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215-159
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 22, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2S-04 KUPARUK RIV UNIT 2S-04 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2022 2S-04 50-103-20721-00-00 215-159-0 G SPT 6141 2151590 1535 3570 3574 3578 3579 200 336 287 277 4YRTST P Brian Bixby 7/2/2022 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2S-04 Inspection Date: Tubing OA Packer Depth 30 2015 1970 1970IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB220704082821 BBL Pumped:3 BBL Returned:2 Friday, July 22, 2022 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,November 09,2016 TO: Jim Regg Il P.I.Supervisor 1 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2S-04 FROM: Chuck Scheve KUPARUK RIV UNIT 2S-04 Petroleum Inspector Src: Inspector Reviewed P.I.Suprvj NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2S-04 API Well Number 50-103-20721-00-00 Inspector Name: Chuck Scheve Permit Number: 215-159-0 Inspection Date: 11/4/2016 Insp Num: mitCS 161105072627 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2S-04 Type Inj W TVD 6141 Tubing• 868 - 868 - 868 • 870 . PTD 2151590 ' Type Test SPT,Test psi 1535 IA 1378 . 2110 2085 - 2085 Interval INITAL ' IP/F P ✓ OA 245 294 - 279 _ 274 • Notes: Well converted from producer to injector Sundry#316-463. SCANNED✓ ':PF' 4 Ciel Wednesday,November 09,2016 Page 1 of 1 • • Brooks, Phoebe L (DOA) 21 S I S`7 0 From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Monday, November 07, 2016 3:39 PM To: Brooks, Phoebe L (DOA) Subject: RE: KRU MITs Attachments: 2S-08 schematic.pdf; 2S-07 schematic.pdf; 2S-04 schematic.pdf Here you go. Thanks Kelly Lyons/ Brent Rogers SCANNED . UN 0 ` 2017, Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Mobile Phone (907) 943-0170 From: Brooks, Phoebe L(DOA) [mailto:phoebe.brooks@alaska.gov] Sent: Monday, November 07, 2016 2:24 PM To: NSK Problem Well Supv<n1617@conocophillips.com> Subject: [EXTERNAL]RE: KRU MITs Kelly/Brent, Will you send me the well schematics for 2S-04, 2S-07, &2S-08? Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: NSK Problem Well Supv [mailto:n1617Pconocophillips.com] Sent: Saturday, November 05, 2016 8:45 AM To: Regg,James B (DOA) <jim.regg@alaska.gov>; Wallace, Chris D (DOA) <chris.wallace@alaska.gov>; Brooks, Phoebe L (DOA) <phoebe.brooks@alaska.gov>; DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe.bay@alaska.gov> Subject: KRU MITs Attached are the MIT forms from the tests completed yesterday at 2S pad. 1 KUP PROD 411 2S-04 Conoc i4iUips Well AttributesMa ,yAngle&eM© „ ID Ai$S& ,ir'1C, Wellbore API/UWI Field Name • Wellbore Statusncl(") MD(ftKB) Act Btm(ftKB) vM,a, y®'� 501032072100 KUPARUK RIVER UNIT PROD 0.00 13,505.0 ••• E Comment HZS(ppm) Dale Annotation Entl Date KB-Grd(ft) `Rig Release Date 25-pa,1v@/201512:01:23PM SSSV:NIPPLE Last WO: 27.50 11/4/2015 Vert"'"h (acipail --Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:GLV C/O pproven 12/8/2015 Casing Strings -- - --- ----. Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread 1. CONDUCTOR 16 15.250 27.5 107.5 107.5 62.5011-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 10 3/4 9.950 28.4 2,815.0 2,562.2 45.50 L-80 HYD 563 g p ( ) ID in To ftKB Sat Depth ftKB Set De th ND...WULen I...Grade Top Thread INTERMEDIATE 7 5/8 6.875 26.1 7,886.0 6,184.9 29.70 L80 Hyd 563 T Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread 1q SLOTTED LINER 4 1/2 3.9581 7,730.9 13,476.0 6,236.7 11.60 L-80 IBTM Liner betails ;; .. 1 , Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(') Item Das Com (in) 7,730.9 6,130.5 66.46 PACKER HRD-E ZXP Liner top packer 5 1/2"x 7 5/8"L-80 5 5.740 00 Reducing ITJSrSI,69 4 1/2"Hydril 563 pin 7,750.6 6,138.3 67.10 NIPPLE RS packoff Seal Nipple 51/2"L-80 51/2"Hydril 563 4.940 box X box 7,753.4 6,139.4 67.19 HANGER DG Flex-Lock Liner hanger 51/2"x75/8"L-80-5 4.830 1/2"Hydril 563 pin X pin _A-A./CONDUCTOR,27.5-107.5 7,763.1 6,143.1 67.50 LOCATOR NO GO XO-51/2"Hydril 563 box X 5"Hydril 521 4.370 box 7,774.5 6,147.4 67.88 SBE Seal Bore Extension 80-40(4"ID)5"Hydril 521 pin x 4.000 NIPPLE;553.2 4 1/2"Hydril 521 box 8,546.9 6,301.6 83.26 SWELL 4-1/2"I13TM Swell Packer Baker 6.35"OD Assy A 3.960 PACKER (8520) I Tubing Strings ' Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 3 1/2 2.922 25.1 7,788.0 0 6,152.4 9.30 L-80 EUE8rd SURFACE;28.4.2,815.0 ompletion Deta�l - " Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des Com (in) 25.1 25.1 0.00 HANGER 4-1/2"Tubing Hanger with a 3.28'pup jt. 3.958 Gns LIFT:4.ass.3 553.2 553.2 0.08 NIPPLE 3-1/2"Camco DS Nipple w/2.875"Profile Ser#T061443 2.875 (540) 7,653.1 6,097.9 64.00 SLEEVE Baker CMU sliding sleeve(closed)with DS nipple w/ 2.812 2.812"(6096 TVD) 7,677.6 6,108.5 64.75 NIPPLE Camco 2.75 D nipple 4.5"OD W/(RHC plug PULLED 11 2.750 10 15)-Ser#T051139(6107 TVD) 7,758.3 6,141.3 67.35 LOCATOR Baker Locator 3.000 Gns LIFT 7,3os.1 7,758.8 6,141.4 67.36 SEAL ASSY Baker 80-40 GBH Locator Seal Assembly(-12 ft Seal to 3.000 Seal,36 ft for Seal travels) Perforations&Slots Shot Den Top(TVD) Btm(TVD) (shoteH SLEEVE;7.653 1 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 8,562.0 12,102.0 6,303.3 6,256.5 10/31/2015 SLOTS SLOTTED LINER NIPPLE;76776- 12,222.0 13,065.0 6,253.3 6,239.2 10/31/2015 SLOTS SLOTTED LINER 13,222.0 13,433.0 6,236,0 6,237.1 10/31/2015 SLOTS SLOTTED LINER Mandrel Inserts st aft N Top(TVD) Valve Lateh POR Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sere Type Type (in) (psi) Run Date Com 1� 4,259.3 3,500.6 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/2/2015 2 7,309.1 5,926.1 Camco MMG 1 1/2 GAS LIFT OV RK 0.313 0.0 12/5/2015 Notes:General&Safety i- < ° LOCATOR;7,758.3 End Date Annotation e' NOTE: a A SEAL ASSY;7758.8 'S S INTERMEDIATE;26.1-7686.0 SLOTS.8,562.0-12,102.0 ,+ w SLOTS;12,222.0-13,065.0 y SLOTS:13,2220-1J433.0 i I SLOTTED LINER:],730.9- , ` 13,476.0 ConocoPhillips Alaskan , P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 NOV 1 0 2016 November 5, 2016 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 SCAMEO % . 20i7, Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC,this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Roger Winter or Aaron Applehans at 907-659-7506, if you have any questions. Sincerely, ‘‘.reovje-- , Aaron Applehans ConocoPhillips Well Integrity Field Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 11/8/2016 3K-24,3K-27,2V-09,2S-1,2S-2,2S-3,2S-4,2N-314 Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 3K-24 50029229350000 1982490 NA NA NA NA 1.7 11/5/2016 3K-27 50029227510000 1970460 NA NA NA NA 3.4 11/5/2016 2V-09 50029213000000 1850370 NA NA NA NA 2 11/5/2016 2N-314 50103203550000 2001930 2' NA 2' NA 10.2 11/6/2016 2S-01 50103207270000 2152030 1.5' NA .98' 7/2/2016 2.55 11/6/2016 2S-02 50103207100000 2150700 2' NA 1' 7/2/2016 3.4 11/6/2016 2S-03 50103207290000 2152050 1.6' NA 1.04' 7/2/2016 3.4 11/6/2016 2S-04 50103207210000 2151590 2.3' NA 1.125' 7/2/2016 3.4 11/6/2016 STATE OF ALASKA Alt OIL AND GAS CONSERVATION COMIPSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon E PlugPerforations r Pull Tubing r Fracture Stimulate Operations shutdown F.- Performed:Performed. Sus endPerforateAlter Casing E r Other Stimulate r E Change Approved Program E Plug for Redrill r Perforate New Pool I— Repair Well F Re-enter Susp Well f Other: PROD to WAG (r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory E 215-159-0 3.Address: 6.API Number: Stratigraphic [ Service P. O. Box 100360, Anchorage, Alaska 99510 50-103-20721-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25603, 25590 KRU 2S-04 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 13505 feet Plugs(measured) None true vertical 6236 feet Junk(measured) None Effective Depth measured 6236 feet Packer(measured) 553, 7759 true vertical 6236 feet (true vertical) 553,6141 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 16 108' 108' SURFACE 2787' 10 3/4 2815' 2562' INTERMEDIATE 7860' 7 5/8 7886' 6185' SLOTTED LINER 5745' 4 1/2 13476' 6303' . RECEIVED NOV 0 8 2016 Perforation depth: Measured depth: 8562-12102,12222-13065, 13222-13433 True Vertical Depth: 6303-6256,6253-6239,6236-6237 AOG Tubing(size,grade,MD,and TVD) 3 1/2 ,L-80, 7758 MD,6141 TVD Packers&SSSV(type,MD,and TVD) SSSV= None NIPPLE=3-1/2"CAMCO DS NIPPLE W/2.875"PROFILE @ 553 MD and 553 TVD SEAL ASSY=BAKER 80-40 GBH LOCATOR SEAL ASSEMBLY @ 7759 MD and 6141 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED =_ ' ji°`'j' 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 456 333 440 978 252 Subsequent to operation 0 0 4296 793 710 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory fl Development I— Service F Stratigraphic r Copies of Logs and Surveys Run 16.Well Status after work: Oil E Gas E WDSPL Printed and Electronic Fracture Stimulation Data r GSTOR E WINJ E WAG F GINJ E SUSP E SPLUG E 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: 316-463 Contact Darrell Humphrey Email: n1139conocophillips.com Printed Name Darrell Humphre Title: NSK Production Engineering Specialist Signature \ Phone:659-7535 Date )(„6,, /44, Form 10-404 Revised 5/20 5 Submit Original Only 4,e1,2S7 Vn– 3/ '' /17 RBDMS Li EMtV142016 • . 2S-04 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/04/16 (ISW) : INITIAL STATE WITNESSED (CHUCK SCHEVE) MIT-IA(PASSED)TO 2110 PSI. 10/25/16 Convert to Produced Water Injection. Well brought online KUP PROD • 2S-04 ConocoPhillips t Well Attributes Max Angle&MD TD A.,-0 1;::,Illi:. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(kKB) Act Blm(11813) cvnocon+alis 501032072100 KUPARUK RIVER UNIT PROD 0.00 13,505.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 29-04,12/6/201512:01:23 PM SSSV:NIPPLE Last WO: 27.50 11/4/2015 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date _._...__Last Tag: Rev Reason:GLV C/O pproven 12/8/2015 ill Casing Strings ......_....................................................................._.. III .... ..........Casing Description OD(in) ID(in) Top(kits) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread rr CONDUCTOR 16 15.250 27.5 107.5 107.5 62.50 H-40 WELDED I 11 0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 10 3/4 9.950 28.4 2,815.0 2,562.2 45.50 L-80 HYD 563 HANGER;25.1®,,,,,,,,,,e e,,,,,uuttauully Casing Description 00(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Lan(I.,.Grade Top Thread INTERMEDIATE 7 5/8 6.875 26.1 7,886.0 6,184.9 29.70 LEO Hyd 563 'II Casing Description SLOTTED LINER OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread 41/2 3.958 7,730.9 13,476.0 6,236.7 11.60 L-80 IBTM Liner Details Nominal ID • Tap(ftKB) Top(TOD)(ftKB) Top Incl 7) Item Des Com (in) 7,730.9 6,130.5 66.46 PACKER HRD-E ZXP Liner top packer 5 1/2"x 7 5/8"L-80 5 5.740 DO Reducing(Tubing);69.4 1/2"Hydril 563 pin 7,750.6 6,138.3 67.10 NIPPLE RS packoff Seal Nipple 5 1/2"L-80 5 1/2"Hydril 563 4.940 box X box 7,753.4 6,139.4 67.19 HANGER DG Flex-Lock Liner hanger 5 1/2"x 7 5/8"L-80-5 4.830 1/2"Hydril 563 pin X pin •/-A/CONDUCTOR;27.5-107.5,vewtn. 7,763.1 6,143.1 67.50 LOCATOR NO GO XO-5 1/2"Hyddl 563 box X 5"Hydril 521 4.370 box 7,774.5 6,147.4 67.88 SBE Seal Bore Extension 80-40(4"ID)5"Hydril 521 pin x 4.000 NIPPLE;553.2 4 1/2"Hydril 521 box 8,546.9 6,301.6 83.26 SWELL 4-1/2"IBTM Swell Packer Baker 6.35"OD Assy A 3.960 PACKER (8520) Tubing Strings Tubing Description String Me...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TOD)(...Wt(lb/ft) Grade Top Connection TUBING 31/2 2.922 25.1 7,788.0 6,152.4 9.30 L-80 EUESrd SURFACE;26.4-2,615.0 Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 25.1 25.1 0.00 HANGER 4-1/2"Tubing Hanger with a 3.28'pup jt. 3.958 GAS LIFT;4,259.3 1 553.2 553.2 0.08 NIPPLE 3-1/2"Cameo DS Nipple w/2.875"Profile Ser#T061443 2.875- (540) 7,653.1 6,097.9 64.00'SLEEVE Baker CMU sliding sleeve(closed)with DS nipple w/ 2.812 2.812"(6096 TVD) 7,677.6' 6,108.5 64.75 NIPPLE Camco 2.75 D nipple 4.5"OD W/(RHC plug PULLED 11 2.750 10 15)-Ser#T051139(6107 TVD) 7,758.3 6,141.3 67.35 LOCATOR Baker Locator 3.000 GAS LIFT;7,309.1 1 7,758.8 6,141.4 67.36 SEAL ASSY Baker 80-40 GBH Locator Seal Assembly(-12 ft Seal to 3.000 Seal,36 ft for Seal travels) Perforations&Slots Shot Dens Top(TVD) BEe(TVD) (shotof SLEEVE;7,653.1 ' Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 8,562.0 12,102.0 6,303.3 6,256.5 10/31/2015 SLOTS SLOTTED LINER NIPPLE:7,677.6 12,222.0 13,065.0 6,253.3 6,239.2 10/31/2015 SLOTS 'SLOTTED LINER 13,222.0 13,433.0 6,236.0 6,237.1 10/31/2015 SLOTS SLOTTED LINER • Mandrel Inserts • St ati • on Top(TVD) Valve Latch Port Size TRO Run N Tap(ftKB) (ftKB) Make - Model OD(in) Sery Type Type (in) (psi) Run Date Com ;. ', _1 4,259.3 3,500.6 Camco MMG 11/2 GAS LIFT DMY RK 0.000 0.0 11/2/2015 2 7,309.1 5,926.1 Camco MMG 1 1/2 GAS LIFT OV RK 0.313 0.0 12/5/2015 Notes:General&Safety LOCATOR.7758.3 ' End Date Annotation a NOTE: O. I. 1'1 SEAL ASSY,7,758.8 I ■ Y }I Y INTERMEDIATE;28.1-7,888.0 SLOTS;8,562.0-12,102.0 SLOTS;12,222.0-13,065.0 SLOTS;13.222.0-13.433.0 SLOTTED LINER;7,730.9- 13,476.0 01 co • •• !.C) .0 — co co ~ > co Xo co N o L1? ani > ,- - h co v o ,_ +, t-- r— th o cc aJ C -o o4-4 N W W 0p ++ t0 > (0 (V 0-o a;e:; ( 9- 'B o — Y Q N O N z O ': ��,, E O�W — co u u > O . O a m v° y' a c c J Q CO CO CO CO CO CO L u L J CC N O a) o co o a) a) L ON CC (n (/) to N co V) ,;:."1-',g Cr ut VG) i_ N O Cr) O N +u' C 4/1 Z Q N N N441 u -O f0 LO y., O C u ~ y L, CO O ,...(13 :cc) -on-2 :2 Lt> C a) N u J J J J J J to C 4= O .. . } W W W W W W •N a1 '� U w H LL LL LL LL U.. LL +-' Q) 0) ti) D O Q J J J J J J a ID > C al Z c a Q Q z Q Q Q a) 0 c - 0. z z z z z z a) a. LL LL LL LL LL LL L -o _ > +° }' > c aa)) KC +., a s O ai E a u v U ., c O , t>a ~ = = a ~ c cua a o o CO ci O 0 £ z N Q a a v, CO. o co CV it L 0 p O O J Q LLco a1 G Wm a ics 2 00 a a U V gE E. 0 Q N '� d U cc J o Alv o0 > U Z W 8y : N V 4s m r�i m 0 cc p .4 O c-• z co CO W O ` t If at u g 4 zaM ' L `0 4t. l'-1104,-)-.1c`:":: 01 wcecececcce W W W W W W W > > > > > > t aCCWCCIXCLCC to II Z Y Y Y Y Y Y 0 C/ Q' W Q' a C W Q Q Q Q Q Q O > CrZi i4 LL a a a a a aa Y Y Y Y Y Y y C 0 u ,.....2 cotu f0 w COCr CO r co O) X cn .co N p co co co co co cc 0 0 0 0 0 0 E TIM M O 0 0 0 0 0 0 y 0 0 0 0 0 0 ijj GV v 0 0 0 U U U -a coN 00 CO 00 CO C se2 0 > c 0000 _Lisi , �. W O p p p O O C 0 Cte 53 0 0 0 0 0 0 C N. 0 0 0 0 0 0 00 -a v r) r) '0- E {n Or N- CO N N N ;� N NNNNNN O _ Sio M 0) 0 N ✓? OSi N 0 N 0 0 0 'y. (a 0 0 3 0 0 0 0 0 0 G. � c v) u') u) u) co u) Q Ou C L u) v A ) �i E a > 4, Oa U �+ Q l.,�W. E C J.1 z pj Q co o co co 0o 0 , n to t1 Z N d E� 0 to N N N N mum CL < a N —IW M N N N N N Vi Z H 6 0 COO a CO Q I= a a Q y of F • y\tel// ,�,$), THE STATE Alaska Oil and Gas w - F �t, ofQ LAsKA Conservation Commission ��i� �,� 1 � 1 333 West Seventh Avenue , , GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF ALA *� Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Darrell Humphrey NSK Production Engineering Specialist to FES ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2S-04 Permit to Drill Number: 215-159 Sundry Number: 316-463 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, G p444,7,4_______ Cath P. Foerster Chair DATED this day of September, 2016. RBDMS V/ SF'' 2 2 2016 III I RECEIVED STATE OF ALASKA SEP 12 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS O GCC 20 AAC 25.280 1.Type of Request: Abandon r Plug Perforations r Fracture Stimulate r Repair Well r Operations shutdown r Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved pproved Program r Rug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing r Other PROD to WAG fq ' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development 215-159-0 3.Address: Stratigraphic r Service f, 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-103-20721-00 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA Will planned perforations require spacing exception? Yes r No F ✓ KRU 2S-04 ^ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25603,25590 . Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective4Depth MD Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 13505 6236 ' 1A5c66?6' 1 6236'• 3800 None None Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 16 108' 108' SURFACE 2787' 10 3/4 2815' 2562' INTERMEDIATE 7860' 7 5/8 7886' 6185' SLOTTED LINER 5745' 4 1/2 13476' 6303' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8562-12102,12222-13065, 13222-13433• 6303-6256,6253-6239,6236-6237 3 1/2 L-80 7758 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) SSSV=None-3-1/2"CAMCO DS NIPPLE W/2.875"PROFILE d MD=553 TVD=553 Packer=HRD-E ZXP liner top packer . MD=7731 TVD=6130 12.Attachments: Proposal Summary r WellBore Schematic 1.7 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service FY• 14.Estimated Date for 15. Well Status after proposed work: CommencingOperations: 09/30/16 OIL r WINJ r r WDSPL r Suspended 16.Verbal Approval: Date: GAS r WAG Pr s GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17.I hereby certify that the foregoing is true Contact: Darrell Humphrey/Bob Christensen Printed Name Darrell Humphrey Phone:659-7535 Email: n1139@conocophillips.com ,^ Title: NSK Production Engineering Specialist Signature 111 Date: 9`S 1-1p I �"""rrr"`eee 006JJJ��\Xl Commi ion Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: `Lz_ Plug Integrity r BOP Test r Mechanical Integrity Test Location Clearance r Other: gl2ltb Post Initial Injection MIT Req'd? Yes No r Spacing Exception Required? Yes r No Subsequent Form Required: 0' ®'4T. RBDMS 1,VSEP 2 2 2016 ���//° APPROVED SI lib Approved b//,y:��/"G COMMISSIONER THE COMMISSION Dater �/�O / a/ aRvicalcNIALorA hSubmit Form and Form 10-403 Revise 11/2015 12 months from the date of approval. Attachments in Duplicate RECEIVED SEP 122.01C6 Darrell Humphrey/ ert Production Engineering Specialists. Greater Kuparuk Unit,NSK-69 PO Box 196105 ConocoPhil I i ps Anchorage,AK 99519-6105 Phone:(907)659-7535 Fax:659-7314 September 8,2016 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave. Ste. 100 Anchorage, AK 99501 Dear Commissioner, ConocoPhillips Alaska, Inc. requests approval to convert Kuparnk Well 2S-04 from Production service to Water Alternating Gas Injection service. / Enclosed you will find 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 2S-04 (PTD#215-159-0). If you have any questions regarding this matter, please contact myself or Robert Christensen at 659-7535. Sincerely, Darrell Humphrey Attachments Sundry application Proposal Summary Well schematic Area Map AOR Detail • • • 2S-04 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert Kupaurk River Well 2S-04 (PTD# 215-159-0) from Oil Production service to Water Alternating Gas Injection service as the pre-production period has been completed. Area of Review: Kuparuk River well 2S-04 was completed as an injector on November 4th 2015 to provide enhanced recovery inj- is o e - - . o increase t e u ima - .,- ' o of. e well was pre-produced for greater than 30 days and a 10-404 converting it to production was submitted 1/3/16/The pre-production period for this well has been completed. Converting this well to a WAG injector well will support existing 'A' sand producers 2S-11 and 2S-09 which is expected to be completed mid October 2016. The top of Kuparuk A4 sand was found at 8562' md, 6303' tvd. Area Map with 1/4 mile radius around target injection zone(see attached): The map attached shows that there are no additional production/injection wells located within a 1/4 mile radius of the 2S-04 penetrations of the Kuparuk interval. Mechanical Condition of Well to be Converted: The mechanical condition of Kuparuk well 2S-04 is good and is classified as a"Dual Casing -Single"well.The injection tubing/casing annulus is isolated via a HRD-E ZXP liner top packer located at 7731' and 6130'tvd). A State-witnessed MIT-IA will be performed once the well is converted to water injection, online, and stabilized. CBL and interpretation of the cement quality: Attached AOR detail The 24" Conductor was pre installed The 10-3/4" Surface casing was cemented with 1203 sx DeepCrete followed by 205 sx DeepCrete. The 7-5/8" Intermediate casing was cemented with 402 sx GasBLOK followed by 158 sx GasBLOK. j- coo cur, G' ei" was /ft- . rte! /0 1Q•gt ever. yo re v%GEV rs eCe5cafy. • 0 • « {\- ~ 2_ �} - : &S\ / $ # [ 2 £ ! 0 § : \ . E{e 0-E / \\\�\ }\ \ \ §z; » (•# .; `,..:r2 } \\ z - _ : ,p! :e.4 ƒ J ; $ / ( •••§ ! ! A \ \ ` ( \ w ƒ( 2•E6 E - V w g0 ` 0 � N O th 2LL a - w :-- co Ce w « E", \ \ 4. U \ } /\ ?A' \ k ;- § , , , § KUP PROD • 2S-04 • ConolcoPhillips a _ Well Attributes Max Angle&MD TD Alaska,Ir1C. Wellbore API/UWI Field Name Wellbore Status ncl I') MD(ftKB) Act Btm(560) 0,..00evt+mm 501032072100 KUPARUK RIVER UNIT PROD 0.00 13,505.0 °Su Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 20-04,1001201512:01.23 PM SSSV:NIPPLE Last WO: 27.50 11/4/2015 Vertical schematic(actual) - - - Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ................................................................_............................__.....................Last Tag: Rev Reason:GLV C/O pproven 12/8/2015 • Casing Strings - ...--.-.....--......--..-. .._J-. Casing Description OD(in) ID(in) Top(500) Set Depth(ftKB) Set Depth(TVD)... WI/Len II...Grade Top Thread CONDUCTOR 16 15.250 27.5 107.5 107.5 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 10 3/4 9.950 28.4 2,815.0 2,562.2 45.50 L-80 HYD 563 HANE'225.1 r.:na rrenrnc , Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread 0 ' Ill INTERMEDIATE 75/8 6.875 26.1 7,886.0 6,184.9 29.70 L80 Hyd 563 'I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread r 1. 1 SLOTTED LINER 4 1/2 3.958 7,730.9 13,476.0 6,236.7 11.60 L-80 IBTM t ' Liner Details [J Nominal ID Top(ftKB) Top(NInd(° D)(ftKB) Top In ) Item Des Com (in) 7,730.9 6,130.5 66.46 PACKER HRD-E ZXP Liner top packer 5 1/2"x 7 5/8"L-80 5 5.740 XO Reducing(Tubing);69.4 1/2"Hydril 563 pin 7,750.6 6,138.3 67.10 NIPPLE RS packoff Seal Nipple 5 1/2"L-80 5 1/2"Hydril 563 4.940 boxX box 7,753.4 6,139.4 67.19 HANGER DG Flex-Lock Liner hanger 5 1/2"x 7 5/8"L-80-5 4.830 1/2"Hydril 563 pin X pin CONDUCTOR;215-107.5 - - - - 7,763.1 6,143.1 67.50 LOCATOR NO GO XO-5 1/2"Hydril 563 box X 5"Hydril 521 4.370 box 7,774.5 6,147.4 67.88 SBE Seal Bore Extension 80-40(4"ID)5"Hydril 521 pin x 4.000 NIPPLE;5532 4 1/2"Hydril 521 box ! 8,546.9 6,301.6 83.26 SWELL 4-1/2"IBTM Swell Packer Baker 6.35"OD AssyA 3.960 PACKER (8520) Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)I...Wt(Ib/ft) Grade Top Connection TUBING 31/2 2.922 25.1 7,788.0 6,152.4 9.30 L-80 EUEBrd SURFACE;28.4-2,875.0 Completion Details Nominal ID Top(865) Top(ND)(ftKB) Top Incl 7) Item Des Com lin) 25.1 25.1 0.00 HANGER 4-1/2"Tubing Hanger with a 3.28'pup jt. 3.958 GAS LIFT;4,259.3 1 1 553.2 553.2 0.08 NIPPLE 3-1/2"Camco DS Nipple w/2.875"Profile Ser#T061443 2.875 I (540) 7,653.1 6,097.9 64.00 SLEEVE Baker CMU sliding sleeve(closed)with DS nipple w/ 2.812 2.812"(6096 TVD) 7,677.6 6,108.5 64.75 NIPPLE Camco 2.75 D nipple 4.5"OD W/(RHC plug PULLED 11 2.750 I 10 15)-Ser#T051139(6107 TVD) 7,758.3 6,141.3 67.35 LOCATOR Baker Locator 3.000 GAS LIFT,7,309.1 111 7,758.8 6,141.4 67.36 SEAL ASSY Baker 80-40 GBH Locator Seal Assembly(-12 ft Seal l0 3.000 Seal,36 ft for Seal travels) Perforations&Slots I Shot Dens Top(ND) etm(ND) (shots# SLEEVE;7,6531 Top(ftKB) Btm(860) (ftKB) (ftKB) Zone Date t) Type Corn I 8,562.0 12,102.0 6,303.3 6,256.5 10/31/2015 SLOTS SLOTTED LINER NIPPLE;7,677.6 ' 12,222.0 13,065.0 6,253.3 6,2392 10/31/2015 SLOTS SLOTTED LINER 13,222.0 13,433.0 6,236.0 6,237.1 10/31/2015 SLOTS SLOTTED LINER I. Mandrel Inserts St ati on Top(ND) Valve Latch Port Size TRO Run N, Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com I i 1 4,259.3 3,500.6 Camco MMG 11/2 GAS LIFT DMY RK 0.000 0.0 11/2/2015 2 7,309.1 5,926.1 Camco MMG 1 1/2 GAS LIFT OV RK 0.313 0.0 12/5/2015 LOCATOR;7,758.3 II' Notes:General&Safety End Date Annotation I NOTE: i SEAL ASSY;7,758.8 1 I 7 Y }I i INTERMEDIATE;26.1-7,886.0 SLOTS;8,562.0-12.102.0 �I � SLOTS;12,222.0-13,065.0 SLOTS;13,222.0-13,433.0 SLOTTED LINER;7, 13,476.0,476,8 • • 31Aug16 ConocoPhillips 2S-04 Alaska, Inc. 10-403 Sundry AN 0 0.1 0.2 0.3 0.4Miles ADL025590 ADL025589 2S-11 :709 ...... \\ 1 2S04 t , t t t , t I t , t I 1 10N- :E ; , , , , , , I 2S-04PB1 ZS it 0 t , , 400/ t t , t , r ADL025603 t t. ADL025604 --2S-04 Open Interval —2S-04 Trajectory ❑1/4 Mi. Radius -- Offset Planned Well — Offset Well .;Well Pad • • r Bettis, Patricia K (DOA) From: NSK Prod Engr Specialist <n1139@conocophillips.com> Sent: Tuesday, September 13, 2016 11:45 AM To: Bettis, Patricia K (DOA) Subject: RE: KRU 2S-04 (PTD 215-159): Sundry Application Patricia-This is what I found. The 6236 MD number should be the TVD and was inadvertently listed as MD.This depth was the TVD depth for 13505' MD taken from the Well Completion Report. Please Change the effective depth to 13505' MD, 6236'TVD. Thanks for catching this. Darrell Humphrey/ Bob Christensen Production Engineering Specialist Conocophillips Alaska Inc. n1139Pconocophillips.com Office (907) 659-7535 Pager(907) 659-7000#924 From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent:Tuesday, September 13, 2016 11:04 AM To: NSK Prod Engr Specialist<n1139@conocophillips.com> Subject: [EXTERNAL]KRU 25-04 (PTD 215-159): Sundry Application Good morning Darrell, On Form 10-403, Box 11, please verify the effective depth in measured depth for KRU 2S-04. As stated on Form 10-403, the effective depth is 6,236' MD. However, on the wellbore schematic, bottom of the slotted liner is shown as 13,433' MD. Appreciate your help. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • prp Is-- Loepp, Victoria T (DOA) From: Voss, Jake <Jake.Voss@conocophillips.com> Sent: Monday, October 12, 2015 1:48 PM To: Loepp, Victoria T (DOA); Callahan, Mike S; Bearden,J Daniel; Herbert, Frederick 0 Subject: PTD#215-159: 2S-04 Attachments: 2S-04 Current Schematic_10-12.pdf Follow Up Flag: Follow up Flag Status: Flagged Good afternoon Victoria, Here is a current update/plan forward for PTD#215-159: Well 2S-04. After pumping the second isolation plug,we healed up losses and achieved a 12.5 ppg FIT. We attempted a kickoff plug that swapped with our mud so we pumped a second plug this morning with favorable results. (Updated schematic attached) Plan forward is to tag the TOC with this cement plug and re-drill the 9-7/8" Intermediate hole, enlarged to 11"with an under reamer. Since our initial LOT on the 10-3/4"Surface Shoe was a 14.95 ppg and we performed an FIT on the shoe after the 2nd isolation plug,we feel we have proven the integrity of the shoe to drill ahead once we kick off. If you have any questions/comments, please let me know. Thanks, Jake Voss Sr Drilling Engineer ConocoPhillips Alaska (Office:(907)265-6935 Mobile: (832)-499-9085 SCANNED JAN 1 $:2417 1 • 2S-04 — 10/12/15 • Grassroots Horizontal A-Sand Injector ConocoPhillips Proposed Wellbore Schematic(Topset) CAMERON Last Edited:Voss-10/12/2015 16"Conductor to-115' 13.5"Surface Hole Surface Casing 10-3/4"45.5#L-80 Hydril563 2,815'MD/2,562'TVD FIT=14.95 ppg EMW(9/23/15) FIT= 12.5 ppg EMW(10/11/15) 17 ppg Cement Kickoff Plug(Plug#6) Set et3,226'MD-2,626'MD 9-7/8"Intermediate Hole 30 bbl HI-Vis Pill Set at 3,506'MD-3,226'MD 17 ppg Cement Kickoff Plug(Plug#4) - I Fell past 3,500'MD-new JC Unkown ECP for Kick off Plug ,.3 Originally set at 3,231'MD,but fell-new Depth Unknown 'D 15.8 ppg Cement Isolation Plug(Plug#3) 3 Estimated TOC at 4,877'MD(158'above Plug#2) r f— C-50:4,987'MD!4,213'TVD 15.8 ppg Cement Isolation Plug(Plug#2) TOC at 5,005'MD(600'above C-37) ECP at 5,594'Mrs!Element at 5,600'MD) C-37:5,612'MD/4,782'TVD Original Estimated Loss zone between C-37 and Bermuda Growler(Iceberg):5,748'MD/4,906'TVD 3-1/2"Cement Stinger cemented in hole Top of Fish at 5,745'MD Top of cement in Stinger=5,957'MD 15.8 ppg Cement Abandonment Plug(Plug#1) Est Top=6,407 MD Bermuda/Caim:6,426'MD/5,478'TVD HRZ:7,180'MD/5,977'TVD Depth: 7,800'MD/6,241'TVD Gas Zone somewhere in the Kalubik Kalubik:7,455'MD/6,106'TVD - Kuparuk Top(Predicted)-6,275'TVD(34'TVD Below TD) • • 0 o .- c N I 0d - oJ oJC o O (U lU NO CD o } \j --c o g o o a c - -oo -oo at c U m 2 NI NI NI NI tuI 2 a�)I a�1 D �I Q co Q rn Q Q o c c co a m O.. co a 0_ .t a)I -o -0 0 0 6" it) ��� 0 U= U _ U 0 c p t) 0 0 ti to ! a� o o ui- I f) `0 0 CC tY Z Z E 1 E 1 E E E > 0 J v o v 0 a I a 1 7 @N Co,— @ Co O 'j E 0 O OU) Ot/) a a) c < ct c <mi a_ci 0 0 2 W w W o w2 ch WI too WU) Q C N LL m LL m LL m LL U NI N NIC CVCVNIp NIO NI> NI> '2 2"U — a) O_ 0 NIL' N a 0_W1 0_ o LL o LL NI a CN 0_NI 0_ NI J a) o too c.>- u) I (no U Z U o U 0 U I U I U I U 1 c m m o m w m e) m o O o 0 o a) o a) 0 u) a N 6_ uiw uito 6a 6a ilia oa X0 0 m (7 m o 0 0 0 0 0o o Z o d p 0 O o p 0 O 0 LL LL 0 LL 0 LL 0 LL 0 Eo E0 o W oCC UW U W 0> o W O W oW V(n vN Ufn Q I o I I I o 0 0 0 Y y E 'c— c ,- c 0 c ,- c,- cr- c.- c 0 'c 0 'c 0 'c 0 w CDO om Opp O W Opp Om om Opp O W O W 2W Il 2111 N !, V 15 CL va v I va 15 a. 15 a_ 15 CL U I 15 ,_I v ,_Ip 15 ,-I..._ Q N-I a)�I Nm OSI --1 N-I (USI Om a)co Nppa 0 in w Ce c WO WO WG_ WO WO WO WO WaLL iii CL WO_ o) a]CL 0) (U O u a 0 c V LO Lt) cn in in in Lr) c0 i0 c0 Om Y > 0 0 0 0 0 0 0 0 0 0 o J .@. 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LU w w w w w w I� ? 0 d 0 0 0 CC • • 0 I O 7:::1 O N 9 06 Na) N 0 'C na N } Q r, U o b 6 1 in0 Z 11, II Y. a 1 J_ 1 O Z co 41 CO 03 Inn U) Ce a .c- c O a Om J W = IJJ 0 C.) v o Z Q o N J a :° O Cl) o a ON p. 00 E N V N U c 00 `'" V a) I! I 0 —I E I 00 Q a a CO tN 5— Z 0 i� GN > co • N w Cn co co D 0 ICC a o o II QC a o D £ o co Z m 3 co N co a) > 11`I m 3 N N I d c 1 I d' el a o a c w U E y £ •Q U d E E d a Cl 0 0 ''c. STATE OF ALASKA ALA.OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well ("Other WINJ to Prod .57 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 215-159-0 3.Address: Service 6.API Number: Stratigraphic r 50-103-20721-00 P. O. Box 100360,Anchorage,Alaska 99510 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25603,25590 KRU2S-04 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 13505 feet Plugs(measured) None true vertical 6236 feet Junk(measured) None Effective Depth measured 6236 feet Packer(measured) 7731 true vertical 6236 feet (true vertical) 6130 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 107 107 0 0 SURFACE 2787 10.75 2815 2562 0 0 INTERMEDIATE 7860 7.625 7886 6185 0 0 SLOTTED LINER 5745 4.5 13476 6237 0 0 0 0 0 o 0 0 Perforation depth: Measured depth: 8562-12102,12222-13065, 13222-13433 True Vertical Depth: 6303-6256, 6253-6239, 6236-6237 G V E{V E D JAN052016 Tubing(size,grade,MD,and TVD) 3.5", L80, 7788'MD,6152'TVD Packers&SSSV(type,MD,and TVD) SSSV=NONE, PACKER= HRD-E ZXP @ 7731 MD,6130 TVD _AOGCG 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 0 Subsequent to operation 1517 1296 1267 1439 388 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Darrell Humphrey/Bob Christensen Email n1 139Conocophillips.com Printed Nae Darrell Humphrey Title NSK Production Engineering Specialist z. Signature 4 Phone:907-659-7535 Date / ` /_ 1P 1771._ i/l3/!. /4 0, 4 )c/ Form 10-404 Revised 5/2015 RBDMS JAN 0 5 2016 Submit Original Only --.. • • 2S-04 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 12/06/15 Open well to production. Pre-produce for greater than 30 days of -.r KUP PROD • 2S-04 ConocoPhillips , +a 1 `„ Well Attributes Max Angie&MD TD 1 Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Blm(ftKB) Alaska,Inc. 501032072100 KUPARUK RIVER UNIT PROD 0.00 13,505.0 ,= ['oPNa1pS -„ Comment IH2S(ppm) (Date Annotation /End Date KB-Grd(ft) Rig Release Date 25-04,12/8/2015 12'.01:23 PM SSSV:NIPPLE l Last WO: 27.50 11/4/2015 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:GLV C/O pproven 12/8/2015 Casing Strings .,___.. ..... it _---. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.250 27.5 107.5 107.5 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread SURFACE 10 3/4 9.950 28.4 2,815.0 2,562.2 45.50 L-80 HYD 563 HANGER 251. Dinar NI ri n a.'. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ,r I INTERMEDIATE 7 5/8 6.875 26.1 7,886.0 6,184.9 29.70 L80 Hyd 563 li it I Casing Description OD(in) 10(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD) Wt/Len(I.. Grade Top Thread I 1,1 l SLOTTED LINER 4 1(2 3.958 7,730.9 13,476.0 6,236.7 11.60 L-80 IBTM Liner Details Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com Nominal ID 7,730.9 6,130.5 66.46 PACKER HRD-E ZXP Liner top packer 5 1/2"x 7 5/8"L-80 5 5.740 XO Reducing(Tubing);69.4 'I 1/2"Hydril 563 pin 7,750.6 6,138.3 67.10 NIPPLE RS packet(Seal Nipple 5 1/2"L-80 5 1(2"Hydril 563 4.940 box X box 7,753.4 6,139.4 67.19 HANGER DG Flex-Lock Liner hanger 5 1/2"x 7 5/8"L-80-5 4.830 1/2"Hydril 563 pin X pin CONDUCTOR 27 5-toz5 - - - - 7,763.1 6,143.1 67.50 LOCATOR NO GO XO-5 ill"Hydril 563 boxX 5"Hydril 521 4.370 box 1 7,774.5 6,147.4 67.88 SBE Seal Bore Extension 80-40(4"ID)5"Hydril 521 pin x 4.000 NIPPLE',5532 '- 4 1/2"Hydril 521 box 8,546.9 6,301.6 83.26 SWELL 4-1(2"IBTM Swell Packer Baker 6.35"OD AssyA 3.960 PACKER (8520) Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/fl) Grade Top Connection TUBING 31/2 2.922 25.1 7,788.0 6,152.4 9.30 L-80 EUE8rd Completion Details SURFACE;28.4-2,815.0 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 1 25.1 25.1 0.00 HANGER 4-10"Tubing Hanger with a 3.28'pup jt. 3.958 GAS LIFT 4,259.3 , 553.2 553.2 0.08 NIPPLE 3-10"Camco DS Nipple w/2.875"Profile Ser#T061443 2.875 1 (540) 7,653.1 6,097.9 64.00 SLEEVE Baker CMU sliding sleeve(closed)with DS nipple wl 2.812 2.812"(6096 TVD) 7,677.6 6,108.5 64.75 NIPPLE Camco 2.75 D nipple 4.5"OD WI(RI-IC plug PULLED 11 2.750 10 15)-Ser#T051139(6107 TVD) II 7,758.3 6,141.3 67.35 LOCATOR Baker Locator 3.000 GAS LIFT;7,309.1 - 7,758.8 6,141.4 67.36 SEAL ASSY Baker 80-40 GBH Locator Seal Assembly(-12 ft Seal to 3.000 1jSeal,36 ft for Seal travels) I Perforations&Slots Shot Dens Top(ND) 8tm(TVD) (shets/f SLEEVE;7,653.1 I, Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 1 8,562.0 12,102.0 6,303.3 6,256.5 10131/2015 SLOTS SLOTTED LINER NIPPLE;7,677.6 _ 12,222.0 13,065.0 6,253.3 6,239.2 10/31/2015 SLOTS SLOTTED LINER 13,222.0 13,433.0 6,236.0 6,237.1 10/31/2015 SLOTS SLOTTED LINER Mandrel Inserts St onl Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com I 1 4,259.3 3,500.6 Camco MMG 1 1(2 GAS LIFT DMY RK 0.000 0.0 11/20015 I{ 2 7,309.1 5,926.1 Camco MMG 1 1/2 GAS LIFT OV RK 0.313 0.0 12(5/2015 Notes::General&Safety End Date Annotation LOCATOR;7,758.3 ■ NOTE: a SEAL ASSY;7,758.8 1 Y I I INTERMEDIATE;26.1-7,886 0 SLOTS;8,562.0-12,102.0 -I SLOTS,12,222.0-13,065.0 SLOTS;13222.0-13433.0 I 1 SLOTTED LINER;7,730.9- 13,476 0 ReCEIVED • STATE • OF ALASKA DEC 0 7 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil❑ Gas SPLUG❑ Other ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ CI WAG❑ WDSPL❑ No.of Completions: Service El Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp.,Susp3 or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. .Aband.: 11/M2015 µG 215-159/ • 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 7 9/18/2015 50-103-20721-00-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 3031 FNL, 1349 FEL, Sec 17,T1ON, R8E, UM •10/27/2015 KRU 2S-04/2S-04PB1 Top of Productive Interval: 9. Ref Elevations: KB:147... 17. Field/Pool(s): 2762 FNL,3379 FEL, Sec 17,T1ON, R8E, UM GL: 27!3" 120104.13F: Kuparuk River Field/Kuparuk River Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 3310 FNL, 1797 FEL, Sec 8,T1ON, R8E, UM n/a ADL 25603,25590 . 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 481221 y- 5930017 Zone-4 13505/6236 2677,2676 TPI: x- 479192 y- 5930291 Zone-4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 480771 y- 5935018 Zone-4 No SSSV 1400/1388 5. Directional or Inclination Survey: Yes 0 (attached) No El 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 n/a (ft MSL) I n/a 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension, or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance,dipmeter,formation tester,temperature,cement evaluation, casing collar locator,jewelry, and perforation record. Acronyms may be used.Attach a separate page if necessary GR/Res/Mud Log/Porosity,CBL NW/Pe41 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 16 62.5 H-40 28 107 28 107 24 Pre-installed 10.75 45.5 L-80 28 2815 28 2562 13.5 405 bbl 11 ppg&66 bbl 12ppg 7.625 29.7 L-80 26.1 7886 26.1 6185 9.875 1st 95 bbl 16ppg,2nd 42 bbl 16 ppg 4.5 11.6 L-80 7731 13476 6130 6237 6.75 slotted liner 24. Open to production or injection? Yes 0 No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3.5 7788 7731/6130 Slotted Liner from 8562-12102=MD,6303-6256=TVD Slotted Liner from 12222-13065=MD,6253-6239=TVD 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. Slotted Liner from 13222-13433=MD,6236-6237=TVD Was hydraulic fracturing used during completion? Yes El No 0 Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): waiting for facility hook-up Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period -0 - Flow Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate - Form 10-407 Revised 11/2015 � ��Z�/J1( CONTINUEDyQNN PAGE 2 RBDM� , DEC 0 9 2015 Submit ORIGINIAL onl • 28. CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No 0 If Yes, list formations and intervals cored(MD/TVD, From/To), and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 0 Permafrost-Top Surface Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1400 1388 Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval gS 10 629" ',ha information, including reports,per 20 AAC 25.071. Top WSAK(WSAK D) 1895 Upper Kalubik 7646 6096 Lower Kalubik 7884 6185 Kuparuk A4 8510 6297 TD(Kuparuk A4) 13505 See additional chart attached 2S-04PB1 Total Dept 7800 6240 Formation at total depth: Kuparuk A4 31. List of Attachments: Cement Detail Report,Schematic, Daily Operations Summary, Definitive Survey Report 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. � � L Contact: Mike Callahan @ 263-4180 Email: Mike.Callahan@cop.com 6 �t /d/-7/), Printed Name: G.L.Alvorrd /nTitle: Alaska Drilling Manager 4..e.Signature: ..4.arA Phone: 265-6120 Date: 1247/1-4 15— INSTRUCTIONS SINSTRUCTIONS 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 1a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible,Water Injection, Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram, summary of daily well operations,directional or inclination survey, and other tests as required including, but not limited to: core analysis,paleontological report, production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only 0 s r Cb 00 00 M 00 OD W OD 0 0 a— 0 00X3% 100 tim (0 (00 OD 0 go N 1D GO em N V' 10 (0wOD coOD OD OD 0 1D O 1D eO 1D VI P. P. 00 ti 00a0e. Oil. h. Ci 00 h. ODCbCI OD e+f 0010 001. eD0 'lNNNN N %— e• N Nat 1D PO OD tO OD OD <D 0100 0erNOD d 4") 10010 ea 00Mm0CD C4 am 0mf00t. Nt. 02elaUIYi CI OO e- rN elleNN . 000000 VI e. i . E LL O 0 O • r 0) L a) c o Q) t I M I M CIi I11 H1I E camr � LUQ ¢ a) Q 0. rsi J 2 E 2 fl Y a. .0+.- Jia UUS =.2 1-- 1 I •1 I 0 . I- O N 1 i N LL 3 KUP PRODir- • 2S-04 ConocoPhillipsn Well Attributes Max Angle&MD TD Alaska inGWellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) ,..„,„..40,.., / 501032072100 KUPARUK RIVER UNIT PROD 0.00 13,505.0 ..- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 28-04.12/1/20153.34:52 PM SSSV NIPPLE Last WO: 27.50 11/4/2015 Vortical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date __ ._.__.... __.........__...,.._. Last Tag: Rev Reason: NEW WELL,GLV C/O lehallf 11/18/2015 Casing Strings ..............._..........._....................................................._. ....................._..Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.250 27.5 107.5 107.5 62.50 H-40 WELDED , Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread SURFACE 10 3/4 9.950 28.4 2,815.0 2,562.2 45.50 L-80 HYD 563 ', Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade 'Top Thread INTERMEDIATE 75/8 6.875 26.1 7,886.0 6,184.9 29.70 L80 Hyd 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SLOTTED LINER 4 1/2 1958 7,730.9 13,476.0 6,236.7 11.60 L-80 IBTM II Liner Details 1 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 7,730.9 6,130.5 66.46 PACKER HRD-E 2:XP Liner top packer 5 1/2"x 7 5/8"L-80 5 5.740 XO Reducing(Tubing);69.4 1 1/2"Hydril 563 pin 7,750.6 6,138.3 67.10 NIPPLE RS packoff Seal Nipple 5 1/2"L-80 5 1/2"Hydril 563 4.940 box X box 7,753.4' 6,139.4 67.19 HANGER DG Flex-Lock Liner hanger 5 1/2"x 7 5/8"L-80-5 4.830 1/2"Hydril 563 pin X pin '�n1CONDUCTOR;27.5-107.5 7,763.1 6,143.1 67.50 LOCATOR NO GO XO-51/2"Hydril 563 box X 5"Hydril 521 4.370 box I 7,774.5 6,147.4 67.88 SBE Seal Bore Extension 80-40(4"ID)5"Hydril 521 pin x 4.000 NIPPLE;5532 4 1/2"Hydril 521 box € 8,546.9 6,301.6 83.26 SWELL 4-1/2"IBTM Swell Packer Baker 6.35"OD Assy A 3.960 PACKER (8520) Tubing Strings Tubing Description Stnng Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ibltt) Grade Top Connection TUBING 31/2 2.922 25.1 7,788.0 6,152.4 9.30 L-80 EUE8rd SURFACE;20.4-2,a1s.0 Completion Details Nominal ID Top(NCB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 25.1 25.1 0.00 HANGER 4-1/2"Tubing Hanger with a 3.28'pup jt. 3.958 GAS LIFT;4,259.3 I: 553.2 5532 0.08 NIPPLE 3-1/2"Camco DS Nipple w/2.875"Profile Ser#1061443 2.875 (540) 17,653.1 6,097.9 64.00 SLEEVE Baker CMU sliding sleeve(closed)with DS nipple w/ 2.812 2.812"(6096 TVD) 7,677.6 6,108.5 64.75 NIPPLE Camco 2.75 D nipple 4.5"OD W/(RHC plug PULLED 1) 2.750 3.000 10)5)-Ser#7051139(6107 TVD) * 7,758.3 6,141.3 67.35 LOCATOR Baker Locator GAS LIFT:7,309.1 ! 7,758.8 6,141.4 67.36 SEAL ASSY Baker 80-40 GBH Locator Seal Assembly(-12 ft Seal to 3.000 ISeal,36 ft for Seal travels) Perforations&Slots Shot Dens Top(TVD) Bim(TVD) (shots/f SLEEVE;7653.1 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com tl 8,562.0 12,102.0 6,303.3 6,256.5 10/31/2015 SLOTS SLOTTED LINER NIPPLE,7,677.6 12,222.0 13,065.0 6,253.3 6,239.2 10/31/2015 SLOTS SLOTTED LINER I. 13,222.0 13,433.0 6,236.0 6,237.1 10/31/2015 SLOTS SLOTTED LINER Mandrel Inserts st f ati )I on Top(TVD) N Valve Latch Port Sin TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sen Type Type (in) (psi) Run Date Com I I,, 1 4,259.3 3,500.6 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/2/2015 I, 2 7,309.1 5,926.1 Cameo MMG 1 1/2 GAS LIFT OV RK 0.313 0.0 11/10/2015 LOCATOR;77583Notes:General&Safety IlilEnd Date NOTE: Annotation SEAL ASSY;7,758.0 1. 4 Y I11 7 INTERMEDIATE;28.1-7,886.0 I � •._SLOTS;8,562.0-12,102.0 1 1 SLOTS;12,222.0-13,065.0 I SLOTS;13,222.0-13,433.0 SLOTTED LINER;7.730.9- 13,476.0 00 Iperations Summary (with Timelogtpths) EC,E'V 2S-04 DEC 18 2015 Conoco`Phif laps AOGC AP:r.An Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/17/2015 9/17/2015 1.00 MIRU MOVE MOB P PJSM for rig move with Peak&hook 0.0 0.0 06:00 07:00 up trucks to move. 9/17/2015 9/17/2015 1.00 MIRU MOVE MOB P Move pipe sheds&rock washer, 0.0 0.0 07:00 08:00 spotting out of way. 9/17/2015 9/17/2015 0.75 MIRU MOVE MOB P Move boiler,motor,pump,&pits 0.0 0.0 08:00 08:45 modules out of way to move sub base. 9/17/2015 9/17/2015 0.50 MIRU MOVE MOB P PJSM;hook up cold start generator to 0.0 0.0 08:45 09:15 sub base. 9/17/2015 9/17/2015 0.50 MIRU MOVE MOB P Move sub base off of 2S-10. 0.0 0.0 09:15 09:45 9/17/2015 9/17/2015 0.50 MIRU MOVE MOB P Move mats from 2S-10 to 2S-04 for 0.0 0.0 09:45 10:15 sub base. 9/17/2015 9/17/2015 1.50 MIRU MOVE MOB P Move sub base down well row to 0.0 0.0 10:15 11:45 position for spotting on 2S-04. 9/17/2015 9/17/2015 0.50 MIRU MOVE MOB P Lay mats for rig modules. 0.0 0.0 11:45 12:15 9/17/2015 9/17/2015 1.50 MIRU MOVE MOB P Spot pits,pump,motor,&boiler 0.0 0.0 12:15 13:45 modules. 9/17/2015 9/17/2015 1.50 MIRU MOVE MOB P Lay mats for pipe sheds.Spot pipe 0.0 0.0 13:45 15:15 sheds&rock washer. 9/17/2015 9/17/2015 2.75 MIRU MOVE RURD P PJSM;work on rig acceptance 0.0 0.0 15:15 18:00 checklist.Spot&berm Envirovac. Level pipe sheds.Calibrate&test gas alarms.Rig up skate to rig floor. Hook up&energize steam,air,water& electrical.Spot Tioga heater to pipe shed.Rig accepted @ 18:00 hrs. 9/17/2015 9/17/2015 3.25 MIRU MOVE NUND P PJSM;nipple up diverter system. 0.0 0.0 18:00 21:15 Energize seals on diverter adapter. Test between seals to 500 psi for 5 min.SIMOPS take on spud mud. 9/17/2015 9/17/2015 0.75 MIRU MOVE RURD P PJSM;moblize 5"handling epuipment 0.0 0.0 21:15 22:00 to rig floor&install.Lay down 4" handling equipment. 9/17/2015 9/17/2015 1.00 MIRU MOVE SVRG P PJSM;service rig,grease TD,grease 0.0 0.0 22:00 23:00 swivel,MP2 on TD. 9/17/2015 9/18/2015 1.00 MIRU MOVE BOPE P PJSM;perform diverter test,knife 0.0 0.0 23:00 00:00 valve open in 10 sec,annular closed in 25 sec.Accumulator test;system pressure 3000 psi,pressure after closure 1800,200 psi recharge time 42 sec,full recharge time 178 sec.5 nitrogen bottles averaged 1975 psi. Tested gas&pit level(gain/loss) alarms,good.Witnessed waived by AOGCC Rep Bob Noble. 9/18/2015 9/18/2015 4.50 MIRU MOVE PULD P PJSM,P/U 27 stands of 5"drill pipe 0.0 0.0 00:00 04:30 and 6 stands of 5"HWDP and stand back in derrick.(Tag bottom @ 92' MD) 9/18/2015 9/18/2015 0.50 MIRU MOVE RURD P L/D mouse hole and clear rig floor. 0.0 0.0 04:30 05:00 9/18/2015 9/18/2015 1.25 MIRU MOVE BHAH P PJSM, P/U SLB BHA tools f/beaver 0.0 0.0 05:00 06:15 slide. 9/18/2015 9/18/2015 2.00 MIRU MOVE BHAH P PJSM, M/U BHA#1 as per SLB rep. 0.0 87.0 06:15 08:15 Page 1/49 Report Printed: 12/18/2015 exkl •perations Summary (with Timelogitpths) 0 2S-04 C000co`Phillips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/18/2015 9/18/2015 3.25 MIRU MOVE RGRP T Attempt to fill lines w/mud. Unable to 87.0 87.0 08:15 11:30 pump.Shut down and troubleshoot rig pumps. Rig pumps had gravel/rocks in valves and seats.Take pumps apart and clean pumps and suction screen pods. 9/18/2015 9/18/2015 0.25 MIRU MOVE SEQP P Flood conductor and pressure test 87.0 87.0 11:30 11:45 lines to 3500 psi,good. 9/18/2015 9/18/2015 1.25 SURFAC DRILL DDRL P Drilled 13-1/2"surface hole f/107'- 87.0 182.0 11:45 13:00 182'MD, 182'TVD.ADT 1.07, Bit hours 1.07,Total Jar hrs 0,PU 50K, SO 50K,ROT 50K,Tq 2K on, 1K off, ECD 10.29,FO 32%,WOB 3-8K,50 rpm,450 gpm,320 psi,max gas 0. 9/18/2015 9/18/2015 0.50 SURFAC DRILL TRIP P PJSM;TOH f/182'-82'MD. 182.0 82.0 13:00 13:30 9/18/2015 9/18/2015 1.00 SURFAC DRILL BHAH P PJSM;pick up 3 joints of NMFC,f/82'- 82.0 182.0 13:30 14:30 182'MD. 9/18/2015 9/18/2015 3.50 SURFAC DRILL DDRL P Drilled 13-1/2"surface hole f/182'- 182.0 455.0 14:30 18:00 455'MD,455'TVD.ADT 3.48, Bit hours 4.55,Total Jar hrs 22.29, PU 62K,SO 65K,ROT 64K,Tq 2K on, 1K off,ECD 10.29,FO 82%,WOB 10- 15K,60 rpm,550 gpm,600 psi,max gas 0. 9/18/2015 9/19/2015 6.00 SURFAC DRILL DDRL P Drilled 13-1/2"surface hole f/455'- 455.0 770.0 18:00 00:00 770'MD,770'TVD.ADT 2.3,AST 1.5, Bit hours 8.35,Total Jar hrs 26.09,PU 70K,SO 73K,ROT 73K,Tq 2K on, 1K off,ECD 10.34,FO 71%,WOB 15- 25K,60 rpm,550 gpm,900 psi,max gas 0. 9/19/2015 9/19/2015 6.00 SURFAC DRILL DDRL P Drilled 13-1/2"surface hole f/770'- 770.0 1,230.0 00:00 06:00 1230'MD, 1225'TVD.AST 2.55,ADT 3.89,Bit hours 12.24,Total Jar hrs 29.98,PU 78K,SO 77K, ROT 78K,Tq 1.5K on, 1-3K off, ECD 10.48,FO 42%,WOB 10-15K,60 rpm,660 gpm, 1190 psi,max gas 0.Total Footage 460'. 9/19/2015 9/19/2015 6.00 SURFAC DRILL DDRL P Drilled 13-1/2"surface hole f/1230'- 1,230.0 1,659.0 06:00 12:00 1691'MD, 1659'TVD.AST 1.23,ADT 3.7,Bit hours 15.94,Total Jar hrs 33.68,PU 88K,SO 84K,ROT 87K,Tq 2-4K on,0-2K off,ECD 10.6, FO 40%, WOB 10-15K,60 rpm,630 gpm, 1180 psi,max gas 0.Total Footage 461'. Spill Drill CRT 87 sec @ 11:30 hrs. 9/19/2015 9/19/2015 6.00 SURFAC DRILL DDRL P Drilled 13-1/2"surface hole f/1691'- 1,659.0 2,252.0 12:00 18:00 2252'MD,2147'TVD.AST 2.3,ADT 1.8, Bit hours 20.05,Total Jar hrs 37.79, PU 97K,SO 91K,ROT 94K,Tq 3-5K on,2-3K off,ECD 10.65,FO 40%,WOB 15-20K,60 rpm,650 gpm, 1375 psi,max gas 0.Total Footage 561'. Page 2/49 Report Printed: 12/18/2015 0 operations Summary (with Timelog�epths) Ict, 2S-04 Conooa`Ptti�ups A&xka Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/19/2015 9/20/2015 6.00 SURFAC DRILL DDRL P Drilled 13-1/2"surface hole f/2252'- 2,252.0 2,622.0 18:00 00:00 2622'MD,2424'TVD.AST 1.6,ADT 3.22, Bit hours 23.27,Total Jar hrs 41.01,PU 95K,SO 90K, ROT 94K,Tq 4-6K on, 1-3K off, ECD 11.2,FO 48%, WOB 20-25K, 100 rpm,750 gpm, 1850 psi,max gas 0.Total Footage 370'. Kick w/Drilling CRT 96 @ 23:00 hrs. 9/20/2015 9/20/2015 2.50 SURFAC DRILL DDRL P Drilled 13-1/2"surface hole f/2622'to 2,622.0 2,825.0 00:00 02:30 2825'MD,2569'TVD.AST.53,ADT 2.81, Bit hours 26.08,Total Jar hrs 43.82, PU 100K,SO 95K,ROT 102K,Tq 5-6K on, 1-3K off,ECD 10.07, FO 48%,WOB 25-28K, 100 rpm,750 gpm, 1750 psi,max gas 0. Total Footage 203'. 9/20/2015 9/20/2015 1.25 SURFAC CASING CIRC P CBU X 2,pump @ 750 gpm=1750 psi, 2,825.0 2,744.0 02:30 03:45 rotate @ 100 rpm's.Stand back one stand to 2744'MD while circulating hole clean. 9/20/2015 9/20/2015 0.50 SURFAC CASING OWFF P OWFF,static.SIMOPS,C/O shaker 2,744.0 2,744.0 03:45 04:15 1 screens. 9/20/2015 9/20/2015 5.75 SURFAC CASING BKRM P BROOH t/548'MD.BROOH t/735' 2,744.0 548.0 04:15 10:00 MDpulling at 1000 fph,pumping @ 750 gpm to permafrost then slowing pumps down to 550/500 gpm.At 735' MD slow pulling speed and CBU X2 on the last 2 stands @ 500 gpm to 548'MD, 9/20/2015 9/20/2015 0.50 SURFAC CASING SRVY P P/U Gyrodata tools and drop multi 548.0 548.0 10:00 10:30shoot gyro @ 548'MD and let free fall. UBHO 85'back from bit depth. 9/20/2015 9/20/2015 1.00 SURFAC CASING PMPO P POOH w/pump @ 3 bpm=120 psi f/ 548.0 181.0 10:30 11:30 548'MD to 181'MD.Taking gyro shoots every stand. 9/20/2015 9/20/2015 1.50 SURFAC CASING BHAH P PJSM;pull Gyro tool,rack back 181.0 0.0 11:30 13:00 NMFC,&lay down BHA1 as per SLB. 9/20/2015 9/20/2015 0.50 SURFAC CASING WWWH P PJSM;flush stack. 0.0 0.0 13:00 13:30 9/20/2015 9/20/2015 0.50 SURFAC CASING BHAH P PJSM;clear&clean rig floor. 0.0 0.0 13:30 14:00 9/20/2015 9/20/2015 0.75 SURFAC CASING RURD P PJSM;rig up casing running 0.0 0.0 14:00 14:45 equipment. 9/20/2015 9/20/2015 3.00 SURFAC CASING PUTB P PJSM;run 10-3/4",45.5#, L-80,Hyd 0.0 1,119.0 14:45 17:45 563,dopeless casing f/surface to 1119'MD.Began to take weight at 1119'MD. 9/20/2015 9/21/2015 6.25 SURFAC CASING PUTB T Work casing with varying parameters 1,119.0 1,147.0 17:45 00:00 f/1119'-1147'MD,PU 80K,SO 70K, ROT 75K, 1-3.5 bpm,70-225 psi,Tq 3 -15K.Hole unloaded with mainly sand &a small amount of pea size gravel. 9/21/2015 9/21/2015 2.50 SURFAC CASING PUTB T PJSM;run 10-3/4",45.5#,L-80,Hyd 1,147.0 1,260.0 00:00 02:30 563,dopeless casing.Work casing with varying parameters through fill f/ 1147'-1260'MD,PU 80K,SO 70K, ROT 75K, 1-3.5 bpm,70-225 psi,Tq 3 -15K Page 3/49 Report Printed: 12/18/2015 "Sling •perations Summary (with Timeloglepths) 2S-04 Conoc*hilhps Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/21/2015 9/21/2015 4.25 SURFAC CASING PUTB P PJSM;run 10-3/4",45.5#, L-80,Hyd 1,260.0 2,722.0 02:30 06:45 563,dopeless casing f/1260'-2722' MD.Worked through spots @ 1575'& 1618'MD.Ran a total of 67 bowspring centralizers.Calculated displacement 27.63,actual 12.61 bbls. 9/21/2015 9/21/2015 1.00 SURFAC CASING HOSO P PJSM; PU 2 10-3/4" pup joints 14.82' 2,722.0 2,815.0 06:45 07:45 &4.78', 1 full joint,&the hanger.Land hanger @ 2815'MD. PU 145K,SO 107K. 10-3/4"HYD 563 DPLS, 1 reject/0 remakes. 9/21/2015 9/21/2015 2.50 SURFAC CEMENT CIRC P Circulate&condition mud for cement 2,815.0 2,815.0 07:45 10:15 job.Stage up pumps f/1-8 bpm, ICP 150 psi,FCP 120 psi,FO 13-21%, MW 9.6 ppg, PU 145K,SO 115K. SIMOPS PJSM for surface cement job. 9/21/2015 9/21/2015 1.00 SURFAC CEMENT RURD P PJSM;blow down TD&rig up cement 2,815.0 2,815.0 10:15 11:15 line to swivel on the Volant CRT. 9/21/2015 9/21/2015 3.75 SURFAC CEMENT CMNT P Pump 5 bbls of CW-100&PT lines to 2,815.0 0.0 11:15 15:00 1600/4000 psi.Continue pumping 8.35 ppg CW-100 for a total of 74.9 bbls,4.8 bpm, 150 psi. Pump 75 bbls of 10.5 ppg MPII w/red dye at 4.5 bpm,200 psi. Drop bottom plug& pump 405 bbls of 11.0 ppg Lead Cement at 5.5 bpm, 175-315 psi. Pump 66 bbls of 12.0 ppg Tail Cement at 5.5 bpm,230 psi.Drop top plug& kick out with 10 bbls of fresh H2O at 6 bpm, 170 psi.Swap to rig&displace cement with 9.7 ppg mud at 8 bpm, 550 psi. Bump plug w/250.1 bbls, pressure up to 1111 psi&hold for 5 min.Check floats,good.CIP at 14:51 hrs.Total of 51 bbls of cement returns to surface. 9/21/2015 9/21/2015 0.25 SURFAC CEMENT OWFF P Monitor well,static. 0.0 0.0 15:00 15:15 9/21/2015 9/21/2015 3.75 SURFAC CEMENT NUND P PJSM;nipple down diverter line,knife 0.0 0.0 15:15 19:00 valve,riser,diverter spool,&annular. 9/21/2015 9/21/2015 1.00 SURFAC WHDBOP NUND P PJSM;nipple up well head . 0.0 0.0 19:00 20:00 9/21/2015 9/21/2015 0.25 SURFAC WHDBOP PRTS P Test seals between the casing hanger 0.0 0.0 20:00 20:15 &well head to 5000 psi for 10 min. witnessed by CPAI Rep. 9/21/2015 9/21/2015 1.75 SURFAC WHDBOP NUND P PJSM;nipple up BOPE&install trip 0.0 0.0 20:15 22:00 nipple. 9/21/2015 9/21/2015 1.00 SURFAC WHDBOP MPDA P PJSM;hook up MPD lines. 0.0 0.0 22:00 23:00 9/21/2015 9/22/2015 1.00 SURFAC WHDBOP SVRG P PJSM,open ram doors&begin 0.0 0.0 23:00 00:00 cleaning inside cavities to begin BWM on BOPE. Page 4/49 Report Printed: 12/18/2015 w operations Summary (with Timelog epths) 2S-04 conoc c hiIIips hErla Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/22/2015 9/22/2015 3.50 SURFAC WHDBOP SVRG P PJSM;continue BWM on BOPE, 0.0 0.0 00:00 03:30 cleaning ram cavities. During inspection found damaged rubber on ODS blind rams.Changed out elements.Close up ram doors. Perform full body test on BOPE to 3500 psi,good.SIMOPS rig up to test BOPE. 9/22/2015 9/22/2015 0.50 SURFAC WHDBOP RURD P PJSM;pick up&make up floors 0.0 0.0 03:30 04:00 valves to test. 9/22/2015 9/22/2015 3.75 SURFAC WHDBOP BOPE P PJSM,test BOPE w/5"test joint to 0.0 0.0 04:00 07:45 250/3500 psi for 5 min each.#1:Top pipe rams,CV 1,12,13, 14&manual kill valve.#2:Upper IBOP, HCR kill, CV 9,&11.#3: Lower IBOP,CV 5,8& 10. #4: Dart,CV 4,6&7. #5:FOSV and CV 2. #6: HCR choke&4"kill line Demco valve, #7: Manual choke valve&HCR kill. #8:Annular preventer tested to 250/2500 psi.#9: Lower pipe rams.#10:Blind rams and CV 3.Test gas,flow&pit level alarms. Accumulator test:system pressure= 3000 psi,After closing= 1900 psi,200 psi attained after 33 sec,full pressure attained after 145 sec,Five bottle nitrogen avg=2000 psi. The BOP test witness was waived by AOGCC Rep. Johnnie Hill. 9/22/2015 9/22/2015 1.00 SURFAC WHDBOP RURD P PJSM;rig down test equipment,blow 0.0 0.0 07:45 08:45 down TD,kill line,choke line,&choke manifold.SIMOPS set 10"ID wear bushing. 9/22/2015 9/22/2015 0.50 SURFAC CEMENT SVRG P PJSM;service rig. 0.0 0.0 08:45 09:15 9/22/2015 9/22/2015 0.75 SURFAC CEMENT RURD P PJSM-RU to pick up 5'DP f/shed 0.0 0.0 09:15 10:00 9/22/2015 9/22/2015 3.50 SURFAC CEMENT PULD P PU&Stand back 105 jts(35 stds)5" 0.0 0.0 10:00 13:30 DP f/pipe shed via mouse hole 9/22/2015 9/22/2015 0.50 SURFAC CEMENT RURD P Clean up rig floor 0.0 0.0 13:30 14:00 9/22/2015 9/22/2015 0.50 SURFAC CEMENT BHAH P Bring BHA components to rig floor via 0.0 0.0 14:00 14:30 beaver slide 9/22/2015 9/22/2015 1.50 SURFAC CEMENT BHAH P PJSM-MU BHA#2-bit-power drive 0.0 747.0 14:30 16:00 -PD receiver sub-PD flex collar- EcoScope-Load RA sources-PU MWD-float/saver sub w/non-ported float-NM flex DC's-floate/saver sub w/non ported float-Well commander -9 jts HWDP-jars-8 jts. HWDP to 747.66' 9/22/2015 9/22/2015 2.50 SURFAC CEMENT PULD P PSJM;single in the hole w/5"DP(54 747.0 2,445.0 16:00 18:30 jts)f/747'-2445'MD. 9/22/2015 9/22/2015 1.25 SURFAC CEMENT MPDA P PJSM;remove master bushings& 2,445.0 2,445.0 18:30 19:45 install split bushings.Remove trip nipple&install RCD. 9/22/2015 9/22/2015 1.25 SURFAC CEMENT MPDA P PJSM;pressure test MPD choke 2,445.0 2,445.0 19:45 21:00 system 200/1000 psi. 9/22/2015 9/22/2015 1.00 SURFAC CEMENT MPDA P Calibrate finger print system with 2,445.0 2,445.0 21:00 22:00 MPD. Page 5/49 Report Printed: 12/18/2015 iterations Summary (with Timelog�epths)rz-4 2S-04 conoc*hiIlps A F.xAa Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/22/2015 9/23/2015 2.00 SURFAC CEMENT MPDA T Trouble shoot MPD system. 2,445.0 2,445.0 22:00 00:00 Spill Drill CRT 97 sec©23:30 hrs. 9/23/2015 9/23/2015 0.50 SURFAC CEMENT MPDA T Cont.troubling shooting MPD ramp 2,445.0 2,445.0 00:00 00:30 schedule as per Safe Kick Rep 9/23/2015 9/23/2015 0.50 SURFAC CEMENT MPDA P Blow down MPD ckoke skid&TD 2,445.0 2,445.0 00:30 01:00 9/23/2015 9/23/2015 0.75 SURFAC CEMENT MPDA P Pulled MPD bearing&set trip nipple 2,445.0 2,445.0 01:00 01:45 9/23/2015 9/23/2015 1.25 SURFAC CEMENT SLPC P PJSM-Slip&cut 65'drill line 2,445.0 2,445.0 01:45 03:00 9/23/2015 9/23/2015 1.00 SURFAC CEMENT COCF P Wash&ream f/2445'to 2699'@ 500 2,445.0 2,699.0 03:00 04:00 gpm©1300 psi w/60 rpm's w/5 k torque 9/23/2015 9/23/2015 0.75 SURFAC CEMENT CIRC P Circ btms up @ 550 gpm @ 1300 psi 2,699.0 2,699.0 04:00 04:45 w/60 rpm's 9/23/2015 9/23/2015 0.25 SURFAC CEMENT RURD P RU to test csg(Blow down TD) 2,699.0 2,699.0 04:45 05:00 9/23/2015 9/23/2015 0.75 SURFAC CEMENT PRTS P Pressure test 10 3/4"csg to 3500 psi 2,699.0 2,699.0 05:00 05:45 for 30 mins-Pumped 4 bbls to pressure up&bled back 4 bbls after test- Good Test 9/23/2015 9/23/2015 0.25 SURFAC CEMENT RURD P RD tes equipment 2,699.0 2,699.0 05:45 06:00 9/23/2015 9/23/2015 0.25 SURFAC CEMENT COCF P Wash&ream f/2699'to 2723'(top of 2,699.0 2,723.0 06:00 06:15 wiper plugs)@ 550 gpm @ 1300 psi w/60 rpm w/5k torque- -PU wt 109 SO wt 89 ROT wt 100 9/23/2015 9/23/2015 4.75 SURFAC CEMENT DRLG P Drilled wiper plugs f/2723'to 2725'- 2,723.0 2,825.0 06:15 11:00 Drilled float collar f/2725'to 2727'- Drilled cmt f/2727'to 2812'Drilled float shoe f/2812'to 2815'-Cleaned out rat hole f/2815'to 2825'w/350 to 550 gpm @ 1300 psi w/28%return flow-60 rpm's w/3 to 10 k torque- Note:float shoe drilled out vey quickly w/1.5kWOB 9/23/2015 9/23/2015 0.25 SURFAC CEMENT DDRL P Drilled 9 7/8"hole f/2825'to 2845'MD 2,825.0 2,845.0 11:00 11:15 2584 TVD ADT-.16 hrs ECD-10.11 ppg Footage 20' WOB 3/5 k RPM 60 GPM 550 @ 1300 psi PUwt 111 SOwt90 ROT wt 101 Torque on/off btm.-6/5 k Total bit hrs.-.16 hrs Total jar hrs. 57.10 hrs. 9/23/2015 9/23/2015 0.25 SURFAC CEMENT CIRC P Circ btms up @ 550 gpm @ 1300 psi- 2,845.0 2,845.0 11:15 11:30 Mud wt in&out 9.7 ppg 9/23/2015 9/23/2015 0.25 SURFAC CEMENT TRIP P Pull&std back 1 std DP f/2845'to 2,845.0 2,761.0 11:30 11:45 2761' 9/23/2015 9/23/2015 0.25 SURFAC CEMENT OWFF P Blow down TD-Monitor well-Static 2,761.0 2,761.0 11:45 12:00 9/23/2015 9/23/2015 0.75 SURFAC CEMENT LOT P PJSM;perform LOT to a EMW of 2,761.0 2,761.0 12:00 12:45 14.95 ppg,with 700 psi applied. 9/23/2015 9/23/2015 0.50 INTRM1 DRILL RURD P PJSM;rig down test equipment&blow 2,761.0 2,761.0 12:45 13:15 down lines. 9/23/2015 9/23/2015 0.25 INTRMI DRILL SRVY P Shoot survey&send commands to 2,761.0 2,845.0 13:15 13:30 Power Drive 2761'-2845'MD,675 gpm, 1550 psi,50 rpm,Tq 2-4K. Page 6/49 Report Printed: 12/18/2015 operations Summary (with Timelog epths) 01 rt 2S-04 Conoco`PhiIGps Ai,kn Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/23/2015 9/23/2015 4.50 INTRM1 DRILL DDRL P DDrilled 9-7/8"intermediate hole 2,845.0 3,187.0 13:30 18:00 f/2845'to 3187'MD,2827'TVD,ADT 3.77, Bit hours 3.77,Total Jar hrs 59.66,PU 115K,SO 93K, ROT 101 K,Tq 4-8K on,4K off, ECD 10.46, FO 41%,WOB 4-6K,80 rpm,675 gpm, 1640 psi,max gas 57.Displace well while drilling ahead 9.7 ppg LSND mud system.Total Footage 342'. SPR's @ 2854'MD,2590'TVD,MW 9.7 ppg, 13:30 hrs #1 30= 120 psi;@ 40=160 psi #2 30= 120 psi;@ 40=160 psi 9/23/2015 9/24/2015 6.00 INTRM1 DRILL DDRL P DDrilled 9-7/8"intermediate hole 3,187.0 3,654.0 18:00 00:00 f/3187'to 3654'MD,3168'TVD,ADT 3.96,Bit hours 7.73,Total Jar hrs 63.62,PU 124K,SO 97K,ROT 108K,Tq 6-8K on,4-5K off,ECD 10.64,FO 42%,WOB 5-7K,80 rpm, 750 gpm,2050 psi,max gas 78.Total Footage 467'. SPR's @ 3527'MD,3074'TVD,MW 9.7 ppg,22:00 hrs #1 30=120 psi;@ 40= 160 psi #2 30=120 psi;@ 40=160 psi 9/24/2015 9/24/2015 6.00 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/3654'to 3,654.0 4,239.0 00:00 06:00 4239'MD 3584'TVD ADT-4.77 hrs ECD-10,82 ppg Footage-585' WOB 9/10 k RPM 80 GPM 751 @ 2150 psi PU wt 135 SO wt 102 ROT wt 117 Torque on/off btm.-10/10 k Max.gas 92 units Total bit hrs. 12.5 hrs Total jar hrs. 68.39 hrs 9/24/2015 9/24/2015 6.00 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/4239'to 4,239.0 4,839.0 06:00 12:00 4829'MD 4077'TVD ADT-4.68 hrs ECD-10.97 ppg Footage-590' WOB 7/10 k RPM 140 GPM 750 @ 2275 psi PU wt 140 SO wt 118 ROT wt 126 Torque on/off btm.-7/5 k Max gas 78 units Total bit hrs. 17.18 hrs Total jar hrs. 68.39 hrs SPR's @ 4773'MD 4023'TVD @ 111.07 hrs w/9.7 ppg #1 30/40 SPM @ 140/180 psi #2 30/40 SPM @ 140/180 psi Page 7/49 Report Printed: 12/18/2015 1114 Ol'i Sperations Summary (with Timelog�epths) 2S-04 Conor hilIps Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/24/2015 9/24/2015 6.00 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/4829'to 4,839.0 5,472.0 12:00 18:00 5472'MD 4629'TVD ADT-5.14 hrs ECD-11.26 ppg Footage-643' WOB 7/12 k RPM 140 GPM 750 @ 2700 psi PU wt 154 SO wt 124 ROT wt 137 Torque on/off btm.-8/4 k Max gas 139 units Total bit hrs.22.32 hrs Total jar hrs. 78.21 hrs SPR's @ 5442'MD 4633'TVD @ 18:00 hrs w/10.0 ppg #1 30/40 SPM @ 180/240 psi #2 30/40 SPM @ 180/240 psi 9/24/2015 9/24/2015 1.25 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/5472'to 5,472.0 5,573.0 18:00 19:15 5537'MD 4713'TVD ADT-.8 hrs ECD-11.26 ppg Footage-65' WOB 7/12 k RPM 140 GPM 750 @ 2700 psi PUwt154 SOwt124 ROT wt137 Torque on/off btm.-8/4 k Max gas 139 units Total bit hrs.23.12 hrs Total jar hrs. 79.01 hrs 9/24/2015 9/24/2015 0.50 INTRM1 DRILL CIRC P CBU @ 750 gpm,2675 psi, 140 rpm, 5,573.0 5,443.0 19:15 19:45 Tq 5-6K.Rack back 1 stand f/5537'- 5443'MD. 9/24/2015 9/24/2015 0.25 INTRM1 DRILL OWFF P Monitor well,slight drop. 5,443.0 5,443.0 19:45 20:00 9/24/2015 9/24/2015 0.75 INTRM1 DRILL MPDA P PJSM;remove trip nipple&install 5,443.0 5,443.0 20:00 20:45 RCD. 9/24/2015 9/24/2015 0.25 INTRM1 DRILL REAM P Wash&ream to bottom 5443'-5573' 5,443.0 5,573.0 20:45 21:00 MD,750 gpm;2700 psi,80 rpm,Tq 7- 8K. 9/24/2015 9/25/2015 3.00 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/5537'to 5,573.0 5,746.0 21:00 00:00 5746'MD 4912'TVD ADT-1.88 hrs ECD-11.29 ppg Footage-209' WOB 8/13 k RPM 140 GPM 750© 2750 psi PU wt 165 SO wt 129 ROT wt 144 Torque on/off btm.-15/8 k Max gas 116 units Total bit hrs.25.0 hrs Total jar hrs. 80.89 hrs SPR's @ 5743'MD 4910'TVD @ 23:30 hrs w/10.0 ppg #1 30/40 SPM @ 160/220 psi #2 30/40 SPM @ 160/220 psi Page 8/49 Report Printed: 12/18/2015 Operations Summary (with Timelog epths) 2S-04 ConoGoPhiltips A;.nAn Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/25/2015 9/25/2015 6.00 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/5746'to 5,746.0 6,399.0 00:00 06:00 6399'MD 5465'TVD ADT-5.10 hrs. ECD-11.24 ppg Footage-653' WOB-10/12 k RPM 140 GPM 750 @ 2800 psi PU wt 175 SO wt. 140 ROT wt. 155 Torque on/off btm.-12/8 k Max.gas 491 units Total bit hrs.30.10 hrs Total jar hrs. 85.99 hrs Fire Drill CRT 120 sec @ 08:20 hrs. 9/25/2015 9/25/2015 1.00 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/6399'to 6,399.0 6,495.0 06:00 07:00 6495'MD-5544'TVD ADT-.76 hrs ECD-11.23 ppg Footage-96' WOB 5/10 k RPM 140 GPM 748© 2880 psi PU wt. 170 SO wt 145 ROT wt. 158 Torque on/off btm.-13/6 k Max.gas 252 units Total bit hrs.30.86 hrs Total jar hrs. 86.75 hrs 9/25/2015 9/25/2015 1.00 INTRM1 DRILL CIRC T Circ&dump mud-Take on& 6,495.0 6,495.0 07:00 08:00 pefromed 290 bbls whole mud dilution Note-Drilled into Cairn formation- decision made to do dilution w/o drilling to have good handle on gains &losses 9/25/2015 9/25/2015 4.00 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/6495'to 6,495.0 6,880.0 08:00 12:00 6880'MD 5820'TVD ADT-3.08 hrs ECD-11.08 ppg Footage-385' WOB 10/15 k RPM 140 GPM 750 @ 2900 psi PU wt. 184 SO wt. 139 ROT wt. 154 Torque on/off btm.-11/7 k Max gas 978 units Total bit hrs.33.94 hrs Total jar hrs. 89.83 hrs SPR @ 6880'MD 5820'TVD @ 1200 hrs w/10.1 ppg #1 30/40 SPM @ 200/260 psi #2 30/40 SPM @ 200/260 psi Fire Drill CRT 120 sec @ 08:20 hrs. Page 9/49 Report Printed: 12/18/2015 Or operations Summary (with Timelog epths) 2S-04 conoc hillrps Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) -End Depth(ftKB) 9/25/2015 9/25/2015 3.50 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/6880'to 6,880.0 7,152.0 12:00 15:30 7152'MD 5976'TVD ADT-2.3 hrs ECD-11.77 ppg Footage-272' WOB 9/13 k RPM 140 GPM 750© 3250 psi PU wt. 181 SO wt. 135 ROT wt. 150 Torque on/off btm.-11/5 k Max gas 591 units Total bit hrs.36.24 hrs Total jar hrs. 92.13 hrs SPR @ 7072'MD 5931'TVD @ 14:30 hrs w/10.5 ppg #1 30/40 SPM @ 170/260 psi #2 30/40 SPM©180/260 psi 9/25/2015 9/25/2015 0.50 INTRM1 DRILL OWFF T Monitor well,static. 7,152.0 7,152.0 15:30 16:00 9/25/2015 9/25/2015 0.50 INTRM1 DRILL MPDA T PJSM;change out RCD,due to 7,152.0 7,152.0 16:00 16:30 bearing failure 9/25/2015 9/25/2015 1.75 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/7152'to 7,152.0 7,260.0 16:30 18:15 7260'MD 6016'TVD ADT-1.11 hrs ECD-11.81 ppg Footage-108' WOB 11/16 k RPM 140 GPM 750 @ 3400 psi PU wt. 180 SO wt. 130 ROT wt. 147 Torque on/off btm.-13/6 k Max gas 432 units Total bit hrs.37.35 hrs Total jar hrs. 93.24 hrs 9/25/2015 9/25/2015 0.50 INTRM1 DRILL MPDA T Change out pressure sensor on MPD 7,260.0 7,260.0 18:15 18:45 system.Circulate @ 750 gpm,3350 psi, 140 rpm,Tq 7-9K, FO 88% 9/25/2015 9/26/2015 5.25 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/7260'to 7,260.0 7,555.0 18:45 00:00 7555'MD 6157'TVD ADT-2.81 hrs ECD-11.86 ppg Footage-295' WOB 10/15 k RPM 140 GPM 750 @ 3400 psi PU wt. 180 SO wt. 130 ROT wt. 147 Torque on/off btm.