Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
201-093
1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Reservoir Abandonment 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7,207'N/A Casing Collapse Conductor N/A Surface 2,020psi Intermediate 5,410psi Liner "A"11,780psi Liner "B"11,780psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng MILNE PT UNIT I-04AL1 MILNE POINT SCHRADER BLUFF OIL N/A 4,070' 7,207' 4,070' 1,164 N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 10/10/2024 3-1/2" x 7" Baker Premier, 7" Halliburton VTL & 7" Baker ZXP and N/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025906 201-093 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22068-60-00 Hilcorp Alaska LLC C.O. 477.07 Length Size Proposed Pools: 115' 115' 9.3# / L-80 / EUE 8rd TVD Burst 4,223' 11,200psi MD N/A 11,200psi 3,520psi 7,240psi 2,354' 3,999' 4,069' 2,599' 4,536' 115' 13-3/8" 9-5/8" 7" 2,599' 2-3/8"2,685' 4,536' 7,184' See Schematic 2,303' See Schematic 3-1/2" 4,125'2-3/8" 4,118 MD/ 3,622 TVD, 4,330 MD/ 3,812 TVD & 4,457 MD/ 3,927 TVD and N/A Todd Sidoti todd.sidoti@hilcorp.com 777-8443 6,834' Perforation Depth MD (ft): No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:21 pm, Oct 02, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.10.02 13:51:15 - 08'00' Taylor Wellman (2143) 324-573 DSR-10/2/24 Lateral SFD 10/4/2024 10-407 SFD * Approved for abandonment of the '04A' and '04AL1' lateral wellbore sections. SB oil pool N sands remain open to perforations. SB Oil Pool is not isolated. * State witness slickline tag of OA lateral TOC (4450' MD). MGR03OCT24JLC 10/4/2024 Gregory Wilson Digitally signed by Gregory Wilson Date: 2024.10.07 13:23:11 -08'00'10/07/24 RBDMS JSB 100824 Res Abandon Well: MPI-04AL1 Date: 09/23/2024 Well Name:MPI-04 API Number:50-029-22068-60-00 Current Status:SI Injector Pad:MPU I-Pad Reg. Approval Req’d?10-403 PTD:201-093 Regulatory Contact:Tom Fouts Job Type:Cementing First Call Engineer:Todd Sidoti Phone:(907) 632-4113 Cost Estimate:$200,000 IOR:N/A Second Call Engineer:Ryan Lewis Phone:(303) 906-5178 Current Bottom Hole Pressure: 1524 psi @ 3600’ TVD SBHPS ran 1/26/24 (8.14 PPGE) MPSP:1164 psi Gas gradient to surface 70 Degree Deviation:~4670’ MD Min ID:2.813” @ 4008’ MD Background: MPI-04 was drilled and completed in 1991 as a vertical Schrader Bluff ESP lifted producer. It was converted to an injector in 2023. The objective of this program is to abandon the OA and OB laterals so that new well J-32 can be drilled. Well History: x 9/1/24 MIT-IA passed to 2033 psi. Non-Sundried Procedure Steps: Slickline & E-line: 1. MIRU SL and PT lubricator to 250 psi low / 1500 psi high. 2. Drift to deviation with dummy 3.5” plug. 3. RDMO SL. 4. MIRU EL and PT lubricator to 250 psi low / 1500 psi high. 5. RIH with 3.5” cement retainer and set at the bottom of the 9.98’ 3.5” pup joint below N sand screens @ ~4450 (see attached screen completion diagram). 6. RDMO EL. Sundried Procedure Steps: Coil & Cementers: 1. MIRU CTU and Cementers. 2. MU and RIH with BHA including stinger for 3.5” cement retainer. 3. Fill CT x TBG annulus with produced water and establish injectivity pressures from 0.5 BPM to max rate in 0.5 BPM increments. 4. Fill CT with produced water and establish injectivity pressures from 0.5 BPM to max rate in 0.5 BPM increments. 5. Batch mix 40 bbls of cement and pump down CT per following schedule. Volumes are based on 2 times length of both laterals (19.5 bbls). a. 5 bbl freshwater spacer b. 40 bbls cement c. Chase cement with produced water Res Abandon Well: MPI-04AL1 Date: 09/23/2024 6. Target squeeze pressure is 1000 psi over baseline injectivity. Hold squeeze pressure for 30 minutes. a. Contact OE to discuss batching up another 20-40 bbls of cement and attempting re- squeeze depending on pressure and rate trends during job. 7. After 39 bbls displaced through retainer, unsting and lay remaining barrel on top. 8. Contaminate remaining cement with gel pill while taking returns to surface. Do not disturb ~20’ cement cap on top of retainer. a. If unable to take returns to surface we can stuff contaminated cement away into N sand screens and chase with 50 bbls produced water. 9. POOH chasing final gel pill at 80%, reciprocate multiple times across screens and jewelry. 10. Freeze protect tubing. 11. Wash up cementers. 12. RDMO CTU and cementers. Slickline: 1. Notify AOGCC 24 hours in advance in order to provide opportunity to witness tag and test. 2. MIRU slickline. 3. RIH with s-bailer and tag cement top at ~4450’. POOH. 4. RDMO SL. Res Abandon Well: MPI-04AL1 Date: 09/23/2024 Res Abandon Well: MPI-04AL1 Date: 09/23/2024 Attachments: Current Schematic Proposed Schematic 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Convert to Injector Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 7,207 feet N/A feet true vertical 4,070 feet N/A feet Effective Depth measured 7,207 feet feet true vertical 4,070 feet feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3# / L-80 / EUE 8rd 4,223' 3,715' 3-1/2" x 7" Baker Premier 7" Halliburton VTL Packers and SSSV (type, measured and true vertical depth)7" Baker ZXP N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Wells Manager Contact Phone: 4,118, 4,330 & 4,457 3,622, 3,812 & 3,927 323-054 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Brian Glasheen Brian.Glasheen@hilcorp.com 907-564-5277 measured true vertical 950 4,069' 4,125' 11,780psi 11,780psi 3,520psi 7,240psi 11,200psi 11,200psi 3,999' BurstMD 115' 1240 Size 115' 2,354' Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 2460 0 00 727 TVD 2-3/8" 2-3/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 201-093 50-029-22068-60-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: Packer ADL0025906 MILNE POINT / SCHRADER BLUFF OIL MILNE PT UNIT SB I-04AL1 Plugs Junk measured measured Length Liner "B" 2,685' 2,303' Casing Conductor 7,184' 6,834' 4,536' 2,599'Surface Intermediate Liner "A" 4,536' 13-3/8" 9-5/8" 7" 115' 2,599' N/A Collapse N/A 2,020psi 5,410psi Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.05.15 08:40:01 - 08'00' Taylor Wellman (2143) RBDMS JSB 051623 WCB 1-8-24 _____________________________________________________________________________________ Revised By: TDF 5/5/2023 SCHEMATIC Milne Point Unit Well: MPU I-04A Last Completed: 4/19/2023 PTD: 201-092 14 16 TD =7,207’(MD) / TD =4,070’(TVD) 2 Orig. KB Elev.: 52.0’/ Orig. GL Elev.: 35.0’ RKB – Hanger: 23.85’ (Doyon 16) 7” 1 9-5/8” 3 5 17 “OA” Lateral PBTD =7,207’(MD) / PBTD =4,070’(TVD) “OB” Lateral 6 8 N Sands 13 4 13-3/8” 7 9 10 11 12 15 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 13-3/8" Conductor 54.5 / K-55 / Welded 12.459” Surf 115' N/A 9-5/8” Surface 36 / J-55 / BTC 8.765” Surf 2,599’ 0.0773 7" Production 26 / L-80 / BTC 6.151” Surface 4,536' 0.0382 2-3/8” Liner “A” 4.6 / L-80 / ST-L 1.901” 4,499’ 7,184’ 0.0039 2-3/8” Liner “B” 4.6 / L-80 / ST-L 1.901” 4,531’ 6,834’ 0.0039 TUBING DETAIL 3-1/2” Tubing 9.3 / L-80 / EUE 8rd 2.992” Surface 4,223’ 0.0087 JEWELRY DETAIL No Depth Item 1 4,008’ 3-1/2” HES Sliding Sleeve - Min ID 2.813’ 2 4,062’ Baker Zenith Gauge Carrier (BPHG) 3 4,118’ 7” x 3-1/2” Baker Premier Packer 4 4,180’ 3-1/2” X Nipple with RHC -Min ID 3.813” 5 4,192’ 3-1/2” WLEG – Bottom @ 4,223’ 6 4,330’ 7” Halliburton VTL Packer (3.880” ID) 7 4,348’ 3-1/2” Halliburton Poroplus 250 micron screen (3 joints; 2.992” ID) 8 4,456’ Baker Seal Assembly, 5.75’ Long (4.50” ID) 9 4,457’ 7” Baker ZXP Packer 10 4,475’ 4-1/2” X Profile (3.813” Packing Bore ID) 11 4,478’ 4-1/2” WLEG (3.958” ID) 12 4,499’ Baker Deployment Sleeve (4” GS Fishing Neck; 3.00” ID) 13 4,510’ Flow-thru Whipstock 14 7,184’ 2-3/8” Btm Baker Guide Shoe 15 4,531’ Baker Deployment Sleeve (4” GS Fishing Neck; 3.00” ID) 16 6,834’ 2-3/8” Btm Baker Guide Shoe 17 4,550’ Cement Retainer OPEN HOLE / CEMENT DETAIL 13-3/8" Cmt w/ 485 sx of PF C in 30” Hole 9-5/8” Cmt w/ 1,111 sx PF E, 244 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 260 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 400’ MD Max Wellbore Angle = 93.5 deg @ 4,971’ MD 25.23 deg @ 4,500’ MD WELLHEAD Tree 2-9/16” CIW Wellhead 11” x 2-7/8” EUE Top & Bottom FMC Tubing Hanger GENERAL WELL INFO API: 50-029-22068-01-00 Sidetracked & Liners Run by Nabors 3S – 7/11/2001 Screens & ESP Completion by Nabors 4ES – 7/19/2001 ESP Replacement by Nabors 4ES – 11/10/2005 ESP Replacement by Nabors 4ES – 10/30/2009 ESP Replacement, Add Y-Tool by Doyon 16 – 2/20/2014 ESP Replacement by ASR – 6/23/2016 Convert to Injector by ASR – 4-/19/2023 LATERAL WINDOW DETAIL Top of “OA” Window @ 4,510’ MD; Bottom @ 4,515’ MD; Angle @ top of window is 25 deg Top of “OB” Window @ 4,536’MD; Bottom @ 4,542’ MD; Angle @ top of window is 25 deg Well Name Rig API Number Well Permit Number Start Date End Date MP I-04A ASR 50-029-22068-01-00 201-092 4/12/2023 5/6/2023 4/14/2022 - Friday Continue to test BOPE with 2 7/8" and 3 1/2" test joints to 250 low / 2500 high for 5 min each. Preform accumulator drawdown test.. R/U ESP sheave and ESP pulling equipment, center stack with chains and binders. Pull test plug and BPV, BOLDS - tubing on vacuum. M/U landing jt and TIW valve, Unseat hanger with 46K, up wt, 42K. Cut ESP and heat trace cables and prep to pull over sheave to spooling unit. L/D hanger and landing jt. L/D ESP completion. 4/12/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Notify AOGCC of upcoming BOP test @ 10:00hrs. N/D tree and N/U BOP's, Spot cellar box and mud boat. Continue Demob equipment from previous well. Lower mast and send carrier in to get serviced, Replaced hyd winch. Continue Demob equipment from previous well. Spot TP and Co.Man shacks. and misc equipment. Spot rig floor 4/13/2022 - Thursday Spot and level rig and pits, install rig floor and spacer spool. spot heaters. hook up electrical lines to rig. Raise mast and guy lines, move adjacent well house. remove rack stabilizers and install pins.. Hook up koomey lines and pressure up koomey, Function test BOP's. R/U Glycol heater, R/U pump lines and winterize rig. N/U riser, spacer spools and bird bath, position stack with chains and boomers. Spot catwalk and pipe sheds, spot spooling unit. R/U choke and kill lines, repair and install 6" flowline, complete rig acceptance check list. M/U test jts and fill stack, test BOP's w/ 2 7/8" and 3 1/2" test jts. to 250 low/ 2500 high for 5 min each. Continue to POOH laying down ESP completion and assembly. Recovered 1 Glm, 1 XN nipple 130 jts 2 7/8" tubing - 17 bad jts / 113 good jts. 39 CC clamps, 97 Dual channel clamps, 439 5' clamps, 3 stainless bands 4 pump clamps, 3 protectroliizers, 2 flat gaurds. R/D ESP equipment, clean and clear rig floor, and pipe shed. Install wear bushing and run in 2 lock downs. Cont cleaning up rig equipment and rack and tally DP. P/U scraper BHA. RIH with 3 1/2" DP to 4332' and tag packer with 5k. POOH and reciprocating scraper from 4,180 to 4,100'. 