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Home My WebLink About213-054By Samantha Carlisle at 8:50 am, Oct 08, 2020 MGR12OCT20 DSR-10/12/2020 SFD 10/8/2020RBDMS HEW 11/2/2020 Surf. Casing 13-3/8" 68 # 4,020' MD / 3,727' TVD Cement up to surface Interm. Casing 9-5/8" 40 # 13 Cr 7,632' MD / 6,528' TVD Production Liner, 7" 26# 13 Cr 8 ½” OH 10,675' MD, 9,521' TVD 4-½” X-Coupling clamps for ESP Power Cable, Single 3/8" SS Chemical Injection Line Confidential Water Producer OP22-WW03 7,397' MD, 6,312' TVD –TOL, and Top of cement- Flex Lock Liner Hanger and ZXP Packer Assy 4-½” 12.6 ppf TSH563 Dopeless 13Cr L80 Production Tubing Wellhead, 13-3/8" x 4-½”, CR Flow-wetted 5,000 psi Conductor, 20" Uninsulated set at 160 ft 2,142' MD / 2,143’ TVD,10ºInc–SLB TR-MAXX-5E TR-SCSSSV, (13Cr-80), 3.813" X Nipple Profile,¼” SS hyd. Control line As Completed 31-Mar-2020 2,040 MD / 2,032’ TVD 7º Inc –4-½” GLM (S13Cr-110) 1", KBG with DCK-2 Ann-to-Tubing 2,100 psi Perf Range 9925'-9953' MD, 8773'-8801' TVD 9980'-10047' MD, 8828'-8894' TVD 10064'-10103' MD, 8911'-8950' TVD 10127'-10188' MD, 8974'-9035' TVD 10223'-10308' MD, 9070'-9155' TVD Approx 5º Inc 7,258' MD / 6,200' TVD - 3.813" X Nipple Profile Pump Monitoring: P intake T intake P discharge T motor V motor 7,397 MD / 6,316’ TVD,28°Inc–Bottom of Centralizer BHGE-ALS ESP, 31-stages 562 PLXSXD P155 Pump, MVC FER Seals, 270 HP KMX-VC Motor –NO CHECK VALVE 13-3/8"x4-½” Tubing Hanger “DD” Trim with 4" nom.Type “H” BPV profile 337' of N2 Gas Cap 7-5/8" 29# 13Cr Shroud Assembly with Penetrator, (1) Chem Inj Line Feed-Thru, 7-½” 13Cr Tieback Seal Stem into Liner PBR 7,334' MD / 6,261' TVD –Pump Discharge Head 40' MD/TVD, Swivel Joint Top of Cement 6,456' MD, 5,567' TVD 2040' MD LVT (freeze protection) 9.8 ppg 3% KCl/NaCl Brine w/ corrosion inhibitor :HOO1DPH23::',5 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Pierfelici Well Operations Project Manager Eni US Operating Co. Inc. 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission Re: Nikaitchuq Field, Ivishak Undefined WTRSP Pool, OP22-WW03 Permit to Drill Number: 213-054 Sundry Number: 320-050 Dear Mr. Pierfelici: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.cogcc.oloslka.gov Enclosed is the approved application for the 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, Wr ce 070 DATED this✓O day of January, 2020. BBDMSIAN 3 01010 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 280 r �.-ter r, s.I JAN 2 B 020 A0yeCt' 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 21 • Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change g a out 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Eni US Operating Co. Inc. Exploratory ❑ Development ❑ Stratigraphic ❑ Service Q - 213-054 3. Address: 6. API Number: 3800 Centerpoint Drive, Ste. 300, Anchorage, AK 99503 50-029-23489-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No ❑� OP22-WW03 9. Property Designation (Lease Number): 10. Field/Pool(s):j ,. 0373301, 0355024, 0390616 Nikaitchuq � U6S/Qk k g 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10,676 9,521 10,675 9,521 3,323 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 154 20" 154 154 Surface 4020 13 3/8" 4020 3728 5,210 2,480 Intermediate 7632 9 5/8" 7632 16475 6,890 4,790 Production Liner 3278 7" 10675 19521 7240 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9,925-10,308 8,773-9,155 4 1/2" 13 Cr L-80 7,397 Packers and SSSV Type: TR-MAXX 5 E SSSV 3.81"" X profile 1/4" SS Packers and SSSV MD (ft) and TVD (ft): hyd control line SSSV 2,263' MD/ 2,251' TVD 12. Attachments: Proposal Summary j Wellbore schematic [�j 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service Q 14. Estimated Date for ` 1 -Mar -20 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS❑ j WAG ❑ GSTOR ❑ SPLUG E]Commission 16. Verbal Approval: Date: Representative: Water Source c GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stefano Pierfelici Contact Name: Arriad Chaudhry Authorized Title: Well Operations Projec anager Contact Email: amiad.Chaudh eni.Com Contact Phone: 907-865-3379 Authorized Signature: Date: 28 -Jan -20 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Sao-oso Plug Integrity ❑ BOPTest21 Integrity Test ❑ Location Clearance ❑ vMechanical Other: X:�5 P i.. t �- [ �L'3 S-0-0 �1 �7 X, ri'st'll -mss + .tea zoo P s j RgDMS I9�AN 3 0 2020 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: /p •• y© t, 16ZAPPROVED BY V Approved by: COMMISSIONER THE COMMISSION Date: 361 '•' V Suhmil Form and Form 10-403 evi / proved applicatio r the date of ap 1XVa . Attachments in Duplicate .fig /11r_o20 En�ii Petroleum 3800 Centerpoint Drive Suite 300 Anchorage, Alaska 99503 Stefano Pierfelici Phone (907) 865-3320 Email: Stefano.pierfelici@eni.com January 281, 2020 Alaska Oil and Gas Conservation Commission 333 West 7" Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval for OP22-WW03 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well OP22-W W03 OP22-WW03 was originally completed on August 151, 2013 with a ESP pump set at depth of 7,397' MD/6315' TVD. Workover was done on this well in November 2016. The ESP has worked until June 111 2017 when an electrical failure was occurred. Another workover was conducted in May 2018, ESP ran until August 2019 when an electrical failure occurred. The well has been scheduled for an intervention with Nordic 4 to change out ESP The estimated date for beginning this work is March 11, 2020 Please find attached for the review of the Commission forms 10-403 and supporting documentation. If you have any questions or require further information, please contact Amjad Chaudhry at 907-865-3379. Sincerely, / l Stefano Pierfelici Well Operations Project Manager OP22-WW03 Workover — Summary Page OP22-WW03 Rig Workover PTD#:213-054 Current Status Well OP22-WW03 is currently down due to an ESP pump failure. Scope of Work Scope of this workover is to pull the current conventional ESP completion and run in with a new conventional ESP system. General Well info Reservoir Pressure/TVD: Reservoir depth is 9925'MD/8773'TVD. This well is expected to have a static max bottom hole pressure of approximately 4300 psi during the time of workover. Wellhead type/pressure rating: Vetco Gray, MB -247/5000 psi BOP configuration: Annular/2-7/8" x 5" VBR/blind/4-1/2" pipe TIFL/MIT-IA/MIT-OA: Intermediate csg 9 5/8" was tested 3000 psi x 30' on August 1" 2013 prior to drill out, and 1500 psi x 15' on Mayl5th 2018 after running completion. Well type: Water Producer Estimated start date: March 1St, 2020 Drilling rig: Nordic 4 Completion Engineer: Carlos Monteiro: carlos.monteirona_,eni.com Work 907-865-3345 Sr. Drilling Engineer: Amjad Chaudhry: Amiad.chaudbry@eni.com Work 907-865-3379 Well Operations Manager: Stefano Pierfelici: Stefano.pierfelicigeni.com Work: 907-865-3320 Procedure: 1. MIRU Nordic 4. 2. R/U on x -tree to pump down tubing. 3. Shear GLM valve and circulate out diesel. 4. Perform well killing by pumping down tubing with 9.7 ppg brine. 5. Ensure well is killed. 6. Set BPV. Nipple down X-mas tree and nipple up BOP and test to 3500 psi. 7. Pull tubing hanger and circulate annulus volume with 9.7 ppg brine. 8. Continue to pull tubing to TRSSV and lay down same. 9. Continue pull tubing and lay down ESP pump assembly. 10. Make up new ESP pump assembly and run in the well to depth. 11. Land hanger, and test it. 12. Pressure test annulus A with 1500 psi x 30'. L l r } re!e o ,J C� � C"- 13. Install BPV and nipple down BOP. < 1 14. Nipple up tubing adapter and tree. 15. Pull BPV, install test plug and test tree (5000 psi test). 16. Circulate Freeze protect through tree down annulus A. 17. Shut in well. 18. RDMO. Below the current schematic of the well: 7,397' MD, 6812' TVD — TOL, and Top of cement- Flex Lock Liner Hanger and ZXP Packer Assy PumO Monitorina: P intake T intake P discharge T motor V motor Interm. Casing 9-5/8"40#13 Cr 7,632' MD 16,527' TVD Confidential Perf Range 9925'-9953' MD, 8773'-8801' TVD 9980'-10047' MD, 8828'-8894' TVD 10064'-10103' MD, 8911'-8950' TVD 10127'-10188' MD, 8974'-9035' TVD 10223'40308' MD, 9070'-9155' TVD Approx 56 Inc Production Liner, 7"26#13 Cr 8'4"OH 10,675' MD. 9,521' TVD OP22-VWH03 l s 4-V." 13Cr 12.6 ppf Vain Top Production Tubing e n i kf oWu m Wellhead. 13-3/8" x 4-%, Pe CR Flow -wetted 5,000 psi Ii' Conductor, 20" Uninsulated set at 160 it Water Producer As Completed 05/17/2018 Tubing Hanger with 4" nom. Type `M" BPV profile 4-%" 12.6ppf 13Cr-1-80 Vam-Tap Production Tubing - 36' MD/36' TVD, Swivel Joint 300' of N2 Cap; 2159' Diesel; 9.5 ppg NaCl paker Fluid 2,160 MD 12,248' TVD 120 Inc — 4-'/:" GLM (41088) 1", KBG with DCK-2 Ann -to -Tubing 2,000 psi i 2,263' MD / 2,251' TVD, 160 Inc — SLB TR -MARX 5E SSSV, (410-13Cr-80) w/3.81"'X' Profile, Y," SS hyd. Control line 4-h' cable clamps, for ESP Power Cable. Single 318" SS Chem Inj Line 7.250' MD / 6,159' VD - Landing Nipple 3.812" XN (wl 3.725" No -Go) 7,328' MO 16,247' TVD - Discharge Gauge Sub Surf. Casing 7,389' MD 16,316' TVO — Motor Gauge Sub 13-318" 68 # 4,020' MD /3,728' TVD 7.391' MD 16,310' TVD, 28' Inc — Bottom of Centralizer Cement up to surface BHGE-ALS ESP, 31 -stages 562 P155 PLXSXD Pump, GST3 4R Sank. 342 HP KMX-VC Motor Top of Cement 6458' MD, 5567 TVD 7-5/8" 29.7# 13Cr Shroud Assembly with y Penetrator, (1) Chem Inj Line Feed-Thrus, Tieback Seal Stem into Liner PBR 7,397' MD, 6812' TVD — TOL, and Top of cement- Flex Lock Liner Hanger and ZXP Packer Assy PumO Monitorina: P intake T intake P discharge T motor V motor Interm. Casing 9-5/8"40#13 Cr 7,632' MD 16,527' TVD Confidential Perf Range 9925'-9953' MD, 8773'-8801' TVD 9980'-10047' MD, 8828'-8894' TVD 10064'-10103' MD, 8911'-8950' TVD 10127'-10188' MD, 8974'-9035' TVD 10223'40308' MD, 9070'-9155' TVD Approx 56 Inc Production Liner, 7"26#13 Cr 8'4"OH 10,675' MD. 9,521' TVD 3g tt ----------------- I 3 1 8 1 0 1 - 1 t _ 1 1 I � 1 1 1 3g 1 1 1 1 1 1 1 i 1 I 3 ; 1 1 1 1 1 1 0 1 I 1 F F 1 1 a 1 1 1 F 1 s � 1 f g a 9 aE t 0 - t t EEa 1 1 1 1 1 1 1 1 i 1 I 3 ; 1 1 1 1 1 1 0 1 I 1 F F 1 1 a 1 1 1 F 1 s � 1 f g a 9 C885015-1 TUBING HEAD ADAPTER, MB -24 ASSY, OFFSET, 4-1/2, SR137 VGRS, VG CLAMP 6.00 HUB BTM. 4-1/16-5000 D-6 STDD TOP, W/ PENETRATOR PROFILE. W/ 1/2 LP TEST PORT Water Source * 0885043-1 ME HEAD, ASSY, MB-247,UPPER, 13-5/8-5000 MOD STD BTM, 13-5/8-5000 VG HUB TOP, C/W (2) 2-1/16-5000 LOWER SSO W/1.900 ISO VR, (1) 4-1/16-5000 UPPER SSO W/ 4 HBPV 15 DEG OFF FROM TWO HOLES CENTERLINE W/ WELD OVERLAY 0885003-1 MB, ASSY, MB -247. LOWER, Q D BTM W/ 17.0-4TPI ACME, 13-5/8-5000 MOD FUG W/ 134 VGRS TOP, TWO 2-1/16-5000 SSO W/ 1.900 SHARP VEE ISO VRT, ANNULUS OUTLETS 15 DEG. OFF FROM CENTERLINE mxs T T 13.44 I} I} m 21.30 17.13 04.06 t 10.250885057-1 BOX BTM C885045-1 TUBING HANGER PART, MB -247, FALSE BOWL ASSY, 13-3/8 X 11 ARR FOR Ill HORIZONTAL 4.06 DIA OUTLET WITH ISOLATION SEALS W/ CLAD WELD OVERLAY H165239-3 CASING HGR ASSY,MB-243,18.19 X 13-3/8,FLUTED MANDREL,13-3/8(68 LBS) BUTTRESS BOX BTM,14.0-2TPI LH SA PIN TOP,W/W-H MULTI -BOWL HEAD LOCKDOWN ADAPTER RING TI --20.00 � 3.44 7.44 4.39 .22 18 T 16.6 01020009-2 LANDING RING, ASSY, 20 X 18.19, 16.881D, 75K 4130 FOR -50 DEG F, ARRANGE FOR 20 X 0.875 CONDUCTOR, C/W CENTERING SET SCREWS 13 8" X 9-a X Normal Operations TUBING HGR, MB -247, OFFSET, ASSY, 11 X 4-f. 4.50012 6# VAM TOP X 4.909-6TPI MCA LIFT W/4 ESPY, Ill HOR2 OUTLET, A/F Ill PENT AND (3) 3/8 CONT CNTR LINES 7. 2 14.95 9.75 _L �- 16 H281504-23 PACKOFF ASSEMBLY, MB -247, 12-13/16(325,5MM) X 9-5/6, WITH DOUBLE ELASTOMER SEALS C885087-1 CASING HER MB -247, FLUTED MANDREL ASSY, 12-13/16 X 9-5/8, 9-5/8 MOD BUTT. BOX BTM. 10.375-2 TPI LEFT HAND STUB ACME EXTERNAL LIFT 508146-5 • • STATE OF ALASKA Reviewed By: ` OIL AND GAS CONSERVATION COMMISSION P.I.Supry '3/3i2- 51Z-3(lb BOPE Test Report for: NIKAITCHUQ OP22-WW03 - Comm Contractor/Rig No.: Nordic 4 - PTD#: 2130540 DATE: 5/10/2018 Inspector Bob Noble Insp Source Operator: ENI US OPERATING CO INC Operator Rep: Russ Wimmer Rig Rep: Ron Holmes Inspector Type Operation: WRKOV Sundry No: Test Pressures: = Inspection No: bopRCN180512154138 Rams: Annular: Valves: MASP: Type Test: WKLY 318-094 250/3000 ' 250/3000- 250/3000 - 3323 Related Insp No: TEST DATA MISC. INSPECTIONS: MUD SYSTEM: ACCUMULATOR SYSTEM: P/F Visual Alarm ! Time/Pressure P/F Location Gen.: P ' Trip Tank P P - System Pressure _ 3000 - P - Housekeeping: P Pit Level Indicators P - P ' 1 Pressure After Closure __2050 - P • PTD On Location P Flow Indicator P - P 200 PSI Attained 22 - P - Standing Order Posted P_ 1 Meth Gas Detector P ' P " Full Pressure Attained 73 - P • Well Sign P - H2S Gas Detector P - P Blind Switch Covers: all stations P • Drl.Rig P - MS Misc NA NA Nitgn.Bottles(avg): 4 p,3200 ' P • Hazard Sec. P_ " ACC Misc 1 - FP Misc NA FLOOR SAFTY VALVES: ,� BOP STACK: 1 CHOKE MANIFOLD: Quantity P/F Quantity Size P/F Quantity P/F Upper Kelly 1 P Stripper 0 none NA No.Valves 14 _ P- Lower Kelly 1 ' P ' Annular Preventer 1 13 5/8" " P Manual Chokes 1 - P - Ball Type 2 P #1 Rams 1 " Blind/Shear ' P . Hydraulic Chokes 1 P Inside BOP 1 ' P ' #2 Rams 1 ' 2 7/8 X 5" VB P - CH Misc 0 NA FSV Misc 0 NA i #3 Rams 1 _ 4 1/2" P #4 Rams 0 none #5 Rams _ 0 none NA INSIDE REEL VALVES: #6 Rams _ 0 none NA (Valid for Coil Rigs Only) _ Choke Ln.Valves 1 ' 3 1/8" P Quantity P/F HCR Valves 2 3 1/8" P Inside Reel Valves 0 NA Kill Line Valves 2 3 1/8" P - Check Valve 0 none NA BOP Misc 0 none NA Number of Failures: 1 Test Results Test Time 6 - Remarks: Pheobe I have one more Kill line valve than they due because they missed the one on the mud line on their report.Accumulator pump#2 failed to come on when turned on.They worked on it and it passed retest. ',1/4;iJrk___Prue gjk p1br 35 9p-?,` PE - J • 51444 , n)...1 316-at4 ql“)1441All Z4 `3()3U eS U( '&- 4#- de..5p14-e_ M P = 3` e-3 s: JgP---" %WED JUN 0 4 201$ • SOF Tji� • • 69��\�1/7:• THE STATE Alaska Oil and Gas , 4 of® ® sKA Conservation Commission Sift 333 West Seventh Avenue " '"'viifyGOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS 1- Fax: 907.276.7542 www.aogcc.alaska.gov Marc Kuck SCANNED D&C Engineering Manager Eni US Operating Co. Inc. 3800 Centerpoint Drive, Suite 300 Anchorage,AK 99503 Re: Nikaitchuq Field, Ivish Undefined Oil Pool, OP22-WW03 Permit to Drill Number: 213-054 Sundry Number: 318-094 Dear Mr. Kuck: 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, LUSC—N---- Hollis S. French Chair DATED this -'day of March,2018. RBDMSI MAR 2 12018 • "' mrE • s STATE OF ALASKA MAR 0 7, 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION ®7S' ' l20`i g.) APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well El Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: _ESP Change outjD 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Eni US Operating Co.Inc. Exploratory ❑ Development ❑ 213-054 ' 3.Address: Stratigraphic ❑ Service 6.API Number: 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 50-029-23489-00-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No El ✓ OP22-WW03 9.Property Designation(Lease Number): 10.Field/Pool(s): r f pig 0373301, 0355024, 0390616 ' Nikaitchuq) 1 V.tsil (1 4 ' krnks-p 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): . 10,676 ' 9,521 10,675 . 9,521 3,323 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 154 20" 154 154 Surface 4020 13 3/8" 4020 3728 5,210 2,480 Intermediate 7632 9 5/8" 7632 6475 6,890 4,790 Production Liner 3278 7" 10675 9521 7240 5410 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9,925-10,308 t 8,773-9,155 4 1/2" 13 Cr L-80 7,397 Packers and SSSV Type: TR-MAXX 5 E SSSV 3.81-X profile 1/4"SS Packers and SSSV MD(ft)and TVD(ft): hyd control line SSSV 2,314'MD/2,300'TVD 12.Attachments: Proposal Summary Q Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑.r BOP Sketch ❑ Exploratory ❑ p ry ❑ Stratigraphic❑ Development❑ Service v 14.Estimated Date for 22-Apr-18 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR Commission Representative: / ❑ SPLUG El Sourced GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Marc Kuck Contact Name: Amjad Chaudhry Authorized Title: D&C Engineering Manager Contact Email: amiad.chaudhry(czlenipetroleum.com_ Contact Phone: 907-865-3379 Authorized Signature: _A----....._` Date: 7-Mar-18 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31E--OIL-I Plug Integrity ❑ BOP Test Er Mechanical Integrity Test ❑ Location Clearance ❑ 71e67-A / ' Other: 1042-e-k 141 130-P6' TAT f' 2 2 d 44C Zss'."'Se**, -4-0 306o p,s t Post Initial Injection MIT Req'd? Yes ❑ No El Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: I -y0 9 RcgV r v&.Q APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 3 f tD ie.) c �� -�,� Algol A 3/I/ M - .- 3f..s7.0- C band �4 Form 10-403 Revised 4/2017 Approved applicatio the date of apialaDmsl. ai t irit to • • 1,04701• Enli Petirolleum cuff RECEWED 3800 Centerpoint Drive Suite 300 MAR 0 7 2013 Anchorage,Alaska 99503 Marc Kuck Phone (907) 865-3322 AOGCC Email: Marc.kuck@enipetroleum.com March 7th, , 2018 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval for OP22-WW03 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well OP22-WW03 OP22-WW03 was originally completed on August 15th, 2013 with a ESP pump set at depth of 7,397' MD/6315' TVD. Workover was done on this well in November 2016. The ESP has worked until June 11th 2017 when an electrical failure was occurred. ' The well has been scheduled for an intervention with Nordic 4 to change out ESP. The estimated date for beginning this work is April 22l , 2018. Please find attached for the review of the Commission forms 10-403 and supporting documentation. If you have any questions or require further information, please contact Amjad Chaudhry at 907-865-3379. Sincerely, Marc Kuck Well Operations Manager • • OP22-WW03 Workover— Summary Page OP22-WW03 Rig Workover PTD#:213-054 Current Status Well OP22-WW03 is currently in production in natural flow. Scope of Work Scope of this workover is to pull the current completion and run in with a new ESP • system. / General Well info Reservoir Pressure/TVD: Reservoir depth is 9925'MD/8773'TVD. This well is expected to have a static max bottom hole pressure of approximately 4200 psi during the time of workover. Wellhead type/pressure rating: Vetco Gray, MB-247/5000 psi BOP configuration: Annular/pipe/blind/Flowcross/pipe TIFL/MIT-IA/MIT-OA: Intermediate csg 9 5/8" was tested 3000 psi x 30' on August 1st 2013 prior to drill out, and 1500 psi x 15' on August 13th 2013 after running completion. Well type: Water Producer Estimated start date: April 22nd, 2018 Drilling rig: Nordic 4 Drilling/Completion Engineer: Amjad Chaudhry: Amjad.chaudhry@a,enipetroleum.com Work 907-865-3379 Drilling&Completion Marc Kuck: marc.kuck@enipetroleum.com Engineering Manager: Work: 907-865-3322 Well Operations Manager: Stefano Pierfelici: Stefano.pierfelici�a enipetroleum.com Work: 907-865-3320 • • Procedure: 1. MIRU Nordic 4. 2. R/U on x-tree to pump down tubing. 3. Displace by bullheading tubing and liner volume with 9.5#brine. 4. Shear GLM valve and circulate out diesel. 5. Ensure well is ��G? 6. Set BP tree and NU BOP and test to 3500 psi. 7. Pull tubing hanger and circulate annulus volume with 9.5 # brine. 8. Continue POOH to SSSV and L/D same. 9. Continue POOH and lay down ESP assembly. 10. MU new ESP assembly and RIH to setting depth. 11. Land hanger, and test it. 12. Pressure Test IA 1500 psi x 30'. 13. Install BPV and nipple down BOP. 14. NU tubing adapter and tree. 15. Pull BPV, install test plug and test tree.( 5000 psi test) 16. Circulate Freeze protect through tree down IA. 17. Shut in well. 18. RDMO. Below the current schematic of the well: 0 • OP22—WW03fief* 4-1/2" 13Cr 12.6 ppf Vam Top Production Tubing 2nd pefr®lleum Wellhead, 13-3/8" x 4-V2'. CR Flow-wetted 5,000 psi Conductor, 20" Uninsulated set at 160 ft Water Producer 200' of N2 Cap As Completed 11/09/2016 2222' MD, 2,205' TVD 12° Inc- GLM, 4-1/2" x 1", KBG with DCK-2 Ann-to-Tubing 2,000 psi II 2320' MD, 2300' TVD, 16° Inc-TR-MAXX 5E SSSV, 3.81"'X' Profile, 1/4" SS hyd. Control line 4-1/2" cable clamps. for ESP Power ;;:, Cable. 3/8"Chem Inj Line --= * ESP Power Cable 1SOLBC 5KV 90 LD B Galv. Dual encapsulated 3/8" SS Chem Inj Lines ,,,:,, ,,,,, 7254' MD, 3 725" Landing Nipple Surf. Casing 13-3/8" 68# EccxD P Assy. PumpGST3 4B 4020' MD3728' TVD ` `/ i 7-5/8" 29.7# 13Cr Shroud Assembly . 1, ,*'#, withPenetrator, (2) Chem Inj Line Feed-Thrus, 7.397' MD—TOL- Flex '., Tieback Seal Stem Lock Liner Hanger and ZXP Packer Assy > , Perf Range 9925'-9953' MD, 8773'-8801'TVD Interm. Casing 9980'-10047' MD, 8828'-8894'TVD 9-5/8"40# 13 Cr 10064'-10103' MD, 8911'-8950'TVD 7,632'MD, 6,475'TVD 10127'-10188'MD, 8974'-9035'TVD 0223'-10308' MD, 9070'-9155'TVD • Approx 5°Inc Pump Monitoring- P intake T intake Production Liner, P discharge 7" 26#13 Cr 8 1/2" OH T motor 10,675' MD, 9,521'TVD V motor Confidential • • I II gQg 8 S1 2 re1 I p. I III ,t "4 e PQ g d xa 1 3 . k ...p ...... Iii _ _ w ` F W -...... ,........ A a Fai No G !'FF� - .s u F _ f " v rc ; ,e. i ft r 4 u� Y I > V e 0 ♦♦ F F1 MN IM a F F 591A10.11 '',#2 '.fib F -�. e — 3 fMt" f ' f • •• M - i.IA y V c F m F P N - E , O. a lila .1j i FN NE Fe - 1II „ u w L—. F Fgz p o = V F V o`s 1 =4_ I r 0 ae: q rc% Z o CO0 Ah MIIF • o ._ ± - , � '71- m1-n E • 0 M 0 z oC CC m ZD 4 ► . m -in 1{.,1 J ) / 1 d' N I N ► m M 0-140CA ► OC' a--+ U N CO CC, O zn m 0 CL 4 ► r-1 '^ Oo Ce c Q 1-LJ p a z LL s• Li V v u 0 "0 I— 2 O N U bu0 OC - 1. lip '_ _ III 4• III ;, W a, to r r7 _ 2 I w IIIIIIe 1.l 1 J ■ n Ta irt, 5 W A l V) 0 ca J W > O }a 0 0 I0 L1-1 d r-1 z ° ,i J J J • • VetcoGray Me-247 SURFACE COMPLETION SYSTEM IMO 37.19 _II d O 111,0 to:, ? q�� _, z + 5- — • 1.0.5. a 28'5-3/4- • • I .062 orvsEr CAcol, EL 25'7--I/4• „SLTP OF WELLHEAD 5.00 EL 25'2-1/4' I r AEEC MCI ja,w° �, _ FEEo*H9U :111 I u sass nX J j w$137 01.9219 �l� =.� _ I 0 �_1J 0 n, .-t ,. 01� iiill 0 - Ili - L ' I!;IIi1!IH1i7 -. --- aP— 109.043 :ee0'- m!'I I 2-, ,e' 11 5000 PSI jr /�\1� 2-1/167 151 r'`V\,I, ill I' I. M.Tt ser a at J RAMON j 13'6006 0. 52.96' "-i'�1in i w 3t 2100. go �5, i�N OW 07 70.2 ` 1 1099' rosnXX+ III I _% I. 1 T TOP OF ORApNG 1�r I ---- EL 111T-1/4. N,er6.91rr wi.. ,pl 20'00 133/K-55 mwaroe ENI ALASKA 00 88/L-80 9-5/8'OD 53.5/L-80 I AieoHORIZONTAL MULTI-80WL SYSTEM 4-1/2'00 WITH 8-5/8 VII II d 20 X 13-3/8 X 9-5/8 X p --- X 4-1/2 WITH 8-5/8 N7 '-- AND ESP FLIT CABLE `1!ar9r?'r�ajj�I �f�AI ifir "17]31-1 r tort®9a� ��e rwr uu■ lwtlrt ..:ti;t, NC t0 OF 10 - 23 JANUARY 2009 GE Imagoot,o0 0:work • • • Enli Petirolleum 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Marc Kuck Phone(907) 865-3322 Email: Marc.kuck@enipetroleum.com March 7th, , 2018 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval for OP22-WW03 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well OP22-WW03 OP22-WW03 was originally completed on August 15th, 2013 with a ESP pump set at depth of 7,397' MD/6315' TVD. Workover was done on this well in November 2016. The ESP has worked until June 11th 2017 when an electrical failure was occurred. The well has been scheduled for an intervention with Nordic 4 to change out ESP. The estimated date for beginning this work is April 22nd ,2018. Please find attached for the review of the Commission forms 10-403 and supporting documentation. If you have any questions or require further information, please contact Amjad Chaudhry at 907-865-3379. Sincerely, Marc Kuck Well Operations Manager STATE OF ALASKA ALAIDA OIL AND GAS CONSERVATION COMI.ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Li Plug Perforations Li Fracture Stimulate Li Pull Tubing U Operations shutdown Li Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: ESP Change Out Q 2.Operator ENI US Operating Co.Inc. 4.Well Class Before Work: 5.Permit to Drill Number: Name: Development ❑ Exploratory ❑ 213-0540 3.Address: 3800 Centerpoint Drive,Ste.300,Anchorage, Stratigraphic❑ Service ❑J 6.API Number: RECEIVED AK,99503 50-029-23489-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: NOV 2 9 2015 0373301,0355024,0390616 OP22-WW03 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): ,OCC Nikaitchuq Ivishak Undefinited WTRSP 11.Present Well Condition Summary: Total Depth measured 10,676' feet Plugs measured feet true vertical 9,521, feet Junk measured feet Effective Depth measured feet Packer measured feet true vertical feet true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor 154 20" 154 154 ^ _ Surface 4,020 13.375" 4,020 3,7285,210 2,480 Intermediate 7,632 9.625" 7,632 6,475 6,890 4,790 Production Liner 3,278 7" 10,675 9,521 7,240 5,410 Perforation depth Measured depth 99,25'-10,308' feet3 rd I z SC�ANNE�r MAR 1 ��r17: True Vertical depth 8,773'-9,155' feet Tubing(size,grade,measured and true vertical depth) 4.5" 12.6 ppf L80 13Cr 7,397'MD 6,807'TVD Packers and SSSV(type,measured and true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 3508 11 75 Subsequent to operation: 7222 804 182 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Cl Exploratory Development❑ Service ❑✓ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after we Water Source Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ Li WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-310 Contact Amjad Chaudpry Email amjad.chaudhry@enipetroleum.com Printed Name Bruno Ray.l.!i Title Drilling Sprintendent Signature aM.e Phone 907-865-3379 Date Ll- a, G. RBDMS G/ DEC - 6 [016 Form 10-404 Revised 5/2015 / tel---lj �/� Submit Original Only • OP22-WW03 • 4-1/2" 13Cr 12.6 ppf Vam Top Production Tubing 2nhI peir00 llEuim Wellhead, 13-3/8" x 4-'/2", CR Flow-wetted 5,000 psi Ir' Conductor, 20" Uninsulated set at 160 ft Water Producer 4,impi 200' of N2 Cap As Completed 11/09/ 2016 2222' MD, 2,205' TVD 12° Inc - GLM, 4-'/2" x 1", KBG with DCK-2 Ann-to-Tubing 2,000 psi i 2320' MD, 2300' TVD, 16° Inc - TR-MAXX 5E SSSV, 3.81" `X' Profile, 1/4" SS hyd. Control line 4-1/2" cable clamps, for ESP Power Cable, 3/8" Chem Inj Line ESP Power Cable 1 SOLBC 5KV 90 LD B Galv. Dual encapsulated 3/8" SS Chem lnj Lines 41.! 7254' MD, 3.725" Landing Nipple ►4 t Surf. Casing 13-3/8" 68 # 4020' MD, 3728' TVD °\04. ESP Assy, 31-562P155PLXSXD Pump, GST3 4B • , � eals, 270 HP KMX Motor v. I 7313' MD, 6241' TVD, 31° Inc 7-5/8" 29.7# 13Cr Shroud Assembly , withPenetrator, (2) Chem lnj Line Feed-Thrus, 7,397 MD TOL - Flex 47, Tieback Tieback Seal Stem Lock Liner Hanger and 4% ZXP Packer Assy Perf Range 9925'-9953' MD, 8773'-8801' TVD Interm. Casing 9980'-10047' MD, 8828'-8894' TVD 9-5/8" 40 # 13 Cr 10064'-10103' MD, 8911'-8950' TVD 7,632' MD, 6,475' TVD !A 10127'-10188' MD, 8974'-9035' TVD 0223'-10308' MD, 9070'-9155' TVD ` Approx 5° Inc Pump Monitoring: P intake T intake Production Liner, P discharge 7" 26# 13 Cr 8 1/2" OH T motor 10,675' MD, 9,521' TVD ✓ motor Confidential Well Name: OP22-WW03• laily Report Wellbore Name: OP22-WW03 Date: 10/14/2016 Well Code: 27295• Report#: 1 2 rn1 ti Job: WORKOVER Page:1 of 2 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Ground Level(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 0.00 16.38 36.62 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date NABORS 245 NABORS ALASKA LAND RIG 0637 10/14/2016 Daily Information • Weather Temperature(°F( Wind Days LTI(days) Days RI(days) POB Overcast 28.0 E @ 17 MPH 26.0 Cost Summary Job Account Currency Code Total AFE Amount(Cost) Daily Cost(Cost) Cumulative Cost(Cost) Daily Mud Field Est(Cost) Cumulative mud Cost(Cost) 7683 USD 5,049,784 52,575 52,575 Safety Incidents-Near Miss Date Category Type Subtype Severity Cause Lost time? 10/14/2016 No Comment NO INCIDENTS REPORTED Safety Drills Days Until Next Check Type #Occur Last Date Next Date (days) Rig Inspection 1 10/14/2016 10/15/2016 1 Safety Meeting 1 10/14/2016 1005/2016 1 Casings seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(RKB) TVD Bot.(ftKB) Run Date CASING 13 3/8 12.42 L-80 -0.8 4,020.0 3,727.6 7/12/2013 CASING 9 5/8 8.84 L-80 0.1 7,631.0 6,526.8 7/29/2013 LINER 7 6.18 L-80 7,396.8 10,668.0 9,513.5 8/5/2013 Last Cementing Cementing Start Date: 8/6/2013 String:LINER,10,668.0ftKB Comment: Stg# Top(RKB) Top Meas Meth Btm(ftKB) Com 1 7,396.0 Volume Calculations 10,658.0 Job Information Job Phase Planned Start Date Start Date End Date P50 Duration(days) P50 Cost(Cost) WORKOVER 10/14/2016 00:00 10/14/2016 12:00 0.00 0 Daily Summary Operations 24h Forecast Continue with rig warm up. 24h Summary Rig crew arrived,went thru camp orientation,Eni safety policies,NAD safety standards and policies,productions safety policies and procedures,rig crew,production leads,Eni HSE,company rep in attendance, Pre tour Safety meeting,Prep cold start engine on pit module for start up,raise/install Tioga air heaters stacks on pits and sub base,remove plywood covers from generators,remove air intake plastic. Reconnect/install air intake shock rubbers,set up drilling office and pre tour area for operations,begin housekeeping procedures. Operation at 07.00 Warming up rig Time Log Start End Cum Dur End Depth Time Time Dur(hr) (hr) Phase Opr. ., Act. Plan Oper.Descr. (ftKB) 12:00 17:00 5.00 5.00 MOB A 1 P Rig crew arrived,went thru camp orientation,Eni safety policies,NAD safety standards and policies, productions safety policies and procedures,rig crew,production leads,Eni HSE,company rep in attendance. 17:00 17:30 0.50 5.50 MOB A 1 P Pre tour Safety meeting 17:30 21:00 3.50 9.00 MOB A 1 P Prep cold start engine on pit module for start up,raise I install Tioga air heaters stacks on pits and sub base, remove plywood covers from generators,remove air intake plastic. 21:00 00:00 3.00 12.00 MOB A 1 P Reconnect/install air intake shock rubbers,set up drilling office and pre tour area for operations,begin housekeeping procedures. Gas Readings Avg Background Gas(14) Max Background Gas(%) Avg Connection Gas VA) Max Connection Gas(%) Avg Drill Gas(%) Max Drill Gas(%) Avg Trip Gas(%( Max Trip Gas(%) Cumulative Mud Volumes Active Volume(bbl) Hole Volume(bbl) Losses(bbl) Cum Additions(bbl) Additions(bbl) Cum Losses(bbl) Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Mitch Billington ENI 'Drilling Supv. 907-685-0722 Eni representative Paul Holley ENI HSE Tool Push Tony Morales Nabors Alaska Drilling Tool Pusher Tool Push Wesley Jeardoe Nabors Alaska Drilling Tool Pusher Personnel Log(POB) Company Serv.Type Work H(hr) Stand-by H(hr) Count Note Solsten Drilling Supervisor 12.00 1 Eni HSE 12.00 1 NABORS Rig Crew 12.00 24 BOP Stack&Components Description Start Date Last Certification Date Pressure Rating(psi) Type Make Model ID Nom(in) P Range(psi) Last Cert Date Slow Circulation Rates Pump Number: Make: Model: Start Date End Date Liner Size(in) Volume Per Stroke Override(bbllstk) Max Pressure(psi) Date Depth(RKB) Slow Spd Strokes(spm) P(psi) Eff(%) Q Flow(gpm) Well Name: OP22-WW03• laily Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 10/14/2016 Job: WORKOVER Page:2 1 o Page: of 2 Daily Bulk Supply Item Description: EQUIPMENT FUEL Unit Label:Gallons Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note Supply Item Description: NAD 245E Diesel Fuel Unit Label:gal us Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note Supply Item Description: WAD 245E Rig Water Unit Label:bbl Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note Last Authority Visit Date Tot insp.Nbr Total I.N.C.number Comment STOP Cards Submitted Company #Rpts Com NABORS ALASKA DRILLING PJSM NABORS ALASKA DRILLING STOP Cards General Notes Comment: Well Name: OP22-WW03I laily Report Wellbore Name: OP22-WW03 Date: 10115/2016 • Well Code: 27295 Report#: 2 cin it Job: WORKOVER Page:1 of 2 Well Header Permit/Concession N" Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Ground Level(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 0.00 16.38 36.62 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date NABORS 245 NABORS ALASKA LAND RIG 0637 10/14/2016 Daily Information Weather Temperature(°F) Wind Days LTI(days) Days RI(days) POB Overcast,light snow 29.0 ENE @ 13 MPH 27.0 • Cost Summary Job Account Currency Code Total AFE Amount(Cost) Daily Cost(Cost) Cumulative Cost(Cost) Daily Mud Field Est(Cost) Cumulative mud Cost(Cost) 7683 USD 5,049,784 42,662 95,237 Safety Incidents-Near Miss Date Category Type Subtype Severity Cause Lost time? 10/15/2016 No Comment NO INCIDENTS REPORTED Safety Drills Days Until Next Check Type #Occur Last Date _ Next Date (days) Rig Inspection 2 10/15/2016 10/16/2016 1 Safety Meeting 2 10/15/2016 10/16/2016 i Spill Drill 1 10/15/2016 10/29/2016 14 Casings seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(RKB) TVD Bot.(RKB) Run Date CASING 133/8 12.42 - L-80 -0.8 4,020.0 3,727.6 7/12/2013 CASING 9 5/8 8.84 L-80 0.1 7,631.0 6,526.8 7/29/2013 LINER 7 6.18 L-80 7,396.8 10,668.0 9,513.5 8/5/2013 Last Cementing Cementing Start Date: 8/6/2013 String:LINER,10,668.0ftKB Comment: Stg# Top(ftKB) Top Meas Meth Btm(ftKB) Com 1 7,396.0 Volume Calculations 10,658.0 Job Information Job Phase Planned Start Date Start Date End Date P50 Duration(days) P50 Cost(Cost) WORKOVER 10/14/2016 00:00 10/14/201612:00 0.00 0 Daily Summary Operations 24h Forecast Continue with rig warm up. 24h Summary PJSM,Trouble shoot cold start on utility module,appears to be over heating.Unwrap equipment, tuggers,motors,ect on sub module.Fire up lister aircompressor.Begin filling generators.Hookup portable air compressor to sub module to give more air pressure to rig,Install new air filters on generator#4,attempt to start generators,electrician inspect SCR room.Pre tour safety meeting,start generator#4 trouble shoot electrical issues,start generator#3 sub power online,unload BOPE,aux fuel tank and genset and position on pad.Spot crane next to sub,PJSM for lifting aux fuel tank to roof of sub Eni HSE present for lift. Restart Generator#3,trouble shoot same=good,install pin and roller for bridge crane in cellar.Prep cord on pits for aux generator hook-up,fill lampson radiators with glycal on sub and inspect. Operation at 07.00 Warming up rig Time Log Start End Cum Dur End Depth Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. (ftKB) 00:00 06:00 6.00 6.00 MOB A1 P PJSM,Trouble shoot cold start on utility module,appears to be over heating.Unwrap equipment, tuggers, motors,ect on sub module.Fire up lister aircompressor. 06:00 12:00 6.00 12.00 MOB A 1 P Begin filling generators.Hookup portable air compressor to sub module to give more air pressure to rig,Install - new air fitters on generator#4,attempt to start generators,electrician inspect SCR room. • 12:00 18:00 6.00 18.00 MOB A 1 P Pre tour safety meeting,start generator#4 trouble shoot electrical issues,start generator#3 sub power online, unload BOPE,aux fuel tank and genset and position on pad.Spot crane next to sub,PJSM for lifting aux fuel tank to roof of sub Eni HSE present for lift. 18:00 00:00 6.00 24.00 MOB A 1 P Restart Generator#3,trouble shoot same=good,install pin and roller for bridge crane in cellar.Prep cord on pits for aux generator hook-up,fill lampson radiators with glycol on sub and inspect. Gas Readings Avg Background Gas(%) Max Background Gas(%) Avg Connection Gas(%) Max Connection Gas(%) Avg Drill Gas)%) Max Drill Gas(%) Avg Trip Gas(%) Max Trip Gas(%) Cumulative Mud Volumes Active Volume(bbl) Hole Volume(bbl) Losses(bbl) Cum Additions(bbl) Additions(bbl) Cum Losses(bbl) Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Mitch Billington ENI Drilling Supv. 907-685-0722 Eni representative Paul Holley ENI HSE Tool Push Tony Morales Nabors Alaska Drilling Tool Pusher Tool Push Wesley Jeardoe Nabors Alaska Drilling Tool Pusher Personnel Log(POB) Company Serv.Type Work H(hr) Stand-by H(hr) Count Note Eni .HSE 12.00 1 Solsten Drilling Supervisor 12.00 2 NABORS Rig Crew 12.00 24 BOP Stack&Components Description Start Date Last Certification Date Pressure Rating(psi) Type Make Model ID Nom(in) P Range(psi) Last Cert Date Slow Circulation Rates Pump Number: Make: Model: Well Name: OP22-WW03• "tally Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 10/15/2016 Job: WORKOVER Pa Page: #: 2 2 of 2 Start Date End Date Liner Size(in) Volume Per Stroke Override(bbl/stk) Max Pressure(psi) Date Depth(ftKB) Slow Spd Strokes(spm) P(psi) Eff(%) 0 Flow(gpm) Daily Bulk Supply Item Description: EQUIPMENT FUEL Unit Label:Gallons Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note Supply Item Description: NAD 245E Diesel Fuel Unit Label:gal us Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note Supply Item Description: NAD 245E Rig Water Unit Label: bbl Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note Last Authority Visit Date Tot insp.Nbr Total I.N.C.number Comment STOP Cards Submitted Company #Rpts Corn NABORS ALASKA DRILLING 16 PJSM NABORS ALASKA DRILLING 12 STOP Cards General Notes Comment: Well Name: OP22-WW0311 Dally Report Wellbore Name: OP22-WW03 • Date: 10/16/2016 • Well Code: 27295 Report#: 3 2n ll Job: WORKOVER p Page:1 of 2 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Ground Level(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 0.00 16.38 36.62 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date NABORS 245 NABORS ALASKA LAND RIG 0637 10/14/2016 Daily Information Weather Temperature(°F) Wind Days LTI(days) Days RI(days) POB Overcast 25.0 NE @ 16 MPH 29.0 Cost Summary Job Account Currency Code Total AFE Amount(Cost) Daily Cost(Cost) Cumulative Cost(Cost) Daily Mud Field Est(Cost) Cumulative mud Cost(Cost) 7683 USD 5,049,784 50,554 145,790 Safety Incidents-Near Miss Date Category Type Subtype Severity Cause Lost time? 10/16/2016 No Comment NO INCIDENTS REPORTED Safety Drills Days Until Next Check Type #Occur Last Date Next Date (days) Fire Drill 1 10/16/2016 10/30/2016 14 Rig Inspection 3 10/16/2016 10/17/2016 1 Safety Meeting 3 10/16/2016 10/17/2016 1 Spill Drill 1 10/15/2016 10/29/2016 13 Casings seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(RKB) TVD Bot.(RKB) Run Date CASING 133/8 12.42 L-80 -0.8 4,020.0 3,727.6 7/12/2013 CASING 9 5/8 8.84 L-80 0.1 7,631.0 6,526.8 7/29/2013 LINER 7 6.18 L-80 7,396.8 10,668.0 9,513.5 8/5/2013 Last Cementing Cementing Start Date: 8/6/2013 String:LINER,10,668.0ftKB Comment: Stg# Top(RKB) Top Meas Meth Btm(ftKB) Com 1 7,396.0 Volume Calculations 10,658.0 Job Information Job Phase Planned Start Date Start Date End Date P50 Duration(days) P50 Cost(Cost) WORKOVER 10/14/2016 00:00 10/14/2016 12:00 0.00 0 Daily Summary Operations 24h Forecast Continue with rig warm up. 24h Summary PJSM,Inspect and test and run rig jacking hydraulics.Jack up sub and install short cribbing blocks.remove berm on sub base and roll up curtains.Drive rig to east to position for cellar box removal.PJSM,Lower dixie cup and release,move sub base 10',N/U BOPE,R/U to annular,set lift ring,M/U annular to double gate and TQ bolts.M/U both manual valves to mud cross.PJSM,M/U mud cross and single gate to to BOP assembly.Connect utility module to standby generator,start up Tioga,clean short side of pipe shed and stage choke hard lines at beaver slide. Operation at 07.00 Warming up rig Time Log Start End Cum Dur End Depth Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. (RKB) 00:00 06:00 6.00 6.00 MOB A 1 P PJSM,Prep bolts for BOPE,Prep lampson motors on sub,suck out sumps in pipe shed,cave take,cellar box. Rig down portable air compressor.Start all 4 lampson motors on sub.Fuel day tank. 06:00 12:00 6.00 ' 12.00 MOB A 1 P PJSM,Inspect and test and run rig jacking hydraulics.Jack up sub and install short cribbing blocks.remove berm on sub base and roll up curtains.Drive rig to east to position for cellar box removal 12:00 18:00 6.00 18.00 MOB A ' 1 P PJSM,Lower dixie cup and release,move sub base 10',N/U BOPE,R/U to annular,set lift ring,M/U annular to double gate and TQ bolts.M/U both manual valves to mud cross. 18:00 00:00 6.00 ' 24.00 MOB A 1 P PJSM,M/U mud cross and single gate to to BOP assembly.Connect utility module to standby generator,start up Tioga,clean short side of pipe shed and stage choke hard lines at beaver slide. Gas Readings Avg Background Gas(%) Max Background Gas(%) Avg Connection Gas(%) Max Connection Gas(%) Avg Drill Gas)%) Max Drill Gas(%) Avg Trip Gas(%) Max Trip Gas(%) Cumulative Mud Volumes Active Volume(bbl) Hole Volume(bbl) Losses(bbl) Cum Additions(bbl) Additions(bbl) Cum Losses(bbl) Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Mitch Billington ENI Drilling Supv. 907-685-0722 Eni representative Paul Holley ENI HSE Tool Push Tony Morales Nabors Alaska Drilling Tool Pusher Tool Push Wesley Jeardoe Nabors Alaska Drilling Tool Pusher Personnel Log(POB) Company Serv.Type Work H(hr) Stand-by H(hr) Count Note Eni HSE 12.00 1 Solsten Drilling Supervisor 12.00 2 CH2M Truck Driuver 12.00 2 NABORS Rig Crew 12.00 24 BOP Stack&Components Description Start Date Last Certification Date Pressure Rating(psi) Type Make Model ID Nom(in) P Range(psi) Last Cert Date Slow Circulation Rates Pump Number: Make: Model: • Well Name: OP22-WW0333 Dally Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 10/16/2016 3 Job: WORKOVER PaPage:2 2 of 2 Start Date End Date Liner Size(in) Volume Per Stroke Override(bbl/stk) Max Pressure(psi) Date Depth(ftKB) Slow Spd Strokes(spm) P(psi) Eff(%) Q Flow(gpm) Daily Bulk Supply Item Description: EQUIPMENT FUEL Unit Label:Gallons Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note Supply Item Description: NAD 245E Diesel Fuel Unit Label:gal us Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note Supply Item Description: NAD 245E Rig Water Unit Label: bbl Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note Last Authority Visit Date Tot insp.Nbr Total I.N.C.number Comment STOP Cards Submitted Company #Rpts Com NABORS ALASKA DRILLING 29 PJSM NABORS ALASKA DRILLING 18 STOP Cards General Notes Comment: jr�•.,, Well Name: OP22-WW03I "Lily Report Wellbore Name: OP22-WW03 Date: 10/17/2016 • Well Code: 27295 Report#: 4 nnI1 Job: WORKOVER Page: 1 of 2 Well Header Permit/Concession N' Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Ground Level(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 0.00 16.38 36.62 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date NABORS 245 NABORS ALASKA LAND RIG 0637 10/14/2016 Daily Information Weather Temperature(°F) Wind Days LTI(days) Days RI(days) POB Overcast,Light Snow 27.0 N @ 7 MPH 29.0 Cost Summary Job Account Currency Code Total AFE Amount(Cost) Daily Cost(Cost) Cumulative Cost(Cost) Daily Mud Field Est(Cost) Cumulative mud Cost(Cost) 7683 USD 5,049,784 52,547 198,337 Safety Incidents-Near Miss Date Category 'Type Subtype Severity Cause Lost time? 10/17/2016 No Comment NO INCIDENTS REPORTED Safety Drills Days Until Next Check Type 8 Occur Last Date Next Date (days) Fire Drill 1 10/16/2016 10/30/2016 13 Rig Inspection 4 10/17/2016 10/18/2016 1 Safety Meeting 4 10/17/2016 10/18/2016 1 Spill Drill 1 10/15/2016 10/29/2016 12 Casings seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(RKB) TVD Bot.(RKB) Run Date CASING 13 3/8 12.42 L-80 -0.8 4,020.0 3,727.6 7/12/2013 CASING 9 5/8 8.84 LOU 0.1 7,631.0 6,526.8 7/29/2013 LINER 7 6.18 L-80 7,396.8 10,668.0 9,513.5 8/5/2013 Last Cementing Cementing Start Date: 8/6/2013 String:LINER,10,668.OftKB Comment: Stg 8 Top(RKB) Top Meas Meth Btm(ftKB) Com 1 7,396.0 Volume Calculations 10,658.0 Job Information Job Phase -- Planned Start Date Start Date End Date P50 Duration(days) P50 Cost(Cost) WORKOVER 10/14/2016 00:00 10/14/2016 12:00 0.00 0 Daily Summary Operations 24h Forecast Continue with rig warm up. 24h Summary M/U remaining BOPE components.Repair air leak on D.S.bridge crane.Lift BOPE stack into cellar and secure to stump.Torque bolts on BOPE stack.Bring piping for choke manifold to rig floor and test fit.Prep and start Lampsons on Utility Module.Check rig jacking system on Utility Module.PJSM Set portable generator on Utility Module with crane.Move Sub over cellar box.Hook up to cellar box and install curtains. PJSM,Cont install dixie curtains,secure dixie cup in cellar,cont to prep for move to OP22,remove hurculite from top drive and drawworks,electrician remove plastic from traction motors and blowers,bring top drive and drawworks on line,break out of stump for access to rotary table for plump bob. Set plywood along well bay for burming,role up curtains on utility module,P/U berming,jack up and set on cribbing blocks move Mod approx.30'line up with well bay move back to set herculite and mats. Operation at 07.00 Warming up rig Time Log Start End Cum Dur End Depth Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. (ftKB) 00:00 06:00 6.00 6.00 MOB A 20 P PJSM M/U remaining BOPE components.Repair air leak on D.S.bridge crane.Lift BOPE stack into cellar and secure to stump.Torque bolts on BOPE stack.Bring piping for choke manifold to rig floor and test fit. 06:00 12:00 6.00 12.00 MOB A 20 P PJSM Prep and start Lampsons on Utility Module.Check rig jacking system on Utility Module.PJSM Set portable generator on Utility Module with crane.Move Sub over cellar box.Hook up to cellar box and install curtains. 12:00 18:00 6.00 18.00 MOB A 1 P PJSM,Cont install dixie curtains,secure dixie cup in cellar,cent to prep for move to OP22,remove hurculite from top drive and drawworks,electrician remove plastic from traction motors and blowers,bring top drive and drawworks on line,break out of stump for access to rotary table for plump bob 18:00 00:00 6.00 24.00 MOB A 1 P Set plywood along well bay for burming,role up curtains on utility module,P/U berming,jack up and set on cribbing blocks move Mod approx.30'line up with well bay move back to set herculite and mats. Gas Readings Avg Background Gas(%( Max Background Gas(%) Avg Connection Gas(%) Max Connection Gas(%) Avg Drill Gas(%) Max Drill Gas(%) Avg Trip Gas(%) Max Trip Gas(%) Cumulative Mud Volumes Active Volume(bbl) Hole Volume(bbl) Losses(bbl) Cum Additions(bbl) Additions(bbl) Cum Losses(bbl) Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Mitch Billington ENI Drilling Supv. 907-685-0722 Eni representative Paul Holley ENI HSE Tool Push Tony Morales Nabors Alaska Drilling Tool Pusher Tool Push Wesley Jeardoe Nabors Alaska Drilling Tool Pusher Personnel Log(POB) Company Serv.Type Work H(hr) Stand-by H(hr( Count Note Eni HSE 12.00 1 Solsten Drilling Supervisor 12.00 2 CH2M Truck Driuver 12.00 2 NABORS Rig Crew 12.00 24 BOP Stack 8 Components Description Start Date Last Certification Date Pressure Rating(psi) Well Name: OP22-WW031k laily Report Wellbore Name: OP22-WW03 Date: 10/17/2016 Well Code: 27295 Report#: 4 Job: WORKOVER Page:2 of 2 Type Make Model ID Nom(in) P Range(psi) Last Cert Date Slow Circulation Rates Pump Number: Make: Model: Start Date End Date Liner Size(in) Volume Per Stroke Override(bbl/stk) Mao Pressure(psi) Date Depth(ftKB) Slow Spd Strokes(spm) P(psi) Eff(%) Q Flow(gpm) Daily Bulk Supply Item Description: EQUIPMENT FUEL Unit Label:Gallons Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Corn Returned Cum On Loc Note 10/17/2016 993.0 993.0 993.0 993.0 0.0 0.0 Supply Item Description: NAD 245E Diesel Fuel Unit Label:gal us Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note Supply Item Description: NAD 245E Rig Water Unit Label:bbl Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note Last Authority Visit Date Tot insp.Nbr Total I.N.C.number Comment STOP Cards Submitted Company #Rpts Corn NABORS ALASKA DRILLING 16 PJSM NABORS ALASKA DRILLING 8 STOP Cards General Notes Comment: I — Well Name: OP22-WW03 •aily 1111 Wellbore Name: P22-WW p ort O 03 Re Well Code: 27295 Date: 10/18/2016 • Report#: 5 en II Job: WORKOVER Page:1 of 2 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Ground Level(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 0.00 16.38 36.62 • Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date NABORS 245 NABORS ALASKA LAND RIG 0637 10/14/2016 Daily Information • Weather Temperature(°F) Wind Days LTI(days) Days RI(days) POB Overcast 18.0 SE @ 6 MPH 29.0 Cost Summary Job Account Currency Code Total AFE Amount(Cost) Daily Cost(Cost) Cumulative Cost(Cost) Daily Mud Field Est(Cost) Cumulative mud Cost(Cost) • 7683 USD 5,049,784 47,818 246,154 • Safety Incidents-Near Miss Date Category Type Subtype Severity Cause Lost time? 10/18/2016 No Comment NO INCIDENTS REPORTED Safety Drills Days Until Next Check Type 6 Occur Last Date Next Date (days) Fire Drill 2 10/18/2016 11/1/2016 14 Rig Inspection 5 10/18/2016 10/19/2016 1 Safety Meeting 5 10/18/2016 10/19/2016 1 Spill Drill 2 10/18/2016 11/1/2016 14 Casings seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(RKB) TVD Bot.(ftKB) Run Date CASING 13 3/8 - 12.42 L-80 -0.8 4,020.0 3,727.6 7/12/2013 CASING 9 5/8 8.84 L-80 0.1 7,631.0 6,526.8 7/29/2013 LINER 7 6.18 L-80 7,396.8 10,668.0 9,513.5 8/5/2013 Last Cementing Cementing Start Date: 8/6/2013 String:LINER,10,668.0ftKB Comment: Stg 6 Top(RKB) Top Meas Meth Btm(ftKB) Com 1 7,396.0 Volume Calculations 10,658.0 Job Information Job Phase Planned Start Date Start Date End Date P50 Duration(days) P50 Cost(Cost) WORKOVER 10/14/2016 00:00 10/14/201612:00 0.00 0 Daily Summary Operations 24h Forecast Continue with rig warm up. 24h Summary PJSM,Cont.setting rig mats,weld herculite extension onto rig berm,get permit review JSA and remove hatch cover over well bay,move sub over well bay OP22-W W03 set down and level sub.PJSM,build ramps onto matting boards for utility module,merry up utility module up to sub base and level,begin hooking up electrical and service lines.Put landings in place under stairs exiting rig.install half moon hatch on well bay.Lower cellar box curtains.PJSM,burming around rig secure landings and stairs,lower Lampson curtains,work on choke manifold valves,continue hooking up service lines and interconnects.take on rig c' water.PJSM,Clean out short side of pipe shed and prep for bridge crane work.Swap over to rig power,place 5 ea.30 min.air packs around rig.test run new bushing pullers,lower dixie cup to top of well bay,turn on water to utility mod,assemble choke lines to cellar. Operation at 07.00 Warming up rig Time Log Start End Cum Dur End Depth Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. (RKB) 00:00 08:00 8.00 8.00 MOB A 1 P PJSM,Cont.setting rig mats,weld herculite extension onto rig berm,get permit review JSA and remove hatch cover over well bay,move sub over well bay OP22r-WoW03 set down and level sub. 08:00 12:00 4.00 12.00 MOB A 1 P PJSM,build ramps onto matting boards for utility module,merry up utility module up to sub base and level, begin hooking up electrical and service lines.Put landings in place under stairs exiting rig.install half moon hatch on well bay.Lower cellar box curtains. 12:00 18:00 6.00 18.00 MOB A 1 P PJSM,burming around rig secure landings and stairs,lower Lampson curtains,work on choke manifold valves,continue hooking up service lines and interconnects.take on rig water. 18:00 00:00 6.00 24.00 MOB A 1 P PJSM,Clean out short side of pipe shed and prep for bridge crane work.Swap over to rig power,place 5 ea. 30 min.air packs around rig.test run new bushing pullers,lower dixie cup to top of well bay,turn on water to utility mod,assemble choke lines to cellar. Gas Readings Avg Background Gas(%) Max Background Gas(%) Avg Connection Gas(%( Max Connection Gas(%) Avg Drill Gas(%( Max Drill Gas(%) Avg Trip Gas)%) Max Trip Gas(%) Cumulative Mud Volumes Active Volume(bbl) Hole Volume(bbl) Losses(bbl) Cum Additions(bbl) Additions(bbl) Cum Losses(bbl( Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Mitch Billington ENI Drilling Supv. 907-685-0722 Eni representative Paul Holley ENI HSE Tool Push Tony Morales Nabors Alaska Drilling Tool Pusher Tool Push Wesley Jeardoe Nabors Alaska Drilling Tool Pusher Personnel Log(POB) Company Serv.Type Work H(hr) Stand-by H(hr) Count Note Eni HSE 12.00 1 Solsten Drilling Supervisor 12.00 2 CH2M Truck Driuver 12.00 2 NABORS Rig Crew 12.00 24 BOP Stack&Components Description Start Date Last Certification Date Pressure Rating(psi) Well Name: OP22-WW03• •aily Report Wellbore Name: OP22-WW03 Date: 10118/2016 Well Code: 27295 5 Job: WORKOVER RePage:port 2 of 2 2 Type Make Model ID Nom(in) P Range(psi) Last Cell Date Slow Circulation Rates Pump Number: Make: Model: Start Date End Date Liner Size(in) Volume Per Stroke Override(bbllstk) Max Pressure(psi) Date Depth(ftKB) Slow Spd Strokes(spm) P(psi) Eff(%) Q Flow(gpm) Daily Bulk Supply Item Description: EQUIPMENT FUEL Unit Label:Gallons Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc •Note 10/17/2016 993.0 993.0 993.0 993.0 0.0 0.0 Supply Item Description: NAD 245E Diesel Fuel Unit Label:gal us Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received 'Cum Returned Cum On Loc Note 10/18/2016 126.0 10,374.0 126.0 10,374.0 0.0 10,248.0 Supply Item Description: NAD 245E Rig Water Unit Label: bbl Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/18/2016 0.0 130.0 0.0 130.0 0.0 130.0 Last Authority Visit Date Tot insp.Nbr Total I.N.C.number Comment STOP Cards Submitted Company #Rpts Com NABORS ALASKA DRILLING 34 PJSM NABORS ALASKA DRILLING 17 STOP Cards General Notes Comment: 1111 Well Name: OP22-WW03 •Daily Report Wellbore Name: OP22-WW03 Date. 10/19/2016 • Well Code: 27295 Report#: 6 en 0 Job: WORKOVER Page:1 of 2 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Ground Level(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 0.00 16.38 36.62 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date NABORS 245 NABORS ALASKA LAND RIG 0637 10/14/2016 Daily Information Weather Temperature("F) Wind Days LTI(days) Days RI(days) POB Partly Cloudy 16.7 SSE @ 11 MPH 31.0 Cost Summary Job Account Currency Code Total AFE Amount(Cost) Daily Cost(Cost) Cumulative Cost(Cost) Daily Mud Field Est(Cost) Cumulative mud Cost(Cost) 7683 USD 5,049,784 62,207 308,361 Safety Incidents-Near Miss Date Category Type Subtype Severity Cause Lost time? 10/19/2016 No Comment NO INCIDENTS REPORTED Safety Drills Days Until Next Check Type 8 Occur Last Date _ Next Date - (days) Fire Drill 3 10/19/2016 11/2/2016 14 Rig Inspection 6 10/19/2016 10/20/2016 1 Safety Meeting 6 10/19/2016 10/20/2016 1 Spill Drill 3 10/19/2016 11/2/2016 14 Casings seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(RKB) TVD Bot.(RKB) Run Date • CASING 13 3/8 12.42 L-80 -0.8 4,020.0 3,727.6 7/12/2013 CASING 95/8 8.84 L-80 0.1 7,631.0 6,526.8 7/29/2013 LINER 7 6.18 L-80 7,396.8 10,668.0 9,513.5 8/5/2013 Last Cementing Cementing Start Date: 8/6/2013 String:LINER,10,668.0ftKB Comment: Stg# Top(ftKB) Top Meas Meth Btm(ftKB) Com 1 7,396.0 Volume Calculations 10,658.0 Job Information Job Phase Planned Start Date Start Date End Date P50 Duration(days) P50 Cost(Cost) WORKOVER 10/14/2016 00:00 10/14/2016 12:00 0.00 0 Daily Summary Operations 24h Forecast Continue with rig warm up. 24h Summary Clear out short side of pipe shed prepping f/bridge crane installation.Assemble mud pumps.hook up new choke manifold plumbing f/test fit.connect service/suction/equalizer lines in charge pump inner connect. Dressing mud pumps.clean up pad around the rig.Reconfigure choke hose,plumbing for better fit.Hammer up flow line at inner connect to shakers.Mechanic continue rebuilding valves on choke manifold.Bring on fuel.fill 81 boiler and stage up temp.PJSM,Cont.installing choke hose bolts and saddle clamps,work with mechanic change seals in choke valves,cont working on mud pumps,change seats and valves, install 6"liners,stage up boiler temp.housekeeping,Western Crane inspect tuggers,manriders and pad eyes.PJSM,Start prep work,set one more matt in shed for work platform,gather tools,hand tools,ladders, chain falls,beam clamps ect.remove hoist motors and set on pallet in shed,turn on steam in utility mod and sub,shut in sub side and B/D for repairs,brake bolts loose on crane carriage. Operation at 07.00 Warming up rig Time Log Start End Cum Dur End Depth Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. (RKB) 00:00 06:00 6.00 6.00 MOB A 20 P Clear out short side of pipe shed prepping f/bridge crane installation.Assemble mud pumps,hook up new choke manifold plumbing f/test fit.connect service/suction/equalizer lines in charge pump inner connect. 06:00 12:00 6.00 12.00 MOB A 20 P Dressing mud pumps.clean up pad around the rig.Reconfigure choke hose,plumbing for better fit.Hammer up flow line at inner connect to shakers.Mechanic continue rebuilding valves on choke manifold.Bring on fuel. fill#1 boiler and stage up temp. 12:00 18:00 6.00 18.00 MOB A 20 P PJSM,Cont.installing choke hose bolts and saddle clamps,work with mechanic change seals in choke valves,cont working on mud pumps,change seats and valves,install 6"liners.stage up boiler temp. housekeeping,Western Crane inspect tuggers,manriders and pad eyes. 18:00 00:00 6.00 24.00 MOB A 20 P PJSM,Start prep work,set one more matt in shed for work platform,gather tools,hand tools,ladders,chain falls,beam clamps ect.remove hoist motors and set on pallet in shed,turn on steam in utility mod and sub, shut in sub side and B/D for repairs,brake bolts loose on crane carriage Gas Readings Avg Background Gas(%) Max Background Gas)%) Avg Connection Gas(%( Max Connection Gas(%) Avg Drill Gas(%) Max Drill Gas(%( Avg Trip Gas(%) Max Trip Gas(%) Cumulative Mud Volumes Active Volume(bbl) Hole Volume(bbl) Losses(bbl) Cum Additions(bbl) Additions(bbl) Cum Losses(bbl) Daily Contacts Position Contact Name Company Title Email Office Mobile • Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com "907-685-0710 '907-320-0058 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Mitch Billington ENI Drilling Supv. 907-685-0722 Eni representative Paul Holley ENI HSE Tool Push Tony Morales Nabors Alaska Drilling Tool Pusher Tool Push Wesley Jeardoe Nabors Alaska Drilling Tool Pusher Personnel Log(P08) Company Serv.Type Work H(hr) Stand-by H(hr) Count Note Eni HSE 12.00 1 Washington Crane Crane Operator 12.00 1 CH2M Truck Driuver 12.00 2 Solsten Drilling Supervisor 12.00 3 NABORS Rig Crew 12.00 24 Well Name: OP22-WW03• •Dally Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 10/19/2016 6 Job: WORKOVER PPage:2 2 of 2 BOP Stack 8 Components Description Start Date Last Certification Date Pressure Rating(psi)' Type Make Model ID Nom(in) P Range(psi) Last Cert Date Slow Circulation Rates Pump Number: Make: Model: Start Date End Date Liner Size(in) Volume Per Stroke Override(bbl/stk) Max Pressure(psi) Date r r Depth(ftKB) Slow Spd Strokes(spm) P(psi) Eff(%( Q Flow(gpm) Daily Bulk Supply Item Description: EQUIPMENT FUEL Unit Label:Gallons Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/19/2016 1,796.0 1,796.0 2,789.0 2,789.0 0.0 0.0 Supply Item Description: NAD 245E Diesel Fuel Unit Label:gal us Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/19/2016 334.0 16,000.0 460.0 26,374.0 0.0 25,914.0 Supply Item Description: NAD 245E Rig Water Unit Label:bbl Unit Size: Note: Date Consumed Received Returned Corn Consumed Corn Received Cum Returned Cum On Loc Note 10/19/2016 144.0 130.0 144.0 260.0 0.0 116.0 Last Authority Visit Date Tot insp.Nbr Total I.N.C.number Comment STOP Cards Submitted Company #Rpts Com NABORS ALASKA DRILLING 34 PJSM NABORS ALASKA DRILLING 9 STOP Cards General Notes Comment: 0 Well Name: OP22-WW03 �DaiIy Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 10/20/2016 • Report#: 7 2 n A Job: WORKOVER Page:1 of 2 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Ground Level(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 0.00 16.38 36.62 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date NABORS 245 NABORS ALASKA LAND RIG 0637 10/14/2016 Daily Information Weather Temperature(°F) Wind Days LTI(days) Days RI(days) POB Overcast,Snow 18.2 SW @ 12.9 MPH 30.0 Cost Summary Job Account Currency Code Total AFE Amount(Cost) Daily Cost(Cost) Cumulative Cost(Cost) Daily Mud Field Est(Cost) Cumulative mud Cost(Cost) 7683 USD 5,049,784 56,382 364,743 Safety Incidents-Near Miss Date Category Type Subtype Severity Cause Lost time? 10/20/2016 No Comment NO INCIDENTS REPORTED Safety Drills Days Until Next Check Type #Occur Last Date Next Date _ (days) Fire Drill 5 10/19/2016 11/2/2016 13 Rig Inspection 7 10/20/2016 10/21/2016 1 Safety Meeting 7 10/20/2016 10/21/2016 1 Spill Drill 3 10/19/2016 11/2/2016 13 Casings seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) TVD Bot.(RKB) Run Date CASING 133/8 12.42 L-80 -0.8 4,020.0 3,727.6 7/12/2013 CASING 9 5/8 8.84 L-80 0.1 7,631.0 6,526.8 7/29/2013 LINER 7 6.18 L-80 7,396.8 10,668.0 9,513.5 8/5/2013 Last Cementing Cementing Start Date: 8/6/2013 String:LINER,10,668.0ftKB Comment: Stg# Top(RKB) Top Meas Meth Btm(ftKB) Com 1 7,396.0 Volume Calculations 10,658.0 Job Information„ Job Phase Planned Start Date Start Date End Date P50 Duration(days) P50 Cost(Cost) WORKOVER 10/14/201600:00 10/14/201612:00 0.00 0 Daily Summary Operations 24h Forecast Continue with rig warm up. 24h Summary PJSM,Dressing mud pumps,work on getting steam around rig,Remove short side pipe shed bridge crane.PJSM,Repair several steam lines going to sub module,cont dressing mud pumps,Begin installing short side of pipe shed bridge crane Hang trucks on hanging/trolley beams.Hang winch on main beam and bolt up main beam to trucks.PJSM,Cont working on mud pumps,choke manifold and bridge crane in pipe shed.PJSM,Cont torque up bonnet flanges on choke valves,finish up mud pumps#1 and#2,gather up tools to hang blocks,remove dog bones off top drive for inspection. Operation at 07.00 Warming up rig Time Log Start End Cum Dur End Depth Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. (RKB) 00:00 06:00 6.00 6.00 MOB A 1 P PJSM,Dressing mud pumps,work on getting steam around rig,Remove short side pipe shed bridge crane. 06:00 12:00 6.00 12.00 MOB A1 P PSJM,Repair several steam lines going to sub module,cont dressing mud pumps,Begin installing short side of pipe shed bridge crane Hang trucks on hanging/trolley beams.Hang winch on main beam and bolt up main beam to trucks 12:00 18:00 ' 6.00 18.00 MOB A1 P PJSM,Cont working on mud pumps,choke manifold and bridge crane in pipe shed. 18:00 00:00 6.00 24.00 MOB A 1 P PJSM,Cont torque up bonnet flanges on choke valves,finish up mud pumps#1 and#2,gather up tools to hang blocks,remove dog bones off top drive for inspection. Gas Readings Avg Background Gas(%) Man Background Gas(%) Avg Connection Gas(%) Max Connection Gas(%) Avg Drill Gas(%) Max Drill Gas(%) Avg Trip Gas(% Max Trip Gas(%) Cumulative Mud Volumes Active Volume(bbl) Hole Volume(bbl) Losses(bbl) Cum Additions(bbl) Additions(bbl) Cum Losses(bbl) Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Russ Wimmer ENI Drilling Supv. 'SIDDrilling@enipetroleum.com 907-685-0710 907-320-0058 Eni representative Mitch Billington ENI Drilling Supv. 907-685-0722 Eni representative Paul Holley ENI HSE Tool Push Tony Morales Nabors Alaska Drilling Tool Pusher Tool Push Wesley Jeardoe Nabors Alaska Drilling Tool Pusher Personnel Log(POD) Company Serv.Type Work H(hr) Stand-by H(hr) Count Note Eni HSE 12.00 1 Washington Crane Crane Operator 12.00 1 Solsten Drilling Supervisor 12.00 2 CH2M Truck Driver 12.00 2 NABORS Rig Crew 12.00 24 BOP Stack&Components Description Start Date Last Certification Date Pressure Rating(psi) Type Make Model ID Nom(in) P Range(psi) Last Cert Date Well Name: OP22-WW03 •�DaiIy Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 10/2012016 Job: WORKOVER Page:2 7 o Page: of 2 Slow Circulation Rates Pump Number: Make: Model: Start Date End Date Liner Size(in) Volume Per Stroke Override(bbl/stk) Max Pressure(psi) Date Depth(ftKB) Slow Spd Strokes(spm) P(psi) Eff)%) 0 Flow(gpm) Daily Bulk Supply Item Description: EQUIPMENT FUEL Unit Label:Gallons Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/20/2016 584.0 584.0 3,373.0 3,373.0 0.0 0.0 Supply Item Description: NAD 245E Diesel Fuel Unit Label:gal us Unit Size: Note: • Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/20/2016 1,218.0 0.0 1,678.0 26,374.0 0.0 24,696.0 Supply Item Description: NAD 245E Rig Water Unit Label:bbl Unit Size: Note: • Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/20/2016 97.0 370.0 241.0 630.0 0.0 389.0 Last Authority Visit Date Tot insp.Nbr Total I.N.C.number Comment STOP Cards Submitted Company #Rpts Com NABORS ALASKA DRILLING 51 PJSM NABORS ALASKA DRILLING 19 STOP Cards General Notes Comment: IP Well Name: OP22-WW03• Dally Report Wellbore Name: OP22-WW03 10 Well Code: 27295• Ret ort#:/ 821/2016 Page:Job: WORKOVER Rep Date: 1 of 2 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Ground Level(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 0.00 16.38 36.62 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date NABORS 245 NABORS ALASKA LAND RIG 0637 10/14/2016 Daily Information Weather Temperature(°F) Wind Days LTI(days) Days RI(days) POB Overcast,Occasional Snow 24.0 SW @ 2010 27 MPH 30.0 Cost Summary Job Account Currency Code Total AFE Amount(Cost) Daily Cost(Cost) Cumulative Cost(Cost) Daily Mud Field Est(Cost) Cumulative mud Cost(Cost) 7683 USD 5,049,784 56,793 421,536 Safety Incidents-Near Miss Date Category Type Subtype Severity Cause Lost time? 10/21/2016 No Comment NO INCIDENTS REPORTED Safety Drills Days Until Next Check Type #Occur Last Date Next Date (days) Fire Drill 5 10/19/2016 11/2/2016 12 Man Down Drill1 10/21/2016 1/19/2017 90 Rig Inspection 8 10/21/2016 10/22/2016 1 Safety Meeting 6 10/21/2016 10/22/2016 1 Spill Drill 3 10/19/2016 11/2/2016 12 Casings seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(RKB) TVD Bot.(RKB) Run Date CASING 13 3/8 12.42 L-80 -0.8 4,020.0 3,727.6 7/12/2013 CASING 9 5/8 8.64 L-80 0.1 7,631.0 6,526.8 7/29/2013 LINER 7 6.18 L-80 7,396.8 10,668.0 9,513.5 8/5/2013 Last Cementing Cementing Start Date: 8/6/2013 String:LINER,10,668.OftKB Comment: Stg# Top(ftKB) Top Meas Meth Btm(ftKB) Corn 1 7,396.0 Volume Calculations 10,658.0 Job Information Job Phase Planned Start Date Start Date End Date P50 Duration(days) P50 Cost(Cost) WORKOVER 10/14/2016 00:00 10/14/201612:00 0.00 0 Daily Summary Operations 24h Forecast Continue with rig warm up. 24h Summary Remove dog bones FI blocks and Top Drive.Hang blocks.Remove guard from Drawworks.Start generator#1 and put it in service,turn off generator#1.Gather all come alongs and chain hosts for inspection. Prep blocks,Top Drive ears for Tubo inspection.Dress#3 mud pump.Begin disassembling Drawwork Brake linkage.Remove short side bridge crane from I-beam.PJSM,work on inspection list,cont.prepping top drive ears,bails,deadman,for Tuboscope inspection.Dress#3 mud pump,cant disassembling draw works brake linkage,remove short side bridge crane from beam and turn around and reinstall same.PJSM, V cont cleaning brake linkage,equalizer bar,dog collar,snubbing posts,long side of pipe shed bridge crane hook,pipe skate,finish assembling pipe shed crane,cont dressing#3 mud pump,clean pipe skate elevators for inspection. Operation at 07.00 Warming up rig Time Log Start End Cum Dur End Depth Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. (RKB) 00:00 06:00 6.00 6.00 MOB A - 20 P PJSM Remove dog bones F/blocks and Top Drive.Hang blocks.Remove guard from Drawworks.Start generator#1 and put it in service,turn off generator#1. 06:00 12:00 6.00 12.00 MOB A 20 P PJSM Gather all come alongs and chain hosts for inspection.Prep blocks,Top Drive ears for Tubo inspection. Dress#3 mud pump.Begin disassembling Drawwork Brake linkage.Remove short side bridge crane from(- beam. 12:00 18:00 6.00 18.00 MOB A i 20 P PJSM,work on inspection list,cont.prepping top drive ears,bails,deadman,for Tuboscope inspection.Dress #3 mud pump,cont disassembling draw works brake linkage,remove short side bridge crane from beam and turn around and reinstall same. 18:00 00:00 6.00 24.00 MOB A 20 P PJSM,cont cleaning brake linkage,equalizer bar,dog collar,snubbing posts,long side of pipe shed bridge crane hook,pipe skate,finish assembling pipe shed crane,cont dressing#3 mud pump,clean pipe skate elevators for inspection. Gas Readings Avg Background Gas(%) Max Background Gas(%) Avg Connection Gas(%) Max Connection Gas(%) Avg Drill Gas)%) Max Drill Gas(%( Avg Trip Gas)%( Max Trip Gas(%) Cumulative Mud Volumes Active Volume(bbl) Hole Volume(bbl) Losses(bbl) Cum Additions(bbl) Additions(bbl) Cum Losses(bbl) Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.corn 907-685-0710 '907-320-0058 Eni representative Mitch Billington ENI Drilling Supv, 907-685-0722 Eni representative Paul Holley ENI HSE Tool Push Tony Morales Nabors Alaska Drilling Tool Pusher Tool Push Wesley Jeardoe Nabors Alaska Drilling Tool Pusher Personnel Log(POB) Company Serv.Type Work H(hr) Stand-by H(hr) _ Count Note Eni HSE 12.00 1 Washington Crane Crane Operator 12.00 1 Solsten Drilling Supervisor 12.00 2 CH2M Truck Driver 12.00 2 NABORS Rig Crew 12.00 24 Well Name: OP22-WW01, Dally Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 10/21/2016 Job: WORKOVER Page:2 8 o Page: of 2 BOP Stack&Components Description Start Date Last Certification Date Pressure Rating(psi) Type Make Model ID Nom(in) P Range(psi) Last Cert Date Slow Circulation Rates Pump Number: Make: Model: Start Date End Date Liner Size(in) Volume Per Stroke Override(bbl/stk) Max Pressure(psi) Date Depth(ftKB) Slow Spd Strokes(spm) P(psi) Eff)%) Q Flow(gpm) Daily Bulk Supply Item Description: EQUIPMENT FUEL Unit Label:Gallons Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/21/2016 473.0 473.0 3,846.0 3,846.0 0.0 0.0 Supply Item Description: NAD 245E Diesel Fuel Unit Label:gal us Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/21/2016 1,470.0 0.0 3,148.0 26,374.0 0.0 23,226.0 Supply Item Description: NAD 245E Rig Water Unit Label:bbl Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/21/2016 21.0 0.0 262.0 630.0 0.0 368.0 Last Authority Visit Date Tot insp.Nbr Total I.N.C.number Comment STOP Cards Submitted Company #Rpts Com NABORS ALASKA DRILLING 20 STOP Cards NABORS ALASKA DRILLING 54 PJSM General Notes Comment: • ir Well Name: OP22-WWO �DaiIy Report oil Wellbore Name: OP22- 03 Well Code: 27295 Date: 10/22/2016 •2n II Job: WORKOVER Papo ge: o 2 Page:1 of 2 Well Header PermiVConcession N° Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Ground Level(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 0.00 16.38 36.62 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date NABORS 245 NABORS ALASKA LAND RIG 0637 10/14/2016 Daily Information Weather Temperature("F) Wind Days LTI(days) Days RI(days) POB Overcast,Occasional Snow 17.0 S @ 17 MPH 30.0 Cost Summary Job Account Currency Code Total AFE Amount(Cost) Daily Cost(Cost) Cumulative Cost(Cost) Daily Mud Field Est(Cost) Cumulative mud Cost(Cost) 7683 USD 5,049,784 59,942 481,477 Safety Incidents-Near Miss Date Category Type Subtype Severity Cause Lost time? 10/22/2016 No Comment NO INCIDENTS REPORTED Safety Drills Days Until Next Check Type #Occur Last Date Next Date (days) - Fire Drill 6 10/22/2016 11/5/2016 14 Man Down Drill 1 10/21/2016 1/19/2017 89 Rig Inspection 9 10/21/2016 10/22/2016 0 Safety Meeting 9 10/22/2016 10/23/2016 1 Spill Drill 4 10/19/2016 11/2/2016 11 Casings seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(RKB) TVD Bot.(RKB) Run Date CASING ' 13 3/8 12.42 L-80 -0.8 4,020.0 3,727.6 7/12/2013 CASING 95/8 8.84 L-80 0.1 7,631.0 6,526.8 7/29/2013 LINER 7 6.18 L-80 7,396.8 10,668.0 9,513.5 8/5/2013 Last Cementing Cementing Start Date: 8/6/2013 String:LINER,10,668.0(1KB Comment: Stg# Top(RKB) Top Meas Meth Btm(ftKB) Com 1 7,396.0 Volume Calculations 10,658.0 Job Information Job Phase Planned Start Date Start Date End Date P50 Duration(days) P50 Cost(Cost) WORKOVER 1004/2016 00:00 10/14/2016 12:00 0.00 0 Daily Summary Operations 24h Forecast Continue with rig warm up. 24h Summary Prep tugger bases,brake linkage,BOPE bridge crane hooks for inspection.Dressing Mud Pump#3 W/6"Liners.Repair steam lines.Finish prep work for Tuboscope inspection.Tuboscope reps inspecting Equip. Finish installation of ESP cable winch under rig floor.Wire in short side bridge crane operational.Build supports F/Choke Manifold plumbing.Remove all unneeded oil,Pipe Dope from landing above Drawworks. Cont.helping Tuboscope inspect Equip.PJSM,cont helping Tuboscope with equipment inspections,help Washington Crane tec with pipe shed hoist,hang SRLS in derrick.and cellar area,finish prep work on tugger and man rider bases for inspection.Start priming and painting all inspect equipment,help electrician run wire to drilling console from dog house.Inspect and change out bad fire extinguishers.PJSM,cont priming and painting inspected equipment,housekeeping through out the rig. Operation at 07.00 Warming up rig Time Log Start End Cum Dur End Depth Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. (RKB) 00:00 06:00 6.00 6.00 MOB A 2 P PJSM Prep tugger bases,brake linkage,BOPE bridge crane hooks for inspection.Dressing Mud Pump#3 W/ 6"Liners.Repair steam lines. 06:00 12:00 6.00 12.00 MOB A 2 P PJSM Finish prep work for Tuboscope inspection.Tuboscope reps inspecting Equip.Finish installation of ESP cable winch under rig floor.Wire in short side bridge crane operational.Build supports F/Choke Manifold plumbing.Remove all unneeded oil,Pipe Dope from landing above Drawworks.Cont.helping Tuboscope inspect Equip. 12:00 18:00 6.00 18.00 MOB A 1 P PJSM,cont helping Tuboscope with equipment inspections,help Washington Crane tee with pipe shed hoist, hang SRLS in derrick.and cellar area,finish prep work on tugger and man rider bases for inspection.Start priming and painting all inspect equipment,help electrician run wire to drilling console from dog house.Inspect and change out bad fire extinguishers. 18:00 00:00 6.00 24.00 MOB A 1 P 'PJSM,cont priming and painting inspected equipment,housekeeping through out the rig. Gas Readings Avg Background Gas(%) Max Background Gas(%) Avg Connection Gas(%) Max Connection Gas(%) Avg Drill Gas(%) 'Max Drill Gas(%) Avg Trip Gas(%) Max Trip Gas(%) Cumulative Mud Volumes Active Volume(bbl) Hole Volume(bbl) Losses(bbl) Cum Additions(bbl) Additions(bbl) Cum Losses(bbl) Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Russ Wimmer ENI Drilling Supv. 'SIDDrilling@enipetroleum.com '907-685-0710 907-320-0058 Eni representative Mitch Billington ENI Drilling Supv. 907-685-0722 Eni representative Paul Holley ENI USE Tool Push Tony Morales Nabors Alaska Drilling Tool Pusher Tool Push Wesley Jeardoe Nabors Alaska Dulling Tool Pusher Personnel Log(POB) Company _ Serv.Type Work H(hr) Stand-by H(hr) Count - Note Eni HSE 12.00 1 Washington Crane Crane Operator 12.00 1 Solsten Drilling Supervisor 12.00 2 CH2M Truck Driver 12.00 2 NABORS Rig Crew 12.00 24 Well Name: OP22-WW03 IP —Daily Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 10/22/2016 9 Job: WORKOVER P #: Paage:ge: 2 2 of 2 BOP Stack 8 Components Description Start Date Last Certification Date Pressure Rating(psi) Type Make Model ID Nom(in) P Range(psi) Last Cert Date Slow Circulation Rates Pump Number: Make: Model: Start Date End Date Liner Size(in) Volume Per Stroke Override(bbl/stk) Max Pressure(psi) Date Depth(ftKB) Slow Spd Strokes(spm) P(psi) Eff)%) Q Flow(gpm) Daily Bulk Supply Item Description: EQUIPMENT FUEL Unit Label:Gallons Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/22/2016 498.0 498.0 4,344.0 4,344.0 0.0 0.0 Supply Item Description: NAD 245E Diesel Fuel Unit Label:gal us Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/22/2016 2,016.0 0.0 5,164.0 26,374.0 0.0 21,210.0 Supply Item Description: NAD 245E Rig Water Unit Label:bbl Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/22/2016 35.0 0.0 297.0 630.0 0.0 333.0 Last Authority Visit Date Tot insp.Nbr Total I.N.C.number Comment STOP Cards Submitted Company #Rpts Com NABORS ALASKA DRILLING 43 PJSM NABORS ALASKA DRILLING 18 STOP Cards General Notes Comment: 1,Well Name: OP22-WW03 wily Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 10/23/2016 • Report#: 10 enll Job: WORKOVER Page:1 of 2 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Ground Level(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 0.00 16.38 36.62 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date NABORS 245 NABORS ALASKA LAND RIG 0637 10/14/2016 Daily Information Weather Temperature(°F) Wind Days LTI(days) Days RI(days) POB Overcast 25.8 S @ 10 MPH 29.0 Cost Summary Job Account Currency Code Total AFE Amount(Cost) Daily Cost(Cost) Cumulative Cost(Cost) Daily Mud Field Est(Cost) Cumulative mud Cost(Cost) 7683 USD 5,049,784 54,588 536,065 Safety Incidents-Near Miss Date Category Type Subtype Severity Cause Lost time? 10/23/2016 No Comment NO INCIDENTS REPORTED Safety Drills Days Until Next Check Type 8 Occur Last Date Next Date (days) - Fire Drill 7 10/23/2016 11/6/2016 14 Man Down Drill 1 10/21/2016 1/19/2017 88 Rig Inspection 10 10/23/2016 10/24/2016 1 Safety Meeting 10 10/23/2016 10/24/2016 1 Spill Drill 5 10/23/2016 11/6/2016 14 Casings seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(RKB) TVD Bot.(RKB) Run Date CASING 13 3/8 12.42 L-80 -0.8 4,020.0 3,727.6 7/12/2013 CASING 95/8 8.84 L-80 0.1 7,631.0 6,526.8 7/29/2013 LINER 7 6.18 L-80 7,396.8 10,668.0 9,513.5 8/5/2013 Last Cementing Cementing Start Date: 8/6/2013 String:LINER,10,668.0ftKB Comment: Stg 8 Top(ftKB) Top Meas Meth Btm(ttKB) Corn 1 7,396.0 Volume Calculations 10,658.0 Job Information Job Phase Planned Start Date Start Date End Date P50 Duration(days) P50 Cost(Cost) WORKOVER 10/14/2016 00:00 10/14/2016 12:00 0.00 0 Daily Summary Operations 24h Forecast Continue with rig warm up. 24h Summary PJSM,cont painting equipment that was inspected,consolidate/tag/bag excess pipe dope and oil.Function test and pressure test pump.Housekeeping,install ported flange on choke hose.PJSM,install dog bones on to Top Drive,Work on mud pump rod wash lines(full of scale),cont fabricating supports for choke line.Washington Crane rep inspecting and testing pad eyes on the rig.Housekeeping.PJSM,Cont fabricating supports for choke line,Washington crane cont to inspect pad eyes on rig,Housekeeping,Cont,WI drawworks brake assembly,adjust brake,hook up grease lines and guards.Electrician wire up stroke counter,re-route epoch wires to choke manifold.PJSM,charge koomey bottles 8 pulsation dampener.cont clean out rod wash lines on mud pumps.Run new super choke lines,Change out long side pipe shed bridge crane. Operation at 07.00 Warming up rig Time Log Start End Cum Dur End Depth Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. (RKB) 00:00 06:00 6.00 6.00 MOB A 20 P PJSM,cont painting equipment that was inspected,consolidate/tag/bag excess pipe dope and oil.Function test and pressure test pump.Housekeeping,install ported flange on choke hose. 06:00 12:00 6.00 12.00 MOB A 20 P PJSM,install dog bones on to Top Drive,Work on mud pump rod wash lines(full of scale),cont fabricating supports for choke line.Washington Crane rep inspecting and testing pad eyes on the rig.Housekeeping. 12:00 18:00 6.00 18.00 MOB . A 20 P -PJSM,Cont fabricating supports for choke line,Washington crane cont to inspect pad eyes on rig, Housekeeping,Cont,W/drawworks brake assembly,adjust brake,hook up grease lines and guards. Electrician wire up stroke counter,re-route epoch wires to choke manifold. 18:00 00:00 6.00 24.00 ' MOB A 20 P PJSM,charge koomey bottles&pulsation dampener.cont clean out rod wash lines on mud pumps.Run new super choke lines,Change out long side pipe shed bridge crane. Gas Readings Avg Background Gas(%) Max Background Gas(%) Avg Connection Gas(%) Max Connection Gas(%) Avg Drill Gas(%) Max Drill Gas(%) Avg Trip Gas)%) Max Trip Gas(%) Cumulative Mud Volumes Active Volume(bbl) Hole Volume(bbl) Losses(bbl) Cum Additions(bbl) Additions(bbl) Cum Losses(bbl) Daily Contacts Position Contact Name Company Title _ Email Office Mobile Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0710 '907-320-0058 Eni representative Mitch Billington ENI Drilling Supv. 907-685-0722 Eni representative Paul Holley ENI HSE Tool Push Tony Morales Nabors Alaska Drilling Tool Pusher Tool Push Wesley Jeardoe Nabors Alaska Drilling Tool Pusher Personnel Log(POB) Company Serv.Type Work H(hr) Stand-by H(hr) Count Note • Eni HSE 12.00 1 Solsten Drilling Supervisor 12.00 2 CH2M Truck Driver 12.00 2 NABORS Rig Crew 12.00 24 BOP Stack&Components Description Start Date Last Certification Date Pressure Rating(psi) Well Name: OP22-WW03O •aily Report ort Wellbore Name: OP22-WW03 Well Code: 27295 Date: 10/23/2016 P10 Job: WORKOVER Page:2 2 of 2 Type Make Model ID Nom(in) P Range(psi) Last Cert Date Slow Circulation Rates Pump Number: Make: Model: Start Date End Date Liner Size(in) Volume Per Stroke Override(bbllstk) Max Pressure(psi) Date Depth(ftKB) Slow Spd Strokes(spm) P(psi) Eff)%) O Flow(gpm) Daily Bulk Supply Item Description: EQUIPMENT FUEL Unit Label:Gallons Unit Size: Note: Date - Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/23/2016 404.0 404.0 4,748.0 4,748.0 0.0 0.0 Supply Item Description: NAD 245E Diesel Fuel Unit Label:gal us Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/23/2016 1,592.0 0.0 6,756.0 26,374.0 0.0 19,618.0 Supply Item Description: NAD 245E Rig Water Unit Label:bbl Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/23/2016 74.0 0.0 371.0 630.0 0.0 259.0 Last Authority Visit Date Tot insp.Nbr Total I.N.C.number Comment STOP Cards Submitted Company #Rpts Corn NABORS ALASKA DRILLING 36 PJSM NABORS ALASKA DRILLING 15 STOP Cards General Notes Comment: Well Name: OP22-WW03• laily Report Wellbore Name: OP22-WW03 10 Well Code: 27295• Ret ort#/2112016 2n II Job: WORKOVER Page:1 of 2 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Ground Level(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 0.00 16.38 36.62 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date NABORS 245 NABORS ALASKA LAND RIG 0637 10/14/2016 Daily Information Weather Temperature(°F) Wind Days LTI(days) Days RI(days) POB Partly Cloudy 14.0 E @ 25 MPH 30.0 Cost Summary Job Account Currency Code Total AFE Amount(Cost) Daily Cost(Cost) Cumulative Cost(Cost) Daily Mud Field Est(Cost) Cumulative mud Cost(Cost) 7683 USD 5,049,784 58,262 594,326 1,150 1.150 Safety Incidents-Near Miss Date Category Type Subtype Severity Cause Lost time? 10/24/2016 No Comment NO INCIDENTS REPORTED Safety Drills Days Until Next Check Type #Occur Last Date Next Date (days) Fire Drill 8 10/24/2016 11/7/2016 14 Man Down Drill 1 10/21/2016 1/19/2017 87 Rig Inspection 11 10/24/2016 10/25/2016 1 Safety Meeting 11 10/24/2016 10/25/2016 1 Spill Drill 6 10/24/2016 11/7/2016 14 Casings seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) TVD But(RKB) Run Date CASING 13 3/8 12.42 L-80 -0.8 4,020.0 3,727.6 7/12/2013 CASING 9 5/8 8.84 L-80 0.1 7,631.0 6,526.8 7/29/2013 LINER 7 6.18 L-80 7,396.8 10,668.0 9,513.5 8/5/2013 Last Cementing Cementing Start Date: 8/6/2013 String:LINER,10,668.OftKB Comment: Stg# Top(ftKB) Top Meas Meth Btm(ftKB) Com 1 7,396.0 Volume Calculations 10,658.0 Job Information Job Phase Planned Start Date Start Date End Date P50 Duration(days) P50 Cost(Cost) WORKOVER 10/14/2016 00:00 10/14/201612:00 0.00 0 Daily Summary Operations 24h Forecast Continue with rig warm up. 24h Summary PJSM Complete pinning blocks to Top-Drive.Remove hanging line from blocks.Torque up saver sub and upper IBOP to Top-Drive.Hookup super choke control lines and function test.Calibrate choke position sensor.Add water to pits and check for leaks.Install bales.Function test mud pumps.Remove drill pipe slips from rig.Installing stops for short side bridge cranes.PJSM,Cont installing stops on short sire pipe / shed bridge crane,welder shortened motor mounts on long side bridge crane,electrician wired up,close out permits.re-route DPP gauge to mud manifold,hook back up on super choke control lines,change out Y fall arrester at board,install crown arrest,work on HRECL for crew.set crown saver on top drive.start derrick inspection.PJSM,Grease crown,blocks,top drive,install black jack in top drive,paint choke manifold pedestal,housekeeping,line up and function brake cooling pump,lower all un-needed subs off rig floor and place on pallets and band down.cont W/zonal derrick inspection and crew HRCI. Operation at 07.00 Warming up rig Time Log Start End Cum Dur End Depth Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. (ftKB) 00:00 06:00 6.00 6.00 MOB A 1 P PJSM Complete pinning blocks to Top-Drive.Remove hanging line for blocks.Torque saver sub and IBOP to Top-Drive. 06:00 12:00 6.00 12.00 MOB A 1 P PJSM Hookup super choke control lines and function test.Calibrate choke position sensor.Add water to pits and check for leaks.Install bales.Function test mud pumps.Remove drill pipe slips from rig.Installing stops for short side bridge cranes. 12:00 18:00 6.00 18.00 MOB A 1 P PJSM,Cont installing stops on short sire pipe shed bridge crane,welder shortened motor mounts on long side bridge crane,electrician wired up,close out permits.re-route DPP gauge to mud manifold,hook back up on super choke control lines,change out fall arrester at board,install crown arrest,work on HRECL for crew.set crown saver on top drive.start derrick inspection. 18:00 00:00 6.00 24.00 MOB A 1 P PJSM,Grease crown,blocks,top drive,install black jack in top drive,paint choke manifold pedestal, housekeeping,line up and function brake cooling pump,lower all un-needed subs off rig floor and place on pallets and band down.cont W/zonal derrick inspection and crew HRCI. Gas Readings Avg Background Gas)%) Max Background Gas)%) Avg Connection Gas)%) Max Connection Gas(%) Avg Drill Gas)%) Max Drill Gas)%) Avg Trip Gas(%) Max Trip Gas(%) Cumulative Mud Volumes Active Volume(bbl) Hole Volume(bbl) Losses(bbl) Cum Additions(bbl) Additions(bbl) Cum Losses(bbl) Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Russ Wimmer ENI Drilling Supv. 