT-I- tc/�/14 ote (°X44 Form 10-404 Revised 5/2015 Submit Original Only RBDMS l-- SEP 1 3 2016 • 4. • 3Q-13L1-01 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/03/16 Well converted to injection and brought online . \ i KUP PROD 0 3Q-13L1-01 ConocoPhillips I Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status Incl 7) MD(ftKB) Act Btm(ftKB) 9Upe 500292166461 KUPARUK RIVER UNIT PROD 99.52 9,700.07 10,457.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 30-13Lr-01,2/420169:26.15 AM SSSV' NONE Last WO: 42.51 12/10/1986 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ,,...,,_,,,.,_,.,,,.,,. Q� Last Tag' Rev Reason:ADD LATERALS;GLV C/O Iehallf 2/4/2016 RANGER 34.0 I`:i il' Casing Strings Casing Description 00(in) ID(in) Top(ft913) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread • L1-01 SLOTTED LINER 2 3/8 1.992 8,755.0 10,456.9 6,287.1 4.60 L-80• STL Liner Details Nominal ID Top(ftKB) Top(TVD)(1190) Top Incl 7) Item Des Com (in) ,� 8,755.0 6,291.0 92.47 BILLET Aluminum Liner Top Billet 1.000 I Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shots/f CONDUCTOR;38.0-115.0-9- Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 8,778.0 10,456.0 6,290.3 6,287.2 A-1,30-13 1/16/2016 SLOTS Notes:General&Safety GAS LIFT;2,690.8 End Date Annotation INOTE: I a�9 OSW Tubing Shut Off;3.509.3 SURFACE;37.0-4,325.3 L GAS LIFT;4,323.6 GAS LIFT,5,551.5 GAS LIFT;6,401.9 GAS LIFT;7,062.8 • I I a GAS LIFT;7,502.4 Il LOCATOR;7,563.2 PACKER;7,565.7 SEAL ASSY;7,564.0, - a PBR;7,569.1 1 9 NIPPLE;7,606.1 at XO Enlarging;7,680.5 .. t Liner;7,681.2 Liner;7,725.6 ill APERF;7,743.0-7,755.0 I 111 — PRODUCTION;34.0-8,168.8 SLOTS;7,743.0-10,546.0 Ll-02 SLOTTED LINER;7,742.2 -10,552.0 le Lf SLOTTED LINER;9,010.0- 10,537.0 SLOTS;8,778.0-10,456.0 L1-01 SLOTTED LINER;8,755,0 -10,456.9 411111 OF Tit \�\�y/��,vA THE STATE Alaska Oil and Gas ti�` 7� ofLASKA Conservati®n Commission Wiwi* 333 West Seventh Avenue ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 �-- Main: 907.279.1433 A ;9Fax: 907.276.7542 www.aogcc.alaska.gov Darrell Humphrey SCANNED JAS 1 2 2D17 NSK Production Engineering Specialist ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3Q-13L1-01 Permit to Drill Number: 215-223 Sundry Number: 316-421 Dear Mr. Humphrey: 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, ag Cathy 7 Foerster Chair DATED this // day of August, 2016. RBDMS VU AUG 1 6 2016 [ . RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AUG 1 1 2016 APPLICATION FOR SUNDRY APPROVALS 07-3 cref/( .�!r.6 / 20 AAC 25.280 +°-�`°^° 1.Type of Request: Abandon r Plug Perforations r Fracture Stimulate r Repair Well r Operations shutdown r Suspend r Perforate r Other Stimulate E Pull Tubing r Change Approved Program r Rug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing 1 Other: PROD to WAG l✓ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development R. • 215-223-0 ' 3.Address: r 6.API Number: `" Stratigraphic Service P. O. Box 100360, Anchorage, Alaska 99510 50-029-21664-61 i 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA Will planned perforations require spacing exception? Yes r No Fi KRU 3Q-13L1-01 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25512 • 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): 10457 • 6287 . 10457'' 6287' • 3000 None None Casing Length Size MD TVD Burst Collapse L1-01 SLOTTED LINER 1702' 2 3/8 10457' 6291' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8755-10457 ' 6291-6287 31/2 L-80 7681 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) SSSV=None MD=0 TVD=0 PACKER=BAKER 7"26#F-1 PACKER MD=7566 TVD=6114 12.Attachments: Proposal Summary Fi WellBore Schematic r 13. Well Class after proposed work: Detailed Operations Program E BOP Sketch r Exploratory r Stratigraphic r Development r Service r i 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations: 09/10/16 OIL r WINJ r WDSPL r Suspended "' 16.Verbal Approval: Date: GAS r WAG GSTOR r SPLUG r— Commission Representative: GINJ fl Op Shutdown r Abandoned fl 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact: Darrell Humphrey/Bob Christensen Printed Name Darrell Humphrey Phone:659-7535 Email: n1139@conocophillips.com Title: NSK Production Engineering Specialist Signature Date: t o- Ib Commission se Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3\Lk.— L{ 2t Rug Integrity r BOP Test r Mechanical Integrity Test Location Clearance r Other: 4,k lot lo Post Initial Injection MIT Req'd? Yes V No j"" a Spacing Exception Required? Yes r No I Subsequent Form Required: '0 —L} (J'J APPROVED BY Approved by: p 26..e.,,,,h_____ COMMISSIONER THE COMMISSION Date: 8/6 lL �1 13/ 1--'IS• VTL e it 57 Liz, die ��(4 Submit Form and Form 10-403 Revised 11/2015 OlvIcI,PIcrin, ./alid for 12 months from the date of approval. Attachments in Duplicate RBDMS CA— AUG 1 6 2016 • • 3Q-13L1-01 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert Kuparuk Well 3Q-13 and it's associated laterals L1, L1- 01, L1-02 (PTD# 186-176, 215-221, 215-223, 215-224) from Oil Production service to Water Alternating Gas Injection service as the production period for this well has been completed. Area of Review: Kuparuk well 3Q-13 and it's associated laterals was completed as an injector on 7/25/16 to provide enhanced recovery injection into the reservoir to increase the ultimate recovery of oil. This well will support existing producers 3Q-07, 3Q-09 and 3Q-11. The top of the A sand was found at 9010' and/6302'tvd Area Map with 1/4 mile radius around target injection zone (see attached): The map attached shows that with the exception of the offset producers 3Q-07 and 3M-13, there are no additional production/injection wells are located within a 1/4 mile radius of the 3Q-13, 3Q-13L1, 3Q-13L1-01, 3Q-13L1-02 penetrations of the Kuparuk interval. Mechanical Condition of Well to be Converted: The mechanical condition of Kuparuk well 3Q-13 and it associated laterals is good and is classified as a"CTD horizontal tri-lateral"well. The injection tubing/casing annulus is isolated via a Baker 7"26# F-1 packer located at 7565' and (6114' tvd). A State-witnessed MIT-IA will be performed once well 3Q-13 and it's associated laterals are converted to water injection, online, and stabilized. CBL and interpretation of the cement quality: The intermediate casing CBL indicates sufficient formation bond (6450' -8169' and/5287' -6567' tvd)to insure injection zone conformance. The CBL interpretation was completed on the PTD's. The 16" Conductor was cemented with 1875# Polyset. The 9-5/8" Surface casing was cemented with 1200sx ASIII and 300sx Class G. The 7" Intermediate casing was cemented with 300sx Class G and 175sx AS1. r' ' ' H <d a5 W71-6 ``17tjzc ✓ ! • -R&/1V..1 — S// //$ ,3 a o0 0 o-- o m Trn a -2o o Q o A ,1 Vi <,`',i mo '^ m`o w J m : 2 a N d N t E < < < E H 0 o on oe oa u n o O u u u F>, d u E $ $ o "' vm a Vy rt `°E m r• °m r 59 a L" fc "SE. n r^1 .° o r Ta @s Y mE _ E E E O we i o 7 m ti N �O �O �O O O R O g O No71 p g O c T c G O0 rp O O O O u 6 O 6 m m U U U H O_ C - w c iO C C C O E 01 w a s e a 6 n 0 ro z z c m Ea w u c J - o u u 3 -o __ a) 0 , a-- co ca 0 a) Q E - " u O o f A'0 C,_ '-Ca'' H zin 6 t" *a 73 c a g 7s a o- '" 18 n_ H O m a -'o -'o v' i a` a` a en en P.;Z o 3 1 0 0 Q am o 0 0 0 °1 2 00 ' c F'. o w m c n • .TiTo To o F o \ Li' a Q \ \ a0 uti o 73 r g F 0 N LI- 7"1 L h Q O rill 2 n .i vf�� a o nn E < a E 0 U U U Fi V m :''F,',' m G @! n O j. o • E. 2) 6 a E o °b o °a o °b o r o 0 0 77 o n Ck\-- V r u-.F... V r O OO u `,9-' U . 0 o V ,',1 W, o n Ti .O O CO O ] G a,' a.0 d n V W E•E` E u u u / c w 9 W i2. r a/ . . J M LL. o o r O E v V G H co) iA W S " Q 0 g N 7 O m Q ' t0 b 9 5 O 1.9 ti K,' N C O m a o n w m `o a H r Q 9 H O a m Z O dEj rn 3 0 o El t'' 0 2n m §a • • 29Jul16 ConocoPhillips • Alaska, Inc. Injection Swap Analysis N 3Q-13 et al 0 0.08 0.16 0.24 0.32 Miles 3Q 0 17 T � •E ADL025512 3Q-13 / ‘41/1/1/13Q-13L1PB1 ADL0255'3 3Q-07 3Q 13L1 ' 3Q-13L1-01 3Q-13L1-02 3M-13 3Q-22 3Q-13 Open Interval 1/4 Mi. Radius 3Q-13 3Q-13L1 Open Interval 1/4 Mi. Radius 3Q-13L1 — 3Q-13L1PB1 Open Interval !,_. 1/4 Mi. Radius 3Q-13L1PB1 ADL025520 —3Q-13L1-01 Open Interval 1/4 Mi. Radius 3Q-13L1-01 _025521 3Q-13L1-02 Open Interval 1/4 Mi. Radius 3Q-13L1-02 _ � I_ Cl NIA° Well Within Radius Well Pad J=LJ p • 09Aug16 • ConocoPhillips Alaska, Inc. Injection Swap Analysis N 3Q-13 et al 0 0.08 0.16 0.24 0.32 Miles 3Q 0 17 T /D(L125512 M IP 3Q-13 Q ADL0255'3 �v! 3Q-13L1 PB1 3Q-07 - 4/1•//////„/ 21 • Yr 0 19 3Q 3L1 30-13L1-01 3Q-13L1-02 .4111M-1'3,........_____ 3Q-13 Open Interval 7 1/4 Mi. Radius 3Q-13 3Q-13L1 Open Interval 1/4 Mi. Radius 3Q-13L1 —3Q-13L1PB1 Open Interval 0 1/4 Mi. Radius 3Q-13L1PB1 ADL025520 --3Q-13L1-01 Open Interval 01/4 Mi. Radius 3Q-13L1-01 _025521 3Q-13L1-02 Open Interval 0 1/4 Mi. Radius 3Q-13L1-02 Well Within Radius Well Pad • ' ` KUP PROD • 3Q-13L1-01 , ConocoPhillips OrA \ Well Attributes Max Angle&MD TD Alaska.Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°I MD(ftKB) Act Btm(ftKB) pR 500292166461 KUPARUK RIVER UNIT PROD 99.52 9,700.07 10,457.0 CcrocciPhil••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 30-13Lt-01,2/4/2016 926 15 AM SSSV:NONE Last WO 42.51 12/10/1986 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ...........................................;34.0_. Last Tag: Rev Reason'ADD LATERALS:GLV C/O lehallf 2/4/2016 HANGER:34.0 it 41 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TOO)... WI/Len(I...Grade Top Thread L1-01 SLOTTED LINER 2 3/8 1.992 8,755.0 10,456.9 6,287.1 4.60 L-80 STL Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(1) Item Des Com (in) Rpm8,755.0 6,291.0 92.47 BILLET Aluminum Liner Top Billet 1.000 Perforations&Slots Shot Dens Top(ND) Btm(TOD) (shotslf CONDUCTOR;38.0-115.0 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 8,778.0 10,456.0 6,290.3 6,287.2 A-1,3Q-13 1/16/2016 SLOTS aNotes:General&Safety GAS LIFT;2,690.8 – End Date Annotation NOTE OSTV Tubing Shut Off;3,509.3 Rill a SURFACE;37B-43253-------- ._. GAS LIFT;4,323.6 GAS LIFT;5551.5 GAS LIFT;0401.9 GAS LIFT;7062.6 GAS LIFT;7002.4 LOCATOR;7,563.2 I PACKER;7,565.7lit.,,, SEAL ASSY;7,564.0-. PBR;7.569.1 `!_' NIPPLE;7,606.1 ' a a XO Enlarging;7,680.5 7 ` Liner;7081.2 Liner;7,725.6 APERF;7,743.0-7,755.0— •,. r PRODUCTION;34.0-0,168.8 — SLOTS;7.743.0-10.546.0— ' t L1-02 SLOTTED LINER;7,742.2 -10,552.0 L1 SLOTTED LINER;9010.0- 10,537.0 SLOTS;8,778.0-10456.0 L1-01 SLOTTED LINER;8,755.0 -10,456.9 • • ,,,,s ,.,,,,_ AD c • o moO • N o E E -0 • 31 • J Wc m m a Q • 1CO 0 V N N Z 1 1 Ts N a) OCO ' J J C J J S a) a) >' C ` �co , N }I m > > C'") c c it U) c c 0 > D - p 9 co (n (a 7 it it co it Il (/) (n co (n > > (n ❑ M 0051 ❑ ❑ j m 2 Z ° H 2 2i_ 2 2 ►- 0 0 _c > > p a) l (1)(1) LU W Z N to l() N in Lo W W LL U) (/) Z > On �O O -' O C) O O C) O O O O O F- (p at) J J Q. 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QO CO11' Y m c a ilk. a a • o �,' z o • 0 a 0 m 0 m b M o E 1 co z fa cn I 1 CD ns co lb cc • oo0 O N C Q N N N W w0 6 ,5,0 wN, I Z '' O co (0 �, m m i as E Ca QN c o 0 0 0 o J E G M O) co co W O O w W Q >. I m N ~ ao 0o co ao co co c w E a I O d r N N N N N N N W p FO- N N N r c E0E Z Oa �, = °i 111 m G !I M l6 R F l9 1 V d Z 0 O o Q o 5 Z o co co 0 U O U U U U U o 2 m '7 m N •Q CU •m v 0 FE a 7 o a n m o E a �O E IIIo 0 0 rn — ° E o o a E 0 cn E E Q Z — a � w w w w w � a' U a � i v U � � V v RECEIVEl < < l ` 1 i `V 115224 w�11 FEB 122016 26817 16818 2 19 26820 BAKER PRINT DISTRIBUTION LIST HUGHES AG Please sign and return one copy of this transmittal form to: COMPANY ConocoPhillips Alaska,Inc. ConocoPhillips Alaska, Inc. Ricky Elgarico.ATO 3-334. DATA LOGGED WELL NAME 3Q-13L1; L1-Ol;L1-02; L1PB1 700 G Street. 2/2.5/20.16 M.K.BENDER Anchorage,Alaska 99510 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE GR-RES BHI DISTRICT Alaska LOG DATE January 19,2016 AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider(cr�bakerhughes.corn TODAYS DATE February 10,2016 Revision STATUS Final Replacement: No Details: Requested by: --- COMPANY FIELD FINAL CD CD ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS (digital/image) Surveys (Finall Surveys) PERSON ATTENTION #OF PRINTS #01-i'NIN 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 TATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska 10 I 0 I 0 Attn:Lynda M.Yaskell and/or Leonardo Elias 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC 1 I 1 1 Attn:Makana Bender '333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 0 I 1 I 1 I I 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. 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N- (ND V V CO CO N O O 0, V r` 4N') CO M M CO n (VO CVD Q C a 0 0 N O M (0 CD 6 V 6 6 6 N N (N N (0 N ' 2. d . .