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214-189
Inspector also called Matt Miller (CPAI KRU Ops Foreman) and provided the details. He committed to CPAI getting a gas sample. Deficiency resolved with info received from CPAI on 7/14/2025 (gas sample analyses) demonstrating the gas bubbling is due to shallow hydrates (history of this on KRU 2L-pad-- J. Regg; 7/15/2025 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:NSK Wells Integrity Eng CPF2 Cc:Automation, AK Wells; Livingston, Erica J; Sullivan, Sean T (OGC) Subject:RE: KRU 2L-326, 2L-327, 2L-328 (PTDs: 209-027, 207-008, 214-189) Gas Bubbling Date:Friday, July 11, 2025 10:36:00 AM Timeframe for receiving the results of sample analyses? CPAI’s inspection frequency while we wait for the results? Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSK Wells Integrity Eng CPF2 <n2549@conocophillips.com> Sent: Wednesday, July 9, 2025 10:19 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Automation, AK Wells <akwellsautomation@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 2L-326, 2L-327, 2L-328 (PTDs: 209-027, 207-008, 214-189) Gas Bubbling Well Name: 2L-326 Facility: CFP2 PTD: 209-027 Well Type: Prod AA Number (if applicable): Internal Waiver (Yes/No if applicable): Type of Issue: Plan Forward Maximum Pressure (if applicable): Date of Occurrence (if applicable): Hi Jim, I was informed that during State Witnessed SVS testing on 2L, Sully requested information regarding gas bubbling in the cellars of 2L-326, 2L-327, and 2L-328 (PTD 209-027, 207-008, 214-189) . These wells are gas lifted production wells. CPAI conducts gas sampling of wells which experience bubbling in cellars and conductors and compares the bubbling gas samples to the lift gas samples and produced gas samples to confirm if the bubbling gases are coming from the applied lift gas in the IA, the target reservoir, or are shallow thawing hydrates on the pad. These wells have been sampled extensively in the past. The test results are attached. New samples were taken but the results will not be available for some time. All well’s bubbling gases have shallow thawing hydrate gas signatures marked by the lack of ethane and heavier gases. CPAI intends to keep these wells online. Please let me know if you have any questions or disagree with the plan. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 ! ! !"#$ %#" #&'! 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BOX 100360 ANCHORAGE,ALASKA 99510-0360 September 28, 2015 �►�4�� MA`( 12�i6 a 4. ✓ �` 3g.g Commissioner Cathy Foerster Alaska Oil& Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field(KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement 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 MJ Loveland or Martin Walters at 907-659-7043, if you have any questions. Sincerely, /27C?A - ' )4 Martin Walters ConocoPhillips Well Integrity Projects Supervisor 0 9 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field 2N&2L PAD Date 9/28/2015 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 2N-316 50103203420000 2000900 13" N/A 13" N/A 5.95 9/25/2015 2N-333 50103205250000 2060250 19" N/A 19" N/A 5.1 9/25/2015 2N-336 50103206930000 2141440 Surface N/A 8" N/A 3.4 9/25/2015 2L-308 50103206940000 2141510 35" 0.10 16" 9/11/2015 4.25 9/25/2015 2L-314 50103206860000 2140230 24" 0.20 15" 9/11/2015 4.25 9/25/2015 2L-316 50103207040000 2150060 Surface NA 15" NA 3.4 9/25/2015 2L-328 50103206980000 2141890 12" NA 12" NA 4.25 9/25/2015 STATE OF ALASKA ' ALA OIL AND GAS CONSERVATION CONOSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations ( Fracture Stimulate P Pull Tubing r Operations Shutdown Performed: Suspend Perforate p r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well E Re-enter Susp Well r Other: (`"" 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development li Exploratory r 214-189-0 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-103-20698-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380051,380052,380053 KRU 2L-328 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Tarn Oil Pool 11.Present Well Condition Summary: Total Depth measured 16168 feet Plugs(measured) none true vertical 5530 feet Junk(measured) none Effective Depth measured 16148 feet Packer(measured) 12023, 12156 true vertical 5530 feet (true vertical) 5213, 5252 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 114 114 SURFACE 2461 10.75 2500 2293 INTERMEDIATE 12230 7.625 12266 5285 LINER-51/2"X4 4007 4.5 16163 5530 RECEIVED JUN 16 2015 Perforation depth: Measured depth: frac sleeve from 13226-16139' A OGCC True Vertical Depth: 5471-5530 APR 0 12016 �'1 Tubing(size,grade,MD,and TVD) 3.5, L-80, 12156 MD,5252 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER PREMIER PACKER @ 12023 MD and 5213 TVD PACKER-BAKER HRD-E ZXP LINER TOP PACKER @12156 MD and 5252 TVD NIPPLE-CAMCO DS NIPPLE @ 551 MD and 551 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 13226-16138'MD Treatment descriptions including volumes used and final pressure: see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations p Exploratory "`" Development F. Service r Stratigraphic Copies of Logs and Surveys Run r co) 16.Well Status after work: Oil p Gas fl WDSPL 1"-- Printed Printed and Electronic Fracture Stimulation Data ]i GSTOR VVINJ 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: _ 315-220 Contact Adam Klem @ 263-4529 Email Adam.Klem@conocophillips.com Printed Name Adam Klem Title Sr. Completions Engineer Signature7( Phone:263-4529 Date k -,�-2..co1S tom- 3/ 0//I- Ca) ,a/os,//r RBDM�V\- JUN 15 2015 Li. 1..w. 2T-,- ltv Form 10-404 Revised 5/2015 Submit Original Only , O c'e.cet�ed l8 Mg-ie., 2L-328 FRAC SUMMARY DATE SUMMARY • • 4/16/2015 SET BAITED PULLING TOOL ON B&R @ 12081' SLM. PULLED SOV FROM 8995' RKB, SET DV @ SAME. MIT TBG 4000 PSI, PASSED. MIT IA 3500 PSI, PASSED. IN PROGRESS. 4/17/2015 PULLED B&R AND 2.75" RHC PLUG BODY FROM 12129' RKB. READY FOR FRAC. 5/10/2015 DRIFT TBG HANGER CLEANLY W/3.86" GAUGE RING DOWN TO 20' SLM (WOULD NOT DRIFT 3.905") READY FOR TREE SAVER. 5/13/2015 Pumped data frac and first 4 stages of fracture stimulation treatment. (est. 455k 16/20 proppant total placed in well). Well freeze protected w/30 diesel. 5/16/2015 Pumped last 4 stages of fracture stimulation treatment of the Bermuda (est.588k 16/20 proppant placed in last 4 stages). Well freeze protected w/25 diesel. 5/31/2015 FCO to 13225' milled 3 frac sleeves to 2.70" and cleaned out to top of forth frac sleeve @ 14553'with slick diesel/gelled diesel sweeps. Temporarily stuck @ 13,082'CTMD, and again @ 11,863' CTMD. Freeze protected well to surface. Job in Progress. 6/1/2015 RIH to 7329' CTMD, find reel swivel leak during walk around. POOH to repair swivel. Restart in a.m. In progress. 6/2/2015 Late start due to change out. RIH and milled out 2 frac sleeves and cleaned out to 6th frac sleeve @ 15,366'with diesel gel and slick diesel.Well freeze protected. Job in progress. 6/3/2015 Milled the last two remaining frac sleeves to 2.70" and cleaned out to the top of the Wellbore Isolation Valve @16,145'. Encountered no "sticky" spots when POOH. Well Freeze protected and ready for Slickline. 6/4/2015 DRIFT TBG W/2.71" GAUGE RING DOWN TO 12.843' RKB (82 DEG DEVIATION); DRIFT W/DMY CA-2 PLUG DOWN TO 12,113' RKB; ATTEMPT TO SET 2.75"CA-2 PLUG (UNABLE TO SHEAR NO-GO PINS). IN PROGRESS. i- KUP PROD • 2L-328 ConocoPhillips - Well Attributes Max Angle&MD TD Alaska,inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) c,+<a4uru,i,4 501032069800 TARN PARTICIPATING AREA PROD 16,168.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2L-328,5/26/201512:27:38 PM SSSV:NIPPLE Last WO: 39.60 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER,351- rCdpm ... Last Tag: Rev Reason:FRAC lehallf 5/23/2015 iii, I LIP m Casing Strings XO Reducing;69.9 -�: Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(WD)...WI/Len(L..Grade Top Thread CONDUCTOR 16 15.250 36.0 114.0 114.0 62.50 H-40 Weld IF Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(L..Grade Top Thread .A.A./CONDUCTOR;36.0-114.0+U SURFACE 103/4 9.950 39.0 2,500.0 2,282.6 45.50 L-80 TSH 563 NIPPLE;5508 _ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(WD)...WULen(i...Grade Top Thread INTERMEDIATE 75/8 6.875 35.9 12,266.2 5,285.4 29.70 L-80 Hydri1563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread 9 9 LINER-51/2"x41/2" 412 3.958 12,156.3 16,163.0 5,530.0 12.60 L-80 IBT-m @12190.21 SURFACE;39.0-2,500.0 - Liner Details Nominal ID GAS LIFT;2,988.9 Top(ftKB) Top(WD)(ftKB) Top Incl(°I Item Des Com (in) GAS LIFT;6,449.8 � 12,156.3 5,252.3 72.71 PACKER BAKER HRD-E ZXP LINER TOP PACKER 4.820 p q:. 12,178.3 5,258.9 72.53 NIPPLE BAKER RS SEAL NIPPLE 4.250 li 12,180.6 5,259.6 72.51 HANGER BAKER FLEX-LOCK LINER HANGER 4.790 GAS LIFT;8,983.6 r 12,190.2 5,262.5 72.43 XO Reducing 5.5"Hyd 563 box x 4.5"IBT pin Crossover Coupling 3.940 13,004.7 5,446.8 84.15 SWELL BAKER SWELL PACKER H-1 3.958 M PACKER GAS LIFT;10,840.6 3' _° `` 13,225.6 5,471.4 83.10 FRAC PORT FRAC SLEEVE W/2.125"BALL,SEAT ID 2.073"-#7 3.950 13,447.2 5,492.7 86.97 SWELL BAKER SWELL PACKER 0-1 3.958 GAS LIFT;11,915.7 Ao- PACKER 13,669.4 5,496.9 89.53 FRAC PORT FRAC SLEEVE W/2.063"BALL,SEAT ID 2.015"-#6 3.940 SLEEVE;11,973.9 13,889.0 5,4992 89.07 SWELL BAKER SWELL PACKER F-1 3.958 PACKER GAUGE;11,998.0 ':'y 14,1112 5,505.3 87.64 FRAC PORT FRAC SLEEVE W/2.000"BALL,SEAT ID 1.948"-#5 3.920 PACKER;12,023.0 _ XO Threads;12,030.9 14,331.1 5,5122 8921 SWELL BAKER SWELL PACKER E-1 3.958 PACKER NIPPLE;12,1132 14,553.1 5,515.8 88.83 FRAC PORT FRAC SLEEVE W/1.938"BALL,SEAT ID 1.885"-#4 3.940 LOCATOR:12,134.9 14,775.0 5,522.2 87.85 SWELL BAKER SWELL PACKER D-1 3.958 &. • PACKER MULE SHOE;12,155.0 Mi sif �3. 14,999.5 5,530.9 88.69 FRAC PORT FRAC SLEEVE WI 1.813"BALL,SEAT ID 1.760"-#3 3.930 It Vii; 15,181.7 5,532.8 89.96 SWELL BAKER SWELL PACKER C-1 3.958 s- PACKER g 15,366.2 5,533.7 89.81 FRAC PORT FRAC SLEEVE W/1.688"BALL,SEAT 10 1.635"-#2 3.930 i. INTERMEDIATE;36.0-12,266.2 - "' 15,547.7 5,532.3 90.40 SWELL BAKER SWELL PACKER B-1 3.958 PACKER 15,731.7 5,532.2 89.93 FRAC PORT FRAC SLEEVE W/1.563"BALL,SEAT ID 1.510"-#1 3.950 PERFP;13,225.6-13,228.3 II.( 15,913.0 5,531.9 90.31 SWELL BAKER SWELL PACKER A-1 3.958 PACKER 16,135.8 5,530.1 90.30 FRAC PORT PRESSURE ACTIVATED FRAC SLEEVE 3.840 16,148.7 5,530.0 90.30 WIV WELLBORE ISOLATION VALVE 3.950 Tubing Strings PERFP;13,669.4-13,672.2 I I 1� Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection 1 TUBING-41/2 x3 312 2.992 35.1 12,156.3 5,252.3 9.30 L-80 EUE8rd ' 12 @ 69.85 FRAC;13,225.6 Completion Details X f Nominal ID Top(ftKB) Top(EVD)(ftKB) Top Incl(°) Item Des Com (in) PERFP;14,111.2-14,114.0 35.1 35.1 0.00 HANGER CAMERON TUBING HANGER 3.900 69.9 69.9 0.30 XO Reducing Crossover 4 1/2"IBTM b x 3 1/2"EUE8rd p 2.992 -- 550.7 550.6 3.18 NIPPLE CAMCO OS NIPPLE 2.875 11,973.9 5,198.6 72.89 SLEEVE BAKER CMU SLIDING SLEEVE-CLOSED 2.810 PERFP,14,553.1-14,555.9 t 11,998.0 5,205.7 72.88 GAUGE SLB GAUGE CARRIER 2.913 12,023.0 5,213.0 72.87 PACKER BAKER PREMIER PACKER 2.880 12,113.2 5,239.6 72.90 NIPPLE CAMCO D NIPPLE W/RHC PLUG 2.750 12,134.8 5,245.9 72.88 LOCATOR BAKER SPECIAL SHEAR FLUTED NO GO LOCATOR 3.000 12,135.9 5,246.3 72.87 NO GO SUB BAKER SPECIAL SHEAR LOCATOR 3.000 PERFP;14,999.5-15,002.2 I 12,155.01 5,251.91 72.721 MULE SHOE 'BAKER SPEICAL SHEAR TYPE WLEG 1 3.000 Perforations&Slots Shot I Dens Top(WD) Atm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com PERFP FRAC SLEEVE#7 PERFP;15.366.2-15,368.9 13,225.6 13,228.3 5,471.4 5,471.7 4/3/2015 13,669.4 13,672.2 5,496.9 5,496.9 4/3/2075 PERFP FRAC SLEEVE#6 14,111.2 14,114.0 5,505.3 5,505.4 4/3/2015 PERFP FRAC SLEEVE#5 FRAC;14,999.5 14,553.1 14,555.9 5,515.8 5,515.8 4/3/2015 PERFP FRAC SLEEVE#4 PERFP;15,731.6-15,734.4 t a 14,999.5 15,002.2 5,530.9 5,531.0 4/3/2015 PERFP FRAC SLEEVE#3 15,366.2 15,368.9 5,533.7 5,533.7 4/3/2015 PERFP FRAC SLEEVE#2 :" 15,731.7 15,734.4 5,532.2 5,532.2 4/3/2015 PERFP FRAC SLEEVE#1 16,135.8 16,138.6 5,530.1 5,530.1 4/3/2015 PERFP PRESSURE FRAC SLV PERFP;10,135.5.16,138.6 _ I f-„ LINER-51/2'a 4 112" ©12190.21;12,156.3-16,163.0 - s KUP PROD 0 2L-328 ConocoPhillips Alaska,Inc, 2L.328,5262015 1227:39 PM Vertical schematic(actual) HANGER;35.1- ;yeed.-; ,m,.mna,am,ama.,,,,m,n.,. ,mm�. m;Stimulations&Treatments XO Reducing,69 9 Min Top Max Btm Depth Depth Top(TVD) Bloc(TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com .MP CONDUCTOR;360-1140.4 - 14,999.5 16,138.0 5530.9 5530.1 FRAC 5/13/2015 1st 4 STAGES,488k 16/20 PROPANT NIPPLE;550.8 13,225.6 14,559.9 5,471.4 5,515.9 FRAC 5/16/2015 2nd 4 remaining STAGES,588k 16/20 Mandrel Inserts ❑ . st + ati SURFACE;39.0-2,500.0 s nn Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sere Type Type (in) (psi) Run Date Com Ic 2,988.9 2,514.2 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 3/4/2015 GAS LIFT,2,988.9 e 2 6,449.8 3,556.8 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 3/4/2015 3 8,983.6 4,304.7 CAMCO KBMG 1 GAS LIFT SOV BEK 0.000 2,500.0 3/4/2015 DCK-2 GAS LIFT;6,449.8 14 4 10,840.6 4,857.9 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 3/4/2015 5 11,915.7 5,181.4 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 3/4/2015 GAS LIFT;8,983.6 Notes:General&Safety End Date Annotation GAS LIFT;10,840.6 NOTE; ::- GAS LIFT;11,915.7 `f SLEEVE;11,973.9 GAUGE;11,998.0 PACKER;12,023.0 a 20 Threads;12,030.9 - NIPPLE;12,113.2 A:. LOCATOR;12,134.8 MULE SHOE;12,155.0 ](�_ J �- pp INTERMEDIATE;36.0-12,266.2 - S PERFP;13.2256-13,228.3 111 I PERFP;13,669.4-13,672.2 III FRAC;1$,225.6 PERFP;14.111.2-14,114.0 II PERFP;14,553.1-14.555.9 II 1 PERFP;14,999.5-15,002.2 It PERFP;15,366.2-15,368.9 ,1 1 FRAC;14,999.5 PERFP;15,731.6-15,734.4 I PERFP;16.135.8-16,138.6 II LINER-512"x412" 6/12190.21;12,156.3-16,163.0 • • civ E E ro 0 • it g ,....›, p tS' N 0 CO 0 0 0 0 N ti N O o 0 0 0 0 0 0 a, � �,H U = ,tea `� U) t) z t F C • d d- to CO N N # 6) O In N- N CO O O O d- CONCON CS) CO d- 71- N. 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Date: /s/ 61P Scanning Preparation x 30 = 0240, ? =TOTAL PAGES L*14/151 (Count does not include cover sh e BY: Date: /s/ Production Scanning Stage 1 Page Count from Scanned File: a5--0 (Count does include cov sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: 410> Date: '. 7//4.5— /s/ V'V1f Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: 0 NO TOTAL PAGES: (0'� Digital version appended by: Mere ' Michal Date: 1 oho I t /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: 3 1 3 Scanning is complete at this point unless rescanning is required. 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N- N- N- N LO LO LO LO LO LO LO LO w E n O re 1 NNNNNNNNN d 0 • w 0 N a N c re o ` = N E EZ a 006 c.0 co co O a' a) 'Li 0 o ro. N Z Q O 00 Q o 0 7., C U ,�„ 0 0 0 0 0 0 0 0 C N 'V • J N y •2' 1 2 81 a) IE ,, CU7 E 0 O c -o o 1 . E ai H E O a W W W w W WW w i 3 z 0 a 0 10 0 w o 0 ¢ • 0 o O 0 o N O m O b coco Z O o _-0 O —• = 1 fV co 1o o z E- O C) V r Z 1 co 3Ili : @ co Q co , G O a � 1 CL J /W 0. = IX V W z J1 C) 0 o Z 3 Q as J o 0I a0) 20 0 C%1 U O U o - to Q N CD M 1." az P. N H co Z C M o G N W m re SII > > CO a ICC a .tQ o Z 0 £ U c Z d • 0 M in v 3 N N d G• c V w co R U c..7E a o O d o 0 d a m c) i i Guhl, Meredith D (DOA) From: Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent: Tuesday, October 13, 2015 1:38 PM To: Guhl, Meredith D (DOA) Cc: Bettis, Patricia K (DOA) Subject: RE: KRU 2L-328, PTD 214-189, Complete List of Geologic Markers Required Meredith, apologies for not getting back to you with this sooner. As requested, here are all of the tops observed from 2L-328. Please let me know if this is what you are looking for or if you would like any more information. Top/Marker MD actual TVD actual TVDSS 10 3/4" Casing Shoe 2,509' 2,281' -2,126' C-80 2,863' 2,472' -2,317' Campanian Sand 3,055' 2,534' -2,379' C-50 7,416' 3,842' -3,687' C-40 8,681' 4,242' _ -4,087' C-37 9,343' 4,413' -4,258' Iceberg 9,853' 4,566' -4,411' 1-7 11,073' 4,926' -4,771' 1-6 11,433' 5,035' -4,880' 1-5 11,809' 5,150' _ -4,995' 1-4.1 11,898' 5,177' -5,022' T-4 12,267' 5,290' -5,135' 7-5/8" Casing Shoe 12,266' 5,286' -5,131' 1-3.1 12,448' 5,339' -5,184' T-3 12,677' 5,400' -5,245' Top Berm 12,758' 5,416' -5,261' Thanks, Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office: (907) 263-4180 Cell: (907) 231-2176 From: Guhl, Meredith D (DOA) [mailto:meredith.guhl©alaska.gov] Sent: Tuesday, October 06, 2015 4:04 PM To: Callahan, Mike S Cc: Bettis, Patricia K (DOA) Subject: [EXTERNAL]KRU 2L-328, PTD 214-189, Complete List of Geologic Markers Required Scott, 1 During a review of the 10-407 form s0itted for KRU 2L-328, PTD 214-189,comped 4/8/2015, it was noted that the geologic markers box lacked detail. Box 29: Geologic Markers and Formations: Only the Top and Seismic Top Bermuda are listed. Please provide a complete list of all geologic formations and markers encountered in this wellbore. The 10-407 form is designed to be a complete and concise record of all data obtained in the completion of a well. Please make sure each well completion form is filled out correctly and fully so that all data is readily available for future users of the AOGCC archive. Please provided the complete list of formations and markers by October 13, 2015. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W.7th Ave,Suite 100,Anchorage,AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 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 Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 2 9 41! ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 9/28/2015 2N&2L PAD Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 2N-336 50103206930000 2141440 Surface N/A 8" N/A 3.4 9/25/2015 2L-308 50103206940000 2141510 35" 0.10 16" 9/11/2015 4.25 9/25/2015 2L-314 50103206860000 2140230 24" 0.20 15" 9/11/2015 4.25 9/25/2015 2L-316 50103207040000 2150060 Surface NA 15" NA 3.4 9/25/2015 2L-328 50103206980000 2141890 12" NA 12" NA 4.25 9/25/2015 RECEIVED • STATE OF ALASKA • MAY 0 6 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AP6PCIRQ la.Well Status: Oil ❑ , Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ • Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service ❑ Stratigraphic Test LII 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: April 8,2015• 214-189/ • 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 February 18,2015• 50-103-20698-00 • 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 229'FNL,909'FEL,Sec.22,T1ON,R7E, UM March 17,2015. KRU 2L-328 • Top of Productive Horizon: 8. KB(ft above MSL): 156'RKB 15.Field/Pool(s): 2061'FNL, 1493'FWL,Sec.25,T1ON, R7E, UM GL(ft above MSL): 115'AMSL Kuparuk River Field . Total Depth: 9.Plug Back Depth(MD+TVD): 106'FSL,2439'FEL,Sec.25,T1ON, R7E, UM 16148'MD/5530'TVD Tarn Oil Pool , 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-460742 y- 5927618 Zone-4 •16168'MD/5530'TVD ADL 380051,380052,380053 TPI: x-468397 y- 5920471 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-469733 y- 5917353 Zone-4 nipple @ 550'MD/550'TVD 4602 18.Directional Survey: Yes ❑✓ • No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1395'MD/1380'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res/Neutron/Density not applicable 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 164.8# A106B 28' 114' 28' 114' 24" pre-installed 10.75" 45.5# L-80 39' 2500' 39' 2293' 13.5" 1118 sx Class G,212 sx Class G 7.625" 29.7# L-80 36' 11832' 36' 5156' 9.875" 984 sx GasBLOK 7.625" 39# TN110S 11832' 12266' 5156' 5285' 9.875" included above 4.5" 12.6# L-80 12156' 16163' 5252' 5530' 6.5" frac sleeve 24.Open to production or injection? Yes LJ No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 3.5" 12156' 12023'MD/5213'TVD frac sleeve from 13226-15139'MD 5471'-5530'TVD 12156'MD/5252'TVD 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Yes❑ No °: /�i DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED none 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) waiting on post-rig well work Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No a Sidewall Cores Acquired? Yes ❑ No ❑✓ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE For4401RRep e(2012 � e/25-//5- A 1714,/DO EVERSE RBDMS, MAY - 6 20#.omitoriginal only 29. GEOLOGIC MARKERS(List all formations and mar•ncountered): 30. t FORMATION TESTS NAME MD TVD Well tested? Yes Q No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1395' 1380' needed,and submit detailed test information per 20 AAC 25.071. Top Bermuda 12757' 5414' Top Bermuda Seismic 13002' 5446' N/A Formation at total depth: Bermuda 31. LIST OF ATTACHMENTS Summary of Daily Operations, schematic,directional survey,cement detail reports 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Callahan @ 263-4180 ire"',ecEmail: Mike.Callahan(a)conocophillips.com Printed Name G. L.Alvord Title: Alaska Drilling Manager Signature —c Ga.� Phone 265-6120 Date 5-1 '2,0 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases 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. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation, or Other.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 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: 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 26: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 • • Guhl, Meredith D (DOA) From: Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent: Tuesday, October 13, 2015 1:38 PM To: Guhl, Meredith D (DOA) Cc: Bettis, Patricia K (DOA) Subject: RE: KRU 2L-328, PTD 214-189, Complete List of Geologic Markers Required Meredith, apologies for not getting back to you with this sooner. As requested, here are all of the tops observed from 2L-328. Please let me know if this is what you are looking for or if you would like any more information. Top/Marker MD actual TVD actual TVDSS 10 3/4" Casing Shoe 2,509' 2,281' -2,126' C-80 2,863' 2,472' -2,317' Campanian Sand 3,055' 2,534' -2,379' C-50 7,416' 3,842' -3,687' C-40 8,681' 4,242' -4,087' C-37 9,343' 4,413' -4,258' Iceberg 9,853' 4,566' -4,411' T-7 11,073' 4,926' -4,771' T-6 11,433' 5,035' -4,880' T-5 11,809' 5,150' -4,995' T-4.1 11,898' 5,177' -5,022' T-4 12,267' 5,290' -5,135' 7-5/8" Casing Shoe 12,266' 5,286' -5,131' T-3.1 12,448' 5,339' -5,184' T-3 12,677' 5,400' -5,245' Top Berm 12,758' 5,416' -5,261' Thanks, Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office: (907) 263-4180 Cell: (907) 231-2176 From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Tuesday, October 06, 2015 4:04 PM To: Callahan, Mike S Cc: Bettis, Patricia K (DOA) Subject: [EXTERNAL]KRU 2L-328, PTD 214-189, Complete List of Geologic Markers Required Scott, 1 During a review of the 10-407 form submitted for KRU 2L-328, PTD 214-189, compiled 4/8/2015, it was noted that the geologic markers box lacked detail. Box 29: Geologic Markers and Formations: Only the Top and Seismic Top Bermuda are listed. Please provide a complete list of all geologic formations and markers encountered in this wellbore. The 10-407 form is designed to be a complete and concise record of all data obtained in the completion of a well. Please make sure each well completion form is filled out correctly and fully so that all data is readily available for future users of the AOGCC archive. Please provided the complete list of formations and markers by October 13, 2015. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave,Suite 100,Anchorage,AK 99501 meredith.guhl(c@alaska.gov Direct: (907) 793-1235 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 Meredith Guhl at 907-793-1235 or meredith.guhlPalaska.gov. 2 KUP PROD 2L-328 ConocoP'hillips Well Attributes •Max Angle&MD TD Alaska.Inc. Wellbore API/UWI Field Name Wellbore Status ncl 7) MD(ftKB) Act Btm(ftKB) - ;.;lenpG _a 501032069800 TARN PARTICIPATING AREA PROD 16,168.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2L-328,4/23/20154'45;37 PM SSSV:NIPPLE Last WO: 39.60 Vertical schematic(actual) - Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;35.1- )(ag, g Last Tag. Rev Reason:NEW WELL smsmith 4/13/2015 nar, ter® I 1�Casing Strings II II Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Sot Depth(TVD)... Wt/Len(I...Grade Top Thread SO Reducing;699 CONDUCTOR 16 15.250 36.0 114.0 114.0 62.50 H-40 Weld Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB( Set Depth(ND)...Wt/Len(I...Grade Top Thread .AA/CONDUCTOR;36.0-114.0AI -. SURFACE 10 3/4 9.950 39.0 2,500.0 2,282.6 45.50 L-80 TSH 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread NIPPLE;550.8 INTERMEDIATE 75/8 6.875 35.9 12,266.2 5,285.4 29.70 L-80 Hydri1563 Casing Description OD(in) ID(in) Top(ftKB( 'Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread j 1 LINER-51/2"x41/2" 41/2 3.958 12,156.3 16,163.0 5,530.0 12.60 L-80 IBT-m @12190.21 SURFACE;39.0-2,5000 - - Liner Details Nominal ID GAS LIFT;2,983.9 Top(ftKB( Top(TVD((ftKB) Top Ind 7) Item Des Com (in) 12,156.3 5,252.3 72.71 PACKER BAKER HRD-E ZXP LINER TOP PACKER 4.820 • 12,178.3 5,258.9 72.53 NIPPLE BAKER RS SEAL NIPPLE 4.250 GAS LIFT;6,449.8 12,180.6 5,259.6 72.51 HANGER BAKER FLEX-LOCK LINER HANGER 4.790 • 12,190.2 5,262.5 72.43 XO Reducing 5.5"Hyd 563 box x 4.5"IBT pin Crossover Coupling 3.940 GAS LIFT;8,983.6 , - • 13,004.7 5,446.8 84.15 SWELL BAKER SWELL PACKER H-1 3.958 PACKER GAS LIFT;10,840.6 • 13,225.6 5,471.4 83.10 FRAC PORT FRAC SLEEVE W/2.125"BALL,SEAT ID 2.073"-#7 3.950 ..': 13,447.2 5,492.7 86.97 SWELL BAKER SWELL PACKER G-1 3.958 PACKER GAS LIFT;11,915.7 _ 13,669.4 5,496.9 89.53 FRAC PORT FRAC SLEEVE W/2.063"BALL,SEAT ID 2.015"-#6 3.940 SLEEVE;11,973.9 • 13,889.0 5,499.2 89.07 SWELL BAKER SWELL PACKER F-1 3.958 PACKER GAUGE:11,998.0 14,111.2 5,505.3 87.64 FRAC PORT FRAC SLEEVE W/2.000"BALL,SEAT ID 1.948"-#5 3.920 PACKER;12,023.0 2 "Ill14,331.1 5,512.2 89.21 SWELL BAKER SWELL PACKER E-1 3.958 x0 Threads;12,030.9 PACKER ` 14,553.1 5,515.8 88.83 FRAC PORT FRAC SLEEVE W/1.938"BALL,SEAT ID 1.885"-#4 3.940 NIPPLE;12,1132 14,775.0 5,522.2 87.85 SWELL BAKER SWELL PACKER D-1 3.958 LOCATOR;12,134.8-e PACKER .1" ` 14,999.5 5,530.9 88.69 FRAC PORT FRAC SLEEVE W/1.813"BALL,SEAT ID 1.760"-#3 3.930 MULE SHOE;12,155.0 15,181.7 5,532.8 89.96 SWELL BAKER SWELL PACKER C-1 3.958 PACKER II 15,366.2 5,533.7 89.81 FRAC PORT FRAC SLEEVE W/1.688"BALL,SEAT ID 1.635"-#2 3.930 X''=' AO r 15,547.7 5,532.3 90.40 SWELL BAKER SWELL PACKER B-1 3.958 INTERMEDIATE;36.0-12,266.2 PACKER 15,731.7 5,532.2 89.93 FRAC PORT FRAC SLEEVE W/1.563"BALL,SEAT ID 1.510"-#1 3.950 15,913.0 5,531.9 90.31 SWELL BAKER SWELL PACKER A-1 3.958 PERFP;13,225.6-13,228.3 _i I: PACKER 16,135.8 5,530.1 90.30 FRAC PORT PRESSURE ACTIVATED FRAC SLEEVE 3.840 16,148.7 5,530.0 90.30 WIV WELLBORE ISOLATION VALVE 3.950 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection PERFP;13,669.4-13,672.2-1 1_ TUBING-41/2 x3 31/2 2.992 35.1 12,156.3 5,252.3 9.30 L-80 EUEBrd 1/2 @ 69.85 Completion Details Nominal ID Top(ftKB) Tap(TVD)(ftKB) Top Incl 7) Item Des Com (in) 35.1 35.1 0.00 HANGER CAMERON TUBING HANGER 3.900 PERFP;14,111.2-14,114.0 i t- 69.9 69.9 0.30 XO Reducing Crossover4 1/2"IBTM b x 3 1/2"EUE8rd p 3.18 NIPPLE CAMCO DS NIPPLE 2.992 550.7 550.6 2.875 11,973.9 5,198.6 72.89 SLEEVE BAKER CMU SLIDING SLEEVE-CLOSED 2.810 11,998.0 5,205.7 72.88 GAUGE SLB GAUGE CARRIER 2.913 PERFP;14,553.1-14,555.9-_1 j_ 12,023.0 5,213.0, 72.87 PACKER BAKER PREMIER PACKER 2.880 12,113.2 5,239.6 72.90 NIPPLE CAMCO D NIPPLE W/RHC PLUG 2.750 12,134.8 5,245.9 72.88 LOCATOR BAKER SPECIAL SHEAR FLUTED NO GO LOCATOR 3.000 12,135.9 5,246.3 72.87 NO GO SUB BAKER SPECIAL SHEAR LOCATOR 3.000 12,155.0 5,251.9 72.72 MULE SHOE BAKER SPEICAL SHEAR TYPE WLEG 3.000 PERFP;14,999.5-15,002.2-_9 I_ Perforations&Slots snot Dens Top(ND) Bim(TVD) (shols/f Top(ftKB( Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com PERFP;15,3662-15,368.9-_j j_ 13,225.6 13,228.3 5,471.4 5,471.7 4/3/2015 PERFP FRAC SLEEVE#7 13,669.4 13,672.2 5,496.9 5,496.9 4/3/2015 PERFP FRAC SLEEVE#6 14,111.2 14,114.0 5,505.3 5,505.4 4/3/2015 PERFP 'FRAC SLEEVE#5 14,553.1 14,555.9 5,515.8 5,515.8 4/3/2015 PERFP FRAC SLEEVE#4 14,999.5 15,002.2 5,530.9 5,531.0 4/3/2015 PERFP FRAC SLEEVE#3 PERFP;15,731.6-15,734.4--1 j_ 15,366.2' 15,368.9 5,533.7 5,533.7 4!3/2015 PERFP FRAC SLEEVE#2 15,731.7 15,734.4 5,532.2 5,532.2 4/3/2015 PERFP FRAC SLEEVE#1 16,135.8 16,138.6 5,530.1 5,530.1 4/3/2015 PERFP PRESSURE FRAC SLV PERFP;18,135.8-16,138.6-_I I l,. LINER-512'x412' i 411219021;12,156.3-16,163.0N S KUP PROD • 2L-328 ConocoPhillips 01 Alaska,IOC, ConocaPNpps 2L-328,4/23/2015 4:45 40 PM Vertcal schematic(actual) HANGER,35.1-) 4031:111315 ,, ,,,, Mandrel Inserts XO Reducing',69.9 ,w y t li Top(TVD) Valve Latch Port Size TRO Run .A /CONDUCTOR,36.0-114.0 i N Top(RKB) (RKBMGKB) Make Model OD(in) Sery Type Type (in) (psi) m Run Date Co 1 2,988.9 2,514.2 CAMCO 1 GAS LIFT DMY BK u 0.000 0.0 3/4/2015 A NIPPLE;550.8 A 2 6,449.8 3,556.8 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 3/4/2015 3 8,983.6 4,304.7 CAMCO KBMG 1 GAS LIFT SOV BEK 0.000 2,500.0 3/4/2015 DCK-2 F 4 10,840.6 4,857.9 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 3/4/2015 SURFACE;39.0-2,500.0 - 5 11,915.7 5,181.4 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 3/4/2015 GAS LIFT;2,9999 Notes:General&Safety End Date Annotation NOTE: GAS LIFT;6,449.8 GAS LIFT;8,983.6 GAS LIFT;10,840.6 GAS LIFT;11,915.7 _ SLEEVE;11,973.9 . , - GAUGE;11,998D PACKER;12,023.0 ::-- - . XO Threads;12,030.9 NIPPLE;12,113.2 LOCATOR;12,134.8 MULE SHOE;12,155.0 / INTERMEDIATE;36.0-12266.2 Ai I PERFP;13,225.6-13,228.3- PERFP;13,669.4-13,672.2 PERFP',14,111 2-14,114.0 PERFP;14,553.1-14,555.9 PERFP;14,999.5-15,002.2 PERFP;15,366.2-15,368.9 PERFP;15,731.6-15,734.4 PERFP;16,135.8-16,138.6- LINER-5121it 412' ©1219021;12,156.3-186,163.0 • • ConocoPhiIlips Time Log & Summary WelIview Web Reporting Report Well Name: 2L-328 Rig Name: DOYON 25 Job Type: DRILLING ORIGINAL Rig Accept: 2/17/2015 8:30:00 AM Rig Release: Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/15/2015 24 hr Summary RD from well and scope derrick down. Swap all modules to cold starts and lower cattle chute. Move casing module and 12:00 00:00 12.00 0 0 DEMOB MOVE MOB P Perform derrick inspection prior to scoping derrick. RD,scope down derrick and break interconnects. Split casing module, power module and pump from pits and move pit module away from sub. Skid rigfloor, LD derrick. 02/16/2015 RDMO of 2L-308. Staging modules in position to hook up with trucks to move Sub over new well. Move in with modules mate up and raise derrick. Mate of pits to sub. 00:00 06:00 6.00 MIRU MOVE MOB P Continue to lower derrick, Lower cattle chute into pipe shed. Remove grating and raid=se cellar. Unpin pipe shed from sub and walk out. Latch onto Sow and pull away. 06:00 12:00 6.00 MIRU MOVE MOB P Move sub out from well and hook up to Sow and pull off mats to stage. Shuffle mats to 2L-328 and place with herculite and Handi-berm around cellar. Pull sub in with Sow and spot over well 2L-328 with stompers. Latch Sow to pipeshed and pull to next to sub. 12:00 18:00 6.00 MIRU MOVE MOB P Continue to spot pipe shed under sub,shim shed and sub. Pin sub and pipe shed. 18:00 00:00 6.00 MIRU MOVE MOB P Shim casing shed. Raise derrick and pin derrick. Skid rigfloor to well center. Spot and shim pit module, spot pump module and power complex. 02/17/2015 R/U and accept rig @ 08:30 hrs. Continue rigging up, service rig and load casing shed with 5" DP,take on 580 bbl mud.Tag ice plug @ 45', prep for diverter test and cleanout. 00:00 01:30 1.50 0 0 MIRU MOVE MOB P Spot pump and power complexes, raise cattle chute, install chicken coop, raise lower cattle chute, lower and shim cellar walls. 01:30 06:15 4.75 0 0 MIRU MOVE RURD P Plug in electrical interconnects, swap power from cold starts to 3516. M/U pits, pump and power interconnects, install cellar grating and chink cellar. Prep derrick for scoping. Page 1 of 61 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:15 08:30 2.25 0 0 MIRU MOVE RURD P Spool drill line, unpin blocks and bridle up, scope up derrick. 178k-195k. Remove bridle lines and yokes. Install kelley hose. Complete rig acceptance checklist, rig accepted @ 08:30 2/17/15. 08:30 12:00 3.50 0 0 MIRU MOVE NUND P Bring riser to rig floor. Nipple up 17' surface riser, bag and pitcher nipple. Rig up Joe's box, flow line and jet lines. 12:00 13:30 1.50 0 0 MIRU MOVE NUND P Rig up 4"conductor valves,energize starting head seals and test 500 psi 15 minutes. SIMOPS-C/O gear oil and hydraulic oil in top drive. 13:30 16:15 2.75 0 0 MIRU MOVE RURD P Continue N/U flowline, C/O 12"air boots. Load casing shed with 216 jts of 5"DP. Test gas alarms. H2S 10 ppm low,20 ppm high, LEL 20%low, 40%high. Continue servicing top drive, SIMOPS-Take on 580 bbl DRILPLEX surface mud in pits. 16:15 16:30 0.25 0 0 MIRU MOVE RURD P PJSM, pull 600V power cord from shop and plug into rig power. 16:30 17:45 1.25 0 0 MIRU MOVE RURD P Pull master bushings and chink Joes flow box. 17:45 20:30 2.75 0 0 MIRU MOVE RURD P Continue loading casing shed with 5" drill pipe, SIMOPS-C/O saver sub to 4'/2'IF. Install 5"DP elevators, spot parts connexes. 20:30 21:00 0.50 0 0 MIRU MOVE PULD P P/U 5" DP double, RIH and tag ice plug @ 44.75'. 21:00 23:00 2.00 0 0 MIRU MOVE SLPC P PJSM cut and slip drilling line, Hang blocks, cut 86', slip 86'back on drum. Calibrate block height Totco and Amphion. 23:00 00:00 1.00 0 0 MIRU MOVE RURD P Energize accumulator, inspect hoses and lines for leaks. Gather conductor C/O BHA, continue loading pipe shed with DP. 02/18/2015 Perform diverter function test(witnees waived), M/U bit and clean out ice to 95'. P/U 5"DP. Continue cleanout per program, M/U BHA and cleanout to 227'.Adjust motor to 1.5°, M/U drilling BHA. 00:00 00:30 0.50 0 0 MIRU MOVE RURD P Function test accumulator, inspect lines and equipment. 00:30 01:00 0.50 0 0 MIRU MOVE BOPE P Diverter function and accumulator test.AOGCC Matt Herrera waived witness. System pressure=3000 psi, Pressure after functioning knife valve and annular=1775 psi. 200 psi attained=13 seconds, Full system pressure attained=157 seconds. Knife valve opened=9 seconds, Annular closed=30 seconds.6 bottle N2 average=2066 psi. 01:00 01:45 0.75 0 0 MIRU MOVE BHAH P M/U cleanout BHA, Bit, bit sub,XO to 5"DP doubles. Page 2 of 61 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:45 02:00 0.25 0 0 MIRU MOVE SEQP 'P Flood lines and PT surface lines to 3500 psi(Good). Fill stack with fresh water and check for leaks(Good). 02:00 02:45 0.75 0 0 MIRU MOVE DRLG P Drill out conductor ice from 45'MD to 100'MD @ 212 gpm,40 psi, 18% flow out,40 rpm, 1.5k Tq. Make room to pick up drill pipe via rotary table. 02:45 03:30 0.75 0 0 MIRU MOVE BHAH P L/D 2 5"DP doubles and clean out BHA. 03:30 04:00 0.50 0 0 MIRU MOVE SFTY P Pre-Spud meeting with night rig crew, Tour pusher, MI, SLB and CPAI WSL. Discussed diverting shallow gas, performed table top divert and rig evac drill. 04:00 12:00 8.00 0 0 MIRU MOVE PULD P M/U stands of 5"DP, picked up 216 singles and 6 doubles. 12:00 16:15 4.25 0 0 MIRU MOVE PULD P Continue picking up 5"DP doubles, P/U 54 doubles total. 16:15 17:15 1.00 0 0 MIRU MOVE PULD P P/U 12 jts 5" HWDP,jars, 5 jts HWDP. 17:15 18:00 0.75 0 0 MIRU MOVE BHAH P P/U 3jts 7"NM DC, stand back in derrick. 18:00 19:00 1.00 0 0 MIRU MOVE BHAH P PJSM, M/U 13%"cleanout BHA 19:00 19:30 0.50 0 114 MIRU MOVE DRLG P RIH to 95',establish pump rate at 300 gpm 110 psi,400 gpm 212 psi 45%flow out. 30 rpm 1k Tq. Clean out to 114' MD conductor shoe. 19:30 21:00 1.50 114 227 SURFA( DRILL DDRL P Drill 13W surface hole from 114' MD to 227' MD,450 gpm 340 psi. 65-75%flow out, 30 rpm @ 1k Tq, 6k WOB. Circulate clean and blow down top drive. 21:00 21:30 0.50 227 0 SURFA( DRILL BHAH P POOH from 227' MD, stand back 5" HWDP, L/D BHA. 21:30 00:00 2.50 0 122 SURFA( DRILL BHAH P Break motor and adjust bend to 1.5 degree, scribe motor, Gyro and MWD. M/U BHA to 122'MD. 32/19/2015 Continue drilling 13%"surface from 227' MD to 1550' MD, 1531'TVD per program. Hydrates at 1340' MD 5271 units gas. Gyro survey until 1297' MD. Held CPAI safety discussion 1 with both crews and contractors, CPAI/RLG. 00:00 00:30 0.50 122 122 SURFA( DRILL BHAH P Continue M/U BHA, P/U DC's and RIH. 00:30 01:30 1.00 122 210 SURFA( DRILL SRVY P Obtain Gyro surveys @ 122'and 210'. Page 3 of 61 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 12:00 10.50 210 868 SURFA( DRILL DDRL P Directional drill 13%"surface hole from 227' MD to 868'MD, 865'TVD. 675 gpm @ 1165 psi, 55%flow out, 70 rpm, Torque on/off=3k/1k, 15k WOB, ECD=10.54, P/U=82k, S/O=85k, ROT=83k.ADT=4.8, AST=2.73,ART=2.07. Total bit hrs=4.8, Total jar hrs=4.8. Obtain Gyro survey every stand. Experience flowline packing off at Totco flow paddle due high gravel returns. remove paddle temporarily using Amphion flow out indicator. 12:00 18:00 6.00 868 1,084 SURFA( DRILL DDRL P Directional drill 13'/2'surface hole from 868'MD to 1092'MD, 1084' TVD. 700 gpm @ 1365 psi, 59%flow out,60 rpm, Torque on/off=3k/1 k, 15k WOB, ECD=10.53, P/U=86k, S/O=90k, ROT=90k.ADT=2.4, AST=1.0,ART=1.4.Total bit hrs=7.2, Total jar hrs=7.2 Obtain Gyro survey every stand. 18:00 21:30 3.50 1,084 1,436 SURFA( DRILL DDRL P Directional drill 13'/2'surface hole from 1092'MD to 1436'MD, 1415' TVD. 725 gpm © 1590 psi, 59%flow out,60 rpm,Torque on/off=3k/1 k, 15k WOB, ECD=10.3, P/U=92k, S/O=95k, ROT=95k. Last Gyro survey at 1297.77' MD. 21:30 22:30 1.00 1,436 1,436 SURFA( DRILL CIRC T Circulate @ 400 gpm to smooth out gas cut mud system. Drilled into gas hydrates @ base permafrost starting at 1340' MD, max gas units 5271. Entrained gas in mud cavitating in charge pumps,degasser, hopper and hole fill pumps. Condition surface system with Skreenkleen and water to regain pumpability. Pressure balance 9.6 ppg, non-pressure balance<6.5 ppg. 22:30 00:00 1.50 1,436 1,550 SURFA( DRILL DDRL P Directional drill 13'/2'surface hole from 1436'MD to 1550'MD, 1531' TVD. 725 gpm @ 1590 psi, 59%flow out,60 rpm,Torque on/off=3k/1 k, 15k WOB, ECD=10.53, P/U=92k, S/O=95k, ROT=95k.ADT=3.31, AST=1.76,ART=1.55. Total bit hrs=10.5, Total jar hrs=10.5. 02/20/2015 Continue drilling 13'/2'surface from 1550'MD per program to TD+-2517' MD. Circulate hole clean and POOH 1580'MD. CBU and backream to HWDP. Page 4of61 Time Logs • .' Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 1,550 2,055 SURFA( DRILL DDRL P Directional drill 13W surface hole from 1550'MD to 2005'MD, 1937' TVD. 720 gpm @ 1650 psi, 58%flow out, 60 rpm, Torque on/off=4k/1 k, 15k WOB, ECD=10.67, P/U=111k, S/0=103k, ROT=106k.ADT=4.35, AST=3.2,ART=1.15.Total bit hrs=14.85,Total jar hrs=14.85. 06:00 12:00 6.00 2,055 2,383 SURFA( DRILL DDRL P Directional drill 13W surface hole from 2005'MD to 2383' MD,2214' TVD. 720 gpm @ 1830 psi, 56%flow out,60 rpm, Torque on/off=6k/2k, 23k WOB, ECD=10.48, P/U=114k, S/0=106k, ROT=107k.ADT=4.2, AST=2.81,ART=1.39. Total bit hrs=19.05,Total jar hrs=19.05. 12:00 14:00 2.00 2,383 2,517 SURFA( DRILL DDRL P Directional drill 13W surface hole from 2005'MD to 2517'MD,2293' TVD. 720 gpm @ 1810 psi, 56%flow out, 60 rpm, Torque on/off=6k/3k, 15k WOB, ECD=10.49, P/U=110k, S/0=106k, ROT=107k.ADT=1.15, AST=.37,ART=.78. Total bit hrs=20.26,Total jar hrs=20.26. Geologist Kelly Umlauf called TD pick. 14:00 17:30 3.50 2,517 2,166 SURFA( CASING CIRC P Circulate while rotating, stand back a stand every 30 minutes to 2166'MD. 720 gpm, 1680 psi, 56%flow out,60 rpm, 2-4k Tq, Total strokes pumped 24,000(6 bottoms up)shakers clean. Mud weight in/out 9.7+. P/U=110k, S/0=106k, ROT=107k. 17:30 18:15 0.75 2,166 2,166 SURFA( CASING OWFF P Blow down top drive and observe well for 30 minutes while rotate 20 rpm per program. 3.5k Tq.Well static with slight drop due hydrates breaking out. 18:15 20:30 2.25 2,166 1,583 SURFA( CASING TRIP P POOH on elevators from 2166'MD to 1583' MD. Enounter 40k overpull on each stand,drop and wipe repeatedly to work through until 1583' MD. Made 5 attempts to pull through without success. Called engineer, decide to stop drop and roll. 20:30 21:15 0.75 1,583 1,720 SURFA( CASING CIRC T RIH 1 stand to 1720'MD. Circulate while rotating 60 rpm, 700 gpm 1490 psi,2.5k Tq, Pull @ 180 fph while pumping 2 bottoms up. 21:15 21:45 0.50 1,720 1,620 SURFA( CASING TRIP T Attempt to POOH on elevators, pulled 40k over repeatedly at 1580' MD. RIH to 1620'MD to commence BROOH. 21:45 00:00 2.25 1,620 776 SURFA( CASING BKRM P M/U Top drive and backream out of hole, 600 gpm, 60 rpm, 25 fpm to base permafrost 1400', reduce pump rate to 500 gpm. BROOH to 776' MD, HWDP. Page 5 of 61 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 32/21/2015 24 hr Summary Lay down BHA, perform dummy run with hanger. R/U Volant and run 10%"45.5#L-80 H563 to 2464', P/U landing joint and hanger. 00:00 00:30 0.50 776 679 SURFA( CASING CIRC P Circulate while R&R from 776' MD to 679'MD @ 400 gpm, 535 psi,42% flow out, 2k Tq. 1991 stks total shakers cleaned up good. 00:30 02:00 1.50 679 214 SURFA( CASING TRIP P POOH on elevators, racking back HWDP. Lay down jar stand, continue rack back HWDP to 214'MD. Monitor well via trip tank. 02:00 05:00 3.00 214 0 SURFA( CASING BHAH P PJSM, lay down BHA per SLB DD/MWD reps. Rack back NMDC, L/D BHA. 05:00 07:00 2.00 0 0 SURFA( CASING RURD P Clean and clear rig floor,send out BHA tools, rig down bails and elevators. 07:00 08:30 1.50 0 0 SURFA( CASING RURD P Drain stack, P/U casing equipment. Rig up long bails,4'extension, spiders, Volant tool. M/U hanger to landing joint and perform dummy run with Cameron rep. L/D landing joint. 08:30 12:00 3.50 0 257 SURFA( CASING PUTB P PJSM picking up casing. Pick up 10%"45.5#L-80 H563 casing per running order. Baker Lok shoe track, torque connections to 18,000 ft/lbs with Volant CRT. RIH to 145'MD. Fill pipe stage pumps up to 8 bpm, 125 psi,28%flow out. Check floats, continue RIH to 257' MD filling on the fly,topping off every 10 jts. Install bow spring centralizers on every joint, 3 on shoe track on stop collars. 12:00 16:00 4.00 257 748 SURFA( CASING PUTB P Continue RIH with 10%"45.5#L-80 H563 casing from 257'to 748' MD, filling casing on the fly topping off every ten joints. Identified bad connection,joints#19 box end#20 pin end. 16:00 17:30 1.50 748 708 SURFA( CASING PUTB T Swap out joints 19&20 with 68&69 due galled threads. 17:30 22:30 5.00 708 2,314 SURFA( CASING PUTB P Continue RIH with 10%"45.5#L-80 H563 casing from 708'to 2314'MD, filling casing on the fly topping off every ten joints plus pump additional 40 bbl. 22:30 23:30 1.00 2,314 2,352 SURFA( CASING PUTB P CBU while washing down JT#60 from 2314'MD to 2352'MD, staging pumps up to 4 bpm, 210 psi, 22% flow out. 23:30 00:00 0.50 2,352 2,464 SURFA( CASING PUTB P Continue RIH with 10%"45.5#L-80 H563 casing from 2314'MD to 2464' MD. Prep to M/U hanger. Total losses while running casing 111 bbl. Page 6 of 61 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 02/22/2015 24 hr Summary Land hanger, circulate and condition mud for cement. Pump surface cement job per program, could not set on landing ring. N/D diverter, P/U 140k and set emergency slips. Cut pipe and weld on transition nipple,wrap with insulation and allow to cool 4 hrs. 00:00 01:30 1.50 2,464 2,507 SURFA( CASING HOSO P M/U landing joint to hanger, stage pumps up to 4 bpm,206 psi,21% flow out.Wash down, landing hanger on depth @ 2507'MD, P/U=136k, S/0=104k. 01:30 03:00 1.50 2,507 2,507 SURFA( CEMEN-CIRC P Circulate and condition mud for cement job, stage pumps up to 8 bpm,266 psi, 33%flow out, reciprocate from 2505' MD to 2481' MD, land hanger every 5th stroke. Condition for 5 bottoms up total 8000 strokes. SIMOPS-clean and clear rig floor, send out casing equipment. 03:00 03:30 0.50 2,507 2,507 SURFA( CEMEN-RURD P Rig up cement hose to cement swivel, blow down top drive. 03:30 05:30 2.00 2,507 2,507 SURFA( CEMEN-CIRC P Establish circulation via cement line and continue conditioning @ 8 bpm while reciprocating pipe. 8 bpm=375 psi 29%flow out. P/U=140k, S/0=107k. SIMOPS-PJSM with CPAI, SLB, Doyon on cementing surface casing. Note:Circulated a total of 1698 bbls while conditioning mud and hole. 05:30 09:30 4.00 2,507 2,500 SURFA( CEMEN-CMNT P Pump surface cement job per program, SLB pump 5 bbl water,test lines to 3500 psi-good. SLB pumped 199.5 bbl 10.5 ppg MudPush II @ 5 bpm, 120 psi 20%flow. Shut down, break out Volant tool and drop bottom plug,follow with 380.4 bbl 11.0 ppg lead cement @ 6.5 bpm, 230 psi 23%flow, 62.7 bbl 12.0 ppg Tail cement 6 bpm, 366 psi 17%flow P/U=149k, S/O=74k.Taking weight and unable to land hanger. Break out Volant and drop top plug, M/U and kick out plug with 10 bbl water. 09:30 10:30 1.00 2,500 2,500 SURFA( CEMEN-CMNT P Swap to rig pumps, attempt to catch cement @ 6 bpm,405 psi,0% returns while attempting to seat on landing ring(unseccessful). Divert returns to cellar, reduce rate to 3 bpm. ICP=269 psi, FCP=536 psi. Bump plug @ 2193 stks(220.8 bbl) pressure to 1039 psi. Bleed off and check floats-good. 79.9 bbl cement to surface,41 bbl lost during cement job. CIP 0955 hrs 2/22/2015. Page 7 of 61 Time Logs III Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 10:30 12:00 1.50 2,500 2,500 SURFA( CEMENT RURD P Flush stack with black water pill, suck out cellar box,flush flowline with black water pill. Clean cementing Demco valves, send out casing equipment. P/U casing spool, pull master bushings. Begin nipple down to set emergency slips. 12:00 14:45 2.75 2,500 2,500 SURFA( WHDBO WWWH T Break apart surface stack, clean Joes box&nipple down flowline, pull pitcher nipple, remove diverter line& pull out of cellar. Raise surface bag, riser and diverter tee 2'3"to facilitate setting emergency slips. Block up annular carrier with 4"square tubing. 14:45 15:15 0.50 2,500 2,500 SURFA(,WHDBO HOSO T Clean out bowl&install emergency slips per Cameron wellhead rep and setting procedure. Pull 150k hookload, slack off block weight for 110k set on slips. Remove Volant CRT from landing joint, P/U 1k on landing joint. 15:15 16:00 0.75 2,500 2,500 SURFA( WHDBO CUTP T Rough cut stump in cellar to drain landing joint. Cut joint above emergency slips. 16:00 18:45 2.75 2,500 2,500 SURFA( WHDBO NUND T Pull landing joint and hanger, break apart and L/D same. Set diverter tee, riser and annular down on riser adapter. Break apart and remove annular. Pull riser,tee and riser adapter, L/D same. 18:45 20:45 2.00 2,500 2,500 SURFA( WHDBO NUND T Weld on Cameron 11"emergency hanger WT-103 metal neck seal x 10%"slip on weld bottom. SIMOPS- Rig down Volant CRT and L/D. R/D 180"bails and install 132"bails. Lower casing and tubing spool to BOP deck. 20:45 00:00 3.25 2,500 2,500 SURFA( WHDBO NUND T Wrap 11"emergency hanger with insulation to cool. SIMOPS-Hold MPD introduction meeting with rig crew. Prep 7.625"casing in casing shed, clean and clear rig floor&BOP deck. 02/23/2015 Test transition nipple with N2 1600 psi, orient and N/U casing/tubing spool,test to 5000 psi 15 min. N/U BOPE, R/U MPD equipment. Process 7-5/8"casing 00:00 03:00 3.00 2,500 0 SURFA( WHDBO NUND T Waiting on Cameron 11"emergency hanger W/T103 metal seal neck x 10.75"slip on weld to cool. Test transition nipple with Nitrigen, inner weld failed. SIMOPS-clean organize rig, loading and prepping 7-5/8"casing. Send out PS-21 inserts, send out knife valve. Remove 4"dump valves from conductor, rig up MPD in BOP deck. 03:00 04:00 1.00 0 0 SURFA(WHDBO NUND T Re-weld inner weld on Cameron tranition nipple(emergency hanger) Page 8 of 61 Time Logs • Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 04:00 06:30 2.50 0 0 SURFA(WHDBO NUND T Wait on hanger to cool. SIMOPS- Continue staging MPD equipment in BOP deck, prep for nipple up BOPE and prep 7-5/8"casing. 06:30 07:00 0.50 0 0 SURFA( WHDBO PRTS T Cameron tested emergency hanger to 1600 psi witness by Co Man 15 minute test. 07:00 09:00 2.00 0 0 SURFA( WHDBO NUND P Orient casing spools per Cameron and CPAI rep. N/U and test to 5000 psi 15 minutes with hydraulic fluid. 09:00 12:00 3.00 0 0 SURFA( WHDBO NUND P Nipple up high pressure riser with 11" x 13-5/8"XO, remove dutch riser nipple from annular. SIMOPS- Continue MP-2 work orders, clean flow line dresser sleeve, change out air boots. Clean out and locate cement just below 4"conductor outlets. Cap the outlets, load 5"test joint in pipe shed. 12:00 16:00 4.00 0 0 SURFA( WHDBO NUND P Nipple up BOPE, install 12'6"high pressure riser, 2'riser, BOP stack. R/U fowline, choke and kill lines. 16:00 18:45 2.75 0 0 SURFA( WHDBO MPDA P Make up MPD RFCD. Slide in Joes box and chink. Fab trip nipple for RCD. SIMOPS-Prep 7-5/8"casing. 18:45 00:00 5.25 0 0 SURFA( WHDBO MPDA P Rig up MPD as per Safe-Kick and CPAI MPD reps. Install trip nipple, install power slips, M/U ball valve and 4"hi pressure hose to RCD. Hoist misc hoses and fittings to rig floor, lower to BOP deck. Install 4"drain line and plumb in lines for catch can. Tie in hole fill line&return line to flowline. 02/24/2015 Held MPD meeting w/SafeKick Rep.-Cont. RU MPD-Lower cattle chute for setting MPD manifold-Set MPD choke manifold in BOP bay w/crane-RUhoses to choke manifold-Lower cattle chute. Test BOPE, witness waived by AOGCC Bob Noble, 00:00 01:30 1.50 0 0 SURFA( CEMEN-SFTY P Held meeting w/SafeKick Rep. and rig crew on MPD 01:30 06:00 4.50 0 0 SURFA( CEMEN'MPDA P Cont. rigging up MPD-Install catch can&skirt to RCD, R/U hi&low pressure hoses-Remove&rotate RCD valve, Install cellar door, Prep cattle chute to lower for access to BOP bay- 06:00 11:00 5.00 0 0 SURFA( CEMEN MPDA P Cont. cleaning pits, Clean cellar& suck out cellar box-Cont. loading 7 5/8"csg,lower cattle chute, Remove BOP cradle stops 11:00 12:00 1.00 0 0 SURFA( CEMEN-MPDA P Prep to set SafeKick choke manifold into BOP bay w/crane-Went through pick plan w/crane operator and crew, made dry run to obtain boom angle-Held pre job meeting on making pick-Set choke manifold into BOP bay-raised cattle chute Page 9 of 61 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 16:15 4.25 0 0 SURFA( CEMEN-MPDA P Continue R/U MPD choke skid per MPD reps. M/U 4"and 2"hoses to skid. Shorten and connect Katch Kan drain line.Wire electrical to skid, paint drain lines. SIMOPS- Continue prepping 7.625"casing in pipe shed. SIMOPS-M/U safety valves for BOP test, open all ram doors on BOP, inspect rams. 16:15 17:45 1.50 0 0 SURFA( WHDBO RURD P M/U and set test plug per Cameron Wellhead rep, R/U testing equipment,flood lines and bleed air. Perform shell test on stack and manifold. SIMOPS-SafeKick rep perfoming system and communication checks on MPD systyem, choke to computer to HMI. 17:45 21:15 3.50 0 0 SURFA( WHDBO BOPE P Tested all BOPE to 250/3500 psi 5 min each charted, 5"TJ.AOGCC Bob Noble waived witness of test. Tested manual and super chokes to 250/2000 psi.Tested annular preventer, 2-7/8"x5%"Upper VBR's, 2-7/8"x5'/2'Lower VBR's, Choke valves 1-15, manual and super choke, manual and HCR choke and kill valves,4"valve on kill line, 5" TIW, 5"Dart valve, Upper and lower IBOP, Blind/shear rams. 21:15 21:45 0.50 0 0 SURFA(WHDBO BOPE P Perform acculmulator drawdown test, System pressure=3000 psi, Manifold=1500 psi, Pressure after functioning all rams and valves=1600 psi,200 psi attained=22 seconds with 2 electric pumps, full pressure attained=108 seconds with 2 electric and 2 air pumps. 6 bottle N2 average=1979 psi. Closing times; Annular=23 sec, UPR=16 sec, Blind/shear=17 sec, LPR=16 sec, HCR Choke=2 sec, HCR kill=2 sec. 21:45 22:00 0.25 0 0 SURFA(WHDBO RURD P Blow down choke line, pull test joint and power slips. 22:00 23:30 1.50 0 0 SURFA( CEMEN-MPDA P Install whipchecks on MPD skid lines. Remove trip nipple and install test nipple. R/U test lines to test MPD. Flood RCD and MPD skid lines with fresh water. • 23:30 00:00 0.50 0 0 SURFA( CEMEN'RURD P Install power slips&bearing stabbing table. Stab bearing on stand of 5" drill pipe. 02/25/2015 Install test cap and pressure test MPD system. M/U BHA and RIH to 2364'MD, C&C perform casing test 3000 psi. Drill CMT and FC to 2456' MD. S/D and perform choke and kill drill. Continue drilling CMT to shoe @ 2499' MD Page 10 of 61 Time LogsII Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:00 3.00 0 0 SURFA( WHDBO MPDA P Install MPD bearing on std of 5"DP- RU&test MPD choke skid to 250& 1000 psi-Pull MPD test nipple& install trip nipple-Blow down MPD skid 03:00 05:00 2.00 0 0 SURFA( WHDBO RURD P Drain stack-Pull test plug-Install wear bushing-Blow down kill line- Blow down test pump-Install PS-21 slips-Install Totco flow paddle 05:00 08:00 3.00 0 754 SURFA( CEMEN-BHAH P MU BHA#2-Bit-power drive w/9 7/8"stabilized control collar(non ported float)-Power drive receiver sub-PD flex collar-EcoScope- MWD-(3)7 1/4"NM flex DC's- Float/save sub w/non ported float- 7"well commander-12 HWDP- Jars-5 HWDP to 754'- 08:00 11:00 3.00 754 1,500 SURFA( CEMEN-PULD P RIH w/BHA f/754'to 1500'picking up doubles f/pipe shed 11:00 11:30 0.50 1,500 1,500 SURFA( CEMEN-RGRP T Change out wash pip 11:30 12:00 0.50 1,500 1,500 SURFA( CEMEN-EQRP T MPD service hands working in drillers cab trouble shooting electronic system 12:00 13:00 1.00 1,500 2,364 SURFA( CEMEN-PULD P RIH picking up doubles from 1500'to 2364'MD, P/U=109k, S/0=102k 13:00 13:15 0.25 2,364 2,364 SURFA( CEMEN-CIRC P Circulate while R&R from 2364'MD to 2269' MD @ 550 gpm, 1600 psi, 22%flow, 30 rpm,4.5k Tq. 13:15 13:45 0.50 2,364 2,364 SURFA( CEMEN'SVRG P Service top drive 13:45 14:30 0.75 2,364 2,364 SURFA( CEMEN-RGRP T Change out washpipe 14:30 14:45 0.25 2,364 2,364 SURFA( CEMEN-CIRC P Circulate while R&R from 2364'MD to 2269' MD @ 600 gpm, 1780 psi, 23%flow, 30 rpm,4.5k Tq. 14:45 15:15 0.50 2,364 2,364 SURFA( CEMEN-RURD P Blow down topdrive and R/U test equipment, flood lines. 15:15 16:30 1.25 2,364 2,364 SURFA( CEMEN-PRTS P Perform casing test 3000 psi 30 minutes charted. 16:30 16:45 0.25 2,364 2,364 SURFA( CEMEN RURD P B/D and R/D test lines. 16:45 17:00 0.25 2,364 2,364 SURFA( CEMEN-CIRCP Establish circulation and obtain MWD torque and drag parameters. 17:00 21:15 4.25 2,364 2,456 SURFA( CEMEN-DRLG P Drill out shoe track from 2404'MD to 2456'MD @ 450 gpm, 1030 psi, 16%flow,60 rpm, 6k Tq.TOC stringers=2404' MD,top of plugs 2415'MD 21:15 22:00 0.75 2,456 2,456 SURFA( CEMEN"CIRC P CBU while R&R from 2456' MD to 2361'MD @ 450 gpm, 1020 psi, 16%flow out, MW in/out 9.9 ppg Page 11 of 61 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:00 23:00 1.00 2,456 2,456 SURFA( CEMEN-SFTY P Take slow pump rates. Held kick while drilling drill, shut in well in casing. Safety meeting and perform choke and kill drill. Pressure up annulus to 200 psi, bump floats and read SIDPP, kill well through choke via pumpdown schedule. Post meeting, bleed and blow down. 23:00 00:00 1.00 2,456 2,499 SURFA( CEMEN DRLG P Continue drilling out shoe track from 2456'MD to 2499'MD @ 450 gpm, 1030 psi, 16%flow, 50 rpm, 5k Tq. Tag top of shoe @ 2497' MD 02/26/2015 Drilled out shoe&20' new hole-Change well over to 9.6 ppg LSND mud-Perform FIT to 16.0 ppg-Slip& cut drill line-Install MPD bearing&commission MPD choke skid-pull MPD bearing&install trip niple- Drilled 9 7/8"hole to 3479'-Circ 00:00 01:30 1.50 2,499 2,517 SURFA( CEMEN'DRLG P Cont. drilling on float shoe@ 2499' - Clean out rat hole to 2517' WOB 15 k RPM 50 GPM 450 @ 1052 psi String wt PU 112 SO 101 ROT 106 Torque 5/6 k 01:30 02:00 0.50 2,517 2,537 SURFA( CEMEN-DDRL P Drilled 20'new hole f/2517'to 2537' MD 2305'TVD ADT-.21 hrs Jar hrs. .21 hrs WOB 15 k RPM 50 GPM 450 @ 1052 psi String wt PU 112 SO 101 ROT 106 Torque 5/6 k 02:00 03:00 1.00 2,537 2,468 SURFAt CEMEN"DISP P Displace well f/10.0 ppg Driplex to 9.6 ppg LSND mud @ 450 gpm- rotate&recip pipe-Obtain SPR's- Pull back to 2468' SPR's @ 2537'@ 0240 hrs. #1 20 spm @ 90 psi 30 spm @ 130 psi #2 20 spm @ 100 psi 30 spm @ 130 pis 03:00 04:30 1.50 2,468 2,468 SURFA( CEMEN-FIT P RU&perform FIT to 16.0 ppg EMW w/9.6 ppg mud w/763 psi @ 2293' TVD-RD&blow down lines 04:30 07:00 2.50 2,468 2,468 INTRM1 DRILL SLPC P PJSM-Slip&cut 572'drill line- Calibrate block height 07:00 07:30 0.50 2,468 2,468 INTRM1 DRILL SVRG P Service TD&blocks 07:30 13:00 5.50 2,468 2,468 INTRM1 DRILL MPDA P Pull PS21 slips-Pull MSP trip nipple-Install MPD bearing- Commission MPD choke skid @ various pump rates-Pull MPD bearing-Install trip nipple-Install PS 21 slips 13:00 13:30 0.50 2,468 2,537 INTRM1 DRILL REAM P Wash&ream to btm f/2468'to 2537' @ 450 gpm @ 850 psi 50 rpm 4 k toruqe 16%return flow-Downlink to MWD Page 12of61 Time Logs 110 Date From To Dur S.Depth E.'Dei th Phase Code Subcode T Comment 13:30 18:00 4.50 2,537 2,929 INTRMI DRILL !DDRL P Drilled 9 7/8" hole w/RSS f/2537'to 2929'MD 2495'TVD ADT-3.2 hrs ECD- 10.41 ppg Footage-392' WOB 8 k RPM 110 GPM 694 @ 1795 psi w/27%flow out String wt PU 113 SO 102 ROT 106 Torque 5.5 k Total bit&jar hrs.-3.41 hrs SPR's @ 2990' 18:54 hrs #1 20 spm @ 100 psi 30 spm @ 140 psi #2 20 spm @ 100 psi 30 spm @ 140 psi 18:00 23:15 5.25 2,929 3,479 INTRM1 DRILL DDRL P Drilled 9 778"hole w/RSS f/2929'to 3479' MD 2664'TVD ADT-3.42 hrs ECD 10.80 ppg Footage-550' WOB 6 k RPM 120 GPM 700 @ 1965 psi w/27%return flow String wt. PU 119 SO 102 ROT 106 Torque 5.5 k Total bit&jar hrs. -6.83 hrs. SPR's 3479' @ 23:59 hrs #1 20 spm @ 120 psi 30 spm @ 140 psi #2 20 psm @ 120 psi 30 spm @ 140 psi 23:15 23:42 0.45 3,479 3,479 INTRM1 DRILL CIRC T Circ btms up @ 3477'@ 694 gpm @ 1965 psi-Prep to pull to shoe to repair TD electrical issue. 32/27/2015 POOH f/3479'to 2454'-Flow ck(static)trouble service loop on TD-RIH-Circ btms up-Drill 9 7/8"hole f/ 3479'to 5672' MD 00:00 00:15 0.25 3,479 3,479 INTRM1 DRILL OWFF T Blow down TD-Flow ck-well static 00:15 01:15 1.00 3,479 2,454 INTRM1 DRILL TRIP T POOH on elevators f/3479'to 2454' 01:15 02:15 1.00 2,454 2,454 INTRMI DRILL RGRP T Trouble shoot service loop w/rig electrician(monitor well on TT) 02:15 02:30 0.25 2,454 3,405 INTRMI DRILL TRIP T RIH f/2454'to 3405' 02:30 03:30 1.00 3,405 3,479 INTRM1 DRILL CIRC T Establish circ&stage pump up to 700 gpm @ 1965 psi w/120 rpm's- Wash to btm-Circ btms up-hole unloaded with cuttings all 3 shakers loaded w/cuttings&4942 units of gas Page 13 of 61 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 06:00 2.50 3,479 3,715 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/3479'to 3715'MD 2956'TVD ATD-1.47 hrs. ECD-10.64 ppg Footage-236' WOB 4 k RPM 130 GPM 700 @ 2065 psi w/27%flow out String wt. -PU 119 SO 103 ROT 109 Torque 5 k Total bit&jar hrs.-8.3 hrs 06:00 12:00 6.00 3,715 4,442 INTRMI DRILL DDRL P Drilled 9 7/8"hole w/RSS f/3715'to 4442'MD 2959'TVD ADT-4 hrs. ECD-10.83 ppg Footage-727' WOB-9 k RPM 130 GPM 700 @ 2272 psi w/30%flow out String wt. PU 125 SO 100 ROT 108 Torque 5 k Total bit&jar hrs.-12.58 hrs SRP's @ 3972'@ 09:40 hrs #1 20 spm 140 psi 30 spm 160 psi #2 20 spm 120 psi 30 spm 140 psi 12:00 18:00 6.00 4,442 5,104 INTRM1 DRILL DDRL P Directional drill 9-7/8"section with RSS from 4442'MD to 5104'MD, 3154'TVD, 700 gpm, 2590 psi,28% flow out, 140 rpm, 11k/7k Tq, 10k WOB, ECD=11.46, P/U=144k, S/0=106k, ROT=114k. 18:00 00:00 6.00 5,104 5,672 INTRMI DRILL DDRL P Directional drill 9-7/8"section with RSS from 5104'MD to 5672'MD, 3320'TVD, 700 gpm, 2800 psi,29% flow out, 150 rpm, 12k/8kTq, 13k WOB, ECD=11.76, P/U=153k, 5/0=104k, ROT=122k.ADT=7.56, Total bit/Jars hrs=20.14 02/28/2015 Drilled 9 7/8"hole f/5672'to 7563'MD-Circ btms up-Stood back 1 std to 7472'-Phase 3 weather condition -Circ&work pipe-Waiting on weather 00:00 06:00 6.00 5,672 6,427 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/5672'to 6427' MD 3550'TVD ADT-4.16 hrs ECD 11.59 ppg Footage-755' WOB 9 k RPM 150 GPM 700 @ 2744 psi w/28%return flow String wt. PU 169 SO 106 ROT 124 Torque on/off btm.-12/8 k ft/lbs Total bit&jar hrs.245.30 hrs SPR's @ 6426'w/9.8 ppg mud @ 06:10 hrs #1 20 spm 180 psi 30 spm 220 psi #2 20 spm 170 psi 30 spm 220 psi Page 14 of 61 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 6,427 7,090 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/RSS f/6427'to 7090' MD 3746'TVD ADT-3.87 hrs ECD- 11.46 ppg Footage-663' WOB 10 k RPM 150 GPM 700 @ 2775 psi w/28% return flow String wt. PU 180 SO 103 ROT 124 Torque on/off btm.-16-17/9-10 k ft/lbs Total bit&jar hrs.-28.17 hrs SPR's @ 6990'w/9.8 ppg @ 11:07 hrs #1 20 spm 160 psi 30 spm 220 psi #2 20 spm 170 psi 30 spm 220 psi 12:00 16:30 4.50 7,090 7,563 INTRM1 DRILL DDRL P Drilled 9 7/8"hole w/RSS f/7090'to 7563'MD 3885'TVD ADT-2.84 hrs. ECD- 11.6 ppg Footage-473' WOB 13 k RPM 140 GPM 700 @ 2965 psi w/28%return flow String wt. PU 160 SO 110 ROT 132 Torque on/off btm.- 14.5/10 k ft/lbs Total bit&jar hrs.-31.01 hrs 16:30 17:30 1.00 7,563 7,468 INTRM1 DRILL CIRC P Obtain survey&SPR's-Circ btms up(R& R pipe)f/7563'to 7468' @ 700 gpm @ 2930 psi w/140 rpm w/ 11 k torque-pumped 5500 stks. - Stood back 1 std DP to 7468'-PU wt160 SOwt110 SPR's @ 7563'@ 1655 hrs #1 20 spm @ 190 psi 30 spm @ 240 psi #2 20 spm @ 180 psi 30 spm @ 230 psi Weather condition went f/Phase 2 to Phase 3 17:30 19:15 1.75 7,468 7,468 INTRM1 DRILL WAIT T Circ&work pipe @ 400 gpm @ 1175 psi f/30 rpm's w/9 to 10 k torque - Circ another btms up 19:15 00:00 4.75 7,468 7,468 INTRM1 DRILL WAIT T Circ©3 bbls/min @ 240 psi w/20 rpm's w/8 k torque-R&R pipe f/ 7468'to 7430' 03/01/2015 Circ&work pipe(wait on weather Phase 3) 00:00 12:00 12.00 7,468 7,468 INTRM1 DRILL WAIT T Circ©3 bbls/min @ 250 psi w/30 rpm's w/11 k torque-waiting on Phase 3 to be down graded Page 15 of 61 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 7,468 7,468 INTRMI DRILL WAIT T Continue circulate at 3 bpm 240 psi, 7%flow out while R&R from 7402' MD-7470' MD,varying stop points, reduce rotary to 10 rpm and slow recip rate to 30'per hr. Crew change at rig @ 18:30 hrs. 33/02/2015 Cont. Circ&work pipe waiting on weather-Trip/backream to casing shoe, install MPD bearing RIH to Condition mud,drill ahead from 7563' 00:00 05:30 5.50 7,468 7,468 INTRMI DRILL WAIT T Cont. circ @ 3 bbls/min @ 237 psi- R&R pipe f/7468'to 7402'w/10 rpm w/11-12 ktorque 05:30 06:00 0.50 7,468 7,379 INTRMI DRILL CIRC P Stage pumps up to 700 gpm @ 3220 psi w/26%flow out w/100 rpm w/12 13 k torque and circ btms up-PU wt 165 SO wt 100-Monitor well 10 mins. (static)stood abck 1 std DP to 7379' SPR's @ 7463'w/10.0 ppg mud # 1 20 spm 210 psi 30 spm 250 psi #2 20 spm 200 psi 30 spm 250 psi 06:00 08:30 2.50 7,379 6,335 INTRM1 DRILL WPRT P POOH on elevators f/7379'to 6335' @ 900 ft/hr-monitoring hole fill on TT-Hole not taking proper fill 08:30 09:30 1.00 6,335 6,247 INTRM1 DRILL CIRC T MU TD&stage pumps up to 700 gpm @ 2959 psi w/100 rpm's w/ 9-10 k torque-R&R pipe f/6335'to 6247'-circ btms up(5130 stks) No gas @ btms up-stood back 1 std DP to 6247' 09:30 12:00 2.50 6,247 5,490 INTRM1 DRILL PMPO P Blow down TD-Pull on elevators f/ 6247'to 6152'-watching fluid level- well swabbing-MU TD POOH w/ pump @ 3 bbls/min @ 217 psi f/ 6152'to 5490'@ 1200 ft/h-Observed signs of packing off 12:00 13:30 1.50 5,490 4,918 INTRM1 DRILL PMPO P Pump out of hole from 5490' MD to 4918' MD @ 3 bpm, 300 psi, 9%flow out, P/U=137k, S/0=95k. 13:30 19:00 5.50 4,918 2,458 INTRM1 DRILL BKRM P BROOH from 4918' MD to 2648'MD @ 700 gpm, 2810 psi,27%flow, 120 rpm, 8k Tq, FCP=2500 psi. Stop rotating and reduce flow, pump out from 2658'to 2458'; MD pulling BHA into casing shoe. Monitor displacement via pits 2&3. 