'SIDDrilling@enipetroleum.com 907-685-0710 907-320-0058 Eni representative Mitch Billington ENI Drilling Supv. 907-685-0722 Eni representative Paul Holley ENI HSE Tool Push Tony Morales Nabors Alaska Drilling Tool Pusher Tool Push Wesley Jeardoe Nabors Alaska Drilling Tool Pusher Personnel Log(POB) Company Serv.Type Work H(hr) Stand-by H(hr) Count Note Eni HSE 12.00 1 Solsten Drilling Supervisor 12.00 2 CH2M Truck Driver 12.00 2 NABORS Rig Crew 12.00 25 Well Name: OP22-WW03 LTFt laily Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 10/2412016 11 Job: WORKOVER PPage:2 2 of 2 BOP Stack 8 Components Description Start Date Last Certification Date Pressure Rating(psi) Type Make Model ID Nom(in) P Range(psi) Last Cert Date Slow Circulation Rates Pump Number: Make: Model: Start Date End Date Liner Size(in) Volume Per Stroke Override(bbl/stk) Max Pressure(psi) Date Depth(MB) Slow Spd Strokes(spm) P(psi) Eff(%) Q Flow(gpm( Daily Bulk Supply Item Description: EQUIPMENT FUEL Unit Label:Gallons Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/24/2016 674.0 674.0 5,422.0 5,422.0 0.0 0.0 Supply Item Description: NAD 245E Diesel Fuel Unit Label:gal us Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/24/2016 1,344.0 0.0 8,100.0 26,374.0 0.0 18,274.0 Supply Item Description: NAD 245E Rig Water Unit Label:bbl Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/24/2016 77.0 120.0 448.0 750.0 0.0 302.0 Last Authority Visit Date Tot insp.Nbr Total I.N.C.number Comment STOP Cards Submitted Company P Rpts Com NABORS ALASKA DRILLING 36 PJSM NABORS ALASKA DRILLING 17 STOP Cards General Notes Comment: 11,Well Name: OP22-WW03 wily Report moil Wellbore Name: OP22- 03 Well Code: 27295 Date: 10125/2016 • 12 2 n 11 Job: WORKOVER Papo ge: of 2 Page:1 2 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Ground Level(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 0.00 16.38 36.62 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date NABORS 245 NABORS ALASKA LAND RIG 0637 10/14/2016 Daily Information Weather Temperature(°F) Wind Days LTI(days) Days RI(days) POB Partly Cloudy 14.5 ESE @ 22 MPH 31.0 Cost Summary Job Account Currency Code Total AFE Amount(Cost) Daily Cost(Cost) Cumulative Cost(Cost) Daily Mud Field Est(Cost) Cumulative mud Cost(Cost) 7683 USD 5,049,784 62,616 656,942 1,150 2,300 Safety Incidents-Near Miss Date Category Type Subtype Severity Cause Lost time? 10/25/2016 Non-Recordable FA Other Minor No Comment FA-Examination only,abrasion on the index finger-Nabors Drilling Safety Drills Days Until Next Check Type #Occur Last Date Next Date (days) Fire Drill 9 10/25/2016 11/8/2016 14 Man Down Drill 1 10/21/2016 1/19/2017 86 Rig Inspection 12 10/25/2016 10/26/2016 1 Safety Meeting 12 10/25/2016 10/26/2016 1 Spill Drill 7 10/24/2016 11/7/2016 13 Casings seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(RKB) _ TVD Bot.(RKB) Run Date CASING 133/8 12.42 L-80 -0.8 4,020.0 3,727.6 7/12/2013 CASING 95/8 8.84 L-80 0.1 7,631.0 6,526.8 7/29/2013 LINER 7 6.18 L-80 7,396.8 10,668.0 9,513.5 8/5/2013 Last Cementing Cementing Start Date: 8/6/2013 String:LINER,10,668.OftKB Comment: Stg# Top(ftKB) Top Meas Meth Btm(ftKB) Com 1 7,396.0 Volume Calculations 10,658.0 Job Information Job Phase Planned Start Date Start Date End Date P50 Duration(days) P50 Cost(Cost) WORKOVER 10/14/2016 00:00 10/14/2016 12:00 0.00 0 Daily Summary Operations 24h Forecast Continue with rig warm up. 24h Summary PJSM Hyro test pits and transfer pumps.Install brake handle guard.Repair short side pipe shed door cables.Stage catch can components and duck ponds.Perform HRECL's.General house keeping.Energize Top-Drive and test.Installing stops for SS bridge crane.Commission mix pumps,#3 MP and Gen#4.Repairing#1 MP blower.Complete choke manifold and grease.Trouble shooting Boiler#2,PJSM,grease choke manifold&prep to test,help welder to build bump stops on bridge crane in short side of pipe shed.Electrical work on boiler#2 control module,Clean out mud pump rod wash reservoirs.PJSM,Fill choke manifold,found loose stud,check and tighten all studs,boiler#2 working staged up to temp.Service pipe skate and function test,change winch on pit#5 riser,pressure up on choke a to 500 psi and found leaks, tighten up choke. Operation at 07.00 Warming up rig Time Log Start End Cum Dur End Depth Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. (ftKB) 00:00 '06:00 - 6.00 ' 6.00 - MOB 7 A ) 20 P PJSM Hyro test pits and transfer pumps.Install brake handle guard.Repair short side pipe shed door cables. Stage catch can components and duck ponds.Perform HRECL's.General house keeping. 06:00 12:00 6.00 12.00 MOB A 20 P PJSM Energize Top-Drive and test.Installing stops for SS bridge crane.Commission mix pumps,#3 mud pump and Gen#4.Repairing#1 MP blower.Complete rebuilding choke manifold and grease.Trouble shooting Boiler#2. 12:00 18:00 - 6.00 ' 18.00 MOB ' A 20 P PJSM,grease choke manifold&prep to test,help welder to build bump stops on bridge crane in short side of pipe shed.Electrical work on boiler#2 control module,Clean out mud pump rod wash reservoirs. 18:00 00:00 6.00 24.00 MOB A - 20 P PJSM,Fill choke manifold,found loose stud,check and tighten all studs,boiler#2 working staged up to temp. Service pipe skate and function test,change winch on pit#5 riser,pressure up on choke a to 500 psi and found leaks,tighten up choke. Gas Readings Avg Background Gas(%) Max Background Gas(%( Avg Connection Gas(%) Max Connection Gas(%) Avg Drill Gas(%) Max Drill Gas(%) Avg Trip Gas(%) Max Trip Gas(%) Cumulative Mud Volumes Active Volume(bbl) Hole Volume(bbl) Losses(bbl) Cum Additions(bbl) Additions(bbl) Cum Losses(bbl) Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0710 907-320-0058 Eni representative Mitch Billington ENI Drilling Supv. 907-685-0722 Eni representative Paul Holley ENI HSE Tool Push Tony Morales Nabors Alaska Drilling Tool Pusher Tool Push Wesley Jeardoe Nabors Alaska Drilling Tool Pusher Personnel Log(POB) Company Serv.Type Work H(hr) Stand-by H(hr) Count Note Eni HSE - 12.00 1 MI Swaco Mud Engineer 12.00 1 Solsten Drilling Supervisor 12.00 2 CH2M Truck Driver 12.00 2 NABORS Rig Crew 12.50 25 Well Name: OP22-WW03. Saily Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 10/25/2016 12 Job: WORKOVER PaPage:ge:2 2 of 2 BOP Stack&Components Description Start Date Last Certification Date Pressure Rating(psi) Type Make Model ID Nom(in) P Range(psi) Last Cert Date Slow Circulation Rates Pump Number: Make: Model: Start Date End Date Liner Size(in) Volume Per Stroke Override(bbl/stk) Max Pressure(psi) Date Depth(ftKB) Slow Spd Strokes(spm) P(psi) Eff)%) Q Flow(gpm) Daily Bulk Supply Item Description: EQUIPMENT FUEL Unit Label:Gallons Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/25/2016 359.0 359.0 5,781.0 5,781.0 0.0 0.0 Supply Item Description: NAD 245E Diesel Fuel Unit Label:gal us Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/25/2016 1.470.0 0.0 9,570.0 26,374.0 0.0 16,804.0 Supply Item Description: NAD 245E Rig Water Unit Label: bbl Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/25/2016 42.0 0.0 490.0 750.0 0.0 260.0 Last Authority Visit Date Tot insp.Nbr Total I.N.C.number Comment STOP Cards Submitted Company 8 Rpts Com NABORS ALASKA DRILLING 39 PJSM NABORS ALASKA DRILLING 18 STOP Cards General Notes Comment: 0110.- * Well Name: 0P22-WW03 •aily Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 10126/2016 • Report#: 13 2n 11p Job: WORKOVER Page:1 of 2 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Ground Level(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 0.00 16.38 36.62 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date NABORS 245 NABORS ALASKA LAND RIG 0637 10/14/2016 Daily Information Weather Temperature(°F) Wind Days LTI(days) Days RI(days) POB Clear 20.1 SE @ 13 MPH 31.0 Cost Summary Job Account Currency Code Total AFE Amount(Cost) Daily Cost(Cost) Cumulative Cost(Cost) Daily Mud Field Est(Cost) Cumulative mud Cost(Cost) 7683 USD 5,049,784 57,791 714,732 1,150 3,450 Safety Incidents-Near Miss Date Category Type Subtype Severity Cause Lost time? 10/26/2016 No Comment NO INCIDENTS REPORTED Safety Drills Days Until Next Check Type #Occur Last Date Next Date (days) Fire Drill 10 10/26/2016 11/9/2016 14 Man Down Drill 1 10/21/2016 1/19/2017 85 Rig Inspection 13 10/26/2016 10/27/2016 1 Safety Meeting 13 10/26/2016 10/27/2016 1 Spill Drill 8 10/26/2016 11/9/2016 14 Casings seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) TVD Bot.(RKB) Run Date CASING 133/8 12.42 L-80 -0.8 4,020.0 3,727.6 - 7/12/2013 CASING 9 5/8 8.84 L-80 0.1 7,631.0 6,526.8 7/29/2013 LINER 7 6.18 L-80 7,396.8 10,668.0 9,513.5 8/5/2013 Last Cementing Cementing Start Date: 8/6/2013 String:LINER,10,668.0(1KB Comment: Stg# Top(RKB) Top Meas Meth Btm(ftKB) Com 1 7,396.0 Volume Calculations 10,658.0 Job Information Job Phase Planned Start Date Start Date End Date P50 Duration(days) P50 Cost(Cost) WORKOVER 10/14/2016 00:00 10/14/2016 12:00 0.00 0 Daily Summary Operations 24h Forecast / ,►);/i Continue with rig warm up. /� ` l.J�" 24h Summary G PJSM,fluid pack choke manifold and attempt to pressure test,several flanges,grease fittings,and hammer unions leaking.Tighten up equipment and get a good test on all choke valves @ 3500 psi.Manual choke holds no pressure.Housekeeping in pits and pump room.Stage 2"high psi hoses and squeeze manifold in pipe shed.PJSM,Cunt tightening up choke manifold flanges,Attempt to retest choke manifold to 5K psi high,first three valves test,then unable to get good test,grease choke manifold,begin testing choke manifold again.250/5000 psi,PJSM,cont to grease choke manifold,begin testing choke manifold again,250/ / 5000 psi,tested good,B/D choke manifold.Eni environmental checked boiler#2 emissions,void pit#5 with vac truck,cont housekeeping through out the rig.PJSM,Install camera's in shaker&pump rooms.Test v trip tank alarm(good),cave tank alarm(good),clean out lampson drip pans.install safety sling to choke hose,Housekeeping&rig maintenance.gather up plug valves and swings clean and oil for up coming well kill. Operation at 07.00 Warming up rig Time Log Start End Cum Dur End Depth Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. (RKB) 00:00 06:00 6.00 6.00 MOB A 12 7 P PJSM,fluid pack choke manifold and attempt to pressure test,several flanges,grease fittings,and hammer unions leaking.Tighten up equipment and get a good test on all choke valves @ 3500 psi.Manual choke holds no pressure.Housekeeping in pits and pump room.Stage 2"high psi hoses and squeeze manifold in pipe shed. 06:00 12:00 6.00 12.00 MOB A 12 P 'PJSM,Cont tightening up choke manifold flanges,Attempt to retest choke manifold to 5K psi high,first three valves test,then unable to get good test,grease choke manifold,begin testing choke manifold again.250/ 5000 psi 12:00 18:00 6.00 ' 18.00 MOB A 12 P PJSM,cont to grease choke manifold,begin testing choke manifold again,250/5000 psi,tested good,B/D choke manifold.Eni environmental checked boiler#2 emissions,void pit#5 with vac truck,cont housekeeping through out the rig. 18:00 00:00 ' 6.00 24.00 MOB A 20 - P PJSM,Install camera's in shaker&pump rooms.Test trip tank alarm(good),cave tank alarm(good),clean out lampson drip pans.install safety sling to choke hose,Housekeeping&rig maintenance,gather up plug valves and swings clean and oil for up coming well kill. Gas Readings Avg Background Gas(%) Max Background Gas(%( Avg Connection Gas(%) Max Connection Gas(%) Avg Drill Gas(%( Max Drill Gas(%( Avg Trip Gas(14) Max Trip Gas(%) Cumulative Mud Volumes Active Volume(bbl) Hole Volume(bbl) Losses(bbl) Cum Additions(bbl) Additions(bbl) Cum Losses(bbl) Daily Contacts Position Contact Name Company Title Email Office Mobile • Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0710 907-320-0058 Eni representative Mitch Billington ENI Drilling Supv. 907-685-0722 Eni representative Paul Holley ENI HSE Tool Push Kelly Cozby Nabors Alaska Dolling Tool Pusher Tool Push Wesley Jeardoe Nabors Alaska Drilling Tool Pusher Personnel Log(POB) Company Serv.Type Work H(hr) Stand-by H(hr) Count Note Eni HOE 12.00 1 MI Swaco Mud Engineer 12.00 1 Solslen Drilling Supervisor 12.00 2 Well Name: OP22-WW03• iaiIy Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 10/2612016 13 Job: WORKOVER PaPage:ge:2 2 of 2 Personnel Log(POB) Company Serv.Type _ Work H(hr) Stand-by H(hr) _ Count Note CH2M Truck Dover 12.00 2 NABORS Rig Crew 12.50 25 BOP Stack&Components Description Start Date Last Certification Date Pressure Rating(psi) Type Make Model ID Nom(in) P Range(psi) Last Cert Date Slow Circulation Rates Pump Number: Make: Model: Start Date End Date Liner Size(in) Volume Per Stroke Override(bbl/stk) Max Pressure(psi) Date Depth(ftKB) Slow Spd Strokes(spm) P(psi) Eff(14) Q Flow(gpm) Daily Bulk Supply Item Description: EQUIPMENT FUEL Unit Label:Gallons Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/26/2016 307.0 307.0 6,088.0 6,088.0 0.0 0.0 Supply Item Description: NAD 245E Diesel Fuel Unit Label:gal us Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/26/2016 1,264.0 0.0 10,834.0 26,374.0 0.0 15,540.0 Supply Item Description: NAD 245E Rig Water Unit Label:bbl Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Corn On Loc Note 10/26/2016 8.0 130.0 498.0 880.0 0.0 382.0 Last Authority Visit Date Tot insp.Nbr Total I.N.C.number Comment STOP Cards Submitted Company #Rpts Com NABORS ALASKA DRILLING 40 PJSM NABORS ALASKA DRILLING 22 STOP Cards General Notes Comment: 41,Well Name: OP22-WW03 likaily Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 1012712016 • Report#: 14 2 fl Job: WORKOVER Page:1 of 2 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Ground Level(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 0.00 16.38 36.62 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date NABORS 245 NABORS ALASKA LAND RIG 0637 10/14/2016 Daily Information Weather Temperature(°F) Wind Days LTI(days) Days RI(days) FOB Partly Cloudy 13.4 S @ 8 MPH 37.0 Cost Summary Job Account Currency Code Total AFE Amount(Cost) Daily Cost(Cost) Cumulative Cost(Cost) Daily Mud Field Est(Cost) Cumulative mud Cost(Cost) 7683 USD 5,049,784 63,211 777,943 1,150 4.600 Safety Incidents-Near Miss Date Category Type Subtype Severity Cause Lost time? 10/27/2016 Non-Recordable Unsafe Condition Other Minor No Comment LIC-Board on the pad with nail protruding-Nabors Drilling Date Category Type Subtype Severity Cause Lost time? 10/27/2016 Non-Recordable Near Miss Other Minor No Comment NM/SWA Employee intervenes to assist co-worker-Nabors Drilling Date Category Type Subtype Severity Cause Lost time? 10/27/2016 Non-Recordable Unsafe Condition Other Minor No Comment UC-Welding leads in the walkway-Nabors Drilling Safety Drills Days Until Next Check Type #Occur Last Date Next Date (days) Fire Drill 11 10/26/2016 11/9/2016 13 Man Down Drill 1 10/21/2016 1/19/2017 84 Rig Inspection 14 10/27/2016 10/28/2016 1 Safety Meeting 14 10/27/2016 10/28/2016 1 Spill Drill 9 10/27/2016 11/10/2016 14 Casings seat Cas.Type OD(in) ID(in) - Grade Top(RKB) Bottom(RKB) TVD Bot.(RKB) Run Date CASING 13 3/8 12.42 L-80 -0.8 4,020.0 3,727.6 7/12/2013 CASING 9 5/8 8.84 L-80 0.1 7,631.0 6,526.8 7/29/2013 LINER 7 6.18 L-80 7,396.8 10,668.0 9,513.5 8/5/2013 Last Cementing Cementing Start Date: 8/6/2013 String:LINER,10,668.0ftKB Comment: Stg# Top(RKB) Top Meas Meth Btm(ftKB) Com 1 7,396.0 Volume Calculations 10,658.0 Job Information Job Phase Planned Start Date Start Date End Date P50 Duration(days) P50 Cost(Cost) WORKOVER 10/14/2016 00.00 10/14/2016 12:00 0.00 0 Daily Summary Operations 24h Forecast Well work on paper safety meeting. 24h Summary PJSA Cut and slip 77'of drill line.Check crown-o-matic.Test upper and lower IBOP valves.Build new bracket for rig floor camera.Grease choke manifold.House keeping. Function test cellar pump.Blow down test pump and mud lines.Spot tiger tank and complete berming.Take on 290 bbls of 9.9 ppg brine to Raw mud.PJSM,Cont.housekeeping&rig maintenance,take 290 bbls 9.9#brine to raw mud pits,calibrate blocks,set crown saver,function test TAC-2 system(good),clean and grease plug valves,PT mud manifold and line to 3,500 psi,check backup nitrogen on koomy 2,175 psi average.PJSM,Cont.painting and rig maintenance,Hang camera for skate operator,off load 2nd load of 9.9#brine to pits,B/D rig water&steam,shut in and turn off boilers,turn off lights and shut do motors. Operation at 07.00 Well work on paper safety meeting. Time Log Start End Cum Dur End Depth Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. (RKB) 00:00 06:00 6.00 6.00 MOB A 12 P PJSM Cut and slip 77'of drill line.Check crown-o-matic.Test upper and lower IBOP valves.House keeping. 06:00 12:00 ' 6.00 12.00 MOB A 20 P PJSA Build new bracket for rig floor camera.Grease choke manifold.House keeping. Function test cellar pump.Blow down test pump and mud lines.Spot tiger tank and complete berming.Take on 290 bbls of 9.9 ppg brine to Raw mud. 12:00 18:00 6.00 18.00 MOB A 20 P PJSM,Cont.housekeeping&rig maintenance,take 290 bbls 9.9#brine to raw mud pits,calibrate blocks,set crown saver,function test TAC-2 system(good),clean and grease plug valves,PT mud manifold and line to 3,500 psi,check backup nitrogen on koomy 2,175 psi average. 18:00 00:00 6.00 24.00 MOB A 20 P PJSM,Cont.painting and rig maintenance,Hang camera for skate operator,off load 2nd load of 9.9#brine to pits,B/D rig water&steam,shut in and turn off boilers,turn off lights and shut do motors. Gas Readings Avg Background Gas(%) Max Background Gas(%) Avg Connection Gas(%) Max Connection Gas(%) Avg Drill Gas(%) Max Drill Gas(%) Avg Trip Gas(%) Max Trip Gas(%) Cumulative Mud Volumes Active Volume(bbl) Hole Volume(bbl) Losses(bbl) Cum Additions(bbl) Additions(bbl) Cum Losses(bbl) Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Bruno Ravagli ENI Superintendent Eni representative Oliver Amend ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 • Eni representative .Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Mitch Billington ENI Rig Clerk 907-685-0722 Eni representative Paul Holley ENI HSE Tool Push Kelly Cozby Nabors Alaska Drilling Tool Pusher Tool Push Wesley Jeardoe Nabors Alaska Drilling Tool Pusher Well Name: OP22-WW03• •aily Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 10/27/2016 14 Job: WORKOVER PaPage:2 2 of 2 Personnel Log(POB) Company Serv.Type Work H(hr) Stand-by H(hr) Count Note ENI Drilling Superintendent 12.00 1 Solsten HSE 12.00 1 Solsten Clerk 12.00 1 MI Swaco Mud Engineer 12.00 1 Vetco Wellhead 12.00 1 Solsten Drilling Supervisor 12.00 2 Baker Centrilift ESP 12.00 2 CH2M Truck Driver 12.00 4 NABORS Rig Crew 12.50 24 BOP Stack 8 Components Description Start Date Last Certification Date Pressure Rating(psi) Type Make Model ID Nom(in) P Range(psi) Last Cert Date Slow Circulation Rates Pump Number: Make: Model: Start Date End Date Liner Size(in) Volume Per Stroke Override(bbl/stk) Max Pressure(psi) Date Depth(ftKB) Slow Spd Strokes(spm) P(psi) Eff(%( Q Flow(gpm) Daily Bulk Supply Item Description: EQUIPMENT FUEL Unit Label:Gallons Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/27/2016 198.0 198.0 6,286.0 6,286.0 0.0 0.0 Supply Item Description: NAD 245E Diesel Fuel Unit Label:gal us Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/27/2016 1,344.0 0.0 12,178.0 26,374.0 0.0 14,196.0 Supply Item Description: NAD 245E Rig Water Unit Label: bbl Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/27/2016 143.0 0.0 641.0 880.0 0.0 239.0 Last Authority Visit Date Tot insp.Nbr Total I.N.C.number Comment STOP Cards Submitted Company #Rpts Com NABORS ALASKA DRILLING 14 STOP Cards NABORS ALASKA DRILLING 27 PJSM General Notes Comment: Iiii* Well Name: OP22-WW03I wily Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 10128/2016 • Report#: 15 2 n IIn Job: WORKOVER Page:1 of 2 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Ground Level(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 0.00 16.38 36.62 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date NABORS 245 NABORS ALASKA LAND RIG 0637 10/14/2016 Daily Information Weather Temperature(°F) Wind Days LTI(days) Days RI(days) POB Overcast/Fog 16.5 E @ 11 MPH 43.0 Cost Summary Job Account Currency Code Total AFE Amount(Cost) Daily Cost(Cost) Cumulative Cost(Cost) Daily Mud Field Est(Cost) Cumulative mud Cost(Cost) 7683 USD 5,049,784 94,461 872.404 32,100 36,700 Safety Incidents-Near Miss Date Category Type Subtype Severity Cause Lost time? 10/28/2016 No Comment NO INCIDENTS REPORTED Safety Drills Days Until Next Check Type 8 Occur Last Date Next Date _ (days) Fire Drill 11 10/26/2016 11/9/2016 12 Man Down Drill 1 10/21/2016 1/19/2017 83 Rig Inspection 15 10/28/2016 10/29/2016 1 Safety Meeting 15 10/28/2016 10/29/2016 1 Spill Drill 9 10/27/2016 11/10/2016 13 Casings seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(RKB) TVD Bot.(ftKB) Run Date CASING 133/8 12.42 - L-80 -0.8 4,020.0 3,727.6 7/12/2013 CASING 9 5/8 8.84 L-80 0.1 7,631.0 6,526.8 7/29/2013 LINER 7 6.18 L-80 7,396.8 10,668.0 9,513.5 8/5/2013 Last Cementing Cementing Start Date: 8/6/2013 String:LINER,10,668.011KB Comment: Stg 8 Top(RKB) Top Meas Meth Btm(ftKB) Com 1 7,396.0 Volume Calculations 10,658.0 Job Information Job Phase Planned Start Date Start Date End Date P50 Duration(days) P50 Cost(Cost) ^, WORKOVER 10/14/2016 00:00 10/14/2016 12:00 0.00 0 { Daily Summary Operations A,--1- 24h Forecast Accept rig 10/29/2016 00:00,Start rig motors,boilers,heaters and turn lights on rig,start rigging up for well kill operations.PT lines,kill well pumping down tubing,monitor well,see if static.pressure up IA and shear valve,R/U pump down tubing taking taking diesel returns from IA to tiger tank,monitor well.rig up Halliburton wireline to change shear valve to dummy valve.R/D wireline. 24h Summary Well work on paper safety meeting with drilling crews, service company hands,Eni drilling superintendent,Eni HSE's,NAD HSE's,NAD superintendent. Operation at 07.00 Rigging up to kill well Time Log Start End Cum Dur End Depth Time Time Dur(hr) (hr) Phase Opr. _ Act. Plan Oper.Descr. (RKB) 00:00 00:00 24,00 24.00 MOB A 1 P Well work on paper safety meeting with drilling crews, service company hands,Eni drilling superintendent,Eni HSE's,NAD HSE's,NAD superintendent. Gas Readings Avg Background Gas(% Max Background Gas(%) Avg Connection Gas(%) Max Connection Gas(%) Avg Drill Gas(%) Max Drill Gas(%) Avg Trip Gas(%) 'Max Trip Gas(%) Cumulative Mud Volumes Active Volume(bbl) Hole Volume(bbl) Losses(bbl) Cum Additions(bbl) Additions(bbl) Cum Losses(bbl) Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Bruno Ravagli ENI Superintendent Eni representative Oliver Amend ENI Drilling Supv. SIDDrilling@enipetroleum.corn 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Mitch Billington ENI Rig Clerk 907-685-0722 Eni representative Troy England ENI HSE Eni representative Paul Holley ENI HSE Tool Push Kelly Cozby Nabors Alaska Drilling Tool Pusher Tool Push Wesley Jeardoe Nabors Alaska Drilling Tool Pusher Personnel Log(POB) Company Serv.Type Work H(hr) _ Stand-by H(hr) Count Note ENI Drilling Superintendent 12.00 1 Solsten Clerk 12.00 1 MI Swaco Mud Engineer 12.00 1 Vetco Wellhead 12.00 1 Solsten Drilling Supervisor 12.00 2 Solsten HSE 12.00 2 HALLIBURTON Slickline 12.00 3 CH2M Truck Driver 12.00 4 Baker Centrilift ESP 12.00 4 NABORS Rig Crew 12.50 24 BOP Stack&Components Description Start Date Last Certification Date Pressure Rating(psi) Well Name: OP22-WW03S •aily Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 10/28/2016 15 Job: WORKOVER Pa #: Pagee:: 2 2 of 2 Type Make Model ID Nom(in) P Range(psi) Last Cert Date Slow Circulation Rates Pump Number: Make: Model: Start Date End Date Liner Size(in) ' Volume Per Stroke Override(bbl/stk) Max Pressure(psi) Date Depth(RKB) Slow Spd Strokes(spm) P(psi) Eff(%) Q Flow(gpm) Daily Bulk Supply Item Description: EQUIPMENT FUEL Unit Label:Gallons Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/28/2016 515.0 515.0 6,801.0 6,801.0 0.0 0.0 Supply Item Description: NAD 245E Diesel Fuel Unit Label:gal us Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/28/2016 0.0 0.0 12,178.0 26,374.0 0.0 14,196.0 Supply Item Description: NAD 245E Rig Water Unit Label:bbl Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/28/2016 0.0 641.0 880.0 0.0 239.0 Last Authority Visit Date Tot insp.Nbr Total I.N.C.number Comment STOP Cards Submitted Company #Rpts Com NABORS ALASKA DRILLING STOP Cards NABORS ALASKA DRILLING PJSM General Notes Comment: • • Well Name: OP22-WW03 DIR Daily Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 10/29/2016 Report#: 16 �• Job: WORKOVER e II Page:1 of 2 Well Header Permit/Concession N° Operator ' -- Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Ground Level(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 0.00 16.38 36.62 • Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date NABORS 245 NABORS ALASKA LAND RIG 0637 10/14/2016 Daily Information Weather Temperature(°F) Wind Days LTI(days) Days RI(days) ROB Overcast 28.9 E @ 22 MPH 41.0 Cost Summary Job Account Currency Code Total AFE Amount(Cost) Daily Cost(Cost) Cumulative Cost(Cost) Daily Mud Field Est(Cost) Cumulative mud Cost(Cost) 7683 USD 5,049,784 98,123 970,527 1,150 37,850 Safety Incidents-Near Miss Date Category Type Subtype Severity Cause Lost time? 10/29/2016 Non-Recordable Unsafe Condition Other Minor No Comment UC-Ice on walking surface in pipe shed(Nabors) Date Category Type Subtype Severity Cause Lost time? 10/29/2016 Non-Recordable Unsafe Condition Other Minor No Comment UC-Defective Portable Ladder(Nabors) Safety Drills Days Until Next Check Type 8 Occur Last Date Next Date (days) Fire Drill 11 10/26/2016 11/9/2016 11 Man Down Drill 1 10/21/2016 1/19/2017 82 Rig Inspection 16 10/29/2016 10/30/2016 1 Safety Meeting 16 10/29/2016 10/30/2016 1 Spill Drill 10 10/29/2016 11/12/2016 14 Casings seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(RKB) TVD Bot.(RKB) Run Date CASING 13 3/8 12.42 1-80 -0.8 4,020.0 3,727.6 7/12/2013 CASING 9 5/8 8.84 L-80 0.1 7,631.0 6,526.8 7/29/2013 LINER 7 6.18 L-80 7,396.8 10,668.0 9,513.5 8/5/2013 Last Cementing Cementing Start Date: 8/6/2013 String:LINER,10,668.0ftKB Comment: Stg 8 Top(RKB) Top Meas Meth Btm(RKB) Com 1 7,396.0 Volume Calculations 10,658.0 Job Information Job Phase Planned Start Date Start Date End Date P50 Duration(days) P50 Cost(Cost) WORKOVER 10/14/2016 00:00 10/14/2016 12:00 0.00 0 Daily Summary Operations 24h Forecast P/U slickline tools,PT lub and lines,RIH set catcher,POOH,RIH pull shear valve,POOH,R/U to displace IA with brine taking diesel returns to tiger tank.Slickline RIH with dummy valve and set,test back side to insure valve set.POOH,RIH and pull catcher.R/D Halliburton.Insure well is dead install BPV,nipple down tree and nipple up BOPE,Test BOPE 24h Summary Rig Accepted @ 00:00 10/29/2016,PJSM,Start generators and boilers,power up lights,steam,water,ect.Obtain permits from DSO,R/U HP hoses and manifold from kill line to tree and out to tiger tank,Attempt ` to PT all lines from rig to flow back tank with air,encounter and repair leaks.PT all HP lines to 3,000 psi(good),test line to flow back tank to 1,000 psi.(good)PJSM for bullheading operations,obtain permit from DSO,clean well bay,label circ.manifold.review JSA for bullheading.PJSM,secure well walk all lines&check equip.open well 400 psi on tubing,pump 210 bbls 9.5 PPG brine @ 4 BPM,ICP 700 psi,FICP 420 psi,shut down monitor well 15 min.-10 psi PJSM,R/U to pump down IA,pumped down IA in attempt to shear GLM valve 4X max psi 2514.valve didn't shear.Bleed off pressure.Halliburton slick on location,spot trucks,PJSM with all involved.Begin R/U Halliburton slickline,P/U tools up slide,M/U lubricator and wireline valve,pull tree cap. Operation at 07.00 Pulling Shear Valve W/slickline Time Log Start End Cum Dur End Depth Time Time Dur(hr) (hr) Phase Opr. Act. Plan _ Oper.Descr. (ftKB) 00:00 02:00 2.00 2.00 W.O. A 20 P Rig Accepted @ 00:00 10/29/2016,PJSM,Start generators and boilers,power up lights,steam,water,eel. 02:00 08:00 6.00 8.00 W.O. A 20 P Obtain permits from DSO,R/U HP hoses and manifold from kill line to tree and out to tiger tank 08:00 11:15 ' 3.25 11.25 W.O. ' A 1 P Attempt to PT all lines from rig to flow back tank with air,encounter and repair leaks.PT all HP lines to 3,000 psi(good),test line to flow back tank to 1,000 psi.(good) 11:15 12:00 ' 0.75 12.00 W.O. M I P 'PJSM for bullheading operations,obtain permit from DSO,clean well bay,label sirs,manifold.review JSA for bullheading. 12:00 13:30 1.50 13.50 ' W.O. M 9 P PJSM,secure well walk all lines&check equip.open well 400 psi on tubing,pump 210 bbls 9.5 PPG brine @ 4 BPM,ICP 700 psi,FICP 420 psi,shut down monitor well 15 min.-10 psi 13:30 16:30 3.00 16.50 W.O. M 9 P PJSM,R/U to pump down IA,pumped down IA in attempt to shear GLM valve 4X max psi 2514.valve didn't shear.Bleed off pressure. 16:30 18:00 ' 1.50 18.00 W.O. R I - P 'Halliburton slick on location,spot trucks,PJSM with all involved. 18:00 00:00 6.00 24.00 W.O. R 5 P Begin R/U Halliburton slickline,P/U tools up slide,M/U lubricator and wireline valve,pull tree cap. Gas Readings Avg Background Gas(%) Max Background Gas)%) Avg Connection Gas(%) Max Connection Gas(%) Avg Drill Gas(%) Max Drill Gas(%( Avg Trip Gas(%) Max Trip Gas WO Cumulative Mud Volumes Active Volume(bbl) Hole Volume(bbl) Losses(bbl) Cum Additions(bbl) Additions(bbl) Cum Losses(bbl) Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Oliver Amend 'ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Mitch Billington ENI Rig Clerk 907-685-0722 Eni representative Troy England ENI HSE Tool Push Kelly Cozby Nabors Alaska Drilling Tool Pusher Tool Push Wesley Jeardoe Nabors Alaska Drilling Tool Pusher • • Well Name: OP22-WW03 DIR Daily Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 10/29/2016 16 Job: WORKOVER PaPage:ge:2 2 of 2 Personnel Log(POB) Company Serv.Type Work H(hr) Stand-by H(hr) Count Note Beacon HSE 12.00 1 Solsten Clerk 12.00 1 MI Swaco Mud Engineer 12.00 1 Vetco Wellhead 12.00 1 Solsten Drilling Supervisor 12.00 2 HALLIBURTON Slickline 12.00 3 CH2M Truck Driver 12.00 4 Baker Centrilift ESP 12.00 4 NABORS Rig Crew 12.50 24 BOP Stack&Components Description Start Date Last Certification Date Pressure Rating(psi) Type Make Model ID Nom(in) P Range(psi) Last Cert Date Slow Circulation Rates Pump Number: Make: Model: Start Date End Date Liner Size(in) Volume Per Stroke Override(bbllstk) Max Pressure(psi) Date Depth(ftKB) Slow Spd Strokes(spm) P(psi) Eff(%( 0 Flow(gpm) Daily Bulk Supply Item Description: EQUIPMENT FUEL Unit Label: Gallons Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/29/2016 6,801.0 6,801.0 0.0 0.0 Supply Item Description: NAD 245E Diesel Fuel Unit Label:gal us Unit Size: Note: Date Consumed Received •Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/29/2016 1,680.0 0.0 13,858.0 26,374.0 0.0 12,516.0 Supply Item Description: NAD 245E Rig Water Unit Label:bbl Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Corn Returned Cum On Loc Note 10/29/2016 76.0 130.0 717.0 1,010.0 0.0 293.0 Last Authority Visit Date Tot insp.Nbr Total I.N.C.number Comment STOP Cards Submitted Company #Rpts Com NABORS ALASKA DRILLING 17 STOP Cards NABORS ALASKA DRILLING 42 PJSM General Notes Comment: • • Well Name: OP22-WW03 DIR Daily Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 10130/2016 • Report#: 17 2 n II Job: WORKOVER Page:1 of 2 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Ground Level(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 0.00 16.38 36.62 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date NABORS 245 NABORS ALASKA LAND RIG 0637 10/14/2016 Daily Information Weather Temperature(°F) Wind Days LTI(days) Days RI(days) POB Overcast 29.4 E @ 23 MPH 42.0 Cost Summary Job Account Currency Code Total AFE Amount(Cost) Daily Cost(Cost) Cumulative Cost(Cost) Daily Mud Field Est(Cost) Cumulative mud Cost(Cost) 7683 USD 5,049,784 112,289 1,082,816 20,264 58,114 Safety Incidents-Near Miss Date Category Type Subtype Severity Cause Lost time? 10/30/2016 Non-Recordable Unsafe Condition Other Minor No Comment UC-Material on pallet not properly banded(Nabors) Date Category Type Subtype Severity Cause Lost time? 10/30/2016 Non-Recordable Unsafe Condition Other Minor No Comment UC-Extension cord trip hazard(Nabors) Safety Drills Days Until Next Check Type #Occur Last Date Next Date (days) Fire Drill 12 10/30/2016 11/13/2016 14 Man Down Drill 1 10/21/2016 1/19/2017 81 Rig Inspection 17 10/30/2016 10/31/2016 1 Safety Meeting 17 10/30/2016 10/31/2016 1 Spill Drill 11 10/30/2016 11/13/2016 14 Casings seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) TVD Bot.(ftKB) Run Date CASING 133/8 12.42 L-80 -0.8 4,020.0 3,727.6 7/12/2013 CASING 9 5/8 8.84 L-80 0.1 7,631.0 6.526.8 7/29/2013 LINER 7 6.18 L-80 7,396.8 10,668.0 9,513.5 8/5/2013 Last Cementing Cementing Start Date: 8/6/2013 String:LINER,10,668.0ftKB Comment: Stg# Top(RKB) Top Meas Meth Btm(ftKB) Com 1 7,396.0 Volume Calculations 10,658.0 Job Information Job Phase Planned Start Date Start Date End Date P50 Duration(days) P50 Cost(Cost) WORKOVER 10/14/201600:00 10/14/2016 12:00 0.00 0 Daily Summary Operations 24h Forecast N/U Hi Pressure riser and test.N/U BOPE and ready for testing.Test BOPE as per AOGCC specs.Guy Cook is to witness. 24h Summary PJSM,M/U Lubricator to tree,PT lub W/LRS to 2,500 psi.bleed off,pump dn tubing W/rig pump,pumped 20 bbls @ 3 BPM 150 psi,shut down pump, tbg psi 0.,RIH with slickline to set catcher,break off lubricator,re-rig on rig floor,hang sheave in blocks,put lubricator on tugger,C/O tools,PT lubricator.RIH to pull SOV in GLM @ 2,215'MD,pull valve,POOH,break off lubricator,C/O tools to run dummy valve, M/U&PT lubricator.Secure well,PJSM,pump 9.5 PPG brine down thg taking returns to tiger tank pumped 212 bbls brine 142 bbls return to tiger tank.shut dn,shut in and monitor tubing and IA.Initial SIP=0 psi. Monitor 15 min.IA and TBG 0 psi.PJSM,Blow down kill line,tiger tank line and manifold,PT lubricator with LRS.RIH&set dummy valve in GLM,PT valve to 500 psi W/LRS,POOH,HES hands timed out,HES crew rest.PJSM,R/D circulating lines and manifold.Transfer brine from raw mud to pits.Prep pipe shed to load spare jnts of tubing,dress dog collar and collar slips to 7 5/8 ESP shroud.PJSM,cont cleaning out sumps in cellar prep for inspection,B.C.L.spot spooling unit.PJSM w/Halliburton,LRS,rig crew,PT lubricator to 2500 psi,bleed off LRS.TBG-6 psi,ANN 420 psi,open swab RIH W/GS pulling tool and retrieve slip stop,POOH.PJSM,R/D Halliburton lubricator and tools.PJSM,NU/ND tree set BPV,remove scaffolding from around tree,Vetco rep begin N/D tree,set tree in cellar.Vetco rep inspect and prepare hanger and false bowl for removal,false bowl inspection was good,prep to P/U riser. Operation at 07.00 Nippling up BOPE Time Log Start End Cum Dur End Depth Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. (RKB) ' 00:00 01:30 1.50 1.50 W.O. R 1 P 'PJSM,M/U Lubricator to tree,PT lub W/LRS to 2,500 psi.bleed off,pump do tubing W/rig pump,pumped 20 bbls @ 3 BPM 150 psi,shut down pump, tbg psi 0. 01:30 03:30 2.00 3.50 ' W.O. R 4 P 'RIH with slickline to set catcher,break off lubricator,re-rig on rig Floor,hang sheave in blocks,put lubricator on tugger,C/O tools,PT lubricator. 03:30 04:30 1.00 4.50 W.O. R 4 P RIH to pull SOV in GLM @ 2,215'MD,pull valve.POOH,break off lubricator,CIO tools to run dummy valve, M/U&PT lubricator. 04:30 06:30 2.00 6.50 W.O. M 9 P Secure well,PJSM,pump 9.5 PPG brine down tbg taking returns to tiger tank pumped 212 bbls brine 142 bbls retum to tiger tank.shut dn,shut in and monitor tubing and IA.Initial SIP=0 psi.Monitor 15 min.IA and TBG 0 psi. 06:30 07:00 0.50 7.00 W.O. M 1 P 'PJSM,Blow down kill line,tiger tank line and manifold,PT lubricator with LRS. 07:00 08:30 1.50 8.50 W.O. R 4 P 'RIH&set dummy valve in GLM,PT valve to 500 psi W/LRS,POOH,HES hands timed out,HES crew rest. 08:30 12:00 3.50 12.00 W.O. L 20 P PJSM,R/D circulating lines and manifold.Transfer brine from raw mud to pits.Prep pipe shed to load spare jots of tubing,dress dog collar and collar slips to 7 5/8 ESP shroud. 12:00 15:00 3.00 15.00 W.O. L 20 P PJSM,cont cleaning out sumps in cellar prep for inspection,B.C.L.spot spooling unit. 15:00 16:30 1.50 16.50 W.O. M 20 P PJSM w/Halliburton,LRS,rig crew,PT lubricator to 2500 psi,bleed off LRS. 16:30 17:00 0.50 17.00 W.O. R 4 P TBG-6 psi,ANN 420 psi,open swab RIH W/GS pulling tool and retrieve slip stop,POOH 17:00 1930 2.50 19.50 W.O. A 5 P PJSM,R/D Halliburton lubricator and tools. 19:30 21:30 2.00 21.50 W.O. L 20 P PJSM,NU/ND tree set BPV,remove scaffolding from around tree,Vetco rep begin N/D tree,set tree in cellar. 21:30 00:00 2.50 24.00 W.O. L 20 P Vetco rep inspect and prepare hanger and false bowl for removal,false bowl inspection was good.Prep to P/U riser Gas Readings Avg Background Gas(%) Max Background Gas(%) Avg Connection Gas(%) Max Connection Gas(%) Avg Drill Gas(%) 'Max Drill Gas(%) Avg Trip Gas(%) 'Max Trip Gas(%) Cumulative Mud Volumes Active Volume(bbl) Hole Volume(bbl) Losses(bbl) Cum Additions(bbl) Additions(bbl) Cum Losses(bbl) • • • • Well Name: OP22-WW03 DIR Daily Report Wellbore Name: OP22-WW03 Date: 10/30/2016 Well Code: 27295 Job: WORKOVER Report#: Paage:ge: 212 of 2 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative 'Oliver Amend ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Mitch Billington ENI Rig Clerk 907-685-0722 Eni representative Troy England ENI HSE • Tool Push Kelly Cozby Nabors Alaska Drilling Tool Pusher Tool Push Wesley Jeardoe Nabors Alaska Drilling Tool Pusher Personnel Log(POB) Company Serv.Type Work H(hr) Stand-by H(hr) Count Note Beacon HSE 12.00 1 Solsten Clerk 12.00 1 MI Swaco Mud Engineer 12.00 1 Vetco Wellhead 12.00 1 SLB SCSSV Tech 12.00 1 Solsten Drilling Supervisor 12.00 2 HALLIBURTON Slickline 12.00 3 CH2M Truck Driver 12.00 4 Baker Cenirilift ESP 12.00 4 NABORS Rig Crew 12.50 24 I BOP Stack&Components Description Start Date Last Certification Date Pressure Rating(psi) Type Make Model ID Nom(in) P Range(psi) Last Cert Date Slow Circulation Rates Pump Number: Make: Model: Start Date End Date Liner Size(in) Volume Per Stroke Override(bbl/stk) Max Pressure(psi) Date Depth(ftKB) Slow Spd Strokes(spm) P(psi) Eff)%) Q Flow(gpm) Daily Bulk Supply Item Description: EQUIPMENT FUEL Unit Label:Gallons Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/30/2016 1,147.0 1,147.0 7,948.0 7,948.0 0.0 0.0 Supply Item Description: NAD 245E Diesel Fuel Unit Label:gal us Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/30/2016 1,195.0 15,936.0 15,053.0 42,310,0 0,0 27,257.0 Supply Item Description: NAD 245E Rig Water Unit Label:bbl Unit Size: Note: Date Consumed Received Returned •Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/30/2016 95.0 260.0 812.0 1,270.0 0.0 458.0 Last Authority Visit Date Tot insp.Nbr Total I.N.C.number Comment STOP Cards Submitted Company #Rpts Com NABORS ALASKA DRILLING 16 STOP Cards NABORS ALASKA DRILLING 44 PJSM General Notes Comment: • • • • • Well Name: OP22-WW03 DIR Daily Report Wellbore Name: OP22-WW03 Well Code: 27295• Date: 10/31/2016 211 11 Job: WORKOVER Report#: 18 Page:1 of 2 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Ground Level(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) • 53.00 0.00 16.38 36.62 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date NABORS 245 NABORS ALASKA LAND RIG 0637 10/14/2016 Daily Information Weather Temperature(°F) Wind Days LTI(days) Days RI(days) POB Clear/Fog 18.5 NE @ 11 MPH 43.0 Cost Summary Job Account Currency Code Total AFE Amount(Cost) Daily Cost(Cost) Cumulative Cost(Cost) Daily Mud Field Est(Cost) Cumulative mud Cost(Cost) 7683 USD 5,049,784 83,455 1,166,270 1,150 59,264 Safety Incidents-Near Miss Date Category Type Subtype Severity Cause Lost time? 10/31/2016 No Comment NO INCIDENTS REPORTED Safety Drills Days Until Next Check Type #Occur Last Date Next Date (days) Authority Visit 1 10/31/2016 11/7/2016 7 Fire Drill 14 10/31/2016 11/14/2016 14 Man Down Drill 1 10/21/2016 1/19/2017 80 Rig Inspection 18 10/31/2016 11/1/2016 1 Safety Meeting 18 10/31/2016 11/1/2016 1 Spill Drill 11 10/30/2016 11/13/2016 13 Casings seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(RKB( TVD Bot.(ftKB) Run Date CASING 133/8 12.42 L-80 -0.8 4,020.0 3,727.6 7/12/2013 CASING 9 5/8 8.84 L-80 0.1 7,631.0 6,526.8 7/29/2013 LINER 7 6.18 L-80 7,396.8 10,668.0 9,513.5 8/5/2013 Last Cementing Cementing Start Date: 8/6/2013 String:LINER,10,668.0f1KB Comment: Stg# Top(RKB) Top Meas Meth Btm(ftKB) Com 1 7,396.0 Volume Calculations 10,658.0 Job Information Job Phase Planned Start Date Start Date End Date P50 Duration(days) P50 Cost(Cost) WORKOVER 10/14/2016 00:00 10/14/2016 12:00 0.00 0 Daily Summary Operations 24h Forecast Finish N/U stack,do shell test,call state man,test BOPE,R/D test equipment.Pull test dart,R/U to pull ESP completion. 24h Summary '}`� 19 PJSM,Pull tree to rig floor,set stack on riser,hook up choke and kill lines,install bell nipple,hook up koomey lines.PJSM,install flow line,M/U dresser sleeve,energize koomey,function test BOPE,install catch 1ttt�/ // can.Hole fill and bleeder lines.Install mouse hole,Get RKB measurements.Bag=11.14',upper pipe rams=14.79',blind rams 16.78',lower pipe rams=21.18',ULDS 32.36',LLDS=35.18.Fill stack with water. �e� Install riser and flow line,secure katch kan and base of BOPS,hook up bleed line to tank,IA psi 600,bleed off.Fill choke manifold and purge out air.Attempt shell test,manual choke leaking,riser off the well head {� leaking.Vetco rep attempt to tighten grey lock.repair choke&test gas monitors witnessed by AOGCC Guy Cook.PJSM,Test BOP re-test,riser leaking,B/D test equipment R/D same.PJSM,N/D riser and spacer {{{{ spools,R/D katch kan,flow line,pull master bushing and bell nipple,LID mouse hole.Hook up bridge crane to stack.NU riser and spacer spools Vetco Rep loosen grey lock clamps,pick up stack,clean and inspect flange seal,install new VG seal,set stack down&tighten grey lock.N/U BOPS&prep to test riser seal,fill stack purge out air,test to 3500 psi 5 min.good. Operation at 07.00 Working on getting shell test. Time Log Start End Cum Dur End Depth Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. (ftKB) 00:00 06:00 6.00 6.00 ' W.O. C 5 P PJSM,Pull tree to rig floor,set stack on riser,hook up choke and kill lines,install bell nipple,hook up koomey lines. 06:00 12:00 6.00 12.00 ' W.O. C 5 P PJSM,install flow line,M/U dresser sleeve,energize koomey,function test BOPE,install catch can.Hole fill and bleeder lines.Install mouse hole,Get RKB measurements.Bag=11.14',upper pipe rams=14.79',blind rams 16.78',lower pipe rams=21.18',ULDS 32.36',LLDS=35.18.Fill stack with water. 12:00 15:30 3.50 15.50 W.O. C 5 P Install riser and flow line,secure katch kan and base of BOPS,hook up bleed line to tank,IA psi 600,bleed off. Fill choke manifold and purge out air. 15:30 16:30 1.00 16.50 W.O. ' C 12 P Attempt shell test,manual choke leaking,riser off the well head leaking.Vetco rep attempt to tighten grey lock. repair choke&test gas monitors witnessed by AOGCC Guy Cook. 16:30 20:00 3.50 20.00 W.O. C ' 12 P PJSM,Test BOP re-test,riser leaking,B/D test equipment R/D same. 20:00 21:00 1.00 21.00 W.O. C 5 P PJSM,N/D riser and spacer spools,R/D katch kan,flow line,pull master bushing and bell nipple,LID mouse hole.Hook up bridge crane to stack. 21:00 22:00 1.00 22.00 W.O. C 5 P NU riser and spacer spools Vetco Rep loosen grey lock clamps,pick up stack,clean and inspect flange seal, install new VG seal,set stack down&tighten grey lock. • 22:00 00:00 2.00 24.00 W.O. C 12 P N/U BOPS&prep to test riser seal,fill stack purge out air,test to 3500 psi 5 min.good. Gas Readings Avg Background Gas(%) Max Background Gas(%) Avg Connection Gas(%) Max Connection Gas(%) Avg Drill Gas(%( Max Drill Gas(%) Avg Trip Gas(%) Max Trip Gas(%) Cumulative Mud Volumes Active Volume(bbl) Hole Volume(bbl) Losses(bbl) Cum Additions)bbl) Additions(bbl) Cum Losses(bbl) Daily Contacts Position Contact Name Company Title Email _ Office Mobile Eni representative Oliver Amend ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Mitch Billington ENI Rig Clerk 907-685-0722 Eni representative Troy England ENI HOE Tool Push Kelly Cozby Nabors Alaska Drilling Tool Pusher Tool Push Wesley Jeardoe Nabors Alaska Drilling Tool Pusher • • Well Name: OP22-WW03 DIR Daily Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 10/31/2016 18 Job: WORKOVER Page: #: 2 Page:2 of 2 Personnel Log(POB) Company Serv.Type Work H(Er) Stand-by H(hr) Count Note Beacon HSE 12.00 1 Solsten Clerk 12.00 1 MI Swaco Mud Engineer 12.00 1 Vetco Wellhead 12.00 1 SLB SCSSV Tech 12.00 1 Quadco Calibrrate Test Equip 12.00 1 Solsten Drilling Supervisor 12.00 2 CH2M Truck Driver 12.00 4 Baker Centdlift ESP 12.00 4 NABORS Rig Crew 12.50 24 BOP Stack&Components Description Start Date Last Certification Date Pressure Rating(psi) Type Make Model ID Nom(in) P Range(psi) Last Cert Date Slow Circulation Rates Pump Number: Make: Model: Start Date End Date Liner Size(in) Volume Per Stroke Override(bbllstk) Max Pressure(psi) Date Depth(ftKB) Slow Spd Strokes(spm) P(psi) Eff(%( Q Flow(gpm) Daily Bulk Supply Item Description: EQUIPMENT FUEL Unit Label:Gallons Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/31/2016 342.0 342.0 8,290.0 8,290.0 0.0 0.0 Supply Item Description: NAD 245E Diesel Fuel Unit Label:gal us Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 10/31/2016 1,595.0 0.0 16,648.0 42,310.0 0.0 25,662.0 Supply Item Description: NAD 245E Rig Water Unit Label:bbl Unit Size: Note: Date Consumed Received Returned Cum Consumed •Cum Received Cum Returned Cum On Loc Note 10/31/2016 40.0 95.0 852.0 1,365.0 0.0 513.0 Last Authority Visit Date Tot insp.Nbr Total I.N.C.number Comment 10/31/2016 BOP Test AOGCC Guy Cook Came to witness BOP test,test failed,will return to retest. STOP Cards Submitted Company #Rpts Com NABORS ALASKA DRILLING 16 STOP Cards NABORS ALASKA DRILLING 36 PJSM General Notes Comment: Well Name: OP22-WW03• *ally Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 1111/2016 • Report#: 19 2n 0 Job: WORKOVER Page:1 of 2 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Ground Level(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 0.00 16.38 36.62 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date NABORS 245 NABORS ALASKA LAND RIG 0637 10/14/2016 Daily Information Weather Temperature(°F) Wind Days LTI(days) Days RI(days) POB Overcast/Fog 19.4 E @ 6 MPH 41.0 Cost Summary Job Account Currency Code Total AFE Amount(Cost) Daily Cost(Cost) Cumulative Cost(Cost) Daily Mud Field Est(Cost) Cumulative mud Cost(Cost) 7683 USD 5,049,784 87,469 1,253,739 11,210 70,474 Safety Incidents-Near Miss Date Category Type Subtype Severity Cause Lost time? 110/2016 No Comment NO INCIDENTS REPORTED Safety Drills Days Until Next Check Type #Occur Last Date Next Date (days) Authority Visit 2 110/2016 11/8/2016 7 Fire Drill 15 11/1/2016 11/15/2016 14 Man Down Drill 1 10/21/2016 1/19/2017 79 Rig Inspection 19 11/1/2016 11/2/2016 1 Safety Meeting 19 11/1/2016 11/2/2016 1 Spill Drill 12 11/1/2016 1105/2016 14 Casings seat Cas.Type OD(in) ID(in) Grade Top(EKE) Bottom(ftKB) TVD Bot.(RKB) Run Date CASING 133/8 12.42 L-80 -0.8 4,020.0 3,727.6 7/12/2013 CASING 95/8 8.84 L-80 0.1 7,631.0 6,526.8 7/29/2013 LINER 7 6.18 L-80 7,396.8 10,668.0 9,513.5 8/5/2013 Last Cementing Cementing Start Date: 8/6/2013 String:LINER,10,668.011KB Comment: Stg 6 Top(ftKB) Top Meas Meth Btm(ftKB) Com 1 7,396.0 Volume Calculations 10,658.0 Job Information Job Phase Planned Start Date Start Date End Date P50 Duration(days) P50 Cost(Cost) WORKOVER 10/14/2016 00:00 10/14/201612:00 0.00 0 Daily Summary Operations 24h Forecast Work on freeing hanger,could not free hanger W/false bowl attached,N/D stack at well head,remove false bowl plate,N/U stack,shell test stack,R/U to pull hanger without false bowl&4.5"completion string,pull hanger&4.5"completion string. 24h Summary PJSM,tighten choke and kill lines.tighten bell nipple,install katch kan,install mouse hole.Screw landing jnt into test dart 8 LH turns.Fill BOPS and choke with water.Shell test BOPS 250/2500 W/Annular,250/ 3500 W/rams.Prepare cellar and wellhead install curtain around katch kan.Ouadco calibrating gauges/WT indicator.Test BOPS,test all BOP components 250/3500 psi(annular 2500 psi)5 min.each.BOP Test witnessed by AOGCC Guy Cook.Koomey draw down start 3000 psi,closing 1800 psi,200 psi=32 sec.,final 159 sec.,no failures.Test PVT,trip tank G/L and flow paddle alarm.PJSM,Cont test PVT alarms,pull test dart.R/D B/D test equipment and choke manifold.P/U Sheaves from pipe shed,hook up primary and secondary slings,hang sheaves in derrick,rope run through both sheaves,hook up elephant trunk.PJSM with GBR hands.P/U tools from shed,start R/U GBR,finish katch kan around BOP stack.PJSM,with all hands,pull BPV,M/U landing joint,back out LDS.Attempt to pull hanger free,pull 275K working it up and down will not release,apply steam to well head in attempt to free hanger. Operation at 07.00 N/D BOPS to pull false bowl plate. Time Log Start End Cum Dur End Depth Time Time Dur(hr) (kr) Phase Opr. Act. Plan Oper.Descr. (EKE) 00:00 03:30 3.50 3.50 W.O. C 5 P PJSM,tighten choke and kill lines.tighten bell nipple,install katch kan,install mouse hole.Screw landing jnt into lest dart 8 LH turns. 03:30 04:30 1.00 4.50 W.O. C 12 P Fill BOPS and choke with water.Shell test BOPS 250/2500 W/Annular,250/3500 W/rams. 04:30 07:00 2.50 7.00 W.O. C 1 P Prepare cellar and wellhead install curtain around katch kan.Quadco calibrating gauges/WT indicator. 07:00 12:00 5.00 12.00 W.O. C 12 P Test BOPS,test all BOP components 250/3500 psi(annular 2500 psi)5 min.each.BOP Test witnessed by AOGCC Guy Cook.Koomey draw down start 3000 psi,closing 1800 psi,200 psi=32 sec.,final 159 sec.,no failures.Test PVT,trip tank G/L and flow paddle alarm. 12:00 12:30 ' 0.50 12.50 W.O. C 12 P PJSM,Cont test PVT alarms,pull test dart. 12:30 13:00 0.50 13.00 W.O. C 5 P R/D B/D test equipment and choke manifold. 13:00 17:30 4.50 17.50 W.O. L 1 P P/U Sheaves from pipe shed,hook up primary and secondary slings,hang sheaves in derrick,rope run through both sheaves,hook up elephant trunk. 17:30 20:30 3.00 20.50 W.O. L 1 P PJSM with GBR hands.P/U tools from shed,start R/U GBR,finish katch kan around BOP stack. 20:30 22:00 1.50 22.00 W.O. L 20 P PJSM,with all hands,pull BPV,M/U landing joint,back out LDS. 22:00 00:00 2.00 24.00 W.O. ' L 19 P Attempt to pull hanger free,pull 275K working it up and down will not release,apply steam to well head in attempt to free hanger. Gas Readings Avg Background Gas(%) Max Background Gas(%) Avg Connection Gas(%) Max Connection Gas(%) Avg Drill Gas(%) Max Drill Gas(%) Avg Trip Gas(%) Max Trip Gas(%) Cumulative Mud Volumes Active Volume(bbl) Hole Volume(bbl) Losses(bbl) Cum Additions(bbl) Additions(bbl) Cum Losses(bbl) Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Oliver Amend ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Mitch Billington ENI Rig Clerk 907-685-0722 Eni representative Troy England ENI HSE Tool Push Kelly Cozby Nabors Alaska Drilling Tool Pusher Tool Push Wesley Jeardoe Nabors Alaska Drilling Tool Pusher Well Name: OP22-WW03I •aily Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 1#: 1 Report#: 2016 19 Job: WORKOVER Page:2 of 2 Personnel Log(POB) Company Serv.Type Work H(hr) Stand-by H(hr) Count Note Beacon HSE 12.00 1 Solslen Clerk 12.00 1 MI Swaco Mud Engineer 12.00 1 Vetco Wellhead 12.00 1 SLB SCSSV Tech 12.00 1 Solsten Drilling Supervisor 12.00 2 GBR Casing hands 12.00 2 CH2M Truck Driver 12.00 4 Baker Centrilift ESP 12.00 4 NABORS Rig Crew 12.50 24 BOP Stack&Components Description Start Date Last Certification Date Pressure Rating(psi) 13 5/8 11/1/2016 5,000.0 Type Make Model ID Nom(in) P Range(psi) Last Cert Date Stack Hydril GK 135/8 5,000.0 8/20/2013 Upper rams Hydril 3 1/2 X 6"VBR 13 5/8 5,000.0 8/20/2013 Middle rams Hydril Blind Shears 13 5/8 5,000.0 8/20/2013 Lower rams Hydril 4 1/2 X 7"VBR 13 5/8 5,000.0 8/20/2013 Slow Circulation Rates Pump Number: Make: Model: Start Date End Date Liner Size(in) Volume Per Stroke Override(bbl/stk) Max Pressure(psi) Date Depth(ftKB) Slow Spd Strokes(spm) P(psi) Eff)%) Q Flow(gpm) Daily Bulk Supply Item Description: EQUIPMENT FUEL Unit Label:Gallons Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 11/1/2016 379.0 379.0 8,669.0 8,669.0 0.0 0.0 Supply Item Description: NAD 245E Diesel Fuel Unit Label:gal us Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 11/1/2016 1,512.0 0.0 18,160.0 42,310.0 0.0 24,150.0 Supply Item Description: NAD 245E Rig Water Unit Label:bbl Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 11/1/2016 46.0 0.0 898.0 1,365.0 0.0 467.0 Last Authority Visit Date Tot insp.Nbr Total I.N.C.number Comment 11/1/2016 BOP Test,AOGCC Guy Cook witnessed BOP Test,Next Test Due 11/8/2016 STOP Cards Submitted Company #Rpts Com NABORS ALASKA DRILLING 10 STOP Cards NABORS ALASKA DRILLING 37 PJSM General Notes Comment: Well Name: OP22-WW03• •aily Report Wellbore Name: OP22-WW03 11 Well Code: 27295 Date: #: 2 016 • Report#: 20 en II Job: WORKOVER Page:1 of 2 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Ground Level(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 0.00 16.38 36.62 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date NABORS 245 NABORS ALASKA LAND RIG 0637 10/14/2016 Daily Information Weather Temperature(°F) Wind Days LTI(days) Days RI(days) POB Overcast 25.3 E @ 42 MPH 40.0 Cost Summary Job Account Currency Code Total AFE Amount(Cost) Daily Cost(Cost) Cumulative Cost(Cost) Daily Mud Field Est(Cost) Cumulative mud Cost(Cost) 7683 USD 5,049,784 78,613 1,332,351 1.150 71,624 Safety Incidents-Near Miss Date Category Type Subtype Severity Cause Lost time? 11/2/2016 No Comment NO INCIDENTS REPORTED Safety Drills Days Until Next Check Type #Occur Last Date Next Date (days) Authority Visit 2 11/1/2016 11/8/2016 6 Fire Drill 15 11/1/2016 11/15/2016 13 Man Down Drill 1 10/21/2016 1/19/2017 78 Rig Inspection 20 11/2/2016 11/3/2016 1 Safety Meeting 20 11/2/2016 11/3/2016 1 Spill Drill 13 11/2/2016 11/16/2016 14 Casings seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) TVD Bot.(RKB) Run Date CASING 133/8 12.42 L-80 -0.8 4,020.0 3,727.6 7/12/2013 CASING 95/8 8.84 L-80 0.1 7,631.0 6,526.8 7/29/2013 LINER 7 6.18 L-80 7,396.8 10,668.0 9,513.5 8/5/2013 Last Cementing Cementing Start Date: 8/6/2013 String:LINER,10,668.0ftKB Comment: Stg# Top(ftKB) Top Meas Meth Btm(ftKB) Com 1 7,396.0 Volume Calculations 10,658.0 Job Information Job Phase Planned Start Date Start Date End Date P50 Duration(days) P50 Cost(Cost) WORKOVER 10/14/201600:00 10/14/201612:00 0.00 0 Daily Summary Operations 24With t 4 /1 POOH With 4.5"ESP completion string,lay down ESP components,clean and inspect 4 1/2"tubing,R/U to RIH W/new ESP 1(/ 1)49 24h Summary Attempting to pull hanger/false bowl free,pulling 270K,Steam wellhead,work several times no progress lift wellhead up ea.time we pick up.Secure well pull landing jot,set BPV RILDS on hanger.Nipple down �� BOPS,remove false bowl pulling plate.Vetco rep test seals on surface casing to 2000 psi and intermediate to 5000 psi.Good test.N/U BOPS Tighten riser connection.Function test BOP components,fill stack, / close blinds and shell test lower riser flange.250/3500 psi 5 min.each,good test.Install riser and flow line,finish N/U BOPS,install flow line,bell nipple,turn buckles,katch kan.Pull test jot pull BPV screw V landing jot into hanger.PJSM,M/U landing jnt,pull bushings,BOLDS and pull hanger free @ 200K,up wt 160K,fill hole with 18 bbls.BCL 8 SLB hands terminate ESP cable and cap tubes.PJSM with all hands, UD hanger and landing jot to pipe shed.R/U GBR compensator,connect ESP cable and cap tubes to rope.Open SSSV,POOH UD VIT jots,Up wt 160K, R/D GBR compensator send to pipe shed,install air slips.Cont.POOH W/4.5"12.6 L-80 VT Tubing F/7,162'T/7,087',connect ESP and Cap tubes to spooling unit,Cont.POOH F/7,087'T/5,401'MD Operation at 07.00 POOH W/4 1/2"12.68 cr13 L-80 VT completion string @ 3,624'and Time Log Start End Cum Dur End Depth Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. (ftKB) 00:00 01:30 1.50 1.50 W.O. L 19 TS01 Attempting to pull hanger/false bowl free,pulling 270K,Steam wellhead,work several times no progress lift wellhead up ea.time we pick up. 01:30 02:00 0.50 2.00 W.O. C 20 TS01 Secure well pull landing jot,set BPV RILDS on hanger 02:00 05:00 3.00 5.00 W.O. C 5 TS01 Nipple down BOPS,remove false bowl pulling plate.Vetco rep test seals on surface casing to 2000 psi and intermediate to 5000 psi.Good test. 05:00 06:00 1.00 6.00 W.O. C 5 TS01 N/U BOPS Tighten riser connection. 06:00 06:30 0.50 6.50 W.O. C 12 TS01 Function test BOP components,fill stack,close blinds and shell test lower riser flange.250/3500 psi 5 min. each,good test 06:30 11:00 4.50 11.00 W.O. C 5 TS01 Install riser and flow line,finish N/U BOPS,install flow line,bell nipple,turn buckles,katch kan. 11:00 12:00 1.00 12.00 W.O. C 5 TS01 Pull test jot put BPV screw landing jnt into hanger. 12:00 13:00 1.00 13.00 W.O. L 4 P PJSM,M/U landing jnt,pull bushings,BOLDS and pull hanger free @ 200K,up wt 160K,fill hole with 18 bbls. 13:00 14:00 1.00 14.00 W.O. L 20 P BCL 8 SLB hands terminate ESP cable and cap tubes. 14:00 15:30 1.50 15.50 W.O. L 4 P PJSM with all hands,UD hanger and landing jnt to pipe shed. 15:30 16:30 1.00 16.50 W.O. L 20 P R/U GBR compensator,connect ESP cable and cap tubes to rope. 16:30 18:00 1.50 18.00 W.O. L 4 P Open SSSV,POOH UD VIT jnts,Up wt 160K, 18:00 19:00 1.00 19.00 W.O. L 20 P R/D GBR compensator send to pipe shed,install air slips. 19:00 00:00 5.00 24.00 W.O. L 4 P Cont.POOH W/4.5"12.6 cr13 L-80 VT Tubing F/7,162'T/7,087',connect ESP and Cap tubes to spooling unit,Cont.POOH Fl 7,087'TI 5,401'MD Gas Readings Avg Background Gas(%( Max Background Gas(%) Avg Connection Gas(%) Max Connection Gas(%) Avg Drill Gas(%) Max Drill Gas)%) Avg Trip Gas(%) Max Trip Gas(%) Cumulative Mud Volumes Active Volume(bbl) Hole Volume(bbl) Losses(bbl) Cum Additions(bbl) Additions(bbl) Cum Losses(bbl) Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Bruce Simonson ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907685-0715 907-320-0058 Eni representative Mitch Billington ENI Rig Clerk 907-685-0722 Eni representative Troy England ENI HSE Well Name: OP22-WW03• laily Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 11/212016 Job: WORKOVER Page:2 20 o Page: of 2 Daily Contacts Position Contact Name Company Title Email Office Mobile Tool Push Kelly Cozby Nabors Alaska Drilling Tool Pusher Tool Push Wesley Jeardoe Nabors Alaska Drilling Tool Pusher Personnel Log(POB) Company Serv.Type Work H(hr) Stand-by H(hr) Count Note Beacon HSE 12.00 1 Solsten Clerk 12.00 1 MI Swaco Mud Engineer 12.00 1 Vetco Wellhead 12.00 1 SLB SCSSV Tech 12.00 1 Solsten Drilling Supervisor 12.00 2 GBR Casing hands 12.00 2 Baker Centrilift ESP 12.00 3 CH2M Truck Driver 12.00 4 NABORS Rig Crew 12.50 24 BOP Stack&Components Description Start Date Last Certification Date Pressure Rating(psi) 135/8 11/1/2016 8/20/2016 5,000.0 Type Make Model ID Nom(in) P Range(psi) Last Cert Date Stack Hydril GK 13 5/8 5,000.0 8/20/2016 Upper rams Hydril 3 1/2 X 6"VBR 13 5/8 5,000.0 8/20/2016 Middle rams Hydril Blind Shears 13 5/8 5,000.0 8/20/2016 Lower rams Hydril 4 1/2 X 7"VBR 13 5/8 5,000.0 8/20/2016 Slow Circulation Rates Pump Number: Make: Model: Start Date End Date Liner Size(in) Volume Per Stroke Override(bbl/stk) Max Pressure(psi) Date Depth(ftKB) Slow Spd Strokes(spm) P(psi) Eff)%) 0 Flow(gpm) Daily Bulk Supply Item Description: EQUIPMENT FUEL Unit Label:Gallons Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 11/2/2016 477.0 477.0 9,146.0 9,146.0 0.0 0.0 Supply Item Description: NAD 245E Diesel Fuel Unit Label:gal us Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 11/2/2016 1,680.0 0.0 19,840.0 42,310.0 0.0 22,470.0 Supply Item Description: NAD 245E Rig Water Unit Label:bbl Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 11/2/2016 21.0 0.0 919.0 1,365.0 0.0 446.0 Last Authority Visit Date Tot insp.Nbr Total I.N.C.number Comment • 11/1/2016 BOP Test,AOGCC Guy Cook witnessed BOP Test,Next Test Due 11/8/2016 STOP Cards Submitted Company #Rpts Com NABORS ALASKA DRILLING 6 STOP Cards NABORS ALASKA DRILLING 27 PJSM General Notes Comment: Well Name: OP22-WWO. 'Doll Report Wellbore Name: OP22- 03 y p Well Code: 27295 Date: 11/3/2016 • Report#: 21 en 0 Job: WORKOVER Page:1 of 2 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Ground Level(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 0.00 16.38 36.62 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date NABORS 245 NABORS ALASKA LAND RIG 0637 10/14/2016 Daily Information Weather Temperature(°F) Wind Days LTI(days) Days RI(days) POB Overcast 21.2 ENE @ 43 MPH 41.0 Cost Summary Job Account Currency Code Total AFE Amount(Cost) Daily Cost(Cost) Cumulative Cost(Cost) Daily Mud Field Est(Cost) Cumulative mud Cost(Cost) 7683 USD 5,049,784 97,462 1,429,813 1.150 72,774 Safety Incidents-Near Miss Date Category Type Subtype Severity Cause Lost time? 11/3/2016 No Comment NO INCIDENTS REPORTED Safety Drills Days Until Next Check Type 0 Occur Last Date Next Date (days) Authority Visit 2 11/1/2016 11/8/2016 5 BOP Drill1 11/3/2016 1100/2016 7 Fire Drill 15 11/1/2016 11/15/2016 12 Kick While Tripping 1 11/3/2016 11/10/2016 7 Man Down Drill1 10/21/2016 1/19/2017 77 Rig Inspection 21 11/3/2016 11/4/2016 1 Safety Meeting 21 11/3/2016 11/4/2016 1 Spill Drill 13 11/2/2016 11/16/2016 13 Casings seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(RKB) TVD Bot.(ftKB) Run Date CASING 13 3/8 12.42 L-80 -0.8 4,020.0 3,727.6 7/12/2013 CASING 9 5/8 8.84 L-80 0.1 7,631.0 6,526.8 7/29/2013 LINER 7 6.18 L-80 7,396.8 10,668.0 9,513.5 8/5/2013 Last Cementing Cementing Start Date: 8/6/2013 String:LINER,10,668.0ftKB Comment: Stg 0 Top(ftKB) Top Meas Meth Btm(ftKB) Com 1 7,396.0 Volume Calculations 10,658.0 Job Information Job Phase Planned Start Date Start Date End Date P50 Duration(days) P50 Cost(Cost) WORKOVER 10/14/2016 00:00 10/14/2016 12:00 0.00 0 Daily Summary Operations 24h Forecast C/O saver sub,M/U test jnt,prep for testing as per AOGCC,SIMOPS load pipe shed W/4"DP and prep for pick up to do clean out run,P/U drill pipe single in the hole,POOH standing pipe back in derrick. 24h Summary PJSM,Cont.POOH with 4 1/2"Completion String Fl 5401'MD up wt 120K, filling hole 10 BPH T/shroud assembly,ESP cable severed at the plug.PJSM,Disconnect/unclamp ESP cable and cap tube F/ shroud.Secure ESP cable and cap tube.M/U landing jnt,hanger,XO to jnt#1.RIH and land hanger in well head.173 x collar cannon clamps,12 VIT clamps,1 SS band recovered.(1 cannon clamp pin fell down hole)Vetco rep RILDS on hanger,attempt to test hanger seals,BCL splice on rope,pull to spooling unit,change out spools,round up tools for next job,change out 9 bad 4 12"12.6#cr13 L-80 VT tubing in pipe shed.Hanger test good 5400 psi 30 min.Pull hanger,UD landing jnt.add 10 bbls V hole,cont to fill hole 5 bbls every hour,UD last joint of tubing to pipe shed.Pump and shroud @ surface,BCL reps terminate motor lead and cap tube,test motor lead(good)upper connector to power lead(bad),Cont.to UD pump and motor assembly and 7.625"shroud assembly to pipe shed.Clear rig floor on unnecessary tools, change elevators.Prep to make clean out run with 4"DP,stage handling equipment on floor. Operation at 07.00 Rigging up test jnt for testing BOPS. Time Log Start End Cum Dur End Depth Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. (ftKB) 00:00 10:00 10.00 10.00 W.O. L 4 P PJSM,Cont.POOH with 4 1/2"Completion String F/5401'MD up wt 120K, filling hole 10 BPH T/shroud assembly,ESP cable severed at the plug. 10:00 11:00 1.00 11.00 W.O. L 20 P PJSM,Disconnect/unclamp ESP cable and cap tube F/shroud.Secure ESP cable and cap tube. 11:00 12:00 1.00 12.00 W.O. C 20 TS01 M/U landing jnt,hanger,XO to jnt#1.RIH and land hanger in well head.173 x collar cannon clamps,12 VIT clamps,1 SS band recovered.(1 cannon clamp pin fell down hole),losses 36 bbls 12:00 17:30 ' 5.50 17.50 W.O. L 20 P Vetco rep RILDS on hanger,attempt to test hanger seals,BCL splice on rope,pull to spooling unit,change out spools,round up tools for next job,change out 9 bad 4 1/2"12.6#cr13 L-80 VT tubing in pipe shed.Hanger test good 5400 psi 30 min. 17:30 19:00 1.50 19.00 W.O. L 20 TS01 Pull hanger,UD landing jnt.add 10 bbls V hole,cont to fill hole 5 bbls every hour,UD last joint of tubing to pipe shed. 19:00 21:30 2.50 21.50 W.O. L 20 P Pump and shroud @ surface,BCL reps terminate motor lead and cap tube,test motor lead(good)upper connector to power lead(bad),Cont.to UD pump and motor assembly and 7.625"shroud assembly to pipe shed. 21:30 22:00 0.50 22.00 W.O. ' L 20 P Clear rig floor on unnecessary tools,change elevators 22:00 00:00 2.00 24.00 W.O. M 1 TP99 Prep to make clean out run with 4"DP,stage handling equipment on floor. Gas Readings Avg Background Gas(%) Max Background Gas(%) Avg Connection Gas(%) Max Connection Gas(%) Avg Drill Gas(%) Max Drill Gas(%( Avg Trip Gas(%) Max Trip Gas(%) Cumulative Mud Volumes Active Volume(bbl) Hole Volume(bbl) Losses(bbl) Cum Additions(bbl) Additions(bbl) Cum Losses(bbl) Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Bruce Simonson ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Mitch Billington ENI Rig Clerk 907-685-0722 Eni representative Troy England ENI HSE Tool Push Kelly Cozby Nabors Alaska Drilling Tool Pusher Well Name: OP22-WWO• °Dally Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 11/3/2016 Job: WORKOVER Page:2 21 o Page: of 2 Daily Contacts Position Contact Name Company Title Email Office Mobile Tool Push Wesley Jeardoe Nabors Alaska Drilling Tool Pusher Personnel Log(POB) Company Serv.Type Work H(hr) Stand-by H(hr) Count Note Beacon HSE 12.00 1 Solsten Clerk 12.00 1 MI Swaco Mud Engineer 12.00 1 Vetco Wellhead 12.00 1 SLB SCSSV Tech 12.00 1 Solsten Drilling Supervisor 12.00 2 GBR Casing hands 12.00 2 CH2M Truck Driver 12.00 4 Baker Centrilift ESP 12.00 4 NABORS Rig Crew 12.50 24 BOP Stack&Components Description Start Date Last Certification Date Pressure Rating(psi) 13 5/8 11/1/2016 8/20/2016 5,000.0 Type Make Model ID Nom(in) P Range(psi) Last Cert Date Stack 'Hydril GK 13 5/8 5,000.0 8/20/2016 Upper rams Hydril 3 1/2 X 6"VBR 13 5/8 5,000.0 8/20/2016 Middle rams Hydril Blind Shears 13 5/8 5,000.0 8/20/2016 Lower rams Hydril 3 1/2 X 6"VBR 13 5/8 5,000.0 8/20/2016 Slow Circulation Rates Pump Number: Make: Model: Start Date End Date Liner Size(in) Volume Per Stroke Override(bbllstk) Max Pressure(psi) Date Depth(ftKB) Slow Spd Strokes(spm) P(psi) Eff)%) Q Flow(gpm) Daily Bulk Supply Item Description: EQUIPMENT FUEL Unit Label:Gallons Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 11/3/2016 9,146.0 9,146.0 0.0 0.0 Supply Item Description: NAD 245E Diesel Fuel Unit Label:gal us Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 11/3/2016 1,974.0 0.0 21,814.0 42,310.0 0.0 20,496.0 Supply Item Description: NAD 245E Rig Water Unit Label:bbl Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note • 11/3/2016 73.0 0.0 992.0 1,365.0 0.0 373.0 Last Authority Visit Date Tot insp.Nbr Total I.N.C.number Comment 11/1/2016 BOP Test,AOGCC Guy Cook witnessed BOP Test,Next Test Due 11/8/2016 STOP Cards Submitted Company #Rpts Com NABORS ALASKA DRILLING 21 STOP Cards NABORS ALASKA DRILLING 38 PJSM General Notes Comment: • iiiiiiii Well Name: OP22-WW0333 Daily Report Wellbore Name: OP22-WW03 Date: 11/4/2016 • Well Code: 27295 Report#: 22 2n o• Job: WORKOVER Page:1 of 2 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Ground Level(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 0.00 16.38 36.62 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date NABORS 245 NABORS ALASKA LAND RIG 0637 10/14/2016 Daily Information Weather Temperature(°F) Wind Days LTI(days) Days RI(days) POB Overcast 20.8 E @ 22 MPH 41.0 Cost Summary Job Account Currency Code Total AFE Amount(Cost) Daily Cost(Cost) Cumulative Cost(Cost) Daily Mud Field Est(Cost) Cumulative mud Cost(Cost) 7683 USD 5,049,784 93,406 1,523,219 1,150 73,924 Safety Incidents-Near Miss Date Category Type Subtype Severity Cause Lost time? 11/4/2016 No Comment NO INCIDENTS REPORTED Safety Drills Days Until Next Check Type #Occur Last Date Next Date (days) Authority Visit 2 11/1/2016 11/8/2016 4 BOP Drill 1 11/3/2016 11/10/2016 6 Fire Drill 15 11/1/2016 11/15/2016 11 Kick While Tripping 2 11/4/2016 11/11/2016 7 Man Down Drill 1 10/21/2016 1/19/2017 76 Rig Inspection 22 11/4/2016 11/5/2016 1 Safety Meeting 22 11/4/2016 11/5/2016 1 Spill Drill 13 11/2/2016 11/16/2016 12 Casings seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) TVD Bot.(RKB) Run Date CASING 13 3/8 12.42 L-80 -0.8 4,020.0 3,727.6 7/12/2013 CASING 9 5/8 8.84 L-80 0.1 7,631.0 6,526.8 7/29/2013 LINER 7 6.18 L-80 7.396.8 10,668.0 9,513.5 8/5/2013 Last Cementing Cementing Start Date: 8/6/2013 String:LINER,10,668.0ftKB Comment: Stg# Top(ftKB) Top Meas Meth Btm(ftKB) Com 1 7,396.0 Volume Calculations 10,658.0 Job Information Job Phase Planned Start Date Start Date End Date P50 Duration(days) P50 Cost(Cost) WORKOVER 10/14/2016 00:00 10/14/2016 12:00 0.00 0 Daily Summary Operations 24h Forecast P/U M/U BHA#1, 5 3/4"OD Jet Basket W/6 3/4"head,Double pin sub,4 3/4"boot basket,bit sub,pump out sub,X-over,4 1/2"extreme clean magnet,X-over to 4"DP,single in hole(158 more jots)to top of • liner hanger @ 7397'MD,POOH rack back pipe UD BHA 81, P/U M/U Clean out BHA#2,RIH 24h Summary PJSM,C/O saver sub to XT39.Grease gripper head,Change out gripper head dies,C/O stabbing guide for 4"DP.Install elevators,Bring on 290 bbls 9.5 brine to raw mud pit.Remove shroud and ESP assembly from pipe shed.Load 4"XT-39 DP to pipe shed.P/U Test tools,M/U 4"test jot.set plug,fill stack,obtain permit from DSO to work in well bay.Test BOPS W/4"test jnt,250/3500 psi 5 min.each,annular 250/ 2500 psi,annular upper rams,lower rams,TIW,dart valve all passed,Lower IBOP(saver sub)failed 250 psi test.C/O saver sub,test to 250/3500 psi,good test.install saver sub clamp.UD Test tools and test jot, • set wear ring per Vetco rep.9"ID.Service top drive adjust foot for new saver sub.P/U 4"XT-39 drill pipe W/X-over and mule shoe on bottom.drift every jnt.RIH to 99',PJSM,Cont P/U 4"XT-39 DP from shed ` drifting every jnt T/2310'MD,UPW 80K,POOH,F/2310'T/2024'MD,Service rig,grease up,Baker on location,pick up tools and stage on rig floor.Down time work on drawworks,POOH F/2004'MD to surface. Lay down BHA,change out heads in iron rough neck,UD XO,and mule shoe.Clear rig floor and prep for cleanout run.24 hour loses to hole 134 bbls. Operation at 07.00 RIH with BHA#1 Time Log Start End Cum Dur End Depth Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. (ftKB) 00:00 04:00 4.00 4.00 W.O. M 20 TP99 PJSM,C/O saver sub to XT39.Grease gripper head,Change out gripper head dies,C/O stabbing guide for 4" DP.Install elevators,Bring on 290 bbls 9.5 brine to raw mud pit.Remove shroud and ESP assembly from pipe shed.Load 4"XT-39 DP to pipe shed. 04:00 06:30 2.50 6.50 W.O. C 12 TP99 P/U Test tools,M/U 4"test jnt.set plug,fill stack,obtain permit from DSO to work in well bay. 06:30 08:00 1.50 8.00 W.O. C 12 TP99 Test BOPS W/4"test jnt,250/3500 psi 5 min.each,annular 250/2500 psi,annular upper rams,lower rams, TIW,dart valve all passed,Lower IBOP(saver sub)failed 250 psi test. 08:00 09:00 1.00 9.00 W.O. C 12 TP99 C/O saver sub,test to 250/3500 psi,good test.install saver sub clamp. 09:00 10:30 1.50 10.50 W.O. C 12 TP99 UD Test tools and test jnt,set wear ring per Vetco rep.9"ID 10:30 11:00 0.50 11.00 W.O. M 20 TP99 Service top drive adjust foot for new saver sub, 11:00 12:00 1.00 12.00 W.O. M 4 TP99 P/U 4"XT-39 drill pipe W/X-over and mule shoe on bottom.drift every jot.RIH to 99' 12:00 18:00 6.00 18.00 W.O. M 4 TP99 PJSM,Cont P/U 4"XT-39 DP from shed drifting every jnt T/2310'MD,UPW 80K 18:00 19:00 1.00 19.00 W.O. M 4 TP99 POOH,F/2310'T/2024'MD 19:00 19:30 0.50 19.50 W.O. M 25 TP99 Service rig,grease up 19:30 21:00 1.50 21.00 W.O. M 20 TP99 Baker on location,pick up tools and stage on rig floor. 21:00 22:00 1.00 22.00 W.O. M 25 TS99 Down time work on drawworks, 22:00 23:00 1.00 23.00 W.O. M 4 TP99 POOH F/2004'MD to surface. 23:00 23:30 0.50 23.50 W.O. M 20 TP99 Lay down BHA,change out heads in iron rough neck,UD XO,and mule shoe. 23:30 00:00 0.50 24.00 W.O. M 1 TP99 Clear rig floor and prep for clean out run.24 hour loses to hole 134 bbls Gas Readings Avg Background Gas(%) Max Background Gas(%) Avg Connection Gas(%) Max Connection Gas(%) Avg Drill Gas(%( Max Drill Gas)%) Avg Trip Gas(%) 'Max Trip Gas(%) Cumulative Mud Volumes Active Volume(bbl) Hole Volume(bbl) Losses(bbl) Cum Additions(bbl) Additions(bbl) Cum Losses(bbl) Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Bruce Simonson ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 • Well Name: OP22-WW03 tTiR Daily Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 11/4/2016 Job: WORKOVER Page:2 22 o Page: of 2 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.corn 907-685-0715 -907-320-0058 Eni representative Mitch Billington ENI Rig Clerk 907-685-0722 Eni representative Troy England ENI HSE Tool Push Kelly Cozby Nabors Alaska Drilling Tool Pusher Tool Push Wesley Jeardoe Nabors Alaska Drilling Tool Pusher Personnel Log(POB) Company Serv.Type Work H(hr) Stand-by H(hr) Count Note Beacon HSE 12.00 1 Solsten Clerk 12.00 1 MI Swaco Mud Engineer 12.00 1 Vetco Wellhead 12.00 1 SLB SCSSV Tech 12.00 1 Baker Hughes Tool Hand 12.00 1 Solsten Drilling Supervisor 12.00 2 GBR Casing hands 12.00 2 CH2M Truck Driver 12.00 4 Baker Centrilift ESP 12.00 4 NABORS Rig Crew 12.50 23 BOP Stack&Components Description Start Date Last Certification Date Pressure Rating(psi) 135/8 11/1/2016 8/20/2016 5,000.0 Type Make _ Model ID Nom(in) P Range(psi) Last Cert Date Stack Hydril GK 13 5/8 5,000.0 8/20/2016 Upper rams Hydril 3 1/2 X 6"VBR 13 5/8 5,000.0 8/20/2016 Middle rams Hydril Blind Shears 13 5/8 5,000.0 8/20/2016 Lower rams Hydril 3 1/2 X 6"VBR 13 5/8 5,000.0 8/20/2016 Slow Circulation Rates Pump Number: Make: Model: Start Date End Date Liner Size(in) Volume Per Stroke Override)bbl/stk) Max Pressure(psi) Date Depth(ftKB) Slow Spd Strokes(spm) P(psi) Eff(%) Q Flow(gym) Daily Bulk Supply Item Description: EQUIPMENT FUEL Unit Label:Gallons Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 11/4/2016 951.0 951.0 10,097.0 10,097.0 0.0 0.0 Supply Item Description: NAD 245E Diesel Fuel Unit Label:gal us Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 11/4/2016 2,016.0 0.0 23,830.0 42,310.0 0.0 18,480.0 Supply Item Description: NAD 245E Rig Water Unit Label:bbl Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 11/4/2016 71.0 130.0 1,063.0 1,495.0 0.0 432.0 Last Authority Visit Date Tot insp.Nbr Total I.N.C.number Comment 11/1/2016 BOP Test,AOGCC Guy Cook witnessed BOP Test,Next Test Due 11/8/2016 STOP Cards Submitted Company #Rpts Com NABORS ALASKA DRILLING 9 STOP Cards NABORS ALASKA DRILLING 33 PJSM General Notes Comment: 0 00011 Well Name: OP22-WW03. Daily Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 11/5/2016 • Report#: 23 en II Job: WORKOVER Page:1 of 2 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Ground Level(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 0.00 16.38 36.62 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date NABORS 245 NABORS ALASKA LAND RIG 0637 10/14/2016 Daily Information Weather Temperature(°F) Wind Days LTI(days) Days RI(days) POB Overcast/Light Snow 12.5 W @ 10 MPH 42.0 Cost Summary Job Account Currency Code Total AFE Amount(Cost) Daily Cost(Cost) Cumulative Cost(Cost) Daily Mud Field Est(Cost) Cumulative mud Cost(Cost) 7683 USD 5,049,784 125,144 1,648.362 37.203 111,127 Safety Incidents-Near Miss Date Category Type Subtype Severity Cause Lost time? 11/5/2016 No Comment NO INCIDENTS REPORTED Safety Drills • Days Until Next Check Type #Occur Last Date Next Date (days) Authority Visit 2 11/1/2016 11/8/2016 3 BOP Drill 1 11/3/2016 11/10/2016 5 Fire Drill 15 11/1/2016 11/15/2016 10 Kick While Tripping 3 11/5/2016 11/12/2016 7 Man Down Drill 1 10/21/2016 1/19/2017 75 Rig Inspection 23 11/5/2016 11/6/2016 1 Safety Meeting 23 11/5/2016 11/6/2016 1 Spill Drill 13 11/2/2016 11/16/2016 11 Casings seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(RKB) TVD Bot.(RKB) Run Date CASING 133/8 12.42 L-80 -0.8 4,020.0 3,727.6 7/12/2013 CASING 9 5/8 8.84 L-80 0.1 7,631.0 6,526.8 7/29/2013 LINER 7 6.18 L-80 7,396.8 10,668.0 9,513.5 8/5/2013 Last Cementing Cementing Start Date: 8/6/2013 String:LINER,10,668.OftKB Comment: Stg 8 Top(ftKB) Top Meas Meth Btm(ftKB) Com 1 7,396.0 Volume Calculations 10,658.0 Job Information Job Phase Planned Start Date Start Date End Date P50 Duration(days) P50 Cost(Cost) WORKOVER 10/14/2016 00:00 10/14/2016 12:00 0.00 0 Daily Summary Operations 24h Forecast P/U M/U BHA#2 Baker milling assembly,RIH to liner top and work into liner top,POOH laying do DP. 24h Summary Pre Job Safety Rig Orientation W/rig team and company rep.&Toolpusher,PJSM,P/U M/U BHA#1 5 3/4"OD JET BASKET W/6 3/4"HEAD,DBL.PIN SUB,BOOT BASKET,BIT SUB,PMP.OUT SUB,4 1/2" IF X 3 1/2"REG X-O,EXTREME CLEAN MAGNET,XT 39 X 4 1/2"IF X-O,"NOTE:1"STEEL BALL PLACED INSIDE JET SUB.Cont P/U 4"15.7#XT-39 DP 1X1 F/pipe shed,Drift ea.jnt.same,M/U torque 18K.Circulate and condition at 2353'MD,unable to obtain parameters for 1600&1800 psi,pump 7 BPM,@ 700 psi.Pumped 30 bbls away,will capture parameters at 7"UT,B/D top drive.Cost P/U 4"15.7 XT- 39 DP from pipe shed F/2353 T/3243'MD.Losses this tour 77 bbls,PJSM,cont P/U 4"DP F/3243'T/5118'MD drifting every jnt,UPW 125K DNW 105K,Install hobble,lower thread protectors T/pipe shed.TIH F/5118'T/7333'MD,make up top drive connection on last stand.Brake circ,fill pipe 9 bbls,23 bbls returns to flow line,@ 6 BPM 730 psi,8 BPM 1560 psi,287 GPM,wash dn F/7333'T/7407'MD,tag on depth wash up and dn 35',3X UPW 170K,DNW 125K.POOH F/7407'T/7333'MD,rack back stand,B/D top Drive.POOH F/7333'to surface.UD BHA#1,no metal or debris recovered,Losses this tour 169 bbls. Operation at 07.00 RIH W/BHA#2 at 4260'MD Time Log Start End Cum Dur End Depth Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. (RKB) 00:00 01:00 1.00 1.00 W.O. M 1 TP99 Pre Job Safety Rig Orientation W/rig team and company rep.&Toolpusher 01:00 04:00 3.00 4.00 W.O. M 1 TP99 PJSM,P/U M/U BHA#1 5 3/4"OD JET BASKET W/6 3/4"HEAD,DBL.PIN SUB,BOOT BASKET,BIT SUB, PMP.OUT SUB,4 1/2"IF X 3 1/2"REG X-O,EXTREME CLEAN MAGNET,XT 39 X 4 1/2"IF X-O,"NOTE: 1"STEEL BALL PLACED INSIDE JET SUB. 04:00 09:30 5.50 9.50 W.O. M 4 TP99 Cont P/U 4"15.78 XT-39 DP 1X1 F/pipe shed,Drift ea.int.same,M/U torque 18K. 09:30 10:00 0.50 10.00 W.O. M ' 1 TP99 Circulate and condition at 2353'MD,unable to obtain parameters for 1600&1800 psi,pump 7 BPM,@ 700 psi.Pumped 30 bbls away,will capture parameters at 7"UT,B/D top drive. 10:00 12:00 2.00 12.00 ' W.O. M ' 4 TP99 Cont P/U 4"15.7#XT-39 DP from pipe shed F/2353 T/3243'MD,Losses this tour 77.5 bbls 12:00 15:00 3.00 15.00 W.O. M 4 TP99 PJSM,cont P/U 4"DP F/3243'T/5118'MD drifting every int,UPW 125K DNW 105K 15:00 15:30 0.50 15.50 W.O. M 4 TP99 Install hobble,lower thread protectors T/pipe shed 15:30 17:00 ' 1.50 17.00 W.O. M ' 4 TP99 TIH F/5118'T/7333'MD,make up top drive connection on last stand. 17:00 18:00 1.00 18.00 ' W.O. M 7 TP99 Brake circ,fill pipe 9 bbls,23 bbls returns to flow line,@ 6 BPM 730 psi,8 BPM 1560 psi,287 GPM,wash do F/7333'T/7407'MD,tag on depth wash up and dn 35',3X UPW 170K,DNW 125K. 18:00 18:30 0.50 18.50 ' W.O. M 4 TP99 POOH F/740T T/7333'MD,rack back stand,B/D top Drive. 18:30 22:30 4.00 ' 22.50 W.O. M 4 TP99 POOH F/7333'to surface. 22:30 00:00 1.50 24.00 W.O. M 20 TP99 UD BHA#1,no metal or debris recovered,Losses this tour 169 bbls Gas Readings Avg Background Gas)%) Max Background Gas(%) Avg Connection Gas(%) Max Connection Gas(%) Avg Drill Gas)%) Max Drill Gas)%( Avg Trip Gas(%) Max Trip Gas(%) Cumulative Mud Volumes Active Volume(bbl) Hole Volume(bbl) Losses(bbl) Cum Additions(bbl) Additions(bbl) Cum Losses(bbl) Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Bruce Simonson ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Mitch Billington ENI Rig Clerk 907-685-0722 Eni representative Troy England ENI HSE • Well Name: OP22-WW0llt Daily Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 11/5/2016 Job: WORKOVER Page:2 23 o Page: of 2 Daily Contacts Position Contact Name Company Title Email Office Mobile Tool Push Kelly Cozby Nabors Alaska Drilling Tool Pusher Tool Push Wesley Jeardoe Nabors Alaska Drilling Tool Pusher Personnel Log(POB) Company Serv.Type Work H(hr) Stand-by H(hr) Count Note Beacon HSE 12.00 1 Solsten Clerk 12.00 1 MI Swaco Mud Engineer 12.00 1 Vetco Wellhead 12.00 1 SLB SCSSV Tech 12.00 1 Baker Hughes Tool Hand 12.00 1 Solsten Drilling Supervisor 12.00 2 GBR Casing hands 12.00 2 CH2M Truck Driver 12.00 4 Baker Centrilift ESP 12.00 4 NABORS Rig Crew 12.50 24 BOP Stack&Components Description Start Date Last Certification Date Pressure Rating(psi) 13 5/8 11/1/2016 8/20/2016 5,000.0 Type Make Model ID Nom(in) P Range(psi) Last Cert Date Stack 'Hydril GK 13 5/8 5,000.0 8/20/2016 Upper rams Hydril 3 1/2 X 6"VBR 13 5/8 5,000.0 8/20/2016 Middle rams Hydril Blind Shears 13 5/8 5,000.0 8/20/2016 Lower rams Hydril 3 1/2 X 6"VBR 13 5/8 5,000,0 8/20/2016 Slow Circulation Rates Pump Number: Make: Model: Start Date End Date Liner Size(in) Volume Per Stroke Override(bbl/stk) Max Pressure(psi) Date Depth(ftKB) Slow Spd Strokes(spm) P(psi) Eff)%) Q Flow(gpm) Daily Bulk Supply Item Description: EQUIPMENT FUEL Unit Label:Gallons Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 11/5/2016 536.0 536.0 10,633.0 10,633.0 0.0 0.0 Supply Item Description: NAD 245E Diesel Fuel Unit Label:gal us Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 11/5/2016 2,058.0 0.0 25,888.0 42,310.0 0.0 16,422.0 Supply Item Description: NAD 245E Rig Water Unit Label: bbl Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 11/5/2016 89.0 130.0 1,152.0 1,625.0 0.0 473.0 Last Authority Visit Date Tot insp.Nbr Total I.N.C.number Comment 11/1/2016 BOP Test,AOGCC Guy Cook witnessed BOP Test,Next Test Due 11/8/2016 STOP Cards Submitted Company #Rpts Com NABORS ALASKA DRILLING 31 STOP Cards NABORS ALASKA DRILLING 15 PJSM General Notes Comment: • Well Name: OP22-WW03' Daily Report Wellbore Name: OP22-WW03 Date: 11/6/2016 • Well Code: 27295 Report#: 24 2 n II Job: WORKOVER Page:1 of 2 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Ground Level(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 0.00 16.38 36.62 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date NABORS 245 NABORS ALASKA LAND RIG 0637 10/14/2016 Daily Information Weather Temperature(°F) Wind Days LTI(days) Days RI(days) POB Overcast/Light Snow 8.6 WSW @ 15 MPH 42.0 Cost Summary Job Account Currency Code Total AFE Amount(Cost) Daily Cost(Cost) 'Cumulative Cost(Cost) Daily Mud Field Est(Cost) Cumulative mud Cost(Cost) 7683 USD 5,049,784 81,622 1,729,985 1,150 112,277 Safety Incidents-Near Miss Date Category Type Subtype Severity Cause Lost time? 11/6/2016 No Comment NO INCIDENTS REPORTED Safety Drills Days Until Next Check Type 6 Occur Last Date Next Date (days) Authority Visit 2 11/1/2016 11/8/2016 2 BOP Drill 1 11/3/2016 11/10/2016 4 Fire Drill 16 11/6/2016 11/20/2016 14 Kick While Tripping 3 11/5/2016 11/12/2016 6 Man Down Drill 1 10/21/2016 1/19/2017 74 Rig Inspection 24 11/6/2016 11/7/2016 1 Safety Meeting 24 11/6/2016 11/7/2016 1 Spill Drill 14 11/6/2016 11/20/2016 14 Casings seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(RKB) TVD Bot.(RKB) Run Date CASING 133/8 12.42 L-80 -0.8 4,020.0 - 3,727.6 7/12/2013 CASING 9 5/8 8.84 L-80 0.1 7,631.0 6,526.8 7/29/2013 LINER 7 6.18 L-80 7,396.8 10,668.0 9,513.5 8/5/2013 ' Last Cementing Cementing Start Date: 8/6/2013 String:LINER,10,668.0f1KB Comment: Stg 8 Top(RKB) Top Meas Meth Btm(ftKB) Com 1 7,396.0 Volume Calculations 10,658.0 Job Information Job Phase Planned Start Date Start Date End Date P50 Duration(days) P50 Cost(Cost) WORKOVER 10/14/2016 00:00 10/14/2016 12:00 0.00 0 Daily Summary Operations 24h Forecast P/U first shroud section M/U to seal assy,then M/U 2nd shroud,M/U ESP completion assembly per Baker&well plan,make up splice,test,RIH with ESP completion. 24h Summary PJSM,Clear rig floor of vender tools.PJSM,Load polish mill assembly on to skate. PJSM W/Baker rep,P/U M/U BHA#2 TRB Dress&Polish milling assembly,4 1/2 IF X XT-39.RIH W/polish assembly Fl 17'T/ 7322'MD,Circ and condition at 7322'MD UPW 170 K,DWT 125 K,M/U Top drive,pump 207 GPM,60 SPM,350 psi,40 RPM,TQ 4 K,W/rotary UWT 140,DWT 140 K,RWT 145 K,wash dn and polish 7"seal bore F/7397'T/7406.5'MD,Ream 2X.,POOH laying down 4"DP to pipe shed F/7383'T/4048'MD.Tour losses 178 bbls.Service rig,grease drawworks,blocks,crown,top drive,pipe skate.PJSM,Cont. POOH laying do 4"XT-39 DP F/4048' UPW 105K T/surface,filling 5 BPH+double displacement.PJSM,L/D Baker Polish Mill Assembly.Remove wear ring L/D to pipe shed,P/U 3rd party tools load seal assembly,pumps,shroud in shod side pipe shed,Finish removing DP from long side of pipe shed,pull ESP and Cap tube over sheaves.P/U seal assembly.Tour losses 93 bbls. 1,' Operation at 07.00 M/U ESP Assembly Time Log Start End Cum Dur End Depth Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. (RKB) 00:00 00:30 0.50 0.50 W.O. M 20 TP99 PJSM,Clear rig floor of vender tools. 00:30 01:00 0.50 1.00 W.O. M 20 TP99 PJSM,Load polish mill assembly on to skate. 01:00 01:30 0.50 1.50 W.O. M 20 TP99 PJSM W/Baker rep,P/U M/U BHA#2 TRB Dress&Polish milling assembly,4 1/2 IF X XT-39. 01:30 05:00 3.50 5.00 W.O. M 4 TP99 RIH W/polish assembly F/17'T/7322'MD 05:00 06:00 1.00 6.00 W.O. M 4 TP99 Circ and condition at 7322'MD UPW 170 K,DWT 125 K,M/U Top drive,pump 207 GPM,60 SPM,350 psi,40 RPM,TQ 4 K,W/rotary UWT 140,DWT 140 K,RWT 145 K,wash do and polish 7"seal bore F/7397'TI 7406.5'MD,Ream 2X. 06:00 12:00 6.00 12.00 W.O. M 4 TP99 POOH laying down 4"DP to pipe shed F/7383'T/4048'MD.Tourly losses 178 bbls. 12:00 12:30 0.50 12.50 W.O. M 25 TP99 Service rig,grease drawworks,blocks,crown,top drive,pipe skate. 12.30 19:30 7.00 19.50 W.O. ' M 4 TP99 PJSM,Cont.POOH laying dn 4"XT-39 DP F/4048' UPW 105K T/surface,filling 5 BPH+double displacement. 19:30 20:00 0.50 20.00 W.O. M 20 TP99 PJSM,UD Baker Polish Mill Assembly. 20:00 20:30 0.50 20.50 W.O. K 20 P Remove wear ring UD to pipe shed 20:30 23:30 3.00 23.50 W.O. K 20 P P/U 3rd party tools load seal assembly,pumps,shroud in short side pipe shed,Finish removing DP from long side of pipe shed,pull ESP and Cap tube over sheaves. 