°.r N N ON N N N N N N N N N N N N N N N N (N VI E - - 8 no LL g M M M N (0 O N N- ti N M N O ((pp V N O V M c Q Q r• r r O N O N- (0 V N O N V M N N V O M N O O O i 0 0 0 0 0 0 c ` NN m (N (N co co co m m NN cN m co rn 0) 0) m 0) 0) (N r O 0) (' O S NO N N (0 N) N O V 0 O (N 0r- 0 V VNN- O O N O CO Cp6 7Nr O O M O t,z(,); N OM iN0 [ CS (N 0 O O CO r N N N CO M V 3 <� N SO O O O O co CL 9)O n '(u G 'LSt rrrrrrrrrrrrrrrr 6. V E ` � vom n a co C3 c • • ' . • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil 0 • Gas[0 SPLUG El Other ❑ Abandoned ❑ Suspended 0 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development E Exploratory D GINJ 0 WINJ E WAGE WDSPL❑ No. of Completions: Service 0 Stratigraphic Test 0 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. _ Aband.: 1/20/2016 215-223 • 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510 1/13/2016 50-029-21664-61 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 2283'FNL,2037'FEL, Sec. 17,T13N, R9E, UM 1/16/2016 3Q-13L1-01 Top of Productive Interval: 9. Ref Elevations: KB: 60' 17. Field/Pool(s): 1573'FNL,4013'FEL, Sec 20,T13N, R9E, UM GL: 42' BF: 42' Kuparuk River Field/Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 2917'FNL, 5025'FEL, Sec 20,T13N, R9E, UM N/A ADL 25512 4b. Location of Well(State Base Plane Coordinates, NAD 27). 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 516300 y- 6025789 Zone- 4 10,457'MD/6,287'TVD ALK 2553 TPI: x- 514348 y- 6021215 Zone- 4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 513343 y- 6019870 Zone- 4 N/A 1658'MD/1604'TVD 5. Directional or Inclination Survey: Yes (attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 9,010'MD/6,301'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 itECEIVEL GR/RES FEB 10 2016 23. CASING, LINER AND CEMENTING RECORD ®GCC WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 62.5 H-40 38 115 38 115 24" 1875#Polyset 9-5/8" 36 J-55 37 4325 37 3713 12-1/4" 1200 sx ASIII&300 sx Class G 7" 26 J-55 34 8168 34 6567 8-1/2" 300 sx Class G&175 sx ASI 5-1/2" 14 H-40 7681 7768 6200 6234 N/A KO joint 2-3/8" 4.6 L-80 8755 10457 6291 6287 3.25" Slotted Liner 24. Open to production or injection? Yes Ei No El 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" 7681' 7565'MD/6114'TVD Slotted Liner from 8755'-10457'MD/6291'-6287'TVD 26.ACID, FRACTURE, CEMENT SQUEEZE, ETC. COMPLETION Was hydraulic fracturing used during completion? Yes E No E DATE Per 20 AAC 25.283(i)(2)attach electronic and printed information t(t0ItLO DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED VERIFIED 0- 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 2/1/2016 Gas Lifted Date of Test: Hours Tested-i., Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 2/3/2016 1 0 1. Test Period 73 281 752 176/176 3861 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 287 1171 24-Hour Rate 230 887 2376 21.7 Form 10-407 R"e/zz1/1c sed 11/2015 vn_ Z t CONTINUED ON PAGE 2 Submit ORIGINIAL only., I � q/G� 40,7*j5 RBDMS U-- FEB 1 0 2016 28.CORE DATA Conventional Os): Yes ❑ No ❑ Sidewall Coree'es ❑ No ❑ If Yes, list formations and intervals cored(MD/TVD, From/To), and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑✓ Permafrost-Top surface surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1658' 1604' Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 8755' 6291' information, including reports,per 20 AAC 25.071. Top Kuparuk Al 9010' TD Kuparuk Al 10457' Formation at total depth: Kuparuk Al 31. List of Attachments: 5UMMAel 047 "VA IIy OR .14 16,115/ 17E1."f4t//T,✓E l 14twb4Tr__ 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.Burke@cop.co 4� 4 _ Printed Name: K.Starck Title: CTD Team Lead Signature: / Phone: 263-4093 Date: 7 — " ?()/6 ` INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class-Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection, Salt Water Disposal,Water Supply for Injection, Observation, or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 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 PROD 3Q-13 ICOt1QCoPtilIp5 & Vg s Well Attrib Max AngD TD Alaska Ir�.l.. Wellbore API/UWI Field Name Wellbore Status ncl(^) MD( ) Act Btm(ftKB) Conocx"raltps 500292166400 KUPARUK RIVER UNIT PROD 44.68 3,100.00 8,190.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3Q-13,2/9/20162:53.23 PM SSSV:NONE _ Last WO: 42.51 12/10/1986 VarWalncbemaec.(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date L Last Tag:SLM 7,954.0 12/13/2015 Rev Reason:ADD LATERALS; GLV C/0 lehallf 2/4/2016 HANGER;34.0 krill tl a Is ng Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 H-40 Welded Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE 95/8 8.765 37.0 4,325.3 3,713.6 36.00 J-55 BTC Casing Description OD(in) 'ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(ND)...'Wt/Len(I...Grade Top Thread ' 1m.. ,1„' t PRODUCTION 7 6.276 34.0 8,168.8 6,567.2 26.00 J-55 BTC Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..)Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection Mf TUBING UPPER 31/2 2.992 34.0 7,585.0 6,128.7 9.30 L-80 EUE 8rd W0 2015 CONDUCTOR;38.0-115.0 ► Completion Details ftKB To Nominal ID Top(ftKB) p(TVD)(ftKB) Top Incl(°) Item Des Com (in) 34.0 34.0 0.19 HANGER CIW tubing hanger 3.500 GAS LIFT;2,890.8 7,563.2 6,112.5 41.81 LOCATOR Baker GBH-22 locator sub 3.000 IL 7,564.0 6,113.1 41.81 SEAL ASSY Baker GBH-22 Seal assembly W/7 ft out 3.000 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING LOWER- 31/2 2.992 7,565.8 7,770.0 6,267.3 9.30 L-80 EUE 8rd W 0 2015 CSTV Tubing Shut O8;3509.3 F3';; '. Completion Details Nominal ID Top(ftKB) Top(TVD)(ft613) Top Incl(°) Item Des Com (in) 7,565.8 6,114.4 41.80 PACKER Baker 7"26#F-1 Packer 4.600 7,569.1 6,116.8 41.77 PBR Baker 80/40 PBR 3.990 •• 7,606.1 6,144.5 41.54 NIPPLE 3.5 X 2.813 X nipple 2.813 7,680.5 6,200.3 41.45 XO Enlarging 3.5"8rd X 5.5"H-40 Ported sub 2.992 7,681.2 6,200.7 41.45 Liner 5.5"X 14#H-40 Wear sox with 5 15/16"wear rings 5.000 SURFACE;31.04,325.3- �_;, ` 7,725.6 6,234.0 41.43 Liner 5.5"X 14#H-40 Wear sox with 5 15/16wear rings Mule 5.000 GAS LIFT;a,323.6 " 9 shoe Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ft6131 (ftKB) CI Des Com Run Date ID(in) 7,745.0 6,248.6 41.43 WHIPSTOCK BAKER GEN II WHIPSTOCK 2 5/8"X 5.5" 12/30/3015 GAS LIFT;5,551.5 Perforations&Slots snot Den Top(TVD) Btm(TVD) (shots/ Top(ftKB) Btm(ft613) (ftKB) (ftKB) Zone Date ft) Type Coin 7.743.0 7.755.0 6,247.1 6,256.1 A-3,3Q-13 8/4/2000 4.0 APERF 2 1/8"Enerjet;180 deg GAS LIFT;8,401.9 phasing;+/-90 degs f/low side. II 7,760.0 7,784.0 6,259.8 6,277.8 A-2,3Q-13 3/26/2000 4.0 RPERF 2 1/8"EJ III DP;+/-90 deg orient II 7,790.0- 7,828.0 6,282.3 6,310.8 A-1,3Q-13 3/26/2000 - 4.0 RPERF 2 1/8"EJ III DP;+/-90 GAS LIFT 7,062.6 deg orient Mandrel Inserts St ati on Top(TVD) Valve Latch Port Size TRO Run ti Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com GAS LIFT,7,502 1 2,690.8 2,508.0 Camco MMG 11/2 GAS LIFT GLV RK 0.188 1,249.0 1/28/2016 2 4,323.7 3,712.4 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,247.0 1/28/2016 Mr EM 3 5,551.5 4,617.7 Camco MMG 1 1/2'GAS LIFT OV RK 0.250 0.0 1/28/2016 ill 4 6,401.9 5,252.2 Camco MMG - 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/22/2015 LOCATOR,7,563.2 5 7,062.6 5,741.3 Camco MMG - 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/22/2015 rte' 6 7,502.4 6,067.3Camco 'MMG 1 1/2 GAS LIFT DMY RKP 0.000 0.0 12/10/2015 PACKER;7,565.7 SEAL ASSY,7,564.0 PBR;7,569.1 1'�' Notes:General&Safety ' End Date Annotation 2/27/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 it11/22/2015 NOTE:Orbit Valve is NOT a safety valve,it does not fail to closed positionalli . 11/22/2015 NOTE:Orbit Valve Control lines/system at Wellhead marked Open/Close NIPPLE;7,006.1 XO Enlarging;7,880.5 Lire,7,681.2 _, Liner;7,7256 RPERF;7,743.0-7,755.0T'T SLOTS;7,743.0-10,5460 i 1 L1-02 SLOTTED LINER;7,742.2 I i -10,552.0 RPERF;7,780.0-7,784.0 : RPERF;7,790.0-7,828.0- PRODUCTION;34.0-8,186.8 l Dag KUP jOD 3Q-13L1-01 CC311QCC� 111l1�35 •>a. s Well AttribMax AngD TD Alaska Inc, Wellbore API/UWI Field Name Wellbore Status ncl(°) MD( ) Act Btm(ftKB) Ganoc60h81.ps 500292166461 KUPARUK RIVER UNIT PROD 99.52 9,700.07 10,457.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 30-13L1-01,2/9/20162:51:40 PM SSSV: NONE Last WO: 42.51 12/10/1986 Verheal schematc I ' Last Taw Rev Reason-ADD2/4/2016 ,,H Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;34.0 l:,„I,ai rings Casing Description OD(in) ID(in) Top(fIKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread 1 r 1 10,45660 :1 STL ELiner Details Nominal ID `^� _ ^r ^ Top(ftKB) Top(ND)(ftKB)I Top Incl(°) Item Des Com (in) 8,755.0 6,291.0 92.47 BILLET Aluminum Liner Top Billet 1.000 11 I Perforations&Slots • Shot Dens CONDUCTOR;38.0-115.0 Top(TVD) Btm(TVD) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 8,778.0 10,456.0 6,290.3 6,287.2 A-1,30-13 1/16/2016 SLOTS Notes:General&Safety GAS LIFT,2,690.8 End Date Annotation NOTE. 11, OSTV Tubing Shut Off;3,509.3 r.::' 11 SURFACE;37.0-4,325.3 {,, L GAS LIFT;4,323.6 N. III GAS LIFT;5,551.5 GAS LIFT;6,401.9 : I GAS LIFT,7,0626 ,4 GAS LIFT;7,5024 LOCATOR;7,563.2 PACKER;7,565.7 j SEAL ASSY;7,564.0` a PBR;7,569.1 u NIPPLE;7606.1 AO Enlarging;7,680.5 Al Liner,7,681.2 Liner,7,725.6 APERF;7,743.0-7,7550 I ,, PRODUCTION;34.0-8,168.8 ( ' '..11yl Efo-. SLOTS;7,743.0-10,548.0 L1-02 SLOTTED LINER;7,742.2 -10,552.0 I I Y L1 SLOTTED LINER;9,010.0. 1, E 10,537.0 T SLOTS;8,778.0-10,456.0 7 L1-01 SLOTTED LINER;8,755.0 , -10,456.9 ` •erations Summary (with Timelogths) 44',, ,..3Q-13 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) 1/4/2016 1/4/2016 0.50 MIRU MOVE MOB P Prep for rig move to 3Q-pad.Load and 0.0 0.0 00:00 00:30 secure tree.check all tree bolts,and complete RD checklist,Prep shop for move.Prep for sow arrival. 1/4/2016 1/4/2016 2.50 MIRU MOVE MOB P PJSM,with Peak and rig crew. Pull rig 0.0 0.0 00:30 03:00 modules off of 3Q-13,install jeeps, ready to move. 1/4/2016 1/4/2016 2.50 MIRU MOVE MOB P Move rig modules and shop to 3Q-pad 0.0 0.0 03:00 05:30 1/4/2016 1/4/2016 1.50 MIRU MOVE MOB P Remove jeeps,prep well,remove tree 0.0 0.0 05:30 07:00 caps,spot rig modules over well. 1/4/2016 1/4/2016 1.50 MIRU MOVE MOB T Rig won't clear well 22,inform rig prep 0.0 0.0 07:00 08:30 crew,dispatch crane to remove well house on well 14,move well house on 22 over 1 ft.Finish spotting over well 13. 1/4/2016 1/4/2016 3.50 MIRU MOVE MOB P Finish spotting rig modules over well 0.0 08:30 12:00 13. 1/4/2016 1/4/2016 2.50 MIRU MOVE MOB P MIRU,CDR2,RU checklist,check tree 0.0 0.0 12:00 14:30 flange bolts,Work on tree alignment, clean and reinstall drip pan,MU MP and cellar lines. 1/4/2016 1/4/2016 1.50 MIRU WHDBOP NUND P ***"Rig Accept: 14:30 hrs on 1/4/16 0.0 14:30 16:00 1/4/2016 1/4/2016 2.00 MIRU WHDBOP NUND P PJSM,Nipple up BOPE stack 0.0 0.0 16:00 18:00 1/4/2016 1/5/2016 6.00 MIRU WHDBOP BOPE P Start full BORE Test.Test witness by 0.0 0.0 18:00 00:00 Brian Bixby,AOGCC 1/5/2016 1/5/2016 3.50 MIRU WHDBOP BOPE P Continue full BOPE test,3 failures 0.0 0.0 00:00 03:30 Blind Shears,R1 valve,and door seal. Replaced and tested. 1/5/2016 1/5/2016 2.50 MIRU WHDBOP RGRP T Replace BOPE Upper shear seals 0.0 0.0 03:30 06:00 1/5/2016 1/5/2016 1.75 MIRU WHDBOP MPSP P PJSM,with rig and valve shop,load 0.0 0.0 06:00 07:45 lubricator and equipment to rig floor, pulled BPV,LD equipment. 1/5/2016 1/5/2016 4.60 MIRU WHDBOP CTOP P PJSM.Rehead coil and pull test. 0.0 0.0 07:45 12:21 Install UQC,and test.Install nozzle, MU QTS and stab on,fill coil,chase methanol to TT. 1/5/2016 1/5/2016 2.70-MIRU WHDBOP PRTS P PT inner reel iron and pack-offs. Install 0.0 0.0 12:21 15:03 floats and PT.PT PDL's. 1/5/2016 1/5/2016 1.80 MIRU WHDBOP CTOP P PJSM.Make several attempts to 0.0 0.0 15:03 16:51 perform closure test on Baker Orbit valve,able to bleed off wellhead,but will not hold.Perforn Valve alignment and prep for pressure deployment. Orbit valve now holding 1/5/2016 1/5/2016 2.60 PROD1 WHPST PULD P M/U BHA#1 Window milling BHA 0.0 74.3 16:51 19:27 with.6°motor,2.79 String Ramer, 2.80 Dimond window mill,Make up to coil and surface test.Position reel to tighten-inspect inner reel iron.Pump meth out of TT 1/5/2016 1/5/2016 1.80 PROD1 WHPST TRIP P RIH BHA#1 EDC open.Pumping 1 74.3 7,560.0 19:27 21:15 BPM seawater 1/5/2016 1/5/2016 0.30 PROD1 WHPST DLOG P Log K1 for+5.5',PUW=30K 7,560.0 7,598.0 21:15 21:33 Page 1/13 Report Printed: 2/2/2016 4 x *orations Summary (with Timelog pths) 3Q-13 t '4,,,,m,01 ConocoPhiilips , Ai1.5AS 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) 1/5/2016 1/5/2016 0.10 PROD1 WHPST TRIP P Continue in well,dry tag whipstock 7,598.0 7,751.0 21:33 21:39 pinch point @ 7750,PUH 1/5/2016 1/5/2016 1.35 PROD1 WHPST CIRC P Displace system to 9.3PPG used flow 7,751.0 7,751.0 21:39 23:00 pro to mill window. Close EDC 1/5/2016 1/6/2016 1.00 PROD1 WHPST WPST P Bring pumps up to 1.47 BPM.3756 psi 7,751.0 7,751.0 23:00 00:00 FS. Begin milling the window per the program.Motor work=125 psi with 500lbs WOB. 1/6/2016 1/6/2016 11.00 PROD1 WHPST WPST P Continue milling the window per the 7,751.0 7,757.0 00:00 11:00 drilling program.Out of casing© 7,756',continue milling to 7,757'. 