19:00 19:30 0.50 2,458 2,458 INTRM1 DRILL CIRC P Circulate bottoms up @ 2458 @ 450 gpm, 2500 psi,40 rpm. 19:30 20:30 1.00 2,458 2,458 INTRM1 DRILL MPDA P Blow down top drive, remove PS-21 slips. Un-clamp and remove RCD trip nipple, re-install slips, M/U stand#19 with RCD bearing, pull slips, install and clamp bearing assy. Install PS-21 slips. Page 16 of 61 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:30 20:45 0.25 2,458 2,458 INTRM1 DRILL SVRG P Service and inspect top drive and blocks. 20:45 21:00 0.25 2,458 2,458 INTRM1 DRILL MPDA P Establish circulation through RCD/choke manifold and check for flow path, check for leaks. 21:00 00:00 3.00 2,458 6,337 INTRM1 DRILL TRIP P RIH from 2458' MD to 6337' MD monitoring displacement via trip tank. Fill pipe and blow down top drive every 20 stands. P/U=125k, 5/0=88k. 03/03/2015 Drill intermediate section at 200-225 ft/hr monitoring ECD 2.0 ppg over mud weight to 8175'where the hole packed off. Circulation was re-established by pumping up the hole and reaching the drillling rates and reaming back in tthe hole. CBU 2X at 8175'and drilled ahead at 100 ft/hr monitoring ECD to remain<1.5 ppg over mud weight. 00:00 01:30 1.50 6,337 7,561 INTRM1 DRILL TRIP T Continue to RIH from 6337'to 7472' at 100 ft/min. Monitor displacement via TT, MU top drive and fill pipe,then stage pumps to 700 GPm with 3066 psi, at 10 RPM with 12K Torque, 23%FO. 01:30 02:30 1.00 7,561 7,561 INTRM1 DRILL CIRC T CBU with Recip and rotation from 7561'to 7466'at 700 GPM with 3089 psi and 100 RPM with 11-12K torque 24%FO, Dump and Dilute mud with total strokes of 7350. 02:30 06:00 3.50 7,861 7,965 INTRM1 DRILL DDRL P Drill 9 7/8"hole from 7861'to 7965'at 700 GPM with 3046 psi, 25% FO, 150 RPM with 13-15K torque and 9K WOB with an ECD= 11.69 ppg. PU= 175K, S0= 110K, Rot= 139K. AST/ART=2.28,ADT=2.28,TTL bit hours=33.29,Jar hours=33.29. 06:00 08:00 2.00 7,965 8,175 INTRM1 DRILL DDRL P Drill 9 7/8"hole from 7965'to 8175'at 700 GPM with 3028 psi, 26% FO, 150 RPM with 13-14K torque and 9K WOB with an ECD= 11.82 ppg. PU= 160K, S0= 101K, Rot= 126K. AST/ART=2.8,ADT=2.8, TTL bit hours=34.49, Jar hours=34.49. Reduce flow to 630 GPM, increase to 160 RPM with 2712 psi, 24% FO with 15-16K torque. Pump pressure increased to 3180 psi during hole pack-off with returns decreasing to near 0% FO. 200 BPH loss rate. Approximately 60 BBLs loss during pack-off. 08:00 10:45 2.75 8,175 8,031 INTRM1 DRILL CIRC T Attempt to establish circulation; reduce flow to 200 GPM with 646 psi. 5% FO while slowly pulling and working pipe to relieve pack-off. Establish circulation at 1 BPM with 270 psi, —1%FO, 10 RPM with 10K torque. Recip pipe from 8126'to 8031'while waiting on mud. Page 17 of 61 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:45 12:00 1.25 8,031 7,500 INTRM1 DRILL PMPO T Continue to pump out of the hole from 8031'to 7500'at 2 BPM with 320 psi^-1%FO. Crew change. 12:00 16:00 4.00 7,500 7,375 INTRM1 DRILL CIRC T Establish circulation with 0.5 BPM increments and initiate rotation at 30 RPM, and continue to stage RPM up with flow rates; 1 BPM=375 psi, 1% FO, 30 RPM with 14K torque. 3 BPM=520 psi,6%FO, 50 RPM with 12K torque, 5BPM=650 psi, 9% FO, 70 RPM with 11K torque, 7 BPM= 815 psi, 12%, 90 RPM with 11K torque. Pump 50 LCM pill at 8 BPM with FCP= 1200 psi, 13% FO. 12 BPM= 1880 psi, 21% FO. 700 GPM with 3170 psi, 25% FO, 150 RPM 13K torque and no dynamic losses noticed. 20% cuttings increase seen at LCM pill back to surface. PU= 167K, SO= 102K. 16:00 19:00 3.00 7,375 8,175 INTRM1 DRILL REAM T Wash and ream from 7472'to 8175' at 700 GPM with 3250 psi, 27% FO, 120 RPM with 12-13K torque, Ream in at 600 FPH. 19:00 21:45 2.75 8,175 8,175 INTRM1 DRILL CIRC T Circulate 2X BU at 700 GPM with ICP=3250 psi, FCP=3090 psi. 27% FO, 150 RPM with 13K torque, ECD= 11.16 ppg. 21:45 00:00 2.25 8,175 8,321 INTRM1 DRILL DDRL P Drill 9 7/8"hole from 8175'to 8321'at 700 GPM with 2950 psi,26% FO, 150 RPM with 15K torque and 9K WOB with an ECD= 11.29 ppg. Perform 290 BBL dilution with 9.5 ppg mud. PU= 175K, SO= 107K, Rot= 138K. AST/ART=2.63,ADT= 2.63, TTL bit hours=35.92,Jar hours=35.92. Crew change. TTL loss for day= 113 BBL. 33/04/2015 Drill intermediate section at 100 FPH to 8470',then 125 FPH to 9025', and 150 FPH monitoring ECD to remain<1.5 ppg over mud weight. ECD has been averaging 1.3 to 1.4 ppg over mud weight in. the ROP was increased at 10395'to 175 FPH in the Iceberg. Drill to 10594'. Page 18 of 61 Time Logs 411 40 Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 8,321 8,800 INTRM1 DRILL DDRL P Drill 9 7/8"hole from 8321'to 8800'at 700 GPM with 3081 psi, 26% FO, 150 RPM with 15K torque and 9K WOB with an ECD= 11.12 ppg. PU= 173K, SO= 114K, Rot= 137K. Increased ROP to 125 FPH at 8470'. AST/ART=4.38,ADT=4.38, Bit hours=40.35,Jar hours=40.35. Centrifuge repaired and in service with current mud weight at 9.7+ppg. SPR's; 8609' MD,4194'TVD, 9.8 ppg #1 MP 2/3 BPM with 230/280 psi #2 MP 2/3 BPM with 230/270 psi 06:00 12:00 6.00 8,800 9,400 INTRM1 DRILL DDRL P Drill 9 7/8"hole from 8800'to 9400'at 700 GPM with 3081 psi, 26% FO, 150 RPM with 15K torque and 8K WOB with an ECD= 11.23 ppg. PU= 178K, SO= 119K, Rot= 145K. AST/ART=4.40,ADT=4.40, Bit hours=44.75,Jar hours=44.75. Centrifuge in service with current mud weight at 9.8+ppg. Increased ROP 150 FPH at 9025'. Crew change. 0 losses this tour. SPR's; 9369' MD,4419'TVD, 9.7+ pp9 #1 MP 2/3 BPM with 230/260 psi #2 MP 2/3 BPM with 230/260 psi 12:00 18:00 6.00 9,400 10,026 INTRM1 DRILL DDRL P Drill 9 7/8"hole from 9400'to 10026' at 700 GPM with 3240 psi,25% FO, 150 RPM with 16K torque and 9K WOB with an ECD= 11.31 ppg. PU= 180K, SO= 122K, Rot= 145K. Line up to MPD chokes A and B on connections starting at 9556'to monitor Annular pressure on connections. Closed at connections stabilizing at 10 psi. SPR's; 9836'MD,4562'TVD, 9.9 ppg #1 MP 2/3 BPM with 170/230 psi #2 MP 2/3 BPM with 180/240 psi 18:00 00:00 6.00 10,026 10,594 INTRM1 DRILL DDRL P Drill 9 7/8"hole from 10026'to 10594' at 700 GPM with 3050 psi, 25% FO, 150 RPM with 19K torque and 8K WOB with an ECD= 11.27 ppg. PU= 197K, SO= 120K, Rot= 150K. AST/ART=8.71,ADT=8.71, Bit hours=53.46, Jar hours=53.46. Increased ROP 175 FPH at 10,305. Perform Dump and Dilute with 290 BBL of 9.5 ppg mud. SPR's; 10499'MD,4757'TVD, 9.9 ppg #1 MP 2/3 BPM with 190/250 psi #2 MP 2/3 BPM with 190/250 psi Crew change. Page 19 of 61 Time Logs • Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 33/05/2015 24 hr summary Drill intermediate section to 12276'MD, 5287'TVD. CBU to confirm TD with Geologist. Circulate hole clean. Pull OOH with MPD pressure schedule. 00:00 06:00 6.00 10,594 11,212 INTRM1 DRILL DDRL P Drill 9 7/8"hole from 10594'to 11212' at 700 GPM with 3250 psi, 25% FO, 150 RPM with 19.5K torque and 10K WOB with an ECD= 11.36 ppg. PU= 195K, SO= 124K, Rot= 155K. AST/ART=4.11,ADT=4.11, Bit hours=57.57,Jar hours=57.57. Closing chokes during connections to check for pressure build up: None. 06:00 12:00 6.00 11,212 11,719 INTRM1 DRILL DDRL P Drill 9 7/8"hole from 11212'to 11719' at 700 GPM with 3370 psi, 25% FO, 150 RPM with 19-20K torque and 8K WOB with an ECD= 11.40 ppg. PU= 178K, SO= 128K, Rot= 158K. AST/ART=4.34,ADT=4.34, Bit hours=61.91, Jar hours=61.91. SPR's; 11632'MD, 5092'TVD, 9.9+ ppg 11:00 #1 MP 2/3 BPM with 260/320 psi #2 MP 2/3 BPM with 250/310 psi Crew change. 12:00 17:30 5.50 11,719 12,276 INTRM1 DRILL DDRL P Drill 9 7/8"hole from 11719'to 12276' MD, 5278'TVD for TD of section at 700 GPM with 3535 psi, 25%FO, 150 RPM with 20K torque and 9K WOB with an ECD= 11.45 ppg. PU=207K, SO= 130K, Rot= 159K. AST/ART=4.04,ADT=4.04, Bit hours=65.95,Jar hours=65.95. SPR's; 12276' MD, 5287'TVD, 9.8+ ppg 20:30 #1 MP 2/3 BPM with 200/260 psi #2 MP 2/3 BPM with 200/270 psi 17:30 22:00 4.50 12,276 12,105 INTRM1 CASING CIRC P Obtain TD survey, SPR's while CBU 1.5X(12000 strokes)with Rotary and Recip full drilling rate. Pump 42 BBL LCM pill S2S at drilling rates with good returns of 25%increase at shakers. Circulate 1.5 BU(13564 strokes)at drilling rates. total strokes pumped after TD 37990. PU=200K, SO= 128K, Rot= 160K. 22:00 22:30 0.50 12,105 12,105 INTRM1 CASING OWFF P Blow down top drive and observe well for flow while circulating across the top to the TT with MPD bearing in place. No gain or loss observed for 30 minutes; Static. Page 20 of 61 Time Logs • Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 22:30 00:00 1.50 12,105 11,354 INTRM1 CASING TRIP P Blow down hole fill line, line up on injection line and set MPD choke parameters. POOH from 12105'to 11354'while holding back pressure per Tripping schedule. Proper fill observed during trip. Crew change. 03/06/2015 Pull on elevators to shoe, holding back pressure per schedule. Open Well Commander and circulate casing clean. Close WC and continue to pull. Remove MPD bearing and install trip nipple. LD BHA,wash stack and pull wear ring. Clean and clear floor,stage casing equipment to rig floor. 00:00 02:00 2.00 11,354 9,245 INTRMI CASING TRIP P Continue to pull out at 50 FPM, holding back pressure per tripping schedule with MPD to 9245. Monitor proper fill via TT. PU= 185K, SO= 110. 02:00 02:30 0.50 9,245 9,245 INTRM1 CASING CIRC P Pump dry job of 20 BBL 1.5 over. blow down top drive. 02:30 06:00 3.50 9,245 5,290 INTRM1 CASING TRIP P Continue to pull at 50 FPM with back presure from 9245 to 5290'. PU= 125K, SO= 103K. 06:00 09:00 3.00 5,290 2,445 INTRMI CASING TRIP P Continue to pull at 50 FPM with back presure from 5290'to 2445'. 09:00 09:15 0.25 2,445 2,445 INTRM1 CASING OWFF P Observe well for flow for 10 minutes; Static. 09:15 10:00 0.75 2,445 2,445 INTRM1 CASING CIRC P MU top drive and break circulation at 3 BPm with 143 psi, Break out TD and drop 2.115"WC open ball. Circulate down at 1 BPM with 65 psi, ball on seat with 33 strokes 1046 psi, hold for 30 seconds and increase pressure at 0.5 BPM and holding at each 500 psi increment for 30 seconds until open at 2100 psi. 40 strokes. Stage pumps up to 928 GPM with 1188 psi. Total strokes pumped 5700. Good returns and casing unloaded cuttings. Crew change. 10:00 11:00 1.00 2,445 2,445 INTRM1 CASING CIRC P Observe well; Static and drop ball to close WC. Perform pressure sequencing and WC closed at 2700 psi. Confirmed with stroke/pressrue comparison. 11:00 12:00 1.00 2,445 2,095 INTRM1 CASING TRIP P Continue to pull with MPD pressure schedule from 2445'to 2095'. 12:00 13:45 1.75 2,095 814 INTRM1 CASING TRIP P Continue to pull with MPD pressure schedule from 2095'to 814'. Over pull in casing at 2070', 1950'and 1900'. observed MPD bearing leaking at 1900'. Proper fill noted on trip out. 13:45 17:00 3.25 814 814 INTRM1 CASING MPDA P Change out MPD bearing to the trip nipple. Blow down all lines and MPD choke skid. Page 21 of 61 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 21:30 4.50 814 0 INTRM1 CASING BHAH P POOH laying down BHA from 814 to surface; LD HWDP,jars and flex collars. Pull RA source and continue to LD BHA. 21:30 22:00 0.50 0 0 INTRM1 CASING WWWH P MU stack cleaning assembly and wash out stack. Blow down top drive and clean and clear floor. 22:00 22:15 0.25 0 0 INTRMI CASING OWFF P Observe well for 15 minutes; Static. 22:15 23:15 1.00 0 0 INTRMI CASING RURD P Drain BOP stack, MU wear ring puller and pull wear ring. 23:15 00:00 0.75 0 0 INTRM1 CASING BHAH P Remove BHA components from rig floor and stage casing equipment to floor. 03/07/2015 Perform hanger dummy run; good. Change rams and test with 7 5/8"test joint. RU casing equipment. PJSM and run casing per detail and pressure schedule to 7037'. 00:00 01:00 1.00 0 0 INTRM1 CASING RURD P MU 7 58"landing joint to hanger. Perform hanger dummy run with landing joint. LD landing joint and hanger. 01:00 03:30 2.50 0 0 INTRM1 CASING RURD P Moblize casing equipment to rig floor. PU and MU long bales and extentions with link tilt clamps and hardware. Change rams to 7 5/8" rams. Perform weekly function test with BOP rams. 03:30 04:30 1.00 0 0 INTRM1 CASING BOPE P Change rams to 7 5/8"rams. Set test plug, attempt to pressure, pull test plug and replace Oring. Test 7 5/8"rams 250/3500 psi for 5 minutes each to chart; Good. 04:30 05:30 1.00 0 0 INTRM1 CASING RURD P RU and PU Volant CRT tool to top drive. 05:30 06:00 0.50 0 0 INTRM1 CASING SFTY P PJSM for running casing with crew, GBR and CPAI rep. 06:00 12:00 6.00 0 1,570 INTRMI CASING PUTB P MU shoe track and bakerLok joints 1-3 with bow spring centralizers and hydroform installed. Run 7 5'8"#39 L-80 Hyd 563 casing to 432'with 22,000 ft-lbs torque. Install#39 to #29.7 casing crossover and continue running 29.7#L-80 Hyd 563 casing to 1570'. Fill every joint and top off the tenth. Install centralizers per detail;2 bow spring with stop rings and hydroforms free-floating. Crew change. 12:00 14:00 2.00 1,570 2,496 INTRM1 CASING PUTB P Continue running 29.7#L-80 Hyd 563 casing to 2496'with 11,900 ft-lbs torque. Fill every joint and top off the tenth. Install centralizers per detail. Monitor displacement with pits#4 and#5; proper fill observed. 14:00 15:00 1.00 2,496 2,496 INTRM1 CASING CIRC P Break circulation and recip casing staging pumps to 7 BPM with 175 psi. Circulate surface to surface with 2500 strokes. PU=96K, SO=99K. Page 22 of 61 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 00:00 9.00 2,496 7,037 INTRM1 CASING PUTB P Continue running 29.7#L-80 Hyd 563 casing to 7037'with 11,900 ft-lbs torque. Fill every joint and top off the tenth. Install centralizers per detail. Monitor displacement with pits#4 and#5; proper fill observed. PU=158K, S0=93K. Crew change. 33/08/2015 Continue to run 7 5/18"casing to 12266'and put hanger on seat. Returns lost at joint#230, pull back and attempt to establish circulation without success. Continue to TD washing in without returns. Work string to attempt to gain circulation at TD. 00:00 06:00 6.00 7,037 9,238 INTRM1 CASING PUTB !P Continue running 29.7#L-80 Hyd 563 casing to 9238'with 11,900 ft-lbs torque. Fill every joint and top off the tenth. Install centralizers per detail. Monitor displacement with pits#4 and#5; proper fill observed. 06:00 07:30 1.50 9,238 9,745 INTRMI CASING PUTB P Continue running 29.7#L-80 Hyd 563 casing to 9745'with 11,900 ft-lbs torque. Fill every joint and top off the tenth. Monitor displacement with pits #4 and#5; proper fill observed until 9700'then returns were lost;joint #230. 07:30 08:00 0.50 9,745 9,745 INTRMI CASING CIRC P Attempt to break circulation without success at 3 BPM with 691 psi and 0% FO. PU= 177K, SO=80K. 08:00 12:00 4.00 9,745 9,238 INTRM1 CASING PULL T PJSM to pull casing. Pull and LD 7 5/8"casing from 9745'to 9238'. Attempting to break circulation without success. PU= 187K, S0= 98K. 12:00 12:15 0.25 9,238 9,196 INTRM1 CASING PULL T Continue to pull and LD 7 5/8"casing from 9238'to 9196'. Attempting to break circulation without success. PU= 187K, SO=98K. 12:15 14:15 2.00 9,196 9,745 INTRM1 CASING PUTB T Continue running 29.7#L-80 Hyd 563 casing from 9196'to 9745'. Pumping 1 BPM with 250 psi and 0% FO. 250 psi to 500 psi dependent on running speed. SO=93K maintaining running speed to scehdule. Monitoring loss/ displacement. 14:15 18:00 3.75 9,745 11,335 INTRM1 CASING PUTB P Continue running 29.7#L-80 Hyd 563 casing from 9745'to 11335'. Pumping 1 BPM with 250 psi and 0%FO. 250 psi to 500 psi dependent on running speed. SO= 93K maintaining running speed to scehdule. Page 23 of 61 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 18:45 0.75 11,335 11,547 INTRM1 CASING PUTB P Continue running 29.7#L-80 Hyd 563 casing from 11335'to 11547'. Pumping 1 BPM with 250 psi and 0% FO. 250 psi to 500 psi dependent on running speed. S0= 93K maintaining running speed to schedule. Turn on hole fill due to annulus fluid dropping. 18:45 20:00 1.25 11,547 11,884 INTRM1 CASING PUTB P Continue running 29.7#L-80 Hyd 563 casing from 11547'to 11884'. Pumping 1 BPM with 250 psi and 0% FO. 250 psi to 500 psi dependent on running speed. SO= 83K maintaining running speed to schedule. 20:00 21:00 1.00 11,884 12,227 INTRM1 CASING PUTB P Continue washing down casing from 11884'to 11227'. Pumping 0.5 BPM with 425 psi and 0%FO. 21:00 21:45 0.75 12,227 12,266 INTRM1 CASING PUTB P Continue washing down casing from 11227'to 12266'. Pumping 0.5 BPM with 450 psi and 0%FO. 21:45 00:00 2.25 12,266 12,266 INTRM1 CEMEN.CIRC P Attempt to establish circulation with pipe reciprocation and staging pumps. Loss this tour= 165 BBL. Total losses for day=361 BBL. 33/09/2015 Attempt to establish circulation at TD. LD hanger and landing joint, PU next joint#289 and work pipe while staging pumps. MU hanger and land, pump cement without returns throughout job. CIP at 20:25. RD cementing equipment. RU to cut and slip drill line. 00:00 00:30 0.50 12,266 12,266 INTRM1 CEMEN-PULL T LD landing joint and hanger. 00:30 04:00 3.50 12,266 12,266 INTRM1 CEMEN-CIRC 'T MU joint#289, continue to recip and Attempt to establish circulation working pipe and staging pumps to apply flow/pressure with max P 400 psi. PU=250K, SO=88K. 04:00 04:30 0.50 12,266 12,266 INTRM1 CEMEN-RURD T PJSM, blow down and change out Volant CRT pack-off cup. Monitor well via TT;static. 04:30 08:30 4.00 12,266 12,266 INTRM1 CEMEN-CIRCT Attempt to establish circulation working pipe and staging pumps to apply flow/pressure with max P 400 psi. PU=250K, SO=88K. 08:30 08:45 0.25 12,266 12,266 INTRM1 CEMEN-SFTY T PJSM for pulling and LD casing. 08:45 11:30 2.75 12,266 11,842 INTRM1 CEMEN-PULL T Pull and LD casing from 12266'to 11842'. PU=225K, SO=88K. 11:30 12:00 0.50 11,842 11,970 INTRM1 CEMEN-PUTB T RIH with casing from 11842'to 11970'with FO=0%. Crew change. 12:00 13:30 1.50 11,970 12,261 INTRM1 CEMEN-PUTB T Continue RIH with casing from 11970' to 12261'with FO=0%. 13:30 14:00 0.50 12,261 12,261 INTRM1 CEMEN-CIRCT Establish injection rates and pressure with 6 BPM with 960 psi with 0%FO. Blow down top drive. 14:00 15:00 1.00 12,261 12,261 INTRM1 CEMEN-HOSO T LD joint#289, PU and MU hanger and landing joint. Page 24of61 Time Logs 41111 Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 15:00 16:00 1.00 12,266 12,266 INTRM1 CEMEN-RURD P RU cementers'equipment; hoses, sensators,transducer and chart recorder. Inject mud and 1.5 BPM with 800 psi with recip from 12266'to 12251'. 16:00 16:30 0.50 12,266 12,266 INTRMI CEMEN-SFTY P Land casing and hold PJSM for cementing with rig crew, SLB cementers and COP rep. 16:30 17:00 0.50 12,266 12,266 INTRM1 CEMEN-CIRCP Establish injection rate and pressure with SLB unit pumps with 9.5 ppg LSND. 17:00 17:15 0.25 12,266 12,266 INTRM1 CEMEN"CMNT P SLB pump 5 BBLs H2O, Pressure test lines to 3000 psi; Good. 17:15 20:30 3.25 12,266 12,266 INTRM1 CEMEN-CMNT P SLB pump 40 BBLS CW100, and 40 BBLs Mud Push III 11.5 ppg, Dis-engage CRT and drop 1st plug at 18:00. Pump 204 BBLs 15.8 ppg cement at 8 BPM with ICP=360 and chase cement to 260 BBL away; 8 BPM FCP=740 psi. Pump at 5 BPM with ICP=575 psi, continue to chase cement, FCP at 5 BPM= 1148 psi. Bump plug at 5480 strokes, pump to achieve 500 psi over and hold 1660 psi for 5 minutes. Bleed pressure and check floats; Good. CIP at 20:25. Complete cement job without returns. 20:30 21:30 1.00 12,266 12,266 INTRMI CEMEN-RURD P RD and blow down cement lines, RD Volant CRT and LD landing joint, RD and LD bales extentions. 21:30 23:30 2.00 12,266 0 INTRM1 CEMEN-WWSP P Drain stack, PU 5"double and MU pack-off running tool. Set pack-off per Cameron rep,test same to 5000 psi for 10 minutes good. Test witnessed by CPAI rep Paul Smith. Pull running tools. SIMOPS; Clean and clear all cement lines, Demco valves, clean and clear rig floor. 23:30 00:00 0.50 0 0 INTRMI CEMEN-SLPCP LD 5"sinlge and MU single to topdrive for slip and cut, hang blocks. Crew change. Total losses for day; 576 BBLs rig mud system. Loss of 40 CW100, Loss of 40 BBL Mud Push III. 03/10/2015 Cut and slip drill line. RD casing handling equipment and RU to handle drill pipe. Pipe management; LD 5" DP. RU and Test BOPE. 00:00 02:00 2.00 0 INTRMI CEMEN-SLPC P Slip and cut drill line, Calibrate block height. 02:00 02:30 0.50 INTRM1 CEMEN-SVRG P Service top drive, blocks and PM top drive. Page 25 of 61 Time Logs • Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 02:30 04:00 1.50 INTRM1 CEMEN-RURD P Remove 7 5/8"side door elevators. remove 180"casing bales, install 130"bales and 5"elevators. Change out PS-21 sli inserts to install mouse hole for laying down DP. 04:00 09:00 5.00 INTRM1 CEMEN'PULD P Pipe management of 5" DP; LD from the mouse hole. LD doubles to the shed. 09:00 09:15 0.25 INTRM1 CEMEN-SFTY P PJSM with rig crew, Co Rep, Little Red Services and truck drivers. 09:15 12:00 2.75 INTRM1 CEMEN-FRZP P PT LRS lines to 4000 psi; Good. Pump 118 BBL H2O flush @ 3 BPM with 800 psi average. Pump 86.5 BBL Isotherm at 2.75 BPM with IP= 700 psi, FCP= 1550 psi. Shut pressure at 650 psi. SIMOP's; LD singles of 5"drill pipe to shed. Crew change. OAP=650 psi. 12:00 14:45 2.75 INTRM1 CEMEN-PULD P Pipe management of 5"DP; LD from the mouse hole. LD singles to the shed. SIMOPS; Install gun lines in the pits. 14:45 15:15 0.50 INTRM1 CEMEN SVRG P Service and inspect ST-80, er-calibrate topdrive link-tilt _operational limiters. 15:15 20:45 5.50 INTRM1 CEMEN PULD P Pipe management of 5" DP; LD from the mouse hole. LD singles to the shed. SIMOPs; Stage BHA components and equipment. Get test joints in the shed for testing. — 20:45 21:30 0.75 INTRM1 CEMEN BOPE P Change upper rams to variable 2 7/8" X 5 1/2". MU floor valves,topdrive test fittings. Clean and clear floor. 21:30 22:00 0.50 INTRM1 WHDBO RURD P PU 3 1/2"test joint, MU and set test plug, RU testing equipment and flush lines with H2O. Page 26 of 61 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:00 00:00 2.00 INTRM1 WHDBO BOPE P Test all BOPE to 250/3500 psi for 5 minutes each to the chart. 3 1/2",4" and 4 1/2"test joints.AOGCC Chuck Scheve waived witness of test.Tested manual and super chokes to 250/2000 psi.Tested annular preventer,2-7/8"x5'/z"Upper VBR's, 2-7/8"x5'/i'Lower VBR's, Choke valves 1-15, manual and super choke, manual and HCR choke and kill valves,4"valve on kill line, 3 1/2" TIW, 3 1/2"Dart valve, Upper and lower IBOP, Blind/shear rams. Perform accumulator drawdown test, System pressure=3000 psi, Manifold=1500 psi, Pressure after functioning all rams and valves=1550 psi,200 psi attained=18 seconds with 2 electric pumps, full pressure attained=110 seconds with 2 electric and 2 air pumps. 6 bottle N2 average=1983 psi. Closing times; Annular=23 sec, UPR=16 sec, Blind/shear=17 sec, LPR=16 sec, HCR Choke=2 sec, HCR kill=2 sec. REcovery with only electric pumps= 84 seconds,with air pumps only= 129 seconds. Crew change. No losses for the day. 03/11/2015 Complete BOP testing,AOGCC rep Chuck Scheve waived witness. Change saver sub, PU 4"DP, POOH and stand back 44 stands in derrick. PU and MU drilling BHA. 00:00 04:30 4.50 0 INTRM1 WHDBO BOPE P Continue testing BOPE to 250/3500 psi for 5 minutes each to the chart. 3 1/2",4"and 4 1/2"test joints. AOGCC Chuck Scheve waived witness of test. Tested manual and super chokes to 250/2000 psi. Tested annular preventer,2-7/8"x5'/2' Upper VBR's, 2-7/8"x5'/z"Lower VBR's, Choke valves 1-15, manual and super choke, manual and HCR choke and kill valves,4"valve on kill line, 3 1/2"TIW, 3 1/2"Dart valve, Upper and lower IBOP, Blind/shear rams. 04:30 05:30 1.00 0 INTRM1 WHDBO RURD P Pull test joint and LD 4 1/2", RD test equipment,drain stack and install 10"wear ring. 05:30 08:30 3.00 0 INTRM1 CEMEN"RURD P PJSM for CO saver sub. Change out 4 1/2"IF to 4"Saver sub, CO PS-21 slip inserts, Install 4" DP elevators, CO link-tilt clamps. Page 27 of 61 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 10:00 1.50 0 INTRM1 CEMEN-MPDA P Meeting for B-crew with MPD Safekick Rep. Discuss operation, application, RU, and RD. Discuss added hardware and function. Discuss drilling,tripping and circulating with MPD equipment. Q and A discussion. 10:00 11:00 1.00 0 INTRM1 CEMEN-SFTY P Safety Discussion#2 with CPAI rep and RLG; "Where is our Safety Culture today?" 11:00 12:00 1.00 0 824 INTRMI CEMEN-PULD P PJSM, PU mule shoe and RIH with doubles to 824'. Proper fill observed on trip. Crew change. OAP=500 psi 12:00 12:30 0.50 824 948 INTRM1 CEMEN-PULD P RIH with doubles from 824'to 948'. Proper fill observed on trip. 12:30 13:00 0.50 948 948 INTRM1 CEMEN-SVRG P Service and inspect rig;topdrive, blocks. and ST-80. 13:00 14:00 1.00 948 948 INTRM1 CEMEN-SFTY P Safety Discussion#2 with CPAI rep and RLG; "Where is our Safety Culture today?" 14:00 16:00 2.00 948 4,174 INTRM1 CEMEN-PULD P RIH with doubles from 948'to 4174'. Proper fill observed on trip. 16:00 19:00 3.00 4,174 0 INTRM1 CEMEN'TRIP P POOH and stand back 44 stands in derrick. 19:00 21:00 2.00 0 0 INTRM1 CEMEN-WAIT T Waiting on Sonic scope and upload. SIMOPs; Clean and clear floor, CO slips,verify DP tally, Mobilize Sonic scope to pipeshed. 21:00 21:15 0.25 0 0 INTRM1 CEMEN SFTY P BHA handling PJSM. 21:15 00:00 2.75 0 229 INTRM1 CEMEN BHAH P PJSM, PU and MU 6 1/2"drilling BHA per SLB DD and MWD. Plug in and double check ADN per Houston RTOC. Continue PU BHA to 137'. Load RA source, MU BHA to 229' Change crew. OAP=440 psi. 03/12/2015 Complete BHA and single in the hole with 4"drill pipe. SPT with MWD; Good. Continue RIH. RIH from 8000' to cement logging Sonic for TOC. RU and start casing test. 00:00 02:00 2.00 229 1,476 INTRMI CEMEN-PULD P Complete MU BHA and RIH with 4" singles from 229'to 1476'. Proper fill observed on trip. 02:00 02:45 0.75 1,476 1,476 INTRMI CEMEN DHEQ P Stage pumps and obtain Shallow Pulse test for MWD; Good. 220 GPM with 1010 psi, 10% FO. Blow down top drive. 02:45 11:00 8.25 1,476 8,000 INTRM1 CEMEN PULD P RIH with 4"singles from 1476'to 8000'. Proper fill observed on trip. 11:00 12:00 1.00 8,000 8,000 INTRM1 CEMEN-CIRC P Establish circulation and perform downlink to MWD for Sonic logging MAD pass while tripping in at 900 FPH. OAP=480 psi. Page 28of61 Time Logs • i' Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 20:30 8.50 8,000 12,008 INTRMI CEMEN-QEVL P Continue to RIH with 4"singles from 8000'at 900 FPH. Filling every 20 stands. Proper fill observed on trip. PU= 159K, SO=79K, Rot= 108K. Crew change at 14:00. 20:30 23:30 3.00 12,008 12,100 INTRMI CEMEN-CIRCP Establish circulation at 126 GPM and wash in hole from 12008'to 10100'. Increase rate to 220 GPM with 1850 psi, 12%FO. Circulate Surface to Surface with rotary and reciprocation for 6100 strokes. Blow down top drive. 23:30 00:00 0.50 12,100 12,100 INTRM1 CEMEN-PRTS P RU and perform casing test 3000 psi for 30 minutes. OAP=480 psi. 03/13/2015 Complete casing test to 3000 psi for 30 minutes; Good. Tag cement 12172'drill to float. Drill shoe track and 20 of new hole. Perform FIT to 16.1 EMW, Install MPD bearing, CBU 2X and drill ahead per plan and Geo-steering. 00:00 01:00 1.00 12,100 12,100 INTRM1 CEMEN-PRTS P Complete testing casing to 3000 psi for 30 minutes; Good. Pumped 5.8 BBL to obtain pressure, bled back 5.4 BBL. RD test equipment. 01:00 01:30 0.50 12,170 12,172 INTRM1 CEMEN-COCF P Wash down and Clean out cement to the float, tag cement at 12170'. 01:30 02:15 0.75 12,172 12,172 INTRM1 CEMEN-CIRCP Establish circulation and downlink to MWD to log with Sonic 12100'to 12170'. Obtain SPR: SPR's; 12100'MD, 5235'TVD, 9.5 ppg 01:50 #1 MP 2/3 BPM with 670/870 psi #2 MP 2/3 BPM with 660/860 psi 02:15 05:15 3.00 12,172 12,176 INTRM1 CEMEN'DRLG P Drill float from 12172'to 12176', 2-10K WOB, 40-50 RPM with 13K torque, 215 GPM with 1730 psi, 8% FO. 05:15 07:00 1.75 12,176 12,276 INTRM1 CEMEN-DRLG P Drill cement in shoe track from 12176'to 12263'. Drill shoe to 12266'. Drill cement out of rat hole to 12276'at 210 GPM with 1655 psi, 8%FO, 50 RPM with 13K torque, 07:00 08:00 1.00 12,276 12,296 INTRM1 CEMEN'DDRL P Drill new hole from 12276'to 12296' with above parameters. 08:00 10:45 2.75 12,296 12,296 INTRMI CEMEN-CIRCP CBU with 210 GPM 1760 psi, 8% FO, 50 RPM with 13K torque. PU= 151K, SO=95K, Rot= 117K. Pull bit into shoe for FIT. 10:45 11:00 0.25 12,296 12,296 INTRM1 CEMEN-OWFF P Observe well for flow while blowing down top drive; Static. 11:00 12:00 1.00 12,296 12,296 INTRM1 CEMEN FIT P PJSM, RU test equipment. Pump 3.8 BBL to achieve 1760 psi for FIT. Shut in for 10 minutes and bleed off 3.5 BBL back. FIT= 16.1 EMW. Start RD test equipment. OAP=480 psi. Page 29 of 61 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 12:45 0.75 12,296 12,296 PROD1 DRILL 'RURD P RD test equipment, blow down all lines. Run bit into open hole for circulation. 12:45 13:30 0.75 12,296 12,314 PROD1 DRILL DDRL P Obtain parameters; PU= 155K, SO 85K, Rot= 107K. 100 RPM with 14-15K torque. Drill from 12296'to 12314'with 10K WOB and 250 GPM with 2160 psi, 5% FO. 13:30 13:45 0.25 12,314 12,314 PROD1 DRILL SFTY P PJSM for displacement to KlaShield mud with rig crew, MI mud engineer, truck drivers and CPAI rep. 13:45 15:30 1.75 12,314 12,314 PROD1 DRILL DISP P Perform displacement of 9.6+ LSND mud to 9.5 ppg KLA-Shield. Pump 72 BBL space, chase with KLA-Shield at 250 GPM, ICP=2266 psi, FCP=2345 psi 6% FO. 60 RPM with 12K torque. Reciprocate pipe, KLA-Shield at surface with 4084 Strokes. 15:30 16:00 0.50 12,314 12,314 PROD1 DRILL CIRC P Pump 20 BBL citric pill through flow line, clean mud troughs, and clean remaining pits of LSND. Blow down topdrive. 16:00 17:45 1.75 12,314 12,314 PROD1 DRILL MPDA P PJSM, remove trip nipple and install RCD bearing. Line up to pump through MPD skid gut line. 17:45 18:00 0.25 12,314 12,314 PROD1 DRILL CIRC P Establish circulation check MPD and bearing for leaks; Good. Obtain SPR: SPR's; 12321' MD, 5424'TVD, 9.5 ppg 18:00 #1 MP 2/3 BPM with 550/800 psi #2 MP 2/3 BPM with 550/800 psi 18:00 21:00 3.00 12,314 12,314 PROD1 DRILL MPDA P Circulate to clear all shoe track rubber for MPD choke precaution. Circ at 225 GPM with 1900 psi, 7% FO,40 RPM with 11K torque. Total strokes pumped 7356. PU= 151K, SO=90K, Rot= 114K. 21:00 00:00 3.00 12,314 12,480 PROD1 DRILL DDRL P Drill from 12314'to 12480' MD, 5349' TVD at 250 GPM with 2180 psi 8% FO, 100 RPM with 13K,torque. 9K WOB. PU= 159K, SO=92K, Rot= 122K. ADT=2.36,TTL bit hours=3.05, Jars 3.05. 03/14/2015 Drill ahead in production zone.After drilling into the Seis Bermuda(12987'),10K units was registered and at 13335'pulled off bottom to assess gas and employ mitigation measures. Decision made to hold 190 psi back pressure and drill ahead. Page 30 of 61 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 12,480 12,838 PROD1 DRILL DDRL P Drill from 12480'to 12838' MD, 5430' TVD at 250 GPM with 2170 psi 8% FO, 100 RPM with 13K,torque. 10K WOB. PU= 167K, SO=87K, Rot= 117K. Obtain SPR: SPR's; 12669'MD, 5399'TVD, 9.5 ppg 03:20 #1 MP 2/3 BPM with 540/740 psi #2 MP 2/3 BPM with 550/720 psi 06:00 10:30 4.50 12,838 13,143 PROD1 DRILL DDRL P Drill from 12838'to 13143'MD, 5456' TVD at 250 GPM with 2307 psi 8% FO, 150 RPM with 14K,torque. 15K WOB. PU= 160K, SO=89K, Rot= 120K. ADT=7.33,TTL bit hours= 10.39, Jars 38.46. Obtain SPR: SPR's; 13140'MD, 5460'TVD, 9.5+ ppg 10:15 #1 MP 2/3 BPM with 560/770 psi #2 MP 2/3 BPM with 550/770 psi 10:30 12:00 1.50 13,143 13,143 PROD1 DRILL CIRC T Circulate out gas,250 GPM with 2290 psi, 3-63% FO, 5 RPM with 8K. Max mudlogger gas units=9865. Crw change. OAP=475 psi. 12:00 12:30 0.50 13,143 13,143 PROD1 DRILL CIRC T Continue to circulate out gas, 250 GPM with 2200 psi, 3-55% FO, 10 RPM with 10K. 12:30 13:45 1.25 13,143 13,238 PROD1 DRILL DDRL P Drill from 13143' to 13238 MD, 5456' TVD at 250 GPM with 2390 psi 10% FO, 150 RPM with 14K,torque. 5K WOB. PU= 155K, SO=88K, Rot= 122K. ADT= 1.19 hours. 13:20 increasee MPD BP to 50 psi. 13:45 17:30 3.75 13,238 13,238 PROD1 DRILL CIRC T Circulate out gas,250 GPM with 2390 psi, 10% FO, 30 RPM with 8K. 15:20 increase MPD BP to 120 psi. With pumps off at connection obtain 396 psi with fingerprint. 17:30 18:45 1.25 13,238 13,334 PROD1 1 DRILL DDRL P Drill from 13238 to 13334'MD at 250 GPM with 2385 psi 10% FO, 120 RPM with 14K,torque. 2K WOB. PU= 160K, SO=89K, Rot= 120K. Drill with BP= 120 psi. Page 31 of 61 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:45 00:00 5.25 13,334 13,334 PROD1 DRILL CIRC T Circulate out gas,250 GPM with 2440 psi, 10%FO, 120 RPM with 13K. Incresasing BP with every bottoms up. With 120 psi BP ECD= 11.34, pump 5010 strokes with no decrease in ML gas. With 140 psi BP ECD= 11.4, pump 6945 strokes with no decrease in ML gas. With 190 psi BP ECD= 11.4, pump 5762 strokes with ML gas units decreasing from 10000 to 5250 units. Make connection with 190 BP on MPD. No losses for day. OAP=500 psi. 03/15/2015 Drill production zone to 14473', circulating out gas and managing levels with MPD back pressure. Increase mud weight from 9.7 ppg to 10.0 ppg while drilling from 13900'to 14200',decreasing MPD back pressure to maintain 11.8 ECD on formation. 00:00 06:00 6.00 13,334 13,617 PROD1 DRILL DDRL P Drill from 13334' to 13617' MD at 250 GPM with 2440 psi 10%FO, 120 RPM with 14K,torque. 10K WOB.PU= 162K, SO=79K, Rot= 79K. ECD= 11.55. Holding 210 psi during drilling and hold 480 psi during connections. Max gas on ML gas detection 10000 units. Obtain SPR: SPR's; 13425' MD, 5494'TVD, 9.6 ppg 02:15 #1 MP 2/3 BPM with 510/760 psi #2 MP 2/3 BPM with 570/770 psi 06:00 10:45 4.75 13,617 13,905 PROD1 DRILL DDRL P Drill from 13617'to 13905' MD at 250 GPM with 2566 psi 8%FO, 120 RPM with 15K, torque. 10K WOB.PU= 162K, SO=79K, Rot= 116K. ECD= 11.88. Holding 210 psi during drilling and hold 480 psi during connections. Max gas on ML gas detection 10000 units. 10:45 12:00 1.25 13,905 13,905 PROD1 DRILL CIRC T Circulate gas out at 252 GPM with 2566 psi 8% FO, 70 RPM with 14K, torque. ECD= 11.88 ppg, applied 230 psi back pressure. Max gas on ML gas detection 10000 units. Crew change. OAP=480 psi. 12:00 13:00 1.00 13,905 13,905 PROD1 DRILL CIRC T Circulate gas out at 250 GPM with 2605 psi 9%FO, 70 RPM with 11K, torque. ECD= 11.80 ppg, applied 230 psi back pressure. Max gas on ML gas detection 10000 units. Page 32of61 ' Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:00 19:00 6.00 13,905 14,200 PROD1 DRILL DDRL P Drill from 13905'to 14200' MD at 250 GPM with 2510 psi 10% FO, 125 RPM with 15K, torque. 5K WOB. PU= 162K, SO=76K, Rot= 118K. ECD= 11.88. Max gas on ML gas detection 10000 units. ART/ADT= 3.69 hours. Obtain SPR: SPR's; 13905'MD, 5499'TVD, 9.7 ppg 13:00 #1 MP 2/3 BPM with 620/890 psi #2 MP 2/3 BPM with 530/800 psi 19:00 00:00 5.00 14,200 14,473 PROD1 DRILL DDRL P Drill from 14200'to 14473' MD, 5514' TVD at 250 GPM with 2625 psi 10% FO, 125 RPM with 15K,torque, 8K WOB. PU= 163K, SO=73K, Rot= 115K. ECD= 11.81. Max gas on ML gas detection 10000 units. ADT/ART=2.84, TTL bit hours= 26.58,jars=54.65. Obtain SPR: SPR's; 14200' MD, 5509'TVD, 10.0 ppg 19:00 #1 MP 2/3 BPM with 700/940 psi #2 MP 2/3 BPM with 590/845 psi 03/16/2015 Circulate out gas imposing 11.8 ECD and increase to 11.9 ECD to suppress gas levels. Drill ahead circulating as needed. Weight up to 10.5 ppg while drilling,drill ahead with no BP on MPD to 15670'. 00:00 02:00 2.00 14,473 14,473 PROD1 DRILL CIRC T Circulate gas out at 250 GPM with 2662 psi 8-60% FO, 120 RPM with 15K,torque. ECD= 11.84 ppg, applied 100 psi back pressure. Max gas on ML gas detection 10000 units. Increase BP to 125 psi to match ECD build up while drilling. 02:00 06:00 4.00 14,473 14,678 PROD1 DRILL DDRL P Drill from 14476'to 14678' MD, 5518' TVD at 250 GPM with 2645 psi 10-50% FO, 125 RPM with 15K, torque, 11K WOB. PU= 177K, SO=84K, Rot= 139K. ECD= 11.91. Max gas on ML gas detection 10000 units, circulate out gas as needed. GW reading=6927 units. Obtain SPR: SPR's; 14663' MD, 5518'TVD, 10.0 ppg 05:30 #1 MP 2/3 BPM with 675/955 psi #2 MP 2/3 BPM with 575/900 psi 06:00 12:00 6.00 14,678 15,043 PROD1 DRILL DDRL P Drill from 14678'to 15043'MD, 5531' TVD at 250 GPM with 2774 psi 3-61%FO, 125 RPM with 15K, torque, 12K WOB. PU= 179K, SO=84K, Rot= 139K. ECD= 12.05. ADT=5.88,TTL bit hours=32.46,Jar hours=60.53. Weight up system from 10.0 to 10.2 ppg Crew change. OAP=480 psi. Page 33 of 61 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 15:30 3.50 15,043 15,236 PROD1 DRILL DDRL P Drill from 15043' to 15236'MD, 5533' TVD at 250 GPM with 2815 psi 10% FO, 120 RPM with 17K,torque, 15K WOB. PU= 180K, SO=58K, Rot= 114K. ECD= 11.92. ADT=2.48, TTL bit hours=34.94, Jar hours= 63.01. Weight up system in stages from 10.0 to 10.4 ppg, reduce choke pressure to 100%open at 10.4 ppg in and out. Obtain SPR: SPR's; 15136' MD, 5533'TVD, 10.2 ppg 13:00 #1 MP 2/3 BPM with 645/935 psi #2 MP 2/3 BPM with 740/1015 psi 15:30 18:00 2.50 15,236 15,236 PROD1 DRILL CIRC P Circulate, roating and reciprocating at 250 GPM with 2820 psi 10% FO, 120 RPM with 13K. Pumped total of 922 BBL on circulation. 18:00 18:30 0.50 15,236 15,236 PROD1 DRILL OWFF P Ramp down pumps and shut in on chokes with 478 psi with MPD, observe fall off to 402 psi. Bleed off pressure and realize a 1.4 BBL gain to the pits. Shut in and allow pressure to build for 10 minutes to 398 psi of equivalent of 11.8 EMW. 18:30 00:00 5.50 15,236 15,670 PROD1 DRILL DDRL P Drill from 15236'to 15670' MD, 5531' TVD at 250 GPM with 3010 psi 10% FO, 150 RPM with 16K,torque, 6K WOB. PU= 188K, SO=56K, Rot= 109K. ECD= 12.05. ADT=3.88, TTL bit hours=38.82, Jar hours= 66.89. Holding BP on connection of 490 psi. Continue weight up to 10.5 ppg. Obtain SPR: SPR's; 15512'MD, 5534'TVD, 10.5 ppg 20:50 #1 MP 2/3 BPM with 800/1110 psi #2 MP 2/3 BPM with 740/1070 psi Crew change. OAP=480 psi. 03/17/2015 Directional drill with MPD holding 11.9 ppg-12.0 ppg with chokes to TD 16,168'MD, 5529'TVD. C&C while weight up tp 11.0 ppg. ML Gas consistant 10000 units, reducing with mud weight to 3000. Page 34 of 61 Time Logs ill • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 15,670 15,985 PROD1 DRILL DDRL P Continue drilling production hole from 15670'MD to 15985'MD, 5536'TVD @ 250 gpm, 3050 psi, 8%flow out, 150 rpm,torque on/off 16k/14k, 5k WOB, P/U=190k, S/O=60k, ROT=114k. SPR's @ 15983'MD, 5531'TVD, 10.5 ppg, 06:00 hrs. #1-20 spm=790 psi, 30 spm=1108 psi #2-20 spm=737 psi, 30 spm=1102 psi 06:00 09:45 3.75 15,985 16,168 PROD1 DRILL DDRL P Continue drilling production hole from 15985'MD to 16168'MD, 5530'TVD . @ 250 gpm, 3090 psi, 8%flow out, 150 rpm,torque on/off 16k/14k, 5k WOB, P/U=190k, S/O=60k, ROT=114k. Max GW gas units=506 units, Max ML gas units=9997. ART/ADT=6.52,Total bit hrs=45.34, Jar hrs=73.41. SPR's @ 16102'MD, 5530'TVD, 10.6+ppg, 11:07 hrs. #1-20 spm=800 psi, 30 spm=1170 psi #2-20 spm=760 psi, 30 spm=1080 psi 09:45 12:00 2.25 16,168 16,089 PROD1 CASING CIRC P Circulate while R&R from 16,160'MD to 16089' MD 250 gpm, 3117 psi, 9% flow out, 80 rpm, 14k tq off. P/U=194k, S/0=60k, ROT=114k, total strokes pumped=6500. OA pressure=480 psi 12:00 18:00 6.00 16,089 15,710 PROD1 CASING BKRM P BROOH form 16089'MD to 15710' MD, 250 gpm, 3270 psi, 9%flow out, 100 rpm, 14k Tq, ECD=12.9 ppg, Weight up active system from 10.6 ppg to 11.0 ppg. Holding 320 psi with MPD during connections. 18:00 22:45 4.75 15,710 16,167 PROD1 CASING REAM P Pump and rotate back to bottom from 15710' MD to 16167' MD while weighting up to 11.0 ppg. 250 gpm, 3270 psi, 9%flow out, 100 rpm, 14k Tq, Holding 320 psi with MPD on connections. Page 35 of 61 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:45 00:00 1.25 16,167 16,167 PROD1 CASING CIRC P Circulate bottoms up from TD while R&R from 16167'MD to 16088'MD, 210 gpm, 2565 psi, 10%flow out, 100 rpm, 14k Tq, 12.82 ppg ECD. Reduced pump rate top maintain ECD below 12.9 ppg. Totco gas reading peaked at 3335 units, Mudlogger gas peaked at 10000 units at 1300 stks and held until 5100 stks before dropping off. 3% LEL in pit room OA pressure=480 psi 33/18/2015 CBU, close chokes and test formation pressure, indicates 12.36 ppg. Backream to shoe and CBU, begin weight up to 11.5 ppg. 00:00 00:45 0.75 16,167 16,168 PROD1 CASING CIRC P Circulate while R&R from 16168'MD to 16089' MD with MPD,209 gpm, 2565 psi, 9%flow out, 100 rpm, 13k Tq. Total strokes pumped=6800. 00:45 01:15 0.50 16,168 16,168 PROD1 CASING OWFF P Monitor well at 16150' MD 30 minutes with MPD system. Close MPD choke and observe pressure ICP=387 psi, FCP=392 psi after 30 minutes. 01:15 02:30 1.25 16,168 16,168 PROD1 CASING CIRC P Circulate while R&R from 16168' MD to 16089'MD with MPD,209 gpm, 2565 psi, 9%flow out, 100 rpm, 13k Tq.Total strokes pumped=3800. SPR's @ 16092' MD, 5530'TVD, 11.0 ppg, 02:05 hrs #1-20 spm=954 psi, 30 spm=1357 psi #2-20 spm=846 psi, 30 spm=1252 psi 02:30 12:00 9.50 16,168 14,096 PROD1 CASING BKRM P PJSM, BROOH from 16168'MD, 5530'TVD to 14096'MD, 5505'TVD. 209 gpm, 2441 psi, 80 rpm, 14k Tq. P/U=198k, S/0=40k, ROT=107k. Holding back pressure with MPD 364 psi, ECD=12.67 ppg, Max gas units on GW=6362 units, Max gas on ML=10000 units. OA pressure=420 psi 12:00 18:00 6.00 14,096 12,768 PROD1 CASING BKRM P Continue BROOH @ 16 fpm from 14096' MD to 12768'MD, 223 gpm, 2400 psi, 10%flow out, 80 rpm, ROT wt=107k, 12k Tq, ECD=12.68. Holding 12.2 ppg during connections with MPD, pressure building from 320 psi to 363 psi while making connection. Page 36 of 61 Time Logs • Date From To Dur S. Depth E. DepthPhase Code Subcode T Comment 18:00 22:15 4.25 12,768 12,191 PROD1 CASING BKRM P Continue BROOH @ 4 fpm from 12768' MD to 12191'MD, 223 gpm, 2400 psi, 10%flow out, 80 rpm, ROT wt=105k, 10k Tq, ECD=12.53. Holding 12.2 ppg during connections with MPD, pressure building from 320 psi to 363 psi while making connection. Slowed pulling rate to circulate gas out of annulus due to spikes observed. ML=10000 units, GW=580 units. Monitor displacement on active, Calc fill=22.7 bbl,Actual fill-.5 bbl. Proceed with caution. 22:15 22:30 0.25 12,096 12,096 PROD1 WHDBO SEQP P Perform weekly BOP function test on upper rams, lower rams, annular, HCR choke and kill. 22:30 00:00 1.50 12,191 12,096 PROD1 CASING CIRC P Circulate while R&R from 12191'-12096'MD 240 gpm, 2680 psi,40 rpm, P/U=173k, S/O=73k, ROT=108k, 10k Tq, 10%flow out, ECD=12.53 ppg, Both chokes open 100%. Circulate bottom up while preparing for 11.5 ppg displacement, total strokes pumped 4679. OA pressure=300 psi 03/19/2015 Displace well to 11.5 ppg mud at shoe. Shut in chokes and fingerprint to determine final KWM. Consistant results @ 12.4+ppg.Weight up system to 12.0 ppg, perform exhale test and repeat fingerprint with consistant results. Begin wt up to 12.5. 00:00 01:00 1.00 12,096 12,191 PROD1 CASING OWFF P Monitor well with MPD chokes closed while preparing for 11.5 ppg mud displacement. ISICP=385 psi, FSICP=405 psi with 11.0 ppg mud. 01:00 03:15 2.25 12,191 12,191 PROD1 CASING CIRC P PJSM displace well to 11.5 ppg mud in 1 circulation, pumped 30 bbl spacer, chase with 11.5 ppg Klashield @ 240 gpm, 2570 psi ICP, 9%flow out,40 rpm, 10k Tq. P/U=145k, 5/O=73k, ROT=107k, total strokes pumped 7378, ECD=12.57 ppg, MPD chokes A&B 100%open. 03:15 04:00 0.75 12,191 12,191 PROD1 CASING OWFF P Monitor well via MPD system. Stop pump, bleed off DP pressure to 0, close MPD chokes A&B.Allow pressure to stabilize @ 270 psi in 30 minutes. Equivilant to 12.44 ppg. Bump floats to verify, inconclusive value 340 psi. Consult with engineer, decide to weight up to 12.0 ppg for further evaluation. Page 37 of 61 Time Logs • Date From To Dur S. Depth E. Depth Phase` Code Subcode T Comment 04:00 10:30 6.50 12,191 12,191 PROD1 CASING CIRC T Circulate while weighting up from 11.5 ppg to 12.0 ppg ICP=2383 psi @ 234 gpm, 12.9 ppg ECD, reduce to 127 gpm 981 psi to manage ECD below 13.0.40 rpm, 8k Tq, P/U=145k, S/O=73k, ROT=105k, MPD chokes A&B 100%open. 10:30 11:00 0.50 12,191 12,191 PROD1 CASING OWFF T With 12 ppg mud in and out perform shut in test. Shut down pumping, shut in MPD chokes. Monitor pressure build up for 30 minutes, recording every 2 minutes.At 10 minutes the pressure was 120 psi (12.44 ppg EMW), after 20 minutes the pressure was 122 psi(12.44 ppg EMW), and after 30 minutes the pressure was 133 psi (12.48 ppg EMW). Rotate 20 rpm,6k Tq. 11:00 16:15 5.25 12,191 12,191 PROD1 CASING CIRC T Circulate and weight up f/12 ppg to 12.2 pg. Reduce pump rate per MPD simulation schedule as heavier mud was in the annulus to not exceed 12.9 ppg EMW. Begin @ 130 gpm, 1100 psi,6%flow calculated 12.96 ECD, stage down to 80 gpm, 722 psi,2%flow out calculated 12.96 ECD.Total strokes pumped 6029, total mud lost 2.5 bbl. 16:15 17:30 1.25 12,191 12,191 PROD1 CASING OWFF T Shut down pumping with 12.2 ppg MW in and out. Shut in well with MPD chokes. Line up to take returns to the trip tank. Pressure built up to 94 psi in 5 minutes. Open well to the trip tank for 5 minutes. Gained .17 bbls. Shut in chokes.Recorded pressure build up every 2 minutes for 30 minutes. Pressure built up to 80 psi in 10 minutes, 88 psi in 20 minutes, and 89 psi(12.52 ppg EMW)final in 30 minutes. Opened the chokes to bleed pressure and measure returns to the trip tank every 2 minutes. Gained .4 bbls the first 10 minutes, .35 bbls the next 10 minutes, and .35 again the next 30 minutes fora total of 1.1 bbl gain in 30 minutes. 17:30 18:30 1.00 12,191 12,191 PROD1 CASING KLWL T Shut in well, monitoring pressure build up every 2 minutes f/30 minutes. In 10 minutes the pressure was 56 psi,at 20 minutes the pressure was 65 psi, and at 30 minutes the pressure was 69 psi. After about 45 minutes the pressure had built to 73 psi(12.46 ppg EMW). Page 38 of 61 Time Logs III all Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 20:30 2.00 12,191 12,191 PROD1 CASING OWFF T Discuss with town Engineer. Decision to open chokes for either a 2-1/2 bbls gain or an hour open. Recording pit gain every 2 minutes averaging .2 bbl every 10 minutes, then 7 minutes,then 6 minutes varying. Gained 1.55 bbl in 1 hour, continued monitoring per engineer and gained additional .95 bbl in 30 minutes for total of 2.5 bbl. 20:30 22:00 1.50 12,191 12,191 PROD1 CASING OWFF T Shut in well on MPD chokes and observe pressure build up linear 2.27 psi per minute to 50 psi then slowed to 1-<1 psi per minute. Pressure stabilized at 66 psi after 1 hour. Discussed results with engineering team. 22:00 00:00 2.00 12,191 12,191 PROD1 CASING COND T Decision made to weight up to 12.5 ppg in one circulation.Weight up surface system to 12.5 ppg for displacement while monitoring well and preparing circulation schedule to maintain ECD<13.0 ppg. 33/20/2015 Displace well to 12.5 ppg mud @ 23 gpm final rate. Exhale test, slight increasing flow. Fingerprint with MPD chokes to 28 psi. Consult and begin weighting up system to 12.65 ppg @ 21 gpm 390 psi. 00:00 01:00 1.00 12,191 12,191 PROD1 CASING COND T Weight up surface system from 12.2 ppg to 12.5 ppg for displacement while monitoring well and preparing circulation schedule to maintain ECD<13.0 ppg. MPD choke pressure 65 psi. 01:00 12:00 11.00 12,191 12,191 PROD1 CASING CIRC T Circulate 12.5 ppg mud into the well. Rotating 26 to 40 rpm w/9k ft lbs of torque and reciprocating slow. Follow MPD pump schedule circulating through MPD chokes. Pumped the first 124 bbls @ 80 gpm w/803 to 1191 psi. Start decreasing flow rate to 70 gpm w/800 to 640 psi for the next 75 bbls. The next 75 bbls, pumping @ 60 gpm w/560 to 538 psi. Slowed to 50 gpm w/498 to 490 psi for the next 75 bbls. Decreased rate to 40 gpm w/432 to 420 psi for the next 75 bbls.After 423 bbls were pumped, pumping was continued at 23 gpm w/335 to 376 psi. Note:After 543 bbls were pumped the MW in is still 12.5 ppg, MW out is 12.2 ppg. 12:00 15:00 3.00 12,191 12,191 PROD1 CASING CIRC T Continue pumping 12.5 ppg mud at 23 gpm w/335 to 376 psi until 12.5 ppg at surface. Rotating 30 rpm w/ 9k ftlbs of torque. Reciprocating slow.Total strokes pumped 7072=713 bbl. Page 39 of 61 11 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 16:45 1.75 12,191 12,191 PROD1 CASING OWFF T Shut down pump and shut in choke, blow down top drive, open choke and perform exhale test to trip tank. Trend appears to be reducing in flow. 16:45 18:00 1.25 12,191 12,191 PROD1 CASING SLPC P Slip and cut 70'drilling line, calibrate Amphion and Totco block height. SIMOPS-Continue exhale test. Trend reducing to as low as 22:53 min/qt. 18:00 18:30 0.50 12,191 12,191 PROD1 CASING SVRG P Service topdrive, blocks and crown. SIMOPS-continue exhale test,trend now increasing in flow slowly, 5 min/qt,4 min/qt,2:03 min/qt, 1:58/qt, 1:54/qt, 1:44/qt, 1:41/qt, 1:34/gt. 18:30 20:00 1.50 12,191 12,191 PROD1 CASING OWFF T Continue performing exhale test, trend increased from low of 22:53 min/qt-.015 bph, increased to 1:34 min/qt-.228 bph over two hours, continually increasing. Total fluid bled back.39 bbl. Discuss results and plan forward with leadership. 20:00 21:00 1.00 12,191 12,191 PROD1 CASING OWFF T Shut in MPD choke and monitor pressure build, pressure build to 15 psi over 30 minutes, increase to 28 psi after 1 hour. Discuss results and plan forward with leadership,decision to weight up system to 12.65 ppg. 21:00 00:00 3.00 12,191 12,191 PROD1 CASING CIRC T Establish circulation @ 21 gpm, 390 psi, minimal flow out, no losses,30 rpm, 9k Tq.weighting up system from 12.5 ppg to 12.65 ppg. OA=100 psi 03/21/2015 Displace well to 12.65 ppg mud, obtain 30 min no flow,strip out of hole with MPD to 10299'MD 1000 fph, 30 psi on MPD choke in slips, 130 psi pulling. 00:00 06:00 6.00 12,191 12,191 PROD1 CASING CIRC T Continue weighting up to from 12.5 ppg to 12.65 ppg while R&R from 12164' MD to 12136'MD @ 30 ffh, 30 rpm, 9k Tq, 5 spm/21 gpm, 378 psi, minimal flow out. SIMOPS-Complete MP2's, clean and organize rig. 06:00 12:00 6.00 12,191 12,191 PROD1 CASING CIRC T Continue weighting up to from 12.5 ppg to 12.65 ppg while R&R from 12164'MD to 12136'MD @ 30 ffh, 30 rpm, 9k Tq, 5 spm/21 gpm, 378 psi, minimal flow out. SIMOPS-Complete MP2's, clean and organize rig. OA pressure=200 psi, Total losses for tour 6 bbl Page 40 of 61 Time Logs • 410 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 19:00 7.00 12,191 12,191 PROD1 CASING CIRC T Continue weighting up to from 12.5 ppg to 12.65 ppg while R&R from 12164'MD to 12136'MD@30ffh, 30 rpm, 9k Tq, 5 spm/21 gpm, 375 psi, minimal flow out. SIMOPS-Complete MP2's, clean and organize rig. 19:00 20:30 1.50 12,191 12,191 PROD1 CASING OWFF T Kill pumps, shut in MPD chokes. Blow down top drive, monitor well via open 2"valve on RCD. Slight vac. Observe well static 30 minutes. 20:30 20:45 0.25 12,191 12,191 PROD1 CASING MPDA P PJSM and line up#1 Mud pump on MPD system. 20:45 00:00 3.25 12,191 10,299 PROD1 CASING TRIP P PJSM-Strip out of hole from 12191' MD to 10299' MD pumping 150 gpm over the top, holding 130 psi on annulus via MPD choke while pulling pipe 1000 fph, 30 psi while in slips. Monitor displacement via pit#3 observe good hole fill. Drop 2.38"drift with 100'steel 5/32"tail line on stand #107.Attempted to drop on stand #123,would not fall with existing 1/8" steel line due kinked and bent. OA pressure=200 psi 03/22/2015 Continue stripping out of hole with MPD to HWDP. Remove RCD bearing, install trip nipple. Lay down BHA and M/U liner assy, RIH with liner to 624'MD. 00:00 06:00 6.00 10,299 6,820 PROD1 CASING TRIP P Continue tripping out of hole from 10299' MD to 6820'MD @ 1000 fph, holding pressure on annulus as per MPD schedule, 30 psi in slips, 130 psi pulling pipe. Monitor displacement via pit#3. 06:00 12:00 6.00 6,820 3,064 PROD1 CASING TRIP P Continue tripping out of hole from 6820'MD to 3064' MD @ 1000 fph, holding pressure on annulus as per MPD schedule, 30 psi in slips, 130 psi pulling pipe. Monitor slight over displacement via pit#3. Losses for tour=8 bbl OA pressure=100 psi 12:00 15:45 3.75 3,064 527 PROD1 CASING TRIP P Continue tripping out of hole from 3064'MD to 527' MD @ 1000 fph, holding pressure on annulus as per MPD schedule, 30 psi in slips, 130 psi pulling pipe. Monitor displacement via pit#3. 15:45 17:30 1.75 527 527 PROD1 CASING MPDA P Remove RCD bearing and install new bearing on stand#1 for next run. Install trip nipple and rack back stand. B;low down MPD skid and R/U hole fill line to RCD. 17:30 18:45 1.25 527 137 PROD1 CASING BHAH P POOH from 527'to 137'MD, rack back HWDP and DC, L/D jars and Well Commander. Page 41 of 61 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:45 19:15 0.50 137 137 PROD1 CASING BHAH P Remove RA source from ADN as per MWD. 19:15 20:15 1.00 137 0 PROD1 CASING BHAH P Continue L/D BHA per DD and MWD from 137'MD. Break bit. Monitor displacement via pit#3. Calc Fill for trip=68.7 bbl,Actual Fill=95.6 bbl Function test blind rams. 20:15 21:00 0.75 0 0 PROD1 CASING RURD P Clean and clear rig floor 21:00 22:00 1.00 0 0 COMPZ CASING RURD P R/U to run 4W liner. R/U elevators, tongs, power slips, fill up hose. Double check swell packers, frac sleeves and other jewelry in pipe shed,verify count. 22:00 22:30 0.50 0 0 COMPZ CASING SFTY P PJSM on running 4W Liner assy with rig crew, BOT, CPAI, Doyon casing. 22:30 00:00 1.50 0 624 COMPZ CASING PUTB P M/U shoe and RIH with 4Y2'IBTM L-80 liner per detail to 624' MD. Monitor displacement via pit#3. Total losses for tour 26.9 bbl, Total for day=34.9 bbl 03/23/2015 Continue P/U and run liner,XO to drill pipe, install RCD bearing. Could not pump through liner @ 800 psi. L/D ZXP. Observe well flowing, shut in SICP=250 psi. Break circ @ 1980 psi, pump dye&id frac sleev open @ 1168'. Strip in to install RCD bearing. Begin stripping in hole w/MPD, swapping out light mud(-10.3 PPG)to 12.65 ppg. 00:00 06:00 6.00 624 4,024 COMPZ CASING PUTB P Continue running 4'/z' 12.6#L-80 IBT-M liner from 624' MD to 4024'MD as per detail, filling on the fly from the top with fill up hose topping off every 10 jts. Monitor displacement via pit#3. Observe 10.9 bbl over calculated displacement, no flow on connections. 06:00 07:00 1.00 4,024 4,070 COMPZ CASING OTHR P P/U Liner hanger,ZXP liner top packer, drain stack, C/O slip inserts. Mix Pal-Mix and allow to set for 30 minutes. 07:00 08:00 1.00 4,070 4,075 COMPZ CASING MPDA P PJSM, remove trip nipple, install RCD bearing assy. M/U stand 4"DP from derrick and RIH to 4075'MD. 08:00 09:00 1.00 4,075 4,075 COMPZ CASING CIRC T M/U to top drive, attempt to circulate with no luck. Liner pressured up to 800 psi no returns. Blow down top drive, blow down MPD skid to eliminate all surface equipment. 09:00 10:45 1.75 4,075 3,834 COMPZ CASING MPDA T PJSM-Pull RCD bearing, install trip nipple, pull up to 4024'MD. Rack back 2 stands DP, C/O slip inserts, pull ZXP out of hole and lay down. 10:45 11:30 0.75 3,834 3,834 COMPZ CASING OWFF T Observe well for flow, observe flow, shut in @ 10-:45. ISICP-100 psi. Fill poor boy, M/U head pin from cement line to attempt circulation through tubing. Page 42 of 61 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:30 12:00 0.50 3,834 4,023 COMPZ CASING SIPB T Rig down circ equipment, continue to monitor casing pressure up to 250 psi. M/U tubing XO to drill pipe, P/U stand of 4"drill pipe, file tool joints to strip through annular. 12:00 13:30 1.50 4,023 4,120 COMPZ CASING RUNL T Strip in hole from 4023'MD to 4120' MD, install bell guide and TIW valve. Monitor tubing and annular pressures. 13:30 14:00 0.50 4,120 4,120 COMPZ CASING CIRC T Establish circulation, pressure up on string to 1980 psi @ 21 gpm pumped 7 bbl. Kill pump and record 380 PSI on casing, 270 psi on tubing.Tubing fell off to 208 psi. Open bleeder and bleed tubing to 75 psi, shut in bleeder pipe pressured up to 230 psi, float not holding or leak in string. 14:00 18:30 4.50 4,120 4,120 COMPZ CASING CIRC T Bring on pump at 1 bpm 345 psi, 300 psi casing. Observe Mud weight out 10.3ppg indicating barite sag @ 580 stks then climb to 12.6 ppg @ 2400 stks. 18:30 19:45 1.25 4,120 4,120 COMPZ CASING CIRC T Mix and pump Rhodamine tracer dye pill @ 2 bpm, 350 psi on pipe, circulating through gas buster due gas/oil in mud. Observe dye back on shakers @ 70 bbl, indicating uppermost Frac Sleeve#7 @ 1168' was open. 19:45 21:15 1.50 4,120 4,120 COMPZ CASING MPDA T Close TIW and install dart valve to strip in hole. Remove trip nipple and install MPD bearing. Open annular and line up#1 mud pump on MPD. SIMOPS-Test second TIW valve. 21:15 22:45 1.50 4,120 4,975 COMPZ CASING TRIP T Strip in hole from 4120'MD to 4975' MD holding 250 psi annular pressure with MPD choke while in slips, 75 psi while stripping in @ 30 fpm. Gaining volume in 2X excess of displacement. Stop at ten stands to circ in kill weight mud. 22:45 00:00 1.25 4,975 4,975 COMPZ CASING CIRC T Establish circulation through MPD choke holding 250 psi annular pressure. Pump 2 bpm, standpipe 355 psi. Return mud weight dropped to 10.7 ppg. 03/24/2015 Continue stripping in to casing shoe, displace well to KWM. Update AOGCC on BOP test timing. 00:00 01:15 1.25 4,975 4,975 COMPZ CASING CIRC T Continue circulating @ 4975'MD @ 2 bpm, 340 psi,4%flow out.Total strokes 2268. Blow down top drive. Page 43 of 61 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:15 03:30 2.25 4,975 6,875 COMPZ CASING RUNL T Strip in hole from 4975' MD @ 2 bpm to 6875' MD(20 stands)while circulating through MPD @ 29 spm. Holding 75 psi on annulus while in slips and 25 psi while stripping in @ 30 fpm. Monitor dispacement via pits 1-2-3. Filling pipe from the top with fillup hose. 03:30 05:30 2.00 6,875 6,875 COMPZ CASING CIRC T Establish SIP 88 psi. Circulate @ 2 bpm through gas buster while holding 100 psi on annulus with rig auto choke for first 100 bbl, slowly open choke as 12.65 ppg mud came around. Pump pressure ICP=245 psi, FCP=275 psi. Blow down top drive. Total pumped 1727 stk=174 bbl. 05:30 10:30 5.00 6,875 10,675 COMPZ CASING RUNL T Continue stripping in hole with MPD @ 30 fpm, reducing to 20 fpm per tripping schedule. Strip in from 6875' MD to 10675' MD(40 stands)filling pipe from the top with fill up hose. Pump to RCD @ 29 spm, holding 50 psi on annulus in slips, 20 stripping, increase to 100/40 psi as annular pressure rises and displacement dictates. 10:30 12:00 1.50 10,675 10,675 COMPZ CASING CIRC T Establish SIP 120 psi. Circulate @ 2 bpm through gas buster while holding 100 psi on annulus with rig auto choke for first 70 bbl, slowly open choke as 12.65 ppg mud came around. Pump pressure ICP=285 psi, FCP=450 psi. Blow down top drive. OA pressure @ 12:00=200 psi 12:00 16:15 4.25 10,675 10,675 COMPZ CASING CIRC T Continue circulating @ 10,675' MD thru poor boy de-gasser @ 2 bpm, FCP=515 psi with fully opened choke. Total pumped 6134 stks=617 bbl until 12.5 ppg out. 16:15 16:30 0.25 10,675 10,675 COMPZ CASING MPDA T Shut down pump with 50 psi on annulus. Blow down top trive and line up pump#1 on MPD. 16:30 20:15 3.75 10,675 12,251 COMPZ CASING RUNL T Continue stripping in hole with MPD @ 8 fpm per tripping schedule. Strip in from 10675' MD to 12251' MD(17 stands). Pump to RCD @ 29 spm, holding 60 psi on annulus in slips, 20 stripping, reduce choke to 100% open @ 11,333'due decreased returns. (Later noted the dart valve was filling pipe, displacement was correct). Page 44 of 61 Time Logs110 S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:15 00:00 3.75 12,251 12,151 COMPZ CASING CIRC T Circulate @ 12251' MD thru poor boy degasser via ful open auto choke. Stage pumps up to 3.5 bpm. Observe 2 bbl to fill pipe, indicating the dart valve leaked and filled pipe. Pump total XXX bbl. .5 bpm=250 psi, 1 bpm=410 psi, 1.5 bpm=475 psi, 2 bpm=545 psi, 2.5 bpm=625 psi, 3 bpm=730 psi, 3.5 bpm=855 psi. FCP=860 psi. 33/25/2015 Complete displacement to 12.7 ppg KWM. Obtain 30 minute no-flow.Stip back up hole to 6670' MD, remove bearing assy. Set Baker storm packer. Test BOPE. Pull storm packer CBU 12.7 in/out. 00:00 00:30 0.50 12,151 12,151 COMPZ CASING CIRC T Continue to circulate 12.7 ppg kill weight mud around thru gas buster 3.5 bpm, 928 psi until 12.7 ppg in/out. Total pumped=825 bbl. 00:30 01:30 1.00 12,151 12,151 COMPZ CASING OWFF T Shut down mud pumps,shut in chokes to monitor pressure for build=0 psi. Open chokes and monitor well for flow at slop tank, then at RCD inlet. No flow 30 minutes. 01:30 06:00 4.50 12,151 9,517 COMPZ CASING TRIP T Strip out of hole with MPD from 12151' MD to 9517' MD @ 100 fph, holding 130 psi on annulus while pulling, 30 psi in slips. Slowly pulling pressure to 120-110 psi. Monitor displacement via pits 1-2-3, pumping in @ 29 spm. 06:00 10:45 4.75 9,517 6,675 COMPZ CASING TRIP T Strip out of hole with MPD from 9517' MD to 6675' MD @ 100 fph, holding 110 psi on annulus while pulling, 30 psi in slips. Monitor displacement via pits 1-2-3, pumping in @ 29 spm. 10:45 11:15 0.50 6,675 6,675 COMPZ CASING OWFF T Shut in chokes and monitor for pressure build-0 psi. No flow check for 30 minutes. 11:15 12:00 0.75 6,675 6,575 COMPZ CASING MPDA T PJSM, pull up to 6575' MD, removing MPD bearing. Install trip nipple. Total losses for tour=8 bbl OA pressure=200 psi 12:00 13:30 1.50 6,575 6,677 COMPZ WHDBO MPSP T P/U BOT test packer and RIH per rep. Set packer @ 63' COE. LID double and test storm packer to 500 psi for 5 minutes charted. 13:30 14:00 0.50 6,677 0 COMPZ WHDBO RURD T Drain stack, pull wear bushing and set test plug 14:00 14:45 0.75 0 0 COMPZ WHDBO RURD T R/U to test BOPE. M/U floor valve#2 &3%" Dart, (Floor valve#1 and Dart are downhole) flood lines with fresh water. Perform shell test. Page 45 of.61 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:45 19:00 4.25 0 0 COMPZ WHDBO BOPE T Test BOPE all tests 250/3500 psi 5 min ea charted. Chokes to 250/2000 psi.Witness waived by AOGCC Lou Grimaldi. Tested using 4",4'/2'and 3'/z"test joints.W/4'%"jt tested annular,2-7/8"x5%"Upper rams, 2-7/8"x5%"lower rams with all test joints.Tested choke valves 1-15, manual operated and super auto choke, choke and kill manual and HCR valves,4"valve on kill line,4" TIW#2,3%" Dart valve, 3%"TIW, upper and lower IBOP.TIW#1 and 4"Dart valve are in hole to be tested when out. Tested blind rams. 19:00 19:30 0.50 0 0 COMPZ WHDBO BOPE T Perform accumulator test. Accumulator pressure=3000 psi, manifold=1500 psi,Accumulator after performing all functions=1650 psi. 200 psi attained=22 seconds with 2 electric pumps,full pressure attained=110 sec with 2 electric and 2 air pumps.6 bottle N2 average=1992 psi. Closing times: Annular=24 sec, UPR=18 sec, Blinds=18 sec, LPR= 16 sec, choke HCR=2 sec, Kill HCR=2 sec. 19:30 20:15 0.75 0 0 COMPZ WHDBO RURD T Drain stack and rig down test equipment. Blow down choke, kill, test pump and top drive. 