4/15/2022 - Saturday Continue to log well ( CBL) 3340' TOC.. R/D wireline equipment. Pull wear bushing and change out handling equipment for completion. P/U 3 1/2" , 9.3#, L-80 EUE Injection completion - WLEG, XN nipple, Packer, Zenith Gauge carrier and sliding sleeve to 2794' - Had to work thru tight spot at 2745' with 16K set down. tested tech- wire after tight spot.. Breaks not functioning properly, trouble shoot system and adjust linkage on main hydraulic pumps.. P/U 3 1/2" , 9.3#, L-80 EUE Injection completion f/ 2794' t/ 4207'. P/U tubing hanger and terminate I-wire, land hanger - up wt 37K. dn wt. 25K, st wt. 28K, EOT @ 4,222', Packer set depth 4,129'. 71 cross collar clamps ran. RILDS R/U to freeze protect well, PJSM. Pump 60 bbls inhibited brine, followed by 52 bbls DSL down annulus taking returns up tubing. 4/16/2023 - Sunday Cont. to POOH with scraper BHA. Service rig and repair hose on radiator. Cont. to POOH with scraper BHA and L/D same. M/U 7" test packer. RIH w 3 1/2" WS to 4160' and rig up power swivel. Set test packer @ 4160' and fill IA ( 11bbls). test 7" casing to 2000psi for 30 min. (good test). release packer. Break circulation to clear oil from WS. 3BPM @ 350 psi. pumped 36 bbls, returned 20 bbls. R/D power swivel. POOH w 3 1/2" WS and L/D test packer. R/U wireline and RIH with CBL to 4,320'. CBL log out of hole to surface. R/D wireline. Note, had to POOH and add centralizers to tool string due to poor log quality. 4/17/2023 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP I-04A ASR 50-029-22068-01-00 201-092 4/12/2023 5/6/2023 Hilcorp Alaska, LLC Weekly Operations Summary Finish freeze protecting well and R/D pump truck. Drop ball and rod, Set packer and test tubing to 2700psi for 30 min, bleed down tubing to 1000 psi and pressure test IA to 2000 psi for 30 min.. Blow down lines, Pull and break down landing jt. Install BPV, Clean pipe shed, rig floor and pits, P/U johny wacker and flush stack with new pump. Drain gas buster and blow down all lines. Demob pipe sheds and catwalk. N/D bird bath, flow line, pop-off valve and riser spools. Release rig. 4/18/2023 - Tuesday Well Name Rig API Number Well Permit Number Start Date End Date MP I-04A ASR 50-029-22068-01-00 201-092 4/12/2023 5/6/2023 4/21/2022 - Friday No operations to report. 4/19/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary WELLHEAD BOP stack pulled, clean tbg hgr void, install new RX54 gasket. PU 4 1/2 " tree/adapter, run 1/4" tech line through adapter and land. Torque to speck, term. tech line and test 500/5000 (PASS). Pull 4" Bpv w/ T bar. All valves incorrect position and tree cap/manifold installed. WELL SHUT-IN ARRIVAL. PULL BALL & ROD, 3-1/2" RHC FROM X-NIPPLE AT 4,180' MD. PUMP 9 bbls 60/40 DOWN TUBING. WELL SHUT-IN ON DEPARTURE, PAD OP NOTIFIED. 4/20/2022 - Thursday No operations to report. No operations to report. No operations to report. 4/22/2022 - Saturday No operations to report. 4/25/2023 - Tuesday 4/23/2023 - Sunday No operations to report. 4/24/2023 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP I-04A LRS 50-029-22068-01-00 201-092 4/12/2023 5/6/2023 5/5/2023 - Friday No operations to report. 5/3/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 5/4/2023 - Thursday No operations to report. No operations to report. T/I/O = 711/753/332 AOGCC MIT-IA 2000 psi Witnessed by Adam Earl **Passed** 0.90 bbls diesel to pressure up, first 15 min ia lost 81 psi, second 15 min ia lost 15 psi, FWP = 713/750/330 5/6/2023 - Saturday No operations to report. 5/9/2023 - Tuesday 5/7/2023 - Sunday No operations to report. 5/8/2023 - Monday This is the lateral of MPU I-04A, PTD 201-092 and sundry 323-053. See that 10-404 for further comments. -WCB AOGCC MIT-IA 2000 psi Witnessed by Adam Earl **Passed** _____________________________________________________________________________________ Revised By: TDF 5/20/2024 SCHEMATIC Milne Point Unit Well: MPU I-04A Last Completed: 4/19/2023 PTD: 201-092 14 16 TD =7,207’(MD) / TD =4,070’(TVD) 2 Orig. KB Elev.: 52.0’/ Orig. GL Elev.: 35.0’ RKB – Hanger: 23.85’ (Doyon 16) 7” 1 9-5/8” 3 5 17 “OA” Lateral PBTD =7,207’(MD) / PBTD =4,070’(TVD) “OB” Lateral 6 8 N Sands 13 4 13-3/8” 7 9 10 11 12 15 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 13-3/8" Conductor 54.5 / K-55 / Welded 12.459” Surf 115' N/A 9-5/8” Surface 36 / J-55 / BTC 8.765” Surf 2,599’ 0.0773 7" Production 26 / L-80 / BTC 6.151” Surface 4,536' 0.0382 2-3/8” Liner “A” 4.6 / L-80 / ST-L 1.901” 4,499’ 7,184’ 0.0039 2-3/8” Liner “B” 4.6 / L-80 / ST-L 1.901” 4,531’ 6,834’ 0.0039 TUBING DETAIL 3-1/2” Tubing 9.3 / L-80 / EUE 8rd 2.992” Surface 4,223’ 0.0087 JEWELRY DETAIL No Depth Item 1 4,008’ 3-1/2” HES Sliding Sleeve - Min ID 2.813’ 2 4,062’ Baker Zenith Gauge Carrier (BPHG) 3 4,118’ 7” x 3-1/2” Baker Premier Packer 4 4,180’ 3-1/2” X Nipple with RHC -Min ID 3.813” 5 4,192’ 3-1/2” WLEG – Bottom @ 4,223’ 6 4,330’ 7” Halliburton VTL Packer (3.880” ID) 7 4,348’ 3-1/2” Halliburton Poroplus 250 micron screen (3 joints; 2.992” ID) 8 4,456’ Baker Seal Assembly, 5.75’ Long (4.50” ID) 9 4,457’ 7” Baker ZXP Packer 10 4,475’ 4-1/2” X Profile (3.813” Packing Bore ID) 11 4,478’ 4-1/2” WLEG (3.958” ID) 12 4,499’ Baker Deployment Sleeve (4” GS Fishing Neck; 3.00” ID) 13 4,510’ Flow-thru Whipstock 14 7,184’ 2-3/8” Btm Baker Guide Shoe 15 4,531’ Baker Deployment Sleeve (4” GS Fishing Neck; 3.00” ID) 16 6,834’ 2-3/8” Btm Baker Guide Shoe 17 4,550’ Cement Retainer OPEN HOLE / CEMENT DETAIL 13-3/8" Cmt w/ 485 sx of PF C in 30” Hole 9-5/8” Cmt w/ 1,111 sx PF E, 244 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 260 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 400’ MD Max Wellbore Angle = 93.5 deg @ 4,971’ MD 25.23 deg @ 4,500’ MD WELLHEAD Tree 2-9/16” CIW Wellhead 11” x 2-7/8” EUE Top & Bottom FMC Tubing Hanger GENERAL WELL INFO API: 50-029-22068-01-00 Sidetracked & Liners Run by Nabors 3S – 7/11/2001 Screens & ESP Completion by Nabors 4ES – 7/19/2001 ESP Replacement by Nabors 4ES – 11/10/2005 ESP Replacement by Nabors 4ES – 10/30/2009 ESP Replacement, Add Y-Tool by Doyon 16 – 2/20/2014 ESP Replacement by ASR – 6/23/2016 Convert to Injector by ASR – 4-/19/2023 LATERAL WINDOW DETAIL Top of “OA” Window @ 4,510’ MD; Bottom @ 4,515’ MD; Angle @ top of window is 25 deg Top of “OB” Window @ 4,536’MD; Bottom @ 4,542’ MD; Angle @ top of window is 25 deg PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Schrader NA 4,383’ 4,392’ 3,860’ 3,868’ 9 March 1995 Open Schrader NB 4,411’ 4,428’ 3,886’ 3,901’ 17 March 1995 Open Schrader NC 4,443’ 4,451’ 3,915’ 3,922’ 8 March 1995 Open _____________________________________________________________________________________ Revised By: TS 9/17/2024 PROPOSED Milne Point Unit Well: MPU I-04A Last Completed: 4/19/2023 PTD: 201-092 15 17 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 13-3/8"Conductor 54.5 / K-55 / Welded 12.459”Surf 115'N/A 9-5/8”Surface 36 / J-55 / BTC 8.765”Surf 2,599’0.0773 7"Production 26 / L-80 / BTC 6.151”Surface 4,536'0.0382 2-3/8”Liner “A”4.6 / L-80 / ST-L 1.901”4,499’7,184’0.0039 2-3/8”Liner “B”4.6 / L-80 / ST-L 1.901”4,531’6,834’0.0039 TUBING DETAIL 3-1/2”Tubing 9.3 / L-80 / EUE 8rd 2.992”Surface 4,223’0.0087 JEWELRY DETAIL No Depth Item 1 4,008’3-1/2” HES Sliding Sleeve - Min ID 2.813’ 2 4,062’Baker Zenith Gauge Carrier (BPHG) 3 4,118’7” x 3-1/2” Baker Premier Packer 4 4,180’3-1/2” X Nipple with RHC -Min ID 3.813” 5 4,192’3-1/2” WLEG – Bottom @ 4,223’ 6 4,330’7” Halliburton VTL Packer (3.880” ID) 7 4,348’3-1/2” Halliburton Poroplus 250 micron screen (3 joints; 2.992” ID) 8 ~4,450’FH-1 Cement Retainer (Capped with ~20’ of cement) 9 4,456’Baker Seal Assembly, 5.75’ Long (4.50” ID) 10 4,457’7” Baker ZXP Packer 11 4,475’4-1/2” X Profile (3.813” Packing Bore ID) 12 4,478’4-1/2” WLEG (3.958” ID) 13 4,499’Baker Deployment Sleeve (4” GS Fishing Neck; 3.00” ID) 14 4,510’Flow-thru Whipstock 15 7,184’2-3/8” Btm Baker Guide Shoe 16 4,531’Baker Deployment Sleeve (4” GS Fishing Neck; 3.00” ID) 17 6,834’2-3/8” Btm Baker Guide Shoe 18 4,550’Cement Retainer OPEN HOLE / CEMENT DETAIL 13-3/8"Cmt w/ 485 sx of PF C in 30” Hole 9-5/8”Cmt w/ 1,111 sx PF E, 244 sx Class “G” in 12-1/4” Hole 7”Cmt w/ 260 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 400’ MD Max Wellbore Angle = 93.5 deg @ 4,971’ MD 25.23 deg @ 4,500’ MD WELLHEAD Tree 2-9/16” CIW Wellhead 11” x 2-7/8” EUE Top & Bottom FMC Tubing Hanger GENERAL WELL INFO API: 50-029-22068-01-00 Sidetracked & Liners Run by Nabors 3S – 7/11/2001 Screens & ESP Completion by Nabors 4ES – 7/19/2001 ESP Replacement by Nabors 4ES – 11/10/2005 ESP Replacement by Nabors 4ES – 10/30/2009 ESP Replacement, Add Y-Tool by Doyon 16 – 2/20/2014 ESP Replacement by ASR – 6/23/2016 Convert to Injector by ASR – 4-/19/2023 LATERAL WINDOW DETAIL Top of “OA” Window @ 4,510’ MD; Bottom @ 4,515’ MD; Angle @ top of window is 25 deg Top of “OB” Window @ 4,536’MD; Bottom @ 4,542’ MD; Angle @ top of window is 25 deg PERFORATION DETAIL Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)FT Date Status Schrader NA 4,383’4,392’3,860’3,868’9 March 1995 Open Schrader NB 4,411’4,428’3,886’3,901’17 March 1995 Open Schrader NC 4,443’4,451’3,915’3,922’8 March 1995 Open 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Convert to Injector 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 7,207'N/A Casing Collapse Conductor N/A Surface 2,020psi Intermediate 5,410psi Liner "A"11,780psi Liner "B"11,780psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Brian Glasheen Contact Email: Contact Phone: Authorized Title: Operations Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 2,303'11,200psi4,125'6,834'2-3/8" 9-5/8" 7" 2,599' 4,536' 2-3/8"2,685' MD N/A 11,200psi 3,520psi 7,240psi 2,354' 3,999' 4,069' 2,599' 4,536' 7,184' Length Size Proposed Pools: 115' 115' TVD Burst PRESENT WELL CONDITION SUMMARY 4,070' 7,207' 4,070' 1,164 N/A 115' 13-3/8" MILNE POINT STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025906 