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Home My WebLink About209-0717. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU C-18B Isolate Brookian, Restore Ivishak Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 209-071 50-029-20785-02-00 341J, Statewide ADL 0028304, 0028305 15089 Conductor Surface Intermediate Liner Liner 8781 80 2894 12038 734 3509 10190 20" x 30" 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" x 2-7/8" 6915 34 - 114 33 - 2927 32 - 12070 11550 - 12284 11580 - 15089 2520 34 - 114 33 - 2676 32 - 8229 7853 - 8393 7874 - 8781 Unknown, 15051 2670 4760 5410 10530 10190, 11562, 13208 5380 6870 7240 10160 9819 - 15015 6671 - 8785 4-1/2" 12.6#, 5-1/2" 17# x 4-1/2" 12.6# L80 31 - 10272, 10271 - 11638 Structural 4-1/2" HES TNT Packers (2 ea.) 5-1/2" BOT Packer 9693, 6592 / 9996, 6876 11506, 7822 Date: Torin Roschinger Operations Manager Leif Knatterud leif.knatterud@hilcorp.com (907) 564-5026 PRUDHOE BAY, Prudhoe Oil / 9/17/2025 Current Pools: Prudhoe Oil / Brookian Undefined Proposed Pools: Prudhoe Oil / Brookian Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov No SSSV Installed By Grace Christianson at 1:19 pm, Sep 03, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.09.03 12:39:58 - 08'00' Torin Roschinger (4662) 325-543 MITT to 2750 psi to verify sleeve is shifted closed and Brookian isolated before opening up to the Ivishak. A.Dewhurst 09SEP25 DSR-9/9/25 10-404 JJL 9/5/25JLC 9/10/2025 Gregory C Wilson Digitally signed by Gregory C Wilson Date: 2025.09.10 13:59:45 -08'00'09/10/25 RBDMS 091125 JSB 1 Return to Ivishak C-18B PTD: 209-071 Well Name:C-18B API Number:50-029-20785-02 Current Status:Operable P Rig:CTU, SL Estimated Start Date:9/17/25 Estimated Duration:3days Regulatory Contact:Abbie Barker First Call Engineer:Leif Knatterud (907) 564-4667 (O)(432) 227-4342 (M) Second Call Engineer:Finn Oestgaard (907) 564-5026 (O)(907) 350-8420 (M) Current Bottom Hole Pressure:2653 psi @ 6,925’ TVD 7.4 PPGE | (Brookian - 5/16/2025) Maximum Expected BHP:3400 psi @ 8,800’ TVD 7.5 PPGE | (Highest Ivishak BHP) Max. Anticipated Surface Pressure:2520psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:1975psi (Taken on 5/16/2025) Min ID:2.30” @ 11,585’ Max Angle:97 Deg @ 12,900’ Brief Well Summary:In October 2024, a RWO replaced the compromised tubing to make the well operable. The completion included a stacker packer assembly over the Brookian interval which was perforated on the rig and accessed by an NCS sleeve in the completion. The well was frac’d in February 2025 as part of a larger Brookian study. The Ivishak production is near marginal GOR, but its return to Operable status is beneficial to GC3s well stock as a cycle well. Objective:Return well to Ivishak Production Coil Tubing- Shift NCS Sleeve/FCO 1. MU Jet Nozzle/Drift BHA. Drift and clean up over NCS sleeve x 5/15/2025: RAN 4-1/2" X-LINE w/ 3" SAMPLE BAILER TO 4,041' SLM (unable to work past - frac sand/ paraffin in tools) 2. MU NCS Innovus Shifting Tool BHA. WSS & NCS hand discretion to utilize agitator in BHA. x NCS Shifting BHA should be configured for shift-frac-close operations. This allows us to shift the sleeves fully closed. x Example BHA:2.0" CTC, 2.25" NO-GO SUB, 2.12" DBPV, 2.12" TJ DISCONNECT (5/8" BALL), 2.0" RUPTURE SUB, 2.78" XO, 2.88" TRIDENT MEMORY GAGE, 2.88" BLAST JOINT, 2.88" XO, 2.88" EQUALIZING VALVE, 3.75" PACKER, 3.76" LOCATOR, 3.06" FLOW CROSSOVER, 3.0" GAGE CARRIER, 3.06" DECOMPRESSION HOUSING, 3.06" XO, 3.77" BULLNOSE 3. RIH w/ NCS Shifting BHA & perform FT of tool at 500’. Once tool is set, pump down the back side of the coil and pressure up well to 500-1000 psi over baseline WHP (~2700 psi). Should pressure up quickly is 3.75” packer is holding. 4. After packer is confirmed to be functioning, PU to release tool. WHP should fall off. Continue RIH to the sleeve at 9,815’ 2 Return to Ivishak C-18B PTD: 209-071 5. Run past the “no-go” of the sleeve and pull back up to engage slips. Slack off to J into the close position, pull primary barrel closed. Slack off to relax slips. 6. Once sleeve is closed, pump on well and pressure up to 500-1000 psi over baseline pressure to ensure sleeve is closed. If PT fails, go through the process of closing the sleeve again. x Contact OE if PT fails a second time 7. If pressure is holding, bring pressure up to 2,750 psi for an MIT-T. 8. MU clean out BHA and RIH to perform FCO to tanks (~115’ of frac sand and parafins. Also see 11/25/24. See pictures in folder.) x Anticipated fill depth is ~10,050 x Clean out down to Junck Catcher at 10,165’ 9. MU pulling BHA and RIH and retrieve junk catcher at 10,165’ 10. MU second pulling BHA and retrieve Evotrieve Plug at 10,190’ 11. MU clean out BHA and RIH to perform FCO to tanks (~62’ of sand and RWO debris. See 10/10/24) x Anticipated fill depth is ~11,500 x Clean out down to PX Plug/Nipple Reducer at 11,562’ 12. RDMO Slickline – Pull PX Plug and Nipple Reducer 1. Pull PX Plug and nipple reducer at 11,562’ Operations – POP 1. POP well until HGOR Coil Tubing- Mill CIBP 1. MU motor/2.70” Mill. Mill SELRT Bushing at 11,585’. 2. MU motor/Venturi burnshoe, mill 3-3/16” Extended Range CIBP (13,208’) & recover/push to XO. 3. MU motor/Mill, mill/push CIBP to PBTD (15,051’) x Last plug mill-7/29/23: 2.30” YJ 2.25" 4 Bladed Junk Mill. Dry Tag CIBP at 14,166.2' CTMD. Mill 4.5 hours stalling not making depth. POOH. No wear middle of 4 blade junk mill. MU 2.28" ventrui/burnshoe. RIH w/ YJ 2.06" Venturi Junk Basket & 2.28" Burnshoe. Dry Tag on CIBP at 14,161.5'. Mill plug and push to PBTD x Due to min ID @ liner top, use 2.25” burn shoe to reduce risk of sticking a possibly flared shoe x Decrease speed to 10fpm across liner top when pulling out with burn shoe. x Record shoe OD in AWGRS after milling operation 3 Return to Ivishak C-18B PTD: 209-071 Contingent Slickline - Set Dreamcatcher 1. Set dream catcher if coil cannot push plug to bottom 2. Pull dream catcher after a minimum of one month Attachments: x Current Wellbore Schematic x Sundry Change Form (Closed) 2.70" Proposed 4 Return to Ivishak C-18B PTD: 209-071 Current Wellbore Schematic 5 Return to Ivishak C-18B PTD: 209-071 Current Wellbore Schematic (Pg 2) 6 Return to Ivishak C-18B PTD: 209-071 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HNS Prepared By (Initials) HNS Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU C-18B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 209-071 50-029-20785-02-00 15089 Conductor Surface Intermediate Liner Liner 8781 80 2894 12038 734 3509 10190 20" x 30" 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" x 2-7/8" 6915 34 - 114 33 - 2927 32 - 12070 11550 - 12284 11580 - 15089 34 - 114 33 - 2676 32 - 8229 7853 - 8393 7874 - 8781 Unknown, 15051 2670 4760 5410 10530 10190, 11562, 13208 5380 6870 7240 10160 9819 - 15015 # 4-1/2" 12.6#, 5-1/2" 17# x 4-1/2" 12.6# L80 31 - 10272, 10271 - 11638 6671 - 8785 Structural 4-1/2" HES TNT Packers (2) 11506, 7822 9639, 9996, 11506 6592, 6786, 7822 Torin Roschinger Operations Manager Brodie Wages david.wages@hilcorp.com 907.564.5006 PRUDHOE BAY, Prudhoe Oil / Brookian Undefined Oil Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028304, 0028305 31 - 6971, 6970 - 7915 Perforations from 9819 - 9840 See attached Fracture Stimulation Report 84 111 6500 3800 6 61 1400 1570 310 360 324-688 13b. Pools active after work:Prudhoe Oil / Brookian Undefined Oil 5-1/2" BOT Packer 9693, 6592 / 9996, 6786 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations No SSSV Installed By Grace Christianson at 3:54 pm, Mar 20, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.03.20 06:53:36 - 08'00' Torin Roschinger (4662) DSR-3/28/25 RBDMS JSB 032725CDW 03/25/2025 ACTIVITY DATE SUMMARY 1/11/2025 ***WELL S/I ON ARRIVAL*** RAN 4-1/2" BRUSH, 3.80" G-RING, CLEANED UP TIGHT SPOT @ 9785' SLM, MADE SEVERAL BRUSH PASSES THROUGH X-NIP @ 10070' MD SET 3.81" X-LOCK w/ FLOW THRU SUB & DUAL SPARTEK GAUGES(lih=83", sec lockdown installed, battery connected @ 10:10 01-11-25) IN X-NIP @ 10070' MD RAN 4-1/2" CHECK SET TO X-LOCK @ 10070' MD (sheared) ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** 1/14/2025 ***WELL S/I ON ARRIVAL*** RAN KJ, 1.99" CENT, SBHPS PER PROGRAM (GOOD DATA) ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** 2/8/2025 LRS 70. Assist Frac (FRACTURING) Test PRVs to 3400 psi. Pad-Op notified upon LRS departure. 2/9/2025 Assist Frac Crew LRS Unit 76 (FRACTURING) Heat 5 frac tanks w/ 2000 BBLS of 3% KCL to 90*. ***Job Cont to 2-10-25 WSR*** 2/10/2025 MIRU SLB Frac, Oil State Tree Saver, LRS IA pump. Pressure test treating iron and tree saver to 8264psi. LRS pressure up IA to 3,100psi Load well with 20bbls of 28# linear gel, perform DFIT with 45bbls of 28# of linear gel. Pump mini frac with 176bbls of XL 28# gel at 20 BPM Flush mini frac with 157 bbls for 28# linear gel Perform step rate test with 102 bbls of 28# linear gel Pump 24bbls of 15% HCL Perform step rate test with 211bbls of 28# linear gel Freeze Protect well with 30bbls of Diesel Shut down for the night to reload acid and 100 mesh sand for scour. ***Job Continued on WSR 2/11/25*** 2/10/2025 ***Job Cont from 02-09-2025 WSR** Heat DSL tanker (FRACTURING) Heat and transfered 135 bbls 85* DSL from Worley tanker to Frac tanker. 2/10/2025 Assist w/Frac holding IA pressure Pumped 33 bbls diesel to pressure up on IA. Maintain IA pressure as directed by SLB Frac Filled up Frak dsl tanker to 130 bbls @ 90* 2/11/2025 Assist w/Frac Ops Maintain IA pressure as requested Pumped 6 bbls diesel to pressure up to 3100 psi Daily Report of Well Operations PBU C-18B Daily Report of Well Operations PBU C-18B 2/11/2025 ***Job Continued from 2/10/25 WSR*** Pressure test treating iron and tree saver to 8249psi, LRS pressure up IA to 3,100psi Load well with 27.7bbls of 28# linear gel Pump 120bbls of 15% HCL, spot with 193bbls of 28# linear gel performing soak cycles with acid in the formation. Pump step rate test with 50bbls of 28# linear gel Pump 3,000# 100 mesh scour with 215bbls of 28# linear gel Pump 429 bbl 28# XL Pad at 24 BPM Pump Fac as follows 1.0 PPA 20/40 CarboLite 75bbls 28# XL 2.0 PPA 20/40 CarboLite 117bbls 28# XL 3.0 PPA 20/40 CarboLite 135bbls 28# XL 4.0 PPA 20/40 CarboLite 154bbls 28# XL 5.0 PPA 20/40 CarboLite 19.1bbls 28# XL Well Screened out when 4 PPA hit perfs. ~55K prop pumped, 3k 100 mesh sand, 52k 20/40 CarboLite. ~27k Placed behind pipe. Freeze protected tree with 6.8bbls of diesel, Pull Tree Saver and Rig Down Frac equipment. ***Job Complete*** 2/12/2025 T/I/O=860/650/20 Freeze Protect Tbg ( Frac ) Pumped 1.5 bbl diesel down tbg, pressured up to 3000 psi. TP fell off to 1745 psi after 30 mins. Pumped 1 bbl diesel to 3500 psi. Bled 1 bbl back to 1000 psi. Slickline attempted to RIH and pull top DGLV. Pump 1.2 bbls diesel down tbg. Tbg lost 94 psi in 1 hour ffrom 3550 psi. Bled Tbg to 1000 psi and got back 1.2 bbls DSL. Pad Op notified of well status per LRS departure. SV,WV,SSV=C MV=O IA,OA=OTG HL and Choke=SI 2/12/2025 ***WELL S/I ON ARRIVAL*** RAN 4 1/2" SLIPSTOP CATCHER TO 2,173' SLM (Unable to work deeper, frac sand in catcher) RAN 2 1/2" SAMPLE BAILER TO 4,015' SLM (Run aborted, bailer empty) ***WELL S/I ON DEPARTURE*** 2/16/2025 CTU #2 w/2"x.156" WT HT-95. Job Objective: Post frac FCO Travel to C-pad. MIRU CTU. RIH w/2" reverse out BHA ***Continued to WSR on 2/17/25*** 2/17/2025 CTU #2 w/2"x.156" WT HT-95. Job Objective: Post frac FCO RIH w/2" reverse out BHA, dry tag CarboLite at 7972' CTMD. Attempt to pump down the CT with 60/40 spear, but well locked up, found return line to tanks was frozen. POOH and pump 60/40 down CTBS to FP well. Tarp and thaw hardline. RIH while forward circulating KCL down to 3500', pump bottoms up and start reverse circulating while RIH. Start cleaning out frac sand from previous tag at 7972. Clean out to 8,170' then shut down for 3 hrs due to lack of vac truck support. Resume clean out at 8,170' to 9650 ***Continued to WSR on 2/18/25*** 2/18/2025 CTU #2 w/2"x.156" WT HT-95. Job Objective: Post frac FCO Continue reverse FCO 9650. Shut down for 3 hours for vac truck availability. 1 truck down for wiring issue, another had blown steering tire while traveling. Resume reverse FCO down to 10043E, 10078M. pump clean gel sweep from bottom. POOH, FP CT with 56bbls diesel and well down to 2500' w/38bbls diesel. RDMO ***Job Complete*** Daily Report of Well Operations PBU C-18B 2/18/2025 ***WELL S/I ON ARRIVAL*** (Fracturing) RIGGED UP POLLARD #61 ***CONTINUE ON 2/19/25 WSR*** 2/19/2025 ***CONTINUED FROM 2/18/25 WSR*** (Fracturing) RAN 3.79" GAUGE RING, 4-1/2" BRUSH & 3" SAMPLE BAILER TO 10,030' SLM (unable to work deeper, frac sand in bailer) BAILED FRAC SAND FROM 10,030' SLM - 10,050' SLM (recovered ~10 gallons) ***CONTINUE ON 2/20/25 WSR*** 2/20/2025 ***CONTINUED FROM 2/19/25 WSR*** (Fracturing) BAILED FRAC SAND DOWN TO GAUGES AT 10,070' MD (recovered ~5 gallons) PULLED DOWNHOLE GAUGES AT 10,070' MD BAILED FRAC SAND FROM 10,056' SLM - 10,059' SLM (recovered 2 gallons) ***CONTINUE ON 2/21/25 WSR*** 2/21/2025 LRS WTU #6, Begin WSR, Post Frac Flowback, Rig Mobilization, Standby for OSL, Cont WSR on 2/22/25 2/21/2025 ***CONTINUED FROM 2/20/25 WSR*** (Fracturing) BAILED FRAC SAND FROM 10,059' - 10,065' SLM (~6 gallons) RAN 4-1/2" BRUSH & 3.79" GAUGE RING TO 10,065' SLM SET FLOW-THRU SUB W/ SPARTEK GAUGES AT 10,070' MD (confirmed w/ check set) ***CONTINUE ON 2/22/25 WSR*** 2/22/2025 ***CONTINUED FROM 2/21/25 WSR*** (Fracturing) PULLED RK-DGLV AT ST# 1 (9,545' md) & ST# 2 (7,397' md) MADE MULTIPLE ATTEMPTS TO PULL RK-DGLV AT ST# 3 (3,961' md) (unable to latch) RAN 1.70" LIB TO ST# 3 AT 3,961' MD (picture of trash) MADE MULTIPLE ATTEMPTS TO SET RK-LGLV AT ST# 2 (7,397' md) (unable to sit down) MADE MULTIPLE ATTEMPTS TO SET RK-OGLV AT ST# 1 (9,545' md) (tools falling past mandrel) ***CONTINUE ON 2/23/25 WSR*** 2/22/2025 LRS WTU #6, Cont WSR from 2/21/25, IL C-18 / OL C-18KF, Post Frac Flowback, Standby for OSL, Cont WSR on 2/22/25 2/23/2025 LRS WTU #6, Cont WSR from 2/22/25, IL C-18 / OL C-18KF, Post Frac Flowback, Standby for OSL, MIRU, Cont WSR on 2/24/25 2/23/2025 T/I/O =450/700/0 (TFS Unit 1 Assist S-Line w/ Brush & Flush ) Pumped 10 bbls Crude down IA for SL. Further pumped 32 bbls Crude down TBG for B&F. FWHPS = 700/700/0 Pollard SL in control of well upon TFS departure 2/23/2025 ***CONTINUED FROM 2/22/25 WSR*** (Fracturing) SET RK-OGLV IN STA #1 @ 9,545' MD SET RK-LGLV IN STA #2 @ 7,397' MD PULLED RK-DGLV FROM STA #3 @ 3,961' MD SET RK-LGLV IN STA #3 @ 3,961' MD ***WELL LEFT S/I ON DEPARTURE, PAD-OP NOTIFIED OF STATUS*** 2/24/2025 LRS WTU #6, Cont WSR from 2/23/25, IL C-18 / OL C-18KF, Post Frac Flowback, Cont RU, PT, pop/flow Cont WSR on 2/25/25 2/25/2025 LRS WTU #6, Cont WSR from 2/24/25, IL C-18 / OL C-18KF, Post Frac Flowback, Cont flowing and opening the choke, PBWT, Cont WSR on 2/25/25 Daily Report of Well Operations PBU C-18B 2/26/2025 LRS WTU #6, Cont WSR from 2/25/25, IL C-18 / OL C-18KF, Post Frac Flowback, PBWT, Flowback, Cont WSR on 2/27/25 2/27/2025 LRS WTU #6, Continue WSR from 2/26/25, Post Frac Flowback, 6 Hr WellTest, 10.5 hr WT , End WSR on 2/28/25 2/27/2025 Freeze Protect FL for Well Test. Pumped 9 BBLS of 60/40 and 120 BBLS of Crude down FL, using the Westside recipe, Tag and flag hung on W.V. **** Job continues to 02-28-2025 **** 2/28/2025 LRS WTU #6, begin WSR on 2/28/25 RD, Weather Standby,RDMO, End WSR on 2/28/25 2/28/2025 **** Job continues from 02-27-2025 **** Freeze Protect hardline for Well Test. Pumped 5 BBLS of 60/40. Tags and flag hung on hardline quater turn vavle. Pad Op notified of well status upon departure. FracCAT Treatment Report Well : C-18 B Field : Prudhoe Bay Formation : Brookian Well Location : Greater Prudhoe Bay State : Alaska Country : United States Prepared for Client : Hilcorp Client Rep : David Wages Date Prepared : 2/10/25 Prepared by Name : Michael Hyatt Division : Schlumberger Phone : 907-227-9897 Pressure (All Zones) Initial Wellhead Pressure on Day 1 (psi)534 Surface Shut in Pressure(psi)977 Initial Wellhead Pressure on Day 2 (psi)689 Maximum Treating Pressure (psi)5,636 Final Surface ISIP (psi)Screenout Treatment Totals (All Zones As Per FracCAT) Total Slurry Pumped (Water+Adds+Proppant) (bbl)2,309.8 Total Proppant Pumped per Lynden (lb)160,000 Total YF128ST Past Wellhead (bbl)1,051 Total Proppant in Formation per FracCat (lb)33,020 Total WF128 Past Wellhead (bbl)1,021 Total Freeze Protect Past Wellhead (bbl)6.5 Total 15% HCl Past Wellhead (bbl)142.9 Chemical Additives Mixed / Used Past WH Chemical Additives Mixed / Used Past WH J580 (lb)2,938 2,374 M275 (lb)30 24 F103 (gal)92 91.5 J753 (gal)5 4 L065 (gal)85 84.5 J475 (lb)495 493 J532 (gal)123 123 J134 (lb)12 0 D206 (gal)2 2 Diesel 55.1 6.5 Disclaimer Notice This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. Client: Hilcorp Well: C-18 B Formation: Brookian District: AKA Country: United States Client: Hilcorp Well: C-18 B Formation: Brookian District: AKA Country: United States Day 1 Summary On February 10, 2025 SLB performed a hydraulic fracturing treatment on C-18B. The day started with the crew arriving on location at 6am. Equipment was started and allowed to warm up. There were some delays in the morning while waiting for the last loads of brine to arrive on location. During this period, SLB performed the pressure tests, bucket checks on all liquid additive systems and the dry add feeders on the POD. The safety meeting was held at 11:45, and gel was mixed after this meeting. Gel viscosity was confirmed and the treatment began at 12:45. The day’s schedule consisted of pumping a DFIT, DataFRAC, two step rate tests and 1,000 gallons of HCl. A step rate test was performed before and after the acid. After the final step rate test, the Hilcorp engineer made the decision to suspend pumping the main treatment and source 100 mesh and have SLB blend an additional 5,000 gallons of HCl. Both would be pumped the next day. The below graphs and tables will summarize the day’s activities: 13:32:04 14:22:04 15:12:04 16:02:04 16:52:04 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 7000 8000 Pressure - psi0 5 10 15 20 25 30 35 40 45 Rate - bbl/minTreating Pressure Annulus Pressure BHP Slurry Rate Displace Surface DFIT DataFrac Step Rate HCl Step Rate Pre Job Analysis © Schlumberger 1994-2017 HilcorpC-18B2-10-2025 Client: Hilcorp Well: C-18 B Formation: Brookian District: AKA Country: United States As Measured Pump Schedule As Measured Pump Schedule Step # Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 Load Hole 20.7 5.1 4.3 WF128 870 0.0 0.0 0 2 DFIT 20.1 4.9 4.2 WF128 845 0.0 0.0 0 3 DFIT 25.3 8.1 3.7 WF128 1064 0.0 0.0 0 4 MiniFrac 176.1 11.8 15.8 YF128ST 7394 0.0 0.0 0 5 MiniFrac Flush 157.5 20.0 8.0 WF128 6616 0.0 0.0 0 6 Step Rate 102.5 18.6 6.9 WF128 4306 0.0 0.0 0 7 Acid 23.8 15.2 21.4 HCl 15 1000 0.0 0.0 0 8 Step Rate 211.3 4.7 6.7 WF128 8875 0.0 0.0 0 9 Freeze Protect 30.6 4.7 6.7 Freeze protect 1286 0.0 0.0 0 Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 Load Hole 5.1 5.6 3345 4240 533 2 DFIT 4.9 5.1 3291 3506 1502 3 DFIT 8.1 10.0 3565 3840 1479 4 MiniFrac 11.8 20.1 3848 4495 3560 5 MiniFrac Flush 20.0 20.0 4282 4513 1363 6 Step Rate 18.6 24.5 4109 4643 1362 7 Acid 15.2 24.2 3859 4675 4 8 Freeze Protect 4.7 5.4 3181 3407 27 As Measured Totals Slurry (bbl) Pump Time (min) Clean Fluid (gal) Proppant (lb) 768.0 70.9 32256 0 Average Treating Pressure:3912 psi Maximum Treating Pressure:4675 psi Minimum Treating Pressure:4psi Average Injection Rate:14.7 bbl/min Maximum Injection Rate:24.5 bbl/min Average Horsepower:1479.8 hhp Maximum Horsepower:2780.1 hhp Maximum Prop Concentration:0.0 PPA Client: Hilcorp Well: C-18 B Formation: Brookian District: AKA Country: United States Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 8:05:41 PJSM 0 0 0.0 0.0 0.0 2 8:31:48 Flooding lines 0 353 0.0 0.0 0.0 3 8:49:55 Priming Pumps 29 354 0.0 0.0 0.0 4 9:31:01 Starting PT 22 354 0.0 0.0 0.0 5 9:37:58 Good Check valve 2314 353 0.0 0.0 0.0 6 9:55:46 Good PT 8110 354 0.0 0.0 0.0 7 10:03:14 Bucket testing Dry adds 4 354 0.0 0.0 0.0 8 11:45:08 PJSM 13 355 0.0 0.0 0.0 9 12:01:16 Mixing Gel 10 355 0.0 0.0 0.0 10 12:42:42 Gels Good 6 437 0.0 0.0 0.0 11 12:45:46 Start Load Hole Automatically 6 499 0.0 0.0 0.0 12 12:45:46 Start No name Automatically 6 499 0.0 0.0 0.0 13 12:45:46 Start Stage 1 Automatically 6 499 0.0 0.0 0.0 14 12:45:53 Started Pumping 6 503 0.0 0.0 0.0 15 13:37:09 Started Pumping 1704 2516 0.0 0.0 0.0 16 13:38:38 Open Well 905 2514 0.0 0.0 0.0 17 13:39:22 Open Well 535 2514 0.0 0.0 0.0 18 13:41:18 Activated Extend Stage 683 2514 0.0 0.0 0.0 19 13:57:20 Deactivated Extend Stage 1643 2921 20.7 0.0 0.0 20 13:57:20 Start DFIT Manually 1643 2921 20.7 0.0 0.0 21 13:57:34 Activated Extend Stage 2060 2939 20.8 2.6 0.0 22 14:23:29 Deactivated Extend Stage 1501 2965 40.8 0.0 0.0 23 14:23:29 Start DFIT Manually 1501 2965 40.8 0.0 0.0 24 14:27:32 Activated Extend Stage 3800 3053 54.9 9.9 0.0 25 14:28:40 Deactivated Extend Stage 3758 3065 66.2 10.0 0.0 26 14:28:40 Start MiniFrac (20 Manually 3758 3065 66.2 10.0 0.0 27 14:30:19 Activated Extend Stage 3693 3086 82.6 10.0 0.0 28 14:37:52 Stage at Perfs: Load Hole 3590 3170 158.4 10.1 0.0 29 14:41:55 Stage at Perfs: DFIT 3808 3145 199.2 10.1 0.0 30 14:43:36 Stage at Perfs: MiniFrac (20 4448 3106 224.5 19.9 0.0 31 14:44:29 Deactivated Extend Stage 4494 3119 242.2 20.0 0.0 32 14:44:29 Start MiniFrac Flu Manually 4494 3119 242.2 20.0 0.0 33 14:44:45 Activated Extend Stage 4509 3124 247.5 19.9 0.0 34 15:27:01 Deactivated Extend Stage 1362 3062 399.7 0.0 0.0 35 15:27:01 Start Step Rate (St Manually 1362 3062 399.7 0.0 0.0 36 15:27:26 Stage at Perfs: MiniFrac Flu 2744 3111 400.8 4.4 0.0 37 15:28:57 Activated Extend Stage 4091 3151 416.9 14.5 0.0 38 15:58:09 Deactivated Extend Stage 1379 3119 502.3 0.0 0.0 39 15:58:09 Start Acid (option Manually 1379 3119 502.3 0.0 0.0 40 15:59:28 Activated Extend Stage 3435 3190 505.9 4.9 0.0 41 16:07:58 Stage at Perfs: Step Rate (St 3634 3065 558.2 10.0 0.0 42 16:15:42 Stage at Perfs: Acid (option 4658 3136 660.7 24.0 0.0 43 16:57:04 Closed Well 1394 3062 737.4 0.0 0.0 Client: Hilcorp Well: C-18 B Formation: Brookian District: AKA Country: United States Day 2 On February 11, 2025 SLB performed a hydraulic fracturing treatment on C-18B. The day started with the crew arriving on location at 6am. Equipment was started and allowed to warm up. While warming up the equipment on location, SLB had operators at the base mixing the 5,000 gallons of HCl. At 12:10 the well was open and the acid was being pumped at 12:30. Following the acid, a step rate was performed and the pressures were analyzed by Hilcorp engineers. Once the data had been analyzed, the pump schedules was modified. A 3,000 pound scour of 100 mesh would be pumped ahead of the Pad. In addition to the scour, Pad volume was increased to 429 bbl and the remaining proppant stages were changed as well. The 9 and 10 ppa steps were removed and only a small 8ppa step would be pumped. Due to the increased volume of fluid an additional amount of gel was delivered to location along with another vac truck of brine. The stage started with a 0.5 and 0.75 ppa scour. Treating pressure remained relatively flat as the proppant was going into formation. Once the 20/40 was being pumped, pressure decreased by about 500 psi once it was entering formation. Pressure generally decreased as proppant was going into formation. During the middle of the 4ppa step, SLB lost communication with a pump and rate decreased to about 18 bpm. Increasing the rate with other pumps, it was determined to keep a constant rate of 22 bpm. Once rate stabilized, pressure dropped and leveled back out. About 15 bbl after pressure and rate stabilized, 4 ppa started to enter the formation. As 4 ppa was entering formation, pressure started to increase and rate was dropped to reduce the effect of pressure. Over a short period of time, the well pressure out. This event was controlled by the pump trips and the GORV did not activate. A maximum pressure of 5,636 was witnessed during the screenout. A total of 55,813 pounds of proppant were pumped in 1,541 bbl of slurry. 33,940 pounds of proppant were placed into location. After the screenout, the crew opened the choke to bleed back the well and force closure. Once pressure had been bled off as much as possible, 6.5 bbls of diesel was pumped to freeze protect the wellhead and allow the treesaver to be pulled. The below graphs and tables will summarize the day’s activities: Client: Hilcorp Well: C-18 B Formation: Brookian District: AKA Country: United States As Measured Pump Schedule 11:35:41 12:17:21 12:59:01 13:40:41 14:22:21 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 7000 Tr. Press - psi0 5 10 15 20 25 30 35 40 45 Slurry Rate - bbl/min0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Prop Con - PPATreating Pressure Annulus Pressure BHP Slurry Rate Prop Con BH Prop Con Open Well Pumping Acid Step Rate Test Acid Treatment © Schlumberger 1994-2017 Hilcorp C-18B 2-11-2025 14:59:29 15:20:19 15:41:09 16:01:59 16:22:49 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 Tr. Press - psi0 5 10 15 20 25 30 35 40 45 Slurry Rate - bbl/min0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Prop Con - PPATreating Pressure Annulus Pressure BHP Slurry Rate Prop Con BH Prop Con Lost Communication with Pump Pressured Out Main Treatment © Schlumberger 1994-2017 Hilcorp C-18B 2-11-2025 Client: Hilcorp Well: C-18 B Formation: Brookian District: AKA Country: United States As Measured Pump Schedule Step # Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 Load Hole 27.7 4.8 6.0 WF128 1165 0.0 0.0 0 2 Acid 120.7 7.7 16.2 HCl 15 5068 0.0 0.0 0 3 Spot Acid 193.3 13.6 17.4 WF128 8118 0.0 0.0 0 4 Step Rate 49.8 14.3 4.3 WF128 2090 0.0 0.0 0 5 Scour 79.3 24.0 3.3 WF128 3362 CarboLite 20/40 0.6 0.4 1275 6 Scour 135.9 24.1 5.6 WF128 5572 CarboLite 20/40 0.8 0.5 3050 7 PAD 429.0 24.0 17.8 YF128ST 18018 0.0 0.0 0 8 1.0 PPA 75.2 24.0 3.1 YF128ST 3028 CarboLite 20/40 1.1 1.0 2930 9 2.0 PPA 116.5 24.0 4.9 YF128ST 4502 CarboLite 20/40 2.3 2.0 8814 10 3 PPA 134.8 24.0 5.6 YF128ST 5004 CarboLite 20/40 3.6 3.0 14855 11 4 PPA 154.2 22.3 7.0 YF128ST 5506 CarboLite 20/40 4.6 4.0 21927 12 5 PPA 19.1 18.2 1.4 YF128ST 674 CarboLite 20/40 5.6 4.4 2962 13 Freeze Protect 6.5 1.0 6.6 Freeze Protect 272 0.0 0.0 0 Client: Hilcorp Well: C-18 B Formation: Brookian District: AKA Country: United States Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 Load Hole 4.8 6.0 3234 3614 687 2 Acid 7.7 8.1 3342 3680 1592 3 Spot Acid 13.6 24.3 3336 4132 1368 4 Step Rate 14.3 23.6 3325 4187 995 5 Scour 24.0 24.1 4071 4182 3974 6 Scour 24.1 24.4 3827 3987 3734 7 PAD 24.0 24.2 3880 4012 3693 8 1.0 PPA 24.0 24.1 3940 3981 3892 9 2.0 PPA 24.0 24.2 3708 3892 3343 10 3 PPA 24.0 24.3 3181 3341 3068 11 4 PPA 22.3 24.3 3026 3334 2569 12 5 PPA 18.2 21.5 3987 5636 63 13 Freeze Protect 1.0 1.0 2026 2245 8 As Measured Totals Slurry (bbl) Pump Time (min) Clean Fluid (gal) Proppant (lb) 1541.8 99.2 62379 55813 Average Treating Pressure:3583 psi Maximum Treating Pressure:5636 psi Minimum Treating Pressure:8psi Average Injection Rate:20.4 bbl/min Maximum Injection Rate:24.4 bbl/min Average Horsepower:1829.4 hhp Maximum Horsepower:2460.4 hhp Maximum Prop Concentration:5.6 PPA Client: Hilcorp Well: C-18 B Formation: Brookian District: AKA Country: United States Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 9:04:36 Flooding Lines 4 731 0.0 0.0 0.0 2 9:10:37 Priming Pumps 44 730 0.0 5.4 0.0 3 9:39:09 Good Check valve 9 727 0.0 0.0 0.0 4 9:54:01 Good PT 8 725 0.0 0.0 0.0 5 12:06:33 Start Load Hole Automatically 41 2480 0.0 0.0 0.0 6 12:06:33 Start No name Automatically 41 2480 0.0 0.0 0.0 7 12:06:33 Start Stage 1 Automatically 41 2480 0.0 0.0 0.0 8 12:06:38 Started Pumping 1643 2480 0.0 0.7 0.0 9 12:10:13 Open Well 691 2414 0.0 0.0 0.0 10 12:15:23 IA Pop off leaking 756 2395 0.2 0.0 0.0 11 12:17:04 Activated Extend Stage 855 2396 0.2 0.0 0.0 12 12:33:28 Deactivated Extend Stage 1592 3002 27.7 0.0 0.0 13 12:33:28 Start Acid 1592 3002 27.7 0.0 0.0 14 12:36:45 Activated Extend Stage 3462 3085 50.5 8.0 0.0 15 12:49:44 Deactivated Extend Stage 2817 3174 148.4 5.0 0.0 16 12:49:44 Start Spot Acid Manually 2817 3174 148.4 5.0 0.0 17 12:49:50 Activated Extend Stage 2808 3172 148.9 5.0 0.0 18 12:51:29 Stage at Perfs: Load Hole 3069 3184 158.3 8.6 0.0 19 12:54:21 Stage at Perfs: Acid (option 3195 3141 186.1 10.5 0.0 20 13:22:49 Stage at Perfs: Spot Acid 3962 3190 307.1 24.2 0.0 21 13:24:20 Deactivated Extend Stage 3246 3197 341.7 15.9 0.0 22 13:24:20 Start Step Rate 3246 3197 341.7 15.9 0.0 23 13:24:24 Activated Extend Stage 3215 3204 342.7 15.5 0.0 24 15:10:44 Deactivated Extend Stage 4172 3143 391.5 23.8 0.0 25 15:10:44 Start Scour Manually 4172 3143 391.5 23.8 0.0 26 15:10:44 Started Pumping Prop 4172 3143 391.5 23.8 0.0 27 15:13:37 Activated Extend Stage 3984 3145 460.7 24.1 0.5 28 15:14:02 Deactivated Extend Stage 3986 3140 470.8 24.1 0.5 29 15:14:02 Start Scour Manually 3986 3140 470.8 24.1 0.5 30 15:15:10 Stage at Perfs: Step Rate 3906 3143 498.0 24.1 0.7 31 15:15:34 Activated Extend Stage 3849 3139 507.7 24.1 0.7 32 15:17:14 Stage at Perfs: Scour 3757 3137 547.8 24.1 0.7 33 15:18:34 Stopped Pumping Prop 3785 3144 580.0 24.2 0.3 34 15:19:40 Deactivated Extend Stage 3769 3128 606.6 24.2 0.0 35 15:19:40 Start PAD Manually 3769 3128 606.6 24.2 0.0 36 15:20:37 Stage at Perfs: Scour 3753 3149 629.6 24.1 0.0 37 15:26:16 Stage at Perfs: Step Rate 3847 3141 765.3 24.0 0.0 38 15:37:31 Start 1.0 PPA Automatically 3983 3136 1035.7 24.1 0.0 39 15:37:32 Started Pumping Prop 3973 3137 1036.1 24.1 0.0 40 15:40:39 Start 2.0 PPA Automatically 3902 3139 1110.8 24.0 1.0 41 15:44:08 Stage at Perfs: PAD 3673 3138 1194.3 23.9 2.3 42 15:45:31 Start 3 PPA Automatically 3322 3132 1227.6 24.2 2.1 43 15:47:15 Stage at Perfs: 1.0 PPA 3180 3136 1269.3 24.2 3.0 44 15:51:07 Start 4 PPA Automatically 3054 3128 1362.1 24.1 3.0 45 15:52:07 Stage at Perfs: 2.0 PPA 3061 3123 1386.1 24.2 4.0 46 15:58:07 Start 5 PPA Automatically 3107 3133 1516.4 21.3 4.0 47 15:58:19 Stage at Perfs: 3 PPA 3482 3140 1520.7 21.4 4.8 48 16:16:50 Stopped Pumping Prop 111 2984 1535.4 0.0 0.1 49 16:24:20 Well Closed 980 2960 1535.4 0.0 0.0 Client: Hilcorp Well: C-18 B Formation: Brookian District: AKA Country: United States Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 50 16:48:37 Started Pumping 8 2262 1535.4 0.0 0.0 51 16:48:40 Start Freeze Protect Manually 8 2261 1535.4 0.0 0.0 52 16:53:10 Open Well 1131 2249 1535.4 0.0 0.0 53 17:13:08 Well Closed 1326 1017 1541.8 0.0 0.0 Hydraulic Fracturing Fluid Product Component Information Disclosure Job Start Date: 02/10/2025 Job End Date: 02/11/2025 State: Alaska County: Beechey Point API Number: 50-029-20785-02-00 Operator Name: Hilcorp Alaska, LLC Well Name and Number: PRUDHOE BAY UNIT C-18B Latitude: 70.298585 Longitude: -148.673075 Datum: NAD27 Federal Well: NO Indian Well: NO True Vertical Depth: 6671 Total Base Water Volume (gal)*: 91850 Total Base Non Water Volume: 0 Water Source Percent Surface Water, < 1000TDS 100.00% Hydraulic Fracturing Fluid Composition: Trade Name Supplier Purpose Ingredients Chemical Abstract Service Number (CAS #) Maximum Ingredient Concentration in Additive (% by mass)** Maximum Ingredient Concentration in HF Fluid (% by mass)** Comments A264A Schlumberger Corrosion Inhibitor A264A D206 Schlumberger Antifoam Agent F103 Schlumberger Surfactant Fluid Schlumberger N/A H036 Schlumberger Acid J475 Schlumberger Breaker J475 J532 Schlumberger Crosslinker J580 Schlumberger Gel J580 J753 Schlumberger Enzyme Breaker J753 L058 Schlumberger Iron Control Agent L058 L065 Schlumberger Scale Inhibitor M275 Schlumberger Bactericide S100 Schlumberger 100 Mesh Sand S522- 2040 Schlumberger Propping Agent W054 Schlumberger Demulsifier U051 Schlumberger Base Oil Items above are Trade Names. Items below are the individual ingredients. Water (Including Mix Water Supplied by Client)*7732-18-5 0.00000 94.44747 None Ceramic materials and wares, chemicals 66402-68-4 65.71776 3.64900 None Hydrochloric acid 7647-01-0 17.04088 0.94620 None Quartz, Crystalline silica 14808-60-7 6.66068 0.36984 None Guar gum 9000-30-0 5.25490 0.29178 None Diammonium peroxodisulphate 7727-54-0 0.87520 0.04860 None 1, 2, 3 - Propanetriol 56-81-5 0.55324 0.03072 None Methanol 67-56-1 0.50030 0.02778 None Sodium tetraborate decahydrate 1303-96-4 0.45176 0.02508 None Ethylene Glycol 107-21-1 0.36623 0.02034 None 2-Propenoic acid, polymer with sodium phosphinate 129898-01-7 0.34219 0.01900 None Propan-2-ol 67-63-0 0.31975 0.01775 None 2-butoxyethanol 111-76-2 0.31755 0.01763 None Ethoxylated C11 Alcohol 34398-01-1 0.29167 0.01619 None Vinylidene chloride/methylacrylate copolymer 25038-72-6 0.20786 0.01154 None Diatomaceous earth, calcined 91053-39-3 0.17334 0.00962 None Ethoxylated Alcohol 68131-39-5 0.15830 0.00879 None Reaction product of: acetophenone, formaldehyde, cyclohexylamine, methanol and acetic acid 224635-63-6 0.09166 0.00509 None Sodium chloride 7647-14-5 0.06844 0.00380 None Cinnamaldehyde 104-55-2 0.05083 0.00282 None Oxirane, Methyl-, polymer with Oxirane 9003-11-6 0.04970 0.00276 None Alcohol, C9-C11, Ethoxylated 68439-46-3 0.03813 0.00212 None Ethoxylated propoxylated 4- nonylphenol-formaldehyde resin 30846-35-6 0.03680 0.00204 None Calcium chloride 10043-52-4 0.03514 0.00195 None Magnesium nitrate 10377-60-3 0.03467 0.00192 None Alcohols, C7-9-iso-, C8-rich, ethoxylated 78330-19-5 0.03395 0.00189 None Sodium erythorbate 6381-77-7 0.03329 0.00185 None Alcohols, C9-11-iso-, C10-rich, ethoxylated 78330-20-8 0.03170 0.00176 None 1-undecanol (impurity) 112-42-5 0.02540 0.00141 None Alcohols, C10-16, ethoxylated 68002-97-1 0.02542 0.00141 None Alcohol, C11-14, ethoxylated 78330-21-9 0.02205 0.00122 None Beta-Mannanase 37288-54-3 0.02074 0.00115 None 5-chloro-2-methyl-4- isothiazolin-3-one and 2- methyl-4-isothiazolin-3-one 55965-84-9 0.02080 0.00115 None Magnesium chloride 7786-30-3 0.01733 0.00096 None Diesel oil #2 68476-34-6 0.01442 0.00080 None Silicon Dioxide (Impurity) 7631-86-9 0.01317 0.00073 None Poly(oxy-1,2-ethanediyl),a- hydro-w-hydroxy- Ethane-1,2- diol, ethoxylated 25322-68-3 0.01125 0.00062 None Acetic acid (impurity) 64-19-7 0.00992 0.00055 None Acetophenone 98-86-2 0.00961 0.00053 None N,N-Dimethyl-N-dodecyl benzylaminium chloride 139-07-1 0.00765 0.00042 None Amines, tallow alkyl, ethoxylated 61791-26-2 0.00763 0.00042 None Solvent naphtha (petroleum), heavy arom.64742-94-5 0.00715 0.00040 None Formaldehyde (impurity) 50-00-0 0.00620 0.00034 None Dimethyl siloxanes and silicones 63148-62-9 0.00581 0.00032 None Magnesium silicate hydrate (talc)14807-96-6 0.00547 0.00030 None poly(tetrafluoroethylene) 9002-84-0 0.00547 0.00030 None 2-Propen-1-aminium, N,N- dimethyl-N-2-propen-1-yl-, chloride (1:1), homopolymer 26062-79-3 0.00515 0.00029 None 2,2''-oxydiethanol (impurity) 111-46-6 0.00370 0.00021 None Siloxanes and silicones, dimethyl, reaction products with silica 67762-90-7 0.00370 0.00021 None Cristobalite 14464-46-1 0.00347 0.00019 None Benzenemethanaminium, N,N- dimethyl-N tetradecyl-, chloride 139-08-2 0.00260 0.00014 None Sodium hydroxide (impurity) 1310-73-2 0.00185 0.00010 None Potassium chloride (impurity) 7447-40-7 0.00185 0.00010 None Acetic acid, potassium salt (impurity)127-08-2 0.00145 0.00008 None Naphthalene (Impurity) 91-20-3 0.00085 0.00005 None Sorbitan stearate 1338-41-6 0.00070 0.00004 None Benzenemethanaminium, N- hexadecylN,N dimethyl-,chloride 122-18-9 0.00055 0.00003 None Potassium oleate 143-18-0 0.00050 0.00003 None 1,2,4 Trimethylbenzene (impurity)95-63-6 0.00055 0.00003 None 2-Propenoic acid, 2-ethylhexyl ester, polymer with 2- hydroxyethyl 2-propenoate 36089-45-9 0.00037 0.00002 None Fatty acids, C18-unsatd., dimers, ethoxylated propoxylated 68308-89-4 0.00037 0.00002 None Siloxanes and Silicones, di-Me, 3-hydroxypropyl Me, ethoxylated propoxylated 68937-55-3 0.00037 0.00002 None Xanthan Gum 11138-66-2 0.00009 0.00001 None Sodium benzoate 532-32-1 0.00015 0.00001 None Sodium carboxymethylcellulose 9004-32-4 0.00009 0.00001 None Sorbitan monooleate polyoxyethylene derivative 9005-65-6 0.00011 0.00001 None Substituted Carboxylic Acid Salt 24634-61-5 0.00007 0.00000 None Tetrahydro-3,5-dimethyl-1,3,5- thiadiazine-2-thione 533-74-4 0.00007 0.00000 None Sodium nitrite 7632-00-0 0.00007 0.00000 None 1,2-Benzisothiazolin-3-one 2634-33-5 0.00004 0.00000 None enzyme 9000-90-2 0.00001 0.00000 None * Total Water Volume sources may include various types of water including fresh water, produced water, and recycled water ** Information is based on the maximum potential for concentration and thus the total may be over 100% Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided. Ingredient information for chemicals subject to 29 CFR 1910.1200(i) and Appendix D are obtained from suppliers Material Safety Data Sheets (MSDS) 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU C-18B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 209-071 50-029-20785-02-00 N/A ADL 0028304, 0028305 15089 Conductor Surface Intermediate Liner Liner 8781 80 2894 12038 734 3509 10190 20" x 30" 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" x 2-7/8" 6915 34 - 114 33 - 2927 32 - 12070 11550 - 12284 11580 - 15089 2376 34 - 114 33 - 2676 32 - 8229 7853 - 8393 7874 - 8781 Unknown, 15051 2670 4760 5410 10530 10190, 11562, 13208 5380 6870 7240 10160 9819 - 15015 6671 - 8785 4-1/2" 12.6#, 5-1/2" 17# x 4-1/2" 12.6#L80 31 - 10272, 10271 - 11638 Structural 4-1/2" HES TNT Packers (2) 5-1/2" BOT Packer 9693, 6592 / 9996, 6786 11506, 7822 Date: Torin Roschinger Operations Manager Michael Hibbert michael.hibbert@hilcorp.com 907-903-5990 PRUDHOE BAY 12/25/2024 Current Pools: Prudhoe Oil / Brookian Undefined Oil Pool Proposed Pools: Prudhoe Oil / Brookian Undefined Oil Pool Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm.MEUIRUMOFComm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 1:54 pm, Dec 06, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.12.06 13:44:08 - 09'00' Torin Roschinger (4662) 324-688 *Per Well Completion Report of 09/02/2009 SFD DSR-12/16/24 10-404 8,815' * Fracture Stimulate CDW 12/10/2024 MGR23DEC24 SFD 12/10/2024 Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2024.12.23 13:52:21 -09'00'12/23/24 RBDMS JSB 122424 Post-RWO – Brookian Wellwork Well: C-18B PTD: 209-071 API: 50-029-20785-02 Well Name:C-18B Permit to Drill:209071 Current Status:Producer API Number:50-029-20785-02 Estimated Start Date:Dec 25, 2024 Estimated Duration:2days Regulatory Contact:Abbie Barker Sundry Number: First Call Engineer:Michael Hibbert (907) 903-5990 (M) Second Call Engineer:Aras Worthington (907) 564-4763 (O)(907) 440-7692 (M) Program Revision:0 Current Bottom Hole Pressure:3060 psi @ 6,835’ TVDssFrom downhole gauges Max Anticipated Surface Pressure:2,376 psi Based on 0.1 psi/ft gas gradient Last SI WHP:2,250 psi 11/24/2024 Min ID:2.30” @ 11,585’ MD SELRT Profile – milled out bushing Max Angle:97 deg @ 13,131’ MD Brief Well Summary: C-18B has been recompleted to the Brookian interval. This procedure and frac application is in addition to Sundry #324-500 for the recomplete work. Objective: Set downhole gauges. Hydraulically fracture stimulation to improve well productivity to further appraise this Brookian interval. Post-frac slickline work and portable test unit flowback and PVT sampling. Current Status: Operable Procedural Steps: Slickline 1. Set downhole gauges w/ 2 second data acquisition frequency in nipple at 10,070’. Frac 1. Conduct Safety meeting, inspect location, and review approved Frac 10-403. 