23:30 00:00 0.50 24.00 W.O. K 20 P P/U seal assembly.Tourly losses 93 bbls Gas Readings Avg Background Gas(%) Max Background Gas(%) Avg Connection Gas(%) Max Connection Gas(%) Avg Drill Gas(%) 'Max Drill Gas(% Avg Trip Gas(% 'Max Trip Gas(%) Cumulative Mud Volumes Active Volume(bbl) Hole Volume(bbl) Losses(bbl) Cum Additions(bbl) Additions(bbl) Cum Losses(bbl) Daily Contacts Position Contact Name Company Title _ Email Office Mobile Eni representative Bruce Simonson ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Mitch Billington ENI Rig Clerk 907-685-0722 Eni representative Troy England ENI HSE • Well Name: OP22-WW03. Daily Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 1116/2016 Job: WORKOVER Pa Page: #: 24 2 of 2 Daily Contacts Position _ Contact Name Company Title Email Office Mobile Tool Push Kelly Cozby Nabors Alaska Drilling Tool Pusher Tool Push Wesley Jeardoe Nabors Alaska Drilling Tool Pusher Personnel Log(POB) Company Serv.Type Work H(hr) Stand-by H(hr) Count Note Beacon HSE 12.00 1 Solsten Clerk 12.00 1 Ml Swaco Mud Engineer 12.00 1 Vetco Wellhead 12.00 1 SLB SCSSV Tech 12.00 1 Baker Hughes Tool Hand 12.00 1 Solsten Drilling Supervisor 12.00 2 GBR Casing hands 12.00 2 CH2M Truck Driver 12.00 4 Baker Centrilift ESP 12.00 4 NABORS Rig Crew 12.50 24 BOP Stack&Components Description Start Date Last Certification Date Pressure Rating(psi) 135/8 11/1/2016 8/20/2016 5,000.0 Type Make Model ID Nom(in) _ P Range(psi) Last Cert Date Stack Hydril 'GK 135/8 5,000.0 8/20/2016 Upper rams Hydril 3 1/2 X 6"VBR 13 5/8 5,000.0 8/20/2016 Middle rams Hydril Blind Shears 13 5/8 5,000.0 8/20/2016 Lower rams Hydril 3 1/2 X 6"VBR 13 5/8 5,000.0 8/20/2016 Slow Circulation Rates Pump Number: Make: Model: Start Date End Date Liner Size(in) Volume Per Stroke Override(bbl/stk( Max Pressure(psi) Date Depth(ftKB) Slow Spd Strokes(spm) P(psi) Eff(%) Q Flow(gpm) Daily Bulk Supply Item Description: EQUIPMENT FUEL Unit Label:Gallons Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 11/6/2016 627.0 627.0 11,260.0 11,260.0 0.0 0.0 Supply Item Description: NAD 245E Diesel Fuel Unit Label:gal us Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 11/6/2016 2,288.0 0.0 28,176.0 42,310.0 0.0 14,134.0 Supply Item Description: NAD 245E Rig Water Unit Label:bbl Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 11/6/2016 102.0 0.0 1,254.0 1,625.0 0.0 371.0 Last Authority Visit Date Tot insp.Nbr Total I.N.C.number Comment 11/1/2016 BOP Test,AOGCC Guy Cook witnessed BOP Test,Next Test Due 11/8/2016 STOP Cards Submitted Company #Rpts Com NABORS ALASKA DRILLING 18 STOP Cards NABORS ALASKA DRILLING 32 PJSM General Notes Comment: • Well Name: OP22-WW031, Daily Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 11/7/2016 n• Report#: 25 2 n fl Job: WORKOVER Page:1 of 2 Well Header Permit/Concession N" Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Ground Level(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 0.00 16.38 36.62 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date NABORS 245 NABORS ALASKA LAND RIG 0637 10/14/2016 Daily Information Weather Temperature(°F) Wind Days LTI(days) Days RI(days) POB Overcast 19.3 S @ 3 MPH 42.0 Cost Summary Job Account Currency Code Total AFE Amount(Cost) Daily Cost(Cost) Cumulative Cost(Cost) Daily Mud Field Est(Cost) Cumulative mud Cost(Cost) 7683 USD 5,049,784 79,893 1,809,877 112,277 Safety Incidents-Near Miss Date Category Type Subtype Severity Cause Lost time? 11/7/2016 No Comment NO INCIDENTS REPORTED Safety Drills Days Until Next Check Type #Occur Last Date Next Date (days) Authority Visit 2 11/1/2016 11/8/2016 1 BOP Drill 1 11/3/2016 11/10/2016 3 Fire Drill 17 11/7/2016 11/21/2016 14 Kick While Tripping 3 11/5/2016 11/12/2016 5 Man Down Drill 1 10/21/2016 1/19/2017 73 Rig Inspection 25 11/7/2016 11/8/2016 1 Safety Meeting 25 11/7/2016 11/8/2016 1 Spill Drill 15 11/7/2016 11/21/2016 14 Casings seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) TVD Bot.(RKB) Run Date CASING ' 13 3/8 12.42 L-80 -0.8 4,020.0 3,727.6 .. 7/12/2013 CASING 9 5/8 8.84 L-80 0.1 7,631.0 6,526.8 7/29/2013 LINER 7 6.18 L-80 7,396.8 10,668.0 9,513.5 8/5/2013 Last Cementing Cementing Start Date: 8/6/2013 String:LINER,10,668.0ftKB Comment: Stg# Top(RKB) Top Meas Meth Btm(ftKB) Com 1 7,396.0 Volume Calculations 10,658.0 Job Information Job Phase Planned Start Date Start Date End Date P50 Duration(days) P50 Cost(Cost) WORKOVER 10/14/201600:00 10/14/201612'00 0.00 0 Daily Summary Operations 24h Forecast Cont.to RIH with 4.1/2"12.6#13cr L-80 tbg W/ESP assembly,sting in seal assembly in packer,pull up space out,sting in seal assemble while landing hanger. 24h Summary PJSM,M/U 7 5/8"29.7#13cr-80 Vam FJL shroud casing,M/U tq 7400 ft/Ib,M/U Centrilift Motor Assembly as per Centrilift Rep.Change Vam Top floor valve crossover assembly to M/U to top drive. M/U motor assembly as per centrilift Rep M/U jot#1 4 1/2"13cr-80 12.6 vain top tbg.Torq turn conn.4440 ft/lbs Perform MLE Splice,losses to hole this tour 63 bbls Cont make MLE splice.Splice trouble,redo splice with updated information.Connect to penetrator,M/U Cap tubes,RIH install first clamp,RIH W/first jnt#1,add 5 bbls to hole and wet splice and test,good.Hold PJSM with all hands,start in hole with 4 1/2"13cr L-80 ,.,-- 12.6#Vam Top tubing,use Jet Lube sealgaurd thread compound,Drift all tubing W/3.833 drift,tq turn T/4,440 ft/lbs,F/147'T/1,517'MD,Installing clamps every jnt.testing cable every 1000',Changed out jnts and collars on jot#7,19,23 with extra jnts.Losses to hole this tour 64 bbls. Operation at 07.00 RIH W/4 1/2"completion string @ 2,482'MD Tinge Log Start End Cum Dur End Depth Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. (RKB) 00:00 01:00 1.00 1.00 W.O. K 20 P PJSM,M/U 7 5/8"29.7#13cr-80 Vam FJL shroud casing,M/U tq 7400 ft/lb 01:00 05:00 4.00 5.00 W.O. K 20 P M/U Centrilift Motor Assembly as per Centrilift Rep. 05:00 05:30 0.50 5.50 W.O. K 20 P Change Vam Top Floor valve crossover assembly to M/U to top drive. 05:30 10:30 5.00 10.50 W.O. K 20 P 'M/U motor assembly as per centrilift Rep M/U jot#1 4 1/2"13cr-80 12.6 yam top tbg.Torq turn conn.4440 ft/ lbs 10:30 12:00 1.50 12.00 W.O. ' K 20 P Perform MLE Splice,losses to hole this tour 63 bbls 12:00 13:00 ' 1.00 13.00 W.O. K 20 P Cont make MLE splice. 13:00 15:00 2.00 15.00 W.O. K 20 TS03 Splice trouble,redo splice with updated information. 15:00 16:00 1.00 16.00 W.O. ' K 20 P Connect to penetrator,M/U Cap tubes,RIH install first clamp,RIH W/first jot#1,add 5 bbls to hole and wet splice and test,good. 16:00 00:00 8.00 24.00 W.O. ' K 4 P Hold PJSM with all hands,start in hole with 4 1/2"13cr L-80 12.6#Vam Top tubing,use Jet Lube sealgaurd thread compound,Drift all tubing W/3.833 drift,tq turn T/4,440 ft/lbs,P/147'T/1,517'MD,Installing clamps every jnt.testing cable every 1000',Changed out jnts and collars on jot#7,19,23 with extra jots.Losses to hole this tour 64 bbls. Gas Readings Avg Background Gas(%) Max Background Gas(%) Avg Connection Gas(%) Max Connection Gas(%) Avg Drill Gas(%) 'Max Drill Gas(%) Avg Trip Gas(%) 'Max Trip Gas(%) Cumulative Mud Volumes Active Volume(bbl) Hole Volume(bbl) Losses(bbl) Cum Additions(bbl) Additions(bbl) Cum Losses(bbl) Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Bruce Simonson ENI Drilling Supv. SIDDrilling@enipetroleum.com ' 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.corn 907-685-0715 907-320-0058 Eni representative Mitch Billington ENI Rig Clerk 907-685-0722 Eni representative Troy England ENI HSE Tool Push Kelly Cozby Nabors Alaska Drilling Tool Pusher Tool Push Wesley Jeardoe Nabors Alaska Drilling Tool Pusher • • Well Name: OP22-WW03LTR Daily Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 11/7/2016 Job: WORKOVER P 2 25 o Page: of 2 Personnel Log(POB) Company Serv.Type Work H(hr) Stand-by H(hr) Count Note Beacon HSE 12.00 1 Solsten Clerk 12.00 1 MI Swaco Mud Engineer 12.00 1 Vetco Wellhead 12.00 1 SLB SCSSV Tech 12.00 1 Baker Hughes Tool Hand 12.00 1 Soisten Drilling Supervisor 12.00 2 GBR Casing hands 12.00 2 CH2M Truck Driver 12.00 4 Baker Centrilift ESP 12.00 4 NABORS Rig Crew 12.50 24 BOP Stack&Components Description Start Date Last Certification Date Pressure Rating(psi) 13 5/8 11/1/2016 8/20/2016 5,000.0 Type Make Model ID Nom(in) P Range(psi) Last Cert Date Stack Hydril GK 13 5/8 5,000.0 8/20/2016 Upper rams Hydril 3 1/2 X 6"VBR 13 5/8 5,000.0 8/20/2016 Middle rams Hydril Blind Shears 13 5/8 5,000.0 8/20/2016 Lower rams Hydril 3 1/2 X 6"VBR 13 5/8 5,000.0 8/20/2016 Slow Circulation Rates Pump Number: Make: Model: Start Date End Date Liner Size(in) Volume Per Stroke Override(bbl/stk) Max Pressure(psi) Date Depth(ftKB) Slow Spd Strokes(spm) P(psi) Eff(TO Q Flow(gpm) Daily Bulk Supply Item Description: EQUIPMENT FUEL Unit Label:Gallons Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 11/7/2016 553.0 553.0 11,813.0 11,813.0 0.0 0.0 Supply Item Description: NAD 245E Diesel Fuel Unit Label:gal us Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 11/7/2016 1,932.0 0.0 30,088.0 42,310.0 0.0 12,222.0 Supply Item Description: NAD 245E Rig Water Unit Label:bbl Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 11/7/2016 22.0 0.0 1,276.0 1,625.0 0.0 349.0 Last Authority Visit Date Tot insp.Nbr Total I.N.C.number Comment 11/1/2016 BOP Test,AOGCC Guy Cook witnessed BOP Test,Next Test Due 11/8/2016 STOP Cards Submitted Company #Rpts Corn NABORS ALASKA DRILLING 15'STOP Cards NABORS ALASKA DRILLING 24 PJSM General Notes Comment: � • f Well Name: OP22-WW03 LFR Daily Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 11/8/2016 • Report#: 26 2 n n 11 Job: WORKOVER Page:1 of 2 Well Header Permit/Concession N" Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Ground Level(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 0.00 16.38 36.62 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date NABORS 245 NABORS ALASKA LAND RIG 0637 10/14/2016 Daily Information Weather Temperature(°F) Wind Days LTI(days) Days RI(days) POB Overcast/Snow 20.4 N @ 13 MPH 42.0 Cost Summary Job Account Currency Code Total AFE Amount(Cost) Daily Cost(Cost) Cumulative Cost(Cost) Daily Mud Field Est(Cost) Cumulative mud Cost(Cost) 7683 USD 5,049,784 1,056,749 2,866,627 23,943 137,370 Safety Incidents-Near Miss Date Category Type Subtype 'Severity Cause Lost time? 11/8/2016 No Comment NO INCIDENTS REPORTED Safety Drills Days Until Next Check Type 8 Occur Last Date Next Date (days) Authority Visit 3 11/8/2016 11/25/2016 17 BOP Drill1 11/3/2016 11/10/2016 2 Fire Drill 17 11/7/2016 11/21/2016 13 Kick While Tripping 4 11/8/2016 11/15/2016 7 Man Down Drill1 10/21/2016 1/19/2017 72 Rig Inspection 26 11/8/2016 11/9/2016 1 Safety Meeting 26 11/8/2016 11/9/2016 1 Spill Drill 16 11/8/2016 11/22/2016 14 Casings seat Cas.Type OD(in) ID(in) _ Grade Top(RKB) Bottom(ftKB) TVD Bot.(RKB) Run Date CASING 133/8 12.42 L-80 -0.8 4,020.0 3,727.6 7/12/2013 CASING 95/8 8.84 L-80 0.1 7,631.0 6,526.8 7/29/2013 LINER 7 6.18 L-80 7,396.8 10,668.0 9,513.5 8/5/2013 Last Cementing Cementing Start Date: 8/6/2013 String:LINER,10,668.0ftKB Comment: Stg 4 Top(MB) Top Meas Meth Btm(ftKB) Com 1 7,396.0 Volume Calculations 10,658.0 Job Information Job Phase Planned Start Date Start Date End Date P50 Duration(days) P50 Cost(Cost) WORKOVER 10/14/2016 00:00 10/14/2016 12:00 0.00 0 Daily Summary Operations 24h Forecast Cont to space out,M/U hanger,terminate lines,spot corrosion inhibitor brine to IA,land hanger and RILDS.Test hanger seals,Pressure test IA to 1500 psi for 30 mins(Charted). 24h Summary PJSM,RIH W 4 1/2"12.60 13Cr L-80 Vam Top ESP Completion F/1517'T/507T MD doping conn.W JLSG&tq turn to 4440 ft/lbs.installing cannon clamps on all connections,Test conductivity every 1000'. R/U SLB's SCSSV control line&Sheave,M/U control line to SCSSV.Losses 59 bbls.PJSM,Test SCSSV to 5,000 psi for 15 min.Cont RIH F/5077'W/4.5"12.6#13Cr L-80 Vam Top using JLSG thread compound on conn.,drifting W/3.83 drift,tq turn 4400 ft lbs DNW 93K,installing canon clamps every 1000'.R/U Head Pin,X-over and cement line.P/U tag out Int,M/U same,brake circulation fill pipe @ 2 BPM, 70 psi fluid in stack at 50 bbls,UPW=155K,DNW=113K,tag up at 7406'MD shut dn pump,61 bbls pumped.R/D head pin and cement line,UD 3 jots to shed.B/D cement line,M/U safety valve,figure space out,P/U pups from shed.M/U pups in string for space out,P/U last jot from shed M/U same.109 bbls losses this tour. Operation at 07.00 Prepping Hanger Time Log Start End Cum Dur End Depth Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. (RKB) 00:00 10:30 10.50 10.50 ' W.O. K 4 P PJSM,RIH W 4 1/2"12.60 13Cr L-80 Vam Top ESP Completion F/1517'T/5077'MD doping conn.W JLSG &tq turn to 4440 6/lbs.installing cannon clamps on all connections,Test conductivity every 1000'. 10:30 12:00 1.50 12.00 W.O. K 4 P R/U SLB's SCSSV control line&Sheave,M/U control line to SCSSV.Losses 59 bbls 12:00 12:30 0.50 12.50 W.O. K 4 P PJSM,Test SCSSV to 5,000 psi for 15 min. 12:30 19:00 6.50 19.00 W.O. K 4 P Cont RIH Ft 5077'W/4.5"12.6/f 13Cr L-80 Vam Top using JLSG thread compound on conn.,drifting W/3.83 drift,tq tum 4400 ft lbs DNW 93K,installing canon clamps every 1000'. 19:00 20:00 1.00 20.00 W.O. K 20 P R/U Head Pin,X-over and cement line. 20:00 21:30 1.50 21.50 W.O. K 7 P P/U tag out jot,M/U same,brake circulation fill pipe @ 2 BPM,70 psi fluid in stack at 50 bbls,UPW=155K, ONW=113K,tag up at 7406'MD shut dn pump,61 bbls pumped. 21:30 22:00 0.50 22.00 W.O. K 4 P R/D head pin and cement line,UD 3 jnts to shed. 22:00 23:00 1.00 23.00 W.O. K 4 P B/D cement line,M/U safety valve,figure space out,P/U pups from shed. 23:00 00:00 1.00 24.00 W.O. K 4 P M/U pups in string for space out,P/U last jot from shed M/U same.109 bbls losses this tour. Gas Readings Avg Background Gas(%( Max Background Gas(%) Avg Connection Gas)%) Max Connection Gas(%) Avg Drill Gas(%) Max Drill Gas(%) Avg Trip Gas(%) 'Max Trip Gas(%) Cumulative Mud Volumes Active Volume(bbl) Hole Volume(bbl) Losses(bbl) Cum Additions(bbl) Additions(bbl) Cum Losses(bbl) Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Bruce Simonson ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Mitch Billington ENI Rig Clerk 907-685-0722 Eni representative Troy England ENI HSE Tool Push Kelly Cozby Nabors Alaska Drilling Tool Pusher Tool Push Wesley Jeardoe Nabors Alaska Drilling Tool Pusher 0 • Well Name: OP22-WW03riTR Daily Report Wellbore Name: OP22-WW03 1/8/2016 Well Code: 27295 ReportDte:Page:e #: 6 2 Job: WORKOVER ge:2 of 26 of 2 Personnel Log(POB) Company Serv.Type Work H(hr) Stand-by H(hr) Count Note Beacon HSE 12.00 1 Solsten Clerk 12.00 1 MI Swaco Mud Engineer 12.00 1 Vetco Wellhead 12.00 1 SLB SCSSV Tech 12.00 1 Baker Hughes Tool Hand 12.00 1 Solsten Drilling Supervisor 12.00 2 GBR Casing hands 12.00 2 CH2M Truck Driver 12.00 4 Baker Centrilift ESP 12.00 4 NABORS Rig Crew 12.50 • 24 BOP Stack&Components Description Start Date Last Certification Date Pressure Rating(psi) 13 5/8 11/1/2016 8/20/2016 5,000.0 Type Make Model ID Nom(in) P Range(psi) Last Cert Date Stack Hydril -GK 135/8 5,000.0 8/20/2016 Upper rams Hydril 3 1/2 X 6"VBR 13 5/8 5,000.0 8/20/2016 Middle rams Hydril Blind Shears 13 5/8 5,000.0 8/20/2016 Lower rams Hydril 3 1/2 X 6"VBR 13 5/8 5,000.0 8/20/2016 Slow Circulation Rates Pump Number: Make: Model: Start Date End Date Liner Size(in) Volume Per Stroke Override(bbl/stk) Max Pressure(psi) Date Depth(ftKB) Slow Spd Strokes(spm) P(psi) Eff(%( 0 Flow(gpm) Daily Bulk Supply Item Description: EQUIPMENT FUEL Unit Label:Gallons Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 11/8/2016 560.0 560.0 12,373.0 12,373.0 0.0 0.0 Supply Item Description: NAD 245E Diesel Fuel Unit Label:gal us Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 11/8/2016 1,642.0 10,000.0 31,730.0 52,310.0 0.0 20,580.0 Supply Item Description: NAD 245E Rig Water Unit Label:bbl Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 11/8/2016 35.0 0.0 1,311.0 1,625.0 0.0 314.0 Last Authority Visit Date Tot insp.Nbr Total I.N.C.number Comment 11/8/2016 BOP Test due,AOGCC Chuck Sheve granted extention of BOP Test 11/8/2016 @ 06:08 AM(Landing Completion today) STOP Cards Submitted Company #Rpts Com NABORS ALASKA DRILLING 13 STOP Cards NABORS ALASKA DRILLING 24 PJSM General Notes Comment: • Well Name: OP22-WW03' Daily Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 11/9/2016 • Report#: 27 2n 0 Job: WORKOVER Page:1 of 2 Well Header Permit/Concession N° Operator Subsidiary 'Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Ground Level(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 0.00 16.38 36.62 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date NABORS 245 NABORS ALASKA LAND RIG 0637 10/14/2016 Daily Information Weather Temperature(°F) Wind Days LTI(days) Days RI(days) FOB Overcast/Snow 0.0 S @ 12 MPH 42.0 Cost Summary Job Account Currency Code Total AFE Amount(Cost) Daily Cost(Cost) Cumulative Cost(Cost) Daily Mud Field Est(Cost) Cumulative mud Cost(Cost) 7683 USD 5,049,784 125,553 2,992,179 1,181 138,551 Safety Incidents-Near Miss Date Category Type Subtype Severity Cause Lost time? 11/9/2016 Non-Recordable Unsafe Condition Other Minor No Comment UC-Nine wire protruding at outside stairwell(eni) Date Category Type Subtype Severity Cause Lost time? 11/9/2016 Non-Recordable Unsafe Condition Other Minor No Comment UC-NOC Camp fire hose and associated hanger removed(eni) Date Category Type Subtype Severity Cause Lost time? 11/9/2016 Non-Recordable Unsafe Condition Other Minor No Comment UC-Snow shed potential at NOC Camp(eni) Date Category Type Subtype Severity Cause Lost time? 11/9/2016 Non-Recordable Unsafe Condition Other Minor No Comment UC-Indent/wear mark on positive battery cable(ASRC) Safety Drills Days Until Next Check Type 8 Occur Last Date Next Date (days) Authority Visit 3 11/8/2016 11/25/2016 16 BOP Drill 1 11/3/2016 11/10/2016 1 Fire Drill 18 11/9/2016 11/23/2016 14 Kick While Tripping 4 11/8/2016 11/15/2016 6 Man Down Drill 2 11/9/2016 11/23/2016 14 Rig Inspection 27 11/9/2016 11/10/2016 1 Safety Meeting 27 11/9/2016 11/10/2016 1 Spill Drill 16 11/8/2016 11/22/2016 13 Casings seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(RKB) TVD Bot.(RKB) Run Date • CASING 133/8 12.42 L-80 -0.8 4,020.0 3,727.6 7/12/2013 CASING 9 5/8 8.84 L-80 0.1 7,631.0 6,526.8 7/29/2013 LINER 7 6.18 L-80 7,396.8 10,668.0 9,513.5 8/5/2013 Last Cementing Cementing Start Date: 8/6/2013 String:LINER,10,668.0ftKB Comment: Stg# Top(RKB) Top Meas Meth Btm(ftKB) Com 1 7,396.0 Volume Calculations 10.658.0 Job Information Job Phase Planned Start Date Start Date End Date P50 Duration(days) P50 Cost(Cost) WORKOVER 10/14/201600:00 10/14/2016 12:00 0.00 0 Daily Summary Operations 24h Forecast L Test pack off and Tree to 5,000 PSI for 10 Min aspen Vetco.R/U lines and LRS.Test IA on chart 1,500 PSI for 15 Min.Press.up to 2,000 PSI and shear valve with LRS.Pump Freeze Protect-120 bbl Diesel down , ►� IA taking returns to rig.Shut in well and RDMO. 24h Summary PJSM R/U pump ASSY.Lines to Hanger and landing joint.Orient Hanger as per Vetco Grey rep onsite.Install Penetrator and connect lower connectors.Terminate chemical lines and SSSV control line through Hanger.R/U return hose Assy.PJSM spotting Brine and corrosion inhibitor.Lower Hanger below Annular Preventer.Close Preventer on landing joint.Pump 150 bbl 9.5 ppg Brine W/corrosion inhibitor and put in n place with 130 bbl 9.5 ppg Brine at 3 bpm,25 PSI ICP.Land Hanger.Note total of 176 Cannon Clamps and 8 stainless steel bands.Vetco Grey RILDS and PT Hanger void and Pack Off to 5,000 PSI for 10 Min. v / Witnessed by ENI Co Rep.PJSM R/D Kill Line F/BOPE.M/U HP hose and test pump to IA.Cont.to R/U to test IA.Fill IA W/10 bbl Brine and purge air out.Test IA to 1,500 PSI for 30 Min on chart regardrr. SIMOPS UD Baker completion tools.R/D testing Equip.R/D landing joint and P/U TBar and set BPV as per Vetco Rep onsite.UD third party tools,pull CAP Tube and ESP lines back to Spooler Unit.R/D control sheaves from Derrick.Clear rig floor of tools.N/D BOPE.Pull and UD mouse hole to Pipe Shed.Secure rig floor.Pull master bushing and set hand rails around rotary table.De Energize Koomey unit.R/D Katch Kan,Bell Nipple,Choke line.Hook up Bridge Crane to BOPE and set on stump.Back out Greylock and pull high Press.riser to rig floor,UD to Pipe Shed.P/U Tree from Pipe Shed.Vetco and SLB SSSV Rep prep well head for Tree.SIMOPS Move pipe bunks,spooling unit and Tiger Tank to AFP.Set Tree on well head and N/U as per Vetco Grey Rep onsite. Operation at 07.00 Freeze Protect well. Time Log Start End Cum Dur End Depth Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. (RKB) 00:00 02:00 2.00 2.00 W.O. K 19 P PJSM R/U pump ASSY.Lines to Hanger and landing joint.Orient Hanger as per Vetco Grey rep onsite. 02:00 05:00 3.00 5.00 W.O. K 20 P Install Penetrator and connect lower connectors.Terminate chemical lines and SSSV control line through Hanger. 05:00 08:00 3.00 8.00 W.O. K 9 P R/U return hose Assy.PJSM spotting Brine and corrosion inhibitor.Lower Hanger below Annular Preventer. Close Preventer on landing joint.Pump 150 bbl 9.5 ppg Brine W/corrosion inhibitor and put in place with 130 bbl 9.5 ppg Brine at 3 bpm,25 PSI ICP.Land Hanger.Note total of 176 Cannon Clamps and 8 stainless steel bands. 08:00 10:00 I 2.00 10.00 W.O. C 12 P Vetco Grey RILDS and PT Hanger void and Pack Off to 5,000 PSI for 10 Min.Witnessed by ENI Co Rep. 10:00 12:00 2.00 12.00 W.O. C 1 P PJSM R/D Kill Line F/BOPE.M/U HP hose and test pump to IA. 12:00 14:30 I 2.50 14.50 W.O. C 12 P Cont.to R/U to test IA.Fill IA W/10 bbl Brine and purge air out.Test IA to 1,500 PSI for 30 Min on chart recorder.SIMOPS UD Baker completion tools.R/D testing Equip. • 14:30 15:00 I 0.50 15.00 W.O. C 20 P R/D landing joint and P/U TBar and set BPV as per Vetco Rep onshe. 15:00 17:00 2.00 17.00 W.O. K 20 P UD third party tools,pull CAP Tube and ESP lines back to Spooler Unit.R/D control sheaves from Derrick. Clear rig floor of tools. 17:00 20:00 3.00 20.00 W.O. C 5 P N/D BOPE.Pull and UD mouse hole to Pipe Shed.Secure rig floor.Pull master bushing and set hand rails • around rotary table.De Energize Koomey unit.R/D Katch Kan,Bell Nipple,Choke line.Hook up Bridge Crane • to BOPE and set on stump. I • Well Name: OP22-WW03 Daily Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 11/912016 Job: WORKOVER Pa Page: #: 27 2 of 2 Time Log Start End Cum Dur End Depth Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. (ftKB) 20:00 23:00 3.00 23.00 W.O. C 5 P Back out Greylock and pull high Press.riser to rig floor,UD to Pipe Shed.P/U Tree from Pipe Shed.Vetco and SLB SSSV Rep prep well head for Tree.SIMOPS Move pipe bunks,spooling unit and Tiger Tank to AFP. 23:00 00:00 1.00 24.00 W.O. C 5 P 7 Set Tree on well head and N/U as per Vetco Grey Rep onsite. Gas Readings Avg Background Gas(%) Max Background Gas(%( Avg Connection Gas(%) Max Connection Gas(%) Avg Drill Gas(%) Max Drill Gas(%) Avg Trip Gas(%) Max Trip Gas(%) Cumulative Mud Volumes Active Volume(bbl) Hole Volume(bbl) Losses(bbl) Cum Additions(bbl) Additions(bbl) Cum Losses(bbl) Daily Contacts Position Contact Name Company Title Email _ Office Mobile Eni representative Bruce Simonson 'ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. SIDDrilling@enipelroleum.com 907-685-0715 Eni representative Troy England ENI HSE Tool Push Tony Morales Nabors Alaska Drilling Tool Pusher Tool Push Wesley Jeardoe Nabors Alaska Drilling Tool Pusher • Personnel Log(POB) Company Serv.Type Work H(hr) Stand-by H(hr) Count Note Beacon HSE 12.00 1 Solsten Clerk 12.00 1 MI Swaco Mud Engineer 12.00 1 Vetco Wellhead 12.00 1 SLB SCSSV Tech 12.00 1 Baker Hughes Tool Hand 12.00 1 Solsten Drilling Supervisor 12.00 2 GBR Casing hands 12.00 2 CH2M Truck Driver 12.00 4 Baker Centrilift ESP 12.00 4 NABORS Rig Crew 12.50 24 BOP Stack&Components Description Start Date Last Certification Date Pressure Rating(psi) 135/8 11/1/2016 8/20/2016 5,000.0 Type Make Model ID Nom(in) P Range(psi) Last Cert Date Stack Hydril GK 13 5/8 5,000.0 8/20/2016 Upper rams Hydril 3 1/2 X 6"VBR 13 5/8 5,000.0 8/20/2016 Middle rams Hydril Blind Shears 13 5/8 5,000.0 8/20/2016 Lower rams Hydril 3 1/2 X 6"VBR 13 5/8 5,000.0 8/20/2016 Slow Circulation Rates Pump Number: Make: Model: Start Date End Date Liner Size(in) Volume Per Stroke Override(bbl/stk) Max Pressure(psi) Date Depth(ftKB) Slow Spd Strokes(spm) P(psi) Eff(14) Q Flow(gpm) Daily Bulk Supply Item Description: Equipment Fuel Unit Label:Gallons Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 11/9/2016 853.0 853.0 13,226.0 13,226.0 0.0 0.0 Supply Item Description: Rig Fuel Unit Label:gal us Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 11/9/2016 2,100.0 33,830.0 52,310.0 0.0 18,480.0 Supply Item Description: Rig Water Unit Label:bbl Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note • 11/9/2016 43.0 1,354.0 1,625.0 0.0 271.0 Last Authority Visit • Date Tot insp.Nbr Total I.N.C.number Comment 11/8/2016 BOP Test due,AOGCC Chuck Sheve granted extention of BOP Test 11/8/2016 @ 06:08 AM(Landing Completion today) • • STOP Cards Submitted • Company #Rpts Com NABORS ALASKA DRILLING 16 STOP Cards NABORS ALASKA DRILLING 24 PJSM • General Notes Comment: • IT,* Well Name: OP22-WW03' Daily Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 11/10/2016 p Report#: 28 ��II Job: WORKOVER Page:1 of 2 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Ground Level(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 0.00 16.38 36.62 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date NABORS 245 NABORS ALASKA LAND RIG 0637 10/14/2016 Daily Information Weather Temperature(°F) Wind Days LTI(days) Days RI(days) POB Overcast/Snow 22.0 E @ 38 MPH 34.0 Cost Summary - Job Account Currency Code Total AFE Amount(Cost) Daily Cost(Cost) Cumulative Cost(Cost) Daily Mud Field Est(Cost) Cumulative mud Cost(Cost) 7683 USD 5,049,784 152,379 3.144,758 138,551 Safety Incidents-Near Miss Date Category Type Subtype Severity Cause Lost time? Comment Safety Drills Days Until Next Check Type #Occur Last Date Next Date (days) Authority Visit 3 11/8/2016 11/25/2016 15 BOP Drill 1 11/3/2016 11/10/2016 0 Fire Drill 18 11/9/2016 11/23/2016 13 Kick While Tripping 4 11/8/2016 11/15/2016 5 Man Down Drill 2 11/9/2016 11/23/2016 13 Rig Inspection 27 11/9/2016 11/10/2016 0 Safety Meeting 27 11/9/2016 11/10/2016 0 Spill Drill 18 11/10/2016 11/24/2016 14 Casings seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) TVD Bot.(ftKB) Run Date CASING 133/8 12.42 L-80 -0.8 4,020.0 3,727.6 7/12/2013 CASING 9 5/8 8.84 L-80 0.1 7,631.0 6,526.8 7/29/2013 LINER 7 6.18 L-80 7,396.8 10,668.0 9,513.5 8/5/2013 Last Cementing Cementing Start Date: 8/6/2013 String:LINER,10,668.0ftKB Comment: Stg# Top(RKB) Top Meas Meth Btm(ftKB) Com 1 7,396.0 Volume Calculations 10,658.0 Job Information Job Phase Planned Start Date Start Date End Date P50 Duration(days) P50 Cost(Cost) WORKOVER 10/14/2016 00:00 10/14/2016 12:00 0.00 0 Daily Summary Operations 24h Forecast Cont.to R/D and move rig. 24h Summary PT Tree void 5000 PSI./10 MIN.on chart,witnessed Co Rep onsite.Pull BPV&install TWC,R/U&chart PT Tree 5000 psi 10min.,pull TWC as per Vetco Rep onsite.Centrilift rep.check.ESP cable/motor electrical integrity&conductivity. SLB Rep.open SSSV&PT to 5000 psi.15 min.R/U to Freeze Protect 9 5/8"x 4 1/2"ann.PJSM w/all personnel,Chart and record,PT lines to 2500 psi,Test IA to 1,500 PSI for 15 Min.on chart,shear GLM valve at 2,100 PSI. Pump 141 bbls 35°F Diesel @ 2bpm,blow down line&R/D,Remove tools from well bay,remove 1502 flange from IA.Install blank flange,blow down mud pumps 1,2,3,offload brine F/pits 1,2,4,Cont prep F/rig move raise and secure Dixie Cup,raise curtains,secure cellar.clean pits,weld pad eye at base of beaver slide for wire line,prep stomper to lift and hang,spot tall crib blocks for rig move,clean and lube Lampson tables,blow down mud pumps drain and secure for move.hook up power cord to auxiliary generator warm up same.All active pits drained and cleaned,swap power on utility to aux generator,lubricate Lampson chain and table,verify motors will start warm up same.Disconnect electrical and charge pump room inner connects.Remove berthing from Sub Module. Operation at 07.00 Cont.rigging down and prep for moving rig. Time Log Start End Cum Dur rEnd Depth Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. (ftKB) 00:00 01:00 1.00 1.00 W.O. C 12 P PT Tree void 5000 PSI./10 MIN.on chart,witnessed Co Rep onsite. 01:00 03:00 2.00 3.00 W.O. C - 12 P Pull BPV&install TWC,R/U&chart PT Tree 5000 psi 10min.,pull TWC as per Vetco Rep onsite..Centrilift rep.check.ESP cable/motor electrical integrity&conductivity. SLB Rep.open SSSV&PT to 5000 psi.15 min. 03:00 09:30 6.50 9.50 W.O. K 9 P R/U to Freeze Protect 9 5/8"x 4 1/2"ann.PJSM w/all personnel,Chart and record,PT lines to 2500 psi,Test IA to 1,500 PSI for 15 Min.on chart,shear GLM valve at 2,100 PSI. Pump 141 bbls 35°F Diesel @ 2bpm, blow down line&R/D,Remove tools from well bay,remove 1502 flange from IA.Install blank flange,blow down mud pumps 1,2,3,offload brine F/pits 1,2,4, � 09:30 11:30 2.00 11.50 W.O. K 9 P R/U LRS to 4 1/2"TBG chart/record pt 2500 psi,pump 30 bbls.Diesel down 4 1/2"TBG @ 2bpm,R/D, remove pump in flange to blank flange TBG. 11:30 17:30 6.00 17.50 W.O. A 1 P Con't prep F/rig move raise and secure Dixie Cup,raise curtains,secure cellar.clean pits,weld pad eye at base of beaver slide for wire line,prep stomper to lift and hang,spot tall crib blocks for rig move,clean and lube Lampson tables,blow down mud pumps drain and secure for move.hook up power cord to auxiliary generator warm up same. 17:30 23:30 6.00 23.50 W.O. A 1 P All active pits drained and cleaned,swap power on utility to aux generator,lubricate Lampson chain and table, verity motors will start warm up same.Disconnect electrical and charge pump room inner connects.Remove berming from Sub Module. Gas Readings Avg Background Gas)%) Max Background Gas(%) Avg Connection Gas(%) Max Connection Gas(%) Avg Drill Gas(Vol 'Max Drill Gas(%( Avg Trip Gas(%) Max Trip Gas(%) Cumulative Mud Volumes Active Volume(bbl) Hole Volume(bbl) Losses(bbl) Cum Additions(bbl) Additions(bbl) Cum Losses(bbl) Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Bruce Simonson ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Troy England ENI HSE Tool Push Tony Morales Nabors Alaska Drilling Tool Pusher Well Name: OP22-WW033 Daily Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 11110/2016 Job: WORKOVER P Page: #: 28 2 of 2 Daily Contacts Position Contact Name Company Title Email Office Mobile Tool Push Wesley Jeardoe Nabors Alaska Drilling Tool Pusher Personnel Log(POD) Company Serv.Type I Work H(hr) I Stand-by H(hr) Count Note Beacon HSE 12.00 1 MI Swans Mud Engineer 12.00 1 Baker Centrilift ESP 12.00 1 Vetco Wellhead 12.00 1 Solsten Drilling Supervisor 12.00 2 CH2M Truck Driver 12.00 4 NABORS Rig Crew 12.50 24 BOP Stack&Components Description Start Date Last Certification Date Pressure Rating(psi) 13 5/8 11/1/2016 8/20/2016 5,000.0 Type Make Model ID Nom(in) P Range(psi) Last Cert Date Stack Hydril GK 13 5/8 5,000.0 8/20/2016 Upper rams Hydril 3 1/2 X 6"VBR 13 5/8 5,000.0 8/20/2016 Middle rams Hydril Blind Shears 13 5/8 5,000.0 8/20/2016 Lower rams Hydril 3 1/2 X 6"VBR 13 5/8 5,000.0 8/20/2016 Slow Circulation Rates Pump Number: Make: Model: Start Date End Date Liner Size(in) Volume Per Stroke Override(bbl/stk) Max Pressure(psi) Date Depth(ftKB) Slow Spd Strokes(spm) P(psi) Eff)%) O Flow(gpm) Daily Bulk Supply Item Description: Equipment Fuel Unit Label:Gallons Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 11/10/2016 1,349.0 1,349.0 14,575.0 14,575.0 0.0 0.0 Supply Item Description: Rig Fuel Unit Label:gal us Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 11/10/2016 2,184.0 36,014.0 52,310.0 0.0 16,296.0 Supply Item Description: Rig Water Unit Label:bbl Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 11/10/2016 67.0 1,421.0 1,625.0 0.0 204.0 Last Authority Visit Date Tot insp.Nbr Total I.N.C.number Comment 11/8/2016 BOP Test due,AOGCC Chuck Sheve granted extention of BOP Test 11/8/2016 @ 06:08 AM(Landing Completion today) STOP Cards Submitted Company #Rpts Com NABORS ALASKA DRILLING 47 PJSM NABORS ALASKA DRILLING 16 STOP Cards General Notes Comment: • • tiro liot Well Name: OP22-WW03' DailyReport Wellbore Name: OP22- 03 p Well Code: 27295 Date: 016 ort#: 29 • Re evil Job: WORKOVER Page:1 of 2 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Ground Level(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 0.00 16.38 36.62 Rigs Rig Name Contractor Rig Type Rig Num Rig Start Date Rig Release Date NABORS 245 NABORS ALASKA LAND RIG 0637 10/14/2016 Daily Information Weather Temperature(CF) Wind Days LTI(days) Days RI(days) POB Overcast/Snow 21.0 E @ 8 MPH 33.0 Cost Summary Job Account Currency Code Total AFE Amount(Cost) Daily Cost(Cost) Cumulative Cost(Cost) Daily Mud Field Est(Cost) Cumulative mud Cost(Cost) 7683 USD 5,049,784 94,247 3.239,006 138.551 Safety Incidents-Near Miss Date Category Type Subtype Severity Cause Lost time? 11/11/2016 No Comment Safety Drills Days Until Next Check Type #Occur Last Date Next Date (days) Authority Visit 3 11/8/2016 11/25/2016 14 BOP Drill 1 11/3/2016 11/10/2016 -1 Fire Drill 18 11/9/2016 11/23/2016 12 Kick While Tripping 4 11/8/2016 11/15/2016 4 Man Down Drill 3 11/11/2016 11/25/2016 14 Rig Inspection 27 11/9/2016 11/10/2016 -1 Safety Meeting 27 11/9/2016 11/10/2016 -1 Spill Drill 18 11/10/2016 11/24/2016 13 Casings seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(RKB) TVD Bot.(RKB) Run Date CASING 133/8 12.42 L-80 -0.8 4,020.0 3,727.6 7/12/2013 CASING 9 5/8 8.84 L-80 0.1 7,631.0 6,526.8 7/29/2013 LINER 7 6.18 L-80 7,396.8 10,668.0 9,513.5 8/5/2013 Last Cementing Cementing Start Date: 8/6/2013 String:LINER,10,668.0ftKB Comment: Stg# Top(RKB) Top Meas Meth Btm(ftKB) Com 1 7,396.0 Volume Calculations 10,658.0 Job Information Job Phase Planned Start Date Start Date End Date P50 Duration(days) P50 Cost(Cost) WORKOVER 10/14/2016 00:00 10/14/2016 12:00 0.00 0 Daily Summary Operations 24h Forecast Cont.to move Drill Mod next to production facility.Move out utility module next to well bay.Move Drill mod towards OP26-DSP02. 24h Summary Off load fluids from Raw Mud Pits 4&5.Transfer rig water from Sub Mod to Utility Mod.Blow down water lines in Sub Mod.Inspect and clean Lampson tracks.Stage spill response.Remove berming from around rig.Move cutting box.Blow down Sub Mod and secure Derrick climber in Derrick,tie off weight bucket.Disconnect lines and pull back inner connects.Stage tall crib blocks on Lampsons.Raise Lampson curtains and secure.Warm up jack hydraulics and cylinders.Set rig on tall shipping blocks.Disconnect hydraulic hoses to jacking cylinders.Raise stomper beam and secure hanging cables.Roll up curtains on Utility Mod. Build ramps to come off sub malts.Start Sub Mod Lampson motors.Remove split hatch from over well.Pull Sub Mod off Matt boards.Install permanent hatch cover over well.Spin Sub 180 degree.Line up to park next to production mod. Operation at 07.00 Cont.to move rig. Time Log Start End Cum Dur End Depth Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. (RKB) 00'00 1200 12.00 12.00 W.O. A 20 P Off load fluids from Raw Mud Pits 4&5.Transfer rig water from Sub Mod to Utility Mod.Blow down water lines in Sub Mod.Inspect and clean Lampson tracks.Stage spill response.Remove berming from around rig.Move cutting box.Blow down Sub Mod and secure Derrick climber in Derrick,tie off weight bucket.Disconnect lines and pull back inner connects.Stage tall crib blocks on Lampsons.Raise Lampson curtains and secure.Warm up jack hydraulics and cylinders.Set rig on tall shipping blocks.Disconnect hydraulic hoses to jacking cylinders.Raise stomper beam and secure hanging cables. 12:00 00:00 12.00 24.00 W.O. A 2 P .Roll up curtains on Utility Mod.Build ramps to come off sub malts.Start Sub Mod Lampson motors.Remove split hatch from over well.Pull Sub Mod off Matt boards.Install permanent hatch cover over well.Spin Sub 180 degree.Line up to park next to production mod. Gas Readings Avg Background Gas(%( Max Background Gas(%( Avg Connection Gas(%) Max Connection Gas(%) Avg Drill Gas(%) Max Drill Gas(%) Avg Trip Gas(%) Max Trip Gas(%) Cumulative Mud Volumes Active Volume(bbl) Hole Volume(bbl) Losses(bbl) Cum Additions(bbl) Additions(bbl) Cum Losses(bbl) Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Bruce Simonson ENI Drilling Supv. SIDDrilling@enipetroleum.com 1907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Paul Holley ENI HSE Tool Push Tony Morales Nabors Alaska Drilling Tool Pusher Tool Push Brian Tiedemann Nabors Alaska Drilling Tool Pusher Personnel Log(P08) Company Serv.Type Work H(hr) Stand-by H(hr) Count Note Beacon HSE 12.00 1 MI SwamMud Engineer 12.00 1 Vetco Wellhead 12.00 1 Solsten Drilling Supervisor 12.00 2 CH2M Truck Driver 12.00 4 S Well Name: OP22-WW03 Daily Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 11/11/2016 Job: WORKOVER Page:2 29 o Page: of 2 Personnel Log(POB) Company Serv.Type Work H(hr) Stand-by H(hr) Count Note NABORS Rig Crew 12.50 24 BOP Stack&Components Description Start Date Last Certification Date Pressure Rating(psi) 135/8 11/1/2016 8/20/2016 5,000.0 Type Make Model ID Nom(in) P Range(psi) Last Cert Date Stack Hydril GK 13 5/8 5,000.0 8/20/2016 Upper rams Hydril 3 1/2 X 6"VBR 13 5/8 5,000.0 8/20/2016 Middle rams Hydril Blind Shears 13 5/8 5,000.0 8/20/2016 Lower rams Hydril 3 1/2 X 6"VBR 13 5/8 5,000.0 8/20/2016 Slow Circulation Rates Pump Number: Make: Model: Start Date End Date Liner Size(in) Volume Per Stroke Override(bbl/stk) Max Pressure(psi) Date Depth(ftKB) Slow Spd Strokes(spm) P(psi) Eff(%( Q Flow(gpm) Daily Bulk Supply Item Description: Equipment Fuel Unit Label:Gallons Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 11/11/2016 475.0 475.0 15,050.0 15,050.0 0.0 0.0 Supply Item Description: Rig Fuel Unit Label:gal us Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 11/11/2016 1,176.0 0.0 37,190.0 52,310.0 0.0 15,120.0 Supply Item Description: Rig Water Unit Label:bbl Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 11/11/2016 79.0 0.0 1,500.0 1,625.0 0.0 125.0 Last Authority Visit Date Tot insp.Nbr Total I.N.C.number Comment 11/8/2016 BOP Test due,AOGCC Chuck Sheve granted extention of BOP Test 11/8/2016 @ 06:08 AM(Landing Completion today) STOP Cards Submitted Company #Rpts Com NABORS ALASKA DRILLING 17 STOP Cards NABORS ALASKA DRILLING 27 PJSM General Notes Comment: 0 Well Name: 0P22-WW03 Daily Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 11/1212016 • Report#: 30 en II Job: WORKOVER Page:1 of 2 Well Header Permit/Concession N° Operator Subsidiary Initial Lahee Code ALASKA ENI PETROLEUM ENI Petroleum Co.Inc. DEVELOPMENT WELL Rotary Table Elevation(ft) Ground Level(ft) First Flange(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 0.00 16.38 36.62 Rigs Rig Name .. Contractor Rig Type Rig Num Rig Start Date Rig Release Date NABORS 245 NABORS ALASKA LAND RIG 0637 10/14/2016 Daily Information Weather Temperature(°F) Wind Days LTI(days) Days RI(days) FOB Overcast 17.0 SW @ 23 MPH 33.0 Cost Summary Job Account Currency Code Total AFE Amount(Cost) Daily Cost(Cost) Cumulative Cost(Cost) Daily Mud Field Est(Cost) Cumulative mud Cost(Cost) 7683 USD 5,049,784 66,185 3,305,190 138,551 Safety Incidents-Near Miss Date Category Type Subtype Severity Cause Lost time? 11/12/2016 Non-Recordable Near Miss Other Minor No Comment NM-Employee in area without required PPE-Nabors Drilling Inc. Date Category Type Subtype Severity Cause Lost time? 11/12/2016 Non-Recordable Unsafe Condition Other Minor No Comment UC-Test pump hose without a safety restraint(whip check)device-Nabors Drilling Inc. Date Category Type Subtype Severity Cause Lost time? 11/12/2016 Non-Recordable Near Miss Caught Between Minor No Comment NM-Contractor in the line of fire at Nabors 245 beaver slide.-Nabors Drilling Inc. Date Category Type Subtype Severity Cause Lost time? 11/12/2016 Non-Recordable Unsafe Condition Other Minor No Comment UC-Self Retracting Lanyard improperly stored-Nabors Drilling Inc. Date Category Type Subtype Severity Cause Lost time? 11/12/2016 Non-Recordable Unsafe Condition Other Minor No Comment :Heater Trunk Melts Ice Creating Tripping Hazard-eni US Operating Safety Drills Days Until Next Check Type 6 Occur Last Date Next Date (days) Authority Visit 3 11/8/2016 11/25/2016 13 BOP Drill 1 11/3/2016 11/10/2016 -2 Fire Drill 18 11/9/2016 11/23/2016 11 Kick While Tripping 4 11/8/2016 11/15/2016 3 Man Down Drill 3 11/11/2016 11/25/2016 13 Rig Inspection 27 11/9/2016 11/10/2016 -2 Safety Meeting 27 11/9/2016 11/10/2016 -2 Spill Drill 20 11/12/2016 11/26/2016 14 Casings seat Cas.Type OD(in) ID(in) Grade __ Top(RKB) Bottom(ftKB) TVD Bot.(RKB) Run Date CASING 13 3/8 12.42 L-80 -0.8 4,020.0 3,727.6 7/12/2013 CASING 9 5/8 8.84 L-80 0.1 7,631.0 6,526.8 7/29/2013 LINER 7 6.18 L-80 7,396.8 10,668.0 9,513.5 8/5/2013 Last Cementing Cementing Start Date: 8/6/2013 String:LINER,10,668.0ftKB Comment: Stg 8 Top(RKB) Top Meas Meth Btm(ftKB) Corn 1 7,396.0 Volume Calculations 10,658.0 Job Information Job Phase Planned Start Date Start Date End Date P50 Duration(days) P50 Cost(Cost) WORKOVER 10/14/2016 00:00 10/14/2016 12:00 0.00 0 Daily Summary Operations 24h Forecast RDMO Last report. 24h Summary Get sub turned&positioned to pull off pad to park,lay mats,pull sub off of pad&park next to plant.Jack up utility module,start crawlers,pull off of mats maneuver rig to pull off of pad. Move and spot utility mod outside of horse shoe.Prep pad for Herculite and rig malt's.Move sub mod back in horse shoe.Turn utility mod 180 degree.Spot utility mod next to sub.Lower stomper and cellar box into position for mouse hole removal Roll out Herculite and begin setting rig matt's. Operation at 07.00 End of well. Time Log Start End Cum Dur End Depth Time Time Dur(hr) (hr) Phase Opr. Act. Plan Oper.Descr. (ftKB) 00:00 12:00 12.00 12.00 W.O. A 2 - P Get sub turned&positioned to pull off pad to park,lay mats,pull sub off of pad&park next to plant.Jack up utility module,start crawlers,pull off of mats maneuver rig to pull off of pad. I 12:00 00:00 12.00 24.00 W.O. A 2 P Move and spot utility mod outside of horse shoe.Prep pad for Herculite and rig matt's.Move sub mod back in home shoe.Turn utility mod 180 degree.Spot utility mod next to sub.Lower stomper and cellar box into position for mouse hole removal.Roll out Herculite and begin setting rig matt's. Gas Readings Avg Background Gas(%) Max Background Gas(14) Avg Connection Gas(%) Max Connection Gas(%) Avg Drill Gas(%) Max Drill Gas(%) Avg Trip Gas(%) Max Trip Gas(%) Cumulative Mud Volumes Active Volume(bbl) Hole Volume(bbl) Losses(bbl) Cum Additions(bbl) Additions(bbl) Cum Losses(bbl) Daily Contacts Position Contact Name Company Title Email Office Mobile - Eni representative Bruce Simonson ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 Eni representative Paul Holley ENI HSE • Well Name: OP22-WW03 Daily Report Wellbore Name: OP22-WW03 Well Code: 27295 Date: 11/12/2016 Job: WORKOVER Page:2 of30 2 Page: 2 Daily Contacts Position Contact Name Company Title Email Office Mobile Tool Push Tony Morales Nabors Alaska Drilling Tool Pusher Tool Push Brian Tiedemann Nabors Alaska Drilling Tool Pusher Personnel Log(POB) Company Serv.Type l Work H(hr) l Stand-by H(hr) Count l Note Beacon HSE 12.00 1 MI Swaco Mud Engineer 12.00 1 Vetco Wellhead 12.00 1 Solsten Drilling Supervisor 12.00 2 CH2M Truck Driver 12.00 4 NABORS Rig Crew 12.50 24 BOP Stack&Components Description Start Date Last Certification Date Pressure Rating(psi) 135/8 11/1/2016 8/20/2016 5,000.0 Type Make Model ID Nom(in) P Range(psi) Last Cert Date Stack Hydril 'OK 135/8 5,000.0 8/20/2016 Upper rams Hydril 3 1/2 X 6"VBR 13 5/8 5,000.0 8/20/2016 Middle rams Hydril Blind Shears 13 5/8 5,000.0 8/20/2016 Lower rams Hydril 3 1/2 X 6"VBR 13 5/8 5,000.0 8/20/2016 Slow Circulation Rates Pump Number: Make: Model: Start Date End Date Liner Size(in) Volume Per Stroke Override(bbl/stk) Max Pressure(psi) Date Depth(ftKB) Slow Spd Strokes)spm) P(psi) Eff(%( Q Flow(gpm) Daily Bulk Supply Item Description: Equipment Fuel Unit Label:Gallons Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 11/12/2016 1,279.0 1,279.0 16,329.0 16,329.0 0.0 0.0 Supply Item Description: Rig Fuel Unit Label:gal us Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 11/12/2016 1,050.0 0.0 38,240.0 52,310.0 0.0 14,070.0 Supply Item Description: Rig Water Unit Label:bbl Unit Size: Note: Date Consumed Received Returned Cum Consumed Cum Received Cum Returned Cum On Loc Note 11/12/2016 13.0 0.0 1,513.0 1,625.0 0.0 112.0 Last Authority Visit Date Tot insp.Nbr Total I.N.C.number Comment 11/8/2016 BOP Test due,AOGCC Chuck Sheve granted extention of BOP Test 11/8/2016 @ 06:08 AM(Landing Completion today) STOP Cards Submitted Company #Rpts Com NABORS ALASKA DRILLING 15 PJSM NABORS ALASKA DRILLING 10 STOP Cards General Notes Comment: PV OF ?jib • • 4. THE STATE Alaska Oil and Gas 7,1 of J\ LJ� Conservation Commission KA 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Marc Kuck Well Operations Manager SCANNED JAN 0 9 ZUI17, Eni US Operating Co. Inc. 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Ivishak Undefined WTRSP Pool, OP22-WW03 Permit to Drill Number: 213-054 Sundry Number: 316-310 Dear Mr. Kuck: 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, f Cathy P. oerster Chair DATED this erlay of June, 2016. RBDMS AA 1 3 2016 ,. .„, IED • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION JU\I 0 3 _O1 APPLICATION FOR SUNDRY APPROVALS OSr 1f6. 20 AAC 25.280 AOG 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑✓ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. _ESP Change Out 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Eni US Operating Co.Inc. Exploratory ❑ Development ❑ 213-054 3.Address: Stratigraphic ❑ Service ❑� • 6.API Number. 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 50-029-23489-00-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No ( ' A OP22-WW03 • 9.Property Designation(Lease Number): 10.Field/Pool(s): 0373301, 0355024, 0390616 Nikaitchuq 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10,676 - 9,521 - 10,675 - 9,521 - 3,369 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 154 20" 154 154 Surface 4020 13 3/8" 4020 3728 5,210 2,480 Intermediate 7632 9 5/8" 7632 6475 6,890 4,790 Production Liner 3278 7" 10675 9521 7240 5410 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9,925-10,308 , 8,773-9,155 4 1/2" 13 Cr L-80 7,397 Packers and SSSV Type: TR-MARX 5 E SSSV 3.81""X profile 1/4"SS Packers and SSSV MD(ft)and TVD(ft): -SSSV 2,314'MD/2,300'ND hyd control line 12.Attachments: Proposal Summary Q Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program El BOP Sketch ❑✓ Exploratory ❑ Stratigraphic ❑ Development ❑ Service ❑✓ 14.Estimated Date for 15-Aug-16 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ M WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: ./Water Source GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Amjad Chaudhry Email amjad.chaudhry@enipetroleum.com Printed Name Marc Kuck 907-865-3328 Title Well Operations Manager 907-865-3379 SignaturePhone 77 Dat COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3\.Lk— l0 Plug Integrity ❑ BOP Test WI Mechanical Integrity Test ❑ Location Clearance ❑ Other: -t 3500 /5 6 d P .7.---e, 1-- Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDMS IA( JUN 1 3 2016 � Spacing Exception Required? Yes ❑ No / Subsequent Form Required: 1 6 " `•J©4 APPROVED BY Approved by: ttaiLCOMMISSIONER THE COMMISSION Date: (p —g_/ 0 RpfG4NtA4lid Form 10-40ised11/2015 for 12 months ro ate Of appfOval. Attachments in Duplicate • • two-` RECEIVED j� EnH ��N o • 3 2016 2n n AOGCC 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Marc Kuck Phone (907) 865-3322 Email: Marc.kuck@enipetroleum.com June 1st , 2016 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval for OP22-WW03 Rig Workover Dear Commissioners, ENI US Operating Co. Inc.hereby applies for a Workover Sundry for well OP22-WW03 OP22-WW03 was originally completed on August 15th, 2013 with a ESP pump set at depth of 7,397' MD/6315' TVD. Workover was done on this well in April 2015. The ESP has worked until November 3rd 2015 when an electrical failure was occurred. The well has been scheduled for an intervention with Nabors 245 to change out ESP. The estimated date for beginning this work is August 15th , 2016. Please find attached for the review of the Commission forms 10-403 and supporting documentation. If you have any questions or require further information, please contact Amjad Chaudhry at 907-865-3379. Sincerely, ✓ ,�''''..dee' Marc Kuck Well Operations Manager • • • OP22-WW03 Workover— Summary Page OP22-WW03 Rig Workover PTD#:213-054 Current Status Well OP22-WW03 is currently in production in natural flow. Scope of Work Scope of this workover is to pull the current completion and run in with a new ESP system. General Well info Reservoir Pressure/TVD: Reservoir depth is 9925'MD/8773'TVD. This well is expected to have a static max bottom hole pressure of approximately 4300 psi during the time of workover. Wellhead type/pressure rating: Vetco Gray, MB-247/5000 psi BOP configuration: Annular/pipe/blind/Flowcross/pipe TIFL/MIT-IA/MIT-OA: Intermediate csg 9 5/8"was tested 3000 psi x 30' on August 1st 2013 prior to drill out, and 1500 psi x 15' on August 13th 2013 after running completion. Well type: Water Producer Estimated start date: August 15th 2016 Drilling rig: Nabors 245 Drilling/Completion Engineer: Amjad Chaudhry: Amjad.chaudhry@enipetroleum.com Work 907-865-3379 Drilling&Completion Marc Kuck: marc.kuck@enipetroleum.com Engineering Manager: Work: 907-865-3322 • • Procedure: 1. MIRU Nabors 245. 2. R/U on x-tree to pump down tubing. 3. Displace by bullheading tubing and liner volume with 9.5#brine. 4. Shear GLM valve and circulate out diesel. 5. Ensure well is killed. 6. Set BPV. ND tree and NU BOP and test to 3500 psi. 7. Pull tubing hanger and circulate annulus volume with 9.5 #brine. 8. Continue POOH to SSSV and L/D same. 9. Continue POOH and lay down ESP assembly. 10. MU new ESP assembly and RIH to setting depth. 11. Land hanger, and test it. 12. Pressure test IA 1,500 psi x 13. Install BPV and nipple down BOP. 14.NU tubing adapter and tree. 15. Pull BPV, install test plug and test tree.( 5000 psi test) 16. Shear GLM valve and circulate freeze protect through tree down IA. Change out GLM valve. 17. Shut in well. 18. RDMO. Below the current schematic of the well: • • s ii i I 3: z p = f,Q a a ., OC ,...;. , -. a1 ; z . / e , .! ,• • w V p Q 7 LC) LL4a I * =Z r u 4) C CZ N '!'""7--171. I1L,,r111= O1 :»:> '_-'. ®' ili in4 #� • 'i g 611 il W X314 i 11 m<14N&tam ~2 kW lilli; 11 6 Y 1-.,i • s ii '„ :i0 Z v o �a111711111111111111,11111 ! 1 � III jz EMI UIIIiIgI frcsz i 1 V 0.....kill S ( IIN_ N i .,/t h,8 h • • VetcoGray MB-247 SURFACE COMPLETION SYSTEM G—MAN/CL 50 „/" "—IS" 37.19 pi f, Iiiimp. //� 1!•♦ i A IOW iijUoviiiI4P -es �ar• - iH a=te `v x �. .• T.O.S. E 26' 5-3/4" ii � .062 OFFSET CA.,TOP 8.0.5_ EL 25' 7-1/4" \tel TOP OF WELLHEAD 5.00" EL 25' 2-1/4- I� -' )I I FL. P� I.or 3 �� a CTRICAL F�EEOTHR 21.81 I3-5/8'5000 PSI _YA 1 VG S137 CLAMP u6l! 5000 PSI S ,iii . �■I II • CID "Ti. '-mi. IIS �` ____C.pf_f____ ill`.,jJft$ljoi1i3 OfTscr IOB.O 111ill WOO PS -7 yy.1JItIiI_ OUT:SIF —. I i�� 66.71 POSmON VG 34 PSI 52.96' 'Mil1, '' u1 YC 134 MOD. 6.5. S�.I� •l.�7. _! �.. ��1: 34.00' 5000 PSI•n.•:� -di._r:,..�_-- I:=..� OUT OF 24.2 1.11 ' �','' I Posmo# _ � tb.25' •ml. 1• TOP OF GRADING % TOG I ill EL 18' I-1/4- — i L1.00 20" OD 13311 K-55 t.. taillessw 13-3/8" 00 68/ L-804_ALVIM00 ° ENI ALASKA 9-5/8" 00 53.5/ L-80 u.m At HORIZONTAL MULTI-BOWL SYSTEM 4-1/Z" OD WITH 6-5/8 VIT I w.amw 20 X 13-3/8 X 9-5/8 X c X 4-1/2 WITH 6-5/8 Vii out Om AND ESP FLAT CABLE 2.3 Ott.06 D,,Z io,"i0"41.41. 15'l ° H173370-1jA"°'' R v,EACe.�a ar-OLIZ .�.r psi x 1,y-14's olsl PRP 10161, NC 10 OF 10 23 JANUARY 2009 0 • 0.0-01 OP22-WW03 2n 4-/" 13Cr 12.6 ppf Vam Top Production Tubing p2 CrOlCur Wellhead, 13-3/8"x 4-'/2" CR Flow-wetted 5,000 psi Conductor. 20" Uninsulated set at 160 ft Water Producer lVIT Jts,4-'/z"x 6" OD, 204' MD As Completed r 4/13/2015 2215' MD. 2,205' TVD 12° Inc- GLM. 4-'//"x 1". KBG with DCK-2 Ann-to-Tubing 2,000 psi 2314' MD. 2300' TVD, 16°Inc-TR-MAXX 5E SSSV. 3.81" 'X' Profile. '/4' SS hyd. Control line 1 1 4-'/2" cable clamps. for ESP Power Cable, 3/8" Chem In] Line ESP Power Cable 1SOLBC 5KV 90 LD B Galv. " e- \- 3/8"SS Chem lnj Lines 7253' MD. 3.725" Landing Nipple Surf. Casing •• 13-3/8" 68# - 4020' MD, 3728'TVDESP Assy, 31-562P155SXD Pump, GST3 4B Seals. 270 HP KMX Motor \-v 7311' MD. 6241'TVD. 31° Inc •. ,. 7-5/8" 29.7# 13Cr Shroud Assembly e . withPenetrator. (2) Chem Inj Line Feed-Thrus. 7,397' MD—TOL- Flex '-�% Tieback Seal Stem Lock Liner Hanger and ♦ _ ZXP Packer Assy Perf Range 9925'-9953' MD, 8773'-8801' TVD • Interm. Casing 9980'-10047' MD, 8828'-8894'TVD 9-5/8"40#13 Cr . 10064'-10103' MD, 8911'-8950' TVD 7,632' MD, 6,475'TVD 10127'-10188' MD, 8974'-9035' TVD 0223'-10308' MD, 9070'-9155' TVD Approx 5°Inc / Pump Monitoring; P intake T intake Production Liner, P discharge 7" 26#13 Cr 8 1/2" OH T motor 10,675' MD, 9,521' TVD V motor Confidential • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, May 06, 2016 10:20 AM To: 'Chaudhry Amjad' Cc: Wallace, Chris D (DOA) Subject: RE: N2_0P22-WW03_Schematic_AS completed (PTD 213-054) Amjad, The AOGCC doesn't have any issue with a partial N2 cap on the IA for this water source well. When MIT-IA's are done the well would then need to be fluid packed so N2 would be bled off at that time. Guy Schwartz Sr. Petroleum Engineer AOGCC MAY 1 1 2016 907-301-4533 cell SCAT" ° 907-793-1226 office 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 Guy Schwartz at(907-793-1226)or(Guy.schwartz@alaska.gov). From: Chaudhry Amjad [mailto:Amjad.Chaudhry@enipetroleum.com] Sent: Thursday, May 05, 2016 3:11 PM To: Schwartz, Guy L(DOA) Subject: N2_0P22-WW03_Schematic_AS completed Hello Guy, As we spoke over the phone, the plan is to pump the Nitrogen cap on top of Diesel in IA for our water source well(s), after workover is completed on these wells I this coming fall, I was checking to see if it is ok to do so or if there are any specific regulations from the AOGCC we need to follow. I have attached a schematic for OP22- WW03, thanks Best regards Amjad Chaudhry Sr. Drilling Engineer eni us operating co. inc. 3800 Centerpoint Dr.Anchorage,AK W: 907-865-3379 D '2: 907-346-0591 M Email: amjad.chaudhry@enipetroleum.com > o us operating 1 RECEIVED STATE OF ALASKA APR 1 6 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon LI Repair Well Lf Plug Perforations Lf Perforate Li Other Li _ESP Change Out Performed: Alter Casing ❑ Pull Tubing Q Stimulate-Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well ❑ 2.Operator Eni US Operating Co Inc. 4.Well Class Before Work: 5.Permit to Drill Number: Name: Development ❑ Exploratory ❑ 213-0540 3.Address: 3800 Centerpoint Drive,Ste.300,Anchorage, Stratigraphic❑ Service Q 6 API Number: AK 99503 50-029-23489-00-00 7.Property Designation(Lease Number): 8 Well Name and Number: 0373301,0355024,0390616 0P22-WW03 9.Logs(List logs and submit electronic and printed data per 20AAC25 071)• 10.Field/Pool(s). Nikaitchuq Ivishak Undefinited WTRSP 11 Present Well Condition Summary: Total Depth measured 10,676 feet Plugs measured feet true vertical 9,521 feet Junk measured feet Effective Depth measured feet Packer measured feet true vertical feet true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor 154 20" 154 154 Surface 4,020 13.375" 4,020 3,728 5,210 2,480 Intermediate 7,632 9.625" 7,632 6,475 6,890 4,790 Production Liner 3,278 7" 10,675 9,521 7,240 5,410 Perforation depth Measured depth 9,925'-10,308' feet S(°BI"l�,0 , True Vertical depth 8,773'-9,155' feet �b�` Tubing(size,grade,measured and true vertical depth) 4.5" 12.6 ppf L80 13Cr 7,397'MD 6,807'TVD Packers and SSSV(type,measured and true vertical depth) 12 Stimulation or cement squeeze summary: Intervals treated(measured). Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 4200 0 105 Subsequent to operation: 0 0 6700 0 140 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development❑ Service Q Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after we Source Water Q Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ 3USP ❑ SPLUG ❑ 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 315-071 Contact Giuseppe Maugeri Email giuseppe.maugeri@enipetroleum.com Printed Name Marc rKuck Title Drilling&Completion Engineering Manager Signature �� i�j %�//g/ Phone (907)865-3328 Date 4/16/2015 RBDMSJ\k APR 1 8 2015 yzo -f S OP22-WW03 • 4-'/2" 13Cr 12.6 ppf Vam Top Production Tubing 2n o pe r O um Wellhead, 13-3/8" x 4-'/2", CR Flow-wetted 5,000 psi r' Conductor, 20" Uninsulated set at 160 ft Water Producer VIT Jts, 4-1/2°' x 6" OD, 204' MD As Completed I 4/13/2015 2215' MD, 2,205' TVD 12° Inc - GLM, 4-'/2" x 1", KBG with DCK-2 Ann-to-Tubing 2,000 psi 2314' MD, 2300' TVD, 16° Inc - TR-MAXX 5E SSSV, 3.81" 'X' Profile, 1/4" SS hyd. Control line 4-1/2" cable clamps, for ESP Power Cable, 3/8" Chem lnj Line ESP Power Cable 1 SOLBC 5KV 90 LD B Galy. 3/8" SS Chem lnj Lines 7253' MD, 3.725" Landing Nipple Surf. Casing \ 13-3/8" 68 # 4020' MD, 3728' TVD ESP Assy, 31-562P155SXD Pump, GST3 4B Seals, 270 HP KMX Motor \* ' 7311' MD, 6241' TVD, 31° Inc 7-5/8" 29.7# 13Cr Shroud Assembly (2) Chem lnjLine Feed-Thrus, , .�� withPenetrator, 7,397' MD — TOL - FlexTieback Seal Stem Lock oc LinerHanger and ZXP Packer Assy Perf Range 9925'-9953' MD, 8773'-8801' TVD Interco. Casing 9980'-10047' MD, 8828'-8894' TVD 9-5/8" 40 # 13 Cr 10064'-10103' MD, 8911'-8950' TVD 7,632' MD, 6,475' TVD 10127'-10188' MD, 8974'-9035' TVD 0223'-10308' MD, 9070'-9155' TVD • Approx 5° Inc O Pump Monitoring: P intake T intake Production Liner, P discharge 7" 26# 13 Cr 8 1/2" OH T motor 10,675' MD, 9,521' TVD ✓ motor Confidential trip* Eni E&P Division Well Nat 22-WW03 DIR I • EN/Petroleum Co.Inc. Daily Report Well Code:27295 Field Name: Nikaitchup • API/UWI: 50-029-23489-00-00 2 II^r, Date:4/2/2015 - Report#: 1 I( II page 1 of 1 Wellbore name: OP22-WW03 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.15 3.72 11.16 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mIhr) DFS(days) OP22-WW03 WORKOVER 635.79 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 0.00 40.0 -16.1 Overcast WC-3' W 3 MPH Daily summary operation 24h Summary Accept rig to Well OP22 @ 0001 hrs.Permitting for stair removal and well bay roof access.Move rig off well OP23 and remove hatch cover f/OP22 and install on well OP23.Move and spot rig over well OP22 and perform rig up operations.CIO drill line spool.Load pits w/brine f/Raw mud and condition to 9.5 ppg. Operation at 07.00 R/U to Pump Brine 24h Forecast Complete R/U for pumping in well and weighting brine to 9.5 ppg.Bull head 250 bbls of brine down tubing,R/U on IA and shear GLM valve,Pump down tubing and clear IA of diesel.Ensure well is dead and R/U slick line to CIO valve in GLM to dummy. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 '08:00 8.00 8.00 COMP A '2 P PJSA Accept rig to Well OP22 @ 0001 hrs.Start cold start and split power on modules.Permit and remove well bay stairs on west side of well 2.Disconnect interconnects and secure all landings.Permit for working on well roof wl all personnel. Jack up utility module and set on crib blocks.Move utility module away from sub.Remove dixie cup curtains.Jack sub up and move away from well center for roof hatch accesses. 08'00 12:00 4.00 12.00 COMP A 2 P PJSA Secure well bay roof by removing hatch f/Well OP22 and covering Well OP23.Move sub and utility to Well OP22 and spot over hole and set.Clean up pad,berming location,connecting interconnects and swap power to Genset rig power. 12:00 19:00 7.00 19.00 COMP A 2 P -PJSA Continue with rigging up operations.Shut down Lampsons and secure curtains.R/U steam throughout rig complexes.Permit for critical lift and C/O drill line spool. 19:00 00:00 5.00 24.00 COMP 'A 1 P PJSA Shipping brine from RAW mud to rig pits and conditioning to 9.5 ppg.Permitting and secure cellar dixie cup and curtains. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Bruce Simonson .ENI Drilling Supv. 907-685-0715 Eni representative Russ Wimmer ENI Dolling Supv, SIDDrillinglenipetroleum.com 907-685-0715 907-320-0058 Eni representative Steve Millea ENI HSE Eni representative Vance Dale ENI Matls Coordinator Eni representative Mitch Billington ENI Rig Clerk akrigclerksdoyon15i enipetroleum.com 907-685-0722 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Tony Morales Nabors Toolpusher 805-797-6720 Tool Push Ralph Langham Nabors Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 6.184 L-80 2,254.55 3,251.61 8/5/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 1,225.60 1,136.41 LSND 1114.4 44.7 1507.9 171.3 Eni E&P Division ., Well NaW r •22- W03 DIR I EN!Petroleum Co.Inc. Daily Report Well Code:27295 Field Name:Nikaitchuq • API/UWI:50-029-23489-00-00 2^r, Date:4/3/2015 - Report#: 2 II II II page 1 of 1 Wellbore name: OP22-WW03 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type ALASKA ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.15 3.72 11.16 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) OP22-WW03 WORKOVER 636.79 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 40.0 -21.7 Overcast WC-30' ENE @ 15 MPH Daily summary operation 24h Summary Bullhead 263 bbls of 9.5 ppg brine down tubing and killed 400 psi formation pressure.Sheared GLM and displaced 125 bbls of diesel from IA.Well static.R/U Halliburton wireline,pull sheared valve and replaced w/dummy valve and tested to 500 psi. Operation at 07.00 Start Nippling down tree. 24h Forecast Vetco to set BPV,N/D tree and N/U BOPE and test as per AOGCC. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1138.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 -06:00 6.00 6.00 COMP L 9 P PJSA 32'from RKB to top LDS.R/U to pump down tubing and IA to go to cuttings box after shearout.PT lines to 1000 psi and open up tubing ig 400 psi.Bullhead 263 bbls of 9.5 ppg brine(g 5 bpm 430 psi ICP,800 psi FCP.Monitor well for 15 min. 06:00 10:00 4.00 10.00 COMP L 7 P PJSA Line up on IA and pressure to 2450 psi and shear out GLM.Pump down tubing w/201 bbls of 9.5 ppg brine II2 3.5 bpm,340 psi taking 125 bbls of diesel returns to cuttings tank.Monitor well.Blow down hoses and R/D.Diesel taken to recycle. 10:00 14:00 4.00 14.00 COMP R 20 P PJSA w/Halliburton wire line,Lil Red and rig personnel.R/U wire line equipment and tools and test lubricator w/Lil Red. 14:00 00:00 10.00 24.00 COMP R 19 P PJSA Run#1 set slip stop catcher.Run#2 pull sheared valve and had trouble coming up through SSSV.R/U and pump down tubing and freed tools.Run#3 set dummy and trouble w/SSSV.Rig pump down tubing and freed tools.R/U on IA and fill and test to 500 psi.Run#4 running in to retrieve slip stop catcher.Lowered brine weight in all pits to 9.2 ppg. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Bruce Simonson ENI Dulling Supv, 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling(genipetroleum.com 907-685-0715 907-320-0058 Eni representative Steve Millea ENI HSE Eni representative Vance Dale ENI Malls Coordinator Eni representative Mitch Billington ENI Rig Clerk akrigclerksdoyon15©enipetroleum.com 907-685-0722 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Tony Morales Nabors Toolpusher 805-797-6720 Tool Push Ralph Langham Nabors Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date ' LINER 7 6.184 L-80 2,254.55 3,251.61 8/5/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P SurfApplied(kgflem') Eq.Mud Weight(g/L) P LeakOff(kgflem') 1,225.60 1,136.41 LSND 1114.4 44.7 1507.9 171.3 iiiiiiiiiit Eni E&P Division Well Nal W 22- W03 DIR I • ENI Petroleum Co.Inc. Daily Report l� Well Code:27295 Field Name:Nikaitchuq • APIIUWI:50-029-23489-00-00 2^ Date:4/4/2015 - Report#: 3 '( II 11 page 1 of 1 Wellbore name: OP22-WW03 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.15 3.72 11.16 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) OP22-WW03 WORKOVER 637.79 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 0.00 42.0 -19.4 Clear WC-29° NNE©23 MPH Daily summary operation 24h Summary Finish Halliburton wire line rig down.Vetco set BPV and N/D tree and N/U riser and BOPE.Test BOPE as per AOGCC specs w/5"and 4.5"test jts.Blow dow and R/D f/test.Test witnessed by Bob Noble. Operation at 07.00 Changing out Koomey line. 24h Forecast Cleanup hydraulic spill from Koomey line.Vetco to pull test dart and BPV.M/U Landing jt and B/O LDS.Pull tieback seal stem from liner hanger and bring tubing hanger to ng floor.Centrilift to perform tests on cable and demob hanger and UD.Circ.500 bbls of 9.2 ppg brine down tubing up IA.Monitor well.R/U GBR equipment and POOH LD Tbg/ESP/Cap tubes. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time _ Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:00 2.00 2.00 COMP R 20 P PJSA Run#4 retrieved slip stop catcher and R/D Halliburton wire line equipment and release from location. 02:00 06:30 4.50 6.50 COMP C '20 -P PJSA Vetco set BPV and N/D tree. 06:30 '14:00 7.50 14.00 COMP C 20 P PJSA N/U Hi Pressure riser and BOPE.Install Katch Kan,cellar pump,set mouse hole,grease choke manifold. 14:00 17:00 3.00 17.00 COMP C 20 P PJSA Vetco install test dart.M/U 5"test jt.and fill stack and choke manifold. 17:00 '23:30 6.50 23.50 COMP C 12 P PJSA Test BOPE w/5"&4.5"test jts,as per AOGCC specs.Witnessed by Bob Noble. 23:30 00:00 0.50 24.00 COMP C 20 P PJSA L/D test jt,Blow down choke and kill lines. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Bruce Simonson ENI -Drilling Supv. -907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrillingl enipetroleum.com 907-685-0715 907-320-0058 Eni representative Paul Holley ENI HSE Eni representative Vance Dale ENI Malls Coordinator Eni representative Mitch Billington ENI Rig Clerk akdgclerksdoyon15@enipetroleum.com 907-685-0722 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Tony Morales Nabors Toolpusher 805-797-6720 Tool Push Ralph Langham Nabors Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 6.184 L-80 2,254.55 3,251.61 8/5/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm°) Eq.Mud Weight(gIL) P LeakOff(kgflcm') 1,225.60 1,136.41 LSND 1114.4 44.7 1507.9 171.3 ipso* Eni E&P Division Well Na ,r322-WW03 DIR ENI Petroleum Co.Inc. Daily Report Well Code:27295 Field Name:Nikaitchuq • APIIUWI:50-029-23489-00-00 2�(( ", Date:4/5/2015 - Report#: 4 page 1 of 1 Wellbore name: OP22-WW03 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.15 3.72 11.16 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) OP22-WW03 WORKOVER 638.79 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 41.0 -17.8 Clear WC-26° ENE @ 25 MPH Daily summary operation 24h Summary B/D&RID from testing.9 hrs.down time w/ruptured Koomey line and 80 bbls hydraulic cleanup.Bring up tools and equip.for decompletion and R/U.Vetco pull test dart and BPV.BIG LDS and M/U landing jt.Pull hanger free w/235k over pull and bring to rig floor.SLB/Vetco/&Centrilift terminate lines and B/D and UD tubing hanger.R/U and pump 9.2 ppg brine down tubing and up IA until 9.2 ppg brine to surface @ 5 bpm,275 psi.Condition all brine to 9.2 ppg.Monitor well.Install Elephant trunk and ready ESP and dual encapsulated tube to spooling unit. Operation at 07.00 Working on Spooler 24h Forecast Pull VIT jts from hole and string lines to spooling unit.SLB spooling control line for SSSV.R/U GBR for breaking out Vam Top tubing and POOH LD old completion string and inspect as pulling.Use trip tank w/continous fill monitoring fluid volumes. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act Plan Oper.Descr. 00.00 01:00 1.00' 1.00 COMP L 20 P PJSA Blow down and R/D from testing.Service ng. 01'.00 10:00 9.00 10.00 COMP L 25 TRO5 PJSA Clean up after 80 gal hydraulic spill from ruptured Koomey line on BOP stack.Reported to each department and ACS and SRT assisted in clean up.Refill accumulator and function test. 10.00 14:00 ' 4.00 14.00 COMP L 20 P PJSA Load spool and tools in shed for decompletion for 3 rd party workers. 14,00 16:00 - 2.00 16.00 COMP L 19 P 'PJSA Vetco pull test dart and BPV. 16,00 17:00 ' 1.00 17.00'COMP L 20 P 'PJSA P/U and M/U Vetco landing jt w/safety valve. 17'.00 20:00 3.00 20.00 COMP L 12 P -PJSA Vetco BO LDS and pull hanger free w/235k over pull @ 275k.Bring to rig floor and R/D penetrator and Centrilift check ESP.SLB terminate cap Gne and-Zeritrilift ready dual encapsulated tube for removal.BO hanger,inspect and L/D. 20.00 23:00 3.00 23.00 COMP L 7 P -------- PJSA R/U and circulate down tubing w/retums up IA to pits w/9.2 ppg brine @ 4 bpm,245 psi to 5 bpm,275 psi.R/U Elephant trunk and prep for UD tubing/ESP completion. ./ 23.00 00:00 1.00 24.00 COMP I` 20 P PJSA Ready ESP and dual encapsulated tube to spooling unit. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Paul Holley ENI HSE Eni representative Vance Dale ENI Matls Coordinator Eni representative Mitch Billington ENI Rig Clerk akngclerksdoyon15@enipetroleum.com 907-685-0722 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Tony Morales Nabors Toolpusher 805-797-6720 Tool Push Ralph Langham Nabors Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 6.184 L-80 2,254.55 3,251.61 8/5/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 1,225.60 1,136.41 LSND 1114.4 44.7 1507.9 171.3 Eni E&P Division IIANIa. .r.22-VVWD3 DIR I EN/Petroleum Co.Inc. Daily Report Well Code:27295 Field Name:Nikaitchuq • APIIUWI:50-029-23489-00-00 2 II II�,II,t Date:4/6/2015 - Report#: 5 page 1 of 1 Wellbore name: OP22-WW03 Well Header Permit/Concession N° Operator ENI Share I%) Well Configuration type ALASKA ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.15 3.72 11.16 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) OP22-WW03 WORKOVER 639.79 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 41.0 -18.7 Clear WC-29° ENE @I 38 MPH WI Gust to 45 MPH Daily summary operation 24h Summary Finish R/U of 3rd party tools and equipment.POOH UD 4.5"ESP completion to 2315'. Operation at 07.00 POOH W ESP Completion at 1,902'MD 24h Forecast Cont.to UD ESP completion.Clear and clean ng floor.Load pipe shed w/5"DP and process.Load Baker cleanout assy.to rig floor. Lithology Shows MAASP(kgf/cm') Mud Weight(g/L) 1102.4 Time Log Start End Cum ' Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 01:00 1.00 1.00 COMP L 20 P PJSA w/3rd party Centrilift,SLB and GBR for R/U ropes to spooler,Stabbing board,SLB spooler and GBR compensator. 01:00 02:00 1.00' 2.00 COMP L 4 P PJSA POOH w/VIT jts.and ESP completion f/7371'-7303'(2 jts.). 02:00 04:30 2.50 4.50 COMP L 25 'TS02 PJSA ENI spooler electrical failure.Called Tec Service and reprogrammed system. 04:30 10:30 6.00 10.50 COMP L 4 P PJSA POOH L/D VII Jts.f/7303'-7169'.R/D Compensator and cont.to POOH w/ESP completion tubing f/7169'-6748'. Inspect elevators and C/O do to broken slip die. 10:30 12:00 1.50 12.00 COMP L 4 P PJSA POOH f/6748'-6173',24 cannon,6-1/2 clamps,34-bands.56 bbls Tourly fluid losses. 12:00 16:00 4.00 16.00 COMP L 4 P PJSA POOH w14.5"ESP completion 0 6173'-5137',120k puw.L/D SSSV and SLB tools and equipment. 16:00 19:30 '' 3.50 19.50 COMP L 4 'P PJSA POOH wl 4.5"ESP completion f/5137'-3839'. 19:30 21:00 1.50 21.00'COMP L 20 -P PJSA Cut out ESP splice from completion. 21:00 00:00 3.00 24.00 COMP L 4 P PJSA POOH w/4.5"ESP completion f/3839'-2315',98k puw. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Bruce Simonson ENI Dolling Supv. 907-685-0715 Eni representative Russ Wmmer ENI Dolling Supv. SIDDrilling©enipetroleum.com 907-685-0715 907-320-0058 Eni representative Paul Holley ENI HSE Eni representative Vance Dale ENI Matls Coordinator Eni representative Mitch Billington ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Ralph Langham Nabors Tour Pusher Tool Push Gary Hoffman Nabors Toolpusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 6.184 L-80 2,254.55 3,251.61 8/5/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm°) Eq.Mud Weight(g/L) P LeakOff(kgflcm°) 1,225.60 1,136.41 LSND 1114.4 44.7 1507.9 171.3 'ifirool Eni E&P Divisionwell Na, z2-wwo3 DIR • ENI Petroleum Co.Inc. Daily Report Well Code:27295 Field Name:Nikaitchuq • API/U Wl:50-029-23489-00-00 2^II,t Date:4/7/2015 - Report#: 6 I� II page 1 of 1 Wellbore name: OP22-WW03 Well Header Permit/Concession N° Operator ENI Share(16) Well Configuration type ALASKA ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.15 3.72 11.16 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) OP22-WW03 WORKOVER 640.79 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 41.0 -16.0 Overcast WC-29 ENE @ 40 MPH Gust 47 Daily summary operation 24h Summary POOH L/D old ESP completion.Clear and clean rig floor.Load pipe shed w/5"DP and process. Operation at 07.00 Single in hole w/Baker Polish mill on 5"DP©600'MD 24h Forecast M/U Baker Polish mill assy.and single 5"DP in hole and dress top of liner.Pump Hi-Vis sweep and CBU. Lithology .Shows MAASP(kgflcm°) Mud Weight(gIL) 1102.4 Time Log Start End CumI Time Time Dur(hr) Dur(hr) Phase Opr. Act Plan Oper.Descr. 00-.00 01:30 1.50 1.50 COMP 'L 4 P PJSA POOH w+'4.5"ESP completion f/2315'-1901'.Fluid u-tubing out of tubing.Stab safety valve and monitor well. 01:30 04:00 2.50 4.00 COMP L7 P PJSA Circulate down tubing CO 3 bpm,90 psi and pump 10 bbl 9.5 ppg dry job. 04:00 09:30 5.50 9.50 COMP L4 P PJSA POOH wl completion f/1901-106'.51-Cannon clamps,1-112 damp,6-bands. 09:30 15:00 5.50 15.00 COMP L4 P PJSA Terminate ESP and Cap tubes,remove penetrator f/shroud hanger,LID pump assy,upper and lower seal assy, motor and shroud assy.Run all ESP and Cap lines to spooler.Clear and dean rig floor. 15:00 00:00 9.00 24.00 COMP L 20 P PJSA Load 5"DP and process. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Bruce Simonson ENI Dulling Supv. 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Paul Holley ENI HSE Eni representative Vance Dale ENI Malls Coordinator Eni representative Mitch Billington ENI Rig Clerk akrigderksdoyon15@enipetroleum.com 907-685-0722 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Ralph Langham Nabors Tour Pusher Tool Push Gary Hoffman Nabors Toolpusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 6.184 L-80 2,254.55 3,251.61 8/5/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm°) Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 1,225.60 1,136.41 LSND 1114.4 44.7 1507.9 171.3 Eni E&P DivisionWell Nei 22-WW03 DIR 019141 ENI Petroleum Co.Inc. Daily Report Well Code:27295 Field Name:Nikaitchug • API/UW:50-029-23489-00-00 2^II r, Date:4/8/2015 - Report#: 7 �( t page 1 of 1 Wellbore name: OP22-WWO3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.15 3.72 11.16 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) OP22-WW03 WORKOVER 641.79 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 0.00 38.0 -13.3 Overcast WC-9° ENE @ 18 MPH Daily summary operation 24h Summary Install wear bushing,M/U Baker cleanout assy.and single in hole to TOL©7399'.Baker dress TOL and P/U 15'and pump 26 bbls 200 vis sweep and CBU until balanced brine @ 9.2 ppg.26#of solids returns.Monitor well and POOH to 50261 Prep.for drill line changeout. Operation at 07.00 Spool new drill line on drawworks 24h Forecast Spool new drill line on draw works,secure and inspect Cont.to POOH LDDP and Baker Polish mill.Clear and clean rig floor and prep for 4.5"ESP completion. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:00 1.00 1.00 COMP L 20 P PJSA w/all personnel for RIH w/Baker cleanout assy.Vetco install wear bushing and prep.to P/U 5"DP. _-- 01:00 12:00 - 11.00- 12.00 COMP L 4 'P PJSA M/U Baker Polish mill cleanout assy.and single 5"DP in hole to 7384',182k puw,150k sow. 12:00 18:30 6.50° 18.50 COMP L 7 P PJSA RIH and tag TOL @ 7399'.P/U 15'and circulate and condition bone @ 8 bpm,270 psi,182k puw,150k sow,165k rotw,80 rpm,4k tq.Set down 4-6k w/7k tq,P/U and repeat 3X as per Baker.P/U 15'and pump 26 bbls,200 Vis sweep @ 8 bpm,270 psi.Circulate until brine balanced @ 9.2 ppg.Recovered 26#retums total. 18:30 23:00 4.50' 23.00 COMP L 4 'P PJSA POOH LDDP f/7399'-5026'. 23:00 00:00 1.00 24.00-COMP L 25 P PJSA to prep.for drill line change.Hang top-drive/blocks,remove deadman clamp/guide bolts,remove draw work cover and line guide,paint line splice. Daily Contacts Position Contact Name Company Title _ E-mail Office Mobile Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Russ Wmmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Paul Holley ENI HSE Eni representative Vance Dale ENI MaOs Coordinator Eni representative Mitch Billington ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Ralph Langham Nabors Tour Pusher Tool Push Gary Hoffman Nabors Toolpusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 6.184 L-80 2,254.55 3,251.61 8/5/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 1,225.60 1,136.41 LSND 1114.4 44.7 1507.9 171.3 111111* Eni E&P DivisionWell Na P22-P22DIR ENI Petroleum Co.Inc. Daily Report Well Code:27295 Field Name:Nikaitchuq • APIIU WI:50-029-23489-00-00 2^n Date:4/9/2015 - Report#: 8 II II II page 1 of 1 Wellbore name: OP22-WW03 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.15 3.72 11.16 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) OP22-WW03 WORKOVER 642.79 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 40.0 -12.2 Overcast WC 1° NNE @ 5 MPH Daily summary operation 24h Summary C/O drill line.POOH LDDP and Baker Polish Mill Assy.Vetco pull wear bushing.RIH wl Bakers tieback seal assy and shroud.Bring ESP to rig floor and Centrilift's safety cables parted and dropped ESP cable to ground w/no injuries or equipment damage.Safety shut down.Report to follow. Operation at 07.00 R/11 4.5"Completion as per tally w/Baker Centrilift. 24h Forecast Complete safety shut down reporting.Continue to R/U completion equipment as per Baker.RIH w/4.5"Completion as per tally. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 13:30 13.50 13.50'COMP L 25 P PJSA for C/O drill line.Prep.floor and pipe shed,Set top-drive in hole on 5"DP and install dog collar,Hang blocks.Slip 2100'of new drill line on blocks.Slip old drill line off draw works and cut every 100'.R/U Draw works for completion operations and test 13:3T- '20:00 6.50 20.00 COMP L 4 _ -- P PJSA POOH LDDP and Baker Polish Mill Assy.Vetco pull wear bushing. 20:00 23:30 3.50 23.50 COMP K 4 P PJSA w/all personnel and M/U Baker tieback seal and shroud assy.and RIH.PJSA wl centrilift on bringing ESP cable to rig floor. • 23:30 00:00 0.50' 24.00-COMP K 20 TS03 One foot from tying off ESP cable at rig floor,Bakers safety cables parted and dropped ESP cable to ground without any personal injuries or equipment damage.Shut down operations for safety stand down.Report to follow. 00:00 00:30 0.50 24.50 COMP K 20 TS03 One foot from tying off ESP cable at rig floor,Bakers safety cables parted and dropped ESP cable to g'o.ind without any personal injuries or equipment damage.Shut down operations for safety stand down.Report to follow. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Bruce Simonson ENI Drilling Supv. '907-685-0715 Eni representative Russ Slimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Paul Holley ENI HSE Eni representative Vance Dale ENI Matls Coordinator Eni representative Mitch Billington ENI Rig Clerk akrigclerksdoyon15@enipetroleum.cow 907-685-0722 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Ralph Langham Nabors Tour Pusher Tool Push Gary Hoffman Nabors Toolpusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 6.184 L-80 2,254.55 3,251.61 8/5/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') 1,225,60 1,136.41 LSND 1114.4 44.7 1507.9 171.3 iiiiiitEniE&P Division WW ell Na .P22- WO3 DIR ENI Petroleum Co.Inc. Daily Report Well Code:27295 Field Name: Nikaitchuq • APIIUWI:50-029-23489-00-00 2�II Il,II r, Date:4/10/2015 - Report#: 9 page 1 of 1 Wellbore name: OP22-WW03 Well Header Permit/Concession N' Operator ENI Share)%) Well Configuration type ALASKA ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.15 3.72 11.16 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(Mhr) DFS(days) OP22-WW03 WORKOVER 643.79 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 0.00 41.0 -16.4 Light Snow WC-13° NNE©11 MPH Daily summary operation 24h Summary 8 hours for Safety Stand Down for ESP Dropped object.M/U motor,seals,pump and lower completion and M/U shroud hanger to shroud.Bring ESP and Cap tube to rig floor wl new JSA's written by Centrilift and Nabors and approved by ENI Safety and Management.Centrilift performed MLE to ESP splice and testing. Operation at 07.00 RIH w/4.5"ESP completion @ 365'MD 24h Forecast P/U&M/U 4.5"12.6#13 Cri L80 Vam Top tubing completion as per tally and RIH to TOL©7397'. Lithology Shows MAASP(kgflcm') Mud Weight(glL) 1102.4 Time Log Start End Cum I Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. -00:00- 02:00 2.00 2.00 COMP K 20 TS03 ENI Safety investigation on dropped object. 02:00 03:00 1.00 3.00 COMP K 20 P PJSA Rerun rope from rig floor through sheave to spooler.Centrilift cut 140'from dropped ESP line and ready for pickup to rig floor. 03:00 11:00 8.00 11.00'COMP K 4 P PJSA RIH wl motor centralizer,gauge sub,motor,seal assy,pump,DGU,offset sub,adjust union and service as per Centrilift.Place seals on shroud hanger,P/U&M/U MLE and cap tubes and M/U shroud hanger to shroud. 11:00 12:00 1.00 12.00 COMP K 20 P PJSA R/U rope to ESP cable wl new swivel and prep.to pull to rig floor. 12:00 18:00 6.00 18.00'COMP 'K 20 TS03 Continue with safety stand down until new JSA's w/Baker Centrilift and Nabors are written correctly and approved by ENI , Safety and Management. 18:00 19:00 1.00 19.00 COMP K 20 P PJSA w/all personnel discussing new JSA's on pulling ESP to rig floor. 19:00 20:30 1.50 20.50 COMP K 20 P PJSA Pull ESP and cap tube to rig floor. 20.30 00:00 3.50 24.00 COMP K 20 P PJSA Centrilift performing MLE to ESP cable splice and tests.R/U cap tube. Daily Contacts Position Contact Name Company Title E-mail Office Mobile En:representative Bruce Simonson ENI Drilling Supv. '907-685-0715 En:representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Paul Holley ENI HOE Eni representative Vance Dale ENI Malls Coordinator Eni representative Mitch Billington ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Ralph Langham Nabors Tour Pusher Tool Push Gary Hoffman Nabors Toolpusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 6.184 L-80 2,254.55 3,251.61 8/5/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(giL) P LeakOff(kgflcm') 1,225.60 1,136.41 LSND 1114.4 44.7 1507.9 171.3 Eni E&P Division Well Na: 22-WW03 DIR I ENI Petroleum Co.Inc. Daily Report Well Code:27295 Field Name:Nikaitchuq • APIIUWI:50-029-23489-00-00 2�,r, Date:4/11/2015 - Report#: 10 '( II II page 1 of 1 Wellbore name: OP22-WW03 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.15 3.72 11.16 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) OP22-WW03 WORKOVER 644.79 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 42.0 -13.0 Overcast WC-4' ENE @ 13 MPH Daily summary operation 24h Summary Centrilift performed MLE/ESP splice and tested cable.PJSA and M/U and RIH w/4.5"Vam Top/ESP completion as per tally to 6019'.Test cable every 1000'. Operation at 07.00 RIH W/ESP Completion at 7,003'MD 24h Forecast RIH w/4.5"VamTop/ESP completion and sting into liner and verify.Space out and continue to M/U completion and Vetco hanger.Centrilif/SLB and Vetco to dress hanger and test equipment.Pump inhibited brine down backside and sting into liner and verify. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time _Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 •02:00 2.00 2.00 COMP K 12 P PJSA Centrilift performing MLE To ESP splice.Hook up cap line,pull and cut 200'of bad control line out and R/U. 02:00 02:30 0.50 2.50 COMP K 20 P PJSA with all personnel on running 4.5"ESP completion. 02:30 '12:00 9.50 12.00 COMP 'K 4 P PJSA M/U 4.5"12.68 13Cd-80 Vam Top tubing/ESP completion as per tally and RIH to 3026',83k puw.Test cable every 1000'. 12:00 '19:00 7.00 19.00 COMP K 4 P PJSA Cont.to RIH w14.5"ESP completion to 5082'. 19:00 '20:30 1.50 20.50 COMP K 12 P PJSA Test ESP cable,install TIW valve in tubing,PJSA wl SLB on P/U SSSV and equipment,P/U&M/U SSSV,hookup cap line and test to 5000 psi for 15 min.R/D TIW valve.Sim Ops;Service skate. 20:30 '00:00 3.50 24.00 COMP K 4 P PJSA Continue to RIH wf 4.5"ESP completion to 6019'.105k puw,98k sow.Test cable every 1000'.Bring cannon clamps to ng floor. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Paul Holley ENI HSE Eni representative Vance Dale ENI Malls Coordinator Eni representative Mitch Billington ENI Rig Clerk akngderksdoyon15@enipetroleum.com 907-685-0722 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmaii.com 907-980-7545 907-980-7545 Tool Push Tony Morales Nabors Toolpusher 805-797-6720 Tool Push Gary Hoffman Nabors Toolpusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 6.184 L-80 2,254.55 3,251.61 8/5/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/em') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 1,225.60 1,136,41 LSND 1114.4 44.7 1507.9 171.3 .lip* Eni E&P Division w .} ell Na WW P22- O3 DIR ENI Petroleum Co.Inc. Daily Report Well Code:27295 Field Name:Nikaitchuq • APIIU WI:50-029-23489-00-00 2��I 'I,II r, Date:4/12/2015 - Report#: 11 page 1 of 1 Wellbore name: OP22-WW03 Well Header Permit/Concession N° Operator ENI Share(V.) Well Configuration type ALASKA ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.15 3.72 11.16 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) OP22-WW03 WORKOVER 645.79 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) P08 Temperature(°C) Weather Wind 0.00 41.0 -13.2 Cloudy WC-4° ENE @ 7 MPH Daily summary operation 24h Summary RIH wl 4.5"12.69 12Crl-80 Vam Top tubing ESP completion and locate Seal assy NO-GO @ 7396'.POOH and LJD 6 jts.tubing and install space out pups and M/U VIT jts,Vetco hanger and landing jt. Displace brine w/440 bbls of 9.4 ppg 1.1%corrosion inhibited brine and spot wl 118 bbls of 9.4 ppg brine.Terminate ESP and cap lines at hanger and perform final splice.RIH and land Vetco hanger w/ Baker liner seal @ 7406'w/9'sting in.RILDS and test upper and lower hanger seals to 5000 psi 1/10 min.R/U and test IA to 1500 psi f/30 min.UD landing jt and set BPV. Operation at 07.00 Nippling Down 24h Forecast NID ROPE and N/U tree and test to 5000 psi.Test void and packoff to 5000 psi.Baker and SLB do final checks.R/U Lil Red and pressure IA to 1500 psi 0 15 min.Cont to pressure up to 2000 psi and shear GLM valve and pump 5000 gals of diesel to freeze protect.RAJ Halliburton slick line and C/O sheared valve and test new shear valve to 500 psi.R/D Slick line and secure well.Release rig from well. Lithology Shows MAASP(kgflcm') Mud Weight((IN) 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 07:30 7.50 7.50 COMP K 19 P PJSA RIH wl 4.5"ESP completion f/6019'-7381',148k puw,110 sow.Cont.to RIH for space out and locate NO-GO @ 7396'and set down 10k while pumping down tubing and observed 150 psi pump pressure increase. 