-11/7 k Max gas 468 units Total bit hrs.40.16 hrs Total jar hrs. 96.05 hrs SPR@ 7547'MD 6154'TVD @ 23:30 hrs w/10.5 ppg #1 30/40 SPM @ 250/340 psi #2 30/40 SPM @ 280/340 psi Page 10149 Report Printed: 12/18/2015 .Q . Operations Summary (with Timeloglepths) ell 2S-04 ConocoPhillips AI:rA:9 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/26/2015 9/26/2015 2.75 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/7555'to 7,555.0 7,800.0 00:00 02:45 7800'MD 6240"TVD ADT-2.56 hrs. ECD-11.78 ppg Footage-245' WOB 10/18 k RPM 140 GPM 750 @ 3450 psi PU wt 195 SO wt 124 ROT wt. 145 Torque on/off btm.-14/12 k Max Gas-2193 units Total bit hrs.42.72 hrs Total jar hrs. 98.61 hrs 9/26/2015 9/26/2015 3.25 INTRM1 CASING CIRC P Pumped 30 bbls Hi-Vis sweep- 7,800.0 0.0 02:45 06:00 followed by 3X btms up @ 750 gpm @ 4350 psi w/140 rpm's w/10 k torque- ECD 11.78 ppg-Max gas 7412 units- Stood back 1 std DP after each btms up-to 7553'-Observed 50%increase in cuttings @ shakers when sweep came back 9/26/2015 9/26/2015 1.00 INTRM1 CASING REAM P Ream back to btm f/7553'to 7800'@ 7,553.0 7,800.0 06:00 07:00 750 gpm @ 3450 psi Observed 9990 units gas @ btms up 9/26/2015 9/26/2015 1.25 INTRM1 CASING OWFF P Performed draw down test w/MPD- 7,800.0 7,800.0 07:00 08:15 SIMOPS held PJSM on mud dilution 9/26/2015 9/26/2015 1.25 INTRM1 CASING CRC P Performed 290 bbls whole mud 7,800.0 7,800.0 08:15 09:30 dilution @ 5 bbls/min @ 490 psi w/20 rpm's 9/26/2015 9/26/2015 1.00 INTRM1 CASING CIRC P Circ btms up @ 750 gpm @ 3450 psi- 7,800.0 7,800.0 09:30 10:30 Observed 9990 units gas 9/26/2015 9/26/2015 1.00 INTRM1 CASING OWFF T Monitor well on trip tank with no gain 7,800.0 7,800.0 10:30 11:30 observed.Open 2"line on RCD to monitor in the cellar.Observe well flowing initially @ 0.16 bph,increase to.26 bph in 30 minutes. 9/26/2015 9/26/2015 1.00 INTRM1 CASING OWFF T Perform draw down test w/MPD. 7,800.0 7,800.0 11:30 12:30 Observe 13 psi pressure increase. 9/26/2015 9/26/2015 3.00 INTRM1 CASING CRC T Weight up mud system f/10.5 to 10.8 7,800.0 7,750.0 12:30 15:30 ppg,750 gpm,3350 psi,20 rpm,Tq 10-13K.While reciprocating encountered tight hole&pack off @ 7750'MD.work pipe free,establish rotation,&stage up pumps to regain circulation.Stage up pumps to 600 gpm,2400 psi. 9/26/2015 9/26/2015 4.25 INTRM1 CASING BKRM T PJSM;BROOH F/7750'-7170'MD, 7,750.0 7,170.0 15:30 19:45 600 gpm,2400 psi,60 rpm,Tq 8-13K, ROT wt 160K. 9/26/2015 9/26/2015 1.50 INTRM1 CASING CIRC T Circulate&condition mud to clean up 7,170.0 7,170.0 19:45 21:15 hole&get 10.8 ppg mud throughout system,600 gpm,2400 psi,60 rpm, Tq 9-11k. 9/26/2015 9/26/2015 1.75 INTRM1 CASING OWFF T Monitor well,rotate 10 rpm,Tq 10- 7,170.0 7,170.0 21:15 23:00 11K,open 2"line from RCD to the cellar&record decrease in flow f/1.02 bph to.38 bph in 90 minutes. 9/26/2015 9/26/2015 0.75 INTRM1 CASING CIRC T CBU @ 700 gpm,3000 psi,50 rpm, 7,170.0 7,074.0 23:00 23:45 Tq 7-8K,gas 300-400 units,rack back 1 stand 7170'-7074'MD. Page 11/49 Report Printed: 12/18/2015 et Operations Summary (with Timelog epths) 2S-04 Conor hiIIips Ak kn Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/26/2015 9/27/2015 0.25 INTRM1 CASING OWFF T Monitor well,rotate 10 rpm,Tq 10- 7,074.0 7,074.0 23:45 00:00 11K,open 2"line from RCD to the cellar&record decrease in flow f/2.68 bph to 1.53 bph in 15 minutes. (Continue to monitor after midnight.) 9/27/2015 9/27/2015 2.25 INTRM1 CASING OWFF T Continue to monitor well,rotate 10 7,074.0 7,074.0 00:00 02:15 rpm,Tq 10-11K,open 2"line from RCD to the cellar&record decrease in flow f/1.53 bph to.52 bph in 120 minutes. 9/27/2015 9/27/2015 3.75 INTRM1 CASING CIRC T Weight up mud system f/10.8 to11.1 7,074.0 7,170.0 02:15 06:00 ppg.Stage up pumps to 650 gpm, 2650 psi.Wash&ream 1 stand to 10' above the HRZ. Reduce rate to 550 gpm,2050 psi,ECD 11.79. Fire Drill CRT 120 sec @ 04:15 hrs. 9/27/2015 9/27/2015 3.00 INTRM1 CASING CIRC T Circulate&condition to bring viscosity 7,170.0 7,170.0 06:00 09:00 up in system,550 gpm,2050 psi,90 rpm,Tq 8-10 K,ECD 11.89. 9/27/2015 9/27/2015 5.75 INTRM1 CASING OWFF T Monitor well,rotate 10 rpm,Tq 10- 7,170.0 7,170.0 09:00 14:45 13K,open 2"line from RCD to the cellar&record decrease in flow f/1.34 bph to.23 bph in 240 minutes.Flow leveled out at.23 bph. 9/27/2015 9/27/2015 2.50 INTRM1 CASING CIRC T Circulate&condition for gas cut mud 7,170.0 7,170.0 14:45 17:15 at 550 gpm,2050 psi,60 rpm,Tq 9- 10K. 9/27/2015 9/27/2015 0.75 INTRM1 CASING OWFF T Monitor well with MPD chokes shut in, 7,170.0 7,170.0 17:15 18:00 no increase observed. 9/27/2015 9/27/2015 1.50 INTRM1 CASING CIRC T Circulate&condition for gas cut mud 7,170.0 7,170.0 18:00 19:30 at 550 gpm,2050 psi,60 rpm,Tq 9- 10K. 9/27/2015 9/27/2015 0.75 INTRM1 CASING MPDA T PJSM;change out RCD bearing. 7,170.0 7,170.0 19:30 20:15 9/27/2015 9/27/2015 2.75 INTRM1 CASING CIRC T Circulate&condition for gas cut mud 7,170.0 7,170.0 20:15 23:00 at 550 gpm,2050 psi,60 rpm,Tq 7- 9K. 9/27/2015 9/28/2015 1.00 INTRM1 CASING CIRC T Load spike fluid in pits&weight up 7,170.0 7,170.0 23:00 00:00 mud system f/11.2 to 11.4 ppg,at 500 gpm, 1750 psi,60rpm,Tq 7-9K. Fire Drill CRT 102 sec at 23:30 hrs. 9/28/2015 9/28/2015 3.50 INTRM1 CASING CIRC T Cont.to circ&wt up mud f/11.1 ppg 7,170.0 7,170.0 00:00 03:30 to 11.4 ppg w/spike fluid @ 485 gpm @ 1675 psi w/60 rmps'w/7/9 K torque ECD-12.01 to 12. 13 9/28/2015 9/28/2015 3.25 INTRM1 CASING OWFF T Obtain SPR's Blow down TD- 7,170.0 7,170.0 03:30 06:45 Monitor well-inital flow rate 1.53 bbls/hr-final rate.117 bbls/hr 9/28/2015 9/28/2015 1.00 INTRM1 CASING TRIP T RIH f/7170'to 7453' 7,170.0 7,453.0 06:45 07:45 PU wt 190 SO wt 130 Rot wt 160 9/28/2015 9/28/2015 2.75 INTRM1 CASING CIRC T Stage pump up to 450 gpm @ 1600 7,453.0 7,453.0 07:45 10:30 psi w/50 rpm's w/8/12 torque- Observed gas @ surface w/4200 stks -Gas peaked @ 9990 units @ 4700 stks-55 bbls before calc.btms up- Cont.circ gas out of hole 9/28/2015 9/28/2015 1.00 INTRM1 CASING TRIP T Blow down TD-RIH f/7453'to 7744' 7,453.0 7,744.0 10:30 11:30 PU wt 210 SO wt. 125 ROT wt. 150 Page 12/49 Report Printed: 12/18/2015 Iperations Summary (with Timelog epths) Oil a 2S-04 Conoc3 hiIIps AL-Aka Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/28/2015 9/28/2015 0.50 INTRM1 CASING REAM T Wash&ream f/7744'to 7765'- 7,744.0 7,765.0 11:30 12:00 string took wt&hole packed-off- Work pipe 9/28/2015 9/28/2015 10.75 INTRM1 CASING BKRM T Work pipe free&BROOH f/7765'- 7,765.0 7,170.0 12:00 22:45 7170'MD,250 gpm,700 psi,60 rpm, Tq 10-20K. 9/28/2015 9/29/2015 1.25 INTRM1 CASING CIRC T CBU above the HRZ @ 425 gpm, 7,170.0 7,170.0 22:45 00:00 1500 psi,50 rpm,Tq 9-11K, PU 190K, SO 150K,ROT 160K, FO 58%,Max Gas 1415. SPR @ 7132'MD,5953'TVD,MW 11.5 ppg,23:40 hrs #1 30=350;@ 40=420 #2 30=350;@ 40=420 9/29/2015 9/29/2015 6.00 INTRM1 CASING OWFF T Monitor well at annulus valve. Initial 7,170.0 7,167.0 00:00 06:00 flow=1.6 bph Final flow=.157 bph 9/29/2015 9/29/2015 1.25 INTRM1 CASING CIRC T CBU.425 gpm, 1500 psi,50 rpm, 10K 7,167.0 7,167.0 06:00 07:15 tq,Rot wt=150K,ECD 12.17 ppg, 58%FO,Max gas 547 units 9/29/2015 9/29/2015 1.50 INTRM1 CASING TRIP T Obtain SPR's Blow down TD.Strip out 7,167.0 6,970.0 07:15 08:45 of hole 7167'MD to 6940'MD.35K overpull at 6940'MD.Work pipe down to 6970'MD.PU 190K,SO 130K. SPR's @ 7167'MD,5966'TVD,MW 11.4 ppg,07:15 hrs #1 30=350 psi;@ 40=420 psi #2 30=350 psi;@ 40=425 psi 9/29/2015 9/29/2015 0.75 INTRM1 CASING BKRM T BROOH from 6970;MD to 6918'MD. 6,970.0 6,879.0 08:45 09:30 425 gpm, 1500 psi, 10K tq,ECD 12.32 ppg.Lost circulation.Slow pump rate to.5 bpm.No returns.BROOH to 6879'MD. 9/29/2015 9/29/2015 0.50 INTRM1 CASING OWFF T Line up and top fill well bore.52 bbls 6,879.0 6,879.0 09:30 10:00 required to fill hole. 9/29/2015 9/29/2015 2.00 INTRM1 CASING CIRC T Pump 25 bbls of 30 ppb nut 6,879.0 6,879.0 10:00 12:00 plug/dynared LCM pill.2 bpm,200 psi, 15 rpm, 12-13K tq.No returns.Spot pill @ 5600'MD.Top of C-37 sand zone. Total losses for tour=365 bbls. 9/29/2015 9/29/2015 0.50 INTRM1 CASING MPDA T Remove RCD bearing assy. Install trip 6,879.0 6,818.0 12:00 12:30 nipple. Reduce surface mud wt.to 10.5 ppg. 9/29/2015 9/29/2015 2.00 INTRM1 CASING WAIT T Wait on mud from mud plant top filling 6,818.0 6,818.0 12:30 14:30 hole w/10.5 ppg mud 9/29/2015 9/29/2015 3.25 INTRM1 CASING COND T Reduce new mud density from 11.5 6,818.0 6,818.0 14:30 17:45 ppg to 10.5 ppg.Mix 35 bbls of 40 ppb nut plug/dynared LCM pill. 9/29/2015 9/29/2015 1.50 INTRM1 CASING CIRC T Pump 35 bbls of 40 ppb nut 6,818.0 6,818.0 17:45 19:15 plug/dynared LCM pill.2 bpm,250 psi, No returns.Spot pill @ 5600'MD. 9/29/2015 9/29/2015 1.25 INTRM1 CASING OWFF T Monitor well.Static loss rate=23 bph. 6,818.0 6,818.0 19:15 20:30 9/29/2015 9/29/2015 1.75 INTRM1 CASING CIRC T Pump 35 bbls of 50 ppb Strata 6,818.0 6,818.0 20:30 22:15 Flex/Strata vanguard LCM pill.2 bpm, 250 psi.Spot pill @ 5600'MD. Page 13/49 Report Printed: 12/18/2015 i. •perations Summary (with Timelog epths) 06 2,4 2S-04 Gon000`Philhps Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/29/2015 9/30/2015 1.75 INTRM1 CASING OWFF T Monitor well.Static loss rate= 10 bph. 6,818.0 6,818.0 22:15 00:00 Total losses for tour=674 bbls. 9/30/2015 9/30/2015 2.00 INTRM1 CASING CIRC T Pump LCM pill#4- 24 bbls-40#/bbl 6,818.0 6,818.0 00:00 02:00 -15#/bbl Nut plug med./15#/bbl Nut plug fine/10#/bbl DynaRed fine- Pumped @ 2 bbls/min w/365 psi- spotting pill to 5600'-Observed very slight returns 9/30/2015 9/30/2015 0.75 INTRMI CASING OWFF T Monitor well-well static fluid level not 6,818.0 6,818.0 02:00 02:45 droppping 9/30/2015 9/30/2015 0.50 INTRM1 CASING CIRC T Break circ @ 1 bbl/min @ 250 psi-w/ 6,818.0 6,818.0 02:45 03:15 15 rpm's w/10/12 k torque-Very slight returns-Lost 35 bbls in 30 mins 9/30/2015 9/30/2015 0.25 INTRM1 CASING OWFF T Monitor well-well static-fluid level 6,818.0 6,818.0 03:15 03:30 not dropping 9/30/2015 9/30/2015 1.75 INTRM1 CASING CIRC T Pumped LCM pill#5-25 bbls/40 6,818.0 6,818.0 03:30 05:15 #/bbl-20#/bbls Strata Vangaurd/20 #/bbl Strata Flex Med.@ 3 bbls/min @ 340 psi-spotting pil up to 5600'- Very slight returns- 9/30/2015 9/30/2015 0.50 INTRM1 CASING OWFF T Monitor well-fluid level dropping 6,818.0 6,818.0 05:15 05:45 slightly-lost 14 bbsl 9/30/2015 9/30/2015 6.25 INTRM1 CASING BKRM T Stood back Std#64 to 6786'- 6,818.0 6,306.0 05:45 12:00 BROOH f/6786'to 6690'@ 1.5 bbls/min @ 200 psi w/45 rpm w/9.7 K torque-BROOH f/6690'to 6306'@ 1 bbl/min 200-250 psi WI 45 rpm's @ 9 k torque losses @ 50 bbl/hr. Note:Lost 812 bbls 10.5 ppm LSND mud to formation last 12 hrs. 9/30/2015 9/30/2015 5.50 INTRM1 CASING BKRM T BROOH from 6306'MD to 5540'MD. 6,306.0 5,540.0 12:00 17:30 1 bpm,200-250 psi,50 rpm,9-14K tq. PU 152K SO 142K ROT 147K. 9/30/2015 9/30/2015 1.00 INTRM1 CASING CIRC T Pumped LCM pill#6-24 bbls/50 5,540.0 5,540.0 17:30 18:30 #/bbl-20#/bbls Strata Vangaurd/30 #/bbl Strata Flex Med.@ 2 bbls/min @ 250 psi. Increase rate to 4 bpm to displace pill into the open hole.400 psi.PU 139K SO 129K ROT 136K. Slight returns. 9/30/2015 9/30/2015 0.50 INTRM1 CASING OWFF T OWFF.3.6 bph loss rate. 5,540.0 5,540.0 18:30 19:00 9/30/2015 10/1/2015 5.00 INTRMI CASING PMPO T Pump OOH from 5540'MD to 4296' 5,540.0 4,296.0 19:00 00:00 MD.250-700 fph, 1-2 bpm,225-300 psi. Rotate and work through tight hole @ 5363'MD and 4943'MD. Total losses for tour=516 bbls 10/1/2015 10/1/2015 4.00 INTRM1 CASING PMPO T Cont.POOH w/pump f/4296'to 2758' 4,296.0 2,758.0 00:00 04:00 MD-@ 2 bbls/min @ 275 psi PU wt 130 k SO wt 105-Lost 240 bbls 10/1/2015 10/1/2015 0.25 INTRM1 CASING CIRC T Break circ. 1 bpm, 180 psi. Unable to 2,758.0 2,758.0 04:00 04:15 establish circ.Lost 12 bbls mud. Page 14/49 Report Printed: 12/18/2015 i'111 6 Iterations Summary (with Timelog!epths) 0 a 2S-04 con000Philhps At,%k, Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/1/2015 10/1/2015 1.00 INTRM1 CASING OWFF T BD TD&monitor well-static after 20 2,758.0 2,758.0 04:15 05:15 mins. 10/1/2015 10/1/2015 6.75 INTRM1 CASING PMPO T Cont. POOH f/2758'to 1131'@ 2 2,758.0 1,131.0 05:15 12:00 bbls/min @ 200 psi-Hole taking fluid &swabbing-Pull @ 575 FPH-total losses for tour 411 bbls 10/1/2015 10/1/2015 0.50 INTRM1 CASING PMPO T Cont. POOH w/pump f/1131'to 939' 1,131.0 939.0 12:00 12:30 @ 2 bbls/min @ 200 psi 10/1/2015 10/1/2015 1.50 INTRM1 CASING OWFF T Observed well-increase in flow-rate 939.0 939.0 12:30 14:00 not slowing as before-gained 12 bbls -Shut in upper pipe rams-Install floor valve&blow down TD-Monitor pressure-No pressure on annulus- Fill poor boy gas buster-line up choke manifold 10/1/2015 10/1/2015 2.00 INTRM1 CASING OWFF T Open super choke and monitor well on 939.0 939.0 14:00 16:00 trip tank-gained 28.56 bbls/-flow rate @ 29 bbls/hr-Shut in choke- Observed casing pressure @ 30 psi 10/1/2015 10/1/2015 1.00 INTRM1 CASING CIRC T Break circ.Stage pump up to 2 bpm 939.0 939.0 16:00 17:00 in.5 bpm increments. 190 psi @ 2 bpm.Pump 31 bbls. Unable to establish circ. 10/1/2015 10/1/2015 4.50 INTRM1 CASING WAIT T Prepare to bullhead hole volume. Mix 939.0 939.0 17:00 21:30 28 bbls 10.5 ppg mud hi-vis spacer. Wait on delivery of mud from Deadhorse mud plant. 10/1/2015 10/2/2015 2.50 INTRM1 CASING CIRC T Bullhead 28 bbls 10.5 ppg hi-vis 939.0 939.0 21:30 00:00 spacer followed by 10.5 ppg mud. Stage pump up from 1 bpm to 5 bpm in 1 bpm increments. 180 psi @ 5 bpm. Total losses for tour=706 bbls 10/2/2015 10/2/2015 1.00 INTRM1 CASING CIRC T Cont. Bullheading 10.5 ppg mud down 939.0 939.0 00:00 01:00 annulus @ 5 bbls/min @ 110 psi (choke panel gauge)180 psi(Totco)- Pumped total of 945 bbls-placing 10.5 ppg mud @ 6558'Bermuda formation-Additional volume pumped to account for gas mirgration rate of 1.42 BMP-Shut in pressure 110 psi- 10/2/2015 10/2/2015 1.50 INTRM1 CASING OWFF T Monitor well-Gained 30.2 bbls-30 939.0 939.0 01:00 02:30 mins.Opening well for 5 mins.& Shuting in for 5 mnis.-Inital csg pressure 120 psi-Final csg pressure 80 psi 10/2/2015 10/2/2015 8.25 INTRM1 CASING WAIT T Conferred with town engineer&Drlg 939.0 939.0 02:30 10:45 Superintendent-decision made to set 11.5 ppg mud cap to 10 3/4"csg shoe -Wait on spike fluid-SIMOPS-Clean rig work on work orders-Service TD, Drawworks&crown-Change out cyclone body on mix hopper#1 10/2/2015 10/2/2015 2.50 INTRM1 CASING COND T Weight up mud in pits to 11.5 ppg w/ 939.0 939.0 10:45 13:15 13.1 ppg microniszed barite spike fluid 10/2/2015 10/2/2015 0.50 INTRM1 CASING SFTY T PJSM on well kill operation. 939.0 939.0 13:15 13:45 Page 15/49 Report Printed: 12/18/2015 •perations Summary (with Timelogtepths) 011 2S-04 conoao`PhilIps Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/2/2015 10/2/2015 2.25 INTRM1 CASING CIRC T Pump 10 bbls 11.5 ppg mud down DP. 939.0 939.0 13:45 16:00 Bullhead 25 bbl 11.5 ppg hi-vis spacer followed by 245 bbls 11.5 ppg mud. Stage pump up from 1 bpm to 3.5 bpm. Initial casing pressure 80 psi. Final casing pressure 10 psi. 10/2/2015 10/2/2015 4.00 INTRM1 CASING OWFF T Monitor well.Well taking fluid. 939.0 939.0 16:00 20:00 Establish loss rate @ 300 to 500 bph while filling through kill line.Lower mud weight to 11 ppg and fill through kill line. Loss rate diminished to 36 bph. 10/2/2015 10/2/2015 0.25 INTRM1 CASING SFTY T PJSM on POOH. 939.0 939.0 20:00 20:15 10/2/2015 10/2/2015 2.00 INTRMI CASING TRIP T POOH to 86'MD. 939.0 86.0 20:15 22:15 10/2/2015 10/2/2015 1.00 INTRM1 CASING BHAH T Unable to latch nuclear source into 86.0 86.0 22:15 23:15 transport shield.Trouble shoot problem. 10/2/2015 10/3/2015 0.75 INTRM1 CASING BHAH T Rig up emergency transport shield on 86.0 29.0 23:15 00:00 EcoScope.Lay down EcoScope with sources. 10/3/2015 10/3/2015 1.75 INTRM1 CASING BHAH T Finish LD BHA-Load out&send 29.0 0.0 00:00 01:45 EcoScope w/emergency shield& Power drive to D&M shop @ Dead horse 10/3/2015 10/3/2015 0.50 INTRM1 CASING BHAH T Clean&clear rig floor of BHA tools 0.0 0.0 01:45 02:15 10/3/2015 10/3/2015 0.75 INTRM1 PLUG RURD T PJSM-RU to run 3 1/2"tbg(cmt 0.0 0.0 02:15 03:00 stinger) 10/3/2015 10/3/2015 0.50 INTRM1 PLUG SFTY T PJSM on runing 3 1/2"tbg 0.0 0.0 03:00 03:30 10/3/2015 10/3/2015 1.25 INTRM1 PLUG PULD T MU&ran 35 jts 3 1/2"9.2#EUE 8 RD 0.0 1,100.0 03:30 04:45 L-80 tbg w/mule shoe to 1100'--No returns-Hole taking 5.6 bbls/hr 10/3/2015 10/3/2015 1.00 INTRM1 PLUG RURD T RD tbg tongs&change elevators to 5" 1,100.0 1,202.0 04:45 05:45 -MU OX&run 1 std 5"DP to 1202' 10/3/2015 10/3/2015 0.75 INTRM1 PLUG RURD T RU MP#1 to 2"RCD adaptor flange- 1,202.0 1,202.0 05:45 06:30 Blow down choke&kill lines 10/3/2015 10/3/2015 1.00 INTRM1 PLUG TRIP T RIH w/3 1/2"cmt stinger f/1202'to 1,202.0 2,734.0 06:30 07:30 2734'-PU wt 67 SO wt 62- Calc.displacement-12.5 bbls-Actual -.4 bbls 10/3/2015 10/3/2015 0.50 INTRMI PLUG OTHR T Moved HWDP f/DS to ODS in derrick 2,734.0 2,734.0 07:30 08:00 10/3/2015 10/3/2015 1.50 INTRM1 PLUG MPDA T PJSM-Pull trip nipple-Install MPD 2,734.0 2,734.0 08:00 09:30 bearing 10/3/2015 10/3/2015 0.50 INTRM1 PLUG CIRC T Line up MP#1 &circ thru 2"HP MPD 2,734.0 2,734.0 09:30 10:00 line across top of hole 10/3/2015 10/3/2015 0.25 INTRM1 PLUG OWFF T Monitor well for losses pumping 2,734.0 2,734.0 10:00 10:15 across top of hole- loss rate @ 1.5 bbls/hr 10/3/2015 10/3/2015 0.50 INTRM1 PLUG CIRC T Attempt to circ btms up-@.5 bbls/min 2,734.0 2,734.0 10:15 10:45 -pumped 4 bbls-No Returns-Shut down pump-Blow down TD Page 16/49 Report Printed: 12/18/2015 •perations Summary (with Timelog epths) rzr ►i 2S-04 Conoco`Philbps Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/3/2015 10/3/2015 1.25 INTRM1 PLUG OWFF T RU-Circ over top of hole&monitor 2,734.0 2,734.0 10:45 12:00 hole for losses-SIMOPS-Changed out beaver slide tugger line-LD drillers side tongs-Prep rig floor to change out Dynamatic Lost 70 bbls last 12 hrs. 10/3/2015 10/4/2015 12.00 INTRM1 PLUG RGRP T Change out Dynamatic on drawworks. 2,734.0 2,734.0 12:00 00:00 Lost 3 bbls last 12 hrs. 10/4/2015 10/4/2015 2.50 INTRM1 PLUG RGRP T PJSM-Cont.Assembling Dyanmatic 2,734.0 2,734.0 00:00 02:30 brake-Weld snub line post-Install gaurds&hangtongs 10/4/2015 10/4/2015 0.25 INTRM1 PLUG OWFF T Observed gas climbing to 400 units- 2,734.0 2,734.0 02:30 02:45 SI well w/MPD 12 psi on DP 10/4/2015 10/4/2015 0.75 INTRM1 PLUG CIRC T Bull head 40 bbls 11.3 ppg mud down 2,734.0 2,734.0 02:45 03:30 DP @ 4 bbls/min @ 115 psi w/41 psi on annulus 10/4/2015 10/4/2015 0.75 INTRM1 PLUG CIRC T Bull head 200 bbls 11.3 ppg down 2,734.0 2,734.0 03:30 04:15 annulus @ 6 bbls/min @ 144 psi SIMOPS-move HWDP to DS 10/4/2015 10/4/2015 1.00 INTRM1 PLUG OWFF T Monitor well loss rate @ 10 bbls/hr 2,734.0 2,734.0 04:15 05:15 10/4/2015 10/4/2015 5.00 INTRM1 PLUG TRIP T RIH f/2734'to 6654'w/3 1/2"tbg 2,734.0 6,654.0 05:15 10:15 stinger on 5"DP PU wt 145 SO wt 110 10/4/2015 10/4/2015 0.25 INTRMI PLUG CIRC T Pumped 10 bbls 11.3 ppg mud down 6,654.0 6,654.0 10:15 10:30 DP@ 125 psi-No retures 10/4/2015 10/4/2015 2.00 INTRM1 PLUG TRIP T Cont. RIH w/3 1/2"tbg stinger on 5' 6,654.0 7,747.0 10:30 12:30 DP f/6654'to 7747' 10/4/2015 10/4/2015 0.50 INTRMI PLUG CIRC T Stage up pump&Attempt to circ- 7,747.0 7,747.0 12:30 13:00 hole packing off-Pressured up to 800 psi 10/4/2015 10/4/2015 1.25 INTRM1 PLUG PMPO T POOH-to 7715'w/pump @ 1/2 7,747.0 7,682.0 13:00 14:15 bbl/min attempting to circ-hole pqcking off-POOH to 7682'establish circ @ 1 bbl/min stage pump up to 3.5 bbls/min @ 275 psi PU wt 170 SO wt. 125 SIMOPS-held PJSM on setting cmt plug 10/4/2015 10/4/2015 0.25 INTRM1 PLUG RURD T Shut down pump-Blow down TD- 7,682.0 7,682.0 14:15 14:30 RU cmt line 10/4/2015 10/4/2015 0.25 INTRM1 PLUG CIRC T Break circ&stage pump up to 4 7,682.0 7,682.0 14:30 14:45 bbls/min @ 300 psi-Working pipe PU wt 170 SO wt 125 Shut down pump-Line up to Dowell Page 17/49 Report Printed: 12/18/2015 iterations Summary (with Timelogg epths) 0i.i a 2S-04 conoco`PhMips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/4/2015 10/4/2015 2.00 INTRM1 PLUG CMNT T Pump P&A plug#1 /w/3 1/2"mule 7,682.0 7,682.0 14:45 16:45 shoe @ 7683'-Pumped 5 bbls 12.0 ppg Mud push-Test lines to 3900 psi -Pumped 29 bbls 12.0 ppg Mud Push @ 4 bbls/min @ 380 psi-Mixed& pumped 123 bbls 15.8 ppg GASBLOK slurry @ 3 bbls/min @ 280 psi- Pumped 6 bbls 12.0 ppg Mud Push @ 3 bbls/min-Switch to rig pumps& displaced w/11.3 ppg LSND mud @ 4 bbls/min @ 1000 psi-slowed pumps to 3.7 bbls/min @ 1500 to 2400 psi- slowed pumps to 3.3 bbls/min @ 2400 to 2800 psi-Pumped 101 bbls to equalize plug CIP @ 1640 hrs worked pipe while pumping-PU 170 SO 125 @ end of displacement hole getting tight pulled to 400 k-no movement 10/4/2015 10/4/2015 0.25 INTRM1 PLUG RURD T Lay down one joint DP. Rig down 7,682.0 7,649.0 16:45 17:00 cement hose. 10/4/2015 10/4/2015 1.75 INTRM1 PLUG OTHR T Attempt to POOH.Tight hole.Work 7,649.0 7,649.0 17:00 18:45 pipe between 410K up wt.to 100k slack wt. 10/4/2015 10/4/2015 0.50 INTRM1 PLUG OTHR T Attempt to twist off 3 1/2"cement 7,649.0 7,649.0 18:45 19:15 stinger.Rotate and work drill string between 350K up weight and 70K slack wt. 15 rpm, 15K tq.Stinger appeared to be rotating in cement plug. 10/4/2015 10/5/2015 4.75 INTRM1 PLUG WAIT T Wait on cement.Sim-ops/Work on 7,649.0 7,649.0 19:15 00:00 MP2's Clean rig. 10/5/2015 10/5/2015 6.00 INTRM1 PLUG WAIT T Wait on cmt to achieve 500 psi 7,649.0 7,649.0 00:00 06:00 compressive strength-Service rig LD 1 jt 5"DP&PU 5"-10"DP pup jt- slack off wt to 170 k 10/5/2015 10/5/2015 3.25 INTRM1 PLUG ELNE T Spot wire line unit-MU tools in pipe 7,649.0 7,649.0 06:00 09:15 shed 10/5/2015 10/5/2015 1.00 INTRM1 PLUG ELNE T PJSM-RU wireline on rig floor-PU 7,649.0 7,649.0 09:15 10:15 tools 10/5/2015 10/5/2015 2.75 INTRM1 PLUG ELNE T Ran tool string#1 Sinker bars w/CCL 7,649.0 7,649.0 10:15 13:00 -RIH thru 5"DP and tagged top of cement @ 5957'-POOH w/tool string #1 Lost 32.5 bbls f/midnight to noon 10/5/2015 10/5/2015 4.50 INTRM1 PLUG ELNE T MU tool string#2-Dual Effect 7,649.0 7,649.0 13:00 17:30 Freepoint tool and magnet-RIH thru 5"DP to 5957'-POOH&LD magnet 10/5/2015 10/5/2015 0.75 INTRM1 PLUG OTHR T Work drill string from 405K up weight 7,649.0 7,649.0 17:30 18:15 to 120K slack weight. 10/5/2015 10/5/2015 2.00 INTRM1 PLUG ELNE T Wireline run#3. Dual Effect Freepoint 7,649.0 7,649.0 18:15 20:15 tool-RIH thru 5"DP to 5957'MD. Determine that pipe is free to 5825' MD. POOH and lay down freepoint tool. Page 18/49 Report Printed: 12/18/2015 Iperations Summary (with Timelogt pths) r01� 2S-04 Conou;Phillps Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/5/2015 10/6/2015 3.75 INTRM1 PLUG ELNE T Wireline run#4.MU string shot tool 7,649.0 7,649.0 20:15 00:00 string-RIH thru 5"DP-Shoot string shot from 5772'MD to 5778'WLM to descale pipe.. POOH w/string shot tool string. Lost 42 bbls f/noon to midnight 10/6/2015 10/6/2015 1.00 INTRM1 PLUG ELNE T POOH and lay down string shot tool 7,649.0 7,649.0 00:00 01:00 string. 10/6/2015 10/6/2015 0.50 INTRM1 PLUG ELNE T MU radial cutting torch tool string. Pull 7,649.0 7,649.0 01:00 01:30 30K tension on DP.Test grease head 300 psi. 10/6/2015 10/6/2015 2.00 INTRM1 PLUG ELNE T Wireline run#5-RIH w/RCT.Set on 7,649.0 7,649.0 01:30 03:30 depth @ 5775'WLM.Attempt to fire RCT. Lost communication with tool. POOH w/RCT. 10/6/2015 10/6/2015 1.00 INTRM1 PLUG ELNE T Lay down RCT tool string.Top AES 7,649.0 7,649.0 03:30 04:30 knuckle had parted leaving 19'of tool string in hole. 10/6/2015 10/6/2015 2.00 INTRMI PLUG ELNE T Wireline run#6-Make up dummy run 7,649.0 7,649.0 04:30 06:30 toolstring w/3.25"CCL.RIH w/dummy run toolstring.Toolstring would not pass 1500'WLM.POOH 10/6/2015 10/6/2015 3.50 INTRM1 PLUG ELNE T Wireline run#7-Make up fishing 7,649.0 7,649.0 06:30 10:00 toolstring and RIH.Tag TOF @ 5835' WLM.Attempt to engage fish.POOH and lay down fishing toolstring.No fish.recovered. 10/6/2015 10/6/2015 3.50 INTRM1 PLUG ELNE T Wireline run#8-Make up RCT 7,649.0 7,649.0 10:00 13:30 toolstring.Test grease head to 400 psi. RIH and set on depth @ 5775' WLM.Fire RCT. POOH w/RCT toolstring. Mud losses for previous 12 hrs=11.5 bbls. 10/6/2015 10/6/2015 1.25 INTRMI PLUG OTHR T RD wireline.Make up top drive and 7,649.0 7,649.0 13:30 14:45 pull on pipe.225K up to 400K hoist weight in 50K increments multiple times.Trap 18K torque on pipe and work pipe from 125K to 400K hoist weight. Pressure up drill pipe to 3000 psi and work pipe up to 400K hoist weight.All indications show pipe not cut. 10/6/2015 10/6/2015 4.25 INTRM1 PLUG WAIT T Wait on Drill Collar Servering Tool to 7,649.0 7,649.0 14:45 19:00 arrive from Deadhorse. 10/6/2015 10/6/2015 3.25 INTRM1 PLUG ELNE T Wireline run#9-Make up DCST 7,649.0 7,649.0 19:00 22:15 toolstring.Test grease head to 300 psi. RIH and set on depth @ 5764' WLM/5751'DP measurement.Fire DCST. POOH with DCST toolstring. 10/6/2015 10/6/2015 1.00 INTRM1 PLUG PMPO T Make up top drive and pull on pipe. 7,649.0 5,457.0 22:15 23:15 PU=140K. Pump out of the hole from 5751'MD to 5457'MD.2 bpm, 100 psi, 12%FO.Loss rate 96 bph. Page 19/49 Report Printed: 12/18/2015 V 01 *perations Summary (with Timelog�epths) 2S-04 con000Pttillips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/6/2015 10/7/2015 0.75 INTRM1 PLUG CIRC T Brk circ,2 bpm, 100 psi,8%FO.Loss 5,457.0 5,457.0 23:15 00:00 rate 107 BPH.Sim-ops/Rig down Halliburton wireline and clear tools from rig floor. Mud losses for previous 12 hrs=55 bbls. 10/7/2015 10/7/2015 1.00 INTRM1 PLUG CIRC T Attempt to circ.2 bpm, 100 psi.Loss 5,457.0 5,413-- 00:00 ,4000:00 01:00 rate increased to 120 bph.Observe gas increase up to 4000 units. 10/7/2015 10/7/2015 2.00 INTRM1 PLUG WAIT T Wait on mud for bullhead operation. 5,457.0 5,457.0 01:00 03:00 Monitor losses across top of hole. Loss rate 2 to 4 bph. 10/7/2015 10/7/2015 2.50 INTRM1 PLUG COND T Bring 11 ppg mud into pits and weight 5,457.0 5,457.0 03:00 05:30 up to 11.3 ppg w/spike fluid. 10/7/2015 10/7/2015 0.50 INTRM1 PLUG CIRC T Bullhead 90 bbls 11.3 ppg mud down 5,457.0 5,457.0 05:30 06:00 DP.5 bpm, 190 psi 10/7/2015 10/7/2015 0.75 INTRM1 PLUG CIRC T Bullhead 200 bbls 11.3 ppg mud down 5,457.0 5,457.0 06:00 06:45 annulus.6 bpm, ICP 170 psi,FCP 150 psi 10/7/2015 10/7/2015 1.25 INTRM1 PLUG OWFF T OWFF.Slight flow from well.Shut 5,457.0 5,457.0 06:45 08:00 MPD choke.2 psi increase in shut in pressure.Open choke and monitor well.Slight flow from well. 10/7/2015 10/7/2015 4.00 INTRM1 PLUG PMPO T Pump out of hole f/5457'MD t/4978' 5,457.0 2,777.0 08:00 12:00 MD.Bull head out of hole f/4978'MD t/2777'MD. 1.5 bpm down DP and 1.5 bpm down annulus. 100 psi on both sides. Calc disp=20.9 bbls Act disp=225.3 bbls 10/7/2015 10/7/2015 0.50 INTRMI PLUG CIRC T Attempt to circ.2 bpm.No returns 2,777.0 2,777.0 12:00 12:30 10/7/2015 10/7/2015 0.25 INTRM1 PLUG RURD T Blow down top drive. 2,777.0 2,777.0 12:30 12:45 10/7/2015 10/7/2015 0.50 INTRM1 PLUG OWFF T OWFF.Monitor while circulating 2,777.0 2,777.0 12:45 13:15 across top of hole.9 bbls loss. 10/7/2015 10/7/2015 1.50 INTRMI PLUG MPDA T Remove RCD bearing assy. Install trip 2,777.0 2,777.0 13:15 14:45 nipple. 10/7/2015 10/7/2015 1.00 INTRMI PLUG PMPO T Pump out of hole f/2777'MD t/2298' 2,777.0 2,298.0 14:45 15:45 MD.2 bpm, 100 psi,0%FO. Calc disp=3.85 bbls Act disp=47 bbls 10/7/2015 10/7/2015 0.25 INTRM1 PLUG RURD T Blow down TD 2,298.0 2,298.0 15:45 16:00 10/7/2015 10/7/2015 3.50 INTRM1 PLUG TRIP T POOH on elevators f/2298'MD. 2,298.0 0.0 16:00 19:30 Calc disp=18.5 bbls Act disp=83 bbls 10/7/2015 10/7/2015 0.75 INTRM1 PLUG RURD T Clean and clear rig floor. 0.0 0.0 19:30 20:15 10/7/2015 10/7/2015 1.75 INTRM1 WHDBOP RURD T Pull wear bushing.Set test plug. Rig 0.0 0.0 20:15 22:00 up to test BOPE. Page 20/49 Report Printed: 12/18/2015 •perations Summary (with Timelog�epths) 2S-04 conoc hiIIips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/7/2015 10/8/2015 2.00 INTRM1 WHDBOP BOPE T PJSM,test BOPE w/5"test joint to 0.0 0.0 22:00 00:00 250/3500 psi for 5 min each.#1:Top pipe rams,CV 1,12,13, 14&manual kill valve.#2,HCR kill,CV 9,&11.#3: ,CV 5,8&10. #4:CV 4,6&7. #5:CV 2. #6:HCR choke&4"kill line Demco valve, Losses for previous 12 hrs=249 bbls 10/8/2015 10/8/2015 3.50 INTRM1 WHDBOP BOPE T Con't BOP test.Test#7 Manual choke 0.0 0.0 00:00 03:30 valve,HCR kill,Dart valve.#8 Annular preventer to 250/2500 psi.#9 Lower pipe rams.Accumulator test:system pressure=3000 psi,After closing= 1850 psi,200 psi attained after 47 sec,full pressure attained after 166 sec,Five bottle nitrogen avg=2000 psi. 10/8/2015 10/8/2015 1.50 INTRM1 WHDBOP RURD 'T Rig down test equipment.Set 10"ID 0.0 0.0 03:30 05:00 wear ring. 10/8/2015 10/8/2015 0.75 INTRM1 PLUG SVRG T Service draworks and top drive. 0.0 0.0 05:00 05:45 10/8/2015 10/8/2015 0.75 INTRM1 PLUG RURD T Rig up to pick up cement stinger assy. 0.0 0.0 05:45 06:30 10/8/2015 10/8/2015 2.75 INTRM1 PLUG PULD T Make up Baker ECP. PU and RIH w/3 0.0 1,146.0 06:30 09:15 1/2"EUE 8rd 9.3# L-80 cement stinger to 1146'MD. Calc disp=3.7 bbls Act disp=-13.7 bbls 10/8/2015 10/8/2015 0.75 INTRM1 PLUG RURD T Rig down casing equipment.Change 1,146.0 1,146.0 09:15 10:00 out elevators.Make up X-O's. 10/8/2015 10/8/2015 2.00 INTRM1 PLUG PULD T RIH w/cement stinger on DP f/1146' 1,146.0 2,395.0 10:00 12:00 MD t/2395'MD,picking up singles from pipe shed Calc disp=6.6 bbls Act disp=-14.3 10/8/2015 10/8/2015 4.25 INTRM1 PLUG PULD T Con't to RIH w/cement stinger on DP 2,395.0 5,662.0 12:00 16:15 f/2395 MD t/5662'MD,picking up singles from pipe shed. Calc disp=31.9 bbls Act disp=-70.16 10/8/2015 10/8/2015 0.25 INTRM1 PLUG RURD T Pick up 10'pup joint. Make up head 5,662.0 5,662.0 16:15 16:30 pin and cement hose. 10/8/2015 10/8/2015 0.50 INTRM1 PLUG CIRC T Attempt to circ.2 bpm,200 psi,PU 5,662.0 5,662.0 16:30 17:00 125K SO 100K.No returns 10/8/2015 10/8/2015 0.50 INTRM1 PLUG CIRC T Drop pump down plug.4 bpm,320 5,662.0 5,662.0 17:00 17:30 psi.Slow pump to 2.5 bpm,240 psi after 750 stks pumped.Land plug @ 832 stks w/500 psi.Bleed off pressure.Max gas=4244 units. Page 21/49 Report Printed: 12/18/2015 •perations Summary (with Timelog�epths) 2S-04 conoc h1Itip5 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/8/2015 10/8/2015 1.00 INTRM1 PLUG MPSP T Inflate ECP as per Baker rep. Line up 5,662.0 5,590.0 17:30 18:30 pump on pill pit.Pressure up to 500 psi and strap pill pit.Pressure up to 1350 psi.Pressure bled to 1173 psi. Pressure up to 1245 psi.Pressure bled to 1229 psi. Hold for 10 min's. Pressure up to 1400 psi.Set down 5K weight.Pick up to neutral weight.Bleed pressure to 0 psi.Set down 5K wt.Pressure up to 500 psi. Strap pill pit.Pressure up to 1700 psi and shear from ECP.ECP packing element set @ 5600'MD.PU 120K. Lay down 10'pup joint. 10/8/2015 10/8/2015 0.75 INTRM1 PLUG CIRC T Attempt to circ.2 bpm, 175 psi.Loss 5,590.0 5,590.0 18:30 19:15 rate 92 bph.Slight returns. Max gas=6249 units 10/8/2015 10/8/2015 2.50 INTRM1 PLUG CIRC T Bullhead 425 bbls 11.3 ppg mud down 5,590.0 5,590.0 19:15 21:45 annulus.3bpm, 100 psi. 10/8/2015 10/8/2015 0.75 INTRM1 PLUG OWFF T Monitor well.Static 5,590.0 5,590.0 21:45 22:30 10/8/2015 10/9/2015 1.50 INTRM1 PLUG CMNT T Pump P&A plug#2/ @ 5990'- 5,590.0 5,590.0 22:30 00:00 Pumped 5 bbls 12.0 ppg Mud push- Test lines to 3500 psi-Pumped 19.1 bbls 12.0 ppg Mud Push @ 3 bbls/min ©150 psi-Mixed&pumped 73.9 bbls 15.8 ppg GASBLOK slurry @ 4.5 bbls/min @ 190 psi-Pumped 3.9 bbls 12.0 ppg Mud Push @ 2.5 bbls/min- Switch to rig pumps&displaced w/ 11.3 ppg LSND mud @ 6 bbls/min @ 185 psi-slowed pumps to 2 bbls/min @ 350 stks.Pumped 74 bbls to equalize plug CIP @ 00:00 hrs 10/9/15 PU 125 SO 100 Losses for previous 12 hrs=668 bbls. 10/9/2015 10/9/2015 1.50 INTRM1 PLUG TRIP T Rig down cement hose. POOH 5,590.0 4,752.0 00:00 01:30 f/5590'MD t/4752'MD. PU 120K Calc disp=6.7 bbls Act disp=6 bbls 10/9/2015 10/9/2015 0.50 INTRM1 PLUG CIRC T Drop wiper ball.Attempt to circ. No 4,752.0 4,752.0 01:30 02:00 returns. Pump one drill string volume. 2 bpm. 100 psi. 10/9/2015 10/9/2015 0.25 INTRM1 PLUG TRIP T POOH f/4752'MD t/4647'MD.Blow 4,752.0 4,647.0 02:00 02:15 down top drive. 10/9/2015 10/9/2015 0.50 INTRM1 PLUG OWFF T Monitor well.Fluid level slowly 4,647.0 4,647.0 02:15 02:45 dropping in BOP stack. 10/9/2015 10/9/2015 2.25 INTRM1 PLUG TRIP T POOH f/4647'MD t/2760'MD. 4,647.0 2,760.0 02:45 05:00 Calc disp=22.95 bbls Act disp=28.96 bbls 10/9/2015 10/9/2015 5.50 INTRM1 PLUG WOC T WOC. Monitor well on trip tank.20-25 2,760.0 2,760.0 05:00 10:30 bph loss rate Sim-ops/Clean and clear rig floor.Slip and cut drilling line.Work on MP2's,Work on top drive compensator,change out PRV on#2 mud pump. 10/9/2015 10/9/2015 1.25 INTRM1 PLUG TRIP T RIH f/2760'MD t/4845'MD. 2,760.0 4,845.0 10:30 11:45 Calc disp=16.16 bbls Act disp=30.95 bbls. Page 22/49 Report Printed: 12/18/2015 Iperations Summary (with Timelog pths) Oli o 2S-04 Conor hilhps hM:Aa Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/9/2015 10/9/2015 0.50 INTRM1 PLUG WASH T Wash down f/4845'MD t/5036'MD. 4,845.0 5,036.0 11:45 12:15 1.5 bpm, 150 psi, PU 107K SO 92K.Tag TOC @ 5036'MD.Set down 4K weight,observe 50 psi pressure increase. Total Losses for previous 12 hrs=173 bbls. 10/9/2015 10/9/2015 0.25 INTRM1 PLUG TRIP T POOH to 5026'MD.Blow down top 5,036.0 5,026.0 12:15 12:30 drive. 10/9/2015 10/9/2015 3.75 INTRM1 PLUG WAIT T Wait on orders and Schlumberger 5,026.0 5,026.0 12:30 16:15 cementers to arrive on location.Work pipe @ 200 fph while monitoring well on trip tank.2bph loss rate. 10/9/2015 10/9/2015 0.25 INTRM1 PLUG SFTY T PJSM on pumping P&A plug#3. 5,026.0 5,026.0 16:15 16:30 10/9/2015 10/9/2015 1.75 INTRM1 PLUG RURD T Load contamination pill on vac truck. 5,026.0 5,026.0 16:30 18:15 Rig up cement trucks. Batch mix mud push. 10/9/2015 10/9/2015 1.50 INTRM1 PLUG CMNT T Pump P&A plug#3/ @ 5026'- 5,026.0 5,026.0 18:15 19:45 Pumped 5 bbls 12.0 ppg Mud push- Test lines to 3850 psi-Pumped 19.1 bbls 12.0 ppg Mud Push @ 3 bbls/min @ 150 psi-Mixed&pumped 43 bbls 15.8 ppg GASBLOK slurry @ 4 bbls/min @ 125 psi-Pumped 4 bbls 12.0 ppg Mud Push @ 2.8 bbls/min- Switch to rig pumps&displaced w/ 11.3 ppg LSND mud @ 6 bbls/min @ 170 psi-slowed pumps to 2 bbls/min @ 350 stks.Pumped 68 bbls to equalize plug.CIP @ 17:48 hrs 10/9/15 PU 107 SO 92 10/9/2015 10/9/2015 0.25 INTRM1 PLUG RURD T Rig down cement equipment 5,026.0 5,026.0 19:45 20:00 10/9/2015 10/9/2015 0.75 INTRM1 PLUG TRIP T POOH f/5026'MD t/4378'MD @ 5,026.0 4,378.0 20:00 20:45 1000 fph. Calc disp=5.38 bbls Act disp=6.8 bbls 10/9/2015 10/10/2015 3.25 INTRM1 PLUG CIRC T CBU x 2.3 bpm, 150 psi, 15%FO.No 4,378.0 4,378.0 20:45 00:00 losses. Total losses for previous 12 hrs=71.5 bbls 10/10/2015 10/10/2015 0.75 INTRM1 PLUG CIRC T CBU @ 4378'MD.3 bpm, 150 psi, 4,378.0 4,378.0 00:00 00:45 15%FO.No losses. 10/10/2015 10/10/2015 0.75-INTRM1 PLUG OWFF T Monitor well.Static. Blow down top 4,378.0 4,378.0 00:45 01:30 drive and kill line. 10/10/2015 10/10/2015 1.50 INTRM1 PLUG TRIP T POOH f/4378'MD t/2700'MD. 4,378.0 2,700.0 01:30 03:00 Calc disp=13.08 bbls Act disp=14.45 bbls 10/10/2015 10/10/2015 3.50 INTRM1 PLUG WOC T Wait on cement. Monitor well on trip 2,700.0 2,700.0 03:00 06:30 tank.No losses.Sim-ops/Clear and clean rig floor,work on MP2's,perform derrick inspection. 10/10/2015 10/10/2015 0.75 INTRM1 PLUG TRIP T RIH f/2700'MD t/4290'MD. 2,700.0 4,290.0 06:30 07:15 10/10/2015 10/10/2015 1.75 INTRM1 PLUG WASH T Wash down f/4290'MD t/4877'MD.2 4,290.0 4,877.0 07:15 09:00 bpm, 150 psi. PU 100K SO 85K.Tag TOC @ 4877'MD.Set down 5K weight. Page 23/49 Report Printed: 12/18/2015 Iperations Summary (with Timelogepths) 0 2S-04 Gond x4ftl6ps AGxAn Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/10/2015 10/10/2015 0.25 INTRM1 PLUG TRIP T POOH f/4877'MD t/4845'MD. 4,877.0 4,845.0 09:00 09:15 10/10/2015 10/10/2015 0.25 INTRM1 PLUG OWFF T Blow down top drive. Monitor well. 4,845.0 4,845.0 09:15 09:30 Mud out of balance flowing out of DP. 10/10/2015 10/10/2015 1.00 INTRM1 PLUG CIRC T CBU.6 bpm,390 psi, 19%FO 4,845.0 4,845.0 09:30 10:30 10/10/2015 10/10/2015 0.50 INTRM1 PLUG OWFF T Monitor well.Static.Blow down top 4,845.0 4,845.0 10:30 11:00 drive. 10/10/2015 10/10/2015 1.75 INTRM1 PLUG TRIP T POOH f/4845'MD t/2790'MD. 4,845.0 2,790.0 11:00 12:45 Calc disp=24.36 bbls Act disp=24.76 bbls 10/10/2015 10/10/2015 0.25 INTRM1 PLUG RURD T Rig up to perform FIT 2,790.0 2,790.0 12:45 13:00 10/10/2015 10/10/2015 0.75 INTRM1 PLUG FIT T Perform FIT to 12.5 ppg EMW 2,790.0 2,790.0 13:00 13:45 10/10/2015 10/10/2015 3.75 INTRM1 PLUG TRIP T POOH. Lay down ECP running tool. 2,790.0 0.0 13:45 17:30 10/10/2015 10/10/2015 0.25 INTRM1 PLUG RURD T Clean and clear rig floor. 0.0 0.0 17:30 17:45 10/10/2015 10/10/2015 1.75 INTRM1 PLUG BHAH T Make up Baker ECP assy. 0.0 80.0 17:45 19:30 10/10/2015 10/11/2015 4.50 INTRM1 PLUG TRIP T RIH w/ECP on 3 1/2"tbg/5"DP f/80' 80.0 3,076.0 19:30 00:00 MD t/3076'MD. Calc disp=18.87 bbls Act disp=15.47 bbls 10/11/2015 10/11/2015 0.50 INTRM1 PLUG TRIP T RIH f/3076'MD t/3300'MD.Top of 3,076.0 3,300.0 00:00 00:30 ECP @ 3231'MD.PU 78K SO 73K 10/11/2015 10/11/2015 0.25 INTRM1 PLUG CIRC T Circulate drill string volume.3 3,300.0 3,300.0 00:30 00:45 bpm=155 psi,4 bpm=185 psi,5 bpm=249 psi.No losses 10/11/2015 10/11/2015 0.25 INTRM1 PLUG CIRC T Drop pump down plug at 5 bpm 220 3,300.0 3,300.0 00:45 01:00 psi.Slow pump to 2 bpm, 126 psi at 400 stks, land on seat w/443 stks. 10/11/2015 10/11/2015 1.50 INTRM1 PLUG MPSP T Establish 500 psi baseline pressure, 3,300.0 3,300.0 01:00 02:30 hold for 1 min.Zero stroke counter. Increase pressure in 200 psi increments holding each for 1 min to 1500 psi(total of 8 stks pumped). Bleed pressure to 500 psi. Pressure up to 1500 psi(total of 6 stks pumped).Bleed pressure to 0 psi. Work string down/up with no set down weight or overpull.Pressure up to 1400 psi.Shut in pumps.No bleed down.Pressure up to 1550 psi.Shut in pumps.No bleed off. Bleed pressure to 500 psi.Pressure up to 1600 psi. No bleed off.Work string. No indication that ECP is inflated. 10/11/2015 10/11/2015 0.50 INTRM1 PLUG WAIT T Consult with drilling engineer and 3,300.0 3,300.0 02:30 03:00 drilling superintendent.Decision made to disconnect from ECP and conduct pump kick off plug. Page 24/49 Report Printed: 12/18/2015 or Iterations Summary (with TimelogiPepths) 2S-04 ConooeittiILips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/11/2015 10/11/2015 0.50 INTRM1 PLUG MPSP T Pressure up to 500 psi baseline 3,300.0 3,226.0 03:00 03:30 pressure. Increase pressure in 200 psi increments to 1700 psi.Disconnect sheared @ 1700 psi.Circ 10 bbls to ensure clear flow path.. Lay down 10' pup joint.Blow down top drive.Top of ECP @ 3231'MD. 10/11/2015 10/11/2015 0.25 INTRM1 PLUG RURD T Rig up head pin and cement hose. 3,225.0 3,226.0 03:30 03:45 10/11/2015 10/11/2015 1.00 INTRM1 PLUG CIRC T CBU.6 bpm,300 psi, 18%FO.Sim- 3,226.0 3,226.0 03:45 04:45 ops/PJSM on pumping cement. 10/11/2015 10/11/2015 1.00 INTRM1 PLUG CMNT T Pump kick off plug @ 3226'- 3,226.0 3,226.0 04:45 05:45 Pumped 5 bbls 12.0 ppg Mud push- Test lines to 3850 psi-Pumped 18 bbls 12.0 ppg Mud Push @ 4.5 bbls/min @ 200 psi-Mixed&pumped 68.5 bbls 17 ppg Class G slurry @ 4 bbls/min @ 150 psi-Pumped 5 bbls 12.0 ppg Mud Push @ 4 bbls/min- Switch to rig pumps&displaced w/ 11.3 ppg LSND mud @ 6 bbls/min @ 190 psi-slowed pumps to 2 bbls/min @ 150 stks. Pumped 30 bbls to equalize plug.CIP @ 05:45 hrs 10/11/2015 10/11/2015 1.25 INTRM1 PLUG TRIP T POOH f/3226'MD t/2482'MD @ 3,226.0 2,482.0 05:45 07:00 1000 fph. Calc disp=7.70 bbls Act disp=6.46 bbls 10/11/2015 10/11/2015 0.75 INTRM1 PLUG CIRC T Drop wiper ball.CBU x 2.450 gpm, 2,482.0 2,482.0 07:00 07:45 300 psi,27%FO. 10/11/2015 10/11/2015 13.75 INTRM1 PLUG WOC T WOC.Sim-ops/POOH to 2387'MD. 2,482.0 2,387.0 07:45 21:30 Rig up to lay down 5"DP.Lay down 60 stds 5"DP.Move HWDP f/drillers side t/off drillers side of rig floor. Pick up 60 jts 5"DP from pipe shed.Work on MP2's,replace service loop softner,service top drive.Monitor well on trip tank.No losses. 10/11/2015 10/11/2015 2.25 INTRM1 PLUG WASH T Wash down f/2387'MD t/3507'MD.2 2,387.0 3,507.0 21:30 23:45 bpm, 125-275 psi. 13%FO. PU 75K SO 73K 10/11/2015 10/12/2015 0.25 INTRM1 PLUG CIRC T CBU.4 bpm,300 psi. 3,507.0 3,507.0 23:45 00:00 10/12/2015 10/12/2015 2.50 INTRM1 PLUG CIRC T Circ and cond mud.4 bpm,300 psi, 3,507.0 3,507.0 00:00 02:30 16%FO.Slow pump to 1.5 bpm,250 psi 8%FO due to contaminated mud flowing over shakers.Stage up to 6 bpm,200 psi, 16%FO 10/12/2015 10/12/2015 0.50 INTRM1 PLUG CIRC T Spot 25 bbl hi-vis pill.6 bpm,600 psi. 3,507.0 3,507.0 02:30 03:00 Blow down TD. 10/12/2015 10/12/2015 0.50 INTRM1 PLUG TRIP T POOH f/3507'MD t/3226'MD 3,507.0 3,226.0 03:00 03:30 10/12/2015 10/12/2015 0.50 INTRM1 PLUG CIRC T CBU.6 bpm,300 psi 18%FO.Sim- 3,226.0 3,226.0 03:30 04:00 ops/Hole PJSM on pumping cement. 10/12/2015 10/12/2015 0.50 INTRM1 PLUG RURD T Blow down TD.Rig up head pin and 3,226.0 3,226.0 04:00 04:30 cement hose. Page 25/49 Report Printed: 12/18/2015 operations Summary (with Timelog�epths) 2S-04 Conon. hiII1ps AFeskn Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/12/2015 10/12/2015 1.00 INTRM1 PLUG CMNT T Pump kick off plug#2 @ 3226'- 3,226.0 3,226.0 04:30 05:30 Pumped 5 bbls 12.0 ppg Mud push- Test lines to 3650 psi-Pumped 18 bbls 12.0 ppg Mud Push @ 4.5 bbls/min @ 200 psi-Mixed&pumped 68.5 bbls 17 ppg Class G slurry @ 4 bbls/min @ 150 psi-Pumped 5 bbls 12.0 ppg Mud Push @ 4.1 bbls/min- Switch to rig pumps&displaced w/ 11.3 ppg LSND mud @ 6 bbls/min @ 190 psi-slowed pumps to 2 bbls/min @ 150 stks.Pumped 30 bbls to equalize plug.CIP @ 05:30 hrs 10/12/2015 10/12/2015 1.00 INTRM1 PLUG TRIP T POOH f/3226'MD t/2480'MD. 3,226.0 2,480.0 05:30 06:30 10/12/2015 10/12/2015 1.00 INTRM1 PLUG CIRC T Drop wiper ball.CBU x 2.450 gpm, 2,480.0 2,480.0 06:30 07:30 300 psi,27%FO. 10/12/2015 10/12/2015 0.50 INTRM1 PLUG OWFF T Monitor well.Static. 2,480.0 2,480.0 07:30 08:00 10/12/2015 10/12/2015 0.75 INTRM1 PLUG TRIP T POOH f/2480'MD t/1046'MD. 2,480.0 1,046.0 08:00 08:45 Calc disp=11.55 bbls Act disp=12.24 bbls. 10/12/2015 10/12/2015 1.75 INTRM1 PLUG PULD T Rig up and lay down 33 jts of 3 1/2" 1,046.0 0.0 08:45 10:30 EUE cement stinger 10/12/2015 10/12/2015 0.75 INTRM1 PLUG RURD T Rig down casing equipment.Clean 0.0 0.0 10:30 11:15 and clear rig floor. 10/12/2015 10/12/2015 0.50 INTRM1 WHDBOP RURD T Drain BOP stack.Pull wear bushing. 0.0 0.0 11:15 11:45 10/12/2015 10/12/2015 1.00 INTRM1 WHDBOP RURD T Rig up to test BOPE. 0.0 0.0 11:45 12:45 10/12/2015 10/12/2015 4.75 INTRM1 WHDBOP RGRP T Test BOPE w/5"test joint to 250/3500 0.0 0.0 12:45 17:30 psi for 5 min each.#1:Top pipe rams, CV 1,12,13, 14&manual kill valve. Upper pipe rams failed. Remove, redress and reinstall upper pipe rams. 10/12/2015 10/12/2015 3.50 INTRM1 WHDBOP BOPE T Test BOPE w/5"test joint to 250/3500 0.0 0.0 17:30 21:00 psi for 5 min each.#1:Top pipe rams, CV 1,12,13, 14&manual kill valve. #2: Upper IBOP,HCR kill,CV 9,&11. #3: Lower IBOP,CV 5,8&10. #4: Dart,CV 4,6&7. #5:FOSV and CV 2. #6:HCR choke&4"kill line Demco valve, #7: Manual choke valve& HCR kill. #8:Annular preventer tested to 250/2500 psi.#9: Lower pipe rams. #10: Blind rams and CV 3. Accumulator test:system pressure= 3000 psi,After closing=2000 psi,200 psi attained after 41 sec,full pressure attained after 140 sec,Five bottle nitrogen avg=2000 psi.Draw down test on manual and hydraulic chokes to 1400 psi. The BOP test was witnessed by AOGCC Rep.Johnnie Hill. 10/12/2015 10/12/2015 1.00 INTRM1 WHDBOP RURD T Rig down test equipment.Set 10"ID 0.0 0.0 21:00 22:00 wear ring. Blow down choke manifold, kill and choke lines Page 26/49 Report Printed: 12/18/20151 illf.:; Iperations Summary (with Timelog•pths) tza 2S-04 Conoco`1 illips A F.r.k. Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftK8) End Depth(ftKB) 10/12/2015 10/12/2015 0.50 INTRM1 PLUG BHAH T Mobilize BHA components to rig floor 0.0 0.0 22:00 22:30 10/12/2015 10/12/2015 0.25 INTRM1 PLUG SFTY T PJSM on making up BHA 0.0 0.0 22:30 22:45 10/12/2015 10/13/2015 1.25 INTRM1 PLUG BHAH T Make up 9 7/8"x 11"BHA as per SLB. 0.0 0.0 22:45 00:00 10/13/2015 10/13/2015 1.75 INTRM1 PLUG BHAH T PJSM, M/U BHA#3 and load nuclear 0.0 723.0 00:00 01:45 sources as per SLB rep. 10/13/2015 10/13/2015 0.50 INTRM1 PLUG TRIP T RIH f/723'MD to 1661'MD w/5"DP 723.0 1,661.0 01:45 02:15 out of derrick. Fire Drill CRT 120 sec @ 02:15 hrs. 10/13/2015 10/13/2015 0.25 INTRM1 PLUG DHEQ T Shallow hole pulse test MWD @ 450 1,661.0 1,661.0 02:15 02:30 gpm, 1050 psi,30%FO. 10/13/2015 10/13/2015 0.75 INTRM1 PLUG TRIP T RIH f/1661'MD to 2480'MD.Actual 1,661.0 2,480.0 02:30 03:15 displacement=38.34 bbls,Calculated displacement=39.04 bbls. 10/13/2015 10/13/2015 0.25 INTRM1 PLUG WASH T Wash down f/2480'-2642'MD tagging 2,480.0 2,642.0 03:15 03:30 cement,3 bpm, 175 psi,FO 15%,tag cement w/6K. 10/13/2015 10/13/2015 0.25 INTRM1 PLUG DRLG T Drill cement f/2642'-2682'MD,453 2,642.0 2,682.0 03:30 03:45 gpm, 1181 psi, FO 28%,40 rpm,Tq 2K. 10/13/2015 10/13/2015 0.50 INTRM1 PLUG CIRC T Circulate hole clean due to shakers 2,682.0 2,682.0 03:45 04:15 running over,453 gpm, 1181 psi,FO 28%,40 rpm,Tq 2K. 10/13/2015 10/13/2015 1.25 INTRM1 PLUG DRLG T Drill cement f/2682'-2782'MD,453 2,682.0 2,782.0 04:15 05:30 gpm, 1181 psi, FO 28%,40 rpm,Tq 2K. 10/13/2015 10/13/2015 1.00 INTRM1 PLUG DISP T PJSM;displace well f/11.1 ppg to 2,782.0 2,782.0 05:30 06:30 10.1 ppg LSND mud. Pump 23 bbls high-vis sweep&chase w/10.1 ppg LSND,460 gpm, 1100 psi,40 rpm,Tq 3K. SPR's @ 2782'MD,2537'TVD,MW 10.1 ppg,06:15 hrs. #1 @ 20=116 psi @ 30=164 psi #2@20=116 psi @ 30=165 psi 10/13/2015 10/13/2015 0.50 INTRM1 PLUG DRLG T Drill cement f/2782'-2815'MD,453 2,782.0 2,815.0 06:30 07:00 gpm, 1100 psi,FO 28%,40 rpm,Tq 2K. 10/13/2015 10/13/2015 2.00 INTRM1 DRILL DDRL T PJSM; Directional drilling f/2815'- 2,815.0 2,952.0 07:00 09:00 2952'MD,2659'TVD,ADT 1.7,Bit 1.7,Jars 100.31, PU 107K,SO 89K, ROT 99K,Tq on 1-9K,off 3-5K,ECD 10.69, FO 38%,WOB 3-5K,80 rpm, 650 gpm, 142 spm, 1760 psi,Max Gas 0,Total Footage 137'. 10/13/2015 10/13/2015 0.25 INTRM1 DRILL CIRC T Circulate hole clean,650 gpm, 1760 2,952.0 2,952.0 09:00 09:15 psi, FO 38%,80 rpm,Tq 4K. 10/13/2015 10/13/2015 1.00 INTRM1 DRILL MPDA T PJSM;remove trip nipple&install 2,952.0 2,952.0 09:15 10:15 RCD. 10/13/2015 10/13/2015 0.25 INTRM1 DRILL CIRC T PJSM,drop opening ball as per 2,952.0 2,952.0 10:15 10:30 reamer hand.6-3 bpm,observed opening at 1300 psi. Page 27/49 Report Printed: 12/18/2015 "fling Iterations Summary (with Timelog•pths) eflls 2S-04 Conoco`PhiIGps iti A I:aAn Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation _ (ftKB) End Depth(ftKB) 10/13/2015 10/13/2015 0.50 INTRM1 DRILL DDRL T PJSM;Directional drilling f/2952'- 2,952.0 2,970.0 10:30 11:00 2970'MD,2672'TVD,ADT.29, Bit 1.99,Jars 100.6,PU 107K,SO 89K, ROT 99K,Tq on 1-9K,off 3-5K, ECD 11.1,FO 38%,WOB 5-10K,80 rpm, 750 gpm, 175 spm, 1755 psi,Max Gas 0,Total Footage 18'. RCD bearing observed leaking. 10/13/2015 10/13/2015 0.25 INTRM1 DRILL CIRC T Circulate hole clean,750 gpm, 1750 2,970.0 2,970.0 11:00 11:15 psi, FO 38%,80 rpm,Tq 4K. 10/13/2015 10/13/2015 0.50 INTRM1 DRILL MPDA T PJSM;change out RCD. 2,970.0 2,970.0 11:15 11:45 10/13/2015 10/13/2015 0.25 INTRM1 DRILL SRVY T Shoot surveys as per SLB. 2,970.0 2,970.0 11:45 12:00 10/13/2015 10/13/2015 6.00 INTRM1 DRILL DDRL T PJSM;Directional drilling f/2970'- 2,970.0 3,343.0 12:00 18:00 3343'MD,2940'TVD,ADT 4.48,Bit 6.47,Jars 105.08, PU 117K,SO 92K, ROT 100K,Tq on 3-8K,off 1-10K, ECD 10.98,FO 76%,WOB 3-5K, 140 rpm,770 gpm, 183 spm, 1975 psi, Max Gas 251,Total Footage 373'. 10/13/2015 10/14/2015 6.00 INTRM1 DRILL DDRL T PJSM;Directional drilling f/3343'- 3,343.0 3,688.0 18:00 00:00 3688'MD,3161'TVD,ADT 3.89,Bit 10.36,Jars 108.97,PU 120K,SO 94K, ROT 103K,Tq on 5-8K,off 4-6K, ECD 10.93,FO 78%,WOB 3-7K, 150 rpm,765 gpm, 180 spm,2000 psi, Max Gas 70,Total Footage 345'. SPR's @ 3625'MD,3127'TVD, MW 10.0 ppg,22:50 hrs. #1 @ 20= 110 psi @ 30= 140 psi #2@20= 110 psi @30=140 psi 10/14/2015 10/14/2015 6.00 INTRM1 DRILL DDRL T PJSM; Directional drilling f/3688'- • 3,688.0 4,135.0 00:00 06:00 4135'MD,3421'TVD,ADT 4.92,Bit 15.28,Jars 113.89,PU 130K,SO 94K, ROT 107K,Tq on 7-9K,off 5-6K, ECD 11.18,FO 77%,WOB 5-8K, 120 rpm,775 gpm, 183 spm,2210 psi, Max Gas 79,Total Footage 447'. Kick w/Drilling CRT=69 sec @ 05:15 hrs. 10/14/2015 10/14/2015 6.00 INTRM1 DRILL DDRL T PJSM; Directional drilling f/4135'- 4,135.0 4,560.0 06:00 12:00 4560'MD,3717'TVD,ADT 4.57,Bit 19.85,Jars 118.6, PU 147K,SO 97K, ROT 115K,Tq on 9-10K,off 6-8K, ECD 11.14,FO 78%,WOB 9-11K, 110 rpm,775 gpm, 183 spm,2285 psi, Max Gas 70,Total Footage 425'. SPR's @ 4467'MD,3642'TVD,MW 10.0+ppg, 10:15 hrs. #1 @ 20= 120 psi @ 30=140 psi #2@20= 120 psi @30=140 psi Page 28/49 Report Printed: 12/18/2015 •perations Summary (with Timelog9pths) r� 0 :i 2S-04 Conon :ahilhps A kxkn Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/14/2015 10/14/2015 2.50 INTRM1 DRILL DDRL T PJSM; Directional drilling f/4560'- 4,560.0 4,747.0 12:00 14:30 4747'MD,3863'TVD,ADT 2.18,Bit 22.03,Jars 120.64,PU 147K,SO 97K, ROT 115K,Tq on 9-10K,off 6- 8K,ECD 11.05, FO 80%,WOB 5-8K, 110 rpm,777 gpm, 184 spm,2450 psi, Max Gas 63,Total Footage 187'. 10/14/2015 10/14/2015 0.50 INTRM1 DRILL OWFF T Observed a pressure build up of 97 4,747.0 4,747.0 14:30 15:00 psi on the shut in chokes during a connection @ 4735'MD. 10/14/2015 10/14/2015 0.75 INTRM1 DRILL CIRC T CBU @ 793-700 gpm,2550-2000 psi, 4,747.0 4,747.0 15:00 15:45 FO 76-69%,60 rpm,Tq 6K,ECD 10.91,Max gas 3268. 10/14/2015 10/14/2015 2.25 INTRM1 DRILL DDRL T PJSM; Directional drilling f/4747'- 4,747.0 4,948.0 15:45 18:00 4948'MD,4016'TVD,ADT 2.24, Bit 24.27,Jars 122.88, PU 155K,SO 104K, ROT 121K,Tq on 9-11K,off 3- 14K, ECD 11.3, FO 79%,WOB 4-8K, 130 rpm,806 gpm, 190 spm,2775 psi, Max Gas 64,Total Footage 201'. 10/14/2015 10/14/2015 0.25 INTRM1 DRILL CIRC T Clamp to RCD was loose and leaking. 4,948.0 4,948.0 18:00 18:15 Circulate @ 800 gpm,2700 psi, FO 80%,ECD 11.02,60 rpm,Tq 7K. 10/14/2015 10/14/2015 0.25 INTRM1 DRILL CIRC T PJSM;tighten clamp&check for 4,948.0 4,948.0 18:15 18:30 leaks. 10/14/2015 10/15/2015 5.50 INTRM1 DRILL DDRL T PJSM; Directional drilling f/4948'- 4,948.0 5,213.0 18:30 00:00 5213'MD,4258'TVD,ADT 3.08,Bit 27.35,Jars 125.96,PU 169K,SO 104K,ROT 125K,Tq on 11-13K,off 9- 10K,ECD 11.2, FO 80%,WOB 10K, 120 rpm,800 gpm, 190 spm,2700 psi, Max Gas 74,Total Footage 265'. SPR's @ 4934'MD,4016'TVD, MW 10.0 ppg, 18:30 hrs. #1 @20= 150 psi @30=190 psi #2@20= 150 psi @30=190 psi 10/15/2015 10/15/2015 6.00 INTRM1 DRILL DDRL T PJSM; Directional drilling f/5213'- 5,213.0 5,677.0 00:00 06:00 5677'MD,4676'TVD,ADT 5,Bit 32.35,Jars 130.96,PU 182K,SO 112K,ROT 134K,Tq on 10-13K,off 10-15K,ECD 11.09,FO 80%,WOB 5- 10K, 120 rpm,800 gpm,2800 psi, Max Gas 255,Total Footage 464'. 10/15/2015 10/15/2015 4.25 INTRM1 DRILL DDRL T PJSM; Directional drilling f/5677'- 5,677.0 5,956.0 06:00 10:15 5956'MD,4923'TVD,ADT 2.96,Bit 35.31,Jars 133.92,PU 190K,SO 113K, ROT 135K,Tq on 7-18K,off 10- 17K, ECD 11.0,FO 80%,WOB 5-8K, 120/130 rpm,800 gpm,2890 psi,Max Gas 311,Total Footage 279'. SPR's @ 5955'MD,4918'TVD,MW 10.0 ppg, 10:15 hrs. #1@20= 150 psi @30=200 psi #2@20= 150 psi @30=200 psi Spill Drill CRT 90 sec @ 09:00 hrs. 10/15/2015 10/15/2015 0.50 INTRM1 DRILL CIRC T Circulate half a BU @ 800 gpm,2950 5,956.0 5,956.0 10:15 10:45 psi,50 rpm,Tq 10K.Observed RCD bearing leaking. Page 29/49 Report Printed: 12/18/2015 Aerations Summary (with Timelog•pths) 0 2S-04 con000`Phillips ALnka Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/15/2015 10/15/2015 1.25 INTRM1 DRILL MPDA T PJSM;change out RCD bearing& 5,956.0 5,956.0 10:45 12:00 break in rebuilt bearing.Hold 100 psi down hole. 10/15/2015 10/15/2015 6.00 INTRM1 DRILL DDRL T PJSM; Directional drilling f/5956'- 5,956.0 6,350.0 12:00 18:00 6350'MD,5258'TVD,ADT 4.52,Bit 39.83,Jars 138.44, PU 197K,SO 120K, ROT 149K,Tq on 15-18K,off 11-13K,ECD 11.15, FO 76%,WOB 14K, 130 rpm,800 gpm,2975 psi, Max Gas 200,Total Footage 394'. 10/15/2015 10/16/2015 6.00 INTRM1 DRILL DDRL T PJSM; Directional drilling f/6350'- 6,350.0 6,700.0 18:00 00:00 6700'MD,5532'TVD,ADT 4.17,Bit 44.0,Jars 142.61,PU 210K,SO 121K, ROT 154K,Tq on 10-13K,off 10-15K,ECD 10.96, FO 80%,WOB 10-13K, 130 rpm,800 gpm,2825 psi, Max Gas 718,Total Footage 350'. SPR's @ 6700'MD,5532'TVD,MW 10.0 ppg,23:18 hrs. #1 @ 20=147 psi @ 30= 180 psi #2@20=130 psi @30=204 psi 10/16/2015 10/16/2015 6.00 INTRM1 DRILL DDRL T PJSM;Directional drilling f/6700'- 6,700.0 7,174.0 00:00 06:00 7174'MD,5848'TVD,ADT 5.83,Bit 49.83,Jars 148.44,PU 200K,SO 127K,ROT 146K,Tq on 13-18K,off 12-13K,ECD 11.18,FO 82%,WOB 10-15K, 140 rpm,800 gpm,3130 psi, Max Gas 1121,Total Footage 474'. Fire Drill CRT 68 sec @ 05:30 hrs. 10/16/2015 10/16/2015 2.25 INTRM1 DRILL DDRL T PJSM;Directional drilling f/7174'- 7,174.0 7,269.0 06:00 08:15 7269'MD,5903'TVD,ADT 1.6,Bit 50.89,Jars 149.50,PU 200K,SO 125K,ROT 151K,Tq on 13-19K,off 12-14K,ECD 11.13,FO 80%,WOB 14-16K, 140 rpm,800 gpm,3160 psi, Max Gas 466,Total Footage 95'. SPR's @ 7269'MD,5903'TVD,MW 10.3 ppg,08:10 hrs. #1 @ 20=115 psi @ 30= 168 psi #2@20=115 psi @30= 168 psi 10/16/2015 10/16/2015 0.25 INTRM1 DRILL SRVY T Shoot survey&blow down top drive. 7,269.0 7,269.0 08:15 08:30 10/16/2015 10/16/2015 0.75 INTRM1 DRILL MPDA T PJSM;change out RCD&break in 7,269.0 7,269.0 08:30 09:15 seals. 10/16/2015 10/16/2015 2.75 INTRM1 DRILL DDRL T PJSM; Directional drilling f/7269'- 7,269.0 7,460.0 09:15 12:00 7460'MD,6006'TVD,ADT 2.36, Bit 53.25,Jars 151.86, PU 200K,SO 126K, ROT 155K,Tq on 11-20K,off 12-15K,ECD 11.24, FO 80%,WOB 10-15K, 140 rpm,800 gpm,3210 psi, Max Gas 912,Total Footage 191'. Losses for tour 70 bbls. 10/16/2015 10/16/2015 6.00 INTRM1 DRILL DDRL T PJSM; Directional drilling f/7460'- 7,460.0 7,845.0 12:00 18:00 7845'MD,6172'TVD,ADT 5.08, Bit 58.33,Jars 156.94, PU 203K,SO 125K, ROT 146K,Tq on 12-18K,off 9- 11K,ECD 11.1, FO 81%,WOB 10- 14K, 140 rpm,800 gpm,3060 psi, Max Gas 1039,Total Footage 385'. Page 30/49 Report Printed: 12/18/2015 ii Iperations Summary (with Timelog•pths) 00 Rpt 2S-04 Con000PtiiIlips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/16/2015 10/16/2015 2.25 INTRM1 DRILL DDRL T PJSM;Directional drilling f/7845'- 7,845.0 7,896.0 18:00 20:15 7896'MD,6188'TVD,ADT 1.34, Bit 59.67,Jars 158.28,PU 205K,SO 125K,ROT 146K,Tq on 14-16K,off 9- 12K,ECD 11.02,FO 81%,WOB 8- 13K, 140 rpm,800 gpm,3160 psi, Max Gas 2063,Total Footage 51'. TD 7896'MD,6188'TVD 10/16/2015 10/16/2015 0.50 INTRM1 CASING CIRC T Drop 1-5/8"closing ball to close 7,896.0 7,896.0 20:15 20:45 reamer @ 6-3.5 bpm,525-325 psi, 30 rpm,Tq 9-11K.Pressure up to 1975 psi to shift tool&bled off to 235 psi confirming closed. 10/16/2015 10/16/2015 1.25 INTRM1 CASING CIRC T CBU for mud properties. 7,896.0 7,896.0 20:45 22:00 SPR's @ 7895'MD,6187'TVD,MW 10.3 ppg,21:30 hrs. #1 @ 20= 105 psi @ 30= 152 psi #2@20= 106 psi @30= 157 psi 10/16/2015 10/16/2015 1.50 INTRM1 CASING TRIP T PJSM;strip out of hole f/7896'-7339' 7,896.0 7,339.0 22:00 23:30 MD,holding 150 psi while pulling&70 psi in the slips. 10/16/2015 10/17/2015 0.50 INTRM1 CASING CIRC T CBU above the HRZ @ 700 gpm, 7,339.0 7,339.0 23:30 00:00 2725 psi,90 rpm,Tq 10K, FO 78%. 10/17/2015 10/17/2015 0.75 INTRMI CASING CIRC T Cont to CBU @ 700 gpm=2725 psi, 7,339.0 7,339.0 00:00 00:45 rot @ 90 rpm,Tq 9-10K,FO=78%as per MI to achieve proper rheology. 10/17/2015 10/17/2015 2.00 INTRM1 CASING OWFF T Perform fingerprint as per MPD rep, 7,339.0 7,339.0 00:45 02:45 Pore pressure= 10.35 ppg. 10/17/2015 10/17/2015 1.50 INTRM1 CASING CIRC T Increase MW f/10.3 ppg to 10.6 ppg, 7,339.0 7,369.0 02:45 04:15 circulate @ 700 gpm=2745 psi,79% FO,reduce pumps to 650 gpm=2415 psi,70%FO,reduce pumps 600 gpm=2150 psi,70 FO. 10/17/2015 10/17/2015 0.25 INTRM1 CASING CIRC T Obtain SPR's @ 7369'MD,5955' 7,369.0 7,369.0 04:15 04:30 TVD,4:20 am.MP#1,30 spm=200 psi,40 spm=280 psi.MP#2,30 spm=200 psi,40 spm=270 psi. 10/17/2015 10/17/2015 1.25 INTRM1 CASING OWFF P OWFF,close MPD choke,no 7,369.0 7,369.0 04:30 05:45 pressure.Open MPD chokes,OWFF, slight flow to static. 10/17/2015 10/17/2015 4.50 INTRM1 CASING TRIP P POOH stripping f/7369'MD to 2782' 7,369.0 2,782.0 05:45 10:15 MD.Hold 50 psi when in slips and 100 psi when pulling pipe.Strap drill pipe in derrick while POOH.Actual displacement=49.7 bbls,Calculated displacement=37.44 bbls. 10/17/2015 10/17/2015 1.00 INTRM1 CASING CIRC P Pump high vis pill and CBU X 2 @ 450 2,782.0 2,782.0 10:15 11:15 gpm=950 psi,30%FO,30 rpm's. P/U= 100K,S/0=90 10/17/2015 10/17/2015 0.75 INTRM1 CASING MPDA P PJSM;flush MPD choke skid&lines 2,782.0 2,782.0 11:15 12:00 w/H2O&blow down same w/TD. 10/17/2015 10/17/2015 0.75 INTRM1 CASING MPDA P PJSM;remove RCD&install trip 2,782.0 2,782.0 12:00 12:45 nipple. 10/17/2015 10/17/2015 1.50 INTRM1 CASING TRIP P PJSM;TOH f/2782'-723'MD. 2,782.0 723.0 12:45 14:15 10/17/2015 10/17/2015 0.25 INTRM1 CASING OWFF P Monitor well static. 723.0 723.0 14:15 14:30 10/17/2015 10/17/2015 2.50 INTRMI CASING BHAH P PJSM;lay down BHA. 723.0 0.0 14:30 17:00 Page 31/49 Report Printed: 12/18/2015 •perations Summary (with Timelog•pths) 2S-04 ConoaiPhillips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/17/2015 10/17/2015 0.75 INTRM1 CASING WWWH P PJSM;pick up stack washer,flush 0.0 0.0 17:00 17:45 stack,&lay down same. 10/17/2015 10/17/2015 0.50 INTRM1 CASING BHAH P PJSM;clear&clean rig floor,send 0.0 0.0 17:45 18:15 tools down the beaver slide. 10/17/2015 10/17/2015 0.50 INTRM1 CASING RURD P PJSM;drain stack&remove wear 0.0 0.0 18:15 18:45 bushing. 10/17/2015 10/17/2015 0.75 INTRM1 CASING BOPE P PJSM;C/O upper VBR's to 7-5/8" 0.0 0.0 18:45 19:30 solid body rams,SIMOPS rig up Volant CRT. 10/17/2015 10/17/2015 1.00 INTRM1 CASING BOPE P PJSM;rig up&test 7-5/8"rams to 0.0 0.0 19:30 20:30 250/3500 psi,annular 250/2500 psi for 5 minutes each.Rig down equipment. 10/17/2015 10/17/2015 0.75 INTRM1 CASING RURD P PJSM;continue rigging up casing 0.0 0.0 20:30 21:15 equipment. 10/17/2015 10/18/2015 2.75 INTRM1 CASING PUTB P PJSM;Run 7-5/8",29.7#,L-80,Hydril 0.0 1,296.0 21:15 00:00 563 casing as per detail f/surface to 1296'MD.Calculated displacement 13.5,actual 16.4 bbls. 10/18/2015 10/18/2015 2.50 INTRM1 CASING PUTB P PJSM;Run 7-5/8",29.7#,L-80,Hydril 1,296.0 2,795.0 00:00 02:30 563 casing as per detail f/1296'-2795' MD. 10/18/2015 10/18/2015 0.75 INTRM1 CASING CIRC P CBU @ 5 bpm, 175 psi,FO 16%. 2,795.0 2,795.0 02:30 03:15 Obtain parameters before going into open hole PU 100K,SO 93K,ROT 96K,Tq 2K. 10/18/2015 10/18/2015 2.75 INTRM1 CASING PUTB P PJSM; Run 7-5/8",29.7#,L-80,Hydril 2,795.0 4,548.0 03:15 06:00 563 casing as per detail f/2795'-4548' MD.Observe displacement decrease. Decision made to circulate. 10/18/2015 10/18/2015 1.00 INTRM1 CASING CIRC T Break circulation @.5 bpm, 145 psi, 4,548.0 4,548.0 06:00 07:00 FO 0%.Stage pumps up as follows 1 bpm,210 psi,slight returns; 1.5 bpm, 215 psi,slight returns.Pump 53 bbls w/24 bbls losses. Spill Drill CRT 75 sec @ 06:30 hrs. 10/18/2015 10/18/2015 6.50 INTRM1 CASING PUTB P PJSM; Run 7-5/8",29.7#,L-80,Hydril 4,548.0 7,857.0 07:00 13:30 563 casing as per detail f/4548'-7857' MD. A total of 52 Hydroform centralizers ran. Ran a total of 193 joints with no bad joints. 10/18/2015 10/18/2015 0.25 INTRM1 CASING HOSO P PJSM;pick up&make up hanger& 7,857.0 7,886.0 13:30 13:45 landing joint f/7857'-7886'MD. PU 230K,SO 145K. 10/18/2015 10/18/2015 0.75 INTRM1 CEMENT CIRC P Circulate&condition for cement job 7,886.0 7,886.0 13:45 14:30 staging up the pumps f/1-5 bpm,350- 550 psi w/minimal returns. 10/18/2015 10/18/2015 0.25 INTRM1 'CEMENT RURD P PJSM;rig up cement line to Baker 7,886.0 7,886.0 14:30 14:45 swivel on CRT. 10/18/2015 10/18/2015 0.75 INTRM1 CEMENT CIRC P Circulate&condition for cement job at 7,886.0 7,886.0 14:45 15:30 1.5 bpm,350-250 psi w/minimal to no returns.Cementers batching up MudPush 2. Page 32/49 Report Printed: 12/18/2015 Iperations Summary (with Timelog�epths) 2S-04 Conor hiIIps Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/18/2015 10/18/2015 2.50 INTRM1 CEMENT CMNT P PJSM;pump 5 bbls of H2O&test 7,886.0 7,886.0 15:30 18:00 lines 350/4000 psi for 5 min. Pump 40 bbls of 12 ppg MudPush 2 @ 5 bpm,650 psi. Drop bottom plug.Pump 95 bbls of 16 ppg tail cement w/1 ppb Cemnet @ 4.5 bpm,650 psi.Drop top plug. Pump 10 bbls of H2O. Displace with rig pump @ 5 bpm,200 psi. Observed 500 psi lift pressure. Bump plug&hold 1200 psi for 5 min.Check floats,good.CIP @ 17:51 hrs. 10/18/2015 10/18/2015 0.50 INTRM1 CEMENT CMNT P Open stage collar as per PESI. 7,886.0 7,886.0 18:00 18:30 Pressure up&observe collar open at 2600 psi.Stage up pump to 4 bpm 400 psi w/minimal to no returns.Slow pumps to 1 bpm while SLB batching up MudPush 2. 10/18/2015 10/18/2015 2.25 INTRM1 CEMENT CMNT P PJSM;Pump 40 bbls of 12 ppg 7,886.0 7,886.0 18:30 20:45 MudPush 2 @ 5 bpm,350 psi. Batch up cement. Pump 42 bbls of 16 ppg tail cement w/Cemnet @ 3.5 bpm, 150 psi. Drop closing plug.Pump 10 bbls of H2O.Displace with rig pump @ 5 bpm, 175 psi.Slow pump to 3 bpm,450 psi, Bump plug w/1200 psi. Observe collar to shift closed at 1600 psi.Pressure up to 1700 psi&hold for 5 min.Verified stage collar was closed,good.CIP @ 20:13 hrs. 10/18/2015 10/18/2015 0.50 INTRM1 CEMENT RURD P PJSM;back out landing joint&flush 0.0 0.0 20:45 21:15 w/H2O. 10/18/2015 10/18/2015 1.50 INTRM1 CEMENT WWSP P PJSM;make up setting tool&set pack 0.0 0.0 21:15 22:45 off.Run in lock down&attempt to test. 10/18/2015 10/19/2015 1.25 INTRM1 CEMENT WWSP T PJSM;pull pack off&find upper,inner 0.0 0.0 22:45 00:00 seal damaged. Unable to determine the cause of damage to seal.Change out all seals&reset pack off. 10/19/2015 10/19/2015 1.25 INTRM1 CEMENT WWSP P PJSM;test 7-5/8"pack off to 5000 psi 0.0 0.0 00:00 01:15 for 10 minutes,witnessed.Back out landing joint&lay down running tool as per CIW. 10/19/2015 10/19/2015 0.75 INTRM1 CEMENT RURD P PJSM;rig down casing equipment& 0.0 0.0 01:15 02:00 clean rig floor.SIMOPS load&strap 4"DP in pipe shed. 10/19/2015 10/19/2015 1.25 INTRM1 CEMENT BORE P PJSM;change out upper rams to 3.5" 0.0 0.0 02:00 03:15 X 6"VBR's.SIMOPS load&strap 4" pipe in shed. 10/19/2015 10/19/2015 1.00 INTRM1 CEMENT RURD P PJSM;rig up to lay down 5"DP. 0.0 0.0 03:15 04:15 10/19/2015 10/19/2015 3.00 INTRM1 CEMENT PULD P PJSM;lay down 17 joints of 5"HWDP 0.0 0.0 04:15 07:15 &jars. Lay down 25 stands of 5"DP. 10/19/2015 10/19/2015 1.00 INTRM1 CEMENT RURD P PJSM;rig up to freeze protect. 0.0' 0.0 07:15 08:15 Page 33/49 Report Printed: 12/18/2015 V ✓ •perations Summary (with Timelog�pths) 0r 2S-04 conocaPhiIlips hr..xLn Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/19/2015 10/19/2015 2.75 INTRM1 CEMENT FRZP P PJSM;pressure test lines to 3000 psi. 0.0 0.0 08:15 11:00 Pump 125 bbls of fresh H2O @ 3 bpm,600 psi,pressure broke over at 800 psi, FCP 500 psi.Pump 85 bbls of Isotherm diesel @ 2 bpm,500 psi, FCP 1000 psi.Chase w/3 bbls of diesel. Blow down&rig down lines. 10/19/2015 10/19/2015 1.00 INTRM1 CEMENT MPDA T PJSM;pull trip nipple. Prep to take 0.0 0.0 11:00 12:00 apart MPD lines&Katch Kan. OA pressure 580 psi @ 12:00 hrs. 10/19/2015 10/19/2015 2.50 INTRM1 CEMENT MPDA T PJSM;remove RCD bowl&adapter 0.0 0.0 12:00 14:30 flange from top of BOPE. 10/19/2015 10/19/2015 7.00 INTRM1 CEMENT MPDA T PJSM;install new adapter flange, 0.0 0.0 14:30 21:30 WFT RCD bowl,air valve, DSA, hoses,hydraulic lines. Measure&cut trip nipple to length. 10/19/2015 10/20/2015 2.50 INTRM1 CEMENT PULD P PJSM;lay down 33 stands of 5"DP 0.0 0.0 21:30 00:00 from derrick. 10/20/2015 10/20/2015 1.50 INTRM1 CEMENT PULD P PJSm-Finish laying down 21 stds 5" 0.0 0.0 00:00 01:30 DP f/derrick 10/20/2015 10/20/2015 1.00 INTRM1 CEMENT RURD P Change handling equipment f/5'to 0.0 0.0 01:30 02:30 4"(SIMOPS)load MWD tools in pipe shed. Rig Evacuation Table Top Drill @ 02:30 Hrs. 10/20/2015 10/20/2015 9.50 INTRM1 CEMENT PULD P PJSM-PU&Stand back 315 jts(105 0.0 0.0 02:30 12:00 stds)4"XT-39 DP in derrick via mouse hole OA Pressure 550 psi @ 12:00 hrs 10/20/2015 10/20/2015 5.00 INTRM1 CEMENT PULD P PJSM-continue picking up 4"DP, 0.0 0.0 12:00 17:00 racking back 47 stands in the derrick. Pick up&rack back NMFC. 10/20/2015 10/20/2015 1.25 INTRM1 CEMENT RURD P PJSM-Change out saver sub from 4- 0.0 0.0 17:00 18:15 1/2"IF to XT 39. 10/20/2015 10/20/2015 1.00 INTRM1 CEMENT MPDA P PJSM-Pull trip nipple,install test plug 0.0 0.0 18:15 19:15 &MPD test cap. 10/20/2015 10/20/2015 1.25 INTRM1 CEMENT MPDA T PJSM-Rig up&attempt test MPD air 0.0 0.0 19:15 20:30 valve to 250 psi,leaking by.Attempt to test at 1000 psi,leaking by.Verified valve leaking with down stream gauge. 10/20/2015 10/20/2015 0.50 INTRM1 CEMENT MPDA T PJSM-Remove MPD test cap& 0.0 0.0 20:30 21:00 install trip nipple. 10/20/2015 10/20/2015 0.50 INTRM1 WHDBOP RURD P PJSM-Rig up to test BOPE. 0.0 0.0 21:00 21:30 10/20/2015 10/21/2015 2.50 INTRM1 WHDBOP BOPE P Test BOPE w/4.5"test joint to 0.0 0.0 21:30 00:00 250/3500 psi for 5 min each.#1:Top pipe rams,CV 1,12,13, 14&manual kill valve.#2:Upper IBOP, HCR kill, CV 9,&11.#3:Lower IBOP,CV 5,8& 10. #4:Dart,CV 4,6&7. #5:FOSV and CV 2. #6:HCR choke&4"kill line Demco valve, #7: Manual choke valve&HCR kill. #8:Annular preventer tested to 250/2500 psi.Test witnessed waived by AOGCC Lou Grimaldi. Spill Drill CRT 98 sec @ 23:30 hrs. OA pressure 540 psi @ 24:00 hrs. Page 34/49 Report Printed: 12/18/2015 G •perations Summary (with Timelog�epths) Oa 2S-04 Cono�iliiips Ak An Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/21/2015 10/21/2015 2.50 INTRM1 WHDBOP BOPE P Continue w/BOP test-tested lower 0.0 0.0 00:00 02:30 pipe rams-blind rams/w 4 1/2"test jt to 250&3500 psi-Change to 3 1/2" test jt.-Tested Annular to 250&2500 psi-Tested upper&lower pipe to 250 &3500 psi-Perform accumulator recovery test-star pressure 3000 psi- After closure 1900 psi-200 psi attained in 48 sec's.-Full pressure attained in 180 sec's.