2. Ensure all pre-frac well work has been completed and the tubing and IA are freeze protected. 3. Install Tree saver. 4. MIRU Halliburton frac equipment and associated frac tanks. 5. Pressure test surface lines and tree saver to at least 8,196psi. 6. Test IA Pop-off system to ensure functioning properly. IA Pop-off to be set at 3,406 psi. 7. Bring IA pressure up to hold pressure of 3,106 psi. 8. Pump the fracture stimulation per the proposed pump schedule attached below. Maximum allowable treating pressure is 7,196 psi. Estimated 1,350 bbl of fluid, and 150,000# proppant. 9. RDMO frac equipment. Ensure tubing is freeze protected. Slickline 1. D&T 2. Install GL design 3. Pull downhole memory gauges if possible Coiled Tubing - Contingent CT FCO if necessary 1. FCO down to memory gauges at 10,070’ Hydraulically fracture stimulation to improve well productivity to further appraise this Brookian interval. Maximum allowable treating pressure is 7,196 psi. Post-RWO – Brookian Wellwork Well: C-18B PTD: 209-071 API: 50-029-20785-02 Portable Testers 1. Post Frac flowback 2. Flow well with nitrogen lift for PVT sampling is possible. Attachments – x Current Wellbore Schematic x Sundry Revision Change Form x Detailed Frac Stimulation Procedure Post-RWO – Brookian Wellwork Well: C-18B PTD: 209-071 API: 50-029-20785-02 Current Wellbore Schematic: Post-RWO – Brookian Wellwork Well: C-18B PTD: 209-071 API: 50-029-20785-02 Post-RWO – Brookian Wellwork Well: C-18B PTD: 209-071 API: 50-029-20785-02 Sundry Revision Change Form: Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HNS Prepared By (Initials) HNS Approved By (Initials) AOGCC Approval Rcv’d (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date Date: November 21, 2024 Subject: C-18B Fracture Stimulation From: Michael Hibbert C: (907) 903-5990 To: AOGCC Estimated Start Date: 12/25/2024 Attached is Hilcorp’s proposal and supporting documents to perform a fracture stimulation on well C- 18B in the Brookian reservoir of the undefined pool under Tract Operation PBU PB25. The objective of this program is to perform a single stage fracture stimulation to the existing Brookian perforations to improve well performance. A RWO has been completed in C-18B to re-complete the well to allow for Brookian formation appraisal. The well has been POP’d post-RWO and has shown favorable signs of black oil production and some amount of reservoir energy that could potentially lead to productivity after the proposed fracture stimulation. Hilcorp requests a variance to sections 20 AAC 25. 283, a, 3- 4 which require identification of fresh - water aquifers and a plan for base-water sampling. Please direct questions or comments to Michael Hibbert. Hilcorp requests a variance to sections 20 AAC 25. 283, a, 3- 4 which require identification of fresh - water aquifers and a plan for base-water sampling.Recommend approving requested variance as this well falls within the Affected Area of AEO 1. SFD SECTION 1 - AFFIDAVIT (20 AAC 25.283, a, 1): Below is an affidavit stating that the owners, landowners, surface owners and operators identified on a plat within one-half mile radius of the current or proposed wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283, a 1. SIGNED AFFIDAVIT: COPY OF NOTIFICATION SENT VIA EMAIL: SECTION 2 - PLAT IDENTIFYING ALL WELLS WITHIN ½ MILE (20 AAC 25.283, a, 2): LIST OF WELLS IN PLAT WITHIN ½ MILES ON SURFACE (20 AAC 25.283, a, 2, C): SECTION 3 - EXEMPTION FOR FRESWATER AQUIFERS (20 AAC 25.283, a, 3): Well C-18B is in the West Operating Area of Prudhoe Bay. Per Aquifer Exemption Order No. 1 dated July 11, 1986 where Standard Alaska Production Company requested the Alaska Oil and Gas Conservation Commission to issue an order exempting those portions of all aquifers lying directly below the Western Operating Area and K Pad Area of the Prudhoe Bay Unit for Class II Injection activities. Findings 1- 4 state: 1. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit do not currently serve as a source of drinking water. 2. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit are situated at a depth and location that makes recovery of water for drinking water purposes economically impracticable. 3. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit are reported to have total dissolved solids content of 7000 mg/ I or more. 4. By letter of July 1, 1986, EPA- Region 10 advises that the aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit qualify for exemption. It is considered to be a minor exemption and a non-substantial program revision not requiring notice in the Federal Registrar. Per the above findings, " Those portions of freshwater aquifers lying directly below the Western Operating and K Pad Areas of the Prudhoe Bay Unit qualify as exempt freshwater aquifers under 20 AC 25. 440" thus allowing Hilcorp exemption from 20 AAC 25. 283, a, 3- 4 which require identification of freshwater aquifers and establishing a plan for base-water sampling.Agree. SFD SECTION 4 - PLAN FOR BASELINE WATER SAMPLING FOR WATER WELLS (20 AAC 25.283, a, 4): There are no water wells located within one-half mile of the current or proposed wellbore trajectory and fracturing interval. A water well sampling plan is not applicable. Agree. SFD SECTION 5 - DETAILED CEMENTING AND CASING INFORMATION (20 AAC 25. 283, a, 5): All casing is cemented in accordance with 20 AAC 25.52, b and tested in accordance with 20 AAC 25.030, g when completed. See wellbore schematic for casing details: SECTION 6 - ASSESSMENT OF EACH CASING AND CEMENTING OPERATION TO BE PERFORMED TO CONSTRUCT OR REPAIR THE WELL (20 AAC 25.283, a, 6): Summary: Spudded 4/25/1982 with a 17-1/2” hole to 2,932’ where 13-3/8” surface casing was set and cemented at 2,927’ with 4350 cuft (775 bbls) Arctic Set II followed by a 250 sx (41.4 bbls) cement top job. The 13-3/8” casing was tested to 3,000 psi and the production hole was started. A leak off test of 0.89 psi/ft gradient was obtained. The production hole was directionally drilled to 12,080’ with a 12-1/4” bit. 9-5/8” casing set at 12,070’ and cemented in place with a two-stage cement job: first stage with 1620 cu. ft. of class G cement followed by second stage of cement pumped through the DV collar at 2,829’ with 186 cu. ft. of Arctic Set I proceeded by Arctic Pack. Tested 9-5/8” casing to 3,000 psi. A CBL pulled during a 2024 workover showed a clear TOC at ~2,150’ MD. Finally, an 8-1/2” hole was drilled to 12,956’ where open hole logs were run. The 7” production liner was run and cemented with 456 cuft (~81 bbls) of Class G cement. The 7” liner was successfully pressure tested to 3,000 psi. The well was swapped over to NaCl and 5-1/2” production tubing was run and tested to 3,500 psi. C-18A was sidetracked out of the 7” liner at ~12,603’ MD. 2-7/8” liner was landed in Zone 1. C-18B was sidetracked out of the 7” liner at 12,284’ and drilled to TD where liner was run to 15,089’. The liner was cemented with 36.4 bbls of cement. Cement was displaced within expected volumes, after cement in place, floats held. A RWO in October 2024 was performed to execute an up hole recompleted from the Ivishak reservoir to the Brookian reservoir. The 2-7/8” liner was isolated with a PX plug at 11,562’. The existing 5-1/2” tubing was cut pre-rig and pulled out of hole. A CBL was run to confirm TOC behind 9-5/8” casing (referenced above). The Brookian formation was perforated on rig from 9,819’-9,840’. A new 4-1/2” upper completion was run and set with production packers straddling the Brookian formation. A sliding sleeve between the packers allows for the Brookian formation to be accessed. All casing is cemented in accordance with 210 AAC 25.030 and each hydrocarbon zone penetrated by the well is isolated. Based on engineering evaluation of the wells referenced in this application, Hilcorp has determined that this well can be successfully fractured within well design limits. A new 4-1/2” upper completion was run and set with production packers straddling the Brookian formation. Agree. SFD clear TOC at ~2,150’ MD.Agree. SFD SECTION 7 - PRESSURE TEST INFORMATION AND PLANS TO PRESSURE TEST CASINGS AND TUBING INSTALLED IN THE WELL (20 AAC 25.283, a, 7): On 10/5/2024, the casing was pressure tested to 3,585 psi for a passing MIT-IA. On 11/27/2024, the tubing was pressure tested to 4,562 psi for a passing MIT-T. The production casing annulus pressure will be monitored during the frac, if any change of pressure is seen outside of thermal expansion, the job will be flushed, and the pressure source diagnosed before frac operations continue. Anticipated Pressures: MIT-T 4,500 psi MIT-IA 3,585 psi Maximum Anticipated Treating Pressure:3,200 psi @ 24 BPM IA Pop-off Set Pressure (95% of MIT-IA):3,406 psi IA Minimum Hold Pressure (POP-off – ~300 psi):3,106 psi Maximum Allowable Treating Pressure (MATP = Ann hold + MIT-T/1.1): 7196 psi w/ 3,106 psi on IA Stagger Pump Kickouts Between 90 – 95% of MATP:6,476 – 6,836 psi Global Kickout (95% of MATP):6,836 psi N2 POP-off set pressure (MATP):7,196 psi Treating Line Test Pressure (MATP + 1000 psi):8,196 psi OA Pressure:Monitor Max Anticipated Proppant Loading:10 PPA SECTION 8 - PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE, WELLHEAD, BOPE AND TREATING HEAD (20 AAC 25.283, a, 8): Wellbore Tubular Ratings: Size/Name Weight Grade Burst, psi Collapse, psi 13-3/8” Surface Casing 72#L80 5,380 2,670 9-5/8” Production Casing 47#L80 6,870 4,750 7” Production Liner 26#L80 7,240 5,410 4-1/2” Production Tubing 12.6#L80 8,430 7,500 3-1/2” Production Liner 9.2#L80 10,160 10,540 3-3/16” Production Liner 6.2#L80 8,620 7,820 2-7/8” Production Liner 6.5#L80 10,570 11,170 Wellhead: McEvoy manufactured wellhead, rated to 5,000 psi Tubing head adaptor: 13-5/8", 5,000 psi x 4-1/16", 5,000 psi Tubing Spool: 13-5/8" 5, 000 psi w/ 3-1/8" side outlets Casing Spool: 13-5/8" 5, 000 psi w/ 3-1/8" side outlets Tree: CIW 4-1/16" 5,000 psi. - A 10,000-psi rated TreeSaver will be used during the fracturing operations. SECTION 9 - DATA FOR FRACTURING ZONE AND CONFINING ZONES (20 AAC 25.283, a, 9): SECTION 10 – LOCATION, ORIENTATION, AND A REPORT ON MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFINING ZONE (20 AAC 25.283, a, 10): No faults in proximity to the C-18 area. C-18 frac length estimates are around 70'. Stress orientation is relatively unknown at this location. The plat shows the location and orientation of each well that transects the confining zone. Hilcorp has formed the opinion, based on the following assessments for each well and seismic, well and other subsurface information currently available that none of these wells will interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. C-18B frac half length of 200 ft. CDW 12/10/2024. around 70'. Casing and Cement assessments for all wells that transect the confining zone: C-33A (PTD 200202) C-33 was spudded 6/3/1993. The 16” hole was drilled to 3,625’ and 13-3/8” casing was run and cemented at 3,609’ MD with 393 bbls of Permafrost F and 87 bbls of Class G cement. The 12-1/4” hole was drilled to 10,350’ md and 9-5/8” casing was ran to 10,428’ md. The 9-5/8” surface casing was cemented with 1415 sx (252 bbl) of 11 ppg Class G lead and 300 sx (61 bbl) of 15.8 ppg Class G tail. The 8-1/2” production hole was drilled to 11,770’ md and 7” casing was ran to 11,770’ md. The 7” casing was cemented with 334 sx (23 bbl) of Class G cement. The plug did bump. Cement was tagged at 11,550’ and drilled out to 11,769’ md. The 9-5/8” cement job has cement from the 9-5/8” shoe at 10,429’ up to an estimated top of cement at 6370’ MD/5306’ TVD which provides for zonal isolation of the formation of interest. A lateral (C-33A) was added to the C-33 parent well on 12/1/2001. The window exited the 7” liner at 11,250’ MD which was in the HRZ. The 2-3/8” liner was run and cemented and a LTP was installed. ®ôīī ĺŕ ÍĲĲĖĲČ ĺŕôť ÍŜĖĲČ ĖƏô èŘĺŜŜ ÍĲĲĖĲČ ĺŕŜôť ÍŜĖĲČ ēĺô "ôŕťē ÍŜĖĲČ ēĺô "ôŕťē iiώaôťēĺî ¾ĺĲÍī IŜĺīÍťĖĺĲ ċťώŜŜ«"ĖĲ ċťώıî ċťώŜŜ«"ŜŜ«" ϱ͒͒͗Ϡ͏͏͏Ѝ ͘ϱ͔ϯ͗Г ͐͏Ϡ͓͑͘Ѝ ͗Ϡ͒͑͘Ѝ ͕Ϡ͔͕͕Ѝ «ĺīŪıôťŘĖè ´ôŜ 6370’ MD/5306’ TVD SECTION 11 - LOCATION OF, ORIENTATION OF, AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE CONFING ZONES (20 AAC 25.283, a, 11): Hilcorp’s technical analysis based on seismic, well and other subsurface information available indicates that there are 0 mapped faults that transect the Canning Topset interval and enter the confining zone within the ½ mile radius of the production and confining zone trajectory for the C-18B well. Fracture gradients within the confining zone (Canning shale) will not be exceeded during fracture stimulation and would therefore confine injected fluids to the pool. The Canning Shale in this area are predominately shale with some silts with an estimated fracture pressure of ~13.3ppg. No faults in proximity to the C-18B area. C-18B frac length estimates are around 200'. Stress orientation is relatively unknown at this location. If a sudden drop in treating pressure or increase in pump rate is seen during the stimulation that cannot be explaining by fluids pumped or annular pressure monitoring, pumping operation will stop until a plan forward and explanation can be put forth. are around 200'.No faults in proximity to the C-18B area. SECTION 12: PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283, a, 12 Proposed Procedure: 1. Conduct Safety meeting, inspect location, and review 10-403. 2. Ensure all pre-frac well work has been completed and the tubing and IA are freeze protected. 3. Install Tree saver. 4. MIRU Halliburton frac equipment and associated frac tanks. 5. Pressure test surface lines and tree saver to at least 8,196psi. 6. Test IA Pop-off system to ensure functioning properly. IA Pop-off to be set at 3,406 psi. 7. Bring IA pressure up to hold pressure of 3,106 psi. 8. Pump the fracture stimulation per the proposed pump schedule attached below. Maximum allowable treating pressure is 7,196 psi. Estimated 1,350 bbl of fluid, and 150,000# proppant. 9. RDMO frac equipment. Ensure tubing is freeze protected. 10. Return the well to production/flowback post slickline gas lift design and contingent coiled tubing cleanout. Fracture Stimulation Pump Schedule Stage #Fluid Stage Volume (bbls) Cumulative Volume (bbls)Rate Prop. Conc. (ppa)Proppant Name Proppant (#) Cumulative Proppant (#) 1 20# Linear Load 150 150 10 2 30# X-link FET 50 200 24 3 20# Linear Flush 150 350 24 Shutdown 4 30# X-Link Pad 313 663 24 5 30# X-Link 1 PPA 22 685 24 1.0 20/40 CarboLite 900 900 6 30# X-Link 2 PPA 27 712 24 2.0 20/40 CarboLite 2,250 3,150 7 30# X-Link 3 PPA 30 742 24 3.0 20/40 CarboLite 3,750 6,900 8 30# X-Link 4 PPA 40 782 24 4.0 20/40 CarboLite 6,752 13,625 9 30# X-Link 5 PPA 46 828 24 5.0 20/40 CarboLite 9,750 23,222 10 30# X-Link 6 PPA 57 885 24 6.0 20/40 CarboLite 14,250 37,472 11 30# X-Link 7 PPA 66 951 24 7.0 20/40 CarboLite 19,502 56,974 12 30# X-Link 8 PPA 78 1029 24 8.0 20/40 CarboLite 26,248 83,222 13 30# X-Link 9 PPA 83 1112 24 9.0 20/40 CarboLite 31,500 114,722 14 30# X-Link 10 PPA 84 1196 24 10.0 20/40 CarboLite 35,100 150,000 15 20# Linear Flush 150 1346 24 There are three overpressure devices that protect the surface equipment and wellbore from overpressure. 1) Each individual frac pump has an electronic kickout that will shift the pumps into neutral as soon as the set pressure is reached. Since there are multiple pumps, these set pressures are staggered between 90% and 95% of the maximum allowable treating pressure. 2) A primary pressure transducer in the treating line will trigger a global kickout that will shift all the pumps into neutral. 3) There is a manual kickout that is controlled from the frac van that can shift all pumps into neutral. All three of these shutdown systems will be individually tested prior to high pressure pumping operations. Additionally, the treating pressure, IA pressure and OA pressure will be monitored in the frac van. Stress orientation is relatively unknown at this location. Frac Dimensions: Frac #MD Location, ft TVDss top, ft TVDss Bottom, ft Frac Half-Length, ft 1 9830 -6550 6690 ~200’ Disclaimer Notice: This model was generated using commercially available modelling software and is based on engineering estimates of reservoir properties. Hilcorp is providing these model results as an informed prediction of actual results. Because of the inherent limitations in assumptions required to generate this model, and for other reasons, actual results may differ from the model results. ~200’ Frac Modelling: Maximum Anticipated Treating Pressure: ~3100 psi Surface pressure is calculated based on a closure pressure of ~0.65 psi/ ft or ~4268 psi. Closure pressure plus anticipated net pressure to be built (1000 psi) and friction pressure minus hydrostatic results in a surface pressure of 3,030 psi at the time of flush. 4,268 psi (closure)+ 1000 psi (net)+ 2,100 psi (friction)- 4,336 psi (hydrostatic)= 3,030 psi (max surface press) The difference in closure pressures of the confining shale layers determines height of the fracture. Average confining layer stress is anticipated to be ~0.69 psi/ ft limiting fracture height to ~140 ft TVD. Fracture half-length is determined from confining layer stress as well as leak-off and formation modulus. The modeled frac is anticipated to reach a half-length of ~200 ft. Average confining layer stress is anticipated to be ~0.69 psi/ ft limiting fracture height to ~140 ft TVD. The modeled frac is anticipated to reach a half-length of ~200 ft. Pre-Job Anticipated Chemicals to be pumped: SECTION 13 - POST FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN (20 AAC 25.283, a, 13): After the fracture stimulation and potentially during the post frac coil fill cleanout, the well will be put on production through a portable well test separator. All liquids will be captured and either sent to production facilities or diverted to flowback tanks if solids percentage becomes too high for the production facility to manage. The initial flowback period is intended to produce back the fracture fluids to tanks as quickly as possible, until the well is producing less than 0.5% solids, at which time the produced fluids meet the GC3 acceptance criteria for start-up. There will be a tank farm on pad to store the produced fluids from flowback operations. The flowback fluids not suitable for GC3 processing will be hauled to another facility’s slop tanks for additional settling time and/or disposal. Hilcorp will work to separate and recover fluid that meets the facility specification for the flowback fluids. A fluid manifest form will be completed for each load trucked offsite. 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ϮϬϮϱ͘Ϯϴϯ,ǇĚƌĂƵůŝĐ&ƌĂĐƚƵƌŝŶŐƉƉůŝĐĂƚŝŽŶʹŚĞĐŬůŝƐƚWhͲϭϴ;WdEŽ͘ϮϬϵͲϬϳϭ͖^ƵŶĚƌǇEŽ͘ϯϮϰͲϲϴϴͿWĂƌĂŐƌĂƉŚ^ƵďͲWĂƌĂŐƌĂƉŚ^ĞĐƚŝŽŶŽŵƉůĞƚĞ͍K' WĂŐĞϰ ĞĐĞŵďĞƌϭϬ͕ϮϬϮϰŚǇĚƌĂƵůŝĐĨƌĂĐƚƵƌŝŶŐĨůƵŝĚǁŝƚŚŝŶЪŵŝůĞŽĨƚŚĞƉƌŽƉŽƐĞĚǁĞůůďŽƌĞƚƌĂũĞĐƚŽƌǇĨƚ͘,ŝůĐŽƌƉƉƌŽǀŝĚĞĚͲϯϯͬͲϯϯĐĞŵĞŶƚĚĞƚĂŝůƐʹŝŶĚŝĐĂƚŝŶŐŝƐŽůĂƚŝŽŶŽĨƚŚĞƌŽŽŬŝĂŶ͘dŚĞƌĞĂƌĞƚŚƌĞĞǁĞůůƐũƵƐƚŽƵƚƐŝĚĞƚŚĞЪŵŝůĞƌĂĚŝƵƐĂƚƚŚĞƚĂƌŐĞƚƌŽŽŬŝĂŶ͘;ĂͿ;ϭϭͿ&ĂƵůƚƐĂŶĚĨƌĂĐƚƵƌĞƐ͕^ƵĨĨŝĐŝĞŶƚŝŶĨŽƌŵĂƚŝŽŶƚŽĚĞƚĞƌŵŝŶĞŶŽŝŶƚĞƌĨĞƌĞŶĐĞǁŝƚŚĐŽŶƚĂŝŶŵĞŶƚŽĨƚŚĞŚǇĚƌĂƵůŝĐĨƌĂĐƚƵƌŝŶŐĨůƵŝĚǁŝƚŚŝŶЪŵŝůĞŽĨƚŚĞƉƌŽƉŽƐĞĚǁĞůůďŽƌĞƚƌĂũĞĐƚŽƌǇEŽŶĞ͘dŚĞŽƉĞƌĂƚŽƌŚĂƐŶŽƚŝĚĞŶƚŝĨŝĞĚĂŶǇĨĂƵůƚƐŽƌĨƌĂĐƚƵƌĞǌŽŶĞƐƚŚƌŽƵŐŚƐĞŝƐŵŝĐŽƌǁĞůůĚĂƚĂǁŝƚŚŝŶĂЪͲŵŝůĞƌĂĚŝƵƐŽĨƚŚĞƉƌŽĚƵĐƚŝŽŶŝŶƚĞƌǀĂůŝŶWhͲϭϴ͘/ƚŝƐƵŶůŝŬĞůǇƚŚĂƚĂŶǇĨĂƵůƚƐ ǁŝůů ŝŶƚĞƌĨĞƌĞ ǁŝƚŚƚŚĞ ĐŽŶƚĂŝŶŵĞŶƚŽĨ ŝŶũĞĐƚĞĚĨƌĂĐƚƵƌŝŶŐĨůƵŝĚƐ͖ŚŽǁĞǀĞƌ͕ŝĨƚŚĞƌĞĂƌĞŝŶĚŝĐĂƚŝŽŶƐƚŚĂƚĂĨƌĂĐƚƵƌĞŚĂƐŝŶƚĞƌƐĞĐƚĞĚĂĨĂƵůƚŽƌŶĂƚƵƌĂůͲĨƌĂĐƚƵƌĞŝŶƚĞƌǀĂůĚƵƌŝŶŐĨƌĂĐŽƉĞƌĂƚŝŽŶƐ͕ƚŚĞŽƉĞƌĂƚŽƌǁŝůůŐŽƚŽĨůƵƐŚĂŶĚƚĞƌŵŝŶĂƚĞƚŚĞƐƚĂŐĞŝŵŵĞĚŝĂƚĞůǇ͘^&ϭϮͬϵͬϮϬϮϰ;ĂͿ;ϭϮͿWƌŽƉŽƐĞĚƉƌŽŐƌĂŵĨŽƌĨƌĂĐƚƵƌŝŶŐŽƉĞƌĂƚŝŽŶWƌŽǀŝĚĞĚǁŝƚŚĂƉƉůŝĐĂƚŝŽŶ͘tϭϮͬϭϬͬϮϬϮϰ;ĂͿ;ϭϮͿ;ͿƐƚŝŵĂƚĞĚǀŽůƵŵĞWƌŽǀŝĚĞĚǁŝƚŚĂƉƉůŝĐĂƚŝŽŶ͘ϭϯϱϬďďůƚŽƚĂůĚŝƌƚǇǀŽů͘ϭϱϬ<ůďƚŽƚĂůƉƌŽƉƉĂŶƚtϭϮͬϭϬͬϮϬϮϰ;ĂͿ;ϭϮͿ;ͿĚĚŝƚŝǀĞƐ͗ŶĂŵĞƐ͕ƉƵƌƉŽƐĞƐ͕ĐŽŶĐĞŶƚƌĂƚŝŽŶƐWƌŽǀŝĚĞĚǁŝƚŚĂƉƉůŝĐĂƚŝŽŶ͘tϭϮͬϭϬͬϮϬϮϰ;ĂͿ;ϭϮͿ;ͿŚĞŵŝĐĂůŶĂŵĞĂŶĚ^ŶƵŵďĞƌŽĨĞĂĐŚWƌŽǀŝĚĞĚǁŝƚŚĂƉƉůŝĐĂƚŝŽŶ͘^ĐŚůƵŵďĞƌŐĞƌĚŝƐĐůŽƐƵƌĞƉƌŽǀŝĚĞĚ͘tϭϮͬϭϬͬϮϬϮϰ;ĂͿ;ϭϮͿ;Ϳ/ŶĞƌƚƐƵďƐƚĂŶĐĞƐ͕ǁĞŝŐŚƚŽƌǀŽůƵŵĞŽĨĞĂĐŚWƌŽǀŝĚĞĚǁŝƚŚĂƉƉůŝĐĂƚŝŽŶ͘tϭϮͬϭϬͬϮϬϮϰ;ĂͿ;ϭϮͿ;ͿDĂǆŝŵƵŵƚƌĞĂƚŝŶŐƉƌĞƐƐƵƌĞǁŝƚŚƐƵƉƉŽƌƚŝŶŐŝŶĨŽƚŽĚĞƚĞƌŵŝŶĞĂƉƉƌŽƉƌŝĂƚĞŶĞƐƐĨŽƌƉƌŽŐƌĂŵ^ŝŵƵůĂƚŝŽŶƐŚŽǁƐŵĂǆƐƵƌĨĂĐĞƉƌĞƐƐƵƌĞϯϮϬϬƉƐŝ͘DĂǆ͘ϳϭϵϲƉƐŝĂůůŽǁĂďůĞƚƌĞĂƚŝŶŐƉƌĞƐƐƵƌĞ͘DĂǆƉƌĞƐƐƵƌĞŝƐϲϰϳϲͲϲϴϯϲƉƐŝƚŽWƵŵƉƐŚƵƚĚŽǁŶ͘tŝƚŚϯϭϬϲƉƐŝďĂĐŬƉƌĞƐƐƵƌĞ/;/ƉŽƉŽĨĨƐĞƚϯϰϬϲƉƐŝͿ͕ŵĂǆƚƵďŝŶŐĚŝĨĨĞƌĞŶƚŝĂůƐŚŽƵůĚďĞϰϬϵϬƉƐŝ͘tϭϮͬϭϬͬϮϬϮϰ;ĂͿ;ϭϮͿ;&Ϳ&ƌĂĐƚƵƌĞƐʹŚĞŝŐŚƚ͕ůĞŶŐƚŚ͕DĂŶĚdsƚŽƚŽƉ͕ĚĞƐĐƌŝƉƚŝŽŶŽĨĨƌĂĐƚƵƌŝŶŐŵŽĚĞůWƌŽǀŝĚĞĚǁŝƚŚĂƉƉůŝĐĂƚŝŽŶ͘dŚĞĂŶƚŝĐŝƉĂƚĞĚŚĂůĨͲůĞŶŐƚŚƐŽĨƚŚĞŝŶĚƵĐĞĚĨƌĂĐƚƵƌĞƐĂƌĞϮϬϬ͛ĂĐĐŽƌĚŝŶŐƚŽƚŚĞKƉĞƌĂƚŽƌ͛ƐĐŽŵƉƵƚĞƌ ƐŝŵƵůĂƚŝŽŶ͘ŽŵƉƵƚĞƌ ƐŝŵƵůĂƚŝŽŶ ŝŶĚŝĐĂƚĞƐ ƚŚĞĂŶƚŝĐŝƉĂƚĞĚŚĞŝŐŚƚŽĨƚŚĞŝŶĚƵĐĞĚĨƌĂĐƚƵƌĞƐǁŝůůďĞϭϰϬ͛;ƚŽƉ^&ϭϮͬϵͬϮϬϮϰ ϮϬϮϱ͘Ϯϴϯ,ǇĚƌĂƵůŝĐ&ƌĂĐƚƵƌŝŶŐƉƉůŝĐĂƚŝŽŶʹŚĞĐŬůŝƐƚWhͲϭϴ;WdEŽ͘ϮϬϵͲϬϳϭ͖^ƵŶĚƌǇEŽ͘ϯϮϰͲϲϴϴͿWĂƌĂŐƌĂƉŚ^ƵďͲWĂƌĂŐƌĂƉŚ^ĞĐƚŝŽŶŽŵƉůĞƚĞ͍K' WĂŐĞϱ ĞĐĞŵďĞƌϭϬ͕ϮϬϮϰds^^ŽĨĂďŽƵƚͲϲ͕ϱϱϬ͛ĂŶĚďĂƐĞds^^ŽĨĂďŽƵƚͲϲ͕ϲϵϬ͛Ϳ͕ƐŽŝŶĚƵĐĞĚ ĨƌĂĐƚƵƌĞƐŵĂǇ ƉĞŶĞƚƌĂƚĞ ŝŶƚŽ͕ ďƵƚ ƐŚŽƵůĚŶŽƚƉĞŶĞƚƌĂƚĞƚŚƌŽƵŐŚ͕ ƚŚĞ ŽǀĞƌůǇŝŶŐ ĐŽŶĨŝŶŝŶŐ ĂŶŶŝŶŐ^ŚĂůĞƚŚĂƚŝƐĂďŽƵƚϮϮ͛ƚŚŝĐŬŝŶƚŚŝƐĂƌĞĂ͘/ŶĚƵĐĞĚĨƌĂĐƚƵƌĞƐĐĞƌƚĂŝŶůǇǁŝůůŶŽƚƉĞŶĞƚƌĂƚĞƚŚƌŽƵŐŚƚŚĞƐŝůƚƐƚŽŶĞͲĚŽŵŝŶĂƚĞĚŝŶƚĞƌǀĂůĂƚƚŚĞďĂƐĞŽĨƚŚĞŽǀĞƌůǇŝŶŐƵƉƉĞƌĂŶŶŝŶŐ&ŽƌŵĂƚŝŽŶ͕ǁŚŝĐŚŝƐĂďŽƵƚϱϯ͛ƚŚŝĐŬŝŶƚŚŝƐĂƌĞĂ͘;ĂͿ;ϭϯͿWƌŽƉŽƐĞĚƉƌŽŐƌĂŵĨŽƌƉŽƐƚͲĨƌĂĐƚƵƌŝŶŐǁĞůůĐůĞĂŶƵƉĂŶĚĨůƵŝĚƌĞĐŽǀĞƌǇtĞůů ĐůĞĂŶŽƵƚ ĂŶĚ ĨůŽǁďĂĐŬ ƉƌŽĐĞĚƵƌĞ ƉƌŽǀŝĚĞĚ ǁŝƚŚĂƉƉůŝĐĂƚŝŽŶ͘ŝƐƉŽƐĂůŽƉƚŝŽŶƐĂǀĂŝůĂďůĞ͘tϭϮͬϭϬͬϮϬϮϰ;ďͿdĞƐƚŝŶŐŽĨĐĂƐŝŶŐŽƌŝŶƚĞƌŵĞĚŝĂƚĞĐĂƐŝŶŐdĞƐƚĞĚхϭϭϬйŽĨŵĂǆĂŶƚŝĐŝƉĂƚĞĚƉƌĞƐƐƵƌĞϯϭϬϲƉƐŝďĂĐŬƉƌĞƐƐƵƌĞ͕ƚĞƐƚĞĚƚŽϯϱϴϱƉƐŝ͕ƉŽƉŽĨĨƐĞƚĂƐϯϰϬϲƉƐŝtϭϮͬϭϬͬϮϬϮϰ;ĐͿ&ƌĂĐƚƵƌŝŶŐƐƚƌŝŶŐ;ĐͿ;ϭͿWĂĐŬĞƌхϭϬϬ͛ďĞůŽǁdKŽĨƉƌŽĚƵĐƚŝŽŶŽƌŝŶƚĞƌŵĞĚŝĂƚĞĐĂƐŝŶŐϰ͘ϱ͟ƚƵďŝŶŐǁŝůůďĞĂŶĐŚŽƌĞĚǁŝƚŚĂƉĂĐŬĞƌƐĞƚĂƚĂƉƉƌŽǆ͘ϵϲϵϯĨƚĂŶĚϵϵϵϲĨƚǁŝƚŚƉĞƌĨŽƌĂƚŝŽŶƐϵϴϭϵͲϵϴϰϬĨƚ͘&ŽƌϵͲϱͬϴ͟ϭϬͬϮͬϮϬϮϰƌĂĚŝĂůĐĞŵĞŶƚďŽŶĚůŽŐĞǀĂů͕ƚǁŽƐƚĂŐĞĐĞŵĞŶƚ ũŽď ŝŶĚŝĐĂƚĞƐ ĐĞŵĞŶƚ ĨƌŽŵ ƐŚŽĞ Ăƚ ϭϮϬϳϬ Ĩƚ ƚŽĐŽŶƐĞƌǀĂƚŝǀĞdKϵϲϱϬĨƚ͘>ƐŚŽǁƐǀĞƌǇŐŽŽĚďŽŶĚŝŶĂƌĞĂŽĨƚŚĞŝŶƚĞŶĚĞĚƉĞƌĨͬĨƌĂĐŝŶƚĞƌǀĂůĂŶĚƉĂĐŬĞƌƐ͘EŽŝƐƐƵĞƐǁŝƚŚĐĞŵĞŶƚĨŽƌƚŚĞƵƉĐŽŵŝŶŐƐƚŝŵƵůĂƚŝŽŶ͘tϭϮͬϭϬͬϮϬϮϰ;ĐͿ;ϮͿdĞƐƚĞĚхϭϭϬйŽĨŵĂǆĂŶƚŝĐŝƉĂƚĞĚƉƌĞƐƐƵƌĞĚŝĨĨĞƌĞŶƚŝĂůdƵďŝŶŐƚĞƐƚŽĨϰϱϬϬƉƐŝ͘DĂǆƉƌĞƐƐƵƌĞĚŝĨĨĞƌĞŶƚŝĂůŝƐĞƐƚŝŵĂƚĞĚĂƐϰϬϵϬƉƐŝ;ϳϭϵϲǁŝƚŚϯϭϬϲƉƐŝďĂĐŬƉƌĞƐƐƵƌĞͿƐŽƚĞƐƚŽĨϰϱϬϬƉƐŝƐĂƚŝƐĨŝĞƐϭϭϬйtϭϮͬϭϬͬϮϬϮϰ;ĚͿWƌĞƐƐƵƌĞƌĞůŝĞĨǀĂůǀĞ>ŝŶĞƉƌĞƐƐƵƌĞфсƚĞƐƚƉƌĞƐƐƵƌĞ͕ƌĞŵŽƚĞůǇĐŽŶƚƌŽůůĞĚƐŚƵƚͲŝŶĚĞǀŝĐĞϴϭϵϲƉƐŝůŝŶĞƉƌĞƐƐƵƌĞƚĞƐƚ͕ŵĂǆ͘ĂůůŽǁĂďůĞƚƌĞĂƚƉƌĞƐƐƵƌĞсϳϭϵϲ͕ƉƵŵƉŬŶŽĐŬŽƵƚϲϰϳϲͲϲϴϯϲĂŶĚϳϭϵϲŐůŽďĂůŬŝĐŬŽƵƚ͘/WZsƐĞƚĂƐϯϰϬϲƉƐŝ͘tϭϮͬϭϬͬϮϬϮϰ;ĞͿŽŶĨŝŶĞŵĞŶƚ&ƌĂĐĨůƵŝĚƐĐŽŶĨŝŶĞĚƚŽĂƉƉƌŽǀĞĚĨŽƌŵĂƚŝŽŶƐWƌŽǀŝĚĞĚǁŝƚŚĂƉƉůŝĐĂƚŝŽŶ͘tϭϮͬϭϬͬϮϬϮϰ;ĨͿ^ƵƌĨĂĐĞĐĂƐŝŶŐƉƌĞƐƐƵƌĞƐDŽŶŝƚŽƌĞĚǁŝƚŚŐĂƵŐĞĂŶĚƉƌĞƐƐƵƌĞƌĞůŝĞĨĚĞǀŝĐĞ/WZsƐĞƚĂƚϯϰϬϲƉƐŝ͘^ƵƌĨĂĐĞĂŶŶƵůƵƐŽƉĞŶ͘&ƌĂĐƉƌĞƐƐƵƌĞƐĐŽŶƚŝŶƵŽƵƐůǇŵŽŶŝƚŽƌĞĚ͘tϭϮͬϭϬͬϮϬϮϰ ϮϬϮϱ͘Ϯϴϯ,ǇĚƌĂƵůŝĐ&ƌĂĐƚƵƌŝŶŐƉƉůŝĐĂƚŝŽŶʹŚĞĐŬůŝƐƚWhͲϭϴ;WdEŽ͘ϮϬϵͲϬϳϭ͖^ƵŶĚƌǇEŽ͘ϯϮϰͲϲϴϴͿWĂƌĂŐƌĂƉŚ^ƵďͲWĂƌĂŐƌĂƉŚ^ĞĐƚŝŽŶŽŵƉůĞƚĞ͍K' WĂŐĞϲ ĞĐĞŵďĞƌϭϬ͕ϮϬϮϰ;ŐͿŶŶƵůƵƐƉƌĞƐƐƵƌĞŵŽŶŝƚŽƌŝŶŐΘŶŽƚŝĨŝĐĂƚŝŽŶϱϬϬƉƐŝĐƌŝƚĞƌŝĂƵƌŝŶŐŚǇĚƌĂƵůŝĐĨƌĂĐƚƵƌŝŶŐŽƉĞƌĂƚŝŽŶƐ͕ĂůůĂŶŶƵůƵƐƉƌĞƐƐƵƌĞƐŵƵƐƚďĞĐŽŶƚŝŶƵŽƵƐůǇŵŽŶŝƚŽƌĞĚĂŶĚƌĞĐŽƌĚĞĚ͘/ĨĂƚĂŶǇƚŝŵĞĚƵƌŝŶŐŚǇĚƌĂƵůŝĐĨƌĂĐƚƵƌŝŶŐŽƉĞƌĂƚŝŽŶƐƚŚĞĂŶŶƵůƵƐƉƌĞƐƐƵƌĞŝŶĐƌĞĂƐĞƐ ŵŽƌĞ ƚŚĂŶϱϬϬ ƉƐŝŐ ĂďŽǀĞ ƚŚŽƐĞ ĂŶƚŝĐŝƉĂƚĞĚŝŶĐƌĞĂƐĞƐ ĐĂƵƐĞĚ ďǇ ƉƌĞƐƐƵƌĞ Žƌ ƚŚĞƌŵĂů ƚƌĂŶƐĨĞƌ͕ ƚŚĞŽƉĞƌĂƚŽƌƐŚĂůů͗tϭϮͬϭϬͬϮϬϮϰ;ŐͿ;ϭͿEŽƚŝĨǇK'ǁŝƚŚŝŶϮϰŚŽƵƌƐ;ŐͿ;ϮͿŽƌƌĞĐƚŝǀĞĂĐƚŝŽŶŽƌƐƵƌǀĞŝůůĂŶĐĞ;ŐͿ;ϯͿ^ƵŶĚƌǇƚŽK';ŚͿ^ƵŶĚƌǇZĞƉŽƌƚ;ŝͿZĞƉŽƌƚŝŶŐ;ŝͿ;ϭͿ&ƌĂĐ&ŽĐƵƐZĞƉŽƌƚŝŶŐ;ŝͿ;ϮͿK'ZĞƉŽƌƚŝŶŐ͗ƉƌŝŶƚĞĚΘĞůĞĐƚƌŽŶŝĐ;ũͿWŽƐƚͲĨƌĂĐǁĂƚĞƌƐĂŵƉůŝŶŐƉůĂŶEŽƚƌĞƋƵŝƌĞĚ;ƐĞĞ^ĞĐƚŝŽŶ;ĂͿ;ϯͿ͕ĂďŽǀĞͿ͘^&ϭϮͬϵͬϮϬϮϰ;ŬͿŽŶĨŝĚĞŶƚŝĂůŝŶĨŽƌŵĂƚŝŽŶůĞĂƌůǇŵĂƌŬĞĚĂŶĚƐƉĞĐŝĨŝĐĨĂĐƚƐƐƵƉƉŽƌƚŝŶŐŶŽŶĚŝƐĐůŽƐƵƌĞEŽŶͲĐŽŶĨŝĚĞŶƚŝĂůǁĞůů͘^&ϭϮͬϵͬϮϬϮϰ;ůͿsĂƌŝĂŶĐĞƐƌĞƋƵĞƐƚĞĚDŽĚŝĨŝĐĂƚŝŽŶƐŽĨĚĞĂĚůŝŶĞƐ͕ƌĞƋƵĞƐƚƐĨŽƌǀĂƌŝĂŶĐĞƐŽƌǁĂŝǀĞƌƐEŽƉůĂŶĨŽƌƉŽƐƚĨƌĂĐƚƵƌĞǁĂƚĞƌǁĞůůĂŶĂůǇƐŝƐ͘ŽŵŵŝƐƐŝŽŶŵĂǇƌĞƋƵŝƌĞƚŚŝƐĚĞƉĞŶĚŝŶŐŽŶƉĞƌĨŽƌŵĂŶĐĞŽĨƚŚĞĨƌĂĐƚƵƌŝŶŐŽƉĞƌĂƚŝŽŶ͘ ϮϬϮϱ͘Ϯϴϯ,ǇĚƌĂƵůŝĐ&ƌĂĐƚƵƌŝŶŐƉƉůŝĐĂƚŝŽŶʹŚĞĐŬůŝƐƚWhͲϭϴ;WdEŽ͘ϮϬϵͲϬϳϭ͖^ƵŶĚƌǇEŽ͘ϯϮϰͲϲϴϴͿWĂƌĂŐƌĂƉŚ^ƵďͲWĂƌĂŐƌĂƉŚ^ĞĐƚŝŽŶŽŵƉůĞƚĞ͍K' WĂŐĞϳ ĞĐĞŵďĞƌϭϬ͕ϮϬϮϰ/ŶĚĞǆDĂƉ ϮϬϮϱ͘Ϯϴϯ,ǇĚƌĂƵůŝĐ&ƌĂĐƚƵƌŝŶŐƉƉůŝĐĂƚŝŽŶʹŚĞĐŬůŝƐƚWhͲϭϴ;WdEŽ͘ϮϬϵͲϬϳϭ͖^ƵŶĚƌǇEŽ͘ϯϮϰͲϲϴϴͿWĂƌĂŐƌĂƉŚ^ƵďͲWĂƌĂŐƌĂƉŚ^ĞĐƚŝŽŶŽŵƉůĞƚĞ͍K' WĂŐĞϴ ĞĐĞŵďĞƌϭϬ͕ϮϬϮϰKϭ Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/30/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20241030 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 221-26 50283202010000 224098 10/20/2024 AK E-LINE Perf BRU 233-23T 50283202000000 224088 10/14/2024 AK E-LINE Perf BRU 241-23 50283201910000 223061 10/12/2024 AK E-LINE Perf GP-ST-18742-33 50733203060000 177032 10/9/2024 AK E-LINE LeakDetect/Packer IRU 11-06 50283201300000 208184 10/4/2024 AK E-LINE Plug/Perf MPU B-28 50029235660000 216027 10/4/2024 READ CaliperSurvey MPU F-13 50029225490000 195027 10/15/2024 READ CaliperSurvey MPU L-36 50029227940000 197148 10/17/2024 READ CaliperSurvey MRU G-01RD 50733200370100 191139 10/10/2024 AK E-LINE Hoist NCIU A-21 50883201990000 224086 10/8/2024 AK E-LINE CBL NCIU B-01B 50883200930200 224097 10/1/2024 AK E-LINE CBL NCIU B-01B 50883200930200 224097 10/11/2024 AK E-LINE Perf PBU 06-18B 50029207670200 223071 10/2/2024 HALLIBURTON RBT PBU 14-32B 50029209990200 224073 10/13/2024 HALLIBURTON RBT PBU C-18B 50029207850200 209071 10/2/2024 HALLIBURTON RBT PBU C-18B 50029207850200 209071 10/2/2024 HALLIBURTON WSTT PBU NK-26A 50029224400100 218009 10/14/2024 HALLIBURTON PPROF PCU 02A 50283200220100 224110 9/30/2024 AK E-LINE CBL PCU 02A 50283200220100 224110 10/4/2024 AK E-LINE Perf SDI 3-25B 50029221250200 203021 10/17/2024 AK E-LINE Patch Please include current contact information if different from above. T39726 T39727 T39728 T39732 T39733 T39734 T39735 T39736 T39737 T39738 T39739 T39739 T39740 T39741 T39742 T39742 T39743 T39744 T39744 T39745 PBU C-18B 50029207850200 209071 10/2/2024 HALLIBURTON RBT PBU C-18B 50029207850200 209071 10/2/2024 HALLIBURTON WSTT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.11.01 13:27:33 -08'00' 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU C-18B Tubing Swap, Recomplete to Brookian Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 209-071 50-029-20785-02-00 15089 Conductor Surface Intermediate Liner Liner 8781 80 2894 12038 734 3509 10190 20" x 30" 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" x 2-7/8" 6915 34 - 114 33 - 2927 32 - 12070 11550 - 12284 11580 - 15089 34 - 114 33 - 2676 32 - 8229 7853 - 8393 7874 - 8781 Unknown, 15051 2670 4760 5410 10530 10190, 11562, 13208 5380 6870 7240 10160 9819 - 15015 4-1/2" 12.6#, 5-1/2" 17# x 4-1/2" 12.6# L80 31 - 10272, 10271 - 11638 6671 - 8785 Structural 4-1/2" HES TNT Packers (2) 11506, 7822 9693, 9996, 11506 6592, 6786, 7822 Torin Roschinger Operations Manager Michael Hibbert michael.hibbert@hilcorp.com 907-903-5990 PRUDHOE BAY, Prudhoe Oil / Brookian Undefined Oil Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028304, 0028305 31 - 6971, 6970 - 7915 N/A N/A 422 84 37223 6500 48 6 1300 1369 970 315 324-500 13b. Pools active after work:Brookian Undefined Oil Pool 5-1/2" BOT Packer 9693, 6592 / 9996, 6786 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations No SSSV Installed By Grace Christianson at 9:57 am, Dec 05, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.12.04 19:45:22 - 09'00' Torin Roschinger (4662) Brookian Undefined Oil Perforate New Pool DSR-12/16/24WCB 2-12-2025 RBDMS JSB 120624 ACTIVITY DATE SUMMARY 7/26/2024 T/I/O 0/350/0 Well shut in. PPPOT-T (PASS), PPPOT-IC (FAIL) IC-PO at 400 psi unable to bleed to 0. Function all TBG HGR LDS and retorque. R/U test equipment and test void to 5,000psi for 30 min. No loss in first 15 min, no loss in final 15 min. passed. S/B for DHD to bleed down IA / OA for repack PO seals and test. 7/27/2024 T/I/O = VAC/380/40. Temp = SI. Bleed IAP/OAP to 0 psi (pre rig). No AL. IA FL @ 110' (5 bbls). Bled IAP to BT 0 in 1hr 30 min (gas). Monitored for 30 min. IAP increased 8 psi. IA FL near surface. OA FL near surface. Bled OAP to BT to 0 psi in < 5 min (gas). Monitored for 30 min. OAP increased 7 psi. OA FL unchanged. Bled IAP & OAP to BT to 0 psi in 3 min (gas). Monitored fo 30 min. IAP & OAP increased 4 psi. Repeat process 4 more times, until IAP & OAP are at 0 psi. IA & OA FL unchanged. Final WHPs = Vac/0/0. SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:00 7/28/2024 T/I/O = SI/0/0 PPPOT-IC (PASS) Verify IC bled to 0. Rig up injection gun to port, back off slotted bleed screw. Pump J- stick untill returns are captured through slotted bleeder. Shut in slotted bleeder and pressure up on Y-seal to 4000 psi, stabilize. Rig up to test port and pressure up to 3500 psi. Loss of 100 psi in first 15 min. No loss in final 15 min. Bleed off test pressure. Rig down injection and test equipment. Secure well. 9/18/2024 T/I/O = 0/250/0. Temp = SI. IA FL (pre slickline). No AL. IA FL @ 360' (16 bbls). 17:00 9/20/2024 ***WELL S/I ON ARRIVAL*** RAN 4-1/2" GS, S/D @ 5,807' MD (SLIPPING OUT, SHEAR GS) ***CONTINUE 9/21/24*** 9/21/2024 ***CONTINUED FROM 9-20-24*** JAR ON BKR 55 FLOWGAURD PATCH @ 5,807' MD (5 HRS JARRING .125") SET RELEASABLE SPEAR @ 5,807' MD (1 HR JARRING .125") SWAP FROM .125" CARBON TO .160" CARBON ***CONTINUE 9/22/24*** Daily Report of Well Operations PBU C-18B Daily Report of Well Operations PBU C-18B 9/22/2024 ***CONTINUE FROM 9/21/22*** PULLED 31.5' x 5 1/2" BAKER FLOGUARD PATCH FROM 5807' MD; ALL COMPONENETS ACCOUNTED FOR. RAN 3' x 1.875" STEM, AND 4.53" CENT. S/D @ 7265' SLM. UNABLE TO WORK DEEPER. RAN 5 1/2" BRUSH, AND 4.40" GAUGE RING. S/D @ 7268' SLM. UNABLE TO WORK DEEPER. RAN 10' x 3" PUMP BAILER. S/D AND WORK THROUGH SPOT @ 7269' SLM. TAG LOWER PATCH @ 10,797' SLM. RAN 3' x 1.875" STEM, AND 4.53" CENT. UNABLE TO WORK PAST 7268' SLM. RAN 4.53" CENT. 2' X 1-7/8" STEM, 4.50" SWAGE S/D @ 7,269' SLM (1 deep gouge starting 3.20" O.D. up to 4.20" on swage) RAN KJ, 2' X 1-7/8" STEM, 4.50" SWAGE, S/D @ 7,269' SLM (unable to pass) LAY DOWN .160" SLICKLINE ***CONTINUE 9/23/24*** 9/23/2024 ***CONTINUE FROM 9/22/24*** SWAGED OBSTRUCTION @ 7269' SLM FROM 4.125" TO 4.55". TAGGED PATCH @ 10,830' MD W/ 4.55" BAR-BELL. SWAPPED TO .160 RAN 3-1/2" PRGS, 3-1/2" X 4-1/2" (releasable spear) S/D @ 10,797' SLM ( 1 hr jarring 3000#, leave spear) RAN 3-1/2" PRGS S/D @ 10,793' SLM (1 hr jarring 3000#) RAN 3-1/2" PRGS S/D @ 10,793' SLM ( 15 minutes 3000#) ***CONTINUE 9/24/24*** 9/24/2024 ***CONTINUE FROM 9/23/24*** PULLED 31.5' x 5 1/2" BAKER FLOGUARD PATCH FROM 10,830' MD (MISSING 1/2 OF AN ELEMENT SPRING). PULLED PRONG FROM 2 7/8" PX PLUG @ 11,523' SLM. RAN 4 1/2" GR TO NIPPLE REDUCER @ 11,529' SLM; LATCHED EASILY, SHEARED GR PULLED 4-1/2" NIPPLE REDUCER W/ 2-7/8" PX-PLUG @ 11,562' MD (RECOVERED 1/2 ELEMENT SPRING) RAN KJ, 4-1/2" BLB, 3.78" GAUGE RING, BRUSH X-LIPPLE @ 11,562' MD SET 4-1/2" PX PLUG BODY (W/FILL EXT.44" OAL) @ 11,562' MD ***CONTINUE 9/25/24*** 9/25/2024 T/I/O=10/171/5 ( RWO CAPITAL ) Combo MIT TxIA. (FAILED) Pumped 47 bbls crude to reach max applied pressure 3800 psi. 15 min Loss-T-218 psi / IA-223 psi. 30 min Loss-T - 178 psi / IA - 178 psi. Bled back 9.8 bbls crude. Pad Op notified upon departure. FWHP = 100/100/15 9/25/2024 ***CONTINUE FROM 9/24/24*** SET PRONG IN PX PLUG @ 11,533' SLM. ***WELL S/I ON DEPARTURE*** Daily Report of Well Operations PBU C-18B 9/25/2024 T/I/O=18/38/22 CMIT TxIA FAILED to 3500 psi ( Pre RWO ) Pump 6 bbls diesel and 24.8 bbls crude down IA to 3781/3797 psi. T/IA lost 398/395 psi in 15 mins. Repressured with 1.9 bbls crude for a LLR=0.12 bpm T/IA lost 396/408 psi in 15 mins on 2nd attempt. Bled back 10 bbls FWHPs=500/515/27 9/25/2024 ***WELL S/I ON ARRIVAL*** HES 759 R/U ***CONT WSR ON 09/26/2024*** 9/26/2024 ***CONT WSR FROM 09/25/2024*** PULLED P-PRONG FROM PX-PLUG BODY @ 11,562'MD PULLED 4-1/2" PX-PLUG BODY FROM X-NIPPLE @ 11,562'MD BRUSH X-NIPPLE @ 11,562' MD SET 4-1/2" PX-PLUG BODY (43" lih, 18" fill ext, 4x1/2" ports) RUN 4-1/2" CHECK TO PX-PLUG BODY @ 11,562' MD RUN 1.75" P-PRONG SET IN PX-PLUG BODY @ 11,562'MD COMBO MIT TxIA=PASS ( log) ***WELL LEFT S/I ON DEPARTURE*** 9/26/2024 T/I/O = 0/0/0 Temp=S/I (Assist Slickliine with CMIT-TxIA) Pumped 17.5 BBLS down TBG/IA in attempt to reach max applied pressure of 3800 PSI for CMIT-TxIA. Target pressure 3500 PSI. CMIT-TxIA *******PASSED******** First 15 minutes TBG/IA lost 70/67 PSI. Second 15 minutes TBG/IA lost 31/31 PSI for a total loss of 101/98 PSI in a 30 minute test. Bleed TBG/IA down to starting pressure. Bleed back 13 BBLS. Final WHPS=500/500/0 SL in control of well upon departure. 9/27/2024 ***WELL SHUT IN ON ARRIVAL*** (TUBING CUT) RIG UP AKEL PCE FUNCTON TEST WLV'S PRESSURE TEST 250L 3000H JET CUT TUBING AT 10271' CCL STOP DEPTH=10268.1 (CCL-CUTTER=2.91') RDMO AKEL JOB COMPLETE ***WELL SHUT IN ON DEPARTURE*** 9/29/2024 T/I/O = 50/5/10 Remove Upper tree install 6" crown valve # 46 on top of master valve PT 300 PSI / 5000 high Pass RDMO FWHP = 50/5/10 9/29/2024 T/I/O = 10/25/25 (RWO CAPITAL) Circ out C-18 down TBG take returns from IA to C- 20 FL. Pump 100 bbls "Deep Clean" Followed by 884 bbls Brine. Pump 168 bbls Diesel Freeze protect. U Tube for 1 hour. Pump 110 bbls Crude down C-20 FL for FP. Pad op and Rig notified upon job completion. C-20 Left S/I. Choke Skid = Closed SV,MV = Closed IA,OA = OTG FWHPs = 420/425/95 9/30/2024 PBU C-18B RWO Scope: Work on maint projects while waitin on pad prep for C-18. R/D and blow down steam, water and air. RDMO C-42A. MIRU over C-18B, Cruz trucks released at 16:00. Plug in and swap over to Gen power at 17:00. Scope derrick and bridal down. Hook up interconnects and energize air, water, and steam systems throughout rig. Complete rig acceptance checklist and ACCEPT RIG AT 21:00. N/D Tree. Clean and inspect Tubing Hanger - (7" IJ4S lift threads damaged). Install tubing spool and BOP to wellhead. Install riser and begin M/U BOP bolts. Verify 0psi on Tubing, IA, and OA. ***CONT WSR ON 10/01/2024*** Daily Report of Well Operations PBU C-18B 9/30/2024 T/I/O=0/0/100. Pre I RIG , Set 6" "J" TWC #424 @90", TWC LTT Passed. PT tree cap to 500 psi. Pass. ***Job Complete*** Final WHP's TWC/0/100. 