20:15 21:00 0.75 0 0 COMPZ WHDBO RURD T Pull test plug and set wear bushing. Fill stack with 12.7 ppg Klashield. 21:00 22:30 1.50 0 6,575 COMPZ WHDBO MPSP T M/U overshot&RIH to retrieve Baker storm packer as per BOT rep. Open equalizer valve and observe no flow via drill pipe. Un-seat packer and observe no flow on casing side. Pull packer to rig floor @ 15 fpm pumping 6 spm, lay down packer. 22:30 23:45 1.25 6,575 6,670 COMPZ CASING CIRC T RIH with double and P/U single from shed to 6670' MD. Establish circulation @ 6670' MD,stage up to 3.5 bpm 360 psi. 23:45 00:00 0.25 6,670 6,670 COMPZ CASING OWFF T Shut down pumps, blow down topdrive and monitor well for flow. OA pressure=50 psi 33/26/2015 Obtain 30 minute no-flow, install bearing assy. Strip out of hole to liner top, pull bearing and trip liner out. Found 2.125"ball in Frac Sleeve#7. UD liner assembly and prep to P/U BHA. 00:00 00:15 0.25 6,670 6,670 COMPZ CASING OWFF T Continue monitoring well for flow after circulation,static 30 min 00:15 01:15 1.00 6,670 6,670 COMPZ CASING MPDA T Pull trip nipple and install RCD bearing. Blow down kill line. Page 46 of 61 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 01:15 06:00 4.75 6,670 4,026 COMPZ CASING TRIP T Establish circulation through MPD choke skid, strip out of hole from 6670'MD to 4026'MD holding 110-80 psi on annulus while pulling, 30 psi in slips. Monitor displacement via pits 1-2-3, pumping 29 spm to RCD. SIMOPS-Bring BHA components to rig floor. 06:00 07:00 1.00 4,026 4,026 COMPZ CASING OWFF T Monitor well for flow,decreasing trend.6.5 min/qt, 13 min/qt, 20 min/qt. Decision to POOH per team. 07:00 08:00 1.00 4,026 4,026 COMPZ CASING MPDA T Pull MPD bearing, install trip nipple. 08:00 11:00 3.00 4,026 2,932 COMPZ CASING PULL T PJSM, L/D 4%" L-80 IBT-M liner assy. Pull from 4026'MD to 2932' MD @ 25 fpm, bad collar on joint #68. Layed down#7 Frac Sleeve and inspected, found 2.125"frac ball left in sleeve. Monitor displacement via TT-2. 11:00 12:00 1.00 2,932 2,932 COMPZ CASING CIRC T Establish circulation through liner shoe,stage pumps up to 3.5 bpm, 360 psi, 8%flow out. OA pressure @ 11:30, 100 psi. Losses for tour=5 bbl. 12:00 16:30 4.50 2,932 2,932 COMPZ CASING CIRC T Continue circulating @ 2932'MD @ 200 gpm 500 psi to even out mud weight, pumped until 12.7 ppg in, 12.5+out. Total pumped 1242 bbl. SIMOPS-Tested 4"TIW valve#1 and 4"Dart valve. 16:30 17:15 0.75 2,932 2,932 COMPZ CASING OWFF T Observe well for flow, 30 minutes static slight drop. 17:15 00:00 6.75 2,932 0 COMPZ CASING PULL T Continue laying down liner assy from 2932'MD. Monitor displacement via TT. Slow pulling speed to 11.7 fpm due hole fill, increase to 15 fpm @ 2000' MD. Calc Fill=11.7 bbl,Actual Fill=15.1 bbl. Sweel A 6.39", B thru F=6.37", G=6.3", H=6.25"OD. Swell A in the hole 95.8 hrs, Swell H in the hole 77.7 hrs.Wrap swell packers for return to Baker along with Frac#7. 03/27/2015 P/U cleanout assembly and RIH to 6000', M/U RCD bearing, C&C and strip in to shoe. Establish circulation @.5 bpm, losses @ 40%,consult engineer and reduce MW to 12.0 ppg to increase pump rate. 00:00 00:30 0.50 0 0 COMPZ CASING RURD T Clean and clear rig floor, rig down tubing handling equipment. __ 00:30 01:45 1.25 0 0 COMPZ CASING BHAH T M/U cleanout BHA#4 to 110' MD. Monitor well via TT. 01:45 02:00 0.25 0 110 COMPZ CASING CIRC T C/O PS-21 inserts, pump on string @ 2 bpm, 186 psi to check floats. Blow down top drive. Page 47 of 61 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 06:30 4.50 110 4,094 COMPZ CASING TRIP T RIH out of derrick with 4"DP @ 50 fpm from 110'MD to 4094'MD filling pipe every 20 stands. Monityor displacement via pit#2. 06:30 07:30 1.00 4,094 4,835 COMPZ CASING PULD T RIH from 4094'MD picking up 4" HWDP and jars out of shed to 4835' MD. 07:30 08:15 0.75 4,835 6,065 COMPZ CASING TRIP T Continue RIH out of derrick @ 50 fpm from 4835'MD to 6065'MD. 08:15 09:00 0.75 6,065 6,065 COMPZ CASING MPDA T PJSM, remove trip nipple, install RCD bearing. 09:00 10:30 1.50 6,065 6,065 COMPZ CASING CIRC T Fill pipe, break circulation through MPD choke manifold. Stage pumps up to 3 bpm, 125 gpm, 300 psi, 7% flow out. Pump total 190 bbl, shuit down blow down top drive. 10:30 12:00 1.50 6,065 8,090 COMPZ CASING TRIP T Continue RIH from 6065'MD to 8090' MD @ 50 fpm, monitoring displacement via pit#2. 12:00 12:30 0.50 8,090 8,090 COMPZ CASING CIRC T Fill pipe staging pumps to 3 bpm, 760 psi,4%flow out, blow down top drive. 12:30 14:30 2.00 8,090 10,338 COMPZ CASING TRIP T Continue RIH from 8090'MD to 10,338' MD @ 50 fpm, monitoring displacement via pits#2-3. 14:30 16:00 1.50 10,338 10,338 COMPZ CASING CIRC T Fill pipe, break circulation and stage up to 2 bpm, 775 psi,4%flow out. Shut down, blow down top drive. P/U=142k, 5/0=73k. 16:00 17:30 1.50 10,338 11,287 COMPZ CASING TRIP T Continue RIH from 10,338' MD to 11,287' MD @ 50 fpm, monitoring displacement via pit#2. 17:30 18:00 0.50 11,287 11,287 COMPZ CASING CIRC T Fill pipe, break circulation and stage up to 1 bpm, 660 psi, 1%flow out. Shut down, blow down top drive. P/U=161k, 5/0=75k. 18:00 19:15 1.25 11,287 12,232 COMPZ CASING TRIP T Continue RIH from 11,287'MD to 12,232' MD @ 50 fpm, monitoring displacement via pit#2. 19:15 20:00 0.75 12,232 12,232 COMPZ CASING CIRC T Fill pipe and break circulation @.5 bpm, attempt to stage up to.8 bpm observe dynamic losses, reduce rate to.5 bpm 580 psi, 1%flow out. Still seeing 30-40%losses. 20:00 00:00 4.00 12,232 12,232 COMPZ CASING CIRC T Continue circulating @ .5 bpm observing losses 10 bph. Discuss with engineer, decide to start cutting mud weight in to 12.0 ppg with centrifuge. MW in @ 00:00 12.0 ppg, MW out 12.4 ppg. SIMOPS=Cut and slip drilling line. Service and inspect blocks,topdrive and crown. Perform PM's on deadman, PS-21 slips,topdrive. Page 48 of 61 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/28/2015 24 hr Summary Complete full circulation at casing shoe, reduce mud weight to 12.0 ppg for cleanout. RIH to 14,100'MD and CBU @ 1-2 bpm. RIH to bottom and CBU,displace to 12.7 NaBr Klashield mud. Pump out of lateral, CBU, flow check and strip to surface. 00:00 06:00 6.00 12,232 12,232 COMPZ CASING CIRC T Continue circulating @ 12,232'MD pumping 12.0 ppg mud in, MW out varying 12.0-12.4+ppg. .5 bpm staging up to 1.2 bpm 689 psi, 20 rpm, minimal returns. SIMOPS-Work on MP2's, clean and organize rig, complete floorhand inventory,work on#2 charge pump. 06:00 09:00 3.00 12,232 12,232 COMPZ CASING CIRC T Continue circulating 12.0 ppg in, @ 1.5 bpm, 825 psi, minimal returns, 30 rpm, 9k Tq, 13.4+ppg mud weight out @ 6709 stks total. Continue circulating until 13.0 ppg coming back. SIMOPS-replace 4W IBT-M Seal rings, Complete MP2's,clean rig. 09:00 12:00 3.00 12,232 13,077 COMPZ CASING REAM T PJSM,wash and ream down from 12,232'MD to 13,077'MD @ 1.5 bpm, 827 psi, 1%flow out, 30 rpm, 9-10k Tq, P/U=161k, 5/0=74k, ROT=109k. Fluid losses for tour=26 bbl. 12:00 15:30 3.50 13,077 13,985 COMPZ CASING REAM T Wash and ream down from 13,077' MD to 13,985'MD @ 1.5 bpm, 830 psi, 1%flow out, 30 rpm, 9-10k Tq, FCP=1080 psi. P/U=167k, 5/O=74k, ROT=100k. 15:30 16:00 0.50 13,985 14,040 COMPZ CASING REAM T With pumps off choke pressure 100 psi,continue wash and ream down from 13,985' MD to 14,040' MD observe 50 bph dynamic loss rate. Reduce pump rate to.8 bpm, 800 psi, minimal returns. 16:00 21:00 5.00 14,040 12,237 COMPZ CASING BKRM T Backream out of hole from 14,040' MD to 12,237'MD @ 15 fpm, 1 bpm, 880 psi, minimal returns,30 rpm, 10-11k Tq, P/U=168k, 5/0=73k, ROT=104k,Approximately 30 bpm losses. 21:00 22:15 1.25 12,237 12,237 COMPZ CASING CIRC T Attempt to circulate @ .5 bpm, 10 rpm. Observe 26 bph losses. Reduce rate to.3 bpm, stop rotary, no reduction in loss rate. Page 49 of 61 Time Logs • Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 22:15 00:00 1.75 12,237 11,287 COMPZ CASING TRIP T Pump out of hole from 12,237' MD to 11,287' MD @ 1.1 bpm 770 psi, 30 fpm, 1%flow out. P/U=162k, S/0=75k. Pumping out to where we can re-gain circulation. Consult with engineer and reduce MW in to 11.5 ppg. Current MW out 12.8 ppg. Total loss for tour 176 bbl,total for day 202 bbl. OA pressure=120 psi 03/29/2015 Pump out of hole to 7397'to re-establish full circulation. Reduce MW to 11.5 ppg to attain 230 gpm. RBIH and perform cleanout to TD 00:00 04:30 4.50 11,287 10,242 COMPZ CASING TRIP T Continue to pump out of hole from 11,287'MD to 10,242' MD @ 1 bpm, 1800 fph, 772 psi, minimal flow out pulling, 0 flow out while stationary. Attempt to establish circulation. Dynamic losses 55 bph. Mud weight out 12.6 ppg 04:30 06:00 1.50 10,242 9,293 COMPZ CASING TRIP T Continue to pump out of hole from 11,242' MD to 9,293'MD @ 1 bpm, 1800 fph, 772 psi, minimal flow out pulling, 0 flow out while stationary. Attempt to establish circulation @.5 bpm losing 24 bph. Continue pumping out 1800 fph to 8,630' MD. Mud weight out 13.4 ppg. 06:00 08:45 2.75 9,293 7,397 COMPZ CASING TRIP T Continue to pump out of hole from 8,630'MD to 8,345' MD @ 1 bpm, 1800 fph, 782 psi, minimal flow out pulling, 0 flow out while stationary. Attempt to establish circulation @.5 bpm losing 24 bph. Continue pumping out 1800 fph to 7,397'MD. 08:45 12:00 3.25 7,397 7,397 COMPZ CASING CIRC T Establish circulation @ 7,397', Rotate and reciprocate. Stage pumps up to 4 bpm full returns 922 psi,7%flow out, 50 rpm, 5k Tq. 11.5 ppg in up to 14.2 ppg max out weight. Circulate until 11.5 ppg in/out. Reduce rate to 2 bpm to treat heavy mud returns. 12:00 12:45 0.75 7,397 7,397 COMPZ CASING CIRC T Continue circulating and treating heavy mud returns in pits. Total pumped 4031 total strokes. 11.5 ppg in/out. P/U=150k, S/O=75k. 12:45 13:30 0.75 7,397 7,397 COMPZ CASING OWFF T Monitor well 20 minutes observing pressure with choke shut in. Pressure build to 250 psi. Obtain SPR's, Blow down top drive. Line up injection line to RCD and circ across top adjusting choke reaction parameters. Page 50 of 61 Time Logs 111 • Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 13:30 17:00 3.50 7,397 9,769 COMPZ CASING TRIP T Strip in hole from 7,397'MD to 9,769' MD @ 100 fph maintaining 160 psi stripping and 260 psi in slips. Monitor displacement via active pits 1-4. 17:00 19:00 2.00 9,769 9,769 COMPZ CASING CIRC T Fill pipe maintaining 260 psi on annulus, establish circulation @ 1 bpm while opening chokes. Shut in injection line @ RCD. Continue circulating while R&R staging puimps up to 220 gpm 1050 psi. Pump total 4530 stks until 11.5 ppg in/out. 19:00 19:30 0.50 9,769 9,769 COMPZ CASING OWFF T Monitor well 20 minutes observing pressure with choke shut in. Pressure build to 230 psi. Blow down top drive. Line up injection line to RCD and circ across top adjusting choke reaction parameters for 260/130 psi stripping. 19:30 23:00 3.50 9,769 12,237 COMPZ CASING TRIP T Strip in hole from 9,769'MD to 12,237'MD @ 100 fph maintaining 160 psi stripping and 260 psi in slips. Monitor displacement via active pits 1-4. 23:00 00:00 1.00 12,237 12,237 COMPZ CASING CIRC T Establish circulation @ 12,237'MD, stage up pumps to 3 bpm 790 psi while R&R,40 rpm, 10k Tq, P/U=175k, S/O=80k, ROT=105k. OA pressure=240 psi Losses today=81 bbl 03/30/2015 Continue CBU @ shoe to 11.5 ppg in/out @ 230 gpm. Ream in@ 16 fph 40 rpm 230 gpm and perform cleanout to TD, utilizing MPD system circulating as required to maintain full circulation. 00:00 01:30 1.50 12,237 12,237 COMPZ CASING CIRC T Continue to circulate while R&R from 12,237' MD to 12,139' MD staging pumps up to 5.5 bpm, ICP=1471 psi, FCP=1344 psi,40 rpm 10-11k Tq, 10%flow out. 01:30 07:15 5.75 12,237 14,035 COMPZ CASING REAM T Wash and ream in hole from 12,237' MD to 14,035'MD @ 5.5 bpm, 1389 psi, 9-10%flow out, 10k Tq @ 1000 ft/hr. P/U=165k, 5/0=81k, ROT=109k. Staging pumps up and down as per MPD schedule holding 250 psi annulus in slips, SIMOPS-Clean#1 suction pot. 07:15 09:45 2.50 14,035 14,035 COMPZ CASING CIRC T Circulate bottoms up while R&R from 14,035' MD to 13,940' MD reducing rate to 4 bpm monitoring loss rate. 1069 psi, 5%flow out,40 rpm, 10k Tq, reducing flow rate to 3 bpm on the down stroke. Page 51 of 61 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 09:45 12:00 2.25 14,035 14,450 COMPZ CASING REAM T Continue to wash and ream from 14,035'MD to 14,450' MD @ 5.5 bpm, 1587 psi, 7%flow out, 490 rpm, 10k Tq, staging pumps up and down per MPD schedule, holding 260 psi on annulus in slips. P/U=165k, 5/0=78k, ROT=110k. OA pressure=300 psi Fluid lost this tour=9 bbl 12:00 14:30 2.50 14,450 14,450 COMPZ CASING CIRC T Circulate bottoms up while R&R from 14,515' MD to 14,420'MD @ 230 gpm 1660 psi, 9%flow out,40 rpm, 10k Tq, reduce flow rate to 128 gpm @ 2000 stks due dynamic loss 7 bph. Pumped 5800 stks until 11.5 ppg in/out. P/U=170k, S/0=79k, _ ROT=110k. 14:30 18:00 3.50 14,450 15,464 COMPZ CASING REAM T Wash and ream down from 14,450' MD to 15,464'MD @ 210 gpm, 1470 psi, 7%flow out,40 rpm, 10k Tq, reduce rate to 189 gpm 1375 psi to manage loss rate. Holding 260 psi on MPD chokes while in slips. P/U=175k, 5/0=75k, ROT=110k. 18:00 22:00 4.00 15,464 15,464 COMPZ CASING CIRC T Circulate bottoms up while R&R from 15,464' MD to 15,369'MD @ 147 gpm 1065 psi, 6%flow out,40 rpm, 12k Tq, Pumped 5757 stks until 11.5 ppg in/out. P/U=172k, S/O=78k, ROT=110k. 22:00 00:00 2.00 15,464 15,938 COMPZ CASING REAM T Wash and ream down from 15,464' MD to 15,938'MD @ 147 gpm, 1070 psi, 5%flow out,40 rpm, 11k Tq, Holding 260 psi on MPD chokes while in slips. P/U=175k, S/O=75k, ROT=110k. 33/31/2015 Wash and ream to bottom, CBU,displace 11.5 ppg to 12.7 ppg sodium bromide KLAshield. Well Static, Pump out of hole to shoe, monitor well; Static, continue to pull on elevators with MPD back pressure to mitigate swab. 00:00 01:00 1.00 15,938 16,168 COMPZ CASING REAM T Wash and ream from 15,464'to 15,938'at 128 GPM, 990 psi,4% FO,40 RPM, 12K Torque, Holding 260 psi on MPD chokes while in slips per MPD schedule. PU=175K, SO=73K, ROT=110K. 01:00 07:30 6.50 16,168 16,168 COMPZ CASING CIRC T Circulate with rotation at 150 GPM with 1120 psi, 5% FO,40 RPM with 13K torque. Total 332 BBL circulated. 07:30 07:45 0.25 16,168 16,168 COMPZ CASING SFTY T PJSM for displacement of 11.5 ppg to 12.7 ppg sodium bromide KLAshield mud. Page 52 of 61 Time Logs Date From To Dur S. Depth E. Death Phase Code .' Subcode T Comment 07:45 12:00 4.25 16,168 16,145 COMPZ CASING DISP T Displace 11.5 ppg to 12.7 ppg sodium bromide KLAshield mud. Rotate and recip from 16050'to 16145'with 40 RPM 13K torque. ICP= 1588 at 220 GPM, 9%FO, reducing rate per MI pump schedule. Pump 17 BBL 12.7 ppg high vis spacer followed by 645 BBL of 12.7 ppg new mud. LD double after BU. Monitor displacement with one for one returns; good. FCP=330 psi at 30 GPM. Crew change. OAP=210 psi. 12:00 13:30 1.50 16,145 16,145 COMPZ CASING DISP T Displace 11.5 ppg to 12.7 ppg sodium bromide KLAshield mud. Rotate and recip from 16050'to 16145'with 40 RPM 13K torque. After 690 BBLs away 12.5 ppg mud in and out. 13:30 14:00 0.50 16,145 16,145 COMPZ CASING OWFF T Blow down top drive and observe well for flow; Static. 14:00 20:30 6.50 16,145 12,237 COMPZ CASING BKRM T PU double and pump out of the hole with 30 RPM rotation at 30 GPM with ICP=280 psi, FCP=200 psi, 1% FO,40 RPM with 13K torque at 2000 FPH. PU= 175K, SO=75K, Rot= 110K. 20:30 21:30 1.00 12,237 12,237 COMPZ CASING OWFF T Blow down top drive at shoe and monitor well for 30 minutes; Static 21:30 00:00 2.50 12,237 9,579 COMPZ CASING STRP T Line up to injection line and obtain MPD parameters for stripping out Vs string speed. Drop 2.41"rabbit and POOH/strip out with 35 psi back pressure on slips, and 180 psi back pressure pulling. Pull per MPD pressure schedule to 9579'. Crew change. 34/01/2015 Continue to strip out on elevators with MPD back pressure to mitigate swab. POOH, LD BHA, RU to run liner and run liner per detail. MU hanger and flow check; good. RIH on drill pipe to 4125'. 00:00 06:00 6.00 9,579 4,378 COMPZ CASING TRIP T POOH/strip out with 35 psi back pressure on slips,and 150 psi back pressure pulling. Pull per MPD pressure schedule to 4378'. LD 1st HW joint, LD jars, PU HW replacement and continue to strip out with 150 psi to 100 psi back pressure. 06:00 10:00 4.00 4,378 205 COMPZ CASING TRIP T Continue to strip out from 4378'to 205'with 100 psi to 50 psi while pulling and 30 psi on slips. 10:00 10:45 0.75 205 205 COMPZ CASING MPDA T PJSM to pull MPD bearing. Pull bearing, LD and install trip nipple. 10:45 11:15 0.50 205 110 COMPZ CASING TRIP T Continue to pull out on elevators monitoring on TT. 11:15 12:00 0.75 110 71 COMPZ CASING BHAH T Pull and LD clean-out BHA per SLB rep. Losses for tour= 12 BBL. Crew change. Page 53 of 61 Time Logs Date From To Dur " S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:00 1.00 71 0 COMPZ CASING BHAH T Continue to pull and LD clean-out BHA per SLB rep. 13:00 14:00 1.00 0 0 COMPZ CASING RURD T Change out slip inserts, PU 9 joints, 4"HW and stand back for liner run. 14:00 15:00 1.00 0 0 COMPZ CASING RURD T Clear and clean rig floor and blow down MPD choke skid. 15:00 16:00 1.00 0 0 COMPZ CASING RURD T RU 4.5"liner handling equipment, line up nad function test fill-up hose, verify liner joint count and jewelry in shed. 16:00 16:15 0.25 0 0 COMPZ CASING SFTY T PJSM for running liner with rig crew, casing hand, Baker hand, CPAI rep. 16:15 22:30 6.25 0 4,030 COMPZ CASING PUTB T Run liner per running detail;4 1/2" 12.6#L-80 IBT-m to 4030', checking floats at 116'; Good. Fill on-the-fly and top every 10 joints. Running speeds per surge schedule. 22:30 23:15 0.75 4,030 4,076 COMPZ CASING OTHR T Change out elevators, PU tubing hanger, check shear screws and PAL mix;good. Change out slip inserts and elevators. 23:15 00:00 0.75 4,076 4,125 COMPZ CASING RUNL P PU stand#1 and change out slip inserts RIH to 4125', break circulation with 0.5 to 1.0 BPM at 120 psi. Blow down topdrive. Crew change. Losses for tour= 16 BBL. TTL today 28 BBL loss. OAP=80 psi. 34/02/2015 RIH with 4.5"liner on DP to 12266',filling every 20 stands, run to TD and tag bottom at 16168'. 00:00 06:00 6.00 4,125 8,773 COMPZ CASING RUNL P Run liner on DP per running detail;4 1/2" 12.6#L-80 IBT-m to 8773.', Fill every 10 stands. Running speeds per surge schedule at 2000 FPH. Hole giving proper displacement. 06:00 11:00 5.00 8,255 12,260 COMPZ CASING RUNL P Run liner on DP per running detail; 4 1/2" 12.6#L-80 IBT-m to 12260.', Fill every 20 stands. Running speeds per surge schedule at 2000 to 1000 FPH. Proper fill observed. 11:00 12:00 1.00 12,260 12,260 COMPZ CASING CIRC P Break circulate and recip pipe with 30 GPM with 300 psi. Circulate liner/DP volume. Crew change. OAP= 100 psi. No losses this tour. 12:00 14:00 2.00 12,260 12,260 COMPZ CASING CIRC P Continue to circulate and recip pipe with 30 GPM with 300 psi. Circulate liner/DP volume staging pumps to 50 GPM with 340 psi FCP, "-3%FO, no losses. PU= 140K, SO=75K, Rot= 104K. 10 RPM=8K torque, 15 RPM =8.5K torque, 20 RPM=9K torque. 14:00 19:30 5.50 12,260 16,150 COMPZ CASING RUNL P Run liner on DP per running detail;4 1/2" 12.6#L-80 IBT-m to 16150.', Fill every 20 stands. Running speeds per surge schedule at 1000 FPH. Proper fill observed. Page 54 of 61 Time Logs • i Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 19:30 20:15 0.75 16,150 16,168 COMPZ CASING RUNL P PU single form the shed and RIH and tag bottom at 16168'. PU and break over at 198K=PU, SO=75K. 20:15 22:30 2.25 16,168 16,163 COMPZ CASING CIRC P Stage pumps and Circulate at 1 BPM with 345 psi. Pump 103 BBL, break connection and drop 1.125" activation ball at 21:45. Establish circulate and attempt to move without success. Pull 40K over and work without success. 22:30 00:00 1.50 16,163 16,163 COMPZ CASING CIRC P Continue to pump 1.125"WIV ball down at 1 BPM with 435 psi, 1%FO. Work stretch in pipe while pumping without success with 85K to 200K indicated pull without success for movement. Crew change. OAP=220 psi. Losses for day=4.3 BBL. 34/03/2015 Pressure test ball on seat in WIV; Good. Set hanger; shoe at 16163'and TOL at 12156'. WIV, liner and IA all pressure tested good. Reverse displaced 12.7 ppg mud with 8.5 ppg brine, CBU 2X and moniotred well; Static. Pulled out sideways with 4"drill pipe. 00:00 02:30 2.50 16,163 16,163 COMPZ CASING CIRC P Continue to pump1.125"WIV ball down at 1 BPM with 440 psi, 1% FO. Work stretch in pipe while pumping without success with 85K to 200K indicated pull without success for movement. Pulled 200K indicated weight and parked string at 195 BBLs away to wait for ball to go on seat. Ball went on seat at 230 BBLs away. Continue to increase pressure to 1100 psi where WIV shifted closed. 02:30 04:00 1.50 16,163 16,163 COMPZ CASING PACK P Pump ball on seat at 230 BBL away. Continue to pressure up to 2000 psi for 30 minutes to chart; Good. Hanger set at 1770 psi per Baker rep. Continue to increase pressure to 3200 psi. Unsuccessful release. Increase pressure to 3400 psi, then 3500 with repeated failure to release. Decision made to Left-hand release. 04:00 05:30 1.50 16,163 16,163 COMPZ CASING PACK T Blow down tip drive and work in Left-hand torque to string with 5K torque slacking and working string to transfer torque to hanger. Stage torque to 10K and trap to work down string, hanger released. Remove torque and PU 8'string to expose dogs. Slack off and put 40K on dogs; no shear. Rotate at 10 RPM with 8K torque while slacking off and shear dogs; observed. Slack off again and verify TOL. TOL at 12141'. Page 55of61 ,J Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 06:30 1.00 16,163 12,141 COMPZ CASING PRTS P RU to test pump and IA, pressure up to 2000 psi for 15 minutes to chart; Good. Test tubing to 1000 psi to verify no communication after release efforts. 06:30 06:45 0.25 12,141 12,141 COMPZ WELLPF SFTY P PJSM for displacement to seawater with Mud engineer and rig crew. 06:45 09:00 2.25 12,141 12,141 COMPZ WELLPF DISP P LD double, blow down top drive, RU to reverse circulate for displacement. Displace reverse circulating with 8.5 brine from 12.7 ppg KLAshield. Pumped 59 BBL 8.5+ppg high Vis spacer followed by 500 BBL of 8.5 ppg brine. Staged pumps to 6 BPM with 2400 psi, 14%FO. Total BBL= 587. 09:00 09:30 0.50 12,141 12,141 COMPZ WELLPF RURD P RD and blow down reverse circ lines and equipment. 09:30 10:00 0.50 12,141 12,141 COMPZ WELLPF OWFF P Observe well for flow; Static. Crew change. 10:00 11:00 1.00 12,141 12,141 COMPZ WELLPF RURD P Clean shakers and troughs before circulation of brine. 11:00 12:00 1.00 12,141 12,141 COMPZ WELLPF CIRC P Circulate 2X BU with 7 BPM at1080 psi,7%FO. Total BBL=272. 12:00 13:15 1.25 12,141 12,141 COMPZ WELLPF CIRC P Continue to Circulate 2X BU with 7 BPM at1080 psi, 7%FO. Total BBL=755. 13:15 15:00 1.75 12,141 12,132 COMPZ WELLPF SLPC P Slip and cut 96'of drill line. Calibrate Totco and Amphion block height sensors. 15:00 15:30 0.50 12,132 12,132 COMPZ WELLPF SVRG P Service and inspect blocks and crown. Service top drive. 15:30 19:00 3.50 12,132 7,760 COMPZ WELLPF PULD P LD 4"doubles from 12132'to 11499'. LD 4"HW singles from 11499'to 10382'. LD 4"singles from 10382'to 7760'. Proper fill observed. 19:00 22:00 3.00 7,760 4,692 COMPZ WELLPF PULD P LD 4"singles from 7760'to 4692' Proper fill observed. Crew change. 22:00 00:00 2.00 4,692 2,675 COMPZ WELLPF PULD P LD 4"singles from 4692'to 2675'. Proper fill observed. 04/04/2015 LD drill pipe and hanger running tool. Continue to LD drill pipe for derrick. RU and run HES CAST-M/CBL logging tools. Decision from 1st run to run CBL with constant pressure. 00:00 02:30 2.50 2,675 75 COMPZ WELLPF PULD P LD 4"singles from 2675'to hanger running tool. Proper fill observed. 02:30 02:45 0.25 75 75 COMPZ WELLPF OWFF P Observe well for flow; Static. 02:45 03:30 0.75 75 0 COMPZ WELLPF BHAH P Change out PS-21 slip inserts. LD hanger running tool per Baker rep. 03:30 05:30 2.00 0 4,555 COMPZ WELLPF TRIP P Trip in the hole with 48 stands from the derrick. 05:30 10:30 5.00 4,555 0 COMPZ WELLPF PULD P Pull out with 4"drill pipe singles from 4555'to surface. Page 56 of 61 Time Logs • 410 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 11:00 0.50 0 0 COMPZ WELLPF RURD P Clear and clean rig floor, prep to RU E-Line. 11:00 12:00 1.00 0 0 COMPZ WELLPF QEVL T PJSM, RU HES E-line and monitor well during rig up via TT. Crew change. OAP=80 psi. 0 losses this tour. 12:00 13:30 1.50 0 0 COMPZ WELLPF QEVL T Continue to RU HES E-line, hoist and secure sheaves. 13:30 19:00 5.50 0 0 COMPZ WELLPF FLOG T RIH with HES CAST-M/CBL logging assembly to 11836'WLM. Unable to enter 39#casing. POOH to assembly to reconfigure centralizers. 19:00 20:00 1.00 0 0 COMPZ WELLPF FLOG T LD HES assembly and reconfigure/ retention centralizers. 20:00 00:00 4.00 0 0 COMPZ WELLPF QEVL T RIH with assembly to 12145'WLM and perform logging over interest interval. POOH with assembly. Attempt to upload data without success, send logs to engineers for evaluation. Crew change. OAP=80 psi No losses for the day. 04/05/2015 Continue POOH with E-Line. RU, RIH and perform CBL logging under pressure for evaluation. RU and run 3.5"9.3#L-80. EUE 8rd completion per running detail . 00:00 02:00 2.00 0 0 COMPZ WELLPF QEVL T POOH with CBL to surface and LD assembly. Proper fill observed while pulling. 02:00 02:15 0.25 0 0 COMPZ WELLPF SFTY T PJSM for change out of trip nipple and installing crossover. 02:15 03:30 1.25 0 0 COMPZ WELLPF QEVL T Pull PS-21 slips and RD MPD trip nipple, install 7"Otis crossover to MPD. MU CBL tool through lubricator. 03:30 03:36 0.10 0 0 COMPZ WELLPF SFTY T PJSM for PU and RU of grease head/lubricator. 03:36 04:00 0.40 0 0 COMPZ WELLPF QEVL T PU and RU of grease head/lubricator and pressure test to 1200 psi; Good. 04:00 08:00 4.00 0 0 COMPZ WELLPF QEVL T RIH with logging assembly to 12145' WLM. 08:00 10:30 2.50 0 0 COMPZ WELLPF QEVL T Pressure up to 1000 psi through Kill line, Log up from 12145' to 11500' with CBL. Bleed off pressure to 0 psi and POOH with assembly. 10:30 11:00 0.50 0 0 COMPZ WELLPF QEVL T LD E-Line logging assembly. RD E-Line equipment and clear off rig. 11:00 12:00 1.00 0 0 COMPZ WELLPF QEVL T RD Otis lubricator and crossover, install trip nipple, install PS-21 slips, blow down Kill lines and equipment. PU test joint. Crew change. OAP=80 psi, No losses for tour. 12:00 12:30 0.50 0 0 COMPZ RPCOM RURD P Drain stack, pull wear bushing, LD test joint and function Rams and bag. 12:30 13:30 1.00 0 0 COMPZ RPCOM RURD P RU tubing handling equipment, verify running detail and running order with staged equipment and jewelry. Page 57 of 61 Time Logs • II Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 15:00 1.50 0 0 COMPZ RPCOM WAIT T Waiting on order for decision on cement quality and quatity. SIMOPs; Mobilize new slips carrier to floor and prep and prime for service. Clear rig floor. 15:00 15:30 0.50 0 0 COMPZ RPCOM SVRG P Mechanical PM on topdrive; transducer replacement, bushing for TD PM'd. 15:30 16:30 1.00 0 0 COMPZ RPCOM RURD P Approval to run Upper completion, mob SLB I-Wire spool and equipment to rig floor, 16:30 16:45 0.25 0 0 COMPZ RPCOM SFTY P PJSM for running 3.5"completion with rig crew, SLB, Baker and CPAI rep. 16:45 23:00 6.25 0 3,187 COMPZ RPCOM RCST P Run 3.5"9.3#L-80. EUE 8rd uppper completion per running order and detail. MU and test guage per SLB and run I-Wire with clamps on every joint. Torque on 3.5"EUE 8rd= 2240 ftlbs. Monitor displacement via TT. RIH to 3187'. Crew change 23:00 00:00 1.00 3,187 3,187 COMPZ RPCOM RCST T While picking up the GLM with SOV, SLB/Camco rep noticed the SOV was not fully latched. LD GLM to shed and engaged latch with slick line 1"running tool. PU GLM and MU to string. 04/06/2015 Continue running 3.5"9.3#L-80. EUE 8rd to 6343'with I-Wire testing good every 30 joints. Tag at 12176'to No-Go. Space out, pump CI, land, RILDS,Test tubing;3500 psi; Good. Premier packer set. 00:00 06:00 6.00 3,187 6,590 COMPZ RPCOM PUTB P Continue to run 3 1/2"9.3#L-80. EUE 8rd upper completion per running order and detail to 6590'. Run with TEC I-Wire with clamps on every joint. MU torque for tubing at 2500 ftlb. Monitor displacement via TT. 06:00 12:00 6.00 6,590 9,954 COMPZ RPCOM PUTB P Continue to run 3 1/2"9.3#L-80. EUE 8rd upper completion to 9954'. Run with TEC I-Wire with clamps on every joint. MU torque for tubing at 2500 ftlb. Monitor displacement via TT. Crew change, OCP=80 psi, No losses this tour. 12:00 15:30 3.50 9,954 12,176 COMPZ RPCOM PUTB P Continue to run 3 1/2"9.3#L-80. EUE 8rd upper completion to 12176'. Run with TEC I-Wire with clamps on every joint. MU torque for tubing at 2500 ftlb. Monitor displacement via TT. TEC I-wire tested every 30 joints; Good tests. PU to joint#390 and tag up at 12176' tubing measure. PU= 105K, SO=70K. Page 58 of 61 Time Logs ! • Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 15:30 16:45 1.25 12,176 12,087 COMPZ RPCOM HOSO P LD joints#390 through#387, 12087'. MU 10.22'and 4.17'pups with 3.5 x4.5 crossover to 1-full 4.5"joint. 16:45 19:45 3.00 12,087 12,157 COMPZ RPCOM THGR P MU XO, headpin, and cement hose to landing joint and PU from skate and MU hanger and landing joint. Terminate TEC I-wire. 19:45 21:00 1.25 12,157 12,157 COMPZ RPCOM CRIH P Pump 132 BBL of Corrosion inhibited seawater from truck at 148 GPM with 400 psi, 2% FO. Chase and spot with 88 BBL seawater at 189 GPM with 600 psi,4% FO. 21:00 22:30 1.50 12,157 12,176 COMPZ RPCOM THGR P Darin stack and land hanger. Verify with Cameron rep pulling onw LDS, then RILDS. Test hanger seals; 5000 psi for 10 minutes witnessed by CPAI rep. blow down cement line and RU test equipment. 22:30 23:00 0.50 12,176 12,176 COMPZ RPCOM SEQP P PJSM. Drop ball and Rod witnessed by CPAI rep. Flush lines and test surface lines to 3500 psi while ball dropping. Line up to pump both directions. 23:00 00:00 1.00 12,176 12,176 COMPZ RPCOM PRTS P Pressure up on tubing to 3500 psi and chart for 30 minutes; Good. On the pressure up,there was a shift on the pressure curve at 1200 psi and 1900 psi as the Premier Packer was set with good indication to the surface. Crew change, OAP=80 psi, No losses for day. 04/07/2015 Complete IA test 3500 psi; Good,shear SOV, check flow both directions, set BPV,test and ND MPD and BOPE. Install and test tree, seals and hanger neck. Freeze protect well and equalize. 00:00 02:00 2.00 12,176 0 COMPZ RPCOM PRTS P Test IA to 3500 psi to chart for 30 minutes; Good. Bleed both sides to 0 psi and Pressure up on IA to 2380 psi to shear SOV, check flow both directions; Good. RD landing joint. 02:00 03:00 1.00 0 0 COMPZ RPCOM WWWH P MU and flush stack,top drive, choke and kill lines with 36 BBL fresh water. RD and LD equipment. 03:00 04:00 1.00 0 0 COMPZ WHDBO MPSP P Install BPV and PT to 1500 psi for 15 minutes; Good. Bleed down and blow down all lines. 04:00 04:15 0.25 0 0 COMPZ WHDBO SFTY P PJSM for ND of MPD and BOPE. 04:15 05:00 0.75 0 0 COMPZ WHDBO MPDA P ND MPD; pull PS-21 slips, remove trip nipple, remove trip nipple clamp. 05:00 10:00 5.00 0 0 COMPZ WHDBO NUND P ND BOPE, remove 2' 13 5/8"spool and slide Joe's box, install 2' 13 5/8" spool, remove 12' 13 5/8"spool. Remove BOP stack and LD 13 5/8" risers 12.5'. 2'and 11'x 13 5/8" adapter spool. Remove choke and kill lines. Page 59 of 61 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 12:00 2.00 COMPZ WHDBO WAIT T Wait on Cameron and Camco due to phase II weather convoy traffic. Prep adapter spool and tree, prep BOP annular to change out element. Crew change. 12:00 17:00 5.00 COMPZ WHDBO NUND P NU adapter spool, SLB terminate I-wire through well head. Cameron NU and test SRL seal and hanger neck 250/5000 psi 15 minutes each CPAI rep witness test; Good. SLB test TEC I-wire for continuity and function; 2340 psi and 130.86° F BHT. Cameron test adapter void 250/5000 psi for 15 minutes each, witness CPAI rep. Orient and NU tree verified by DSO. SIMOPs; clean RCD head atop annular,welder instil 2"nipple in floor for clean pits, stage tree to the BOP deck, Cut grating for carrier landing. 17:00 18:00 1.00 COMPZ WHDBO NUND P Continue to NU tree with wing valve. 18:00 21:00 3.00 COMPZ WHDBO PRTS P RU test equipment, fill and test tree 250/5000 psi for'5 minutes each; Good.dry rod BPV top plug, 21:00 22:00 1.00 COMPZ WHDBO MPSP P RU lubricator and test 1000 psi for 5 minutes; Good. Pull BPV. 22:00 23:15 1.25 COMPZ WHDBO FRZP P RU lines and valves, PJSM, pump diesel for freeze protect with rig. Pump 86 BBLs down the IA with returns to the tubing to the pits. PUmp at 76 GPM with ICP=550 psi, FCP=650 psi, 4% FO. 23:15 00:00 0.75 COMPZ WHDBO FRZP P Line up the IA and tubing in communication to allow diesel to equalize. SIMOPs; remove paint and excess rubber from new annular element. pre annular cap for removal. 04/08/2015 Continue to equalize diesel for FP. Set BPV and complete NU of tree. Button up tree and secure with tree cap. Perform rig maintenance until released for move. RDMO Rig Released 23:59 00:00 01:00 1.00 i 0 COMPZ WHDBO FRZP P Continue to allow IA and tubing to equalize diesel. Final pressures; Tubing=60 psi, IA= 0 psi, OA=80 psi. 01:00 02:30 1.50 COMPZ WHDBO OTHR P Blow down lines, drain stack, remove tree cap. 02:30 03:30 1.00 COMPZ WHDBO MPSP P MU and install BPV with lubricator by Cameron rep. LD lubricator and install tree cap. 03:30 04:30 1.00 DEMOB MOVE RURD P Secure tree cap, remove 1502 flanges for OA and IA, install gauges on OA and IA, install gauges on well head and secure well head. SIMOPs; finish cleaning pits. 1 Page 60 of 61 Time Logs 41110 • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 09:00 4.50 DEMOB MOVE RURD P Disconnect cement lines and mud lines at interconnects, slide Joe's flow box forward, install flow line, remove Kelly hose from TD. 09:00 12:00 3.00 DEMOB MOVE WAIT T Waiting on order; Fuel stand-down. PJSM; Change out Schaffer annular element, disconnect flow line and slide Joe's box out of the way, remove annular element, clean element cavity, install new element and torque all bonnet bolts to 3000 ft-lbs. Crew change 12:00 14:00 2.00 DEMOB MOVE WAIT T Waiting on order; Fuel stand-down. Continue to assembly annular, re-attach rotation cylinders, remove seized bolts from Joe's box, mobilize master bushing to rig floor. 14:00 17:00 3.00 DEMOB MOVE WAIT T Waiting on order; Fuel stand-down. Continue to remove seized bolts from Joe's box, change out#3 mix valve in pits, welder tie in slop tank to flow line in pits, change out PS-21 hydraulic isolation valve on floor, RD warm up shack for move, move and lay mats in courtyard. 17:00 19:00 2.00 DEMOB MOVE WAIT T Waiting on order; Fuel stand-down. Change out saver sub to 4 1/2" IF. 19:00 22:00 3.00 DEMOB MOVE RURD P Fuel restriction lift. Prep rig floor for scoping of derrick. Install bridle lines and bridle yokes to topdrive. LD used element, move parts house and stage on ice pad. Clean BOP deck and stack. 22:00 22:12 0.20 DEMOB MOVE SFTY P PJSM for derrick scope operations. 22:12 00:00 1.80 DEMOB MOVE RURD P Scope derrick down; bridle down, and pin top drive and blocks to move position, remove handrails at drawworks, RIG RELEASE; 23:59 4/8/2015 Move to 2L-316 Page 61 of 61 • • NADConversion Kuparuk River Unit Kuparuk 2L Pad 2L-328 Definitive Survey Report 23 March, 2015 4110 Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2L-328(Sierra) Project: Kuparuk River Unit TVD Reference: 115+41.06 @ 156.06usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: 115+41.06 @ 156.06usft(Doyon 25) Well: 2L-328(Sierra) North Reference: True Wellbore: 2L-328 Survey Calculation Method: Minimum Curvature Design: 2L-328 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 2L-328(Sierra) Well Position +N/-S 0.00 usft Northing: 5,927,617.60 usft Latitude: 70°12'47.492 N +E/-W 0.00 usft Easting: 460,742.41 usft Longitude: 150°18'59.777 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 115.O0usft Wellbore 2L-328 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2014 2/10/2015 18.73 80.78 57,545 Design 2L-328 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 41.06 Vertical Section: - Depth From(TVD) +N/-S +E/-W Direction 'i (usft) (usft) (usft) (°) 41.06 0.00 0.00 158.00 Survey Program Data y111111191 $111IIj� 0iii!,$',.''-,',11!1,,0,I,1'1,,ti '11,k11.'IhhN(Ai',''''ki 1i111;l0 From To N0Dd1I (usft) (usft) Survey(Wellbore) Tool Name Description - Survey Date 80.38 1,297.77 2L-328 Srvy#1-GYD-GC-SS(2L-328) GYD-GC-SS Gyrodata gyro single shots 3/19/2015 4:2 1,356.90 2,437.12 2L-328 Srvy#2-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/19/2015 4:3, 2,513.32 12,203.94 2L-328 Srvy#3-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/23/2015 11:2 12,295.68 16,104.26 2L-328 Srvy#4-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/23/2015 11:2 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 41.06 0.00 0.00 41.06 -115.00 0.00 0.00 5,927,617.60 460,742.41 0.00 0.00 UNDEFINED 80.38 0.41 259.05 80.38 -75.68 -0.03 -0.14 5,927,617.57 460,742.27 1.04 -0.03 GYD-GC-SS(1) 167.67 0.40 250.76 167.67 11.61 -0.19 -0.73 5,927,617.41 460,741.68 0.07 -0.10 GYD-GC-SS(1) 262.37 0.29 252.97 262.37 106.31 -0.37 -1.27 5,927,617.24 460,741.14 0.12 -0.14 GYD-GC-SS(1) 354.83 0.68 172.26 354.82 198.76 -0.98 -1.42 5,927,616.63 460,740.98 0.75 0.37 GYD-GC-SS(1) 446.99 1.70 158.60 446.96 290.90 -2.79 -0.85 5,927,614.81 460,741.55 1.14 2.27 GYD-GC-SS(1) 540.16 3.05 150.79 540.05 383.99 -6.24 0.86 5,927,611.35 460,743.24 1.49 6.11 GYD-GC-SS(1) 636.45 4.21 151.06 636.15 480.09 -11.57 3.82 5,927,606.01 460,746.17 1.20 12.16 GYD-GC-SS(1) 729.37 5.53 153.91 728.73 572.67 -18.58 7.44 5,927,598.98 460,749.76 1.44 20.01 GYD-GC-SS(1) 824.16 9.13 162.80 822.73 666.67 -29.87 11.68 5,927,587.67 460,753.93 3.97 32.07 GYD-GC-SS(1) 918.30 10.26 160.17 915.53 759.47 -44.89 16.73 5,927,572.62 460,758.91 1.29 47.89 GYD-GC-SS(1) 1,012.84 11.09 158.53 1,008.43 852.37 -61.27 22.91 5,927,556.21 460,765.00 0.93 65.39 GYD-GC-SS(1) 1,107.44 12.13 158.42 1,101 09 945.03 -78.98 29.90 5,927,538.47 460,771.90 1.10 84.43 GYD-GC-SS(1) 1,202.21 13.85 155.99 1,193.43 1,037.37 -98.60 38.18 5,927,518.80 460,780.07 1.90 105.73 GYD-GC-SS(1) 1,297.77 15.31 156.91 1,285.91 1,129.85 -120.66 47.78 5,927,496.70 460,789.56 1.55 129.77 GYD-GC-SS(1) 3/23/2015 4:48:58PM Page 2 COMPASS 5000.1 Build 65 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2L-328(Sierra) Project: Kuparuk River Unit TVD Reference: 115+41.06 @ 156.06usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: 115+41.06 @ 156.06usft(Doyon 25) Well: 2L-328(Sierra) North Reference: True Wellbore: 2L-328 Survey Calculation Method: Minimum Curvature Design: 2L-328 Database: OAKEDMP2 -nimmimmmimmmnnnrtn in.. Survey iii iiiiiiii ii ii ii 9( ( 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 1,356.90 16.08 158.82 1,342.84 1,186.78 -135.48 53.80 5,927,481.86 460,795.50 1.57 145.77 MWD+1FR-AK-CAZ-SC(2) 1,450.82 16.24 157.98 1,433.05 1,276.99 -159.78 63.42 5,927,457.51 460,805.00 0.30 171.90 M1ND+1FR-AK-CAZ-SC(2) 1,545.80 19.79 152.95 1,523.36 1,367.30 -186.42 75.72 5,927,430.80 460,817.15 4.08 201.21 MWD+IFR-AK-CAZ-SC(2) 1,640.91 21.82 150.66 1,612.27 1,456.21 -216.17 91.71 5,927,400.97 460,832.98 2.30 234.79 MWD+IFR-AK-CAZ-SC(2) 1,735.85 24.17 147.83 1,699.66 1,543.60 -248.01 110.70 5,927,369.04 460,851.81 2.73 271.42 MWD+IFR-AK-CAZ-SC(2) 1,831.33 27.05 145.86 1,785.75 1,629.69 -282.54 133.30 5,927,334.40 460,874.23 3.15 311.90 MWD+IFR-AK-CAZ-SC(2) 1,924.59 31.69 143.07 1,867.01 1,710.95 -319.69 159.93 5,927,297.11 460,900.67 5.19 356.32 MWD+IFR-AK-CAZ-SC(2) 2,020.63 35.31 142.38 1,947.08 1,791.02 -361.85 192.04 5,927,254.79 460,932.55 3.79 407.45 MWD+IFR-AK-CAZ-SC(2) 2,114.81 39.29 141.13 2,021.99 1,865.93 -406.65 227.39 5,927,209.81 460,967.66 4.30 462.22 MWD+IFR-AK-CAZ-SC(2) 2,209.11 43.59 141.30 2,092.66 1,936.60 -455.29 266.47 5,927,160.97 461,006.48 4.56 521.96 MWD+IFR-AK-CAZ-SC(2) 2,304.24 48.14 139.09 2,158.89 2,002.83 -507.69 310.20 5,927,108.35 461,049.94 5.06 586.92 MWD+IFR-AK-CAZ-SC(2) 2,398.22 51.71 137.70 2,219.39 2,063.33 -561.43 357.96 5,927,054.37 461,097.41 3.96 654.64 MWD+IFR-AK-CAZ-SC(2) 2,437.12 51.70 138.26 2,243.49 2,087.43 -584.11 378.39 5,927,031.58 461,117.73 1.13 683.33 MWD+I FR-AK-CAZ-SC(2) 2,464.00 51.54 137.72 2,260.18 2,104.12 -599.77 392.50 5,927,015.85 461,131.75 1.70 703.13 MWD+IFR-AK-CAZ-SC(3) 103/4"x13-1/2 „.. 2,513.32 51.24 136.71 2,290.96 2,134.90 -628.05 418.67 5,926,987.44 461,157.77 1.70 739.16 MWD+1FR-AK-CAZ-SC(3) 2,572.84 52.98 136.06 2,327.51 2,171.45 -662.06 451.08 5,926,953.27 461,189.99 3.05 782.82 MWD+IFR-AK-CAZ-SC(3) 2,668.20 57.14 133.57 2,382.12 2,226.06 -717.10 506.54 5,926,897.94 461,245.17 4.86 854.64 MWD+IFR-AK-CAZ-SC(3) 2,763.02 62.40 132.76 2,429.85 2,273.79 -773.12 566.28 5,926,841.62 461,304.61 5.60 928.95 MWD+IFR-AK-CAZ-SC(3) 2,857.80 67.43 131.46 2,470.02 2,313.96 -830.64 629.96 5,926,783.77 461,367.98 5.45 1,006.14 MWD+IFR-AK-CAZ-SC(3) 2,951.94 71.76 130.37 2,502.83 2,346.77 -888.41 696.62 5,926,725.67 461,434.34 4.73 1,084.67 MWD+IFR-AK-CAZ-SC(3) 3,047.05 73.63 130.38 2,531.12 2,375.06 -947.22 765.80 5,926,666.50 461,503.20 1.97 1,165.12 MWD+IFR-AK-CAZ-SC(3) 3,143.57 72.37 131.80 2,559.34 2,403.28 -1,007.88 835.36 5,926,605.48 461,572.44 1.92 1,247.43 MWD+IFR-AK-CAZ-SC(3) 3,238.51 71.68 134.40 2,588.65 2,432.59 -1,069.58 901.30 5,926,543.45 461,638.05 2.70 1,329.33 MWD+IFR-AK-CAZ-SC(3) 3,333.89 71.63 135.60 2,618.67 2,462.61 -1,133.59 965.31 5,926,479.11 461,701.72 1.20 1,412.66 MWD+I F R-AK-CAZ-SC(3) 3,427.90 71.50 135.33 2,648.40 2,492.34 -1,197.17 1,027.86 5,926,415.22 461,763.93 0.31 1,495.04 MWD+IFR-AK-CAZ-SC(3) 3,523.25 71.78 134.46 2,678.43 2,522.37 -1,261.04 1,091.97 5,926,351.02 461,827.70 0.91 1,578.27 MWD+I FR-AK-CAZ-SC(3) 3,617.70 71.91 133.07 2,707.86 2,551.80 -1,323.12 1,156.78 5,926,288.62 461,892.19 1.41 1,660.11 MWD+IFR-AK-CAZ-SC(3) 3,711.60 71.94 133.19 2,736.99 2,580.93 -1,384.14 1,221.93 5,926,227.26 461,957.01 0.13 1,741.10 MWD+IFR-AK-CAZ-SC(3) 3,806.53 71.82 133.43 2,766.52 2,610.46 -1,446.03 1,287.58 5,926,165.03 462,022.33 0.27 1,823.07 MWD+I F R-AK-CAZ-SC(3) 3,901.24 71.76 132.94 2,796.12 2,640.06 -1,507.60 1,353.18 5,926,103.13 462,087.60 0.50 1,904.73 MWD+I F R-AK-CAZ-SC(3) 3,995.03 72.18 132.87 2,825.15 2,669.09 -1,568.31 1,418.50 5,926,042.08 462,152.60 0.45 1,985.50 MWD+IFR-AK-CAZ-SC(3) 4,087.61 72.36 132.41 2,853.34 2,697.28 -1,628.05 1,483.37 5,925,982.02 462,217.15 0.51 2,065.18 MWD+IFR-AK-CAZ-SC(3) 4,181.64 72.22 131.15 2,881.94 2,725.88 -1,687.73 1,550.17 5,925,922.00 462,283.63 1.29 2,145.54 MWD+IF R-AK-CAZ-SC(3) 4,276.58 72.90 131.02 2,910.40 2,754.34 -1,747.25 1,618.44 5,925,862.13 462,351.58 0.73 2,226.30 MWD+IFR-AK-CAZ-SC(3) 4,371.32 72.89 131.40 2,938.26 2,782.20 -1,806.91 1,686.56 5,925,802.12 462,419.39 0.38 2,307.13 MWD+IFR-AK-CAZ-SC(3) 4,465.48 72.82 131.24 2,966.02 2,809.96 -1,866.31 1,754.13 5,925,742.37 462,486.64 0.18 2,387.53 MWD+I FR-AK-CAZ-SC(3) 4,559.48 72.86 129.68 2,993.76 2,837.70 -1,924.60 1,822.47 5,925,683.74 462,554.67 1.59 2,467.16 MWD+IFR-AK-CAZ-SC(3) 4,653.97 72.85 128.14 3,021.61 2,865.55 -1,981.30 1,892.72 5,925,626.67 462,624.62 1.56 2,546.06 MWD+IFR-AK-CAZ-SC(3) 4,749.39 72.82 128.81 3,049.77 2,893.71 -2,038.03 1,964.10 5,925,569.59 462,695.69 0.67 2,625.39 MWD+IFR-AK-CAZ-SC(3) 4,843.61 72.83 130.00 3,077.60 2,921.54 -2,095.17 2,033.65 5,925,512.09 462,764.94 1.21 2,704.43 MWD+IFR-AK-CAZ-SC(3) 4,938.38 72.70 130.47 3,105.68 2,949.62 -2,153.64 2,102.75 5,925,453.27 462,833.73 0.49 2,784.52 MWD+IFR-AK-CAZ-SC(3) 5,032.40 72.92 130.31 3,133.46 2,977.40 -2,211.84 2,171.16 5,925,394.72 462,901.83 0.28 2,864.11 MWD+IFR-AK-CAZ-SC(3) 5,126.88 72.86 130.14 3,161.26 3,005.20 -2,270.15 2,240.10 5,925,336.05 462,970.46 0.18 2,944.01 MWD+IFR-AK-CAZ-SC(3) 3/23/2015 4:48:58PM Page 3 COMPASS 5000.1 Build 65 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2L-328(Sierra) Project: Kuparuk River Unit TVD Reference: 115+41.06 @ 156.06usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: 115+41.06 @ 156.06usft(Doyon 25) Well: 2L-328(Sierra) North Reference: True Wellbore: 2L-328 Survey Calculation Method: Minimum Curvature Design: 2L-328 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 5,220.19 72.82 130.37 3,188.79 3,032.73 -2,327.76 2,308.15 5,925,278.09 463,038.20 0.24 3,022.91 MWD+IFR-AK-CAZ-SC(3) 5,314.97 72.96 130.19 3,216.68 3,060.62 -2,386.33 2,377.25 5,925,219.18 463,106.99 0.23 3,103.10 MWD+IFR-AK-CAZ-SC(3) 5,410.55 72.88 130.54 3,244.75 3,088.69 -2,445.50 2,446.87 5,925,159.65 463,176.29 0.36 3,184.04 MWD+IFR-AK-CAZ-SC(3) 5,505.59 72.92 131.29 3,272.69 3,116.63 -2,504.99 2,515.51 5,925,099.80 463,244.62 0.76 3,264.92 MWD+IFR-AK-CAZ-SC(3) 5,600.46 72.86 132.07 3,300.61 3,144.55 -2,565.29 2,583.23 5,925,039.17 463,312.02 0.79 3,346.19 MWD+IFR-AK-CAZ-SC(3) 5,695.02 72.74 132.58 3,328.57 3,172.51 -2,626.11 2,650.02 5,924,978.00 463,378.48 0.53 3,427.60 MWD+IFR-AK-CAZ-SC(3) 5,789.26 72.40 132.53 3,356.80 3,200.74 -2,686.92 2,716.25 5,924,916.86 463,444.39 0.36 3,508.79 MWD+IFR-AK-CAZ-SC(3) 5,884.25 72.34 132.62 3,385.57 3,229.51 -2,748.17 2,782.91 5,924,855.27 463,510.73 0.11 3,590.55 MWD+IFR-AK-CAZ-SC(3) 5,978.38 72.45 133.03 3,414.04 3,257.98 -2,809.15 2,848.72 5,924,793.95 463,576.21 0.43 3,671.75 MWD+IFR-AK-CAZ-SC(3) 6,072.93 72.40 133.35 3,442.59 3,286.53 -2,870.85 2,914.43 5,924,731.92 463,641.59 0.33 3,753.57 MWD+IFR-AK-CAZ-SC(3) 6,168.03 72.34 133.38 3,471.39 3,315.33 -2,933.08 2,980.32 5,924,669.35 463,707.15 0.07 3,835.95 MWD+I FR-AK-CAZ-SC(3) 6,262.17 72.38 132.97 3,499.92 3,343.86 -2,994.46 3,045.75 5,924,607.63 463,772.25 0.42 3,917.38 MWD+IFR-AK-CAZ-SC(3) 6,356.23 72.35 131.73 3,528.41 3,372.35 -3,054.85 3,112.00 5,924,546.91 463,838.18 1.26 3,998.18 MWD+IFR-AK-CAZ-SC(3) 6,450.97 72.26 130.87 3,557.21 3,401.15 -3,114.42 3,179.80 5,924,486.99 463,905.67 0.87 4,078.81 MWD+IFR-AK-CAZ-SC(3) 6,545.17 72.78 130.81 3,585.51 3,429.45 -3,173.17 3,247.78 5,924,427.89 463,973.33 0.56 4,158.76 MWD+IFR-AK-CAZ-SC(3) 6,640.94 72.90 130.82 3,613.76 3,457.70 -3,232.99 3,317.03 5,924,367.73 464,042.26 0.13 4,240.15 MWD+IFR-AK-CAZ-SC(3) 6,736.08 72.76 131.37 3,641.85 3,485.79 -3,292.73 3,385.54 5,924,307.63 464,110.45 0.57 4,321.21 MWD+I FR-AK-CAZ-SC(3) 6,831.82 72.73 131.53 3,670.25 3,514.19 -3,353.26 3,454.07 5,924,246.75 464,178.66 0.16 4,403.00 MWD+IFR-AK-CAZ-SC(3) 6,925.16 72.76 131.82 3,697.93 3,541.87 -3,412.53 3,520.65 5,924,187.15 464,244.92 0.30 4,482.90 MWD+IFR-AK-CAZ-SC(3) 7,018.96 73.06 132.32 3,725.50 3,569.44 -3,472.60 3,587.20 5,924,126.73 464,311.16 0.60 4,563.53 MWD+IFR-AK-CAZ-SC(3) 7,114.68 72.73 132.91 3,753.65 3,597.59 -3,534.54 3,654.53 5,924,064.45 464,378.15 0.68 4,646.18 MWD+IFR-AK-CAZ-SC(3) 7,209.40 72.82 132.35 3,781.70 3,625.64 -3,595.82 3,721.09 5,924,002.84 464,444.39 0.57 4,727.93 MWD+IFR-AK-CAZ-SC(3) 7,303.41 72.89 132.79 3,809.42 3,653.36 -3,656.59 3,787.25 5,923,941.73 464,510.23 0.45 4,809.06 MWD+IFR-AK-CAZ-SC(3) 7,397.98 72.89 133.13 3,837.24 3,681.18 -3,718.18 3,853.39 5,923,879.80 464,576.04 0.34 4,890.95 MWD+IFR-AK-CAZ-SC(3) 7,490.28 72.77 132.88 3,864.49 3,708.43 -3,778.33 3,917.88 5,923,819.32 464,640.21 0.29 4,970.87 MWD+IFR-AK-CAZ-SC(3) 7,587.31 72.76 132.00 3,893.24 3,737.18 -3,840.87 3,986.27 5,923,756.43 464,708.27 0.87 5,054.48 MWD+IFR-AK-CAZ-SC(3) 7,682.42 72.93 131.05 3,921.29 3,765.23 -3,901.11 4,054.31 5,923,695.84 464,775.99 0.97 5,135.82 MWD+I FR-AK-CAZ-SC(3) 7,777.47 72.91 129.92 3,949.21 3,793.15 -3,960.10 4,123.41 5,923,636.50 464,844.78 1.14 5,216.40 MWD+IF R-AK-CAZ-SC(3) 7,872.16 73.01 129.06 3,976.96 3,820.90 -4,017.68 4,193.28 5,923,578.57 464,914.34 0.87 5,295.96 MWD+IFR-AK-CAZ-SC(3) 7,966.09 73.00 130.13 4,004.41 3,848.35 -4,074.93 4,262.50 5,923,520.96 464,983.25 1.09 5,374.97 MWD+IFR-AK-CAZ-SC(3) 8,060.82 73.01 132.55 4,032.10 3,876.04 -4,134.76 4,330.51 5,923,460.78 465,050.94 2.44 5,455.92 MWD+IFR-AK-CAZ-SC(3) 8,155.84 72.59 131.54 4,060.20 3,904.14 -4,195.55 4,397.92 5,923,399.65 465,118.02 1.11 5,537.54 MWD+IFR-AK-CAZ-SC(3) 8,249.54 72.91 131.98 4,087.99 3,931.93 -4,255.15 4,464.67 5,923,339.71 465,184.46 0.56 5,617.80 MWD+IF R-AK-CAZ-SC(3) 8,345.19 72.83 131.72 4,116.16 3,960.10 -4,316.13 4,532.76 5,923,278.38 465,252.22 0.27 5,699.85 MWD+IF R-AK-CAZ-SC(3) 8,440.00 72.90 130.78 4,144.10 3,988.04 -4,375.87 4,600.87 5,923,218.29 465,320.02 0.95 5,780.76 MWD+IFR-AK-CAZ-SC(3) 8,534.12 72.87 130.77 4,171.79 4,015.73 -4,434.62 4,668.99 5,923,159.20 465,387.83 0.03 5,860.74 MWD+I FR-AK-CAZ-SC(3) 8,629.10 72.65 131.48 4,199.94 4,043.88 -4,494.28 4,737.32 5,923,099.19 465,455.84 0.75 5,941.66 MWD+I FR-AK-CAZ-SC(3) 8,724.35 72.91 131.38 4,228.14 4,072.08 -4,554.48 4,805.54 5,923,038.64 465,523.73 0.29 6,023.03 MWD+IFR-AK-CAZ-SC(3) 8,818.49 72.85 132.11 4,255.85 4,099.79 -4,614.38 4,872.66 5,922,978.39 465,590.54 0.74 6,103.71 MWD+IFR-AK-CAZ-SC(3) 8,913.07 72.94 132.62 4,283.67 4,127.61 -4,675.30 4,939.45 5,922,917.14 465,657.01 0.52 6,185.21 MWD+IFR-AK-CAZ-SC(3) 9,008.49 72.31 132.58 4,312.17 4,156.11 -4,736.94 5,006.49 5,922,855.16 465,723.71 0.66 6,267.48 MWD+IFR-AK-CAZ-SC(3) 9,103.38 72.35 132.44 4,340.97 4,184.91 -4,798.03 5,073.14 5,922,793.73 465,790.04 0.15 6,349.09 MWD+I FR-AK-CAZ-SC(3) 9,198.17 72.42 131.72 4,369.66 4,213.60 -4,858.58 5,140.19 5,922,732.84 465,856.77 0.73 6,430.34 MWD+IFR-AK-CAZ-SC(3) 9,292.33 72.34 131.89 4,398.16 4,242.10 -4,918.40 5,207.09 5,922,672.67 465,923.35 0.19 6,510.87 MWD+IFR-AK-CAZ-SC(3) 3/23/2015 4:48:58PM Page 4 COMPASS 5000.1 Build 65 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2L-328(Sierra) Project: Kuparuk River Unit TVD Reference: 115+41.06 @ 156.06usft(Doyon 25) Site: -Kuparuk 2L Pad MD Reference: 115+41.06 @ 156.06usft(Doyon 25) Well: A 2L-328(Sierra) North Reference: True Wellbore: =2L-328 Survey Calculation Method: Minimum Curvature Design: 2L-328 Database: OAKEDMP2 Survey oiieRkm Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 9,387.23 72.31 131.53 4,426.97 4,270.91 -4,978.56 5,274.59 5,922,612.17 465,990.53 0.36 6,591.94 MWD+IFR-AK-CAZ-SC(3) 9,482.07 72.35 131.16 4,455.76 4,299.70 -5,038.26 5,342.43 5,922,552.13 466,058.05 0.37 6,672.70 MWD+IFR-AK-CAZ-SC(3) 9,576.71 72.31 130.82 4,484.48 4,328.42 -5,097.40 5,410.49 5,922,492.63 466,125.80 0.34 6,753.04 MWD+IFR-AK-CAZ-SC(3) 9,671.21 72.34 130.27 4,513.18 4,357.12 -5,155.93 5,478.91 5,922,433.75 466,193.91 0.56 6,832.94 MWD+IFR-AK-CAZ-SC(3) 9,765.46 72.84 130.18 4,541.38 4,385.32 -5,214.01 5,547.58 5,922,375.33 466,262.26 0.54 6,912.51 MWD+IFR-AK-CAZ-SC(3) 9,860.41 72.90 130.28 4,569.34 4,413.28 -5,272.61 5,616.85 5,922,316.37 466,331.23 0.12 6,992.79 MWD+IFR-AK-CAZ-SC(3) 9,954.21 72.91 130.55 4,596.92 4,440.86 -5,330.74 5,685.11 5,922,257.90 466,399.18 0.28 7,072.26 MWD+IFR-AK-CAZ-SC(3) 10,049.22 72.95 131.22 4,624.81 4,468.75 -5,390.19 5,753.78 5,922,198.10 466,467.52 0.68 7,153.10 MWD+IFR-AK-CAZ-SC(3) 10,145.11 72.85 131.86 4,653.00 4,496.94 -5,450.97 5,822.38 5,922,136.97 466,535.80 0.65 7,235.15 MWD+IFR-AK-CAZ-SC(3) 10,238.26 72.89 132.06 4,680.44 4,524.38 -5,510.48 5,888.57 5,922,077.11 466,601.68 0.21 7,315.13 MWD+IFR-AK-CAZ-SC(3) 10,333.37 72.83 131.73 4,708.47 4,552.41 -5,571.17 5,956.23 5,922,016.08 466,669.01 0.34 7,396.74 MWD+IFR-AK-CAZ-SC(3) 10,429.10 72.89 131.15 4,736.68 4,580.62 -5,631.72 6,024.80 5,921,955.19 466,737.26 0.58 7,478.57 MWD+IFR-AK-CAZ-SC(3) 10,524.15 72.99 131.29 4,764.57 4,608.51 -5,691.59 6,093.15 5,921,894.96 466,805.29 0.18 7,559.69 MWD+IFR-AK-CAZ-SC(3) 10,618.22 72.85 131.48 4,792.20 4,636.14 -5,751.04 6,160.62 5,921,835.17 466,872.44 0.24 7,640.08 MWD+IFR-AK-CAZ-SC(3) 10,712.76 72.73 132.17 4,820.17 4,664.11 -5,811.26 6,227.91 5,921,774.60 466,939.42 0.71 7,721.13 MWD+IFR-AK-CAZ-SC(3) 10,807.64 72.86 132.46 4,848.23 4,692.17 -5,872.28 6,294.93 5,921,713.24 467,006.11 0.32 7,802.81 MWD+IFR-AK-CAZ-SC(3) 10,901.61 72.93 132.07 4,875.87 4,719.81 -5,932.68 6,361.40 5,921,652.50 467,072.26 0.40 7,883.71 MWD+IFR-AK-CAZ-SC(3) 10,996.10 72.79 131.08 4,903.72 4,747.66 -5,992.60 6,428.95 5,921,592.24 467,139.48 1.01 7,964.57 MWD+IFR-AK-CAZ-SC(3) 11,090.95 72.94 130.43 4,931.66 4,775.60 -6,051.77 6,497.61 5,921,532.72 467,207.83 0.67 8,045.15 MWD+IFR-AK-CAZ-SC(3) 11,186.07 72.38 130.84 4,960.01 4,803.95 -6,110.90 6,566.51 5,921,473.24 467,276.42 0.72 8,125.79 MWD+IFR-AK-CAZ-SC(3) 11,279.02 72.35 131.31 4,988.17 4,832.11 -6,169.11 6,633.29 5,921,414.69 467,342.88 0.48 8,204.77 MWD+IFR-AK-CAZ-SC(3) 11,373.25 72.29 131.08 5,016.79 4,860.73 -6,228.24 6,700.84 5,921,355.22 467,410.12 0.24 8,284.90 MWD+IFR-AK-CAZ-SC(3) 11,468.45 72.39 130.49 5,045.67 4,889.61 -6,287.49 6,769.53 5,921,295.61 467,478.49 0.60 8,365.57 MWD+IFR-AK-CAZ-SC(3) 11,563.94 72.25 130.24 5,074.67 4,918.61 -6,346.42 6,838.85 5,921,236.33 467,547.50 0.29 8,446.17 MWD+IFR-AK-CAZ-SC(3) 11,657.61 72.30 130.58 5,103.19 4,947.13 -6,404.26 6,906.78 5,921,178.15 467,615.13 0.35 8,525.25 MWD+IFR-AK-CAZ-SC(3) 11,753.29 72.29 130.96 5,132.29 4,976.23 -6,463.78 6,975.81 5,921,118.27 467,683.84 0.38 8,606.30 MWD+IFR-AK-CAZ-SC(3) 11,847.05 72.29 131.36 5,160.81 5,004.75 -6,522.56 7,043.06 5,921,059.15 467,750.77 0.41 8,685.99 MWD+IFR-AK-CAZ-SC(3) 11,940.80 72.91 131.79 5,188.84 5,032.78 -6,581.93 7,109.98 5,920,999.44 467,817.38 0.79 8,766.10 MWD+IFR-AK-CAZ-SC(3) 12,035.57 72.86 132.11 5,216.73 5,060.67 -6,642.47 7,177.34 5,920,938.55 467,884.42 0.33 8,847.48 MWD+IFR-AK-CAZ-SC(3) 12,130.90 72.91 131.91 5,244.79 5,088.73 -6,703.45 7,245.04 5,920,877.23 467,951.79 0.21 8,929.37 MWD+IFR-AK-CAZ-SC(3) 12,203.94 72.32 132.27 5,266.61 5,110.55 -6,750.17 7,296.77 5,920,830.24 468,003.27 0.93 8,992.07 MWD+IFR-AK-CAZ-SC(3) 12,266 00 72.51 131.39 5,285.36 5,129.30 -6,789.63 7,340.85 5,920,790.56 468,047.14 1.39 9,045.16 MWD+IFR-AK-CAZ-SC(4) 7-5/8"x 9-7/8" 12,295.68 72.60 130.97 5,294.26 5,138.20 -6,808.27 7,362.16 5,920,771.81 468,068.35 1.39 9,070.43 MWD+IFR-AK-CAZ-SC(4) 12,324.19 72.78 130.57 5,302.75 5,146.69 -6,826.04 7,382.77 5,920,753.93 468,088.87 1.48 9,094.63 MWD+IFR-AK-CAZ-SC(4) 12,418.67 72.68 130.44 5,330.79 5,174.73 -6,884.64 7,451.37 5,920,694.98 468,157.16 0.17 9,174.66 MWD+IFR-AK-CAZ-SC(4) 12,513.55 73.47 131.22 5,358.42 5,202.36 -6,943.99 7,520.05 5,920,635.29 468,225.52 1.15 9,255.42 MWD+IFR-AK-CAZ-SC(4) 12,610.78 76.05 132.59 5,383.97 5,227.91 -7,006.64 7,589.86 5,920,572.28 468,294.99 2.98 9,339.66 MWD+IFR-AK-CAZ-SC(4) 12,706.22 78.47 135.03 5,405.02 5,248.96 -7,071.08 7,657.02 5,920,507.49 468,361.81 3.56 9,424.56 MWD+IFR-AK-CAZ-SC(4) 12,800.42 81.09 139.20 5,421.74 5,265.68 -7,139.00 7,720.08 5,920,439.26 468,424.51 5.17 9,511.16 MWD+IFR-AK-CAZ-SC(4) 12,894.67 83.09 144.25 5,434.72 5,278.66 -7,212.26 7,777.87 5,920,365.70 468,481.92 5.72 9,600.74 MWD+IFR-AK-CAZ-SC(4) 12,989.50 84.17 148.60 5,445.24 5,289.18 -7,290.77 7,829.98 5,920,286.94 468,533.61 4.70 9,693.04 MWD+IFR-AK-CAZ-SC(4) 13,083.22 84.03 150.97 5,454.88 5,298.82 -7,371.32 7,876.89 5,920,206.15 468,580.09 2.52 9,785.30 MWD+IFR-AK-CAZ-SC(4) 13,177.46 82.98 153.31 5,465.54 5,309.48 -7,454.09 7,920.64 5,920,123.16 468,623.41 2.71 9,878.44 MWD+IFR-AK-CAZ-SC(4) 3/23/2015 4:48:58PM Page 5 COMPASS 5000.1 Build 65 • Schlumberger411 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2L-328(Sierra) Project: Kuparuk River Unit TVD Reference: 115+41.06 @ 156.06usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: 115+41.06 @ 156.06usft(Doyon 25) Well: 2L-328(Sierra) North Reference: True Wellbore: 2L-328 Survey Calculation Method: Minimum Curvature Design: 2L-328 Database: OAKEDMP2 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 13,273.88 83.22 156.72 5,477.13 5,321.07 -7,540 84 7,961.07 5,920,036.21 468,663.38 3.52 9,974.02 MWD+IFR-AK-CAZ-SC(4) 13,368.87 84.81 158.98 5,487.03 5,330.97 -7,628.34 7,996.68 5,919,948.54 468,698.54 2.90 10,068.48 MWD+IFR-AK-CAZ-SC(4) 13,463.93 87.43 158.43 5,493.47 5,337.41 -7,716.69 8,031.12 5,919,860.01 468,732.51 2.82 10,163.30 MWD+IFR-AK-CAZ-SC(4) 13,559.69 89.57 159.99 5,495.97 5,339.91 -7,806.18 8,065.09 5,919,770.36 468,766.02 2.77 10,259.00 MWD+IFR-AK-CAZ-SC(4) 13,654.17 89.52 163.45 5,496.72 5,340.66 -7,895.88 8,094.72 5,919,680.52 468,795.18 3.66 10,353.27 MWD+IFR-AK-CAZ-SC(4) 13,749.88 89.59 163.04 5,497.47 5,341.41 -7,987.52 8,122.31 5,919,588.74 468,822.29 0.43 10,448.57 MWD+IFR-AK-CAZ-SC(4) 13,845.33 89.15 162.72 5,498.52 5,342.46 -8,078.73 8,150.41 5,919,497.39 468,849.91 0.57 10,543.67 MWD+IFR-AK-CAZ-SC(4) 13,938.71 88.97 161.84 5,500.05 5,343.99 -8,167.67 8,178.83 5,919,408.32 468,877.86 0.96 10,636.78 MWD+IFR-AK-CAZ-SC(4) 14,033.86 88.12 159.30 5,502.46 5,346.40 -8,257.37 8,210.47 5,919,318.47 468,909.03 2.81 10,731.79 MWD+IFR-AK-CAZ-SC(4) 14,129.80 87.52 155.89 5,506.11 5,350.05 -8,345.99 8,247.00 5,919,229.67 468,945.10 3.61 10,827.64 MWD+IFR-AK-CAZ-SC(4) 14,224.16 88.04 155.31 5,509.77 5,353.71 -8,431.85 8,285.95 5,919,143.61 468,983.60 0.83 10,921.85 MWD+IFR-AK-CAZ-SC(4) 14,317.33 89.19 156.10 5,512.02 5,355.96 -8,516.74 8,324.27 5,919,058.53 469,021.48 1.50 11,014.92 MWD+I FR-AK-CAZ-SC(4) 14,413.39 89.36 161.66 5,513.24 5,357.18 -8,606.31 8,358.87 5,918,968.79 469,055.60 5.79 11,110.92 MWD+IFR-AK-CAZ-SC(4) 14,508.53 88.72 159.57 5,514.83 5,358.77 -8,696.04 8,390.44 5,918,878.91 469,086.70 2.30 11,205.94 MWD+IFR-AK-CAZ-SC(4) 14,603.91 88.95 157.58 5,516.77 5,360.71 -8,784.80 8,425.27 5,918,789.97 469,121.07 2.10 11,301.29 MWD+IFR-AK-CAZ-SC(4) 14,697.13 87.90 157.30 5,519.33 5,363.27 -8,870.86 8,461.02 5,918,703.74 469,156.37 1.17 11,394.47 MWD+IFR-AK-CAZ-SC(4) 14,792.22 87.84 158.25 5,522.87 5,366.81 -8,958.82 8,496.96 5,918,615.60 469,191.85 1.00 11,489.49 MWD+IFR-AK-CAZ-SC(4) 14,888.21 87.20 158.26 5,527.02 5,370.96 -9,047.90 8,532.49 5,918,526.35 469,226.91 0.67 11,585.39 MWD+IFR-AK-CAZ-SC(4) 14,983.86 88.56 159.41 5,530.56 5,374.50 -9,137.03 8,567.00 5,918,437.05 469,260.95 1.86 11,680.96 MWD+IFR-AK-CAZ-SC(4) 15,076.13 89.35 162.11 5,532.24 5,376.18 -9,224.12 8,597.40 5,918,349.81 469,290.89 3.05 11,773.10 MWD+IFR-AK-CAZ-SC(4) 15,170.52 90.01 160.97 5,532.77 5,376.71 -9,313.65 8,627.29 5,918,260.13 469,320.31 1.40 11,867.31 MWD+IFR-AK-CAZ-SC(4) 15,266.64 89.55 161.09 5,533.14 5,377.08 -9,404.55 8,658.53 5,918,169.08 469,351.08 0.49 11,963.29 MWD+IFR-AK-CAZ-SC(4) 15,360.38 89.75 157.65 5,533.71 5,377.65 -9,492.27 8,691.55 5,918,081.20 469,383.64 3.68 12,056.99 MWD+IFR-AK-CAZ-SC(4) 15,455.27 90.78 151.60 5,533.27 5,377.21 -9,577.96 8,732.20 5,917,995.31 469,423.84 6.47 12,151.67 MWD+IFR-AK-CAZ-SC(4) 15,551.98 90.38 153.33 5,532.29 5,376.23 -9,663.71 8,776.90 5,917,909.34 469,468.09 1.84 12,247.92 MWD+IFR-AK-CAZ-SC(4) 15,646.36 89.92 153.14 5,532.05 5,375.99 -9,747.97 8,819.40 5,917,824.86 469,510.15 0.53 12,341.97 MWD+IFR-AK-CAZ-SC(4) 15,740.03 89.93 154.61 5,532.17 5,376.11 -9,832.07 8,860.65 5,917,740.56 469,550.95 1.57 12,435.40 MWD+IFR-AK-CAZ-SC(4) 15,834.24 90.11 153.29 5,532.14 5,376.08 -9,916.71 8,902.02 5,917,655.71 469,591.88 1.41 12,529.37 MWD+IFR-AK-CAZ-SC(4) 15,931.13 90.35 154.96 5,531.75 5,375.69 -10,003.88 8,944.30 5,917,568.33 469,633.70 1.74 12,626.03 MWD+I FR-AK-CAZ-SC(4) 16,025.44 90.65 154.64 5,530.92 5,374.86 -10,089.21 8,984.46 5,917,482.80 469,673.41 0.47 12,720.19 MWD+IFR-AK-CAZ-SC(4) 16,104.26 90.30 154.97 5,530.27 5,374.21 -10,160.53 9,018.01 5,917,411.32 469,706.59 0.61 12,798.89 MWD+I FR-AK-CAZ-SC(4) 16,168.00 90.30 154.97 5,529.94 5,373.88 -10,218.28 9,044.98 5,917,353.43 469,733.25 0.00 12,862.54 PROJECTED to TD Projection to TD 3/23/2015 4:48:58PM Page 6 COMPASS 5000.1 Build 65 • Cement Detail Report 2L-328 ConocoPhillips String: Conductor Cement Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Conductor Cement 4/16/2000 20.30 4/16/2000 21:30 2L-328 Comment Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Conductor Cement Cement conductor 44.0 114.0 No No No 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) No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) High Early 44.0 114.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 4/22/2015 • Cement Detail Report 4=2 k2rip -Polikp,opri:. 2L-328 ConoaoPhi[lilps String: Surface Casing Cement Job: DRILLING ORIGINAL, 2/15/2015 12:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 2/22/2015 06.00 2/22/2015 10.00 2L-328 Comment Pump surface cement job per program, SLB pump 5 bbl water,test lines to 3500 psi-good.SLB pumped 99.5 bbl 10.5 ppg MudPush II©5 bpm, 120 psi 20% flow.Shut down, break out Volant tool and drop bottom plug,follow with 380.4 bbl 11.0 ppg lead cement(Yield 1.91 cuft/sx, mix water 6.816 gal/sx,thickening time 4 hr 33 min)pumping 6.5 bpm,230 psi 23%flow,62.7 bbl 12.0 ppg Tail cement(yield 1.66 cuft/sx, mix water 5.818 gal/sx,thickening time 3 hr 21 min) pumping 6 bpm, 366 psi 17%flow P/U=149k, S/O=74k.Taking weight and unable to land hanger. Break out Volant and drop top plug, M/U and kick out plug with 10 bbl water. Swap to rig pumps, attempt to catch cement @ 6 bpm,405 psi,0%returns while attempting to seat on landing ring(unseccessful). Divert returns to cellar, reduce rate to 3 bpm. ICP=269 psi, FCP=536 psi. Bump plug @ 2193 stks(220.8 bbl)pressure to 1039 psi. Bleed off and check floats-good. 79.9 bbl cement to surface,41 bbl lost during cement job. ----. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Surface Casing Cement Cement surface casing 41.0 2,517.0 No 79.9 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) 7 6 6 460.0 1,053.0 Yes 25.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 9 7/8 Comment Pump surface cement job per program, SLB pump 5 bbl water,test lines to 3500 psi-good.SLB pumped 99.5 bbl 10.5 ppg MudPush II @ 5 bpm, 120 psi 20% flow. Shut down, break out Volant tool and drop bottom plug,follow with 375 bbl 11.0 ppg lead cement(yield 1.91 cuft/sx, mix water 6.816 gal/sx,thickening time 4 hr 33 min) pumping 6.5 bpm,230 psi 23%flow,59 bbl 12.0 ppg Tail cement(yield 1.66 cufUsx, mix water 5.818 gal/sx,thickening time 3 hr 21 min)pumping 6 bpm, 366 psi 17%flow P/U=149k, S/0=74k.Taking weight and unable to land hanger. Break out Volant and drop top plug, M/U and kick out plug with 10 bbl water.Swap to rig pumps,attempt to catch cement @ 6 bpm,405 psi,0%returns while attempting to seat on landing ring(unseccessful). Divert returns to cellar, reduce rate to 3 bpm. ICP=269 psi, FCP=536 psi. Bump plug @ 2193 stks(220.8 bbl)pressure to 1039 psi. Bleed off and check floats-good.79.9 bbl cement to surface,41 bbl lost during cement job. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 41.0 2,017.0 1,118 G 380.4 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.91 6.82 11.00 114.0 4.55 Additives Additive Type Concentration Conc Unit label D046 Antifoam 0.2 %BWOC Additive Type Concentration Conc Unit label D185 Dispers. LT 0.07 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 2,017.0 2,517.0 212 G 62.7 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(!b/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.66 5.82 12.00 164.0 3.35 Additives Additive Type Concentration Conc Unit label D046 Antifoam 0.2 %BWOC Additive Type Concentration Conc Unit label D185 Disper. LT 0.06 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) MudPush 99.5 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 10.50 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 4/22/2015 0 • 0.: Cement Detail Report 2L-328 Phillips String: Intermediate casing cement Job: DRILLING ORIGINAL, 2/15/2015 12:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate casing cement 3/9/2015 17:50 3/9/2015 21:30 2L-328 Comment Cement job performed with no returns. Pressure test lines to 3000 psi. SLB pump 40 BBLS CW100,and 40 BBLs MudPush II 11.5 ppg, Dis-engage CRT and drop 1st plug at 18:00. Pump 204 BBLs 15.8 ppg/.17 ft3/gal yield GASBLOK cement at 8 BPM with ICP=360 and chase cement to 260 BBL away;8 BPM FCP=740 psi. Pump at 5 BPM with ICP=575 psi,continue to chase cement, FCP at 5 BPM=1148 psi. Continue to pump at 5 BPM until bumping plug at 5480 strokes, pump to achieve 500 psi over FCP and hold 1660 psi for 5 minutes. Bleed pressure and check floats;Good. CIP at 20:25. Complete cement job without returns. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate casing Cement shoe and cover 11,611.0 12,276.0 No 0.0 Yes Yes cement to 8843'MD. 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 5 1,148.0 1,148.0 Yes 15.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement job performed with no returns. Pressure test lines to 3000 psi. SLB pump 40 BBLS CW100,and 40 BBLs MudPush II 11.5 ppg, Dis-engage CRT and drop 1st plug at 18:00. Pump 204 BBLs 15.8 ppg/.17 ft3/gal yield GASBLOK cement at 8 BPM with ICP=360 and chase cement to 260 BBL away;8 BPM FCP=740 psi. Pump at 5 BPM with ICP=575 psi,continue to chase cement, FCP at 5 BPM=1148 psi. Continue to pump at 5 BPM until bumping plug at 5480 strokes, pump to achieve 500 psi over FCP and hold 1660 psi for 5 minutes. Bleed pressure and check floats;Good. CIP at 20:25. Complete cement job without returns. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 8,843.0 12,276.0 984 G 204.0 Yield(ft5sack) Mix H2O Ratio(gallsa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.17 5.25 15.80 11.00 Additives Additive Type Concentration Conc Unit label Antifoam D047 gal/sx Additive Type Concentration Conc Unit label Dispersant D065 %BWOC Additive Type Concentration Conc Unit label Gas Block D600G gal/sx Page 1/1 Report Printed: 4/22/2015 • • 1 rP z/ 1-i57 Loepp, Victoria T (DOA) From: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Tuesday, May 05, 2015 12:04 PM To: Loepp,Victoria T(DOA) Subject: RE: KRU 2L-328(PTD 214-189) Frac Sundry Number 315-220 Attachments: ConocoPhillips Alaska - 2L-328 - Prejob Disclosure Report vl.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria,the treating pressures should be around the same, if not slightly less since we are switching to a delayed xl. I have attached the new CAS. From: Loepp, Victoria T(DOA) [mailto:victoria.loeppOalaska.gov] Sent: Thursday, April 30, 2015 1:29 PM To: Klem, Adam Subject: [EXTERNAL]RE: KRU 2L-328(PTD 214-189) Frac Sundry Number 315-220 Adam, Please email changes to the procedure including the CAS if it has changed. Has the treating pressure changed? It won't be necessary to resubmit the sundry. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(ala laska.qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.LoeoQ@alaska.gov From: Klem, Adam [mailto:Adam.Klem@conocophillips.com] Sent: Thursday, April 30, 2015 10:07 AM To: Foerster, Catherine P (DOA) Subject: KRU 2L-328 Frac Sundry Number 315-220 Hello, We have decided to change around our design a bit on the fracture treatment.The designed height,width,xf of the fracture design should all stay very close to what was submitted, but we plan to change the fluid system as well as proppant amounts. Do I need to resubmit the sundry? Thanks, 1 Adam Klem • Senior Completions Engineer Greater Kuparuk Area ConocoPhillips Alaska 700 G St ATO 1410 Anchorage,AK 99510 907-263-4529 Office 970-317-0300 Cell Adam.Klem@conocophillips.com 2 r • • Client: ConocoPhillips Alaska Inc. Schlumberger Well: 2L-328 Basin/Field: Colville-Prudhoe Basin/ Tarn State: Alaska County/Parish: North Slope Borough Case: Disclosure Type: Pre-Job Well Completed: 5/15/2015 Date Prepared: 5/4/2015 10:12 AM Report ID: RPT-36644 Fluid Name&Volume Additive Additive Description Concentration 1blun B882 Guar Polymer Slurry 6.3 Gal/1000 Gal 2,745.0 Gal _ F103 Surfactant 1 Gal/1000 Gal 440.0 Gal J218 Breaker 0.1 Lb/1000 Gal 25.0 Lb _ J475 Breaker 9.9 Lb/1000 Gal 4,310.0 Lb YF1275T,WF127 437,010 Gal J511 Stabilizing Agent 4.9 Lb/1000 Gal 2,150.0 Lb J604 Crosslinker 2.4 Gal/1000 Gal 1,070.0 Gal 1.065 Scale Inhibitor 2 Gal/1000 Gal 880.0 Gal M002 Additive 2.7 Lb/1000 Gal 1,200.0 Lb M275 Bactericide 0.3 Lb/1000 Gal 125.0 Lb S522-1620 Propping Agent varied concentrations 1,045,000.0 Lb The total volume listed in the tables above represents the summation of water and additives.Water Is supplied by client. CAS Number Chemical Name Mass Fraction - Water(Including Mix Water Supplied by Client)* ^.77% 66402-68-4 Ceramic materials and wares,chemicals ^'22% _ 64742-47-8 Distillates(petroleum),hydrotreated light <1% 9000-30-0 Guar gum <1 % 107-21-1 _ Ethylene Glycol <1% 7727-54-0 -_ Dia mm onium peroxidisulphate <0.1% 50-70-4 Sorbitol <0.1 % 129898-01-7 2-Propenoic add,polymer with sodium phosphinate <0.1 % 1310-73-2 - Sodium hydroxide(impurity) <0.1 % 25038-72-6 Vinylidene chloride/methylacrylate copolymer <0.1 % 111-76-2 2-butoxyethano) <0.1 % 67-63-0 _ Prn-2-ol <0.1 % 11138-66-2 Gum,xanthan <0.1 % 1330-43-4 Sodium tetraborate <0.01% 7647-14-5 Sodium chloride <0.01 % 34.398-01-1(3E0) Linear C11 alcohol ethoxylate(3eo) <0.01 % 68131-39-5 C12-15 alcohol ethyoxylated <0.01 % 34398-01-1(7E0) Linear C11 alcohol ethoxylate(leo) <0.01% 68953-58-2 Dihydrogenated tallow dimethyl ammonium bentonite <0.01 % 7631-86-9 Silicon Dioxide <0.01 % 10043-52-4 Calcium Chloride <0.01% 108-32-7 _ 4-methyl-1,3-dioxolan-2-one <0.01% 91053-39-3 Diatomaceous earth,calcined <0.01% 14807-96-6 Magnesium silicate hydrate(talc) <0.001 % 11146-6 _ 2,2°-oxydiethanol(impurity) <0.001 % 68153-30-0 Amine treated smectite clay <0.001 % 10377-60-3 Magnesium nitrate _ <0.001 % _ 9002-84-0 poly(tetrafluoroethylene) <0.001 % _ 26172-55-4 5-chloro-2-methyl-2h-isothiazolol-3-one _ <0.001 % _ 7786-30-3 Magnesium chloride <0.001 % _ 7447-40-7 Potassium chloride(impurity) <0.001 % _ 2682-20-4 2-methyl-2h-isothiazol-3-one <0.0001 % 14808-60-7 Crystalline silica(impurity) <0=1 % 14464-46-1 Cristobalite <0.0001 % *Mix water Is supplied by the client.Schlumberger has performed no analysis of the water and cannot provide a breakdown of components that may have been added to the water by third-parties. 0 Schlumberger 2015.Used by ConocoPhillips Alaska Inc.by permission. Page:1/1 • • 25-110 WELL LOG TRANSMITTAL : s To: Alaska Oil and Gas Conservation Comm. April 21, 2015 Attn.: Makana Bender MAY 0 I 2/_1315 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 AOGCCZa1S M.K.BENDER RE: CASTM-CBL&Advanced Cement Eval. (ACE): 2L-328 Run Date: 4/4/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2L-328 Data in LAS or DLIS format, Digital Log Image files 1 CD Rom 50-103-20698-00 ACE Log 1 Color Log 50-103-20698-00 CAST-M Field print 1 Color Log 50-103-20698-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: ,fAi r % ' ./ 21 4189 25774 REutivEi ConocoPhillips MAY 0 1 2015 AO DEA LOGGED fu� TRANSMITTAL Gco M.K.BE2o, ND R CONFIDENTIAL DATA FROM; Sandra D. Lemke,ATO3-0340 TO; Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W.7t1'Ave., Suite 100 Anchorage AK 99510-0360 Anchorage,Alaska 99501 RE: 2L-328 DATE: 04/30/2015 Transmitted: Kuparuk River Unit, Alaska 3 2L-328 11 hardcopy report with digital data on CD j Halliburton Surface logging data/End of well report; table of contents: General information, daily summary, days vs. tl !depth, after action review, mud record, bit record, morning reports, survey report. Formation Evaluation log -2"MD Gas ratio -2"MD 11 Engineering Log-2"MD 11 11 OCD contains digital data of Final Log files/Final End of Well report/Final LAS exports/Halliburton Log Viewer/EMF Log 1Viewer Please promptly sign, scan and return electronically to Sano'ra.D.Lemke000P.com CC: 2L-328 transmittal folder, production well files, eSearch Receipt; Altaget-'fruLd AA, 4ite. GIS-Technical Data Management I ConocoPhitlips I Anchorage, Alaska I Ph: 907.265.6947 21 41 89 RE!EIVED • 2 5 6 6 1 APR 0 9 2015 Schlumberger AOGC _ Transmittal#: 09APR15 SP01 Idling & Measurements DATA LOGGED MWD/LWD Log Product Delivery 5 ri/2015 M.K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2L-328 Date Dispatched: 9-Apr-15 Job#: 15AKA0042 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 1 Contents on CD N/A PTS Answer Products Top of Cement x x LAS Digital Data N/A Contents on CD N/A x Directional Data N/A Contents on CD N/A As-Built Survey N/A Contents on CD N/A CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pds/pdf x Please sign and email a copy to: Please sign and email a copy to: Catherine.Roso(c�conocophillips.com AlaskaPTSPrintCenter(c�slb.com Catherine Roso Attn:Stephanie Pacillo 907-265-6189 ATO 1707 Received By: hl, va& V - / ' 1/, 21 4189 • RELIVED • 2 5 6 3 7 APR 082015 ScblumbergerAOGCO Drilling & Measurements Transmittai#: 08APR15SP02 DATA LOGGED MWD/LWD Log Product Delivery 5/y/2015 M. K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2L-328 Date Dispatched: 8-Apr-15 Job#: 15AKA0042 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 4 Contents on CD N/A VISION*Service 2" MD x x VISION*Service 2'TVD x x VISION*Service 5'MD x x VISION*Service 5'TVD x x LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 x x As-Built Survey 1 Contents on CD N/A Nad83 x x CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf/tiff x Surveys:pdf/txt x Please sign and email a copy to: Please sign and email a copy to: Catherine.Roso(a�conocophillips.com AlaskaPTSPrintCenter(c�slb.com Catherine Roso Attn:Stephanie Pacillo 907-265-6189 ATO 1707 Received By: 14 .' 4 _- ./✓ • • 2141 $ 9 25637 RECEIVED APR 08 2015 AOGCC FINAL NADConversion Kuparuk River Unit Kuparuk 2L Pad 2L-328 Definitive Survey Report NAD 27 23 March, 2015 • • - Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2L-328(Sierra) Project: Kuparuk River Unit TVD Reference: 115+41.06 @ 156.06usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: 115+41.06 @ 156.06usft(Doyon 25) Well: 2L-328(Sierra) North Reference: True Wellbore: 2L-328 Survey Calculation Method: Minimum Curvature Design: 2L-328 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 2L-328(Sierra) Well Position +N/-S 0.00 usft Northing: 5,927,617.60 usfi Latitude: 70°12'47.492 N +El-W 0.00 usft Easting: 460,742.41 usfi Longitude: 150°18'59.777 W Position Uncertainty 0.00 usft Wellhead Elevation: usfi Ground Level: 115.00 usft Wellbore 2L-328 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2014 2/10/2015 18.73 80.78 57,545 Design 2L-328 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 41.06 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 41.06 0.00 0.00 158.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 80.38 1,297.77 2L-328 Srvy#1 -GYD-GC-SS(2L-328) GYD-GC-SS Gyrodata gyro single shots 3/19/2015 4:2 1,356.90 2,437.12 2L-328 Srvy#2-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/19/2015 4:3 2,513.32 12,203.94 2L-328 Srvy#3-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/23/2015 11:2 12,295.68 16,104.26 2L-328 Srvy#4-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/23/2015 11:2 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 41.06 0.00 0.00 41.06 -115.00 0.00 0.00 5,927,617.60 460,742.41 0.00 0.00 UNDEFINED 80.38 0.41 259.05 80.38 -75.68 -0.03 -0.14 5,927,617.57 460,742.27 1.04 -0.03 GYD-GC-SS(1) 167.67 0.40 250.76 167.67 11.61 -0.19 -0.73 5,927,617.41 460,741.68 0.07 -0.10 GYD-GC-SS(1) 262.37 0.29 252.97 262.37 106.31 -0.37 -1.27 5,927,617.24 460,741.14 0.12 -0.14 GYD-GC-SS(1) 354.83 0.68 172.26 354.82 198.76 -0.98 -1.42 5,927,616.63 460,740.98 0.75 0.37 GYD-GC-SS(1) 446.99 1.70 158.60 446.96 290.90 -2.79 -0.85 5,927,614.81 460,741.55 1.14 2.27 GYD-GC-SS(1) 540.16 3.05 150.79 540.05 383.99 -6.24 0.86 5,927,611.35 460,743.24 1.49 6.11 GYD-GC-SS(1) 636.45 4.21 151.06 636.15 480.09 -11.57 3.82 5,927,606.01 460,746.17 1.20 12.16 GYD-GC-SS(1) 729.37 5.53 153.91 728.73 572.67 -18.58 7.44 5,927,598.98 460,749.76 1.44 20.01 GYD-GC-SS(1) 824.16 9.13 162.80 822.73 666.67 -29.87 11.68 5,927,587.67 460,753.93 3.97 32.07 GYD-GC-SS(1) 918.30 10.26 160.17 915.53 759.47 -44.89 16.73 5,927,572.62 460,758.91 1.29 47.89 GYD-GC-SS(1) 1,012.84 11.09 158.53 1,008.43 852.37 -61.27 22.91 5,927,556.21 460,765.00 0.93 65.39 GYD-GC-SS(1) 1,107.44 12.13 158.42 1,101.09 945.03 -78.98 29.90 5,927,538.47 460,771.90 1.10 84.43 GYD-GC-SS(1) 1,202.21 13.85 155.99 1,193.43 1,037.37 -98.60 38.18 5,927,518.80 460,780.07 1.90 105.73 GYD-GC-SS(1) 1,297.77 15.31 156.91 1,285.91 1,129.85 -120.66 47.78 5,927,496.70 460,789.56 1.55 129.77 GYD-GC-SS(1) 3/23/2015 4:48:58PM Page 2 COMPASS 5000.1 Build 65 • S . Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2L-328(Sierra) Project: Kuparuk River Unit TVD Reference: 115+41.06 @ 156.06usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: 115+41.06 @ 156.06usft(Doyon 25) Well: 2L-328(Sierra) North Reference: True Wellbore: 2L-328 Survey Calculation Method: Minimum Curvature Design: 2L-328 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 1,356.90 16.08 158.82 1,342.84 1,186.78 -135.48 53.80 5,927,481 86 460,795.50 1.57 145.77 MWD+IFR-AK-CAZ-SC(2) 1,450.82 16.24 157.98 1,433.05 1,276.99 -159.78 63.42 5,927,457.51 460,805.00 0.30 171.90 MWD+IFR-AK-CAZ-SC(2) 1,545.80 19.79 152.95 1,523.36 1,367.30 -186.42 75.72 5,927,430.80 460,817.15 4.08 201.21 MWD+I FR-AK-CAZ-SC(2) 1,640.91 21.82 150.66 1,612.27 1,456.21 -216.17 91.71 5,927,400.97 460,832.98 2.30 234.79 MWD+IFR-AK-CAZ-SC(2) 1,735.85 24.17 147.83 1,699.66 1,543.60 -248.01 110.70 5,927,369.04 460,851.81 2.73 271.42 MWD+IFR-AK-CAZ-SC(2) 1,831.33 27.05 145.86 1,785.75 1,629.69 -282.54 133.30 5,927,334.40 460,874.23 3.15 311.90 MWD+IFR-AK-CAZ-SC(2) 1,924.59 31.69 143.07 1,867.01 1,710.95 -319.69 159.93 5,927,297.11 460,900.67 5.19 356.32 MWD+IFR-AK-CAZ-SC(2) 2,020.63 35.31 142.38 1,947.08 1,791.02 -361.85 192.04 5,927,254.79 460,932.55 3.79 407.45 MWD+IFR-AK-CAZ-SC(2) 2,114.81 39.29 141.13 2,021.99 1,865.93 -406.65 227.39 5,927,209.81 460,967.66 4.30 462.22 MWD+IFR-AK-CAZ-SC(2) 2,209.11 43.59 141.30 2,092.66 1,936.60 -455.29 266.47 5,927,160.97 461,006.48 4.56 521.96 MWD+IFR-AK-CAZ-SC(2) 2,304.24 48.14 139.09 2,158.89 2,002.83 -507.69 310.20 5,927,108.35 461,049.94 5.06 586.92 MWD+IFR-AK-CAZ-SC(2) 2,398.22 51.71 137.70 2,219.39 2,063.33 -561.43 357.96 5,927,054.37 461,097.41 3.96 654.64 MWD+IFR-AK-CAZ-SC(2) 2,437.12 51.70 138.26 2,243.49 2,087.43 -584.11 378.39 5,927,031.58 461,117.73 1.13 683.33 MWD+I FR-AK-CAZ-SC(2) 2,464.00 51.54 137.72 2,260.18 2,104.12 -599.77 392.50 5,927,015.85 461,131.75 1.70 703.13 MWD+IFR-AK-CAZ-SC(3) 10 3/4"x 13-1/2 2,513.32 51.24 136.71 2,290.96 2,134.90 -628.05 418.67 5,926,987.44 461,157.77 1.70 739.16 MWD+IFR-AK-CAZ-SC(3) 2,572.84 52.98 136.06 2,327.51 2,171.45 -662.06 451.08 5,926,953.27 461,189.99 3.05 782.82 MWD+IFR-AK-CAZ-SC(3) 2,668.20 57.14 133.57 2,382.12 2,226.06 -717.10 506.54 5,926,897.94 461,245.17 4.86 854.64 MWD+I FR-AK-CAZ-SC(3) 2,763.02 62.40 132.76 2,429.85 2,273.79 -773.12 566.28 5,926,841.62 461,304.61 5.60 928.95 MWD+IFR-AK-CAZ-SC(3) 2,857.80 67.43 131.46 2,470.02 2,313.96 -830.64 629.96 5,926,783.77 461,367.98 5.45 1,006.14 MWD+IFR-AK-CAZ-SC(3) 2,951.94 71.76 130.37 2,502.83 2,346.77 -888.41 696.62 5,926,725.67 461,434.34 4.73 1,084.67 MWD+IFR-AK-CAZ-SC(3) 3,047.05 73.63 130.38 2,531.12 2,375.06 -947.22 765.80 5,926,666.50 461,503.20 1.97 1,165.12 MWD+IFR-AK-CAZ-SC(3) 3,143.57 72.37 131.80 2,559.34 2,403.28 -1,007.88 835.36 5,926,605.48 461,572.44 1.92 1,247.43 MWD+IFR-AK-CAZ-SC(3) 3,238.51 71.68 134.40 2,588.65 2,432.59 -1,069.58 901.30 5,926,543.45 461,638.05 2.70 1,329.33 MWD+IFR-AK-CAZ-SC(3) 3,333.89 71.63 135.60 2,618.67 2,462.61 -1,133.59 965.31 5,926,479.11 461,701.72 1.20 1,412.66 MWD+IFR-AK-CAZ-SC(3) 3,427.90 71.50 135.33 2,648.40 2,492.34 -1,197.17 1,027.86 5,926,415.22 461,763.93 0.31 1,495.04 MWD+IFR-AK-CAZ-SC(3) 3,523.25 71.78 134.46 2,678.43 2,522.37 -1,261.04 1,091.97 5,926,351.02 461,827.70 0.91 1,578.27 MWD+IFR-AK-CAZ-SC(3) 3,617.70 71.91 133.07 2,707.86 2,551.80 -1,323.12 1,156.78 5,926,288.62 461,892.19 1.41 1,660.11 MWD+I F R-AK-CAZ-SC(3) 3,711.60 71.94 133.19 2,736.99 2,580.93 -1,384.14 1,221.93 5,926,227.26 461,957.01 0.13 1,741.10 MWD+IFR-AK-CAZ-SC(3) 3,806.53 71.82 133.43 2,766.52 2,610.46 -1,446.03 1,287.58 5,926,165.03 462,022.33 0.27 1,823.07 MWD+IFR-AK-CAZ-SC(3) 3,901.24 71.76 132.94 2,796.12 2,640.06 -1,507.60 1,353.18 5,926,103.13 462,087.60 0.50 1,904.73 MWD+IFR-AK-CAZ-SC(3) 3,995.03 72.18 132.87 2,825.15 2,669.09 -1,568.31 1,418.50 5,926,042.08 462,152.60 0.45 1,985.50 MWD+IFR-AK-CAZ-SC(3) 4,087.61 72.36 132.41 2,853.34 2,697.28 -1,628.05 1,483.37 5,925,982.02 462,217.15 0.51 2,065.18 MWD+IFR-AK-CAZ-SC(3) 4,181.64 72.22 131.15 2,881.94 2,725.88 -1,687.73 1,550.17 5,925,922.00 462,283.63 1.29 2,145.54 MWD+IFR-AK-CAZ-SC(3) 4,276.58 72.90 131.02 2,910.40 2,754.34 -1,747.25 1,618.44 5,925,862.13 462,351.58 0.73 2,226.30 MWD+IFR-AK-CAZ-SC(3) 4,371.32 72.89 131.40 2,938.26 2,782.20 -1,806.91 1,686.56 5,925,802.12 462,419.39 0.38 2,307.13 MWD+IFR-AK-CAZ-SC(3) 4,465.48 72.82 131.24 2,966.02 2,809.96 -1,866.31 1,754.13 5,925,742.37 462,486.64 0.18 2,387.53 MWD+IFR-AK-CAZ-SC(3) 4,559.48 72.86 129.68 2,993.76 2,837.70 -1,924.60 1,822.47 5,925,683.74 462,554.67 1.59 2,467.16 MWD+IFR-AK-CAZ-SC(3) 4,653.97 72.85 128.14 3,021.61 2,865.55 -1,981.30 1,892.72 5,925,626.67 462,624.62 1.56 2,546.06 MWD+IFR-AK-CAZ-SC(3) 4,749.39 72.82 128.81 3,049.77 2,893.71 -2,038.03 1,964.10 5,925,569.59 462,695.69 0.67 2,625.39 MWD+IFR-AK-CAZ-SC(3) 4,843.61 72.83 130.00 3,077.60 2,921.54 -2,095.17 2,033.65 5,925,512.09 462,764.94 1.21 2,704.43 MWD+IFR-AK-CAZ-SC(3) 4,938.38 72.70 130.47 3,105.68 2,949.62 -2,153.64 2,102.75 5,925,453.27 462,833.73 0.49 2,784.52 MWD+I F R-AK-CAZ-SC(3) 5,032.40 72.92 130.31 3,133.46 2,977.40 -2,211.84 2,171.16 5,925,394.72 462,901.83 0.28 2,864.11 MWD+IFR-AK-CAZ-SC(3) 5,126.88 72.86 130.14 3,161.26 3,005.20 -2,270.15 2,240.10 5,925,336.05 462,970.46 0.18 2,944.01 MWD+IFR-AK-CAZ-SC(3) 3/23/2015 4:48:58PM Page 3 COMPASS 5000.1 Build 65 • S Schlurnberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2L-328(Sierra) Project: Kuparuk River Unit TVD Reference: 115+41.06 @ 156.06usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: 115+41.06 @ 156.06usft(Doyon 25) Well: 2L-328(Sierra) North Reference: True Wellbore: 2L-328 Survey Calculation Method: Minimum Curvature Design: 2L-328 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 5,220.19 72.82 130.37 3,188.79 3,032.73 -2,327.76 2,308.15 5,925,278.09 463,038.20 0.24 3,022.91 MWD+IFR-AK-CAZ-SC(3) 5,314.97 72.96 130.19 3,216.68 3,060.62 -2,386.33 2,377.25 5,925,219.18 463,106.99 0.23 3,103.10 MWD+IFR-AK-CAZ-SC(3) 5,410.55 72.88 130.54 3,244.75 3,088.69 -2,445.50 2,446.87 5,925,159.65 463,176.29 0.36 3,184.04 MWD+IFR-AK-CAZ-SC(3) 5,505.59 72.92 131.29 3,272.69 3,116.63 -2,504.99 2,515.51 5,925,099.80 463,244.62 0.76 3,264.92 MWD+IFR-AK-CAZ-SC(3) 5,600.46 72.86 132.07 3,300.61 3,144.55 -2,565.29 2,583.23 5,925,039.17 463,312.02 0.79 3,346.19 MWD+IFR-AK-CAZ-SC(3) 5,695.02 72.74 132.58 3,328.57 3,172.51 -2,626.11 2,650.02 5,924,978.00 463,378.48 0.53 3,427.60 MWD+IFR-AK-CAZ-SC(3) 5,789.26 72.40 132.53 3,356.80 3,200.74 -2,686.92 2,716.25 5,924,916.86 463,444.39 0.36 3,508.79 MWD+IFR-AK-CAZ-SC(3) 5,884.25 72.34 132.62 3,385.57 3,229.51 -2,748.17 2,782.91 5,924,855.27 463,510.73 0.11 3,590.55 MWD+IFR-AK-CAZ-SC(3) 5,978.38 72.45 133.03 3,414.04 3,257.98 -2,809.15 2,848.72 5,924,793.95 463,576.21 0.43 3,671.75 MWD+IFR-AK-CAZ-SC(3) 6,072.93 72.40 133.35 3,442.59 3,286.53 -2,870.85 2,914.43 5,924,731.92 463,641.59 0.33 3,753.57 MWD+IFR-AK-CAZ-SC(3) 6,168.03 72.34 133.38 3,471.39 3,315.33 -2,933.08 2,980.32 5,924,669.35 463,707.15 0.07 3,835.95 MWD+IFR-AK-CAZ-SC(3) 6,262.17 72.38 132.97 3,499.92 3,343.86 -2,994.46 3,045.75 5,924,607.63 463,772.25 0.42 3,917.38 MWD+IFR-AK-CAZ-SC(3) 6,356.23 72.35 131.73 3,528.41 3,372.35 -3,054.85 3,112.00 5,924,546.91 463,838.18 1.26 3,998.18 MWD+I FR-AK-CAZ-SC(3) 6,450.97 72.26 130.87 3,557.21 3,401.15 -3,114.42 3,179.80 5,924,486.99 463,905.67 0.87 4,078.81 MWD+IFR-AK-CAZ-SC(3) 6,545.17 72.78 130.81 3,585.51 3,429.45 -3,173.17 3,247.78 5,924,427.89 463,973.33 0.56 4,158.76 MWD+IFR-AK-CAZ-SC(3) 6,640.94 72.90 130.82 3,613.76 3,457.70 -3,232.99 3,317.03 5,924,367.73 464,042.26 0.13 4,240.15 MWD+IFR-AK-CAZ-SC(3) 6,736.08 72.76 131.37 3,641.85 3,485.79 -3,292.73 3,385.54 5,924,307.63 464,110.45 0.57 4,321.21 MWD+I F R-AK-CAZ-SC(3) 6,831.82 72.73 131.53 3,670.25 3,514.19 -3,353.26 3,454.07 5,924,246.75 464,178.66 0.16 4,403.00 MWD+IF R-AK-CAZ-SC(3) 6,925.16 72.76 131.82 3,697.93 3,541.87 -3,412.53 3,520.65 5,924,187.15 464,244.92 0.30 4,482.90 MWD+IFR-AK-CAZ-SC(3) 7,018.96 73.06 132.32 3,725.50 3,569.44 -3,472.60 3,587.20 5,924,126.73 464,311.16 0.60 4,563.53 MWD+IFR-AK-CAZ-SC(3) 7,114.68 72.73 132.91 3,753.65 3,597.59 -3,534.54 3,654.53 5,924,064.45 464,378.15 0.68 4,646.18 MWD+I FR-AK-CAZ-SC(3) 7,209.40 72.82 132.35 3,781.70 3,625.64 -3,595.82 3,721.09 5,924,002.84 464,444.39 0.57 4,727.93 MWD+IFR-AK-CAZ-SC(3) 7,303.41 72.89 132.79 3,809.42 3,653.36 -3,656.59 3,787.25 5,923,941.73 464,510.23 0.45 4,809.06 MWD+IF R-AK-CAZ-SC(3) 7,397.98 72.89 133.13 3,837.24 3,681.18 -3,718.18 3,853.39 5,923,879.80 464,576.04 0.34 4,890.95 MWD+IFR-AK-CAZ-SC(3) 7,490.28 72.77 132.88 3,864.49 3,708.43 -3,778.33 3,917.88 5,923,819.32 464,640.21 0.29 4,970.87 MWD+IFR-AK-CAZ-SC(3) 7,587.31 72.76 132.00 3,893.24 3,737.18 -3,840.87 3,986.27 5,923,756.43 464,708.27 0.87 5,054.48 MWD+IFR-AK-CAZ-SC(3) 7,682.42 72.93 131.05 3,921.29 3,765.23 -3,901.11 4,054.31 5,923,695.84 464,775.99 0.97 5,135.82 MWD+I FR-AK-CAZ-SC(3) 7,777.47 72.91 129.92 3,949.21 3,793.15 -3,960.10 4,123.41 5,923,636.50 464,844.78 1.14 5,216.40 MWD+IFR-AK-CAZ-SC(3) 7,872.16 73.01 129.06 3,976.96 3,820.90 -4,017.68 4,193.28 5,923,578.57 464,914.34 0.87 5,295.96 MWD+IFR-AK-CAZ-SC(3) 7,966.09 73.00 130.13 4,004.41 3,848.35 -4,074.93 4,262.50 5,923,520.96 464,983.25 1.09 5,374.97 MWD+IFR-AK-CAZ-SC(3) 8,060.82 73.01 132.55 4,032.10 3,876.04 -4,134.76 4,330.51 5,923,460.78 465,050.94 2.44 5,455.92 MWD+IFR-AK-CAZ-SC(3) • 8,155.84 72.59 131.54 4,060.20 3,904.14 -4,195.55 4,397.92 5,923,399.65 465,118.02 1.11 5,537.54 MWD+IFR-AK-CAZ-SC(3) 8,249.54 72.91 131.98 4,087.99 3,931.93 -4,255.15 4,464.67 5,923,339.71 465,184.46 0.56 5,617.80 MWD+IFR-AK-CAZ-SC(3) 8,345.19 72.83 131.72 4,116.16 3,960.10 -4,316.13 4,532.76 5,923,278.38 465,252.22 0.27 5,699.85 MWD+IFR-AK-CAZ-SC(3) 8,440.00 72.90 130.78 4,144.10 3,988.04 -4,375.87 4,600.87 5,923,218.29 465,320.02 0.95 5,780.76 MWD+IFR-AK-CAZ-SC(3) 8,534.12 72.87 130.77 4,171.79 4,015.73 -4,434.62 4,668.99 5,923,159.20 465,387.83 0.03 5,860.74 MWD+I FR-AK-CAZ-SC(3) 8,629.10 72.65 131.48 4,199.94 4,043.88 -4,494.28 4,737.32 5,923,099.19 465,455.84 0.75 5,941.66 MWD+IFR-AK-CAZ-SC(3) 8,724.35 72.91 131.38 4,228.14 4,072.08 -4,554.48 4,805.54 5,923,038.64 465,523.73 0.29 6,023.03 MWD+IFR-AK-CAZ-SC(3) 8,818.49 72.85 132.11 4,255.85 4,099.79 -4,614.38 4,872.66 5,922,978.39 465,590.54 0.74 6,103.71 MWD+I F R-AK-CAZ-SC(3) 8,913.07 72.94 132.62 4,283.67 4,127.61 -4,675.30 4,939.45 5,922,917.14 465,657.01 0.52 6,185.21 MWD+IFR-AK-CAZ-SC(3) 9,008.49 72.31 132.58 4,312.17 4,156.11 -4,736.94 5,006.49 5,922,855.16 465,723.71 0.66 6,267.48 MWD+IFR-AK-CAZ-SC(3) 9,103.38 72.35 132.44 4,340.97 4,184.91 -4,798.03 5,073.14 5,922,793.73 465,790.04 0.15 6,349.09 MWD+IFR-AK-CAZ-SC(3) 9,198.17 72.42 131.72 4,369.66 4,213.60 -4,858.58 5,140.19 5,922,732.84 465,856.77 0.73 6,430.34 MWD+IFR-AK-CAZ-SC(3) 9,292.33 72.34 131.89 4,398.16 4,242.10 -4,918.40 5,207.09 5,922,672.67 465,923.35 0.19 6,510.87 MWD+IFR-AK-CAZ-SC(3) 3/23/2015 4:48:58PM Page 4 COMPASS 5000.1 Build 65 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2L-328(Sierra) Project: Kuparuk River Unit TVD Reference: 115+41.06 @ 156.06usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: 115+41.06 @ 156.06usft(Doyon 25) Well: 2L-328(Sierra) North Reference: True Wellbore: 2L-328 Survey Calculation Method: Minimum Curvature Design: 2L-328 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 9,387.23 72.31 131.53 4,426.97 4,270.91 -4,978.56 5,274.59 5,922,612.17 465,990.53 0.36 6,591.94 MWD+IFR-AK-CAZ-SC(3) 9,482.07 72.35 131.16 4,455.76 4,299.70 -5,038.26 5,342.43 5,922,552.13 466,058.05 0.37 6,672.70 MWD+IFR-AK-CAZ-SC(3) 9,576.71 72.31 130.82 4,484.48 4,328.42 -5,097.40 5,410.49 5,922,492.63 466,125.80 0.34 6,753.04 MWD+IFR-AK-CAZ-SC(3) 9,671.21 72.34 130.27 4,513.18 4,357.12 -5,155.93 5,478.91 5,922,433.75 466,193.91 0.56 6,832.94 MWD+IFR-AK-CAZ-SC(3) 9,765.46 72.84 130.18 4,541.38 4,385.32 -5,214.01 5,547.58 5,922,375.33 466,262.26 0.54 6,912.51 MWD+I F R-AK-CAZ-SC(3) 9,860.41 72.90 130.28 4,569.34 4,413.28 -5,272.61 5,616.85 5,922,316.37 466,331.23 0.12 6,992.79 MWD+IFR-AK-CAZ-SC(3) 9,954.21 72.91 130.55 4,596.92 4,440.86 -5,330.74 5,685.11 5,922,257.90 466,399.18 0.28 7,072.26 MWD+IFR-AK-CAZ-SC(3) 10,049.22 72.95 131.22 4,624.81 4,468.75 -5,390.19 5,753.78 5,922,198.10 466,467.52 0.68 7,153.10 MWD+IFR-AK-CAZ-SC(3) 10,145.11 72.85 131.86 4,653.00 4,496.94 -5,450.97 5,822.38 5,922,136.97 466,535.80 0.65 7,235.15 MWD+IFR-AK-CAZ-SC(3) 10,238.26 72.89 132.06 4,680.44 4,524.38 -5,510.48 5,888.57 5,922,077.11 466,601.68 0.21 7,315.13 MWD+IFR-AK-CAZ-SC(3) 10,333.37 72.83 131.73 4,708.47 4,552.41 -5,571.17 5,956.23 5,922,016.08 466,669.01 0.34 7,396.74 MWD+IFR-AK-CAZ-SC(3) 10,429.10 72.89 131.15 4,736.68 4,580.62 -5,631.72 6,024.80 5,921,955.19 466,737.26 0.58 7,478.57 MWD+IFR-AK-CAZ-SC(3) 10,524.15 72.99 131.29 4,764.57 4,608.51 -5,691.59 6,093.15 5,921,894.96 466,805.29 0.18 7,559.69 MWD+IFR-AK-CAZ-SC(3) 10,618.22 72.85 131.48 4,792.20 4,636.14 -5,751.04 6,160.62 5,921,835.17 466,872.44 0.24 7,640.08 MWD+IFR-AK-CAZ-SC(3) 10,712.76 72.73 132.17 4,820.17 4,664.11 -5,811.26 6,227.91 5,921,774.60 466,939.42 0.71 7,721.13 MWD+IFR-AK-CAZ-SC(3) 10,807.64 72.86 132.46 4,848.23 4,692.17 -5,872.28 6,294.93 5,921,713.24 467,006.11 0.32 7,802.81 MWD+IFR-AK-CAZ-SC(3) 10,901.61 72.93 132.07 4,875.87 4,719.81 -5,932.68 6,361.40 5,921,652.50 467,072.26 0.40 7,883.71 MWD+IFR-AK-CAZ-SC(3) 10,996.10 72.79 131.08 4,903.72 4,747.66 -5,992.60 6,428.95 5,921,592.24 467,139.48 1.01 7,964.57 MWD+IFR-AK-CAZ-SC(3) 11,090.95 72.94 130.43 4,931.66 4,775.60 -6,051.77 6,497.61 5,921,532.72 467,207.83 0.67 8,045.15 MWD+IFR-AK-CAZ-SC(3) 11,186.07 72.38 130.84 4,960.01 4,803.95 -6,110.90 6,566.51 5,921,473.24 467,276.42 0.72 8,125.79 MWD+IFR-AK-CAZ-SC(3) 11,279.02 72.35 131.31 4,988.17 4,832.11 -6,169.11 6,633.29 5,921,414.69 467,342.88 0.48 8,204.77 MWD+IFR-AK-CAZ-SC(3) 11,373.25 72.29 131.08 5,016.79 4,860.73 -6,228.24 6,700.84 5,921,355.22 467,410.12 0.24 8,284.90 MWD+IFR-AK-CAZ-SC(3) 11,468.45 72.39 130.49 5,045.67 4,889.61 -6,287.49 6,769.53 5,921,295.61 467,478.49 0.60 8,365.57 MWD+IFR-AK-CAZ-SC(3) 11,563.94 72.25 130.24 5,074.67 4,918.61 -6,346.42 6,838.85 5,921,236.33 467,547.50 0.29 8,446.17 MWD+IFR-AK-CAZ-SC(3) 11,657.61 72.30 130.58 5,103.19 4,947.13 -6,404.26 6,906.78 5,921,178.15 467,615.13 0.35 8,525.25 MWD+IFR-AK-CAZ-SC(3) 11,753.29 72.29 130.96 5,132.29 4,976.23 -6,463.78 6,975.81 5,921,118.27 467,683.84 0.38 8,606.30 MWD+I F R-AK-CAZ-SC(3) 11,847.05 72.29 131.36 5,160.81 5,004.75 -6,522.56 7,043.06 5,921,059.15 467,750.77 0.41 8,685.99 MWD+IFR-AK-CAZ-SC(3) 11,940.80 72.91 131.79 5,188.84 5,032.78 -6,581.93 7,109.98 5,920,999.44 467,817.38 0.79 8,766.10 MWD+IFR-AK-CAZ-SC(3) 12,035.57 72.86 132.11 5,216.73 5,060.67 -6,642.47 7,177.34 5,920,938.55 467,884.42 0.33 8,847.48 MWD+IFR-AK-CAZ-SC(3) 12,130.90 72.91 131.91 5,244.79 5,088.73 -6,703.45 7,245.04 5,920,877.23 467,951.79 0.21 8,929.37 MWD+IFR-AK-CAZ-SC(3) 12,203.94 72.32 132.27 5,266.61 5,110.55 -6,750.17 7,296.77 5,920,830.24 468,003.27 0.93 8,992.07 MWD+IFR-AK-CAZ-SC(3) 12,266.00 72.51 131.39 5,285.36 5,129.30 -6,789.63 7,340.85 5,920,790.56 468,047.14 1.39 9,045.16 MWD+IFR-AK-CAZ-SC(4) 7-5/8"x 9-7/8" 12,295.68 72.60 130.97 5,294.26 5,138.20 -6,808.27 7,362.16 5,920,771.81 468,068.35 1.39 9,070.43 MWD+IFR-AK-CAZ-SC(4) 12,324.19 72.78 130.57 5,302.75 5,146.69 -6,826.04 7,382.77 5,920,753.93 468,088.87 1.48 9,094.63 MWD+IFR-AK-CAZ-SC(4) 12,418.67 72.68 130.44 5,330.79 5,174.73 -6,884.64 7,451.37 5,920,694.98 468,157.16 0.17 9,174.66 MWD+IFR-AK-CAZ-SC(4) 12,513.55 73.47 131.22 5,358.42 5,202.36 -6,943.99 7,520.05 5,920,635.29 468,225.52 1.15 9,255.42 MWD+IFR-AK-CAZ-SC(4) 12,610.78 76.05 132.59 5,383.97 5,227.91 -7,006.64 7,589.86 5,920,572.28 468,294.99 2.98 9,339.66 MWD+IFR-AK-CAZ-SC(4) 12,706.22 78.47 135.03 5,405.02 5,248.96 -7,071.08 7,657.02 5,920,507.49 468,361.81 3.56 9,424.56 MWD+IFR-AK-CAZ-SC(4) 12,800.42 81.09 139.20 5,421.74 5,265.68 -7,139.00 7,720.08 5,920,439.26 468,424.51 5.17 9,511.16 MWD+IFR-AK-CAZ-SC(4) 12,894.67 83.09 144.25 5,434.72 5,278.66 -7,212.26 7,777.87 5,920,365.70 468,481.92 5.72 9,600.74 MWD+IFR-AK-CAZ-SC(4) 12,989.50 84.17 148.60 5,445.24 5,289.18 -7,290.77 7,829.98 5,920,286.94 468,533.61 4.70 9,693.04 MWD+IFR-AK-CAZ-SC(4) 13,083.22 84.03 150.97 5,454.88 5,298.82 -7,371.32 7,876.89 5,920,206.15 468,580.09 2.52 9,785.30 MWD+IFR-AK-CAZ-SC(4) 13,177.46 82.98 153.31 5,465.54 5,309.48 -7,454.09 7,920.64 5,920,123.16 468,623.41 2.71 9,878.44 MWD+IFR-AK-CAZ-SC(4) 3/23/2015 4:48:58PM Page 5 COMPASS 5000.1 Build 65 S . Schlumberger •► Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2L-328(Sierra) Project: Kuparuk River Unit TVD Reference: 115+41.06 @ 156.06usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: 115+41.06 @ 156.06usft(Doyon 25) Well: 2L-328(Sierra) North Reference: True Wellbore: 2L-328 Survey Calculation Method: Minimum Curvature Design: 2L-328 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 13,273.88 83.22 156.72 5,477.13 5,321.07 -7,540.84 7,961.07 5,920,036.21 468,663.38 3.52 9,974.02 MWD+IFR-AK-CAZ-SC(4) 13,368.87 84.81 158.98 5,487.03 5,330.97 -7,628.34 7,996.68 5,919,948.54 468,698.54 2.90 10,068.48 MWD+IFR-AK-CAZ-SC(4) 13,463.93 87.43 158.43 5,493.47 5,337.41 -7,716.69 8,031.12 5,919,860.01 468,732.51 2.82 10,163.30 MWD+IFR-AK-CAZ-SC(4) 13,559.69 89.57 159.99 5,495.97 5,339.91 -7,806.18 8,065.09 5,919,770.36 468,766.02 2.77 10,259.00 MWD+IFR-AK-CAZ-SC(4) 13,654.17 89.52 163.45 5,496.72 5,340.66 -7,895.88 8,094.72 5,919,680.52 468,795.18 3.66 10,353.27 MWD+IFR-AK-CAZ-SC(4) 13,749.88 89.59 163.04 5,497.47 5,341.41 -7,987.52 8,122.31 5,919,588.74 468,822.29 0.43 10,448.57 MWD+IFR-AK-CAZ-SC(4) 13,845.33 89.15 162.72 5,498.52 5,342.46 -8,078.73 8,150.41 5,919,497.39 468,849.91 0.57 10,543.67 MWD+IFR-AK-CAZ-SC(4) 13,938.71 88.97 161.84 5,500.05 5,343.99 -8,167.67 8,178.83 5,919,408.32 468,877.86 0.96 10,636.78 MW D+I F R-AK-CAZ-SC(4) 14,033.86 88.12 159.30 5,502.46 5,346.40 -8,257.37 8,210.47 5,919,318.47 468,909.03 2.81 10,731.79 MWD+IFR-AK-CAZ-SC(4) 14,129.80 87.52 155.89 5,506.11 5,350.05 -8,345.99 8,247.00 5,919,229.67 468,945.10 3.61 10,827.64 MWD+IFR-AK-CAZ-SC(4) 14,224.16 88.04 155.31 5,509.77 5,353.71 -8,431.85 8,285.95 5,919,143.61 468,983.60 0.83 10,921.85 MWD+IFR-AK-CAZ-SC(4) 14,317.33 89.19 156.10 5,512.02 5,355.96 -8,516.74 8,324.27 5,919,058.53 469,021.48 1.50 11,014.92 MWD+IFR-AK-CAZ-SC(4) 14,413.39 89.36 161.66 5,513.24 5,357.18 -8,606.31 8,358.87 5,918,968.79 469,055.60 5.79 11,110.92 MWD+IFR-AK-CAZ-SC(4) 14,508.53 88.72 159.57 5,514.83 5,358.77 -8,696.04 8,390.44 5,918,878.91 469,086.70 2.30 11,205.94 MWD+IFR-AK-CAZ-SC(4) 14,603.91 88.95 157.58 5,516.77 5,360.71 -8,784.80 8,425.27 5,918,789.97 469,121.07 2.10 11,301.29 MWD+IFR-AK-CAZ-SC(4) 14,697.13 87.90 157.30 5,519.33 5,363.27 -8,870.86 8,461.02 5,918,703.74 469,156.37 1.17 11,394.47 MWD+IFR-AK-CAZ-SC(4) 14,792.22 87.84 158.25 5,522.87 5,366.81 -8,958.82 8,496.96 5,918,615.60 469,191.85 1.00 11,489.49 MWD+IFR-AK-CAZ-SC(4) 14,888.21 87.20 158.26 5,527.02 5,370.96 -9,047.90 8,532.49 5,918,526.35 469,226.91 0.67 11,585.39 MWD+IFR-AK-CAZ-SC(4) 14,983.86 88.56 159.41 5,530.56 5,374.50 -9,137.03 8,567.00 5,918,437.05 469,260.95 1.86 11,680.96 MWD+IFR-AK-CAZ-SC(4) 15,076.13 89.35 162.11 5,532.24 5,376.18 -9,224.12 8,597.40 5,918,349.81 469,290.89 3.05 11,773.10 MWD+IF R-AK-CAZ-SC(4) 15,170.52 90.01 160.97 5,532.77 5,376.71 -9,313.65 8,627.29 5,918,260.13 469,320.31 1.40 11,867.31 MWD+IFR-AK-CAZ-SC(4) 15,266.64 89.55 161.09 5,533.14 5,377.08 -9,404.55 8,658.53 5,918,169.08 469,351.08 0.49 11,963.29 MWD+IFR-AK-CAZ-SC(4) 15,360.38 89.75 157.65 5,533.71 5,377.65 -9,492.27 8,691.55 5,918,081.20 469,383.64 3.68 12,056.99 MWD+IFR-AK-CAZ-SC(4) 15,455.27 90.78 151.60 5,533.27 5,377.21 -9,577.96 8,732.20 5,917,995.31 469,423.84 6.47 12,151.67 MWD+IFR-AK-CAZ-SC(4) 15,551.98 90.38 153.33 5,532.29 5,376.23 -9,663.71 8,776.90 5,917,909.34 469,468.09 1.84 12,247.92 MWD+IFR-AK-CAZ-SC(4) 15,646.36 89.92 153.14 5,532.05 5,375.99 -9,747.97 8,819.40 5,917,824.86 469,510.15 0.53 12,341.97 MWD+IFR-AK-CAZ-SC(4) 15,740.03 89.93 154.61 5,532.17 5,376.11 -9,832.07 8,860.65 5,917,740.56 469,550.95 1.57 12,435.40 MWD+IFR-AK-CAZ-SC(4) 15,834.24 90.11 153.29 5,532.14 5,376.08 -9,916.71 8,902.02 5,917,655.71 469,591.88 1.41 12,529.37 MWD+IFR-AK-CAZ-SC(4) 15,931.13 90.35 154.96 5,531.75 5,375.69 -10,003.88 8,944.30 5,917,568.33 469,633.70 1.74 12,626.03 MWD+IF R-AK-CAZ-SC(4) 16,025.44 90.65 154.64 5,530.92 5,374.86 -10,089.21 8,984.46 5,917,482.80 469,673.41 0.47 12,720.19 MWD+IFR-AK-CAZ-SC(4) 16,104.26 90.30 154.97 5,530.27 5,374.21 -10,160.53 9,018.01 5,917,411.32 469,706.59 0.61 12,798.89 MWD+IF R-AK-CAZ-SC(4) 16,168.00 90.30 154.97 5,529.94 5,373.88 -10,218.28 9,044.98 5,917,353.43 469,733.25 0.00 12,862.54 PROJECTED to TD Projection to TD 3/23/2015 4:48:58PM Page 6 COMPASS 5000.1 Build 65 • • 214189 RECEIVED APR 0 8 2015 AOGCC [FINAL ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2L Pad 2L-328 Definitive Survey Report NAD 83 23 March, 2015 0 • - Schlumberger ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2L-328(Sierra) Project: Kuparuk River Unit TVD Reference: 115+41.06 @ 156.06usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: 115+41.06 @ 156.06usft(Doyon 25) Well: 2L-328(Sierra) North Reference: True Wellbore: 2L-328 Survey Calculation Method: Minimum Curvature Design: 2L-328 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 2L-328(Sierra) Well Position +N/-S 0.00 usft Northing: 5,927,366.81 usfl Latitude: 70°12'46.357 N +EI-W 0.00 usft Easting: 1,600,776.16 usfl Longitude: 150°19'10.928 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 115.00 usft Wellbore 2L-328 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BGGM2014 2/10/2015 18.73 80.78 57,545 IDesign 2L-328 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 41.06 Vertical Section: Depth From(TVD) +N/-S +EI-W Direction (usft) (usft) (usft) (°) 41.06 0.00 0.00 158.00 Survey Program Date 3/23/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 80.38 1,297.77 2L-328 Srvy#1 -GYD-GC-SS(2L-328) GYD-GC-SS Gyrodata gyro single shots 3/19/2015 4:2 1,356.90 2,437.12 2L-328 Srvy#2-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/19/2015 4:3 2,513.32 12,203.94 2L-328 Srvy#3-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/23/2015 11:2 12,295.68 16,104.26 2L-328 Srvy#4-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/23/2015 11:2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 41.06 0.00 0.00 41.06 -115.00 0.00 0.00 5,927,366.81 1,600,776.16 0.00 0.00 UNDEFINED 80.38 0.41 259.05 80.38 -75.68 -0.03 -0.14 5,927,366.78 1,600,776.02 1.04 -0.03 GYD-GC-SS(1) 167.67 0.40 250.76 167.67 11.61 -0.19 -0.73 5,927,366.63 1,600,775.43 0.07 -0.10 GYD-GC-SS(1) 262.37 0.29 252.97 262.37 106.31 -0.37 -1.27 5,927,366.45 1,600,774.88 0.12 -0.14 GYD-GC-SS(1) 354.83 0.68 172.26 354.82 198.76 -0.98 -1.42 5,927,365.84 1,600,774.73 0.75 0.37 GYD-GC-SS(1) 446.99 1.70 158.60 446.96 290.90 -2.79 -0.85 5,927,364.02 1,600,775.29 1.14 2.27 GYD-GC-SS(1) 540.16 3.05 150.79 540.05 383.99 -6.24 0.86 5,927,360.56 1,600,776.99 1.49 6.11 GYD-GC-SS(1) 636.45 4.21 151.06 636.15 480.09 -11.57 3.82 5,927,355.22 1,600,779.92 1.20 12.16 GYD-GC-SS(1) 729.37 5.53 153.91 728.73 572.67 -18.58 7.44 5,927,348.19 1,600,783.50 1.44 20.01 GYD-GC-SS(1) 824.16 9.13 162.80 822.73 666.67 -29.87 11.68 5,927,336.88 1,600,787.68 3.97 32.07 GYD-GC-SS(1) 918.30 10.26 160.17 915.53 759.47 -44.89 16.73 5,927,321.84 1,600,792.65 1.29 47.89 GYD-GC-SS(1) 1,012.84 11.09 158.53 1,008.43 852.37 -61.27 22.91 5,927,305.42 1,600,798.75 0.93 65.39 GYD-GC-SS(1) 1,107.44 12.13 158.42 1,101.09 945.03 -78.98 29.90 5,927,287.68 1,600,805.64 1.10 84.43 GYD-GC-SS(1) 1,202.21 13.85 155.99 1,193.43 1,037.37 -98.60 38.18 5,927,268.02 1,600,813.82 1.90 105.73 GYD-GC-SS(1) 1,297.77 15.31 156.91 1,285.91 1,129.85 -120.66 47.78 5,927,245.91 1,600,823.30 1.55 129.77 GYD-GC-SS(1) 3/23/2015 3:51:57PM Page 2 COMPASS 5000.1 Build 65 • • _ ` Schlumberger Conoco PhiHHips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2L-328(Sierra) Project: Kuparuk River Unit TVD Reference: 115+41.06 @ 156.06usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: 115+41.06 @ 156.06usft(Doyon 25) Well: 2L-328(Sierra) North Reference: True Wellbore: 2L-328 Survey Calculation Method: Minimum Curvature Design: 2L-328 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 1,356.90 16.08 158.82 1,342.84 1,186.78 -135.48 53.80 5,927,231.07 1,600,829.24 1.57 145.77 MWD+IFR-AK-CAZ-SC(2) 1,450.82 16.24 157.98 1,433.05 1,276.99 -159.78 63.42 5,927,206.72 1,600,838.74 0.30 171.90 MWD+IFR-AK-CAZ-SC(2) 1,545.80 19.79 152.95 1,523.36 1,367.30 -186.42 75.72 5,927,180.01 1,600,850.89 4.08 201.21 MWD+IFR-AK-CAZ-SC(2) 1,640.91 21.82 150.66 1,612.27 1,456.21 -216.17 91.71 5,927,150.18 1,600,866.72 2.30 234.79 MWD+IFR-AK-CAZ-SC(2) 1,735.85 24.17 147.83 1,699.66 1,543.60 -248.01 110.70 5,927,118.24 1,600,885.55 2.73 271.42 MWD+IFR-AK-CAZ-SC(2) 1,831.33 27.05 145.86 1,785.75 1,629.69 -282.54 133.30 5,927,083.61 1,600,907.96 3.15 311.90 MWD+IFR-AK-CAZ-SC(2) 1,924.59 31.69 143.07 1,867.01 1,710.95 -319.69 159.93 5,927,046.32 1,600,934.40 5.19 356.32 MWD+IFR-AK-CAZ-SC(2) 2,020.63 35.31 142.38 1,947.08 1,791.02 -361.85 192.04 5,927,003.99 1,600,966.28 3.79 407.45 MWD+IFR-AK-CAZ-SC(2) 2,114.81 39.29 141.13 2,021.99 1,865.93 -406.65 227.39 5,926,959.01 1,601,001.39 4.30 462.22 MWD+IFR-AK-CAZ-SC(2) 2,209.11 43.59 141.30 2,092.66 1,936.60 -455.29 266.47 5,926,910.17 1,601,040.21 4.56 521.96 MWD+IFR-AK-CAZ-SC(2) 2,304.24 48.14 139.09 2,158.89 2,002.83 -507.69 310.20 5,926,857.55 1,601,083.66 5.06 586.92 MWD+IFR-AK-CAZ-SC(2) 2,398.22 51.71 137.70 2,219.39 2,063.33 -561.43 357.96 5,926,803.56 1,601,131.13 3.96 654.64 MWD+IFR-AK-CAZ-SC(2) 2,437.12 51.70 138.26 2,243.49 2,087.43 -584.11 378.39 5,926,780.78 1,601,151.44 1.13 683.33 MWD+IFR-AK-CAZ-SC(2) 2,464.00 51.54 137.72 2,260.18 2,104.12 -599.77 392.50 5,926,765.05 1,601,165.46 1.70 703.13 MWD+IFR-AK-CAZ-SC(3) 10 3/4"x 13-1/2 2,513.32 51.24 136.71 2,290.96 2,134.90 -628.05 418.67 5,926,736.63 1,601,191.49 1.70 739.16 MWD+IFR-AK-CAZ-SC(3) 2,572.84 52.98 136.06 2,327.51 2,171.45 -662.06 451.08 5,926,702.46 1,601,223.71 3.05 782.82 MWD+IFR-AK-CAZ-SC(3) 2,668.20 57.14 133.57 2,382.12 2,226.06 -717.10 506.54 5,926,647.13 1,601,278.88 4.86 854.64 MWD+IFR-AK-CAZ-SC(3) 2,763.02 62.40 132.76 2,429.85 2,273.79 -773.12 566.28 5,926,590.81 1,601,338.32 5.60 928.95 MWD+IFR-AK-CAZ-SC(3) 2,857.80 67.43 131.46 2,470.02 2,313.96 -830.64 629.96 5,926,532.95 1,601,401.69 5.45 1,006.14 MWD+IFR-AK-CAZ-SC(3) 2,951.94 71.76 130.37 2,502.83 2,346.77 -888.41 696.62 5,926,474.85 1,601,468.04 4.73 1,084.67 MWD+IFR-AK-CAZ-SC(3) 3,047.05 73.63 130.38 2,531.12 2,375.06 -947.22 765.80 5,926,415.67 1,601,536.90 1.97 1,165.12 MWD+IFR-AK-CAZ-SC(3) 3,143.57 72.37 131.80 2,559.34 2,403.28 -1,007.88 835.36 5,926,354.65 1,601,606.14 1.92 1,247.43 MWD+IFR-AK-CAZ-SC(3) 3,238.51 71.68 134.40 2,588.65 2,432.59 -1,069.58 901.30 5,926,292.62 1,601,671.74 2.70 1,329.33 MWD+IFR-AK-CAZ-SC(3) 3,333.89 71.63 135.60 2,618.67 2,462.61 -1,133.59 965.31 5,926,228.28 1,601,735.41 1.20 1,412.66 MWD+IFR-AK-CAZ-SC(3) 3,427.90 71.50 135.33 2,648.40 2,492.34 -1,197.17 1,027.86 5,926,164.38 1,601,797.62 0.31 1,495.04 MWD+IFR-AK-CAZ-SC(3) 3,523.25 71.78 134.46 2,678.43 2,522.37 -1,261.04 1,091.97 5,926,100.18 1,601,861.39 0.91 1,578.27 MWD+IFR-AK-CAZ-SC(3) 3,617.70 71.91 133.07 2,707.86 2,551.80 -1,323.12 1,156.78 5,926,037.77 1,601,925.87 1.41 1,660.11 MWD+IFR-AK-CAZ-SC(3) 3,711.60 71.94 133.19 2,736.99 2,580.93 -1,384.14 1,221.93 5,925,976.41 1,601,990.68 0.13 1,741.10 MWD+IFR-AK-CAZ-SC(3) 3,806.53 71.82 133.43 2,766.52 2,610.46 -1,446.03 1,287.58 5,925,914.18 1,602,056.00 0.27 1,823.07 MWD+I FR-AK-CAZ-SC(3) 3,901.24 71.76 132.94 2,796.12 2,640.06 -1,507.60 1,353.18 5,925,852.28 1,602,121.27 0.50 1,904.73 MWD+IFR-AK-CAZ-SC(3) 3,995.03 72.18 132.87 2,825.15 2,669.09 -1,568.31 1,418.50 5,925,791.22 1,602,186.27 0.45 1,985.50 MWD+IFR-AK-CAZ-SC(3) 4,087.61 72.36 132.41 2,853.34 2,697.28 -1,628.05 1,483.37 5,925,731.16 1,602,250.82 0.51 2,065.18 MWD+IFR-AK-CAZ-SC(3) 4,181.64 72.22 131.15 2,881.94 2,725.88 -1,687.73 1,550.17 5,925,671.13 1,602,317.29 1.29 2,145.54 MWD+IFR-AK-CAZ-SC(3) 4,276.58 72.90 131.02 2,910.40 2,754.34 -1,747.25 1,618.44 5,925,611.26 1,602,385.24 0.73 2,226.30 MWD+IFR-AK-CAZ-SC(3) 4,371.32 72.89 131.40 2,938.26 2,782.20 -1,806.91 1,686.56 5,925,551.25 1,602,453.04 0.38 2,307.13 MWD+IFR-AK-CAZ-SC(3) 4,465.48 72.82 131.24 2,966.02 2,809.96 -1,866.31 1,754.13 5,925,491.50 1,602,520.30 0.18 2,387.53 MWD+IFR-AK-CAZ-SC(3) 4,559.48 72.86 129.68 2,993.76 2,837.70 -1,924.60 1,822.47 5,925,432.86 1,602,588.32 1.59 2,467.16 MWD+IFR-AK-CAZ-SC(3) 4,653.97 72.85 128.14 3,021.61 2,865.55 -1,981.30 1,892.72 5,925,375.79 1,602,658.27 1.56 2,546.06 MWD+IFR-AK-CAZ-SC(3) 4,749.39 72.82 128.81 3,049.77 2,893.71 -2,038.03 1,964.10 5,925,318.70 1,602,729.34 0.67 2,625.39 MWD+IFR-AK-CAZ-SC(3) 4,843.61 72.83 130.00 3,077.60 2,921.54 -2,095.17 2,033.65 5,925,261.20 1,602,798.58 1.21 2,704.43 MWD+IFR-AK-CAZ-SC(3) 4,938.38 72.70 130.47 3,105.68 2,949.62 -2,153.64 2,102.75 5,925,202.38 1,602,867.37 0.49 2,784.52 MWD+IFR-AK-CAZ-SC(3) 5,032.40 72.92 130.31 3,133.46 2,977.40 -2,211.84 2,171.16 5,925,143.82 1,602,935.47 0.28 2,864.11 MWD+IFR-AK-CAZ-SC(3) 5,126.88 72.86 130.14 3,161.26 3,005.20 -2,270.15 2,240.10 5,925,085.15 1,603,004.10 0.18 2,944.01 MWD+IFR-AK-CAZ-SC(3) 3/23/2015 3:51:57PM Page 3 COMPASS 5000.1 Build 65 • ` Schlumberger ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2L-328(Sierra) Project: Kuparuk River Unit TVD Reference: 115+41.06 @ 156.06usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: 115+41.06 @ 156.06usft(Doyon 25) Well: 2L-328(Sierra) North Reference: True Wellbore: 2L-328 Survey Calculation Method: Minimum Curvature Design: 2L-328 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 5,220.19 72.82 130.37 3,188.79 3,032.73 -2,327.76 2,308.15 5,925,027.19 1,603,071.83 0.24 3,022.91 MWD+IFR-AK-CAZ-SC(3) 5,314.97 72.96 130.19 3,216.68 3,060.62 -2,386.33 2,377.25 5,924,968.27 1,603,140.62 0.23 3,103.10 MWD+IFR-AK-CAZ-SC(3) 5,410.55 72.88 130.54 3,244.75 3,088.69 -2,445.50 2,446.87 5,924,908.74 1,603,209.91 0.36 3,184.04 MWD+IFR-AK-CAZ-SC(3) 5,505.59 72.92 131.29 3,272.69 3,116.63 -2,504.99 2,515.51 5,924,848.89 1,603,278.24 0.76 3,264.92 MWD+IFR-AK-CAZ-SC(3) 5,600.46 72.86 132.07 3,300.61 3,144.55 -2,565.29 2,583.23 5,924,788.25 1,603,345.63 0.79 3,346.19 MWD+IFR-AK-CAZ-SC(3) 5,695.02 72.74 132.58 3,328.57 3,172.51 -2,626.11 2,650.02 5,924,727.08 1,603,412.09 0.53 3,427.60 MWD+IFR-AK-CAZ-SC(3) 5,789.26 72.40 132.53 3,356.80 3,200.74 -2,686.92 2,716.25 5,924,665.93 1,603,478.00 0.36 3,508.79 MWD+IFR-AK-CAZ-SC(3) 5,884.25 72.34 132.62 3,385.57 3,229.51 -2,748.17 2,782.91 5,924,604.34 1,603,544.33 0.11 3,590.55 MWD+I F R-AK-CAZ-SC(3) 5,978.38 72.45 133.03 3,414.04 3,257.98 -2,809.15 2,848.72 5,924,543.01 1,603,609.81 0.43 3,671.75 MWD+I F R-AK-CAZ-SC(3) 6,072.93 72.40 133.35 3,442.59 3,286.53 -2,870.85 2,914.43 5,924,480.98 1,603,675.20 0.33 3,753.57 MWD+IFR-AK-CAZ-SC(3) 6,168.03 72.34 133.38 3,471.39 3,315.33 -2,933.08 2,980.32 5,924,418.41 1,603,740.75 0.07 3,835.95 MWD+I FR-AK-CAZ-SC(3) 6,262.17 72.38 132.97 3,499.92 3,343.86 -2,994.46 3,045.75 5,924,356.69 1,603,805.85 0.42 3,917.38 MWD+IFR-AK-CAZ-SC(3) 6,356.23 72.35 131.73 3,528.41 3,372.35 -3,054.85 3,112.00 5,924,295.97 1,603,871.77 1.26 3,998.18 MWD+IFR-AK-CAZ-SC(3) 6,450.97 72.26 130.87 3,557.21 3,401.15 -3,114.42 3,179.80 5,924,236.05 1,603,939.26 0.87 4,078.81 MWD+IFR-AK-CAZ-SC(3) 6,545.17 72.78 130.81 3,585.51 3,429.45 -3,173.17 3,247.78 5,924,176.94 1,604,006.91 0.56 4,158.76 MWD+IFR-AK-CAZ-SC(3) 6,640.94 72.90 130.82 3,613.76 3,457.70 -3,232.99 3,317.03 5,924,116.77 1,604,075.85 0.13 4,240.15 MWD+IFR-AK-CAZ-SC(3) 6,736.08 72.76 131.37 3,641.85 3,485.79 -3,292.73 3,385.54 5,924,056.67 1,604,144.03 0.57 4,321.21 MWD+I F R-AK-CAZ-SC(3) 6,831.82 72.73 131.53 3,670.25 3,514.19 -3,353.26 3,454.07 5,923,995.79 1,604,212.23 0.16 4,403.00 MWD+I FR-AK-CAZ-SC(3) 6,925.16 72.76 131.82 3,697.93 3,541.87 -3,412.53 3,520.65 5,923,936.18 1,604,278.50 0.30 4,482.90 MWD+IFR-AK-CAZ-SC(3) 7,018.96 73.06 132.32 3,725.50 3,569.44 -3,472.60 3,587.20 5,923,875.76 1,604,344.73 0.60 4,563.53 MWD+IFR-AK-CAZ-SC(3) 7,114.68 72.73 132.91 3,753.65 3,597.59 -3,534.54 3,654.53 5,923,813.48 1,604,411.72 0.68 4,646.18 MWD+IFR-AK-CAZSC(3) 7,209.40 72.82 132.35 3,781.70 3,625.64 -3,595.82 3,721.09 5,923,751.86 1,604,477.96 0.57 4,727.93 MWD+IFR-AK-CAZ-SC(3) 7,303.41 72.89 132.79 3,809.42 3,653.36 -3,656.59 3,787.25 5,923,690.75 1,604,543.79 0.45 4,809.06 MWD+IFR-AK-CAZ-SC(3) 7,397.98 72.89 133.13 3,837.24 3,681.18 -3,718.18 3,853.39 5,923,628.81 1,604,609.60 0.34 4,890.95 MWD+IFR-AK-CAZ-SC(3) 7,490.28 72.77 132.88 3,864.49 3,708.43 -3,778.33 3,917.88 5,923,568.33 1,604,673.77 0.29 4,970.87 MWD+IFR-AK-CAZ-SC(3) 7,587.31 72.76 132.00 3,893.24 3,737.18 -3,840.87 3,986.27 5,923,505.44 1,604,741.82 0.87 5,054.48 MWD+I FR-AK-CAZ-SC(3) 7,682.42 72.93 131.05 3,921.29 3,765.23 -3,901.11 4,054.31 5,923,444.85 1,604,809.54 0.97 5,135.82 MWD+IFR-AK-CAZ-SC(3) 7,777.47 72.91 129.92 3,949.21 3,793.15 -3,960.10 4,123.41 5,923,385.50 1,604,878.32 1.14 5,216.40 MWD+IFR-AK-CAZ-SC(3) 7,872.16 73.01 129.06 3,976.96 3,820.90 -4,017.68 4,193.28 5,923,327.57 1,604,947.88 0.87 5,295.96 MWD+IFR-AK-CAZ-SC(3) 7,966.09 73.00 130.13 4,004.41 3,848.35 -4,074.93 4,262.50 5,923,269.96 1,605,016.79 1.09 5,374.97 MWD+IFR-AK-CAZ-SC(3) 8,060.82 73.01 132.55 4,032.10 3,876.04 -4,134.76 4,330.51 5,923,209.78 1,605,084.48 2.44 5,455.92 MWD+IFR-AK-CAZ-SC(3) 8,155.84 72.59 131.54 4,060.20 3,904.14 -4,195.55 4,397.92 5,923,148.64 1,605,151.56 1.11 5,537.54 MWD+I F R-AK-CAZ-SC(3) 8,249.54 72.91 131.98 4,087.99 3,931.93 -4,255.15 4,464.67 5,923,088.70 1,605,217.99 0.56 5,617.80 MWD+I FR-AK-CAZ-SC(3) 8,345.19 72.83 131.72 4,116.16 3,960.10 -4,316.13 4,532.76 5,923,027.36 1,605,285.75 0.27 5,699.85 MWD+I FR-AK-CAZ-SC(3) 8,440.00 72.90 130.78 4,144.10 3,988.04 -4,375.87 4,600.87 5,922,967.27 1,605,353.54 0.95 5,780.76 MWD+IFR-AK-CAZ-SC(3) 8,534.12 72.87 130.77 4,171.79 4,015.73 -4,434.62 4,668.99 5,922,908.18 1,605,421.35 0.03 5,860.74 MWD+IFR-AK-CAZSC(3) 8,629.10 72.65 131.48 4,199.94 4,043.88 -4,494.28 4,737.32 5,922,848.16 1,605,489.36 0.75 5,941.66 MWD+I FR-AK-CAZ-SC(3) 8,724.35 72.91 131.38 4,228.14 4,072.08 -4,554.48 4,805.54 5,922,787.61 1,605,557.25 0.29 6,023.03 MWD+I FR-AK-CAZ-SC(3) 8,818.49 72.85 132.11 4,255.85 4,099.79 -4,614.38 4,872.66 5,922,727.36 1,605,624.05 0.74 6,103.71 MWD+IFR-AK-CAZ-SC(3) 8,913.07 72.94 132.62 4,283.67 4,127.61 -4,675.30 4,939.45 5,922,666.10 1,605,690.52 0.52 6,185.21 MWD+IFR-AK-CAZ-SC(3) 9,008.49 72.31 132.58 4,312.17 4,156.11 -4,736.94 5,006.49 5,922,604.12 1,605,757.22 0.66 6,267.48 MWD+IFR-AK-CAZ-SC(3) 9,103.38 72.35 132.44 4,340.97 4,184.91 -4,798.03 5,073.14 5,922,542.68 1,605,823.54 0.15 6,349.09 MWD+IFR-AK-CAZ-SC(3) 9,198.17 72.42 131.72 4,369.66 4,213.60 -4,858.58 5,140.19 5,922,481.79 1,605,890.27 0.73 6,430.34 MWD+IFR-AK-CAZ-SC(3) 9,292.33 72.34 131.89 4,398.16 4,242.10 -4,918.40 5,207.09 5,922,421.62 1,605,956.84 0.19 6,510.87 MWD+IFR-AK-CAZ-SC(3) 3/23/2015 3:51:57PM Page 4 COMPASS 5000.1 Build 65 • • - Schlurnberger ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2L-328(Sierra) Project: Kuparuk River Unit TVD Reference: 115+41.06 @ 156.06usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: 115+41.06 @ 156.06usft(Doyon 25) Well: 2L-328(Sierra) North Reference: True Wellbore: 2L-328 Survey Calculation Method: Minimum Curvature Design: 2L-328 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 9,387.23 72.31 131.53 4,426.97 4,270.91 -4,978.56 5,274.59 5,922,361.11 1,606,024.02 0.36 6,591.94 MWD+IFR-AK-CAZ-SC(3) 9,482.07 72.35 131.16 4,455.76 4,299.70 -5,038.26 5,342.43 5,922,301.07 1,606,091.54 0.37 6,672.70 MWD+I FR-AK-CAZ-SC(3) 9,576.71 72.31 130.82 4,484.48 4,328.42 -5,097.40 5,410.49 5,922,241.57 1,606,159.29 0.34 6,753.04 MWD+IFR-AK-CAZ-SC(3) 9,671.21 72.34 130.27 4,513.18 4,357.12 -5,155.93 5,478.91 5,922,182.69 1,606,227.39 0.56 6,832.94 MWD+IFR-AK-CAZ-SC(3) 9,765.46 72.84 130.18 4,541.38 4,385.32 -5,214.01 5,547.58 5,922,124.26 1,606,295.74 0.54 6,912.51 MWD+I FR-AK-CAZ-SC(3) 9,860.41 72.90 130.28 4,569.34 4,413.28 -5,272.61 5,616.85 5,922,065.30 1,606,364.70 0.12 6,992.79 MWD+IFR-AK-CAZ-SC(3) 9,954.21 72.91 130.55 4,596.92 4,440.86 -5,330.74 5,685.11 5,922,006.82 1,606,432.65 0.28 7,072.26 MWD+I FR-AK-CAZ-SC(3) 10,049.22 72.95 131.22 4,624.81 4,468.75 -5,390.19 5,753.78 5,921,947.02 1,606,501.00 0.68 7,153.10 MWD+I FR-AK-CAZ-SC(3) 10,145.11 72.85 131.86 4,653.00 4,496.94 -5,450.97 5,822.38 5,921,885.89 1,606,569.27 0.65 7,235.15 MWD+IFR-AK-CAZ-SC(3) 10,238.26 72.89 132.06 4,680.44 4,524.38 -5,510.48 5,888.57 5,921,826.03 1,606,635.14 0.21 7,315.13 MWD+IFR-AK-CAZ-SC(3) 10,333.37 72.83 131.73 4,708.47 4,552.41 -5,571.17 5,956.23 5,921,764.99 1,606,702.47 0.34 7,396.74 MWD+IFR-AK-CAZ-SC(3) 10,429.10 72.89 131.15 4,736.68 4,580.62 -5,631.72 6,024.80 5,921,704.09 1,606,770.72 0.58 7,478.57 MWD+IFR-AK-CAZ-SC(3) 10,524.15 72.99 131.29 4,764.57 4,608.51 -5,691.59 6,093.15 5,921,643.86 1,606,838.75 0.18 7,559.69 MWD+IFR-AK-CAZ-SC(3) 10,618.22 72.85 131.48 4,792.20 4,636.14 -5,751.04 6,160.62 5,921,584.07 1,606,905.90 0.24 7,640.08 MWD+IFR-AK-CAZ-SC(3) 10,712.76 72.73 132.17 4,820.17 4,664.11 -5,811.26 6,227.91 5,921,523.50 1,606,972.87 0.71 7,721.13 MWD+IFR-AK-CAZ-SC(3) 10,807.64 72.86 132.46 4,848.23 4,692.17 -5,872.28 6,294.93 5,921,462.14 1,607,039.56 0.32 7,802.81 MWD+I FR-AK-CAZ-SC(3) 10,901.61 72.93 132.07 4,875.87 4,719.81 -5,932.68 6,361.40 5,921,401.39 1,607,105.70 0.40 7,883.71 MWD+I F R-AK-CAZ-SC(3) 10,996.10 72.79 131.08 4,903.72 4,747.66 -5,992.60 6,428.95 5,921,341.13 1,607,172.92 1.01 7,964.57 MWD+I F R-AK-CAZ-SC(3) 11,090.95 72.94 130.43 4,931.66 4,775.60 -6,051.77 6,497.61 5,921,281.60 1,607,241.27 0.67 8,045.15 MWD+I F R-AK-CAZ-SC(3) 11,186.07 72.38 130.84 4,960.01 4,803.95 -6,110.90 6,566.51 5,921,222.12 1,607,309.85 0.72 8,125.79 MWD+I FR-AK-CAZ-SC(3) 11,279.02 72.35 131.31 4,988.17 4,832.11 -6,169.11 6,633.29 5,921,163.57 1,607,376.32 0.48 8,204.77 MWD+I F R-AK-CAZ-SC(3) 11,373.25 72.29 131.08 5,016.79 4,860.73 -6,228.24 6,700.84 5,921,104.09 1,607,443.55 0.24 8,284.90 MWD+I FR-AK-CAZ-SC(3) 11,468.45 72.39 130.49 5,045.67 4,889.61 -6,287.49 6,769.53 5,921,044.48 1,607,511.92 0.60 8,365.57 MWD+I FR-AK-CAZ-SC(3) 11,563.94 72.25 130.24 5,074.67 4,918.61 -6,346.42 6,838.85 5,920,985.20 1,607,580.92 0.29 8,446.17 MWD+IFR-AK-CAZ-SC(3) 11,657.61 72.30 130.58 5,103.19 4,947.13 -6,404.26 6,906.78 5,920,927.01 1,607,648.55 0.35 8,525.25 MWD+IFR-AK-CAZ-SC(3) 11,753.29 72.29 130.96 5,132.29 4,976.23 -6,463.78 6,975.81 5,920,867.13 1,607,717.26 0.38 8,606.30 MWD+IF R-AK-CAZ-SC(3) 11,847.05 72.29 131.36 5,160.81 5,004.75 -6,522.56 7,043.06 5,920,808.00 1,607,784.19 0.41 8,685.99 MWD+IFR-AK-CAZ-SC(3) 11,940.80 72.91 131.79 5,188.84 5,032.78 -6,581.93 7,109.98 5,920,748.29 1,607,850.79 0.79 8,766.10 MWD+IFR-AK-CAZ-SC(3) 12,035.57 72.86 132.11 5,216.73 5,060.67 -6,642.47 7,177.34 5,920,687.40 1,607,917.83 0.33 8,847.48 MWD+IFR-AK-CAZ-SC(3) 12,130.90 72.91 131.91 5,244.79 5,088.73 -6,703.45 7,245.04 5,920,626.08 1,607,985.20 0.21 8,929.37 MWD+IFR-AK-CAZ-SC(3) 12,203.94 72.32 132.27 5,266.61 5,110.55 -6,750.17 7,296.77 5,920,579.09 1,608,036.67 0.93 8,992.07 MWD+IFR-AK-CAZ-SC(3) 12,266.00 72.51 131.39 5,285.36 5,129.30 -6,789.63 7,340.85 5,920,539.41 1,608,080.54 1.39 9,045.16 MWD+IFR-AK-CAZ-SC(4) 7-5/8"x 9-7/8" 12,295.68 72.60 130.97 5,294.26 5,138.20 -6,808.27 7,362.16 5,920,520.65 1,608,101.75 1.39 9,070.43 MWD+IFR-AK-CAZ-SC(4) 12,324.19 72.78 130.57 5,302.75 5,146.69 -6,826.04 7,382.77 5,920,502.77 1,608,122.27 1.48 9,094.63 MWD+IFR-AK-CAZ-SC(4) 12,418.67 72.68 130.44 5,330.79 5,174.73 -6,884.64 7,451.37 5,920,443.82 1,608,190.55 0.17 9,174.66 MWD+IFR-AK-CAZ-SC(4) 12,513.55 73.47 131.22 5,358.42 5,202.36 -6,943.99 7,520.05 5,920,384.12 1,608,258.91 1.15 9,255.42 MWD+IFR-AK-CAZ-SC(4) 12,610.78 76.05 132.59 5,383.97 5,227.91 -7,006.64 7,589.86 5,920,321.10 1,608,328.38 2.98 9,339.66 MWD+IFR-AK-CAZ-SC(4) 12,706.22 78.47 135.03 5,405.02 5,248.96 -7,071.08 7,657.02 5,920,256.32 1,608,395.20 3.56 9,424.56 MWD+IFR-AK-CAZ-SC(4) 12,800.42 81.09 139.20 5,421.74 5,265.68 -7,139.00 7,720.08 5,920,188.08 1,608,457.89 5.17 9,511.16 MWD+IFR-AK-CAZ-SC(4) 12,894.67 83.09 144.25 5,434.72 5,278.66 -7,212.26 7,777.87 5,920,114.52 1,608,515.30 5.72 9,600.74 MWD+IFR-AK-CAZ-SC(4) 12,989.50 84.17 148.60 5,445.24 5,289.18 -7,290.77 7,829.98 5,920,035.75 1,608,566.98 4.70 9,693.04 MWD+IFR-AK-CAZ-SC(4) 13,083.22 84.03 150.97 5,454.88 5,298.82 -7,371.32 7,876.89 5,919,954.96 1,608,613.46 2.52 9,785.30 MWD+I F R-AK-CAZ-SC(4) 13,177.46 82.98 153.31 5,465.54 5,309.48 -7,454.09 7,920.64 5,919,871.97 1,608,656.78 2.71 9,878.44 MWD+IFR-AK-CAZ-SC(4) 3/23/2015 3:51:57PM Page 5 COMPASS 5000.1 Build 65 . Schlumberger ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2L-328(Sierra) Project: Kuparuk River Unit TVD Reference: 115+41.06 @ 156.06usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: 115+41.06 @ 156.06usft(Doyon 25) Well: 2L-328(Sierra) North Reference: True Wellbore: 2L-328 Survey Calculation Method: Minimum Curvature Design: 2L-328 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 13,273.88 83.22 156.72 5,477.13 5,321.07 -7,540.84 7,961.07 5,919,785.02 1,608,696.74 3.52 9,974.02 MWD+IFR-AK-CAZ-SC(4) 13,368.87 84.81 158.98 5,487.03 5,330.97 -7,628.34 7,996.68 5,919,697.35 1,608,731.89 2.90 10,068.48 MWD+I FR-AK-CAZ-SC(4) 13,463.93 87.43 158.43 5,493.47 5,337.41 -7,716.69 8,031.12 5,919,608.82 1,608,765.87 2.82 10,163.30 MWD+IFR-AK-CAZ-SC(4) 13,559.69 89.57 159.99 5,495.97 5,339.91 -7,806.18 8,065.09 5,919,519.16 1,608,799.37 2.77 10,259.00 MWD+IFR-AK-CAZ-SC(4) 13,654.17 89.52 163.45 5,496.72 5,340.66 -7,895.88 8,094.72 5,919,429.32 1,608,828.52 3.66 10,353.27 MWD+IFR-AK-CAZ-SC(4) 13,749.88 89.59 163.04 5,497.47 5,341.41 -7,987.52 8,122.31 5,919,337.54 1,608,855.63 0.43 10,448.57 MWD+IFR-AK-CAZ-SC(4) 13,845.33 89.15 162.72 5,498.52 5,342.46 -8,078.73 8,150.41 5,919,246.19 1,608,883.24 0.57 10,543.67 MWD+IFR-AK-CAZ-SC(4) 13,938.71 88.97 161.84 5,500.05 5,343.99 -8,167.67 8,178.83 5,919,157.11 1,608,911.19 0.96 10,636.78 MWD+I FR-AK-CAZ-SC(4) 14,033.86 88.12 159.30 5,502.46 5,346.40 -8,257.37 8,210.47 5,919,067.26 1,608,942.36 2.81 10,731.79 MWD+IFR-AK-CAZ-SC(4) 14,129.80 87.52 155.89 5,506.11 5,350.05 -8,345.99 8,247.00 5,918,978.46 1,608,978.42 3.61 10,827.64 MWD+IFR-AK-CAZ-SC(4) 14,224.16 88.04 155.31 5,509.77 5,353.71 -8,431.85 8,285.95 5,918,892.40 1,609,016.92 0.83 10,921.85 MWD+IFR-AK-CAZ-SC(4) 14,317.33 89.19 156.10 5,512.02 5,355.96 -8,516.74 8,324.27 5,918,807.32 1,609,054.79 1.50 11,014.92 MWD+IFR-AK-CAZ-SC(4) 14,413.39 89.36 161.66 5,513.24 5,357.18 -8,606.31 8,358.87 5,918,717.58 1,609,088.91 5.79 11,110.92 MWD+IFR-AK-CAZ-SC(4) 14,508.53 88.72 159.57 5,514.83 5,358.77 -8,696.04 8,390.44 5,918,627.70 1,609,120.01 2.30 11,205.94 MWD+IFR-AK-CAZ-SC(4) 14,603.91 88.95 157.58 5,516.77 5,360.71 -8,784.80 8,425.27 5,918,538.76 1,609,154.37 2.10 11,301.29 MWD+IFR-AK-CAZ-SC(4) 14,697.13 87.90 157.30 5,519.33 5,363.27 -8,870.86 8,461.02 5,918,452.53 1,609,189.66 1.17 11,394.47 MWD+IFR-AK-CAZ-SC(4) 14,792.22 87.84 158.25 5,522.87 5,366.81 -8,958.82 8,496.96 5,918,364.38 1,609,225.14 1.00 11,489.49 MWD+I FR-AK-CAZ-SC(4) 14,888.21 87.20 158.26 5,527.02 5,370.96 -9,047.90 8,532.49 5,918,275.13 1,609,260.20 0.67 11,585.39 MWD+IFR-AK-CAZ-SC(4) 14,983.86 88.56 159.41 5,530.56 5,374.50 -9,137.03 8,567.00 5,918,185.83 1,609,294.23 1.86 11,680.96 MWD+IFR-AK-CAZ-SC(4) 15,076.13 89.35 162.11 5,532.24 5,376.18 -9,224.12 8,597.40 5,918,098.58 1,609,324.17 3.05 11,773.10 MWD+IFR-AK-CAZ-SC(4) 15,170.52 90.01 160.97 5,532.77 5,376.71 -9,313.65 8,627.29 5,918,008.91 1,609,353.58 1.40 11,867.31 MWD+IFR-AK-CAZ-SC(4) 15,266.64 89.55 161.09 5,533.14 5,377.08 -9,404.55 8,658.53 5,917,917.85 1,609,384.35 0.49 11,963.29 MWD+IFR-AK-CAZ-SC(4) 15,360.38 89.75 157.65 5,533.71 5,377.65 -9,492.27 8,691.55 5,917,829.98 1,609,416.91 3.68 12,056.99 MWD+IFR-AK-CAZ-SC(4) 15,455.27 90.78 151.60 5,533.27 5,377.21 -9,577.96 8,732.20 5,917,744.08 1,609,457.10 6.47 12,151.67 MWD+IFR-AK-CAZ-SC(4) 15,551.98 90.38 153.33 5,532.29 5,376.23 -9,663.71 8,776.90 5,917,658.11 1,609,501.35 1.84 12,247.92 MWD+I FR-AK-CAZ-SC(4) 15,646.36 89.92 153.14 5,532.05 5,375.99 -9,747.97 8,819.40 5,917,573.63 1,609,543.40 0.53 12,341.97 MWD+IFR-AK-CAZ-SC(4) 15,740.03 89.93 154.61 5,532.17 5,376.11 -9,832.07 8,860.65 5,917,489.32 1,609,584.20 1.57 12,435.40 MWD+IFR-AK-CAZ-SC(4) 15,834.24 90.11 153.29 5,532.14 5,376.08 -9,916.71 8,902.02 5,917,404.48 1,609,625.12 1.41 12,529.37 MWD+IFR-AK-CAZ-SC(4) 15,931.13 90.35 154.96 5,531.75 5,375.69 -10,003.88 8,944.30 5,917,317.09 1,609,666.94 1.74 12,626.03 MWD+IFR-AK-CAZ-SC(4) 16,025.44 90.65 154.64 5,530.92 5,374.86 -10,089.21 8,984.46 5,917,231.56 1,609,706.64 0.47 12,720.19 MWD+IFR-AK-CAZ-SC(4) 16,104.26 90.30 154.97 5,530.27 5,374.21 -10,160.53 9,018.01 5,917,160.07 1,609,739.82 0.61 12,798.89 MWD+IFR-AK-CAZ-SC(4) 16,168.00 90.30 154.97 5,529.94 5,373.88 -10,218.28 9,044.98 5,917,102.18 1,609,766.48 0.00 12,862.54 PROJECTED to TD Projection to TD 3/23/2015 3:51:57PM Page 6 COMPASS 5000.1 Build 65 — • • V of Ty ,.,-0",\ 1//7_,,'6.,,� �_ THE STATE Alaska Oiland Gas f..4 �>��� o f,(� 1\cKA Conservation Commission � ,=- .- - 333 West Seventh Avenue kGOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 110Z-7.77C.- Main: 907.279.1433 0.A.ALAS�� Fax: 907.276.7542 www.aogcc.alaska.gov Adam Klem �,— l 31 Sr. Completions Engineer • �' ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2L-328 Sundry Number: 315-220 Dear Mr. Klem: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, a/8 /°7;e....s../1,----- Cathy P. oerster � -(' Chair "da DATED this 24 y of April, 2015 Encl. STATE OF ALASKANRECEIVED A�tA OIL AND GAS CONSERVATION COMll1 ION ti a11\- APPLICATION FOR SUNDRY APPROVALS APR 13 2015 20 AAC 25.280 AOGCC 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate 17. Alter casing r Other:Frac Treatment F, 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development iV. 214-189-0 ' 3.Address: Stratigraphic r Service 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-103-20698-00 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No 1./ KRU 2L-328 ` 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 380051,380052.380053. Kuparuk River Field/Tarn Oil Pool. 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft)j2Affective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 16170 s6"$$o29j none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 114' 114' SURFACE 2461 10.75 2500' 2293' INTERMEDIATE 12230 7.625 12266' 5287' LINER 12096 4.5 12096' 5219' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): none none 3.5 L-80 12096 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) no packer no SSSV -?P r 12,,I Lii kb 12.Attachments: Description Summary of Proposal F 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch Exploratory r Stratigraphic rDevelopment , Service 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 4/25/2015 Oil 17 • Gas r WDSPL r Suspended r 16.Verbal Approval: Date: VVINJ r GINJ r WAG E Abandoned 1-- Commission Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Adam Klem @ 263-4529 Email: Adam.Klem(c�conocophillips.com Printed Name A Klem Title: Sr. Completions Engineer Signature Phone:263-4529 Date y/i3/7S Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3%5.220 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r tr 0 N Other: 73 a S f /j-2 f o / /,,,ter ,� i'c.., c_._? q /i i t -1 f0 7,6 F e C /y-a C 0 S C �I'1 C h�,,,c 4r , CV CV s � D/ cI/0Sz�re re" 15 �y wIA/w(.�f✓ctc foGc,S. O a3 vv- ii 45 itcLv,'rr.1,7z-n f-S oc dafl%--cz�. ZE93 _ Q Spacing Exception Required? Yes ❑ No d Subsequent Form Required: /G- /0 4 co Approved by:( 0-4-4-7"1-1,----- APPROVED SBY / C3 " — '� COMMISSIONER THE COMMISSION Date: -2( -'`� � ZApproved application is valid tor 12 months trom the date of approval. y gel Is-- CO Form 10-403(Revised 10/2012) (�� Submit Form and Attachments in Duplicate vrL4/Z// C ORIGINAL /�`(� ' 1/2i /s p • • Section 1 - Affidavit 10 AAC 25.283 (a)(1) Exhibit 1 is an affidavit stating that the owners, landowners, surface owners and operators within one-half mile radius of the current or proposed wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283(a)(1). TO TH•LASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) AFFIDAVIT OF Paul K.Wharton Request of ConocoPhillips Alaska, Inc.for ) Hydraulic fracturing for the 2L-328 Well ) under the Provisions ) of 20AAC 25.280 ) STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) Paul K.Wharton, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Paul K. Wharton. I am over 19 years old and have personal knowledge of the matters set forth herein. 2. I am Staff Landman for the well operator, ConocoPhillips Alaska, Inc. ("CPAP') 3. Pursuant to 20 AAC 25.283(1) CPAI prepared the attached Notice of Operations("Notice"). 4. On or about March 30, 2015, CPAI sent a copy of the Notice by certified mail to the last known address of all other owners, landowners, surface owners, and operators of record within a one-half mile radius of the current proposed well trajectory. Subscribed and sworn to this 30th day of March,2015. 