07:30 09:00 1.50 9.00 COMP K 4 P PJSA POOH and L/D Jts.176-170,150k puw. 09:00 11:30 2.50 11.50 COMP K 4 P PJSA P/U 8 M/U space out pups,9.72',9.72',9.73',2.10',2.07',3 VIT jts RIH f/7135'-7270',145k puw,100k sow. 11:30 12:00 0.50 12.00 COMP K 20 P PJSA Clear and clean rig floor and service floor equipment. 12:00 13:30 1.50 13.50 COMP K 4 P PJSA Cont.RIH w/VIT jts.to 7374'. 13:30 18:00 4.50 18.00 COMP K 7 P PJSA M/U Vetco hanger and landing jt.Screw into top-drive and pump 440 bbls of 9.4 ppg brine wl 1.1% corrosion inhibitor and spot w/118 bbls of 9.4 ppg brine @ ICP 30 psi @ 2 bpm and FCP 230 psi @ 5 bpm.Sim Ops;R/D SLB,GBR equipment.Terminate ESP and cap lines @ hanger and perform final splice.174-Cannon clamps,12-Single clamps,372 -Pins,3-1 1/4"SS bands,2-Protectolizers. 18.00 2000 2.00 20.00 COMP K 19 P PJSA Drain and flush stack,Vetco run in guide pin,Blow down hole fill,choke and kill lines.RIH and set hanger,152k puw, 110k sow.Btrn of Baker Liner seal assy @ 7406'wd 9'sting in. 20.00 21 00 1.00 21.00 COMP K 12 P PJSA RILDS Test Upper and Lower Hanger seals to 5000 psi for 10 min and RN on IA to test. 21 00 00.00 3.00 24.00 COMP K 12 P PJSA Perform MIT IA test to 1500 psi 0 30 min.while pumping down tubing.Witnessed.Blow down top-drive,L/D landing ' jt,and Vetco installed HIV. , Daily Contacts Position Contact Name Company Title E+naN Office Mobile Eni representative Bruce Simonson ENI Dulling Supv. 907-685-0715 Eni representative Russ Wimmer ENI Dulling Supv, SIDDrilling(genipetroleum.com 907-685-0715 907-320-0058 Eni representative Paul Holley ENI HSE Eni representative Vance Dale ENI Malls Coordinator Eni representative Mitch Billington ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Tony Morales Nabors Toolpusher 805-797-6720 Tool Push Gary Hoffman Nabors Toolpusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 6.184 L-80 2,254.55 3,251.61 8/5/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 1,225.60 1,136.41 LSND 1114.4 44.7 1507.9 171.3 . Eni E&P Division .} Well Na. P22-WWo3 DIR EN!Petroleum Co.Inc. Daily Report Well Code:27295 Field Name:Nikaitchuq • APIIUWI:50-029-23489-00-00 2^ Date:4/13/2015 - Report#: 12 (I II page 1 of 1 Wellbore name: OP22-WW03 Well Header Permit/Concession N° Operator ENI Share(16) Well Configuration type ALASKA ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.15 3.72 11.16 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) OP22-WW03 WORKOVER 646.79 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 38.0 -16.4 Overcast WC-10° E @ 13 MPH Daily summary operation 24h Summary Flush Kill,Choke&HCR lines.Remove Katch Kan&skirt,bell nipple,Remove Kill&Choke lines from stack.R/D ESP and Cap line sheaves from derrick.Pull rams from stack&clean cavities for inspection.Remove Koomey lines&cap.Secure BOP doors, remove stack&secure on stump.Install low torq valves on Kill&Choke lines.Flush and blow down TDS.Remove Vetco Hi-Pressure riser and inspect well head.SLB terminated cap line for SSSV and opened valve.N/U tree,pull BPV and install TWC.Vetco Tested void to 5000 psi 0 10 min.R/U and test tree to 5000 psi 0 10 charted min. Baker performed final ESP checks all good.Removed TWC. Operation at 07.00 Rig up Slickline 24h Forecast Pressure IA with to 1500 psi f/15 min.Cont to pressure up to 2000 psi and shear GLM valve and pump 5000 gals of diesel to freeze protect.R/U Halliburton slick line and CIO sheared valve and test new shear valve to 500 psi.R/D Slick line and secure well.Release rig from well. Lithology Shows MAASP(kgfIcm') Mud Weight(gIL) 1126.4 Time Log Start End Cum Time Time Dur(hr)_Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06:00 6.00 6.00 COMP C 20 P PJSA Flush Kill and Choke HCR lines and blow down.Remove Katch Kan&skirt,bell nipple,Remove Kill&Choke lines from stack. 06,00 07:00 1.00' 7.00 COMP K 20 P 'PJSA RID ESP and Cap line sheaves from derrick. 07.00 12:00 5.00' 12.00 COMP C 20 P PJSA Pull rams from stack&clean cavities for inspection. 12.00 19:00 7.00' 19.00 COMP C 20 P PJSA Remove Koomey lines from stack and cap lines.Secure BOP doors,raise landings and remove stack and secure on stump.Install low torq valves on Kill&Choke lines.Flush and blow down top-drive.Remove Vetco Hi-Pressure riser and inspect well head. 19.00 00:00 5.00' 24.00 COMP C 12 P PJSA SLB terminate cap line for SSSV and opened valve.N/U tree,pull BPV and install TWC.Vetco Tested void to 5000 psi f/10 min.R/U and test tree to 5000 psi f/10 charted min.Baker performed final ESP checks all good.Removed TWC. PJSA wd Lil Red on freeze protecting and R/U tree. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Bruce Simonson ENI Drilling Supv. '907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDdlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Satoh Bowe ENI Drilling Supv. Eni representative Paul Halley ENI HSE Eni representative Vance Dale ENI Malls Coordinator Eni representative Mitch Billington ENI Rig Clerk akrigderksdoyon15@enipetroleum.com 907-685-0722 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Tony Morales Nabors Toolpusher 805-797-6720 Tool Push Gary Hoffman Nabors Toolpusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 6.184 L-80 2,254.55 3,251.61 8/5/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') 1,225.60 1,136.41 LSND 1114.4 44.7 1507.9 171.3 Eni E&P Division 11.11a. -P22-WW03 DIR 1 ENI Petroleum Co.Inc. Daily Report Well Code:27295 Field Name:Nikartchuq • API/UW1:50-029-23489-00-00 2^ Date:4/14/2015 - Report#: 13 II II page 1 of 1 Wellbore name: OP22-VWV03 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.15 3.72 11.16 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date •Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) OP22-WW03 WORKOVER 647.79 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 36.0 -20.6 Clear WC-28° ENE @ 19 MPH Daily summary operation 24h Summary R/U choke line to take returns from tubing as Little Red Services pumps diesel for freeze protection.Pressure test LRS lines&IA.Shear out SOV,pump diesel,ICP @ 2 BPM,800psi,FCP @ 2 BPM, 1,150psi.Total 117 bbls pumped.Flush lines with fresh water&R/D.R/U Halliburton wire line.M/U tools&test lubricator.RIH with catcher assembly to 2,245'&set.Come out&0/0 tools.RIH to retrieve SOV @ 2,194',second attempt successful.RIH&set new SOV @ 2,194'.Two attempts to remove catcher assembly from 2,245'.L/D wireline&sheave assembly.R/D Lubricator,BOP& extension.Reinstall Well Head cap on tree.Complete cleaning well bay&renistall blind flanges.Clean&clear rig floor.Remove bails from top drive&prep crib blocks for rig move.Remove cameras from derrick.Begin cleaning pits&pipe shed.Well released to production @ 00:00 4-15-2015 Operation at 07.00 Rig down 24h Forecast Continue rigging down&prep for move. Lithology Shows MAASP(kgflcm°) Mud Weight(gIL) 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:00 2.00 2.00 COMP 0 8 P PJSM:With all pertinent personnel.R/U choke line to take retums from tubing as Little Red Services pumps diesel for freeze protection. 02:00 04:30 2.50 4.50 COMP 0 9 P PJSA:Pressure test LRS lines to 3,000psi,PT IA to 1,500psi.Shear out SOV,sheared at 2,400psi.Begin pumping diesel ICP @ 2 BPM,800psi,FCP @ 2 BPM,1,150psi.Total 117 bbls pumped.LRS cleared back lines. 04:30 06:00 1.50 6.00 COMP K 20 P PJSA:Flush choke&surface lines with fresh water&B/D.R/D high pressure lines. 06:00 09:30 3.50 9.50 COMP R 15 P PJSM:With all pertinent personnel.R/U Halliburton wire line.Mill tool assembly&pressure test lubricator to 1,500psi. 09:30 12:00 2.50 12.00 COMP R 15 P PJSA:RIH with catcher assembly to 2,245'&set.Come out&C/O tools.RIH with kick over tool to retrieve SOV @ 2,194'. First attempt unsuccessful, 12.00 17:00 5.00 17.00 COMP R 15 P PJSA:RIH to to pull SOV,second attempt successful.RIH&set new SOV @ 2,194'.Two attempts remove catcher assembly from 2,247'. 17.00 18:30 1.50 18.50 COMP R 20 P PJSA:UD wireline&sheave assembly.RID Lubricator,BOP&extension.Reinstall Well Head cap on tree. 18.30 00:00 5.50 24.00 COMP K 20 P PJSA:Complete cleaning well bay&renistall blind flanges.Clean&clear rig floor.Remove bails from top drive&prep crib blocks for rig move.Remove cameras from derrick.Begin cleaning pits&pipe shed.Well released to production @ 00:00 4 -15-2015 Daily Contacts Position Contact Name Company Title E-mail Office Mobile • Eni representative Bruno Ravagli ENI Dating Superintendt - Eni representative Russ Wimmer ENI Drilling Supv. SIDDdlling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Satch Bowe ENI Drilling Supv. Eni representative Paul Holley ENI HSE Eni representative Vance Dale ENI Mads Coordinator Eni representative Mitch Billington ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Tony Morales Nabors Toolpusher 805-797-6720 Tool Push Gary Hoffman Nabors Toolpusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 6.184 L-80 2,254.55 3,251.61 8/5/2013 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 1,225.60 1,136.41 LSND 1114.4 44.7 1507.9 171.3 Tji(croF �� y, s THE STATE Alaska Oil and Gas 701 o Conservation Commission fALAsKA 333 West Seventh Avenue J GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OFALAS1 ' Fax• 907.276.7542 www.aogcc.alaska.gov Marc Kuck _ O � I� Drilling and Completion Engineering Manager Eni US Operating Co. Inc. 3800 Centerpoint Dr., Ste. 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Ivishak Undefined WTRSP, OP22-WW03 Sundry Number: 315-071 Dear Mr. Kuck: 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, Cathy P. Foerster Chair DATED this wY February,Februar , 2015. Encl. SCANNED FEE 2 6 2.; =i • RECEIVED " STATE OF ALASKA FEB 1 0 2015 • ALASKA OIL AND GAS CONSERVATION COMMISSION 2.(18) 1,5 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25280 1.Type of Request: Abandon ❑ Plug for Redrill El Perforate New Pool ❑ Repair Well Q % Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing❑D - Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate ❑ Alter Casing❑ Other: _ESP Change Out_ ❑✓ ' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Eni US Operating Co.Inc.• Exploratory ❑ Development ❑ 213-0540 . 3.Address: Stratigraphic ❑ Service Q, 6.API Number. 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 50-029-23489-00-00• 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A / ✓ Will planned perforations require a spacing exception? Yes ❑ No ❑ OP22-WW03 • 9.Property Designation(Lease Number): 10.Field/Pool(s): 0373301,0355024,0390616 • Nikaitchuq Ivishak Undefinited WTRSP ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): •10,676 9,521 . 10,675 ' 9521 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 154 20" 154 154 Surface 4020 13.375" 4020' 3728 5,210 2,480 Intermediate 7632 9.625" 7632 6475 6,890 4,790 Production Liner 3278 7" 10675 9521 7,240 5,410 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9,925'-10,308' , 8,773'-9,155' 4 1/2 13 Cr L80 7,397 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A N/A 12.Attachments: Description Summary of Proposal ❑✓ • 13.Well Class after proposed work: Detailed Operations Program ❑., BOP Sketch 2 Exploratory ❑ Stratigraphic❑ Development❑ Service 2 14.Estimated Date for 1-Apr-15 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ El GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: Source Water Well Q. GSTOR ❑ SPLUG El 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Giuseppe Maugeri Email giuseppe.maugeri@enipetroleum.com Printed Name Marc Kuck Title Drilling&Completion Engineering Manager Signature Phone Contact 907-865-3328.0.171 Date 2/9/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ,/ 315 - 071 Plug Integrity ❑ BOP Test LLT Mechanical Integrity� Test EI Location Clearance ❑ Other: JOU /Os ,6C1/ - f ( /1/1AS P °Diep 5-•) Spacing Exception Required? Yes ❑ No Subsequent Form Required: / o —y 0 r'( n THERO MM BY 2_/� Approved by. Y COMMISSIONER 414-- APPROVED ' THE COMMISSION p Date: ()R4cGpicNnAL, '�/�)/�S )C +Z 3"tr.ta SubmnFormane Fo 0-403(Revised1012012) for 12 months from the date of approval. Attachments in Duplicate RBDMS FEB 2 3 201 . 2///m /1,4 a-/s RECEIVED FEB 102015 �li�lll PetrHurn AOGCC 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Marc Kuck Phone(907) 865-3322 Email: Marc.kuck@enipetroleum.com February 9th, 2015 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 RE: Application for Sundry Approval for OP22-WW03 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well OP22-WW03 OP22-WW03 was originally completed on August 15th, 2013 with a ESP pump set at depth of 7,397' MD/6315' TVD. The ESP has worked until June 11th when an electrical failure was occurred. The well has been scheduled for an intervention with Nabors 245 to change out ESP. The estimated date for beginning this work is April 1St,2015. Please find attached for the review of the Commission forms 10-403 and supporting documentation. If you have any questions or require further information, please contact Giuseppe Maugeri at 907-865-3328. Sincerely,�. ,� Marc Kuck Drilling&Completion Engineering Manager • OP22-WW03 Workover— Summary Page OP22-WW03 Rig Workover PTD#:213-054 Current Status Well OP22-WW03 is currently in production in natural flow. Scope of Work Scope of this workover is to pull the current completion and run in with a new ESP system. General Well info Reservoir Pressure/TVD: Reservoir depth is 9925'MD/8773'TVD. Static wellhead pressure was approximately 430 psi during a short shut in time in August 2014. This well is expected to have a static max bottom hole pressure of approximately 4300 psi during the time of workover. (Static tubing head pressure appr. 440 psi). Wellhead type/pressure rating: Vetco Gray, MB-247/5000 psi BOP configuration: Annular/pipe/blind/Flowcross/pipe TIFL/MIT-IA/MIT-OA: Intermediate csg 9 5/8" was tested 3000 psi x 30' on August 1st 2013 prior to drill out, and 1500 psi x 15' on August 13th 2013 after running completion. Well type: Water Producer Estimated start date: April 1St 2015 Drilling rig: Nabors 245 Completion Engineer: Giuseppe Maugeri: giuseppe.maugeri@enipetroleum.com Work 907-865-3328 Drilling&Completion Marc Kuck: marc.kuck@enipetroleum.com Engineering Manager: Work: 907-865-3322 • Procedure: 1. MIRU Nabors 245. 2. R/U on x-tree to pump down tubing. 3. Displace by bullheading tubing and liner volume with 9.5#brine. L` 4. Shear GLM valve and circulate out diesel. 5. Ensure well is killed. 6. Set BPV. ND tree and NU BOP and test to 3500 psi. 7. Pull tubing hanger and circulate annulus volume with 9.5 #brine. 8. Continue POOH to SSSV and L/D same. 9. Continue POOH and lay down ESP assembly. 10. MU new ESP assembly and RIH to setting depth. 11. Land hanger, and test it. 12. Pressure test IA 1,500 psi x 30'. 'i I`'M i r- ( I4 13. Install BPV and nipple down BOP. 14. NU tubing adapter and tree. 15. Pull BPV, install test plug and test tree.( 5000 psi test) 16. Shear GLM valve and circulate freeze protect through tree down IA. Change out GLM valve. 17. Shut in well. 18. RDMO. Below the current schematic of the well: oP22-wwa3 toit 4-'/_" 13Cr 12.6 ppf Vam Top Production Tubing p 'iirnill Wellhead, 13-3/8"x 4-W,CR Flow-wetted 5.000 psi Conductor, 20"Uninsulated set at 160 ft Water Producer Jts,4-1/2"x 6"OD,204'MD As Campleteu August 15 2013 2223'MD,2212'TVD, 12°Inc-TR-MAXX 5E SSSV,3.81"'X'Profile,Y."SS hyd. Control line 3265'MD, 3,152'TVD 37°Inc-GLM,4-'/"x 1", KBG with DCK-2 Ann-to-Tubing 2,000 psi 4-'/-"cable clamps,for ESP Power Cable. (2)318"Chem lnj Line ESP Power Cable 1SOLBC 510J 90 LD B Galv. Dual encapsulated 3/8'SS Chem lnj Lines 7254' MD, Landing Nipple Surf.Casing 13-3!8"68# 4020'MD.3728'TVD � '►. ESP Assy,31-562P155SXD Pump.GST3 46 `\ - - -- Seals,270 HP KMX Motor 7311'MD,6241'ND, 31°Inc 7-518'29.7# 13Cr Shroud Assembly withPenetrator,(2)Chem Inj Line Feed-Thrus 7,397'MD-TOL-Flex =_ :- Tieback Seal Stem Lock Liner Hanger and ZXP Packer Assy Perf Range 9925'-9953'MD. 8773'-8801'TVD Intenn, Casing 9960'-10047'MD, 8828'-8894'TVD 9-518"40#13 Cr 10064'-10103' MD,8911'-8950' ND 7.63T MD,6,475'ND 10127'-10188' MD,8974'-9035'ND • . 0223'-10308' MD.9070'-9155'ND Approx 5°Inc Pump Monotorinq: P intake T intake Production Liner, P discharge 7"264 13 Cr 8 OH T motor 10.675' MD. 9.521 ND motor Confidential 4 rsa, Pau P"v b J €res £ .s., .. ..0 W ; g al Q I. z C li li 1 i� lb Hi R -, _ „ 1ppiiuii_I w cn J _ Uaa ., Iv LL 0 d I:i w cc co d r.;.!- II nm nm W d N cD ct > nnnm. ---ik—rAi- _ n I - 111 2,w I. Plil III [II.,,III= OII :.<�_:. Zcta ' _ III �7 _26711 + I F z I PikIt - III '__ :._ ctm 25 mQo€ a WI ! F!P . C4iap! -2 coE n vnu,d2� wy. by I W �= Tk � � :2§I \W 2I nr-1 mm h i� Y' :4W y NV 2 •. ��" .y.N2 ,�c7 1 -NS t AL N o IL ■� : � .� T y _ a Z 6 O z O _ . K ,�� Q -- II ::II _ H I i W hlin m , J E \ N ...g ; 1. .tin h-,8 k iV VetcoGray MB-247 SURFACE COMPLETION SYSTEM F-6 '.SO l►IAN/CL ../ "15 37.19 •u IJ 8 gerst 1�11� i11/1 /.� �� F -- ,—ll�klik/ i wan 0 1 r.04.1 7. II:ovilk ok4b g 01:1Pep=fu. 1. ' "NI , ' T.O.S. EL 26' 5-3/4" .062 OFFSET C/L I B.O.S. EL 25' 7-1/4" OO TOP OF WELLHEAD 5'00" EL 25' 2-1/4" ( 1 a 4104 PFT 1 �Pil or� CD 21.81 13-5/8-5000 PSIA VG S137 CLAMP ��_I,11 1111110 � . 4-1/16" 5000 PSI � ��-r,;,_ -� 111 INF _ „I ....._:,. ~SCLJ__ ___ _ ■11 3.437 OFFSET 108.0 Ck IN 6.50'_ 2-1 16" 1, ii 2�ifa18" 7 CC'• ' ~ _ -1 6 "'[ . ' 66.71 POSmON - IM . 13"osm Vc 15341%011 52.96" ul lul 25.5 — r ' --- 'II."' . _ 34.00- PSIOU 24.2 .MI1 ' 15.25" POSMON •II■ _ • TOG TOP OF GRADING f 1� I 1 EL 16' 1-1/4" `1.00 PROPRIETARY NOIICC t¢:. vetcograyy- 20" OD 133w K-55 r 9 'moi Ph ENI ALASKA 13-3/6" OD 68/ 1-BO °N, 9-5/8" OD 53.5# L-80 17 Rees Oh HORIZONTAL MULTI-BOWL SYSTEM 4-1/2" OD WITH 6-5/8 MT 20 X 13-3/8 X 9-5/8 X ""MO/P" X 4-1/2 WITH 6-5/8 VIT L DOR* RIM OM AND ESP FLAT CABLE 23 AP6L OP ITMm.gv 4)-e • 'IeCS3° H173370-1 ' PO 4IW[Play —MCXXXI.aP 6* P P X 1 I PRP 10161. NC 10 OF 10 23 JANUARY 2009 16 G=lmaginat)cn a:work Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. oP_ I - 0 54- Well History File Identifier Organizing(done) Two-sided 11111111111 III 11111 ❑ Rescan Needed III 1111111II 111111 TAN DIGITAL DATA OVERSIZED (Scannable) Colo Items: ❑ Diskettes, No. ❑ Maps: reyscale Items: ❑ Other, No/Type: ther Items Scannable by a Large Scanner 1_©(,..g ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: C Maria Date: 3 /O f /s/ rnP Project Proofing I IMMO BY: Maria Date: 3//61/ /s/ r Scanning Preparation _ x 30 = 3,1+0 + I T = TOTAL PAGES (Count does not include cover sheet) �^ BY: CMaria� Date: 3/1 0 f, /s/ Y Production Scanning III IIIIIIIIII 11111 Stage 1 Page Count from Scanned File: as-7 (Count does include cover eet) Page Count Matches Number in Scanning Preparation: YES ^NO /n BY: Date:31/01/[_ /s/ �/k/`f Stage 1 If NO in stage 1, page(s)discrepancies were found: YES NO 1 BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. 11111111111111 ReScanned I BY: Maria Date: /s/ Comments about this file: Quality Checked 111 1111111111111111 O M_ p N I O) co O col 0 u. co 8 0 LL a) O of cj '� O O OI a OI a c (� O c .°'o CI 2 co rn g OI �I �I OI �I �I c �1 O lZ m J a) O N 0 1 ft N NO O 2 LL O J J a) T ! �I �I CI CI CI CI Q LL LL 0 [i c•J Z 7 a) E I �I TI TI TI TI co co I N co f") WI co F. cn a? a)— > > > > E 1 1 0 1 1 rn Q {o N it .-9.- N N in in N i 0 O N Cl) N o N Cl). 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U ■ RECEIVED HALLIBURTON SEP 112013 Sperry Drilling AOGCC To: Alaska Oil and Gas Conversation Commission DATA LOGGED 2`3-off 7th Al/2013 2 333 W 7 Ave Suite 1 OO ..M K BENDER �� 1 Anchorage, AK 99501 Attn: Howard Oakland From: Sperry Drilling - Alaska Attn: Robert Haverfield 6900 Arctic Blvd. Anchorage, AK 99518 907-273-3559 Office 907-273-3535 Fax Robert.Haverfield@Halliburton.com Re: Eni Well — OP22-WW03 AFE # 6151 Rig — Nabors 245 Oliktok Point—Nikaitchuq, Alaska Shipment Includes: 1 End of Well Reports 1 Final Data Listing on CD-ROM 1 Sets of Final Logs—for each well contains: • 2" Color Log — Formation Evaluation TVD • 2" Color Log — Formation Evaluation MD • 2" Color Log — Drilling Engineering MD • 2" Color Log — Gas Ratio MD Received By: Print Name Sign Name Date °111"1 ( 13 Please sign acknowledgement of receipt - email, fax, or mail back. Thank you. • STATE OF ALASKA SEP 0 9 2013 AL .rKA OIL AND GAS CONSERVATION COM....oSION WELL COMPLETION OR RECOMPLETION REPORT AND LO la.Well Status: Oil❑ Gas ❑ SPLUG ❑ Other Q . Abandoned ❑ Suspended❑ lb.Well Class: WA�i'ek ��AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑• GINJ ❑ WINJ❑ WAG ❑ WDSPL❑ No.of Completions: Service 0 . Stratigraphic Test ❑ 2.Operator Name: 5.Date Comp.,Syef� 12.Permit to Drill Number: ENI US Operating Co.Inc. Aband.: 213-054 3.Address: 6.Date Spudded: 13.API Number: 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 7/6/2013' 50-029-23489-00-00 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 3133.8 FSL 1696.4 FEL S5 T13N R9EUM 8/3/2013 • OP22-WW03 Top of Productive Horizon: 8.KB(ft above MSL): 53 15.Field/Pool(s): Plat- 937 FSL 3468 FEL 32 T14N R9EUM GL(ft above MSL): 12.2 Nikaitchuq/Ivishak (i JkF 14.7TAS7' Total Depth: 9.Plug Back Depth(MD+TVD): 987 FSL 3514 FEL 32 T14N R9EUM N/A - • 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: , Surface: x- 516583.96 y- 6036486.83 Zone- 4 10676 MD/9521 TVD . ADL 355024,373301,390616 TPI: x- 514795.70 y- 6039566.00 Zone- 4 - 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 514749.69 y- 6039615.44 Zone- 4 2223 MD/2212 TVD ADL 417493 18.Directional Survey: Yes U. No U 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) 1793'MD/1786'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MD/TVD: GR/RES • N/A • 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20 178.89 X-65 SURFACE 160 SURFACE 160 Driven N/A N/A SURFACE 4020 SURFACE 3728 609 bbls 11.2ppg Artic Lite, 13.375 68 L80 16 68 bbls 12.5ppg(Tail) " N/A 9.625 40 13CrL-8C SURFACE 7632 SURFACE 6475 12.25 108 bbls 15.8ppg / N/A 7" 26 13Cr 7397 10668 6315 9521 8.5 110 bbls 15.8ppg / N/A 24.Open to production or injection? Yes IN 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) 9925-9953 MD,8773-8801 TVD 5spf 4.5 7406 7407 9980-10047 MD,8828-8894 TVD 5spf 10064-10103 MD,8911-8950 TVD 5spf � r 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 10127-10188 MD,8974-9035 TVD 5spfA,.� 113 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 1 10223-10308 MD,9070-9155 TVD 5spf 4"` e ; 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): Flowina Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bb: Choke Size: Gas-Oil Ratio: Test Period - Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate - 28. CORE DATA Conventional Core(s)Acquired? Yes❑ No 0 • Sidewall Cores Acquired? Yes ❑ No El • 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. RBDMS SEP 12 2 Form 10-407 Revised 12/2009 CONTINUED ON RE SE Submit origin I only G 1 rt, la 3 13 1'w3 �ai3i/3 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? U Yes ✓�lo If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if Permafrost-Top surf surf needed,and submit detailed test information per 20 AAC 25.071. Permafrost-Base 1793 1786 Ugnu Top(UG4) 2025 2017 Schrader Bluff Top 3514 3346 N Sequence Top 3566 3386 OA sand top 3816 3577 Torok Top 6979 5966 J Formation at total depth: Ivishak 10676 9521 31. List of Attachments: Directional Survey,As Run Wellbore Schematic,Well Operations Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Giuseppe Maugeri Printed Name: James Wright Title: Drilling&Completion Engineering Manager Signature: Phone: (907)865-3328 Date: 9/5/2013 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 1b: 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 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 0P22-WW03 • If* 4-1/2" 13Cr 12.6 f Vam Top Production Tubing 2n o 0 pp p 9 ��C��II�um Wellhead, 13-3/8" x 4-W, CR Flow-wetted 5,000 psi Conductor, 20" Uninsulated set at 160 ft Water Producer VIT Jts, 4'1/2" x 6" OD, 204' MD As Completed ' August 15 2013 2223' MD, 2212' TVD, 12° Inc-TR-MAXX 5E 1 SSSV, 3.81" 'X' Profile, 1/<" SS hyd. Control line I 3265' MD, 3,152' TVD 37° Inc- GLM, 4-Y2" x 1", KBG with DCK-2 Ann-to-Tubing 2,000 psi 4-'/2" cable clamp s, for ESP Power Cable, (2) 3/8" Chem Inj Line ESP Power Cable 1SOLBC 5KV 90 LD B Galv. Dual encapsulated 3/8" SS Chem Inj Lines 7254' MD, Landing Nipple Surf. Casing 13-3/8" 68 # 4020' MD, 3728' TVD ESP Assy, 31-562P155SXD Pump, GST3 4B Seals, 270 HP KMX Motor 7311' MD, 6241' TVD, 31° Inc �� 7-5/8 29.7# 13Cr Shroud Assembly ;� .% ,,y� ��, withPenetrator, (2) Chem Inj Line Feed-Thrus, 7,397' MD—TOL - Flex ® Tieback Seal Stem Lock Liner Hanger and �'��. r.73�� y� i�.z.�3 ZXP Packer Assy �' rz Perf Range 9925'-9953' MD, 8773'-8801' TVD Interm. Casing 9980'-10047' MD, 8828'-8894' TVD 9-5/8" 40 # 13 Cr ', 10064'-10103 MD, 8911'-8950' TVD 7,632' MD, 6,475' TVD w 10127'-10188' MD, 8974'-9035' TVD 0223'-10308' MD, 9070'-9155' TVD Approx 5° Inc *- Pump Monitoring: • P intake T intake Production Liner, P discharge 7" 26# 13 Cr 8 1/2" OH T motor 10,675' MD, 9,521' TVD V motor Confidential Eni E&P Division 'Well Name:0P22-WW03 ENI Petroleum Co.Inc. Daily Report Well Code:27295 Field Name:Nikaitchuq • API/UWI:50-029-23489-00-00 2^n Date:7/2/2013 - Report#: 1 II 'I II page 1 of 1 Wellbore name: OP22-WW03 Well Header PermiVConcession N° Operator ENI Share(%) I Well Configuration type ALASKA ENI PETROLEUM 100.00 VERTICAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.00 12.20 36.62 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date 'Target Depth(ftKB) Target Depth(TVD..]Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P22-WW03 DRILLING 7/6/2013 10,855.0 9.694.41 10,154.00 121.12 83.8 -3.21 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) 'Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather 'Wind 0.0 87.0 43.0 Overcast Calm Daily summary operation 24h Summary PREP AND MOB UTILITY MODULE TO END OF WELL ROW. SET HERCULITE AND MATS FOR DRILLING MODULE MOVE TO OP-22. Operation at 07.00 Spotting Drill module over well OP22-WW03 24h Forecast MOB DRILLING MODULE.R/U.N/U R/U DIVERTER SYSTEM. TEST PER AOGCC. MIX SPUD MUD. P/U DP,HWDP RACK BACK Lithology Shows MAASP Pressure(psi) Mud Weight(1b/gall Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 16:00 18:00 2.00 2.00 PREP A 2 P PREP RIG MOVE F/OP08 T/OP22. SECURE CELLAR,RAISE DIXIE CUP,SECURE BOP STACK. P/U BERMING, CUTTINGS BOXES,MATS. DISCONNECT INTERCONNECTS,STEAM,WATER 18:00 20:00 2.00 4.00 MOB A 2 P SECURE ALL LANDINGS AND DOORS BETWEEN SUB AND UTILITY MODULES. SET MATS TO MOVE UTILITY MODULE. 20:00 22:00 2.00 6.00 MOB A 2 P JACK UP UTILITY MODULE,SET ON CRIB BLOCKS.MOVE TO END OF WELL ROW. 22.00 00.00 2.00 8.00 MOB A 2 P P/U MATTING,SPREAD HERCULITE AND MATS AT OP-22. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Bruce Simonson Eni Petroleum Sr.Ddg.Spvr. 907-685-0710 Eni representative Craig Ruminer Eni Petroleum Drilling Supv. Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Tom Klein Eni Petroleum Materials Coordinate 907-685-1491 Eni representative Ken Bogner Eni Petroleum Materials Coordinato Eni representative Bill Petty Eni Petroleum HSE Tool Push Mike Williams Nabors Alaska Dolling Tool Pusher 907-670-1492 Tool Push David Hanson Nabors Alaska Drilling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(kKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(ftKB) 'TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) P. * Eni E&P Division .. !Well Name:0P22-WW03 EN!Petroleum Co.Inc. Daily Report Well Code:27295 Field Name:Nikaitchuq • API/t1Wl:50-029-23489-00-00 2^ft Date:7/4/2013 - Report#: 3 II II II page 1 of 1 Wellbore name: OP22-WW03 Well Header PermiVConcession N° [Operator ENI Share(%) [Well Configuration type ALASKA ENI PETROLEUM 100.00 VERTICAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) IRKB-Tubing Spool(ft) 53.00 12.20 36.62 Rig Information . Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) !Target Depth(TVD..]Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) W OP22- W03 DRILLING 7/6/2013 10.855.0 9694.4 10,154.00 121.12 83.8 -1.21 Daily Information End Depth(ftKB) End Depth(TVD)(f..-Depth Progress(ft) Drilling Hours(hr) [Avg ROP(fl/hr) IPOB Temperature(°F) Weather Wind 0.0 87.0 42.0 Mostly Cloudy ENE @ 9 MPH Daily summary operation 24h Summary N/U DIVERTER SYSTEM AND FLOW RISER. LOAD 240 JTS 5"DP IN SHED,STRAP. MODIFY RISER. INSTALL RISER AND FLOWLINE. P/U M/U STDS 5"DP RACK-BACK IN DERRICK. Operation at 07.00 P/U Drill Pipe 24h Forecast FINISH N/U DIVERTER SYSTEM,TEST. P/U M/U STDS 5"DP,RACK-BACK. BUILD SPUD MUD. P/U MU BHA#1.SPUD WELL. Lithology Shows MAASP Pressure(psi) Mud Weight(I13(gal) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06:00 6.00 6.00 MOB -A 5 P N/U DIVERTER SYSTEM.TO DIVERTER BAG,STING AND N/U DIVERTER COMPONENTS ON WELLHOUSE ROOF. SPOT CUTTINGS BOXES,INSTALL BERMING. LOAD 5"DP IN SHED. 06:00 14:30 8.50 14.50'MOB 'A 5 P N/U DIVERTER AND FLOW RISER. LOAD 5"DP IN SHED,STRAP. WELDER MODIFY RISER. 14:30 16•00 1.50 16.00 MOB E 20 P P/U M/U RACK-BACK 5"DP IN DERRICK. 16:00 '19:00 3.00 19.00 MOB -E 5 P INSTALL RISER AND FLOWLINE. 19:00 '00:00 5.00 24.00 MOB E 20 P P/U M/U RACK-BACK 5"DP IN DERRICK. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Bruce Simonson Eni Petroleum Sr.Ddg.Spvr. 907-685-0710 Eni representative Craig Ruminer Eni Petroleum Drilling Supv. Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 • Eni representative Tom Mein Eni Petroleum Materials Coordinato 907-685-1491 Eni representative Ken Bogner Eni Petroleum Materials Coordinato Eni representative Bill Petty Eni Petroleum HSE Tool Push Kelly Cozby Nabors Alaska Drilling Tool Pusher Tool Push David Hanson Nabors Alaska Dolling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(1b(gal) Leak Off Pressure(psi) 1S Eni E&P Division 1Well Name:0P22-WW03 ENI Petroleum Co.Inc. Daily Report` Well Code:27295 Field Name:Nikaitchuq • APIIUWI:50-029-23489-00-00 enI�n Date:7/5/2013 - Report#: 4 '� 'I page 1 of 1 Wellbore name: OP22-WW03 Well Header PermitlConcession N° 'Operator ENI Share(%) I Well Configuration type ALASKA ENI PETROLEUM 100.00 VERTICAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.00 12.20 36.62 Rig Information Contractor I Rig Name Rig Type NABORS ALASKA !NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date 'Target Depth(ftKB) 'Target Depth(TVD..]Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) I DFS(days) OP22-WW03 DRILLING 7/6/2013 10,855.0 9,694.41 10,154.00 121.12 838 -0,21 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) 'Drilling Hours(hr) 'Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 86.0 49.0 Clear NE @ 4 MPH Daily summary operation 24h Summary FINISH INSTALL DIVERTER LINE.CHANGE OUT KNIFE VALVE W/CRANE,TEST. INSTALL KATCH PAN. P/U M/U R/B 5"DP. DIVERTER SYSTEM TEST-BAG/37 SEC,VALVE/12 SEC.P/U M/U R/B 5"DP 81 STDS TOTAL,4 STDS 5"HWDP. BUILD SPU MU D. CUT AND SLIP DRILL LINE.85'. Operation at 07.00 PRE-SPUD MEETING 24h Forecast FILL STACK,LEAK CHECK.PRE-SPUD MEETING,P/U BHA#1.CLEAN OUT CONDUCTOR,P/U BHA#2,DRILL AHEAD 16"SURFACE HOLE. Lithology 'Shows MAASP Pressure(psi) 'Mud Weight(Iblgal) 8.70 Time Log Start End Cum Time _ Time -Dur(hr(_Dur(hr) Phase Opr. Act. Plan _ Oper.Descr. 00:00 02:30 2.50 2.50 MOB E 5 P FINISH INSTALL DIVERTER LINE. REPLACE KNIFE VALVE WICRANE,TEST. INSTALL KATCH PAN. 02:30 10:00 7.50 10.00 MOB E 20 P P/U M/U RACK-BACK 5"DP IN DERRICK. 10:00 '10:30 ' 0.50' 10.50 MOB E 12 P 'TEST DIVERTER SYSTEM. BAG CLOSING TM=37 SEC. KNIFE VALVE TM=12 SEC. 10.30 18:00 7.50' 18.00 MOB E 20 P 'P/U M/U RACK-BACK 5"DP IN DERRICK. TOTAL 81 STDS 5"DP. P/U M/U 4 STDS 5"HWDP,RACK-BACK IN DERRICK. BUILD SPUD MUD. 18:00 21:00 3.00 21.00 MOB E 25 P CUT AND SLIP DRILL LINE-85' J 21:00 21:30 0.50 21.50 MOB E 25 P SERVICE RIG 21:30 00:00 2.50 24.00 MOB E 1 P 'P/U M/U DRILL COLLARS,L/D DRILL COLLARS Daily Contacts Position Contact Name _ Company _ Title E-mail _ Office Mobile Eni representative Bruce Simonson Eni Petroleum Sr.Ddg.Spvr. 907-685-0710 Eni representative Craig Ruminer Eni Petroleum Dolling Supv. Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Tom Klein Eni Petroleum Materials Coordinato 907-685-1491 Eni representative Ken Bogner Eni Petroleum Materials Coordinato Eni representative Bill Petty Eni Petroleum HSE Tool Push Kelly Cozby Nabors Alaska Drilling Tool Pusher Tool Push David Hanson Nabors Alaska Drilling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(ftKB) 'TVD(ftKB) Fluid Type 'Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) c Eni E&P Division 'Well Name:0P22-WW03 EN!Petroleum Co.Inc. Daily Report Well Code:27295 Field Name:Nikaitchuq • APIIUWI:50-029-23489-00-00 2^o - Date:7/6/2013 - Report#: 5 • II II page 1 of 1 Wellbore name: OP22-WW03 Well Header Permit/Concession N° Operator I EM Share(%) I Well Configuration type ALASKA ENI PETROLEUM 100.00 VERTICAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 12.20 36.62 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA _NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Date 'Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) IDFS(days) OP22-WW03 DRILLING 7/6/2013 10,855.0 9.694.4 10,154.00 121.12 83.8 0.79 Daily Information End Depth(ftKB) End Depth(TVD)(f..f Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather I Wind 677.0 676.0 517.00 3.96 130.6 97.0 47.0 Clear ENE @ 10 MPH Daily summary operation 24h Summary L/D FLEX NMDC. FILL RISER,TEST DIVERTER SYSTEM FOR LEAKS. PRE-SPUD MTG. P/U M/U BHA#1 CLEAN-OUT CONDUCTOR. P/U M/U BHA#2. ROT AND SLIDE DRILL F/160'T/677'. Operation at 07.00 ROT AND SLIDE DRILL AT 950'MD. 24h Forecast ROT AND SLIDE DRILL T/3991'. DIRECTIONAL PLAN PER SLB. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.00 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:00 1.00 1.00 MOB E 1 P L/D FLEX NMDC. 01:00 02:00 1.00 2.00 MOB E '12 P PUMP MUD/FILL RISER. CHECK FOR LEAKS-KNIFE VALVE.FLOW LINE,WELL BAY OUTLETS,ALL CONNECTIONS. NO LEAKS. 02:00 03:00 1.00 3.00 MOB E 1 P PRE-SPUD MTG.ALL PERSONNEL AND 3RD PARTY CONTRACTORS. 03:00 05:00 2.00 5.00 MOB E '20 P PJSM,P/U M/U BHA#1,PER SLB/PROG. 05:00 06:00 1.00 6.00 DRILL E 6 P REAM/WASH T/160'460 GPM,400 PSI,30 RPM.STAGE UP TO 650 GPM.750 PSI,40 RPM. 06:00 06:30 0.50 6.50 DRILL E 4 P TOH,R/B 2 STDS HWDP. 06:30 11:00 4.50 11.00 DRILL E 20 P P/U M/U BHA#2,PER SLB/PROG. 11:00 1330 2.50 13.50 DRILL E 3 P ROTARY DRILL T/310'. SURVEY AT 218',310'PER SLB. 13:30 17:00 3.50 17.00 DRILL E 4 P TOH.R/B 2 SIDS HWDP. UD XO. P/U M/U 3 FLEX DC.JARS,2 HWDP. 17:00 00:00 7.00' 24.00 DRILL E 3 P ROTARY DRILL AND SLIDE F/310'T/677' 10 KWOB,430 GPM,800/1050 PSI,40 RPM,1.9-3.8 KTO.PU WT 95,SO 95 RW 95 -..._._� Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Bruce Simonson Eni Petroleum Sr.DrIg.Spvr. 907-685-0710 Eni representative Craig Ruminer Eni Petroleum Dulling Supv. Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Tom Klein Eni Petroleum Materials Coordinato 907-685-1491 Eni representative Ken Bogner Eni Petroleum Materials Coordinato Eni representative Bill Petty Eni Petroleum HSE Tool Push Kelly Cozby Nabors Alaska Drilling Tool Pusher Tool Push David Hanson Nabors Alaska Drilling Tour Pusher Last Casing seat Cas.Type 1 OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type 'Fluid Density(1b/gall P Surf Applied(psi) Eq.Mud Weight(1b/gall Leak Off Pressure(psi) Eni E&P Division I Well Name:OP22-WW03 cf* ENI Petroleum Co.Inc. Daily Report Well Code:27295 • Field Name:Nikaitchuq Date:7/7/2013 - Report#: 6 APIIUWI:50-029-23489-00-00 t i i page 1 of 1 Wellbore name 0P22-WW03 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA .ENI PETROLEUM 100.00 VERTICAL Rotary Table Elevation(ft) !Ground Level(ft) I Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.00 12.2011 36.62 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E ILAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P22-WW03 DRILLING 7/6/2013 10,855.0 9,694.4 10,154.00 121.12 83.8 1.79 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 2,495.0 2,472.7 1.818.00 14.54 125.0 97.0 38.0 Partly Cloudy _NNE @ 16 MPH Daily summary operation 24h Summary ROT AND SLIDE DRILL F/677'T/2495',PER SLB DIR. Operation at 07.00 ROT AND SLIDE DRILL AT 2,721'MD. 24h Forecast ROT AND SLIDE DRILL T/3991',PER SLB DIR. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.30 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00,00 00:00 24.00 24.00 DRILL E '3 P ROT AND SL DRILL F/677'T/2495'. WOB 20-30K,560 GPM,1250 PSI,40 RPM,2-5 KID. PU 145K,SO 120K.RW 129K.ART=8.68 HRS,AST=5.86 HRS,ADT=14.54 HRS. LOAD 102 JTS 13-3/8"CSG IN SHED,DRIFT,STRAP,TALLY. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative 'Bruce Simonson Eni Petroleum Sr.Ddg.Spvr. 907-685-0710 Eni representative Craig Ruminer Eni Petroleum Drilling Supv. Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Tom Klein Eni Petroleum Materials Coordinato 907-685-1491 Eni representative Ken Bogner Eni Petroleum Materials Coordinato Eni representative Pete Adams Eni Petroleum HSE Tool Push Kelly Cozby Nabors Alaska Drilling Tool Pusher Tool Push David Hanson Nabors Alaska Drilling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type Fluid Density(Iblgal) P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) Ili* Eni E&P Division Well Name:OP22-WW03 I ENI Petroleum Co.Inc. Daily Report Well Code:27295 Field Name:Nikaitchuq • AP/UWI:50-029-23489-00-00 7/8/2013 - Repo #: 7 page 1 of 1 ,Wellbore name: OP22-WW03 Well Header Permit/Concession N° 'Operator EM Share(%) Well Configuration type ALASKA IENI PETROLEUM 100.00 VERTICAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.00 12.20 36.62 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date 'Target Depth(ftKB) !Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP22-WW03 DRILLING 7/6/2013 10,855.0 9,694.4 10,154.00 121.12 83.8 2.79 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 3,299.0 3,179.2 804.00 12.84 62.6 97.0 36.0 Light Rain NE @ 15 MPH Daily summary operation 24h Summary ROT AND SLIDE DRILL F/2495'T/3299',PER SLB DIR. ROUGH/HARD DRILLING,TQ AND PRESS SPIKES. BROOH FOR NEW BIT/BHA. Operation at 07.00 BROOH FOR NEW BIT/BHA.TOH ON ELEVATORS AT 2,302' 24h Forecast BR/TOH L/D BHA#2,P/U BHA#3. TIH,ROT AND SL TO CASING PT,3948' Lithology 'Shows MAASP Pressure(psi) 'Mud Weight(lb/gal) 9.20 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 18:30 18.50 18.50 DRILL E 3 P ROT AND SL DRILL F/2495'T/3299'. WOB 10-25K,660 GPM.1500 PSI,45 RPM,3-8 KTQ. PU 160K,SO 125K,RW 135K.ART=7.04 HRS,AST=5.80 HRS,ADT=12.84 HRS. TIGHT-2594-8',2806',2981'. HARD/ROUGH DRILLING AT 3290'. TOPDRIVE AND MOTOR STALL-PRESS AND TO SPIKES. P/U REAM TO BOTTOM. 18:30 20:00 1.50 20.00 DRILL E 7 P CIRC AND RECIP PIPE 60'. EVALUATE DRILLING DATA-TRIP FOR NEW BIT,MOTOR,AND TOOLS. 20:00 21:30 1.50 21.50 DRILL E 19 P PERFORM MWD SURVEY AT BOTTOM,DOWN-LINK GYRO TOOL. 21:30 00:00 ' 2.50 24.00 DRILL E 6 P BROOH 6 STDS AT 1 BU CIRC/STD. BR F/3299'T/3000',800 GPM,1600 PSI,80 RPM. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Bruce Simonson Eni Petroleum 'Sr.DrIg.Spvr. 907-685-0710 Eni representative Craig Ruminer Eni Petroleum Drilling Supv. Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Tom Klein Eni Petroleum Materials Coordinate 907-685-1491 Eni representative Ken Bogner Eni Petroleum Materials Coordinate Eni representative Pete Adams Eni Petroleum HSE Tool Push Kelly Cozby Nabors Alaska Drilling Tool Pusher Tool Push David Hanson Nabors Alaska Drilling Tour Pusher Last Casing seat Can.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date Ca-ii Leakoff Test Depth(ftKB) I TVD(ftKB) Fluid Type 'Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) • Eni E&P Division 'Well Name:OP22-WW03 I PI* ENI Petroleum Co.Inc. Daily Report Well Code:27295 Field Name:Nikaitchuq • APIIUWI:50-029-23489-00-00 2�, Date:7/9/2013 - Report#: 8 I' II page 1 of 1 Wellbore name: OP22-WW03 Well Header Permit/Concession N° Operator I ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 VERTICAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 12.20 36.62 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date 'Target Depth(ftKB) !Target Depth(ND..1 Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) I DFS(days) OP22-WW03 DRILLING 7/6/2013 10,855.01 9,694.41 10,154.00 121.12 83.8 3.79 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) I POB Temperature(°F) Weather 'Wind 3,299.0 3,179.2 0.00 101.0 34.0 Overcast ENE @ 16 MPH Daily summary operation 24h Summary TRIP FOR BHA#3 Operation at 07.00 DRILLING AHEAD @ 3,337'MD 24h Forecast DRILLING AHEAD Lithology I Shows MAASP Pressure(psi) 'Mud Weight(Iblgal) 9.30 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:00 3.00 3.00 DRILL E 6 P BACK REAMING F/3013'T/2687'PUMP 1600-1700 PSI @ 800 GPM.RPM 80 ROT TO 3-7K PUMP 1X BTMS.UP PER STD.FLOW CHECK WELL OK,BLOW DN TOP DRIVE. 03:00 09:30 6.50 9.50 DRILL E 4 P TRIP OUT OF HOLE F/2687'ON ELEVATORS,CHECK F/SWABBING OK.PUMP SURVEYS @ 1725'1247'NOTE: OCCASIONAL BRIEF OVER PULL 30K THAN NORMAL. 09:30 12:00 2.50 12.00 DRILL E 4 P LAY DOWN BHA TOP STABILIZER,ARC,TELESCOPE,&GYRO,B/O BIT @ E.O.T. 12:00 13:30 1.50 13.50 DRILL E 4 P LAY DOWN BHA CON'T L/D BHA#2 STABE,XO,L/D PDM T/SHED 13:30 14:00 0.50 14.00 DRILL E 4 P CLEANING RIG/PLATFORM L/D TOOLS TO SHED,CLEAN OFF FLOOR PREP T/P/U BHA 14:00 20:30 6.50 20.50 DRILL E 4 P PICK UP BHA#3 MOTOR,STAB,ARC,MWD,AND DD ORIENTATE TOOLS,M/U BIT,RIH,P/U COLLER.XO,STAB. COLLER STD,JAR STD,HWDP, RIH 1 STD T/760'SHALLOW HOLE TEST,615 GPM,850 PSI,B/D TOP DRIVE, 20:30 23:30 3.00 23.50 DRILL E 4 P CON'T TIH F/760,T/3298'UPW=155,DNW=120,RTW=138,FILL EVERY 20 STDS,26 BBLS T/FILL,TIGHT SPOT @ 1991'-2130 ROT 20'WIPE THROUGH, 23:30 00:00 0.50 24.00 DRILL E 4 P MAD PASS F/3298'T/3189'40 RPM,650 GPM,1425 PSI,400 FPH MAX Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Nelson Carballo Eni Petroleum Drilling Superintend Eni representative Bruce Simonson Eni Petroleum Sr.Drlg.Spvr. 907-685-0710 Eni representative Dean Sherman Eni Petroleum Drilling Supv. 907-685-0710 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Tom Klein Eni Petroleum Materials Coordinato 907-685-1491 Eni representative Ken Bogner Eni Petroleum Materials Coordinato Eni representative Pete Adams Eni Petroleum HSE Tool Push Kelly Cozby Nabors Alaska Drilling Tool Pusher Tool Push David Hanson Nabors Alaska Drilling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(ftKB) IND(ftKB) Fluid Type 'Fluid Density(lb/gal) IP Surf Applied(psi) IEq.Mud Weight(lb/gal) Leak Off Pressure(psi) • Eni E&P Division Well Name:0P22-WW03 11* ENI Petroleum Co.Inc. Daily Report Well Code:27295 Field Name: Nikaitchuq • AP/UWI:50-029-23489-00-00 Date:7/10/2013 - Repo #: 9 2^n page 1 of 1 Wellbore name: OP22-WW03 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 VERTICAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) 'RKB-Tubing Spool(ft) 53.00 12.20 36.62 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) !Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) W OP22- W03 DRILLING 7/6/2013 10,855.01 9,694.4 10,154.00 121.12 83.8 4.79 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 4.031.0 3,735.7 732.00 17.06 42.9 100.0 37.0 Partly Cloudy.WC ENE @ 18 MPH 27' Daily summary operation 24h Summary DRILLING F/3299-4031' Operation at 07•0 BROOH at 3,449'MD. 24h Forecast BROOH.UD BHA#3. PREP TO RUN 13-3/8"CASING. Lithology 'Shows MAASP Pressure(psi) Mud Weight(Iblgal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 12:00 12.00 12.00 DRILL E 3 P DRILLING F/3299'T/3500'PUMP 1400-1500 PSI @ 660 GPM,RPM 20-50 ROT TO 6-7K UP W.T.163K DN W.T.120K ROT W.T.142K WOB 10-25K ART=6.79 AST=.67 BIT HRS 8.3 @ E.O.T. 12:00 22:00 10.00 22.00 DRILL E 3 P DRILLING F/3500'T/4031'1750 PSI @ 750 GPM,RPM 20-60 ROT TO 6-7K UPW=175K DNW=128K RTW=145K WOB 10-25K ART=8.61AST=.15 ADT=8.76 JARS=56.71 2200 00:00 2.00' 24.00 DRILL E 3 P CBU F/4031'T/3934'CIRC 800 GPM,ROT 80 RPM,T0=5.2-6.3K,1800 PSI. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Davide Simeone Eni Petroleum 'Drilling Manager Eni representative Nelson Carballo Eni Petroleum Dolling Superintend Eni representative Bruce Simonson Eni Petroleum Sr.Drlg.Spvr. 907-685-0710 Eni representative Dean Sherman Eni Petroleum Drilling Supv. 907-685-0710 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Tom Klein Eni Petroleum Materials Coordinato 907-685-1491 • Eni representative Ken Bogner Eni Petroleum Materials Coordinato Eni representative Pete Adams Eni Petroleum HSE Tool Push Kelly Cozby Nabors Alaska Drilling Tool Pusher Tool Push David Hanson Nabors Alaska Drilling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date Last Leakoff Test I Depth(ftKB) /TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) Eni E&P Division [Well Name:0P22-WW03 Iff* ENI Petroleum Co.Inc. Daily Report Well Code:27295 Field Name:Nikaitchuq •" Date:7/11/2013 - Report#: 10 APIIUWI:50-029-23489-00-00 2" page 1 of 1 Wellbore name: OP22-WW03 Well Header Permit/Concession N° Operator ENI Share(%) I Well Configuration type ALASKA ENI PETROLEUM 100.00 VERTICAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) IRKB-Tubing Spool(ft) 53.00 12.20 36.62 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) [Target Depth(TVD..]Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) I DFS(days) WW OP22- 03 DRILLING 7/6/2013 10,855.01 9,694.41 10,154.00 121.12 83.8 5.79 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 4,031.0 3,735.7 0.00 100.0 34.0 Scattered Clouds, ENE @ 16 MPH • WC 24' Daily summary operation 24h Summary BROOH F/CASING Operation at 07.00 TIH W/13 3/8"CSG 24h Forecast TIH W/13 3/8"CASING Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.50 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:00 1.00 1.00 DRILL E 4 -P BACK REAMING F/3934 PUMP 1800 PSI @ 800 GPM,RPM 80-100 ROT TO 6-7K ROT W.T.143K UP W.T.175K DN W.T.129K PULL SPEED 5-10 FT PER MIN. 01:00 01:15 0.25 1.25 DRILL E 4 P 'D3 DRILL.DIVERTING SHALLOW GAS W/CREW 01:15 12:00 10.75 12.00 DRILL E 4 P BACK REAMING F/3823'F/1348'PUMP 1450 PSI @ 800 GPM,RPM 120 ROT TO 2K ROT W.T.110K PULL SPEED 5- 10 FT PER MIN.NOTE:HOLE CUTTINGS UNLOADED @ SHAKERS F/1444'T/1412'SLOWED PULLING RATE BACKED OFF PUMPS T/500-600 GPM.STAGED PUMPS BACK T/800 GPM 12:00 14:00 2.00 14,00 DRILL E 4 P BACK REAMING F/1348'F/679'PUMP 1450 PSI @ 800 GPM,RPM 120 ROT TO 2K RTW=110K PULL SPEED 5-10 FT PER MIN. 14:00 14:30 0.50 14.50 DRILL E 4 P D-3 DRILL WITH ALL HAND ON RIG,DISSCUSED LESSONS LEARNED.CREW ROSTER MISSING HANDS,NEED TO SIGN IN AT SHACK, 14:30 15:30 1.00 15.50 DRILL E 7 P CIRC 2X BUS TILL CLEAN AS PER MI MUD MAN,CICP 15-20'800 GPM,120 RPM,1200 PSI,T0=800-1000K 15:30 21:00 5.50 21.00 DRILL E 4 P LAY DOWN BHA POOH ON ELEVATORS F/679'RACK BACK 4 STDS 5"HWDP IN DERRICK L/D BHA*3 T/SHED 21:00 23.00 2.00 23.00 DRILL E 25 U DOWNTIME-HOISTING/LIFTING HYD HOSE FAILURE.REMOVE AND REPAIR,CLEAN RIG FLOOR,SERVICE RIG. 23:00 00:00 1.00 24.00 DRILL E 4 P CON'T L/D BHA F/57' Daily Contacts Position Contact Name _ Company Title E-mail Office Mobile Eni representative Davide Simeone Eni Petroleum Drilling Manager Eni representative Bruce Simonson Eni Petroleum Sr.Drig.Spvr. 907-685-0710 Eni representative Dean Sherman Eni Petroleum Dulling Supv. 907-685-0710 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Tom Klein Eni Petroleum Materials Coordinato 907-685-1491 Eni representative Ken Bogner Eni Petroleum Materials Coordinato Eni representative Pete Adams Eni Petroleum HSE Tool Push Kelly Cozby Nabors Alaska Drilling Tool Pusher Tool Push Kenny Sullivan Nabors Alaska Drilling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(ftKB) I TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gat) Leak Off Pressure(psi) cEni E&P Division `Well Name:0P22-WW03 11* ENI Petroleum Co.Inc. Daily Report Well Code:27295 Field Name: Nikaitchuq El• Date:7/12/2013 - Report#: 11 API/UWI:50-029-23489-00-00 2" " page 1 of 1 Wellbore name: OP22-WW03 Well Header Permit/Concession N° (Operator (ENI Share)%) Well Configuration type ALASKA ENI PETROLEUM 100.00 VERTICAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.00 12.20 36.62 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Date 'Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DES(days) OP22-WW03 DRILLING 7/6/2013 10,855.0 9694.4 10,154.00 121.12 83.8 6.79 Daily Information End Depth(ftKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 4,031.0 3,735.7 0.00 101.0 39.0 Partly Cloudy.WC ENE @ 14 MPH 31' Daily summary operation 24h Summary TIH 13 3/8"CSG Operation at 07.00 TIH 13 3/8"CSG 24h Forecast TIH 13 3/8"CSG.CMT,NIPPLE DN Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.50 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 01:30 1.50 1.50 DRILL E 4 P 'LAY DOWN BHA ARC,LOWER STAB 8,MUD MOTOR AS PER SCHLUMBERGER. 01:30 03:00 1.50 3.00 DRILL G 12 P '13 3/8"LANDING HANGER T/VERIFY HANGER WAS LANDED ON THE LOAD SHOULDER,L/D LANDING HANGER. 03:00 08:00 5.00 8.00 DRILL G 4 P PICK UP 3RD PARTY TOOLS F/RUNNINGI3 3/8"CSG.RU VOLANT TOOL RUN CASING M/U SHOE TRACK BAKER LOK FIRST TWO CONNECTIONS,FILL PIPE CHECK FLOATS OK.INSTALL CENTRALIZERS AS PER RUNNING SHEET. 08.00 12:00 4.00 12.00 DRILL G 4 P RUN CASING T/1037"FILL EVERYJT.WHILE RIH,DN W.T.90-95K 12:00 15:15 3.25 15.25 DRILL G 4 P 'RUN 13 3/8 CASING L-80 BTC 68 LBS.PER FT.USING VOLANT TOOL,FROM 1037'TO 1280'DEPTH. 15:15 16:00 0.75 16.00 DRILL G 7 P 'RECIPROCATE CASING WHILE WHILE CIRCULATING TO CLEAN UP HOLE.MAX.PUMPING RATE 6 BPM,TOTAL STROKES APPROX.2700. 16:00 23.00 7.00 23.00 DRILL G 4 P RUN 13 3/8 CASING TO 3270 FT.DEPTH(JOINT 82). 23:00 00.00 1.00 24.00 DRILL G 7 P CIRCULATE AND CONDITION 5 BLS/MIN MONITOR LOSSES.RECIPROCATE WHILE CIRCULATING TOTAL STKS 2500 Daily Contacts Position Contact Name Company Title E-mail _ Office Mobile Eni representative Bruce Simonson 'Eni Petroleum Sr.DrIg.Spvr. 907-685-0710 Eni representative Dean Sherman Eni Petroleum Dulling Supv. 907-685-0710 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Tom Klein Eni Petroleum Materials Coordinato 907-685-1491 Eni representative Ken Bogner Eni Petroleum Materials Coordinato Eni representative Pete Adams Eni Petroleum HSE Tool Push Kelly Cozby Nabors Alaska Drilling Tool Pusher Tool Push Kenny Sullivan Nabors Alaska Drilling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L-80 -0.8 4,020.0 7/12/2013 Last Leakoff Test Depth(ftKB) I TVD(ftKB) Fluid Type Fluid Density(1b/gall I P Surf Applied(psi) Eq.Mud Weight(lb/gal) !Leak Off Pressure(psi) 177771 Eni E&P Division /Well Name:OP22-WW03 EN!Petroleum Co.Inc. Daily Report Well Code:27295 Field Name:Nikaitchuq • Date:7/13/2013 - Report#: 12 API/t1Wl:50-029-23489-00-00 2 rr rr Q page 1 of 1 Wellbore name OP22-WW03 Well Header Permit/Concession N° Operator IENI Share(%) 'Well Configuration type ALASKA ENI PETROLEUM 100.00 VERTICAL Rotary Table Elevation(ft) 'Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) 'RKB-Tubing Spool(ft) 53.00 12.20 36.62 Rig Information Contractor Rig Name 1Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date 'Target Depth(ftKB) Target Depth(TVD..lDepth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP22-WW03 DRILLING 7/6/2013 10.855.0 9,694.4 10,154.00 121.12 83.8 7.79 Daily Information End Depth(ftKB) End Depth(TVD((f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POE Temperature(°F) Weather Wind 4,031.0 3,735.7 0.00 100.0 40.0 Partly Cloudy.WC ENE @ 16 MPH 33' Daily summary operation 24h Summary TIH 13 3/8"CSG,CMT,N/D ANNULAR.R/D DIVERTER SYSTEM.R/D KNIFE VALVE. Operation at 07.00 N/U BOPE. 24h Forecast N/U BOPE AND TEST Lithology 'Shows MAASP Pressure(psi) 'Mud Weight(lb/gal) 9.50 Time Log Start End Cum • Time Time Dur(hr) Dur(hr) Phase Opr. Act. • Plan Oper.Descr. 00:00 00:30 ' 0.50 0.50 DRILL G 7 ‘P CIRCULATE AND CONDITION @ 3272'PUMP 5 BPM @ 100 PSI rr 00:30 03:00 2.50 3.00 DRILL G 4 .P RUN CASING F/3273'T/4020'DN W.T.240K W/LANDING JT. C. 03:00 05:00 2.00 5.00 DRILL G 7 'P CIRCULATE ANDCONDITION(@4020'PUMP 5 BPM @ 123?SY'� -� ,(``I, 05:00 12:00 7.00 12.00 DRILL H 7 'P ,/ PRE JOB SAFETY MEETING W/SCHLUMBERGER&THIRD PARTY PERSONAL INVOLED W/CMT JOB,PRESSURE'\"') 5v_ TEST CEMENT LINES T/3500 PSI CIRCULATE/CEMENT/DISPLACE 100 BBLS OF MUD PUSH 10.1 PPG 330 PSI @ 5 I .,! BPM,DROP BTM PLUG PUMP 609 BBLS OF ARCTIC LITE CMT 11.2 PPG 675 PSI @ 5.5 BPM,PUMP 68 BBL OF TAIL . � 12.5 PPG @ 4.5 BPM,700 PSI PUMP 10 BBLS OF H2O. CIRCULATE/CEMENT/DISPLACE W/CONDITIONAL MUD PUMP 4.5 BPM @ 400 PSI @ E.O.T. 4,0 12:00 13:00 1.00 13.00 DRILL H 7 'P PUSH CEMENT WITH RIG PUMP,BUMP PLUG.C.I.P.12:21 P.M.(5700 STROKES)FCP 600 3 PSI.PUMP 1-1.5 BPM TO 1100 PSI. '2 13:00 17:30 ' 4.50 17.50 DRILL G 4 'P USH STACK,LD LANDING JOINT AND VOLANT CASING RUNNING TOOL. __�// - J 17:30 00.00 6.50 24.00 DRILL G 5 'P N/D D YST RRJSi_DOWN KATCH KAN FLOW LINEAND RISER:CtfPtt/FLUSH RESIDUAL CEMENT FROM ANNULAR.N/DN ANNULAR Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Bruce Simonson Eni Petroleum Sr.DrIg.Spvr. 907-685-0710 Eni representative Dean Sherman Eni Petroleum Drilling Supv. 907-685-0710 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Tom Klein Eni Petroleum Materials Coordinato 907-685-1491 Eni representative Ken Bogner Eni Petroleum Materials Coordinato Eni representative Pete Adams Eni Petroleum HSE Tool Push Kelly Cozby Nabors Alaska Drilling Tool Pusher Tool Push Kenny Sullivan Nabors Alaska Drilling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L-80 -0.8 4,020.0 7/12/2013 Last Leakoff Test Depth(ftKB) 'ND(ftKB) Fluid Type 'Fluid Density(lb/gal) 'P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) P. _n Eni E&P Division 'Well Name:0P22-WW03 ENI Petroleum Co.Inc. Daily Report Well Code:27295 Field Name:Nikaitchuq • APIIUW:50-029-23489-00-00 2^n Date:7/14/2013 - Report#: 13 i i II page 1 of 1 Wellbore name: OP22-WW03 Well Header Permit/Concession N° Operator ENI Share(%) !Well Configuration type ALASKA ENI PETROLEUM 100.00 VERTICAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 12.20 36.62 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD..]Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) I DFS(days) OP22-WW03 DRILLING 7/6/2013 10,855.0 9.694.41 10,154.00 121.12 83.8 8.79 Daily Information End Depth(RKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) •POB Temperature(°F) Weather Wnd 4.031.0 3,735.7 0.00 99.0 41.0 Partly Cloudy.WC ENE @ 11 MPH 32- Daily summary operation 24h Summary RIG MOVE PREP,TEST CSG SHOE Operation at 07.00 L/D DRILL PIPE 24h Forecast L/D DRILL PIPE,DISPLACE Lithology Shows MAASP Pressure(psi) I Mud Weight(lb/gal) 9.30 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. _ Act. Plan _ Oper.Descr. 00.00 12:00 12.00 12.00 DRILL A 1 P INSPECT DIVERTER LINES.CLEANING PITS/CMT 12.00 22:00 10.00 22.00 DRILL A 1 P CLEANING PITS/CMT 22.00 00:00 2.00 24.00'DRILL A 1 P 'SET WEAR RING,PRESSURE TEST CSG/SHOE RIG UP AND PERFORM CASING TEST AS PER COMPANY MAN.30 G6Sf1 MIN.TEST,2500 PSI,CHARTED. d Daily Contacts S Position _ Contact Name Company Title E-mail Office Mobile Eni representative Bruce Simonson Eni Petroleum Sr.Ddg.Spvr. 907-685-0710 Eni representative Dean Sherman Eni Petroleum Drilling Supv. 907-605-0710 Eni representative Bemie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Tom Klein Eni Petroleum Materials Coordinato 907-685-1491 Eni representative Ken Bogner Eni Petroleum Materials Coordinato Eni representative Pete Adams Eni Petroleum HSE Tool Push Kelly Cozby Nabors Alaska Dolling Tool Pusher Tool Push Kenny Sullivan Nabors Alaska Drilling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L-80 -0.8 4,020.0 7/12/2013 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type 'Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) i i S 31 378 Eni E&P Division 'Well Name:0P22-WW03 ft* ENI Petroleum Co.Inc. Daily Report Well Code:27295 Field Name:Nikaitchuq • Date:712312013 - Report#: 14 API/UWI:50-029-23489-00-00 2" " page 1 of 1 Wellbore name: OP22-WW03 Well Header Permit/Concession N° I Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100._00_VERTICAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.00 12.20 36.62 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) 'Target Depth(TVD..,Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) W OP22- W03 DRILLING 7/6/2013 10,855.01 9694.4 10,154.00 121.12 83.8 17.79 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 4.031.0 3,735.7 0.00 88.0 44.0 Mostly Cloudy W @ 19 MPH Daily summary operation 24h Summary TEST BOPE. Operation at 07.00 • P/U DP 24h Forecast P/U DP,BHA,13/0 SHOE TRACK.DISP T/LSND Lithology 'Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.30 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 12,00 12:30 0.50 0.50 DRILL H 4 P POOH,UD TBG HNGR 12:30 00:00 11.50 12.00 DRILL C 12 P TEST BOPS W/5"TEST JT.TO 250 PSI LOW,5,000 PSI HIGH.ANNULAR BAG 250 LOW 5,000 HIGH.ACCUMULATOR n n TEST 200 PSI FOR 36 SEC.FULL RECOVERY=162 SEC.N2=2,500 PSI AVG.6 BOTTLES.BOPE TEST WITNESSED 'J 0,.Y BY AOGCC REP JEFF TURKINGTON. YYY Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative 'Oliver Amend Eni Petroleum Drliing Supervisor J Eni representative Dean Sherman Eni Petroleum Drilling Supv. 907-685-0710 Eni representative Tom Klein Eni Petroleum Materials Coordinato 907-685-1491 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Shaun Denning ENI Petroleum HSE Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Kenny Sullivan Nabors Alaska Dulling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L-80 -0.8 4,020.0 7/12/2013 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(1b/gall I P Surf Applied(psi) Eq.Mud Weight(1b/gal) Leak Off Pressure(psi) 5� 1 Eni E&P Division (Well Name.0P22-WW03 ENI Petroleum Co.Inc. Daily Report Well Code:27295 Field Name:Nikaitchuq Date:7/2412013 - Report#: 15 APIIl1Wl:50-029-23489-00-00 e n r' page 1 of 1 Wellbore name OP22-WW03 Well Header Permit/Concession N° 'Operator ENI Share(%) I Well Configuration type ALASKA ENI PETROLEUM 100.00 VERTICAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) IRKB-Tubing Spool(ft) 53,00 12.20 36.62 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) 'Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P22-WW03 DRILLING 7/6/2013 10,855.0 9694.4 10,154.00 121.12 83.8 18.79 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 4,031.0 3,735.7 0.00 82.0 42.0 Cloudy WSW @ 18 MPH Daily summary operation 24h Summary P/U DP,BHA#4 Operation at 07.00 DRILLING SHOE TRACK '24h Forecast TIH,DRILL SHOE TRACK,DISP W/LSND,FIT,DRILL AHEAD Lithology Shows MAASP Pressure(psi) /Mud Weight(Iblgal) 9.30 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 03:30 3.50 3.50 DRILL C 12 P TEST BOPE 03:30 08:30 5.00' 8.50 DRILL E 4 P P/U DP T/2835 08:30 10:00 1.50 10.00 DRILL E 4 P TOOH STAND BACK SLM,CULL PIPE 10:00 13:00 3.00' 13.00 DRILL E 4 P P/U PIPE,TOOH,STAND BACK,SLM 13:00 14.30 1.50 14.50 DRILL E 4 P P/U BHA#4 14:30 15.00 0.50 15.00 DRILL E 4 P SERV.RIG 15:00 23:00 8.00 23.00 DRILL E 4 P P/U BHA#4„TIH T/658'.SHLW PLS TEST @600 GPM 23.00 00:00 1.00 24.00 DRILL E 4 P TIH Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Oliver Amend Eni Petroleum Drliing Supervisor Eni representative Dean Sherman En:Petroleum Dulling Supv. 907-685-0710 Eni representative Tom Klein Eni Petroleum Materials Coordinato 907-685-1491 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Shaun Denning ENI Petroleum HSE Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Kenny Sullivan Nabors Alaska Drilling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L-80 -0.8 4,020.0 7/12/2013 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type 'Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 4,021.0 3,728.37 LSND 1 9.30 636.0 12.58 2,437.2 I f Eni E&P Division I Well Name:0P22-WW03 ENI Petroleum Co.Inc. Daily Report Well Code:27295 Field Name: Nikaitchuq • API/UWI:50-029-23489-00-00 2 I'^rl Date:7/25/2013 - Report#: 16 I' II page 1 of 1 Wellbore name: OP22-WW03 Well Header Permit/Concession N° Operator IENI Share(%( I Well Configuration type ALASKA ENI PETROLEUM 100.00 VERTICAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 12.20 36.62 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) IDFS(days) W OP22- W03 DRILLING 7/6/2013 10,855.0 9.694.4 10.154.00 121.12 838 19.79 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ftlhr) 'P06 Temperature(°F) Weather Wind 4,679.0 4,219.9 648.00 6.22 104.2 90.0 44.0 Mostly Cloudy SW @ 11 MPH Daily summary operation 24h Summary DRL SH/TRACK,FIT,DRL Operation at 07.00 DRL @ 5063'MD 24h Forecast DRL AHEAD Lithology Shows MAASP Pressure(psi) 'Mud Weight(1b/gal) 9.30 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:30 1.50 1.50 DRILL E 4 P TIH TOC 3923' 01:30 04:00 2.50' 4.00 DRILL E 4 P D/O CMT,FLT CLR&CMT T/4013'MD 04:00 06:30 2.50 6.50 DRILL E 7 P DISP BRINE T/LSND 06:30 09:00 2.50 9.00 DRILL E 20 P CUT AND SLP,SERV.RIG 09:00 11:30 2,50 11.50 DRILL E 3 P DRL THR/SHOE&20'NEW HOLE 11:30 12:30 1.00 12.50 DRILL E 7 P CBU 12:30 14:30 2.00 14.50 DRILL E I 19 P \s„ FIT,12.58 EMW 14:30 15:00 0.50 15.00 DRILL E 20 P G SERV! 15:00 00:00 9.00 24.00 DRILL E 3 P DRL Daily Contacts Position Contact Name Company Title E-mail Office Mobile • • Eni representative Oliver Amend Eni Petroleum Ddiing Supervisor + Eni representative Dean Sherman Eni Petroleum Drilling Supv. 907.685-0710 Eni representative Tom Klein Eni Petroleum Materials Coordinato 907-685-1491 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Shaun Denning ENI Petroleum HSE Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Dolling Tool Pusher 907-670-1492 Tool Push Kenny Sullivan Nabors Alaska Drilling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L-80 -0.8 4,020.0 7/12/2013 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type 'Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Oft Pressure(psi) 4,021.0 3,728.37 LSND 9.30 636.0 12.58 2,437.2 1 Eni E&P Division (Well Name:0P22-WW03 ENI Petroleum Co.Inc. Daily Report Well Code:27295 Field Name:Nikaitchuq • Date:7/26/2013 - Report#: 17 APIIUWI:50-029-23489-00-00 2" " page 1 of 1 Wellbore name: OP22-WW03 Well Header Permit/Concession N° Operator ENI Share(%) 'Well Configuration type ALASKA ENI PETROLEUM 100.00 VERTICAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.00 12.20 36.62 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD..JDepth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP22-WW03 DRILLING 7/6/2013 10,855.0_ 9.694.41 10,154.00 121.12 83.8 20.79 Daily Information End Depth(ftKB) End Depth(TVD)(f..JDepth Progress(ft) 'Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 6.528.0 5.613.9 1,849.001 16.99 108.8 84.0 50.0 Mostly Cloudy N @ 4 MPH Daily summary operation 24h Summary DRL F/4679'-6528'MD,5614'TVD Operation at 07.00 DRL @ 6,754'MD 24h Forecast DRL T/CSG PT,BROOH Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.30 Time Log Start End Cum Time _ Time Dur(hr) Dur(hr) Phase Opr. Act. _ Plan Oper.Descr. 00.00 06:00 6.00 6.00 DRILL E 3 P DRL F/4679'MD T/5270'MD,4663'TVD.GPM=900 RPM=100 TQ=6-7K,UP=170,DN=140,ROT=150,WOB=10-20K, PSI=1800-1950, SPR @5061'MD-4570'TVD.#1 30/40 STKS-180/220,#3 30/40 STKS-160/200.SLDG AS PER DD 06.00 '12:00 - 6.00 12.00 DRILL E3 P ROTARY DRILLING F/5270'T/'5731 GPM=900 RPM=100 TO=8-9K UP=190 DN=153 ROT=170 WOB=10-20K PSI=2200 ADT=8.57 JAR HRS=8.57 AST=2.04 MD=5636 TVD=4934 SPR=#1&#3 30/40 200/280 180/230 12:00 '00:00 - 12.00 24.00 DRILL E 3 P ROTARY DRILLING F/5731"T/'6528'GPM=900 RPM=100 TQ=9-13K UPW=200 DNW=162 RTW=174 WOB=10-15 K PSI=2350 ART=6.77 AST=1.65 ADT=8.42 JAR HRS=23.74 SPR'S @ MD=6110 TVD=5294 MW=9.4 PMP#16#3 30/40 220/240 200/240 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Oliver Amend -Eni Petroleum Ddiing Supervisor Eni representative Dean Sherman Eni Petroleum Dulling Supv. 907-685-0710 Eni representative Tom Klein Eni Petroleum Materials Coordinato 907-685-1491 Eni representative Mitch Bitlington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Shaun Denning ENI Petroleum HSE Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push David Hanson Nabors Alaska Drilling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L-80 -0.8 4,020.0 7/12/2013 Last Leakoff Test Depth(ftKB) IND(ftKB) Fluid Type Fluid Density(lb/gal) IP Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 4,021.0 3,728.37 LSND 9.30 636.0 12.58 2,437.2 1 D Eni E&P Division 'Well Name:0P22-WW03 ENI Petroleum Co.Inc. Daily Report Well Code:27295 Field Name:Nikaitchuq • Date:7/27/2013 - Report#: 18 APIIl1Wl:50-029-23489-00-00 2n ii Wellbore name: OP22-WW03 page 1 of 1 Well Header Permit/Concession N° 'Operator ENI Share)%) Well Configuration type ALASKA ENI PETROLEUM 100.00 VERTICAL Rotary Table Elevation(It) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 12.20 36.62 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD..]Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) IDES(days) OP22-VVW03 DRILLING 7/6/2013 10.855.0 9.694.4 10,154.00 121.12 83.8 21.79 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) 'Drilling Hours(hr) 'Avg ROP(fUhr) P08 Temperature(°F) Weather Wind 7646.0 6,540.4 1.118.00 14.93 74.9 89.0 57.0 Overcast S @ 9 MPH Daily summary operation 24h Summary DRL T/CSG PT.7646'MD Operation at 07.00 BROOH 24h Forecast BROOH,TIH W/CSG Lithology I Shows MAASP Pressure(psi) Mud Weight(1b/gal) 9.80 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06.00 6.00 6.00 DRILL E 3 P ROTARY DRILLING F/6528'T/6881'GPM=850 RPM=100 PSI=2450 TO=9-13K WOB=9-12K UP=205 DN=170 ROT= 185 SPR MD=6690 TVD=5719 MWT=9.5+#1 8 93 STKS=30/40 190/220 210/240 GAS=45 UNITS SLIDE AS PER DD 06:00 12.00 6.00 12.00 DRILL E 3 P ROTARY DRILLING F/6881'T/7200 GPM=850 RPM=100 TQ=10-14 PSI=2500 WOB=10-14 UP=215 DN=173 ROT=193 GAS=40 SPR-MD=7168 TVD=6116#183 30/40 220/250 210/260 ADT=9.02 AST=3.39 ART=5.63 JAR=9.02 12.00 20:30 8.50 20.50 DRILL E 3 P ROTARY DRILLING F/7200'T/7646'TD FOR 9 5/8"CSG,GPM=850 RPM=100 TQ=7-10 PSI=2765 WOB=10-14 UP=220 DN=185 RT=195 SPR'S @ MD=7643 TVD=6535#183 30/40 260/280 240/280 ADT=5.91 AST=2.52 ART=3.39 JAR=38.68 20:30 21:30 1.00 21.50 DRILL E 7 P PUMP 40 BBL HI VIS SWEEP.CIRC BUS @ 900 GPM,ROT=80 RPM.212 SPM,2800 PSI,TQ=6K.RICP 90' 21:30 00:00 2,50 24.00 DRILL E 4 P BROOH F/7643'T/7168'80 RPM,900 GPM,2700 PSI.TO 4-5 RTW UP 185,5-6 MIN PER STD Daily Contacts Position Contact Name Company Title 1 E-mail Office Mobile Eni representative Oliver Amend Eni Petroleum Duffing Supervisor Eni representative Dean Sherman Em Petroleum Dulling Supv. 907-685-0710 Eni representative Tom Klein Eni Petroleum Materials Coordinato 907-685-1491 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Shaun Denning ENI Petroleum HSE Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push David Hanson Nabors Alaska Drilling Tour Pusher ' Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Data CASING 13 3/8 12.415 L-80 -0.8 4,020.0 7/12/2013 Last Leakoff Test Depth(ftKB) I TVD(ftKB) Fluid Type 'Fluid Density(1b/gal) IP Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 4,021.0 3,728.37 LSND 9.30 636.0 12.58 2,437.2 1� Eni E&P Division .. 'Well Name:OP22-WW03 ENI Petroleum Co.Inc. Daily Report Well Code:27295 Field Name:Nikaitchuq • Date:7/28/2013 - Report#: 19 APIIl1WI:50-029-23489-00-00 2 r' rr� page 1 of 1 Wellbore name: OP22-WW03 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 VERTICAL Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 12.20 36.62 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245 E I LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP22-WW03 DRILLING 7/6/2013 10,855.0 9.694.4 10,154.00 121.12 83.8 22.79 Daily Information _ End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 7,646.0 6,540.4 0.00 84.0 57.0 Overcast WSW @ 25 MPH Gust 32 MPH Daily summary operation 24h Summary BROOH,L/D BHA.XO RAMS Operation at 07.00 Testing 9 5/8"Rams 24h Forecast TIH W/9 5/8"COG.CMT Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.80 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. _ Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E 4 P BROOH F/7168 T/4200 GPM=900 PSI=2500 RPM=80 TQ=5-6 GAS=65 UNITS 06:00 10:00 4.00 10.00 DRILL -E 4 P BROH F/4200'T/3000'GPM=900 SPM=212 PSI=2000 TQ=6-8 MONITOR WELL FOR 10 MIN @ 4000' 10:00 11:30 1.50' 11.50 DRILL E 7 P CIRCULATE @ 3000'UNTIL HOLE CLEAN,GPM=900 PSI=1950 RPM=80 SPM=212 11:30 12:00 ' 0.50' 12.00 DRILL E 4 P PUMP DRY JOB POOH ON ELEVATORS F/3000 T/2954 12:00 14:00 2.00 14.00 DRILL E 4 P POOH F/2954'T/662' UPW=140 DRILLS-BOP ETC D-1 DRILL ERT=1.40 MIN 14:00 23:30 9.50' 23.50 DRILL E 4 'P L/D BHA#4 RACK BACK 4 STDS 5"HWDP, CLR RIG FLR L/D XO'S,STAB'S,BIT,ECT T/SHED,• 23:30 00:00 0.50' 24.00 DRILL E 5 P VOID STACK,PULL W/R SET TEST PLUG, Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative -Oliver Amend Eni Petroleum Ddiing Supervisor Eni representative Dean Sherman Eni Petroleum Dulling Supv. 907-685-0710 Eni representative Tom Klein Eni Petroleum Materials Coordinate 907.685-1491 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Shaun Denning ENI Petroleum HSE Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push David Hanson Nabors Alaska Drilling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(9KB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L-80 -0.8 4,020.0 7/12/2013 Last Leakoff Test Depth(RKB) ND(ftKB) Fluid Type 'Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 4,021.0 3.728.37 LSND 9.30 636.0 12.58 2,437.2 fillAriLli Eni E&P Division 'Well Name:0P22-WW03 ENI Petroleum Co.Inc. Daily Report Well Code:27295 Field Name:Nikaitchuq • APIIUW1:50-029-23489-00-00 2^n Date:7/29/2013 - Report#: 20 II Ii II page 1 of 1 Wellbore name: OP22-WW03 Well Header Permit/Concession N° I Operator !ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 VERTICAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) !RKB-Tubing Spool(ft) 53.00 12.20 36.62 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) !Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) W OP22- W03 DRILLING 7/6/2013 10,855.01 9.694.4 10,154.00 121.12 83.8 23.79 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) I P" Temperature(°F) 'Weather 'Wind 7,646.0 6,540.4 0.00 97.0 40.0 Overcast WNW @ 4 MPH Daily summary operation 24h Summary CHG RAMS,TEST,TIH W/9 5/8"CSG Operation at 07.00 RIH W/9 5/8"Casing at 5291'MD 24h Forecast TIH 9 5/8"CSG,CMT Lithology •Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.80 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 03'.00 3.00 3.00 DRILL G 5 P PULL WEAR RING,DRAIN STACK,RUN IN TEST PLUG,CHANGE RAMS TO 9 5/8 03:00 06:00 3.00 6.00 DRILL G 5 P TEST BOPS FILL TEST JOINT ATTEMP 3500 PSI TEST DIDNT HOLD PULL TEST PLUG,0-RING WAS BROKEN, / REPLACE SAME CLEAN CAVITY DRAIN STACK,FILL TEST JOINT,TEST 9 5/8 RAMS TO 250 LOW 3500 HIGH ,./ 06:00 07:00 1.00 7.00+DRILL G 5 P DUMMY RUN WITH LANDING JOINT,VETCO GREY,VERIFY SET 07.00 11:00 4.00 11.00 DRILL G 4 P R/UTO RUN9 5/8"CSG RIG UP TESCO AND GBR CASING EQUIPMENT,RIG UP FILL UP LINE 11 00 12:00 1.00 12.00 DRILL G 4 P RUN CASING RUN 9 5/8 CASING 477E PICK UP SHOE TRACK FILL WITH MUD,PICK UP CHECK FLOATS 12:00 16:00 4.00 16.00 DRILL G 4 P CONT.RIH W/9 5/8 L-80 405 CSG F/133',GBR TO TURN T/13,076 FT LBS,USE SEAL GUARD PIPE DOPE ON CONNECTINS,INSTALL CENTRALIZERS AS PER RUNNING ORDER,FILL EVERY JT,TOP OFF EVERY 20,T/1103' 16.00 23:30 7.50 23.50 DRILL G 4 'P R/U SPIDERS ON FLOOR,RIH W/9 5/8 L-80 CSG F/1102'T/3962'UPW=187 DNW=153 2330 00:00 0.50 24,00 DRILL G 7 P DRILLS-BOP D-1 DRILL ERT=2 MIN, R/U T/B/C,CIRC CBU @ 3962' Daily Contacts Position Contact Name Company • Title E-mail Office _ Mobile •Eni representative Oliver Amend 'Eni Petroleum 'Drliing Supervisor Eni representative Dean Sherman Eni Petroleum Dulling Supv. 907-685-0710 Eni representative Tom Klein Eni Petroleum Materials Coordinate 907-685-1491 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Shaun Denning ENI Petroleum HSE Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Dulling Tool Pusher 907-670-1492 Tool Push David Hanson Nabors Alaska Drilling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L-80 0.1 7,631,0 7/29/2013 Last Leakoff Test Depth(•KB) TVD(ftKB) Fluid Type 'Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 4,021.0 3,728.37 LSND 9.30 636.0 12.58 2,437.2 Eni E&P Division I Well Name:0P22-WW03 EN!Petroleum Co.Inc. Daily Report Well Code:27295 Field Name:Nikaitchuq • Date:7130/2013 - Report#: 21 APIIUWI:50-029-23489-00-00 2'r i page 1 of 1 Wellbore name: OP22-WW03 Well Header Permit/Concession N° I Operator ENI Share(14) Well Configuration type ALASKA I ENI PETROLEUM 100.00 VERTICAL Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 12.20 36.62 Rig Information Contractor Rig Name IRig Type NABORS ALASKA NABORS 245 E I LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) !Target Depth(TVD..J Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) W OP22- W03 DRILLING 7/6/2013 10.855.0 9.694.41 10,154.00 121.12 83.8 24.79 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) 'Avg ROP(ft/hr) I POB Temperature(°F) Weather Wind 7,646.0 6,540.4 0.00 81.0 54.0 Overcast SW @ 8 MPH Daily summary operation 24h Summary RIH 9 5/8"CASING 1/7632'. PERFORM CEMENT JOB. PUMP 50 BBLS MUD PUSH,PUMP 108 BBLS 15.8 PPG CEMENT. DISPLACE W/9.8 PPG MUD USING RIG PUMPS,562+3.3 BBLS,PLUG DID NOT BUMP. HELD 600 PSI,10 MIN-FLOAT HELD. R/D CEMENT JOB. SET/TEST CASING HANGER PACK-OFF. CHANGE-OUT BOP PIPE RAMS. Operation at 07.00 P/U,RIH 90 JTS 5"DP. 24h Forecast C/O BOP RAMS,PULL BOP TEST PLUG,P/U AND RIH 90 JTS 5"DP. TOH,RACK BACK,STRAP DP. TEST BOPS. P/U,RIH BHA#5. PERFORM CASING TEST. SWAP-OUT MUD. DRILL OUT 9 5/8"CASING SHOE. PERFORM LOT. DRILL AHEAD 8 1/2"HOLE. Lithology 'Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.80 Time Log `� Start End Cum K--� p Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. I t,S� 00:00 01:30 1.50 1.50 DRILL G 7 P CIRC/COND MUD,BU AT 3964',6 BPM,250 PSI ¶ (J 01 30 05:30 4.00 5.50 DRILL G 4 P -_RIH_W/9 5/8 L-80 CSG F/3964'T/6000'UPW=230 DNW=170 t...)1 05.30 06:30 1.00 6.50 DRILL G 7 P CIRC/COND MUD,BU AT 6000',6 BPM 400 PSI 06:30 10:30 4.00 10.50 DRILL G 4 P RIH W/9 5/8 L-80 CSG F/6000'T/7595'UPW=300 DNW=230 10:30 13:30 3.00 13.50 DRILL G 7 P M/U LANDING JT AND CIRC SWEDGE. WASH DN CASING F/7595'T/7632'. SEAT 9 5/8"HANGER IN WELLHEAD. CIRC 8 BPM,550 PSI. 13:30 15:30 2.00' 15.50 DRILL H 5 P PJSM W/CREWS. R/D CIRC SWEDGE. LOAD PLUGS IN CEMENTING HEAD,R/U HEAD AND LI S. BREAK CIRC THRU CEMENTING HEAD 4 BPM,300PSt.- ___.-- - ---�- _ 1530 18:00 2.50 18.00 DRILL H 7 P °PJSM W/SCHL&PERSONNEL VOLVED W/CMT JOB,PRESSURE TEST CEMENT LINES T/250/4000 PSI ' \ CIRC/CEMENT/DISPL 50 EELS MUD PUSH 12 PPG,DROP BTM PLUG. PUMP 108 BBLS CEMENT 15.8 PPG. DROP '\ TOP PLUG. PUMP 10 BBLS OF H2O. CIRC/CEMENT/DISPL W/RIG MUD PUMP 552 BBLS AT 8.5 BPM.SLOW RATE T/3 BPM,PUMP 10 BBLS(562 BBLS TOTAL)PLUG DID NOT BUMP.PUMPED 3.3 BBLS(1/2 SHOE TRACK VOL,565.3 j HELD. BBLS TOTAL). PLUG DID NOT BUMP. SHUT DOWN PUMP,HELD 600 PSI,10 MIN. BLED-OFF PRE SURE,FLOAL `� 18:00 20.30 2.50 20.50 DRILL H 5 P R/D B/QJ-EVENT HEAD AND LINES. VOID STACK,BACK-OUT AND RINSE LANDING JT,L/D TO PIPE SHED. RINSE ACK. C/O ELEVATORS T/5"DP. UD XO'S AND SIDE-DOOR ELEVATORS TO PIPE SHED. 20:30 23:00 2.50 23.00 DRILL C 5 P P/U PACK-OFF AND RUNNING TOOL. SET/TEST T/2400 PSI,10 MIN. 23:00 00.00 1.00 24.00 DRILL C 5 P P/U BOP TEST PLUG. SET. CHANGE OUT RAMS F/9 5/8"FIXED T/4.5-7"VARIABLE RAMS. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry -Eni Petroleum Sr.DrIg.Spvr. '907-685-0710 Eni representative Craig Ruminer Eni Petroleum Drilling Supv. Eni representative Satoh Bowe Eni Petroleum Materals Coordinator 907-685-1491 907-299-0531 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Shaun Denning ENI Petroleum HSE Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push David Hanson Nabors Alaska Drilling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L-80 0.1 7,631.0 7/29/2013 Last Leakoff Test Depth(ftKB) /TVD(ftKB) 'Fluid Type Fluid Density(1b/gall 'P Surf Applied(psi) Eq.Mud Weight(Ib/gal) !Leak Off Pressure(psi) 4,021.0 3,728.37 LSND 9.30 636.0 12.58 2437.2 I Eni E&P Division I Well Name:0P22-WW03 ENI Petroleum Co.Inc. Daily Report Well Code:27295 Field Name: Nikaitchuq • APIIIINA:50-029-23489-00-00 2^o Date:7/31/2013 - Report#: 22 II II page 1 of 1 Wellbore name: OP22-WW03 Well Header PermiVConcession N° Operator I ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 VERTICAL Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 12.20 36.62 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) (Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ftlhr) DFS(days) OP22-WW03 DRILLING 7/6/2013 10,855.01 9.694.4 10,154.00 121.12 83.8 25.79 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) !Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 7,646.0 6,540.4 0.00 83.0 48.0 Overcast E @ 8 MPH Daily summary operation 24h Summary CHANGE OUT BOPE RAMS. P/U 27 STDS 5"DP. PERFORM BOPE TEST. SERVICE RIG. P/U RIH BHA#5. Operation at 07.00 TIH W/BHA#5 at 6,364'MD 24h Forecast TIH BHA#5,TAG CEMENT,TEST CASING. DRILL OUT FLOAT AND CEMENT TO SHOE,SWAP OUT MUD. DRILL OUT SHOE TRACK AND 10'NEW FORMATION. PERFORM LOT. DRILL AHEAD 8 1/2"HOLE. Lithology !Shows MAASP Pressure(psi) !Mud Weight(Iblgal) 9.80 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:00 1.00 1.00 DRILL C 5 P C/O BOPE PIPE RAMS-9 5/8"FIXED TO 4.5-7"VARIABLE 01:00 02:00 1.00 2.00 DRILL C 5 P PULL TEST PLUG,INSTALL 9 1/8"WEAR RING 0200 08:00 6.00 8.00 DRILL E 4 P P/U M/U RIH 81 JTS 5"DP. TOH,R/B,STRAP 27 STDS. 08.00 18:30 10.50 18.50 DRILL C 12 P PJSM. P/U TEST TOOLS. PULL WEAR RING. INSTALL TEST PLUG. TEST CHOKE,KILL,RAMS T/250 PSI-L/5000 PSI-H. TEST ANNULAR T/250 PSI-L/3500 PSI-H. ACCUMULATOR TEST 200 PSI,40 SEC. FULL RECOVERY=156 SEC. N2=2600 PSI AVG,6 BOTTLES. BOPE TEST WITNESS WAIVED BY LOU GRIMALDI,AOGCC. R/D B/D TEST JT. B/D CHOKE MANIFOLD,CHOKE AND KILL LINES. 18.30 20:00 1.50 20.00 DRILL E 20 P RIG SERVICE-GREASE CROWN,BLOCKS,TOPDRIVE,DRAWWORKS.ROUGHNECK.MANIFOLD VALVES. PREP TO P/U BHA#5. 20.00 00:00 4.00 24.00 DRILL 'E 4 P PJSM. P/U RIH BHA#5 T/282'. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spvr. 907-685-0710 Eni representative Craig Ruminer Eni Petroleum Drilling Supv. Eni representative Satch Bowe Eni Petroleum Materals Coordinator 907-685-1491 907-299-0531 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Shaun Denning ENI Petroleum HSE Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push David Hanson Nabors Alaska Drilling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L-80 0.1 7,631.0 7/29/2013 Last Leakoff Test Depth(ftKB) IND(ftKB) Fluid Type Fluid Density(Iblgal) IP Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 4,021.0 3,728.37 LSND 9.30 636.0 12.58 2,437.2 Eni E&P Division Name:OP22-WW03 I . IP* EN!Petroleum Co.Inc. Daily Report Well Code:27295 Field Name:Nikaitchuq • API/UWI:50-029-23489-00-00 2^n Date:8/1/2013 - Report#: 23 IfI o page 1 of 1 Wellbore name: OP22-WW03 Well Header • Permit/Concession N° Operator ENI Share(14) Well Configuration type ALASKA ENI PETROLEUM 100.00 VERTICAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) IRKB-Tubing Spool(ft) 53.00 12.20 36.62 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245 E I LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P22-WW03 DRILL NG 7/6/2013 10,855.0 9694.4 10,154.00 121.12 83.8 26.79 Daily Information End Depth(ftKB) End Depth(TVD)(f..'Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 7,646.0 6,540.4 0.00 87.0 55.0 Light Rain E @ 5 MPH Daily summary operation 24h Summary RIH BHA#5 T/7483',TEST CASING 3000 PSI/30 MIN. DRL OUT CEMENT AND FLOAT,SWAP OUT MUD F/10.5 PPG,LSND. DRL OUT SHOE AND 20'NEW FORMATION,FIT=13.0 PPGE. ROT AND SLIDE,DRILL 8.5"HOLE F/7656'T/8007'. Operation at 07.00 ROT AND SLIDE DRILL F/8007'T/8,200' MD 24h Forecast ROT AND SLIDE DRILL T/10(155'MD Lithology 'Shows MAASP Pressure(psi) 'Mud Weight(lb/gal) 10.50 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 05:00 5.00 5.00 DRILL E 4 P RIH BHA#5,TAG AT 7483'. 05:00 06:00 1.00 6.00 DRILL E 20 P CASING TEST 3000 PSI,30 MIN.PUMP DOWN KILL LINE AND TOPDRIVE. 06:00 09:30 3.50 9.50 DRILL E 20 P DRL OUT CEMENT AND FLOAT F/7483'T/7610'. WOB 3-5 KLBS,450 GPM,900 PSI,30 RPM. 09:30 11:30 2.00 11.50 DRILL E 7 P PJSM. CHANGE OUT MUD 10.5 PPG,LSND. PUMP 30 BBL SPACER,MUD AT 6-8 BPM. 11:30 13:00 1.50 13.00 DRILL E 3 P DRL OUT CEMENT AND SHOE,20'NEW FORMATION F/7610'T/7667'. WOB 3-5 KLBS,400 GPM.1350 PSI.40 RPM, 5-7 KTO. PU 235.SO 160,RT 185. 13:00 14:30 1.50 14.50 DRILL E 7 P CIRC/COND MUD BU AT 7667'. 500 GPM,1650 PSI,40 RPM,4.5 KTO. RACK BACK 1 STD PREP FOR LOT. FIT=850 PSI,13.0 PPGE. 14:30 15:30 - 1.00 15.50 DRILL �E 20 P FIT TEST. PUMP 2 BPM T/886 PSI,HELD FOR 10 MIN. FIT=8`64 PS1Q.P I, 3 GE. BLED OFF PRESS,R/D TEST .. TOOLS. P/U STD OF DP. .. 15:30 00:00 8.50 24.00 DRILL E 3 P ROT AND SLIDE DRILL F/7667'T/8007'. WOB 3-5 KLBS,400 GPM,1350 PSI.40 RPM,5-7 KTO. PU 235.SO 160,RT 185. SPR AT 7717'MD/6606'TVD-PUMP#1 30/280 40/360,PUMP#2 30/270 40/350. MW 10.5, ART=3.31 HRS. AST=2.66 HRS,ADT=5.97 HRS Daily Contacts Position Contact Name Company Title E-mail Office , Mobile Eni representative Ben Perry Eni Petroleum Sr.Dig.Spvr. 907-685-0710 Eni representative Craig Ruminer Eni Petroleum Dulling Supv. Eni representative Satch Bowe Eni Petroleum Materals Coordinator 907-685-1491 907-299-0531 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Shaun Denning ENI Petroleum HSE Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mice Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push David Hanson Nabors Alaska Drilling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L-80 0.1 7,631.0 7/29/2013 Last Leakoff Test Depth(ftKB) PhD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 4,021.0 3,728.37 LSND 9.30 636.0 12.58 2,437.2 • Eni E&P Division 'Well Name:0P22-WW03 fil* ENI Petroleum Co.Inc. Daily Report Well Code:27295 Field Name:Nikaitchuq •2^n Date:8/2/2013 - Report#: 24 APIIl1VJl:50-029-23489-00-00 II �I II page 1 of 1 Wellbore name: OP22-WW03 Well Header Permit/Concession N° !Operator ENI Share)%) I Well Configuration type ALASKA ENI PETROLEUM 100.00 VERTICAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.00 12.20 36.62 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E ILAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) I DFS(days) 0P22-WW03 DRILLING 7/6/2013 10,855.0 9694.4 10,154.00 121.12 83.8 27.79 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) 'Drilling Hours(hr) !Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 9,349.0 8,199.6 1.341.00 16.771 80.0 87.0 62.0 Partly Cloudy S @ 16 MPH Daily summary operation 24h Summary ROT AND SLIDE DRILL F/8007'T/9349'MD Operation at 07.00 ROT AND SLIDE DRILL F/9349'T 9,638'MD 24h Forecast ROT AND SLIDE DRILL T/10855'MD Lithology 'Shows MAASP Pressure(psi) 'Mud Weight(lb/gal) 10.55 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 '12:00 12.00 12.00 DRILL E 3 P ROT AND SLIDE DRILL F/8007'T/6614'. WOB 14-17 KLBS,550 GPM,2050 PSI,100 RPM,11 KTO. PU 245,SO 185, ROT 201. MW 10.5.SPR AT 8200'MD/7064'TVD PUMP 1-30/310,40/390. PUMP 2-30/310.40/400. 12.00 00:00 ' 12.00 24.00 DRILL E 3 P ROT AND SLIDE DRILL F/8614'T/9349'. WOB 13-15 KLBS,500 GPM,2030 PSI,100 RPM,13-15 KTQ. PU 260,SO 200,ROT 210. MW 10.5.SPR AT 9250'MD/8101'TVD PUMP 1-30/390,40/470. PUMP 2-30/390,40/490.ART=13.10 HRS,AST=3.67 HRS,ADT=16.77 HRS. Daily Contacts Position Contact Name Company Title i E-mail Office Mobile Eni representative Ben Perry Eni Petroleum 'Sr.Drig.Spvr. 907-685-0710 Eni representative Craig Ruminer Eni Petroleum Drilling Supv. Eni representative Satch Bowe Eni Petroleum Materals Coordinator 907-685-1491 907-299-0531 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Shaun Denning ENI Petroleum HSE Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push David Hanson Nabors Alaska Drilling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L-80 0.1 7,631.0 7/29/2013 Last Leakoff Test Depth(ftKB) TVD(ftKB) I Fluid Type Fluid Density(Iblgal) I P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 4,021.0 3,728.37 LSND 9.301 636.0 12.58 2,437.2 Eni E&P Division 'Well Name:0P22-wwo3 1 EN!Petroleum Co.Inc. Daily Repo..}` Well Code:27295 Field Name:Nikaitchuq • Date:8/3/2013 - Report#: 25 APIIUWI:50-029-23489-00-00 2" " page 1 of 1 Wellbore name: OP22-WW03 • Well Header Permit/Concession N° Operator ENI Share(%) 'Well Configuration type ALASKA ENI PETROLEUM 100.00 VERTICAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 12.20 36.62 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date 'Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(it) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P22-WW03 DRILLING 7/6/2013 10,855.0 9.694.4 10,154.00 121.12 83.8 28.79 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) 'Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 10,676.0 9,521.4 1,327.00 17.81 74.5 86.0 50.0 Overcast E @ 8 MPH Daily summary operation 24h Summary ROT AND SLIDE DRILL F/9349'T/10676'MD,TD. PUMP SWEEP,CBU. Operation at 07.00 BROOH T19,697'MD 24h Forecast FINISH CBU,MONITOR WELL. BROOH TO CASING SHOE AT 5-6 MIN/STD. CIRC/SWEEP HOLE,CBU. MONITOR WELL. PUMP SLUG,DROP RABBIT,TOH ON ELEVATORS. L/D HWDP AND BHA. REMOVE WEAR RING. TEST BOPE.4.5-7"VARI RAMS ON 7"TEST JT. R/U,RUN 7"LINER. M/U HANGER ASSEMBLY. RIH ON 5"DP. Lithology 'Shows MAASP Pressure(psi) Mud Weight(lb/gal) 10.50 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 '12.00 ' 12.00 12.00 DRILL 8 3 P 'ROT AND SLIDE DRILL F/9349'T/10210'. WOB 10-15 KLBS,500 GPM.2200 PSI,80 RPM,14-16 KTQ. PU 280,SO 208,ROT 230. MW 10.5.SPR AT 9732'MD/8415'TVD PUMP 1-30/420.40/490. PUMP 2-30/400,40/500. 