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212-022
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. c J - ©aa Well History File Identifier Organizing (done) ❑ Two-sided ❑ Rescan Needed 7RE AN: OVERSIZED: NOTES: pi R p u1E L L C or Items: ❑ Maps: Grayscale Items: ❑ Logs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: del. Date: l 01 / li' /s/ MP Project Proofing BY: Maria Date: `' 3 ' /s/ rill° Scanning Preparation x 30 = + = TOTAL PAGES a(D (Count does not include cover sheet) I froBY: Maria Date: 1I � /s/ Production Scanning i Stage 1 Page Count from Scanned File: fag (Count does include cove sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: 4M Date: `1 3 I{ /s/ t ' Vf Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc Hunt, Jennifer L (DOA) From: Lastufka,Joseph N <Joseph.Lastufka@bp.com> Sent: Wednesday,June 25, 2014 10:00 AM To: Hunt,Jennifer L(DOA) Subject: MPG-08B PTD#212-022 Jennifer, This Permit to Drill has expired. Please note as such. Please let me know if you have any additional questions or need any additional information. Thank you, Joe Lastufka Alaska Wells Technologist Cell: (907) 227-84961 Office: (907) 564-4091 vvlo „i„edRig BP Exploration AlaskaI900 E.Benson Blvd.IRoom: 788DIAnchorage,AK 1 QCC+{ rC 1 A ; a 's p i p � - y SEAN PARNELL, GOVERNOR �- LLA ALASKA OIL AND GAS 333 W 7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Ken Allen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Field, Schrader Bluff Oil Pool, MPG-08B BP Exploration (Alaska), Inc. Permit No: 212-022 Surface Location: 2104' FSL, 3460' FEL, SEC. 27, T13N, R10E, UM Bottomhole Location: 745' FSL, 3786' FEL, SEC. 22, T13N, R10E, UM Dear Mr. Allen: Enclosed is the approved application for permit to redrill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy,4. Foerster Chair • DATED this (v day of March, 2012. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) 1 • STATE OF ALASKA �'•+�IVE — ALAS. OIL AND GAS CONSERVATION COMM, ON 1 Q 70120.2-404? PERMIT TO DRILL 20 AAC 25.005 -.FIs.Commission la.Type of work: 1b.Proposed Well Class: 1 c. Specify if.well ie osed for: 0 Development Oil IN -Winj 0Single Zone Ili ❑ Drill IS Redrill 0 Stratigraphic Test 0 Development Gas 0 Service-Supply 0 Multiple Zone 0 Coalbed Gas 0 Gas Hydrates ❑ Re-Entry 0 Exploratory 0 Service-WAG 0 Service-Disp 0 Shale Gas 2. Operator Name: 5.Bond: ® Blanket 0 Single Well 11. Well Name and Number: BP Exploration(Alaska) Inc. Bond No. 6194193 MPG-08B 3. Address: 6. Proposed Depth: 12.Field/Pool(s): P.O. Box 196612,Anchorage,Alaska 99519-6612 MD 6347' TVD 4366'ss Milne Point/Schrader Bluff 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): Surface: ADL 025906&025516 2104'FSL,3460'FEL, SEC.27,T13N, R10E, UM Top of Productive Horizon: 8. Land Use Permit. 13. Approximate Spud Date: 543' FSL,3796'FEL, SEC.22,T13N, R10E, UM April 5,2012 Total Depth: 9 Acres in Property: 14.Distance to Nearest Property: 745' FSL, 3786'FEL, SEC.22,T13N, R10E, UM 1280 11125' 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 63.9' feet 15.Distance to Nearest Well Open Surface: x- 557143 y-6014539 Zone- ASP4 GL Elevation above MSL: 29.6' feet to Same Pool: 1125' 16.Deviated Wells: Kickoff Depth: 2742 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 59 degrees Downhole: 2049 Surface: 1651 18. Casing Program: Specifications Top-Setting Depth-Bottom Quantity of Cement,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND (including stage data) 8-3/4" 7" 26# L-80 VamTop HC 6347' Surface,Surface 6347' 4430' 492 sx Class'G' . 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effective Depth MD(ft): Effective Depth TVD(ft): Junk(measured): 5234' 4313' None 5234' 4313' None Casing Length 1 Size Cement Volume MD TVD Conductor/Structural 115' 20" 452 sx Arctic Set IV 115' 115' Surface 2736' 9-5/8" 900 sx PF'E'.300 sx Class'G' 2736' 2366' Intermediate 4870' 7" 195 sx Class'G' 4865' 3952' Production Liner Perforation Depth MD(ft): Open Hole w/Gravel Pack Assembly: Perforation Depth ND(ft): 3710'-4305' 4609'-5226' 20.Attachments: ® Property Plat IS BOP Sketch ®Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis IN Diverter Sketch 0 Seabed Report ®Drilling Fluid Program Z 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Dave Johnson,564-4171 Printed Name Ken Allen Title Engineering Team Leader Prepared By Name/Number Signature 7_____t, ---- 0 _________ Phone 564-4366 Dated.