10/1/2024 T/I/0 = TWC/0/0+ Pull "J" TWC, 0 psi on tbg, 0 psi on IA, spear tubing hanger, back out LDS to 5" & pull tubing hanger to floor, disconnect & cap control lines. RDMO. Final WHP's = 0/0/0+ 10/1/2024 PBU C-18B RWO Scope: Finish N/U BOPE and function test - Good. Rig up testing equipment. Test all BOPE components per Sundry to 250/3000psi for 5 min each test with 4-1/2" and 5-1/2" test joints. States right to witnessed waived by AOGCC rep Brian Bixby. One fail/pass on HCR Choke. Rig down testing equipment, clean and clear rig floor. Remove TWC. Rig up Parker TRS equipment. M/U YJ Spear with 5- 1/2" Grapple. BOLDS per Vault rep. Pull Tubing Hanger to rig floor observing break over at 262K PUW, free travel at 250K. Terminate control lines and L/D Spear/Hanger. Rock out freeze protect and pump heated soap pill overboarding 185bbls diesel/crude. Slug pipe and POOH L/D 5-1/2" BTC 17# L-80 Tubing and control line F/ 10,271' - T/ 7935' and terminate control lin from SSSV. Continue OOH T/ 6346'. Total clamps - 26, bands- 3. ***CONT WSR ON 10/02/2024*** 10/1/2024 T/I/O=TWC/0/0+ ND Dry hole tree & THA, Plug 1/8" npt control line ports. Clean & inspect 7" IJ4S lift threads, threads appear damaged, attempted to make up lift sub, could only get 3-1/2 turns before sub locked up. Tubing hanger will need to be speared to pull. LDS all function as they should, clear bowl = 4-1/4". Torque all gland nuts, install new BX 160 ring gasket. RKB to upper LDS = 22.71' 10/2/2024 MIRU HALLIBURTON RIG UP RBT TOOL MAX OD: 3.625" OAL: 29.52' LOG RBT FROM 10230' - 1930' RIG DOWN RBT RIG UP WAVESONIC TOOL: MAX OD: 6" OAL: 51.48' LOG WAVESONIC FROM 10254'-9000' POOH WITH WAVESONIC TOOL ***JOB STILL ON GOING. WSR WILL CONTINUE TOMORROW*** 10/2/2024 PBU C-18B RWO Scope: Continue POOH L/D 5-1/2" BTC 17# L-80 Tubing F/ 6346' - T/ Surface. Cut joint was 37.01', the flare on cut waas 6.2" OD. Calculated holefill observed. Rig down Parker TRS equipment. Remove control line spool and spooling unit off rig floor. Clean and clear rig floor. Install 5" elevators. M/U stack washer and flush BOP, M/U and install 10.25" ID wear bushing. Spot in HES E-Line unit. Bring equipment to rig floor and R/U. M/U CBL tool string per HES reps. RIH T/ 10,230'ELM and POOH performing CBL T/ 1930'ELM, Logged TOC at 2150'ELM (CBL sent in to AOGCC and given approval to move forward with well plan). POOH and L/D CBL tool string. M/U dipole sonic log tool string and RIH T/ 10,257'ELM, correlate and log up to 9000'ELM, Cont POOH T/ 6000'ELM. ***CONT WSR ON 10/03/2024*** Daily Report of Well Operations PBU C-18B 10/3/2024 ***WSR CONTINUED FROM 10/2/2024*** RIG DOWN WAVESONIC AND SHEAVE WHEELS. LEAVE LOCATION MIRU HALLIBURTON ELINE AFTER TCP GUN WAS RAN INTO HOLE ON DRILL PIPE. RAN GR-CCL INSIDE DRILL PIPE TO CORRELATE TCP GUNS MAX OD: 1.69" OAL: 21.35' CORRELATION PASS #1 SHOWED DRILL PIPE NEEDED TO MOVE UPHOLE 3.2' RIG DOWN TOOL AND SHEAVES. RIG MOVED DRILL PIPE RAN GR-CCL FOR 2ND TIME CORRELATION PASS #2 SHOWED DRILL PIPE NEEDED TO MOVE UPHOLE 2.2' POOH ***JOB STILL ON GOING. WSR WILL CONTINUE TOMORROW*** 10/3/2024 PBU C-18B RWO Scope: POOH with dipole sonic log tool string F/ 6000'ELM T/ Surface and L/D per HES reps. Rig down all HES E-Line equipment and remove from rig floor. Clean and clear rig floor. Perform rig Service. While waiting on TCP Gun rep to finish previous job P/U 60 jts DP and rack back in the derrick and perform rig maintenance tasks. On location at 07:00. M/U 3.125" Maxforce 23 gram gun BHA per HES rep. RIH with guns conveyed on 5" DP T/ 9848'. Rig up HES E-Line unit/equipment. RIH with CCL tool string T/ 9780'ELM, log up T 9310'ELM. Use 5' pup jt to correlate depth. Top of pup logged at 9681'ELM putting the bottom of guns at 9843.23'ELM (Desired depth 9840'). Matched gamma with sundry reference log to verify placement. Move drill string up 3.23' picking up in tension and perform second correlation run with E-Line logging top of pup at 9680'ELM. Decision made to pick drill string up another 2.23' and correlate with E-Line. POOH with CCL tool string T/ 2800'ELM. ***CONT WSR ON 10/04/2024*** 10/4/2024 ***WSR CONTINUED FROM 10/3/2024*** POOH WITH GR-CCL TOOL RIG DOWN TOOL AND SHEAVE WHEEL. RIG MOVED DRILL PIPE RAN GR-CCL FOR 3RD TIME CORRELATION PASS #3 SHOWED GUNS WERE ON DEPTH. POOH RDMO HALLIBURTON E-LINE JOB COMPLETED Daily Report of Well Operations PBU C-18B 10/4/2024 POOH F/ 2800' - T/ Surface with CCL tool string. Pick drill string up 2.23' and leave in tension. RIH with E-line T/ 9780' and log up correlating pup joint with CCL. Top of pup logged at 9677.5'ELM putting bottom of guns at 9840.27' (Desired bottom 9840'). POOH and rig down E-line equipment/unit. M/U TIW and circulate drill string volume to ensure ball seat clear of junk. Drop 5/8" ball and P/U to firing mark with string in tension. Pump ball down at 4bpm 600psi, once pressure increased and ball on seat shut down pumps, shut annular and open up to choke. Come on with pumps and walk pressure up observing guns fire at 1923psi. Strip up through the bag 20' while continuing to pump. Shut down and monitor through choke observing no pressure increase. Open Annular and visually flow check - Static. Break off TIW and CBU. PERFS at 9818.89' - 9839.73'. CBU at 9bpm 1100psi. Blow down choke, kill, and top drive. Line up for well control. Monitor well -Static. L/D 5" DP and BHA F/ 9810' - T/ Surface, verified all shots fired. Remove wear ring and rig uip Parker TRS. RIH w/ 4- 1/2" 12.6# L-80 VamTop upper completion per tally F/ Surface - T/ 3593' at 90fpm per tally. ***CONT WSR ON 10/05/2024*** 10/5/2024 Rig freeze protect; Travel to location, SB 10/5/2024 PBU C-18B RWO Scope: Continue to RIH with 4-1/2" 12.6# L-80 VamTop upper completion F/ 3593' - T/ 10,264' and lightly tag top of cut jt. Attempt to slide in dry with no success. M/U to top drive and pump/rotate rolling mule shoe into cut jt. Perform space out, M/U hanger, and land per vault rep having to rotate into cut jt again. RILDS and perform void test on hanger to 5000psi - Good. Reverse circulate 550bbls of 9.0ppg corrosion inhibited brine down the IA. Pressure up to 3500psi setting packer and hold for 5 min. Attempt to perform MIT-T 3x's with no success finding leaking valves on rig each time. Service rig valves. Perform MIT-T and MIT-IA for 30 min each - Good. Bleed off tubing shearing out GLM valve. Vault rep install BPV. M/U Stack washer and flush through BOP and all surface lines, blow down same. N/D BOPE, N/U Tree. Test void to 500/5000psi for 5/30 min and test tree to 500/5000psi for 5 min each - Good. ***Final Report*** 10/6/2024 Rig freeze protect; Pump 173 bbls DSL down IA to FP. U-tube TxIA. 10/6/2024 T/I/O=0/0/0. Post I-Rig RWO, Removed SV from DH configuration and installed new 4" CIW production tree. Torqued to specs. PT'd to 5000 psi (Passed). FWHP=0/0/0. ***Job Complete*** 10/6/2024 T/I/O=0/0/0 Make up hanger to string, run in hole, land on RKB, verify landed by looking @ mark on pup through IA, run in lock down screws, stand by for circ. set 4" CTS BPV via T- bar, stand by for BOP ND, clean void, hanger neck, ring groove, & BPV void, install CTS plug, new BX-160, grease hanger neck, pick up THA/dry hole tree, inspect ID, orient same as wells in row, torque w/ Sweeney, test void 500 psi/5 min., 5,000 psi/30 min., good tests, bleed off test psi, stand by for tree test, pull CTS plug & BPV, RDMO. Final WHP's T/I/O=0/0/0 10/7/2024 ***WELL S/I ON ARRIVAL*** RIG UP POLLARD UNIT 61 ***WSR CONT. ON 10-08-2024*** Daily Report of Well Operations PBU C-18B 10/8/2024 ***WSR CONT. FROM 10-07-2024*** PULL BALL & ROD @ 10071' MD MULTIPLE ATTEMPTS TO PULL ST #2 @ 7406' MD (No Success) RAN KJ, 4-1/2'' OM-1, 10' EXT, 3' EXT, 1.75' LIB TO ST @ 7406' MD RAN 4-1/2" BLB, 3.80" G-RING, BRUSHED STs #1 & #2 MORE ATTEMPTS TO PULL ST #2 @ 7406' MD (No Success) PULLED RK-SOV IN ST# 1 @ 3970' MD MULTIPLE ATTEMPTS TO PULL ST# 3 @ 9554' MD (No Success) ***WSR CONT. ON 10-09-2024*** 10/8/2024 (TFS unit 1 perform FL Freeze Protect). Pumped 9 BBLS of 60/40 and 114 BBLS of crude in accordance to west side recipe. 10/9/2024 ***WSR CONT. FROM 10-08-2024*** MULIPLE ATTEMPTS TO PULL ST#3 @ 9554' MD RAN 3.50" LIB TO RHC @ 10071 MD/10045' SLM (pic of valve in rhc) RECOVERED DGLV FROM RHC @ 10045' SLM SET RK-LGLV (16-64" ports - 1800 tro) IN ST #1 @ 3970' MD SET RK-OGLV (20/64" oriffice) IN ST #3 @ 9554' MD PULL 3.80'' RHC @ 10071' MD ***WSR CONT. ON 10-10-2024*** 10/10/2024 ***WSR CONT FROM 10-09-2024*** RAN 3.70'' CENT, 2' x 1.875'' STEM, 3.74'' CENT, 3.50'' LIB TO S/D @ 11458' SLM (No Picture) RAN 3.70'' CENT, 2' x 1.875'' STEM, 2.50'' S. BAILER TO S/D @ 11458' SLM (2 Cups of Sand) MULTIPLE RUNS w/ 2.50'' x 10' P. BAILER (msfb), BAIL FROM 11458' TO 11473' SLM RAN w/ 10x2.66" D.G, XO, 10'x3.66" D.G., XO, 4-1/2" TEL, B.N FOR CORRECTION OFF TT @ 10271'MD (+26' correction) SET 4-1/2" EVOTRIEVE @ 10190' MD/10164' SLM SET 4-1/2'' JUNK CATCHER (115'' oal, 3.76'' max od) @ 10,165' SLM RUNNING 3.81'' X-LOCK, GAUGE CARRIER, DUAL SPAR-TEK GAUGES (cont on next day) ***WSR CONT ON 10-11-24*** 10/11/2024 ***WSR CONT FROM 10-10-24*** SET 3.81'' X-LOCK, DOWN HOLE GAUGES (sbhps) IN X-NIP @ 10048' SLM / 10071' MD RAN 4-1/2'' CHECK SET TO @ 10,071' MD (sheared) ***JOB COMPLETE, WELL*** 10/26/2024 SLB CTU #8, 1.75" Coil, 0.156" WT. Job Objective: Open NCS Sleeve Post-RWO MIRU and make up NS MHA with NCS sleeve shifting BHA. RIH and open the sleeve at 9815' MD. Good indication sleeve is open (see log for details). POOH and circulate the well to diesel from 4000' MD to surface. RDMO. ***Job Complete*** Daily Report of Well Operations PBU C-18B 10/28/2024 T/I/O = 200/1380/40. Temp = 70°. IA FL (Ops). PBGL online. IA FL @ 9545' (sta #1 SO, 511 bbls). Ops in control of well upon departure. 11:15 10/30/2024 LRS Test Unit 6, Begin WSR on 10/30/24, IL- C-18, OL, C-18KF, Unit Move, Begin RU, Continue WSR on 10/31/24 10/31/2024 LRS Test Unit 6, Continue WSR from 10/30/24, IL- C-18, OL, C-18KF, Continue RU,SB for WS, POP, Stabilize well , Continue WSR on 11/01/24 11/1/2024 LRS Test Unit 6, Continue WSR from 10/31/24, IL- C-18, OL, C-18KF, Continue to Stabilize well, SI, Stack Out Well , Continue WSR on 11/02/24 11/1/2024 T/I/O = 50/170/10. Temp = SI. T FL (WT). PBGL SI @ CV. Made 6 T FL attempts over a 1 hr time period. TP increased 50 psi. IA FL inconclusive. LRS in control of valves upon departure. 21:30 11/1/2024 T/I/O = 80/260/10. Temp = SI. T FL (LRS Well Testing Req). PBGL SI @ CV. LRS well testing rigged up to tree cap. T FL inconclusive. WV = C. SV, SSV, MV = O. IA, OA = OTG. 17:00 11/2/2024 LRS Test Unit 6, Continue WSR from 11/01/24, IL- C-18, OL, C-18KF, Continue to Stack Out Well, Flow Well , Continue WSR on 11/03/24 11/3/2024 LRS Test Unit 6, Continue WSR from 11/02/24, IL- C-18, OL, C-18KF, Continue to Flow Well , Day Light Savings 11/3/2024 LRS Test Unit 6, Daylight savings, IL- C-18, OL, C-18KF, Continue to Flow Well, Begin 12 Hr Well Test , Continue WSR on 11/04/24 11/4/2024 LRS Test Unit 6, Continue WSR from 11/3/24, IL- C-18, OL, C-18KF, Continue 12 Hr Well Test, Continue FLowing , Continue WSR on 11/05/24 11/5/2024 LRS Test Unit 6, Continue WSR from 11/4/24, IL- C-18, OL, C-18KF, Continue FLowing, RDMO, Job Complete, END WSR 11/5/2024 T/I/OA= 340/100/0 (Assist LRS Well Testing with Freeze Protect) Pumped 9 bbls 60/40 followed by 114 bbls crude down F-Line per west side Recipe. Further Pumped 3 bbls of 60/40 from C-18 PBGL to C-20. DSO Notified of well status upon departure. FWHP= 1200/100/0 11/8/2024 LRS Well Testing Unit #6, Begin WSR on 11/8/24, Completed C-18 RD, End WSR on 11/8/24 11/11/2024 T/I/O = SSV/2020/100. Temp = SI. Bleed IAP (OP's request). No AL. IA FL @ 9545' ( Sta# 1 SO, 510 bbls). Bled IAP to OT to 780 psi in 2.75 hrs, OAP decreased 50 psi. IA FL unchanged. Monitor for 30 min, IAP increased 10 psi. FWHP's = SSV/790/100. SV, WV, SSV = C. MV = O. IA & OA = OTG. 16:45. 11/24/2024 ***WELL S/I ON ARRIVAL*** PULL DUEL SPARTEC GAUGES ON X-LOCK FROM 10,070' MD ***CONT WSR ON 11/25/2024*** 11/25/2024 ***CONT WSR FROM 11/24/2024*** TAG JUNK CATCHER @ 10,165' SLM W/ 2.25" CENT & 1.75" S.BAILER (cement sample) PULL STA #1 1.5" RK-ORIF GLV @ 9,545' MD PULL STA #3 1.5" RK-DOME GLV @ 3,961' MD SET 1-1/2" RK-DMY GLV IN STA #3 @ 3,961' MD SET 1-1/2" RK-CIRC VALVE IN STA #1 @ 9,545' MD ***CONT WSR ON 11/26/2024*** Daily Report of Well Operations PBU C-18B 11/26/2024 T/I/O=1411/1359/16 ( PRESSURE TEST ) Assist Slickline. Pumped 5 bbls 60/40 Down IA. Pumped 595 bbls SW down IA. Pumped 180 crude down IA (You Tube TxIA). Freeze Protect Flow line w/ 8 bbls 60/40 and 114 bbls Crude Catch sample Pressure up to 1500 Psi. Test #`1-MIT-T .(FAILED) Pumped 13 bbls crude down TBG to reach max pressure applied 4750 psi. 15 min Loss 199 Psi. 30 min Loss 63 Psi Test #2- MIT-T (PASSED) Pumped 4.7 bbls crude down TBG to reach max pressure applied 4750 psi. 15 min Loss 140 Psi . 30 min Loss 51 Psi Bleed back 3 bbls FWHP=725/216/26 *** Job Continued 11-27-24 *** 11/26/2024 ***CONT WSR FROM 11/25/2024*** SET 4-1/2" PX IN X-NIPPLE @ 9,623' MD SET P-PRONG W/ 4-1/2" BAIT SUB & GUTTED 2-1/2" JD IN 4-1/2" PX @ 9,623' MD LRS CIRC OUT TBG & IA W/ 595 BBLS SEA WATER & 180 BBLS CRUDE. HELD WELL CONTROL DRILL W/ CREW PULLED RKP-FLOWSLEEVE FROM ST#1 @ 9,545' MD. LRS PERFORMED PRESSURE TEST ON PLUG TO ~3000psi. SET 1-1/2" RK-DMY GLV IN STA #1 @ 9,545' MD LRS PERFORM PASSING MIT-T 4500# (seel log for details) ***CONT WSR ON 11/27/2024*** 11/27/2024 ***CONT WSR FROM 11/26/2024*** PULL 4-1/2" PX PLUG & PRONG FROM X-NIPPLE @ 9,623' MD ***WELL S/I ON DEPARTURE, PAD-OP NOTIFIED OF WELL STATUS*** 11/27/2024 *** Job Continued from 11-26-24 *** ( PRESSURE TEST ) RD SB for Grease Crew to RD off of IA Put heater on IA. 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU C-18B Recomplete to Brookian Undefined Oil Pool Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 209-071 50-029-20785-02-00 341J ADL 0028304, 0028305 15089 Conductor Surface Intermediate Liner Liner 8781 80 2894 12038 734 3509 11562 20" x 30" 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" x 2-7/8" 7861 34 - 114 33 - 2927 32 - 12070 11550 - 12284 11580 - 15089 2611 34 - 114 33 - 2676 32 - 8229 7853 - 8393 7874 - 8781 Unknown, 15051 2670 4760 5410 10530 11562, 13208 5380 6870 7240 10160 12935 - 15015 5-1/2" 17# x 4-1/2" 12.6# L80 31 - 116388775 - 8785 Structural 5-1/2" BOT Packer No SSSV Installed 11506, 7822 Date: Torin Roschinger Operations Manager Michael Hibbert michael.hibbert@hilcorp.com 907-903-5990 PRUDHOE BAY 9/13/2024 Current Pools: Prudhoe Oil Proposed Pools: Prudhoe Bay,Brookian Undefined Oil Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov 324-500 By Grace Christianson at 3:07 pm, Aug 30, 2024 DSR-9/5/24 * BOPE test to 3000 psi. Annular to 2500 psi. Review condition of 9-5/8" CBL with AOGCC before perforating. -A.Dewhurst 04SEP24 10-404 A.Dewhurst 04SEP24MGR10AUG24 2611 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.09.11 18:42:04 -05'00'09/11/24 RBDMS JSB 091624 RWO – Brookian UHRC Well: C-18B Well Name:C-18B Permit to Drill:209-071 Current Status:NotOperable, Producer API Number:50-029-20785-02 Estimated Start Date:Sept 25, 2024 Estimated Duration:7days Rig:CDR2 Regulatory Contact:Abbie Barker Sundry Number: First Call Engineer:Michael Hibbert (907) 903-5990 (M) Second Call Engineer:Aras Worthington (907) 564-4763 (O)(907) 440-7692 (M) Program Revision:0 Current Bottom Hole Pressure:3250 psi @ 8,800’ TVDss Res Estimate from Offsets Max Ivishak Anticipated Surface Pressure:2,370 psi Based on 0.1 psi/ft gas gradient Anticipated Brookian BHP:2901 psi Based on normally pressured Reservoir Post Brookian Perf KWF: 8.8 ppg Last SI WHP:2,148 psi 12/15/2023 Min ID:2.30” @ 11,585’ MD SELRT Profile – milled out bushing Max Angle:97 deg @ 13,131’ MD Brief Well Summary: C-18B is an Ivishak natural flow producer that is Not Operable currently due to TxIA communication. Well currently has two 5-1/2” tubing patches and an additional tubing leak below the top patch. The Ivishak production is near marginal GOR, but its return to Operable status would be beneficial to GC3s well stock as a cycle well. The original completion documents indicate that the primary cement job on the 9-5/8” casing went as planned. 10 bbls of losses were noted and after placing 289 bbls of cement that an estimated cement top of 5757’ was achieved behind the 9-5/8” casing. This will be verified during the RWO via cement bond log after the 5-1/2” completion is pulled. Objective: Pull tubing patches. Secure and perform pre-RWO integrity test. Cut and pull the 5-1/2” tubing. Log cement top behind the 9-5/8” casing to confirm TOC. Perforate the Brookian sands, 9820’-9840’. Run 4- 1/2” straddle completion with NCS frac sleeve over the Brookian perforations. The NCS frac sleeve will allow for opening and closing the Brookian interval. The Ivishak lateral will be available in the future to unsecure and flow, but no commingling of the Ivishak and Brookian intervals is planned. Post RWO the Brookian interval will be flow tested. A frac to stimulate the Brookain formation will take place after the flow test. A separate sundry request will be submitted for the fracture stimulation. Current Status: Not Operable, TxIA communication Well Completion Information: Wellhead: McEvoy, 13-5/8” x 4-1/2” tubing hanger 9-5/8” TOC: Top of cement at 5,757’ MD. 30% excess volume pumped. 1620 cu ft of cement circulated behind pipe, 56 cu ft losses. Recent Integrity: ¾04/23/2024 – TIFL FAILED – tubing leak below top patch ¾07/26/2024 – PPPOT-T Passed to 5000 psi ¾07/28/24 – PPPOT-IC Passed to 3500 psi RWO – Brookian UHRC Well: C-18B RWO Procedural Steps: Wellhead 1. PPPOT-T to 5,000 psi (PASSED 07/26/2024), PPPOT-IC to 3,500 psi (PPPOT-IC PASSED 07/28/2024). 2. Function tubing lockdown screws. Slickline & Fullbore 1. Pull 5-1/2” patches from 5807’ and 10,830’. 2. Pull nipple reducer from 11,562’. 3. Set 4-1/2” RWO PX plug in nipple at 11562’. 4. CMIT-TxIA to 3500 psi, max applied 3800 psi. Use dead crude to liquid pack tubing/IA. 5. RDMO All subsequent work pending sundry approval E-Line & Fullbore 1. Jet cut tubing at 10,271’ MD. Targeting to 5’ above collar at 10,276’. Reference Leak Point Survey 8/26/22. 2. Circulate out well to 9.0 brine (add Barakleen to brine to help clean pipe) with diesel freeze protect on tubing and IA. a. After full circ, shutdown and wait ~3 hrs and circ out additional 9.0 ppg brine to remove additional crude. DHD 1. Bleed WHP’s to 0 psi. Valve Shop 1. Set and test TWC (Cameron Type J 6-3/8”). RWO 1. MIRU workover rig. 2. Nipple down tree and tubing head adapter. Inspect landing threads. 3. NU BOPE configuration top down: Annular, 3-1/2” x 6” VBRs, blind/shear rams and integral flow cross. 4. Test BOPE to 250 psi low / 3,000 psi high, annular to 250 psi low / 2,500 psi high, (hold each ram/valve and test for 5-min). a. Record accumulator pre-charge pressures and chart tests. b. Notify AOGCC 24 hrs in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test the 3-1/2” x 6” VBRs with 3-1/2” and 5-1/2” test joint. e. Test the annular with 3-1/2” test joint. f. Submit a completed 10-424 form to the AOGCC within 5 days of BOPE test. 5. RU and pull TWC. RU lubricator if pressure is expected. 6. Rock out crude/diesel freeze protect with 9.0 ppg brine. 7. MU landing joint or spear, BOLDS and pull hanger to the floor. Circulate bottoms up with 1% KCl. a. Expected PU weight in 8.4 ppg KCl = 152k lbs. b. Tensile strength of 5-1/2”, 17# = 428k lbs. 8. Pull existing 5-1/2” tubing from cut. RWO – Brookian UHRC Well: C-18B a. Take pictures of the tubing cut that is pulled out and fit test the 4-1/2” half mule-shoe. b. Place pictures in the well folder. 9. RU EL and complete the following scope of work. a. Run cement log and confirm TOC – log from 10,200’ to 3000’. b. Run dipole sonic log from 9000’ to 10,500’ MD. 10. RIH w/ 3.5” work-string, storm packer and tubing conveyed perforation guns – a. Tie-in, set packer and perforate interval 9,780’-9,850’ MD. Final perforation interval decision will be made post logging runs but will be within the 9,780’-9,850’ MD interval. b. Shut in well and confirm 0 WHP and no flow. c. Kill well as needed. Perform no flow test. d. POOH 11. Run 4-1/2” gas lifted tubing string as per draft tally. Confirm final tally with OE prior to running. a. Torque turn connections. b. NCS sleeve run in closed position – final sleeve depth will be shifted slightly to center across from the perforated interval. 12. Land hanger and reverse in corrosion inhibited 1% KCl or seawater. 13. Drop ball and rod and pressure up to set packers. 14. Perform MIT-T to 4,500 psi (higher test pressure to confirm integrity for subsequent frac). 15. Bleed off tubing pressure to 2,000 psi and MIT-IA to 3,500 psi for 30 charted minutes. 16. Bleed down IA to 2,500 psi after passing MIT-IA. 17. Once IA is bled down to 2,500 psi, bleed off tubing pressure to shear out valve in the top GLM. FP tubing and IA with diesel to 2,500’ MD. 18. Set TWC and ND BOPE. 19. NU tree and tubing head adapter. 20. Test both tree and tubing hanger void to 500 psi low / 5,000 psi high. 21. RDMO workover rig. Valve Shop 1. Pull TWC. Slickline 1. Pull shear-out valve, run KO GLV design. 2. Pull B&R and RHC profile. Coiled Tubing a. Shift NCS sleeve open Portable Testers 1. Post RWO flowback. Attachments – x Current Wellbore Schematic x Proposed Wellbore Schematic x BOP Schematic x Reference Log for Brookian Perforations x Sundry Revision Change Form log from 10,200’ to 3000’ CBL to AOGCC upon completion. - mgr RWO – Brookian UHRC Well: C-18B Current Wellbore Schematic: RWO – Brookian UHRC Well: C-18B Proposed Wellbore Schematic: RWO – Brookian UHRC Well: C-18B CDR2 BOP Schematic: RWO – Brookian UHRC Well: C-18B Reference Log for Brookian Perforations: RWO – Brookian UHRC Well: C-18B Sundry Revision Change Form: Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HNS Prepared By (Initials) HNS Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU C-18B Extended Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 209-071 50-029-20785-02-00 15089 Conductor Surface Intermediate Liner Liner 8781 80 2894 12038 734 3509 13208 20" x 30" 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" x 2-7/8" 8779 34 - 114 33 - 2927 32 - 12070 11550 - 12284 11580 - 15089 34 - 114 33 - 2676 32 - 8229 7853 - 8393 7874 - 8781 Unknown, 15051 2670 4760 5410 10530 13208 5380 6870 7240 10160 12935 - 15015 5-1/2" 17# x 4-1/2" 12.6# L80 31 - 11638 8775 - 8785 Structural 5-1/2" BOT Packer 11506, 7822 11506 7822 Torin Roschinger Operations Manager Michael Hibbert michael.hibbert@hilcorp.com 907-903-5990 PRUDHOE BAY, Prudhoe Oil Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028304, 0028305 31 - 7915 N/A N/A 520 857 48238 25078 72 288 750 800 1052 826 323-649 13b. Pools active after work:Prudhoe Oil No SSSV Installed STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 1:21 pm, Mar 26, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2024.03.26 13:01:35 -08'00' Torin Roschinger (4662) DSR-4/12/24WCB 2024-07-01 RBDMS JSB 040224 ACTIVITY DATE SUMMARY 3/8/2024 TFS U3, (Assist LRS Coil with FL FP), Pumped 9 bbls 60/40 and 114 bbls crude westside recipe for FL FP. Coil in control of well upon departure. 3/8/2024 LRS CTU #1 - 1.50" Blue Coil. Job Objective: Set CIBP, Extended AddPerf MIRU CTU. Make up HES logging toolstring in 2.2" GR/CCL carrier with 2.285" JSN. RIH and load well with slick 1% KCL. Troubleshoot depth encoder discrepancies. ***Job in Progress*** 3/9/2024 LRS CTU #1 - 1.50" Blue Coil. Job Objective: Set CIBP, Extedend AdPerf Continue RIH with HES logging toolstring. Log from 13300' to 11500' at 50 FPM. Painted a green flag at ~ 13100'. POOH. Make up 2.28" NS Extra Range CIBP and RIH. Tie-in to flag and attempt to set at 13195'. Unable to stack weight until a tag at 13208' and set down 6k without movement. Plug apears to have set/stuck in the liner connection. PT CIBP to 1050 psi and lost only 108 psi in 10 mins. Discuss with OE and will move forward with perforating. Perform weekly BOP test. Standby due to low temps. ***Job in Progress*** 3/10/2024 LRS CTU #1 - 1.50" Blue Coil. Job Objective: Set CIBP, Extended Adperf Continue standing by for low temps. ***Job in Progress*** 3/11/2024 LRS CTU #1 - 1.50" Blue Coil. Job Objective: Set CIBP, Extended Adperf Continue standing by for low temps. MU 1.75" DJN and pressure test the lubricator. Start RIH. ***Job in Progress*** 3/12/2024 Coil Pressure-23 (PERFORATING) Assist CTU. Pumped 129 bbls 140* diesel down CTU Coils. Pumped 20 bbls 60/40 down CTU Coils. RD Secure Hardline. 3/12/2024 LRS CTU #1 - 1.50" Blue Coil. Job Objective: Set CIBP, Extended Adperf Continue RIH with 1.75" DJN and circulate in hot 1% KCL from 5750' and place 10 BBL 60/40 freeze protect cap on the well. Perform no-flow test and PJSM / WCD for open hole deployment. Deploy 200' of 2" Maxforce (164' loaded), 6 SPF, 60 degree phase gun. RIH. Tie-in at flag and tag CIBP for confirmation. Perforate 4 intervals: 12935-12965, 12974-13022, 13042-13092, and 13102-13138. Re-tag CIBP to confirm no movement. POOH maintaining hole fill. Confirm well is dead and retrieve perf gun BHA. Make up nozzle BHA with 2.0" JSN. RIH to 7500' and circulate in diesel in attempt to underbalance and assist POP. LRS Hot Oil pump needed to heat diesel. Well still dead when at surface. Stand by for minimum temp before rigging down. ***Job in Progress*** 3/13/2024 LRS CTU #1 - 1.50" Blue Coil. Job Objective: Set CIBP, Extended Adperf Continue standing by for cold temperatures. Finished rigging down and move over to C-41B. ***Job Complete*** Daily Report of Well Operations PBU C-18B )g Perforate 4 intervals:ggg 12935-12965, 12974-13022, 13042-13092, and 13102-13138 g Make up 2.28" NS Extra Range CIBP andggg RIH. Tie-in to flag and attempt to set at 13195'. Unable to stack weight until a tag at g 13208' and set down 6k without movement. CIBP and adperfs are correctly shown on the new WBS, below. -WCB 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU C-18B Extended Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 209-071 50-029-20785-02-00 341J ADL 0028304, 0028305 15089 Conductor Surface Intermediate Liner Liner 8781 80 2894 12038 734 3509 15051 20" x 30" 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" x 2-7/8" 8783 34 - 114 33 - 2927 32 - 12070 11550 - 12284 11580 - 15089 2370 34 - 114 33 - 2676 32 - 8229 7853 - 8393 7874 - 8781 Unknown, 15051 2670 4760 5410 10530 None 5380 6870 7240 10160 13255 - 15015 5-1/2" 17# x 4-1/2" 12.6# L80 31 - 116388779 - 8785 Structural 5-1/2" BOT Packer No SSSV Installed 11506, 7822 Date: Aras Worthington for Torin Roschinger Operations Manager Michael Hibbert michael.hibbert@hilcorp.com (907) 903-5990 PRUDHOE BAY 1/1/2024 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 2:53 pm, Dec 06, 2023 Digitally signed by Aras Worthington (4643) DN: cn=Aras Worthington (4643) Date: 2023.12.06 14:14:39 - 09'00' Aras Worthington (4643) 323-649 10-404 MGR07DEC23 SFD 12/19/2023 Plug Perforations Perforate DSR-11/6/23 2370 *&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.12.20 11:21:18 -09'00'12/20/23 RBDMS JSB 122326 Plug & ExtPerf & Contingent Choke C-18B Well Name:C-18B API Number:50-029-20785-02-00 Current Status:Operable – cycle well Rig:CTU Estimated Start Date:1/1/24 Estimated Duration:4day Reg.Approval Req’std?10-403 Date Reg. Approval Rec’vd: Regulatory Contact:Abbie Barker Permit to Drill Number:209071 First Call Engineer:Michael Hibbert (907) 903-5990 (C) Second Call Engineer:Kirsty Schultz (907) 350-4310 (C) Current Bottom Hole Pressure:3250 psi @ 8,800’ TVD (Based on Average Ivishak BHP) Maximum Expected BHP:3250 psi @ 8,800’ TVD (Based on Average Ivishak BHP) Max. Anticipated Surface Pressure:2370psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:2012 psi (Taken on 11/14/23) Min ID:2.30” SELRT bushing at liner top @ 11,585’ Max Angle:97 Deg @ 13,131’ MD Tie-in Log:SLB Memory PPROF/GHOST dated 10/3/12 (on depth with Reference depths) – see annotated log at the end of this program. The digital log is in .pds format only) Brief Well Summary: CTD sidetrack completed in 2009 as a Zone 1 well. Well had TxIA and was SI from 2015 until 2 patches were set and the well was returned to operable status in September of 2022. Well was competitive for ~1 year. Then in August 2023, CT milled a CIBP that had been set in 2012. Well returned to competitive GOR for ~3 months but has started to cycle again. Objective:This program will isolate the current perforations and add 164’ of charges over 203’ to the well. Operations will POP the well and attempt to flow the well in this configuration. If unable to maintain production, then the CIBP will be milled and a downhole choke will be installed to choke gas production from the toe, but allow the well to get better drawdown from the new heel perforations. Procedure: Coiled Tubing 1. MU GR/CCL with ~2.25” JSN drift. RIH to ~13,250’. Flag pipe and pull tie-in log. a. Flag pipe for plug set (13,195’) and perforating depth as needed. 2. POOH. Correlate with SLB Memory PPROF/GHOST dated 10/3/12 (see attached annotated log). Correct flag and send to Jeff Nelson or OE. 3. Bullhead 1.5X wellbore volume - 425 bbls 1% KCL/SW down tubing. Max tubing pressure 2500 psi. a. Wellbore volume to top perf = 283 bbls b. 5-1/2” Tubing - 11,518’ X .0232 bpf = 268 bbls c. 4-1/2” Tubing – 62’ X .0152 bpf = 1 bbls d. 3-1/2” Liner – 67’ X 0.0087 bpf = 1 bbls e. 3-3/16” Liner – 1608’ X .0076 bpf = 13 bbls 4. MU extra range bridge plug (NS 325-228) or similar. RIH. 5. Set CIBP at 13,195’. 6. POOH. While pulling out of hole confirm well is fluid packed. Coil – Extended Perforating Notes: x Remote gas monitoring for H2S and LELs are required for Open Hole Deployment Operations x Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. isolate the current perforations and add 164’ of charges over 203’ t Remote gas monitoring for H2S and LELs Plug & ExtPerf & Contingent Choke C-18B The well will be killed and monitored before making up the initial perf guns. This is generally done during the drift/logging run. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. 7. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through the brass upon POOH with guns. 8. Use flag from CIBP drift if possible. If needed MU and RIH with GR/CCL in carrier with 2.25” JSN. f. Flag pipe as appropriate per WSS for adperf g. POOH and freeze protect tubing as needed. h. Confirm good log data. 9. At surface, prepare for deployment of TCP guns. 10. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/KWF, 8.4 ppg 1% KCl or 8.5 ppg as needed. Maintain hole fill taking returns to tank until lubricator connection is re-established. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 11.*Perform drill by picking up safety joint with TIW valve and space out before MU guns. Review well control steps with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. i.At the beginning of each job, the crossover/safety joint must be physically MU to the perf guns one time to confirm the threads are compatible. 12.Break lubricator connection at QTS and begin makeup of TCP guns per schedule below. Constantly monitor fluid rates pumped in and fluid returns out of the well. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. Perf Schedule Use 2” Maxforce guns or similar Perf Interval Perf Length Gun Length Weight of Gun (lbs) Run #1 12,935’– 12,965’ – charges 12,965’– 12,974’ – blank 12,974’– 13,022’ – charges 13,022’– 13,042’ – blank 13,042’– 13,092’ – charges 13,092’– 13,102’ – blank 13,102’ – 13,138’ – charges 30’ 9’ 48’ 20’ 50’ 10’ 36’ 164’ 203’ 1137 lbs (5.6 ppf) 13. RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate interval per Perf Schedule above. j. Note any tubing pressure change in WSR. 14. After perforating, PUH to top of liner or into tubing tail to ensure debris doesn’t fall in on the guns and stick the BHA. Confirm well is dead and re-kill if necessary, before pulling to surface. 15. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary. Make up PCE. - mgr Plug & ExtPerf & Contingent Choke C-18B 16. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 17. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 18. RDMO CTU. 19. Turn well over to Operations POP. Contingent CT Step – if well will not maintain flow 1. Confirm with NS downhole choke availability and work with OE/GEO to determine correct orifice size based on flow rates seen from heel perforations. 2. MIRU CT 3. MU milling BHA with 2.25” venturi burn shoe and mill up CIBP and push to ~15,000’ a. Dry tag and flag pipe at CIBP prior to milling and use as tie-in for downhole choke set depth if possible. 4. Make GR/CCL drift/flag run, if needed. 5. MU downhole choke from NS and set at 13,165’. 6. POOH. RDMO. 7. Turn well over to Operations to POP. Attachments: x Wellbore Schematic x Proposed Schematic x Tie-In Log x BOPE diagram x Standing Orders x Equipment Layout x Sundry Change Form Plug & ExtPerf & Contingent Choke C-18B Current Wellbore Schematic Plug & ExtPerf & Contingent Choke C-18B Proposed Wellbore Schematic CIBP –13,195’ C C C C C C C C C C C C C Add perforations from: Contingent Polar Choke –13,165’ Plug & ExtPerf & Contingent Choke C-18B Tie-In Log Plug & ExtPerf & Contingent Choke C-18B Plug & ExtPerf & Contingent Choke C-18B Set CIBP at 13,195’ Contingent Polar choke set depth at 13,165’ Plug & ExtPerf & Contingent Choke C-18B BOP Schematic Plug & ExtPerf & Contingent Choke C-18B Plug & ExtPerf & Contingent Choke C-18B Plug & ExtPerf & Contingent Choke C-18B Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date 2..0°1– 0-1 i Gyrodata Incorporated 0 0 2.Ce,SCall 3000 Northwest Lake Dr. gyro/data " 'Houston;-rexas 77095 T: (281) 213-6300 G F: (281) 213-6301 Precision Wellbore Placeibent SCANNED SEP 1 4 2016 c-- , ,-,,•c„l'','..,'7'4- ...,'' ' t. .. ,., . SURVEY REPORT BP Exploration C-Pad #C-18B Wellhead Prudhoe Bay, North Slope Borough, AK AK0915GCM176 26 September 2015 RIGHT PLACE FIRST TIME • - ,:! 7z- : ,: SQ ',.' •, '.,-2,'.:::; ,., www.gyrodata.com • Gyrodata Incorporated • '13000 Northwest Lake Dr. gyro/clta Houston,Texas 77095 Precision Wellbore Placement T: (281) 213-6300 • F: (281) 213-6301 October 14, 2015 State of Alaska -AOGCC Attn: Makana Bender 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Re: C-Pad, Well # C-18B Prudhoe Bay, Alaska Enclosed, please find one (1) copies, and one (1) disk of the completed survey for the above referenced well. We would like to take this opportunity to thank you for using Gyrodata, and we look forward to serving you in the future. Sincerely, Kelly Landram Senior Operations Assistant RIGHT PLACE FIRST TIME �S \ www.gyrodata.com • • 0 0 ed 0 O O •Y N 0 ox y 3 x 00 o 0 z • , o 5 Z , H Z to o M 0 .-.y •to0•,:i P4 R , . .„:, 6 „, a� . 0 ,� ai o U N .. 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' - • SURVEY QUALITY CONTROL-SPECIFICATION DATA PRE-30B CALIBRATION VERIFICATION CHECK(ROLL TEST) Station ToolFace Gravity Error Scale Factor Rate Error (deg) (Mg) Uncertainty (deg/min) 68 271.65 217.14 0.00005463 -10.95 67 271.65 225.93 0.00005684 -9.89 66 225.75 447.34 0.00011186 -11.09 65 225.75 450.12 0.00011255 -11.89 64 45.30 409.97 0.00010250 -7.42 63 45.29 412.87 0.00010322 -7.32 62 0.17 70.64 0.00001756 -9.71 61 0.17 68.74 0.00001709 -9.65 60 331.51 -211.69 -0.00005276 -9.90 59 331.51 -213.72 -0.00005327 -9.12 58 300.66 -146.66 -0.00003678 -10.77 57 300.66 -149.45 -0.00003748 -10.03 56 271.31 229.35 0.00005770 -9.96 55 271.31 233.82 0.00005883 -9.68 54 242.74 458.04 0.00011493 -11.65 53 242.74 471.27 0.00011825 -11.68 52 211.68 391.34 0.00009758 -12.10 51 211.68 384.31 0.00009582 -11.64 50 181.57 124.55 0.00003096 -9.66 49 181.57 137.96 0.00003430 -9.47 48 151.51 -181.56 -0.00004526 -8.56 47 151.51 -181.44 -0.00004523 -8.44 46 121.83 -151.46 -0.00003798 -7.29 45 121.83 -147.93 -0.00003709 -7.34 44 92.39 193.37 0.00004865 -8.54 43 92.39 194.91 0.00004904 -8.34 42 61.83 428.11 0.00010740 -7.73 41 61.82 431.90 0.00010835 -8.35 40 29.15 331.65 0.00008265 -10.88 39 29.15 337.58 0.00008413 -10.22 38 357.78 16.13 0.00000401 -10.59 37 357.78 11.31 0.00000281 -10.26 36 356.98 5.31 0.00000132 -11.33 35 13.29 46256.03 0.01264112 -70.29 34 356.98 6.27 0.00000156 -10.57 33 269.00 246.42 0.00006200 -16.57 32 269.00 251.25 0.00006321 -16.57 31 224.46 434.43 0.00010860 -13.07 30 224.46 441.57 0.00011039 -16.19 29 44.77 371.41 0.00009284 -11.25 28 44.77 376.64 0.00009415 -11.06 27 359.24 2.72 0.00000068 -13.70 26 359.24 14.72 0.00000366 -14.39 25 328.22 -276.31 -0.00006890 -12.53 24 328.21 -273.47 -0.00006820 -12.88 23 299.66 -161.85 -0.00004060 -12.10 22 299.66 -160.13 -0.00004017 -12.86 21 269.18 249.47 0.00006277 -12.35 20 269.18 243.69 0.00006131 -12.31 19 242.08 468.01 0.00011742 -13.56 18 249.03 20223.88 0.00528709 -102.81 17 242.08 471.24 0.00011823 -14.12 16 208.08 331.19 0.00008252 -12.87 15 208.08 337.90 0.00008420 -12.35 14 180.29 42.92 0.00001067 -9.39 13 180.29 47.13 0.00001171 -9.07 12 150.81 -237.59 -0.00005922 -7.38 11 • 150.81 -236.55 -0.00005897 -7.68 10 118.74 -118.11 -0.00002963 -6.62 9 118.74 -119.41 -0.00002996 -6.21 SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 1 of 7 AK0915GCM176 r • Survey QC - RGS-CT Specification Sheetgy . a 8 90.11 264.09 0.00006645 -5.41 7 90.11 262.88 0.00006614 -5.35 , 6 58.90 446.26 0.00011189 -7.47 5 58.90 456.11 0.00011436 -8.16 4 29.22 287.13 0.00007155 -8.04 3 29.22 284.41 0.00007087 -8.85 2 359.08 -41.56 -0.00001033 -7.59 1 359.08 -41.33 -0.00001027 -7.82 MBO = 0.07 Gravity Error= 1124.28 Scale Factor Uncertainty =0.00030039 Rate Error= -12.51 POST-30B CALIBRATION VERIFICATION CHECK(ROLL TEST) Station ToolFace Gravity Error Scale Factor Rate Error (deg) (Mg) Uncertainty (deg/min) 21712 269.92 181.43 0.00004564 -23.60 21711 269.92 189.83 0.00004776 -24.70 21710 225.88 410.51 0.00010264 -19.91 21709 225.88 413.52 0.00010340 -19.79 21708 44.60 377.36 0.00009433 -18.03 21707 44.60 374.51 0.00009361 -17.93 21706 359.55 49.76 0.00001237 -18.45 21705 359.55 54.39 0.00001352 -18.52 21704 330.31 -235.56 -0.00005872 -20.67 21703 330.31 -227.28 -0.00005666 -19.74 21702 300.16 -180.31 -0.00004522 -19.99 21701 300.16 -183.15 -0.00004593 -20.43 21700 270.13 195.67 0.00004923 -21.35 21699 270.13 203.75 0.00005126 -21.45 21698 240.28 430.26 0.00010790 -19.83 21697 240.28 435.40 0.00010919 -20.24 21696 210.66 365.50 0.00009112 -18.55 21695 210.66 373.21 0.00009304 -18.42 21694 180.53 104.13 0.00002588 -16.03 21693 180.53 108.21 0.00002690 -15.49 21692 150.04 -200.86 -0.00005008 -14.50 21691 150.04 -196.93 -0.00004910 -13.73 21690 120.77 -178.03 -0.00004465 -11.70 21689 120.77 -174.91 -0.00004387 -12.52 21688 91.20 181.38 0.00004563 -12.49 21687 91.20 183.89 0.00004626 -13.99 . 21686 60.08 399.17 0.00010010 -14.62 21685 60.08 406.29 0.00010188 -15.35 21684 29.98 328.79 0.00008195 -16.62 21683 29.98 332.48 0.00008287 -16.49 21682 1.24 77.69 0.00001931 -16.93 21681 1.24 81.27 0.00002020 -17.55 21680 270.13 205.69 0.00005175 -13.66 21679 270.13 210.65 0.00005300 -14.17 21678 226.67 411.88 0.00010300 -18.01 21677 226.67 414.26 0.00010360 -18.78 21676 47.22 376.52 0.00009417 -10.07 21675 47.22 385.67 0.00009646 -11.43 21674 0.50 51.25 0.00001274 -13.34 21673 0.50 54.87 0.00001364 -13.26 21672 330.32 -236.94 -0.00005907 -13.87 21671 330.32 -235.08 -0.00005860 -14.43 21670 300.34 -172.41 -0.00004324 -14.32 21669 300.34 -168.33 -0.00004222 -13.50 21668 270.74 224.44 0.00005647 -14.13 21667 270.74 229.11 0.00005764 -14.98 21666 241.41 444.28 0.00011145 -14.96 21665 241.41 450.90 0.00011311 -15.44 21664 210.73 365.25 0.00009105 -12.37 SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 2 of 7 AK0915GCM176 • • ( M Survey QC - RGS-CT Specification Sheetgy . •' - 21663 210.73 361.55 0.00009013 -13.04 21662 181.66 85.45 0.00002124 -8.26 21661 181.66 96.23 0.00002392 -9.17 21660 151.48 -185.13 -0.00004615 -12.33 21659 151.48 -178.55 -0.00004451 -5.61 21658 122.25 -90.88 -0.00002279 -4.58 21657 122.26 -76.37 -0.00001915 -4.18 21656 93.51 377.59 0.00009503 -4.05 21655 93.51 396.41 0.00009977 -2.64 21654 60.95 642.44 0.00016120 0.06 21653 60.95 693.18 0.00017395 0.17 21652 31.06 585.42 0.00014602 2.31 21651 31.06 567.44 0.00014153 1.46 21650 1.18 264.08 0.00006567 -0.67 21649 1.18 301.36 0.00007494 -0.16 MBO = 0.86 Gravity Error= 180.21 Scale Factor Uncertainty = 0.00004512 Rate Error= -13.61 INITIALISATION Gyro Compass Reading/Station Raw Inclination Raw Azimuth Abs(ERMeas-ERrhee) 111 10.18 48.83 0.0066 112 10.18 49.02 0.0084 113 10.18 48.98 0,0200 114 10.18 48.96 0.0104 115 10.18 48.88 0.0118 116 10.18 48.82 0.0069 117 10.18 48.79 0.0060 Average 10.18 48.90 0.0100 Tolerance on Average* 0.0821 Standard Deviation 0.00 0.09 0.0049 Tolerance on St. Dev.** 0.10 0.20 0.0382 Advanced Initialisation Azimuth Advanced Initialisation Standard Deviation Tolerance=TBA * Tolerance on Average of earth horizontal rate difference is given by (1/Cost)*J[(CosA*SinI*0.1)2+0.0821 °/hr ** Tolerance on Standard Deviation of earth horizontal rate difference tolerance is given by (1/Cosi)*4[(CosA*SinI*0.1)2+(0.082/(n-1))J °/hr DRIFT TUNES Drift Tune Ending Ending Ending Ending Residual Gx Bias Residual Gy Bias Number Time Depth Inclination Azimuth Start End Start End 1 1350.82 2200.73 24.10 32.29 0.005 0.005 -0.002 0.001 2 604.40 2500.71 39.57 31.93 0.004 -0.000 -0.001 0.001 3 1305.13 3901.19 57.00 35.38 0.003 0.000 -0.001 0.001 4 1327.05 5300.85 53.52 35.04 0.003 0.000 -0.003 0.003 5 1366.29 6701.47 52.03 35.45 0.005 -0.001 -0.002 0.002 6 1396.20 8101.85 56.76 38.60 0.005 -0.003 -0.006 0.006 7 1448.02 9602.17 52.01 37.01 0.002 0.000 -0.005 0.005 8 1449.45 11101.68 47.77 36.02 0.004 -0.003 -0.009 0.009 9 783.80 11549.35 45.89 38.09 0.004 -0.004 -0.003 0.004 10 773.74 11002.17 46.72 35.61 -0.008 0.007 0.003 -0.002 SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 3 of 7 AK0915GCM176 • • Survey QC - RGS-CT Specification Sheetg • ' • - •'' 11 1359.45 9602.26 52.05 36.96 -0.004 0.004 0.009 -0.008 12 417.29 9425.98 53.57 37.03 0.000 -0.000 0.002 -0.001 13 1407.73 8103.15 56.94 38.35 -0.003 0.002 0.007 -0.005 14 1570.98 6703.29 51.81 35.33 -0.005 0.003 0.004 -0.002' 15 1450.10 5303.26 53.48 34.56 -0.002. 