1/6/2016 1/6/2016 3.20 PROD1 WHPST WPST P Mill rathole: 1.52 BPM @ 3,730 PSI, 7,757.0 7,770.0 11:00 14:12 BHP=3,840,CTW=8.5K,WOB=2K, ROP=4.Lost pump three times,had to pick-up, PUW=31 K,breaker issue, problem resolved. 1/6/2016 1/6/2016 2.10 PROD1 WHPST REAM P Make back reaming passes as per 7,770.0 7,770.0 14:12 16:18 well plan,dress window.Dry drift, clean.Jet 5.5"BTP. 1/6/2016 1/6/2016 2.70 PROD1 WHPST TRIP P POOH for build assembly.Open EDC 7,770.0 72.0 16:18 19:00 and jet Baker Orbit valve @ 3,509'. Continue out of the hole. Shut Orbit valve,and observe well.Static. 1/6/2016 1/6/2016 0.75 PROD1 WHPST PULD P LD BHA#1. Window mill 2.79"no go. 72.0 0.0 19:00 19:45 1/6/2016 1/6/2016 1.00 PROD1 DRILL PULD P PU build BHA#2,with 2.5°AKO motor 0.0 72.0 19:45 20:45 and HCC 3.25"short shank bit.Hang off in WH. Injector maintenance,check pack-offs. 1/6/2016 1/6/2016 0.50 PROD1 DRILL PULD P MU QC,stab on WH. Test MWD. 72.0 72.0 20:45 21:15 Equalize pressure above the Orbit valve and open. 1/6/2016 1/6/2016 1.75 PROD1 DRILL TRIP P RIH with Build BHA#2. Tie into the 72.0 7,760.0 21:15 23:00 K1 for a+4.5 ft correction.Continue RIH. 1/6/2016 1/6/2016 0.25 PROD1 DRILL TRIP P Set down at 7760 ft. PUH,roll pumps 7,760.0 7,770.0 23:00 23:15 and RBIH.Slight bobble runnig back though. Continue running in the hole. 1/6/2016 1/7/2016 0.75 PROD1 DRILL DRLG P On bottom.Begin drilling build section 7,770.0 7,788.0 23:15 00:00 from 7770 ft to midnight depth of 7788 ft. 1/7/2016 1/7/2016 2.00 PROD1 DRILL DRLG P Continue drilling build section from 7,788.0 7,872.0 00:00 02:00 7788 ft to end of section at 7872 ft. Pumping 1.5 BPM at 2942 psi FS. 3870 psi BHP. 164 psi WHP.Swap mud to 9.5 PPG PWR PRO,New mud @ bit 7793. Ave 43.6°DLS over build interval. 1/7/2016 1/7/2016 2.00 PROD1 DRILL TRIP P POOH with build BHA#2.Cycle orbit 7,872.0 72.0 02:00 04:00 valve closed. Valve appears to be leaking.Cycle valve open and closed again.WHP still increasing. 1/7/2016 1/7/2016 3.00 PROD1 DRILL TRIP T Run back in hole to jet Orbit valve 72.0 4,000.0 04:00 07:00 area through the EDC several times. 1/7/2016 1/7/2016 0.75 PROD1 DRILL TRIP T POOH. Make several attempt for 4,000.0 72.2 07:00 07:45 closure test on Orbit valve,all failed. Page 2/13 Report Printed: 2/2/2016 *orations Summary (with Timelog•pths) rf < 3Q-13 ConocoPhillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Stan Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/7/2016 1/7/2016 2.25 PROD1 DRILL PULD P PJSM.PUD BHA#2,make another 72.2 0.0 07:45 10:00 attempt to closure test Orbit valve, failed. 1/7/2016 1/7/2016 1.50 PROD1 DRILL PULD P PJSM.PD BHA#3,open Orbit valve. 0.0 72.0 10:00 11:30 1/7/2016 1/7/2016 2.50 PROD1 DRILL TRIP P RIH w/lateral drilling assembly,+0.5 72.0 7,872.0 11:30 14:00 AKO HCC bit,tie-in K1 for+2.5' correction,continue in hole,log RA @ 7,752'.Mad pass 7,871'to 7,777'. RBIH. 1/7/2016 1/7/2016 5.00 PROD1 DRILL DRLG P BOBD:1.50 BPM @ 3,290 PSI, 7,872.0 8,180.0 14:00 19:00 BHP=3,900 PSI,CTW=8 klbs- 10.5klbs,WOB=1.5K,ROP=45. 1/7/2016 1/7/2016 1.00 PROD1 DRILL WPRT P Wiper trip to 7800 ft.PUW=31 klbs. 8,180.0 8,180.0 19:00 20:00 1/7/2016 1/8/2016 4.00 PROD1 DRILL DRLG P Back on bottom drilling. 1.6 BPM at 8,180.0 8,445.0 20:00 00:00 3390 psi FS.BHP=3880 psi. 1.5-2 klbs WOB.CTW=8 klbs.ROP=70 fph.At 8350 add.5%776 due to less then exspected surface weight. Observed no appriciable increase in surface weight.No problems with weight transfer 1/8/2016 1/8/2016 6.00 PROD1 DRILL DRLG P Conintue drilling L1 lateral.Pumping 8,445.0 8,580.0 00:00 06:00 1.6 BPM at 3390 psi FS.BHP=3900 psi.CTW=6 klbs,WOB=2-3 klbs. ROP 10-20 fph. 1/8/2016 1/8/2016 0.50 PROD1 DRILL WPRT P Wiper trip to 7,780',PUW=30K,RBIH. 8,580.0 8,580.0 06:00 06:30 1/8/2016 1/8/2016 5.00 PROD1 DRILL DRLG P BOBD: 1.62 BPM @ 3,610, 8,580.0 8,625.0 06:30 11:30 BHP=3,900,CTW=7K,WOB=1.8K, ROP=10.Drilling for data.Town called,time to plug back,pump sweep. 1/8/2016 1/8/2016 2.25 PROD1 STK TRIP T POOH for plug back assembly,jet 5.5" 8,625.0 72.0 11:30 13:45 BTP,continue OOH.Small jog at surface,more solids in returns, POOH. 1/8/2016 1/8/2016 1.25 PROD1 STK PULD T PJSM.PUD BHA#3 72.0 0.0 13:45 15:00 1/8/2016 1/8/2016 1.50 PROD1 STK PULD T PJSM.MU Anchored billet, PD BHA 0.0 73.5 15:00 16:30 #4 1/8/2016 1/8/2016 2.50 PROD1 STK TRIP T RIH w/OH anchored billet,tie-in at K1 73.5 8,160.0 16:30 19:00 for+2 ft correction. 1/8/2016 1/8/2016 0.25 PROD1 STK WPST T Pick up to set depth.27klbs PUW.Set 8,160.0 8,150.0 19:00 19:15 anchor and release running tool.Top of billet at 8150 ft. 1/8/2016 1/8/2016 2.00 PROD1 STK TRIP T POOH with running tool BHA#4. 8,150.0 72.0 19:15 21:15 Jetted around orbit valve area through EDC before continuing out of the hole. 1/8/2016 1/8/2016 0.25 PROD1 STK TRIP T Closed Orbit valve with 800 psi WHP. 72.0 72.0 21:15 21:30 Bled WHP down to 500 psi and shut in. WHP slowly increasing.Bleed additonal 300 psi and shut in. WHP climbing. Orbit valve not holding pressure. Prepare to PUD. 1/8/2016 1/8/2016 1.50 PROD1 STK PULD T PJSM.PUD running tool BHA#4. 72.0 0.0 21:30 23:00 Page 3/13 Report Printed: 2/2/2016 4 ° i •erations Summary (with Timelog,ths) tst to �� A 3Q-13 Conochifliips 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) 1/8/2016 1/9/2016 1.00 PROD1 STK PULD T PJSM. PD lateral BHA#5 with 0.7°+ 0.0 0.0 23:00 00:00 AKO motor and RR HCC 3.25"bit. 1/9/2016 1/9/2016 0.50 PROD1 STK PULD T Finish PD lateral BHA#5.Begin RIH. 0.0 72.0 00:00 00:30 1/9/2016 1/9/2016 1.00 PROD1 STK TRIP T RIH with lateral BHA#5.Tie in to K1 72.0 8,150.0 00:30 01:30 for a+2.5 ft correction.Continue RIH and dry tag billet at 8150.9 ft. 1/9/2016 . 1/9/2016 2.95 PROD1 STK KOST T Time mill off of billet. 1.65 BPM at 8,150.0 7,158.0 01:30 04:27 3508 psi FS.700-1000 lbs WOB.Off billet. 1/9/2016 1/9/2016 1.75 PROD1 DRILL DRLG T Drill ahead. 1.64 BPM @ 3,670,BHP= 7,158.0 8,255.0 04:27 06:12 3910 PSI,CTW=10.5K,WOB=1K, ROP=60. 1/9/2016 1/9/2016 0.25 PROD1 DRILL TRIP T PUW=30K,dry drift billet,billet clean, 8,255.0 8,255.0 06:12 06:27 RBIH. 1/9/2016 1/9/2016 6.75 PROD1 DRILL DRLG T Drill ahead. 1.64 BPM @ 3,652,BHP= 8,255.0 8,560.0 06:27 13:12 3940 PSI,CTW=10.5K,WOB=1K, ROP=30. 1/9/2016 1/9/2016 0.80 PROD1 DRILL WPRT T Wiper trip,PUW=30K,RBIH. 8,560.0 8,560.0 13:12 14:00 1/9/2016 1/9/2016 3.00 PROD1 DRILL DRLG T Drill ahead. 1.64 BPM @ 3,725,BHP= 8,560.0 8,625.0 14:00 17:00 3930 PSI,CTW=7.5K,WOB=1.5K, ROP=35.Off trouble time. 1/9/2016 1/9/2016 3.50 PROD1 DRILL DRLG P Drill ahead.1.64 BPM @ 3,770,BHP= 8,625.0 8,716.0 17:00 20:30 3935 PSI,CTW=8.5K,WOB=1.5K, ROP=30. ROP dropping to<20 fph.Suspect bit balling. Pump 5/10 low/high vis pill followed by 20bbl screenkleen pill. 1/9/2016 1/9/2016 0.25 PROD1 DRILL CIRC P Pick up and work pipe off bottom 8,716.0 8,716.0 20:30 20:45 at1.75 BPM to try and clear bit. 1/9/2016 1/10/2016 3.25 PROD1 DRILL CIRC P Back on bottom drilling.ROP up to 45 8,716.0 8,841.0 20:45 00:00 FPH.Pumping 1.64 GPM at 3553 psi FS.BHP=3930 psi.CTW=9KIbs,WOB =1.5-2Klbs. ROP continues to be variable depending on formation. Note:Choke B showed signs of plugging.Switch to Choke A.Blow down Choke B. :ine back up on Choke B. 1/10/2016 1/10/2016 3.00 PROD1 DRILL DRLG P Continue drilling L1 lateral.Pumping 8,841.0 8,912.0 00:00 03:00 1.68 BPM at 3684 psi FS.BHP=3940 psi.CTW=7 klbs,WOB=1.7 klbs. ROP betweenl5 fph and 50 fph depending on formation.Start mud swap. 1/10/2016 1/10/2016 0.50 PROD1 DRILL DRLG P Geo wiper to ft. RBIH,new mud at bit 8,912.0 8,912.0 03:00 03:30 at 8912 ft. 1/10/2016 1/10/2016 0.50 PROD1 DRILL DRLG P Continue drilling L1 lateral.Pumping 8,912.0 8,925.0 03:30 04:00 1.7 PM at 3720 psi FS.BHP=3925 psi.CTW=7.8 Klbs,WOB=2 klbs. ROP=80 fph. 1/10/2016 1/10/2016 0.60 PROD1 DRILL WPRT P Choke B appears to have packed off. 8,925.0 8,925.0 04:00 04:36 Trouble shoot same.Pull off bottom to clear, RBIH to pull wiper from 8905 Page 4/13 Report Printed: 2/2/2016 Iterations Summary (with Timeloglpths) m- 3Q-13 Conoco �t itlips A[,.s 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) 1/10/2016 1/10/2016 2.35 PROD1 DRILL WPRT P 8905,Pull wiper to window, 8,925.0 8,925.0 04:36 06:57 PUW=29K,tie-in for+1'correction, • resolve choke issues,recalibrate choke.RBIH. 1/10/2016 1/10/2016 2.50 PROD1 DRILL DRLG P Drill ahead: 1.63 BPM @ 3,650 PSI, 8,925.0 9,075.0 06:57 09:27 BHP=3,950 PSI,CTW=6.5K, WOB=1.7K,ROP=40.Multiple wipers, drilling break,stacking,trouble getting started,increase Safe lube.5%to 1.5%. 1/10/2016 1/10/2016 1.00 PROD1 DRILL WPRT P Wiper to 8,300',PUW=32K, RBIH. 9,075.0 9,075.0 09:27 10:27 Lost 3K CTW through silt zone. 1/10/2016 1/10/2016 6.55 PROD1 DRILL DRLG P Drill ahead: 1.60 BPM @ 3,550 PSI, 9,075.0 9,192.0 10:27 17:00 BHP=3,960 PSI,CTW=-2.5K, WOB=1.5K,ROP=20.Multiple wipers, stacking,weight transfer issues, pumped 5 X5 sweeps couple times, gain additional 50'each time. 1/10/2016 1/10/2016 1.00 PROD1 DRILL WPRT P Wiper to 8,300',PUW=31K,add.5% 9,192.0 9,192.0 17:00 18:00 776 to mud system. CTW down to-5KIbs while tripping back through the lower Al silt. Regained weight after exiting that interval. 1/10/2016 1/10/2016 3.50 PROD1 DRILL DRLG P Continue drilling L1 lateral.Pumping 9,192.0 9,315.0 18:00 21:30 1.67 BPM at 3450 psi FS.CTW 7 Klbs. WOB 1.5 Klbs.ROP variable depending on formation,5-40 fph. 1/10/2016 1/10/2016 0.75 PROD1 DRILL DRLG P Continue drilling L1 lateral. Losing 9,315.0 9,322.0 21:30 22:15 CTW and weight transfer to the bit. Pull 3 BHA wipers in an attempt to make it drill. 1/10/2016 1/11/2016 1.75 PROD1 DRILL WPRT P Made decsion to pull wiper and jet big 9,322.0 9,322.0 22:15 00:00 tail pipe area. Begin wiper trip to 7,690 ft. No overpulls coming up through the lower Al silt.Saw an increase in cuttings from the BTP area. RBIH and tie-in to RA for a+3 ft correction.No drag observed on the way back to bottom.Hole is in good shape. 1/11/2016 1/11/2016 0.25 PROD1 DRILL WPRT P Finish wiper trip. 9,322.0 9,322.0 00:00 00:15 1/11/2016 1/11/2016 3.75 PROD1 DRILL DRLG P BOBD.Pumping 1.62 BPM at 3608 9,322.0 9,520.0 00:15 04:00 psi FS.BHP=3933 psi.CTW=8 Klbs,WOB=1.55 Klbs,ROP=30-60 fph 1/11/2016 1/11/2016 1.00 PROD1 DRILL WPRT P Wiper trip.PUW=29 Klbs.RBIH. 9,520.0 9,520.0 04:00 05:00 1/11/2016 1/11/2016 3.35 PROD1 DRILL DRLG P BOBD. Pumping 1.64 BPM at 3630 9,520.0 9,700.0 05:00 08:21 psi FS.BHP=3985 psi.CTW=2 Klbs,WOB=1.8 Klbs,ROP=60-80 fph.Couple of mini wipers,pump 5 x 5 sweeps,losing weight transfer. 1/11/2016 1/11/2016 2.25 PROD1 DRILL WPRT P Wiper for tie-in, PUW=30K,jet 5.5" 9,700.0 9,700.0 08:21 10:36 BTP,log RA for+2'correction,RBIH. 1/11/2016 1/11/2016 3.75 PROD1 DRILL DRLG P BOBD. Pumping 1.66 BPM at 3630 9,700.0 9,915.0 10:36 14:21 psi FS. BHP=3975 psi.CTW=4 Klbs,WOB=2.2 Klbs,ROP=60-80 fph,losing weight transfer again. Page 5/13 Report Printed: 2/2/2016 liberations Summary (with Timelog ths) ,� ►tee, Oig 3Q-13 Conoc hiHlips 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) 1/11/2016 1/11/2016 0.65 PROD1 DRILL WPRT P Wiper to 8,900',PUW=30K,RBIH. 9,915.0 9,915.0 14:21 15:00 1/11/2016 1/11/2016 0.75 PROD1 DRILL DRLG P BOBD.Pumping 1.64 BPM at 3,630 9,915.0 9,985.0 15:00 15:45 psi FS.BHP=3995 psi.CTW=-2 Klbs,WOB=1.7 Klbs,ROP=30.Did not gain much with that wiper,pump sweep,wait on sweep,continue drilling.Mini wiper @ 9,985'. 1/11/2016 1/11/2016 2.00 PROD1 DRILL DRLG P BOBD.Pumping 1.64 BPM at 3,630 9,985.0 9,999.0 15:45 17:45 psi FS.BHP=3995 psi.CTW=-2 Klbs,WOB=1.3 Klbs.Stacking weight.PU and restart.Try reducing pump rate to 1.5 bpm. 1/11/2016 1/11/2016 0.50 PROD1 DRILL CIRC P Pump 5/5 sweep. 9,999.0 9,999.0 17:45 18:15 1/11/2016 1/11/2016 0.75 PROD1 DRILL DRLG P BOBD.Pumping 1.64 BPM at 3,630 9,999.0 10,025.0 18:15 19:00 psi FS.BHP=3995 psi.CTW=-3 Klbs,WOB=1.8 Klbs.Stacking weight.PU and restart.Try reducing pump rate to 1.5 bpm. 1/11/2016 1/11/2016 2.50 PROD1 DRILL WPRT P Pump 5/5 sweep. Wiper trip to the 10,025.0 10,025.0 19:00 21:30 window.Pull into pipe with minimum rate through the window.Jet BTP. RBIH,tie into RA for+2 ft correction. 1/11/2016 1/12/2016 2.50 PROD1 DRILL DRLG P BOBD.Pumping 1.62 BPM at 3618 10,025.0 10,124.0 21:30 00:00 psi FS.BHP 4000 psi.CTW between- 5 and+3 Klbs.WOB between 0 and 1.9 klbs.Variable ROP. Difficult drilling conditions.Multiple pick ups and mini wipers to try and get drilling and improve weight transfer. Prepare for mud swap. 1/12/2016 1/12/2016 3.00 PROD1 DRILL DRLG P Continue drilling L1 lateral.Pumping 10,124.0 10,180.0 00:00 03:00 1.62 BPM at 3620 psi FS.BHP 3990 psi.CTW between-5 and+3 Klbs. WOB between 0 and 1.9 klbs. Variable ROP. Still having weight transfer issues. New mud at the bit at 10,167 ft (02:15).No improvement in weight transfer. 