//Z Terrie Hubble,564-4628 Commission Use Only Permit To DrillqAPI Number: Permit A r val te* See cover letter for Number: p?,p?0,i?.R 50-029-22141-02-00 D Wv1, other requirements Conditions of Approval: If box is checked,well may notwbe used to explore for,test,or produce coalbed m than ,gas hydrates,or gas contained shales: Err Other: .X 3500 psi- t3OP '"S1"-- Samples Req'd: ❑�Y s No Mud Log Req'd: ❑,-,/Yes Ild'No H25 Measures: B Yes 0 No Directional Survey Req'd: Il Yes 0 No V c& 4 M 17— re c,tide*Q / L a ,oro l 0 13 / / I APPROVED BY THE COMMISSION Date 3-(0 ` / - / ` Z COMMISSIONER Form 10-401 Revised 07/2009 This permit is valid for 24 monthsQrrReIG If Aar AAC 25.005(g)) 'Omit In Duplicate by 0 To: Alaska Oil & Gas Conservation Commission From: Dave Johnson, ODE Date: February 10, 2012 Re: MPG-08B Sidetrack Permit to Drill It is planned to plug and abandon the MPG-08A and drill MPG-08B. The proposed sidetrack will be a conventional, single selective completion, Schrader Bluff NB, OA and OBa injector. This will be part of a pattern development to provide waterflood support to producers in HUO7 in the Milne Point Unit. This injector will be drilled just south of the northern bounding fault for the hydraulic unit. This well will be drilled by Doyon 14 using their 5000 psi four preventer BOP stack (3 rams and an annular). The BOP's will be tested to 3500 psi. The rig work is expected to start April 5th, 2012. The sidetrack plan for the MPG-08B includes the following: - P&A MPG-08A per Sundry Notice submitted. - Dress off cement plug set across 9-5/8" surface casing shoe and • sidetrack well immediately below shoe. - Drill 8-3/4" production hole to 6,347' MD (+/- 150' MD below base of OB) - - Run FMI Sonic Scanner/ Sidewall cores and MDT samples on electric line. - Run and cement a 7" full casing string with 15.8 ppg glass G tail cement. - Perforate the NB, OA and OBa sands as determined from LWD and wireline logs. - Complete well with 3-1/2" tubing and zonal isolation packers. Please find attached the MPG-08B Planned Well Summary, directional plan and proposed completion diagram. If you have any questions or require any additional information, please contact me at 564-4171. Speer", Dave Johnson Operations Drilling Engineer BP Exploration (Alaska), Inc. MPG-08B PTD Page 1 2/10/2012 Planned Well Summary Well MPG-08B Well Injector - Target Schrader Type Objective Bluff API Number: 50-029-22141-02-00 Current Status Shut-In Estimated Start Date: 4/5/2012 Time to Complete: 26 Days Northing Easting Offsets TRS Surface 6,014,538.9 557,142.4 3176' FNL/ 3459' FEL 13N, 10E, Section 27 T1 - Top OA 6,018,255.0 556,770.0 4766' FNL/ 3797' FEL 13N, 10E, Section 22 TD 6,018,457.0 556,778.0 4534' FNL/ 3786' FEL 13N, 10E, Section 22 Planned KOP: 2,742' MD/2,305' TVDss Planned TD: 6,347' MD/4,366' TVDss Rig: Doyon 14 • BF/RT: 29.6'/34.3' RTE: 63.9' Directional — Schlumberger WP09 KOP: 2,742 MD Maximum Hole Angle: —59° in the 8-3/4" production section Close Approach Wells: MPG-10, an active water injector, failed the major risk collision analysis at 3009' MD (MPG-08B). It passed minor risk collision analysis at 1:200. MPG-10 will be secured with a downhole plug in the tubing and shut in at surface prior to drilling. It will remain shut in until after MBG-08B until MPG- 08 has finished drilling. All other wells passed the major risk collision analysis. Survey Program: Surface to 2742' MD = Existing Gyro Multi-Shot 2742' to 3200' MD = Inc+ Trend 2742' to 3200' MD= Gyro Multi-Shot 3200' to 4600' MD= MWD 3200'to 6347' MD = MWD + IIFR+ Multi Station Nearest Property Line: 11,125' Nearest Well within Pool: 1125' to MPG-08 (Plugged &Abandoned) Wells within 1/4 mile of this injection well @ top of reservoir: Well Name Dist, Ft. Annulus Integrity Comments MPG-08 1,125' MPG-08 was plugged and abandoned in 1993 for MPG-08A sidetrack. ✓ (to top OB MPG-13 1240' This well is in a different fault block, no integrity problems. (To top NB) MPG-08B PTD Page 2 2/10/2012 Formation Tops & Pore Pressure Estimate Estimated Depth Fluid Type Pore Pressure Formation Formation Top Uncertainty (for Sands) Most Likely Minimum Maximum (TVDss) (+/-TVD) (EMW ppg) _ (EMW ppg) (EMW ppg) SV6 775.0 above KOP Water(Ice) 8.40 8.35 8.45 SV5 1,400.0 above KOP Water(Ice) 8.40 8.35 8.45 SV4 1,510.0 above KOP Water(Ice) 8.40 8.35 8.45 _ SV3 1,670.0 above KOP Water(Ice) 8.40 8.35 8.45 SV2 1,830.0 above KOP Water(Ice) 8.40 8.35 8.45 BPRF 1,860.0 above KOP - 8.60 8.35 8.60 SV1 2,110.0 above KOP Methane Hydrates 8.60 8.35 9.30 KOP 2,311.0 - UG4 2,450.0 30 Brine/CBM 8.40 8.35 9.30 UG4A 2,500.0 30 Brine/CBM 8.40 8.35 9.30 UG3 2,820.0 30 - 8.40 8.35 9.30 M87F 3,705.0 30 Heavy Oil 8.88 8.35 9.10 M80T 3,725.0 30 Heavy Oil 8.88 8.35 9.10 M80F 3,775.0 30 Brine 8.88 8.35 9.10 M80S 3,825.0 30 - 8.88 8.35 9.10 NA 3,945.0 35 Viscous Oil 9.15 8.20 10.60 NB 3,980.0 35 Viscous Oil 9.40 8.20 10.60 NC 4,000.0 35 Viscous Oil 9.15 8.20 10.60 ND 4,020.0 30 Viscous Oil 9.15 8.20 10.60 NE 4,030.0 30 Viscous Oil 9.15 8.20 10.60 NF 4,075.0 25 Viscous Oil 9.15 8.20 10.60 OA 4,110.0 25 Viscous Oil 8.70 8.20 10.60 OA_sb 4,145.0 25 - 8.70 8.20 10.60 OBA 4,180.0 30 Viscous Oil 8.70 8.20 10.60 SBA5 4,205.0 30 - 8.70 8.20 10.60 TD 4,366.0 - - 8.70 8.20 10.60 Casing/Tubing Program