0.001 0.007 -0.006 16 1488.29 3903.64 57.11 34.83 -0.005 0.003 0.002 -0.002 17 1567.59 2503.12 41.14 31.57 -0.002 -0.001 -0.001 0.001 18 636.02 2203.54 24.58 31.56 0.006 -0.002 0.001 -0.000 19 1400.55 903.44 10.47 45.54 -0.002 0.009 0.007 0.000 Average 0.001 0.001 0.001 0.000 Standard Deviation 0.004 0.004 0.005 0.004 Tolerance for both the Average and the Standard Deviation 0.033°/hr 0.033°/hr 0.033°/hr 0.033°/hr INCLINATION AND AZIMUTH INRUN AND OUTRUN COMPARISON Depth Corrected Inclination Corrected Azimuth Inrun * I Outrun* I Difference Inrun * I Outrun* I Difference 100.00 0.26 0.05 0.22 38.34 142.95 -104.61 200.00 0.17 0.24 -0.07 324.69 15.65 -50.96 300.00 0.27 0.27 -0.00 11.43 20.13 -8.70 400.00 0.31 0.32 -0.01 54.93 82.10 -27.17 500.00 1.17 1.16 0.01 57.54 67.85 -10.31 600.00 2.80 2.89 -0.09 49.50 49.01 0.49 700.00 4.55 4.61 -0.06 42.47 42.92 -0.45 800.00 6.96 7.56 -0.60 47.75 49.19 -1.44 900.00 10.16 10.02 0.15 47.07 46.30 0.77 1000.00 11.88 11.88 0.01 43.65 42.58 1.07 1100.00 14.72 14.85 -0.13 40.47 39.38 1.08 1200.00 17.03 17.02 0.01 39.87 39.00 0.87 1300.00 18.34 18.35 -0.01 40.05 39.02 1.03 1400.00 18.97 18.89 0.09 39.72 39.10 0.63 1500.00 19.17 19.08 0.08 46.75 46.20 0.55 1600.00 18.09 17.91 0.18 47.56 46.15 1.41 1700.00 16.42 16.23 0.18 37.23 36.06 1.17 1800.00 15.10 15.03 0.07 39.11 38.32 0.79 1900.00 14.20 14.09 0.11 42.35 41.53 0.82 2000.00 16.31 16.38 -0.07 34.64 33.81 0.84 2100.00 19.28 19.50 -0.22 33.53 32.72 0.81 2200.00 23.93 24.11 -0.18 32.30 31.62 0.68 2300.00 27.89 28.04 -0.15 32.23 31.66 0.57 2400.00 32.71 32.96 -0.25 32.34 31.79 0.56 2500.00 39.46 39.82 -0.36 31.94 31.41 0.53 2600.00 46.70 47.05 -0.34 31.95 31.38 0.58 2700.00 50.11 50.25 -0.13 31.80 31.20 0.60 2800.00 51.20 51.39 -0.19 32.56 31.95 0.61 2900.00 54.71 54.86 -0.14 33.00 32.46 0.54 3000.00 56.05 56.15 -0.10 33.47 32.92 0.54 SURV-Q167(OPS SUR-MA-003) 19'^Nov 03/Rev 15 Page 4 of 7 AK0915GCM176 • 0 Survey QC - RGS-CT Specification Sheet gy t • . . 3100.00 56.18 56.28 -0.10 34.22 33.67 0.55 3200.00 56.17 56.24 -0.06 34.22 33.68 0.54 3300.00 55.89 55.85 0.04 34.18 33.63 0.56 3400.00 56.57 56.72 -0.15 34.25 33.69 0.56 3500.00 57.30 57.44 -0.13 34.42 33.86 0.56 3600.00 57.72 57.78 -0.06 34.72 34.16 0.56 3700.00 56.80 56.90 -0.10 35.22 34.73 0.49 3800.00 56.95 57.07 -0.12 35.42 34.87 0.55 3900.00 56.90 56.93 -0.02 35.38 34.86 0.52 4000.00 56.74 56.78 -0.04 35.31 34.79 0.52 4100.00 56.70 56.74 -0.04 35.34 34.84 0.50 4200.00 56.67 56.77 -0.10 35.34 34.85 0.49 4300.00 56.41 56.47 -0.06 35.23 34.76 0.47 4400.00 55.65 55.70 -0.05 35.24 34.81 0.43 4500.00 55.54 55.63 -0.09 35.42 34.97 0.46 4600.00 55.02 55.06 -0.04 35.44 34.93 0.51 4700.00 54.93 55.01 -0.08 35.26 34.82 0.44 4800.00 54.83 54.92 -0.09 35.17 34.73 0.44 4900.00 54.55 54.61 -0.06 35.17 34.70 0.47 5000.00 54.35 54.45 -0.11 35.06 34.57 0.49 5100.00 54.00 54.09 -0.08 34.92 34.45 0.48 5200.00 53.09 53.23 -0.15 34.98 34.44 0.54 5300.00 53.40 53.46 -0.05 35.05 34.60 0.45 5400.00 52.91 52.93 -0.03 34.78 34.28 0.50 5500.00 52.45 52.43 0.02 34.58 34.14 0.44 5600.00 52.40 52.43 -0.03 34.48 34.03 0.45 5700.00 52.17 52.24 -0.07 34.41 33.99 0.42 5800.00 52.05 52.09 -0.03 34.29 33.85 0.44 5900.00 52.09 52.15 -0.06 34.10 33.72 0.38 6000.00 51.89 51.86 0.02 34.15 33.81 0.34 6100.00 51.55 51.48 0.07 34.26 33.94 0.31 6200.00 51.61 51.59 0.01 34.33 33.93 0.39 6300.00 51.10 51.11 -0.01 34.49 34.19 0.31 6400.00 51.27 51.30 -0.03 34.99 34.67 0.32 6500.00 51.57 51.53 0.04 35.26 34.98 0.28 6600.00 51.73 51.82 -0.09 35.46 35.17 0.28 6700.00 51.99 51.95 0.03 35.42 35.18 0.24 6800.00 52.13 52.28 -0.15 35.74 35.47 0.27 6900.00 52.51 52.53 -0.01 35.96 35.66 0.29 7000.00 52.45 52.47 -0.02 36.17 35.85 0.31 7100.00 52.67 52.75 -0.08 36.13 35.84 0.29 7200.00 53.16 53.26 -0.10 36.42 36.18 0.24 7300.00 53.25 53.35 -0.10 36.58 36.31 0.27 7400.00 53.53 53.64 -0.11 36.71 36.55 0.16 SURV-Q167(OPS SUR-MA-003) .19th Nov 03/Rev 15 Page 5 of 7 AK0915GCM176 • • Survey QC - RGS-CT Specification Sheet gy • ,` 7500.00 55.12 55.17 -0.05 37.46 37.28 0.18 7600.00 55.05 55.13 -0.08 37.65 37.44 0.21 7700.00 55.48 55.58 -0.10 37.96 37.80 0.15 7800.00 56.46 56.52 -0.06 38.46 38.27 0.19 7900.00 56.42 56.49 -0.07 38.59 38.40 0.19 8000.00 56.57 56.53 0.04 38.65 38.49 0.16 8100.00 56.73 56.81 -0.07 38.60 38.40 0.21 8200.00 56.93 56.99 -0.07 38.33 38.13 0.20 8300.00 56.85 56.85 0.01 38.01 37.87 0.14 8400.00 57.07 57.05 0.02 37.95 37.76 0.19 8500.00 57.01 56.99 0.03 37.92 37.84 0.09 8600.00 56.40 56.38 0.02 37.78 37.66 0.12 8700.00 56.57 56.55 0.02 37.90 37.82 0.08 8800.00 55.82 55.80 0.01 37.87 37.81 0.06 8900.00 55.68 55.73 -0.04 37.94 37.92 0.02 9000.00 55.83 55.76 0.07 37.87 37.80 0.07 9100.00 55.31 55.37 -0.06 37.70 37.58 0.12 9200.00 55.15 55.01 0.14 37.68 37.54 0.14 9300.00 54.23 54.23 -0.01 37.67 37.53 0.14 9400.00 53.73 53.70 0.03 37.41 37.29 0.12 9500.00 52.78 52.82 -0.05 37.16 37.03 0.13 9600.00 52.02 52.06 -0.04 36.95 36.89 0.06 9700.00 51.31 51.32 -0.01 36.59 36.51 0.07 9800.00 50.57 50.60 -0.03 36.58 36.54 0.04 9900.00 49.63 49.64 -0.01 36.20 36.19 0.01 10000.00 48.67 48.68 -0.00 35.98 35.98 -0.01 10100.00 48.23 48.23 -0.00 35.97 36.06 -0.10 10200.00 47.60 47.60 -0.00 35.63 35.69 -0.07 10300.00 47.02 47.03 -0.00 35.21 35.29 -0.08 10400.00 46.25 46.23 0.01 34.87 34.92 -0.05 10500.00 45.74 45.72 0.01 34.98 35.04 -0.06 10600.00 45.08 45.08 0.00 34.75 34.81 -0.07 10700.00 45.13 45.14 -0.01 34.70 34.77 -0.08 10800.00 45.52 45.52 -0.01 34.62 34.70 -0.07 10900.00 46.06 46.08 -0.02 35.23 35.34 -0.11 11000.00 46.73 46.74 -0.01 35.42 35.54 -0.12 11100.00 47.67 47.71 -0.03 36.01 36.11 -0.10 11200.00 47.96 48.00 -0.04 36.17 36.41 -0.25 11300.00 47.57 47.60 -0.04 36.08 36.31 -0.23 11400.00 46.49 46.50 -0.01 36.97 37.14 -0.17 11500.00 46.03 45.96 0.07 37.99 38.11 -0.12 Average -0.0429 0.3224 Standard Deviation 0.1029 0.2998 SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 6 of 7 AK0915GCM176 • • Survey QC - RGS-CT Specification Sheet ► • Tolerance for both the Average and the Standard Casing 0.3° Casing 0.50 Deviation Drillpipe 0.3° Drillpipe 0.75° * Inclination and Azimuth interpolated to same depths as shown. SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 7 of 7 AK0915GCM176 r v di t Survey QC - RGS-CT Analysis Sheetg • 41I I SURVEY QUALITY CONTROL-DATA ANALYSIS REFERENCE SYSTEMS Grid System I I Grid Correction 10.00 Azimuth reference: Grid/True North TRUE NORTH Vertical reference: RKB/MSL/Other RKB I If other give details I TIE ON DATA Depth 0.00 Inclination 0.00 Azimuth 0.00 I TVD 10.00 Northings 0.00 Eastings 0.00 Latitude 70.2989 Az. Ref:Grid/True True Grid Corrected Y/N? N Description I CALIBRATION Tool Number I F0040 I Calibration Date 123 Mar 2015 OPERATING TEMPERATURE Calibration range From 29.88 To 120.05 Gyro operating range From 52.69 To 78.38 I Spec'-Within calibration range FIELD ROLL TEST Only valid on fixed structures. When not ossible input roll test data performed after return to base) Cal value Pre job offset Post job Abs dif.cal.post Abs dif.pre.post Spec' offset Accel Scale 0.000000 0.000000 N/A Cal/Post-0.00015 Mass Unbalance 0.00 0.00 N/A Pre/Post-0.4°/hr INITIALISATION Depth (Approx) 900.65 No of stns 7 Spec'-Min No. -6 Azimuth Mean 48.90 Std deviation 0.09 Spec'-Azi SD 0.2° Inclination Mean 10.18 Std deviation 0.00 Spec'-Inc SD 0.1° Earth Horizontal Rate Mean(Abs(meas-theor)) 10.01 Std deviation 0.00 Spec'-See Q167 DRIFT TUNE Residual x gyro bias Mean 0.001 Std dev' 0.004 Spec's-Mean and SD -0.333°/hr Residual y gyro bias Mean 0.000 Std dev' 0.004 Spec's-Mean and SD - 0.333°/hr TOOLFACE RATE Maximum toolface rate 115.07 I Spec'-400°/sec IN/OUT COMPARISON (AZI' N/A IF INC' <15°) Inclination Difference Mean -0.04 Std dev' 0.10 Spec's -Casing 0.3°/Drill pipe 0.3° Azimuth Difference Mean 0.32 Std dev' 0.30 Spec's -Casing 0.5°/Drill pipe 0.75° Lateral Divergence/1000 3.44 Spec- 5.0/1000 Vertical Divergence/1000 0.54 Spec'- 2.0/1000 DEPTH CONTROL Wireline Company Schlumberger I Line type 7/32 Encoder SF I Schlumberger Max Depth (TD) 11549 CCL Corrected NO Zero Depth(Rig up) RKB @ 66.83 ft AMSL Rezero Depth -13.7 Given pup joint depth NA Measured PJ NA Strech cor.At TD divided by TD/1000 .6061 Spec'- 1.5/1000 Dif. Between rigup and rezero depths divided by TD/1000 1.186 Spec'-2.0/1000 Dif. Between given and meas depth divided by meas/1000 NA Spec'-2.0/1000 SURV-Q165(OPS SUR-MA-010)22nd San 2004/Revision 20 Page 1 of 1 AK0915GCM176 t r • • fit` ♦ y Survey QC - RGS-CT Acceptance Sheet FIELD AND SURVEY INFORMATION Operator BP Exploration(Alaska)Inc. Field/Platform Wellhead Well Number C-Pad C-18 B Survey section From 0.00 ft. to 11549.00 ft. Date 26 Sep 2015 Gyrodata Job No AK0915GCM176 Gyrodata Surveyors Joshua Camacho,Adam O'Connor Job Objective High Accuracy Gyro Survey SURVEY PERFORMANCE In Spec' QC Parameter Yes/No/NA Possible Actions Contact Duty Engineer to discuss options: Operational temperature within Yes 1. Recalibrate tool to higher temperature specification 2. Resurvey with backup tool 3. Resurvey'Hot'section at higher speed Roll test data within specification Contact Duty Engineer to discuss options: Only valid on land/fixed installations Yes 1. Recalibrate tool and reprocess survey 2. Resurvey with backup tool Continuous initialisation within Take new initialisation,after three failures: specification Yes 1. Contact Duty Engineer or, 2. Resurvey with back up tool. Contact Duty Engineer to discuss options: Toolface rate within specification Yes Resurvey section from previous bias check Investigate and comment if effects are negligible Contact Duty Engineer to discuss options: Drift tunes within specification Yes 1. Reprocess with different software settings 2. Resurvey with backup tool Inrun/Outrun comparison within Contact Duty Engineer to discuss options. specification Yes Resurvey is usually not required if either inrun or outrun meet all other QC parameters Depth control within specification Yes Contact Duty Engineer to discuss options. Action taken: Note: Provided satisfactory action has been taken, parameters out with specification will not necessarily fail a survey. SURVEY ACCEPTED Gyrodata Representative Client's Representative SURV-Q166(OPS SUR-MA-003)13th Nov 03/Revision 12 Page 1 of 1 AK0915GCM176 Y V O tr • 6 a) a - v °° L) -D ..t _o _ > 0 u u m X a , a) a) o co � L C tin I- > rts 'c5 ra j:, ! iU '6 ❑ L� a-LLI 1/1 N N N N .LO In L ro Ou L CD O Cr • Y a) u — N L.-7:1C �,, wlnw O 3 °) ^ c c ro O W -, ? 7 Q 7 7 ? i_ 'p Q Q) N Q W HN N "- C -Qi > > N J''''CS] Q C (0 a 2 F-J ❑ O wY u o C Ou > •••• ate-+ u L _c 0 ❑ ❑ ❑ 0 ❑ -I 0 L.C Qi u Q CL w w w w w w w tiA a O O LL LL LL LL LL LL LL a) E -0 Q Q J J J J J J J p_ y0 c a) Cf) I- Q Q Q Q Q Q Q o CD (0 , G C Q Z Z Z Z Z Z Z u r0 -O p u O M1) ❑ LL LL LL LL LL LL LL a) LU L1 a) �/ ".,. . CC u `- a) O 'E R• 7L y '_)> + u L Q; v o S) a v O `" Z r c o _o c v V 0 O w co v v ° w = a �" > H C m o a) Z O U v Z D Q a) _c u > N 2 LL V `° o J J W 2 a 0 2 LIJ C4 O 0 J, 0 m ~ N W o. N .� m o a I.. E. O 3) :. cc w: I cn c d > d w a1 c.) .. W w a a) W `� > o: ❑ \ o . b x tO x ki 01 o3 1 5 a 0 0 0 .J O J J CO VI VI t"----,11 ,1rf o R r r r r r r r o 2 m m m m m m 03 0 2 0 0 0 0 0 0 0 E ❑ x x x x x x x s J ❑ ❑ ❑ ❑ ❑ ❑ ❑ a) u R, a a a a a a a a C > Liu :^7 ,r . C G J 0: L X N o • N / �• W e- t0 O) O) N C) M u �� \Va 0 O O T O O C) 00 .) 0 ,- 0 0 0 0 O f0 p 0 0 0 0 0 0 O Q 0 0 0 0 0 0 O . > ce N N- Q Q W V ❑ V L..) ❑ ❑ V C JJ Nns X Lli CCI Cr O O N O O O Z U IO 0 0 0 0 0 0 0 'CC U N O) c0 O Q) O M N- t C� T 1() co M U) N VCO V Cy) N I"- O C`') CO V 8l 'U) 0 N 0 0 0 N N 0 u N a N N N N N N N F.. Q co O) O) 0) Q) 0) O) O N N N N N N N 7,O) 0 0 0 0 0 0 O v 0 0 0 0 0 0 Oi Il) IC) N In In N II) 3 C. CO c 2- 0 c = W N E GJ U > u QW O W a' C ,c G) I.,- m M Z 01) CO N p o J p « 0J H N d '� a Q N W o V LL 0 C� d x E c co Z d ns H 8 a E i Q ro 117 a a Q Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Monday, January 19, 2015 10:08 AM To: AK, OPS GC3 Facility& Field OTL;AK, OPS GC3 Operators;AK, OPS GC3 Wellpad Lead; AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel, Ryan;AK, D&C Well Services Operations Team Lead;AK, D&C Wireline Operations Team Lead;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS Prod Controllers; AK, OPS Well Pad CX; Wallace, Chris D (DOA); Haffener,Jordan Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Well Integrity Coordinator;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Regg,James B (DOA) Subject: NOT OPERABLE: Producer C-18B (PTD#2090710) Demonstrated TxIA communication Attachments: C-18B Wellbore Schematic.pdf; image001 jpg; image002.png All, Producer C-18B (PTD#2090710) has a tubing leak that was identified by a leak detection log on 01/18/2015. The leak is located in the tubing at 10842MD'. The leak confirms there are not two competent barriers in the wellbore. A tubing tail plug was then set in the well for secure, and a subsequent CMIT-TxIA passed on 01/18/15.The well is reclassified as Not Operable until tubing integrity is restored and verified. Plan forward: 1. APE: Evaluated for repair options A wellbore schematic is attached for reference. Please call with any questions. Thank you, Kevin Parks BP Alaska-Well Integrity Coordinator schwa AN .� �'h G'VV Global Wells Organization Office: 907.659.5102 WIC Email:AKDCWeIllntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Friday, December 26, 2014 2:26 PM To: AK, OPS GC3 Facility &Field OTL; AK, OPS GC3 Operators; AK, OPS GC3 Wellpad Lead; AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Prod Controllers; AK, OPS Well Pad CX; Morrison, Spencer; AK, OPS GC3 Field OTL; Farinez, Javier Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R Subject: Under Evaluation: Producer C-18B (PTD #2090710) Demonstrated TxIA communication 1 All, Producer C-18B(PTD#2090710) is a naturally flowing well exhibited signs of tubing by inner annulus communication while online. While performing initial diagnostics,the inner annulus rapidly tracked the tubing pressure. A patch was set 5810-5830'MD on March 07, 2014 to remediate previous TxIA communication.At this time,the well has been reclassified as Under Evaluation for additional diagnostics. Plan Forward: 1. Slickline: Set Plug, Perform LDL 2. WIE: Additional diagnostics as needed A copy of the TIO plot and wellbore schematic have been included for reference. Please call with any questions. Thank you, Laurie Climer (A11ernale•Jack Disbrow) BP Alaska-Well Integrity Coordinator GW G`� I'Neils Y Y (7rganizat:on WIC Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator@BP.com 1 2 ' " WELLHEAD `�" C-1 8 B WELLHEAD= MCEVOY SAFE]y NOTES: WELL ANGLE>70"@ 12900'. ACTUATOR= OTIS PREVIOUS WELLBORES NOTSHOWN INITIAL KB.ELE 66.83' BF.ELEV= 34.43' O KOP= 900' 2331' —15-1/2"OTIS SSSVN,D=4.562" Max Angle= 97"@ 13131' 2829' H9-518"DV PKR Datum MD= 128.13' Datum TVD= 8700'SS S 5808'-5835' H 5-1/2"BKR PATCH,D=2.87"(03/07/14) 13-3/8"CSG,72#,L-80-BTRS, D=12.347" H 2927' S. $ ( i I 11420' —15-1/2"OTIS XA SLD SLV,ID=4.562" ` - 11488' —15-1/2"TBG SEAL ASSY 5-1/2"TBG,17#,L80-MOD-BTRS, — 11488' -- 11506' --19-518"X 5-1/2"BOT PKR, ID=4.750" .0232 bpf,D=4.897' p / 11518' —{5-1/2"X4-112"XO,D= TOP OF 7"LNR H 11550' 1 I — _ 11550' H9-5/8"X 7"BOT LNR HGR 4-112"X 2-718"NIPPLE REDUCER(01/16/14) H 11562' -------* lir 11562' —4-1/2"OTIS X NIP,D=3.813"BBiPD CT LNR iii 11580' -13.70"BTT DEPLOY RENT SLV Minimum ID =2.30" @ 11585' w14'GS,D-3.00" SELRT PROFILE 11585' HsELRTBUSFINGMLLEDOUT To2.30" I I 11592' 14-1/2'011SXNF*',WILLED TO 3.80"13 BEH ND CT LNR 4-1/2"TBG, 12.6#,L-80,.0152 bpf,ID=3.958" H l 11638' ------____/ \ 11638' 1813-INUCTLNR 4-1/2" WLEG,D=3958" 3-1/2"LNR,9.2#,L-80 STL, H 11647' 1----"----- 1 11647' --13-1/2"X 3-3/16"XO,ID=2.786" .0087 bpf,D=2.992" 9-5/8"CSG,47#,L-80-BTRS,D=8.681" H 12070' , TOC H 12200' '1111 (111 MLLOUT WINDOW(C-18B) 12284'- 12292' WHIPSTOCK — 12280' �11 ►111 ' • RA TAG —I 12289' I ,14Q14�` , — 7"LNR,26#,L-80,114S,ID=6.276" H 1294T l ‘ J :I:t:1:t:�:A 13313' —13-3/16"X 2-7/8"XO,D=2.387" PERFORATION SUMMARY REF LOG:BKR HUGHES MEG GR&WIR 08/08/09 ANGLE AT TOP PEW: 90°@ 13255' , Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz SHOT SO7 ,I 14115' —2-7/8' P 2" 6 13255-13275 0 08/11/09 3-3/16"LM ,6.2#,L80 TCI, H 13313' , qB , (10/04/12) 2" 6 13300- 13350 0 08/11/09 .0076 bpf,D=2.80" , 2" 6 13370-13390 0 08/11/09 2" 6 13485-13525 0 08/11/09 d\, ♦•1 2" 6 13780-13870 0 08/11/09 % 2" 6 14040- 14060 0 08/11/09 , 2" 6 14175--14200 C 08/11/09 1 2" 6 14210-14265 C 08/11/09 e1• 1 2" 6 14280-14390 C 08/11/09 MID --[15051' 14 2" 6 14435-14570 C 08/11/09 2" 6 14630- 14740 C 08/11/09 2-7/8"LW,6.16#,L80 STL,.0058 bpf,13=2.441" H 15089' 2" 6 14835- 14910 C 08/11/09 2" 6 14955-15015 C 08/11/09 I]ATE REV BY COMVENTS DATE REV BY COt? 'JTS PRU DHOE BAY UNIT- 05/23/82 NT05/23/82 N26E IMTIAL COMPLETION 09/11/13 TJH/JMD SET FXN PLUG(08/26/13) VVELL: C-18B 01/28/00 NORDIC 1 CTD SIDETRACK(C-18A) 01/21/14 RK/14) PULLED PXN'SET NP RED(01/16/14 FERMT No: 209071 08/12/09 NORDIC 1 CTD SIDETRACK(C-18B) 03/11/14 GW/JM) SET BKR PATCH(03/07/14) API No: 50-029-20785-02-00 08/13/09 TLH DRLG HO CORRECTIONS SEC 19,T11 N,R14E,555'FNL&1521'FEL 11/13/09 MR/JM) DRLG DRAFT CORRECTIONS 11/16/12 JKC/JND SET 2-7/8"CIBP(10/04/12) BP Exploration(Alaska) • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~ - ~ ~ ~ Well History File Identifier Organizing (done) RESCAN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: „~..ce, iuumiuiriuu DIGITAL DATA ^ Diskettes, No. ^ Other, No/Type: _ R~~,~~~cea uumiiiiiiuiu OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: BY' ~ Maria ~_ Date: % ~`~~ _ /s/ ~ r I I Pro'ect Proofin III II'I II I I III I I III 1 g BY: Maria Date: ~ !s/ ration x 30 = + =TOTAL PAGES Scanning Prepa ^ ~ (Count does not include cover sheet) BY: Maria Date: `/'I/ !s/ Production Scanning "' """""' "" Sta e 1 Pa a Count from Scanned File: ~ (Count does include cover heet) g g Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: /~ ' ~ /s/ ~' Q qi Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO gY: Maria Date: /s/ nnin is coin lete at this Dint unless rescanning is required. (I (II II I) I (III I I II Sca g p P ReScanned III 111111 IIIII II III gY: Maria Date: /s/ Qualit Checked IIIIIIIIIIIIII~IIII Comments about this fife: y 10!6/2005 Well History File Cover Page.doc 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU C-18B Mill CIBP Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 209-071 50-029-20785-02-00 15089 Conductor Surface Intermediate Liner Liner 8781 80 2894 12038 734 3509 15051 20" x 30" 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" x 2-7/8" 8783 34 - 114 33 - 2927 32 - 12070 11550 - 12284 11580 - 15089 34 - 114 33 - 2676 32 - 8229 7853 - 8393 7874 - 8781 Unknown, 15051 2670 4760 5410 10530 None 5380 6870 7240 10160 13255 - 15015 5-1/2" 17# x 4-1/2" 12.6# L80 31 - 11638 8779 - 8785 Structural 5-1/2" BOT Packer 11506, 7822 11506 7822 Torin Roschinger Area Operations Manager Michael Hibbert michael.hibbert@hilcorp.com 907-903-5990 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028304, 0028305 31 - 7915 N/A N/A 477 Well Not Online 42497 42 600 400 1180 0 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV Installed STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 8:31 am, Aug 03, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.08.03 05:53:22 -08'00' Torin Roschinger (4662) WCB 3-8-2024 DSR-8/7/23 RBDMS JSB 080323 ACTIVITY DATE SUMMARY 7/27/2023 CTU#9 1.75" Coil x 0.156" wt Job Objective: Mill CBP, Push to TD MIRU. MU YJ 2.25" 4 Bladed Junk Mill. Pump 240 bbls 1% KCL to knock down WHP. RIH w/ mill. ...Job In Progress... 7/28/2023 CTU#9 1.75" Coil x 0.156" wt Job Objective: Mill CBP, Push to TD Continue RIH w/ YJ 2.25" 4 Bladed Junk Mill. Dry Tag CIBP at 14,166.2' CTMD. Mill 4.5 hours stalling not making depth. POOH. No wear middle of 4 blade junk mill. MU 2.28" ventrui/burnshoe. RIH w/ YJ 2.06" Venturi Junk Basket & 2.28" Burnshoe. Dry Tag on CIBP at 14,161.5'. Mill plug and push to PBTD at 15088.3' CTMD. POOH. ...Job In Progress... 7/29/2023 CTU#9 1.75" Coil x 0.156" wt Job Objective: Mill CBP, Push to TD BD YJ venturi junk basket & burnshoe - recovered small bits of debris. RDMO. ...Job Complete... Daily Report of Well Operations PBU C-18B Mill plug and push to PBTD at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y Anne Prysunka at 2:31 pm, Oct 03, 2022 'LJLWDOO\VLJQHGE\6WDQ*ROLV '1FQ 6WDQ*ROLV RX 8VHUV 'DWH 6WDQ*ROLV RBDMS JSB 120723 MGR06OCT2022 DSR-10/3/22 $&7,9,7<'$7(6800$5< :(//6,21$55,9$/ '5,)7: 3$7&+'5,)7PD[RG 7$*72&526629(5 # 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APP Q h Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ r Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc i Development0 Exploratory ❑ 209-071-0 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number Anchorage,AK 99519-6612 50-029-20785-02-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028305 ` 3D 11- PBU C-18B 9.Logs(List logs and submit electronic and printed data per 201 C25.071): '10.Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth measured 15089 feet Plugs measured 14115 feet true vertical 8815.33 feet Junk measured None feet Effective Depth measured 14115 feet Packer measured See Attachment feet true vertical 8807.81 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"x 30" 32-112 32-112 0 0 Surface 2896 13-3/8"72#L-80 31-2927 31-2660.29 4930 2670 Intermediate None None None None None None Production 12040 9-5/8"47#L-80 30-12070 30-8263.19 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet e�N I' I True Vertical depth See Attachment feet SCANNED `/U L 02014 Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): RBDM MAY 14 2014 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 486 36877 41 0 1304 - Subsequent to operation: 513 27365 44 0 889 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 0 Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil 0 Gas ❑ WDSPLI GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A I Contact Nita Summerhays Email Nita.Summerha s• b..com Printed Name Nita Summerh- s Title Data Coordinator Signatu = ^yam/*,. - -%�/;��yly�i�� Phone 564-4035 Date 4/7/2014 VLF Form 10-404 Revised 10/2012 ,f�/�1 7 Submit Original Only Daily Report of Well Operations ADL0028305 ACTIVITYDATE I SUMMARY TY I • V• pa c - u•Ing Iver 1/14/2014 1/15/2014 ***WSR continued to 1-16-14*** ****CONT JOB FROM 1-14-14****(patch-tubing/liner) DRIFT W/3' 1-7/8" STEM, 4.55" CENT TO 5950' SLM. DRIFT W/5-1/2" DUMMY PATCH DRIFT TO 6000' SLM**see log for details**(dropped drift pulling ooh) PULL 5-1/2" DUMMY PATCH DRIFT FROM 11,448' SLM. 1/15/2014 ****CONT JOB ON 1-16-14**** ***WSR continued from 1/15/14*** Rig to Lubricator. Standby for S-line. ( Performed 1/16/2014 simulated fire drill ) Standby for Weather. ***WSR continued to 1-17-14*** ****CONT JOB FROM 1-15-14**** PULLED PX PLUG FROM X-NIP @ 11,523' SLM/11,562' MD SET 4-1/2"x 2-7/8" NIPPLE REDUCER IN X-NIP @ 11,523' SLM/11,562' MD 1/16/2014 ****LAY DOWN DUE TO WEATHER, CONT JOB ON 1-17-14**** 1/17/2014 ***WSR continue from 1-16-14***Standby for weather to improve. Job delayed. 1/19/2014 T/I/O=x (Assist S-Line/ Load and test***WSR continued to 1-20-14*** ****WELL S/I ON ARRIVAL****(patch-tubing/liner) R/U SLICKLINE 1/19/2014 ****CONT JOB ON 1-20-14**** ***WSR continued from 1-19-14***T/I/O = 88/89/5 Temp= S/I Assist SSL with Load and Test(CMIT TxIA to 2500 psi PASSED ) Pumped 22 bbls Dead Crude down TBG and IA to achieve a test pressure of 2500 psi. (CMIT TxIA) T/IA lost 7/6 psi in 1st 15 min T/IA lost 5/4 si in 2nd 15 min. T/IA lost a total of 12/10 psi over the 30 min test. Bleed Tx IA to 300 psi. Standby for S-Line to pull TTP. SSL in control notified pad op upon departure. FWHP =67/55/7 SV/W/SSV/M = SSL 1/20/2014 IA/OA= OTG ****CONT JOB FROM 1-19-14**** (patch-tubing/liner) CHECK SET 4-1/2" NIP REDUCER @ 11,523' SLM/11,562' MD.(check set confirms good set) SET 2-7/8"XX-PLUG IN 4-1/2" NIP REDUCER @ 11,562' MD. PASSING CMIT T x IA TO 2500psi PULLED 2-7/8" XX-PLUG IN 4-1/2" NIP REDUCER @ 11,562' MD. 1/20/2014 ****WELL LEFT S/I ON DEPARTURE, NOTIFY PAD-OP OF STATUS**** 1/I/O =80/110/0+. Temp=SI. T& IA eine . No AL. T FL @ surface. IA FL near surface. 2/15/2014 SV, WV=C. SSV, MV=0. IA, OA=OTG. 12:15. 3/6/2014 Assist E-Line (PATCH TUBING/LINER) ***Job continued to 3/7/14*** ***JOB CONTINUED FROM 6-MARCH-2014*** (ELINE PATCH SET) RIH W/ ELINE TOOLSTRING W/BAKER 5-1/2" PATCH SET PATCH.@ 5810-5830' ELEMENT TO ELEMENT (TOP @ 5808')/BTM @ 5835') (SPECS OF PATCH = 27.14' OAL/4.52" MAX OD/2.87" MIN ID) WELL LEFT SI ON DEPARTURE.- NOTIFIED PAD OP OF WELL STATUS FINAL T/I/O = 0/150/0 3/7/2014 ***JOB COMPLETED*** ***Job continued from 3/6/14 WSR*** Assist E-line (PATCH I UBING / LINER) Job 3/7/2014 posponed Daily Report of Well Operations ADL0028305 T/I/O= 77/122/20 Temp=S/l MIT-IA to 2500 PSI PASSED (Post patch) Pumped 17.84 bbls MEOH to test. 1st 15 min IAP lost 60 &2nd 15 min IAP lost 28 for a total IAP loss of 88 in 30 min. Bled back— 9 bbls. FWHP's=64/230/0 Upon departure DSO notified of 3/8/2014 SWV,WV=S/I IAV,OAV=OTG FLUIDS PUMPED BELS 4 DIESEL 22 CRUDE 18 METH 44 TOTAL m N 0 m O W N LO r CO 00 N N 0 00 OO OO t ti M t() 01 N O II) Tr OO M N N , N Ti Ti 1.11 00 0 a r ' ' ' 000T- e � N e- y- p 00000000 OO OD OD OO OD OD 00 0000 00CO 000000 OD CO OD OO OD 00 0000 W Z m W p O a0 > O Y NC- I- I- CO CO 141 C- 0) N CD M N U) M U U W W 141 C'J ' OO CO CO N CO N Q) M CO r a s m LIJZ N M OO O C� C� M 0 Lo 0 OO W m r r r O O O O r r r r r J W W O (7 C] 000000000000000000000 0000 O JJ J p J c) CO CO O CO CO CO CO CO CO CO CO co CO = 0 0 0_ W 0 F- Z 1- p p a ¢ a O v) v) v) m• m ar w (a • LO00LO000tnoOO OLO ++ C- tO) O) N C- 00 O 0) C- i r • 0 CNCMCMt0iMCOnrnrnrnrnrnr nrLO EA .0 2 a, _ H 0 d J d 0 0 CO U) v)03 cn v) c co a N O O ~ C p Y to O O to O O to O O Ul O UI UI J p, t41 O f� CO8 C� CO M M Mtig lL') QG cN7mmmmCO00 T' r TrTrNV TrTr TrTr eco L a, O 2 t a O U c E a a a a a a a a a a a a s • m m m m m m CO m CO m m m m O. 0 t ar a. W p u) J G Tr Tr Tr Tr v Tr Tr Tr v v v Tr Tr 0 O O O O O O O O O O O O O O O J ZLL O N N N N N N N N N N N N N 0. :5 W W 0 0 0 0 0 0 0 0 0 0 0 0 0 W J W W U- C a N N N N N N N N N N N N N (9 0 W W LL W ap J J > > 0: a J J O CL _ C7 C7 W w m ti LL Cn 0) 0- 0: a> E co zmcoca coca cam mmmm mm 3 00 CO OD CO OD CO OD OD CO 00 CO OD CO CO 0 N CL LL 0- 0 -100LLICI- • U U U U U U U 6._(3 U U U V m LL LL m co 0. CD CD ego � a°'o'� N- CO0 p 71- 11"c M v N M 0- V CD 1.0000 "Cr , 0- M M M• N- Or _ C CO 0- 00 O r 0 M O CD Nr CC) Nr CO O) r N O) CO • A-- CO M 0 M O M ✓ r0rrCD0000dh OD O) W O N CO CO o0 N- O o0 co N ti ▪ UD Nr u Off) C") 00 NC) M m-M o coN- N- w co C) N- O) 0000 CO CO r O) CO MOON 0 0 r N r M 0 N r r r r r r ren N r r 02 NinO r O r r CO CN M0000MMMC() 0 CO r r r M r r r r C I-- 0 QO 000 m 0 0 m _1_1 •N N COr) N CSO N• CSO _ - T- /. NCCO NNinCO- QObpN - N - t) M M M N O 0 t DOO�) NC(OCO � 000 COC') v- (0N- CO N J r r r r N r z W H D D < o o 0 OWWWWoLLZZ ZwWWWOcmm O ZZZZWDDD O C/) I— I— • Packers and SSV's Attachment ADL0028305 SW Name Type MD ND Depscription C-18B PACKER 5808 4249.84 5-1/2" BAKER ZXP PACKER C-18B PACKER 5835 4266.63 5-1/2" BAKER ZXP PACKER C-18B PACKER 11506 7788.69 5-1/2" BOT Packer MEE SAFE.. .IOTES: WELL ANGLE>70'@ 12900' WELLFEAD= MCEVOYC $ DEPLOYMENT SLV DEPTH IS OFF BY 27"' ACTUATOR= OTIS MIfiAL KB.R F 66,83' Il , PREVIOUS WELLBORES NOTSHOWN BF.ELEV= 34.43' 2331' -I 5-117 OTtS SSSVN,D=4.562" KOP= 900' Max Angle=---97'@ 13131' 2829' -19-5/8"DV PKR Datum MD= 12813' Datum ND= 8700'SS FSS'-{ 5808'-5835' -15-1/7 BKR PATCH D=2.87"(03/07/14) 13-3/8"CSG,72#,L-80-BTRS, D 1=12.347" - 2927' $ 11420' H 5-1/2"OTIS XA SLD SLV,D=4.562" II • 11488' -�5-1/2"TBG SEAL ASSY 5-1/2"TBG,17#,L80-MOD-BTIZS, - 11488' 11506' H9 5i8"X 5 1Y2"�T PKR D=4.750" .0232 bpf,D=4.897 11518' --I 5-1/7 x 4-1/T X0,D=7 TOP OF 7"LNR H 11550' t ] 11550' -I 9-5/8"X 7"BOT LNR HGR 4-1/2"X 2-7/8"NIPPLE REDUCER(01!16/14) - 11562' IF 11562' -4-1/2"OTlS X NP,D=3.813"BHIND CT LNR 11580' -3.70`BTT DE OY t&NT SLV Minimum ID = 2.30" @ 11585' -- w!4"GS,D-3.tX1" SELRT PROFILE 11585' �SEIRTBUSEWIGMILLEDO TTO2.30" 11592' -4-1/2"OTIS XN NP,PALLED TO 3.80"D BEHNDCT LNR I_4-1/7'TBG, 12.6#,L-80,.0152 bpf,ID=3.958" - 11638' ---�� \ 11638' -4-1/2" WLEG,D=3.958" BEHIND CT LNR 3-1/2"LHR,9.2#,L-80 SIL, -1 11647' 1---"---- - 11647' -{3-1/7X3-3/16"X0,ID=2.786" .0087 bpf,D=2.992" 9-5/8"CSG 47#,L-80-BTPS,D=8.681" -j 12070' , TOC --{ 12200' I ,4'4 'cc MLLOUT WINDOW(C-18B) 12284'- 12292' HIPSTOCK H 12280' -�V. ►,.. W . RA TAG -i 12289' I-- ,'•,.. , 7'LHR,26#,L-80,U4S,D=6.276" -{ 12947' 4� :tttttiVi 13313' -3-3/16"X2-7/8"X0,D=2.387" 1 PERFORATION SUMMARY / REF LOG BKR HUGI-ES IJTEG GR&MF�2 08/08/09 ANGLE AT TOP FEW: 90"@ 13255' % Note:Refer to R'oduction DB for historical perf data , SIZE SPF INTERVAL Opn/Sqz SHOT SOZ , L 14115' -2-7/8'CIBP 7 6 13255-13275 0 08/11/09 3-3116"LNR,6.2#,L80 TC11„, - 13313' , (10/04/12) 2" 6 13300- 13350 0 08/11/09 .0076 bpf,D=2.80" , 7 6 13370-13390 0 08/11/09 7 6 13485-13525 0 08/11/09 1\, 7 6 13780-13870 0 08!11/09 , 7 6 14040-14060 0 08/11/09 , 2" 6 14175-14200 C 08/11/09 7 6 14210- 14265 C 08/11/09 �4. 7 6 14280 14390 C 08/11109 PBTD i 15051' 4.v 7 6 14435-14570 C 08/11/09 2" 6 14630-14740 C 08/11/09 2-7/8"LW,6.16#,L80 STL,.0058 bpf,D=2.441' - 15089' 2" 6 14835-14910 C 08/11/09 7 6 14955-15015 C 08/11/09 DATE REV BY CONIVENTS DATE REV BY COMMENTS PRUDFIOE BAY INT 05/23/82 N26E INITIAL COMPLETION 09/11/13 TJWJMD SET PXN PLUG(08/26/13) WELL: 0-188 01/28/00 NORDIC 1 CTD SIDETRACK(C-18A) 01/21/14 RK/JM? RILED PXN/SET NP RED(01/16/14 PERMIT WI 209071 08/12/09 NORDIC 1 CTD SIDETRACK(C-18B) 03/11/14 GW/JM? SET BKR PATCH(03/07/14) AR No: 50-029-20785-02-00 08/13/09 TLH DRLG HO CORRECTIONS SEC 19,T11 N,R14E,555'FTI-.&1521'FEL 11/13/09 MR/JMD CRLG DRAFT CORRECTIONS 11/16/12 JKC/JMD SET 2-7/8"CBP(10/04/12) BP Exploration(Alaska) STATE OF ALASKA • AKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon L_I Repair Well U Plug Perforations U Perforate LJ OtherU Performed: Alter Casing ❑ Pull TubinJ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development Exploratory ❑ 209 -071 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20785 -02 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028305 PBU C -18B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 15089 feet Plugs measured 14114 feet true vertical 8815.33 feet Junk measured None feet Effective Depth measured 14114 feet Packer measured 11506 feet true vertical 8807.81 feet true vertical 7855.52 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" x 30" 32 - 112 32 - 112 Surface 2896 13 -3/8" 72# L -80 31 - 2927 31 - 2660.29 4930 2670 Intermediate None None None None None None 1 Production 12040 9 -5/8" 47# L -80 30 - 12070 30 - 8263.19 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet a ' k NO 1 ?01Z True Vertical depth See Attachment feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) 5 -1/2" BOT Packer 11506 7855.52 Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 663 42013 56 0 1456 Subsequent to operation: 831 28102 69 0 1223 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development El Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil 151 Gas ❑ WDSPLI J GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Garry Catron Email Gar/ .Catront BP.Com Printed Name Garry Catron Title PDC PE Signature ea C _,. Phone 564 -4424 Date 10/31/2012 V do , ///i It tL 1 Form 10 -404 Revised 10/2012 Submit Original Only Daily Report of Well Operations ADL0028305 ACTIVITYDATE amaiiiiiiim 1 ' - . of o• cope: "' • : • MIRU Coil. POP well, make up 2.25" Drift BHA and RIH for Tag. Tagged TD at 14966'. PUH 26' and flag pipe at 14940'. POOH. MU WFD MHA and SLB logging toolstring and RIH. 10/2/2012 ** *Job continued on 10/3/12 * ** CTU #3 - 1.75" Coil Job Scope:PPROF /CIBP RIH w/ WFD MHA and SLB logging toolstring. Wait for well to stabilize and log stop counts at 11530', 11700', 13000', 13437', 13652', 13955', 14117', 14412', 14600', 14787', and 14932'. Finish stop counts RBIH allow well to stabilize. Perform 40,60 and 80 fpm up passes Painted white and • red flag at 13399' . POOH at surface BD tools check for data. * * * * * ** Job continued on 10/4/12 10/3/2012 * * * * * ** CTU #3 - 1.75" Coil Job Scope: Set CIBP RIH w/ WFD 2 -7/8" CIBP. Tie -in using MCNL LEE TNN /TNF /GR /CCL 09- Aug -2009. Set CIBP ME at 14115'. POOH.At surface recovered ball. Perform weekly BOP test. Packoffs and chain inspection 10/4/2012 RDMO. * * * * * * ** Job Complete * * * * * * ** • I I Casing / Tubing Attachment ADL0028305 Casing Length Size M D TVD Burst Collapse CONDUCTOR 80 20" x 30" 32 - 112 32 - 112 LINER 1397 7" 26# L -80 11550 - 12947 7886.45 - 8811.85 7240 5410 LINER 58 3 -1/2" 9.2# L -80 11590 - 11648 7914.65 - 7955.7 10160 10530 LINER 1665 3- 3/16" 6.2# L -80 11648 - 13313 7955.7 - 8813.51 LINER 1776 2 -7/8" 6.16# L -80 13313 - 15089 8813.51 - 8815.33 13450 13890 PRODUCTION 12040 9 -5/8" 47# L -80 30 - 12070 30 - 8263.19 6870 4760 SURFACE 2896 13 -3/8" 72# L -80 31 - 2927 31 - 2660.29 4930 2670 • TUBING 11487 5 -1/2" 17# L -80 31 - 11518 31 - 7863.94 7740 6280 TUBING 120 4 -1/2" 12.6# L -80 11518 - 11638 7863.94 - 7948.6 8430 7500 • f Perforation Attachment ADL0028305 SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base C -18B 8/11/2009 PER 13255 13275 8812.58 8812.79 C -18B 8/11/2009 PER 13300 13350 8813.26 8814.39 C -18B 8/11/2009 PER 13370 13390 8815.1 8815.52 C -18B 8/11/2009 PER 13485 13525 8814.85 8814.35 C -18B 8/11/2009 PER 13780 13870 8807.87 8805.21 C-1115____ 8/11/2OQ� _ _ ,PER _____� ,_��14040.. _ _ 4060 8807.69 :807.56_ C 18B \ /4/2012 -- ' BB'S T4175 —' — 14 — r0 8807 -1 8808:18 ■ • / C -18B 10/4/2012 BPS 14210 14265 8808.62 8810.52 C -18B 10/4/2012 BPS 14280 14390 8810.29 8810.42 C -18B 10/4/2012 BPS 14435 14570 8813.93 8811.88 C -18B 10/4/2012 BPS 14630 14740 8815.32 8822.38 b ? C -18B 10/4/2012 BPS 14835 14910 8818.65 8817.28 C -18B 10/4/2012 BPS 14955 15015 8818.13 8819.26 AB ABA ' • NED IR MECHANICAL ISOLATED • ' OVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED • RPF REPERF TREE ; CM/ e S NOTES: ** *ORIGINAL & C-1 8A WELLBORES WELLHEAD = MCEVOY C -1 1 8 B NOT SHOWN BELOW WHIPSTOCK** *WELL ANGLE > ACTUATOR = OTIS .... .. 70° A 12900'. KB. ELEV = 66.83' I ' BF. ELEV = 34.43' I 2331' H5 -1/2" OTIS SSSVN, ID = 4.562" KOP = 900' Max Angle = 97° @ 131 — — 2829' H9 -5/8" DV PKR I Datum MD = 12813' Datum TVD = 8700' SS 113 -3/8" CSG, 72 #, L -80 -BTRS, ID = 12.347" 292T I I 11420' —I 5-1/2" OTIS XA SLD SLV, ID = 4.562" I 5 -1/2" TBG, 17 #, L80- MOD -BTRS, —I 11488' 11488' H5-1/2" TBG SEAL ASSY I .0232 bpf, ID = 4.892" 11506' H9-5/8" X 5-1/2" BOT PKR ID = 4.750" I I 11518' 1-15-1/2" X 4-1/2" XO, ID = ? I TOP OF 7" LNR H 11550' 11550' I-19-5/8" X 7" BOT LNR HGR I I 11562' I— 4 -1/2" OTIS X NIP, ID = 3.813" BEHIND CT LNR Minimum ID = 2.30" @ 11585' I 11580' I— 3.70" BTT DEPLOYMENT SLV SELRT PROFILE w /4" GS, ID -3.00" 11585' H SELRT BUSHING MILLED OUT TO 2.30" I I 11592' I— 4 -1/2" OTIS XN NIP, MILLED TO 3.80" ID BEHIND CT LNR 4 -1/2" TBG, 12.6 #, L -80, .0152 bpf, ID = 3.958" H 11638' I I 11638' I—I4 -112" WLEG, ID = 3.958" ( BEHIND CT LNR 3 -1/2" LNR, 9.2 #, L -80 STL, --I 11647' 11647' H3-1/2" X 3- 3/16" XO, ID = 2.786" I .0087 bpf, ID = 2.992" 19 -5/8" CSG, 47 #, L -80 -BTRS, ID = 8.681" H 12070' TOC 12200' I� I �1 ��•1 I MILLOUT WINDOW (C -18B) 12284' - 12292' I WHIPSTOCK H 12280' j • � • � • • • � • � ■ IRA TAG H 12289' I ,`/4, • , 4, 17" LNR, 26 #, L -80, IJ4S, ID = 6.276" I-i 12947' Att•Attl 13313' -13-3/16" X 2 -7/8" XO, ID = 2.387" I PERFORATION SUMMARY REF LOG: BKR HUGHES INTEG GR & MPR 08/08/09 ANGLE AT TOP PERF: 90° @ 13255' , Note: Refer to Production DB for historical perf data , SIZE SPF INTERVAL Opn /Sqz DATE 2" 6 13255 - 13275 0 08/11 /09 3- 3/16" LNR, 6.2 #, L80 TGI, 13313' 1 w i t s' G I a P 2" 6 13300 - 13350 0 08/11/09 0076 bpf, ID = 2.80" % 1014112. 2" 6 13370 -13390 0 08/11/09 2" 6 13485 -13525 0 08/11/09 , 2" 6 13780 -13870 0 08/11/09 % 2" 6 14040 - 14060 0 08/11/09 ` 2" 6 14175 - 14200 fis O 08/11/09 2" 6 14210 - 14265 121 08/11/09 4, ♦ 2" 6 14280 -14390 ,0r G 08/11 /09 I PBTD H 15051' . 