1/12/2016 1/12/2016 2.00 PROD1 DRILL WPRT P Pull wiper to 8,200 ft.No increase in 10,180.0 10,180.0 03:00 05:00 cutttings. Clean trip in and out of the hole.Hole appears to be in good condition. 1/12/2016 1/12/2016 2.95 PROD1 DRILL DRLG P BOBD:1.63 BPM @ 3,925 PSI, 10,180.0 10,351.0 05:00 07:57 BHP=3,990 PSI,CTW=7K, WOB=1.8K,ROP=70.Lost push. 1/12/2016 1/12/2016 1.50 PROD1 DRILL WPRT P Wiper to 8,250',PUW=28K,RBIH. 10,351.0 10,351.0 07:57 09:27 1/12/2016 1/12/2016 3.00 PROD1 DRILL DRLG P BOBD.Trouble getting started, 10,351.0 10,450.0 09:27 12:27 several mini wipers,pumped 5X5 sweeps,stacking ,try reduced pump rate,no luck,perform 500'wiper,no help. 100'in 3 HRS. 1/12/2016 1/12/2016 2.55 PROD1 DRILL WPRT P Wiper to jet BTP, PUW=28K,clean 10,450.0 10,450.0 12:27 15:00 5.5"BTP,log RA tie-in for+2' correction,RBIH. Page 6/13 Report Printed: 2/2/2016 aerations Summary (with Timelogpths) It t e , 3Q-13 ConocoPhillips g{ 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) 1/12/2016 1/12/2016 2.25 PROD1 DRILL DRLG P BOBD: 1.63 BPM @ 3,915 PSI, 10,450.0 10,504.0 15:00 17:15 BHP=4,005 PSI,CTW=2-4K, WOB=1.8K,ROP=70.Start losing weight transfer @ 10,505,pump 10 bbl lube pill,try another 500'wiper, pump 20 lube pill. 1/12/2016 1/12/2016 2.25 PROD1 DRILL DRLG P BOBD.Pumping 1.3 bpm.3066 psi 10,504.0 10,537.0 17:15 19:30 FS.BHP 4000 psi.WOB 2.2 Klbs. Saw brief increase in ROP then began stacking again.Discussion with town.Called TD at 10537 ft. 1/12/2016 1/12/2016 3.00 PROD1 DRILL WPRT P Pump sweeps,begin wiper trip to the 10,537.0 72.0 19:30 22:30 swabs.Open EDC above window.No issues pulling out of the hole.Hole is clean. 1/12/2016 1/13/2016 1.50 PROD1 DRILL WPRT P Tag up.Reset depths.Run back in the 72.0 6,112.0 22:30 00:00 hole. 1/13/2016 1/13/2016 1.50 PROD1 DRILL WPRT P Continue running in the hole.Tie into 6,112.0 10,537.0 00:00 01:30 the K1 for a+5 ft correction.Close EDC above the window.No issues RIH.Hole is in good condition.Tag bottom.Confirm TD at 10,537 ft. 1/13/2016 1/13/2016 3.00 PROD1 DRILL DISP P Pull out of the hole laying in 45 10,537.0 72.0 01:30 04:30 bbls11.8 ppg liner running pill followed by 11.8 ppg NaBr completion fluid. Paint window and TD EOP flags. 1/13/2016 1/13/2016 0.50 PROD1 DRILL OWFF P Flow check 72.0 72.0 04:30 05:00 1/13/2016 1/13/2016 2.50 PROD1 DRILL PULD P PJSM.LD BHA#5,prep floor for 72.0 0.0 05:00 07:30 function test.Function test BOP. 1/13/2016 1/13/2016 4.05 COMPZ1 CASING PUTB P PJSM.MU L1 liner assembly,bull 0.0 1,590.0 07:30 11:33 nose,52 jts slotted,one solid pup,OH anchored billet.MU BHA#6. 1/13/2016 1/13/2016 3.65 COMPZ1 CASING RUNL P RIH w/liner assembly,tie-in flag for 1,590.0 10,536.0 11:33 15:12 -.5 correction,weight above window, PUW=31K,saw 5K bobble @ 7,782', sounded like injector chain slipped, inspected coil,excessive lube on coil, check pack-offs,replace pack-off, pressure washed chains.Continue in hole,no issues to TD @ 10,536', PUW=33K,set back down,PU to 30K, pressure up 4,200 psi,release from liner,TOL depth @ 9,009',PUW=30K. Reset depth. 1/13/2016 1/13/2016 1.75 COMPZ1 CASING TRIP P POOH for drilling assembly 10,536.0 70.0 15:12 16:57 1/13/2016 1/13/2016 0.55 COMPZ1 CASING OWFF P Flow check. Well is static. 70.0 70.0 16:57 17:30 1/13/2016 1/13/2016 1.00 COMPZ1 CASING PULD P PJSM.LD Liner running BHA#6 70.0 0.0 17:30 18:30 1/13/2016 1/13/2016 1.25 PROD2 STK PULD P PJSM,PU lateral drilling BHA#7 with 0.0 72.0 18:30 19:45 0.7°AKO motor and new HYC 3.25" bit. MU QC.Test MWD,tag,set depth, open EDC and RIH. 1/13/2016 1/13/2016 2.50 PROD2 STK TRIP P RIH with BHA#7.Tie in to K1 for a 72.0 9,010.0 19:45 22:15 +2.5 ft correction.Close EDC.No issues through window. Dry tag billet at 9010 ft. Page 7/13 Report Printed: 2/2/2016 aerations Summary (with Timelog laths) �VV„v" £ - 3Q-13 Coinoc hillips 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) 1/13/2016 1/13/2016 0.75 PROD2 STK DISP P Displace 11.8 ppg NaBr completion 9,010.0 9,010.0 22:15 23:00 fluid with 9.5 ppg PowerPro drilling mud. 1/13/2016 1/14/2016 1.00 PROD2 STK KOST P Tag and begin time milling off of billet. 9,010.0 9,010.0 23:00 00:00 Pumping 1.59 BPM at 3761 psi FS. 1/14/2016 1/14/2016 2.00 PROD2 STK KOST P Continue time milling off of billet at 1.5 9,010.0 9,020.0 00:00 02:00 fph,working up to 2 fph.Lost prime on charge pump.PU,regain pump rate, RBIH.1 stall. Restart time milling at 2 fph increasing to 3 fph. Control drill with lklbs WOB to 9020 ft. 1/14/2016 1/14/2016 0.75 PROD2 DRILL DRLG P Continue drilling pumping 1.53 BPM at 9,020.0 9,060.0 02:00 02:45 3850 psi FS. 1.5 klbs WOB. 1/14/2016 1/14/2016 0.25 PROD2 DRILL DRLG P Dry drift billet at 25 fpm.Clean.RBIH. 9,060.0 9,060.0 02:45 03:00 1/14/2016 1/14/2016 2.50 PROD2 DRILL DRLG P Continue drilling the L1-01 lateral. 9,060.0 9,220.0 03:00 05:30 1.57 BPM at 3580 psi FS. 1.8 klbs WOB.ROP 50-70 fph. 1/14/2016 1/14/2016 1.75 PROD2 DRILL WPRT . P Wiper trip,PUW=29K, RBIH. 9,220.0 9,220.0 05:30 07:15 1/14/2016 1/14/2016 5.90 PROD2 DRILL DRLG P Drill ahead: 1.55 BPM @ 3,560 PSI, 9,220.0 9,427.0 07:15 13:09 BHP=3,925 PSI,CTW=1OK, WOB=1.5K,ROP=35.Trouble getting bit to drop,several restarts,try back reaming,couple drilling breaks,trying to acquire bottom of Al pay. 1/14/2016 1/14/2016 1.85 PROD2 DRILL WPRT P Wiper for tie-in,PUW=31K,Clean 5.5" 9,427.0 9,427.0 13:09 15:00 BTP,log RA for+1'correction,RBIH. - 1/14/2016 1/14/2016 0.50 PROD2 DRILL DRLG P Drill ahead:1.58 BPM @ 3,560 PSI, 9,427.0 9,437.0 15:00 15:30 BHP=3,975 PSI,CTW=10K, WOB=1.8K,ROP=60-90.GEO quit trying to get drop. 1/14/2016 1/14/2016 2.75 PROD2 DRILL DRLG P Drill ahead: 1.58 BPM @ 3,560 PSI, 9,437.0 9,601.0 15:30 18:15 BHP=3,925 PSI,CTW=10K, WOB=1.5K,ROP=35.Starting to stack weight. 1/14/2016 1/14/2016 0.50 PROD2 DRILL WPRT P Pump 5/5 sweep and pull 500 ft wiper 9,601.0 9,601.0 18:15 18:45 to improve weight transfer.Observed increase in cuttings come up with sweep. 1/14/2016 1/14/2016 3.50 PROD2 DRILL DRLG P Drill ahead:1.56 BPM @ 3,495 PSI, 9,601.0 9,753.0 18:45 22:15 BHP=3,950 PSI,CTW=6-10K, WOB=1.5K,ROP=35-40. Erratic ROP.Trouble bringing inclination down. 1/14/2016 1/14/2016 0.75 PROD2 DRILL WPRT P Pull 500 ft wiper.Lost comms with 9,753.0 9,753.0 22:15 23:00 MWD. Reboot MWD system. • Continued wiper trip keeping BHA below any jewelry using Academy screen for depth control.No issues with reset.Re-established comms with MWD.RBIH. 1/14/2016 1/15/2016 1.00 PROD2 DRILL DRLG P Drill ahead: 1.57 BPM @ 3,536 PSI, 9,753.0 9,798.0 23:00 00:00 BHP=3,920 PSI,CTW=8.4K, WOB=1.5K,ROP=60 fph. Page 8/13 Report Printed: 2/2/2016 aerations Summary (with Timelog Ibths) 4 4444-444 ;44 4444, 3Q-13 conocciphimps 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) 1/15/2016 1/15/2016 0.50 PROD2 DRILL DRLG P Drill ahead: 1.57 BPM @ 3,536 PSI, 9,798.0 9,801.0 00:00 00:30 BHP=3,920 PSI,CTW=1.7K, WOB=2K,ROP=10 fph.Observed increase in vibration. 1/15/2016 1/15/2016 2.00 PROD2 DRILL WPRT P Pull wiper to the BTP and clean out 5- 9,801.0 9,801.0 00:30 02:30 1/2".PUW=35 KIbs.Tie in to the RA for a+2 foot correction and confirmed depth after MWD reboot yesterday. 1/15/2016. 1/15/2016 5.75 PROD2 DRILL DRLG P Drill ahead: 1.54 BPM @ 3,532 PSI, 9,801.0 10,003.0 02:30 08:15 BHP=3,965 PSI,CTW=8K, Vary WOB to try and get BHA to drop. Mini wiper,pump 5 x5 sweeps,BHA wiper,several restarts. 1/15/2016 1/15/2016 0.70 PROD2 DRILL WPRT P Wiper trip to 9,100',PUW=35K,RBIH. 10,003.0 10,003.0 08:15 08:57 1/15/2016 1/15/2016 3.25 PROD2 DRILL DRLG P Drill ahead: 1.55 BPM @ 3,955 PSI, 10,003.0 10,220.0 08:57 12:12 BHP=4,005 PSI,CTW=7K, WOB=1.6K, ROP=60-80.Start pumping new mud system,at bit @ 10,036'. 1/15/2016 1/15/2016 2.20 PROD2 DRILL WPRT P Wiper for tie-in,PUW=30K,clean 5.5" 10,220.0 10,220.0 12:12 14:24 BTP,log RA for+3'correction,RBIH. 1/15/2016 1/15/2016 3.10 PROD2 DRILL DRLG P Drill ahead: 1.57 BPM @ 3,980 PSI, 10,220.0 10,420.0 14:24 17:30 BHP=4,010 PSI,CTW=7.5K, WOB=2K,ROP=70-90. Mini wiper at 10,297 ft. Started stacking weight.Could not restart. Pump 5/5 sweep. 1/15/2016 1/15/2016 0.50 PROD2 DRILL WPRT P Pull 1,000 ft wiper to improve weight 10,420.0 10,420.0 17:30 18:00 transfer.PUW 28KIbs. 1/15/2016 1/15/2016 1.25 PROD2 DRILL DRLG P Drill ahead: 1.54 BPM @ 3,850 PSI, 10,420.0 10,457.0 18:00 19:15 BHP=4,000 PSI,CTW=7K,WOB=2K, ROP=70-90. Attempt to PU and restart.CT would not go up or down.Appears to be differentially stuck.Begin working pipe. 1/15/2016 1/15/2016 1.25 PROD2 DRILL DRLG T Worked pipe up to 42KIbs max.No 10,457.0 10,457.0 19:15 20:30 WOB change.Orients freely.Full returns.Lower annular pressure 150 psi to 11.4 ppgemw.Continue to work pipe with max PU of 52KIbs.Stop pump,relax CT and continue to work pipe with no success. 1/15/2016 1/15/2016 2.50 PROD2 DRILL CIRC T Pump 5/5 sweep and prepare to pump 10,457.0 10,457.0 20:30 23:00 mineral oil pill.Saw an increase in cuttings with 5/5 sweep at surface. Continued to work pipe while loading pill pit with 15 bbls of mineral oil. 1/15/2016 1/15/2016 0.50 PROD2 DRILL CIRC T Pump 14 bbls of mineral oil into the 10,457.0 10,457.0 23:00 23:30 OH annulus,underdisplacing leaving 2 bbls in the CT.Push 3-5KIbs down on CT below normal SO weight.CTW= 7Klbs. As mineral oil turned the corner,WOB began to increase from 100Ibs to 400Ibs. PU CT and broke over at 32KIbs.CT free. Page 9/13 Report Printed: 2/2/2016 d s aerations Summary (with Timelog ths) 21,V 'dam a �< 3Q-13 ConocoPhillips % Al xka 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) 1/15/2016 1/16/2016 0.50 PROD2 DRILL WPRT T With pipe free,pull wiper to the big tail 10,457.0 10,457.0 23:30 00:00 pipe. 1/16/2016 1/16/2016 1.50 PROD2 DRILL DRLG P Continue wiper trip to the window.Jog 10,457.0 10,450.0 00:00 01:30 5-1/2"casing.Tie into RA for a+3 ft correction.RBIH to 10450 ft. A sample from the shakers from the build section,showed thin steel shavings.Pictures in the well file. 1/16/2016 1/16/2016 3.50 PROD2 DRILL WPRT P From 10,450 ft,pump 10/10 sweep 10,450.0 72.0 01:30 05:00 and begin chasing to the swab valves. 1/16/2016 1/16/2016 2.90 PROD2 DRILL TRIP P Tag up and reset depths.Run back in 72.0 ' 10,450.0 05:00 07:54 the hole,tie-in K1 for+2.5'correction, continue in hole. 1/16/2016 1/16/2016 3.45 PROD2 DRILL CIRC P POOH laying in liner pill/completion 10,450.0 73.0 07:54 11:21 fluid,paint EOP flags @ 8,706'& 5,900',continue OOH. 1/16/2016 1/16/2016 0.50 PROD2 DRILL OWFF P Flow check,no flow. 73.0 73.0 11:21 11:51 1/16/2016 1/16/2016 0.90 PROD2 DRILL PULD P PJSM. LD BHA#7,bit had one 73.0 0.0 11:51 12:45 chipped tooth and some balling. 1/16/2016 1/16/2016 0.65 COMPZ2 CASING PUTB P Prep floor to run liner 0.0 0.0 12:45 13:24 1/16/2016 1/16/2016 3.60 COMPZ2 CASING PUTB P PJSM.MU L1-01 Liner assembly,bull 0.0 1,745.0 13:24 17:00 nose,58 jts slotted,two pups,billet. MU BHA#8 1/16/2016 1/16/2016 3.00 COMPZ2 CASING RUNL P RIH w/liner assembly.Stop at pipe 1,745.0 10,457.0 17:00 20:00 flag for a minus 1 ft correction. Suspect that is incorrect.Tie in to K1 on the fly for a+2 ft correction.Tag bottom on depth at 10,457 ft.Weight check,PUW=36 Klbs.Release liner on bottom.PUW=32 Klbs.Continue POOH. 1/16/2016 1/16/2016 1.50 COMPZ2 CASING TRIP P POOH with liner running BHA#8. 10,457.0 72.0 20:00 21:30 1/16/2016 1/16/2016 0.50 COMPZ2 CASING OWFF P Flow check well.Static. 72.0 72.0 21:30 22:00 1/16/2016 1/16/2016 0.50 COMPZ2 CASING PULD P PJSM,LD liner running BHA#8.Prep 72.0 0.0 22:00 22:30 for BOP Test. 1/16/2016 1/17/2016 1.50 PROD3 WHDBOP BOPE Remove checks from UQC,install 0.0 0.0 22:30 00:00 nozzle,stab WH. Line up and flush stack and lines. Swap coil to fresh water. 1/17/2016 1/17/2016 1.50 PROD3 WHDBOP BOPE P Line up and test Inner-reel valve and 0.0 0.0 00:00 01:30 stripper. Unstab,remove nozzle and QTS. Skid. Install Night cap,fluid pack lines. 1/17/2016 1/17/2016 10.50 PROD3 WHDBOP BOPE P Continue testing BOPE.250/4500 psi, 0.0 0.0 01:30 12:00 annular 2500 psi.BOP test waived by AOGCC(Chuck Scheve). 1/17/2016 1/17/2016 1.50 PROD3 STK -CIRC P Move cart,install nozzle,swap coil 0.0 0.0 12:00 13:30 back to KWF.Check for flow. 1/17/2016 1/17/2016 1.00 PROD3 'STK PULD P PJSM.MU BHA#9,surface test,open 0.0 72.5 13:30 14:30 EDC Page 10/13 Report Printed: 2/2/2016 ' & •erations Summary (with Timelog laths) i 3Q-13 ConocoPhiflips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(EKE) 1/17/2016 1/17/2016 2.50 PROD3 STK TRIP P RIH w/drilling assembly, .7 AKO 72.5 8,754.0 14:30 17:00 motor,3"Hughes bit,pumping forward,tie-in for+1'correction, continue in hole,dry tag billet @ 8,754'. 1/17/2016 1/17/2016 0.75 PROD3 STK DISP = P Circulate hole back to drilling mud. 8,754.0 8,754.0 17:00 17:45 RIH and dry tag billet. PU,bring pumps up,and RIH.Begin time drilling billet. 1/17/2016 1/17/2016 4.25 PROD3 STK KOST P Time drilling billet at 1.51 BPM 13KIbs 8,754.0 8,785.0 17:45 22:00 CTW,and 0.5Klbs WOB.Observed 4 motor stalls while trying to get kicked off the billet.Drilled to 8785. 