12:00 22:30 10.50' 22.50 DRILL E 3 P 'ROT AND SLIDE DRILL F/10210'T/10676'. WOB 10-15 KLBS,550 GPM,2350 PSI,80 RPM.14-16 KTQ. PU 295,SO 215,ROT 238. MW 10.5.SPR AT 10671'MD/9517'TVD PUMP 1-30/400,40/520. PUMP 2-30/420,40/500. ART=17.81 HRS,AST=0 HRS,ADT=17.81 HRS. 22:30 .00100 • 1.50' 24.00 DRILL 'E 7 P PUMP HI VIS SWEEP,CBU X 2. 550 GPM,2100 PSI,80 RPM. Daily Contacts Position Contact Name Company Title E-mail Office Mobile • Eni representative Ben Perry Eni Petroleum Sr.Drlg.Spot. 907-685-0710 Eni representative Craig Ruminer Eni Petroleum Drilling Supv. Eni representative Satch Bowe Eni Petroleum Materals Coordinator 907-685-1491 907-299-0531 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Shaun Denning ENI Petroleum HSE Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Kelly Cozby Nabors Alaska Drilling Tool Pusher Tool Push David Hanson Nabors Alaska Drilling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.835 L-80 0.1 7,631.0 7/29/2013 Last Leakoff Test Depth(ftKB) 'TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 4,021.0 3,728.37 LSND 9.30 636.0 12.58 2,437.2 Eni E&P Division [Well Name:0P22-WW03 OW* ENI Petroleum Co.Inc. Daily Report Well Code:27295 Field Name:Nikaitchuq • API/UWI:50-029-23489-00-00 2^n II Date:8/4/2013 - Report#: 26 II I� page 1 of 1 Wellbore name: OP22-WW03 Well Header Permit/Concession N° Operator ENI Share W%) Well Configuration type ALASKA ENI PETROLEUM 100.00 VERTICAL Rotary Table Elevation(ft) Ground Level(ft) `Water Depth(ft) RKB-Base Flange(ft) 'RKB-Tubing Spool(ft) 53.00 12.20 36.62 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date 'Target Depth(ftKB) Target Depth(TVD..]Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) IDFS(days) OP22-WW03 DRILLING 7/6/2013 10,855.0 9,694.4 10,154.00 121.12 83.81 29.79 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) FOB Temperature(°F) Weather rind 10 676.0 9,521,4 0.00 92.0 57.0 Light Rain S @ 8 MPH Daily summary operation 24h Summary CBU,SWEEP HOLE CLEAN. BROOH T/7618',6 MIN/STD. CBU X3,SHAKERS CLEAN. PUMP SLUG,DROP 2.5"RABBIT,MONITOR WELL. SLIP/CUT DRILL LINE. TOH T/5334',PUMP 2ND SLUG,TOH T/643'. RIG SERVICE. REPAIR RIG,PIPE SKATE-PIPE HANDLER/LAYDOWN MACHINE. TOH,L/D HWDP AND BHA#5 T/182'. Operation at 07.00 TESTING 4.5-7"VARI RAMS ON 7"TEST JT. 24h Forecast FINISH L/D BHA#5. REMOVE WEAR RING. TEST BOPE,4.5-7"VARI RAMS ON 7"TEST JT. INSTALL WEAR RING. R/U GBR,RUN 7"LINER. M/U HANGER ASSEMBLY. RIH ON 5"DP. R/U BAKER,SLB,PERFORM CEMENT JOB,DISPLACE W/RIG PUMP.SET PACKER.PRESSURE TEST LINER. TOH. Lithology 'Shows MAASP Pressure(psi) I Mud Weight(lb/gal) 10.50 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Deuce. 00:00 '01:00 1.00 1.00 DRILL E 7 P PUMP HI VIS SWEEP,CBU X 2. 550 GPM,2100 PSI,80 RPM,14-15 KTQ. 01:00 09:30 8.50 9.50 DRILL E 6 'P BROOH,6 MIN/STD T/7618'. 550 GPM,1800 PSI,100 RPM,6-7 KTQ. SLOW TO 450 GPM,50 RPM AT SHOE. MONITOR WELL-STATIC,NO LOSSES. 09:30 11:30 2.00 11.50 DRILL E 7 P CIRC/COND MUD. CBU X3,ROT AND RECIP UNTIL SHAKERS CLEAN,550 GPM,1800 PSI,100 RPM. PUMP SLUG. DROP 2.5"RABBIT,MONITOR WELL-STATIC. 11:30 '12:00 0.50 12.00 DRILL E 4 P TOH ON ELEVATORS,T/7151' 12:00 14:00 2.00 14.00 DRILL E 25 P SLIP AND CUT 69'DRILL LINE 14:00 15:30 1.50 15.50 DRILL E 4 P TOH ON ELEVATORS,T/5334' 15:30 16:00 0.50 16.00 DRILL E 7 P PIPE PULLING WET. PUMP 2ND SLUG. BLOW DOWN TOPDRIVE. 16:00 19:30 3.50 19.50 DRILL E 4 P TOH T/643' 19:30 20:00 0.50 20.00 DRILL E 4 P TRIP DRILL. PREP TO UD BHA. 20:00 20:30 0.50 20.50 DRILL E 25 .P RIG SERVICE.GREASE ROUGHNECK,TOPDRIVE,DRAWWORKS. 20:30 22:00 1.50 22.00 DRILL E 25 TR99 REPAIR RIG,PIPE SKATE-PIPE HANDLER/LAYDOWN MACHINE. 22:00 00:00 2,00 24.00 DRILL E 4 P TOH,L/D HWDP AND BHA#5 T/182'. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spvr. 907-685-0710 Eni representative Craig Ruminer Eni Petroleum Drilling Supv. Eni representative Satch Bowe Eni Petroleum Materals Coordinator 907-685-1491 907-299-0531 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Shaun Denning ENI Petroleum HSE Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Kelty Cozby Nabors Alaska Drilling Tool Pusher Tool Push David Hanson Nabors Alaska Drilling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.835 L-80 0,1 7,631.0 7/29/2013 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) IP Surf Applied(psi) 'Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 4,021.0 3,728.37 LSND 9.30 636.01 12.58 2,437.2 1 Eni E&P Division !Well Name: 0P22-WW03 ENI Petroleum Co.Inc. Daily Repo 1..}` Well Code:27295 Field Name:Nikaitchuq • APIIUWI:50-029-23489-00-00 Date:8/5/2013 - Report#: 27 (s ifli page 1 of 1 Wellbore name. OP22-WW03 Well Header Permit/Concession N° Operator ENI Share(%) I Well Configuration type ALASKA ENI PETROLEUM 100.00 VERTICAL Rotary Table Elevation(ft) 'Ground Level(ft) I Water Depth(ft) RKB-Base Flange(ft) 'RKB-Tubing Spool(ft) 53001 12.20 36.62 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) 'Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P22-WW03 DRILLING 7/6/2013 10,855.0 9.694.4 10,154.00 121.12 83.8 30.79 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) !Drilling Hours(hr) 'Avg ROP(ft/hr) I POB Temperature(°F) Weather Wind 10,676.0 9,521.4 0.00 89.0 39.0 Overcast NE @ 13 MPH Daily summary operation 24h Summary FINISH L/D BHA#5. REMOVE WEAR RING. TEST BOPE,4.5-7"VARI RAMS ON 7"TEST JT,CONN ON PORTED SUB LEAKED. P/U,PULL TEST PLUG,RE-TORQUE CONN,RE-INSTALL TEST PLUG,REPEAT TEST 250 PSI LOW.5000 PSI HI. INSTALL WEAR RING. R/U GBR,RUN 7"LINER. C/O ELEVATORS T/5". M/U HANGER ASSEMBLY. C/O PUMP#2 LINERS T/5.5". Operation at 07.00 RIH 7"LINER ON 5"DP T14,224' 24h Forecast RIH 7"LINER ON 5"DP. CIRC/COND MUD. R/U BAKER,SLB,PERFORM CEMENT JOB,DISPLACE W/RIG PUMP.SET PACKER.PRESSURE TEST LINER. TOH.UD 29 STDS 5"DP, Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 10.50 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 03:00 3.00 3.00 DRILL E 4 P TOH,L/D BHA#5 F/182'. BIT IN-GAUGE,GRADED 1-1.CLEAN UP RIG FLOOR. 03.00 08:30 5.50 8.50 DRILL E 20 P PJSM. PULL WEAR BUSHING,PER VETCO REP. P/U M/U TEST TOOLS. TEST BOPE 4.5X7"VARI-RAMS,250 PSI LOW,5000 PSI HIGH. CONN LEAKED,PU AND RETORQUE CONN. INSTALL WEAR BUSHING. R/D UD TEST TOOLS,CLEAR RIG FLOOR. 08.30 11:00 2.50 11.00 DRILL G 4 P PJSM W/ALL PERSONNEL. P/U,R/U 7"LINER RUNNING TOOLS. 11:00 23:30 12.50 23.50 DRILL G 4 P P/U SHOE JT. PJSM W/ALL PERSONNEL(TOUR CHANGE). FINISH R/U 7"LINER RUNNING TOOLS,BAKER-LOCK 3 JTS,INSTALL CENTRALIZER EVERY OTHER CONN. FILL EVRY JOINT. TORQUE-TURN W/GBR T/9400 FTLBS. RIH T/3239'. CHANGE PUMP#2 LINERS T/5.5"PU 130 KLBS.SO 90 KLBS. 23.30 00.00 0.50 24.00 DRILL G 4 P -C/O ELEVATORS T/5". P/U M/U LINER HANGER. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative -Ben Perry Eni Petroleum Sr.Ddg.Spvr. • 907-685-0710 • Eni representative Craig Ruminer Eni Petroleum Drilling Supv. Eni representative Satch Bowe Eni Petroleum Materals Coordinator 907-685-1491 907-299-0531 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Shaun Denning ENI Petroleum HSE Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Kelly Cozby Nabors Alaska Drilling Tool Pusher Tool Push David Hanson Nabors Alaska Dulling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 7 6.184 L-80 7,396.8 10,668.0 8/5/2013 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 4.021.0 3,728.37 LSND 9.30 636.0 12.58 2,437.2 IP* Eni E&P Division 'Well Name:0P22-WW03 ENI Petroleum Co.Inc. Daily Report Well Code:27295 Field Name:Nikaitchuq • APIIUWI:50-029-23489-00-00 2^rl Date:8/6/2013 - Report#: 28 I' n I1 page 1 of 1 Wellbore name: OP22-WW03 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 VERTICAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(tt) RKB-Base Flange(ft) RKB-Tubing Spool(tt) 53.00 12.20 36.62 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E I LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) IDES(days) 0P22-WW03 DRILLING 7/6/2013 10,855.0 9694.4 10,154.00 121.12 838 31.79 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather I Wind 10,676.0 9,521.4 0.00 89.0 46.0 Mist ENE @ 15 MPH Daily summary operation 24h Summary RIH 7"LINER ON 5"DP, 1.5 MIN/STD,FILU10 STDS. CIRC/COND MUD AT SHOE. WASH/ROT THRU SHOE. TIH T/10670'. CIRC/COND MUD. R/U BAKER CEMENT HEAD,SLB,PERFORM CEMENT JOB-26 EELS 12.5 PPG MUD PUSH II,110 BBLS 15.8 PPG CEMENT,DISPLACE 2 BBLS H2O,DROP DART,PUMP 5.5 BBLS H2O,DISPLACE W/RIG PUMP 235 BBLS TO BUMP PLUG. SET PACKER,RELEASED TOOL.CIRC/CLEAN TOL,PUMP CEMENT FROM HOLE. PRESSURE TEST LINER,1500 PSI/15 MIN. BEGIN TOH. Operation at 07.00 TOH W/5"DP. 24h Forecast TOH 5"DP. L/D BAKER LINER HANGER RUNNING TOOL. P/U RIH 108 JTS 4"DP. M/U CROSS-OVER,RIH W/5"DP TO BOTTOM. DISPLACE MUD W/BRINE,9.5 PPG. TOH. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 10.50 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:00 1.00 1.00 DRILL G 4 P R/D L/D LINER RUNNING TOOLS.CLEAN FLOOR. R/U RUN 5"DP. 01:00 02:00 1.00 2.00 DRILL G 7 P CIRC/COND MUD,LINER CAP 120 BBLS AT 4 BPM,360 PSI.PU 143 K,SO 105 K. 02.00 07:00 5.00 7.00 DRILL G 4 P TIH ON 5"DP,1.5 MIN/STD,FILL/10 STDS. 07:00 08:00 1.00- 8.00 DRILL G 7 -P CIRC/COND,CBU AT CASING SHOE. 7 BPM,600 PSI,30 RPM. PU 220 K,SO 160 K,ROT 181 K. 08:00 09:00 1.00 9.00 DRILL G 4 P RIH,TAG AT 7650'.WASH/ROT DOWN. CIRC 1 BPM,275 PSI,10 RPM,4-5 KTO. 09:00 12.00 3.00 12.00 DRILL G 4 P RIH T/10670'FILL/10 STDS (I 12:00 15:30 3.50 15.50 DRILL G 7 P CIRC/COND MUD.6 BPM.860 PSI.RECIP PIPE 35'. PREP TO P/U CEMENT HEAD. PU 285 K,SO 190 K,W/PUMPS , Apt.N. PU 320 K,SO 200 K.W/O PUMPS. 15:30 16:30 1.00 16.50 DRILL H 1 P SHUT DOWN PUMP,BLOW DOWN TOPDRIVE AND CEMENT LINE. M/U CEMENT HEAD. Lµ 16:30 .17:00 0.50 17.00 DRILL H 7 BREAK CIRC THRU CEMENT HEAD. 5 BPM.750 PSI. 17:00 '17:30 ' 0.50 17.50 DRILL H 12 P PJSM. PRESS TEST SLB LINES TI 4500 PSI. 17:30 20:00 2.50' 20.00 DRILL H 7 P MIX/PUMP MUD PUSH II SPACER-12.5 PPG,27 BBLS. MIX/PUMP CEMENT-15.8 PPG.110 BBLS,1.17 FT3/SX, 5.2 13 GAUSX. PUMP 2 BBLS H2O,DROP DART,PUMP 5.5 BBLS H2O,SHUT DOWN. DISPLACE CEMENT W/RIG PUMPS,BUMP PLUG AT 2780 STKS. PRESSURE UP F/1445 PSI T/1950 PSI. BLED OFF PRESSURE,FLOAT HELD. ETIRELEASE LINER HANGER PACKER.TOL-7396',SHOE-10658'. 20:00 20:30 0.50 20.50 DRILL H 7 P CIRC/CLEAN I OH 01-LINER,8 BPM.1000 PSG. 20:30 '21:00 ' 0.50 21.00 DRILL H 5 P R/D L/D CEMENT HEAD AND LINES. 21:00 22:00 ' 1.00' 22.00 DRILL H 7 P CIRC/CLEAN CEMENT IN HOLE,7 BPM,500 PSI.5000 STKS. NO CEMENT RETURNS. 22:00 23:00 ' 1.00 23.00 DRILL G 12 P R/U TEST LINER T/1500 PSI,15 MIN. R/D TEST EQUIP. 23:00 23:30 ' 0.50' 23.50 DRILL G 7 P PUMP SLUG,PREP TO TRIP PIPE. 23:30 00:00 ' 0.50 24.00 DRILL G 4 P TOH 5"DP,RACK BACK.T/7141'. Daily Contacts Position _ Contact Name Company _ Title E-mail Office Mobile _ Eni representative James Wright ENI Petroleum Dulling Superintend Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spur. 907-685-0710 Eni representative Craig Ruminer Eni Petroleum Drilling Supv. Eni representative Satoh Bowe Eni Petroleum Materals Coordinator 907-685-1491 907-299-0531 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Shaun Denning ENI Petroleum HSE Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Kelly Cozby Nabors Alaska Drilling Tool Pusher Tool Push David Hanson Nabors Alaska Drilling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(f1KB) Bottom(ftKB) Run Date LINER 7' 6.184 L-80 7.396.8 10,668.0 8/5/2013 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 4 021.0 3.728.37 LSND 9.30 636.0 12.58 2.437.2 Eni E&P Division I Well Name:OP22-WW03 $r* EN/Petroleum Co.Inc. Daily Report Well Code:27295 Field Name:Nikaitchuq Date:8/7/2013 - Report#: 29 APllU M:50-029-23489-00-00 • 2" " page 1 of, Wellbore name: OP22-WW03 Well Header Permit/Concession N° 'Operator ENI Share(%) 'Well Configuration type ALASKA ENI PETROLEUM 100.00 VERTICAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 12.20 36.62 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245 E ILAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0P22-WW03 DRILLING 7/6/2013 10,855.0 9,694.4 10,154.00 121.12 83.8 32.79 Daily Information End Depth(ftKB) End Depth(TVD)(f..r Depth Progress(ft) Drilling Hours(hr) Avg ROP(ftlhr) POB Temperature(°F) Weather Wind 10,676.0 9,521.4 0.00 91.0 50.0 Cloudy NE @ 8 MPH Daily summary operation 24h Summary TOH 5"DP. BOP DRILL. L/D BAKER LINER HANGER RUNNING TOOL. B/D L/D BAKER CEMENT HEAD. SWAP TO COMPLETION MODE 0500 Operation at 07.00 WELL ON COMPLETION MODE. 24h Forecast NOTE FINAL DAILY DRILLING REPORT. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 10.50 Time Log { Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 -04:00 4.00 4.00'DRILL G 4 P TOH 5'DP,RACK BACK. 04-.00 05.00 1.00 5.00 DRILL G 4 P BOP TRIP DRILL-1 MIN 48 SEC. L/D BAKER LINER HANGER RUNNING TOOL. P/U,B/D L/D BAKER CEMENT HEAD. CHANGE OPS MODE TO COMPLETION AT 05:00. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative James Wright ENI Petroleum Dulling Superintend Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spur. 907-685-0710 Eni representative Craig Ruminer Eni Petroleum Drilling Supv. Eni representative Satch Bowe Eni Petroleum Materals Coordinator 907-685-1491 907-299-0531 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Shaun Denning ENI Petroleum HSE Eni representative Ken Bogner Eni Petroleum Materials Coordinate Tool Push Kelly Cozby Nabors Alaska Drilling Tool Pusher Tool Push Kenny Sullivan Nabors Alaska Drilling Tour Pusher Last Casing seat Gas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 7 6.184 L-80 7,396.8 10,668.0 8/5/2013 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type 'Fluid Density(Iblgal) I P Surf Applied(psi) IEq.Mud Weight(lb/gal) Leak Off Pressure(psi) 4,021.0 3,728.37 LSND 9.30 636.0 12.58 2,437.2 Eni E&P Division Well Name:OP22-WW03 PI* ENI Petroleum Co.Inc. Daily Report` Well Code:27295 Field Name:Nikaitchuq • APIIUWU:50-029-23489-00-00 2^n Date:8/7/2013 - Report#: 1 II 'I II page 1 of 1 Wellbore name: OP22-WWO3 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 VERTICAL Rotary Table Elevation(ft) Ground Level(ft) !Water Depth(ft) RKB-Base Flange(ft) IRKB-Tubing Spool(ft) 53.00 12.20 36.62 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date 'Target Depth(ftKB) 'Target Depth(TVD...I Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP22-WW03 COMPLETION I 32.79 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather rind 0.0 90.0 50.0 Cloudy NE @ 8 MPH Daily summary operation 24h Summary PULL WEAR BUSHING,R/U TEST BOP-ANN T/250/3500 PSI AND 3.5X6"VARI-RAMS T/250/5000 PSI,REINSTALL WEAR BUSHING. P/U M/U CEMENT STINGER AND XO,RIH ON 4"DP, T/3470'. P/U 108 JTS 4"DP. M/U XO,RIH ON 5"DP,T/10586',TAG UP. BREAK CIRC,CIRC/DISPL LSND MUD W/9.5 PPG BRINE. Operation at 07.00 DISPLACING WELL TO 9.5 PPG BRINE. 24h Forecast FINISH DISPLACE LSND MUD W/BRINE,SPOT VISC PILL IN LINER. TOH W/4"DP AND 5"DP, RACK BACK. P/U PERF BHA W/SLB MWD. TIH. UP-LOG PERF ZONE FOR DEPTH CORRELATION.TIH TO CORR DEPTH. PERF,MONITOR WELL F/GAIN/LOSS. TOH. Lithology 'Shows MAASP Pressure(psi) Mud Weight(Iblgal) Time Log Start End Cum Time Time Our(hr) Our(hr) Phase Opr. Act. _ Plan Oper.Descr. • 05:00 11:00 6.00 6.00 COMP C 12 P PULL WEAR BUSHING,PUMP OUT STACK. P/U 4"TEST TOOLS AND PLUG. FILL STACK W/H2O. TEST ANN T/250 PSI-LOW,3500 PSI-HIGH. TEST 3.5X6"VARI-RAMS,TIW,AND DART VALVE T/250 PSI-LOW,5000 PSI-HIGH. INSTALL WEAR BUSHING PER VETCO REP. B/D L/D TEST TOOLS. 11:00 11:30 0.50 6.50 COMP K 5 'P P/U 4"DP HANDLING TOOLS. 11:30 12:30 1.00 7.50 COMP K 25 P RIG SERVICE. GREASE CROWN,BLOCK.DRAWWORKS,PIPE SKATE,IRON ROUGHNECK. 12:30 18:30 6.00 13.50 COMP K 4 P P/U M/U XO AND CEMENT STINGER,RIH ON 4"DP. P/U 108 JTS,T/3470'. 18:30 23:00 4.50 18.00 COMP K 4 P C/O DP ELEVATORS F/5",C/O SHIMS IN IRON ROUGHNECK. P/U M/U XO. RIH ON 5"DP T/10586'.TAG UP. 23:00 00:00 1.00 19.00 COMP K 7 P CIRC/DISPL LSND MUD W/BRINE,9.5 PPG.5 BPM,750 PSI. Daily Contacts Position _ Contact Name Company Title E-mail Office Mobile Eni representative James Wright •Eni Petroleum 'Drilling Superintend Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spvr. 907-685-0710 Eni representative Craig Ruminer Eni Petroleum Drilling Supv. Eni representative Satch Bowe Eni Petroleum Materals Coordinator 907-685-1491 907-299-0531 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Ken Bogner Eni Petroleum Materials Coordinalo Tool Push Kelly Cozby Nabors Alaska Drilling Tool Pusher Tool Push Kenny Sullivan Nabors Alaska Drilling Tour Pusher Last Casing seat Can.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 7 6.184 L-80 7,396.8 10,668,0 8/5/2013 Last Leakoff Test Depth(ftKB) ' TVD(ftKB) Fluid Type Fluid Density(1b/gall IP Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 4.021.0 3,728.37 LSND 9.30 636.0 12.58 2437.2 Eni E&P Division Name:0P22-WW03 ENI Petroleum Co.Inc. Daily Report Well Code:27295 Field Name:Nikaitchuq • APIIUWI:50-029-23489-00-00 2 rill*�,r, Date:8/8/2013 - Report#: 2 II II II page 1 of 1 Wellbore name: OP22-WW03 Well Header Permit/Concession N° Operator ENI Share(%) I Well Configuration type ALASKA ENI PETROLEUM 100.00 VERTICAL Rotary Table Elevation(ft) Ground Level(ft) !Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 12.20 36.62 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) 'Target Depth(TVD...Il Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) I OP22-WW03 COMPLETION 33.79 Daily Information End Depth(RKB) End Depth(TVD)(f..'Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) 'POB Temperature(oF( Weather Wind 0.0 89.0 48.0 Cloudy NW @ 4 MPH Daily summary operation 24h Summary FINISH DISPLACE LSND MUD W/BRINE,SPOT VISC PILL IN LINER. TOH W/4"DP AND 5"DP, RACK BACK. P/U PERF BHA W/SLB MWD AND PERF GUNS. TIH ON 4"DP T/3924'. TIH ON 5" DP T/5356'. Operation at 07.00 TIH ON 5"DP,AT 10028' 24h Forecast TIH ON 5"DP F/5356'T/10586'. UP-LOG PERF ZONE FOR DEPTH CORRELATION.TIH TO CORR DEPTH. PERF,MONITOR WELL F/GAIN/LOSS. TOH.L/D 5"AND 4"DP. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.50 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 01:00 1.00 1.00 COMP K 7 P CIRC/COND MUD,10.5 PPG LSND MUD,5 BPM,750 PSI 01 00 03:00 2.00 3.00 COMP 'K 7 P CIRC/DISPLACE PUMP 90 BBL HI-VIS SWEEP,PUMP 9.5 PPG BRINE,500 GPM,1500 PSI. DIVERT MUD AND SWEEP TO CUTTINGS BOX.BRINE RETURNED TO ACTIVE PITS PER MI ENG. 0300 06:00 3.00 6.00 COMP K 7 P CIRC/COND. BUILD PERF PILL.PUMP/SPOT 125 BBL HI-VIS PILL IN LINER. 06.00 12:00 6.00. 12.00 COMP K 4 P TOH/RACKBACK 4"AND 5"DP. LJD CEMENT STINGER. 12.00 12:30 0.50 12.50 COMP K 25 P C/O MU LINE ON CAT HEAD. CLEAR/CLEAN RIG FLOOR. 12.30 13.00 0.50 13.00 COMP -K 25 P RIG SERVICE. 13.00 1700 4.00 17.00 COMP K 4 P PJSM. P/U M/U TOOLS M/U SAFETY JT,L/D. P/U GUNS.XO'S.MWD T/463'. 17.00 18:00 1.00 18.00 COMP K 5 TWO2 MODIFY SLB MWD CENTRILIZER,WRONG COLLAR ID.INSTALL MWD IN COLLAR. 18.00 19.00 1.00 19.00 COMP 'K 4 P B/D L/D SAFETY JT. RIH ON 4"DP F/463'T/1042'. SHALLOW HOLE TEST MWD 19.00 19.30 0.50 19.50 COMP K 7 P SHALLOW HOLE TEST MWD,200 GPM,180 PSI. B/D TOPDRIVE 19.30 00.00 4.50 24.00 COMP K 4 P TIH ON 4"DP T/3924. C/O DP ELEVATORS T/5". M/U XO,TIH ON 5"DP T/5356' Daily Contacts Position Contact Name Company Title E-mail _ Office Mobile Eni representative 'James Wright Eni Petroleum Dolling Superintend Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spur. 907-685-0710 Eni representative Craig Ruminer Eni Petroleum Drilling Supv. Eni representative Satch Bowe Eni Petroleum Materals Coordinator 907-685-1491 907-299-0531 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Ken Bogner Eni Petroleum Materials Coordinato Tool Push Kelly Cozby Nabors Alaska Dolling Tool Pusher Tool Push Kenny Sullivan Nabors Alaska Drilling Tour Pusher Last Casing seat Can.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 7 6.184 L-80 7,396.8 10,668.0 8/5/2013 Last Leakoff Test Depth(ftKB) TVD(f1KB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 4,021.0 3,728.37 LSND 9.30 636.0 12.58 2,437.2 I Eni E&P Division 'Well Name:OP22-WW03 IP* EN!Petroleum Co.Inc. Daily Report Well Code:27295 Field Name:Nikaitchuq • API/UWI:50-029-23489-00-00 2^n Date:8/9/2013 - Report#: 3 II 'I II page 1 of 1 Wellbore name: OP22-WW03 Well Header ALASKA Permit/Concession N° [OM ENI I ENI Share(4) 100.00'WE Well Configuration type Rotary Table Elevation(ft) Ground Level(ft) !Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.00 12.20 36.62 Rig Information Contractor NA Name 5E Rig LAND I NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Date J'Target Depth(flKB) 'Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) IDFS(days) OP22-WW03 COMPLETION 34.79 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather 'Wind 0.0 95.0 47.0 Cloudy I NNW @ 7 MPH Daily summary operation 24h Summary TIH PERF BHA ON 4"AND 5"OP.TAG AT 10582'. CBU BRINE. TOH T/10333'. UPLOG F/9892'T/9835'(MEAS DEPTH). SHOOT PERF GUNS AT 08:15. MONITOR WELL,LOSSES 4 BBL/HR. TOH,L/D 5"DP AND 4"DP,T/750'. Operation at 07.00 TOH,L/D 5"DP. 24h Forecast FINISH L/D 4"DP,SLB MWD,SLG TCP GUNS. RIH 44 STDS 5"DP. TOH,L/D 132 JTS. R/U RUN 4.5"PRODUCTION TUBING ASSEMBLY,ESP. Lithology 'Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.50 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan _ Oper.Descr. 00:00 04:00 4.00 4.00 COMP K 4 P TIH PERF BHA ON 4"AND 5"DP.TAG AT 10582'. PU 280 K,SO 220 K. 04:00 05:30 1.50 5.50 COMP K 7 P CIRC BU 9.5 PPG BRINE,300 GPM,650 PSI. DIVERT 36 BBLS PERF PILL TO CUTTINGS BOX. ADJUST FLOW/PRESS FOR SLB MWD. 05:30 06:00 0.50 6.00 COMP K 4 P TOH 7/10333'. 06:00 07:30 1.50 7.50 COMP K 19 P LOG UP F/9892'T/9835'(TOOL MEASUREMENT DEPTH)TO CORRELATE PERF DEPTH. 07:30 08:30 1.00 8.50 COMP K 16 P PJSM FOR PERF JOB. CLOSE ANN,PRESSURE UP T/1000 PSI,HOLD PRESSURE,BLEED OFF,4 TIMES TO FIRE GUNS. GUNS FIRED AT 08:15. BLED OFF ALL PRESSURE,OPENED ANN,PUT ON TRIP TANK. MONITORED WELL FOR 10 MIN. WELL STATIC FOR SEVERAL MINUTES,SLOW STARTED LOSING LESS THAN 4 BBL/HR. SHOT INTERVALS 9925'-9953',9980'-10047',10064'-10103',10127'-10188',10223'-10308'. TOTAL 280.18 FT MD,279.2 FT TVD,5 SPF,1356 TOTAL CHARGES. 08:30 09:00 0.50 9.00 COMP K 4 P .TOH 5 STDS. MONITOR WELL. LOSSES 4 BPH. 09:00 12:00 3.00 12.00 COMP K 4 P TOH 5"DP,L/D 69 JTS. HOLE FULL,CIRC ON TRIP TANK. 12:00 12:30 0.50 12.50 COMP K 4 P PJSM. TRIP PIPE/UD TO PIPE SHED.MOVE TO TUBS. INSPECT EQUIP,IRON ROUGHNECK. 12:30 13:00 0.50 13.00 COMP K 25 P SERVICE RIG. 13:00 18:00 5.00 18.00 COMP K 4 P TOH 5"DP,L/D 117 JTS. HOLE FULL.CIRC ON TRIP TANK. 18:00 19:00 1.00 19.00 COMP K 4 P 'B/D L/D XO. CIO ELEVATORS,SHIMS IN IRON ROUGHNECK FOR 4"DP. 19:00 0000 5.00 24.00 COMP K 4 P TOH 4"DP,L/D T/750'. HOLE FULL,CIRC ON TRIP TANK. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry -Ent Petroleum Sr.Ddg.Spvr. 907-685-0710 Eni representative Craig Ruminer Eni Petroleum Drilling Supv. Eni representative Bill Petty Eni Petroleum HSE Eni representative Satch Bowe Eni Petroleum Materals Coordinator 907-685-1491 907-299-0531 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Ken Bogner Eni Petroleum Materials Coordinato Tool Push Kelly Cozby Nabors Alaska Drilling Tool Pusher Tool Push Kenny Sullivan Nabors Alaska Drilling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 7 6.184 L-80 7,396.8 10,668.0 8/5/2013 Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) IP Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 4,021.0 3,728.37 LSND 9.301 636.0 12.58 2,437.2 I 1.* Eni E&P Division (Well Name:0P22-WW03 ENI Petroleum Co.Inc. Daily Report Well Code:27295 Field Name:Nikaitchuq • Date:8110/2013 - Report#: 4 APIIl1W 50-029-23489-00-00 2" "ii page 1 of 1 Wellbore name: OP22-WW03 Well Header Permit/Concession N° 'Operator I ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 VERTICAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.00 12.20 36.62 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...I Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP22-WW03 COMPLETION 35.79 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) 'Drilling Hours(hr) Avg ROP(ft/hr) I POB Temperature(°F) Weather 'Wind 0.0 97.0 55.0 Cloudy NNW @ 8 MPH I Daily summary operation 24h Summary FINISH L/D 4"DP,SLB MWD,SLB TCP GUNS. RIH 44 STDS 5"DP. TOH,L/D 132 JTS. R/U CENTRILIFT SPOOLING UNIT,SHEAVES,LINES. Operation at 07.00 P/U M/U SHROUD AND PUMP ASSEMBLY. 24h Forecast P/U M/U RUN ESP PUMP ASS. 4.5"PRODUCTION TUBING ASSEMBLY,ESP. Lithology 'Shows MAASP Pressure(psi) I Mud Weight(lb/gal) 9.50 Time Log F Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:00 2.00 2.00 COMP K 4 P L/D 4"DP,XO,SLB MWD PER SLB REP. 02.00 02:30 0.50 2.50 COMP K 4 P PJSM. SLB,GBR,CREW HANDLING TCP TOOLS. NOTIFY PROD AND ENI SEC. 02:30 04:30 - 2.00 4.50 COMP K 4 P BIG L/D SLB TCP GUNS 0430 06:00 1.50 6.00 COMP K I 4 P L/D ALL 4"HANDLING TOOLS. C/O ELEVATORS,CIO SHIMS IN IRON ROUGHNECK FOR 5"DP. CONTINUE MONITOR WELL FOR LOSSES-STATIC. 06.00 08:00 2.00 8.00 COMP K 4 P P/U M/U MULE SHOE,TIH 44 STDS 5"DP. 08.00 08:30 0.50 8.50 COMP K 7 P CIRC/COND MUD,CIRC 1 COMPLETE CIRC. 08.30 14:30 6.00 14.50 COMP K 4 P TOH,L/D 132 JTS. INSPECT HARD BANDS. 14.30 15:00 0.50 15.00 COMP C 5 P PULL WEAR BUSHING. 15.00 16.00 1.00 16.00 COMP K 5 P CLEAN UP RIG FLOOR.PREP FOR R/U CENTRILIFT. 16.00 00.00 8.00 24.00 COMP K 5 P P/U CENTRILIFT EQUIP TO RIG FLOOR. R/U SHEAVES,ROPE FOR PULLING ESP CABLE AND INJ LINE FROM SPOOLING UNIT. CALL ELECTRICIAN FOR CENTRILIFT GENSET. PULL DUAL CONTROL LINES TO RIG FLOOR. Daily Contacts IPosition Contact Name Company Title E-mail Office Mobile Eni representative -Ben Perry Em Petroleum Sr.Dig.Spvr. 907-685-0710 Eni representative Craig Ruminer Eni Petroleum Dolling Supv. Eni representative Bill Petty Em Petroleum HSE Eni representative Satoh Some Eni Petroleum Materals Coordinator 907-685-1491 907-299-0531 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Ken Bogner Eni Petroleum Materials Coordinate Tool Push Kelly Cozby Nabors Alaska Drilling Tool Pusher Tool Push Kenny Sullivan Nabors Alaska Drilling Tour Pusher Last Casing seat Gas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date LINER 7 6.184 L-80 7,396.8 10,668.0 8/5/2013 Last Leakoff Test Depth(RKB) I TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(1b/gall Leak Off Pressure(psi) 4,021.0 3,728.37 LSND 9.30 636.0 12.58 2437,2 1 Eni E&P Division I Well Name:OP22-WW03 EN!Petroleum Co.Inc. Daily Report Well Code:27295 Field Name:Nikaitchuq • API/UWI:50-029-23489-00-00 2 n• Date:8/11/2013 - Report#: 5 II II page 1 of 1 ,Wellbore name: OP22-WW03 Well Header ALASKA PermibConcession N° I Operator OpI PETROLEUM I ENI Share(%) 100.00I Well Configuration type Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) IRKS-Tubing Spool(ft) 53.00 12.20 36.62 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) IDFS(days) OP22-WW03 COMPLETION 36.79 Daily Information End Depth(ftKB) End Depth(TVD)(f..'Depth Progress(ft) 'Drilling Hours(hr) 'Avg ROP(ft/hr) I POB Temperature(°F) Weather Wind 0.0 96.0 53.0 Cloudy NE @ 11 MPH Daily summary operation 24h Summary R/U GBR TONGS. M/U SEAL JT,SHROUD JTS,AND HANGER XO. P/U M/U 562 SERIES MOTOR,513 SERIES TANDEM SEALS,562 SERIES PUMP W/INTEGRAL INTAKE,DISCHARGE,AND GAUGE HOUSING.FILL W/CL5 OIL. M/U SHROUD HANGER,MAKE MLE CONN,ESP SPLICES AND TUBING PENETRATIONS. INSTALL SPIN COLLAR. TEST SEALS. CONN ESP CABLE, TEST. INSTALL CONTROL LINES. RIH ON 4.5'TUBING. Operation at 07.00 RIH ESP PUMP ASSEMBLY ON 4.5'TUBING. ATTACH CLAMP ACROSS EACH CONNECTION. 24h Forecast RIH ESP PUMP ASSEMBLY ON 4.5"TUBING,INSTALL SSSV AND GLM IN STRING. INSTALL CLAMPS ACROSS CONN'S,TEST ESP/1000 FT. AT 200 FT RIH ON 5"DP FOR SPACE-OUT. INSTALL SPACE-OUT PUPS,VIT JTS, AND TUBING HANGER. MAKE FINAL ESP SPLICE,TUBING FEED-THRUS. TEST ESP. LAND TUBING HANGER,TEST HANGER SEALS. INSTALL BPV. N/D STACK,N/U TUBING ADAPTER AND TREE. PULL BPV,INSTALL TEST PLUG,TEST TREE AND HANGER VOIDS. PULL TEST PLUG. TEST ESP. Lithology 'Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.50 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:00 1.00 1.00 COMP K 4 P R/U GBR DBL STACK CHROME TONGS AND RELATED EQUIPMENT. 01:00 04:00 3.00 4.00 COMP K 4 P M/U 7"SEAL ASS.TO 7-5/8"SHROUD JT. ADJ TONGS SO BACKUP JAWS WOULD BITE W/O SLIPPING,TO OBTAIN PROPER TORQUE. 04:00 06:00 2.00 6.00 COMP K 4 P C/O GBR TONGS TO BACK-UP SET. HAD TO HAVE NEW JAWS SENT FROM TOWN. 06:00 08:00 2.00 8.00 COMP K 4 P P/U SECOND 7-5/8"SHROUD JT.DRIFT STUCK MID-JT. L/D P/U SPARE JT. 08:00 09:30 1.50 9.50 COMP K 4 P M/U SECOND SHROUD JT AND XO FOR SHROUD HANGER. 09.30 21:00 11.50 21.00 COMP K 4 P INSTALL ESP 562 SERIES MOTOR W/6"CENTRILIZER AT BOTTOM, 513 SERIES TANDEM SEALS,562 SERIES PUMP W/INTEGRAL INTAKE,DISCHARGE,AND GAUGE HOUSING. ADD CL5 OIL IN MOTOR AND SEALS. CONNECT MLE F/MOTOR T/SHROUD HANGER. COMPLETE PENETRATOR SPLICE AND CONTROL LINE FEED THRUS. INSTALL SPIN COLLAR. 21:00 22:30 1.50 22.50 COMP K 4 P PRESSURE TEST T/300/5000 PSI.5 MIN, TEST ESP CONNECTION. ATTACH INJ LINES. INSTALL BAND CLAMPS, 22:30 00:00 1.50 24.00 COMP K 4 P PJSM. R/U GBR TONGS. P/U M/U RIH 4.5"TUBING. ATTACH CLAMP ACROSS EACH CONNECTION. Daily Contacts Position Contact Name Company - Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spur. '907-685-0710 Eni representative Craig Ruminer Eni Petroleum Dolling Supv. Eni representative Bill Petty Eni Petroleum HSE Eni representative Satoh Bowe Eni Petroleum Materals Coordinator 907-685-1491 907-299-0531 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Ken Bogner Eni Petroleum Materials Coordinate Tool Push Kelly Cozby Nabors Alaska Drilling Tool Pusher Tool Push Kenny Sullivan Nabors Alaska Dulling Tour Pusher Last Casing seat Ca s.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 7 6.184 L-80 7,396.8 10.668.0 8/5/2013 Last Leakoff Test 1 Depth(HKB) ITVD(ftKB) Fluid Type 'Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 4,021.0 3,728.37 LSND 9.30 636.0 12.58 2,437.2 Eni E&P Division I Well Name:OP22-WW03 fa* ENI Petroleum Co.Inc. Daily Report Well Code:27295 Field Name:Nikaitchuq • 2^n Date:8/12/2013 - Report#: 6 APIIUWI:50-029-23489-00-00 nII page 1 of 1 Wellbore name: OP22-WW03 - Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 VERTICAL Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 12.20 36.62 Rig Information Contractor Rig Name •Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date 'Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP22-WW03 COMPLETION 37.79 Daily Information End Depth(11KB) End Depth(TVD)(f.. Depth Progress(ft) 'Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 98.0 54.0 Mostly Cloudy NE @ 7 MPH Daily summary operation 24h Summary RIH ESP PUMP ASSEMBLY ON 4.5"TUBING,T/3606'. SPLICE ESP CABLE. INSTALL GLM IN STRING. INSTALL CLAMPS ACROSS CONN'S,TEST ESP/1000 FT. RIH T/5173'. R/U TO INSTALL SSSV. Operation at 07.00 CONTINUE RIH ESP COMPLETION STRING ON 4.5"TUBING. 24h Forecast RIH ESP PUMP ASSEMBLY ON 4.5"TUBING,INSTALL CLAMPS ACROSS CONN'S,TEST ESP/1000 FT. AT 200 FT RIH ON 5"DP FOR SPACE-OUT,TOH. INSTALL SPACE-OUT PUPS,VIT JTS, AND TUBING HANGER. MAKE FINAL ESP SPLICE,TUBING FEED-THRUS. TEST ESP. LAND TUBING HANGER.TEST HANGER SEALS. INSTALL BPV. N/D STACK,N/U TUBING ADAPTER AND TREE. PULL BPV,INSTALL TEST PLUG,TEST TREE AND HANGER VOIDS. PULL TEST PLUG. TEST ESP. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.50 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 11:00 11.00 11.00 COMP K 4 P CONTINUE RIH ESP COMPLETION STRING ON 4.5"TUBING T/3606'. INSTALL CANNON CLAMP EACH CONN. M/U TO 4400 FTLBS. CHECK CONTINUITY/1000 FT. 11:00 17:00 6.00 17.00 COMP K 4 P C/O ESP REEL IN SPOOLING UNIT. LOWER ESP CABLE TO GROUND,PULL NEW CABLE UP OVER SHEAVE TO RIG FLOOR. MAKE SPLICE. RECEIVE AIR SLIPS FROM NABORS 7ES. 17:00 19:00 2.00 19.00 COMP K 12 P CONTINUITY TEST SPLICE. GBR INSPECT AND R/U AIR SLIPS,C/O DIES F/3.5"T/4.5". 19:00 00:00 5.00 24.00 COMP K 4 P CONTINUE RIH ESP COMPLETION STRING ON 4.5"TUBING T/5173'. INSTALL CANNON CLAMP EACH CONN. M/U TO 4400 FTLBS. CHECK CONTINUITY/1000 FT. BRING SSSV TO RIG FLOOR,BEGIN R/U SLB EQUIP.TO RUN. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spvr. '907-685-0710 Eni representative Craig Ruminer Eni Petroleum Grilling Supv. Eni representative Bill Petty Eni Petroleum HSE Eni representative Satch Bowe Eni Petroleum Materals Coordinator 907-685-1491 907-299-0531 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Ken Bogner Eni Petroleum Materials Coordinato Tool Push Kelly Cozby Nabors Alaska Drilling Tool Pusher Tool Push /Kenny Sullivan Nabors Alaska Drilling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 7 6.184 L-80 7,396.8 10668.0 8/5/2013 Last Leakoff Test Depth(ftKB) IND(ftKB) Fluid Type Fluid Density(1b/gall P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 4,021.0 3,728.37 LSND 9.30 636.0 12.58 2,437.2 Eni E&P Division Vie Name:0P22-WW03 ENI Petroleum Co.Inc. Daily Report Well Code:27295 Field Name: Nikaitchuq iiiiii*2^ Date:8/13/2013 - Report#: 7 APIIUWI:50-029-23489-00-00 o II II page 1 of 1 Wellbore name: OP22-WW03 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 VERTICAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 53.00 12.20 36.62 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...I Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) OP22-WW03 COMPLETION 38.79 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) 'Drilling Hours(hr) Avg ROP(fUhr) IP013 Temperature(°F) Weather Wind 0.0 98.0 42.0 Cloudy ENE @ 12 MPH Daily summary operation 24h Summary INSTALL SSSV,TEST ON CONTROL LINE SPOOL. RIH ESP PUMP ASSEMBLY ON 4.5"TUBING F/5173'T/7161',INSTALL CLAMPS ACROSS CONN'S.TEST ESP/1000 FT. RIH ON 5"DP FOR SPACE-OUT,TOH. INSTALL SPACE-OUT PUPS,VIT JTS, AND TUBING HANGER. MAKE FINAL ESP SPLICE,TUBING FEED-THRUS. TEST ESP. LAND TUBING HANGER.TEST HANGER SEALS. INSTALL BPV. R/D GBR AND CENTRILIFT EQUIPMENT. Operation at 07.00 N/U TUBING ADAPTER AND TREE. 24h Forecast N/D STACK,N/U TUBING ADAPTER AND TREE. PULL BPV,INSTALL TEST PLUG.TEST TREE AND HANGER VOIDS. PULL TEST PLUG. TEST ESP. R/U PRESSURE TEST ANN,SHEAR VALVE ON GLM,PUMP 60 BBLS DIESEL TO FREEZE PROTECT. R/U HES SLICKLINE,C/O GLM VALVE.SHUT IN WELL. SET BPV. R/D M/O RIG. Lithology (Shows MAASP Pressure(psi) I Mud Weight(lb/gal) 9.50 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan _ Oper.Descr. 00:00 03:00 3.00 3.00 COMP K 4 P R/U SLB 1/4"CONTROL LINE SPOOLER AND HANG SHEAVE. M/U SSSV,TQ T/4440 FTLBS. TEST SSSV THRU SPOOL T/5000 PSI/10 MIN. RUN SSSV THRU WELLHEAD-NO HANGUPS. 03:00 0930 6.50 9.50 COMP K 4 P CONTINUE RIH ESP COMPLETION STRING ON 4.5"TUBING F/5173'T/7161'. INSTALL CANNON CLAMP EACH CONN, M/U TO 4400 FTLBS. CHECK CONTINUITY/1000 FT. 09:30 12:00 2.50 12.00 COMP K 4 P M/U XO T/5"DP. RIH,ENGAGE INTO TIE-BACK SEALS. PU 160K,SO 110K.SET 20K ON NO-GO.MEASURE SPACE OUT. PULL OUT OF SEALS,TOH 3 STDS. 12:00 15:30 3.50 15.50 COMP K 4 P CONFIRM SPACE OUT.LOCATE 4.5"PUPS(5.77'AND 2.00'). M/U,RIH W/PUPS AND 6 JTS VIT. CENTRILIFT PERFORMED CONTINUITY TESTS. 15:30 16:00 0.50 16.00 COMP K 4 P P/U M/U LANDING JT,TUBING HANGER AND XO. • 16:00 20:00 4.00 20.00 COMP K 4 P TERMINATE ESP CABLE AND CONTROL LINES TO TUBING HANGER. DRAIN STACK. LAND TUBING HANGER. PU 165K,SO 112K. 20:00 22:00 2.00 22.00 COMP K 5 P VETCO INSTALL LOCKDOWNS ON WELLHEAD IN WELL BAY. INSTALL VALVE. PRESSURE TEST HANGER UPPER AND LOWER SEALS T/5000 PSI/10 MIN. 22:00 00:00 2.00 24.00 COMP K 5 P 'L/D LANDING JT. SET BPV. R/D UD GBR AND CENTRILIFT EQUIPMENT. BLOW DOWN TOPDRIVE,CHOKE AND KILL LINES. PUMP OUT STACK. Daily Contacts Position Contact Name Company Title _ E-mail Office Mobile Eni representative Bruce Simonson Eni Petroleum Sr.Drlg.Spvr. 907-685-0710 Eni representative Craig Ruminer Eni Petroleum Dolling Supv. Eni representative Bill Petty Eni Petroleum HSE Eni representative Satoh Bowe Eni Petroleum Materals Coordinator 907-685-1491 907-299-0531 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Ken Bogner Eni Petroleum Materials Coordinato Tool Push Kelly Cozby Nabors Alaska Dolling Tool Pusher Tool Push Kenny Sullivan Nabors Alaska Dulling Tour Pusher Last Casing seat Cris.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 7 6.184 L-80 7,396.8 10668.0 8/5/2013 Last Leakoff Test Depth(RKB) I TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 4,021.0 3,728.37 LSND 9.30 636.0 12.58 2,437.2 ft* Eni E&P Division I Well Name:OP22-WW03 EN!Petroleum Co.Inc. Daily Report Well Code:27295 • Field Name:Nikaitchuq enE Date:8/1412013 - Report#: 8 APIIUWI:50-029-23489-00-00 (' II page 1 of 1 Wellbore name: OP22-WW03 Well Header Permit/Concession N° I Operator ENI Share(%) Well Configuration type ALASKA ENI PETROLEUM 100.00 VERTICAL Rotary Table Elevation(ft) Ground Level(ft) 'Water Depth(ft) RKB-Base Flange(ft) I RKB-Tubing Spool(ft) 53.00 12.20 36.621 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date 'Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ftlhr) I DFS(days) OP22-WW03 COMPLETION 39.79 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) 'Drilling Hours(hr) Avg ROP(f/hr) POB Temperature(°F) Weather I W nd 0.0 100.0 42.0 Rain ENE @ 12 MPH Daily summary operation 24h Summary N/D STACK,FLOWLINE,PITCHER NIPPLE,AND KATCH PAN. REMOVE VETCO LOCK-DOWNS,LIFT STACK,SET ON PEDESTAL. N/D RISER. N/U TUBING ADAPTER AND TREE. INSTALL PENETRATOR,TEST ESP. PULL BPV,INSTALL TEST PLUG,TEST TREE AND HANGER VOIDS. PULL TEST PLUG. R/U PRESSURE TEST ANN,SHEAR VALVE ON GLM,PUMP 60 BBLS DIESEL TO FREEZE PROTECT. R/U HES SLICKLINE,LUBRICATOR,AND BOPS,PRESSURE TEST. Operation at 07.00 HES SLICKLINE CIO GLM SHEAR VALVE, 24h Forecast HES SLICKLINE CIO GLM SHEAR VALVE,R/D BOP AND LUBRICATOR. RELEASE RIG,MOB RIG TO OP19-T1N. Lithology I Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.50 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 07:00 7.00 7.00 COMP K 20 P N/D BOP STACK-DE-ENERGIZE KOOMEY UNIT.BLEED OFF PRECHARGE,CHECK N2 BOTTLES,CIO 2 BLADDERS,RECHARGE N2. R/D L/D CENTRILIFT SHEAVES,PULL L/D MOUSEHOLE,BLOW DOWN HOLE-FILL LINE AND MUD PUMPS. CLEAN OUT MUD PITS 1-4,PILL PIT,AND TRIP TANK. REMOVE INTERCONNECTS. CLEAN OUT WELLHEAD. N/D KATCH PAN,PITCHER NIPPLE,AND FLOWLINE. REMOVE TURNBUCKLES FROM STACK. VETCO BACK-OUT LOCK-DOWNS ON WELLHEAD.P/U,SET BOPS ON PEDESTAL. N/D RISER. 07:00 14:00 7.00 14.00 COMP K 20 P TERMINATE SSSV CONTROL LINE. INSTALL,CHECK CONDUCTIVITY OF ESP PENETRATOR. N/U TREE.M/U GRAY-LOCKS. 14:00 16:00 2.00 16.00 COMP K 20 P PJSM. PULL BPV,INSTALL TEST PLUG, R/U VETCO PRESSURE TEST TREE T/5000 PSI/10 MIN. PRESSURE TEST HANGER VOIDS/PACKOFF T/5000 PSI/10 MIN. 16:00 18:30 2.50 18.50 COMP K 19 P PJSM. PULL TEST PLUG. R/U LRS,PRESSURE TEST/CHART ANN T/1500 PSI/10 MIN. SHEAR GLM VALVE,PUMP 60 BBLS DIESEL INTO ANN FOR FREEZE PROTECTION,TAKE BRINE RETURNS THRU CHOKE LINE TO CUTTINGS BOX. R/D LRS. BLOW DOWN CHOKE LINE. 18:30 00:00 5.50 24.00 COMP K 19 P PJSM. R/U HES SLICKLINE UNIT,LUBRICATOR.AND BOPS. PRESSURE TEST-REPLACE 0-RING,RETEST T/3000 PSI. R/D TESTING EQUIPMENT. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Bruce Simonson Eni Petroleum Sr.Drlg.Spvr. 907-685-0710 Eni representative Craig Ruminer Eni Petroleum Drilling Supv. Eni representative Bill Petty Eni Petroleum HOE Eni representative Vance Dale Eni Petroleum Malls Coordinator Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Ken Bogner Eni Petroleum Materials Coordinate Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Kenny Sullivan Nabors Alaska Drilling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 7 6.184 L-80 7,396.8 10,668.0 8/5/2013 Last Leakoff Test Depth(ftKB) IND(ftKB) I Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) 'Leak Off Pressure(psi) 4,021.0 3,728.37 LSND 9.30 636.0 12.58 2,437.2 I Eni E&P Division 'Well Name:OP22-WW03 EN!Petroleum Co.Inc. Daily Report Well Code:27295 Field Name:Nikaitchuq • API/UWI:50-029-23489-00-00 2^II n Date:8/15/2013 - Report#: 9 I' I� page 1 of 1 Welibore name: OP22-WW03 Well Header Permit/Concession N° [Operator ENI Share(%) I Well Configuration type ALASKA ENI PETROLEUM 100.00 VERTICAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) [RKB-Tubing Spool(ft) 53.00 12.20 36.62 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Welibore Job Phase Spud Date [Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DES(days) OP22-WW03 COMPLETION 40.79 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 100.0 43.0 Light Rain ENE @ 12 MPH Daily summary operation 24h Summary HES C/O GLM SHEAR VALVE,R/D. SHUT IN WELL. Operation at 07.00 BEGIN MOB OPERATIONS. FINAL COMPLETION REPORT. 24h Forecast MOB RIG TO OP19-T1 N. RIG RELEASED 06,00. Lithology [Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.50 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 COMP K 19 P HES SLICKLINE CATCHER WOULD NOT SET AT GLM,SET AT SHROUD HANGER. CIO GLM SHEAR VALVE. RETRIEVE CATCHER. R/D HES LUBRICATOR,BOPS,AND UNIT. SHUT IN WELL. RIG RELEASED 06:00. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Bruce Simonson Eni Petroleum Sr.Ddg.Spvr. '907-685-0710 • Eni representative Craig Ruminer Eni Petroleum Drilling Supv. Eni representative Bill Petty Eni Petroleum HSE Eni representative Vance Dale Eni Petroleum Matls Coordinator Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8601 907-575-9427 Eni representative Ken Bogner Eni Petroleum Materials Coordinato Tool Push Mike Williams Nabors Alaska Dolling Tool Pusher 907-670-1492 Tool Push Kenny Sullivan Nabors Alaska Dulling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date LINER 7 6.184 L-80 7,396.8 10,668.0 8/5/2013 Last Leakoff Test Depth(RKB) IND(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 4.021.0 3,728.37 LSND 9.30 636.0 12.58 2,437.2 4 �1yy�1pp�1y� {r�mm oo 1p cp o ay00.h m mn w< of 17 b y{qp 17�N1pp Yfa Or S Ap y��a.r- CyD�yy�Y I�`�Q( A O n§ A.Op pNNp��pp� "8 1E2i? 1717Yro Oi N Wi- mo �i ibNON @ 6 A N N N N N N Egg.,-, N N N .0 mg N N ..I W O'...: :o.O.. ...01. .O:to01 A..:. :::O: ...A: O'.::01 2 . . . r . r . 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E E Tn' I V OYO�C N.D.Oz.gdiMp g0 tav 40 m M U � g a. n O 3 ° § E O. 00 0 'tM M N & .� N o W I m i N tO O A G zI- ° W SIM 4•0 iJ Vl n n C Y�� G 13 4 W q w� W r r--- fat. Y"1 q V . 0 0 0 O �r1"nr' � ��«+' *IMd1iw1� C M L _ J _. 8 CX 1 e Q. 3 E. ° E a Lt% a 3 d _ � a 8 L o a u = a t 1. . , _...I. _.. al °. 8 S O p +1 E In H N N O p N 0 p N S p N O p 0 O N ry N N 1 N N 10 ime g O N O M O N O N N O 0 . .e a g $ " O .5 a E o . 3 L W V L s s Schlumberger Cementing Jou Report CemCATv1.5 Pro z13-c ( Well OP22-WW03 Client ENI Field Oliktok Point SIR No. BY1G-00161 S h / Engineer Steve Abbott • Job Type Intermediate casing Country United States Job Date 07-30-2013 • Time Pressure - Rate -- Density -- Rig Pressure Messages • 15:17:47 Circulate With Rig Pumps at 4 BPI Shut Down Rig Pumps.Line Up to Pump 5 bbls of Water Ahead End Water Ahead — Low Pressure Stall r .-- High Pressure Test 15:33:00 Reset Total,Vol=5.10 bbl Start MudPUSH Mud Balance Weight= 12 ppg 15:48:00 [r . [,,c Reset Total,Vol=53.10 bbl Bottom Plug Away 16:03:00 Start Pumping Cement Slurry Temp=81 degF 16:18:00 ral 40 bbls Mix Water Away 50 bbls Mix Water End Cement Slurry 16:33:00 _ Reset Total,Vol= 111.49 bbl Pump 10 bbls of Water Behind End Water,Rig Pumps Take Over, Riq Pumps Pumping @ 81 SPM 650 Strokes Away 16:48:00 3 1000 Strokes,84 SPM 1600 Strokes Away,84 SPM 17:03:00 2000 Strokes Away,84 SPM F 2500 Strokes Away,84 SPM • • 17:18:00 3250 Strokes Away,84 SPM lit Water Ahead at Shoe @ 3983 St I ' MudPUSH at Shoe @ 4033 Stroke I Cement at Shoe @ 4553 Strokes i 17:33:00 /( e55 5000 Strokes Away,82 SPM I 5400S ti_e.s,Reduce Rate to 20 17:48:00 Pumped 1/2 Shoe-Track.Shut Do 18:03:00 Bleed Off,Check Floats 18:11:04 Floats Holding hh:mm:ss 0.00 1000 2000 3000 4000 5000 0.00 1.7 3.3 5.0 6.7 8.3 10.0 5.0 10.0 15.0 20.0 25.0 0.00 1000 2000 3000 4800 5000 07n0/2013 MI,. PSI B/M LB/G PSI 07/30/2013 18:22:02 $cblumberger Cementing Job Report CemCATv1.4 os? flYell 0P22-WW03 Client ENI Petroleum Field 011ktok Point SIR No. BYFZ-00123 Engineer Richard Grant 3ob Type 7"Liner Country United States 3ob Date 0k:T6-2013 Time Pressure Rate Density � Messages MIMI WWI 16:15:40 rig up cement head 1 I f� f 16:31:00 >> I 16:46:00 Safety meeting 17:01:00 17:16:00 I r 17:31:00 done priming up/rig to glue to SA start pumping water ahead to break drt 17:46:00 shut dorm Pressure Test Lines start batcteng up MudPush11 Spacer Reset Total,Vol=2.77 bbl 18:01:00 start purling Spacer got returns I I Reset Total,Vol=29 bbI 18:16:00 start hatching cement start pumping cement 18:31:00 18:46:00 I Reset Total,Vol=110 bbl on water Reset Total,Vol=2.2bbl Drop Dart start water nbehlnd dart shut down give to rig 19:0I:00 !! Reset Total,Vol=5.5 bbl 19:16:00 19:31:00 -- plug landed 19:46:001 J shear pin 19:51:55 lob Completed Ok hh:mm:ss OA. $$m 7000 MOO Mb 1100 OAS u ,A le SA WA IA .. SUA Si MO w41.21 a PSI B/N la/G 08/0612013 20:28:15 DATA L. .,ED '� ,y ‘g 40013 R M K BENDER �] i•• EI%IJ61 LOIS Schiumberger AOGCC Drilling & Measurements 2_\ MWD/LWD Log Product Delivery Customer ENI US Operating Co.Inc.Alaska Dispatched To: Makana Bender Well No 0P22-WW03 Date Dispatched: 15-Aug-13 Installation/Rig NABORS 245 Dispatched By: Hector Echeto Data No Of Prints No of CDs 0 P22-WW03 Log 1 2 in MD 1 2 in TVD 1 5 in MD 1 5inTVD 1 Received By: ✓ --- Please sign and return one copy to: D&M,2525 Gambell Street,Suite 400 Anchorage,Alaska 99503 hecheto(a)slb.com Hector Echeto Fax:907-561-8317 TRANSMITTAL#:6411 • 0A1'' OF//7,Tye� THE STATE Alaska Oil�I �, A las a Oil and Gas �� of l 1 �� Conservation Commission fir. GOVERNOR SEAN PARNELL 333 West Seventh Avenue ALAS"- Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 James Wright // Drilling Engineer Manager `� — 054' ENI Petroleum GIs 3800 Centerpoint Drive Anchorage, AK 99503 Re: Nikaitchuq Field, Ivish Undefined Pool, 0P22-WW03 Sundry Number: 313-378 Dear Mr. Wright: 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, Cathy P oerster Chair DATED this 7 day of July, 2013. Encl. .)1 RECEIVED STATE OF ALASKA .∎(\ � JUL 1 7 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION D75 -7/17/4-3 APPLICATION FOR SUNDRY APPROVALS AOGC 20 MC 25.280 1.Type of Request; Abandon❑ Plug for Redrill❑ Perforate New Poop Repair Well❑ Change Approved Program❑ Suspend�L,/ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension ❑ Operations Shutdown iv-- Re-enter Susp.Well❑ Stimulate Alter Casing❑ Other: ❑ 2.Operator Name: 'T 4.Current Well Class: 5.Permit to Drill Number: ENI Petroleum Exploratory ❑ Development ( I 213-054' 3800 Centerpoint Drive Stratigraphic ❑ Service [ 6.API Number: Anchorage Alaska 99503 50-029-23489-00-00 . 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? OP22-WW03• Will planned perforations require a spacing exception? Yes❑ No❑ 1 9.Property Designation(Lease Number): 10.Field/Pool(s): u'3 _ADL 355024, 373301, 390616• Nikaitchug1 %VISI+ t„N_EiF wTR' ? 043 Ai; 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 3,940',- 3,670'. 3,977' 3,707' Casing Length Size MD ND Burst Collapse Structural 160' 20" 160 160 Conductor 3,940' 13 3/8" 3,940 3,670 5380 2670 Surface Intermediate ' Production Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): 12.Attachments: Description Summary of Proposal El 13.Well Class after proposed work: 4,1143"�1_1b Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development[] Service izr. it 14.Estimated Date for July 15th,2013 15,Well Status after proposed work: Commencing Operations: Oil U Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: -7-/'/./3 WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: ( 'r r igSP� GSTOR ❑ SPLUG ❑ "17.I hereby certify that the foregoing is true and corr Che best of my knowledge. Contact 907 865 3321/907 306 6224 Jam--. right Drilling Engineering Manager Email James.Wrightaenietroleum.COm Printed Name Title 14-Jul-13 Signature OF Phone Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 313f5-7 n Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Sher; RBDMS JUL 2 3 20 k4 PrcSSA- 77e.5 ,L Ca-s€k.f lb 2_5-6 aps:. Spacing Exception Required? Yes ❑ No Subsequent Form Required: /b- y a7 a t ft....C. 14.-4.- APPROVED BY Approved by: PPIK4.44........, COMMISSIONER THE COMMISSION Date: 7,-1.?.„4.' Submit Form and Form 10 403(Revised 10/2012) Appro a c i s d r 2 onths from the date of approval. Attachments in Duplicate �I, t G C °�� 7.,>:.,3 p .Ll lrO‘� Rai Enli PetiroIIeim Sundry Application for Well OP22-WW3 OP22-WW3 Proanosis Objective Move rig from well OP22-WW3 to OP17-02 and perform (workover) ESP swap. Once the OP17-02 workover is complete, move rig back to well OP22-WW3 and complete planned works. The workover of well OP17-02 is estimated to take 15 days. Current Status - 13 3/8"Casing run and cemented to a depth of 3,940 measured depth - The 13 3/8"casing is set in the top of the Canning. The HRZ, Kuparuk, or Sag have not been penetrated. - The target formation is the Ivishak-Water Reservoir cfr Proposed Works 1) AS NOTED ABOVE-The 13 3/8"casing is set and cemented. 2) Prepare Rig 245 to move from Well OP22-WW3 to Well OP17-02 3) Rig up on Well OP17-02 4) Install and test wellhead to 5000 PSI. ,i 5) Nipple up 13-5/8"5K BOP and test to 3500 PSI. Notify AOGCC 24 hrs before test. 6) Execute ESP Swap. 5� 7) Test ESP and release rig 3(_'- 3G 8) Move Rig from Well OP17-02 to Well Op22-WW3 9) Rig up on Well OP22-WW3 10) Install and test wellhead to 5000 PSI. 11) Run in Hole-Test 13 3/8"Casing 12) Return to the OP22-WW3 Drilling Program OP22-WW3 Sundry Prognosis 143u1y13.doc Page 1 of 1 Printed: 14-Jul-13 . • Schwartz, Guy L (DOA) From: Wright James <James.Wright @enipetroleum.com> Sent: Sunday,July 14, 2013 10:53 AM To: Schwartz, Guy L(DOA) Cc: Bettis, Patricia K(DOA);Carballo Nelson;Simeone Davide; Regg,James B (DOA); DOA AOGCC Prudhoe Bay Subject: RE:OP22-WW3 Sundry Request Attachments: OP22-WW3 Sundry Request with Prognosis 14July13 revl.pdf Guy! Thank you for the quick response. Rig 245 will go on stand-by this afternoon,so,there is urgency to get verbal (or email) approval to shut down operations on well OP22-WW3 and move the rig to OP17-02 today. Can I get Jim's cell#to discuss? Please see attached revised Sundry application stating the"Type of Request" as Operations Shutdown. Thank you, James Wright Original Message From:Schwartz, Guy L(DOA) [mailto_guy_schwartz@DaL ska.gov] Sent: Sunday,July 14, 2013 10:42 AM To: Wright James Cc: Bettis, Patricia K(DOA); Carballo Nelson; Simeone Davide; Regg,James B(DOA) Subject: RE: OP22-WW3 Sundry Request James, Operational shutdown(not suspend) may require a verbal depending on your status. Call first thing Monday morning... I'm out of town till,tuesday but Jim Regg can help you. From:Wright James [James.Wright @enipetroleum.com] Sent:Sunday,July 14, 2013 9:54 AM To:Schwartz,Guy L(DOA) Cc: Bettis, Patricia K(DOA);Carballo Nelson;Simeone Davide Subject: RE: OP22-WW3 Sundry Request Guy! Please see attached notification of Eni's intent to move off Well OP22-WW3 to Well OP17-02 to perform an ESP swap. Once the OP17-02 Workover is complete,eni will move the rig back to well OP22-WW3 and complete planned works. It is estimated that the OP17-02 workover will take 15 days. The current status of well OP22-WW3: - 13 3/8"casing run and cemented to a depth of 3,940 md. (Cement has not been drilled out) - The 13 3/8"casing is set in the top of the Canning.The HRZ, Kuparuk,or Sag have not been penetrated. 1 Thank you, James Wright Eni Drilling Engineering Manager 907 306 6224-Cell This message may contain information that is confidential,and is being sent exclusively to the Recipient. If you are not the designated Recipient,you are prohibited from utilizing,copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake,we ask you to kindly inform the Sender and to delete the message. It is understood that,with regard to messages sent by its network,the Company is not responsible for any statements made or opinions expressed,that are not strictly related to the Company's operations. This message may contain information that is confidential,and is being sent exclusively to the Recipient. If you are not the designated Recipient,you are prohibited from utilizing,copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake,we ask you to kindly inform the Sender and to delete the message. It is understood that,with regard to messages sent by its network,the Company is not responsible for any statements made or opinions expressed,that are not strictly related to the Company's operations. 2 En ° °t 0 rill fl iirolleum Oliktok Point OP22- Nikaitchuq Field p WW03(As-built) North Slope - Alaska DIR/LWD FORM DEPTH HOLE CASING MUD INFO WL Logging MWD MD I TVD SIZE SPECS Hazards Cement to Surface 20" Hole Angle ,' X-65 0° 20"Conductor Shoe 160' 160' N/A Welded/Driven N/A !If ° o Surface Csq D i r/P W D -0:-.1 0 13-3/8" -o 68 lbs/ft Wellbore Stability Mud Motor ai L-80,BTC 9.2-9.6 ppg Lost Circulation r B/Permafrost 1,800' 1,789' Hole Cleaning KOP:300' o Hole Angle 40 13-3/8"Casing Point 3,940' 3,670' C°L''° _ 16" 50°F SPUD /�9 k eT 25�/5� C , 30 M' 1 La4 OPZ2-Wv^3 3 frt 2I3o5 Regg, James B (DOA) From: Simonson Bruce [Bruce.Simonson @enipetroleum.com] Sent: Monday, July 15, 2013 7:38 AM To: DOA AOGCC Prudhoe Bay g l 71/ /g(I 3 Cc: Wright James; Occhionero Lara; Carballo Nelson; Simeone Davide; Kuck Marc; Cesari Michele Attachments: 7-14 CSG TEST.pdf 13 3/8" casing test chart. Bruce Simonson Rig Supervisor OPP Eni Petroleum 907-685-0710 Bruce.Simonson(a�enipetroleum.com This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that, with regard to messages sent by its network, the Company is not responsible for any statements made or opinions expressed, that are not strictly related to the Company's operations. 1 ka, l-cttAA1 OPZ1 - uow3 Psb 2-k3,6154-0 -- - - 15 M. v\xk 1.00.,0 ,M'AMr, Ogro yao•WMF -07..4 i to a ro wi 111*1**64144, 144°4.414* '' 1 ./0;°0.:• 1"10 0 1 Kg&116w1 W,- ,#: *,'ft 1 4* r, reTOOWF-21M ■w) •Zo difibb 4* IN 4,e°,4, ro 010.0 0 0•MAWMaiti ,4 1 tlki 4 1 1%LI k\kob. i k%, ,i44,e, ..worom _0 0•£ 4 i 1 i 11%i p '1 7 wiu IN% /f/A0 ,4040Vrstr."., rim,A v.pm i m iii i",„ko wftwit kp '1‘141‘ ' ' ‘‘‘‘, 00,, II 1,/ */ 0#1 /40 tolar, ot-N*01•\\**1\ % \ q #44* 4 / vsept..4.4,0 * a 1111%%11 4 iss# 4 ilittittetit.taf;.ou. 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' 4. i Iiiiirplim 11111 ,,, ,,, ..40 ,./4,Hvo,64 owpoilirio 1 II Ill ‘. 114•ttitiliptess 111140111001141111111 1 I ‘ *It 4° V410104 00111/60011114111111 I •VP, s•° 40411" # i - / wit 0 i / As 411-410.****" i t 411 *k* ,, -4.7 .41-4-o•oo ,•■# 0./ # ilvillt - -#400 .6-0-1.°- Acv 0 i I 4Wor.movrfoov-so--- ,--70.0.0903$1, ' - ---: ..,„ .iyot-ft. ..r... •••-•wailill."-W.000,- , F - / „„ •••, ,, .wsv K\ 1 tik�j OPZZ v-t,,;ti 2-13054-o Regg, James B (DOA) From: Simonson Bruce [Bruce.Simonson @enipetroleum.com] Sent: Sunday, July 14, 2013 8:01 PM f t 'I i 5-11 To: DOA AOGCC Prudhoe Bay Subject: NABORS 245 BOP TEST OP22 ENI Inspectors, This is to inform you that we have verbal approval from Jim Regg to suspend operations on well OP22. His instructions are to test csg. @ 2500#for 30 mins., chart it and pass the results along to you. He stated that BOP test is not required- — Thanks, Bruce Simonson Rig Supervisor OPP Eni Petroleum 907-685-0710 Bruce.Simonson(c�enioetroleum.com This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that, with regard to messages sent by its network, the Company is not responsible for any statements made or opinions expressed, that are not strictly related to the Company's operations. 1 kile-a-t tvum CPU-w,0013 Regg, James B (DOA) I From: Wright James [James.Wright @enipetroleum.com] Sent: Sunday, July 14, 2013 7:12 PM To: Regg, James B (DOA) Subject: Re: OP22-WW3 Sundry Request 2-1305- I will give you a call at 7:30. We are currently nippling up BOP and then will perform pressure test. After pressure test, perform the 13 3/8 pressure test. Well will be cemented in shoe track and filled with kill weight fluid .2 over reservoir pressure (1640 psi) - 1900' of diesel & 1700' of 9.3# brine. Thank you Tzn,' (� i� G J� r Y James cos Sit tvi NAAA oyt op ZZ-- t:J J Z 1 305-40 Sent from my iPhone ■ e-t( f-zrrit 4W as " On Jul 14, 2013, at 6:01 PM, "Regg, James B (DOA)" <jim.regg @alaska.gov> wrote: 13-3/8 tested? Need a better description of how you will leave OP22-WW3 at surface. As stated by Guy Schwartz this is a request for operations shut down. I do not have regs in front of me so please make sure you are compliant with those requirements. I will be available after 730pm this evening or you can contact me in the morning. Cell # 301-6470. Sent from Samsung Mobile Original message From: Wright James <James.Wright(c- enipetroleum.com> Date: 07/14/2013 10:54 AM (GMT-09:00) To: "Schwartz, Guy L (DOA)" <guy.schwartz @alaska.gov> Cc: "Bettis, Patricia K (DOA)" <patricia.bettis a alaska.gov>,Carballo Nelson <nelson.carballo @enipetroleum.com>,Simeone Davide <Davide.Simeone @enipetroleum.com>,"Regg, James B (DOA)" <jim.regg @alaska.gov>,DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay @alaska.gov> Subject: RE: OP22-WW3 Sundry Request Guy! Thank you for the quick response.Rig 245 will go on stand-by this afternoon, so,there is urgency to get verbal(or email)approval to shut down operations on well OP22-WW3 and move the rig to OP17-02 today. Can I get Jim's cell#to discuss? Please see attached revised Sundry application stating the"Type of Request" as Operations Shutdown. Thank you, James Wright 1 Original Message • From: Schwartz,Guy L(DOA) [mailto:guy.schwartz @alaska.gov] Sent: Sunday,July 14,2013 10:42 AM To: Wright James Cc: Bettis,Patricia K(DOA); Carballo Nelson; Simeone Davide;Regg,James B (DOA) Subject: RE: OP22-WW3 Sundry Request James, Operational shutdown(not suspend)may require a verbal depending on your status. Call first thing Monday morning ... I'm out of town till,tuesday but Jim Regg can help you. From: Wright James [James.Wright a,enipetroleum.com] Sent: Sunday,July 14,2013 9:54 AM To: Schwartz,Guy L(DOA) Cc: Bettis, Patricia K(DOA); Carballo Nelson; Simeone Davide Subject: RE: OP22-WW3 Sundry Request Guy! Please see attached notification of Eni's intent to move off Well OP22-WW3 to Well OP17-02 to perform an ESP swap. Once the OP17-02 Workover is complete,eni will move the rig back to well OP22-WW3 and complete planned works. It is estimated that the OP17-02 workover will take 15 days. The current status of well OP22-WW3: 13 3/8"casing run and cemented to a depth of 3,940 md. (Cement has not been drilled out) The 13 3/8" casing is set in the top of the Canning. The HRZ,Kuparuk,or Sag have not been penetrated. Thank you, James Wright Eni Drilling Engineering Manager 907 306 6224-Cell This message may contain information that is confidential,and is being sent exclusively to the Recipient. If you are not the designated Recipient,you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that,with regard to messages sent by its network,the Company is not responsible for any statements made or opinions expressed,that are not strictly related to the Company's operations. This message may contain information that is confidential,and is being sent exclusively to the Recipient. If you are not the designated Recipient,you are prohibited from utilizing,copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that,with regard to messages sent by its network,the Company is not responsible for any statements made or opinions expressed,that are not strictly related to the Company's operations. This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that, with regard to messages sent by its network, the Company is not responsible for any statements made or opinions expressed, that are not strictly related to the Company's operations. 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrili❑ Perforate New Poo❑ Repair Well❑ Change Approved Program❑ Suspend L Plug Perforations❑ Perforate0 Pull Tubing❑ Time Extension ❑ Operations ShutdownA ' Re-enter Susp.Well❑ Stimulate Alter Casing❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ENI Petroleum Exploratory ❑ Development IS 213-054 3600 Centerpoint Drive Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-029-23489-00-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? OP22- VVW03 Will planned perforations require a spacing exception? Yes❑ No❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 355024, 373301, 390616 Nikaitchuq 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 3,940' 3,670' 3,977' 3,707' Casing Length Size MD TVD Burst Collapse Structural 160' ' 20" 160 160 Conductor 3,940' 13 318" 3,940 3,670 5380 2670 Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): '12.Attachments: Description Summary of Proposal IN 13,Well Class after proposed work: . Detailed Operations Program ❑ 80P Sketch ❑ Exploratory ❑ Stratigraphic❑ Development El Service ❑ 14, Estimated Date for July 15th,2013 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and corre o the best of my knowledge. 907 865 3321/907 306 6224 Contact Jame- right Drilling Engineering Manager Email JameS.wright(C�enietr0leum.COm Printed Name Title 14-Jul-13 Signature dr Phone Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Submit Form and Form 10-403(Revised 10/2012) Approved application is valid for 12 months from the date of approval. Attachments in Duplicate =n1[ PtiroIIim Sundry Application for Well OP22-WW3 Pr z13p; r OP22-WW3 Proanosis Objective Move rig from well OP22-WW3 to OP17-02 and perform (workover) ESP swap. Once the OP17-02 workover is complete, move rig back to well OP22-WW3 and complete planned works. The workover of well OP17-02 is estimated to take 15 days. Current Status - 13 3/8"Casing run and cemented to a depth of 3,940 measured depth ✓ - The 13 3/8"casing is set in the top of the Canning. The HRZ, Kuparuk, or Sag have not been penetrated. - The target formation is the Ivishak-Water Reservoir Proposed Works 1) AS NOTED ABOVE-The 13 3/8"casing is set and cemented. 2) Prepare Rig 245 to move from Well OP22-WW3 to Well OP17-02 3) Rig up on Well OP17-02 4) Install and test wellhead to 5000 PSI. 5) Nipple up 13-5/8"5K BOP and test to 3500 PSI. Notify AOGCC 24 hrs before test. 6) Execute ESP Swap. 7) Test ESP and release rig 8) Move Rig from Well OP17-02 to Well Op22-WW3 9) Rig up on Well OP22-WW3 10) Install and test wellhead to 5000 PSI. 11) Run in Hole-Test 13 3/8"Casing 12) Return to the OP22-WW3 Drilling Program OP22-WW3 Sundry Prognosis 14July13.doc Page 1 of 1 Printed: 14-Jul-13 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Poo❑ Repair Well❑ Change Approved Program ❑ Suspend El Plug Perforations❑ Perforate❑ Pull Tubing • Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing % Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ENI Petroleum Exploratory ❑ Development r 213-054 3800 Centerpoint Drive Stratigraphic ❑ Service 6.API Number: Anchorage Alaska 99503 50-029-23489-00-00 1 7. If perforating 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? OP22- VVW03 Will planned perforations require a spacing exception? Yes❑ No❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 355024, 373301, 390616 Nikaitchuq 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth D(ft): Plugs(measured): Junk(measured): 3,940' 3,670' 3,977' 3,707' Casing Length Size MD TVD Burst Collapse Structural 160' 20" 160 160 Conductor 3,940' 13 3/8" 3,940 3,670 5380 2670 Surface ik3 Intermediate / V \ Production ( / l() Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: ( YYYeee Tubing Grade: Tubing MD(ft): Packers and SSSV Type: q ackers and SSSV MD(ft)and TVD(ft): 12.Attachments: Description Summary of Proposal is v J 13.Well Class after proposed work: I Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development El Service ❑ 14.Estimated Date for July 15th,2013 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and corr o he best of my knowledge. Contact 907 865 3321/907 306 6224 James right Drilling Engineering Manager Email James.wrightaenietroleum.com Printed Name _.rte Title 14-Jul-13 —e...i Signature Or Date COMMISSION USE ONLY Conditions of approval: Notify Commission that a representative may witness Sundry Number: Plug Integrity ❑ BOP at ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Submit Form and Form 10-403(Revised 10/2012) Approved application is valid for 12 months from the date of approval. Attachments in Duplicate 10#1.424- • Enil PtiroIkuim ci Sundry Application for ell OP22-WW3 OP22-WW3 Prognosis Objective Move rig from well OP22-WW3 to OP17-02 and perform (workover) E • swap. Once the OP17-02 workover is complete, move rig back to well OP22-WW3 and comple'- planned works. The workover of well OP17-02 is estimated to take 15 days. Current Status — 13 3/8"Casing run and cemented to a depth of 3,9'0 measured depth — The 13 3/8"casing is set in the top of the Captnin.. The HRZ, Kuparuk, or Sag have not been penetrated. — The target formation is the Ivishak—W r Reservoir \� Proposed Works 1) AS NOTED ABOVE—The 13 3/8"casing is .et and cemented. 2) Prepare Rig 245 to move from Well OP2 -WW3 to Well OP17-02 3) Rig up on Well OP17-02 4) Install and test wellhead to 5000 PS'. 5) Nipple up 13-5/8"5K BOP and to to 3500 PSI. Notify AOGCC 24 hrs before test. 6) Execute ESP Swap. 7) Test ESP and release rig 8) Move Rig from Well OP17-• to Well Op22-WW3 9) Rig up on Well OP22-WW: 10) Install and test wellhea'i to 5000 PSI. 11) Run in Hole—Test 1 3/8"Casing 12) Return to the OP2 W3 Drilling Program t` OP22-WW3 Sundry Prognosis 14Ju1y13.doc Page 1 of 1 Printed: 14-Jul-13 w��\\OF 1%%%s9 THE STATE Alaska Oil and Gas F fi►�� O �-� e m o _ f onservation Commission -- GOVERNOR SEAN PARNELL 333 West Seventh Avenue *R. O " Anchorage, Alaska 99501-3572 A LASY' Main: 907.279.1 433 Fax: 907.276.7542 James Wright Drilling& Completion Engineering Manager ENI US Operating Co. Inc. 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Undefined Pool, OP22-WW03 ENI US Operating Co. Inc. Permit No: 213-054 Surface Location: 3133.8' FSL, 1696.4' FEL, SEC. 5, T13N, R9E, UM Bottomhole Location: 1108' FSL, 3534' FEL, SEC. 32, T14N, R9E, UM Dear Mr. Wright: Enclosed is the approved application for permit to drill the above referenced service 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 Commission 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 Commission 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 Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, ile / /D-)61 ,4„.____ Cathy P. roerster Chair DATED this day of May, 2013. RECEIVED STATE OF ALASKA APR 16 2013 AL :A OIL AND GAS CONSERVATION COMF ON PERMIT TO DRILL AOGCC 20 AAC 25.005 1a.Type of Work: 1b.Proposed Well Class: Development-Oil U Service- Winj U Single Zone ❑ 1c.Specify if well is proposed for: Drill • Redrill ❑ Stratigraphic Test ❑ Development-Gas❑ Service-Supply El• Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Re-entry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket 0 Single Well ❑ 11.Well Name and Number: ENI US Operating Co Inc Bond No. RLB0008627' OP22-WW03 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive Suite 300,Anchorage 99503 MD: 10855'• TVD: 9695' . Nikaitchuq, 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 3133.8 FSL 1696.4 FEL S5 T13N R9E UM - ADL 355024,373301,390616 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1071 FSL 3513 FEL 32 T14N R9EUM ADL 417493 .711 7/1/2013 Total Depth: 9.Acres in Property: 'i 1r1ID 14.Distance to Nearest Property: 1108 FSL 3534 FEL 32 T14N R9EUM 1289-3-1..S- , fS 600'to unit boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 53.2 feet 15.Distance to Nearest Well Open Surface:x- 516584 y- 6036487 Zone- 4 • GL Elevation above MSL: 12 feet to Same Pool: 1400'NE to OP26-DSPO2 t 16.Deviated wells: Kickoff depth: c 300 feet y�lq ib 17.Maximum Anticipated PressufR3cpsig(see 20 AAC 25.035) -"-A- 5•I.13 Maximum Hole Angle: 39 369 degrees Downhole: 38�6psig '-/Gy2 4111 Surface: 37/3 29 • 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Driven 20" 178.89 X-65 Welded 84 36 36 120 120 pre-installed 16" 13-3/8" 68 L-80 BTC 3956 35 35 3991 3672 1409 sx 10.7#ASL,228 sx 12.5#Deeperete 12.25" 9-5/8" 40 L-80 Hydri11563 7635 33 33 7668 6563 550 sx 15.8#Class G 8.5" 7" 26 13CrL80 Vam Top 3387 7468 6513 10855 9695 479 sx 15.8#Class G 6,,,"...0 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat 0 ' BOP Sketch 0 - Drilling Program 0. Time v.Depth Plot ❑ Shallow Hazard Analysis 0 Diverter Sketch 0 • Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements is 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Luca Boni @ 907-865-3328 Printed Name -.Wright Title Drilling&Completion Engineering Manager Signature `i��w. / Phone Date Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: j J 3 0 5 L( 50-019-‘,23 1•1 V - QO-00 Date: ,- requirements. Conditions of approval: If box is checked, WI ked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: Other: ‹.000 (S.:-0 (S.:- /3f -1;--S14--- - f 1;--Sj Samples req'd: Yes Li No Mud log req'd: Yes ❑ No [✓] q u c.�Si 11•� -rs. . H2S measures: Yes❑ No Directional svy req'd: Yes Er No ❑ l 8 7 SDd /oSL A-S c..4nrr fXckjiI)•on Aty viY'J : /U %/FS ril/ )o APPROVED BY THE COMMISSION DATE: .5 7-- /3 ,COMMISSIONER 5 ( l3 ORIGINAL ,, tA, Form 10-401(Revised 7/2009) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Submit in Duplic ,`/ 7 G RECEIVED Villik APR 16 2013 Enli• ') ttir .IeurnAOGCC �o 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 James Wright Phone(907)865-3321 Email: James.Wright @enipetroleum.com April 16,2013 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 RE: Application for Permit to Drill Water Source OP22-WW03 Dear Commissioners, ENI US Operating Co. Inc.hereby applies for a Permit to Drill for the onshore water source well OP22- WW03.The well will be drilled and completed using Nabors rig 245E. The planned spud date could be 7/01/2013. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for this well bore. If you have any questions or require further information,please contact Luca Borri at 907-865-3328. Sinc , c James Wright Drilling&Completion Engineering Manager tfri* EMI PetroF um REvi'Sk,1 ?�yi,2_03 Application for Permit to Drill Well OP22-WWO3 Saved: 19-Apr-13 Application for Permit to Drill Document Water Source Well OP22-WW03 Table of Contents 1. Well Name 2 Requirements of 20 AAC 25.005(f) 2 2. Location Summary 2 Requirements of 20 AAC 25.005(c)(2) 2 Please see Attachment 7: Surface Platt 3 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 3 4. Drilling Hazards Information 3 Requirements of 20 AAC 25.005(c)(4) 3 5. Procedure for Conducting Formation Integrity Tests 4 Requirements of 20 AAC 25.005(c)(5) 4 6. Casing and Cementing Program 4 Requirements of 20 AAC 25.005(c)(6) 4 7. Diverter System Information 5 Requirements of 20 AAC 25.005(c)(7) 5 8. Drilling Fluid Program 5 Requirements of 20 AAC 25.005(c)(8) 5 Surface Hole Mud Program(extended bentonite) 6 Intermediate Hole Mud Program(LSND) 6 Production Hole Mud Program (MI VersaClean Mineral Oil Base) 6 9. Abnormally Pressured Formation Information 6 Requirements of 20 AAC 25.005(c)(9) 6 10.Seismic Analysis 6 Requirements of 20 AAC 25.005(c)(10) 6 11.Seabed Condition Analysis 7 04192013 OP22-WW03 PERMIT Document.docx Page 1 of 9 Printed: 19-Apr-13 Enli ' tiroHeurn Application for Permit to Drill Well OP22-WW03 Saved: 19-Apr-13 Requirements of 20 AAC 25.005(c)(11) 7 12.Evidence of Bonding 7 Requirements of 20 AAC 25.005(c)(12) 7 13.Proposed Drilling Program 7 Requirements of 20 AAC 25.005(c)(13) 7 14.Discussion of Mud and Cuttings Disposal and Annular Disposal 8 Requirements of 20 AAC 25.005(c)(14) 8 15.Attachments 9 Attachment 1 Directional Plan 9 Attachment 2 Drilling Hazards Summary 9 Attachment 3 BOP and Diverter Configuration 9 Attachment 4 Cement Loads and CemCADE Summary 9 Attachment 5 Well Schematic 9 Attachment 6 Formation Integrity And Leak Off Test Procedure 9 Attachment 7 Surface Platt 9 1. Well Name Requirements of 20 AA C 25.005(f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. Well Name: OP22-WW03 2. Location Summary Requirements of 20 AA C 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2)a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; 04192013 OP22-WW03 PERMIT Document.docx Page 2 of 9 Printed:19-Apr-13 IR* em En• Application for Permit to Drill Well OP22-WW03 Saved: 19-Apr-13 Location at Surface 3133.8 FSL 1696.4 FEL S5 T13N R9E UM ASP Zone 4 NAD 27 Coordinates RKB Elevation 53.2'AMSL Northings 6036486.830 Eastings 516583.960 Pad Elevation 12'AMSL Location at Top of Ivishak Sand Target 971 FSL 3459 FEL 32 T14N R9EUM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 9921 Northings: 6039598.380 Eastings:514805.710 Total Vertical Depth, RKB:_ 8773 Total Vertical Depth, SS: 8720 Location at Total Depth 1108 FSL 3534 FEL 32 T14N R9EUM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 10855 Northings: 6039737.120 Eastings: 514729.650 Total Vertical Depth, RKB: 9695 Total Vertical Depth, SS: 9642 Please see Attachment 7: Surface Platt and (D)other information required by 20 MC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill(Form 10-401)must (1)include a plat, drawn to a suitable scale,showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 MC 25.035, 20 MC 25.036, or 20 MC 25.037, as applicable; Please see Attachment 3: BOP and Diverter Configuration 4. Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Doll must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4)information on drilling hazards, including (A)the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; 04192013 OP22-WW03 PERMIT Document.docx Page 3 of 9 Printed:19-Apr-13 Eni ✓ tiroIIeur Application for Permit to Drill Well OP22-WW03 Saved: 19-Apr-13 Sag River sand: The expected reservoir pressure is 0.55 psi/ft, or 10.5 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, methane gradient(0.11), and the planned vertical depth of the formation: MPSP = (8440 ft ND)(0.55 0.11 psi/ft) V`i`f ox •SS `Wiz- l . = 3713 psi Ivishak sand: The expected reservoir pressure is 0.51 psi/ft, or 9.8 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the planned vertical depth of the formation: MPSP = (8773 ft TVD)(0.51 - 0.11 psi/ft) = 3509 psi (B)data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C)data concerning potential causes of hole problems such as abnormally geo pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25030(f); Please see Attachment 6: Formation Integrity And Leak Off Test Procedure 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner,pre- perforated liner, or screen to be installed; 04192013 OP22-WW03 PERMIT Document.docx Page 4 of 9 Printed: 19-Apr-13 • Eni II^OO N��UII 1 Application for Permit to Drill Well OP22-WW03 Saved: 19-Apr-13 Casing and Cementing Program See also Attachment 4: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Connecti (ft) (ft) (ft) Cement Program on 20 178.89 X-65 Welded 124 36 / 36 1607 160' Cemented to surface Cemented to Surface with 1409 sx 10.7#ASLite Lead Yield 4.33 cu. Ft./sk, 13-3/8 16" 68 L-80 BTC 3956' 35 / 35 3991'/ 3672' 228 sx 12.5# DeepCRETE Tail Yield 1.54 cu.ft./sk Cement Top plan©6468'MD Cemented w/550 sx 9-5/8 12-1/4" 40 L-80 Hydrill 7635' 33 / 33 7668'/ 6563' 15.8#Class G 563 Yield 1.16 cu.ft./sk 13 Cement Top plan @ 7468'MD 7" liner 8-1/2" 26 Chrome Vann 3387' 7468'/ 6513' 10855'/ 9695' Cemented w/479 sx L-80 Top 15.8#Class G Yield 1.16 cu.ft./sk 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); 1.13 �✓ Please see Attachment 3: BOP Configuration. 'r'j €NI-requests-that-AOGEEwatve-diverter-regwirements-per-20-AAC 25.035. (h-)-(2). 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8)a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 MC 25.033; Drilling will be done with muds having the following properties over the listed intervals: 04192013 OP22-WW03 PERMIT Document.docx Page 5 of 9 Printed: 19-Apr-13 116#1 • = 1n — tiroIIeum Application for Permit to Drill Well OP22-WW03 Saved: 19-Apr-13 Surface Hole Mud Program (extended bentonite) Spud to Base of Permafrost Base of Permafrost to Casing Point Initial Value Final Value Initial Value Final Value Density(ppg) 8.8 / 9.2 / 9.2 ✓ 9.6 Funnel Viscosity 250 250 150 200 (seconds) • Yield Point 35 45 30 35 (lb/100 sf) Plastic Viscostiy (CP) 30 55 15 20 pH 9.0 9.5 9.0 9.5 API Filtrate NC 8.0 <6.0 <6.0 (cc/30 min)) Intermediate Hole Mud Program (LSND) Production Hole Mud Program (Mineral Oil Base) 13-3/8"Csg Shoe to 9-5/8"Csg Point Value 10,5'Rf').-- Value Density 10.0- 10.5 Density(ppg) 9.6 - 10.0,/ y(ppg) 6.3a '5 Plastic Viscostiy <23.0 Funnel Viscosity 45 - 60 (CP) (seconds) Yield Point Plastic Viscostiy 12 - 18 (lb/100 s fl 20-25 (CP) - HTHP Fluid loss Yield Point (lb/100 sfJ 18-24 (m1/30 min @ <5.0 API Filtrate 200psi& 100°F (cc/30 min)) 4 - 6 ; Oil/Water Ratio 75/25 Chlorides(mg/I) <500 Electrical 650-900 Stability pH 9.0- 10.0 MBT <18.0 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) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9)for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.0330; Not applicable: Application is not for an exploratory or stratigraphic test well. 10.Seismic Analysis Requirements of 20 AAC 25.005(c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: 04192013 OP22-WW03 PERMIT Document.docx Page 6 of 9 Printed:19-Apr-13 • 10#14" ern CAIN tirolleurn Application for Permit to Drill Well OP22-WW03 Saved: 19-Apr-13 (10)for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 MC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11.Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11)for a well drilled from an offshore platform, mobile bottom-founded structure,jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 MC 25.061(b); Not applicable: Application is not for an offshore well. 12.Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12)evidence showing that the requirements of 20 AAC 25.025{Bonding}have been met, Evidence of bonding for ENI is on file with the Commission. 13.Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 5, Well Schematic. 1. Move in/ rig up Nabors 245E. 2. RU Diverter and test as per AOGCC requirements (notify Inspectors) 3. Spud and directionally drill 16" hole to casing point at as per directional plan. Run Gyro and MWD tools as required for directional monitoring. 4. Run and cement 13-3/8", 68#, L80, BTC casing to surface. Pump cement and displace with mud, land casing hanger and bump plug. 5. Install and test wellhead to 5000 PSI. 6. Nipple up 13-5/8"5K BOP and test to 5000 PSI. Notify AOGCC 24 hrs before test. 7. Pressure test casing to 2500 psi per AOGCC regulations. Record results. S-497i �"'�� — 13 -80 8. PU 12-1/4"bit and directional drilling assembly with MWD, LWD and PWD. 9. Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recording results. t' t T _ //.o /3 / / 10. Directionally drill to 9-5/8"casing point per directional plan. Pull out of hole backreaming to the surface casing shoe. 11. Install 9-5/8"casing rams in the BOP and test to 5000 PSI. 12. Run and cement 9-5/8", 40# L80, casing. Pump cement and displace with mud, land casing hanger and bump plug. 13. Install 9-5/8"packoff and test to 5000 psi. 14. Flush 13-3/8"x 9-5/8"annulus with diesel freeze protect. 04192013 OP22-WW03 PERMIT Document.docx Page 7 of 9 Printed:19-Apr-13 CAIN tirHeurn Application for Permit to Drill Well OP22-WW03 1 Saved: 19-Apr-13 15. Pressure test casing to 3000 psi per AOGCC regulations. Record results. 16. PU 8-1/2" bit and directional drilling assembly including MWD, LWD, PWD. RIH, clean out cement to top of float equipment. 17. Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recprding results. F 1T ►...^- _ /Z o p/ ns � /3,0 P* 18. Directionally drill 8-1/2" hole to TD as per directional plan. Pull out of hole backreaming to casing shoe. 19. Run and cement 7", 26# 13CrL80, Vann Top Liner. 20. Liner hanger to be set with 200' Liner lap inside the 9-5/8" intermediate casing. POOH laying down DP as required. 21. Test casing and liner to 3000 psi and record. 7" Zo 41.p- L -Yv 7" 72 Yo P s. 22. Rig up E-line and perforate. (Zo-,.e 23. PU 4 1/2"completion string as required and RIH to depth. Land tubing seals. Pressure test IA to 1500 PSI and record. Set BPV 24. Nipple down BOP, nipple up tree and test. Pull BPV. 25. Freeze protect well with diesel through shear out valve in tubing. 26. Set BPV and move rig off. 27. Rig up wire line unit. Pull BPV. 28. Set dummy valve in mandrel. 29. Place well on production. • ENI requests that the AOGCC waive surface safety valve requirements per 20 MC 25.265. (c). (1). • The Vetco horizontal wellhead utilized physically prevents locating the SSV in the vertical run of trt,. the tree as there is no vertical tree on this wellhead. 11:),v • Wellhead schematics should be on file with the AOGCC. . 14.Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well; Waste fluids generated during the drilling process will be disposed of by injection down an Oliktok Point Class I disposal well or by hauling the fluids to the Prudhoe Bay Grind and Inject Facility. All cuttings generated will be disposed of either down an Oliktok Point Class I grind and inject disposal well or hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well. 04192013 OP22-WW03 PERMIT Document.docx Page 8 of 9 Printed:19-Apr-13 Eni 42- �I�C�Heu 1 i1 Application for Permit to Drill Well 0P22-WW03 Saved: 19-Apr-13 15.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 BOP and Diverter Configuration Attachment 4 Cement Loads and CemCADE Summary Attachment 5 Well Schematic Attachment 6 Formation Integrity And Leak Off Test Procedure Attachment 7 Surface Platt Attachment 8 Casing Design 04192013 OP22-WW03 PERMIT Document.docx Page 9 of 9 Printed: 19-Apr-13 • JL -SyasFcikcA ii 119 mod , 1 Em �!-�� I 1 Application for Permit to Drill Well 0P22-WW03 Saved: 15-Apr-13 Application f o r Permit to Drill Document t -WW P22 Well Water Source W e O 03 1 Table of Contents 1. Well Name 2 Requirements of 20 AAC 25.005(0 2 2. Location Summary 2 Requirements of 20 AAC 25.005(c)(2) 2 Please see Attachment 7: Surface Platt 3 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 3 4. Drilling Hazards Information 3 Requirements of 20 AAC 25.005(c)(4) 3 5. Procedure for Conducting Formation Integrity Tests 4 Requirements of 20 AAC 25.005(c)(5) 4 6. Casing and Cementing Program 4 Requirements of 20 AAC 25.005(c)(6) 4 7. Diverter System Information 5 Requirements of 20 AAC 25.005(c)(7) 5 8. Drilling Fluid Program 5 Requirements of 20 AAC 25.005(c)(8) 5 Surface Hole Mud Program (extended bentonite) 6 Intermediate Hole Mud Program(LSND) 6 Production Hole Mud Program(MI VersaClean Mineral Oil Base) 6 9. Abnormally Pressured Formation Information 6 Requirements of 20 AAC 25.005(c)(9) 6 10.Seismic Analysis 7 Requirements of 20 AAC 25.005(c)(10) 7 101215 OP21-WW01 PERMIT Document.doc Page 1 of 9 Printed: 15-Apr-13 zu, ' trHeum 000 Application for Permit to Drill Well 0P22-WW03 Saved: 15-Apr-13 11.Seabed Condition Analysis /° 7 Requirements of 20 AAC 25.005(c)(11) ,` 7 12.Evidence of Bonding 7 Requirements of 20 AAC 25.005(c)(12) 7 13.Proposed Drilling Program ,/ 7 Requirements of 20 AAC 25.005(c)(13) 7 14.Discussion of Mud and Cuttings Disposal and Annular DiSposal 9 Requirements of 20 AAC 25.005(c)(14) 9 15.Attachments 9 Attachment 1 Directional Plan 9 Attachment 2 Drilling Hazards Summary f 9 Attachment 3 BOP and Diverter Configuration 9 Attachment 4 Cement Loads and CemCADE Summary / 9 Attachment 5 Well Schematic 9 Attachment 6 Formation Integrity And Leak Off Test ProJedure 9 Attachment 7 Surface Platt �' 9 1. Well Name / Requirements of 20 AAC 25.005(t) Each well must be identified by a unique name desi nated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(6). For a well with multiple ell branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name design d for the well by the operator and to the number assigned to the well by the commission. Well Name: OP22-WW03 2. Location Suimmary Requirement of 20 AAC 25.005(c)(2) An applicatio for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commissio and identified in the application: (2)a plat dentifying the property and the property's owners and showing (A)the oordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth, refer ced to governmental section fines. (B) he coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; 101215 OP21-WW01 PERMIT Document.doc Page 2 of 9 Printed:15-Apr-13 — .!L Enil ' (= tir4eu Lem Application for Permit to Drill Well OP22-WW03 Saved: 15-Apr-13 Location at Surface 3133.8 FSL 1696.4 FEL S5 T13N R9E UM ASP Zone 4 NAD 27 Coordinates RKB Elevation 53. 'AMSL Northings 6036486.830 Eastings 516583.960 Pad Elevation 'AMSL Location at Top of // Ivishak Sand Target 1071 FSL 3513 FEL 32 T14N R9EUM / ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB:/ 10605 Northings: 6039700.000 Eastings:514750.000 Total Vertical Depth, RK ; 9448 Total Vertical Depth, 5: 9396 Location at Total Depth 1108 FSL 3534 FEL 32 T14N R9EUM ASP Zone 4 NAD 27 Coordinates Measured Deh, RKB: 10855 Northings: 6039737.120 Eastings: 514729.650 Total Vertical epth, RKB: 9695 Total Verti I Depth, 55: 9642 Please see Attachment 7: Surface Platt i and (D)other information required by 20 MC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill(Form 10-401)must (1)include a plat, drawn to a suitable scale,showing the path f the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2)for all wells within 200 feet of the proposed well ore (A)list the names of the operators of those veils, to the extent that those names are known or discoverable in public records, and show that each named operator has b&hn furnished a copy of the application by certified mail;or (B)state that the applicant is the only affcted owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.Qb5(c)(3) An application for a Permit to Drill/rust be accompanied by each of the following items, except for an item already on file with the commission and identified in the pplication: (3)a diagram and description pf the blowout prevention equipment(BOPE)as required by 20 MC 25.035, 20 MC 25.036, or 20 MC 25.037,as applicable; / Please see Attachmrt 3: BOP and Diverter Configuration i 4. Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4)information on drilling hazards, including 101215 OP21-WW01 PERMIT Document.doc Page 3 of 9 Printed:15-Apr-13 etti Enil tr II um Application for Permit to Drill Well OP22-WW03 Saved: 15-Apr-13 (A)the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; Sag River sand: The expected reservoir pressure is 0.55 psi/ft, or 10.5 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient(0.11), and the planned vertical depth of the formation: MPSP = (8388 ft TVD)(0.55 - 0.11 psi/ft) = 3355 psi / /. Ivishak sand: The expected reservoir pressure is 0.51 psi/ft, or 9.8 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient(0.11), and the planned vertical depth of the formation: MPSP = (8721 ft TVD)(0.51 - 0.11 psi/ft) = 3488 psi . (B)data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C)data concerning potential causes of hole problms such as abnormally geo-pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5)a description of the procedure,for conducting formation integrity tests,as required under 20 MC 25.030(f); Please see Attachment 6: Formation Integrity And Leak Off Test Procedure 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application.' (6)a complete proposed casing and cementing program as required by 20 MC 25.030,and a description of any slotted liner,pre- perforated liner, or screen to be installed; 101215 OP21-WW01 PERMIT Document.doc Page 4 of 9 Printed: 15-Apr-13 Enhi ii troIIeui r Application for Permit to Drill Well OP22-WW03 Saved: 15-Apr-13 Casing and Cementing Program See also Attachment 4: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (Ib/ft) Grade Connecti (ft) (ft) (ft) Cement Program on 20 178.89 X-65 Welded 124 36/ 36 1607 160 Cemented to surface Cemented to Surface with 1409 sx 10.7#ASLite Lead Yield 4.33 cu. Ft./sk, 13-3/8 16" 68 L-80 BTC 3956' 35/ 35 3991'/ 3672' 228 sx 12.5# DeepCRETE Tail Yield 1.54 cu.ft./sk Cement Top plan @ 6468'MD Cemented w/550 sx 9-5/8 12-1/4" 40 L-80 H56311 7635' 33/ 33 7668'/ 6563' 15.8#Class G Yield 1.16 cu.ft./sk 13 Cement Top plan @ 7468'MD 7"liner 8-1/2" 26 Chrome Vam 3387' 7468'/ 6513' 10855'/ 9695' Cemented w/479 sx L-80 Top 15.8#Class G Yield 1.16 cu.ft./sk 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 MC 25.035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2); Please see Attachment 3: BOP Configuration. ENI requests that AOGCC waive diverter requirements per 20 MC 25.035. (h). (2). 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system, as required by 20 MC 25.033; Drilling will be done with muds having the following properties over the listed intervals: 101215 OP21-WW01 PERMIT Document.doc Page 5 of 9 Printed:15-Apr-13 • Enli tir 'sIum ,,, . .:etu Application for Permit to Drill Well OP22-WW03 Saved: 15-Apr-13 Surface Hole Mud Program (extended bentonite) Spud to Base of Permafrost Base of Permafrost to Casing Point Initial Value Final Value Initial Value Final Value Density(ppg) 8.8 9.2 9.2 9.6 Funnel Viscosity 250 250 150 200 (seconds) Yield Point 35 45 30 35 (lb/100 sf) Plastic Viscostiy 30 55 15 20 (CP) pH 9.0 9.5 9.0 9.5 API Filtrate NC 8.0 <6.0 <6.0 (cc/30 min)) Intermediate Hole Mud Program (LSND) Production Hole Mud Program (Mineral Oil Base) 13-3/8"Csg Shoe to 9-5/8"Csg Point Value Value Density(ppg) 10.0- 10.5 ` Density(ppg) 9.6- 10.0 Plastic Viscostiy <23.0 Funnel Viscosity (CP) 45 - 60 (seconds) Yield Point 20-25 Plastic Viscostiy 12 - 18 (lb/100 st) (CP) HTHP Fluid loss Yield Point (ml/30 min @ <5.0 (lb/100 st) 18-24 200psi& 100°F API Filtrate Oil/Water Ratio 75/25 (cc/30 min)) 4 - 6 Electrical 650-900 Chlorides(mg/I) <500 Stability pH 9.0- 10.0 MBT <18.0 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9)for an exploratory or stratigraphic test well,a tabulation setting out the depths of predicted abnormally geo pressured strata as required by 20 AAC 25,033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 101215 OP21-WW01 PERMIT Document.doc Page 6 of 9 Printed:15-Apr-13 •Eno tr4uirn Application for Permit to Drill Well OP22-WWO3 Saved: 15-Apr-13 10.Seismic Analysis Requirements of 20 AAC 25.005(c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already do file with the commission and identified in the application: (10)for an exploratory or stratigraphic test well,a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11.Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11)for a well drilled from an offshore platform, mobile bottom-founded structure,jack-up rig, or floating drilling vessel,an analysis of seabed conditions as required by 20 MC 25.061(6); Not applicable: Application is not for an offshore well. 12.Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12)evidence showing that the requirements of 20 AAC 25.025{Bonding}have been met; Evidence of bonding for ENI is on file with the Commission. 13.Proposed Drilling Program � Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 5, Well Schematic. 1. Move in/ rig up Nabors 245E. 2. RU Diverter and test as per AOGCC requirements (notify Inspectors) 3. Spud and directionally drill 16"hole to casing point at as per directional plan. Run Gyro and MWD tools as required for directional monitoring. 4. Run and cement 13-3/8", 68#, L80, BTC casing to surface. Pump cement and displace with mud, land casing hanger and bump plug. 5. Install and test wellhead to 5000 P I. 6. Nipple up 13-5/8"5K BOP and t st to 5000 PSI. Notify AOGCC 24 hrs before test. 7. Pressure test casing to 2500 per AOGCC regulations. Record results. 8. PU 12-1/4"bit and directio al drilling assembly with MWD, LWD and PWD. 9. Drill out cement and be een 20'and 50' of new hole. Perform formation integrity test, recording results. 10. Directionally drill to- -5/8"casing point per directional plan. Pull out of hole backreaming to the surface casing shoe. / 11. Install 9-5/8"casing rams in the BOP and test to 5000 PSI. 101215 OP21-WW01 PERMIT Document.doc Page 7 of 9 Printed: 15-Apr-13 En' •�N c- trolleulr1 Application for Permit to Drill Well OP22-WW03 Saved: 15-Apr-13 12. Run and cement 9-5/8", 40# L80, casing. Pump cement and displace with mud, land -sing hanger and bump plug. 13. Install 9-5/8"packoff and test to 5000 psi. 14. Flush 13-3/8"x 9-5/8"annulus with diesel freeze protect. 15. Pressure test casing to 3000 psi per AOGCC regulations. Record results. 16. PU 8-1/2"bit and directional drilling assembly including MWD, LWD, PWD/RIH, clean out cement to top of float equipment. 17. Drill out cement and between 20'and 50' of new hole. Perform form ion integrity test, recording results. 18. Directionally drill 8-1/2" hole to TD as per directional plan. Pull o of hole backreaming to casing shoe. 19. Run and cement 7", 26# 13CrL80, Vam Top Liner. / 20. Liner hanger to be set with 200' Liner lap inside the 9-5/8"irmediate casing. POOH laying down DP as required. 21. Test casing and liner to 3000 psi and record. 22. Rig up E-line and perforate. 23. PU 4 1/2"completion string as required and RIH to epth. Land tubing seals. Pressure test IA to 1500 PSI and record. Set BPV 24. Nipple down BOP, nipple up tree and test. Pull/BPV. 25. Freeze protect well with diesel through she9/out valve in tubing. 26. Set BPV and move rig off. 27. Rig up wire line unit. Pull BPV. 28. Set dummy valve in mandrel. 29. Place well on production. • ENI requests that tFte AOGCC waive surface safety valve requirements per 20 MC 25.265. (c). (1). • The Vetco horizontal wellhead utilized physically prevents locating the SSV in the vertical run of the tree as there is no vertical tree on this wellhead. • Wellhead/schematics should be on file with the AOGCC. 101215 OP21-WW01 PERMIT Document.doc Page 8 of 9 Printed: 15-Apr-13 Arn Enil - troHeui Application for Permit to Drill Well OP22-WW03 Saved: 15-Apr-13 14.Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 MC 25.080 for an annular disposal operation in the well; Waste fluids generated during the drilling process will be disposed of by injection down an Oliktok Point Class I disposal well or by hauling the fluids to the Prudhoe Bay Grind and Inject Facility. All cuttings generated will be disposed of either down an Oliktok Point Class I grind and inject disposal well or hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well. 15.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 BOP and Diverter Configuration Attachment 4 Cement Loads and CemCADE Summary Attachment 5 Well Schematic Attachment 6 Formation Integrity And Leak Off Test Procedure Attachment 7 Surface Platt 101215 OP21-WW01 PERMIT Document.doc Page 9 of 9 Printed: 15-Apr-13 — ..EVISION: us opereing WELL OP22-WW03 Drilling Procedure OP22-WW03 Oliktok Point Conductor slot #22 Water Well Producer (Ivishak) Reservoir location #3 Nikaitchuq Project Drilling and Completion Wellplan Page 1 of 45 04/15/13 fiRiet VISION: eno us operating WELL OP22-WW03 Table of Contents WELL PLAN SUMMARY 3 MIRU SECTION 6 SURFACE SECTION 7 Surface Drilling 8 Surface Casing 10 Surface Cementing 13 12-1/4" INTERMEDIATE HOLE SECTION 15 Pick Up Intermediate Drilling Assembly 16 Intermediate Drilling 18 Intermediate Casing 19 Intermediate Cementing 22 8-1/2" PRODUCTION HOLE SECTION 24 Pick Production Drilling Assembly 25 Production Drilling 27 Production Liner 28 Production Liner Cementing 31 COMPLETION SECTION 33 Running Procedures. 36 ATTACHMENTS 38 Recommended Drilling Practices 39 Health, Safety & Environment 40 Safety Meeting Topics 41 Well Shut In Procedure While Running Production Tubing 43 Conductor Broach—Contingency Cementing Plan 44 TAM PORT COLLAR Utilization Decision Tree 45 Drilling and Completion Wellplan Page 2 of 45 04/15/13 !POI .REVISION: o 2n0 �S op reing 1 WELL OP22-WW03 WELL PLAN SUMMARY Rig: Nabors 245E Type of Well: Water Producer Well Design: 13-3/8"surf.x 9-5/8"inter.x 7"liner Casing Setting Methods 13-3/8"68#L80 BTC Conventional: Set on Mandrel Hanger. 9-5/8" 40#L80 H563/47# 13CrL80 VamTop Conventional: Set on Mandrel Hanger. 7" 26#/29.7# 13CrL80 VamTop Conventional: 9-5/8"x 7"Flexlock Liner hanger/ZXP Liner Top Packer Close Approach and Offset Well Interception Risks It is important to stay as close as practical to the planned directional program. The directional program and a summary of close approaches can be found in the attachments. These close approaches will be in conformance with the minimum well separation criteria detailed by the Drilling Anti-Collision Analysis and Close Approach Guidelines. It is the responsibility of the Directional Driller and the Drilling Supervisor to ensure that the directional plan is executed as planned,that the position of the well as it is drilled is monitored on an anti-collision diagram and that no tolerance line for close approach wells is crossed. It is important that the well bore remains close to the planned well path as any major deviations from the profile may adversely affect the ability to drill future wells and still adhere to the current close crossing guidelines. Survey Program &Procedures Take MWD surveys as frequently as needed,but no less than every 100 ft. Carefully review the anticipated close crossings with existing wellbores and future well paths. Make sure that directional drillers are aware of all drilling close crossing issues,hard lines and no-go lines. If a no-go or hard line has been or will be crossed,stop drilling immediately and contact the Drilling Superintendent to discuss options. Mud Logging Program Refer to the Geological Mud Logging Procedure document. Drilling and Completion Wellplan Page 3 of 45 04/15/13 iwilit VISION: ena us opc rr1Cing 1 WELL OP22-WW03 viol eni EnI Petroleum Oliktok Point Nikaitchuq Field OP22-WW03(P4) North Slope - Alaska DIR/LWD FORM DEPTH HOLE CASING MUD INFO WL Logging MWD MD TVD SIZE SPECS Hazards Cement to Surface 20" Hole Angle n X-65 0° 20"Conductor Shoe 160' 160' ° WA Welded/Driven WA 0 Surface Csg Dr/PVVD v e 13-3/8" -a m 68 lbs/ft Wellbore Stability Mid Motor c L-80,BTC 9.2-9.6 ppg Lost Circulation B/F<?rmafrost 1,800' 1,789' Hole Cleaning w KOP.250' Surface Tail Cement 3,491' 3,286' Hole Angle - - 40 13-3/8"Casing Point 3,991' 3,672' 6111 16" 50°F SPUD Dr/PiND Inter.Casing Wellbore Stability 9-5/8" Lost Circulation Motor 40 lbs/ft 9.6_- ppg Hole Cleaning L-80,Hydrill 563 • 9-5/8" 47 lbs/ft TOC 6,468' 5,586' 13Cr,Vam Top IN i in O -2 e N a a TOL 7,468' 6,381' Hole Angle ggli 22 9-5/8"Casing Point 7,668' 6,563' 1 12-1/4" 95°F MOBM Jurassic Wellbore Stability Lost Circulation production Liner Hole Cleaning Sag D ib 7" •-o 26 lbs/ft •Motor T/',Ashok E 0 45 13Cr,yam Top R3 W.0-'D 5 ppg a --- a a G) B/Nishaq 7"Liner 4 Hole Angle 10 Proposed TD 10,855' 9,695' 8-1/2" 210°F MOBM Drilling and Completion Wellplan Page 4 of 45 04/15/13 ..EVISION: en us operahnS WELL OP22-WW03 OBJECTIVES: 1. Drill the water source well at or under AFE cost and time.Perform work in a safe and professional manner meeting all ENI Petroleum Health,Safety,and Environmental requirements. 2. Land 13-3/8"Surface Casing Below Schrader Bluff Formation. 3. Top set Kuparuk with 9-5/8"Casing. 4. TD well with LWD below the base of the Ivishak within 500'radius. 5.Water Source Producer. Target Rate:>5000 BWPD Drilling and Completion Wellplan Page 5 of 45 04/15/13 VISION: o 2rr110 �s operrafin9 WELL OP22-WW03 MIRU SECTION OD WT Grade Conn. ID(in) Collapse Burst Tensile Yield (in) (PPt) Type (psi) (psi) (kips) 20 178.89 X-65 Welded 18.25 3240 4980 3417 1. Move in and Rig up on Conductor#22. 2. Confirm that the identification markings on the conductor match the planned surface location with the "as-built survey." If identification markings are not present on the conductor, contact the Drilling Supt. prior to moving the rig onto the well. D. Each conductor is to be marked with a common pad elevation survey mark by the surveyors D. Surveyors to also mark each conductor with a degree of angle to set each horizontal wing valve 3. Move in and rig up. Record move distance and rig floor distance to pad and sea level in WellView and on IADC reports. Initiate a Rig Elevation Record and place it on the N drive. • Ensure all concerned parties(Directional Drillers,MWD Operators,and Geologists)are using the same rig floor elevation. 4. Post drilling permit in the rig office and company office. 5. Nipple up the Vetco Gray landing ring,Vetco starter head. ➢ Notify AOGCC prior to spudding well and 24 hours prior to performing diverter function test D. Test lower seals of the starting head to 80%collapse of the pipe,but do not exceed 500 PSI. ➢ Confirm proper signage is on the pad indicating the rig has diverter equipment rigged up and to restrict access to diverter line area D. Place drip berm under the end of diverter line 6. Verify that two 3"threaded nipples have been welded on the conductor on opposite sides angled up at 45°. Include ball valves and Cam-Lock male fittings on each nipple. Top of the nipple to be no higher than 22"below the cut on the conductor(measurement to be verified with Well Containment Shelter in place). Ensure threaded ball valves can be installed without running into the OD of the diverter head. Nipples are to be used as follows: D. Assist in washing out surface casing hanger on cement jobs D. Take returns to Vac trucks while cementing D. Provide access to annulus for top job through small diameter tubing 7. RU Diverter and test as per AOGCC ➢ Inform AOGCC 24hrs prior to diverter test 8. Build spud mud. Drilling and Completion Wellplan Page 6 of 45 04/15/13 1 ..c VISION: eno us op rahnc WELL OP22-WW03 SURFACE SECTION Surface Formation Markers: (all depths Nabors 245: Schlumberger Plan (P4) OP22-WW03) Formation Tops Measured Depth,ft True Vertical Depth,ft Comments SV-4 717 715 SV-3 966 958 SV-2 1228 1217 SV-1 1711 1700 B/Permafrost 1800 1789 Ugnu Top(UG4) 2033 2021 UG-2 Coal Bed Marker 2519 2489 Lower Ugnu 3299 3138 Schrader Bluff Top 3552 3333 N Sequence Top 3585 3385 N Top 3633 3396 N Bottom 3672 3426 N Sequence Base 3724 3466 OA Top 3800 3525 OA-2 Top 3811 3533 OA-3 Top 3822 3541 OA-4 Top 3839 3555 Canning 3848 3561 13 3/8"casing point 3991 3672 13 3 4 HRZ Top 2012 7558 6461 U Kalubik 7637 6534 9 5/8"casing point 7668 6563 9 5/8"ICP Kalubik Marker 2012 7742 6632 Kuparuk Marker 2012 7868 6752 LCU 2012 7939 6821 Sag-D 2012 9583 8440 Sag-C 2012 9616 8473 Sag-B 2012 9629 8485 Shublik 2012 9687 8543 Ivishak 2012 9921 8773 Kavik 2012 10604 9446 TD/7"Casing Point 10855 9695 Drilling and Completion Wellplan Page 7 of 45 04/15/13 111,* ;VISION: • o 2n0 us operating WELL OP22-WW03 Surface Close Approach Wells NOTE: It is the responsibility of the Directional Driller and the Drilling Supervisor to ensure that the directional plan is executed as planned,that the position of the well as it is drilled is monitored on an anti-collision diagram and that no tolerance line for close approach wells is crossed. Surface Mud Program: Density Viscosity Fluid Interval Depth (PPg) (seconds) YP Loss PH 120'—1900' 8.8-9.2 250 35-45 <8 9.0—9.5 Surface: 1900'—3991' 9.2—9.6 150-200 30-35 <6 9.0—9.5 Surface Logging/Formation Evaluation Program: Surface: MWD Directional/PWD/MVC LWD GR/Resistivity Surface Drill Pipe Pipe WT Grade Conn. Tool Tool Body Make Up Joint Body DP Tensile (ppJ) type Joint Joint ID(in) Torque Torsion Torsional capacity Capacity OD ID(in) (ft.lbs) al Yield Yield w/conn. (laps) (in) (ft lbs) (ft.lbs) (gal/ft) 5"DP 19.5 S-135 NC50 6-5/8 3-1/4 4.276 26,800 51,700 74,100 .726 712 5"HWDP 49.5 Surface Drilling Surface Hole Notes: • The area around the conductor should be continuously monitored during drilling,circulating,and cementing operations. If broaching occurs,stop drilling immediately. Contact the AOGCC field inspector and the Drilling Superintendent and inform them of the broach. The Conductor Broach Procedure will then be implemented. • Efforts should be made to minimize high doglegs in surface hole. • Prior to spud,a safety meeting will be held with the rig crews to discuss open hole drilling procedures. Suggested topics include: • Conductor broaching operations and contingencies • Well control procedures and rig evacuation procedures with a diverter • Flow rates and hole cleaning • Ported float valves are required in all hole sections Drilling and Completion Wellplan Page 8 of 45 04/15/13 'VISION: o 2n uis operating WELL OP22-WW03 1. Pick up and drift all DP,HWDP,and DC's for surface section to confirm free of debris. 2. PU BHA(Include UBHO for Single shot E-line Gyro if MWD surveys are not clean initially)for directionally drilling to Surface Casing point with one BHA Directionally drill surface hole: ➢ Drilling Parameters: • 650-800 GPM • Lower flow rates of 450-600 GPM will help avoid anti-collision boundaries by minimizing hole washout and optimize dog leg capability in the build section • RPM:40-80 RPM ➢ Avoid anti-collision boundaries ➢ Take MWD surveys as frequently as needed. Carefully review the anticipated close crossings with existing wellbores. Make sure that directional drillers are aware of all drilling close crossing issues,hardlines and no-go lines. If a no-go or hardline has been or will be crossed,stop drilline immediately and contact the Drilling Superintendent to discuss options. 4. Hole conditions will always determine final mud properties. ➢ Watch returns closely for signs of gas when near the base of the permafrost and circulate out all gas-cut mud before continuing to drill. • Due to expected gas hydrates,keep mud as cool as possible(cold lake water). • Control drill at 100 to 120 fph through any troublesome zone so the hole does not load-up with gas cut mud. • Check and report trip gas. • Have 2 ppb Lecithin on location prior to drilling below the permafrost to minimize the effects of hydrates on the mud if hydrates are encountered. ➢ Consider adding 0.5%Drilzone for screen blinding in shallow intervals right below the conductor. 5. Surface casine point: ➢ Land in good shale found at 3660'TVDSS BELOW SCHRADER BLUFF OA SANDS ➢ Drill the hole to fit casing,if possible,to reduce pup joints in the string. Leave at least 15' rathole. 6. Backream out of the hole at surface casine point: ➢ Circulate until shakers are clean(+/-3 to 5 bottoms up per K&M model)while backreaming one(1)stand for every bottoms up during the cleanup cycle. • 800 GPM or higher • 80 RPM or higher ➢ Backream to the HWDP • 800 GPM or higher • 80 RPM or higher • Pull 5-10 feet per minute • Decrease backreaming speed as torque and pump pressure dictate. Drilling and Completion Wellplan Page 9 of 45 04/15/13 o ;VISION: ono us op rainc IWELL OP22-WW03 • NOTE: once backreaming in the open hole has been started,do not stop backreaming until the HWDP. Do not attempt to pull out on elevators once backreaming has started. • Expect+/-100%increase in cuttings from 1800'-600'. • Lesson Learned from:While backreaming out of the hole in the transition from horizontal to vertical, have the shaker box sub-guns running or ready to run at the first sign of clay balling. Have the flow line jets hooked up and ready to activate to assist flowline cleaning. Pitwatchers should notify the rig floor at first clay show on the screen beds. • If shakers/mud return system become overloaded and flow rate is cut to handle the issue,then do not continue to Backream until the parameters are brought back to full backreaming rate r Once the HWDP is reached,circulate until hole is clean(shakers clean) 7. Pull and lay down BHA. 8. Perform a dummy hanger run before running casing. Surface Casing Program: (all depths feet RKB) Top Btm Hole Size CsODbg Wt/Ft Grade Conn. Length MD/TVD MD/TVD 16" 13-3/8" 68# L-80 BTC 4023' SURF 3991'/3672' Surface Casing& Liner OD WT Conn. Cplg OD Collapse Burst Tensile Yield (in) (PPf) Grade Type (in) ID(in) Drift(in) (psi) (psi) (kips) 13-3/8 68 L-80 BTC 14.375 12.415 12.259 1950 3450 1069 Surface Casing Connection Make Up Torque (ft.lbs) OD WT Opt. (in) (pp}) Grade Conn.Type Make Up Torque 13-3/8 68 L-80 BTC Triangle Surface Casing Casing Running Notes a. Perform dummy run prior to running casing b. Surface casing will be landed on hanger,emergency casing slips will be used as contingency. c. Rig up and utilize a fill up tool for the casing job. d. Break circulation before reaching the base of the permafrost if casing run indicates poor hole conditions. Drilling and Completion Wellplan Page 10 of 45 04/15/13 ��c VISION: en(' us operating WELL OP22-WW03 e. Any packing off while running casing,and especially while above the base permafrost,should be treated as a very serious problem if major returns are lost. It is preferable to pull casing out until circulation can be re- established rather than risk not getting cement to surface. Contact the Drilling Superintendent if the casing packs off high for discussion of the options. f. Have Vetco representative verify the correct casing hanger is on location prior to the point at which it is needed. g. Torque values for the BTC casing are determined at the rig by making up the connection to the make-up mark (base of triangle). Record torque values for the first 10 connections made up in this manner and average. This average will be used as the make up torque for the remainder of the string. Running Procedure 1. Inspect and drift all surface casing to 12.259". 2. Break circulation before reaching the base of the permafrost if casing run indicates poor hole conditions. 3. While RIH with the Casing: D obtain SO Weights as per K&M D obtain PU Weights as per K&M 4. Run the surface casing as follows: Surface Casing Running Order 1 Float shoe Bakerlock 2 2 joints 13-3/8"68#L-80 BTC casing Bakerlock 3 Float Collar Bakerlock 4 13-3/8"68#L-80 BTC casing **• TAM BTC port collar+/-1000 ft Only run if losses are expected 6 13-3/8"68#L-80 BTC casing to hanger 7 Vetco Gray 13-3/8"mandrel hanger 13-3/8"landing joint Slick landing joint if not 8 running the TAM port collar **If TAM port collar is run: • A landing joint,which has a connection that can be broken below the rotary table,will need to be run to allow for running the drill pipe inside the 13-3/8"without needing a false rotary table. Also,the drill pipe running tool needs to be on location and stood back in the derrick ready to run in case the TAM port collar needs to be opened to circulate cement to surface. • If decision to run is at the last minute,ensure the additional footage of the port collar plus handling pup will allow for sufficient rathole below the surface casing shoe. Surface Centralizers +/- 18 13-3/8"Tandem Rise Weatherford Drilling and Completion Wellplan Page 11 of 45 04/15/13 roc - • VISION: • eni us °pealing WELL OP22-WW03 Surface Centralizer Placement 10' oa 13-3/8"x 16"Tandem Rise Centralizers Collar • 2 at 5'& 8' above Float shoe on stop collars,using stop buttons or stop collars. • No centralization on collar of 1s`joint. • 1 at 10' above Float Collar,using stop buttons or stop collars. • From 3rd joint through tail slurry(500'tail slurry), 1 centralizer per joint run on collars. Do not allow centralizer to float between collars. • 2 on 13-3/8"casing collars,inside conductor @ TD so csg can be reciprocated. A Drilling and Completion Wellplan Page 12 of 45 04/15/13 /111* itd VISION: o 2nd us °p r-aCring 1 WELL OP22-WW03 Surface Cementing Surface Cementing Program Section Casing Size/Depth Type of Fluid/Cmt Volume Properties Mudpush II 100 bbls Densityl0.1 ppg Lead Slurry 564 bbls Density 10.7 ppg Surface 13-3/8" at 4075' MD (ArcticSet Lite) (1409 sacks) Yield 2.25 ft 3/sk Tail Slurry 63 bbls Density 12.5 ppg (Liail @ 3 (228 sacks) Yield 1.55 ft3/sk Top of Tail @ 3499 1' MD Casing Cementing Notes a. Obtain and review the Test Report from the cementing lab on the job blend prior to pumping the cement. DO NOT pump cement if there are any doubts as to cement quality,quantities,pumping times,or thickening times. b. Use split landing joint if TAM port collar is utilized. It will need to be opened by running tool on drill pipe and this will allow using standard rotary slips. Cementing Procedure 1. After reaching bottom, rig up and circulate with casing on bottom at 5 bpm, if possible, without losing returns. Reduce mud viscosity prior to pumping cement if necessary. D To help ensure good cement to surface after running the casing, and if practical for existing hole conditions, condition mud to YP < 20 lb/100ft2 prior to cementing the casing but after the casing is on bottom. Have adequate supply of cold lake water on hand to ensure the desired rheologies can be achieved. 2. Rig up to cement and pressure test cement lines. 3. Pump Mud Push Spacer. Shut down and drop bottom plug. 4. Pump cement job per the attached Schlumberger cementing plan. Cement volumes are based on 35%excess below the Permafrost and 200%excess in the Permafrost. D If necessary,verify that the TAM Tech has located the proper crossovers to combo running tool. D If necessary,rack TAM running tool in derrick and ready to run. 5. Report the number of bbls of cement returned to surface: D Task one person to be in charge of monitoring for cement returns and volume of cement returns D Recommend that a dye or small amount of celloflake be added to the wash or spacer to give an indication of top of cement. 6. Drop top plug after the tail slurry. 7. Pump displacement at 8.5 bpm maximum. 8. Drop circulation rate 3 BPM for last 20 bbls of displacement prior to bumping plug. Drilling and Completion Wellplan Page 13 of 45 04/15/13 fo VISION: • o 2nd �s ope1r t n9 I WELL OP22-WW03 9. Pump until the plug bumps and then pressure up to 500 psi above Final Circulating Pressure(FCP)to ensure the plug has landed. If floats do not hold,maintain FCP on casing and shut in cement head for a minimum of 6 hours before rechecking. > Do not over displace the cement(Pump NO MORE than '%the shoe joint volume). > Watch for signs of packing-off during pumping operations and closely monitor the cellar area for mud or cement returns around the conductor. ➢ In the event cement is not circulated to surface,pump the calculated volumes and prepare to open the TAM Port Collar(if applicable)for a secondary cement job. D AOGCC and Drilling Superintendent must be contacted prior to beginning top job. Do not proceed with top job without AOGCC approval. 10. Drain and wash cement from riser. Nipple down riser and flush all lines. 11. Nipple up Vetco Gray Well Head,orienting the well head valves as indicated on the conductor markings. ➢ If there is any doubt about the proper orientation,call the Drilling Superintendent. ➢ Ensure that the seal between the casing hanger and well head is tested to 5,000 psi for 10 minutes. ➢ Measure the distance from the rig floor to the top flange of the well head and record on the IADC report and in WellView. Complete the Rig Elevation Record and place it in the electronic well folder. 12. Nipple up the 13-5/8"5M BOP stack and test per the AOGCC Permit to Drill(attached) > Test rams and choke manifold components to 5000 psi high/250 psi low > Test annular preventer to 2500 psi high/250 psi low ➢ Do not test BOPE against casing. D Notify AOGCC 24 hours prior to performing BOP test. • PERMIT TO DRILL BOP testing frequency: Every 14 days unless notified otherwise by AOGCC Drilling and Completion Wellplan Page 14 of 45 04/15/13 rigTiii itd VISION: o 2nd us operahng WELL OP22-WW03 12-1/4" INTERMEDIATE HOLE SECTION Formation Markers: (all depths Nabors 245: Schlumberger Plan (4) Formation Tops Measured Depth,ft True Vertical Depth,ft Comments SV-4 717 715 SV-3 966 958 SV-2 1228 1217 SV-1 1711 1700 B/Permafrost 1800 1789 Ugnu Top(UG4) 2033 2021 UG-2 Coal Bed Marker 2519 2489 Lower Ugnu 3299 3138 Schrader Bluff Top 3552 3333 N Sequence Top 3585 3385 N Top 3633 3396 N Bottom 3672 3426 N Sequence Base 3724 3466 OA Top 3800 3525 OA-2 Top 3811 3533 OA-3 Top 3822 3541 OA-4 Top 3839 3555 i Canning 3848 3561 13 3/8"camng po: 3991 3672 ii 3/8"SCP HRZ Top 2012 7558 6461 U Kalubiic 7637 6534 9 5/8"casing point 7668 6563 9 5/8"ICP Kalubik Marker 2012 7742 6632 Kuparuk Marker 2012 7868 6752 LCU 2012 7939 6821 Sag-D 2012 9583 8440 Sag-C 2012 9616 8473 Sag-B 2012 9629 8485 Shublik 2012 9687 8543 Ivishak 2012 9921 8773 Kavik 2012 10604 9446 TD/7"Casing Point 10855 9695 TD Drilling and Completion Wellplan Page 15 of 45 04/15'13 los VISION: • en us operahng WELL OP22-WW03 Pick Up Intermediate Drilling Assembly 1. Install wear bushing. Pick up: > 12-1/4"bit • Motor • PWD • GR/RES > Flow rate of 900 GPM > >80 RPM 2. RIH to top of float equipment and pressure test surface casing to 2500 psi for 30 min and record on chart. > Plot Casing Pressure Test on LOT form on N drive. Verify that the test indicates a linear line and that there is no air entrained in the mud. Repeat Casing pressure test if needed. > Note: All BHA trips thru the TAM port collar(if applicable)should be done slowly with slow rotation to avoid accidentally opening port collar. If set-down weight is noted,stop immediately,PU,resume slow rotation and try slacking off through port collar area. 3. Drill out the float collar&shoe. > See Float Equipment and Plugs PDC Bit Drillout Recommendations Attachment 4. Drill 20'-50' of new hole using spud mud. 5. Displace hole to new LSND mud system. 6. Perform Leak Off Test as per AOGCC requirements following the attached LOT Procedure. > PU into casing and perform LOT. > If the pressure continues to rise past 13.0 ppg EMW,shut down and call it a FIT per the FIT Guidelines (attached). > If LOT is unacceptable to drill ahead(less than 11.0 ppg EMW),contact Drilling Superintendent to discuss options. > Plot on LOT form on N drive. Drilling and Completion Wellplan Page 16 of 45 04/15/13 10* 41tVISION: 0 fl us operating WELL OP22-WW03 Intermediate Mud Program:: Interval Depth Density 6 RPM (ppg) Reading Surface Shoe to 200' Prior to HRZ @ 3991'—7558' 9.2-9.5 8-13 7,558' HRZ to TD 7558'—7668' 9.8-9.9 8-13 Intermediate Logging/Formation Evaluation Program: MWD Directional/PWD/MVC LWD GR/Res Intermediate Drill Pipe Tool Tool Make Up Joint Body DP Tensile Pipe WT Grade Conn. Joint Joint Body Torque Torsion Torsional capacity Capacity (P13.1) Type OD ID(in) al Yield Yield w/conn. ID in (in) t' s (ft lbs) (ft.lbs) (gal/ft) (fps) 5"DP 19.5 S-135 NC50 6-5/8 3-1/4 4.276 26,800 51,700 74,100 .726 712 w/G-105 cplg 5"HWDP 49.5 Intermediate Section Notes: a. 6 RPM Reading Shall be in the 12-15 range. b. IF LOSSES ARE ENCOUNTERED NOTIFY DRILLING ENGINEER AND SUPERINTENDENT IMMEDIATELY! c. Carefully track loss volume and parameters if losses are encountered. d. Efforts should be made to minimize high doglegs above the pump tangent(if applicable). e. Shallow test MWD tools. f. Monitor hole conditions carefully. Be alert for early signs of lost circulation and differential sticking. If any of these problems are observed immediately notify the Drilling Supervisor or Toolpusher(attempt to keep the pipe moving and circulation established). Ensure that all team members are communicating with each other on any observed drilling trends and that everyone understands the potential risks. g. Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. h. Keep shut down times to a minimum during connections. i. Swab/Surge: Make"easy on,easy off'slips a standard practice j. Control the ROP if necessary to maintain good hole cleaning k. Ensure the Top Drive Torque Limit is set below the lowest make up torque in the string. Do not run the risk of further make up downhole while drilling. J Drilling and Completion Wellplan Page 17 of 45 04/15/13 111* VISION: 0 us operr has 1 WELL OP22-WW03 Intermediate Drilling 1. Directionally Drill 12-1/4"hole to 7668' MD/6563'TVD D Use the following hydraulics/Parameters: • 900 GPM • >80 RPM D See M-I mud program for additional mud properties/concerns in the intermediate hole interval. 2. Penetrate the upper part of the Kalubik Marker in order to land Intermediate casing above the Kuparuk Sand. D Do not Drill into the Kuparuk Formation • Drill the hole to leave minimal footage below the casing shoe without needing pup joints 3. Backream at Intermediate Casing point: D Circulate until shakers are clean as per K&M. • 900 GPM • >80 RPM D POOH on elevators as per K&M to the surface casing shoe. • NOTE: If backreaming is necessary,once backreaming in the open hole has been started,DO NOT stop backreaming until the surface casing shoe. DO NOT attempt to pull out on elevators once backreaming has started. • Circulate until shakers are clean as per K&M model. • 900 GPM • >80 RPM 4. POOH on elevators and lay down BHA Drilling and Completion Wellplan Page 18 of 45 04/15/13 VISION: eno us operating WELL OP22-WW03 Intermediate Casing Program OD WT Conn. Cplg Collapse Burst Tensile (in) (pp� Grade Type OD(in) ID(in) Drift(in) (psi) (psi) Yield(kips) Hydril **Special 9-5/8 40 L80 563 10.625 8.835 Drift 3090 5750 916 8.75 9-5/8 47 13CrL80 TOP 10.396 8.681 8.525 4760 6870 1086 Intermediate Connection Make Up Torque (ft.lbs) OD WT Conn. Min. Opt. Max. Yield Grade Make Up Make Up Make Up (in) (ppI) Type Torque, ft-Ibs Torque Torque Torque 9-5/8 40 L80 H5631 10800 13000 --- 75000 AM 9-5/8 47 13CrL80 TOP 14400 15900 17400 --- Running Method Conventional—Tesco Casing Drive System Set on mandrel hanger Intermediate Casing Interval Notes: a. ANY LOSSES WHILE RUNNING THE 9-5/8"CASING SHALL BE CONSIDERED SERIOUS. NOTIFY DRILLING ENGINEER AND SUPERINTENDENT IMMEDIATELY. b. Ensure proper sized rams are in the lower BOP body and tested prior to running intermediate casing. c. —200' of the 9-5/8"casing string will be 13 Chrome L80. Due to the high CO2 content of the Ivishak water the 7"x 9-5/8"liner top packer will be set through this interval. d. The 4-5 jts. of 9-5/8" 13 Chrome L80 will be run above the shoe track. The shoe track will be of strictly L80 material. e. Utilize Tesco Casing Drive System. Drilling and Completion Wellplan Page 19 of 45 04/15/13 iftmf#41 :VISION: • o 2rnl1 ass operahnS WELL OP22-WW03 Casing Run: 1. Inspect and drift intermediate casing ➢ 40#drift—8.75" ➢ 47#drift—8.525" 2. Ensure 9-5/8"x 12-1/4"Tandem Rise Centralizers are on location 3. Pull wear bushing. Install 9-5/8"rams and test. Pick up and run casing. Casing Running Order 1 Float shoe 9-5/8" Baker-Lock 2 2 joints 9-5/8"40# L80 H563 Baker-Lock 3 Float Collar L-80 Baker-Lock 4 1 jt.9-5/8"40# L80 H563 5 XO,9-5/8"9Cr-L80 VAM TOP box x Hydril 563 pin 6 5 jts. 9-5/8"47# 13Cr VAM TOP 200' chrome casing window for landing future chrome liner and hanger 7 XO,9-5/8"9Cr-L80 Hydril 563 box x VAM TOP pin 8 9-5/8"40# L80 H563 casing to casing hanger 9 Vetco Gray 9-5/8"mandrel hanger 9-5/8"landing joint Slick landing joint for reciprocation purposes Centralizers +/-38 9-5/8"x 12-1/4" Tandem Rise—Around Collars I Weatherford 4. Monitor running speeds to minimize surge and swab pressures while running in or picking up off slips. ➢ Break circulation at surface casing shoe,then break circulation every+/-2,000'MD and check flow through floats. Circulate bottoms up each time. 5. While RIH with the Casing: ➢ obtain SO Wei2hts as per K&M ➢ obtain PU Wei2hts as per K&M 6. Run the casing string to bottom. Establish circulation rate and pressure while pumping at least 1-2 bottoms up to condition hole. Reciprocate casing while circulating and cementing. 7. If needed,circulate and thin mud to properties slightly as outlined in CemCADE and Mud plan summary after running casing to bottom and prior to pumping cement. ➢ YP= 15-18 Drilling and Completion Wellplan Page 20 of 45 04/15/13 .. VISION: • o 2r110 us operating 1 WELL OP22-WW03 Intermediate .� Centralizer Placement 10' Imoat Collar 9-5/8" x 12-1/4"Tandem Rise Centralizers Run 1 Tandem Rise • On Stop collar 5' & 8' above Float shoe. • No centralizer on next joint • On Stop collar 10' above Float Collar. • From 3rd joint to+/-1000'above the shoe- 1 centralizer placed over collars A 8' 5' Drilling and Completion Wellplan Page 21 of 45 04/15/13 VISION: o 2nd �s operrarins WELL OP22-WW03 Intermediate Cementing Program Section Casing Size/Depth Type of Fluid/Cmt Volume Properties Intermediate 9-5/8"at 7668' Mudpush II 50 bbls Density 12.0 ppg Class"G" 107 bbls Density 15.8 ppg Top of Cement @ 6468' MD (516 sacks) Yield 1.16 ft3/sk Intermediate Cementing Intermediate Cementing Notes: a. Obtain and review the Test Report from cementing lab on the job blend prior to pumping the cement. DO NOT pump cement if there are any doubts as to cement quality,quantities,pumping times,or thickening times. If need be,confer with Drilling Superintendent. b. While circulating and cementing,reciprocate the entire casing string a minimum of 30'as long as possible. Continue reciprocating 30'until the slack off weight starts to decrease. At that point,continue to reciprocate with progressively shorter strokes in preparation for total loss of string weight. The goal is to reciprocate the greatest distance for as long as possible with cement in the annulus. c. Do not over displace the cement(no more than Y2 the shoe joint volume). d. 6 hours after the cement job,rig up to flush and freeze protect the surface by intermediate annulus. 1. Batch mix cement. Test cement lines and pump cement job as per the attached Schlumberger program. Cement volume is based on 50%excess and on at least 1000'of annular fill above the shoe. Refer to attached cement detail sheet for volumes. D Discuss adding celloflake to the MudPush if lost circulation is a concern. D Displace cement with rig pumps. Ensure that the cement unit is manifolded so that the cementers can take over displacement of the slurry if there should be a failure of the rig pumps. D Pump cement at 5 bpm and displace with 8 bpm if possible without losing returns. Slow rate to 3 bpm during last+/-30 bbls prior to bumping plug. 2. Land casing on mandrel hanger when 30-50 bbls left in displacement or if hole starts to become sticky. 3. When the plug bumps,pressure the casing to 500 psi over the final displacement pressure and ensure that the string is holding pressure. Notify the Drilling Superintendent if the string will not hold pressure. Bleed off pressure and ensure the floats are holding. If the floats leak,pressure back up to final displacement pressure and shut in cementing head. 4. Install Vetco 9-5/8"packoff assembly. 5. Pressure test packoff per Vetco Gray. D Do not exceed 80%of intermediate casing collapse D Record test on IADC report and in WellView 6. Install rams and test per the AOGCC Permit to Drill(attached) Drilling and Completion Wellplan Page 22 of 45 04/15/13 c .. VISION: en us opealing WELL OP22-WW03 D Test rams and choke manifold components to 5000 psi high/250 psi low D Test annular preventer to 2500 psi high/250 psi low D Do not test BOPE against casing. ➢ Notify AOGCC 24 hours prior to performing BOP test. • PERMIT TO DRILL requires BOP testing frequency every 14 days unless notified otherwise by AOGCC 7. Install wear bushing. 8. Freeze protect 13-3/8"x 9-5/8"annulus to the surface casing shoe. D Cement Consistency of 50 Bc(Bingham consistency)is not pumpable. 50 Bc is achieved roughly 4 hrs after mixing cement and starting downhole. ➢ Pressure limitations are as follows: 80%of surface burst or 80%of intermediate collapse,whichever is less. • 2472 PSI is 80%Intermediate casing collapse(9-5/8"40#L-80) ➢ Freeze protect the surface by intermediate annulus with diesel at 1-1/2 to 3 BPM. Pump enough diesel to flush and freeze protect to the surface casing shoe. f6 Drilling and Completion Wellplan Page 23 of 45 04/15/13 ;VISION: ern10 us operrahnc WELL OP22-WW03 8-1/2" PRODUCTION HOLE SECTION Formation Markers: (all depths Nabors 245: Schlumberger Plan (5) Formation Tops Measured Depth,ft True Vertical Depth,ft Comments SV-4 717 715 SV-3 966 958 SV-2 1228 1217 SV-1 1711 1700 B/Permafrost 1800 1789 Ugnu Top(UG4) 2033 2021 UG-2 Coal Bed Marker 2519 2489 Lower Ugnu 3299 3138 Schrader Bluff Top 3552 3333 N Sequence Top 3585 3385 N Top 3633 3396 N Bottom 3672 3426 N Sequence Base 3724 3466 OA Top 3800 3525 OA-2 Top 3811 3533 OA-3 Top 3822 3541 OA-4 Top 3839 3555 Canning 3848 3561 13 3/8"casing point 3991 3672 13 3/8"SCP HRZ Top 2012 7558 6461 U Kalubilc 7637 6534 9 5/8"casing point 7668 6563 9 5/8"ICP Kalubik Marker 2012 7742 6632 Kuparuk Marker 2012 7868 6752 LCU 2012 7939 6821 Sag-D 2012 9583 8440 Sag-C 2012 9616 8473 Sag-B 2012 9629 8485 Shublik 2012 9687 8543 Ivishak 2012 9921 8773 Kavik 2012 10604 9446 TD/7"Casing Point 10855 9695 TD Drilling and Completion Wellplan Page 24 of 45 04/15/13 ff 411 VISION: o 2rn10 us op rrrahng WELL OP22-WW03 Pick Production Drilling Assembly 1. PU 8-1/2"BHA Assembly D 8-1/2"PDC D 675 PDM 1.5°ABH D 650 gpm D >80 RPM 2. RIH to the float equipment. ➢ Pressure test the casing to 3000 psi for 30 min and record on chart(AOGCC required casing integrity test). D Plot Casing Pressure Test on the Pressure LOT form. • N:\Alaska\Nikaitchuq\Drilling and Wells\Oliktok Point\OP21-WW01\01 Operational Data\BOP-CSG-FIT- LOT Tests Oil Based Mud Fluid Displacement 3. Displace casing to new Oil Based Reservoir Drilling Fluid D Do not contaminate new OBM in rig pits > Displace old water based fluid to trucks or exterior tanks for disposal 4. Drill out the float collar&shoe. > See Float Equipment and Plugs PDC Bit Drillout Recommendations Attachment 5. Drill 20'-50' of new hole using the Oil Based Reservoir Drill-In fluid. F I 6. Perform Leak Off Test as per AOGCC requirements following the attached LOT Procedure. > PU into casing and perform LOT. > If the pressure continues to rise past 13.0 ppg EMW,shut down and call it a FIT per the FIT Guidelines (attached). D If LOT is unacceptable to drill ahead(less than 12.0 EMW contact Drilling Superintendent to discuss P ( ppg ), g P options. > Do not pump more than 1/2 bbl after leak off is determined. There is no need to pump more than 1/2 bbl into the leak off and extend the fracture. D Plot on LOT form in N drive Drilling and Completion Wellplan Page 25 of 45 04/15/13 foitir—A6 VISION: • • o 2rn1 us operra fine 1 WELL OP22-WW03 Production Mud Program: Interval Depth Density HTHP FL OWR ES (ppg) (ml/30min) • Production 7668'—10855' 10.5—11.0 <5.0 60:40 to 70:30 >600 Production Logging/Formation Evaluation Program: Production: MWD Directional/PWD/MVC LWD GR/RES/SONIC(Memory) Production Drill Pipe Pipe WT Grade Conn. Tool Tool Body Make Up Joint Body DP Tensile (ppi7 type Joint Joint ID(in) Torque Torsion Torsional capacity Capacity OD ID(in) (ft.lbs) al Yield Yield w/conn. (laps) (in) (ft lbs) (ft.lbs) (gal/ft) 5"DP 19.5 S-135 NC50 6-5/8 3-1/4 4.276 26,800 51,700 74,100 .726 712 w/G-105 cplg 5"HWDP 49.5 Production Section Notes: a. Use torque and drag data and MI fluids hole cleaning model to monitor hole cleaning and predict ECD's based on ROP. b. Monitor returns and PWD data. Back off pump rate if lost returns are seen. Refer to the LCM decision tree prior to pumping any LCM pills. c. Monitor hole conditions carefully. Be alert for early signs of lost circulation and differential sticking. If any of these problems are observed immediately notify the Drilling Supervisor or Toolpusher(attempt to keep the pipe moving and circulation established). Ensure that all team members are communicating with each other on any observed drilling trends and that everyone understands the potential risks. d. Shallow test MWD tools. e. Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. f. Keep shut down times to a minimum during connections. When surveying in this hole section reciprocate the pipe slowly while the survey is transmitted uphole. Keep the pipe rotating whenever possible. g. Ensure the Top Drive Torque Limit is set below the lowest make up torque in the string. Do not run the risk of further make up to a connection while drilling. h. Ensure that torque and drag data recorded by drillers at each connection is transmitted to the Drilling Engineer each day. A Driller's data collection sheet will be provided by Drilling Engineer. i. Wellsite Geologists will be onsite to identify faults,pick TD,and evaluate logs as they become available. j. Keep logs detailing the effectiveness of any sweeps pumped and report them in Wellview. Drilling and Completion Wellplan Page 26 of 45 04/15/13 nC VISION: • en us operating WELL OP22-WW03 li Production Drilling 1. Directionally drill the 8-1/2"hole to TD at 10855' MD/9695' I VD D Maintain sufficient flow rate with maximum pipe rotation as needed to bring mud/well properties in line. D Maintain proper Calcium Carbonate concentration per MI mud plan • Ensure Centrifuges are operating effectively to remove fine drill solids 2. At TD: D Circulate the hole clean as per K&M. D POOH on elevators to the intermediate casing shoe. • If tight hole is encountered and BROOH becomes necessary DO NOT stop BROOH until the intermediate casing shoe is reached. 3. Circulate hole clean as per K&M D Pull out on elevators D Drop rabbit down workstring to be used for landing the liner: • Minimum 2.00"OD rabbit 4. Lay down BHA Drilling and Completion Wellplan Page 27 of 45 04/15/13 VISION: o 2rn10 us operrahng WELL OP22-WW03 Production Liner Production Liner Program (all depths feet RKB) Hole Size CsgO/DTbg Wt/Ft Grade Conn. Length MD/TVD MD/TVD 8-1/2" 7" 26.0 13Cr-80 Vam Top +/-3400 7468'/6381' 10855'/9695' Production Liner OD WT Conn. Cplg OD Collapse Burst Tensile Yield (in) (ppJ) Grade Type (in) ID(in) Drift(in) (psi) (psi) (kips) 7 26.0 13Cr-80 Vam Top 7.565 6.276 6.151 5410 7240 604 Production Liner Connection Make Up Torque (ft-lbs) Min. Opt. Max. Min.Make(in) (p� Grade Conn. Type Torq ep Make Up Make Up Yield ft-lbs Torque Torque Torque 7 26.0 13Cr-80 Vam Top 7470 8300 9130 Production Liner Centralization From To Centralizers/Joint Fixed/Floating Type Shoe Liner 1 every other joint Floating between collars 7"x 8-1/4"Spiro-Glider top (PESI) Liner Running Procedure Notes: • Liner top should be placed a minimum of 200 ft above the intermediate casing shoe. This should be placed in the middle of the 13Cr-80 section of the 9-5/8"casing. • Perform visual inspection,measure and caliper all components prior to running any assembly in the hole. Ensure accurate dimensional data is recorded for all equipment run in the well and recorded in WellView. • Ensure all equipment has been hydraulically and operationally tested. Also ensure all equipment to be run is dimensionally compatible with all other equipment. • Review all setting operations and shear pressures with Baker Oil Tools service hand. • Ensure drill pipe dart and liner wiper plug are correct size and on location. Liner wiper plug should arrive on location installed in the liner hanger assembly • Drop Drill Pipe drift on final run coming out of the hole prior to liner running operations. DP rabbit should be minimum 2.00"OD. • Ensure shoe track is Baker-locked and proper centralization is installed. Drilling and Completion Wellplan Page 28 of 45 04/15/13 If* ..�VISION: o 2rnlo us operreAns WELL OP22-WW03 • If the HRD liner running tool does not release with DP pressure,this can be released with 4,650 ft-lbs of Left Hand torque. Ensure liner make-up torque is sufficient to allow LH release in the event plugs do not bump and liner hanger does not set. See Contingency Plans below for further details. • All liner and hanger components in these assemblies are 13Cr material and require special handling and make up. Refer to equipment vendors and tubing/casing make-up specialists on location for proper makeup,torque-turning and handling of equipment. • Ensure all proper chrome handling and make-up equipment is on location including tong dies,slips,dog collars,lift subs,wrenches,etc. • Use JetLube SealGuard thread compound,or equivalent,on all chrome tubing connections. Implement proper cleaning and doping procedures on all connection make-ups. • Torque ratings for string components: Running String Component Yield Torque(ft-lb) 5" 19.5#NC50 Drill Pipe 51,700 HRD Running Tool 40,000 _ 7"26#Vam Top 9,130 7"29#Vam Top 10,340 • Shear pressures for liner hanger assembly: Item Description Shear Value Shear Range 7"x 9-5/8"FlexLock Hanger Nominal- 2500 psi 15°0%- 2125 psi 15/o+ 2875 psi HRD Running Tool,7" Nominal- 3332 psi 15%- 2832 psi p 4650 mch rel,2 pins 15%+ 3832 psi Plug Holder Bushing Nominal- 900 psi 1500- 765 psi 15%+ 1035 psi Connection/Tubular Data: OD WT Cplg Drift Collapse Burst Tensile (in) (pp� Grade Conn. Type OD(in) ID(in) field (in) (psi) (psi) (kips) 5"DP 19.5# S-135 NC50 6-5/8 3.25 4.276 26,800 51,700 74,100 7 26# 13Cr-L80 Vam Top 7.565 6.276 6.151 5410 7240 604 7 26# 13Cr-L80 Vam Top HT 7.565 6.276 6.151 5410 7240 604 7 29# 13Cr-L80 Vam Top 7.644 6.184 6.059 7030 8160 676 Liner Make-up Torque: OD WT(pill) Grade Conn. Type M/U Torque M/U Torque M/U Torque (in) Min (ft-lb) Optimum (ft-lb) Max(ft-lb) *7 26# 13Cr-L80 Vam Top 7470 8300 9130 *7 26# 13Cr-L80 Vam Top HT 10850 11950 13050 *7 29# 13Cr-L80 Vam Top _ 8460 9400 10340 *Vam Top 26#, Vam Top 29#, and Vam Top HT 26# connections are interchangeable. If there is an overlap in the torque range for the two weights, use a make-up torque that satisfies both weights. If the torque ranges do not overlap,use a make-up torque that does not exceed the maximum make-up torque of the lower range. Drilling and Completion Wellplan Page 29 of 45 04/15/13 11* VISION: en us op rraung WELL OP22-WW03 Procedure: 1. Pick up shoe track joints as outlines above and baker lock connections. Check float equipment to ensure proper functioning. 2. Continue to pick up liner filling every five joints or as required. Follow proper chrome make-up and doping procedures as recommended by GBR/Frank's specialists on location 3. Continue running in hole until the liner hanger is reached. Pick up liner hanger assembly and ensure proper make-up. 4. Fill Liner Tieback Sleeve with "Pal Mix". Be sure mixture is thin enough to travel past the HRD running tool and down to the RS Packoff. Fill to top of Liner Tieback Sleeve and wait 30 minutes until mixture has properly set up. 5. Pick up one stand of drill pipe and circulate one liner volume to ensure all flowpaths are free and open. 6. While RIH with the Casing: D obtain SO Weights as per K&M D obtain PU Weights as per K&M 7. Make-up rotating plug dropping head and flag sub to single drill pipe joint and stand back in the derrick. 8. Continue running in hole to casing shoe filling drill pipe every+/- 10 stands or as required. Monitor mud flow while running in hole and slow running speed if necessary. 9. Circulate a minimum of one drill pipe and liner volume. Record pick-up and slack-off weights and also rotating weight. 10. Continue running in hole with liner assembly filling pipe and breaking circulation as necessary. If necessary, rotate and wash pipe to bottom as per Baker on-site specialist. 11. After reaching one joint from bottom,pick up Baker cementing manifold and single drill pipe joint. 12. Break circulation and slowly tag bottom with liner string. Space out to get Baker rotating cementing head at a convenient working height. Also ensure liner hanger assembly is spaced out to the middle of the 13Cr-80 section of the 9-5/8"casing as this is critical for long term integrity of the well bore. 13. Company man and Baker specialist should discuss reciprocating and rotating parameters prior to continuing operation. 14. Circulate 1-1/2 bottoms up or until hole is sufficiently cleaned. Maximize flowrates during sweeps to clean hole. Rotate and reciprocate as required while watching closely for torque-up and backlash. Note: The liner hanger setting pressure is 2,500 PSI +1- 15%. Do not exceed 2,000 PSI circulating pressure without consulting Baker specialist. Drilling and Completion Wellplan Page 30 of 45 04/15/13 oilItE VISION: en us operrahnS WELL OP22-WW03 Production Liner Cementing Section Casing Size/Depth Type of Fluid/Cmt Volume Properties Citric/DeepClean 30 bbls XXX Production Top of liner at approximately Mudpush II 30 bbls Density 12.5 ppg 7468' MD Class"G„ 114 bbls Density 15.8 ppg (550 sks) Yield 1.17 ft3/sk Production Liner Cementing Notes a) Obtain and review the Test Report from Dowell's North Slope Lab on the job blend prior to pumping the cement. Send this report to the Drilling Engineer. b) DO NOT pump cement if there are any doubts as to cement quality,quantities,pumping times or thickening times. If necessary confer with Drilling Engineer. c) Annular volumes have been determined assuming 35%excess. Plan to batch mix the slurry. d) Keep the down time periods(dropping the plug)as short as possible. e) Cement head assembly should be staged on the pipe skate. Verify installation of wiper plug. 1. RU Schlumberger Cement Unit. Batch mix cement. 2. Pressure test the cement lines to 4500 psi. > —4000 psi surface pressure is needed for liner setting operation 3. Break circulation and pump the cement job as outlined in the Schlumberger cement plan and follow with DP wiper plug and displacement. Check attached cement detail for the Production Liner. D Rotate slowly and Reciprocate liner as long as possible during cement job. 1 D Discuss adding celloflakes to the MudPush and to the cement if lost circulation is a concern. 4. Displace using rig pumps. 5. Witness drill pipe dart latch liner wiper plug: D Stop Rotation and reciprocation D Slow rate to 3 BPM D Shear should be at+/-900 psi D If observed,recalculate displacement volumes from this point. 6. Continue displacing cement while rotating and reciprocating at original displacement rate. 7. For the last 40 bbls of displacement slow pump rate to 4.0 BPM for bumping plug. Drilling and Completion Wellplan Page 31 of 45 04/15/13 VISION: I • 0 n us operating 1 WELL OP22-WW03 8. Slowly reciprocate and rotate pipe while pumping cement. If hole becomes sticky immediately land liner on depth. 9. Approximately 5 barrels prior to bumping plugs,stop reciprocation and place liner hanger and shoe on depth. Slow pump rate to 4 BPM to bump liner wiper plug. Increase pressure to+/-3,000 psi to set liner hanger. Slack off liner weight plus a minimum of 20K lbs. Increase pressure to+/-4,000 psi to release HRD running tool. 10. Note: If plugs do not bump,refer to Contingency Plan below. 11. Bleed pressure to zero and check floats for flow back. 12. Pick up to check for HRD running tool release. Continue picking up until packer setting sub dogs are exposed above top of liner. 13. Slack off 50K lbs at the running tool. Rotate if required to transfer weight down hole to the packer setting sub. 14. After setting packer,apply 500 psi down drill pipe string and pick up to release RS packoff. When pressure drops off,engage pumps to wash excess cement from liner top and clean ID of tie back sleeve with a minimum of 50 barrels. Continue to circulate cement out of hole with acceptable rate,or begin reverse circulating to remove excess cement. If reciprocating during this procedure,ensure that the running string is not lowered enough to tag the plug holder bushing on the liner top. 15. Pressure test casing and liner to 1500 PSI for 15 minutes and chart results. D Monitoring for liner top packer integrity D Ensure testing is done before cement has reached the Transition time(Transition time begins at the time the cement has become unpumpable) 16. POOH to running tool. Clean and inspect rotating dog sub for shear to ensure liner top packer was set properly. 17. Continue to lay day running string and clear rig floor. Contingency Plan/Options: 18. If plug does not bump,then DO NOT over displace cement from shoe track. 19. Mechanical Left Hand release of HRD running tool: D Slack off to TD with liner and running string. Begin working left hand rotation down the string until a quarter turn is seen at the tool with 4,650 ft-lbs of torque. Move string as needed to work torque down hole. Slack off liner weight and an additional 10K lbs minimum to release running tool. Care must be taken to prevent back- off on liner below liner packer assembly. 20. Pick up without pumping to clear liner top with pack-off and packer setting sub 21. Circulate cement from liner top and set down 50,000#weight to set packer 22. Circulate BU to remove all cement from drill pipe and 9-5/8"casing. If mechanical problems occur and circulation is not possible after releasing from the hanger and setting the packer,POOH in stands to clear green cement ASAP and prepare for a cleanout run. Drilling and Completion Wellplan Page 32 of 45 04/15/13 ..:'VISION: en us operating WELL OP22-WW03 COMPLETION SECTION PERFORATING Notes: 1. Pre job safety meeting should be held before beginning operations listed below. Topics covered should include general personnel safety,well control,spill prevention,tasks and assignments,maximum safe pumping pressures and contingencies. Safety meetings should also be held prior to each major step in the procedure. 2. Only"essential personnel"should be on the rig floor while picking up and running the perforating string. All other personnel to stay off rig floor and out of the cellar until string is at least 300 feet below rotary table. 3. Radio silence is not required with the system planned for this perforation operation. 4. SLB will provide detailed string diagram with strapped and callipered dimensions. Company Man to verify all dimensional data. 5. Gun adapters will have bleed ports for trapped pressure procedures. 6. All guns must be handled with slips and dog collars. 7. All drill pipe should be cleaned and drifted prior to running with TCP operations. 8. Clean pits,solids-control equipment and surface lines prior to displacement by pumping water treated with Safe Surf 0 through pumps,pits,manifolds hoses and lines that will be exposed to completion fluid. 9. Planned fluid is 9.5 ppg inhibited brine with a viscosified pill placed across perforation interval. The brine/fluid weight is subject to change per well conditions. 10. Planned guns will be 100' of 4-1/2"High Shot Density,PowerJet 4505,HMX,38.6 g charge,72 deg phasing,5 SPF. Exact spacing and placement will be determined from log data. Completion Engineer will communicate to Company Man exact perforating locations after data is reviewed. Connection/Tubular Data: Pipe WT Grade Conn. Tool Tool Body Make Up Joint Body DP Tensile (ppJ) type Joint Joint ID(in) Torque Torsiona Torsional capacity Capacity OD ID(in) (ft.lbs) I Yield Yield w/conn. (kips) (in) (ft lbs) (Albs) (gal/ft) 5"DP 19.5 S-135 NC50 6-5/8 3-1/4 4.276 26,800 51,700 74,100 .726 712 3-1/2"DP 15.15 G-105 NC38 5 2.438 2.764 11,100 22,200 20,100 .307 297 BHA: The bottom hole assembly for fluid swap and perforation will include the following: • 4-1/2"HSD PowerJet 4505HMX guns • Crossover to LWD GR Tool • Crossover to Drill Pipe • One Stand Drill Pipe • Short Joint or RA Sub • 3-1/2"NC38 DP to above 7"x 9-5/8"Liner Top • Crossover,NC38 to NC50 • 5"Drill Pipe to Surface The detailed BHA will be communicated by SLB to Completion Engineer and Company Man after receiving log data and perforation location has been determined. Drilling and Completion Wellplan Page 33 of 45 04/15/13 VISION: 2nd us operafi nng WELL OP22-WW03 Procedure: 1. Hold pre job safety meeting discussing at minimum the items listed in the Notes section above. 2. Make up the bottomhole assembly as outlined above using slips and dog collars on the gun sections. 3. Run in the hole with the string on drill pipe. Pick up enough 3-1/2"DP so that the crossover to 5"DP will be above the liner top when the BHA is tagged on the bottom of the 7"liner string. Place dope on the pin ends only in minimal quantity and do not dope the box end of the connections. 4. Run in the hole,filling DP as necessary,to depth to place the circulating ports above the firing head below the bottom of the lowest planned perforating interval. 5. Position string so that the LWD tools are far enough below perforation interval to allow tie-in and logging of target interval. Begin pumping and log up for correlation pass to reference log and to determine depth correction needed. Perform a second confirmation logging pass to confirm depth correction. Repeat confirmation as necessary so all parties are in agreement on depth. Company Man,Eni on-site geologist,SLB TCP specialist and all involved parties must be in agreement on depth measurements.Log up to place guns on depth and mark pipe with"G 0 D". 6. Drop back down to place circulation ports below lower most perforation interval. Displace the liner volume with 125 barrels of viscosified NaCl brine perforation pill. 7. Pick back up to place guns on corrected firing depth. 8. Rig up flow lines to reverse circulate. Begin reverse circulating to clear any air from fluid system. 9. Prepare to pump in order to fire guns. Keep the rig floor clear from this point and be aware that significant losses may occur after firing. TCP specialist may send training pulses as needed. During this process,adjust choke so that a sufficient bleed-down rate is reached. At this point,all that is needed is to open the gate valve. (35 on the choke stem may be a good starting point) Fire guns by pressuring up and bleeding off pressure per direction of TCP specialist on location. 10. Rig up shot detection equipment to verify the guns have fired. 11. POOH while ensuring the hole is full using inhibited NaC1 brine. After the guns are above the perforation interval, stop and monitor the well for losses or gains and circulate as necessary. 12. Continue POOH with perforating guns. Monitor fill-ups closely while accounting for the static loss rate observed after perforating. 13. Conduct a safety meeting before the first gun reaches surface. SLB specialist will address well control,gun handling and trapped pressure issues. 14. Continue POOH and lay down TCP equipment. Inspect and report all shots fired. II Drilling and Completion Wellplan Page 34 of 45 04/15/13 i.EVISION: en o u ope ahng 1 WELL OP22-WW03 RUNNING 4-1/2"COMPLETION Notes: 1. Verify that the rig is centered over the well prior running the completion. 2. All tubing and completion components in these assemblies are 13Cr material and require special handling and make up. Refer to equipment vendors and tubing/casing make-up specialists on location for proper makeup, torque- turning and handling of equipment. 3. Ensure all proper chrome handling and make-up equipment is on location including tong dies, slips,dog collars, lift subs,wrenches,etc. 4. Use JetLube SealGuard thread compound, or equivalent, on all chrome tubing connections. Implement proper cleaning and doping procedures on all connection make-ups. 5. Monitor hole volume while RIH due to open perforations and ensure available pit volumes of inhibited brine and space for fluid gain/loss. 6. The pump assembly should be spaced out so that the seal stem on the shroud assembly is fully landed in the liner hanger tieback sleeve with minimal compression. Space out should be done below VIT. 7. Strap and record the dimensions of each piece of equipment prior to RIH. 8. Drilling Foreman shall witness the following checks: 9. Drift all 4-1/2", 12.6#tubing and equipment with a 3.833"OD rabbit. 10. Verify all completion equipment has been operationally and pressure tested as necessary, and is dimensionally compatible with other equipment to be run. Record OD's and ID's of all auxiliary equipment, including discharge pressure sub,on tubing detail. 11. One SS 3/8"chemical injection line will be run to the mandrel just above the seal assembly. One SS '/<"hydraulic line will be run to the SSSV. 12. The chemical injection line spooler and SSSV line spooling unit will be in operation during the completion installation. Sheave placement for the injection line and SSSV line must be provided concurrently on the rig floor. 13. Rig up all sheaves prior to beginning RIH with completion. Run lines through sheave and then raise sheaves to final placement. 14. Clamp every joint until reaching the GLM and then clamp every other joint until reaching the VIT joints. 15. Make sure to count all bands and clamps RIH. Connection/Tubular Data: OD WT(ppf) Grade Conn. Cplg OD ID(in) Drift(in) Collapse Burst Tensile (in) Type (in) (psi) (psi) Yield (kips) 4-1/2 12.6 13Cr-80 Vam Top 4.937 3.958 3.833 7500 8430 288 7 26 13Cr-80 Vam Top 7.565 2.276 6.151 5410 7240 604 Make-up Torque: OD WT(ppf) Grade Conn. Type M/U Torque M/U Torque M/U Torque (in) Min(ft-lb) Optimum(ft-lb) Max(ft-lb) 4-1/2 12.6 13Cr-80 Vam Top 4000 4440 4880 7 26 13Cr-80 Vam Top 7470 8300 9130 Drilling and Completion Wellplan Page 35 of 45 04/15/13 co* VISION: • o 2rnlll us cooperafing WELL OP22-WW03 Running Procedures: 1. Prior to running the completion,hold a pre job safety meeting to review completion procedures and communicate individual responsibilities to all parties on location.Repeat safety meeting at any crew change while running the completion. 2. Pick up first full joint of 4-1/2'tubing in elevators. 3. Pick up 3.81"X nipple assembly and make up to bottom of first full joint. 4. Pick up chemical injection mandrel and make up to bottom of nipple assembly. 5. Pick up 7"tieback seal assembly and make up to bottom of string. Unwrap seal stem and lower string to place the chemical injection mandrel at working height on floor. 6. Prepare 3/8"chemical injection line and connect to mandrel per SLB representative. Ensure 2,500 psi check valve is installed in lower portion of chemical injection line above mandrel. Begin clamping line to tubing at first connection above mandrel using Cannon cross-coupling clamps. 7. Continue RIH with injection lines on 4 1/2"tubing installing Cannon single-channel cross-coupling cable clamps every joint until reaching the SSSV(+/-2,200 ft MD). Make up 4-1/2"SSSV and pup joint assembly. Connect 1/4" SS control line to SSSV. Apply pressure to SSSV through control line at spooling unit to hold valve open while RIH. See below for SSSV Specifications: Description Max OD Min ID Nipple Profile Working Press. Open Pressure Close Pressure (in) (in) (psi) (psi) (psi) 4-1/2" 6.932 3.812 3.812 X 5,000 2,610 1,260 TRMAXX-4E 8. Continue RIH with injection line and SSSV control line on 4 1/2"tubing installing Cannon single-channel cross- coupling cable clamps every joint until reaching the GLM. Make up GLM,4-1/2"x 1"Model KBG-2,with DCK-2 shear valve installed. Install Cannon single-channel cross-coupling clamps below and above the GLM on the pup joints. Use caution when placing lines across round GLM body and ensure lines do not run casing. • A 2,100 psi annulus to tubing DCK-2 shear valve should be installed in the KBMG GLM within+/- 2,000 ft MD. The Completion Engineer will determine and communicate GLM/shear valve placement before the completion is to be run. 9. Continue RIH with injection line and SSSV control line on 4-1/2"tubing installing Cannon single-channel cross- coupling cable clamps every other joint to surface. 10. Prior to picking up the VIT joints,space out the landing of the tieback seal stem. Pick up additional joints of 4-1/2" tubing and land out seals to obtain proper tubing hanger space out measurements. Ensure engagement and landing of seals in tieback sleeve. Mark pipe,measure and calculate proper space out for tubing hanger placement. 11. Install correct pup joints below VIT section to allow the tubing hanger to land properly while the seal stem is fully engaged with a minimal amount of compression in tubing string. Ensure no-go on seal stem will be landed when tubing hanger is set. 12. Make up VIT joints and place 6"mid joint clamps on top and bottom of VIT body approximately 1-3 feet from each end. Drilling and Completion Wellplan Page 36 of 45 04/15/13 Pi* o 2no �S operrafins 1 WELL OP22-WW03 13. MU tubing hanger in completion string. Assemble chemical injection line and SSSV feed-throughs. 14. Drain and rinse BOP stack before landing tubing. 15. Land tubing with extreme caution to avoid damage to lines or penetrators. Run in all lock down screws. 16. Test hanger body seals(upper and lower)to 5,000 psi for 10 minutes. 17. Pull landing joint. 18. Install BPV and ND stack. 19. NU tubing adapter and tree ensuring that tree is oriented properly. 20. Pull BPV and install test plug. 21. Test tree to 5,000 psi. Test tubing hanger void/packoff to 5,000 psi for 10 minutes. Pull test plug. 22. Rig up to pump down annulus and take returns from tubing string while recording on chart. 23. Pressure test annulus by slowly increasing pressure in annulus to 1,500 psi and hold for 15 minutes while recording on chart. 24. Open tubing return and slowly increase pressure to 2,200 psi to shear valve in GLM. If valve does not shear initially,cycle annular pressure from 0 to 2400 psi until valve shears open. 25. Displace inhibited brine to diesel freeze protect by pumping diesel down the annulus taking returns through the GLM and up the 4 1/2"tubing. Displace enough diesel to fill the annulus and also the tubing volume. Estimated diesel volume required is 140 bbl. SSSV below valve will be closed to ensure returns. 26. Shut in well. 27. Set BPV. 28. RDMO drilling rig. 29. Prepare Handover Form and post to N: drive in the operations folder.Form is located under N:•IAlaskalNikaitchug1Drilling and Wells101iktokPoint\WellsIOP21-WW01101 Operational Data\Handovers. Handover must be completed to ensure a reliable resource for the production engineer to reference during planning and execution of post-rig work. Drilling and Completion Wellplan Page 37 of 45 04/15/13 ife* VISION: o 2rnl� us op rating WELL OP22-WW03 ATTACHMENTS 1. Recommended Drilling Practices 2. Health,Safety,and Environment 3. Safety Meeting Topics 4. Well Shut In Procedure While Running Tubing 5. Conductor Broaching Contingency Plan 6. LOT procedure 7. FIT Guidelines 8. Port Collar Decision Tree 9. TAM Port Collar and Combo Tool Running Procedure 10. Schlumberger Directional Program 11. Schlumberger Cement Program Drilling and Completion Wellplan Page 38 of 45 04/15/13 ..dVISION: 2nd us operating WELL OP22-WW03 Recommended Drilling Practices Hole Cleaning With a deviated well path and potential for losses,hole cleaning will require special practices. Pipe rotation is critical for effective hole cleaning. The maximum string RPM,as determined by the BHA,is specified for each hole section in the detailed procedures. The shakers should be monitored as an indicator of adequate circulating time. If circulation is of long duration,then pipe movement to prevent casing wear is critical and a stand should be laid down occasionally to prevent excess hole erosion over the length of pipe reciprocation. In addition the following practices should be employed at all times: a) Use all available solids control equipment to keep mud as clean as possible. b) Emphasize proper hole cleaning after slides by rotating at maximum allowable RPM c) As the hole angle increases,hole cleaning practices must be altered. Maximum pipe rotating speeds along with maximum achievable flow rates will increase hole cleaning efficiencies. Circulating times prior to trips should be increased accordingly to account for longer times required to remove cuttings from higher angle wells. d) Use good connection practices while drilling. After reaching the bottom of a stand,allow a small amount of circulating time to allow cuttings to get above the BHA prior to picking up off bottom. Be sure to pick up slowly to prevent packing off the cuttings bed around the top of the drill collars. Slower Trip/Connection Speeds High POOH and RIH speeds can aggravate fragile shales/formations due to the pressure variations between surge/swab. PWD data shows that excessive tripping and reaming speeds can exert pressure spikes in excess of 2 ppg equivalent. Effective ROP Strive to find the maximum effective rate of penetration.That is,the maximum rate at which a clean hole can be produced. While on bottom ROPs in excess of 400 fph may be possible,but such ROPs may load a high angle hole with cuttings that are not being removed fast enough. Using torque and drag trends,ECD and the shakers,establish a base line clean hole ROP,and then try to improve it by altering the hole cleaning practices. Slower Initial Pump Rates PWD data has shown that the most significant period for increased ECD occurs when the pumps are brought on at drilling rate while washing a connection to bottom. The study also concluded the least damaging procedure is if pump rates are held at 40%or less of drilling rate while reaming connections. Drilling and Completion Wellplan Page 39 of 45 04/15/13 VISION: an us operating WELL OP22-WW03 Health, Safety & Environment The following are part of the mitigation&contingency measures to be put in place in order to complete this project while helping to meet our HS&E goals. It is the Drilling Supervisor's responsibility that these measures are implemented and communicated to the relevant parties on location. Good communication when drilling is essential for increasing the safety of personnel and equipment. H2S Contingency Measures Assume all locations have the potential for H2S. 1. The AOGCC will be notified within 24 hours if H25 is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. Manual detectors in accordance with 20 AAC 25.065 will also be maintained on location. 3. Self-contained Breathing Apparatus for all rig personnel will be maintained on location. 4. All personnel engaged in the drilling operation will be trained in H2S emergency procedures and the use of proper personal protective equipment. 5. A standard H2S contingency plan will be posted at the rig. All rig personnel should read and familiarize themselves with this document and copies should be posted in the rig floor doghouse and in the camp on location. 6. H2S treating material for the drilling mud system will be available on location in the event that any H2S is encountered. It is expected that the rig and personnel will have the equipment and training to identify and contain a H2S emergency situation. If it becomes necessary to notify the AOGCC of an H,S encounter,drilling will be suspended and will resume only after the development of detailed remedial and contingency procedures,full compliance with 20 AAC 25.065 and the applicable referenced sections of API RP49 and approval of the AOGCC. Lessons Learned Documentation of lessons learned has been proven to reduce downtime and increase efficiency of rig operations. It is expected that planning meetings,daily operations meetings and pre-tour meetings will be held on a regular and consistent basis and that the records of those meetings will be placed on the N drive in the appropriate folder for this well. Drilling and Completion Wellplan Page 40 445 04/15/13 .. VISION: en us operr mg WELL OP22-WW03 Safety Meeting Topics Move In, Rig Up ➢ Prior to spud,a safety meeting should be held with the rig crews to discuss open hole drilling procedures. - Subsidence around wellheads-use of buddy system, - Conductor broaching operations and contingencies, - Shallow gas hydrate drilling practices, - Proper tripping practices and hole fill calculations with various sizes of pipe and tubing, - Well control procedures, - Flow rates and hole cleaning,and - Diverter operation and crew responsibilities. ➢ A'Diverting Shallow Gas'drill should be held with rig crews prior to spud,unless each crew on tour has completed this drill within the past 3 months. Document drill and record on morning report. ➢ An'Accumulator'drill should be held with rig crews prior to spud. Document drill and record on morning report. > Shut-in drills should be held on a regularly scheduled basis. A suggested minimum is once per day on alternating tours. Document and record on morning report. ➢ Check trip tank for leaks and confirm gauges are calibrated. Complete trip sheets and submit to the Drilling Supervisor after each trip. ➢ Perform and document all drills. ➢ Designate crew member to control access at the pad entrance in case of diverter operation. Surface ➢ A'Stripping'drill should be held with rig crews prior to drill out,unless each crew on tour has completed this drill within the past 3 months. Document drill and record on morning report. > A'Well Kill'drill should be held with rig crews prior to drill out,unless each crew on tour has completed this drill within the past 3 months. Document drill and record on morning report. ➢ A well kill sheet shall be posted in the doghouse and updated each tour. Intermediate ➢ Prior to picking up the BHA a safety meeting should be held with the rig crews to discuss hole risks and open hole drilling procedures. > Potential formation pressures and mud weight,Well control procedures. ➢ Hole cleaning best practices,flow rates. > Stuck pipe,Lost circulation. > Proper tripping practices and hole fill calculations with various sizes of pipe and tubing. Production ➢ Prior to picking up the BHA a safety meeting should be held with the rig crews to discuss production hole risks and open hole drilling procedures. ➢ Potential formation pressures and mud weight,Well control procedures. > Hole cleaning best practices,flow rates. ➢ Stuck pipe,Lost circulation. > Proper tripping practices and hole fill calculations with various sizes of pipe and tubing. Drilling and Completion Wellplan Page 41 of 45 04/15/13 rot VISION: o 2nn ass operating WELL OP22-WW03 Completion D Operation of the control line spooler. D Pinch points associated with tongs and slips. D Proper tripping practices and hole fill calculations with tubing and control line. D Well control practices while running production tubing with control line. D Pressure testing and minimizing personnel exposure to pressurized lines. Drilling and Completion Wellplan Page 42 of 45 04/15/13 fifi* VISION: en us operraing WELL OP22-WW03 Well Shut In Procedure While Running Production Tubing If well is suspected to be flowing: 1. Install TIW valve and pull back to the first banding point below the BOP stack. 2. Shut off air to control line spool and bleed off line pressure while checking well for flow. 3. If well is confirmed to be flowing,cut control line with bolt cutters directly above a banding point. 4. Slack off until full joint of pipe with no control line attached is spaced out across BOP stack. 5. Close annular and monitor pressure. If well is coming in rapidly and time is not permitted to complete above operations: 1. Install TIW and close annular around pipe and control line. 2. Shut off air to control line spool and bleed off line pressure while picking up a joint of drill pipe and making it up to TIW and top drive. 3. Close IBOP on top drive and open TIW valve. 4. Cut control line and strip the joint of drill pipe across stack for ram closure if needed. 5. If annular does not seal off around tubing and control line and the joint of drill pipe cannot be safely picked up, close blind/shear rams on production tubing. Notes: • Specify location of bolt cutters required to cut control line. • Need to have access to a joint of drill pipe and the appropriately sized elevators at all times. Drilling and Completion Wellplan Page 43 of 45 04/15/13 tiffoOs VISION:• ern10 us operating 1 WELL OP22-WW03 Conductor Broach— Contingency Cementing Plan In the event of a broach to surface of drilling fluids during the drilling of the surface interval,the following contingency plan is recommended to remediate the situation. Conductor Hole Diameter Conductor Casing Size 20" Conductor Setting Depth +/- 120'MD DP/Conductor Annular Volume 5"DP x 18.25"ID:(36 bbls) Conductor Pipe Volume 39 bbls 16"Open Hole Capacity 0.2487 bbls/ft 1. Upon establishing that a broach of the conductor casing has occurred,POOH and stand back BHA. 2. RIH with open-ended drill pipe to 20'below the base of the conductor pipe. 3. Establish circulation with mud at normal drilling rate. Begin circulating and establish rate of flow through broach with drilling fluid. 4. Circulate up to 120 bbls of water or until water returns are seen from the broach. 5. RIH to 200'below the base of the conductor. If mud viscosity is<300sec/qt.,spot a 150'pill of 150K cp polymer (Biozan)to 50'below the conductor. POOH to 20' inside the conductor. 6. Mix and displace+/-80 bbls of Artie Set 1 cement at 15.8 ppg. Cement may U-tube with no ability to obtain squeeze. Do not over displace DP. Monitor and gauge all returns. 7. POOH and WOC for 8 hours. 8. PU 16"bit and BHA and RIH to clean out cement to 40'below conductor. Establish normal circulating rate and evaluate broaching. If no broaching is seen,continue with planned operations. If additional broaching occurs, repeat steps 6,7 and 8. Drilling and Completion Wellplan Page 44 of 45 04/15/13 4 s VISION: o 2nd us operating 1 WELL OP22-WW03 TAM PORT COLLAR Utilization Decision Tree TAM Port Collar Utilization Decision Tree Begin Primary One Stage Cement Job No Cement jr—Cement to to Surface Surface Drilling Foreman and rpleUpand Engineer determine the X est BOP's Top of Cement • • Top of Top of Cement Cement Continue with above Port below Port Completion Collar Collar (1000'TVD) (1000'TVD) • • X Indicators of Cement Top Perform Top Job as per --► Open Port Collar ' If Top Job is ineffective or 1. Observation of Tracers in Spacer ahead of lead cement requirements of using drillpipe 2. Calculated Displacement AOGCC unacceptable to AOGCC P 3. Displacement Pressures during Primary Cement Job 4. Other indications that cement is near surface Nipple Up and Circulate Cement Test BOP's to Surface and ose Port Collar • • Continue with I Nipple Up and Completion Test BOP's Continue with Completion Drilling and Completion Wellplan Page 45 of 45 04/15/13 N 1pp{pp O C c° 88;82, 1'488 t6O 4A Q NN;p4 {p6'88�p8p A Mp 0^01800 " A 8 88 Q NNN p8 9,S t7co«" 0'%0N o 00082 $fO 8.‘i. 10 65 0 O 0 0 H0 0 0 a cm m Z' 1m�m 0007(O (O �n 10 �p �(1 �O �O �0 W 0Od0 b b81002 b O EO10 c08O c0 8E 888 8 8 2 810 22O 1O b """Y)Y) "c0""" Y)1610"y, 0c001010 I.0 Y)U)Y)i0 7.; " N 178 N N"N N Y) Q co W^ 88222 081008 0 Q N.-0 AOJN 28 g•-•10 A 8.- O 1n O NA Nn88 ry v C N GOm OtON ntpOQ 8 F)A1D00 {Mp tnp{gyp 1108{{Npp "NN O) 0 0 0a 0 WW$n $N$hOOQ °cm7 Cn')A',, t717 AA8 2OMMM A A A O V m$$O/•,. 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O)LLLL• A.M., MM M8)M MMMMM MM M M M) 8MNN N• NNNNN W 0. U �0 ;0)666 66666 m LL 00 �M' d O O 2 8 Q f -m, LL J J J 0 tOMLL LL LL 0 nano 0 78°:: • Q^ ppp ;.7.2.38,0 NNN 0)O O$G 0 O88 8$ ' O 2;2; N O m«:- 80000 6,.:4 7 N 66., : ::88 pO SOOOo^ N g.1K 80 N g 1b Op616 8801816101E :::A 8^01080^ n 1080 11 0 180 1. ^ W ?.' 1.I0. W O::N Y t N N ''N c. l�l� 1�C 0 n g. y ` O ZNNN �. TT E ()Ogg- m19Nt� ,1%t7i m t0 O N O N N UNNN C 0y 0 Y• C E O o uM~ mMQ QQ “16t N e Yv7 m o 2.o U LUX a=)a 040 a U W-,ozz 22000 00,0 S 1� z. YN YN 2 M2YHH az Q Schlumberger • can a WELL FIELD I STRUCTURE OP22-WWO3 (P4b) Nikaitchuq Oliktok Point Magnetic Parameters —Surface Location NAD27 Alaska Stale Plane,Zone 04,US Fast Misullaneous Mode) SCUM 2012 Dip: 61050' Dale. June 202013 Lat. N 70 Nos 3 hing. 65466 BU 83 S Grid Cony.0.128' Slot. OM ND Ref: Rotary Table152.20 above MSL) Mag Dec. 19692' F5: 57608 acT Lon'. W 149 51 51 459 Fasting 516583 96 Scale Fact.099990031 Plan: OP22-WW3(Pan) Slay Data March 25,2013 0 1200 2400 3600 4800 • 0 RTE g• 0 KOP Cry 1/100 Cry 3/100 Cry 3/100 V-4 1200 -V.2 1200 C v 0.0/100 Cry 3/100 _.._.._.._.._. .._.........._.._.._...........�....._._.. .._.._....._........_A......_.._.._.._.._.._..__... nu Top(U04) 2400 4 4 2400 G-2 Coal Bed Marker• End ry wer Ugnu ::st:s::s:ls::Siata:s::s::s:: •:s::s:: 'stu::z::s::.:a.sats:.:as::.s slrs::s::s::z::s::s:as::s:s::s:as::s::s::s::z::s::s/ls:l 3600 unlnuninUa.uuu.uuuu MifnieuUuUllUunuuUtu;utuu.uu mmum uuntUummum Pummu•uUh•n 3600 13-3/0••Csg o CI 4800 4 4 4 '• 4800 Cry 31100 6000 4 4 4 • 4 6000 Target ::_::_::_::_ _.._.._.._.._._.._....._.._.._.._.._.._._.._.._....._.._....._.._._.._.._.._.. =-.i5lcabik .t._.._.._.._.._.._.._.._.._•._ _ _ aluDik Marker 2012 .._. ...._....._.._.._.._.._...._..—.._.._.._.._.._.._.._._.._..2: -co 201 •?A1i.:�::�::�::.::_._ End Cry 7200 4 7200 8400 _.._.._.._.._>t _.. ._.._.._.._.._.._.._.._.._:�Y 3 8400 ..L...aa....aGiiao.ka.k........kr..�.. - ..r...k.kk..a.aa. • hak 2012 Target vik 2012 ` 9600 - • :• OP22-wvw31P4t 9600 0 1200 2400 3600 4800 Vertical Section(ft)Azim=330.42°Scale= 1:1200(ft) Origin=0 N/-S,0 E/-V can a Schlumberger WELL I FIELD STRUCNRE OP22-WW03 (P4b) Nikaitchuq I Oliktok Point Magnetic ParenteMrs Surlace Loca0on NAD22 Alaska Stale Rape,Zone 04 US Feet I Mrxa1Mrecus Mode, 855M2012 Dip: 81.050' Date: June 20.2013 Lat'. N 703039.137 Northing 6036486838US Grid Con:01281 Slot 0P22 NO Ref RUalo TabU(52211 otove MSL) Mag Dec: 19.892' FS- 5)6054,7 Lan W 149 51 51 458 Eaatng• 516583 9 6 11U5 Scale Fact 099990031 Plan- 0P2241903(Pan) Sny Date:March 25.2013 -2500 -2000 -1500 -1000 -500 0 500 TD Target OP22-15/81103(P4b) 3000 3000 End Cry Target �.4 9S/9•• • "4 2500 ••••• Crv3/100 .... 