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Home My WebLink About212-1071. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ESP Swap 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 21,118 (main) 21,075 (L1) Casing Collapse Conductor NA Surface 2,260psi Intermediate 3,090psi Liner (main) Slotted Liner (L1) Slotted Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng NA NA and NA 21,0769,364 5-1/2" NA 907-777-8438 keith.lopez@hilcorp.com Operations Manager November 15, 2025 19,9209,577 4-1/2" 3,886 Perforation Depth MD (ft): See Schematic 3,8775-1/2" 160 20" 13-3/8" 9-5/8" 3,674 See Schematic Slotted MD NA 11,919 5,020psi 5,750psi 2,427 3,903 3,674 11,919 Hilcorp Alaska, LLC Length Size Proposed Pools: 3,863 19,920 3,886 SCHRADER BLUFF OIL Same TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0388571, ADL0388574, ADL0388583, ADL0391283 212-107 / 219-183 NIKAITCHUQ SP10-FN05 / L1 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-629-23473-00-00 / 60-00 NIKAITCHUQ AOGCC USE ONLY Slotted Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 12.6#, L-80 Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 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 and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY 3,875 21,076 3,877 1,024 NA Keith Lopez 160 160 Burst 10,210 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Sara Hannegan (2519) DN: cn=Sara Hannegan (2519) Date: 2025.11.04 14:38:12 - 09'00' Sara Hannegan (2519) 325-679 By Grace Christianson at 3:10 pm, Nov 04, 2025 DSR-11/6/25MGR04NOV2025 10-404 A.Dewhurst 04NOV25 * BOPE test to 2500 psi. 48 hour notice. JLC 11/7/2025 11/07/25 Well: SP10-FN05 & L1 PTD: 212-107 & 219-183 API: 50-629-23473-00-00 / 60-00 Well Name:SP10-FN05 & L1 API Number:50-629-23473-00-00 / 60-00 Current Status:Producer Rig:Team Snubbing 101 Estimated Start Date:11/15/25 Estimated Duration:10 days Regulatory Contact:Darci Horner Permit to Drill Number:212-107 First Call Engineer:Keith Lopez (907) 777-8438 (O) (907) 903-5432 (M) Second Call Engineer:Ryan Rupert (907) 777-8503 (O) (907) 301-1736 (M) Current Bottom Hole Pressure: 1,400 psi @ 3,756 TVD |7.2 PPGE Max Potential Surface Pressure: 1,024 psi Gas Column Gradient (0.1 psi/ft) Max Angle: 78° Sail Angle from 3,388 MD to ESP setting depth of 10,200 MD Brief Well Summary: SP10 was drilled and completed as a single lateral Schrader Bluff Oa sand producer in September 2012. A second Oa lateral was added in February 2020. The current ESP ran for 2.4 years before suffering a shaft part on 10/23/25. Objectives: Pull ESP completion, perform wellbore cleanout as necessary, and run new ESP completion. Notes Regarding Wellbore Condition: 9-5/8 casing was tested before adding the second lateral on 02/27/20 to 1,500 psi for 30 minutes (good test). HWO Conditions Traditional well control approach will be implemented. KWF will be a barrier at all times during HWO operations. No snubbing operations are planned during this work. Team Snubbings BOP stack will be used for this operation (see attachment). Pre-Rig Procedure (Non Sundried Work) Operations: 1. Bleed off gas cap from IA before the rig move to the well. HWO Procedure (Begin Sundried Work) 1. MIRU Team Snubbing Hydraulic Workover (HWO) Unit 101, ancillary equipment, and lines. 2. Displace corrosion inhibitor from capillary line prior to pulling ESP. 3. Kill well by bullheading the tubing string and the IA with injection water. a. Tubing volume 155 bbls. b. Annulus volume 583 bbls. c. Monitor OA annulus during kill. 4. Flow check for 30 min to ensure the well is killed. Well: SP10-FN05 & L1 PTD: 212-107 & 219-183 API: 50-629-23473-00-00 / 60-00 5. Install BPV/TWC inside tubing hanger as per Vault. 6. Nipple up BOP. 7. Conduct BOP Test. a. Notify AOGCC 48 hours in advance for witness b. Test to 250psi Low /2,500psi High / 2,500psi Annular c. BOPE will be used as needed to circulate the well 8. Pull BPV/TWC from the tubing hanger per Vault procedure. 9. Call out ESP Contractor to pull ESP and pull tubing hanger. 10. RU tubing handling equipment. 11. Pump approximately 10 bbl/hour (+ pipe displacement while pulling pipe) of injection water down the annulus throughout the operations to maintain well fill. 12. POOH with 4-1/2 ESP completion with shroud and seal assembly laying down. Record number of clamps recovered. 13. PU cleanout assembly and cleanout casing and liner as deep as practical. 14. RIH with ESP completion on 3-1/2 or 4-1/2 tubing to +/- 10,200. a. Check electrical continuity every 1000. b. Note PU and SO weights on tally. 15. Land tubing hanger. Use extra caution to not damage cable. 16. Lay down landing joint. 17. Set BPV/TWC, ND BOP. 18. NU tree and test, pull BPV/TWC. 19. RDMO TS HWO 101. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Snubbing BOP diagram (TSI) 4. HWO Fluid Flow Diagrams (TSI) 5. Snubbing stack stabilization diagram (TSI) If risk of pressure under BPV - Lubricate to remove. - mgr 4-½ 12.6 ppf L80 W563 Production Tubing TK15-XT Internal CoatedSP10-FN5Dual Lateral Producerwith ESP LiftNikaitchuq Field Spy IslandAs CompletedMay 202310,343' MD, 3,748'TVD Baker SLZXPLiner Hanger/Packer11,555'-11,572' MD,3,877'-3,878' TVDCasing Exit Window4-½ X-coupling cable clamps, for ESPPower Cable, (2) 3/8" Chem Inj Line with2500 psi injection check valve at bottom10,210' MD, 3,722' TVD - Discharge Gauge Sub10,306' MD, 3,756' TVD, 79º Inc Bottom of Motor CentralizerCentrilift, Conventional ESP, 65 stages Flex80 SXD +20 stage GINPSHH SXD, 513 GSB3 seals,Motor 400 HP 562XPSurf. Casing13-3/8", 68 #3,674' MD,2,426' TVD81º Inc. Interm. Casing9-5/8", 40#11,919' MD, 3,902' TVD84º Inc.11,717' MD, 3,888' TVDBaker SLZXP LinerHanger/PackerTD 8 3/421,118' MD,3,874' TVD 91º Inc.Silver Bullet Nose Guide Shoe21,076' MD, 3,875' TVD, 90º Inc.Silver Bullet Ecc. NoseGuide Closed Shoe19,920' MD, 3,885' TVD,92º Inc.TD 8 3/421,075' MD,3,866' TVD90.4º Inc.5-½ 15.5 ppf L80Slotted LinerSealbore Receptacle4.75" IDNo stabbed in dummy sealassembly on the bottom ofMLZXP11,626' MD, 3,882' TVDBaker MLZXP LinerHanger/Packer Resman Oil/WaterTracersHAL 5-½ Oil SwellPacker10,461' MDOil Swell PackerMain bore swell packers:Main bore tracers: 3-½ or 4-½ 12.6 ppf L80 W563 ProductionTubing TK15-XT Internal CoatedSP10-FN5Dual Lateral Producerwith ESP LiftNikaitchuq Field Spy IslandProposedNovember 202510,343' MD, 3,748'TVD Baker SLZXPLiner Hanger/Packer11,555'-11,572' MD,3,877'-3,878' TVDCasing Exit Window3-½ or 4-½ X-coupling cable clamps, forESP Power Cable, (2) 3/8" Chem Inj Linewith 2500 psi injection check valve atbottom~10,210' MD, 3,722' TVD - Discharge Gauge Sub~10,306' MD, 3,756' TVD, 79º Inc Bottom of Motor CentralizerCentrilift, Conventional ESP, 65 stages Flex80 SXD +20 stage GINPSHH SXD, 513 GSB3 seals,Motor 400 HP 562XPSurf. Casing13-3/8", 68 #3,674' MD,2,426' TVD81º Inc. Interm. Casing9-5/8", 40#11,919' MD, 3,902' TVD84º Inc.11,717' MD, 3,888' TVDBaker SLZXP LinerHanger/PackerTD 8 3/421,118' MD,3,874' TVD 91º Inc.Silver Bullet Nose Guide Shoe21,076' MD, 3,875' TVD, 90º Inc.Silver Bullet Ecc. NoseGuide Closed Shoe19,920' MD, 3,885' TVD,92º Inc.TD 8 3/421,075' MD,3,866' TVD90.4º Inc.5-½ 15.5 ppf L80Slotted LinerSealbore Receptacle4.75" IDNo stabbed in dummy sealassembly on the bottom ofMLZXP11,626' MD, 3,882' TVDBaker MLZXP LinerHanger/Packer Resman Oil/WaterTracersHAL 5-½ Oil SwellPacker10,461' MDOil Swell PackerMain bore swell packers:Main bore tracers: TEAM SNUBBINGINTERNATIONALSP-12BOP Stack Drawing54.13"33.8"33.8"24.0"13 5/8"00 PSI Annular5000 PSI Single Gae VBR:2 7/8" - 5 1/2"5000 PSI Single GaeBlinds5000 PSI Flow Cross5000 PSI Riser5013 5/8" 13 5/8" 13 5/8" 13 5/8" 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: _ESP Changeout___ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 21118 feet N/A feet true vertical 3876 feet N/A feet Effective Depth measured 21076 feet N/A feet true vertical 3875 feet N/A feet Perforation depth Measured depth 11,919-21,118 feet True Vertical depth 3,902-3,874 feet Tubing (size, grade, measured and true vertical depth)4.5"L-80 10210 3722 Packers and SSSV (type, measured and true vertical depth)N/A N/A N/A N/A 12. Stimulation or cement squeeze summary:N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:Schrader Bluff 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Giorgio Iannucci Digital Signature with Date:6//2023 Contact Name:Amjad Chaudhry Contact Email:amjad.chaudhry@eni.com Authorized Title:Well Operations Project Manager Contact Phone:907-865-3379 measured TVD Production Liner 11919 9364 Casing Structural 3507 5.5" 11919 21076 3875 Plugs Junk measured 3674 2453 20" 13.375" Size 160 9.625" Slotted 5210 6890 Burst Collapse 2480 4790 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL 0391283, 0388583, 0388574, 0388571 Nikaitchuq Schrader Bluff Oil Pool Eni US Operating Co. Inc. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 212-107 50-629-23473-00-00 3700 Centerpoint Drive, Ste. 500, Anchorage, AK 99503 3. Address: SP36-W5 MD 146 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 829 1583722 Length 160 3674 160Conductor Surface Intermediate 323-274 Sr Pet Eng: Slotted Sr Pet Geo:Sr Res Eng: WINJ WAG 52 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Gas-Mcf 2052 035 225 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 198 p k ft t Fra O s 6.A G L PG , _ Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Iannucci By Grace Christianson at 9:19 am, Jun 14, 2023 RBDMS JSB 120623 DSR-6/15/23 SP10-FN5 4-½” 12.6 ppf L80 W563 Production Tubing – TK15-XT Internal CoatedSP10-FN5Dual Lateral Producer with ESP LiftNikaitchuq Field –Spy IslandAs CompletedMay 202310,343' MD, 3,748’' TVD Baker SLZXP Liner Hanger/Packer11,555'-11,572' MD, 3,877'-3,878' TVDCasing Exit Window4-½” X-coupling cable clamps, for ESP Power Cable, (2) 3/8" Chem Inj Line with 2500 psi injection check valve at bottom10,210' MD, 3,722' TVD - Discharge Gauge Sub10,306' MD, 3,756' TVD, 79º Inc – Bottom of Motor Centralizer Centrilift, Conventional ESP, 65 stages Flex80 SXD + 20 stage GINPSHH SXD, 513 GSB3 seals, Motor 400 HP 562XPSurf. Casing13-3/8", 68 # 3,674' MD,2,426' TVD81º Inc. Interm. Casing 9-5/8", 40#11,919' MD, 3,902' TVD 84º Inc.11,717' MD, 3,888' TVDBaker SLZXP LinerHanger/PackerTD 8 3/4” 21,118' MD,3,874' TVD 91º Inc.Silver Bullet Nose Guide Shoe21,076' MD, 3,875' TVD, 90º Inc.Silver Bullet Ecc. Nose Guide Closed Shoe19,920' MD, 3,885' TVD, 92º Inc.TD 8 3/4” 21,075' MD,3,866' TVD90.4º Inc.5-½” 15.5 ppf L80 Slotted Liner Sealbore Receptacle4.75" IDNo stabbed in – dummy seal assembly on the bottom of MLZXP11,626' MD, 3,882' TVDBaker MLZXP LinerHanger/PackerItem MD(ft)5Ͳ1/2"SwellPkr#1 202925Ͳ1/2"SwellPkr #2 188775Ͳ1/2"SwellPkr#3 170005Ͳ1/2"SwellPkr#4 159415Ͳ1/2"SwellPkr#5 142285Ͳ1/2"SwellPkr#6 13082Item MD(ft)ResmantracerSub#1ͲROS504/RWS573 13139ResmantracerSub#2ͲROS505/RWS57414304ResmantracerSub#3ͲROS506/RWS575 15996ResmantracerSub#4ͲROS507/RWS576 17056ResmantracerSub#5ͲROS508/RWS577 18934 Resman Oil/Water TracersHAL 5-½” Oil Swell Packer10,461' MDOil Swell PackerMain bore swell packers: Well Name: SP10-FN5 OR Wellbore Name: SP10-FN5 Well Code: 26749 Job: WORKOVER WCEI: N/A Daily Report Date: 5/27/2023 Report #: 1 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.92 Ground Level (ft) First Flange (ft) 21.59 RKB - Base Flange (ft) 32.33 RKB - Tubing Spool (ft) 31.75 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 27.1 Wind N @ 23 MPH Days LTI (days) 1,239.00 Days RI (days) POB 68.0 Daily Summary Operations 24h Forecast Clean and inspect multibowl and tubing hanger. Make up blanking plug on top of tubing hanger. Nipple up BOPE. Test BOPE with 4.5” and 5” joints at 250/3500 psi. 24h Summary Spot and shim pits. Rig up interconnects. Lower stompers and skid floor to drill position. Set berm and spot accumulator. Spot pump #3. Burm around rig. Take on brine. Bullhead 210 bbls down tubing and 760 bbls down annulus A to kill well. Monitor well to ensure dead. Blow down and rig down bull heading lines. Set back pressure valve. Nipple down Tree. Operation at 07.00 Nippling up BOPE. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 W.O. A 2 P Move pit system down well bay, spot and shim. Spot accumulator, lower stompers and skid floor to drill position. Set berm and spot accumulator. Spread Herculite and lay mats to move pump #3 into position. Make up interconnects under rig floor and in boiler room. Rig down pipe shed support beams, run high line cable to rig, pick up mats from bridge, and take on water. 06:00 12:00 6.00 12.00 W.O. A 2 P Lug up pit module and top drive. Make up mud and secondary kill interconnects. Remove top drive torque tube chains and binders used to dock top drive, and function test same, all good. Change power from rig power to high line power. Berm around rig, and pits. Continue to make up interconnects, make up utility lines to rig floor, and pits. Lug up accumulator, and run hoses. Connect suitcase mud line, air and fuel to valve house, and suitcase alarms. Make up flow line from pits to sub, spot mud pump #3 and lug up same. Make up mud lines to mud pump #3, install hand rails, and pressure test suitcase transfer lines. 12:00 16:30 4.50 16.50 W.O. A 1 P Rig up pump #3. Set slop tank under auger. Rig up to bullhead down well to kill. Bring on brine from mud plant. Prime mud pumps. Clean and organize rig after rig move. 16:30 20:30 4.00 20.50 W.O. M 9 P PJSM. Flood lines and pressure test lines to 3500 psi. Bull head 210 bbls down tubing at 4.5 BPM, initial circulating pressure=20 psi, final tubing pressure=896 psi. Bullhead 760 bbls down A annulus at 7 BPM, initial circulating pressure=145 psi, final circulating pressure=306 psi. Tubing and A annulus pressures dropped to vacuum after shutting down pumps. Loading 4.5” tubing in pipe shed. 20:30 21:30 1.00 21.50 W.O. M 20 P Monitor well for 1 hour. A Annulus pressure = -13 psi, Tubing pressure = -13 psi, dropping to -14 psi after 1 hour. Loading 4.5” tubing in pipe shed. 21:30 00:00 2.50 24.00 W.O. C 20 P Blow down and rig down bull heading lines. Set back pressure valve. Nipple down tree. Loading 4.5” tubing in pipe shed. Note: 24 Hour loses of 8.6 PPG 3% KCL/NaCl brine inhibited with biocide = 1000 bbls. Total loses of 8.6 PPG 3% KCL/NaCl brine inhibited with biocide = 1000 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Tool Push Ryan Pankratz Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Andrew Yochum Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Safety Representative Pat Ahern ASRC Energy Services HSE Patrick.Ahern@external.eni.com 907-685-0721 Safety Representative Derek Ambrose Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Safety Representative John Lettow Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 2,216.1 21,076.0 3,830.4 9/27/2012 Well Name: SP10-FN5 OR Wellbore Name: SP10-FN5 Well Code: 26749 Job: WORKOVER WCEI: N/A Daily Report Date: 5/28/2023 Report #: 2 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.92 Ground Level (ft) First Flange (ft) 21.59 RKB - Base Flange (ft) 32.33 RKB - Tubing Spool (ft) 31.75 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 30.7 Wind E @ 16 MPH Days LTI (days) 1,240.00 Days RI (days) POB 68.0 Daily Summary Operations 24h Forecast Pull ESP completion out of hole from 10,260’ to surface. Laying down 4.5” HYD 563, internal coated, 12.6# tubing ESP completion. 24h Summary Clean and inspect multibowl and tubing hanger. Make up blanking plug on top of tubing hanger. Nipple up BOPE. Test BOPE with 4.5” and 5” joints and test at 250/3500 psi. Witnessed waived by AOGCC rep Austin McLeod. Rig up to pull ESP completion. Pull tubing hanger. Prep and lay down hanger and landing joint, lay down from 10,300’ to 10,260’ MD. Operation at 07.00 Pulling ESP completion out of hole. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:00 2.00 2.00 W.O. C 5 P Clean and inspect tubing hanger, and prep capillary line for de-completion. Install blanking plug on top of tubing hanger. Stab high pressure riser and toque up VG clamp. 02:00 06:00 4.00 6.00 W.O. C 5 P Stab stack on riser and nipple up. Make up primary and secondary choke and kill lines. Make up choke and kill HCR and manual valves and lines. Start making up flow line and riser. Add 10 BPH of 8.6 PPG 3% KCL, NaCl brine inhibited with biocide, to A annulus. 06:00 11:00 5.00 11.00 W.O. C 5 P Connect supplied airline to flow line air boot, center BOP with rotary table, install drip pan covers, measure and record KB distances, and install kelly bushings. Add 10 BPH of 8.6 PPG 3% KCL, NaCl brine inhibited with biocide, to A annulus. 11:00 12:00 1.00 12.00 W.O. C 25 P Service hydraulic IBOP, choke manifold, along with choke and kill valves. Make up test joint, flood BOPE, and perform shell test to 3500 PSI. Test good. Add 10 BPH of 8.6 PPG 3% KCL, NaCl brine inhibited with biocide, to A annulus. 12:00 16:00 4.00 16.00 W.O. C 12 P Perform BOP test 250 PSI low and 3500 PSI high for 5 minutes each. Test on 4.5” and 5” test joints. Perform accumulator draw down test accumulator pressure 3,000 PSI, after function 2000 PSI, 200 PSI recovery time 9 seconds, full recovery time 54 seconds. 10 BTL N2 average 3800 PSI. BOPE test witnessed waived by AOGCC rep Austin McLeod. Add 10 BPH of 8.6 PPG 3% KCL, NaCl brine inhibited with biocide, to A annulus. 16:00 17:30 1.50 17.50 W.O. C 1 P Lay down test joints. Rig down test equipment. Blow down lines. 17:30 21:00 3.50 21.00 W.O. L 1 P Rig up to pull ESP completion. rig up GBR power tongs. Adjust spool house for de-completion. Rig up handling equipment. 21:00 00:00 3.00 24.00 W.O. L 4 P Make up landing joint and back out lock down screws. Unseat tubing hanger and pull to rig floor, pick up 125 k and hold for 1 minute, Slack off. Pick up to 150 k and hold for 2 minutes, slack off. Pick up again to 150 k and pulled loose. UW=135 k. Test then disconnect penetrator. Dis-connect cap tube from hanger. Break connection at center of swivel joint and lay down hanger. Pulling out of hole from 10,300’ to 10,260’ MD. 24 Hour loses of 8.6 PPG 3%KCL/NaCl brine inhibited with biocide = 200 bbls. Total loses of 8.6 PPG 3%KCL/NaCl brine inhibited with biocide = 1200 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Tool Push Ryan Pankratz Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Andrew Yochum Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Safety Representative Pat Ahern ASRC Energy Services HSE Patrick.Ahern@external.eni.com 907-685-0721 Safety Representative Derek Ambrose Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Safety Representative John Lettow Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 2,216.1 21,076.0 3,830.4 9/27/2012 Well Name: SP10-FN5 OR Wellbore Name: SP10-FN5 Well Code: 26749 Job: WORKOVER WCEI: N/A Daily Report Date: 5/29/2023 Report #: 3 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.92 Ground Level (ft) First Flange (ft) 21.59 RKB - Base Flange (ft) 32.33 RKB - Tubing Spool (ft) 31.75 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) 29.1 Wind E @ 9 MPH Days LTI (days) 1,241.00 Days RI (days) POB 67.0 Daily Summary Operations 24h Forecast Run cable and cap tube over sheaves in derrick and down to floor. Make up ESP assembly and run in hole. Test ESP cable. Perform cap tube pump through and stabilization for check valves. Run in hole with 4.5” 12.6# HYD 563 tubing making cable checks every 1000’ and continuously testing cap tube. 24h Summary Pull out of hole laying down 4.5” tubing with ESP completion from 10,260’ to ESP pump. Lay down ESP assembly and inspect same. Clean rig floor. Spot ESP components and clamps. Rig up to run completion. Change out spools in spool house for ESP cable and dual cap tube spool. Operation at 07.00 Making up ESP assembly. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 W.O. L 4 P PJSM. Pull out of hole laying down 4.5” tubing with ESP completion from 10,260’ to 7170’ MD, UW 117K. Break circulation every 3000’. Adding 10 bbls per hour plus pipe displacement down A annulus with 8.6 PPG 3% KCL/NaCl brine inhibited with biocide. 06:00 11:30 5.50 11.50 W.O. L 4 P Pull out of hole laying down 4.5” tubing with ESP completion from 7170’ to 3274’ MD, UW 94K. Break circulation every 3000’. Adding 10 bbls per hour plus pipe displacement down A annulus with 8.6 PPG 3% KCL/NaCl brine inhibited with biocide. 11:30 13:00 1.50 13.00 W.O. L 9 P PJSM. Remove full ESP cable spool and install empty spool to complete ESP decompletion. Make up high pressure circulating hose and pump a tubing volume 50 BBL of 8.6 PPG NaCl brine inhibited with biocide, at 4.3 GPM, 1000 PSI. 13:00 16:30 3.50 16.50 W.O. L 4 P Pull out of hole laying down 4.5” tubing with ESP completion from 3274’ to ESP assembly at 132’ MD. Break circulation every 3000’. Adding 10 bbls per hour plus pipe displacement down A annulus with 8.6 PPG 3% KCL/NaCl brine inhibited with biocide. 16:30 19:00 2.50 19.00 W.O. L 4 P Lay down ESP assembly from 132' to surface. No scale or sand observed on BHA. Upper pump top rotation difficult. Bottom spin free, possible broken shaft. ESP cable on motor one leg melted through armored cable approximately 4’. Total clamps recovered=263, 1-half clamp, 1-MLE clamp, 1-splice clamp, 4 equipment clamps, 6 pump clamps and 250 cross collar clamps. 19:00 00:00 5.00 24.00 W.O. M 20 P Clean and clear floor. Lay down used equipment, clamps and pins. Lower ESP cable and hydraulic control lines down sheave and spool up on spools in spool house. Prepare spools for removal. Remove elephant trunk from sheave in derrick. Lay down tubing hanger, swivel joint and pups. Box up used ESP components in pipe shed for shipping. Remove from pipe shed. Load new pump assembly boxes in pipe shed. Swap out ESP and dual cap tube spools in spooler. Notes: 24 Hour loses of 8.6 PPG 3%KCL/NaCl brine inhibited with biocide = 341 bbls. Total loses of 8.6 PPG 3%KCL/NaCl brine inhibited with biocide = 1541 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Mike Grubb ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Tool Push Ryan Pankratz Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Andrew Yochum Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Safety Representative Pat Ahern ASRC Energy Services HSE Patrick.Ahern@external.eni.com 907-685-0721 Safety Representative Derek Ambrose Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Safety Representative John Lettow Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 2,216.1 21,076.0 3,830.4 9/27/2012 Well Name: SP10-FN5 OR Wellbore Name: SP10-FN5 Well Code: 26749 Job: WORKOVER WCEI: N/A Daily Report Date: 5/30/2023 Report #: 4 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.92 Ground Level (ft) First Flange (ft) 21.59 RKB - Base Flange (ft) 32.33 RKB - Tubing Spool (ft) 31.75 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 33.8 Wind E @ 6 MPH Days LTI (days) 1,242.00 Days RI (days) POB 66.0 Daily Summary Operations 24h Forecast Continue trouble shooting another option on pipe handler assembly function. Continue running in hole as per tally with 4.5” 12.6# HYD 563 tubing making cable checks every 1000’ and continuously monitoring of cap lines. 24h Summary Pick-up Baker ESP pump assembly and perform cap tube pump through and stabilization for check valves. Perform MLE splice and test ESP cable. Run in hole with 4.5” 12.6# HYD 563 tubing making cable checks every 1000’ and continuously monitoring of cap lines to 1,859’. Lower rotating link assembly adaptor seal failure on top drive, work on isolating lower seal assembly and continue use pipe handler function, with no success. Doyon mechanic trouble shooting another option on pipe handler assembly function. Operation at 07.00 Run in hole with ESP assembly. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:00 2.00 2.00 W.O. M 1 P PJSM - Logistics remove old spools from spooler. Baker prepare new spools and run ESP cable and flat pack capillary tube over sheaves in derrick and back to rig floor. Un-load new ESP components into pipe shed and stage on short side in order to pick up. Mobilize rig air to spooling unit for cap tube testing. Add 10 BPH 3% KCL/NaCl brine inhibited with biocide down A annulus. 02:00 09:00 7.00 9.00 W.O. K 5 P Pick up ESP assembly, service motor and seals, ensure free rotation of all equipment. Make up capillary “A” to check valve, pressure line to 1000 PSI and held for 10 minutes, continue to pressure up and saw valve open at 4100 PSI, continue to pump through valve for 5 minutes, shut down and seen valve close at 3540 PSI. Make up capillary “B” to check valve, pressure line to 1000 PSI and held for 10 minutes, continue to pressure up and saw valve open at 4300 PSI, continue to pump through valve for 5 minutes, shut down and seen valve close at 3900 PSI. Add 10 BPH 3%KCL/NaCl brine inhibited with biocide down annulus. 09:00 15:00 6.00 15.00 W.O. K 5 P PJSM - Rig up sheave for motor lead, and build hooch on rig floor for MLE splice due to rain. Install MLE to motor, perform continuity test, and install MLE clamps. Perform MLE splice to ESP cable, with splice being witnessed by ENI electrician Rob Fontain. Demobe pump boxes from pipe shed and continue with MP2’s, housekeeping, and removed scissor lift ramp. Add 10 BPH 3% KCL/NaCl brine inhibited with biocide down annulus. 15:00 16:30 1.50 16.50 W.O. K 12 P PJSM - Rig up GBR torque turn equipment and perform dum test. 16:30 19:30 3.00 19.50 W.O. K 4 P PJSM - Run in hole with ESP assembly, pickup 4-1/2” tubing (12.6#/L-80/ Hydril 563 / TK-15XT coating) GBR torque turn each connection, inspected and witness by Superior thread rep from 93’ to 1,859’ DW 90K. Baker perform continuity and gauge readings check every 1,000’ and maintain 1000 psi on capillary lines (with data logger). Add 10 BPH 3% KCL/NaCl brine inhibited with biocide down annulus. Note: MLE splice land out at 10,204’ from RKB. 19:30 00:00 4.50 24.00 W.O. M 25 TR04 PJSM - Top drive lower rotating link assembly adaptor seal failure. Continue trouble shooting to bypass rotating link assembly adaptor lower seal and make pipe handler function operation. Add 10 BPH 3% KCL/NaCl brine inhibited with biocide down annulus. Note: 24 Hour loses of 8.6 PPG 3%KCL/NaCl brine inhibited with biocide = 240 bbls. Total loses of 8.6 PPG 3%KCL/NaCl brine inhibited with biocide = 1781 bbls. 24 Hour metal recovered = 0 lbs. Total metal recovered = 0 lbs. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative David Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Tool Push Ryan Pankratz Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Ted Kruger Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Safety Representative Pat Ahern ASRC Energy Services HSE Patrick.Ahern@external.eni.com 907-685-0721 Safety Representative Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 907-685-0796 Safety Representative John Lettow Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 2,216.1 21,076.0 3,830.4 9/27/2012 Well Name: SP10-FN5 OR Wellbore Name: SP10-FN5 Well Code: 26749 Job: WORKOVER WCEI: N/A Daily Report Date: 5/31/2023 Report #: 5 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.92 Ground Level (ft) First Flange (ft) 21.59 RKB - Base Flange (ft) 32.33 RKB - Tubing Spool (ft) 31.75 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 35.8 Wind SW @ 5 MPH Days LTI (days) 1,243.00 Days RI (days) POB 63.0 Daily Summary Operations 24h Forecast Continue running ESP completion as per tally. Pick-up tubing hanger and landing joint, terminate penetrator and two capillary lines in hanger, test. Land hanger and test with umbilical cord. Nipple down BOP and Nipple-up tree. 24h Summary Continue trouble shooting RLA function tested (good test). Continue running in hole as per tally with 4-1/2” 12.6#. HYD 563 tubing, from 1,859’ to 3,997’. Safety Stand Down due to skate incident. Continue running in hole as per tally with 4-1/2” 12.6# HYD 563 tubing from 3,997’ to 7,327’. Perform ESP cable splice. Continue running in hole as per tally with 4-1/2” 12.6# HYD 563 tubing from 7,327’ to 9,263’. Operation at 07.00 Making penetrator splice. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:30 1.50 1.50 W.O. K 25 TR04 PJSM – Continue trouble shooting rotating link assembly adaptor by plugging holes on hydraulic diverter block. Perform function test. Good test. Reinstall guards and perform drops inspection. Add 10 BPH 3% KCL/NaCl brine inhibited with biocide down annulus. 01:30 06:00 4.50 6.00 W.O. K 4 P PJSM – Baker, GBR and Doyon crews, continue running in hole as per tally with ESP assembly, pickup 4-1/2” tubing (12.6#/L- 80/ Hydril 563 / TK-15XT coating) GBR torque turn each connection, inspected and witness by Superior thread rep from 1,859’ to 3,997’ DW = 87K. Baker perform continuity and gauge readings check every 1,000’ and maintain 1000 psi, on capillary lines (with data logger). Add 10 BPH 3% KCL/NaCl brine inhibited with biocide down annulus, and break circulation every 3000’. 06:00 08:00 2.00 8.00 W.O. K 1 U Incurred LQFLGHQW involving skate operations, shut down, took witness reports, took pictures to document LQFLGHQW, and completed initial reporting)LUVW$LGRQO\. Add 10 BPH 3% KCL/NaCl brine inhibited with biocide down annulus. 08:00 10:00 2.00 10.00 W.O. K 1 U Safety stand down regarding skate incident. Discussed incident and possible ramifications. Discussed related mitigations, and how they can be implemented. Add 10 BPH 3% KCL/NaCl brine inhibited with biocide down annulus. 10:00 12:00 2.00 12.00 W.O. K 4 P PJSM – Baker, GBR and Doyon crews, continue running in hole as per tally with ESP assembly, pickup 4-1/2” tubing (12.6#/L- 80/ Hydril 563 / TK-15XT coating) GBR torque turn each connection, inspected and witness by Superior thread rep from 3,997’ to 4,745’ DW = 86K. Baker perform continuity and gauge readings check every 1,000’ and maintain 1000 psi, on capillary lines (with data logger). Add 10 BPH 3% KCL/NaCl brine inhibited with biocide down annulus, and break circulation every 3000’. Implemented and followed new skate procedure. 12:00 17:00 5.00 17.00 W.O. K 4 P PJSM - Run in hole with ESP assembly, pickup 4-1/2” tubing (12.6#/L-80/ Hydril 563 / TK-15XT coating) GBR torque turn each connection, inspected and witness by Superior thread rep from 4,745’ to 7,327’ DW = 89K. Baker perform continuity and gauge readings check every 1,000’ and maintain 1000 psi on capillary lines (with data logger). Add 10 BPH 3% KCL/NaCl brine inhibited with biocide down annulus. Implemented and followed new skate procedure. 17:00 21:00 4.00 21.00 W.O. K 20 P PJSM – Change out ESP cable spools in unit and perform ESP cable splice per Baker Centrilift, being witnessed by ENI electrician Rob Fontain. Perform continuity and gauge readings after splice (good test) and capillary lines pressure had 1062 psi on data logger. Pump 28 bbls at 5 bpm, caught pressure with 500 psi, reduce rate to 2 bpm. 21:00 00:00 3.00 24.00 W.O. K 4 P DW = 89K. Baker perform continuity and gauge readings check every 1,000’ and maintain 1000 psi on capillary lines (with data logger). Add 10 BPH 3% KCL/NaCl brine inhibited with biocide down annulus, and break circulation every 3000’. ESP cable splice landed 27’ up on joint #184. Note: 24 Hour loses of 8.6 PPG 3%KCL/NaCl brine inhibited with biocide = 298 bbls. Total loses of 8.6 PPG 3%KCL/NaCl brine inhibited with biocide = 2079 bbls. 24 Hour metal recovered = 0 lbs. Total metal recovered = 0 lbs. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative David Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Tool Push Ryan Pankratz Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Ted Kruger Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Safety Representative Pat Ahern ASRC Energy Services HSE Patrick.Ahern@external.eni.com 907-685-0721 Safety Representative Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 907-685-0796 Safety Representative John Lettow Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 2,216.1 21,076.0 3,830.4 9/27/2012 Well Name: SP10-FN5 OR Wellbore Name: SP10-FN5 Well Code: 26749 Job: WORKOVER WCEI: N/A Daily Report Date: 6/1/2023 Report #: 6 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.92 Ground Level (ft) First Flange (ft) 21.59 RKB - Base Flange (ft) 32.33 RKB - Tubing Spool (ft) 31.75 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Clear Temperature (°F) 32.0 Wind W @ 13 MPH Days LTI (days) 1,244.00 Days RI (days) POB 58.0 Daily Summary Operations 24h Forecast Continue nipple down BOP and nipple up tree. Perform passport test. 24h Summary RIH and land ESP completion at 10,306’. Demobe equipment from rig floor and derrick. Clean floor and drip pan. Remove bell nipple, flow line and rams from BOP stack. Nipple down BOP. Operation at 07.00 Perform passport test. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:30 2.50 2.50 W.O. K 12 U PJSM – Trouble shooting capillary line leak, pressure up line and inspect flat pack from sheave in derrick to rig floor. No leaks observed. Add 10 BPH 3% KCL/NaCl brine inhibited with biocide down annulus. 02:30 05:00 2.50 5.00 W.O. K 4 P PJSM with Baker, GBR and Doyon crews, continue running in hole as per tally with ESP assembly, pickup 4-1/2” tubing (12.6#/L-80/ Hydril 563 / TK-15XT coating) GBR torque turn each connection, inspected and witness by Superior thread rep from 9,263’ to 10,255’ DW = 84K. Baker perform continuity and gauge readings check every 1,000’ and maintain 1000 psi, on capillary line (with data logger). Add 10 BPH 3% KCL/NaCl brine inhibited with biocide down annulus. 05:00 06:00 1.00 6.00 W.O. K 5 P Install tubing hanger with swivel joint, orientate tubing hanger to Vault rep and make up swivel joint per vendor recommendation, GBR made-up to 4796 ft./lbs., swivel gap 0.300 mm after make-up. Install TWC and landing joint on tubing hanger. Note UW 143K / DW 84K. Add 10 BPH 3% KCL/NaCl brine inhibited with biocide down annulus. 06:00 08:30 2.50 8.50 W.O. K 20 P Cut ESP cable and prep for penetrator adapter to be spliced on. Rig down GBR equipment, blow down choke and kill lines, and complete ESP cable to penetrator connector splice. Install penetrator in tubing hanger, and attach ESP cable, terminate capillary lines through tubing hanger and test voids to 5000 PSI, good test. Perform electrical continuity test, all good. Pump down capillary line, with check valve opening at 4300 PSI, continue to pump for 5 minutes to ensure ability to pump through, shut down and monitored pressure seen valve close at 2100 psi. Add 10 BPH 3% KCL/NaCl brine inhibited with biocide down annulus. 08:30 10:00 1.50 10.00 W.O. K 5 P Land tubing hanger with bottom of 7-5/8” MGU centralizer at 10,306’, UW = 143K, DW = 84K. Run in lock down screws and test tubing hanger body seals to 5000 psi for 10 minutes, all good. Perform electrical checks via umbilical cord. All good test. Remove landing joint. Run ESP cable and capillary lines over sheaves and back to spooler. 10:00 12:00 2.00 12.00 W.O. K 20 P PJSM – Demobe Baker Centrilift ESP completion running equipment and GBR equipment from rig floor. Remove ESP and capillary sheaves from derrick. 12:00 18:30 6.50 18.50 W.O. K 1 P PJSM – Power wash and scrub rig floor/drip pan. Remove brine from active system and clean pits. 18:30 00:00 5.50 24.00 W.O. C 5 P PJSM – Remove bell nipple and flow line. Remove rams from BOP stack and cellar area. Continue nipple down accumulator lines, choke/kill lines and valves from stack. Note: 24 Hour loses of 8.6 PPG 3%KCL/NaCl brine inhibited with biocide = 80 bbls. Total loses of 8.6 PPG 3%KCL/NaCl brine inhibited with biocide = 2159 bbls. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative David Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Tool Push Ryan Pankratz Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Ted Kruger Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Safety Representative Pat Ahern ASRC Energy Services HSE Patrick.Ahern@external.eni.com 907-685-0721 Safety Representative Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 907-685-0796 Safety Representative John Lettow Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 2,216.1 21,076.0 3,830.4 9/27/2012 Well Name: SP10-FN5 OR Wellbore Name: SP10-FN5 Well Code: 26749 Job: WORKOVER WCEI: N/A Daily Report Date: 6/2/2023 Report #: 7 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) 53.92 Ground Level (ft) First Flange (ft) 21.59 RKB - Base Flange (ft) 32.33 RKB - Tubing Spool (ft) 31.75 Rig Information Rig Name RIG 15 Contractor DOYON Rig Type LAND RIG Rig Num 0723 Daily Information Weather Overcast Temperature (°F) 28.4 Wind SW @ 20 MPH Days LTI (days) 1,245.00 Days RI (days) POB 56.0 Daily Summary Operations 24h Forecast Continue with rig down of components for stack out. 24h Summary Continue Nipple down BOP, and Nipple up tree. Perform passport test. Baker perform final electrical checks, good test. Completed hand-over for SP10-FN5 well to production. Clean and flush active pits. Clean/scrub derrick and disassembling HCR and manual choke/kill valves, prep BOP stack components for removal from cellar area. Disassemble #3 mud fluid end. Final report on SP10-FN5. Operation at 07.00 Power washing derrick. Final report on SP10-FN5. Reporting moved to Doyon 15 Cold Stack. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:30 2.50 2.50 W.O. C 5 P PJSM – Continue nipple down BOP, rig-up on stack and rack back on stump, install lifting equipment on high riser, with Vault rep disconnected gray lock clamp, pulled riser and secured in BOP deck. SIMOPS clean active pit system. 