1/17/2016 1/18/2016 2.00 PROD3 DRILL DRLG P Dry drift billet area.Clean drift up and 8,785.0 8,862.0 22:00 00:00 down.Continue drilling the L1-02 lateral. 1.51 BPM @ 3535 PSI FS, BHP=3,930 PSI,CTW=11 K WOB=2.3K, ROP=50 FPH 1/18/2016 1/18/2016 3.00 PROD3 DRILL DRLG P Continue drilling the L1-02 lateral. 8,862.0 8,956.0 00:00 03:00 1.50 BPM @ 3380 PSI FS, BHP=3,930 PSI,CTW=9K dropping to 6K WOB=2.3K,ROP=50 FPH 1/18/2016 1/18/2016 0.75 PROD3 DRILL WPRT P Lower than expected surface weight. 8,956.0 8,956.0 03:00 . 03:45 Pump 5/5 sweep,pull wiper to the window chasing sweep. Substantial cuttings observed over the shakers as low vis and hi vis came to surface.RBIH from 7789 ft to Bottom. 1/18/2016 1/18/2016 5.40 PROD3 DRILL DRLG P Continue drilling the L1-02 lateral. 8,956.0 9,210.0 03:45 09:09 1.50 BPM @ 3330 PSI FS, BHP=3,920 PSI,CTW=Back up to 9K. WOB=1.8K,ROP=50 FPH 1/18/2016 1/18/2016 0.85 PROD3 DRILL WPRT P Wiper trip,PUW=28K,RBIH. 9,210.0 9,210.0 09:09 10:00 1/18/2016 1/18/2016 4.25 PROD3 DRILL DRLG P Drill ahead: 1.56 BPM @ 3,700 PSI, 9,210.0 9,460.0 10:00 14:15 BHP=3,950 PSI,CTW=9K,WOB=2K, ROP=60-80. 1/18/2016 1/18/2016 1.75 PROD3 DRILL WPRT P Wiper for tie-in, PUW=28K,clean 5.5" 9,460.0 9,460.0 14:15 16:00 BTP,tie-in for+2.5'correction, RBIH.Start pumping new mud system. 1/18/2016 1/18/2016 3.50 PROD3 DRILL DRLG P Drill ahead: 1.50 BPM @ 3,640 PSI, 9,460.0 9,712.0 16:00 19:30 BHP=3,940 PSI,CTW=9.1K, WOB=1.3K,ROP=70. New mud at bit at 9466 ft. 1/18/2016 1/18/2016 0.75 PROD3 DRILL DRLG P Wiper trip to 8800 ft.PUW=32 Klbs. 9,712.0 9,712.0 19:30 20:15 RBIH. 1/18/2016 1/19/2016 3.75 PROD3 DRILL DRLG P Drill ahead: 1.50 BPM @ 3,590 PSI, 9,712.0 9,960.0 20:15 00:00 BHP=4,000 PSI,CTW=9K, WOB=1.5K,ROP=80-100 FPH. 1/19/2016 1/19/2016 0.75 PROD3 DRILL WPRT P Wiper trip to 8800 ft. 9,960.0 9,960.0 00:00 00:45 1/19/2016 1/19/2016 2.00 PROD3 DRILL DRLG P Continue drilling the L1-02 lateral. 9,960.0 10,120.0 00:45 02:45 1.50 BPM @ 3630 PSI FS,BHP=4100 PSI,CTW=8K.WOB=1.5K,ROP=100 FPH Page 11/13 Report Printed: 2/2/2016 ext aerations Summary (with Timelog ths) - 3Q-13 Conoco hUUiiipos 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) 1/19/2016 1/19/2016 1.25 PROD3 DRILL WPRT T Lost some WITS data to BHI display. 10,120.0 10,120.0 02:45 04:00 HMI screen still displaying all drilling parameters. PUH to troubleshoot MWD computers/WITS feed.RBIH. 1/19/2016 1/19/2016 1.00 PROD3 DRILL DRLG Continue drilling L1-02 lateral.All 10,120.0 10,210.0 04:00 05:00 drilling parameters correctly displayed on HMI screen.BHI screen still missing some data but is displaying GR/RES data for steering. 1.50 BPM @ 3640 PSI FS,BHP=4100 PSI,CTW=8K.WOB=1.8K,ROP=50- 110 FPH 1/19/2016 1/19/2016 2.35 PROD3 DRILL WPRT P Wiper trip,PUW=29K,jet 5.5"BTP, 10,210.0 10,210.0 05:00 07:21 log RA for+4'correction,RBIH. 1/19/2016 1/19/2016 3.85 PROD3 DRILL DRLG P Drill ahead: 1.48 BPM @ 4,035 PSI, 10,210.0 10,460.0 07:21 11:12 BHP=4,005 PSI,CTW=8K, WOB=1.8K,ROP=90. 1/19/2016 1/19/2016 0.85 PROD3 DRILL WPRT P 10,460 ft.wiper up hole to 9,460 ft. 10,460.0 9,460.0 11:12 12:03 PUW 29k 1/19/2016 1/19/2016 0.50 PROD3 DRILL WPRT P 9,460 ft.wiper back in hole.RIW 10k 9,460.0 10,460.0 12:03 12:33 1/19/2016 1/19/2016 1.25 PROD3 DRILL DRLG P 10,460 ft.BOBD 1.6 bpm at 3736 psi. 10,460.0 10,550.0 12:33 13:48 FS,BHP 3997,WHP 150, IA 447,OA 375 1/19/2016 1/19/2016 2.85 PROD3 DRILL WPRT P 10,550 ft.TD L1-02 lateral,PUH,line 10,550.0 72.2 13:48 16:39 up and pump 10x10 sweep,wiper to the swab valve,jetting 5.5"BTP 1/19/2016 1/19/2016 3.20 PROD3 DRILL TRIP P Tag up and reset depths.RBIH,tie-in 72.2 10,552.0 16:39 19:51 at K1 for+2.5 ft. correction,continue in hole,confirm TD at 10,552 ft,Pump beaded liner pill. 1/19/2016 1/19/2016 2.70 PROD3 DRILL DISP P POOH laying in liner pill/completion 10,552.0 72.2 19:51 22:33 fluid,paint EOP flags at 7,600 ft.and 4,800 ft. 1/19/2016 1/19/2016 0.50 PROD3 DRILL OWFF P On surface,monitor well for flow.LD 72.2 72.2 22:33 23:03 BHA on dead well. 1/19/2016 1/19/2016 0.70 PROD3 DRILL PULD P LD BHA#9, bit condition 72.2 0.0 23:03 23:45 1/19/2016 1/20/2016 0.25 COMPZ3 CASING PUTB P Prep floors to run liner. 0.0 0.0 23:45 00:00 1/20/2016 1/20/2016 0.35 COMPZ3 CASING PUTB P Continue prep floors to run liner. 0.0 0.0 00:00 00:21 1/20/2016 1/20/2016 5.00 COMPZ3 CASING PUTB P PJSM-MU bull nose,pup jt,97 jts 0.0 2,809.8 00:21 05:21 slotted,shorty deployment sleeve. 1/20/2016 1/20/2016 1.25 COMPZ3 CASING PULD P PJSM-MU L1-02 liner assmbly to 2,809.8 2,854.1 05:21 06:36 BHA#10,MU to CoilTrak,surface test. 1/20/2016 1/20/2016 2.00 COMPZ3 CASING RUNL P RIH w/L1-02 slotted liner completion, 2,854.1 7,654.0 06:36 08:36 97 jts,shorty deployment,and non- ported bullnose. 1/20/2016 1/20/2016 0.25 COMPZ3 CASING RUNL P 7,654 ft.Correct to the EOP flag plus 7,654.0 7,654.0 08:36 08:51 0.4 ft.PUW 32k 1/20/2016 1/20/2016 1.00 COMPZ3 CASING RUNL P Continue RIH w/liner 7,654.0 10,345.0 08:51 09:51 1/20/2016 1/20/2016 0.25 COMPZ3 CASING RUNL P 10,345 ft.Tie into the K1 marker 10,345.0 10,552.0 09:51 10:06 correction of zero. Page 12/13 Report Printed: 2/2/2016 •erations Summary (with Timelog ths) ,t 3Q-13 ConocoPhilii ps , 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) 1/20/2016 1/20/2016 0.25 COMPZ3 CASING RUNL P 10,550 ft.PUW 34k,Set down 4k, 10,552.0 7,742.0 10:06 10:21 bring pump up 1.3 bpm at 4300 psi, 1.2 bpm returns,release liner,PUW 28k. 1/20/2016 1/20/2016 2.00 COMPZ3 CASING TRIP P 7,742 ft.Line up and displace well to 7,742.0 2,500.0 10:21 12:21 seawater,while POOH 1/20/2016 1/20/2016 1.50 COMPZ3 CASING FRZP P 2,500 ft.PJSM with rig crew and Little 2,500.0 44.2 12:21 13:51 Red Services,FP well with diesel. 1/20/2016 1/20/2016 1.50 COMPZ3 CASING PULD P At surface,PJSM,with rig team,PUD 44.2 0.0 13:51 15:21 and LD liner setting tools 1/20/2016 1/20/2016 4.65 DEMOB WHDBOP RURD P Install nozzle,stab INJH,and flush 0.0 0.0 15:21 20:00 surface lines with inhibitor.Blow down coil,surface lines and TT line. 1/20/2016 1/20/2016 2.50 DEMOB WHDBOP MPSP P Valve crew onsite,bring in lubricator 0.0 0.0 20:00 22:30 and equipment.PJSM-Lubricate in BPV,SITP 930 psi,rig down,off load lubricator and equipment. 1/20/2016 1/21/2016 1.50 DEMOB WHDBOP NUND P PJSM-ND BOPE Equipment.RD 0.0 0.0 . 22:30 00:00 cellar.Prep shop for move. Rig Release 00:00 on 01/21/2016 Page 13/13 Report Printed: 2/2/2016 S ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3Q Pad 3Q-13L1-01 50-029-21664-61 Baker Hughes INTEQ BAKER Definitive Survey Report HUGHES 20 January,2016 • • ConocoPhillips IrdriII ConocoPhillips Definitive Survey Report BAKERIHIUGHES Company: ConocoPhillips(Alaska)Inc-Kup2 Local Co-ordinate Reference: Well 3Q-13 l Project: Kuparuk River Unit TVD Reference: 3Q-13 @ 60.00usft(30-13) Site: Kuparuk 30 Pad MD Reference: 3Q-13(4)60 00usft(3Q-13) Welt: 30-13 North Reference: True Wellbore: 3Q-13 Survey Calculation Method: Minimum Curvature Design. 3Q-13 Database: EDM Alaska NSK Sandbox Project Kuparuk River Unit,North Slope Alaska,United States '_ Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point I'.Map Zone: Alaska Zone 04 Using geodetic scale factor r, Well 3Q-13 Well Position +Ni-S 0.00 usft Northing: 6,025,789.31 usft Latitude: 70°28'53.925 N p +El-W 0.00 usft Easting: 516,299.52usft Longitude: 149°52'0.528 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Weitbore 3Q-13L1-01 Magnetics Model Name Sample Date Declination - DipAngle Field Strength (°} t.(•) (nT) BGGM2015 3/1/2016 18.51 81.05 57,493 Design 3Q-13L1-01 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 8,990 50 Vertical *N!S +El-W Direction Section: Depth From(IVO) (usft) (usft) (u (°) 60.00 0 00 0 00 225 00 s Survey Program Date 1/20/2016 ' From To Survey Survey i (usft) (usft) Survey(Wellbore) Tool Name Description Start Date End Date ) 100.00 7,700.00 3Q-13(3Q-13) BOSS-GYRO Sperry-Sun BOSS gyro multishot 1/15/2001 t 7,745.00 8,140.90 3Q-13L1PB1(3Q-13L1PB1) MWD MWD-Standard 1/4/2016 1/8/2016 t 8,150.00 8,990.50 3Q-13L1(3Q-13L1) MWD MWD-Standard 1/9/2016 1/12/2016 t e 9,010.00 10,425.46 3Q-13L1-01(3Q-13L1-01) MWD MWD-Standard 1/13/2016 1/16/2016 : 1!20/2016 3:00:45PM Page 2 COMPASS 5000.1 Build 74 • . ConocoPhillips Ffil 01. ConocoPhillips Definitive Survey Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3Q-13 Project: Kuparuk River Unit TVD Reference: 3Q-13(g)60.00usft(30-13) Site: Kuparuk 3Q Pad MD Reference: 3Q-13 @ 60.00ustt(3Q-13) I'Well: 3Q-13 NOrth Reference: True €Wellbore: 3Q-13 Survey Calculation Method: Minimum Curvature Design: 3Q-13 Database: EDM Alaska NSK Sandbox Survey Map Map Vertical MD Inc ATI TVO TVDSS *NIS +E/-W Northing Fasting DLS Section Survey Tool Name Annotation (usft) (°) O (usft)I (usft) (usft) (usft). 1fti (ft) (°1100') (ft) 8,990 50 91.44 207.35 6,302.19 6,242.19 -4,752.27 -2,108.26 6,021,032.91 514,201.88 12.98 4,851.13 MWD(3) TIP 9,010.00 9246 204.19 6,301.53 6,241.53 -4,769.82 -2116.74 6,021,015.34 514,193.45 17.02 4,869.53 MWD(4) KOP i 9,040.87 87.21 204.90 6,301.62 6,241.62 -4,797.89 -2,129.55 6,020,987.25 514,180.69 17.16 4,898.44 MWD(4) 9,070.58 85.58 206.00 6,303.48 6,243.48 -4,824.66 -2142.30 6,020,960.45 514,168.01 6.61 4,926.38 MWD(4) 9,100.48 86.56 209.44 6,305.53 6,245.53 -4,851.06 -2,156.17 6,020,934.02 514,154 20 11.94 4,954.86 MWD(4) { 9,130.44 85.91 21218 6,307.50 6,247.50 -4,876.74 -2171.48 6,020,908.31 514,138.95 9.38 4,983.84 MWD(4) 9,160.48 86.07 214.95 6,309.60 6,249.60 -4,901.70 -2188.05 6,020,883.31 514,122.44 9.21 5,013.21 MWD(4) n 9,191.83 85.76 217.21 6,311.84 6,251.84 -4,926.98 -2,206.46 6,020,858.00 514,104.08 7.26 5,044.10 MWD(4) E 9,220.35 86.90 219.58 6,313.66 6,253.66 -4,949.28 -2,224.14 6,020,835.66 514,086.45 9.24 5,072.37 MWD(4) i9,250.25 84.19 221.12 6,315.98 6,255.98 -4,971.99 -2,243.44 6,020,812.91 514,06720 10.40 5,102.08 MWD(4) 1 9,280.34 85.67 224.78 6,318.64 6,258.64 -4,993.92 -2263.86 6,020,790.94 514,046.84 13.08 5,13203 MWD(4) 9,31030 87.91 229.24 6,320.32 6,260.32 -5,014.31 -2,285.73 6,020,770.50 514,025.01 16.64 5,161.91 MWD(4) 9,34029 91.07 233.33 6,320.59 6,260.59 -5,033.06 -2309.12 6,020,751.70 514,001.66 1723 5,191.71 MWD(4) 9,370.93 90.80 234.55 6,320.09 6,260.09 -5,051.10 -2,333.89 6,020,733.62 513,976.94 4.08 5,221.97 MWD(4) 9,405.39 90.12 233.86 6,319.81 6,259.81 -5,071.25 -2,361.84 6,020,713.40 513,949.03 281 5,255.99 MWD(4) 9,430.38 87.42 233.92 6,320.35 6,26035 5,085.97 -2382.02 6,020,698.64 513,928.89 10.81 5,280.67 MWD(4) 9,460.50 87.82 229.95 6,321.60 6,261.60 -5,104.53 -2,405.71 6,020,680.04 513,905.24 13.24 5,310.54 MWD(4) 1 9,490.40 91.04 227.69 6,321.90 6,261.90 -5,124.21 -2,428.21 6,020,660.31 513,882.79 13.16 5,340.36 MWD(4) 9,520.44 93.29 224.15 6,320.76 6,26076 -5,145.09 -2,449.77 6,020,639.38 513,861.27 13.96 5,370.37 MWD(4) i 9,550.46 93.16 220.90 6,319.07 6,259.07 -5,167.17 -2,470.02 6,020,617.26 513,841.07 10.82 5,400.31 MWD(4) 1 9,580.41 95.56 217.92 6,316.80 6,256.80 -5,190.24 -2,488.98 6,020,594.15 513,822.17 12.75 5,430.03 MWD(4) 1 9,610.26 94.92 214.50 6,314.07 6,254.07 -5,214.22 -2,506.54 6,020,570.13 513,804,66 11.61 5,459.40 MWD(4) 1 9,640.38 95.78 211.68 6,311.26 0251.26 -5,239.34 -2522.91 6,020,544.98 513,788.35 9.75 5,488.74 MWD(4) 19,670.48 97.85 209.01 6,307.69 6,247.69 -5,265.13 -2,538.01 6,020,519.16 513,773.31 11.17 5,517.65 MWD(4) 9,700.07 99.52 205.94 6,303.22 6,243.22 5,291.08 -2551.50 6,020,493.18 513,759.87 11.71 5,545.54 MWD(4) 9,730.68 98.47 203.73 6,298.43 6,238.43 5,318.51 -2,564.20 6,020,465.72 513,747.24 7.91 5,573.92 MWD(4) 1 9,760.34 95.81 204.21 6,294.75 6,234.75 5,345.40 -2576.15 6,020,438.81 513,735.34 9.11 5,601.38 MWD(4) 9,790.32 93.38 203.94 6,292.35 6,232.35 5,372.68 -2,588.34 6,020,411.50 513,723.21 8.15 5,629.30 MWD(4) 9,820.62 93.14 203.65 6,290.62 6,230.62 -5,400.36 -2,600.55 6,020,383.80 513,711.07 1.24 5,657.50 MWD(4) 9,850.65 90.00 204.67 6,289.80 6,229.80 -5,427.75 -2,612.83 6,020,356.39 513,698.85 10.99 5,685.55 MWD(4) ?. 1/102016 3:00:45PM Page 3 COMPASS 5000.1 Build 74 • i ConocoPhillips ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3Q-13 Project: Kuparuk River Unit TVD Reference: 3Q-13 @ 60.00usft(3Q-13) Site: Kuparuk 3Q Pad MD Reference: 3Q-13 it 60.00usft(30-13) Well: 3Q-13 North Reference: True Wellbore: 3Q-13 Survey Calculation Method: Minimum Curvature Design: 30-13 Database: EDM Alaska NSK Sandbox Survey. Map Map Vertical I MD Inc Azi ND TVDSS +NI-S +E(-W OLS Northing Easting Section Survey Tool Name Annotation (usfq r) r) (u ) mai : (usft) (usft) (ft) (ft) C/100') (ft). 