2500 1 1 2000 •-•• 2000 A A A • • Z 0 0 `•°• 1500 •••• 1500 1n co V V V 1000 •••• • 1000 •3.31-Cog 500 •••• • 500 End Cr0 RTE KOP Cry 1/100 0 0 Cry 3/100 Cry 3/100 Cry 3/100 Cry 0.5/100 -2500 -2000 -1500 -1000 -500 0 500 «< W Scale=1:500(ft) E >>> • • • kikalargsr OP22-WW03(P4b)Anti-Collision Summary Report Analysis Dale-2ahr Time: March 25,2013-07.49 Analysis Method: Normal Plane Client: ENI Reference Trajectory: OP22-W WO7 (Del Plan) Field: Nikailchun Depth Interval: Every 1900 Measuease red Depth(II) • Structure: Oliktok Point Rule Set: DIM AnliCollision Standard S002 85.115.2 Slot: 01722 Min Pts: All local minima indicated. Wall: OP22-W W 03 Borehole: OP22-W W03 • Offset Trajectories Summary Offset Selection Criteria Wellhead distance scan: Nol performed! Selection filters. Definitive Surveys.Definitive Plans-Definitive surveys exclude definitive plans -All Non-Del Surveys when no DO-Survey is set in a borehole•MI Non-Oef Plans when no Oaf-Plan is set in a borehole Offset Trajectory Separation Allow I Sap. Controlling Reference Tra)acleey Risk Level Alert Status CI-CI(ft)I MAS(ft)I EOU(ft) Dev.(ft) Fact. Rule MD(It) I TVD 01) Alms I Minor I Major OP23-W W02(Oaf Survey) Warning AM 8.06 667 6.83 1.39 907278 MAS-2.03(m) 9.00 9.00 CtC14•15m<15.00 Enter Alert I"' 07 6 67 4.70 IIIIIIKIE 5.85 MAS•2.03(m) 26798 267.98 McRs 7•W 6.67�.j�® MAS=203(m) 33658 336.56 Mnns 11�Ot1 667 4.6• 5.31 MAS•2.031m) 34911 34101 502%s 6.97 6.67 4.70 0.31 MEM MAS=2.03(m) 399.01 399.01 M,nyi-O-SF 1 6.93 8.6 4.6 0.26 5.63 SIA5=2.03(m) 40901 40901 MINPT-0-EOU D 6.67 4.70 0.25 974 MAS=2.03(m) 414.56 414.55 Min%s 4909 6.67 46.15 4142 27.95 MAS•2.03(m) 801.73 79717 CICI4•15m>15.00 Ent Alen 162.61 6.67 15829 155.94 MIKE MAS•203(m) 1389.36 1378.58 Ming-0-SF 2459.36 198.11 232696 2261.2 immii OSF t.50 7075.54 505484 MnR-06F 398950 270.18 3842.39 3769.3 MgiiIE OSF 160 10655 90 9694.79 MmR-0-SE OP21-WW01(De Survey) Warning Alert 7.95 6 60 6.73 1.36 19813.90 MAS=2.01(m) 8.58 8.58 CICI=•15m=15.00 Enter Alen I 7.54 6.60 5.46 999I 6.97 MAS.2.05(m( 205.07 20507 Mnns 7.66 6. 5 at 106 629 MAS•2.01(m) 228.55 22855 MINPT-0-00U 7.79 6 5.41 1.19 5.69 085.2.01 lml 248.52 248.52 MINP7-0-EOU 10.52 6.60 7.16 192 :11 MAS=2.01(m) 33815 338.35 Ming-0-SF 21.19 739 15.85 11..IIIM1M 050 1.50 53142 538.18 Men-O-SF ' 3522 8.62 29.06 26.6. OSF 1.50 85834 85131 Mn1=1-0-SF 48.86 9.83 41.90 3903 8.30 OSF 150 989.93 981.26 CICI4•15m>15.00 Exit Mel 868.08 39.29 841.48 828.7 MMIE OSF 1.50 3277.96 3121.76 MON0-SF 3692.75 191.02 3565.08 3501.7 MIMIC OSF 1.50 7113.37 808426 Min%-0-SF 4431.94 21812 4286.20 42118 050 1.50 1011291 8962.53 Ming-0-SE 446710 221 28 431996 4246.5 OSF 1.50 1029102 9140.03 Mc1.143-SF • !I 0120-07081(Del Survey) Warning Mot 15.91 12.97 14.64 2.9944 WA MAS-595(m) 0.00 0,00 004•15m415 00 Enle Akn MEM 12.97 1468 4.ay WA IM5.195(m) 40.00 40.00 Minns lei 14.977 12.11 1.831 927 M45.195(m) 259.02 259.02 Minns I 1504 1291, 11.91 2.07 7.23 MAS•3.95(m) 288.95 28895 MWP7-0-EOU I 1523 12.9 11.88 2.26 6.57 MAS•3.951m) 298.92 298.92 MwPTO-E017 18.83 12.97 14.36 5.961-1 MAS•3.95(m) 368.36 36136 Minn-0-SF 47.79 12.97 42.56 34.82 11.64 MAS•3.95 On) 552.50 552 21 CICI=.15m>1500 Out Met 106.15 12.97 9861 911. MAS•3.95(m) 740.29 73711 Mnn-0-SF 4129.33 98.40 406140 40301 11.13E11 OSF 150 4758.89 426556 MnPI-0-SF 6077.51 14256 5982.14 5934.9 MIK OSF 1.50 598061 5212.25 6ling-O-SF 6287.07 147.44 618145 6139.6 111111111MIE OSF 1.50 612042 5317.15 M01P1.0-SF 652193 15111 6427.53 6376.8 MIK OSF 1.50 6278.44 503920 MinR.O-SF 1 6646.78 15985 6542.55 6490.9=ME 0001.50 6355.43 5098,66 Ming-O-SF 7028.10 171.]5 60x32] 6856.3 61.7 0061.•A 658022 5672.28 Mull-O-SE 0120 97082(Del Survey) Warning Merl 15.91 1297 14.68 2.94 WA MAS-3.05(m) 000 0.00 CIC14•1S11c1500 Enter Alert 12.97 14..:;MEM WA MAS•3.95(m) 40.00 40.00 Mnns .0 12.97 12.11 Min 127 045.3.95(m) 259.02 259.02 Minns 15.04 12.9 nom 2.07 7.23 085.3.95(m) 28895 288.95 01607.0.009 15.23 12.97 MEE 2.26 6.57 MAS=3.95(m) 298.92 298.92 MINP7O-000l 18.83 12.97 1e36 5.861-1.il MAS.195(m) 368.36 36136 Mn111-0-SF 47 79 1217 42.56 34.82 11.64 MAS•3.95(m) 55250 552.21 Ct0c.rsm.1500 EM MOt 108.15 12.97 98.61 9118 16.60 MAS•3.95(m) 740.29 737.91 MMR-06F 4129.33 9136 4063.43 4030.97 63.59 OSF 1.50 4758.89 4265.56 MinR-O-SF 6077.51 14252 5982.17 5934.991 64.40 OSF 1.50 5984.61 5212.75 MinntOSF 6287.01 14719 6180.48 6139.67 64.40 OSF 190 6120.42 5317.15 MnP1-0.SF 6312,17 147.98 6213.19 6164.201 64.40 OSF 1.50 6135.90 5319.80 0n1.0-6F 647180 151.89 637021 632791 64.40 050 1.50 624555 5413.79 04081.0 6F 7072,75 167.01 6951.08 6905.74 63.89 05F 1.50 6650.85 5126.83 MinR,O.SF 7578.15 178.47 7458.84 7399.68, 64.04 OSF 1.50 6952.93 5960.15 Min111.06F 13081,91 17199 12961 59 12901937 109.62 0501.50 7665.55 6550.52 Ming-O-SF 0120-07(Del Survey) Warning Merl 1991 12.97 1468 2.94 WA MAS•3.95(m) 0.00 0.00 CICI•=15m=1500 Enter Alen r 12.97 14.58 2,g WA MAS•195(m) 40.00 40,00 Mnns Man t2.97 12.10 164 120 M65=3.95(m) 259.92 25192 Mnns 15.06 12.9 11.91 209 7.18 MAS•3.95(m) 26985 289.85 MINPT-O.EOU 15.25 129 11.884 228 6.52 085-3.95)m( 29982 299.82 MINPTO-E00 18.90 12.97 1442 994 5.431 MAS•3.95(m) 369.25 36925 M6179-0-SF 41.97 1297 42.75 35.00 11.69 MAS•3.95(m) 553.36 553.06 CICIc•1faretS 00 Ent Mel 106.15 12.97 90.61 911:111.10•-I MAS•3.95(m) 740.29 737.91 Mont-0.6F 4129.33 9840 406140 4030.9 0001.50 475889 416556 MnR-06F 807827 14258 5982.88 5935.6 m3NE 0501.50 5985.10 5212.63 Mln%-0-SF 6287.82 14745 6189.19 6140.3 MMIE., OSF 1.50 6120.92 5317.53 Mnn.0.SF 648055 15115 6378.93 632861 MMIlE OSF 1.50 6246.04 5414.17 MinR43-SF 7073.51 16797 6961.80 6906. 1111111an 0501.50 6651.32 5727.20 1011-91.06F 1 7578.92 17854 7459.56 7400. MMIE OSF 1.50 6953.41 5960.51 M61g-06F 15307.18 176.27 15189.33 1513990 130.98 OSF 1.50 7752.64 6641.10 TD 1743309 64.70 17389.63 17368.391 410.391 0501.50 87077 87271 Mnn.0.SF 0124-08 fool Survey) a.nng Men 15.97 13.01 14.74 2.96 WA MAS•3.96(m) 0.00 000 004•15m415.00 Enter Alert ert W E 1101 14.11 2.82 29.37 5865.396(m) 150.00 150.00 10101115 15.84 13.011 14.051 2.831 26.1.31 MAS.3.96(m) 16363 163.63 Mnns 28.80 1101 25.52 1579 13.111 SOS.3.96(m) 39952 399.51 MnR-0.5F 48.63 1101 44.11 3561 14.41 MAS•3.96(m) 563.65 563.30 CICIc=15m>15.00 En Mel 8597 1101 79.04 72.'.NEM MAS•7.96(m) 70797 706.15 Ming-0-SF 1787,79 46.83 1756.21 1740.96 1111.Z1al OSF 1.50 3424.51 3234.95 Ming-0-SF 5709.64 160.91 5602.04 55417 MEC 080 1.50 6613.01 5697.60 Ming-06F • 14053.70 146.07 1395599 1390713 145.29 0901.50 7836.92 6722.29 TD Drilling Office 2.6.1166.0 Nikaitchug1Oliktok Point1OP22-WW0310P22-WW0310P22-WW03(P4b) 3/25/2013 7:51 AM Page 1 of 5 • Offset Trajectory Separation Allow Sep. Controlling Reference Trajectory Risk Level Alert Status CI-Ct 10111 MAS(It)I EOU(It) Day.(11) Fact. Rule MD(ft) I ND(11) Alert I Minor 1 Major 16635.36 4385 1660580 16591.51 582.09 OSF 150 91x.99 907.93 MnR-O-SF OP17-02(Del Survey) Warning Nat 47.95 3211 46.73 15.14 8692603 MPS=60.00(m) 8.95 195 Cla<=15m•15.00 Enter Alert MOM 32.81 42.8 F5 1999 045=1000(m) 348.69 348.69 MnP1. 36.69 32.81 28.81 1;;AIME MAS=10.00(m) 72675 72462 46101.0-SF 36.33 32.81 28,51 152 111111111112ff MAS=(0.00(m) 736.53 734,22 M11111-0-SF 35.88 32811 28.23 3.07 5.40 MAS=10.00On) 756.04 753.34 MINPT-0-600 35.811 32.81 28.281 3.001 549 MAS=1000(m) 765.77 76287 MinPls 4878 32.81 40.10 1597 8.37 005•10.00)11) 90158 894 65 CIC1<=1517715.00 Eul Met 8104 3281 70.45 56.24 11111.20 MAS=10.00(m) 1101.19 1091.10 00R-0-SF 778.57 3507 754.84 74151 MME 0581.50 3101,62 2985.55 00111-0-SF 2720.93 89 04 2661.24 2631.. .v, OSF 150 466256 4191.16 54i481-0-SF 1319116 131.35 1311027 13066.81 15115 058 1.50 783767 6723.01 TD OP17-02P131(Del Survey) W amig Melt 47.9$ 32.81 4673 15.14 827865.39 005=10.00(m) 000 000 CICt<015m.115.00 Enter Alan 32.81 42.8 MOE 19.99 MAS•10.00(17) 34169 348.69 M nnF 35.69 32.81 28.81 3... 5. MAS:moo(m) 726.75 724.62 MInR.O-SF 76.33 32.81 2851 J 5.3 MAS=moo(m) 778.53 73122 Ming-O-SF 35.88 32.81 28.2 3.07 5.40 06$=10.00117) 75604 75134 MINPT.0-EOU 1 35811 32.81 28.28 100 5.49 MAS=10.00On) 76577 76217 MinPla I 48.78 3281 40.10 15.97 6.37 MAS=1000(17) 901.56 894.85 CICl•=15m7I5.00 Eut Nat 89.04 32.81 7045 5524 mem 140S=10.00(m) 1101.19 1091.10 1.9177-0-SF 778.57 35.07 754.84 743,51 M'S 0581.50 3101.62 2985.55 0i7111.0-SF 272093 89.04 2661.24 26311;MIME OSF 1.50 466256 4191.16 4071RA-SF 1393641 13300 1384742 1380341 15133 OSF 1.50 785693 6741.49 TO 0718-08702(000 Survey) Warning Merl 39.95 32.20 3872 7.75 WA MAS=9.81(m) 000 0.00 pt04=1517<1500 Enle Alert 1 37.481 32.20 34.4 5.2 19.53 514S=981(17) 387.80 387.80 Minas 37.49 322 3436 529 1901 MAS=9.81(17) 397,71 397.70 M114P7-0-E0U I 4122 3720 3152 11.02�''1'2 MAS=981(0) 514.41 $1426 1.4,11410-SF 48,68 3220 44.86 16.47 MEM MAS=9 81(m) 55204 552.14 CICt<66517715.00 E44 Nat 6475.71 155.64 637152 6320,0 '. OSF 1.50 7073.99 605165 Ming-0.SF 1352907 15270 1342694 1337617 1333.75 OSF 1.50 7780.11 666111 TD OP16-08PB1(Del Survey) Warning Alert 3995 3220 38.72 7.75 1.1/0 MAS=9.81(m) 0.00 0.00 CICt.1=150 015.00 Enter Alert MIRE 32.20 34,40 5.2 19.53 0PS=9.81(m) 387,80 387.80 0nR0 37.49 3220 34.36 5.29 19.01 MAS=9.81(m) 397.71 397.70 MINPT-O-EOU • 4322 32.20 39.52 11.02 M MAS•9.81(m) 51441 514.26 08111.0-SF 4868 32.20 44.66 664-�.'1 LAS=981(m) 55244 552.14 CICt<=15••15.00 Exit Net 45102 3220 44103 418.82 5195 MAS=9.81(m) 126650 125575 TO OP18-08(D9 S(ervey) Warning Alen 39.95 3220 38.72 7,75 N/A MAS=981On) 000 000 001•=15m•15 OD Enter Alen I 1 37.481 32.20 34 5291 19.53 005=081(m) 38780 38780 Minns I 37.49 32.20L 34.36 529 19.01 MAS=9.81(17) 397.71 397.70 MINPT-0•EOU 4322 32.20 3152 11.02 M MAS=9.81(m) 51441 514.26 MinP1.0-SF I 4868 3220 44,66 16.4 Man OAS=9.81(m) 552.44 552.14 C1C10915111>15.50 604 Nat 6475.71 15585 6371.62 6320...M OSF 1.50 7073.99 605165 01777-0-SF 15053.67 14816 14954.57 14905.51 153.42 OSF 1,50 784114 6733.05 TD 17243.27 32.20 17223,47 17211.07 916,61 MAS•9.81(17) 826.16 821.74 01011.0-SF 1694328 3220 16923.75 16911,06 914.57 MAS=9.811n) 83177 829.13 Mi171.0-SF 1703110 32.20 1701139 1700591 909.78 04$•9.81(0) 895.28 888.74 0i111-0-SF 17263.22 3220 17243.28 17231 02, 91019 MPS=9.81(m) 903,02 896.27 94i7lR-0-0F OP16-03(Del Survey) Pas MMEI 3281 54.4 23.131 222.38 MAS=10.0D(m) 112.61 112.61 9401715 56.32 32.811 53.44 27.51 33.37 MAS=10.00(m) 35893 358.93 M1N7T-0-COO 56.51 32.81 53.59 23.•MEC MAS=10.0D Im( 398.80 398.80 0.71-0-SF 134.02 32 81 11773 101.21 1111111.110 MAS=1000(m) 990.34 981.66 M01g-04F 1■80 77 41.53 1452.73 1439.24 MM OSF 1.50 3357.15 3182.92 007-0-SF 4224.74 103.64 415532 4121.11 OSF 150 4960.07 420.94 081171-0-SF 5555.01 13108 546463 5419.9 MIER OSF 1.50 5745.65 502719 0i771-0-SF 740630 18406 7283.27 7222.24 M.•.( OSF 1.50 7072.10 6052.19 14001.0-SF 14674.63 15714 14569.01 1451169 140.23 OSF 1.50 7792.29 6679.68 TO 16998.10 34.22 16974.96 1696188 MIME OSF 1.50 876.78 870.78 0i777-0-SF 011554(pet Survey) Pass 63.9 32.81 ® N/A MAS=(0.00(m) 9,00 9,00 140%s 62.8 32.81 60.04 IIIMIEM 38.55 146$=10.00(m) 378.64 37864 667719 62.91 3281 59.' 30.10_ 36.50 MAS•10.00(m) 398.53 398.53 07477-0-500 101.61 3281 91.50 68.80 11.• MAS=10.00 lm) 749.31 746.76 Ming-0-SF 912.47 32.81 899.23 879-- 74.8 MAS=10.00(m) 2629.55 2589.87 WM-047 1159.07 3281 1140.44 1126.2. 65.'• MAS=10.00(17) 363465 3397.24 0'1171-0-SF 3104.63 5574 3067.15 3048.• 85.0 058 1.50 5808.50 507624 0I17-0-SF 3747.34 66.51 370267 36808 85.7 OSF 1,50 651115 5618.93 1.1n11-0-SF 381140 67.76 3772.90 375064 85.7 OSF 150 6585,91 5676.67 0011-0-SF 4010.95 71.17 3963 17 3939.7. 85.• OSF 1.50 678503 5830.47 001171-0-SF 4281.34 7676 4230.24 4205.18 8541 OSF 1.50 7077,07 605603 Ming 4D-SF 13824.09 95.07 13760,38 13729.02 220.39 OSF 1.50 7932,63 6814.64 TO 1877146 40.70 1675100 (6737,76=•u OSF 1.50 74411 742.4 0i111-0-SF 1544164 36.69 15418.86 15406.96 0681.50 77204 76900 0771.0-SF 14130.75 3281 1410175 (409714 C 04$=10.00(0) 802.07 798.31 0n11-0-SF 12340.73 32.81 1232110 12307,92N"I MAS=10.00(m) 853.00 847.76 0n71-0-SF 12358.10 32.81 12339.23 123225.2'M MAS•10.00117) 864.72 859.10 0811-0-SF 15512.90 37.07 1548786 15475 L OSF ISO 971.88 96153 68171-0-SF 16785.99 41.05 16758.30 1674.'MEE OSF 750 1004.70 995.19 0118-0-SF 1691233 61.83 16870.78 16850.•NEM 058 1.50 1007.20 99824 01177-0-SF 0774-53(Del Survey) Pass 7171 3281 69.••;'•. 80.10 MAS=10.00(0) 238.97 238.97 MnRs 71.71 3281 69,1 1111111E10 52.67 045=10.00(m) 391.58 39157 01170 71.73 3281 69.1' 38.93 51.15 MAS=10.00117) 418.34 418.33 MIN77-0-EOU 130.15 32.81 119.58 97.34 MEE MAS=10.00(0) 84918 844,06 0n77-0.9F 1204.46 4105 117543 7161.41 NMEll OSF 1,50 4100.44 375701 01177.0-SF 1656.26 5912 161151 1597.1 ® OSF 150 448143 405512 0701-0-SF 2724.36 92.99 2662.03 2631.•Mu• OSF 1.50 5340.19 4714 53 14701.0-SF 2784.04 9503 2720.36 2689.01 N OSF 1.50 5389.85 4752.88 Min111-0-5F 14016.31 111 42 13941.70 1390489 190.37 OSF 1.50 7951.64 5833.13 TD 16974.23 8161 16914.82 16885.61 C OSF 150 734 48 732 20 0n7.0.SF 1482176 7940 14768.49 14742.3, OSF 1.50 776.95 77180 Mn7-0-5F 14598.72 7820 14546.26 1452052 0581.50 78097 777.73 Mn77-0-SF 14319.05 76.88 1426747 14242.114 058 1 50 78803 78461 01,7-0-SF 12812.46 6775 12766.97 12744.72 0501 1.50 833.13 828.50 0n7-0-SF 12561.98 66.37 12517 41 12495.61 ME ' OSF 150 840.01 83517 0.01-0-SF 12277.86 64.70 12234.41 12213.1 C OSF 1.50 846.82 841.77 MnR-0-SF 12171.46 64.14 1212818 12107.3®.'•.' OSF 1.50 849.89 84.75 1.15177-0-SF Drilling Office 2.6.1166.0 Nikaitchuq\Oliktok Point\OP22-WW0310P22-W W03\0P22-WW03(P4b) 3/25/2013 7:51 AM Page 2 of 5 I Offset Trajectory Separation Allow Sep. Controlling Reference Trajectory Risk Level Alert Status CI-Ct(88)I MAS(R)I EOU(ft) Dec.OD Fact. Rule MD la) I TVO(ft) Alert I Minor 1 Major _ 12099.75 6176 12056.92 1203899 28909 05F 1.50 852.08 846.86 MMR-O.SF 12198.27 6431 12155.07 12133% 288.91 OSF 150 86935 86358 04071-057 12295.48 64 64 1225193 1223064 288.87 OSF 1.50 873.15 867 26 Mm71-0-SF 12562 20 66.45 12517 57 12495.74 287.80 057 150 881 75 87560 Mnq-0.5F 12812.88 6786 12767.31 1274501 287.35 OSF 1.50 891.01 88460 Mm%-0'SF 1309998 6920 13053.52 13030 76, 28803 OSF 1.50 90244 895.71 Mnq-0-SF 1319945 69.72 13152.65 1312874 288.04 OSF 150 907.22 900.36 04n871-0-SF 14322.21 77.26 1427018 14246.9628164 OSF 150 950.17 942.17 01771-0-SF 14611.09 78.67 14558.31 14532.42 281,09 05F 150 95935 951.26 84i771-0-SF 1482595 79.66 1477238 14746.09118"M OSF 1.50 964.09 955.90 1.471.17.0-SF 14911.09 80.30 14857.23 14830.79 281.99 OSF 150 965 75 95752 Mi7Pl-O-5F 16213.14 8573 16155.66 1612741 286.96 0571.50 100244 993.55 MinFt-0-SF 16906.78 8897 16847 14 1681701 288.22 OSF 150 101415 1005.07 Min%-0-SF 1699196 8941 16932.03 1690155 288.24 OSF 150 101583 1006.73 62671-0-SF 0113-0(Def Survey) Pass imTrzi 3281 736 45271 23.83 MAS•70.00(m) 39797 397.97 84,7715 78.80 32.811 77.21 45.99 17.77 MAS•10.00(7) 45631 45827 01671-0-EOU 10996 3281 9710 77.16 MPS.10.00(m) 659.88 658.73 0i771-0-SF 130676 32.81 1291.7a 12719 iiiimglz 060•70.00(m) 3031.34 2930.79 14i7%-0-SF 5066.97 86.82 5008.76 4980.1 MEM 05F 1.50 7077.27 605618 84,771.0-SF 16937.07 114.42 16860.46 16822.65 22194 OSF 1.50 7966,76 8847.87 TO 1686517 36.16 1684071 16829.01 MEM OSF 150 770.94 76792 84771.0-SF 16209.77 3485 16186.19 16174. MEE OSF 150 784.64 781.31 M8176-0-SF 16047.71 34 51 16024.34 160112, OSF 1.50 786.67 783.29 0071-0-SF 15741 17 33.93 1571019 15707.2 MEE 057 150 79269 789.16 0i176-0-SF 1435960 32.81 14338.16 14326.1=EOM MAS•10.00(m) 823.28 87894 84i771-0-SF 1424017 32.81 1422749 142153 7264 MAS=10001ml 82642 821.99 01771-0-SF 14165.20 32.81 14144.63 14132.3- 726.48 MAS•10.00(7) 82874 824.25 0i771-0-SF • 14081.31 32.81 14061.87 1401951=EMT MAS.10.00(m) 830.91 82675 84,771.0-SF 1375204 3181 13732.06 13719.2 ME '1 MAS•10.00(m) 838.89 834.08 0n71-0-SF 13752.25 32.81 1373127 1371944 MOM MAS•10.00(m) 88404 877.83 01171-0-SF 1409194 32.81 14071 47 14059.1 1845•10.08(m) 89542 888.88 0071-0-SF 14184.14 32.81 14163.54 14151. - MAS.70.00(m) 898.78 892.14 0071-0-SF 14248.74 3201 14228.06 14215.' MI ME MAS=1000(m) 90127 894.57 0071-0-SF 14368.94 3181 1434009 14336.t4 1.1113E MAS.(0.00(0) 90594 899.17 Mm%-0-SF 14553.84 32.81 14532.71 14521.4 MEM MAS•10.00(7) 913.04 906.02 96001-0-SF • 15743.52 33.96 1572052 75708.MIME OSF 1.50 9x6.42 938.61 61170-0-SF 16057.51 34.57 16030.17 16023.01 OSF 150 954.75 946.36 UI771-0-SF 16212.71 34.89 16189.09 16177.82 MIMI OSF 1.50 956.72 94068 017 71-0-SF 1659074 35.64 16566.63 16555.11..1 OSF 1.50 964.56 956.36 M1771-0-SF 16708.59 35 80 1668431 166]231 184 1 OSF 1.50 969.40 96111 84071-0-SF 16851.88 36.18 16927 00 16815.1111111/5110 OSF 1.50 9]3.83 965.15 61071-0-SF 1981586 41.73 19787.68 (9774.1 73094 OSF1.50 1036.39 1027.00 04171-0-SF OP12-01(Oer Survey) Pass MEM 32.81 MIMI M7IIIEV 201386,60 MAS=10170(7) 7.62 7.62 gs 3281 99.48 •70.26 43.07 MAS=10 Mn 00(m) 376.91 376.90 n%s 10113 32111 99.18 70.32 37.33 8405•10.00(m) 416.28 416.27 0161.111-0-600 176.35 72.81 162.90 143.54 065•10.00(m) 847.25 842.19 0i7,71-0-5F 19595 3281 181 27 183.14 MUD MAS 0 10.00(m) 893 40 88692 0071-0-SF 1387.58 37.89 1361 99 134969 C OSF 150 467082 4197.54 74i771.0-SF 8229 78 81.41 8174.58 8147.77 15147 OSF 150 ]669.85 6566.51 TO 0111-01761(Der Survey) Pass 3261 110.1 NEM 26122 5005=10.00(0) 138.95 138.95 007715 11168 3281=EU 79.07 179.14 MAS=1000(m) 188.95 18895 6961P7-0-EOU 112.20 32.81 IMI:M 79.39 101.15 MAS.10.00(m) 298.95 298.95 MIMPT-0.601.1 315.81 32.81 299.15 28300 M 64A5•1000(rn) 125184 1243 10 84671-0-SF 117599 38.53 114995 11374 C OSF 1.50 3681.09 3433.12 01771-0-SF 1801.77 56.89 176152 1744.8-∎IIM OSF 1.50 476242 4268.29 01771-0-SF 195914 61.67 1917.70 1897.4 C OSF 1.50 5018.93 4466.40 01171-0-SF 231162 71.34 226173 2240.2 MEM OSF 1.50 563141 494100 01771-0-SF 11 2456.28 76.99 2405.96 2387.1 IIMEM OSF 150 5834.25 5096.12 84,771,0-SF 326275 8346 3206.79 317930 59.32 OSF 1.50 6510.14 5618.75 TO 0111-01(De Survey) Pass 1 111.781 32.81 110.1 7997 26112 MAS•10.00(m) 13695 13895 047 715 11188 32.81=1r 79.07 179.14 MAS.1000(m) 188.95 188.95 011471-0-EOU 11 111.20 32 81 109.88 79.39 101.15 0405=1900(m) 298.95 29095 MIMPT-0.005 315.81 32.81 29915 283.00 M MAS•10.00(0) 125184 1243.10 84,771.0-SF 1175.90 38.53 1149.95 1137.4 NEMER OSF 1.50 3681.09 3433.12 61m71-0-5F 1801.77 5619 176152 1744.89 Man OSF 1.50 4762.42 4268.29 0'm71-0-SF 195914 61.67 1917 70 189747 M OSF 1.50 5018.93 4466.40 610171-0-SF 231182 71.34 226373 224018 C OSF 1.50 5433,41 4941.00 00171-0-SF 2456.28 74.99 2405.96 2381.7 111=MI OSF 1.50 5834.25 5096.12 0071.0-5F 5806.59 66 00 5762.26 5740 59 13190 OSF 130 746907 6382.14 70 1 OP10-09(Del Survey) Pas C 32.81minEmmi 307251.25 MAS•10.00(m) 907 907 Mn71s 120.34 32.81 118.35 8753 15586 MAS•7000(m) 19907 19907 01570.0 600 186.90 32.87 17579 154.09 M. ' 5.145.1000(7) 77472 77162 0071-0-SF 124032 32.81 1220.27 1207.51 C 065.1000(m) 339188 321128 0n71-0-SF 14178.39 101.99 14110.07 14076.40 210.55 OSF 150 7921.46 6803.80 TO I 15895.60 41.77 1%167.42 158518 M. n, OSF 150 775.11 772.00 0n71-0-SF 12817.91 32.92 1279864 12784.•• OSF 1.50 850.13 844.98 0071.0-SF 1781795 32.93 12795.66 7278501 IMIMIN OSF 150 868.08 862.35 0571.0-SF 13709.13 33.97 13286.16 13275.1.=ME OSF 1.50 890.58 884 18 84071-0-5F 13566.76 34.50 1354143 13532.2- 01fl OSF 1.50 901.45 894.74 58071-0-SF•j 1366618 34 75 1364169 13631.4 M OSF 150 90518 899.15 8.1071-0-SF 1592590 4102 15897.56 15883.E r OSF 1.50 968.35 96008 58071-0-SF 1715756 4576 1712673 1711181/1112152.1. OSF 150 996.75 98795 84i7,71-0-SF OP26-09702(Del Sur•e1) Pe55 MEM 32.81=IOU 211.11 WA MAS•10.00(m) 0.00 000 Min71s ' 244.16 3181 241.70 211. 181.24 MAS.10.00(m) 308.76 308.76 0071-0-SF 242.42 3281 239.98 20861 181.1. MAS•1000(m) 398.24 398.23 890171-0-SF MEE 32.81 117.60 91.95 20.61 MAS=1000(m) 1027.65 101838 840%6 12478 31811 117.61 9198 20.40 MAS=1000(m) 1036.64 102725 MIMPT-O-EOU 12729 3281 11885 94.- 1895 6.8090 1000(m) 1082.03 707212 84061-0-SF 731.44 3281 71844 698.6 61.43 MAS•10.00(m) 269186 2647.31 88471-0-SF MEM 187.22 M4 M 11.63 OSF 750 7911.77 679441 00710 1 0709.51(0er Survey) Pas MEM 32.81 C M 282094,77 065•1000(m) 8.80 8.80 84'7715 128.56 3181 125.22 9576 59.97 MAS•10.00(m) 358]9 358.39 01577-0.500 156.68 3281 150.42 723.8 MA5=70.00(m) 710.02 708.17 04i771.0-SF 180.61 32 87 173 16 147.81 065•10.00(m) 795.17 791.58 58671-0-SF 79158 32 81 18552 160.77 28.1 0465•10.00(m) 82870 82818 044171-0-SF 1406.66 44 00 137698 1362.6 49.11 0571.50 3423.67 323430 84771.OSF I1, Drilling Office 2.6,1166.0 Nikaitchuq\Oliktok Point 10P22-WW03\OP22-WW0310P22-WW03(P4b) 3/25/2013 7:51 AM Page 3 of 5 • Offset Trajectory Separation Allow Sep. Controlling Reference Trajectory Risk Level Alert Status Ct-Ct(ft)I MAS(ft)I EOU(ft) Dev.(It) Fact. Rule MD(It) I TVD(III Alert I Minor I Major _ 358437 98.34 351848 348603 55.21 OSF 1.50 519105 4800.89 M00)-0-5F 371446 10116 364623 3812.61 55.22 OSF 1,50 531555 4695.50 Minq-0-5F 3791 76 10400 372210 3887.76 5520 OSF 1.50 5388.01 475147 0i781-0-SF 437709 119.92 4296.81 4257.16s 55.19 OSF 150 5918.56 5181.24 00181-0-50 5160.56 14185 5066 33 501171 55.33 058 1.50 6578.27 567077 14WPt-0-50 540193 147.50 5311.26 5262.42 55.37 OSF 1.50 6786.93 583193 141387-0-SF 549348 149.77 539330 534171 55.37 OSF 1.50 685835 5887.09 54001.0-SF 5667.16 154.49 5563.83 5512.68 55.37 OSF1.50 701085 600487 04,787.058 15034.81 128.26 14948.97 14906.55 177.18 OSF 1.50 7%5.75 6876.19 TO • 16756 15 92.92 16693.88 16863.2 C 058 1.50 739.92 73755 14I381-0-SF 1663850 9230 16576.64 16546.2.:M OSF 1.50 741.78 73137 Minq-0-SF 16647.12 92.75 16580.96 16554.3 1 OSF 150 1004.54 99562 14n01-0.50 16773.53 93.43 1671091 16880.11 MEE OSF 1,50 100685 997.89 0071-05F 1827363 10382 1820408 18169.81 MORI OSF 1.50 1044.85 1035.35 Minq-0-SF OFOB-04P3I(003 Survey) Pees 1 135.921 3281 MEOW non WA MAS•10.03(m) 000 0.00 Mings • 13820 32.81 134.13 10139 158.42 MAS•1100(m) 178.90 178.90 MINPT.O-EOU 209.98 3281 19195 177 171 21711 MAO•10.00(m) 75706 75434 0001.0-58 1- 1 37 05 935.09 92110 39.98 OSF 150 336113 3187.51 64•01-CICI 960.66 3142 934.6. 922.24 38.53 OSF 1.50 340212 321758 09903-0.806 961.29 3912 934.. I� 37.85 0501.50 3421.47 7171.59 Ming-0.-008 1257 49 71.97 1209.18 1185.5 26.5 0681.50 44).51 38)064 Mnq-O-SF 4632.67 131 23 454485 4501.43 53.34 OSF 150 713181 6098 80 TO I 0808-04(Del Survey) Pass C 3281 13470 103.111 425195.62 MAS.10 8% g 00)m) 890 Mn5 136.20 32.811 134.13' 10139 158.42 MAS•10.00(m) 178.90 178.90 MINPT-0-EOU 209.98 3281 19195 177.17® MAS•10.013 On) 757.06 754.34 Ming-0-SF /^1 3705 935.09 92110 39.98 OSF 1.50 336113 318751 00101-6107 960.66 38.4 C 922.24 38.53 058 1.50 3402.02 3217.58 1683-0.800 961.29 39.12 934.8 /KIM 37.85 OSF 150 3421.47 323259 0371-0-ADP 1257.49 7117 1209.18 1185.52 26.• 06F 150 4247.57 387164 843880-SF 5845.09 95,97 5750.78 5749.12 92.29 058 1,50 7460.46 6374.51 TD 010704(Oef Survey) Pass C 32•87=MI�i` WA MAS•10.00(m) 8.88 8.88 Min0IS 144.12 32.81 141.61 111.31 11097 1405•10.00(m) 308.81 308.81 074P7-0-E0U 44 17 32 81 141.65 111. NEM MAS•10.00(0) 338.57 338.57 141301-0 5F 144 32.81 141 87 11161 N MAS•10.%(m) 39009 39809 140781-0-SF 1 21864 32.81 211.64 185.8 C MAS•1100(m) 85925 853.81 Minq-0-SF 2267.89 89.56 2207.85 2178.3 i=TiliE 058150 426643 3885.20 14i301-0-5F 8001 45 170 78 7887 27 7830.67 7168 OSF 1.50 7476.63 6388.84 TO 01%415851(000 Survey) ''1 Pass 159.67 32 81 157 35 126.81 145.35 MAS•10.0010) 219.07 21907 Mn87s 159.67 3281 156.97 126.% 10760 M65•10.%)m) 259.02 259.02 Mn815 �'1 161.4 31811 155.65 129.03 32.31 MAS.10.%(m) 496.21 496.11 MINPT-0-006 16307 3281 155.74 13126 2653 1.445.10.00(m) 545.34 54508 011487.0-600 21613 40.82 188.71 175.811111111111 OSF 1.50 1006.06 997.11 Mnq-0-SF 7960.67 21627 7816.16 774a 4.0 0681.50 6802.61 584404 1.10q-0-SF 8211,87 223.15 %62.78 7988.72 N OSF 1.50 699104 5991.12 Ming-0-5F 931969 22847 9167.04 909121 6144 0601,50 7319.50 6252.53 TO 006-05(De7 Survey) Pass 159.671 3281 157.35 126. 14535 MAS.10.%(m) 21907 219.07 MmP5 159.61 32.81 156.97 12686 10760 MAS.10.%(m) 25902 259.02 Mmgs 16184 32811 15565 129.03 32.31 SIAS•10.00(m) 496.21 496.11 MINPT'0-E0U 16307 3181 155.74 130.26 2653 MAS.moo(m) 545.34 54508 0415P3-0-000 216.33 4182 188.71 175.51 C OSF 1.50 1006.06 997.11 0m01-0-SF 7%0.67 216.27 7816.16 7744,4.C OSF 1.50 6802.61 58444 66387-0-5F 821187 223.15 8062.78 7988.72=En OSF 150 6993.04 5991.12 00701-0-SF 8311.70 22585 8160.81 8085.8 C OSF 150 7073.13 6052 98 Mnq-0-SF 974821 22837 9595.64 9519.84 64.30 0581.50 740300 6324.17 TO OP05-06P821007 Survey) Pass NEM 32.81 16589 134.891 286.71 MAS.10.%(m) 14894 148.94 08i305 167.74 32811 16583 13493 24569 64A5•10.00(m) 16894 168.94 0,IINP3-0-E00 26177 32.81 247.72 230.%® HAS•10.%(0) 96122 955.05 M'nq-0-SF 9696.62 23707 9538.24 9459.5 C OSF 1.50 707570 6054.97 14101-0-SF 9938% 23981 9779.89 97%35 62.48 0581.50 7)56.98 611879 TO OP0506(De Survey) Pass C 32.81 165.89 134. 286.71 MAS•10%On) 148.4 1414 SAW. 167.74 32.81 165.8 134.93 245.69 MAS•1000(m) 16891 168.94 MI74PT •600 263.77 3211 247.72 230.%® MAS•10%(m) 963.22 955.05 Ming-O-SF 9678.38 237.00 9520.06 9441.39M 0581.50 7076.56 605563 Min01-0'SF 11119.38 244.64 1095596 10874.74 68.45 OSF 1.50 7403.98 632511 TD OP0806P81(LW Suvy) Pass 167.701 >?81 16589 131.89 286.71 MAS•10.%(m) 14194 148.4 MnRs 167.74 32.81 165. 134.93 24569 MAS•10.00(30) 168.4 168.4 MINFT-0-600 263.77 32.81 24772 231%® MAS•10,00(0) 96122 955.05 Mi301-05F 4814 32.81 546422 451.03 29728 544,5.10.00(m) 267023 262631 TO OPO4.07P81)087 Survey) Pass I 175.151 32.81 17274 142.341 146.49 MAS•10. (m) 278.84 278.84 Mg n5 175.18 32.811 172.70) %142.37 138.71 MAS=10.%1m) 298.4 29884 1417403-0-600 175.22 32.81 172.74 142.41 138. 645.10.00(m) 308.76 308.76 14n01-0-58 • 28336 32.81 278.29 250 73.52 MAS•taco(m) 896.93 890.35 144187.0-5F 50022 15109 4894.50 484213 47.7 OSF 1.50 74520 6008.24 14n01-0-SF 6949.96 155.64 645.88 6794.32 67.40 OSF 1.50 7441.% 635823 TD 0PO4-07(Der Survey) Pass 1 175.151 32 81 72)4 42.41 146.49 MAS•10.% 4 g (m) 2]8 2]8 84 Mins 05.18 32811 172.]01 142.37 138.71 1145•moo pa) 2984 290.84 M1117-0-800 175.22 3281 172.74 14241 S MAS•1000(m) 30876 30876 14n87-0SF 283.36 32.81 278.29 250.5® MAS•10.00(m) 896.93 890.35 14n01-0SF 5000.22 1.5809 489449 4842.13 MMf. 058 1.50 7015.20 6008.24 001W-0-SF 8387.82 152.91 8285.55 8234.91 82.80 06F 1 50 760861 650716 TO OP03.F05802(13e7 Survey) 8096 763.85 32 81 182.55 151.41 2544.59 MAS•10 00(m) 68.00 68.00 140gs 83.9 3281 181.% 151.15 219.08 1,105•7000(m) 24327 24337 Mngs 14.05 32.111 181.80 15124 177.96 MAS.law(no 289.00 289.00 69883-0.800 2%95 3281 285.42 25814 MOM 1405.1000 On) 918% 910.94 04n81-0.58 316.82 3281 310.4 284.01 EMME MAS•1000(m) 990.43 981.75 Mnq-0-SF 598.98 3281 5%23 566 1 =gm 045510 0(m) 1740.61 1729.70 0 •80-68 5022.99 137.76 493083 1885.24 C 068 1.50 553213 4862.86 0m01-0-6F 5402.36 146.72 530289 525164 1111111gal OSF 150 5825.17 508911 0087-0-5F Drilling Office 2.6.1166.0 Nikaitchuq\Oliktok Point\OP22-WW03\OP22-WW03\OP22-W W03(P4b) 3/25/2013 7:51 AM Page 4 of 5 • • Offset Trajectory Separation Allow Sep. Controlling I Reference Trajectory Risk levet Alen Status CFCI(11)I MAS(R)I EOU(ft) Dev.(R) Fact. Rule MD(ft) I TVD(1f) Alert I Minor L Major 562933 15453 5525.71 547440 54.84 056 1.50 600195 522565 84015.0.SF 6058.19 166.39 5946.93 589150 54.93 OSF 1.50 634605 5491 42 MinP9O-SF 6086.24 16716 597447 591507" 54.93 OSF 1.50 6370.31 5510.16 M0P90.56 6249.84 171.34 613528 6078.50 5502 OSF 1.50 6,195.09 560153 TO OP03-P05(Del Survey) Pass • 11.3,85 3211 182.5"5 151.04 254459 MAS+10.00(m) 68.00 60.00 Minns 18390 32.61 181,901 1511 21958 MAS=10.01(m) 243.37 24137 MnFes 184.05 32.811 161.80 151.24 177.96 MAS=10.00(m) 28900 289.00 MISIPT.0.600 290.95 32 81 28542 258.14=ME MAS=1000(0) 918.09 91094 98i591A-SF 316.82 32.81 31094 284.01.E M4S=10.00(m) 99543 981.75 94301.0.SF 59198 32.81 59123 566.1. MAS=10.00(m) 1740.61 1729 70 MnR-0-SF 5022.99 137.76 4930.83 4885.24 IMZ'.' 056 1.50 5532.23 4862.86 84071-03F 5402.36 148.72 530289 5253.64 C 056 1.50 5825.17 5089.11 684901-03F 562933 15493 5525.71 54744.MI 006 1.50 6001.95 5225.65 9901-03F 6118.66 168.51 6006.00 59501 MEM 0561.50 640443 5536.50 Mnq-O-SF 6453.29 177 72 6334.48 6275.57 C 056 150 6687.22 5754.92 MnRASF 6489.28 178.70 636982 6310..MICR 050 150 6716.79 5777.76 81001-0SF 6892.37 18962 676562 6702.74 E�2E OSF 1.50 704011 602748 10001-0-5F 8019 09 189 27 7892.59 7829.82 6388 OSF 150 7321.83 6254 50 TD OP03-PO5PB1(13el Survey) _ Pass 183.85 32.81 182.55 15184 2544.59 5605=10.00(0) 68.00 6890 Mons 183.9 3281 181. 151.1 21908 MAS 10.01(m) 24337 24337 MoPIS 184.05 32.811 181.80 151.24 177.96 MAS=1080(m) 289.00 28900 848907-0-000 29095 32.81 28542 258.1 ' 1 MPS=100010) 9t809 910.94 84001-03F 316.82 32 81 310 94 28401 MIE MAS=1000(m) 99543 981 75 MmP4D-SF 598 98 3281 590.23 566.1. MAS=1000(m) 174561 1729.70 140191-0-SF 370478 8493 364712 3619.85 MOE 056 130 4203.80 3836.83 MnH-0-SF 01k1ck P9111-2081(Del Survey) Pass 192.45 32.81 19117 159.64 WA MAS=10.00(0) 500 500 Surface =ME 3281 191.37 159.64 WA MAS=70.00(m) 4000 4000 00019 188.83 32.81 186.09 156.02 113241 MAS=10.00(m) 414.76 414.75 MinR-0SF 32.811 185.411 155.29 11537 MAS=1900(in) 492.25 492.15 840015 268.94 32 81 262.92 236.13 5422 MAS=10.00(m) 94973 941.85 0001.0-SF 314 28 3281 307.40 281.47 53.99 MAS=10.00(m) 1067.36 105759 Mi161-0-SF 351.73 32.81 344.10 318.92 53.47 MAS=10.00(m) 1154.76 114431 MinR-04F 36051 32.81 35271 327.70 5346 MAS=10.03(m) 117195 116742 (4007-0-SF 348088 11529 338302 3344.58 4501 0501.50 6291.56 544933 68001.03F Oliklat Point 1-2(Del Survey) Pass 192.45 32.81 191.37 159.64 WA 1.40$=1080 9,1) 000 0.00 Surface 3281 191.37=KM WA MAS=10.00(m( 4900 40.00 100Ra 188.83 3281 186.09 156.. Main MAS=10.00(m) 41476 41475 84001.0-SF 32.81amamC 116.37 68890 1050(m) 49225 492.15 440015 26194 32.81 262.92 2361 MrEE 8050010.0000 94973 94185 MmR-0-SF 314.28 3281 30740 2814 1111Man MAS=0100(m) 106716 1057.59 MnO40-SF 351.73 3281 344.10 318.920 MAS=1000(m) 1154.76 1144.31 84001-0.50 360.51 32 81 352 71 327.•MEE MAS•1000(m) 117195 116342 005.0.50 314644 10341 307717 3043.0 C OSF 1.50 586842 5122.51 6400•-0-SF 8458 53 104 83 8388.31 835370 122.17 0561.50 764948 6545 62 TO 0807*Pant 1.2082(Del Survey) Pass 192.45 32.81 19117 15964 MA MAS=10.00(0) 000 0.00 Surface E 3281 1913=;, WA MAS=10.00)0) 40.03 40.00 MmRs 168.83 3281 186.08 156.,•MIME 8.500=1000(0) 414.76 814.75 66001-0.5F MIMI 32.81 CC 116.37 MAS=10.00 on 49225 492.15 Mons 26594 32.81 28292 236.1 Min 1.1A9•1000(m) 94973 941.85 MnR-0.SF 314 28 32.81 307.40 2810 C MAS=1000(m) 106716 105759 8001 0-SF 351.73 32.81 344.10 318.92 M MAS=1000(m) 1154.76 1144.31 000n-0-SF 360 51 3281 352.71 327.7.C MAS=10.00(m) 1173.95 1163.42 68001-03F 314644 10141 3077.17 304303 C 0501.50 586842 5122.51 4*101.03F 5855.12 11518 5777.87 5739.74 7176 OSF 150 735379 6281.72 TO 0)1941(Pointl-1(Del Survey) Pass 200.49 32.81 199.37 167.68 WA MAS=1900(m) 000 0.00 Surface MI= 32.81 199.37 167.681 628114,66 MAS•10.00(m) 40.10 40.10 Minns 200.57 32.811 199.281 167.76 1159.76 MAS=10.00(m) 7920 79.20 841907.0.600 377.07 32.81 369.59 344.26 C MAS=1000(m) 1001.06 992.20 84i101-0-SF 723122 58 13 719414 7175..•NEM 006 1.50 348156 327924 0001-0.9F • ) III Drilling Office 2.6.1166.0 Nikaitchuq\Oliktok Point\OP22-WW03\0P22-WW03\0P22-WW03(P4b) 3/25/2013 7:51 AM Page 5 of 5 9 9 ( ) 9 Schlumberger TRAVELING CYLINDER PLO T NoGo Region EOU's based Client: ENI on: Oriented EOU N Well: OP22-WW03 Dimension A-. Field: Nikaitchuq Structure: Oliktok Point NoGo Region Anti- *4 ■IF Collision rule used: Minor Date: March 25, 2013 Risk - Separation Factor North 0 - 800 'and 350 0 10 340 Ai _� �/,� 20 330 �� i/ C" -� a y30 ,./.iii ► -y, ,/a ` ., ..320 � 40 310 ` 1 if'`�/ `� I,�,� - \ 300 arl\� ��► � �� Ofli� �� :A 60 •At 2so . gh,�*4. t�ri ►4ill iar. 1104 vA 70 Aill' atost*,/ li■ 11;;ZAtk■i".,....-,:;■18u-t:i :\ ,280 la w \l r_, .- _ r.` ,'�I . '�\ �- ■,®�ezv�� yr ik A, ,0`` 80 0.1Pez4,44;;:■. ift• ii.9.' -:"1-.7---- '0:0411i-77,-,-i-iig74%'v7 i h't lei 270 /2so _► � , 4.V` .4T. -A�A:1 �� 100 ibb*M16.11 250 ,1� ' �' ,;��_7 &•�ikliti►P�`1. ` -•110 • ir 240 . / , �,.' % 120 '7,4;•,"1--. ....- II.at'.■. __.....004* all li 230 ill"`k�'-. r , ,..1/4.,, 230 I i itfil INWts 'Ir 220 AlrjllIllVplia.i" 140 11► I�OP21-VWV01 210 � �,�50 200 160 Well Ticks Type: MD on OP22-WW03 (P4b) Calculation Method: Normal Plane Ring Interval: _5.00 ft Azimuth Interval: 10.00 deg Scale: 1 INCH= 10.00 ft Schlumberger TRAVII,ING CYLINDER PLO T NoGo Region EOU's based Client: ENI on: Oriented EOU N Well: OP22-WW03 Dimension A., Field: Nikaitchuq Structure: Oliktok Point NoGo Region Anti- ,4 f�• Date: March 25, 2013 Collision rule used: Minor Risk - Se.aration Factor North 0 - 800 'md 350 ° 10 340 10 a WIFA �NIP/20 330 ,�'��+i 30 320 a;,'. .,.1��i�i,j�,� �I:S1!:-10(D9 i 1 I- ' 1tt� \f�, . ::�•. -0•�S1 ,.a�.Q,j►,, it AI41 ;►r'1;:`;..., - ‘-08-04PB1`i,'L4i-.7�� L! y f`•• t �'‘-•�' . e107-04■40!4-1. �i•,-1► ! r• •∎•,a ., .N 60 ■ ``•,�*�, 4p, ijj , e ,..0,, ,, . ''`,1106-05PB1 29V'i��'��i l�! 1, 70 I.�, ` Pi •./. Ise k, `. —�►�280 p4 �/1,.. %:I! ` . \., - - ��' 80 270 . 4 F Ilhilti%e,";/.1- ��t r��_�_ i1L. ,, ��. Mfr i. Ar / 11111111 260 ii •111 . 0��.r1'11:: 'a,° y / _. 100 .•, "J ' vim; *MI 0 250 ,■t, #4P,'.4 110 1111k .��0 o w'31 •■III 240 •.,, Oc'' 0 120 . % 230 .� i 130 ` 220 ` �s ' 140 210 W&■*111111111111111100101 50 2000 160 Well Ticks Type: MD on OP22-WW 03 (P4b) _ Calculation Method: Normal Plane _ Ring Interval: 5.00 ft Azimuth Interval: _110.00 deg Scale: 11 INCH=50.00 ft Schlumberger TRAVELING CYLINDER PLO T NoGo Region EOU's based Client: ENI on: Oriented EOU ?v Well: OP22-WW03 Dimension . �, Field: Nikaitchuq Structure: Oliktok Point NoGo Region Anti- i�f�• Date: March 25, 2013 Collision rule used: Minor Risk - Se'aration Factor F North 1 800 'md - 4000 'md 350 0 10 T 330 , ` � i;vir�,�apo.%_30 iiiropi 320 44 !4)24450� � , -.._ ....►��._ !ii 300 ts'��' \�/ :t' �; •------ i 290 .?zw • ``'•,�� ±,, , i11�%. I■„\\Itai.,4.41110411,1 280 rellrgy ♦ \ .�� 80 liggilli Pm"1,41TII.V \♦ ��i�l, l,1 ,, A, filmanlft,i, "1111Varwmmum 270 * -./ ��-'c ��m . 90 IN 1 r 260 .r ,�'•� 'Ali t>`• 100 250 imi, .. .� .#1110 �•► ■Ea 1 2410,94 \teitiet):70.1 12 0 �� r� . (�tp1-WW01 220 , 11111.11111.1. 140 210 . 200 60 Well Ticks Type: MD on OP22-WW03 (P4b) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: IN=%50.00 ft Schlumberger TRAVELING CYLINDER PLOT NoGo Region EOU's based Client: ENI on: Oriented EOU N Well: OP22-WW03 Dimension •• Field: Nikaitchuq 4 Structure: Oliktok Point NoGo Region Anti- •�f�• Date: March 25, 2013 Collision rule used: Minor Risk - Separation Factor North 4000 'md - 7700 'md 350 0 10 340 320 020 330 111111 300 *30 sit i 280 0 40 320 Oil 26'M 240 310 • 220 ' 50 01111141* 300 , �® 44460 ip 290 ♦ . ■R ♦ ♦ sI 2 /270 0 11111111111111agrir-260 II .i �i1►,,�t1 ilfOlap ,00 250 0 0 •....• s ®: �, ` 110 o 9)cn e* 4/1111111114 ex 240 •■■• • ° °°w c, 120 o 230 \S / 130 ♦�411..■r�I 220 `•-r' 140 210 _-'�50 20'�_�60 Well Ticks Type: MD on 0P22-WW03 (P4b) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: 1 INCH= 100.00 ft Schlumberger TRAVELING CYLINDER PLO T NoGo Region EOU's based Client: ENI on: Oriented EOU 3`1 Well: OP22-WW03 Dimension 4* Field: Nikaitchuq Structure: Oliktok Point NoGo Region Anti- c ■V Date: March 25, 2013 Collision rule used: Minor Risk - Separation Factor North 7700 'md - TD 350 0 10 34320 20 .r280 260 �� 40 MIMI 240 310 , I 220 b 4 W 300 -® 4, 444460 wge s 290 ■♦VIIIII. ♦ , 70 280 iS 011 gilt t t ', ,,.. . , 80 270 111111Millititratt4r44411111111111111 260 51111.130 4 37.1I1et 1��'��i41, 4.141°t4';'250 ?10b00 0 c4 4411 1110V o el e4 11411110 Ob * 240 O 40 120 o 230 ♦,,'--r I f 130 220 ftallialgl.' 140 21` __ �50 200__60 Well Ticks Type: MD on 0P22-WW03 (P4b) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: 1 INCH= 100.00 ft 1 re��pgap a t. I() g B n` N b O W E=P9sx x a O o Z Jh a Z 0x Wax k �Q x 8 J �-0 J �a Z J J Z J � \L ge J i 1 JJZ W W N I O U CO Z g� I Z MZO_(1� r")0O^ J� Liu r'O(n0�NF �s t QUZ^ W �_I (n_ W^ C c 4 ct0 —lc) z--.1.Q_ 0o\acs, -..J 6-2 - Y oz� �o o g = to i x t. N a v N 1 act m< og 3;., oo Lr;O J t J O z I U M , , V N ILI O I\ a a - - - 4)1 + N - -1 n , t-7 f—7 , n_ y OD O 0\—. acv — u) 4 O N CO a KK1 i a O Z W CO 3-, W yam, J 3 °oQ WI o�> X I W 0 1 4i PIM� % a 1 cc 0 9 li X 1 Ii 1 Z sago c ti m _ • g �I■ Wo sti w • QC� J LL d I " ro cc 0 1111 _ 11 � co a W a a. - l -.. _�_ ' - I 1I'1111''I1I 5 OI'I � 1 '�-��Iv &I III a n....... c.,) �5$§° Ili d� .w,-,-, §40 m Eig o % ' a b'l Q i lei h y (v>>�N h2 �~N N_ O 2 ,h 3k C a 0 Q 7 aU h 11:1 Z 1.3 \ 1 I No"N ,o , - fif 11,i N O rc 11\11- ., _ < Z to Lam A V Z a �, 1 L W III"' IL w O o _ _ 111 Y « \I a 1 I 0 A o m r-7:4p N N Q' W i \1v�1 k222 § § g.I D 2 a a :fa .4/L+-.e k 0 I p E � p Ilit • %IP . o i-or ,„,41i, !„ A , o8 , `hiw ig.1'/ ■ i :miff asAii,),.4.- N O ' O . 1 a) a) 0 r ,... , i k ollipoijork c c co co a) v c c c U) \ tr 0 0 0 ° o . :J as ccoo co 3 '� C 2 2 2 2 a� 2 0 0 0 0 co a ai 0 r f r > w •.. ] c RS w 0 4 cv 4 c� s 0 m G7 Q > o I-- .0 r � 0 .—°oU c co >, c >, > aaa � � _ z CC E 2 co ca U _ -c o a> o . z Iz mow co ' IP' ED a) cz Schlumberger CemCAD E* well cementing recommendation for Surface Casing Operator : Eni Petroleum Well : OP22-WW03 Country : US Field : Nikaitchuq State : Alaska Prepared for : Mr.Luca Borri Location : Oliktok Point Proposal No. : v1 Service Point : Prudhoe Bay,Alaska Date Prepared : 4/9/2013 Business Phone : 907 659 2434 FAX No. Prepared by : Stephen Lauper Phone : 907 952 0445 E-Mail Address : SLAUPER@slb.com O • • • Oh. 1VRTE Disclaimer Notice: Schlumberger submits this document with the benefit of its judgment,experience,and good oilfield practices. This information is provided in accordance with generally accepted industry practice.relying on facts or information provided by others,limitations,computer models,measurements.assumptions and inferences that are not infallible. Calculations are estimates based on provided information.All proposals,recommendations,or predictions are opinions only. NO WARRANTY IS GIVEN CONCFRNNG ACCURACY OR COMPLETENESS OF DATA,INFORMATION PRESENTED.EFFECTNfNESS OF MATER Led,PRODUCTS OR SUPPI IFS.RFCOMMFNCATIONS MADE.OR RESULTS OF THE SERVICES RENDEIED. Freedom from infringement of any intellectual property rights of Schlumberger or others is not to be inferred and no intellectual property rights are granted hereby Mark of Schlumberger Page 1 0P22-VVW03 CemCADE.ctw;04-10-2013: LoadCase 13-3/ein Surface Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : 0P22-WW03 ScMumberger String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/8in Surface Casing Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 3991.0 ft BHST : 50 degF Bit Size : 16 in ft (x 1000) psi I ) — — — L 0 2.5 -Siltstone— . .• Sandstone - � ■ , 1 ' - • ,_ �� - - _ M tti _ • • •Sandstone • • • , Ca 11 Coal M • 0 'v";ell Litholagy Formation Press. Page 2 0P22-WW03 CemCADE.cfw:04-10-2013: LoadCase 13-3/Bin Surface Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : OP22-WW03 Schlumliergcr String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/Bin Surface Casing Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 160.0 20 169.0 18.376 Landing Collar MD : 3911.0 ft Casing/liner Shoe MD : 3991.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 3991.0 13 3/8 40.0 68.0 12.415 L-80 2270 5020 BTC Mean OH Diameter : 16.000 in Mean Annular Excess : 105.6 % Mean OH Equivalent Diameter: 18.370 in Total OH Volume : 1255.8 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. (ft) (in) (%) (in) 1800.0 16.000 200.0 20.254 3991.0 16.000 35.0 16.822 Max. Deviation Angle : 39 deg Max. DLS : 3.084 deg/100ft Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (113/gal) 717.2 11.50 8.39 SV-4 Siltstone 966.0 11.50 8.40 SV-3 Sandstone 1228.5 11.50 8.40 SV-2 Shale 1710.7 11.70 8.42 SV-1 Siltstone 1800.0 12.00 8.43 Permafrost Base Coal 2032.9 12.30 8.44 Ugnu Top(UG4) Shale 2518.8 12.60 8.45 UG-2 Coal Bed Sandstone Marke 3299.4 12.70 8.50 Lower Ugnu Coal 3551.9 12.60 8.60 Schrader Bluff Top Shale 3584.8 12.60 8.60 N Seq.Top Sandstone 3633.1 12.60 8.60 N Top Sandstone 3672.0 12.60 8.70 N Bottom Sandstone 3723.7 12.60 8.70 N Seq Base Sandstone 3800.3 12.50 8.70 OA Top Sandstone 3811.2 12.50 8.70 OA-2 Top Sandstone 3821.6 12.50 8.70 OA-3 Top Sandstone 3839.3 12.50 8.70 OA-4 Top Sandstone 3991.0 12.50 8.70 TD She Page 3 OP22-WW03 CemCAOE.cfw;04-10-2013; LoadCase 13-3/Bin Surface Casing:Version wcs-cem472_05 Client : Eni Petroleum Well : OP22-WWO3 ScMlmnlie String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/Bin Surface Casing Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 1800.0 1789.0 32 0.7 3991.0 3672.5 50 0.8 • Page 4 OP22-WW03 CemCADE.clw:04-10-2013: LoadCase 13-3/ein Surface Casing;Version wcs-cen1472_05 Client : Eni Petroleum Well : OP22-WW03 Scam limier String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/Bin Surface Casing Section 2: fluid sequence Job Objectives: ArcticSET Light cement to Surface, 500' 12.5 ppg DeepCRETE Slurry Tail Original fluid Mud 9.60 lb/gal k : 5.41E-4 Ibf.s^n/ft2 n : 0.975 Tv : 17.24 Ibf/100ft2 Displacement Volume 585.6 bbl Total Volume 1312.6 bbl TOC 0.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 100.0 0.0 10.10 k:6.58E-2 Ibf.s^n/ft2 n:0.291 Ty:6.34 Ibf/100ft2 Lead Slurry 564.0 3486.4 10.70 k:1.87E-1 Ibf.s^n/ft2 n:0.276 Ty:1.48 Ibf/100ft2 Tail Slurry 63.0 504.6 3486.4 12.50 k:2.53E-2 Ibf.s^n/ft2 n:0.624 Ty:27.12 Ibf/100ft2 Mud 585.6 0.0 9.60 k:5.41 E-4 Ibf.s^n/ft2 n:0.975 Ty:17.24 Ibf/100ft2 Static Security Checks: Frac 7 psi at 160.0 ft Pore 19 psi at 160.0 ft Collapse 1904 psi at 3911.0 ft Burst 5020 psi at 0.0 ft Csg.Pump out 90 ton Check Valve Diff Press 237 psi ft (x 1000) psi < 0 25 i lir 1 -Hydrostatic - • ---Frac -Pore c. C"4 r_, C, C' Fluid Sequence Static Well Security Page 5 0822-W W03 CemCAUE.ctw;04-10-2013: LoadCase 13-3/8in Surface Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : OP22-WW03 Sclimberger String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/8in Surface Casing Section 3: pumping schedule Start Job: Circulate Two Hole Volumes; Safety Meeting; Test Surface Equipment Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 5.0 100.0 20.0 100.0 80 Spacer Ahead Pause 0.0 0.0 10.0 0.0 80 Drop Bottom Plug Lead Slurry 5.0 564.0 112.8 564.0 80 Mix&Pump Lead Slurry Pause 0.0 0.0 5.0 0.0 80 Tail Slurry 4.0 63.0 15.8 63.0 80 Mix&Pump Tail Slurry Pause 0.0 0.0 10.0 0.0 80 Drop Top Plug Mud 8.5 575.6 67.7 575.6 80 Kick Out Top Plug Mud 2.0 10.0 5.0 585.6 80 Slow rate for Plug Bump Shut-In 0.0 0.0 3.0 0.0 80 Line Up Rig Pumps Total 04:06 1312.6 bbl hr:mn End Job: Bump Plug; Check floats Dynamic Security Checks: _ Frac 3 psi at 160.0 ft Pore 10 psi at 160.0 ft Collapse 1904 psi at 3911.0 ft Burst 4587 psi at 0.0 ft Temperature Results BHCT 64 degF Simulated Max HCT 73 degF Simulated BHCT 73 degF Max HCT Depth 3991.0 ft CT at TOC 67 degF Max HCT Time 04:06:15 hr:mn:sc Static temperatures: At Time (hr:mn) 00:03 hr:mn Geo.Temp. Top of Cement (degF) 67 degF 20 degF Bottom Hole _ (degF) 73 degF 50 degF Page 6 OP22-WW03CemCADE.cfw;04-10-2013; LoadCase 13-3/Bin Surface Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : OP22-WW03 Schlumberger String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/Bin Surface Casing Simulated ECDs at Surface Shoe during Placement o Depth= 3991 ft pi Frac Fbre t _ 4- ._-1---i-- -1- I 4 } 1 --�—_i._..j_ } .___ _.- 1-_.�_ Ln - Hydrostatic CI uynamc __W __, nu_ __ ._ _ I ' i gams . ......_ _ . ., __, _ ___ .... _ ....,.. _, ,r, ____ IMMINIIIIIMINI In 1 MI —IIIIIIIMINI/ I--•I 1)cp. 111111111 ' . 1111 MINNINNIIIIIYANNISE=111 I _ :, ... . — sz-4 _ = _ . 0-- ---_� . ski_ J a== -s !�,_ _ ; _.. .—�.... __s. n _um _m - - :M - Ilia— -- E� M, - G 1 l. 111111111111111111111111111111111_ = - — I ME I .�. Lo cd I I - -T I I 1 ----.--- I I 0 30 60 90 120 150 180 210 240 270 Time (min) i Page 7 OP22-WW03 CemCADEcfw;04-10-2013: LoadCase 13-3/8in Surface Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : 0P22-WW03 Schlumberger String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/Bin Surface Casing Simulated Surface Pressure during Placement CD O —Calc.PLmp Press. . —Calc.Cerr11-IP --_— O 1 f` O 1- O N O i k 1 -- cn° 1. 1 - ` 1 t- o El CD- ''.."""i........T.%.„............r........,. -- — l i r O r , r r , r r r 1 0 30 60 90 120 150 180 210 240 270 Time (min) Page 8 OP22-WW03 CemCADE.cfw:04-10-2013: LoadCase 13-3/Sin Surface Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : OP22-WWD3 Schlembergcr String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/Bin Surface Casing Simulated Slurry Temperatuers during Placement CV°O Last Sack Ternp �-O ■ First Sack Temp. ��:� NM in API BHCT --- m--- �-- N c00"1 ��■1.M MN �� O ■..� ■■■p ■ ■: : o �_ ..� . Lo ■ 1111111111111111 INIM ■■■�■� OE. M -o (D 111111111111.1111,11.11 IIIHIIIIIIIIIIUIIIIIIIIMIIIUIIII 0 ■ � =a■■ ■::: = ° N : s . " ■ "" " ■ "■ ■ ■■ ■S■ ■ ■ .cu CL 0 _: (1) --In ■ .. . ■ _ .a i - ■� r . . N _- i ....ce ___ . ....... . _ N 1 - ■ '_ � __ =__ 011 _ �•_ ........ Nam �� - c,i CO all "" In ■ ..:mot-_ =M- _ CO- _ _ .MI 0 lP 0 30 60 90 120 150 180 210 240 270 Time (min) Page 9 0822-WW03 CemCADE.cfw.04-10-2013; LoadCase 13-3/8in Surface Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : OP22-WW03 Undergo' String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/Bin Surface Casing Simulated Slurry Temperatures up to 24 hours after Placement N- O — Last Sack Temp. L-- - - - - FrstSack Temp. _._ _ • as -u - - IN - _ . N AR BC O • m •• • • •• • • _o ... ...._�/��.l..5......==�L�!■!ii o,, co L ........E.T.................., „......H ...... ... ... . ........... 6 IIIIIIH!IIIHIIIIIIIIIIIII 3 OM E ■ III MI _.M __. o 4) _ _ MENU .._•.m... mum_. N O S- u) . . -„' x_.._ a ■m mg um Iil a Q- _••:E ■ ■ __ _ ■■_ : _o S.. m . . .. • �..m�!�1.... N aaa_ as uuu• a ••.•aaMIZM.■ _ MI _ MUM .. ......� ........mmi, _L RI! ■M MI �MMI•NIMMEMM■MOIMMEMMI•I�M� -N_ Iiiir MMINNOMMIIIMMMIIMMIMMOIMMMIMM �_ ��11��n��MINUMI�■ _ S . ° amama= IN a am MOM aa11MMEM MEM N O r r r i i r r r r M 0 200 400 600 800 1000 1200 1400 1600 1800 Time (min) Page 10 OP22-WW03 CemCADE.cfw;04-10-2013; EoadCase 13-3Bin Surface Casing;Version wcs-cem472_05 .--_... ...... Client : Eni Petroleum Well : 0P22-WW03 Schhniorger String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/8in Surface Casing Section 4: fluid description Mud DESIGN Fluid No: 1 Density : 9.60 lb/gal Rheo. Model : HERSCHEL_B. k : 5.41 E-4 Ibf.s^n/ft2 At temp. : 120 degF n :0.975 Ty : 17.24 lbf/100ft2 Gel Strength :32.02 Ibf/100ft2 MUD Mud Type :WBM Job volume :585.6 bbl Water Type : Fresh VOLUME FRACTION Solids :4.0% Oil : 0.0% Water :96.0% MUDPUSH II DESIGN Fluid No:2 Density : 10.10 lb/gal Rheo. Model : HERSCHEL_B. k :6.58E-2 Ibf.s^n/ft2 At temp. :80 degF n :0.291 Ty :6.34lbf/100ft2 Gel Strength :(Ibf/100ft2) Job volume : 100.0 bbl Lead Slurry DESIGN Fluid No:3 Density : 10.70 lb/gal Rheo. Model : HERSCHEL_B. k : 1.87E-1 Ibf.s^n/ft2 At temp. :76 degF n :0.276 Ty : 1.48 lbf/100ft2 Gel Strength : 11.88 Ibf/100ft2 DESIGN BLEND SLURRY Name : B809 Mix Fluid :9.609 gal/sk Job volume :5 Dry Density : 103.77 lb/ft3 Yield :2.25 ft3/sk✓ Quantity 1408.54 sk Sack Weight : 100 lb Solid Fraction :42.9% BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid :9.609 gal/sk Page 11 OP22-W W03 CemCADE.cfw;04-10-2013; LoadCase 13-3/8in Surface Casing:Version wcs-cem472_05 Client : Eni Petroleum Well : OP22-WW03 ScIimtirger String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/8in Surface Casing Tail Slurry DESIGN Fluid No:4 Density : 12.50 lb/gal Rheo.Model : HERSCHEL_B. k :2.53E-2 Ibf.s^n/ft2 At temp. :76 degF n :0.624 Ty :27.12 lbf/100ft2 Gel Strength : 74.59 Ibf/100ft2 DESIGN BLEND SLURRY Name : 12.5(0.76) Mix Fluid :5.198 gal/sk Job volume : I Dry Density : 119.32 lb/ft3 Yield : 1.55 ft3/sk Quantity :228.57 s Sack Weight : 100 lb Solid Fraction :55.1 % BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid :5.198 gal/sk Additives Code Conc. Function D046 0.200%BWOB Antifoam D065 0.500%BWOB Dispersant D167 0.250%BWOB Fluid loss S002 0.500%BWOB Accelerator • Page 12 0P22-WW03 CemCADE.cfw;04-10-2013; LoadCase 13-3/8in Surface Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : 0P22-WW03 Schlumberger String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/8in Surface Casing Section 5: centralizer placement Top of centralization :100.0 ft Bottom Cent. MD :3971.0 ft Casing Shoe :3991.0 ft NB of Cent. Used :48 NB of Floating Cent. :48 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min.STO @ Depth (ft) Joint (%) (ft) 1831.0 22 1/2 NW-TR-13 3/8-8-TR 3 W304 0.0 1211.0 3511.0 14 1/3 NW-TR-13 3/8-8-TR 3 W304 0.0 3466.8 3991.0 12 1/1 NW-TR-13 3/8-8-TR 3 W304 72.0 3511.0 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min.OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (lbf) (lbf) NW-TR-13 3/8-8-TR 3 W304 13 3/8 16.654 15.394 No Hannover 16.000 283.26 2832.59 ft °`o 0 70 G0 60 80 100 - —Beaver Z e-r I I I + 4kt Cent $i . 1 ' - 1. , .._______tH T7...ill ' ____ . =_ 111 ---J I f__ _ 1 a iiui- 1 1 11 I ._111 Pipe Staloff Page 13 OP22-W W03 CemCADE.ctw:04-10-2013; LoadCase 13-3/ein Surface Casing;Version wcs-cem472_05 Client : Eni Petroleum Well : 0P22-WW03 Schloberger String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/Bin Surface Casing Section 6: WELLCLEAN II Simulator ft % e%0 11 0 20 40 60 80 100 0 20 40 60 80 100 o_ -Std Betw.Cent. ——Mud Contamination 1 —Cement Coverage ■—_.... — —Uncontaminated Slurry i w_ t 7—•.. 1 I - I0 I ..r.'"- 111.1.1:."—..72-7° o I ------ J I O O O O LC)— Cement Coverage Uncontaminated Slurry Md.Cacrcdo-c Pa Mw on M Wd z z 0 0 0 0 - # 500– 500 500 - 500 1000– 1000 1000 ' 1000 — 1500– 1500 1500 .. w - �' ' 1500 • °8 .c 2000– 11 2000 -c -c 2000 11111-4, 2000 a a a 0 2500 2500 0 0 2500 z((� 2500 0 ' 3000– iiiir 3000 3000 3000 3500 3500 3500 E ` 3500 t 4000 4000 4000 4000 a) 3 a) a) 3 a) o -o o -o 3 3 L o o Z z .1'1....,, M OFVSHII •M.*, •Mar.. Page 14 OP22-WW03 CemCADE.cfw;0410-2013; LoadCase 13-3/Bin Surface Casing;Version wcs-cem47235 Client : Eni Petroleum Well : OP22-WW03 Schlirger String : Surface Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 13-3/8in Surface Casing Section 7: operator summary MIXING PREPARATION MUDPUSH II Volume: 100.0 bbl Density: 10.10 lb/gal Code Quantity Design Fresh water 92.508 bbl D046 64.652 lb 0.200%BWOW D182 555.049 lb 6.000 lb/bbl of base fluid D031 9474.279 lb 94.74 lb/bbl of spacer Lead Slurry Volume : 564.0 bbl Density : 10.70 lb/gal Yield :2.25 ft3/sk Dry Phase Liquid Phase Blend: 146099 lb Design Mix Water 334.3 bbl 10.0 bbl LAS Design Tail Slurry Volume : 63.0 bbl Density : 12.50 lb/gal Yield : 1.55 ft3/sk Dry Phase Liquid Phase Blend: 23189 lb Design Mix Water 28.3 bbl 10.0 bbl LAS Design 12.5(0.76) 22857.492 lb Fresh water 28.291 bbl 10.001 bbl D046 45.715 lb 0.200%BWOB D065 114.287 lb 0.500%BWOB D167 57.144 lb 0.250%BWOB S002 114.287 lb 0.500%BWOB Page 15 OP22-W W03 CemCADE.cfw;04-10-2013; LoadCase 13-3/8in Surface Casing;Version wcs-cem472_05 Schlumberger Ce m CAD E well cementing recommendation for Intermediate Casing Operator : Eni Petroleum Well : OP22-WW03 Country : US Field : Nikaitchuq State : Alaska Prepared for : Mr.Luca Borri Location : Oliktok Point Proposal No. : v1 Service Point : Prudhoe Bay,Alaska Date Prepared : 3/29/2013 Business Phone : 907 659 2434 FAX No. Prepared by : Stephen Lauper Phone : 907 952 0445 E-Mail Address : SLAUPER®slb.com %,, • 40ATE Disclaimer Notice: Schlumberger submits the document with the benefit of its judgment,experience.and good oilf ield practices This information is provided in accordance wdh generally accepted industry practice,relying on facts or information provided by others,limitations,computer models,measurements,assumptions and inferences that are not infallmle Calculations are estimates based at provided information.All proposals,recommendations,or predictions are opinions only. NO WARRANTY IS GIVEN CONCERNING ACCURACY OR COMPLETENESS OF DATA,INFORMATION PRESENTED,FFEECTIVENESS OF MATFRNL,PRODUCTS OR SUPPI IES,RECOMMENDATIONS MADE,OR RESULTS OF THE SERVICES RENDERED. Freedom from infringement of any intellectual property rights of Schlumberger or others is not to be inferred and no intellectual prapeny rights am granted hereby. * Mark of Schlumberger Page 1 0P22-WW03 CemCADE.ctw;04-10-2013; LoadCase 9 5/8 Intermediate(a);Version wcs-cem472_05 Client : Eni Petroleum Well : 0P22-WW03 Schlumberger String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 9 5/8 Intermediate(a) Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land 1 Mud Line : 0.0 ft Total MD : 7668.0 ft BHST : 95 degF Bit Size : 12 1/4 in ft (x 1000)psi < > 0 9 5.0 — — — • • F.- —Siltstone—_ 't,- - • INE MI- -Siltstone— U 1: 1 1 II I . . . .Sandstone. . . . III . , ' 11Ell o- Coal O I t •- f l s 1 Ihl ti 11 c_ - - -- . 1I1 _— — 11 ,t u1 - — 11 II 11 if III _ 1i I III .- 1111 _ I11 . III I I11 II 'v"Nell Litholog Formation PIESS. i Page 2 01322-WW03 CerCADE.ctw;04-10-2013; LoadCase 9 5/8 Intermediate(a);Version wcs-cem472_05 Client : Eni Petroleum Well : 0P22-WW03 Schlumbergcr String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 95/8 Intermediate(a) Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 3991.0 13 3/8 68.0 12.415 Landing Collar MD : 7588.0 ft Casing/liner Shoe MD : 7668.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 7668.0 9 5/8 40.0 47.0 8.681 L-80 4760 6870 BTCM Mean OH Diameter : 12.250 in Mean Annular Excess : 50.0 Mean OH Equivalent Diameter: 13.371 in Total OH Volume : 638.6 bbl (including excess) Max. Deviation Angle : 39 deg Max. DLS : 3.084 deg/100ft Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 717.2 11.35 8.39 SV-4 Siltstone 966.0 11.50 8.40 SV-3 Sandstone 1228.5 11.50 8.40 SV-2 Shale 1710.7 11.70 8.42 SV-1 Siltstone 1800.0 12.00 8.43 Permafrost Base Coal 2032.9 12.30 8.44 Ugnu Top(UG4) Shale 2518.8 12.60 8.45 UG-2 Coal Bed Sandstone Marke 3299.4 12.70 8.50 Lower Ugnu Coal 3551.9 12.60 8.60 Schrader Bluff Top Shale 3584.8 12.60 8.60 N Seq.Top Sandstone 3633.1 12.60 8.60 N Top Sandstone 3672.0 12.60 8.70 N Bottom Shale 3723.7 12.60 8.70 N Seq Base Sandstone 3800.3 12.50 8.70 OA Top Shale 3811.2 12.50 8.70 OA-2 Top Sandstone 3821.6 12.50 8.70 OA-3 Top Sandstone 3839.3 12.50 8.70 OA-4 Top Sandstone 3991.0 12.50 8.70 Surface Shoe Shale 7668.0 12.55 8.70 TD Shale Page 3 0P22-W W03 CemCADE.cfw:04-10-2013; LoadCase 9 5/8 Intermediate)a).Version wcs-cem472_05 Client : Eni Petroleum Well : 0P22-WW03 S Schbonloger String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 9 5/8 Intermediate(a) Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 1800.0 1789.0 32 0.7 3991.0 3672.5 50 0.8 7668.0 6562.9 95 1.1 Page 4 OP22-W W03 CemCADE.cfw;04-10-2013; LoadCase 9 5/8 Intermediate(a);Version wcs-cem472_05 Client : Eni Petroleum Well : OP22-WW03 Schiobcrgcr String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 95/8 Intermediate(a) Section 2: fluid sequence Original fluid Mud 9.60 lb/gal k:2.06E-3 Ibf.s^n/ft2 n :0.812 Ty:8.74 lbf/100ft2 Displacement Volume 555.5 bbl Total Volume 712.5 bbl TOC 6459.2 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 50.0 597.6 5861.6 12.00 k:8.54E-2 Ibf.s^n/ft2 n:0.279 Ty:2.63 lbf/100ft2 Tail Slurry 107.0 1208.8 6459.2 15.80 k:8.43E-3 Ibf.s^n/ft2 n:0.829 Ty:1.24 lbf/100ft2 Mud 555.5 0.0 9.60 k:2.06E-3lbf.s^n/ft2 n:0.812 Ty:8.74 lbf/100ft2 Static Security Checks: Frac 553 psi at 3991.0 ft Pore 172 psi at 3991.0 ft Collapse 4092 psi at 7588.0 ft Burst 6870 psi at 0.0 ft Csg.Pump out 119 ton Check Valve Diff Press 351 psi ft (x 1000)psi 0 5.0 —Hydrostatic _ —Frac -Pore - _ • o U... • _ • 0 o IIIII 1, ■ o _ rn- Fluid Sequence Static Well Security Page 5 0P22-WW03CemCADE.cfw:04-10-2013; LoadCase95/8 Intermediate(a),Version wcs-cem472_05 Client : Eni Petroleum Well : OP22-WW03 Sehlumbrger String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 95/8 Intermediate(a) Section 3: pumping schedule Start Job: Circulate Two Hole Volumes; Safety Meeting; Test Surface Equipment Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol lnj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 5.0 50.0 10.0 50.0 80 Spacer Ahead Pause 0.0 0.0 5.0 0.0 80 Drop Bottom Plug Pause 0.0 0.0 5.0 0.0 80 Line Up Cement Unit Tail Slurry 4.0 107.0 26.8 107.0 80 Mix&Pump Cement Slurry Pause 0.0 0.0 5.0 0.0 80 Drop Top Plug Mud 8.5 545.5 64.2 545.5 80 Kick Out Plug Mud 2.0 10.0 5.0 555.5 80 Slow Rate for Plug Bump Shut-In 0.0 0.0 5.0 0.0 80 Line Up Rig Pumps Total 02:00 712.5 bbl hr:mn End Job: Bump Plug; Check floats Dynamic Security Checks: Frac 442 psi at 3991.0 ft Pore 172 psi at 3991.0 ft Collapse 4086 psi at 7588.0 ft Burst 6360 psi at 0.0 ft Temperature Results BHCT 89 degF Simulated Max HCT 73 degF Simulated BHCT 69 degF Max HCT Depth 0.0 ft CT at TOC 69 degF Max HCT Time 01:55:55 hr:mn:sc Static temperatures: At Time (hr:mn) 00:05 hr:mn Geo.Temp. Top of Cement (degF) 69 degF 80 degF Bottom Hole (degF) 69 degF 95 degF `-- Page 6 OP22-WW03 CemCADE.ctw;04-10-2013; loadCase 9 5/8 Intermediate(al;Version wcs-cem472_05 Client : Eni Petroleum Well : 0P22-WW03 Schlumbergcr String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 9 5/8 Intermediate(a) Simulated ECDs at Casing Shoe ° Depth= 7668 ft r) Frac Fore 1._�h --- 4 _ .L ' }..---1--- ----} um LO d ,(ostatic --- .am. Dynamic MIMI IIIIIIIIII MI LI r........- ' .-1 - ,- ,_ . -�___ _- .-------------••— ........ — - ---- — ----EI MI �::—=s—:ANN— - — _- Min ' --�� d o- _ _ ..Ei Q° - ...r.�. _ _.., L. ... in _—__ � = _ = ""-' w 1 I 1 1 0 20 40 60 80 100 120 140 Time (min) Page 7 OP22-WW03 CemCADE.cfw;04-10-2013: LoadCase 9 5/9 Intermediate(al;Version wcs-cem472_05 Client : Eni Petroleum Well : OP22-WW03 Schlumbergcr String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 9 5/8 Intermediate lal Simulated Surface Pressures o_ • Calc.Pump Press. Calc.Cent-IP 0 o— (0 N N a) z o- M o t r r 0 20 40 60 80 100 120 140 Time(min) Page 8 0P22-WW03CemCADE.cfw;04-10-2013; loadCase95/8 Intermediate(a);Version wcs-cem472_05 Client : Eni Petroleum Well : 0P22-WW03 Schlemberger String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 9 5/8 Intermediate(a) Simulated Slurry Temperatures during placement _o o I..-- I act Cark Tarrn I — First Sack Temp. r In API BHCT 1 ____ _�____ mu , N co - ___ _ - -__ M_� _ _ o ci IIIIIII 1111111111111111111111111111•1111111111•11111111111 IMO MIMI NiVIAIMMUIrilrennalial _N_. cNi- 111111111111•1111= 11111.111111111111111111 MEIN°D amommummum ■ 1J-2 marsamorm - EMMA?laillallitainaliariliMa -U) O ilnal 11.111111111111 IIIIIIIIIIIIIIIIIIIIIIIIIIIII ..— ,- O —111111Mmm111111111 on 11111111111111111M11111111111111111111.5-- --- �� _��I�_r _� .)o fir_ �r___� �� _r a U • �� — =sf __ _ _E -- o a - 0 NM . _ =____�i� - -� N o Nom _.� �� -�-_,__. . _ ._ -. - - . - N �– ..._E _—. - ■ __- f` CD — — o _ _._. fi -._. 11 – 0 6 o CO , I 1 I I 1 I r M 0 20 40 60 80 100 120 140 Time (min) Page 9 0P22-WW03 CemCADE cfw;04-10-2013; LoadCase 9 5/8 Intermediate(a).Version wcs-cem472_05 Client : Eni Petroleum Well : 0P22-WW03 Sehlumberger String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 9 5/8 Intermediate(a) Simulated Slurry Temperatures up to 24 hours after placement ci O I O � o I act Sark Tarns I t-_..."' - — First Sack Temp. I - --4-- _i m m - --- LL _ _ W: - _ : _N �- =-s-Q- -----r:-: --:::= O MI _ ° co _iii i_�rilM_M M _ MMMMIIIMMMMMMMIIIME I Lc) (Ni_ MWOMMOMMMINNIMMMIIMMILIMMIMMINEMMIMMUMEMOMMMIMI MIOMMMMMmMMMMMimmmmIMMM=MMmMmw!iM .6 IIIIIMMIMIIIMIMMIII MOM 1111=====MMMMIIMmt:■MM ,— t.L cn m 'o ii � i lii ■i.m...Tii�i L o• -.co millimu o� SC" : � �t Z , _ D ��I� M In ° arm cl as MN a MI LO } M _=MC L..CM°M _O CD O .m��=..mi..� .� N 0 .:::._.:.C.:C:........0::_.... 0 OT.._._._ _..._- ... __ _._ _._.___._ O to O (.0 I I r I I I I I M 0 250 500 750 1000 1250 1500 1750 Time (min) Page 10 OP22-WW03 CemCADE.ctw;04-10-2013; LoadCase95/8 Intermediate(al:Version wcs-cem472_05 Client : Eni Petroleum Well : 0P22-WW03 Schlloger String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 9 5/8 Intermediate(a) Section 4: fluid description Mud DESIGN Fluid No: 1 Density : 9.60 lb/gal Rheo. Model : HERSCHEL_B. k : 2.06E-3 Ibf.s"n/ft2 At temp. :80 degF n : 0.812 Ty : 8.741bf/100ft2 Gel Strength : 38.42 Ibf/100ft2 MUD Mud Type :WBM Job volume : 555.5 bbl Water Type : Fresh VOLUME FRACTION Solids :4.0% Oil : 0.0% Water : 96.0% MUDPUSH II DESIGN Fluid No:2 Density : 12.00 lb/gal Rheo. Model : HERSCHEL_B. k :8.54E-2 Ibf.s^n/ft2 At temp. :80 degF n :0.279 Ty :2.631bf/100ft2 Gel Strength :(Ibf/100ft2) Job volume :50.0 bbl Tail Slurry DESIGN Fluid No: 4 Density : 15.80 lb/gal Rheo. Model : HERSCHEL_B. k :8.43E-3 Ibf.s^n/ft2 At temp. :80 degF n :0.829 Ty : 1.241bf/100ft2 Gel Strength : 5.94 Ibf/100ft2 DESIGN BLEND SLURRY Name : G Mix Fluid :5. k Job volume : 107.0 bbl Dry Density : 199.77 Ib/ft3 Yield :4.16 f ,,.)<. Quantity :516.41 sk Sack Weight : 94 lb Solid Fraction :41.2% BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid :5.086 gal/sk Additives Code Conc. Function D046 0.200%BWOC Antifoam D167 0.500%BWOC Fluid loss D153 0.200%BWOC Antisettling D186 0.030 gal/sk blend Accelerator Thickening Time Schedule () (Bc) at (hr:mn) Compressive Strength Schedule () (psi) at (hr:mn) Page 11 0P22-WW03 CemCADE.cfw;04-10-2013; LoadCase 9 5/0 Intermediate(a);Version wcs-cem472_05 Client : Eni Petroleum Well : OP22-WW03 Schlumberger String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 95/8 Intermediate(a) Section 5: centralizer placement Top of centralization :6468.0 ft Bottom Cent. MD :7648.0 ft Casing Shoe :7668.0 ft NB of Cent. Used :30 NB of Floating Cent. :30 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min. STO @ Depth (ft) Joint (%) (ft) 7668.0 30 1/1 541 -STL-9 5/8-6-36(.171") 2.5 6488.0 Centralizer Description Centralizer Tests Cent.Name Code Casing Max. Min.OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (Ibf) (Ibf) 541 -STL-9 5/8-6-36 9 5/8 13.126 9.720 No Houma 12.250 238.30 1690.56 (.171") ft % _ 0 2n 60 80 100 --Beteeen Cent. I I - . + a At Cent . 11111111111111111111■ o _ ■■■■■■�■■■■■■■■■ ■■■■ ■ ■■ ■ ■■■ ■ --- . • 191 ■■■■■ ■ ■ _ ■■•■■■■ ■ • •••••••••!•••••••• -- ■■■■■■■■:■■■• ■■ ■ um 'pits .: a • ■•■i■ii - ' u ■ ni ■ ��- 11.1111 III Mini II Pipe Standoff Page 12 OP22-W W03 CemCADE.clw;04-10.2013; LoadCase 9 5/B Intermediate(a);Version wcs-cem472_05 Client : Eni Petroleum Well : OP22-WW03 Schibergcr String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 95/8 Intermediate(al Section 6: WELLCLEAN II Simulator ft 25 50 75 100 0 20 40 60 80 100 QQ }K Std Batw.Cent. —Mud Contamination cc�� Cement Coverage —Uncontaminated Slurry i gi- Cement Coverage Uncontaminated Slurry ilad,Cmcr,ima eal.Mud anta Wd z 3 3 z 3 6500 6500 6500 6500 6600 6600 6600 6600 6700 6700 6700 6700 6800 6800 6800 6800 6900 6900 ,— 6900 6900 7000 7000 7000 7000 a 7100 7100 a a 7100 7100 a 0 7200 7200 0 0 7200 7200 0 7300 7300 7300 7300 7400 7400 7400 7400 7500 7500 7500 7500 7600 7600 7600 7600 m ; a) al 3 m o -o -0 o -D L 3 L 0 0 z z IW ■"*4 . ./.1. ■H iYMWS Ii Mf/ia Page 13 0P22-WW03 CemCADE.cfw;04-10-2013; LoadCase 9 5/e Intermediate(al;Version wcs-cem472_05 Client : Eni Petroleum Well : OP22-WW03 Schloberger String : Intermediate Casing District : Prudhoe Bay,Alaska Country : US Loadcase : 95/8 Intermediate(a) Section 7: operator summary MIXING PREPARATION MUDPUSH II Volume : 50.0 bbl Density: 12.00 lb/gal Code Quantity Design Fresh water 38.065 bbl D182 228.391 lb 6.000 lb/bbl of base fluid F103 100.000 gal 2.000 gal/bbl of spacer U066 100.000 gal 2.000 gal/bbl of spacer D031 10137.057 lb 202.74 lb/bbl of spacer Tail Slurry Volume : 107.0 bbl Density : 15.80 lb/gal Yield : 1.16 ft3/sk Dry Phase Liquid Phase Blend: 48979 lb Design Mix Water 62.9 bbl 10.0 bbl LAS Design G 48542.281 lb Fresh water 62.534 bbl 9.942 bbl D046 97.085 lb 0.200%BWOC D186 15.492 gal 2.463 gal 0.030 gal/sk blend D167 242.711 lb 0.500%BWOC D153 97.085 lb 0.200%BWOC Page 14 0P22-WW03 CemCADE.cfw;04-10-2013; LoadCase 9 5/0 Intermediate(a);Version wcs-cem472_05 Schlumberger CemCAD E*well cementing recommendation for Production Liner Operator : Eni Petroleum Well : 0P22-WW03 Country : USA Field : Nikaitchuq State : Alaska Prepared for : Mr.Luca Borri Location : Oliktok Point Proposal No. : v1 Service Point : Prudhoe Bay,Alaska Date Prepared : 4/10/2013 Business Phone : 907 659 2434 FAX No. Prepared by : Stephen Lauper Phone : 907 952 0445 E-Mail Address : SLAUPER@slb.com C,. FL ,f 1, Disclaimer Notice: Schlumberger submits this document with the benefit of its judgment,experience,and good oilfmid practices. This information is provided in accordance with generally acoepred industry practice,relying on facts or information provided by others,limitations,computer models,measurements,assumptions and inferences that are not ntallible. Calculations are estimates based on provided information.All proposals,recommendations.or predictions are opinions only NO WARRANTY IS GMFN CONCERNING ACCURACY OR COMPLETENESS OF DATA,INFORMATION PRESENTED,FFFECTrePNESS OF MATERIAL,PRODUCTS OR SLIP%IFS,RECOMMENDATIONS MADE.OR RFSIATS OF THE SERVICES RENOFRED. Freedom from infringement of any intellectual property rights of Schlumberger or others is not to be inferred and no intellectual property rights are granted hereby. Mark of Schlumberger Page 1 OP22-W W03 CemCADE.ctw;04-10-2013; LoadCase 7 in.Liner la);Version wcs-cem472_05 Client : Eni Petroleum Well : 0P22-WW03 Schlumbergcr String : Production Liner District : Prudhoe Bay,Alaska Country : USA Loadcase : 7 in.Liner(a) Section 1 : well description Configuration : Liner Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 10855.0 ft BHST : 210 degF Bit Size : 8 112 in ft (x 1000) psi < 0 9 C 5.0 7.5 — — Fo-e 1 o ) { j .'.....'.'.'.'.'.'.'.'. _ T Shale • = Shale • • ••••.Sandstone. • • • M a".ell Litholog_•v Formation Press Page 2 OP22-WW03 CemCADE.c1w;04-10-2013: LoadCase 7 in.Liner(a);Version wcs-cem472_05 Client : Eni Petroleum Well : OP22-WW03 S hlimbrgcr String : Production Liner District : Prudhoe Bay,Alaska Country : USA Loadcase : 7 in.Liner(a) Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 7668.0 9 5/8 47.0 8.681 Drill Pipe MD OD Weight ID Grade Collapse Burst (ft) (in) (lb/ft) (in) (psi) (psi) 7468.0 5 19.5 4.276 E-75 9960 9500 Liner Hanger : 7468.0 ft Landing Collar MD : 10775.0 ft Casing/liner Shoe MD : 10855.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 10855.0 7 40.0 26.0 6.276 L-80 5410 7240 Vam Top Mean OH Diameter : 8.500 in Mean Annular Excess : 35.0 % Mean OH Equivalent Diameter: 8.966 in Total OH Volume : 248.9 bbl (including excess) Max. Deviation Angle : 39 deg Max. DLS : 3.084 deg/100ft Page 3 OP22-W W03 CemCADE.cfw;04-10-2013; LoadCase 7 in.Liner(a):Version wcs-cem472_05 Client : Eni Petroleum Well : 0P22-WW03 Schlumbrgcr String : Production Liner District : Prudhoe Bay,Alaska Country : USA Loadcase : 7 in.Liner(a) Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 717.2 11.35 8.39 SV-4 Siltstone 966.0 11.50 8.40 SV-3 Sandstone 1228.5 11.50 8.40 SV-2 Shale 1710.7 11.70 8.42 SV-1 Siltstone 1800.0 12.00 8.43 B/Permafrost Coal 2032.9 12.30 8.44 Ugnu Top(UG4) Shale 2518.8 12.60 8.45 UG-2 Coal Bed Sandstone Marke 3299.4 12.70 8.50 Lower Ugnu Coal 3551.9 12.60 8.60 Schrader Bluff Top Shale 3584.8 12.60 8.60 N Sequence Top Sandstone 3633.1 12.60 8.60 N Top Sandstone 3672.0 12.60 8.70 N Bottom Shale 3723.7 12.60 8.70 N Sequence Base Sandstone 3800.3 12.50 8.70 OA Top Shale 3811.2 12.50 8.70 OA-2 Top Sandstone 3821.6 12.50 8.70 OA-3 Top Sandstone 3839.3 12.50 8.70 OA-4 Top Sandstone 3847.7 12.50 8.70 Canning Sandstone 7557.6 12.50 8.70 HRZ Top 2012 Shale 7636.6 12.50 8.70 U Kalubik Shale 7741.8 12.50 8.70 Kalubik Marker Sandstone 2012 7868.2 12.54 8.70 Kuparuk Marker Sandstone 2012 7939.2 12.55 8.70 LCU 2012 Shale 9582.8 13.30 8.80 Sag-D 2012 Sandstone 9616.3 13.30 8.85 Sag-C 2012 Shale 9628.9 13.30 8.85 Sag-B 2012 Sandstone 9687.5 13.50 8.90 Shublik 2012 Sandstone 9921.4 13.80 9.00 Ivishak 2012 Shale 10603.9 14.00 9.00 Kavik 2012 Shale 10855.0 14.00 9.00 TD Sandstone Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 40 0.0 1800.0 1789.0 32 -0.4 3991.0 3672.5 50 0.3 7668.0 6562.9 95 0.8 10855.0 9694.1 210 1.8 Page 4 OP22-WW03 CemCADE.cfw;04-10-2013; LoadCase 7 in.Liner(a);Version wcs-cem472_05 Client : Eni Petroleum Well : OP22-WW03 Scrlberger String : Production Liner District : Prudhoe Bay,Alaska Country : USA Loadcase : 7 in.Liner(a) Section 2: fluid sequence Job Objectives: Zonal isolation: Cement to top of liner hanger at 7468 Original fluid FAZEPRO 10.50 lb/gal k:2.66E-3 Ibf.s^n/ft2 n :0.808 Ty:5.66 lbf/100ft2 Displacement Volume 259.2 bbl Drill Pipe Volume 132.6 bbl Total Volume 433.7 bbl TOC 7268.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) Weighted Citric Push 30.0 613.2 6041.5 11.00 k:2.66E-2 Ibf.s^n/ft2 n:0.361 Ty:0.28 lbf/100ft2 I Pill MUDPUSH II 30.0 613.2 6654.8 12.50 k:1.35E-1 Ibf.s^n/ft2 n:0.235 Ty:1.38 lbf/100ft2 Liner Slurry 114.5 3587.0 7268.0 15.80 k:7.75E-2 Ibf.s^n/ft2 n:0.514 Ty:9.66 lbf/100ft2 I FAZEPRO 259.2 0.0 10.50 k:2.66E-3 lbf.s^n/ft2 n:0.808 Ty:5.66 lbf/100ft2 Static Security Checks: Frac 496 psi at 7939.2 ft Pore 773 psi at 7668.0 ft Collapse 3868 psi at 10775.0 ft Burst 7240 psi at 10775.0 ft Csg.Pump out 71 ton Check Valve Diff Press 1000 psi ft (x 1000)psi o_ ) 0 96 co 7.5 Hydrostatic on c o . -Fra -.--- o -Pore o_ Ir r. _ oo_ MONO . In a) . 111111111 I f__ o - I_ MU n "I_I C-- an . in ° - ■■ ' o- ■■ ■ ■■ Fluid Sequence Static Well Security Page 5 OP22-W W03 CemCADE.cfw.04-10-2013; LoadCase 7 in.Liner la);Version wcs-cem472_05 Client : Eni Petroleum Well : OP22-WW03 S hlimbrgcr String : Production Liner District : Prudhoe Bay,Alaska Country : USA Loadcase : 7 in.Liner(a) Section 3: pumping schedule Start Job: Circulate Bottoms Up; Safety Meeting; Test Surface Equipment Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) Weighted Citric 5.0 30.0 6.0 30.0 80 Citric Pill Ahead Push Pill Pause 0.0 0.0 1.0 0.0 80 Line Up Spacer MUDPUSH II 5.0 30.0 6.0 30.0 80 Spacer Ahead Pause 0.0 0.0 2.0 0.0 80 Line Up Slurry Pause 0.0 0.0 5.0 0.0 80 Weight Up Slurry Tub Liner Slurry 4.0 114.5 28.6 114.5 80 Mix&Pump Slurry Pause 0.0 0.0 2.0 0.0 80 Shut Down Mixing Pause 0.0 0.0 3.0 0.0 80 Launch Wiper Dart FAZEPRO 8.0 200.2 25.0 200.2 80 Kick Out Dart(flush line) FAZEPRO 5.0 20.0 4.0 220.2 80 Slow Rate for ECDs FAZEPRO 2.0 39.0 19.5 259.2 80 Slow Rate fro ECDs/Plug Bump Pause 0.0 0.0 3.0 0.0 80 Swap to Rig Pumps Shut-In 0.0 0.0 1.0 0.0 80 Bleed Off/Check Floats Total 01:45 433.7 bbl hr:mn End Job: Set LTP, Circulate out excess cement, note volumes returned. Dynamic Security Checks: Frac 30 psi at 10855.0 ft Pore 614 psi at 7668.0 ft Collapse 3860 psi at 10775.0 ft Burst 5721 psi at 7468.0 ft Temperature Results BHCT 156 degF Simulated Max HCT 155 degF Simulated BHCT 147 degF Max HCT Depth 9968.9 ft CT at TOC 136 degF Max HCT Time 01:42:07 hr:mn:sc Static temperatures: At Time 1 (hr:mn) 00:01 hr:mn Geo.Temp. Top of Cement (degF) 136 degF 190 degF Bottom Hole (degF) 148 degF 210 degF Page 6 0P22-W W03 CemCADE.ctw;04-10-2013; LoadCase 7 in.Liner(a);Version wcs-cem472_05 Client : Eni Petroleum Well : 0P22-WW03 Schlumberger String : Production Liner District : Prudhoe Bay,Alaska Country : USA Loadcase : 7 in.Liner(a) Simulated ECDs at Liner Shoe L.r, Depth= 10855 ft -- Frac - Fbre - Hydrostatic 1 __ moon Dynamic Ili. I i __ c , . ID c\I I N _ M I c3)-1 i co— I I I 1 1 0 20 40 60 80 100 120 Time (min) Page 7 OP22-WW03 CemCADE.ctw;04-10-2013; LoadCane 7 in.Liner(al;Version wcs-cem472 D5 Client : Eni Petroleum Well : 0P22-WW03 Schlemberger String : Production Liner District : Prudhoe Bay,Alaska Country : USA Loadcase : 7 in.Liner(a) Simulated Surface Pressures N — Calc.FLmp Press. I -- - — Calc.Cecil-IP I 1—, * - 11111 1 rr i 1 f --- _ _ - -_ ._..111' i i�r .,W _.�.—...s_._......... _-- —.�.. ....�.;_E ___ — ==�0. l ' i-1 - l � a -- — - . ___ -----�■��i ( _1 N - ��EMr� ....1111•11.11111111M1111 _ .MI cl-6" 11111111111111111111•1111111 11111111111111111111111111111111111 all 'E 111111111111111111•11•1111 NIONIIIIIMIIIIIN 10111 = 111•FINININ 111111111111111= MI _, III co co MN c5-\ 1-- •INE Mrl'inil - _____________ .11 = N \ , ,_.„ = O r f r r I r 0 20 40 60 80 100 120 Time(min) Page 8 OP22-VVVV03 CemCADE.cfw;04-10-2013; LoadCase 7 in.Liner(al;Version wcs-cem472_05 Client : Eni Petroleum Well : 0P22-WW03 Schlumberger String : Production Liner District : Prudhoe Bay,Alaska Country : USA Loadcase : 7 in.Liner(a) Simulated Slurry Temperatures during Placement o _o <,.2 1.. .. Last Sack Terra. ■ First Sack Temp. j i r — _ u, AR BHCT _N Ci o e 4_- 111 IMO - '.- o 11,4 I o CD cm co Ellitilinill . _ / a ■■ ' LJ cu IIU. • o .. al _ 1111/1111111111111111 prom _ammo — r.immi.70.,' • --„c °° + _ ___ 1111111 -N Lo __.__ . I N CD (D 1 ' i M 0 20 11 40 60 80 100 120 Time (min) Page 9 OP22-WW03CemCADE.cfw;04-10-2013: LoadCase7in.Liner(a);Version wcs-cem472_05 Client : Eni Petroleum Well : 0P22-WW03 SchI berger String : Production Liner District : Prudhoe Bay,Alaska Country : USA Loadcase : 7 in.Liner(a) Simulated Slurry Temperatures up to 24 hours after placement o _o cp N — Last Sack Temp. _ — First Sack Temp. U) API BHCT PP"' ; _ . _A ^____ —N O 0 � . _ .. ■■.�. 1 0 r 1 _ -NO O rn _ - = a t IIIIIIIIIIIIN III liiiil _O N in O -N ■L IIII 1 _a N e O 1 r r r r - - I r I M 0 250 500 750 1000 1250 1500 1750 Time (min) Page 10 OP22-W W03 CemCADE.ctw;04-10-2013; LoadCase 7 in.Liner(a);Version wcs-cem472_05 Client : Eni Petroleum Well : 0P22-WW03 ScImberger String : Production Liner District : Prudhoe Bay,Alaska Country : USA Loadcase : 7 in.Liner(a) Section 4: fluid description FAZEPRO DESIGN Fluid No: 1 Density : 10.50 lb/gal Rheo. Model : HERSCHEL_B. k :2.66E-3 lbf.s^n/ft2 At temp. : 120 degF n :0.808 Ty : 5.661bf/100ft2 Gel Strength :6.401 bf/100ft2 MUD Mud Type :OBM Job volume :259.2 bbl Water Type : Fresh VOLUME FRACTION Solids : 13.0% Oil :31.0% Water : 56.0% MUDPUSH II DESIGN Fluid No:2 Density : 12.50 lb/gal Rheo. Model : HERSCHEL_B. k : 1.35E-1 Ibf.s^n/ft2 At temp. : 155 degF n : 0.235 Ty : 1.381bf/100ft2 Gel Strength :25.30 lbf/100ft2 Job volume :30.0 bbl Weighted Citric Push Pill DESIGN Fluid No: 3 Density : 11.00 lb/gal Rheo. Model : HERSCHEL_B. k :2.66E-2 Ibf.s^n/ft2 At temp. : 155 degF n :0.361 Ty :0.281bf/100ft2 Gel Strength : 7.15 lbf/100ft2 Job volume :30.0 bbl Liner Slurry DESIGN Fluid No:4 Density : 15.80 lb/gal Rheo. Model : HERSCHEL_B. k : 7.75E-2 Ibf.s^n/ft2 At temp. : 155 degF n :0.514 Ty :9.66 lbf/100ft2 Gel Strength :72.58 Ibf/100ft2 DESIGN BLEND SLURRY Name : G Mix Fluid :5.217 gal/sk Job volume .- •• Dry Density : 199.77 lb/ft3 Yield :1.17 ft3/sk Quantity :550.30 sk Sack Weight :94 lb Solid Fraction :40.9% BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid :2.681 gal/sk Page 11 OP22-W W03 CemCADE.cfw:04-10-2013: LoadCase 7 in.Liner(a):Version wcs-cem472_05 Client : Eni Petroleum Well : 0P22-WWO3 ScIimerger String : Production Liner District : Prudhoe Bay,Alaska Country : USA Loadcase : 7 in.Liner(a) Additives Code Conc. Function D047 0.400 gal/sk cement Antifoam D065 0.500%BWOC Dispersant D600G 2.000 gal/sk cement GASBLOK D167 0.200%BWOC Fluid loss D177 0.080 gal/sk cement Retarder Thickening Time Schedule () 100 Bc at 07:00 hr:mn Compressive Strength Schedule () (psi) at (hr:mn) Page 12 OP22-W W03 CemCADE.cfw;04-10-2013; LoadCase 7 in.Liner la);Version wcs-cem472_05 Client : Eni Petroleum Well : OP22-WWD3 Schlumberger String : Production Liner District : Prudhoe Bay,Alaska Country : USA Loadcase : 7 in.Liner(a) Section 5: centralizer placement Top of centralization :7668.0 ft Bottom Cent. MD :10835.0 ft Casing Shoe :10855.0 ft NB of Cent. Used :26 NB of Floating Cent. :26 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min.STO @ Depth (ft) Joint (%) (ft) 7935.0 0 0/0 0.0 7992.1 8255.0 4 1/2 6412070XX81/4-7-0-RIGID 0.0 8241.1 9175.0 0 0/0 0.0 8255.0 10775.0 20 1/2 6412070XX81/4-7-0-RIGID 0.0 9228.9 10855.0 2 1/1 6412070XX81/4-7-0-RIGID 51.2 10855.0 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min.OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (lbf) (lbf) 6412070XX8 1/4-7-0- 7 8.252 8.252 Yes Houma N.A. N.A. N.A. RIGID 0,4 ft 0 71) 40 60 80 100 :-..Er,..- - CE-1 1 I I I - 0-.-.t -t i . 0 11 ■ ■ = 111 1i - . .. .. ■ ... _-_-- ::1111:::: . _ 111111111111111 1111..Pa:�.._. Il so imam" 111 . - • l .� ....r. ,,c,_ .... ... i .....!•.... 1 1 CD - . • • MUM /. ■O ... -. . _-_ _ • • • • _____ �_ _ __ _ Pipe Standoff Page 13 OP22-WW03 CemCADE.cfw;04-10-2013; LoadCase 7 in liner(a);Version wcs-cem472_05 ill 1 Client : Eni Petroleum Well : 0P22-WW03 Schllrnberger String : Production Liner District : Prudhoe Bay,Alaska Country : USA Loadcase : 7 in.Liner(a) Section 6: WELLCLEAN II Simulator 0,0 % ft 0 20 40 60 80 100 0 20 40 60 80 100 g- 0 I I I I Std Batw.Cent. on Mud Contaminati CO - —Cement Coverage -Uncontaminated Slurry 8 I .- s– - 1 I , , _____ • § _ s,_ Cement Coverage Uncontaminated Slurry IWC>e>emn t*MW co be Wd z 3 3 * 111 riti . 8000– –8000 8000 0 8000 8500– –8500 8500 8500 S 9000- -9000 w " 9000 9000 L - - _c L - - t (t) 9500 9500– –9500 aa) aai 9500 9500 aa> o i o o 0 r - 10000- -10000 10000 10000 9 10500– –10500 10500 10500 m 3 a) a, 3 w o -a o -o 3 3 3 L 3 o 0 z z Page 14 OP22-W W03 CemCADE.cfw,04-10-2013; LoadCase 7 in.Liner(a);Version wcs-cem472_15 Client : Eni Petroleum Well : OP22-WWO3 Schlumhrgcr String : Production Liner District : Prudhoe Bay,Alaska Country : USA Loadcase : 7 in.Liner(a) Section 7: operator summary MIXING PREPARATION MUDPUSH II Volume: 30.0 bbl Density: 12.50 lb/gal Code Quantity Design Fresh water 23.744 bbl F104 60.000 gal 2.000 gal/bbl of spacer D182 166.210 lb 7.000 lb/bbl of base fluid D031 6780.874 lb 226.03 lb/bbl of spacer Weighted Citric Volume : 30.0 bbl Density: 11.00 lb/gal Push Pill Code Quantity Design Brine 27.110 bbl D031 4386.820 lb 146.23 lb/bbl of spacer Liner Slurry - Volume : 114.5 bbl Density : 15.80 lb/gal Yield : 1.17 ft3/sk Dry Phase Liquid Phase Blend: 51728 lb Design Mix Water 68.4 bbl 10.0 bbl LAS Design G 51727.730 lb Fresh water 35.121 bbl 5.139 bbl D047 220.118 gal 32.206 gal 0.400 gal/sk cement D065 258.639 lb 0.500%BWOC D600G 1100.591 gal 161.031 gal 2.000 gal/sk cement D167 103.455 lb 0.200%BWOC D177 44.024 gal 6.441 gal 0.080 gal/sk cement Page 15 0022-W W03 CemCADE.cfw:04-10-2013; LoadCase 7 in.Liner(a);Version wcs-cem472_05 Dr_ ing Hazards Sum*iry 16" Open Hole / 13-3/8" Casing Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low Monitor continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Lecithin. Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight,use weighted sweeps. Hole swabbing on trips Moderate Trip speeds,proper hole filling (use of trip sheets),pumping out 12-1/4" Open Hole / 9-5/8" Casing Interval Hazard Risk Level Mitigation Strategy Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight,use weighted sweeps. Gas Hydrates Low Control drill,reduced pump rates,reduced drilling fluid temperatures, additions of Lecithin. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Low BOP training and drills, increased mud weight. Pressure Lost circulation Low Reduced pump rates,mud rheology, LCM Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets),pumping out 8-1/2" Open Hole / 7" Liner Interval Hazard Risk Level Mitigation Strati Abnormal Reservoir Low Stripping drills, shut-in drills, increased mud Pressure weight. Stuck Pipe Moderate Good hole cleaning, PWD tools,hole opener runs, decreased mud weight Lost Circulation Low Reduced pump rates,mud rheology, LCM Hole Swabbing on Trips Moderate Trip speeds,proper hole filling (use of trip sheets),pumping out,backreaming Drilling Hazards Summary.doc 4/15/2013 2:23:19 PM REV DATE BY CK APP DESCRIPTION REV DATE BY ..,% APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductors 4-24 2 12/23/08 JFC JMS Add New Well Conductor OP26 Oliktok OLIKTOK 0 5 xl Point INTAKE DOCK \ OPP THIS L_ MODULE Pit P� �5 SURVEY if O . N ,:\--,v‘,,,,;,, I DS-.3R O DEW UAE 9 , SITE STP _1 OUKTOK P01N1 MODULES I __—' NDC STAGING AREA•. T13N R9E DS-3Q J f 18 -,: , f.. .o ;5 SCALE: .1_ r Ds�30 1" = 150' s - 21� , S TP PAD \ VICINITY MAP 90 \\ SCALE: 1" = 1 Mile o°°-0 0 ‘-‘0,..,-.0, . 0 0,oar, \ o°d° a° ', 0°-0 .-jo+'7' \ -�a0 cP \ `,.v. . 0909-o oG \ �O 0900.0 °°L�� °io \ lP \\\3\ 090.o.sue s o \ Z 90.0,0 o. f / ,\ ' 000 Z \ ` OLIKTOK 0 POINT PAD `� vps 0 \ 9 LA \ / \ SEE SHEET 3 FOR NOTES \ • Existing Conductor LOUNSBURY �� & ASSOCIATES, INC. • Conductor Asbuilt this survey / S tiAVEYORS ENGINEERS PLANTERS / AREA: MODULE: UNIT: _' _ Eni P tiroIIetutirn OLIKTOK POINT PAD Cnq L 'r WELL CONDUCTOR ASBUILT LOCATIONS CAD LK680D1 10/9/08 DRAWING NO: NSK 6.80-d1 I PART: 1 OF 3 REV: 2 REV DATE BY , CK APP DESCRIPTION REV DATE BY APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductors 4-24 2 12/23/06 JFC JMS Add New Well Conductor OP26 PROTRACTED SECTION 5, T. 13 N., R. 9 E., UMIAT MERIDIAN AK STATE PLANE(NAD83) LATITUDE(N) LONGITUDE(W) SEC. LINE PAD O.G. WELL NO. 'y' 'X NAD83 NAD83 OFFSET ELEV. ELEV. F.N.L. F.E.L. OP-11 6,036,332.70 1,656,791.89 70°30'39.015" 149°51'57.587" 2,052 1,519 12.1 4.0 OP-12 6,036,328.85 1,656,784.83 70°30'38.977" 149° 51'57.795" 2,056 1,526 12.2 4.0 0P03-P05 6,036,325.10 1,656,777.76 70°30'38.940" 149°51'58.004" 2,059 1,533 12.2 4.0 0PO4-P07 6,036,321.43 1,656,770.69 70°30'38.904" 149°51'58.212" 2,063 1,541 12.2 3.8 OP05 6,036,317.71 1,656,763.67 70°30'38.868" 149°51'58.419" 2,067 1,548 12.2 3.7 OP06 6,036,313.96 1,656,756.55 70°30'38.831" 149°51'58.629" 2,070 1,555 12.2 3.6 OP07 6,036,306.41 1,656,742.45 70°30'38.757" 149°51'59.045" 2,078 1,569 12.2 3.5 OP08 6,036,302.66 1,656,735.36 70°30'38.720" 149° 51'59.254" 2,082 1,576 12.2 3.5 OP09 6,036,298.90 1,656,728.32 70°30'38.683" 149° 51'59.462" 2,085 1,583 12.2 3.5 OP10 6,036,295.16 1,656,721.26 70°30'38.647" 149°51'59.670" 2,089 1,590 12.2 3.7 OP11 6,036,291.38 1,656,714.21 70°30'38.610" 149°51'59.878" 2,093 1,597 12.2 3.8 OP12 6,036,287.63 1,656,707.14 70°30'38.573" 149°52'00.086" 2,097 1,604 12.2 4.0 OP13 6,036,276.37 1,656,685.97 70°30'38.463" 149°52'00.711" 2,108 1,626 12.2 3.6 OP14 6,036,272.66 1,656,678.89 70°30'38.426" 149°52'00.920" 2,112 1,633 12.2 3.5 OP15 6,036,268.88 1,656,671.79 70°30'38.389" 149°52'01.129" 2,115 1,640 12.2 3.4 OP16 6,036,265.11 1,656,664.75 70°30'38.353" 149° 52'01.337" 2,119 1,647 12.2 3.3 OP17 6,036,261.36 1,656,657.70 70°30'38.316" 149° 52'01.545" 2,123 1,654 12.2 3.2 OP18 6,036,257.62 1,656,650.62 70°30'38.279" 149° 52'01.753" 2,127 1,681 12.2 3.1 OP19 6,036,250.09 1,656,636.50 70°30'38.205" 149°52'02.170" 2,134 1,675 12.2 2.5 OP20 6,036,246.31 1,656,629.41 70°30'38.168" 149°52'02.379" 2,138 1,682 12.2 2.2 OP21 6,036,242.57 1,656,622.39 70°30'38.132" 149°52'02.586" 2,141 1,689 12.2 1.9 OP22 6,036,238.82 1,656,615.39 70°30'38.095" 149°52'02.793" 2,145 1,696 12.2 1.7 OP23 6,036,235.05 1,656,608.27 70°30'38.058" 149°52'03.003" 2,149 1,703 12.2 1.5 OP24 6,036,231.36 1,656,601.27 70°30'38.022" 149°52'03.209" 2,153 1,710 12.2 1.3 DISPOSAL WELLS AK STATE PLANE (NAD83) LATITUDE(N) LONGITUDE(W) SEC. LINE PAD O.G. WELL NO. 'y' ' ' NAD83 NAD83 OFFSET ELEV. ELEV. F.N.L. F.E.L. OP25 6,036,004.35 1,656,510.91 70°30'35.791" 149°52'05.885" 2,380 1,802 12.2 -2.7 OP26 6,036,012.10 1,656,525.47 70°30'35.867" 149°52'05.456" 2,372 1,787 12.2 -2.7 LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS AREA: MODULE: UNIT: iiiN �ino• Pettr0o lIeuin'nl WELL OCONDUCTOR PAD EMI ASBUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: LK680D1 10/9/08 NSK 6.80-di 2 OF 3 2 REV DATE BY CK APP DESCRIPTION REV DATE BY APP DESCRIPTION 1 12/16/o8 MRT AJR Add New Well Conductos 4-24 2 12/23/08 JFC I JMS Add New Well Conductor OP26 NOTES 1. COORDINATES SHOWN ARE A.S.P. ZONE 4, NAD 83. DISTANCES SHOWN ARE TRUE HORIZONTAL DISTANCES. 2. GEODETIC COORDINATES SHOWN ARE NAD 83. 3. BASIS OF LOCATIONS ARE DERIVED FROM OPUS SOLUTIONS. 4. CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTION 5, TOWNSHIP 13 NORTH, RANGE 9 EAST, UMIAT MERIDIAN. 5. ALL ELEVATIONS SHOWN ARE B.P.M.S.L. DATUM. 6. SEE LOUNSBURY DOCUMENT L-2539 FOR NAD27 INFORMATION. SURVEYOR'S CERTIFICATE ? ��• �1,•• A i `- 'I . • h 1' : x l I HEREBY CERTIFY THAT I AM PROPERLY 0 ,. 0 REGISTERED AND LICENSED TO PRACTICE `,' ,,. /0- 0 LAND SURVEYING IN THE STATE OF j.V1 ROO KUS o i ALASKA AND THAT THIS PLAT REPRESENTS ♦ a�w OFJ. S-803 : J�'i A SURVEY DONE BY ME OR UNDER MY 7. 'F •. : :3- " DIRECT SUPERVISION AND THAT ALL • '1Z(' p•,ly1Z3;Qg*P��:�,� DIMENSIONS CORRECT AND OTHER DETAILS ARE DECEMBER 23, 2008. ,,,"1\r`„t•��+ 0 LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS AREA: MODULE: UNIT: Cnii Petroo llaulim WELL OCONDUCTOR D C=lni ASBUILT LOCATIONS CAD LK680D1 10/9/08 DRAWING NO: NSK 6.80-d1 PART: REV: 3 OF 3 _ 2 „k k k k k k k k k k R Y a b R R k R n $ iV141§§§WW$ $$$$$3$$ a$�1p($$W_- ;§EEEEEEEEEEEEEEEEEg o O y - I� F I� f[ N N N N N N N N N b N N z a o k G&G G G 6 i$$i t $S a S O S`o t$ i gliNIBEMERIaIIIMEIR! 'g q e§4 4 4 4 4 4 N§4 4 4 q§ 4 4 4 g 4 4§i t $R R $ R R R $$$$R O wkk�yRR"k.",aakk: aasR RRRkRR aR a � 0 0 E - ., .q0. 4“- 5 U §E bS “. ! as 'Ea Es LLgla W = ^�r6 .it; -.1%k350 -iFovicA;g w ! RRggsppRRRR° ='I, _= dog?4H U Y ° R K. „. . . .. E 0 3 R:R F F R r§! l iii 3 a U o o g a B. w OA 11,-;- 11111 1 gOdg 01 _w U u !,-LI € h .gogs, ti8 i t gN q yy y �jf jj$ yy gF, s °G . s �� uSbR tihog tAitli �3 i=00, z �„�\ 1,( ','�'� -YI F E lm gglidgffliiitiOVizilingi goo=>o ��J(( ?'\�\ '� ` a R'pRFkk.^.R ui$QW°m 1 Y�b Yx ,aB 111 ,.• i `` R a2r if r n . dd, �':At �i ■■5 8 HERR t ,.4 N. 9 3$3sfE85 S V g I "'a 5J, Val g a a i i s oaz I- :;! g ;-1a iLI 0 o L13O1f1ONS aVOa_ —/6 —1— — --4---- -- ---- ero Y _—� N '5§R L \�A.1.a3d0ad 03iMa3d 1 �\ ^ I —— a) ——1\\ — — § \ /®O = `.6 ;/ 4 \ 10® 1 a \II — Elt WwWW ` N -®O - a`N 4::\ I - I —J _ J \e zfff, gP°R°° g is 4 _ o ib I •I Wry Nr, v5 Rmo a am 3 e1 o W R I ;i E,�\ - o 00001 , o th t 1 I- nJo�ti g 04 i _.41111 , 11IWI g IF-N, I ' 3 : MIMI.E0 11 / L �/ I a• I ; .904 I F gi a \ RI kJ..1...........II.! \ ' W ',_.