02:30 06:30 4.00 6.50 W.O. C 5 P Clean and prep wellhead, terminate “A” and “B” capillary lines through wellhead housing. Install tree and test void to 5000 PSI for 15 minutes, all good. Rig up testing equipment for passport test, and purge tree. 06:30 12:00 5.50 12.00 W.O. C 12 P Perform passport as per procedure. SIMOPS: Flushing citric pill through mud pumps, and high pressure lines to rig floor bleeder, followed with fresh water. Pit-watcher flushed all lines and centrifugal pumps. Rig-down accumulator lines and move trailer to containment area. Rig down passport testing equipment from well and secured. 12:00 13:30 1.50 13.50 W.O. C 5 P Baker perform final electrical checks all good. Submitted passport documentation turning well over from Drilling to Production. SIMOPS: Disassembling HCR and manual choke/kill valves in cellar. 13:30 18:00 4.50 18.00 W.O. A 5 P PJSM – Scrub and power wash derrick top to bottom. Continue disassembling HCR and manual choke/kill valves in cellar. Flush and rinse out active pits and lines with fresh water. Disconnect electrical leads from traction motor #2 of #1 mud pump, install table for removal. 18:00 00:00 6.00 24.00 W.O. A 1 P Continue scrubbing and power wash derrick. Remove HCR and manual choke/kill valves from cellar to parts house. Flush and rinse out active pits and lines with fresh water, remove fluid from pits. Start disassembling #3 mud pump fluid end and preserving the components. Final report on SP10-FN5. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Steve Lawrence ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative David Smith ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-685-0715 Eni representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Tool Push Ryan Pankratz Doyon Drilling Tool Pusher rig15@doyondrilling.com 907-685-0716 Tool Push Ted Kruger Doyon Drilling Tour Pusher rig15@doyondrilling.com 907-685-0716 Safety Representative Pat Ahern ASRC Energy Services HSE Patrick.Ahern@external.eni.com 907-685-0721 Safety Representative Harold Richardson Doyon Drilling HSE hrichardson@doyondrilling.com 907-685-0796 Safety Representative John Lettow Doyon Drilling HSE rig15@doyondrilling.com 907-685-0796 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 1/2 L80 2,216.1 21,076.0 3,830.4 9/27/2012 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ESP Changeout___ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 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 9. Property Designation (Lease Number): 10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 21,118 N/A Casing Collapse Structural Conductor Surface 2,270 Intermediate 4760 Production Liner slotted Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A N/A 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Giorgio Iannucci 5/8/2023 Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng N/A 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 and Digital Signature with Date: AOGCC USE ONLY Amjad Chaudhry amjad.chaudhry@eni.com 907-865-3379 Well Operations Project Manager slotted Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: L80 10,206 5/11/2023 Nikaitchuq Schrader Bluff Oil Pool 3,874 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 0391283, 0388583, 0388574, 0388571 212-107 3700 Centerpoint Drive, Ste. 500, Anchorage, AK 99503 50-629-23473-00-00 Eni US Operating Co. Inc. SP10-FN5 21,076 3,875 10 Length Size TVDMD 6870 5,020 160 2426 3902 160 3674 Burst 11919 20" 13.375" 160 3674 Perforation Depth MD (ft): 9.625"11919 11,919-21,118 5.5" 3,902-3,874 210769364 4.5" 3875 m n P s 2 6 5 6 t uttt____ Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov nnucci 323-274 By Kayla Junke at 11:07 am, May 09, 2023 BOPtestto3500psi. May 09, 2023 DSR-5/9/23 10-404 BJM 5/10/23 X SFD 5/10/2023GCW 5/10/23JLC 5/10/2023 5/10/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.05.10 13:42:13 -08'00' RBDMS JSB 051523 3700 Centerpoint Drive Suite 500 Anchorage, Alaska 99503 Giorgio Iannucci Phone (907) 865-3320 Email: Giorgio.iannucci@eni.com May 9, 2023 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval for SP10-FN5 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well SP10-FN5. SP10-FN5 was completed on Spy Island on October 2nd, 2012 with a through-tubing conveyed electric submersible pump (TTC-ESP) set at a depth of 10,267’ MD. This ESP producer was completed without a packer. The well was started up for production on October 4, 2012. The well was operated until November 21, 2013, when a mechanical ESP failure occurred. Workover was performed and another ESP was installed, SP10-FN5 L1 lateral was added in 2020 and new conventional ESP was run which was on production until May 2023 when it stops because of an electrical failure. The estimated date for beginning this work is May 11, 2023. 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, Giorgio Iannucci Well Operations Project Manager s May 11, 2023. SP10-FN5 Workover –Proposal Summary and Wellbore Schematic SP10-FN5 Rig Workover PTD#:212-107 Status Well SP10-FN5 is currently stopped waiting for workover. Scope of Work Scope of this workover is to pull the current ESP tubing completion and swap with a new tubing and conventional ESP system. General Well Info Reservoir Pressure/TVD: Maximum expected reservoir pressure is 1,400 psi at 3,877’TVD, which yields a MASP of 1,012 psi. SP10-FN5 MASP Shut-in BHP (Max) 1,400 psi, 6.9 ppge Depth 3,877 ft. TVD Gradient 0.1 psi/ft MASP 1,012 TIFL/MIT-IA/MIT-OA:Intermediate csg 9 5/8” was tested to 1600 psi on March 3 rd, 2020 Wellhead type/pressure rating: Vault, MB-247/5000 psi BOP configuration: Annular/VBR/Shear Rams/VBR Well type: Producer Estimated start date: May 11 th, 2023 Drilling Rig: Doyon 15 Sr. Drilling Engineer: Amjad Chaudhry amjad.chaudhry@eni.com Work: 907-865-3379 Well Operations Project Manager: Giorgio Iannucci giorgio.iannucci@eni.com Work: 907-865-3320 Intermediate csg 9 5/8” was tested to 1600 psi ong March3rd,2020 Procedure Summary 1. MIRU Doyon 15. 2. Circulate brine through tree. 3. Set BPV. ND tree and NU BOP and test to 250/3500 psi; 48-hour notice to AOGCC to witness; 4. Pull out of hole Blanking Plug and BPV 5. POOH and lay down ESP assembly. 6. Contingent Cleanout run , PU work string and RIH to cleanout above SLZXP LTP 7. POOH and LD the BHA. 8. MU new Conventional ESP assembly and RIH to setting depth. 9. Land hanger and test it. 10. Install BPV and nipple down BOP. 11. NU tubing adapter and tree. 12. Pull BPV, install test plug and test tree. (5000 psi test) 13. Circulate Freeze protect through tree down IA. 14. Shut in well. 15. RDMO. Current Completion Schematic Proposed Completion Schematic will be the same as current schematic with few feet difference in the setting depth of ESP Vetco Gray, MB-247/5000 psi • • o x 25 O it r O v ^ O OM/ O O O r C N CO 'OV VO CO O i- CO •- co r r- 0) co0 N CO ' q j N U c4 0 LL / 2 co COMa to O m o CO CO h co r v } n r N N CO ' w a , N N CO C') CO N vO CO N C') `OV N V. M \y tCO I." z. W H U C 0 m 4:,O N C) N r N 0 COM N N COMN OVr COm m CO 0 CO CO m n CONNO COm O mC 0 NNsrNK) CO . oON h N N 'UN M M O 'NO < < O g N O 0. O i_' m rn ro OD W O 0 0) m m m n a n r m CO a N N N a CO n m m n a) 2 L CO N {EO N N m Q Z m C 1 P--! t N to O o c m , COGNG NN O) CO M 0 CO 0 O) N N O O '- n M ' O M 0iC ONNKMANpp ? 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LL co a z u. co co z 'z 3 y .0 m 'u�) C c3 g A 8 O O N 4 tb n com �,� CL 0 _( 0 coO N m N N N N N N C•O G Z w 3 a a a a a a a a a a a a r a" — 0- 0 0 0 0 0 0 0 0 0 0 0 0 ai on to h to fp co y h N coaco N co co coaco cO a 2 a Technical Report Title Date Client: ENI Petroleum Field: Nikaitchuq Rig: Doyon 15 Date: October 1, 2012 Surface Data Logging End of Well Report SP10-FN5 TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Morning Reports 4. Bit Record 5. Mud Record 6. Show Reports 7. Formation Tops 8. Survey Report 9. Days vs. Depth Digital Data to include: Final Logs Halliburton Log Viewer EMF Log Viewer End of Well Report in PDF format ADI Backup GENERAL WELL INFORMATION Company: Eni Petroleum Rig: Doyon 15 Well: SP10-FN5 Field: Nikaitchuq Borough: North Slope Borough State: Alaska Country: United States API Number: 50-629-23473-00-00 Sperry Job Number: AK-AM-0009650301 Job Start Date: 27 Aug 2012 Spud Date: 31 Aug 2012 Total Depth: 21,118’ MD, 3874.6’ TVD Total Depth Date: 24 Sep 2012 North Reference: True Declination: 20.371˚ Dip Angle: 81.090˚ Total Field Strength: 57643.861 nT Date Of Magnetic Data: 01 Sep 2012 Wellhead Coordinates N: North 70° 33’ 28.09700” Wellhead Coordinates W: West 149° 54’ 15.70029“ Drill Floor Elevation: 53.920’ Ground Elevation: 13.1’ Permanent Datum: Mean Sea Level SDL Engineers: Leigh Ann Rasher, Alexander Kalenuik, Kori Jo Anderson, Brad Causey Company Geologist: Andrew Buchanan Company Representatives: Jack Keener, Mike Ross SSDS Unit Number: 110 DAILY SUMMARY Begin SP10-FN5 08/27/2012 Rig is being moved. Mudloggers are on standby. 08/28/2012 Rig is being moved. Mudloggers are on standby. 08/29/2012 Mudloggers rigged up equipment in the unit to get ready to spud. 08/30/2012 Continued to work on drawworks breaks and load 13 3/8” casing into the pipe shed. Hang blocks and slip line. Finish rigging up the diverter line and the diverter. Pick up 5” drill pipe and 5” heavy weight drill pipe and rack back. Test the diverter bag and knife valve. Pick up BHA #1 to clean out conductor. Find leak in the knife valve and fix it. Drill out conductor to 127’ MD. 08/31/2012 Continue to clean out conductor to 160’ MD. Rig up wireline and pick up BHA #2. Drill ahead to 251’ MD and pull out of hole to pick up 8” flex collar and jars. Run in hole and drill ahead from 251’ MD to 752’ MD taking gyro surveys as needed. 09/01/2012 Drill ahead from 752’ MD to 2653’ MD. The max gas observed the past 24 hours was 1137 units at 1965’ MD. 09/02/2012 Drill ahead from 2653’ MD to TD of surface section at 3690’ MD at 40 RPM, 700 gpm, 1,560 psi, and 25- 40K WOB. Monitor well at TD for 10 minutes. Begin to back ream out of hole from 3690’ MD to 2903’ MD as of midnight. Mas gas observed was 196 units at 2954’ MD. 09/03/2012 Continue to back ream out of the hole from 2903’ MD at 800 gpm to 252’ MD. Pick up BHA #2 on elevators and lay down. Pick up 13 3/8” casing and run in hole. 09/04/2012 Continue to run in hole with 13 3/8” casing from 1,914’ MD to 3674’ MD. Condition mud at 5 bpm and rig up cementers and proceed with cement job. Rig down cementers. Nipple down riser and diverter as of midnight. 09/05/2012 Clean all surface equipment of spud mud. Nipple down riser and diverter, Prep and spot Vetco casing head and lower multi bowl and test. Load pipe shed of 5” drill pipe. Nipple up BOPE stack, install blind rams and test BOPE’s 09/06/2012 Continue to change saver sub. Pick up 245 single joints of 5” drill pipe in mouse hole. Pick up BHA#3 and run in hole to 1,485’ MD and perform shallow hole test per directional driller. Run in hole to 3540’MD and circulate and condition for casing test. Test 13.375” casing to 2500 PSI for 30 min. Cut and slip drill line and adjust brakes. 09/07/2012 Drill out of shoe track and shoe. Drill 20 feet of new hole to 3,710’ MD. Displace spud mud with 9.25 ppg new LSND mud at 7 bpm. Clean surface equipment and perform FIT to 12.0 ppg EMW. Drill ahead from 3,710’ MD to 6,150’ MD with parameters of 900 gpm, 1,820 psi, 120 to 200 RPM, 8-12K torque. 09/08/2012 Drilling ahead from 6,150’ MD’ to 8,905’ MD with parameters of 900 gpm, 2,300 psi, 120 to 200 RPM, and 12-15K torque. Max gas observed the past 24 hours was 104 units at 8,714’ MD. No losses noted while drilling. 09/09/2012 Drill ahead from 8,905’ MD to 11,474’ MD with parameters of 900 gpm, 2,500 psi, 120 to 200 RPM, and 16K torque. Max gas observed the past 24 hours was 660 units at 10,360’ MD. No losses noted while drilling. 09/10/2012 Drill ahead from 11,474’ MD to TD at 11,939’ MD/3905’ TVD with parameters of 900 gpm, 2,740 psi, 200 RPM, and 17K torque.. No losses noted while drilling. Circulate bottoms up and backream to 11,477’ MD per K&M. Continue to backream out of hole at drill rate to 7,182’ MD as hole dictated. 09/11/2012 Back ream out of hole at drill rate from 7,182’ MD to 3,630’ MD as hole dictated with parameters of 900 gpm, 1,730 psi and 140 rpm. Monitor well, static, and continue to back ream out of hole. Backream to 2,976’ MD at 900 gpm and reduce to 800 gpm to 1,762’ MD. 09/12/2012 Backream from 1,762’ MD to 916’ MD. Circulate bottoms up and monitor well, static. Pull out of hole with elevators to 262’ MD. Lay down BHA. Change rams and test. Flush stack and rig up Tesco for 9.625” casing run. Float casing to 815’ MD and repair pipe skate. Continue to run casing to 3,012’ MD at time of report. 9/13/2012 Continue to run 9 5/8” casing from 3,012’ MD to 11,919’ MD. Calculated displacement observed. Rig up “fill pipe” through choke with cement head. Fill pipe at 3 bbls/min per fill up plan. 902 bbls to fill pipe. Load cement plugs. Break circulation at 0.5 bpm & 420 psi. No daily LSND losses. 9/14/2012 Circulate 9 5/8” at 11,919’ MD at 0.5 bpm, 420 psi and stage up to 7 bpm and 500 psi. Cement job: 70 bbls 10.5 lb/gal MudPush and 227 bbls 12.5 lb/gal cement. Chase with LSND and bump plug at 885 bbls. Pump 20 bbls LSND for injectivity test. Nipple down BOP, cut casing and install packoff. Begin to nipple up BOP stack. 9/15/2012 Finish nipple up of BOP stack and perform “body” test. Freeze protect 13 3/8” x 9 5/8” annulus with 219 bbls of diesel. Pick up 4.5” drill pipe. Rig up and begin testing BOP per AOGCC requirement. 9/16/2012 Rig down testing equipment and pick up tools. Make up BHA#4 and load nukes. Perform shallow hole test and run in hole to 10,900’MD filling pipe every 20 stands. Taking all returns to pit #5 isolated with the old LSND. Washdown from 10,900’ MD to 10,948’ MD at 1550 psi. 9/17/2012 Finish washdown from 10,948’ MD through11,819’ MD. Pre-job on displacement to oil based mud. Displace to 9.4ppg FazePro. Cut and slip drill line, clean shakers and trough to Pit #5. Perform LOT to 13.0 ppg EMW and begin to drill 8 ¾” production section to 12,150’ MD. 9/18/2012 Continue drilling from 12,150’ MD to 13,710’ MD at 160 RPM, 550 gpm, 8-10K WOB, 3,170 psi and 16- 17K torque. Max gas for today was 1,107 units at 13,630’ MD. No losses to formation. 9/19/2012 Continue to drill ahead from 13,710’ MD to 15,920’ MD with drilling parameters of 8-10K WOB, 160 RPM, 550 gpm, 3320 psi, and 16-17K torque. Encountered connection gas during drilling. Max gas of 5,136 units at 15,310’ MD. No losses to formation. 9/20/2012 Continue to drilling ahead from 15,920’ MD to 17,257’ MD with 2-8K WOB, 160 RPM, 550 gpm , 3500 psi and 16-17K torque. Encountered connection gas drilling. Max gas of 1,098 units at 16,385’ MD. No losses to formation. 9/21/2012 Continue drilling ahead from 17,257’ MD to 18,299’ MD at which time the D.S. was to pick up to 18,251’ MD as per directional driller and begin troughing due to high inclination. Decision was made to go back to bottom and control drill with light weight. Drilling continued to 18,339’ MD at 550 gpm, 3680 psi, 160 RPM, 8-10K WOB and 17-18 torque. Max gas observed was 965 units at 17,941’ MD. 9/22/2012 Continue to drill ahead from 18,339’ MD to 19,290’ MD with 120 RPM, 550 gpm, 3,610 psi, 10K WOB, and 18K torque. Still encountering drilling breaks and concretions. Max gas observed was 682 units at 18,431’ MD. 9/23/2012 Drill ahead from 19,290’ MD to 20,874’ MD with 140 RPM, 550 gpm, 3,790 psi, and 10-15 torque. Max gas observed was 826 units at 19,550’ MD. 9/24/2012 Continue to drill ahead from 20,874’ MD to TD at 21,118’ MD at 540 gpm, 140 RPM, 10-16K WOB and 18-22 torque. Circulate bottoms up and back ream out of hole per K&M. Slight packing off noticed around 18,974’ MD, slowed pumps and drop back down to ream through slowly. Max gas observed was 355 units at 19,550’ MD. 9/25/2012 Continue to backream out of the hole from 15,600’ MD to 12,195’ MD at 550 gpm, 140 RPM, and 3420 psi. Service rig and continue to backream out of the hole from 12,195’ MD to 9,759’ MD. Circulate bottoms up and change out saver sub and wash pipe swivel. Continue to backream out of the hole from 9,759’ MD to 6,500’ MD per K&M. Circulate 2 bottoms up and pull out of the hole on elevators. 9/26/2012 Continue to pull out of the hole on elevators from 3,300’ MD to HWDP. Lay down BHA #4 and change out saver sub to HT 525. Cut and slip drill line and rig up casing equipment. Make up ECC nose guide show with Baker Lok and run in hole with 5.5” slotted liner. 9/27/2012 Continue to run in hole with 5.5” liner. Rig down casing equipment and pick up liner hanger. Run in hole with 5” DP to bottom. Pick up to set depth of 21,076’ MD and set hanger per Baker Rep. Release and test packer to 1,500 psi. Displace hole to 9.00 ppg brine. Pull out of hole and lay down 5” DP. 9/28/2012 Continue to lay down 5” DP. Lay down Baker running tool and change out saver sub. Run in hole with 4.5” DP to 9,448’ MD and pull out of hole. Lay down 4.5” DP, pull wear ring and rig up test equipment. Test BOP’s as of midnight. 9/29/2012 Rigged down testing equipment from BOP test. Rigged up Spooling unit and wireline for completion string. Set Pack Off and test to 1,000 psi for 15 minutes. Picked up Motor Assembly and stand back in Derrick. Making up ESP splice as of midnight. 