9,880.61 89.08 205.27 6,290.04 6,230.04 -5,454.91 -2,625.48 6,020,329.21 513,686.26 367 5,713.70 MWD(4) i 9,910.46 87.85 205.62 6,290.84 6,230.84 -5,481.85 -2,638.30 6,020,302.24 513,673.50 4.28 5,741 81 MWD(4) 9,940.66 88.00 208.14 6,291.93 6,231.93 -5,508.77 -2,651.94 6,020,275.29 513,659.92 8.35 5,770.49 MWD(4) 9,971.95 87.79 210.42 6,293.08 6,233.08 -5,536.04 -2,667.23 6,020,247.99 513,644.69 7.31 5,800.59 MWD(4) jJ 10,000.29 86.77 213.43 6,294.43 6,234.43 -5,560.06 -2,682.20 6,020,223.94 513,629.77 11.20 5,828.16 MWD(4) @ 10,030.56 88.47 216.38 6,295.69 6,235.69 -5,584.86 -2,699.51 6,020,199.10 513,612.52 11.24 5,857.93 MWD(4) ) 10,060.69 89.26 219.71 6,296.28 6,236.28 -5,608.58 -2,718.07 6,020,175.35 513,594.02 11.36 5,887.83 MWD(4) 10,090.54 90.03 223.04 6,296.47 6,236.47 -5,630.98 -2737.80 6,020,152.91 513,574.34 11.45 5,917.62 MWD(4) 10,120.56 89.88 224.09 6,296.49 6,236.49 -5,652.73 -2758.48 6,020,131.11 513,553.70 3.53 5,947.63 MWD(4) 10,151.04 88.40 223.90 6,296.95 6,236.95 -5,674.65 -2,779.65 6,020,109.15 513,532.58 4.90 5,978.10 MWD(4) 10,180.56 87.36 223.45 6,298.04 6,238.04 -5,695.99 -2,800.02 6,020,087.77 513,512.26 3.84 6,007.59 MWD(4) 10,210.71 87.94 221.17 6,299.28 6,239.28 -5,718.27 -2,820.30 6,020,065.45 513,492.04 7.80 6,037.68 MWD(4) 155 10,240.61 87.61 218.52 6,300.44 6,240.44 -5,741.20 -2,839.44 6,020,042.47 513,472.95 8.92 6,067.43 MWD(4) 10,271.40 90.46 216.87 6,300.96 6,240.96 -5,765.56 -2,858.26 6,020,018.08 513,454.18 10.69 6,097.96 MWD(4) 10,300.34 95.01 213.37 6,299.58 6,239.58 -5,789.19 -2,874.89 6,019,994.41 513,437.61 19.83 6,126.43 MWD(4) 10,330.72 92.39 212.37 6,297.61 6,237.61 -5,814.65 -2,891.34 6,019,968.91 513,421.21 9.23 6,156.07 MWD(4) • 10,360.50 94.24 215.38 6,295.89 6,235.89 -5,839.34 -2,907.91 6,019,944.20 513,404.70 11.85 6,185.23 MWD(4) e 10,390.50 96.03 218.79 6,293.21 6,233.21 -5,863.17 -2925.92 6,019,920.33 513,386.74 12.80 6,214.82 MWD(4) 10,425.46 95.01 221.64 6,289.84 6,229.84 -5,889.74 -2948.39 6,019,893.72 513,364.34 8.62 6,249.50 MWD(4) 10,457.00 95.01 221.64 6,287.09 6,227.09 -5,913.22 -2969.26 6,019,870.19 513,343.52 0.00 6,280.86 PROJECTED to TO , .....,,M„ ........a ,„ �,�.. .. _...�....«,,, �,.m..�. �....�, ,., ... :........-. �.,...,w. ..�.mm......w...»,m..,.�,..a 4 112012016 3:00:45PM Page 4 COMPASS 5000.1 Hudd 74 SEcovEDI JAN 22 2016 ® CC Letter of Transmittal „rigA BAKER Date: DATA LOGGED January 21, 2016 t K.BENDE/ R HUGHES To: From: Makana Bender Yosha Ragbirsingh/Michael Soper AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 3Q-13L1PB1 21 5 2 21 2 6 7 0 1 3Q-13L1 2 1 52-2 1 2 6 7 0 0 3Q-13L1-01 21 52 23 26 70 2 3Q-13L1-02 21 52 24 26 70 3 (4) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BakerHughes.com Yosha Ragbirsingh, Baker Hughes, Survey Manager Yosha.Ragbirsingh • BakerHughes.com 1 0 al " voo � A = = o n S oj13 � N Il-i` C, o w • 0 0 0 —. _ C7) -10 C) 17M0 0 U .• (1) Z to 610 '< H X m D CD 0 11) o x � : o IX c Ts N rr Z 0 0 tt: mo N 4, ods CO ' 1110 CSC IR i'III IA -4 cri o N N iV W • • • • N z Wlc ��w 4tppyr�5 a 03 Mogi co jt O O) o mus I NN_ i -Om 41 � g11, ��I O U 4 I O o i sr ._ o y co U o > R O CO CO d N 3 ❑ O O O N N O O N t N N M U !n d Jau'"" a a ' 'O _ 7 = o y t J J U'L Z71 co O V co H xa a= N ca 7 y E = = N8 8 Co O 7 ?'. - it Q) b coo U 4` - s E c `o _ cn a -o a C3 3 19 ti I) w o O `m R m co r ¢ a ([I } O m a a a ? = p R ... 3 T O c cc cc m cO O f W m c� .a cn cn ra j . , )v) v, _ O CO tl) N .,_____s___, ' a) J N `Q Cn > Om ( O CNA = � dQ N o CO = _ r CO CD n -O O � rN_ L p ,o v •c Co 00T w y ta) d E bl 6"Co LT. c _ o 0 u)a :: S 5 ❑ CO V d U cc d O O V V [�' 0as . 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(D (D -a (n u) ad d CO (d O) CO v r) co of (6 r) of ui N "- 0 0 O NNINCSIN N N ,.2_ 15d Q N N N N N N N N N N N N N N N N N N N N L d' CO •O/1 a Y Y . 0 i i M M M W (n O O) I� I� W M W O W V )O O (M') N O O O C OO_ 00_ ,- � O o W O IT r V' N O W V M O) W 0 0 3 O N- O I'` W W 0) O 0) W N. n r O (0 N V' O (n ([) S U Y Y O Cco M1 i;, C 2 CO W co co W co co 0) co co co co W rn co co co co O) m o LO OO c0 VW W N N) W 0W VW V W W O M NN- O O W O CO OO O ' boo OO OO O OddO (0n of C C ❑ of - n O M Or NNNpM (pM77y co co D) O O0 co O O C T nO ) 00) OO O O O O O O O O O O OOO O OO O .. 0 - - - - - - - - - - - - - - - - V EO O OV._ .. O O O n. 0) 0 co tioF Tk-n • • 0,r,\1//7, S • THE STATE Alaska Oil and Gas , ofA LAsKA. Conservation Commission S `•t itt= 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 -J" *�., ALAS*1' Fax: 907.276.7542 www.aogcc.alaska.gov Daniel Venhaus CTD Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3Q-13L1-01 ConocoPhillips Alaska, Inc. Permit No: 215-223 Surface Location: 2283' FNL, 2037' FEL, SEC. 17, T13N, R9E, UM Bottomhole Location: 3008' FNL, 5143' FEL, SEC. 20, T13N, R9E, 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. 186-176, API No. 50-029- 21664-00-00. 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 . Foerster � � Chair DATED this G day of December, 2015. RECEIVED STATE OF ALASKA A 4 OIL AND GAS CONSERVATION COMrt jN DEC 15 2015 PERMIT TO DRILL ����� 20 AAC 25.005 1 a.Type of Work: 1 b. Proposed Well Class: Exploratory-Gas ❑ Service- WAG Li- Service-Disp le 1 c.Specify if well is proposed for: Drill ❑ •Lateral ❑✓ Stratigraphic Test ❑ Development-Oil ❑ Service- Winj ❑ Single Zone Coalbed Gas ❑ Gas Hydrates ❑ Redril❑ Reentry ❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q Single Well ❑`14(15 11.Well Name and Number: ConocoPhillips Alaska Inc Bond No. #69€4-24-2.7,54,51 18•0 ‘4.9...v 3Q-13L1-01 - 3.Address: 6.Proposed Depth: 12.Field/Pool(s): PO Box 100360 Anchorage,AK 99510-0360 MD: 10575' TVD: 6175' ^ Kuparuk River Field/ 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Kuparuk Oil Pool Surface: 2283'FNL,2037'FEL,Sec.17,T13N, R9E,UM ' ADL 25512 • Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1521'FNL,3940'FEL,Sec.20,T13N, R9E,UM ALK 2553 1/1/2016 Total Depth: 9.Acres in Property: ?<8. 14.Distance to Nearest Property: 3008'FNL,5143 FEL,Sec.20,T13N, R9E,UM 2 D .25'{ 14060' 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): - 60' 15.Distance to Nearest Well Open Surface: x-516300 y-6025789 Zone-4 . GL Elevation above MSL(ft): . 42' to Same Pool: 1265' (3M-13) 16. Deviated wells: Kickoff depth: • 8990 feet 17.Maximum Potential Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 96 degrees Downhole: 4509 psi , Surface: 4022 psi 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing _ Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3.25" 2-3/8" 4.6# L-80 ST-L 1925' 8650' 6249' 10575' 6175' Slotted Liner 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): 8168' 6195' none 8083'MD 6502'TVD None Casing Length Size Cement Volume MD TVD Conductor/Structural 115' 16" 1875#Poleset 115' 115' Surface 4325' 9-5/8" 1200 sx ASIII&300 sx Class G 4325' 3713' Intermediate Production 8168' 7" 300 sxs Class G&175 sx AS I 8168' 6567' Liner Perforation Depth MD(ft): 7743'-7755',7760'-7784'&7790'- Perforation Depth TVD(ft): 6247'-6256',6259'-6277'&9282'-6310' 7828' 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Dat-41110.4 , ' - -- 22. I hereby certify that the foregoing is true and the procedure approved herein will not Jpso be deviated from without prior written approval. Contact iason.burke(a�cop.com Email Printed Name Daniel Venhaus Title CTD Supervisor Signature 0 Phone 907-263-4372 Date /2 - /`i— 1 5 Commission Use Only Permit to Drill API Number: Permit ApprovalSee cover letter for other Number: !S'aa 50-0V.....2 J t0(/-GI -p0 Date: 1 a (j31-16 requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane gas hydrates,or gas contained in shales: Z f-c Other:5Op 5I- to O 5- U 5 i y Samples req'd: Yes❑ Nod Mud log req'd:Yes No[ ' 7�/-7 I'?v I Ge/ p rC v e-!/t t` !S t/' � 74"0 0.-_5-0 U p 3)4S measures: Yes m No Directional svy req'd:Yes❑�No❑ 5t4fc kr , tYr L-55-cd .41.1 Tixception 1 t1- Spacing req'd: Yes ❑ No , Inclination-only svy req'd:Yes No[r rc T v Irc d 4 f f r r 51-4 b l,7 e d I"'' ha^c ft'cry--1 Post initial injection MIT req'd:Yes❑ No❑ APPROVED BY Approved by: COMMISSIONERygTl(H�COMMISSION Date:12 -2-3 -15- 1/77_ � -(S V7 I 2 3 /S /� �( "`� l'�1"`^� Submit Form and Form 10-401(Revised 11/2015) °Rile it I f 2a months from the date of approval 20 AAC 25.005(9)) Attachments in Duplicate �� ' v L /3/Z. • ConocoPhillips s Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 December 9, 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 permits to drill a tri-lateral out of the KRU 3Q-13 using the coiled tubing drilling rig, Nabors CDR2-AC. The work is scheduled to begin mid-January 2016. The CTD objective will be to drill three laterals(3Q-13L1, L1-01 & L1-02), 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 30-13L1, L1-01 & L1-02 — Detailed Summary of Operations — Directional Plans for 3Q-13L1, L1-01 & L1-02 — Current wellbore schematic — Proposed wellbore schematic If you have any questions or require additional information please contact me at 907-263-6097. Sincerely, Jason Burke Coiled Tubing Drilling Engineer • • 0 b Kuparuk CTD Laterals WU eRLA R ffi 3Q-13L1, L1-01 & L1-02 ConocoRaps Application for Permit to Drill Document 2110 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 4 (Requirements of 20 AAC 25.005(c)(13)) 4 Summary of Operations 4 Liner Running 6 14. Disposal of Drilling Mud and Cuttings 6 (Requirements of 20 AAC 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 6 (Requirements of 20 AAC 25.050(b)) 6 16. Attachments 7 Attachment 1: Directional Plans for 3Q-13L1, 3Q-13L1-01 &3Q-13L1-02 7 Attachment 2: Current Well Schematic for 3Q-13 7 Attachment 3: Proposed Well Schematic for 3Q-13L1, 3Q-13L1-01 &3Q-13L1-02 7 Page 1 of 7 June 30,2015 • • PTD Application: 3Q-13L1, 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 3Q-13L1, L1-01 & L1-02. All laterals will be classified as "Development—Oil"wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 3Q-13L1, 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 p9 and to 4500 psi. Using the maximum formation pressure in the area of 4509 psi in 3M-13 (i.e. 14.2 ppg EMW), the maximum potential surface pressure in 3Q-13, assuming a gas gradient of 0.1 psi/ft, would be 4022 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 Downhole Pressure(Requirements of 20 AAC 25.005(c)(4)(a)) The formation pressure in KRU 3Q-13 was measured to be 3135 psi(11.9 ppg EMW) on 10/21/2015. However the pressure is expected to decline to less than 11.8 ppg by the spud date. The maximum downhole pressure in the 3Q-13 vicinity is to the southwest in the 3M-13 injector at 4509 psi (14.2 ppg EMW) measured in November 2015. Due to a large fault between the 3M-13 and the 3Q-13, that high pressure is not expected during operations. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) Offset injection wells to 3Q-13 are under active MI gas injection. If significant gas is detected in the returns, the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) The major expected risk of hole problems is 1 large fault crossing. Managed pressure drilling (MPD)will be used to reduce the risk of shale instability associated with the fault crossing. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 3Q-13 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 7 December 9, 2015 • S PTD Application: 3Q-13L1, 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 3Q-13L1 8990' 10575' 6188' 6195' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 3Q-13L1-01 8650' 10575' 6249' 6175' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 3Q-13L1-02 7740' 10575' 6015' 6210' 2%", 4.7#, L-80, ST-L slotted liner; deployment sleeve on top Existing Casing/Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (PPO MD MD TVD TVD psi psi Conductor 16" 62.5 H-40 Welded 38' 115' 0' 115' 1640 630 Surface 9-5/8" 36.0 J-55 BTC 37' 4325' 0' 3713' 3520 2020 Production 7" 26.0 J-55 BTC 34' 8168' 0' 6567' 4980 4330 Liner 5-1/2" 14.0 H-40 STC 7680' 7770' 6140' 6444' 3110 2620 Tubing 3-1/2" 9.3 L-80 8rd EUE 38' 7680' 0' 6140' 10160 10530 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride-based FloVis mud (9.7 ppg) — Drilling operations: Chloride-based PowerVis mud (9.5 ppg).` This mud weight will not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: The 3Q-13 contains a downhole deployment valve allowing deployment of tool strings and liner without pumping kill weight fluid. If the valve does not hold, BHA's will be deployed using standard pressure deployments and the well will be loaded with an overbalanced completion fluid in order to provide formation over-balance and maintain wellbore stability while running completions Managed Pressure Drilling Practice Managed pressure drilling (MPD)techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 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". Page 3 of 7 December 9,2015 • PTD Application: 3Q-13L1, L1-01 & L1-02. In the 3Q-13 laterals we will target a constant BHP of 11.8 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Pressure at the 3Q-13 Window(7745' MD, 6189'TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure(11.5ppg) 3737 psi 3737 psi Mud Hydrostatic(9.5 ppg) 3087 psi 3087 psi Annular friction (i.e. ECD, 0.060 psi/ft) 465 psi 0 psi Mud+ ECD Combined 3552 psi 3087 psi (no choke pressure) (underbalanced (underbalanced 185 psi) —650 psi) Target BHP at Window(11.8 ppg) 3834 psi 3834 psi Choke Pressure Required to Maintain 283 psi 747 psi Target BHP 9. Abnormally Pressured Formation Information (Requirements of 20 AA C 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. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well KRU 3Q-13is a Kuparuk A-sand injection well equipped with 31/2"tubing and 5 1/2"big tail pipe kick out joint. Three laterals will be drilled to the southwest of the parent well with the laterals targeting the Al, A2 and A3 sands. A thru-tubing whip-stock will be set inside the 51/2"liner at the planned kickoff point of 7745' MD to drill all 3 laterals. The 3Q-13L1 southwestern lateral will exit through the 51/2"liner at 7745' MD and TD at 10,575' MD, targeting the Al sand. It will be completed with 2%"slotted liner from TD up to 8990' MD with an aluminum billet for kicking off the 3Q-13L1-01 lateral. Page 4 of 7 December 9,2015 a s PTD Application: 3Q-13L1, L1-01 & L1-02. The 3Q-13L1-01 will drill southwest to a TD of 10575' MD targeting the A3 sand. It will be completed with 2%"slotted liner from TD up to 8650' MD with an aluminum billet for kicking off the 3Q-13L1-02 lateral. The 3Q-13L1-02 will turn east and drill to a TD of 10575' MD targeting the A2 sands. It will be completed with 2%"slotted liner from TD up to 7740' MD,back into the 5 '/2"liner and completed with a deployment sleeve. Pre-CTD Work 1. RU Slickline:Dummy all gas lift valves and obtain an A-sand SBHP, drift a dummy whip-stock to TD. 2. RU E-line: Set Baker Hughes 31/2"x 51/2"thru-tubing whip-stock at 7745' MD 3. Perform injection test 4. Pump degradable plug for temporary parent bore isolation 5. Prep site for Nabors CDR2-AC, including setting BPV. Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 3Q-13L1 Lateral(Al sand southwest) a. Mill 2.80"window at 7745' MD. b. Drill 3.25"bi-center lateral to TD of 10575' MD. c. Run 2%"slotted liner with an aluminum billet from TD up to 8990' MD. 3. 3Q-13L1-01 Lateral(A3 sand southwest) a. Kick off of the aluminum billet at 8990' MD. b. Drill 3.25"bi-center lateral to TD of 10575' MD. c. Run 2%"slotted liner from TD up to 8650' MD 4. 3Q-13L1-02 Lateral(A2 sand southwest) a. Kick off of the aluminum billet at 8650' MD. b. Drill 3.25"bi-center lateral to TD of 10575' MD. c. Run 2%"slotted liner from TD back into the liner at 7740' MD 5. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV. 2. Pre-produce for less than 30 days 3. Return 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. MPD operations require the BHA to be lubricated under pressure, so installed in this well is a deployment valve. This valve, when closed using hydraulic control lines from surface, isolates the well pressure and allows long BHA's to be deployed/un-deployed without killing the well. If the deployment valve fails, operations will continue using the standard pressure deployment process. A system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick-line lubricator can be used. This pressure control equipment listed ensures Page 5 of 7 December 9,2015 PTD Application: 3Q-13L1, L1-01 & L1-02. there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse Liner Running — The 3Q-13 well has a deployment valve installed. It will serve to deploy liners into the newly drilled laterals. If the valve fails the laterals will be displaced to an overbalance completion fluid (as detailed in Section 8"Drilling Fluids Program") prior to running liner. — While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal./ • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18 i or 1B disposal facilities)or Prudhoe DS-4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional 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) Lateral Name Distance 3Q-13L1 14060' Page 6 of 7 December 9, 2015 s • PTD Application: 3Q-13L1, L1-01 & L1-02. 3Q-13L1-01 14060' 3Q-13L1-02 14060' — Distance to Nearest Well within Pool Lateral Name Distance Well 3Q-13L1 3M-13 1265' 3Q-13L1-01 3M-13 1265' 3Q-13L1-02 3M-13 1265' 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) 3M-13 & 3Q-07 are within %4-mile of the 3Q-13L1, L1-01 & L1-02 wells 3Q-13 (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#J-55 production casing. The last MIT-IA was completed on 4/10/15 and passed at 3000 psi. • Classified as a "Normal Well" • A-sand perforations(open): A3: 7743'—7755' MD,A2: 7760'—7784' &Al: 7790'—7828' MD • Well was recently worked over on 11-27-15, new tubing was run and an down hole deployment valve was installed 3M-13(producer), 1265' away from 3Q-13L1, L1-01 & L1-02 lateral to southwest • Well is classified as a troubled well due to T x IA leak at 3634' • Well has a surface casing patch 7' 7"from surface • Well is completed with 7"26#J-55 production casing, 3 '/" 9.3# L-80 tubing and a 4.5"x 3.5" scab liner from 5590'—9015' MD • Packers located at 9002' &9181' MD the lowest most which is located less than 200'from the top of the perforations • A/C sand perforations from 9269--9379' MD • Production casing was cemented with 350 sxs Class`G' & 175 sx AS I 3Q-07(producer), —1275' away from 3Q-13L1, L1-01 &L1-02 lateral to northwest • 3Q-07 currently producing from the Kuparuk A&C sand intervals • Classified as a waivered well due to IA x OA communication • Waivered with passing MIT-OA and fluid level. • Well is completed with 7"26#J-55 production casing and 2-7/8"6.5#L-80 tubing • NC-sand perforations: 8732'—8830' MD • Packer at 8619 ' MD, which is less than 200' from the perforations • Production casing was cemented with 100 sx 50/50 `G' 12.0 ppg and 200 sx`G' 15.8 ppg 17. Attachments Attachment 1: Directional Plans for 3Q-13L1, 3Q-13L1-01 & 3Q-13L1-02 Attachment 2: Current Well Schematic for 3Q-13 Attachment 3: Proposed Well Schematic for 3Q-13L1, 3Q-13L1-01 & 3Q-13L1-02 Page 7 of 7 December 9,2015 • 0 ! /> { re {\ %\k��/\ i i L.| ) ; . / ) / \ \ k k k , , II i i {\ }\ {� ! { ! i ! ( la 1) \§ \\ ! . m 4' k! \! E re } !} 2 !■ i E 0 (I)t , Elrx ƒ j § Cri / a) . « }k$ §2 £ k � k§ tI a,. F f ,! , !e \ } \ \ } \ § ` § s § ) )§k | pal- r. k • • Project.Kuparuk RiverUnit M,mex rom.+a sr WELLBOREDETAILS:37-13L1 REFERENCEINFORM4TpN .. Site:Kuparuk 30 Pad Mar Brea Cmartlnala(WE)Relerenre:Wx030-ITTrue NMI, Well:30-13 Parent Wellbore:77.03 Vertical Releeme:33-13 60 00.11 X13 m.m•n°srasaov.r Tie on MD:7700.00 Section(�vsjPNerenca sml-(O.00N,0.a0E) ) /+�n���p� Well 3,2-13L1 (3013Da.3/1/2016 >L,.is�RJt{Jf Il��l�ps Plan:30-13L1_Wp03(3Q-13/30-13L1) Oppinple BIOS ,roa.;eccrnzo+s MeasveaOryN Releren®:3GI3�La.asusR( 13) HUGHES Cahlatbn What Minimum Cuonge 3999e959s' a99ess` � .43,3• 33»N r —7 ' i .,,9i ■ ■■E 1 1 l 3Q3 I IFAMIIIIIIP 325+ _ _..._.P _ • }�pB. NEJ" __ r+Gb flI t? i $ l T r1111.Eltiling.,Miiii sx a«4 i• i. 1951 g �C� ` `4 i,.. - 13"a�iv.m. :e _ `-' - e` 1�` 1- _ --... 650 NINE;� �,-�.� _,__ .-. __ _- - - • y �' ' MEVIA'raT -650•• ■6GG: =■.77iiiRSi 1. I }. ,--...".1--A- � 9 -- —�- - 1300 ill.99 eliWililllinlle :::99esf.. ■ n■ - ,„ , a '' C_1950 11111■iiGG: i.Ti ■r SJ1 - ---- -;.,a-''''' .&Y27!!� --- - - -32200 Ems.�..�..... ■■ ■ __ . _ r q. ►- _.___ ____ r1CEE" •a . -- _ �� i--- _ iT NMOPPERMIll 1111111 119 OF - o _io , "Iligrlifil IF — — iii v-5200 ■ ■ rii� irk, ' ilJI■ . _ .._ . liti -_ _ :a.tM I — 4...er �� B -i -715+ . I .. ttp.GPRiti 1111 Rr . tf ■ i , = a ' m�s� io -'4 3;,7, ,' 9100' r■ i r . p8 011/, .. '''''j:'_'• l: Lti l...e�^++aw.al..!�r.`-w.s -.1...- _ _ I ,+ l 1 , Ilk 10400G'^" � V4,...47lt.t. ` ._ v — f f '!, - .—. •.i-''i�ie -i ori _ _ 4 W Y ill µ ?9,il � r. I 1.31.arsl,, 3 1 M 11050 ear -- .' ` . '.,� 1�/., , •! 4gr 0 '32 ' r I moo.a q► 123so1:4):4477.41 ag :4...1.44- .moi 1' 37-13 t,-,ii 3. = i,v �' e. ,:iO4:1:4--H .1 fi L 1:;:;.- 3` ttf�1, -_- 4 o- ;.-1 .r,-1 C ., .r1--t •lam.1 � � -13650-13000-12350-11700-11050-10400-9750-9100-8450-7800-7150-6500-5850-5200-4550-3900-3250-2600-1950-1300 -650 0 650'•.1300 1950 2600 3250 3900 4550 5200 5850 6500 7150 7800 8450 9100 9750 10400 West(-)/East(+)(650 usft/in) • • °Phillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3Q Pad 3Q-13 3Q-13L1-01 Plan: 3Q-13L1-01_wp01 Standard Planning Report 04 December, 2015 EMI BAKER HUGHES • • Baker Hughes INTEQ Kill ConocoPhillips Planning Report BAKER HUGHES Database: OAKEDMP2 Local Co-ordinate Reference: Well 3Q-13 Company: ConocoPhillips(Alaska)Inc.-Kup2 ND Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3Q-13 @ 60.00usft(3Q-13) Site: Kuparuk 3Q Pad North Reference: True Well: 30-13 Survey Calculation Method: Minimum Curvature Wellbore: 3Q-13L1-01 Design: 30-13 L 1-01_wp01 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 3Q Pad Site Position: Northing: 6,025,873.14 usft Latitude: 70°28'54.757 N From: Map Easting: 515,959.89usft Longitude: 149°52'10.513 W Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.12 ° Well 3Q-13 Well Position +N/-S 0.00 usft Northing: 6,025,789.31 usft Latitude: 70°28'53.925 N +E/-W 0.00 usft Easting: 516,299.52 usft Longitude: 149°52'0.528 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 3Q-13L1-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 3/1/2016 18.51 81.05 57,493 Design 3Q-13L1-01_wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,990.00 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 225.00 Plan Sections Measured ND Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°1100usft) (°/100usft) (°/100usft) (°) Target 8,990.00 95.21 214.51 6,227.29 -4,762.59 -2,120.18 0.00 0.00 0.00 0.00 9,060.00 97.66 210.24 6,219.44 -4,821.31 -2,157.42 7.00 3.50 -6.12 -60.00 9,160.00 94.16 204.15 6,209.14 -4,909.74 -2,202.84 7.00 -3.50 -6.08 -120.00 9,280.00 90.61 211.77 6,204.14 -5,015.54 -2,259.00 7.00 -2.96 6.34 115.00 9,530.00 91.65 229.24 6,199.20 -5,204.87 -2,420.70 7.00 0.42 6.99 86.60 9,600.00 91.65 224.34 6,197.18 -5,252.76 -2,471.68 7.00 0.00 -7.00 -90.00 9,820.00 91.25 208.94 6,191.62 -5,428.71 -2,602.53 7.00 -0.18 -7.00 -91.50 9,890.00 91.25 213.84 6,190.10 -5,488.43 -2,638.97 7.00 0.00 7.00 90.00 10,090.00 91.25 227.84 6,185.74 -5,639.33 -2,769.40 7.00 0.00 7.00 90.00 10,210.00 91.25 219.44 6,183.13 -5,726.07 -2,852.12 7.00 0.00 -7.00 -90.00 10,310.00 91.25 212.44 6,180.96 -5,806.97 -2,910.76 7.00 0.00 -7.00 -90.00 10,575.00 91.25 230.99 6,175.19 -6,003.87 -3,086.29 7.00 0.00 7.00 90.00 12/4/2015 2:30:25PM Page 2 COMPASS 5000.1 Build 74 • • Baker Hughes INTEQ Iffdiall ConacoPh dhips Planning Report BAKER HUGHES Database: OAKEDMP2 Local Co-ordinate Reference: Well 3Q-13 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3Q-13 @ 60.00usft(30-13) Site: Kuparuk 3Q Pad North Reference: True Well: 3Q-13 Survey Calculation Method: Minimum Curvature Wellbore: 3Q-13L1-01 Design: 30-13 L1-01_wp01 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +NI-S +E/-W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°1100usft) (/ (usft) (usft) 8,990.00 95.21 214.51 6,227.29 -4,762.59 -2,120.18 4,866.85 0.00 0.00 6,021,022.56 514,189.99 TIP/KOP 9,000.00 95.56 213.90 6,226.35 -4,770.82 -2,125.78 4,876.63 7.00 -59.97 6,021,014.32 514,184.41 9,060.00 97.66 210.24 6,219.44 -4,821.31 -2,157.42 4,934.71 7.00 -59.80 6,020,963.76 514,152.88 Start 7 dls 9,100.00 96.26 207.80 6,214.59 -4,856.03 -2,176.68 4,972.88 7.00 -119.85 6,020,929.01 514,133.70 9,160.00 94.16 204.15 6,209.14 -4,909.74 -2,202.84 5,029.35 7.00 -119.83 6,020,875.25 514,107.66 3 9,200.00 92.98 206.69 6,206.64 -4,945.79 -2,219.97 5,066.96 7.00 114.92 6,020,839.16 514,090.61 9,280.00 90.61 211.77 6,204.14 -5,015.54 -2,259.00 5,143.88 7.00 114.90 6,020,769.33 514,051.74 4 9,300.00 90.70 213.16 6,203.91 -5,032.42 -2,269.73 5,163.40 7.00 86.59 6,020,752.44 514,041.04 9,400.00 91.11 220.15 6,202.33 -5,112.58 -2,329.39 5,262.27 7.00 86.55 6,020,672.15 513,981.57 9,500.00 91.53 227.14 6,200.03 -5,184.87 -2,398.35 5,362.15 7.00 86.52 6,020,599.71 513,912.77 9,530.00 91.65 229.24 6,199.20 -5,204.87 -2,420.70 5,392.09 7.00 86.57 6,020,579.67 513,890.47 5 9,600.00 91.65 224.34 6,197.18 -5,252.76 -2,471.68 5,462.01 7.00 -89.93 6,020,531.67 513,839.60 6 9,700.00 91.47 217.34 6,194.46 -5,328.34 -2,537.01 5,561.64 7.00 -91.40 6,020,455.95 513,774.44 9,800.00 91.28 210.34 6,192.06 -5,411.33 -2,592.64 5,659.66 7.00 -91.41 6,020,372.85 513,719.00 9,820.00 91.25 208.94 6,191.62 -5,428.71 -2,602.53 5,678.94 7.00 -91.49 6,020,355.45 513,709.15 7 9,890.00 91.25 213.84 6,190.10 -5,488.43 -2,638.97 5,746.94 7.00 89.95 6,020,295.66 513,672.85 8 9,900.00 91.25 214.54 6,189.88 -5,496.70 -2,644.58 5,756.76 7.00 89.99 6,020,287.38 513,667.25 10,000.00 91.25 221.54 6,187.70 -5,575.39 -2,706.15 5,855.94 7.00 89.92 6,020,208.56 513,605.86 10,090.00 91.25 227.84 6,185.74 -5,639.33 -2,769.40 5,945.87 7.00 89.93 6,020,144.49 513,542.76 9 10,100.00 91.25 227.14 6,185.53 -5,646.08 -2,776.77 5,955.86 7.00 -89.99 6,020,137.72 513,535.40 10,200.00 91.25 220.14 6,183.35 -5,718.39 -2,845.72 6,055.74 7.00 -89.92 6,020,065.27 513,466.62 10,210.00 91.25 219.44 6,183.13 -5,726.07 -2,852.12 6,065.70 7.00 -89.99 6,020,057.57 513,460.24 10 10,300.00 91.25 213.14 6,181.17 -5,798.56 -2,905.35 6,154.59 7.00 -89.93 6,019,984.97 513,407.17 10,310.00 91.25 212.44 6,180.96 -5,806.97 -2,910.76 6,164.36 7.00 -89.99 6,019,976.56 513,401.78 11 10,400.00 91.25 218.74 6,179.00 -5,880.10 -2,963.10 6,253.09 7.00 89.93 6,019,903.32 513,349.61 10,500.00 91.25 225.74 6,176.82 -5,954.07 -3,030.26 6,352.89 7.00 89.92 6,019,829.21 513,282.61 10,575.00 91.25 230.99 6,175.19 -6,003.87 -3,086.29 6,427.71 7.00 89.94 6,019,779.29 513,226.70 Planned TD at 10575.00 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (••) (") 10,575.00 6,175.19 23/8" 2-3/8 3 12/4/2015 2:30:25PM Page 3 COMPASS 5000.1 Build 74 • • r' Baker Hughes INTEQ HIM ConocoPhillips Planning Report BAKER HUGHES Database: OAKEDMP2 Local Co-ordinate Reference: Well 30-13 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3Q-13 @ 60.00usft(30-13) Site: Kuparuk 3Q Pad North Reference: True Well: 3Q-13 Survey Calculation Method: Minimum Curvature Wellbore: 3Q-13L1-01 Design: 3 Q-13 L 1-01_wp 01 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +El-W (usft) (usft) (usft) (usft) Comment 8,990.00 6,227.29 -4,762.59 -2,120.18 TIP/KOP 9,060.00 6,219.44 -4,821.31 -2,157.42 Start 7 dls 9,160.00 6,209.14 -4,909.74 -2,202.84 3 9,280.00 6,204.14 -5,015.54 -2,259.00 4 9,530.00 6,199.20 -5,204.87 -2,420.70 5 9,600.00 6,197.18 -5,252.76 -2,471.68 6 9,820.00 6,191.62 -5,428.71 -2,602.53 7 9,890.00 6,190.10 -5,488.43 -2,638.97 8 10,090.00 6,185.74 -5,639.33 -2,769.40 9 10,210.00 6,183.13 -5,726.07 -2,852.12 10 10,310.00 6,180.96 -5,806.97 -2,910.76 11 10,575.00 6,175.19 -6,003.87 -3,086.29 Planned TD at 10575.00 12/4/2015 2:30:25PM Page 4 COMPASS 5000.1 Build 74 • • ConocoPhillips V/lilt ConocoPhithps Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3Q-13 Project: Kuparuk River Unit TVD Reference: 3Q-13 @ 60.00usft(30-13) Reference Site: Kuparuk 3Q Pad MD Reference: 3Q-13 @ 60.00usft(3Q-13) Site Error: 0.00 usft North Reference: True Reference Well: 3Q-13 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 3Q-13L1-01 Database: EDM Alaska ANC Prod Reference Design: 30-13L1-01_wp01 Offset TVD Reference: Offset Datum Reference 30-13L1-01_wp01 Filter type: GLOBAL FILTER APPLIED:All weilpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 8,990.00 to 10,575.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,251.50 usft Error Surface: Elliptical Conic Survey Tool Program Date 12/4/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 100.00 7,700.00 3Q-13(3Q-13) BOSS-GYRO Sperry-Sun BOSS gyro multishot 7,700.00 8,990.00 3Q-13L1_wp03(3Q-13L1) MWD MWD-Standard 8,990.00 10,575.00 3Q-13L1-01_wp01 (3Q-13L1-01) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 10,575.00 6,235.19 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 3Q Pad 3Q-05-3Q-05-3Q-05 Out of range 3Q-07-3Q-07-3Q-07 Out of range 3Q-13-3Q-13L1-3Q-13L1_wp03 9,000.00 9,000.00 0.07 0.49 -0.39 FAIL-Minor 1/10 3Q-13-30-13L1-02-30-13L1-02_wp01 8,999.78 9,000.00 20.29 1.34 19.31 Pass-Minor 1/10 3Q-14-3Q-14A-3Q-14A Out of range 30-14-3Q-14AL1-3Q-14AL1 Out of range 30-14-3Q-14AL2-3Q-14AL2 Out of range 3Q-22-3Q-22-3Q-22 Out of range Offset Design Kuparuk 3Q Pad- 3Q-13-30-13L1-30-13L1_wp03 Offset Site Error: 0.00 cult Survey Program: 100-BOSS-GYRO.7700-MWD Rule Assigned:Minor 1/10 Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Tootface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-6 +EJ-w Hole Size Centre Distance Deviation (usft) )usft) (usft) (usft) (usft) (usft) (°) (usft) (usft) (") (usft) (usft) (usft) 9,000.00 6,286.35 9,000.00 6,286.41 0.04 0.03 29.41 -4,770.82 -2,125.79 2-11/16 0.07 0.49 -0.39 FAIL-Minor 1/10,CC,ES,SF 9,024.98 6,283.74 9,025.00 6,284.55 0.12 0.13 28.75 -4,791.67 -2,139.46 2-11/16 0.82 0.63 0.41 Pass-Minor 1/10 9,049.90 6,280.75 9,050.00 6,283.15 0.20 0.22 27.20 -4,812.88 -2,152.62 2-11/16 2.42 0.80 2.08 Pass-Minor 1/10 9,074.81 6,277.53 9,075.00 6,282.20 0.29 0,32 25.50 -4,834.41 -2,165.28 2-11/16 4.72 0.95 4.23 Pass-Minor 1/10 9,099.77 6,274.61 9,100.00 6,281.69 0.37 0.41 22.99 -4,856.24 -2,177.47 2-11/16 7.14 1.08 6.57 Pass-Minor 1/10 9,124.73 6,272.08 9,125.00 6,281.29 0.46 0.52 14.19 -4,877.84 -2,190.03 2-11/16 9.46 1.18 8.76 Pass-Minor 1/10 9,149.58 6,269.93 9,150,00 6,280.89 0.55 0.64 1.24 -4,899.06 -2,203.25 2-11/16 11.99 1.27 11.07 Pass-Minor 1/10 9,174.45 6,268.14 9,175.00 6,280.48 0.64 0.75 -10.22 -4,919.86 -2,217.11 2-11/16 15.15 1.34 14.00 Pass-Minor 1/10 9,199.54 6,266.67 9,200.00 6,280.08 0.74 0.87 -17.15 -4,940.23 -2,231.60 2-11/16 18.61 1.38 17.31 Pass-Minor 1/10 9,224.77 6,265.52 9,225.00 6,279.68 0.83 1.00 -22.05 -4,960.15 -2,246.70 2-11/16 22.20 1.39 20.82 Pass-Minor 1/10 9,250.13 6,264.69 9,250.00 6,279.28 0.93 1.12 -25.78 -4,979.59 -2,262.40 2-11/16 25.86 1.40 24.47 Pass-Minor 1/10 CC-Min centre to center distance or covergent point,SF-min separation factor.ES-min ellipse separation 12/412015 3:30:40PM Page 2 COMPASS 5000.1 Build 74 e • ..a�cnw wm WELLBORE DETAILS:3Q-1317-01 REFERBICE 1NFdu.Nna Kill Project:Kuparuk River Unit w>�c wtl..est' Site:Kuparuk 3Q Pad Comings 81/876eam Wd30.13ine ROM • Wpm.,.1, Parent Weetwre:30.1311 Vatid(ry01R.r m®:14�5azl.ewl Soden 6/68.168868 dia-alaan coon ��� Well:3Q-13 a+ou S7amoart Te on MD:8880.00 ConocoPhillips Wellbore:7Q-1717-07 11-01_wp01(3Q-13/3Q-13U-01) 08 at m„„® Meowed Dept apt®m.mud(3at3) , HUGHILS WELL DETAILS: 3Q-13 •34 I■■■■■■■■■■■■■E■■■■, ,-NI-S aE/-W Northing Easting Latitude Longitude -3.11 ■■■•■■••■■■■IrA•■■•■' 0.00 0.00 6025789.31 516299.52 70°28'53.925 N 149°52'0.528 W 3s0o •••••••••••rIi.1•••••1 Sec MD Inc Ali NDSS +N/-S +E/-W Dleg TFace VSect Annotation ....■.■.■■.,FI■■■.■1 t 8990.00 95.2176 214.51 6227.29 -4762.59 -2120.18 0.00 0.00 4866.85 TIP/KOPt -4000 ■■■.■...■■,�.'iaij■■■' 2 9060.00 97.66 210.24 6219.44 -4821.31 -2157.42 7.00 -60.00 4934.71 Start7dls 3 9160.00 94.1601 204.1511 6204.14 -4909.74 -2202.84 7.00 -120.00 5029.35 3 -4200 ■■■■■■■...'.�©��■■■' 4 9280.00 90.61 211.77 6204.14 -5015.54 -2259.00 7.00 115.00 5143.88 4 5 9530.00 91.65 229.24 6197.28 -5204.87 -2471.68 7.00 86.60 5392.0941 5 5.a4a0 ■■■■.■■■.V �.■■■..1 6 9600.00 91.65 224.34 6197.18 -5252.76 -2471.68 7.00 -90.00 5462.01 6 1 7 9820.00 91.25 213.84 619.10 -5428.715 -2638.97 7.00 -90.00 5746.94 7 N-a60o ■■■■■.3Q-1 1-01 ���,I■ ��.■.' 8 9890.00 91.25 213.84 6190.10 -5488.43 -2638.97 7.00 90.00 5746.94 8 o 0.13 1-01_ 30.13 9 10090.00 91.25 227.84 6185.74 -5639.33 -2769.40 7.00 90.00 5945.87 9 -4800 r� 10 10210.00 91.25 219.44 6183.13 -5726.07 -2652.12 7.00 -90.00 6065.70 10 ■■■■.i:� �/I lieinpi .■■■.■1 11 10310.00 91.25 212.44 6180.96 -6003.87 -2910.76 7.00 -90.00 6164.361 11 .';-'2'.500a ■1..1.119�Ira■X311�■■■111 12 10575.00 91.25 230.99 6175.19 -6003.87 -3086.29 7.00 90.00 6427.71 Planned TDat10575.00 0 t54„ ■■■1111M ia..■■■.■.■' e. ■■ESI:EI z•••.■■■.■.1 5.11 ■U,•W.aiIUuI■■■■■1 .6611 .�E Pi . at 10.70100■■.■.■■■1 -6211 1111■11►M11�■��■■■■���1 mmunimmmummussecimmomainiomms -4000-3800-3600-3400-3200•3000-2800-2600-2400-2200-2000-1800-1600-1400-1200-1000 -800 -600 -400 West(-)/East(+)(200 usft/in) 5780 yy }� 5865- ‘ N R,_, 4, I; F q 4 4 4 ? 4 R .E s950- m Id ^; ,^y '� FaL K- i .X R .X �VauW TD^i^S Cm 7 6035 00 30.13 3Q-13.1-01 6120 ' .$ T1�/KOP i II N 6205 .....- - Q ° . . 3Q-13I3QJ3L1 ✓ 6290- Starl7 die 3 4 5 0 7 8 0 10 II t 3Q-.1.3‘3Q.-13..1-02 j 6375 N � 6460 F' 3Q-13130113 6545 6630 3Q-1.11;_Fu1t1 30.131_Paula 3Q-1 L_88683 Mean See L8.4 3570 3655 3740 3825 3910 3995 4080 4165 4250 4335 4420 4505 4590 4675 4760 4845 4930 5015 5100 5185 5270 5355 5440 5525 5610 5695 5780 5865 5950 6035 6120 6205 6290 6375 6460 6545 6630 6715 6800 Vertical Section at 225.00°(85 usft/in) • • KUP INJ 3Q-13 ConocoPhillip)s 0. Well Attributes Max Angle&MD TD Ates'1wi inc. oioloora APIIJWI FSAO M5118 Watbore Status Man'') MO 100a) act atm(CKB) 5:3232766405 KUPARUK RIVER UNIT INS as 94 3 t__x- 5,150,0 ... - C.-Town iloSyann3 Data Annotation EDM Data 00.Gre(rt) 1118 Refuse.Gale 1C'a,1:.1.:0'I::'Sat PM 5Ev-..C:EDHJT 3.1'::X'2 Last WO. 42.51 2;0.:1035 041 •cn011010'xa�; Asinotallon �''��(nKBI ',7.1",...2.C• ;.rinoi3tlCh Last Moa By 00at Last 1'a^7 _ R_e _ C:7 _... ,. - "-. :,..v.,. .22:5:2 Casing Strings corn 00.CIpItCn DD(m) 1G ON Tap(0,01 Sat Dope Oil,BI Sat OoptIl(Tvel...WVLwtII_Grade TC9111rae. CONDUCTOR 15^5215 v 7750 1'5.0 82.5 5-43 We'd,. Caeing0011cIptlan 00{m1 0itel 11p3500) Sot Def.111001 Nil Oaptn(5,01. Wt..(I. On. Teel:Wee1 SURFACE 91'5 3.755 4,325.3 3.7'3.6 30.00 2-55 5TC CaMn000009ptiOn DO flat 0(Mt Top(nual V sot Depth(MITI Ss)Capin(TDO...WM.IL.Gratz Tel:To000 a.a« - _PROGUOTIOPI 5274 34.0 3,',SS 1 6.5572 26.CO 5-55 STC .,ti^�^^,,,, - Tubing Strings Tuaing Deecnpilon SnM5 Ma...10 Mt Top(0110) Sot Depth(ft..let Dapio.(T9)(...01(100) Greoe TepEonna;.ttun uSx.e-:Mater .2 2._52 34.x0 7.507.0 5,120.7 9.32 L-30 =u=s I rdxtl.. Completion Details 000..Wi......171100 - 140011nsl ID Tap)r)KO( Top4T'G)(1MKa) Top ln114'( Ham cos Cor (1411 I 34.0 34.0 v.'9 Han_. CV!tab:0grar5_ 3.55x0 7.503.2 .2,5 47 3, Loco.; Ear£•::2-1-22'a.4ao-s.:c 3.0{'0 .5''S. 47 3Sea P_ezmhny 03v:s,'.22 .a.casse ,Lt'7 el a-. 3.0:00 Tuning Dearflpnon String Mlln a_..in vocal sal own(0,..Sat O..(T/O){...WI(lo.Tt) Gratis Top connection Lower arker 2.332 7.505 3 7.77__ 4.267"s _ 5.3: EUE3 oor<lPietor: Completion Details calvmn-aaa40It04013 P s Ha011,1110- Tap ITtK01 11,1110Tap)ttK8) Top(Mt(nKn) 117 ina)') tarn Gas ....1. 410) ( _.555. 0.:74.4 47 00 .esker t o-T'i_. °-'_<..a. 4.6> 1 7.554.' 0.177.E 4177 PER(PPir-n__ _21.40?ER 3.590 Rte EY Recep.;c U} ..315.1 5-.44.5. 47.54 Nipal£-DE. 350.03,3 0. =a7',- .7.-i,7,522 2.015 XN.DS.D 41 T3:.7 41 45 L inet 1 r 1 1Ik 5 000e'H=,+as.ra-,az� • x257 _ ,<:#3 !Ire -,1_e. N. _ 5,5-wee, a S..E 5.000 Other in 11010(wireline retrievable plugs,valves,pumps.fish,etc.) topin,v) 107.lnd Top(flKo) 111100) (1 12'00 corn Run Gats iso itn1 011i1value 05041^0^111010.8 17;25'2715 2 350 (17z:o-e:de.1."10 Perforations&Slots shot Cane lop(TTI) 010(1431 (Mfat01 1'17)1(08) CImil1KB) fnKB) 4rtKe) Zona Gale I) Typa C.. 7.743.0 7,755.0 n3,2.47.1 3,255.4 A.-3,30-13 3:4.,2070 4.0 APERF 1:00--0e-.e1 e'l_o.; g, Jew=.V. 0.11.5 zmxT.-c�rrm y:4.0010 �3' Vicar ate. 7.760.0 7.734.0 5,259.0 0,007.5 1.2,30-13 3 2312000 4.0 P.PERF 20:8"J tit DP.ei-010 400711-00 7,700.0 7,320.0 0.2E3.3 5.555_ A-1,70-13 1232500 4.0 RPER0 2k$OJ tit DP,e.,93 8egoncrd ft r4,,,,..,T'f..1' 1 Mandrel Inserts s ei 011 Tap[010) 30K'a Lat;t1 Port 0114 T00000 e Top 11tKa) tVIKD) Make MoSN OD l.ell _gem Type Type (In) (7a) Run Data Cam .. 7Z 7 .-a miresDum 1:':m RK 1.00 1-.' '2015 2 4,:23.% _.7;2.4 :arcs 1..70,@0 Dumm RY. 1.500 11122/2015 o5.507 4617.7 4.3“. same Dumm RK 1.500 11/22/2015 Y 4 - _ - 5.2'522 Comoro 54143i Dumm RK 1.500 11:2212015 �c_a:0,.00 a 5 '1,052.9 2.-+ s.co... _ tat% .n RK ..500 11722!2015 , a_ 5 x 532 4 3 067.3.':E-,.. WAS:WAS: . RKR 7.500 11/2:'2015 55¢14+.� BIN 7e�l laded-,:Y:.bW..- '_' 1:.115000 vao'.e....194)07.4 :14 1 Notes:General&Safety rE.33. `� 17:031414 Annctslicn ...E .E..__._4... .-arui2S4:225 _rr_..__ 01110001170 00011031, 3 l 77sa1 €112907-tS`,A...3=C-�--Ir- 1` l L. PACAntt.OY.2171&,11211 • 3Q-13 Proposed CTD Sidetrack 3Q-13 Proposed CTD Schematic Modified n JAB 12-2-15 3-1/2"9.3#L-80 EUE 8rd,AB-Mod tubing to surface 3.1/2"Camco MMM gas lift mandrels:2690',4327, 5551',6401'8 7062' 3-1/2"Baker Orbit deployment valve at 3509'MD Note:2.835"min ID,no nipple profile 3-1/2"SOV t 7502' Packer l t 7565'MD 111. 3-1/2"X-nipple 7606'MD(2.812"min ID) 16"62.5#H-40 shoe @ 115'MD 5-1/2"Big Tail Pipe configuration 7681'-7770'MD 9-518"36*J-55 shoe @ 4325'MD ISI --s s - 7680'MD Crossover 3-1/2"to 0-12"liner Vented/Ported for installation i 1l 7745'proposed TOWS depth �. 3Q-13L1-01,Planned TD=10,575 MD =--r=-I.' ^- 2%"slotted liner with billet at 8650'• A-sand perfs • • 7743-7828' r \\ 30-13L1,Planned TD=10,575'MD •;• slotted liner with billet at 8990' \\ is 3Q-13L1-02,Planned TD=10,575 MD 7"26#J-55 shoe 2W slotted liner 7670'-10,585' @ 8168'MD • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • I TRANSMITTAL LETTER CHECKLIST WELL NAME: K. -3 Q -/3./..1 - 0 PTD: IS- 223 Development V Service Exploratory _Stratigraphic Test Non-Conventional FIELD: XyA.A4. �,IU POOL: gyatAK RAJt+r, yMr.t.tetM Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existin well Permit LATERAL No. /$(o— /7(o , API No. 50-023 - 6 -UO - oo. ✓ (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 1111 0 17 E1 N C) p a) 0- (0 N O _ (6 0' N a 0' 3 • Ea, c v' p WI c co c Z c c. m' o' o v; w r 0 0 p- c : os C `m u m, a 1/4...• °' �' a)` , tn, m Uy „ Cl tn, a U rn 3 c 0, T C, - O' � .c ; 3. � a a) 0 - ~ N. _ o c O @ o w; of g. ';; p. m' �, w' o E,o cry 0. M J o. E �, O "3, > N 4 7. N, N ~I � O. 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