__ ill AVMOV021 301M .0£ g z ,,,--.. .. — -. ___.---* w A.' -. 1111.11.111=111, i R I c‘. PV" $ o Illppgll zi :1 / 4S Yo w C C 201§ As tae _ `0 zzi xne x,«=�,x x,sr��wx<,.„� n rx-x,00-wx:,-„�,.n,w.w..�,x.rev,��xxx«•m,�ewx,a�,rv�xnvxroe•,,m�sn vh o w„, re- String Summary String OD/Weight/Grade Connection MD Interval(m) Drift Dia.(in) Burst Collapse Axial Surface Casing 13 3/8",68.000 ppf,L-80 BTC,L-80 32.0-3991.0 12.259 2.29 1.42 3.15 Burst Design(13 3/8"Surface Casing) Collapse Design(13 3/8"Surface Casing) Axial Design(13 3/8"Surface Casing) - - Design Load Line _ - Pipe Rating 950- ' 950 950 co - u) y 7 7 m - L _ L L Q 1900- Q 1900 O 1900 13 - .a " N - N N 7 - 7 7 0 N U) N 2850- N 2850 N 2850 M ' 3800- 3800 - Design Load Line 3800 - Design Load Line Pi.e Ratin. - Pi.e Ratin. 0 2500 5000 7500 10000 0 700 1400 2100 700000 1050000 1400000 Burst Rating(psi) Collapse Rating(psi) Axial Force(lbf) Minimum Safety Factors(13 3/8"Surface Casing) Burst Load Data(13 3/8"Surface Casing) MD(m) OD/Weight/Grade Conection Burst(A) Collapse(A) Axial(A) Triaxial(A) Drilling Load: Pressure Test Test Pressure: 2000.00 psi 32 13 3/8",68.000 ppf,L-80 BTC,L-80 2.47 85 +100.00 C1 4.23 A4 3.17 B5 Mud Weight: 9.40 ppg 40 2.47 B5 +100.00 C1 4.24 A4 3.16 B5 Assigned Ext.Pressure: Fluid Gradients(w/Pore Pressure) 300 2.45 B5 17.44 C1 4.38 A4 3.14 B5 300 2.45 B5 17.44 C1 3.84 A4 3.08 B5 Drilling Load: Fracture @ Shoe w/1/3 BHP at Surface 717 2.43 B5 7.32 C1 3.15 A4 2.82 B5 Surface Pressure(1/3'BHP): 983.01 psi 717 2.43 B5 7.32 C1 3.15 A4 2.83 B5 Shoe Depth,MD: 3991.0 usft 1100 2.41 B5 4.80 C1 3.27 A4 2.78 135 Fracture Pressure at Shoe: 2365.39 psi 2033 2.37 B5 2.59 C1 3.60 A4 2.66 B5 Fracture Margin of Error: 0.00 ppg 2300 2.36 B5 2.29 C1 3.73 A4 2.63 B5 2500 2.35 B5 2.12 C1 3.83 A4 2.60 B5 External Pressure: Fluid Gradients(w/Pore Pressure) 2600 2.34 135 2.04 C1 3.88 A4 2.59 B5 TOC,MD: 32.0 usft 2700 2.348 5 1.97 C1 3.94 A4 2.58 135 Prior Shoe,MD: 32.0 usft 2800 2.33 85 1.91 C1 4.00 A4 2.57 B5 Mud Weight Above TOC: 9.40 ppg 2900 2.33 85 1.85 C1 4.06 A4 2.56 B5 Fluid Gradient Below TOC: 8.60 ppg 3000 2.33 85 1.80 C1 4.13 A4 2.55 B5 Pore Pressure In Open Hole: No 3100 2.32 B5 1.75 C1 4.19 A4 2.84 B5 3500 2.31 B5 1.59 C1 4.48 A4 2.81 B5 Axial Load Data(133/8"Surface Casing) 3990 2.29 135 1.42 C1 4.88 A4 2.76 B5 3991 2.29 85 1.42 C1 4.88 A4 2.76 B5 Running in Hole-Avg.Speed: 0.7 ft/s L Connection Leak Overpull Force: 150000 Ibf B5 Pressure Test C1 Full/Partial Evacuation Green Cement Pressure Test: 1000.00 psi A4 Overpull Force Collapse Load Data(13 3/8"Surface Casing) Drilling Load: Full/Partial Evacuation Mud Weight: 10.00 ppg Mud Level,MD: 3991.0 usft Assigned External PressureFluid Gradients(w/Pore Pressure) External PressureFluid Gradients(w/Pore Pressure) TOC,MD: 32.0 usft Prior Shoe,MD: 32.0 usft Fluid Gradient Above TOC: 8.30 ppg Fluid Gradient Below TOC: 8.30 ppg Pore Pressure In Open Hole Below TOC: No String Summary String OD/Weight/Grade Connection MD Interval(m) Drift Dia.(in) Burst Collapse Axial Production Casing 9 5/8",40.000 ppf,L-80 Series 500 Type 563(TC) 32.0-7368.0 8.750 A 1.48 0.94 2.15 9 5/8",47.000 ppf,L-80 VAM TOP 7368.0-7668.0 8.625 A 1.79 1.40 1.67 Burst Design(9 5/8"Production Casing) Collapse Design(9 5/8"Production Casing) Axial Design(9 5/8"Production Casing) - - Design Load Line - Pipe Rating • 2000- 2000 2000 cn N y z ' c L L L a - a a 0 4000- 0 4000 � 0 4000 N - a, y z z 1 • ° 6000- ° 6000 6000 - Design Load Line • - Design Load Line 8000- 8000 - • - 8000 iii -. Pi.e Ratin• - Pi.e Ra in. 0 2500 5000 7500 10000 0 1500 3000 4500 600000 800000 1000000 Burst Rating (psi) Collapse Rating(psi) Axial Force(lbf) Minimum Safety Factors(9 5/8"Production Casing) Burst Load Data(9 5/8"Production Casing) MD(m) OD/Weight/Grade Conection Burst(A) Collapse(A) Axial(A) Triaxial(A) Production Load: Tubing Leak Packer Fluid Density: 8.30 ppg 32 9 5/8",40.000{$yib 800 Type 563(TC) 1.48 B6 +100.00 C5 2.41 A4 1.76 B6 Packer Depth,MD: 7468.0 usft 40 1.48 B6 +100.00 C5 2.42 A4 1.76 B6 Perforation Depth,MD: 10855.9 usft 300 1.49 B6 19.35 05 2.47 A4 1.76 B6 Gas Gravity: 0.70 300 1.49 B6 19.35 C5 2.33 A4 1.73 B6 Reservoir Pressure: 4532.70 psi 717 1.50 B6 8.12 C5 2.15 A4 1.66 B6 Assigned Ext.Pressure: Fluid Gradients(w/Pore Pressure) 717 1.50 136 8.12 C5 2.15 A4 1.68 B6 1100 1.52 B6 5.33 C5 2.21 A4 1.67 B6 External Pressure: Fluid Gradients(w/Pore Pressure) 1100 1.52 B6 5.33 C5 2.21 A4 1.66 B6 TOC,MD: 6468.0 usft 2033 1.55 B6 2.87 C5 2.35 A4 1.62 B6 Prior Shoe,MD: 3991.0 usft 2300 1.56 B6 2.54 C5 2.40 A4 1.63 B6 Mud Weight Above TOO: 10.00 ppg 2300 1.56 B6 2.54 C5 2.40 A4 1.64 B6 Fluid Gradient Below TOG: 8.60 ppg 2500 1.57 B6 2.35 C5 2.43 A4 1.63 B6 Pore Pressure In Open Hole: Yes 2500 1.57 B6 2.35 C5 2.43 A4 1.64 B6 2600 1.57 B6 2.26 C5 2.45 A4 1.64 B6 2700 1.58 B6 2.19 05 2.47 A4 1.64 B6 2800 1.58 B6 2.12 C5 2.48 A4 1.64 B6 2900 1.58 B6 2.06 C5 2.50 A4 1.64 B6 Axial Load Data(9 5/8"Production Casing) 3000 1.59 B6 2.00 C5 2.52 A4 1.64 B6 3500 1.60 B6 1.76 C5 2.61 A4 1.74 B6 Running in Hole-Avg.Speed: 0.7 ft/s 3991 1.62 B6 1.58 C5 2.71 A4 1.73 B6 3991 1.62 B6 1.58 C5 2.71 A4 1.72 B6 Overpull Force: 150000 lbf 6468 1.71 B6 1.04 C5 3.44 A4 1.63 B6 6468 1.50 B6 1.04 C5 3.44 A4 1.71 B6 Green Cement Pressure Test: 1000.00 psi 6951 1.50 B6 0.98 C5 3.67 A4 1.64 B6 7006 1.50 B6 0.98 C5 3.60 A4 1.63 B6 Collapse Load Data(9 5/8"Production Casing) 7100 1.50 B6 0.97 C5 (2.52)C5 1.62 B6 7100 1.50 B6 0.97 C5 (2.51)C5 1.61 B6 Production Load: Full Evacuation 7200 1.50 B6 0.96 C5 (2.51)C5 1.62 B6 Assigned External PressureFluid Gradients(w/Pore Pressure) 7300 1.50 B6 0.95 C5 (2.50)C5 1.62 B6 7368 1.50 B6 0.94 C5 (2.50)C5 1.62 B6 External PressureFluid Gradients(w/Pore PressL re) 7368 95/8",47.000 ppf,L-80 VAM TOP 1.79 B6 1.45 C5 (1.68)C5 1.86 B6 TOC,MD: 6468.0 usft 7400 1.79 B6 1.44 C5 (1.68)C5 1.86 B6 Prior Shoe,MD: 3991.0 usft 7468 1.79 B6 1.43 C5 (1.68)C5 1.86 B6 Fluid Gradient Above TOC: 10.00 ppg 7468 4.55 B6 1.43 C5 (1.68)C5 2.39 C5 Fluid Gradient Below TOC: 8.30 ppg 7557 4.64 86 1.42 C5 (1.67)C5 2.37 C5 Pore Pressure In Open Hole Below TOC: No 7558 4.64 B6 1.42 C5 (1.77)C5 2.40 C5 7558 4.64 B6 1.42 C5 (1.68)C5 2.37 C5 7637 4.97 B6 1.41 C5 (1.67)C5 2.35 C5 7667 5.01 B6 1.40 05 (1.67)C5 2.35 C5 7668 5.01 B6 1.40 C5 (1.67)C5 2.35 C5 C Connection Critical B6 Tubing Leak C5 Full Evacuation Production A4 Overpull Force () Compression String Summary String OD/Weight/Grade Connection MD Interval(m) Drift Dia.(in) Burst Collapse Axial Production Liner 7",29.000 ppf,L-80 VAM TOP 7468.0-10855.0 6.059 2.60 2.36 1.48 Burst Design(7"Production Liner) Collapse Design(7"Production Liner) Axial Design(7"Production Liner) - Design Load Line - Pipe Rating 7500 7500 7500 - 1 N En En 7 7 7 L L L a 9000 a 9000 a 9000 a> a> a> m m M 10500 10500 - cp 10500 - Design Load Line - Design Load Line 12000 - 12000 - Pi.e Ratin. 12000 - - - - Pi.e Ratin. I I I I I I I I I I I I I I I I I I I I I 0 2500 5000 7500 10000 4500 6000 300000 450000 600000 Burst Rating (psi) Collapse Rating (psi) Axial Force(lbf) Minimum Safety Factors(7"Production Liner) Burst Load Data(7"Production Liner) MD(m) OD/Weight/Grade Conection Burst(A) Collapse(A) Axial(A) Triaxial(A) Production Load: Tubing Leak Packer Fluid Density: 8.30 ppg 7468 7",29.000 ppf,L-80 VAM TOP 2.60 B6 2.12 C5 2.38 C5 2.83 B6 Packer Depth,MD: 7468.0 usft 7558 9.10 B6 2.10 C5 (2.52)C5 2.85 A4 Perforation Depth,MD: 10855.9 usft 7558 9.10 B6 2.10 C5 (2.38)C5 2.85 A4 Gas Gravity: 0.70 7668 9.47 B6 2.07 C5 (2.37)C5 2.87 A4 Reservoir Pressure: 4532.70 psi 7668 6.25 B6 2.07 C5 (2.37)C5 2.87 A4 Assigned Ext.Pressure: Fluid Gradients(w/Pore Pressure) 7742 6.37 B6 2.05 C5 (2.37)C5 2.88 A4 7939 6.83 B6 2.01 C5 (2.36)C5 2.86 C5 External Pressure: Fluid Gradients(w/Pore Pressure) 7939 6.83 B6 2.01 C5 (2.37)C5 2.86 C5 TOC,MD: 7468.0 usft 8100 7.22 B6 1.97 C5 (3.04)C5 2.84 C5 Prior Shoe,MD: 7668.0 usft 9583 15.12 86 1.67 C5 (2.94)C5 2.41 C5 Mud Weight Above TOC: 10.00 ppg 9628 16.29 B6 1.67 C5 (2.94)C5 2.40 C5 Fluid Gradient Below TOC: 8.33 ppg 9687 18.76 B6 1.66 C5 (2.93)C5 2.38 C5 Pore Pressure In Open Hole: Yes 10638 +100.00 B6 1.51 C5 (2.87)C5 2.17 C5 10800 +100.00 B6 1.49 C5 (2.86)C5 2.13 C5 10854 +100.00 B6 1.48 C5 (2.86)C5 2.12 C5 10855 +100.00 B6 1.48 C5 2.86 C5 2.12 C5 Axial Load Data(7"Production Liner) C Connection Critical B6 Tubing Leak Running in Hole-Avg.Speed: 0.7 ft/s C5 Full Evacuation Production A4 Overpull Force Overpull Force: 100000 lbf Collapse Load Data(7"Production Liner) Production Load: Full Evacuation Assigned External PressureFluid Gradients(w/Pore Pressure) External PressureFluid Gradients(w/Pore Pressure) TOC,MD: 7468.0 usft Prior Shoe,MD: 7668.0 usft Fluid Gradient Above TOC: 10.00 ppg Fluid Gradient Below TOC: 8.30 ppg Pore Pressure In Open Hole Below TOC: No t I Schwartz, Guy L (DOA) From: Kuck Marc <marc.kuck @enipetroleum.com> Sent: Friday, May 03, 2013 2:15 PM To: Schwartz, Guy L(DOA) Cc: Borri Luca;Wright James Subject: RE:OP22-WW3 (PTD 213-054) Guy, 1) Attached is the planned schematic with completion and estimated Ivishak formation and perf interval. We are not planning to run an ESP in this well. 2) We are not requesting a diverter waiver are will rig up accordingly. 3) We reviewed the MASP and agree: Sag River sand: The expected reservoir pressure is 0.55 psi/ft,or 10.5 ppg EMW(equivalent mud weight). The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient(0.11), and the planned vertical depth of the formation: MPSP = (8440 ft TVD)(0.55-0.11 psi/ft)=3713 psi Hope this answers your questions. If you need any further information just let know. Have a good weekend! Thanks and regards, Marc D. Kuck Production Optimization Coordinator Eni Petroleum Inc. Office: 907 865-3322 Cell: 907 2426942 From: Kuck Marc Sent: Friday, May 03, 2013 8:56 AM To: 'Schwartz, Guy L(DOA)'; Borri Luca Subject: RE: OP22-WW3 (PTD 213-054) Guy, Luca is out for the next couple weeks. Myself and James Wright will address these issues and get back to you shortly. Thanks, Marc From: Schwartz, Guy L(DOA) [maiitogjuy schwartr(uualaska.gov] Sent: Wednesday, May 01, 2013 3:55 PM To: Boni Luca Cc: Kuck Marc Subject: RE: OP22-WW3 (PTD 213-054) 1 Also... in box 17 I get a Max form prt,3ure based on the Sag. at 4642 psi (MASP would then be 3713 psi) ... is this correct? Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From: Schwartz, Guy L(DOA) Sent: Wednesday, May 01, 2013 3:30 PM To: Boni Luca Cc: Marc.Kuck j Enipetroieum.com Subject: OP22-WW3 (PTD 213-054) Luca, Do you have a schematic for the final well completion and approx. perf intervals for the ivashak? Also.. it is unclear if you are requesting a diverter Waiver..I did not see the request in the cover letter but was mentioned in the procedure. Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that, with regard to messages sent by its network, the Company is not responsible for any statements made or opinions expressed, that are not strictly related to the Company's operations. 9 ....* OP22-W1NO3 • 2rr110 perrollcurnn� 4-'/2" 13Cr 12.6 ppf Vam Top Production Tubing o 0 Wellhead. 13-3/8" x 4-W, CR Flow-wetted 5,000 psi Conductor, 20" Uninsulated set at 160 ft Water Producer Vacuum Insulated Tubing (VIT), As planned 'I 4-'/2" x 6", approx 105' p5 2204' MD, 2191' TVD, 11° Inc - TR-MAXX 5E SSSV, 3.81" 'X' Profile, '/4" SS hyd. Control line 3231' MD, 3,130' TVD 37° Inc- GLM, 4-'/2" x 1", KBG with DCK-2 Ann-to-Tubing 2,000 psi 4-'/2" cable clamps, for ESP Power Cable, (2) 3/8" Chem lnj Line it' 4: \ Dual encapsulated 3/8" SS Chem lnj Lines \i 'A' 7449' MD, 26° Inc - 3.81" 'X' Profile Surf. Casing 7463' MD, Chemical Injection Mandrel 13-3/8" 68 # a 3948' MD, 3672' TVD >- 7480' MD, 6410' TVD No go- Tieback Seal Stem \\ z.., \ 7,460' MD—TOL - Flexes �* Lock Liner Hanger ands' _. ZXP Packer Ass , y Plan Perf Range 10,010'- 10,400' MD, 8,850'- 9,244' Interm. Casing TVD 9-5/8" 40 # 13 Cr Approx 9° Inc 7,664' MD, 6,562" , TVD, 1.:. Production Liner, 7" 26# 13Cr 8 1/2" OH 10,855' MD, 9,695' TVD Confidential Bettis, Patricia K (DOA) From: Bettis, Patricia K(DOA) Sent: Friday, April 19, 2013 2:47 PM To: 'Borri Luca' Subject: Permit to Drill Application: Updated Form Luca, Thank you so much for providing the information for the OP22-WW03 well. I noticed that the Permit to Drill form (10- 401) is an outdated form from 2009. For future permit to drill application submittals, please use the 10-401 Form (Revised 10/2012). It may be found at the following address: http://doa.alaska.gov/ogc/forms/forms.html. Have a wonderful weekend, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments, contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettisPalaska.gov. 1 Bettis, Patricia K (DOA) From: Borri Luca [Luca.Borri @enipetroleum.com] Sent: Friday, April 19, 2013 1:36 PM To: Bettis, Patricia K(DOA) Subject: RE: OP22-WW03: Permit to Drill Application Attachments: 04192013 OP22-WW03 PERMIT Document.docx Sorry It was my mistake.... 1)The data in the application is wrong. Attached is the correct file in (TVDSS).The data in the drilling procedure are fine (TVD including rotary table). There was a copy and paste mistake sorry. 2) another typo the anticipated maximum bottom hole is 3975 psig. If you need anything else let me know Regards L.Borri From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@aalaska.gov] Sent: Friday, April 19, 2013 11:02 AM To: Borri Luca Subject: OP22-WW03: Permit to Drill Application Good morning Luca, I am reviewing the application and I have a couple of questions. 1. On page 3 of the Application for Permit to Drill Document, it states that the anticipated Ivishak Top is 10,605 ft MD. However, on page 7 of the Drilling Procedure, the estimated top of Ivishak is given as 9,921 ft MD and top Kavik is at 10,604 ft MD. Which is correct? 2. I also wanted to verify that the anticipated maximum bottom hole is 3878 psig. Is this correct? Thank you so much for your help, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If 1 you are an unintended recipient of this e-nl,.,,, please delete it,without first saving or forwa._.,ig it, and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that, with regard to messages sent by its network, the Company is not responsible for any statements made or opinions expressed, that are not strictly related to the Company's operations. 2 TRANSMITTAL LETTER CHECKLIST WELL NAME N i ka,-i-al, ��a - O PTD# 0.2/30 Development / Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: Ai i c.i POOL: J Il rl i Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE 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 (_ PH) and API number (50- - - ) from records, data and logs acquired for well • SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev:9/09/2011 1 1 Co U) a) 0 U N U 0 `o m c a Q ~ co a 6 N a O 'ci T C d C 0 Co O a) E L N O 0 O co 0 O 1E H O cO E co CC 'L O O 0 (0 0 y W o7 CO a`) a a n ° U O o0 3 O O o m E m • ° q E O U c a n C a rn o a> c m Q n E co d O O C1 C7> in co 7 L 0 w c ° 0 E co T 0 u-> N a) .3 N U ,- E 5 co U cp Q L N - 0 CD CC) ° O - 3 m c = -0 0 n csi o 3 a U 0 3 0 = = c co @ W � ° -a < 0 a - co _ cn vi 2 0 ° m - E Z' E 3 0 o c a °' U ° m N ra g a) 0 CO 0 0 ac) w a Q o°o a o -o w E E 0. C c O M E N C a O O Co a o N N = O U U C O - N U U d . 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HALLIBURTON RECEIV SEP 112013 E D Sperry Drilling AOGGC Surface Data Logging End of Well Report O P22-WW03 Client: ENI Petroleum Field: Nikaitchuq Rig: Nabors 245 Date: August 14, 2013 !„, , j" 1111 „dr yp HALLIBURTON I Sperry Drilling TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Days vs. Depth 4. After Action Review 5. Formation Tops 6. Mud Record 7. Bit Record 8. Morning Reports 9. Survey Report Digital Data to include: Final Logs Halliburton Log Viewer EMF Log Viewer EOW Report PDF Version ADI Backup HALLIBURTON I Sperry Drilling GENERAL WELL INFORMATION Company: ENI Petroleum Rig: Nabors 245E Well: OP22-WW03 Field: Nikaitchuq—Oliktok Point Borough: North Slope Borough State: Alaska Country: United States API Number: 50-029-23489-00-00 Sperry Job Number: AK-AM-0900579414 Job Start Date: 05 July 2013 Spud Date: 06 July 2013 Total Depth Date: 03 August 2013 Total Depth: 10676' MD, 9521.5' TVD North Reference: True Magnetic Declination: 19.818° Magnetic Dip Angle: 81.020° Total Magnetic Field Strength: 57632.000 nT Date Of Magnetic Data: 10 July 2013 Wellhead Coordinates N: North 70° 30' 39.13659" Wellhead Coordinates W: West 149° 51' 51.45817" Drill Floor Elevation 53.0' Ground Elevation: 12.2' Permanent Datum: Mean Sea Level SDL Engineers: Emil Opitz, Todd A. Wilson, David McKechnie Josiah Failing, Charles Sinn Company Geologist: Andrew Buchanan Company Representatives: Bruce Simonson, Ben Perry SSDS Unit Number: 121 HALLIBURTON I Sperry Drilling DAILY SUMMARY 07/04/2013 SDL remained on location from previous well. 07/05/2013 Remove diverter knife valve, installed new one and tested. Pick up drill pipe and rack back in derrick. Function test diverter. Pick up 81 stands of 5 inch drill pipe and 4 stands of HWDP. Begin picking up BHA. 07/06/2013 Pick up 16" mill tooth and mud motor. Ream from 160' MD. Pull out of hole and picked up drilling BHA. Drill ahead to 218' MD taking surveys. Drill ahead from 218' MD to 310' MD. Pull out of hole and added 3 flex collars and 2 joints of HWDP. Tripped in the hole to 306' MD and drilled ahead and taking surveys to 709' MD. Gas: The max gas was 7 units at 855' MD and the average gas was 4 units. 07/07/2013 Drill ahead from 709' MD to 2530' MD surveying at every connection. Background gas is running approximately 130 to 150 units. Gas: The max gas was 886 units at 1945' MD and the average gas was 139 units. 07/08/2013 Drill ahead from 2530' MD to 3290' MD and hit a hard spot. Made several attempts to dill thru and motor stalled. Pick up off bottom and circulated. Start back reaming out of hole for 6 stands, then attempt to pull on elevators to change BHA. Background gas is running around 40 to 50 units. Gas: The max gas was 350 units at 3026' MD and the average gas was 103 units. 07/09/2013 Back ream from 3013' MD to 2687' MD. Trip out of hole on elevators and lay down BHA#2. Pick up BHA#3. Trip in hole to 760' MD and shallow test MWD trip in hole and reamed thru tight spots at 1991' MD and 2130' MD. Back ream MAD Pass from 3298' MD to 3189' MD. Gas: The max gas was 117 units trip gas and the average gas was 11 units. 07/10/2013 Drill ahead from 3299' MD to TD at 4031' MD. Circulate bottoms up or until shakers clean. Started to see an increase in drill gas around 3800' MD. Gas peaked out at 3454 units at 3806' MD, decreased and then maxed out at 5641 units at 3825' MD. Background gas was running around 430 units. Start back reaming out of hole from 4031' and circulate bottoms up after 3 stands. Gas: The max gas was 5641 units at 3825' MD and the average gas was 430 units. 07/11/2013 Back ream out of hole. Lay down BHA#3 and prepare rig for casing run. Gas: The max gas was 867 units and the average gas was 45 units. 07/12/2013 Lay down BHA#3. Rig up to run 13 3/8" casing. Run casing to 3200' circulate bottoms up. Monitor losses. HALLIBURTON I Sperry Drilling Gas: The max gas was 96 units and the average gas was 11 units. 07/13/2013 Circulate and condition hole. Continue running 13.375" casing form 3200' MD to 4020' MD. Circulate bottoms up. Max gas while circulating was 260 units. Rig up cementers and test lines. Pump 100 bbls of mud push, 590 bbls of lead and 63 bbls tail. Displace with 603 bbls of mud. Flush stack and nipple down diverter. Gas: The max gas was 260 units and the average gas was 15 units. 07/14/2013 Nipple up BOP and test same. Take on 9.3 ppg NaCI brine. Test casing for 30 minutes to 2500 psi. Flush stack and nipple down diverter. 07/15/2013 Nipple down BOP and nipple up tree then test to 5000 psi. Rig up to freeze protect well. 07/22/2013 Freeze protected the well with 120 bbls of diesel. Moved rig over from OP17-02 to OP22- VWV03. Held pre-job safety meeting in the doghouse for setting BOP stack. Sperry standing by, running SDL checklist in preparation for drillout run 400. 07/23/2013 Continued nippling up BOP. Unseated hanger, shut top rams and reverse circulated 40 bbls of diesel through the choke to the possum belly. Shut down and pumped down 260 bbls of diesel from the backside at 30 bbls/min at 40 psi. Laid down tubing hanger and landing joint. Testing BOPS at report time. 07/24/2013 Finish BOP testing; laid down testing tool and pulled test plug. Installed wear ring. Picked up and made up drill pipe; single-in hole; Racked back 81 stands in derrick; picked up BHA and began RIH. 07/25/2013 Run in hole with 12.25" bit. Tag cement @ 3923. Drilled out cement to 13 3/8" shoe. Displaced 9.1 PPG brine w/9.25 PPG LSND. Slipped and cut. Performed FIT to 12.53. Drilling out to 4720' at report time. Gas: The max gas was 404 units and the average gas was 60 units. 07/26/2013 Continue drilling ahead from 4720' MD to 6550' MD. Gas: The max gas was 90 units and the average gas was 39 units. 07/27/2013 Continue drilling ahead from 6550' MD to intermediate casing point at 7646' MD. Back ream out of the hole. Gas: The max gas was 223 units and the average gas was 76 units. 07/28/2013 Finish back reaming out of the hole and lower down BHA#4. Begin to change RAMs. HALLIBURTON I Sperry Drilling 07/29/2013 Rig up to run casing, and begin running casing to 3940' MD. 07/30/2013 Run casing to 7632' MD. Rig up Schlumberger Cementing. Cement casing. Rig down cementing and change out RAMs. Gas: A max trip gas of 968 units was seen. 07/31/2013 Finish changing out RAMs. Test BOPs. Make up and pick up BHA#5. Run in hole with BHA#5. 08/01/2013 Perform casing pressure test. Displace to new LSND mud. Drill out cement and 20' new formation. Perform FIT to 13.0 ppg EMW. Drill ahead in 8.5" section. Gas: The max gas was 1809 units and the average gas was 69 units. 08/02/2013 Continue to drill ahead in 8.5" section Gas: The max gas was 203 units and the average gas was 52 units. 08/03/2013 Continue to drill ahead in 8.5" section to final TD of 10676' MD. Begin to back ream out of hole per K&M. Gas: The max gas was 495 units and the average gas was 107 units. 08/04/2013 Back ream out of hole per K&M. Circulate hole at casing shoe. Pull out of hole and begin to lay down BHA#5. Gas: A max trip gas of 199 units was seen. 08/05/2013 Finish lay down BHA#5. Test RAMs. Rig down for 7" liner run, and begin to rig down. At 3250' MD at report time. 08/06/2013 Finish lay down BHA#5. Test RAMs. Rig up for 7" liner run, and begin to run in hole. At 3250' MD at report time. Gas: A max trip gas of 92 units was seen. 08/07/2013 Finish trip out of hole and racking back 5" DP. Pick up and TIH w/ 106 4" DP singles. Finish TIH on 5" DP to 10577' MD. Begin to circulate and condition mud in preparation for displacement to 9.5ppg brine. 08/08/2013 Displace hole to 9.5 ppg Brine. Pull out of hole. Make up and pick up perforating BHA and RIH. At 5900' MD at report time. 08/09/2013 Log hole with Gamma to correlate perforating depths. Perforate well as per Geo. Pull out of hole and lay down 5" DP and 4" DP HALLI BiJ RTD N Sperry Drilling Days vs. Depth WELL NAME: OP22-WW03 LOCATION: Oliktok Point OPERATOR: ENI Petroleum AREA: North Slope MUD CO: MI SWACO STATE:Alaska RIG: Nabors 245E SPUD:6-Jul-2013 SPERRY JOB:AK-XX-0900579414 TD:3-Aug-2013 0 I l l l l l l 05 July 2013 Commenced 16"Surface Sperry SDL Remain on location Hole Section from previous well On Bot:05:15 06 July 2013 I I 1000 -- - -- —Prognosed - - Actual 2000 -- — --- POOH to change BHA 08 July 2013 3000 --- -- Landed 13.375"Casing 4026'MD, 3730'TVD 13 July 2013 Commenced 12.25" Intermediate Hole Section 4000 , On Bot:01:30 25 July 2013 ++ TD Surface Hole Section a, 5000 I 4031'MD,3735.4'TVD Off Bot:22:00 10 July 2013 . I - CI CD 6000 111111 1111 MMIMMMM 7000 I t t TD Intermediate Hole Section Commenced 8.5"Production — 7646' MD,6540'TVD Hole Section Off Bot:20:00 27 July 2013 is On Bot:15:45 04 Aug 2013 — 8000 Landed 9.625"Casing 7632'MD, 6540'TVD 29 July 2013 9000 • 10000 •- TD Production Hole Section 10676' MD,9521'TVD Off Bot:22:45 03 August 2013 11000 12000 0 5 10 15 20 25 30 Rig Days IF4A1-1-1BLJIf:TDP4J Surface Data Logging sP rry t rng After Action Review WELL NAME: OP22-WW03 LOCATION: Oliktok Point OPERATOR: ENI Petroleum AREA: North Slope SPERRY JOB: AK-XX-0900579414 STATE: Alaska RIG: Nabors 245E HOLE SECTION Surface EMPLOYEE NAME: Todd A Wilson DATE: 14-Jul-2013 What went as, or better than,planned: Once we were able to reset the WITS configuration files, the surface section drilling went smoothly. Difficulties experienced: We experienced difficulty with the WITS configuration files being reset to default, which caused our WITS sending/receiving to malfunction. Recommendations: Make sure to take lots of screen shots of the WITS set up along with saving a copy of the WITS configuration files to prevent down time in case of the files being reset to default. Innovations and/or cost savings: N/A Sperry Drilling Confidential Document v 3.0 II-4ALL1BUR7"-"‘ Surface Data Logging •S par,'"y iClietnirkg After Action Review WELL NAME: OP22-WW03 LOCATION: Oliktok Point OPERATOR: ENI Petroleum AREA: North Slope SPERRY JOB: AK-XX-0900579414 STATE: Alaska RIG: Nabors 245E HOLE SECTION Intermediate EMPLOYEE NAME: Emil Opitz DATE: 28-Jul-2013 What went as, or better than, planned: Insite worked as planned. Difficulties experienced: Hydrogen Generator failing, Sucking up mud in gas lines. Recommendations: Keep an eye on the task at hand. Not routinely checking on our gear-gas trap and associated lines-will lead to inability to monitor gas while drilling. Innovations and/or cost savings: N/A Sperry Drilling Confidential Document v 3.0 it HALL.1EILiF TC31\t Surface Data Logging pr rry cord hrto9 After Action Review WELL NAME: OP22-WW03 LOCATION: Oliktok Point OPERATOR: ENI Petroleum AREA: North Slope SPERRY JOB: AK-XX-0900579414 STATE: Alaska RIG: Nabors 245E HOLE SECTION Production EMPLOYEE NAME: Emil Opitz DATE: 6-Aug-2013 What went as, or better than, planned: Insite worked as planned. Difficulties experienced: Sucking up mud in gas lines. WITS still not functional with SLB. Recommendations: Making sure to check our equipment on a regular basis; i.e. every connection. Will be able to troubleshoot WITS now that the well is completed. Innovations and/or cost savings: N/A Sperry Drilling Confidential Document v 3.0 HALLID JRTOIV Sperry o.-nn.,q Formation Tops WELL NAME: OP22-WW03 LOCATION: Oliktok Point OPERATOR: ENI Petroleum AREA: North Slope MUD CO: MI SWACO STATE: Alaska RIG: Nabors 245E SPUD: 6-Jul-2013 SPERRY JOB: AK-XX-0900579414 TD: 3-Aug-2013 Marker MD INC AZ TVD TVDSS 16"Surface Section _ SV-4 716.00 8.23 174.45 715.30 -662.30 SV-3 960.00 9.26 177.05 956.30 -903.30 SV-2 1229.00 4.12 182.59 1223.30 -1170.30 SV-1 1710.00 2.72 305.38 1703.20 -1650.20 Permafrost Base 1793.00 4.14 325.12 1786.00 -1733.00 Ugnu Top(UG4) 2025.00 7.11 336.30 2017.70 -1964.70 UG-2 Coal Bed Marker 2529.00 20.32 338.56 2505.10 -2452.10 Lower Ugnu 3253.00 36.40 329.14 3142.70 -3089.70 Schrader Bluff Top 3514.00 39.41 332.11 3347.00 -3294.00 N Sequence Top 3566.00 39.04 332.77 3387.20 -3334.20 N Top 3615.00 39.15 333.08 3425.20 -3372.20 N-2 Top 3633.00 39.20 331.20 3439.10 -3386.10 N-3 Top 3647.00 39.20 333.30 3450.00 -3397.00 N Bottom 3676.00 39.31 333.36 3472.30 -3419.30 N Sequence Base 3740.00 40.99 333.74 3521.10 -3468.10 OA Top 3816.00 42.02 334.51 3578.00 -3525.00 OA-2 Top 3829.00 42.15 334.67 3587.60 -3534.60 OA-3 Top 3847.00 42.33 334.89 3601.00 -3548.00 OA-4 Top 3861.00 42.46 335.00 3611.40 -3558.40 OA Bottom 3869.00 42.50 334.95 3617.30 -3564.30 13 3/8"Casing Point 4020.00 42.50 334.87 3727.40 -3674.40 TD 16"Hole Section 4031.00 42.42 334.95 3735.50 -368' 12 1/4"Intermediate Section Torok Top 6979.00 35.50 329.02 5967.20 -5914.20 Torok Base 7197.00 33.60 329.80 6145.50 -6092.50 HRZ 7530.00 24.89 331.31 6436.00 -6383.00 HRZ Base 7588.00 24.71 331.56 6488.60 _-6435.60 9 5/8"Casing Point 7632.00 24.69 332.30 6527.80 -6474.80 TD 12 1/4"hole section 7646.00 24.80 332.50 6540.50 -6487.50 8 1/2"Production Section Kalubik Marker 7693.00 23.50 333.10 6584.40 -6531.40 Kuparuk Top 7824.00 20.00 332.80 6706.00 -6653.00 LCU 7894.00 17.80 330.80 6772.30 -6719.30 Kuparuk Base 7908.00 17.37 330.59 6786.60 -6733.60 Marker 1 9177.00 8.09 331.68 8030.00 -7977.00 Marker 2 9362.40 6.74 325.50 8213.80 -8160.80 Sag D 9518.00 5.80 326.40 8368.50 -8315.50 Sag C 9541.00 5.80 325.70 8391.40 -8338.40 Sag B 9557.00 5.70 325.30 8407.30 -8354.30 Sag A 9591.00 5.60 324.60 8441.10 -8388.10 _ Shublik 9614.00 5.60 324.30 8464.00_ 111.00 Ivishak 9842.00 4.79 319.69 8691.10 _-8638.10 Kavik Shale 10469.00 4.60 317.20 9316.00 -9263.00 7"Liner 10658.00 4.40 314.60 9503.60 -9450.60 TD 8 1/2"hole section 10676.00 4.40 316.60 9521.50 -9468.50 HAWDUPTON T __F m_� Sperry Min Water and Oil Based Mud Record - 0 a m a h a `m 0 d m a m at0i c v m ¢ m E m u . _ a u _I zn Y o •U °�°� y - c a10i `0 z n a a m a e, -8 c o o d a `¢ a = N = ° = r L E 2 an d E 2 0 . rn m m ° m ¢ ¢ ¢ m m c c) E c)m a - .�l,;.' 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CO c9:c9:6 ")° , O O M N o 0 0 ¢ o 0 0 ° oo ° 0, U ar Q N Q Q Z Q Q Q o a o Q c n . m . . m cn O o 0 o cn-- O r Q Q O n n n n n n O) U 0 en LO N en .d.� J J J J J J J J d J > > > J J J J g g g g g Of O ,.:, ,L O N M Q in N CO 0 N N N N N N M M 4 N C cD HAL_LIBURTON Sperry Drilling Bit Record d c c O c ° o O O 0 O p O QI (n C U (/) O O YO U E a) (a a) U O E U = cn ° O 0 c a O F ❑ 0 d O ❑ ❑ ❑ H H 6 F- FT O d (n m Z N - f0 w w X X Q Q (7 Q 5 M N a- a C7 z o ° O 0 o E n ,n o O.� co co CM 0 J C a M p ❑_ O O Y O N d X O O O O O _c Y N O] d V E m N -O a1 Q E N N O z ¢ co r) z < W 0 C 2 m o O O Q d cc E V O O a• a (n0) U m O N •-- E 120 L N lA r <a O a QMi r Q N O N O N H O • y O O O _O •] O M I M M V a) O) a) Q N 8 M) O O M -- M ID M ^ M M r O ,p O m M N r Q O M V N V m M 3 w Lf) .r.. g O ° M v `°N O• ` N ° ❑ Q N Xj • a n '` N O O ( N a z m Y °' n N O w z ¢ CO w o 6 a0 O U K O z < j > + U -J W R' a) X 2 < X W a W o. r_ r 6 O • O a F- o ~°o rn O 0 m F-- F X ❑ () ax N M V N Ut enn O O O O Ut =• N In HALLIBtJRTOIV Sparry Grilling Morning Report Report#1 Customer: ENI Petroleum Job No.: AK-AM- Yesterdays Depth: 160' Well: OP22-W W03 Daily Charges: Current Depth: 160' Area: Nikaitchuq Total Charges: 24 Hour Progress: 0' Location: Oliktok Point Rig Activity: TIH w/Bridge Plug Date: 5-Jul-2013 Rig: Nabors 245 Report For: B.Simonson/C.Ruminer Time: 11:59 PM ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP ft/hr - - - - Flow In •.m - SPP •si - ---- Flow In (spm) - Gallons/stroke 4.23 @ 96% '.F,..�,.:: :'..«. �,^ .. .��».. ..... ..2,u�s.,..,._.:a-'bx... .,�zu.�.W,_ >-,.,,_ vns. ;;�,a:.�� .,..Ww&.� W�:r.�`• ��au�' ,,..mom.. .. MWD Summary Tools �' Min Max 0, Depth to 0 ECD (ppg) N/A N/A N/A Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud Tyse in out (sec/it) ••b Es cP (Ib/100ft2) ml/30min m./I % 160' Spud 8.70 8.70 130 N/A 32 33 8.6 9.00 3200.00 N/A Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition Size Set At Type Weight rade Comments I Casing 20" 160' Conductor 179.2 Summary Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) ------------ Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 - - - - - - - - Minimum 0 - - - - - - - - Average 0 - - - - - - - Background 0 Trip 0 Connection N/A ` 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Remove diverter knife valve,installed new one and tested.Pick up drill pipe and rack back in derrick.Function test diverter. Picked up 81 stands of 5 inch drill pipe and 4 stands of HWDP.Begin picking up BHA. Logging Engineers: Todd A.Wilson/Charles Sinn Report By: Todd A.Wilson Unit Phone: N/A 1 F-I LLIE JRTON parry Morning Report Rep ort# Or-tflir-rg ..z..®„ s Customer: ENI Petroleum Job No.: AK-AM- Yesterday's Depth: 160' Well: OP22-WW03 Daily Charges: Current Depth: 709' Area: Nikaitchuq Total Charges: 24 Hour Progress: 549' Location: Oliktok Point Rig Activity: Drilling Ahead Date: 6-Jul-2013 Rig: Nabors 245 Report For: B.Simonson/C.Ruminer Time: 11:59 PM ROP Current Avg 24 hr Max Max @ ft Current Pum• & Flow Data: ROP ft/hr - 284.0 475.0 688' Flow In ••m 487 SPP •si 816 ---- Flow In (spm) 136 Gallons/stroke 4.23 @ 96% _ Depth Tools Avg Min Max MWD Summary 0' to 0 ECD (ppg) N/A N/A N/A _ y Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids De•th Mud T •e in out (sec/qt) ••b E• cP (Ib/100ft2) ml/30min m•/I 160' Spud 8.70 8.70 130 N/A 32 33 8.6 9.00 3200.00 N/A Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Mill Tooth XR+ 16" 1.117 ------ Size Set At Type Weight Grade Comments Casing 20" 160' Conductor 179.2 Summary Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) -----_------ � f • Gas Summary i Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 7 855' - - - - - - - Minimum 1 381' - - - - - - - Average 4 - - - - - - - Background 0 Trip 0 Connection N/A * 10,000 Units = 100%Gas In Air 4 (current) (max) (max) 24 hr Recap: Picked up 16"mill tooth and mud motor.Reamed from 160'.Pull out of hole and picked up drilling BHA. Drilled ahead to 218'taking surveys. Drilled ahead from 218'to 310'.Pulled out of hole and added 3 flex collars and 2 joints of HWDP.Tripped in the hole to 306'and drilled ahead and taking surveys to 709'. Max Gas: 7 units Avg.Gas: 4 units Logging Engineers: Todd A.Wilson/Charles Sinn Report By: Todd A.Wilson Unit Phone: N/A HALLIBLJRTON 'Sperry Dremrig Morning Report Report#3 Customer: ENI Petroleum Job No.: AK-AM- Yesterday's Depth: 709' Well: OP22-W W03 Daily Charges: Current Depth: 2530' Area: Nikaitchuq Total Charges: 24 Hour Progress: 1821' Location: Oliktok Point Rig Activity: Drilling Ahead Date: 7-Jul-2013 Rig: Nabors 245 Report For: B.Simonson/C.Ruminer Time: 11:59 PM ROP Current Avg 24 hr Max Max @ ft Current6Pum• & Flow Data: ROP ft/hr 167.0 106.4 387.0 1801' Flow In •.m 551 SPP •si 1045 ---- Flow In (spm) 130 Gallons/stroke 4.23 @ 96% _ . . _ MWD Summary Death Tools �� ECD (ppg) Av. Min Max 0' to 0' N/A N/A N/A Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Death Mud Type in out (sec/•t) •.b E. cP (Ib/100ft2) ml/30min mg/I 2320' Spud 9.30 93.00 110 17.5 25 33 6.1 9.50 2800.00 3.0 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Mill Tooth XR+ 16' 1.117 ------ ._. Size Set At Type Weight Grade Comments Casing 20" 160' Conductor 179.2 Summary Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) ------------ Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 886 1945' 46448 0 0 0 0 0 0 Minimum 5 2058' 50 0 0 0 0 0 0 Average 139 19388 7 4 4 4 1 1 Background 130 Trip 0 Connection 635 * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Drill ahead from 709'MD to 2530'MD surveying at every connection.Background gas running approximately 130 to 150 units. Max Gas: 886 units Avg.Gas: 139 units Logging Engineers: Todd A.Wilson/Charles Sinn Report By: Todd A.Wilson Unit Phone: 907-685-1490 HALLIB[JRTON ekp Sperry (Drilling lli» Morning R ¢� , Customer: ENI Petroleum Job No.: AK-AM- Yesterday's Depth: 2530' Well: OP22-W W03 Daily Charges: Current Depth: 3299' Area: Nikaitchuq Total Charges: 24 Hour Progress: 770' Location: Oliktok Point Rig Activity: Backreaming- POOH Date: 8-Jul-2013 Rig: Nabors 245 Report For: B.Simonson/C.Ruminer Time: 11:59 PM ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP ft/hr 0.0 106.0 288.0 3225' Flow In .•m 806 SPP 'Si 1620 ---- Flow In (spm) 190 Gallons/stroke 4.23 @ 96% MWD Summary Det.th Tools ECD (ppg) Av. Min Max 0' to 0' N/A N/A N/A Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Death Mud Type in out (sec/qt) •.b E. cP (Ib/100ft2) ml/30min m./I % 3299' Spud 9.20 9.20 88 15.0 23 31 5.0 9.50 2000.00 4.0 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Mill Tooth XR+ 16" 1.117 33.30 160' 3299 3139' 24.0 50.0 Size Set At Type Weight Grade Comments Casing 20" 160' Conductor 179.2 Summary . .. Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) -_---------- Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 350 3026' 13418 0 0 0 0 0 0 Minimum 4 3279' 33 0 0 0 0 0 0 Average 103 12814 0 0 0 0 0 0 Background 45 Trip 0 Connection 350 * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Drill ahead from 2530'MD to 3290'MD and hit a hard spot.Made several attempts to dill thru and motor stalled. Pick up off bottom and circulated.Start backreaming out of hole for 6 stands,then attempt to pull on elevators to change BHA.Background gas running around 40 to 50 units. Max Gas: 350 units Avg.Gas: 103 units Logging Engineers: Todd A.Wilson/Charles Sinn Report By: Todd A.Wilson Unit Phone: 907-685-1490 HALLIBIJRTON -" /, r' Morning ,$ Spcerry Oritling '''..f-:At '"4 ,4,,,,,,, ,- r Customer: ENI Petroleum Job No.: AK-AM-0900579414 Yesterday's Depth: 3299' Well: OP22-WW03 Daily Charges: Current Depth: 3299' Area: Nikaitchuq Total Charges: 24 Hour Progress: 0' Location: Oliktok Point Rig Activity: Drilling Ahead Date: 9-Jul-2013 Rig: Nabors 245 Report For: B.Simonson/C.Ruminer Time: 11:59 PM ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP ft/hr 0.0 0.0 0.0 0' Flow In •am 650 SPP • 1320 ---- Flow In (spm) 153 Gallons/stroke 4.23 @ 96% ECD (ppg) MWD Summary De•th --.—.:77-72.7--Tools � �� Avg Min Max 0' to 0' N/A N/A N/A Mud Data Density(ppg) Viscosity MBT PV._ YP API FL pH Chlorides Cor Solids Death Mud Tyse in out (sec/at) a sb Es cP (Ib/100ft2) ml/30min mg/I 3299' Spud 9.30 9.30 90 15.0 25 31 5.6 9.00 2000.00 4.0 r Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Mill Tooth XR+ 16" 1.117 33.30 160' 3299' 3139' 24.0 50.0 2 Mill Tooth MX 1 16" 1.200 - 3299' ---- Size Set At Type Weight rade Comments Casing 20" 160' Conductor 179.2 Summary Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) ------------ Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 177 3299' 0 0 0 0 0 0 0 Minimum 0 0 0 0 0 0 0 0 Average 11 0 0 0 0 0 0 0 Background 35 Trip 177 Connection 0 * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Back ream from 3013'MD to 2687'MD.Trip out of hole on elevators.Lay down BHA#2.Pick up BHA#3.Trip in hole to 760'MD and shallow test MWDtrip in hole and reamed thru tight spots at 1991'MD and 2130'MD.Back ream MAD Pass from 3298'MD to 3189'MD. Max Gas: 117 units Avg.Gas: 11 units Logging Engineers: Todd A.Wilson/Charles Sinn Report By: Todd A.Wilson Unit Phone: 907-685-1490 HALL113iRTON ' O. `trit"i pesrry Clrilling Morning - ,€ n a, , IC 4 Customer: ENI Petroleum Job No.: AK-AM-0900579414 Yesterday's Depth: 3299' Well: OP22-W W03 Daily Charges: Current Depth: 4031' Area: Nikaitchuq Total Charges: 24 Hour Progress: 732' Location: Oliktok Point Rig Activity: POOH Backreaming Date: 10-Jul-2013 Rig: Nabors 245 Report For: B.Simonson/C.Ruminer Time: 11:59 PM SwF. ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP ft/hr 0.0 88.0 317.0 3345' Flow In ••m 744 SPP •si 1752 ---- Flow In (spm) 175 Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg Min Max 0' to 0' N/A N/A N/A Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Death Mud Type in out (sec/qt) •.b Es cP (Ib/100ft2) ml/30min mg/I % 4031' Spud 9.40 9.40 86 12.5 23 32 5.0 9.50 2000.00 3.0 v Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Mill Tooth XR+ 16" 1.117 33.30 160' 3299 3139' 24.0 50.0 2 Mill Tooth MX 1 16" 1.200 16.30 3299' 4031' 732' 40 59 Size Set At Type Weight rade Comments Casing 20" 160' Conductor 179.2 Summary Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) ------------ Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 5641 3825' 429186 4863 5034 2123 3219 1762 843 Minimum 15 3470' 1245 0 0 0 0 0 0 Average 429 37871 386 339 191 256 203 75 Background 170 Trip 0 Connection 991 * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Drill ahead from 3299'MD to TD at 4031'MD.Circulate bottoms up or until shakers clean.Started to see an increase in drill gas around 3800'MD.Gas peaked out at 3454 units at 3806'MD,decreased and then maxed out at 5641 units at 3825'MD. Background gas was running around 430 units.Start backreaming out of hole from 4031'and circulate bottoms up after 3 stands. Max Gas:5641 units Avg.Gas:429 units Logging Engineers: Todd A.Wilson/Charles Sinn Report By: Todd A.Wilson Unit Phone: 907-685-1490 HALLIBIJ RTC)N : ;, Sperry Oritiing Morning &��'� � � r Customer: ENI Petroleum Job No.: AK-AM-0900579414 Yesterday's Depth: 4031' Well: OP22-W W03 Daily Charges: Current Depth: 4031' Area: Nikaitchuq Total Charges: 24 Hour Progress: 732' Location: Oliktok Point Rig Activity: L/D BHA, Rig Repair Date: 11-Jul-2013_ Rig: Nabors 245 Report For: B.Simonson/C.Ruminer Time: 11:59 PM S�4'.9 .b ��fy.,. _u..�'F.r sa._ w..> .:A....,.,... � i ,.s .c<u... � a.�.... „..,..✓`.... ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP ft/hr 0.0 0.0 0.0 0' Flow In •am 0 SPP •si 0 ---- Flow In (spm) 0 Gallons/stroke 4.23 @ 96% MWD Summary Tools Avg Min Max 0, Depth to 0' ECD (ppg) N/A N/A N/A Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Death Mud Type in out (sec/at) a.b E. cP (Ib/100ft2) m1/30min ma/I 4031' Spud 9.50 9.50 88 25.0 16 23 5.7 8.50 1700.00 8.0 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Mill Tooth XR+ 16" 1.117 33.30 160' 3299' 3139' 24.0 50.0 2 Mill Tooth MX 1 16" 1.200 16.30 3299' 4031' 732' 40 59 „, ffi .° Size Set At Type Weight rade Comments Casing 20" 160' Conductor 179.2 Summary Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) ------------ Gas Summary Chromatograph(ppm) Units` Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 867 0 0 0 0 0 0 0 Minimum 5 0 0 0 0 0 0 0 Average 45 0 0 0 0 0 0 0 Background 0 Trip 0 Connection 0 10,000 Units = 100%Gas In Air (current) (max) (maxi 24 hr Recap: Backream out of hole.Lay down BHA#3 and prepare rig for casing run. Max Gas: 867 units Avg.Gas: 45 units Logging Engineers: Todd A.Wilson/Charles Sinn Report By: Todd A.Wilson Unit Phone: 907-685-1490 I HALLIBtJRTO1V i �� Bperry Clrilling ■ o F� Customer: ENI Petroleum Job No.: AK-AM-0900579414 Yesterday's Depth: 4031' Well: OP22-WW03 Daily Charges: Current Depth: 4031' Area: Nikaitchuq Total Charges: 24 Hour Progress: 732' Location: Oliktok Point Rig Activity: Running Casing Date: 12-Jul-2013 Rig: Nabors 245 Report For: B.Simonson/C.Ruminer Time: 11:59 PM 7 ROP Current Avg 24 hr Max Max @ ft Current Pum• & Flow Data: ROP ft/hr 0.0 0.0 0.0 0' Flow In ••m 203 SPP •si 101 ---- Flow In (spm) 48 Gallons/stroke 4.23 @ 96% Ww MWD Summary Depth Tools ECD (ppg) Av. Min Max 0' to 0' N/A N/A N/A Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Death Mud T se in out (sec/.t) •.b E. cP (1b/100(t2) ml/30min mg/I 4031' Spud 9.50 9.50 82 27.5 13 19 6.0 8.00 1600.00 8.0 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Mill Tooth XR+ 16" 1.117 33.30 160 3299' 3139' 24.0 50.0 2 Mill Tooth MX 1 16" 1.200 16.30 3299' 4031' 732' 40 59 Size Set At Type Weight Grade Comments Casing 20" 160' Conductor 179.2 Summary Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) ------------ Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 96 0 0 0 0 0 0 0 Minimum 2 0 0 0 0 0 0 0 Average 11 0 0 0 0 0 0 0 Background 11 Trip 0 Connection 0 * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Lay down BHA#3.Rig up to run 13 3/8"casing.Run casing to 3200'circulate bottoms up.Monitor losses. Max Gas:96 units Avg.Gas: 11 units Logging Engineers: Todd A.Wilson/Charles Sinn Report By: Todd A.Wilson Unit Phone: 907-685-1490 HALLIBLiRTON , "; Morn: Sperry Drilling a �: s .,.t ,. ....... dam' r, ✓-,.. 9r Customer: ENI Petroleum Job No.: AK-AM-0900579414 Yesterday's Depth: 4031' Well: OP22-WW03 Daily Charges: Current Depth: 4031' Area: Nikaitchuq Total Charges: 24 Hour Progress: 732' Location: Oliktok Point Rig Activity: Nipple down Date: 13-Jul-2013 Rig: Nabors 245 Report For: B.Simonson/C.Ruminer Time: 11:59 PM ROP Current Avg 24 hr Max Max @ ft Current Pum• & Flow Data: ROP ft/hr 0.0 0.0 0.0 0' Flow In ••m 203 SPP •si 101 ---- Flow In (spm) 48 Gallons/stroke 4.23 @ 96% MWD Summary Death Tools ECD (ppg) Av. Min Max 0' to 0' N/A N/A N/A Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Death Mud T se in out (sec/at) ••b Es cP (Ib/100ft2) m1/30min mg/I N/A N/A 0.00 0.00 0 0.0 0 0 0.0 0.00 0.00 0.0 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Mill Tooth XR+ 16" 1.117 33.30 160 3299' 3139' 24.0 50.0 2 Mill Tooth MX 1 16" 1.200 16.30 3299' 4031' 732' 40 59 Size Set At Type Weight Grade Comments Casing 20" 160' Conductor 179.2 Summary 13.375" 4020' Liner 66.1 ,.. .:a ,n � 7�. "fir d. _:, 3' ..`vn ?: Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) ----_------- .._-_ Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 260 0 0 0 0 0 0 0 Minimum 15 0 0 0 0 0 0 0 Average 15 0 0 0 0 0 0 0 Background 0 Trip 0 Connection 0 * 10,000 Units = 100%Gas In Air (current) (max) (max) _fi v 24 hr Recap: Circulate and condition hole.Continue running 13.375"casing form 3200'MD to 4020'MD.Circulate bottoms up. Max gas while circulating was 260 units.Rig up cementers and test lines. Pump 100 bbls mud push,590 bbls lead and 63 bbls tail. Displace with 603 bbls of mud.Flush stack and nipple down diverter. Max Gas:260 units Avg.Gas: 15 units Logging Engineers: Todd A.Wilson/Charles Sinn Report By: Todd A.Wilson Unit Phone: 907-685-1490 HALLIBLi I QN Morning .' :aiiIIIIii;;iIIIJIi perry drilling � Customer: ENI Petroleum Job No.: AK-AM-0900579414 Yesterday's Depth: 4031' Well: OP22-W W03 Daily Charges: Current Depth: 4031' Area: Nikaitchuq Total Charges: 24 Hour Progress: 732' Location: Oliktok Point Rig Activity: Casing Test Date: 14-Jul-2013 Rig: Nabors 245 Report For: B.Simonson/C.Ruminer Time: 11:59 PM ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP ft/hr 0.0 0.0 0.0 0' Flow In ..m 203 SPP .si 101 ---- Flow In (spm) 48 Gallons/stroke 4.23 @ 96% MWD Summary De•tn Tools ECD (ppg) Av• Min Max 0' to 0' N/A N/A N/A Mud Data Density(ppg) Viscosity MBT _ PV G .7_7 YP API FL pH Chlorides Cor Solids Death Mud Tyae in out (sec/at) ..b E. cP (Ib/100ft2) ml/30min me/1 % 4031' NaCI brine 9.30 9.30 0 0.0 0 0 0.0 0.00 0.00 0.0 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Mill Tooth XR+ 16" 1.117 33.30 160 3299' 3139' 24.0 50.0 2 Mill Tooth MX 1 16" 1.200 16.30 3299' 4031' 732' 40 59 Size Set At TYpe,_.._ Weight Grade Gr .._�,_. , . .....,,. Comments Casing 20" 160' Conductor 179.2 Summary 13.375" 4020' Liner 66.1 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) ------------ . ,.. ..�,,..,..,,.s.,w.w�`,:..v..�.,. �a .it:.., ..r.� ,..,.L.=_: . .: Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0 0 0 0 0 0 0 Minimum 0 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 0 Background 0 Trip 0 Connection 0 * 10,000 Units = 100%Gas In Air (current) - (max) (max) 24 hr Recap: Nipple up BOP and test.Take on 9.3 ppg NaCI brine.Test casing for 30 minutes to 2500 psi. Max Gas:0 units Avg.Gas:0 units Logging Engineers: Todd A.Wilson/Charles Sinn Report By: Todd A.Wilson Unit Phone: 907-685-1490 -IALLIBURTON f3parry Grilling Morning . f Customer: ENI Petroleum Job No.: AK-AM-0900579414 Yesterday's Depth: 4031' Well: OP22-W W03 Daily Charges: Current Depth: 4031' Area: Nikaitchuq Total Charges: 24 Hour Progress: 732' Location: Oliktok Point Rig Activity: Nipple down BOP Date: 15-Jul-2013 Rig: Nabors 245 Report For: B.Simonson/C. Ruminer Time: 11:59 PM ROP Current Avg 24 hr Max Max @ ft Current Pum• & Flow Data: ROP ft/hr 0.0 0.0 0.0 0' Flow In ••m 203 SPP •si 101 ---- Flow In (spm) 48 Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg Min Max 0' to 0' N/A N/A N/A Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Death Mud Ty.e in out (sec/qt) •.b Es cP (Ib/100ft2) ml/30min mg/I % N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A . mow.=. ,,.. Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 Mill Tooth XR+ 16" 1.117 33.30 160' 3299' 3139' 24.0 50.0 2 Mill Tooth MX 1 16" 1.200 16.30 3299' 4031' 732' 40 59 Size Set At Type Weight rade Comments Casing 20" 160' Conductor 179.2 Summary 13.375" 4020' Liner 66.1 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) ------------ Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0 0 0 0 0 0 0 Minimum 0 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 0 Background 0 Trip 0 Connection 0 * 10,000 Units = 100%Gas In Air (current) (max) lmax) 24 hr Recap: Nipple down BOP.Nipple up tree and test to 5000 psi.Rig up to freeze protect well. Max Gas:0 units Avg.Gas:0 units Logging Engineers: Todd A.Wilson/Charles Sinn Report By: Todd A.Wilson Unit Phone: 907-685-1490 HALLIE JRTON Sperry rail-Ming ._._....__. Morning Report Report#12 Customer: ENI Petroleum Job No.: AK-AM-0900599800 Yesterday's Depth: Well: OP22-WWO3 Daily Charges: Current Depth: 4031' Area: Nikaitchuq Total Charges: 24 Hour Progress: 0' Location: Oliktok Point Rig Activity: Setting BOP Stack Date: 22-Jul-2013 Rig: Nabors 245 Report For: Cozby/Sullivan Time: 11:59 PM ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP ft/hr 0.0 0.0 0.0 0' Flow In ..m 0 SPP .si 0 ---- Flow In(spm) 0 Gallons/stroke 4.23 @ 96% MWD Summary De.th Tools ECD Av. Min Max o' to 0 ... N/A N/A N/A :,=.�u.__ ...-....:1:1-.--22:�=II ''Y d_ ...r....71-1- .r spa =:=s Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud T se in out sec/qt) ..b E. cP (Ib/100ft2) ml/30min m•/I % 4031' N/A N/A N/A -------- Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 2 ------ Size Set At Type Weight rade Comments Casing 20" 160' 178.9 Summary 13 3/4" 4020' . == Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) _-----_----- Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0 0 0 0 0 0 0 Minimum 0 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 0 Background 0 Trip 0 Connection 0 * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Freeze protected the well with 120 bbls of diesel.Moved rig over from OP17-02 to OP22-WW03.Held pre-job safety meeting in the doghouse for setting BOP stack.Sperry standing by,running SDL checklist in preparation for drillout run 400. Max Gas:0 units Avg.Gas:0 units Logging Engineers: David McKechnie/Josiah Failing Report By: David McKechnie Unit Phone: 907-685-1490 144.1l_1-113URTON * b perry drilling Morning Report Report#12 Customer: ENI Petroleum Job No.: AK-AM-0900599800 Yesterday's Depth: Well: OP22-WWO3 Daily Charges: Current Depth: 4031' Area: Nikaitchuq Total Charges: 24 Hour Progress: 0' Location: Oliktok Point Rig Activity: Testing BOP Date: 23-Jul-2013 Rig: Nabors 245 Report For: Cozby/Sullivan Time: 11:59 PM ' a7«..:rr.77 ... .= 71 ^a. =., .. •"_ ,.... �. ' at,esiaLwut'.3s`m" ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP ft/hr 0.0 0.0 0.0 0' Flow In ..m 0 SPP .si 0 ---- Flow In (spm) 0 Gallons/stroke 4.23 @ 96% MWD Summary De.th Tools ECD Av. Min Max 0' to 0' ... N/A N/A N/A Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids De.th Mud T •e in out (sec/•t) ..b E. cP (Ib/100ft2) ml/30min m./I % 4031' N/A 9.30 N/A N/A N/A N/A N/A N/A N/A 108700 N/A Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 2 ------ Size Set At Type Weight ra.e Comments Casing 20" 160' 178.9 Summary 13 3/4" 4020' -- Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) ------------ �__ Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0 0 0 0 0 0 0 Minimum 0 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 0 Background 0 Trip 0 Connection 0 * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Continued nippling up BOP.Unseated hanger,shut top rams and reverse circulated 40 bbls of diesel through the choke to the possum belly.Shut down and pumped down 260 bbls of diesel from the backside at 30 bbls/min at 40 psi.Laid down tubing hanger and landing joint.Testing BOPS at report time. Max Gas:0 units Avg.Gas:0 units Logging Engineers: David McKechnie/Josiah Failing Report By: David McKechnie Unit Phone: 907-685-1490 HALLrID JRTON (:',:' 1r" Morning . ai .Fx Sperry Chilling 4 y,. Customer: ENI Petroleum Job No.: AK-AM-0900599800 Yesterday's Depth: Well: OP22-WWO3 Daily Charges: Current Depth: 4031' Area: Nikaitchuq Total Charges: 24 Hour Progress: 0' Location: Oliktok Point Rig Activity: RIH on 5" Drill pipe Date: 24-Jul-2013 Rig: Nabors 245 Report For: Cozby/Sullivan Time: 11:59 PM ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP ft/hr 0.0 0.0 0.0 0' Flow In s am 0 SPP .si 0 f ---- Flow In (spm) 0 Gallons/stroke 4.23 @ 96% MWD Summary Death Tools ECD Av• Min Max 4031' to 0' ... N/A N/A N/A Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Death Mud T se in out (sec/qt) ..b E. cP (Ib/100ft2) ml/30min m•/I % 4031' N/A 9.30 N/A N/A N/A N/A N/A N/A N/A 108700 N/A Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 4 MSX619S-A6C 12.125 1.178 0.00 4031' 0' 0.0 0.0 N/A Size Set At Type Weight rase Comments Casing 20" 160' 178.9 Summary 13 3/4" 4020' 66.1 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) --_--------- r , Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0 0 0 0 0 0 0 Minimum 0 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 0 Background 0 Trip 0 Connection 0 * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Finished testing BOP. Laid down testing tool and pulled test plug. Installed wear ring. Picked up and made up drill pipe,running in on singles.Racked back 81 stands in the Derrick.Picked up BHA and began running in the hole.Running in the hole to 1,526'at report time. Max Gas:0 units Avg.Gas:0 units Logging Engineers: David McKechnie/Josiah Failing Report By: David McKechnie Unit Phone: 907-685-1490 HALLIBLIF1TON Sperry Oriiring --- Morning Report Report#15 Customer: ENI Petroleum Job No.: AK-AM-0900599800 Yesterday's Depth: 4020' Well: OP22-WWO3 Daily Charges: Current Depth: 4720' Area: Nikaitchuq Total Charges: 24 Hour Progress: 689' Location: Oliktok Point Rig Activity: Drilling Ahead Date: 25-Jul-2013 Rig: Nabors 245 Report For: Cozby/Sullivan Time: 11:59 PM ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP ft/hr 140.0 160.0 318.0 4357' Flow In ..m 0 SPP •si 0 ---- Flow In (spm) 0 Gallons/stroke 4.23 © 96% MWD Summary De.th Tools ECD . Min Max 4031' to 0 ... N/A N/A N/A - - - �..�___. �...�.� �Wes• �>�, �� _ -vim� Mud Data Density(ppg) Viscosity MBT PV YP API FL pH Chlorides Cor Solids Depth Mud T pe in out sec/.t ••b E. cP (Ib/100ft2) m1/30min m./I % 4720' LSND 9.30 9.35 48' N/A 8.00 18.00 6.0 9.50 3000 4.0 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 4 MSX619S-A6C 12.125 1.178 11.00 4031 689' 0.0 0.0 N/A Size Set At Type Weight re-de Comments Casing 20" 160' 178.9 Summary 13 3/8" 4020' 66.1 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) ------------ Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 404 45613 459 238 102 99 147 171 Minimum 40 5808 57 29 13 12 20 24 Average 60 6283 39 4 4 0 12 18 Background 60 Trip 0 Connection 0 * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Ran in the hole with 12 1/4"bit and tagged cement at 3,923. Drilled out cement to 13 3/8"shoe.Displaced 9.1 PPG brine with 9.25 PPG LSND.Slipped and cut drill line.Performed FIT to 12.53.Drilling out to 4,720 at report time. Max Gas:404 units Avg.Gas:60 units Logging Engineers: David McKechnie/Josiah Failing Report By: David McKechnie Unit Phone: 907-685-1490 ,,€HALLIBURTON ,, 4 Sperry Qritiing M ori�ng d-#: IElilir(it Id' �!?gLff„'�@„hrii, r a SFr ..s �` Customer: ENI Petroleum Job No.: AK-AM-0900579414 Yesterday's Depth: 4720' Well: OP22-WW03 Daily Charges: Current Depth: 6550' Area: Nikaitchuq Total Charges: 24 Hour Progress: 1830' Location: Oliktok Point Rig Activity: Drilling Ahead Date: 26-Jul-2013 Rig: Nabors 245 Report For: O.Amend/D.Sherman Time: 24:00:00 "',os. .....,,u„x k�a.._;.,.t3. .....,... v.., _ xA., sv. m,.. ..,.._.u. �':"?....,x ...u...c...,z� .� ...,. .,Mti n...:....... ✓.. ROP Current Avg 24 hr Max Max @ ft Current Pum• & Flow Data: ROP ft/hr 121.6 118.5 283.6 5927' Flow In ••m 895 SPP •si 2434 ---- Flow In (spm) 211 Gallons/stroke 4.23 @ 96% , n,i'. ¢.y.. ...a:L.wri�»� ,- €vi. ..w;Y'wt'.:b3,... .,v.._..2`td"��'.s�..r °p" d."a�...✓.S�r�' ..,,ar... .......x ,.us'.i� ...,d L°idiv:...c MWD Summary De.th Tools ECD (ppg) Avg Min Max 4720' to 6550' PDM 1.5 Bend,ARC 825, Powerpulse 825 N/A N/A N/A Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal pH Cor Solids Death Mud T pe in out (sec/qt) Ratio cP (Ib/100ft2) ml/30min Mud 6600' LSND 9.50 9.50 55 2/92 13 31 4.0 0.33 9.70 6.00 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 3 MSX619S-A6C 12.25 1.178 - 4031' ---- d . Size Set At Type Weight rade Comments Casing 20" 160' 178.9 X-65 Summary 13 3/8" 4020' BTC 68.0 L-80 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) ------------ .� Gas Summary Chromatograph(ppm) Units" Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 90 5114' 11349 74 3 3 3 9 0 Minimum 25 6502' 3043 47 11 3 5 0 0 Average 39 4681 39 5 1 1 2 3 Background 20 Trip - Connection - * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Continue drilling ahead. Logging Engineers: E.Opitz/J.Failing Report By: E.Opitz Unit Phone: (907)685-1490 HALLIBIJFiTON " "' Mornr Spec^ry aril line iIIIIILJiII1d Customer: ENI Petroleum Job No.: AK-AM-0900579414 Yesterday's Depth: 6550' Well: OP22-WW03 Daily Charges: Current Depth: 7646' Area: Nikaitchuq Total Charges: 24 Hour Progress: 1096' Location: Oliktok Point Rig Activity: BROOH Date: 27-Jul-2013 Rig: Nabors 245 Report For: O.Amend/D.Sherman Time: 24:00:00 _• a ROP Current Avg 24 hr Max Max @ ft Current Pum• & Flow Data: ROP ft/hr 82.3 140.5 7611' Flow In •em 897 SPP 'Si 2741 ---- Flow In (spm) 212 Gallons/stroke 4.23 @ 96% De.th Tools Av. Min Max MWD Summary?TT.6550' to 7646' PDM 1.5 Bend,ARC 825, Powerpulse 825 ECD (ppg) N/A N/A N/A _ Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal pH Cor Solids Death Mud Type in out (sec/it) Ratio cP (Ib/100ft2) ml/30min Mud % 7500' LSND 9.80 9.85 58 2/91 15 26 4.2 0.30 9.70 7.50 7,= Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM _ Condition 3 MSX619S-A6C 12.25 1.178 - 4031' ---- Size Set At Type Weight Grade Comments Casing 20" 160' 178.9 X-65 Summary 13 3/8" 4020' BTC 68.0 L-80 7..._w._ .... . . . _ . . . - ._... . 7__. ._ : 7.1 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) ------------ Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 223 7622' 25019 1010 473 82 155 46 80 Minimum 28 6600' 3150 55 15 5 7 3 0 Average 76 8331 245 90 17 27 9 14 Background 69 Trip 121 Connection - * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Continue drilling ahead to intermediate TD of 7646'MD. BROOH. Logging Engineers: E.Opitz/J. Failing Report By: E.Opitz Unit Phone: (907)685-1490 1.91ALL113tJRTON gpdr ry Drilling Morning Report Report# 18 Customer: ENI Petroleum Job No.: AK-AM-0900579414 Yesterday's Depth: 7646' Well: OP22-W W03 Daily Charges: Current Depth: 7646' Area: Nikaitchuq Total Charges: 24 Hour Progress: 0' Location: Oliktok Point Rig Activity: Change RAMs Date: 28-Jul-2013 Rig: Nabors 245 Report For: O.Amend/D.Sherman Time: 24:00:00 ROP Current Avg 24 hr Max Max @ It Current Pump & Flow Data: ROP (ft/hr) Flow In (gpm) SPP (psi) Flow In (spm) Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg Min Max 7646' to 7646' N/A N/A N/A - ='•ins:. Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal pH Cor Solids Depth Mud Type in out (sec/qt) Ratio cP (Ib/100ft2) ml/30min Mud 7646' LSND 9.80 54 2/91 13 28 4.4 0.20 9.60 7.50 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 3 MSX619S-A6C 12.25 1.178 38.70 4031' 7646' 3615' 15.0 100.0 1-1-CT-G-X-2-WT-TD Size Set At Type Weight rade Comments Casing 20" 160' 178.9 X-65 Summary 13 3/8" 4020' BTC 68.0 L-80 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) Gas Summary Chromatograph(ppm) Units" Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0 0 0 0 0 0 Minimum 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 Background - Trip 177 Connection - " 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Finish BROOH and L/D BHA#4. Begin to change RAMs. Logging Engineers: E.Opitz/J. Failing Report By: E.Opitz Unit Phone: (907)685-1490 HALLIBURTOIV Sperry Drilling Morning Report Report#19 Customer: ENI Petroleum Job No.: AK-AM-0900579414 Yesterday's Depth: 7646' Well: OP22-W W03 Daily Charges: Current Depth: 7646' Area: Nikaitchuq Total Charges: 24 Hour Progress: 0' Location: Oliktok Point Rig Activity: Change RAMs Date: 29-Jul-2013 Rig: Nabors 245 Report For: O.Amend/D.Sherman Time: 24:00:00 ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP(ft/hr) Flow In(gpm) SPP (psi) Flow In (spm) Gallons/stroke 4.23 @ 96% ,:f MWD Summary Depth Tools ECD (ppg) Avg Min Max 7646' to 7646' N/A N/A N/A Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal pH Cor Solids Depth Mud Type in out (sec/qt) Ratio cP (Ib/100ft2) ml/30min Mud 7646' LSND 9.80 56 2/91 15 21 4.4 0.23 9.60 7.50 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 3 MSX619S-A6C 12.25 1.178 38.70 4031' 7646' 3615' 15.0 100.0 1-1-CT-G-X-2-WT-TD �.W, � .. ___ -_._. _ �,x �_�..�. ._, e ,.�:` : :: •. :•.,, .gam, _ ;�;, Size Set At Type Weight Grade Comments Casing 20" 160' 178.9 X-65 Summary 13 3/8" 4020' BTC 68.0 L-80 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0 0 0 0 0 0 Minimum 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 Background - Trip 255 Connection - * 10,000 Units = 100%Gas In Air (current) - (max) (max) 24 hr Recap: R/U to run casing,and begin to run casing. At 3940'MD as of report time. Logging Engineers: E.Opitz/J. Failing Report By: E.Opitz Unit Phone: (907)685-1490 HALL1BlJRTC: "V Sperry rDrirring Morning Report Report#20 Customer: ENI Petroleum Job No.: AK-AM-0900579414 Yesterday's Depth: 7646' Well: OP22-WW03 Daily Charges: Current Depth: 7646' Area: Nikaitchuq Total Charges: 24 Hour Progress: 0' Location: Oliktok Point Rig Activity: Change RAMs Date: 30-Jul-2013 Rig: Nabors 245 Report For: B. Perry/C. Ruminer Time: 24:00:00 ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP ft/hr ---- Flow In .•m SPP .si ---- Flow In (spm) Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg Min Max 7646' to 7646' N/A N/A N/A Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal pH Cor Solids Desth Mud T se in out (sec/qt) Ratio cP (Ib/100ft2) ml/30min Mud 7646' LSND 9.80 53 2/91 12 17 4.2 0.50 8.50 7.50 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition Size Set At Type Weight Grade Comments Casing 20" 160' 178.9 X-65 Summary 13 3/8" 4020' BTC 68.0 L-80 9 5/8" 7632' Hydril 563 40.0 L-80 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) --------_--- Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0 0 0 0 0 0 Minimum 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 Background - Trip 968 Connection - * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Run casing to 7632'MD. R/U SLB Cementing. Cement casing. R/D cementing and change out RAMs. Logging Engineers: E.Opitz/J. Failing Report By: E.Opitz Unit Phone: (907)685-1490 HALLIBIJRTON parry Qrirling Morning Report Report#21 Customer: ENI Petroleum Job No.: AK-AM-0900579414 Yesterday's Depth: 7646' Well: OP22-W W03 Daily Charges: Current Depth: 7646' Area: Nikaitchuq Total Charges: 24 Hour Progress: 0' Location: Oliktok Point Rig Activity: RIH w/BHA#5 Date: 31-Jul-2013 Rig: Nabors 245 Report For: B. Perry/C. Ruminer Time: 24:00:00 ., ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: ROP ft/hr ---- Flow In ..m SPP .si ---- Flow In (spm) Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Av. Min Max 7646' to 7646' ARC 675, PowerPulse 675 _-- Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal pH Cor Solids De.th Mud T se in out (sec/qt) Ratio cP (Ib/100ft2) ml/30min Mud 7646' LSND 9.80 52 2/91 12 17 4.2 0.05 8.50 7.50 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 4 Hughes DP606X 8.5" 0.902 _ 7646' ---- . Size Set At Type Weight Grade Comments Casing 20" 160' 178.9 X-65 Summary 13 3/8" 4020' BTC 68.0 L-80 9 5/8" 7632' Hydril 563 40.0 L-80 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) ---------_-- .. Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0 0 0 0 0 0 Minimum 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 Background - Trip - Connection - * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Finish changing out RAMs. Test BOPs. M/U and P/U BHA#5. RIH w/BHA#5. Logging Engineers: E.Opitz/C.Sinn Report By: E.Opitz Unit Phone: (907)685-1490 HALLIBLJF;TON ■drry Or cling Morning Report Report#22 Customer: ENI Petroleum Job No.: AK-AM-0900579414 Yesterday's Depth: 7646' Well: OP22-W W03 Daily Charges: Current Depth: 8007' Area: Nikaitchuq Total Charges: 24 Hour Progress: 361' Location: Oliktok Point Rig Activity: Drill Ahead Date: 1-Aug-2013 Rig: Nabors 245 Report For: B. Perry/C. Ruminer Time: 24:00:00 ROP Current Avg 24 hr Max Max @ ft Current Pum• & Flow Data: ROP ft/hr 73.0 82.9 243.2 7744' Flow In ••m 554 SPP •si 2119 ---- Flow In (spm) 131 Gallons/stroke 4.23 @ 96% 7 _: MWD Summary Death Tools ECD (ppg) Avg Min Max 7646' to 8007' ARC 675, PowerPulse 675 --- Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal pH Cor Solids Death Mud T se in out (sec/•t) Ratio cP (Ib/100ft2) m1/30min Mud % 7950' LSND 10.50 10.50 53 3/88 15 22 4.4 0.30 9.50 10.00 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 4 Hughes DP606X 8.5" 0.902 - 7646' ---- Size Set At Type Weight Grade Comments Casing 20" 160' 178.9 X-65 Summary 13 3/8" 4020' BTC 68.0 L-80 9 5/8" 7632' Hydril 563 40.0 L-80 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) ------------ Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 1809 7947' 156620 7700 4880 1233 1403 582 410 Minimum 11 7843' 965 42 33 9 14 4 5 - Average 69 6904 263 133 30 38 13 11 Background 12 Trip 66 Connection - ` 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Perform casing pressure test. Displace to new LSND mud. Drill out cement and 20'new formation. Perform FIT to 13.0 ppg EMW. Drill ahead in 8.5"section. Logging Engineers: E.Opitz/C.Sinn Report By: E.Opitz Unit Phone: (907)685-1490 HALLI8 JRTOIV Sperry Orirring Morning Report Report#23 Customer: ENI Petroleum Job No.: AK-AM-0900579414 Yesterdays Depth: 8007' Well: OP22-WW03 Daily Charges: Current Depth: 9348' Area: Nikaitchuq Total Charges: 24 Hour Progress: 1341' Location: Oliktok Point Rig Activity: Drill Ahead Date: 2-Aug-2013 Rig: Nabors 245 Report For: B. Perry/C. Ruminer Time: 24:00:00 ROP Current Avg 24 hr Max Max @ ft Current Pum• & Flow Data: ROP ft/hr 118.0 105.6 264.7 8583' Flow In ••m 491 SPP •si 2263 ---- Flow In (spm) 116 Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Min Max 8007' to 9348' ARC 675, PowerPulse 675 --- :: 7 w Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal . pH Cor Solids Death Mud Type in out (sec/•t) Ratio cP (Ib/100ft2) ml/30min Mud % 9350' LSND 10.60 10.60 58 3/88 18 25 4.5 0.40 9.90 10.50 m T h _ $7," w,...s.... .®_ �.4..=.o- .,.�..s.. Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 4 Hughes DP606X 8.5" 0.902 - 7646 ---- Size Set At Type Weight Grade Comments Casing 20" 160' 178.9 X-65 Summary 13 3/8" 4020' BTC 68.0 L-80 9 5/8" 7632' Hydril 563 40.0 L-80 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) ------------ Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 203 8027' 21201 839 468 111 129 55 40 Minimum 11 8708' 811 24 26 9 17 9 6 Average 52 5054 174 132 27 52 19 15 Background 21 Trip - Connection - * 10,000 Units = 100%Gas In Air (current) (max) (max) ... _. 24 hr Recap: Continue to drill ahead in 8.5"section Logging Engineers: E.Opitz/C.Sinn Report By: E.Opitz Unit Phone: (907)685-1490 HALLIBLJRTON Mornin 3 Sperry Critling "�"""" � � Customer: ENI Petroleum Job No.: AK-AM-0900579414 Yesterday's Depth: 9348' Well: OP22-W W03 Daily Charges: Current Depth: 10676' Area: Nikaitchuq Total Charges: 24 Hour Progress: 1328' Location: Oliktok Point Rig Activity: BROOH Date: 3-Aug-2013 Rig: Nabors 245 Report For: B. Perry/C. Ruminer Time: 24:00:00 ROP Current Avg 24 hr Max Max @ ft Current Pum• & Flow Data: ROP ft/hr 92.5 171.9 9932' Flow In ••m 550 SPP •si 2063 ---- Flow In (spm) 130 Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg) Avg Min Max 9348' to 10676' ARC 675, PowerPulse 675 -_- Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal pH Cor Solids Depth Mud Type in out (sec/it) Ratio cP (Ib/100ft2) ml/30min Mud 0/0 10676' LSND 10.50 10.50 56 2/87 17 28 4.5 0.30 9.60 11.00 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 4 Hughes DP606X 8.5" 0.902 - 7646' ---- T Size Set At Type Weight Grade Comments Casing 20" 160' 178.9 X-65 Summary 13 3/8" 4020' BTC 68.0 L-80 9 5/8" 7632' Hydril 563 40.0 L-80 . Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst ... Coal Gvl Tuff Cement (current) ------------ Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 495 9894' 54870 2151 832 113 304 84 122 Minimum 13 10663' 1027 26 16 0 8 0 0 Average 107 8933 362 223 32 109 31 44 Background 6 Trip 32 Connection 200 * 10,000 Units = 100%Gas In Air (current) (max) tmaxf 24 hr Recap: Continue to drill ahead in 8.5"section to final TD of 10676'MD. Begin to BROOH per K&M. Logging Engineers: E.Opitz/C.Sinn Report By: E.Opitz Unit Phone: (907)685-1490 HALLIBLJRTON "' , parry frilling Morning Report Report#25 Customer: ENI Petroleum Job No.: AK-AM-0900579414 Yesterday's Depth: 10676' Well: OP22-W W03 Daily Charges: Current Depth: 10676' Area: Nikaitchuq Total Charges: 24 Hour Progress: 0' Location: Oliktok Point Rig Activity: BROOH Date: 4-Aug-2013 Rig: Nabors 245 Report For: B. Perry/C. Ruminer Time: 24:00:00 ROP Current Avg 24 hr Max Max @ ft Current Pum• & Flow Data: ROP ft/hr ---- Flow In •sm SPP •si ---- Flow In (spm) Gallons/stroke 4.23 @ 96% MWD Summary 10676 Depth Tools ECD (ppg)=== ' to 10676' Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal pH Cor Solids Depth Mud Tyse in out (sec/st) Ratio cP (lb/100ft2) m1/30min Mud 10676' LSND 10.50 58 3/86 15 36 4.5 0.30 9.80 11.00 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 4 Hushes DP606X 8.5" 0.902 - 7646' ---- Size Set At Type Weight Grade Comments Casing 20" 160' 178.9 X-65 Summary 13 3/8" 4020' BTC 68.0 L-80 9 5/8" 7632' Hydril 563 40.0 L-80 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) ------------ Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0 0 0 0 0 0 Minimum 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 Background - Trip 199 Connection - ' 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: BROOH per K&M. Circulate hole at casing shoe. POOH and begin to L/D BHA#5. Logging Engineers: E.Opitz/C.Sinn Report By: E.Opitz Unit Phone: (907)685-1490 HALLIBtJRTON 0 ;k Morning Sparoy Grilling g Z' ¢ rr Customer: ENI Petroleum Job No.: AK-AM-0900579414 Yesterday's Depth: 10676' Well: OP22-WW03 Daily Charges: Current Depth: 10676' Area: Nikaitchuq Total Charges: 24 Hour Progress: 0' Location: Oliktok Point Rig Activity: RIH w/7" liner Date: 5-Aug-2013 Rig: Nabors 245 Report For: B. Perry/C. Ruminer Time: 24:00:00 ROP Current Avg 24 hr Max Max @ ft Current Pum• & Flow Data: ROP ft/hr ---- Flow In ••m SPP •si ---- Flow In (spm) _ Gallons/stroke 4.23 @ 96% .. MWD Summary Depth Tools ECD (ppg) === 10676' to 10676' Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal pH Cor Solids Death Mud Ty.e in out (sec/qt) Ratio cP (Ib/100ft2) ml/30min Mud % 10676' LSND 10.50 58 3/86 15 37 4.5 0.30 9.80 11.00 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 4 Hughes DP606X 8.5" 0.902 - 7646' ---- Size Set At Type Weight Grade Comments Casing 20" 160' 178.9 X-65 Summary 13 3/8" 4020' BTC 68.0 L-80 9 5/8" 7632' Hydril 563 40.0 L-80 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) ------------ Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0 0 0 0 0 0 Minimum 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 Background - Trip 2 Connection - * 10,000 Units = 100%Gas In Air (current) (max) tmax) 24 hr Recap: Finish L/D BHA#5. Test RAMs. R/U for 7"liner run,and begin to RIH. At 3250'MD at report time. Logging Engineers: E.Opitz/C.Sinn Report By: E.Opitz Unit Phone: (907)685-1490 HALLI BU FITON Sperry Drilling Morning Report Report#27 Customer: ENI Petroleum Job No.: AK-AM-0900579414 Yesterday's Depth: 10676' Well: OP22-W W03 Daily Charges: Current Depth: 10676' Area: Nikaitchuq Total Charges: 24 Hour Progress: 0' Location: Oliktok Point Rig Activity: TOOH w/5" DP Date: 6-Aug-2013 Rig: Nabors 245 Report For: B. Perry/C. Ruminer Time: 24:00:00 ROP Current Avg 24 hr Max Max @ it Current Pump & Flow Data: ROP ft/hr ---- Flow In ..m SPP .si ---- Flow In (spm) Gallons/stroke 4.23 @ 96% MWD Summary De•tn Tools ECD (ppg)=== 10676' to 10676' Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal pH Cor Solids De•th Mud T .e in out (sec/it) Ratio cP (Ib/100ft2) ml/30min Mud % 10676' LSND 10.50 - 50 - 13 17 - - 8.10 - Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 4 Hughes DP606X 8.5" 0.902 41.10 7646' 10676' 3030' 15.0 100.0 1-1-WT-A-X-I-NO-TD .= ,... r:„ r. ,,,.,: te :� `%'';�,_ «.,�.;�...'.�,;,s_:, .2.22._=7— - �> T. 5. Size Set At Type Weight Grade Comments Casing 20" 160' 178.9 X-65 Summary 13 3/8" 4020' BTC 68.0 L-80 9 5/8" 7632' Hydril 563 40.0 L-80 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) --_--------- Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0 0 0 0 0 0 Minimum 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 Background - Trip 92 Connection - * 10,000 Units = 100%Gas In Air (current) (max) lmax) 24 hr Recap: Finish RIH with 7"liner to 10658'MD. R/U and cement liner. R/D cementing equipment and begin to TOOH with 5". Logging Engineers: E.Opitz/C.Sinn Report By: E.Opitz Unit Phone: (907)685-1490 HALLIBtJRTON ,, v fi, l.01 PsrrY ClrHiing --_.`--"' Morn' t �� . lAWil Customer: ENI Petroleum Job No.: AK-AM-0900579414 Yesterday's Depth: 10676' Well: OP22-WW03 Daily Charges: Current Depth: 10676' Area: Nikaitchuq Total Charges: 24 Hour Progress: 0' Location: Oliktok Point Rig Activity: Circulate and condition Date: 7-Aug-2013 Rig: Nabors 245 Report For: B. Perry/C. Ruminer Time: 24:00:00 ROP Current Avg 24 hr Max Max @ ft Current Pum• & Flow Data: ROP ft/hr ---- Flow In •on SPP •si ---- Flow In (spm) _ Gallons/stroke 4.23 @ 96% MWD Summary Depth Tools ECD (ppg)== Max 10676' to 10676' 277 ._.. _- Mud Data Density(ppg) Viscosity Oil/Water PV YP API FL Alkal pH Cor Solids Depth Mud Type in out (sec/it) Ratio cP (Ib/100ft2) ml/30min Mud 10676' LSND 10.50 - 50 - 13 17 - - 8.50 Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition L. g 2.. .,.. ,... _ =7 emu. 77 Size Set At Type Weight rade Comments Casing 20" 160' 178.9 X-65 Summary 13 3/8" 4020' BTC 68.0 L-80 9 5/8" 7632' Hydril 563 40.0 L-80 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) ------_----- „t Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0 0 0 0 0 0 Minimum 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 Background - Trip - Connection - * 10,000 Units = 100%Gas In Air (current) (max) (max) 24 hr Recap: Finish TOOH and racking back 5"DP. Pick up and TIH w/106 4"DP singles. Finish TIH on 5"DP to 10577'MD. Begin to circulate and condition mud in preparation for displacement to 9.5ppg brine. Logging Engineers: E.Opitz/C.Sinn Report By: E.Opitz Unit Phone: (907)685-1490 I-IALLIBLill:ITON Sp„nrry Orfilir.cg. Mar`fIfr -' ` "d �, Customer: ENI Petroleum Job No.: AK-AM-090057941.4 Yesterday's Depth: 10676' Well: OP22-W W03 Daily Charges: Current Depth: 10676' Area: Nikaitchuq Total Charges: 24 Hour Progress: 0' Location: Oliktok Point Rig Activity: TIH w/Perforating BHA Date: 8-Aug-2013 Rig: Nabors 245 Report For: B. Perry/C. Ruminer Time: 24:00:00 ROP Current Avg 24 hr Max Max @ ft Current Pum• & Flow Data: ROP ft/hr ---- Flow In ..m SPP .si ---- Flow In (spm) _ Gallons/stroke 4.23 @ 96% MWD Summary Death Tools ECD (ppg) Av. Min Max 10676' to 10676' --- Mud Data Density(ppg) Viscosity Oil/Water PV YP Chlorides Alkal pH Cor Solids Death Mud T •e in out (sec/•t) Ratio cP (lb/1 00ft2) m•/L Mud % 10676' NaCI/KCI Brine 9.50 - 28 - - - 134000 as - . Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition Size Set At Type Weight Grade Comments Casing 20" 160' 178.9 X-65 Summary 13 3/8" 4020' BTC 68.0 L-80 9 5/8" 7632' Hydril 563 40.0 L-80 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) ------------ Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0 0 0 0 0 0 Minimum 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 Background - Trip 3 Connection - * 10,000 Units = 100%Gas In Air (current) (max) fmax) 24 hr Recap: Displace hole to 9.5 ppg Brine. POOH. M/U and P/U perforating BHA and RIH. At 5900'MD at report time. Logging Engineers: E.Opitz/C.Sinn Report By: E.Opitz Unit Phone: (907)685-1490 HALL1E3URTON pf..,•.-Y orif g Morning Report Report#30. Customer: ENI Petroleum Job No.: AK-AM-0900579414 Yesterday's Depth: 10676' Well: OP22-WW03 Daily Charges: Current Depth: 10676' Area: Nikaitchuq Total Charges: 24 Hour Progress: 0' Location: Oliktok Point Rig Activity: L/D Perforating BHA Date: 9-Aug-2013 Rig: Nabors 245 Report For: B. Perry/C. Ruminer Time: 24:00:00 ROP Current Avg 24 hr Max Max @ ft Current Pum• & Flow Data: ROP ft/hr ---- Flow In ••m SPP •si ---- Flow In (spm) _ Gallons/stroke 4.23 @ 96% MWD Summary De.th Tools ECD (ppg)=-- 10676' to 10676' Gamma 'I:7=1_1_ ::_.. _ _h : - _J.1W .. 7. Mud Data Density(ppg) Viscosity Oil/Water PV YP Chlorides Alkal pH Cor Solids De.th Mud T .e in out (sec/qt) Ratio cP (Ib/100ft2) mg/L Mud 10676' NaCI/KCI Brine 9.50 - 28 - - - 133000 - --. ....... .. .g...w ,e„ < a: = �., ,..:.�.::.:.. ., � _.._„ ,. _:'2 _ .:mot, Bit# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition Size Set At Type Weight Grade Comments Casing 20” 160' 178.9 X-65 Summary 13 3/8" 4020' BTC 68.0 L-80 9 5/8" 7632' Hydril 563 40.0 L-80 Lithology(%) Ss Cht Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff Cement (current) ------------ Gas Summary Chromatograph(ppm) Units* Depth C-1 C-2 C-3 C-4i C-4n C-5i C-5n Maximum 0 0 0 0 0 0 0 Minimum 0 0 0 0 0 0 0 Average 0 0 0 0 0 0 0 Background - Trip - Connection - * 10,000 Units = 100%Gas In Air I (current) (max) tmaxt _ _ . 24 hr Recap: Log hole w/Gamma to correlate perforating depths. Perforate well per Geo. POOH and L/D 5"DP and 4"DP singles. I Logging Engineers: E.Opitz/C.Sinn Report By: E.Opitz Unit Phone: (907)685-1490 IHALLIBURTON I Sperry Drilling WELL INFORMATION A Customer : ENI Petroleum Survey Report Well Name : OP22-WW03 Job Number : AK-XX-0900579414 Rig Name : Nabors 245E Field Name : Nikaitchuq-Oliktok Point Country : USA DIRECTIONAL SURVEY DATA Tie-in 115.23 0.13 279.44 115.23 0.01 N 0.08 W Measured Depth Inclination Direction Vertical Depth Latitude Departure Vertical Section Dogleg (ft) (deg) (deg) (ft) (ft) (ft) (ft) (°/100') 115.23 0.13 279.44 115.23 0.01 N 0.08 W 0.05 0.00 173.73 0.35 253.57 173.73 0.03 S 0.32 W 0.13 0.41 264.75 0.10 40.82 264.75 0.05 S 0.53 W 0.22 0.48 297.76 0.46 182.79 297.76 0.16 S 0.52 W 0.12 1.64 324.06 0.87 170.93 324.06 0.46 S 0.49 W -0.16 1.64 353.97 1.07 171.44 353.96 0.96 S 0.42 W -0.63 0.67 386.32 1.74 170.03 386.30 1.74 S 0.29 W -1.38 2.07 416.89 2.43 168.99 416.85 2.84 S 0.08 W -2.43 2.26 445.64 2.71 169.44 445.57 4.10 S 0.16 E -3.65 0.98 477.66 3.52 168.31 477.55 5.81 S 0.50 E -5.30 2.54 508.05 4.20 169.45 507.87 7.82 S 0.89 E -7.24 2.25 535.36 4.56 173.14 535.10 9.88 S 1.20 E -9.19 1.67 627.31 6.36 170.54 626.63 18.53 S 2.48 E -17.34 1.98 723.18 8.21 174.70 721.72 30.59 S 3.98 E -28.57 2.01 • 819.11 8.94 174.08 816.58 44.82 S 5.38 E -41.64 0.77 914.92 9.63 175.58 911.13 60.22 S 6.77 E -55.71 0.76 1010.80 8.62 178.89 1,005.80 75.40 S 7.53 E -69.29 1.19 1106.50 5.94 182.75 1,100.72 87.52 S 7.43 E -79.78 2.85 1166.04 5.20 182.42 1,159.98 93.29 S 7.17 E -84.67 1.24 1260.76 3.57 182.72 1,254.41 100.52 S 6.84 E -90.80 1.72 1356.55 1.98 197.68 1,350.09 105.08 S 6.20 E -94.44 1.81 1452.18 1.14 239.28 1,445.69 107.14 S 4.88 E -95.59 1.42 1548.02 1.32 260.66 1,541.51 107.81 S 2.97 E -95.22 0.51 1644.03 2.17 293.96 1,637.47 107.25 S 0.22 E -93.38 1.34 1740.57 3.00 309.19 1,733.91 104.91 S 3.41 W -89.55 1.11 1835.06 5.18 332.45 1,828.16 99.56 S 7.30 W -82.98 2.85 1930.23 5.30 338.67 1,922.94 91.66 S 10.88 W -74.34 0.61 2026.01 7.13 336.23 2,018.15 82.10 S 14.89 W -64.05 1.93 2121.92 9.65 337.82 2,113.03 69.21 S 20.32 W -50.15 2.64 2217.66 11.82 340.20 2,207.09 52.55 S 26.68 W -32.53 2.31 2313.36 16.17 338.20 2,299.92 30.94 S 34.95 W -9.66 4.57 2409.31 18.05 338.04 2,391.62 4.75 S 45.47 W 18.32 1.96 Job No: AK-XX-0900579414 Well Name: OP22-WW03 Survey Report INSITE V7.4.20 Page 1 HALLIBURTON Sperry Drilling DIRECTIONAL SURVEY DATA Measured Depth Inclination Direction Vertical Depth Latitude Departure Vertical Section Dogleg (ft) (deg) (deg) (ft) (ft) (ft) (ft) (°I100') 2505.15 19.99 338.53 2,482.23 24.27 N 57.02 W 49.25 2.03 2601.06 21.31 338.64 2,571.97 55.76 N 69.37 W 82.73 1.38 2697.01 22.74 336.42 2,660.92 88.99 N 83.14 W 118.44 1.72 2792.82 24.74 331.73 2,748.63 123.63 N 100.04 W 156.90 2.87 2891.70 27.01 330.87 2,837.59 161.47 N 120.78 W 200.05 2.33 2984.53 30.06 329.32 2,919.13 199.89 N 142.91 W 244.38 3.38 3080.38 33.64 328.27 3,000.54 243.13 N 169.13 W 294.93 3.78 3176.22 34.53 328.31 3,079.91 288.82 N 197.36 W 348.60 0.93 3283.65 37.15 329.45 3,166.99 342.68 N 229.85 W 411.48 2.52 3379.46 39.08 331.80 3,242.38 394.21 N 258.83 W 470.60 2.52 3475.25 39.68 331.63 3,316.42 447.73 N 287.63 W 531.36 0.64 3570.93 39.01 332.83 3,390.41 501.40 N 315.89 W 591.99 1.06 I 3666.77 39.30 333.36 3,464.73 555.36 N 343.28 W 652.44 0.46 3762.34 41.50 333.85 3,537.50 610.85 N 370.80 W 714.28 2.33 3858.21 42.44 335.02 3,608.78 668.68 N 398.46 W 778.23 1.28 3953.93 43.01 334.40 3,679.10 727.40 N 426.21 W 842.99 0.74 4051.63 42.26 335.10 3,750.98 787.25 N 454.44 W 908.97 0.91 4103.31 42.30 333.72 3,789.21 818.61 N 469.46 W 943.66 1.80 4198.58 42.61 331.46 3,859.51 875.68 N 499.06 W 1007.91 1.63 4294.29 41.67 328.93 3,930.48 931.40 N 530.96 W 1072.11 2.03 4390.20 40.77 328.17 4,002.63 985.32 N 563.93 W 1135.28 1.07 4485.82 41.15 327.60 4,074.83 1,038.41 N 597.26 W 1197.90 0.56 4580.94 41.48 328.27 4,146.28 1,091.63 N 630.59 W 1260.64 0.58 4676.55 41.91 328.84 4,217.67 1,145.88 N 663.77 W 1324.20 0.60 4772.29 42.21 328.59 4,288.75 1,200.69 N 697.08 W 1388.31 0.36 4868.09 41.31 328.70 4,360.21 1,255.18 N 730.28 W 1452.08 0.94 4963.69 41.34 328.09 4,432.01 1,308.94 N 763.36 W 1515.17 0.42 5059.41 40.50 327.33 4,504.33 1,361.94 N 796.85 W 1577.79 1.02 5155.25 39.84 327.19 4,577.57 1,413.95 N 830.28 W 1639.52 0.70 5250.86 40.42 327.20 4,650.67 1,465.74 N 863.67 W 1701.05 0.61 5346.68 41.10 328.04 4,723.25 1,518.57 N 897.17 W 1763.53 0.91 5442.38 41.66 328.62 4,795.06 1,572.42 N 930.38 W 1826.75 0.71 5538.13 41.05 329.46 4,866.93 1,626.66 N 962.93 W 1889.99 0.86 5634.10 41.34 330.50 4,939.15 1,681.39 N 994.55 W 1953.20 0.78 5729.65 40.52 332.11 5,011.34 1,736.29 N 1,024.61 W 2015.78 1.40 5825.40 41.43 331.96 5,083.63 1,791.75 N 1,054.05 W 2078.54 0.96 5921.22 42.04 332.14 5,155.13 1,848.09 N 1,083.95 W 2142.30 0.65 6017.02 40.85 332.21 5,226.94 1,904.17 N 1,113.54 W 2205.68 1.24 6112.86 40.05 332.00 5,299.87 1,959.13 N 1,142.63 W 2267.84 0.85 6208.64 40.85 332.26 5,372.76 2,014.06 N 1,171.68 W 2329.95 0.85 6304.46 41.48 332.81 5,444.89 2,070.02 N 1,200.77 W 2392.98 0.76 , 6400.36 40.28 333.34 5,517.40 2,125.98 N 1,229.19 W 2455.67 1.30 6496.19 40.81 332.56 5,590.22 2,181.46 N 1,257.52 W 2517.90 0.77 6592.11 40.24 331.17 5,663.13 2,236.42 N 1,286.91 W 2580.21 1.11 6687.78 40.05 328.99 5,736.27 2,289.87 N 1,317.67 W 2641.88 1.48 Job No: AK-XX-0900579414 Well Name: OP22-WW03 Survey Report INSITE V7.4.20 Page 2 HALLIBURTON I sperry Drarng DIRECTIONAL SURVEY DATA Measured Depth Inclination Direction Vertical Depth Latitude Departure Vertical Section Dogleg (ft) (deg) (deg) (ft) (ft) (ft) (ft) (°/100') 6783.52 39.06 329.31 5,810.08 2,342.21 N 1,348.93 W 2702.83 1.06 6879.41 36.36 329.22 5,885.94 2,392.62 N 1,378.91 W 2761.47 2.82 I 6975.16 35.48 329.01 5,963.48 2,440.83 N 1,407.74 W 2817.62 0.93 7070.30 35.95 329.14 6,040.72 2,488.47 N 1,436.28 W 2873.15 0.50 7166.29 34.13 329.45 6,119.31 2,535.86 N 1,464.42 W 2928.25 1.91 7261.27 32.48 330.55 6,198.69 2,581.01 N 1,490.51 W 2980.39 1.85 7357.27 29.57 331.90 6,280.95 2,624.36 N 1,514.34 W 3029.86 3.12 7453.10 25.63 331.10 6,365.86 2,663.38 N 1,535.50 W 3074.24 4.13 7550.70 24.69 331.37 6,454.20 2,699.75 N 1,555.47 W 3115.73 0.97 7650.64 24.75 332.50 6,544.98 2,736.63 N 1,575.14 W 3157.51 0.48 7745.35 22.01 333.68 6,631.91 2,770.13 N 1,592.16 W 3195.05 2.93 7841.57 19.50 332.58 6,721.87 2,800.55 N 1,607.55 W 3229.10 2.64 7937.15 16.48 331.29 6,812.77 2,826.61 N 1,621.42 W 3258.60 3.19 8033.13 15.02 328.18 6,905.15 2,849.12 N 1,634.51 W 3284.65 1.76 8127.12 14.34 327.75 6,996.07 2,869.31 N 1,647.15 W 3308.44 0.73 8224.56 11.98 328.09 7,090.94 2,888.10 N 1,658.93 W 3330.60 2.42 8320.01 11.08 329.57 7,184.47 2,904.42 N 1,668.82 W 3349.67 0.99 8415.96 10.58 329.26 7,278.71 2,919.94 N 1,677.99 W 3367.70 0.52 8511.58 10.23 329.44 7,372.75 2,934.80 N 1,686.79 W 3384.96 0.37 8607.05 9.63 329.67 7,466.79 2,948.99 N 1,695.13 W 3401.43 0.63 8703.08 9.70 330.50 7,561.46 2,962.97 N 1,703.17 W 3417.55 0.16 8798.54 9.84 331.00 7,655.54 2,977.10 N 1,711.09 W 3433.75 0.17 8894.63 9.25 331.23 7,750.29 2,991.05 N 1,718.79 W 3449.68 0.62 8990.58 8.80 331.08 7,845.06 3,004.23 N 1,726.05 W 3464.73 0.47 9086.51 8.29 331.73 7,939.92 3,016.75 N 1,732.87 W 3478.98 0.54 9182.40 8.07 332.76 8,034.84 3,028.82 N 1,739.23 W 3492.62 0.28 9278.32 7.57 329.84 8,129.86 3,040.27 N 1,745.48 W 3505.66 0.67 9374.34 6.63 325.91 8,225.15 3,050.33 N 1,751.77 W 3517.51 1.10 9469.63 6.00 326.74 8,319.86 3,059.05 N 1,757.58 W 3527.97 0.67 9565.64 5.63 323.87 8,415.37 3,067.05 N 1,763.11 W 3537.65 0.49 9661.67 5.48 323.16 8,510.95 3,074.52 N 1,768.64 W 3546.88 0.17 9756.65 5.09 321.52 8,605.53 3,081.45 N 1,773.98 W 3555.54 0.44 9852.49 4.72 319.46 8,701.02 3,087.78 N 1,779.19 W 3563.61 0.43 9947.74 4.77 318.60 8,795.94 3,093.73 N 1,784.35 W 3571.34 0.09 10043.25 4.76 317.87 8,891.12 3,099.64 N 1,789.64 W 3579.09 0.06 10139.40 4.81 317.97 8,986.94 3,105.60 N 1,795.01 W 3586.92 0.05 10235.10 4.68 318.24 9,082.31 3,111.49 N 1,800.30 W 3594.66 0.14 10330.84 4.68 316.90 9,177.73 3,117.25 N 1,805.57 W 3602.27 0.11 10426.24 4.64 316.80 9,272.81 3,122.91 N 1,810.87 W 3609.81 0.04 10522.57 4.51 315.14 9,368.84 3,128.43 N 1,816.21 W 3617.25 0.19 10605.05 4.37 314.60 9,451.07 3,132.94 N 1,820.73 W 3623.40 0.18 10676.00 4.37 314.60 9,521.81 3,136.73 N 1,824.58 W 3628.60 0.00 Job No: AK-XX-0900579414 Well Name: OP22-WW03 Survey Report INSITE V7.4.20 Page 3 I