9/30/2012 Continued to make up ESP splice. Ran in hole with 4.5” Tubing and control lines to 7,862’. Continued on ESP Reel and work on splice as of midnight. . . Density (ppg) Viscosity out (sec/qt) ROP Set AtSize 178.9 X-65 Bit # Current in cP Area: Location: Grade Silt Siltst 4.23 Tuff Footage Make ROP (ft/hr) Bit Type 96% Gallons/stroke @ Lst EVAMAR Weight TFA pH % MBT Flow In (spm) Flow In (gpm) Hours SPP (psi) (ppb Eq) Mud Data PV 160' 160' 0' Current Pump & Flow Data: Current Depth: 24 Hour Progress: $6,610.00 Rig Up Yesterday's Depth: Rig Activity:$2,810.00 Ross/Smith/BuchananReport For: Daily Charges: Max @ ft Lithology (%) Casing Summary WOB 160' Ss 20" ShClystCly Customer: Well: Avg MWD Summary Depth 160' to 160' Rig: Total Charges: ENI Petroleum Chlorides SP10-FN5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009650301Job No.: 3 29-Aug-2012 24:00Time: Report #: Date: Size (current) Cht YP (lb/100ft2) Condition Depth Mud Type mg/l Coal Gvl API FL Cor Solids ml/30min RPM ECD (ppg) Avg Depth in / out Tools Min Max * 10000 units = 100% Gas In Air Connection 0 0 C-5n Leigh Ann Rasher C-3 0 0 0 Logging Engineers:Leigh Ann Rasher/Kori Jo Anderson (max)(current) Report By: (max) 0 0 C-5i Chromatograph (ppm) 0 0 C-1 Minimum C-4i 0 C-4nC-2 000 0 Cont. to rig up. Work on BOP stack and brakes. md Average 0 Gas Summary Units* 0 00000 Maximum Depth 907-685-0772Unit Phone: 24 hr Recap: TripBackground . . Density (ppg) Viscosity out (sec/qt) Max ml/30min RPM ECD (ppg) Avg 750 Depth in / out Tools Min mg/l Coal Gvl API FL 7.0 Cor Solids Spud Mud Depth Mud Type Condition YP 1 8.70 (lb/100ft2) 0' 170 (current) Cht 4 30-Aug-2012 24:00Time: Report #: Date: ENI Petroleum Chlorides SP10-FN5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009650301Job No.: Customer: Well: Avg MWD Summary Depth 160' to 160' Rig: Total Charges: ShClystCly 160' Ss 20" Lithology (%) 2.0 Casing Summary WOB 35 $2,810.00 Ross/Smith/BuchananReport For: Daily Charges: Max @ ft 160' 160' 0' Current Pump & Flow Data: Current Depth: 24 Hour Progress: $9,420.00 Drill Ahead Yesterday's Depth: Rig Activity: (ppb Eq) Smith XR+ Mill Tooth Mud Data 110' PV 20.0 1.117 23 Size Flow In (spm) Flow In (gpm) Hours SPP (psi) 9.30 TFA pH % MBT @ Lst EVAMAR Weight ROP (ft/hr) Bit Type 96% Gallons/stroke Make 4.23 Tuff Footage Silt Siltst Grade Area: Location: ROP Set AtSize 178.9 X-65 Bit # Current in cP * 10000 units = 100% Gas In Air knife valve and fixed. Drill out conductor to 127' MD. Background 907-685-0772Unit Phone: 24 hr Recap: Trip Maximum Depth 00000 0 Units* 0 Gas Summary md Average Work on drawworks brake. Load 13 3/8" casing into pipe shed. Hang blocks and slip line. Finish R/U of diverter line 0 000 C-4nC-2 Minimum C-4i 0 C-5i Chromatograph (ppm) 0 0 C-1 0 0 (max)(current) Report By: and diverter. P/U 5" D.P and 5" HWDP and rack back. Test diverter bag and knife valve. P/U BHA #1 for clean out. Found leak in (max) Leigh Ann Rasher C-3 0 0 0 Logging Engineers:Leigh Ann Rasher/Kori Jo Anderson Connection 0 0 C-5n . . Density (ppg) Viscosity out (sec/qt) ROP Set AtSize 178.9 X-65 Bit # Current in 94.4 cP Area: Location: Grade Silt Siltst 4.23 Tuff Footage ROP (ft/hr) Bit Type 96%125 Gallons/stroke @ 231.6 Lst EVAMAR Weight TFA pH % MBT Flow In (spm) Flow In (gpm) Hours 539 SPP (psi) 9.50 (ppb Eq) Smith XR+ Mill Tooth Mud Data 110' PV 17.5 1.117 17 Size 160' 752' 592' Current Pump & Flow Data: Current Depth: 24 Hour Progress: $12,230.00 Drill Ahead Yesterday's Depth: Rig Activity: 1366.4 $2,810.00 253' Ross/Smith/BuchananReport For: Daily Charges: 671 Max @ ft 4.0 Casing Summary WOB 39 Make 160' Ss 20" ShClystCly Customer: Well: Avg MWD Summary Depth 160' to 752' Rig: Total Charges: ENI Petroleum Chlorides SP Motor 1.83, ARC 825, TeleScope 825 SP10-FN5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009650301Job No.: 5 31-Aug-2012 24:00Time: Report #: Date: (current) Cht Lithology (%) YP 1 9.05 (lb/100ft2) 160' 116 Condition Spud Mud Depth Mud Type 10.26 mg/l 9.54 Coal Gvl API FL 5.8 Cor Solids 10.85 ml/30min RPM ECD (ppg) Avg 3,000 Depth in / out Tools Min Max * 10000 units = 100% Gas In Air Logging Engineers:Leigh Ann Rasher/Kori Jo Anderson Connection 0 0 C-3 0 0 0 C-5n (current) Report By: jars. RIH and drill ahead from 251' MD to 752' MD taking Gyro surveys as needed. (max) Leigh Ann Rasher 97 2 (max) Chromatograph (ppm) 0 0 C-1 0 Minimum C-4i 1284 C-5iC-4nC-2 000161' 736'0 Cont. to clean out conductor to 160'. R/U wireline and P/U BHA #2. Drill to 251' MD and POOH to P/U 8" flex collar and 4 md Average 0 Gas Summary Units* 0 00000 Maximum Depth 907-685-0772Unit Phone: 24 hr Recap: 7 Trip 14 Background . . Density (ppg) Viscosity out (sec/qt) Max ml/30min RPM ECD (ppg) Avg 1,300 Depth in / out Tools Min mg/l Coal Gvl API FL 6.0 Cor Solids Spud Mud Depth Mud Type Condition YP 1 9.40 (lb/100ft2) 160' 65 (current) Cht Lithology (%) 6 1-Sep-2012 24:00Time: Report #: Date: ENI Petroleum Chlorides SP Motor 1.83, ARC 825, TeleScope 825 SP10-FN5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009650301Job No.: Customer: Well: Avg MWD Summary Depth 752' to 2653' Rig: Total Charges: ShClystClySs 20" 5.5 Casing Summary WOB 26 Make 160' Rig Activity: 782.7 $3,810.00 1603' Ross/Wimmer/BuchananReport For: Daily Charges: 1264 Max @ ft Size 752' 2653' 1901' Current Pump & Flow Data: Current Depth: 24 Hour Progress: $16,040.00 Drill Ahead Yesterday's Depth: 647 SPP (psi) 9.50 (ppb Eq) Smith XR+ Mill Tooth Mud Data 2404' PV 20.0 MBT Flow In (spm) Hours 1.117 20 178.7 Lst EVAMAR Weight TFA pH Flow In (gpm) 153 Gallons/stroke @ % ROP (ft/hr) Bit Type 96%4.23 Tuff Footage Silt Siltst Grade Area: Location: ROP Set AtSize 178.9 X-65 Bit # Current in 147.5 cP * 10000 units = 100% Gas In Air 1137 Background 24 hr Recap: 97 Trip Maximum Depth 00000 0 Units* Average 0 Gas Summary Drill ahead from 752' MD to 2653' MD. Max gas observed the past 24 hours was 1137 units at 1965' MD. 132 md 1895' 1965'0 00220 C-5iC-4nC-2C-1 0 Minimum C-4i 132222 (max) Chromatograph (ppm) 0 0 (max) Leigh Ann Rasher 16176 6 Report By: 907-685-0772Unit Phone: C-3 0 0 0 C-5n (current) Logging Engineers:Leigh Ann Rasher/Kori Jo Anderson Connection 0 0 . . Density (ppg) Viscosity out (sec/qt) ROP Set AtSize 178.9 X-65 Bit # Current in cP Area: Location: Grade Silt Siltst 4.23 Tuff Footage ROP (ft/hr) Bit Type 96%@ % 168.8 Lst EVAMAR Weight TFA pH Flow In (gpm) MBT Flow In (spm) Hours 1.117 23 Smith XR+ Mill Tooth Mud Data 3690' PV 17.0 BROOH Yesterday's Depth: 791 SPP (psi) 9.60 (ppb Eq) 187 Gallons/stroke 1590 Max @ ft Size 2653' 3690' 1037' Current Pump & Flow Data: Current Depth: 24 Hour Progress: $18,850.00 Make 160' Rig Activity: 491.1 $2,810.00 3459' Ross/Wimmer/BuchananReport For: Daily Charges: 6.0 Casing Summary WOB 26 ShClystCly Customer: Well: Avg MWD Summary Depth 2653' to 3690' Rig: Total Charges: ENI Petroleum Chlorides SP Motor 1.83, ARC 825, TeleScope 825 SP10-FN5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009650301Job No.: 7 2-Sep-2012 24:00Time: Report #: Date: Cht Lithology (%)Ss 70 (current) 20" YP 1 9.25 (lb/100ft2) 160' Condition Spud Mud Depth Mud Type 10.17 mg/l 9.82 Coal Gvl API FL 5.7 Cor Solids 11.23 ml/30min RPM ECD (ppg) Avg 900 Depth in / out Tools Min Max * 10000 units = 100% Gas In Air Logging Engineers:Leigh Ann Rasher/Alexander Kalenuik Connection 0 0 C-3 0 0 0 C-5n (current) Report By: well at TD for 10 min. BROOH from 3690' MD to 2903' MD as of midnight. Max gas observed was 196 units at 2954' MD. 907-685-0772Unit Phone: (max) Leigh Ann Rasher 7684 5 (max) Chromatograph (ppm) 0 0 C-1 0 Minimum C-4i 12581 C-5iC-4nC-2 00766 0 Drill ahead from 2653' MD to TD of surface section at 3690' MD 40 RPM, 700 gpm, 1,560 psi, 25-40K WOB. Monitor 68 md 3554' 2954' Average 0 Gas Summary 0 00000 DepthUnits* Maximum 43 24 hr Recap: Trip 196 Background . . Density (ppg) Viscosity out (sec/qt) Min Max ml/30min RPM ECD (ppg) Avg 800 Depth in / out Tools Coal Gvl API FL 5.6 2-2-WT-A-E-In-No-TD Cor Solids Condition 40.0 YP 1 9.40 (lb/100ft2) 160' 3690' 3530' Spud Mud (current) 20" Cht Lithology (%)Ss 8 3-Sep-2012 24:00Time: Report #: Date: ENI Petroleum Chlorides SP10-FN5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009650301Job No.: Customer: Well: Avg MWD Summary Depth 3690' to 3690' Rig: Total Charges: ShClystCly 5.5 Casing Summary 29.30 WOB 33 160' Rig Activity:$2,810.00 Ross/Wimmer/BuchananReport For: Daily Charges: 80 0' Current Pump & Flow Data: Current Depth: 24 Hour Progress: $21,660.00 Make mg/l Yesterday's Depth: SPP (psi) 8.90 (ppb Eq) Gallons/stroke Max @ ft 3690' 3690' Mud Data 3690' PV 17.5 16" Run 13 3/8" Casing Size Depth Mud Type MBT Flow In (spm) Hours 1.117 21 Smith XR+ Mill Tooth Lst EVAMAR Weight TFA pH Flow In (gpm) @ % ROP (ft/hr) Bit Type 96%4.23 Tuff Footage Silt Siltst 22.0 Grade Area: Location: ROP Set AtSize 178.9 X-65 Bit # Current in cP * 10000 units = 100% Gas In Air Background 768 24 hr Recap: Trip Maximum DepthUnits* 00000 00 Gas Summary Cont to BROOH from 2903' MD at 800 gpm to 252' MD. P/U BHA #2 on elevators and L/D. P/U 13 3/8" casing on RIH. md Average 0 000 C-5iC-4nC-2C-1 0 Minimum C-4i 0 (max) Chromatograph (ppm) 0 0 (max) Leigh Ann Rasher 0 Report By: 907-685-0772Unit Phone: C-3 0 0 0 C-5n (current) Logging Engineers:Leigh Ann Rasher/Alexander Kalenuik Connection 0 0 . . Density (ppg)Viscosity out (sec/qt) Min Max ml/30min RPM ECD (ppg) Avg 800 Depth in / out Tools Coal Gvl API FL 5.2 2-2-WT-A-E-In-No-TD Cor Solids 5.5 pH Condition 40.0 YP 1 9.45 (lb/100ft2) 160' 3690' 3530' Spud Mud (current) Casing Summary LstCht Lithology (%)Ss Job No.: 9 4-Sep-2012 24:00Time: Report #: Date: Total Charges: ENI Petroleum Chlorides SP10-FN5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009650301 Customer: Well: Avg MWD Summary Depth 3690' to 3690' Rig: ShClystCly 29.30 WOB 31 160' 80 EVAMAR Weight TFA 20" Make mg/l Rig Activity:$3,810.00 3690' 3690' 0' Current Pump & Flow Data: Current Depth: 24 Hour Progress: $25,470.00 Ross/Wimmer/BuchananReport For: Depth Mud Type Yesterday's Depth: SPP (psi) 9.00 (ppb Eq) Gallons/stroke Max @ ft PV 16.0 16" Casing/Cementing Size Daily Charges: Flow In (gpm) Flow In (spm) Hours Gas Summary 1.117 36 Smith XR+ Mill Tooth Mud Data @ % MBT ROP (ft/hr) Bit Type Silt Siltst 3690' 96%4.23 Tuff Footage 22.0 Grade Area: Location: ROP Set AtSize 178.9 X-65 Bit # Current in cP *10000 units = 100% Gas In Air Background 0 24 hr Recap: Trip Continued RIH 13 3/8" casing F/ 1,914' to 3,674'. Condition mud at 5 bpm. R/U. Cementers and proceeded with cement job. Rig down cementers. N/D Riser and Diverter as of midnight. (max) Maximum DepthUnits* 00000 0 0 md. Average 0 000 0 C-5iC-4nC-1 0 Minimum C-4iC-2 (max) Chromatograph (ppm) 0 0 Leigh Ann Rasher 0 Report By: cement job. Rig down cementers. N/D Riser and Diverter as of midnight. 907-685-0772Unit Phone: C-3 0 0 0 C-5n (current) Logging Engineers:Leigh Ann Rasher/Alexander Kalenuik Connection 0 0 . . Density (ppg)Viscosity out (sec/qt) ROP Set AtSize 178.9 X-65 Bit # Current in cP Area: Location: 22.0 Grade 4.23 Tuff Footage 96% ROP (ft/hr) Bit Type Silt Siltst @ % MBT Flow In (spm) Hours Gas Summary 1.117 18 Smith XR+ Mill Tooth Mud Data 3690' PV 16.0 16" Testing BPOE's Size Depth Mud Type Yesterday's Depth: SPP (psi) 8.70 (ppb Eq) Gallons/stroke Max @ ft 3690' 3690' 0' Current Pump & Flow Data: Current Depth: 24 Hour Progress: $28,280.00 Make mg/l Rig Activity:$2,810.00 Ross/Wimmer/BuchananReport For: Daily Charges: Flow In (gpm) 29.30 WOB 18 160' 61 EVAMAR Weight TFA ShClystCly Customer: Well: Avg MWD Summary Depth 3690' to 3690' Rig: Total Charges: ENI Petroleum Chlorides SP10-FN5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009650301Job No.: 10 5-Sep-2012 24:00Time: Report #: Date: Ss 20" Cht Lithology (%) (current) Casing Summary Lst YP 1 9.30 (lb/100ft2) 160' 3690' 3530' Spud Mud Condition 40.0 Coal Gvl API FL 5.4 2-2-WT-A-E-In-No-TD Cor Solids 5.4 pH ml/30min RPM ECD (ppg) Avg 800 Depth in / out Tools Min Max *10000 units = 100% Gas In Air Logging Engineers:Leigh Ann Rasher/A.Paul Kalenuik Connection 0 0 C-3 0 0 0 0 C-5n (current) Report By: Lower Multi bowl and test. Load pipe shed of 5" DP. Nipple up BOPE stack: install blind rams. 907-685-0772Unit Phone:A.Paul Kalenuik 0 0 (max) Chromatograph (ppm) 0 0 C-1 0 Minimum C-4i 0 C-5iC-4nC-2 000 0 0 md. Average 00 00000 Units*Depth Maximum 0 24 hr Recap: Trip Clean All surface equipment of spud mud. N/D Riser & Diverter. Prep & spot Vetco casing head. (max) Test BOPE's. 0 Background . . Density (ppg)Viscosity out (sec/qt) ROP Set AtSize 178.9 X-65 Bit # Current in cP Area: Location: 22.0 Grade 4.23 Tuff Footage 96% ROP (ft/hr) Bit Type Silt Siltst 3690' @ % MBT Flow In (spm) Hours Gas Summary 1.117 18 Smith XR+ Mill Tooth Mud Data PV 16.0 16" Cut/Slip Drill Line Size Daily Charges: Flow In (gpm) Depth Mud Type Yesterday's Depth: SPP (psi) 8.70 (ppb Eq) Gallons/stroke Max @ ft Current Pump & Flow Data: Current Depth: 24 Hour Progress: $31,690.00 Ross/Wimmer/BuchananReport For: Make mg/l Rig Activity:$3,410.00 29.30 WOB 2 18 160' 61 EVAMAR Weight TFA 20" ShClystCly Customer: Well: Avg MWD Summary Depth 3690' to 3690' Rig: Total Charges: ENI Petroleum Chlorides SP10-FN5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009650301Job No.: 11 6-Sep-2012 24:00Time: Report #: Date: 3690' 3690' 0' Ss 3690' Cht Lithology (%) 13.375" (current) 3674' Casing Summary Lst YP 1 9.30 (lb/100ft2) 160' 3690' 3530' Spud Mud Hycalog SKHI716-E4C Condition 40.0 Coal Gvl API FL 5.4 2-2-WT-A-E-In-No-TD Cor Solids 5.4 pH ml/30min RPM ECD (ppg) Avg 800 Depth in / out Tools Min Max 12.25 *10000 units = 100% Gas In Air Logging Engineers:A.Paul Kalenuik/ Brad Causey Connection 0 0 C-3 0 0 0 0 C-5n (current) Report By: MD and perform SHT per DD. Run in hole to 3540'. Circulate and condition for casing test. Test 13.375" casing to 2500 PSI for 907-685-0772Unit Phone:A.Paul Kalenuik 0 0 (max) Chromatograph (ppm) 0 0 C-1 0 Minimum C-4iC-2 0 C-5iC-4n 000 0 0 md. Average 00 00000 Units*Depth Maximum 0 24 hr Recap: Trip Cont. change saver sub. P/U 245 single joints 5" drill pipe in mouse hole. P/U BHA #3. Run in hole to 1485'. (max) 30 min. Cut and Slip Drill Line and adjust brakes. 0 Background . . Density (ppg)Viscosity out (sec/qt) ROP Set AtSize 178.9 X-65 Bit # Current in 172.0 cP Area: Location: 22.0 Grade 4.23 Tuff Footage 96% ROP (ft/hr) Bit Type Silt Siltst 6176' @ % MBT Flow In (spm) Hours Gas Summary 1.117 10 Smith XR+ Mill Tooth Mud Data PV 2.0 16" Drill 12.25" Hole 1886 Size Daily Charges: 11.1 Flow In (gpm) Depth Mud Type Yesterday's Depth: 873 SPP (psi) 0.10 (ppb Eq) Gallons/stroke Max @ ft Current Pump & Flow Data: Current Depth: 24 Hour Progress: $34,500.00 Ross/Wimmer/BuchananReport For: Make 29 10.12 mg/l 9.45 Rig Activity: 348.0 $2,810.00 3709' 29.30 WOB 2 18 160' 47 EVAMAR Weight TFA 20" ShClystCly 20 Customer: Well: Avg MWD Summary Depth 3710' to 6176' Rig: Total Charges: ENI Petroleum Chlorides SP10-FN5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009650301Job No.: 11 7-Sep-2012 24:00Time: Report #: Date: 3710' 6176' 2466' Ss 80 3690' Cht Lithology (%) 13.375 (current) 3674' Casing Summary Lst YP 1 9.25 (lb/100ft2) 160' 3690' 3530' Spud Mud Hycalog SKHI716 Condition 40.0 Coal Gvl API FL 5.4 2-2-WT-A-E-In-No-TD Cor Solids 4.0 pH 10.49 ml/30min RPM ECD (ppg) Avg 650 Depth in / out Tools Min Max 12.25 *10000 units = 100% Gas In Air Logging Engineers:Leigh Ann Rasher/A.Paul Kalenuik Connection 1 519 C-3 499 41 1285 0 C-5n (current) Report By: Mud with 9.25 ppg new LSND at 7 bpm. Perform FIT per Co. Rep. R/D Testing. Drilling from 3710' to 6176' 907-685-0772Unit Phone:A.Paul Kalenuik 679 2 (max) Chromatograph (ppm) 2 1319 C-1 1298 Minimum C-4iC-2 5301 C-5iC-4n 111 2663 13 md. 5324' Average 11 11422 Units*Depth Maximum 0 24 hr Recap: Trip Cut and Slip Drill Line& adjust brakes. Drill out shoe track & shoe. Drill drill 20' of new hole to 3710'. Displace spud mud with 9.25 ppg newLSND at 7 bpm. Perform FIT per Co rep. Drilling from 3710' to 6176'. (max) 295 Background . . Density (ppg)Viscosity out (sec/qt) Min Max 12.25 10.49 ml/30min RPM ECD (ppg) Avg 1,100 Depth in / out Tools Coal Gvl API FL 5.6 2-2-WT-A-E-In-No-TD Cor Solids 5.3 199 pH Condition 40.0 YP 1 9.40 (lb/100ft2) 160' 3690' 3530' LSND Hycalog SKHI716 (current) 3674' Casing Summary Lst 90 3690' Cht Lithology (%) 13.375 Ss Job No.: 12 8-Sep-2012 24:00Time: Report #: Date: 6176' 9006' 2830' Total Charges: ENI Petroleum Chlorides SP10-FN5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009650301 Customer: Well: Avg MWD Summary Depth 3710' to 6176' Rig: ShClystCly 10 29.30 WOB 2 32 160' 60 EVAMAR Weight TFA 20" Make 29 10.12 mg/l 9.45 Rig Activity: 419.0 $2,810.00 8714' Current Pump & Flow Data: Current Depth: 24 Hour Progress: $37,310.00 Ross/Wimmer/BuchananReport For: Depth Mud Type Yesterday's Depth: 898 SPP (psi) 9.70 (ppb Eq) Gallons/stroke Max @ ft PV 13.5 16" Drill 12.25" Hole 2311 Size Daily Charges: 122.0 Flow In (gpm) Flow In (spm) Hours Gas Summary 1.117 13 Smith XR+ Mill Tooth Mud Data @ % MBT ROP (ft/hr) Bit Type Silt Siltst 8905' 96%4.23 Tuff Footage 22.0 Grade Area: Location: ROP Set AtSize 178.9 X-65 Bit # Current in 219.0 cP *10000 units = 100% Gas In Air 104 Background 0 24 hr Recap: 9 Trip Drilling from 6176' to 9006'. Gas units varied:12, 12, 27, and 38 units. No losses noted while drilling. (max) Maximum DepthUnits* 11163122 1 1 24 md. 8714' Average 12653 111 12707 C-5iC-4nC-1 1559 Minimum C-4iC-2 (max) Chromatograph (ppm) 2 1578 A.Paul Kalenuik 1598 2 Report By: 907-685-0772Unit Phone: C-3 557 41 1285 263 C-5n (current) Logging Engineers:Leigh Ann Rasher/A.Paul Kalenuik Connection 1 597 . . Density (ppg)Viscosity out (sec/qt) Min Max 12.25 10.49 ml/30min RPM ECD (ppg) Avg 1,600 Depth in / out Tools Coal Gvl API FL 5.2 2-2-WT-A-E-In-No-TD Cor Solids 6.0 199 pH Condition 40.0 YP 1 9.50 (lb/100ft2) 160' 3690' 3530' LSND Hycalog SKHI716 (current) 3674' Casing Summary Lst 30 3690' Cht Lithology (%) 13.375 Ss Job No.: 14 9-Sep-2012 24:00Time: Report #: Date: 8905' 11474' 2569' Total Charges: ENI Petroleum Chlorides SP10-FN5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009650301 Customer: Well: Avg MWD Summary Depth 9006' to 11474' Rig: ShClystCly 70 29.30 WOB 2 25 160' 84 EVAMAR Weight TFA 20" Make 10 10.12 mg/l 9.45 Rig Activity: 297.0 $2,810.00 11399' Current Pump & Flow Data: Current Depth: 24 Hour Progress: $34,500.00 Ross/Wimmer/BuchananReport For: Depth Mud Type Yesterday's Depth: 901 SPP (psi) 0.00 (ppb Eq) Gallons/stroke Max @ ft PV 15.0 16" Drill 12.25" Hole 2688 Size Daily Charges: 114.0 Flow In (gpm) Flow In (spm) Hours Gas Summary 1.117 13 Smith XR+ Mill Tooth Mud Data @ % MBT ROP (ft/hr) Bit Type Silt Siltst 11474' 96%4.23 Tuff Footage 22.0 Grade Area: Location: ROP Set AtSize 178.9 X-65 Bit # Current in 172.0 cP *10000 units = 100% Gas In Air 660 Background 0 24 hr Recap: 69 Trip Drilling from 8905' to 11474'. Parameters are 900 gpm, 2650 psi , 120 to 200 RPM. Gas units varied : 43, 145, 400 (max) Maximum DepthUnits* 1628611823 1 1 74 md. 10360' Average 4099 111 80947 C-5iC-4nC-1 2006 Minimum C-4iC-2 (max) Chromatograph (ppm) 25 2032 A.Paul Kalenuik 7533 3 Report By: & 600 units. No losses noted while drilling.LSND ajusted denisty depending on hole conditions. WIF USAGE : 14 FLOWZAN. 907-685-0772Unit Phone: C-3 775 1 1994 310 C-5n (current) Logging Engineers:A.Paul Kalenuik/ Brad Causey Connection 1 800 . . Density (ppg)Viscosity out (sec/qt) ROP Set AtSize 178.9 X-65 Bit # Current in 0.0 cP Area: Location: 22.0 Grade 4.23 Tuff Footage 96% ROP (ft/hr) Bit Type Silt Siltst 11939' @ % MBT Flow In (spm) Hours Gas Summary 1.117 12 Smith XR+ Mill Tooth Mud Data PV 17.5 16" Backream 2740 Size Daily Charges: 41.2 Flow In (gpm) Depth Mud Type Yesterday's Depth: 900 SPP (psi) 9.90 (ppb Eq) Gallons/stroke Max @ ft Current Pump & Flow Data: Current Depth: 24 Hour Progress: $42,930.00 Ross/Wimmer/BuchananReport For: Make 13 10.12 mg/l 9.45 Rig Activity: 514.0 $2,810.00 11450' 29.30 WOB 2 26 160' 53 EVAMAR Weight TFA 20" ShClystCly 60 Customer: Well: Avg MWD Summary Depth 11474' to 11939' Rig: Total Charges: ENI Petroleum Chlorides SP10-FN5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009650301Job No.: 15 10-Sep-2012 24:00Time: Report #: Date: 11474' 11939' 465' Ss 40 3690' Cht Lithology (%) 13.375 8249' (current) 3674' Casing Summary Lst YP 1 9.60 (lb/100ft2) 160' 3690' 3530' LSND Hycalog SKHI716 Condition 40.0 Coal Gvl API FL 4.8 2-2-WT-A-E-In-No-TD Cor Solids 6.0 202 pH 10.49 ml/30min RPM 11939' ECD (ppg) Avg 1,500 Depth in / out Tools Min Max 12.25 *10000 units = 100% Gas In Air Logging Engineers:A.Paul Kalenuik/ Brad Causey Connection 1 1304 C-3 816 1 2098 89 C-5n (current) Report By: 11477' per K&M. Backream OOH at drill rate to 7182' as hole dictated. 