Hole Csg / Burst Collapse Top Bottom Size Tbg OD Wt/Ft Grade Conn (psi) (psi) Length MD/TVD MD/TVDrkb 8-3/4" 7" 26# L-80 VamTop HC 7,240 5,410 6,347' Surface 6,347'/4,430' Tubing 3-1/2" 9.2# L-80 TC-II 11,160 10,540 6,110 surface 6,240/4,346' Mud Program Production Mud Properties: LSND 8-3/4" hole section Depth Interval Mud Plastic Yield MBT API pH LGS Weight Viscosity Point ml 2,736' -6,347' 9.3-9.5 6-12 18-25 <14 <8 8.5-10 ` 5.5 Logging Program 8-3/4" Production: Drilling: Dir/GR/Res/Neu/Den , Open Hole: FMI Sonic Scanner/Sidewall Cores / MDT samples Cased Hole: Cement Bond Log MPG-08B PTD Page 3 2/10/2012 Cement Program Casing Size 7"26#, L-80 Production Casing Basis: Lead: None Tail: Volume of 2,626' open hole above the shoe +40%excess + 83' shoe track. Tail TOC at-3732' 1000' below surface casing shoe). Total Cement Spacer 40 bbls of Viscosified Spacer weighted to 11.0 ppg (Mud Push II) Volume: Lead N/A Tail 101.6 bbls, 570.5 cuft, 491.8 sxs 15.8 lb/gal Class G + adds- 1.1R r.i'frisk Temp BHST=80° F, BHCT TBD by Schlumberger Surface and Anti-Collision Issues Surface Shut-in Wells: MPG-15 has a failed ESP will remain shut-in while moving over MPG-08. MPG-18 is a high water cut well and will be shut-in while moving over MPG-08. Close Approach Shut-in Wells: MPG-10, an active injector, failed the major risk collision analysis at 3009' MD (MPG-08B). It passed minor risk collision analysis at 1:200. MPG-10 will be secured with a downhole plug in the tubing and shut in at surface prior to drilling. It will remain shut in until after MBG-08B has finished drilling. Hydrogen Sulfide • MPG Pad is not designated as an H2S Pad. H2S detected from G-Pad wells: Well Name H2S Level Reading Date Comments Parent Well H2S Level MPG-08A 0 ppm 12/1/2005 Schrader producer #1 Closest SHL Well H2S Level MPG-18 5 ppm 9/9/2011 Schrader producer #2 Closest SHL Well H2S Level MPG-15 0 ppm 6/1/2001 Schrader producer #1 Closest BHL Well H2S Level MPG-10i N/A - injector, no readings #2 Closest BHL Well H2S Level MPG-07i N/A - injector, no readings #3 Closest BHL Well H2S Level MPJ-05 1 ppm 9/9/2011 Schrader producer #4 Closest BHL Well H2S Level MPG-04 0 ppm 12/1/2005 Schrader producer Max. Recorded H2S on Pad/Facility 5 ppm 9/9/2011 Schrader producer No samples on MPG-Pad have been greater than 100 ppm. Faults • No fault crossings are predicted for this well. Drilling Waste Disposal • There is no annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul Class I waste to DS-04 and/or Pad 3 for disposal/Contact the GPB Environmental Advisors(659-5893) f/guidance. Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below,annular preventer will be tested to 3500 psi. Rams will be tested to 3500 psi.The BOP test frequency will be conducted on a 14 day frequency,with a function test every 7 days. Except for significant operational issues that may effect well integrity or pose safety concerns, an extension to the 14 day BOP test period should not be requested. MPG-08B PTD Page 4 2/10/2012 Production Interval Maximum anticipated BHP 2049 psi @ TNB at 3,980'TVDss(9.4 ppg EMW + 0.5 over anticipated) Maximum surface pressure 1651 psi (.10 psi/ft gas gradient to surface) 25.4 bbls with 12.9 ppg frac gradient, assuming a maximum 9.9 ppg max pore pressure in the NB and 9.5 ppg MW. Kick tolerance Note: MPS-08 had a 15.3 ppg LOT in 1991 MPG-08A unable to find a 1993 FIT or LOT report G-Pad FITs ranged from 10 to 12.5 ppg. MPG-07 had a 15.5 ppg LOT Planned BOP test pressure Rams test to 3,500 psi/250 psi. Annular test to 3,500 psi/250 psi 9-5/8" Casing Test 2500 psi surface pressure 7" Casing Test 3500 psi surface pressure Integrity Test-8-1/2" hole LOT after drilling 20'-50' from 9-5/8"shoe. 7" Casing The VBRs will be changed to 7" rams for running the 7"casing Planned completion fluids -9.5 ppg Brine/6.8 ppg Diesel Freeze Protect. Densities will be adjusted based on MDT readings MPG-08B General Operational Summary Procedure Pre-Rig Operations per Sundry 1. Pressure test pack-offs on tubing and tubing spools to 5000 psi. Function all lockdown screws. 2. Verify that DGLV is set in top station @141' and that DGLV is pulled from bottom station 3. SBHPS prior to start of rig work. (SBHPS on 8/26/11 showed static BHP building 4. Circulate well & freeze protect. 5. Injectivity test/ MIT-OA (verify casing shoe is open) 6. Set & test BPV. Drilling Rig Operations 1. Move in and rig up Doyon 14. 