6),u.), Lir(rIAA Paul K.Wharton STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this30th day of March,2015, by Paul K.Wharton. (icc!" Notary Public, State of Alaska My Commission Expires: STATE OF ALASKA 1 I NOT. ';Y PUBLIC REBECCATO c. T,. My Commission Expires Aug.27®2011 • • ConocoPhillips Alaska, Inc. Paul K.Wharton Staff Landman P.O.Box 100360—Suite ATO 1482 Anchorage,Alaska 99510-0360 Phone(907)263-4076 Fax (907)263-4966 Paul.K.Wharton@conocophillips.com Date: March 30, 2015 To: Operator and Owners (shown on Exhibit 2) Re: Notice pursuant to 20 AAC 25.283 (1) 2L-328 Kuparuk River Unit, Alaska Dear Sirs: ConocoPhillips Alaska, Inc. ("CPAI") as Operator and on behalf of the Kuparuk River Unit ("KRU") working interest owners, hereby notifies you that it intends to submit an Application for Sundry Approvals for stimulation by hydraulic fracturing pursuant to the provisions of 20 AAC 25.280 ("Application") for the 2L-328 Well (the "Well"). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about March 31, 2015. This Notice is being provided pursuant to 20 AAC 25.283. The Well has been drilled as a directional well on lease ADL 380052, KRU Tract 130; ADL 380051, KRU Tract 131; and ADL 380053, KRU Tract 134 as depicted on Exhibit 1 as follows: Surface Location: 229' FNL, 909' FEL, Section 22, T1ON, RO7E, UM Target Location: 2408' FNL, 3560' FEL, Section 25, T1ON, RO7E, UM Bottomhole Location: 5174'FNL, 2438' FEL, Section 25, T1ON, RO8E, UM Exhibit 1 shows the location of the Well and the lands that are within a one-half mile radius of the current proposed trajectory of the Well, including the reservoir section ("Notification Area"). Exhibit 2 is a list of the names and addresses of all owners, landowners and operators of record of all properties within the Notification Area. Upon your request CPAI will provide a complete copy of the Application to you. If you require any additional information, please contact the undersigned. Very truly yours, aul Wharton Staff Landman cc: Adam Klem 2L-238 Hydraulic Fracturing Noticetetter • March 30, 2015 Page 2 Exhibit 1 A DL350051 ADL025603 1/2 mile radius from �_� 2L-308 Well 2 ADL330054 _..,;08 4 K 1, ADL375074iNt " PA ItlItt Legend ik 1/2 Mile Trajectory Radius ®Proposed Well Trajectory Proposed Open Section likt LEASE_NO Si M ADL025608 ADL380051 ADL390982 ADL380052 ADL380053 CPAI Operated Units REFERENCES: Well Data:ConocoPhillipsAlaska Wells DatabaseATDB ConocoPhillips Surface Facilities:North Slope 6K Survey 7/25/12 Published 3/20/13 Alaska Statewide Oil&Gas Leases 1/12/2015 Alaska,Inc. Water Well Data:DNR-Groundwater Division >No Potable Water Wells are in the Kuparuk River Unit. N 2L-328 Plat Anaysis >No Potable Water Aquifers ate in the Kuparuk River Unit Leases 3/17/2015 1 0.s 0 Mlles 3s520FmcLease.matl CSR 042015 • 2L-238 Hydraulic Fracturing Notice Letter March 30,2015 Page 3 Exhibit 2 Mineral Owners: Kuparuk River Unit Lands Operator: ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO 1226 (Zip 99501) P.O. Box 100360 Anchorage, AK 99510-0360 Attention: Patrick J. Wolfe, NS Development Manager Non-Operators: BP Exploration (Alaska) Inc. P.O. Box 196612 900 E. Benson Boulevard (Zip 99508) Anchorage, AK 99519-6612 Attention: Mr. Robert Kinnear Chevron U.S.A. Inc. 310 K Street, Suite 406 Anchorage, AK 99501 Attention: Mr. Glenn Fredrick ExxonMobil Alaska Production Inc. P.O. Box 196601 3301 C Street, Suite 400 (Zip 99503) Anchorage, AK 99519-6601 Attention: Mr. Gilbert Wong Surface Owner: State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7t" Avenue, Suite 1100 Anchorage, AK 99501-3560 Attention: Director 4) • Section 2 — Plat 20 AAC 25.283 (a)(2) I >L-314Pl31 N tl30aa01 2 �a 2L 3(21.329q.62L 3,��11 319-2L-a12 'b7 21--307 21-.304,.21-3701 21-;`4g/32`-31,.ZL.3093��<? •&';.1,< 9 3T 21--30.:-,4 oi .3�P d; i 'i3�, `�\ `to,,, et�N a d, `Z�' iT,y,, t j ,Dc9 a37T,y`� 8 NZ 3 11 Tarn K aruk Riv ynit IF\<0• ,.....„) 2N r Legend Q 1/2 Mile Trajectory Radius —21328trajbuffwells —Proposed Well Trajectory ®Proposed Open Section 1/2 Mile Open Section Radius Participating Area j Tarn PA =CPA!Operated Units REFERENCES: Well Data:ConocoPhillips Alaska Wells Database ATDB Surface Facilities:North Slope 6K Survey 7/25/12 Published 3/20/13 ConocoPhill ips Alaska Statewide Oil&Gas Leases 1/12/2015 Alaska,Inc. Water Well Data:DNR-Groundwater Division >No Potable Water Wells are in the Kuparuk River Unit. N 2L-328 Plat Anaysis >No Potable Water Aquifers are in the Kuparuk River Unit A Wells 3/17/2015 05 0 MIes 3,520F=lease 5.CSR ba,2015 0 • WELL_NAME PERMIT_NUM API BUS_AREA_ID BUB FLUID WELL STATUS 2L-03 201-239 501032039800 KRU KUP OIL PROD OPSH 2L-301 208-192 501032058800 TARNDB KUP MWAG INJ ACTIVE 2L-304 210-011 501032061300 TARNDB KUP OIL PROD ACTIVE 2L-305 198-240 501032027900 TARNDB KUP MWAG INJ ACTIVE 2L-306 210-182-0 501032063000 TARNDB KUP OIL PROD ACTIVE 2L-306PB1 210-182-0 501032063070 TARNDB KUP EXPEND PA 2L-307 198-256 501032028400 TARNDB KUP OIL PROD ACTIVE 2L-307L1 211-093-0 501032028460 TARNDB KUP OIL PROD ACTIVE 2L-307L2 211-094-0 501032028461 TARNDB KUP OIL PROD ACTIVE 2L-307L2-01 211-136-0 501032028462 TARNDB KUP OIL PROD ACTIVE 2L-308 214-151-0 501032069400 TARNDB KUP OIL PROD PROP 2L-309 205-210 501032052100 TARNDB KUP OIL PROD ACTIVE 2L-309PB1 205-210 501032052170 TARNDB KUP EXPEND PA 2L-310 210-028-0 501032061600 TARNDB KUP MWAG INJ ACTIVE 2L-311 203-155 501032046900 TARNDB KUP OIL PROD ACTIVE 2L-312 210-164-0 501032062600 TARNDB KUP OIL PROD ACTIVE 2L-313 198-219 501032027700 TARNDB KUP OIL PROD ACTIVE 2L-314 214-023-0 501032068600 TARNDB KUP OIL PROD ACTIVE 2L-314PB1 214-023-0 501032068670 TARNDB KUP EXPEND PA 2L-315 198-218 501032027600 TARNDB KUP OIL PROD ACTIVE 2L-317 200-060 501032033600 TARNDB KUP PROD PA 2L-317A 200-210 501032033601 TARNDB KUP MWAG INJ ACTIVE 2L-318 213-183-0 501032068100 TARNDB KUP PW INJ ACTIVE 2L-319 207-112 501032055200 TARNDB KUP MWAG INJ ACTIVE 2L-320 210-166-0 501032062700 TARNDB KUP OIL PROD ACTIVE 2L-320PB1 210-166-0 501032062770 TARNDB KUP EXPEND PA 2L-320PB2 210-166-0 501032062771 TARNDB KUP EXPEND PA 2L-321 198-262 501032028600 TARNDB KUP OIL PROD ACTIVE 2L-322 210-174-0 501032062800 TARNDB KUP OIL PROD PA 2L-322A 213-167-0 501032062801 TARNDB KUP OIL PROD ACTIVE 2L-322PB1 210-174-0 501032062870 TARNDB KUP EXPEND PA 2L-323 198-251 501032028200 TARNDB KUP MWAG INJ ACTIVE 2L-325 198-209 501032027500 TARNDB KUP OIL PROD ACTIVE 2L-326 209-027 501032059700 TARNDB KUP OIL PROD ACTIVE 2L-327 207-008 501032054200 TARNDB KUP OIL PROD ACTIVE 2L-329 198-198 501032027200 TARNDB KUP PROD PA 2L-329A 198-225 501032027201 TARNDB KUP MWAG INJ ACTIVE 2L-330 207-128 501032055400 TARNDB KUP OIL PROD ACTIVE 2N-304PB1 201-130 501032038270 TARNDB KUP OIL EXPEND PA 2N-310 207-090 501032054900 TARNDB KUP MWAG INJ ACTIVE 2N-322 213-179-0 501032067800 TARNDB KUP OIL PROD ACTIVE BERMUDA 1 191-001 501032014900 NAK NAK OIL PROD PA • • TARN 2 197-011 501032024700 TARNDB KUP OIL EXPLOR PA J . I Vex United States Search legal information SEARCH Intelligent legal information (//vlex.com) +1-888-223-0621 ENTER WHY vLex PRODUCTS CONTENTS(//vlex.com/jurisdictions/US) ABOUT US SUPPORT Regulations (http://regulations.vlex.com) 40 CFR 147.102 - Aquifer exemptions. Updated to: July 2013 CONTENT snare snare Tweet(https://twitter.com/share) Title 40:Protection of Environment CHAPTER I: ENVIRONMENTAL PROTECTION AGENCY (CONTINUED) SUBCHAPTER D:WATER PROGRAMS(CONTINUED) PART 147:STATE,TRIBAL, AND EPA-ADMINISTERED UNDERGROUND INJECTION CONTROL PROGRAMS Subpart C:Alaska 147.102-Aquifer exemptions. (a)This section identifies any aquifers or their portions exempted in accordance with?? 144.7(b)and 146.4 of this chapter at the time of program promulgation.EPA may in the future exempt other aquifers or portions,according to applicable procedures,without codifying such exemptions in this section.An updated list of exemptions will be maintained in the Regional office. (b)The following aquifers are exempted in accordance with the provisions of??144.7(b) and 146.4 of this chapter for Class II injection activities only: (1)The portions of aquifers in the Kenai Peninsula,greater than the indicated depths below the ground surface,and described by a 1/4 mile area beyond and lying directly below the following oil and gas producing fields: (i)Swanson River Field?1700 feet. (ii)Beaver Creek Field?1650 feet. (iii)Kenai Gas Field?1300 feet. (2)The portion of aquifers beneath Cook Inlet described by a 1/4 mile area beyond and lying directly below the following oil and gas producing fields: (i)Granite Point. (ii)McArthur River Field. (iii)Middle Ground Shoal Field. 4/15/2015 (iv)Trading Bay Field. • • (3)The portions of aquifers on the North Slope described by a 1/4 mile area beyond and lying directly below the Kuparuk River Unit oil and gas producing field. Related searches: exempted limited partnership law 2003 revision of the cayman islands(http://topics.vlex.com/tags/exempted-limited-partnership-law-2003- revi si on-of-the-cayman-i slands-1140164) Other documents of interest: 47 CFR 1.316-Depositions upon written interrogatories—notice and preliminary procedure.(http://cfr.vlex.com/vid/316-depositions-interr... +1-888-223-0621 t f in (http:/,(latt(teKtistmliwkwOlheati ertt Constitutions Regulations U.S.Code(http://us-code.vlex.com) Case Law(http://case-law.vlex.com) (http://constitutions.vlex.com) (http://regulations.vlex.com) Tags(//topics.vlex.com/tags) All sources(//vlex.com/all_sources) Books and Journals(http://law- Contracts(http://forms.vlex.com) journals-boo ks.vl ex.co m) Payment methods Security paypal VISA ( er ,wr (https://sealinfo.thawte.com/thawtesplash? form_file=fdf/thawtesplash.fdf&dn=vlex.com&lang=en) Terms of use(http://us.vlex.com/terms-use) ©2015 vLex.com All rights reserved 4/15/2015 • SECTION 3 — FRESHWATER AQUIFERS 20 AAC 25.283(a)(3) / There are no freshwater aquifers or underground sources of drinking water within a one-half mile radius of the current or proposed wellbore trajectory. See conclusion of the Aquifer Exception Order No. 2 — Milne Point Unit. ` hich states "Those portions of freshwater aquifers lying directly below Mi - _ u qu.Ffy as exempt freshwater aquifers under'\0 AAC 25.440" • S SECTION 4 — PLAN FOR BASELINE WATER SAMPLING FOR WATER WELLS 20 AAC 25.283(a)(4) There are no water wells located within one-half mile of the current or proposed wellbore trajectory and fracturing interval. A water well sampling plan is not applicable. • SECTION 5 — DETAILED CEMENTING AND CASING INFORMATION 20 AAC 25.283(a)(5) All casing is cemented in accordance with 20 AAC 25.52(b) and tested in accordance with 20 AAC 25.030 (g) when completed. See Wellbore schematic for casing details. SECTION 6 — ASSESSMENT OF EACH CASING AND CEMENTING OPERATION TO BE PERFORMED TO CONSTRUCT OR REPAIR THE WELL 20 AAC 25.283(a)(6) Casing & Cement Assessments: 2L-328: 10 & 3/4" casing cement pump report on 2/22/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 11 ppg Deeperete lead cement and 12 ppg tail cement, displaced with 9.6 ppg mud. The plug bumped @ 1,039 psi and the floats were checked and they held. 41 bbls were dost during the job, but 79.9 bbls cement were returned at surface. 7 & 5/8" casing cement pump report on 3/9/2015 shows that the job was not pumped as designed. The cement job was pumped with 15.8ppg Gasblok cement, displaced with 9.7 ppg mud. The job was pumped with no returns, however the TOC estimation based on lift pressure showed adequate TOC, and was given approval from the state to proceed. The CAST-M/CBL log ran shows TOC at 11,612' or 313' TVD above the top of Bermuda. The plug bumped @ 1660 psi and the floats were checked and they held. Summary All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone penetrated by the well is isolated. Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. i i SECTION 7 — PRESSURE TEST INFORMATION AND PLANS TO PRESSURE-TEST CASINGS AND TUBINGS INSTALLED IN THE WELL 20 AAC 25.283(a)(7) On 2/25/2015 the 10 & 3/4" casing was pressure tested to 3000 psi for 30 mins. On 3/13/2015 the 7 & 5/8" casing was pressure tested to 3000 psi for 30 mins. The 7 & 5/8" casing and production packer will be pressure tested to 3500 psi for 30 mins The 3.5" tubing will be pressure tested to 3500 psi for 30 mins. • • SECTION 8 — PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE, WELLHEAD, BOPE AND TREATING HEAD 20 AAC 25.283(a)(8) Size Weight Grade API Burst API Collaspe 10 3/4" 45.5 L-80 5,210 psi 2,470 psi 7 5/8" 29.7 L-80 6,890 psi 4,790 psi 7 5/8" 39 TN-110 SS 12,620 psi 11,060 psi 3.5" 9.3 L-80 10,160 psi 10,540 psi • Stimulation Surface Rig-Up F Bleed r Tattle T0Tale Tank v n 2 6:1 • Minimum pressure rating on all surface 1101 1104 rtC8C1 treating lines 10,000 psi • Main treating line PRV is set to 95%of max treating pressure • IA parallel PRV set to 3500 psi 1'1`101./ • Frac pump trip pressure setting are staggered and set below main treating line PRV H • Tree saver used on all fracs rated for 15,000 .. h t psi. to g c 04:41 IL 2 c- 0 A►7 Y I v 4nJ1 dwnd c� Pop-Off Tank a d too Pump Truck Pap-Ott Tank N g C d •tit F-J J itu J I ray Purrp Iii-- i-- --1)3C "Sl-- Frac Pump Fra;:PurrpHD8(1— a - - Frac Pump I- LA_Pump (`Ai )8Q— —DaH"'71- Frac Pump • • Stimulation Tree Saver OPEN POSITION CLOSED POSITION (PRIOR TO MANDREL INSERTION) (MANDREL INSERTED) FRAt IRON CONNECTION n i � „,,_ 1 ; t ...„_.. • T,,„, , -:11-*” REMOTE OPERATED t ..,,TT�,,,. Y I MASTER VALVE iiiiiiimorim +T41111 0�ii MANUAL OPERATED *41t 1. MASTER VALVE moom,,,,,,,.... 0111111111111111111111111111 Fl tv / Stinger / Stinger {{{ MANDREL Iwally 2 '1-- \ I VENT x.!01!-VALVE t�``\ i; OPEN 111 ' III l I - w, kir VENT VALVE r.A��:N FLOW TEE AND * .- IIII* ��' WELLHEAD •.a ,'.... —MSI' VALVES — —4 i...._._._ •/4 %60... OPEN F,.,.., 11111 WELLHEAD VALVES 'y,:„, ` CLOSED ^^''N `' . 411 ttr Slik Y, ,,-: ”-^r+ '`OUAD PACKOFF j*r t ASSEMBLY IN la` "% ' PEACE IN TUBING ; I w' \Ig TURING ti r ra • The universal tool is rated for 15,000 psi and has 84" of stroke. • Tool ID 2.25" down 4 V2 tubing and 1.75" down 3 1/4 tubing. • Max rate with 2.25" mandrel is 60 bpm and with 1.75" mandrel 36 bpm • Tarn 2L-328 Sierra • Grass Roots Tonset Pilot Hole Horizontal Multi-Stage Frac'd Producer ConocoPhillips As-Built Schematic f 'CAMERON 4-%"tree,to •oint is 4-'/2'12.6#IBTM,crossed over(for frac equipment) lJ 1 " Existing Conductor; Bearden 4/7/2015 16"62.6#H-40 130' MD 3 7"Camco DS Nipple 2.875" 500'MD Fresh Water 13-1/2"Surface Hole DrilPlex 9.6 PPG 3'G"x 1"Camco KBMG Surface Casing: 10-3/4"45.5#L-80 Hydril 563 2,500' MD/2,283'TVD @ 51° 3'''A"x 1"Camco KBMG Gam000.6..I.op 3 Q5 (2,6 MD 3�iv LSND 9.6-10.0 PPG Tubing; Keep up with 3 r"x 1"Camco KBMG111-1 3-1/z'9.3#L-80 EUE8RD Dilution 4-1/2" 12.6#L-80 IBTM top joint to surface 9-7/8"Intermediate Hole 3%"x1"Camco KBMG G37 Top 91342 M©(4,413 . i . . . Top of cement @ 11,610'MD Baker CMU Sliding Sleeve CLOSED w/2.812"Camco'DS'Profile Down hole gauge-12,000'MD 3%"Camco D Nipple 2.75"nog , 3.5"x 7-5/8",Baker Premier Packer 12,>oo/MD 7-5/8"x 4-W Baker Flex Lock Liner hanger ZXP liner top packer w/RS tipple, 12,141'MD 1 Intermediate Casing Topset: 7-5/8"29.7#L-80&433'TN 110SS 39#—all Hydril 563 connections Top of Berm Seis 13,002'MD 5,446'TVD 12,266' MD/5,285'TVD @ 73° • _ ?aokers : :::6-1/2;.:ProEactlon:MoEa KEASH EELO`:`: 9 :.227 PPG 0 111 0 0 0 MI 0 .1111 NI gT4v!a F9t•Fe R►?eS . .•.•.•. . .•.•. .•.•.•.•.•.•.•. . ...•. . .•.•. t?tr3durxrtrtti Liner 89 ;:::::::: :: ....t�p9 ........ ........................ ....................... ..............4-.1�2: 72;6#:��80��TI�E: : ; : : ; : ; ; ; : :�:�:�: : (3;540 psig): : 12 141`:MD to:16 168 MD, . . . . . . . . . . . . . . . . . . . . . . . . 0 �#'\/D tci:5;529.T�1� � � . . . . . . . . . . . . . . . . . . . . 5.28 • ! SECTION 9 — DATA FOR FRACTURING ZONE AND CONFINING ZONES 20 AAC 25.283(a)(9) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that the fracturing zone, the Bermuda interval, is approximately 121' TVT (2,210' MD) thick at the heel and approximately 100' TVT at the toe of the well, with the top of the Bermuda starting at 12,509' MD/5,357' TVD. The Bermuda is a mix of laminated shale, siltstone, and sandstone with an estimated fracture pressure of—13.5 ppg. The confining zone of the C-37 to the T-3 is approximately 944' TVT (3,167' MD) thick, with the top of the C-37 starting at 9,342' MD/4,258' TVD. The C-37 to the T-3 is a mix of shale, siltstone, and sandstone lithologies with an estimated fracture pressure as high as —16 ppg. • • SECTION 10 — LOCATION, ORIENTATION AND A REPORT ON MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFINING ZONE 20 AAC 25.283(a)(10) The plat shows the location and orientation of each well that transects the confining zone. ConocoPhillips has formed the opinion, based on following assessments for each well and seismic, well, and other subsurface information currently available that none of these wells will interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. Casing & Cement assessments for all wells that transect the confining zone: 2L-309: 3 1/2" casing cement pump report on 2/20/2006 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement. No discussion of returns on the job report, however 6-8 bbls v. cement was circulated to surface after liner hanger was set. The plug bumped @ 3,200 psi and a flow test showed no flow indicating the floats held. 2L-317: This main wellbore did not have enough pay and was plugged back during original drilling and sidetracked. 2L-317A: 3 1/2" casing cement pump report on 12/22/2000 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 13 ppg lead and 15.8ppg Class G tail cement, displaced with 8.6 ppg seawater. No discussion of returns on the job report. The plug bumped the floats were checked and they held. 2L-321: 5 1/2" x 3 1/2" casing cement pump report on 1/10/1999 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with 8.6 ppg seawater. Initially returns were only at 50%, final rate had 90% returns to surface. The plug bumped and the floats were checked and they held. In 2007 a casing leak from 7694-8415 was discovered and was squeezed with 95 bbls 15.8ppg Class G cement. The squeeze was not drilled out until 11/6/2008, and it was discovered to be leaking. An uncemented 4 '/2" scab liner was run from 11,440' to surface. 2L-330: 3 1/2" casing cement pump report on 11/30/2007 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Gas-Block cement, displaced with drilling mud. Full returns were seen throughout the displacement. The plug bumped to 2700psi the floats were checked and they held. 5-6 bbls of cement was circulated to surface after the liner was set. 2N-304PB1: This wellbore was plugged back during original drilling operations and sidetracked on 8/8/2001. 2N-310: 4 1/2" casing cement pump report on 11/30/2007 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement displaced with 11.4ppg drilling mud. No discussion of returns on the job report, however 2 bbls cement was circulated to surface after liner hanger was set. The plug bumped @ 2032 psi and the floats held. Bermuda 1: This was an ice road exploratory well. It was P&A'd on 2/2/1991 with 170 sx Class G balanced plug, 200 sx Class G balanced plug, set a cement retainer and squeezed 50sx Class G below with 25sx on top, and pumped a 90 sx Class G surface plug. V • • SECTION 11 — LOCATION OF, ORIENTATION OF AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE CONFINING ZONES 20 AAC 25.283(a)(11) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that there is no known fault or fracture that transects the confining zone within one half mile radius of the wellbore trajectory for 2L-328. S • L 2L • D8 Tarn P4 Kuparuk River Unit 2N Legend ---Proposed Well Trajectory Proposed Open Section 1/2 Mile Open Section Radius Participating Area ri Tarn PA oCPA I Operated Units REFERENCES: Well Data:ConocoPhillips Alaska Wells Database ATDB ConocoPhi I I i ps Surface Facilities:North Slope 6K Survey 7/25/12 Published 3/20/13 Alaska Statewide Oil&Gas Leases 1/12/2015 Alaska,Inc. Water Well Dalai DNR-Groundwater Division >No Potable Water Wells are in the Kuparuk River Unit. N 2L-328 Plat Anaysis >No Potable Water Aquifers are in the Kuparuk River Unit Faults 3/17/2015 05 0 Mies 3020Fraclease m.CSR 2/42015 • • SECTION 12 — PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) 2L-328 was completed in 2015 as horizontal producer in the Bermuda formation. The well will be completed with 3.5" tubing and a 4.5" liner with ball actuated sliding sleeves. After the 1st stage we will drop a ball (progressively getting larger) after each remaining stage, these balls will provide isolation from the previous stage and allow us to move from the toe of the well towards the heel. Proposed Procedure: Schlumberger Pumping Services: (Bermuda Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre-frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 24 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100° F seawater (approx. 10484 bbls are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU Stinger Tree Saver Equipment and SLB Frac Equipment. 7. PT Surface lines to 9,500 psi using a Pressure test fluid. 8. Test IA Pop off system 6 ensure lines are clear and all components are functioning properly. 9. Set popoff valve on OA to 1000psi and test. 10. Pressure up and maintain 2,500 psi on the IA. We can ramp up to 3,000 then 3,500 as treating pressures allow-7- 11. llow.11. Pressure up tubing to probably around 4500 psi to shift open P-sleeve. Exact shift pressures will be determined once P-sleeve is ran. 12. Displace tubing with 27# linear gel. 13. SD for 5 minutes. 14. Pump the 171 bbl breakdown stage (27# linear gel, WF127) according to the attached excel SLB pump schedule. Bring pumps up to maximum rate of 20 BPM as quick as possible, pressure permitting. Slowly increase annulus pressure from 2,500 psi to 3,500 psi as the tubing pressures up. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 15. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 16. Pump the Frac job by following schedule @ 20bpm with a maximum expected treating pressure of 6610 psi. 17. RDMO SLB Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 18. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). • s ATTACHMENT 1:PUMP SCHEDULE MAW Slurry Rale 20 Highest Pump Trip Proppant Density 2.11 Well Name 2L428 AFE Nitrogen PRV Annulus Pressure Fluid Type YF727ST Proppant Used 1020 CarboLlte STEP STAGE COMMENTS FLUID PUMP CF DIRTY VOLUME DIRTY VOLUME PROPPANT CLEAN VOLUME Clean Encaps. a 6 TYPE RATE RATE STAGE CUM STAGE CUM STAGE CUM 512E GROSS CUM Pulse Breaker (BPMI WPM) (BBL) (BBL) (GAL) IGAL) ILOS) (LOS) 1681) (BBL) Iseel IAssall t Injection test WF127 20 20.0 171 171 7187 7187 171 171 8.0 Hard shutdown;monitor pressure. 0.0 2 Pad 75127ST 20 20.0 80 251 3360 10547 90 251 8.0 3 1 Sand YF127ST 20 19.2 50 301 2100 12647 2011 2011 sono 5areoum. 48 299 0.0 4 Spacer YF127ST 20 20.0 80 381 3360 16007 80 379 8.0 5 DIsplacemerd WF127 20 20.0 171 552 7187 23194 171 550 8.0 Hard shutdown;monitor pressure. FLUID PUMP cF DIRTY VOLUME DIRTY VOLUME PROPPANT CLEAN VOLUME Clean Encaps. STEP ST GE AVERAGE COMMENTS TYPE RATE RATE STAGE CUM STAGE CUM STAGE CUM SIZE GROSS CUM Pulse Breaker O PPA )SPM) (BPM) (BBL) (BBL) (GAL) (GAL) (LBS) (LBS) (BBL) (BBL) (sec) (WMg0l) 6 PAD 75727ST 20 20.0 400 952 16800 39994 0 2011 0 400 950 8.0 7 0.6 FLAT 7512765 20 19.6 40 992 1680 41674 822 2,833 39 989 8.0 8 1 PULSES 7512785 20 19.2 80 1072 3380 45034 1610 4,443 ono care,. 77 1066 10 8.0 9 2 PULSED 75127ST 20 18.4 80 1152 3360 48394 3090 7,533 tanot5,USAG 73 1139 10 8.0 10 3 PULSED 75127ST 20 17.7 80 7232 3360 51754 4455 11,988 ma CarboL. 71 1210 10 10.0 11 4 PULSED 75127ST 20 17.0 100 1332 4200 55954 7149 19,137 Iwo Carbollte85 1295 10 10.0 12 5 PULSED 75127ST 20 18.4 140 7472 5880 61834 12061 31,198 ono CarSouer 115 1410 10 10.0 13 6 PULSED 75127ST 20 15.8 180 1652 7560 69394 17963 49,161 vino came.. 142 1552 10 10.0 14 6 TAIL-IN 75727ST 20 15.8 40 1692 1680 71074 7965 57,126 lama 00000ur 32 1583 10.0 15 Ball 1.51' DISPLACE YF127ST 20 20.0 10 1702 420 71494 0 57,126 10 1593 8.0 18 PAD 75127S1 20 20.0 400 2102 16800 88294 0 57,126 400 1993 8.0 17 0.5 FLAT 75127ST 20 19.6 40 2142 1680 89974 822 57,948 tono...Lite 39 2033 , 8.0 18 i PULSED YF1275T 20 79.2 80 2222 3360 93334 1610 59,558 tem car.. 77 2109 10 8.0 59 2 PULSED 7F12787 20 184 80 2302 3360 96694 3090 62,648 73 2183 10 8.0 20 3 PULSED 75127ST 20 17.7 80 2382 3360 100054 4455 67.103 15.120 CarboLite 71 2253 10 10.0 21 4 PULSED 75127ST 20 17.0 105 2482 4200 104254 7149 74,252 ono caro.E. 85 2338 10 10.0 22 5 PULSED 7512781 20 16.4 140 2622 5880 110134 12061 86,313 16120 Car111.11e115 2453 10 10.0 23 6 PULSED 7F12787 20 15.8 180 2802 7560 117694 17963 104,276 142 2595 10 10.0 24 6 TAIL-IN 7512761 20 15.8 40 2842 1680 119374 7965 112 241 16, .lA 32 2627 10.0 25 Ball 1.635" DISPLACE 7572787 20 20.0 10 2852 420 119794 0 112,241 10 2637 8.0 26 PAD YF127ST 20 20.0 350 3202 14700 134494 0 112,241 350 2987 8.0 27 0.5 FLAT 75127ST 20 19.6 50 3252 2100 136594 1027 113,268 -,e 49 3036 8.0 28 1 PULSED YF127ST 20 19.2 100 3352 4200 140794 2012 115,281 96 3131 10 8.0 29 2 PULSED 75127ST 20 18.4 100 3452 4200 144994 3862 119,143 1617 92 3223 10 8.0 30 3 PULSED YF127ST 20 17.7 100 3552 4200 149194 5569 124,712 1512 88 3312 10 10.0 31 4 PULSED 7F127S1 20 17.0 120 3672 5040 154234 8578 133,290 102 3414 10 10.0 32 5 PULSED 75127ST 20 164 180 3852 7560 161794 15507 148,797 147 3561 10 10.0 33 6 PULSED YF127ST 20 15.8 233 4088 9799 171592 23286 172,083 184 3745 10 10.0 34 6 TA1L4N Y57275T 20 15.8 40 4126 1680 173272 7985 180,048 _ 1,e0 88 32 3777 10.0 35 Ball 1.76" DISPLACE 75127ST 20 20.0 10 4138 420 173692 0 180 048 10 3787 8.0 35 PAD 75127ST 20 200 350 4488 14700 188392 0 180.048 350 4137 8.0 37 0.5 FLAT 75127ST 20 19.6 50 4536 2100 190492 1027 181,075 16,0 CarIxoLite49 4186 8.0 38 1 PULSED 75127ST 20 19.2 100 4636 4200 194892 2012 183,087 10120 Car1.1.11e96 4282 10 8.0 39 2 PULSED 7512787 20 18.4 100 4736 4200 198892 3862 186,949 16,0 earlaeLlle92 4373 10 8.0 40 3 PULSED 751278T 20 17.7 100 4836 4200 203092 5569 192,516 16120C-r,Lile 88 4462 10 10.0 41 4 PULSED 75127ST 20 17.0 120 4956 5040 208132 8578 201,096 102 4584 10 10.0 42 5 PULSED Y512781 20 16.4 180 5136 7560 215692 15507 216,503 a .90 147 4711 10 10.0 43 6 PULSED 75127S1 20 15.8 233 5389 9799 225491 23256 239,889 ,Lite 184 4895 10 10.0 44 6 TAIL-IN YF127ST 20 15.8 40 5409 1680 227171 7965 247,855 Lite 32 4927 10.0 80 Ball 1.885" DISPLACE 75127ST 20 20 10 5419 420 227591 0 247,855 10 4937 8.0 El PAD YF127ST 20 20.0 450 5869 18900 246491 0 247,855 450 5387 8.0 62 0.S FLAT 75127ST 20 19.6 - 90 5929 2520 249011 1233 249,088 59 5448 8.0 63 1 PULSED 75127ST 20 19.2 73 6002 3079 252090 1475 250,56370 5516 10 8.0 84 2 PULSED 75127ST 20 184 80 6082 3360 255450 3090 253,653 73 5589 10 8.0 65 3 PULSED Y512767 20 17.7 87 6169 3641 259081 4826 258,479 ,i 77 5686 10 10.0 66 4 PULSED 75127ST 20 170 93 6262 3919 263010 6672 265,151 1 e.,F C.,reoLlta 79 5745 10 10.0 67 5 PULSED 7512787 20 16.4 111 6375 4759 267768 9764 274,915 ono car.L. 93 5838 10 10.0 68 6 PULSED 75127ST 20 15.8 127 6502 5321 273090 12641 287,556 16n0 0055.1,. 100 5938 - 10 10.0 89 7 PULSED 7F727ST 20 153 140 6642 5880 278970 15754 303,310 1620 Cobol. 107 6045 10 10.0 70 8 PULSED 75127ST 20 14.8 140 6782 5880 284850 17421 320,731 jimaiiia., 103 6148 10 10.0 71 8 TAIL-IN 75127ST 20 14.8 40 6822 1680 288530 9926 330,657 30 6178 10.0 72 Ball 1.948" DISPLACE 75127ST 20 20.0 10 6832 420 286950 0 330,657 10 6188 8.0 73 PAD 75127S1 20 20.0 450 7282 18900 305850 0 330,657 450 6638 8.0 74 0.5 FLAT 7512751 20 19.6 60 7342 2520 308370 1233 331,890 16/20 CarboLite 59 8697 8.0 75 1 PULSED 7512787 20 19.2 73 7415 3079 311448 1475 333,385 16120 CarboL. 70 8767 10 8.0 15 2 PULSED 7F727ST 20 18.4 80 7495 3360 314808 3090 336,455 16120 Garbed,. 73 6840 10 8.0 17 3 PULSED 75727ST 20 17.7 87 7582 3641 318450 4826 341,261 Imo car... 77 6917 10 10.0 76 4 PULSED 75127ST 20 17.0 93 7675 3919 322368 6672 347,953 teno carb.t. 79 6996 10 10.0 70 5 PULSED 75127ST 20 16.4 113 7789 4759 327127 9784 357,717 'Eno Car.L. 93 7089 10 10.0 80 6 PULSED 75127ST 20 15.8 127 7915 5321 332448 12641 370.358 10120 cmmum100 7189 10 10.0 81 7 PULSED 7512787 20 15.3 140 0055 5880 338328 15754 386,112 16120 cemoLw107 7298 10 10.0 Bx 8 PULSED YF12761 20 14.8 140 8195 5880 344208 17421 403,533 ...1.. 103 7399 10 10.0 83 8 TAIL.IN YF72701 20 14.8 40 8235 1680 345888 9926 413,459 10120 500904.00 30 7429 10.0 ed Ball 2" DISPLACE Y712781 20 20.0 8235 0 345888 0 413,459 0 7429 8.0 05 PAD 7512781 20 20.0 450 8685 18900 364788 0 413,459 450 7879 8.0 68 0.5 FLAT 75127ST 20 19.6 60 8745 2520 367308 1233 414,692 15220 Catbellte 59 7938 8.0 87 1 PULSED 7F12781 20 19.2 73 8819 3079 370387 1475 416,167 18120 001e.ul. 70 8008 10 8.0 88 2 PULSED 751278T 20 18.4 80 8899 3380 373747 3090 419,257 161200e0e.L100 73 8081 10 8.0 Se 3 PULSED 75127ST 20 17.7 87 8986 3641 377388 4826 424,083 Carlap111. 77 8158 10 10.0 90 4 PULSED 7512781 20 17.0 93 9079 3919 381307 6872 430,755 10120 CarboLIM79 8237 10 10.0 91 5 PULSED 751278T 20 16.4 113 9192 4759 386065 9764 440,519 Ism CarboLlle93 8330 10 10.0 92 6 PULSED 7F727ST 20 15.8 127 9319 5321 391387 12641 453,160 18,0 careoLl. 100 8430 10 10.0 93 7 PULSED 75127ST 20 15.3 140 9458 5880 397267 15754 468,914 16/20 CarboLlte 107 8537 10 10.0 94 8 PULSED YF127ST 20 14.8 140 9599 5880 403147 17421 486,335 'Eno carboon 103 8640 10 10.0 95 8 TAIL-IN 7F727ST 20 14.8 40 9639 1680 404827 9926 496,261 1e120001e0u0 30 8670 10.0 108 Ball 2.010" DISPLACE 7512701 20 20 10 9649 420 405247 0 498,261 10 8880 8.0 107 PAD 7F127ST 20 20.0 450 10099 , 18900 424147 0 496,261 450 9130 8.0 108 0.5 FLAT YF12781 20 19.6 60 10159 2520 426667 1233 497,494 59 9189 8.0 109 1 PULSED 75127ST 20 19.2 73 10232 3079 429745 1475 498,969 ata CarSOLIN 70 9259 10 8.0 110 2 PULSED 75127ST 20 184 80 10312 3360 433105 3090 502,059 59186508.1,. 73 9332 10 8.0 111 3 PULSED 751278T 20 17.7 87 10399 3641 436747 4826 506,885 MOO Catheldle 77 9409 10 10.0 112 4 PULSED 75127ST 20 17.0 93 10492 3919 440665 6672 513,557 79 9488 10 10.0 113 5 PULSED 75127ST 20 16.4 113 10605 4759 445424 9764 523,321 93 9581 10 10.0 114 6 PULSED 7F127ST 20 15.8 127 10732 5321 450745 12641 535,962 100 9681 10 10.0 115 7 PULSED 7512781 20 15.3 140 10872 5880 456625 15754 551,718 ono carnsute 107 9788 10 10.0 118 6 PULSED 75127ST 20 14.8 140 11012 5880 462505 17421 569,137 ono carboub 103 9891 10 10.0 117 8 TAIL-19 75127ST 20 14.8 40 11052 1680 464185 9926 579,064 1e000016096 30 9921 10.0 118 FLUSH 75727ST 20 20.0 56 11108 2370 466556 56 9977 16.0 119 FLUSH WF127 20 20.0 56 11165 2370 468926 56 10034 16.0 120 FLUSH Free0e50rOt208 15 15.0 19 11184 804 46972919 10053 TOTALS 11184 579064 10053 8D and 060016 ISN S 5 016 SIP. WATER VOL FLUSH INFORMATION WFIJ AND TREATING PRESSURE INFORMATIQft MODEI AND FRAC ORIENTATION INFORMATION DUaFRAC= 550 bbIs VOL TO TOP PORT 01135.1 ISIP GRADIENT= 0.76 BHP=4152 psi TVD Ped.H,%= MAIN JOB= 9494 bb1s Extra 450 bbls -UNSFRFI USH03,0 FLUID SG= 1.030 ERIC=4663 psi TOTAL JOB= 10034 bb1s FLUSH VOL=132 FRICTION LOSS= 0.2798 a PERF ERIC=0300 psi 10484 bb1s -wtn contingency MD TO Dag Tail= 13114 -NYS HEAD=2440 psi Angle Through Parts GENERAL JOB INFO TVD BTM SLEEVE- 6469 EST.MAO WHIM 6675 psi Wail Azimuth OMod87 TANKS REQUIRED PIPE TOE(511).6.8 MD FIRST SLEEVE= 16666 r0 23.30 a=450 661 per tank pump.° PAD/SLURRY RATIO Stage 35% Slagae 32% Stage2 35% Stage7 32% TOTALS FOR A STAGF3 Stage 327% Stage8 32% UPPER TUBING SCE= 9.5000 0.0007 0e10.11 Pon, Slage4 27% Stage MIDDLE TUBWGSEE= 661021 Water UMW NW Stage 532% Slags 10 LOWER TUBWG SCE= eelsM Reservoir Pressure=3400 %link gold 9691 bbla Stage Porta MO DISp1aci LENGTH MIDDLE TBG= Pemwa605s- Linear gunk 999 b61s name ft volume Seat S95 LENGTH LONER TBG= Temperature= 160 Prappanl 679,064 lb stage 16066 168.1 b51s Peri Sub CASING SEE= 4.5000 0.4154 bbb.M Diesel 57 bbls Stage 2 16310 1627 OMs 1.61 J475 4,242 lb Stage 9 15963 157.9 Ws 1.605 Pump time 09.19.16 Mumm:as Stage 15697 151.0 bb1s 1.700 Stage 6 18211 146.0 Ms 1.886 J475 4,242 lbs Stage 6 14064 140.6 We 1.848 LOSS 044 gel Stage 7 14498 195.1 600 2010 F103 422 gel J692 2,277 gal M002 TBD lbs 8682 2,660 gal 1 J622 7.190 lbs 16-315 • . Client: ConocoPhillips Alaska Inc. Schlnberger Well: 2L-328 Basin/Field: Colville-Prudhoe Basin/ Tarn State: Alaska County/Parish: North Slope Borough Case: Disclosure Type: Pre-Job Well Completed: 4/4/2015 Date Prepared: 3/16/2015 2:37 PM Report ID: RPT-35605 Fluid Name&Volume Additive Additive Description Concentration Volume B882 Guar Polymer Slurry 6.3 Gal/1000 Gal 2,720.0 Gal D047 AntiFoam Agent 0.1 Gal/1000 Gal 25.0 Gal F103 Surfactant 1 Gal/1000 Gal 440.0 Gal J218 Breaker 0.1 Lb/1000 Gal 25.0 Lb J475 Breaker 10.1 Lb/1000 Gal 4,360.0 Lb YF127ST:WF127 432,768 Gal J532 Crosslinker 5.4 Gal/1000 Gal 2,350.0 Gal J622 Low Temperature Fiber J622 17.4 Lb/1000 Gal 7,550.0 Lb L065 Scale Inhibitor 2 Gal/1000 Gal 880.0 Gal M002 Additive 0.7 Lb/1000 Gal 310.0 Lb M275 Bactericide 0.6 Lb/1000 Gal 250.0 Lb S522-1620 Propping Agent varied concentrations 605,000.0 Lb The total volume listed in the tables above represents the summation of water and additives. Water is supplied by client. CAS Number Chemical Name Mass Fraction - Water(Including Mix Water Supplied by Client)* -84 % 66402-68-4 Ceramic materials and wares,chemicals "'14 % 64742-47-8 Distillates(petroleum),hydrotreated light <1 % 9000-30-0 Guar gum <1 % 9051-89-2 Polylactide resin <1 % 56-81-5 1,2,3-Propanetriol <1 % 7727-54-0 Diammonium peroxidisulphate <0.1 % 1303-96-4 Sodium tetraborate decahydrate <0.1 % 107-21-1 Ethylene glycol <0.1 % 129898-01-7 2-Propenoic acid,polymer with sodium phosphinate <0.1 % 25038-72-6 Vinylidene chloride/methylacrylate copolymer <0.1 % 111-76-2 2-butoxyethanol <0.1 % 67-63-0 Propan-2-ol <0.1 % 7647-14-5 Sodium chloride(impurity) <0.01 % 68131-39-5 , C12-15 alcohol ethyoxylated <0.01 % 34398-01-1(3E0) Linear C11 alcohol ethoxylate(3eo) <0.01 % 34398-01-1(7E0) Linear C11 alcohol ethoxylate(7eo) <0.01 % 68953-58-2Dihydrogenated tallow dimethyl ammonium bentonite <0.01 % 1310-73-2 Sodium hydroxide(impurity) <0.01 % 25322-69-4 Polypropylene glycol <0.01 % 7631-86-9 Silicon Dioxide <0.01 % 10043-52-4 Calcium Chloride <0.01 % 91053-39-3 Diatomaceous earth,calcined <0.01 % 108-32-7 4-methyl-1,3-dioxolan-2-one <0.01 % 10377-60-3 Magnesium nitrate <0.001 % 14807-96-6 Magnesium silicate hydrate(talc) <0.001 % 111-46-6 2,2"-oxydiethanol(impurity) <0.001 % 26172-55-4 5-chloro-2-methyl-2h-isothiazolol-3-one <0.001 % 7786-30-3 Magnesium chloride <0.001 % 68153-30-0Amine treated smectite clay <0.001 % 9002-84-0 poly(tetrafluoroethylene) <0.001 % 72283-36-4 Oxirane,2-methyl-,polymer with oxirane,mono-(9Z)-9-octadecenoate,methyl ether <0.001 % 7447-40-7 Potassium chloride(impurity) <0.001 % 39322-78-6 Phosphoric acid,dodecyl ester,potassium salt <0.001 % 9016-88-0 1,4-Benzenedicarboxylic acid,polymer with 1,2-ethanediol and a-hydro-w-hydroxypoly <0.001 % (oxy-1,2-ethanediyl) 2682-20-4 2-methyl-2h-isothiazol-3-one <0.001 % 14808-60-7 Crystalline silica(impurity) <0.0001 % 14464-46-1 Cristobalite <0.0001 % 112-53-8 C12 fatty alcohol <0.0001 % 0 Schlumberger 2015.Used by ConocoPhillips Alaska Inc.by permission. Page:1/2 • • Client: ConocoPhillips Alaska Inc. Scblaberger Well: CL-328 Basin/Field: Colville Prudhoe Basin/ Tarn State: Alaska County/Parish: North Slope Borough Case: Disclosure Type: Pre-Job Well Completed: 4/4/2015 Date Prepared: 3/16/2015 2:37 PM Report ID: RPT-35605 CAS Number Chemical Name Mass Fraction 9043-30-5 C13 alcohol ethoxylate <0.00001 52-51-7 2-bromo-2-nitropropane-1,3-diol <0.00001 Total 100% *Mix water is supplied by the client.Schlumberger has performed no analysis of the water and cannot provide a breakdown of components that may have been added to the water by third-parties. "�Yr v 0 Schlumberger 2015.Used by ConocoPhillips Alaska Inc.by permission. Page:2/2 • • o 0) co 1-?' :4= -5 2 -8 COO -o 2(C-0) L .) LL cc CO CN Cr) J CN • • c. 6Q o 0 0 0 0 0 0 0 0 o 0 0 O c a. o Ln o 0 0 0 0 0 0 0 0 0 CL V d_ O O N- N M 4 O (O --- O O O 0 0 0 0 0 0 0 0 0 0 NNNNNNNNNN t CO CD CD CD O O CO CO CO CD N CD a) N N Cll Cl.) 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A' 0) — U rn > U J _ = I — 4_, 73 -0 8 8 ai 0 CD > E w -a H O CaO Q• C6 I—p MQ W ", 4., W . ■ CZ O rl 8 0%0 fa) ,i2L_ :co _c_5, 2 2 E.) 46 cs) 0_ L N Q 7 Q. _ (n O C to To Q. i 0 -0 0) " (6 L-- CO a) ° o > E O c .o � � — L a W Q •— CU N CU as cn -c a) = •— o -o • — ocncna) oo e H E E E ._ 0 • • SECTION 13 — POST-FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN 20 AAC 25.283(a)(13) Flowback will be initiated through a third party flowback vendor until the fluids clean up at which time it will be turned over to production. (Initial flowback fluids to be taken to a disposal well until they are clean enough for production.) Pio 2/4- / gq • Loepp, Victoria T (DOA) From: Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent: Thursday,April 02,2015 2:55 PM To: Loepp,Victoria T(DOA) Cc: Bearden,J Daniel; Klem,Adam Subject: PTD#214-189 2L-328 Update Follow Up Flag: Follow up Flag Status: Flagged Victoria,just a quick update on our status. We began running our liner last night,and just began running into the open hole at 12,250' MD about an hour ago. A full bottoms up at the shoe indicated that our mud is in good condition and we have very little to no sag. If all goes well,we expect to have our liner on bottom this eventing. We will then set our liner hanger and packer and swap to seawater above it. After a 30 minute no flow check to confirm the liner as a barrier,we will pull out of hole laying down our drill pipe. We estimate we will be ready to run the Cast-M/CBL log sometime early tomorrow afternoon. As soon as we have those results I will send them to you for your review. Please let me know if you have any questions or would like any more information. Thanks, Mike Callahan Drilling Engineer ConocoPhillips Alaska (907)231-2176 1 • • QTc ?14--1g9 Loepp, Victoria T (DOA) From: Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent Monday, March 30, 2015 7:05 AM To: Loepp,Victoria T(DOA) Cc: Schwartz, Guy L(DOA); Bettis, Patricia K(DOA);Wallace, Chris D (DOA) Subject: 2L-328 Update Follow Up Flag: Follow up Flag Status: Flagged Victoria,just wanted to update you on our status. Over the weekend we made it to 13,900' MD on our cleanout run, roughly 1,700'outside of our intermediate shoe. At that point we attempted to circulate the well clean before continuing to TD, but were unable to circulate without losses. We eventually had to pull up to "7,400' MD to regain full circulation. Our mud weight in returns got as high as 14.2 ppg(from a base of 12.6 ppg), indicating significant barite sag. At this time we are on our way back to TD to complete the cleanout run, reaming in the hole at—14,000' MD with full returns. My best guess for timing going forward is to hopefully finish our cleanout run and fluid swap in the next 24 hours,then be ready to run liner starting late tomorrow night. If all goes well we will likely be running the Cast-M/CBL log sometime Thursday. I will keep you updated with any further changes,and be in touch as soon as we have the log results to go over. Thanks, Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office:(907)263-4180 Cell: (907)231-2176 2 ra/ ,, • 11, Loepp, Victoria T (DOA) From: Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent: Friday, March 27, 2015 3:19 PM To: Loepp,Victoria T(DOA) Cc: Schwartz, Guy L(DOA); Bettis, Patricia K(DOA);Wallace, Chris D (DOA) Subject: RE: PTD#214-189 2L-328 Request for Permission to Frac/ Produce Follow Up Flag: Follow up Flag Status: Flagged Thank you Victoria. We appreciate the quick response and allowing us to proceed. I will keep you up to date on the status of the well and path forward. We are currently running in the hole for our cleanout run at about 10,000' MD. It will take us some time to work down to bottom, clean up the hole, and perform our fluid swap to the NaBr based fluid. Best estimate for timing is that we will begin running liner sometime late tomorrow night or early Sunday. We hope to be running the Cast-M/CBL log sometime Monday if all goes well. As soon as we have the log results we will consult with you before proceeding any further. I will also make sure that a flowback gas sample is obtained and the results sent to you. Regards, Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office: (907) 263-4180 Cell: (907) 231-2176 From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Friday, March 27, 2015 3:12 PM To: Callahan, Mike S Cc: Schwartz, Guy L (DOA); Bettis, Patricia K(DOA); Wallace, Chris D (DOA) Subject: [EXTERNAL]RE: PTD# 214-189 2L-328 Request for Permission to Frac/ Produce Mike, In response to your requests,you have approval to proceed as follows: 1. Run the Cast-M/CBL combo log and review log and interpretation with the AOGCC.The liner may be run prior to running the CBL log. 2. If adequate good quality cement is present, approval to fracture stimulate the well will be granted. 3. Approval to produce the well with OA monitoring will be granted subsequent to CBL results. We also request that a flowback gas sample be obtained and analyzed. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer 3 State of Alaska • • Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(o.alaska.qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Callahan, Mike S [ vlike.Callahan@conocophillips.cor ] Sent: Thursday, March 26, 2015 3:48 PM To: Loepp, Victoria T(DOA); Bettis, Patricia K(DOA) Cc: Bearden, J Daniel; Kurnia, Dadang; Hayden, Philip; Klem, Adam; Umlauf, Kelly K Subject: PTD# 214-189 2L-328 Request for Permission to Frac/ Produce Victoria/Patricia, Thank you again for your time this afternoon. As we discussed, here are our requests and a proposed path forward on 2L-328. A copy of the presentation we went through today is also attached. Requests: • Would a Cast-M/CBL combo log showing good quality cement across the T-4.1 interval be adequate for you to approve a waiver to proceed with frac'ing this well? • Is our plan to run liner prior to performing the log acceptable? o This will forfeit roughly 100-150'of the log(depending on liner hanger set depth), although the bottom 87'will likely be compromised anyways due to the presence of drilled out cement left inside the intermediate shoe track. However, it gives us the safest path forward to secure the reservoir. The alternative would be setting a plug above the reservoir and running the log,then pulling the plug before running liner. This would add roughly 2 days of the hole being open and create a potentially dangerous pressure scenario if a gas bubble migrates below the plug. • Would we be approved to put the well on production with constant OA pressure monitoring in place? Proposed path forward: • Currently we are pulling out of hole with our remaining 4-1/2" liner with the well static. • After laying down the liner,we will perform a cleanout run to TD of the well (16,168' MD) and swap our fluid from our Kla-Shield (NaCl based) drilling fluid to a similar NaBr based fluid. This fluid will have a much lower degree of Barite sag,which is what we believe has caused the lighter mud column and well control issues to date. We will then pull out of hole and lay down our cleanout assembly. • We would then like to run our 4-1/2" liner to secure the open hole and give us a permanent barrier to the overpressured ("'12.5-12.6 ppg) reservoir. We view this as the safest option to eliminate any additional well control scenarios. • After running closed-toe liner we would swap the well above the liner top to seawater(giving us the cleanest possible fluid for logging). • We would then run a Cast-M/CBL combo log on e-line from the top of the liner(planned to be set at—12,116' MD, but could be moved down as low as 12,166, 100' above the intermediate shoe)to the top of cement at 4 • 11,612' MD. The particular point of interest on this log would be across the T-4.1 shale,from 11,860' MD— 11,940' MD,which is a known barrier above the Bermuda formation. We believe good cement across this zone will create an adequate barrier for all potential pressure scenarios that could be encountered during the planned frac job. • If the Cast-M/CBL log shows good quality cement across the T-4.1 interval,we would like to proceed with running of our upper completion and moving Doyon 25 off the well,then proceeding with the planned frac job. Please let us know if you have any questions or would like any further information. Regards, Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office: (907) 263-4180 Cell: (907)231-2176 5 0 • co 73 N.)Nrim) N --1 r- 6) 1 cN o cri CD -in ./•.J = CD C Q CD n 0.0 ea R-' Dm CD _. mom _. iii 13 • • 11.0 �V .m....�.7:.�::::::::.S L.i _1 ry o :::. T. L� eye+ ..:. :::.:47:-......... :.:_.'af:::. • -4 .,,- .110 :j R 88 0 i ...' i . i 0 }jilt ',. 1#1 I 1- CD ................ . y li ua/ , oi. n g 3 2Y� a 0 — w i'_ A e .. [l C A W H _ _.v tda a 2� r9. tea03 --,1?C "..-. 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'-- .. -''--" -.,-.. ..• •,•., . \ ...\. (In . ..,.., -7.*-''''''''''' . .."...,"'''''''''''''''-... ',7...''''''''''•''''''-' '.r... ......,_. ' 1...47'."''.41*- '-,, -7=r.....-*-^. - -..i- -,=.-m.-7:7 . •-.1,..,e,.., 447*--- < •.-.7 .1=.......-„--=,. .r.._._,_....._ ,.„,„.:,. ,....,____ ,. .. . .. idli‘owillittallove , 41101101011Wili , gPii • IV 10.401~,0411 r..4.40it • - , ^ .COIOW , , 11;Zeair.._. '' . .1"'.. ."11/ AM. • . , 71"1"1 CD 0 OM.• CI) i 1 i I L , , _ c '-'- '-k--- _,-----.1-- ..--- .,-, L S S Pro Loepp, Victoria T (DOA) From: Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent: Tuesday, March 24, 2015 4:04 PM To: Loepp, Victoria T (DOA) Subject: RE: PTD#214-189 2L-328 Notification of BOPE Use Follow Up Flag: Follow up Flag Status: Flagged Victoria,we were unable to regain circulation through the toe of the liner(a frac sleeve shallower in the string shifted open, leaving that as our circulation point). We are currently stripping in the hole at "10,600' MD, approximately 1,600' from our intermediate casing shoe. Our plan is to circulate around kill weight fluid at that depth and then perform the BOP test once the well is confirmed to be static. Likely timing for that test is tomorrow morning sometime,depending on how long the next couple of steps take. The company man on the rig(Lee Martin just switched in today on days) has been keeping in touch with Jeff Jones on test timing, I will make sure he continues to do so. Please let me know if you need any more information. Thanks, Mike From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Tuesday, March 24, 2015 3:56 PM To: Callahan, Mike S Subject: [EXTERNAL]RE: PTD #214-189 2L-328 Notification of BOPE Use Mike, What is the current status of the BOP testing timing? Please be aware of Guidance Bulletin No 06-01 which requires that BOPE components used must be function pressure tested to the required pressure before the next wellbore entry. Thanx, Victoria From: Callahan, Mike S [mailto:Mike.Callahan@@conocophillios.com] Sent: Monday, March 23, 2015 4:04 PM To: DOA AOGCC Prudhoe Bay Cc: Loepp, Victoria T(DOA); Doyon 25 Company Man; Bearden, J Daniel; Herbert, Frederick 0 Subject: PTD #214-189 2L-328 Notification of BOPE Use Date/time of BOPE use: 3/23/2015, 10:45 AM Well/Location/PTD Number: 2L-328, Kuparuk(Tarn), PTD#214-189 Rig name: Doyon 25 Operator Contact: Mike Callahan (drilling engineer)—(907) 231-2176 or Company man (907) 659-7501 1 • e Operations Summary: While running liner,flow was observed while static after picking up the liner hanger and two stands of drill pipe (@ "'4,100' MD). Annular preventer was shut in and SICP of 180 psi was observed (liner is plugged preventing circulation, so a SIDP pressure was not obtained). Full sequence of events is shown in the email below. BOPE Used: Annular Preventer Reason for BOP Use: Flow observed while running liner Actions to be taken: Continue to hold pressure to prevent further influx. If circulation is regained through the toe of the liner, pick up the liner hanger and strip in the hole with the liner holding pressure. If circulation is shallower in the string and not through the toe,do no pick up the liner hanger, run in with the current string. Once to the intermediate casing shoe, circulate kill weight mud around. Please let me know if you need any more information. Thanks, Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office: (907) 263-4180 Cell: (907) 231-2176 From: Callahan, Mike S Sent: Monday, March 23, 2015 3:17 PM To: Loepp, Victoria T(DOA) (victoria.loepp@alaska.gov) Cc: Bearden, J Daniel; Herbert, Frederick 0 Subject: FW: PTD # 214-189 2L-328 Status Update Victoria,just wanted to give you a quick update on the status of this well. We began running liner this morning and got all of our liner and the liner hanger in the hole. While running the liner we had slightly higher returns than the calculated pipe displacement, but the well appeared static on connections. After picking up the liner hanger we attempted to break circulation at^'4,100' MD, but were unable to circulate at all (pressure built to 1200 psi before we stopped pumping to avoid prematurely setting the liner hanger). At this time,we observed a slight flow on the well while static. The annular preventer was shut in, and the SICP built to^'180 psi. In order to regain circulation, we pressured up to attempt to shift our P-sleeve (approximately 60'from the shoe),which should shift open at approximately 4,000 psi. At 1,980 psi of drill pipe pressure, something opened and we regained circulation. We are not sure if the P-sleeve shifted early,one of the frac sleeves higher in the string shifted open, or if we cleared an obstruction that was in the float and the liner is now clear and intact. We are currently circulating to get even mud weight in and out and then will bleed off our drill pipe pressure to check if the floats are holding. If this is the case it would confirm that the problem was an obstruction in the float and that the liner is intact, in which case we would pick up the liner hanger and continue running as planned. If we cannot confirm this, our plan forward is to begin stripping in the hole to the intermediate shoe with the current assembly on drill pipe and circulate the well clean, making sure we have 12.7 ppg kill weight fluid all the way around. We would then come out of the hole and lay down the liner equipment to perform a cleanout run to TD with drill pipe before picking up the liner again. Our bi-weekly BOP test is due on Wednesday. If we are able to run the liner now as hoped,we would perform the BOP test at our intermediate shoe before going into the open hole ahead of the due date. If we are unable to do that and 2 0 • have to run in to circulate out the influx in the well, it may result in needing additional time before the BOP test to handle the well control situation. I will keep you updated on our progress and will be in communication no later than tomorrow if we need to request a waiver for more time on the BOP test. If you have any questions or would like any more information on the status of the well, please let me know. Thanks, Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office: (907) 263-4180 Cell: (907) 231-2176 3 • • K,2L4 ZL - IA-I6'r0 Regg, James B (DOA) From: Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent: Monday, March 23, 2015 4:04 PM 31z-4(t� To: DOA AOGCC Prudhoe Bay Cc: Loepp, Victoria T (DOA); Doyon 25 Company Man; Bearden, J Daniel; Herbert, Frederick 0 Subject: PTD #214-189 2L-328 Notification of BOPE Use Date/time of BOPE use: 3/23/2015, 10:45 AM Well/Location/PTD Number: 2L-328, Kuparuk (Tarn), PTD #214-189 Rig name: Doyon 25 Operator Contact: Mike Callahan (drilling engineer)—(907) 231-2176 or Company man (907) 659-7501 Operations Summary: While running liner, flow was observed while static after picking up the liner hanger and two stands of drill pipe (@ —4,100' MD). Annular preventer was shut in and SICP of 180 psi was observed (liner is plugged preventing circulation, so a SIDP pressure was not obtained). Full sequence of events is shown in the email below. - BOPE Used: Annular Preventer Reason for BOP Use: Flow observed while running liner Actions to be taken: Continue to hold pressure to prevent further influx. If circulation is regained through the toe of the liner, pick up the liner hanger and strip in the hole with the liner holding pressure. If circulation is shallower in the string and not through the toe, do no pick up the liner hanger, run in with the current string. Once to the intermediate casing shoe, circulate kill weight mud around. Please let me know if you need any more information. Thanks, Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office: (907) 263-4180 Cell: (907) 231-2176 From: Callahan, Mike S Sent: Monday, March 23, 2015 3:17 PM To: Loepp, Victoria T (DOA) (victoria.loepp@alaska.gov) Cc: Bearden, J Daniel; Herbert, Frederick 0 Subject: FW: PTD # 214-189 2L-328 Status Update Victoria,just wanted to give you a quick update on the status of this well. We began running liner this morning and got all of our liner and the liner hanger in the hole. While running the liner we had slightly higher returns than the calculated pipe displacement, but the well appeared static on connections. After picking up the liner hanger we 1 • attempted to break circulation at—4, 00' MD, but were unable to circulate at all (pressure built to 1200 psi before we stopped pumping to avoid prematurely setting the liner hanger). At this time, we observed a slight flow on the well while static. The annular preventer was shut in, and the SICP built to—180 psi. In order to regain circulation, we pressured up to attempt to shift our P-sleeve (approximately 60' from the shoe), which should shift open at approximately 4,000 psi. At 1,980 psi of drill pipe pressure, something opened and we regained circulation. We are not sure if the P-sleeve shifted early, one of the frac sleeves higher in the string shifted open, or if we cleared an obstruction that was in the float and the liner is now clear and intact. We are currently circulating to get even mud weight in and out and then will bleed off our drill pipe pressure to check if the floats are holding. If this is the case it would confirm that the problem was an obstruction in the float and that the liner is intact, in which case we would pick up the liner hanger and continue running as planned. If we cannot confirm this, our plan forward is to begin stripping in the hole to the intermediate shoe with the current assembly on drill pipe and circulate the well clean, making sure we have 12.7 ppg kill weight fluid all the way around. We would then come out of the hole and lay down the liner equipment to perform a cleanout run to TD with drill pipe before picking up the liner again. Our bi-weekly BOP test is due on Wednesday. If we are able to run the liner now as hoped, we would perform the BOP test at our intermediate shoe before going into the open hole ahead of the due date. If we are unable to do that and have to run in to circulate out the influx in the well, it may result in needing additional time before the BOP test to handle the well control situation. I will keep you updated on our progress and will be in communication no later than tomorrow if we need to request a waiver for more time on the BOP test. If you have any questions or would like any more information on the status of the well, please let me know. Thanks, Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office: (907) 263-4180 Cell: (907) 231-2176 2 • • Pip Z/ 4-! g ? Loepp, Victoria T (DOA) From: Bearden, J Daniel <J.Daniel.Bearden@conocophillips.com> Sent: Tuesday, March 10, 2015 11:20 AM To: Loepp, Victoria T (DOA) Cc: Herbert, Frederick 0;Alvord, Chip; Doyon 25 Company Man; Hallford, Kelsey; Callahan, Mike S Subject: RE:2L-328 (PTD#214-189) BOP Test extension request Attachments: Intermediate TOC.pptx Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria, The 7-5/8" intermediate hole cement job was successfully pumped and the plug bumped. Based on these facts and the calculated cement height based on the lift pressure data (attached),ConocoPhillips plans to proceed with our BOP testing, then pick up our 6-1/2" production hole drilling BHA(including memory Sonic to log TOC) and continue operations without running an E-line CBL prior to drilling ahead. Please give me a shout if you have any questions or concerns. Daniel Bearden Supervising Drilling Engineer ConocoPhillips, Alaska 907-263-4864 work 907-602-7068 cell From: Bearden, J Daniel Sent: Monday, March 09, 2015 4:32 PM To: Loepp, Victoria T(DOA) (yictoria.loer @alaska.gov) Cc: Herbert, Frederick 0; Alvord, Chip (Chip.Alvord@conocophillips.com); Doyon 25 Company Man; Hallford, Kelsey; Callahan, Mike S Subject: RE: 2L-328 (PTD# 214-189) BOP Test extension request Hi Victoria, Please table this request. We were able to achieve 6BPM at 900 psi and ran to bottom to begin our cementing operations. We will keep you abreast of the cement job results. Regards, Daniel Bearden Supervising Drilling Engineer ConocoPhillips, Alaska 907-263-4864 work 907-602-7068 cell From: Bearden, J Daniel Sent: Monday, March 09, 2015 1:06 PM To: Loepp, Victoria T(DOA) (victoria.loepp@alaska.gov) 1 • Cc: Herbert, Frederick 0; Alvord, Chip (C.hip.Alvord@conocophillips.com); Doyon 25 Company Man; HaIlford, Kelsey; Callahan, Mike S Subject: 2L-328 (PTD# 214-189) BOP Test extension request Victoria, ConocoPhillips hereby requests an extension for our required BOP testing on Doyon 25 on well 2L-38 (PTD#214-189) until the 7-5/8" intermediate cement job has been accomplished,or failing that, until we have pulled the 7-5/8" casing into the safety of the surface casing shoe. We ran our 7-5/8" intermediate casing to TD last night in plenty of time to cement and accomplish our planned BOP test due before midnight on March 10th. However due to packoff up hole,we are currently unable to achieve circulation rates necessary to guarantee our planned cement job to cover 500' above the top of the Tarn oil pool (C37). We can only circulate 0.5 BPM at 700 psi surface pressure with 9.7 ppg mud in the hole at TD of 5287'TVD. We have worked the pipe up and down, and currently pulled 10 joints in an attempt to regain circulation. Our plan is to return to bottom, and attempt to pressure up to 1,200 psi surface pressure to see if circulation rates>2.0 BPM can be established. If that fails,we plan to pull the 7-5/8" casing out of the hole and perform a cleanout run. Halting circulation efforts to prepare for BOP testing operations prior to having cement pumped will be detrimental to current hole conditions by ceasing pipe movement and circulation, increasing the likelihood of getting stuck, a well control incident,or jeopardizing the cement job. 2 ! • f 'KF-Pa x9 Zit a`4) Ft•'.t::s',=t^. SFY4..: '4#FT,tmi§To,- 12-rEl::0:0-****rWL1z 141891 U 002 r I I r 020 6:09 i 4 .go tr.- ILL1 i I 1900 I rr ill , 2 e� I d 26rN 160 ono se n. i {{{ r 300 i ?aD I �:. 960 1044 WO i 6,+,490 11 * t 1 1 Two Sew M4 t'000 A a 990 S, - I Pruf44.3 t2.Mena 4 egil r#Ainr 8000` vQ OM toss returns noted)4708'MD. t 200 Broke cif 0.1411011 and circulated QD began pumping out csg.. Me" 2500'MD,Surface Casing Shoe. _ Ski t j Oil 9000 k Tripping In wf o breaking c[rculabon. Weyhcd to bottom. t 14gd4 4 in ,'1 :i1 i,r' I d a ;�y t 12000103 aQu03 y /2200 r 100 a ¢ i■I$d I «f f®1 I I4 .J J JI I,, , J..111._ I 1 1 'H I !Ik 1 I ,: 0400 4102 1000 1200 1100 1409 1404 2000 22 X 0000 0200 0100 0400 04000 100: 1240 1100 1094 1400 26-Or 0P00 &)CO 1100 4#00 9000 1700 1400 ?400 2)00 0190 a)*a 0000 0102 0000 9400 1300 4000 1100 1400 rem 07.ux-,30t0 0000 SO 7ma Daniel Bearden Supervising Drilling Engineer ConocoPhillips, Alaska 907-263-4864 work 907-602-7068 cell 3 • CY cZ) uF ., --QP of s S A N t� Q <I LI O ? 1 1 i 11* ":12 � coo z !f-11 ' o 7'. a 5 a_ , -,i 1\3" 0-D—Cti:' 43- I gir I 1 i ! ! ill ! - 5,3 c(2 E): 1 .L. , -„, .... _ , . , , , 1 La o 11.. 111111 jIUI1HdIIILIIii n` - = ffw $ ° —o l al CD El Iit' _ !' !! I,lIII111 lilil w iiil , , __L_____________ . _ -;m7";C':- 1A 0 0 0 , I n rl. ; _ a fp ; pp :rims; c IIS®® li' MIIP _ . ,:, I ...... ....,diiii en CO r+ D_ 2 _ ____.„.,_________ .. k g.,>... i al S. 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C � Ilh m ro c g • r w n _ 03 m 1.o n V 14 �� -4. ,.41yN n p _ 5W.-., c" pa oma` _ i�r g'° U.. -w (4" gi c_,,, z 0,7; ,,, 0 0 N Q E. 62 0 0.a _ n i e .222 O G U OF T • • w s THE STATE Alaska Oil and Gas of /A LAsKA Conservation Commission 'Witt_ 333 West Seventh Avenue ' x- � Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER g Main: 907.279.1433 OF ALAS'P' 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, Tarn Oil Pool, KRU 2L-328 ConocoPhillips Alaska, Inc. Permit No: 214-189 Surface Location: 229' FNL, 909' FEL, SEC. 22, T1ON, R7E, UM Bottomhole Location: 4734' FNL, 2655' FEL, SEC. 25, T1ON, R7E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development 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 a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, ,oft7g/ Daniel T. Seamount, Jr. Commissioner DATED this 17 day of December, 2014. r 0 RECEIVED STATE OF ALASKA 0 cLEV.3-5,=r) ALASKA OIL AND GAS CONSERVATION COMMISSION _ DEC 1 1 .2014. PERMIT TO DRILL 20 AAC 25.005 AOGCC 1 a.Type of Work: lb.Proposed Well Class: Development-Oil 0 - Service-Winj ❑ Single Zone 2. 1c.Specify if well is proposed for: Drill ❑✓ . Lateral ❑ Stratigraphic Test❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates El Redrill El Reentry❑ Exploratory ❑ Service-WAG ❑ Service-Disp El Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: U Blanket • LI Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. . Bond No. 59-52-180 . ML) 2L-328 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 15668' , TVD: 5528' • Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): ) 6 kb L .38"ooS1 _3800S-3 Tarn Oil Pool Surface:229'FNL,909'FEL,Sec.22,T1ON,R7E,UM , ADL 380052,38053 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2912'FNL,3731'FEL,Sec.25,T1ON, R7E,UM 4602 1/1/2015 Total Depth: 9.Acres in Property: 14.Distance to 4734'FNL,2655'FEL,Sec.25,T1ON, R7E,UM 5120 Nearest Property: 2655' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 155 feet 15.Distance to Nearest Well Open Surface:x- 460742 y- 5927618 Zone- 4 GL Elevation above MSL: 115 feet to Same Pool: none, 16.Deviated wells: Kickoff depth: 400 ft., 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 90° - deg Downhole:3400 psig Surface:2859 psig 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND (including stage data) 24" 16" 62.6# H-40 Welded 91' 28' 28' 130' 130' driven 13.5" 10.75" 45.5# L-80 Hydril 563 2671' 28' 28' 2710' 2400' 1132 sx AS C, 195 sx 9.875" 7.625" _ 29.7# L-80 Hydril 563 11888' 28' 28' 11927' 5168' ✓ 984 sx GasBLOK 9.875" 7.625" 39# FN-110S: Hydril 563 500' 5238' 12427' 5315' 1 included with the above 6.5" 4.5" 12.6# L-80 IBTM 3154' 2515' 5339' 15669' 5528' frac sleeves 19 PRESENT WELL CONDITION SUMMARY /y�6 4'`2 7 i(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured) I'ffeCti06h (ft): Effective Depth ND(ft): Junk(measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20.Attachments: Property Plal❑ BOP Sketch❑ Drilling Prograrr ❑✓ - Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch El Seabed Report ❑ Drilling Fluid Program ❑✓ • 20 AAC 25.050 requirements ❑• 21.Verbal Approval: Commission Representative: Date: yj�f/� 22. I hereby certify that the foregoing is true and correct. Contact Mike Callahan @ 263-4180 %"w Email Mike.Callahancop.com Printed Name G L. AlvordA � Title Alaska Drilling Manager / Signature ,J� Phone:265-6120 Date "IC"ID L( Commission Use Only Permit to Drill �( Q API Number: Permit Approval See cover letter Number: a.