907-685-0772Unit Phone:A.Paul Kalenuik 9145 6 (max) Chromatograph (ppm) 138 1396 C-1 1590 Minimum C-4iC-2 136367 C-5iC-4n 1116 1649 143 md. 11880' Average 11 7471958892 Units*Depth Maximum 0 24 hr Recap: 7 Trip Drilling from 11474' to TD at 11939' MD/3905 TVD at 900 gpm, No losses noted while drilling. CBU and backream to (max) 1616 Background . . Density (ppg)Viscosity out (sec/qt) Min Max 12.25 ml/30min RPM 11939' ECD (ppg) Avg 1,300 Depth in / out Tools Coal Gvl API FL 5.6 2-2-WT-A-E-In-No-TD Cor Solids 6.0 202 pH Condition 40.0 YP 1 9.45 (lb/100ft2) 160' 3690' 3530' LSND Hycalog SKHI716 (current) 3674' Casing Summary Lst 40 3690' Cht Lithology (%) 13.375 8249' Ss Job No.: 16 11-Sep-2012 24:00Time: Report #: Date: 11939' 11939' 0' Total Charges: ENI Petroleum Chlorides SP10-FN5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009650301 Customer: Well: Avg MWD Summary Depth 11939' to 11939' Rig: ShClystCly 60 29.30 WOB 2 12 160' 49 EVAMAR Weight TFA 20" Make 13 mg/l Rig Activity: $2,810.00 Current Pump & Flow Data: Current Depth: 24 Hour Progress: $42,930.00 Ross/Wimmer/BuchananReport For: Depth Mud Type Yesterday's Depth: 799 SPP (psi) 9.80 (ppb Eq) Gallons/stroke Max @ ft PV 17.0 16" Backream 1100 Size Daily Charges: Flow In (gpm) Flow In (spm) Hours Gas Summary 1.117 12 Smith XR+ Mill Tooth Mud Data @ % MBT ROP (ft/hr) Bit Type Silt Siltst 11939' 96%4.23 Tuff Footage 22.0 Grade Area: Location: ROP Set AtSize 178.9 X-65 Bit # Current in cP *10000 units = 100% Gas In Air 0 Background 0 24 hr Recap: 3 Trip BROOH at drill rate from 7182' to 3630' as hole dictated. 900 gpm, 1730 psi and 140 rpm. Monitor well. Static. (max) Maximum DepthUnits* 00000 0 0 0 md. 0' Average 0 000 0 C-5iC-4nC-1 0 Minimum C-4iC-2 (max) Chromatograph (ppm) 0 0 A.Paul Kalenuik 0 0 Report By: Continue BROOH. Backream to 2976' at 900 gpm. Reduce to 800 gpm to 1762'. 907-685-0772Unit Phone: C-3 0 0 0 0 C-5n (current) Logging Engineers:A.Paul Kalenuik/ Brad Causey Connection 0 0 . . Density (ppg)Viscosity out (sec/qt) ROP Set AtSize 178.9 X-65 Bit # Current in cP Area: Location: l-80 22.0 Grade Tuff Footage ROP (ft/hr) Bit Type Silt Siltst 11939' @ % MBT Flow In (spm) Hours Gas Summary 1.117 12 Smith XR+ Mill Tooth Mud Data PV 18.0 16" Run 9 5/8" Csg Size Daily Charges: Flow In (gpm) Depth Mud Type Yesterday's Depth: SPP (psi) 9.70 (ppb Eq) Gallons/stroke Max @ ft Current Pump & Flow Data: Current Depth: 24 Hour Progress: $46,740.00 Ross/Wimmer/BuchananReport For: Make 13 mg/l Rig Activity: $3,810.00 29.30 WOB 2 21 160' 46 EVAMAR Weight TFA 20" ShClystCly 60 Customer: Well: Avg MWD Summary Depth 11939' to 11939' Rig: Total Charges: ENI Petroleum Chlorides SP10-FN5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009650301Job No.: 17 12-Sep-2012 24:00Time: Report #: Date: 11939' 11939' 0' Ss 40 3690' Cht Lithology (%) 13.375 8249' (current) 40.03674' Casing Summary Lst YP 1 9.40 (lb/100ft2) 160' 3690' 3530' LSND Hycalog SKHI716 Condition 40.0 Coal Gvl API FL 5.6 2-2-WT-A-E-In-No-TD Cor Solids 6.0 202 pH ml/30min RPM 11939' ECD (ppg) Avg 1,000 Depth in / out Tools 3-2-BT-N-I-CT-TD Min Max 12.25 42.30 *10000 units = 100% Gas In Air Logging Engineers:A.Paul Kalenuik/ Brad Causey Connection 0 0 C-3 0 0 0 0 C-5n (current) Report By: Flush Stack. R/U Tesco for 9.625" csg run. "Float" csg to 815'. Repair pipe skate. Continue to run casing to 3012' at time of report. 907-685-0772Unit Phone:A.Paul Kalenuik 0 0 (max) Chromatograph (ppm) 0 0 C-1 0 Minimum C-4iC-2 0 C-5iC-4n 000 0 0 md. 0' Average 00 00000 Units*Depth Maximum 0 24 hr Recap: 0 Trip Backream from 1762' to 916'. CBU. Monitor well. Static POH w/elevators to 262'. L/D BHA. Change rams and test. (max) 0 Background . . Density (ppg)Viscosity out (sec/qt) Min Max 12.25 42.30 ml/30min RPM 11939' ECD (ppg) Avg 1,100 Depth in / out Tools 3-2-BT-N-I-CT-TD Coal Gvl API FL 5.9 2-2-WT-A-E-In-No-TD Cor Solids 6.1 202 pH Condition 40.0 YP 1 9.40 (lb/100ft2) 160' 3690' 3530' LSND Hycalog SKHI716 (current) 40.03674' Casing Summary Lst 40 3690' Cht Lithology (%) 13.375 8249' Ss Job No.: 18 13-Sep-2012 24:00Time: Report #: Date: 11939' 11939' 0' Total Charges: ENI Petroleum Chlorides SP10-FN5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009650301 Customer: Well: Avg MWD Summary Depth 11939' to 11939' Rig: ShClystCly 60 29.30 WOB 2 11 160' 47 EVAMAR Weight TFA 20" Make 13 mg/l Rig Activity: $2,810.00 Current Pump & Flow Data: Current Depth: 24 Hour Progress: $49,550.00 Ross/Wimmer/BuchananReport For: Depth Mud Type Yesterday's Depth: SPP (psi) 9.60 (ppb Eq) Gallons/stroke Max @ ft PV 18.0 16" Circ & Cond Size Daily Charges: Flow In (gpm) Flow In (spm) Hours Gas Summary 1.117 11 Smith XR+ Mill Tooth Mud Data @ % MBT ROP (ft/hr) Bit Type Silt Siltst 11939' Tuff Footage 22.0 Grade Area: Location: l-80 ROP Set AtSize 178.9 X-65 Bit # Current in cP *10000 units = 100% Gas In Air 0 Background 0 24 hr Recap: 0 Trip Continue to run 9 5/8" csg F/3012' MD to 11919'. Calculated displacement observed. Rig up t "fill pipe" thru choke (max) Maximum DepthUnits* 00000 0 0 0 md. 0' Average 0 000 0 C-5iC-4nC-1 0 Minimum C-4iC-2 (max) Chromatograph (ppm) 0 0 A.Paul Kalenuik 0 0 Report By: with Cmt. Head. Fill pipe @ 3 bbls /min per fill up plan. It took 902 bbls to fill pipe. Load cement plugs. Total LSND losses: 56 bbls. 907-685-0772Unit Phone: C-3 0 0 0 0 C-5n (current) Logging Engineers:A.Paul Kalenuik/ Brad Causey Connection 0 0 . . Density (ppg)Viscosity out (sec/qt) Min Max 12.25 42.30 ml/30min RPM 11939' ECD (ppg) Avg 1,200 Depth in / out Tools 3-2-BT-N-I-CT-TD Coal Gvl API FL 6.0 2-2-WT-A-E-In-No-TD Cor Solids 6.0 202 pH Condition 40.0 YP 1 9.50 (lb/100ft2) 160' 3690' 3530' LSND Hycalog SKHI716 (current) 40.03674' Casing Summary Lst 40 3690' Cht Lithology (%) 13.375 8249' Ss Job No.: 19 14-Sep-2012 24:00Time: Report #: Date: 11939' 11939' 0' Total Charges: ENI Petroleum Chlorides SP10-FN5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009650301 Customer: Well: Avg MWD Summary Depth 11939' to 11939' Rig: ShClystCly 60 29.30 WOB 2 18 160' 58 EVAMAR Weight TFA 20" Make 13 mg/l Rig Activity: $2,810.00 Current Pump & Flow Data: Current Depth: 24 Hour Progress: $52,360.00 Ross/Wimmer/BuchananReport For: Depth Mud Type Yesterday's Depth: SPP (psi) 9.40 (ppb Eq) Gallons/stroke Max @ ft PV 16.0 16" N/U BOPE's Size Daily Charges: Flow In (gpm) Flow In (spm) Hours Gas Summary 1.117 11 Smith XR+ Mill Tooth Mud Data @ % MBT ROP (ft/hr) Bit Type Silt Siltst 11939' Tuff Footage 22.0 Grade Area: Location: l-80 ROP Set AtSize 178.9 X-65 Bit # Current in cP *10000 units = 100% Gas In Air 5 bbl loss while cementing. Pump 20 bbls LSND for injectivity test. Cut casing and install packoff. N/U BOP stack. 0 Background 0 24 hr Recap: 0 Trip Circ 9 5/8" at 11919 at .5 bpm and 420 psi and stage up to 7 bpm and 500 psi. 21,500 strokes circ. 30 bbl loss while (max) Maximum DepthUnits* 00000 0 0 0 md. 0' Average 0 000 0 C-5iC-4nC-1 0 Minimum C-4iC-2 (max) Chromatograph (ppm) 0 0 A.Paul Kalenuik 0 0 Report By: circulating. Cement job : 70 bbls 10.5 lb/gal MudPush and 227 bbls 12.5 lb/gal cement. Chase w/LSND and bump plug at 885 bbl. 907-685-0772Unit Phone: C-3 0 0 0 0 C-5n (current) Logging Engineers:A.Paul Kalenuik/ LeighAnn Rasher Connection 0 0 . . Density (ppg)Viscosity out (sec/qt) ROP Set AtSize 178.9 X-65 Bit # Current in cP Area: Location: l-80 22.0 Grade Tuff Footage ROP (ft/hr) Bit Type Silt Siltst 11939' @ % MBT Flow In (spm) Hours Gas Summary 1.117 12 Smith XR+ Mill Tooth Mud Data PV 16.0 16" Testing BOP's Size Daily Charges: Flow In (gpm) Depth Mud Type Yesterday's Depth: SPP (psi) 9.40 (ppb Eq) Gallons/stroke Max @ ft Current Pump & Flow Data: Current Depth: 24 Hour Progress: $55,770.00 Ross/Wimmer/BuchananReport For: Make 13 mg/l Rig Activity: $3,410.00 29.30 WOB 2 17 160' 58 EVAMAR Weight TFA 20" ShClystCly 60 Customer: Well: Avg MWD Summary Depth 11939' to 11939' Rig: Total Charges: ENI Petroleum Chlorides SP10-FN5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009650301Job No.: 20 15-Sep-2012 24:00Time: Report #: Date: 11939' 11939' 0' Ss 40 3690' Cht Lithology (%) 13.375 8249' (current) 40.03674' Casing Summary Lst YP 1 9.40 (lb/100ft2) 160' 3690' 3530' LSND Hycalog SKHI716 Condition 40.0 Coal Gvl API FL 6.0 2-2-WT-A-E-In-No-TD Cor Solids 6.0 202 pH ml/30min RPM 11939' ECD (ppg) Avg 1,200 Depth in / out Tools 3-2-BT-N-I-CT-TD Min Max 12.25 42.30 *10000 units = 100% Gas In Air Logging Engineers:A.Paul Kalenuik/ LeighAnn Rasher Connection 0 0 C-3 0 0 0 0 C-5n (current) Report By: P/U 4.5" DP. R/u and begin testing BOP per AOGCC requirement. Begin to "Move" and relocate WIF per move plan. 907-685-0772Unit Phone:A.Paul Kalenuik 0 0 (max) Chromatograph (ppm) 0 0 C-1 0 Minimum C-4iC-2 0 C-5iC-4n 000 0 0 md. 0' Average 00 00000 Units*Depth Maximum 0 24 hr Recap: 0 Trip Finish N/U BOP stack. Perform "Body " test. Freeze protect 13 3/8" x 9 5/8" Annulus w/ 219 bbls of diesel. (max) 0 Background . . Density (ppg)Viscosity out (sec/qt) ECD (ppg) Tools API FL Depth 11939'to11939' Avg Min Max 11939'LSND/FAZEPRO Depth Mud Type YP Cor Solids (lb/100ft2) 3.582.75 Mud (lb/bbl)ml/30min 60 Cht Silt Siltst 40 HYDRIL Ss Lst EVAMAR Make 9.40 1.8 17 WOB 21 16-Sep-2012 24:00:00Time: Report #: Date: AK-AM-0009649170 Customer: Well: Avg 1258 PVOil / Water Footage ENI Petroleum SI25-N2 Spy Island 24 hr Max North Slope Lithology (%) (current) ShClyst 40.0 Weight Size 160' 3674' 11939' TuffGvlCoal $3,410.00 9.9 Alkal Lime $59,180.00 Report For: Ratio cP Keener/Wimmer/Buchanan Flow In (gpm) Total Charges: 11939' 11939' 0' Current Depth: 24 Hour Progress: Washing downRig Activity: Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 4.23 Flow In (spm) MWD Summary Bit Type TFA Cly Gas Summary RPM Hours Depth in / out % Casing Summary Condition in Mud Data @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) Area: Location: 96% SPP (psi) Gallons/stroke ROP Set AtSize 178.9 X-65 Bit # L-80 Grade L-80 40.0 20" 13 3/8" 9 5/8" *10000 units = 100% Gas In Air 0Connection(max) Chromatograph (ppm) 0 24 hr Recap: 0Background Trip 0 0 0 0 0 0 C-4i C-4n C-5n 00 0 0 md. at 9bpm w/1550 psi, 56 rpm. equipment. P/U tools. M/U BHA #4 . Load "Nukes". SHT. RIH to 10900' MD filling pipe every 20 stds. Washdown f/10900' t 10984' Finished testing BOP's per AOGCC requirement. Complete "Move " and relocate WIF per move "Plan". R/D Testing 0 Units* 0 11939'0 0 0 00Minimum Average 00 0 Depth C-2 C-3 0 C-1 0Maximum0 907-685-0772Unit Phone: 0 A Paul KalenuikReport By:Logging Engineers:A Paul Kalenuik/Leigh Rasher (max)(current) C-5i . . Density (ppg)Viscosity out (sec/qt) 20" 13 3/8" 9 5/8" L-80 Grade L-80 40.0 ROP Set AtSize 178.9 X-65 Bit # Area: Location: 96% 541 SPP (psi) Gallons/stroke 3130 @ Yesterday's Depth: 36.0 Rig: Job No.: ROP (ft/hr) Condition in Mud Data Depth in / out % Casing Summary RPM HoursBit Type TFA Cly Gas Summary Current Pump & Flow Data: Max @ ft Current 12286'26.8 4.23 Flow In (spm) MWD Summary Total Charges: 11939' 12150' 211' Current Depth: 24 Hour Progress: Drill AheadRig Activity: Doyon 15 Daily Charges:$9,210.00 8.4 Alkal Lime $68,390.00 Report For: Ratio cP Keener/Wimmer/Buchanan Flow In (gpm) TuffGvlCoal 40.0 Weight Size PDC 160' 3674' 11939' Lithology (%) (current) ShClyst Footage ENI Petroleum SP10-FN5 Spy Island 24 hr Max North Slope 270.0 Customer: Well: Avg 0.902 1247 8.75 211' PVOil / Water 11939' WOB 22 17-Sep-2012 24:00:00Time: Report #: Date: AK-AM-0009649170 9.00 1.8 13 Ss Lst EVAMAR Make 9.40 71.03 10 Cht Silt Siltst 90 HYDRIL YP Cor Solids (lb/100ft2) 3.252.50 Mud (lb/bbl)ml/30min 12150'FAZEPRO Depth Mud Type Depth 12150'to11939' Avg Min MaxECD (ppg) Tools API FL 10.4 *10000 units = 100% Gas In Air Logging Engineers:A Paul Kalenuik/Leigh Rasher (max)(current) C-5i 907-685-0772Unit Phone: 19 A Paul KalenuikReport By: C-1 37Maximum95 1 Depth C-2 C-3 1Minimum Average 41478727 80 11 44195 Units* 12584 12136' Prejob on displace of OBM. Displace to 9.4ppg FazePro. Cut and Slip drill line. Perform LOT. Drill ahead. 14476 md. 44195 240 C-5n 11 C-4i C-4n 78 44 12 1 35 130 Trip N/A 24 hr Recap: 22Background N/AConnection(max) Chromatograph (ppm) . . Density (ppg)Viscosity out (sec/qt) ECD (ppg) Tools API FL 11.2 Depth 13710'to12150' 11.50 Avg Min Max 13710'FAZEPRO Depth Mud Type YP Cor Solids (lb/100ft2) 3.122.40 Mud (lb/bbl)ml/30min 3 0 Cht Silt Siltst 100 HYDRIL Ss Lst EVAMAR Make 9.40 165.09.00 64/36 21 11939' WOB 23 18-Sep-2012 24:00:00Time: Report #: Date: AK-AM-0009649170 Customer: Well: Avg 0.902 1549 8.75 1560' PVOil / Water Footage ENI Petroleum SP10-FN5 Spy Island 24 hr Max North Slope 356.0 Lithology (%) (current) ShClyst 40.0 Weight Size PDC 160' 3674' 11939' TuffGvlCoal $3,410.00 10.5 Alkal Lime $71,800.00 Report For: Ratio cP Keener/Wimmer/Buchanan Flow In (gpm) Total Charges: 12150' 13710' 1560' Current Depth: 24 Hour Progress: Drill AheadRig Activity: Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 13588'71.9 4.23 Flow In (spm) MWD Summary Bit Type TFA Cly Gas Summary RPM Hours Depth in / out % Casing Summary Condition in Mud Data @ Yesterday's Depth: 152.0 Rig: Job No.: ROP (ft/hr) Area: Location: 96% 556 SPP (psi) Gallons/stroke 3204 ROP Set AtSize 178.9 X-65 Bit # L-80 Grade L-80 40.0 20" 13 3/8" 9 5/8" *10000 units = 100% Gas In Air N/AConnection(max) Chromatograph (ppm) N/A 24 hr Recap: 59Background Trip 391 253 158 79 1 149 C-4i C-4n C-5n 11 124934 693 md. No losses to formation. Continue drilling from 12150' MD to 13710' MD at 160 RPM. Max gas for today was 1107 units at 13630'. . 561.50 Units* 16 13632'1107 113 252 11Minimum Average 4543711 1 Depth C-2 C-3 1 C-1 156Maximum312 907-685-0772Unit Phone: 94 A Paul KalenuikReport By:Logging Engineers:A Paul Kalenuik/Leigh Rasher (max)(current) C-5i . . Density (ppg)Viscosity out (sec/qt) 20" 13 3/8" 9 5/8" L-80 Grade L-80 40.0 ROP Set AtSize 178.9 X-65 Bit # Area: Location: 96% 556 SPP (psi) Gallons/stroke 3204 @ Yesterday's Depth: 152.0 Rig: Job No.: ROP (ft/hr) Condition in Mud Data Depth in / out % Casing Summary RPM HoursBit Type TFA Cly Gas Summary Current Pump & Flow Data: Max @ ft Current 13588'71.9 4.23 Flow In (spm) MWD Summary Total Charges: 13710' 15920' 2210' Current Depth: 24 Hour Progress: Drill AheadRig Activity: Doyon 15 Daily Charges:$3,410.00 12.1 Alkal Lime $75,210.00 Report For: Ratio cP Keener/Wimmer/Buchanan Flow In (gpm) TuffGvlCoal 40.0 Weight Size PDC 160' 3674' 11939' Lithology (%) (current) ShClyst Footage ENI Petroleum SP10-FN5 Spy Island 24 hr Max North Slope 356.0 Customer: Well: Avg 0.902 1343 8.75 3981' PVOil / Water 11939' WOB 24 19-Sep-2012 24:00:00Time: Report #: Date: AK-AM-0009649170 57.00 70/30 18 Ss Lst EVAMAR Make 9.45 160.03 0 Cht Silt Siltst 100 HYDRIL YP Cor Solids (lb/100ft2) 3.952.45 Mud (lb/bbl)ml/30min 15920'FAZEPRO Depth Mud Type Depth 15920'to13710' 11.45 Avg Min MaxECD (ppg) Tools API FL 19.0 *10000 units = 100% Gas In Air Logging Engineers:A Paul Kalenuik/Leigh Rasher (max)(current) C-5i 907-685-0772Unit Phone: 153 A Paul KalenuikReport By: C-1 256Maximum497 1 Depth C-2 C-3 31Minimum Average 7474719153 388 11 5136 Units* 14 15310' drilling. Max gas of 5025 units. No losses to formation. cont. drilling ahead f/13,710 to 15,920. WOB 8-10, 160 RPM, 550 gpm, 3320 psI. Encountered connection Gas during 1461 md. 328930 1045 C-5n 11 C-4i C-4n 321 206 123 1 204 577 Trip N/A 24 hr Recap: 57Background N/AConnection(max) Chromatograph (ppm) . . Density (ppg)Viscosity out (sec/qt) ECD (ppg) Tools API FL 19.0 Depth 17257'to15920' 11.9411.0211.64 Avg Min Max 17257'FAZEPRO Depth Mud Type YP Cor Solids (lb/100ft2) 3.712.85 Mud (lb/bbl)ml/30min 3 0 Cht Silt Siltst 100 HYDRIL Ss Lst EVAMAR Make 9.40 162.057.00 70/30 19 11939' WOB 25 20-Sep-2012 24:00:00Time: Report #: Date: AK-AM-0009649170 Customer: Well: Avg 0.902 1333 8.75 PVOil / Water Footage ENI Petroleum SP10-FN5 Spy Island 24 hr Max North Slope 825.0 Lithology (%) (current) ShClyst 40.0 Weight Size PDC 160' 3674' 11939' TuffGvlCoal $3,410.00 9.2 Alkal Lime $77,620.00 Report For: Ratio cP Keener/Wimmer/Buchanan Flow In (gpm) Total Charges: 15920' 17257' 1337' Current Depth: 24 Hour Progress: Drill AheadRig Activity: Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 17256'63.1 4.23 Flow In (spm) MWD Summary Bit Type TFA Cly Gas Summary RPM Hours Depth in / out % Casing Summary Condition in Mud Data @ Yesterday's Depth: 140.0 Rig: Job No.: ROP (ft/hr) Area: Location: 96% 556 SPP (psi) Gallons/stroke 3204 ROP Set AtSize 178.9 X-65 Bit # L-80 Grade L-80 40.0 20" 13 3/8" 9 5/8" *10000 units = 100% Gas In Air N/AConnection(max) Chromatograph (ppm) N/A 24 hr Recap: 19Background Trip 448 174 117 76 1 119 C-4i C-4n C-5n 11 117931 726 md. No losses to formation. Cont. drilling ahead F/15,920' MD to 17,257' MD. Encountered connection Gas during drilling, Max Gas of 1078 units. 198 Units* 16 16385'1098 93 314 11Minimum Average 4729650 1 Depth C-2 C-3 17 C-1 196Maximum377 907-685-0772Unit Phone: 113 A Paul KalenuikReport By:Logging Engineers:A Paul Kalenuik/Leigh Rasher (max)(current) C-5i . . Density (ppg)Viscosity out (sec/qt) 20" 13 3/8" 9 5/8" L-80 Grade L-80 40.0 ROP Set AtSize 178.9 X-65 Bit # Area: Location: 96% 537 SPP (psi) Gallons/stroke 3229 @ Yesterday's Depth: 0.0 Rig: Job No.: ROP (ft/hr) Condition in Mud Data Depth in / out % Casing Summary RPM HoursBit Type TFA Cly Gas Summary Current Pump & Flow Data: Max @ ft Current 17926'46.4 4.23 Flow In (spm) MWD Summary Total Charges: 17257' 18339' 1082' Current Depth: 24 Hour Progress: Drill AheadRig Activity: Doyon 15 Daily Charges:$3,410.00 9.1 Alkal Lime $81,030.00 Report For: Ratio cP Keener/Wimmer/Buchanan Flow In (gpm) TuffGvlCoal 40.0 Weight Size PDC 160' 3674' 11939' Lithology (%) (current) ShClyst Footage ENI Petroleum SP10-FN5 Spy Island 24 hr Max North Slope 297.0 Customer: Well: Avg 0.902 1345 8.75 PVOil / Water 11939' WOB 26 21-Sep-2012 24:00:00Time: Report #: Date: AK-AM-0009649170 57.00 69/31 19 Ss Lst EVAMAR Make 9.45 162.03 0 Cht Silt Siltst 100 HYDRIL YP Cor Solids (lb/100ft2) 2.802.15 Mud (lb/bbl)ml/30min 18339'FAZEPRO Depth Mud Type Depth 18339'to17257' 11.7711.3111.55 Avg Min MaxECD (ppg) Tools API FL 8.0 *10000 units = 100% Gas In Air Logging Engineers:A Paul Kalenuik/Leigh Rasher (max)(current) C-5i 907-685-0772Unit Phone: 106 A Paul KalenuikReport By: C-1 196Maximum392 1 Depth C-2 C-3 21Minimum Average 4930967123 348 11 965 Units* 22 17941' high inclination. Decision was made to go back to bottom and control drill with light weight. Drilling continued to 18,339' 550 gpm, cont. drilling ahead F/17,257' to 18,299' at which time theD.S. was P/U to 18,251' and as perDD begin troughing due to 383 md. 3680 psi, 160 RPM, WOB 8-10 and 17-18 TRQ as of midnight. 