4,4), 2" 6 14435 -14570 12(C/ 08/11/09 2" 6 14630 - 14740 RI C/ 08/11 /09 12 -7/8" LNR, 6.16 #, L80 STL, .0058 bpf, ID = 2.441" I-I 15089' 2" 6 14835 - 14910 kr G 08/11/09 2" 6 14955 - 15015 .d Ci 08/11/09 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/23/82 ORIGINAL COMPLETION WELL: C-18B 01/28/00 CT SIDETRACK PERMIT No: 209071 08/12/09 NORDIC 1 CTD SIDETRACK (C -18B) API No: 50- 029 - 20785 -02 -00 08/13/09 TLH DRLG HO CORRECTIONS SEC 19, 711N, R14E, 555' FNL & 1521' FEL 11/13/09 MR/JMD DRLG DRAFT CORRECTIONS BP Exploration (Alaska) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 August 22, 2011 RECEIVED • Mr. Tom Maunder AUG R 1 21111 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue ' O a Gag Cm Cm. B on Anchorage, Alaska 99501 Ancl~envq Subject: Corrosion Inhibitor Treatments of GPB C -Pad c Ocj— C)7/ Dear Mr. Maunder, — J Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB C- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) C -Pad 7/19/11 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft na gal C -01A 2030100 500292012101 0.3 NA 0.3 NA 3.40 11/16/2010 C -02 1730040 500292012300 0.3 NA 0.3 NA 3.40 11/16/2010 C -03B 2051580 500292012402 0.3 NA 0.3 NA 3.40 11/16/2010 C -04B 2060570 500292012502 1.25 NA 1.25 NA 23.80 10/26/2010 C -05A 2010020 500292012601 0.8 NA 0.8 NA 3.40 11/23/2010 C -06B 2061040 500292012702 1 NA 1 NA 5.10 11/22/2010 C -07A 2000520 500292012801 0.3 NA 0.3 NA 1.70 11/22/2010 C -08B 2050110 500292012902 1 NA 1 NA 5.10 11/20/2010 C -09A 2020940 500292036601 0.1 NA 0.1 NA 0.85 11/23/2010 C -10A 2051370 500292037101 0.1 NA 0.1 NA 3.40 11/12/2010 C -11A 2030480 500292038201 0.1 NA 0.1 NA 1.70 11/13/2010 C -12B 2090850 500292038702 2 NA 2 NA 10.20 11/11/2010 C -13A 1971430 500292040401 10.7 NA 10.7 NA 74.80 11/25/2010 C -15A 2090520 500292042701 10.5 NA 10.5 NA 64.60 11/25/2010 C -16B 2060510 500292043802 45 10.0 0.6 7/19/2011 3.40 7/19/2011 C -17B 2040940 500292043902 1 NA 1 NA 6.80 11/13/2010 C -18B 2090710 500292078502 9.6 NA 9.6 NA 69.70 11/23/2010 C -198 2000050 500292073502 11 NA 11 NA 76.50 10/27/2010 C -20C 2091300 500292074503 1.9 NA 1.9 NA 10.20 11/11/2010 C -21 1820810 500292074503 1.7 NA 1.7 NA 8.50 11/11/2010 C -22A 2060390 500292075801 0.7 NA 0.7 NA 5.10 11/11/2010 C -23C 2081700 500292077503 25 4.0 0.08 7/15/2011 0.85 7/19/2011 C -24A 2040580 500292081601 Sealed NA NA NA NA NA C -25B 2041090 500292081902 0.7 NA 0.7 NA 3.40 11/22/2010 C -26A 1981450 500292083401 0.8 NA 0.8 NA 3.40 11/22/2010 C -27B 2031860 500292084302 7.5 NA 7.5 NA 39.10 11/21/2010 C -288 2100630 500292086702 1 NA 1 NA 5.10 11/21/2010 C -29A 1961700 500292147201 23 10.0 0.9 7/15/2011 6.80 7/19/2011 C -30A 2081690 500292177701 0.2 NA 0.2 NA 1.70 11/20/2010 C -31B 2030080 500292177502 0.8 NA 0.8 NA 5.10 11/22/2010 C -32C 2061390 500292155903 0 NA 0 NA 0.00 11/13/2010 C -33A 2002020 500292237301 1 NA 1 NA 6.80 11/11/2010 C -34A 2060370 500292178501 2.2 NA 2.2 NA 10.20 11/20/2010 C -35B 2061290 500292155302 1.5 NA 1.5 NA 10.20 11/15/2010 C -36A 2000020 500292179001 2 NA 2 NA 10.20 11/13/2010 C -37B 2101000 500292236002 4.7 NA 4.7 NA 30.60 10/28/2010 C -38 1860660 500292157100 0.1 NA 0.1 NA 0.85 11/15/2010 C -39A 2050030 500292238301 1 NA 1 NA 0.85 11/23/2010 C -41A 2041880 500292238501 Sealed NA NA NA NA NA C-42 1930500 500292235700 2.6 NA 2.6 NA 13.60 11/13/2010 DATA SUBMITTAL COMPLIANCE REPORT 8/31 /2010 Permit to Drill 2090710 Well Name/No. PRUDHOE BAY UNIT C-18B Operator BP EXPLORATION (ALASK/y INC API No. 50-029-20785-02-00 ~~~ MD 15089 TVD ~$~49' Completion Date 8/1 212 0 09 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION L/ Mud Log No Samples No Directional Survey Yes DATA INFORMATON Types Electric or Other Logs Run: MWD DIR / GR / RES, GR /CCL / CNL (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Ty Med/Frmt Number N Scale Media No Start Stop CH Received Comments D C Lis 18724 eutron 11312 14979 Case 10/2/2009 LIS Veri, GR, CNT og Neutron 5 Blu 11306 14964 Case 10/2/2009 MCNL, LEE, TNN, TNF, GR, CCL 9-Aug-2009 Rpt LIS Verification 12096 14712 Open 11/2/2009 PB1 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS D C Lis 18856flnduction/Resistivity 12096 14712 Open 11/2/2009 P61 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS Lo~ Induction/Resistivity 25 Col 12279 14707 Open 11/2/2009 P61 MD MPR, GR t"O Induction/Resistivity 5 Col 12279 14707 Open 11/2/2009 PB1 TVD MPR, GR Gamma Ray 25 Col 12279 14707 Open 11/2/2009 PB1 MD GR og Gamma Ray 5 Blu 12105 14720 Open 11/2/2009 P61 Depth Shift Monitor Plot Rpt LIS V 'tication 12095 15085 Open 11/3/2009 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS D C Lis 18876- nduction/Resistivity 12095 15085 Open 11/3/2009 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS Log Induction/Resistivity 25 Col 12279 15089 Open 11/5/2009 MD MPR, GR og Induction/Resistivity 5 Col 12279 15089 Open 11/5/2009 TVD MPR, GR Log Gamma Ray 25 Col 12279 15089 Open 11!5/2009 MD GR Log Gamma Ray 5 Col 12090 15090 Open 11/5/2009 Depth Shit Monitor Plot DATA SUBMITTAL COMPLIANCE REPORT 8/3112010 Permit to Drill 2090710 Well Name/No. PRUDHOE BAY UNIT C-18B Operator BP EXPLORATION (ALASYC~ INC C~~tS.- MD 15089 TVD ~ZA~J~ Completion Date 8/12/2009 Completion Status 1-OIL Current Status 1-OIL Well Cores/Samples Information: Name Sample Interval Set Start Stop Sent Received Number Comments API No. 50-029-20785-02-00 UIC N r ~ ~_J ADDITIONAL INFORMATION Well Cored? Y l~N~ Chips Received? .~F-f#~ Analysis ~Yl~- Received? Daily History Received? `~ N Formation Tops ~'-'/ N Comments: Compliance Reviewed By: ___ Date: - `- 1 L C~ i • ~/~® BAKER NV6NE5 Balser Atlas PRINT DISTRIBUTION LIST WMYANY BY EXYLUKA'1'IUN (ALASKA) IN(_ CUUN'fY WELL NAME C-18B STATE FIELD PRUDHOE BAY UNIT THIS DISTRIBUTION LIST AUTHORIZED BY. NUK'I'H SLUYE BURUUGH ALASKA DATE 11/2/2009 CATRINA GUIDRY SO #: 2711512 Copies of Copies Digital ~ Copies of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC ] Company DNR -DIVISION OF OIL & GA Person PETROTECHNICAL DATA CENTER Person CORAZON MANAOIS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 800 ANCHORAGE, AK 99508 ANCHORAGE, AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE, AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated Bv: BAKER ATLAS-PDC 17015 Aldine Westfield, Houston, Texas 77073 This Distribution List Completed Bv: -~ ~ . 1 _° ' ~. T_ - NQV ~~ ~ ?009 ~dg ~~ ~~$SKe ~8~ ~ ~aB$ GQI1;8 ~Lt;S'19i1a`~'++!' A~~~1~I~t< Page 1 of 1 INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: C-18BPB1 Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 color print - GR Directional Measured Depth Log (to follow) 1 color print - MPR/Directional TVD Log (to follow) 1 color print - MPR/Directional Measured Depth Log (to follow) LAC Job#: 2711512 Sent by: Catrina Guidry Date: 10l~0~01 Received by: Date: 4 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 ~~ ~ '~ 1~lQ~1ES INTEQ Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 °l'd~~ ~ ~ ~ ~5~ INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: C-18B Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 color print - GR Directional Measured Depth Log (to follow) 1 color print - MPR/Directional TVD Log (to follow) 1 color print - MPR/Directional Measured Depth Log (to follow) LAC Job#: 2711512 Sent by: Cat ' a u dry Date: 11/02/09 Received b Date: Lam" PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ ~~ ~ 7260 Homer Drive n / ~~~ Anchorage, Alaska 995 18 ~ ~ - 1 Direct: (907) 267-6612 ~( t NT EQ FAX: (907) 267-6623 ' ~ ~ • //~~ EI,AKER NV~sNES Baker Atlas PRINT DISTRIBUTION LIST CUMYAN Y BY EXYLUKA'11UN (ALASKA) INC WELL NAME C-18BPB1 CUUN'1 Y NUK'1'H SLUYl:: BUKUUGH STATE ALASKA FIELD PRUDHOE BAY UNIT DATE 10/30/2009 TH[S DISTRIBUTION LIST AUTHORIZED BY: CATRINA GUIDRY SO #: 2711512 Copies of Copies Digital Copies of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKAI INC I Company DNR -DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person CORAZON MANAOIS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 800 ANCHORAGE AK 99508 ANCHORAGE AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 I Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE. AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated By' BAKER ATLAS-PDC 17015 Aldine Westfield. Houston, Texas 77073 This Distribution List Completed By: Page l of I ~ ~~,o~ ~ Schlumberger N0. 5405 Alaska Data & Consulting Services 2s25 Geml»II Street, suite 40o Company: State of Alaska Anchorage, AK 99503-2838 Alaska Oil & Gas Cons Comm ATTN: Beth Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CO K-11 AY1M-00033 SBHP SURVEY - L4-30 AWLB•00031 PRODUCTION PROFILE ( 09/12/09 1 1 P2-31 AP3O-00045 LDL L ..~ 08/06/09 1 1 01-29 86JE-00009 PRODUCTION PROFILE - 07/11/09 1 1 J-22A B69K-00013 PRODUCTION PROFILE - 08/11/09 1 1 W-44 8148-00071 INJECTION PROFILE - 08/30/09 1 1 12-25 858F00010 INJECTION PROFILE 09/06/09 1 1 L5-33 AYKP-00051 SBHP SURVEY - 08/22/09 1 1 P2-48 B69K-00015 SBHP SURVEY 09/01/09 1 1 Z-28 B69K-00016 INJECTION PROFIL 09/01/09 1 1 O-02A AP3O-00054 IBP/LDL 09/19/09 1 1 N-10A AXED-00040 MEM PROD PR FILE - 07/24/09 1 1 W-24 AWJI.00044 MEM INJECTION PROFILE 08/25/09 1 1 V-03 62NJ-00021 ~ MEM PROD PROFILE (~ - 8/15/09 1 1 H-148 B2WY-00026 MEM PROD PROFILE ~ 09/03/09 1 1 P1-01 AY1M-00031 INJECTION PROFILE 08/27/09 1 1 P1-OS BSBF00009 PRODUCTION PROFIL 08/20/09 1 1 NK-10 82WY-00023 MEM INJECTION PROFILE - G D8/20/09 1 1 13-27A 82NJ-00019 MEMORY SCMT 08/22/09 1 1 18-028 B2WY-00021 MEMORY SCMT 08/13/09 / 1 NK-38A AYKP-00049 USIT ~ 08/19/09 1 1 06-09 SWLB-00028 USIT 08/17/09 1 1 13-03A 09AKA0/50 OH MWD/LWD EDIT 07/30/09 1 1 C-188 82NJ-00017 MCNL - 07/06/09 2 1 1-3510-25 B69K-00011 RST - 08/09/09 1 1 04.35A AX80.00025 MCNL 08/26/09 1 1 05/13/09 1 1 PLEASE ACKNOWLEDGE REC EIPT BY SIGNIN G AND RETURNING ONE COPY eAr-w m- ~, ~wp,v, croon Laesnal inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street. SuBe 400 Anchorage, AK 99503-2838 I0/01/09 ,'~~ J STATE OF ALASKA ~~ ~w' ALASKA AND GAS CONSERVATION COM~ION ` WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 1b., Well Class: zoAACZS.~os zoAACZS.~~o ~® Development ^ Exploratory ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One ^ Service ^ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 8/12/2009 / 209-071 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 7/30/2009 ~ 50-029-20785-02-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: ' ' 8/7/2009 '~ PBU C-18B '~ 554 FNL, 1521 FEL, SEC. 19, T11N, R14E, UM Top of Productive Horizon: 8. KB (ft above MSL): 66.83' / 15. Field /Pool(s): 1086' FSL, 3654' FWL, SEC. 08, T11 N, R14E, UM Ground (ft MSL): 32.93' , Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+ND) Oil Pool ~ 2854' FSL, 3519' FWL, SEC. 08, T11 N, R14E, UM 15051' 8817' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+ND) ' 16. Property Designation: Surface: x- 663839 y- 5960654 Zone- ASP4 15089 ADL 028305 & 028304 TPI: x- 668836 y- 5967686 Zone- ASP4 11. SSSV Depth (MD+TVD) ~~[• ~ 17. Land Use Permit: Total Depth: x- 668655 y- 5969451 Zone- ASP4 None 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore 20. Thickness of Permafrost (TVD): Su mi I r ni and rin ed inf rm i n er 2 AAC 25.050 N/A ft MSL 19 0' (Ap rox.) 21. Logs Obtained (List all logs here and submit electronic and printed informatio r 20 AA 25: 71): ~O n MWD DIR / GR / RES, GR / CCL / CNL /~' 9~ 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 30" In ulated C n u or urfa 110' urfa 110' 36" 8 cu ds Con rete 1-/" 2# 2' 17-1/2" 4 2 u A i II 9- / " 47# L- Surfa 12070' Surface 8263' 12-1/4" 162 cu ft Cla s' 18 A 7" 26# L-80 11550' 7 8 ' 4 7' -1/2" 4 cu Class'G' 3-1/2" x 3-3/16" 9.2# / 6.2# 11 1 7 1 4-1 2 4 I x 2-7/8" 16.16 # 23. Open to production or inject ion? ®Yes ^ No 24. TUBING RecoRD If Yes, list each i (MD+ND of Top & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH .SET MD PACKER SET MD 2" Gun Diameter, 6 spf 2" Gun Diameter 6 spf 5-1/2", 17#, L-80 11487' , MD ND MD ND x 4-1/2", 12.6#, L-80 11487' - 11638' 11506' 13255' - 13275' 8813' - 8813' 14210' - 14265' 8809' - 8811' ACID FRACTURE CEMENT SQUEEZE, ETC ' 25 13300' - 13350' 8813' - 8814' 14280' - 14390' 8810' - 8810' , ; . . 13370' - 13390' 8815' - 8816' 14435' - 14570' 8814' - 8812' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 13485' - 13525' 8815' - 8814' 14630' - 14740' 8815' - 8822' 13780' - 13870' 8808' - 8805' 14835' - 14910' 8819' - 8817' Freeze Protected w/ Diesel 14040' - 14060' 8808' - 8808' 14955' - 15015' 8818' - 8819' 14175' - 14200' 8807' - 8808' 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): August 29, 2009 Flowing Date Of Test: HOUrS Tested: PRODUCTION FOR OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: 8/22/2009 4 TEST PERIOD 832 827 .3333 128 994 Flow Tubing CaSing PreSS: CALCULATED OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): Press. 640 1,500 24-HOUR iZaTE• 4,994 4,964 2 Not Available 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Core s A uired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None Z~= . , t` Form 10-407 Revised 02/2007 CONTINUED ON REVER~~ Yyw..~ ~ ~~ (/-~ D' t~E f' ~r e~ Lllo~ I~- l4 28. GEOLOGIC MARKERS (LIST ALL FORMATfONS AND S ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No If yes, list intervals and formations tested, briefly summarizing test Permafrost Top results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Zone 3 12396' 8505' None Zone 2 12499' 8575' Zone 1 B 12839' 8778' Formation at Total Depth (Name): Zone 1 B 12839' 8778' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the forego' g is true and correct to the best of my knowledge. 0~ / / O~ Signed Terrie Hubble Title Drilling Technologist Date / PBU C-18B 209-071 Prepared ey Name/Number. Terrie Hubble, 564-4628 Well Number P i N . / A rov I N Drilling Engineer: Ron Phillips, 564-5913 INSTRUCTIONS GeNeRA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only BP EXPLORATION Page 1 of 15 Operations Summary Report Legal Well Name: C-18 Common Well Name: C-18 Spud Date: 4/25/1982 Event Name: REENTER+COMPLETE Start: 7/25/2009 End: 8/6/2009 Contractor Name: NORDIC CALISTA Rig Release: 8/12/2009 Rig Name: NORDIC 1 Rig Number: N1 Date From - To !Hours Task Code NPT Phase Description of Operations 7/25/2009 09:45 - 14:00 4.25 MOB P PRE Move rig from G pad to C pad. 5 mile rig move. 14:00 - 14:15 0.25 MOB P PRE SAFETY MEETING. Review procedure, hazards and 14:15 - 16:00 1.75 MOB P 16:00 - 16:15 0.25 MOB P 16:15 - 16:30 0.25 MOB P 16:30 - 21:30 I 5.001 BOPSUR P 21:30 - 00:00 2.50 BOPSU P 7/26/2009 00:00 - 03:30 3.50 BOPSU P 03:30 - 06:00 2.50 PULL P 06:00 - 08:00 2.00 PULL P 08:00 - 10:30 2.50 PULL P 10:30 - 10:45 I 0.251 PULL I P 10:45 - 13:15 2.50 PULL P 13:15 - 13:30 0.25 PULL P 13:30 - 17:00 3.50 PULL P 17:00 - 19:15 2.25 WHIP P 19:15 - 20:45 1.50 EVAL P 20:45 - 21:30 0.75 BOPSU P 21:30 - 22:45 1.25 EVAL P 22:45 - 00:00 1.25 EVAL P mitigation for scoping up the rig derrick. PRE Scope up derrick. Position rig mats in front of well to set rig on. PRE SAFETY MEETING. Review procedure, hazards and mitigation for backing rig over well. PRE Back rig over well and set down. ACCEPT RIG AT 1630 HRS, 07/25/09. PRE N/U BOPE Spot cuttings box Fill pits w/ 2% KCL double slick PRE PRESSURE TEST BOPE Witness waived by Bob Noble, AOGCC PRE Continue BOPE TEST Witness waived by Bob Noble, AOGCC DECOMP SAFETY MEETING, re: MU new CTC & PU fishing tools MU Baker CTC w/ 2-3/8" REG P, Pull test & pressure test PU Fishing tools--DBPV, 2 jts 2-3/8" PH6, Bowen Oil Jar, Hi-Lo Hyd Discon, Rupture disk sub, and 4" GS Spear. DECOMP RIH to 11,500'. DECOMP Swap well to double slick 2% KCL. 3.0 bpm, 2900 psi, circ 240 bbls diesel/crude out of well to Tiger tank. Sent to GC-2 for beneficial re-use. DECOMP Up wt = 41 K at 11500', no pump. RIH and tag fish at 11,915' Stack 5K down on fish and pick up with 46K. We have fish. DECOMP POH with fish while circ across the top holding 200 psi WHP. DECOMP SAFETY MEETING. Review procedure, hazards and mitigation for laying out fishing tools and used liner. DECOMP Lay out 2-7/8", FL4S used liner. First few jts had bad threads, thin wall and holes in pipe. Laid out total of 25 jts and cut jt, clean chemical cut on liner. Tool service checked liner for NORM scale, no NORM scale measured. WEXIT Prep to swap coils. Circ 50 bbl fresh water, 10 bbl inhibitor and 5 bbl MEOH thru coil. Rig up SWS N2 unit. WEXIT SAFETY MEETING, re: Pumping N2 PT N2 lines Slowdown coil w/ N2. Bleed off pressure. RD SWS N2 unit. SAFETY MEETING, re: Cut off CTC, pull CT back to reel, & secure Cut off CTC WEXIT Body test BOP stack and PT kill line check valve after cleaning out check valve. WEXIT Install grapple Pull coil back to reel and secure. WEXIT SAFETY MEETING, re: RU slickline RU slickline Printed: 8/17/2009 10:18:53 AM t ~ BP EXPLORATION Page 2 of 15 Operations Summary Report Legal Well Name: C-18 Common Well Name: C-18 Spud Date: 4/25/1982 Event Name: REENTER+COMPLETE Start: 7/25/2009 End: 8/6/2009 Contractor Name: NORDIC CALISTA Rig Release: 8/12/2009 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task i Code' NPT '~ Phase Description of Operations - __- 7/26/2009 22:45 - 00:00 1.25 EVAL P WEXIT SIM OPS: SAFETY MEETING, re: reel swap SIM OPS: Lower cementing reel & PU a-line reel. 7/27/2009 00:00 - 00:45 0.75 EVAL P WEXIT Finish RU slickline 00:45 - 03:15 2.50 EVAL P WEXIT PU Whipstock dummy drift (20' long, 3.68" OD) w/ weight bars, hydraulic jar, spangs, & GR spear. Run WS dummy drift run to 12349' SLMD. POH. L/D WS drift 03:15 - 06:00 2.75 EVAL P WEXIT PU PDS Memory Caliper Logging Tool, weight bars, hydraulic jar, &spangs. RIH to 12349' SLMD Run Caliper Log from 12349' to 11500' SLMD 06:00 - 07:00 1.00 EVAL P WEXIT POH with memory logging tool. 07:00 - 07:15 0.25 EVAL P WEXIT SAFETY MEETING. Review procedure, hazards and mitigation for laying out logging tools and rig down slickline unit. 07:15 - 09:00 1.75 EVAL P WEXIT Lay out logging tools and download caliper data to determine if log was OK. Good caliper data. 7", 26# liner is OK for setting the Baker Gen 1 whipstock. Average ID in the set area is 6.30". 09:00 - 10:00 1.00 WHIP P WEXIT SAFETY STAND DOWN. Held a safety discussion with all the rig crew and talked about preventing dropped objects and reducing risk by recognizing potential hazards. 10:00 - 13:30 3.50 WHIP P WEXIT Install internal grapple, pull test and pull E-Coil to injecter head. Fill coil with double slick KCL water. Reverse circ via kill line and pump slack into coil. Pump max rate of 4.5 bpm for 20 sec after E-Line started moving. Cut off 17' coil. 13:30 - 16:00 2.50 WHIP P WEXIT M/U SWS CTC. M/U BHI UOC. Test E-Line. Press test CTC and UOC. 16:00 - 17:50 1.83 WHIP P WEXIT M/U Baker Gen 1 Whi stock, setting tool. Install 2 PIP tags in WS. Length from top of tray to PIP tags = 10.1'. M/U CoilTrak. BHA OAL = 80.64' Test CoilTrak tools at surface. Open EDC. Circ. 0.9 bpm, 170 psi. 17:50 - 18:30 0.67 WHIP P WEXIT RIH with CoilTrak Whipstock setting BHA #2. Circ. 0.8 bpm, 190 psi 18:30 - 19:30 1.00 WHIP P WEXIT SAFETY STAND DOWN. Held safety discussion with all the rig crew, Nordic safety advisor, & BP HSE advisor about the dropped object last night. Thoroughly discussed the job of lowering the reel. Further discussed recognizing potential hazards, use of barricading, and thorough documentation of safety meetings & hazards of the job. 19:30 - 20:00 0.50 WHIP P WEXIT Continue RIH w/ CoilTrak Whipstock setting BHA. Circ 0.88 bpm, 260 psi 20:00 - 20:50 0.83 WHIP P WEXIT Log tie-in, -38' correction which is consistent with the depth discrepancy of the 4-1/2" tubing tail between the Caliper log and the wellbore schematic. 20:50 - 21:25 0.58 WHIP P WEXIT RIH to 12297'. Close EDC. Pressure up 3200 psi to set WS. Set down 1k# to ensure WS has set. Top of Whi stock set at 12280', HS orientation. 21:25 - 00:00 2.58 WHIP P WEXIT POH Printed: 8/17/2009 10:18:53 AM BP EXPLORATION Page 3 of 15 Operations Summary Report Legal Well Name: C-18 Common Well Name: C-18 Spud Date: 4/25/1982 Event Name: REENTER+COMPLETE Start: 7/25/2009 End: 8/6/2009 Contractor Name: NORDIC CALISTA Rig Release: 8/12/2009 Rig Name: NORDIC 1 Rig Number: N1 Date I From - To Hours Task Code NPT Phase Description of Operations WHIP P WEXIT SAFETY MEETING, re: UD Whipstock BHA 7/28/2009 (00:105 010:15 10.00 _- _ _ __-- -_ _ _ _ _ WHIP P WEXIT UD whipstock setting tools & CoilTrak. 01:15 - 02:05 0.83 WHIP C WEXIT 02:05 - 08:15 6.17 WHIP X SFAL WEXIT 08:15-11:00 2.75WHIP IC 11:00 - 11:15 0.25 WHIP C 11:15 - 13:20 2.08 WHIP C 13:20 - 14:00 0.67 WHIP C 14:00 - 17:30 3.50 WHIP C 17:30 - 18:15 0.75 WHIP C 18:15 - 20:40 2.42 STWHIP X 20:40 - 21:40 1.00 STWHIP C 21:40 - 21:50 0.17 STWHIP C 21:50 - 22:05 0.25 STWHIP P 22:05 - 22:50 0.75 STWHIP P 22:50 - 00:00 1.17 STWHIP P 7/29/2009 00:00 - 02:40 2.67 STWHIP P WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT Remove checks from UOC PU Cement Nozzle BHA RIH to 3000'. Chain on injector is misaligned and breaking cotter pins. POH to surface to fix chain alignment. Work on chain alignment at surface. Replaced 45 cotter pins and 4 tie rods. This coil is heavy wall 0.204" RIH with cementing BHA. Circ 0.5 bpm, 110 psi. Tag whipstock pinch point at 12,323', uncorrected depth. The last tie-in was -38', so the whipstock is still set in place. SAFETY MEETING. Review procedure, hazards and mitigation for pumping 5 bbl cement job. Circ 1.9 bpm, 900 psi, full returns. Press test cement line. Cement at wt at 12:26 hrs. Coil capacity = 57.8 bbl. Stage 5 bbl G Cement. 1.3 bpm, 600 psi, 15.6 PPG. Stage 10 bbl water displ, 1.3 bpm, 800 psi. Stage 40 bbl Biozan displ, 1.3 bpm, 500 psi, 50 bbl displ. Stage KCL water displ. 1.2 bpm, 350 psi 53 bbl displ,,cement at nozzle at 12,323'. Press increasing due to loss of cement head. 55 bbl displ, 2 bbl out, lair in 1 for 1, 1.2 bpm, 530 psi, pull coil at 30 fpm. 58 bbl displ, 5 bbl out, 1.3 bpm, 650 psi, TOC at 12240'. Stop pump, pull to safety at 12000'. Circ at min rate at safety. Let cement settle for 30 min. Circ 0.25 bpm, 230 psi at safety. RIH to TOC at 12240' at 1350 hrs. Dress off cement to 20' above pinch point at 12,303'. 3.6 bpm, 2700 psi. POH while chasing cement to surface. 3.4 bpm, 3200 psi. Dump contaminated cement. UO cementing BHA. Change out Flange to Bowen XO on top of annular. Change out a-line pressure bulkhead inside reel. Pick up injector, install swizzle stick for jetting stack. Jet stack then PT riser and pressure bulkhead, good. Test a-line cable, good. Install check valves in cable head. Install tree cap and open swab and master valves. SAFETY MEETING. PJSM to discuss hazards and mitigations of picking up BHA. Pick up BHA #4 - 3.80" Window Mill, 3.80" String Mill, 2-7/8" X-treme motor, 2 jts 2-3/8" PH6, 3.0" CoilTrak with DPS. BHA OAL = 118.87 ft. RIH. Stop at 697 ft and replace counter wheel, then continue RIH. Continue RIH with window milling BHA #4. Panted: sinrzoos tuaa:5sann BP EXPLORATION Page 4 of 15 Operations Summary Report Legal Well Name: C-18 Common Well Name: C-18 Spud Date: 4/25/1982 Event Name: REENTER+COMPLETE Start: 7/25/2009 End: 8/6/2009 Contractor Name: NORDIC CALISTA Rig Release: 8/12/2009 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task ;Code NPT ..Phase Description of Operations --_- _ _- 7/29/2009 00:00 - 02:40 2.67 STWHIP P WEXIT Log from 12,140 ft, correct -24 ft. RIH, wt check is 50K at 12240 ft. 02:40 - 03:15 0.58 STWHIP N SFAL WEXIT Counter wheel isn't turning in OOH direction, stop and fix. Tie-in depth again from 12145 ft, correct +3 ft. 03:15 - 03:30 0.25 STWHIP P WEXIT RIH 30 ft/min tag at 12,278 ft at minimum rate. 03:30 - 06:45 06:45 - 08:00 3.25 1.25 STWHIP STWHIP P P WEXIT WEXIT Bring pump up to 2.65 bpm, RIH take wt at 12276 ft, drill to 12278 ft at 90 fUhr with low motor work. Pull up and swap well to milling fluid. Cement compressive strength at 1731 psi at 04:00 and still increasing. Milling firm cement down to pinch point. 2.6 bpm, 1 K WOB, 30 fph. Milled firm cement from 12278-12286.5' WEXIT Milled 3.80" window thru 7", 26#, L-80 Liner. 2.6 bpm, 2600-2900 psi, 1-3K WOB, 1 FPH. Milled to 12288'. 10:30 - 13:30 3.00 STWHIP P WEXIT Milling, 2.6 bpm, 2600-2900 psi, 2-3K WOB, 0.5 FPH. 2 Milled to 12289.5'. ~~ \~ 13:30 - 16:00 2.50 STWHIP P WEXIT Milling, 2.6 bpm, 2600-2900 psi, 2-3K WOB, 0.5 FPH. ~„~/~ Milled to 12291.2'. ~~ _/' , ` 16:00 - 19:20 3.33 STWHIP P WEXIT Milling, 2.6 bpm, 2450-2800 psi, 2-3K WOB, 0.5 FPH. ~ Milled to 12293.3 ft ~la 19:20 - 21:50 2.50 STWHIP P WEXIT Take 2 stalls at 12,293.3 ft. 19:40 12293.21 ft 0.54 Klbs DWOB 21:00 12293.99 ft 0.57 Klbs 21:50 - 22:20 0.50 STWHIP P WEXIT Drilling formation at 7 fUhr with 1 Klbs DWOB. Likely casing exit is 12,293 ft. Start Geo-Vis down CT at 12,298 ft. Drill rathole to 12,303 ft. 22:20 - 00:00 1.67 STWHIP P WEXIT Backream from TD to above whipstock, 3 times. Complete fluid swap to Geo-Vis. 7/30/2009 00:00 - 01:20 1.33 STWHIP P WEXIT Continue 3 reaming passes through window and to TD of rathole. 01:20 - 03:45 2.42 STWHIP P WEXIT Dry pass through window is smooth, firm tag at TD. POOH. 03:45 - 04:00 0.25 STWHIP P WEXIT SAFETY MEETING. PJSM for pulling milling BHA and M/U first drilling BHA. 04:00 - 05:40 1.67 DRILL P PROD1 Tag stripper and UD window mill and string reamer. Mill is 3.73" no-go, Reamer is 3.79" no-go. M/U BHA #5 -Used T-Rex bit, 1.5 deg Motor, 3.0" CoilTrak. BHA OAL = 66.17 ft. 05:40 - 07:45 2.08 DRILL P PROD1 RIH BHA #5 with re-run HYC T-Rex BC Bit #1, 1.5 deg Xtreme motor and CoilTrak. OAL = 66.17' Circ 0.3 bpm, 950 psi. 07:45 - 09:15 1.50 DRILL P PROD1 Log GR tie-in with mother wellbore from 12170 to 12303'. -27' correction. 09:15 - 10:15 1.00 DRILL P PROD1 Drill Zone 4 build section. 2.6 bpm, 2600-3100 psi, 10R TF, 1 K WOB, 100 FPH, Drilled to 12350' 10:15 - 12:30 2.25 DRILL P PROD1 Drill Z3 build section. 2.6 bpm, 2600-3100 psi, 90R TF, 1 K WOB, 40 FPH, Drilled to 12450'. 12:30 - 13:20 0.83 DRILL P PROD1 Drill Z3 build section. 2.6 bpm, 2600-3100 psi, 80R TF, 1 K WOB, 50 FPH, C Printed: 8/17/2009 10:18:53 AM ~ ~ BP EXPLORATION Page 5 of 15 Operations Summary Report Legal Well Name: C-18 Common Well Name: C-18 Spud Date: 4/25/1982 Event Name: REENTER+COMPLETE Start: 7/25/2009 End: 8/6/2009 Contractor Name: NORDIC CALISTA Rig Release: 8h 2/2009 Rig Name: NORDIC 1 Rig Number: N1 Date 'I From - To Hours Task Code'. NPT Phase Description of Operations 7/30/2009 12:30 - 13:20 0.83 DRILL P PROD1 Drilled to 12500'. 13:20 - 13:30 0.17 DRILL P PROD1 Wiper trip to window. Clean hole. RIH clean to bottom. 13:30 - 14:30 1.00 DRILL P PROD1 Drill Z2 build section. 2.6 bpm, 2600-3100 psi, 60R TF, 1-2K WOB, 80 FPH, Drilled to 12550'. 14:30 - 16:45 2.25 DRILL P PROD1 Drill Z2 build section. 2.6 bpm, 2600-3100 psi, 60L TF, 1-2K WOB, 80 FPH, Drilled to 12650'. 16:45 - 17:10 0.42 DRILL P PROD1 Wiper trip to window. Clean hole. RIH clean to bottom. 17:10 - 20:00 2.83 DRILL P PROD1 Drill Z2 build section. 2.6 bpm, 2600-3100 psi, 60L TF, 1-2K WOB, 60 FPH Drill to 12,800 ft. 20:00 - 21:30 1.50 DRILL P PROD1 Wiper trip back to 11,600 ft to clean 7" csg. Log GR tie-in to RA marker in whipstock, correct +3.5 ft. Clean pass up and down. 21:30 - 00:00 2.50 DRILL P PROD1 Drill from 12800 ft. Hold 30L TF to I nd at 7 T D 2.70 / 2.69 bpm ~ 2700-3000 psi. ROP is 50-60 ft/hr with 1.7 Klbs DWOB. PVT = 313 bbls 8.70 / 8.80 ppg. Drill to 12935 ft. 7/31/2009 00:00 - 00:30 0.50 DRILL P PROD1 Continue drilling from 12935 ft to 12950 ft. 00:30 - 01:00 0.50 DRILL P PROD1 Wiper trip from 12950 ft to window. Clean pass up and down. 01:00 - 03:15 2.25 DRILL P PROD1 Drill from 12,950 ft. Continue building angle for 8755 ft TVD landing. 2.63 / 2.61 bpm C«~ 2800-3100 psi. ROP is 50 ft/hr with 3.8 Klbs DWOB. Drill to 13,041 ft, landed at 90 deg at target TVD. 03:15 - 06:00 2.75 DRILL P PROD1 P H or bit and AKO change, and to pick up Resistivity tool. 06:00 - 06:15 0.25 DRILL P PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for changing BHA. 06:15 - 06:45 0.50 DRILL P PROD1 La out CoilTrak build BHA #5. Bit was fully worn and rung out. Good bit run, Z4, Z3 and Z2. 738'. Bit graded at 06:45 - 07:15 0.50 BOPSU P PROD1 Function test BOPE early in case next BHA stays in hole for entire lateral section. Good test. 07:15 - 08:00 0.75 DRILL P PROD1 M/U CoilTrak Lateral RES BHA #6 with Rerun HYC SRR BC Bit #2, 1.2 ceg Xtreme motor, RES and CoilTRak. OAL = 79.02' 08:00 - 10:15 2.25 DRILL P PROD1 RIH-with lateral /RES BHA. circ at 0.3 bpm, 1000 psi. 10:15 - 10:45 0.50 DRILL P PROD1 Log GR tie-in at RA tag. -31' CTD. 10:45 - 11:15 0.50 DRILL P PROD1 RIH to bottom. Circ 2.5 bpm, 2650 psi, Tag bottom at 13039'. 11:15 - 12:45 1.50 DRILL P PRODi Log MAD pass from bottom up to window at 600 FPH. 49K up wt, 2.50 bpm, 2620 psi. 12:45 - 13:15 0.50 DRILL P PROD1 RIH clean to bottom. 13:15 - 17:00 3.75 DRILL P PROD1 Drill Zi B lateral. 2.6 bpm, 2600-3200 psi, 90R TF, 120-30 fph, 2-5K wob, stacking wt. Drilled to 13195'. 17:00 - 18:00 1.00 DRILL P PRODi Wiper trip to window. Clean hole. RIH clean to bottom. 18:00 - 22:30 4.50 DRILL P PROD1 Drill from 13195 ft. Stacking wt, slow drilling. 5-6K DWOB, 20-30 ft/hr. PVT = 301 bbls. Reduce inc to 89 de tot and et out of shale zone. At 13,335 ft still in shale, pick up and drill high-side toolface to Pnntea: turnzoos toae:5srnn s +~ BP EXPLORATION Page 6 of 15 Operations Summary Report Legal Well Name: C-18 Common Well Name: C-18 Spud Date: 4/25/1982 Event Name: REENTER+COMPLETE Start: 7/25/2009 End: 8/6/2009 Contractor Name: NORDIC CALISTA Rig Release: 8/12/2009 Rig Name: NORDIC 1 Rig Number: N1 Date From - To ~ Hours ~ Task Code NPT Phase Description of Operations 7/31/2009 18:00 - 22:30 4.50 DRILL P PROD1 try and get out of it. Drill to 13350 ft. 22:30 - 00:00 1.50 DRILL P PROD1 Wiper trip back to tubing tail to clean 7" csg. Overpulls and motor work at 13160, 13140 ft. 8/1/2009 00:00 - 00:40 0.67 DRILL P PROD1 Continue wiper trip from tubing tail back to bottom. Clean pass through the window. Stacking wt at 13160-13230 ft 00:40 - 05:15 4.58 DRILL P PROD1 Drill from 13350. Hold OL TF to build angle to 94 deg and hopefully find better sand. 2.62 / 2.62 bpm ~ 2800-3000 psi. ROP 20-40 ft/hr with 5-6 Klbs DWOB. Drilling break 150 ft/hr from 13450-13479 ft, then stacking wt a ain. Stall 4 times at 13476 ft, then continue drilling. Drill to 13,500 ft. 05:15 - 06:00 0.75 DRILL P PROD1 Wiper trip from 13500 ft to tubing tail. 06:00 - 07:20 1.33 DRILL P PROD1 Safety Stand Down for Lifting Ops & Dropped Objects. Pull into casing and circulate while rig crew participates in conference call and debrief session. 07:20 - 09:30 2.17 DRILL P PROD1 Log tie-in from 12,300 ft. Correct +10 ft. Continue RIH to bottom. Stacking wt at 12400 ft Ream down thru shales to 12500', backream up to window. RIH to bottom. 09:30 - 11:15 1.75 DRILL P PROD1 Drill Zone 1 B lateral 2.5 bpm, 2400-2900 psi, 80L TF, 92 deg incl, 30-80 fph. Drilled to 13585'. 11:15 - 13:30 2.25 DRILL P PROD1 Drill Zone 1 B lateral, 2.5 bpm, 2400-2900 psi, 90L TF, 90 deg incl, 30-80 fph. Drilled to 13655'. 13:30 - 15:30 2.00 DRILL P PROD1 Wiper trip to window, overpull at 13250' in shale. Wiper up to tailpipe, RIH and cleanout 7" liner. RIH clean to bottom. 15:30 - 16;45 1.25 DRILL P PROD1 Drill Zone 1 B lateral, 2.5 bpm, 2400-2900 psi, 90L TF, 90 deg incl, 30-80 fph. Drilled to 13700' 16:45 - 18:00 1.25 DRILL P PRODi Drill Zone 1 B lateral, 2.5 bpm, 2400-2900 psi, 90L TF, 90 deg incl, 30 fph. Drilled 13721'. 18:00 - 20:00 2.00 DRILL P PROD1 Continue drilling Zone 1 B lateral, 2.7 bpm, 40-60 ft/hr ROP with 2-6 Klbs DWOB. Drill to 13800 ft. 20:00 - 22:15 2.25 DRILL P PROD1 Wiper trip from 13800 ft to tubing tail. Slight overpulls through shale zone. - Some wt stacking around 13,200 ft going back down. 22:15 - 00:00 1.75 DRILL P PRODi Drill from 13,800 ft. Hold 82-84 deg inc to drop into 1A target. 2.67 / 2.67 bpm ~ 3000-3300 psi. ECD = 9.60 ppg. ROP is 60-90 fUhr with 3.3 Klbs DWOB. Drill to 13885 ft. 8/2/2009 00:00 - 01:10 1.17 DRILL P PROD1 Drill to 13919 ft. Stacking wt, try to pick up and are stuck differential) . Cycle pipe several times. 01:10 - 03:15 2.08 DRILL N STUC PROD1 Cycle pipe and pump several times, no luck. Park CT at neutral wt and pump bottoms up, cycle pipe periodically. Printed: 8/17/2009 10:18:53 AM BP EXPLORATION Page 7 of 15 Operations Summary Report Legal Well Name: C-18 Common Well Name: C-18 Spud Date: 4/25/1982 Event Name: REENTER+COMPLETE Start: 7/25/2009 End: 8/6/2009 Contractor Name: NORDIC CALISTA Rig Release: 8/12/2009 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code; NPT Phase Description of Operations 8/2/2009 01:10 - 03:15 2.08 DRILL N STUC PROD1 2.15 / 2.16 bpm ~ 2620 psi. 03:15 - 04:15 1.00 DRILL N STUC PROD1 Shut down pump for 15 min, let hole relax. Cycle pipe 5 times -3K to 95K, no luck. Pump 20 bbl ill mineral oil. After 5 bbls out shut down and let it soak, work i e and free it at 90K. 04:15 - 06:00 1.75 DRILL P PROD1 Wiper trip to tubing tail and Circ remaining oil out of hole. ECD > 9.3 while oil is bought to surface. 06:00 - 06:20 0.33 DRILL P PROD1 Log GR tie-in at RA tag, add 17 ft. 06:20 - 07:00 0.67 DRILL P PROD1 RIH clean to bottom. Circ 2.4 bpm, 2900 psi. 07:00 - 08:40 1.67 DRILL P PROD1 Drill Zone 1A, 2.5 bpm, 3100-3800 psi, 60L TF, 87 deg incl, 40-60 fph, 4K wob, Stacking wt, overpulls Drilled to 13955'. 08:40 - 09:40 1.00 DRILL P PROD1 Short wiper trip to clean up hole while swapping to new GeoVis. RIH to bottom when new GeoVis at bit. 09:40 - 11:45 2.08 DRILL P PROD1 GEO decided to dro thru Z1A to 8876' TVD. Drop incl to 83 de . Drill Zone 1A, 2.6 bpm, 2450-3200 psi, 170E TF, 83 deg incl, 30-40 fph, 4K wob, Drilled to 14,000'. . 11:45 - 12:45 1.00 DRILL P PROD1 Drill Z1A lateral, 2.6 bpm, 2450-3100 psi, 90L TF, 82 deg incl, 5K Wob, 40 fph, Stacking wt, slow ROP. Bit is worn out. Drilled to 14008'. 12:45 - 16:45 4.00 DRILL P PROD1 POH for bit. circ 2. bpm, 2900 psi. 16:45 - 17:00 0.25 DRILL P PRODi SAFETY MEETING. Review procedure, hazards and mitigation for changing out drilling BHA. 17:00 - 18:00 1.00 DRILL P PROD1 UD BHA #6. Bit is OK, will re-run. Bearing race on motor was pulled awav from its housing, resulting in bit box hanging down about 2". Internal no-go prevented the bit box from being left in hole. 18:00 - 18:15 0.25 DRILL P PROD1 SAFETY MEETING. Tour change and PJSM for picking up BHA #7. 18:15 - 19:00 0.75 DRILL P PROD1 Pick u BHA #7 - Re-run SRR, 1.4 deg AKO Xtreme, Agitator, Float Sub, Res, 3.0" CoilTrak. BHA OAL = 88.06 ft. 19:00 - 22:15 3.25 P PROD1 Surface test agitator, good. RIH. Log GR tie-in from 12,320 ft, correct -32 ft. 22:15 - 22:45 0.50 DRILL N DFAL PROD1 While RIH at 12850 ft increase in CT pressure and BHA internal pressure, not motor work. BHA is partially plugged off below'the DPS. Cycle pump and Baker choke, try and clear it. Pump 0.44 bpm ~ 4000 psi. Pull into casing to troubleshoot. Cycle pump and choke several times, still pressuring up. Open EDC and POOH. 22:45 - 00:00 1.25 DRILL N DFAL PROD1 POOH pump through EDC 2.37 bpm ~ 1800 psi. 8/3/2009 00:00 - 00:20 0.33 DRILL N DFAL PROD1 Continue POOH. 00:20 - 00:35 0.25 DRILL N DFAL PRODi SAFETY MEETING. PJSM for UD BHA. 00:35 - 02:20 1.75 DRILL N DFAL PRODi UD BHA #7. Break off bit, all ports are clear. Break off Printed: 8/17/2009 10:18:53 AM • i BP EXPLORATION Page 8 of 15 Operations Summary Report Legal Well Name: C-18 Common Well Name: C-18 Spud Date: 4/25/1982 Event Name: REENTER+COMPLETE Start: 7/25/2009 End: 8/6/2009 Contractor Name: NORDIC CALISTA Rig Release: 8/12/2009 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours ! Task Code NPT Phase ~ Description of Operations 8/3/2009 00:35 - 02:20 1.75 DRILL N DFAL PROD1 agitator and motor, no indication of why it was plugging at high 02:20 - 07:00 4.671 DRILL N DFAL ~ PROD1 07:00 - 09:45 2.751 DRILL P 09:45 - 11:00 1.25 i DRILL P 11:00 - 13:15 2.25 DRILL P 13:15 - 16:15 3.00 DRILL P 16:15 - 16:50 I 0.581 DRILL P 16:50 - 20:30 3.671 DRILL P 20:30 - 23:00 2.501 DRILL i P 23:00 - 00:00 1.00 DRILL P 8/4/2009 00:00 - 01:35 1.58 DRILL P 01:35 - 03:30 1.92 DRILL P 03:30 - 06:40 I 3.171 DRILL I P 06:40 - 08:50 I 2.171 DRILL I P PROD1 PROD1 PROD1 PROD1 PRODi PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 pump rate. Able to blow air and water through entire BHA when it was at surface. P/U BHA #8 with Re-run SRR bit, new motor and agitator, rebuilt float sub, 3" CoilTrak with Res. Surface test agitator, good. RIH. Problem with SLB depth encoder, stop and replace it. Continue RIH. Log tie-in, correct -30 ft. Continue RIH to bottom. GEO target is 8783' TVD. RIH clean to bottom. Drill Zone 1A lateral, 2.6 bpm, 3200-3800 psi, 60L TF, 84-89 deg incl, 4-5K wob, 30-40 fph, Good steady drilling with agitator. Still drilling shales in Z1A. Drilled to 14110'. Drill Z1 A lateral, 2.6 bpm, 3200-3800 psi, 80L TF, 89 deg incl, 4-5K wob, 30-40 fph, Drilled shale to 14150'. Wiper trip to window. Overpull /motor work in shale at 13850'. Wiper to window. RIH Drill Zi A lateral, 2.6 bpm, 3200-3800 psi, 50L TF, 94 deg incl, 4-5K wob, 30 fph, Drilled to 14250'. Drill Z1A lateral, 2.6 bpm, 3200-4000 psi, 70L TF, 98 deg incl, 4-5K wob, 60 fph, Fast drilling in sand at 10274'. 30K overpull off bottom. Drilled to 14285'. W iper trip to window. Shales were not bad, some motor work/overpull. Wiper trip up to tailpipe to cleanout 7" liner. 2.8 bpm thru bit. 40 fpm up, 70 fpm down to window. Log tie-in, correct +9.5 ft. Continue RIH to bottom. Drill from 14285 ft. Keep 170E TF for now to reduce inc. 2.66 / 2.69 bpm ~ 3600-3900 psi. ECD = 9.63 bpm. ROP is 90-100 ft/hr with 1-2 Klbs DWOB, PVT = 297 bbls. Short wiper trip at 14,400 ft, clean pass up and down. Drill to 14450 ft. Wiper trip from 14450 ft to window. 80-90K pulls to get through shales from 14000-14100 ft. Continue wiper trip. Stacking wt through shale zone 14000-14200 ft. Drill from 14450 ft. Aim for 91 deg inc. 2.74 / 2.76 bpm ~ 3800-4300 psi. ECD = 9.69 ppg. ROP is 70-80 ft/hr with 5 Klbs DWOB. PVT = 284 bbls. Drill to 14600 ft. Wiper trip from 14,600 ft to tubing tail. 20K overpulls through shale interval from 14000-14200 ft. RIH to bottom, some motor work in shales at 14000-14250' but not bad. Drill up out of Z1A thru 13N shale. 8-10' thick, 2.6 bpm, Printetl: 8/77/2009 10:18:53 AM i 1 BP EXPLORATION Page 9 of 15 Operations Summary Report Legal Well Name: C-18 Common Well Name: C-18 Spud Date: 4/25/1982 Event Name: REENTER+COMPLETE Start: 7/25/2009 End: 8/6/2009 Contractor Name: NORDIC CALISTA Rig Release: 8/12/2009 Rig Name: NORDIC 1 Rig Number: N1 ~ ~ Description of Operations Date ;From - To Hours ~ Task Code NPT Phase 8/4/2009 06:40 - 08:50 2.17 DRILL P PROD1 3300-3900 psi, 20L TF, Drilling break at 14630', ROP increased to 100 fph, Swapped to new GeoVis at 14650'. Drilled to 14,707'. 