2. Pull the BPV with tested lubricator. Circulate out diesel freeze protection with 9.6 ppg brine through tubing perfs at -4167' MD. 3. Set BPV and perform a rolling test to 500 psi from below for 10 minutes. If unable to attain 500 psi, record rate and pressure and visually confirm that BPV is not leaking 4. Rig up OA to bleeder tank and bleed pressure to zero psi. Monitor to ensure well is dead in preparation for 7" cut and pull. 5. Nipple down tree and tubing adapter. Nipple up BPOE with 2-7/8" X 5-1/2" VBRs '/ in upper and lower ram cavities. Test BOPE to 250 psi low/ 3500 psi high including annular with 2-7/8" and 4" test joints. Note: If there is sufficient height, install spacer spool above the tubing spool to allow testing of the lower set of rams with a conventional test plug. If unable to install spacer spool, test lower rams with a test joint screwed into the tubing hanger. MPG-08B PTD Page 5 2/10/2012 6. Pull BPV with tested lubricator per FMC. 7. Pull and lay down 2-7/8" 6.4#, L-80 tubing and ESP completion from 4253'. 8. RIH with bit and scraper. Clean out well to liner top packer @ 4609' MD. 9. RU Eline. Run CBL with either USIT or isolation scanner and log 7" casing from -4590' MD to surface. 10.Run Gyro CAAT log on Eline from -4590' MD to Surface 11.Run and set 7" cement retainer @ 4569' MD. Test cement retainer and 7" casing to 3500 psi. 12.Sting into retainer and establish injection into gravel packed screened liner for cement squeeze. If unable to establish injection proceed to step 14. 13.Cement squeeze the screened liner with 15.8 ppg class G cement (yield - 1.16 cuft/sx). The cement volume to be squeezed will be determined from the injection rate. The 12" X 4-1/2" annulus has been gravel packed with 20/40 and the annular volume is very limited. The pipe volume equals 7.6 bbls or 36.6 sxs. 14.Pull out of the cement retainer and set a balanced cement plug from the retainer to the top of cement in the annulus as determined from the cement bond logs or 500' above the cement retainer which ever is greater. The top of cement in the annulus is estimated at 4075' MD (494'). Cement will be 15.8 ppg with a yield of 1.16 Cu. Ft. /sack. The 500' minimum plug will require 19.1 bbls or 92.6 sacks of cement and the top of cement inside casing is at -4069'. 15.Pull up to -4069' MD and circulate the well clean at the top of the cement plug. 16.If cement bond log showed poor quality bonding in the annulus: a. Rig up lubricator and pressure test. RIH with E-line and perforate a 5 ft interval in the 7" casing at -20' above top of cement (-4069') in annulus as picked from cement bond log. Perforations are estimated at -4049'. b. Perforate a second 5 ft interval at -3950' MD (99 ft above first perforations). c. Run a gauge ring (minimum 5.560") through the upper perforation interval to ensure the EZSV cement retainer will pass drift. Rig down E-line and lubricator. d. Run in hole with a 7" EZSV cement retainer on 4" drill pipe. Set EZSV at -3970' MD between the perforation intervals. Break circulation through perforations behind 7" casing and condition hole for cement. Note: if circulation is not achieved, increase pressure over formation fracture gradient and inject -5 bbls to verify zonal isolation. e. Pump -10 bbls of 15.8 ppg class G cement to fill casing x 7" annulus. f. Pull out of the cement retainer and set a 600' balanced cement plug on top of the cement retainer. Cement will be 15.8 ppg class G with a yield of 1.16 Cu. Ft. / sack. The 600' plug will require 32.1 bbls or 155.6 sacks of cement and the top of cement will be at -3370'. g. Pull up to -3370' MD and circulate out any excess cement. 17.Pull out of hole. Close blind/shear rams. Pressure test cement plug to 250 psi low and 2000 psi high for 30 minutes. Confirm strength of cement plug is at least 1000 psi prior to pressure testing 18.Based on cement bong log, plan to cut casing @ 2836' -100' below 9-5/8" casing shoe. Run in hole with a 7" EZSV cement retainer on E-line. Set EZSV at -2940' MD 19.Make-up a 7" casing cutting assembly and RIH. Tag top of cement retainer at 2940'. MPG-08B PTD Page 6 2/10/2012 20.Pickup and cut casing at 2836'. Displace the annulus with 9.3 ppg brine and pump sweeps of Safe-Surf-O as needed until returns clean up. POH and lay down multi-string cutter. Note: Be prepared for diesel freeze protect and potentially dead crude in OA returns. 21.Change out top variable rams to 7" casing rams and test to 250 psi low and 3500 psi high. Have a safety joint with FOSV for 7" casing. 22.Engage mandel hanger with spear and pull the mandrel hanger and 7" casing from the cut through the Wellhead/BOPE per FMC. Lay down casing. 23.Change 7" casing rams to variable rams. Test rams to 250 psi low/ 3500 psi high including annular with 3-1/2" and 4" test joints. 24.RIH with 3-1/2" tubing stinger on DP and tag top of cement retainer. 25.Pull out of the cement retainer and set a 600' balanced cement plug on top of the cement retainer from 3940' to 2340 w. Cement will be 17.0 ppg class G with a yield of 1.01 Cu. Ft. / sack. The 600' plug will require 45.3 bbls or 253.2 sacks of cement. 