-N2 bottles average-1960 psi-performed draw down pressure on Hyd&manual chokes-Tested gas alarms-Tested flow sensor&gain/loss alarms- Witnessing of test waived by Lou Grimaldi AOGCC 10/21/2015 10/21/2015 0.50 INTRM1 WHDBOP RURD P Blow down lines&RD test equipment 0.0 0.0 02:30 03:00 10/21/2015 10/21/2015 1.00 INTRM1 WHDBOP MPDA T Attempt to retest Weatherford Orbit 0.0 0.0 03:00 04:00 valve-Unable to get test 10/21/2015 10/21/2015 4.00 INTRM1 WHDBOP MPDA -T Blow down MPD lines Remove Orbit 0.0 0.0 04:00 08:00 valve-Installed back up valve 10/21/2015 10/21/2015 1.75 INTRM1 WHDBOP MPDA T Install test cap-perform full body test 0.0 0.0 08:00 09:45 on MPD unit-to 1000 psi-opened MPD chokes&tested orbit valve to 1000 psi(Good Tests)-Blow down lines-Pull test cap-Install trip nipple 10/21/2015 10/21/2015 0.50 INTRM1 WHDBOP RURD P Pull test plug-Set wear bushing(10" 0.0 0.0 09:45 10:15 ID) 10/21/2015 10/21/2015 1.25 INTRM1 CEMENT BHAH P Clear floor of 5"subs&floor valves- 0.0 0.0 10:15 11:30 PU 4"lift subs&BHA tools to rig floor 10/21/2015 10/21/2015 0.50 INTRM1 CEMENT BHAH P PJSM-MU BHA#4(6 3/4"rotary 0.0 23.0 11:30 12:00 steerable) 6 3/4"Smith(513 PDC) PowerDrive X6&PD receiver sub to 23' OA Pressure 530 psi @ 12:00 hrs. 10/21/2015 10/21/2015 2.50 INTRM1 CEMENT BHAH P Cont. MU BHA#4-PeriScope- 23.0 447.0 12:00 14:30 MircoScrope-ImPulse-SonicScope- adnVision-Load RA source-MU float subs-NM Dc-Stab-2 NM flex DC's- -XO-3jts 4"HWDP-jars-2jts.4' HWDP to 446.63' 10/21/2015 10/21/2015 0.50 INTRM1 CEMENT TRIP P PJSM;TIH f/447'-1500'MD. 447.0 1,500.0 14:30 15:00 10/21/2015 10/21/2015 0.50 INTRM1 CEMENT DHEQ •P Shallow hole test MWD,pump 250 1,500.0 1,500.0 15:00 15:30 gpm, 1600 psi. 10/21/2015 10/21/2015 1.25 INTRM1 CEMENT TRIP P TIH F/1500'-5000'MD. 1,500.0 5,000.0 15:30 16:45 Kick w/Tripping Drill CRT 87 sec @ 16:30 hrs. 10/21/2015 10/21/2015 3.50 INTRM1 CEMENT DLOG P MAD pass f/5000'-5779'MD,450 5,000.0 5,779.0 16:45 20:15 fph,240 gpm, 1700 psi.Tag up on cement stringer @ 5579'MD. 10/21/2015 10/21/2015 0.50 INTRM1 CEMENT PRTS P PJSM;rack back stand,rig up&test 5,779.0 5,779.0 20:15 20:45 casing to 1000 psi for 10 minutes. 10/21/2015 10/21/2015 0.50 INTRM1 CEMENT COCF P Clean out cement f/5770'-5816',240 5,779.0 5,816.0 20:45 21:15 gpm, 1850 psi,60 rpm,Tq 5-7K,WOB 1-5K.Tagged up©5800'MD on something solid.Observe black rubber back to shakers,to confirm stage collar plug was drilled up. Page 35/49 Report Printed: 12/18/2015 perations Summary (with Timelogpths) ' Conoco`Phiikps 2S-04 Mask, Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/21/2015 10/21/2015 1.25 INTRM1 CEMENT DRLG P Drill stage collar f/5816'5820'MD, 5,816.0 5,820.0 21:15 22:30 240 gpm, 1850 psi,60 rpm,Tq 5-7K, WOB 1-5K. 10/21/2015 10/21/2015 0.50 INTRM1 CEMENT CIRC P CBU&dress stage collar @ 240 gpm, 5,820.0 5,820.0 22:30 23:00 1850 psi,60 rpm,Tq 5-7K. 10/21/2015 10/22/2015 1.00 INTRM1 CEMENT DLOG P Mad pass f/5820'-5963'MD @ 450 5,820.0 5,963.0 23:00 00:00 fph,240 gpm, 1840 psi.Tag a stringer of cement 5925'-5935'MD. OA Pressure 650 psi @ 24:00 hrs. 10/22/2015 10/22/2015 6.75 INTRM1 CEMENT DLOG P Continue RIH @ 450'/hr pumping 240 5,963.0 7,737.0 00:00 06:45 gpm @ 1840 psi-MAD pass w/ SonicScope f/5963'to 7737'- Tagged cmt @ 7737' 10/22/2015 10/22/2015 0.25 INTRM1 CEMENT COCF P Drilled cmt ft 7737'to 7745'MD @ 240 7,737.0 7,745.0 06:45 07:00 gpm @ 1840 psi w/60 rpm's w/10/12 k torque-PU wt 175 SO wt 98 ROT wt. 112 10/22/2015 10/22/2015 0.25 INTRM1 CEMENT TRIP P POOH f/7745'to 7727'-Blow down 7,745.0 7,727.0 07:00 07:15 TD 10/22/2015 10/22/2015 1.25 INTRM1 CEMENT SLPC P PJSM-Slip&cut 65'drill line. 7,727.0 7,727.0 07:15 08:30 10/22/2015 10/22/2015 0.50 INTRM1 CEMENT SVRG P Service rig-Draworks-TD-Crown 7,727.0 7,727.0 08:30 09:00 10/22/2015 10/22/2015 0.50 INTRM1 CEMENT RURD P RU to test casing 7,727.0 7,727.0 09:00 09:30 10/22/2015 10/22/2015 0.50 INTRM1 CEMENT PRTS P Tested 7 5/8"casing to 3500 psi for 30 7,727.0 7,727.0 09:30 10:00 mins.-Good test 10/22/2015 10/22/2015 0.50 INTRM1 CEMENT RURD P RD test equipment-Blow down kill 7,727.0 7,727.0 10:00 10:30 line 10/22/2015 10/22/2015 1.00 INTRM1 CEMENT MPDA P PJSM-Pulled trip nipple-Installed 7,727.0 7,727.0 10:30 11:30 RCD bearing 10/22/2015 10/22/2015 1.00 INTRM1 CEMENT MPDA P Test MPD ramp schedule as per 7,727.0 7,727.0 11:30 12:30 Safekick&Conoco rig engineer. OA Pressure 610 psi @ 12:00 hrs. 10/22/2015 10/22/2015 0.50 INTRM1 CEMENT MPDA P PJSM-Remove RCD&install trip 7,727.0 7,727.0 12:30 13:00 nipple. 10/22/2015 10/22/2015 0.25 INTRM1 CEMENT CIRC P Obtain SPR's @ 7727'MD;6129' 7,727.0 7,727.0 13:00 13:15 TVD; MW 10.5 ppg; 13:11 hrs. #1 @ 20=440 psi;@ 30=670 psi #2 @ 20=430 psi;@ 30=680 psi 10/22/2015 10/22/2015 0.25 INTRM1 CEMENT COCF P Wash down&drill out cement to baffle 7,727.0 7,754.0 13:15 13:30 collar f/7727'-7754'MD;240 gpm, 2100 psi,40 rpm,Tq 10K. 10/22/2015 10/22/2015 1.50 INTRM1 CEMENT DRLG P Drill baffle collar f/7754-7757'MD; 7,754.0 7,757.0 13:30 15:00 220 gpm, 1800 psi,60 rpm,Tq 10- 12K,WOB 5-8K. 10/22/2015 10/22/2015 3.75 INTRM1 CEMENT COCF P Drill out cement to float collar f/7757'- 7,757.0 7,797.0 15:00 18:45 7797'MD;220 gpm,2000 psi,60 rpm, Tq 10-12 K,WOB 5-8K. 10/22/2015 10/22/2015 0.75 INTRM1 CEMENT DRLG P Drill out float collar f/7797'-7799'MD; 7,797.0 7,799.0 18:45 19:30 215 gpm, 1780 psi,60 rpm,Tq 10-12 K,WOB 7-9 K. 10/22/2015 10/22/2015 1.75 INTRM1 CEMENT DRLG P Drill out shoe track&rat hole f/7799'- 7,799.0 7,896.0 19:30 21:15 7896'MD;215 gpm, 1780 psi,60 rpm, Tq 10-12K,WOB 7-9 K. 10/22/2015 10/22/2015 1.75 INTRM1 CEMENT CIRC P Circulate&condition mud system; 7,896.0 7,896.0 21:15 23:00 pump a weighted high-vis sweep @ 230 gpm,2000 psi,30 rpm,Tq 10- 11K. Page 36/49 Report Printed: 12/18/2015 ii •perations Summary (with Timelog•pths) 03 2S-04 ConoO hilhps A&xka Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/22/2015 10/22/2015 0.50 INTRM1 CEMENT OWFF P Monitor well,static. 7,896.0 7,896.0 23:00 23:30 10/22/2015 10/23/2015 0.50 INTRM1 CEMENT MPDA P PJSM;pull trip nipple&begin to install 7,896.0 7,896.0 23:30 00:00 RCD. OA Pressure 550 psi @ 24:00 hrs. 10/23/2015 10/23/2015 0.75 INTRM1 CEMENT MPDA P Finish installing MPD bearing-PU wt. 7,896.0 7,896.0 00:00 00:45 185 SO wt 85 Rot wt. 117 10/23/2015 10/23/2015 1.00 INTRM1 CEMENT DDRL P Drilled 6 3/4"hole w/RSS&MDP f/ 7,896.0 7,916.0 00:45 01:45 7896'to 7916'MD 6194'TVD ADT-1.05 hrs. ECD-11.63 ppg Footage-20' WOB 10/15 k RPM 100 GPM 260 @ 2325 psi w/20%Flow out PU wt 185 SOwt85 Rot wt. 117 Torque on/off btm-11/11 k Max.gas-51 units Total Footage 20'MD. Total bit hrs. 1.05 hrs Total jar hrs. 1.05 hrs 10/23/2015 10/23/2015 0.75 INTRM1 CEMENT CIRC P Circ hole clean©260 gpm @ 2325 7,916.0 7,916.0 01:45 02:30 psi w/50 rpm w/10 k torque 10/23/2015 10/23/2015 0.25 INTRM1 CEMENT PMPO P POOH f/7916'to 7821'w/pump @ 7,916.0 7,821.0 02:30 02:45 230 gpm @ 1890 psi w/50 rpm w/11 / 12 k torque 10/23/2015 10/23/2015 0.50 INTRM1 CEMENT OWFF P Monitor well-(Static)SIMOPS-blow 7,821.0 7,821.0 02:45 03:15 down TD-RU for FIT 10/23/2015 10/23/2015 0.25 INTRM1 CEMENT FIT P Performed FIT to 14.5 ppg w/1260 psi 7,821.0 7,821.0 03:15 03:30 applied pressure w/10.6 ppg mud @ 6185'TVD 10/23/2015 10/23/2015 0.50 PROD1 DRILL RURD P RD test equipment -Blow down kill & 7,821.0 7,916.0 03:30 04:00 cmt line-RIH to 7916' 10/23/2015 10/23/2015 2.00 PROD1 DRILL DISP P Displace well f/10.6 ppg LSND to 10.5 7,916.0 7,916.0 04:00 06:00 ppg Flow-Thru mud 230 gpm©1780 psi w/20 rpm's/9 k torque-FCP- 200 psi-PU wt 175 SO wt 92 ROT wt 120 10/23/2015 10/23/2015 6.00 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS&MPD f/ 7,916.0 8,124.0 06:00 12:00 7916'to 8124'MD;6248'TVD, ADT 4.06, Bit 5.11,Jars 5.11,PU 174K,SO 82K, 108K,Tq on 9-10K,off 9K,ECD 11.64, FO 29%,WOB 10-15K,rpm 120,gpm 250,2475 psi, Max Gas 5873,total footage 208'MD. Kick w/Drilling CRT 86 sec @ 09:10 hrs. OA Pressure 620 psi @ 12:00 hrs. 10/23/2015 10/23/2015 6.00 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS&MPD f/ 8,124.0 8,313.0 12:00 18:00 8124'to 8313'MD;6273'TVD,ADT 5.09,Bit 10.20,Jars 10.20,PU 170K, SO 84K, 110K,Tq on 10-11K,off 9K, ECD 11.79,FO 33%,WOB 6-8K,rpm 130,gpm 240,2340 psi,Max Gas 5499,total footage 189'MD. Page 37/49 Report Printed: 12/18/2015 Iperations Summary (with Timelog•pths) Oti 2S-04 Con000`PhiIhps AL,kn Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/23/2015 10/24/2015 6.00 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS&MPD f/ 8,313.0 8,605.0 18:00 00:00 8313'to 8605'MD;6309'TVD,ADT 4.77, Bit 14.97,Jars 14.97,PU 167K, SO 85K, 109K,Tq on 10-11K,off 10K, ECD 11.83, FO 26%,WOB 7-10K, rpm 140,gpm 250,2500 psi,Max Gas 9999,total footage 292'MD. Obtain SPR's @ 8481'MD;6290' TVD;MW 10.5+ppg;22:00 hrs. #1 @ 20=480 psi;@ 30=730 psi #2 @ 20=444 psi;@ 30=780 psi Kick w/Drilling CRT 107 sec @ 22:00 hrs. OA Pressure 570 psi @ 24:00 hrs. 10/24/2015 10/24/2015 6.00 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS&MPD f/ 8,605.0 9,132.0 00:00 06:00 8605;to 9132'MD 6289'TVD ADT-4.84 hrs ECD-12.17 ppg Footage-527' WOB 10/15 k RPM 150 GPM 250 @ 2600 psi w/26%flow out PUwt 172 SOwt78 ROT wt 110 Torque on/off btm.-11/10.5 k Max.Gas 9905 units Total bit hrs.-19.81 hrs Total jar ghrs. 19.81 hrs SPR's @ 8955'ND 6308'TVD w/10.5 +ppg @ 0400 hrs #1 20/30 SPM @ 555/875 psi #2 20/30 SPM @ 500/870 psi 10/24/2015 10/24/2015 1.50 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS&MPD f/ 9,132.0 9,238.0 06:00 07:30 9132'to 9238'MD 6280'TVD ADT-1.09 hrs ECD-12.14 ppg Footage-106' WOB 8/10 k RPM 150 GPM 250 @ 2640 psi PU wt. 167 SO wt 78 ROT wt 110 Torque on/off btm.-12/10 k Max.gas 9905 unit Total bit hrs.20.9 hrs Total jar hrs. 20.9 hrs 10/24/2015 10/24/2015 1.25 PROD1 DRILL CIRC T Circ btms up @ 250 gpm @ 2600 psi 9,238.0 9,238.0 07:30 08:45 w/140 rpm's w/11 k torque-ECD 12.09 ppg Page 38/49 Report Printed: 12/18/2015 VIperations Summary (with Timelog epths) 0 2S-04 conoc hilaps M k:9 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/24/2015 10/24/2015 3.25 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS&MPD f/ 9,238.0 9,428.0 08:45 12:00 9238'to 9428'MD 6271'TVD ADT-1.95 hrs. ECD-12.20 ppg Footage-190' WOB 9/13 k RPM's 140 GPM 250 @ 2650 psi w/26%flow out PUwt. 168 SOwt77 ROT wt 110 Torque on/off btm.-12/11 k Max gas-9904 units OA Pressure 640 psi @ 12:00 hrs. Total bit hrs-22.85 hrs Total jar hrs. 22.85 hrs SPR's @ 9428'MD 6271'TVD w/10.7 ppg @ 11:45 hrs #1 20/30 SPM @ 590/890 psi #2 20/30 SPM @ 600/900 psi 10/24/2015 10/24/2015 6.00 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS&MPD f/ 9,428.0 9,899.0 12:00 18:00 9428'to 9899'MD 6268'TVD ADT-4.70 hrs. ECD-12.35 ppg Footage-471' WOB 9/13 k RPM's 140 GPM 250 @ 2775 psi w/26%flow out PU wt. 185 SO wt 75 ROT wt 106 Torque on/off btm.-12/11 k Max gas-9916 units. Total bit hrs-27.55 hrs Total jar hrs. 27.55 hrs 10/24/2015 10/24/2015 4.25 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS&MPD f/ 9,899.0 10,183.0 18:00 22:15 9899'to 10183'MD 6247'TVD ADT-2.89 hrs. ECD-12.34 ppg I Footage-284' WOB 8/12 k RPM's 140 GPM 250 @ 2800 psi w/25%flow out PU wt. 162 SO wt 71 ROT wt 106 Torque on/off btm.-11/8 k Max gas-9055 units. Total bit hrs-30.44 hrs Total jar hrs. 30.44 hrs SPR's©10088'MD 6257'TVD w/ 10.7+ppg @ 20:30 hrs #1 20/30 SPM @ 600/910 psi #2 20/30 SPM©630/880 psi 10/24/2015 10/24/2015 0.50 PROD1 DRILL OWFF P Perform draw down test @ 10183' 10,183.0 10,183.0 22:15 22:45 MD,6247'TVD.Bled pressure down from 400 psi to 300 psi three times. Observe pressure increase to 379 psi each time.Average TVD of A4 sand 6275'TVD, EMW of 11.96 ppg. Page 39/49 Report Printed: 12/18/2015 Iterations Summary (with Timelog�epths) 2S-04 ConocoPhillips AF:nA.e Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/24/2015 10/25/2015 1.25 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS&MPD f/ 10,183.0 10,252.0 22:45 00:00 10183'to 10252'MD 6244'TVD ADT-.79 hrs. ECD-12.36 ppg Footage-69' WOB 10/15 k RPM's 140 GPM 250 @ 2800 psi w/25%flow out PU wt. 170 SO wt 71 ROT wt 107 Torque on/off btm.-12/9 k Max gas-9055 units. Total bit hrs-31.23 hrs Total jar hrs. 31.23 hrs OA Pressure 630 @ 24:00 hrs. 10/25/2015 10/25/2015 6.00 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS&MPD f/ 10,252.0 10,656.0 00:00 06:00 10,252,to 10,656'MD 6264'TVD ADT-4.60 hrs ECD-12.44 ppg Footage-404' WOB 5/15 k RPM's 110 GPM 250 ©2850 psi w/25%flow out PU wt. 185 SO wt.70 ROT wt. 109 Torque on/off btm.-13/11 k Max gas-9906 units Kick w/Drilling CRT 120 sec @ 00:30 hrs. Total bit hrs.35.83 hrs Total jar hrs.- 35.83 hrs SPR's @ 10557'MD 6264'TVD w/ 10.8 ppg mud @ 0430 hrs #1 20/30 SPM @ 660/930 psi #2 20/30 SPM @ 820/955 psi 10/25/2015 10/25/2015 6.00 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS&MPD f/ 10,656.0 11,030.0 06:00 12:00 10,656'to 11.030'MD 6248'TVD ADT-4.80 hrs ECD-12.44 ppg Footage-374' WOB 8/16 k RPM's 110 GPM 250 @ 2880 psi w/23%flow out PU wt. 184 SO wt 70 ROT wt. 108 Torque on/off btm.-14/12 k Max. gas 9904 units Total bit hrs.40.63 hrs Total jar hrs. 40.63 hrs. OA Pressure 610 psi©12:00 hrs. 10/25/2015 10/25/2015 6.00 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS&MPD f/ 11,030.0 11,365.0 12:00 18:00 11,030'to 11.365'MD 6253'TVD ADT-4.57 hrs ECD-12.35 ppg Footage-335' WOB 10/15 k RPM's 130 GPM 250 @ 2925 psi w/22%flow out PU wt. 194 SO wt 65 ROT wt. 107 Torque on/off btm.-14/11 k Max. gas 9901 units Total bit hrs.45.20 hrs Total jar hrs. 45.20 hrs. SPR's @ 11033'MD 6247'TVD w/ 10.8 ppg mud @ 12:15 hrs #1 20/30 SPM @ 590/840 psi #2 20/30 SPM @ 590/930 psi Page 40/49 Report Printed: 12/18/2015 V 0 •perations Summary (with Timelog epths) 2S-04 Con000`Philips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/25/2015 10/26/2015 6.00 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS&MPD f/ 11,365.0 11,824.0 18:00 00:00 11,365'to 11.824'MD 6264'TVD ADT-4.36 hrs ECD-12.59 ppg Footage-459' WOB 8/10 k RPM's 140 GPM 250 @ 3050 psi w/25%flow out PU wt. 190 SO wt 64 ROT wt. 107 Torque on/off btm.-14/11 k Max. gas 9901 units Total bit hrs.49.56 hrs Total jar hrs. 49.56 hrs. SPR's @ 11506'MD 6253'TVD w/ 10.8 ppg mud©20:00 hrs #1 20/30 SPM©720/990 psi #2 20/30 SPM @ 740/1040 psi OA Pressure 600 psi @ 24:00 hrs. 10/26/2015 10/26/2015 6.00 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS&MPD f/ 11,824.0 12,258.0 00:00 06:00 11,824'to 12,258'MD 6250'TVD ADT-4.34 hrs ECD-12.57 ppg Footage-434' WOB 10/14 k RPM's 140 GPM 250 @ 3080 psi w/25%flow out PU wt. 190 SO wt.62 ROT wt 105 Torque on/off btm.-14/12 k Max gas-9902 units Total bit hrs.-54.49 hrs. Total jar hrs. 54.49 hrs. SPR's @ 12,074'MD 6259'TVD w/ 10.8 ppg mud @ 0330 hrs. #1 20/30 SPM @ 710/1020 psi #2 20/30 SPM @ 695/970 psi 10/26/2015 10/26/2015 1.50 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS&MPD f/ 12,258.0 12,357.0 06:00 07:30 12,258'to 12,357'MD 6250'TVD ADT-.82 hrs. ECD-12.56 ppg Footage-99' WOB 10/14 k RPM's 140 GPM 250 @ 3100 psi w/25%flow out PU wt. 190 SO wt.62 ROT wt 105 Torque on/off btm.-14/12 k Max gas-5420 units Spill Drill CRT 120 sec @ 07:00 hrs. Total bit hrs.-55.31 hrs Total jar hrs. 55.31 hrs 10/26/2015 10/26/2015 1.50 PROD1 DRILL MPDA T PJSM-Change out Weatherford RCD 12,357.0 12,357.0 07:30 09:00 bearing 10/26/2015 10/26/2015 1.50 PROD1 DRILL CIRC T Circ btms up @ 211 gpm @ w/80 12,357.0 12,357.0 09:00 10:30 rpm's w/12/13 k torque Page 41/49 Report Printed: 12/18/2015 •perations Summary (with Timelog epths) 2S-04 C.on000`PhiIhps hGaAn Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/26/2015 10/26/2015 1.50 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS&MPD f/ 12,357.0 12,452.0 10:30 12:00 12,357'to 12,452'MD 6246'TVD ADT-.82 hrs. ECD-12.56 ppg Footage-95' WOB 10/15 k RPM's 140 GPM 250 @ 3090 psi w/23%flow out PU wt. 190 SO wt.62 ROT wt 103 Torque on/off btm.-14/13 k Max gas-7800 units OA Pressure 580 psi @ 12:00 hrs. Fire Drill CRT 98 sec @ 13:15 hrs. Total bit hrs.-56.13 hrs Total jar hrs.- 56.13 hrs 10/26/2015 10/26/2015 6.00 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS&MPD f/ 12,452.0 12,858.0 12:00 18:00 12,452'to 12,858'MD 6238'TVD ADT-4.61 hrs. ECD-12.69 ppg Footage-406' WOB 8/10 k RPM's 130 GPM 250 @ 3150 psi w/23%flow out PU wt.214 SO wt.58 ROT wt 104 Torque on/off btm.-15/13 k Max gas-7351 units Total bit hrs.-59.90 hrs Total jar hrs.- 59.90 hrs SPR's @ 12,829'MD 6240'TVD w/ 10.8 ppg mud @ 17:30 hrs. #1 20/30 SPM @ 680/1080 psi #2 20/30 SPM @ 680/1030 psi 10/26/2015 10/27/2015 6.00 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS&MPD f/ 12,858.0 13,205.0 18:00 00:00 12,858'to 13,205'MD 6238'TVD ADT-4.61 hrs. ECD-12.57 ppg Footage-347' WOB 9/11 k RPM's 125 GPM 250 @ 3150 psi w/25%flow out PU wt.205 SO wt.48 ROT wt 103 Torque on/off btm.-13/11 k Max gas-5181 units Total bit hrs.-64.51 hrs Total jar hrs.- 64.51 hrs OA Pressure 610 psi @ 24:00 hrs. 10/27/2015 10/27/2015 6.00 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS&MPD f/ 13,205.0 13,477.0 00:00 06:00 13,205'to 13,477'MD 6240'TVD ADT-4.89 hrs. ECD-12.65 ppg Footage-272' WOB 6/11 k RPM's 120 GPM 250 @ 3225 psi w/24%flow out PU wt. 195 SO wt.55 ROT wt. 105 Torque on/off btm.-15/11.5 k Max gas-9595 units Total bit hrs.69.40 hrs Total jar hrs 69.40 hrs SPR's @ 13,302'MD 6233'TVD w/ 10.8 ppg @ 0130 hrs #1 20/30 SPM @ 700/1060 psi #2 20/30 SPM @ 660/1125 psi Hole taking fluid Page 42/49 Report Printed: 12/18/2015 •perations Summary (with Timelog epths) 2S-04 Conoce Phillips Aim.Aa Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/27/2015 10/27/2015 1.50 PROD1 DRILL CIRC T PU&Spot 25 bbls LCM pill 35#/bbl- 13,477.0 13,477.0 06:00 07:30 20#safe Carb 250-5#Safe Carb 20 -5#Safe Garb 500-5#safe Garb 750 @ 147 gpm @ 1600 psi w/100 rpm's w/12 k torque 10/27/2015 10/27/2015 1.00 PROD1 DRILL DDRL P Drilled 6 3/4"hole w/RSS&MPD f/ 13,477.0 13,505.0 07:30 08:30 13,477'to 13.305'MD 6236'TVD ADT-1.09 hrs. ECD-12.36 ppg Footage-28' WOB 2/5 k RPM 100 GPM 250 @ 3075 psi w/23%flow out PU wt. 195 SO wt 55 ROT wt 105 Torque on/off btm.-14/13 k Max gas-790 units Total bit hrs.70 49 hrs Total jar hrs. 70.49 hrs TD called @ 13,505'MD 6236'TVD 10/27/2015 10/27/2015 2.00 PROD1 CASING OWFF P Stand back 1 std DP to 13,490'- 13,505.0 13,490.0 08:30 10:30 perform draw down test w/MPD built to 440 psi(12.2 ppg) 10/27/2015 10/27/2015 1.50 PROD1 CASING CIRC P Circulating hole clean @ 250 gpm @ 13,490.0 13,306.0 10:30 12:00 3050 psi w/100 rpm's w/13 k torque- stood back 2 sdts DP to 13400' Max gas 8278 units Lost 173.5 bbls 10/27/2015 10/27/2015 6.00 PROD1 CASING CIRC T Circulate to clear gas from mud and 13,306.0 13,306.0 12:00 18:00 pump SafeCarb LCM sweeps to manage losses.250 gpm,3150 psi, 100 rpm, 10-11K tq.Losses @ 26 bph. Increase MPD back pressure to 12.5 ppg EMW. 10/27/2015 10/28/2015 6.00 PROD1 CASING OWFF T Perform dynamic draw down test to 13,306.0 13,306.0 18:00 00:00 establish kill weight mud.Decrease EMW from 12.5 ppg to 12.3 ppg in.1 ppg increments.250 gpm,3150 psi, 100 rpm, 10-11K tq.Establish pore pressure @ 12.35 ppg. Lost 195 bbls for tour. OA=610 psi. 10/28/2015 10/28/2015 4.25 PROD1 CASING CIRC T Cont.circ out gas @13,303'@ 250 13,303.0 13,303.0 00:00 04:15 gpm @ 3100 psi w/100 rpm's w/11 k torque-holding 12.5 ppg ECD w/ MPD choke-Pumped 25 bbls-LCM pill Lost 85 bbls -f6/28/2015 10/28/2015 7.75 PROD1 CASING PMPO P POOH w/pump f/13,303'to 11.035' 13,303.0 11,035.0 04:15 12:00 @ 200 gpm @ 2300 psi w/No rotation -holding 270 psi on MPD choke while pumping&trapping 500 psi on connections-PU wt 175 Lost 127 while pumping out Total losses for tour 212 bbls Page 43/49 Report Printed: 12/18/2015 - ,� operations Summary (with Timelog�epths) gt ,,# ens:# 2S-04 Conoci hi1Gps A 4mka Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/28/2015 10/28/2015 3.00 PROD1 CASING PMPO P POOH w/pump f/11,035'to 9934'w/ 11,035.0 9,934.0 12:00 15:00 200 gpm @ 2225 psi w/no rotation- holding 270 psi w/MPD choke while pumping&trapping 500 psi on connections-Encountered tigh hole @ 9934' 10/28/2015 10/28/2015 2.00 PROD1 CASING CIRC T Worked pipe 2x with 25K over pull. 9,934.0 10,095.0 15:00 17:00 RIH to 10,095'MD.CBU 2x.250 gpm, 2800 psi, 100 rpm,9-10K tq. 10/28/2015 10/28/2015 1.00 PROD1 CASING EQRP T Erratic MPD choke operation.Trouble 10,095.0 10,095.0 17:00 18:00 shoot choke skid.Flush choke skid w/ mud. Pump 10 bpm/1000 psi through chokes to clear chokes. 10/28/2015 10/28/2015 1.25 PROD1 CASING EQRP T CBU while manually controlling MPD 10,095.0 10,095.0 18:00 19:15 "B"choke.Continue to trouble shoot choke skid."A"choke inoperable. 10/28/2015 10/28/2015 4.00 PROD1 CASING PMPO P Pump OOH f/10,095'MD t/8600'MD. 10,095.0 8,600.0 19:15 23:15 200 gpm,2100 psi,600 fph. 10/28/2015 10/29/2015 0.75 PROD1 CASING PMPO P Pump OOH f/8600'MD t/8506'MD. 8,600.0 8,506.0 23:15 00:00 200 gpm,2100 psi,200 fph. PU 160K SO 85K. OA=590 psi. 10/29/2015 10/29/2015 1.25 PROD1 CASING PMPO P Cont. POOH w/pump f/8506'to 8320' 8,506.0 8,320.0 00:00 01:15 @ 200 gpm @ 200'/hr-Holding pressure w/MPD choke 10/29/2015 10/29/2015 3.75 PROD1 CASING REAM T Hole packed off @ 8320'-Work pipe 8,320.0 8,657.0 01:15 05:00 down to 8657'holding pressure w/ MPD choke w/20 rpm's w/5 to 15 k- Regained circ @ 8657'-stage pump up to 3 bbls/min @ 1300 psi 10/29/2015 10/29/2015 1.00 PROD1 CASING CIRC T Circ btms up @ 3 bbls/min @ 1300 psi 8,657.0 8,657.0 05:00 06:00 w/45 rpm's 10/29/2015 10/29/2015 6.00 PROD1 CASING PMPO T Work pipe up to 8647'-Hole packed 8,657.0 8,833.0 06:00 12:00 off-worked pipe down hole to 8833' Attempt to regain circulation pumping 1 bbls/min @ 1000 psi w/50 to 100 rpm's Mud losses for tour=510 bbls. 10/29/2015 10/29/2015 7.25 PROD1 CASING BKRM T Back ream f/8833'MD t/8063'MD. 1 8,833.0 8,063.0 12:00 19:15 bpm,850 psi,15 rpm,9-12K tq,MPD back pressure 525-550 psi. PU 119K, ROT 116K, 100 fph. 10/29/2015 10/30/2015 4.75 PROD1 CASING BKRM T Tight hole @ 8063'MD.Torqueing up 8,063.0 8,019.0 19:15 00:00 and stalling out.Work pipe f/8063'MD t/8019'MD. 15 rpm,8-15K tq, 1.5 bpm, 1235 psi.PU 115K,SO 96K, ROT 110K.Partial returns and repeated packing off. Mud losses for tour=520 bbls OA=540 psi 10/30/2015 10/30/2015 5.50 PROD1 CASING BKRM T Back ream out of hole f/8019'MD to 8,019.0 7,886.0 00:00 05:30 shoe @ 7886'MD. 1 bpm, 1100 psi, 20 rpm,8K tq. Partial returns and repeated packing off. 10/30/2015 10/30/2015 3.50 PROD1 CASING CIRC P CBU x2.200 gpm,2200 psi,70 rpm, 7,886.0 7,896.0 05:30 09:00 9K tq.On second BU pump @ 220 gpm,2300 psi. 10/30/2015 10/30/2015 0.25 PROD1 CASING SFTY P PJSM on displacement procedure. 7,896.0 7,896.0 09:00 09:15 Page 44/49 Report Printed: 12/18/2015 Iperations Summary (with Timelog�epths) Or 2S-04 ConocoPhiIHps A fask:� Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/30/2015 10/30/2015 2.75 PROD1 CASING DISP P Pump and spot @ bit 40 bbl 12.6 ppg 7,896.0 7,348.0 09:15 12:00 hi-vis mud spacer followed by 25 bbl 12.6 ppg hi vis brine spacer. Lay in spacers f/7886'MD to 7348'MD @ 800 fph, .7 bpm,300 psi,PU 170K Mud losses for tour=231 bbls. 10/30/2015 10/30/2015 2.25 PROD1 CASING DISP P Continue to lay in spacers f/7348'MD 7,348.0 6,689.0 12:00 14:15 to 6689'MD @ 800 fph, .7 bpm,300 psi, PU 165K 10/30/2015 10/30/2015 1.50 PROD1 CASING DISP P Displace 10.8 ppg Flothru mud to 12.6 6,689.0 6,689.0 14:15 15:45 ppg NaBr brine.200 gpm reducing rate to 150 gpm to control ECD. 1450 psi to 850 psi.30 rpm,8-10K tq. Pumped 270 bbls with 40 bbls lost. 10/30/2015 10/30/2015 1.00 PROD1 CASING OWFF P OWFF.Static. 6,689.0 6,889.0 15:45 16:45 10/30/2015 10/30/2015 1.75 PROD1 CASING MPDA P Flush and blow down with water MPD 6,889.0 6,889.0 16:45 18:30 lines and choke skid.Remove RCD bearing assy. Install trip nipple.Blow down choke and kill lines 10/30/2015 10/31/2015 5.50 PROD1 CASING PMPO P Pump OOH f/6889'MD t/4509'MD. 6,889.0 4,509.0 18:30 00:00 .5 bpm, 125 psi, 1000-1500 FPH. Calc disp=14 bbls Act disp=55.65 bbls. 10/31/2015 10/31/2015 0.75 PROD1 CASING PMPO P POOH w/pump @ 1/2 bbl/min @ 125 4,509.0 4,228.0 00:00 00:45 psi f/4509'to 4228'@ 1500 ft/hr 10/31/2015 10/31/2015 0.25 PROD1 CASING RURD P Blow down top drive 4,228.0 4,228.0 00:45 01:00 10/31/2015 10/31/2015 4.00 PROD1 CASING TRIP P Trip out of hole on elevators f/4228'to 4,228.0 446.0 01:00 05:00 446' 10/31/2015 10/31/2015 0.50 PROD1 CASING OWFF P Monitor well-SIMOPS held PJSM on 446.0 446.0 05:00 05:30 laying down BHA&removing RA sources(static loss rate @ 7 bbls/hr) 10/31)2015 10/31/2015 3.00 PROD1 CASING BHAH P Lay down BHA-Calc.fill 27.2 bbls- 446.0 0.0 05:30 08:30 Actual fill 52.8 bbls 10/31/2015 10/31/2015 0.50 PROD1 CASING RURD P Clear&clean up rig floor 0.0 0.0 08:30 09:00 10/31/2015 10/31/2015 1.25 COMPZN CASING RURD P RIG up to run 4 1/2"liner 0.0 0.0 09:00 10:15 10/31/2015 10/31/2015 0.50 COMPZN CASING SFTY P Held PJSM w/crew&tong hand on 0.0 0.0 10:15 10:45 running 4 1/2"liner 10/31/2015 10/31/2015 7.25 COMPZN CASING PUTB P Ran 4 1/2"11.6#L-80 IMT-M slotted 0.0 5,680.0 10:45 18:00 &blank liner as follows:Ray Oil Tools silver bullett shoe- 1 jt blank-5 jts slotted-4 jts.blank-20 jts slotted-3 jts.blank-84 jts slotted-Swell packer -9 jts blank-All jts 4 1/2"liner have torque rings installed-Run 6.13" Hydroform centralizers on every third jt(45 total) 4 1/2" 11.6#IBTM-0 rejects/0 remakes Page 45/49 Report Printed: 12/18/2015 V 0 •perations Summary (with Timelog epths) so 2S-04 con000`Philbps Aknky Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/31/2015 10/31/2015 1.50 COMPZN CASING OTHR T MU seal bore extenstion-lift sub 5,680.0 5,745.0 18:00 19:30 pulled out of XO sub on top of seal bore when driller started to pick up sting out of slips-LD down seal bore extenstion-Inspected threads in top of XO(threads good)lowered lift sub back to rig floor-Lift sub was 5 1/2" Hydril 521 -XO sub top thread 5 1/2" Hydril 563 PU liner hanger assembly-MU stringer&pack-off to btm of hanger assembly-PU seal bore extension- MU liner hanger assembly w/ZXP packer to seal bore extenstion-Made up OK-MU hanger assembly/seal bore to string-Mix &Spot Pal mix in liner hanger sleeve 10/31/2015 10/31/2015 0.50 COMPZN CASING OTHR P PU liner hanger assembly-MU 5,745.0 5,745.0 19:30 20:00 stringer&pack-off to btm of hanger assembly-PU seal bore extension- MU liner hanger assembly w/ZXP packer to seal bore extenstion-Made up OK-MU hanger assembly/seal bore to string- 10/31/2015 10/31/2015 1.00 COMPZN CASING OTHR P Mix and set pal mix.Rig down csg. 5,745.0 5,745.0 20:00 21:00 running tools and clear from rig floor 10/31/2015 11/1/2015 3.00 COMPZN CASING RUNL P RIH w/4 1/2"11.6#L-80 IMT-M 5,745.0 8,400.0 21:00 00:00 slotted&blank liner on 4"DP f/5745' MD t/8400'MD.Obtain torque and drag parameters @ 7835'MD. PU 130K, SO 80K, ROT 95K, 15 rpm, 5K tq. Calc disp=38.3 Act disp=-61.98 for trip 11/1/2015 11/1/2015 5.00 COMPZN CASING RUNL P Cont.RIH w/4 1/2"liner on 4"DP f/ 8,400.0 13,476.0 00:00 05:00 8400'to 13,476'-PU wt 235 SO wt. 70-Calc displacement 39.7 bbls- Actual-55.5 bbls 11/1/2015 11/1/2015 1.25 COMPZN CASING CIRC P Break circ @ 1.7 bbl/min @ 300 psi- 13,476.0 13,476.0 05:00 06:15 Circ DP volume 11/1/2015 11/1/2015 2.00 COMPZN CASING PACK P Dropped 1 1/2"ball&circ down to ball 13,476.0 13,476.0 06:15 08:15 seat -Pressure up to 2100 to set liner hanger- slack off wt to confirm hanger is set OK-Pressure up to 4500 psi to set ZXP liner top packer & release running tool-Test ZXP liner top packer to 3000 psi for 5 mins- bled off pressure to 600 psi-Pull up slowly to pull setting tool f/liner- observed pressure drop-running tool free f/liner-Break circ Liner top @ 7730' Shoe @ 13,476' 11/1/2015 11/1/2015 3.50 COMPZN WELLPR CIRC P LD single of DP-Circ 2X bmts up @ 7,786.0 7,786.0 08:15 11:45 2.5 bbls/min @ 375 psi 11/1/2015 11/1/2015 0.25 COMPZN WELLPR TRIP P Pull&std back 1 std 4"DP to 7695' 7,786.0 7,695.0 11:45 12:00 11/1/2015 11/1/2015 1.00 COMPZN WELLPR OWFF P Monitor well static in 20 mins.- 7,695.0 7,695.0 12:00 13:00 Monitored for 30 mins.-Static 11/1/2015 11/1/2015 3.75 COMPZN WELLPR PMPO P Pump OOH f/7695'MD t/5758'MD. 1 7,695.0 5,758.0 13:00 16:45 bpm,225 psi, 1500 fph. Calc disp=19.62 bbls Act disp=39.45 bbls Page 46/49 Report Printed: 12/18/2015 •perations Summary (with Timelog epths) of.d:; 2S-04 ConocoPhilliips Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/1/2015 11/1/2015 0.25 COMPZN WELLPR RURD P Blow down top drive. 5,758.0 5,758.0 16:45 17:00 11/1/2015 11/1/2015 4.25 COMPZN WELLPR TRIP P POOH on elevators f/5758'MD 5,758.0 1,055.0 17:00 21:15 t/1055;MD. 11/1/2015 11/1/2015 0.25 COMPZN WELLPR OWFF P OWFF.Slight loss. 1,055.0 1,055.0 21:15 21:30 11/1/2015 11/1/2015 0.50 COMPZN WELLPR TRIP P POOH on elevators to liner running 1,055.0 73.0 21:30 22:00 tool. Calc disp=33.6 bbls Act disp=39.1 bbls. 11/1/2015 11/1/2015 0.75 COMPZN 'WELLPR BHAH P Lay down liner running tool as per 73.0 0.0 22:00 22:45 Baker rep. 11/1/2015 11/2/2015 1.25 COMPZN RPCOMP WWWH P Pull wear ring.Flush BOPE 0.0 0.0 22:45 00:00 11/2/2015 11/2/2015 0.75 COMPZN RPCOMP WWWH P Flush stack-Test#2 charge&mud 0.0 0.0 00:00 00:45 pump-Blow down TD 11/2/2015 11/2/2015 8.25 COMPZN RPCOMP PUTB P PJSM-Ran 3 1/2"9.3#EUE 8 RD-M 0.0 7,685.0 00:45 09:00 upper completion as follows: Baker 80 -40 GBH seal assembly w/locator-2 jts.tbg-Camco D nipple 2.75" w/ RHC plug installed-Baker CMU sliding sleeve-10 jts tbg-Camco GLM WI SO valve-96 jts.tbg-Camco GLM w/dummy valve-225 jts tbg- Camco DS nipple w/2,875"14 jts.tbg to 7685' 3 1/2" 9.3#EUE 8rdM L-80-0 rejects/0 remakes 11/2/2015 11/2/2015 2.25 COMPZN RPCOMP HOSO P PU 4 jts.tbg&land locator on No-Go 7,685.0 7,685.0 09:00 11:15 -Obtain space out measurements- Test annulus to 500 psi to confirm seals in Seal bore(Good)LD 3 jts.tbg -Used jt#240 for space out-MU XO -1 jts 4 1/2"IBT tbg- 11/2/2015 11/2/2015 0.75 COMPZN RPCOMP RURD 'P MU tbg hanger&landing jt.-RU head 7,685.0 7,685.0 11:15 12:00 pin&cement line-PU wt 105 SO wt. 85 11/2/2015 11/2/2015 0.50 COMPZN RPCOMP SFTY P PJSM on pumping corrosion inhibited 7,685.0 7,685.0 12:00 12:30 fluid 11/2/2015 11/2/2015 1.00 COMPZN RPCOMP CRIH P Pumped 20 bbls @ 2 bbls/min 12.6 7,685.0 7,685.0 12:30 13:30 ppg inhibited brine-spotted out of tbg tail @ 7685'to cover above GLM in IA 11/2/2015 11/2/2015 2.25 COMPZN RPCOMP THGR P Drain BOPE.Land tubing hanger. 7,685.0 7,788.0 13:30 15:45 RILDS.Test hanger seals to 5000 psi..Test IA to 1000 psi/5 min to confirm seals are stabbed into SBE. 11/2/2015 11/2/2015 0.50 COMPZN RPCOMP OWFF P OWFF.Static. 7,788.0 7,788.0 15:45 16:15 11/2/2015 11/2/2015 1.75 COMPZN RPCOMP PRTS P Drop 1.30 OD roller rod and ball.Wait 7,788.0 7,788.0 16:15 18:00 10 min's.Test tubing to 3500 psi/30 min. Bleed tubing down to 2000 psi. Test IA to 3500 psi/30 min. Page 47/49 Report Printed: 12/18/2015 f 0 operations Summary (with Timelogg pths) r 2S-04 Con000PhiIGps At.L, Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/2/2015 11/2/2015 0.25 COMPZN RPCOMP CIRC P Bleed off pressure from IA and tbg. 7,788.0 7,788.0 18:00 18:15 Pressure up IA to 3000 psi to shear SOV. Did not shear.Bleed off IA pressure. Pressure up IA to 3000 psi to shear SOV. Did not shear.Pressure up tbg to 2000 psi.Pressure up IA to 3500 psi. Dump tbg pressure and shear SOV. 11/2/2015 11/2/2015 1.00 COMPZN RPCOMP CIRC P Rig up and pump down tbg taking 7,788.0 7,788.0 18:15 19:15 returns from IA,rig up and pump down IA taking returns from tbg to confirm clear flow path. 11/2/2015 11/2/2015 0.50 COMPZN RPCOMP RURD P Rig down circ lines and lay down 7,788.0 0.0 19:15 19:45 landing jt. 11/2/2015 11/2/2015 1.00 COMPZN WHDBOP MPSP P Drain BOPE.Set BPV.Test BPV in 0.0 0.0 19:45 20:45 direction of flow to 2500 psi/10 min. 11/2/2015 11/2/2015 0.50 COMPZN WHDBOP OTHR P Blow down choke and circ lines. 0.0 0.0 20:45 21:15 11/2/2015 11/3/2015 2.75 COMPZN WHDBOP NUND P Clean RCD and Katch Kan.Remove 0.0 0.0 21:15 00:00 trip nipple and Katch Kan.Rig down MPD lines and scaffold. ND BOPE. Sim-ops/Change out saver sub on top drive to 4 1/2 IF. 11/3/2015 11/3/2015 5.50 COMPZN WHDBOP NUND P Continue to ND BOPE.Sim- 0.0 0.0 00:00 05:30 ops/Change out top drive saver sub, clean pits, shovel out rock washer containment berm.Prep mud pumps for rig move. 11/3/2015 11/3/2015 4.50 COMPZN WHDBOP NUND P Orient and NU adapter flange.Test 0.0 0.0 05:30 10:00 seals to 300/5000 psi/15 mins.NU tree. On rig power @ 06:45 hrs 11/3/2015 11/3/2015 1.00 COMPZN WHDBOP PRTS P Test tree.250/5000 psi/15 mins. 0.0 0.0 10:00 11:00 11/3/2015 11/3/2015 1.00 COMPZN WHDBOP FRZP P Rig up circ lines and scaffold in cellar. 0.0 0.0 11:00 12:00 Set mousehole. 11/3/2015 11/3/2015 1.25 COMPZN WHDBOP OTHR P Clean and clear rig floor.Transport XT 0.0 0.0 12:00 13:15 -39 thread protectors to rig floor. 11/3/2015 11/3/2015 0.50 COMPZN WHDBOP PULD P Lay down 4"drillpipe via mousehole. 0.0 0.0 13:15 13:45 (18 jts) 11/3/2015 11/3/2015 0.25 COMPZN WHDBOP MPSP P Pull BPV. 0.0 0.0 13:45 14:00 11/3/2015 11/3/2015 5.75 COMPZN WHDBOP FRZP P Spot and rig up Little Red 0.0 0.0 14:00 19:45 Services..Test lines to 3000 psi.Pump 95 bbls diesel down annulus 1.75 bpm. ICP=500 psi,FCP=1500 psi.. Allow to u-tube into tubing.Sim- ops/Lay down 4"drillpipe.(285 jts) 11/3/2015 11/3/2015 1.25 COMPZN WHDBOP MPSP P Rig up lubricator and test to 2500 psi. 0.0 0.0 19:45 21:00 Set BPV. Rig down lubricator. 11/3/2015 11/4/2015 3.00 DEMOB MOVE PULD P Lay down 4"DP via mousehole.(177 0.0 0.0 21:00 00:00 jts).Sim-ops/Rig down scaffold and freeze protect lines in cellar. 11/4/2015 11/4/2015 1.50 DEMOB MOVE PULD P Continue to lay down DP.(36 jts) 0.0 0.0 00:00 01:30 OA=475 psi IA=425 psi Page 48/49 Report Printed: 12/18/2015 Iterations Summary (with Timelog epths) r41114 2S-04 Conoco`PthiHips ht kn Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/4/2015 11/4/2015 4.50 DEMOB MOVE RURD P Clean rig floor and drip pan.Remove 0.0 0.0 01:30 06:00 flange from MPD air valve.Blow down water and steam systems.Prep rig for move. Rig released @ 06:00 hrs 11/4/15 Page 49/49 Report Printed: 12/18/2015 • 0 0 ta Daily Operations Summary• 2S-04 +i on cca'E+hdrips Rig: DOYON 141 Job: DRILLING ORIGINAL Daily Operations Start Date Last 24hr Sum 9/17/2015 Tie on to trucks&move from 2S-10 to 2S-04. Complete rig acceptance checklist.Finish nipple up of diverter system.Take on spud mud. Mobilize 5"handling equipment to rig floor.Service rig. Perform diverter test,AOGCC Rep.Bob Noble waived witness. Rig up to pick up 5"DP. 9/18/2015 Pick up 5"DP&rack back in derrick. PU BHA 1.Clean out mud pumps of gravel.Flood lines&conductor checking for leaks.Test mud lines to 3500 psi.Spud well,drilling ahead surface section from surface to 770'MD. 9/19/2015 Continued to drill surface section from 770'-2622'MD.Total footage for 24 hrs 1852'MD. 9/20/2015 Continue to drill surface section to TD-2831'MD.CBU 2X. Back ream out of hole.Reduce parameters at the base of the permafrost and drop Gyro 548'MD on the way out of the hole. Lay down BHA1. Prep and run 10 3/4"surface casing to 1119'MD.Work casing with varying parameters f/1119'-1147'MD. 9/21/2015 Continue to work 10 3/4"surface casing to TD.Circulate and condition mud for cement. Pump cement as per SLB. Nipple down diverter system. Nipple up wellhead&BOPE. Perform BWM on BOPE. 9/22/2015 Finish BWM on BOPE.Test BOPE 250/3500 psi. Pick up&rack back 35 stands of 5"DP. Make up BHA 2&single in w/5"DP to-2500'MD. Test&troubleshoot MPDE. 9/23/2015 Slipped&cut drill line-Tested csg to 3500 psi-Drilled shoe track &20'new hole to 2845'-Performed LOT to 14.95 ppg EMW-Drilled 9 7/8" hole f/2845'to 3654'MD,3168'TVD.Total footage drilled for 24 hrs 829'MD. 9/24/2015 Drilled 9 7/8"hole f/3654'to 5537'MD.CBU&install RCD.Continue drilling 5537'to 5746'MD,4912'TVD.Total footage for 24 hrs,2092'MD. 9/25/2015 Drilled 9 7/8"hole f/5746'to 6399'-Performed 290 bbls whole mud dilution-Drilled 9 7/8"hole f/6399'to 7156'-Monitor well 30 mins.static- Change out MPD bearing-Drill 9 7/8 hole f/7156'to 7260'.C/O MPD pressure sensor. Drill 9 7/8 hole f/7260'to 7555'MD,6157'TVD.Total footage for 24 hrs, 1809'MD. 9/26/2015 Drilled to TD,f/7555'-7800'MD,6240'TVD.CBU 3X, racking back a stand each BU. Ream back to bottom,7800'MD. Perform draw down test. Perform 290 bbls mud dilution.Circulate out gas cut mud. Monitor well,observe flow.Weight up mud system f/10.5 to 10.8 ppg. Encountered tight hole&pack off.Work pipe free&re-establish parameters. BROOH to above the HRZ&CBU. Monitor well,reducing flow observed.CBU, observing gas cut mud.Monitor well,reducing flow observed. 9/27/2015 Continue monitoring the well,observe flow decrease,leveling out at.5 bph.Weight up mud system f/10.8 to 11.1 ppg. Monitor well,observe flow decrease,leveling out a to .23 bph.Circulate&condition gas cut mud. Monitor well with MPD shut in.C&C gas cut mud.Change out MPD bearing.C&C gas cut mud. Begin weight up mud system w/spike fluid f/11.2 to 11.4 ppg. 9/28/2015 Monitor well-RIH to 7457'-Circ btms up-Gas peak @ 9900 units @ 4700 stks(55 bbls before btms up)-RIH f/7457'-7744'-Wash down f/ 7744'to 7765'-took wt&packed off-Work pipe free-BROOH f/7765 to 7170'MD-CBU. 9/29/2015 Monitor well. Slight flow.CBU.Strip OOH.Tight @ 6940'MD. RIH to 6970'MD. BROOH to 6879'MD. Lost circ. Fill hole w/52 bbls mud.Spot LCM pill to 5600'MD. Remove RCD bearing assy.Wait on mud from mud plant. Condition mud.Spot LCM pill to 5600'MD.Monitor well.Spot LCM pill to 5600'MD. Monitor well. 9/30/2015 Pump LCM pill#4-Monitor well-Attempt to circ. Monitor well. Pump LCM pill#5-Monitor well-Begin BROOH f/6784'to 5504'. Pump LCM pill #6. Monitor well. Pump OOH f/5540'to 4296'. 10/1/2015 Cont. POOH w/pump from 4296'MD to 2758'MD.Attempt to circ @ 2758'MD.OWFF. POOH w/pump from 2758'MD to 939'MD.Pit gain and flow increase observed.Shut well in.Open choke and monitor flow. Initial gain rate @28.5 bph.Shut well in.Wait on mud from mud plant. Bullhead hi-vis spacer followed with 10.5 ppg mud. 10/2/2015 Cont. Bullheading 10.5 ppg mud down annulus @ 5 bbls/min @ 110 psi(choke panel gauge) 180 psi(Totco)-Pumped total of 945 bbls-placing 10.5 ppg mud @ 6558'Bermuda formation-Additional volume pumped to account for gas mirgration rate of 1.42 BMP-Shut in pressure 110 psi- Monitor well-Ordered spike fluid for 11.5 ppg mud cap-Weight up mud in pits to 11.5 ppg. Bullhead 270 bbls 11.5 ppg mud. Monitor well. Losses @ 300 to 500 bph. Lower mud weight to 11 ppg and fill through kill line. Losses diminished to 35 bph. POOH.Trouble shoot source transport shield problem. Lay down BHA. 10/3/2015 Finish LD BHA-RU&Ran 3 1/2"tbg(cmt.stinger)to 1100'-RIH w/3 1/2"cmt stinger on 5"DP to 2734'-Pull trip nipple&Install MPD bearing- Attempt to circ btms up pumped 4 bbls(No returns)-Circ over top of hole to keep hole full-Change out Dynamatic on drawworks 10/4/2015 Finish change out of Dynamatic-Observed gas increasing-SI well w/MPD choke 12 psi-Bullhead 40 bbls-11.3 ppg mud down Dp&Bullhead 200 bbls 11.3 ppg mud down annulus-Monitor well losses @ 1.5 bbls/hr-RIH w/cmt stinger from 2734'MD to 6654'MD. Pump 10 bbls 11.3 ppg mud down DP. No returns. RIH from 6654'MD to 7747'MD.Attempt to circ. Hole packing off. POOH to 7715 MD. Brk circ. Packing off. POOH to 7682'MD. Brk circ. Pump P&A plug per program.Attempt to POOH.Work stuck pipe.Attempt to twist off cement stinger.WOC. 10/5/2015 Monitor well&servicing rig while waiting on E line-Spot WL unit&MU tools in pipe shed-RU wireline on rig floor-Ran tool string#1 sinker bars w/CCL to 5957; RU tool string#2-Dual Effect Free Point and magnet to 5957'-POOH-Work drill string-RU tool string#3-Dual Effect Free Point and RIH to 5957'-Determine drill string is free to 5825'. POOH-RU tool string#4 string shot. RIH and fire string shot(/5772'MD t/5778'MD. POOH. 10/6/2015 Lay down string shot toolstring. MU Radial Cutting Torch tool string.RIH and attempt to cut pipe @ 5775'WLM.. POOH. Lost RCT down hole. Make dummy run w/3.25"CCL. Unable to get past 1500'. POOH. Make up fishing toolstring and RIH.Attempt to latch fish. POOH. Make up RCT toolstring and RIH ton 5775'WLM.Fire RCT and POOH. Pull on DP to confirm cut. Pipe not cut.Wait on Drill Collar Serering Tool. Make up DCST toolstring and RIH.Cut pipe @ 5764'WLM/5751"DP measurement. POOH w/toolstring. Pump out of hole w/DP to 5457'MD.Attempt to brk circ and rig down wireline Page 1/3 Report Printed: 12/2/2015 • III Daily Operations Summary 2S-04 ConocoPhmips • $ttt, Rig: DOYON 141 Job: DRILLING ORIGINAL Daily Operations Start Date Last 24hr Sum 10/7/2015 Attempt to circ @ 5457'MD. 120 bph loss rate.Wait on mud.Take on and condition mud to 11.3 ppg.Bullhead 90 bbls down DP. Bullhead 200 bbls down annulus.OWFF. Pump OOH to 4978'MD. Bullhead down DP and annulus while POOH to 2777'MD.Attempt to circ. No returns. OWFF. Remove RCD bearing assy. Install trip nipple. Pump OOH to 2298'MD. POOH on elevators.Clean and clear rig floor. RU to test BOPE. Test BOPE. 10/8/2015 Complete BOPE test.Rig up casing equip. PU ECP and cement stinger. RIH w/cmt stinger on DP picking up DP from pipe shed to—5662'MD. Inflate and release from ECP. ECP element @ 5600'MD.Attempt to circ.92 bph loss rate with 6000+units of gas. Bullhead 425 bbls 11.3 ppg mud.Spot 600'P&A cement plug. 10/9/2015 POOH to 4752'MD. Drop wiper ball and circ string vol.OWFF. POOH to 2700'MD.WOC. RIH and tag cement plug @ 5036'MD.Wait on orders. Prepare to pump P&A plug#3. Pump P&A plug#3(/5026'MD t/4677'MD. POOH to 4378'MD.Drop wiper ball and CBU. 10/10/2015 Circ @ 4378'MD.OWFF. POOH to shoe @ 2815'MD.WOC. RIH and tag P&A plug#3 @4877'MD. POOH to 4845'MD.CBU. Monitor well. POOH to 2790'MD. Perform FIT to 12.5 ppg EMW. POOH. Lay down ECP running tool.Clear rig floor. Make up ECP#2 assy. RIH to 3076'MD.. 10/11/2015 RIH to 3300'MD(top of ECP @ 3231' MD).Circ drillstring volume.Drop dart and attempt to inflate ECP. No indication of inflation.Consult with drilling engineer. Release from ECP @ 3231'MD.CBU. Mix and pump kick off plug.POOH to 2482'MD. Drop wiper ball and CBU x 2. POOH to 2387'MD.WOC.Wash down from 2387'MD to 3507'MD. Did not tag plug.CBU. 10/12/2015 Circ and cond mud. Spot 30 bbl. hi-vis pill. POOH to 3226'MD.CBU. Spot kick off plug#2. POOH to 2480'MD.CBU.OWFF. POOH. Lay down cement stinger.Rig up to test BOPE.Change out upper VBR's.Test BOPE. Rig down test equip. Make up 9 7/8"x 11"drilling BHA. 10/13/2015 Con't to make up BHA. RIH.Shallow test MWD.RIH to 2480'MD.Wash down and tag cement @ 2642'MD. Drill out cement.Displace f/11.1 to 10.1 ppg LSND mud. Kick off and side track intremediate hole section f/2815'-2952'.CBU. Install RCD bearing. Directional drill 9-7/8"x 11" intermediate hole section f/2952-2970'. CBU&C/O leaking RCD. Directional drill 9-7/8"x 11"intermediate hole section f/2970-3688'MD. Total footage 873'. 10/14/2015 Directional drill 9-7/8"x 11"intermediate hole section as per plan f/3688'-4747'MD.Observed pressure increase of 97 psi during a connection w/ MPD chokes closed.CBU&observe gas back at surface.Continue drilling ahead holding 100 psi on connections f/4747'-4948'MD.Observe RCD clamp leaking&CBU.Tighten clamp&continue drilling ahead f/4948'-5213'MD.Total footage 1525'MD. 10/15/2015 Directional drill 9-7/8"x 11"intermediate hole section as per plan f/5213'-5956'MD. RCD bearing was observed leaking.Circulate half a BU. Change out RCD bearing&break in same. Directional drill 9-7/8"x 11"intermediate hole section as per plan f/5956'-6700'MD.Total footage for 24 hrs 1487'MD. 10/16/2015 Directional drill 9-7/8"x 11"intermediate hole section as per plan f/6700'-7269'MD. RCD bearing was observed leaking.Change out RCD bearing &break in same. Directional drill 9-7/8"x 11"intermediate hole section to TD f/7269'-7896'MD. Closed reamer.CBU for even mud properties. StripOOH f/7895'-7339'MD.CBU.Total footage for 24 hrs 1196'MD.TD 7896'MD,6188'TVD. 10/17/2015 Continue CBU. Finger print&weight up to 10.6 ppg.StripOOH to shoe. CBU.OWFF to remove RCD&install trip nipple. POOH&lay down BHA. Flush stack&remove wear bushing. CIO VBR's to 7-5/8"rams&test the same. Rig up&run 7-5/8"casing as per plan from surface to 1296'MD. 10/18/2015 Continue running 7-5/8"casing as per detail to 2795'MD&CBU. Continue to run casing to 4548'MD. Observed displacement decrease&try to establish circulation,with minimal returns.Continue to RIH w/7-5/8"casing f/4548'-7886'MD. Circulate&condition mud for cement job,with minimal to no returns. Perform 2 stage cement job as per SLB. Install 7-5/8"pack off&attempt to test. Found seal damaged&changed out same. 10/19/2015 Test 7-5/8"pack off. Rig down casing equipment.Change out upper rams to VBR's&load pipe shed w/4"DP. Freeze protect OA. Remove Elite MPD system&install WFT MPD system. Lay down 5"DP from derrick. 10/20/2015 Finish LD 5'DP-Change handling equipment for 4'Dp-PU&Std back 152 stds 4"DP-PU&std back 4 3/4'NM flex DC's-Change out saver sub-Test MPD- RU&test BOPE 10/21/2015 Finish BOP test-Attempt to retest Weatherford Orbit valve(no test)-Changed out Orbit valve&tested to 1000 psi(Good test)-RD test equipment-Set wear bushing-Bring BHA tools to rig floor-MU BHA-RIH 10/22/2015 Continue MAD pass w/SonicScope f/5963'to 7737'-Tag cmt @ 7737'-CIO cmt to 7745'-Slip&cut drill line-Test csg to 3500 psi(30 mins. Good Test)Test MPD ramp schedule-Drill shoe track&rat hole-Circulate&condition mud-Begin installing RCD. 10/23/2015 Cont.installing MPD bearing-Driled 20'new hole f/7896'to 7916'(for FIT)circ hole clean-monitor well(static) RU&perform FIT to 14.5 ppg EMW-Change well over to 10.5 ppg Flow-Thru system-Drill 6 3/4"hole f/7916'to 8605'MD.Total footage for 24 hrs,709'MD. 10/24/2015 Drilled 6 3/4"hole w/RSS&MPD f/8605'to 9238'MD.Circulate out gas cut mud @ 9238'MD. DDrill f/9238'to 10183'MD. Performed draw down test @ 10183'MD.DDrill f/10183'to 10252'MD.Total footage for 24 hrs 1647'MD. 10/25/2015 Drilled 6 3/4"hole w/RSS&MPD f/10,252'to 11,824'MD,6264'TVD.Total footage for 24 hrs, 1572'MD. 10/26/2015 Drilled 6 3/4"hole w/RSS&MPD f/11,824'to 12,357'-Changed out Wertherford RCD bearing-Drilled 6 3/4"hole w/RSS&MPD f/12,357'to 13205'MD,6238'TVD.Total footage for 24 hrs, 1381'MD. 10/27/2015 Drilled 6 3/4"hole w/RSS&MPD f/13205'to 13,477'-Hole taking fluid-Spot LCM pill-Drilled 6 3/4"hole f/13477'to 13505'MD 6236'TVD-TD of production hole-Peform draw down w/MPD-Circ out gas and pump LCM pills.Perform dynamic draw down test. Determine pore pressure @ 12.35 ppg. 10/28/2015 Circulate out gas @ 13,303'MD. Spot LCM pill.Pump OOH f/13,300'MD t/9934'MD.Work tight hole@ 9934'MD. RIH to 10,095'MD. CBU x2. Trouble shoot MPD choke system.CBU. Pump OOH f/10,095'MD t/8506'MD. 10/29/2015 Cont. POOH w/pump V 8506' Hole pscked off @ 8320'-Work pipe to regain retunrs @ 8657'-Circ-hole pcaked off @ 8647'-Work pipe down to 8647'Attempting to regain circ-POOH w/pump f/8833' t/8063'MD.Work through tight hole(/8063'MD t/8019'MD. Page 2/3 Report Printed: 12/2/2015 • • • Daily Operations Summary &Wens 2S-04 ConocoPhillips Rig: DOYON 141 Job: DRILLING ORIGINAL Daily Operations Start Date Last 24hr Sum 10/30/2015 Back ream out of hole f/8019'MD to 7 5/8"shoe @ 7886'MD..CBU x2..Spot hi-vis mud and brine spacer pills f/7886'MD to 6689'MD.. Displace well to 12.6 ppg NaBr brine. OWFF.Flush and blow down MPD equipment. Remove RCD bearing assy. Install trip nipple Pump out of hole f/6689' MD t/4509'MD 10/31/2015 Cont. POOH w/pump 4509'to 4228'-Blow down TD-POOH on elevators f/4228'to 446'-Monitor(static losses @ 7 bbls/hr-LD BHA-RU to run 4 1/2"liner-Ran 4 1/2"liner to 5680'MD.Make up SBE. Lift sub pulled out of SBE.Lay down SBE and inspect threads. Make up SBE and packer/hanger assy.Rig down casing equip.and clear rig floor. RIH w/liner on DP to 8400'MD. 11/1/2015 Cont. RIH w/4-1/2"liner on 4"DP-to 13,476'-Set liner hanger&ZXPliner top packer-Release running tool f/liner-Circ 2X btms up-Monitor well(static)Pump OOH w/liner running tool to 5758'MD. POOH on elevators. Lay down liner running tool.Pull wear bushing. Flush BOPE. 11/2/2015 Flush stack-RU&Ran 3 1/2"upper completion-Land out w/locator on NO-GO-Space out and MU hanger.Spot 20 bbls inhibited brine. Land and test hanger.OWFF. Drop ball and rod.Test tbg and IA. Shear SOV.Confirm clear flow path.RD circ lines and lay down landing jt.Set and test BPV.ND BOPE. 11/3/2015 Con't to ND BOPE. NU and test tree. Erect scaffold and freeze protect lines. Freeze protect well with diesel. Lay down DP while pumping freeze protect.Set BPV.Con't to lay down DP. 11/4/2015 Lay down remaining DP.Clean rig. Prep rig for move. Page 3/3 Report Printed: 12/2/2015 • • NADConversion Kuparuk River Unit Kuparuk 2S Pad 2S-04 Definitive Survey Report 04 November, 2015 0 . . 1 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-04 Project: Kuparuk River Unit TVD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Well: 2S-04 North Reference: True Wellbore: 2S-04 Survey Calculation Method: Minimum Curvature Design: 2S-04 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2S-04 Well Position +N/-S 0.00 usft Northing: 5,930,017.59 usfl Latitude: 70°13'11.873 N +E/-W 0.00 usft Easting: 481,221.00 usfl Longitude: 150°9'5.394 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 120.00 usft Wellbore 2S-04 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2015 9/30/2015 18.56 80.87 57,488 Design 2S-04 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 2,755.06 Vertical Section: Depth From(TVD) +NI-S +E/-W Direction (usft) (usft) (usft) (°) 27.50 0.00 0.00 18.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 78.00 447.00 2S-04PB1 Srvy#1 -GYD-GC-SS(2S-04 GYD-GC-SS Gyrodata gyro single shots 9/21/2015 8:5; 476.76 2,755.06 25-04PB1 Snry#2-MWD+IFR-AK-CAZ-MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/21/2015 9:1 2,850.10 2,850.10 2S-04 Srvy#1 -INC TREND(2S-04) INC+TREND Inclinometer+known azi trend 10/14/2015 8:: 2,881.04 7,825.68 2S-04 Srvy#2-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/14/2015 8:: 7,836.01 7,836.01 2S-04 Srvy#3-INC+TREND(2S-04) INC+TREND Inclinometer+known azi trend 10/19/2015 10: 7,930.59 13,411.95 2S-04 Srvy#4-MWD+IFR-AK-CAZ(2S-MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/26/2015 8:: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 27.50 0.00 0.00 27.50 -120.00 0.00 0.00 5,930,017.59 481,221.00 0.00 0.00 UNDEFINED 78.00 0.30 241.15 78.00 -69.50 -0.06 -0.12 5,930,017.53 481,220.88 0.59 -0.10 GYD-GC-SS(1) 170.00 0.45 266.98 170.00 22.50 -0.20 -0.69 5,930,017.39 481,220.31 0.24 -0.40 GYD-GC-SS(1) 263.00 0.52 264.61 262.99 115.49 -0.26 -1.47 5,930,017.34 481,219.53 0.08 -0.70 GYD-GC-SS(1) 355.00 0.64 262.29 354.99 207.49 -0.37 -2.40 5,930,017.23 481,218.60 0.13 -1.09 GYD-GC-SS(1) 447.00 0.58 275.81 446.98 299.48 -0.39 -3.37 5,930,017.21 481,217.63 0.17 -1.41 GYD-GC-SS(1) 476.76 0.31 285.28 476.74 329.24 -0.35 -3.60 5,930,017.25 481,217.40 0.94 -1.45 MWD+IFR-AK-CAZ-SC(2) 567.94 0.04 243.25 567.92 420.42 -0.30 -3.86 5,930,017.30 481,217.14 0.31 -1.48 MWD+IFR-AK-CAZ-SC(2) 660.98 1.43 217.97 660.95 513.45 -1.23 -4.61 5,930,016.37 481,216.39 1.50 -2.59 MWD+IFR-AK-CAZ-SC(2) 696.02 2.12 219.06 695.98 548.48 -2.08 -5.28 5,930,015.52 481,215.71 1.97 -3.61 MWD+IFR-AK-CAZ-SC(2) 11/412015 9:39:08AM Page 2 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-04 Project: Kuparuk River Unit TVD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Well: 2S-04 North Reference: True Wellbore: 2S-04 Survey Calculation Method: Minimum Curvature Design: 2S-04 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 757.33 2.58 214.47 757.23 609.73 -4.10 -6.78 5,930,013.51 481,214.21 0.81 -5.99 MWD+IFR-AK-CAZ-SC(2) 853.64 3.59 211.81 853.40 705.90 -8.45 -9.60 5,930,009.17 481,211.38 1.06 -11.00 MWD+IFR-AK-CAZ-SC(2) 948.89 4.60 201.35 948.41 800.91 -14.54 -12.56 5,930,003.08 481,208.41 1.31 -17.71 MWD+IFR-AK-CAZ-SC(2) 1,045.12 7.88 197.52 1,044.06 896.56 -24.43 -15.95 5,929,993.21 481,204.99 3.43 -28.16 MWD+IFR-AK-CAZ-SC(2) 1,140.42 10.66 202.74 1,138.11 990.61 -38.79 -21.33 5,929,978.86 481,199.58 3.04 -43.48 MWD+IFR-AK-CAZ-SC(2) 1,237.11 13.56 204.84 1,232.63 1,085.13 -57.33 -29.55 5,929,960.34 481,191.31 3.03 -63.65 MWD+IFR-AK-CAZ-SC(2) 1,332.94 17.82 206.38 1,324.87 1,177.37 -80.67 -40.79 5,929,937.03 481,180.02 4.47 -89.32 MWD+IFR-AK-CAZ-SC(2) 1,428.89 20.05 207.90 1,415.63 1,268.13 -108.36 -55.01 5,929,909.38 481,165.73 2.38 -120.05 MWD+IFR-AK-CAZ-SC(2) 1,525.28 19.63 209.48 1,506.29 1,358.79 -137.06 -70.71 5,929,880.72 481,149.96 0.71 -152.20 MWD+IFR-AK-CAZ-SC(2) 1,621.34 21.86 208.07 1,596.12 1,448.62 -166.89 -87.06 5,929,850.94 481,133.53 2.38 -185.62 MWD+IFR-AK-CAZ-SC(2) 1,715.89 22.82 207.21 1,683.57 1,536.07 -198.73 -103.73 5,929,819.14 481,116.78 1.07 -221.06 MWD+IFR-AK-CAZ-SC(2) 1,811.64 25.43 208.33 1,770.95 1,623.45 -233.34 -121.98 5,929,784.58 481,098.45 2.77 -259.61 MWD+IFR-AK-CAZ-SC(2) 1,909.25 28.51 211.22 1,857.94 1,710.44 -271.72 -144.01 5,929,746.26 481,076.33 3.43 -302.92 MWD+IFR-AK-CAZ-SC(2) 2,003.73 29.77 212.20 1,940.46 1,792.96 -310.85 -168.19 5,929,707.19 481,052.05 1.43 -347.61 MWD+IFR-AK-CAZ-SC(2) 2,098.75 32.65 215.49 2,021.73 1,874.23 -351.70 -195.65 5,929,666.42 481,024.49 3.52 -394.94 MWD+IFR-AK-CAZ-SC(2) 2,195.36 35.25 219.32 2,101.87 1,954.37 -394.50 -228.46 5,929,623.70 480,991.58 3.48 -445.79 MWD+IFR-AK-CAZ-SC(2) 2,290.95 38.19 223.06 2,178.49 2,030.99 -437.44 -266.13 5,929,580.86 480,953.81 3.86 -498.27 MWD+IFR-AK-CAZ-SC(2) 2,387.10 40.65 224.33 2,252.77 2,105.27 -481.57 -308.31 5,929,536.84 480,911.52 2.69 -553.27 MWD+IFR-AK-CAZ-SC(2) 2,483.15 44.04 225.78 2,323.75 2,176.25 -527.25 -354.11 5,929,491.28 480,865.61 3.67 -610.87 MWD+IFR-AK-CAZ-SC(2) 2,547.93 43.50 225.21 2,370.53 2,223.03 -558.66 -386.07 5,929,459.95 480,833.58 1.03 -650.62 MWD+IFR-AK-CAZ-SC(2) 2,579.52 43.26 226.72 2,393.49 2,245.99 -573.74 -401.67 5,929,444.91 480,817.94 3.37 -669.78 MWD+IFR-AK-CAZ-SC(2) 2,675.03 44.34 227.55 2,462.42 2,314.92 -618.70 -450.13 5,929,400.07 480,769.38 1.28 -727.52 MWD+IFR-AK-CAZ-SC(2) 2,755.06 44.33 227.28 2,519.67 2,372.17 -656.55 -491.31 5,929,362.33 480,728.11 0.24 -776.24 MWD+IFR-AK-CAZ-SC(2) 2,756.06 44.34 227.26 2,520.38 2,372.88 -657.02 -491.82 5,929,361.86 480,727.60 2.00 -776.85 INC+TREND(3) 10 3/4"x 13-1/2 2,850.10 45.74 225.48 2,586.83 2,439.33 -702.94 -539.97 5,929,316.06 480,679.34 2.00 -835.40 INC+TREND(3) 2,881.04 45.64 226.26 2,608.44 2,460.94 -718.36 -555.86 5,929,300.69 480,663.41 1.83 -854.97 MWD+IFR-AK-CAZ-SC(4) 2,943.47 45.46 226.07 2,652.16 2,504.66 -749.23 -588.01 5,929,269.90 480,631.19 0.36 -894.26 MWD+IFR-AK-CAZ-SC(4) 2,991.33 45.20 224.82 2,685.81 2,538.31 -773.10 -612.26 5,929,246.09 480,606.88 1.94 -924.46 MWD+IFR-AK-CAZ-SC(4) 3,085.27 43.88 219.67 2,752.79 2,605.29 -821.82 -656.56 5,929,197.48 480,562.47 4.09 -984.49 MWD+IFR-AK-CAZ-SC(4) 3,178.47 42.77 215.51 2,820.60 2,673.10 -872.46 -695.56 5,929,146.95 480,523.34 3.29 -1,044.70 MWD+IFR-AK-CAZ-SC(4) 3,271.17 42.52 213.65 2,888.79 2,741.29 -924.16 -731.21 5,929,095.35 480,487.57 1.39 -1,104.88 MWD+IFR-AK-CAZ-SC(4) 3,365.26 45.80 215.59 2,956.28 2,808.78 -978.07 -768.46 5,929,041.53 480,450.18 3.77 -1,167.67 MWD+IFR-AK-CAZ-SC(4) 3,460.11 49.61 215.68 3,020.10 2,872.60 -1,035.08 -809.34 5,928,984.63 480,409.17 4.02 -1,234.52 MWD+IFR-AK-CAZ-SC(4) 3,553.94 52.54 216.98 3,079.05 2,931.55 -1,093.87 -852.59 5,928,925.96 480,365.78 3.30 -1,303.79 MWD+IFR-AK-CAZ-SC(4) 3,648.55 54.97 217.69 3,134.98 2,987.48 -1,154.53 -898.87 5,928,865.42 480,319.35 2.64 -1,375.78 MWD+IFR-AK-CAZ-SC(4) 3,741.04 56.65 219.60 3,186.96 3,039.46 -1,214.26 -946.65 5,928,805.81 480,271.43 2.49 -1,447.36 MWD+IFR-AK-CAZ-SC(4) 3,835.72 54.45 221.60 3,240.52 3,093.02 -1,273.55 -997.44 5,928,746.65 480,220.50 2.90 -1,519.44 MWD+IFR-AK-CAZ-SC(4) 3,928.58 52.58 223.97 3,295.74 3,148.24 -1,328.35 -1,048.13 5,928,691.99 480,169.68 2.87 -1,587.22 MWD+IFR-AK-CAZ-SC(4) 4,021.35 52.75 227.26 3,352.01 3,204.51 -1,379.93 -1,100.83 5,928,640.54 480,116.85 2.83 -1,652.56 MWD+IFR-AK-CAZ-SC(4) 11/4/2015 9:39:08AM Page 3 COMPASS 5000.1 Build 74 • • . Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-04 Project: Kuparuk River Unit TVD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Well: 2S-04 North Reference: True Wellbore: 2S-04 Survey Calculation Method: Minimum Curvature Design: 2S-04 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,113.90 52.56 228.80 3,408.15 3,260.65 -1,429.13 -1,155.53 5,928,591.48 480,062.03 1.34 -1,716.26 MWD+IFR-AK-CAZ-SC(4) 4,208.67 50.02 228.75 3,467.41 3,319.91 -1,477.86 -1,211.15 5,928,542.90 480,006.30 2.68 -1,779.79 MWD+IFR-AK-CAZ-SC(4) 4,301.46 46.76 227.94 3,529.02 3,381.52 -1,523.95 -1,262.98 5,928,496.93 479,954.35 3.57 -1,839.65 MWD+IFR-AK-CAZ-SC(4) 4,395.36 43.84 229.66 3,595.07 3,447.57 -1,567.93 -1,313.18 5,928,453.09 479,904.06 3.37 -1,896.98 MWD+IFR-AK-CAZ-SC(4) 4,489.19 41.49 231.86 3,664.06 3,516.56 -1,608.17 -1,362.40 5,928,412.98 479,854.74 2.97 -1,950.46 MWD+IFR-AK-CAZ-SC(4) 4,582.90 39.21 235.77 3,735.49 3,587.99 -1,644.01 -1,411.32 5,928,377.26 479,805.74 3.63 -1,999.67 MWD+IFR-AK-CAZ-SC(4) 4,675.87 37.43 239.72 3,808.44 3,660.94 -1,674.79 -1,460.02 5,928,346.60 479,756.96 3.26 -2,043.99 MWD+IFR-AK-CAZ-SC(4) 4,768.94 35.56 243.94 3,883.26 3,735.76 -1,700.95 -1,508.77 5,928,320.57 479,708.15 3.36 -2,083.94 MWD+IFR-AK-CAZ-SC(4) 4,862.31 33.64 247.09 3,960.12 3,812.62 -1,722.95 -1,556.99 5,928,298.69 479,659.88 2.81 -2,119.76 MWD+IFR-AK-CAZ-SC(4) 4,955.74 32.18 251.11 4,038.57 3,891.07 -1,741.08 -1,604.38 5,928,280.68 479,612.45 2.81 -2,151.65 MWD+IFR-AK-CAZ-SC(4) 5,048.21 30.67 256.38 4,117.49 3,969.99 -1,754.61 -1,650.61 5,928,267.27 479,566.20 3.39 -2,178.80 MWD+IFR-AK-CAZ-SC(4) 5,140.73 29.15 262.10 4,197.70 4,050.20 -1,763.27 -1,695.87 5,928,258.72 479,520.91 3.49 -2,201.02 MWD+IFR-AK-CAZ-SC(4) 5,234.08 27.93 266.68 4,279.71 4,132.21 -1,767.66 -1,740.22 5,928,254.44 479,476.56 2.68 -2,218.90 MWD+IFR-AK-CAZ-SC(4) 5,327.06 26.50 271.02 4,362.41 4,214.91 -1,768.55 -1,782.71 5,928,253.66 479,434.07 2.63 -2,232.88 MWD+IFR-AK-CAZ-SC(4) 5,419.24 26.54 275.28 4,444.89 4,297.39 -1,766.29 -1,823.78 5,928,256.02 479,393.01 2.06 -2,243.42 MWD+IFR-AK-CAZ-SC(4) 5,513.02 26.04 281.19 4,528.99 4,381.49 -1,760.36 -1,864.85 5,928,262.05 479,351.97 2.84 -2,250.47 MWD+IFR-AK-CAZ-SC(4) 5,606.43 26.56 286.86 4,612.74 4,465.24 -1,750.33 -1,904.95 5,928,272.18 479,311.89 2.75 -2,253.32 MWD+IFR-AK-CAZ-SC(4) 5,699.36 27.79 293.84 4,695.43 4,547.93 -1,735.54 -1,944.66 5,928,287.07 479,272.22 3.67 -2,251.53 MWD+IFR-AK-CAZ-SC(4) 5,792.34 28.43 302.34 4,777.48 4,629.98 -1,714.93 -1,983.20 5,928,307.77 479,233.73 4.36 -2,243.84 MWD+IFR-AK-CAZ-SC(4) 5,884.39 28.70 309.56 4,858.35 4,710.85 -1,689.12 -2,018.77 5,928,333.66 479,198.24 3.76 -2,230.29 MWD+IFR-AK-CAZ-SC(4) 5,977.79 29.61 314.67 4,939.93 4,792.43 -1,658.61 -2,052.47 5,928,364.25 479,164.61 2.84 -2,211.69 MWD+IFR-AK-CAZ-SC(4) 6,072.66 30.87 320.85 5,021.91 4,874.41 -1,623.25 -2,084.52 5,928,399.69 479,132.66 3.54 -2,187.96 MWD+IFR-AK-CAZ-SC(4) 6,165.55 32.00 327.23 5,101.18 4,953.68 -1,584.07 -2,112.89 5,928,438.94 479,104.38 3.78 -2,159.46 MWD+IFR-AK-CAZ-SC(4) 6,258.24 33.33 333.53 5,179.24 5,031.74 -1,540.60 -2,137.54 5,928,482.46 479,079.84 3.94 -2,125.74 MWD+IFR-AK-CAZ-SC(4) 6,350.42 34.72 337.96 5,255.64 5,108.14 -1,493.59 -2,158.69 5,928,529.52 479,058.82 3.08 -2,087.56 MWD+IFR-AK-CAZ-SC(4) 6,443.20 36.41 343.31 5,331.13 5,183.63 -1,442.71 -2,176.52 5,928,580.44 479,041.12 3.82 -2,044.68 MWD+IFR-AK-CAZ-SC(4) 6,536.63 37.96 346.32 5,405.57 5,258.07 -1,388.22 -2,191.28 5,928,634.96 479,026.49 2.56 -1,997.42 MWD+IFR-AK-CAZ-SC(4) 6,629.43 39.31 348.66 5,478.06 5,330.56 -1,331.66 -2,203.81 5,928,691.55 479,014.10 2.14 -1,947.50 MWD+IFR-AK-CAZ-SC(4) 6,723.45 42.58 350.05 5,549.07 5,401.57 -1,271.12 -2,215.16 5,928,752.12 479,002.90 3.61 -1,893.43 MWD+IFR-AK-CAZ-SC(4) 6,819.26 46.18 352.52 5,617.54 5,470.04 -1,204.89 -2,225.27 5,928,818.36 478,992.96 4.17 -1,833.57 MWD+IFR-AK-CAZ-SC(4) 6,912.82 48.15 351.82 5,681.15 5,533.65 -1,136.93 -2,234.62 5,928,886.34 478,983.78 2.18 -1,771.82 MWD+IFR-AK-CAZ-SC(4) 7,008.39 49.84 353.41 5,743.86 5,596.36 -1,065.41 -2,243.88 5,928,957.87 478,974.70 2.17 -1,706.66 MWD+IFR-AK-CAZ-SC(4) 7,103.40 51.32 354.31 5,804.19 5,656.69 -992.44 -2,251.72 5,929,030.86 478,967.04 1.72 -1,639.68 MWD+IFR-AK-CAZ-SC(4) 7,199.44 53.25 356.24 5,862.94 5,715.44 -916.73 -2,257.96 5,929,106.57 478,960.99 2.56 -1,569.61 MWD+IFR-AK-CAZ-SC(4) 7,295.02 55.93 359.36 5,918.32 5,770.82 -838.91 -2,260.92 5,929,184.39 478,958.23 3.86 -1,496.51 MWD+IFR-AK-CAZ-SC(4) 7,390.99 58.61 3.49 5,970.22 5,822.72 -758.24 -2,258.87 5,929,265.05 478,960.48 4.57 -1,419.16 MWD+IFR-AK-CAZ-SC(4) 7,486.96 59.93 6.23 6,019.27 5,871.77 -676.06 -2,251.87 5,929,347.21 478,967.68 2.81 -1,338.83 MWD+IFR-AK-CAZ-SC(4) 7,582.65 61.84 7.68 6,065.83 5,918.33 -593.08 -2,241.73 5,929,430.15 478,978.02 2.40 -1,256.79 MWD+IFR-AK-CAZ-SC(4) 7,676.97 64.73 9.33 6,108.23 5,960.73 -509.77 -2,229.26 5,929,513.42 478,990.70 3.44 -1,173.70 MWD+IFR-AK-CAZ-SC(4) 7,773.60 67.84 9.94 6,147.09 5,999.59 -422.56 -2,214.45 5,929,600.58 479,005.73 3.27 -1,086.18 MWD+IFR-AK-CAZ-SC(4) 11/412015 9:39:08AM Page 4 COMPASS 5000.1 Build 74 . . • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-04 Project: Kuparuk River Unit TVD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Well: 2S-04 North Reference: True Wellbore: 2S-04 Survey Calculation Method: Minimum Curvature Design: 2S-04 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,825.68 70.41 11.42 6,165.64 6,018.14 -374.75 -2,205.43 5,929,648.37 479,014.87 5.60 -1,037.92 MWD+IFR-AK-CAZ-SC(4) 7,836.01 70.89 11.42 6,169.07 6,021.57 -365.19 -2,203.50 5,929,657.92 479,016.82 4.65 -1,028.24 INC+TREND(5) 7,886.00 72.13 11.88 6,184.92 6,037.42 -318.76 -2,193.92 5,929,704.32 479,026.51 2.62 -981.12 MWD+IFR-AK-CAZ-SC(6) 7-5/8"x 9-7/8" 7,930.59 73.23 12.28 6,198.20 6,050.70 -277.14 -2,185.02 5,929,745.92 479,035.52 2.62 -938.78 MWD+IFR-AK-CAZ-SC(6) 8,023.06 75.54 13.47 6,223.09 6,075.59 -190.33 -2,165.17 5,929,832.67 479,055.58 2.79 -850.09 MWD+IFR-AK-CAZ-SC(6) 8,117.89 78.25 11.95 6,244.59 6,097.09 -100.24 -2,144.86 5,929,922.69 479,076.11 3.26 -758.13 MWD+IFR-AK-CAZ-SC(6) 8,213.29 81.93 15.59 6,261.01 6,113.51 -9.00 -2,122.48 5,930,013.87 479,098.72 5.39 -664.44 MWD+IFR-AK-CAZ-SC(6) 8,306.79 84.03 18.25 6,272.44 6,124.94 79.77 -2,095.47 5,930,102.56 479,125.94 3.61 -571.67 MWD+IFR-AK-CAZ-SC(6) 8,400.93 82.63 20.01 6,283.37 6,135.87 168.10 -2,064.83 5,930,190.81 479,156.80 2.38 -478.20 MWD+IFR-AK-CAZ-SC(6) 8,496.09 82.81 18.44 6,295.43 6,147.93 257.23 -2,033.75 5,930,279.85 479,188.10 1.65 -383.83 MWD+IFR-AK-CAZ-SC(6) 8,590.73 83.65 19.01 6,306.59 6,159.09 346.23 -2,003.58 5,930,368.77 479,218.48 1.07 -289.86 MWD+IFR-AK-CAZ-SC(6) 8,685.73 87.52 17.02 6,313.90 6,166.40 436.28 -1,974.30 5,930,458.74 479,247.99 4.58 -195.16 MWD+IFR-AK-CAZ-SC(6) 8,779.52 91.96 15.61 6,314.33 6,166.83 526.27 -1,947.96 5,930,548.65 479,274.55 4.97 -101.44 MWD+IFR-AK-CAZ-SC(6) 8,873.58 92.94 17.04 6,310.31 6,162.81 616.45 -1,921.55 5,930,638.76 479,301.18 1.84 -7.51 MWD+IFR-AK-CAZ-SC(6) 8,968.74 94.80 19.10 6,303.88 6,156.38 706.71 -1,892.10 5,930,728.93 479,330.85 2.91 87.42 MWD+IFR-AK-CAZ-SC(6) 9,063.38 95.93 18.58 6,295.03 6,147.53 795.88 -1,861.68 5,930,818.02 479,361.50 1.31 181.64 MWD+IFR-AK-CAZ-SC(6) 9,157.20 94.70 18.81 6,286.34 6,138.84 884.37 -1,831.73 5,930,906.42 479,391.66 1.33 275.05 MWD+IFR-AK-CAZ-SC(6) 9,251.96 92.77 17.91 6,280.17 6,132.67 974.11 -1,801.95 5,930,996.08 479,421.66 2.25 369.60 MWD+IFR-AK-CAZ-SC(6) 9,348.85 91.54 15.94 6,276.53 6,129.03 1,066.73 -1,773.77 5,931,088.62 479,450.07 2.40 466.40 MWD+IFR-AK-CAZ-SC(6) 9,441.70 89.75 17.00 6,275.48 6,127.98 1,155.76 -1,747.45 5,931,177.58 479,476.61 2.24 559.20 MWD+IFR-AK-CAZ-SC(6) 9,536.76 89.22 18.83 6,276.34 6,128.84 1,246.20 -1,718.21 5,931,267.94 479,506.07 2.00 654.25 MWD+IFR-AK-CAZ-SC(6) 9,631.22 90.85 20.79 6,276.28 6,128.78 1,335.06 -1,686.20 5,931,356.71 479,538.30 2.70 748.66 MWD+IFR-AK-CAZ-SC(6) 9,725.08 91.78 21.91 6,274.12 6,126.62 1,422.46 -1,652.04 5,931,444.01 479,572.67 1.55 842.33 MWD+IFR-AK-CAZ-SC(6) 9,819.77 92.29 21.14 6,270.76 6,123.26 1,510.49 -1,617.32 5,931,531.95 479,607.61 0.97 936.78 MWD+IFR-AK-CAZ-SC(6) 9,914.29 92.98 20.74 6,266.42 6,118.92 1,598.67 -1,583.57 5,931,620.04 479,641.57 0.84 1,031.08 MWD+IFR-AK-CAZ-SC(6) 10,007.93 93.95 23.06 6,260.76 6,113.26 1,685.39 -1,548.71 5,931,706.66 479,676.64 2.68 1,124.32 MWD+IFR-AK-CAZ-SC(6) 10,103.74 93.89 22.70 6,254.21 6,106.71 1,773.45 -1,511.55 5,931,794.62 479,714.02 0.38 1,219.56 MWD+IFR-AK-CAZ-SC(6) 10,197.05 91.91 21.34 6,249.49 6,101.99 1,859.84 -1,476.61 5,931,880.91. 479,749.17 2.57 1,312.51 MWD+IFR-AK-CAZ-SC(6) 10,290.76 89.24 19.20 6,248.55 6,101.05 1,947.73 -1,444.15 5,931,968.71 479,781.84 3.65 1,406.13 MWD+IFR-AK-CAZ-SC(6) 10,386.03 85.91 16.55 6,252.58 6,105.08 2,038.30 -1,414.94 5,932,059.20 479,811.27 4.47 1,501.29 MWD+IFR-AK-CAZ-SC(6) 10,480.31 86.96 16.47 6,258.44 6,110.94 2,128.51 -1,388.20 5,932,149.34 479,838.24 1.12 1,595.36 MWD+IFR-AK-CAZ-SC(6) 10,575.41 90.07 15.40 6,260.90 6,113.40 2,219.92 -1,362.10 5,932,240.67 479,864.56 3.46 1,690.35 MWD+IFR-AK-CAZ-SC(6) 10,669.02 89.95 15.08 6,260.89 6,113.39 2,310.23 -1,337.50 5,932,330.91 479,889.39 0.37 1,783.85 MWD+IFR-AK-CAZ-SC(6) 10,765.36 91.60 16.18 6,259.58 6,112.08 2,403.00 -1,311.55 5,932,423.60 479,915.57 2.06 1,880.10 MWD+IFR-AK-CAZ-SC(6) 10,858.51 92.65 16.43 6,256.13 6,108.63 2,492.34 -1,285.41 5,932,512.87 479,941.92 1.16 1,973.14 MWD+IFR-AK-CAZ-SC(6) 10,955.10 92.35 15.23 6,251.92 6,104.42 2,585.18 -1,259.09 5,932,605.63 479,968.47 1.28 2,069.57 MWD+IFR-AK-CAZ-SC(6) 11,049.82 89.44 14.47 6,250.44 6,102.94 2,676.71 -1,234.82 5,932,697.10 479,992.97 3.18 2,164.12 MWD+IFR-AK-CAZ-SC(6) 11,143.17 87.41 11.85 6,253.00 6,105.50 2,767.56 -1,213.58 5,932,787.89 480,014.43 3.55 2,257.09 MWD+IFR-AK-CAZ-SC(6) 11,237.78 91.20 10.43 6,254.15 6,106.65 2,860.36 -1,195.30 5,932,880.63 480,032.94 4.28 2,351.00 MWD+IFR-AK-CAZ-SC(6) 11/42015 9:39:08AM Page 5 COMPASS 5000.1 Build 74 • • . Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-04 Project: Kuparuk River Unit TVD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Well: 2S-04 North Reference: True Wellbore: 2S-04 Survey Calculation Method: Minimum Curvature Design: 2S-04 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Fasting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,332.11 89.96 11.14 6,253.20 6,105.70 2,953.02 -1,177.65 5,932,973.24 480,050.81 1.51 2,444.57 MWD+IFR-AK-CAZ-SC(6) 11,425.41 88.16 13.98 6,254.73 6,107.23 3,044.06 -1,157.37 5,933,064.22 480,071.32 3.60 2,537.43 MWD+IFR-AK-CAZ-SC(6) 11,520.84 88.04 15.35 6,257.89 6,110.39 3,136.33 -1,133.22 5,933,156.42 480,095.70 1.44 2,632.64 MWD+IFR-AK-CAZ-SC(6) 11,615.20 88.28 17.63 6,260.92 6,113.42 3,226.76 -1,106.46 5,933,246.77 480,122.69 2.43 2,726.91 MWD+IFR-AK-CAZ-SC(6) 11,710.79 89.24 20.52 6,262.99 6,115.49 3,317.07 -1,075.23 5,933,336.99 480,154.14 3.19 2,822.45 MWD+IFR-AK-CAZ-SC(6) 11,804.91 90.55 21.27 6,263.16 6,115.66 3,404.99 -1,041.66 5,933,424.83 480,187.92 1.60 2,916.45 MWD+IFR-AK-CAZ-SC(6) 11,898.63 90.71 19.66 6,262.13 6,114.63 3,492.79 -1,008.89 5,933,512.53 480,220.90 1.73 3,010.08 MWD+IFR-AK-CAZ-SC(6) 11,994.43 91.60 19.74 6,260.20 6,112.70 3,582.96 -976.61 5,933,602.62 480,253.41 0.93 3,105.81 MWD+IFR-AK-CAZ-SC(6) 12,087.51 92.24 19.82 6,257.08 6,109.58 3,670.50 -945.13 5,933,690.07 480,285.10 0.69 3,198.79 MWD+IFR-AK-CAZ-SC(6) 12,182.24 91.26 18.91 6,254.19 6,106.69 3,759.83 -913.73 5,933,779.31 480,316.72 1.41 3,293.45 MWD+IFR-AK-CAZ-SC(6) 12,278.29 91.64 24.18 6,251.76 6,104.26 3,849.11 -878.48 5,933,868.49 480,352.18 5.50 3,389.25 MWD+IFR-AK-CAZ-SC(6) 12,328.82 92.02 23.57 6,250.14 6,102.64 3,895.29 -858.04 5,933,914.62 480,372.74 1.42 3,439.49 MWD+IFR-AK-CAZ-SC(6) 12,372.32 92.77 24.01 6,248.33 6,100.83 3,935.06 -840.51 5,933,954.34 480,390.37 2.00 3,482.73 MWD+IFR-AK-CAZ-SC(6) 12,466.67 91.78 24.86 6,244.58 6,097.08 4,020.89 -801.51 5,934,040.06 480,429.57 1.38 3,576.41 MWD+IFR-AK-CAZ-SC(6) 12,561.30 90.19 23.56 6,242.95 6,095.45 4,107.18 -762.71 5,934,126.24 480,468.58 2.17 3,670.47 MWD+IFR-AK-CAZ-SC(6) 12,656.17 90.44 20.66 6,242.43 6,094.93 4,195.06 -727.01 5,934,214.03 480,504.50 3.07 3,765.08 MWD+IFR-AK-CAZ-SC(6) 12,751.22 90.45 13.11 6,241.69 6,094.19 4,285.95 -699.42 5,934,304.83 480,532.31 7.94 3,860.04 MWD+IFR-AK-CAZ-SC(6) 12,845.85 90.58 15.87 6,240.84 6,093.34 4,377.55 -675.75 5,934,396.37 480,556.21 2.92 3,954.48 MWD+IFR-AK-CAZ-SC(6) 12,935.20 90.40 15.86 6,240.08 6,092.58 4,463.50 -651.33 5,934,482.25 480,580.85 0.20 4,043.77 MWD+IFR-AK-CAZ-SC(6) 13,033.35 90.27 16.27 6,239.50 6,092.00 4,557.81 -624.17 5,934,576.49 480,608.24 0.44 4,141.86 MWD+IFR-AK-CAZ-SC(6) 13,127.01 91.49 16.88 6,238.07 6,090.57 4,647.57 -597.45 5,934,666.17 480,635.17 1.46 4,235.48 MWD+IFR-AK-CAZ-SC(6) 13,220.65 90.97 19.01 6,236.06 6,088.56 4,736.63 -568.61 5,934,755.14 480,664.23 2.34 4,329.09 MWD+IFR-AK-CAZ-SC(6) 13,317.85 88.48 20.08 6,236.52 6,089.02 4,828.21 -536.09 5,934,846.64 480,696.97 2.79 4,426.24 MWD+IFR-AK-CAZ-SC(6) 13,411.95 90.57 24.34 6,237.30 6,089.80 4,915.30 -500.53 5,934,933.64 480,732.75 5.04 4,520.06 MWD+IFR-AK-CAZ-SC(6) 13,476.00 90.57 24.34 6,236.67 6,089.17 4,973.66 -474.14 5,934,991.92 480,759.29 0.00 4,583.71 PROJECTED to TD 4 112"x 6-3/4" 13,505.00 90.57 24.34 6,236.38 6,088.88 5,000.08 -462.19 5,935,018.31 480,771.30 0.00 4,612.54 PROJECTED to TD Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. 2Yes 0 No I have checked to the best of ray ability that the following data is correct: 2 Surface Coordinates n Declination & Convergence GRS Survey Corrections Survey Tool Codes w,M„g,,,NNom.Ow„ Vincent Osara amt Dm 3m SLB DE: Dana.1511.16-0....120 Client Representative: Mike Callahan'` `.' Date: 03-Nov-2015 11/4/2015 9:39:08AM Page 6 COMPASS 5000.1 Build 74 1 • NADConversion Kuparuk River Unit Kuparuk 2S Pad 2S-04PB1 Definitive Survey Report 14 October, 2015 NAD 27 Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-04 Project: Kuparuk River Unit TVD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Well: 2S-04 North Reference: True Wellbore: 2S-04PB1 Survey Calculation Method: Minimum Curvature Design: 2S-04PB1 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2S-04 Well Position +N/-S 0.00 usft Northing: 5,930,017.59 usfl Latitude: 70°13'11.873 N +El-W 0.00 usft Easting: 481,221.00 usfl Longitude: 150°9'5.394 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 120.00 usft Wellbore 2S-04PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 9/30/2015 18.56 80.87 57,488 Design 2S-04PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.50 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 27.50 0.00 0.00 18.00 Survey Program Date 10/14/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 78.00 447.00 2S-04PB1 Srvy#1-GYD-GC-SS(2S-04 GYD-GC-SS Gyrodata gyro single shots 9/21/2015 8:5: 476.76 2,755.06 2S-04PB1 Srvy#2-MWD+IFR-AK-CAZ-MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/21/2015 9:1 2,785.43 2,785.43 2S-04PB1 Srvy#3-INC+TREND(2S-04 INC+TREND Inclinometer+known azi trend 9/28/2015 8:31 2,881.48 7,729.43 2S-04PB1 Srvy#4-MWD+IFR-AK-CAZ-MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/28/2015 8:3 7,800.00 7,800.00 2S-04PB1 Srvy#5-Projection to TD(2S BLIND Blind drilling 10/13/2015 1:: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 27.50 0.00 0.00 27.50 -120.00 0.00 0.00 5,930,017.59 481,221.00 0.00 0.00 UNDEFINED 78.00 0.30 241.15 78.00 -69.50 -0.06 -0.12 5,930,017.53 481,220.88 0.59 -0.10 GYD-GC-SS(1) 170.00 0.45 266.98 170.00 22.50 -0.20 -0.69 5,930,017.39 481,220.31 0.24 -0.40 GYD-GC-SS(1) 263.00 0.52 264.61 262.99 115.49 -0.26 -1.47 5,930,017.34 481,219.53 0.08 -0.70 GYD-GC-SS(1) 355.00 0.64 262.29 354.99 207.49 -0.37 -2.40 5,930,017.23 481,218.60 0.13 -1.09 GYD-GC-SS(1) 447.00 0.58 275.81 446.98 299.48 -0.39 -3.37 5,930,017.21 481,217.63 0.17 -1.41 GYD-GC-SS(1) 476.76 0.31 285.28 476.74 329.24 -0.35 -3.60 5,930,017.25 481,217.40 0.94 -1.45 MWD+IFR-AK-CAZ-SC(2) 567.94 0.04 243.25 567.92 420.42 -0.30 -3.86 5,930,017.30 481,217.14 0.31 -1.48 MWD+IFR-AK-CAZ-SC(2) 660.98 1.43 217.97 660.95 513.45 -1.23 -4.61 5,930,016.37 481,216.39 1.50 -2.59 MWD+IFR-AK-CAZ-SC(2) 696.02 2.12 219.06 695.98 548.48 -2.08 -5.28 5,930,015.52 481,215.71 1.97 -3.61 MWD+IFR-AK-CAZ-SC(2) 10/14/2015 1:14:46PM Page 2 COMPASS 5000.1 Build 74 • •• . Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-04 Project: Kuparuk River Unit ND Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Well: 2S-04 North Reference: True Wellbore: 2S-04PB1 Survey Calculation Method: Minimum Curvature Design: 2S-04PB1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi ND TVDSS +NI-S +EI-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 757.33 2.58 214.47 757.23 609.73 -4.10 -6.78 5,930,013.51 481,214.21 0.81 -5.99 MWD+IFR-AK-CAZ-SC(2) 853.64 3.59 211.81 853.40 705.90 -8.45 -9.60 5,930,009.17 481,211.38 1.06 -11.00 MWD+IFR-AK-CAZ-SC(2) 948.89 4.60 201.35 948.41 800.91 -14.54 -12.56 5,930,003.08 481,208.41 1.31 -17.71 MWD+IFR-AK-CAZ-SC(2) 1,045.12 7.88 197.52 1,044.06 896.56 -24.43 -15.95 5,929,993.21 481,204.99 3.43 -28.16 MWD+IFR-AK-CAZ-SC(2) 1,140.42 10.66 202.74 1,138.11 990.61 -38.79 -21.33 5,929,978.86 481,199.58 3.04 -43.48 MWD+IFR-AK-CAZ-SC(2) 1,237.11 13.56 204.84 1,232.63 1,085.13 -57.33 -29.55 5,929,960.34 481,191.31 3.03 -63.65 MWD+IFR-AK-CAZ-SC(2) 1,332.94 17.82 206.38 1,324.87 1,177.37 -80.67 -40.79 5,929,937.03 481,180.02 4.47 -89.32 MWD+IFR-AK-CAZ-SC(2) 1,428.89 20.05 207.90 1,415.63 1,268.13 -108.36 -55.01 5,929,909.38 481,165.73 2.38 -120.05 MWD+IFR-AK-CAZ-SC(2) 1,525.28 19.63 209.48 1,506.29 1,358.79 -137.06 -70.71 5,929,880.72 481,149.96 0.71 -152.20 MWD+IFR-AK-CAZ-SC(2) 1,621.34 21.86 208.07 1,596.12 1,448.62 -166.89 -87.06 5,929,850.94 481,133.53 2.38 -185.62 MWD+IFR-AK-CAZ-SC(2) 1,715.89 22.82 207.21 1,683.57 1,536.07 -198.73 -103.73 5,929,819.14 481,116.78 1.07 -221.06 MWD+IFR-AK-CAZ-SC(2) 1,811.64 25.43 208.33 1,770.95 1,623.45 -233.34 -121.98 5,929,784.58 481,098.45 2.77 -259.61 MWD+IFR-AK-CAZ-SC(2) 1,909.25 28.51 211.22 1,857.94 1,710.44 -271.72 -144.01 5,929,746.26 481,076.33 3.43 -302.92 MWD+IFR-AK-CAZ-SC(2) 2,003.73 29.77 212.20 1,940.46 1,792.96 -310.85 -168.19 5,929,707.19 481,052.05 1.43 -347.61 MWD+IFR-AK-CAZ-SC(2) 2,098.75 32.65 215.49 2,021.73 1,874.23 -351.70 -195.65 5,929,666.42 481,024.49 3.52 -394.94 MWD+IFR-AK-CAZ-SC(2) 2,195.36 35.25 219.32 2,101.87 1,954.37 -394.50 -228.46 5,929,623.70 480,991.58 3.48 -445.79 MWD+IFR-AK-CAZ-SC(2) 2,290.95 38.19 223.06 2,178.49 2,030.99 -437.44 -266.13 5,929,580.86 480,953.81 3.86 -498.27 MWD+IFR-AK-CAZ-SC(2) 2,387.10 40.65 224.33 2,252.77 2,105.27 -481.57 -308.31 5,929,536.84 480,911.52 2.69 -553.27 MWD+IFR-AK-CAZ-SC(2) 2,483.15 44.04 225.78 2,323.75 2,176.25 -527.25 -354.11 5,929,491.28 480,865.61 3.67 -610.87 MWD+IFR-AK-CAZ-SC(2) 2,547.93 43.50 225.21 2,370.53 2,223.03 -558.66 -386.07 5,929,459.95 480,833.58 1.03 -650.62 MWD+IFR-AK-CAZ-SC(2) 2,579.52 43.26 226.72 2,393.49 2,245.99 -573.74 -401.67 5,929,444.91 480,817.94 3.37 -669.78 MWD+IFR-AK-CAZ-SC(2) 2,675.03 44.34 227.55 2,462.42 2,314.92 -618.70 -450.13 5,929,400.07 480,769.38 1.28 -727.52 MWD+IFR-AK-CAZ-SC(2) 2,755.06 44.33 227.28 2,519.67 2,372.17 -656.55 -491.31 5,929,362.33 480,728.11 0.24 -776.24 MWD+IFR-AK-CAZ-SC(2) 2,785.43 44.48 227.79 2,541.36 2,393.86 -670.90 -506.98 5,929,348.02 480,712.40 1.27 -794.73 INC+TREND(3) 2,815.00 44.50 227.32 2,562.46 2,414.96 -684.88 -522.27 5,929,334.08 480,697.08 1.12 -812.75 NOT an Actual Survey 10314"x131/2" 2,881.48 44.55 226.26 2,609.85 2,462.35 -716.80 -556.25 5,929,302.25 480,663.03 1.12 -853.61 MWD+IFR-AK-CAZ-SC(4) 2,977.31 44.60 226.74 2,678.12 2,530.62 -763.10 -605.03 5,929,256.08 480,614.13 0.36 -912.71 MWD+IFR-AK-CAZ-SC(4) 3,071.57 44.65 227.98 2,745.21 2,597.71 -807.95 -653.74 5,929,211.35 480,565.32 0.93 -970.42 MWD+IFR-AK-CAZ-SC(4) 3,168.67 44.66 229.23 2,814.28 2,666.78 -853.07 -704.94 5,929,166.36 480,514.01 0.90 -1,029.16 MWD+IFR-AK-CAZ-SC(4) 3,263.71 44.66 230.63 2,881.88 2,734.38 -896.07 -756.05 5,929,123.49 480,462.79 1.04 -1,085.85 MWD+IFR-AK-CAZ-SC(4) 3,361.00 44.66 231.90 2,951.09 2,803.59 -938.86 -809.40 5,929,080.84 480,409.35 0.92 -1,143.03 MWD+IFR-AK-CAZ-SC(4) 3,456.24 44.48 228.26 3,018.94 2,871.44 -981.73 -860.64 5,929,038.10 480,358.00 2.69 -1,199.64 MWD+IFR-AK-CAZ-SC(4) 3,552.55 44.55 226.29 3,087.62 2,940.12 -1,027.54 -910.24 5,928,992.42 480,308.30 1.44 -1,258.53 MWD+IFR-AK-CAZ-SC(4) 3,647.60 44.54 226.21 3,155.37 3,007.87 -1,073.65 -958.40 5,928,946.44 480,260.02 0.06 -1,317.26 MWD+IFR-AK-CAZ-SC(4) 3,743.62 44.62 227.00 3,223.76 3,076.26 -1,119.95 -1,007.37 5,928,900.26 480,210.94 0.58 -1,376.43 MWD+IFR-AK-CAZ-SC(4) 3,839.54 44.49 225.94 3,292.11 3,144.61 -1,166.30 -1,056.17 5,928,854.04 480,162.04 0.79 -1,435.59 MWD+IFR-AK-CAZ-SC(4) 3,935.56 44.45 224.70 3,360.63 3,213.13 -1,213.59 -1,103.99 5,928,806.87 480,114.10 0.91 -1,495.35 MWD+IFR-AK-CAZ-SC(4) 4,031.01 44.58 224.94 3,428.69 3,281.19 -1,261.06 -1,151.16 5,928,759.52 480,066.82 0.22 -1,555.07 MWD+IFR-AK-CAZ-SC(4) 4,126.56 44.57 225.31 3,496.76 3,349.26 -1,308.38 -1,198.69 5,928,712.33 480,019.18 0.27 -1,614.75 MWD+IFR-AK-CAZ-SC(4) 4,223.26 40.97 229.06 3,567.74 3,420.24 -1,353.04 -1,246.78 5,928,667.80 479,970.98 4.56 -1,672.09 MWD+IFR-AK-CAZ-SC(4) 10/14/2015 1:14:46PM Page 3 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-04 Project: Kuparuk River Unit TVD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Well: 2S-04 North Reference: True Wellbore: 2S-04PB1 Survey Calculation Method: Minimum Curvature Design: 2S-04PB1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,318.98 37.39 232.33 3,641.94 3,494.44 -1,391.37 -1,293.51 5,928,629.58 479,924.16 4.32 -1,722.99 MWD+IFR-AK-CAZ-SC(4) 4,415.63 35.48 236.70 3,719.71 3,572.21 -1,424.72 -1,340.19 5,928,596.36 479,877.40 3.33 -1,769.13 MWD+IFR-AK-CAZ-SC(4) 4,511.12 33.51 239.67 3,798.41 3,650.91 -1,453.25 -1,386.11 5,928,567.94 479,831.42 2.71 -1,810.45 MWD+IFR-AK-CAZ-SC(4) 4,606.71 31.82 244.45 3,878.89 3,731.39 -1,477.45 -1,431.63 5,928,543.86 479,785.84 3.23 -1,847.53 MWD+IFR-AK-CAZ-SC(4) 4,702.88 30.21 250.19 3,961.33 3,813.83 -1,496.59 -1,477.28 5,928,524.83 479,740.14 3.50 -1,879.84 MWD+IFR-AK-CAZ-SC(4) 4,798.41 28.48 255.89 4,044.61 3,897.11 -1,510.29 -1,522.00 5,928,511.25 479,695.40 3.44 -1,906.69 MWD+IFR-AK-CAZ-SC(4) 4,891.71 26.73 261.96 4,127.31 3,979.81 -1,518.65 -1,564.36 5,928,502.99 479,653.02 3.55 -1,927.73 MWD+IFR-AK-CAZ-SC(4) 4,987.74 25.09 266.69 4,213.69 4,066.19 -1,522.84 -1,606.08 5,928,498.90 479,611.30 2.75 -1,944.62 MWD+IFR-AK-CAZ-SC(4) 5,083.19 23.95 268.43 4,300.53 4,153.03 -1,524.54 -1,645.65 5,928,497.30 479,571.73 1.41 -1,958.46 MWD+IFR-AK-CAZ-SC(4) 5,179.21 23.78 271.10 4,388.34 4,240.84 -1,524.71 -1,684.49 5,928,497.23 479,532.89 1.14 -1,970.62 MWD+IFR-AK-CAZ-SC(4) 5,276.11 24.10 276.78 4,476.92 4,329.42 -1,521.99 -1,723.67 5,928,500.04 479,493.72 2.40 -1,980.15 MWD+IFR-AK-CAZ-SC(4) 5,371.57 23.37 280.19 4,564.31 4,416.81 -1,516.34 -1,761.66 5,928,505.79 479,455.75 1.63 -1,986.51 MWD+IFR-AK-CAZ-SC(4) 5,468.54 23.90 288.47 4,653.17 4,505.67 -1,506.72 -1,799.23 5,928,515.51 479,418.20 3.46 -1,988.96 MWD+IFR-AK-CAZ-SC(4) 5,562.91 24.43 296.81 4,739.29 4,591.79 -1,491.85 -1,834.79 5,928,530.46 479,382.69 3.66 -1,985.82 MWD+IFR-AK-CAZ-SC(4) 5,658.75 24.32 305.65 4,826.62 4,679.12 -1,471.40 -1,868.53 5,928,550.99 479,349.00 3.81 -1,976.80 MWD+IFR-AK-CAZ-SC(4) 5,754.18 25.57 314.22 4,913.18 4,765.68 -1,445.58 -1,899.27 5,928,576.88 479,318.33 4.00 -1,961.73 MWD+IFR-AK-CAZ-SC(4) 5,850.08 28.10 321.16 4,998.76 4,851.26 -1,413.54 -1,928.27 5,928,608.99 479,289.41 4.20 -1,940.23 MWD+IFR-AK-CAZ-SC(4) 5,946.05 30.04 326.69 5,082.65 4,935.15 -1,375.85 -1,955.65 5,928,646.75 479,262.13 3.45 -1,912.84 MWD+IFR-AK-CAZ-SC(4) 6,041.42 32.15 331.02 5,164.33 5,016.83 -1,333.69 -1,981.06 5,928,688.96 479,236.83 3.22 -1,880.60 MWD+IFR-AK-CAZ-SC(4) 6,137.35 33.87 335.80 5,244.78 5,097.28 -1,286.97 -2,004.39 5,928,735.74 479,213.62 3.25 -1,843.37 MWD+IFR-AK-CAZ-SC(4) 6,233.12 35.40 340.82 5,323.59 5,176.09 -1,236.42 -2,024.45 5,928,786.34 479,193.69 3.38 -1,801.49 MWD+IFR-AK-CAZ-SC(4) 6,328.67 36.73 342.85 5,400.83 5,253.33 -1,182.97 -2,041.97 5,928,839.82 479,176.30 1.87 -1,756.08 MWD+IFR-AK-CAZ-SC(4) 6,425.03 37.33 345.47 5,477.76 5,330.26 -1,127.15 -2,057.79 5,928,895.67 479,160.61 1.75 -1,707.88 MWD+IFR-AK-CAZ-SC(4) 6,521.61 39.51 347.41 5,553.43 5,405.93 -1,068.81 -2,071.84 5,928,954.04 479,146.72 2.58 -1,656.74 MWD+IFR-AK-CAZ-SC(4) 6,617.13 42.16 349.65 5,625.70 5,478.20 -1,007.61 -2,084.22 5,929,015.27 479,134.48 3.17 -1,602.35 MWD+IFR-AK-CAZ-SC(4) 6,713.19 44.54 350.61 5,695.55 5,548.05 -942.65 -2,095.51 5,929,080.25 479,123.36 2.57 -1,544.06 MWD+IFR-AK-CAZ-SC(4) 6,809.07 48.08 352.73 5,761.77 5,614.27 -874.06 -2,105.52 5,929,148.85 479,113.52 4.02 -1,481.93 MWD+IFR-AK-CAZ-SC(4) 6,903.59 51.65 355.00 5,822.69 5,675.19 -802.23 -2,113.20 5,929,220.70 479,106.02 4.20 -1,415.98 MWD+IFR-AK-CAZ-SC(4) 7,000.64 54.62 357.07 5,880.91 5,733.41 -724.79 -2,118.54 5,929,298.15 479,100.87 3.50 -1,343.98 MWD+IFR-AK-CAZ-SC(4) 7,096.65 57.93 0.79 5,934.22 5,786.72 -644.98 -2,119.98 5,929,377.95 479,099.63 4.72 -1,268.52 MWD+IFR-AK-CAZ-SC(4) 7,191.66 60.72 4.50 5,982.70 5,835.20 -563.38 -2,116.17 5,929,459.53 479,103.64 4.46 -1,189.74 MWD+IFR-AK-CAZ-SC(4) 7,287.73 61.75 6.28 6,028.93 5,881.43 -479.55 -2,108.26 5,929,543.34 479,111.77 1.95 -1,107.56 MWD+IFR-AK-CAZ-SC(4) 7,364.26 62.00 7.94 6,065.01 5,917.51 -412.58 -2,099.90 5,929,610.28 479,120.29 1.94 -1,041.29 MWD+IFR-AK-CAZ-SC(4) 7,383.13 62.47 7.85 6,073.80 5,926.30 -396.04 -2,097.61 5,929,626.81 479,122.62 2.53 -1,024.85 MWD+IFR-AK-CAZ-SC(4) 7,439.43 63.75 9.08 6,099.27 5,951.77 -346.37 -2,090.22 5,929,676.45 479,130.14 2.99 -975.33 MWD+IFR-AK-CAZ-SC(4) 7,479.98 63.87 9.01 6,117.16 5,969.66 -310.44 -2,084.50 5,929,712.37 479,135.95 0.33 -939.39 MWD+IFR-AK-CAZ-SC(4) 7,575.45 65.10 10.69 6,158.29 6,010.79 -225.56 -2,069.75 5,929,797.20 479,150.90 2.04 -854.11 MWD+IFR-AK-CAZ-SC(4) 7,669.77 67.56 12.72 6,196.15 6,048.65 -140.98 -2,052.21 5,929,881.73 479,168.65 3.27 -768.25 MWD+IFR-AK-CAZ-SC(4) 7,729.43 70.09 14.00 6,217.70 6,070.20 -86.87 -2,039.36 5,929,935.81 479,181.64 4.69 -712.81 MWD+IFR-AK-CAZ-SC (4) 7,800.00 72.50 15.00 6,240.33 6,092.83 -22.16 -2,022.62 5,930,000.47 479,198.54 3.67 -646.10 Projected to TD 10/14/2015 1:14:46PM Page 4 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Final Definitive Survey Verified and Signed-off Al!targets and/or well position objectives have been achieved. P1 Yes ❑ No I have checked to the best of my ability that the following data is correct: Cid Surface Coordinates R Deppcclination & Convergence GRS L"J Survey Corrections plgltaltYsh]ne.3bY:'t:1[zntOsar_ El Survey Tool Codes Vincent =cn=vincent0Eara, o=Schlumberger, ou=Schlumbeger, DSdra 17sSLB DE: ve20510.1423054 oo• o r�=6„,�.�,6, Okm GIEvt,e:[imeNntp.wL Mike Callahana.;, =,-Ir Client Representative: Ptlr'.MMIC 'I,,4.0 47 411 .11111 Date: 14-Oct-2015 10/14/2015 1:14:46PM Page 5 COMPASS 5000.1 Build 74 • • • Cement Detail Report 011 2S-04 conocovhillips String: Surface Casing Cement Job: DRILLING ORIGINAL, 9/17/2015 06:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 9/21/2015 11:15 9/21/2015 14:51 2S-04 Comment Pump 5 bbls of CW-100&PT lines to 1600/4000 psi.Continue pumping 8.35 ppg CW-100 for a total of 74.9 bbls,4.8 bpm, 150 psi. Pump 75 bbls of 10.5 ppg MPII w/red dye at 4.5 bpm,200 psi. Drop bottom plug&pump 405 bbls of 11.0 ppg Lead Cement at 5.5 bpm, 175-315 psi. Pump 66 bbls of 12.0 ppg Tail Cement at 5.5 bpm,230 psi. Drop top plug&kick out with 10 bbls of fresh H2O at 6 bpm, 170 psi.Swap to rig&displace cement with 9.7 ppg mud at 8 bpm, 550 psi. Bump plug w/250.1 bbls, pressure up to 1111 psi&hold for 5 min. Check floats,good. CIP at 14:51 hrs.Total of 51 bbls of cement returns to surface. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Surface Casing Cement 30.3 2,825.0 No 51.0 Yes Yes Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 6 3 6 525.0 1,100.0 Yes 10.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Pump 5 bbls of CW-100&PT lines to 1600/4000 psi.Continue pumping 8.35 ppg CW-100 for a total of 74.9 bbls,4.8 bpm, 150 psi. Pump 75 bbls of 10.5 ppg MPH w/red dye at 4.5 bpm,200 psi. Drop bottom plug&pump 405 bbls of 11.0 ppg Lead Cement at 5.5 bpm, 175-315 psi. Pump 66 bbls of 12.0 ppg Tail Cement at 5.5 bpm,230 psi. Drop top plug&kick out with 10 bbls of fresh H2O at 6 bpm, 170 psi. Swap to rig&displace cement with 9.7 ppg mud at 8 bpm, 550 psi. Bump plug w/250.1 bbls, pressure up to 1111 psi&hold for 5 min. Check floats,good.CIP at 14:51 hrs.Total of 51 bbls of cement returns to surface. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 30.3 2,315.0 1,513 LiteCRETE 504.0 Yield(ft'/sack) Mix 1-120 Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.87 6.42 11.00 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOB Additive Type Concentration Conc Unit label Dispersant D185 0.07 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 2,315.0 2,825.0 230 LiteCRETE 66.3 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.62 5.38 12.00 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOB Additive Type Concentration Conc Unit label Retarder D177 0.07 gal/sx Additive Type Concentration Conc Unit label Dispersant D185 0.01 gal/sx Page 1/1 Report Printed: 12/2/2015 • • • • WEmig Cement Detail Report eds 2S-04 C.onocoPhititps String: Intermediate Casing Cement Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 10/18/2015 15:30 10/18/2015 20:45 2S-04 Comment 1st Stage Pump 5 bbls of H2O&test lines 350/4000 psi for 5 min. Pump 40 bbls of 12 ppg MudPush 2 @ 5 bpm,650 psi. Drop bottom plug. Pump 95 bbls of 16 ppg tail cement w/1 ppb Cemnet @ 4.5 bpm,650 psi. Drop top plug. Pump 10 bbls of H2O. Displace with rig pump @ 5 bpm,200 psi. Observed 500 psi lift pressure. Bump plug&hold 1200 psi for 5 min.Check floats,good.CIP @ 17:51 hrs. 2nd Stage Pump 40 bbls of 12 ppg MudPush 2 @ 5 bpm,350 psi. Batch up cement. Pump 42 bbls of 16 ppg tail cement w/Cemnet @ 3.5 bpm, 150 psi. Drop closing plug. Pump 10 bbls of H2O. Displace with rig pump @ 5 bpm, 175 psi.Slow pump to 3 bpm,450 psi, Bump plug w/1200 psi.Observe collar to shift closed at 1600 psi.Pressure up to 1700 psi&hold for 5 min.Verified stage collar was closed,good.CIP @ 20.13 hrs. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Casing 6,761.0 7,896.0 No Yes Yes Cement Q Pump Init(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 3 4 5 677.0 717.0 Yes 10.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment PJSM;pump 5 bbls of H2O&test lines 350/4000 psi for 5 min. Pump 40 bbls of 12 ppg MudPush 2 @ 5 bpm,650 psi. Drop bottom plug. Pump 95 bbls of 16 ppg tail cement w/1 ppb Cemnet @ 4.5 bpm,650 psi. Drop top plug. Pump 10 bbls of H2O. Displace with rig pump @ 5 bpm,200 psi.Observed 500 psi lift pressure. Bump plug&hold 1200 psi for 5 min.Check floats,good.CIP @ 17:51 hrs. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 6,761.0 7,896.0 458 G 95.4 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.17 3.90 15.80 94.0 4.50 Additives Additive Type Concentration Conc Unit label Antifoam D047 0.2 gal/sx Additive Type Concentration Conc Unit label Dispersant D065 0.4 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.2 %BWOC Additive Type Concentration Conc Unit label Acelerator(Calcium Chloride) D186 0.05 gal/sx Additive Type Concentration Conc Unit label Gas Block D600G 1.0 gal/sx Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing 5,284.0 5,819.0 No Yes Yes Cement Q Pump Init(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 4 4 4 480.0 820.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment PJSM; Pump 40 bbls of 12 ppg MudPush 2 @ 5 bpm,350 psi. Batch up cement. Pump 42 bbls of 16 ppg tail cement w/Cemnet @ 3.5 bpm, 150 psi. Drop closing plug. Pump 10 bbls of H2O. Displace with rig pump @ 5 bpm, 175 psi.Slow pump to 3 bpm,450 psi, Bump plug w/1200 psi.Observe collar to shift closed at 1600 psi. Pressure up to 1700 psi&hold for 5 min.Verified stage collar was closed,good.CIP @ 20:13 hrs. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 5,284.0 5,819.0 204 G 42.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.17 3.25 15.80 111.2 4.40 Additives Additive Type Concentration Conc Unit label Antifoam D047 0.2 gal/sx Additive Type Concentration Conc Unit label Dispersant D065 0.4 %BWOC Page 1/2 Report Printed: 12/2/2015 Drillirsg Cement Detail Report &Weds 2S-04 Conoco+hi hps String: Intermediate Casing Cement Job: Additives Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.2 %BWOC Additive Type Concentration Conc Unit label Acelerator(Calcium Chloride) D186 0.15 gal/sx Additive Type Concentration Conc Unit label Gas Block D600G 1.6 gal/sx Page 2/2 Report Printed: 12/2/2015 • 21 51 59 flECEIVED ' 2 6 5 0 3 17o►s ConocoPhilhIps 2 6 5 0 4 AOGCC TRANSMITTAL FROM: Sandra D. Lemke, ATO3-0346 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 DATA LOGGED /2018 RE: 2S-04 iK.BENDER DATE: 12/01/2015 Transmitted: Kuparuk River Unit, Alaska 2S-04PB 1/2S-04 1 CD &1 hardcopy report& 1 color prints each log: Surface Data Logging End of Well report- Mud Log; 2S-04PB1 & 2S-04; 11/4/2015; general information, daily summary, days vs. depth, after action review, Mud record, bit record, morning reports, Survey data; digital data includes: Final log files, final end of well report, Final LAS exports, Halliburton Log viewer, EMF log viewer 2 - 2" MD Formation Evaluation log 2 - 2" MD Drilling Engineering log 2 - 2" MD Gas ration log *All lithology remarks relate to the 2S-04PB1 wellbore. Please promptly sign, scan and return electronically to Sandra.D.Lemke@Conocophi//ips.com CC: 2S-02 transmittal folder, production well files, eSearch 17) Recei 6-eitteette: ""h7. GIS-Technical Data Management I ConocoPhillips I Anchorage, Alaska Ph: 907.265.6947 0 • 215159 26466 SchlumbergerDrilling & Measurements Transmittal#: 23NOV15-SP01 DATA LOGGED MWD/LWD Log Product Delivery ``M K BENDER N Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2S-04 Date Dispatched: 23-Nov-15 Job#: 15AKA0091 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 5 Contents on CD N/A VISION*Service 2" MD x x VISION*Service 2'TVDRECE` x x VISION*Service 5' MD x x VISION*Service 5'TVD NOV G 3 261, x x MicroScope Resisti 2"MD p� x x AOGCC LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 x x As-Built Survey 1 Contents on CD N/A Nad83 x x CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf/tiff x Surveys:pdf/txt x Please sign and email a copy to: Please sign and email a copy to: Richard.E.Elqaricoconocophillips.com AlaskaPTSPrintCenter(a�slb.com Ricky Elgarico Attn:Stephanie Pacillo 907-265-6580 ii-).,(4.01.47.4,,..47) Received By: • 215159 26466 liverctec \:,;3\1 7-\"J OG,GG" FINAL NADConversion Kuparuk River Unit Kuparuk 2S Pad 2S-04 Definitive Survey Report 04 November, 2015 NAD 27 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-04 Project: Kuparuk River Unit TVD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Well: 2S-04 North Reference: True Wellbore: 2S-04 Survey Calculation Method: Minimum Curvature Design: 2S-04 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2S-04 Well Position +N/-S 0.00 usft Northing: 5,930,017.59 usfi Latitude: 70°13'11.873 N +E/-W 0.00 usft Easting: 481,221.00 usfi Longitude: 150°9'5.394 W Position Uncertainty 0.00 usft Wellhead Elevation: usfi Ground Level: 120.00 usft Wellbore 2S-04 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2015 9/30/2015 18.56 80.87 57,488 Design 2S-04 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 2,755.06 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 27.50 0.00 0.00 18.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 78.00 447.00 2S-04PB1 Srvy#1 -GYD-GC-SS(2S-04 GYD-GC-SS Gyrodata gyro single shots 9/21/2015 8:5, 476.76 2,755.06 2S-04PB1 Srvy#2-MWD+IFR-AK-CAZ-MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/21/2015 9:1 2,850.10 2,850.10 2S-04 Srvy#1 -INC TREND(2S-04) INC+TREND Inclinometer+known azi trend 10/14/2015 8:; 2,881.04 7,825.68 2S-04 Srvy#2-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/14/2015 8: 7,836.01 7,836.01 2S-04 Srvy#3-INC+TREND(2S-04) INC+TREND Inclinometer+known azi trend 10/19/2015 10 7,930.59 13,411.95 2S-04 Srvy#4-MWD+IFR-AK-CAZ(2S-MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/26/2015 8: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 27.50 0.00 0.00 27.50 -120.00 0.00 0.00 5,930,017.59 481,221.00 0.00 0.00 UNDEFINED 78.00 0.30 241.15 78.00 -69.50 -0.06 -0.12 5,930,017.53 481,220.88 0.59 -0.10 GYD-GC-SS(1) 170.00 0.45 266.98 170.00 22.50 -0.20 -0.69 5,930,017.39 481,220.31 0.24 -0.40 GYD-GC-SS(1) 263.00 0.52 264.61 262.99 115.49 -0.26 -1.47 5,930,017.34 481,219.53 0.08 -0.70 GYD-GC-SS(1) 355.00 0.64 262.29 354.99 207.49 -0.37 -2.40 5,930,017.23 481,218.60 0.13 -1.09 GYD-GC-SS(1) 447.00 0.58 275.81 446.98 299.48 -0.39 -3.37 5,930,017.21 481,217.63 0.17 -1.41 GYD-GC-SS(1) 476.76 0.31 285.28 476.74 329.24 -0.35 -3.60 5,930,017.25 481,217.40 0.94 -1.45 MWD+IFR-AK-CAZ-SC(2) 567.94 0.04 243.25 567.92 420.42 -0.30 -3.86 5,930,017.30 481,217.14 0.31 -1.48 MWD+IFR-AK-CAZ-SC(2) 660.98 1.43 217.97 660.95 513.45 -1.23 -4.61 5,930,016.37 481,216.39 1.50 -2.59 MWD+IFR-AK-CAZ-SC(2) 696.02 2.12 219.06 695.98 548.48 -2.08 -5.28 5,930,015.52 481,215.71 1.97 -3.61 MWD+IFR-AK-CAZ-SC(2) 11/4/2015 9:39:08AM Page 2 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-04 Project: Kuparuk River Unit TVD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Well: 2S-04 North Reference: True Wellbore: 2S-04 Survey Calculation Method: Minimum Curvature Design: 2S-04 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100) (ft) Survey Tool Name 757.33 2.58 214.47 757.23 609.73 -4.10 -6.78 5,930,013.51 481,214.21 0.81 -5.99 MWD+IFR-AK-CAZ-SC(2) 853.64 3.59 211.81 853.40 705.90 -8.45 -9.60 5,930,009.17 481,211.38 1.06 -11.00 MWD+IFR-AK-CAZ-SC(2) 948.89 4.60 201.35 948.41 800.91 -14.54 -12.56 5,930,003.08 481,208.41 1.31 -17.71 MWD+IFR-AK-CAZ-SC(2) 1,045.12 7.88 197.52 1,044.06 896.56 -24.43 -15.95 5,929,993.21 481,204.99 3.43 -28.16 MWD+IFR-AK-CAZ-SC(2) 1,140.42 10.66 202.74 1,138.11 990.61 -38.79 -21.33 5,929,978.86 481,199.58 3.04 -43.48 MWD+IFR-AK-CAZ-SC(2) 1,237.11 13.56 204.84 1,232.63 1,085.13 -57.33 -29.55 5,929,960.34 481,191.31 3.03 -63.65 MWD+IFR-AK-CAZ-SC(2) 1,332.94 17.82 206.38 1,324.87 1,177.37 -80.67 -40.79 5,929,937.03 481,180.02 4.47 -89.32 MWD+IFR-AK-CAZ-SC(2) 1,428.89 20.05 207.90 1,415.63 1,268.13 -108.36 -55.01 5,929,909.38 481,165.73 2.38 -120.05 MWD+IFR-AK-CAZ-SC(2) 1,525.28 19.63 209.48 1,506.29 1,358.79 -137.06 -70.71 5,929,880.72 481,149.96 0.71 -152.20 MWD+IFR-AK-CAZ-SC(2) 1,621.34 21.86 208.07 1,596.12 1,448.62 -166.89 -87.06 5,929,850.94 481,133.53 2.38 -185.62 MWD+IFR-AK-CAZ-SC(2) 1,715.89 22.82 207.21 1,683.57 1,536.07 -198.73 -103.73 5,929,819.14 481,116.78 1.07 -221.06 MWD+IFR-AK-CAZ-SC(2) 1,811.64 25.43 208.33 1,770.95 1,623.45 -233.34 -121.98 5,929,784.58 481,098.45 2.77 -259.61 MWD+IFR-AK-CAZ-SC(2) 1,909.25 28.51 211.22 1,857.94 1,710.44 -271.72 -144.01 5,929,746.26 481,076.33 3.43 -302.92 MWD+IFR-AK-CAZ-SC(2) 2,003.73 29.77 212.20 1,940.46 1,792.96 -310.85 -168.19 5,929,707.19 481,052.05 1.43 -347.61 MWD+IFR-AK-CAZ-SC(2) 2,098.75 32.65 215.49 2,021.73 1,874.23 -351.70 -195.65 5,929,666.42 481,024.49 3.52 -394.94 MWD+IFR-AK-CAZ-SC(2) 2,195.36 35.25 219.32 2,101.87 1,954.37 -394.50 -228.46 5,929,623.70 480,991.58 3.48 -445.79 MWD+IFR-AK-CAZ-SC(2) 2,290.95 38.19 223.06 2,178.49 2,030.99 -437.44 -266.13 5,929,580.86 480,953.81 3.86 -498.27 MWD+IFR-AK-CAZ-SC(2) 2,387.10 40.65 224.33 2,252.77 2,105.27 -481.57 -308.31 5,929,536.84 480,911.52 2.69 -553.27 MWD+IFR-AK-CAZ-SC(2) 2,483.15 44.04 225.78 2,323.75 2,176.25 -527.25 -354.11 5,929,491.28 480,865.61 3.67 -610.87 MWD+IFR-AK-CAZ-SC(2) 2,547.93 43.50 225.21 2,370.53 2,223.03 -558.66 -386.07 5,929,459.95 480,833.58 1.03 -650.62 MWD+IFR-AK-CAZ-SC(2) 2,579.52 43.26 226.72 2,393.49 2,245.99 -573.74 -401.67 5,929,444.91 480,817.94 3.37 -669.78 MWD+IFR-AK-CAZ-SC(2) 2,675.03 44.34 227.55 2,462.42 2,314.92 -618.70 -450.13 5,929,400.07 480,769.38 1.28 -727.52 MWD+IFR-AK-CAZ-SC(2) 2,755.06 44.33 227.28 2,519.67 2,372.17 -656.55 -491.31 5,929,362.33 480,728.11 0.24 -776.24 MWD+IFR-AK-CAZ-SC(2) 2,756.06 44.34 227.26 2,520.38 2,372.88 -657.02 -491.82 5,929,361.86 480,727.60 2.00 -776.85 INC NOT an Actual Survey 103/4"x13-1/2 2,850.10 45.74 225.48 2,586.83 2,439.33 -702.94 -539.97 5,929,316.06 480,679.34 2.00 -835.40 INC+TREND(3) 2,881.04 45.64 226.26 2,608.44 2,460.94 -718.36 -555.86 5,929,300.69 480,663.41 1.83 -854.97 MWD+IFR-AK-CAZ-SC(4) 2,943.47 45.46 226.07 2,652.16 2,504.66 -749.23 -588.01 5,929,269.90 480,631.19 0.36 -894.26 MWD+IFR-AK-CAZ-SC(4) 2,991.33 45.20 224.82 2,685.81 2,538.31 -773.10 -612.26 5,929,246.09 480,606.88 1.94 -924.46 MWD+IFR-AK-CAZ-SC(4) 3,085.27 43.88 219.67 2,752.79 2,605.29 -821.82 -656.56 5,929,197.48 480,562.47 4.09 -984.49 MWD+IFR-AK-CAZ-SC(4) 3,178.47 42.77 215.51 2,820.60 2,673.10 -872.46 -695.56 5,929,146.95 480,523.34 3.29 -1,044.70 MWD+IFR-AK-CAZ-SC(4) 3,271.17 42.52 213.65 2,888.79 2,741.29 -924.16 -731.21 5,929,095.35 480,487.57 1.39 -1,104.88 MWD+IFR-AK-CAZ-SC(4) 3,365.26 45.80 215.59 2,956.28 2,808.78 -978.07 -768.46 5,929,041.53 480,450.18 3.77 -1,167.67 MWD+IFR-AK-CAZ-SC(4) 3,460.11 49.61 215.68 3,020.10 2,872.60 -1,035.08 -809.34 5,928,984.63 480,409.17 4.02 -1,234.52 MWD+IFR-AK-CAZ-SC(4) 3,553.94 52.54 216.98 3,079.05 2,931.55 -1,093.87 -852.59 5,928,925.96 480,365.78 3.30 -1,303.79 MWD+IFR-AK-CAZ-SC(4) 3,648.55 54.97 217.69 3,134.98 2,987.48 -1,154.53 -898.87 5,928,865.42 480,319.35 2.64 -1,375.78 MWD+IFR-AK-CAZ-SC(4) 3,741.04 56.65 219.60 3,186.96 3,039.46 -1,214.26 -946.65 5,928,805.81 480,271.43 2.49 -1,447.36 MWD+IFR-AK-CAZ-SC(4) 3,835.72 54.45 221.60 3,240.52 3,093.02 -1,273.55 -997.44 5,928,746.65 480,220.50 2.90 -1,519.44 MWD+IFR-AK-CAZ-SC(4) 3,928.58 52.58 223.97 3,295.74 3,148.24 -1,328.35 -1,048.13 5,928,691.99 480,169.68 2.87 -1,587.22 MWD+IFR-AK-CAZ-SC(4) 4,021.35 52.75 227.26 3,352.01 3,204.51 -1,379.93 -1,100.83 5,928,640.54 480,116.85 2.83 -1,652.56 MWD+IFR-AK-CAZ-SC(4) 11/4/2015 9:39:08AM Page 3 COMPASS 5000.1 Build 74 • S Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-04 Project: Kuparuk River Unit TVD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Well: 2S-04 North Reference: True Wellbore: 2S-04 Survey Calculation Method: Minimum Curvature Design: 2S-04 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,113.90 52.56 228.80 3,408.15 3,260.65 -1,429.13 -1,155.53 5,928,591.48 480,062.03 1.34 -1,716.26 MWD+IFR-AK-CAZ-SC(4) 4,208.67 50.02 228.75 3,467.41 3,319.91 -1,477.86 -1,211.15 5,928,542.90 480,006.30 2.68 -1,779.79 MWD+IFR-AK-CAZ-SC(4) 4,301.46 46.76 227.94 3,529.02 3,381.52 -1,523.95 -1,262.98 5,928,496.93 479,954.35 3.57 -1,839.65 MWD+IFR-AK-CAZ-SC(4) 4,395.36 43.84 229.66 3,595.07 3,447.57 -1,567.93 -1,313.18 5,928,453.09 479,904.06 3.37 -1,896.98 MWD+IFR-AK-CAZ-SC(4) 4,489.19 41.49 231.86 3,664.06 3,516.56 -1,608.17 -1,362.40 5,928,412.98 479,854.74 2.97 -1,950.46 MWD+IFR-AK-CAZ-SC(4) 4,582.90 39.21 235.77 3,735.49 3,587.99 -1,644.01 -1,411.32 5,928,377.26 479,805.74 3.63 -1,999.67 MWD+IFR-AK-CAZ-SC(4) 4,675.87 37.43 239.72 3,808.44 3,660.94 -1,674.79 -1,460.02 5,928,346.60 479,756.96 3.26 -2,043.99 MWD+IFR-AK-CAZ-SC(4) 4,768.94 35.56 243.94 3,883.26 3,735.76 -1,700.95 -1,508.77 5,928,320.57 479,708.15 3.36 -2,083.94 MWD+IFR-AK-CAZ-SC(4) 4,862.31 33.64 247.09 3,960.12 3,812.62 -1,722.95 -1,556.99 5,928,298.69 479,659.88 2.81 -2,119.76 MWD+IFR-AK-CAZ-SC(4) 4,955.74 32.18 251.11 4,038.57 3,891.07 -1,741.08 -1,604.38 5,928,280.68 479,612.45 2.81 -2,151.65 MWD+IFR-AK-CAZ-SC(4) 5,048.21 30.67 256.38 4,117.49 3,969.99 -1,754.61 -1,650.61 5,928,267.27 479,566.20 3.39 -2,178.80 MWD+IFR-AK-CAZ-SC(4) 5,140.73 29.15 262.10 4,197.70 4,050.20 -1,763.27 -1,695.87 5,928,258.72 479,520.91 3.49 -2,201.02 MWD+IFR-AK-CAZ-SC(4) 5,234.08 27.93 266.68 4,279.71 4,132.21 -1,767.66 -1,740.22 5,928,254.44 479,476.56 2.68 -2,218.90 MWD+IFR-AK-CAZ-SC(4) 5,327.06 26.50 271.02 4,362.41 4,214.91 -1,768.55 -1,782.71 5,928,253.66 479,434.07 2.63 -2,232.88 MWD+IFR-AK-CAZ-SC(4) 5,419.24 26.54 275.28 4,444.89 4,297.39 -1,766.29 -1,823.78 5,928,256.02 479,393.01 2.06 -2,243.42 MWD+IFR-AK-CAZ-SC(4) 5,513.02 26.04 281.19 4,528.99 4,381.49 -1,760.36 -1,864.85 5,928,262.05 479,351.97 2.84 -2,250.47 MWD+IFR-AK-CAZ-SC(4) 5,606.43 26.56 286.86 4,612.74 4,465.24 -1,750.33 -1,904.95 5,928,272.18 479,311.89 2.75 -2,253.32 MWD+IFR-AK-CAZ-SC(4) 5,699.36 27.79 293.84 4,695.43 4,547.93 -1,735.54 -1,944.66 5,928,287.07 479,272.22 3.67 -2,251.53 MWD+IFR-AK-CAZ-SC(4) 5,792.34 28.43 302.34 4,777.48 4,629.98 -1,714.93 -1,983.20 5,928,307.77 479,233.73 4.36 -2,243.84 MWD+IFR-AK-CAZ-SC(4) 5,884.39 28.70 309.56 4,858.35 4,710.85 -1,689.12 -2,018.77 5,928,333.66 479,198.24 3.76 -2,230.29 MWD+IFR-AK-CAZ-SC(4) 5,977.79 29.61 314.67 4,939.93 4,792.43 -1,658.61 -2,052.47 5,928,364.25 479,164.61 2.84 -2,211.69 MWD+IFR-AK-CAZ-SC(4) 6,072.66 30.87 320.85 5,021.91 4,874.41 -1,623.25 -2,084.52 5,928,399.69 479,132.66 3.54 -2,187.96 MWD+IFR-AK-CAZ-SC(4) 6,165.55 32.00 327.23 5,101.18 4,953.68 -1,584.07 -2,112.89 5,928,438.94 479,104.38 3.78 -2,159.46 MWD+IFR-AK-CAZ-SC(4) 6,258.24 33.33 333.53 5,179.24 5,031.74 -1,540.60 -2,137.54 5,928,482.46 479,079.84 3.94 -2,125.74 MWD+I F R-AK-CAZ-SC(4) 6,350.42 34.72 337.96 5,255.64 5,108.14 -1,493.59 -2,158.69 5,928,529.52 479,058.82 3.08 -2,087.56 MWD+I F R-AK-CAZ-SC(4) 6,443.20 36.41 343.31 5,331.13 5,183.63 -1,442.71 -2,176.52 5,928,580.44 479,041.12 3.82 -2,044.68 MW D+I F R-AK-CAZ-SC(4) 6,536.63 37.96 346.32 5,405.57 5,258.07 -1,388.22 -2,191.28 5,928,634.96 479,026.49 2.56 -1,997.42 MWD+IFR-AK-CAZ-SC(4) 6,629.43 39.31 348.66 5,478.06 5,330.56 -1,331.66 -2,203.81 5,928,691.55 479,014.10 2.14 -1,947.50 MWD+IFR-AK-CAZ-SC(4) 6,723.45 42.58 350.05 5,549.07 5,401.57 -1,271.12 -2,215.16 5,928,752.12 479,002.90 3.61 -1,893.43 MWD+IFR-AK-CAZ-SC(4) 6,819.26 46.18 352.52 5,617.54 5,470.04 -1,204.89 -2,225.27 5,928,818.36 478,992.96 4.17 -1,833.57 MWD+IFR-AK-CAZ-SC(4) 6,912.82 48.15 351.82 5,681.15 5,533.65 -1,136.93 -2,234.62 5,928,886.34 478,983.78 2.18 -1,771.82 MWD+IFR-AK-CAZ-SC(4) 7,008.39 49.84 353.41 5,743.86 5,596.36 -1,065.41 -2,243.88 5,928,957.87 478,974.70 2.17 -1,706.66 MWD+IFR-AK-CAZ-SC(4) 7,103.40 51.32 354.31 5,804.19 5,656.69 -992.44 -2,251.72 5,929,030.86 478,967.04 1.72 -1,639.68 MWD+IFR-AK-CAZ-SC(4) 7,199.44 53.25 356.24 5,862.94 5,715.44 -916.73 -2,257.96 5,929,106.57 478,960.99 2.56 -1,569.61 MWD+IFR-AK-CAZ-SC(4) 7,295.02 55.93 359.36 5,918.32 5,770.82 -838.91 -2,260.92 5,929,184.39 478,958.23 3.86 -1,496.51 MWD+IFR-AK-CAZ-SC(4) 7,390.99 58.61 3.49 5,970.22 5,822.72 -758.24 -2,258.87 5,929,265.05 478,960.48 4.57 -1,419.16 MWD+IFR-AK-CAZ-SC(4) 7,486.96 59.93 6.23 6,019.27 5,871.77 -676.06 -2,251.87 5,929,347.21 478,967.68 2.81 -1,338.83 MWD+IFR-AK-CAZ-SC(4) 7,582.65 61.84 7.68 6,065.83 5,918.33 -593.08 -2,241.73 5,929,430.15 478,978.02 2.40 -1,256.79 MWD+IFR-AK-CAZ-SC(4) 7,676.97 64.73 9.33 6,108.23 5,960.73 -509.77 -2,229.26 5,929,513.42 478,990.70 3.44 -1,173.70 MWD+IFR-AK-CAZ-SC(4) 7,773.60 67.84 9.94 6,147.09 5,999.59 -422.56 -2,214.45 5,929,600.58 479,005.73 3.27 -1,086.18 MWD+IFR-AK-CAZ-SC(4) 11/4/2015 9:39:08AM Page 4 COMPASS 5000.1 Build 74 • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-04 Project: Kuparuk River Unit TVD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Well: 2S-04 North Reference: True Wellbore: 2S-04 Survey Calculation Method: Minimum Curvature Design: 2S-04 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,825.68 70.41 11.42 6,165.64 6,018.14 -374.75 -2,205.43 5,929,648.37 479,014.87 5.60 -1,037.92 MWD+IFR-AK-CAZ-SC(4) 7,836.01 70.89 11.42 6,169.07 6,021.57 -365.19 -2,203.50 5,929,657.92 479,016.82 4.65 -1,028.24 INC+TREND(5) 7,886.00 72.13 11.88 6,184.92 6,037.42 -318.76 -2,193.92 5,929,704.32 479,026.51 2.62 -981.12 MWI NOT an Actual Survey 7-5/8"x 9-718" 7,930.59 73.23 12.28 6,198.20 6,050.70 -277.14 -2,185.02 5,929,745.92 479,035.52 2.62 -938.78 MWD+IFR-AK-CAZ-SC(6) 8,023.06 75.54 13.47 6,223.09 6,075.59 -190.33 -2,165.17 5,929,832.67 479,055.58 2.79 -850.09 MWD+IFR-AK-CAZ-SC(6) 8,117.89 78.25 11.95 6,244.59 6,097.09 -100.24 -2,144.86 5,929,922.69 479,076.11 3.26 -758.13 MWD+IFR-AK-CAZ-SC(6) 8,213.29 81.93 15.59 6,261.01 6,113.51 -9.00 -2,122.48 5,930,013.87 479,098.72 5.39 -664.44 MWD+IFR-AK-CAZ-SC(6) 8,306.79 84.03 18.25 6,272.44 6,124.94 79.77 -2,095.47 5,930,102.56 479,125.94 3.61 -571.67 MWD+IFR-AK-CAZ-SC(6) 8,400.93 82.63 20.01 6,283.37 6,135.87 168.10 -2,064.83 5,930,190.81 479,156.80 2.38 -478.20 MWD+IFR-AK-CAZ-SC(6) 8,496.09 82.81 18.44 6,295.43 6,147.93 257.23 -2,033.75 5,930,279.85 479,188.10 1.65 -383.83 MWD+IFR-AK-CAZ-SC(6) 8,590.73 83.65 19.01 6,306.59 6,159.09 346.23 -2,003.58 5,930,368.77 479,218.48 1.07 -289.86 MWD+IFR-AK-CAZ-SC(6) 8,685.73 87.52 17.02 6,313.90 6,166.40 436.28 -1,974.30 5,930,458.74 479,247.99 4.58 -195.16 MWD+IFR-AK-CAZ-SC(6) 8,779.52 91.96 15.61 6,314.33 6,166.83 526.27 -1,947.96 5,930,548.65 479,274.55 4.97 -101.44 MWD+IFR-AK-CAZ-SC(6) 8,873.58 92.94 17.04 6,310.31 6,162.81 616.45 -1,921.55 5,930,638.76 479,301.18 1.84 -7.51 MWD+IFR-AK-CAZ-SC(6) 8,968.74 94.80 19.10 6,303.88 6,156.38 706.71 -1,892.10 5,930,728.93 479,330.85 2.91 87.42 MWD+IFR-AK-CAZ-SC(6) 9,063.38 95.93 18.58 6,295.03 6,147.53 795.88 -1,861.68 5,930,818.02 479,361.50 1.31 181.64 MWD+IFR-AK-CAZ-SC(6) 9,157.20 94.70 18.81 6,286.34 6,138.84 884.37 -1,831.73 5,930,906.42 479,391.66 1.33 275.05 MWD+IFR-AK-CAZ-SC(6) 9,251.96 92.77 17.91 6,280.17 6,132.67 974.11 -1,801.95 5,930,996.08 479,421.66 2.25 369.60 MWD+1FR-AK-CAZ-SC(6) 9,348.85 91.54 15.94 6,276.53 6,129.03 1,066.73 -1,773.77 5,931,088.62 479,450.07 2.40 466.40 MWD+IFR-AK-CAZ-SC(6) 9,441.70 89.75 17.00 6,275.48 6,127.98 1,155.76 -1,747.45 5,931,177.58 479,476.61 2.24 559.20 MWD+IFR-AK-CAZ-SC(6) 9,536.76 89.22 18.83 6,276.34 6,128.84 1,246.20 -1,718.21 5,931,267.94 479,506.07 2.00 654.25 MWD+IFR-AK-CAZ-SC(6) 9,631.22 90.85 20.79 6,276.28 6,128.78 1,335.06 -1,686.20 5,931,356.71 479,538.30 2.70 748.66 MWD+IFR-AK-CAZ-SC(6) 9,725.08 91.78 21.91 6,274.12 6,126.62 1,422.46 -1,652.04 5,931,444.01 479,572.67 1.55 842.33 MWD+IFR-AK-CAZ-SC(6) 9,819.77 92.29 21.14 6,270.76 6,123.26 1,510.49 -1,617.32 5,931,531.95 479,607.61 0.97 936.78 MWD+IFR-AK-CAZ-SC(6) 9,914.29 92.98 20.74 6,266.42 6,118.92 1,598.67 -1,583.57 5,931,620.04 479,641.57 0.84 1,031.08 MWD+IFR-AK-CAZ-SC(6) 10,007.93 93.95 23.06 6,260.76 6,113.26 1,685.39 -1,548.71 5,931,706.66 479,676.64 2.68 1,124.32 MWD+IFR-AK-CAZ-SC(6) 10,103.74 93.89 22.70 6,254.21 6,106.71 1,773.45 -1,511.55 5,931,794.62 479,714.02 0.38 1,219.56 MWD+IFR-AK-CAZ-SC(6) 10,197.05 91.91 21.34 6,249.49 6,101.99 1,859.84 -1,476.61 5,931,880.91 479,749.17 2.57 1,312.51 MWD+IFR-AK-CAZ-SC(6) 10,290.76 89.24 19.20 6,248.55 6,101.05 1,947.73 -1,444.15 5,931,968.71 479,781.84 3.65 1,406.13 MWD+IFR-AK-CAZ-SC(6) 10,386.03 85.91 16.55 6,252.58 6,105.08 2,038.30 -1,414.94 5,932,059.20 479,811.27 4.47 1,501.29 MWD+IFR-AK-CAZ-SC(6) 10,480.31 86.96 16.47 6,258.44 6,110.94 2,128.51 -1,388.20 5,932,149.34 479,838.24 1.12 1,595.36 MWD+IFR-AK-CAZ-SC(6) 10,575.41 90.07 15.40 6,260.90 6,113.40 2,219.92 -1,362.10 5,932,240.67 479,864.56 3.46 1,690.35 MWD+IFR-AK-CAZ-SC(6) 10,669.02 89.95 15.08 6,260.89 6,113.39 2,310.23 -1,337.50 5,932,330.91 479,889.39 0.37 1,783.85 MWD+IFR-AK-CAZ-SC(6) 10,765.36 91.60 16.18 6,259.58 6,112.08 2,403.00 -1,311.55 5,932,423.60 479,915.57 2.06 1,880.10 MWD+IFR-AK-CAZ-SC(6) 10,858.51 92.65 16.43 6,256.13 6,108.63 2,492.34 -1,285.41 5,932,512.87 479,941.92 1.16 1,973.14 MWD+IFR-AK-CAZ-SC(6) 10,955.10 92.35 15.23 6,251.92 6,104.42 2,585.18 -1,259.09 5,932,605.63 479,968.47 1.28 2,069.57 MWD+IFR-AK-CAZ-SC(6) 11,049.82 89.44 14.47 6,250.44 6,102.94 2,676.71 -1,234.82 5,932,697.10 479,992.97 3.18 2,164.12 MWD+IFR-AK-CAZ-SC(6) 11,143.17 87.41 11.85 6,253.00 6,105.50 2,767.56 -1,213.58 5,932,787.89 480,014.43 3.55 2,257.09 MWD+IFR-AK-CAZ-SC(6) 11,237.78 91.20 10.43 6,254.15 6,106.65 2,860.36 -1,195.30 5,932,880.63 480,032.94 4.28 2,351.00 MWD+IFR-AK-CAZ-SC(6) 11/4/2015 9:39:08AM Page 5 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-04 Project: Kuparuk River Unit TVD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Well: 2S-04 North Reference: True Wellbore: 2S-04 Survey Calculation Method: Minimum Curvature Design: 2S-04 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°1100) (ft) Survey Tool Name 11,332.11 89.96 11.14 6,253.20 6,105.70 2,953.02 -1,177.65 5,932,973.24 480,050.81 1.51 2,444.57 MWD+IFR-AK-CAZ-SC(6) 11,425.41 88.16 13.98 6,254.73 6,107.23 3,044.06 -1,157.37 5,933,064.22 480,071.32 3.60 2,537.43 MWD+IFR-AK-CAZ-SC(6) 11,520.84 88.04 15.35 6,257.89 6,110.39 3,136.33 -1,133.22 5,933,156.42 480,095.70 1.44 2,632.64 MWD+IFR-AK-CAZ-SC(6) 11,615.20 88.28 17.63 6,260.92 6,113.42 3,226.76 -1,106.46 5,933,246.77 480,122.69 2.43 2,726.91 MWD+IFR-AK-CAZ-SC(6) 11,710.79 89.24 20.52 6,262.99 6,115.49 3,317.07 -1,075.23 5,933,336.99 480,154.14 3.19 2,822.45 MWD+IFR-AK-CAZ-SC(6) 11,804.91 90.55 21.27 6,263.16 6,115.66 3,404.99 -1,041.66 5,933,424.83 480,187.92 1.60 2,916.45 MWD+IFR-AK-CAZ-SC(6) 11,898.63 90.71 19.66 6,262.13 6,114.63 3,492.79 -1,008.89 5,933,512.53 480,220.90 1.73 3,010.08 MWD+IFR-AK-CAZ-SC(6) 11,994.43 91.60 19.74 6,260.20 6,112.70 3,582.96 -976.61 5,933,602.62 480,253.41 0.93 3,105.81 MWD+IFR-AK-CAZ-SC(6) 12,087.51 92.24 19.82 6,257.08 6,109.58 3,670.50 -945.13 5,933,690.07 480,285.10 0.69 3,198.79 MWD+IFR-AK-CAZ-SC(6) 12,182.24 91.26 18.91 6,254.19 6,106.69 3,759.83 -913.73 5,933,779.31 480,316.72 1.41 3,293.45 MWD+IFR-AK-CAZ-SC(6) 12,278.29 91.64 24.18 6,251.76 6,104.26 3,849.11 -878.48 5,933,868.49 480,352.18 5.50 3,389.25 MWD+IFR-AK-CAZ-SC(6) 12,328.82 92.02 23.57 6,250.14 6,102.64 3,895.29 -858.04 5,933,914.62 480,372.74 1.42 3,439.49 MWD+IFR-AK-CAZ-SC(6) 12,372.32 92.77 24.01 6,248.33 6,100.83 3,935.06 -840.51 5,933,954.34 480,390.37 2.00 3,482.73 MWD+IFR-AK-CAZ-SC(6) 12,466.67 91.78 24.86 6,244.58 6,097.08 4,020.89 -801.51 5,934,040.06 480,429.57 1.38 3,576.41 MWD+IFR-AK-CAZ-SC(6) 12,561.30 90.19 23.56 6,242.95 6,095.45 4,107.18 -762.71 5,934,126.24 480,468.58 2.17 3,670.47 MWD+IFR-AK-CAZ-SC(6) 12,656.17 90.44 20.66 6,242.43 6,094.93 4,195.06 -727.01 5,934,214.03 480,504.50 3.07 3,765.08 MWD+IFR-AK-CAZ-SC(6) 12,751.22 90.45 13.11 6,241.69 6,094.19 4,285.95 -699.42 5,934,304.83 480,532.31 7.94 3,860.04 MWD+IFR-AK-CAZ-SC(6) 12,845.85 90.58 15.87 6,240.84 6,093.34 4,377.55 -675.75 5,934,396.37 480,556.21 2.92 3,954.48 MWD+IFR-AK-CAZ-SC(6) 12,935.20 90.40 15.86 6,240.08 6,092.58 4,463.50 -651.33 5,934,482.25 480,580.85 0.20 4,043.77 MWD+IFR-AK-CAZ-SC(6) 13,033.35 90.27 16.27 6,239.50 6,092.00 4,557.81 -624.17 5,934,576.49 480,608.24 0.44 4,141.86 MWD+IFR-AK-CAZ-SC(6) 13,127.01 91.49 16.88 6,238.07 6,090.57 4,647.57 -597.45 5,934,666.17 480,635.17 1.46 4,235.48 MWD+IFR-AK-CAZ-SC(6) 13,220.65 90.97 19.01 6,236.06 6,088.56 4,736.63 -568.61 5,934,755.14 480,664.23 2.34 4,329.09 MWD+IFR-AK-CAZ-SC(6) 13,317.85 88.48 20.08 6,236.52 6,089.02 4,828.21 -536.09 5,934,846.64 480,696.97 2.79 4,426.24 MWD+IFR-AK-CAZ-SC(6) 13,411.95 90.57 24.34 6,237.30 6,089.80 4,915.30 -500.53 5,934,933.64 480,732.75 5.04 4,520.06 MWD+IFR-AK-CAZ-SC(6) 13,476.00 90.57 24.34 6,236.67 6,089.17 4,973.66 -474.14 5,934,991.92 480,759.29 0.00 4,583.71 PR NOT an Actual Survey 4 1/2"x 6-3/4" 13,505.00 90.57 24.34 6,236.38 6,088.88 5,000.08 -462.19 5,935,018.31 480,771.30 0.00 4,612.54 PROJECTED to TD Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. C Yes ❑ No I have checked to the best of my ability that the following data Is correct: LI Surface Coordinates P1 Declination & Convergence E] GRS Survey Corrections ID Survey Tool Codes ,,8-, mfe1Oar Vincent Osara ^� SLB DE: m..2015'119 141457 Client Representative: Mike Callahan .. - Date: 03-Nov-2015 11/4/2015 9:39:08AM Page 6 COMPASS 5000.1 Build 74 • • 215159 26466 ffi:ece' 0\s, OG°° FINAL �' ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad 2S-04 Definitive Survey Report 03 November, 2015 NAD 83 i Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-04 Project: Kuparuk River Unit TVD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Well: 2S-04 North Reference: True Wellbore: 2S-04 Survey Calculation Method: Minimum Curvature Design: 2S-04 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska, United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well 2S-04 Well Position +N/-S 0.00 usft Northing: 5,929,767.18 usft Latitude: 70°13'10.753 N +E/-W 0.00 usft Easting: 1,621,254.32 usfi Longitude: 150°9'16.543 W Position Uncertainty 0.00 usft Wellhead Elevation: usfi Ground Level: 120.00 usft Wellbore 2S-04 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 9/30/2015 18.56 80.87 57,488 Design 2S-04 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 2,755.06 Vertical Section: Depth From(TVD) +NI-S +El-W Direction (usft) (usft) (usft) (°) 27.50 0.00 0.00 18.00 Survey Program Date 11/3/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 78.00 447.00 2S-04PB1 Srvy#1 -GYD-GC-SS(2S-04 GYD-GC-SS Gyrodata gyro single shots 9/21/2015 8:5, 476.76 2,755.06 2S-04PB1 Srvy#2-MWD+IFR-AK-CAZ-MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/21/2015 9:1 2,850.10 2,850.10 2S-04 Srvy#1 -INC TREND(2S-04) INC+TREND Inclinometer+known azi trend 10/14/2015 8: 2,881.04 7,825.68 2S-04 Srvy#2-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/14/2015 8:. 7,836.01 7,836.01 2S-04 Srvy#3-INC+TREND(2S-04) INC+TREND Inclinometer+known azi trend 10/19/2015 10 7,930.59 13,411.95 2S-04 Srvy#4-MWD+IFR-AK-CAZ(2S-MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/26/2015 8:: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 27.50 0.00 0.00 27.50 -120.00 0.00 0.00 5,929,767.18 1,621,254.32 0.00 0.00 UNDEFINED 78.00 0.30 241.15 78.00 -69.50 -0.06 -0.12 5,929,767.12 1,621,254.20 0.59 -0.10 GYD-GC-SS(1) 170.00 0.45 266.98 170.00 22.50 -0.20 -0.69 5,929,766.98 1,621,253.63 0.24 -0.40 GYD-GC-SS(1) 263.00 0.52 264.61 262.99 115.49 -0.26 -1.47 5,929,766.93 1,621,252.84 0.08 -0.70 GYD-GC-SS(1) 355.00 0.64 262.29 354.99 207.49 -0.37 -2.40 5,929,766.82 1,621,251.92 0.13 -1.09 GYD-GC-SS(1) 447.00 0.58 275.81 446.98 299.48 -0.39 -3.37 5,929,766.80 1,621,250.95 0.17 -1.41 GYD-GC-SS(1) 476.76 0.31 285.28 476.74 329.24 -0.35 -3.60 5,929,766.84 1,621,250.72 0.94 -1.45 MWD+IFR-AK-CAZ-SC(2) 567.94 0.04 243.25 567.92 420.42 -0.30 -3.86 5,929,766.89 1,621,250.45 0.31 -1.48 MWD+IFR-AK-CAZ-SC(2) 660.98 1.43 217.97 660.95 513.45 -1.23 -4.61 5,929,765.96 1,621,249.71 1.50 -2.59 MWD+IFR-AK-CAZ-SC(2) 696.02 2.12 219.06 695.98 548.48 -2.08 -5.28 5,929,765.12 1,621,249.03 1.97 -3.61 MWD+IFR-AK-CAZ-SC(2) 11/3/2015 3:58:45PM Page 2 COMPASS 5000.1 Build 74 S S . Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-04 Project: Kuparuk River Unit TVD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Well: 2S-04 North Reference: True Wellbore: 2S-04 Survey Calculation Method: Minimum Curvature Design: 2S-04 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 757.33 2.58 214.47 757.23 609.73 -4.10 -6.78 5,929,763.10 1,621,247.53 0.81 -5.99 MWD+IFR-AK-CAZ-SC(2) 853.64 3.59 211.81 853.40 705.90 -8.45 -9.60 5,929,758.76 1,621,244.70 1.06 -11.00 MWD+IFR-AK-CAZ-SC(2) 948.89 4.60 201.35 948.41 800.91 -14.54 -12.56 5,929,752.68 1,621,241.72 1.31 -17.71 MWD+IFR-AK-CAZ-SC(2) 1,045.12 7.88 197.52 1,044.06 896.56 -24.43 -15.95 5,929,742.80 1,621,238.31 3.43 -28.16 MWD+IFR-AK-CAZ-SC(2) 1,140.42 10.66 202.74 1,138.11 990.61 -38.79 -21.33 5,929,728.45 1,621,232.90 3.04 -43.48 MWD+IFR-AK-CAZ-SC(2) 1,237.11 13.56 204.84 1,232.63 1,085.13 -57.33 -29.55 5,929,709.94 1,621,224.63 3.03 -63.65 MWD+IFR-AK-CAZ-SC(2) 1,332.94 17.82 206.38 1,324.87 1,177.37 -80.67 -40.79 5,929,686.62 1,621,213.33 4.47 -89.32 MWD+IFR-AK-CAZ-SC(2) 1,428.89 20.05 207.90 1,415.63 1,268.13 -108.36 -55.01 5,929,658.97 1,621,199.04 2.38 -120.05 MWD+IFR-AK-CAZ-SC(2) 1,525.28 19.63 209.48 1,506.29 1,358.79 -137.06 -70.71 5,929,630.32 1,621,183.27 0.71 -152.20 MWD+IFR-AK-CAZ-SC(2) 1,621.34 21.86 208.07 1,596.12 1,448.62 -166.89 -87.06 5,929,600.53 1,621,166.84 2.38 -185.62 MWD+IFR-AK-CAZ-SC(2) 1,715.89 22.82 207.21 1,683.57 1,536.07 -198.73 -103.73 5,929,568.74 1,621,150.09 1.07 -221.06 MWD+IFR-AK-CAZ-SC(2) 1,811.64 25.43 208.33 1,770.95 1,623.45 -233.34 -121.98 5,929,534.17 1,621,131.76 2.77 -259.61 MWD+IFR-AK-CAZ-SC(2) 1,909.25 28.51 211.22 1,857.94 1,710.44 -271.72 -144.01 5,929,495.85 1,621,109.64 3.43 -302.92 MWD+IFR-AK-CAZ-SC(2) 2,003.73 29.77 212.20 1,940.46 1,792.96 -310.85 -168.19 5,929,456.79 1,621,085.35 1.43 -347.61 MWD+IFR-AK-CAZ-SC(2) 2,098.75 32.65 215.49 2,021.73 1,874.23 -351.70 -195.65 5,929,416.02 1,621,057.79 3.52 -394.94 MWD+IFR-AK-CAZ-SC(2) 2,195.36 35.25 219.32 2,101.87 1,954.37 -394.50 -228.46 5,929,373.30 1,621,024.88 3.48 -445.79 MWD+IFR-AK-CAZ-SC(2) 2,290.95 38.19 223.06 2,178.49 2,030.99 -437.44 -266.13 5,929,330.46 1,620,987.11 3.86 -498.27 MWD+IFR-AK-CAZ-SC(2) 2,387.10 40.65 224.33 2,252.77 2,105.27 -481.57 -308.31 5,929,286.44 1,620,944.81 2.69 -553.27 MWD+IFR-AK-CAZ-SC(2) 2,483.15 44.04 225.78 2,323.75 2,176.25 -527.25 -354.11 5,929,240.89 1,620,898.90 3.67 -610.87 MWD+IFR-AK-CAZ-SC(2) 2,547.93 43.50 225.21 2,370.53 2,223.03 -558.66 -386.07 5,929,209.56 1,620,866.86 1.03 -650.62 MWD+IFR-AK-CAZ-SC(2) 2,579.52 43.26 226.72 2,393.49 2,245.99 -573.74 -401.67 5,929,194.52 1,620,851.23 3.37 -669.78 MWD+IFR-AK-CAZ-SC(2) 2,675.03 44.34 227.55 2,462.42 2,314.92 -618.70 -450.13 5,929,149.68 1,620,802.67 1.28 -727.52 MWD+IFR-AK-CAZ-SC(2) 2,755.06 44.33 227.28 2,519.67 2,372.17 -656.55 -491.31 5,929,111.95 1,620,761.40 0.24 -776.24 MWD+IFR-AK-CAZ-SC(2) 2,756.06 44.34 227.26 2,520.38 2,372.88 -657.02 -491.82 5,929,111.47 1,620,760.88 2.00 -776.85 I NOT an Actual Survey 10 3/4"x 13-1/2 2,850.10 45.74 225.48 2,586.83 2,439.33 -702.94 -539.97 5,929,065.68 1,620,712.62 2.00 -835.40 INC+TREND(3) 2,881.04 45.64 226.26 2,608.44 2,460.94 -718.36 -555.86 5,929,050.31 1,620,696.69 1.83 -854.97 MWD+IFR-AK-CAZ-SC(4) 2,943.47 45.46 226.07 2,652.16 2,504.66 -749.23 -588.01 5,929,019.52 1,620,664.47 0.36 -894.26 MWD+IFR-AK-CAZ-SC(4) 2,991.33 45.20 224.82 2,685.81 2,538.31 -773.10 -612.26 5,928,995.71 1,620,640.15 1.94 -924.46 MWD+IFR-AK-CAZ-SC(4) 3,085.27 43.88 219.67 2,752.79 2,605.29 -821.82 -656.56 5,928,947.11 1,620,595.74 4.09 -984.49 MWD+IFR-AK-CAZ-SC(4) 3,178.47 42.77 215.51 2,820.60 2,673.10 -872.46 -695.56 5,928,896.58 1,620,556.61 3.29 -1,044.70 MWD+IFR-AK-CAZ-SC(4) 3,271.17 42.52 213.65 2,888.79 2,741.29 -924.16 -731.21 5,928,844.98 1,620,520.84 1.39 -1,104.88 MWD+IFR-AK-CAZ-SC(4) 3,365.26 45.80 215.59 2,956.28 2,808.78 -978.07 -768.46 5,928,791.16 1,620,483.45 3.77 -1,167.67 MWD+IFR-AK-CAZ-SC(4) 3,460.11 49.61 215.68 3,020.10 2,872.60 -1,035.08 -809.34 5,928,734.26 1,620,442.44 4.02 -1,234.52 MWD+IFR-AK-CAZ-SC(4) 3,553.94 52.54 216.98 3,079.05 2,931.55 -1,093.87 -852.59 5,928,675.59 1,620,399.04 3.30 -1,303.79 MWD+IFR-AK-CAZ-SC(4) 3,648.55 54.97 217.69 3,134.98 2,987.48 -1,154.53 -898.87 5,928,615.05 1,620,352.61 2.64 -1,375.78 MWD+IFR-AK-CAZ-SC(4) 3,741.04 56.65 219.60 3,186.96 3,039.46 -1,214.26 -946.65 5,928,555.44 1,620,304.68 2.49 -1,447.36 MWD+IFR-AK-CAZ-SC(4) 3,835.72 54.45 221.60 3,240.52 3,093.02 -1,273.55 -997.44 5,928,496.30 1,620,253.75 2.90 -1,519.44 MWD+IFR-AK-CAZ-SC(4) 3,928.58 52.58 223.97 3,295.74 3,148.24 -1,328.35 -1,048.13 5,928,441.63 1,620,202.93 2.87 -1,587.22 MWD+IFR-AK-CAZ-SC(4) 4,021.35 52.75 227.26 3,352.01 3,204.51 -1,379.93 -1,100.83 5,928,390.19 1,620,150.10 2.83 -1,652.56 MWD+IFR-AK-CAZ-SC(4) 11/3/2015 3:58:45PM Page 3 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-04 Project: Kuparuk River Unit TVD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Well: 2S-04 North Reference: True Wellbore: 2S-04 Survey Calculation Method: Minimum Curvature Design: 2S-04 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (01100') (ft) Survey Tool Name 4,113.90 52.56 228.80 3,408.15 3,260.65 -1,429.13 -1,155.53 5,928,341.13 1,620,095.28 1.34 -1,716.26 MWD+IFR-AK-CAZ-SC(4) 4,208.67 50.02 228.75 3,467.41 3,319.91 -1,477.86 -1,211.15 5,928,292.55 1,620,039.54 2.68 -1,779.79 MWD+IFR-AK-CAZ-SC(4) 4,301.46 46.76 227.94 3,529.02 3,381.52 -1,523.95 -1,262.98 5,928,246.59 1,619,987.59 3.57 -1,839.65 MWD+IFR-AK-CAZ-SC(4) 4,395.36 43.84 229.66 3,595.07 3,447.57 -1,567.93 -1,313.18 5,928,202.75 1,619,937.29 3.37 -1,896.98 MWD+IFR-AK-CAZ-SC(4) 4,489.19 41.49 231.86 3,664.06 3,516.56 -1,608.17 -1,362.40 5,928,162.64 1,619,887.97 2.97 -1,950.46 MWD+IFR-AK-CAZ-SC(4) 4,582.90 39.21 235.77 3,735.49 3,587.99 -1,644.01 -1,411.32 5,928,126.92 1,619,838.97 3.63 -1,999.67 MWD+IFR-AK-CAZ-SC(4) 4,675.87 37.43 239.72 3,808.44 3,660.94 -1,674.79 -1,460.02 5,928,096.27 1,619,790.19 3.26 -2,043.99 MWD+IFR-AK-CAZ-SC(4) 4,768.94 35.56 243.94 3,883.26 3,735.76 -1,700.95 -1,508.77 5,928,070.24 1,619,741.38 3.36 -2,083.94 MWD+IFR-AK-CAZ-SC(4) 4,862.31 33.64 247.09 3,960.12 3,812.62 -1,722.95 -1,556.99 5,928,048.36 1,619,693.11 2.81 -2,119.76 MWD+IFR-AK-CAZ-SC(4) 4,955.74 32.18 251.11 4,038.57 3,891.07 -1,741.08 -1,604.38 5,928,030.35 1,619,645.68 2.81 -2,151.65 MWD+IFR-AK-CAZ-SC(4) 5,048.21 30.67 256.38 4,117.49 3,969.99 -1,754.61 -1,650.61 5,928,016.94 1,619,599.42 3.39 -2,178.80 MWD+IFR-AK-CAZ-SC(4) 5,140.73 29.15 262.10 4,197.70 4,050.20 -1,763.27 -1,695.87 5,928,008.40 1,619,554.14 3.49 -2,201.02 MWD+IFR-AK-CAZ-SC(4) 5,234.08 27.93 266.68 4,279.71 4,132.21 -1,767.66 -1,740.22 5,928,004.12 1,619,509.78 2.68 -2,218.90 MWD+IFR-AK-CAZ-SC(4) 5,327.06 26.50 271.02 4,362.41 4,214.91 -1,768.55 -1,782.71 5,928,003.34 1,619,467.30 2.63 -2,232.88 MWD+IFR-AK-CAZ-SC(4) 5,419.24 26.54 275.28 4,444.89 4,297.39 -1,766.29 -1,823.78 5,928,005.70 1,619,426.24 2.06 -2,243.42 MWD+IFR-AK-CAZ-SC(4) 5,513.02 26.04 281.19 4,528.99 4,381.49 -1,760.36 -1,864.85 5,928,011.73 1,619,385.19 2.84 -2,250.47 MWD+IFR-AK-CAZ-SC(4) 5,606.43 26.56 286.86 4,612.74 4,465.24 -1,750.33 -1,904.95 5,928,021.87 1,619,345.12 2.75 -2,253.32 MWD+IFR-AK-CAZ-SC(4) 5,699.36 27.79 293.84 4,695.43 4,547.93 -1,735.54 -1,944.66 5,928,036.76 1,619,305.45 3.67 -2,251.53 MWD+IFR-AK-CAZ-SC(4) 5,792.34 28.43 302.34 4,777.48 4,629.98 -1,714.93 -1,983.20 5,928,057.46 1,619,266.96 4.36 -2,243.84 MWD+IFR-AK-CAZ-SC(4) 5,884.39 28.70 309.56 4,858.35 4,710.85 -1,689.12 -2,018.77 5,928,083.35 1,619,231.47 3.76 -2,230.29 MWD+IFR-AK-CAZ-SC(4) 5,977.79 29.61 314.67 4,939.93 4,792.43 -1,658.61 -2,052.47 5,928,113.95 1,619,197.84 2.84 -2,211.69 MWD+IFR-AK-CAZ-SC(4) 6,072.66 30.87 320.85 5,021.91 4,874.41 -1,623.25 -2,084.52 5,928,149.39 1,619,165.89 3.54 -2,187.96 MWD+IFR-AK-CAZ-SC(4) 6,165.55 32.00 327.23 5,101.18 4,953.68 -1,584.07 -2,112.89 5,928,188.64 1,619,137.62 3.78 -2,159.46 MWD+IFR-AK-CAZ-SC(4) 6,258.24 33.33 333.53 5,179.24 5,031.74 -1,540.60 -2,137.54 5,928,232.16 1,619,113.08 3.94 -2,125.74 MWD+IFR-AK-CAZ-SC(4) 6,350.42 34.72 337.96 5,255.64 5,108.14 -1,493.59 -2,158.69 5,928,279.22 1,619,092.06 3.08 -2,087.56 MW D+I FR-AK-CAZ-SC(4) 6,443.20 36.41 343.31 5,331.13 5,183.63 -1,442.71 -2,176.52 5,928,330.14 1,619,074.36 3.82 -2,044.68 MWD+IFR-AK-CAZ-SC(4) 6,536.63 37.96 346.32 5,405.57 5,258.07 -1,388.22 -2,191.28 5,928,384.66 1,619,059.74 2.56 -1,997.42 MWD+IFR-AK-CAZ-SC(4) 6,629.43 39.31 348.66 5,478.06 5,330.56 -1,331.66 -2,203.81 5,928,441.25 1,619,047.35 2.14 -1,947.50 MWD+IFR-AK-CAZ-SC(4) 6,723.45 42.58 350.05 5,549.07 5,401.57 -1,271.12 -2,215.16 5,928,501.82 1,619,036.15 3.61 -1,893.43 MWD+IFR-AK-CAZ-SC(4) 6,819.26 46.18 352.52 5,617.54 5,470.04 -1,204.89 -2,225.27 5,928,568.06 1,619,026.22 4.17 -1,833.57 MWD+IFR-AK-CAZ-SC(4) 6,912.82 48.15 351.82 5,681.15 5,533.65 -1,136.93 -2,234.62 5,928,636.04 1,619,017.04 2.18 -1,771.82 MWD+IFR-AK-CAZ-SC(4) 7,008.39 49.84 353.41 5,743.86 5,596.36 -1,065.41 -2,243.88 5,928,707.58 1,619,007.96 2.17 -1,706.66 MWD+IFR-AK-CAZ-SC(4) 7,103.40 51.32 354.31 5,804.19 5,656.69 -992.44 -2,251.72 5,928,780.56 1,619,000.31 1.72 -1,639.68 MWD+IFR-AK-CAZ-SC(4) 7,199.44 53.25 356.24 5,862.94 5,715.44 -916.73 -2,257.96 5,928,856.28 1,618,994.26 2.56 -1,569.61 MWD+IFR-AK-CAZ-SC(4) 7,295.02 55.93 359.36 5,918.32 5,770.82 -838.91 -2,260.92 5,928,934.10 1,618,991.50 3.86 -1,496.51 MWD+IFR-AK-CAZ-SC(4) 7,390.99 58.61 3.49 5,970.22 5,822.72 -758.24 -2,258.87 5,929,014.75 1,618,993.76 4.57 -1,419.16 MWD+IFR-AK-CAZ-SC(4) 7,486.96 59.93 6.23 6,019.27 5,871.77 -676.06 -2,251.87 5,929,096.91 1,619,000.97 2.81 -1,338.83 MWD+IFR-AK-CAZ-SC(4) 7,582.65 61.84 7.68 6,065.83 5,918.33 -593.08 -2,241.73 5,929,179.85 1,619,011.31 2.40 -1,256.79 MWD+IFR-AK-CAZ-SC(4) 7,676.97 64.73 9.33 6,108.23 5,960.73 -509.77 -2,229.26 5,929,263.12 1,619,023.99 3.44 -1,173.70 MWD+IFR-AK-CAZ-SC(4) 7,773.60 67.84 9.94 6,147.09 5,999.59 -422.56 -2,214.45 5,929,350.29 1,619,039.02 3.27 -1,086.18 MWD+IFR-AK-CAZ-SC(4) 11/3/2015 3:58:45PM Page 4 COMPASS 5000.1 Build 74 • • . Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-04 Project: Kuparuk River Unit TVD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Well: 2S-04 North Reference: True Wellbore: 2S-04 Survey Calculation Method: Minimum Curvature Design: 2S-04 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (*MOO') (ft) Survey Tool Name 7,825.68 70.41 11.42 6,165.64 6,018.14 -374.75 -2,205.43 5,929,398.07 1,619,048.17 5.60 -1,037.92 MWD+IFR-AK-CAZ-SC(4) 7,836.01 70.89 11.42 6,169.07 6,021.57 -365.19 -2,203.50 5,929,407.62 1,619,050.12 4.65 -1,028.24 INC+TREND(5) 7,886.00 72.13 11.88 6,184.92 6,037.42 -318.76 -2,193.92 5,929,454.02 1,619,059.81 2.62 -981.12 M`NOT an Actual Survey 6) 7-5/8"x 9-7/8" 7,930.59 73.23 12.28 6,198.20 6,050.70 -277.14 -2,185.02 5,929,495.62 1,619,068.82 2.62 -938.78 MWD+IFR-AK-CAZ-SC(6) 8,023.06 75.54 13.47 6,223.09 6,075.59 -190.33 -2,165.17 5,929,582.37 1,619,088.89 2.79 -850.09 MWD+IFR-AK-CAZ-SC(6) 8,117.89 78.25 11.95 6,244.59 6,097.09 -100.24 -2,144.86 5,929,672.39 1,619,109.43 3.26 -758.13 MWD+IFR-AK-CAZ-SC(6) 8,213.29 81.93 15.59 6,261.01 6,113.51 -9.00 -2,122.48 5,929,763.57 1,619,132.03 5.39 -664.44 MWD+IFR-AK-CAZ-SC(6) 8,306.79 84.03 18.25 6,272.44 6,124.94 79.77 -2,095.47 5,929,852.26 1,619,159.26 3.61 -571.67 MWD+IFR-AK-CAZ-SC(6) 8,400.93 82.63 20.01 6,283.37 6,135.87 168.10 -2,064.83 5,929,940.50 1,619,190.12 2.38 -478.20 MWD+IFR-AK-CAZ-SC(6) 8,496.09 82.81 18.44 6,295.43 6,147.93 257.23 -2,033.75 5,930,029.54 1,619,221.43 1.65 -383.83 MWD+IFR-AK-CAZ-SC(6) 8,590.73 83.65 19.01 6,306.59 6,159.09 346.23 -2,003.58 5,930,118.46 1,619,251.82 1.07 -289.86 MWD+IFR-AK-CAZ-SC(6) 8,685.73 87.52 17.02 6,313.90 6,166.40 436.28 -1,974.30 5,930,208.43 1,619,281.33 4.58 -195.16 MWD+IFR-AK-CAZ-SC(6) 8,779.52 91.96 15.61 6,314.33 6,166.83 526.27 -1,947.96 5,930,298.34 1,619,307.89 4.97 -101.44 MWD+IFR-AK-CAZ-SC(6) 8,873.58 92.94 17.04 6,310.31 6,162.81 616.45 -1,921.55 5,930,388.45 1,619,334.53 1.84 -7.51 MWD+IFR-AK-CAZ-SC(6) 8,968.74 94.80 19.10 6,303.88 6,156.38 706.71 -1,892.10 5,930,478.62 1,619,364.20 2.91 87.42 MWD+IFR-AK-CAZ-SC(6) 9,063.38 95.93 18.58 6,295.03 6,147.53 795.88 -1,861.68 5,930,567.71 1,619,394.85 1.31 181.64 MWD+IFR-AK-CAZ-SC(6) 9,157.20 94.70 18.81 6,286.34 6,138.84 884.37 -1,831.73 5,930,656.11 1,619,425.02 1.33 275.05 MWD+IFR-AK-CAZ-SC(6) 9,251.96 92.77 17.91 6,280.17 6,132.67 974.11 -1,801.95 5,930,745.76 1,619,455.02 2.25 369.60 MWD+IFR-AK-CAZ-SC(6) 9,348.85 91.54 15.94 6,276.53 6,129.03 1,066.73 -1,773.77 5,930,838.30 1,619,483.44 2.40 466.40 MWD+IFR-AK-CAZ-SC(6) 9,441.70 89.75 17.00 6,275.48 6,127.98 1,155.76 -1,747.45 5,930,927.26 1,619,509.99 2.24 559.20 MWD+IFR-AK-CAZ-SC(6) 9,536.76 89.22 18.83 6,276.34 6,128.84 1,246.20 -1,718.21 5,931,017.62 1,619,539.45 2.00 654.25 MWD+IFR-AK-CAZ-SC(6) 9,631.22 90.85 20.79 6,276.28 6,128.78 1,335.06 -1,686.20 5,931,106.39 1,619,571.68 2.70 748.66 MWD+IFR-AK-CAZ-SC(6) 9,725.08 91.78 21.91 6,274.12 6,126.62 1,422.46 -1,652.04 5,931,193.69 1,619,606.06 1.55 842.33 MWD+IFR-AK-CAZ-SC(6) 9,819.77 92.29 21.14 6,270.76 6,123.26 1,510.49 -1,617.32 5,931,281.62 1,619,641.00 0.97 936.78 MWD+IFR-AK-CAZ-SC(6) 9,914.29 92.98 20.74 6,266.42 6,118.92 1,598.67 -1,583.57 5,931,369.71 1,619,674.97 0.84 1,031.08 MWD+IFR-AK-CAZ-SC(6) 10,007.93 93.95 23.06 6,260.76 6,113.26 1,685.39 -1,548.71 5,931,456.33 1,619,710.04 2.68 1,124.32 MWD+IFR-AK-CAZ-SC(6) 10,103.74 93.89 22.70 6,254.21 6,106.71 1,773.45 -1,511.55 5,931,544.29 1,619,747.43 0.38 1,219.56 MWD+IFR-AK-CAZ-SC(6) 10,197.05 91.91 21.34 6,249.49 6,101.99 1,859.84 -1,476.61 5,931,630.58 1,619,782.58 2.57 1,312.51 MWD+IFR-AK-CAZ-SC(6) 10,290.76 89.24 19.20 6,248.55 6,101.05 1,947.73 -1,444.15 5,931,718.37 1,619,815.26 3.65 1,406.13 MWD+IFR-AK-CAZ-SC(6) 10,386.03 85.91 16.55 6,252.58 6,105.08 2,038.30 -1,414.94 5,931,808.86 1,619,844.70 4.47 1,501.29 MWD+IFR-AK-CAZ-SC(6) 10,480.31 86.96 16.47 6,258.44 6,110.94 2,128.51 -1,388.20 5,931,899.00 1,619,871.66 1.12 1,595.36 MWD+IFR-AK-CAZ-SC(6) 10,575.41 90.07 15.40 6,260.90 6,113.40 2,219.92 -1,362.10 5,931,990.33 1,619,897.99 3.46 1,690.35 MWD+IFR-AK-CAZ-SC(6) 10,669.02 89.95 15.08 6,260.89 6,113.39 2,310.23 -1,337.50 5,932,080.57 1,619,922.82 0.37 1,783.85 MWD+IFR-AK-CAZ-SC(6) 10,765.36 91.60 16.18 6,259.58 6,112.08 2,403.00 -1,311.55 5,932,173.26 1,619,949.01 2.06 1,880.10 MWD+IFR-AK-CAZ-SC(6) 10,858.51 92.65 16.43 6,256.13 6,108.63 2,492.34 -1,285.41 5,932,262.53 1,619,975.36 1.16 1,973.14 MWD+IFR-AK-CAZ-SC(6) 10,955.10 92.35 15.23 6,251.92 6,104.42 2,585.18 -1,259.09 5,932,355.29 1,620,001.92 1.28 2,069.57 MWD+IFR-AK-CAZ-SC(6) 11,049.82 89.44 14.47 6,250.44 6,102.94 2,676.71 -1,234.82 5,932,446.75 1,620,026.42 3.18 2,164.12 MWD+IFR-AK-CAZ-SC(6) 11,143.17 87.41 11.85 6,253.00 6,105.50 2,767.56 -1,213.58 5,932,537.54 1,620,047.89 3.55 2,257.09 MWD+IFR-AK-CAZ-SC(6) 11,237.78 91.20 10.43 6,254.15 6,106.65 2,860.36 -1,195.30 5,932,630.28 1,620,066.40 4.28 2,351.00 MWD+IFR-AK-CAZ-SC(6) 11/3/2015 3:58:45PM Page 5 COMPASS 5000.1 Build 74 • S Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-04 Project: Kuparuk River Unit TVD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Well: 2S-04 North Reference: True Wellbore: 2S-04 Survey Calculation Method: Minimum Curvature Design: 2S-04 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) ("/100') (ft) Survey Tool Name 11,332.11 89.96 11.14 6,253.20 6,105.70 2,953.02 -1,177.65 5,932,722.89 1,620,084.28 1.51 2,444.57 MWD+IFR-AK-CAZ-SC(6) 11,425.41 88.16 13.98 6,254.73 6,107.23 3,044.06 -1,157.37 5,932,813.87 1,620,104.79 3.60 2,537.43 MWD+IFR-AK-CAZ-SC(6) 11,520.84 88.04 15.35 6,257.89 6,110.39 3,136.33 -1,133.22 5,932,906.06 1,620,129.17 1.44 2,632.64 MWD+IFR-AK-CAZ-SC(6) 11,615.20 88.28 17.63 6,260.92 6,113.42 3,226.76 -1,106.46 5,932,996.41 1,620,156.17 2.43 2,726.91 MWD+IFR-AK-CAZ-SC(6) 11,710.79 89.24 20.52 6,262.99 6,115.49 3,317.07 -1,075.23 5,933,086.63 1,620,187.62 3.19 2,822.45 MWD+IFR-AK-CAZ-SC(6) 11,804.91 90.55 21.27 6,263.16 6,115.66 3,404.99 -1,041.66 5,933,174.47 1,620,221.41 1.60 2,916.45 MWD+IFR-AK-CAZ-SC(6) 11,898.63 90.71 19.66 6,262.13 6,114.63 3,492.79 -1,008.89 5,933,262.17 1,620,254.39 1.73 3,010.08 MWD+IFR-AK-CAZ-SC(6) 11,994.43 91.60 19.74 6,260.20 6,112.70 3,582.96 -976.61 5,933,352.25 1,620,286.91 0.93 3,105.81 MWD+IFR-AK-CAZ-SC(6) 12,087.51 92.24 19.82 6,257.08 6,109.58 3,670.50 -945.13 5,933,439.70 1,620,318.61 0.69 3,198.79 MWD+IFR-AK-CAZ-SC(6) 12,182.24 91.26 18.91 6,254.19 6,106.69 3,759.83 -913.73 5,933,528.94 1,620,350.23 1.41 3,293.45 MWD+IFR-AK-CAZ-SC(6) 12,278.29 91.64 24.18 6,251.76 6,104.26 3,849.11 -878.48 5,933,618.12 1,620,385.70 5.50 3,389.25 MWD+IFR-AK-CAZ-SC(6) 12,328.82 92.02 23.57 6,250.14 6,102.64 3,895.29 -858.04 5,933,664.25 1,620,406.25 1.42 3,439.49 MWD+IFR-AK-CAZ-SC(6) 12,372.32 92.77 24.01 6,248.33 6,100.83 3,935.06 -840.51 5,933,703.97 1,620,423.88 2.00 3,482.73 MWD+IFR-AK-CAZ-SC(6) 12,466.67 91.78 24.86 6,244.58 6,097.08 4,020.89 -801.51 5,933,789.69 1,620,463.10 1.38 3,576.41 MWD+IFR-AK-CAZ-SC(6) 12,561.30 90.19 23.56 6,242.95 6,095.45 4,107.18 -762.71 5,933,875.87 1,620,502.11 2.17 3,670.47 MWD+IFR-AK-CAZ-SC(6) 12,656.17 90.44 20.66 6,242.43 6,094.93 4,195.06 -727.01 5,933,963.66 1,620,538.03 3.07 3,765.08 MWD+IFR-AK-CAZ-SC(6) 12,751.22 90.45 13.11 6,241.69 6,094.19 4,285.95 -699.42 5,934,054.46 1,620,565.85 7.94 3,860.04 MWD+IFR-AK-CAZ-SC(6) 12,845.85 90.58 15.87 6,240.84 6,093.34 4,377.55 -675.75 5,934,146.00 1,620,589.75 2.92 3,954.48 MWD+IFR-AK-CAZ-SC(6) 12,935.20 90.40 15.86 6,240.08 6,092.58 4,463.50 -651.33 5,934,231.87 1,620,614.39 0.20 4,043.77 MWD+IFR-AK-CAZ-SC(6) 13,033.35 90.27 16.27 6,239.50 6,092.00 4,557.81 -624.17 5,934,326.11 1,620,641.79 0.44 4,141.86 MWD+IFR-AK-CAZ-SC(6) 13,127.01 91.49 16.88 6,238.07 6,090.57 4,647.57 -597.45 5,934,415.79 1,620,668.73 1.46 4,235.48 MWD+IFR-AK-CAZ-SC(6) 13,220.65 90.97 19.01 6,236.06 6,088.56 4,736.63 -568.61 5,934,504.76 1,620,697.79 2.34 4,329.09 MWD+IFR-AK-CAZ-SC(6) 13,317.85 88.48 20.08 6,236.52 6,089.02 4,828.21 -536.09 5,934,596.26 1,620,730.54 2.79 4,426.24 MWD+IFR-AK-CAZ-SC(6) 13,411.95 90.57 24.34 6,237.30 6,089.80 4,915.30 -500.53 5,934,683.25 1,620,766.31 5.04 4,520.06 MWD+IFR-AK-CAZ-SC(6) 13,476.00 90.57 24.34 6,236.67 6,089.17 4,973.66 -474.14 5,934,741.53 1,620,792.86 0.00 4,583.71 NOT an Actual Survey 4 1/2"x 6-3/4" 13,505.00 90.57 24.34 6,236.38 6,088.88 5,000.08 -462.19 5,934,767.92 1,620,804.87 0.00 4,612.54 PROJECTED to TD Final Definitive Survey Verified and Signed-off All targets and/or wed position objectives have been achieved. Yes ❑ No I have checked to the best of my ability that the following data Is correct: L7 Surface Coordinates 11 Declination & Convergence [] GRS Survey Corrections D Survey Tool Codes Vincent Osara ... "..l SLB DE: 1..9,:,mKalil OM Client Representative: Mike Callahan Date: 03-Nov-2015 11/3/2015 3:58:45PM Page 6 COMPASS 5000.1 Build 74 215159 26465 SchlumbergerDrilling & Measurements Transmittal#: 23NOV15-SP02 DATA LOGGED MWD/LWD Log Product Delivery k.t VA/2015 fv1. K. BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2S-04 Top of Cement Date Dispatched: 23-Nov-15 Job#: 15AKA0091 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 1 Contents on CD N/A SonicScope Top of Cement x x 4869' -8000' MD 2 . Lu LAS Digital Data N/A Contents on CD N/A x Directional Data N/A Contents on CD N/A As-Built Survey N/A Contents on CD N/A CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf x Please sign and email a copy to: Please sign and email a copy to: Richard.E.Elgarico(a�conocophillips.com AlaskaPTSPrintCenter(cr�slb.com Ricky Elgarico Attn:Stephanie Pacillo 907-265-6580 Received By: ✓afi %as'tw / 4 4/ 2 1 5 1 5 9 vac 2 6 4 4 4 o WELL LOG TRANSMITTAL# DATA LOGGED 10/2015 M.K.BENDER To: Alaska Oil and Gas Conservation Comm. November 6, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Pipe Recovery Services: 2S-04 Run Date: 10/5/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2S-04 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20721-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed vat -422, 0 • 'I 6159 26 430 AOGCC SchlumbergerDrilling & Measurements Transmittal#: 05NOV15 SP01DATA LOGGED MWD/LWD LogProduct Delivery « /9/2015 M.K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2S-04PB1 Date Dispatched: 5-Nov-15 Job#: 15AKA0094 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 6 Contents on CD N/A EcoScope 2" MD x x EcoScope 2'TVD x x EcoScope __ 2'TVDSS x x EcoScope 5"MD x x EcoScope 5'TVD x x EcoScope 5'TVDSS x x LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 x x As-Built Survey 1 Contents on CD N/A Nad83 x x CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf/tiff x Surveys:pdf/txt x Please sign and email a copy to: Please sign and email a copy to: Richard.E.Elqaricoconocophillips.com AlaskaPTSPrintCenter@_slb.com Ricky Elgarico Attn: Stephanie Pacillo 907-265-658p) `��`L Received By: { • • 215159 26430 FINAL J NADConversion Kuparuk River Unit Kuparuk 2S Pad 2S-04PB1 RECEIVED S, AOGCC Definitive Survey Report 14 October, 2015 NAD 27 • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-04 Project: Kuparuk River Unit TVD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Well: 2S-04 North Reference: True Wellbore: 2S-04PB1 Survey Calculation Method: Minimum Curvature Design: 2S-04PB1 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2S-04 Well Position +N/-S 0.00 usft Northing: 5,930,017.59 usfl Latitude: 70° 13'11.873 N +EI-W 0.00 usft Easting: 481,221.00 usfl Longitude: 150°9'5.394 W' Position Uncertainty 0.00 usft Wellhead Elevation: usfi Ground Level: 120.00 usft Wellbore 2S-04PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 9/30/2015 18.56 80.87 57,488 Design 2S-04PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.50 - Vertical Section: Depth From(TVD) +N/-S +EI-W Direction (usft) (usft) (usft) (°) 27.50 0.00 0.00 18.00 Survey Program Date 10/14/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 78.00 447.00 2S-04PB1 Srvy#1 -GYD-GC-SS(2S-04 GYD-GC-SS Gyrodata gyro single shots 9/21/2015 8:5; 476.76 2,755.06 2S-04PB1 Srvy#2-MWD+IFR-AK-CAZ-MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/21/2015 9:1 2,785.43 2,785.43 2S-04PB1 Srvy#3-INC+TREND(2S-04 INC+TREND Inclinometer+known azi trend 9/28/2015 8:31 2,881.48 7,729.43 2S-04PB1 Srvy#4-MWD+IFR-AK-CAZ-MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/28/2015 8:3: 7,800.00 7,800.00 2S-04PB1 Srvy#5-Projection to TD(2S BLIND Blind drilling 10/13/2015 1:: Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 27.50 0.00 0.00 27.50 -120.00 0.00 0.00 5,930,017.59 481,221.00 0.00 0.00 UNDEFINED 78.00 0.30 241.15 78.00 -69.50 -0.06 -0.12 5,930,017.53 481,220.88 0.59 -0.10 GYD-GC-SS(1) 170.00 0.45 266.98 170.00 22.50 -0.20 -0.69 5,930,017.39 481,220.31 0.24 -0.40 GYD-GC-SS(1) 263.00 0.52 264.61 262.99 115.49 -0.26 -1.47 5,930,017.34 481,219.53 0.08 -0.70 GYD-GC-SS(1) 355.00 0.64 262.29 354.99 207.49 -0.37 -2.40 5,930,017.23 481,218.60 0.13 -1.09 GYD-GC-SS(1) 447.00 0.58 275.81 446.98 299.48 -0.39 -3.37 5,930,017.21 481,217.63 0.17 -1.41 GYD-GC-SS(1) 476.76 0.31 285.28 476.74 329.24 -0.35 -3.60 5,930,017.25 481,217.40 0.94 -1.45 MWD+IFR-AK-CAZ-SC(2) 567.94 0.04 243.25 567.92 420.42 -0.30 -3.86 5,930,017.30 481,217.14 0.31 -1.48 MWD+IFR-AK-CAZ-SC(2) 660.98 1.43 217.97 660.95 513.45 -1.23 -4.61 5,930,016.37 481,216.39 1.50 -2.59 MWD+IFR-AK-CAZ-SC(2) 696.02 2.12 219.06 695.98 548.48 -2.08 -5.28 5,930,015.52 481,215.71 1.97 -3.61 MWD+IFR-AK-CAZ-SC(2) 10/14/2015 1:14:46PM Page 2 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-04 Project: Kuparuk River Unit TVD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Well: 2S-04 North Reference: True Wellbore: 2S-04PB1 Survey Calculation Method: Minimum Curvature Design: 2S-04PB1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°M00') (ft) Survey Tool Name 757.33 2.58 214.47 757.23 609.73 -4.10 -6.78 5,930,013.51 481,214.21 0.81 -5.99 MWD+IFR-AK-CAZ-SC(2) 853.64 3.59 211.81 853.40 705.90 -8.45 -9.60 5,930,009.17 481,211.38 1.06 -11.00 MWD+IFR-AK-CAZ-SC(2) 948.89 4.60 201.35 948.41 800.91 -14.54 -12.56 5,930,003.08 481,208.41 1.31 -17.71 MWD+IFR-AK-CAZ-SC(2) 1,045.12 7.88 197.52 1,044.06 896.56 -24.43 -15.95 5,929,993.21 481,204.99 3.43 -28.16 MWD+IFR-AK-CAZ-SC(2) 1,140.42 10.66 202.74 1,138.11 990.61 -38.79 -21.33 5,929,978.86 481,199.58 3.04 -43.48 MWD+IFR-AK-CAZ-SC(2) 1,237.11 13.56 204.84 1,232.63 1,085.13 -57.33 -29.55 5,929,960.34 481,191.31 3.03 -63.65 MWD+IFR-AK-CAZ-SC(2) 1,332.94 17.82 206.38 1,324.87 1,177.37 -80.67 -40.79 5,929,937.03 481,180.02 4.47 -89.32 MWD+IFR-AK-CAZ-SC(2) 1,428.89 20.05 207.90 1,415.63 1,268.13 -108.36 -55.01 5,929,909.38 481,165.73 2.38 -120.05 MWD+IFR-AK-CAZ-SC(2) 1,525.28 19.63 209.48 1,506.29 1,358.79 -137.06 -70.71 5,929,880.72 481,149.96 0.71 -152.20 MWD+IFR-AK-CAZ-SC(2) 1,621.34 21.86 208.07 1,596.12 1,448.62 -166.89 -87.06 5,929,850.94 481,133.53 2.38 -185.62 MWD+IFR-AK-CAZ-SC(2) 1,715.89 22.82 207.21 1,683.57 1,536.07 -198.73 -103.73 5,929,819.14 481,116.78 1.07 -221.06 MWD+IFR-AK-CAZ-SC(2) 1,811.64 25.43 208.33 1,770.95 1,623.45 -233.34 -121.98 5,929,784.58 481,098.45 2.77 -259.61 MWD+IFR-AK-CAZ-SC(2) 1,909.25 28.51 211.22 1,857.94 1,710.44 -271.72 -144.01 5,929,746.26 481,076.33 3.43 -302.92 MWD+IFR-AK-CAZ-SC(2) 2,003.73 29.77 212.20 1,940.46 1,792.96 -310.85 -168.19 5,929,707.19 481,052.05 1.43 -347.61 MWD+IFR-AK-CAZ-SC(2) 2,098.75 32.65 215.49 2,021.73 1,874.23 -351.70 -195.65 5,929,666.42 481,024.49 3.52 -394.94 MWD+IFR-AK-CAZ-SC(2) 2,195.36 35.25 219.32 2,101.87 1,954.37 -394.50 -228.46 5,929,623.70 480,991.58 3.48 -445.79 MWD+IFR-AK-CAZ-SC(2) 2,290.95 38.19 223.06 2,178.49 2,030.99 -437.44 -266.13 5,929,580.86 480,953.81 3.86 -498.27 MWD+IFR-AK-CAZ-SC(2) 2,387.10 40.65 224.33 2,252.77 2,105.27 -481.57 -308.31 5,929,536.84 480,911.52 2.69 -553.27 MWD+IFR-AK-CAZ-SC(2) 2,483.15 44.04 225.78 2,323.75 2,176.25 -527.25 -354.11 5,929,491.28 480,865.61 3.67 -610.87 MWD+IFR-AK-CAZ-SC(2) 2,547.93 43.50 225.21 2,370.53 2,223.03 -558.66 -386.07 5,929,459.95 480,833.58 1.03 -650.62 MWD+IFR-AK-CAZ-SC(2) 2,579.52 43.26 226.72 2,393.49 2,245.99 -573.74 -401.67 5,929,444.91 480,817.94 3.37 -669.78 MWD+IFR-AK-CAZ-SC(2) 2,675.03 44.34 227.55 2,462.42 2,314.92 -618.70 -450.13 5,929,400.07 480,769.38 1.28 -727.52 MWD+IFR-AK-CAZ-SC(2) 2,755.06 44.33 227.28 2,519.67 2,372.17 -656.55 -491.31 5,929,362.33 480,728.11 0.24 -776.24 MWD+IFR-AK-CAZ-SC(2) 2,785.43 44.48 227.79 2,541.36 2,393.86 -670.90 -506.98 5,929,348.02 480,712.40 1.27 -794.73 INC+TREND(3) 2,815.00 44.50 227.32 2,562.46 2,414.96 -684.88 -522.27 5,929,334.08 480,697.08 1.12 -812.75 NOT an Actual Survey 10 3/4"x 13 1/2" 2,881.48 44.55 226.26 2,609.85 2,462.35 -716.80 -556.25 5,929,302.25 480,663.03 1.12 -853.61 MWD+IFR-AK-CAZ-SC(4) 2,977.31 44.60 226.74 2,678.12 2,530.62 -763.10 -605.03 5,929,256.08 480,614.13 0.36 -912.71 MWD+IFR-AK-CAZ-SC(4) 3,071.57 44.65 227.98 2,745.21 2,597.71 -807.95 -653.74 5,929,211.35 480,565.32 0.93 -970.42 MWD+IFR-AK-CAZ-SC(4) 3,168.67 44.66 229.23 2,814.28 2,666.78 -853.07 -704.94 5,929,166.36 480,514.01 0.90 -1,029.16 MWD+IFR-AK-CAZ-SC(4) 3,263.71 44.66 230.63 2,881.88 2,734.38 -896.07 -756.05 5,929,123.49 480,462.79 1.04 -1,085.85 MWD+IFR-AK-CAZ-SC(4) 3,361.00 44.66 231.90 2,951.09 2,803.59 -938.86 -809.40 5,929,080.84 480,409.35 0.92 -1,143.03 MWD+IFR-AK-CAZ-SC(4) 3,456.24 44.48 228.26 3,018.94 2,871.44 -981.73 -860.64 5,929,038.10 480,358.00 2.69 -1,199.64 MWD+IFR-AK-CAZ-SC(4) 3,552.55 44.55 226.29 3,087.62 2,940.12 -1,027.54 -910.24 5,928,992.42 480,308.30 1.44 -1,258.53 MWD+IFR-AK-CAZ-SC(4) 3,647.60 44.54 226.21 3,155.37 3,007.87 -1,073.65 -958.40 5,928,946.44 480,260.02 0.06 -1,317.26 MWD+IFR-AK-CAZ-SC(4) 3,743.62 44.62 227.00 3,223.76 3,076.26 -1,119.95 -1,007.37 5,928,900.26 480,210.94 0.58 -1,376.43 MWD+IFR-AK-CAZ-SC(4) 3,839.54 44.49 225.94 3,292.11 3,144.61 -1,166.30 -1,056.17 5,928,854.04 480,162.04 0.79 -1,435.59 MWD+IFR-AK-CAZ-SC(4) 3,935.56 44.45 224.70 3,360.63 3,213.13 -1,213.59 -1,103.99 5,928,806.87 480,114.10 0.91 -1,495.35 MWD+IFR-AK-CAZ-SC(4) 4,031.01 44.58 224.94 3,428.69 3,281.19 -1,261.06 -1,151.16 5,928,759.52 480,066.82 0.22 -1,555.07 MWD+IFR-AK-CAZ-SC(4) 4,126.56 44.57 225.31 3,496.76 3,349.26 -1,308.38 -1,198.69 5,928,712.33 480,019.18 0.27 -1,614.75 MWD+IFR-AK-CAZ-SC(4) 4,223.26 40.97 229.06 3,567.74 3,420.24 -1,353.04 -1,246.78 5,928,667.80 479,970.98 4.56 -1,672.09 MWD+IFR-AK-CAZ-SC(4) i 10/14/2015 1:14:46PM Page 3 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-04 Project: Kuparuk River Unit TVD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Well: 2S-04 North Reference: True Wellbore: 2S-04PB1 Survey Calculation Method: Minimum Curvature Design: 2S-04PB1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,318.98 37.39 232.33 3,641.94 3,494.44 -1,391.37 -1,293.51 5,928,629.58 479,924.16 4.32 -1,722.99 MWD+IFR-AK-CAZ-SC(4) 4,415.63 35.48 236.70 3,719.71 3,572.21 -1,424.72 -1,340.19 5,928,596.36 479,877.40 3.33 -1,769.13 MWD+IFR-AK-CAZ-SC(4) 4,511.12 33.51 239.67 3,798.41 3,650.91 -1,453.25 -1,386.11 5,928,567.94 479,831.42 2.71 -1,810.45 MWD+IFR-AK-CAZ-SC(4) 4,606.71 31.82 244.45 3,878.89 3,731.39 -1,477.45 -1,431.63 5,928,543.86 479,785.84 3.23 -1,847.53 MWD+IFR-AK-CAZ-SC(4) 4,702.88 30.21 250.19 3,961.33 3,813.83 -1,496.59 -1,477.28 5,928,524.83 479,740.14 3.50 -1,879.84 MWD+IFR-AK-CAZ-SC(4) 4,798.41 28.48 255.89 4,044.61 3,897.11 -1,510.29 -1,522.00 5,928,511.25 479,695.40 3.44 -1,906.69 MWD+IFR-AK-CAZ-SC(4) 4,891.71 26.73 261.96 4,127.31 3,979.81 -1,518.65 -1,564.36 5,928,502.99 479,653.02 3.55 -1,927.73 MWD+IFR-AK-CAZ-SC(4) 4,987.74 25.09 266.69 4,213.69 4,066.19 -1,522.84 -1,606.08 5,928,498.90 479,611.30 2.75 -1,944.62 MWD+IFR-AK-CAZ-SC(4) 5,083.19 23.95 268.43 4,300.53 4,153.03 -1,524.54 -1,645.65 5,928,497.30 479,571.73 1.41 -1,958.46 MWD+IFR-AK-CAZ-SC(4) 5,179.21 23.78 271.10 4,388.34 4,240.84 -1,524.71 -1,684.49 5,928,497.23 479,532.89 1.14 -1,970.62 MWD+IFR-AK-CAZ-SC(4) 5,276.11 24.10 276.78 4,476.92 4,329.42 -1,521.99 -1,723.67 5,928,500.04 479,493.72 2.40 -1,980.15 MWD+IFR-AK-CAZ-SC(4) 5,371.57 23.37 280.19 4,564.31 4,416.81 -1,516.34 -1,761.66 5,928,505.79 479,455.75 1.63 -1,986.51 MWD+IFR-AK-CAZ-SC(4) 5,468.54 23.90 288.47 4,653.17 4,505.67 -1,506.72 -1,799.23 5,928,515.51 479,418.20 3.46 -1,988.96 MWD+IFR-AK-CAZ-SC(4) 5,562.91 24.43 296.81 4,739.29 4,591.79 -1,491.85 -1,834.79 5,928,530.46 479,382.69 3.66 -1,985.82 MWD+IFR-AK-CAZ-SC(4) 5,658.75 24.32 305.65 4,826.62 4,679.12 -1,471.40 -1,868.53 5,928,550.99 479,349.00 3.81 -1,976.80 MWD+IFR-AK-CAZ-SC(4) 5,754.18 25.57 314.22 4,913.18 4,765.68 -1,445.58 -1,899.27 5,928,576.88 479,318.33 4.00 -1,961.73 MWD+IFR-AK-CAZ-SC(4) 5,850.08 28.10 321.16 4,998.76 4,851.26 -1,413.54 -1,928.27 5,928,608.99 479,289.41 4.20 -1,940.23 MWD+IFR-AK-CAZ-SC(4) 5,946.05 30.04 326.69 5,082.65 4,935.15 -1,375.85 -1,955.65 5,928,646.75 479,262.13 3.45 -1,912.84 MWD+IFR-AK-CAZ-SC(4) 6,041.42 32.15 331.02 5,164.33 5,016.83 -1,333.69 -1,981.06 5,928,688.96 479,236.83 3.22 -1,880.60 MWD+IFR-AK-CAZ-SC(4) 6,137.35 33.87 335.80 5,244.78 5,097.28 -1,286.97 -2,004.39 5,928,735.74 479,213.62 3.25 -1,843.37 MWD+IFR-AK-CAZ-SC(4) 6,233.12 35.40 340.82 5,323.59 5,176.09 -1,236.42 -2,024.45 5,928,786.34 479,193.69 3.38 -1,801.49 MWD+IFR-AK-CAZ-SC(4) 6,328.67 36.73 342.85 5,400.83 5,253.33 -1,182.97 -2,041.97 5,928,839.82 479,176.30 1.87 -1,756.08 MWD+IFR-AK-CAZ-SC(4) 6,425.03 37.33 345.47 5,477.76 5,330.26 -1,127.15 -2,057.79 5,928,895.67 479,160.61 1.75 -1,707.88 MWD+IFR-AK-CAZ-SC(4) 6,521.61 39.51 347.41 5,553.43 5,405.93 -1,068.81 -2,071.84 5,928,954.04 479,146.72 2.58 -1,656.74 MWD+IFR-AK-CAZ-SC(4) 6,617.13 42.16 349.65 5,625.70 5,478.20 -1,007.61 -2,084.22 5,929,015.27 479,134.48 3.17 -1,602.35 MWD+IFR-AK-CAZ-SC(4) 6,713.19 44.54 350.61 5,695.55 5,548.05 -942.65 -2,095.51 5,929,080.25 479,123.36 2.57 -1,544.06 MWD+IFR-AK-CAZ-SC(4) 6,809.07 48.08 352.73 5,761.77 5,614.27 -874.06 -2,105.52 5,929,148.85 479,113.52 4.02 -1,481.93 MWD+IFR-AK-CAZ-SC(4) 6,903.59 51.65 355.00 5,822.69 5,675.19 -802.23 -2,113.20 5,929,220.70 479,106.02 4.20 -1,415.98 MWD+IFR-AK-CAZ-SC(4) 7,000.64 54.62 357.07 5,880.91 5,733.41 -724.79 -2,118.54 5,929,298.15 479,100.87 3.50 -1,343.98 MWD+IFR-AK-CAZ-SC(4) 7,096.65 57.93 0.79 5,934.22 5,786.72 -644.98 -2,119.98 5,929,377.95 479,099.63 4.72 -1,268.52 MWD+IFR-AK-CAZ-SC(4) 7,191.66 60.72 4.50 5,982.70 5,835.20 -563.38 -2,116.17 5,929,459.53 479,103.64 4.46 -1,189.74 MWD+IFR-AK-CAZ-SC(4) 7,287.73 61.75 6.28 6,028.93 5,881.43 -479.55 -2,108.26 5,929,543.34 479,111.77 1.95 -1,107.56 MWD+IFR-AK-CAZ-SC(4) 7,364.26 62.00 7.94 6,065.01 5,917.51 -412.58 -2,099.90 5,929,610.28 479,120.29 1.94 -1,041.29 MWD+IFR-AK-CAZ-SC(4) 7,383.13 62.47 7.85 6,073.80 5,926.30 -396.04 -2,097.61 5,929,626.81 479,122.62 2.53 -1,024.85 MWD+IFR-AK-CAZ-SC(4) 7,439.43 63.75 9.08 6,099.27 5,951.77 -346.37 -2,090.22 5,929,676.45 479,130.14 2.99 -975.33 MWD+I F R-AK-CAZ-SC(4) 7,479.98 63.87 9.01 6,117.16 5,969.66 -310.44 -2,084.50 5,929,712.37 479,135.95 0.33 -939.39 MWD+IFR-AK-CAZ-SC(4) 7,575.45 65.10 10.69 6,158.29 6,010.79 -225.56 -2,069.75 5,929,797.20 479,150.90 2.04 -854.11 MWD+IFR-AK-CAZ-SC(4) 7,669.77 67.56 12.72 6,196.15 6,048.65 -140.98 -2,052.21 5,929,881.73 479,168.65 3.27 -768.25 MWD+IFR-AK-CAZ-SC(4) 7,729.43 70.09 14.00 6,217.70 6,070.20 -86.87 -2,039.36 5,929,935.81 479,181.64 4.69 -712.81 MWD+IFR-AK-CAZ-SC (4) 7,800.00 72.50 15.00 6,240.33 6,092.83 -22.16 -2,022.62 5,930,000.47 479,198.54 3.67 -646.10 Projected to TD 10/14/2015 1:14:46PM Page 4 COMPASS 5000.1 Build 74 • Schlumberger • • Definitive Survey Report Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. Yes ❑ No I have checked to the best of my ability that the following data is correct: U Surface Coordinates Fl Declination & Convergence LJ GRS Survey Corrections Digt*.signed brVincent osaa rd Survey Tool Codes Vincent cn=vincerit Our* ou=scNumberger. Osa ra email r tw= SLB DE: Date:MS.10.1412MS"-0800 ay.wr�qq�aara.caa.. u.m rGCJ..lwl a cvnm4ec.wJ, Client Representative: Mike Callahan =T." , Yw2011101-4I2S534 Date: I4-Oct-2015 10/14/2015 1:14:46PM Page 5 COMPASS 5000.1 Build 74 • • 21 5159 26 430 FINAL \ J ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad 2S-04PB1 RECE1VEL NOV 05 2dij AOGCC Definitive Survey Report 14 October, 2015 NAD 83 • Schlumberger • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-04 Project: Kuparuk River Unit TVD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Well: 2S-04 North Reference: True Wellbore: 2S-04PB1 Survey Calculation Method: Minimum Curvature Design: 2S-04PB1 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well Rig:2S-04 Well Position +N/-S 0.00 usft Northing: 5,929,767.18 usfl Latitude: 70°13'10.753 N +E/-W 0.00 usft Easting: 1,621,254.32 usft Longitude: 150°9'16.543 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 120.00 usft Wellbore 2S-04PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 9/30/2015 18.56 80.87 57,488 Design 2S-04PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.50 Vertical Section: Depth From(TVD) +N/-S +EI-W Direction (usft) (usft) (usft) (°) 27.50 0.00 0.00 18.00 Survey Program Date 10/14/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 78.00 447.00 2S-04PB1 Srvy#1 -GYD-GC-SS(Rig:2 GYD-GC-SS Gyrodata gyro single shots 9/21/2015 8:5 476.76 2,755.06 2S-04PB1 Srvy#2-MWD+IFR-AK-CAZ-MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/21/2015 9:1 2,785.43 2,785.43 2S-04PB1 Srvy#3-INC+TREND(Rig:2 INC+TREND Inclinometer+known azi trend 9/28/2015 8:31 2,881.48 7,729.43 2S-04PB1 Srvy#4-MWD+IFR-AK-CAZ-MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/28/2015 8:3: 7,800.00 7,800.00 2S-04PB1 Srvy#5-Projection to TD(Ric BLIND Blind drilling 10/13/2015 1:: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 27.50 0.00 0.00 27.50 -120.00 0.00 0.00 5,929,767.18 1,621,254.32 0.00 0.00 UNDEFINED 78.00 0.30 241.15 78.00 -69.50 -0.06 -0.12 5,929,767.12 1,621,254.20 0.59 -0.10 GYD-GC-SS(1) 170.00 0.45 266.98 170.00 22.50 -0.20 -0.69 5,929,766.98 1,621,253.63 0.24 -0.40 GYD-GC-SS(1) 263.00 0.52 264.61 262.99 115.49 -0.26 -1.47 5,929,766.93 1,621,252.84 0.08 -0.70 GYD-GC-SS(1) 355.00 0.64 262.29 354.99 207.49 -0.37 -2.40 5,929,766.82 1,621,251.92 0.13 -1.09 GYD-GC-SS(1) 447.00 0.58 275.81 446.98 299.48 -0.39 -3.37 5,929,766.80 1,621,250.95 0.17 -1.41 GYD-GC-SS(1) 476.76 0.31 285.28 476.74 329.24 -0.35 -3.60 5,929,766.84 1,621,250.72 0.94 -1.45 MWD+IFR-AK-CAZ-SC(2) 567.94 0.04 243.25 567.92 420.42 -0.30 -3.86 5,929,766.89 1,621,250.45 0.31 -1.48 MWD+IFR-AK-CAZ-SC(2) 660.98 1.43 217.97 660.95 513.45 -1.23 -4.61 5,929,765.96 1,621,249.71 1.50 -2.59 MWD+IFR-AK-CAZ-SC(2) 696.02 2.12 219.06 695.98 548.48 -2.08 -5.28 5,929,765.12 1,621,249.03 1.97 -3.61 MWD+IFR-AK-CAZ-SC(2) 10/14/2015 12:17:44PM Page 2 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-04 Project: Kuparuk River Unit TVD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Well: 2S-04 North Reference: True Wellbore: 2S-04PB1 Survey Calculation Method: Minimum Curvature Design: 2S-04PB1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 757.33 2.58 214.47 757.23 609.73 -4.10 -6.78 5,929,763.10 1,621,247.53 0.81 -5.99 MWD+IFR-AK-CAZ-SC(2) 853.64 3.59 211.81 853.40 705.90 -8.45 -9.60 5,929,758.76 1,621,244.70 1.06 -11.00 MWD+IFR-AK-CAZ-SC(2) 948.89 4.60 201.35 948.41 800.91 -14.54 -12.56 5,929,752.68 1,621,241.72 1.31 -17.71 MWD+IFR-AK-CAZ-SC(2) 1,045.12 7.88 197.52 1,044.06 896.56 -24.43 -15.95 5,929,742.80 1,621,238.31 3.43 -28.16 MWD+IFR-AK-CAZ-SC(2) 1,140.42 10.66 202.74 1,138.11 990.61 -38.79 -21.33 5,929,728.45 1,621,232.90 3.04 -43.48 MWD+IFR-AK-CAZ-SC(2) 1,237.11 13.56 204.84 1,232.63 1,085.13 -57.33 -29.55 5,929,709.94 1,621,224.63 3.03 -63.65 MWD+IFR-AK-CAZ-SC(2) 1,332.94 17.82 206.38 1,324.87 1,177.37 -80.67 -40.79 5,929,686.62 1,621,213.33 4.47 -89.32 MWD+IFR-AK-CAZ-SC(2) 1,428.89 20.05 207.90 1,415.63 1,268.13 -108.36 -55.01 5,929,658.97 1,621,199.04 2.38 -120.05 MWD+IFR-AK-CAZ-SC(2) 1,525.28 19.63 209.48 1,506.29 1,358.79 -137.06 -70.71 5,929,630.32 1,621,183.27 0.71 -152.20 MWD+IFR-AK-CAZ-SC(2) 1,621.34 21.86 208.07 1,596.12 1,448.62 -166.89 -87.06 5,929,600.53 1,621,166.84 2.38 -185.62 MWD+IFR-AK-CAZ-SC(2) 1,715.89 22.82 207.21 1,683.57 1,536.07 -198.73 -103.73 5,929,568.74 1,621,150.09 1.07 -221.06 MWD+IFR-AK-CAZ-SC(2) 1,811.64 25.43 208.33 1,770.95 1,623.45 -233.34 -121.98 5,929,534.17 1,621,131.76 2.77 -259.61 MWD+IFR-AK-CAZ-SC(2) 1,909.25 28.51 211.22 1,857.94 1,710.44 -271.72 -144.01 5,929,495.85 1,621,109.64 3.43 -302.92 MWD+IFR-AK-CAZ-SC(2) 2,003.73 29.77 212.20 1,940.46 1,792.96 -310.85 -168.19 5,929,456.79 1,621,085.35 1.43 -347.61 MWD+IFR-AK-CAZ-SC(2) 2,098.75 32.65 215.49 2,021.73 1,874.23 -351.70 -195.65 5,929,416.02 1,621,057.79 3.52 -394.94 MWD+IFR-AK-CAZ-SC(2) 2,195.36 35.25 219.32 2,101.87 1,954.37 -394.50 -228.46 5,929,373.30 1,621,024.88 3.48 -445.79 MWD+IFR-AK-CAZ-SC(2) 2,290.95 38.19 223.06 2,178.49 2,030.99 -437.44 -266.13 5,929,330.46 1,620,987.11 3.86 -498.27 MWD+IFR-AK-CAZ-SC(2) 2,387.10 40.65 224.33 2,252.77 2,105.27 -481.57 -308.31 5,929,286.44 1,620,944.81 2.69 -553.27 MWD+IFR-AK-CAZ-SC(2) 2,483.15 44.04 225.78 2,323.75 2,176.25 -527.25 -354.11 5,929,240.89 1,620,898.90 3.67 -610.87 MWD+IFR-AK-CAZ-SC(2) 2,547.93 43.50 225.21 2,370.53 2,223.03 -558.66 -386.07 5,929,209.56 1,620,866.86 1.03 -650.62 MWD+IFR-AK-CAZ-SC(2) 2,579.52 43.26 226.72 2,393.49 2,245.99 -573.74 -401.67 5,929,194.52 1,620,851.23 3.37 -669.78 MWD+IFR-AK-CAZ-SC(2) 2,675.03 44.34 227.55 2,462.42 2,314.92 -618.70 -450.13 5,929,149.68 1,620,802.67 1.28 -727.52 MWD+IFR-AK-CAZ-SC(2) 2,755.06 44.33 227.28 2,519.67 2,372.17 -656.55 -491.31 5,929,111.95 1,620,761.40 0.24 -776.24 MWD+IFR-AK-CAZ-SC(2) 2,785.43 44.48 227.79 2,541.36 2,393.86 -670.90 -506.98 5,929,097.64 1,620,745.68 1.27 -794.73 INC+TREND(3) 2,815.00 44.50 227.32 2,562.46 2,414.96 -684.88 -522.27 5,929,083.69 1,620,730.36 1.12 -812.75 I NOT an Actual Survey 4) 10 3/4"x 13 1/2" 2,881.48 44.55 226.26 2,609.85 2,462.35 -716.80 -556.25 5,929,051.87 1,620,696.31 1.12 -853.61 MWD+IFR-AK-CAZ-SC(4) 2,977.31 44.60 226.74 2,678.12 2,530.62 -763.10 -605.03 5,929,005.70 1,620,647.41 0.36 -912.71 MWD+IFR-AK-CAZ-SC(4) 3,071.57 44.65 227.98 2,745.21 2,597.71 -807.95 -653.74 5,928,960.98 1,620,598.59 0.93 -970.42 MWD+IFR-AK-CAZ-SC(4) 3,168.67 44.66 229.23 2,814.28 2,666.78 -853.07 -704.94 5,928,915.99 1,620,547.29 0.90 -1,029.16 MWD+IFR-AK-CAZ-SC(4) 3,263.71 44.66 230.63 2,881.88 2,734.38 -896.07 -756.05 5,928,873.12 1,620,496.07 1.04 -1,085.85 MWD+IFR-AK-CAZ-SC(4) 3,361.00 44.66 231.90 2,951.09 2,803.59 -938.86 -809.40 5,928,830.47 1,620,442.62 0.92 -1,143.03 MWD+IFR-AK-CAZ-SC(4) 3,456.24 44.48 228.26 3,018.94 2,871.44 -981.73 -860.64 5,928,787.73 1,620,391.27 2.69 -1,199.64 MWD+IFR-AK-CAZ-SC(4) 3,552.55 44.55 226.29 3,087.62 2,940.12 -1,027.54 -910.24 5,928,742.05 1,620,341.56 1.44 -1,258.53 MWD+IFR-AK-CAZ-SC(4) 3,647.60 44.54 226.21 3,155.37 3,007.87 -1,073.65 -958.40 5,928,696.07 1,620,293.29 0.06 -1,317.26 MWD+IFR-AK-CAZ-SC(4) 3,743.62 44.62 227.00 3,223.76 3,076.26 -1,119.95 -1,007.37 5,928,649.90 1,620,244.20 0.58 -1,376.43 MWD+IFR-AK-CAZ-SC(4) 3,839.54 44.49 225.94 3,292.11 3,144.61 -1,166.30 -1,056.17 5,928,603.68 1,620,195.30 0.79 -1,435.59 MWD+IFR-AK-CAZ-SC(4) 3,935.56 44.45 224.70 3,360.63 3,213.13 -1,213.59 -1,103.99 5,928,556.51 1,620,147.36 0.91 -1,495.35 MWD+IFR-AK-CAZ-SC(4) 4,031.01 44.58 224.94 3,428.69 3,281.19 -1,261.06 -1,151.16 5,928,509.17 1,620,100.07 0.22 -1,555.07 MWD+IFR-AK-CAZ-SC(4) 4,126.56 44.57 225.31 3,496.76 3,349.26 -1,308.38 -1,198.69 5,928,461.98 1,620,052.43 0.27 -1,614.75 MWD+IFR-AK-CAZ-SC(4) 4,223.26 40.97 229.06 3,567.74 3,420.24 -1,353.04 -1,246.78 5,928,417.45 1,620,004.23 4.56 -1,672.09 MWD+IFR-AK-CAZ-SC(4) 10/14/2015 12:17:44PM Page 3 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-04 Project: Kuparuk River Unit TVD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Site: Kuparuk 2S Pad MD Reference: Actual:27.5+120 @ 147.50usft(Doyon141) Well: 2S-04 North Reference: True Wellbore: 2S-04PB1 Survey Calculation Method: Minimum Curvature Design: 2S-04PB1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,318.98 37.39 232.33 3,641.94 3,494.44 -1,391.37 -1,293.51 5,928,379.23 1,619,957.41 4.32 -1,722.99 MWD+IFR-AK-CAZ-SC(4) 4,415.63 35.48 236.70 3,719.71 3,572.21 -1,424.72 -1,340.19 5,928,346.01 1,619,910.65 3.33 -1,769.13 MWD+IFR-AK-CAZ-SC(4) 4,511.12 33.51 239.67 3,798.41 3,650.91 -1,453.25 -1,386.11 5,928,317.60 1,619,864.66 2.71 -1,810.45 MWD+IFR-AK-CAZ-SC(4) 4,606.71 31.82 244.45 3,878.89 3,731.39 -1,477.45 -1,431.63 5,928,293.52 1,619,819.08 3.23 -1,847.53 MWD+IFR-AK-CAZ-SC(4) 4,702.88 30.21 250.19 3,961.33 3,813.83 -1,496.59 -1,477.28 5,928,274.50 1,619,773.39 3.50 -1,879.84 MWD+IFR-AK-CAZ-SC(4) 4,798.41 28.48 255.89 4,044.61 3,897.11 -1,510.29 -1,522.00 5,928,260.91 1,619,728.64 3.44 -1,906.69 MWD+IFR-AK-CAZ-SC(4) 4,891.71 26.73 261.96 4,127.31 3,979.81 -1,518.65 -1,564.36 5,928,252.66 1,619,686.26 3.55 -1,927.73 MWD+IFR-AK-CAZ-SC(4) 4,987.74 25.09 266.69 4,213.69 4,066.19 -1,522.84 -1,606.08 5,928,248.57 1,619,644.54 2.75 -1,944.62 MWD+IFR-AK-CAZ-SC(4) 5,083.19 23.95 268.43 4,300.53 4,153.03 -1,524.54 -1,645.65 5,928,246.97 1,619,604.97 1.41 -1,958.46 MWD+IFR-AK-CAZ-SC(4) 5,179.21 23.78 271.10 4,388.34 4,240.84 -1,524.71 -1,684.49 5,928,246.91 1,619,566.13 1.14 -1,970.62 MWD+IFR-AK-CAZ-SC(4) 5,276.11 24.10 276.78 4,476.92 4,329.42 -1,521.99 -1,723.67 5,928,249.72 1,619,526.96 2.40 -1,980.15 MWD+IFR-AK-CAZ-SC(4) 5,371.57 23.37 280.19 4,564.31 4,416.81 -1,516.34 -1,761.66 5,928,255.46 1,619,488.99 1.63 -1,986.51 MWD+IFR-AK-CAZ-SC(4) 5,468.54 23.90 288.47 4,653.17 4,505.67 -1,506.72 -1,799.23 5,928,265.19 1,619,451.45 3.46 -1,988.96 MWD+IFR-AK-CAZ-SC(4) 5,562.91 24.43 296.81 4,739.29 4,591.79 -1,491.85 -1,834.79 5,928,280.14 1,619,415.93 3.66 -1,985.82 MWD+IFR-AK-CAZ-SC(4) 5,658.75 24.32 305.65 4,826.62 4,679.12 -1,471.40 -1,868.53 5,928,300.67 1,619,382.25 3.81 -1,976.80 MWD+IFR-AK-CAZ-SC(4) 5,754.18 25.57 314.22 4,913.18 4,765.68 -1,445.58 -1,899.27 5,928,326.57 1,619,351.58 4.00 -1,961.73 MWD+IFR-AK-CAZ-SC(4) 5,850.08 28.10 321.16 4,998.76 4,851.26 -1,413.54 -1,928.27 5,928,358.68 1,619,322.65 4.20 -1,940.23 MWD+IFR-AK-CAZ-SC(4) 5,946.05 30.04 326.69 5,082.65 4,935.15 -1,375.85 -1,955.65 5,928,396.44 1,619,295.38 3.45 -1,912.84 MWD+IFR-AK-CAZ-SC(4) 6,041.42 32.15 331.02 5,164.33 5,016.83 -1,333.69 -1,981.06 5,928,438.65 1,619,270.08 3.22 -1,880.60 MWD+IFR-AK-CAZ-SC(4) 6,137.35 33.87 335.80 5,244.78 5,097.28 -1,286.97 -2,004.39 5,928,485.43 1,619,246.87 3.25 -1,843.37 MWD+IFR-AK-CAZ-SC(4) 6,233.12 35.40 340.82 5,323.59 5,176.09 -1,236.42 -2,024.45 5,928,536.03 1,619,226.94 3.38 -1,801.49 MWD+IFR-AK-CAZ-SC(4) 6,328.67 36.73 342.85 5,400.83 5,253.33 -1,182.97 -2,041.97 5,928,589.51 1,619,209.56 1.87 -1,756.08 MWD+IFR-AK-CAZ-SC(4) 6,425.03 37.33 345.47 5,477.76 5,330.26 -1,127.15 -2,057.79 5,928,645.37 1,619,193.87 1.75 -1,707.88 MWD+IFR-AK-CAZ-SC(4) 6,521.61 39.51 347.41 5,553.43 5,405.93 -1,068.81 -2,071.84 5,928,703.74 1,619,179.98 2.58 -1,656.74 MWD+IFR-AK-CAZ-SC(4) 6,617.13 42.16 349.65 5,625.70 5,478.20 -1,007.61 -2,084.22 5,928,764.96 1,619,167.75 3.17 -1,602.35 MWD+IFR-AK-CAZ-SC(4) 6,713.19 44.54 350.61 5,695.55 5,548.05 -942.65 -2,095.51 5,928,829.95 1,619,156.63 2.57 -1,544.06 MWD+IFR-AK-CAZ-SC(4) 6,809.07 48.08 352.73 5,761.77 5,614.27 -874.06 -2,105.52 5,928,898.55 1,619,146.80 4.02 -1,481.93 MWD+IFR-AK-CAZ-SC(4) 6,903.59 51.65 355.00 5,822.69 5,675.19 -802.23 -2,113.20 5,928,970.40 1,619,139.30 4.20 -1,415.98 MWD+IFR-AK-CAZ-SC(4) 7,000.64 54.62 357.07 5,880.91 5,733.41 -724.79 -2,118.54 5,929,047.85 1,619,134.15 3.50 -1,343.98 MWD+IFR-AK-CAZ-SC(4) 7,096.65 57.93 0.79 5,934.22 5,786.72 -644.98 -2,119.98 5,929,127.65 1,619,132.92 4.72 -1,268.52 MWD+IFR-AK-CAZ-SC(4) 7,191.66 60.72 4.50 5,982.70 5,835.20 -563.38 -2,116.17 5,929,209.23 1,619,136.93 4.46 -1,189.74 MWD+IFR-AK-CAZ-SC(4) 7,287.73 61.75 6.28 6,028.93 5,881.43 -479.55 -2,108.26 5,929,293.03 1,619,145.06 1.95 -1,107.56 MWD+IFR-AK-CAZ-SC(4) 7,364.26 62.00 7.94 6,065.01 5,917.51 -412.58 -2,099.90 5,929,359.98 1,619,153.58 1.94 -1,041.29 MWD+IFR-AK-CAZ-SC(4) 7,383.13 62.47 7.85 6,073.80 5,926.30 -396.04 -2,097.61 5,929,376.51 1,619,155.92 2.53 -1,024.85 MWD+IFR-AK-CAZ-SC(4) 7,439.43 63.75 9.08 6,099.27 5,951.77 -346.37 -2,090.22 5,929,426.15 1,619,163.44 2.99 -975.33 MWD+IFR-AK-CAZ-SC(4) 7,479.98 63.87 9.01 6,117.16 5,969.66 -310.44 -2,084.50 5,929,462.06 1,619,169.25 0.33 -939.39 MWD+IFR-AK-CAZ-SC(4) 7,575.45 65.10 10.69 6,158.29 6,010.79 -225.56 -2,069.75 5,929,546.90 1,619,184.21 2.04 -854.11 MWD+IFR-AK-CAZ-SC(4) 7,669.77 67.56 12.72 6,196.15 6,048.65 -140.98 -2,052.21 5,929,631.42 1,619,201.96 3.27 -768.25 MWD+IFR-AK-CAZ-SC(4) 7,729.43 70.09 14.00 6,217.70 6,070.20 -86.87 -2,039.36 5,929,685.50 1,619,214.95 4.69 -712.81 MWD+IFR-AK-CAZ-SC(4) 7,800.00 72.50 15.00 6,240.33 6,092.83 -22.16 -2,022.62 5,929,750.16 1,619,231.85 3.67 -646.10 BLIND(5) 10/14/2015 12:17:44PM Page 4 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. Yes ❑ No !have checked to the best of my ability that the following data is correct: J Surface Coordinates ❑ Declination & Convergence GRS Survey Corrections °loyaltysired byvmcencOsa. DN_ H Survey Tool Codes Vincent m-> entOsara. a Schlumberger. ou Schlumberger. Qs a ra small=vosaraeslb.corn.c-us SLB DE: Date:24315.10.14123034-08'00 Mike Callahan---,— Client Representative: h Date: 14-Oct-2015 10/14/2015 12:17:44PM Page 5 COMPASS 5000.1 Build 74 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 1 ° DATE: 10/10/15 P. I. Supervisor FROM: Bob Noble SUBJECT: Pressure Integrity Test Petroleum Inspector KRU 2S-04 CPAI Doyon Rig 141 PTD 2151590 10/10/15: Brian Bixby and I traveled to Doyon Rig 141 at CPAI's KRU 2S-pad to witness a pressure integrity test on open-hole plugs in well KRU 2S-04. On arrival at Doyon 141 we got with CPAI representative Dave Coates and went over their procedure for doing a FIT test on the well. Dave told us that they had set an open-hole plug — cement top tagged at 5957 ft measured depth — to isolate a severe loss circulation zone; the well continued to experience fluid losses. A second plug was set with a cement top at 5035 ft measured depth and the well was still experiencing some fluid loss. A third plug was set on top of the second plug with a final cement top at 4877 ft measured depth. The drill pipe was pulled up to the bottom of the surface casing shoe at 2815' measured depth and the pressure integrity test was started. There was 11.3ppg mud in the well; the target equivalent mud weight for the integrity test was 12.5ppg (pressure up to 160 psi). Details of the pressure integrity test are attached. - Summary: We witnessed a successful pressure integrity test of isolation plugs set in KRU 2S-04. 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', Boz .1:0. 10- 11.0.11fiMer lirlillki4OW 1P'- IliWIMAI=FriftsrsiimWP oar imililialaW °I.11011111.410 II IIMPIN 01011100.111111r.ft ill* 001111.IUMAIN, \ \ \ 011.0009 roialWarer orriessiffearr hhhil 4 I IWO oo MI% NOE N V 1u111111111III1 fignimillriTibillir 1u tate �� y1111111111111o� SX % 04 � b ��11111111111114 oll o v3o 1 "1/440114' Iii ISO? \ 044ilasts ,Af4 oit„Ato„„ki„ li hi 1 SEM N ir114101110 ...0......... s000 "'PA amr=11111.5% 'i V 1100 ft 41.1"jalm...rjillifil-ds° 4,.. ..mwrarmiiMg i fi 444,7401 +741.1a000 . r44 ai*V 3 3000 i.M00 __al IX Or Ap%t&M.PJAWMPAria,010. 1°, *Cr-7 / 4114141441441.71roir2000 nom illaNWIIIWAt Opp 0 • • prig ZcS-l�� Loepp, Victoria T (DOA) From: Noble, Robert C (DOA) Sent: Saturday, October 10, 2015 4:58 PM To: Regg,James B (DOA); Loepp, Victoria T (DOA) Subject: FIT test, KRU, 2S-04, PTD 215-159 Attachments: FIT Test, KRU, 2S-04, PTD 215-159, 10-10-15, bn.docx Follow Up Flag: Follow up Flag Status: Flagged Bob Noble AOGCC 333 W. 7th Ave. Ste. 100 Anch AK. 99501 Cell 907-299-1362 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Bob Noble at 907-299-1362 or bob.noble@alaska.gov MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 10/10/15 P. I. Supervisor FROM: Bob Noble SUBJECT: FIT Test Petroleum Inspector KRU 2S-04 CPA PTD# 215-159 10/10/15: Brian Bixbe and myself traveled to CPA, KRU, 2S-04 to witness a FIT test on their well. On arrival on location we got with CPA rep. Dave Coates and went over their procedure for doing a FIT test on the well. Dave told us that they had set the second plug with a TOC at 5035'. They still had fluid loss so they sent another plug on top of the second plug with a TOC of 4877'. The drill pipe was pulled up to the bottom of the surface casing shoe at 2815' MD and the FIT test was started. 160 psi at surface = 12.5 MW. Min. PSI. Int. 165 1 min 165 2 min 160 3 min 160 4 min 160 5 min 158 6 min 156 7min 154 8 min 152 9 min 152 10 min 152 Summary: Attachments: [File name] Page 1 of 1 • • PTD 215--15-1 Loepp, Victoria T (DOA) From: Voss,Jake <Jake.Voss@conocophillips.com> Sent: Friday, October 09, 2015 1:51 PM To: Callahan, Mike S; Loepp, Victoria T (DOA) Cc: Regg,James B (DOA); DOA AOGCC Prudhoe Bay; Doyon 141 Company Man; Herbert, Frederick 0; Bearden,J Daniel; Brunswick, Scott A Subject: PTD#215-159: 2S-04 Attachments: 2S-04 Proposed Schematic_10-9-15.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, I am covering for Mike Callahan for the weekend and wanted to give you an updated on PTD#215-159:Well 2S-04. We pumped our 15.8 ppg Isolation Plug(Cement plug#2 for the well)after setting an External Casing Packer at 5,600' MD (just above the C-37—5,612' MD) at Midnight. We continued to experience static losses at—15 bph. We just tagged the TOC at 5,005' MD which was right on depth for our 600' plug.This leads us to believe that our loss zone is higher and is estimated to be due to a fault right around 4980' MD. Our updated plan forward is as followed: • Pump an additional 400 ft 15.8 ppg Isolation Plug(Plug#3) on top of Plug#2. • WOC Cement until we reach 500 psi compressive strength,tag TOC and FIT to 12.5 to ensure integrity. (This assumes losses are healed, if we continue to experience losses,we will update our plan forward based on our TOC for Plug#3) • Proceed with original plan forward with 17#kick off plug and sidetrack the well (State to Witness TOC Tag). Attached is a schematic with the Proposed design prior to drilling out the sidetrack, showing the cement plug's placement. Please let me know if you have any questions. Thanks, Jake Voss r Drilling Engineer I ConocoPhillips Alaska I Office: (907)265-6935 I Mobile:(832)-499-9085 From: Callahan, Mike S Sent: Monday, October 05, 2015 12:27 PM To: Loepp, Victoria T(DOA) Cc: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Doyon 141 Company Man; Herbert, Frederick 0; Bearden, J Daniel; Voss, Jake Subject: RE: [EXTERNAL]Re: PTD# 215-159 2S-04 Notification of BOPE Use per Guidance Bulletin 10-003 A quick update: We just tagged the top of cement in the drill pipe on e-line. The top of cement came in at 5,957' MD,giving us 1,725' of cement inside the pipe down to the string TD at 7,682' MD. That calculates to 19.5 bbls out of the 123 bbls of cement 1 • • we pumped, leaving 103.5 bbls in the annulus. The 103.5 bbls of cement in the annulus gives a calculated cement height of 6,721' MD (961' of cement) with a 30%washed out hole, or 6,407' MD (1,275' of cement) in a perfectly gauge hole. Thanks, Mike From: Callahan, Mike S Sent: Monday, October 05, 2015 9:56 AM To: Loepp, Victoria T(DOA) Cc: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Doyon 141 Company Man; Herbert, Frederick 0; Bearden, J Daniel; Voss, Jake Subject: RE: [EXTERNAL]Re: PTD# 215-159 2S-04 Notification of BOPE Use per Guidance Bulletin 10-003 Victoria et al., here is our latest status update and proposed plan forward: We repaired the Dynamatic and continued running in hole with our cement stinger. The trip in hole was fairly smooth until the last couple hundred feet. We worked the pipe down to 7,747' MD, 53'from TD, but were packed off when we attempted to circulate. In order to get circulation we had to pull to 7,682' MD, 118'from bottom. From there we pumped our cement abandonment plug as planned. The job went well and showed good lift pressure (we did not have returns, as we continue to lose into our suspected loss zone at 6,500', but the lift pressure indicated that cement was lifted throughout the job). After pumping the cement,our pipe was stuck, and we were unable to work it free. Because the cement job went well and we were confident we got a good plug, we decided to leave the pipe cemented rather than getting too aggressive trying to free it. Currently the cement has been in place for approximately 14 hours—the time to build 500 psi compressive strength was about 10 hours. We are currently rigging up e-line to run in hole and tag the cement inside our drill pipe/cement stinger. Once we get that depth,we will be able to calculate exactly how much cement we got around the outside of the pipe. Because of the cutoff pipe left in the cement,we will not be able to tag the top of the plug on the outside of the pipe. We will have the height of the cement inside our pipe and a calculated height outside the pipe, combined with our pumping data that gives us a high level of confidence that we have a good cement plug. Based on volumes pumped, our cement top inside the pipe at the end of our displacement was 5,412' MD, and the height of cement in the annulus was 6,435' MD, assuming 30%excess hole. We expect that they should have come close to balanced after we stopped pumping, and will be able to determine where after we tag the cement inside the pipe. Our pump pressure increased from ^'700 psi as cement exited the shoe to just over 3,000 psi at the end of the displacement, a good indication that we were lifting cement the entire time. Once we are able to cut our drill pipe and pull out of the hole,we would like to proceed on with the plan I sent you on Saturday. The only modification to that will be tagging on the inside of the pipe and calculating cement height outside the pipe, as opposed to the original planned tag of the abandonment plug with no pipe left in the hole. We also are now planning to set an external casing packer(ECP) below each of our next two cement plugs to provide a base for cement and reduce the likely hood of the cement dropping. We will pump the same plugs as planned, and still be able to tag and pressure test after setting our plug above the top of the C-37. I have attached two schematics,one of our current situation and one of our proposed abandonment plan for this intermediate hole. The kickoff will still happen from the surface casing shoe, as outlined in the previous email. Please let me know if you have any questions or would like to discuss further. Mike Callahan 2 • • Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office: (907) 263-4180 Cell: (907) 231-2176 From: Callahan, Mike S Sent: Saturday, October 03, 2015 3:13 PM To: Loepp, Victoria T(DOA) Cc: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Doyon 141 Company Man; Herbert, Frederick 0; Bearden, J Daniel; Voss, Jake Subject: Re: [EXTERNAL]Re: PTD# 215-159 2S-04 Notification of BOPE Use per Guidance Bulletin 10-003 Victoria, here is a quick update on our status and plan forward: We have pulled the BHA out of the hole and are in the process of tripping back in to set the cement abandonment and kickoff plugs. The Dynamatic on our draw works has failed, so we are currently sitting at our surface casing shoe while we prepare to replace it. The well is on very slight static losses,and we are pumping just enough to keep the hole full. Once repaired,we will run in and set the cement abandonment plug as planned. Because of the length of time the hole has been open and the drilling challenges with the original hole,we have decided to kickoff and redrill from the surface casing shoe at 2815' MD instead of at 5,000' MD. We will still set a cement plug at the same depths as planned to isolate our loss zone (cement from 5,000-5,600' MD). After tagging and performing an open hole FIT on that plug,we will pull up hole and set a 3rd plug up into our casing shoe to kickoff of. We will redrill the intermediate hole with a 9-7/8 x 11" underreamer to give additional ECD relief and clearance for our casing run. Please let me know if you would like any more information on our current status, or the proposed modification to our plan forward. Thanks, Mike On Oct 1,2015, at 2:29 PM, "Loepp,Victoria T(DOA)"<victoria.loepp@alaska.gov>wrote: Mike, Approval is granted to test the BOP components used after pulling out of hole with the cementing string as proposed below. Thanx, Victoria Sent from my iPhone On Oct 1, 2015, at 2:16 PM, Callahan, Mike S<Mike.Callahan@conocophillips.com>wrote: Date,Time of BOPE Use: 10/1/15, 12:37 PM 3 41110 • Well/Location/PTD Number: KRU 2S-04/Kuparuk Drill Site 2S/ PTD#: 215-159 Rig Name: Doyon 141 Operator Contact: Mike Callahan (Drilling Engineer)—(907) 231-2176 Doyon 141 Company Man (Robert Wall—days)—(907) 670-4976 Operations Summary, including events leading up to BOPE use: While pumping out of hole to pick up cement stinger, observed increase in gas and flow out. Shut in the lower pipe rams,with a 12 bbl pit gain observed. No pressure buildup was observed upon shut-in. BOPE Used: Lower pipe rams Reason for BOPE Use: Gas increase,flow observed Actions Taken/To Be Taken (including the date used BOPE was tested): Date of last BOPE test was Tuesday, 9/22/15. Plan forward is to open the choke and observe for flow, bleed off if flowing Lineup to pump down the annulus and bullhead fluid to a depth of the suspected loss zone at^'6,500'. After bullheading, shut down and observe well for flow. If no flow is observed, pull remaining heavy-weight drill pipe and BHA and pick up 3-1/2 cement stinger to pump isolation and kickoff plugs as detailed in the attached email chain. We request an extension on the required BOPE test on our first trip out of hole. Because of the current situation with the open loss zone with potential continue gas flow below,we would like to run in and pump our cement isolation plug as soon as possible to allow as little time for gas migration as possible. We propose to test our BOPE after we pull out of hole with our cementing string prior to picking up the drilling BHA for the sidetrack. Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office: (907) 263-4180 Cell: (907) 231-2176 <mime-attachment> 4 • 2S-04 — 10/9/15 Grassroots Horizontal A-Sand Injector ConocoPhillips Proposed Wellbore Schematic(Topset) I CAMERON ,16"Conductor to Last Edited:Voss-10/9/2015 -115' 13.5"Surface Hole Surface Casing 10-3/4"45.5#L-80 HydriI563 2,815'MD/2,562'TVD i -- „sus = 14.95 ppg EMW 9-718"Intermediate Hole 17 ppg Cement Kickoff Plug(Plug#4) • ECP for Kick off Plug 15.8 ppg Cement Isolation Plug(Plug#3) Estimated TOC at 4,605'MD(400'above Plug#2) to. • f— E C-50:4,987'MD/4,213'ND ; 15.8 ppg Cement Isolation Plug(Plug#2) TOC at 5,005'MD(600'above C-37) ECP i at 5 594'MD(Element at 5,600'MD) C-37:5,612'MD/4,782'ND Original Estimated Loss zone between C-37 and Bermuda Growler(Iceberg):5,748'MD/4,906'ND 3-W Cement Stinger cemented in hole Top of Fish at 5745'MD Top of cement in Stinger=5,957'MD 15.8 ppg Cement Abandonment Plug(Plug#1) Est Top=6.407 MD Bermuda/Cairn:6,426'MD/5,478'ND HRZ:7,180'MD/5,977'ND Gas Zone somewhere in the Kalubik Kalubik:7,455'MD/6,106'ND Kuparuk Top(Predicted)-6,275'ND(34'ND Below TD) • . PTD 2/5--!5-4/ Loepp, Victoria T (DOA) From: Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent: Wednesday, October 07, 2015 6:10 AM To: Loepp, Victoria T (DOA) Subject: RE: PTD#215-159 2S-04 Notification of BOPE Use per Guidance Bulletin 10-003 Follow Up Flag: Follow up Flag Status: Flagged Victoria,we were unable to make the cut with our first two attempts on E-line. On our third attempt we managed to get the cut, but this put us behind quite a bit. We are just beginning to come out of the hole with our drill pipe. Our gas has started to climb again, so we are bullheading—200 bbls down now before we continue out of the hole. If we don't run into further problems, we should be testing our BOPE sometime this afternoon. I will keep you updated if we encounter any other delays that might push it back further. Thanks, Mike From: Callahan, Mike S Sent: Tuesday, October 06, 2015 1:02 PM To: 'Loepp, Victoria T(DOA)' Subject: RE: PTD# 215-159 2S-04 Notification of BOPE Use per Guidance Bulletin 10-003 Great,thank you Victoria. I will keep you updated on our progress. Mike From: Loepp, Victoria T(DOA) [rnailto:victoria.loepo@alaska.gov] Sent: Tuesday, October 06, 2015 12:57 PM To: Callahan, Mike S Subject: [EXTERNAL]PTD# 215-159 2S-04 Notification of BOPE Use per Guidance Bulletin 10-003 Mike, Approval is granted to proceed with the plan outlined in your 10/3/15 email below. An extension of your BOP test for 24 hours is granted as requested if you have not been able to POOH by midnight tonight. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loem a)_alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended 1 • • recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Callahan, Mike S [mailto:Mike.CallahanOconocophillips.com] Sent: Monday, October 05, 2015 12:27 PM To: Loepp, Victoria T(DOA) Cc: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Doyon 141 Company Man; Herbert, Frederick 0; Bearden, J Daniel; Voss, Jake Subject: RE: [EXTERNAL]Re: PTD# 215-159 2S-04 Notification of BOPE Use per Guidance Bulletin 10-003 A quick update: We just tagged the top of cement in the drill pipe on e-line. The top of cement came in at 5,957' MD,giving us 1,725' of cement inside the pipe down to the string TD at 7,682' MD. That calculates to 19.5 bbls out of the 123 bbls of cement we pumped, leaving 103.5 bbls in the annulus. The 103.5 bbls of cement in the annulus gives a calculated cement height of 6,721' MD (961'of cement) with a 30%washed out hole, or 6,407' MD(1,275' of cement) in a perfectly gauge hole. Thanks, Mike From: Callahan, Mike S Sent: Monday, October 05, 2015 9:56 AM To: Loepp, Victoria T(DOA) Cc: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Doyon 141 Company Man; Herbert, Frederick 0; Bearden, J Daniel; Voss, Jake Subject: RE: [EXTERNAL]Re: PTD# 215-159 2S-04 Notification of BOPE Use per Guidance Bulletin 10-003 Victoria et al., here is our latest status update and proposed plan forward: We repaired the Dynamatic and continued running in hole with our cement stinger. The trip in hole was fairly smooth until the last couple hundred feet. We worked the pipe down to 7,747' MD, 53'from TD, but were packed off when we attempted to circulate. In order to get circulation we had to pull to 7,682' MD, 118'from bottom. From there we pumped our cement abandonment plug as planned. The job went well and showed good lift pressure(we did not have returns, as we continue to lose into our suspected loss zone at^'6,500', but the lift pressure indicated that cement was lifted throughout the job). After pumping the cement,our pipe was stuck, and we were unable to work it free. Because the cement job went well and we were confident we got a good plug,we decided to leave the pipe cemented rather than getting too aggressive trying to free it. Currently the cement has been in place for approximately 14 hours—the time to build 500 psi compressive strength was about 10 hours. We are currently rigging up e-line to run in hole and tag the cement inside our drill pipe/cement stinger. Once we get that depth,we will be able to calculate exactly how much cement we got around the outside of the pipe. Because of the cutoff pipe left in the cement, we will not be able to tag the top of the plug on the outside of the pipe. We will have the height of the cement inside our pipe and a calculated height outside the pipe, combined with our pumping data that gives us a high level of confidence that we have a good cement plug. Based on volumes pumped, our cement top inside the pipe at the end of our displacement was 5,412' MD,and the height of cement in the annulus was 6,435' MD, assuming 30%excess hole. We expect that they should have come close to balanced after we stopped pumping,and will be able to determine where after we tag the cement inside the 2 • pipe. Our pump pressure increased from 700 psi as cement exited the shoe to just over 3,000 psi at the end of the displacement, a good indication that we were lifting cement the entire time. Once we are able to cut our drill pipe and pull out of the hole,we would like to proceed on with the plan I sent you on Saturday. The only modification to that will be tagging on the inside of the pipe and calculating cement height outside the pipe, as opposed to the original planned tag of the abandonment plug with no pipe left in the hole. We also are now planning to set an external casing packer(ECP) below each of our next two cement plugs to provide a base for cement and reduce the likely hood of the cement dropping. We will pump the same plugs as planned, and still be able to tag and pressure test after setting our plug above the top of the C-37. I have attached two schematics, one of our current situation and one of our proposed abandonment plan for this intermediate hole. The kickoff will still happen from the surface casing shoe, as outlined in the previous email. Please let me know if you have any questions or would like to discuss further. Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office: (907) 263-4180 Cell: (907)231-2176 From: Callahan, Mike S Sent: Saturday, October 03, 2015 3:13 PM To: Loepp, Victoria T(DOA) Cc: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Doyon 141 Company Man; Herbert, Frederick 0; Bearden, 3 Daniel; Voss, Jake Subject: Re: [EXTERNAL]Re: PTD# 215-159 2S-04 Notification of BOPE Use per Guidance Bulletin 10-003 Victoria, here is a quick update on our status and plan forward: We have pulled the BHA out of the hole and are in the process of tripping back in to set the cement abandonment and kickoff plugs. The Dynamatic on our draw works has failed, so we are currently sitting at our surface casing shoe while we prepare to replace it. The well is on very slight static losses,and we are pumping just enough to keep the hole full. Once repaired,we will run in and set the cement abandonment plug as planned. Because of the length of time the hole has been open and the drilling challenges with the original hole,we have decided to kickoff and redrill from the surface casing shoe at 2815' MD instead of at 5,000' MD. We will still set a cement plug at the same depths as planned to isolate our loss zone (cement from^'5,000-5,600' MD). After tagging and performing an open hole FIT on that plug,we will pull up hole and set a 3rd plug up into our casing shoe to kickoff of. We will redrill the intermediate hole with a 9-7/8 x 11" underreamer to give additional ECD relief and clearance for our casing run. Please let me know if you would like any more information on our current status, or the proposed modification to our plan forward. Thanks, Mike 3 • • On Oct 1, 2015, at 2:29 PM, "Loepp,Victoria T(DOA)"<victoria.loepp)alaska_gov>wrote: Mike, Approval is granted to test the BOP components used after pulling out of hole with the cementing string as proposed below. Thanx, Victoria Sent from my iPhone On Oct 1, 2015, at 2:16 PM, Callahan, Mike S<Mike.Callahan@conocophillips.com>wrote: Date,Time of BOPE Use: 10/1/15, 12:37 PM Well/Location/PTD Number: KRU 25-04/Kuparuk Drill Site 2S/PTD#: 215-159 Rig Name: Doyon 141 Operator Contact: Mike Callahan (Drilling Engineer)—(907) 231-2176 Doyon 141 Company Man (Robert Wall—days)—(907)670-4976 Operations Summary, including events leading up to BOPE use: While pumping out of hole to pick up cement stinger, observed increase in gas and flow out. Shut in the lower pipe rams,with a 12 bbl pit gain observed. No pressure buildup was observed upon shut-in. BOPE Used: Lower pipe rams Reason for BOPE Use: Gas increase,flow observed Actions Taken/To Be Taken (including the date used BOPE was tested): Date of last BOPE test was Tuesday,9/22/15. Plan forward is to open the choke and observe for flow, bleed off if flowing Lineup to pump down the annulus and bullhead fluid to a depth of the suspected loss zone at 6,500'. After bullheading, shut down and observe well for flow. If no flow is observed, pull remaining heavy-weight drill pipe and BHA and pick up 3-1/2 cement stinger to pump isolation and kickoff plugs as detailed in the attached email chain. We request an extension on the required BOPE test on our first trip out of hole. Because of the current situation with the open loss zone with potential continue gas flow below,we would like to run in and pump our cement isolation plug as soon as possible to allow as little time for gas migration as possible. We propose to test our BOPE after we pull out of hole with our cementing string prior to picking up the drilling BHA for the sidetrack. 4 • 0 Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office:(907)263-4180 Cell: (907)231-2176 <mime-attachment> 5 • S Loepp, Victoria T (DOA) From: Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent: Thursday, October 01, 2015 2:15 PM To: Loepp,Victoria T(DOA); Regg,James B(DOA); DOA AOGCC Prudhoe Bay Cc: Doyon 141 Company Man; Herbert, Frederick 0; Bearden,J Daniel;Voss,Jake Subject: PTD#215-159 2S-04 Notification of BOPE Use per Guidance Bulletin 10-003 Attachments: [EXTERNAL]RE: PTD#215-159 2S-04 Status Update&Plan Forward Follow Up Flag: Follow up Flag Status: Completed Date,Time of BOPE Use: 10/1/15, 12:37 PM Well/Location/PTD Number: KRU 2S-04/Kuparuk Drill Site 2S/PTD#:215-159 Rig Name: Doyon 141 Operator Contact: Mike Callahan (Drilling Engineer)—(907)231-2176 Doyon 141 Company Man(Robert Wall—days)—(907)670-4976 Operations Summary, including events leading up to BOPE use: While pumping out of hole to pick up cement stinger,observed increase in gas and flow out. Shut in the lower pipe rams,with a 12 bbl pit gain observed. No pressure buildup was observed upon shut-in. BOPE Used: Lower pipe rams Reason for BOPE Use: Gas increase,flow observed Actions Taken/To Be Taken (including the date used BOPE was tested): Date of last BOPE test was Tuesday,9/22/15. Plan forward is to open the choke and observe for flow, bleed off if flowing. Lineup to pump down the annulus and bullhead fluid to a depth of the suspected loss zone at 6,500'. After bullheading,shut down and observe well for flow. If no flow is observed,pull remaining heavy-weight drill pipe and BHA and pick up 3-1/2 cement stinger to pump isolation and kickoff plugs as detailed in the attached email chain. We request an extension on the required BOPE test on our first trip out of hole. Because of the current situation with the open loss zone with potential continue gas flow below,we would like to run in and pump our cement isolation plug as soon as possible to allow as little time for gas migration as possible. We propose to test our BOPE after we pull out of hole with our cementing string prior to picking up the drilling BHA for the sidetrack. Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 1 • Loepp, Victoria T (DOA) From: Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent: Thursday, October 01, 2015 9:34 AM To: Loepp, Victoria T (DOA) Subject: RE: PTD#215-159 2S-04 Status Update & Plan Forwarda Follow Up Flag: Follow up Flag Status: Flagged Victoria, as we just discussed, the only change to our plan is as follows: Instead of attempting to spot a balanced abandonment plug with a base of cement at 7,455' MD,we will be attempting to run to bottom with our cement stinger and pump cement all the way from TD at 7,800'. Our planned TOC will not change, this just adds an additional—345'of cement and gives us a better chance of the plug setting without mud contamination from below. After setting the plug, we will wait—8 hours until the cement builds 500 psi compressive strength, then run back in and tag the top to ensure we have solid cement in place. If the tag is too low or does not show hard cement,we have enough cement loaded out to pump a second plug there. After pumping the kickoff plug above, we will do the same tagging procedure,then do an open hole FIT to confirm that we are isolated from the loss zone below. Please let me know if you would like any more details. Thanks, Mike From: Callahan, Mike S Sent: Thursday, October 01, 2015 6:14 AM To: Loepp, Victoria T(DOA) (victoria.loepp@alaska.gov); Bettis, Patricia K(DOA) (patricia.bettis@alaska.gov) Subject: RE: PTD #215-159 2S-04 Status Update&Plan Forward Victoria/Patricia, Attached are our real time logs for the intermediate hole section. I've attached both the MD and TVD versions. Our geologists identified a couple of small sections of the Growler(5,748'—5,980' MD) and a small sand stringer at^'5,550' MD that could have some hydrocarbons based on the resistivity. Please let me know if you would like any more information. Thanks, Mike From: Callahan, Mike S Sent: Wednesday, September 30, 2015 1:11 PM To: Loepp, Victoria T(DOA) (victoria.loepp@alaska.gov) Subject: FW: PTD #215-159 2S-04 Status Update &Plan Forward • 1 • • From: Callahan, Mike S Sent: Wednesday, September 30, 2015 10:53 AM To: Loepp, Victoria T(DOA) (victoria.loepp(aalaska.gov) Subject: PTD #215-159 2S-04 Status Update &Plan Forward Victoria,as we discussed on the phone, here is our updated status and proposed plan forward on 2S-04: Since yesterday,we have pumped 5 LCM pills,as well as adding LCM to our active mud system. This has controlled the losses to the point we are no longer losing while static, but we still have no returns when pumping. We have cut our mud weight to 10.5 ppg and have not seen any signs of gas. We are currently backreaming slowly to get the bit above the top of our suspected loss zone. We believe the losses are somewhere between the top of the Growler formation (5,748 MD/4,906'TVD) and the base of the Bermuda formation (6,679' MD/5,670'TVD). We are currently at 6,400' MD and slowly working our way out. Our proposed plan forward is to continue pulling until our bit is above the suspected loss zones. From there,we will spot some more LCM and attempt to regain at least partial circulation. Once we observe the well to be static,we will pull out of the hole, lay down our BHA,and pick up a 3-1/2" cement stinger. We will attempt to isolate the Kalubik shale (the zone where we encountered the gas)from the base of the Bermuda with a cement isolation plug,from 7,455' MD (top of Kalubik)to 6,679' MD (base of Bermuda). We will pump Schlumberger's 15.8 ppg GasBlok slurry with CemNet LCM material to give the best chance of preventing any gas migration and slow any losses that could occur. After setting the isolation plug,we will pull up to the top of the C-37 sand at 5,612' MD/4,782'TVD. From there we will attempt to set a kickoff plug with the top at 5,000' MD to sidetrack the well. We are still working on a directional plan for the sidetrack, but will attempt to steer roughly 100 feet away from the existing wellbore and follow it's trajectory, landing approximately 15'TVD higher than the original well to avoid the gas we saw at TD. This will put our packer an additional 15'TVD above the top of the reservoir than was initially planned. I will not know what the additional MD footage will be until we finalize the directional plan, but it should be roughly 65-75 feet MD further than the originally permitted 410' MD. I have attached a rough schematic of the current status that has the formation depths included. If you would like any more information or have further questions, please let me know. Thanks, Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office: (907) 263-4180 Cell: (907)231-2176 From: Callahan, Mike S Sent: Tuesday, September 29, 2015 12:34 PM To: Loepp, Victoria T(DOA) (victoria.loepp@alaska.gov) Subject: PTD #215-159 2S-04 Status Update Victoria, I just wanted to update you on the current status of our operations on 2S-04. 2 S • Doyon 141 reached topset TD in the Kalubik shale roughly 34'ND above the expected depth of the Kuparuk sands. We had 10.5 ppg LSND in the hole, but increased weight to 11.5ppg due to increasing gas levels over the past 3 days prior to attempting to come OOH. After getting the gas back to background levels this morning,we began backreaming OOH(attempted to pull on elevators but were unable).We reached an ECD of 12.3 ppg and the well went on total losses. Currently we have no returns and are losing statically,but don't have the rate of static losses at this time because we cannot keep the hole full yet by pumping across the top. Our plan forward is the following: 1. We are attempting to keep the hole full with the LSND mud we currently have—and are starting to dilute toward 10.5#with fresh water 2. We are pumping our first LCM pill(MI's Nut Plug+Dyna Red),and mixing a second LCM pill(Strata FlexFine/Medium+Vanguard material) 3. We have multiple loads of mud on the way to the rig to ensure we have sufficient mud to keep the hole full. 4. We will attempt to keep the hole full while healing the losses until we have adequate returns. From that point we will assess whether weight needs to be added through flow checks and/or pressure buildups,and determine our path forward from there. We will keep you updated with further progress. Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office: (907) 263-4180 Cell: (907)231-2176 3 p7W S-15-7 • Loepp, Victoria T (DOA) From: Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent: Tuesday, September 29, 2015 12:34 PM To: Loepp,Victoria T(DOA) Subject PTD#215-159 2S-04 Status Update Follow Up Flag: Follow up Flag Status: Flagged Victoria, I just wanted to update you on the current status of our operations on 2S-04. Doyon 141 reached topset TD in the Kalubik shale roughly 34'ND above the expected depth of the Kuparuk sands. We had 10.5 ppg LSND in the hole, but increased weight to 11.5ppg due to increasing gas levels over the past 3 days prior to attempting to come OOH. After getting the gas back to background levels this morning,we began backreaming OOH(attempted to pull on elevators but were unable).We reached an ECD of 12.3 ppg and the well went on total losses. Currently we have no returns and are losing statically,but don't have the rate of static losses at this time because we cannot keep the hole full yet by pumping across the top. Our plan forward is the following: 1. We are attempting to keep the hole full with the LSND mud we currently have—and are starting to dilute toward 10.5#with fresh water 2. We are pumping our first LCM pill (MI's Nut Plug+Dyna Red),and mixing a second LCM pill (Strata FlexFine/Medium+Vanguard material) 3. We have multiple loads of mud on the way to the rig to ensure we have sufficient mud to keep the hole full. 4. We will attempt to keep the hole full while healing the losses until we have adequate returns. From that point we will assess whether weight needs to be added through flow checks and/or pressure buildups,and determine our path forward from there. We will keep you updated with further progress. Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office: (907)263-4180 Cell: (907)231-2176 1 OF 71.1 w //7,. .,7,..s THE STATE Alaska Oil and. Gas ofLASKA. Conservation Commission glitt 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 oFALA�"' Fax: 907.276.7542 www.aogcc.alaska.gov G. L. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2S-04 ConocoPhillips Alaska, Inc. Permit No: 215-159 Surface Location: 3030' FNL, 1349' FEL, SEC. 17, T1ON, R8E, UM Bottomhole Location: 2229' FNL, 1376' FEL, SEC. 8, T1ON, R8E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cath P. Foerster Chair DATED this /r/f--lay of September, 2015. 11110 S STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 0 4 Z015 PERMIT TO DRILL r� 20 AAC 25.005 AOGCC la.Type of Work: 1 b.Proposed Well Class: Development-Oil ❑ Service-Winj ❑ s Single Zone El, 1 c.Specify if well is proposed for: Drill Q • Lateral f Stratigraphic Test❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill ❑ Reentry Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: 4 LJ Blanket . Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 -. KRU 2S-04 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 14207' TVD: 6286' r Kuparuk River Field, 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:3030'FNL, 1349'FEL,Sec. 17,T1ON, R8E, UM • ADL 25603,25590• Kuparuk River Oil Pool , Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2889'FNL,3306'FEL, Sec. 17,T1ON, R8E, UM 2677,2676 9/15/2015 Total Depth: 9.Acres in Property: jr 14.Distance to 2229'FNL, 1376'FEL,Sec.8,T1ON, R8E, UM 7C32 5013 Nearest Property: 3931 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: ' 148 feet 15.Distance to Nearest Well Open Surface:x- 481221 y- 5930018 Zone- 4 - GL Elevation above MSL: .120 feet to Same Pool: 2S-08,136' 16.Deviated wells: Kickoff depth: . 600 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: \ 90° deg Downhole:3750 psig . Surface:3117 psig - 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 62.5# H-40 Welded 78' 28' 28' 106' 106' pre-installed 13.5" 10.75" 45.5# L-80 Hydril 563 2803' 28' 28' 2831' 2569' 1203 sx DeepCRETE,205 sx DeepCRETE 9.875" 7.625" 29.7# L-80 Hydril 563 7936' 28' 28' 7964' 6293' 402 sx GasBLOK, 158 sx GasBLOK 6.75" 4.5" 11.6# L-80 IBTM 6393' 7814' 6257' 14207' 6286' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth TVD(ft): Junk(measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Production Scab Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20.Attachments: Property Plat ❑ BOP Sketch❑ Drilling Program ❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements O 21.Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Mike Callahan @ 263-4180 / Email Mike.Callahan(a�cop.com Printed Name G. L. Alvord Title Alaska Drilling Manager Signature A.-`C,. 0 Phone:265-6120 Date 1(41-(/-0 cc Commission Use Only Permit to Drill API Number: Permit Appro/v I I See cover letter Number: 02 1 S- 1,5-/ 50- 1133-�o72I-0O-0QI Date: V '{ l`11 Ifor other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed m thane,gas hydrates,or gas contained in shales: d Other:8.6pfic 5/ f0 3 SOO r S,9 Samples req'd: Yes No Mud log req'd: Yes❑ No Q A nnu,/ear,(7re-w cvrrlr- feST` 1a Z 5560 p5 2S measures: Yes No r❑-y Directional svy req'd: Yes No 4waIVcr/5�J re.-)tcdf'o aI/c'. pacl� acingxceptionreq'd: Yes ❑ No L±'1 Inclination-only svy req'd: Yes Li No II .1 f?/aL'Cc/'� 4![7`MDG4�J6Vt 5/of1'cc�'flvirr �ap(fl ' .4G 2S•412 (b j) 51:ir v/tnr55cd �rJ4 rrQv7)e'dafir#- sf46//j`jr !L./cctIoV7 . P. VJCW �&V" C w2}h A-05CC - APPROVED$YTHE /� Approved by �_ COMMISSIONER COMMISSION Date: '/ l ,(- / 5 Form 10-401 (Re sed 10/2012) T t o mq�th from the date of approval(20 AAC 25.005(g)) 'PP'g ' S 6" vr� qi/r/1s � � � H L !� 6 • • Application for Permit to Drill,Well 2S-04 Saved:4-Sep-15 Post Office Box 100360 11 Anchorage,Alaska 99510-0360 ConocoPhillips Phone(907)263-4180 Email: mike.callahan@conocophillips.com September 4,2015 RECEIVED Alaska Oil and Gas Conservation Commission 333 West 7th Avenue,Suite 100 SEP 0 4 2015 Anchorage,Alaska 99501 /� //�� Re: Application for Permit to Drill Well 2S-04,A Kuparuk A4 Sand Pre-Produced Injector AOGCC Dear Commissioner: ConocoPhillips Alaska,Inc. hereby applies for a permit to drill an onshore grassroots pre-produced injector well from the 2S pad. The expected spud date for this well is September 15,2015.It is planned to use rig Doyon 141. 2S-04 is planned to be a horizontal well in the Kuparuk A4 sand.The surface section will be drilled with 13-1/2"bit and run 10-3/4"casing to+/-2,83I'MD/2,569'TVD.The intermediate section will be drilled with 9-7/8"bit and run 7-5/8" casing to 7,964'MD/6,293'TVD.The production hole will be drilled with 6-3/4"bit and run 4-1/2"slotted liner to+/- 14,207'MD/6,286'TVD.The upper completion will be run with 3-1/2"tubing. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d)(2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b). 7. A proposed completion diagram. 8. Request for waiver of AOGCC regulation 20 AAC 25.412(b)on packer setting depth for injectors Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a)and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Mike Callahan at 263-4180 (mike.callahan@conocophillips.com)or Chip Alvord at 265-6120. Sincerely, n tij-C., • Chip Alvord Drilling Manager • 411 Application for Permit to Drill Document Kuparuk Well 2S-04 CorxxcPhillips Well Name Requirements of 20 AAC 25.005(0 The well for which this application is submitted will be designated as 2S-04 Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (2)a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth,referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 3030'FNL, 1349'FEL, Sec 17, T 10N,R008E,UM NGS Coordinates RKB Elevation 148'AMSL Northings: 5,930,017.59' Eastings: 481,221.00' Pad Elevation 120'AMSL Location at Top of 2889'FNL,3306'FEL,Sec 17,T1ON,R008E,UM Productive Interval (Kuparuk A4 Sand) NGS Coordinates Measured Depth, RKB: 8,224' Northings: 5,930,164.10' Eastings: 479,264.19' Total Vertical Depth,RKB: 6,329' Total Vertical Depth, SS: 6,181' Location at Total Depth 2229'FNL, 1376'FEL, Sec 8,T1ON,R008E,UM NGS Coordinates Measured Depth, RKB: 14,207' Northings: 5,936,098.61' Eastings: 481,191.28' Total Vertical Depth, RKB: 6,286' Total Vertical Depth, SS: 6,138' and (D)other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated,the application for a Permit to Drill(Form 10-901)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment: Directional Plan And (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells,to the extent that those names are known or discoverable in public records,and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 AAC 25.035,20 AAC 25.036,or 20 AAC 25.037,as applicable; Please reference BOP schematics on file for Doyon 141. • I Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient; The maximum potential surface pressure (MPSP)while drilling 2S-04 is calculated using an estimated maximum reservoir pressure of 3,750 psi 0.1.5 ppg, based on Shark Tooth #1 appraisal well and nearby recently drilled 2S wells), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A4 sand at 6,329' TVD (WP10): A Sand Estimated. BHP = 3,750 psi A Sand estimated depth (WP10) = 6,329' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 633 psi (6,329' TVD * 0.10 psi/ft) MPSP =BHP—gas column =3,117 psi (3,750 psi—633 psi) (B)data on potential gas_ones; The well bore is not expected to penetrate any shallow gas zones. And (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; See attached 2S-02 Drilling Hazards Summary Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25.030(); A procedure is on file with the commission for performing LOT's. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030.and a description of any slotted liner,pre perforated liner,or screen to be installed Casing and Cement Program Casing and Cementing Program Csg/Tbg Hole Weigh Length Top MD/TVD Btm MD/TVD OD(in) Vii) t(lb/ft) Grade Conn. (ft) (ft) (ft) Cement Program 16 24 62.5 H-40 Welded 78 Surf 106/106 Existing Hydril Cement to Surface with 10-3/4 13-1/2 45.5 L-80 563 2,803 Surf 2,831/2,569 1,203 sx DeepCRETE Lead 11.0 ppg, 205 sx DeepCRETE Tail Slurry 12.0 ppg Stage 1: 402 sx Class G+GASBLOK at Hydril 15.8 ppg w/TOC at 6,400'MD 7-5/8 9-7/8 29.7 L-80 563 7,936 Surf 7,964/6,293 Stage 2: 158 sx Class G+GASBLOK at 15.8 ppg w/TOC at 5,083'MD 4 1/2 6-3/4 11.6 L-80 IBTM 6,393 7,814/6,257 14,207/6,286 Slotted liner • Diverter System Information Requirements of 20 AAC 25.005(e)(7) An application for a Permit to Drill must be accompanied by each of the following items.except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 AAC 25035,unless this requirement is waived by the commission under 20 AAC 25,035(h)(2); Please reference diverter schematic on file for Doyon 141. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items,except/or an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 AAC 25.033; Mud Program Summary Surface Intermediate Production 13-1/2" Hole 9-7/8" Hole 6-3/4" Hole 10-3/4" Casing 7-5/8" Casing 4-1/2" Liner FLO-PRO NT Mud System Drilplex LSND(WBM) (WBM) Density 9.3- 10 9.2- 10.5 10.5-11.5 PV 30-50 10-20 10-20 YP 40-80 16-24 16-24 Funnel Viscosity 200-300 N/A N/A Initial Gel 30-50 10- 12 5-8 10 minute Gel 30-50 10- 18 5-12 API Filtrate NC <6 <6 HTHP Fluid Loss at 160 F N/A < 10 < 10 pH 9.0- 10.0 9.0- 10.0 9.5- 10.0 Diagram of Doyon 141 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) N/A - Application is not for an offshore well. i S Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer to attachment for proposed well schematic. • • 1. Move in/rig up Doyon Rig 141. Install 21-1/4"Annular with 16"diverter line and function test. 2. Spud and directionally drill 13.5"hole to casing point at+/-2,831 MD/2,569'TVD as per directional plan (wp10). Survey with MWD,Gamma,Resistivity,Gyro. 3. Run and cement 10-3/4",45.5#,L80,Hyd-563 casing to surface. Displace cement with mud. Evacuate top 2 feet of cement from annulus for sealant job(post rig.) 4. In the event cement returns are not seen at surface,perform a top job. 5. Remove diverter system,install and test 13-5/8"x 5,000 psi BOP's to 3500 psi(annular preventer to 2500 psi) high and 250 psi low. Notify AOGCC 24 hrs before test. 6. PU 9-7/8"PDC bit and directional drilling assembly,with MWD/LWD(Gamma,resistivity). RIH and clean out to 100'above shoe. Test surface casing to 3500 psi for 30 minutes. 7. Drill out shoe track and 20'of new hole. Perform leak off test to a minimum of 12.5 ppg,maximum of 16 ppg EMW leak off,recording results. 8. Directionally drill to the top of the HRZ at-7,254'MD/6,032'TVD. Begin applying back pressure on connections with MPD for shale stability at this time. 9. Directionally drill to intermediate TD of 7,964'MD/6,293' TVD,landing approximately 50'TVD below the K- 1 marker in the lower Kalubik Shale. Wellsite geologist will call intermediate TD. Circulate and rotate at maximum rates until shakers are clean,minimum of 3 bottoms up. 10. POOH on elevators. Closely monitor drag and address any problem areas by dropping below and circulating/rotating to clean up. Backream through tights spots only if necessary. If substantial drag was observed through a large part of the trip,consider making a wiper trip back to bottom from the surface casing shoe,otherwise continue pulling out of hole. 11. Laydown intermediate BHA and rack back 5"DP(to lay down after casing run,this will minimize shale exposure time.) 12. Run 7-5/8",29.7#L80,Hydril 563 casing from surface to TD at 7,954'MD. 13. Pump two stage cement job as per Schlumberger proposal. Top of first stage to be 6,400'MD(30'MD above top of Cairn formation),top of second stage to be 5,083'MD(500' above C37). 14. Flush 10-3/4"x 7-5/8"annulus with water,followed by diesel to freeze protect. 15. Lay down 5"DP. 16. PU 4"DP,6-3/4"bit,and drilling assembly with MWD/LWD(Gamma,resistivity,Periscope,Microscope, Sonicscope and neutron density). Re v t( `"' L" ' may' fl o tz ` . 17. RIH and clean out cement to 100'above shoe. Mad pass with sonic log to verify top of cement on the way in the hole. Test intermediate casing to 3500 psi for 30 minutes. 18. Drill out shoe track and 20'of new hole. Perform formation integrity test to minimum of 12.5 ppg,maximum of 16 ppg EMW leak off,recording results. 19. Directionally drill 6-3/4"hole,geosteering through the Kuparuk A4 sand to TD-14,207'MD as per directional plan(wp10). 20. Circulate hole clean and POOH. 21. Lay down Production BHA. • • 22. PU and run 4-1/2", 11.6/1 slotted liner. The top of liner will be placed at 7,814'MD,allowing for 150'of overlap in the 7-5/8"casing. NOTE: This will put the liner—410'MD,72'TVD above the top of the A4 reservoir,greater than the 200'MD required. ConocoPhillips requests a waiver to use this well for injection with the packer at this depth. 23. Set liner hanger. Slackoff and set liner top packer. 24. Monitor well for flow for 15 minutes 25. Displace to clear brine. PT liner to 3,000 psi at surface for 30 minutes,chart results. 26. Flow check well for 30 minutes to run 3-1/2"upper completion. 27. Nipple down BOPE,nipple up tree and test. 28. Freeze protect well with diesel and install BPV. 29. RDMO. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(141 1 n application jot-a Permit to Drill music be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement ofwhether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well (1R-18 or new facilities at DS1B). All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well,or stored,tested for hazardous substances,and(if free of hazardous substances)used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: Attachment 1 Well Schematic Attachment 2 Diverter Layout Diagram Attachment 3 Directional Plan Attachment 4 Drilling Hazards Summary Attachment 5 Cement Summaries Attachment 6 Request for Waiver of Packer Setting Death IP III 2S-04 -..--- Grassroots Horizontal A-Sand Injector conocoPhillips Proposed Wellbore Schematic (Topset) , eCANIIIROP* Last Edited: 4-14'tree.top jotlt is 4-1iii' 12.84 1BTM Callahan-91212015 f A 1 6"Conductor to 44 115' 13.5" Surface Hole Hu 3-4-7 2.875DS Landing WM Upple . Surface Casino NM Z. umul 10-314"45.5#1...-80 „r. Hydri1563 9-718" Intermediate 2,531 MD 1 2568'TAD Hole 1t7 2 3#L-80 EU E eRD- MOD Tubing 2'4 Stage TOC 5,083'MD: 4,300'TVD 1E33'MD above C371 1111 'i- .1"1-•rcl Stage Collar:5,10V MD/ :c..375.E gy topf4,7571vii. 3 Growler(Iceberg):-5,262'MD14,972'TVD '4 4 Saw ten"0 1.0 Stage IOC:6,400'MD I 5,4431'TVD Plwares fTop of Cairn/Bennudal 1-iir sir D MI 1r$ 0: BennudaCairni 6,43C'hil 2.:5.495'TV:: si-,,e-Hes wrap D^ • '. - 77---Fnn't Plug . Ha-der IZXP HRZ:7,254'MD i 6,032'TVD Kaiub iki7,322"MD/6,103'TVD \ F Intermediate Caiina\ ----,. --...,_., Kuparuk A4:8 224 MD,'e,32g TVD 7-518"29.7#1-80 Ify{15 -i5' '3 -.anvil:A-I 964'IMP/6,293'TV13)---.... -.`"•--... -- TD:14.207'MD i 0280' 7 /7 tor x 41-,,,Swag Pablo., 6-3/4" Production Hole NOTE:Swell Packer will be adjusted as necessary using microscope and periscope data ul O N N o 44 I c z o o Z O IPLV /(oma] $ ' 0 ® \/ >— U f di i. I F w a I El U G ❑ © .Q [ — 1 J r (n N 1:1 n'n l r V Ni. 0 0 NN C �1 �---. ` ~ w [1'1 1 fM M ❑ v� _ O _ „, \ 6, V ' N N V y f 4 (Ell o ce ❑ o) / MVM 4EI ® _ e if 00 El H oo J Nao .- J I. ❑ O Qlik M o a ® — z _ < N I El ® En 00 , 0 0 ® > s a ❑ w — e C a ® o ® —I , J E ❑ ® a 8 0 H 1 El ® o w17', n > a- < II (n m N U J H J E2 ci g ) i ig 0 z z ni. on I I 2S-O4wplO[Lemon] 6.706 Plan Summary 14uparuk C(Top C4) S Top W Sak(W Sak09yG 6 Hf� -5 '250(1 : gym 1 Base permafrost(? '� r� -+ h/ - ) /� , \ ,v.i .111 /l�.' I.t ..-._ 1 I I o t kEZE FE _ 9000 11 It25.0 N 0 1 1 I 1 I 1 r I 0 0 A 0 / FP 3500 7000 10500 14000 / k. - V 00-3/4"x 13-1/4 Measured Depth 14-1/2"x 6-3/41 p• `! •--- -2500 0-110-3/4"x 13-1/2'' Geodetic Datum: North American Datum 1983 1 . 0' Depth Reference: Plan:120+28 @ 148.00usft(Doyon 141) / fir.,! i Rig: Doyon 141 N , ��°, bO00 I I - "Li...--` -10000 400 17-5/8"X 9-7/8'1 14-1/2"x 6-3/41 I -1200 0 6006' ,� I R. 11 -15000 ��hg' �,p1 till 0 1 I � 1 1 0- 1 1 I i I i I I WI I I I 'r.>'I oI Air' 26 ."_ Boo 0 1500 3000 4500 6010 0 7500 o 90 00500 5 0 Horizontal Departure 790 - 900 - 70 0 330 m7,2 30 I� 1�1 ` mo 970 - 1160 C Y ... ! .... .i Ae �•�Al!:11 � r 1160 - 1340 o �I •�x oszsze, 1340 - 1530 o N 60P ����-, ,,,o���I 1i .�kV,/ p •/ ? 2430 2950 /n / 2950 - 3480 Uc)30 1 `i'_ f� % i/" 3480 - 4000 - 111 II I 270 _7 �r" r„!9+&� (zs-o,.ao�IM 4000 - 4530 ;12 - . •`,' o Av IA p 5050 - , s z5 n 4530 - 5050 1:45580 c) 0 Iorf ,�2`°'dj4 p 4��'1t�e" '.4'. 1..,.;',f./../air" ° 'i® 5580 - 6190 1 I I 1 I I 1 I I I I I I I I 1 I I 1 ; }►, // 0 �' Iilk ���fs 34 re'ii' 6100 - 7160 0 1500 3000 4500 6000 7500 9000 240 .,'/^`• `. .e�/,v/iir�� 7160 - 8210 SURVEY PROGRAM Surface Location ��' ,,5�+�//to!F : ,� 8210 - 9270 _ ,•,'``_°.,(i�7 ;,•f 9270 - 10320 Depth From Depth To Survey/Plan Tool Pad Elevation: 120.00 ry/,r /.14,V 10320 - 11380 28.00 1000.00 2S-04wp10[Lemon](Plan 2S-04) GYD-GC-SS210°� z 'rt/•�,.11 a=. 11380 12430 1000.00 2000.00 2S-04wp10[Lemon (Plan 2S-04) MWD - 1000.00 2831.36 2S-04wp10[Lemon](Plan 2S-04)1WD+IFR-AK-CAZ-SC 180 12430 13490 2831.36 4331.36 2S-04wp10[Lemon](Plan 2S-04) MWD CASING DETAILS 13490 - 14542 2831.36 7964.25 25-04wp10[Lemon](Plan 2S-04y1WD+IFR-AK-CAZ-SC 7964.25 9464.25 2S-04wp10[Lemon](Plan 2S-04) MWD TVD MD Name 7964.25 14207.48 2S-04wp10[Lemon](Plan 2S-0,01WD+IFR-AK-CAZ-SC 2569.00 2831.36 10-3/4"x 13-1/2" Magnetic Model: BGGM2014 T 6293.00 7964.25 7-5/8"X 9-7/8" Magnetic Model Date: 05-Feb-15 - 6286.00 14207.48 4-1/2"X 6-3/4" Magnetic Declination: 18.80° To convert a Magnetic Direction to a True Direction,Add 18.80°East SECTION DETAILS _372ti,p� T-3 Sand Sec MD Inc Azi TVD +N/-S SE/-W Dleg TFace VSect Target Annotation 1 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 0.00 2 600.00 0.00 0.00 600.00 0.00 0.00 0.00 0.00 0.00 KOP.Start 1.5°/100'DLS,200°TF,for 200.09' K-15 Marker 3 800.09 3.00 200.00 800.00 -4.92 -1.79 1.50 200.00 -5.24 Start 2.5°/100'DLS,0°TF,for 200 99' 4 1001.09 8.03 200.00 1000.00 -23.07 -8.40 2.50 0.00 -24.53 Adjust TF to 10°,for 484.32' 5 1485.40 20.06 206.10 1469.00 -129.83 -56.68 2.50 10.00 -140.99 Hold for 106.46' -1361.0 6 1591.86 20.06 206.10 1569.00 -162.62 -72.74 0.00 0.00 -177.14 Start 3°/100'DLS,35.09°TF,for 875.12' 7 2466.98 44.09 227.53 2307.27 -509.03 -368.51 3.00 35.09 -598.00 Hold for 1648.41' Base permafrost(? 8 4115.39 44.09 227.53 3491.30 -1283.38 -1214.51 0.00 0.00 -1595.88 Start 3°/100'DLS,145.35°TF,for 3848.87' 9 7964.25 78.00 15.88 6293.00 141.56 -1957.37 3.00 145.35 -470.23 Hold for 20' - 1954.0 10 7984.25 78.00 15.88 6297.16 180.38 -1952.02 0.00 0.00 -450.68 Start 4.5°/100'DLS,35.46°TF,for 37.07' lop W Sak(W Sak)) 11 8021.32 79.38 16.86 8304.43 195.25 -1941.77 4.50 35.46 -414.35 Hold for 8.85' 12 8030.17 79.36 16.86 6306.07 203.57 -1939.25 0.00 0.00 -405.65 Start 4°/100'DLS,7.77°TF,for 117.05' -2519.0 13 8147.22 84.00 17.50 6323.00 314.19 -1905.04 4.00 7.77 -289.88 28-Lemon 1.Heel Adjust TF to 3.38°,for 161.16' Base W Sak 14 8308.38 90.44 17.88 6330.82 467.46 -1856.15 4.00 3.38 -129.00 Hold for 5899.11' -2788.0 15 14207.48 90.44 17.88 8288.00 6081.53 -45.18 0.00 0.00 5769.92 2S-Lemon 2.Toe TD:14207.48'MD,6286'TVD C-80 -4103.0 C-55550 -4939.07 `j¢$�Growle�rr--AAA Z 988Y?9, xaaa g C-35 j5zz p(�22�KK(0r�,�ppI -e3 @fllk '(4bRriktk Z) P.signing this I acknowledge that I have been informed of all risks,checked that the data is correct,ensured it's completeness,and all surrounding wells are assigned to the proper position and I approve the scan and ollision avoidance plan as set out in the audit pack.I approve it as the basis for the final well plan and wellsite drawings.I also acknowledge that.unless notified otherwise,all targets have a 100 feet lateral tolerance. Prepared by: Checked by: Accepted by: Approved by: Brij Potnis Nate Beck lfeanyi Ifesie I ,, . an®cxo CD - N Northing (3500 usftlin) • O 01 fia'N , N Y N N _ ,^ _ N 7• N \1 cc, WG N — h i._....N c At i ON N - J {t5 Y N CD- 1 N Q Q _ CO M O N0 - . `1 -tea / . ' cs, Y 0E- _N O — O Ys 3 - avN — t. CD --E- O 0 0 3 Y _ Co 73 - N U - — N N m O N 01 V in i✓ (;) Q`Oa — C) M th —O° 0O9! O 3 OM N �� fiIllj;? O CO 13Nd d dIUO °NCa _ N CL N M C M N M N '- ca o E • a` - N 7 1 N N (n Cn CO Ti .i0 ,� — 7 cn CO C a S e 13 C ca t m ` "E'�' o - uco J W N - t CO c73 iflJ - N I 't '.l . cr ( N • N N 0.• C, M q _ - 3 °° = 3 ` - () ` �`� - m J M J O 'C' C `- NO! _ O N N M O Z — JN - O — a N _ M ?D - N / • M 6) �- - - MN 19 - - J M + _ N _ m %a1 N Q J 3 N — M M CL O r� M N M O - O J - M ir N `�-., m _ J �.V N J N— N elf. M O Lo N N•g J QHI m \r_/� N d V— m ;N N ii NCL M NNa O M JNN \\=_.N _ NJ / NMMp �� NZ — N M N d - ft/�i� M Z N .0 N a i <///9" /J (l) - 111111111 I l i 1 1 1 1 i 1 l l l i l i 1 1 1 i 1 1 1 [ 1 m i I 1 1 1 1 1 1 1 1 ' (- (upon 002E) 6uiypoN T 6 • • .0 c. a) 0 •� o (7.) o > = o 0 V) = o N o HO = O w cti o N Lo ' C r 0. , O E oI O co - t th m O — , co U) O itiN IO L. Ni `O' ^ �OO Oco w (Q , C o -, 0 O LOa) 0 ch J (Ni 0 4-. CO ch . + O X N M o +=� N a �0Os.c 4.00 -L) ca W M V=.+ 1 O CO N- a)•• 1-':: o a) o et X –o Q u oo co' wE .2 � In NI- Wo J 0 _ _ 1- Li Nem Ow 0 o o CO 1 a CO °' o N iI O p o o o o o o O o o o Ln O Ln Ln co -1. (ui'.jsn (AO (+)woN`/Z-)uinoS • • ---_ . - ' 4207 2S-04wp10[Lemon] 14k0 n x N .- I m J • 1\ i i C 0 o 1`A0{ to 0 W O o O N 11100 od 76 c 0 0 o U oo r u) 11000 (6 0 ^L^'' \W rim, o o 41100E o 0 0 0 0 J b 006 _ o Loma `V 00pg - 0 7r t �\ QQQ N 0 O D 09 M BOO X ` i oco x �QLo O 1-1-- I 1 o oo 0 CO (1) o 4.0 co —o N 0 0 0 0 0 00 0 0 LU o Lc) o y�daa jco ea!peA anal • • 1 2S-04wp10[Leman] O 4207• \. 00 .1.. 00, C< x a T CN in - 3000 VO LU W N 2000 O O O co 06 <a C _O LU w 1'000 N to TicsU N O O ti 0-000 E 4) JO u co 0 s000 CI 006 _ —O 44. 1 O 0008 (1l) O N co co --I— X O O O < - O O LU O LU < EU in O • • N N < ' M `p unde ° Ieai1aa^ ti al m co • • ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-04 Plan: 2S-04 Plan: 2S-04wp10[Lemon] Report - Basic 02 September, 2015 4111 • Report-Basic Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-04 Project: Kuparuk River Unit TVD Reference: Plan:120+28 @ 148.00usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: Plan:120+28 @ 148.00usft(Doyon 141) Well: Plan:2S-04 North Reference: True Wellbore: Plan:2S-04 Survey Calculation Method: Minimum Curvature Design: 2S-04wp 10[Lemon] Database: OAKE DM P2 Project Kuparuk River Unit,North Slope Alaska,United States System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor Site Kuparuk 2S Pad .4,86. .e,3..r?stre.i'.s.+.2,,- ie s.,.€i+w,v+:. A,.. a ci,..:_.....,..,--,rd:.� attMat w:82,PA se. . ... ma6,,,,b...,:t.✓-..x.ssa` ttaisnCOMd d aSBC .._... Site Position: From: Map Position Uncertainty: 0.00 usft Well Plan:2S-04 ,4401, Well Position +N/-S 0.00 usft +EI-W 0.00 usft Position Uncertainty 0.00 usft Wellbore Plan:2S-04 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2014 2/5/2015 18.80 80.80 57,550 Design 2S-04wp10[Lemon] Audit Notes: Version: Phase: PLAN Tie On Depth: 28.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 28.00 0.00 0.00 18.00 Survey Tool Program Date 9/2/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 28.00 1,000.00 2S-04wp10[Lemon](Plan:2S-04) GYD-GC-SS Gyrodata gyro single shots 1,000.00 2,000.00 25-04wp10[Lemon](Plan:2S-04) MWD MWD-Standard 1,000.00 2,831.36 2S-04wp10[Lemon](Plan:2S-04) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,831.36 4,331.36 2S-04wp10[Lemon](Plan:2S-04) MWD MWD-Standard 2,831.36 7,964.25 2S-04wp10[Lemon](Plan:2S-04) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7,964.25 9,464.25 2S-04wp10[Lemon](Plan:2S-04) MWD MWD-Standard 7,964.25 14,207.48 2S-04wp10[Lemon](Plan:2S-04) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey Comments apply , the line before it. MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 28.00 0.00 0.00 28.00 -120.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 -48.00 0.00 0.00 0.05 200.00 0.00 0.00 200.00 52.00 0.00 0.00 0.20 239.00 0.00 0.00 239.00 91.00 0.00 0.00 0.34 top T-3 Sand 300.00 0.00 0.00 300.00 152.00 0.00 0.00 0.34 9/2/2015 12:03:12PM Page 2 COMPASS 5000.1 Build 74 • • Report-Basic Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-04 Project: Kuparuk River Unit TVD Reference: Plan:120+28 @ 148.00usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: Plan:120+28©148.00usft(Doyon 141) Well: Plan:2S-04 North Reference: True Wellbore: Plan:2S-04 Survey Calculation Method: Minimum Curvature Design: 2S-04wp 10[Lemon] Database: OAKE D M P2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (°) (usft) (usft) (°/100usft) (0) (usft) 373.00 0.00 0.00 373.00 225.00 0.00 0.00 0.49 K-15 Marker 400.00 0.00 0.00 400.00 252.00 0.00 0.00 0.49 500.00 0.00 0.00 500.00 352.00 0.00 0.00 0.63 600.00 0.00 0.00 600.00 452.00 0.00 0.00 0.78 KOP:Start 1.5°/100'DLS,200°TF,for 200.09' 700.00 1.50 200.00 699.99 551.99 1.50 200.00 0.86 800.00 3.00 200.00 799.91 651.91 1.50 0.00 0.89 800.09 3.00 200.00 800.00 652.00 1.50 0.00 0.89 Start 2.5°/100'DLS,0°TF,for 200.99' 900.00 5.50 200.00 899.63 751.63 2.50 0.00 0.95 1,000.00 8.00 200.00 998.93 850.93 2.50 0.00 0.99 1,001.09 8.03 200.00 1,000.00 852.00 2.50 0.00 1.00 Adjust TF to 10°,for 484.32' 1,100.00 10.47 202.36 1,097.62 949.62 2.50 10.00 1.06 1,200.00 12.95 203.85 1,195.53 1,047.53 2.50 7.67 1.21 1,300.00 15.44 204.87 1,292.47 1,144.47 2.50 6.21 1.47 1,371.41 17.22 205.42 1,361.00 1,213.00 2.50 5.23 1.82 Base permafrost(?) 1,400.00 17.93 205.61 1,388.25 1,240.25 2.50 4.70 1.82 1,485.40 20.06 206.10 1,469.00 1,321.00 2.50 4.52 2.18 Hold for 106.46' 1,500.00 20.06 206.10 1,482.71 1,334.71 0.00 0.00 2.25 1,591.86 20.06 206.10 1,569.00 1,421.00 0.00 0.00 2.68 Start 3°/100'DLS,35.09°TF,for 875.12' 1,600.00 20.26 206.50 1,576.64 1,428.64 3.00 35.09 2.72 1,700.00 22.79 210.91 1,669.67 1,521.67 3.00 34.71 3.22 1,800.00 25.41 214.47 1,760.95 1,612.95 3.00 30.60 3.78 1,900.00 28.11 217.40 1,850.23 1,702.23 3.00 27.35 4.40 2,000.00 30.86 219.85 1,937.27 1,789.27 3.00 24.74 5.10 2,019.54 31.40 220.28 1,954.00 1,806.00 3.00 22.61 2.83 Top W Sak(W Sak D) 2,100.00 33.65 221.93 2,021.84 1,873.84 3.00 22.24 2.83 2,200.00 36.46 223.72 2,103.70 1,955.70 3.00 20.85 3.16 2,300.00 39.30 225.29 2,182.62 2,034.62 3.00 19.38 3.53 2,400.00 42.16 226.68 2,258.39 2,110.39 3.00 18.14 3.92 2,466.98 44.09 227.53 2,307.27 2,159.27 3.00 17.08 4.19 Hold for 1648.41' 2,500.00 44.09 227.53 2,330.99 2,182.99 0.00 0.00 4.33 2,600.00 44.09 227.53 2,402.82 2,254.82 0.00 0.00 4.75 2,700.00 44.09 227.53 2,474.64 2,326.64 0.00 0.00 5.17 2,761.75 44.09 227.53 2,519.00 2,371.00 0.00 0.00 5.59 Base W Sak 2,800.00 44.09 227.53 2,546.47 2,398.47 0.00 0.00 5.59 2,831.36 44.09 227.53 2,569.00 2,421.00 0.00 0.00 6.02 10-3/4"x 13.1/2" 9/2/2015 12:03:12PM Page 3 COMPASS 5000.1 Build 74 • • Report-Basic Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-04 Project: Kuparuk River Unit TVD Reference: Plan:120+28 @ 148.O0usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: Plan:120+28 @ 148.O0usft(Doyon 141) Well: Plan:2S-04 North Reference: True Wellbore: Plan:2S-04 Survey Calculation Method: Minimum Curvature Design: 2S-04wp10[Lemon] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 2,900.00 44.09 227.53 2,618.30 2,470.30 0.00 0.00 6.02 3,000.00 44.09 227.53 2,690.13 2,542.13 0.00 0.00 6.57 3,100.00 44.09 227.53 2,761.96 2,613.96 0.00 0.00 7.24 3,133.47 44.09 227.53 2,786.00 2,638.00 0.00 0.00 7.99 C-80 3,200.00 44.09 227.53 2,833.79 2,685.79 0.00 0.00 7.99 3,300.00 44.09 227.53 2,905.62 2,757.62 0.00 0.00 8.82 3,400.00 44.09 227.53 2,977.44 2,829.44 0.00 0.00 9.69 3,500.00 44.09 227.53 3,049.27 2,901.27 0.00 0.00 10.60 3,600.00 44.09 227.53 3,121.10 2,973.10 0.00 0.00 11.54 3,700.00 44.09 227.53 3,192.93 3,044.93 0.00 0.00 12.50 3,800.00 44.09 227.53 3,264.76 3,116.76 0.00 0.00 13.47 3,900.00 44.09 227.53 3,336.59 3,188.59 0.00 0.00 14.46 4,000.00 44.09 227.53 3,408.42 3,260.42 0.00 0.00 15.47 4,100.00 44.09 227.53 3,480.24 3,332.24 0.00 0.00 16.48 4,115.39 44.09 227.53 3,491.30 3,343.30 0.00 0.00 16.64 Start 3°/100'DLS,145.35°TF,for 3848.87' 4,200.00 42.02 229.69 3,553.13 3,405.13 3.00 145.35 17.27 4,300.00 39.63 232.47 3,628.80 3,480.80 3.00 143.78 17.77 4,400.00 37.32 235.54 3,707.09 3,559.09 3.00 141.67 9.24 4,500.00 35.09 238.94 3,787.79 3,639.79 3.00 139.27 9.22 4,600.00 32.97 242.74 3,870.67 3,722.67 3.00 136.52 9.17 4,700.00 30.98 246.97 3,955.50 3,807.50 3.00 133.38 9.06 4,800.00 29.14 251.71 4,042.06 3,894.06 3.00 129.78 8.89 4,869.37 27.97 255.32 4,103.00 3,955.00 3.00 125.68 8.62 C-50 4,900.00 27.49 257.00 4,130.11 3,982.11 3.00 122.51 8.62 5,000.00 26.06 262.86 4,219.40 4,071.40 3.00 121.02 8.25 5,100.00 24.89 269.29 4,309.70 4,161.70 3.00 115.79 7.77 5,200.00 24.02 276.22 4,400.74 4,252.74 3.00 109.99 7.17 5,300.00 23.48 283.56 4,492.29 4,344.29 3.00 103.67 6.50 5,400.00 23.30 291.10 4,584.09 4,436.09 3.00 96.95 5.79 2S-Wobbegong 6.Toe 061214 BP-2S_W16-Toe 5,429.78 23.32 293.36 4,611.45 4,463.45 3.00 90.03 5.15 2S-Wobbegong Toe 050714 PB 5,430.39 23.32 293.41 4,612.00 4,464.00 3.00 87.95 5.15 C-40 5,439.31 23.33 294.08 4,620.20 4,472.20 3.00 87.91 5.15 2S-Wobbegong 4.T3 050714 PB-2S-Wobbegong 5.14 050714 PB 5,500.00 23.48 298.65 4,675.90 4,527.90 3.00 87.29 5.15 5,583.10 23.90 304.77 4,752.00 4,604.00 3.00 83.10 4.67 C-37-2S-Wobbegong 3.72 050714 PB 5,600.00 24.02 305.99 4,767.45 4,619.45 3.00 77.49 4.67 5,649.56 24.41 309.48 4,812.65 4,664.65 3.00 76.38 4.42 2S-Wobbegong 2.T1 050714 PB 9/2/2015 12:03:12PM Page 4 COMPASS 5000.1 Build 74 • • Report-Basic Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-04 Project: Kuparuk River Unit TVD Reference: Plan:120+28 @ 148.00usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: Plan:120+28 @ 148.00usft(Doyon 141) Well: Plan:2S-04 North Reference: True Wellbore: Plan:2S-04 Survey Calculation Method: Minimum Curvature Design: 2S-04wp 10[Lemon] Database: OAKE DM P2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (0) (usft) (usft) (°1100usft) (0) (usft) 5,700.00 24.88 312.93 4,858.50 4,710.50 3.00 73.19 4.42 5,735.08 25.26 315.25 4,890.28 4,742.28 3.00 70.06 4.43 2S_W16-Heel 5,751.35 25.45 316.30 4,904.97 4,756.97 3.00 67.96 4.43 2S-Wobbegong 1.HeeI 061214 BP 5,776.32 25.75 317.89 4,927.50 4,779.50 3.00 67.01 4.43 2S-Wobbegong Heel 060114 BP 5,789.10 25.91 318.69 4,939.00 4,791.00 3.00 65.58 4.43 Growler-AA 5,800.00 26.05 319.36 4,948.80 4,800.80 3.00 64.86 4.43 5,900.00 27.48 325.23 5,038.10 4,890.10 3.00 64.25 4.64 5,929.40 27.94 326.84 5,064.13 4,916.13 3.00 59.01 4.97 2S-Wobbegong Heel 050714 PB 6,000.00 29.13 330.51 5,126.16 4,978.16 3.00 57.59 4.97 6,100.00 30.96 335.26 5,212.73 5,064.73 3.00 54.36 5.36 6,200.00 32.95 339.50 5,297.58 5,149.58 3.00 50.25 5.75 6,300.00 35.07 343.30 5,380.47 5,232.47 3.00 46.65 6.13 6,400.00 37.30 346.70 5,461.19 5,313.19 3.00 43.50 6.49 6,430.07 37.99 347.66 5,485.00 5,337.00 3.00 40.75 6.83 Top Cairn 6,500.00 39.61 349.78 5,539.50 5,391.50 3.00 39.99 6.83 6,525.42 40.21 350.51 5,559.00 5,411.00 3.00 38.34 7.15 Top Bermuda 6,600.00 42.00 352.56 5,615.19 5,467.19 3.00 37.78 7.15 6,634.96 42.85 353.47 5,641.00 5,493.00 3.00 36.24 7.46 Base Bermuda 6,690.13 44.20 354.85 5,681.00 5,533.00 3.00 35.57 7.46 C-35 6,700.00 44.45 355.09 5,688.06 5,540.06 3.00 34.56 7.46 6,800.00 46.95 357.41 5,757.90 5,609.90 3.00 34.39 7.75 6,900.00 49.49 359.54 5,824.53 5,676.53 3.00 32.77 8.03 7,000.00 52.07 1.52 5,887.76 5,739.76 3.00 31.35 8.32 7,100.00 54.68 3.36 5,947.41 5,799.41 3.00 30.10 8.60 7,200.00 57.32 5.09 6,003.33 5,855.33 3.00 29.00 8.89 7,254.16 58.75 5.99 6,032.00 5,884.00 3.00 28.03 9.19 Top HRZ(K-2 mkr) 7,300.00 59.98 6.72 6,055.36 5,907.36 3.00 27.56 9.19 7,399.22 62.63 8.25 6,103.00 5,955.00 3.00 27.18 9.49 Upper Kalubik(base HRZ) 7,400.00 62.65 8.26 6,103.36 5,955.36 3.00 26.45 9.49 7,500.00 65.35 9.73 6,147.19 5,999.19 3.00 26.44 9.81 7,600.00 68.05 11.14 6,186.75 6,038.75 3.00 25.80 10.14 7,700.00 70.77 12.49 6,221.91 6,073.91 3.00 25.24 10.48 7,767.14 72.60 13.38 6,243.00 6,095.00 3.00 24.77 10.84 Lower Kalubik(K-1 mkr) 7,800.00 73.50 13.80 6,252.58 6,104.58 3.00 24.49 10.84 9/2/2015 12:03:12PM Page 5 COMPASS 5000.1 Build 74 0 • Report-Basic Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-04 Project: Kuparuk River Unit TVD Reference: Plan:120+28 @ 148.00usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: Plan:120+28 @ 148.00usft(Doyon 141) Well: Plan:2S-04 North Reference: True Wel(bore: Plan:2S-04 Survey Calculation Method: Minimum Curvature Design: 2S-04wp10[Lemon] Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 7,900.00 76.24 15.08 6,278.68 6,130.68 3.00 24.36 11.21 7,964.25 78.00 15.88 6,293.00 6,145.00 3.00 24.03 11.30 Hold for 20'-7-5/8"X 9-7/8" 7,984.25 78.00 15.88 6,297.16 6,149.16 0.00 23.85 11.29 Start 4.5°/100'DLS,35.46°TF,for 37.07' 8,000.00 78.58 16.30 6,300.35 6,152.35 4.50 35.46 11.28 8,021.32 79.36 16.86 6,304.43 6,156.43 4.50 35.37 11.27 Hold for 8.85' 8,030.17 79.36 16.86 6,306.07 6,158.07 0.00 0.00 11.27 Start 4°/100'DLS,7.77°TF,for 117.05' 8,100.00 82.13 17.25 6,317.30 6,169.30 4.00 7.77 11.33 8,112.84 82.64 17.31 6,319.00 6,171.00 4.00 7.71 11.42 Kuparuk C(Top C4) 8,147.22 84.00 17.50 6,323.00 6,175.00 4.00 7.70 11.42 Adjust TF to 3.38°,for 161.16'-2S-Lemon 1.Heel 8,200.00 86.11 17.62 6,327.55 6,179.55 4.00 3.38 11.57 8,224.40 87.08 17.68 6,329.00 6,181.00 4.00 3.36 11.98 A4 8,300.00 90.10 17.86 6,330.86 6,182.86 4.00 3.36 11.98 8,308.38 90.44 17.88 6,330.82 6,182.82 4.00 3.36 12.02 Hold for 5899.11' 8,400.00 90.44 17.88 6,330.12 6,182.12 0.00 0.00 12.55 8,500.00 90.44 17.88 6,329.36 6,181.36 0.00 0.00 13.25 8,600.00 90.44 17.88 6,328.60 6,180.60 0.00 0.00 14.08 8,700.00 90.44 17.88 6,327.84 6,179.84 0.00 0.00 15.00 8,800.00 90.44 17.88 6,327.08 6,179.08 0.00 0.00 16.00 8,900.00 90.44 17.88 6,326.32 6,178.32 0.00 0.00 17.07 9,000.00 90.44 17.88 6,325.56 6,177.56 0.00 0.00 18.19 9,100.00 90.44 17.88 6,324.80 6,176.80 0.00 0.00 19.36 9,200.00 90.44 17.88 6,324.04 6,176.04 0.00 0.00 20.57 9,300.00 90.44 17.88 6,323.29 6,175.29 0.00 0.00 21.80 9,400.00 90.44 17.88 6,322.53 6,174.53 0.00 0.00 23.07 9,500.00 90.44 17.88 6,321.77 6,173.77 0.00 0.00 13.86 9,600.00 90.44 17.88 6,321.01 6,173.01 0.00 0.00 14.20 9,700.00 90.44 17.88 6,320.25 6,172.25 0.00 0.00 14.56 9,800.00 90.44 17.88 6,319.49 6,171.49 0.00 0.00 14.93 9,900.00 90.44 17.88 6,318.73 6,170.73 0.00 0.00 15.31 10,000.00 90.44 17.88 6,317.97 6,169.97 0.00 0.00 15.71 10,100.00 90.44 17.88 6,317.21 6,169.21 0.00 0.00 16.11 10,200.00 90.44 17.88 6,316.45 6,168.45 0.00 0.00 16.53 10,300.00 90.44 17.88 6,315.69 6,167.69 0.00 0.00 16.95 10,400.00 90.44 17.88 6,314.93 6,166.93 0.00 0.00 17.38 10,500.00 90.44 17.88 6,314.17 6,166.17 0.00 0.00 17.83 10,600.00 90.44 17.88 6,313.41 6,165.41 0.00 0.00 18.28 10,700.00 90.44 17.88 6,312.65 6,164.65 0.00 0.00 18.73 9/2/2015 12.:03:12PM Page 6 COMPASS 5000.1 Build 74 • • Report-Basic Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-04 Project: Kuparuk River Unit TVD Reference: Plan:120+28 @ 148.00usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: Plan:120+28 @ 148.Oousft(Doyon 141) Well: Plan:2S-04 North Reference: True Wellbore: Plan:2S-04 Survey Calculation Method: Minimum Curvature Design: 2S-04wp 10[Lemon] Database: OAKE DM P2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (0) (usft) 10,800.00 90.44 17.88 6,311.89 6,163.89 0.00 0.00 19.19 10,900.00 90.44 17.88 6,311.13 6,163.13 0.00 0.00 19.66 11,000.00 90.44 17.88 6,310.37 6,162.37 0.00 0.00 20.14 11,100.00 90.44 17.88 6,309.61 6,161.61 0.00 0.00 20.61 11,200.00 90.44 17.88 6,308.85 6,160.85 0.00 0.00 21.10 11,300.00 90.44 17.88 6,308.09 6,160.09 0.00 0.00 21.59 11,400.00 90.44 17.88 6,307.33 6,159.33 0.00 0.00 22.08 11,500.00 90.44 17.88 6,306.57 6,158.57 0.00 0.00 22.57 11,600.00 90.44 17.88 6,305.81 6,157.81 0.00 0.00 23.07 11,700.00 90.44 17.88 6,305.05 6,157.05 0.00 0.00 23.58 11,800.00 90.44 17.88 6,304.29 6,156.29 0.00 0.00 24.08 11,900.00 90.44 17.88 6,303.53 6,155.53 0.00 0.00 24.59 12,000.00 90.44 17.88 6,302.77 6,154.77 0.00 0.00 25.11 12,100.00 90.44 17.88 6,302.01 6,154.01 0.00 0.00 25.62 12,200.00 90.44 17.88 6,301.25 6,153.25 0.00 0.00 26.14 12,300.00 90.44 17.88 6,300.49 6,152.49 0.00 0.00 26.66 12,400.00 90.44 17.88 6,299.73 6,151.73 0.00 0.00 27.18 12,500.00 90.44 17.88 6,298.97 6,150.97 0.00 0.00 27.71 12,600.00 90.44 17.88 6,298.21 6,150.21 0.00 0.00 28.23 12,700.00 90.44 17.88 6,297.45 6,149.45 0.00 0.00 28.76 12,800.00 90.44 17.88 6,296.69 6,148.69 0.00 0.00 29.29 12,900.00 90.44 17.88 6,295.93 6,147.93 0.00 0.00 29.82 13,000.00 90.44 17.88 6,295.17 6,147.17 0.00 0.00 30.36 13,100.00 90.44 17.88 6,294.41 6,146.41 0.00 0.00 30.89 13,200.00 90.44 17.88 6,293.65 6,145.65 0.00 0.00 31.43 13,300.00 90.44 17.88 6,292.89 6,144.89 0.00 0.00 31.96 13,400.00 90.44 17.88 6,292.13 6,144.13 0.00 0.00 32.50 13,500.00 90.44 17.88 6,291.38 6,143.38 0.00 0.00 33.04 13,600.00 90.44 17.88 6,290.62 6,142.62 0.00 0.00 33.58 13,700.00 90.44 17.88 6,289.86 6,141.86 0.00 0.00 34.13 13,800.00 90.44 17.88 6,289.10 6,141.10 0.00 0.00 34.67 13,900.00 90.44 17.88 6,288.34 6,140.34 0.00 0.00 35.21 14,000.00 90.44 17.88 6,287.58 6,139.58 0.00 0.00 35.76 14,100.00 90.44 17.88 6,286.82 6,138.82 0.00 0.00 36.31 14,200.00 90.44 17.88 6,286.06 6,138.06 0.00 0.00 36.85 14,207.48 90.44 17.88 6,286.00 6,138.00 0.00 0.00 36.89 TD:14207.48'MD,6286'TVD-4-1/2"x 63/4"-2S-Lemon 2.Toe 9/2/2015 12:03:12PM Page 7 COMPASS 5000.1 Build 74 • • Report-Basic Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-04 Project: Kuparuk River Unit TVD Reference: Plan.120+28 @ 148.00usft(Doyon 141) Site: Kuparuk 2S Pad MD Reference: Plan:120+28©148.00usft(Doyon 141) Well: Plan:2S-04 North Reference: True Wellbore: Plan:2S-04 Survey Calculation Method: Minimum Curvature Design: 2S-04wp10[Lemon] Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") ('•) 2,831.36 2,569.00 10-3/4"x 13-1/2" 10-3/4 13-1/2 7,964.25 6,293.00 7-5/8"X 9-7/8" 7-5/8 9-7/8 14,207.48 6,286.00 4-1/2"x6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (0) (0) 5,430.39 4,612.00 C-40 373.00 373.00 K-15 Marker 0 0 6,525.42 5,559.00 Top Bermuda 2,019.54 1,954.00 Top W Sak(W Sak D) 239.00 239.00 top T-3 Sand 0.00 6,430.07 5,485.00 Top Cairn 8,224.40 6,329.00 A4 6,690.13 5,681.00 C-35 6,634.96 5,641.00 Base Bermuda 7,254.16 6,032.00 Top HRZ(K-2 mkr) 5,583.10 4,752.00 C-37 5,789.10 4,939.00 Growler-AA 4,869.37 4,103.00 C-50 7,399.22 6,103.00 Upper Kalubik(base HRZ) 7,767.14 6,243.00 Lower Kalubik(K-1 mkr) 3,133.47 2,786.00 C-80 1,371.41 1,361.00 Base permafrost(?) 2,761.75 2,519.00 Base W Sak 8,112.84 6,319.00 Kuparuk C(Top C4) Plan Annotations Measured Vertical Local Coordinates Depth Depth +NI-S +E/-W (usft) (usft) (usft) (usft) Comment 600.00 600.00 0.00 0.00 KOP:Start 1.50/100'DLS,200°TF,for 200.09' 800.09 800.00 -4.92 -1.79 Start 2.5°/100'DLS,0°TF,for 200.99' 1,001.09 1,000.00 -23.07 -8.40 Adjust TF to 10°,for 484.32' 1,485.40 1,469.00 -129.83 -56.68 Hold for 106.46' 1,591.86 1,569.00 -162.62 -72.74 Start 3°/100'DLS,35.09°TF,for 875.12' 2,466.98 2,307.27 -509.03 -368.51 Hold for 1648.41' 4,115.39 3,491.30 -1,283.38 -1,214.51 Start 30/100'DLS,145.35°TF,for 3848.87' 7,964.25 6,293.00 141.56 -1,957.37 Hold for 20' 7,984.25 6,297.16 160.38 -1,952.02 Start 4.5°/100'DLS,35.46°TF,for 37.07' 8,021.32 6,304.43 195.25 -1,941.77 Hold for 8.85' 8,030.17 6,306.07 203.57 -1,939.25 Start 40/100'DLS,7.77°TF,for 117.05' 8,147.22 6,323.00 314.19 -1,905.04 Adjust TF to 3.38°,for 161.16' 8,308.38 6,330.82 467.46 -1,856.15 Hold for 5899.11' 14,207.48 6,286.00 6,081.53 -45.16 TD:14207.48'MD,6286'TVD Checked By: Approved By: Date: 9/2/2015 12:03:12PM Page 8 COMPASS 5000.1 Build 74 • • N CL rs 2. I c O sio p c /' m N v a a c v 0 N d _E v N O U J a O /rte y W O •Y ` a x m o Ix o o N d O p O Z o £ N c CU L y LE Q c O • N r. y 3 T c N E ma . a � . c a O p 7 a V+ c• o T . y 3 T, N Q ,- a Q 0 c U R H m m W ■. c d 0 0 0 J C o . o 2 c d a n_ - ++ p 0. 'TN0 N N p V W CL ^C ■ LO N Ud w W J O r E 3 N n .�'� N -.! L ■NMI c 7( m c N = Q n LL Q. N N Q p. 2 4 ¢ J O J a = ° a m o /1 I- CO T' w� i CL Y c a r` .5 .5 0 C V Ce N O O CV 0 r m r /� d p al a o -- Lc (7 N O Y Y N � Q V E Z 'y ., o a m o d N L N O • L L N N . w 4'� D. 1:3E 0 'a U) "' a s O CO ' ` a N V = = 5 w Lp A O N l0 % 1 Y a a N V N 3`° " RI (7 p °' 011 Ci L' o re 0 y CO CD > CO 0 • • N :"'' 0. C cn a a m x 0 co �, .1Y .Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y eet )�y G N N N N N N N N N N N N N N V) N N N tll N N N N J) N N N N (C - d' 0.' d' a: a: a: K K a a a a LL' red' Q' 2' cC Q' Q: LL' K a W c Q_ Q' 2' O O O 8888cot N m O m m m Om Om m m m m ,m m m m m O _ai O m m m m m m m ma 0) 111111 C/) N N N N N NN N N N N N N N N N N N N N N N N N N CO CO N Q, N N N N N N N N N N N N N N N N N N N N N N N N CO N N N W N N C3 N N C) N N N N (a a) N N 03 4 I W N N N N () CO N (a N N a a a a a a a a a a a a a a a a a a a a a a a a a a a a n. O 0o I.) a 0 aE ° ° ° ° d i) d U d t, d 3 d U d U d U d U d CJ d U d U o U U d U C m E CN C CICa CaC (aCa CN C N CN C NC (aCO C N C (a U 2' C (a lL O LL (a LL O LL LL (a L.L. (a LL N a N LL Lo LL O LL s, (L (a LL a E N d N a) y a) N a) N a) N a) N a) N d N d N d 0 a) N a) m d N d oUOOao000 ° aoO ° 0OOOa OiOo0o0 ° 0O E ` 2 d N d N d N d N d N d N d N ` 2 d d 2 d N d N d N O C o C N C f0 C o C N C N C O C O C O C N C U) E. O C N C a 0 d d d d as d d d d d d d w d d d d d d d d d d d d d d d 000000 000000 000000 000000 0000 co (O O O r C) A- 00 M O 0 CO V C) M CO (0 r h. O O N- O V d co CO O) CO CO V) 0) N O N I� N- O W O) CO CO CO CO CO N. O) CO O) N co U) N (N M r (O (0 CO N (O (O CO CO CO CO CO N. CO N- CO f� N. M (° r (n CO R• r N N- V V (0 N V M N N V V V V) (O C n O c O r r m (O O (O (O V. o .- c- .- co M co N V V R N d LL 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 a o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O (O M M O O O N O O N O O M (O O U1 O (O V) (O N O O (O (O (O O c▪ L (O N N N O O (O h (O O N (O (O N- N O N O r N N- N N M NI--- NO $ N CO CO V CO V M V N- 00 N I V CO V ..0 N- N CO CO CO CO CO V CO CO CO V (yo •.-',-, i� s- A- N-A - N N- i p 8 V V C) (O CO CO (O O 4') (O O N CO M CO C) N. h. C) U) (O (O (O C) C) Cr V CO C V CO V V CO V CO V N O (O CO O N 0) n N. V CO CO CO CO N. C) V CO V CO d 0 N N. CO V M M N O co M CO N N M CO V V M C) M C) M N V V (O . y M (O V V CO M N N V V s CO O O N N O C) O O CO CO () co M N a i .'� r .- .-- -- N � N A-- NN NNNN U) w d CO U) `o O M O C) O C) O N O C) N C) O (O M N M O (O O (O O C) O N O M N a (O V O C) O C) O C) V V N O O 00 CO N Oh- O O O O O O O M O C) 2 O (O U) V O o) 6 V O O (n 6 6 6i I� N V M M M M M O Ci (n (n (O a) O L co N N N O M (O n (O O N (O (O CO O CO r O r r A- u) V N N. N C) y a$ N CO CO V CO CO CO V CO n N- V N l0 CO C) CO C) CO V CO (O CO (O an d 7 ^ r — - r N N d Q -Fal 6 r`+ £ C N (MO N- (°O COM ((°O 00 O) (OO O - M V V N M W m M N. (° n CO O N- N M CO O E d C C) C) O C O C) o CO C 6) m O (O N N O co O M O O O N y O C (O (O (O (D CO C) N CO N N (O (O N CO CO CO V V N N V V N- N r N �(�E NNNNNN NNNN C £ IO y .- .- .- N— x— W O Ewa, Va %Q O a d A O c6 O co O W O C) O M O O N C) O (O M N M O (O O (O O C) O N O 00 E co a $ (O (O V O W O C) O O V V NO O CO CO N O O O O O O C) COMOO d y L O (O V O O O V O O l0 O O 6) I- N (O V M M M M O O (1') O (O ( U C h N N N O M (O N M O N (O (O (O O M N- C) N- r (O V N N- N C) C p y a y N CO CO V CO CO CO V N. M r r V N (O (O CO O CO C) CO V CO (O M (O d W N 0 7 N. ,- ,-- N N CO C C 4 N t N d O ( O ? (oj) c Cl)IW N = L L C C V) N a 'B > > 0 O C coca O) O) > > N y C1 $ C d d C C - l OO i a L 2 .0) 00 cL L` O0t a a 0 ° C ° a ° y v o o d aas ° a a m m o o E E a s mC7 7 'CI -0 O 03 4o E E y 2 E E E E ` B a a is = = oo2 2 N a m co > > CiOm 0 0 ` m D M d U d£ as.3 co I _ Fr 77 oco 2 0 0 L $ L L O N N M a a O UC a 23 Z OO co OOOO OoJOO .- A- JJ co) N a s a a a a a a a a a a a a a s a s a a M M ° c dO 2 2 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 - - 3 3 3 3 L L CO CO (() (O (O CO CO CO 6) C) O O ,- N N CO CO C a • a HF O O O O O O O O O O O O A- s- .- . U) UJ .- .- .- .-- NNRC7W U) UUU / / UUn OW UUUUUN N co UUU Tis Q0co a 7 V NN NNNNNN NNNNNN NN NN NN CL :' NV oo ,- x- M CO (O (O (D CO CO CO C) C) O O = = r ,- N N CO CO CO CO 0) £ i 2,- $ d 33O0 000000 OOOOx- A- = = = A- r- r- A- A IN E N N N N U) U) U) co co co co co co co co co co co U) U) U) U) U) U) co U) U) co (() Q C. y N 2 a O O O O N N NNNNNN N N N N N N N N N N N N NNNN O a 7 ,- m _ U) U) U) (ACC C CCCCCC CCCCCC CCCCEC CCCC N w y 0. N N N N C7 (a CS (a (a CS W N (a (a (0 N (a (a (a (a N la ca C) (a 07 N O s a C a a a a a a a a a a a a d a a a a o n a s a) E 3 Cl)N . Z O CO N O O O O . M M (O (O (O M M M C) m C C N N M M M M E COv� .y C y d y Y U) Co Cl) co O O O O O O O O O O O O - - - - Cl y 0 'y £ L N N N N U) U) U) U) U) U) U) U) co U) U) O U) U) U) U) O U) U) O) C C U) U) 0. Q a 7 C) C7 NN N N N N NN NNNNNN N NCV NNN NNNN d C d CO Z Ea Q. N N N N .. .. .. .. .. .. CO £ O O O O C C C E C C C C C C C C C C C C C C C C C C C C (V U `I a "'' 0 U) U) U) U) co co O O co l9 (a co (a N co C7 co co N W C3 co W N (a co (0 U Y N N N N a a a a a a a a a a a a a a a a a a a a a a a a ▪C > d (Ca UG < C d o O F X U) y • • N O Q co 3.3. d o o 1-0 et 3 y0y c • ct N N N N N N N N N N WI R R o ,o• ` 0 0 0 0 0 ,0 0 0 0 a o m cl c m c m m m c I) N N N N N N N Cl) co) co) Co O CO CO CO CO O O O CO CO LL a LL LL a 0. a a LL LL 5.0 O c U a 0E ` N `o a ` o `o m CNNCNCmmO m E C c U 2+ C O LL O LL CO LL O LL 03 LL O 76 U . U 0 co .11 U O U E c c c 22 0 0 0 E 2 m 2 O m N O V O c <n � ( • C c c c aJ c P. I- N N N N 000000 0 0 0 U Z 0 0 0 o n 00 O) N CO N- CO V 7 (/) Q Q Q y 0) CO CO 00 0) N- n 0 (n Cl) U , (n n CO V N N O O 0) 0) 5 Q' CL LL' Co if) O 4 N (O M N N N N 0 LL LL LL V .-, (0 N d u_ o' 0 0 0 0 0 0 0 } 2i 0 0 0 0 0 0 0 0 0 0 a 0 0 0 0 0 0 0 0 0 0 O L N n 0 0 n h (00 N U) 0 .' M M M V N M CO. V 01. CO. N O O y u N r r r r g O 6 c v i+? (n0. n `- v 0) n (o a) Pi M 00) OM) ui N V V CO (() C.ja �' N N N N c`'.4 M w a— .— o ON O 0) O O M W V (v) a O co O O O O co n n it(] O 0) N O6 N M4 c a) O L N n 0 0) n U) CD V CO CO N a.' co N co co N M CO_ V N co„. d a B�pd N r r r r- d N L! 7 ✓, E u) C Ch.O N co W 1- CO0On) M N CO E W £ C e N N M M M M O O W W C O O 0• 'c W O �� J_ g Ci O C 0 0 0 0 0 0 0 a- EEEEE d /r/.� O 0 N 0 0) 0 0 CO CO VN- 0000) 00 N N N N N N O Yf. E y •O O M 0 0 0 0 C06- 1---- N- J J J J J J J N d N L )O O 0) (O O (O N M R 0 0 0 0 0 0 0 a U J O. O V N n O 0) n (n (O 4 co 6 N 8. W N O. 7 CO N M M N M CO 61 3 3 3 3 3 3 3 m w a! -6 O d cl 0 0 0 0 0 0 0 C • I .)`d.. 3 N 2 0 0 0 0 0 0 0 U N s. Cl) 0' Q 2 N N N co N N N a) p E I C N N L O N O . TD � 7 ggr ? a E o 0 co co 1n u) co ei 3 a) CO O CO 4 C O O M M N N V C C 2 1O N O O 4 V n •O 0 CM O O 0 0. aN O m0 CD N o y 0 0 m co 0) V N N >. '— a) 0, m O O C C ~ C 7 N N 7 n O) Vo 8 2 at o 'c) 2 0 0 _o ` 7 . C. 7 N) ,_ Ua s � N V ym E qaa ) 'RI ) Np ` C C 4 d d 2y6 ON d 3 Oa) ao 0 3 T 41 N A _ _ y 0 0 0 00 CO n (n ••ei N LL mm O LL LL n n co co 000MMNN 2 ` QN N O) LU aZ CO MOaaaCOC 2 C _ V N C 0NOc O c C- . N (NiN ENO CO 47 . 20 0 3 3 3 3 O O O coW a0 CO 0) N L C0NN0 ,- ,- NNnn O UOl aO L C a 4 O V' 10 / coCh 3 _ NNNN n n U O a ` O ' vo N a 3 U O] m 0) O) NN CO NOg • i � N a MM V V n n LLR • V fQC ..L, m 0 E I . O N 3 EUo n 6 cn o 0 0 o N N N N N N NO N 52 8 N CO OD. a N CO 6. CO Z CO CO CO O C a 3 0? — C C C C C C N N N N CO 6 N Y r y CO CO O CO O OK 0 N0 y . 0a) • O COO _ L N C II CN 2 •y EC oo w y aa CO d O n n n n Z OOOO G () U o. w O- O O 0 a C m LL U Q. C l N N N N N N NNNN 0 = Q - E C C C C C C ` c co co O w O aU o (NI NQQO O O d O a, = E V e i wc fl. U 49, N N < H & UM W U U) D U Q 12:59, September 02 2015 Lemon Ladder View 2S-04w 10 p 0[Lemon] The Reference Well is along the X—axis. rror Ellipses are the Sum of the Reference and Offset Well Errors a . ci-eo p m c E 0 E�'� � � m E . 1.311 z _ F i e3 33_3 3 3 7q�97 o q4 T o ..NN1 N grw'ww.' r E N W N nlll��1 III �I I f a111 Ir I IIII!i 1111IIIIIIDyIIUII IIIII�Y tea �I111 pt� Ii i i 300 unn°t .11111111111111111111111 "AlI IIIA ,d�111 11 P111111111111 �nnnllliillllll�l ]I f 1 OMNI f 11 I'll Uli ( II.IiIIII����liI11d11100Ill ,1111 o .....,.nmmNillllllll 1 fi 1,l' IIIilltii ro�.110111� �,oil :! IIIIII, II nnf ll IaIIIIIII,� I ....,.ntllnm�illllllllllllll111111oI ;�11�,►� r I'P ID I��IIIUul1 I I, i 1,1, if (I .....emmn°glglll 1 1;1111 lIliil fi 2 141 /I1II,1 X11 III SII (' 111 . Irv' t •I�lil�l�111 �22 ,,� ��1�IIIII 1l tit�� 1 1�i,lllllll: 1111I11!,'tlllllllllll,11rtualillll,ll1011 0 Equivelant Magnetic Distance 0 1500 3000 4500 6000 7500 9000 Displayed interval could be less than entire well:Measured Depth 28.00 To 14207.48 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 28.00 1000.00 25-04wp10[Lemon] (Plan: 2S-04) GYD-GC-SS 2569.0E831.36 10-3/4"x 13-1/2" 1000.00 2000.00 25-04wp10[Lemon] (Plan: 2S-04) MWD 6293.064.25 7-5/8"X 9-7/8" 1000.00 2831.36 25-04wp10[Lemon] (Plan: 2S-04) MWD+IFR-AK-CAZ-SC 6286124207.48 4-1/2"x 6-3/4" 2831.36 4331.36 25-04wp10[Lemon] (Plan: 2S-04) MWD 2831.36 7964.25 25-04wp10[Lemon] (Plan: 2S-04) MWD+IFR-AK-CAZ-SC 7964.25 9464.25 25-04wp10[Lemon] (Plan: 2S-04) MWD 7964.2514207.48 25-04wp10[Lemon] (Plan: 2S-04) MWD+IFR-AK-CAZ-SC 1 a E..2 62 g n s ss m 8 N 3 33 a 9 9 99 9 N M non M N N NV N �!II 11111111/14 II4111//1111111' I ' •11nIItci . ;1 At y : U 30 ,• 11111111111 I 10.101.d , 0 2 - -4111 a, 1 0 I , I I I I I I I I I I I 1 1 1 I I I I I I I I I . I 1 I I 1 TJ 0 500 1000 1500 2000 2500 3000 3500 Partial Measured Depth Equivelant Magnetic Distance "mil2S-04wp10[Lemon] MD Inc Azi TVD Dleg TFace Target 600 790 28.00 0.00 0.00 28.00 0.00 0.00 28.00 To 14207.48 600.00 0.00 0.00 600.00 0.00 0.00 790 970 800.09 3.00 200.00 800.00 1.50 200.00 970 1160 1001.09 8.03 200.00 1000.00 2.50 0.00 13:01,September 02 2015 1485.40 20.06 206.10 1469.00 2.50 10.00 1160 1340 1591.86 20.06 206.10 1569.00 0.00 0.00 _ _ CASING DETAILS 2466.98 44.09 227.53 2307.27 3.00 35.09 1340 "� 1530 TVD MD Name 4115.39 44.09 227.53 3491.30 0.00 0.00 1530 -- 1710 2569.00 2831.36 10-3/9" x 13-1/2" 7964.25 78.00 15.88 6293.00 3.00 145.35 6293.00 7969.25 7-5/8" X 9-7/6" 7984.25 78.00 15.88 6297.16 0.00 0.00 1710 "- 1900 6286.00 14207.48 9-1/2" x 6-3/4" 8021.32 79.36 16.86 6304.43 4.50 35.46 8030.17 79.36 16.86 6306.07 0.00 0.00 1900 2430 8147.22 84.00 17.50 6323.00 4.00 7.77 25-Lemon 1.Heel aaEYrroG 8308.38 90.44 17.88 6330.82 4.00 3.38 2430 2950 wzn To s n.v,e,� o0 14207.48 90.44 17.88 6286.00 0.00 0.00 2S-Lemon 2.Toe 2950 3480 9pi0[r�0t (Plan:xe-0a.m«xec-.x-<u-s< -I.5»2pla(t1�ln], ,a>o:240 2031 36 4331 36 3480 - 4000o,�atm t (Plan 25-o.� 6:s9 0410( ,Pian -04,�.IPP-.e-�-5< :s =e,;a 22-04510 1] (Plan 2S-49(9 4000 4530 4530 5050 5050 5580 2S-06wp06 [Salmon] 2S-10wp12 [Wobbegong] 5580 6100 6100 7160 • -0/360 2S-03wp06 [Bamboo] 7160 8210 •� 711. �. 8210 9270 �iiSre.114 ,>: 9270 10320 -30/330 4).,•`!•. v,1,...--_-ami.-ms., '' 30 `c j�`�eE�►�...r1,i��.�r 4 10320 11380 A4®�®n* `pati ii.LW_`l/��►ii 11380 12430 ® �Lt►.' �r/� =.1�i 1� 12430 13490 ,/ �3;..+ I-- '•r qm \ilk, _AlOVAIV/AVOM.-4•V 111" 1,1 `004P/7 13490 - 14542 60/300 ���$®,ps, zr *'1;�1s•4�:�yp1. ®t,���®� a ►AZT 62S-01wp07 [Mako] ( 'q ►%lk.tr 1►jlirttS 12.90 o�„'w 2S-02wp08.1 [Thresher] 10IliarifftetititillpillitOk( Aka .''..t 'tv. ,45;s4 -1:::.4.1'.:,,-4._. ' 90/270 /da I? ,• ti ✓ / pp�1190 1.;`�^!A4.- ,'w �, '"` (, ,� s ir;' i;sd 4150 r itr.---imp.....1•Stiftl► i ''''-Trot ii.-,-41-,..,T:11,1•fr.:;.4..-4-.1,f,•041 ..t, S¢ • . 1a I; • • i fI.M- (��fff _ -10' --- 00,4%,'4"•••!!'� V . 4,l I r a f y fuer`i ',P IlitiVitl.._ i,•w,. / �i •c 9��?� -°-,j*tt.��1�� �i r r .tea. ! 3.14%+ C�f r1, n7. f•;to..:_.;.4.10.,�,4 Ni..,0itt N._ i i .r, o! ../� •'moi Ott r �II,itoi��� �t11�� ������ ,�,,.�,s.�ti• �d 25-02 '44 rr ok t ve„,6-4.4:7,34:::-_..7„zstoivitireemt...:41:01,410„ a, ♦ % 4 fes' , r/7 rf' ,06.,;.4 AAA A k w 3 4�iO�A/:?'"Pi��„a. o•.t t%14 - f! • +®PA � -120/240 4 i 0s°1041I%/04 ii7�Initiri 'wo j/crOf0. �/>' , �®R°1 r 1 2P G w 4,".v.-i:...;--,- - �/ICr + 61, ��`\ tib - - ��1.., !S-08wp07 [Hammerhead , �'� �®` 1,ebm- S� -.,./�►.'i1,'�I 2S-05wp06 [Nurse] �.' -7,,,,,,;:, `�� `, 4*'ca '_►is I" .9 • -150/210 A :t;`;;� ���/ i %� ..:, 150 2S-11wp06 [Great White] v,;;;;; v���o�at% {' ' '' ��•ra� Rig: 2S-07 2S-11L1wp06 [Great White] 180/180 2S-07wp12.1 [Goblin] 2S-09wp06 [Tiger] • • Northing (3500 usftlin) 1 1 1 _I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I 111111111111111111111111111111111 I I I _I_i 1 I I 1 I 1 1 1 1 I , 1 1 1 I , I — co — I N o — - Y - - . — CO s_. t` _ cs - 0_ - - 0_ c 3 — D 13 Y U� o d� - m L N - N N 0) - N ^ N � - 9 - O i - N , 00 O C\I _ N Z O O rn o 3 No E ^03 - E' CD 1 O. 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C (*.) l`NP.71--- ! 4.4V 1 i I a C) 1 LO -..,A, co' 1 i Cg AL-- . tt cv I ..- 1 co al LLI e. 411% et. I....4 — —1-- Lf) 4-1 C . 1 CD ow #1, C NJ W i CD 0 Lo . 0. s.. (I) c c 0 as LO co a CSI a 0 , o 1 o i .--- to 1 O.- N N ! 0 , wE 0 0 0 0 0 'rim 0 LO 0 In LO (uUllsn 009Z) (+)L-11-10N/(-)LilnoS . 6 �. nm _ MJ • N• N 0 N N O E N V O N M r • • • • • 0 •• • E . ., . ... . . 0) J �,,, 0 r •• ••• • • • o � 4 I , N ,� 4s �� �� �� �� `� Surface Location - '' / ' ]~ ri CP/�Coo'dinat:[on ^\ �� ��2���� From: ---'--- --- ---- -Tu --- -- Datum: (N4D83 ~ Region: |��`k Datum: �MAD27 ~ Region: [ oku ~ . __ ` . / . r Latitude/Longitude }DooimuD °~'~ 21 C Latitude/Longitude I-DecimoDegrees ~ ' /- UTM Zone: [ — 7- South <, UTM Zone: 'True - F- South [i. S�eP�ne Zone: 14 --�� Units: � /~ State Plane Zone: Units: |u'k �� . __ iris-Tr~~~ . __ . r LegalDescription t1; Legal Description Starting Coordinates: — ---- Legal Description X: 3162125432 Township: 6�T- IN _ Range |00 �-�/ ' ' / Y1 159297617.181 Meridian: Sechon|17 11.r - - -- ----'-1 - �FNL -| 30302882 |FEL ~| . _~ . 1 _ ___ ___ �_ I | Transform Quit 1 . ,1 Help, . I • Intermediate casing , r ne CP Coo-dinate Converter -- 1 = i Q l= From: —To: Datum: INAD83 ...7.1 Region: lalaska _II Datum: INAD27 .....j Region: lalaska ....d r Latitude/Longitude !Decimal Degrees .i.: (-- Latitude/Longitude !Decimal Degrees - C UTM Zone: I 1— South C UTM Zone: I True r South 6- State Plane Zone: 174--- , Units: lus.it ,1 C State Plane Zone: I 4 ,.I Units-. us.it r— i C !.,,,,lai De-cri;licln 110E127 only) ( Legal Description(NAD27 only) Starting Coordinates: Legal Description X: 11619297.51 Township: 1010ra .,.-a.. Range: r"-- loos li:3. Y: 15929913.69 Meridian: 17----7,1 Section:117 IFNL _II 12888.8533 fIEJ 13306.2359 Transform I , Quit Help I • 0 TD ......- ,- -v, -,..- :-,i.-L,:t----,,,.---[p;;;EI"P'r X in CPA:Coonclinate Converter:: -',--•0840111Er ,,'''.Y, From: To: i Datum: 1NAD83 zi Region: lalaska v• Datum: 1NAD27 zi Region: Jalaska zi r: Latitude/Longitude 1Decimal Degrees ,.. C Latitude/Longitude Decimal Degrees (- UTM Zone: 1--- r South C UTM Zone:'True r South State Plane Zone: —4 :- l.1 Units: r]Tft r Legal De-7CliOtiOn IN ts D 27 only) r State Plane Zone: -irmarue , Units: Jus-ft .... ,(4.` Legal Description(NAD27 only) Starting Coordinates: Legal Description - X: 11621224.60 Township: 1010 iii- - Range: 1073- ii---A- Y: 159-3-5-8-46'.20 ' Meridian. 16---D, Section:18 [ NL ----j 12228.8727 rFEETA 11375.9292 * Transform Quit I Help i ____ --------- ------------ ------ . As - built REV DATE BY CK APP • DESCRIPTION REV DATE BY APP DESCRIPTION 1 5/28/15 SZ JAH Created Drowing Per K140173ACS NOTES: ,a 16 x_15 oszA ''� ) s , f 26 6. t‘ • L link . \ i. BASIS OF LOCATION AND ELEVATION IS DS2S 21 ''� 2°cc w 3I •' ,, 23 It WS 20 `� , 9 MONUMENTATION PER LOUNSBURY & ASSOC. — -- ...„....4.31.......2, , �,, CPF2 1'2) 2 7111"/ 20 22 ;2 2s 3� „ 2c , 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, 2822 l Dsz�n _ {_y , ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES y . . DS2Hto ARE NAD 27. 's `, .32 3 �13 �,Si 12 3, )i--'-•-.4.3!: ,GG• 9'.`� t1 DS2G / T11N 4, 1 v w w PTr. T10N 3. ELEVATIONS ARE B.P.M.S.L. N/ { ; `$ 3 \2 g2 22 e , 4 1 4. ALL CONDUCTORS ARE LOCATED WITHIN PROTRACTED Q�� c2s2 icya �,. } ,. 2 Z. a M 11 .7 2 1 f ,o SECTION 17, TOWNSHIP 10 NORTH, RANGE 8 EAST, p , '" {. i 1 \1 UMIAT MERIDIAN. 1 j i;,/ ,, 'S2S c- �� ': ,a u S 7e •`: ,3 \•}-� ,}� 5. DATES OF SURVEY: 5-2 THRU 5-27-15 FIELD BOOKS / ` N sem, ' �s t' �' L15-28, L15-29, L15-32, L15-35 s ; -:4 sr 1 r kg rat 41 2 8 2 i•A 4")b t4 f, 12 1 41 ,- 22 6. ALL DISTANCES SHOWN ARE TRUE. f <LOpN > } ,i REV, DATE BY , CK , APP , • DESCRIPTION _REV DATE BY • APP DESCRIPTION 1 5/28/15 SZ JAH Created Drawing Per K140173ACS CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 17, T. 10 N., R. 8 E., UMIAT MERIDIAN W- ell NAD 27 NAD 27 Section Elev. No. ASP Coordinates Geographic Coordinates Offset. Y X Lat. Long. F.S.LI F.E.L. 0.0. PAD 1 5,930,036.15 481,309.02 70' 13' 12.058" 150° 09' 02.839" 2268' 1261' 112.0' 120.0' 2 5,930,029.92 481,279.68 70' 13' 11.996" 150' 09' 03.690" 2262' 1291' 112.4' 120.0' 3 5,930,023.62 481,250.32 70' 13' 11.933" 150' 09' 04.543" 2255' 1320' 112.1' 120.0' 4 5,930,017.59 481,221.00 70' 13' 11.873" 150' 09' 05.394" 2249' 1349' 112.0' 120.0' . .;.•20.0 - �, CPA:Coo-dinate f p � '' 20.0' From: -To: 20.0' Datum: NAD27 Region: lalaska Datum: NADS3 Region: lalaska 20.0' r- Latitude/Longitude 'Decimal Degrees j! r Latitude/Longitude 'Decimal Degrees20.0' 20.0' - ( UTM Zone:1 r South C" UTM Zone: [True r South 20.0' -4I i or State Plane Zone: 14 , Units: us-ft . ( State Plane Zone: 4 Units: us-ft . 20.0' -( 20.0' . C Legal Description(NAD27 only) C Legal Description(NAD27 only) i 20.0' Starting Coordinates: ; Ending Coordinates: j X: 1481221 X: 1 1 621 2514.31741763 Y: 15930017.59 Y: 1 5929767.1799003 Transform Quit I Help I , iogiookikaik%ii 4._ Ai C,.;• •.•�oe SURVEYOR'S CERTIFICATE '' 49th " %•' ♦# I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OE ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY r Q-/ DONE BY ME OR UNDER MY DIRECT SUPERVISION AND A 0 1 JEREMIAH F. CORNELL; o/ to J' LS-12663 0' ��� THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT ♦♦2.' •q. •., •'�e-! AS OF MAY 27, 2015. ®o4k o Q " essioNPA-44.7' Iraa®s.ae'' LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS • lirV AREA:2S MODULE: XXXX UNIT: D2 Conoc®Phiilips DS2S WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD FILE NO. DRAWING NO. PART: REV: LK6219d24 5/28/15 CEA-D2SX-6219D24 2 OF 2 1 • • 2S-04 Drilling Hazards Summary 13-1/2" Hole/ 10-3/4" Casing Interval Event Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Low If observed-control drill,reduce pump rates,reduce drilling fluid temperatures,Additions of Lecithin. Anti-collision Low Run Gyro as needed for magnetic interference. Gravel/Sand Sloughing Low Increase mud weight/viscosity,High viscosity sweeps. Monitor fill on connections. Hole Swabbing/Tight Hole on Moderate Circulate hole clean prior to trip. Proper hole fill(use of Trips trip sheets),Pumping out of hole as needed. Lost circulation Low Prevent by keeping hole clean. If losses occur-reduce pump rates and mud rheology,use LCM Unsuccessful cement job Moderate Use lower density cement slurry.Adjust the mud properties prior pump cement.Use proper pump rate. i Squeeze job or top job to remediate if needed. 9-7/8" Hole/7-5/8" Casing Interval Event Risk Level Mitigation Strategy Shale stability Moderate For the unstable HRZ and Kalubik shales with high inclination control with higher MW and proper tripping practices to avoid surging or swabbing. Minimize pressure cycling by stripping out using MPD to eliminate swab. High ECD and swabbing with Low Condition mud prior to trips. Monitor ECD's with PWD higher MW's required tool while drilling. Backream out on trips as a last resort. Strip out with MPD to eliminate swab. Lost circulation Moderate Use PWD and T&D to monitor hole cleaning. Reduced pump rates,adjust mud rheology,add LCM. Use GKA LC decision tree. Keep ECD below known frac gradient of--12.5 ppg in Tarn formations crossed in intermediate. Hole cleaning Low Use PWD and T&D to monitor hole cleaning.Control the ROP and use the best hole cleaning practice. Stuck pipe Low Good hole cleaning,stabilized BHA,proper mud weight, PWD to monitor ECD. 6-3/4" Hole/4-1/2" Liner Interval Event Risk Level Mitigation Strategy High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with PWD higher MW's required tool while drilling across pay interval. Backream out on trips as a last resort. Strip out with MPD to eliminate swab. Abnormal Reservoir Pressure Moderate Follow mud weight schedule and do not fall behind. Adjust mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Utilize MPD to contain any pressure and prevent allowing an influx in the event pressure is higher than expected. Lost Circulation Moderate Use PWD and T&D to monitor hole cleaning. Reduced pump rates,adjust mud rheology,add LCM. Use GKA LC decision tree. Use of MPD will allow lower mud weights to reduce ECD while shutting on connections to prevent any potential influx. • • Stuck pipe Moderate Good hole cleaning,stabilized BHA,proper mud weight to minimize differential stuck,PWD to monitor ECD. Hole swabbing on trips Moderate Monitor proper hole fill while tripping,good hole cleaning.Backream out to intermediate shoe,then utilize MPD to strip out and eliminate swab. 2S-04 CemCADE* Preliminary Job Design Schlumberger 10-3/4" Surface Casing (V1) Preliminary Job Design based on limited input data.For estimate purposes only. Volume Calculations and Cement Systems Rig: Doyon 141 Volumes are based on 250% excess in the permafrost and 50% excess below the Location: Kuparuk permafrost. The top of the tail slurry is designed to be at 2331' MD. Client: CPAI Revision Date: September 3, 2015 Prepared by: Jenna Houston Location: Anchorage, AK Lead Slurry Minimum pump time: -230 min. (pump time plus 120 min.) Phone: (907)263-4207 DeepCRETE @ 11 ppg- 1.91 ft3/sk Mobile: (907)223-8916 email:jhouston2@slb.com 1.339 ft3/ft x(110') x 1.00 (no excess) = 148 ft3 0.3637 ft3/ft x(1371 - 110') x 3.50 (250% excess) = 1606 ft3 < TOC at Surface 0.3637 ft3/ft x(2331 - 1371) x 1.50 (50% excess) = 524 ft3 148 ft3 + 1606 ft3+ 524 ft3= 2278 ft3 2278 ft3/ 1.91 ft3/sk = 1193 sks(-1203 sks) Please have extra DeepCRETE on location for top out. Tail Slurry Minimum pump time: -180 min. (pump time plus 120 min.) Previous csg. DeepCRETE @ 12 ppg - 1.63 ft3/sk < 20", 106.5#casing at 110'MD 0.3637 ft3/ft x(2831 -2331) x 1.50 (50% excess) = 273 ft3 0.5400 ft3/ft x 80' (Shoe Joint) = 44 ft3 273 ft3+44 ft3 = 317 ft3 317 ft3/ 1.63 ft3/sk = 195 sks Round up to 205 sks BHST= 61°F, Estimated BHCT =73°F. (Based on 2.1°F/100 ft. from surface) < Base of Permafrost at PUMP SCHEDULE 1371' MD(-1,360'TVD) Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) CW 100 7.00 75.0 10.7 10.7 MUDPUSH II 7.00 75.0 10.7 21.4 Pause 0.00 0.0 5.0 26.4 < Top of Tail at 11 ppg DeepCRETE 7.00 405.4 57.9 84.3 2,331' MD Surface Tail 7.00 56.3 8.0 92.3 DeepCRETE Slurry Pause 0.00 0.0 5.0 97.3 Fresh Water 7.00 10.0 1.4 98.7 Pause 0.00 0.0 5.0 103.7 Mud 8.00 244.6 30.6 134.3 Mud' 3.00 10.0 3.3 137.6 < 10-3/4",45.5#casing n 13.5"off MUD REMOVAL Expected Mud Properties: 9.5 ppg, Pv<20, Tv<20 TD at 2,831'MD Spacer Properties: 10.5 ppg MudPUSH* II, Pv 17-21, Tv 20-25 (2,569'TVD) Centralizers: As per CPAi program. *Mark of Schlumberger • i 2S-04 Schlumberger CemCADE* Preliminary Job Design 7-5/8" Intermediate Casing Rig: Doyon 141 1st Stage (V1) Location: Kuparuk Client CPAI Revision Date: September 3, 2015 Volume Calculations and Cement Systems Prepared by: Jenna Houston Volumes are based on 30% excess. The topof the 1st stage tail slurryis designed to be Location: Anchorage, AK g g Phone: (907)263-4207 at-6,400' MD. Mobile: (907)223-8916 email:jhouston2@slb.com Tail Slurry Minimum pump time: -220 min. (pump time plus 120 min.) 15.8 ppg GASBLOK * + adds - 1.17 ft3/sk 0.2148 ft3/ft x(7964'-6400') x 1.30 (30% excess) = 437 ft3 0.2578 ft3/ft x 80' (Shoe Joint) = 21 ft3 437 ft3+ 21 ft3 = 458 ft3 458 ft3/ 1.17 ft3/sk = 392 sks Round up to 402 sks Previous Csg. < 10-3/4",45.5.#casing BHST = 152°F, Estimated BHCT = 108°F. at 2,831'MD (BHST calculated using a gradient of-2.1°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) MUDPUSH II 5.00 40.0 8.0 8.0 Pause 0.00 0.0 5.0 13.0 15.8 ppg GASBLOK` 5.00 81.4 16.3 29.3 < Stage tool at 5,700'MD Slurry Pause 0.00 0.0 5.0 34.3 Fresh Water 5.00 10.0 2.0 36.3 Pause 0.00 0.0 5.0 41.3 Mud 5.00 342.0 68.4 109.7 Mud 3.00 10.0 3.3 113.0 < Top of Cement at MUD REMOVAL -6,400 MD Expected Mud Properties: -10.5 ppg, Pv< 20, Yield Point< 25. Spacer Properties: 12.0 ppg MudPUSH* II, Pv=20 -24, Yield Point= 20-30 < 7-5/8",29.7#casing Centralizers: As per program in 9-7/8"OH TD at-7,964 MD (6,293'TVD) *Mark of Schlumberger • • 2S-04 Schlumberger CemCADE* Preliminary Job Design 7-5/8" Intermediate Casing Rig: Doyon 141 2nd Stage (V1) Location: Kuparuk Client: CPAI Revision Date: September 3, 2015 Volume Calculations and Cement Systems Prepared by: Jenna Houston Volumes are based on 30% excess. The topof the 2nd stage tail slurryis designed to be Location: Anchorage, AK g g Phone: (907)263-4207 at-5,083 MD, 500' above the C37. Mobile: (907)223-8916 email:jhouston2@slb.com Tail Slurry Minimum pump time: -200 min. (pump time plus 120 min.) 15.8 ppg Class G +GASBLOK* + adds- 1.17 ft3/sk 0.2148 ft3/ft x(5700'-5083') x 1.30 (30% excess) = 173 ft3 173 ft3= 173 ft3 173 ft3/1.17 ft3/sk = 148 sks Previous Csg. Round up to 158 sks < 10-3/4",45.5.#casing at 2,831'MD BHST= 117°F, Estimated BHCT= 83°F. (BHST calculated using a gradient of-2.1°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) MUDPUSH II 5.00 40.0 8.0 8.0 15.8 ppg GASBLOK* 5.00 30.7 6.1 14.1 Slurry Pause 0.00 0.0 5.0 19.1 Fresh Water 5.00 10.0 2.0 21.1 Pause 0.00 0.0 5.0 26.1 Mud 5.00 241.7 48.3 74.4 Mud 3.001 10.0 3.3 77.7 < Top of Cement at MUD REMOVAL -5,083 MD Expected Mud Properties: -10.5 ppg, Pv<20, Yield Point < 25. Spacer Properties: 12.0 ppg MudPUSH* II, Pv= 20 -24, Yield Point = 20-30 Centralizers: As per program < 7-5/8",29.7#casing in 9-7/8"OH Stage tool at-5,700' MD (4,859'TVD) *Mark of Schlumberger • • Request for Waiver of AOGCC Regulation 20 AAC 25.412(b) ConocoPhillips requests approval of our proposed plan to topset the Kuparuk sands per the following Alaska Administrative Codes. 20 AAC 25.030(c)(5)"production casing must be set and cemented through,into,or just above the production interval" 20 AAC 25.030(d)(5)"intermediate and production casing must be cemented with sufficient cement to fill the annular space from the casing shoe to a minimum of 500 feet above all significant hydrocarbon zones and abnormally geo-pressured strata or,if zonal coverage is not required under(a)of this section,from the casing shoe to a minimum of 500 feet above the casing shoe;if indications of improper cementing exist,such as lost returns,or if the formation integrity test shows an inadequate cement job,remedial action must be taken" Due to the elevated reservoir pressure(-11.4 ppg)of the Kuparuk'A' Sands and the low fracture gradient (11.8 ppg)observed in shallow sand stringers in offset wells,landing intermediate casing in the Kuparuk Sands is not feasible. We propose to topset the overpressured Kuparuk'A' sands by landing—35'TVD above them, setting our 7-5/8"intermediate casing in the Lower Kalubik shale,and cementing from the shoe to the top of the Cairn formation. A cement stage tool in the 7-5/8"casing will also provide an additional 500' of cement above the C-37(Tarn area)interval with a second cement stage. This plan is similar to our recent wells on 2S pad that adjusted to a topset design on the fly after encountering losses in the intermediate section(2S-02,2S- 07,and 2S-10). Please refer to the attached schematic for a diagram of the planned design. To confirm the presence of cement behind the intermediate casing,a recorded mode sonic log to confirm top of cement and integrity,as well as a leak-off test below the intermediate casing shoe,will be performed. Additionally,the heel of the 4-1/2"production liner will be blank pipe,with a swell packer run on the blank pipe to isolate the 7-5/8"casing shoe from the slotted liner. Due to this top set design,ConocoPhillips requests a waiver to the AOGCC regulation(20 AAC 25.412(b)) stating that injection packers must be within 200 feet of the upper most perforations on injection wells.Packer placement is planned to be—410' MD/72' TVD above the slotted liner/top of Kuparuk A-sand. • • Bettis, Patricia K (DOA) From: Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent: Tuesday, September 08, 2015 11:51 AM To: Bettis, Patricia K (DOA) Subject: RE: KRU 2S-04: Permit to Drill Application (PTD 215459) Patricia, we are planning to pre-produce 2S-04 for approximately 6 months because of the following reasons: (1) it improves project economics by accelerating its production profile, and (2) it improves drillability on upcoming offset wells by drawing down expected pressures. We have modeled cases where injectors are pre-produced for 3 months and several other cases (see graph below). It shows how^2.5% HCPV Withdrawn (which occurs at^'6months) is in the sweet spot of pre-production based on the early volumes. Anything beyond this point reduces reservoir pressure and could impair economics significantly. 