125046 779 C-5n 11 C-4i C-4n 221 148 84 1 120 495 Trip N/A 24 hr Recap: 32Background N/AConnection(max) Chromatograph (ppm) . . Density (ppg)Viscosity out (sec/qt) 20" 13 3/8" 9 5/8" BTC L-80 Grade L-80 40.0 ROP Set AtSize 178.9 X-65 Bit # Area: Location: 96% 529 125 SPP (psi) Gallons/stroke 3528 @ Yesterday's Depth: 122.3 Rig: Job No.: ROP (ft/hr) Condition in Mud Data Depth in / out % Casing Summary RPM HoursBit Type TFA Cly Gas Summary Current Pump & Flow Data: Max @ ft Current 19188'42.6 4.23 Flow In (spm) MWD Summary Total Charges: 18339' 19290' 951' Current Depth: 24 Hour Progress: Drill AheadRig Activity: Doyon 15 Daily Charges:$4,410.00 9.2 Alkal Lime $85,440.00 Report For: Ratio cP Keener/Simonson/Buchanan Flow In (gpm) TuffGvlCoal 68.0 Weight Size Hughes QD506X PDC 160' 3674' 11919' Lithology (%) (current) ShClyst Footage ENI Petroleum SP10-FN5 Spy Island 24 hr Max North Slope 651.2 Customer: Well: Avg 0.902 1344 8.75 PVOil / Water 11939' WOB 27 22-Sep-2012 24:00:00Time: Report #: Date: AK-AM-0009649170 69/31 16 Ss - Lst EVAMAR Make 9.45 3 10 Cht Silt Siltst 90 HYDRIL YP Cor Solids (lb/100ft2) 3.382.60 Mud (lb/bbl)ml/30min 19001'FAZEPRO Depth Mud Type Depth 19290'to18339' 12.0011.2211.60 Avg Min MaxECD (ppg) Tools Xceed675, PeriScope675, TeleScope675, adnVISION675 API FL *10000 units = 100% Gas In Air Logging Engineers:Leigh Ann Rasher/Brad Causey (max)(current) C-5i 907-685-0772Unit Phone: 59 Leigh Ann RasherReport By: C-1 112Maximum225 0 Depth C-2 C-3 283Minimum Average 191425248 200 2219059' 682 Units* 21 18431' encountering drilling breaks and concretions. Max gas observed is 682 units at 18,431' MD. Lithology consist of Sst. Cont. to drill ahead from 18,339' MD to 19,290' MD 120 RPM, 550 gpm, 3,610 psi, 10K WOB, and 18K torque. Still 151 md. 75346 463 C-5n 03 C-4i C-4n 78 56 35 4 59 290 Trip N/A 24 hr Recap: 56Background N/AConnection(max) Chromatograph (ppm) . . Density (ppg)Viscosity out (sec/qt) ECD (ppg) Tools Xceed675, PeriScope675, TeleScope675, adnVISION675 API FL Depth 20874'to19290' 12.0611.99 Avg Min Max 20770'FAZEPRO Depth Mud Type YP Cor Solids (lb/100ft2) 4.423.40 Mud (lb/bbl)ml/30min 3 0 Cht Silt Siltst 100 HYDRIL Ss - Lst EVAMAR Make 9.50 67/33 17 11939' WOB 28 23-Sep-2012 24:00:00Time: Report #: Date: AK-AM-0009649170 Customer: Well: Avg 0.902 1446 8.75 PVOil / Water Footage ENI Petroleum SP10-FN5 Spy Island 24 hr Max North Slope 312.4 Lithology (%) (current) ShClyst 68.0 Weight Size Hughes QD506X PDC 160' 3674' 11919' TuffGvlCoal $3,410.00 8.8 Alkal Lime $88,850.00 Report For: Ratio cP Keener/Simonson/Buchanan Flow In (gpm) Total Charges: 19290' 20874' 1584' Current Depth: 24 Hour Progress: Drill AheadRig Activity: Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 19300'69.6 4.23 Flow In (spm) MWD Summary Bit Type TFA Cly Gas Summary RPM Hours Depth in / out % Casing Summary Condition in Mud Data @ Yesterday's Depth: 0.0 Rig: Job No.: ROP (ft/hr) Area: Location: 96% 535 126 SPP (psi) Gallons/stroke 3771 ROP Set AtSize 178.9 X-65 Bit # L-80 Grade L-80 40.0 20" 13 3/8" 9 5/8" BTC *10000 units = 100% Gas In Air N/AConnection(max) Chromatograph (ppm) N/A 24 hr Recap: 44Background Trip 353 151 97 73 20 110 C-4i C-4n C-5n 2126 85505 549 md. MD. Drill ahead from 19290' MD to 20874' Md; 140 RPM, 550 gpm, 3790 psi, 10-15K torque. Max gas 826 units @ 19550' 288 Units* 21 19550'826 20716' 85 258 105Minimum Average 4323627 0 Depth C-2 C-3 236 C-1 155Maximum301 907-685-0772Unit Phone: 83 Leigh Ann RasherReport By:Logging Engineers:Leigh Ann Rasher/Brad Causey (max)(current) C-5i . . Density (ppg) Viscosity out (sec/qt) 20" 13 3/8" 9 5/8" BTC L-80 Grade L-80 40.0 ROP Set AtSize 178.9 X-65 Bit # Area: Location: 96% 545 128 SPP (psi) Gallons/stroke 3272 @ Yesterday's Depth: 0.0 Rig: Job No.: ROP (ft/hr) Condition in Mud Data Depth in / out % Casing Summary RPM HoursBit Type TFA Cly Current Pump & Flow Data: Max @ ft Current 20878'20.9 4.23 Flow In (spm) MWD Summary Total Charges: 20874' 21118' 244' Current Depth: 24 Hour Progress: BROOHRig Activity: Doyon 15 Daily Charges:$3,410.00 8.9 Alkal Lime $92,260.00 Report For: Ratio cP Keener/Simonson/Buchanan Flow In (gpm) TuffGvlCoal 68.0 Weight Size Hughes QD506X PDC 160' 3674' 11919' Lithology (%) (current) ShClyst Footage ENI Petroleum SP10-FN5 Spy Island 24 hr Max North Slope 265.6 Customer: Well: Avg 0.902 1346 8.75 PVOil / Water 11939' WOB 29 24-Sep-2012 24:00:00Time: Report #: Date: AK-AM-0009650301 68/32 16 Ss - Lst EVAMAR Make 9.45 3 Cht Silt Siltst HYDRIL YP Cor Solids (lb/100ft2) 3.512.70 Mud (lb/bbl)ml/30min 21118' FAZEPRO Depth Mud Type Depth 21118'to20874' 12.23 Avg Min MaxECD (ppg) Tools Xceed675, PeriScope675, TeleScope675, adnVISION675 API FL * 10000 units = 100% Gas In Air Logging Engineers:Leigh Ann Rasher/Brad Causey (max)(current) C-5i 907-685-0772Unit Phone: 50 Leigh Ann RasherReport By: C-1 82Maximum144 0 Depth C-2 C-3 503Minimum Average 341554964 117 151020975' 355 Units* 30 20954' and BROOH per K&M. Slight packing off noticed around 18974' MD, slowed pumps and drop back down to ream through. Max gas Cont to drill ahead from 20874' MD to TD at 21118' MD at 540 gpm, 140 RPM, 10-16K WOB and 18-22 torque. Circ B/U 142 md observed the past 24 hours is 355 units at 19550' MD. 38593 257 Gas Summary C-5n 1728 C-4i C-4n 108 73 58 27 83 154 Trip 185 24 hr Recap: N/ABackground N/AConnection(max) Chromatograph (ppm) . . Density (ppg) Viscosity out (sec/qt) ECD (ppg) Tools Xceed675, PeriScope675, TeleScope675, adnVISION675 API FL Depth 21118'to21118' Avg Min Max 21118' FAZEPRO Depth Mud Type YP Cor Solids (lb/100ft2) 3.903.00 Mud (lb/bbl)ml/30min 3 Cht Silt Siltst HYDRIL Ss - Lst EVAMAR Make 9.45 68/32 14 11939' 21118' WOB 30 25-Sep-2012 24:00:00Time: Report #: Date: AK-AM-0009650301 Customer: Well: Avg 0.902 1345 8.75 9179' PVOil / Water Footage ENI Petroleum SP10-FN5 Spy Island 24 hr Max North Slope Lithology (%) (current) ShClyst 68.0 Weight Size Hughes QD506X PDC 160' 3674' 11919' TuffGvlCoal $3,410.00 9.4 Alkal Lime $95,670.00 Report For: Ratio cP Keener/Simonson/Buchanan Flow In (gpm) Total Charges: 21118' 21118' 0' Current Depth: 24 Hour Progress: POOHRig Activity: Doyon 15 Daily Charges: Current Pump & Flow Data: Max @ ft Current 4.23 Flow In (spm) MWD Summary Bit Type TFA Cly RPM Hours Depth in / out % Casing Summary Condition in Mud Data @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) Area: Location: 96% SPP (psi) Gallons/stroke ROP Set AtSize 178.9 X-65 Bit # L-80 Grade L-80 40.0 20" 13 3/8" 9 5/8" BTC * 10000 units = 100% Gas In Air N/AConnection(max) Chromatograph (ppm) 13 24 hr Recap: N/ABackground Trip 0 0 0 0 0 0 C-4i C-4n C-5n 00 00 Gas Summary md Circ 2X B/U and POOH on elevators. from 12195' MD to 9759' MD. Circ B/U. C/O saver sub and wash pipe swivel. Cont to BROOH from 9759' MD to 6500' MD per K&M. Cont. to BROOH from 15600' MD to 12195' MD @ 550 gpm, 140 RPM, and 3420 psi. Service rig and cont to BROOH Units* 0 0 00Minimum Average 00 0 Depth C-2 C-3 0 C-1 0Maximum0 907-685-0772Unit Phone: 0 Leigh Ann RasherReport By:Logging Engineers:Leigh Ann Rasher/Brad Causey (max)(current) C-5i . . Density (ppg) Viscosity out (sec/qt) 20" 13 3/8" 9 5/8" BTC L-80 Grade L-80 40.0 ROP Set AtSize 178.9 X-65 Bit # Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) Condition in Mud Data Depth in / out % Casing Summary RPM HoursBit Type TFA Cly Current Pump & Flow Data: Max @ ft Current 4.23 Flow In (spm) MWD Summary Total Charges: 21118' 21118' 0' Current Depth: 24 Hour Progress: RIH 5.5" LinerRig Activity: Doyon 15 Daily Charges:$2,810.00 8.9 Alkal Lime $98,480.00 Report For: Ratio cP Keener/Simonson/Buchanan Flow In (gpm) TuffGvlCoal 68.0 Weight Size Hughes QD506X PDC 160' 3674' 11919' Lithology (%) (current) ShClyst Footage ENI Petroleum SP10-FN5 Spy Island 24 hr Max North Slope Customer: Well: Avg 0.902 1245 8.75 9179' PVOil / Water 11939' 21118' WOB 31 26-Sep-2012 24:00:00Time: Report #: Date: AK-AM-0009650301 68/32 15 Ss - Lst EVAMAR Make 9.45 3 Cht Silt Siltst HYDRIL YP Cor Solids (lb/100ft2) 3.903.00 Mud (lb/bbl)ml/30min 21118' FAZEPRO Depth Mud Type Depth to Avg Min MaxECD (ppg) Tools API FL * 10000 units = 100% Gas In Air Logging Engineers:Leigh Ann Rasher/Brad Causey (max)(current) C-5i 907-685-0772Unit Phone: 0 Leigh Ann RasherReport By: C-1 0Maximum0 0 Depth C-2 C-3 0Minimum Average 000 0 00 Units* equip. M/U ECC nose guide show w/ Baker Lok and RIH w/ 5.5" slotted liner. Cont to POOH on elevators from 3300' to HWDP. L/D BHA#4. C/O saver sub to HT 525. Cut and slip drill line. R/U csg md 00 Gas Summary C-5n 00 C-4i C-4n 0 0 0 0 0 0 Trip N/A 24 hr Recap: N/ABackground N/AConnection(max) Chromatograph (ppm) . . Density (ppg) Viscosity out (sec/qt) 20" 13 3/8" 9 5/8" BTC L-80 Grade L-80 40.0 ROP Set AtSize 178.9 X-65 Bit # Area: Location: 96% SPP (psi) Gallons/stroke @ Yesterday's Depth: Rig: Job No.: ROP (ft/hr) Condition in Mud Data Depth in / out % Casing Summary RPM HoursBit Type TFA Cly Current Pump & Flow Data: Max @ ft Current 4.23 Flow In (spm) MWD Summary Total Charges: 21118' 21118' 0' Current Depth: 24 Hour Progress: L/D 5" DPRig Activity: Doyon 15 Daily Charges:$2,810.00 Alkal Lime $101,290.00 Report For: Ratio cP Perry/Simonson/Buchanan Flow In (gpm) TuffGvlCoal 68.0 Weight Size Hughes QD506X PDC 160' 3674' 11919' Lithology (%) (current) ShClyst Footage ENI Petroleum SP10-FN5 Spy Island 24 hr Max North Slope Customer: Well: Avg 0.902 23 8.75 9179' PVOil / Water 11939' 21118' WOB 32 27-Sep-2012 24:00:00Time: Report #: Date: AK-AM-0009650301 103.90 Ss Lst EVAMAR Make 9.00 140.03 Cht Silt Siltst HYDRIL YP 1-1-CT-A-X-IN-NO-TD Cor Solids (lb/100ft2)Mud (lb/bbl)ml/30min 21118' FAZEPRO Depth Mud Type Depth to Avg Min MaxECD (ppg) Tools API FL 10.0 * 10000 units = 100% Gas In Air Logging Engineers:Leigh Ann Rasher/Brad Causey (max)(current) C-5i 907-685-0772Unit Phone: 0 Leigh Ann RasherReport By: C-1 0Maximum0 0 Depth C-2 C-3 0Minimum Average 000 0 00 Units* set hanger per Baker Rep. Release & test packer to 1500 psi. Displace hole to 9.00 ppg brine. POOH and L/D 5" DP. Cont RIH w/ 5.5" liner. R/D casing equip & P/U liner hanger. RIH w/ 5" DP to bottom. P/U to set depth of 21076' MD and md 00 Gas Summary C-5n 00 C-4i C-4n 0 0 0 0 0 0 Trip N/A 24 hr Recap: N/ABackground N/AConnection(max) Chromatograph (ppm) . . Density (ppg) Viscosity out (sec/qt) Min Max ml/30min RPM ECD (ppg) Avg 92,000 Depth in / out Tools Coal Gvl API FL 1-1-CT-A-X-IN-NO-TD Cor SolidspH Condition 140.0 YP 3 9.00 (lb/100ft2) L-80 11939' 21118' 9179' FazePro (current) 68.03674' Casing Summary Lst 40.0 Cht Lithology (%) 11919' 13 3/8" 9 5/8" Ss Job No.: 33 28-Sep-2012 24:00Time: Report #: Date: 21118' 21118' 0' Total Charges: ENI Petroleum Chlorides SP10-FN5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009650301 Customer: Well: Avg MWD Summary Depth to Rig: ShClystCly 103.90 WOB 160' 23 EVAMAR Weight TFA 20" Make mg/l Rig Activity: $3,810.00 Current Pump & Flow Data: Current Depth: 24 Hour Progress: $114,219.00 Perry/Simonson/BuchananReport For: Depth Mud Type Yesterday's Depth: SPP (psi) (ppb Eq) Gallons/stroke Max @ ft PV 8.75 Testing BOP Size Daily Charges: Flow In (gpm) Flow In (spm) Hours 0.902 Hughes QD506X PDC Mud Data @ % MBT ROP (ft/hr) Bit Type Silt Siltst 21118' BTC Tuff HYDRIL Footage 10.0 Grade Area: Location: L-80 ROP Set AtSize 178.9 X-65 Bit # Current in cP * 10000 units = 100% Gas In Air 0 Background 0 24 hr Recap: 0 Trip Cont to L/D 5" DP. L/D Baker running tool and change out saver sub. RIH 4.5" DP to 9448' MD and POOH. L/D 4.5" DP. (max) Maximum DepthUnits* 00000 00 Gas Summary 0 md 0' Average 0 000 0 C-5iC-4nC-1 0 Minimum C-4iC-2 (max) Chromatograph (ppm) 0 0 Leigh Ann Rasher 0 0 Report By: Pull wear ring and R/U test equip. Test BOP. 907-685-0772Unit Phone: C-3 0 0 0 0 C-5n (current) Logging Engineers:Leigh Ann Rasher/Brad Causey Connection 0 0 . . Density (ppg) Viscosity out (sec/qt) ROP Set AtSize 178.9 X-65 Bit # Current in cP Area: Location: L-80 10.0 Grade Tuff HYDRIL Footage BTC ROP (ft/hr) Bit Type Silt Siltst 21118' @ % MBT Flow In (spm) Hours 0.902 Hughes QD506X PDC Mud Data PV 8.75 M/U ESP Splice Size Daily Charges: Flow In (gpm) Depth Mud Type Yesterday's Depth: SPP (psi) (ppb Eq) Gallons/stroke Max @ ft Current Pump & Flow Data: Current Depth: 24 Hour Progress: $118,029.00 Perry/Simonson/BuchananReport For: Make mg/l Rig Activity: $3,810.00 103.90 WOB 160' 23 EVAMAR Weight TFA 20" ShClystCly Customer: Well: Avg MWD Summary Depth to Rig: Total Charges: ENI Petroleum Chlorides SP10-FN5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009650301Job No.: 34 29-Sep-2012 24:00Time: Report #: Date: 21118' 21118' 0' 9 5/8" Ss 40.0 Cht Lithology (%) 11919' 13 3/8" (current) 68.03674' Casing Summary Lst YP 3 9.00 (lb/100ft2) L-80 11939' 21118' 9179' Brine Condition 140.0 Coal Gvl API FL 1-1-CT-A-X-IN-NO-TD Cor SolidspH ml/30min RPM ECD (ppg) Avg 92,000 Depth in / out Tools Min Max * 10000 units = 100% Gas In Air Logging Engineers:Kori Jo Plowman/Brad Causey Connection 0 0 C-3 0 0 0 0 C-5n (current) Report By: midnight. 907-685-0772Unit Phone:Kori Jo Plowman 0 0 (max) Chromatograph (ppm) 0 0 C-1 0 Minimum C-4iC-2 0 C-5iC-4n 000 0 0 md 0' Average 0 Gas Summary 0 00000 Units*Depth Maximum 0 24 hr Recap: 0 Trip R/D testing equipment from BOP test. R/U Spooling unit and wireline for completion string. Make up ESP splice as of (max) 0 Background . . Density (ppg) Viscosity out (sec/qt) Min Max ml/30min RPM ECD (ppg) Avg 92,000 Depth in / out Tools Coal Gvl API FL 1-1-CT-A-X-IN-NO-TD Cor SolidspH Condition 140.0 YP 3 9.00 (lb/100ft2) L-80 11939' 21118' 9179' Brine (current) 68.03674' Casing Summary Lst 40.0 Cht Lithology (%) 11919' 13 3/8" 9 5/8" Ss Job No.: 35 30-Sep-2012 24:00Time: Report #: Date: 21118' 21118' 0' Total Charges: ENI Petroleum Chlorides SP10-FN5 Spy Island 24 hr Max North Slope Doyon 15 AK-AM-0009650301 Customer: Well: Avg MWD Summary Depth to Rig: ShClystCly 103.90 WOB 160' 23 EVAMAR Weight TFA 20" Make mg/l Rig Activity: $2,810.00 Current Pump & Flow Data: Current Depth: 24 Hour Progress: $120,839.00 Perry/Simonson/BuchananReport For: Depth Mud Type Yesterday's Depth: SPP (psi) (ppb Eq) Gallons/stroke Max @ ft PV 8.75 W/O ESP Splice Size Daily Charges: Flow In (gpm) Flow In (spm) Hours 0.902 Hughes QD506X PDC Mud Data @ % MBT ROP (ft/hr) Bit Type Silt Siltst 21118' BTC Tuff HYDRIL Footage 10.0 Grade Area: Location: L-80 ROP Set AtSize 178.9 X-65 Bit # Current in cP * 10000 units = 100% Gas In Air 0 Background 0 24 hr Recap: 0 Trip RIH 4.5" Tubing and control lines to 7, 862'. Continued to make up ESP Reel and work on splice as of midnight (max) Maximum DepthUnits* 00000 00 Gas Summary 0 md 0' Average 0 000 0 C-5iC-4nC-1 0 Minimum C-4iC-2 (max) Chromatograph (ppm) 0 0 Kori Jo Plowman 0 0 Report By: 907-685-0772Unit Phone: C-3 0 0 0 0 C-5n (current) Logging Engineers:Kori Jo Plowman/Brad Causey Connection 0 0 W E L L N A M E : SP 1 0 - F N 5 LO C A T I O N : Spy Island OP E R A T O R : EN I P e t r o l e u m AR E A : North Slope MU D C O : MI S w a c o ST A T E : Alaska RI G : Do y o n 1 5 SP U D : 31-Aug-12 SP E R R Y J O B : AK - A M - 0 0 0 9 6 5 0 3 0 1 TD : 24-Sep-12 BI T R E C O R D MW D BH A # SD L RU N # Bi t # B i t T y p e B i t Si z e De p t h In ( f t ) De p t h Ou t ( f t ) Fo o t a g e B i t Ho u r s TF A A V G RO P WO B (m a x ) RP M (m a x ) SP P (m a x ) FL O W G P M (m a x ) Bi t G r a d e R e m a r k s 1 1 0 0 1 S m i t h X R + M i l l T o o t h 1 6 " 1 6 0 3 6 9 0 3 5 3 0 2 9 . 3 0 1 . 1 1 7 1 2 0 . 4 22 40 1 3 5 0 6 1 6 2- 2 - W T - A - E - I n - N o - T D Surface TD 4 2 0 0 2 H y c a l o g S K H I 7 1 6 D - E 4 C P D C 1 2 . 2 5 " 3 6 9 0 1 1 9 3 9 8 2 4 9 4 2 . 1 0 0 . 9 6 9 1 9 6 . 0 8 18 0 2 7 0 0 8 7 5 3 - 2 - B T - N - I - C T - T D I n t e r m e d i a t e T D 6 3 0 0 3 H u g h e s Q D 5 0 6 X P D C 8 . 7 5 " 1 1 9 3 9 2 1 1 1 8 9 1 7 9 1 0 3 . 9 0 0 . 9 0 2 8 8 . 3 10 14 0 3 8 5 0 5 5 0 1- 1 - C T - A - X - I N - N O - T D Production TD W E L L N A M E : L O C A T I O N : OP E R A T O R : A R E A : MU D C O : S T A T E : RI G : S P U D : SP E R R Y J O B : T D : Mu d R e c o r d W a t e r B a s e d M u d R e c o r d 16 0 ' t o 3 6 9 0 ' 36 9 0 t o 1 1 9 3 9 ' Da t e D e p t h W t V i s P V Y P G e l s F i l t R6 0 0 / R 3 0 0 / R 2 0 0 / R 1 0 0 / R6 / R 3 Ca k e S o l i d s Oi l / W a t e r Sd P m p H M B T P f / M f C h l o r H a r d R e m a r k s ft - M D p p g s e c l b / 1 0 0 l b / 1 0 0 f t 2 m / 3 0 m R h e o m e t e r 3 2 n d s % v o l % v o l m g / l C a + + 29 - A u g - - - - - - - - - - - - - - - - - - C o n t R i g U p 30 - A u g 1 1 0 8 . 7 0 1 7 0 2 3 3 5 1 9 / 4 1 / 5 4 7 . 0 8 1 / 5 8 / 4 9 / 3 8 / 1 7 / 1 6 3 / - 2 . 0 1 / 9 8 - 0 . 0 5 9 . 3 2 0 . 0 . 0 3 / 1 . 5 0 7 5 0 6 0 D r ill Ahead 31 - A u g 6 2 7 9 . 0 5 1 1 6 1 7 3 9 2 7 / 6 2 / 6 8 5 . 8 7 3 / 5 6 / 4 9 / 3 9 / 2 4 / 2 3 2 / - 4 . 0 1 / 9 6 0 . 1 5 0 . 0 8 9 . 5 1 7 . 5 . 0 5 / 2 . 0 0 3 0 0 0 8 0 D r ill Ahead 1- S e p 2 4 0 4 9 . 4 0 6 5 2 0 2 6 1 8 / 4 6 / 5 1 6 . 0 6 6 / 4 6 / 3 8 / 1 8 / 1 5 / 1 4 3 / - 5 . 5 1 / 9 4 0 . 3 0 0 . 0 5 9 . 5 2 0 . 0 . 0 3 / . 2 0 1 3 0 0 4 0 D r ill Ahead 2- S e p 3 6 9 0 9 . 2 5 7 0 2 3 2 6 1 4 / 3 5 / 4 1 5 . 7 7 2 / 4 9 / 4 0 / 2 9 / 1 4 / 1 2 2 / - 6 . 0 1 / 9 4 0 . 2 0 0 . 0 8 9 . 6 1 7 . 0 . 0 3 / . 1 5 9 0 0 4 0 B R O O H 3- S e p 3 6 9 0 9 . 4 0 8 0 2 1 3 3 1 6 / 4 2 / 5 1 5 . 6 7 5 / 5 4 / 4 4 / 3 2 / 1 4 / 1 3 2 / - 5 . 5 1 / 9 4 0 . 2 0 0 . 0 3 8 . 9 1 7 . 5 . 0 2 / . 1 5 8 0 0 4 0 R I H 1 3 3 / 8 " C a s i n g 4- S e p 3 6 9 0 9 . 4 5 1 1 4 3 6 3 1 1 4 / 3 8 / 4 1 5 . 2 1 0 3 / 6 7 / 5 3 / 3 6 / 1 2 / 1 0 2 / - 5 . 5 1 / 9 4 0 . 2 0 0 . 0 2 9 . 0 1 6 . 0 . 0 1 / . 1 5 8 0 0 4 0 N / D D i v e r t e r 5- S e p 3 6 9 0 9 . 3 0 6 1 1 8 1 8 0 5 / 0 8 / 1 2 5 . 4 5 4 / 3 6 / 2 6 / 1 8 / 0 5 / 0 4 2 / - 5 . 4 1 / 9 5 0 . 1 0 0 . 0 2 8 . 7 1 6 . 0 . 0 1 / . 1 0 8 0 0 4 0 C / O s a v e r s u b 6- S e p 3 6 9 0 9 . 3 0 6 1 1 8 1 8 0 5 / 0 8 / 1 2 5 . 4 5 4 / 3 6 / 2 6 / 1 8 / 0 5 / 0 4 2 / - 5 . 4 1 / 9 3 0 . 1 0 0 . 0 2 8 . 7 1 6 . 0 . 0 1 / . 1 8 0 0 4 0 C u t / s l i p D r ill Line 7- S e p 6 1 5 0 9 . 