201-093 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22068-60-00 Hilcorp Alaska LLC SCHRADER BLUFF OIL N/A C.O. 477.07 MILNE PT UNIT I-04AL1 See Schematic See Schematic 2-7/8" Perforation Depth MD (ft): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: 6.5# / L-80 / 8rd 4,250' 2/20/2023 Halliburton VTL & Baker ZXP and N/A 4,330 MD/ 3,812 TVD & 4,457 MD/ 3,927 TVD and N/A Authorized Name and Digital Signature with Date: AOGCC USE ONLY Brian.Glasheen@hilcorp.com 907-564-5277 Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Meredith Guhl at 12:17 pm, Jan 27, 2023 323-054 Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2023.01.27 11:08:22 -09'00' David Haakinson (3533) DLB 02/03/2023 DSR-1/30/23 X MGR10FEB23 10-404 * BOPE test to 2500 psi. Annular to 2500 psi. * CBL to be run from ~4,300' MD to confirmed TOC on 7" inner casing. CBL emailed: melvin.rixse@alaska.gov * MIT-IA to 2000 psi after new completion run and packer set. * MIT-IA to 2000 psi after 5 days of stabilized injection. GCW 02/13/23 JLC 2/13/2023 2/13/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.02.13 14:27:43 -09'00' RBDMS JSB 021423 Convert to injector Well: MPI-04AL1 PTD: 201-093 API:50-029-22068-60-00 Well Name:MPI-04 API Number:50-029-22068-60-00 Current Status:SI Failed ESP Rig:ASR 1 Estimated Start Date:02/20/2023 Estimated Duration:5 days Reg.Approval Req’d? Yes Date Reg. Approval Rec’vd:TBD Regulatory Contact:Tom Fouts Permit to Drill Number:201-093 First Call Engineer:Brian Glasheen 907-545-1144 (M) Second Call Engineer:Taylor Wellman 907-947-9533 AFE Number:232-00048 Current Bottom Hole Pressure: 1524 psi @ 3600’ TVD SBHP on 1/26/20232 Maximum Expected BHP: 1524 psi @ 3600’ TVD 8.14 PPGE No new perfs Max. Proposed Surface Pressure:1164 psi Gas Column Gradient (0.1 psi/ft) Min ID:2.205” @ 4,165’ XN Nipple Brief Well Summary I-04 original well was drilled and completed in 1991 as a vertical Schrader Bluff ESP lifted producer. In July 2001 the well was sidetracked in both the Schrader Oa and Oba sands using coiled tubing. The N sands were left as initially completed with gravel pack and an ESP was run for artificial lift. In August 2005 the ESP failed and was replaced via RWO in November of 2005. The ESP ran until March of 2009 and then was replaced via RWO in October 2009. The ESP ran until March of 2012 and was replaced during RWO in February of 2014. During the RWO a caliper was run from 1050’ to surface as well as a Y-tool installed at the ESP to allow for access to the formation. That ESP failed in January of 2016 and was subsequently replaced in June of 2016 during RWO. During the RWO the ESP completion was pulled and indicated that sand had plugged the pump. A 7” casing scraper was run down to the top of the N sands gravel pack at 4330’. A clean out run was made with 2 7/8” tubing down to below the gravel pack at 4480’ with no obstructions encountered. A 7” RTTS packer was then run to 4300’, set and test to 1500 psi for 30 min. The new ESP was then run in hole. That ESP stopped lifting fluid in March of 2017. A coil tubing FCO was performed in November 2017 which was able to tag the top of the pump at 4179’ CTMD. Acid was place on top of the pump and were unable to squeeze. Multiple attempts were made to run the ESP but would not surface fluids. The well has remained SI since that time. AOR Attached for conversion to injection. 7’’ Casing tested 6/22/2016 to 1500 psi Objective x Pull ESP replace with an injection string Pre-Rig Procedure Non Sundried work: 1) OA integrity test. PPPOT-T to 5000 psi. PPPOT-IC to 3500 psi. Function all LDS SL 1) SBHP for mud weight adjustment 2) Caliper well from 4207’ MD to surface 3) DMY St 2 GLM 4) Pull St 1 DMY GLV and leave pocket open for RWO Convert to injector Well: MPI-04AL1 PTD: 201-093 API:50-029-22068-60-00 Sundried work: Well Support- 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 3. Pressure test lines to 3,000 psi. 4. Circulate at least one wellbore volume with 9.5 ppg brine down tubing, taking returns up casing to 500 bbl returns tank. a. Returns will likely not be seen. After attempting circulation down the tubing, bullhead and load the tubing and IA. 5. RD Little Red Services and reverse out skid. 6. RU crane. Set CTS BPV. ND Tree. NU BOPE. RD Crane. 7. NU BOPE house. Spot mud boat. Brief RWO Procedure: 8. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines. 9. Check for pressure and if 0 psi. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/ 9.5 brine prior to setting CTS Plug. Set CTS Plug. 10. Test BOPE to 250 psi Low/ 2,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR rams on 2-7/8’’ and 3-1/2’’ test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 11. Contingency: (If the tubing hanger won’t pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer (Hilcorp), Mr. Mel Rixse (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn’t hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 12. Bleed any pressure off casing to the returns tank. Pull CTS, lubricate if pressure expected. Kill well as needed. Convert to injector Well: MPI-04AL1 PTD: 201-093 API:50-029-22068-60-00 13. MU landing joint or spear and BOLDS. 14. Attempt to pull tubing. a. 2016 RWO PUW= 42k and SOW=30k b. Do not exceed 80 percent of 2-7/8” tubing tensile rating 84 Klbs (Yield at 100% 105 Klbs) c. RU spooler for ESP Cable and heat trace. 15. Recover the tubing hanger. Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger (or test plug) in tubing head. Test BOPE per standard procedure. 16. POOH and lay down the 2-7/8’’ tubing. a. Tubing will be reused based on pre RWO caliper. b. Ensure all clamps are recovered 2016 RWO noted c. Total clamps= i. 440 5’ mid clamps ii. 97 dual cross collars iii. 39 single channel cross collars iv. 3 protectorlizers v. 2 flat guards vi. 4 pump guards vii. 3 1-1/4" Bands on heat trace terminator head 17) MU 7” casing scraper BHA and TIH w/ 3-1/2” workstring to ±4330’ MD tag HAL packer. 18) POOH and reciprocate the 7” scraper across the following interval. a. 4100- 4180MD 19) POOH and LD scraper BHA. 20) PU 7’’ test packer and RIH on work string to ±4150’ MD. 1. Set Packer and test 7” casing to 2000 psi 2. If fails PU to 200 feet until 3250’ MD and retest. 3. Call OE if no passing test. 21) PU new 3-1/2’’ injection completion. Colors indicate assemblies to be bucked up prior to RWO. Nom. Size ~Length Item Lb/ft Material Notes WLEG L-80 3.5'' 1 joint 9.3 L-80 3.5''10'Pup Joint 9.3 L-80 3.5''X Nip with RHC 9.3 L-80 RHC required 3.5''10'Pup Joint 9.3 L-80 3.5'' 1 joint 9.3 L-80 3.5''10'Pup Joint 9.3 L-80 3.5'' 7'' Baker premier Packer Set ~4150' MD 9.3 L-80 20) Run CBL email: melvin.rixse@alaska.gov Convert to injector Well: MPI-04AL1 PTD: 201-093 API:50-029-22068-60-00 3.5''10' Pup Joint 9.3 L-80 3.5'' 1 joint 9.3 L-80 3.5''10'Pup Joint 9.3 L-80 3.5''BHPG 9.3 L-80 3.5''10'Pup Joint 9.3 L-80 3.5'' 1 joint 9.3 L-80 3.5''10'Pup Joint 9.3 L-80 3.5''HAL Sliding Sleeve 9.3 L-80 3.5''10'Pup Joint 9.3 L-80 3.5''Joints 9.3 L-80 3.5''Space out PUPS 9.3 L-80 3.5'' 1 joint 9.3 L-80 3.5''PUP 9.3 L-80 3.5''Tubing Hanger 9.3 L-80 22) Space out and land the hanger. 1. Use caution not to Damage BHPG Cable while landing the hanger. 2. Note PU (Pick Up) and SO (Slack Off) weights on tally. 3. During space out do not forget to maintain constant hole fill 23) RILDS. Lay down landing joint. 24) Pump 58 bbls 9.5 ppg brine with Corrosion inhibitor down the IA followed by 52 bbls of diesel while taking returns up the tubing. 1. This is to protect the area above the packer. 25) Drop ball and rod and complete loading tubing with 9.5 ppg and hydraulically set the packer as per Vendor setting procedure 26) Pressure up and test the tubing to 2000 psi for MIT-T. Bleed off the tubing to 0 psi. Test the IA to 2000 psi for MIT-IA. Record and notate all pressure tests (30 minutes) on chart. 27) Set CTS BPV. 28) RDMO ASR. Post-Rig Procedure: 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE. 3. NU tree and tubing head adapter. 4. Test both tree and tubing hanger void to 500psi low/5,000psi high. 5. Pull CTS. State to witness MIT-IA to 2000 psi. 24 hour notice. Convert to injector Well: MPI-04AL1 PTD: 201-093 API:50-029-22068-60-00 6. RD crane. Move 500 bbl returns tank and rig mats to next well location. 7. Replace gauge(s) if removed. 8. Turn well over to injection. Post Rig Work Slickline 1. Spot Slickline unit and RU. 2. Pressure test lubricator to 300psi low and 2,000psi high. 3. Pull Ball and rod 4. Pull RHC profile Attachments: 1. Well Schematic Current 2. Well schematic Proposed 3. BOP Drawing 4. AOR 5. Surface Owner Affidavit (. AOGCC to witness MIT-IA to 2000 psi after 5 days of stabilized injection. _____________________________________________________________________________________ Revised By: TDF 12/2/2021 SCHEMATIC Milne Point Unit Well: MPU I-04A Last Completed: 6/23/16 PTD: 201-092 19 21 TD =7,207’(MD) / TD =4,070’(TVD) Orig. KB Elev.: 52.0’/ Orig. GL Elev.: 35.0’ RKB – Hanger: 23.85’ (Doyon 16) 7” 9-5/8” 1 3 22 “OA” Lateral PBTD =7,207’(MD) / PBTD =4,070’(TVD) “OB” Lateral 11 5 10 13 N Sands 18 4 2 13-3/8” 6 7 8 9 12 14 15 16 17 20 9 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 13-3/8" Conductor 54.5 / K-55 / Welded 12.459” Surf 115' N/A 9-5/8” Surface 36 / J-55 / BTC 8.765” Surf 2,599’ 0.0773 7" Production 26 / L-80 / BTC 6.151” Surface 4,536' 0.0382 2-3/8” Liner “A” 4.6 / L-80 / ST-L 1.901” 4,499’ 7,184’ 0.0039 2-3/8” Liner “B” 4.6 / L-80 / ST-L 1.901” 4,531’ 6,834’ 0.0039 TUBING DETAIL 2-7/8” Tubing 6.5 / L-80 / EUE 8rd 2.441” Surf 4,250’0.0058 JEWELRY DETAIL No Depth Item 1175’ST 2: 2-7/8” GLM 2.875” x 1” Patco GLM (BK-2 Orifice Valve Set 6/24/16) 2 ±2,800’ Heat Trace (3,000’ spool) 34,052’ST 1: 2-7/8” GLM 2.875” x 1” Patco GLM (BK-2 Dummy Valve Set 6/24/16) 4 4,165’ 2-7/8” XN Profile (2.205” No-Go Packing Bore ID) 5 4,207’ Discharge Head 6 4,208’ Centrilift ESP: P4 124 Stages 7 4,220’ Gas Separator 8 4,225’ Tandem Seal Section 9 4,239’ Single ESP Motor (75 HP each) 10 4,246’ Phoenix Sensor w 6 fin Centralizer – Bottom @ 4,250’ 11 4,330’ 7” Halliburton VTL Packer (3.880” ID) 12 4,348’ 3-1/2” Halliburton Poroplus 250 micron screen (3 joints; 2.992” ID) 13 4,456’ Baker Seal Assembly, 5.75’ Long (4.50” ID) 14 4,457’ 7” Baker ZXP Packer 15 4,475’ 4-1/2” X Profile (3.813” Packing Bore ID) 16 4,478’ 4-1/2” WLEG (3.958” ID) 17 4,499’ Baker Deployment Sleeve (4” GS Fishing Neck; 3.00” ID) 18 