1 i • Impaired Initial Prod Impaired EUR Less initial volume Reduced reservoir pressure pre-produced before producers bought online s 4 4.01- S l• .WelitZ,f CL Z :,,< y 4110 55.4 s r 0 1 2 3 4 5 6 HCPV Withdrawn Before Start of Injection 0.0 0.6 0.9 1.1 1.6 2.2 2.7 . Avg Injector GOR at End of Pre-Prod Period, mscf/stb Please let me know if this answers your question or if you would like any further information. Thanks, Mike From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Tuesday, September 08, 2015 11:02 AM To: Callahan, Mike S Subject: [EXTERNAL]KRU 2S-04: Permit to Drill Application (PTD 215-159) Good morning Mike, 2 • • How long does ConocoPhillips anticipate to pre-produce the KRU 2S-04? If the duration of pre-production is more than 3 months, please provide a justification. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 3 • • 1. Move in/rig up Doyon Rig 141. Install 21-1/4"Annular with 16"diverter line and function test. 2. Spud and directionally drill 13.5"hole to casing point at+/-2,831 MD/2,569'TVD as per directional plan (wp10). Survey with MWD,Gamma,Resistivity,Gyro. / 3. Run and cement 10-3/4",45.5#,L80,Hyd-563 casing to surface. Displace cement with mud. Evacuate top 2 feet of cement from annulus for sealant job(post rig.) 4. In the event cement returns are not seen at surface,perform a top job. 5. Remove diverter system,install and test 13-5/8"x 5,000 psi BOP's to 3500 psi(annular preventer to 2500 psi) high and 250 psi low. Notify AOGCC 24 hrs before test. 6. PU 9-7/8"PDC bit and directional drilling assembly,with MWD/LWD(Gamma,resistivity). RIH and clean out to 100'above shoe. Test surface casing to 3500 psi for 30 minutes. 7. Drill out shoe track and 20'of new hole. Perform leak off test to a minimum of 12.5 ppg,maximum of 16 ppg EMW leak off,recording results. 8. Directionally drill to the top of the HRZ at 7,254'MD/6,032'TVD. Begin applying back pressure on connections with MPD for shale stability at this time. 9. Directionally drill to intermediate TD of 7,964'MD/6,293'TVD,landing approximately 50'TVD below the K- 1 marker in the lower Kalubik Shale. Wellsite geologist will call intermediate TD. Circulate and rotate at maximum rates until shakers are clean,minimum of 3 bottoms up. 10. POOH on elevators. Closely monitor drag and address any problem areas by dropping below and circulating/rotating to clean up. Backream through tights spots only if necessary. If substantial drag was observed through a large part of the trip,consider making a wiper trip back to bottom from the surface casing shoe,otherwise continue pulling out of hole. 11. Laydown intermediate BHA and rack back 5"DP(to lay down after casing run,this will minimize shale exposure time.) 12. Run 7-5/8",29.7#L80,Hydril 563 casing from surface to TD at 7,9514. .R SE 13. Pump two stage cement job as per Schlumberger proposal. Top of first stage to be 6,400' MD(30'MD above top of Cairn formation),top of second stage to be 5,083'MD(500'above C37}.-'� 14. Flush 10-3/4"x 7-5/8"annulus with water,followed by diesel to freeze protect. 15. Lay down 5"DP. 16. PU 4"DP,6-1/2"bit,and drilling assembly with MWD/LWD(Gamma,resistivity,Periscope,Microscope,and neutron density) k 17. RIH and clean out cement to 100' above shoe. Test intermediate casing to 3500 psi for 30 minutes. 18. Drill out shoe track and 20'of new hole. Perform formation integrity test to minimum of 12.5 ppg,maximum of 16 ppg EMW leak off,recording results. 19. Directionally drill 6-3/4"hole,geosteering through the Kuparuk A4 sand to TD 14,207' MD as per directional plan(wpl0). 20. Circulate hole clean and POOH. 21. Lay down Production BHA. 22. PU and run 4-1/2", 11.6#slotted liner. The top of liner will be placed at 7,814' MD,allowing for 150'of overlap in the 7-5/8"casing. i • NOTE: This will put the liner—410'MD,72'TVD above the top of the A4 reservoir,greater than the 200'MD required. ConocoPhillips requests a waiver to use this well for injection with the packer at this depth. 23. Set liner hanger. Slackoff and set liner top packer. 24. Monitor well for flow for 15 minutes 25. Displace to clear brine. PT liner to 3,000 psi at surface for 30 minutes,curt results. 26. Flow check well for 30 minutes to run 3-1/2"upper completion. 27. Nipple down BOPE,nipple up tree and test. 28. Freeze protect well with diesel and install BPV. 29. RDMO. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill music be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement ofwhether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well (1R-18 or new facilities at DS1B). All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well,or stored,tested for hazardous substances,and(if free of hazardous substances)used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: "5EO ,D Attachment 1 Well Schematic Attachment 2 Diverter Layout Diagram Attachment 3 Directional Plan Attachment 4 Drilling Hazards Summary Attachment 5 Cement Summaries Attachment 6 Request for Waiver of Packer Setting Depth SUPERSEDE • • Bettis, Patricia K (DOA) From: Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent: Tuesday, September 08, 2015 11:51 AM To: Bettis, Patricia K (DOA) Subject: RE: KRU 2S-04: Permit to Drill Application (PTD 215-159) Patricia, we are planning to pre-produce 2S-04 for approximately 6 months because of the following reasons: (1) it improves project economics by accelerating its production profile, and (2) it improves drillability on upcoming offset wells by drawing down expected pressures. We have modeled cases where injectors are pre-produced for 3 months and several other cases (see graph below). It shows how' 2.5% HCPV Withdrawn (which occurs at"6months) is in the sweet spot of pre-production based on the early volumes. Anything beyond this point reduces reservoir pressure and could impair economics significantly. 1 • • Impaired initial Prod impaired EUR Less initial volume Reduced reservoir pressure pre-produced before producers bought,;online S' i i41 f .. G 2 o F 0 1 2 3 4 5 6 HCPV Withdrawn Before Start of Injection 0.0 0.6 0.9 1.1 1.6 2.2 2.7 Avg Injector GOR at End of Pre-Prod Period, mscf/stb Please let me know if this answers your question or if you would like any further information. Thanks, Mike From: Bettis, Patricia K (DOA) [mailto:patricia.bettis©alaska.gov] Sent: Tuesday, September 08, 2015 11:02 AM To: Callahan, Mike S Subject: [EXTERNAL]KRU 2S-04: Permit to Drill Application (PTD 215-159) Good morning Mike, 2 . • How long does ConocoPhillips anticipate to pre-produce the KRU 2S-04? If the duration of pre-production is more than 3 months, please provide a justification. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 3 • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Tuesday, September 08, 2015 11:02 AM To: Callahan, Mike S (Mike.Callahan@conocophillips.com) Subject: KRU 2S-04: Permit to Drill Application (PTD 215-159) Good morning Mike, How long does ConocoPhillips anticipate to pre-produce the KRU 2S-04? If the duration of pre-production is more than 3 months, please provide a justification. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • • TRANSMITTAL LETTER CHECKLIST WELL NAME: i<R(.. S-oy PTD: c?J•5- Sj. Development /Service Exploratory _Stratigraphic Test _Non-Conventional FIELD: X P t/LiI' POOL: ?4lJ -, ku ) 11/4,4"-- Check V4rCheck Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements v Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 0 • III 0 0) p • N a w, fl_.' 0 n o. ` a so c6 oSC. O)' C N ' � , C C .= 7. Q CO �, m, a �, L 4 m, m 2 co c rn , � C cn E O ay o n r>; 04 ° , o, 5 a o' U rn 3 a°i, � N N �. c -0 • 3, c. a ', .5> Cl) c v, c� ,o .n °� o. a V f"c\iI ZA p. O. U N, E CO. •3p 0. E co, �, C, a C O. 2 a), D E, f=1, - N c �, y. m c. a a, �, ami > coi, Q. o' •0, o a, 0 E o hi w m, 3, N. 2 Y o. ~ a y m, , o, , as a), CO E N. � , N. ' a> CC « , a N a)' .L.,. , �, �, 00 U a, M� 0, 0, N. cn. 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N 0' cC, , Nc 1c, � - `� c � o yNU 0rof U ' _ cac 1a 0 D a � 0C 1 , O N. C a. m, a), a �, O. C. N• m, O• O rn m' a, L. C• C �. C O E' a>. N, E ' Na c gc D 1 ME . E v cC , m m, o , C' c N H c O , .5 , Oc N' C N L L-, cr Qm. o o v ° c> m, 0 ° ai c, ' s a) . o ) 0 � 3 om ° T d !/> O � � , ' Cv , 2 N , 000, a E ( ' aCl-, IT' . , > D0 mC To V � oc O770 ' ; Y ' O0a> -an., @, m. Q. , . N TO. ° p. . D 5 Ea ° m 1 ..* p. p 0 Omm, f — " . E 3 a) o u m 3 . E ° c n _ 3 m Q cOa N. - co �� '3; � m E, tiC0yoM 0 _N N ° Ow ° C >> jOE .co 0' : 2 d a .. ,- . -pmNar () @ - ov a y � 0om' ma> o CO oa0, 0 ° c ,, N, m vNmO3, 'O3. >. < . t . o m N m a - Tm v o Nz' a U O c . , V, > a . E p. O � OOC -pEO Eo d. , ,C ) . ,_ m00C' NN w O N 4- C J oa) 1 -p aaN -2 7 7 a C . °' O � N — � a) r' � vm E � U - 'Jyc ° O = NLUCu OO �a 0N' +� 64 •y N a _= d� CTO• 6 .6C6OO) 0OaOS N "° ° � C > N = c N ' o a 'O ` of O 7• ` N 0 co a7p N ° -pN . LLdWm m Ca a Naya . C, a) . 7t5 8. yC -, mo , O "5y O a> Y, > N 0 .. m _o 'O 'O v Uco - aa •o '_ N ) N > .y: _. 7, co 8 U -0 8' 6 CE A() Uy, 0Ea0 :? • • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Technical Report Title Date Client: ConocoPhillips Alaska, Inc Field: Kuparuk River Unit Rig: Doyon 141 Date: November 4, 2015 Surface Data Logging End of Well Report 2S-04 2S-04 PB1 TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Days vs. Depth 4. After Action Review 5. Mud Record 6. Bit Record 7. Morning Reports 8. Survey Report Digital Data to include: Final Log Files Final End of Well Report Final LAS Exports Halliburton Log Viewer EMF Log Viewer GENERAL WELL INFORMATION Company: ConocoPhillips Alaska Inc. Rig: Doyon 141 Well: 2S-04 & 2S-04 PB1 Field: Kuparuk River Unit Borough: North Slope Borough State: Alaska Country: United States API Number: 50-103-20721-00-00 (2S-04) 50-103-20721-70-00 (2S-04 PB1) Sperry Job Number: AK-AM-0902772867 Job Start Date: 22 September 2015 Spud Date: 18 September 2015 Total Depth: 13505’ MD, 6238’ TVD (2S-04) 7800’ MD, 6240’ TVD (2S-04 PB1) North Reference: True Declination: 18.562° Dip Angle: 80.866° Total Field Strength: 57488.108 nT Date Of Magnetic Data: 30 September 2015 Wellhead Coordinates N: North 70° 13’ 10.75264” Wellhead Coordinates W: West 150° 9’ 16.54313” Drill Floor Elevation 147.50’ Ground Elevation: 120.00’ Permanent Datum: Mean Sea Level SDL Engineers: Kyle Wiseman, Hilary Garney, Eric Andrews, Michael LaDouceur, Tyler Dretke Company Geologist: Zack Beekman, Matthew Smith, Company Representatives: Andy Lundale, Bob Finkbiner, Robert Wall, Dave Coates SSDS Unit Number: 125 DAILY SUMMARY 09/22/2015 SDL crew rigged up unit, calibrated gas equipment, and setup computers. Begin to run into the hole while MPD rigged up and tested their equipment. 09/23/2015 Continued trouble shooting Managed pressure drilling equipment and decision was made to pull managed pressure drilling bearing and install trip nipple. Pressure tested the casing to 3500 pounds per square inch for 30 minutes. Drilled to 2845' MD and circulated bottoms up and monitored the well until it was static. Performed formation integrity test to 14.95 equivalent mud weight. Rigged down test equipment then began to displace the well to 9.6 pounds per gallon LSND then proceeded to drill ahead from 2845' MD to 3672' MD. Gas The max gas was 1311 units and average background gas was 32 units. Fluids: 0 barrels of water-based mud lost downhole. Geology: The samples have been predominately gray, silty, soft, amorphous, slightly hydrophyllic claystone. 09/24/2015 Drilled ahead from 3672' MD to 5537' MD then circulated bottoms up and monitored the well for 15 minutes. Removed the trip nipple and installed RCD bearing per Managed pressure drilling representative then continued to drill ahead to 5793' MD. Gas: The max gas was 911 units and average background gas was 54 units. Fluids: 0 bb barrels of water-based mud lost downhole. Geology: The samples have been predominately Claystone that is very light to medium gray, slightly silty, gummy and soft. 09/25/2015 Continued to drill ahead in intermediate then stopped to monitor the well for 30 minutes, which was static while RCD bearing was changed out. Continued to drill ahead, changed out pressure sensor per Managed pressure drilling rep. Gas: The max gas was 10008 units and the average background gas was 285 units. Fluids: 27 barrels of water based mud was lost downhole. Geology: The samples have been predominantly Shale that is very light to medium gray, very soft, platy to flakey, some laminating, and slightly silty and calcareous in places. 09/26/2015 Drilled ahead from 7604’ MD to 7800’ MD, TD intermediate hole section. Circulated 3 bottoms up and monitored the well. Began to pull out of the hole where a tight spot was encountered and packed off at 7750’ MD. Worked the pipe until it was freed and rotation was established. Circulated bottoms up and conditioned the mud before monitoring the well per company man. Gas: The max gas was 5833 units and average background gas was 817 units. Fluids: 31 barrels of water-based mud lost downhole. 09/27/2015 Monitored well with 0.5 barrels gain then bagan to weight up to 11.1pounds per gallon where 9989 units of gas was observed on bottoms up. Circulated and conditioned the mud to 11.1 pounds per gallon, then monitored the well from the cellar with a 0.39bbl gain. Continued to monitor the well for flow then circulated bottoms up to circulate out any remaining high gas. Changed out the Managed pressure drilling bearing then continued to circulate while weighting up to 11.4 pounds per gallon. Gas: The max gas was 9989 units and average background gas was 709 units. Fluids: 33 barrels of water-based mud lost downhole. 09/28/2015 Weighted up the mud system from 11.1 pounds per gallon to 11.4 pounds per gallon, and then monitored the well for flow. Circulated out gas cut mud and circulated bottoms up. Begin running in hole washing and reaming from 7444' MD to 7765' MD. Hole packed off which resulted in loss of circulation. Worked the pipe free then began to back ream out of hole from 7765' MD to 7170' MD. Circulate bottoms up and monitored the well. Gas: The max gas was 9911 units and the average background gas was 1198 units. Fluids: 57 barrels of water-based mud lost downhole. 09/29/2015 Back reamed out of hole to 6918' MD until circulation was lost. Decision was made to pump 52 barrels down the backside with no returns. Pumped 30 barrel lost circulation material pill down the backside at 2 barrels per hour with no returns. Removed RCD bearing and installed trip nipple. Filled the hole with charge pump, then pumped a 35 barrel sweep with no returns. Pumped at 2 barrels per hour and pumped a 35 barrel Strata lost circulation material sweep which was spotted at 5600' MD. Began to monitor losses as per Company Man. Gas: The max gas was 547 units and the average background gas was 40 units. Fluids: 1039 barrels of water-based mud lost downhole. 09/30/2015 SDL crew performed a weekly safety meeting about hands, how important they are in everyday life, what type of gloves should be worn depending on the activity being performed and to be very careful about hand placement. Pumped 30 barrel lost circulation material pill then monitored the well and was static. Pumps came on and the rig continued to see loses so the pumps were shut off and the well was monitored and was static. Pumped another 30 barrel strata lost circulation material pill then began to back ream out of the hole from 6784' MD to 5540' MD. Pumped 30 barrel strata lost circulation material pill and monitored the well and lost 1.8 barrels in 30 minutess. Continued to pump out of the hole and encountered tight spots at 5363' MD and 4943' MD, which were worked through until the pipe was free. Gas: The max gas was 25 units and the average background gas was 10 units. Fluids: 1328 barrels of water-based mud lost downhole. 10/01/2015 Continued to pump out of the hole to 2758' MD then brok e circulation with no returns from which the well was monitored for 30 minutes and it was static. Continued to pump out of the hole to 939' MD when an increase in flow was noticed with max gas of 4029 units observed, from which the well was shut in. The super choke was opened 25% of the way with no returns but a gain rate of 28 barrels per hour was observed. After waiting for additional mud trucks from Deadhorse, the rig began to bullhead to 6600' MD starting with a high viscosity pill and chasing it with LSND. Gas: The max gas was 4029 units and the average background gas was 411 units. Fluids: 1117 barrels of water-based mud lost downhole. 10/02/2015 Bullheaded well with 10.5 pounds per gallon mud to 6600' MD then monitored the well and observed a gain 30.2bbls in 30 minutes. Decision was made to weight up mud to 11.5 pounds per gallon. While waiting on mud, performed rig maintenance. Weighted up mud with 11.5 pound per gallon spike fluid then proceeded to kill the well with 10 barrel 11.5 pound per gallon mud down the drill pipe, 25 barrel high viscosity spacer pill followed by 11.5 pound per gallon LSND mud. The well was then monitored with 10-20 barrel per hour loss rate. Decision was made to proceed to pull out of the hole and lay down bottom hole assembly per Schlumberger representative. SDL calibrated gas equipment for next section. Gas: The max gas was 61 units and the average background gas was 9 units. Fluids: 1230 barrels of water-based mud lost downhole. 10/03/2015 Finished laying down the bottom hole assembly. Began running into the hole with 3.5" tubing to 1100' MD followed by one stand of drill pipe. Blow down choke lines then continued to run into the hole with tubing to 2734' MD. Removed the trip nipple and installed the RCD bearing then circulated bottoms up but with no returns. The rig began to monitor the hole while repairs for the Elmagco break took place. Gas: The max gas was 335 units and the average background gas was 152 units. Fluids: 74 barrels of water-based mud lost downhole. 10/04/2015 Finished repairs on the Elmagco break. The well was bull headed with 200 barrels due to gas migration up the hole. The well was then monitored for losses. Continued to run into the hole to 7747' MD when the hole packed off, from which the decision was made topull out of the hole to 7682' MD where the first abandonment plug was pumped per Schlumberger cementers. An attempt was made to pull out of the hole with no success. Gas: The max gas was 468 units and the average background gas was 61 units. Fluids: 579 barrels of water-based mud lost downhole. 10/05/2015 Finished waiting on cement and continued to try and work tubing free, which was unsuccessful. Decision was made to call in wireline. Gas: The max gas was 10 units and the average background gas was 3 units. Fluids: 75 barrels of water-based mud lost downhole. 10/06/2015 Pulled out of the hole with the string shot tools and made up and proceeded to run into the hole with a cutting torch. Had to troubleshoot cutter after there was no communication with the tool and attempted to pull out of the hole but couldn’t and lost the tool. Made up and ran into the hole with a fishing tool to 5835' MD. Then pulled out of the hole and laid down the fishing tool, but no fish. Made up and ran into the hole with cutting torch, cut the drill pipe at 5775' MD and pulled out of the hole. Rigged down Wireline and attempted to work pipe free, but it was still stuck. Made up severing tool and fired a charge into the hole then began to circulate. Gas: The max gas was 3209 units and the average background gas was 27 units. Fluids: 66 barrels of water-based mud lost downhole. 10/07/2015 Began circulating and observed gas steadily rising from which the decision was made to bull head the well. Continued to Pump out of the hole to the inside of the surface casing and monitored the well for flow and it was static. Continued to pump out of the hole to the surface then rigged up and began BOP testing. Gas: The max gas was 4265 units and the average background gas was 627 units. Fluids: 455 barrels of water-based mud lost downhole. 10/08/2015 Finished testing the blowout preventers, rigged down testing equipment and began to run into the hole with cement stinger on 3.5" tubing and singled into the hole with 5" drill pipe to 5662' MD. Bullheaded the well with 425 barrels then monitored the well, which was static. Proceeded to pump abandonment plug per Schlumberger cementers. Gas: The max gas was 6250 units and the average background gas was 553 units. Fluids: 697 barrels of water-based mud lost downhole. 10/09/2015 Rigged down cement equipment and loaded the nerf ball and pumped it down the drillstring with no returns. Began to pull out of the hole to 4647' MD then monitored the well. Continued to pull out of the hole to 2794' MD then cleared and cleaned the rig floor while monitoring well on TT while waiting on cement. Slip and cut the drill line and performed rig maintenance while waiting. Ran into the hole to 4845' MD and washed down to 4937' MD with the top of cement at 5036' MD. Pulled out of the hole to 5026' MD then rigged up cementers and pumped balance plug. Rigged down the cementers and pulled out of the hole to 4378' MD. Dropped wiper ball and circulated bottoms up two times with no losses. Gas: The max gas was 1640 units and the average background gas was 273 units. Fluids: 244 barrels of water-based mud lost downhole. 10/10/2015 Continued to circulate bottoms up twice with no losses, then proceeded to monitor the well, which was static. Began to pull out of the hole from 4378' MD to 2700' MD and waited on cement while monitoring the well on the trip tank. Ran into the hole from 2700' MD to tag the top of cement at 4877' MD then pulled out of the hole to 4845' MD and monitored the well, with fluid over flowing out of pipe so the decision was made to circulate bottoms up. Monitored the well again and was static. Continued to pull out of the hole from 4845' MD to 2790' MD where testing equipment was rigged up and a formation integrity test was performed to 12.5 pounds per gallon. Rigged down test equipment then continued to pull out of the hole from 2790' MD to surface. Laid down ECP running tool, cleaned and cleared the rig floor then made up ECP #2 and began to run into the hole, filling pipe every five stands. Gas: The max gas was 383 units and the average background gas was 65 units. Fluids: 0 barrels of water-based mud lost downhole. 10/11/2015 Ran into the hole from 3076' MD to 3300' MD and broke circulation to clean drill string. Dropped dart and pressured up to 500 pounds per square inch and held for 1 min, increasing at 200 pounds per square inch increments, holding for 1 min to 1500 pounds per square inch, bled pressure down then back up to 1500 pounds per square inch with no indication ECP has inflated. Decision was made to shear off ECP and proceed to pump cement. Circulated bottoms up at 6 barrels per minute then performed cement job. Pulled out of the hole from 3226' MD to 2387' MD left cement string in hole, while laying down drillpipe while waiting on cement. Laid down 28 stands of 5" drill pipe from the derrick and monitored the well on the trip tank. Ran into the hole from 2387' MD to 3507' MD at 2 barrels per minute then began to circulate bottoms up at 4 barrels per minute. Gas: The max gas was 161 units and the average background gas was 19 units. Fluids: 0 barrels of water-based mud lost downhole. 10/12/2015 Circulated mud at 4 barrels per minute slowing to 1.5 barrels per minute then proceeded to pump 23.6 barrel Hi-Vis Gel pill then circulated bottoms up at 6 barrels per minute. Rigged up cementers and pumped 68.5 barrels of cement. Pulled out of the hole from 3226' MD to 2480' MD, dropped wiper ball and circulated bottoms up then monitored the well which was static. Continued to pull out of the hole from 2480' MD to surface and laid down 33 joints of 3.5" tubing. Then rigged up and performed blowout preventer test. Made up bottom hole assembly #3. SDL crew calibrated and tested gas equipment for redrill. Gas: The max gas was 282 units and the average background gas was 23 units. Fluids: 0 barrels of water-based mud lost downhole. 10/13/2015 Finished picking up bottom hole assembly number 3 and began to run into the hole to 1661' MD to shallow hole test tools. Continued to run into the hole to 2642' MD and began to wash down to tag up the top of cement at 2642' MD then drilled out cement plug to the kick off point of 2952' MD. Circulated and conditioned the mud. Pulled the trip nipple and installed RCD bearing. Dropped ball and opened reamer. Drilled ahead to 2970' MD, circulated and conditioned the mud, changed out RCD bearing then continued to drill ahead. Gas: The max gas was 252 units and the average background gas was 54 units. Fluids: 0 barrels of water-based mud lost downhole. 10/14/2015 Continued to drill ahead to 4747' MD when during a connection pressure was observed on the management pressure drilling choke at 97 pounds per square inch, decision was made to circulate bottoms up, with a max gas of 3322 units observed. Continued to drill ahead until the clamp on RCD mounting tool needed to be tightened then continued to drill ahead. Gas: The max gas was 3322 units and the average background gas was 58 units. Fluids: 50 barrels of water-based mud lost downhole. 10/15/2015 Continued to drill ahead to 5956' MD, stopped to circulate bottoms up and change out RCD bearing, then continue to drill ahead. Gas: The max gas was 728 units and the average background gas was 150 units. Fluids: 120 barrels of water-based mud lost downhole. 10/16/2015 Drilled 9.875" intermediate section from 6,720' MD to 7,269'. Shot MWD Survey and changed out the RCD bearing. Drilled ahead to 7,896' MD. (6,223' TVD). Break connection, drop ball to close Rhino reamer, pressure confirmed closed. Shut in MPD, holding 60 psi on choke. Pressure built up from to 71 PSI. Decision was made to circulate bottoms up and SPR at 7,895" MD (6,187' TVD). Strip out of hole from 7,896' MD to 7,338' MD. Circulate bottoms up at 700 gpm. Gas: The max gas was 2063 units and the average background gas was 368 units. Fluids: 115 barrels of water-based mud lost downhole. 10/17/2015 After circulating two bottoms up at 7,338’ MD, mud system weighted up to 10.6 pounds per gallon from 10.3 pounds per gallon. Continue to trip out of the hole from 7,338’ MD to surface. Lay down bottom hole assembly. Begin to run 7 5/8” casing to 1296’ MD. Gas: The max gas was 1221 units and the average background gas was 40 units. Fluids: 0 barrels of water-based mud lost downhole. 10/18/2015 Ran 7 5/8" Casing downhole from 1296' MD and landed it at 7890' MD. Mud losses were experienced beginning at 2896' MD. Losses continued till casing was landed and experienced a loss of 215 bbls total during the trip. Max trip gas was 203 units. While prepping and circulating for cement job, 308 bbls more were lost downhole. When Stage one of the cement job was completed 370 bbls more were lost down hole. Stage 2 resulted in a loss of 335 bbls more. Minimal returns were received back during stage one and two of the cement job. Throughout the cement job gas remained consistent with an average of 158 units and a max of 370 units. Gas: The max gas was 370 units while circulating and an average of 66 units. Fluids: 1228 barrels of water-based mud were lost downhole. 10/19/2015 Wait on cement to cure. Lay down 5” drill pipe. Gas: The max gas was 0 units while circulating and an average of 0 units. Fluids: 0 barrels of water-based mud were lost downhole. 10/20/2015 Pick up 4” drill pipe. Test managed pressure drilling equipment. Test blow out prevention equipment. Gas: The max gas was 0 units while circulating and an average of 0 units. Fluids: 0 barrels of water-based mud were lost downhole. 10/21/2015 Complete test of blow out prevention equipment. Pick up bottom hole assembly. Begin tripping into the hole. Begin measure after drilling pass from 5000’ MD to 5800’ MD. Drill out stage collar and cement at 5800’ MD. Continue to measure after drilling pass to 6000’ MD. Gas: The max gas was 0 units while circulating and an average of 0 units. Fluids: 0 barrels of water-based mud were lost downhole. 10/22/2015 Complete to measure after drilling pass from 6000’ MD to 7737’ MD (top of cement). Drill cement to 7896’ MD. Clean out hole. Gas: The max gas was 0 units while circulating and an average of 0 units. Fluids: 0 barrels of water-based mud were lost downhole. 10/23/2015 Drill from 7896' MD to 7916' MD. Perform Formation integrity test to 14.5 pounds per gallon. Displace mud from water based mud to FloThru drilling mud. Drill from 7916' MD to 8615' MD. Max gas was seen at 8150' MD and 8481' MD where the equipment maxed out at 9906 units. No Pit Volume gains were seen during these events. Gas: The max gas was 9906 units while circulating and an average of 2612 units. Fluids: 0 barrels of FloThru mud were lost downhole. 10/24/2015 Drill from 8615' MD to 10270' MD. Gas equipment was maxed out (9917 units) for majority of the day. Increased Mud weight to 10.7 pounds per gallon at 9230' MD to try and reduce gas levels. After mud weight increased, gas level diminished as expected. No gains were seen during gas events. Gas: The max gas was 9917 units while circulating and an average of 6780 units. Fluids: 0 barrels of FloThru mud were lost downhole. 10/25/2015 Drill from 10270' MD to 11840' MD. Gas equipment was maxed out for majority of the day. Losses of 27 bbls were seen between 10660' MD to 11000' MD. 1 bbl loss was seen between 11000' MD and 11840' MD. Gas: The max gas was 9904 units while circulating and an average of 6127 units. Fluids: 28 barrels of FloThru mud were lost downhole. 10/26/2015 Drill from 11840' MD to 12358' MD, Changed out RCD bearing, continued Drilling from 12358' MD to 13208' MD while experiencing an average of 5187 units throughout the day. Gas: The max gas was 9800 units while drilling at 12350’, with an average of of 5187 units for the day. Fluids: 12 Barrels of FloThru mud were lost downhole. 10/27/2015 Drill from 12358' MD to TD, called at 13505' MD. We began taking losses at 13300' MD, just after midnight. After reaching TD we continued reading high gas, the max gas being 9912 units. Racked back a stand and began circulating bottoms up. Continued to monitor gas and pit levels while rig performed a draw down test. Gas: The max gas was 9912 units while circulating bottoms up, with an average of 3688 units throughout the day. Fluids: 368 barrels of FloThru mud were lost downhole. 10/28/2015 Started pulling out of the hole from 13298’ MD to 10119’ MD; where we encountered a tight spot. Dropped down a stand and began circulating mud and working the pipe. Continue pulling pipe while pumping from 100958’ to 8507’ MD. We continued to experienced losses of about 20 bbls per hour throughout the day. Gas: The Max gas was 8703 units from circulated mud, with an average of 432 units. Fluids: 437 barrels of FloThru mud were lost downhole. 10/29/2015 Continue back reaming out of hole through various tight spots. Lost an average of about 40 barrels per hour throughout the day. Gas: The max gas was 1403 units for the day, with an average of 127 units. Fluids: 1030 barrels of FloThru mud were lost downhole. 10/30/2015 Continued to back ream out of the hole. While back reaming, the hole packed off and lost circulation. Circulation was reestablished at 7900’. After pulling into the shoe, the rig circulated bottoms up and spotted a pill. The well was displaced to 12.6 ppg brine. After observing that the well was static, the rig began pulling out of the hole. Gas: The max gas was 903 units for the day with an average of 78 units. The peak of 903 units correlates to the sands located at 8044’. Following that peak, the gas dropped to a background of 20-30 units. Once in the shoe, gas dropped to a background of 10-20 units. Fluids: 275 barrels of mud were lost downhole. 10/31/2015 The rig finished pulling out of the hole and laid down the BHA. After picking up the casing running equipment, the rig began running the 4.5” slotted production liner. 135 stands of liner were run in and then it was run to bottom with 4” drill pipe. Gas: The max gas was 9 units with an average of 1 unit throughout the day. There were no notable gas peaks throughout the day. Upon entering the shoe, the gas dropped off significantly. A bag test was performed to ensure that the gas lines were clear and that the equipment was functioning correctly. The bag test was good. Fluids: 130 barrels of mud were lost downhole. 11/01/2015 Surface data logging released. Rigged down unit, computers, and gas equipment. 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 0 5 10 15 20 25 30 35 40 45 Me a s u r e d D e p t h Rig Days Prognosed Actual WELL NAME: 2S-04 & 2S-04 PB1 OPERATOR: ConocoPhillips Alaska, Inc MUD CO: MI Swaco RIG: Doyon 141 SPERRY JOB: AK-XX-0902772867 Days vs. Depth 22 Sept 2013 Sperry SDL Arrived on Location LOCATION: Kuparuk River Unit AREA: North Slope Borough STATE: Alaska SPUD: 18-Sep-2015 TD: 27-Oct-2015 Commenced 9.875" Intermediate Hole Section On Bot: 07:03 13 Oct 2015 TD Intermediate Hole Section 7896' MD, 6188' TVD Off Bot: 20:15 16 Oct 2015 Commenced 6.75" Production Hole Section On Bot: 00:56 23 Oct 2015 TD Production Hole Section 13505' MD, 6238' TVD Off Bot: 08:40 27 Oct 2015 Landed 7.625" Casing 7886' MD, 6186' TVD 18 Oct 2015 Commenced 9.875" Intermediate Hole Section On Bot: 11:10 23 Sept 2015 TD Intermediate Hole Section 7800' MD, 6240' TVD Off Bot: 02:56 26 Sept 2015 Monitered well due to well flow and high gas. Cement and sidetrack 28 Sept - 11 Oct WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 2S-04 Kuparuk River Unit ConocoPhillips Alaska, Inc North Slope Borough AK-XX-0902772867 Alaska Doyon 141 Intermediate Kyle Wiseman 30-Sep-2015 What went as, or better than, planned: Gas equipment worked well with no issues. Difficulties experienced: Troubleshooting the Gas Trap: The level of the possum belly fluctuated often during this section. The trap and sample line became clogged with mud more than normal. Recommendations: I have spoken to with Pit Watchers about keeping a more consistent level in the possum belly. I will also be monitoring flow out more closely, especially in sections with high clay content. Innovations and/or cost savings: N/A Surface Data Logging After Action Review Surface Data Logging WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Difficulties experienced: During high gas events large acumulations of moisture occurred. Gas fumes in the unit during long periods of high gas. Recommendations: Blow back every connection. Empty drop out jars every other connection. Need to find a way to change out the air in the unit more effectively. Opening doors could provide issues with H2 generators freezing especially as temperatures begin to fall. Innovations and/or cost savings: Adaptor was created to bag test to the 1/2" trap tube. More effectivly captured the integrity of the lines to the unit and more accuratly calculated the trap to sample equipment time. Doyon 141 Production Michael LaDouceur 28-Oct-2015 What went as, or better than, planned: The ability to change from medium to low gain and back again based on the current gas readings of the well. Communication of mud volumes between the mud engineer, pit watcher and loggers was phenominal. 2S-04 Kuparuk River Unit ConocoPhillips Alaska, Inc North Slope Borough AK-XX-0902772867 Alaska Surface Data Logging After Action Review Surface Data Logging 2S-04 & 2S-04 PB1 ConocoPhillips Alaska, Inc MI Swaco Doyon 141 AK-XX-0902772867 Date Depth Wt Vis PV YP Gels Filt R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Sd Pm pH MBT Pf/Mf Chlor Hard ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%%ppb Eqv mg/l Ca++ 22-Sep 2825 9.70 -16 11 16/24/34 -43/27/26/22/16/15 -/-7.0 /92 0.50 1.60 10.7 20.0 1.60/2.80 360 160 Troubleshoot MPD 23-Sep 3672 9.70 49 11 29 10/12/13 6.4 51/40/34/26/11/9 2/-6.5 2/92 0.25 0.50 10.0 3.3 .45/1.6 440 180 Drilling Ahead in Intermediate 24-Sep 5536 10.00 53 15 28 12/14/17 4.7 58/43/38/29/12/11 1/-9.5 3/88 Tr 0.40 9.8 19.0 0.30/1.15 320 120 Drilling Ahead in Intermediate 25-Sep 7432 10.50 57 17 26 12/14/16 3.4 60/43/35/28/12/11 1/2 12.0 3/86 0.50 0.30 9.5 22.0 0.20/1.30 450 80 Drilling Ahead in Intermediate 26-Sep 7800 10.90 50 18 30 11/15/21 2.8 66/48/41/31/12/11 1/2 13.5 3/84 Tr 0.50 9.6 21.0 0.35/1.90 850 320 TD Intermediate 27-Sep 7800 11.20 62 18 36 13/18/24 3.1 72/54/45/34/15/13 1/-14.8 4/82 Tr 0.60 9.6 21.0 0.35/2.20 820 360 Circulating/Weighting Up 28-Sep 7800 11.50 61 21 38 15/21/26 2.7 80/59/49/38/17/15 1/-15.8 3/81 1.00 0.65 9.6 21.3 0.6/2.20 750 120 Circulating/Monitoring 29-Sep 7800 10.50 50 11 26 10/14/19 -48/37/31/24/11/10 -----9.3 ----Monitor Well 30-Sep 7800 10.50 55 13 37 16/19/21 7.6 63/50/43/35/16/15 2/-10.0 -/90 Tr 0.25 9.9 0.0 0.10/2.10 480 40 POOH 1-Oct 7800 10.60 52 13 33 13/15/18 8.3 59/46/41/32/14/13 1/-10.5 -/90 Tr 0.20 9.7 -0.15/2.10 480 40 Bull Heading 2-Oct 7800 11.20 57 16 30 14/17/21 8.3 62/46/41/32/14/13 1/-12.8 -/87 Tr 0.20 9.7 -0.10/2.10 480 60 L/D BHA 3-Oct 7800 11.30 51 14 34 13/16/20 8.5 62/48/41/32/14/13 1/-13.0 -/87 Tr 0.20 9.7 -0.15/2.10 480 40 Repair Elmagco Break 4-Oct 7800 11.30 51 13 22 10/12/16 8.3 48/35/30/25/10/9 1/-13.0 -/87 Tr 0.20 9.5 -0.10/1.90 480 40 WOC 5-Oct 7800 11.30 50 13 22 9/12/15 8.3 48/35/30/25/10/9 1/-13.0 -/87 Tr 0.20 9.5 -0.10/2.00 500 40 Wireline Operations 6-Oct 7800 11.30 50 14 23 10/12/16 8.5 51/37/31/26/11/10 1/-13.0 -/87 0.00 0.20 9.8 -0.15/2.10 500 40 Circulate 7-Oct 7800 11.30 63 16 36 15/18/19 9.0 68/52/45/36/16/14 1/-13.0 -/87 0.00 0.50 9.7 -0.35/3.20 400 40 BOP Test 8-Oct 7800 11.30 50 17 29 13/15/17 8.9 63/46/40/33/13/12 1/-13.0 -/87 0.00 0.35 9.2 -0.15/2.90 460 40 POOH 9-Oct 7800 11.30 51 14 27 12/14/15 8.8 55/41/36/27/12/11 1/-13.0 -/87 0.00 0.40 10.3 -0.30/3.10 400 40 Circulating 10-Oct 7800 11.30 53 13 34 12/14/15 8.7 60/47/41/31/12/11 1/-13.0 -/87 0.00 0.38 10.6 -0.19/2.45 400 60 RIH w/ ECP 11-Oct 7800 11.30 56 17 31 12/14/15 8.9 65/48/42/31/13/12 -/-13.0 tr/87 0.00 0.55 11.3 -0.25/3.00 600 60 Circulating 12-Oct 7800 11.30 55 15 30 13/15/16 8.7 60/45/40/31/13/12 1/-13.0 tr/87 0.00 0.35 10.2 -0.32/2.70 460 60 P/U BHA #3 13-Oct 3507 10.00 60 16 36 13/17/19 5.8 68/52/45/35/13/12 1/-9.0 3/87 Tr 1.20 9.9 4.5 0.50/3.10 800 80 Drilling Ahead in Intermediate 14-Oct 5028 10.00 52 16 33 12/16/21 4.5 65/49/42/33/13/12 1/-9.5 3/88 Tr 0.40 9.9 14.8 0.25/2.30 700 20 Drilling Ahead in Intermediate 15-Oct 6545 10.00 48 14 28 10/12/15 4.5 56/42/36/28/12/11 1/-10.0 3/88 0.25 0.20 9.5 19.5 0.10/1.70 550 20 Drilling Ahead in Intermediate 16-Oct 7896 10.30 43 12 25 9/12/15 3.8 49/37/32/25/11/10 1/2 12.3 3/89 0.25 0.15 9.5 16.8 0.10/1.71 480 20 Circulating 17-Oct 7896 10.60 60 13 25 10/13/17 4.0 51/38/33/26/12/10 1/NA 13.0 3/85 0.25 0.25 10.0 18.3 .20/1.9 500 20 RIH Intermediate Casing 18-Oct 7896 10.60 54 12 24 9/12/15 4.0 48/36/31/24/10/9 1/NA 13.0 2.5/84.5 0.25 0.20 9.5 18.0 0.1/1.7 560 20 Cement Casing 19-Oct 7896 10.60 64 15 22 9/13/17 4.0 52/37/33/28/11/10 1/NA 13.0 2/85 tr 0.20 9.5 18.3 .1/1.8 600 20 Wait on cement 20-Oct 7896 10.60 71 14 25 9/13/17 4.0 53/39/34/26/12/10 1/NA 13.0 2/85 tr 0.20 9.5 18.3 .1/1.7 580 20 Test BOPE 21-Oct 7896 10.55 49 9 30 9/12/17 4.0 48/39/31/2310/9 1/NA 13.0 3/85 tr 0.25 10.5 18.3 .15/1.8 580 60 TIH 22-Oct 7896 10.50 52 15 37 13/17/24 4.0 67/52/45/36/14/12 1/NA 13.0 3/85 tr 0.30 10.5 18.3 .2/2.0 540 120 MAD Pass/Clean out Hole 23-Oct 8615 10.50 62 20 30 8/10/12 2.4 70/50/41/30/9/8 1/2 15.0 1/84 tr 3.90 9.6 1.6 3.5/8.5 156500 80 Drilling Ahead in Production Section 24-Oct 10113 10.75 61 23 33 8/10/11 2.5 79/56/45/32/10/8 1/1 16.5 2/82 tr 5.40 9.5 1.8 4.8/9.5 165000 60 Drilling Ahead in Production Section 25-Oct 11600 10.80 64 22 42 9/12/13 2.2 86/64/51/36/10/9 1/1 16.8 2/81 tr 4.60 9.5 1.8 4.3/9.2 160000 40 Drilling Ahead in Production Section 26-Oct 13018 10.80 63 27 33 9/10/11 2.2 87/60/49/34/10/9 1/1 17.3 2.5/80 tr 4.10 9.6 2.0 3.6/8.1 163000 40 Drilling Ahead in Production Section 27-Oct 13208 10.60 63 26 34 8/10/11 3.4 86/60/49/34/10/6 1/1 17.0 2/81 tr 3.90 9.7 1.8 3.5/8.0 125000 40 Drilling Ahead in Production Section 28-Oct 13504 10.80 63 25 34 8/9/10 2.7 84/59/47/33/9/8 1/NA 17.0 3/81 tr 3.90 9.5 1.6 3.5/8.0 127000 40 TD Production 29-Oct 13504 10.80 59 22 33 9/10/11 2.7 77/55/45/33/10/8 1/NA 17.0 3/81 tr 3.50 9.4 1.6 3.2/7.5 121000 40 Pulling Out Of Hole 30-Oct 13504 12.60 47 9 18 7/8/8 -36/27/24/18/7/6 -20.0 0/80 0.00 2.50 10.1 0.0 1.50/4.50 246000 60 Pulling Out Of Hole 31-Oct 13504 12.70 43 9 17 6/7/8 1.0 35/26/21/17/8/7 -20.0 0/80 0.00 2.20 9.6 0.0 0.70/2.30 229000 60 RIH w/ 4.5" Liner Casing Record Remarks 10.75" Casing @ 2815' MD, 2562'TVD 7.625" Casing @ 7886' MD, 6186'TVD WELL NAME:LOCATION:Kuparuk River Unit OPERATOR:AREA:North Slope Borough MUD CO:STATE:Alaska RIG:SPUD:18-Sep-15 SPERRY JOB:TD:27-Oct-15 W a t e r a n d O i l B a s e d M u d R e c o r d BHA#SDL RUN #Bit #Bit Type Bit Size Depth In Depth Out Footage Bit Hours TFA AVG ROP WOB (max) RPM (max) SPP (max) FLOW GPM (max)Bit Grade Comments 1 N/A 1 Milled Tooth Bit 13.50 91 2825 2734 23.03 0.994 111.1 30 100 1775 750 1-1-WT-A-E-1/16-NO-TD Surface TD 2 100 2 PDC 9.875 2825 7800 4975 42.72 1.131 116.7 14 140 3465 750 1-3-LT-N-X-I-BT-TD Intermediate TD 3 200 3 PDC 9.875 2815 7896 5081 94.34 0.098 89.0 17 140 3276 800 1-1-WT-N-X-I-NA-TD Intermediate TD 4 300 4 PDC 6.75 7896 13505 5609 70.40 0.482 79.6 18 150 3225 260 3-4-BT-G-X-I-CT-TD Production TD WELL NAME:2S-04 & 2S-04 PB1 LOCATION:Kuparuk River Unit OPERATOR:ConocoPhillips Alaska, Inc AREA:North Slope Borough MUD CO: SPERRY JOB:AK-XX-0902772867 TD:27-Oct-15 MI Swaco STATE:Alaska RIG:Doyon 141 SPUD:18-Sep-15 B i t R e c o r d . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 218.97 -2175278.88 59.91 12 (max)(current) 4410 0 Cly 14175 Set AtSize 45.5 L-80 Grade 10.75'' 907-670-4906Unit Phone: 874 Macy Williams Maximum Report By:Logging Engineers:Macy Williams/Kyle Wiseman 3802 357 753 178 Units* Casing Summary Lithology (%) 11 MBT 3672' pH 1.131 0 2283 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 3.349 C-5n 2836' 114.0 C-2 1311 in 3 2847'Minimum Depth Time: 2845' MD. Circulate bottoms up and monitor well until static. Perform FIT to 14.95 EMW. Rig down test equipment. Displace well to 32 2830' 3672' 842' Max @ ft Current 2828'146.0 Date: Avg to2830' Yesterday's Depth: Current Depth: 24 Hour Progress: 198.0 Flow In (gpm) Flow In (spm) Gas Summary 0 2247 897 (current) D. Mickey/A. Lundale ShClyst TuffGvlCoal cP 11 Footage Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 Drilling Ahead PV 24 hr Max Weight 32 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 10.00 384 LSND 6.43672'29 Depth in / out Mud Type Lst Type Average -30Background (max) Trip 10.0110.34 Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) WOB Surface 100% Gas In Air=10,000 Units-Connection 100 2254 9.6 ppg LSND. Drill from 2845' MD to 3672' MD. 2659' ConditionBit # 2 6.5 9.875 9.70 PDC 9.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.67 Doyon 141 Report For: Morning Report Report # 1 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough ROP ROP (ft/hr) 4.23 @ Mud Data Depth 23-Sep-2015 12:00 AM Current Pump & Flow Data: 2051 Max 8 Chlorides mg/l 440.00 Continue trouble shooting MPD. Pull MPD bearing and trip nipple. Test Casing to 3500 psi for 30 minutes. Drill to rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 409.2 100 406355595.11 23 (max)(current) 86 0 Cly 9415 Set AtSize 45.5 L-80 Grade 10.75'' 907-670-4906Unit Phone: 0 Macy Williams Maximum Report By:Logging Engineers:Macy Williams/Kyle Wiseman 30% 7361 65 749 177 Units* Casing Summary Lithology (%) 6 MBT 5793' pH 1.131 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 19.053 C-5n 4962' 133.0 C-2 911 in 2 4237'Minimum Depth Time: and install RCD bearing. Continue drilling ahead to 5793' MD. 54 3672' 5793' 2121' Max @ ft Current 4395'123.0 Date: Avg to3672' Yesterday's Depth: Current Depth: 24 Hour Progress: 161.0 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) D. Mickey/A. Lundale ShClyst TuffGvlCoal cP 15 Footage Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 Drilling Ahead PV 24 hr Max Weight 131 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.80 071 LSND 4.75793'28 Depth in / out Mud Type Lst 30% Type Average -53Background (max) Trip 10.1211.06 Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) WOB Surface 100% Gas In Air=10,000 Units-Connection 40% 9 2659' ConditionBit # 2 9.5 9.875 10.05 PDC 10.00 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.61 Doyon 141 Report For: Morning Report Report # 2 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough ROP ROP (ft/hr) 4.23 @ Mud Data Depth 24-Sep-2015 12:00 AM Current Pump & Flow Data: 2051 Max 39 Chlorides mg/l 320.00 Drill ahead from 3672' MD to 5537' MD. Circulate bottoms up and monitor well for 15 minutes. Remove trip nipple rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Continued to drill ahead in intermediate. Monitor well for 30 mins, static while RCD bearing was changed out. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 450.00 806 25-Sep-2015 12:00 AM Current Pump & Flow Data: 3255 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 3 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 141 Report For: ConditionBit # 2 12.0 9.875 10.50 PDC 10.50 Size -27 bbls lost for the day 2659' 100% Gas In Air=10,000 Units-Connection 2214 Tools API FL Chromatograph (ppm) W OB Surface Avg Min Comments RPM ECD (ppg) ml/30min 285Background (max) Trip Average - Mud Type Lst 10% Type LSND 5.67432'26 Depth in / out YP (lb/100ft2) 9.50 7328863 027 CementCht Silt C-4i C-4n 24 hr Max W eight 1447 Hours C-3 70 Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 Drilling Ahead PV Footage D. Mickey/A. Lundale ShClyst TuffGvlCoal cP 17 Gas Summary 0 855 182 (current) Avg to3672' Yesterday's Depth: Current Depth: 24 Hour Progress: 166.0 Flow In (gpm) Flow In (spm) 5793' 7604' 1811' Max @ ft Current 6114'121.0 Date: Time: Continued to drill ahead, changed out pressure sensor per MPD rep. 196 in 5 5788'Minimum Depth C-5n 7409' 113.0 C-2 1008 SPP (psi) Gallons/stroke TFABit Type Depth 22.057 MBT 5793' pH 1.131 56 256 11 Siltst 743 175 Units* Casing Summary Lithology (%) 96 20% 20420 687 907-670-4906Unit Phone: 201 Macy Williams Maximum Report By:Logging Engineers:Macy Williams/Kyle Wiseman Set AtSize 45.5 L-80 Grade 10.75'' (max)(current) 4712 64 Cly 79449 Bottoms Up Time 530 149 5268726127 30 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 547 158 5320742131 30 (max)(current) 37894 7 Cly 364718 Set AtSize 45.5 L-80 Grade 10.75'' 907-670-4906Unit Phone: 1205 Macy Williams Maximum Report By:Logging Engineers:Macy Williams/Kyle Wiseman 66702 72 Units* Casing Summary Lithology (%) 308 MBT 7800' pH 1.131 5 2385 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 21.050 C-5n 7770' - C-2 5833 in 4 7619'Minimum Depth Time: flowing. Begin trying to pull out of hole. Encountered tight spot and packed off at 7750' MD. Work pipe until free and rotation is 817 7604' 7800' 196' Max @ ft Current 7607'96.0 Date: Avg to7604' Yesterday's Depth: Current Depth: 24 Hour Progress: 116.0 Flow In (gpm) Flow In (spm) Gas Summary 0 5488 1223 (current) D. Mickey/A. Lundale ShClyst TuffGvlCoal cP 18 Footage Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 Drilling Ahead PV 24 hr Max Weight 5475 Hours C-3 02 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.60 242870221 LSND 2.87800'30 Depth in / out Mud Type Lst Type Average -4Background (max) Trip 11.6011.81 Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) WOB Surface 100% Gas In Air=10,000 Units-Connection 16631 -31 bbls lost for the day established. Circulate bottoms up and condition mud. Monitor well as per Coman. 2659' ConditionBit # 2 13.5 9.875 10.80 PDC 10.90 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.92 Doyon 141 Report For: Morning Report Report # 4 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough ROP ROP (ft/hr) 4.23 @ Mud Data Depth 27-Sep-2015 12:00 AM Current Pump & Flow Data: Max 2342 Chlorides mg/l 850.00 Drill ahead from 7604' MD to 7800' MD (TD). Circulate 3 bottoms up and monitor well. Weight up mud due to well rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Monitored well w/ 0.5bbl gain. Began to weight up mud to 11.1ppg, 9989 units of gas on BU. Circ and cond mud at rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 820.00 4922 27-Sep-2015 12:00 AM Current Pump & Flow Data: 1767 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 5 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 141 Report For: ConditionBit # 2 14.8 9.875 11.20 PDC 11.20 Size -33 bbls lost for the day C/O MPD bearing then continued to circulate while weighting up to 11.4. 2659' 100% Gas In Air=10,000 Units-Connection 48897 Tools API FL Chromatograph (ppm) W OB Surface Avg Min Comments RPM ECD (ppg) ml/30min 400Background (max) Trip Average - Mud Type Lst Type LSND 3.17800'36 Depth in / out YP (lb/100ft2) 9.60 10003063913 00 CementCht Silt C-4i C-4n 24 hr Max W eight 8313 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 W eighting Up Mud System PV Footage D. Mickey/A. Lundale ShClyst TuffGvlCoal cP 18 Gas Summary 0 19816 4240 (current) Avg to7604' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 7800' 7800' 0' Max @ ft Current -- Date: Time: 11.1, then monitored well for flow in cellar, 0.39bbl gain. Continued to monitor for flow then CBU to circulate out high gas. 709 in 1 -Minimum Depth C-5n - - C-2 9989 SPP (psi) Gallons/stroke TFABit Type Depth 21.062 MBT 7800' pH 1.131 0 8080 0 Siltst 503 119 Units* Casing Summary Lithology (%) 109774965 0 907-670-4906Unit Phone: 4379 Macy Williams Maximum Report By:Logging Engineers:Macy Williams/Kyle Wiseman Set AtSize 45.5 L-80 Grade 10.75'' (max)(current) 104877 0 Cly 913179 Bottoms Up Time 389 158 5160520131 43 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 389 158 5160520131 43 (max)(current) 88879 0 Cly 690241 Set AtSize 45.5 L-80 Grade 10.75'' 907-670-4906Unit Phone: 3933 Macy Williams Maximum Report By:Logging Engineers:Macy Williams/Kyle Wiseman 66429 0 Units* Casing Summary Lithology (%) 982 MBT pH 1.131 0 6968 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 21.361 C-5n - - C-2 9911 in 2 -Minimum Depth Time: Begin running in hole washing and reaming from 7444' MD to 7765' MD. Hole packing off and loss of circulation. Work pipe free. 1198 7800' 7800' 0' Max @ ft Current -- Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gas Summary 0 17090 3791 (current) D. Mickey/A. Lundale ShClyst TuffGvlCoal cP 21 Footage Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 Monitoring Well PV 24 hr Max Weight 7079 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.60 9912837883 LSND 2.77800'38 Depth in / out Mud Type Lst Type Average -15Background (max)Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) WOB Surface 100% Gas In Air=10,000 Units-Connection 41488 -57 bbls lost for the day Back ream out of hole from 7765' MD to 7170' MD. Circulate bottoms up and monitor well. 2659' ConditionBit # 2 15.8 9.875 11.50 PDC 11.50 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 141 Report For: Morning Report Report # 6 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough ROP ROP (ft/hr) 4.23 @ Mud Data Depth 28-Sep-2015 12:00 AM Current Pump & Flow Data: Max 4212 Chlorides mg/l 750.00 Weight up mud from 11.1 ppg to 11.4 ppg, then monitor well. Circulate out gas cut mud and circulate bottoms up. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Backream out of hole to 6918' MD. Loss circulation. Pump 52 bbls down the backside. No returns. Pump 30 bbl rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l - 119 29-Sep-2015 12:00 AM Current Pump & Flow Data: Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 7 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 141 Report For: ConditionBit # 2 - 9.875 10.50 PDC 10.50 Size -1039 bbls lost for the day Company Man. pump a 35 bbl sweep. No returns. Pump at 2 bpm and pump a 35 bbl Strata LCM sweep spot at 5600' MD. Monitor losses as per 2659' 100% Gas In Air=10,000 Units-Connection 1791 Tools API FL Chromatograph (ppm) WOB Surface Avg Min Comments RPM ECD (ppg) ml/30min 13Background (max) Trip Average - Mud Type Lst Type LSND -7800'26 Depth in / out YP (lb/100ft2) 9.30 7815764 00 CementChtSilt C-4i C-4n 24 hr Max Weight 105 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 Monitor Well PV Footage R. Wall/D. Mickey/B. Finkbiner ShClyst TuffGvlCoal cP 11 Gas Summary 0 1951 747 (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 7800' 7800' 0' Max @ ft Current -- Date: Time: LCM pill down the backside at 2 bpm. No returns. Remove RCD bearing and install trip nipple. Fill hole with charge pump, then 40 in 3 -Minimum Depth C-5n - - C-2 547 SPP (psi) Gallons/stroke TFABit Type Depth -50 MBT pH 1.131 0 577 0 Siltst Units* Casing Summary Lithology (%) 441028 43 907-670-4906Unit Phone: 870 Macy Williams Maximum Report By:Logging Engineers:Macy Williams/Kyle Wiseman Set AtSize 45.5 L-80 Grade 10.75'' (max)(current) 2048 0 Cly 27499 Bottoms Up Time 389 158 5160520131 43 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 248.84 158 403774272.3 202 (max)(current) 14 0 Cly 76 Set AtSize 45.5 L-80 Grade 10.75'' 907-670-4906Unit Phone: 68 Hilary Garney Maximum Report By:Logging Engineers:Hilary Garney/Kyle Wiseman 15 0 - - Units* Casing Summary Lithology (%) 2 MBT - pH 1.131 0 22 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 0.055 C-5n - - C-2 25 in 2 -Minimum Depth Time: strata LCM pill. BROOH F/ 6784' to 5540'. Pumped 30 bbl strata LCM pill, monitor well, 1.8bbl lost in 30 mins. Pumped out of hole 7 7800' 7800' 0' Max @ ft Current -- Date: Avg to - Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gas Summary 0 90 55 (current) R. W all/D. Mickey/B. Finkbiner ShClyst TuffGvlCoal cP 13 Footage Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 POOH PV 24 hr Max W eight 8 Hours C-3 00 CementCht Silt C-4i C-4n YP (lb/100ft2) 9.90 13109 LSND 7.67800'37 Depth in / out Mud Type Lst Type Average -10Background (max) Trip - - Avg Min Comments RPM ECD (ppg) ml/30min Tools - API FL Chromatograph (ppm) WOB 100% Gas In Air=10,000 Units-Connection 36 - 1328 bbls lost for the day encountered tight spot at 5363' and 4943', reamed until no longer tight. 2659' ConditionBit # 2 12.0 9.875 10.50 PDC 10.50 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Morning Report Report # 8 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough ROP ROP (ft/hr) 4.23 @ Mud Data Depth 30-Sep-2015 12:00 AM Current Pump & Flow Data: - Max 3 Chlorides mg/l 480.00 Pumped 30 bbl LCM, monitor well, static. Pumps came on, continued to lose, monitor well, static. Pumped 30 bbl rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 63.1 158 62791.2 9.6 6 (max)(current) 24464 0 Cly 295559 Set AtSize 45.5 L-80 Grade 10.75'' 907-670-4906Unit Phone: 984 Hilary Garney Maximum Report By:Logging Engineers:Hilary Garney/Kyle Wiseman 29438 20 211 50 Units* Casing Summary Lithology (%) 256 MBT - pH 1.131 0 1916 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth -52 C-5n - - C-2 4029 in 5 -Minimum Depth Time: static. Continued to pump out of the hole to 939' MD, increase in flow was noticed with max gas of 4029 U observed, shut in well, 411 7800' 7800' 0' Max @ ft Current -- Date: Avg to - Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gas Summary 0 4320 999 (current) R. W all/D. Mickey/B. Finkbiner ShClyst TuffGvlCoal cP 13 Footage Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 Bull Heading PV 24 hr Max W eight 2652 Hours C-3 00 CementCht Silt C-4i C-4n YP (lb/100ft2) 9.70 241654198 LSND 8.37800'33 Depth in / out Mud Type Lst Type Average -0Background (max) Trip - - Avg Min Comments RPM ECD (ppg) ml/30min Tools - API FL Chromatograph (ppm) WOB Surface 100% Gas In Air=10,000 Units-Connection 10324 - 1117 bbls lost for the day Chasing with LSND. open super choke 25% with no returns but a gain rate of 28 BPH. Began to bullhead to 6600' MD starting with Hi Vis pill. 2659' ConditionBit # 2 10.5 9.875 - PDC 10.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Morning Report Report # 9 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough ROP ROP (ft/hr) 4.23 @ Mud Data Depth 1-Oct-2015 12:00 AM Current Pump & Flow Data: 173 Max 1232 Chlorides mg/l 480.00 Continued to pump out of the hole to 2758' MD. Broke circulation with no returns. Monitored the well for 30 mins rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Bullheaded well with 10.5ppg mud to 6600' MD. Monitored well, gained 30.2bbls in 30 mins. Decision was made rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 480.00 22 2-Oct-2015 12:00 AM Current Pump & Flow Data: - Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 10 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: ConditionBit # 2 12.8 9.875 - PDC 11.20 Size - 1230 bbls lost for the day POOH and L/D BHA. SDL calibrated gas equipment for next section. Killed well with 10bbl 11.5ppg down DP, 25bbl hi vis spacer followed by 11.5ppg LSND. Monitored well, 10-20BPH loss rate. 2659' 100% Gas In Air=10,000 Units-Connection 332 Tools - API FL Chromatograph (ppm) 2825' 7800' WOB Surface - - Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max) Trip Average - Mud Type Lst Type LSND 8.37800'13 Depth in / out YP (lb/100ft2) 9.70 152712 00 CementCht Silt C-4i C-4n 24 hr Max W eight 18 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 L/D BHA PV 4975' Footage R. W all/D. Mickey/B. Finkbiner ShClyst TuffGvlCoal cP 16 Gas Summary 0 246 104 (current) Avg to - Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 7800' 7800' 0' Max @ ft Current -- Date: Time: to weight up mud to 11.5ppg. While waiting on mud, performed rig maintenance. Weighted up mud with 11.5ppg spike fluid. 9 in 2 -Minimum Depth C-5n - - C-2 61 SPP (psi) Gallons/stroke TFABit Type Depth -57 MBT - pH 1.131 0 89 0 Siltst - - Units* Casing Summary Lithology (%) 882 0 907-670-4906Unit Phone: 122 Hilary Garney Maximum Report By:Logging Engineers:Hilary Garney/Kyle Wiseman Set AtSize 45.5 L-80 Grade 10.75'' (max)(current) 494 0 Cly 3055 Bottoms Up Time ------ Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap:Finished L/D BHA. RIH w/ 3.5" tubing to 1100' MD and 1 std of DP. Blow down choke lines. Cont to RIH w/ tubing rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 480.00 320 3-Oct-2015 12:00 AM Current Pump & Flow Data: - Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 11 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Condition 1-3-LT-N-X-I-BT-TD Bit # 2 13.0 9.875 11.30 PDC 11.30 Size - 74 bbls lost for the day 2659' 100% Gas In Air=10,000 Units-Connection 642 Tools - API FL Chromatograph (ppm) 14.02825' 7800' WOB Surface - - Avg Min Comments RPM ECD (ppg) ml/30min 100Background (max) Trip Average - Mud Type Lst Type 140.0 LSND 8.57800'34 Depth in / out YP (lb/100ft2) 9.70 3113534 00 CementCht Silt C-4i C-4n 24 hr Max Weight 861 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 Repairing Elmagco Break PV 4975' Footage 42.70 R. Wall/D. Mickey/B. Finkbiner ShClyst TuffGvlCoal cP 14 Gas Summary 0 194 29 (current) Avg to - Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 7800' 7800' 0' Max @ ft Current -- Date: Time: to 2734' MD. Remove trip nipple and install RCD bearing. CBU w/ no returns. Monitor hole while repairing Elmagco break. 152 in 0 -Minimum Depth C-5n - - C-2 335 SPP (psi) Gallons/stroke TFABit Type Depth -51 MBT - pH 1.131 0 103 0 Siltst - - Units* Casing Summary Lithology (%) 9814217 0 907-670-4906Unit Phone: 27 Hilary Garney Maximum Report By:Logging Engineers:Hilary Garney/Kyle Wiseman Set AtSize 45.5 L-80 Grade 10.75'' (max)(current) 1861 0 Cly 31057 Bottoms Up Time ------ Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time ------ (max)(current) 3614 0 Cly 45455 Set AtSize 45.5 L-80 Grade 10.75'' 907-670-4906Unit Phone: 1038 Hilary Garney Maximum Report By:Logging Engineers:Hilary Garney/Kyle Wiseman 4650 0 - - Units* Casing Summary Lithology (%) 79 MBT - pH 1.131 0 1336 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth -51 C-5n - - C-2 468 in 0 -Minimum Depth Time: losses. RIH to 7747' MD. Hole packed off, POOH to 7682' MD. Pumped abandonment plug per SLB cemeters. Attempted to 61 7800' 7800' 0' Max @ ft Current -- Date: Avg to - Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gas Summary 0 3755 922 (current) R. Wall/D. Mickey/B. Finkbiner ShClyst TuffGvlCoal cP 13 4975' Footage 42.70 Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 W OC PV 24 hr Max Weight 439 Hours C-3 00 CementCht Silt C-4i C-4n YP (lb/100ft2) 9.50 6022054 140.0 LSND 8.37800'22 Depth in / out Mud Type Lst Type Average -0Background (max) Trip - - Avg Min Comments RPM ECD (ppg) ml/30min Tools - API FL Chromatograph (ppm) 14.02825' 7800' WOB Surface 100% Gas In Air=10,000 Units-Connection 5030 - 579 bbls lost for the day POOH w/ no success. Currently WOC. 2659' Condition 1-3-LT-N-X-I-BT-TD Bit # 2 13.0 9.875 11.30 PDC 11.30 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Morning Report Report # 12 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough ROP ROP (ft/hr) 4.23 @ Mud Data Depth 4-Oct-2015 12:00 AM Current Pump & Flow Data: - Max 329 Chlorides mg/l 480.00 Finished repairing Elmagco break. Bull headed well w/ 200bbls due to gas migration up hole. Monitored well for rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Finished W OC, tried to work tubing free, unsuccessful. Decision was made to call wireline. Currently running rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 500.00 17 5-Oct-2015 12:00 AM Current Pump & Flow Data: - Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 13 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Condition 1-3-LT-N-X-I-BT-TD Bit # 2 13.0 9.875 11.30 PDC 11.30 Size - 75 bbls lost for the day 2659' 100% Gas In Air=10,000 Units-Connection 102 Tools - API FL Chromatograph (ppm) 14.02825' 7800' WOB Surface - - Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max) Trip Average - Mud Type Lst Type 140.0 LSND 8.37800'22 Depth in / out YP (lb/100ft2) 9.50 2182 00 CementCht Silt C-4i C-4n 24 hr Max Weight 12 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 W ireline Operations PV 4975' Footage 42.70 R. Wall/D. Mickey/B. Finkbiner ShClyst TuffGvlCoal cP 13 Gas Summary 0 119 33 (current) Avg to - Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 7800' 7800' 0' Max @ ft Current -- Date: Time: wireline operations. 3 in 0 -Minimum Depth C-5n - - C-2 10 SPP (psi) Gallons/stroke TFABit Type Depth -50 MBT - pH 1.131 0 40 0 Siltst - - Units* Casing Summary Lithology (%) 343 0 907-670-4906Unit Phone: 41 Hilary Garney Maximum Report By:Logging Engineers:Hilary Garney/Kyle Wiseman Set AtSize 45.5 L-80 Grade 10.75'' (max)(current) 51 0 Cly 117 Bottoms Up Time ------ Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap:POOH w/ string shot tools. M/U and RIH w/ cutting torch. Troubleshoot cutter and attempted to POOH, lost tool. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 500.00 261 6-Oct-2015 12:00 AM Current Pump & Flow Data: - Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 14 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Condition 1-3-LT-N-X-I-BT-TD Bit # 2 13.0 9.875 11.25 PDC 11.30 Size - 66 bbls lost for the day and POOH. R/D Wireline. Attempted to work pipe, still stuck. M/U severing tool and fire charge. Circulate. 2659' 100% Gas In Air=10,000 Units-Connection 29559 Tools - API FL Chromatograph (ppm) 14.02825' 7800' WOB Surface - - Avg Min Comments RPM ECD (ppg) ml/30min 250Background (max) Trip Average - Mud Type Lst Type 140.0 LSND 8.57800'23 Depth in / out YP (lb/100ft2) 9.80 5020344 00 CementCht Silt C-4i C-4n 24 hr Max Weight 180 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 Circulating PV 4975' Footage 42.70 D. Coates/D. Mickey/B. Finkbiner ShClyst TuffGvlCoal cP 14 Gas Summary 0 19955 4417 (current) Avg to - Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 7800' 7800' 0' Max @ ft Current -- Date: Time: M/U and RIH w/ fishing tool to 5835' MD. POOH and L/D fishing tool, no fish. M/U and RIH w/ cutting torch, cut DP at 5775' MD 27 in 0 -Minimum Depth C-5n - - C-2 3209 SPP (psi) Gallons/stroke TFABit Type Depth -50 MBT - pH 1.131 0 7554 0 Siltst - - Units* Casing Summary Lithology (%) 71245 0 907-670-4906Unit Phone: 4729 Hilary Garney Maximum Report By:Logging Engineers:Hilary Garney/Kyle Wiseman Set AtSize 45.5 L-80 Grade 10.75'' (max)(current) 22737 0 Cly 28072 Bottoms Up Time ------ Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap:Began circulating and observed gas steadily rising, decision was made to bull head well. Continued to P ump OOH rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 400.00 4385 7-Oct-2015 12:00 AM Current Pump & Flow Data: - Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 15 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Condition 1-3-LT-N-X-I-BT-TD Bit # 2 13.0 9.875 11.30 PDC 11.30 Size - 455 bbls lost for the day 2659' 100% Gas In Air=10,000 Units-Connection 29906 Tools - API FL Chromatograph (ppm) 14.02825' 7800' WOB Surface - - Avg Min Comments RPM ECD (ppg) ml/30min -Background (max) Trip Average - Mud Type Lst Type 140.0 LSND 9.07800'36 Depth in / out YP (lb/100ft2) 9.70 9983418881 00 CementCht Silt C-4i C-4n 24 hr Max Weight 4376 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 BOP Test PV 4975' Footage 42.70 D. Coates/B. Finkbiner ShClyst TuffGvlCoal cP 16 Gas Summary 0 21608 5086 (current) Avg to - Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 7800' 7800' 0' Max @ ft Current -- Date: Time: to inside surface casing. Monitored well, static. Cont to pump OOH to surface. R/U and began BOP testing. 