26.Run bit and scraper in 9-5/8" casing to -2300' MD 27.RU Eline. Run CBL with either USIT or isolation scanner and log 9-5/8" casing from -2300' MD to surface 28.Run Gyro CAAT log on Eline from -2300' MD to Surface 29.Dress off top of cement and pressure test plug and casing to 2500 psi 4,t--314 Sundry Notice Permit to Drill air- o 30.Cleanout remaing cement to KOP of 2742' and side track well below 9-5/8" casing shoe. r J (( 2.01 L. o-r vz.1 P/d Emu.) 4 31.Drill 8-3/4" hole as per directional plan to 6 47 MD/4430' TVD (-150' below base OB). 32.Condition hole for electric line logging. 33.RU electric line. Run FMI/Sonic Scanner in open hole across Scrader and Ugnu formations. Take MDT samples in the Schrader N and 0 sands as determined from logs for PVT anaylysis. Run and take sidewall cores in the Ugnu as determined from logs. Note: A PEX log may be run if LWD data is poor. A production hole FMI may be run as a substitute for cores if required. 34.Trip in hole with drilling assembly and condition hole for running casing. 35.Change top VBRs to 7" casing rams and to test 250 psi low and 3500 psi high . 36.Run and cement 7" casing. 37.Change 7" casing rams to variable rams. Test rams to 250 psi low/ 3500 psi high including annular with 3-1/2" and 4" test joints. Have a safety joint with FOSV for 7" casing. 38.RU E-line and run GR/USIT/CCL."' • 39.Perforate NB, OA and OBa sands with TCP guns as determined from logs. 40.Run single 3-1/2" tubing string with straddle packers and injection mandrels for zonal isolation. Spaceout and land tubing. 41.Set packers. Test tubing string and IA to 3500 psi high and 250 psi low. 42.ND BOPE. NU and test tree to 5000 psi. 43.Freeze protect inner annulus and tubing string. 44.RDMO Doyon 14. MPG-08B PTD Page 7 2/10/2012 MPG-08B Proposed Completion Tree: :.5"• EM MPG-08B Y.B Elev = 56 1'Estimated Wellhead' 11"EM FMC 1r,r V RT to CL Elev = 28.5'Nsbord 7ES Tbo Hna: 0.5""x 11"FMC" eta=k wi!be lands:or emergen:y sips 'C" 91 1 ppf, H-4C F-717 C T urer Hanger 8 Tieback 5725 "_5:5 36#K-55 5-C I 2736'. A 'see rote beiow, 3 5'HESX-Nipple 12813'pkg) j 2047 "Note" 9 518"f,-55 tett 5-51 BTC-M (Drift ID s 8756.sap...07721 t•pf) Collapse 2C 2C psi 1-.0P dt 2708' Internal Yield 2E2C poi Max hole angle= EC deo from Pipe Body yield-564,CCC is to EEC(' Hole angle through pert:= 28 deo DRAFT SCHEMATIC Actual Packet Depths 3 5'x 1 5"Cameo MMG GLM 5728' Subject to Change TentatNe Based on Pressures 3 5'HES X-Nipple{2 813'pkg) 5783 3.5'9.2 ppf, L-80. IBT tubing T x 3 5 Baker Premier Packer 572+4 ( Drift id =2.992',cap.=0.0087 bpf) — Ported 3.5'HES X-N&pple{2813'pkg) 5816 7" 26 ppf, L-8C,BTC-M prod.casing (drift ID=6.151",cap.=.CCBB bpQ 3.5'NPG Single Sub 5812 (cap with 3.5"tbg inside=.0 64 bpQ 1\1 3.5'x1 5'Cameo MMGGLM 5535 3.5'x 1 5"Cameo MMG-W GLM 524 T x 35'HES TNT Ported Packer 5987 3 5'HES X-Nipple{2 813'pkg SlPS'. MIK Perforation Summary 3.5'NPG Single Sub 6305 Rei log I� 3.5'x1 5'Cameo MMGGLM ( 6323 Six SPF Interval ITVD) N' S-and 35'x 1 5 Cameo MMG-W GLM ( 6081 4.5" 6 T x 35'HES TNT Packer Ported 6299 CA Sand 3.5'HES X-Nrppie{2813'pkg) 6111 4.5" OB Sand t� 3.5'NPG Single Sub 6115 4.5 6 3.5'x1 5'Cameo MMGGLM 6125 Pert G ung wI Powerjet Charges 0 9 3.5'x 1 5'Cameo MMG-W GLM 6167 ci deg phamnp 35'I•ESX-Nipplel2.813'pkg 1 I 6207 3.5'I•ESXN-Nipple(2.813'pkg) ( 6227 2750'No-Go ID 3 S WLEG 6243 AINEMBERNIL 7"Float Cellar(PBTD) 6265' 7"float shoe 6247' DATE /REV BY CON? NTS MLNE POINT UNIT ?!2Gl1 0 Johnson, Proposed Comoieton Draft WELL M'G-06B API NO: 50-029- BP EXPLORATION (AK) MPG-08B PTD Page 8 2/10/2012 Dovon 14 BOP Schematic .. . . g g . k•;re ... 1 . 1 -• 0.-P:! L r13 ' I. ' . ',._ \i' !. • -• ' !- ' ?••• . a J. r i ,. Ill I- .1 I 1 i • &•-' _ I — PP1Ii okiti , ii ill —. n II „... ".,-;'• --.I , 1 1 1 I g N. ._,..1 !i i.-,•-i'1 iffi4ig , •_. 1 • ,;.,..„ . ... ......, '' .1., r . .+.,..1.1 ci. ' KU I .,- ‘–r. '. A 0,7 • ,... ! -6 ..••••_,A1 3 mr, ..... ...... I '-, .. . I . i. --- ..., fil : 1V t x At 2 t 'I " 4 . ..,1 6 • / i r 9 r$ '-' - ; t' N rl 1., el' 11 1-171r -1;. III i i 1 .-1 7.:V." - . . 4 ...r I 7-. 1• 1 ill ... 1. V V_[_ .--.! I I 1_'-‘.... .— 4. •_i• , ,,, 11:631,1t110(_;::_. 1 .., / . .. .- ...- 7.9. --„ I r7. 1 MPG-08B PTD Page 9 2/10/2012 Doyon 14 Choke Manifold tin v t'0 j a a g 2 > c 0 0 y Q . > Fu) Z o dU o rc4 W = o N 0v w Ica R ® .— 0 t `o U '- 0 L - --� J az az ill Ilk a "'mil ....A......10:30tyagasoustw— .46,,‘, 4 tiojdr...,.... a c "MN MIL 11141 0 V E a u.. 03 tah.....);ILL ak11111 Gni/ O 0 hill 4k '4\ 4J i1111 40• 031 ria Adki, > a • J (2) 4111 rill _F. , _ . 10. : 1 : iw 0 r. 1 ., . >o ii i 11F < m i liti .114411 . 