4,510’ Flow-thru Whipstock 19 7,184’ 2-3/8” Btm Baker Guide Shoe 20 4,531’ Baker Deployment Sleeve (4” GS Fishing Neck; 3.00” ID) 21 6,834’ 2-3/8” Btm Baker Guide Shoe 22 4,550’ Cement Retainer OPEN HOLE / CEMENT DETAIL 13-3/8" Cmt w/ 485 sx of PF C in 30” Hole 9-5/8” Cmt w/ 1,111 sx PF E, 244 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 260 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 400’ MD Max Wellbore Angle = 93.5 deg @ 4,971’ MD 25.23 deg @ 4,500’ MD WELLHEAD Tree 2-9/16” CIW Wellhead 11” x 2-7/8” EUE Top & Bottom FMC Tubing Hanger GENERAL WELL INFO API: 50-029-22068-01-00 Sidetracked & Liners Run by Nabors 3S – 7/11/2001 Screens & ESP Completion by Nabors 4ES – 7/19/2001 ESP Replacement by Nabors 4ES – 11/10/2005 ESP Replacement by Nabors 4ES – 10/30/2009 ESP Replacement, Add Y-Tool by Doyon 16 – 2/20/2014 ESP Replacement by ASR – 6/23/2016 LATERAL WINDOW DETAIL Top of “OA” Window @ 4,510’ MD; Bottom @ 4,515’ MD; Angle @ top of window is 25 deg Top of “OB” Window @ 4,536’MD; Bottom @ 4,542’ MD; Angle @ top of window is 25 deg _____________________________________________________________________________________ Revised By: DH 1/19/2023 PROPOSED Milne Point Unit Well: MPU I-04A Last Completed: 6/23/16 PTD: 201-092 14 16 TD =7,207’(MD) / TD =4,070’(TVD) 2 Orig. KB Elev.: 52.0’/ Orig. GL Elev.: 35.0’ RKB – Hanger: 23.85’ (Doyon 16) 7” 1 9-5/8” 3 5 17 “OA” Lateral PBTD =7,207’(MD) / PBTD =4,070’(TVD) “OB” Lateral 6 8 N Sands 13 4 13-3/8” 7 9 10 11 12 15 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 13-3/8" Conductor 54.5 / K-55 / Welded 12.459” Surf 115' N/A 9-5/8” Surface 36 / J-55 / BTC 8.765” Surf 2,599’ 0.0773 7" Production 26 / L-80 / BTC 6.151” Surface 4,536' 0.0382 2-3/8” Liner “A” 4.6 / L-80 / ST-L 1.901” 4,499’ 7,184’ 0.0039 2-3/8” Liner “B” 4.6 / L-80 / ST-L 1.901” 4,531’ 6,834’ 0.0039 TUBING DETAIL 3-1/2” Tubing 9.3 / L-80 2.867” Surface TBD 0.0087 JEWELRY DETAIL No Depth Item 1 TBD 3-1/2” HAL Sliding Sleeve 2 TBD Bottom Hole Pressure Gauge 3 ~4,150’ 7” x 3-1/2”Baker Premier Packer 4 TBD 3-1/2” X Nipple with RHC 5 TBD 3-1/2” WLEG 6 4,330’ 7” Halliburton VTL Packer (3.880” ID) 7 4,348’ 3-1/2” Halliburton Poroplus 250 micron screen (3 joints; 2.992” ID) 8 4,456’ Baker Seal Assembly, 5.75’ Long (4.50” ID) 9 4,457’ 7” Baker ZXP Packer 10 4,475’ 4-1/2” X Profile (3.813” Packing Bore ID) 11 4,478’ 4-1/2” WLEG (3.958” ID) 12 4,499’ Baker Deployment Sleeve (4” GS Fishing Neck; 3.00” ID) 13 4,510’ Flow-thru Whipstock 14 7,184’ 2-3/8” Btm Baker Guide Shoe 15 4,531’ Baker Deployment Sleeve (4” GS Fishing Neck; 3.00” ID) 15 6,834’ 2-3/8” Btm Baker Guide Shoe 16 4,550’ Cement Retainer OPEN HOLE / CEMENT DETAIL 13-3/8" Cmt w/ 485 sx of PF C in 30” Hole 9-5/8” Cmt w/ 1,111 sx PF E, 244 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 260 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 400’ MD Max Wellbore Angle = 93.5 deg @ 4,971’ MD 25.23 deg @ 4,500’ MD WELLHEAD Tree 2-9/16” CIW Wellhead 11” x 2-7/8” EUE Top & Bottom FMC Tubing Hanger GENERAL WELL INFO API: 50-029-22068-01-00 Sidetracked & Liners Run by Nabors 3S – 7/11/2001 Screens & ESP Completion by Nabors 4ES – 7/19/2001 ESP Replacement by Nabors 4ES – 11/10/2005 ESP Replacement by Nabors 4ES – 10/30/2009 ESP Replacement, Add Y-Tool by Doyon 16 – 2/20/2014 ESP Replacement by ASR – 6/23/2016 LATERAL WINDOW DETAIL Top of “OA” Window @ 4,510’ MD; Bottom @ 4,515’ MD; Angle @ top of window is 25 deg Top of “OB” Window @ 4,536’MD; Bottom @ 4,542’ MD; Angle @ top of window is 25 deg Updated 8/11/2020 Milne Point ASR Rig 1 BOPE 2022 11” BOPE 4.48' 4.54' 2.00' CIW-U 4.30'Hydril GK 11" - 5000 VBR or Pipe Rams Blind11'’- 5000 DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualHCR Stripping Head 2-7/8” x 5” VBR Area of Review Summary – Milne Point Unit I-04 (PTD 201092)This Area of Review is required prior to the conversion of well MPU I-04 from a producer to a polymer injector. This AOR discusseswells with ¼ mile of the well’s entry point into the Schrader to the bottom of MPU I-04 well bore completion. Figure 1: Map showing wells within ¼ mile radius from MPU I-04.The list of all operators and surface owners within ¼ mile of MPU I-04 is below:#Operators#Surface Owners1Hilcorp Alaska, LLC1Alaska Department of Natural Resources (ADNR)Table 1: List of operators and surface ownersAn affidavit has been submitted to the following operators and surface owners:#Operators#Surface Owners1N/A1Alaska Department of Natural Resources (ADNR)Table 2: List of operators and surface owners receiving an affidavit The tables below illustrate all wells with in the ¼ mile of MPU I-04:Area of Review MPU I-04 SB Inj ConversionPTDAPIWELLSTATUSTopof SBNa(MD)TopofSBNa(TVD)TopofCement(MD)Top ofCement(TVD)Schrader NSand/Oa/Oba statusZonal Isolation201-09250-029-22068-01-00MPI-04ASI producer4376385432502890Open260 sax class G in 8-1/2'' hole204-17450-029-23224-00-00MPU H-18OBa lateral Shutin613939933652'2795'ClosedNot Open CIBP set204-17550-029-23224-60-00MPU H-18L1OA Lateral Hut in61373932N/AN/AClosedNot Open ISO sleeve with TTP inplace204-17650-029-23224-61-00MPU H-18L2NB Lateral61503932N/AN/AOpenOpen to Injection Support19009850-029-22073-00-00MPU J-04Shut in Producer:Na/Nb/Nc/Ne/Oa/Oba5523394632002571Open83 bbls Pumped of class G cementPlug bumbed float held.20419050-029-23227-00-00MPU H-16Active Producer:Oba5727386723422197Open123 bbls Class G cement floatheld.20419150-029-23227-60-00MPU H-16L1Active Producer:Oa57263866N/AN/AOpenOpen to Injection Support220-04950-029-23679-00-00MPU I-20Active Producer:Oba40123780SurfaceSurfaceOpen9-5/8" Cemented to surface22101350-029-23692-00-00MPU I-27Active Producer:Oa40853766SurfaceSurfaceOpen9-5/8" Cemented to surface22101050-029-22602-01-00MPU I-07AActive Injector:Na/Nb/Nc/Ne/Oa/Oba Prod3877378035503477OpenOpen Vertical injector inall SBSands190-09750-029-22072-00-00MPU J-03AbandonedProducer:Na/Nb/Nc/Ne/Oa/Oba481337922927'2532'ClosedRes P&A Table 3: Zonal isolation of wells within AORI-04A current location is not suitable as a producing well there is minimal injection support due to fault proximity and distance from injection asindicated by it’s low rates and pressures over time. It is planned to work this well over to convert to an injector and support H-16 producer inthe Oa/Oba sands as well as the planned addition of the N sands perforations in upcoming H-16 RWO. This will help support the current 230bopd rate from the O sands and sweep suspected unswept area in H-16 and support the expected 110 bopd from the addition of the N sands. STATE OF ALASKA ALGA OIL AND GAS CONSERVATION COMO/SION z REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Li Plug Perforations U Fracture Stimulate u Pull Tubing U Operations shutdown ❑ Performed: Suspend El Perforate ❑ Other Stimulate El Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Well ❑ Re-enter Susp Well El Other: ESP Change-out Q 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development Q Exploratory ❑ 201-093 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-22068-60-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025906 MILNE PT UNIT SB I-04AL1 RECEIVED 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL .1[11 2 5 2016 11.Present Well Condition Summary: GCC Total Depth measured 7,207 feet Plugs measured N/A felt "^' true vertical 4,070 feet Junk measured N/A feet Effective Depth measured 7,207 feet Packer measured 4,330&4,457 feet true vertical 4,070 feet true vertical 3,812&3,927 feet Casing Length Size MD TVD Burst Collapse Conductor 115' 13-3/8" 115' 115' N/A N/A Surface 2,599' 9-5/8" 2,599' 2,354' 3,520psi 2,020psi Intermediate 4,536' 7" 4,536' 3,999' 7,240psi 5,410psi Liner"A" 2,685' 2-3/8" 7,184' 4,069' 11,200psi 11,780psi Liner"B" 2,303' 2-3/8" 6,834' 4,125' 11,200psi 11,780psi Perforation depth Measured depth: 4,383 to 4,451,4,560 to 7,151 Slotted&7,184 to 7,207 Open Hole True Vertical depth: 3,860 to 3,921,4,016 to 4,068 Slotted&4,069 to 4,070 Open Hole Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/8rd 4,250' 3,740' Halliburton VTL Packers and SSSV(type,measured and true vertical depth) Baker ZXP N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A SCANNED rEfel 0 6 201 , Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 600 0 Subsequent to operation: 56 6 83 240 228 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory Development El Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ El 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: Contact Stan Porhola Email sporhola(cr�hilcorp.com 5-1-P Printed Name Bo York Title Operations Manager Signature , Phone 777-8345 Date 7/25/2016 L,' Form 10-404 Revised 5/2015 II 7....2 L6 RBDMS 1,t./JUL 2 6 2016 L LOA Submit Original Only • Milne Well: Point MPU I-0Unit/I • SCHEMATIC Last Completed: 6/23/16 Hilcora Alaska,LLC PTD: 201-092 WELLHEAD OPEN HOLE/CEMENT DETAIL Tree 2-9/16"CIW 13-3/8" Cmt w/485 sx of PF C in 30"Hole Wellhead 11"x 2-7/8"EUE Top&Bottom 9-5/8" Cmt w/1,111 sx PF E,244 sx Class"G"in 12-1/4"Hole Orig.KB Elev.:52.0'/Orig.GL Elev.:35.0' , FMC Tubing Hanger 7" Cmt w/260 sx Class"G"in 8-1/2"Hole RKB–Hanger:23.85'(Doyon 16) J 1 b CASING DETAIL t Size Type Wt/Grade/Conn Drift ID Top Btm BPF 13-3/8" 44 s 1 13-3/8" Conductor 54.5/K-55/Welded 12.459" Surf 115' N/A 9-5/8" Surface 36/J-55/BTC 8.765" Surf 2,599' 0.0773 r 7" Production 26/L-80/BTC 6.151" Surface 4,536' 0.0382 9-50 r11 6 2-3/8" Liner"A" 4.6/L-80/ST-L 1.901" 4,499' 7,184' 0.0039 2 2-3/8" Liner"B" 4.6/L-80/ST-L 1.901" 4,531' 6,834' 0.0039 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441" Surf 4,250' 0.0058 WELL INCLINATION DETAIL KOP@400'MD 11 s Max Wellbore Angle=93.5 deg @ 4,971'MD 25.23 deg @ 4,500'MD 4 JEWELRY DETAIL No Depth Item 5 1 175' ST 2:2-7/8"GLM 2.875"x 1"Patco GLM(BK-2 Orifice Valve Set 6/24/16) 6 2 ±2,800' Heat Trace(3,000'spool) 3 4,052' ST 1:2-7/8"GLM 2.875"x 1"Patco GLM(BK-2 Dummy Valve Set 6/24/16) ir 7 4 4,165' 2-7/8"XN Profile(2.205"No-Go Packing Bore ID) 8 5 4,207' Discharge Head 6 4,208' Centrilift ESP:P4 124 Stages 7 4,220' Gas Separator `" `` 1 9 8 4,225' Tandem Seal Section 9 4,239' Single ESP Motor(75 HP each) 10 10 4,246' Phoenix Sensor w 6 fin Centralizer–Bottom @ 4,250' – 11 4,330' 7"Halliburton VTL Packer(3.880"ID) 12 4,348' 3-1/2"Halliburton Poroplus 250 micron screen(3 joints;2.992"ID) 13 4,456' Baker Seal Assembly,5.75'Long(4.50"ID) 11 14 4,457' 7"Baker ZXP Packer 15 4,475' 4-1/2"X Profile(3.813"Packing Bore ID) ' 16 4,478' 4-1/2"WLEG(3.958"ID) N Sands — IP, 12 17 4,499' Baker Deployment Sleeve(4"GS Fishing Neck;3.00"ID) 18 4,510' Flow-thru Whipstock 13 19 7,184' 2-3/8"Btm Baker Guide Shoe y,?, 14 20 4,531' Baker Deployment Sleeve(4"GS Fishing Neck;3.00"ID) 15 21 6,834' 2-3/8"Btm Baker Guide Shoe 16 22 4,550' Cement Retainer 17 OA Lateral - `\ 18 19 LATERAL WINDOW DETAIL Top of"OA"Window @ 4,510'MD;Bottom @ 4,515'MD;Angle @ top of window is 25 deg 20 Top of"OB"Window @ 4,536'MD;Bottom @ 4,542'MD;Angle @ top of window is 25 deg OB`Lateral 21 GENERAL WELL INFO API:50-029-22068-01-00 Sidetracked&Liners Run by Nabors 3S–7/11/2001 22' xJ,_JK Screens&ESP Completion by Nabors 4ES–7/19/2001 ESP Replacement by Nabors 4ES–11/10/2005 a• 1 ESP Replacement by Nabors 4ES-10/30/2009 TD=7,207'(MD)/TD=4,070(TVD) ESP Replacement,Add Y-Tool by Doyon 16–2/20/2014 PBTD=7,207'(MD)/PBTD=4,070'(TVD) ESP Replacement by ASR–6/23/2016 Revised By:TDF 7/25/2016 • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date 1 MP I-04A ASR#1 50-029-22068-01-00 201-092 6/17/16 6/24/16 Daily Operations: ` 6/15/2016-Wednesday No activity to report. 