627 in 0 -Minimum Depth C-5n - - C-2 4265 SPP (psi) Gallons/stroke TFABit Type Depth -63 MBT - pH 1.131 0 7976 0 Siltst - - Units* Casing Summary Lithology (%) 119214338 0 907-670-4906Unit Phone: 5568 Hilary Garney Maximum Report By:Logging Engineers:Hilary Garney/Kyle Wiseman Set AtSize 45.5 L-80 Grade 10.75'' (max)(current) 28379 0 Cly 84935 Bottoms Up Time ------ Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time ------ (max)(current) 39286 0 Cly 211166 Set AtSize 45.5 L-80 Grade 10.75'' 907-670-4906Unit Phone: 5635 Hilary Garney Maximum Report By:Logging Engineers:Hilary Garney/Kyle Wiseman 9585 0 91 21 Units* Casing Summary Lithology (%) 565 MBT - pH 1.131 0 9590 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth -50 C-5n - - C-2 6250 in 0 -Minimum Depth Time: w/ 425bbls. Monitored well, static. Pump P&A plug per SLB cementers. 553 7800' 7800' 0' Max @ ft Current -- Date: Avg to - Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gas Summary 0 25053 5518 (current) D. Coates/B. Finkbiner ShClyst TuffGvlCoal cP 17 4975' Footage 42.70 Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 POOH PV 24 hr Max Weight 1942 Hours C-3 00 CementCht Silt C-4i C-4n YP (lb/100ft2) 9.20 4831612429 140.0 LSND 8.97800'29 Depth in / out Mud Type Lst Type Average -400Background (max) Trip - - Avg Min Comments RPM ECD (ppg) ml/30min Tools - API FL Chromatograph (ppm) 14.02825' 7800' WOB Surface 100% Gas In Air=10,000 Units-Connection 35625 - 697 bbls lost for the day 2659' Condition 1-3-LT-N-X-I-BT-TD Bit # 2 13.0 9.875 11.30 PDC 11.30 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Morning Report Report # 16 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough ROP ROP (ft/hr) 4.23 @ Mud Data Depth 8-Oct-2015 12:00 AM Current Pump & Flow Data: 50 Max 1894 Chlorides mg/l 460.00 Finished BOP Test. RIH w/ cement stinger on 3.5" tubing, singled in hole with 5" DP to 5662' MD. Bullheaded well rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:R/D cement equipment. Load nerf ball and pump down drill string w/ no returns. Began to POOH to 4647' MD. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 400.00 1130 9-Oct-2015 12:00 AM Current Pump & Flow Data: 167 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 17 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Condition 1-3-LT-N-X-I-BT-TD Bit # 2 13.0 9.875 11.20 PDC 11.30 Size - 244 bbls lost for the day computers and calibrated Chromatograph while WOC. R/D cementers and POOH to 4378' MD. Dropped wiper ball and CBU x2, no losses. SDL Crew performed maintenance on maintenance. RIH to 4845' MD and washed down to 4937' MD, TOC 5036' MD. POOH to 5026' MD. R/U and pumped balance plug 2659' 100% Gas In Air=10,000 Units-Connection 10049 Tools - API FL Chromatograph (ppm) 14.02825' 7800' WOB Surface - - Avg Min Comments RPM ECD (ppg) ml/30min 100Background (max) Trip Average - Mud Type Lst Type 140.0 LSND 8.87800'27 Depth in / out YP (lb/100ft2) 10.30 3681049322 00 CementCht Silt C-4i C-4n 24 hr Max Weight 1123 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 Circulating PV 4975' Footage 42.70 D. Coates/B. Finkbiner ShClyst TuffGvlCoal cP 14 Gas Summary 0 9134 2702 (current) Avg to - Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 7800' 7800' 0' Max @ ft Current -- Date: Time: Monitored well, cont to POOH to 2794' MD. Clear and clean rig floor while monitoring well on TT. Slip & cut drill line. WOC. Rig 273 in 8 -Minimum Depth C-5n - - C-2 1640 SPP (psi) Gallons/stroke TFABit Type Depth -51 MBT - pH 1.131 0 3061 0 Siltst 125 30 Units* Casing Summary Lithology (%) 3635660 0 907-670-4906Unit Phone: 2997 Hilary Garney Maximum Report By:Logging Engineers:Hilary Garney/Kyle Wiseman Set AtSize 45.5 L-80 Grade 10.75'' (max)(current) 10517 0 Cly 56637 Bottoms Up Time ------ Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time ------ (max)(current) 2808 0 Cly 17411 Set AtSize 45.5 L-80 Grade 10.75'' 907-670-4906Unit Phone: 728 Hilary Garney Maximum Report By:Logging Engineers:Hilary Garney/Kyle Wiseman 2195 0 - - Units* Casing Summary Lithology (%) 103 MBT - pH 1.131 0 649 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth -53 C-5n - - C-2 383 in 0 -Minimum Depth Time: RIH from 2700' MD to TOC @ 4877' MD. POOH to 4845' MD and monitored well, fluid over flowing out of pipe, CBU. Monitored 65 7800' 7800' 0' Max @ ft Current -- Date: Avg to - Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gas Summary 0 2034 624 (current) D. Coates/B. Finkbiner ShClyst TuffGvlCoal cP 13 4975' Footage 42.70 Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 TIH w/ ECP PV 24 hr Max Weight 425 Hours C-3 00 CementCht Silt C-4i C-4n YP (lb/100ft2) 10.60 135337112 140.0 LSND 8.77800'34 Depth in / out Mud Type Lst Type Average -25Background (max) Trip - - Avg Min Comments RPM ECD (ppg) ml/30min Tools - API FL Chromatograph (ppm) 14.02825' 7800' WOB Surface 100% Gas In Air=10,000 Units-Connection 2336 - 0 bbls lost for the day surface. L/D ECP running tool. Clean and clear rig floor. M/U ECP #2 and RIH, filling pipe every 5 stands. well, static. POOH from 4845' MD to 2790' MD. R/U and performed FIT to 12.5ppg. R/D test equipment. POOH from 2790' MD to 2659' Condition 1-3-LT-N-X-I-BT-TD Bit # 2 13.0 9.875 11.30 PDC 11.30 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Morning Report Report # 18 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough ROP ROP (ft/hr) 4.23 @ Mud Data Depth 10-Oct-2015 12:00 AM Current Pump & Flow Data: - Max 387 Chlorides mg/l 400.00 Cont CBU x2, no losses, monitored well, static. POOH from 4378' MD to 2700' MD. WOC. Monitored well on TT. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time ------ (max)(current) 1267 0 Cly 7134 Set AtSize 45.5 L-80 Grade 10.75'' 907-670-4906Unit Phone: 305 Hilary Garney Maximum Report By:Logging Engineers:Hilary Garney/Kyle Wiseman 629 0 169 40 Units* Casing Summary Lithology (%) 29 MBT - pH 1.131 0 271 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth -56 C-5n - - C-2 161 in 0 -Minimum Depth Time: min, increasing @ 200PSI increments, holding for 1 min to 1500PSI, bled pressure down then back up to 1500PSI w/ no indication 19 7800' 7800' 0' Max @ ft Current -- Date: Avg to - Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gas Summary 0 873 265 (current) D. Coates/B. Finkbiner ShClyst TuffGvlCoal cP 17 4975' 9.875 1.035 Footage 42.70 Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 Circulating PV 24 hr Max Weight 117 Hours C-3 00 CementCht Silt C-4i C-4n YP (lb/100ft2) 11.30 4310035 140.0 PDC LSND 8.97800'31 Depth in / out Mud Type Lst Type Average -20Background (max) Trip - - Avg Min Comments RPM ECD (ppg) ml/30min Tools - API FL Chromatograph (ppm) 14.02825' 7800' WOB Surface 100% Gas In Air=10,000 Units-Connection 1100 3 - 0 bbls lost for the day 2387' MD to 3507' MD @ 2BPM. CBU @ 4BPM. to 2387' MD. Left cement string in hole, L/D DP while WOC. L/D 28 stnds of 5" DP from derrick, monitor well on TT. RIH from ECP inflated. Decision made to shear off ECP and pump cement. CBU @ 6BPM. Performed cement job. POOH from 3226' MD 2659' Condition 1-3-LT-N-X-I-BT-TD Bit # 2 13.0 9.875 113.00 PDC 11.30 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Morning Report Report # 19 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough ROP ROP (ft/hr) 4.23 @ Mud Data Depth 11-Oct-2015 12:00 AM Current Pump & Flow Data: 268 Max 104 Chlorides mg/l 600.00 RIH from 3076' MD to 3300' MD, break circulation to clean drillstring. Drop dart. Pressure up to 500PSI, hold for 1 rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time ------ (max)(current) 2108 0 Cly 19657 Set AtSize 45.5 L-80 Grade 10.75'' 907-670-4906Unit Phone: 256 Hilary Garney Maximum Report By:Logging Engineers:Hilary Garney/Kyle Wiseman 1511 0 - - Units* Casing Summary Lithology (%) 30 MBT - pH 1.131 0 350 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth -55 C-5n - - C-2 282 in 0 -Minimum Depth Time: 68.5bbls of cement. POOH from 3226' MD to 2480' MD, dropped wiper ball and CBU. Monitored well, static. POOH from 2480' MD 23 7800' 7800' 0' Max @ ft Current -- Date: Avg to - Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gas Summary 0 974 240 (current) D. Coates/B. Finkbiner ShClyst TuffGvlCoal cP 15 4975' 9.875 1.035 Footage 42.70 Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 P/U BHA #3 PV 24 hr Max Weight 172 Hours C-3 00 CementCht Silt C-4i C-4n YP (lb/100ft2) 10.20 329627 140.0 PDC LSND 8.77800'30 Depth in / out Mud Type Lst Type Average --Background (max) Trip - - Avg Min Comments RPM ECD (ppg) ml/30min Tools - API FL Chromatograph (ppm) 14.02825' 7800' WOB Surface 100% Gas In Air=10,000 Units-Connection 1543 3 - 0 bbls lost for the day to surface. L/D 33 jts of 3.5" tubing. BOP test. M/U BHA #3. SDL crew calibrated and tested gas equipment for redrill. 2659' Condition 1-3-LT-N-X-I-BT-TD Bit # 2 13.0 9.875 11.30 PDC 11.30 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Morning Report Report # 20 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough ROP ROP (ft/hr) 4.23 @ Mud Data Depth 12-Oct-2015 12:00 AM Current Pump & Flow Data: - Max 127 Chlorides mg/l 460.00 Circ @ 4 BPM slowing to 1.5 BPM. Pumped 23.6 bbl Hi-Vis Gel pill. CBU @ 6 BPM. R/U cementers and pumped rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Finished P/U BHA#3, RIH to 1661' MD and shallow hole tested tools. Cont to RIH to 2642' MD and began to wash rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 800.00 5 13-Oct-2015 12:00 AM Current Pump & Flow Data: 1900 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 21 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 141 Report For: Condition 1-3-LT-N-X-I-BT-TD Bit # 2 9.0 9.875 10.00 PDC 10.00 Size 3 - 0 bbls lost for the day Dropped ball and opened reamer. Drill ahead to 2970' MD, circ and cond, C/O RCD bearing. Cont to drill ahead. 2659' 100% Gas In Air=10,000 Units-Connection 24 Tools Telescope, Ecoscope API FL Chromatograph (ppm) 14.02825' 7800' WOB Surface Avg Min Comments RPM ECD (ppg) ml/30min 50Background (max) Trip Average - Mud Type Lst Type 140.0 PDC LSND 5.836 Depth in / out YP (lb/100ft2) 9.90 0616 00 CementCht Silt C-4i C-4n 24 hr Max Weight 17 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 Drilling Ahead PV 4975' 9.875 1.035 Footage 42.70 D. Coates/A. Lundale ShClyst TuffGvlCoal cP 16 Gas Summary 0 21 49 (current) Avg to2815' Yesterday's Depth: Current Depth: 24 Hour Progress: 116.0 Flow In (gpm) Flow In (spm) 2815' 3700' 885' Max @ ft Current 3629'87.0 Date: Time: down to TOC @ 2642' MD. Drilled out cement plug to KOP of 2952' MD. Circ and Cond. Pull trip nipple and installl RCD bearing. 54 in 0 2862'Minimum Depth C-5n 2949' 98.0 C-2 252 SPP (psi) Gallons/stroke TFABit Type Depth 4.560 MBT 3700' pH 1.131 0 46 0 Siltst 736 174 Units* Casing Summary Lithology (%) 105455 0 907-670-4906Unit Phone: 40 Hilary Garney Maximum Report By:Logging Engineers:Hilary Garney/Kyle Wiseman Set AtSize 45.5 L-80 Grade 10.75'' (max)(current) 132 0 Cly 24276 Bottoms Up Time 58.28 0 264667.29 9.01 15 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 78 0 4278879 23 (max)(current) 5141 0 Cly 332607 Set AtSize 45.5 L-80 Grade 10.75'' 907-670-4906Unit Phone: 130 Hilary Garney Maximum Report By:Logging Engineers:Hilary Garney/Kyle Wiseman 5102 147 800 189 Units* Casing Summary Lithology (%) 0 MBT 5221' pH 1.131 0 327 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 14.852 C-5n 4748' 110.0 C-2 3322 in 2 3703'Minimum Depth Time: 3322 U observed. Cont to drill ahead. Tightened clamp on RCD mounting tool. Cont to drill ahead. 58 3700' 5221' 1521' Max @ ft Current 4299'92.0 Date: Avg to2815' Yesterday's Depth: Current Depth: 24 Hour Progress: 158.0 Flow In (gpm) Flow In (spm) Gas Summary 0 823 145 (current) D. Coates/A. Lundale ShClyst TuffGvlCoal cP 16 4975' 9.875 1.035 Footage 42.70 Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 Drilling Ahead PV 24 hr Max Weight 15 Hours C-3 00 CementCht Silt C-4i C-4n YP (lb/100ft2) 9.90 000 140.0 PDC LSND 4.55028'33 Depth in / out Mud Type Lst Type Average -50Background (max) Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools Telescope, Ecoscope API FL Chromatograph (ppm) 14.02825' 7800' WOB Surface 100% Gas In Air=10,000 Units98Connection 2173 3 - 50 bbls lost for the day 2659' Condition 1-3-LT-N-X-I-BT-TD Bit # 2 9.5 9.875 10.00 PDC 10.00 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 141 Report For: Morning Report Report # 22 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough ROP ROP (ft/hr) 4.23 @ Mud Data Depth 14-Oct-2015 12:00 AM Current Pump & Flow Data: 2783 Max 0 Chlorides mg/l 700.00 Cont to drill ahead to 4747' MD. During connection, observed MPD choke pressure at 97 PSI, CBU, Max gas of rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 78.27 0 573287.28 9.01 30 (max)(current) 3775 0 Cly 61833 Set AtSize 45.5 L-80 Grade 10.75'' 907-670-4906Unit Phone: 95 Hilary Garney Maximum Report By:Logging Engineers:Hilary Garney/Kyle Wiseman 14842 29 803 190 Units* Casing Summary Lithology (%) 45 MBT 6720' pH 1.131 0 152 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 19.548 C-5n 6670' 80.0 C-2 728 in 2 5946'Minimum Depth Time: 150 5221' 6720' 1499' Max @ ft Current 5863'91.0 Date: Avg to2815' Yesterday's Depth: Current Depth: 24 Hour Progress: 206.0 Flow In (gpm) Flow In (spm) Gas Summary 0 489 94 (current) D. Coates/A. Lundale ShClyst TuffGvlCoal cP 14 4975' 9.875 1.035 Footage 42.70 Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 Drilling Ahead PV 24 hr Max Weight 635 Hours C-3 00 CementCht Silt C-4i C-4n YP (lb/100ft2) 9.50 199923 140.0 PDC LSND 4.566545'28 Depth in / out Mud Type Lst Type Average -125Background (max) Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools Telescope, Ecoscope API FL Chromatograph (ppm) 14.02825' 7800' WOB Surface 100% Gas In Air=10,000 Units360Connection 1520 3 - 120 bbls lost for the day 2659' Condition 1-3-LT-N-X-I-BT-TD Bit # 2 10.0 9.875 10.00 PDC 10.00 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 141 Report For: Morning Report Report # 23 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough ROP ROP (ft/hr) 4.23 @ Mud Data Depth 15-Oct-2015 12:00 AM Current Pump & Flow Data: 2983 Max 326 Chlorides mg/l 550.00 Cont to drill ahead to 5956' MD. CBU. C/O RCD bearing. Drill ahead. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 631 0 6301754123 38 (max)(current) 9082 0 Cly 199391 Set AtSize 45.5 L-80 Grade 10.75'' 907-670-4906Unit Phone: 385 Elijah Callan Maximum Report By:Logging Engineers:Elijah Callan/Kyle Wiseman 31208 26 702 166 Units* Casing Summary Lithology (%) 155 MBT 7896' pH 1.131 0 522 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 16.844 C-5n 7877' 0.0 C-2 2063 in 0 6695'Minimum Depth Time: bearing. Drilled ahead to 7,896' MD. (6,223' TVD). Break connection, drop ball to close Rhino reamer, pressure confirmed closed. 368 6720' 7896' 1176' Max @ ft Current 7654'50.0 Date: Avg to6720' Yesterday's Depth: Current Depth: 24 Hour Progress: 138.0 Flow In (gpm) Flow In (spm) Gas Summary 0 2091 398 (current) D. Coates/A. Lundale ShClyst TuffGvlCoal cP 12 4975' 9.875 1.035 Footage 53.25 4645' 42.70 Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 Circulating PV 24 hr Max Weight 2118 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.50 134618137 140.0 PDC LSND 3.87896'25 Depth in / out Mud Type Lst Type Average -210Background (max) Trip 10.7011.09 Avg Min Comments RPM ECD (ppg) ml/30min Tools Telescope, Ecoscope API FL Chromatograph (ppm) 14.02825' 7800' WOB Surface 100% Gas In Air=10,000 Units1412Connection 5012 3 - 115 bbls lost for the day at 7,895" MD (6,187' TVD). Strip out of hole from 7,896' MD to 7,338' MD. Circulate bottoms up at 700 gpm. Shut in MPD, holding 60 psi on choke. Pressure built up from to 71 PSI. Decision was made to circulate bottoms up and SPR 2659' Condition 1-3-LT-N-X-I-BT-TD Bit # 2 12.3 9.875 10.30 PDC 10.30 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 12.30 Doyon 141 Report For: Morning Report Report # 24 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough ROP ROP (ft/hr) 4.23 @ Mud Data Depth 16-Oct-2015 12:00 AM Current Pump & Flow Data: 2731 Max 1322 Chlorides mg/l 480.00 Drilled 9.875" intermediate section from 6,720' MD to 7,269'. Shot MWD Survey and changed out the RCD rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 795 086859 (max)(current) Intermediate 6910 0 Cly 106059 Set AtSize 45.5 L-80 Grade 10.75'' 907-670-4906Unit Phone: 140 Michael LaDouceur Maximum Report By:Logging Engineers:Michael LaDouceur/Kyle Wiseman 2780 26 7.63'' Units* Casing Summary Lithology (%) 28 L-80 MBT pH 1.131 0 378 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 18.360 C-5n 0.0 C-2 1221 in 0Minimum Depth Time: Laid Down BHA. Began to Run 7 5/8" Casing downhole to 1296' MD. 40 7896' 7896' 0' Max @ ft Current 0.0 Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) Gas Summary 0 1441 276 (current) D. Coates/A. Lundale ShClyst TuffGvlCoal cP 13 4975' 9.875 1.035 Footage 53.25 4645' 42.70 Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 Tripping in Intermediate Casing PV 24 hr Max 29.0 Weight 225 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 10.00 3612137 140.0 PDC LSND 4.07896'25 Depth in / out Mud Type Lst Type Average 12216Background (max) Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 14.02825' 7800' WOB Surface 100% Gas In Air=10,000 Units-Connection 3841 3 - 0 bbls lost for the day 2659' Condition 1-3-LT-N-X-I-BT-TD Bit # 2 13.0 9.875 10.60 PDC 10.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 141 Report For: Morning Report Report # 25 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough ROP ROP (ft/hr) 4.23 @ Mud Data Depth 17-Oct-2015 12:00 AM Current Pump & Flow Data: Max 179 Chlorides mg/l 500.00 Continued to trip out of the hole to 7,273' MD . Weighted up mud to 10.6ppg. Tripped out of hole to Surface. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Ran 7 5/8" Casing downhole from 1296' MD and landed it at 7890' MD. Mud losses were experienced beginning at rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 560.00 146 18-Oct-2015 12:00 AM Current Pump & Flow Data: Max 1-1-WT-N-X-I-NA-TD ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 26 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 141 Report For: Condition 1-3-LT-N-X-I-BT-TD Bit # 2 13.0 9.875 10.60 PDC 10.60 Size 3 - 1228 bbls lost for the day during Stage one or two of the cement job. Throughout the cement job gas remained consistent with an average of 158 units and a completed 370 bbls more were lost down hole. Stage 2 resulted in a loss of 335 bbls more. Minimal returns were received back units. While prepping and circulating for cement job, 308 bbls more were lost downhole. When Stage one of the cement job was 7891' 2659' 100% Gas In Air=10,000 Units-Connection 506 Tools API FL Chromatograph (ppm) 17 14.02825' 7800' WOB Surface Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max) Trip Average 203 Mud Type Lst Type 140 140.0 PDC LSND 4.0 2815' 7896'24 7896' Depth in / out YP (lb/100ft2) 9.50 3310535 00 CementChtSilt C-4i C-4n 24 hr Max 29.0 Weight 150 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 WOC PV 4975' 9.875 1.035 Footage 53.25 4645' 42.70 D. Coates/A. Lundale ShClyst TuffGvlCoal cP 12 Gas Summary 0 271 75 (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) 7896' 7896' 0' Max @ ft Current 0.0 Date: Time: 2896' MD. Losses continued till casing was landed and experienced a loss of 215 bbls total during the trip. Max trip gas was 203 66 max of 370 units. in 0Minimum Depth C-5n 0.0 C-2 370 SPP (psi) Gallons/stroke TFABit Type Depth 18.054 L-80 MBT pH 1.131 0 80 0 Siltst 7.63'' Units* Casing Summary Lithology (%) 286983 20 907-670-4906Unit Phone: 67 Michael LaDouceur Maximum Report By:Logging Engineers:Michael LaDouceur/Kyle Wiseman Set AtSize 45.5 L-80 Grade 10.75'' (max)(current) Intermediate 599 0 Cly 42552 Bottoms Up Time 3633630 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 3633630 (max)(current) Intermediate 0 0 Cly 0 Set AtSize 45.5 L-80 Grade 10.75'' 907-670-4906Unit Phone: 0 Michael LaDouceur Maximum Report By:Logging Engineers:Michael LaDouceur/Kyle Wiseman 0 0 7.63'' Units* Casing Summary Lithology (%) 0 L-80 MBT pH 1.131 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 18.364 C-5n 0.0 C-2 0 in 0Minimum Depth Time: Drill pipe from 5" to 4". 0 7896' 7896' 0' Max @ ft Current 0.0 Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) D. Coates/A. Lundale ShClyst TuffGvlCoal cP 15 4975' 9.875 1.035 Footage 53.25 4645' 42.70 Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 Drill Pipe Management PV 24 hr Max 29.0 Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.50 000 140 140.0 PDC LSND 4.0 2815' 7896'22 7896' Depth in / out Mud Type Lst Type Average -0Background (max) Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 17 14.02825' 7800' WOB Surface 100% Gas In Air=10,000 Units-Connection 0 3 0 bbls lost for the day 7891' 2659' Condition 1-3-LT-N-X-I-BT-TD Bit # 2 13.0 9.875 10.60 PDC 10.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 141 Report For: Morning Report Report # 27 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough 1-1-WT-N-X-I-NA-TD ROP ROP (ft/hr) 4.23 @ Mud Data Depth 19-Oct-2015 12:00 AM Current Pump & Flow Data: Max 0 Chlorides mg/l 600.00 Waited On Cement. MPD changed RCD Bearing. Changed out Mud in pits for Production section. Change out rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 3633630 (max)(current) Intermediate 0 0 Cly 0 Set AtSize 45.5 L-80 Grade 10.75'' 907-670-4906Unit Phone: 0 Michael LaDouceur Maximum Report By:Logging Engineers:Michael LaDouceur/Kyle Wiseman 0 0 7.63'' Units* Casing Summary Lithology (%) 0 L-80 MBT pH 1.131 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 18.371 C-5n 0.0 C-2 0 in 0Minimum Depth Time: 0 7896' 7896' 0' Max @ ft Current 0.0 Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) D. Coates/A. Lundale ShClyst TuffGvlCoal cP 14 4975' 9.875 1.035 Footage 53.25 4645' 42.70 Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 BOPE Test PV 24 hr Max 29.0 Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.50 000 140 140.0 PDC LSND 4.0 2815' 7896'25 7896' Depth in / out Mud Type Lst Type Average -0Background (max) Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 17 14.02825' 7800' WOB Surface 100% Gas In Air=10,000 Units-Connection 0 3 0 bbls lost for the day 7891' 2659' Condition 1-3-LT-N-X-I-BT-TD Bit # 2 13.0 9.875 10.60 PDC 10.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 141 Report For: Morning Report Report # 28 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough 1-1-WT-N-X-I-NA-TD ROP ROP (ft/hr) 4.23 @ Mud Data Depth 20-Oct-2015 12:00 AM Current Pump & Flow Data: Max 0 Chlorides mg/l 580.00 Pick Up 4" Drill pipe. Test MPD equipment. Test BOPE. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Complete BOPE Test. Pick up BHA. TIH to 6000' MD . rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 580.00 0 21-Oct-2015 12:00 AM Current Pump & Flow Data: Max 1-1-WT-N-X-I-NA-TD ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 29 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 141 Report For: Condition 1-3-LT-N-X-I-BT-TD Bit # 2 13.0 9.875 10.60 PDC 10.60 Size 3 0 bbls lost for the day 7891' 2659' 100% Gas In Air=10,000 Units-Connection 0 Tools API FL Chromatograph (ppm) 17 14.02825' 7800' WOB Surface Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max) Trip Average - Mud Type Lst Type 140 140.0 PDC LSND 4.0 2815' 7896'30 7896' Depth in / out YP (lb/100ft2) 10.50 000 00 CementChtSilt C-4i C-4n 24 hr Max 29.0 Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 TIH PV 4975' 9.875 1.035 Footage 53.25 4645' 42.70 D. Coates/A. Lundale ShClyst TuffGvlCoal cP 9 Gas Summary 0 0 0 (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) 7896' 7896' 0' Max @ ft Current 0.0 Date: Time: 0 in 0Minimum Depth C-5n 0.0 C-2 0 SPP (psi) Gallons/stroke TFABit Type Depth 18.349 L-80 MBT pH 1.131 0 0 0 Siltst 7.63'' Units* Casing Summary Lithology (%) 00 0 907-670-4906Unit Phone: 0 Michael LaDouceur Maximum Report By:Logging Engineers:Michael LaDouceur/Kyle Wiseman Set AtSize 45.5 L-80 Grade 10.75'' (max)(current) Intermediate 0 0 Cly 0 Bottoms Up Time 3633630 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 3633630 (max)(current) Intermediate 0 0 Cly 0 Set AtSize 45.5 L-80 Grade 10.75'' 907-670-4906Unit Phone: 0 Michael LaDouceur Maximum Report By:Logging Engineers:Michael LaDouceur/Kyle Wiseman 0 0 7.63'' Units* Casing Summary Lithology (%) 0 L-80 MBT pH 1.131 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 18.352 C-5n 0.0 C-2 0 in 0Minimum Depth Time: 0 7896' 7896' 0' Max @ ft Current 0.0 Date: Avg to7896' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) D. Coates/A. Lundale ShClyst TuffGvlCoal cP 15 4975' 9.875 1.035 Footage 53.25 4645' 42.70 Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 Install RCD Bearing PV 24 hr Max 29.0 Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 10.50 000 140 140.0 PDC LSND 4.0 2815' 7896'37 7896' Depth in / out Mud Type Lst Type Average -0Background (max) Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools Sonic, Gamma, Resistivity, Density, ECD API FL Chromatograph (ppm) 17 14.02825' 7800' WOB Surface 100% Gas In Air=10,000 Units-Connection 0 3 0 bbls lost for the day 7891' 2659' Condition 1-3-LT-N-X-I-BT-TD Bit # 2 13.0 9.875 10.60 PDC 10.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 141 Report For: Morning Report Report # 30 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough 1-1-WT-N-X-I-NA-TD ROP ROP (ft/hr) 4.23 @ Mud Data Depth 22-Oct-2015 12:00 AM Current Pump & Flow Data: Max 0 Chlorides mg/l 540.00 TIH to 7896' MD. Clean Out Hole. Begin to install RCD bearing. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Drill from 7896' MD to 7916' MD. Performed FIT to 14.5 ppg. Displace mud from LSND to FloThru. Drilled ahead from rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 156500.00 6168 23-Oct-2015 12:00 AM Current Pump & Flow Data: 2480 Max 1-1-WT-N-X-I-NA-TD ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 31 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.98 Doyon 141 Report For: Condition 1-3-LT-N-X-I-BT-TD Bit # 2 15.0 9.875 10.50 PDC 10.50 Size 3 0 bbls lost for the day gains were seen during these events. 7891' 2659' 100% Gas In Air=10,000 Units9906Connection 28358 Tools Sonic, Gamma, Resistivity, Density, ECD API FL Chromatograph (ppm) 17 14.02825' 7800' WOB Surface 7.0011.79 Avg Min Comments RPM ECD (ppg) ml/30min 652Background (max) Trip Average - Mud Type Lst Type 140 140.0 PDC FloThru 2.4 2815' 8443'30 7896' Depth in / out YP (lb/100ft2) 9.60 5231709410 1650 CementChtSilt C-4i C-4n 24 hr Max 29.0 Weight 14266 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 Drill Ahead PV 4975' 9.875 1.035 Footage 53.25 4645' 42.70 R. Wall/A. Lundale ShClyst TuffGvlCoal cP 20 Gas Summary 13 7320 1708 (current) Avg to7896' Yesterday's Depth: Current Depth: 24 Hour Progress: 145.0 Flow In (gpm) Flow In (spm) 7896' 8615' 719' Max @ ft Current 7898'43.0 Date: Time: 7916' MD to 8615' MD. Max gas was seen at 8150' MD and 8481' MD where the equipment maxed out at 9906 units. No Pit Volume 2612 in 5 8090'Minimum Depth C-5n 8481' 77.0 C-2 9906 SPP (psi) Gallons/stroke TFABit Type Depth 1.662 L-80 MBT pH 1.131 122 3194 18 Siltst 7.63'' 250 59 Units* Casing Summary Lithology (%) 722173449 1351 907-670-4906Unit Phone: 7477 Michael LaDouceur Maximum Report By:Logging Engineers:Michael LaDouceur/Kyle Wiseman Set AtSize 45.5 L-80 Grade 10.75'' (max)(current) Intermediate 62527 187 Cly 636624 Bottoms Up Time 305.58 0 2578394.35 88.77 44 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 307.03 0 3051413.27 106.24 53 (max)(current) Intermediate 77694 488 Cly 778233 Set AtSize 45.5 L-80 Grade 10.75'' 907-670-4906Unit Phone: 2119 Michael LaDouceur Maximum Report By:Logging Engineers:Michael LaDouceur/Kyle Wiseman 504050 3483 7.63'' 250 59 Units* Casing Summary Lithology (%) 2669 L-80 MBT pH 1.131 316 3665 41 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 1.761 C-5n 9680' 93.0 C-2 9917 in 158 8979'Minimum Depth Time: 10.7 ppg @ 9230' MD to try to reduce gas levels. After mud weight increased gas level diminished as expected. No gains 6780 8615' 10270' 1655' Max @ ft Current 9996'69.1 Date: Avg to7896' Yesterday's Depth: Current Depth: 24 Hour Progress: 162.7 Flow In (gpm) Flow In (spm) Gas Summary 58 8434 2078 (current) R. Wall/A. Lundale ShClyst TuffGvlCoal cP 23 4975' 9.875 1.035 Footage 53.25 4645' 42.70 Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 Drill Ahead PV 24 hr Max 29.0 Weight 49941 Hours C-3 70163 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.50 250763211616 140 140.0 PDC FloThru 2.5 2815' 10113'33 7896' Depth in / out Mud Type Lst Type Average -1384Background (max) Trip 11.8412.20 Avg Min Comments RPM ECD (ppg) ml/30min Tools Sonic, Gamma, Resistivity, Density, ECD API FL Chromatograph (ppm) 17 14.02825' 7800' WOB Surface 100% Gas In Air=10,000 Units9906Connection 33457 3 0 bbls lost for the day were seen during gas events. Changed Chromatographs due to moisture build up in the equipment. 7891' 2659' Condition 1-3-LT-N-X-I-BT-TD Bit # 2 16.5 9.875 10.75 PDC 10.75 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 12.37 Doyon 141 Report For: Morning Report Report # 32 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough 1-1-WT-N-X-I-NA-TD ROP ROP (ft/hr) 4.23 @ Mud Data Depth 24-Oct-2015 12:00 AM Current Pump & Flow Data: 2480 Max 26810 Chlorides mg/l 16500.00 Drill from 8615' MD to 10270' MD. Gas equipment was maxed out for majority of the day. Increased Mud weight to rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 352.12 0 3508537112.81 59 (max)(current) Intermediate 70450 41 Cly 706146 Set AtSize 45.5 L-80 Grade 10.75'' 907-670-4906Unit Phone: 1942 Michael LaDouceur Maximum Report By:Logging Engineers:Michael LaDouceur/Kyle Wiseman 397650 401 7.63'' 250 59 Units* Casing Summary Lithology (%) 2345 L-80 MBT pH 1.131 21 30421 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 1.864 C-5n 10374' 117.0 C-2 9904 in 2 10416'Minimum Depth Time: seen Between 10660' MD to 11000' MD. 1 bbl loss was seen between 11000' MD and 11840' MD. Total Losses for the day are 6127 10270' 11840' 1570' Max @ ft Current 11508'67.0 Date: Avg to7896' Yesterday's Depth: Current Depth: 24 Hour Progress: 176.7 Flow In (gpm) Flow In (spm) Gas Summary 0 3554 1858 (current) R. Wall/A. Lundale ShClyst TuffGvlCoal cP 22 4975' 9.875 1.035 Footage 53.25 4645' 42.70 Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 Drill Ahead PV 24 hr Max 29.0 Weight 38351 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.50 200255921380 140 140.0 PDC FloThru 2.2 2815' 11600'42 7896' Depth in / out Mud Type Lst Type Average -3174Background (max) Trip 12.1212.40 Avg Min Comments RPM ECD (ppg) ml/30min Tools Sonic, Gamma, Resistivity, Density, ECD API FL Chromatograph (ppm) 17 14.02825' 7800' WOB Surface 100% Gas In Air=10,000 Units9904Connection 33457 3 28 bbls lost for the day 28 bbls. Changed Chromatographs due to suspected moisture build up in the equipment. 7891' 2659' Condition 1-3-LT-N-X-I-BT-TD Bit # 2 16.8 9.875 10.80 PDC 10.80 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 12.61 Doyon 141 Report For: Morning Report Report # 33 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough 1-1-WT-N-X-I-NA-TD ROP ROP (ft/hr) 4.23 @ Mud Data Depth 25-Oct-2015 12:00 AM Current Pump & Flow Data: 2480 Max 22740 Chlorides mg/l 160000.00 Drilled from 10270' MD to 11840' MD. Gas equipment was maxed out for majority of the day. Losses of 27 bbls were rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Drilled from 11840' MD to 12358' MD. Changed out RCD bearing. Drilled from, 12358' MD to 13208' MD. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 125k 16860 26-Oct-2015 12:00 AM Current Pump & Flow Data: 3151 Max 1-1-WT-N-X-I-NA-TD ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 34 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 12.76 Doyon 141 Report For: Condition 1-3-LT-N-X-I-BT-TD Bit # 2 17.0 9.875 10.80 PDC 10.80 Size 3 12 bbls lost for the day 7891' 2659' 100% Gas In Air=10,000 Units3324Connection 37915 Tools Sonic, Gamma, Resistivity, Density, ECD API FL Chromatograph (ppm) 17 14.02825' 7800' WOB Surface 12.3912.58 Avg Min Comments RPM ECD (ppg) ml/30min 3440Background (max) Trip Average - Mud Type Lst Type 140 140.0 PDC FloThru 2.2 2815' 13208'34 7896' Depth in / out YP (lb/100ft2) 9.60 144352661316 63120 CementChtSilt C-4i C-4n 24 hr Max 29.0 Weight 30927 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 Drill Ahead PV 4975' 9.875 1.035 Footage 53.25 4645' 42.70 R. Wall/A. Lundale ShClyst TuffGvlCoal cP 26 Gas Summary 38 10589 2507 (current) Avg to7896' Yesterday's Depth: Current Depth: 24 Hour Progress: 154.0 Flow In (gpm) Flow In (spm) 11840' 13208' 1368' Max @ ft Current 12741'105.0 Date: Time: Experienced an average of 5187 units throughout the day. Total losses of 12 bbls were seen. 5187 in 96 12857'Minimum Depth C-5n 12350' 129.0 C-2 9800 SPP (psi) Gallons/stroke TFABit Type Depth 1.863 L-80 MBT pH 1.131 221 4615 32 Siltst 7.63'' 250 59 Units* Casing Summary Lithology (%) 2178334299 2045 907-670-4906Unit Phone: 2530 Eric Andrews Maximum Report By:Logging Engineers:Michael LaDouceur/Eric Andrews Set AtSize 45.5 L-80 Grade 10.75'' (max)(current) Intermediate 71217 302 Cly 628858 Bottoms Up Time 391.4 0 3913579137.25 67 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap:Drilled from 12358' MD to TD, called at 13505' MD. Started taking losses at 13300' MD. Total Daily rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 127k 15450 27-Oct-2015 12:00 AM Current Pump & Flow Data: 3151 Max 1-1-WT-N-X-I-NA-TD ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 35 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 12.73 Doyon 141 Report For: Condition 1-3-LT-N-X-I-BT-TD Bit # 2 17.0 9.875 10.80 PDC 10.80 Size 3 368 bbls lost for the day test. stand and began cirulating bottoms up. Continued monitoring gas and pit levels while rig performed a draw down 7891' 2659' 100% Gas In Air=10,000 Units9912Connection 31709 Tools Sonic, Gamma, Resistivity, Density, ECD API FL Chromatograph (ppm) 17 14.02825' 7800' WOB Surface 12.5012.64 Avg Min Comments RPM ECD (ppg) ml/30min 1000Background (max) Trip Average - Mud Type Lst Type 140 140.0 PDC FloThru 2.7 2815' 13504'34 7896' Depth in / out YP (lb/100ft2) 9.50 132349051216 5631424 CementChtSilt C-4i C-4n 24 hr Max 29.0 Weight 26693 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 POOH PV 4975' 9.875 1.035 Footage 53.25 4645' 42.70 R. Wall/A. Lundale ShClyst TuffGvlCoal cP 25 Gas Summary 471 9434 2176 (current) Avg to7896' Yesterday's Depth: Current Depth: 24 Hour Progress: 138.2 Flow In (gpm) Flow In (spm) 13208' 13505' 297' Max @ ft Current 13349'91.2 Date: Time: Losses: 368 bbls. After reaching TD we continued reading high gas, the max gas being 9912 units. Racked back a 4489 in 658 13474'Minimum Depth C-5n 13208' 0.0 C-2 8827 SPP (psi) Gallons/stroke TFABit Type Depth 1.663 L-80 MBT 13505' pH 1.131 2731 3940 465 Siltst 7.63'' 250 59 Units* Casing Summary Lithology (%) 1957293002 31697 907-670-4906Unit Phone: 2250 Eric Andrews Maximum Report By:Logging Engineers:Michael LaDouceur/Eric Andrews Set AtSize 45.5 L-80 Grade 10.75'' (max)(current) Intermediate 54540 3456 Cly 589890 Bottoms Up Time 393.26 0 3905531137.93 66 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 256.41 0 2546565.25 344.04 53 (max)(current) Intermediate 55524 103 Cly 593216 Set AtSize 45.5 L-80 Grade 10.75'' 907-670-4906Unit Phone: 2144 Eric Andrews Maximum Report By:Logging Engineers:Michael LaDouceur/Eric Andrews 21717 784 7.63'' 203 48 Units* Casing Summary Lithology (%) 245 L-80 MBT 13505' pH 1.131 87 3471 25 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 1.659 C-5n 13505' - C-2 8703 in 54 13505'Minimum Depth Time: down a stand and began circulating mud and working the pipe. Continue pulling pipe while pumping from 100958’ to 432 13505' 13505' 0' Max @ ft Current -- Date: Avg to7896' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gas Summary 53 8349 2089 (current) R. W all/A. Lundale ShClyst TuffGvlCoal cP 22 4975' 9.875 1.035 Footage 53.25 4645' 42.70 Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 POOH PV 24 hr Max 29.0 Weight 1954 Hours C-3 7897 CementCht Silt C-4i C-4n YP (lb/100ft2) 9.40 412764305 140 140.0 PDC FloThru 2.7 2815' 13504'33 7896' Depth in / out Mud Type Lst Type Average 970129Background (max) Trip - - Avg Min Comments RPM ECD (ppg) ml/30min Tools Sonic, Gamma, Resistivity, Density, ECD API FL Chromatograph (ppm) 17 14.02825' 7800' WOB Surface 100% Gas In Air=10,000 Units-Connection 26945 3 437 bbls lost for the day 8507 'MD. Experienced losses of about 20 bbls per hour throughout the day for a total of 437 Barrels. 7891' 2659' Condition 1-3-LT-N-X-I-BT-TD Bit # 2 17.0 9.875 10.80 PDC 10.80 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Morning Report Report # 36 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough 1-1-WT-N-X-I-NA-TD ROP ROP (ft/hr) 4.23 @ Mud Data Depth 28-Oct-2015 12:00 AM Current Pump & Flow Data: 2100 Max 1283 Chlorides mg/l 121k Started pulling out of the hole from 13298’ MD to 10119’ MD; where we encountered a tight spot. Dropped rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Continue back reaming out of hole through various tight spots. Lost an average of about 40 barrels per rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 128k 147 29-Oct-2015 12:00 AM Current Pump & Flow Data: 1150 Max 1-1-WT-N-X-I-NA-TD ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 37 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Condition 1-3-LT-N-X-I-BT-TD Bit # 2 17.0 9.875 10.80 PDC 10.80 Size 3 1030 bbls lost for the day 7891' 2659' 100% Gas In Air=10,000 Units-Connection 2890 Tools Sonic, Gamma, Resistivity, Density, ECD API FL Chromatograph (ppm) 17 14.02825' 7800' WOB Surface - - Avg Min Comments RPM ECD (ppg) ml/30min 9Background (max) Trip Average 1403 Mud Type Lst Type 140 140.0 PDC FloThru 2.6 2815' 13504'33 7896' Depth in / out YP (lb/100ft2) 9.50 508237 310 CementCht Silt C-4i C-4n 24 hr Max 29.0 Weight 351 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 POOH PV 4975' 9.875 1.035 Footage 53.25 4645' 42.70 R. W all/A. Lundale ShClyst TuffGvlCoal cP 23 Gas Summary 0 766 202 (current) Avg to7896' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 13505' 13505' 0' Max @ ft Current -- Date: Time: hour throughout the day for a total of 1030 barrels lost. 127 in 8 -Minimum Depth C-5n - - C-2 1403 SPP (psi) Gallons/stroke TFABit Type Depth 1.663 L-80 MBT 13505' pH 1.131 5 319 0 Siltst 7.63'' 89 21 Units* Casing Summary Lithology (%) 255847 53 907-670-4906Unit Phone: 223 Eric Andrews Maximum Report By:Logging Engineers:Michael LaDouceur/Eric Andrews Set AtSize 45.5 L-80 Grade 10.75'' (max)(current) Intermediate 8070 0 Cly 127639 Bottoms Up Time 242.45 0 2407567.68 82.5 114 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 242.45 0 2407567.68 82.5 114 (max)(current) Intermediate 3957 0 Cly 93195 Set AtSize 45.5 L-80 Grade 10.75'' 907-670-4906Unit Phone: 95 Tyler Dretke Maximum Report By:Logging Engineers:Eric Andrews/Tyler Dretke 7970 0 7.63'' - - Units* Casing Summary Lithology (%) 15 L-80 MBT 13505' pH 1.131 0 127 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 0.047 C-5n 8044' - C-2 903 gas has dropped to an average of 10-20 units. in 0 -Minimum Depth Time: Circulation was reestablished at 7900'. After pulling into the shoe, the rig circulated bottoms up and spotted a pill. 78 peak, gas dropped to a background of 20-30 units before peaking at 787 units and 429 units. Since pulling into the shoe, 13505' 13505' 0' Max @ ft Current -- Date: Avg to7896' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gas Summary 0 323 84 (current) R. W all/A. Lundale ShClyst TuffGvlCoal cP 9 4975' 9.875 1.035 Footage 53.25 4645' 42.70 Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 - - POOH PV 24 hr Max 29.0 Weight 408 Hours C-3 30 CementCht Silt C-4i C-4n YP (lb/100ft2) 10.10 174513 140 140.0 PDC FloThru - 2815' 13504'/6236 18 7896' Depth in / out Mud Type Lst Type Average -0Background (max) Trip - - Avg Min Comments RPM ECD (ppg) ml/30min Tools Sonic, Gamma, Resistivity, Density, ECD API FL Chromatograph (ppm) 17 14.02825' 7800' WOB Surface 100% Gas In Air=10,000 Units-Connection 1237 3 275 bbls lost for the day The 903 units of gas observed while backreaming out of the hole correlates to the sands located at 8044'. Following that The well was displaced to a 12.6 brine. After observing that the well was static, the rig began pulling out of the hole. 7891' 2659' Condition 1-3-LT-N-X-I-BT-TD Bit # 2 20.0 9.875 12.60 PDC 12.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Morning Report Report # 38 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough 1-1-WT-N-X-I-NA-TD ROP ROP (ft/hr) 4.23 @ Mud Data Depth 30-Oct-2015 12:00 AM Current Pump & Flow Data: - Max 140 Chlorides mg/l 246k Continued to backream out of the hole. While backreaming, the hole packed off and lost circulation. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:The rig finished pulling out of the hole. After laying down the BHA, the casing equipment was rigged up. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 229K - 31-Oct-2015 12:00 AM Current Pump & Flow Data: - Max 1-1-WT-N-X-I-NA-TD ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 39 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Condition 1-1-WT-N-X-I-NA-TD Bit # 3 60.0 9.875 12.70 PDC 12.70 Size 4 130 bbls lost for the day test to ensure that the gas lines were free of obstructions was performed while tripping in the the hole. The test came back There were no notable gas peaks during throughout the day. Upon entering the shoe, gas dropped off significantly. A bag 7891' 2659' 100% Gas In Air=10,000 Units-Connection 5 Tools Sonic, Gamma, Resistivity, Density, ECD API FL Chromatograph (ppm) 7-18 172815' 7896' WOB Surface - - Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max) Trip Average - Mud Type Lst Type 80-150 140 PDC FloThru - 7896' 13504'/6236 17 13505' Depth in / out YP (lb/100ft2) 9.60 --- -- CementCht Silt C-4i C-4n 24 hr Max 29.0 Weight - Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 - - RIH w/ 4.5" Liner PV 4645' 6.75 0.482 Footage 70.41 5609' 53.25 R. W all/A. Lundale ShClyst TuffGvlCoal cP 9 Gas Summary - -- (current) Avg to7896' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 13505' 13505' 0' Max @ ft Current -- Date: Time: Began running the 4.5" lower completions liner as ordred. After 135 joints of 4.5" liner, began running in on 4" drill pipe. 1 good. in 0 -Minimum Depth C-5n - - C-2 8 SPP (psi) Gallons/stroke TFABit Type Depth 0.043 L-80 MBT 13505' pH 1.035 - 5 - Siltst 7.63'' - - Units* Casing Summary Lithology (%) -27 - 907-670-4906Unit Phone: - Tyler Dretke Maximum Report By:Logging Engineers:Eric Andrews/Tyler Dretke Set AtSize 45.5 L-80 Grade 10.75'' (max)(current) Intermediate 10 - Cly 235 Bottoms Up Time 242.45 0 2407567.68 82.5 114 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 242.45 0 2407567.68 82.5 114 (max)(current) Intermediate 466 - Cly 10057 Set AtSize 45.5 L-80 Grade 10.75'' 907-670-4906Unit Phone: - Tyler Dretke Maximum Report By:Logging Engineers:Eric Andrews/Tyler Dretke 747 - 7.63'' - - Units* Casing Summary Lithology (%) 0 L-80 MBT 13505' pH 1.035 - 6 - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 0.043 C-5n - - C-2 77 in 0 -Minimum Depth Time: out of the hole. 4 13505' 13505' 0' Max @ ft Current -- Date: Avg to7896' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gas Summary - 17 - (current) R. W all/A. Lundale ShClyst TuffGvlCoal cP 9 4645' 6.75 0.482 Footage 70.41 5609' 53.25 Ss (ppb Eq) C-1 C-5i AK-AM-0902772867 - - RIH w/ 4.5" Liner PV 24 hr Max 29.0 Weight 35 Hours C-3 -- CementCht Silt C-4i C-4n YP (lb/100ft2) 9.60 -1 - 80-150 140 PDC FloThru - 7896' 13504'/6236 17 13505' Depth in / out Mud Type Lst Type Average 770Background (max) Trip - - Avg Min Comments RPM ECD (ppg) ml/30min Tools Sonic, Gamma, Resistivity, Density, ECD API FL Chromatograph (ppm) 7-18 172815' 7896' WOB Surface 100% Gas In Air=10,000 Units-Connection 96 4 SDL was released at 1500 hours. 7891' 2659' Condition 1-1-WT-N-X-I-NA-TD Bit # 3 60.0 9.875 12.70 PDC 12.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Morning Report Report # 40 Customer: Well: Area: Location: Rig: 2S-04 ConocoPhillips Alaska, Inc Kuparuk North Slope Borough 1-1-WT-N-X-I-NA-TD ROP ROP (ft/hr) 4.23 @ Mud Data Depth 1-Nov-2015 12:00 AM Current Pump & Flow Data: - Max 9 Chlorides mg/l 229K Finished running in the hole with the 4.5" Completions liner on 4" drill pipe. Set the liner and began pulling rig Density (ppg) out (sec/qt) Viscosity Cor Solids % WELL INFORMATION Created On : Nov 06 2015 Customer :ConocoPhillips Alaska, Inc. Well Name :2S-04 Job Number :AK-XX-0902772867 Rig Name :Doyon 141 Field Name :Kuparuk River Unit Country :USA Survey Report SURVEY HEADER Survey data provided by Schlumberger. DIRECTIONAL SURVEY DATA Tie-in 0.00 0.00 0.00 0.00 0.00 N 0.00 E (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 27.50 0.00 0.00 27.50 0.00 N 0.00 E 0.00 0.00 78.00 0.30 241.15 78.00 0.06 S 0.12 W -0.06 0.59 170.00 0.45 266.98 170.00 0.20 S 0.69 W -0.20 0.24 263.00 0.52 264.61 262.99 0.26 S 1.47 W -0.26 0.08 355.00 0.64 262.29 354.99 0.37 S 2.40 W -0.37 0.13 447.00 0.58 275.81 446.98 0.39 S 3.37 W -0.39 0.17 476.76 0.31 285.28 476.74 0.35 S 3.60 W -0.35 0.94 567.94 0.04 243.25 567.92 0.30 S 3.86 W -0.30 0.31 660.98 1.43 217.97 660.95 1.23 S 4.61 W -1.23 1.50 696.02 2.12 219.06 695.98 2.08 S 5.28 W -2.08 1.97 757.33 2.58 214.47 757.23 4.10 S 6.78 W -4.10 0.81 853.64 3.59 211.81 853.40 8.45 S 9.60 W -8.45 1.06 948.89 4.60 201.35 948.41 14.54 S 12.56 W -14.54 1.31 1045.12 7.88 197.52 1,044.06 24.43 S 15.95 W -24.43 3.43 1140.42 10.66 202.74 1,138.11 38.79 S 21.33 W -38.79 3.04 1237.11 13.56 204.84 1,232.63 57.33 S 29.55 W -57.33 3.03 1332.94 17.82 206.38 1,324.87 80.67 S 40.79 W -80.67 4.47 1428.89 20.05 207.90 1,415.63 108.36 S 55.01 W -108.36 2.38 1525.28 19.63 209.48 1,506.29 137.06 S 70.71 W -137.06 0.71 1621.34 21.86 208.07 1,596.12 166.89 S 87.06 W -166.89 2.38 1715.89 22.82 207.21 1,683.57 198.73 S 103.73 W -198.73 1.07 1811.64 25.43 208.33 1,770.95 233.34 S 121.98 W -233.34 2.77 1909.25 28.51 211.22 1,857.94 271.72 S 144.01 W -271.72 3.43 2003.73 29.77 212.20 1,940.46 310.85 S 168.19 W -310.85 1.43 2098.75 32.65 215.49 2,021.73 351.70 S 195.65 W -351.70 3.52 2195.36 35.25 219.32 2,101.87 394.50 S 228.46 W -394.50 3.48 2290.95 38.19 223.06 2,178.49 437.44 S 266.13 W -437.44 3.86 2387.10 40.65 224.33 2,252.77 481.57 S 308.31 W -481.57 2.69 2483.15 44.04 225.78 2,323.75 527.25 S 354.11 W -527.25 3.67 2547.94 43.50 225.21 2,370.54 558.66 S 386.08 W -558.66 1.03 INSITE V8.3.0 Page 1Job No:AK-XX-0902772867 Well Name:2S-04 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2579.53 43.26 226.72 2,393.50 573.74 S 401.68 W -573.74 3.37 2675.04 44.34 227.55 2,462.43 618.71 S 450.13 W -618.71 1.28 2755.07 44.33 227.28 2,519.67 656.55 S 491.31 W -656.55 0.24 2850.10 45.74 225.48 2,586.83 702.94 S 539.97 W -702.94 2.00 2881.04 45.64 226.26 2,608.44 718.36 S 555.86 W -718.36 1.83 2943.47 45.46 226.07 2,652.16 749.23 S 588.01 W -749.23 0.36 2991.33 45.20 224.82 2,685.81 773.10 S 612.26 W -773.10 1.94 3085.27 43.88 219.67 2,752.79 821.82 S 656.55 W -821.82 4.09 3178.47 42.77 215.51 2,820.60 872.46 S 695.56 W -872.46 3.29 3271.17 42.52 213.65 2,888.79 924.16 S 731.21 W -924.16 1.39 3365.26 45.80 215.59 2,956.28 978.07 S 768.46 W -978.07 3.77 3460.11 49.61 215.68 3,020.10 1,035.08 S 809.33 W -1035.08 4.02 3553.94 52.54 216.98 3,079.05 1,093.87 S 852.59 W -1093.87 3.30 3648.55 54.97 217.69 3,134.98 1,154.53 S 898.86 W -1154.53 2.64 3741.04 56.65 219.60 3,186.96 1,214.26 S 946.65 W -1214.26 2.49 3835.72 54.45 221.60 3,240.52 1,273.55 S 997.43 W -1273.55 2.90 3928.58 52.58 223.97 3,295.74 1,328.35 S 1,048.13 W -1328.35 2.87 4021.35 52.75 227.26 3,352.01 1,379.93 S 1,100.83 W -1379.93 2.83 4113.90 52.56 228.80 3,408.15 1,429.13 S 1,155.53 W -1429.13 1.34 4208.67 50.02 228.75 3,467.41 1,477.86 S 1,211.15 W -1477.86 2.68 4301.46 46.76 227.94 3,529.02 1,523.95 S 1,262.98 W -1523.95 3.57 4395.36 43.84 229.66 3,595.07 1,567.93 S 1,313.18 W -1567.93 3.37 4489.19 41.49 231.86 3,664.06 1,608.17 S 1,362.40 W -1608.17 2.97 4582.90 39.21 235.77 3,735.49 1,644.01 S 1,411.32 W -1644.01 3.63 4675.87 37.43 239.72 3,808.44 1,674.79 S 1,460.02 W -1674.79 3.26 4768.94 35.56 243.94 3,883.26 1,700.95 S 1,508.77 W -1700.95 3.36 4862.31 33.64 247.09 3,960.12 1,722.95 S 1,556.99 W -1722.95 2.81 4955.74 32.18 251.11 4,038.57 1,741.08 S 1,604.38 W -1741.08 2.81 5048.21 30.67 256.38 4,117.49 1,754.61 S 1,650.61 W -1754.61 3.39 5140.73 29.15 262.10 4,197.70 1,763.27 S 1,695.87 W -1763.27 3.49 5234.08 27.93 266.68 4,279.71 1,767.66 S 1,740.22 W -1767.66 2.68 5327.06 26.50 271.02 4,362.41 1,768.55 S 1,782.71 W -1768.55 2.63 5419.24 26.54 275.28 4,444.90 1,766.29 S 1,823.78 W -1766.29 2.06 5513.02 26.04 281.19 4,528.99 1,760.36 S 1,864.85 W -1760.36 2.84 5606.43 26.56 286.86 4,612.74 1,750.33 S 1,904.95 W -1750.33 2.75 5699.36 27.79 293.84 4,695.43 1,735.54 S 1,944.66 W -1735.54 3.67 5792.34 28.43 302.34 4,777.48 1,714.93 S 1,983.20 W -1714.93 4.36 5884.39 28.70 309.56 4,858.35 1,689.13 S 2,018.77 W -1689.13 3.76 5977.79 29.61 314.67 4,939.93 1,658.62 S 2,052.47 W -1658.62 2.84 6072.66 30.87 320.85 5,021.91 1,623.25 S 2,084.52 W -1623.25 3.54 6165.55 32.00 327.23 5,101.19 1,584.07 S 2,112.89 W -1584.07 3.78 6258.24 33.33 333.53 5,179.24 1,540.61 S 2,137.54 W -1540.61 3.94 6350.42 34.72 337.96 5,255.64 1,493.59 S 2,158.69 W -1493.59 3.08 6443.20 36.41 343.31 5,331.13 1,442.71 S 2,176.52 W -1442.71 3.82 6536.63 37.96 346.32 5,405.57 1,388.22 S 2,191.28 W -1388.22 2.56 INSITE V8.3.0 Page 2Job No:AK-XX-0902772867 Well Name:2S-04 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 6629.43 39.31 348.66 5,478.06 1,331.66 S 2,203.81 W -1331.66 2.14 6723.45 42.58 350.05 5,549.07 1,271.12 S 2,215.16 W -1271.12 3.61 6819.26 46.18 352.52 5,617.54 1,204.89 S 2,225.27 W -1204.89 4.17 6912.82 48.15 351.82 5,681.15 1,136.93 S 2,234.62 W -1136.93 2.18 7008.39 49.84 353.41 5,743.86 1,065.41 S 2,243.88 W -1065.41 2.17 7103.40 51.32 354.31 5,804.19 992.44 S 2,251.72 W -992.44 1.72 7199.44 53.25 356.24 5,862.94 916.73 S 2,257.96 W -916.73 2.56 7295.02 55.93 359.36 5,918.32 838.91 S 2,260.92 W -838.91 3.86 7390.99 58.61 3.49 5,970.22 758.24 S 2,258.87 W -758.24 4.57 7486.96 59.93 6.23 6,019.27 676.06 S 2,251.87 W -676.06 2.81 7582.65 61.84 7.68 6,065.83 593.08 S 2,241.73 W -593.08 2.40 7676.97 64.73 9.33 6,108.23 509.77 S 2,229.26 W -509.77 3.44 7773.60 67.84 9.94 6,147.09 422.56 S 2,214.45 W -422.56 3.27 7825.68 70.41 11.42 6,165.65 374.75 S 2,205.43 W -374.75 5.60 7896.00 72.70 12.25 6,187.89 309.47 S 2,191.74 W -309.47 3.44 7930.59 73.24 11.55 6,198.02 277.10 S 2,184.92 W -277.10 2.49 8023.06 75.55 12.92 6,222.90 190.07 S 2,166.05 W -190.07 2.88 8117.89 78.26 12.66 6,244.38 100.01 S 2,145.60 W -100.01 2.87 8213.29 81.92 15.75 6,260.80 8.94 S 2,122.53 W -8.94 4.99 8306.79 83.99 18.35 6,272.27 79.76 N 2,095.32 W 79.76 3.54 8400.93 82.64 19.26 6,283.23 168.27 N 2,065.19 W 168.27 1.73 8496.09 82.82 18.71 6,295.27 257.53 N 2,034.48 W 257.53 0.60 8590.73 83.68 18.28 6,306.39 346.66 N 2,004.67 W 346.66 1.01 8685.73 87.53 17.13 6,313.67 436.88 N 1,975.87 W 436.88 4.23 8779.52 91.92 15.14 6,314.12 526.94 N 1,949.81 W 526.94 5.14 8873.58 92.95 17.76 6,310.13 617.06 N 1,923.20 W 617.06 2.99 8968.74 94.80 19.13 6,303.70 707.12 N 1,893.17 W 707.12 2.42 9063.38 95.91 18.60 6,294.86 796.29 N 1,862.70 W 796.29 1.30 9157.20 94.70 18.84 6,286.19 884.76 N 1,832.72 W 884.76 1.31 9251.96 92.78 17.94 6,280.01 974.49 N 1,802.89 W 974.49 2.24 9348.85 91.54 15.96 6,276.36 1,067.09 N 1,774.67 W 1067.09 2.41 9441.70 89.76 16.97 6,275.30 1,156.13 N 1,748.35 W 1156.13 2.20 9536.76 89.25 18.86 6,276.12 1,246.57 N 1,719.11 W 1246.57 2.06 9631.22 90.86 20.79 6,276.03 1,335.42 N 1,687.08 W 1335.42 2.66 9725.08 91.78 21.94 6,273.87 1,422.81 N 1,652.90 W 1422.81 1.57 9819.77 92.30 21.08 6,270.50 1,510.85 N 1,618.20 W 1510.85 1.06 9914.29 92.99 20.75 6,266.14 1,599.04 N 1,584.49 W 1599.04 0.81 10007.93 93.95 23.08 6,260.47 1,685.75 N 1,549.61 W 1685.75 2.69 10103.74 93.88 22.72 6,253.93 1,773.80 N 1,512.42 W 1773.80 0.38 10197.05 91.92 21.37 6,249.21 1,860.18 N 1,477.44 W 1860.18 2.55 10290.76 89.25 19.16 6,248.25 1,948.07 N 1,444.99 W 1948.07 3.70 10386.03 85.95 16.49 6,252.24 2,038.66 N 1,415.86 W 2038.66 4.45 10480.31 86.98 16.49 6,258.05 2,128.89 N 1,389.15 W 2128.89 1.09 10575.41 90.03 15.42 6,260.54 2,220.28 N 1,363.02 W 2220.28 3.40 10669.02 89.97 15.09 6,260.54 2,310.60 N 1,338.39 W 2310.60 0.36 INSITE V8.3.0 Page 3Job No:AK-XX-0902772867 Well Name:2S-04 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 10765.36 91.61 16.20 6,259.21 2,403.35 N 1,312.41 W 2403.35 2.06 10858.51 92.64 16.43 6,255.75 2,492.69 N 1,286.26 W 2492.69 1.13 10955.10 92.33 15.22 6,251.56 2,585.53 N 1,259.95 W 2585.53 1.29 11049.82 89.45 14.48 6,250.09 2,677.06 N 1,235.68 W 2677.06 3.14 11143.17 87.46 11.83 6,252.61 2,767.92 N 1,214.44 W 2767.92 3.55 11237.78 91.13 10.42 6,253.77 2,860.73 N 1,196.19 W 2860.73 4.16 11332.11 89.97 11.16 6,252.87 2,953.38 N 1,178.54 W 2953.38 1.46 11425.41 88.18 13.97 6,254.38 3,044.42 N 1,158.25 W 3044.42 3.57 11520.84 88.05 15.37 6,257.52 3,136.69 N 1,134.09 W 3136.69 1.47 11615.20 88.28 17.64 6,260.54 3,227.11 N 1,107.30 W 3227.11 2.42 11710.79 89.25 20.52 6,262.60 3,317.42 N 1,076.06 W 3317.42 3.18 11804.91 90.55 21.28 6,262.76 3,405.34 N 1,042.49 W 3405.34 1.60 11898.63 90.72 19.65 6,261.72 3,493.14 N 1,009.72 W 3493.14 1.75 11994.43 91.61 19.71 6,259.78 3,583.32 N 977.47 W 3583.32 0.93 12087.51 92.23 19.83 6,256.66 3,670.87 N 946.00 W 3670.87 0.68 12182.24 91.27 18.90 6,253.76 3,760.19 N 914.61 W 3760.19 1.41 12278.29 91.65 24.18 6,251.32 3,849.47 N 879.37 W 3849.47 5.51 12328.82 92.02 23.56 6,249.70 3,895.66 N 858.93 W 3895.66 1.43 12372.32 92.74 24.01 6,247.89 3,935.43 N 841.40 W 3935.43 1.95 12466.67 91.78 24.86 6,244.17 4,021.26 N 802.40 W 4021.26 1.36 12561.30 90.21 23.56 6,242.53 4,107.55 N 763.60 W 4107.55 2.15 12656.17 90.45 20.65 6,241.98 4,195.43 N 727.91 W 4195.43 3.08 12751.22 90.45 13.11 6,241.23 4,286.32 N 700.33 W 4286.32 7.93 12845.85 90.58 15.87 6,240.38 4,377.93 N 676.66 W 4377.93 2.92 12935.20 90.41 15.86 6,239.61 4,463.87 N 652.23 W 4463.87 0.19 13033.35 90.27 16.27 6,239.03 4,558.19 N 625.07 W 4558.19 0.44 13127.01 91.47 16.88 6,237.61 4,647.94 N 598.36 W 4647.94 1.44 13220.65 90.96 19.01 6,235.62 4,737.00 N 569.51 W 4737.00 2.34 13317.85 88.53 20.08 6,236.05 4,828.59 N 537.00 W 4828.59 2.73 13411.95 90.57 24.34 6,236.79 4,915.68 N 501.44 W 4915.68 5.02 13505.00 90.55 24.34 6,235.88 5,000.46 N 463.09 W 5000.46 0.02 INSITE V8.3.0 Page 4Job No:AK-XX-0902772867 Well Name:2S-04 Survey Report DIRECTIONAL SURVEY DATA NOTES - Calculation based on minimum curvature method. - Survey coordinates relative to well system reference point. - TVD values given relative to drilling measurement point. - Vertical section relative to well head. - Vertical section is computed along a direction of 0.00 degrees (True) - A total correction of 18.56 deg from Magnetic north to True north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 13,505.00 feet is 5,021.86 feet along 354.71 degrees (True) WARRANTY HALLIBURTON ENERGY SERVICES, INC. WILL USE ITS BEST EFFORTS TO FURNISH CUSTOMERS WITH ACCURATE INFORMATION AND INTERPRETATIONS THAT ARE PART OF, AND INCIDENT TO, THE SERVICES PROVIDED. HOWEVER, HALLIBURTON ENERGY SERVICES, INC. CANNOT AND DOES NOT WARRANT THE ACCURACY OR CORRECTNESS OF SUCH INFORMATION AND INTERPRETATIONS. UNDER NO CIRCUMSTANCES SHOULD ANY SUCH INFORMATION OR INTERPRETATION BE RELIED UPON AS THE SOLE BASIS FOR ANY DRILLING, COMPLETION, PRODUCTION, OR FINANCIAL DECISION OR ANY PROCEDURE INVOLVING ANY RISK TO THE SAFETY OF ANY DRILLING VENTURE, DRILLING RIG OR ITS CREW OR ANY THIRD PARTY. THE CUSTOMER HAS FULL RESPONSIBILITY FOR ALL DRILLING, COMPLETION, AND PRODUCTION OPERATION. HALLIBURTON ENERGY SERVICES, INC. MAKES NO REPRESENTATIONS OR WARRANTIES, EITHER EXPRESSED OR IMPLIED, INCLUDING, BUT NOT LIMITED TO, THE IMPLIED WARRANTIES OF MERCHANTABILITY OR FITNESS FOR A PARTICULAR PURPOSE, WITH RESPECT TO THE SERVICES RENDERED. IN NO EVENT WILL HALLIBURTON ENERGY SERVICES, INC. SERVICES BE LIABLE FOR FAILURE TO OBTAIN ANY PARTICULAR RESULTS OR FOR ANY DAMAGES, INCLUDING, BUT NOT LIMITED TO, INDIRECT, SPECIAL OR CONSEQUENTIAL DAMAGES, RESULTING FROM THE USE OF ANY INFORMATION OR INTERPRETATION PROVIDED BY HALLIBURTON ENERGY SERVICES, INC. INSITE V8.3.0 Page 5Job No:AK-XX-0902772867 Well Name:2S-04 Survey Report WELL INFORMATION Created On : Nov 06 2015 Customer :ConocoPhillips Alaska, Inc. Well Name :2S-04 PB1 Job Number :AK-XX-0902772867 Rig Name :Doyon 141 Field Name :Kuparuk River Unit Country :USA Survey Report SURVEY HEADER Survey data provided by Schlumberger. DIRECTIONAL SURVEY DATA Tie-in 0.00 0.00 0.00 0.00 0.00 N 0.00 E (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 27.50 0.00 0.00 27.50 0.00 N 0.00 E 0.00 0.00 78.00 0.30 241.15 78.00 0.06 S 0.12 W -0.06 0.59 170.00 0.45 266.98 170.00 0.20 S 0.69 W -0.20 0.24 263.00 0.52 264.61 262.99 0.26 S 1.47 W -0.26 0.08 355.00 0.64 262.29 354.99 0.37 S 2.40 W -0.37 0.13 447.00 0.58 275.81 446.98 0.39 S 3.37 W -0.39 0.17 476.76 0.31 285.28 476.74 0.35 S 3.60 W -0.35 0.94 567.94 0.04 243.25 567.92 0.30 S 3.86 W -0.30 0.31 660.98 1.43 217.97 660.95 1.23 S 4.61 W -1.23 1.50 696.02 2.12 219.06 695.98 2.08 S 5.28 W -2.08 1.97 757.33 2.58 214.47 757.23 4.10 S 6.78 W -4.10 0.81 853.64 3.59 211.81 853.40 8.45 S 9.60 W -8.45 1.06 948.89 4.60 201.35 948.41 14.54 S 12.56 W -14.54 1.31 1045.12 7.88 197.52 1,044.06 24.43 S 15.95 W -24.43 3.43 1140.42 10.66 202.74 1,138.11 38.79 S 21.33 W -38.79 3.04 1237.11 13.56 204.84 1,232.63 57.33 S 29.55 W -57.33 3.03 1332.94 17.82 206.38 1,324.87 80.67 S 40.79 W -80.67 4.47 1428.89 20.05 207.90 1,415.63 108.36 S 55.01 W -108.36 2.38 1525.28 19.63 209.48 1,506.29 137.06 S 70.71 W -137.06 0.71 1621.34 21.86 208.07 1,596.12 166.89 S 87.06 W -166.89 2.38 1715.89 22.82 207.21 1,683.57 198.73 S 103.73 W -198.73 1.07 1811.64 25.43 208.33 1,770.95 233.34 S 121.98 W -233.34 2.77 1909.25 28.51 211.22 1,857.94 271.72 S 144.01 W -271.72 3.43 2003.73 29.77 212.20 1,940.46 310.85 S 168.19 W -310.85 1.43 2098.75 32.65 215.49 2,021.73 351.70 S 195.65 W -351.70 3.52 2195.36 35.25 219.32 2,101.87 394.50 S 228.46 W -394.50 3.48 2290.95 38.19 223.06 2,178.49 437.44 S 266.13 W -437.44 3.86 2387.10 40.65 224.33 2,252.77 481.57 S 308.31 W -481.57 2.69 2483.15 44.04 225.78 2,323.75 527.25 S 354.11 W -527.25 3.67 INSITE V8.3.0 Page 1Job No:AK-XX-0902772867 Well Name:2S-04 PB1 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2547.93 43.50 225.21 2,370.53 558.66 S 386.07 W -558.66 1.03 2579.52 43.26 226.72 2,393.49 573.74 S 401.67 W -573.74 3.37 2675.03 44.34 227.55 2,462.42 618.70 S 450.13 W -618.70 1.28 2755.06 44.33 227.28 2,519.67 656.55 S 491.30 W -656.55 0.24 2785.43 44.48 227.79 2,541.36 670.90 S 506.98 W -670.90 1.27 2881.48 44.55 226.69 2,609.85 716.61 S 556.42 W -716.61 0.81 2977.31 44.60 227.12 2,678.12 762.57 S 605.53 W -762.57 0.32 3071.57 44.65 228.14 2,745.20 807.19 S 654.45 W -807.19 0.76 3168.67 44.66 229.42 2,814.28 852.16 S 705.78 W -852.16 0.93 3263.71 44.66 230.82 2,881.88 894.99 S 757.04 W -894.99 1.04 3361.00 44.66 232.11 2,951.08 937.59 S 810.54 W -937.59 0.93 3456.24 44.48 228.64 3,018.94 980.20 S 862.00 W -980.20 2.56 3552.55 44.55 226.47 3,087.62 1,025.76 S 911.82 W -1025.76 1.58 3647.60 44.54 226.47 3,155.36 1,071.68 S 960.16 W -1071.68 0.01 3743.62 44.62 227.22 3,223.76 1,117.78 S 1,009.33 W -1117.78 0.55 3839.54 44.49 225.79 3,292.11 1,164.10 S 1,058.15 W -1164.10 1.05 3935.56 44.45 224.94 3,360.63 1,211.36 S 1,106.01 W -1211.36 0.62 4031.01 44.58 224.99 3,428.69 1,258.71 S 1,153.30 W -1258.71 0.14 4126.56 44.57 225.15 3,496.76 1,306.07 S 1,200.78 W -1306.07 0.12 4223.26 40.97 228.98 3,567.74 1,350.83 S 1,248.78 W -1350.83 4.59 4318.98 37.39 232.21 3,641.94 1,389.25 S 1,295.44 W -1389.25 4.30 4415.63 35.48 236.56 3,719.71 1,422.69 S 1,342.05 W -1422.69 3.32 4511.12 33.51 239.51 3,798.41 1,451.34 S 1,387.89 W -1451.34 2.70 4606.71 31.82 244.44 3,878.89 1,475.61 S 1,433.38 W -1475.61 3.30 4702.88 30.21 250.17 3,961.33 1,494.76 S 1,479.02 W -1494.76 3.50 4798.41 28.48 255.85 4,044.61 1,508.49 S 1,523.73 W -1508.49 3.43 4891.71 26.73 262.07 4,127.31 1,516.82 S 1,566.09 W -1516.82 3.61 4987.74 25.09 266.84 4,213.69 1,520.93 S 1,607.82 W -1520.93 2.76 5083.19 23.95 268.35 4,300.53 1,522.60 S 1,647.39 W -1522.60 1.36 5179.21 23.78 271.11 4,388.34 1,522.78 S 1,686.23 W -1522.79 1.18 5276.11 24.10 276.88 4,476.92 1,520.04 S 1,725.41 W -1520.04 2.44 5371.57 23.37 280.36 4,564.31 1,514.30 S 1,763.39 W -1514.30 1.65 5468.54 23.90 288.39 4,653.17 1,504.64 S 1,800.95 W -1504.64 3.36 5562.91 24.43 296.61 4,739.29 1,489.86 S 1,836.55 W -1489.86 3.61 5658.75 24.32 305.58 4,826.62 1,469.50 S 1,870.34 W -1469.50 3.86 5754.18 25.57 314.11 4,913.17 1,443.72 S 1,901.12 W -1443.72 3.99 5850.08 28.10 321.16 4,998.76 1,411.71 S 1,930.15 W -1411.71 4.24 5946.05 30.04 326.73 5,082.65 1,374.01 S 1,957.51 W -1374.01 3.47 6041.42 32.15 331.41 5,164.33 1,331.76 S 1,982.76 W -1331.76 3.36 6137.35 33.87 335.64 5,244.78 1,284.98 S 2,006.00 W -1284.98 3.00 6233.12 35.40 340.52 5,323.59 1,234.51 S 2,026.26 W -1234.51 3.31 6328.67 36.73 342.69 5,400.83 1,181.14 S 2,044.00 W -1181.14 1.93 6425.03 37.33 345.26 5,477.76 1,125.37 S 2,060.00 W -1125.37 1.72 6521.61 39.51 347.21 5,553.43 1,067.08 S 2,074.26 W -1067.08 2.58 6617.13 42.16 349.69 5,625.70 1,005.89 S 2,086.73 W -1005.89 3.25 INSITE V8.3.0 Page 2Job No:AK-XX-0902772867 Well Name:2S-04 PB1 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 6713.19 44.54 350.38 5,695.54 940.95 S 2,098.13 W -940.95 2.53 6809.07 48.08 352.78 5,761.77 872.38 S 2,108.23 W -872.38 4.11 6903.59 51.65 355.15 5,822.69 800.54 S 2,115.79 W -800.54 4.24 7000.64 54.62 356.98 5,880.91 723.09 S 2,121.09 W -723.09 3.41 7096.65 57.93 0.89 5,934.22 643.29 S 2,122.52 W -643.29 4.83 7191.66 60.72 4.67 5,982.70 561.70 S 2,118.52 W -561.70 4.51 7287.73 61.75 6.21 6,028.93 477.87 S 2,110.53 W -477.87 1.77 7364.26 62.00 8.00 6,065.01 410.90 S 2,102.19 W -410.90 2.09 7383.13 62.47 7.88 6,073.80 394.36 S 2,099.88 W -394.36 2.55 7439.43 63.75 9.21 6,099.27 344.71 S 2,092.42 W -344.71 3.10 7479.98 63.87 8.89 6,117.16 308.77 S 2,086.69 W -308.77 0.77 7575.45 65.10 10.69 6,158.29 223.88 S 2,072.04 W -223.88 2.13 7669.77 67.56 12.78 6,196.16 139.31 S 2,054.45 W -139.31 3.30 7729.43 70.09 14.01 6,217.71 85.20 S 2,041.56 W -85.20 4.66 7800.00 72.50 15.00 6,240.34 20.50 S 2,024.82 W -20.50 3.66 DIRECTIONAL SURVEY DATA NOTES - Calculation based on minimum curvature method. - Survey coordinates relative to well system reference point. - TVD values given relative to drilling measurement point. - Vertical section relative to well head. - Vertical section is computed along a direction of 0.00 degrees (True) - A total correction of 18.56 deg from Magnetic north to True north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 7,800.00 feet is 2,024.92 feet along 269.42 degrees (True) WARRANTY HALLIBURTON ENERGY SERVICES, INC. WILL USE ITS BEST EFFORTS TO FURNISH CUSTOMERS WITH ACCURATE INFORMATION AND INTERPRETATIONS THAT ARE PART OF, AND INCIDENT TO, THE SERVICES PROVIDED. HOWEVER, HALLIBURTON ENERGY SERVICES, INC. CANNOT AND DOES NOT WARRANT THE ACCURACY OR CORRECTNESS OF SUCH INFORMATION AND INTERPRETATIONS. UNDER NO CIRCUMSTANCES SHOULD ANY SUCH INFORMATION OR INTERPRETATION BE RELIED UPON AS THE SOLE BASIS FOR ANY DRILLING, COMPLETION, PRODUCTION, OR FINANCIAL DECISION OR ANY PROCEDURE INVOLVING ANY RISK TO THE SAFETY OF ANY DRILLING VENTURE, DRILLING RIG OR ITS CREW OR ANY THIRD PARTY. THE CUSTOMER HAS FULL RESPONSIBILITY FOR ALL DRILLING, COMPLETION, AND PRODUCTION OPERATION. HALLIBURTON ENERGY SERVICES, INC. MAKES NO REPRESENTATIONS OR WARRANTIES, EITHER EXPRESSED OR IMPLIED, INCLUDING, BUT NOT LIMITED TO, THE IMPLIED WARRANTIES OF MERCHANTABILITY OR FITNESS FOR A PARTICULAR PURPOSE, WITH RESPECT TO THE SERVICES RENDERED. IN NO EVENT WILL HALLIBURTON ENERGY SERVICES, INC. SERVICES BE LIABLE FOR FAILURE TO OBTAIN ANY PARTICULAR RESULTS OR FOR ANY DAMAGES, INCLUDING, BUT NOT LIMITED TO, INDIRECT, SPECIAL OR CONSEQUENTIAL DAMAGES, RESULTING FROM THE USE OF ANY INFORMATION OR INTERPRETATION PROVIDED BY HALLIBURTON ENERGY SERVICES, INC. INSITE V8.3.0 Page 3Job No:AK-XX-0902772867 Well Name:2S-04 PB1 Survey Report