1 cci oW! m ¢' m i– (< V. --; ;--,' r." ND 2 rrr,mi Q) t NIllilt a.MPG-08B PTD Page 10 2/10/2012 MPG-08B 1/4 Mile Area of Review Top OA Reservoir Depth Structure Map J L Vtit 4 L- \� illi'—`,..v. u'l c ' d S ) _ / MGc-33 3wN04 S" ,�.1) 1 Ci p / t'. ETA 3 '3 r S MWh.39 /,7 5QN IN, \ - �l _ ) /' ‘S:,2 e \.._ 'V '195.6 , ---., i „4. ,:-_-_- ({ \ N - fitt+: M MPG-08B PTD Page 11 2/10/2012 MPG-08B Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. Decomplete - Schrader over pressure during decomplete is expected in MPG-08. A 1067 day SI-BHP on 8/6/2011 showed a 9.2 ppg equivalent. A 75 psi over balance will require a 9.6 ppg B. Production Hole - Schrader over pressure during drilling is expected in the Schrader "N" sands. Current best estimate for pore pressure in these sands is 9.15 ppg except for the Schrader NB which could be 9.4 ppg (Assumes over-injection due to good quality reservoir.) The Schrader "0" sands are expected to be normally pressured. The entire production interval could potentially be as low as 8.2 ppg or has high as 10.6 ppg. II. Lost Circulation/Breathing A. Production Hole - There are no potential faults crossing. Lost circulation problems in this area have not been significant and the lost circulation risk for this well has been characterized as "low" III. Kick Tolerance/Integrity Testing A. With the planned mud weights, the kick tolerance for the production section is 25.4 bbls with 12.9 ppg frac grad. B. Integrity Testing Test Point Test Depth Test EMW (lb/gal) type 9-5/8" shoe 20'-50' below the 9-5/8" shoe LOT 12.9 minimum V IV. Hydrogen Sulfide MPG-Pad is not considered an H2S site. The highest recorded H2S on the pad was 5 ppm. V. Faults No fault crossings are predicted for this well. VI. Close Approach Shut-in Wells: MPG-10, an active water injector, failed the major risk collision analysis at 3009' MD (MPG-08B). It passed minor risk collision analysis at 1:200. MPG-10 will be secured with a downhole plug in the tubing and shut in at surface prior to drilling. It will remain shut in until after MBG-08B has finished drilling. All other wells passed the major risk collision analysis. CONSULT THE MPS-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. MPG-08B PTD Page 12 2/10/2012 I - I N 2800 I - 20 in 21 2:�i X22' o _A '?....�; a F- THIS SURVEY G-8 a o "\)-)? U } I 29C J P O,\ ,y 4 I G-6 * �1? , PAD, % * 1 1 cl J r'l0 ;2 X33 5 • 34 I yA0--k) H PAD G-4 ■ c-3 • VICINITY MAP LEGEND N.T.S. G-2 ■ ■ EXISTING WELL CONDUCTORS G-1 ■ AS-BUILT WELL CONDUCTORS I I u,,,,,,,. I W '`� P ° °„ s ? ° y (, a ° / = , N 2000 E*: 4 9 Id ' °x�, , °°. S% AK 110, IOW t IF cc°o° ST:PHEN STOLL °r % • -�s�F°° 6726-S °-'"e"` , NOT1. DATES OF SURVEY: MAY 1-2, 1997 ,,-ita FESSIONA- �› JULY 16 AND AUGUST 2, 1994. ,t 2. REFERENCE FIELD BOOKS: MP97-04 (PGS 29-30) 3. ALASKA STATE PLANE COORDINATES ARE SURVEYOR'S CERTIFICATE ZONE 4, ALASKA, NAD 27 4. PAD SCALE FACTOR IS 0.999903725. I HECERTIFYSTHAT I AM PROPERLY REGISTERED AND LICENSE[, 5. HORIZONTAL/VERTICAL CONTROL IS BASED ON TO PRACTICE LAND SURVEYING IN G PAD MONUMENTS G-1 AND G-2. THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY 6. ELEVATIONS ARE BPX MILNE POINT DATUM M.S.L. MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF MAY 2, 1997. LOCATED WITHIN PROTRACTED SEC. 27, T. 13 N., R. 10 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS Y=6,014,361.06 N 2,499.73 7026'59.539" 70.4498719' FSL G-5 X= 557,169.42 E 1,135.60 149'32'00.897" 149.5335825' 29'4 3,434' FEL Y=6,014,420.84 N 2,560.22 70'27'00.128" 70.4500356' 1,985' FSL G-6 X= 557,160.16 E 1,134.85 149'32'01.155" 149.5336542' 29,3' 3,443' FEL Y=6,014,480.29 N 2,620.35 70'27'00.713" 70.4501981' 2 045' FSL G-7 X= 557,151.18 E 1,134.33 149'32'01.406" 149.5337239' 29'4 3,451' FEL Y= 6,014,538.91 N 2,679.62 70'27'01.290" 70.4503583' 2,104' FSL G-8 X= 557,142.41 E 1,133.90 149'32'01.650" 149.5337917' 29'6 3,460' FEL F. Robert,., DRAW SS/JJ --__ �11411 � CHECKED: RFA BP BP EXPLORATION �1 DATE: — -- V 444 5/8/97 /f DRAMS. S,,EE1: — yccy �s.� J09 No.GPADAS.DWG MILNE PT. UNIT G-PAD 1 7/8/97 CORRECTED PUNT ROTATION ARROW SS LON LLT%T.bO scAL WELL CONDUCTORS AS-BUILT 0 5/6/97 ISSUED FOR AS—BUILT INFORMATION JJ RFA mrlvm LAT""'°"` WELLS G-5, G-6, G-7 AND G-8 1 °F 1 NO. DAIS REVISION BY CHK .04. 4 ALAS. .05031"= 200. `0 Ph '422NQn 82qt8 m8WP2a Vminvo m8 u1C ON1(0)0 1A'omoe a.jw.4` m((011SCO1oo ^an m Mv1§111 iLc)000 ll I n31 4LL a 0 a mm y p pN C to 183:=8 am:1mN :22.28A�pppM MD)O 1No O N r. r- 8288§▪C 0MOLD aD N8lD(O�O f")ON a a N c (m mm�o((U mcorNON- maom(0m _ Z M 8888p88 88888 88888 88888 Fa8 N W W m(0 0(rn 0800 .m01U(O rNM M 1010 c0 m r r r r r o vovvv oriri0(U viriciviri ri1) 1) 0vi vi vi d d�+ O U_ E O rm m m m 0 0 0 00000 OOOOO 00000 p 0 _i ..- ,-M000 00000 00000 00000 p0 122 0g 0 0 0 0 0 44444 O O O 0 0 44444 O O Cm CD MIV- a a'a'a'a'a' a'a'a'a'a' a'oJJJ pJ JJ�i IA 0 OO88 �- 80(000 -W O(0W 2m82'.; t0«GD= = x_.7.V.00 00 t-M ONtDp� N M anoint: mMNMt6+I M NmN NNm� pmION cn((pp Nr1p j ilm 88 ,r E; o co N cop Z 2 8 m O C N K �`$�oc- ���O'e 4c71��fi� rn�i 1S,�O0Npi�`c- 1N 1N am`pa�i�a con U~00 ca m M N p L v v y v v v 9 N ;O r c?t�I th c?c?4 C'c5 73 0 C W 0 N e pOp o N m Oa N m Z N= m _-- SW Ol m 1:m O•C W 0 8 r�> m 1(00Oa'1M0NN11mQmFON> �1pp .