08:50 - 13:00 4.17 DRILL C PROD1 POH for Open hole sidetrack off of AL Billet at 13.070'. __ _ Pulled 70K at 14075' and 14000'. POH. Cleanout 7" liner at 2.8 bpm, POH. 13:00 - 14:00 1.00 DRILL C PROD1 LD Drilling BHA. 14:00 - 15:30 1.50 STKOH C PRODi PU aluminum billet and sidetrack BHA. 15:30 - 18:10 2.67 STKOH C PROD1 RIH. 18:10 - 18:35 0.42 STKOH X PROD1 Missing snap ring found on injector bearing pin. Perform lockout / tagout of injector, PJSM, then repair snap ring. 18:35 - 20:20 1.75 STKOH C PRODi Continue RIH, slow down for jewelry restrictions. Pass through window, pump min rate through open EDC. Log GR tie-in from 12,320 ft, correct -31 ft. Continue RIH. Wt check at 12900 ft is 48 Klbs. 20:20 - 20:30 0.17 STKOH C PROD1 RIH to setting depth of 13081.2 ft, leaves billet top at 13070 ft. Pick up to get wt back and close EDC. ~ h Pressure up CT to set billet. Shears off at 2950 psi with 1.8 Klbs DWOB. Pick up is 50K with no pump. 20:30 - 22:30 2.00 STKOH C PROD1 POOH pump 2.0 bpm. Leave billet at 13,070 ft with tray set at OL. 22:30 - 22:45 0.25 STKOH C PROD1 AFETY MEETING. PJSM for C/O BHA. 22:45 - 00:00 1.25 STKOH C PROD1 Tag stripper and L/D CoilTrak and setting tool. Tool has functioned normally. P/U BHA #10 -Rebuilt HCC bit, 1.5 deg AKO Xtreme, 3" CoilTrak with Res. 8/5/2009 00:00 - 03:00 3.00 STKOH C PROD1 RIH BHA #10. Log GR tie-in from 12340 ft, correct -31 ft. RIH and dry tag billet lightly at 13071.1 ft. 03:00 - 03:50 0.83 STKOH C PROD1 Pick up off billet and pump 2.5 bpm, zero DWOB. 2270 psi FS C~3 2.5 bpm, 0.3 Klbs DWOB, stall at 13070.4 ft. Ease down from 13,070.3 ft at 2-5 ft/hr, 0-50 psi motor work, 0-0.5 Klbs DWOB. Motor doesn't appear to be sliding very smoothly. From 13,072.5 ft go to 20 Whr. From 13,075 ft go to 30 fUhr. Stacking wt at surface, doesn't appear to be moving downhole. Shut off pump and pick up. 03:50 - 05:00 1.17 STKOH C PROD1 Shut off pump and pick up, dry tag again at 13,071.3 ft. Go to 2.5 bpm and ease down again 2-4 ft/hr, get 100-200 psi motor work with 1 - 1.6 Klbs DWOB. Stall at 13071.7 ft. Drill from 13070.7 ft with DWOB 0.5-1 Klbs, 100-200 psi motor work. After 13073 ft DWOB falls off, drill at 20-30 fUhr, 0.4-0.6 Klbs DWOB, 100-200 psi motor work. 05:00 - 06:40 1.67 DRILL C PROD1 After 13077 ft drill at 40 Whr. After 13082 ft 90 ft/hr. Hold 20L TF to build angle to 97 deg. 2.53 / 2.54 bpm ~ 2300-2500 psi. 06:40 - 07:45 1.08 DRILL C PROD1 Wiper to window Printed: 8/17/2009 10:18:53 AM ~ ~ BP EXPLORATION Page 10 of 15 Operations Summary Report Legal Well Name: C-18 Common Well Name: C-18 Spud Date: 4/25/1982 'Event Name: REENTER+COMPLETE Start: 7/25/2009 End: 8/6/2009 Contractor Name: NORDIC CALISTA Rig Release: 8/12/2009 Rig Name: NORDIC 1 Rig Number: N1 Date I From - To Hours Task Code NPT Phase ~ Description of Operations 8/5/2009 07:45 - 09:15 1.50 DRILL C PROD1 09:15 - 10:30 1.25 DRILL C PROD1 10:30 - 12:40 2.17 DRILL C PROD1 12:40 - 14:30 1.83 DRILL C PROD1 14:30 - 17:00 2.50 DRILL C PROD1 17:00 - 18:40 1.67 DRILL C PROD1 18:40 - 21:00 2.33 DRILL C PROD1 21:00 - 23:05 I 2.081 DRILL I C I I PRODi 8/6/2009 ~ sn/loos 23:05 - 00:00 ( 0.921 DRILL C PRODi 00:00 - 00:45 0.75 DRILL P PROD1 00:45 - 03:15 2.50 DRILL P PROD1 03:15 - 05:00 1.75 DRILL P PROD1 05:00 - 08:45 3.75 DRILL P PROD1 08:45 - 11:45 3.00 DRILL P PRODi 11:45 - 14:10 2.42 DRILL P PROD1 14:10 - 14:30 0.33 DRILL P PROD1 14:30 - 15:35 1.08 DRILL P PRODi 15:35 - 18:00 2.42 DRILL P PROD1 18:00 - 19:50 1.83 DRILL P PROD1 19:50 - 20:45 0.92 DRILL P PROD1 20:45 - 21:05 0.331 DRILL ~ N ~ STUC I PROD1 21:05 - 00:00 I 2.921 DRILL I P 00:00 - 00:30 0.50 DRILL P 00:30 - 01:40 1.17 DRILL P PROD1 PROD1 PROD1 Drill 2.6 / 2.61 bpm ~ 2790 psi, 2300 psi.FS. Wiper to window. Drill 2.62/2.69 bpm Q 2911 psi, DWOB 5.25K, ECD 9.43, Drill to 13550. Wiper to tailpipe. Drill 2.68 / 2.67 bpm ~ 3131 psi. DWOB 2.26K, ECD 9.48, ROP 85. Drill to 13700 ft. Wiper trip from 13,700 ft to window. Drill from 13,700 ft. Hold 92 deg inc for now, still in shales. 2.69 / 2.62 bpm ~ 2800-3100 psi. PVT = 257 bbls. ROP = 60-80 ft/hr with 1-3 Klbs DWOB. Drill to 13,850 ft. Wiper trip to tubing tail. Slow down pump going across billet. Some overpull and wt stacking going across shale zone 13750-13800 ft. Drill from 13,850 ft. 2.74 / 2.75 bpm @ 2800-3100 psi. ROP is 100 ft/hr with 2-3- Klbs DWOB. Drill to 13943 ft. Continue drilling from 13,943 ft to 14,000 ft. Wiper trip from 14,000 ft to window. 80K off bottom. Tie-in depth, correct +9.5 ft. Drill from 14,000 ft. Start mud swap. Try to maintain TVD around 8740 ft for now. 2.77 / 2.79 bpm C~ 3100-3400 psi (old mud). ROP is around 100 ft/hr with 3.4 Klbs DWOB. Drill to 14150'. POH for agitator. LD bit graded 3-3. PU agitatior. Change out stripper. RIH to 12340'. Log tie-in. Correction-29'. RIH .Tag at 14148.5 Drill 2.17/2.71 bpm ~ 3340 psi, 3000 psi FS, DWOB 1.61 K, ECD 9.44, ROP 70. Wiper to window. Mostly clean pass up and down. Drill from 14,300 ft. Plan is to hold 89 deg and drift down to 8748 ft TVD. 2.54 / 2.56 bpm ~ 2900-3300 psi. 8.58 / 8.62 ppg, ECD = 9.49 ppg. ROP is 100-120 ft/hr with 1-2 Klbs DWOB. Drill to 14,363 ft. Motor drills off at 14.363 ft. trv to pick up and are stuck Cycle pipe twice, no luck. Pump open hole clear of cuttings then shut down for several min, until ECD quits dropping. Cycle pipe twice, pops free at 98K. Wiper trip to tubing tail. Some 10K overpulls through shale zones. Tie-in depth, correct +13.5 ft. Continue wiper trip from tubing tail. Drill from 14363 ft. Continue holding 88-89 deg to drift downwards. ROP is 50-100 fUhr with 1-4 Klbs DWOB. Printed: 8/17/2009 10:18:53 AM • • BP EXPLORATION Page 11 of 15 Operations Summary Report Legal Well Name: C-18 Common Well Name: C-18 Spud Date: 4/25/1982 Event Name: REENTER+COMPLETE Start: 7/25/2009 End: 8/6/2009 Contractor Name: NORDIC CALISTA Rig Release: 8/12/2009 Rig Name: NORDIC 1 Rig Number: N1 Date ~ From - To Hours '~ Task :Code NPT Phase I Description of Operations 8/7/2009 00:30 - 01:40 1.17 DRILL P 01:40 - 03:45 2.08 DRILL P 03:45 - 05:10 1.42 DRILL P 05:10 - 08:30 I 3.331 DRILL I P 08:30 - 09:50 09:50 - 11:30 11:30 - 11:40 11:40 - 13:00 13:00 - 14:00 14:00 - 17:15 17:15 - 18:00 1.331 DRILL I P 1.67 DRILL P 0.17 DRILL P 1.33 DRILL P 1.00 DRILL P 3.25 DRILL P 0.75 DRILL P 18:00 - 18:15 18:15 - 19:05 19:05 - 22:50 0.25 DRILL P 0.83 DRILL P 3.75 DRILL P 22:50 - 00:00 1.17 DRILL P 8/8/2009 00:00 - 02:30 2.50 DRILL P 02:30 - 02:45 0.25 DRILL P 02:45 - 03:30 0.75 DRILL P 03:30 - 04:20 0.83 CASE P 04:20 - 05:00 0.671 CASE P 05:00 - 06:00 I 1.001 CASE I P 06:00 - 08:00 2.00 CASE P 08:00 - 08:15 0.25 CASE P 08:15 - 15:00 6.75 CASE P 15:00 - 17:30 2.50 CASE P PROD1 Drill to 14473 ft. PROD1 Wiper trip to window. Stack wt 13430 ft going down. PROD1 Drill from 14473 ft. Hold 8748 ft TVD for now. 2.64 / 2.64 bpm (~ 3100-3700 psi. 8.63 / 8.64 ppg, ECD = 9.59 ppg. ROP is 120 ft/hr with 2.3 Klbs DWOB. PVT = 246 bbls. Drill to 14,594 ft. Frequent 80K pickups. PRODi Wiper trip from 14594 ft to tubing tail. MW in shales at 12830-12930. Set down at 13416. Tool face getting kicked around. Reorient and work thru. MW at 14360, MW thru 14400-14460. PROD1 Drill 2.70 / 2.74 BPM @ 3820 psi, 3420 psi FS, DWOB 1.11 K, ECD 9.72, PROD1 Wiper. Backream 13450 -13375. PRODi Log tie - in . Correction +13'. PROD1 RIH . No Problem at 13416. Tag TD at 14760. PROD1 Drill 2.77 / 2.76 bpm DWOB 1.84K, ECD 9.77, ROP 150', Swapped mud. PROD1 Wiper to tailpipe. PROD1 Drill 2.77 / 2.75 f~ 3830 psi, 3360 psi FS, DWOB 2.5K, ECD 9.55, ROP 150+. Drill to 14997 ft. PROD1 Pull a short 200 ft wiper. PROD1 Drill from 14997 ft to 15,080 ft. PROD1 Call TD at 15,080 ft due to reaching end of polygon. Log GR to tie-in depth, correct +11.5 RIH and to bottom at 15,089 ft. PROD1 POOH laying in liner pill, 0.6 bpm ~ 35 fUmin PROD1 Continue POOH. Pass through window and open EDC, pump 3.6 bpm (~ 3000 psi while POOH. Pipe flags at 11342 ft EOP and 8500 ft EOP. PROD1 SAFETY MEETING. PJSM for UD BHA. PROD1 Tag stripper and UD BHA. Bit is 1-3, 1 plugged jet in nose. Remove BHI cable head. RUNPRD M/U 1 jt PH6, get on well and pump slack forward out of reel. Geo-Vis 5 bpm 3 times. Pop off well, pull cable out. Cut off 286 of cable. RUNPRD Remove jt of 2-3/8" PH6 from well. Re-boot cable. Load BTT liner running equipment onto rig. Lift tongs out of stabbing box and hook up hydraulics. RUNPRD Install CT connector. Pull test to 35K, good. Fill well then PT CT connector to 3500 psi, good. RUNPRD Safety shut down. Dropped objects /Lifting operations. RUNPRD PJSM for picking up liner. RUNPRD PU 2-7/8 X 3-3/16 liner. Liner running tool and 6 jt PH6 tubing. PU injector and MU to liner. Stab onto well. RUNPRD RIH with liner. Up WT at 12,200 49K (-12' to flag didnt correct Printetl: 8/17/2009 10:123:53 Ann • • BP EXPLORATION Page 12 of 15 Operations Summary Report Legal Well Name: C-18 Common Well Name: C-18 Spud Date: 4/25/1982 Event Name: REENTER+COMPLETE Start: 7/25/2009 End: 8/6/2009 Contractor Name: NORDIC CALISTA Rig Release: 8/12/2009 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task ~, Code NPT Phase Description of Operations 8/8/2009 15:00 - 17:30 2.50 CASE P 17:30 - 18:00 0.50 CEMT P 18:00 - 19:00 1.00 CEMT P 19:00 - 20:45 1.75 CEMT P 20:45 - 21:15 21:15 - 00:00 8/9/2009 00:00 - 01:30 01:30 - 01:45 01:45 - 02:40 02:40 - 04:00 RUNPRD to flag). RIH ~ .7 BPM 1300 psi, Tag 15107 un corrected. Break circulation full returns 1 bpm C«? 1560 psi. PU to ball drop position. Up wt is 68 Klbs. RUNPRD Launch 5/8" STL ball with 3000 psi. didn't hear ball. Roll reel while pumping .Nothing rolling. Shut in and repressure attempt relaunch. Hear nothing .Roll out of hole. RUNPRD RIH to bottom and pump a reel volume. Slow pump to 1 bpm after 35 bbls to watch it land, nothing seen after 65 bbls. Increase rate to 3 bpm, then pressure up to 4000 psi and surge it, nothing heard moving. RUNPRD Pick up to check wt, breaks back at 52K stop moving coil 3 ft A ear to be disconnected from liner. Still pumping 2 bpm without pressuring up, so didn't pull tube out of flappers. Consult with Anc Drilling Eng, decide to drop a second ball through a piece of hydraulic hose to ensure its past the plug valve and the "Y" going back to the bulkhead. Use a piece of e-line to push the ball through the hose. 0.50 CEMT P RUNPRD Pressure up against ground valve 1000 psi and launch with a hi-vis pill, ball is heard rolling. Sounds like 2 balls rolling. Ball(s) is heard leaving the reel house and over the gooseneck. Slow down after 30 bbls to watch it land. Ball lands at 54 bbls, shears out at 4600 psi. 2.75 CEMT P RUNPRD Pick up wt is now 39K, RIH back down and stack wt to 15,117 ft. Swap well over to 2% KCI double slick. 1.50 CEMT P RUNPRD Continue circulating well over to KCI. Mix up 80 bbls 2# biozan in pit #3. Replace HP screen in reel house. Pumping KCI at 2.08 / 2.06 bpm ~ 912 psi when all the way around. 0.25 CEMT P RUNPRD SAFETY MEETING. PJSM for pumping cmt. Discuss hazards and mitigations for pumping 36.4 bbl cmt. 0.92 CEMT P RUNPRD Batch up 36.4 bbls cmt. 1.33 CEMT P RUNPRD Cement is up to weight. CT is at 15,117 ft. PT cement line to 6500 psi, good. Start cement down CT, zero In /Out MM on density change. Pump cement at 2.0 bpm. After 36.4 bbls in CT, shut down SLB pump, close choke. Clean up cmt line with biozan, re-zero In /Out MM. Open choke and start displacement with rig pump. Slow pump to 1.5 bpm when cmt reaches dart. After 45.6 bbls on In MM cmt is at shoe, zero Out MM leave In MM running. Displace at 2.12 / 2.09 bpm. Volume In /Out (bbls) 45.6 / 0 50 / 4.3 56.5 / 10.7 Shut down pump at 56.5 bbls, leaving 2 bbls above SELRT. Punted: 8/772009 10:78:53 AM BP EXPLORATION Page 13 of 15 Operations Summary Report Legal Well Name: C-18 Common Well Name: C-18 Spud Date: 4/25/1982 Event Name: REENTER+COMPLETE Start: 7/25/2009 End: 8/6/2009 Contractor Name: NORDIC CALISTA Rig Release: 8/12/2009 Rig Name: NORDIC 1 Rig Number: N1 Date From - To !Hours Task Code NPT Phase Description of Operations 8/9/2009 02:40 - 04:00 1.33 CEMT P RUNPRD Pick up and exhaust 5 bbls. Open choke and slack back down to 15,117 ft with 0 wt. Close choke and shear out LWP at 1700 psi. 62.1 / 10.7 65/13.2 Qin/gout=2.56/2.47 70 / 18.1 2.6 / 2.51 75 / 22.9 2.68 / 2.60 80 / 27.8 2.48 / 2.47 85.5 bump / 33.8 All arameters of cement job were normal. Total of 33.8 bbls cmt behind pipe. 04:00 - 06:00 2.00 CEMT P RUNPRD Bump plug and hold 1000 psi over, holding. Open Baker choke, floats are holding. Pressure up to 1000 psi and pull out of seals, when pressure drops pump 1 bbl then POOH replacing voidage. 06:00 - 06:15 0.25 CEMT P RUNPRD SAFETY MEETING. PJSM for UD liner running tools and PH6. 06:15 - 07:00 0.75 CEMT P RUNPRD Tag stripper and UD liner running tools. Recover both balls, tool has functioned normally. 07:00 - 10:30 3.50 CEMT P RUNPRD PU nozzel jet stack. LD same prep floor for BOP test. 10:30 - 17:00 6.50 BOPSU P LOWERI ,Test BOP. Witnessing of test waived by AOGCC 's Chuck Scheeve 17:00 - 18:00 1.00 EVAL P LOWERI Pre ri floor to run Cleanout + MCNL to . Load MCNL tools to rig floor. 18:00 - 18:15 0.25 EVAL P LOW ER1 SAFETY MEETING. PJSM for running MCNL + 58 stds. 18:15 - 22:00 3.75 EVAL P LOWERI M/U BHA #13 -New 2.30 mill, 2-1/8" Xtreme, 1 std CSH, MGR/CCL tool, 1/2" Circ Sub, 5/8" Disconnect, 58 stds 1-1/4" CSH, 3/4" Disconnect, DBPV, 2 jts PH6, Lockable swivel. BHA OAL = 3757.65 ft. 22:00 - 00:00 2.00 EVAL P LOW ERi Hook up SLB loggers depth cable. Pump 5 bbls ahead then RIH. RIH, 0.3 bpm ~ 210 psi. Wt check at 11350 ft is 38 Klbs. 8/10/2009 00:00 - 00:15 0.25 EVAL LOWERI Continue RIH. 'i 00:15 - 02:00 1.75 EVAL LOWERi Tag at 11606 ft, pick up and start milling SELRT profile. Two stalls getting started, then steady progress. 02:00 - 02:30 0.50 EVAL LOWERI Mill through it, RIH to 11800 ft then pull back to 11400 ft to start logging. 02:30 - 04:30 2.00 EVAL LOWERi Log down at 30 ft/min. Ta PBTD at 15,069 ft twice, good tag. 04:30 - 05:30 1.00 EVAL LOWERI Start pert pill down CT, pick up slowly. 05:30 - 06:30 1.00 EVAL LOWERI Log up at 60 ft/min, lay in pert pill. 06:30 - 08:30 2.00 EVAL LOWERI POH. 08:30 - 11:00 2.50 EVAL LOWERI Standback CSH 11:00 - 12:00 1.00 EVAL LOW ER1 LD logging tools. No data. Anchorage decided not to rerun memory log. 12:00 - 13:00 1.00 EVAL LOWERI Jet stack. 13:00 - 14:15 1.25 EVAL LOWERI Test liner la to 2000 si. Lost 70 si in 30 minutes. Good Test. 14:15 - 16:00 1.75 PERFO LOWERi Load erforatin uns. 16:00 - 22:30 6.50 PERFO LOWERI PU 84 guns + 30 stands CSH and MHA and 2 jts PH6. Shut down for 30 min for Nordic crew change. 22:30 - 00:00 1.50 PERFO LOWERi M/U injector to riser, RIH. Printed: S/17/2009 10:18:53 AM BP EXPLORATION Operations Summary Report Page 14 of 15 ~ Legal Well Name: C-18 .Common Well Name: C-18 Spud Date: 4/25/1982 Event Name: REENTER+COMPLETE Start: 7/25/2009 End: 8/6/2009 Contractor Name: NORDIC CALISTA Rig Releaser 8/12/2009 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 8/10/2009 22:30 - 00:00 1.50 8/11/2009 00:00 - 02:00 2.00 02:00 - 02:30 I 0.50 02:30 - 03:30 1.00 i P 03:30 - 04:00 I 0.50 04:00 - 05:30 1.50 PERFO P 05:30 - 06:15 0.75 PERFO P 06:15 - 06:30 0.25 PERFO P 06:30 - 07:30 1.00 PERFO P 07:30 - 09:15 1.75 PERFO P 09:15 - 15:00 5.75 PERFO N 15:00 - 18:00 3.00 PERFOB~ P 18:00 - 18:45 0.75 PERFO P LOWERI Pump 0.3 bpm ~ 180 psi while RIH. P LOWERI Continue RIH. Wt check just above liner top is 42 Klbs. Tag at 15,073 ft, three times, correct depth to tally PBTD. Up wt is 54 Klbs. P LOWERI Pick up to 2 ft below firing depth, line up well returns through choke. Practice with 2 different pump rates, use 0.5 and 1.5 bpm. Start pump sequence to fire guns. 0.5 bpm / 1 min 1.5 bpm / 1 min 0.5 bpm / 1 min 1.5 bpm / 1 min 0.5 bpm / 1 min 1.5 bpm / 1 min 0.5 bpm / 1 min 1.5 bpm / 2-1/2 min 0.5 bpm, wait for shot, shot indication on acoustic after about 1 min with loss of returns for 3-4 min. Depth when fired is 15015.4 ft. PERFORATION INTERVALS: 13255-13275 13300-13350 13370-13390 13485-13525 13780-13870 14040-14060 14175-14200 14210-14265 14280-14390 14435-14570 14630-14740 14835-14910 14955-15015 Total perforated length is 81.0 ft. LOWERI POOH, hold 300-400 psi choke pressure and 60 ft/min while inside liner. LOWERI Park above liner top at 11485 ft and flow check for 30 min. No flow. LOWERi Fill well with 0.4 bbls then continue POOH. LOWERI Tag stripper and flow check well for 30 min. Fill well with 1 bbl. LOWERI PJSM for laying down guns. LOWERI Stand back CSH. LOWERI LD guns LOWERI Accident occured. Pinched between. Nikolai Soshnin SBL perforating hand pinched right ring finger between the lifting nubbin in the gun assy in the slips and the lifting nubbin in the joint that was released from the pipe elevators. Shut down for investigation. P P Safety reps from SLB, Nordic, & BP investigated incident. LOWERI Continue UD perf guns. LOWERi Offload perf guns. Rig down tongs from floor. Printed: 8/17/2009 10:18:53 AM ~ ~ BP EXPLORATION Operations Summary Report Legal Well Name: C-18 Common Well Name: C-18 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Start: 7/25/2009 Rig Release: 8/12/2009 Rig Number: N1 Date From - To Hours , Task Code NPT Phase Page 15 of 15 ~ Spud Date: 4/25/1982 End: 8/6/2009 Description of Operations 8/11/2009 18:45 - 20:05 1.33 PERFUB N LOWERI Wait on 5' pipe segment from Nordic 2 for nozzle BHA for swapping wellbore over to diesel. 20:05 - 20:15 0.17 PERFUB P LOWERI SAFETY MEETING. PJSM for MU Nozzle and stabbing on injector. 20:15 - 20:30 0.25 PERFUB P LOWERi MU Nozzle BHA 20:30 - 22:45 2.25 PERFUB P LOWERi Stab on injector and RIH with Nozzle ass .Nozzle, XO, BPV, 5' Stinger, XO, XO, XO, BTT CTC. BHA total length 10.59' RIH circulating minimum rate taking gas cut returns 7.8 to 8.3 PP9 22:45 - 23:00 0.25 PERFUB P LOWERI SAFETY MEETING. PJSM with LRS over pumping diesel using LRS unit. 23:00 - 00:00 1.00 PERFUB P LOWERI POH after diesel rounds the corner. Pull at 67 fpm while pumping at 1.55 in, holding 300 psi on choke. Step rate to 2.3 in and 100 fpm once SLB shifts gears, still holding 300 psi. 8/12/2009 00:00 - 01:10 1.17 PERFUB P LOWERI Cont. POH at 100 fpm laying in diesel at 2.3 bpm and holding 300 psi. Tag up, § u ow g 198 psi.Close master, 34 turns. 01:10 - 01:20 0.17 PERFUB P LOWERI Pop off well and stand back injector. Lay down nozzle 01:20 - 01:45 0.42 WHSUR P POST Valve crew greased the tree as per new procedure. 01:45 - 01:55 0.17 WHSUR P POST SAFETY MEETING. PJSM regarding bringing up lubricator. 01:55 - 02:25 0.50 WHSUR P POST Bring lubricator up beaver slide to the rig floor 02:25 - 02:35 0.17 WHSUR P POST SAFETY MEETING. PJSM over MU and setting BPV. 02:35 - 03:15 0.67 WHSUR P POST MU bar and BPV assembly. Attempt to RIH but could not get past flow cross /SSV. Confirm that SSV is totally open. Still cannot RIH. 03:15 - 04:15 1.00 WHSUR P POST Suck down stack and tree. RIH with BPV and set. Rig down lubricator. 04:15 - 04:30 0.25 WHSUR P POST SAFETY MEETING. PJSM sending down lubricator. 04:30 - 04:45 0.25 WHSUR P POST Send lubricator down beaver slide and load out. 04:45 - 07:30 2.75 WHSUR N WAIT POST Wait on SLB N2 unit. 07:30 - 09:45 2.25 WHSUR P POST SAFETY MEETING, re: N2 blowdown Cool down N2 unit then blowdown reel. Bleed down pressure then S/B injector. 09:45 - 12:00 2.25 RIGD P POST SAFETY MEETING, re: ND BOP N/D BOP i NU & PT Tree Cap t RDMO RELEASE RIG ~ 12:00 TOTAL TIME FROM ACC PT TO RELEASE = 17 Days 19.5 hours Move to DS 18-02. rnrnea: sn nzuua IU:IS:J3 HM i ^~,~~ BAKER H1,I~NES INTEQ North America -ALASKA - BP Prudhoe Bay PB C Pad C-18 -Slot 18 C-18BPB1 Design: C-18BPB1 Survey Report -Geographic 17 August, 2009 by ~~~ s ua~~ Company:. North America -ALASKA - BP Survey Report -Geographic Project: Prudhoe Bay Site: PB C Pad Well: C-18 Wellbore:- C-18BPB1 De5igrr; C-18BP81 by Local Co-ordinate Reference: Well C-18 -Slot 18 TVD Reference: Mean Sea Level MD Reference: 20:18 4!25/1982 00:00 @ 66.80ft (generic drillinc North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM .16 - Anc Prod - WH24P project Prudhoe Bay, North Slope, UNITED STATES Aap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Leo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Aap Zone: Alaska Zone 04 Using geodetic scale factor Site PB C Pad, TR-11-14 Site Position: From: Map Position Uncertainty: Well C-18 Well Position +N/-S +E/-W Position Uncertainty Northing: Fasting: 0.00 ft Slot Radius: 5,957,218.72ft Latitude: 70° 17' 22.367 N 662,550.03ft Longitude: 148° 41' 2.797 W O.000in Grid Convergence: 1.24 ° API No 500292078500 0.00 ft Northing: 5,960,654.00 ft Latitude: 70° 17' 55.872 N 0.00 ft Fasting: 663,839.00 ft Longitude: 148° 40' 23.063 W 0.00 ft Wellhead Elevation: ft Ground Level: O.OOft Wellbore C-18BPB1 API No 500292078570 Magnetics Model Name Sample bate Declination Dip Angle Field Strength BGGM2008 6/11/2009 22.68 80.92 57,712 Design C-188PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 12,200.00 Vertical Section:. Depth From (TVD) +N/-S +E/-W Direction ... -33.00 0.00 0.00 32.99 I Survey Program Date:: 8/17/2009 From To (ft) (ft) Survey (Wellbore) Tool Name Description 100.00 12,200.00 1 : Sperry-Sun BOSS gyro multi (C-18) BOSS-GYRO Sperry-Sun BOSS gyro multishot ~, 12,279.00 14,707.00 MWD (C-186P61) MWD MWD -Standard 8/17x1009 3:46:09PM Page 2 COMPASS 2003.16 Build 71 sw ~R ~ 1iltl~iFlS 1NTEQ Company: North America -ALASKA - BP Project: Prudhoe Bay Site::- PB C Pad We1L• C-18 Wellbore: C-186PB1 .Design: C-18BPB1 Survey Measured Depth Inclination Azimuth ~~~ 12,200.00 39.13 TIP 12,279.00 39.62 ~~ KOP 12,302.28 41.79 12,335.42 46.60 12,366.00 48.45 12,395.38 47.97 12,420.62 47.30 '~ 12,448.68 46.50 12,480.42 46.31 12,509.76 47.52 12,540.46 48.99 12,570.90 48.19 12,600.06 49.26 12,630.02 50.96 12,662.04 51.58 it 12,693.96 51.56 12,722.54 52.65 12,759.98 57.98 12,789.84 60.99 ~'i 12,819.86 63.77 12,850.68 67.67 12,878.50 69.62 12,908.68 72.89 12,938.78 76.81 12,968.68 81.09 12,997.06 84.63 13,028.93 90.06 i~ 13,060.37 88.83 13,090.85 89.97 13,120.43 90.22 13,150.21 90.18 13,179.51 89.14 13,216.81 91.14 ', 13,246.45 89.20 13,275.01 88.74 13,305.49 88.10 13,335.31 88.37 13,364.41 92.12 13, 394.37 96.64 13,421.67 93.38 13,454.65 93.10 ', 13,487.91 92.80 13,521.10 92.37 13,549.69 90.25 i 13,584.01 90.49 13,611.15 90.83 13,640.21 89.20 13,665.21 89.60 13,695.39 89.23 13,723.69 88.62 i 13,755.33 85.02 13,785.73 82.09 13,818.79 82.98 -~-~, p S s Survey Report -Geographic Loeal Co-ordinate References Well G18 -Slot 18 TVD Reference: Mean Sea Level MD Reference: 20:18 4/25/1982 00:00 @ 66.80ft (generic drilling North References True Survey Calculation Method: Minimum Curvature Database: EDM .16 - Anc Prod - WH24P TVD Belovu Map Map System +N/~ +FJ-W Northing Fasting (ft) (f1v) {ft) {ffi (ft) Latitude Longitude 8,295.12 6,651.88 4,766.69 5,967,407.76 668,459.20 70° 19' 1.278 N 148° 38' 3.985 W 44.80 44.64 8,356.19 6,687.49 4,801.95 5,967,444.13 668,493.68 70° 19' 1.628 N 148° 38' 2.955 W 46.57 8,373.84 6,698.11 4,812.80 5,967,454.98 668,504.30 70° 19' 1.732 N 148° 38' 2.638 W 49.11 8,397.59 6,713.59 4,829.93 5,967,470.83 668,521.08 70° 19' 1.885 N 148° 38' 2.138 W 51.26 8,418.24 6,728.03 4,847.26 5,967,485.64 668,538.09 70° 19' 2.026 N 148° 38' 1.632 W 53.18 8,437.82 6,741.45 4,864.57 5,967,499.43 668,555.10 70° 19' 2.158 N 148° 38' 1.127 W 58.20 8,454.84 6,751.96 4,879.96 5,967,510.27 668,570.26 70° 19' 2.262 N 148° 38' 0.678 W 61.86 8,474.01 6,762.19 4,897.70 5,967,520.89 668,587.77 70° 19' 2.362 N 148° 38' 0.160 W 69.43 8,495.92 6,771.66 4,918.61 5,967,530.81 668,608.47 70° 19' 2.455 N 148° 37' 59.549 W 76.24 8,515.97 6,777.96 4,939.07 5,967,537.56 668,628.78 70° 19' 2.517 N 148° 37' 58.953 W 80.74 8,536.42 6,782.52 4,961.50 5,967,542.61 668,651.11 70° 19' 2.562 N 148° 37' 58.298 W 75.62 8,556.56 6,787.19 4,983.84 5,967,547.76 668,673.33 70° 19' 2.607 N 148° 37' 57.646 W 69.69 8,575.80 6,793.73 5,004.73 5,967,554.75 668,694.08 70° 19' 2.672 N 148° 37' 57.036 W 63.42 8,595.03 6,802.88 5,025.80 5,967,564.36 668,714.94 70° 19' 2.761 N 148° 37' 56.421 W 56.96 8,615.07 6,815.29 5,047.45 5,967,577.24 668,736.31 70° 19' 2.883 N 148° 37' 55.790 W 50.68 8,634.93 6,830.04 5,067.61 5,967,592.42 668,756.15 70° 19' 3.028 N 148° 37' 55.201 W 45.92 8,652.49 6,845.04 5,084.44 5,967,607.78 668,772.65 70° 19' 3.176 N 148° 37' 54.710 W 40.58 8,673.80 6,867.47 5,105.48 5,967,630.67 668,793.19 70° 19' 3.396 N 148° 37' 54.095 W 41.09 8,688.96 6,886.93 5,122.30 5,967,650.49 668,809.58 70° 19' 3.587 N 148° 37' 53.604 W 35.63 8,702.88 6,907.78 5,138.78 5,967,671.69 668,825.61 70° 19' 3.792 N 148° 37' 53.123 W 32.19 8,715.55 6,931.10 5,154.44 5,967,695.34 668,840.75 70° 19' 4.022 N 148° 37' 52.665 W 31.08 8,725.68 6,953.16 5,168.03 5,967,717.69 668,853.85 70° 19' 4.238 N 148° 37' 52.268 W 36.35 8,735.39 6,976.91 5,183.89 5,967,741.78 668,869.19 70° 19' 4.472 N 148° 37' 51.805 W 42.23 8,743.26 6,999.37 5,202.29 5,967,764.64 668,887.09 70° 19' 4.693 N 148° 37' 51.268 W 40.23 8,748.99 7,021.44 5,221.62 5,967,787.12 668,905.94 70° 19' 4.910 N 148° 37' 50.703 W 42.23 8,752.52 7,042.61 5,240.18 5,967,808.69 668,924.03 70° 19' 5.118 N 148° 37' 50.161 W 45.02 8,753.99 7,065.64 5,262.13 5,967,832.19 668,945.48 70° 19' 5.344 N 148° 37' 49.520 W 49.91 8,754.30 7,086.89 5,285.29 5,967,853.94 668,968.17 70° 19' 5.553 N 148° 37' 48.844 W 55.01 8,754.62 7,105.45 5,309.45 5,967,873.02 668,991.91 70° 19' 5.735 N 148° 37' 48.139 W 59.93 8,754.57 7,121.36 5,334.38 5,967,889.46 669,016.49 70° 19' 5.892 N 148° 37' 47.411 W 65.02 8,754.46 7,135.11 5,360.78 5,967,903.79 669,042.58 70° 19' 6.027 N 148° 37' 46.640 W 70.47 8,754.64 7,146.21 5,387.89 5,967,915.47 669,069.44 70° 19' 6.136 N 148° 37' 45.849 W 78.27 8,754.55 7,156.25 5,423.78 5,967,926.29 669,105.10 70° 19' 6.234 N 148° 37' 44.802 W 79.80 8,754.46 7,161.88 5,452.88 5,967,932.56 669,134.06 70° 19' 6.289 N 148° 37' 43.953 W 75.23 8,754.97 7,168.06 5,480.75 5,967,939.34 669,161.79 70° 19' 6.350 N 148° 37' 43.139 W 69.05 8,755.81 7,177.40 5,509.74 5,967,949.31 669,190.57 70° 19' 6.441 N 148° 37' 42.293 W 65.53 8,756.73 7,188.90 5,537.23 5,967,961.41 669,217.80 70° 19' 6.554 N 148° 37' 41.491 W 64.47 8,756.61 7,201.20 5,563.59 5,967,974.28 669,243.89 70° 19' 6.675 N 148° 37' 40.721 W 62.40 8,754.32 7,214.55 5,590.31 5,967,988.21 669,270.30 70° 19' 6.806 N 148° 37' 39.941 W 56.81 8,751.93 7,228.31 5,613.75 5,968,002.47 669,293.44 70° 19' 6.941 N 148° 37' 39.257 W 50.40 8,750.07 7,247.83 5,640.24 5,968,022.57 669,319.49 70° 19' 7.133 N 148° 37' 38.484 W 46.47 8,748.36 7,269.87 5,665.09 5,968,045.14 669,343.85 70° 19' 7.350 N 148° 37' 37.758 W 41.39 8,746.86 7,293.74 5,688.08 5,968,069.50 669,366.32 70° 19' 7.584 N 148° 37' 37.087 W 38.88 8,746.20 7,315.59 5,706.50 5,968,091.75 669,384.26 70° 19' 7.799 N 148° 37' 36.549 W 33.53 8,745.98 7,343.27 5,726.77 5,968,119.86 669,403.92 70° 19' 8.071 N 148° 37' 35.957 W 29.86 8,745.67 7,366.36 5,741.02 5,968,143.25 669,417.66 70° 19' 8.298 N 148° 37' 35.540 W 25.84 8,745.66 7,392.04 5,754.60 5,968,169.23 669,430.67 70° 19' 8.551 N 148° 37' 35.144 W 22.02 8,745.92 7,414.89 5,764.73 5,968,192.29 669,440.31 70° 19' 8.775 N 148° 37' 34.847 W 17.83 8,746.23 7,443.26 5,775.02 5,968,220.87 669,449.97 70° 19' 9.054 N 148° 37' 34.547 W 14.57 8,746.76 7,470.42 5,782.91 5,968,248.20 669,457.27 70° 19' 9.321 N 148° 37' 34.316 W 11.87 8,748.52 7,501.17 5,790.13 5,968,279.10 669,463.82 70° 19' 9.624 N 148° 37' 34.104 W 9.57 8,751.93 7,530.84 5,795.75 5,968,308.88 669,468.79 70° 19' 9.915 N 148° 37' 33.939 W 2.27 8,756.23 7,563.43 5,799.13 5,968,341.53 669,471.46 70° 19' 10.236 N 148° 37' 33.840 W 8/17/2009 3:46:09PM Page 3 COMPASS 2003.16 Build 71 swKiR ~ llilt~es Survey Report -Geographic ~ by u.~~~ Company: North America -ALASKA - BP Project: Prudhoe Bay Site: PB C Pad Well: C-18 Wellbore: ' C-18BPB1 Design;.. C-18BPB1 Survey w~ass Measured TVD Below Depth - Inclination Azimuth System +N/~ (~) (°) (°) (~) (ft) 13,847. 07 83. 75 0. 01 8,759.50 7,591. 51 13,885. 63 82. 72 354. 63 8,764.05 7,629. 74 13,924. 53 86. 44 350. 50 8,767.72 7,668. 13 13,956. 07 87. 39 346. 40 8,769.42 7,698. 98 13,991. 79 81. 77 343. 89 8,772.79 7,733. 33 14,023. 25 83. 07 339. 78 8,776.94 7,762. 96 14,055. 85 86. 72 336. 34 8,779.84 7,793. 07 14,085. 51 86. 34 332. 64 8,781.64 7,819. 78 14,116. 43 92. 12 331. 22 8,782.06 7,847. 05 14,145. 25 91. 56 325. 90 8,781.13 7,871. 62 14,175. 23 93. 16 323. 78 8,779.89 7,896. 10 14,206. 97 96. 89 322. 60 8,777.12 7,921. 41 14,236. 69 101. 07 320. 52 8,772.48 7,944. 40 14,268. 21 101. 99 316. 16 8,766.17 7,967. 47 14,300. 69 98. 24 314. 52 8,760.47 7,990. 21 14,329. 61 94. 02 314. 45 8,757.38 8,010. 35 14,360. 89 91. 47 311. 19 8,755.88 8,031. 58 14,392. 83 92. 72 316. 77 8,754.72 8,053. 74 14,426. 67 91. 72 322. 78 8,753.40 8,079 .54 14,463. 03 91. 32 328. 28 8,752.44 8,109 .50 14,495. 43 89. 57 332. 41 8,752.19 8,137 .65 14,524. 87 92. 09 337. 00 8,751.76 8,164 .25 14,566. 91 90. 71 341. 11 8,750.73 8,203 .49 14,602. 91 92. 55 338. 91 8,749.71 8,237 .31 14,633 .11 96. 72 334. 40 8,747.27 8,264 .93 14,707 .00 96. 72 334. 40 8,738.62 8,331 .11 TD Local Co-ordinate Reference: Well G18 -Slot 18 TVD Reference: Mean Sea Level MD Reference: 20:1 8 412511 982 00:00 @ 66.80ft (generic drillinc North References True Survey Calculation Method:. Minimum Curvature Database: EDM .16 - Anc Prod - WH24P Map, Map +E/.W Northing Fasting (ft) (ft) (tt) Latitude Longitude 5,799.69 5,968,369.62 669,471.40 70° 19' 10.512 N 148° 37' 33.823 W 5,797.90 5,968,407.80 669,468.78 70° 19' 10.888 N 148° 37' 33.875 W 5,792.89 5,968,446.06 669,462.93 70° 19' 11.266 N 148° 37' 34.020 W 5,786.58 5,968,476.77 669,455.96 70° 19' 11.569 N 148° 37' 34.203 W 5,777.47 5,968,510.91 669,446.10 70° 19' 11.907 N 148° 37' 34.468 W 5,767.75 5,968,540.32 669,435.74 70° 19' 12.198 N 148° 37' 34.751 W 5,755.62 5,968,570.15 669,422.95 70° 19' 12.495 N 148° 37' 35.105 W 5,742.87 5,968,596.58 669,409.63 70° 19' 12.757 N 148° 37' 35.476 W 5,728.33 5,968,623.52 669,394.50 70° 19' 13.026 N 148° 37' 35.900 W 5,713.31 5,968,647.75 669,378.94 70° 19' 13.267 N 148° 37' 36.338 W 5,696.06 5,968,671.86 669,361.17 70° 19' 13.508 N 148° 37' 36.840 W 5,677.12 5,968,696.75 669,341.68 70° 19' 13.758 N 148° 37' 37.392 W 5,658.88 5,968,719.33 669,322.94 70° 19' 13.984 N 148° 37' 37.924 W 5,638.36 5,968,741.95 669,301.93 70° 19' 14.211 N 148° 37' 38.523 W 5,615.89 5,968,764.19 669,278.96 70° 19' 14.435 N 148° 37' 39.178 W 5,595.38 5,968,783.88 669,258.02 70° 19' 14.633 N 148° 37' 39.776 W 5,572.46 5,968,804.60 669,234.65 70° 19' 14.842 N 148° 37' 40.444 W 5,549.50 5,968,826.25 669,211.22 70° 19' 15.060 N 148° 37' 41.114 W 5,527.68 5,968,851.57 669,188.84 70° 19' 15.314 N 148° 37' 41.750 W 5,507.12 5,968,881.07 669,167.63 70° 19' 15.609 N 148° 37' 42.350 W 5,491.09 5,968,908.86 669,150.99 70° 19' 15.886 N 148° 37' 42.817 W 5,478.52 5,968,935.18 669,137.84 70° 19' 16.147 N 148° 37' 43.183 W 5,463.50 5,968,974.08 669,121.97 70° 19' 16.533 N 148° 37' 43.621 W 5,451.20 5,969,007.62 669,108.94 70° 19' 16.866 N 148° 37' 43.979 W 5,439.28 5,969,034.97 669,096.42 70° 19' 17.138 N 148° 37' 44.326 W 5,407.57 5,969,100.44 669,063.28 70° 19' 17.789 N 148° 37' 45.250 W 8/17/2009 3:46:09PM Page 4 COMPASS 2003.16 Build 71 i • t/~~ saKER Nu~NEs INTEQ North America -ALASKA - BP Prudhoe Bay PB C Pad C-18 -Slot 18 C-18B Survey: MWD Survey Report -Geographic 10 August, 2009 by ~ u- R NuaM~s ~INTEQ Company: North America - ALASIG4 - BP Project: Prudhoe Bay Site: PB C Pad We1L• C-18 Wellbore: C-18B Design: C-18B Survey Report -Geographic ~ by local. Co-ordinate Reference: Well C-18 -Slot 18 TVD Reference: Mean Sea Level MD Reference: 20:18 4/25/1982 00:00 @ 66.80ft (generic drillinc North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM .16 - Anc Prod - WH24P 'roject Prudhoe Bay, North Slope, UNITED STATES dap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level ieo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point ilap Zone: Alaska Zone 04 Using geodetic scale factor Site PB C Pad, TR-11-14 Site Position: Northing: 5,957,218.72ft Latitude: 70° 17' 22.367 N From: Map Easting: 662,550.03ft Longitude: 148° 41' 2.797 W Position Uncertainty: 0.00 ft Slot Radius: 0.000 in Grid Convergence: 1.24 ° Well C-18 API No 500292078500 Well Position +NI-S 0.00 ft Northing: 5,960,654.00 ft Latitude: 70° 1T 55.872 N +E/-W 0.00 ft Easting: 663,839.00 ft Longitude: 148° 40' 23.063 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: O.OOft Wellbore C-188 API No 500292078502 Magnetics Model Name Sample Date Declination Dip Angle Fietd Strength BGGM2009 8!4/2009 22.57 80.93 57,669 --- Design C-1.86 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 13,060.37 Vertical Section: Depth From (TVD) +N/~ +~/-W Direction (ft) (ft) (ft) (°) _33.00 0.00 0.00 35.60 Survey Program Date'8110/2009 From To (ft) (ft) Survey (Wellbore) Toot Name Description 100.00 12,200.00 1 : Sperry-Sun BOSS gyro multi (C-18) BOSS-GYRO Sperry-Sun BOSS gyro multishot 12,279.00 13,060.37 MWD (C-18BPB1) MWD MWD -Standard 13,070.00 15,089.00 MWD (C-18B) MWD MWD -Standard 8/10/2009 f 0:29:09AM Page 2 COMPASS 2003.16 Build 71 ~i%~ BAKtR NYANts INTEQ Company: North America -ALASKA - BP Project: Prudhoe Bay Site: : PB C Pad Well: C-18 Wellbore: C-186 Design: C-18B Survey Measured Depth inclination Azimuth 13,060.37 88.83 49.91 TIP 13,070.00 89.19 51.52 KOP 13,100.99 96.15 47.94 13,130.77 96.65 44.13 13,163.19 91.51 43.53 13,191.69 91.07 39.72 13,220.57 91.44 44.39 13,258.01 89.54 50.32 13,290.75 88.80 55.11 13,323.43 89.02 61.13 13,356.09 87.73 59.41 13,387.51 89.11 55.51 13,428.91 91.26 48.30 13,461.51 90.15 41.70 13,490.59 90.40 39.01 13,520.41 91.07 35.21 13,550.65 90.31 31.14 13,580.85 90.71 27.04 13,611.09 89.75 22.13 13,642.11 91.81 17.46 13,674.67 93.10 12.43 13,707.43 91.04 7.31 13,739.79 91.78 1.50 13,771.71 93.65 357.19 13,809.11 91.26 351.50 13,845.09 91.84 346.78 13,884.77 90.18 339.63 13,916.73 90.12 337.06 13,948.17 90.12 334.13 13,979.43 88.07 331.58 14,012.33 86.99 326.48 14,055.79 90.98 320.73 14,085.41 89.14 314.92 14,114.19 89.97 310.03 14,144.59 91.71 305.55 14,175.17 88.87 310.22 14,204.83 86.78 316.05 14,238.21 87.42 323.05 14,270.13 91.08 330.62 14,300.89 90.12 335.49 14,340.31 91.20 342.74 14,373.53 88.50 347.98 'I 14,416.83 84.28 344.84 'I 14,449.31 88.37 340.18 14,480.15 92.06 334.6C 14,510.13 ~ 92.61 329.4E 14,539.83 91.54 323.55 14,578.90 88.89 320.6E 14,607.67 85.63 325.97 ', 14,639.47 83.94 332.OC 'I 14,677.81 84.88 340.47 14,696.25 86.89 343.67 14,725.89 89.23 342.32 Survey Report -Geographic by Local Co-ordinate Reference: 'Well G18 -Slot 18 TVD Reference: `Mean Sea Level MD Reference:.. 20:18 4/25/1982 00:00 @ 66.80ft (generic drillinc North. Reference: True .Survey Calculation Method: Minimum Curvature Database: EDM .16 - Anc Prod - WH24P 7`' V D s s ND Below Map Map System +Nt-S +E/-W Northing Fasting ; (ft) (ft) (ft), (ft) (ft) Latitude Longitude 8,754.30 7,086.89 5,285.29 5,967,853.94 668,968.17 70° 19' 5.553 N 148° 37' 48.844 W 8,754.46 7,092.99 5,292.75 5,967,860.20 668,975.48 70° 19' 5.613 N 148° 37' 48.627 W 8,753.02 7,112.98 5,316.35 5,967,880.70 668,998.64 70° 19' 5.809 N 148° 3T 47.937 W'~~ 8,749.70 7,133.52 5,337.65 5,967,901.69 669,019.49 70° 19' 6.011 N 148° 3T 47.316 W ~ ~ 8,747.39 7,156.84 5,360.03 5,967,925.50 669,041.36 70° 19' 6.240 N 148° 3T 46.662 W '~i 8,746.75 7,178.13 5,378.96 5,967,947.20 669,059.81 70° 19' 6.450 N 148° 37' 46.109 W 8,746.12 7,199.57 5,398.29 5,967,969.04 669,078.67 70° 19' 6.660 N 148° 37' 45.545 W 8,745.80 7,224.92 5,425.82 5,967,994.99 669,105.64 70° 19' 6.909 N 148° 37' 44.741 W 8,746.27 7,244.74 5,451.85 5,968,015.37 669,131.23 70° 19' 7.104 N 148° 3T 43.981 W'~ 8,746.90 7,261.99 5,479.59 5,968,033.22 669,158.58 70° 19' 7.274 N 148° 37' 43.171 W 8,747.82 7,278.18 5,507.93 5,968,050.02 669,186.57 70° 19' 7.433 N 148° 3T 42.344 W'~, 8,748.69 7,295.07 5,534.41 5,968,067.49 669,212.66 70° 19' 7.599 N 148° 3T 41.571 W', 8,748.55 7,320.59 5,566.96 5,968,093.71 669,244.66 70° 19' 7.849 N 148° 3T 40.620 W', 8,748.15 7,343.63 5,590.00 5,968,117.24 669,267.18 70° 19' 8.076 N 148° 3T 39.948 W'. 8,748.01 7,365.79 5,608.83 5,968,139.81 669,285.52 70° 19' 8.294 N 148° 3T 39.398 W' 8,747.63 7,389.56 5,626.82 5,968,163.97 669,302.98 70° 19' 8.527 N 148° 3T 38.872 W 8,747.27 7,414.87 5,643.36 5,968,189.62 669,318.97 70° 19' 8.776 N 148° 3T 38.389 W'' 8,747.00 7,441.25 5,658.04 5,968,216.32 669,333.07 70° 19' 9.035 N 148° 3T 37.960 W'', 8,746.88 7,468.74 5,670.61 5,968,244.07 669,345.04 70° 19' 9.306 N 148° 3T 37.592 W I, ~ 8,746.45 7,497.92 5,681.12 5,968,273.47 669,354.91 70° 19' 9.592 N 148° 3T 37.285 W 'I 8,745.06 7,529.33 5,689.50 5,968,305.06 669,362.60 70° 19' 9.901 N 148° 3T 37.040 W I 8,743.87 7,561.58 5,695.11 5,968,337.41 669,367.51 70° 19' 10.218 N I 148° 37' 36.876 W 8,743.08 7,593.82 5,697.59 5,968,369.70 669,369.29 70° 19' 10.535 N 148° 3T 36.802 W 8,741.56 7,625.69 5,697.23 5,968,401.55 669,368.23 70° 19' 10.849 N 148° 3T 36.812 W', 8,739.96 7,662.86 5,693.55 5,968,438.63 669,363.74 70° 19' 11.215 N 148° 3T 36.919 W 8,738.99 7,698.17 5,686.78 5,968,473.78 669,356.20 70° 19' 11.562 N 148° 3T 37.116 W'i 8,738.29 7,736.12 5,675.32 5,968,511.48 669,343.92 70° 19' 11.935 N 148° 3T 37.449 W 8,738.20 7,765.82 5,663.53 5,968,540.91 669,331.48 70° 19' 12.227 N 148° 3T 37:793 W', 8,738.14 7,794.45 5,650.54 5,968,569.25 669,317.87 70° 19' 12.509 N 148° 3T 38.171 W ~, 8,738.63 7,822.26 5,636.28 5,968,596.74 669,303.01 70° 19' 12.783 N 148° 3T 38.587 W', ~ 8,740.05 7,850.44 5,619.37 5,968,624.53 669,285.49 70° 19' 13.060 N ', 148° 3T 39.079 W 8,740.82 7,885.39 5,593.60 5,968,658.92 669,258.97 70° 19' 13.404 N 148° 3T 39.831 W', 8,740.79 7,907.33 5,573.73 5,968,680.42 669,238.62 70° 19' 13.620 N 148° 3T 40.410 W 8,741.01 7,926.76 5,552.51 5,968,699.38 669,216.99 70° 19' 13.811 N 148° 3T 41.029 W 8,740.57 7,945.38 5,528.49 5,968,717.47 669,192.57 70° 19' 13.994 N 148° 3T 41.729 W i, 8,740.41 7,964.15 5,504.37 5,968,735.71 669,168.05 70° 19' 14.179 N 148° 3T 42.433 W I, 8,741.54 7,984.41 5,482.75 5,968,755.48 669,145.99 70° 19' 14.378 N 148° 37' 43.063 W 8,743.23 8,009.76 5,461.13 5,968,780.36 669,123.83 70° 19' 14.628 N ° ' 148° 37' 43.694 W ° 8,743.65 8,036.45 5,443.69 5,968,806.66 669,105.81 14.891 N 70 19 3T 44.202 W 148 8,743.33 8,063.86 5,429.75 5,968,833.76 669,091.28 70° 19' 15.160 N 148° 3T 44.608 W''~, 8,742.87 8,100.67 5,415.71 5,968,870.25 669,076.44 70° 19' 15.522 N 148° 3T 45.017 W', 8,742.96 8,132.79 5,407.32 5,968,902.18 669,067.35 70° 19' 15.838 N 148° 3T 45.261 W' 8,745.68 8,174.78 5,397.17 5,968,943.94 669,056.29 70° 19' 16.251 N 148° 3T 45.557 W'. 8,747.77 8,205.68 5,387.43 5,968,974.61 669,045.88 70° 19' 16.555 N 148° 3T 45.840 W', 8,747.65 8,234.14 5,375.58 5,969,002.80 669,033.42 70° 19' 16.835 N 148° 3T 46.186 W'~ ~ 8,746.43 8,260.59 5,361.54 5,969,028.94 669,018.80 70° 19' 17.096 N I 148° 3T 46.595 W ~ 8,745.35 8,285.33 5,345.18 5,969,053.32 669,001.91 70° 19' 17.339 N 148° 3T 47.072 W ', 8,745.21 8,316.17 5,321.20 5,969,083.62 668,977.26 70° 19' 17.642 N 148° 3T 47.771 W'', 8,746.58 8,339.20 5,304.04 5,969,106.27 668,959.61 70° 19' 17.869 N 148° 3T 48.271 W' 8,749.47 8,366.33 5,287.73 5,969,133.04 668,942.71 70° 19' 18.136 N 148° 3T 48.747 W' 8,753.22 8,401.22 5,272.37 5,969,167.58 668,926.59 70° 19' 18.479 N 148° 37' 49.194 W 8,754.54 8,418.71 5,266.71 5,969,184.95 668,920.55 70° 19' 18.651 N 148° 37' 49.359 W 8,755.54 8,447.04 5,258.05 5,969,213.07 668,911.27 70° 19' 18.930 N 148° 37' 49.611 W 8/10/2009 10:29:09AM Page 3 COMPASS 2003.16 Build 71 swK~~ bP NYa11Ef Survey Report -Geographic ~INTEQ !Company: North America -ALASKA- BP Locat Co-ordinate Reference: Well G18 -Slot 18 'Project: Prudhoe Bay TVD Reference: Mean Sea Level Site: PB C Pad MD Reference: 20:18 4/25/1982 00:00 @ 66.80ft (generic drillinc Well: C-18 North Reference: True Welibare: C-18B Survey Calculation Method: Minimum Curvature Design: C-186 Database: EDM .16 - Anc Prod - WH24P 'Survey ~~~~ ~• ', Measured TVD Below Map Map Depth Inclination Azimuth System +NI~ +Ef W Northing Fasting. (ft) (°) ' (°) (ft) (~) (ft) (ft) (ft) Latitude Longitude :. 14,755.35 91.96 337.28 8,755.24 8,474.67 5,247.88 5,969,240.48 668,900.51 70° 19' 19.202 N 148° 3T 49.907 W'. 