6/16/2016-Thursday No activity to report. 6/17/2016-Friday Spot Rig and Equipment on Location, (AOGCC was notified of right to witness BOP Test for 6-18-16 @ 19:11 Hours on 6-17- 16. Well Kill Operations with Little Red Services Pumped 290 BBL. 8.5 ppg Sea Water @ 2 bpm @ 500 Psi (Well Dead). Back Blade Around well Head & Level,Set Half Mats Installed Horse Shoe Scaffolding around Tree. Well Head Rep Install BPV in Hanger. Nipple Down Tree, Check Travel on Lock Down Screws and Hanger Lifing Threads 8 Turns. Lay out and Set Matting Boards for ASR Rig and Equipment. Nipple up Bope Stack. 6/18/2016-Saturday Spot Mud Boat, Back Rig on Mud Boat, Raise Derrick, Spot Mud tanks, Spot Cat walk,torque up BOP connections. Rig up, install stairs, Rig up Circulating hoses, Install Gas alarm Connections &Calibrate and test same, change out Accumulator hoses to BOP. Rig up for BOP Test. Conduct shell Test 2,500 psi (Good Test) Pressure up on Test 1' Leaking, Chasing Leak Called out Well Support Greases all Valves, Replaced 2-6,000 Psi Needle Valves on Test Pump, Rebuild Pop off Valve isolated all Choke Valve Pressure up on Test Pump Leaking, Called out Little Red Services to Assist Testing BOP, Put Packing in Hanger seal,Tighten Gland nut (Test was witnessed by AOGCC Bob Noble). Repairing valves on Choke manifold for BOP Test. 6/19/2016-Sunday Repair C-16& K-8 Valves on Choke manifold, Repair Test pump, release little Red services. Repair leak on Stand Pipe line. Test Choke Manifold to 250 PSI Low/2500 PSI High. Notify Work over Engineer&AOGCC Jim Regg&Guy Schwartz of intent to perform a Rolling Test due to a suspected leak in the tubing Hanger. Perform Rolling Test on 2-7/8"VBRs To 2500 PSI & Annular To 1500 PSI & Blind Rams to 2500 PSI.Test IBOP & Floor Valves to 250 PSI Low& 2500 PSI High. Perform Accumulator Function Test. Pull TWC, Back out LDS, Pull Tubing Hanger to Rig Floor 46K Pick up Weight. Remove Penetrators and inspect 0-Rings, Inspect Seals on Tubing Hanger, Hanger seals shown some wear, Replace 0-Rings on Penetrators, Replace Seals on Tubing Hanger. Land Hanger RILDS Install TWC. Rig Service, Check Fluid Levels.Test 2-7/8" Test Joint TIW Valve and I-BOP Valve Pipe Rams, to 250/2,500 Psi 5 Min Each,Test Annular 250/1,500 Psi 5 Min Each, Rig down Test Equipment. Well Head Rep (Dean Norris) Removed TWC Valve from Hanger. Pump 10 bbl. down the Tubing Make up Landing Joint Screw into Hanger BOLDS, Pull Hanger to the Rig Floor at 46k Break out& Lay Down.Trip out of the hole Lay yawn 2-7/R Tubing Haft Traces& ESP Cable to 3 500 ft • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP I-04A ASR#1 50-029-22068-01-00 201-092 6/17/16 6/24/16 Daily Operations: 6/20/2016- Monday Service Rig, Check Fluid Levels.Trip out of the hole Lay down 2-7/8 Tubing Heat Trace& ESP Cable (Replaced 40 Bad Joints From Well) Break and Lay Down ESP Pump Assembly(Pump Locked up Sanded up). Clear and Clean Rig Floor Wind Wall and Cellar Area, (Little Red Services Heating Sea Water in Pits to 110 Degrees). Pick and Make up 7' 26#Casing Scraper and xo Sub.Trip in the Hole with 2-7/8 Tubing to±1250'. Continue to RIH w/2-7/8" tubing w/casing scraper& bit to 4,324' (137 jts). PU joint# 138. Break circulation and lightly tag top of packer at 4,330'. Circulate 227 bbls to clear oil from well bore (approximately 80 bbls of oil returned to surface).Take on source water in pits. Line up & reverse circulate tubing volume x 3. Down hole losses while circulating= 110 bbls. Monitor well (OK). POH LD 2-7/8"Tubing f/4,330'to surface. LD BHA. Clear/Clean Rig floor. RU to PU 1.66" Clean out BHA for screens. 6/21/2016-Tuesday Change over Handling Equipment From 2-7/8 to 1.660 BTS-8 (Small Tubing) Remove old Tubing from Pipe Racks, Replace 2- 7/8 Production String w/New Tubing, Load and Tally. Pick and Make up 1.660 BTS-8 Mule shoe and ( 6 Joints Small Tubing).Trip in Hole w/2-7/8 Tubing and BHA Assembly to 3,100 ft. install TIW Valve in Tubing. Service Rig,Change Motor Oil Fuel and Air Filter, Check Fluid Levels. Continue Tripping in Hole w/2-7/8 Tubing and BHA Assembly From 3,100 ft.to 4,330 Did not see (7'x 3.880 ID) PKR Top Continued RIH to 4,480 ft. (Did not tag any Sand our Objects). R/U to Circulate with a pump Rate of 144 spm @ 400 psi, Fill well Bore, R/U to Reverse Circulate 70 bbls at 2 bpm, 214 psi. No returns observed. POH LD 6 jts to place mule shoe above packer. Break circulation and reverse circulate w/3 bpm, 350 psi. Observed returns at 160 bbls away. Take on source water. Continue to reverse circulate for 1 x tubing volume. POH LD 2 7/8'tubing f/4,330'to 195'. Change handling equipment to 1.66". LD BHA. Clean/Clear rig floor. Change over to 2-7/8" handling equipment. PU 7" RTTS Packer and XO's. RIH w/RTTS on 2-7/8" tubing. 1,5060 FT. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP I-04A ASR#1 50-029-22068-01-00 201-092 6/17/16 6/24/16 Daily Operations: u! 6/22/2016-Wednesday Service Rig, Check Fluid Levels. Continued RIH with 7' 26# RTTS Packer on 2-7/8" Tubing from 1,500'to 4,300' (136 Jts). Fill up Back Side with 12 bbl. Close Annular.Tested 7' 26#Casing from 4,300'to Surface 1,500psi 30 min Charted (Tested Good).Trip out of the Hole Laying down 2-7/8"Tubing& 7' RTTS Storm Packer. Clear and Clean Rig Floor Hang ESP sheave in Derrick, Pull ESP Cable over onto Rig Floor, Load Pump Assembly onto Cat walk. Pick& Make up ESP Completion Pump Assembly. Continue to MU pump assembly. RIH w/ ESP completion on 2 7/8" 6.5# EUE tubing to ±2,400'. Check conductivity every 2,000'. Begin Heat Trace at joint#43 ±2,800'. 6/23/2016-Thursday •�I Service Rig, Check Fluid Levels. RIH w/ ESP Completion on 2-7/8" 6.5# EUE Tubing From 2,500' to 4,350'. Check conductivity on ESP Cable every 2,000'. Pick and Make up Tubing Hanger, Well Head Rep Align Penetrator up with Flow Line. MU connector& install on hanger. Install penetrators. MU connector to ESP cable & install on hanger. Install final clamps. Meg test cable (OK). Ran a total of 130 jts of 2-7/8" 6.5# EUE tubing.Total Clamps=440- 5' mid clamps, 97 dual cross collar, 39 single channel cross collar, 3 protectorlizers, 2 flat guards, 4 pump clamps& 3 - 1-1/4" bands. Final PUW 42k-SOW 30k. Land Tubing hanger in wellhead. RILDS. LD landing joint. Install BPV. Electrician disconnected alarm system on rig. Nipple down BOP stack to four bolts. Remove ESP Sheave from Derrick. Remove 2-7/8" handling equipment from Rig Floor. Break over and Lower Derrick, Pull rig off of well Remove mud Boat, Roads and Pads unload 186 bbls unused source water from pits. Hauled to ORT. Remove pipe racks. Remove cat walk. 6/24/2016- Friday Roads and Pads Crane Assisted in Removing Rig Floor and Well House, Finished Nipple Down and Removed Bop, Hoisted into Bop Trailer, Hoisted Tree onto well Flange, Nipple up Tree,Test Hanger Void and Tree 5,000psi RDMO. 6/25/2016-Saturday No activity to report. 6/26/2016-Sunday No activity to report. 6/27/2016- Monday No activity to report. 6/28/2016-Tuesday No activity to report. • et/LT_ 04-AL l P ►-6 2-01O t30 Regg, James B (DOA) From: Craig Smith - (C) <crsmith@hilcorp.com> Sent: Tuesday, June 21, 2016 3:34 PM To: Regg,James B (DOA) Ze � (z-(i Cc: Stan Porhola; Paul Chan Subject: RE:ASR Rig 1' Bope Test Results Milne Point I-04A Attachments: Rolling Test 001.jpg;TEST CHART 2 001.jpg; TEST CHART 3 001jpg; ROLLING TEST CHART 2.875X5 RAMS 004.jpg; TEST CHART 5 001.jpg; TEST CHART 6 001.jpg Jim This is the Final Full BOPE Test, I have the Rolling Test Chart in my Hand the Annular Rolling Test& Blind Ram Rolling Test& 2-7/8 x 5 Pipe Rams Rolling Test I will send you all Test Charts & Rolling Test Charts to you Thank you Craig R Smith Well Site Supervisor Hilcorp Alaska ASR RIG 1 ow DEC 1 4 7Cl16 0 (907) 310-0243 C (208) 816-6803 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, June 21, 2016 2:53 PM To: Craig Smith - (C) Cc: Brooks, Phoebe L (DOA); Noble, Robert C (DOA) Subject: RE: ASR Rig 1' Bope Test Results Milne Point I-04A Explain what this test represents. Is it documenting just the rolling test or both rolling test and normal BOPE test (as per Step 5 of the procedure)? I do need you to submit the test charts for the rolling tests. In the past, we have received a combined test report that includes the results of both rolling and subsequent full BOPE test (accounting for any failures during the rolling test)along with the test charts. Please clarify. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, 1 • • please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: Craig Smith - (C) [mailto:crsmithPhilcorp.com] Sent: Tuesday, June 21, 2016 7:39 AM To: Regg, James B (DOA); Brooks, Phoebe L (DOA) Cc: DOA AOGCC Prudhoe Bay Subject: ASR Rig 1' Bope Test Results Milne Point I-04A Craig R Smith Well Site Supervisor Hilcorp Alaska ASR RIG 1 0 (907) 310-0243 C (208) 816-6803 2 • STATE OF ALASKA • OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: jim.reqqalaska.gov AOGCC.Inspectorsaalaska.gov phoebe.brooksaalaska.gov Contractor: Hilcorp Rig No.: ASR 1 DATE: 6/19/16 Rig Rep.: Dusty Schulze Rig Phone: 907-310-0887 Operator: Hilcorp Alaska Op. Phone: 907-310-0243 Rep.: Craig Smith E-Mail crsmith©hilcorp.com Well Name: MPU I-04AL1 PTD# 2010930 - Sundry# 316-242 - Operation: Drilling: Workover: X Explor.: Test: Initial: X - Weekly: Bi-Weekly: Test Pressure(psi): Rams: 250/2500 • Annular: 250/1500 Valves: 250/2500 -MASP: 1,156 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen. P - Well Sign P . Upper Kelly 0 NA Housekeeping P Rig P - Lower Kelly 0 NA PTD On Location P - Hazard Sec. P - Ball Type 1 P . Standing Order Posted P - Misc. NA Inside BOP 1 - P . FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank NA NA Annular Preventer 1 - 11" FP ,/ Pit Level Indicators P - P #1 Rams 1 ' 2 7/8"x 5" P Flow Indicator NA NA #2 Rams 1 Blinds P Meth Gas Detector P - P #3 Rams 0 NA H2S Gas Detector P - P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves I - 2 1/16" P . Inside Reel valves 0 NA HCR Valves I ` 2 1/16" P Kill Line Valves 2 ' 2 1/16" P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 1 - Standpipe • FP `7. Time/Pressure Test Result System Pressure(psi) 3000 P CHOKE MANIFOLD: Pressure After Closure(psi) 1600 - P - Quantity Test Result 200 psi Attained(sec) 12 - P No.Valves 15 FP ✓ Full Pressure Attained(sec) 65 P Manual Chokes 1 - P - Blind Switch Covers: All stations Yes Hydraulic Chokes 1 - P - Nitgn. Bottles#&psi(Avg.): 4 @ 2500 - P CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 4 Test Time: 27.0 y Hours Repair or replacement of equipment will be made within days. Notify the AOGCC of repairs with written confirmation to:AOGCC.Inspectors@alaska.gov Remarks: Tested with 2 7/8"test Joint, Had 2 Choke manifold valves leak, Rebuilt valves and retested good, Had a leak_on the Stand pipe line on a threaded connection, repaired and retested good.Perform Rolling Test on 2 7/8"VBRs To 2500 PSI &Annular To 1500 PSI&Blind Rams to 2500 PSI.Test IBOP&Floor Valves to 250 PSI Low&2500 PSI High. Pumped approximately 1 bbls away during rolling Test. AOGCC Inspection 24 hr Notice Yes Date/Time 6/17/16 1700 Waived By Bob Noble Test Start Date/Time: 6/18/2016 17:00 (date) (time) _ Witness Test Finish Date/Time: 6/19/2016 , 20:00 pm Form 10-424(Revised 11/2015) 2016-0619_BOP_Hilcorp_ASR1_rolling-test_MPU_I-04L1_bn.xlsx , • • 15 • \O - 1 / >7 7 0 ...---- _--..-•--- • _---- — --------,:---7.---------...„:-`1-600, N N\\\\ X 1 z 7/,/' 7'. ...,,f30° --•'.----- %--- • ------- ' : -- '.00,.:''4,, N.,,, \ , f f4°) //V / '"- / f i °°O\ rte!��*_ ---,—-'4,--f--' A-r�f2-- 00•/ ,,,7 /- _,.• _„---- „.....---- _____-----r------------ ..,,,, ' --I ----t--0-1.„.7tci--V . „,, .: \ \ \ / 0 \.--- . '- ', • , / / , /./re,c).00V-j_-_----7–____,'_____--_—_,______:„' ,./ 00-_-_..„,,,,,,N,'"."--,--„,,,,N2N,„IN:\.,\\\\\\\\, \\, \-,,,, \\ _:,\....„4. :'; / , / ./ // �/ 1. / ,�,, O _t _500 `'� '\ -, ,,v \ - .- l 7 f�`/ app/ �'\ ' \4':\ ''' A \\\\ \ \ \ ',,, ' • , ' / / / ---/ / 7 //'' / // / \ ',•1. ; i ! I I I / ' ''..-./ / t IC/ 6 il ‘; I,- - '&,,.. ,. -63, \ 6-, \ ,,,:...?, \ so -,,, 4 - _ = 0 I 421_1 l' —1 j - - + ,� , v \ Z, , � - ,i 'l i / / � \.\ � \ 1 \ / 1, i \ \ \ \\ \ �\ °per' ; /f � / l \\/\ \ OS - _ •[''' \ \ \ \ ' \ \ \ \ \ 'NN,-'' ''''. --7----------1 _---..---- 0& 1///" ,,,,, ' \ , ''' ' \ \'' \\\ ' / / / \ o - _ ./ . o"" ' S. / / f \ \ O —\ Om °°p S jjj xl \'.\''-\'‘..\‘ ', -., 000s,_,.- ------___1_---_- _-___ -_----._1,11--:_-_-_:.--_-_-:::-____- ,--:> epc,C7,1/„ , / //// i` _,/ % 0 % \ OQSO \��� — ------- -- _. --rte p"0 g 11 '1 5 ----_ 00 400-0 --I-----'''''''' 'NNN:' ' -F�. -'`-4500 ` —_ - _, \ j � - 35 b 47/l / :7-: /r % 30001__ ~` \ -- f � O N ���N 1 / —2000 - \-. '. / � / 00 / /� / / / / O / // / -' / -1500 ��� \\\ \ A O 1i / ' // ° / / !�� _� 1000 � \ �� / / ' r\ / i. -----7----_, \ \ / J / / , f J c�00 • 2 -'�/ 1 , ° /f / � o' / / / / / cc:p A- \ o \\ o i / / it7 � ., i //I / / / // � / O / > \ �/• r� \ J d0 0 \ \ \ : 1 , iLIi l , , / ;` �a X00 , \\\\ -.. 7 ',/ 1 ,... " , I i i I 1'1-- , , / i 1 ,' -jc '� i ( t, , \ \ \ \ \ , I \ \ \ , , ‘/y v p . i , , „ , ,i__,L , , _,.,,_,, , y, I 1 i ,, \ \ I I \ \ \ , \ \---\--\\,c ,,, / ,, 1, 1 .,\\\\ ,, '` �\ , \\ \ , ,.� "D. �o� \ \' ���� \o; r P:7 rc.:',f \?‘) 4-7-- ' ' . - , / . V \ t . - O O v A _ , \ O \ \\\\\ \ \ \ \ \ //` J / { \ \ \ . \ \\ '.,\>,, , ''',.„,,/, ____„--- //,,,ea,777/ ///,/:// 61 / / \ `\� \\ \ ----- 0001--— 7 / / O° CVCrti '1. \ \ \ \ , \N , s, N,,,„. .....,, "--....,,„_ --- -000e, - - __.,_ „„/". ,/ Xi/ / , \ \ \\ . \ , N --, ,/.-- ./.„,,7 VY \\\\ , \\\ \. 'NN N Nx.N,.,.,,', ///;X. N - 00s2 Z / o00 41.11. ' - 00 � \\ `` S r /ter - /7/f \\ - ° l �..�` \ OOsy- 0 5 • i (ickby O C. j _ ,r /i / o -------.7.____. ` 4000 \ `N . ��� o . iso / / / //// / / Oj " y - / / �° �--" _ -/ / / ' , [Y. ' . / ' ' ,/... , • '' ,--------: t- i: - . ''''' /\ \'', /- ` / > ,r'7,,,,, / / j / ',,,,>'-' �\ . `\ v � S i / I 5/ beP/CA k' % \\ \ \ \ \ \ ‘ '''' - 01 0 o a o 0 0 r 0 0 ':. � , I I , , J T ( I A .\ C '; \ , \ ,7. '',.,Po ' ,9, \ 0 Po \ ;i-)) \ cc?) \ '5)? \ - ' , , , , .. ,, . N --- \ --,', \ \ \ i / / / ' , \\\ \ i \ l\ \ \ ` \ \\ \ ON �/' `\ \ \ \ \ P, 5 \\ \\.\\\ '-''' \ \ .\ • • i . , < ,, ______ __,--- -- cr ol:///,. .,,,..'.— -, . :, ,.\. .'.-* \ \ *,.. , \-- • .\-,‘.. --, 0 . r .-r"" -, \ _.. - ` \\. \\\.N \\ ,,.,, 0004`_ ',,..-----t----->" - -- ° /.�. f i \ \\\\\\ \\ � ~ QOM' _-'_ '' ,,� '�, / ' ct. � — ;: ` --7 / / � s �_� .- q /� � r, �_ oNN OOO � � '` /Si: _ _ / 0,g, ` . o ON')ac- �\ — __ s2t(, • • - • 15 p ' - �-- ::____:___-T:----:::::o::::::,,..Too',—:o X4000/ b• ,-/„—j _ _ :?`'` N. \ ,po / _ 0 ,'” \‘',. 1 j \�..- ��/ � / app ��/ --�.. �- o \0 N NN \ \�.\�:� \\\1:\:\\\,, �\`` ,'' :,,, //''''' ; /17./K4 o 7/1''''';..:-- __11----------.7 ____,._:'-------,;--------__7_,S- ''''': ''''‘, '.\"; \ .' \--- \ '\ i r t� � \ ` `l f ap ' �' , \ �o -`` . \ /77,,„ ' . / • 0 ---/- ,,,„,--‹ - _ -------.1_ -----,,,,,„„ ----„,„ - \ .\\ \ \ \\ _ ; ! /,,/ , / i (C\‘fkkt't U- 0 \ \ \ \ \ \ \ .\ \ \ \ , ‘f1� =Il W \ p .l fin0 ls Cn O O OO Cn� . 0 Y ,,,.., ,,, ,, i ' I 'i. ' '''' e„! CD t' ' ' Z ° I T l/ i / t { E0u7 oOo ,n o zo ' \ \ ' \ \ \ \ \ \ \ \ \ \ IS 6, L•k / .. . ' / / / 1 ' 1 .�� y , �\ v a a s � � \'''\ \-\ � � / v c..) ,- / / / , 1 ._.1Opp /// , 1` i� 0/ „ ' , ' �� \ . - A v \ \ � — j Opp ��/ I A3c\ v �` N Ol -- �/' ,•'' pp "/ // /) L .,," \ \ \--\ \\-. -, N. - --._ . ' _;._..-- , „,„...--- ,„,,,,,„.7 ,,0 // ' i / r,.,,,,' N., '',- '- , ---..„/ ooa,. ,,,,, \ ,,,, •--,,,,,..-----...„, „ 00,9 ,._ -----------7 -- — __'------- ' 00c,C-74 / \\\\\•,\ \\\N‘'.:...N„N,,.:. `\\ ., , 0005' / / / // - \` pci 41c, Sq • 25 2.0 ..------- --_ - �, O (0 / >Z00 - ` Qao c`\ /,/. //7//zz-, -.----._... -------- \\:\ /I//// ' „;.-' ( /z-„77.,-, „„., ____„,----, '---,, ,i_____ '-, -------____~.----,,,„„i--,--- 00>c \ ,,,\ ..\- JJ / ! ji, _ / 0 �. ,S \ \ \ \ 60 0 f / /% // i / / / '/ i ,/ - >7/ o ,\\ / // ppp 0 \ \ < 1 ,, , / ,,, , //. .,,,,,„ ,,„ ,i,, /, ,,,,,/, ,..,....„ • _______ „ _ .,.,,,,_ .,.... ,..„ \\\\,: „, \ \ \ \ \,....„.. , : / 7 .1 / i , „, , ,.. 4 1 7 7 l ^ —,,,,,, \,.... . \. ,s ‘, \......„.___\--, , \ _,\:), --\\ \ \ , \ V owl- ! / / 77/ i, , 1 1 . •/. . / .,,,,,,, ,,„. ---.N... \\ \ _ ,.. ,/ _ J 1,4e71 �% , , J � s i \ . . i (.9 1 o.:'- -----1. 1,:./__ i 1 i ( \.\-. 1 �/,00_ y dy I N o ' 0 . o `'. --1-'--,.. ' n, - - --t---.±..1o • o 1 I \ I 1 7V V 0 J i ,! , \ _ \, I . . A k \ . \ ,., OA, d / \ e tio / ' -s ‘ V\ -\ \ \ ' ' • "-s, .•------ 417‘/....--7-;<?4'../. ' )7. l''' /// ///1/ / / I / / /7 r J- \ \ \ a S -------7____' „,....„-- , ,,,:// is, / .- // -. \..•• • \, \ ___„..,-0_,,,,,--/ . . /// , ' �• � as \� ' ___ ------s- Opc,, / 00 -' -'.---'•--T -'------'- - —177 /, / „,-., „ \ SO✓ af O ti \\\ \ ` f , J f , ` o0Y/ , \ �. --_ ' -'`` .Oi \ 0 \\ 00 ab\\`'` G1ii __ 005 �� - :=77----------.Lfes. - - -- 0 Ss • • 10 — 1S -----"---..„..� � 1 \'r-! A5o° - , A 0 -.___ y / / / / / ,,,,/ ;/'„ t .„/ ,,,,./' /. Q / , / / / // // .,, / ii/- //i/r2,...- // „'`// ,/ / / '7 ,i 500 ----7-- ---- -� °° // / / / ."' / // r / :/ / / / / / f- \ i / / / / / 1 C/ t 5? i It-i, I i � / / , //// ! r -`)! k,\� 2 k C \, JJ�� 1 o 2 / / ` I j ,a 1- I "nZ. p G cii y p p f , /\ \ '\ ' \ ,„ \ , , \ , \ \,,, \ I , ,,, , \ \ \ \ , \.‘ \ .\ \ .\ ,\,- \ \ \\ \:\ , __„_-\---\---' \\ A is. \� y A\ \ � �/ \ \ \ 00..s.:.-":7'7 r .-":7' _ °OC' \ \ V y yv \\ >°0 - /7= / / / \:\ / \ \ �V V � v *tea° c? �� :_i_.1„,-___;_, .000. ,:,z, -///�/ f .,__ _,____---:-______:,__. \\ , \\ ,\ \ \\\ s �' jea , \ O \\-'2\°°,9A\ N. � \. ~�`"`-- ,. —_~--------t p0�1� �/r% jl {. oo . Sp ..-______L_________ b — ._ Ov ti OF Tit, • S • y ����yy��s� THE STATE Alaska Oil and Gas / ,,;- ofLASKA Conservation Commission 333 West Seventh Avenue i GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 *+' Main: 907.279.1433 A g1i� Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations ManagerSC.At�M `F I;Y Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB I-04AL1 Permit to Drill Number: 201-093 Sundry Number: 316-242 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this 40 day of April, 2016. RBDMS Vt/APR 2 9 2016 . • • RECEIVED STATE OF ALASKA n pp 9I) 9rng ALASKA OIL AND GAS CONSERVATION COMMISSION 0775 442E j/.6 APPLICATION FOR SUNDRY APPROVALS AOG GO 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate El Repair Well D Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull-I ubing El Change Approved Program El Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change-out El 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska, LLC Exploratory ❑ Development El. 201-093 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ElService ❑ 6.API Number. Anchorage,AK 99503 50-029-22068-60-00 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No D I MILNE PT UNIT SB I-04AL1 9. Property Designation(Lease Number): 10. Field/Pool(s): ADL0025906 MILNE POINT/SCHRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: tMPSP(psi): Plugs(MD): Junk(MD): 7,207' _ 4,070' • 7,207' • 4,070' 1,156 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 115' 13-3/8" 115' 115' N/A N/A Surface 2,599' 9-5/8" 2,599' 2,354' 3,520psi 2,020psi Intermediate 4,536' 7" 4,536' 3,999' 7,240psi 5,410psi Liner"A" 2,685' 2-3/8" 7,184' 4,069' 11,200psi 11,780psi Liner"B" 2,303' 2-3/8" 6,834' 4,125' 11,200psi 11,780psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 4,383-4,451 3,860-3,921 4,560-7,151 Slotted 4,016-4,068 Slotted 2-7/8" 6.5#/L-80/8RD 4,182 7,184-7,207 Open Hole 4,069-4,070 Open Hole Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Halliburton VTL, Baker ZXP;N/A 4,330(MD)/3,812(TVD),4,457(MD)/3,927(TVD); N/A 12.Attachments: Proposal Summary El Wellbore schematic D 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch D Exploratory ❑ Stratigraphic ❑ Development D • Service Cl 14.Estimated Date for 15.Well Status after proposed work: 5/4/2016 Commencing Operations: OIL D WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: N/A GAS ❑ WAG ❑ GSTOR El SPLUG ❑ Commission Representative: N/A GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved -7-,1e45 herein will not be deviated from without prior written approval. Contact Stan Porhola Email sporhola@hilcorp.com Printed Name Bo York Title Operations Manager Signature Phone 777-8345 Date 4120/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 2-412- �L A \� Plug Integrity ❑ BOP Test P Mechanical Integrity Test ❑ Location Clearance CIOther: Z Soe) eSi.. /3 L. / t— C .,...0„ [/ �t s -,..) ,- (rets 6l, "1"' a.4- - !cc-6-6r s Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Ga, Subsequent Form Required: , Q — LI 0 RBDMS (,tom APR 2 9 2016 APPROVED BY Approved by: /4COMMISSIONER THE COMMISSION Date:4 • 2.