- - .9.2 m ZE ONt000)0 NNCmm MN000i((0 opa(010NN ar } C� X6ap46�pp�OOm 6 m 46 6666.4 Ol0 (801 N V r 010 0,- .NN.. .-....m0 g(O(0CMM ()t6') L))NNm t t rvinmm m Z z m 880 o 0 0 d d o 6CL ct C ° 0 �a a Q) '6 '5 c E m E v ^ u63 IX 5 Ern i awl o r c m e o a•- 'E . 5 "' 21117-' 5,111 d O o 0 ` O ad' C d Q dC Uj dd .. ` y Vie' 0 .-7-4-0N0,- r- V m V r N 1� pp N,- .-0 aa 0 Wn,mmON MN0 0 M LL Ch n - - CC0 aOU0O , O N 600'-6 r1..:6.-6 rNOM NmNV ca0 0a00NcM< 0MLOM .-coONM NM "6 O -J aa, a, d `O O C O C O d N0 00223 MOOppM thO OM (OO d0- co 0)w w U 7, U Nu N '6 O % T.it° aVUu a- a > a C - C C c L , c YY00Am2AA:0 ° ud m _ y m » i- i- m`2 ~ 202X71-J ^ cwt m0. �, m�MMm �� 0� mm��$ �� K pp�0(m(0N p: q mm 1p 0_ {.L �' F l0(O RQO V DD OION NNiN0m4C0 mo(UN ,-Na C /y� CD NNNNN 1NO 1NOg g'iON N NtOM M 8,7-97r; 00 CO W ❑ O 1 c Kil N C m 0 0)M ... D) ,N ..... p O CL1/4� y NM Nt0 N-Y)0 qrn 10(U-(Uq q01 Or 0 p0 d0p�mm1O0pp� 1� Cpp�pm�61p (Ui0 co�N1y1 oirrpod6p�ci mm G 488100 V 1"10810 r7r7RP00 OD WOO t0 NNNNN NNNNN NNMMffOO //00 Mvv a et0 i 2 J to m co W g g W . 2M"W 0.-.-0510 ..-000Q,- W M mv-,- NI, w w- 0f m OOO 0N OON1 0 Zo O OO6 MM66 1() mOM^ vvvov 76666 NV M 00 2U NM E MM MMMM H 1: a'K oinIZZ O m �� a W ..J 1(-y 1-(� Olt C .2--(/) LL J N N (N O 3 ,-.2i,;(6 0, 0 -D _ E(O W J J N Y)m0a Ormr -�N'O O aO LLW W '"'m Y ( 00)O C'a"' 4N(N0 S0ON( F,888:2 -� M ()8 a�pgO11p0-LL N c 0 C 0 M W ��NNM m6OMm 01010610 rc66Mm m 6a'+010)0,0 M 2 7 o j O_00 N m.� 00000 0010(010 )Ooo,n(O ,nntvm O am0(0 Y J Mmr p((OOJ 2 m��8� g �rnt[fno o_ rn onm �'u_WC0 a W cC7C7050 7 S.21 r M 6m a a a c a C m 0 010 N LL co E22D2�0Z22oo 3Cl(0 NN fC 88888 88"1pp88 8 8pop-p8 p8 888888Z 80 8S1= NrN0( 8888 t�cg)(U(10 W 8�)t001N00 (r)(00 N~L 0 E d N N N N N M MMM M 16 O d 01 / D m 0 0: 1) 0 o1 ci o re d SS m2O m a Ce ou yg u T $ 0. O E L o . dOW0 10 a . w-a- _J -2 ;.2 0 N O lICIlt d O raO d 8. - E ". Vado = ❑ : -° o 8 m0 ,..2 aLl a ii Z 0 2 C c oc U d 7 j moTOd 00 E ,0 a add ` O ZCOOOoma E 7 a- 0 O 4O Et a0- 'C K 0 ii to 3 m m N N F O J J 0 U' o N Y WO 2 N-I- O • by Schlumberger WELL MPG-08B (P9) FIELD STRUCTURE Milne Point Unit MPG MagneIc Parameters Surface Location N0D27 islacka State Plane,Enna 00,US Feet MSc019000us Model. BGGM 2011 Dip: 51.000' Date: 95M 21,2012 lac. N 7027 1.290 Northrop 8314538 91 655 Grd Cony:0.43933305' Slot MPG 08 NO Rel: RKB(N3.9tt anew MSL) Mag Dec: 20.712' FS'. 57648.701 Lon: W 109 32 1 850 Eas9ng: 557142.41909 Scale Fad:0.99990371 Plan: 51PG-085(P9) Spry Date:January 12,2012 0 750 1500 2250 3000 3750 0 0 RTE 750 •••• a 750 1500 1500 0 0 (0 2250 2250 cN 1114n Survey U OP Cry 4/100 11/0 End Cry • 3000 a a 3000 Cry 4/100 3750 3750 MPG-08B Heel tgt MPG-08B(P9 4500 PG-08 :TD 4500 0 750 1500 2250 3000 3750 Vertical Section(ft)Azim=355.13°Scale=1:600(ft) Origin=0 N/-S,0 E/-V by 0 Schlumberger WELL MPG-08B (P9) FIELD Milne Point Unit STRUCTURE MPG Magw4c Parameters Surface Loca0on 334027 Alaska Vote Plane,Zone 04,US Feet Miscellaneous Mode: BGGM 2011 Dip: 81 040' Dote: 481121,2012 at N 7027 1.290 Northing 6014538.9151JS Grid Cony.0.41933345' Slot: MFG-08 NO Ref: RKB(63.9R above MSL) M49 Dec: 20.712' FS 57648 785 Lon: W 14932 1650 Eawan° 557142415118 Scab Fact:099993371 Plan: MPG-066(P9) Sny Date:January 12,2012 -1000 -500 0 500 MPG-08B Fault#1 4500 4500 MPG-08B(P9) 4000 0 4000 1D N MPG-08B Heel tgt MPG-08B 5%cont.dd tgt MPG-088 Heel tgt 3500 3500 Cry 41100 A A 3000 PG-U8 3000 z o ✓ B a) 2500 a 2500 to to V V V 2000 a 2000 End Cry 1500 1500 1000 pp C 1000 K TienN Survey MPG-08 -1000 -500 0 500 «< W Scale=1:500(ft) E >>> Project: Milne Point ppyy���� Site: M Pt G Pad 470& 13/MpG-13 Well: MPG-08 Wellbore: MPG-08B Plan Design: Plan #9 MPG-08B 3900 3g01 3700 4000 7,. 31p0 4613N cont. A -08/Plan#9 MPG-088 3750 . 2910 3500 3500 4J-08B Top OA Tgt 3500 3900 3300 3250 ti 3300 0BIMPG-O8 3700 3000— 3100 -+ 4300 1 2750— 2100 41003500 c 2500— 3900 /11 G Z 3300 0 31'i 3900% PG�aP 2900 `n 2250 .c L 0 3500 0 o 3100 Z2000 V' 3300 L 5 o w 1750 V%3104' 2500 2900 2,00 2700 1500 N %% 290 cl 3 ��yp,� c 1,\"OO 1250 O :43 �i u 0, 9 5/r 2500 1000- 00._ 03 750- - o _ ,,h oo 2300 a co 500— oo,o a. ii. _ _ v o \ o 250 �_ o �. lb II2 0 o - 318"IMPG-18wp07 g � mMtoc, ao �., o $ $ og _ U 250— cn -0( . . -- I 11 I 1 1 1 1 I I 1 1 1 + 1 I T` _f 1 1 1 1 [r I� 0 0,, -2000 -1750 -1500 -1250 -1000 -750 -500 -250 0 250 500 750 0 1000 1250 1503 West(-)/East(+)(500 Win) .oG-" lne Project:WeSitll: Pad MIPG 08 Point 0a1tJ4G•o0P "9 G.° 08 MPG-OS/Plan#9 MPG-08B Wellbore: MPG-08B Plan eRG Design: Plan #9 MPG-08B 3000 3p00 1600— MPG.1011RG"A0 14 1550— \ . V 2800 - 2g00 1500- 29p -, 2300 1450— \ , , op 1400— 2700 0 1350 Z�0 2100 .� 1300— -- 0 0 2600 +1250— 2..'. 00 t 'Co Z 1200— - - 0 V7 1150— • �� 2°C) •u• 1100— 1050— 1 21,00 9 5/8" 1000— 950— \illk .50° _ 300 900— — 850— _ 800— \ 2100 750 , r r l , r „ i r , , , l „ l , . 