14,788.89 92.61 332.23 8,753.90 8,504.98 5,233.59 5,969,270.46 668,885.56 70° 19' 19.500 N 148° 3T 50.324 W' 14,818.65 92.61 327.59 8,752.54 8,530.69 5,218.69 5,969,295.84 668,870.11 70° 19' 19.753 N 148° 37' 50.758 W ', 14,847.21 92.08 322.45 8,751.37 8,554.06 5,202.33 5,969,318.85 668,853.25 70° 19' 19.983 N 148° 3T 51.235 W 'I 14,878.03 90.77 317.21 8,750.61 8,577.60 5,182.47 5,969,341.95 668,832.87 70° 19' 20.215 N 148° 3T 51.814 W 14,909.33 89.72 313.22 8,750.47 8,599.81 5,160.42 5,969,363.67 668,810.35 70° 19' 20.433 N 148° 37' 52.457 W i 14,939.47 88.80 308.37 8,750.86 8,619.49 5,137.61 5,969,382.85 668,787.12 70° 19' 20.627 N 148° 37' 53.122 W ~', 14,967.83 87.02 302.84 8,751.90 8,635.99 5,114.58 5,969,398.84 668,763.74 70° 19' 20.789 N 148° 3T 53.794 W 14,999.13 89.94 297.95 8,752.73 8,651.81 5,087.60 5,969,414.07 668,736.42 70° 19' 20.945 N 148° 37' 54.581 W 15,022.93 93.10 294.74 8,752.10 8,662.37 5,066.29 5,969,424.16 668,714.88 70° 19' 21.049 N 148° 3T 55.203 W 'i 15,089.00 93.10 294.74 8,748.52 8,689.98 5,006.37 5,969,450.45 668,654.38 70° 19' 21.321 N 148° 3T 56.951 W TD -- 8/10/2009 10:29:09AM Page 4 COMPASS 2003.16 Build 71 ~i%i~ MY M . O Es INTEQ Company: North America -ALASKA - BP Project: Prudhoe Bay Site: PB C Pad WeIL• C-18 Wellborer C-186 Design: C-18B Targets Target Name ' - hitlmiss target Dip Angle.- Dip Dir. ND -Shape (°) (°) (ft) Survey Report -Geographic by .Local Co-ordinate Reference: Well G18 -Slot 18 ND Reference: 'Mean Sea Level MD Reference: 20:18 4/25/1982 00:00 @ 66.80ft (generic drillinc North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM .16 - Anc Prod - WH24P +N/-S +E!-W Northing Fasting (~) (~) (~) (~) Latitude Longitude C-18B Fault 2 0.00 0.00 0.00 7,900.02 5,890.04 5,968,680.00 669,555.00 70° 19' 13.545 N 148° 37' 31.180 W - actual wellpath m isses target center by 8742.06ft at 13948.17ft MD (8738.14 TVD, 7794.45 N , 5650.54 E) - Polygon Point 1 0.00 7,900.02 5,890.04 5,968,680.00 669,555.00 Point 2 0.00 8,421.91 5,581.32 5,969,195.00 669,235.00 Point 3 0.00 8,664.16 5,481.57 5,969,435.00 669,130.00 Point 4 0.00 8,421.91 5,581.32 5,969,195.00 669,235.00 C-18B Target 3 0.00 0.00 8,780.00 7,880.15 5,654.53 5,968,655.00 669,320.00 70° 19' 13.352 N 148° 37' 38.053 W - actual wellpath m isses target center by 60.63ft at 14016.09ft MD (8740.24 ND, 7853.56 N, 5617.28 E) - Point C-186 Fault 4 0.00 0.00 0.00 8,681.91 4,896.78 5,969,440.00 668,545.00 70° 19' 21.242 N 148° 38' 0.150 W - actual wellpath m isses target center by 8749.21ft at 15089.OOft MD (8748.52 ND, 8689.98 N , 5006.37 E) - Polygon Point 1 0.00 8,681.91 4,896.78 5,969,440.00 668,545.00 Point 2 0.00 9,151.54 4,461.88 5,969,900.00 668,100.00 C-18B Target 1 0.00 0.00 8,755.00 7,056.93 5,331.49 5,967,825.00 669,015.00 70° 19' 5.258 N 148° 37' 47.497 W - actual wellpath m isses target center by 52.40ft at 13076.24ft MD (8754.48 ND, 7096.90 N, 5 297.60 E) - Point C-18B Polygon 0.00 0.00 0.00 7,141.90 5,563.41 5,967,915.00 669,245.00 70° 19' 6.092 N 148° 37' 40.728 W - actual wellpath m isses target center by 8747.27ft at 13258.01ft MD (8745.80 ND, 7224.92 N , 5425.82 E) - Polygon Point 1 0.00 7,141.90 5,563.41 5,967,915.00 669,245.00 Point 2 0.00 7,373.68 5,943.58 5,968,155.00 669,620.00 Point 3 0.00 8,486.14 5,387.66 5,969,255.00 669,040.00 Point 4 0.00 8,753.30 5,063.39 5,969,515.00 668,710.00 Point 5 0.00 8,665.06 4,981.44 5,969,425.00 668,630.00 Point 6 0.00 8,339.11 5,249.41 5,969,105.00 668,905.00 Point 7 0.00 7,703.22 5,510.63 5,968,475.00 669,180.00 Point 8 0.00 7,455.77 5,390.20 5,968,225.00 669,065.00 C-18B Target 4 0.00 0.00 8,790.00 8,259.44 5,462.74 5,969,030.00 669,120.00 70° 19' 17.084 N 148° 37' 43.641 W - actual wellpath misses target center by 99.23ft at 14469.84ft MD (8747.91 TVD, 8224.75 N, 5379.85 E) - Point C-18B Fault 3 0.00 0.00 0.00 8,735.25 5,203.04 5,969,500.00 668,850.00 70° 19' 21.765 N 148° 37' 51.211 W - actual wellpath misses target center by 8750.85ft at 15089.OOft MD (8748.52 TVD, 8689.98 N, 5006.37 E) - Polygon Point 1 0.00 8,735.25 5,203.04 5,969,500.00 668,850.00 Point 2 0.00 9,494.06 4,809.46 5,970,250.00 668,440.00 C-186 Target 5 0.00 0.00 8,810.00 8,841.12 4,935.26 5,969,600.00 668,580.00 70° 19' 22.808 N 148° 37' 59.024 W - actual wellpath misses target center by 177.99ft at 15089.OOft MD (8748.52 TVD, 8689.98 N, 5006.37 E) - Point C-18B Fault 1 0.00 0.00 0.00 6,800.44 5,625.99 5,967,575.00 669,315.00 70° 19' 2.733 N 148° 37' 38.909 W - actual wellpath misses target center by 8758.18ft at 13220.57ft MD (8746.1 2 ND, 7199.57 N, 5398.29 E) - Polygon Point 1 0.00 6,800.44 5,625.99 5,967,575.00 669,315.00 Point 2 0.00 7,128.98 5,468.10 5,967,900.00 669,150.00 Point 3 0.00 7,705.43 5,180.58 5,968,470.00 668,850.00 Point4 0.00 7,128.98 5,468.10 5,967,900.00 669,150.00 C-18B Target 2 0.00 0.00 8,755.00 7,464.12 5,695.48 5,968,240.00 669,370.00 70° 19' 9.260 N 148° 37' 36.867 W - actual wellpath misses target center by 26.11ft at 13615.06ft MD (8746.88 TVD, 7472.42 N, 5672.09 E) - Point 8/10/2009 10:29:09AM Page 5 COMPASS 2003.16 Build 71 aw~R MYaMif ~ Survey Report -Geographic IN'I'EQ Company: North America -ALASKA - B P Local Co-ordinate Reference: Well G18 - Slot 18 Project: Prudhoe Bay TVD Reference: Mean Sea Level Site:. PB C Pad MD Reference: 20:18 4/25!1982 00:00 @ 66.80ft (generic drillinc WeIL• C-18 North Reference: True Wellbore: C-18B Survey Calculation Method:. Minimum C urvature Design: C-186 Database: EDM .16 - Anc Prod - WH24P_ Targets Target Name - hitlmiss target Dip Angle. Dip`Dir. TVD +NI-S +E!-W Northing Fasting , -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude C-18B Fault 2 0.00 0.00 0.00 7,900.02 5,890.04 5,968,680.00 669,555.00 70° 19' 13.545 N 148° 37' 31.180 W - actual wellpath misses target center by 8742.06ft at 13948.17ft MD (8738.14 TVD, 7794.45 N, 5650.54 E) - Polygon Point 1 0.00 7,900.02 5,890.04 5,968,680.00 669,555.00 Point 2 0.00 8,421.91 5,581.32 5,969,195.00 669,235.00 Point 3 0.00 8,664.16 5,481.57 5,969,435.00 669,130.00 Point 4 0.00 8,421.91 5,581.32 5,969,195.00 669,235.00 C-18B Target 3 0.00 0.00 8,780.00 7,880.15 5,654.53 5,968,655.00 669,320.00 70° 19' 13.352 N 148° 37' 38.053 W - actual wellpath misses target center by 60.63ft at 14016.09ft MD (8740.24 TVD, 7853.56 N, 56 17.28 E) - Point C-186 Fault 4 0.00 0.00 0.00 8,681.91 4,896.78 5,969,440.00 668,545.00 70° 19' 21.242 N 148° 38' 0.150 W - actual wellpath misses target center by 8749.21ft at 15089.OOft MD (8748.52 TVD, 8689.98 N, 5006.37 E) - Polygon Point 1 0.00 8,681.91 4,896.78 5,969,440.00 668,545.00 Point 2 0.00 9,151.54 4,461.88 5,969,900.00 668,100.00 C-186 Target 1 0.00 0.00 8,755.00 7,056.93 5,331.49 5,967,825.00 669,015.00 70° 19' 5.258 N 148° 37' 47.497 W - actual wellpath misses target center by 52.40ft at 13076.24ft MD (8754.48 TVD, 7096.90 N, 52 97.60 E) - Point C-188 Polygon 0.00 0.00 0.00 7,141.90 5,563.41 5,967,915.00 669,245.00 70° 19' 6.092 N 148° 37' 40.728 W - actual wellpath misses target center by 8747.27ft at 13258.01ft MD (8745.80 TVD, 7224.92 N, 5425.82 E) - Polygon Point 1 0.00 7,141.90 5,563.41 5,967,915.00 669,245.00 Point 2 0.00 7,373.68 5,943.58 5,968,155.00 669,620.00 Point 3 0.00 8,486.14 5,387.66 5,969,255.00 669,040.00 Point 4 0.00 8,753.30 5,063.39 5,969,515.00 668,710.00 Point 5 0.00 8,665.06 4,981.44 5,969,425.00 668,630.00 Point 6 0.00 8,339.11 5,249.41 5,969,105.00 668,905.00 Point 7 0.00 7,703.22 5,510.63 5,968,475.00 669,180.00 Point 8 0.00 7,455.77 5,390.20 5,968,225.00 669,065.00 C-186 Target 4 0.00 0.00 8,790.00 8,259.44 5,462.74 5,969,030.00 669,120.00 70° 19' 17.084 N 148° 37' 43.641 W - actual wellpath misses target center by 99.23ft at 14469.84ft MD (8747.91 TVD, 8224.75 N, 5379.85 E) - Point C-18B Fault 3 0.00 0.00 0.00 8,735.25 5,203.04 5,969,500.00 668,850.00 70° 19' 21.765 N 148° 37' 51.211 W - actual wellpath misses target center by 8750.85ft at 15089.OOft MD (8748.52 TVD, 8689.98 N, 5006.37 E) - Polygon Point 1 0.00 8,735.25 5,203.04 5,969,500.00 668,850.00 Point 2 0.00 9,494.06 4,809.46 5,970,250.00 668,440.00 C-186 Target 5 0.00 0.00 8,810.00 8,841.12 4,935.26 5,969,600.00 668,580.00 70° 19' 22.808 N 148° 37' 59.024 W - actual wellpath misses target center by 177.99ft at 15089.OOft MD (8748.52 TVD, 8689.98 N, 5006.37 E) - Point C-18B Fault 1 0.00 0.00 0.00 6,800.44 5,625.99 5,967,575.00 669,315.00 70° 19' 2.733 N 148° 37' 38.909 W - actual wellpath misses target center by 8758.18ft at 13220.57ft MD (8746.12 TVD, 7199.57 N, 5398.29 E) - Polygon Point 1 0.00 6,800.44 5,625.99 5,967,575.00 669,315.00 Point 2 0.00 7,128.98 5,468.10 5,967,900.00 669,150.00 Point 3 0.00 7,705.43 5,180.58 5,968,470.00 668,850.00 Point 4 0.00 7,128.98 5,468.10 5,967,900.00 669,150.00 C-18B Target 2 0.00 0.00 8,755.00 7,464.12 5,695.48 5,968,240.00 669,370.00 70° 19' 9.260 N 148° 37' 36.867 W - actual wellpath misses target center by 26.11ft at 13615.06ft MD (8746.88 TVD, 7472.42 N, 5672.09 E) - Point Casing Points... 8/10/2009 10:29:09AM Page 6 COMPASS 2003.16 Build 71 ~~~ BAKER IIY~iNEf Survey Report -Geographic by 'INTEQ Company: North America -ALASKA - B P Locaf Co-ordinate Reference: Well G18 -Slot 18 Project: Prudhoe Bay TVD Refeirence Mean Sea Level Site: PB C Pad MD Reference: 20:18 4/25/1982 00:00 @ 66. 80ft (generic drillinc Well: C-18 North Reference: True Wellbore: C-18B Survey Calculation Method: Minimum Curvature Design: C-186 Database: EDM .16 - Anc Prod - WH24P Targets Target Name - hitJmiss target Dip Angle Dip Dir. TVD +NJ~ +E/-W Northing Fasting -Shape (°) (°) (ft) (ft) (ft) (ft) (~) Latitude Longitude C-186 Fault 2 0.00 0.00 0.00 7,900.02 5,890.04 5,968,680.00 669,555.00 70° 19' 13.545 N 148° 37' 31.180 W - actual wellpath misses target center by 8742.06ft at 13948.17ft MD (8738.14 TVD, 7794.45 N, 5650.54 E) - Polygon Point 1 0.00 7,900.02 5,890.04 5,968,680.00 669,555.00 Point 2 0.00 8,421.91 5,581.32 5,969,195.00 669,235.00 Point 3 0.00 8,664.16 5,481.57 5,969,435.00 669,130.00 Point 4 0.00 8,421.91 5,581.32 5,969,195.00 669,235.00 C-186 Target 3 0.00 0.00 8,780.00 7,880.15 5,654.53 5,968,655.00 669,320.00 70° 19' 13.352 N 148° 37' 38.053 W - actual wellpath misses target center by 60.63ft at 14016.09ft MD (8740.24 TVD, 7853.56 N, 56 17.28 E) - Point C-18B Fault 4 0.00 0.00 0.00 8,681.91 4,896.78 5,969,440.00 668,545.00 70° 19' 21.242 N 148° 38' 0.150 W - actual wellpath misses target center by 8749.21ft at 15089.OOft MD (8748.52 TVD, 8689.98 N, 5006.37 E) - Polygon Point 1 0.00 8,681.91 4,896.78 5,969,440.00 668,545.00 Point 2 0.00 9,151.54 4,461.88 5,969,900.00 668,100.00 C-186 Target 1 0.00 0.00 8,755.00 7,056.93 5,331.49 5,967,825.00 669,015.00 70° 19' 5.258 N 148° 37' 47.497 W - actual wellpath misses target center by 52.40ft at 13076.24ft MD (8754.48 TVD, 7096.90 N, 5297.60 E) - Point C-18B Polygon 0.00 0.00 0.00 7,141.90 5,563.41 5,967,915.00 669,245.00 70° 19' 6.092 N 148° 37' 40.728 W - actual wellpath misses target center by 8747.27ft at 13258.01ft MD (8745.80 TVD, 7224.92 N, 5425.82 E) - Polygon Point 1 0.00 7,141.90 5,563.41 5,967,915.00 669,245.00 Point 2 0.00 7,373.68 5,943.58 5,968,155.00 669,620.00 Point 3 0.00 8,486.14 5,387.66 5,969,255.00 669,040.00 Point 4 0.00 8,753.30 5,063.39 5,969,515.00 668,710.00 Point 5 0.00 8,665.06 4,981.44 5,969,425.00 668,630.00 Point 6 0.00 8,339.11 5,249.41 5,969,105.00 668,905.00 Point 7 0.00 7,703.22 5,510.63 5,968,475.00 669,180.00 Point 8 0.00 7,455.77 5,390.20 5,968,225.00 669,065.00 C-18B Target 4 0.00 0.00 8,790.00 8,259.44 5,462.74 5,969,030.00 669,120.00 70° 19' 17.084 N 148° 37' 43.641 W - actual wellpath misses target center by 99.23ft at 14469.84ft MD (8747.91 TVD, 8224.75 N, 5379.85 E) - Point C-18B Fault 3 0.00 0.00 0.00 8,735.25 5,203.04 5,969,500.00 668,850.00 70° 19' 21.765 N 148° 37' 51.211 W - actual wellpath misses target center by 8750.85ft at 15089.OOft MD (8748.52 TVD, 8689.98 N, 5006.37 E) - Polygon Point 1 0.00 8,735.25 5,203.04 5,969,500.00 668,850.00 Point 2 0.00 9,494.06 4,809.46 5,970,250.00 668,440.00 C-18B Target 5 0.00 0.00 8,810.00 8,841.12 4,935.26 5,969,600.00 668,580.00 70° 19' 22.808 N 148° 37' 59.024 W - actual wellpath misses target center by 177.99ft at 15089.OOft MD (8748.52 TVD, 8689.98 N, 5006.37 E) - Point C-18B Fault 1 0.00 0.00 0.00 6,800.44 5,625.99 5,967,575.00 669,315.00 70° 19' 2.733 N 148° 37' 38.909 W - actual wellpath misses target center by 8758.18ft at 13220.57ft MD (8746.12 TVD, 7199.57 N, 5398.29 E) - Polygon Point 1 0.00 6,800.44 5,625.99 5,967,575.00 669,315.00 Point 2 0.00 7,128.98 5,468.10 5,967,900.00 669,150.00 Point 3 0.00 7,705.43 5,180.58 5,968,470.00 668,850.00 Point 4 0.00 7,128.98 5,468.10 5,967,900.00 669,150.00 C-18B Target 2 0.00 0.00 8,755.00 7,464.12 5,695.48 5,968,240.00 669,370.00 70° 19' 9.260 N 148° 37' 36.867 W - actual wellpath misses target center by 26.11ft at 13615.06ft MD (8746.88 TVD, 7472.42 N, 5672.09 E) - Point Measured Vertical,. C asing Hole Depth Depth, Diameter Diameter (~) (ff) Name fin) (in) 8!10/2009 10:29:09AM Page 7 COMPASS 2003.16 Build 71 • ~ii~ eAt;tR NYONtf ~ Survey Report -Geographic ~~ INTEQ Company: North America -ALASKA - B P Local Co-ordinate Reference: Well G18 -Slot 18 :Project: Prudhoe Bay TVD Reference: '' Mean Sea Level °Site: PB C Pad MD Reference: 20:18 4/25/1982 00:00 @ 66.80ft (generic drillinc Welk C-18 North Reference: True Wetlbore: C-18B Survey :Calculation Method: ,-.Minimum Curvature Design:: C-186 Database: EDM .16 - Anc Prod - WH24P Targets Target Name - hit/miss target "Dip Angle bip Dir. TVD +N/-S +E/-W _ Northing Fasting '. -Shape (°1 (°) (ff) {~) (~) (~) (~) Latitude Longitude C-186 Fault 2 0.00 0.00 0.00 7,900.02 5,890.04 5,968,680.00 669,555.00 70° 19' 13.545 N 148° 37' 31.180 W - actual wellpath misses target center by 8742.O6ft at 13948.17ft MD (8738.14 TVD, 7794.45 N, 5650.54 E) - Polygon Point 1 0.00 7,900.02 5,890.04 5,968,680.00 669,555.00 Point 2 0.00 8,421.91 5,581.32 5,969,195.00 669,235.00 Point 3 0.00 8,664.16 5,481.57 5,969,435.00 669,130.00 Point 4 0.00 8,421.91 5,581.32 5,969,195.00 669,235.00 C-186 Target 3 0.00 0.00 8,780.00 7,880.15 5,654.53 5,968,655.00 669,320.00 70° 19' 13.352 N 148° 37' 38.053 W - actual wellpath misses target center by 60.63ft at 14016.09ft MD (8740.24 TVD, 7853.56 N, 56 17.28 E) - Point C-186 Fault 4 0.00 0.00 0.00 8,681.91 4,896.78 5,969,440.00 668,545.00 70° 19' 21.242 N 148° 38' 0.150 W - actual wellpath misses target center by 8749.21ft at 15089.OOft MD (8748.52 TVD, 8689.98 N, 5006.37 E) - Polygon Point 1 0.00 8,681.91 4,896.78 5,969,440.00 668,545.00 Point 2 0.00 9,151.54 4,461.88 5,969,900.00 668,100.00 C-18B Target 1 0.00 0.00 8,755.00 7,056.93 5,331.49 5,967,825.00 669,015.00 70° 19' 5.258 N 148° 37' 47.497 W - actual wellpath misses target center by 52.40ft at 13076.24ft MD (8754.48 TVD, 7096.90 N, 5297.60 E) - Point C-18B Polygon 0.00 0.00 0.00 7,141.90 5,563.41 5,967,915.00 669,245.00 70° 19' 6.092 N 148° 37' 40.728 W - actual wellpath misses target center by 8747.27ft at 13258.01ft MD (8745.80 TVD, 7224.92 N, 5425.82 E) - Polygon Point 1 0.00 7,141.90 5,563.41 5,967,915.00 669,245.00 Point 2 0.00 7,373.68 5,943.58 5,968,155.00 669,620.00 Point 3 0.00 8,486.14 5,387.66 5,969,255.00 669,040.00 Point 4 0.00 8,753.30 5,063.39 5,969,515.00 668,710.00 Point 5 0.00 8,665.06 4,981.44 5,969,425.00 668,630.00 Point 6 0.00 8,339.11 5,249.41 5,969,105.00 668,905.00 Point 7 0.00 7,703.22 5,510.63 5,968,475.00 669,180.00 Point 8 0.00 7,455.77 5,390.20 5,968,225.00 669,065.00 C-186 Target 4 0.00 0.00 8,790.00 8,259.44 5,462.74 5,969,030.00 669,120.00 70° 19' 17.084 N 148° 37' 43.641 W - actual wellpath misses target center by 99.23ft at 14469.84ft MD (8747.91 TVD, 8224.75 N, 5379.85 E) - Point C-18B Fault 3 0.00 0.00 0.00 8,735.25 5,203.04 5,969,500.00 668,850.00 70° 19' 21.765 N 148° 37' 51.211 W - actual wellpath misses target center by 8750.85ft at 15089.OOft MD (8748.52 TVD, 8689.98 N, 5006.37 E) - Polygon Point 1 0.00 8,735.25 5,203.04 5,969,500.00 668,850.00 Point 2 0.00 9,494.06 4,809.46 5,970,250.00 668,440.00 C-18B Target 5 0.00 0.00 8,810.00 8,841.12 4,935.26 5,969,600.00 668,580.00 70° 19' 22.808 N 148° 37' 59.024 W - actual wellpath misses target center by 177.99ft at 15089.OOft MD (8748.52 TVD, 8689.98 N, 5006.37 E) - Point C-18B Fault 1 0.00 0.00 0.00 6,800.44 5,625.99 5,967,575.00 669,315.00 70° 19' 2.733 N 148° 37' 38.909 W - actual wellpath misses target center by 8758.18ft at 13220.57ft MD (8746.12 TVD, 7199.57 N, 5398.29 E) - Polygon Point 1 0.00 6,800.44 5,625.99 5,967,575.00 669,315.00 Point 2 0.00 7,128.98 5,468.10 5,967,900.00 669,150.00 Point 3 0.00 7,705.43 5,180.58 5,968,470.00 668,850.00 Point4 0.00 7,128.98 5,468.10 5,967,900.00 669,150.00 C-18B Target 2 0.00 0.00 8,755.00 7,464.12 5,695.48 5,968,240.00 669,370.00 70° 19' 9.260 N 148° 37' 36.867 W - actual wellpath misses target center by 26.11ft at 13615.06ft MD (8746.88 TVD, 7472.42 N, 5672.09 E) - Point - - __ 2,927.00 2,593.49 13 3/8" 13.375 17.500 12,070.00 8,196.39 9 5/8" 9.625 12.250 8/10/2009 10:29:09AM Page 8 COMPASS 2003.16 Build 71 ~^ • eA NYdN~s Survey Report -Geographic by INTEQ Company: North America -ALASKA - BP Local Co-ordinate Reference: 'Well G18 -Slot 18 Project: Prudhoe Bay TVD Reference:. Mean Sea Level Site: PB C Pad MD Reference: 20 ' 18 4/25/1982 00:00 @ 66.80ft (generic drillinc WeN C-18 North Reference: True Wellbore: C-186 ..Survey Calculation Method: Minimum Curvature Design: C-186 Database: EDM .16 - Anc Prod - WH24P .Design Annotations Measured Vertical Local Coordinates Depth Depth. +N/~° +E1-W (ft) (ft) (~? (~l Comment 13,060.37 8,754.30 7,086.89 5,285.29 TIP 13,070.00 8,754.46 7,092.99 5,292.75 KOP 15,089.00 8,748.52 8,689.98 5,006.37 TD Checked By: Approved By: Date: 8/10/2009 10:29:09AM Page 9 COMPASS 2003.16 Build 71 TREE _ - 6" CIW WELLHEAD= MCEVOY ACTUATOR = OTIS KB. ELEV = _ 66.83' BF. ELEV = 34.43' KOP = 900' Max Angle = 97 ~ 13131' Datum MD = 12813` Datum TV D = 8700' SS S NOT : W L> 7fl° `(290{}` D i` .,®,,, HORlZO 13028'. ® ~, ~ ~w 13-3/8" CSG, 72#, L-$0-BTRS, ID = 12.347" H 2927' Minimum ID = .3 '" x°1585" EL T Prole 5-1/2" TBG, 17#, L80-MOD-BTRS, 11487 .0232 bpf, ID = 4.892" IT' BOT LNR HGR ~ 17550 3.70" BKR LNR DEPLOY T SLV, ID = 2.30" 11580' TOP 3-1 /2" X 3-3116°' X 2-7f8" LNR 11 ~ 0° 41 /2" TBG, 12.6 #, L-80, .0152 bpf, ID = 3.958" 11637 9-5/8" CSG, 47#, L-80-BTRS, ID = 8.681" ~-I 12070 TOC ~ 12240" 4-112" x 7"whipstock RA tag 12289' Cut 2-718" liner 12 ' PERFORATION SlA1ANARY REF LOG: Baker Hughes teq GR & MPR 08/0$/2009 ANGLE AT TOP PERF: 90° ~ 13255' Note: Refer to Roduction DB for historical perf data SQE SPF INTERVAL Opn/Sqz DATE 2" 6 13255-13275 O 08111109 2" 6 13300-13350 O 08{11109 2" 6 13370-13390 O 08111109 2" 6 13485-13525 O 08/11109 2" 6 13780-13870 O 08111709 2" 6 14040-14060 O 08t11/09 2" 6 14175-14200 O 08{11!09 2" 6 14210-14265 O 08{11109 2" 6 14280-14390 O 08111109 2" 6 14485-14570 O 0$111109 2" 6 14630-14740 O 08111 /09 2" 6 14835-14910 O 08111/09 2" 6 14955-15015 O 08/11 /09 7" LNR, 26#, L-80, u4S, ID = 6.276" 12947 2364' --~ 5-1 /2" OTIS SSSV N, ID = 4.562" 2829' ~~9-5/8" DV PKR 11479 --I5-1 /2" OTIS XA SLIDING SLV, ID = 4.562" 11487 5-1/2" TBG SEAL ASSY 11506" 9-518" X 41 /2" BOT PKR, ID = 4.750" 11561' ~-14-1/2" OTIS X NIP, ID = 3.813" (BE}iIND PIPS 11592' 41 /2" Ol1S XN NIP, MILLED ID = 3.80" (BEHIND 11638 41 /2" WLEG (BEHIND PIPE) "('~ T 3-if2" LNR. 32#. L-8t1, STL, ID = 3.0" -3 4 f .. 13313° 3-311 &" LNR w t turbos, 6.2#, L 80; TC-II, ID 2.80" 13324' 2-7{8" 10' marker joint, 6=1 , L-80, STL f `'~°R PBTD 15059' w ~~.o~ti~.~ ~~ - ~ _--~.~~un,~ __ _ _~ -~ ~, 2-718°' LNR w'turbos, 6.16#, L-8t}, STL, ID = 2.44" c 2-7/8" LNR, 6.16#, L80, .0058 bpf, ID = 2.372" ~- j 14451' DATE REV BY COMMENTS DATE REV BY COMMENTS 45/23/82 ORIGINAL COMPLETION 41/28/00 CT SIDETRACK 07/29/01 CH/KAK CORRECTIONS 08/12/09 NORDICI CTDSIDETRACK(C-18B) 08/13/09 TLH DRLG HO CORRECTIONS PRUDHOE BAY UNIT WELL: G1 SB PERMfr No: 209071 API No: 50-029-20785-02 SEC 19, T71 N, R14E, 554' SNL & 1521' WEL BP Exploration (Alaska) ALASKA OIL A1~TD GA5 CO1~T5ERQA'I'IO1~T COM1~II55IO1~T Mr. John McMullen Engineering Team Leader BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU C-18B BP Exploration (Alaska) Inc. Permit No: 209-071 Surface Location: 554' FNL, 1521' FEL, Sec. 19, T11N, R14E, UM Bottomhole Location: 2845' FSL, 3582' FWL, Sec. 08, T11N, R14E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely 1 ~ Dan T. Seamount 'J" Chair DATED this ~ day of July, 2009 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI~N PERMIT TO DRILL 20 AAC 25.005 ~~.~~ ~~ 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is proposed for: ^Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU C-18B 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 15100' TVD 8813'ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: ' ' 7. Property Designation: ADL 028305 & 028304 Oil Pool FEL, SEC. 19, T11 N, R14E, UM 554 FNL, 1521 Top of Productive Horizon: R14E UM 3656' FWL SEC 08 T11 N 934' FSL 8. Land Use Permit: 13. Approximate Spud Date: July 26, 2009 , , , , , . Total Depth: 2845' FSL, 3582' FWL, SEC. 08, T11N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 17,570' 4b. Location of Well (State Base Plane Coordinates): Surface: x-663839 y-5960654 Zone-ASP4 10. KB Elevation (Height above GL): 66.83' feet 15. Distance to Nearest Well Within Pool: 126' 16. Deviated Wells: Kickoff Depth: 12310 feet Maximum Hole An le: 90 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3150 Surface: 2273 1 asin Pr r m: ifi i ns T - in be h - B m uan i of em ` .f. r s Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 4-1 /8" ~~n'. X 3~~s" 8.81 # / 6.2# L-80 STL / TCII 3550' 1155 ' 7820'ss 15100' 881 'ss 202 cu X 2a~s' / 4.7# 4 a I a~ ~o 1 g, PRESE NT WELL CONDITION S UMMARY (To be completed for Redrill and Re-entry Operation Total Depth MD (ft): 12895' Total Depth TVD (ft): 7 Plugs (measured): 13000' Effective Depth MD (ft): 14390' Effective Depth TVD (ft): Junk (measured): 8833' 13563' Casing Length- Size Cement Volume MD TVD Conductor /Structural 1 20" x 8 d n r a 110' 1' Surface 2927' 13-3/8" 4582 cu ft Ar icset I I 2 27' 2660' Intermediate 1207 ' 9-5/8" 1620 cu ft I s 'G' 186 ft Arai a 12070' 8263' Pr i n Liner 1 53' 7" 56 cu ft I ss'G' 11550' - 12603' 7886' - 8673' Lin r 28 2-7/8" 135 cu ft CI ss'G' 11583' - 14451' 7910' - 0' Perforation Depth MD (ft): 12950' - 12980' Perforation Depth TVD (ft): 8806' - 8809' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that th or of is u nd correct. Contact Ron Phillips, 564-5913 Printed Name Jo f e ~~' Title Engineering Team Leader Prepared By NameMumber: Si nature'"~ ~ ~ Phone 564-4711 Date ~ / 0 Terrie Hubble, 564-4628 ~` Commission Use Onl Permit To Drill Number: m?O9~ API Number: 50-029-20785-02-00 Permit Ap r a See cover letter for p her re uir ments Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce Coalbed methane, gas hydrates, or gas contained shales: ,_,/ 3Sb0~;s~ ~`tY.r-~'~E~~ Samples Req'd: ^ Yes ~No Mud Log Req'd: ,^_,/Yes lies No a ~~~~ ~~~~ ~~ ~~~~~~ ~~ HZS Measures: Yes ^ No Directional Survey Req'd: t,1Q Yes ^ No Other: v~ APPROVED BY THE COMMISSION Date ,COMMISSIONER Form 'f~-401 Revised 12%2005 Submit In Duplicate ~.~~`~,~~~~ G • C-18B - Coiled Tubing Dr'RFng To: Tom Maunder Petroleum Engineer ~.Jp Alaska Oil & Gas Conservation Commission ~-J From: Mel Rixse CTD Engineer Date: June 29, 2009 Re: C-18B Application for Permit to Drill Request CTD Drill and Complete C-186 program: Spud July 26. 2009 Pre-Rig Operations 1. O MIT-OA - 2000 psi Passed 03/09/2009 DONE 2. O MIT-IA - 3000 psi Passed 03/09/2009 DONE 3. O PPPOT-IC, AC-LDS 4. E Set 2-7/8" CIBP at 12,400'MD. Pressure test tubing to 3000 psi. 5. E Run SCMT/ CCL to assure TOC location behind 2-7/8" liner is at or below 12,340' ELMD and to obtain jewelry location in tubing tail below 11,506'MD. 6. E Jet cut 2-7/8" liner at 12,340' MD 7. O PT tree (MV,SV,WV), function LDS 8. O Bleed gas lift and production flowlines down to zero and blind flange 9. O Remove S-Riser, Remove wellhouse, level pad Rig Sidetrack Operations: (Scheduled to begin on July 26, 2009) 1. NU 7-1/16" CT Drilling BOPE and test to 250 psi low and 3500 psi high 2. Pull BPV. 3. Pull 2-7/8" liner that was jet cut at 12340'MD. 4. Drift for 4-1/2" X 7" Baker whipstock. 5 Set 4-1/2" X 7" whipstock ~12 310' ELM 6. Mill 3.80" window at 12,310'. 7. Drill build/turn section with 4.25" bicenter bit, and land well. 8. Drill lateral section to 15,100' MD w/ resistivity log. 9. Run 3-1/2"x 3-3/16"x 2-7/8" solid liner w/cementralizers to TD. Place liner top at 11,550' MD 10. Cement liner from TD to 12,200` MD with 36 bbls of 15.8ppb cement. 11. Clean out liner/Run MCNVGR/CCL log. 12. Test liner lap to 2000 psi. 13. Perforate per geologist. 14. Set liner top packer (if fails liner lap test) 15. Freeze protect well to 2500' with methanol. 16. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 17. RDMO Nordic 1. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. RU test separator, flow test well ~~4 ~~M`~ June 29, 2009 • C-18B - Coiled Tubing D~ng Mud Program: • Well kill: 8.6 ppg brine • Milling/drilling: 8.6 ppg Geovis or biozan for milling, GeoVis for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 4-1/8" Casing Program: • 3-1/2", 8.81 #, L-80, STL connection solid liner - 11,555'MD - 11,595' MD w/ liner top packer. • 3-3/16", 6.2#, L-80, STL TC-II connection solid liner - 11,595'MD - 13,300' MD. • 2-7/8", 4.7# , L-80, STL connection Solid liner - 13,300'MD - 15,100' MD. • A minimum of 36 bbls 15.8 ppg cement will be used for liner cementing. (TOC 12,200'MD) Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off- will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Maximum planned hole angle is 90 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property line - 17,570' NW Anticollision Summary • E-31 A 126' ctr-ctr, Status: Producing • E-31 - 325' ctr-ctr, Status: Abandoned • 15-18A - 580' ctr-ctr, Status: Producing • E-19A - 799' ctr-ctr. Status: Abandoned • 15-18 - 1073' ctr-ctr. Status: Abandoned Logging • MWD directional, Gamma Ray, and Resistivity will be run over all of the open hole section. • A cased hole GR/CCL/CNL log will be run. Hazards • The maximum recorded H2S level on C Pad is 25 ppm on C-39A (04-16-2007). C Pad is not an H2S pad. • Lost circulation risk is low. No fault crossings are expected. Reservoir Pressure • Res. press. is estimated to be 3,150 psi at 8,765'ss (6.9 ppg EMW). Maximum surface pressure with gas (0.10 psi/ft) to surface is 2273 psi. Mel Rixse CTD Engineer June 29, 2009 • C-18B - Coiled Tubing Drl~Fng = 6' CM1 1NE1LHfiAD= MCEVOY ACTUATOR = OTIS KB. EiEV = 88.63' BF. ELEV = 34.43' KOP= 900' Max Angk = i5 ®13998' Datum MD = NIA Datum TVD = 8800' S5 13318' CSG, 72i, L-80• BTRS, ID = 12.647' 2927' Minimum ID = 2.372" ~ 11588' TOP OF 2-718" LINER 5-112' TBG, 17f, L80-MOD-BTRS, 11487 .0262 bpf, ID = 4.892' C -18A g~ NOTES: WELL > 70° ~ 12741' AND GOES HORIZONTAL ~ 13332'. 2364' 5-1/2' OTIS SSSVN, D = 4.582 3.75' BKR LNR DEPLOYMENT SLV, ID = 3.00' H 11583' TOP OF 2-718' LNR D = 2.372' 11589' 41/2" TBG, 12.8 *, L-80, .0152 bpf, ID = 3.958' 11637' 9-518' CSG.474. L-80-BTRS. ID=8.881' PERFORATION SUMMARY Rff LOG SWSMEMDRY CNL CN 012X00 ANGLEATTOPPERF: 82 ®12950' Note: Refer to Produetan DB for historical pert data S¢E 5PF I;`fTERVAL OpnlSgz DATE 2' 8 12950 -12980 O 121D91D2 2' 8 12925 -12955 O 05125105 2' 8 13020-13050 C 05!25!05 2' 8 13054 - 13084 C 0525N5 2' 4 13130-13221 C 01f03A1 2' 4 13250-13370 C 01103101 ??? 4 13580 - 13832 C 02101 AO ??? 4 13870 - 13781 C 02/01A0 ??? 4 13810 - 13830 C 02101A0 ??? 4 14020-14050 C 02101A0 ??? 4 14090- 14150 C 02/01100 ??? 4 14180 -14250 C 02/011D0 I 12947' I DV PKR 11479' H 5-12' OTB XA SLIDNG SLV, ID = 4.582' 11487' 5-1/2' TBG SEAL ASSY 11506' 9-5/8' X 4 12' BOT PKR ID = 4.750' 11561' - {4112'OTISX NP, ID=6.816' ~ 11592' 412' OTIS XN NP, MILLED TO 5.80' ID 11638' 412' YVI.EG 11602' ELMD TT LOG NOT AVAILABLE ~ ' ~ 7' MLLOUT WNOOW 12803'-12809' TOP OF WiIPSTOCK ®1 2800' RA TAG ®12810' BKR 2-118' HYD Disconnected 5 TCP Fring Head, SWS 2' ~ Pert GUna, Feh Length 445' DATE RE/ BY COMMBVTS DATE REV BY COMMBdTS OSf27192 ORIGINAL COMPLETION 0525A5 t1Yf5/PJC PERFS 01129100 CT SIDETRACK 11115A8 OOB/TLH PERF CORRECTIONS (2000) 0729!01 CWKAK CORRECTONS 10A7A8 RLMRLH CBPSET(OBIIDAB) 12/D9/02 JBMlIIh ADD PERFS 09/15/05 CMO/TLP DATUMMD/TVDCORRECTKIN 08/08/04 RYIKAK TOP OFCEMENi PRUDHOE BAY UNR WaL: G18A PERMR No: 1991290 API No: 50.029-20785-D1 SEC 19, T11N, R14E 554' SNL d~ 1521'tAlEl BA t3rploratlon (Alaska) June 29, 2009 C-186 - Coiled Tubing Drlfring HEAD= 8' aw MCEVOY ~ - SAFETY NOTES: WELL > 70° ~ 72741' AND IATOR = 016 LEV = 88.83' Proposed CTD Sidetrack ~~ HORIZONTAL ~ 13332'. _EV = 34.43' - 900' Ingle = 35 ®13998' 2364' 5-112' OTIS SSSVN, D = 4.582" ~MD= WA ® ~TVD = 8800' SS 9-518' DV P1CR Minimum ID = 2.30" ~ 11555' TOP OF 3-3M6" LINER 5.1/2' TBG, 17f, L80-MOD-BTRS, 11481 .0232 bpf, ID = 4.892' 3.70' BKR LNR DEPLOYMBYT SLV, D = 2.30' TOP 11 R' X 3.3/18' X 2-T1B' LP 4112' TBC, 12.8 tF, L-80, .0152 bpf, D= 3.85 11637' 9-518' CSG, 47tR, L-80-BTRS, ID = 8.881' I 120 TOC 1 4712' x 7' w hipstock r,+ z~nr r.,.. PERFORATION SUMMARY Rff LOG SWS-MEMORY CNL ON 0127ro0 ANGLEATTOP R3iF: 82 ®12950' Note: Refer to Production DB for hiatorieal pert data S2E SPF NTERVAL Opn/So~ DATE 2' 8 12950 - 12980 O 12ro9ro2 Z' 8 12925 - 12955 O OSr15ro5 Z' 8 13020 -13050 C 05125ro5 2' 8 13054 - 13084 C 05125ro5 2' 4 13130-13221 C 01ro3ro1 2' 4 13250 -13370 C 01ro3ro1 ??? 4 13580-13832 C 02ro1ro0 ??? 4 13870- 13781 C 02ro7ro0 'n? 4 13810- 13830 C 02ro1ro0 ??? 4 14020 -14050 C 02ro1ro0 ??? 4 14090-14150 C 02ro1ro0 ??? a 14190-1azsD c ozrolroo ~ 11479' H 5-7R' 076 XA SLIDNG SLV, D= 4.582' 17487' 5-1n• TBG SEAL ASSY 11506' 9_5/8' X 4 7 R' BOT PKR, ID = 4.750' 1540' Baksr KB LTP D = 2.375' 11581' 4112' OTIS X NP, ID = 3.873' 11592' 412' OTIS XN NIP. MLLED TO 3.80' ID 11838' 4t2' WLEG 11502' ELMD TT LOG NOT AVALABLE TSGR 12070' 151 ~' 13!18' X 2.719' crrt'sd and parf~d 133D0 XO pgTp 15050' 7" MLLOUT WINDOW 12603'-12604' roa of W+~iPSro~K a 1z6DD' DATE REV BY COMMENTS DATE REV BY COMMB~TS 05/23182 ORIGINAL COMPLETION 05!25!05 WTSIPJC PERFS 01128100 CT SIDETRACK 11/15108 OOB/TLH PERF CORRECTK7N5 2000 07/29101 CHA(AK CORRECTIONS 10/07108 RLMITLH CBPSEf(09l10ro8) 12/09102 JBMRh ADD PERFS 08!08109 MSE PROPOSED CTD SDETRACK 09/15103 CMOfTLP DATUM MDRVD CORRECTION 08ro81D4 RYlKAK TOP OF CEMB+IT PRUOF70E BAY UNIT WELL C-188 PERMIT No: AR No: 50-029-2078502 St3; 19, T11N, R74E, 554' SNL & 1521' t9P Brpbration (Alaska) June 29, 2009 ~la~ Baker Hughes INTEQ Planning Report by INTEQ Company: North America -ALASKA - BP Local Co-ordinate Reference: Well C-18 -Slot 18 Project: Prudhoe Bay TVD Reference: Mean Sea Level Site: PB C Pad MD Reference: 20:18 4/25/1982 00:00 @ 66.80ft (generic drillinc Well: C-18 North Reference: True Wellbore: Plan 4, C-188 Survey Calculation Method: Minimum Curvature Design: Plan #4 Database: EDM .16 - Anc Prod - WH24P Survey Tool Program Date 6/11/2009 From To (ft) (ft) Survey (Wellbore) Tool Name 100.00 12,300.00 1 : Sperry-Sun BOSS gyro multi (C-18) BOSS-GYRO 12,300.00 15,100.00 Plan #4 (PIan 4, C-186) BLIND Planned Survey MD Inc Azi TVDSS N/S (ft) (°) (°) (ft) (ft) 12,300.00 39.75 44.60 8,372.35 6,697.04 TIP 12,310.00 39.74 44.54 8,380.04 6,701.59 KOP 12,330.00 41.54 44.54 8,395.22 6,710.88 End of 9 Deg/100' DLS 12,380.00 47.54 44.54 8,430.84 6,735.86 4 12,400.00 47.59 47.79 8,444.34 6,746.08 12,500.00 49.17 63.73 8,511.00 6,787.78 12,600.00 52.79 78.48 8,574.16 6,812.57 12,604.00 52.98 79.03 8,576.57 6,813.19 5 12,700.00 53.84 64.71 8,633.99 6,837.12 12,763.00 55.32 55.61 8,670.55 6,862.65 6 12,800.00 59.76 55.61 8,690.40 6,880.28 12,900.00 71.76 55.61 8,731.39 6,931.69 13,000.00 83.76 55.61 8,752.56 6,986.79 13,052.04 90.00 55.61 8,755.40 7,016.12 7 13,100.00 90.00 49.85 8,755.40 7,045.16 Description Sperry-S un BOSS gyro multishot Blind drill ing E/W Northing Easting DLeg V. Sec TFace ~i (ft) (ft) (ft) (°/100ft) (ft) (°) 4,811.37 5,967,453.87 668,502.89 0.00 7,090.89 0.00 4,815.86 5,967,458.53 668,507.27 0.40 7,095.82 -104.63 4,824.99 5,967,468.01 668,516.20 9.00 7,105.87 0.00 4,849.58 5,967,493.52 668,540.24 12.00 7,132.90 0.00 4,860.23 5,967,503.97 668,550.66 12.00 7,144.01 90.00 4,921.72 5,967,546.99 668,611.22 12.00 7,190.90 87.81 4,994.93 5,967,573.37 668,683.87 12.00 7,221.98 77.18 4,998.06 5,967,574.06 668,686.98 12.00 7,222.88 67.8 5,070.97 5,967,599.57 668,759.35 12.00 7,253.07 -90.00 5,115.40 5,967,626.07 668,803.21 12.00 7,282.37 -81.43 5,141.15 5,967,644.25 668,828.58 12.00 7,302.18 0.00 5,216.26 5,967,697.28 668,902.54 12.00 7,359.94 0.00 5,296.75 5,967,754.12 668,981.80 12.00 7,421.84 0.00 5,339.61 5,967,784.38 669,024.01 12.00 7,454.80 0.00 5,377.76 5,967,814.23 669,061.52 12.00 7,487.05 -90.00 6/12/2009 3:39:57PM Page 3 COMPASS 2003.16 Build 70 ~.r Baker Hughes INTEQ Planni ng Report bP INTEQ Company: North America -ALASKA - BP Local Co-ordinate Reference: Well C-18 -Slot 18 Project: Prudhoe Bay TVD Reference: Mean Sea Level Site: PB C Pad MD Reference: 20:18 4/25/1982 00:00 @ 66.80ft (generic drillinc Well: C-18 North Reference: True Wellbore: Plan 4, C-1$B Survey Calculation Method: Minimum Curvature Design: Plan #4 Database: EDM .16 - Anc Prod - WH24P Planned Survey MD Inc Azi TVDSS N/S E/W Northing Easting DLeg V. Sec TFace (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) (°) 13,152.04 90.00 43.61 5,755.40 7,080.81 5,415.63 5,967,850.70 669,098.60 12.00 7,525.87 -90.00 8 ) 13,200.00 90.00 49.36 8,755.40 7,113.82 5,450.40 5,967,884.46 669,132.64 12.00 7,561.78 90.00 13,272.04 90.00 58.01 8,755.40 7,156.44 5,508.39 5,967,928.33 669,189.68 12.00 7,609.29 90.00 9 13,300.00 90.00 54.65 8,755.40 7,171.94 5,531.66 5,967,944.33 669,212.60 1.2.00 7,626.76 -90.00 13,400.00 90.00 42.65 8,755.40 7,237.88 5,606.60 5,968,011.89 669,286.08 12.00 7,698.98 -90.00 13,500.00 90.00 30.65 8,755.40 7,317.96 5,666.18 5,968,093.24 669,343.90 12.00 7,783.95 -90.00 13,572.04 90.00 22.01 8,755.40 7,382.46 5,698.11 5,968,158.42 669,374.41 12.00 7,850.99 -90.00 10 13,600.00 90.00 18.65 8,755.40 7,408.68 5,707.82 5,968,184.84 669,383.55 12.00 7,877.96 -90.00 13,672.04 90.00 10.01 8,755.40 7,478.41 5,725.63 5,968,254.94 669,399.83 12.00 7,948.97 -90.00 11 13,700.00 86.64 10.01 8,756.21 7,505.93 5,730.49 5,968,282.56 669,404.09 12.00 7,976.81 -180.00 13,704.04 86.16 10.01 8,756.47 7,509.90 5,731.19 5,968,286.54 669,404.70 12.00 7,980.83 180.00 12 13,800.00 86.24 358.47 8,762.85 7,605.22 5,738.25 5,968,381.99 669,409.69 12.00 8,076.41 -90.0 13,900.00 86.48 346.45 8,769.23 7,703.98 5,725.17 5,968,480.43 669,394.46 12.00 8,173.64 -89.23 14,000.00 86.88 334.43 8,775.04 7,797.87 5,691.81 5,968,573.56 669,359.06 12.00 8,264.27 -88.47 14,004.04 86.89 333.95 8,775.26 7,801.50 5,690.05 5,968,577.15 669,357.22 12.00 8,267.74 -87.77 i 13 14,100.00 86.96 322.41 8,780.43 7,882.79 5,639.62 5,968,657.32 669,305.03 12.00 8,344.32 -90.00 14,104.04 86.96 321.93 8,780.64 7,885.97 5,637.14 5,968,660.45 669,302.49 12.00 8,347.27 -89.38 14 14,200.00 89.20 333.23 8,783.86 7,966.80 5,585.82 5,968,740.13 669,249.42 12.00 8,423.32 79.00 14,204.04 89.30 333.71 8,783.91 7,970.41 5,584.02 5,968,743.70 669,247.53 12.00 8,426.76 78.62 15 14,300.00 89.31 322.19 8,785.08 8,051.60 5,533.18 5,968,823.76 669,194.94 12.00 8,503.21 -90.00 6/12/2009 3:39:57PM Page 4 COMPASS 2003.16 Build 70 ~a~ R s Baker Hughes INTEQ Planni ng Report bP INTEQ Company: North America -ALASKA - BP Local Co-ordinate Reference: Well C-18 -Slot 18 Project: Prudhoe Bay TVD Reference: Mean Sea Level Site: PB C Pad MD Reference: 20:18 4/25/1982 00:00 @ 66.80ft (generic drillinc Well: C-18 North Reference: True Wellbore: Plan 4, C-186 Survey Calculat ion Method: Minimum Curvature Design: Plan #4 Database: EDM .16 - Anc Prod - WH24P Planned Survey MD Inc Azi TVDSS N/S E/W Northing Easting DLeg V. Sec TFace (ftl (°) (°) (~) (ft) (ft) (ft) (ft) (°/100ft) (ft) (°) 14,304.04 89.31 321.71 8,785.13 8,054.78 5,530.69 5,968,826.88 669,192.39 12.00 8,506.16 -89.86 16 14,400.00 89.13 333.22 8,786.43 8,135.54 5,479.17 5,968,906.49 669,139.12 12.00 8,582.12 91.00 14,500.00 88.97 345.22 8,788.10 8,228.85 5,443.77 5,968,999.01 669,101.69 12.00 8,671.99 90.84 14,504.04 88.97 345.71 8,788.17 8,232.76 5,442.75 5,969,002.89 669,100.59 12.00 8,675.80 90.64 17 14,600.00 88.39 334.20 8,790.39 8,322.73 5,409.92 5,969,092.12 669,065.82 12.00 8,762.57 -93.00 14,700.00 87.86 322.21 8,793.68 8,407.53 5,357.36 5,969,175.74 669,011.42 12.00 8,842.46 -92.73 14,754.04 87.61 315.72 8,795.82 8,448.23 5,321.93 5,969,215.66 668,975.11 12.00 8,879.92 -92.34 ~~ 18 14,800.00 87.33 310.21 8,797.85 8,479.52 5,288.35 5,969,246.21 668,940.86 12.00 8,908.16 -93.00 14,874.04 86.94 301.32 8,801.56 8,522.69 5,228.41 5,969,288.06 668,879.99 12.00 8,945.95 -92.76 I, 19 14,900.00 86.94 304.44 8,802.95 8,536.77 5,206.64 5,969,301.66 668,857.92 12.00 8,958.07 90.00 i 15,000.00 87.04 316.46 8,808.22 8,601.44 5,130.79 5,969,364.65 668,780.69 12.00 9,015.88 89.83 15,100.00 87.27 328.47 8,813.20 8,680.49 5,070.05 5,969,442.36 668,718.25 12.00 9,089.34 89.20 TD at 15100.00 ' 6/12/2009 3:39:57PM Page 5 COMPASS 2003.16 Build 70 by [ Project: Prudhoe Ba , AzimuMS ro rn.e Nonh Ma rieGC rmnn: zz se WELLBORE DETAILS: Plan 4, C-188 REFERENCE INFORMATION y Site: PB C Pad g Magnetic Field Parent Wellbore: C-18 CoaNinate (NIE) Reference. Wel C-18 - Sbt 18, Tme North We!B: C-11{ SaengN' Srr11.9en TIe On MD: 12300 00 V¢rtlral (TVD) Reference: Mean Sea Level Wellbore: Plan 4, C-188 Dlp Mgle. 6x92 . Sectbn VS Reference: Slot - 18 O.OON, 0.00E I 1 ( ) Plan: Plan #4 (C-18IPIen 4, C-18B) lMm: 6111120 Modal. ~~ Measured Depth Reference' 20:18 4/2511982 00:00 @ 66.80fl (generic ddlYng rig) Calculation Method: Minimum Curvature WELL DETAILS: C-18 cro~nd Leer o 00 «w-s ~e1-w No-1r~~y ezsr,y taut~ce ~o~~~y~rae smt 0.00 0 00 55~Jb5/ OJ o6S&39 00 /'1 1 /' S5 872 N 1~8 ° ~ 23.'J63 W 18 SECTION DETAILS ANNOTATIONS Sec MD Inc Azi ssTVD +W-S +EI-W DLeg TFace VSec Target Annotation 1 12300.00 39.75 44.60 8372.35 6697.04 4811.37 0.00 0.00 7090.89 TIP 2 12310.00 39.74 44.54 8380.04 6701.59 4815.86 0.40 •104.63 7095.82 KOP 3 12330.00 41.54 44.54 8395.22 6710.88 4824.99 9.00 0.00 7105.87 End of 9 Deg1100' DLS 4 12380.00 47.54 44.54 8430.84 6735.86 4849.58 12.00 0.00 7132.90 4 5 12604.00 52.98 79.03 8576.57 6813.19 4996.06 12.00 90.00 7222.88 5 6 12763.00 55.32 55.61 8670.55 6862.65 5115.40 12.00 270.00 7282.37 6 7 13052.04 90.00 55.61 8755.40 7016.12 5339.61 12.00 0.00 7454.80 7 8 13152.04 90.00 43.61 8755.40 7080.81 5415.63 12.00 270.00 7525.87 8 9 13272.04 90.00 58.01 8755.40 7156.44 5506.39 12.00 90.00 7609.29 9 10 13572.04 90.00 22.01 8755.40 7382.46 5698.11 12.00 270.00 7650.99 10 11 13672.04 90.00 10.01 8755.40 7478.41 5725.63 12.00 270.00 7948.97 11 12 13704.04 86.16 10.01 8756.47 7509.90 5731.19 12.00 180.00 7980.83 12 13 14004.04 86.89 333.95 8775.26 7801.50 5690.05 12.00 270.00 8267.74 13 14 14104.04 86.96 321.93 8780.64 7885.97 5637.14 12.00 270.00 8347.27 14 15 14204.04 89.30 333.71 8783.91 7970.41 5584.02 12.00 79.00 8426.76 15 16 14304.04 89.31 321.71 8785.13 8054.78 5530.69 12.00 270.00 8506.16 16 17 14504.04 88.97 345.71 8788.17 8232.76 5442.75 12.00 91.00 8675.80 17 18 14754.04 87.61 315.72 6795.82 8448.23 5321.93 12.00 267.00 8879.92 18 19 14874.04 86.94 301.32 8801.56 8522.69 5228.41 12.00 267.00 8945.95 19 20 15100.00 87.27 328.47 8813.20 8680.49 5070.05 12.00 90.00 9069.34 TD at 15100.00 Cam. t~F. 0. N Q U .