(:)- ,4 Submit Form and Form 10-403 Revised 11/2t a` If, t.015 n lid for 12 months from the date of approval. Attachments in Duplicate • • Well Prognosis Well: MPU l-04A11 flilrorp Alaska,LL, Date:4/20/2016 Well Name: MPU I-04AL1 API Number: 50-029-22068-60-00 Current Status: SI Oil Well [Failed ESP] Pad: I-Pad Estimated Start Date: May 4, 2016 Rig: ASR#1 - Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 201-093 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907)777-8333 (0) (907)444-2881 (M) Current Bottom Hole Pressure: 1,556 psi @ 4,000' TVDss (SBHPS 01/11/2014/7.48 ppg EMW) Maximum Expected BHP: 1,556 psi @ 4,000' TVDss (No new perfs being added) / MPSP: 1,156 psi - (0.10 psi/ft gas gradient) Brief Well Summary: MPU I-04AL1 was drilled in July 2001 using Nabors 3S and coil tubing to drill the dual laterals into the Schrader Bluff OA and OB sands. The initial ESP was installed using Nabors 4ES in July 2001. The ESP was changed out using Nabors 4ES in November 2005 and October 2009. The ESP was changed out using Doyon 16 in February 2014 and a Y-tool was added to the ESP completion.The ESP recently failed on 1/25/2016. Notes Regarding Wellbore Condition • Casing tested to 1,000 psi down to 4,330' MD(VTL Packer)on 7/19/2001. Objective: Pull failed ESP, pressure test casing, and run a new ESP. / Brief RWO Procedure: Pre-Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 8.5 ppg sea water down tubing,taking returns up casing to 500 bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 7. RD Little Red Services and reverse out skid. 8. RU crane. Set BPV. ND Tree. NU 11" BOPE. RD Crane. 9. NU BOPE house.Spot mud boat. WO Rig Procedure: 10. MIRU Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 11. Check for pressure and if 0 psi pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/8.5 ppg sea water prior to pulling BPV. Set TWC. i • Well Prognosis Well: MPU I-04AL1 Hilcorp Alaska,LL, /Date:4/20/2016 12. Test BOPE to 250 psi Low/2,500 psi High, annular to 250 psi Low/1,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 2-7/8" test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 13. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz(AOGCC) and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 14. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/8.5 ppg sea water as needed. 15. MU landing joint or spear and recover the tubing hanger. Contingency(If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 16. POOH and lair down the 2-7/8"tubing. Tubing may be re-used. Lay down failed ESP. Replace bad joints of tubing as necessary. 17. RIH with scraper assembly to 4,330' MD on 2-7/8"tubing. Circulate the well clean. 18. If needed, spot sized salt pill to control losses. POOH and LD tubing. 19. MU 2-1/4" mill, 1-11/16" motor,jars and RIH 6 jts of 1.660" 3.02# BTS-8 small tubing. 20. MU crossover from 1.660" BTS-8 x 2-7/8" EUE tubing. 21. RIH to—4,480' MD on 2-7/8"tubing. Circulate the well clean (cleanout inside of 3-1/2" screens). a. Min ID thru screens is 2.992". b. Do not tag deployment sleeve that 4" GS fishing neck and 3.0" ID at 4,499'. 61 22. If needed, spot sized salt pill to control losses. POOH and LD tubing. c, 23. PU test packer and RIH to^'4,300' MD. Pressure test casing to 1,500 psi for 30 charted minutes. .k POOH and LD test packer and tubing. 24. PU new ESP and RIH on 2-7/8" tubing. Set base of ESP at±4,250' MD. • • Well Prognosis Well: MPU I-04AL1 Hikorp Alaska,LL Date:4/20/2016 25. Land tubing hanger. RILDS. Lay down landing joint. Note PU (Pick Up) and SO (Slack Off) weights on tally. 26. Set BPV. 27. Rig down ASR#1. Post-Rig Procedure: 28. RD mud boat. RD BOPE house. Move to next well location. 29. RU crane. ND BOPE. 30. NU existing 2-9/16" 5,000#tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 31. RD crane. Move 500 bbl returns tank and rig mats to next well location. 32. Replace gauge(s) if removed. 33. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Existing Tree/Wellhead 5. FWD Circ to Kill Tank Flow Diagram 6. REV Circ to Kill Tank Flow Diagram 7. Bleed to Pits Flow Diagram 8. Blank RWO MOC Form 14 • • Milne Point Unit Well: MPU I-04AL1 SCHEMATIC Last Completed: 2/20/2014 HiIcoru Alaska,LLC PTD: 201-093 WELLHEAD OPEN HOLE/CEMENT DETAIL Tree 2-9/16"CIW 13-3/8" _ Cmt w/485 sx of PF C in 30"Hole Wellhead 11"x 2-7/8"EUE Top&Bottom 9-5/8" Cmt w/1,111 sx PF E,244 sx Class"G"in 12-1/4"Hole Orig.KB Elev.:52.0'/Orig.GL Elev.:35.0' FMC Tubing Hanger 7" Cmt w/260 sx Class"G"in 8-1/2"Hole RKB—Hanger:23.85'(Doyon 16) c ;,A CASING DETAIL +< Size Type Wt/Grade/Conn Drift ID Top Btm BPF 13-3/8" 13-3/8" Conductor 54.5/K-55/Welded 12.459" Surf 115' N/A 1 1 9-5/8" Surface 36/J-55/BTC 8.765" Surf 2,599' 0.0773 7" Production 26/L-80/BTC 6.151" _ Surface 4,536' 0.0382 >41, 6' 2-3/8" _ Liner"A" 4.6/L-80/ST-L 1.901" _ 4,499' 7,184' 0.0039 9-5/8 2-3/8" Liner"B" 4.6/L-80/ST-L 1.901" 4,531' 6,834' 0.0039 I 2 TUBING DETAIL 3 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441" Surf 4,182' 0.0058 I WELL INCLINATION DETAIL KOP@400'MD 4 Max Wellbore Angle=93.5 deg @ 4,971'MD 25.23 deg @ 4,500'MD 5 JEWELRY DETAIL 1; k. 6 to , No Depth Item • 'c'a 8 1 166' ST 2:2-7/8"GLM 2.875"x 1"KBMM GLM(BK-Orifice Valve Set 2/17/16) Blanking Plug ,F ` s'' 2 3,500' Heat Trace sr 9 t: 3 4,007' ST 1:2-7/8"GLM 2.875"x 1"KBMM GLM(BK-Dummy Valve Set 2/20/14) ° ii 1p 4 4,143' 2-7/8"XN Profile(2.205"No-Go Packing Bore ID) 4, 11 5 4,182' Y-Tool(1.995"ID) , 6 4,183' 2-3/8"AAN Profile(1.80"ID w/1.875"BM Blanking Plug) 0 00 7 , 7 4,259' 2-3/8"WLEG(Btm of 1.82"ID By-Pass Tubes) '!` 12 8 4,189' WellLift Discharge Gauge Unit ,` 9 4,190' Centrilift ESP:P6 at 11, + 1,13 10 4,203' Gas Separator ffi •o; 11 4,207' Tandem Seal Section '*' = s, 12 4,220' Tandem ESP Motors(46 HP each) 4' 13 4,250' Phoenix Sensor w 6 fin Centralizer—Bottom @ 4,254' "` „ ,4 p.-- ',y 14 14 4,330' 7”Halliburton VTL Packer(3.880"ID) _ 15 4,348' 3-1/2"Halliburton Poroplus 250 micron screen(3 joints;2.992"ID) --{-:-.— 16 4,456' Baker Seal Assembly,5.75'Long(4.50 ID) NSarxls �15 17 4,457' 7"Baker ZXP Packer 1.118 4,475' 4-1/2"X Profile(3.813"Packing Bore ID) 4,383-4,451 » 19 4,478' 4-1/2"WLEG(3.958"ID) ®� '_ �' 17 20 4,499' Baker Deployment Sleeve(4"GS Fishing Neck;3.00"ID) '.F y is 21 4,510' Flow-thru Whipstock s '' 18 22 7,184' 2-3/8"Btm Baker Guide Shoe j;19 — , 23 4,531' Baker Deployment Sleeve(4"GS Fishing Neck;3.00"ID) 1, 24 6,834' 2-3/8"Btm Baker Guide Shoe ;� � \\' 25 4,550' Cement Retainer Ok Lateral " " •'' `` l.�l 214 m.... 22 SB I-04AL1:7,207'MD/4,070'ND LATERAL WINDOW DETAIL ^* Top of"OA"Window @ 4,510'MD;Bottom @ 4,515'MD;Angle @ top of window is 25 deg a Top of"OB"Window @ 4,536'MD;Bottom @ 4,542'MD;Angle @ top of window is 25 deg 10t "OB"Lateral 24 GENERAL WELL INFO ' • API:50-029-22068-01-00 V SB I-04A:6,888'MD/4,125'ND Sidetracked&Liners Run by Nabors 3S—7/11/2001 25 ¢, Screens&ESP Completion by Nabors 4ES—7/19/2001 /" c ESP Replacement by Nabors 4ES—11/10/2005 7'W.4)1'.0 `f, ESP Replacement by Nabors 4ES—10/30/2009 ESP Replacement,Add Y-Tool by Doyon 16—2/20/2014 Revised By:JLL 4/20/2016 11 . Milne Point Unit Well: MPU I-04AL1 PROPOSED SCHEMATIC Last Completed: Proposed Hilcorp Alaska,LLC PTD: 201-093 WELLHEAD OPEN HOLE/CEMENT DETAIL Tree 2-9/16"CIW 13-3/8" Cmt w/485 sx of PF C in 30"Hole Wellhead 11"x 2-7/8"EUE Top&Bottom 9-5/8" Cmt w/1,111 sx PF E,244 sx Class"G"in 12-1/4"Hole Orig.KB Elev.:52.0'/Orig.GL Elev.:35.0' FMC Tubing Hanger 7" Cmt w/260 sx Class"G"in 8-1/2"Hole RKB—Hanger:23.85'(Doyon 16) j ,,:.,411, i1 A �,° CASING DETAIL i +' l Size Type Wt/Grade/Conn Drift ID Top I Btm BPF 13-3/8" 1 13-3/8" Conductor 54.5/K-55/Welded 12.459" Surf 115' N/A 9-5/8" Surface 36/J-55/BTC 8.765" Surf 2,599' 0.0773 7" Production 26/L-80/BTC 6.151" Surface 4,536' 0.0382 2-3/8" Liner"A" 4.6/L-80/ST-L 1.901" 4,499' 7,184' 0.0039 9-5/8 2-3/8" Liner"B" 4.6/L-80/ST-L 1.901" 4,531' 6,834' 0.0039 2 TUBING DETAIL 3 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441" Surf 4,254' 0.0058 WELL INCLINATION DETAIL KOP@400'MD i 4 Max Wellbore Angle=93.5 deg @ 4,971'MD CI ° if 25.23 deg @ 4,500'MD !: F A\W) Q JEWELRY DETAIL le w No Depth Item i • 5 1 200' ST 2:2-7/8"GLM 2.875"x 1"KBMM GLM(BK-Orifice Valve Set 2/17/16) N 2 3,500' Heat Trace 6 3 4,050' ST 1:2-7/8"GLM 2.875"x 1"KBMM GLM(BK-Dummy Valve Set 2/20/14) ' 7 4 4,150' 2-7/8"XN Profile(2.205"No-Go Packing Bore ID) 1 5 4,199' WeIILift Discharge Gauge Unit 8 6 4,200' Centrilift ESP:P4 P i 7 4,213' Gas Separator g 8 4,217' Tandem Seal Section i 9 4,230' Single ESP Motor(84 HP each) 74 f10 10 4,250' Phoenix Sensor w 6 fin Centralizer—Bottom @ 4,254' yIf - 11 4,330' 7"Halliburton VTL Packer(3.880"ID) e 12 4,348' 3-1/2"Halliburton Poroplus 250 micron screen(3 joints;2.992"ID) 13 4,456' Baker Seal Assembly,5.75'Long(4.50"ID) 11 ley 14 4,457' 7"Baker ZXP Packer ‘ 15 4,475' 4-1/2"X Profile(3.813"Packing Bore ID) 16 4,478' 4-1/2"WLEG(3.958"ID) N Sand12 17 4,499' Baker Deployment Sleeve(4"GS Fishing Neck;3.00"ID) 18 4,510' Flow-thru Whipstock 4,383-4,451 1+13 19 7,184' 2-3/8"Btm Baker Guide Shoe 41', >_, ,14 20 4,531' Baker Deployment Sleeve(4"GS Fishing Neck;3.00"ID) 1.1 r 15 6,834' 2-3/8"Btm Baker Guide Shoe i°1'. '16 �� 22 4,550' Cement Retainer 17 P19(= "OA"Latey '� r 18 • 19 14 SB I-04AL1:7,207'MD/4,070'TVD ` LATERAL WINDOW DETAIL „*; Top of"OA"Window @ 4,510'MD;Bottom @ 4,515'MD;Angle @ top of window is 25 deg , Top of"OB"Window @ 4,536'MD;Bottom @ 4,542'MD;Angle @ top of window is 25 deg ii. "OB"Lateral 41, 21 GENERAL WELL INFO SB I-04A:6,888'MD/4,125'TVD • API:50-029-22068-01-00 �' Sidetracked&Liners Run by Nabors 3S—7/11/2001 ,, 22,, Screens&ESP Completion by Nabors 4ES—7/19/2001 ` . f ESP Replacement by Nabors 4ES-11/10/2005 7 .0"! ;"i ESP Replacement by Nabors 4ES—10/30/2009 ESP Replacement,Add Y-Tool by Doyon 16—2/20/2014 Revised By:1LL 4/20/2016 • S Milne Point ASR Rig 1 BOPE nstr„rr %h*4ut.1 I C 11" BOPE Stripping Head 1' 1 3.98' ili °I Shaffer 11"- 5000 II iii 11111111i H— ILITTV till 11!I' M- CI 1 -U ERIE 4.54' :_.t �= VBR or Pipe Rams 11" 5000 `M _� i = Blind Iii Illi Iii III II 21/16 5M Kill Line Valves 21/16 5M Choke Line Valves `kr2.00' ,17„ ® 1r 1 . 