�i `'p� 50- i')3-(Z.bG $-(p -QC Date: I21kciap`L for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed thane,gas hydrates,or gas contained in shales: VI Other: go P 71-t S f p t-t 55 urC 3 50 D p 5./ Samples req'd: Yes ❑ No [✓f Mud log req'd: Yes❑ No IA ,f}n - JGi r p rC ren tri 425-0, p 5 i H2S measures: Yes L No ❑ Directional svy req'd: Yes[f No❑ Spacing exception req'd: Yes ❑ No Inclination-only svy req'd: Yes❑ No LrV�J APPROVED BY THE 'Zit 1 ` ` -Q--P -211°.7 1 Approved by: COMMISSIONER COMMISSION Date: Form 10-401(Revised 10/2012) This permi of ` ' rA date of approval(20 AAC 25.005(g)) 13111/19. 04:1)304:1)3A0/y�� /r VT1. 1.y.//1//.4., t Tl l Con Post Office Box 100360 oPhilI1i Anchorage,Alaska 99510-0360 Phone(907)263-4180 Email: mike.callahan(n conocophillips.com December 10, 2014 RECEIVED Alaska Oil and Gas Conservation Commission DEC 11 2014 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 AOGCC Re: Revision of Application for Permit to Drill 2L-328 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill for the onshore production well slot 2L-328 from the Tarn 2L drilling pad. This well is intended to be a horizontal producing well from the Bermuda horizon. The intended spud date for this well is January 1st, 2015 using Doyon 25. When the Doyon 25 rig moves onto 2L-328,the proposed plan is to nipple up and test the diverter system utilizing the existing 16"conductor,spud the well with a 13-1/2"bit, drill to the surface casing point,then run and cement the 10-3/4"45.5#L-80 Hydril 563 surface casing in place. A 9-7/8"bit will be made up and the surface casing drilled out. The well will then be drilled down to the intermediate casing point(topsetting the Bermuda by—100'TVD)where a string of 7-5/8"29.7#L-80 Hydril 563 casing will be run and cemented in place. A 6-1/2"bit will be run to drill the horizontal lateral portion of the well to TD. A 4-1/2"production liner with swell packers and frac sleeves will be slid in position for future frac operations. Finally,the upper completion will consist of 3-1/2"gaslifted 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. A proposed drilling program 3. A drilling fluids program summary. 4. Proposed Completion Diagram 5. Pressure information as required by 20 ACC 25.035(d)(2). 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b). 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. Sincerely, lyy, Mike Callahan Drilling Engineer • AppTcation for Permit to Drill,Well 2L-328 Saved:9-Dec-14 2L-328 Application for Permit to Drill Document—Revision conocoPhiOtps . Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (f)) 3 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) 3 Requirements of 20 AAC 25.050(b) 4 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) 4 4. Drilling Hazards Information (Requirements of 20 AAC 25.005 (c)(4)) 4 ASP CALCULATIONS 4 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5)) 5 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) 5 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) 5 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) 5 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) 6 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) 6 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) 6 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) 6 13. Proposed Drilling Program (Requirements of 20 AAC 25.005 (c)(13)) 7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal7 (Requirements of 20 AAC 25.005 (c)(14)) 7 2L-308 APD Page 1 of 14 Printed:9-Dec-14 ORIGINAL • App'cationfor Permit to Drill,Well 2L-328 Saved:9-Dec-14 15. Attachments 8 Attachment 1 Directional Plan 8 Attachment 2 Drilling Hazards Summary 8 Attachment 3 Proposed Well Schematic 8 Attachment 4 Cement Summaries .8 2L-308 APD Page 2 of 14 Printed:9-Dec-14 IGINAL • App'cation for Permit to Drill,Well 2L-328 Saved:9-Dec-14 1. Well Name (Requirements of 20 AAC 25.005(f)) The well for which this application is submitted will be designated as 2L-328. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This well is planned as a horizontal producer to improve Bermuda oil recovery and pattern sweep efficiency in the newly discovered pay from the 2010 seismic program at Tarn. The Doyon 25 rig will drill a 13-1/2" surface hole and case with 10-3/4", L-80 with premium Hydril 563 connections. The 9-7/8" intermediate section will be drilled to+/- 100' TVD above the Bermuda sand, and 7-5/8" casing will be run to top-set the reservoir. This set depth is -50' TVD higher than on most recent Tarn wells due to the presence of a thin sand stringer identified in a nearby offset log (2N-322) that. If the casing shoe is set in this zone, it will likely lead to a lower than desired FIT/LOT value that could compromise drilling the production lateral. We would therefore like to set the intermediate casing higher, -100' TVD above the top of the Bermuda reservoir, to avoid this issue and achieve a higher FIT/LOT value. The rig will then drill a 6-1/2" horizontal production lateral. A 4-1/2" production liner, equipped with swell packers and frac sleeves will be run into the open hole for the lower completion. Finally, a 3-1/2" gas-lifted tubing assembly will be run for the upper completion. Location at Surface 229.27' FNL, 908.81' FEL, Sec 22, T1ON, R7E, UM NAD 1927 RKB Elevation 154.9'AMSL Northings: 5,927,617.58 Eastings: 460,741.94 Pad Elevation 115.4'AMSL Location at 7 5/8" Intermediate Csg Pt. 2588.16' FNL, 3464.55' FEL, Sec 25, T1ON, R7E, UM Nad 1927 Measured Depth, RKB: 12,427' Northings: 5,920,707.31 Eastings: 468,183.55 Total Vertical Depth, RKB: 5,315' Total Vertical Depth, SS: 5,160' Location at Top of Productive 2,911.73' FNL, 3731.49' FEL, Sec 25, T10N, R7E, UM Interval (Bermuda) Nad 1927 Measured Depth, RKB: 12,858' Northings: 5,920,383.74 Eastings:468,450.49 Total Vertical Depth, RKB: 5,415' Total Vertical Depth, SS: 5,260' Location at Total Depth 4734.39' FNL, 2654.72' FEL, Sec 25, T10N, R7E, UM (Toe) Nad 1927 Measured Depth, RKB: 15,668' Northings: 5,917,792.81 Eastings: 469,519.05 Total Vertical Depth, RKB: 5,528' Total Vertical Depth, SS: 5,373' 2L-308 APD Page 3 of 14 Printed:9-Dec-14 ORIGINAL 1 App'cation for Permit to Drill,Well 2L-328 Saved:9-Dec-14 Requirements of 20 AAC 25.050(b) Please see Attachment 1: Directional Plan The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference BOP schematics on file for Doyon 25. 4. Drilling Hazards Information (Requirements of 20 AAC 25.005(c)(4)) The following presents data used for calculation of anticipated surface pressure(ASP) during drilling of this well: • NOTE: The Doyon 25 5000 psi BOP equipment is adequate. Test BOP to 3500 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) (A) ASP is determined as the lesser of 1)surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2)formation pore pressure at the next casing point less a gas gradient to the surface as follows: The maximum potential surface pressure (MPSP)while drilling 2L-328 is calculated using a maximum possible reservoir pressure of 3,400 psig (12.1 ppg), a gas gradient of 0.10 psi/ft, and the estimated depth of the Bermuda formation at 5,415' TVD. 1) ASP = [(FG x 0.052)—0.1]D Where: ASP =Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from lb./gal to psi/ft 0.1 = Gas gradient in psi/ft D =true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP—(0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. MPSP/MASP calculation ASP = [(FG x 0.052)—0.1] D = [(14.5 x 0.052)—0.1]x 5,415' = 3,541 psi OR ASP = FPP—(0.1 x D) =3,400—(0.1 x 5,415') = 2,859 psi (B)Data on potential gas zones; The well bore is not expected to penetrate any gas zones. 2L-308 APD Page 4 of 14 Printed.9-Dec-14 ORIGINAL 110 Application for Permit to Drill,Well 2L-328 Saved:9-Dec-14 (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; The Tarn reservoir model predicts the 2L-328 will find reservoir pressure in the range of 2,200 to 3,400 psig, with expected at—2500 psig. We will continue to monitor pressures as the spud date approaches. 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5)) Drill out from casing shoe and perform LOT or FIT in accordance with the Kuparuk LOT/ FIT procedure that ConocoPhillips, Alaska has on file with the Commission. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) Casing and Cementing Program Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Conn. (ft) (ft) (ft) Cement Program 16 24 62.6 H-40 Welded 91' Surf 130'/130' N/A Hydril Cemented to Surface with 10-3/4 13-1/2 45.5 L-80 563 2,671' Surf 2,710/2,400' 1,132 sx ASC Lead 11 ppg 195 sx Tail Slurry 12 ppg 7-5/8 9-7/8 29.7 L-80 Hydril 11,888' Surf 11,927'/5,168' 563 Cement Top planned @ 8,900'MD/ TN- 4,274'TVD. Cemented w/ 7-5/8 9-7/8 39 110S Hydril 500' 12,165'/5,238' 12,427'/5,315' 984 sx GasBLOK Class G 15.8 ppg 563N/A,will have swell packers&frac 4 1/2 6 1/2 12.6 L-80 IBTM 3,154' 12,515'/5,339' 15,669'/5,528' sleeves Casing / Liner Design: The 85% collapse and burst ratings are listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 10-3/4" 45.5 L-80 3 Hyd563 2,480 psi 2,108 psi 5,210 psi 4,429 psi 7-5/8" 29.7 L-80 3 Hyd563 4,790 psi 4,072 psi 6,890 psi 5,857 psi 4.5" 12.6 L-80 3 IBTM 7,500 psi 6,375 psi 8,440 psi 7,174 psi 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Please reference diverter schematic on file for Doyon 25. 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Drilling will be done using Fresh water and seawater-based LSND mud systems having the following properties: 2L-308 APD Page 5 of 14 Printed:9-Dec-14 ORIGINAL App'cation for Permit to Drill,Well 2L-328 Saved:9-Dec-14 Surface Intermediate Production 13-1/2" hole 9-7/8" hole 6-1/2" hole 10-3/4" Casing 7-5/8" Casing 4-1/2" Liner Density 9.6 - 10 ppg 9.6— 10.0 ppg 10.0—12.2 ppg YP 60-80 18-28 12- 18 Funnel Viscosity(sec) 75—250 40-55 PV 20-60 20-25 18-22 Initial Gels 10-35 4—8 5-9 10 minute gels <18 <4 API Filtrate NC—8.0-10 cc/30 min 4-12cc/30 min <10 cc/30 min HPHT Fluid Loss at 160 8.5—9.0 <12 <5 PH 9.0-9.5 9-9.5 9.3- 10 Chlorides <1000 9.0— 10 Surface Hole Section: Fresh water Drilplex spud mud system. Standard high viscosity fresh water/ gel spud mud will be used for the surface interval. Viscosity will be reduced prior to cementing. Maintain mud weight between 9.6 - 10.0 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: LSND water-based mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity through the sticky upper clays. There is potential for lost circulation, particularly after the Campanian and Iceberg zones are penetrated. Maintain mud weight at or above 9.6 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required)will all be important in maintaining wellbore stability. Production Hole Section: LSND/KLASHIELD water-based mud system. Ensure good hole cleaning by maintaining low end rheology and pumping of regular sweeps. Maximize fluid annular velocity. There is potential for lost circulation in the target Bermuda reservoir. Maintain minimum mud weight of at least 10.0 ppg and be prepared to add loss circulation material. Be prepared to weight up if higher than expected pore pressure is encountered. Good filter cake quality, hole cleaning and maintenance of low drill solids will all be important in maintaining wellbore stability. Diagram of Doyon 25 Mud System is on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an offshore well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 2L-308 APD Page 6 of 14 Printed:9-Dec-14 ORG1NAL • App'cation for Permit to Drill,Well 2L-328 Saved:9-Dec-14 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) The proposed drilling program is listed below. Please refer to Attachment 3: Well Schematic. 1. MIRU Doyon 25 on 2L-328 existing 16" conductor. 2. NU and function test diverter system and prepare 9.6 ppg fresh water Drilplex spud mud. 3. Place warning signs on location indicating the rig has diverter equipment rigged up. 4. Cleanout to below the conductor to get 13-1/2" BHA below ground level. 5. Spud and directionally drill 13-1/2" hole to the 10-3/4"surface casing point(2,710' MD/2,400'TVD) according to the directional plan. Run MWD/LWD logging tools in drill string (GR/RES/PWD/Gyro while drilling) and on-site mud logging for directional monitoring and formation data gathering. 6. Run and cement 10-3/4"45.5#L-80 Hydril 563 casing to surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job if losses do not occur. Displace cement with mud. Perform top job if required to bring cement to surface. 7. Nipple down diverter and install wellhead and test to 5000 psi. Notify State 24 hrs prior to BOPE test. Nipple up BOPE and test to 3,500 psi. Record results. 8. Shut in GOP's and pressure test surface casing to 3,000 psi per AOGCC regulations. Record results. 9. Drill out cement and 20' minimum to 50' maximum of new hole. Perform LOT. 10. Directionally drill 9-7/8" intermediate hole to 12,427' MD/5,315'TVD. Run MWD/LWD logging tools in drill string (GR/RES/NEUT/DENS/PWD)with on-site mud logging and field geologist for directional monitoring and formation data gathering. 11. Circulate bottoms up to clean hole, POOH and lay down 5" drill pipe. 12. RU and run 7-5/8", 29.7#and 39#, L-80 and Tenaris110SS with Hydril 563 connections on the intermediate casing to TD and cement in place with a minimum of 500' of cement above the C37 formation. 13. MU 6-1/2" bit and RIH on 4" drill pipe. 14. Directionally drill 6-1/2" production hole to 15,669' MD/5,528' TVD as per directional program. Run MWD/LWD logging tools in drill string (GR/RES/Neut/DENS/PWD/Periscope/Stethoscope/Sonicscope for CBL evaluation)for navigational monitoring and formation data gathering. POOH --- 15. 15. POOH, and RU casing crew and cementers. 16. MU and run a 4-1/2" liner to TD and set the ZXP liner top packer on top of the Flex Lock liner hanger leaving a 150' liner lap. 17. Perform a pressure test on the liner top packer, POOH and LD 4" drill pipe 18. Run 3-1/2" completion tubing with premier packer and seals and set packer at+/- 12,515' MD/5,338' TVD. 19. ND BOP and NU tree. Test tree and freeze protect annulus. Rig down and move out rig. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005(c)(14)) 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. 2L-308 APD Page 7 of 14 Printed:9-Dec-14 ORIGINAL • Apppcation for Permit to Drill,Well 2L-328 Saved:9-Dec-14 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Proposed Well Schematic Attachment 4 Cement Summaries 2L-308 APD Page 8 of 14 Printed:9-Dec-14 RIGmAL • Loepp, Victoria T (DOA) From: Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent: Thursday, December 18, 2014 2:43 PM To: Loepp, Victoria T (DOA) Subject: RE: KRU 2L-328(PTD 214-189) Anti-collison & Diverter layout Follow Up Flag: Follow up Flag Status: Flagged Victoria,these two wells were flagged because they fall below a 1.5 separation factor on their ellipses, but they are still above our minimum required separation factor of 1.0, so they have been minor risked. We will plan to get a little bit ahead of our planned line as we approach the wells to avoid a situation where the separation factor falls below 1.0. We should also be able to see if we are approaching too close well in advance due to MWD interference from the casing of the other well. If we get in a situation where we are off of our directional plan causing us to fall below a separation factor of 1.0,we will shut-in the offset well and further evaluate before proceeding. Please let me know if this answers your question or if you would like any more information. Thanks, Mike From: Loepp, Victoria T(DOA) [mailto:victoria.loeDp@alaska.gov] Sent: Thursday, December 18, 2014 11:33 AM To: Callahan, Mike S Subject: [EXTERNAL]RE: KRU 2L-328(PTD 214-189) Anti-collison &Diverter layout Mike, In the anti-collision report, what mitigation factors will be used to minor risk collision with 2L-318 and with 2L-325? Were these major risk failures prior to the minor 1/200 risk? Thanx, Victoria From: Callahan, Mike S [mailto:Mike.Callahan@conocoohillios.com] Sent: Thursday, December 18, 2014 10:18 AM To: Loepp, Victoria T(DOA) Subject: RE: KRU 2L-328(PTD 214-189) Anti-collison &Diverter layout Victoria, please see the attached AC report and pad layout showing the diverter route. Our preferred orientation for the diverter is straight out of the back of the rig(the north facing line), but if the cable trays at the pipe rack interfere with that we may orient it along our second option,shown as the southwest line. That decision will be made when they rig up on the well. Please let me know if this answers your questions and if you need anything else from me. Thanks, Mike Callahan Drilling Engineer ConocoPhillips Alaska 1 • • Loepp, Victoria T (DOA) From: Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent: Thursday, December 18, 2014 10:18 AM To: Loepp, Victoria T (DOA) Subject: RE: KRU 2L-328(PTD 214-189) Anti-collison & Diverter layout Attachments: 2L-328 Pad Areal Photograph_Diverter Layout.pdf; 2L-328wp05.1 - Anticollision Report.pdf Victoria, please see the attached AC report and pad layout showing the diverter route. Our preferred orientation for the diverter is straight out of the back of the rig (the -north facing line), but if the cable trays at the pipe rack interfere with that we may orient it along our second option, shown as the"southwest line. That decision will be made when they rig upon the well. Please let me know if this answers your questions and if you need anything else from me. Thanks, Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office: (907) 263-4180 Cell: (907) 231-2176 From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Thursday, December 18, 2014 9:08 AM To: Callahan, Mike S Subject: [EXTERNAL]KRU 2L-328(PTD 214-189) Anti-collison & Diverter layout Mike, Please provide the following: 1. Anti-collision report-Please provide the summary page of the anti-collision report and a traveling cylinder plot 2. Diverter layout sketch- Please provide a diverter route schematic showing the rig on the pad and the route with approximate dimensions for the diverter. Show at least a 90' radius around the diverter outlet. This will have to be a part of all PTD application submissions in the future. Thanx in advance, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(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 r-, r _ , L r _ � . . :.-s- "-. ;v LW ^` 11 k, L.tt'%' _ } ro r 1l 1 `$ 11 t J {{51`1 tri \ '''',.1.' 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O O (` CI c0 O V V N CO 0 a0 N` 1` CO t` N` c.''. N O. N co r CO V V V )O h N V V V V V V (O c CO 0 �, r r r N N N co co- CO CO CO u) CO CO (n C 0 'O i7O a (D N >� - CON 2 J N p O_ 0 0 0 0 0 CO CO N N CO N NCO CO C Y Y J 3 a In (n (O (O N N N O CO N <- 1- LO CO. L- L- Cr ° ` 2 N CO (O i �_ M M O (O 0) V V OO (O CO CO Co Co O ,.L.+ v (0 CO CO CO CO N CO N 0) CO h CO CO (0 0 n. o_ O M M N a 0 M N- 7. CO V N. (` ,- s- CO N CO V h N-- co co Q D D L J J (c° 0 ° ,- .- .- N N M CO- r CO M. .M- CO- CO- r Z Y Y (L N N 7 N 0T N m O > y C Q 7 C .. so a O a co. U c) ain330 a 0 ORIGINAL „ • 0 2L-328 wp05 Surface Location r CPAI Coordinate Converter i ":�ry From: _ —To: -- Datum: 1NAD27 .j Region: lalaska .1 Datum: [NAD27 Region: ]alaska C. LatitudelLongitude 'Decimal Degrees +i C- Latitude/Longitude 'Decimal Degrees + t-- UTM Zone: 1 I— South C UTM Zone: 'True f South C. State Plane Zone:14 J Units: us-ft + C State Plane Zone: True + Units: us ft + r Legal Description(NAD27 only) a Legal Description(NAD27 only) Starting Coordinates: — — -Legal Description —— X: 1460741.94 Range: 1010 'N 1007 'E • L.. Y: 5927617.58 Meridian: IU +' Section:122 1FNL + 1229.27050 IFEL +.11908.80735 I i Transform 1 Quit I Help I 2L-328 wp05 7-5/8” Casing Shoe 1:73. CPAI Coordinate Converter " r From: To: Datum: 1NAD27 Region: lalaska .) Datum: 1NAD27 Region: 'alaska -..-- r- C' Latitude/Longitude 'Decimal Degrees .211 - Latitude/Longitude 'Decimal Degrees ' C UTM Zone:I r South r UTM Zone:ITrue_ E South a State Plane Zone: [4 j Units: FIFA. C State Plane Zone: 'True_ IUnits: us ft r Legal Description(NAD27 only) !+ Legal Description(NAD27 only) —Starting Coordinates: —Legal Description - 468650.12 Township: I010 IN Range: (007 [E--".j. Y: 15920001.28 Meridian: lU + Section:125 FNL .i 12529.2716 'FEL +I 13531.8584 I I Transform I Quit Help DflG1NAL•R I • 411/ 2L-328 wp05 TD c CPA:Coo-dinate Converter From: To: Datum: 1NAD27 Region: Ialaska 2L1 Datum: INAD27 j Region: Ialaska 2:1 ( Latitude/Longitude 1Decimal Degrees ( Latitude/Longitude 'Decimal Degrees 2.1 (- UTM Zone: 1 1— South C UTM Zone: 1True r South 4 State Plane Zone:142.j Units: ,17-7A r State Plane Zone: crrue .1r-1 Units: lus-ft Legal De-3criptionINAD27 only) c Legal Description(NAD27 only) Starting Coordinates: —Legal Description X: 1469519.05 Township: 1-010 IN .1 Range: 1007 F-3-1. Y: 15917792.81 Meridian: Ju .1 Section:125 IFNL 14734.3916 IFEL .1 12654.7189 Transform 11 Quit Help ORIGINAL • • 2L-328 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 Moderate If observed -control drill, reduce pump rates, reduce drilling fluid temperatures, Additions of Lecithin. Gravel/Sand Sloughing Moderate 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 Trips (use of 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 9-7/8" Hole / 7-5/8" Casing Interval Event Risk Mitigation Strategy Level Campanian/Iceberg Sands Low Control with higher MW and proper drilling practices. High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with higher MW's required PWD tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Abnormal Reservoir Pressure Low Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills, PWD Tools, Increase mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Lost Circulation Low Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. 6-1/2" Hole /4-1/2" Horizontal Liner Interval Event Risk Mitigation Strategy Level High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with higher MW's required PWD tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Abnormal Reservoir Pressure Low Plan to top set the 7-5/8" intermediate casing above the Bermuda placing the entire intermediate section behind pipe prior to drilling the Bermuda Mud weight will be used for offsetting formation pressure Lost Circulation Low Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. RIGINAL r •2L-328 Sierra w/o Pilot ! 'VP' ` Grass Roots Tooset Pilot Hole Horizontal Multi-Stacie Frac'd Producer ConocoPhillips Proposed Wellbore Schematic WP05.1 CAMERON 4-1A"tree,to.joint is 4-'/z"12.6#IBTM,crossed over(for frac equipment) l J 16" Existing Conductor: 16"62.6#H-40 Callahan 12/9/2014 130' MD 3'/:"Camco DS - Nipple 2.875" 500'MD Fresh Water 13-1/2"Surface Hole DrilPlex 9.6 PPG 3%"x 1"Camco KBMG 11/1 Surface Casing: 10-3/4"45.5#L-80 Hydril 563 2,710' MD/2,400'TVD @ 60° 3%"x 1"Camco KBMGEj Campanian Top 3,000 MD(?,s Tvo LSND 9.6-10.0 PPG Tubing: Keep up with 3 i"x1"Camco KBMGtj 3-%" 9.3#L-80 EUE8RD Dilution 4-1/2" 12.6#L-80 IBTM top joint to surface 9-7/8" Intermediate Hole Estimated top of cement @+/-8,905'MD (500'above C37) 3''/z"x 1"Camco KBMG 4444 Iceberg Top 9,813'MD(4544 TVD) . 1]EJI] Baker CMU Sliding Sleeve CLOSED w/2.812"Camco'DS'Profile 10'above Packer / Down hole gauge—12,000'MD 3.5"x 7-5/8",Baker Premier Packer 12,127 MD 3 1"Camco D Nipple 2.75"nogo °' c tt 7-5/8"x 4-M"Baker Flex Lock Liner hanger ZXP liner top packer :,. y w/RS Nipple, 12,277'MD Intermediate Casing Topset: 7-5/8"29.7#L-80&500'TN 1 l oss 39#—all Hydril 563 connections Top of Bermuda 12,858'MD 5,415'TVD 12,427' MD/5,315'TVD @ 74° 612'Running:OD8akerSwell 6-1/2!' Productiti hlt le Llner i�Heel Pa•c•ker•s ffLASHEt:LD . 10 D PPG 4 1/2 12 6#Hydrll, illIIIIII 521:::::: a O O O O O ,i: Bermuda:Pore Pressure. u -48.9 12 Protl ctlor Utter 90Q :,;iigii,i,i;,i,H,,H,,Hi,; HH,,i/H,,.i,i;i (2,20E1—2 00 0;40 Ps9) 41/2' 126#fiTN110SS H ,:..-4.:!!:6:::6.:H4,6:.:21 : l 80IBTM Pet toi. r8ted Pu i 1.2.277'MD to 15 68 MD .. 5,272'TVD to 5,528'TVD ) RIGINAL • 2L-328 Schlumberger CemCADE Preliminary Job Design 10 3/4" Surface Casino (V1) Preliminary Job Design based on limited input data.For estimate purposes only. Volume Calculations and Cement Systems Rig: Doyon 25 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 2210' MD. Client:CPAI Revision Date: November 13,2014 Prepared by:Jenna Houston Location:Anchorage,AK Lead Slurry Minimum pump time: -225 min. (pump time plus 120 min.) Phone: (907)263-4207 DeepCRETE @ 11.0 ppg- 1.91 ft3/100 lb sk Mobile: (907)223-8916 email:jhouston2@slb.com 0.638 ft3/ft x 106 x 1.0 (0%excess) = 68 ft3 0.3637 ft3/ft x (1405-106) x 3.50 (250%excess) = 1654 ft3 < TOC at Surface 0.3637 ft3/ft x (2210-1405) x 1.50 (50%excess) = 440 ft3 1654 ft3+440 ft3+68 ft3= 2162 ft3 2162 ft3/ 1.91 ft3/sk= 1132 sks(1145 sks) Tail Slurry Minimum pump time: -180 min. (pump time plus 120 min.) 12.0 ppg DeepCRETE-1.63 ft3/1001b sk 0.3637 ft3/ft x (2710-2210) x 1.50 (50%excess) = 273 ft3 0.54000 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 200 sks BHST= 70°F, Estimated BHCT =76°F. (Based on 2.1 °F/100 ft. from base permafrost) PUMP SCHEDULE Stage Cumulative Pump Rate Stage Time < Base Permafrost at Stage (bpm) Volume (min) Time 1,405'MD(-1,390'TVD) (bbl) (min) MUDPUSH I I 7.0 100.0 14.3 14.3 Pause 0.0 0.0 5.0 19.3 11ppg DeepCRETE 7.0 384.8 55.0 74.3 12.0 ppg Tail Slurry 7.0 56.3 8.0 82.3 Pause 0.0 0.0 5.0 87.3 < Top of Tail at Water 7.0 10.0 1.4 88.7 2,210'MD Pause 0.0 0.0 5.0 93.7 Drilplex Mud 8.0' 232.9 29.1 122.8 Drilplex Mud 3.0` 10.0 3.3 126.1 MUD REMOVAL Expected Mud Properties:9.6 ppg, Pv<20, Ty<20 10 3/4",45.5#casing Spacer Properties:10.5 ppg MudPUSH* II, Pv= 17-21, Ty-20-25 in 13.5"OH Centralizers: As per CPAi program. TD at 2,710'MD (2,400'TVD) * Mark of Schlumberger ORIGINAL 2L-328 CemCADE Preliminary Job Design Schlumberger 7 5/8" Intermediate (v2) Preliminary Job Design based on limited input data.For estimate purposes only. Rig: Doyon 25 Volume Calculations and Cement Systems Location: Kuparuk Client: CPAi Revision Date: December 10, 2014 Volumes are based on 40% excess. The Top of the tail slurry is designed to be at-8905- Prepared by: Stephen Lauper ft MD Location:Anchorage,AK Phone: (907)273-1765 Tail Slurry Minimum thickening time: -276.2 min. (pump time plus 120 min.) Mobile: (907)952-0445 15.8 ppg GASBLOK Slurry+adds- 1.17 ft3/sk email:slauper@slb.com Annular Volume: 0.2148 ft3/ft x(12427'-8905') x 1.4 (40% excess) = 1060 ft3 Shoe Volume: 0.2394 ft3/ft x 80'x 1.00 (no excess) = 20 ft3 Totals: 1060 ft3+20 ft3= 1080 ft3 1080 ft3/1.17 ft3/sk= 923 sks BHST= 147 °F, Estimated BHCT= 104 °F. (BHST calculated using a gradient of 2.1 °F/100 ft. from surface) PUMP SCHEDULE Previous Casing Stage Cumulative 10 3/4",45.5#casing Stage Pump Rate Volume Stage Time _ Time at 2710'MD (bpm) (bbl) (min) (min) CW100 6.0 40.0 6.7 6.7 MUDPUSH II 6.0 40.0 6.7 13.4 Pause 0.0 0.0 5.0 18.4 Tail Slurry 6.0 192.3 32.0 50.4 Pause 0.0 0.0 5.0 55.4 Top of Tail at Fresh Water 6.0 10.0 1.4 end of pumping 56.8 < 8905'MD Pause 0.0 0.0 5.0 61.8 Mud 6.0 546.5 91.1 152.9 Mud 3.0 10.0 3.3 156.2 MUD REMOVAL 9 7/8"OH Recommended Mud Properties: 10.0 ppg, Pv<20, Ty<20. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 11.5 ppg MudPUSH* II, Pv 20-24, Ty= 37-41 Centralizers: As per CPAi program 7 5/8"29.7# TD at-12427'MD (5315'TVD) *Mark of Schlumberger ORIGINAL • ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2L Pad Plan: 2L-328 (Sierra) 2L-328 2L-328wp05.1 Clearance Summary Anticollision Report 06 November,2014 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 2L Pad-Plan:2L-328(Sierra)-2L-328-2L-328wp05.1 Well Coordinates: 5,927,366.79 N,1,600,775.69 E(70°12'46.36"N,150°19'10.94"W) Datum Height: plan:(115.4+39.5) 154.90usft(Doyon 25) Scan Range: 0.00 to 15,668.56 usft.Measured Depth. Scan Radius is 1,762.91 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build: 65 Scan Type: GLOBAL FILTER APPLIED.All wellpaths within 200'+100/1000 of reference Scan Type: 25.00 • ConocoPhillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 2L-328 (Sierra) -2L-328wp05.1 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 2L Pad-Plan:2L-328(Sierra)-2L-328-2L-328wp05.1 Scan Range: 0.00 to 15,668.56 usft.Measured Depth. Scan Radius is 1,762.91 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft Kuparuk 2L Pad 21-307-2L-307-2L-307 154.90 315.07 154.90 312.59 152.05 126.902 Centre Distance Pass-Major Risk 2L-307-2L-307-2L-307 277.84 315.80 277.84 311.35 275.00 70.891 Clearance Factor Pass-Major Risk 2L-307-2L-307L1-2L-307L1 154.90 315.07 154.90 312.59 152.05 126.902 Centre Distance Pass-Major Risk 2L-307-2L-307L1-2L-307L1 277.84 315.80 277.84 311.35 275.00 70.889 Clearance Factor Pass-Major Risk 2L-307-2L-307L2-2L-307L2 154.90 315.07 154.90 312.59 152.05 126.902 Centre Distance Pass-Major Risk 2L-307-2L-307L2-2L-307L2 277.84 315.80 277.84 311.35 275.00 70.889 Clearance Factor Pass-Major Risk 2L-307-2L-307L2-01-2L-307L2-01 154.90 315.07 154.90 312.59 152.05 126.902 Centre Distance Pass-Major Risk 2L-307-2L-307L2-01-2L-307L2-01 277.84 315.80 277.84 311.35 275.00 70.889 Clearance Factor Pass-Major Risk 2L-309-2L-309-2L-309 39.60 284.81 39.60 283.84 33.98 295.066 Centre Distance Pass-Major Risk 2L-309-2L-309-2L-309 330.57 287.48 330.57 281.16 325.00 45.502 Clearance Factor Pass-Major Risk 2L-309-2L-309PB1-21-309PB1 39.60 284.81 39.80 283.80 33.98 281.400 Centre Distance Pass-Major Risk 2L-309-2L-309PB1-2L-309PB1 330.57 287.48 330.57 281.11 325.00 45.167 Clearance Factor Pass-Major Risk 2L-310-2L-310-2L-310 213.00 269.38 213.00 265.63 200.00 71.779 Centre Distance Pass-Major Risk 2L-310-2L-310-2L-310 263.00 269.76 263.00 285.20 250.00 59.177 Clearance Factor Pass-Major Risk 2L-311-2L-311-2L-311 211.60 254.71 211.60 251.25 200.00 73.535 Centre Distance Pass-Major Risk 2L-311-2L-311-2L-311 286.59 255.37 286.59 250.67 275.00 54.431 Clearance Factor Pass-Major Risk 2L-312(Cassidy)-2L-312-2L-312 40.10 240.32 40.10 239.30 40.10 236.055 Centre Distance Pass-Major Risk 2L-312(Cassidy)-2L-312-2L-312 450.62 240.89 450.62 232.52 450.00 28.791 Clearance Factor Pass-Major Risk 2L-313-2L-313-2L-313 610.25 224.90 610.25 215.67 600.00 24.379 Centre Distance Pass-Major Risk 2L-313-2L-313-2L-313 660.37 225.19 680.37 215.20 650.00 22.529 Clearance Factor Pass-Major Risk 2L-314(Tarawa)-21-314-2L-314 336.59 208.11 336.59 202.22 325.00 35.327 Centre Distance Pass-Major Risk 2L-314(Tarawa)-2L-314-2L-314 436.99 208.84 436.99 201.54 425.00 28.594 Clearance Factor Pass-Major Risk 2L-314(Tarawa)-2L-314PB1-2L-314PB1 336.59 208.11 336.59 202.22 325.00 35.327 Centre Distance Pass-Major Risk 21-314(Tarawa)-2L-314PB1-2L-314PB1 436.99 208.84 436.99 201.54 425.00 28.594 Clearance Factor Pass-Major Risk 2L-315-2L-315-2L-315 509.54 190.87 509.54 183.05 500.00 24.417 Centre Distance Pass-Major Risk 2L-315-2L-315-2L-315 660.09 192.23 660.09 182.14 650.00 19.047 Clearance Factor Pass-Major Risk 2L-317-2L-317-2L-317 154.90 164.96 154.90 162.47 152.81 66.440 Centre Distance Pass-Major Risk 2L-317-2L-317-2L-317 277.08 165.69 277.08 161.19 275.00 36.857 Clearance Factor Pass-Major Risk 06 November,2014- 9:19 Page 2 of 7 COMPASS 0 0 ('onocoPhillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 2L-328 (Sierra) -2L-328wpO5.1 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 2L Pad-Plan:2L-328(Sierra)-2L-328-2L-328wp05.1 Scan Range: 0.00 to 15,668.56 usft.Measured Depth. Scan Radius is 1,762.91 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft 2L-317-2L-317A-2L-317A 154.90 164.96 154.90 162.47 152.81 66.440 Centre Distance Pass-Major Risk 2L-317-2L-317A-2L-317A 277.08 165.69 277.08 161.19 275.00 36.857 Clearance Factor Pass-Major Risk 2L-318(Libra)-2L-318-2L-318 3,152.03 111.18 3,152.03 69.80 3,000.00 2.687 Clearance Factor Pass-Minor 1/200 2L-318(Libra)-2L-318-2L-318 3,172.47 109.97 3,172.47 69.99 3,025.00 2.751 Centre Distance Pass-Minor 1/200 21-319-2L-319-21-319 39.60 134.90 39.60 133.89 30.04 133.289 Centre Distance Pass-Major Risk 2L-319-2L-319-2L-319 459.75 136.87 459.75 128.11 450.00 15.613 Clearance Factor Pass-Major Risk 2L-320-2L-320.2L-320 40.00 120.03 40.00 119.01 40.95 118.039 Centre Distance Pass-Major Risk 2L-320-2L-320-2L-320 324.00 123.74 324.00 117.44 325.00 19.651 Clearance Factor Pass-Major Risk 2L-320-2L-320PB1-2L-320PB1 40.00 120.03 40.00 119.01 40.95 118.039 Centre Distance Pass-Major Risk 2L-320-2L-320PB1-2L-320PB1 324.00 123.74 324.00 117.44 325.00 19.651 Clearance Factor Pass-Major Risk 2L-320-2L-320PB2-2L-320PB2 40.00 120.03 40.00 119.01 40.95 118.039 Centre Distance Pass-Major Risk 2L-320-2L-320PB2-2L-320PB2 324.00 123.74 324.00 117.44 325.00 19.651 Clearance Factor Pass-Major Risk 2L-321-2L-321•2L-321 154.90 104.93 154.90 102.58 146.10 44.604 Centre Distance Pass-Major Risk 2L-321-2L-321-2L-321 8,843.84 524.83 8,843.84 92.27 8,575.00 1.213 Clearance Factor Pass-Major Risk 21-322(North)-2L-322-2L-322 1,326.72 45.83 1,326.72 22.30 1,325.00 1.948 Clearance Factor Pass-Major Risk 2L-322(North)-2L-322A-2L-322A 1,337.63 45.88 1,337.63 22.23 1,325.00 1.940 Clearance Factor Pass-Major Risk 2L-323-2L-323-2L-323 154.90 74.95 154.90 72.47 146.10 30.189 Centre Distance Pass-Major Risk 21-323-21-323-2L-323 683.72 76.06 683.72 65.49 675.00 7.198 Clearance Factor Pass-Major Risk 2L-325-2L-325-2L-325 683.71 38.55 683.71 34.81 675.00 10.333 Centre Distance Pass-Minor 1/200 2L-325.2L-325-2L-325 708.61 38.60 708.61 34.76 700.00 10.054 Clearance Factor Pass-Minor 1/200 2L-326-2L-326-2L-326 305.14 29.01 305.14 23.10 300.00 4.906 Centre Distance Pass-Major Risk 2L-326-2L-326-2L-326 355.02 29.40 355.02 22.50 350.00 4.263 Clearance Factor Pass-Major Risk 21-327-2L-327-2L-327 57.80 14.86 57.80 13.62 50.00 11.990 Centre Distance Pass-Major Risk 2L-327-2L-327-2L-327 657.67 18.01 657.67 5.75 650.00 1.469 Clearance Factor Pass-Major Risk 2L-329-2L-329-21-329 383.78 13.22 383.78 7.01 375.00 2.128 Centre Distance Pass-Major Risk 2L-329-21-329-2L-329 433.73 13.63 433.73 6.72 425.00 1.971 Clearance Factor Pass-Major Risk 2L-329-2L-329A•2L-329A 383.78 13.22 383.78 7.01 375.00 2.128 Centre Distance Pass-Major Risk 2L-329-2L-329A-2L-329A 433.73 13.83 433.73 6.72 425.00 1.971 Clearance Factor Pass-Major Risk 2L-330-2L-330-2L-330 508.77 28.74 508.77 19.87 500.00 3.242 Centre Distance Pass-Major Risk 2L-330-2L-330-2L-330 558.81 29.04 558.81 19.53 550.00 3.052 Clearance Factor Pass-Major Risk 06 November,2014- 9:19 Page 3 of 7 COMPASS • I ConocoPhillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 2L-328(Sierra)-2L-328wpO5.1 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 2L Pad-Plan:2L-328(Sierra)-2L-328-2L-328wp05.1 Scan Range: 0.00 to 15,668.56 usft.Measured Depth. Scan Radius is 1,762.91 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft 2L-330-Prelim:2L-330ST1-2L-330ST1wp02 509.42 28.74 509.42 19.91 500.00 3.256 Centre Distance Pass-Major Risk 2L-330-Prelim:2L-330ST1-2L-330ST1wp02 55946 29.05 559.46 19.57 550.00 3.065 Clearance Factor Pass-Major Risk Plan:2L-308(Bertha)-Plan:2L-308-2L-308 wp05 298.30 299.90 298.30 294.58 300.00 56.452 Centre Distance Pass-Major Risk Plan:2L-308(Bertha)-Plan:2L-308-2L-308 wp05 474.17 301.06 474.17 292.95 475.00 37.083 Clearance Factor Pass-Major Risk Plan:2L-308(Bertha)-Plan:2L-308PB1-2L-308PB1w 298.30 299.90 298.30 294.58 300.00 56.452 Centre Distance Pass-Major Risk Plan:2L-308(Bertha)-Plan:2L-308PB1-2L-308PB1w 474.17 301.06 474.17 292.95 475.00 37.083 Clearance Factor Pass-Major Risk Plan:2L-316-Plan:2L-316-2L-316wp06.1 298.30 179.83 29830 174.51 300.00 33.850 Centre Distance Pass-Major Risk Plan:2L-316-Plan:2L-316-2L-316wp06.1 573.56 181.05 573.56 171.39 575.00 18.731 Clearance Factor Pass-Major Risk Kuparuk 2N Pad Plan:2N-312(ShangriLa)-Plan:2N-312-2N-312 wp0 13,148.15 899.70 13,148.15 640.76 13,155.88 3.475 Clearance Factor Pass-Major Risk Kuparuk Tarn Tarn 2-Tarn 2-Tam 2 7,875.29 566.75 7,875.29 409.03 4,150.00 3.593 Clearance Factor Pass-Major Risk Tarn 2-Tam 2-Tam 2 7,874.77 566.45 7,874.77 409.12 4,175.00 3.600 Centre Distance Pass-Major Risk Plan:Kuparuk 2S Pad Survey tool program From To SurveylPlan Survey Tool (usft) (usft) 39.50 1,511.50 2L-328wp05.1 GYD-GC-SS 1,511.50 2,711.50 2L-328wp05.1 MWD 1,511.50 2,711.50 2L-328wp05.1 MWD+IFR-AK-CAZ-SC 2,711.50 3,711.50 2L-328wp05.1 MWD 2,711.50 13,294.16 2L-328wp05.1 MWD+IFR-AK-CAZ-SC 13,294.16 14,311.50 2L-328wp05.1 MWD - 13,294.16 15,668.56 2L-328wp05.1 MWD+IFR-AK-CAZ-SC 06 November,2014- 919 Page 4 of 7 COMPASS S0Inc TVD +0.00 +E/-W 0.00 TFace. Target 3�J JOU 1 3 0.00 0.00 39.50 0.00 0.00 0.00 0.00 21.-328wp05.1 3 761.50 5 25 160.00 761 065 06 5 46 0.00 160 16.0101 350 700 39.50 To 15668.56 4 1111.50 11.25 160.00 1106.69 -68.97 25.10 1.50 0.00 73.35 700 1000 5 1361.50 17.44 156.38 1348.78 -126.26 48.47 2.50 -10.00 135.23 6 1461.50 17.44 156.38 1444,19 -153.72 60.48 0.00 0.00 165.18 7 2733.21 60.66 136.52 2411.50 -761.37 542.77 3.50 -25.00 909.25 1000 1400 8 2753.21 60.66 136.52 2421.30 -774.02 554.77 0.00 0.00 925.48 9:08,November 06 2014 9 3128.91 73.08 130.50 2568.70 -1010.66 805.30 3.62 -25.26 1238.74 1400 1700 0 3155.25 72.81 131.28 2576.42 -1027.14 824.33 3.00 109.73 1261.15 1 12329.21 72.81 131.28 5286.98 -6809.18 7410.88 0.00 0.00 9089.52 1700 2000 SURVEY PROGRAM 2 13294.16 85.20 158.00 5473.90 -7575.41 7948.87 3.00 67.78 10001.49 2L-328 Heel EB 17Sep14 MpiM1 From Depth To Survey/Men roof 3 13314.16 85.20 158.00 5475.57 -7593.89 7956.34 0.00 0.00 10021.42 30.50 1511.50 203285005.1(20-326) GYD-Gass 4 13458.61 90.25 157.84 5481.30 -7727.59 8010.58 3.50 -1.82 10165.71 2000 2400 1511.50 2711.50 20326x005.1(20329) ewe 5 13771 60 90.25 157.84 5479.92 -8017.46 8128.64 0.00 0.00 10478.70 1511.50 2711.50 21,326x051(21-328) MWD.1FR.A5<CAZ-sc 6 13780.16 90.00 158.00 5479.90 -8025.40 8131.85 3.50 147.66 10487.26 2L-328 Inv lection point EB 17Sep14 2400 2710 2711.50 3211.50 2-328w005.1(20328) MWD 2711.50 13294.16 21,329,05.1(21,328) MwDelF22-11acA2-sc 7 13856.17 88.51 158.32 5480.89 -8095.94 8160.13 2.00 167.92 10563.26 1329416 14311,50 20326x005.1(2,328) MWD 8 15668.56 88.51 158.32 5527.90 -9779.53 8829.49 0.00 0.00 12375.01 2L-328 Toe EB 17Sep14 13294.16 15666.56 20326x005.1(20-328) MWDelFR-AK-CAZ SC 2710 4000 CASING DETAILS 4000 5400 TVD MD Name Size 5400 6700 2400.10 2710.23 10-3/4"x 13-1/2" 10-3/4 5473.90 13294.16 7-5/8"x 9-7/8" 7-5/8 6700 8000 5527.90 15668.56 3-1/2"x 6" 3-1/2 8000 9300 9300 10700 12L-3261 10700 12000 12000 13300 0/360 ', 13300 13600 120-3271 /` _,��,,,,Ali 13600 13900 -306330 330 '%H��� ` 30 13900 14200 i �IIIII��p," s'�\ 14200 14500 �iQ����//' 111 opL���� �\ 14500 14800 atifreir_� cam' i� 00 i, ` � 14800 15100 120-329A1 �.�rm i�' �, 4,41,%�iswgive ►,fin�� �k.�art i ��3�lV� ` 'l\ 15100 15400 ��ti\1�%� � �. .ir �_Mr��',���i�l�� `!t� ��- 15400 15700 .Adri'AP'IPr4gli/IP"IIII111411AtieStliiAltit; :„ 60 , oa:4,----,?,v...1,4016.-..v.4.asaritippor#41"2.4o,t, 4„,,,:114%,1,„/ ;..4-11onte,, 12,_„241 �����a � � � ,0` r pn�. �Z4411 �.e ® ,, �r�►►11,;;3.: .4111/tir-A-tu-AV.‘tr:Aligtf.: el O !A It A1�>,.;..-1-141401,: �������r f� �`h�11i1I/�G�� �•�h "(611:i�y /����% i --f,. �Itltl/!/ \��Ql;rl3 "1100 2901 itraviLd�� /11,49114,44-gtvox, •:`�wu �.�5���N�VI�!� ;! >i`�� ���..rte -90/270 �w�. ,� .iA n.a 90 �ev�11t/�►/ .. '�) `�+..® �� ��►r.moi.�/I �i�► � .r®�: ,V;(:1 iii i� �i i i, �� �� 111►�I�D�. iii1011106 rte,:. iii ii ;� ♦ i!3 �i/1// rl kiTn ev04.4i"'F /4a / . ♦ d..*, 21., N -3251 •L�•` aAti' -� a <, 120/240 , pg.�\ll��<A`+ ��rI�A!' r-ma.,o, �'�� ,��,, 120 • , KK .,V,I,tAi '� j��-=�AI,e X11 *►�wri \�� v4�A•opp, ogi,, �taW:`S®i' oa /►111111 0 150 -150/210 ``�1,� '- Kees!^.•_ -, rk` 12L-322A�_ 1N ��FrIe4k•*lt 121-3221-- -180/180 12L-3301 4r 20107.2L 307 2L 307 V2 $ 2L 31317x,..,.20 314.20 310 VO $ x $ Prelim. s0w202v2 -} 9 20 314 0x50*,1.21.0 2551 2031225120 21322 11.1001 20-321 -e- Plan 20 305 110200, an 21.308.20.303 ww5v0 2 22 coon,O.WM 0 3222 20 $ Pun 20 302(30810.5123 20.308551.2 18505 v0 $▪ z 01 v0 $ x $ 2 $ v n. " 15,.00021.20 44 2 44 an. 18 125 221 523 2252,arI 31 -o*2 25 03 156 20.318 12021 20 318 a31520 R 3302.3102.002. -X-▪ 20 310 22 310 20 310 VC -IS- -e- 2 -a Plan. n 2817,28 10,0511220101 20 -I- 20311 20311 -* 20 320 20 320 2010 VO -I- 2 $ 21.328w205 3121123a,2.322Lal220 2 20 320P81 2D -A- 20129 20 3292 20 3292 V2 20 313,22 513.20315 v2 -6- 21.320.21.325552.20 320522 20 94 21.130 20 330.21330 2* 0 ConocoPhillips 2 L-328wp05 Schlumberger Alaska it P. N V? V? TM N J N N tyN 1111110.1149,1.1011 i 1 QC �,I * , , • ' ' l'l' 1....Q ItiprapprippIr i / INVII1Iiiiil!fr 111111 Equivelant Magnetic Distance 1 0 I I I I ` I I I I I I I 1 I I I I I I I II I ill I I 0 4001 800 1200 1600 2000 2400 Displayed interval could be less than entire raptured Depth 28.00 To 15657.06 ANTI-COLLISION SETTINGS Interpolation Method: MD,interval:25.00 Depth Range From: 28.00 To 15657.06 Results Limited By: Centre Distance: 1762.91 GLOBAL FILTER APPLIED:All welipaths within 200'+ 100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 28.00 1500.00 2L-328wp05 (2L-328) GYD-GC-SS 1500.00 2700.00 2L-328wp05 (2L-328) MWD 1500.00 2700.00 2L-328wp05(2L-328) MWD+IFR-AK-CAZ-SC 2700.00 3700.00 2L-328wp05 (2L-328) M W D 2700.00 13282.66 2L-328wp05 (2L-328) MWD+IFR-AK-CAZ-SC 13282.66 14300.00 2L-328wp05 (2L-328) MWD 13282.66 15657.06 2L-328wp05 (2L-328) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2388.60 2698.73 10-3/4"x 13-1/2" 10-3/4 5462.40 13282.66 7-5/8"x 9-7/8" 7-5/8 5516.40 15657.06 3-1/2"x 6" 3-1/2 LEGEND - 2L-307,2L-307,2L-307 V2 -X- 2L-317,2L-317,2L-317 V2 -X- 2L-327,2L-327,2L-327 V2 -e- 2L-307,2L-307L1,2L-307L1 VO -- - 2L-317,2L-317A,2L-317A V6 -e- 2L-329,2L-329,2L-329 V2 - 2L-307,2L-307L2,2L-307L2 VO -e- 2L-318(Libra),2L-318,2L-318 VO -8- 2L-329,2L-329A,2L-329A V2 --e- 2L-307.2L-307L2-01,2L-307L2-01 VO -8- 2L-319,2L-319,2L-319 V4 -e- 2L-330,2L-330,2L-330 V8 - 2L-309,2L-309,2L-309 V5 -- - 2L-320,2L-320,2L-320 VO -0- 2L-330,Prelim:2L-330ST1,2L-330ST1wp02 V2 -X- 2L-309,2L-309PB1,2L-309PB1 V6 $- 2L-320,2L-320PB1,2L-320PB1 VO X Plan:2L-308(Bertha),Plan:2L-308,2L-308 vg05 VO 2L-310,2L-310,2L-310 VO $ 2L-320,2L-320PB2,2L-320PB2 VO -As-- Plan:2L-308(Bertha),Plan:2L-308PB1,2L-308PB1wp05 VO - 2L-311,2L-311,2L-311 VO _e- 2L-321,2L-321,2L-321 V2 - - Plan:2L-316,Plan:2L-316,2L-316 wp05 VO 2L-312(Cassidy),2L-312,2L-312 VO - 2L-322(North),2L-322,2L-322 VO -8- Tarn 2,Tarn 2,Tarn 2 VO -X- 2L-313,2L-313,2L-313 V2 -& 2L-322(North),2L-322A,2L-322A VO -#- Plan:2S-17,Plan:2S-17,25-17wp05(Hybodus)VO -0- 2L-314(Tarawa),2L-314,2L-3I4 VO -A- 2L-323,2L-323,2L-323 V2 $ 2L-328wp05 -X- 2L-314(Tarawa),2L-314PB1,2L-314PB1 VO 2L-325,2L-325,2L-325 V2 - 2L-315,2L-315,2L-315 V2 $ 2L-326,2L-326,2L-326 VO • • RECEIVED STATE OF ALASKA f ALASKA OIL AND GAS CONSERVATION COMMISSION NOV-1 8 2014 PERMIT TO DRILL 20 AAC 25.005 AO "'C la.Type of Work: lb.Proposed Well Class: Development-Oil ❑✓ - Service-Winj ❑ Single Zone E. 1c.Specify if well isdroposed for: Drill Q- Lateral ElStratigraphic Test ❑ Development-Gas ElService-Supply ❑ Multiple Zone❑ Coalbed Gas lik Gas Hydrates❑ Redrill ❑ Reentry❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal fill Shale Gas ❑ 2.Operator Name: 5. Bond: .LJ Blanket ❑Single Well 11.Well Na e and Number: ConocoPhillips Alaska, Inc.. Bond No. 59-52-180 • Q(i 2L-328• 3.Address: 6.Proposed Depth: 12. Fi d/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 15668' - TVD: 5528' ' Kuparuk River Field• 4a. Location of Well(Governmental Section): 7.Property Designation(Lease umber: Surface:229'FNL,909'FEL,Sec.22,T1ON, R7E, UM • Pr�1t•98 ADL 380052,380E3-��3 Tarn Oil Pool• Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2912'FNL,3731'FEL, Sec.25,T1ON,R7E, UM x 4602 1/1/2015 Total Depth: 9.Acres in Property: 14.Distance to 4734'FNL,2655'FEL,Sec.25,T1ON, R7E, UM 5120 Nearest Property: 2655' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: • 155 feet 15.Distance to Nearest Well Open Surface:x- 460742 y- 5927618 Zone- 4 • GL Elevation above MSL: , % 115 feet to Same Pool: none, 16.Deviated wells: Kickoff depth: 400 ft.• 17.Maximum Anticipated ressures in psig(see 20 MC 25.035) b Maximum Hole Angle: 90° ,deg Downhole:3400 ig . Surface:2859 psig • 18.Casing Program: Specifications Top - Setti pth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD MD TVD (including stage data) 24" 16" 62.6# H-40 Welded 91' 28' - rr 30' 130' driven 13.5" 10.75" 45.5# L-80 Hydril 563 2671' 28' �, 2'8; \ x` 22710' 2400` 1132 sx AS C, 195 sx 9.875" 7.625" 29.7# L-80 Hydril 563 12126' 28' 12165' 5238' 984 sx GasBLOK 9.875" 7.625" 39# rN-110S. Hydril 563 500' 12165 \5238' 12665' 5375' included with the above r 6.5" 4.5" 12.6# L-80 IBTM 3154' 12515'/ 5339' 15669' 5528' frac sleeves 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) tive Depth MD(ft): Effective Depth TVD(ft): Junk(measured) Casing Length Size ment Volume MD TVD Conductor/Structural JJJJ���� Surface 1 �/ Intermediate Production Liner Perforation Depth MD(ft): / !� Perforation Depth TVD(ft): 20.Attachments: Property Plat 11 BOP S i Y r---, Drilling Program ❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter4ketch❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements ❑✓ 21.Verbal Approval: Commission Representative Date: 22. I hereby certify that the foregoing is true andAorrect. Contact Mike Callahan @ 263-4180 .M-6- Email Mike.Callahan@coo.com Printed Name G. L. Alvord Title Alaska Drilling Manager Signature Aq.0.-, Phone:265-6120 Date 11117(20(4-- Commission ¢Commission Use Only Permit to Drill API Number: Permit Approval See cover letter Number: Rill- i I 50- /Q3- Qo 7 -OQ l0c Date: for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed m bane,gas hydrates,or gas contained in shales: EX Other: Samples req'd: Yes [� No [J Mud log req'd: Yes❑ No int H2S measures: Yes �]f No Directional svy req'd: Yes d No Spacing exception req'd: Yes ❑ No Inclination-only svy req'd: Yes❑ No APPROVED BY THE Approved by: COMMid 2N V NM, Date: Form 10-401 (Revised 10/2012) This permit is valid {o t s approval(20 AAC 25. 5( )) o')�(�j 111�1/1 y S RECEIVED 11) NOV 182014 Post Office Box 100360 AOGCC ConocoPhillips Anchorage,Alaska 99510-0360 Phone(907)263-4180 Email: mike.callahan(aconocophillips.com November 13, 2014 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 Re: Application for Permit to Drill 2L-328 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill for the onshore production well slot 2L-328 from the Tarn 2L drilling pad. This well is intended to be a horizontal producing well from the Bermuda horizon. The intended spud date for this well is January 1st,2015 using Doyon 25. ( When the Doyon 25 rig moves onto 2L-328,the proposed plan is to nipple up and test the diverter system utilizing the existing 16"conductor, spud the well with a 13-1/2" bit, drill to the surface casing point,then run and cement the 10-3/4"45.5#L-80 Hydril 563 surface casing in place. A 9-7/8"bit will be made up and the surface casing drilled out. The well will then be drilled down to the intermediate casing point(topsetting the f Bermuda)where a string of 7-5/8"29.7#L-80 Hydril 563 casing will be run and cemented in place. A 6-1/2" bit will be run to drill the horizontal lateral portion of the well to TD. A 4-1/2"production liner with swell packers and frac sleeves will be slid in position for future frac operations. Finally, the upper completion will consist of 3-1/2"gaslifted 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. A proposed drilling program 3. A drilling fluids program summary. 4. Proposed Completion Diagram 5. Pressure information as required by 20 ACC 25.035(d)(2). 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b). 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. Sincerely, Mike Callahan Drilling Engineer Application for Permit to Drill,Well 2L-328 Saved: 13-Nov-14 2L-328 Application for Permit to Drill Document trl ConocoPhillips 'r Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (f)) 3 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) 3 Requirements of 20 AAC 25.050(b) 4 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) 4 4. Drilling Hazards Information (Requirements of 20 AAC 25.005 (c)(4)) 4 ASP CALCULATIONS 4 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25,005(c)(5)) 5 6. Casing and Cementing Program (Requirements of 20 AAC 25,005(c)(6)) 5 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) 5 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) 5 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) 6 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) 6 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) 6 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) 6 13. Proposed Drilling Program (Requirements of 20 AAC 25.005 (c)(13)) 7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal7 (Requirements of 20 AAC 25.005 (c)(14)) 7 2L-308 APD Page 1 of 14 Printed: 13-Nov-14 ORIGINAL • Application for Permit to Drill,Well 2L-328 Saved: 13-Nov-14 15. Attachments 8 Attachment 1 Directional Plan 8 Attachment 2 Drilling Hazards Summary 8 Attachment 3 Proposed Well Schematic 8 Attachment 4 Cement Summaries 8 2L-308 APD Page 2 of 14 Printed:13-Nov-14 ORIGINAL App!cation for Permit to Drill,Well 2L-328 Saved: 13-Nov-14 1. Well Name (Requirements of 20 AAC 25.005(f)) The well for which this application is submitted will be designated as 2L-328. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This well is planned as a horizontal producer to improve Bermuda oil recovery and pattern sweep efficiency in the newly discovered pay from the 2010 seismic program at Tarn. The Doyon 25 rig will drill a 13-1/2" surface hole and case with 10-3/4", L-80 with premium Hydril 563 connections. The 9-7/8" intermediate section will be drilled to+/-250' MD above the Bermuda sand, and 7-5/8" casing will be run to top-set the reservoir.PThe rig will then drill a 6-1/2" horizontal production lateral. A 4-1/2" production liner, equipped with swell packers and frac sleeves will be run into the open hole for the lower completion. Finally, a 3-1/2" gas-lifted tubing assembly will be run for the upper completion. Location at Surface 229.27' FNL, 908.81' FEL, Sec 22, T1ON, R7E, UM NAD 1927 RKB Elevation 154.9'AMSL Northings: 5,927,617.58 Eastings: 460,741.94 Pad Elevation 115.4'AMSL Location at 7 5/8" Intermediate Csg Pt. 2529.27' FNL, 3531.86' FEL, Sec 25, T1ON, R7E, UM Nad 1927 Measured Depth, RKB: 12,665' Northings: 5,920,001.28 Eastings:468,650.12 Total Vertical Depth, RKB: 5,375' Total Vertical Depth, SS: 5,220' Location at Top of Productive 2,911.73' FNL, 3731.49' FEL, Sec 25, T1ON, R7E, UM Interval (Bermuda) Nad 1927 Measured Depth, RKB: 12,858' Northings: 5,920,383.74 Eastings:468,450.49 Total Vertical Depth, RKB: 5,415' Total Vertical Depth, SS: 5,260' Location at Total Depth 4734.39' FNL, 2654.72' FEL, Sec 25, T1ON, R7E, UM (Toe) Nad 1927 Measured Depth, RKB: 15,668' Northings: 5,917,792.81 Eastings: 469,519.05 Total Vertical Depth, RKB: 5,528' Total Vertical Depth, SS: 5,373' 2L-308 APD Page 3 of 14 Printed:13-Nov-14 ORIGINAL • Application for Permit to Drill,Well 2L-328 Saved: 13-Nov-14 Requirements of 20 AAC 25.050(b) Please see Attachment 1: Directional Plan The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference BOP schematics on file for Doyon 25. 4. Drilling Hazards Information (Requirements of 20 AAC 25.005(c)(4)) The following presents data used for calculation of anticipated surface pressure(ASP) during drilling of this well: • NOTE: The Doyon 25 5000 psi BOP equipment is adequate. Test BOP to 3500 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) (A) ASP is determined as the lesser of 1)surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2)formation pore pressure at the next casing point less a gas gradient to the surface as follows: The maximum potential surface pressure (MPSP)wile drilling 2L-328 is calculated using a maximum possible reservoir pressure of 3,400 psig (12.1 ppg), a gas gradient of 0.10 psi/ft, and the estimated depth of the Bermuda formation at 5,415' TVD. 1) ASP = [(FG x 0.052)—0.1]D Where: ASP =Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052= Conversion from lb. /gal to psi/ft 0.1 = Gas gradient in psi/ft D =true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP—(0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. MPSP/MASP calculation ASP = [(FG x 0.052)—0.1] D = [(14.5 x 0.052)—0.1]x 5,415' = 3,541 psi OR ASP = FPP—(0.1 x D) =3,400—(0.1 x 5,415') = 2,859 psi (B)Data on potential gas zones; The well bore is not expected to penetrate any gas zones. 2L-308 APD Page 4 of 14 Printed:13-Nov-14 ORIGINAL • App'cation for Permit to Drill,Well 2L-328 Saved: 13-Nov-14 (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; The Tarn reservoir model predicts the 2L-328 will find reservoir pressure in the range of 2,200 to 3,400 psig, with expected at-2500 psig. We will continue to monitor pressures as the spud date approaches. 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5)) Drill out from casing shoe and perform LOT or FIT in accordance with the Kuparuk LOT/ FIT procedure that ConocoPhillips,Alaska has on file with the Commission. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) Casing and Cementing Program Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Conn. (ft) (ft) (ft) Cement Program 16 24 62.6 H-40 Welded 91' Surf 130'/130' N/A Hydril Cemented to Surface with 10-3/4 13-1/2 45.5 L-80 563 2,671' Surf 2,710/2,400' 1,132 sx ASC Lead 11 ppg 195 sx Tail Slurry 12 ppg 7-5/8 9-7/8 29.7 L-80 Hydril 12,126' Surf 12,165'/5,238' 563 Cement Top planned @ 8,900'MD/ TN- 4,274'TVD. Cemented w/ 7-5/8 9-7/8 39 110S H56311 500' 12,165'/5,238' 12,665'/5,375' 984 sx GasBLOK Class G 15.8 ppg N/A,will have swell packers&frac 4 1/2 6 1/2 12.6 L-80 IBTM 3,154' 12,515'/5,339' 15,669'/5,528' sleeves Casing / Liner Design: The 85% collapse and burst ratings are listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 10-3/4" 45.5 L-80 3 Hyd563 2,480 psi 2,108 psi 5,210 psi 4,429 psi 7-5/8" 29.7 L-80 3 Hyd563 4,790 psi 4,072 psi 6,890 psi 5,857 psi 4.5" 12.6 L-80 3 IBTM 7,500 psi 6,375 psi 8,440 psi 7,174 psi 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Please reference diverter schematic on file for Doyon 25. 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Drilling will be done using Fresh water and seawater-based LSND mud systems having the following properties: 2L-308 APD Page 5 of 14 Printed:13-Nov-14 ORIGINAL • Application for Permit to Drill,Well 2L-328 • Saved: 13-Nov-14 Surface Intermediate Production 13-1/2" hole 9-7/8" hole 6-1/2" hole 10-3/4" Casing 7-5/8" Casing 4-1/2" Liner Density 9.6 - 10 ppg 9.6— 10.0 ppg 10.0—12.2 ppg r. YP 60-80 18—28 12- 18 Funnel Viscosity(sec) 75—250 40-55 PV 20-60 20 -25 18-22 Initial Gels 10-35 4—8 5-9 10 minute gels <18 <4 API Filtrate NC—8.0-10 cc/30 min 4-12cc/30 min <10 cc/30 min HPHT Fluid Loss at 160 8.5—9.0 <12 <5 PH 9.0-9.5 9-9.5 9.3- 10 Chlorides <1000 9.0— 10 Surface Hole Section: Fresh water Drilplex spud mud system. Standard high viscosity fresh water/ gel spud mud will be used for the surface interval. Viscosity will be reduced prior to cementing. Maintain mud weight between 9.6 - 10.0 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: LSND water-based mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity through the sticky upper clays. There is potential for lost circulation, particularly after the Campanian and Iceberg zones are penetrated. Maintain mud weight at or above 9.6 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required)will all be important in maintaining wellbore stability. Production Hole Section: LSND/KLASHIELD water-based mud system. Ensure good hole cleaning by maintaining low end rheology and pumping of regular sweeps. Maximize fluid annular velocity. There is potential for lost circulation in the target Bermuda reservoir. Maintain minimum mud weight of at least 10.0 ppg and be prepared to add loss circulation material. Be prepared to weight up if higher than expected pore pressure is encountered. Good filter cake quality, hole cleaning and maintenance of low drill solids will all be important in maintaining wellbore stability. Diagram of Doyon 25 Mud System is on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an offshore well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 2L-308 APD Page 6 of 14 Printed:13-Nov-14 ORIGINAL 111 Application for Permit to Drill,Well 2L-328 • Saved: 13-Nov-14 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) The proposed drilling program is listed below. Please refer to Attachment 3: Well Schematic. 1. MIRU Doyon 25 on 2L-328 existing 16" conductor. 2. NU and function test diverter system and prepare 9.6 ppg fresh water Drilplex spud mud. 3. Place warning signs on location indicating the rig has diverter equipment rigged up. 4. Cleanout to below the conductor to get 13-1/2" BHA below ground level. 5. Spud and directionally drill 13-1/2" hole to the 10-3/4" surface casing point(2,710' MD/2,400' TVD) according to the directional plan. Run MWD/LWD logging tools in drill string (GR/RES/PWD/Gyro while drilling) and on-site mud logging for directional monitoring and formation data gathering. 6. Run and cement 10-3/4"45.5#L-80 Hydril 563 casing to surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job if losses do not occur. Displace cement with mud. Perform top job if required to bring cement to surface. 7. Nipple down diverter and install wellhead and test to 5000 psi. Notify State 24 hrs prior to BOPE test. Nipple up BOPE and test to 3,500 psi. Record results. 8. Shut in BOP's and pressure test surface casing to 3,000 psi per AOGCC regulations. Record results. 9. Drill out cement and 20' minimum to 50' maximum of new hole. Perform LOT. 10. Directionally drill 9-7/8" intermediate hole to 12,665' MD/5,375' TVD. Run MWD/LWD logging tools in drill string (GR/RES/NEUT/DENS/PWD)`'with on-site mud logging and field geologist for directional '/ monitoring and formation data gathering. 11. Circulate bottoms up to clean hole, POOH and lay down 5" drill pipe. 12. RU and run 7-5/8", 29.7#and 39#, L-80 and Tenaris110SS with Hydril 563 connections on the intermediate casing to TD and cement in place with a minimum of 500' of cement above the C37 formation. 13. MU 6-1/2" bit and RIH on 4" drill pipe. 14. Directionally drill 6-1/2" production hole to 15,669' MD/5,528' TVD as per directional program. Run MWD/LWD logging tools in drill string (GR/RES/Neut/DENS/PWD/Periscope/Stethoscope/Sonicscope for CBL evaluation) for navigational monitoring and formation data gathering. POOH 15. POOH, and RU casing crew and cementers. 16. MU and run a 4-1/2" liner to TD and set the ZXP liner top packer on top of the Flex Lock liner hanger leaving a 150' liner lap. 17. Perform a pressure test on the liner top packer, POOH and LD 4" drill pipe 18. Run 3-1/2" completion tubing with premier packer and seals and set packer at+/- 12,515' MD/5,338' TVD. 19. ND BOP and NU tree. Test tree and freeze protect annulus. Rig down and move out rig. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005(c)(14)) 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 DS1 B).J 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. 2L-308 APD Page 7 of 14 Printed: 13-Nov-14 ORIGINAL • App'cation for Permit to Drill,Well 2L-328 Saved: 13-Nov-14 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Proposed Well Schematic Attachment 4 Cement Summaries 2L-308 APD Page 8 of 14 Printed:13-Nov-14 ORIGINAL • • 0 1.421- NI 4•4 q, III IRMA2 Ill ti ir,MI as Es E ori Q.. 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Lit-WON . , 0 • 2L-328 wp05 Surface Location -------1 ,,.. n CPA1 Coordinate Convert- From: To: Datum: 1NAD27 I Region: l1 alaska .71 Datum: I NAD27 .... Region: lalaska zi C Latitude/Longitude 'Decimal Degrees .2:1 C Latitude/Longitude DecimalDegrees —71 C UTM Zone: I 1- South C UTM Zone: I True E South a State Plane Zone: 14 71 Units: 1us-ft 7: C State Plane Zone: [True w1 Units: lus-ft C .egal Description(NAD27 only) a Legal Description(NAD27 only) Starting Coordinates: Legal Description X: 1460741.94 Township: 1 1010 F4 Range: I 1007 FC1 Y: 15927617.58 Meridian: lu , Section:122 IFNL . f229.27050 1EEL . 1908.80735 1 Ii Transform ii Quit I Help 1 I 2L-328 wp05 7-5/8" Casing Shoe 4-- In, CPA I Coo-dinate Con...erter --From: To: Datum: 1NAD 27 ..7.1 Region: lalaska .1.1 Datum: NAD27 .., Region: idclaskTi -.1 C Latitude/Longitude 'Decimal Degrees 2: C Latitude/Longitude 1Decimal Degrees __71 C UTM Zone: 1 E South C UTM Zone: 1True E South (;" State Plane Zone:F---.-A, Units: 1L1;47,A. 1True . Units: [ ft ....d C State Plane Zone: C Least Description(NAD27 only) a' Legal Description(NAD27 only) -Starting Coordinates: Legal Description I X: 1468650.12 Township: l ion IN:LI Range: Fiji- JE1 I 1 Y: 15920001.28 Meridian: F-----E. Section:125 FrNIT 71 12529.2716 ii-- 1 3531.8584 Transform Quit Help 1 NIMINIIIIC ,t ORIGINAL i • 2L-328 wp05 TD 1 ' 1 I*07E344 c rZt CPA:Coordinate Converter o I From: -------...._._---------- To: _. Datum: INAD27 �1 Region: lalaska J Datum: INAD27 Nr Region: ialaska i- Latitude/Longitude (Decimal Degrees zi C Latitude/Longitude 'Decimal Degrees " UTM Zone:1 r South C UTM Zone: True r South t+' State Plane Zone:1-4----" . J Units: 1us-ft . C State Plane Zone: (True ;-I Units: Ius•ft _I i C' Legal Description INAD27 only) 6- Legal Description(NAD27 only) i 1 Starting Coordinates: -- ; Legal Description ---- - X: 1469519.05 Township: 10-1(1- IN Range: 007 IE Y: 15917792.$1 Meridian: IU Section:125 I FNL 14734.3916 FEL . 