~ E-' Meal ~~ar BAKtR ~~~~Ill~lfe 9000 __.. +._ 1 Fyel_~ -___ ___. 8800 - 8600 C-18B Target 4 8400 18 -- 8200 --- C-1 BTar et 3 t 7 8000 -- 16 - 78W - - 1 3 I d 76 W C-1 B Ta et 1 1 2- - -I8B Tar et 2 74W t 72W --- --- - E°~' - - ~ ~ to 70W - of 9- ~ I I ~~ t 9 68W -- KOP _ l 7 I 6600 - 4 64W -- 62 W C I8/C- I A 60 W w 0 0 i. O z 0 3800 4000 4200 44W 46W 4800 5000 5200 5400 5600 5800 bOW 62W 6400 6600 6800 70W 7200 7400 wP~tr_vFa~rr+~ r~nn fri~n~ - . 3385 _ _ K '- P End f 9 De 1 W' LS 845 - 4 6515 - - 858 8645 - ~ C-1 - Tar t 1 C-186 Tar et 2 - 871 _ -- ~, - ~ C-1 BTar et 3 -188 arget n ' C-I8 Targe 5 -- - - -- 8775 C-18/ -18A ~~ 7 8 9 1 ll 13 14 1 6 17 18 r/ 884U - - TD t ISl .W 8905 ' ----- 897 9035 ~~ ve • /VriJ /IJU /.IJ /.bU /S4J /41U /4/J /JYU /VUJ /U/U //JJ /ifUV IoUJ /YJV /YYJ eUOV e1GJ eIYU DL]J oJLU oJeJ ifvJU oJIJ oJOU oUYJ O/IU O//J ooYU eYUJ oY/U >UJJ >rw >r VJ >LJU >G>J >JUU >vGJ >v>U >JJJ >UGU Vertical Section at 5.00° (65 ft/in) Isw~oi ~ u u~sa~a Company: North America -ALASKA - BP Project: Prudhoe Bay Reference Site: PB C Pad Site Error: O.OOft Reference Well: C-18 Well Error: O.OOft Reference Wellbore Plan 4, C-18B Reference Design: Plan #4 Travelling Cylinder Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well G18 -Slot 18 Mean Sea Level 20:18 4/25/1982 00:00 @ 66.80ft (generic drilling rig) ;: True Minimum Curvature 1.00 sigma EDM .16 - Anc Prod - WH24P Offset Datum teference Plan #4 ~ilter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refers nterpolation Method: MD Interval 25.OOft Error Model: ISCWSA )epth Range: 12,300.00 to 15,100.OOft Scan Method: Trav. Cylinder North tesults Limited by: Maximum center-center distance of 1,706.62ft Error Surtace: Elliptical Conic __ _ - ~i Survey Tool Program Date 6/11/2009 --- - From To (ft) (ft) Survey (Wellbore) Tool Name Description 100.00 12,300.00 1 : Sperry-Sun BOSS gyro multi (C-18) BOSS-GYRO Sperry-Sun BOSS gyro multishot 12,300.00 15,100.00 Plan #4 (Plan 4, C-186) BLIND Blind drilling ~~ __ Casing Points -- Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 'I 2,927.00 2,593.49 13 3/8" 13.375 17.500 12,070.00 8,196.39 9 5/8" 9.625 12.250 15,100.00 8,813.20 3 3/16" 3.188 4.125 Site Name Offset Well -Wellbore -Design PB C Pad C-18 - C-18 - C-18 C-18 - C-18A - C-18A C-20 - C-20 - C-20 C-20 - C-206 - C-206 C-33 - C-33 - C-33 C-33 - C-33PB1 - C-33P61 PBDS15 15-18 - 15-18 - 15-18 15-18 - 15-18A - 15-18A 15-21 A - 15-21 A - 15-21 A PB E Pad E-19 - E-19A - E-19A E-31 - E-31 - E-31 E-31 - E-31 A- E-31 A E-31 - E-31 A - E-31 wp25 PB K Pad K-05 - K-05C - K-05C K-05 - K-05C -Plan #11 Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Depth Depth Distance (ft) from Plan (ft) (ft) (ft) (ft) 12,325.00 12,325.00 0.18 4.62 -1.77 FAIL -Major Risk 12,325.00 12,325.00 0.18 4.62 -1.77 FAIL -Major Risk Out of range Out of range Out of range Out of range 13,573.80 13,562.00 1,073.14 1,802.86 -729.59 FAIL -Major Risk 13,411.97 14,187.00 580.35 1,684.24 -1.,103.68 FAIL -Major Risk 13,825.00 13,925.00 1,457.56 1,415.92 45.22 Pass -Major Risk 12,460.87 13,448.00 15,092.74 13,075.00 13,800.87 14,550.00 13,764.17 14,600.00 798.52 1,598.55 -720.98 FAIL -Major Risk 325.31 2,369.94 -2,011.12 FAIL -Major Risk 126.07 1,592.69 -1,381.87 FAIL -Major Risk 160.40 1,648.03 -1,432.63 FAIL -Major Risk 14,814.39 11,325.00 1,636.23 1,076.20 924.35 Pass -Major Risk 14,814.52 11,375.00 1,679.24 1,076.77 966.76 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 6/12/2009 11:43:05AM Page 2 of 21 COMPASS 2003.16 Build 70 • C-186 - Coiled Tubing Drl'Ring are ser i _~ BAG 7 1/16" 5000 psi. Blind/Shears m P cross 2 3/8" combi ram/slips Mud Cross variable bore pipe 31/2"-2 318" 2 3/8" combi ram/slips Swab Valve Flow Tee TOTs 7 1/16" 5000psi Mud Cross 7 1/16" 5000psi TOTs 7 1/16" 5000psi June 29, 2009 Alaska Department of Natural~ources Land Administration System • Page 1 of,~~ Alaska Mapper Land Records/Status Plats Recorder's Search State Cabins Natural Resources ~~ Alaska DNR Case Summary File Type: ADL File Number: 28304 ~ Printable Case File Summary See Township, Range, Section and Acreage? New Search ~ Yes ~ No LAS Menu ~ Case Abstract ~ Case Detail ~ Land Abstract . _, File: ADL 28304 +,~~F' Se_arch for Status Plat Updates As of 07/09/2009 Customer.• 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Tlpc: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/14/1965 Total Acs°es: 2469.000 Date Initiated: 05/28/1965 Office of Prinia~y Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED Meridian: U Township: O11N Range: 014E Section: OS Section Acres: 640 Search Plats Meg°idian: U Township: 011N Range: 014E Sectioi~~: 06 Section Acres: 593 Meridian: U Township: O11N Range: 014E Section: 07 Section Acres: 596 Meridian: U Township: O11N Range: 014E Section: 08 Section Acres: 640 Legal Description OS-28-1965 ***S.ALE NOTICE LEGAL DESCRIPTION*** C14-125 11 N 14E UM 5, 6, 7, 8 2469.00 U- 3- 7 End of Case Summary Last updated on 07109/2009. http://dnr. alaska.gov/proj ects/las/Case_Summaiy.cfin?FileType=ADL&FileNumber=28304... 7/9/2009 Alaska Department of Naturalsources Land Administration System ~~~ ~ Alaska Mapper Land Records/Status Plats Recorder's Search State Cabins Natural Resources ~~ Alaska DNR Case Summary File Type: ADL File Number: 28305 ~ Printable Case File Summary See Township, Range, Section and Acreage? New Search C) Yes ~~~ No LAS Menu ~ Case Abstract ~ Case Detail ~ Land Abstract _~, File: ADL 28305 '''~~' Search for Statu_s_Plat Updates As of 07/09/2009 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: 7s4 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Cuse Status: 35 ISSUED Stati~rs Date: 08/19/1965 Total Acres: 2480.000 Date Initiated: 05/28/1965 Office of Prima~~% Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED Meridian: U Township: O11N Range: 014E Section: 17 Section Acres: 640 Search Plats Meridian: U Township: O11N Range: 014E Section: 18 Section Acres: 599 Meridian: U Township: O11N Range: 014E Section: 19 Section Acres: 601 Meridian: U Township: O11N Range: 014E Section: 20 Section Acres: 640 Legal Description OS-28-1965 *** SALE NOTICE LEGAL DESCRIPTION*** C14-12611 N 14E UM 17,18,19, 20 2480.00 U- 3- 7 End of Case Summary Last updated on 07/0912009. http://dnr.alaska.gov/projects/las/CaseSummary.cfin?FileType=ADL&FileNumbei=28305... 7/9/2009 TRANSMITTAL LETTER CHECKLIST WELL NAME ~.U ~ ~ f~~ PTD# ~~~~~1 Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: T-'.e~/Lr~/~~' ..C~~il~ POOL: ~,P!/D.~O~ ~~~ ©/G Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. , API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception, assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and ] 0' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed. and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: I / I 1 /2008 WELL. PERMIT.CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL •840150 Web Name: PRUDHOE BAY UNIT C-18B Program DEV Well bore sag ^ PTD#:2090710 Company BP EXPLORATION (ALASKAI INC Initial ClasslType DEV I PEND GeoArea 890 Unit 11850 On10ff Shore. -Qn Annular Disposal ^ Administration 1 Peonitfee.attached--------- ----------------------------------- NA__... ..--------- --------- ------ ---------------------- --------...- --- 2 i.easenurot~appropriaie----- ----------------------------------- Yes-- -- -- ------- ---------- ------ ------------------------------------ .. 3 Uniquawellrrameandnumber------------------------ ------------ - Y~---.. .--------- -------•---•-.......---------------------------- -------... 4 IrtleJl~catedinadefinedpool-----------------•----------- --------.. Yes_..-- -------------- - ---------------------- - ------------ ----------- ----~ 5 WellJocatedProperdistancefmmdrUlingunftboundary------------- ----------- Y~----- -----.....---- --- ---------- ------------------------------------ -- 6 WeJilocatedprcpeCdistans;aflQmGthel'hells------------------------------- Yes.---- -----------------...---------...-------------------------------------- 7 Sufficierltacre~geavailableindriUiogunit--------•------------------------ Yes..--. -----.......---.-------._..__...---------------.----.---.------------. 6 Jfdekiated,iSwelU~replatincJUded.----------•------------------------ Y~-•--- ----.....---------------..._...--------------------------------------- 9 0-peratorcnly affactedparty---• -------------•------....:..--------- Y~----- -----------------..._..... --------------------------•---------------- 10 Operatorhasappropdatebondin.force--.------.----.-------•-•----.... Yes....- --6lanket.8-and#6194193------------------------------------------------------- 11 permitcarlbe.Iasu~rykhoUtS~onBerYationoldel .............•---..._..------ Y~----- ------------------••---•---------------------------------------~----•- Appr Date 12 Permit-cer1 be-issued N1Rheut adroigistrative approval . . . . . . . . . . . ...... . .. . . .. . . . Yea _ .... ....... - ................................ _ ......... - - - - - - - - - - - - - - - . - _ - - 13 Can permitbaapproYedJ~eforal5•dayoYalt-------------------------------- Yes---•- -------------------------..._........-----•------------...- --------- ACS 71912009 14 Well lo~atedn~ithln.areaandatrataautbedzadl~lN~tlon.Qrder#(Pskip#in.ccmmer>ts)(Forsenc NA ----- -- - - - - - - - - - - - - - - - - - - • - - - - - - . - - - - - - - - - - - - - - - • - 15 All wellswithln914milaareaoJre~tewldentiBad.(Feraervlcavr~lenly) .....:........... .NA•-•--- -----------•----•-•--....,......----.----.-------.--.----------.----•- 16 Pre•produced-ir>)ector;.durationolpr~.produ~tipn lessthan3mantha(F9r-se[vlcewelionly~ .. - - NA - - - - - - - - - - - - - - --- ~ , .................. - - - - - - . - - • . • - - . - - . - - - - - - - - - - - - ..... _ . _ 17 honcanven..gasconforroatoAS31,~i.03Q(yt.A),0.2A-D)_...-------• ............ .NA....-- ----------------- -- ---.......-----------•----------------.....----- 18 Conduct~:€tdngp[oxided-------------------•---------------------- .NA.---- --Candu~tortatlnC•f@U62-Q491•..------...-----------•-------------------•------ Engineering 19 Su[faceS~asingpCOte9t$allknownUSOW$-------------------------------- -NA----- .-Allaquitets-e~mpted,AEQ1,---.....----------.-----•-----.-----......-. 20 CMTv91-adequate to-clroulak@on.corldVOtorBSurf_cSg------------------------- -NA..... ..SUrfacecasipgaet in C-18,.----.---------.--_.•----•----------....._.....---- 21 CMT-v9l-adequate to tle•inlong.stringtosudcsg----------------------------- -NA--•-- -.Prgd~lctioncaeing-set.inC-16•------.---....----.-----•-------------------------- 22 CMT.willcovelallknownProductlveh4-itvns------------------------------- Yes.---- -•---•----------...----------...-----•-----•-----------.........------ 23 CesiOgdesiggs-adequatBfotG.T,J9.i~petmafro9t-----------------------••--- Yes..--• -----------------•----------.....----------•----------...-•----------- 24 Adequate tankage or.r@seNe plt . - - ..... • .. • - - - - - .. • -- - - - - - - - - - - - - - - - - Yes . _ ... .. Rlg equipped vrkh ske~pita..No-reserve pit Planned, All waste to approved disposal well(s),.......... - . - - . - 25 If.ere•ddll,haeal4.4Q3 for.abandonmentbeenapproYed--•-• ................... Yes..... ..-226...---------•---•- ---•------------------•-------------------- 26 Adequate wellbore separation.propoaed . . . .. . .. . . . .... . . . . . . . . . . .... . • . - - Yes - - - - - - - Proximity.anaysisperformed, Close approaches identified. Nearest segmentP~Aportlon-of 0~1QA,- - - .. - - - .. - 27 ifdlvederregUir-ed,-does.U.meetragulalions.-----• ......................... NA_.... ..80Pstadc.will-aln~dybein place.....--------------.----.--.•..----.------------- Appr Date 28 D~Uingfluid.prog[am.achematic S equlp.liet adequate . ... . .... . ... . . • - - - - • . - • - - Yes. - • - . - - - Maximim expected fomlaUoh.preasure 6,8 EMW, MV11 planned 9.S ppg. • .. - . _ • .. • . - .. - - - - - - - - - - • - - TEM 711012009 ~ 69PEs,dotheymeetregu~tion----------------------•--------...... Yes.---- --- --------•--•------------------------•-•----------- -------------- 30 J30PJ:-press ratigg.appropriate~te~ to-(put pslg ~ s~roroents) . - - - - • . . . . . . ......... Yes ... - - - - MASP calculated at.22I3. psi. 350Q Psi 60P testplanned...... - .. - - - - - - ..... - - - .......... _ . _ 31 Chokemanifald.ccmpl~ewfAPIRP•53(May$4)-----------•-------------- -- Yes.---- -----------------------------------------•----------------•--------... 32 WorkwiUoccx~r.wRb4uiGperatiQnshutdown----------•--------------------- YSS----- --------------------.....-------•-----------------------------•----- 33 J& Presence of H2S, gab Probable . . . . ........ . ... . ... • - - - - - - - - .. - ...... Yes - . - - - - - H2S i$ reported at.C Pad, Mud should preclude-H2S on rig.. Rig has_sens9ra aadalarms. - - - - _ - _ _ .... - - _ _ - 34 McChanical s~ndition of wells within AOR VarlPad (Ear serYice yreA 90~} . . ............ . . .NA- - - . - - - . - - - - . - _ ...... _ ..... - ............ _ _ .... - . - . - - - - - . - - • - - - - - - - - ..... _ .. . 35 Permit can be.issued wlo hydrogen sutfxle m~sures - - - - - - - - - - - - - • - - - - - - - - - - . _ .No, - . - - - - - Maxlevel_H23 on Cpad was_25ppm onn~eh ¢-39A (4J16l071• ..... _ • _ _ • . - _ .. - - - _ . - . _ .. - . - _ - - . _ Geology 36 AakapreeeMedoDP4tentialoverPres;~rsZones------------- -------- •--- - -~----- --------------..------------------•----•------------------------------ Appr Date 37 Selamicanalyaisofshallowgaszon~----------------------- ----------- -HA------ --------- ...--------------------------------------- -------------,- ACS 71912009 38 Seabedc~znd~ionsurvey.(tfoff•6ho[e)----------------------------------- -MA._.... -----------..........._.------------------------------ ----------- --- 39 Cogtaetnaroe/Phone.forvteeldy_Pregrese[epcrts~exPlerat9ryallyl------------------- Yes...-- --Ron_Philhpe~66.4513.------..-----•-----------•--------.-------............ Geologic Engineering Commissioner: Date: C issioner: Date m ' oner Date • • iNelt History File APPENDIX Information of detailed nature that is not CJ particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the fife under APPENDIX. No special effort has been made to chronologically organize this category of information. • tapescan.txt **** REEL HEADER **** MWD 09/10/29 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 09/08/08 2711512 O1 3" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las version information VERS. 1.20: OWLS log ASCII Standard -VERSION 1.20 WRAP. NO: one line per frame well Information Block #MNEM.UNIT Data Type Information STRT.FT 12095.5000: Starting Depth STOP.FT 15085.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent value COMP. COMPANY: BP Exploration (Alaskd), InC. WELL. WELL: C-18B FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 17' 55.872"N 148 deg 40' 23.063"w CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 08 Aug 2009 API API NUMBER: 500292078502 Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 19 TOWN.N T11N RANG. R14E PDAT. MSL EPD .F 0 LMF DF FAPD.F 66.83 DMF DF EKB .F 0 EDF .F 66.83 EGL .F 0 CASE.F N/A OS1 DIRECTIONAL Remarks Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True vertical Depths (TVDSS) are subsea corrected. (4) All Formation Evaluation data is realtime data. Page 1 ~ ~g -D~ ( ~~ ~ ~-~ • 2009 tapescan.txt (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well.. <6) Tools ran in the string included casing Collar Locator, an Electrical Disconnect and circulating Sub, a Drilling Performance sub (Inner and outer Downhole Pressure, vibration and Downhole weight on Bit), a Directional and Gamma Sub, and a Hydraulic orienting sub with a Near Bit Inclination Sensor. (7) Data presented here is final and has been depth ad]]'usted to a Primary Depth Control (PDC) log provided by schlumberger GR CNL dated 09 Aug per Adam van Holland with BP Exploration (Alaska), Inc. (8) The sidetrack was drilled from c-18 through a milled window in a 7 inch liner. Top of window 12284 ft.MD (8360.0 ft.TVDSS) Bottom of window 12292 ft.MD (8366.1 ft.TVDSS) (9) Tied to C-18 at 12279 feet MD (8356.2 feet TVDSS). (10) Baker Hughes INTEQ run 5 and 6 were used to drill C-186P61. (11) The interval from 15040 feet to 15089 feet MD (8751.2 feet to 8748.5 feet TVDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) RoPwG -> Rate of Penetration, feet/hour RACLX -> Resistivity (AT)(LS)400kHZ-Compensated Borehole Corrected (OHMM) RACHX -> Resistivity (AT)(LS)2MHz-Compensated Borehole Corrected (OHMM) RPCLX -> Resistivity (PD)(LS)400kHz-Compensated Borehole corrected (OHMM) RPCHX -> Resistivity (PD)(LS)2MHZ-Compensated Borehole Corrected (OHMM) TvDSS -> True vertical Depth (subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 12115.3, 12114.9, ! -0.359375 12118.5, 12117.6, ! -0.896484 12122.8, 12122.7, ! -0.178711 12125.3, 12126.4, ! 1.07715 12130.7, 12131.1, ! 0.358398 12137.7, 12137.5, ! -0.178711 12142.4, 12142.9, ! 0.538086 12146, 12 145.4, ! -0.538086 12152.3, 12152.8, ! 0.538086 12156.9, 12156.9, ! 0 12158.2, 12158, ! -0.179688 12159.2, 12159, ! -0.179688 12162.8, 12162.1, ! -0.717773 12164.9, 12164.8, ! -0.178711 12167.1, 12167.1, ! 0 12170.9, 12170, ! -0.897461 12175.9, 12175.3, ! -0.539062 12179.1, 12179.1, ! 0 12180.9, 12180.4, ! -0.538086 12188.6, 12189.2, ! 0.538086 12191.3, 12190.8, ! -0.539062 12194.2, 12193.6, ! -0.538086 12201.5, 12201.7, ! 0.179688 12208, 12207.6, ! -0.358398 12210, 12209.6, ! -0.358398 12213.9, 12213.6, ! -0.359375 12218.8, 12218.6, ! -0.179688. 12225.7, 12226.2, ! 0.538086 12249.9, 12250.6, ! 0.716797 12269.7, 12270.2, ! 0.538086 12288.4, 12288.4, ! 0 12289.2, 12290, ! 0.717773 12291.4, 12292.5, ! 1.07617 12299.2, 12299.6, ! 0.359375 12303.9, 12303.2, ! -0.717773 12313.2, 12314.5, ! 1.25586 12324.2, 12325.1, ! 0.896484 12328.1, 12328.7, ! 0.539062 12331.4, 12332.4, ! 1.07715 12347, 12347, ! 0 12350.9, 12351.1, ! 0.179688 12355.4, 12356.3, ! 0.897461 Page 2 a6~d 60TL8'Z f9fL6'I ZffSI'Z ZTOL8'Z LSbfb'T 56f6L'T T9bL68'0 0 0 LT9L0'T- SiLLO'T- 8896LT'0 9855Z'T 0 L6L9TL'0 b8b968'0 86£85£ '0 SSSfb'i 0 bf ZSI' Z 56f6L'i fOZff'Z SSSfb'i LSbfb'T SSSfb'T 6b6ZZ'f- 9950f ' b- 6Z9b6' f - SiLLO'T Z906f5'0- LT9L0'T- 8896LT'0- 8896Li'0 9808f5'0- TTL8Li'0- ITL8LT'0 LT9L0'T- 8896Li'0 9855Z'T- 86f85f'0 fLLLiL'0- 9808f5'0 86£85 £ ' 0 8896LT'0 9808£5'0 fLLLTL'0 8896LT'0 0 86f85f'0- fLLLTL'0- Z906f5'0- £LLLTL'0- TTL8LT'0 8896LT'0- 8896LT'0 fLLLTL'0- IIL8LT'0 SLf65f'0- iIL8Li'0 8896LT'0 9808£ 5 ' 0 0 fLLLTL'0- SLf65f '0 Li9L0'T 8896LT'0- 86f85f'0 fLLLTL'0 88bSZ'I 9808£5'0 ~x~•u~asad~~ `Z'IfOfT `f'BZOfT i `bZOfi `ZZOfT `Z'866Zi `T'966ZT '8'T66Zi `6'886Zi i `696ZT `S'L96ZT i 'L96ZT `Z'S96ZT `Z'096Zi `f'656ZT `L'S56Zi `L'S56ZI `f'Z56ZT `f'Z56ZI i `6'8b6Zi `056Zi i `6'bb6ZT `9b6Zi i 'Z'Lf6Zi `Lf6ZT `b'bf6Zi `T'ff6ZT `8'9Z6Zi `8'9Z6ZI `9'8T6ZT `6'LT6Zi `b'906Zi `S'S06ZT `9'Z06ZT `f'Z06ZT `Z'668ZT `8'L68Zi `f'688Zi `f'688ZT i `098ZT `8'L58ZT `6'958Zi `i'S58Zi `9'b58ZT `f'Z58ZT `b'bb8Zi `6'ZbBZT `S'ObBZT `T'6f8ZT i `9f8Zi `9'bf8ZT `9'fZ8ZT '6'9Z8ZT `f'TZSZi `9'SZ8Zi i `ZT8Zi `6'STBZT `L'Z6LZT `9'i6LZT `Z'6LLZT `8'6LLZI `S'fLLZi `9'bLLZi `6'65LZT 'T'09LZT `9'fSLZT `b'fSLZT i `b'bbLZT `SbLZi `S'OfLZi `9'OfLZT `f'8TLZT `T'8TLZi `f'90LZT `b'LOLZI `f'TOLZi `i'TOLZi `T'L69ZT `b'869ZT '8'b69ZT `b'b69Zi `b'8L9ZT `T'6L9ZT `6'b99Zi `b'b99Zi `f'859ZT `6'L59ZT i `8b9Zi `6'Lb9Zi `9'Zf9ZT `T'Zf9ZT i `L'6Z9ZI `6Z9ZT `b'bZ9Zi `Z'bZ9ZT `6'ZZ9ZT `6'ZZ9Zi `Z'6T9ZT `S'6I9ZT `b'SI9ZT `T'9T9ZI `9'609Zi `Z'OI9ZT i `Z65ZT `L'Z65ZT `T'985ZT '6'S85Zi `L'f85ZT `6'f85ZT `8'LLSZT `9'LLSZT `S'955ZT `Z'LSSZT `S'SfSZi `f'S£SZT `6'TZSZT `f'ZZSZT `T'6bbZi `6'8bbZT `S'bZbZi `f'bZbZT i `S'ZZbZT `ZZbZT `Z'9TbZT `Z'9TbZT `Z'TibZT `6'TTbZT '6'80bZi `S'80bZT `6'bObZT `8'fObZT `S'08fZi `L'08fZT `L'SLfZi `f'SLfZT `b'iL£ZT `9'OLfZT `9'Z9f ZT `f'T9fZT `f'65fZT `8'85fZT tapescan.txt 13038.7, 13041, ! 2.33301 13041, 13043.6, ! 2.51074 13044.8, 13048, ! 3.22949 13063.3, 13067.1, ! 3.76758 13092, 13091.7, ! -0.358398 13095.8, 13095.3, ! -0.538086 13101.4, 13100.6, ! -0.717773 13107.1, 13108, ! 0.896484 13113.4, 13113.7, ! 0.358398 13117.1, 13117.7, ! 0.538086 13121.4, 13121.4, ! 0 13131.7, 13132.2, ! 0.538086 13137.6, 13137.9, ! 0.359375 13141.4, 13141.9, ! 0.538086 13156.4, 13157.3, ! 0.896484 13166.6, 13166.2, ! -0.358398 13175.7, 13174.8, ! -0.897461 13186.7, 13187.2, ! 0.538086 13188.5, 13189.2, ! 0.717773 13190.8, 13191, ! 0.179688 13195.5, 13195.8, ! 0.358398 13201.6, 13201.4, ! -0.178711 13209.5, 13210.1, ! 0.539062 13213.3, 13214.9, ! 1.61523 13217.4, 13219.2, ! 1.79395 13224.4, 13226.7, ! 2.33301 13228.9, 13229.6, ! 0.717773 13261.2, 13263.7, ! 2.51074 13281.6, 13282.9, ! 1.25586 13287, 13288.4, ! 1.43457 13294.2, 13295.6, ! 1.43555 13331.3, 13332.7, ! 1.43457 13351.4, 13353.9, ! 2.51172 13369, 13367.2, ! -1.79492 13380, 13378.7, ! -1.25586 13393.4, 13392.3, ! -1.07617 13394.5, 13393.8, ! -0.717773 13399.2, 13399.7, ! 0.538086 13402.4, 13404.2, ! 1.79395 13413.7, 13411.7, ! -1.97266 13416.9, 13414.2, ! -2.69043 13419.1, 13417.6, ! -1.43555 13422.7, 13420.1, ! -2.51172 13426.6, 13425, ! -1.61523 13428.9, 13427, ! -1.97363 13430.6, 13428.8, ! -1.79395 13436.5, 13436.1, ! -0.359375 13439.2, 13438.6, ! -0.538086 13445.6, 13444.2, ! -1.43555 13447.8, 13447.2, ! -0.538086 13450.5, 13451.7, ! 1.25586 13452.6, 13453.9, ! 1.25586 13457.6, 13458.9, ! 1.25586 13468, 13469.3, ! 1.25586 13473.2, 13474.3, ! 1.07617 13477.2, 13478.4, ! 1.25586 13482.4, 13483.5, ! 1.07617 13486.9, 13487.8, ! 0.896484 13494.6, 13492.8, ! -1.79395 13498.9, 13497.1, ! -1.79395 13503.4, 13502.5, ! -0.897461 13510.9, 13510.9, ! 0 13525.6, 13524.1, ! -1.43555 13533.1, 13533.5, ! 0.358398 13536, 1 3534.9, ! -1.07617 13539.6, 13536.9, ! -2.69043 13541, 1 3538.7, ! -2.33203 13543, 1 3541.7, ! -1.25586 13545.1, 13543, ! -2.15234 13548.2, 13546.4, ! -1.79395 Page 4 • 13550.7, 13549.4, 13554.3, 13552.1, 13561.1, 13558.9, 13562.9, 13561.6, 13567.7, 13565.4, 13574.5, 13572.8, 13582.6, 13578.4, 13590.6, 13586.5, 13594.2, 13591.4, 13596.4, 13594, 13604.1, 13603.5, 13611.1, 13610.5, 13615.4, 13613.4, 13626.7, 13624.7, 13638.5, 13635.5, 13643.2, 13640.3, 13651.4, 13648, 13663.2, 13662.9, 13666.8, 13666.8, 13674.5, 13674.2, 13677.9, 13677, 13695.3, 13693.9, 13700.2, 13699.7, 13702.9, 13702, 13705.9, 13705.4, 13709.7, 13710.2, 13715.4, 13714.2, 13718.7, 13717.8, 13732.3, 13733.6, 13737.9, 13737.7, 13741.1, 13742.2, 13749.2, 13749.2, 13787, 13789.2, 13881, 13878.7, 13909.9, 13907.2, 13927.9, 13924.3, 13942.1, 13938.1, 13982.4, 13980.6, 14001.4, 13998, 14010.8, 14007, 14017.2, 14013.8, 14031.9, 14027.9, 14034.6, 14030.5, 14044.6, 14040.9, 14053.6, 14049.8, 14057.5, 14054.7, 14061.3, 14057.9, 14066.9, 14064.5, 14074.4, 14070.8, 14081.6, 14077.3, 14087.1, 14081.8, 14090.2, 14084.3, 14096.6, 14093.2, 14101.5, 14099, 14108.3, 14107, 14124.8, 14120.9, 14131, 14127.1, 14134.1, 14133.2, 14143.6, 14141.6, 14147.5, 14144.8, 14151.1, 14148.6, 14156.9, 14156, 14162.1, 14160.3, 14183.5, 14180, 14188.3, 14185.8, 14192.2, 14191, 14198.2, 14199.4, 14225.9, 14222.2, 14274.6, 14267.9, 14376.5, 14371.8, C~ tapescan.txt -1.25586 -2.15234 -2.15234 -1.25586 -2.33301 -1.79395 -4.12598 -4.12598 -2.87109 -2.33203 -0.538086 -0.538086 -1.97363 -1.97363 -3.0498 -2.87012 -3.40918 -0.359375 ! -0.358398 -0.897461 ! -1.43555 ! -0.538086 -0.896484 ! -0.538086 ! 0.538086 ! -1.25586 ! -0.897461 ! 1.25488 ! -0.179688 ! 1.07715 ! 0 ! 2.15234 ! -2.33203 ! -2.69141 ! -3.58887 ! -3.94727 ! -1.79492 ! -3.40918 ! -3.76758 ! -3.4082 ! -3.94629 ! -4.12598 ! -3.76758 ! -3.76758 ! -2.87109 ! -3.40918 ! -2.33301 ! -3.58789 ! -4.30566 ! -5.38184 ! -5.91992 ! -3.40918 -2.51172 ! -1.25586 ! -3.94629 ! -3.94727 ! -0.896484 ! -1.97363 -2.69043 ! -2.51074 ! -0.896484 -1.79395 ! -3.40918 ! -2.51172 ! -1.25586 ! 1.25586 ! -3.76758 ! -6.63867 ! -4.66504 Page 5 14385.3, 14381.9, 14401.3, 14399.3, 14410.6, 14408.4, 14424.4, 14423.7, 14443.1, 14442.4, 14449, 14448.7, 14526.6, 14524.1, 14535.1, 14531.7, 14540.6, 14536.7, 14548.5, 14547.8, 14573.9, 14575.3, 14577.4, 14579.4, 14581.8, 14583.4, 14589.5, 14590.2, 14595, 14593.8, 14599.5, 14600.6, 14607.2, 14609.2, 14613, 14613.9, 14618.5, 14619.2, 14633.2, 14633.8, 14639.8, 14642, 14651.5 ,14653.5, 14662.2, 14660.6, 14666.9, 14668.2, 14675, 14675.2, 14677, 14676.6, 14720.3, 14719.6, 14728, 14727.5, 14743.5, 14739.5, 14751.9, 14747.4, 14785.6, 14781.3, 14789, 14784.4, 14792.6, 14791, 14807.1, 14803.9, 14817.7, 14814.8, 14826.9, 14825.4, 14874.1, 14874.5, 14892.8, 14893.3, 14902.1, 14899.8, 14908.9, 14905.5, 14923.3, 14918.8, 14930.1, 14929.6, 14949.7, 14946.8, 14954.4, 14950.4, 14957.8, 14954.2, 14963.1, 14959.2, EOZ END BASE CURVE: GROH, Tape Subfile: 1 Minimum record length: Maximum record length: ~*** FILE HEADER ~`*** MWD .001 1024 tapescan.txt -3.4082 -1.97266 -2.15234 -0.717773 -0.717773 -0.359375 -2.51172 -3.4082 -3.94727 -0.717773 1.43457 1.97363 1.61426 0.717773 -1.25586 1.07617 1.97266 0.897461 0.717773 0.539062 2.15234 1.97363 -1.61426 1.25586 0.179688 -0.359375 -0.717773 -0.538086 -3.94727 -4.48535 -4.30566 -4.66504 -1.61523 -3.22949 -2.87012 -1.43457 0.358398 0.538086 -2.33203 -3.4082 -4.48535 -0.538086 -2.87109 -3.94629 -3.58789 -3.94727 OFFSET CURVE: GRAX 373 records... 10 bytes 132 bytes *** INFORMATION TABLE: CONS Page 6 s • tapescan.txt *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 The data presented here is final and has been depth adjusted a Primary Depth Control (PDC) log provided by schlumberger GR cNL dated 09 Aug 200 per Adam van Holland with BP Exploration (Alaska), Inc. *** INFORMATION TABLE: CIFO * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame size is: 28 bytes Logging direction is down (value= 255) optical Lod Depth scale units: Feet Frame spacing: 0.500000 Frame spacing units: [F Number of frames per record is: 36 one depth per frame (value= 0) Datum Specification Block sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool code Samples units 1 GR MWD 68 1 AAPI 2 ROP MWO 68 1 F/HR 3 RAD MWD 68 1 OHMM 4 RAs MWD 68 1 OHMM 5 RPD MWD 68 1 OHMM 6 RPS MWD 68 1 OHMM Total Data Records: 167 1 size Length 4 4 4 4 4 4 4 4 4 4 4 4 --- 24 Tape File Start Depth = 12095.500000 Tape File End Depth = 15085.000000 Tape File Level spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape subfile: 2 180 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 Page 7 ~ i tapescan.txt *** INFORMATION TABLE: CONS *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 This file contains the raw-unedited field MwD data. *** INFORMATION TABLE: CIFO * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame size is: 28 bytes Logging direction is down (value= 255) Optical Lod Depth Scale units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 one depth per frame (value= 0) Datum Specification Block sub-type is: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR 3 RAD MWD 68 1 OHMM 4 RAs MWD 68 1 OHMM 5 RPD MWD 68 1 OHMM 6 RPS MWD 68 1 OHMM Total Data Records: 333 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File Start Depth = 12096.000000 Tape File End Depth = 15089.000000 Tape File Level spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape subfile: 3 -346 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 09/08/08 2711512 O1 Page 8 **** REEL TRAILER **** MWD 09/10/29 BHI O1 tapescan.txt Tape subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes 0 Tape .subfile 1 is type: Lis D Tape subfile 2 is type: LIS DEPTH GR ROP RPD RPS 12095.5000 -999.2500 -999.2500 -999.2500 -999.2500 12096.0000 -999.2500 -999.2500 -999.2500 -999.2500 15085.0000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 12095.500000 Tape File End Depth = 15085.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 3 is type: LIS DEPTH GR ROP RPD RPS 12096.0000 -999.2500 -999.2500 -999.2500 -999.2500 12096.2500 -999.2500 -999.2500 -999.2500 -999.2500 15089.0000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File start Depth = 12096.000000 Tape File End Depth = 15089.000000 Tape File Level Spacing = 0.250000 Tape File Depth units = feet D Tape Subfile 4 is type: LIS Page 9 RAD -999.2500 -999.2500 -999.2500 RAD -999.2500 -999.2500 -999.2500 RAS -999.2500 -999.2500 -999.2500 RAS -999.2500 -999.2500 -999.2500 ~~ i tapescan.txt **** REEL HEADER **** MWD 09/10/28 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 09/08/04 2711512 O1 3" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las version Information VERS. 1.20: OWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame well Information Block #MNEM.UNIT Data Type Information STRT.FT 12096.0000: starting Depth STOP.FT 14712.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: C-18BP61 FLD FIELD: Prudhoe Bay Unit LoC~. LOCATION: 70 deg 17' 55.872"N 148 deg 40' 23.063"w CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 04 AUg 2009 API API NUMBER: 500292078570 Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 19 TOWN.N T11N RANG. R14E PDAT. MSL EPD .F 0 LMF DF FAPD.F 66.83 DMF DF EKB .F 0 EDF .F 66.83 EGL .F 0 CASE.F N/A OS1 DIRECTIONAL Remarks Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True vertical Depths (TVDSS) are Subsea corrected. (4) All Formation Evaluation data is realtime data. Page 1 ~D9 _ O~ ~ l ~ ~s6 • • tapescan.txt (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to lob this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance sub (Inner and outer Downhole Pressure, vibration and Downhole weight on Bit), a Directional and Gamma sub, and a Hydraulic orienting sub with a Near Bit Inclination sensor. (7) Data presented here is final and has been depth adjusted to well C-18B above the Kick off Point of 13070 feet MD dated 08 Aug 2009 per Adam van Holland with BP Exploration (Alaska), Inc. The MwD data is now the Primary Depth Control (PDC) log for well C-18BPB1. (8) The sidetrack was drilled from C-18 through a milled window in a 7 inch liner. Top of window 12284 ft.MD (8360.0 ft.TVD55) Bottom of window 12292 ft.MD (8366.1 ft.TVDSS) (9) Tied to C-18 at 12279 feet MD (8356.2 feet TVD55). (10) The interval from 14658 feet to 14707 feet MD (8744.4 feet to 8738.6 feet TVD55) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROPJaVG -> Rate of Penetration, feet/hour RACLX -> Resistivity (AT)(LS)400kHZ-Compensated Borehole Corrected (OHMM) RACHX -> Resistivity (AT)(LS)2MHZ-Compensated Borehole Corrected (oHMM) RPCLX -> Resistivity (PD)(LS)400kHz-compensated Borehole corrected (OHMM) RPCHX -> Resistivity (PD)(LS)2MHZ-Compensated Borehole corrected (oHMM) TVDSS -> True Vertical Depth (subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 12115.8, 12115.6, ! -0.179688 12120.7, 12120.5, ! -0.179688 12122.8, 12123, ! 0.178711 12125.7, 12126.9, ! 1.25586 12130.7, 12131.2, ! 0.538086 12138.2, 12138.1, ! -0.179688 12142, 1 2142.4, ! 0.359375 12145.8, 12145.4, ! -0.358398 12152.4, 12152.8, ! 0.358398 12155.3, 12155.6, ! 0.358398 12158, 1 2158, ! 0 12163.9, 12163.7, ! -0.179688 12165.3, 12165.1, ! -0.179688 12167.1, 12167.1, ! 0 12170.7, 12170, ! -0.717773 12176.1, 12175.4, ! -0.717773 12177.2, 12176.8, ! -0.359375 12179.5, 12179.3, ! -0.179688 12181.1, 12180.6, ! -0.538086 12182.7, 12182.4, ! -0.359375 12184.3, 12184.7, ! 0.358398 12188.5, 12189, ! 0.538086 12191.3, 12190.6, ! -0.717773 12194, 1 2193.3, ! -0.717773 12201.3, 12201.5, ! 0.179688 12208.5, 12208.1, ! -0.359375 12210.2, 12209.9, ! -0.359375 12213.8, 12213.3, ! -0.538086 12218.3, 12218.5, ! 0.178711 12225.9, 12226.2, ! 0.359375 12239.3, 12240, ! 0.716797 12241.5, 12242.2, ! 0.717773 12250.3, 12251.1, ! 0.896484 12269.3, 12270.2, ! 0.897461 12278.2, 12279.1, ! 0.896484 12284.8, 12284.8, ! 0 12288.2, 12288.4, ! 0.179688 12289.3, 12290, ! 0.716797 12291.3, 12292.4, ! 1.07715 12299.5, 12300.1, ! 0.538086 12303.8, 12303.3, ! -0.538086 12313.3, 12314.6, ! 1.25586 12318.6, 12319.4, ! 0.897461 Page ~ ~ 12324.3, 12325.4, 12328.2, 12329.1, 12331.3, 12332.4, 12346.6, 12346.8, 12350.9, 12351.1, 12355.6, 12356.5, 12361.5, 12362.8, 12370.5, 12371.4, 12375.3, 12375.7, 12380.9, 12380.7, 12404, 12404.9, 12408.6, 12409.4, 12411.5, 12411.3, 12416.4, 12416.5, 12422.1, 12422.5, 12424.4, 12424.4, 12432.9, 12433.1, 12448.7, 12448.7, 12485.9, 12485.5, 12504.3, 12504.2, 12522.3, 12521.9, 12535.5, 12535.5, 12557.3, 12556.6, 12581.2, 12581.2, 12584.1, 12583.9, 12585.9, 12586.4, 12588, 12588.4, 12590, 12589.8, 12595.5, 12594.8, 12608.5, 12608, 12612.8, 12612.3, 12619.5, 12619.1, 12622.9, 12622.9, 12624.2, 12624.3, 12628.8, 12629.4, 12631.9, 12632..4, 12635.8, 12636.4, 12648, 12648.2, 12658.4, 12658.6, 12661.1, 12661.6, 12664, 12664.5, 12678.9, 12678.5, 12692.6, 12693, 12694.6, 12695, 12698.4, 12697.1, 12700.9, 12701.4, 12703, 12702.5, 12708.4, 12707.3, 12710.4, 12709.8, 12714.9, 12714.9, 12717.9, 12718.3, 12730.5, 12730.3, 12742, 12741.5, 12753.7, 12753.7, 12756.7, 12756.5, 12760.1, 12759.9, 12775, 12773.9, 12782, 12781.3, 12791.3, 12792.4, 12794.6, 12795.6, 12798.3, 12798.7, 12814.3, 12810.9, 12819.6, 12815.5, 12825.7, 12821.2, 12827.3, 12824.8, 12834.5, 12835.9, 12839.2, 12840.4, 12842.4, 12844, 12846, 12848.1, 12852.6, 12854.8, tapescan.txt 1.07617 0.897461 1.07617 0.179688 0.179688 0.897461 1.25586 0.897461 0.359375 -0.178711 0.897461 0.717773 -0.179688 0.179688 0.358398 0 0.179688 0 -0.359375 -0.178711 -0.358398 0 -0.717773 0 -0.178711 0.538086 0.358398 -0.179688 -0.717773 -0.538086 -0.538086 -0.358398 0 0.178711 0.538086 0.538086 0.538086 0.179688 0.179688 0.538086 0.538086 -0.359375 0.358398 0.359375 -1.25586 0.538086 -0.538086 -1.07617 -0.538086 0 0.358398 -0.178711 -0.538086 0 -0.178711 -0.179688 -1.07617 -0.717773 1.07617 1.07617 0.358398 -3.40918 -4.12598 -4.48438 -2.51172 1.43555 1.25586 1.61523 2.15332 2.15234 Page 3 tapescan.txt 12857.5, 12859.8, ! 2.33203 12860.5, 12862.7, ! 2.15234 12885.3, 12886, ! 0.716797 12889.4, 12889.6, ! 0.179688 12898, 12898.9, ! 0.897461 12902.5, 12902.9, ! 0.358398 12905.5, 12906.3, ! 0.717773 12909, 12909.3, ! 0.359375 12917.7, 12918.8, ! 1.07617 12926.9, 12926.9, ! 0 12929.9, 12930.7, ! 0.717773 12932.8, 12934.1, ! 1.25586 12934.4, 12935.3, ! 0.896484 12939.6, 12939.6, ! 0 12945.9, 12944.6, ! -1.25586 12949.8, 12948.9, ! -0.897461 12952.8, 12952.7, ! -0.179688 12956.8, 12956.8, ! 0 12959.3, 12960.4, ! 1.07617 12963.6, 12965.4, ! 1.79395 12967.4, 12969.2, ! 1.79492 12974.2, 12976.4, ! 2.15332 12981.7, 12984.4, ! 2.69141 12988.9, 12992, ! 3.0498 12996.1, 12998.1, ! 1.97363 13012.8, 13014.9, ! 2.15234 13021.7, 13024.1, ! 2.33203 13025.9, 13028.4, ! 2.51074 13028.4, 13031.1, ! 2.69141 13032.1, 13034.8, ! 2.69141 13034.1, 13036.6, ! 2.51172 13039, 1 3041.5, ! 2.51172 13040, 1 3042.7, ! 2.69043 13043.4, 13046.1, ! 2.69141 13044.8, 13048.2, ! 3.4082 13056.8, 13060.4, ! 3.58887 13063.1, 13066.9, ! 3.76758 13069, 1 3072.8, ! 3.7666 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape subfile: 1 226 records... Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER**** MWD .001 1024 *** INFORMATION TABLE: CONS ~** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 The data presented here is final and has been depth adjusted well c-186 above the Kick off Point of 13070 feet MD dated 08 Aug 2009 per Adam van Holland with BP Exploration (Alaska), Inc. The MwD data is now the Primary Depth Control (PDC) log for well C-186P61 Page 4 ~ ~ tapescan.txt *** INFORMATION TABLE: CIFO * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Lod Depth scale units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 one depth per frame (value= 0) Datum specification Block sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code samples units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR 3 RAD MWD 68 1 OHMM 4 RAS MWD 68 1 OHMM 5 RPD MWD 68 1 OHMM 6 RPS MWD 68 1 OHMM Total Data Records: 146 1 size Length 4 4 4 4 4 4 4 4 4 4 4 4 -----24 Tape File Start Depth = 12096.000000 Tape File End Depth = 14712.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER ***~ Tape subfile: 2 159 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 This file contains the raw-unedited field MWD data. Page 5 n ~. *** INFORMATION TABLE: CIFO * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame size is: 28 bytes Logging direction is down (value= 255) optical Lod Depth scale units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 one depth per frame (value= 0) Datum specification Block sub-type is: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR 3 RAD MWD 68 1 OHMM 4 RAS MWD 68 1 OHMM 5 RPD MWD 68 1 OHMM 6 RPS MWD 68 1 OHMM Total Data Records: 291 tapescan.txt 1 Size Length. 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File Start Depth = 12096.000000 Tape File End Depth = 14708.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 304 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 09/08/04 2711512 O1 **** REEL TRAILER **** MWD 09/10/28 BHI O1 Page 6 --, .,~ • tapescan.txt Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes 0 Tape Subfile 1 is type: LI5 0 Tape Subfile 2 is type: LI5 DEPTH GR ROP RPD RPS 12096.0000 -999.2500 -999.2500 -999.2500 -999.2500 12096.5000 -999.2500 -999.2500 -999.2500 -999.2500 14712.0000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 12096.000000 Tape File End Depth = 14712.000000 Tape File Level Spacing = 0.500000 rape File Depth units = feet 0 Tape Subfile 3 is type: LIS DEPTH GR ROP RPD RPS 12096.0000 -999.2500 -999.2500 -999.2500 -999.2500 12096.2500 -999.2500 -999.2500 -999.2500 -999.2500 14708.0000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 12096.000000 Tape File End Depth = 14708.000000 Tape File revel Spacing = 0.250000 Tape File Depth units = feet D Tape Subfile 4 is type: LIS RAD -999.2500 -999.2500 -999.2500 RAD -999.2500 -999.2500 -999.2500 RAs -999.2500 -999.2500 -999.2500 RAS -999.2500 -999.2500 -999.2500 Page 7