2 5 4 7 1 0 1 8 0 8 / 0 9 / 1 1 7 . 0 3 8 / 2 8 / 2 4 / 1 9 / 0 9 / 0 8 1 / - 4 . 0 1 / 9 5 0 . 1 3 0 . 2 8 0 . 1 2 . 0 . 1 0 / . 5 0 6 5 0 4 0 D r ill 12.25" hole 8- S e p 8 9 0 5 9 . 4 0 6 0 1 3 3 2 1 3 / 2 6 / 3 1 5 . 6 5 8 / 4 5 / 3 8 / 2 9 / 1 4 / 1 3 1 / - 5 . 3 1 / 9 3 0 . 2 0 0 . 2 2 9 . 7 1 3 . 5 . 0 7 / . 5 0 1 1 0 0 6 0 D r ill 12.25" hole 9- S e p 1 1 4 7 4 9 . 5 0 5 2 1 3 2 5 1 1 / 2 5 / 3 2 5 . 2 5 1 / 3 8 / 3 2 / 2 4 / 1 2 / 1 1 1 / - 6 . 0 2 / 9 2 0 . 1 5 0 . 2 4 0 . 0 1 5 . 0 . 0 9 / . 5 1 1 6 0 0 6 0 D r ill 12.25" hole 10 - S e p 1 1 9 3 9 9 . 6 0 5 3 1 2 2 6 1 1 / 2 7 / 3 4 4 . 8 5 0 / 3 8 / 3 2 / 2 8 / 1 2 / 1 1 1 / - 6 . 0 2 / 9 2 0 . 1 5 0 . 2 0 9 . 9 1 7 . 5 . 0 9 / . 5 1 1 5 0 0 6 0 B R O O H 11 - S e p 1 1 9 3 9 9 . 4 5 4 9 1 2 2 6 1 1 / 2 7 / 2 5 5 . 6 5 0 / 3 8 / 3 2 / 2 5 / 1 2 / 1 1 1 / - 6 . 0 2 / 9 2 0 . 1 5 0 . 1 6 9 . 8 1 7 . 0 . 1 0 / . 5 0 1 3 0 0 4 0 B R O O H 12 - S e p 1 1 9 3 9 9 . 4 0 4 6 1 2 2 1 1 0 / 2 7 / 3 9 5 . 8 4 5 / 3 3 / 2 8 / 2 1 / 1 1 / 1 0 1 / - 6 . 0 2 / 9 2 0 . 1 5 0 . 1 7 9 . 7 1 8 . 0 . 0 9 / . 4 8 1 0 0 0 4 0 R u n 9 5 / 8 ' ' C a s i n g 13 - S e p 1 1 9 3 9 9 . 4 0 4 7 1 1 2 3 1 0 / 2 6 / 3 8 5 . 9 4 5 / 2 4 / 2 8 / 2 1 / 1 1 / 9 1 / - 6 . 1 2 / 9 2 0 . 1 5 0 . 1 6 9 . 6 1 8 . 0 . 0 8 / . 4 8 1 1 0 0 4 0 C i r c & C o n d 14 - S e p 1 1 9 3 9 9 . 5 0 5 8 1 1 1 8 0 7 / 1 3 / 2 3 6 . 0 4 0 / 2 9 / 2 5 / 1 9 / 0 8 / 0 7 1 / - 6 . 0 2 / 9 2 0 . 1 3 0 . 0 9 9 . 4 1 6 . 0 . 0 5 / . 4 8 1 2 0 0 6 0 N / U B O P E ' s 15 - S e p 1 1 9 3 9 9 . 4 0 5 8 1 2 1 7 0 7 / 1 3 / 2 2 6 . 0 4 1 / 2 9 / 2 5 / 1 9 / 0 8 / 0 7 1 / - 6 . 0 2 / 9 2 0 . 1 3 0 . 1 0 9 . 4 1 6 . 0 . 0 5 / . 5 5 1 2 0 0 6 0 T e s t B O P Oi l B a s e d M u d R e c o r d 11 , 9 3 9 ' t o 2 1 , 1 1 8 ' Da t e D e p t h W t V i s P V Y P G e l s F i l t R6 0 0 / R 3 0 0 / R 2 0 0 / R 1 0 0 / R6 / R 3 Ca k e C or r . So l i d Oi l / W a t e r Oi l P m L i m e S a l t C l - Em u l St a b i l i t y S d R e m a r k s ft - M D p p g s e c l b / 1 0 0 l b / 1 0 0 f t 2 m / 3 0 m R h e o m e t e r 3 2 n d s % v o l % v o l l b / b b l % W t m g / L m g / l % v o l 16 - S e p 1 1 9 3 9 9 . 4 0 4 7 1 2 1 4 5 / 5 / 5 - 3 8 / 2 6 / 2 1 / 1 5 / 0 6 / 0 5 - / 2 9 . 9 6 4 / 3 6 5 6 2 . 7 5 3 . 5 8 2 7 . 9 9 7 7 0 0 0 4 0 5 R I H 17 - S e p 1 2 1 5 0 9 . 4 0 4 7 1 2 1 3 5 / 5 / 5 5 . 6 3 7 / 2 5 / 2 0 / 1 4 / 0 6 / 0 5 - / - 8 . 6 6 4 / 3 6 5 6 2 . 5 0 3 . 2 5 2 7 . 9 9 7 7 0 0 0 4 0 5 D r ill Ah ead 8.75" 18 - S e p 1 3 7 1 0 9 . 4 0 4 9 1 5 2 1 9 / 9 / 1 0 2 . 0 5 1 / 3 6 / 3 0 / 2 3 / 1 0 / 0 9 - / - 1 0 . 5 6 4 / 3 6 5 5 2 . 4 0 3 . 1 2 2 7 . 1 5 7 5 0 0 0 6 0 6 D r ill Ah ead 8.75" 19 - S e p 1 5 9 2 0 9 . 4 5 4 3 1 3 1 8 8 / 8 / 8 2 . 3 4 4 / 3 1 / 2 6 / 1 9 / 0 9 / 0 8 - / - 1 2 . 0 7 0 / 3 0 6 0 2 . 4 5 3 . 1 9 2 6 . 9 1 6 0 0 0 0 6 0 5 D r ill Ah ead 8.75" 20 - S e p 1 7 2 5 7 9 . 4 0 3 3 1 3 1 9 7 / 7 / 8 3 . 6 4 5 / 3 2 / 2 6 / 1 9 / 0 9 / 0 8 - / - 9 . 2 7 0 / 3 0 6 2 2 . 8 5 3 . 7 1 2 8 . 8 9 6 7 5 0 0 6 2 5 D r ill Ah ead 8.75" 21 - S e p 1 8 3 3 9 9 . 4 5 4 5 1 3 1 9 7 / 7 / 8 4 . 1 4 5 / 3 2 / 2 7 / 2 0 / 0 9 / 0 8 - / - 9 . 1 6 9 / 3 1 6 1 2 . 1 5 2 . 8 0 2 8 . 8 6 7 0 0 0 0 6 0 5 D r ill Ah ead 8.75" 22 - S e p 1 9 0 0 1 9 . 4 5 4 4 1 3 1 6 6 / 7 / 7 3 . 6 4 2 / 2 9 / 2 4 / 1 7 / 7 / 6 - / 2 9 . 2 6 9 / 3 1 6 1 2 . 6 0 3 . 3 8 3 2 . 0 2 8 1 2 5 0 6 1 0 D r ill Ah ead 8.75" 23 - S e p 2 0 7 7 0 9 . 5 0 4 6 1 4 1 7 7 / 7 / 8 3 . 9 4 5 / 3 1 / 2 5 / 1 8 / 8 / 7 - / 2 8 . 8 6 7 / 3 3 5 8 3 . 4 0 4 . 4 2 2 9 . 4 9 7 7 5 0 0 6 0 5 D r ill Ah ead 8.75" 24 - S e p 2 1 1 1 8 9 . 4 5 4 6 1 3 1 6 6 / 7 / 7 4 . 1 4 2 / 2 9 / 2 3 / 1 7 / 7 / 6 - / 2 8 . 9 6 8 / 3 2 6 0 2 . 7 0 3 . 5 1 2 9 . 5 4 7 5 0 0 0 6 3 5 B R O O H 25 - S e p 2 1 1 1 8 9 . 4 5 4 5 1 3 1 4 6 / 6 / 7 4 . 2 4 0 / 2 7 / 2 1 / 1 5 / 6 / 5 - / 2 9 . 4 6 8 / 3 2 6 0 3 . 0 0 3 . 9 0 2 9 . 5 4 7 5 0 0 0 6 8 5 P O O H 4 . 5 " D P 26 - S e p 2 1 1 1 8 9 . 4 5 4 5 1 2 1 5 6 / 6 / 7 - 3 9 / 2 7 / 2 1 / 1 5 / 6 / 5 - 8 . 9 6 8 / 3 2 6 0 3 . 0 0 3 . 9 0 2 9 . 5 4 7 5 0 0 0 6 8 5 R I H 5 . 5 " L i n e r 27 - S e p 2 1 1 1 8 9 . 0 0 2 3 92 0 0 0 L / D 5 " D P 28 - S e p 2 1 1 1 8 9 . 0 0 2 3 92 0 0 0 T e s t B O P ' s 20 " C o n d u c t o r @ 16 0 ' M D AK - A M - 0 0 0 9 6 5 0 3 0 1 13 3 / 8 " S u r f a c e @ 3 , 6 7 4 ' M D Ca s i n g R e c o r d Pr o d u c t i o n S e c t i o n In t e r m e d i a t e S e c t i o n Sp y I s l a n d No r t h S l o p e Al a s k a 31 - A u g - 1 2 24 - S e p - 1 2 5. 5 " P r o d u c t i o n @ 2 1 , 07 6 ' M D SP 1 0 - F N 5 EN I P e t r o l e u m MI S w a c o Do y o n 1 5 9 5 / 8 " I n t e r m e d i a t e @ 1 1 , 9 1 9 ' M D Su r f a c e S e c t i o n Fa z e P r o MI S p u d M u d LS N D Well Name: Depth (MD) to ft Location: (TVD) to ft Operator:Show Report No. Show Report Report Prepared By: Formation: Report Delivered To: Date Drilled: 9/9/2012 & 9/10/2012 N Sands & OA Sands 10277 11876 Spy Island eni Petroleum Leigh Ann Rasher SP10-FN5 3900 1 3723 Andrew Buchanan Dt h ft C1 C1 C1 C1 1 10277 Interpretation: GU i t 529 1600Md C h l i d ( / L ) Hydrocarbon Ratios No producible oil within these zones based upon gas and chromatograph data collected. Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= 10277 Gas Units #DIV/0!9 529 59 0 56744 962 6305 115 494 0 9 0 59 513 19 9323 66067 0 0 1600Mud Chlorides (mg/L) = 1000 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = 2 Gas Units 71624 667 686 10357 80947 660 19 9323 Mud Chlorides (mg/L) = 107 682 1600 10 100 Gas C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios3 Gas Units 3581 0 15 0 105 10874 20 0 4775105 15 20 436 Mud Chlorides (mg/L) =1600 1 Oil NPH pp pp pp Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 4 147 262 89 36 1940 647223 12 280 235 43356 20072 99 444 182 246 158 316 23284 100 1000 NPH Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = 4 1181 Gas Units 86 317 96912 1616 72 82 463 1127 306 1395 1089 1649 468 11876 2089 747 1342 1590 136367 39455 Mud Chlorides (mg/L) =1500 10 NPH Oil Gas C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 2089 747 1342 1 NPH Well Name: Depth (MD) to ft Location: (TVD) to ft Operator:Show Report No. Show Report Report Prepared By: Formation: Report Delivered To: Date Drilled: SP10-FN5 3923 2 3915 Andrew Buchanan 12300 12600 Spy Island eni Petroleum Leigh Ann Rasher 18-Sep-12 OA Sands Dt h ft C1 C1 C1 C1 Hydrocarbon Ratios No producible oil within these zones based upon gas and chromatograph data collected. 75000Md C h l i d ( / L )73512303 Interpretation: GU i t 1 Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= 75000Mud Chlorides (mg/L) = 8 113 25 245 464 10 1119 86856 189 454 121 347 759322 735 254 9 85737 350 266 12303 Gas Units 1000 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = 75000 173 306 Mud Chlorides (mg/L) = 526 12395 90408 782 10 1119 Gas Units 89289 516 2 10 100 Gas C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Mud Chlorides (mg/L) =75000 292 169 230 1128 528 238 8 9 194 25 301 12511 388 Gas Units Hydrocarbon Ratios3 1 Oil NPH pp pp pp Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 305 115941 353683 79 387 248 124934 8993 59 41 805 439104 144 192 264 604 4 328 100 1000 NPH Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = Mud Chlorides (mg/L) =75000 8993 273 41 232 338 106600 219 104 588 79 12592 115 421 192 59 279 350 849 97607 938 509 Gas Units 4 10 NPH Oil Gas C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 273 41 232 1 NPH Well Name: Depth (MD) to ft Location: (TVD) to ft Operator:Show Report No. Show Report Report Prepared By: Formation: Report Delivered To: Date Drilled: SP10-FN5 3911 3 3909 Andrew Buchanan 13800 14500 Spy Island eni Petroleum Leigh Ann Rasher 19-Sep-12 OA Sands Dt h ft C1 C1 C1 C1 Hydrocarbon Ratios No producible oil within these zones based upon gas and chromatograph data collected. 60000Md C h l i d ( / L )91013835 Interpretation: GU i t 1 Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= 60000Mud Chlorides (mg/L) = 118 123 179 256 556 68 6978 101665 194 488 241 524 770345 910 324 68 94687 370 274 13835 Gas Units 1000 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = 60000 189 364 Mud Chlorides (mg/L) = 719 13920 130310 1188 68 6978 Gas Units 123332 651 2 10 100 Gas C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Mud Chlorides (mg/L) =65000 339 101 238 1207 1221 356 118 68 280 179 407 14371 518 Gas Units Hydrocarbon Ratios3 1 Oil NPH pp pp pp Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 379 121924 342713 55 416 295 129543 7619 59 127 968 484169 126 185 252 658 4 357 100 1000 NPH Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = Mud Chlorides (mg/L) =65000 7619 323 127 196 354 108997 252 169 605 55 14472 83 517 184 59 295 344 1221 101378 1027 550 Gas Units 4 10 NPH Oil Gas C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 323 127 196 1 NPH Well Name: Depth (MD) to ft Location: (TVD) to ft Operator:Show Report No. Show Report Report Prepared By: Formation: Report Delivered To: Date Drilled: SP10-FN5 3905 4 3911 Andrew Buchanan 14900 15400 Spy Island eni Petroleum Leigh Ann Rasher 19-Sep-12 OA Sands Dt h ft C1 C1 C1 C1 Hydrocarbon Ratios No producible oil within these zones based upon gas and chromatograph data collected. 65000Md C h l i d ( / L )198414980 Interpretation: GU i t 1 Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= 65000Mud Chlorides (mg/L) = 37 280 41 354 615 17 4347 205001 336 598 317 633 717592 1984 369 15 200654 567 339 14980 Gas Units 1000 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = 65000 383 752 Mud Chlorides (mg/L) = 760 15047 280662 3262 35 3073 Gas Units 277589 725 2 10 100 Gas C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Mud Chlorides (mg/L) =65000 369 125 235 4150 2221 371 136 51 294 169 420 15160 1181 Gas Units Hydrocarbon Ratios3 1 Oil NPH pp pp pp Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 439 302883 676879 35 496 343 306301 3418 48 134 1692 993164 179 359 305 844 4 448 100 1000 NPH Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = Mud Chlorides (mg/L) =66000 9850 488 163 325 577 328930 388 206 1045 68 15309 182 982 327 73 504 633 1753 319080 5136 977 Gas Units 4 10 NPH Oil Gas C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 488 163 325 1 NPH Well Name: Depth (MD) to ft Location: (TVD) to ft Operator:Show Report No. Show Report Report Prepared By: Formation: Report Delivered To: Date Drilled: 19-Sep-12 OA Sands 15500 15800 Spy Island eni Petroleum Leigh Ann Rasher SP10-FN5 3905 5 3903 Andrew Buchanan Dt h ft C1 C1 C1 C1 1 15501 Interpretation: GU i t 2202 66000Md C h l i d ( / L ) Hydrocarbon Ratios No producible oil within these zones based upon gas and chromatograph data collected. Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= 15501 Gas Units 1247445 2202 365 50 218232 693 490 380 575 305 597 152 315 621 46 6697 224929 130 175 66000Mud Chlorides (mg/L) = 1000 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = 2 Gas Units 154648 498 544 15568 161345 1524 46 6697 Mud Chlorides (mg/L) = 311 554 66000 10 100 Gas C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios3 Gas Units 836 50 242 152 329 15680 315 130 1718279 90 185 1177 Mud Chlorides (mg/L) =66000 1 Oil NPH pp pp pp Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 4 303 554 212 196 1038 599136 113 119 249 125951 8615 45 599 45 348 387 315 117336 100 1000 NPH Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = 4 862 Gas Units 313 626 152713 1577 438 177 45 488 244 380 136 907 45 15797 468 119 349 533 161328 8615 Mud Chlorides (mg/L) =73750 10 NPH Oil Gas C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 468 119 349 1 NPH Well Name: Depth (MD) to ft Location: (TVD) to ft Operator:Show Report No. Show Report Report Prepared By: Formation: Report Delivered To: Date Drilled: 20-Sep-12 OA Sands 16100 16500 Spy Island eni Petroleum Leigh Ann Rasher SP10-FN5 3897 6 3898 Andrew Buchanan Dt h ft C1 C1 C1 C1 1 16134 Interpretation: GU i t 633 67500Md C h l i d ( / L ) Hydrocarbon Ratios No producible oil within these zones based upon gas and chromatograph data collected. Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= 16134 Gas Units 561326 633 246 16 68441 298 210 171 401 203 396 70 230 414 13 1815 70256 81 122 67500Mud Chlorides (mg/L) = 1000 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = 2 Gas Units 84083 498 525 16257 87269 785 27 3186 Mud Chlorides (mg/L) = 169 292 67500 10 100 Gas C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios3 Gas Units 450 29 225 90 317 16371 271 84 623288 135 187 1098 Mud Chlorides (mg/L) =67500 1 Oil NPH pp pp pp Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 4 403 678 164 286 550 389112 202 91 314 117931 6743 45 726 48 448 276 377 111188 100 1000 NPH Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = 4 505 Gas Units 297 670 87071 981 431 172 45 293 130 242 112 553 48 16473 293 91 202 338 93814 6743 Mud Chlorides (mg/L) =72500 10 NPH Oil Gas C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 293 91 202 1 NPH Well Name: Depth (MD) to ft Location: (TVD) to ft Operator:Show Report No. Show Report Report Prepared By: Formation: Report Delivered To: Date Drilled: SP10-FN5 3895 7 3900 Andrew Buchanan 17400 18100 Spy Island eni Petroleum Leigh Ann Rasher 21-Sep-12 OA Sands Dt h ft C1 C1 C1 C1 Hydrocarbon Ratios No producible oil within these zones based upon gas and chromatograph data collected. 70000Md C h l i d ( / L )98317403 Interpretation: GU i t 1 Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= 70000Mud Chlorides (mg/L) = 29 224 38 397 653 12 1295 105473 163 641 253 617 465579 983 411 14 104178 262 180 17403 Gas Units 1000 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = 71500 158 254 Mud Chlorides (mg/L) = 580 17540 86667 806 48 2531 Gas Units 84136 532 2 10 100 Gas C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Mud Chlorides (mg/L) =71500 331 137 242 1190 614 339 97 59 290 153 390 17943 348 Gas Units Hydrocarbon Ratios3 1 Oil NPH pp pp pp Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 386 123179 273774 30 491 346 125046 1867 39 63 507 381103 243 166 323 744 4 452 100 1000 NPH Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = Mud Chlorides (mg/L) =71500 1695 297 75 222 345 79077 254 87 524 17 18029 167 349 153 25 320 242 463 77382 731 507 Gas Units 4 10 NPH Oil Gas C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 297 75 222 1 NPH Well Name: Depth (MD) to ft Location: (TVD) to ft Operator:Show Report No. Show Report Report Prepared By: Formation: Report Delivered To: Date Drilled: SP10-FN5 3862 8 3868 Andrew Buchanan 19500 20000 Spy Island eni Petroleum Leigh Ann Rasher 23-Sep-12 OA Sands Dt h ft C1 C1 C1 C1 Hydrocarbon Ratios No producible oil within these zones based upon gas and chromatograph data collected. 72500Md C h l i d ( / L )82619550 Interpretation: GU i t 1 Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= 72500Mud Chlorides (mg/L) = 74 164 124 302 549 51 6057 85505 160 498 238 560 484436 826 353 51 79448 263 182 19550 Gas Units 1000 NPH Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = 72500 160 266 Mud Chlorides (mg/L) = 426 19653 68410 632 45 7492 Gas Units 60918 381 2 10 100 Gas C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Mud Chlorides (mg/L) =72500 229 111 171 583 549 223 52 35 190 79 264 19797 356 Gas Units Hydrocarbon Ratios3 1 Oil NPH pp pp pp Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 266 55558 244421 60 286 222 62343 6785 58 87 741 310147 75 154 179 361 4 228 100 1000 NPH Depth ft Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = Mud Chlorides (mg/L) =73000 5568 245 78 167 262 59187 202 134 397 54 19992 68 321 156 56 206 260 789 53619 556 343 Gas Units 4 10 NPH Oil Gas C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 245 78 167 1 NPH Marker MD INC AZ TVD TVDSS 16" Surface Borehole 20" Conductor Shoe 160.0 0.5 36.1 160.0 -106.1 SV-4 771.0 17.2 317.9 763.5 -709.5 SV-3 1,169.0 33.2 324.9 1,119.2 -1,065.2 SV-2 1,507.0 43.0 323.7 1,381.5 -1,327.6 Permafrost Base 2,014.0 44.3 323.3 1,750.9 -1,697.0 SV-1 2,299.0 53.4 321.4 1,938.6 -1,884.6 Ugnu Top (UG4)2,983.0 69.2 318.4 2,268.1 -2,214.2 13 3/8" Casing Shoe 3,674.0 81.1 318.5 2,426.2 -2,372.3 TD 16" Borehole 3,690.0 80.9 318.3 2,428.7 -2,374.8 12 1/4" Intermediate Borehole UG-2 Coal Bed marker 5,331.0 77.7 314.4 2,747.8 -2,693.9 Lower Ugnu 8,542.0 79.3 316.6 3,400.3 -3,346.3 Schrader Bluff Top 9,949.0 79.0 316.4 3,672.1 -3,618.2 N Sequence Top 10,066.0 78.9 315.9 3,694.6 -3,640.7 N Top 10,305.0 78.8 317.3 3,740.7 -3,686.8 N-2 Top 10,353.0 79.0 317.2 3,750.0 -3,696.1 N-3 Top 10,366.0 79.0 317.1 3,752.5 -3,698.5 N Bottom 10,445.0 79.2 317.5 3,767.3 -3,713.4 N Sequence Base 11,033.0 85.8 326.5 3,839.1 -3,785.1 OA Top 11,861.0 86.0 327.6 3,898.6 -3,844.7 9 5/8" Intermediate Casing 11,919.0 86.8 328.3 3,902.4 -3,848.5 TD 12 1/4" Borehole 11,939.0 87.3 328.9 3,903.4 -3,849.5 8 3/4" Lateral Borehole OA-2 Top 12,003.0 87.4 329.1 3,905.9 -3,852.0 OA-3 Top 12,121.0 87.8 329.1 3,911.5 -3,857.6 OA-4 Top 12,645.0 90.0 325.2 3,923.8 -3,869.8 OA-4 Top 12,822.0 92.5 320.4 3,920.1 -3,866.2 OA-3 Top 13,049.0 92.2 315.7 3,909.3 -3,855.4 OA-2 Top 13,157.0 90.5 315.9 3,907.0 -3,853.1 OA-2 Top 14,050.0 91.1 319.8 3,906.1 -3,852.2 OA-3 Top 14,253.0 87.5 319.2 3,906.9 -3,853.0 OA-3 Top 15,339.0 91.5 312.4 3,904.6 -3,850.7 OA-3 Top 15,481.0 88.5 312.1 3,903.7 -3,849.8 OA-3 Top 15,932.0 91.8 310.5 3,902.5 -3,848.6 OA-2 Top 16,001.0 92.3 311.1 3,899.9 -3,846.0 OA-2 Top 16,620.0 89.6 310.6 3,897.9 -3,844.0 OA-2 Top 16,800.0 90.1 313.4 3,895.6 -3,841.7 OA-2 Top 16,838.0 91.1 313.5 3,894.9 -3,841.0 OA-3 Top 17,091.0 87.0 312.5 3,897.4 -3,843.5 OA-3 Top 18,085.0 89.8 308.3 3,895.9 -3,842.0 OA-2 Top 18,218.0 92.7 311.2 3,894.9 -3,841.0 OA-3 Top 18,707.0 91.8 311.2 3,885.4 -3,831.4 OA-2 Top 19,034.0 92.7 308.5 3,874.2 -3,820.3 OA-2 Top 20,218.0 87.5 308.9 3,867.3 -3,813.4 OA-3 Top 20,334.0 87.2 310.1 3,872.8 -3,818.9 OA-3 Top 21,000.0 91.0 307.7 3,876.4 -3,822.5 TD 8 3/4" Borehole 21,118.0 90.8 308.2 3,874.6 -3,820.7 SP10-FN5 Interpolated Tops DIRECTIONAL SURVEY REPORT Eni Petroleum SP10-FN5 Nikaitchuq Alaska United States -XX-0009650301 Measured Vertical Vertical Depth Inclination Direction Depth Latitude Departure Section Dogleg (feet)(degrees)(degrees)(feet)(feet)(feet)(feet)(deg/100ft) 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 TIE-IN 53.92 0.00 0.00 53.92 0.00 N 0.00 E 0.00 0.00 66.00 0.05 171.00 66.00 0.01 S 0.00 E -0.01 0.41 128.00 0.27 48.03 128.00 0.07 N 0.11 E 0.07 0.48 161.00 0.53 35.86 161.00 0.24 N 0.26 E 0.24 0.82 193.00 0.75 39.30 193.00 0.52 N 0.48 E 0.52 0.70 282.00 2.05 27.01 281.97 2.39 N 1.57 E 2.39 1.49 316.00 2.88 22.66 315.94 3.72 N 2.18 E 3.72 2.50 346.00 3.55 9.32 345.89 5.33 N 2.62 E 5.33 3.33 378.00 4.37 358.22 377.81 7.53 N 2.74 E 7.53 3.50 409.00 4.94 341.43 408.71 9.98 N 2.28 