12654.7189 1 Transform Quit I Help 1 • • } 2L-328 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 Moderate If observed -control drill, reduce pump rates, reduce drilling fluid temperatures, Additions of Lecithin. Gravel/Sand Sloughing Moderate 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 Trips (use of 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 9-7/8" Hole / 7-5/8" Casing Interval Event Risk Mitigation Strategy Level Campanian/Iceberg Sands Low Control with higher MW and proper drilling practices. High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with higher MW's required PWD tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Abnormal Reservoir Pressure Low Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills, PWD Tools, Increase mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Lost Circulation Low Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. 6-1/2" Hole /4-1/2" Horizontal Liner Interval Event Risk Mitigation Strategy Level High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with higher MW's required PWD tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Abnormal Reservoir Pressure Low Plan to top set the 7-5/8" intermediate casing above the Bermuda placing the entire intermediate section behind pipe prior to drilling the Bermuda Mud weight will be used for offsetting formation pressure Lost Circulation Low Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. ORIGJ \ AL 2• L-328 Sierra w/o Pilot ♦ Grass Roots TODset t of Hole Horizontal Multi-Stage Frac'd Producer ConocoPhillips Proposed Wellbore Schematic WP05.1 eCAMERON 4-%"tree,to. •oint is 4-W 12.6#IBTM,crossed over(for frac equipment) lJ 166::62.6#H 40 Callahan 11/10/2014 130' MD 3''A"Camco DS Nipple 2.875" 500'MD Fresh Water 13-1/2"Surface Hole DrilPlex 9.6 PPG 3%"x 1"Camco KBMG1111 Surface Casing: 10-3/4"45.5#L-80 Hydril 563 2,710' MD/2,400'TVD @ 60° 3'/:"x 1"Camco KBMG i Campanian Top 3000:MD i2,s2 Tv. LSND 9.6-10.0 PPG Tubing: Keep up with 3'"x1"Camco KBMG1111 3-'/2' 9.3#L-80 EUE8RD Dilution 4-'/z' 12.6#L-80 IBTM top joint to surface 9-7/8" Intermediate Hole Estimated top of cement @+/-8,905'MD (500'above C37)7774,50-13 1/2"x 1"Camco KBMG774,50-1 iceberg Top 9j613 M D(a 54a'TVD) Baker CMU Sliding Sleeve CLOSED w/2.812"Camco'DS'Profile 10'above Packer Down hole gauge-12,000'MD 3.5"x 7-5/8",Baker Premier Packer 12,485'MD 3'''N'Camco D Nipple 2.75"nogo 7-5/8"x 4-'4"Baker Flex Lock Liner hanger :..- ZXP liner top packer w/RS Nipple, 12,515 MD Intermediate Casing Topset: 7-5/8"29.7#L-80&500'TN 1 l 0ss 39#—all Hydril 563 connections Top of Bermuda 12,911'MD 5,425'TVD 12,665' MD/5,375'TVD @ 77° ,trr:I un,iing QRSa cer 8✓eU 6 1/2' Prodl ction Hole �:fnee i� Packers IL,4SEiE�t D` Heel 10 4 PPG1nN4 1/2m 12 6# - • H521 O O O O O • .. �.. � � Bermuda Pore Pss roure : Pt^oductton Liner.@ 9 nmmN 1014'/ € 4 2" 12,6 L-80:IBTM ( 00':4 2r500 . 40O po#g) 12;615 MD to 15,669 MD 5;319:1)/D to 5528 TVQ . Peri€gr6ted Pup ORIGINAL • ,= 2L-328 Schlumberger CemCADE Preliminary Job Design 10 3/4" Surface Casin. (V1 Preliminary Job Design based on limited input data.For estimate purposes only. Volume Calculations and Cement Systems Rig: Doyon 25 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 2210' MD. Client:CPAI Revision Date: November 13, 2014 Prepared by:Jenna Houston Location:Anchorage,AK Lead Slurry Minimum pump time: -225 min. (pump time plus 120 min.) Phone: (907)263-4207 DeepCRETE @ 11.0 ppg- 1.91 ft3/100 lb sk Mobile: (907)223-8916 email:jhouston2@slb.com 0.638 ft3/ft x 106 x 1.0 (0%excess) = 68 ft3 0.3637 ft3/ft x (1405-106) x 3.50 (250%excess) = 1654 ft3 < TOC at Surface 0.3637 ft3/ft x (2210-1405) x 1.50 (50%excess) = 440 ft3 1654 ft3+440 ft3 + 68 ft3= 2162 ft3 2162 ft3/ 1.91 ft3/sk = 1132 sks(-1145 sks) Tail Slurry Minimum pump time: -180 min. (pump time plus 120 min.) 12.0 ppg DeepCRETE- 1.63 ft3/1001b sk 0.3637 ft3/ft x (2710-2210) x 1.50 (50%excess) = 273 ft3 0.54000 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 200 sks BHST= 70°F, Estimated BHCT =76°F. (Based on 2.1 °F/100 ft. from base permafrost) PUMP SCHEDULE Stage Cumulative Pump Rate Stage Time < Base Permafrost at Stage (bpm) Volume (min) Time 1,405'MD(-1,390'TVD) (bbl) (min) MUDPUSH II 7.0 100.0 14.3 14.3 Pause 0.0 0.0 5.0 19.3 11 ppg DeepCRETE 7.0 384.8 55.0 74.3 12.0 ppg Tail Slurry 7.0 56.3 8.0 82.3 Pause 0.0 0.0 5.0 87.3 < Top of Tail at Water 7.0 10.0 1.4 88.7 2,210'MD Pause 0.0 0.0 5.0 93.7 Drilplex Mud 8.0 232.9 29.1 122.8 Drilplex Mud 3.0 10.0 3.3 126.1 MUD REMOVAL Expected Mud Properties:9.6 ppg, Pv<20, Ty<20 < 10 3/4",45.5#casing Spacer Properties:10.5 ppg MudPUSH* ll, Pv= 17-21, Ty=20-25 M. in 13.5"OH Centralizers: As per CPAI program. TD at 2,710'MD (2,400'TVD) Mark of Schlumberger ORIGINAL • • 2L-328 Schlumberger CemCADE Preliminary Job Design 7-5/8" Intermediate Casing (V1) Preliminary Job Design based on limited input data.For estimate purposes only. Rig: Doyon 25 Location: Kuparuk Client:CPAI Revision Date: November 13,2014 Volume Calculations and Cement Systems Prepared by:Jenna Houston Volumes are based on 40%excess. The top of the tail slurry is designed to be Location:Anchorage,AK Phone: (907)263-4207 at 8905' MD. Mobile: (907)223-8916 email:jhouston2@slb.com Tail Slurry Minimum pump time: '-265 min. (pump time plus 120 min.) 15.8 ppg GASBLOK slurry+adds- 1.17 ft3/sk 0.2148 ft3/ft x (12665'-8905') x 1.40 (40%excess) = 1131 ft3 0.2394 ft3/ft x 80' (Shoe Joint) = 20 ft3 1131 ft3+20 ft3= 1151 ft3 1151 ft3/ 1.17 ft3/sk = 984 sks Previous Csg. Round up to 995 sks < 10-3/4",45.5.#casing at 2710'MD BHST = 133°F, Estimated BHCT= 105°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) CW100 6.0 40.0 6.7 6.7 MUDPUSH II 6.0 40.0 6.7 13.4 Pause 0.0 0.0 5.0 18.4 15.8 ppg GASBLOK 6.0 204.8 34.1 52.5 Slurry Pause 0.0 0.0 5.0 57.5 Fresh Water 6.0 10.0 1.7 59.2 Pause 0.0 0.0 5.0 64.2 Mud 6.0 556.4 92.7 156.9 Mud 3.0 10.0 3.3 160.2 < Top of Cement at -8905'MD MUD REMOVAL Expected Mud Properties:'-10.0 ppg, Pv <20, Yield Point<25. < 7-5/8",29.7#casing x Spacer Properties:11.5 ppg MudPUSH* Il, Pv=20 -24, Yield Point =37-41 500'of 7-5/8"39#casing Centralizers: As per program in 9-7/8"OH TD at-12665'MD (5376'TVD) * Mark of Schlumberger ORIGINAL S Loepp, Victoria T (DOA) From: Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent: Thursday, December 18, 2014 2:43 PM To: Loepp, Victoria T (DOA) Subject: RE: KRU 2L-328(PTD 214-189) Anti-collison & Diverter layout Follow Up Flag: Follow up Flag Status: Flagged Victoria,these two wells were flagged because they fall below a 1.5 separation factor on their ellipses, but they are still above our minimum required separation factor of 1.0,so they have been minor risked. We will plan to get a little bit ahead of our planned line as we approach the wells to avoid a situation where the separation factor falls below 1.0. We should also be able to see if we are approaching too close well in advance due to MWD interference from the casing of the other well. If we get in a situation where we are off of our directional plan causing us to fall below a separation factor of 1.0,we will shut-in the offset well and further evaluate before proceeding. Please let me know if this answers your question or if you would like any more information. Thanks, Mike From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@ alaska.gov] Sent: Thursday, December 18, 2014 11:33 AM To: Callahan, Mike S Subject: [EXTERNAL]RE: KRU 2L-328(PTD 214-189) Anti-collison &Diverter layout Mike, In the anti-collision report,what mitigation factors will be used to minor risk collision with 2L-318 and with 2L-325? Were these major risk failures prior to the minor 1/200 risk? Thanx, Victoria From: Callahan, Mike S [mailto:Mike.Callahan@conocophillips.com] Sent: Thursday, December 18, 2014 10:18 AM To: Loepp, Victoria T(DOA) Subject: RE: KRU 2L-328(PTD 214-189) Anti-collison & Diverter layout Victoria, please see the attached AC report and pad layout showing the diverter route. Our preferred orientation for the diverter is straight out of the back of the rig(the "north facing line), but if the cable trays at the pipe rack interfere with that we may orient it along our second option, shown as the—southwest line. That decision will be made when they rig up on the well. Please let me know if this answers your questions and if you need anything else from me. Thanks, Mike Callahan Drilling Engineer ConocoPhillips Alaska 1 S • Loepp, Victoria T (DOA) From: Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent: Thursday, December 18, 2014 10:18 AM To: Loepp, Victoria T (DOA) Subject: RE: KRU 2L-328(PTD 214-189) Anti-collison & Diverter layout Attachments: 2L-328 Pad Areal Photograph_Diverter Layout.pdf; 2L-328wp05.1 - Anticollision Report.pdf Victoria, please see the attached AC report and pad layout showing the diverter route. Our preferred orientation for the diverter is straight out of the back of the rig (the north facing line), but if the cable trays at the pipe rack interfere with that we may orient it along our second option, shown as the southwest line. That decision will be made when they rig upon the well. Please let me know if this answers your questions and if you need anything else from me. Thanks, Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office: (907) 263-4180 Cell: (907) 231-2176 From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Thursday, December 18, 2014 9:08 AM To: Callahan, Mike S Subject: [EXTERNAL]KRU 2L-328(PTD 214-189) Anti-collison & Diverter layout Mike, Please provide the following: 1. Anti-collision report-Please provide the summary page of the anti-collision report and a traveling cylinder plot 2. Diverter layout sketch - Please provide a diverter route schematic showing the rig on the pad and the route with approximate dimensions for the diverter. Show at least a 90' radius around the diverter outlet. This will have to be a part of all PTD application submissions in the future. Thanx in advance, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp at7alaska.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 1 ~ },gi3 KC f CzPN�W}� 2i.'" l e Y'12'4J' F- 1 ., x 1 ',1.-kA 1 ti.' tt } 1] Z, i a _ �l t 751 1 Lti2 • • u, t 1_ %t } s • 1,F t ,. „ •J 4 1 Z`1 .n . 1 .: F- ti t .' .4. Ali - % • J - 1S .”' Q. 1 S •5A t. - '. ` 1' l``5s } ' 1 ` l 18 } it r:,\ y1ys} i•-'- ry x. 1 Wig ; Qi E. . U �tt • 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: ITU. PTD: 021 — L I" Development Service Exploratory Stratigraphic Test _Non-Conventional FIELD: I4 4. ►VW— POOL: I\i U& k1/4/4.4.r' 1("Ain I Check Box for Appropriate Letter/ Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. , API No. 50- - - - in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. 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 name Pilot Hole ( 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 Spacing Exception conservation 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. 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Technical Report Title Date Client: ConocoPhillips Alaska, Inc Field: Kuparuk River Unit Rig: Doyon 25 Date: April 03, 2015 Surface Data Logging End of Well Report 2L-328 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 25 Well: 2L-328 Field: Kuparuk River Unit Borough: North Slope Borough State: Alaska Country: United States API Number: 50-103-20698-00-00 Sperry Job Number: AK-AM-0902171410 Job Start Date: 20 February 2015 Spud Date: Month 2013 Total Depth: 16168’ MD, 5530’ TVD North Reference: True Declination: 18.73° Dip Angle: 80.78° Total Field Strength: 57545 nT Date Of Magnetic Data: 10 February 2015 Wellhead Coordinates N: North 70° 12’ 46.357” Wellhead Coordinates W: West 150° 19’ 10.941“ Drill Floor Elevation 39.5’ Ground Elevation: 115.4’ Permanent Datum: Mean Sea Level SDL Engineers: Craig Amos, Macy Williams, Todd A. Wilson SDL Sample Catchers: Kyle Blazian, Kruz Kleewain Company Geologist: Matt Smith, Kristin Hannon Company Representatives: Granville Rizek, Paul Smith, Larry Hill, Rob Rehinhardt SSDS Unit Number: 125 DAILY SUMMARY 02/20/2015 SDL arrive on location. Finish drilling surface to 2517' MD. Circulate and monitor well. Begin pulling out of hole. 02/21/2015 Continue pulling out of hole. Lay down BHA. Pick up and begin running in hole with 10.75" casing to 2450' MD. 02/22/2015 Pump Cement, flush lines, and pick up casing spool. Clean out surface stack and weld on cameron hanger. 02/23/2015 Wait on emergency hanger slip on weld to cool and test seal. Orient casing spools, install riser, and rig up MPD equipment. 02/24/2015 Continue rigging up MPD equipment. Test BOP. Blow down choke lines. Test MPD. 02/25/2015 Continue installing MPD equipment. Test MPD equipment. Pick up BHA and run in hole with double from 1500’ MD to 2364’ MD. Perform casing test and begin drilling out shoe. 02/26/2015 Complete Mud displacement, FIT Test, commence drilling intermediate section of well at 13:30 on 26th of February. Drill from 2537’ to 3478’ MD. At 23:30 pick up off bottom and being trip to shoe to service top drive loop. Gas: The max gas was 351 units at 3085’ MD and the average drilling background gas was 70 units. Fluids: There were no losses down hole. Geology: The samples have been predominantly Claystone, medium grey to dark grey, very soft to soft, amorphous to plastic, moderately silty throughout, slightly calcareous with a good trace of glauconite. 02/27/2015 Continue to TIH after top drive repair, circulate a bottoms up after trip, gas of 4907 units seen, gas went back to background levels after a full circulation. Continue to drill ahead to 5672' MD at midnight. Low background gas of less than 100 units seen, with no large formation gas peaks. No connection gas has been present. Current formation is Sandy Siltstone with occasional Sandstone beds. A harder Calcareous Sandstone bed was encountered at 5502' MD which produced a slower ROP. Gas: The max gas was 139 units at 5613’ MD and the average drilling background gas was 72 units. Fluids: There were no losses down hole. Geology: The samples have been predominantly Siltstone with inter bedded sands, clear – off white, occasionally grey, very fine to fine grained, sub rounded to sub angular, moderately to well sorted, slightly arenaceous, predominantly loose with occasional calcareous cement. 02/28/2015 Drilled from 5672' MD to 7567' MD. Circulate and reciprocate pipe while waiting on Phase 3 Conditions. Gas: The max gas was 116 units at 6719’ MD and the average drilling background gas was 64 units. Fluids: There were no losses down hole. Geology: The samples have been predominantly Siltstone, light to medium grey, occasionally brown grey and light brown, firm, rarely hard, blocky to crumbly, amourphous in places, slightly calcareous, argillaceous throughout, good trace pyrite. 03/01/2015 Circulate and reciprocate pipe while waiting on Phase 3 Conditions. Phase 3 conditions expected to be in place until at least 6am. Gas: The max gas was 28 units at 7567’ MD and the average was 20 units. Fluids: There was 0 barrels of water based mud lost down hole. 03/02/2015 24 hr Recap: Circulate and reciprocate till 6am, begin TOOH to 2470' MD, install MPD bushing. Begin TIH currently at 6300' MD. Max Trip gas of 147' units seen so far, a full bottoms up circulation has not been completed yet. Gas: The max gas was 147 units while tripping and the average background gas was 28 units. Fluids: There was 0 barrels of water based mud lost down hole. 03/03/2015 Complete TIH to bottom, circulate begin drilling from 7564' MD to 8175' MD, experience pack off event loses of 63 bbls, establish circulation and begin tripping out of hole to 7400' MD, TIH to bottom and establish circulate, dilute mud and recommence drill from 8175' MD to 8330' MD. Trip gas of 274 units seen whilst circulating at 7400' MD. No trip gas once back on bottom. 113 bbls lost to formation. Gas: The max gas was 274 units at 8830’ MD and the average drilling background gas was 52 units. Fluids: There was 113 barrels of water based mud lost down hole. Geology: The samples are currently drilling in a Shale formation with interbeds of Siltstone and some fine sands. Shale: medium dark grey to black, platey, occasionally blocky, earthy, moderately hard, calcareous, slightly arenaceous. 03/04/2015 Continue to drill from 8330' MD to 10590' MD. A gas peak of 478 units was seen at 9385' MD, this is believed to be the top of the Iceberg Formation. Background gas has been from 140 -160 units. No connection gases have been noted. Gas: The max gas was 478 units at 9385’ MD and the average drilling background gas was 147 units. Fluids: There were no losses down hole. Geology: Sandstone, clear to off white, translucent to transparent, very fine to fine grained rarely medium grained, sub rounded, sub spherical, well sorted, loose quartz, occasional calcite cement, trace tuff. 03/05/2015 Continue to drill from 10590' MD to TD of intermediate section at 12276' MD (5289' MD). No connection gas and no trip gas was seen. Gas: The max gas was 333 units at 11956’ MD and the average drilling background gas was 105 units. Fluids: There were no losses down hole. Geology:. Shale, medium dark grey to dark grey, platy to blocky, firm to moderately hard, silty, slightly calcareous. 03/06/2015 Continue tripping out of hole from TD. Lay Down BHA. Begin rigging up to run casing. Minimal gas seen on trip out with a max gas of 155 units seen at 952' MD and an average gas of 33 units seen whilst pumping on the trip out. Gas: The max gas was 155 units at 11956’ MD and the average drilling background gas was 33 units. Fluids: There were no losses down hole. 03/07/2015 Continue running casing, partially lose circulation around 9432' MD, attempt to reestablish circulation failed, continue running casing. Complexly lose returns around 9500' MD. Losses for the trip at 361 bbls so far. Max gas of 409 units seen at 7210' MD whilst running in, with an average of 150 units whilst getting returns and 54 units for the 24 hours. . Gas: The max trip gas was 1627 units. Fluids: There were no losses down hole. 03/08/2015 Continue running casing, partially lose circulation around 9432' MD, attempt to reestablish circulation failed, continue running casing. Complexly lose returns around 9500' MD. Losses for the trip at 361 bbls so far. Max gas of 409 units seen at 7210' MD whilst running in, with an average of 150 units whilst getting returns and 54 units for the 24 hours. Gas: The max trip gas was 409 units. Fluids: There was 361 barrels of water based mud lost down hole. 03/09/2015 Continue running casing, land casing and attempt to establish circulation. Pump cement and complete cement job. Currently waiting on cement. Max gas of 32 units seen on trip in, minimal gas due to lack of returns. 562 bbls lost during the 24 hours. Gas: The max trip gas was 32 units. Fluids: There was 562 barrels of water based mud lost down hole. 03/10/2015 Complete cement job. Lay down 5" pipe racked back in derrick. Begin BOP test. Gas: There was no gas observed. Fluids: There were no losses down hole. 03/11/2015 Finish BOP Test. Install wear bushing. Begin making up 4” DP. Gas: There was no gas observed. Fluids: There were no losses down hole. 03/12/2015 Begin running in with 6.5" BHA, running with doubles before singling in to TD. Performing casing test at midnight. No loses on trip in, no trip gas due to cased hole. Gas: There was no gas observed. Fluids: There were no losses down hole. 03/13/2015 Continue casing test, begin drilling cement/floats and shoe track. Drill 20' new hole to 12296' MD. Perform FIT test to 16.1 ppg. Begin drilling production section from 12296' MD to 12480' MD at midnight. Max gas of 76 units seen whilst drilling new formation with an average of 41 units. 0 bbls of mud lost. The samples have been Siltstone, medium grey to light grey, soft to firm, blocky to crumbly, calcareous, argillaceous throughout. Gas: The max gas was 76 units at 12386’ MD and the average drilling background gas was 41 units. Fluids: There were no losses down hole. Geology:. Siltstone, medium grey to light grey, soft to firm, blocky to crumbly, calcareous, argillaceous throughout. 03/14/2015 24 hr Recap: Continue drilling 6.5" hole section from 12480' MD to 13334' MD at report time. Background gas was low at around 120 units until 13020' MD, after 13020' MD gas increase to 10,000 units maxing out the SDL equipment, also indicating the top of the Seismic Bermuda. The gas stayed around 10,000 units until 13334' MD, the well was then circulated in order to reduce the gas levels. The mud was showing as low as 9.0 ppg unpressurised when the gas was around 10,000 units. The gas was eventually reduced to +- 5500 units by increasing the MPD back pressure from 140 to 190psi. The C1 - C5 break down of gas shows very high levels of C2-C5 indicating a heavier wetter gas. The Carbon Comparison between the Total Hydrocarbon Analyzer and Chromatograph break down, shows very similar numbers with a larger proportion of the Total Gas being made up of heavier gases, this is similar to the 2L-308 well. Gas: The max gas was 10,000 units at 13334’ MD and the average drilling background gas was 5723 units. Fluids: There were no losses down hole. Geology:. Sandstone, light grey, tan, cream to white, very fine to fine grained, sub spherical, rounded, well sorted, friable, occasionally moderately hard, crumbly, moderate to poorly consolidated, very silty, trace glauconite. Show, strong odor, 50% dull yellow fluorescence, blooming blue white cut, pale straw color cut, bright white residual fluorescence. 03/15/2015 Continue drilling 6.5" hole section from 13334' MD to 14473' MD at report time. Sperry gas THA has been maxed out at 10,000 units for a large part of the day, the C1 to C5 spread is similar to yesterday with high levels of C2 - C5 with particularly large amounts of C3 throughout the interval. 263078 ppm C3 is high, with a methane equivalent of several thousand units. The formation is predominantly Sandstone from 13022' MD with Siltstone increasing around 14200' MD. The Sandstone has good shows with dull yellow fluorescence, a slow blue white blooming cut and dull yellow residual florescence. Oil condensate is also being collected from the gas sampling lines due to the high efficiency of the Sperry system. 0 bbls of mud were lost down hole. Gas: The max gas was 10,000 units at 14226’ MD and the average drilling background gas was 10,000 units. Fluids: There were no losses down hole. Geology:. Sandstone, light grey, tan, cream to white, very fine to fine grained, sub spherical, rounded, well sorted, friable, occasionally moderately hard, crumbly, moderate to poorly consolidated, very silty, trace glauconite. Show, strong odor, 50% dull yellow fluorescence, blooming blue white cut, pale straw color cut, bright white residual fluorescence. 03/16/2015 Continue drilling 6.5" hole section from 14473' MD to 15673' MD at report time. Gas remained above 10,000 units with small periods around 8800 units. After weighting up at 15260' MD to 10.5 ppg the gas dropped down to +- 6000 units with connection gases above 10,000 units. The gas still contains significant heavies C3 and C5 particularly the Total Alkane Response of the Chromatograph still indicates similar values to that of the THA. 0 bbls of mud were lost down hole. Gas: The max gas was 10,000 units at 14473’ MD and the average drilling background gas was 8766 units. Fluids: There were no losses down hole. Geology:. Sandstone, light grey, tan, cream to white, very fine to fine grained, sub spherical, rounded, well sorted, friable, occasionally moderately hard, crumbly, moderate to poorly consolidated, very silty, trace glauconite. Show, strong odor, 50% dull yellow fluorescence, blooming blue white cut, pale straw color cut, bright white residual fluorescence. 03/17/2015 Continue drilling 6.5" hole section from 15673' MD to TD at 16168' MD. Gas remained above 10,000 units until TD. Circulate well and weight up mud to 11.0 ppg whilst cleaning the well. Background gas was reduced to 2500 units after mud was weighed up, currently at 1720 units. 0 bbls lost down hole. The formation is predominantly Sandstone with shows of moderate odor, 60% dull yellow fluorescence, blooming blue white cut, pale straw color cut, bright white residual fluorescence. Gas: The max gas was 10,000 units at 15805’ MD and the average drilling background gas was 8049 units. Fluids: There were no losses down hole. Geology:. Sandstone, light grey, tan, cream to white, very fine to fine grained, sub spherical, rounded, well sorted, friable, occasionally moderately hard, crumbly, moderate to poorly consolidated, very silty, trace glauconite. Show, strong odor, 50% dull yellow fluorescence, blooming blue white cut, pale straw color cut, bright white residual fluorescence. 03/18/2015 Continue conditioning mud to 11 ppg, begin POOH whilst pumping currently at 12194' MD. Displace well to 11.5 ppg at report time. Gas remained high at 10,000 units until 15,900' MD when it decreased to around 4250 units, decreasing to 3400 units around 13790' MD. 0 bbls mud lost down hole. Samples were picked up and shipped this afternoon. No mud data received at report time. Gas: The max gas was 10,000 units at 16085’ MD and the average drilling background gas was 4759 units. Fluids: There were no losses down hole. 03/19/2015 Continue conditioning mud to 12.5 ppg, perform exhale test to determine flow. Gas remained high at the shoe dropping to 3000-4000 units inside casing. 0 bbls of mud lost. Gas: The max gas was 10,000 units at 12187’ MD and the average drilling background gas was 3169 units. Fluids: There were no losses down hole 03/20/2015 Continue conditioning mud to 12.5 ppg, circulate mud around. Perform well shut in and monitor for losses/gains. Max gas of 2585 units seen whilst circulating at 12189' MD, an average background gas of 661 units seen and currently at 331 units. 0 bbls of mud lost. Gas: The max gas was 2585 units at 12189’ MD and the average drilling background gas was 661 units. Fluids: There were no losses down hole 03/21/2015 Continue conditioning mud to 12.6+ ppg, circulate mud around. Begin stripping out of hole. Gas remained low, with a maximum of 464 units at 12189' MD, an average of 281 units. 0 bbls of mud lost down hole. Gas: The max gas was 454 units at 12189’ MD and the average drilling background gas was 281 units. Fluids: There were no losses down hole 03/22/2015 Continue Trip out with 6.5" drilling BHA and lay down same. Begin Rigging up and running 4.5" casing. Max gas 126 units, with an average of 28 units. 35 bbls lost downhole. Gas: The max gas was 126 units at 9986’ MD and the average drilling background gas was 28 units. Fluids: There were 35 losses down hole 03/23/2015 24 hr Recap: Continue running 4.5" casing. Attempt to circulate after picking up one stand of 4" DP, Unable to establish circulation, shut down pumps and note increase in flow, shut in well, 100 psi gain. Oil content of mud increased from 2% to 4%. Max gas of 10,000 units when circulating at 4975' MD after stripping in hole. Large amounts of heavier gases C2/C3 noted with over 300,000 ppm of C3. An average of 956 units. 0 bbls lost downhole. Gas: The max gas was 126 units at 9986’ MD and the average drilling background gas was 28 units. Fluids: There were no losses down hole 03/24/2015 Continue stripping in the hole with 4.5" casing, weigh up mud to 12.7 ppg mud. Max gas of 6802 units seen whilst circulating at 4976' MD. Gas then remained static at around 4900 unit, decreasing to 3000 units at 10269' MD. 0 bbls lost down hole. Gas: The max gas was 6802 units at 4976’ MD and the average drilling background gas was 1635 units. Fluids: There were no losses down hole 03/25/2015 TOOH with liner to 6669' MD and hang off liner with storm packer. BOP test. Begin circulating 12.7 ppg mud round. Max gas of 3601 units at 6669' MD, gas measurements at the shoe were low due to rigs utilization of the gas buster bypassing the Sperry system. Average Gas 658 units. 8 bbls lost down hole. Gas: The max gas was 3601 units at 6669’ MD and the average drilling background gas was 658 units. Fluids: There were 8 losses down hole 03/26/2015 Continue TOOH with 4.5" liner. Max gas 1698 units when circulating at 3660' MD, average gas 439 units. 5 bbls lost down hole. Gas: The max gas was 1698 units at 3660’ MD and the average drilling background gas was 439 units. Fluids: There were 5 losses down hole 03/27/2015 Continue TIH with clean out assembly. Currently circulating B/U at 12228' MD. Max gas of 2531 units seen at 5630' MD with an average of 977 units whilst tripping. 0 bbls of mud lost down hole. Gas: The max gas was 2531 units at 5630’ MD and the average drilling background gas was 977 units. Fluids: There were 0 losses down hole 03/28/2015 Continue TIH with clean out assembly to 13940' MD, attempt to circulate and lose returns, cut mud weight to 11.5 ppg and TOOH to shoe. Gas returns were minimal due to lost returns, max gas of 2073 units whilst tripping in at 12327' MD, with an average of 872 whilst getting returns. 202 bbls of mud lost down hole. Gas: The max gas was 2073 units at 12327’ MD and the average drilling background gas was 872 units. Fluids: There were 202 losses down hole 03/29/2015 Continue TOOH to 7320' MD and establish circulation. Begin TIH to casing shoe at 12200' MD and step up circulation from 0.5 bbls a min. Max gas of 2339 units when establishing returns at 7320' MD, with an average circulating gas of 436 units. 81 bbls of mud lost down hole. Gas: The max gas was 2339 units at 7320’ MD and the average drilling background gas was 436 units. Fluids: There were 81 losses down hole 03/30/2015 Continued to TIH. Washed from 12,237' to 14,515' before circulating a bottoms-up. Then washed and reamed down to 15,369' where another bottoms-up was circulated before continuing to TIH. 29 bbls lost downhole. Gas: The max gas was 1977 units and the average background gas was 656 units. Fluids: There were 29 losses down hole 03/31/2015 Washed and reamed from 15,938' down to TD (16168') and circulated a bottoms-up. Then displaced the 11.5 ppg mud with new 12.7 ppg NaBr KLA-SHIELD mud. The well was then monitored at bottom before beginning to TOOH. Washed out of hole to shoe and monitored well at the shoe. The well was static at the shoe so tripping proceeded on elevators. 0 bbls lost downhole. Gas: The max gas was 9040 units and the average background gas was 1018 units. Fluids: There were 0 bbls losses down hole 04/1/2015 Finished tripping out of hole and layed down BHA. Rigged up to run in 4.5" Liner. Began TIH with 4.5" liner. 25 bbls lost downhole. Gas: The max gas was 19 units and the average background gas was 12 units. Fluids: There were 25 losses down hole 04/2/2015 Finished TIH with 4.5" liner. Liner landed at 16149’ on 4/2/2015 at 19:30 hrs. Gas: The max gas was 49 units and the average background gas was 15 units. Fluids: There were 4 losses down hole 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 16000 17000 0 5 10 15 20 25 30 35 40 45 Me a s u r e d D e p t h Rig Days WELL NAME: 2L-328 (Sierra) OPERATOR: ConocoPhillips Alaska, Inc. MUD CO: MI Swaco RIG: Doyon 25 SPERRY JOB: AK-XX-0902171410 Days vs. Depth 20 Feb 2015 Sperry SDL Arrived on Location LOCATION: Kuparuk River Unit AREA: North Slope Borough STATE: Alaska SPUD: 22-Feb-2015 TD: 17-Mar-2015 Commenced 9.875" Intermediate Hole Section On Bot: 00:58 26 Feb 2015 Waiting on Weather 28 Feb 2015 Continued 9.875" Intermediate Hole Section On Bot: 02:00 03 March 2015 Landed 7.625" Casing 12266' MD, 5285' TVD 09 Mar 2015 TD Intermediate Hole Section 12276' MD, 5289' TVD Off Bot: 17:32 05 Mar 2015 Commenced 6.5" Production Hole Section On Bot: 07:00 13 Mar 2014 TD Production Hole Section 16168' MD, 5529' TVD Off Bottom: 09:33 17 Mar 2015 Landed 4.5" Liner 16148' MD, 5530' TVD 02 Apr 2015 WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Difficulties experienced: The unit was moved further away from the rig during the move and none of the communications cables or heat trace cable were long enough to reach the new position. Recommendations: Although Sperry requires units to be within 150' of Shakers it's not always possible therefore having lengths of cable run that are longer than where the original position of the unit is during rig up is a good idea. Innovations and/or cost savings: N/A Doyon 25 Intermediate Craig Amos 16-Mar-2015 What went as, or better than, planned: The CVE system is still working well, it is efficiant and requires little monitoring. 2L-328 (Sierra)Kuparuk River Unit ConocoPhillips Alaska, Inc.North Slope Borough AK-XX-0902171410 Alaska Surface Data Logging After Action Review WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Difficulties experienced: Large amounts of gas condensate was collected in drop out jars both inside the unit and at the shakers. This needed to be regularly emptied and disposed of to prevent a fire hazard. Discrepancies between the Gas Watch and Insite systems were noted. The heavier gases noted by Insite are not recorded by the gas watch system therefore giving a discrepancy. Recommendations: Using differnet levels of calibration gas to provide more accurate readings with the fast gas system could improve the system. Innovations and/or cost savings: N/A Doyon 25 Production Craig Amos 31-Mar-2015 What went as, or better than, planned: The CVE system worked without stopping and required little maintenance. The fast gas system worked hard recording gas at very high levels but didn't fail and held a good calibration. 2L-328 (Sierra)Kuparuk River Unit ConocoPhillips Alaska, Inc.North Slope Borough AK-XX-0902171410 Alaska Surface Data Logging After Action Review 2L-328 (Sierra) ConocoPhillips Alaska, Inc. MI Swaco Doyon 25 AK-XX-0902171410 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++ 25-Feb 2517 10.00 -11 14 2/19/29 10.0 36/25/19/12/2/2 3/-8.5 2/90 TR 1.05 10.1 17.5 1.00/3.5 1100 120 Rigging Up 26-Feb 3478 9.60 10 24 9/10/10 7.0 44/34/29/22/9/8 2/-4.0 2/90 0.25 1.00 10.1 -0.2/98 700 40 Drilling new mud 27-Feb 5672 9.90 50 15 25 9/11/15 4.3 48/36/38/23/8/7 1/-10.0 2/90 0.25 1.00 10.2 18.3 0.1/.90 120 80 Drilling new mud 28-Feb 7564 9.90 46 14 22 8/9/11 4.6 50/36/30/24/8/7 1/-10.0 2/87 0.25 0.35 10.0 10.0 0.15/1 500 40 Drilling then waiting on Weather 1-Mar 7564 10.00 58 18 23 8/11/15 3.5 59/41/34/25/10/9 1/-12.0 2/87 0.25 0.35 10.0 18.3 0.16/1.0 550 40 Waiting on Weather 2-Mar 7564 9.90 59 16 19 8/11/13 4.4 51/35/30/22/9/8 1/-10.0 2/86 0.25 0.38 10.4 16.3 0.22/0.9 500 60 Tripping In Hole 3-Mar 8330 9.90 53 20 25 10/13/20 4.5 65/45/38/28/10/10 1/-12.0 2/87 0.25 0.40 10.0 20.0 0.13/0.78 480 40 Drilling 4-Mar 10590 10.00 45 13 19 7/8/10 3.9 45/32/26/19/8/7 1/-12.5 2/88 0.25 0.08 9.5 21.5 0.05/1.00 500 40 Drilling 5-Mar 12276 9.90 44 12 20 7/10/11 4.0 44/32/28/21/8/7 1/-11.6 2/88 TR.0.06 9.6 22.75 0.43/0.79 500 40 TD Intermediate 6-Mar 12276 9.70 43 8 17 7/10/12 4.0 33/25/21/17/7/6 1/-10 2/88 TR.0.05 9.3 22.5 0.33/0.80 500 40 Casing 7-Mar 12276 9.70 44 9 14 6/7/8 4.0 32/23/19/14/6/5 1/-10 2/88 TR.0.05 9.1 22.5 0.30/0.80 500 40 Casing 8-Mar 12276 9.70 64 19 26 9/13/18 4.8 64/45/38/28/10/9 1/-10 2/88 TR.0.02 8.3 20 .02/1.00 500 40 Casing 9-Mar 12276 9.70 64 19 25 9/13/18 4.8 63/44/37/28/10/9 1/-10 2/89 TR.0.02 8.3 20 .02/1.01 500 40 Cementing 10-Mar 12276 -----------------No mud in pits 11-Mar 12276 9.70 56 10 22 8/9/10 6.5 42/32/29/22/9/8 2/-5 2/93 TR.0.30 9.8 1.25 0.19/0.94 500 40 New Drilling Mud 12-Mar 12276 9.60 52 11 18 8/9/10 6.5 40/29/24/20/8/7 1/-6 2/92 TR.0.30 10.5 2 0.22/1.02 720 40 TIH with 6.5" BHA 13-Mar 12480 9.50 50 10 19 6/7/8 4.2 39/29/24/18/7/6 1/1 7.8 2/90 0.25 4.25 10.0 1.25 6.65/8.30 125000 100 Drillling 6.5" Section 14-Mar 13334 9.60 45 10 20 7/8/9 3.8 40/30/26/20/7/6 1/2 7 2/91 0.25 5.25 10.0 1.875 6.60/6.60 57000 100 Drillling 6.5" Section 15-Mar 14474 10.00 45 10 25 7/8/8 2.0 45/35/29/23/8/7 1/2 8.5 3/89 0.25 4.85 10.0 2 5.10/7.82 54000 100 Drillling 6.5" Section 16-Mar 15670 10.50 50 17 26 8/11/12 4.0 60/43/36/27/9/8 1/2 11.5 8/81 0.25 5.02 10.0 3.75 5.15/8.25 54000 100 Drillling 6.5" Section 17-Mar 16168 11.00 53 21 34 11/13/13 4.0 76/55/46/36/13/11 1/2 15 11/75 0.25 5.10 10.0 6.25 3.60/7.10 35000 100 TD Production Section 18-Mar 16168 11.50 55 21 30 10/11/12 4.4 73/52/43/33/12/10 1/2 16 5/78 0.25 5.10 10.0 3.0 3.5/6 50000 100 Condition mud 19-Mar 16168 12.20 56 21 28 9/11/13 4.8 70/49/40/30/10/9 1/2 17.5 3/80 0.25 5.15 10.0 1.9 3.50/3.20 93000 40 TOOH 20-Mar 16168 12.60 55 16 30 8/10/13 4.1 62/46/39/27/9/8 1/2 18.5 3/79 1.25 7.40 10.0 1.9 5.40/7.20 62500 40 TOOH 21-Mar 16168 12.60 57 15 29 8/9/11 5.2 59/44/37/27/9/8 1/2 18.5 2/80 0.75 4.70 10.0 1.9 3.80/3.30 56000 40 TOOH 22-Mar 16168 12.70 56 17 29 9/10/11 5.2 63/46/37/27/10/9 1/2 18.5 2/80 0.75 4.50 10.0 1.9 3.52/4.90 56500 40 TIH 4.5" Liner 23-Mar 16168 12.65 68 19 32 10/12/13 5.3 70/51/43/32/12/10 1/2 18.8 3/78 0.60 3.10 10.0 1.9 3.20/6.90 72000 40 TIH 4.5" Liner 24-Mar 16168 12.70 62 17 42 13/14/15 5.3 76/59/49/37/14/12 1/2 19.5 6/75 0.60 3.20 10.0 1.9 4.40/7.10 105000 40 TIH 4.5" Liner 25-Mar 16168 12.70 65 23 33 11/13/15 4.1 79/56/46/35/13/11 1/2 19.5 5/76 0.50 2.90 10.0 1.9 3.20/7.80 87000 40 BOP Test 26-Mar 16168 12.70 74 23 36 11/15/17 4.6 82/59/49/37/14/11 1/2 20 5/75 0.50 2.80 10.5 2.0 3.20/6.80 87000 40 TOOH 27-Mar 16168 12.40 60 20 34 11/13/17 4.3 74/54/45/34/12/11 1/-18 4/78 0.50 2.60 10.4 2.6 3.10/7.10 83000 40 TIH with Cleanout BHA 28-Mar 16168 11.90 46 12 22 8/10/11 4.7 68/34/28/20/8/7 1/-17 4/79 0.50 2.90 10.4 2.0 3.20/6.70 81000 40 TIH with Cleanout BHA 29-Mar 16168 11.50 48 12 24 8/9/10 3.6 48/36/30/23/9/8 1/-15 3/82 TR.2.00 10.3 2.8 3.40/6.50 81000 40 TIH with Cleanout BHA 30-Mar 16168 11.50 48 11 28 8/9/10 3.7 50/39/31/25/9/8 1/-15 3/82 Tr 2.80 10.3 1.5 3.20/6.30 80000 40 TIH with Cleanout BHA 31-Mar 16168 12.60 48 11 15 9/11/12 4.4 37/26/22/17/8/7 1/-21.0 2/77 -4.20 10.0 -4.50/8.10 180000 40.000 Displaced to 12.7 ppg mud / TOOH 1-Apr 16168 12.70 46 11 18 8/9/10 4.6 40/29/24/18/8/7 1/-22 1/77 -4.20 10.3 -4.50/8.10 181000 40 TIH w/ 4.5" Liner 2-Apr 16168 12.70 46 11 17 8/9/10 4.8 39/28/21/17/8/7 1/-22 1/77 -4.20 10.3 -4.50/8.00 180000 40 TIH w/ 4.5" Liner, land liner at TD Casing Record WELL NAME:LOCATION:Kuparuk River Unit OPERATOR:AREA:North Slope Borough MUD CO:STATE:Alaska RIG:SPUD:22-Feb-2015 SPERRY JOB:TD:17-Mar-2015 Remarks 16" Conductor @ 130' MD, 130'TVD 7.625" Casing @ 12266' MD, 5285' TVD 10.75" Casing @ 2507' MD, 2286'TVD 4.5" Casing @ 16148' MD, 5530'TVD 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 2 100 2 PDC Security 9.875"2517 12276 9759 65.95 0.991 148.0 32 140 3530 700 1-1-WT-A-X-I-TD TD Intermediate 3 200 3 Hycalog 6.5" 12276 16168 3892 45.34 0.383 85.8 38 150 3111 250 1-1-CT-A-X-I-TD TD Production Alaska RIG:Doyon 25 SPUD:22-Feb-2015 WELL NAME:2L-328 (Sierra)LOCATION:Kuparuk River Unit OPERATOR:ConocoPhillips Alaska, Inc.AREA:North Slope Borough MUD CO: SPERRY JOB:AK-XX-0902171410 TD:17-Mar-2015 MI Swaco STATE: B i t R e c o r d . . * 24 hr Recap:Finish drilling surface to 2517' MD. Circulate and monitor well. Begin pulling out of hole. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 950.00 20-Feb-2015 12:00 AM Current Pump & Flow Data: 1100 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 1 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: ConditionBit # 8.09.809.80 Size 100% Gas In Air=10,000 UnitsConnection Tools API FL Chromatograph (ppm) WOB Avg Min Comments RPM ECD (ppg) ml/30min Background (max) Trip Average Mud Type Lst Type Drilplex 10.02517'39 Depth in / out YP (lb/100ft2) 10.60 CementChtSilt C-4i C-4n 24 hr Max Weight Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902171410 POOH PV Footage Granville Rizek/Rob Reinhardt ShClyst TuffGvlCoal cP 22 Gas Summary (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 2517' 2517' 0' Max @ ft Current Date: Time: in Minimum Depth C-5nC-2 SPP (psi) Gallons/stroke TFABit Type Depth 12.5 MBT pH Siltst 550 130 Units* Casing Summary Lithology (%) 907-659-7599Unit Phone:Macy Williams Maximum Report By:Logging Engineers:Danielle Dawson\ Macy Williams Set AtSize Grade (max)(current) Cly Bottoms Up TimeVolumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap:Continue pulling out of hole. Lay down BHA. Pick up and begin running in hole with 10.75" casing to 2450' MD. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 1050.00 21-Feb-2015 12:00 AM Current Pump & Flow Data: 1100 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 2 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: ConditionBit # 9.010.0010.00 Size 100% Gas In Air=10,000 UnitsConnection Tools API FL Chromatograph (ppm) WOB Avg Min Comments RPM ECD (ppg) ml/30min Background (max) Trip Average Mud Type Lst Type Drilplex 10.02517'44 Depth in / out YP (lb/100ft2) 10.50 CementChtSilt C-4i C-4n 24 hr Max Weight Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902171410 RIH Casing 10.75" PV Footage Granville Rizek/Rob Reinhardt ShClyst TuffGvlCoal cP 27 Gas Summary (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 2517' 2517' 0' Max @ ft Current Date: Time: in Minimum Depth C-5nC-2 SPP (psi) Gallons/stroke TFABit Type Depth 16.3 MBT pH Siltst 550 130 Units* Casing Summary Lithology (%) 907-659-7599Unit Phone:Macy Williams Maximum Report By:Logging Engineers:Danielle Dawson\ Macy Williams Set AtSize Grade (max)(current) Cly Bottoms Up TimeVolumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap:Pump Cement, flush lines, and pick up casing spool. Clean out surface stack and weld on cameron hanger. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 1150.00 22-Feb-2015 12:00 AM Current Pump & Flow Data: 1100 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 3 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: ConditionBit # 8.510.0010.00 Size 100% Gas In Air=10,000 UnitsConnection Tools API FL Chromatograph (ppm) WOB Avg Min Comments RPM ECD (ppg) ml/30min Background (max) Trip Average Mud Type Lst Type Drilplex 10.02517'18 Depth in / out YP (lb/100ft2) 9.20 CementChtSilt C-4i C-4n 24 hr Max Weight Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902171410 Well Head Service PV Footage Granville Rizek/Rob Reinhardt ShClyst TuffGvlCoal cP 22 Gas Summary (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 2517' 2517' 0' Max @ ft Current Date: Time: in Minimum Depth C-5nC-2 SPP (psi) Gallons/stroke TFABit Type Depth 17.5 MBT pH Siltst 550 130 Units* Casing Summary Lithology (%) 907-659-7599Unit Phone:Macy Williams Maximum Report By:Logging Engineers:Danielle Dawson\ Macy Williams Set AtSize Grade (max)(current) Cly Bottoms Up TimeVolumes 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) Cly Set AtSize Grade 907-659-7599Unit Phone:Macy Williams Maximum Report By:Logging Engineers:Danielle Dawson\ Macy Williams 550 130 Units* Casing Summary Lithology (%) MBT pH Siltst SPP (psi) Gallons/stroke TFABit Type Depth C-5nC-2 in Minimum Depth Time: equipment. 2517' 2517' 0' Max @ ft Current Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Gas Summary (current) Granville Rizek/Rob Reinhardt ShClyst TuffGvlCoal cP 10 Footage Ss (ppb Eq) C-1 C-5i AK-AM-0902171410 Rig Up MPD PV 24 hr Max Weight Hours C-3 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.80LSND7.02517'22 Depth in / out Mud Type Lst Type Average Background (max) Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) WOB 100% Gas In Air=10,000 UnitsConnection ConditionBit # 3.09.609.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: Morning Report Report # 4 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad ROP ROP (ft/hr) 4.23 @ Mud Data Depth 23-Feb-2015 12:00 AM Current Pump & Flow Data: 1100 Max Chlorides mg/l 750.00 Wait on emergency hanger slip on weld to cool and test seal. Orient casing spools, install riser, and rig up MPD rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Continue rigging up MPD equipment. Test BOP. Blow down choke lines. Test MPD. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 750.00 24-Feb-2015 12:00 AM Current Pump & Flow Data: 1100 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 5 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: ConditionBit # 3.09.609.60 Size 100% Gas In Air=10,000 UnitsConnection Tools API FL Chromatograph (ppm) WOB Avg Min Comments RPM ECD (ppg) ml/30min Background (max) Trip Average Mud Type Lst Type LSND 7.02517'22 Depth in / out YP (lb/100ft2) 9.80 CementChtSilt C-4i C-4n 24 hr Max Weight Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902171410 MPD Testing PV Footage Don Mickey/Rob Reinhardt ShClyst TuffGvlCoal cP 10 Gas Summary (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 2517' 2517' 0' Max @ ft Current Date: Time: in Minimum Depth C-5nC-2 SPP (psi) Gallons/stroke TFABit Type Depth MBT pH Siltst 550 130 Units* Casing Summary Lithology (%) 907-659-7599Unit Phone:Macy Williams Maximum Report By:Logging Engineers:Danielle Dawson\ Macy Williams Set AtSize Grade (max)(current) Cly Bottoms Up TimeVolumes 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) Intermediate Cly Set AtSize 62.6 Grade 16.00'' 907-659-7599Unit Phone:Macy Williams Maximum Report By:Logging Engineers:Travis Howe\ Macy Williams 10.75'' 550 130 Units* Casing Summary Lithology (%) MBT pH Siltst SPP (psi) Gallons/stroke TFABit Type Depth 17.5 C-5nC-2 in Minimum Depth Time: to 2364' MD. Perform casing test and drill out shoe. 2517' 2517' 0' Max @ ft Current Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Gas Summary (current) Don Mickey/Rob Reinhardt ShClyst TuffGvlCoal cP 11 Footage Ss (ppb Eq) C-1 C-5i AK-AM-0902171410 F.I.T Test PV 24 hr Max 45.5 Weight Hours C-3 CementChtSilt C-4i C-4n YP (lb/100ft2) 10.10LSND10.02517'14 Depth in / out Mud Type Lst Type Average Background (max) Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) WOB Conductor 100% Gas In Air=10,000 UnitsConnection 2500' 130' ConditionBit # 8.59.9510.00 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: Morning Report Report # 6 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad ROP ROP (ft/hr) 4.23 @ Mud Data Depth 25-Feb-2015 12:00 AM Current Pump & Flow Data: 1100 Max Chlorides mg/l 1100.00 Continue installing MPD equipment. Test MPD equipment. Pick up BHA and run in hole with doubles from 1500' MD rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Complete mud displacement, FIT Test, commence drilling intermediate section of well at 13.30 on the 26th of Feb. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 700.00 26-Feb-2015 12:00 AM Current Pump & Flow Data: 2000 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 7 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: ConditionBit # 1 5.0 9.875 9.60 PDC 9.60 Size Cuttings are currently predominantly Sandstone interbedded with Siltstone and Claystone with occasional Tuffs and Volcanics. The max gas was 351 units seen at 3085' MD with an average background gas of 70 - 100 units. 0 bbls of mud lost. 2500' 130' 100% Gas In Air=10,000 UnitsConnection 60 Tools API FL Chromatograph (ppm) WOB Conductor Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max) Trip Average 0 Mud Type Lst 40% Type LSND 7.02517'24 Depth in / out YP (lb/100ft2) 10.10 00 CementChtSilt C-4i C-4n 24 hr Max 45.5 Weight Hours C-3 10% Ss (ppb Eq) C-1 C-5i AK-AM-0902171410 Short Trip for Top Drive PV Footage Don Mickey/Rob Reinhardt ShClyst TuffGvlCoal cP 11 Gas Summary 0 0 0 (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: 222.4 Flow In (gpm) Flow In (spm) 2517' 3478' 961' Max @ ft Current 2300'87.0 Date: Time: Drill from 2537' to 3478' MD. At 23.30 pick up off bottom and begin trip to shoe to service top drive loop. 70 in 25 2580'Minimum Depth C-5n 3085' 0.0 C-2 351 SPP (psi) Gallons/stroke TFABit Type Depth 5.056 MBT pH 0 37 0 Siltst 10.75'' 694 164 Units* Casing Summary Lithology (%) 50% 9722 3200 907-659-7599Unit Phone: 0 Craig Amos Maximum Report By:Logging Engineers:Craig Amos\ Macy Williams Set AtSize 62.6 Grade 16.00'' (max)(current) Intermediate 335 0 Cly 47390 Bottoms Up Time 248 0 246033355 15 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Continue to TIH after top drive repair, circulate a bottoms up after trip, gas of 4907 units seen, gas went back to background levels after a full circulation. Continue to drill ahead to 5672' MD at midnight. Low background gas of <100 units seen, with no large formation gas peaks. No connection gas has been present. Current formation is Sandy Siltstone with occasional Sandstone beds. A harder Calcareous Sandstone bed was encountered at 5502' MD which produced a slower ROP. 0 bbls of mud were lost downhole. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 405 5 414254094 26 (max)(current) Intermediate 365 0 Cly 21239 Set AtSize 62.6 Grade 16.00'' 907-659-7599Unit Phone: 0 Craig Amos Maximum Report By:Logging Engineers:Craig Amos\ Macy Williams 60% 6742 1364 10.75'' 694 163 Units* Casing Summary Lithology (%) MBT pH 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 18.350 C-5n 5613' 161.0 C-2 139 in 13 5334'Minimum Depth Time: 54 3478' 5672' 2194' Max @ ft Current 4520'91.0 Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: 216.0 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) Don Mickey/Rob Reinhardt ShClyst TuffGvlCoal cP 15 Footage Ss (ppb Eq) C-1 C-5i AK-AM-0902171410 Drilling Ahead PV 24 hr Max 45.5 Weight Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 10.20LSND4.35381'25 Depth in / out Mud Type Lst 40% Type Average 490772Background (max)Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) WOB Conductor 100% Gas In Air=10,000 Units0Connection 12 2500' 130' ConditionBit # 1 10.0 9.875 10.00 PDC 9.90 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: Morning Report Report # 8 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad ROP ROP (ft/hr) 4.23 @ Mud Data Depth 27-Feb-2015 12:00 AM Current Pump & Flow Data: 2344 Max Chlorides mg/l 120.00 rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 500.00 13 28-Feb-2015 12:00 AM Current Pump & Flow Data: 2344 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 9 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.81 Doyon 25 Report For: ConditionBit # 1 14.0 9.875 9.85 PDC 9.90 Size 100% Gas In Air=10,000 Units-Connection 18 Gamma, Res, ECD, Directional API FL Chromatograph (ppm) WOB Conductor 2500' 11.1411.48 Avg Min Comments RPM ECD (ppg) ml/30min 27Background (max)Trip Average - Mud Type Lst 50% Type 7564'22 Depth in / out 130' 020 0 CementChtSilt C-4i C-4n 24 hr Max 45.5 Weight 69 Hours C-3 10% 0 AK-AM-0902171410 Circulating PV YP (lb/100ft2) 10.00 Ss (ppb Eq) C-1 C-5i LSND 4.3 GvlCoal cP 14 Footage 0 (current) Don Mickey/Rob Reinhardt ShClyst Tuff Avg to5672' Yesterday's Depth: Current Depth: 24 Hour Progress: 283.0 Flow In (gpm) Flow In (spm) 5672' 7567' 1895' Max @ ft Current 6334'191.0 Date: Depth Time: in 5 6633' 64 Gas Summary 0 5 C-5n 6719' - C-2 116 SPP (psi) Gallons/stroke TFABit Type Depth 10.046 Tools 5 MBT 7567' pH 3 7 0 10.75'' 694 163 Units* Casing Summary Lithology (%)Siltst Minimum 40% 9068 2695 907-659-7599Unit Phone: 0 Craig Amos Maximum Report By:Logging Engineers:Craig Amos\ Macy Williams Set AtSize 62.6 Grade 16.00'' Intermediate 114 19 Cly 15786 5382669.61 127.57 26 (max)(current) 24 hr Recap: Drilled from 5672' MD to 7567' MD. Circulate and reciprocate pipe while waiting on Phase 3 Conditions. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 542.05 5 . . * 24 hr Recap: Circulate and reciprocate pipe while waiting on Phase 3 Conditions. Phase 3 conditions expected to be inplace until at least 6am. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 542.05 5 (max)(current) 5382669.61 127.57 185 Size 62.6 Grade 16.00'' Intermediate 907-659-7599Unit Phone: 0 Craig Amos Maximum Report By:Logging Engineers:Craig Amos\ Macy Williams 2208 897 57 3 2926 10.75'' 123 30 Units* Casing Summary Lithology (%)Siltst Minimum 0 MBT 7567' pH 0 0 0 28 SPP (psi) Gallons/stroke TFABit Type Depth 18.3 7567' 0.0 C-2 58 Tools 40% Set At in 8 7567' 20 Gas Summary 0 0 Depth Time: 7567' 7567' 0' Max @ ft Current 0'0.0 Date: Avg to7567' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) (current) Don Mickey/Rob Reinhardt ShClyst Tuff C-5n cP 18 Footage Ss (ppb Eq) C-1 C-5i LSND 3.5 GvlCoal AK-AM-0902171410 Circulating PV YP (lb/100ft2) 9.80 24 hr Max 45.5 Weight 69 Hours C-3 10% Silt C-4i C-4n Cly 000 0 Cement 0 0 7564'23 Depth in / out 130' Cht Mud Type Lst 50% Type Average -15Background (max) Trip Avg Min Comments RPM ECD (ppg) ml/30min Gamma, Res, ECD, Directional API FL Chromatograph (ppm) WOB Conductor 2500' 100% Gas In Air=10,000 Units-Connection 10 Bit # 1 12.0 9.875 10.00 PDC 10.00 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: Morning Report Report # 10 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad ROP ROP (ft/hr) 4.23 @ Mud Data Depth Condition 1-Mar-2015 12:00 AM Current Pump & Flow Data: 253 Max 13 mg/l 550.00 rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides . . * rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 500.00 4 Depth Condition ROP ROP (ft/hr) 4.23 @ Mud Data Current Pump & Flow Data: 0 Max Morning Report Report # 11 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: Bit # 1 10.0 9.875 9.90 PDC 9.90 Size 100% Gas In Air=10,000 Units-Connection 16 Gamma, Res, ECD, Directional API FL Chromatograph (ppm) 2517' WOB Conductor 2500' Avg Min Comments RPM ECD (ppg) ml/30min 5Background (max) Trip Average 147 Mud Type Lst Type 7564'19 Depth in / out 130' Cht Cement 0 0 C-4n Cly 000 0 28 Hours C-3 C-4i AK-AM-0902171410 TIH PV YP (lb/100ft2) 10.40 C-1 C-5i LSND 4.4 GvlCoal 45.5 Weight Footage Ss Silt (current) Don Mickey/Rob Reinhardt ShClyst Tuff C-5n Avg to7567' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) Current 0'0.0 Date: 24 hr Max 2-Mar-2015 12:00 AM 7564' 7564' 0' Max @ ft cP 16 (ppb Eq) 0 0 Depth Time: Set At in 0 0' 23 Gas Summary Depth 16.3 0' 0.0 C-2 59 Tools 0 147 SPP (psi) Gallons/stroke TFABit Type Minimum 0 MBT 7567' pH 0 016504 10.75'' 0 0 Units* Casing Summary Lithology (%)Siltst 907-659-7599Unit Phone: 0 Craig Amos Maximum Report By:Logging Engineers:Craig Amos\ Macy Williams Size 62.6 Grade 16.00'' Intermediate 5382669.61 127.57 185 0 143 (max)(current) 3278 0 24 hr Recap: Circulate and reciprocate till 6am, begin TOOH to 2470' MD, install MPD bushing. Begin TIH currently at 6300' MD. Max Trip gas of 147' units seen so far, a full bottoms up circulation has not been completed yet. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 542.05 5 . . * 24 hr Recap: Complete TIH to bottom, circulate begin drilling from 7564' MD to 8175' MD, experience pack off event loses of 63 bbls, establish circulation and begin tripping out of hole to 7400' MD, TIH to bottom and establish circulate, dilute mud and recommence drill from 8175' MD to 8330' MD. Trip gas of 274 units seen whilst circulating at 7400' MD. No trip gas once back on bottom. 113 bbls lost to formation. Currently drilling in a Shale formation with interbeds of Siltstone and some fine sands. Shale: medium dark grey to black, platey, occasionally blocky, earthy, moderately hard, calcareous, slightly arenaceous. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 600.78 5 (max)(current) 3278 16 6066742.86 142.08 37 1846 32 Size 62.6 Grade 16.00'' Intermediate 907-659-7599Unit Phone: 0 Craig Amos Maximum Report By:Logging Engineers:Craig Amos\ Macy Williams 6432 10.75'' 698 164 Units* Casing Summary Lithology (%)Siltst Minimum 0 MBT 7567' pH 1 7 0 59 SPP (psi) Gallons/stroke TFABit Type Depth 20.0 8251' 80.0 C-2 53 Tools Set At in 16 8139' 27 Gas Summary 0 6 Depth Time: 7564' 8330' 766' Max @ ft cP 20 (ppb Eq) 7763'72.0 Date: 24 hr Max 3-Mar-2015 12:00 AM Tuff C-5n Avg to7567' 180.0 Flow In (gpm) Flow In (spm) Current Ss Silt (current) Don Mickey/Paul ShClyst LSND 4.5 GvlCoal 45.5 Weight Footage YP (lb/100ft2) 10.00 C-1 C-5iC-4i AK-AM-0902171410 Drilling PV Yesterday's Depth: Current Depth: 24 Hour Progress: 0 0 28 Hours C-3 90% Cement 0 0 C-4n Cly Depth in / out 130' Cht 10% Mud Type Lst Type Average 27451Background (max)Trip 10.0711.30 Avg Min Comments RPM ECD (ppg) ml/30min API FL Chromatograph (ppm) 2517' WOB Conductor 2500' 25 100% Gas In Air=10,000 Units-Connection 14 Bit # 1 12.0 9.875 9.90 PDC 9.90 Size 8330' Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 12.01 Doyon 25 Report For: Morning Report Report # 12 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad ROP ROP (ft/hr) 4.23 @ Mud Data Current Pump & Flow Data: 2853 Max Gamma, Res, ECD, Directional Depth Condition 4 00 mg/l 480.00 rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides . . * rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 500.00 183 019 Depth Condition ROP ROP (ft/hr) 4.23 @ Mud Data Current Pump & Flow Data: 3025 Max Gamma, Res, ECD, Directional Morning Report Report # 13 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: Bit # 1 12.5 9.875 10.05 PDC 10.00 Size 10590' 100% Gas In Air=10,000 Units-Connection 1817 API FL Chromatograph (ppm) 2517' WOB Conductor 2500' 19 -- Avg Min Comments RPM ECD (ppg) ml/30min 162Background (max)Trip Average - Mud Type Lst 100% Type Depth in / out 130' Cht Cement 0 302 C-4n Cly 0 10 737 Hours C-3 C-4i AK-AM-0902171410 Drilling PV Yesterday's Depth: Current Depth: 24 Hour Progress: YP (lb/100ft2) 9.50 C-1 C-5i LSND 3.9 GvlCoal 45.5 Weight Footage Ss Silt (current) Don Mickey/Paul ShClyst Tuff C-5n Avg to8830' 282.0 Flow In (gpm) Flow In (spm) Current 9081'94.0 Date: 24 hr Max 4-Mar-2015 12:00 AM 8330' 10590' 2260' Max @ ft cP 13 (ppb Eq) 0 1515 Depth Time: Set At in 51 8369' 142 Gas Summary Depth 21.5 9385' 120.0 C-2 45 Tools 13 478 SPP (psi) Gallons/stroke TFABit Type Minimum 20 MBT 10590' pH 37 54137923 10.75'' 698 165 Units* Casing Summary Lithology (%)Siltst 907-659-7599Unit Phone: 201 Craig Amos Maximum Report By:Logging Engineers:Craig Amos\ Macy Williams Size 62.6 Grade 16.00'' Intermediate 7520938.11 180.76 46 7387 3091 (max)(current) 15643 147 24 hr Recap: Continue to drill from 8330' MD to 10590' MD. A gas peak of 478 units was seen at 9385' MD, this is believed to be the top of the Iceberg Formation. Backgound gas has been from 140 -160 units. No connection gases have been noted. 0 bbls of water based mud were lost down hole. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 757.35 10 . . * • 24 hr Recap: Continue to drill from 10590' MD to TD of intermediate section at 12276' MD (5289' MD). Max gas of the 333 units seen at 11956 units, with an average background gas of 105 units. No connection gas and no trip gas was seen. 0 bbls of water based mud lost down hole. The last sample consisted of predominantly Shale, medium dark grey to dark grey, platey to blocky, firm to moderately hard, silty, slightly calcareous. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 880.56 10 (max)(current) 10123 510 88011091.77 211.21 53 7941 2188 Size 62.6 Grade 16.00'' Intermediate 907-659-7599Unit Phone: 122 Craig Amos Maximum Report By:Logging Engineers:Craig Amos\ Macy Williams 28815 10.75'' 25 59 Units* Casing Summary Lithology (%)Siltst Minimum 65 MBT 12276' pH 302 400 52 333 SPP (psi) Gallons/stroke TFABit Type Depth 22.8 11956' 0.0 C-2 44 Tools 20% Set At in 73 11448' 105 Gas Summary 0 1055 Depth Time: 10590' 12276' 1686' Max @ ft cP 12 9759' (ppb Eq) 11180'93.6 Date: 24 hr Max 5-Mar-2015 12:00 AM Tuff C-5n Avg to10590' 347.0 Flow In (gpm) Flow In (spm) Current Ss Silt (current) Don Mickey/Paul Smith ShClyst LSND 4.0 GvlCoal 45.5 Weight Footage YP (lb/100ft2) 9.60 C-1 C-5i 150.0 C-4i AK-AM-0902171410 Drilling PV Yesterday's Depth: Current Depth: 24 Hour Progress: 5 121 645 Hours C-3 60% 66.60 Cement 0 182 C-4n Cly Depth in / out 130' Cht Mud Type Lst 20% Type Average -26Background (max)Trip 11.1011.41 Avg Min Comments RPM ECD (ppg) ml/30min API FL Chromatograph (ppm) 15.02517' 12276' WOB Conductor 2500' 20 100% Gas In Air=10,000 Units-Connection 1466 Bit # 1 11.6 9.875 9.90 PDC 9.90 Size 12776' Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.56 Doyon 25 Report For: Morning Report Report # 14 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad ROP ROP (ft/hr) 4.23 @ Mud Data Current Pump & Flow Data: 935 Max Gamma, Res, ECD, Directional Depth Condition 352 14120 mg/l 500.00 rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides . . * rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 500.00 10 02 Depth Condition ROP ROP (ft/hr) 4.23 @ Mud Data Current Pump & Flow Data: - Max Gamma, Res, ECD, Directional Morning Report Report # 15 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: Bit # 1 10.0 9.875 9.70 PDC 9.70 Size 12776' 100% Gas In Air=10,000 Units-Connection 63 API FL Chromatograph (ppm) 15.02517' 12276' WOB Conductor 2500' 17 -- Avg Min Comments RPM ECD (ppg) ml/30min -Background (max)Trip Average 155 Mud Type Lst Type Depth in / out 130' Cht Cement 0 6 C-4n Cly 0 0 63 Hours C-3 66.60 C-4i AK-AM-0902171410 Tripping PV Yesterday's Depth: Current Depth: 24 Hour Progress: YP (lb/100ft2) 9.30 C-1 C-5i 150.0 LSND 4.0 GvlCoal 45.5 Weight Footage Ss Silt (current) Don Mickey/Paul Smith ShClyst Tuff C-5n Avg to12276' - Flow In (gpm) Flow In (spm) Current -- Date: 24 hr Max 6-Mar-2015 12:00 AM 12276' 12276' 0' Max @ ft cP 8 9759' (ppb Eq) 0 15 Depth Time: Set At in 0 0' 33 Gas Summary Depth 22.5 952' - C-2 43 Tools 0 155 SPP (psi) Gallons/stroke TFABit Type Minimum 4 MBT 12276' pH 0 4518506 10.75'' - - Units* Casing Summary Lithology (%)Siltst 907-659-7599Unit Phone: 4 Craig Amos Maximum Report By:Logging Engineers:Craig Amos\ Macy Williams Size 62.6 Grade 16.00'' Intermediate 01091.77 211.21 0 0 508 (max)(current) 10123 0 • 24 hr Recap: Continue tripping out of hole from TD. Lay Down BHA. Begin rigging up to run casing. Minimal gas seen on trip out with a max gas of 155 units seen at 952' MD and an average gas of 33 units seen whilst pumping on the trip out. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 880.56 10 . . # * rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 500.00 23 020 Depth Condition ROP ROP (ft/hr) 4.23 @ Mud Data Current Pump & Flow Data: - Max Gamma, Res, ECD, Directional Morning Report Report # 16 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: Bit # 1 10.0 9.875 9.70 PDC 9.70 Size 12776' 100% Gas In Air=10,000 Units-Connection 201 API FL Chromatograph (ppm) 15.02517' 12276' WOB Conductor 2500' 14 -- Avg Min Comments RPM ECD (ppg) ml/30min 278Background (max)Trip Average 1627 Mud Type Lst Type Depth in / out 130' Cht Cement 0 32 C-4n Cly 3 0 57 Hours C-3 66.60 C-4i AK-AM-0902171410 Tripping PV Yesterday's Depth: Current Depth: 24 Hour Progress: YP (lb/100ft2) 9.10 C-1 C-5i 150.0 LSND 4.0 GvlCoal 45.5 Weight Footage Ss Silt (current) Don Mickey/Paul Smith ShClyst Tuff C-5n Avg to12276' - Flow In (gpm) Flow In (spm) Current -- Date: 24 hr Max 7-Mar-2015 12:00 AM 12276' 12276' 0' Max @ ft cP 9 9759' (ppb Eq) 0 133 Depth Time: Set At in 0 0' 110 Gas Summary Depth 22.5 2509' - C-2 44 Tools 0 1627 SPP (psi) Gallons/stroke TFABit Type Minimum 7 MBT 12276' pH 0 50206980 10.75'' - - Units* Casing Summary Lithology (%)Siltst 907-659-7599Unit Phone: 24 Craig Amos Maximum Report By:Logging Engineers:Craig Amos\ Macy Williams Size 62.6 Grade 16.00'' Intermediate 01091.77 211.21 0 0 581 (max)(current) 11926 0 24 hr Recap: Continue rigging up casing handling tools, begin running in with 7.625" casing, currently at 7158' MD. Gas peak of 1627 units seen when circulating at shoe. Since leaving shoe gas has been between 100 - 500 units consistently with occasional peaks of around 800 units. This is a trend that was higher than when the section was drilled and is probably caused by the TOOH and the length of time the formation has been left open. 0 bbls have been lost on the trip so far. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 880.56 10 . . * 24 hr Recap: Continue running casing, patially lose circulation around 9432' MD, attempt to restablish circulation failed, continue running casing. Complelty lose returns around 9500' MD. Losses for the trip at 361 bbls so far. Max gas of 409 units seen at 7210' MD whilst running in, with an average of 150 units whilst getting returns and 54 units for the 24 hours. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 880.56 10 (max)(current) 5826 0 01091.77 211.21 0 0 446 Size 62.6 Grade 16.00'' Intermediate 907-659-7599Unit Phone: 3 Craig Amos Maximum Report By:Logging Engineers:Craig Amos\ Macy Williams 44612 10.75'' - - Units* Casing Summary Lithology (%)Siltst Minimum 13 MBT 12276' pH 0 63 0 409 SPP (psi) Gallons/stroke TFABit Type Depth 20.0 7210' - C-2 64 Tools Set At in 0 0' 54 Gas Summary 0 145 Depth Time: 12276' 12276' 0' Max @ ft cP 19 9759' (ppb Eq) -- Date: 24 hr Max 8-Mar-2015 12:00 AM Tuff C-5n Avg to12276' - Flow In (gpm) Flow In (spm) Current Ss Silt (current) Larry Hill/Paul Smith ShClyst LSND 4.8 GvlCoal 45.5 Weight Footage YP (lb/100ft2) 8.30 C-1 C-5i 150.0 C-4i AK-AM-0902171410 Tripping PV Yesterday's Depth: Current Depth: 24 Hour Progress: 0 0 72 Hours C-3 66.60 Cement 0 0 C-4n Cly Depth in / out 130' Cht Mud Type Lst Type Average 409278Background (max)Trip -- Avg Min Comments RPM ECD (ppg) ml/30min API FL Chromatograph (ppm) 15.02517' 12276' WOB Conductor 2500' 28 100% Gas In Air=10,000 Units-Connection 250 1-1-WT-A-X-I-TD Bit # 1 10.0 9.875 9.70 PDC 9.70 Size 12776' Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: Morning Report Report # 17 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad ROP ROP (ft/hr) 4.23 @ Mud Data Current Pump & Flow Data: - Max Gamma, Res, ECD, Directional Depth Condition 49 038 mg/l 500.00 rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides . . * rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 500.00 2 00 Depth Condition ROP ROP (ft/hr) 4.23 @ Mud Data Current Pump & Flow Data: - Max Gamma, Res, ECD, Directional Morning Report Report # 18 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: 1-1-WT-A-X-I-TD Bit # 1 10.0 9.875 9.70 PDC 9.70 Size 12776' 100% Gas In Air=10,000 Units-Connection 6 API FL Chromatograph (ppm) 15.02517' 12276' WOB Conductor 2500' 25 -- Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max)Trip Average 16 Mud Type Lst Type Depth in / out 130' Cht Cement 0 0 C-4n Cly 0 0 3 Hours C-3 66.60 C-4i AK-AM-0902171410 Cementing PV Yesterday's Depth: Current Depth: 24 Hour Progress: YP (lb/100ft2) 8.30 C-1 C-5i 150.0 LSND 4.8 GvlCoal 45.5 Weight Footage Ss Silt (current) Larry Hill/Paul Smith ShClyst Tuff C-5n Avg to12276' - Flow In (gpm) Flow In (spm) Current -- Date: 24 hr Max 9-Mar-2015 12:00 AM 12276' 12276' 0' Max @ ft cP 19 9759' (ppb Eq) 0 0 Depth Time: Set At in 0 0' 5 Gas Summary Depth 20.0 12106' - C-2 64 Tools 0 32 SPP (psi) Gallons/stroke TFABit Type Minimum 0 MBT 12276' pH 0 03941 10.75'' - - Units* Casing Summary Lithology (%)Siltst 907-659-7599Unit Phone: 0 Craig Amos Maximum Report By:Logging Engineers:Craig Amos\ Macy Williams Size 62.6 Grade 16.00'' Intermediate 01091.77 211.21 0 0 86 (max)(current) 466 0 24 hr Recap: Continue running casing, land casing and attempt to establish circulation. Pump cement and complete cement job. Currently waiting on cement. Max gas of 32 units seen on trip in, minimal gas due to lack of returns. 562 bbls lost during the 24 hours. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 880.56 10 . . * 24 hr Recap: Complete cement job. Lay down 5" pipe racked back in derrick. Begin BOP test. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 880.56 10 (max)(current) 0 0 01091.77 211.21 0 0 0 Size 62.6 Grade 16.00'' Intermediate 907-659-7599Unit Phone: 0 Craig Amos Maximum Report By:Logging Engineers:Craig Amos\ Macy Williams 0 10.75'' - - Units* Casing Summary Lithology (%)Siltst Minimum 0 MBT 12276' pH 0 0 0 0 SPP (psi) Gallons/stroke TFABit Type Depth - 0' - C-2 - Tools Set At in 0 0' 0 Gas Summary 0 0 Depth Time: 12276' 12276' 0' Max @ ft cP - 9759' (ppb Eq) -- Date: 24 hr Max 10-Mar-2015 12:00 AM Tuff C-5n Avg to12276' - Flow In (gpm) Flow In (spm) Current Ss Silt (current) Granville Rizek/Paul Smith ShClyst LSND - GvlCoal 45.5 Weight Footage YP (lb/100ft2) - C-1 C-5i 150.0 C-4i AK-AM-0902171410 Pipe Handeling PV Yesterday's Depth: Current Depth: 24 Hour Progress: 0 0 0 Hours C-3 66.60 Cement 0 0 C-4n Cly Depth in / out 130' Cht Mud Type Lst Type Average 00Background (max)Trip -- Avg Min Comments RPM ECD (ppg) ml/30min API FL Chromatograph (ppm) 15.02517' 12276' WOB Conductor 2207' - 100% Gas In Air=10,000 Units-Connection 0 1-1-WT-A-X-I-TD Bit # 1 - 9.875 - PDC - Size 12776' Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: Morning Report Report # 19 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad ROP ROP (ft/hr) 4.23 @ Mud Data Current Pump & Flow Data: - Max Gamma, Res, ECD, Directional Depth Condition 0 00 mg/l - rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides . . * rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l - 0 00 Depth Condition ROP ROP (ft/hr) 4.23 @ Mud Data Current Pump & Flow Data: - Max Gamma, Res, ECD, Directional Morning Report Report # 20 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: 1-1-WT-A-X-I-TD Bit # 1 - 9.875 - PDC - Size 12776' 100% Gas In Air=10,000 Units-Connection 0 API FL Chromatograph (ppm) 15.02517' 12276' WOB Conductor 2207' - -- Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max)Trip Average 0 Mud Type Lst Intermediate Type 2 Depth in / out 130' Cht Cement 0 0 12276' C-4n Cly 0 0 0 Hours C-3 66.60 C-4i AK-AM-0902171410 Pipe Handeling PV Yesterday's Depth: Current Depth: 24 Hour Progress: YP (lb/100ft2) - C-1 C-5i 150.0 0.00Hycalog LSND - GvlCoal 45.5 Weight 6.5 0.383 Footage Ss Silt (current) Granville Rizek/Paul Smith ShClyst Tuff C-5n Avg to12276' - Flow In (gpm) Flow In (spm) Current -- Date: 24 hr Max 11-Mar-2015 12:00 AM 12276' 12276' 0' Max @ ft cP - 9759' (ppb Eq) 0 0 Depth Time: 29.7 Set At in 0 0' 0 Gas Summary Depth - 0' - C-2 - Tools 0 0 SPP (psi) Gallons/stroke TFABit Type Minimum 0 MBT 12276' pH 0 00 10.75'' - - Units* Casing Summary Lithology (%)Siltst 907-659-7599Unit Phone: 0 Craig Amos Maximum Report By:Logging Engineers:Craig Amos\ Macy Williams Size 62.6 Grade 12266' 16.00'' 7.69'' Surface 01091.77 211.21 0 0 0 (max)(current) 0 0 24 hr Recap: Complete BOP test, pick up 4" DP and rack back. Begin picking up BHA and load sources. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 880.56 10 . . * 24 hr Recap: Begin running in with 6.5" BHA, running with doubles before singiling into to TD. Performing casing test at midnight. No loses on trip in, no trip gas due to cased hole. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 379 0 (max)(current) 0 0 3864509130 0 0 0 Size 62.6 Grade 12266' 16.00'' 7.69'' Surface 907-659-7599Unit Phone: 0 Craig Amos Maximum Report By:Logging Engineers:Craig Amos\ Macy Williams 0 10.75'' - - Units* Casing Summary Lithology (%)Siltst Minimum 0 MBT 12276' pH 0 0 0 0 SPP (psi) Gallons/stroke TFABit Type Depth 2.0 0' - C-2 52 Tools Set At in 0 0' 0 Gas Summary 0 0 Depth Time: 29.7 12276' 12276' 0' Max @ ft cP 11 9759' (ppb Eq) -- Date: 24 hr Max 12-Mar-2015 12:00 AM Tuff C-5n Avg to12276' - Flow In (gpm) Flow In (spm) Current Ss Silt (current) Granville Rizek/Paul Smith ShClyst Hycalog LSND 6.5 GvlCoal 45.5 Weight 6.5 0.383 Footage YP (lb/100ft2) 10.50 C-1 C-5i 150.0 0.00 C-4i AK-AM-0902171410 TIH PV Yesterday's Depth: Current Depth: 24 Hour Progress: 0 0 0 Hours C-3 66.60 Cement 0 0 12276' C-4n Cly Depth in / out 130' Cht Mud Type Lst Intermediate Type 2 Average 00Background (max)Trip -- Avg Min Comments RPM ECD (ppg) ml/30min API FL Chromatograph (ppm) 15.02517' 12276' WOB Conductor 2207' 18 100% Gas In Air=10,000 Units-Connection 0 1-1-WT-A-X-I-TD Bit # 1 6.0 9.875 9.50 PDC 9.50 Size 12776' Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: Morning Report Report # 21 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad ROP ROP (ft/hr) 4.23 @ Mud Data Current Pump & Flow Data: - Max Gamma, Res, ECD, Directional Depth Condition 0 00 mg/l 720.00 rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides . . * Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 125000 120 04 Depth Condition ROP ROP (ft/hr) 4.23 @ Mud Data Current Pump & Flow Data: 2211 Max Gamma, Res, ECD, Directional Morning Report Report # 22 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.01 Doyon 25 Report For: 1-1-WT-A-X-I-TD Bit # 1 7.8 9.875 9.50 PDC 9.50 Size 12776' 100% Gas In Air=10,000 Units0Connection 250 API FL Chromatograph (ppm) 15.02517' 12276' WOB Conductor 2207' 19 10.6810.88 Avg Min Comments RPM ECD (ppg) ml/30min 68Background (max)Trip Average 0 Mud Type Lst Intermediate Type 2 Depth in / out 130' Cht 90% Cement 0 2 12276' C-4n Cly 0 1 351 Hours C-3 10% 66.60 C-4i AK-AM-0902171410 Drilling PV Yesterday's Depth: Current Depth: 24 Hour Progress: YP (lb/100ft2) 10.00 C-1 C-5i 150.0 0.00Hycalog LSND 4.2 GvlCoal 45.5 Weight 6.5 0.383 Footage Ss Silt (current) Granville Rizek/Paul Smith ShClyst Tuff C-5n Avg to12276' 90.0 Flow In (gpm) Flow In (spm) Current 12479'86.0 Date: 24 hr Max 13-Mar-2015 12:00 AM 12276' 12480' 204' Max @ ft cP 10 9759' (ppb Eq) 0 8 Depth Time: 29.7 Set At in 25 12319' 41 Gas Summary Depth 1.3 12386' 78.0 C-2 50 Tools 16 76 SPP (psi) Gallons/stroke TFABit Type Minimum 24 MBT 12276' pH 84 836645 10.75'' 250 59 Units* Casing Summary Lithology (%)Siltst 907-659-7599Unit Phone: 1 Craig Amos Maximum Report By:Logging Engineers:Craig Amos\ Todd Wilson Size 62.6 Grade 12266' 16.00'' 7.69'' Surface 3954521.5 51 67 2165 546 (max)(current) 3487 120 24 hr Recap: Continue casing test, begin drilling cement/floats and shoe track. Drill 20' new hole to 12296' MD. Perform FIT test to 16.1 ppg. Displace well to 9.5 ppg Kla-Shield. Begin drilling production section from 12296' MD to 12480' MD at midnight. Max gas of 76 units seen whilst drilling new formation with an average of 41 units. 0 bbls of mud lost. The samples have been Siltstone, medium grey to light grey, soft to firm, blocky to crumbly, calcareous, argillaceous throughout. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 388 0 . . * 24 hr Recap: Continue drilling 6.5" hole section from 12480' MD to 13334' MD at report time. Background gas was low at around 120 units until 13020' MD, after 13020' MD gas increase to 10,000 units maxing out the SDL equipment, also indicating the top of the Seismic Bermuda. The gas stayed around 10,000 units until 13334' MD, the well was then circulated in order to reduce the gas levels. The mud was showing as low as 9.0 ppg unpressurised when the gas was around 10,000 units. The gas was eventually reduced to +- 5500 units by increasing the MPD back pressure from 140 to 190psi. The C1 - C5 break down of gas shows very high levels of C2-C5 indicating a heavier wetter gas. The Carbon Comparison between the Total Hydrocarbon Analyzer and Chromatograph break down, shows very similar numbers with a larger proportion of the Total Gas being made up of heavier gases, this is similar to the 2L-308 well. 0 bbls mud lost last 24 hours. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 410.7 0 (max)(current) 347032 1925 4178553.3 53.8 70 9126 95918 Size 62.6 Grade 12266' 16.00'' 7.69'' Surface 907-659-7599Unit Phone: 81334 Craig Amos Maximum Report By:Logging Engineers:Craig Amos\ Todd Wilson 546376 10.75'' 250 59 Units* Casing Summary Lithology (%)Siltst Minimum 22478 MBT 12276' pH 0.916 914 36753 934 10,000 SPP (psi) Gallons/stroke TFABit Type Depth 1.9 13207' 53.0 C-2 45 Tools Set At in 140 12819' 5723 Gas Summary 247 119803 Depth Time: 29.7 12480' 13334' 854' Max @ ft cP 10 9759' (ppb Eq) 12916'38.1 Date: 24 hr Max 14-Mar-2015 12:00 AM Tuff C-5n Avg to12276' 158.0 Flow In (gpm) Flow In (spm) Current Ss Silt (current) Granville Rizek/Paul Smith ShClyst Hycalog LSND 3.8 GvlCoal 45.5 Weight 6.5 0.383 Footage YP (lb/100ft2) 10.00 C-1 C-5i 150.0 0.00 C-4i AK-AM-0902171410 Drilling PV Yesterday's Depth: Current Depth: 24 Hour Progress: 9097 912 48889 Hours C-3 66.60 Cement 216 18160 12276' C-4n Cly Depth in / out 130' Cht 10% Mud Type Lst 90% Intermediate Type 2 Average 05092Background (max)Trip 10.6810.88 Avg Min Comments RPM ECD (ppg) ml/30min API FL Chromatograph (ppm) 15.02517' 12276' WOB Conductor 2207' 20 100% Gas In Air=10,000 Units2283Connection 102944 1-1-WT-A-X-I-TD Bit # 1 7.0 9.875 9.60 PDC 9.60 Size 12776' Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.70 Doyon 25 Report For: Morning Report Report # 23 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad ROP ROP (ft/hr) 4.23 @ Mud Data Current Pump & Flow Data: 2370 Max Gamma, Res, ECD, Directional Depth Condition 55293 6974639951 mg/l 57000 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides . . * Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 54000 116253 6974639951 Depth Condition ROP ROP (ft/hr) 4.23 @ Mud Data Current Pump & Flow Data: 2580 Max Gamma, Res, ECD, Directional Morning Report Report # 24 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 12.00 Doyon 25 Report For: 1-1-WT-A-X-I-TD Bit # 1 8.5 9.875 10.00 PDC 10.00 Size 12776' 100% Gas In Air=10,000 Units10,000Connection 263078 API FL Chromatograph (ppm) 15.02517' 12276' WOB Conductor 2207' 25 11.4011.80 Avg Min Comments RPM ECD (ppg) ml/30min 10,000Background (max)Trip Average N/A Mud Type Lst 70% Intermediate Type 2 Depth in / out 130' Cht 30% Cement 36818 20315 12276' C-4n Cly 9097 36547 54268 Hours C-3 66.60 C-4i AK-AM-0902171410 Drilling PV Yesterday's Depth: Current Depth: 24 Hour Progress: YP (lb/100ft2) 10.00 C-1 C-5i 150.0 0.00Hycalog LSND 2.0 GvlCoal 45.5 Weight 6.5 0.383 Footage Ss Silt (current) Granville Rizek/Paul Smith ShClyst Tuff C-5n Avg to12276' 90.0 Flow In (gpm) Flow In (spm) Current 14279'38.1 Date: 24 hr Max 15-Mar-2015 12:00 AM 13334' 14473' 1139' Max @ ft cP 10 9759' (ppb Eq) 8952 118454 Depth Time: 29.7 Set At in 5646 14120' 10,000 Gas Summary Depth 2.0 14226' 53.0 C-2 45 Tools 10654 10,000 SPP (psi) Gallons/stroke TFABit Type Minimum 22478 MBT 12276' pH 0.916 54627 33839548354 10.75'' 250 59 Units* Casing Summary Lithology (%)Siltst 907-659-7599Unit Phone: 97195 Craig Amos Maximum Report By:Logging Engineers:Craig Amos\ Todd Wilson Size 62.6 Grade 12266' 16.00'' 7.69'' Surface 4466594.2 154.49 77 243714 164472 (max)(current) 347032 44008 24 hr Recap: Continue drilling 6.5" hole section from 13334' MD to 14473' MD at report time. Sperry gas THA has been maxed out at 10,000 units for a large part of the day, the C1 to C5 spread is similar to yesterday with high levels of C2 - C5 with particularly large amounts of C3 throughout the interval. 263078 ppm C3 is high, with a methane equivalent of several thousand units. The formation is predominantly Sandstone from 13022' MD with Siltstone increasing around 14200' MD. The Sandstone has good shows with dull yellow fluorescence, a slow blue white blooming cut and dull yellow residual florescence. Oil condensate is also being collected from the gas sampling lines due to the high efficiency of the Sperry system. 0 bbls of mud were lost down hole. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 439.72 0 . . * 24 hr Recap: Continue drilling 6.5" hole section from 14473' MD to 15673' MD at report time. Gas remained above 10,000 units with small periods around 8800 units. After weighting up at 15260' MD to 10.5 ppg the gas dropped down to +- 6000 units with connection gases above 10,000 units. The gas still contains significant heavies C3 and C5 particularly the Total Alkane Response of the Chromatograph still indicates similar values to that of the THA. 0 bbls of mud were lost down hole. The formation is predominantly Sandstone with some Siltstone 40% around 15420' MD with a Show of moderate odor, 40% dull yellow fluorescence, blooming blue white cut, pale straw color cut, bright white residual fluorescence. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 471.95 0 (max)(current) 347951 8694 4786639.6 167.7 81 89299 154779 Size 62.6 Grade 12266' 16.00'' 7.69'' Surface 907-659-7599Unit Phone: 93328 Craig Amos Maximum Report By:Logging Engineers:Craig Amos\ Todd Wilson 854263 10.75'' 250 59 Units* Casing Summary Lithology (%)Siltst Minimum 12390 MBT 12276' pH 0.916 18181 32115 3718 10,000 SPP (psi) Gallons/stroke TFABit Type Depth 3.8 14473' 70.0 C-2 50 Tools Set At in 1651 15401' 8,766 Gas Summary 6047 108637 Depth Time: 29.7 14473' 15673' 1200' Max @ ft cP 17 9759' (ppb Eq) 15475'61.0 Date: 24 hr Max 16-Mar-2015 12:00 AM Tuff C-5n Avg to12276' 107.0 Flow In (gpm) Flow In (spm) Current Ss Silt (current) Granville Rizek/Paul Smith ShClyst Hycalog LSND 4.0 GvlCoal 45.5 Weight 6.5 0.383 Footage YP (lb/100ft2) 10.00 C-1 C-5i 150.0 0.00 C-4i AK-AM-0902171410 Drilling PV Yesterday's Depth: Current Depth: 24 Hour Progress: 10138 18212 67113 Hours C-3 66.60 Cement 37729 17093 12276' C-4n Cly Depth in / out 130' Cht 20% Mud Type Lst 80% Intermediate Type 2 Average N/A10,000Background (max)Trip 11.4011.80 Avg Min Comments RPM ECD (ppg) ml/30min API FL Chromatograph (ppm) 15.02517' 12276' WOB Conductor 2207' 26 100% Gas In Air=10,000 Units10,000Connection 225963 1-1-WT-A-X-I-TD Bit # 1 11.5 9.875 10.50 PDC 10.50 Size 12776' Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 12.00 Doyon 25 Report For: Morning Report Report # 25 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad ROP ROP (ft/hr) 4.23 @ Mud Data Current Pump & Flow Data: 2957 Max Gamma, Res, ECD, Directional Depth Condition 81265 4225345360 mg/l 54000 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides . . * Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 35000 81621 5954837147 Depth Condition ROP ROP (ft/hr) 4.23 @ Mud Data Current Pump & Flow Data: 2540 Max Gamma, Res, ECD, Directional Morning Report Report # 26 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 12.00 Doyon 25 Report For: 1-1-WT-A-X-I-TD Bit # 1 15.0 9.875 11.00 PDC 11.00 Size 12776' 100% Gas In Air=10,000 Units10,000Connection 208868 API FL Chromatograph (ppm) 15.02517' 12276' WOB Conductor 2207' 34 11.4011.80 Avg Min Comments RPM ECD (ppg) ml/30min 10,000Background (max)Trip Average N/A Mud Type Lst 90% Intermediate Type 2 16168' Depth in / out 130' Cht 10% Cement 56984 13791 12276' C-4n Cly 8174 35269 76730 Hours C-3 66.60 C-4i AK-AM-0902171410 Condition Mud PV Yesterday's Depth: Current Depth: 24 Hour Progress: YP (lb/100ft2) 10.00 C-1 C-5i 150.0 0.00 3892'Hycalog LSND 4.0 GvlCoal 45.5 Weight 6.5 0.383 Footage Ss Silt (current) Granville Rizek/Paul Smith ShClyst Tuff C-5n Avg to12276' 99.0 Flow In (gpm) Flow In (spm) Current 15933'52.0 Date: 24 hr Max 17-Mar-2015 12:00 AM 15673' 16168' 495' Max @ ft cP 21 9759' (ppb Eq) 7546 81710 Depth Time: 29.7 Set At in 8049 15698' 9,793 Gas Summary Depth 6.3 15805' 0.0 C-2 53 Tools 9865 10,000 SPP (psi) Gallons/stroke TFABit Type Minimum 10929 MBT 12276' pH 0.916 79652 24522713648 10.75'' 207 49 Units* Casing Summary Lithology (%)Siltst 907-659-7599Unit Phone: 91775 Craig Amos Maximum Report By:Logging Engineers:Craig Amos\ Todd Wilson Size 62.6 Grade 12266' 16.00'' 7.69'' Surface 4921659.1 173.3 100 354963 156355 (max)(current) 392953 70236 24 hr Recap: Continue drilling 6.5" hole section from 15673' MD to TD at 16168' MD. Gas remained above 10,000 units until TD. Circulate well and weight up mud to 11.0 ppg whilst cleaning the well. Background gas was reduced to 2500 units after mud was weighed up, currently at 1720 units. 0 bbls lost down hole. The formation is predominantly Sandstone with shows of moderate odor, 60% dull yellow fluorescence, blooming blue white cut, pale straw color cut, bright white residual fluorescence. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 485.7 0 . . * 24 hr Recap: Continue conditioning mud to 11 ppg, begin POOH whilst pumping currently at 12194' MD. Displace well to 11.5 ppg at report time. Gas remained high at 10,000 units until 15,900' MD when it decreased to around 4250 units, decreasing to 3400 units around 13790' MD. 0 bbls mud lost down hole. Samples were picked up and shipped this afternoon. No mud data received at report time. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 485.7 0 (max)(current) 128161 0 4921659.1 173.3 100 0 29728 Size 62.6 Grade 12266' 16.00'' 7.69'' Surface 907-659-7599Unit Phone: 57910 Craig Amos Maximum Report By:Logging Engineers:Craig Amos\ Todd Wilson 728749 10.75'' 0 0 Units* Casing Summary Lithology (%)Siltst Minimum 4965 MBT 12276' pH 0.916 0 14904 0 10,000 SPP (psi) Gallons/stroke TFABit Type Depth 16085' n/a C-2 Tools Set At in 0 0' 4,759 Gas Summary 0 46172 Depth Time: 29.7 16168' 16168' 0' Max @ ft cP 9759' (ppb Eq) n/an/a Date: 24 hr Max 17-Mar-2015 12:00 AM Tuff C-5n Avg to12276' n/a Flow In (gpm) Flow In (spm) Current Ss Silt (current) Granville Rizek/Rob Reinhardt ShClyst Hycalog LSND GvlCoal 45.5 Weight 6.5 0.383 Footage YP (lb/100ft2) C-1 C-5i 150.0 0.00 3892' C-4i AK-AM-0902171410 Displacing Mud PV Yesterday's Depth: Current Depth: 24 Hour Progress: 4141 0 141560 Hours C-3 66.60 Cement 0 8461 12276' C-4n Cly 16168' Depth in / out 130' Cht Mud Type Lst Intermediate Type 2 Average 10000297Background (max)Trip Avg Min Comments RPM ECD (ppg) ml/30min API FL Chromatograph (ppm) 15.02517' 12276' WOB Conductor 2207' 100% Gas In Air=10,000 Unitsn/aConnection 133637 1-1-WT-A-X-I-TD Bit # 1 9.875 11.00 PDC 11.00 Size 12776' Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: Morning Report Report # 27 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad ROP ROP (ft/hr) 4.23 @ Mud Data Current Pump & Flow Data: 0 Max Gamma, Res, ECD, Directional Depth Condition 34185 3110816863 mg/l Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides . . * Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 93000 23399 2191511969 Depth Condition ROP ROP (ft/hr) 4.23 @ Mud Data Current Pump & Flow Data: 0 Max Gamma, Res, ECD, Directional Morning Report Report # 28 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: 1-1-WT-A-X-I-TD Bit # 1 17.5 9.875 12.20 PDC 12.20 Size 12776' 100% Gas In Air=10,000 Unitsn/aConnection 154188 API FL Chromatograph (ppm) 15.02517' 12276' WOB Conductor 2207' 28 Avg Min Comments RPM ECD (ppg) ml/30min 201Background (max)Trip Average 10000 Mud Type Lst Intermediate Type 2 16168' Depth in / out 130' Cht Cement 0 10133 12276' C-4n Cly 2946 0 21677 Hours C-3 66.60 C-4i AK-AM-0902171410 Displacing Mud PV Yesterday's Depth: Current Depth: 24 Hour Progress: YP (lb/100ft2) 10.00 C-1 C-5i 150.0 0.00 3892'Hycalog LSND 4.8 GvlCoal 45.5 Weight 6.5 0.383 Footage Ss Silt (current) Granville Rizek/Rob Reinhardt ShClyst Tuff C-5n Avg to12276' n/a Flow In (gpm) Flow In (spm) Current n/an/a Date: 24 hr Max 19-Mar-2015 12:00 AM 16168' 16168' 0' Max @ ft cP 21 9759' (ppb Eq) 0 51750 Depth Time: 29.7 Set At in 0 0' 3,147 Gas Summary Depth 1.9 12189' n/a C-2 55 Tools 0 10,000 SPP (psi) Gallons/stroke TFABit Type Minimum 3405 MBT 12276' pH 0.916 0 16312686165 10.75'' 0 0 Units* Casing Summary Lithology (%)Siltst 907-659-7599Unit Phone: 69008 Craig Amos Maximum Report By:Logging Engineers:Craig Amos\ Macy Williams Size 62.6 Grade 12266' 16.00'' 7.69'' Surface 4921659.1 173.3 100 0 166495 (max)(current) 107167 0 24 hr Recap: Continue conditioning mud to 12.5 ppg, perform exhale test to determine flow. Gas remained high at the shoe dropping to 3000-4000 units inside casing. 0 bbls of mud lost. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 485.7 0 . . * 24 hr Recap: Continue conditioning mud to 12.5 ppg, circulate mud around. Perform well shut in and monitor for losses/gains. Max gas of 2585 units seen whilst circulating at 12189' MD, an average background gas of 661 units seen and currently at 331 units. 0 bbls of mud lost. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 485.7 0 (max)(current) 13095 0 4921659.1 173.3 100 0 13261 Size 62.6 Grade 12266' 16.00'' 7.69'' Surface 907-659-7599Unit Phone: 16016 Craig Amos Maximum Report By:Logging Engineers:Craig Amos\ Macy Williams 89472 10.75'' 21 5 Units* Casing Summary Lithology (%)Siltst Minimum 465 MBT 12276' pH 0.916 0 2133 0 2585 SPP (psi) Gallons/stroke TFABit Type Depth 1.9 12189' n/a C-2 55 Tools Set At in 0 0' 610 Gas Summary 0 7513 Depth Time: 29.7 16168' 16168' 0' Max @ ft cP 16 9759' (ppb Eq) n/an/a Date: 24 hr Max 20-Mar-2015 12:00 AM Tuff C-5n Avg to12276' n/a Flow In (gpm) Flow In (spm) Current Ss Silt (current) Granville Rizek/Rob Reinhardt ShClyst Hycalog LSND 4.1 GvlCoal 45.5 Weight 6.5 0.383 Footage YP (lb/100ft2) 10.00 C-1 C-5i 150.0 0.00 3892' C-4i AK-AM-0902171410 Weighing Up Mud PV Yesterday's Depth: Current Depth: 24 Hour Progress: 616 0 2053 Hours C-3 66.60 Cement 0 2112 12276' C-4n Cly 16168' Depth in / out 130' Cht Mud Type Lst Intermediate Type 2 Average 2585331Background (max)Trip Avg Min Comments RPM ECD (ppg) ml/30min API FL Chromatograph (ppm) 15.02517' 12276' WOB Conductor 2207' 30 100% Gas In Air=10,000 Unitsn/aConnection 16319 1-1-WT-A-X-I-TD Bit # 1 18.5 9.875 12.60 PDC 12.60 Size 12776' Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: Morning Report Report # 29 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad ROP ROP (ft/hr) 4.23 @ Mud Data Current Pump & Flow Data: 360 Max Gamma, Res, ECD, Directional Depth Condition 2296 50051816 mg/l 62500 0 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides . . * 0 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 56000 755 3008855 Depth Condition ROP ROP (ft/hr) 4.23 @ Mud Data Current Pump & Flow Data: 471 Max Gamma, Res, ECD, Directional Morning Report Report # 30 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: 1-1-WT-A-X-I-TD Bit # 1 18.5 9.875 12.60 PDC 12.60 Size 12776' 100% Gas In Air=10,000 Unitsn/aConnection 1521 API FL Chromatograph (ppm) 15.02517' 12276' WOB Conductor 2207' 29 Avg Min Comments RPM ECD (ppg) ml/30min 135Background (max)Trip Average 464 Mud Type Lst Intermediate Type 2 16168' Depth in / out 130' Cht Cement 0 686 12276' C-4n Cly 347 0 427 Hours C-3 66.60 C-4i AK-AM-0902171410 POOH PV Yesterday's Depth: Current Depth: 24 Hour Progress: YP (lb/100ft2) 10.00 C-1 C-5i 150.0 0.00 3892'Hycalog LSND 5.2 GvlCoal 45.5 Weight 6.5 0.383 Footage Ss Silt (current) Granville Rizek/Rob Reinhardt ShClyst Tuff C-5n Avg to12276' n/a Flow In (gpm) Flow In (spm) Current n/an/a Date: 24 hr Max 21-Mar-2015 12:00 AM 16168' 16168' 0' Max @ ft cP 15 9759' (ppb Eq) 0 1748 Depth Time: 29.7 Set At in 0 0' 281 Gas Summary Depth 1.9 12189' n/a C-2 57 Tools 0 464 SPP (psi) Gallons/stroke TFABit Type Minimum 200 MBT 12276' pH 0.916 0 4504449 10.75'' 152 36 Units* Casing Summary Lithology (%)Siltst 907-659-7599Unit Phone: 5607 Craig Amos Maximum Report By:Logging Engineers:Craig Amos\ Macy Williams Size 62.6 Grade 12266' 16.00'' 7.69'' Surface 4921659.1 173.3 100 0 997 (max)(current) 1897 0 24 hr Recap: Continue conditioning mud to 12.6+ ppg, circulate mud around. Begin stripping out of hole. Gas remained low, with a maximum of 464 units at 12189' MD, an average of 281 units. 0 bbls of mud lost down hole. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 485.7 0 . . * 24 hr Recap: Continue Trip out with 6.5" drilling BHA and lay down same. Begin Rigging up and running 4.5" casing. Max gas 126 units, with an average of 28 units. 35 bbls lost downhole. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 485.7 0 (max)(current) 200 0 4921659.1 173.3 100 0 116 Size 62.6 Grade 12266' 16.00'' 7.69'' Surface 907-659-7599Unit Phone: 1616 Craig Amos Maximum Report By:Logging Engineers:Craig Amos\ Macy Williams 449 10.75'' 0 0 Units* Casing Summary Lithology (%)Siltst Minimum 9 MBT 12276' pH 0.916 0 118 0 126 SPP (psi) Gallons/stroke TFABit Type Depth 1.9 9685' n/a C-2 56 Tools Set At in 0 0' 28 Gas Summary 0 191 Depth Time: 29.7 16168' 16168' 0' Max @ ft cP 17 9759' (ppb Eq) n/an/a Date: 24 hr Max 22-Mar-2015 12:00 AM Tuff C-5n Avg to12276' n/a Flow In (gpm) Flow In (spm) Current Ss Silt (current) Granville Rizek/Rob Reinhardt ShClyst Hycalog LSND 5.2 GvlCoal 45.5 Weight 6.5 0.383 Footage YP (lb/100ft2) 10.00 C-1 C-5i 150.0 0.00 3892' C-4i AK-AM-0902171410 TIH PV Yesterday's Depth: Current Depth: 24 Hour Progress: 15 0 3 Hours C-3 66.60 Cement 0 147 12276' C-4n Cly 16168' Depth in / out 130' Cht Mud Type Lst Intermediate Type 2 Average 12626Background (max)Trip Avg Min Comments RPM ECD (ppg) ml/30min API FL Chromatograph (ppm) 15.02517' 12276' WOB Conductor 2207' 29 100% Gas In Air=10,000 Unitsn/aConnection 611 1-1-WT-A-X-I-TD Bit # 1 18.5 9.875 12.70 PDC 12.70 Size 12776' Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: Morning Report Report # 31 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad ROP ROP (ft/hr) 4.23 @ Mud Data Current Pump & Flow Data: 0 Max Gamma, Res, ECD, Directional Depth Condition 35 23579 mg/l 56500 0 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides . . * 0 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 72000 1-1-CT-A-X-I-TD 10574 63174647 Depth Condition ROP ROP (ft/hr) 4.23 @ Mud Data Current Pump & Flow Data: 390 Max Gamma, Res, ECD, Directional Morning Report Report # 32 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: 1-1-WT-A-X-I-TD Bit # 1 18.8 9.875 12.60 PDC 12.65 Size 12776' 100% Gas In Air=10,000 Unitsn/aConnection 351037 API FL Chromatograph (ppm) 40 15.02517' 12276' WOB Conductor 2207' 32 Avg Min Comments RPM ECD (ppg) ml/30min 5,564Background (max)Trip Average 10000 Mud Type Lst Intermediate Type 2 16168' Depth in / out 130' Cht Cement 0 13554 12276' C-4n Cly 905 1 8086 Hours C-3 66.60 C-4i AK-AM-0902171410 TIH PV Yesterday's Depth: Current Depth: 24 Hour Progress: YP (lb/100ft2) 10.00 150 C-1 C-5i 150.0 0.00 3892'Hycalog LSND 5.3 GvlCoal 45.5 Weight 6.5 0.383 Footage Ss Silt (current) Granville Rizek/Rob Reinhardt ShClyst Tuff C-5n Avg to12276' n/a Flow In (gpm) Flow In (spm) Current n/an/a Date: 24 hr Max 23-Mar-2015 12:00 AM 16168' 16168' 0' Max @ ft cP 19 9759' (ppb Eq) 0 102608 Depth Time: 29.7 Set At in 25 1026' 956 Gas Summary Depth 1.9 4975' n/a C-2 68 Tools 4 10000 SPP (psi) Gallons/stroke TFABit Type Minimum 1372 MBT 12276' pH 0.916 10 34154307983 10.75'' 85 20 Units* Casing Summary Lithology (%)Siltst 907-659-7599Unit Phone: 84121 Craig Amos Maximum Report By:Logging Engineers:Craig Amos\ Macy Williams Size 62.6 Grade 12266' 16.00'' 7.69'' Surface 1427656.5 58 71 2602 307983 (max)(current) 26430 23 24 hr Recap: Continue running 4.5" casing. Attempt to circulate after picking up one stand of 4" DP, Unable to establish circulation, shut down pumps and note increase in flow, shut in well, 100 psi gain. Oil content of mud increased from 2% to 4%. Max gas of 10,000 units when circulating at 4975' MD after stripping in hole. Large amounts of heavier gases C2/C3 noted with over 300,000 ppm of C3. An average of 956 units. 0 bbls lost downhole. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 428.2 0 . . * 24 hr Recap: Continue stripping in the hole with 4.5" casing, weigh up mud to 12.7 ppg mud. Max gas of 6802 units seen whilst circulating at 4976' MD. Gas then remained static at around 4900 unit, decreasing to 3000 units at 10269' MD. 0 bbls lost down hole. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 329 0 (max)(current) 14186 0 3372515.2 185 0 0 36714 Size 62.6 Grade 12266' 16.00'' 7.69'' Surface 907-659-7599Unit Phone: 49214 Craig Amos Maximum Report By:Logging Engineers:Craig Amos\ Macy Williams 114364 10.75'' 148 35 Units* Casing Summary Lithology (%)Siltst Minimum 1978 MBT 12276' pH 0.916 0 8301 0 6802 SPP (psi) Gallons/stroke TFABit Type Depth 1.9 4976' n/a C-2 62 Tools Set At in 0 0' 1,635 Gas Summary 0 30221 Depth Time: 29.7 16168' 16168' 0' Max @ ft cP 17 9759' (ppb Eq) n/an/a Date: 24 hr Max 24-Mar-2015 12:00 AM Tuff C-5n Avg to12276' n/a Flow In (gpm) Flow In (spm) Current Ss Silt (current) Granville Rizek/Rob Reinhardt ShClyst Hycalog LSND 5.3 GvlCoal 45.5 Weight 6.5 0.383 Footage YP (lb/100ft2) 10.00 150 C-1 C-5i 150.0 0.00 3892' C-4i AK-AM-0902171410 TIH PV Yesterday's Depth: Current Depth: 24 Hour Progress: 2124 0 4422 Hours C-3 66.60 Cement 0 6963 12276' C-4n Cly 16168' Depth in / out 130' Cht Mud Type Lst Intermediate Type 2 Average 68025,564Background (max)Trip -- Avg Min Comments RPM ECD (ppg) ml/30min API FL Chromatograph (ppm) 40 15.02517' 12276' WOB Conductor 2207' 42 100% Gas In Air=10,000 Unitsn/aConnection 138451 1-1-WT-A-X-I-TD Bit # 1 19.5 9.875 12.70 PDC 12.70 Size 12776' Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: Morning Report Report # 33 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad ROP ROP (ft/hr) 4.23 @ Mud Data Current Pump & Flow Data: 885 Max Gamma, Res, ECD, Directional Depth Condition 9466 162517696 mg/l 105000 1-1-CT-A-X-I-TD 0 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides . . * 0 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 87000 1-1-CT-A-X-I-TD 2987 69232278 Depth Condition ROP ROP (ft/hr) 4.23 @ Mud Data Current Pump & Flow Data: 360 Max Gamma, Res, ECD, Directional Morning Report Report # 34 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: 1-1-WT-A-X-I-TD Bit # 1 19.5 9.875 12.70 PDC 12.70 Size 12776' 100% Gas In Air=10,000 Unitsn/aConnection 45464 API FL Chromatograph (ppm) 40.0 15.02517' 12276' WOB Conductor 2207' 33 -- Avg Min Comments RPM ECD (ppg) ml/30min 391Background (max)Trip Average 3601 Mud Type Lst Intermediate Type 2 16168' Depth in / out 130' Cht Cement 0 2321 12276' C-4n Cly 827 0 608 Hours C-3 66.60 C-4i AK-AM-0902171410 BOP Test PV Yesterday's Depth: Current Depth: 24 Hour Progress: YP (lb/100ft2) 10.00 150.0 C-1 C-5i 150.0 0.00 3892'Hycalog LSND 4.1 GvlCoal 45.5 Weight 6.5 0.383 Footage Ss Silt (current) Granville Rizek/Rob Reinhardt ShClyst Tuff C-5n Avg to12276' n/a Flow In (gpm) Flow In (spm) Current n/an/a Date: 24 hr Max 25-Mar-2015 12:00 AM 16168' 16168' 0' Max @ ft cP 23 9759' (ppb Eq) 0 9476 Depth Time: 29.7 Set At in 0 0' 658 Gas Summary Depth 1.9 6669' n/a C-2 65 Tools 0 3601 SPP (psi) Gallons/stroke TFABit Type Minimum 987 MBT 12276' pH 0.916 0 3023148913 10.75'' 148 35 Units* Casing Summary Lithology (%)Siltst 907-659-7599Unit Phone: 20647 Craig Amos Maximum Report By:Logging Engineers:Craig Amos\ Macy Williams Size 62.6 Grade 12266' 16.00'' 7.69'' Surface 1781515.2 102 61 0 21098 (max)(current) 32648 0 24 hr Recap: TOOH with liner to 6669' MD and hang off liner with storm packer. BOP test. Begin circulating 12.7 ppg mud round. Max gas of 3601 units at 6669' MD, gas measurements at the shoe were low due to rigs utilization of the gas buster bypassing the Sperry system. Average Gas 658 units. 8 bbls lost down hole. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 329 0 . . * 24 hr Recap: Continue TOOH with 4.5" liner. Max gas 1698 units when circulating at 3660' MD, average gas 439 units. 5 bbls lost down hole. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 0 0 (max)(current) 2618 0 07230 0 0 8277 Size 62.6 Grade 12266' 16.00'' 7.69'' Surface 907-659-7599Unit Phone: 11994 Craig Amos Maximum Report By:Logging Engineers:Craig Amos\ Macy Williams 4989 10.75'' 0 0 Units* Casing Summary Lithology (%)Siltst Minimum 265 MBT 12276' pH 0.916 0 1608 0 1698 SPP (psi) Gallons/stroke TFABit Type Depth 2.8 3660' n/a C-2 74 Tools Set At in 0 0' 439 Gas Summary 0 5530 Depth Time: 29.7 16168' 16168' 0' Max @ ft cP 23 9759' (ppb Eq) n/an/a Date: 24 hr Max 26-Mar-2015 12:00 AM Tuff C-5n Avg to12276' n/a Flow In (gpm) Flow In (spm) Current Ss Silt (current) Granville Rizek/Rob Reinhardt ShClyst Hycalog LSND 4.6 GvlCoal 45.5 Weight 6.5 0.383 Footage YP (lb/100ft2) 10.50 150.0 C-1 C-5i 150.0 0.00 3892' C-4i AK-AM-0902171410 BOP Test PV Yesterday's Depth: Current Depth: 24 Hour Progress: 464 0 531 Hours C-3 66.60 Cement 0 1556 12276' C-4n Cly 16168' Depth in / out 130' Cht Mud Type Lst Intermediate Type 2 Average 1698117Background (max)Trip -- Avg Min Comments RPM ECD (ppg) ml/30min API FL Chromatograph (ppm) 40.0 15.02517' 12276' WOB Conductor 2207' 36 100% Gas In Air=10,000 Unitsn/aConnection 43336 1-1-WT-A-X-I-TD Bit # 1 20.0 9.875 12.70 PDC 12.70 Size 12776' Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: Morning Report Report # 35 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad ROP ROP (ft/hr) 4.23 @ Mud Data Current Pump & Flow Data: 0 Max Gamma, Res, ECD, Directional Depth Condition 970 40542278 mg/l 87000 1-1-CT-A-X-I-TD 0 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides . . * 24 hr Recap: Continue TIH with clean out assembly. Currently circulating B/U at 12228' MD. Max gas of 2531 units seen at 5630' MD with an average of 977 units whilst tripping. 0 bbls of mud lost down hole. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 363 0 (max)(current) 16506 0 3712723128 742 0 13514 Size 62.6 Grade 12266' 16.00'' 7.69'' Surface 907-659-7599Unit Phone: 11037 Craig Amos Maximum Report By:Logging Engineers:Craig Amos\ Macy Williams 124409 10.75'' 21 5 Units* Casing Summary Lithology (%)Siltst Minimum 477 MBT 12276' pH 0.916 0 1746 0 2531 SPP (psi) Gallons/stroke TFABit Type Depth 2.0 5630' n/a C-2 60 Tools Set At in 0 0' 753 Gas Summary 0 5584 Depth Time: 29.7 16168' 16168' 0' Max @ ft cP 20 9759' (ppb Eq) n/an/a Date: 24 hr Max 27-Mar-2015 12:00 AM Tuff C-5n Avg to12276' n/a Flow In (gpm) Flow In (spm) Current Ss Silt (current) Lee Martin/Rob Reinhardt ShClyst Hycalog LSND 4.3 GvlCoal 45.5 Weight 6.5 0.383 Footage YP (lb/100ft2) 10.40 150.0 C-1 C-5i 150.0 0.00 3892' C-4i AK-AM-0902171410 TIH with cleanout assembly PV Yesterday's Depth: Current Depth: 24 Hour Progress: 630 0 2220 Hours C-3 66.60 Cement 0 1458 12276' C-4n Cly 16168' Depth in / out 130' Cht Mud Type Lst Intermediate Type 2 Average 2531977Background (max)Trip -- Avg Min Comments RPM ECD (ppg) ml/30min API FL Chromatograph (ppm) 40.0 15.02517' 12276' WOB Conductor 2207' 34 100% Gas In Air=10,000 Unitsn/aConnection 11257 1-1-WT-A-X-I-TD Bit # 1 18.0 9.875 12.40 PDC 12.40 Size 12776' Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: Morning Report Report # 36 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad ROP ROP (ft/hr) 4.23 @ Mud Data Current Pump & Flow Data: 608 Max Gamma, Res, ECD, Directional Depth Condition 2422 53011835 mg/l 83000 1-1-CT-A-X-I-TD 0 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides . . * 0 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 81000 1-1-CT-A-X-I-TD 37455 68452601 Depth Condition ROP ROP (ft/hr) 4.23 @ Mud Data Current Pump & Flow Data: 0 Max Gamma, Res, ECD, Directional Morning Report Report # 37 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: 1-1-WT-A-X-I-TD Bit # 1 17.0 9.875 12.40 PDC 11.90 Size 12776' 100% Gas In Air=10,000 Unitsn/aConnection 37455 API FL Chromatograph (ppm) 40.0 15.02517' 12276' WOB Conductor 2207' 22 -- Avg Min Comments RPM ECD (ppg) ml/30min 260Background (max)Trip Average 2073 Mud Type Lst Intermediate Type 2 16168' Depth in / out 130' Cht Cement 0 1765 12276' C-4n Cly 837 0 2688 Hours C-3 66.60 C-4i AK-AM-0902171410 TIH with cleanout assembly PV Yesterday's Depth: Current Depth: 24 Hour Progress: YP (lb/100ft2) 10.40 150.0 C-1 C-5i 150.0 0.00 3892'Hycalog LSND 4.7 GvlCoal 45.5 Weight 6.5 0.383 Footage Ss Silt (current) Lee Martin/Rob Reinhardt ShClyst Tuff C-5n Avg to12276' n/a Flow In (gpm) Flow In (spm) Current n/an/a Date: 24 hr Max 28-Mar-2015 12:00 AM 16168' 16168' 0' Max @ ft cP 12 9759' (ppb Eq) 0 5950 Depth Time: 29.7 Set At in 0 0' 872 Gas Summary Depth 2.0 12327' n/a C-2 46 Tools 0 2073 SPP (psi) Gallons/stroke TFABit Type Minimum 676 MBT 12276' pH 0.916 0 169065863 10.75'' 0 0 Units* Casing Summary Lithology (%)Siltst 907-659-7599Unit Phone: 15220 Craig Amos Maximum Report By:Logging Engineers:Craig Amos\ Macy Williams Size 62.6 Grade 12266' 16.00'' 7.69'' Surface 3430723117 686 0 9187 (max)(current) 16346 0 24 hr Recap: Continue TIH with clean out assembly to 13940' MD, attempt to circulate and lose returns, cut mud weight to 11.5 ppg and TOOH to shoe. Gas returns were minimal due to lost returns, max gas of 2073 units whilst tripping in at 12327' MD, with an average of 872 whilst getting returns. 202 bbls of mud lost down hole. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 335 0 . . * 24 hr Recap: Continue TOOH to 7320' MD and establish circulation. Begin TIH to casing shoe at 12200' MD and step up circulation from 0.5 bbls a min. Max gas of 2339 units when establishing returns at 7320' MD, with an average circulating gas of 436 units. 81 bbls of mud lost down hole. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 361 0 (max)(current) 5669 0 3689723127 95 0 11511 Size 62.6 Grade 12266' 16.00'' 7.69'' Surface 907-659-7599Unit Phone: 11349 Craig Amos Maximum Report By:Logging Engineers:Craig Amos\ Macy Williams 101187 10.75'' 148 35 Units* Casing Summary Lithology (%)Siltst Minimum 291 MBT 12276' pH 0.916 0 1760 0 2339 SPP (psi) Gallons/stroke TFABit Type Depth 2.0 7320' n/a C-2 48 Tools Set At in 0 0' 436 Gas Summary 0 5915 Depth Time: 29.7 16168' 16168' 0' Max @ ft cP 12 9759' (ppb Eq) n/an/a Date: 24 hr Max 29-Mar-2015 12:00 AM Tuff C-5n Avg to12276' n/a Flow In (gpm) Flow In (spm) Current Ss Silt (current) Lee Martin/Rob Reinhardt ShClyst Hycalog LSND 3.6 GvlCoal 45.5 Weight 6.5 0.383 Footage YP (lb/100ft2) 10.30 150.0 C-1 C-5i 150.0 0.00 3892' C-4i AK-AM-0902171410 TIH with cleanout assembly PV Yesterday's Depth: Current Depth: 24 Hour Progress: 1521 0 955 Hours C-3 66.60 Cement 0 396 12276' C-4n Cly 16168' Depth in / out 130' Cht Mud Type Lst Intermediate Type 2 Average 2339353Background (max)Trip -- Avg Min Comments RPM ECD (ppg) ml/30min API FL Chromatograph (ppm) 40.0 15.02517' 12276' WOB Conductor 2207' 24 100% Gas In Air=10,000 Unitsn/aConnection 15976 1-1-WT-A-X-I-TD Bit # 1 15.0 9.875 11.50 PDC 11.50 Size 12776' Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: Morning Report Report # 38 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad ROP ROP (ft/hr) 4.23 @ Mud Data Current Pump & Flow Data: 880 Max Gamma, Res, ECD, Directional Depth Condition 1338 33251146 mg/l 81000 1-1-CT-A-X-I-TD 0 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides . . * 0 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 80000 1-1-CT-A-X-I-TD 4304 39042119 Depth Condition ROP ROP (ft/hr) 4.23 @ Mud Data Current Pump & Flow Data: 1100 Max - Morning Report Report # 39 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: 1-1-WT-A-X-I-TD Bit # 1 15.0 9.875 11.55 PDC 11.50 Size 16168' 100% Gas In Air=10,000 Unitsn/aConnection 7881 API FL Chromatograph (ppm) 40.0 15.02517' 12276' WOB Conductor 2207' 28 -- Avg Min Comments RPM ECD (ppg) ml/30min 549Background (max)Trip Average 1977 Mud Type Lst Intermediate Type 2 16168' Depth in / out 130' Cht Cement 2115 871 12276' C-4n Cly 524 849 5086 Hours C-3 66.60 C-4i AK-AM-0902171410 TIH with cleanout assembly PV Yesterday's Depth: Current Depth: 24 Hour Progress: YP (lb/100ft2) 10.30 150.0 C-1 C-5i 150.0 0.00 3892'Hycalog LSND 3.7 GvlCoal 45.5 Weight 6.5 0.383 Footage Ss Silt (current) Lee Martin/Rob Reinhardt ShClyst Tuff C-5n Avg to- n/a Flow In (gpm) Flow In (spm) Current n/an/a Date: 24 hr Max 30-Mar-2015 12:00 AM 16168' 16168' 0' Max @ ft cP 11 9759' (ppb Eq) 260 3739 Depth Time: 29.7 Set At in 154 N/A 656 Gas Summary Depth 1.5 N/A n/a C-2 48 Tools 234 1977 SPP (psi) Gallons/stroke TFABit Type Minimum 640 MBT - pH 0.916 1346 1165110977 10.75'' 144 35 Units* Casing Summary Lithology (%)Siltst 907-659-7599Unit Phone: 6235 Connor Murray Maximum Report By:Logging Engineers:Connor Murray\ Macy Williams Size 62.6 Grade 12266' 16.00'' 7.69'' Surface 4582723175 131 14609 10042 (max)(current) 49191 1415 24 hr Recap: Continued to TIH. Washed from 12,237' to 14, 515' before circulating a bottoms-up. Then washed and reamed down to 15,369' where another bottoms-up was circulated before continuing to TIH. 29 bbls lost downhole. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 461 0 . . * 24 hr Recap: Washed and reamed from 15,938' down to TD (16168') and circulated a bottoms-up. Then displaced the 11.5 ppg mud with new 12.7 ppg NaBr KLA-SHIELD mud. The well was then monitored at bottom before beginning to TOOH. Washed out of hole to shoe and monitored well at the shoe. The well was static at the shoe so tripping proceeded on elevators. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 583 0 (max)(current) 29905 9 390872398 71 107 58777 Size 62.6 Grade 12266' 16.00'' 7.69'' Surface 907-659-7599Unit Phone: 46199 Connor Murray Maximum Report By:Logging Engineers:Connor Murray \ Macy Williams 184712 10.75'' 173 41 Units* Casing Summary Lithology (%)Siltst Minimum 986 MBT - pH 0.916 12 10105 0 9040 SPP (psi) Gallons/stroke TFABit Type Depth - N/A n/a C-2 48 Tools Set At in 19 N/A 1,018 Gas Summary 0 34087 Depth Time: 29.7 16168' 16168' 0' Max @ ft cP 11 9759' (ppb Eq) n/an/a Date: 24 hr Max 31-Mar-2015 12:00 AM Tuff C-5n Avg to- n/a Flow In (gpm) Flow In (spm) Current Ss Silt (current) Lee Martin / Paul Smith ShClyst Hycalog LSND 4.4 GvlCoal 45.5 Weight 6.5 0.383 Footage YP (lb/100ft2) 10.00 150.0 C-1 C-5i 150.0 0.00 3892' C-4i AK-AM-0902171410 TOOH PV Yesterday's Depth: Current Depth: 24 Hour Progress: 799 11 5598 Hours C-3 66.60 Cement 0 6784 12276' C-4n Cly 16168' Depth in / out 130' Cht Mud Type Lst Intermediate Type 2 Average 10033Background (max)Trip -- Avg Min Comments RPM ECD (ppg) ml/30min API FL Chromatograph (ppm) 40.0 15.02517' 12276' WOB Conductor 2207' 15 100% Gas In Air=10,000 Unitsn/aConnection 74283 1-1-WT-A-X-I-TD Bit # 1 21.0 9.875 12.70 PDC 12.60 Size 16168' Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: Morning Report Report # 40 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad ROP ROP (ft/hr) 4.23 @ Mud Data Current Pump & Flow Data: 620 Max - Depth Condition 6392 57843426 mg/l 180000 1-1-CT-A-X-I-TD 0 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides . . * 0 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 181000 1-1-CT-A-X-I-TD 6 88 Depth Condition ROP ROP (ft/hr) 4.23 @ Mud Data Current Pump & Flow Data: 0 Max - Morning Report Report # 41 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: 1-1-WT-A-X-I-TD Bit # 1 22.0 9.875 12.70 PDC 12.70 Size 16168' 100% Gas In Air=10,000 Unitsn/aConnection 13 API FL Chromatograph (ppm) 40.0 15.02517' 12276' WOB Conductor 2207' 18 -- Avg Min Comments RPM ECD (ppg) ml/30min 11Background (max)Trip Average 19 Mud Type Lst Intermediate Type 2 16168' Depth in / out 130' Cht Cement 0 0 12276' C-4n Cly 1 0 1 Hours C-3 66.60 C-4i AK-AM-0902171410 TIH w/ 4.5" Liner PV Yesterday's Depth: Current Depth: 24 Hour Progress: YP (lb/100ft2) 10.30 150.0 C-1 C-5i 150.0 0.00 3892'Hycalog LSND 4.6 GvlCoal 45.5 Weight 6.5 0.383 Footage Ss Silt (current) Lee Martin / Paul Smith ShClyst Tuff C-5n Avg to- n/a Flow In (gpm) Flow In (spm) Current n/an/a Date: 24 hr Max 1-Apr-2015 12:00 AM 16168' 16168' 0' Max @ ft cP 11 9759' (ppb Eq) 0 17 Depth Time: 29.7 Set At in 9 N/A 12 Gas Summary Depth - N/A n/a C-2 46 Tools 0 19 SPP (psi) Gallons/stroke TFABit Type Minimum 1 MBT - pH 0.916 0 0331 10.75'' 0 0 Units* Casing Summary Lithology (%)Siltst 907-659-7599Unit Phone: 68 Connor Murray Maximum Report By:Logging Engineers:Connor Murray \ Macy Williams Size 62.6 Grade 12266' 16.00'' 7.69'' Surface 73172376 Pumps Off 339 0 (max)(current) 242 0 24 hr Recap: Finished tripping out of hole and layed down BHA. Rigged up to run in 4.5" Liner. Began TIH with 4.5" liner. 25 bbls lost downhole. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 131 0 . . * 24 hr Recap: Ran in 4.5" liner from 4121' to 12260' filling every 10 stands. Circulated and reciprocated from 12260' to 12179' before continuing to run in hole to 16150' filling every 20 stands. Tagged bottom at 16168' and picked up to 16148'. Circulated and reciprocated from 16165' to 16138', dropped 1.125" WIV activation ball, and reestablished circulation. Continued to pump down ball @ 42 GPM. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 353 0 (max)(current) 516 0 3599723228 360 433 186 Size 62.6 Grade 12266' 16.00'' 7.69'' Surface 907-659-7599Unit Phone: 276 Connor Murray Maximum Report By:Logging Engineers:Connor Murray \ Macy Williams 2402 10.75'' 42 10 Units* Casing Summary Lithology (%)Siltst Minimum 4 MBT - pH 0.916 7 25 0 49 SPP (psi) Gallons/stroke TFABit Type Depth - N/A n/a C-2 46 Tools Set At in 6 N/A 15 Gas Summary 0 98 Depth Time: 29.7 16168' 16168' 0' Max @ ft cP 11 9759' (ppb Eq) n/an/a Date: 24 hr Max 2-Apr-2015 12:00 AM Tuff C-5n Avg to- n/a Flow In (gpm) Flow In (spm) Current Ss Silt (current) Lee Martin / Paul Smith ShClyst Hycalog LSND 4.8 GvlCoal 45.5 Weight 6.5 0.383 Footage YP (lb/100ft2) 10.30 150.0 C-1 C-5i 150.0 0.00 3892' C-4i AK-AM-0902171410 TIH w/ 4.5" Liner PV Yesterday's Depth: Current Depth: 24 Hour Progress: 4 0 18 Hours C-3 66.60 Cement 0 32 12276' C-4n Cly 16168' Depth in / out 130' Cht Mud Type Lst Intermediate Type 2 Average 3327Background (max)Trip -- Avg Min Comments RPM ECD (ppg) ml/30min API FL Chromatograph (ppm) 40.0 15.02517' 12276' WOB Conductor 2207' 17 100% Gas In Air=10,000 Unitsn/aConnection 162 1-1-WT-A-X-I-TD Bit # 1 22.0 9.875 12.70 PDC 12.80 Size 16168' Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: Morning Report Report # 42 Customer: Well: Area: Location: Rig: 2L-328 Conoco Phillips TARN 2L Pad ROP ROP (ft/hr) 4.23 @ Mud Data Current Pump & Flow Data: 444 Max - Depth Condition 25 4519 mg/l 180000 1-1-CT-A-X-I-TD 0 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides WELL INFORMATION Created On : Apr 21 2015 Customer :ConocoPhillips Alaska, Inc. Well Name :2L-328 (Sierra) Job Number :AK-XX-0902171410 Rig Name :Doyon 25 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 80.38 0.41 259.05 80.38 0.05 S 0.28 W -0.05 0.51 167.67 0.40 250.76 167.67 0.21 S 0.88 W -0.21 0.07 262.37 0.29 252.97 262.37 0.39 S 1.42 W -0.39 0.12 354.83 0.68 172.25 354.82 1.01 S 1.57 W -1.01 0.75 446.99 1.70 158.60 446.96 2.82 S 1.00 W -2.82 1.14 540.16 3.05 150.78 540.05 6.27 S 0.72 E -6.27 1.49 636.45 4.41 151.06 636.13 11.75 S 3.76 E -11.75 1.41 729.37 5.52 153.91 728.70 18.89 S 7.46 E -18.89 1.22 824.16 9.13 162.79 822.71 30.17 S 11.69 E -30.17 3.98 918.30 10.26 160.17 915.50 45.19 S 16.74 E -45.19 1.29 1012.84 11.09 158.53 1,008.41 61.57 S 22.93 E -61.57 0.93 1107.44 12.13 158.41 1,101.07 79.28 S 29.91 E -79.28 1.10 1202.21 13.84 155.99 1,193.41 98.90 S 38.19 E -98.90 1.89 1297.77 15.31 156.91 1,285.89 120.94 S 47.79 E -120.94 1.56 1356.90 16.08 158.82 1,342.82 135.76 S 53.81 E -135.76 1.57 1450.82 16.24 157.98 1,433.03 160.06 S 63.43 E -160.06 0.30 1545.80 19.79 152.95 1,523.34 186.71 S 75.73 E -186.71 4.08 1640.91 21.82 150.66 1,612.25 216.46 S 91.71 E -216.46 2.30 1735.85 24.17 147.83 1,699.64 248.30 S 110.71 E -248.30 2.73 1831.33 27.05 145.86 1,785.73 282.82 S 133.31 E -282.82 3.15 1924.59 31.69 143.07 1,866.99 319.97 S 159.94 E -319.97 5.19 2020.63 35.31 142.38 1,947.06 362.14 S 192.05 E -362.14 3.79 2114.81 39.29 141.13 2,021.97 406.93 S 227.40 E -406.93 4.30 2209.11 43.59 141.30 2,092.64 455.57 S 266.48 E -455.57 4.56 2304.24 48.14 139.09 2,158.87 507.97 S 310.21 E -507.97 5.06 2398.22 51.71 137.70 2,219.37 561.72 S 357.97 E -561.72 3.96 2437.12 51.70 138.26 2,243.47 584.40 S 378.40 E -584.40 1.13 2513.32 51.24 136.71 2,290.94 628.34 S 418.68 E -628.34 1.70 2572.84 52.98 136.06 2,327.50 662.34 S 451.08 E -662.34 3.05 INSITE V8.1.10 Page 1Job No:AK-XX-0902171410 Well Name:2L-328 (Sierra)Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2668.20 57.15 133.56 2,382.10 717.38 S 506.56 E -717.38 4.87 2763.02 62.34 132.75 2,429.86 773.37 S 566.30 E -773.37 5.52 2857.80 67.41 131.46 2,470.09 830.88 S 629.95 E -830.88 5.49 2951.94 71.71 130.38 2,502.96 888.63 S 696.60 E -888.63 4.69 3047.05 73.57 130.39 2,531.33 947.45 S 765.74 E -947.45 1.96 3143.57 72.38 131.80 2,559.59 1,008.10 S 835.29 E -1008.10 1.86 3238.51 71.69 134.42 2,588.88 1,069.81 S 901.22 E -1069.81 2.72 3333.89 71.63 135.62 2,618.90 1,133.85 S 965.21 E -1133.85 1.20 3427.90 71.51 135.36 2,648.62 1,197.45 S 1,027.74 E -1197.45 0.29 3523.25 71.77 134.48 2,678.65 1,261.35 S 1,091.82 E -1261.35 0.92 3617.70 71.89 133.08 2,708.10 1,323.44 S 1,156.61 E -1323.44 1.41 3711.60 71.93 133.20 2,737.26 1,384.48 S 1,221.74 E -1384.48 0.13 3806.53 71.83 133.45 2,766.79 1,446.38 S 1,287.37 E -1446.38 0.27 3901.24 71.77 132.95 2,796.37 1,507.97 S 1,352.96 E -1507.97 0.51 3995.03 72.17 132.87 2,825.40 1,568.69 S 1,418.28 E -1568.69 0.43 4087.61 72.34 132.43 2,853.61 1,628.43 S 1,483.13 E -1628.43 0.49 4181.64 72.23 131.16 2,882.23 1,688.13 S 1,549.91 E -1688.13 1.29 4276.58 72.89 131.02 2,910.68 1,747.66 S 1,618.17 E -1747.66 0.71 4371.32 72.89 131.40 2,938.55 1,807.31 S 1,686.29 E -1807.31 0.38 4465.48 72.83 131.24 2,966.30 1,866.72 S 1,753.87 E -1866.72 0.17 4559.48 72.87 129.69 2,994.02 1,925.01 S 1,822.20 E -1925.01 1.58 4653.97 72.85 128.14 3,021.87 1,981.73 S 1,892.46 E -1981.73 1.57 4749.39 72.83 128.82 3,050.02 2,038.46 S 1,963.83 E -2038.46 0.68 4843.61 72.82 130.00 3,077.85 2,095.61 S 2,033.38 E -2095.61 1.20 4938.38 72.70 130.46 3,105.94 2,154.06 S 2,102.48 E -2154.06 0.48 5032.40 72.92 130.30 3,133.72 2,212.25 S 2,170.90 E -2212.25 0.28 5126.88 72.86 130.14 3,161.52 2,270.56 S 2,239.85 E -2270.56 0.17 5220.19 72.82 130.37 3,189.05 2,328.17 S 2,307.89 E -2328.17 0.24 5314.97 72.96 130.18 3,216.93 2,386.73 S 2,377.00 E -2386.73 0.24 5410.55 72.88 130.53 3,245.01 2,445.89 S 2,446.63 E -2445.89 0.36 5505.59 72.93 131.29 3,272.94 2,505.38 S 2,515.28 E -2505.38 0.77 5600.46 72.86 132.07 3,300.85 2,565.68 S 2,583.00 E -2565.68 0.79 5695.02 72.73 132.59 3,328.82 2,626.50 S 2,649.78 E -2626.50 0.54 5789.26 72.41 132.53 3,357.05 2,687.32 S 2,716.00 E -2687.32 0.34 5884.25 72.35 132.63 3,385.80 2,748.57 S 2,782.67 E -2748.57 0.12 5978.38 72.45 133.04 3,414.26 2,809.58 S 2,848.46 E -2809.57 0.43 6072.93 72.42 133.36 3,442.80 2,871.28 S 2,914.17 E -2871.28 0.32 6168.03 72.35 133.38 3,471.58 2,933.52 S 2,980.06 E -2933.52 0.08 6262.17 72.38 132.98 3,500.10 2,994.92 S 3,045.48 E -2994.92 0.41 6356.23 72.35 131.74 3,528.59 3,055.31 S 3,111.72 E -3055.31 1.26 6450.97 72.26 130.87 3,557.39 3,114.89 S 3,179.52 E -3114.89 0.88 6545.17 72.77 130.82 3,585.69 3,173.65 S 3,247.49 E -3173.65 0.54 6640.94 72.89 130.83 3,613.97 3,233.47 S 3,316.73 E -3233.47 0.13 6736.08 72.77 131.37 3,642.05 3,293.22 S 3,385.23 E -3293.22 0.56 6831.82 72.73 131.54 3,670.44 3,353.76 S 3,453.76 E -3353.76 0.17 INSITE V8.1.10 Page 2Job No:AK-XX-0902171410 Well Name:2L-328 (Sierra)Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 6925.16 72.77 131.84 3,698.12 3,413.04 S 3,520.32 E -3413.04 0.31 7018.96 73.05 132.33 3,725.69 3,473.14 S 3,586.86 E -3473.14 0.58 7114.68 72.74 132.93 3,753.84 3,535.10 S 3,654.17 E -3535.10 0.68 7209.40 72.84 132.36 3,781.87 3,596.39 S 3,720.73 E -3596.39 0.58 7303.41 72.89 132.80 3,809.56 3,657.18 S 3,786.87 E -3657.18 0.45 7397.98 72.89 133.15 3,837.39 3,718.79 S 3,853.00 E -3718.79 0.35 7490.28 72.77 132.89 3,864.64 3,778.95 S 3,917.48 E -3778.95 0.30 7587.31 72.77 132.01 3,893.38 3,841.50 S 3,985.86 E -3841.50 0.87 7682.42 72.92 131.06 3,921.43 3,901.76 S 4,053.89 E -3901.76 0.97 7777.47 72.92 129.94 3,949.35 3,960.77 S 4,122.97 E -3960.77 1.13 7872.16 73.00 129.07 3,977.10 4,018.36 S 4,192.83 E -4018.36 0.88 7966.09 73.01 130.14 4,004.55 4,075.62 S 4,262.03 E -4075.62 1.09 8060.82 73.01 132.55 4,032.24 4,135.47 S 4,330.04 E -4135.47 2.43 8155.84 72.59 131.55 4,060.34 4,196.26 S 4,397.44 E -4196.26 1.10 8249.54 72.89 132.00 4,088.14 4,255.87 S 4,464.17 E -4255.87 0.56 8345.19 72.84 131.75 4,116.32 4,316.89 S 4,532.23 E -4316.89 0.26 8440.00 72.90 130.81 4,144.24 4,376.66 S 4,600.32 E -4376.66 0.95 8534.12 72.86 130.78 4,171.95 4,435.43 S 4,668.42 E -4435.43 0.05 8629.10 72.66 131.50 4,200.10 4,495.11 S 4,736.73 E -4495.11 0.75 8724.35 72.89 131.39 4,228.31 4,555.33 S 4,804.93 E -4555.33 0.27 8818.49 72.86 132.12 4,256.03 4,615.24 S 4,872.05 E -4615.24 0.74 8913.07 72.92 132.62 4,283.85 4,676.16 S 4,938.83 E -4676.16 0.51 9008.49 72.31 132.59 4,312.36 4,737.80 S 5,005.85 E -4737.80 0.64 9103.38 72.36 132.45 4,341.16 4,798.91 S 5,072.49 E -4798.91 0.15 9198.17 72.41 131.72 4,369.84 4,859.46 S 5,139.54 E -4859.46 0.74 9292.33 72.34 131.88 4,398.35 4,919.27 S 5,206.44 E -4919.27 0.18 9387.23 72.32 131.54 4,427.16 4,979.44 S 5,273.94 E -4979.44 0.34 9482.07 72.34 131.15 4,455.95 5,039.13 S 5,341.79 E -5039.13 0.39 9576.71 72.32 130.82 4,484.67 5,098.27 S 5,409.86 E -5098.27 0.33 9671.21 72.35 130.28 4,513.35 5,156.81 S 5,478.28 E -5156.81 0.55 9765.46 72.83 130.18 4,541.55 5,214.90 S 5,546.93 E -5214.90 0.52 9860.41 72.89 130.29 4,569.53 5,273.50 S 5,616.20 E -5273.50 0.13 9954.21 72.91 130.55 4,597.11 5,331.63 S 5,684.45 E -5331.63 0.27 10049.22 72.94 131.24 4,625.01 5,391.09 S 5,753.11 E -5391.09 0.69 10145.11 72.86 131.87 4,653.21 5,451.89 S 5,821.69 E -5451.89 0.63 10238.26 72.89 132.08 4,680.64 5,511.42 S 5,887.87 E -5511.42 0.22 10333.37 72.83 131.75 4,708.67 5,572.14 S 5,955.50 E -5572.14 0.34 10429.10 72.90 131.17 4,736.87 5,632.71 S 6,024.06 E -5632.71 0.58 10524.15 72.98 131.30 4,764.75 5,692.60 S 6,092.39 E -5692.60 0.16 10618.22 72.85 131.49 4,792.39 5,752.06 S 6,159.85 E -5752.06 0.24 10712.76 72.74 132.19 4,820.36 5,812.30 S 6,227.13 E -5812.30 0.72 10807.64 72.85 132.47 4,848.42 5,873.33 S 6,294.13 E -5873.33 0.30 10901.61 72.93 132.08 4,876.07 5,933.75 S 6,360.59 E -5933.75 0.41 10996.10 72.79 131.10 4,903.92 5,993.68 S 6,428.12 E -5993.68 1.00 11090.95 72.93 130.44 4,931.87 6,052.87 S 6,496.76 E -6052.87 0.68 INSITE V8.1.10 Page 3Job No:AK-XX-0902171410 Well Name:2L-328 (Sierra)Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 11186.07 72.38 130.85 4,960.23 6,112.01 S 6,565.65 E -6112.01 0.71 11279.02 72.35 131.31 4,988.39 6,170.22 S 6,632.42 E -6170.22 0.47 11373.25 72.30 131.09 5,017.00 6,229.36 S 6,699.98 E -6229.36 0.23 11468.45 72.39 130.49 5,045.87 6,288.62 S 6,768.66 E -6288.62 0.61 11563.94 72.26 130.24 5,074.86 6,347.55 S 6,837.98 E -6347.55 0.28 11657.61 72.30 130.57 5,103.37 6,405.38 S 6,905.92 E -6405.38 0.34 11753.29 72.29 130.96 5,132.47 6,464.90 S 6,974.96 E -6464.90 0.39 11847.05 72.29 131.34 5,160.99 6,523.67 S 7,042.21 E -6523.67 0.39 11940.80 72.89 131.89 5,189.04 6,583.08 S 7,109.09 E -6583.08 0.85 12035.57 72.89 131.41 5,216.92 6,643.27 S 7,176.77 E -6643.27 0.48 12130.90 72.93 131.68 5,244.94 6,703.71 S 7,244.97 E -6703.71 0.27 12203.94 72.32 132.14 5,266.75 6,750.27 S 7,296.84 E -6750.27 1.03 12295.68 72.60 130.97 5,294.40 6,808.29 S 7,362.30 E -6808.29 1.25 12324.19 72.78 130.57 5,302.88 6,826.06 S 7,382.92 E -6826.06 1.48 12418.67 72.68 130.44 5,330.93 6,884.66 S 7,451.52 E -6884.66 0.17 12513.55 73.47 131.22 5,358.55 6,944.01 S 7,520.20 E -6944.01 1.15 12610.78 76.05 132.59 5,384.11 7,006.67 S 7,590.00 E -7006.67 2.98 12706.22 78.47 135.03 5,405.16 7,071.11 S 7,657.16 E -7071.11 3.56 12800.42 81.09 139.20 5,421.88 7,139.02 S 7,720.22 E -7139.02 5.17 12894.67 83.09 144.25 5,434.86 7,212.29 S 7,778.02 E -7212.29 5.72 12989.50 84.17 148.60 5,445.38 7,290.79 S 7,830.12 E -7290.79 4.70 13083.22 84.03 150.97 5,455.02 7,371.34 S 7,877.03 E -7371.34 2.52 13177.46 82.98 153.31 5,465.68 7,454.11 S 7,920.79 E -7454.11 2.71 13273.88 83.22 156.72 5,477.27 7,540.87 S 7,961.21 E -7540.87 3.52 13368.87 84.81 158.98 5,487.17 7,628.36 S 7,996.82 E -7628.36 2.90 13463.93 87.43 158.43 5,493.60 7,716.72 S 8,031.26 E -7716.72 2.82 13559.69 89.57 159.99 5,496.11 7,806.20 S 8,065.24 E -7806.20 2.77 13654.17 89.52 163.45 5,496.86 7,895.90 S 8,094.87 E -7895.90 3.66 13749.88 89.59 163.04 5,497.60 7,987.54 S 8,122.46 E -7987.54 0.43 13845.33 89.15 162.72 5,498.65 8,078.76 S 8,150.55 E -8078.76 0.57 13938.71 88.97 161.84 5,500.19 8,167.69 S 8,178.97 E -8167.69 0.96 14033.86 88.12 159.30 5,502.60 8,257.39 S 8,210.61 E -8257.39 2.81 14129.80 87.52 155.89 5,506.25 8,346.01 S 8,247.15 E -8346.01 3.61 14224.16 88.04 155.31 5,509.91 8,431.87 S 8,286.10 E -8431.87 0.83 14317.33 89.19 156.10 5,512.16 8,516.77 S 8,324.42 E -8516.77 1.50 14413.39 89.36 161.66 5,513.38 8,606.33 S 8,359.01 E -8606.33 5.79 14508.53 88.72 159.57 5,514.97 8,696.06 S 8,390.59 E -8696.06 2.30 14603.91 88.95 157.58 5,516.91 8,784.83 S 8,425.42 E -8784.83 2.10 14697.13 87.90 157.30 5,519.47 8,870.88 S 8,461.17 E -8870.88 1.17 14792.22 87.84 158.25 5,523.01 8,958.84 S 8,497.11 E -8958.84 1.00 14888.21 87.20 158.26 5,527.16 9,047.92 S 8,532.64 E -9047.92 0.67 14983.86 88.56 159.41 5,530.70 9,137.05 S 8,567.15 E -9137.05 1.86 15076.13 89.35 162.11 5,532.38 9,224.14 S 8,597.55 E -9224.14 3.05 15170.52 90.01 160.97 5,532.91 9,313.67 S 8,627.43 E -9313.67 1.40 15266.64 89.55 161.09 5,533.28 9,404.57 S 8,658.68 E -9404.57 0.49 INSITE V8.1.10 Page 4Job No:AK-XX-0902171410 Well Name:2L-328 (Sierra)Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 15360.38 89.75 157.65 5,533.85 9,492.29 S 8,691.70 E -9492.29 3.68 15455.27 90.78 151.60 5,533.41 9,577.98 S 8,732.34 E -9577.98 6.47 15551.98 90.38 153.33 5,532.43 9,663.73 S 8,777.05 E -9663.73 1.84 15646.36 89.92 153.14 5,532.18 9,748.00 S 8,819.55 E -9748.00 0.53 15740.03 89.93 154.61 5,532.31 9,832.09 S 8,860.79 E -9832.09 1.57 15834.24 90.11 153.29 5,532.27 9,916.73 S 8,902.17 E -9916.73 1.41 15931.13 90.35 154.96 5,531.89 10,003.90 S 8,944.45 E -10003.90 1.74 16025.44 90.65 154.64 5,531.06 10,089.23 S 8,984.60 E -10089.23 0.47 16104.26 90.30 154.97 5,530.41 10,160.55 S 9,018.15 E -10160.55 0.61 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 18.73 deg from Magnetic north to True north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 16,104.26 feet is 13,585.43 feet along 138.41 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 V8.1.10 Page 5Job No:AK-XX-0902171410 Well Name:2L-328 (Sierra)Survey Report