1 1 1 I 1 „ I i l 1 , I I I I , , l , , I , l , , , , r , „ i r i 1 -1000 -950 -900 -850 -800 -750 -700 -650 -600 -550 -500 -450 -400 -350 -300 West(-)/East(+) (100 Win) 50— • — — 47— 45— 42— 40— 37— 35— 32— -G-08A(dupfcatepM• cc• c30- • - u) - o27— N _ c6 _ 0. a) - Co 25— a) - c - a) - U 022— '8 22— c - a) _ 020- 17— Project: Milne Point Site: M Pt G Pad Well: MPG-08 15— Wellbore: MPG-08B Plan Design: Plan#9 MPG-08B 12— _ 10- 7- 5- 2—__ Equivelant Magnetic Distance 0 "111108$01141111010"Y`rY`1 i i I l i i i ( i i i i I i II i I i i i i I i i I i i i i i i i i I i i i i IIII I i i I i 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 4100 Measured Depth (200 ft/in) Land Administration System Page 1 of 2 Alaska DNR Case Summary File Type:ADL File Number. 25906 See Township,Range,Section and Acreage? ° Yes No New Search i File: ADL 25906 maP Search for Status Plat Updates As of 02/16/2012 Customer: 000107377 BP EXPLORATION(ALASKA)INC PO BOX 196612/900 E.BENSON BL ATTN:LAND MANAGER-ALASKA ANCHORAGE AK 995196612 Case Type:784 OIL&GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location:DOG DIV OIL AND GAS Case Status:35 ISSUED Status Date: 02/19/1965 Total Acres: 2560.000 Date Initiated:11/02/1964 Office of Primary Responsibility:DOG DW OIL AND GAS Last Transaction Date:10/23/2003 Case Subtype: NS NORTH SLOPE Last Transaction:AA-NRB ASSIGNMENT APPROVED Meridian: U Township: o13N Range: oioE Section: 27 Section Acres:640 Search Plats Meridian: U Township: o13N Range: oioE Section: 28 Section Acres:640 Meridian: U Township: o13N Range: oioE Section: 33 Section Acres:640 Meridian: U Township: o13N Range: omoE Section: 34 Section Acres:64o Legal Description 11-02-1964***SALE NOTICE LEGAL DESCRIPTION*** U-3-1-14 ALL SECTION 27 Ti3N,R1oE,UM 64o ALL SECTION 28,"""64o ALL SECTION 33,"""64o ALL SECTION 34,"""640 CONTAINING 256oACRES,MORE OR LESS. 11-02-1988***UNITIZED*** T.13N, R.ioE.,U.M. SECTION27:ALL 640 SECTION28:ALL 64o SECTION 33:ALL 640 SECTION 34:ALL 640 CONTAINING 256oACRES,MORE OR LESS. 7-30-91***PARTICIPATING AREA LEGAL DESCRIPTION*** SCHRADER BLUFF PA SAME AS THE UNIT LEGAL DESCRIPTION ABOVE,DATED 11-2-88 http://dnr.alaska.gov/projects/1as/Case Summary.cfin?FileType=ADL&FileNumber=2590... 2/16/2012 Land Administration System Page 1 of 2 Alaska DNR Case Summary File Type:ADL File Number. 25516 See Township,Range,Section and Acreage? 0 Yes No New Search_] File: ADL 25516 ,.wP_' Search for Status Plat Updates As of 02/16/2012 Customer: 000107377 BP EXPLORATION(ALASKA)INC PO BOX 196612/900 E.BENSON BLATTN:LAND MANAGER-ALASKA ANCHORAGE AK 995196612 Case Type:784 OIL&GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location:DOG DIV OIL AND GAS Case Status:35 ISSUED Status Date: 01/22/1965 Total Acres: 1280.000 Date Initiated:11/02/1964 Office of Primary Responsibility:DOG DIV OIL AND GAS Last Transaction Date:09/11/2009 Case Subtype: NS NORTH SLOPE Last Transaction:PACN1 PARTICIPATING AREA CONTRACIT D Meridian: U Township: o>3N Range: 010E Section: 15 Section Acres:64o Search Plats Meridian: U Township: oi3N Range: moE Section: 22 Section Acres:640 Legal Description 11-02-1964***SALE NOTICE LEGAL DESCRIPTION*5* U-3-1-11 ALL SECTION 15, T13N,R10E,UM 640 ALL SECTION 16, " " " 640 ALL SECTION 21, " " " 640 ALL SECTION 22, " " " 640 CONTAINING 2,560 ACRES,MORE OR LESS. ************************************************************** 05-28-1980***UNITIZED/SEGREGATION LEGAL DESCRIPTION*** LANDS REMAINING-MILNE POINT UNIT TI3N,R10E,UM SECTION 15: ALL,640 ACRES SECTION 22: ALL,640 ACRES CONTAINING APPROXIMATELY 1,280 ACRES. ************************************************************** 04-23-1986***PARTICIPATING AREA ESTABLISHED LEGAL DESCRIPTION*** MILNE POINT PARTICIPATING AREA T13N,R10E,UM SECTION 15: ALL 640 ACRES CONTAINING 640 ACRES,MORE OR LESS. ************************************************************** 07-30-1991 **PARTICIPATING AREA LEGAL DESCRIPTION*** SCHRADER BLUFF PA SAME AS THE UNIT LEGAL DESCRIPTION ABOVE,DATED 5-28-80 ************************************************************** 02-01-2005 **SAG RIVER PARTICIPATING AREA APPROVED*** LEGAL DESCRIPTION MILNE POINT UNIT SAG RIVER PARTICIPATING AREA TRACT 4(PARTIAL) T.13N.,R.10E.,UMIAT MERIDIAN,ALASKA SECTION 15: N2,SE4,480.00 ACRES; SECTION 22: NE4,160.00 ACRES; THIS TRACT CONTAINS 640.00 ACRES,MORE OR LESS. ************************************************************** 12-01-2008**SAG RIVER PA CONTRACTED,LEASE CONTRACTED FROM PA** http://dnr.alaska.gov/projects/las/Case Surnmary.cfrn?FileType=ADL&FileNumber=2551... 2/16/2012 TRANSMITTAL LETTER CHECKLIST WELL NAME , -11q9 PTD# Development ✓ Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: A4 4/E- /042/4/7 POOL: ...._—cH. ',44 /me I . Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. 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