E 9.98 4.74 440.00 6.23 329.98 439.57 12.70 N 1.01 E 12.70 5.48 470.00 7.65 325.57 469.35 15.76 N 0.93 W 15.76 5.05 500.00 8.94 326.15 499.03 19.34 N 3.36 W 19.34 4.31 529.00 9.76 326.13 527.65 23.25 N 5.98 W 23.25 2.83 560.00 10.13 327.62 558.18 27.73 N 8.91 W 27.73 1.45 586.23 10.32 323.43 583.99 31.57 N 11.54 W 31.57 2.93 619.36 10.92 321.02 616.56 36.39 N 15.29 W 36.39 2.25 650.15 12.38 317.09 646.71 41.08 N 19.37 W 41.08 5.39 679.20 13.64 316.26 675.02 45.83 N 23.86 W 45.83 4.38 713.13 15.21 316.99 707.87 51.98 N 29.66 W 51.98 4.66 773.69 17.26 317.93 766.02 64.46 N 41.10 W 64.46 3.41 869.36 22.07 319.84 856.08 88.74 N 62.21 W 88.74 5.07 960.70 27.25 322.37 939.07 118.44 N 86.06 W 118.44 5.79 1053.55 29.43 324.68 1020.78 153.89 N 112.23 W 153.89 2.63 1145.60 32.88 324.68 1099.55 192.75 N 139.76 W 192.75 3.75 1240.30 34.30 325.68 1178.43 235.76 N 169.67 W 235.76 1.61 1333.76 39.00 324.67 1253.39 281.53 N 201.54 W 281.53 5.07 1427.67 43.79 323.95 1323.82 331.93 N 237.77 W 331.93 5.13 1521.74 42.80 323.66 1392.29 383.99 N 275.87 W 383.99 1.07 1613.88 43.91 323.35 1459.28 434.84 N 313.49 W 434.84 1.23 1708.36 43.87 323.40 1527.37 487.41 N 352.57 W 487.41 0.06 1801.36 42.65 323.58 1595.10 538.64 N 390.49 W 538.64 1.32 1894.79 42.16 324.12 1664.09 589.51 N 427.65 W 589.51 0.65 1987.34 43.93 323.04 1731.72 640.34 N 465.16 W 640.34 2.07 2081.76 45.18 323.77 1799.00 693.52 N 504.65 W 693.52 1.43 2175.29 49.87 322.87 1862.14 748.82 N 545.86 W 748.82 5.06 2268.51 52.95 321.59 1920.28 806.40 N 590.50 W 806.40 3.47 2362.16 54.44 321.02 1975.73 865.29 N 637.68 W 865.29 1.66 2455.43 58.34 319.43 2027.35 924.96 N 687.38 W 924.96 4.42 2548.53 59.53 318.96 2075.39 985.33 N 739.50 W 985.33 1.35 2641.29 60.62 316.40 2121.67 1044.75 N 793.62 W 1044.75 2.66 2734.99 63.27 316.80 2165.74 1104.83 N 850.43 W 1104.83 2.85 2828.15 64.70 316.66 2206.60 1165.79 N 907.82 W 1165.79 1.54 2920.42 66.67 317.41 2244.59 1227.32 N 965.12 W 1227.32 2.26 3014.06 70.49 318.80 2278.78 1292.20 N 1023.31 W 1292.20 4.31 3108.39 70.65 317.02 2310.16 1358.21 N 1082.93 W 1358.21 1.79 3201.71 75.02 318.62 2337.70 1424.28 N 1142.77 W 1424.28 4.96 3294.83 75.38 319.20 2361.49 1492.13 N 1201.95 W 1492.13 0.72 3388.22 77.28 318.01 2383.56 1560.20 N 1261.95 W 1560.20 2.38 3483.10 82.00 319.63 2400.61 1630.43 N 1323.38 W 1630.43 5.25 3576.43 83.32 319.54 2412.54 1700.90 N 1383.39 W 1700.90 1.42 3618.23 81.90 319.32 2417.91 1732.39 N 1410.35 W 1732.39 3.44 3717.50 80.45 317.96 2433.14 1806.02 N 1475.16 W 1806.02 1.99 3773.50 80.42 319.08 2442.45 1847.39 N 1511.74 W 1847.39 1.97 3866.71 80.04 319.62 2458.27 1917.08 N 1571.58 W 1917.08 0.70 3960.49 79.51 319.86 2474.91 1987.51 N 1631.22 W 1987.51 0.62 4052.80 79.25 319.14 2491.93 2056.50 N 1690.14 W 2056.50 0.82 4146.67 78.88 318.95 2509.73 2126.10 N 1750.55 W 2126.10 0.44 4240.02 79.12 317.07 2527.55 2194.21 N 1811.85 W 2194.21 1.99 4333.16 78.84 317.71 2545.35 2261.49 N 1873.75 W 2261.49 0.74 4427.65 78.78 317.11 2563.69 2329.73 N 1936.48 W 2329.73 0.63 4519.92 79.01 316.29 2581.46 2395.63 N 1998.57 W 2395.63 0.91 4614.18 78.42 315.30 2599.91 2461.89 N 2063.02 W 2461.89 1.21 4707.51 78.35 315.59 2618.70 2527.03 N 2127.16 W 2527.03 0.31 4800.10 78.33 314.59 2637.41 2591.25 N 2191.18 W 2591.25 1.06 4894.84 78.04 313.73 2656.81 2655.86 N 2257.70 W 2655.86 0.94 4987.65 78.08 313.41 2676.01 2718.44 N 2323.49 W 2718.44 0.34 5080.20 78.35 314.75 2694.91 2781.47 N 2388.57 W 2781.47 1.45 5174.04 77.62 314.73 2714.45 2846.07 N 2453.77 W 2846.07 0.78 5267.11 77.81 313.98 2734.25 2909.65 N 2518.79 W 2909.65 0.81 5360.17 77.60 314.56 2754.07 2973.12 N 2583.90 W 2973.12 0.65 5454.06 77.64 314.75 2774.20 3037.57 N 2649.14 W 3037.57 0.20 5547.26 78.11 315.35 2793.77 3102.06 N 2713.51 W 3102.06 0.81 5640.23 77.85 315.23 2813.14 3166.68 N 2777.48 W 3166.68 0.31 5733.37 77.51 314.11 2833.01 3230.65 N 2842.19 W 3230.65 1.23 5826.96 77.72 314.55 2853.08 3294.53 N 2907.58 W 3294.53 0.51 5920.09 77.54 314.05 2873.03 3358.06 N 2972.69 W 3358.06 0.56 6013.50 78.11 314.50 2892.73 3421.81 N 3038.06 W 3421.81 0.77 6107.12 77.84 313.26 2912.24 3485.27 N 3104.06 W 3485.27 1.33 6200.33 77.86 314.47 2931.86 3548.42 N 3169.76 W 3548.42 1.27 6294.11 78.57 314.85 2951.01 3612.94 N 3235.06 W 3612.94 0.85 6386.44 77.74 313.60 2969.96 3675.97 N 3299.81 W 3675.97 1.60 6480.32 77.77 313.57 2989.88 3739.22 N 3366.26 W 3739.22 0.04 6573.86 77.71 314.15 3009.74 3802.56 N 3432.17 W 3802.56 0.61 6667.24 77.82 313.56 3029.53 3865.78 N 3497.98 W 3865.78 0.63 6760.85 78.09 313.76 3049.06 3928.99 N 3564.21 W 3928.99 0.36 6854.43 78.11 313.29 3068.36 3992.05 N 3630.60 W 3992.05 0.49 6947.36 78.15 314.14 3087.47 4054.90 N 3696.33 W 4054.90 0.90 7040.95 78.09 313.58 3106.74 4118.35 N 3762.37 W 4118.35 0.59 7134.47 78.90 314.28 3125.39 4181.93 N 3828.37 W 4181.93 1.13 7227.95 79.04 315.04 3143.28 4246.43 N 3893.63 W 4246.43 0.81 7321.21 78.60 315.10 3161.36 4311.20 N 3958.24 W 4311.20 0.48 7414.47 78.64 315.46 3179.76 4376.16 N 4022.58 W 4376.16 0.38 7507.74 78.79 316.33 3198.02 4441.84 N 4086.23 W 4441.84 0.93 7601.58 78.68 316.33 3216.35 4508.41 N 4149.78 W 4508.41 0.12 7695.49 78.30 316.20 3235.09 4574.90 N 4213.40 W 4574.90 0.43 7788.64 78.74 316.54 3253.62 4640.97 N 4276.39 W 4640.97 0.59 7882.22 78.79 316.51 3271.86 4707.58 N 4339.54 W 4707.58 0.06 7975.98 78.72 316.52 3290.14 4774.30 N 4402.82 W 4774.30 0.08 8068.93 78.89 316.59 3308.19 4840.50 N 4465.52 W 4840.50 0.20 8161.99 78.61 315.99 3326.34 4906.48 N 4528.59 W 4906.48 0.70 8255.49 78.48 316.64 3344.91 4972.74 N 4591.89 W 4972.74 0.70 8348.86 78.92 316.21 3363.21 5039.08 N 4655.00 W 5039.08 0.65 8441.52 78.73 316.23 3381.17 5104.71 N 4717.89 W 5104.71 0.21 8535.72 79.33 316.66 3399.09 5171.73 N 4781.62 W 5171.73 0.78 8629.64 79.27 316.29 3416.53 5238.64 N 4845.17 W 5238.64 0.39 8723.16 79.47 316.01 3433.78 5304.93 N 4908.85 W 5304.93 0.36 8816.12 79.40 316.14 3450.82 5370.75 N 4972.24 W 5370.75 0.16 8908.83 79.42 315.53 3467.86 5436.12 N 5035.73 W 5436.12 0.65 9002.21 78.64 315.35 3485.63 5501.44 N 5100.06 W 5501.44 0.86 9095.61 79.07 316.12 3503.69 5567.06 N 5164.02 W 5567.06 0.93 9189.08 77.79 315.47 3522.43 5632.70 N 5227.86 W 5632.70 1.53 9282.44 78.55 314.67 3541.57 5697.39 N 5292.40 W 5697.39 1.17 9375.88 78.49 314.30 3560.17 5761.56 N 5357.72 W 5761.56 0.39 9469.24 78.74 315.37 3578.60 5826.09 N 5422.63 W 5826.09 1.16 9562.59 78.54 314.99 3596.99 5891.01 N 5487.14 W 5891.01 0.45 9655.93 78.70 314.80 3615.40 5955.59 N 5551.96 W 5955.59 0.26 9749.33 78.98 314.98 3633.48 6020.26 N 5616.88 W 6020.26 0.35 9842.82 78.72 316.22 3651.56 6085.79 N 5681.05 W 6085.79 1.33 9936.25 78.97 316.44 3669.64 6152.10 N 5744.35 W 6152.10 0.35 10029.50 78.87 315.85 3687.56 6218.09 N 5807.75 W 6218.09 0.63 10122.86 78.87 316.08 3705.58 6283.94 N 5871.43 W 6283.94 0.24 10216.49 78.94 316.61 3723.60 6350.42 N 5934.85 W 6350.42 0.56 10308.98 78.77 317.31 3741.48 6416.74 N 5996.79 W 6416.74 0.76 10402.44 79.21 317.01 3759.32 6484.01 N 6059.16 W 6484.01 0.57 10495.91 79.08 317.97 3776.93 6551.68 N 6121.19 W 6551.68 1.02 10495.91 79.08 317.97 3776.93 6551.68 N 6121.19 W 6551.68 1.02 10589.50 79.97 319.59 3793.94 6620.90 N 6181.83 W 6620.90 1.95 10682.71 83.32 322.50 3807.49 6692.60 N 6239.79 W 6692.60 4.74 10776.13 83.76 324.40 3818.00 6767.17 N 6295.07 W 6767.17 2.08 10869.55 85.48 325.11 3826.76 6843.13 N 6348.74 W 6843.13 1.99 10962.91 85.75 326.60 3833.90 6920.16 N 6400.98 W 6920.16 1.62 11056.25 85.83 326.50 3840.75 6997.83 N 6452.30 W 6997.83 0.14 11149.67 86.04 326.94 3847.37 7075.74 N 6503.43 W 7075.74 0.52 11243.04 85.92 327.20 3853.92 7153.91 N 6554.06 W 7153.91 0.31 11336.40 85.71 326.90 3860.73 7232.05 N 6604.70 W 7232.05 0.39 11429.78 85.74 327.76 3867.69 7310.43 N 6654.97 W 7310.43 0.92 11523.20 85.89 327.33 3874.51 7389.05 N 6704.97 W 7389.05 0.49 11616.63 86.07 328.01 3881.06 7467.80 N 6754.81 W 7467.80 0.75 11710.00 85.79 327.83 3887.69 7546.72 N 6804.28 W 7546.72 0.36 11803.33 85.85 327.70 3894.49 7625.45 N 6853.93 W 7625.45 0.15 11895.26 86.12 327.55 3900.93 7702.90 N 6903.03 W 7702.90 0.34 11967.72 88.21 329.11 3904.51 7764.49 N 6941.02 W 7764.49 3.60 12025.90 86.81 329.10 3907.04 7814.37 N 6970.87 W 7814.37 2.41 12119.18 87.79 329.12 3911.43 7894.33 N 7018.70 W 7894.33 1.05 12212.58 88.61 327.69 3914.37 7973.84 N 7067.61 W 7973.84 1.76 12306.04 89.59 328.84 3915.83 8053.31 N 7116.76 W 8053.31 1.62 12399.54 88.11 328.32 3917.71 8133.09 N 7165.49 W 8133.09 1.68 12493.01 87.83 327.27 3921.02 8212.12 N 7215.28 W 8212.12 1.16 12586.47 89.27 326.43 3923.39 8290.34 N 7266.36 W 8290.34 1.78 12679.91 90.47 324.55 3923.60 8367.34 N 7319.30 W 8367.34 2.39 12773.37 91.66 321.07 3921.86 8441.76 N 7375.77 W 8441.76 3.93 12866.69 93.24 319.76 3917.87 8513.62 N 7435.18 W 8513.62 2.20 12960.11 92.65 317.62 3913.07 8583.69 N 7496.76 W 8583.69 2.37 13053.40 92.17 315.56 3909.15 8651.40 N 7560.82 W 8651.40 2.27 13146.65 90.40 315.92 3907.06 8718.16 N 7625.88 W 8718.16 1.94 13240.03 90.96 315.30 3905.95 8784.88 N 7691.19 W 8784.88 0.89 13333.38 90.20 316.75 3905.00 8852.06 N 7756.01 W 8852.06 1.75 13426.78 90.47 316.62 3904.46 8920.01 N 7820.08 W 8920.01 0.32 13520.09 87.55 318.95 3906.07 8989.10 N 7882.75 W 8989.10 4.00 13613.53 89.06 319.32 3908.83 9059.73 N 7943.86 W 9059.73 1.66 13706.94 89.71 319.75 3909.84 9130.79 N 8004.48 W 9130.79 0.83 13800.28 91.06 319.59 3909.21 9201.94 N 8064.89 W 9201.94 1.46 13893.66 90.55 319.36 3907.90 9272.92 N 8125.56 W 9272.92 0.60 13987.05 90.57 319.21 3906.99 9343.70 N 8186.47 W 9343.70 0.16 14080.44 91.31 320.06 3905.45 9414.85 N 8246.95 W 9414.85 1.21 14173.98 89.47 320.64 3904.82 9486.86 N 8306.63 W 9486.86 2.06 14267.20 87.17 318.90 3907.55 9557.99 N 8366.80 W 9558.00 3.09 14360.52 88.45 316.89 3911.12 9627.17 N 8429.32 W 9627.17 2.55 14453.86 90.60 315.92 3911.89 9694.77 N 8493.68 W 9694.77 2.53 14547.28 90.99 313.20 3910.59 9760.30 N 8560.23 W 9760.30 2.94 14640.67 88.84 311.32 3910.73 9823.10 N 8629.34 W 9823.10 3.06 14734.04 89.90 310.77 3911.76 9884.41 N 8699.76 W 9884.41 1.28 14827.41 89.89 311.99 3911.93 9946.13 N 8769.81 W 9946.13 1.31 14920.75 90.66 312.26 3911.48 10008.74 N 8839.04 W 10008.74 0.87 15014.15 90.61 311.92 3910.45 10071.34 N 8908.35 W 10071.34 0.37 15107.51 90.73 312.05 3909.35 10133.78 N 8977.74 W 10133.78 0.19 15200.94 90.98 312.03 3907.96 10196.34 N 9047.12 W 10196.34 0.27 15294.31 91.67 312.00 3905.80 10258.82 N 9116.47 W 10258.82 0.74 15387.65 91.22 312.81 3903.45 10321.75 N 9185.37 W 10321.75 0.99 15481.08 88.50 312.08 3903.68 10384.79 N 9254.31 W 10384.79 3.01 15574.47 88.64 312.17 3906.01 10447.41 N 9323.55 W 10447.42 0.18 15667.80 89.94 312.43 3907.16 10510.22 N 9392.58 W 10510.22 1.42 15761.25 91.78 313.02 3905.76 10573.61 N 9461.22 W 10573.61 2.07 15854.51 90.38 311.55 3904.00 10636.35 N 9530.19 W 10636.35 2.18 15947.94 92.10 310.30 3901.98 10697.53 N 9600.77 W 10697.53 2.28 16041.37 92.53 311.74 3898.21 10758.80 N 9671.20 W 10758.80 1.61 16134.79 89.63 310.18 3896.45 10820.02 N 9741.72 W 10820.02 3.52 16228.21 89.32 309.87 3897.30 10880.10 N 9813.26 W 10880.10 0.47 16321.67 89.39 309.29 3898.35 10939.64 N 9885.29 W 10939.64 0.63 16415.12 90.40 310.23 3898.53 10999.41 N 9957.12 W 10999.41 1.48 16508.54 90.69 310.85 3897.64 11060.13 N 10028.11 W 11060.13 0.73 16601.92 89.23 310.37 3897.70 11120.91 N 10099.00 W 11120.91 1.65 16695.26 91.09 311.34 3897.44 11181.96 N 10169.60 W 11181.96 2.25 16788.60 90.92 313.33 3895.80 11244.81 N 10238.58 W 11244.81 2.14 16881.93 91.21 313.64 3894.07 11309.02 N 10306.29 W 11309.02 0.45 16975.38 89.59 312.79 3893.42 11373.01 N 10374.39 W 11373.01 1.96 17068.73 86.96 312.81 3896.23 11436.40 N 10442.84 W 11436.40 2.82 17162.13 87.27 311.29 3900.93 11498.88 N 10512.11 W 11498.88 1.66 17162.13 87.27 311.29 3900.93 11498.88 N 10512.11 W 11498.88 1.66 17255.54 90.92 311.86 3902.40 11560.84 N 10581.97 W 11560.84 3.95 17348.90 90.82 311.44 3900.99 11622.88 N 10651.72 W 11622.88 0.46 17442.39 90.85 312.31 3899.62 11685.28 N 10721.32 W 11685.28 0.93 17535.87 88.50 311.97 3900.15 11747.99 N 10790.63 W 11748.00 2.54 17629.26 90.78 314.63 3900.74 11812.03 N 10858.59 W 11812.03 3.75 17722.75 90.51 317.50 3899.69 11879.35 N 10923.44 W 11879.35 3.08 17816.17 89.90 318.79 3899.35 11948.93 N 10985.78 W 11948.93 1.53 17909.49 90.85 318.34 3898.74 12018.89 N 11047.53 W 12018.89 1.13 18002.93 91.54 319.03 3896.79 12089.05 N 11109.21 W 12089.05 1.04 18096.37 89.50 317.22 3895.95 12158.62 N 11171.57 W 12158.62 2.92 18189.72 90.94 310.86 3895.59 12223.48 N 11238.64 W 12223.48 6.99 18283.09 93.39 311.94 3892.06 12285.17 N 11308.62 W 12285.17 2.87 18376.47 87.77 310.38 3891.12 12346.60 N 11378.89 W 12346.60 6.25 18469.85 91.34 309.18 3891.84 12406.34 N 11450.64 W 12406.34 4.03 18563.25 91.38 309.11 3889.62 12465.28 N 11523.05 W 12465.28 0.09 18656.35 91.89 308.26 3886.97 12523.45 N 11595.70 W 12523.45 1.06 18750.08 91.64 308.33 3884.08 12581.51 N 11669.22 W 12581.51 0.28 18843.51 91.88 308.41 3881.21 12639.47 N 11742.44 W 12639.47 0.27 18936.85 91.88 308.24 3878.15 12697.33 N 11815.63 W 12697.33 0.18 19030.23 92.76 308.45 3874.37 12755.21 N 11888.80 W 12755.21 0.97 19123.57 91.34 308.68 3871.03 12813.36 N 11961.74 W 12813.36 1.54 19216.97 91.10 308.28 3869.04 12871.46 N 12034.84 W 12871.46 0.50 19310.46 90.88 308.88 3867.43 12929.76 N 12107.91 W 12929.75 0.68 19403.89 89.33 309.58 3867.26 12988.84 N 12180.28 W 12988.84 1.82 19497.28 89.39 309.56 3868.30 13048.33 N 12252.26 W 13048.33 0.07 19590.50 90.34 309.91 3868.52 13107.92 N 12323.95 W 13107.92 1.09 19683.38 90.93 309.86 3867.49 13167.47 N 12395.22 W 13167.47 0.64 19776.62 91.44 310.52 3865.56 13227.63 N 12466.43 W 13227.63 0.89 19870.08 90.88 309.90 3863.67 13287.95 N 12537.79 W 13287.95 0.89 19963.42 90.13 310.03 3862.85 13347.90 N 12609.32 W 13347.90 0.82 20056.08 89.49 308.67 3863.15 13406.65 N 12680.97 W 13406.65 1.62 20150.29 88.49 308.43 3864.81 13465.36 N 12754.64 W 13465.36 1.09 20243.77 87.16 309.07 3868.36 13523.82 N 12827.49 W 13523.82 1.58 20337.19 87.15 310.08 3873.00 13583.27 N 12899.40 W 13583.27 1.08 20430.55 88.88 310.01 3876.23 13643.29 N 12970.83 W 13643.29 1.85 20523.89 87.72 310.23 3879.00 13703.41 N 13042.17 W 13703.41 1.26 20617.31 88.58 310.21 3882.02 13763.71 N 13113.47 W 13763.71 0.92 20710.68 89.69 310.47 3883.43 13824.14 N 13184.63 W 13824.14 1.22 20804.04 93.03 310.86 3881.21 13884.95 N 13255.41 W 13884.95 3.60 20897.42 90.86 307.39 3878.04 13943.82 N 13327.80 W 13943.82 4.38 20990.84 91.00 307.59 3876.52 14000.67 N 13401.92 W 14000.67 0.26 21053.34 90.84 308.18 3875.52 14039.05 N 13451.24 W 14039.05 0.98 21118.00 90.84 308.18 3874.57 14079.01 N 13502.06 W 14079.01 0.00 CALCULATION BASED ON MINIMUM CURVATURE METHOD SURVEY COORDINATES RELATIVE TO WELL SYSTEM REFERENCE POINT TVD VALUES GIVEN RELATIVE TO DRILLING MEASUREMENT POINT VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION IS COMPUTED ALONG A DIRECTION OF 0.00 DEGREES (TRUE) A TOTAL CORRECTION OF 0.00 DEG FROM MAGNETIC NORTH TO TRUE NORTH HAS BEEN APPLIED HORIZONTAL DISPLACEMENT IS RELATIVE TO THE WELL HEAD. HORIZONTAL DISPLACEMENT(CLOSURE) AT 21118.00 FEET IS 19507.03 FEET ALONG 316.20 DEGREES (TRUE) Date Printed:07 November 2012 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 16000 17000 18000 19000 20000 21000 0 5 10 15 20 25 30 35 Me a s u r e d D e p t h Rig Days Prognosed Actual SP10-FN5 Days vs. Depth 02 Sep 2012 Reached surface TD at 1645 hrs 3,690' MD / 2,428' TVD 13 Sep 2012 Run & Land 9 5/8" casing at 11,919' MD 17 Sep 2012 RIH with BHA #3, FIT to13.0 ppg EMW, Drill ahead 04 Sep 2012 Run & Land 13 3/8" casing at 3,674' MD 07 Sep 2012 RIH with BHA #2, LOT 12.0 ppg EMW, Drill ahead 27 Aug 2012 SDL rig up unit and gas equipment 31 Aug 2012 Pre Spud meeting and spud the well 10 Sep 2012 Reached intermediate TD at 0330 hrs 11,939' MD / 3,904' TVD 24 Sep 2012 Reached production TD at 0545 hrs 21,118' MD/ 3,874' TVD Surface Data Logging After Action Review Employee Name: Leigh Ann Rasher Date: 02-Sep-2012 Well: SP10-FN5 Hole Section: Surface What went as, or better than, planned: Rigging up for this well went very smooth and we did not run into any difficulties. The surface section went well and we hit TD earlier than expected. There was good communication between loggers and rig crew members during surface section especially when we were on the lookout for potential high gas around 1900' MD. The gas equipment and INSITE operated as they should and we did not run into any major issues Difficulties experienced: We received the ARUBA network box and are waiting to rig up the same. Communication with GCI has been very limited making it difficult to troubleshoot the ARUBA box. We are also experiencing moisture through the poly flow lines and still waiting on a quick disconnect before using the Vortex Cooler which will help eliminate the moisture. Recommendations: Bring the ARUBA network box online so town can assist with troubleshooting. Comission Vortex Cooler as soon as possible to eliminate moisture for polyflow lines and protect gas gear. Innovations and/or cost savings: None for this section. Surface Data Logging After Action Review Employee Name: Alexander Kalenuik Date: 14-Sept 2012 Well: SP10-FN5 Hole Section: Intermediate What went as, or better than, planned: Insite worked as it was supposed to with minimal to no problems. Difficulties experienced: Troubleshooted Vortex Cooler with minimal success. Will wait till next casing break to continue working with Vortex Cooler. Had a WITS issue with Canrig that caused the mudlog some gaps in data. Recommendations: None at this time. Innovations and/or cost savings: None for this section. Surface Data Logging After Action Review Employee Name: Leigh Ann Rasher Date: 24-Sep-2012 Well: SP10-FN5 Hole Section: Production What went as, or better than, planned: During casing break, we took the time to replace the old sample line with a new one. The operation went very smoothly due to preplanning, prejob safety meetings, and JSA's. Difficulties experienced: There was an issue with Iris, the pump configurations were reset while drilling. We had an issue with the depth jumping ahead a few feet during connections. The upper gas trap functioned well after having some troubles getting it running right before they started drilling this section. The top plate on the gas trap motor was bent inwards from being raised up too high. After taking the gas trap out of the possum belly and bending out the metal plate the motor was able to function properly. We were also able to replace a broken aggitator blade on the lower gas trap before they started this section. Recommendations: The vortex cooler is all rigged up and ready to be tested. This should be used during next well to reduce the amount of moisture in the poly flow line. Innovations and/or cost savings: None for this section.