1 ii„ iJIIpIIILtII trill" Manual Manual Manual HCR Updated 8/19/2015 • • MPU I-04A . H EXISTING TREE/WELLHEAD Wellhead/Tree Milne Point Unit Hilcorp Alaska,LLC y,1 Ilb sat 411111111W- tsi Oft tai 117, 7 0 2 9/16"CIW 5M Swab Valve 0'0 a• _ Sa c 0,aH. q / rl N its ..411"/"... 2 9/16" CIW 5M Wing Valve 0 2 9/16" CIW 5M $SV with Baker actuator ala-",.. I a} 0 r ,, p 2 9/16" CIW 5M Master Valve a 0p 0` Iii ;. .: ••a I 11"x 2 9/16" CIW 5M al ESP Tbg Adapter 11"x11"FMC 5M -_ - Tubing Head K i i i■ice . loft...... ,_ El `' c; t, = ;lot 2 1/16" CIW 3M HWO Valve �. I c 9)o III - w- o 1 NM 1"FMC 5M imair 11"x Casing Head •— _ +� " !f1 i1 _ 144711k,"`© ig 0 2 1/16" CIW 3M HWO Valve j • 0 to - E = < I § § As It ,..c....: .bt ,..i .f...2 ri2 cs = 7., cu o E 1 0 .?.- > •.-'> .Y. •E C < 1 X Z 13-213 0 co a, § il In f Dal Mil -c OM 9TD O w •• - r, ; > „ c.D ‘...7 ra. a — ,.. a 2 co 1- 0 ns L'ei <Lposi7E i c.9 2 0 0 i co co J CI3 e . c. Lra o o < ).n 8D7-1T u. lil a) .'' 7., a, _v 4------..< V o ..c u i . .301' i'•:::. ‘-)'-'Muc ':--1'.1"-'''''mi?.::,..: ..... au 4 MIN2MitailM110...: 'I I It 1 1!.. 1 - --.....- -a 0, ,..., ,,,,• , ,.,.. ,.. , z ,_- 1— u a., u c to =, m 7t: o an '..' -DOI ji, i Ur< H 1 HF co < 1-- 2 (..7 ).1.z < Npt 9)1 yr Tr Is ki _, ----i i— If'11 1-- 1-- v., >- an a LO 2 1- F. HF2 n ce o. ,n 0 2 7- —-N-- *— —NJ- -I I- I 0:74"31- (— 0- 7., • • 12 2 e rd o dU c - xwa cox 0 u OTS 9TH a m0 > > oJ O u ^ Oa p Z V " Z u:Q y oH7gl 3 A •Z w ZD Ln: 6) TT) 17T) m J (7 M u. M U O z u^ U u E m Da v m m 0 oo (° g In Q g,NIn4 u a, v ..fl S m 1 Y O L u O p wa1 i 2 o m m U .`i.9 c u _ A • - m t. u F 0 C wgnl ..44M ' - m Z .a 13 • N V C F- R 9 o.• Z r D u c m C m 0 m •y C a w H F- H � Dy f11cc O y$ y 10.7 Ysr 9)1 Y L Ik•� .4.4 J r 9 M Y a 1- L.,H T H z — —I I- gO a. u LLjO K V Vvii • • � £ < I § § Ao cn Ce. b > o C O v t o v A et G G, cL U .d o" R t.. ❑ J R rt, #n�S Li.� m -1 m § §p� N — TO TO c. t U .',.74 o �7 J Ca F > „ U pv V ,n R z �, m m a> Z E u VII •ai > v °' o v' Z a a DOO G DOQDOo--D04 m W > (.. a Q p. bT) 13.7 Y ZD 8 U 6) jjM V' Y U i V® V V� A m a v m m o m V tra oa 8D 11 V C C CDC C .0 D N C d Y 0 = V A O ON a 2 - o O CO u . °° p— 4 V—ppa.l �ugnl • c,Tiii; 1__ Y N N 6d...w Z 'C Z_ 7 V c m c m 0 m Q< H I w -I 1— . 00 J 2 oo2 ut of 2 I r O y y 0 u z 4°4 2 � 9)1 L M Y Y = 2 -I I— 0 a L v) 2 0 E H r z a vi p Q -NI — 2 , L Y T 4,,,_ - � � a --1,04- C p. . o �' LL ! u v, 0 . • • � � R / > � 2 o 0 Tel a 2 c 0 o § U 2 � 0 = �«W E - 0 of 0 U = § 10- » 0. £< , - = 0 / _0 < � �- > = f �� / \.§ g 7 % .\ el -0 a) ■ 2 \ .4 � - 9 k k - o S§ t� ,- C3co Z OL 0 0 / $ Q � Z .46 L. / a « > a) 9 2 ° 0 v-0 CO 2 A Cn 2 U. n Ak = a =191 § / ■ 7 / U) J% « .c a)L.cb E % a) a)0 is o c o .§ a -o ET) \ a a) \ / co c § c -o ® E Cl) \ p tn Ui § 73 2 - o o 0. 0_ 5 0. 03 4 go 0 0. ct - u) � � E 0 2 » 0 c * @ ' © ■ � @ a ■ 2 04 U V 7k 2 it C.4 © . 0 9 o t. o 0 ° >TO / . 2 >.0 U &0. 0 2 2 k 9 Q a COt3 0 STATE OF ALASKA ~~~~~~~~ ALA~OIL AND GAS CONSERVATION COM~ ON REPORT OF SUNDRY WELL OPERATIONS ~lOV 1~ 2009 1. Operations Performed: ' ^ Abandon ~ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended ~~Of~~ ^ Alter Casing ~ Pull Tubing ^ Perforate New Pool ^ Waiver ~ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension C nge Out ESP 2. Operator Name: 4. Well Class Before Work: . Permit To Drill Number: BP Exploration (Alaska) Inc. ~ Development ^ Exploratory 201-093 3. Address: ^ Service ^ Stratigraphic . API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22068-60-00 7. Property Designatio~ . Well Name and Number: ADL 025906 MPI-04AL1 9. Field / Pool(s): ~ Mil~e Point Unit / Schrader Bluff 10. Present weil condition summary Total depth: measured ~ 72p7~ feet true vertical ~ 4070' feet Plugs (measured) None Effective depth: measured 72Q7' feet Junk (measured) None true vertical 4070' feet Casing Length Size MD ND Burst Coilapse Structural Conductor $0' 20" 115' 115' 2730 1130 Surface 2564' 9-5/8" 2599' 2354' 3520 2020 Intermediate Production 4475' 7" 4510' 3975' 7240 5410 ~iner 2685' 2-3/8" 4499' - 7184' 3965' - 4069' 11200 11780 Perforation Depth: Measured Depth: 4383' - 7207' True Vertical Depth: 3860' - 4070' Tubing (size, grade, measured and true vertical depth): 2-~~$ ~ 6'~ L-80 4272' 3760' Packers and SSSV (type, measured and true vertical depth): ~~~ Halliburton 23-29# VTL Versa-trieve 4338' 3819' _.,. .._. _.,~...~, _ _....._.._. 7" Baker "SLZXP" 4463' 3933' 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: ~,~ ~ ~~ ~} ~ ~ ~' ~~{J~ ~"~~;U~ ~~! ~ 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 13. Attachments: ~ Copies of Logs and Surveys run 4. Well Class after work: ^ Exploratory ~ Development ^ Service ~ Daily Report of Well Operations ~ Well Schematic Diagram . Well Status after work: ~ Oil ^ Gas ^ WDSPL ^ GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG 16. 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: Contact Mehrdad Nadem, 564-5941 N/A Printed Name Terrie Hubble Title Technical Assistant ~ ~ 4 Prepared By Name/Number: Signature Phone 564-4628 Date ~ 7 Terrie Hubble, 564-4628 'an Form 10-404 Revised 07/2009 t~~ Submit Original Only ~.~.~ ~ ~ 1/~ ~y ,,~,~` ~~/zo%s WELLHEAD6115 5M W M w/ ~ M P I-04A Orig~ GL = 35' (NABORS 27E) 2-7/8" 8rd TREE TOP CONNECTION 13 3/8", 54.5#/ft, K-55 Weld Set 115' 9 5/8", 36#/ft, K-55 Butt 2599' 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg. ( drift ID = 2.347", cap. = 0.00592 bpf ) 7" 26 ppf, L-80, Btrc. production casing ( drift ID = 6.151", cap. = 0.0383 bpf ) KOP @ 600 ' Max wellbore Angle: 38° @ 2200' MD Hole angle trough perfs = 90 deg. N SAND PERFORATION SUMMARY Size SPF Interval (ND) 24 gm 24 4,383' - 4392' 3860' - 3868' 24 gm 24 4,411' - 4428' 3885' - 3901' 24 gm 24 4,443' - 4451' 3914' - 3921' 4" Deployment Sleeve top of liner 4,499' Baker 3.5" FL4S x 2-3/8" FL4S Top of window @ 4510' 4" Deployment Sleeve top of liner 4,531' Baker 3.5" FL4S x 2-3/8" FL4S Top of window @ 4536' O SAND PERFORATION SUMMARY (SQUEEZED OFF, BELOW CEMENT RETAINER) Size SPF Interval (ND) 37 gm 37 gm 5 5 4,554' - 4,588' 4,624' - 4,655' 4,015' - 4,045' 4,078' - 4,106' Camco 2-7/8" x 1" 160' sidepocket KBMM GLM ~ Heat trace run to 3450' RA Tag @ 3,623' Camco 2-7/8" x 1" 040' 4 sidepocket KBNiM GLM , 2-7/8" XN nipple 4 176` (ID 2.205") ' , WeI1Lift DGU 4,211 ` Centrilift Tandem ESP ' 63-G-12 MVP/SSD 4,223 68-P6 SXD Tandem Gas Separator 4 244' GRSFTX AR H6 , Tandem Seal Section ~ Model GSB3 DB UT/LT 4,249 SB/SB PFSA Motor, 76 HP, 1360 volt, 4 262` 34 amp, Model KMH , WeIILift MGU 4,269' w/6 fin Centralizer 7" Halliburton 23-29# "VTL" Versa-trieve Packer H-S 3-1/2" X-O H-S 3-1/2" 250 micron "Poroplus" Screen (87' total, 4371 ` - 4458') Baker Seal Assembly 7" Baker "SLZXP" Packer (4.5" ID) 4-1/2" Halliburton X Nipple (3.813" ID) @ 4475` Tubing Tail @ 4477.5' IHole td @ I-04A L1 ~173~ 81 jts. of Pre-Drilled 2-3/8" (4,560' - 7,151') 2-3/8" 4.6#, L-80 STL tubing. Baker Guide shoe @ 7,184' I Hole td @ I-04A 6895' 69jts. of Pre-Drilled 2-3/8" (4,583' - 6,794') 2-3/8 " 4.6#, L-80 STL tubing. Baker Guide shoe @ 6,834' 7", 26#/ft, L-80 Butt Shoe 4,881' DATE REV. BY COMMENTS 3/9/95 RWO - INSTALL ESPCP 8-29-96 ESP RWO POLAR #1 7 13/ 1 7/22/01 MD B. Hasebe Nabors 3 rilling sidetrac Nabors 4ES Completion 118//05 Lee Hulme Nabors 4ES Completion 10/29/09 REH ESP RWO w/HT - Nabors 4ES MILNE POINT UNIT WELL I-04A ~i nin• ~n_ma_~~nFA ~ ~ $P E~P~C~F~AT1~3N Pa~e 1 c~f 7 ~~e~~~i~nS ~~r~~~r~ R~p4rt Legal Well Name: MPI-04 Common Well Name: MPI-04 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 4ES IlatQ ~~rnm - Tn ~ Hn~~r~ I TaSk ~ Code 1 NPT I Spud Date: 11/15/1990 Start: 10/16/2009 End: Rig Release: 10/30/2009 Rig Number: 4ES Phase Descriptic~n of Qp~erations 10/23/2009 06:00 - 18:00 12.00 MOB N WAIT PRE WAITING FOR CTU TO VACATE MPI PAD SO WE CAN MOVE RIG ON MPI PAD. 18:00 - 00:00 6.00 MOB N WAIT PRE -WAITING FOR CTU TO VACATE MPI-04 -RIGGING DOWN, CLEANING RIG -HANGING DOUBLE SHEAVE 10/24/2009 00:00 - 06:00 6.00 MOB N WAIT PRE WAITING FOR CTU TO VACATE MPI PAD SO WE CAN MOVE RIG ON MPI PAD. RIG STILL OVER MPL-29. -LRS FREEZE PROTECTED MPL-29 WELL BY BULLHEADING 65-BBLS. DEAD CRUDE DOWN IA AND BULLHEADING 15-BBLS. DEAD CRUDE DOWN TUBING. 06:00 - 18:00 12.00 MOB N WAIT PRE WAITING FOR CTU TO VACATE MPI PAD SO WE CAN 18:00 - 21:30 I 3.501 MOB I P 21:30 - 22:00 I 0.50I MOB ~ P 22:00 - 00:00 I 2.001 MOB ~ P I 10/25/2009 100:00 - 03:00 I 3.00 ~ MOB ~ P 03:00 - 09:00 I 6.00 ~ MOB ~ P 09:00 - 12:00 I 3.00 I RIGU I P MOVE RIG IN MPI PAD. -CTU HAD MEOH SPILL. MPU ENVIROMENTAL CLEANING UP SPILL. -RIG CREW CONTINUING TO DISCUSS INPUT TO SAFE WORK PLAN. -MPU WELL OPS MOVED ESP CABLE SPOOLER TO MPG PAD FOR STAGING TO MPI PAD. -REVIEWED MPU WELL TRACKING TOOL OUTPUT FOR MPL-29 WITH DAY CREW. -GAINED INDIVIDUAL COMMITMENT FROM EACH CREW MEMBER THAT THEY ARE +100% COMMITTED TO WOFiKING IN A SAFE AND CONTROLLED MANNER AT ALL TIMES AND THAT THEY WILL ALWAYS LOOK OUT FOR EACH OTHER AND THAT THEY ARE EACH RESPONSIBLE FOR THEIR OWN SAFETY AS WELL. -16:00-HRS. RECEIVED RELEASE FROM MPU WELL OPS TO COMMENCE RIG MOVE TO MPI PAD. PRE R/D FLOWLINE, SCOPE DOWN AND LOWER DERRICK. -BLOW DOWN AND UNHOOK LINES. -PULL PITS FROM SUB. -NOTIFIED AOGCC WITH 24 HOUR NOTICE OF UPCOMING 80P TEST FOR MPI-04 AT 19:00 HOURS PRE PEAK TRUCKS AND PUSHER ON LOCATION. HOLD PREJOB MEETING FOR RIG MOVE WITH ALL PERSONNEL. LOAD SHOP AND MOVE OUT OF WAY. PRE MOVE PIPE SHED, PITS AND SUB OFF WELL. NOTIFIED PAD OPERATOR OF IMPENDING MOVE PRIOR TO MOVING SUB OFF WELL. PICKED UP HERCULITE BERM AND RIG MATS AROUND WELL CELLAR. CLEANED UP AROUND WELL CELLAR AND IOADED OUT RIG MATS AND DUNNAGE ON LOWBOY. PRE CLEANED UP AROUND WELL CELLAR AND LOADED OUT RIG MATS AND DUNNAGE ON LOWBOY. LINE UP MODULES IN ORDER OF MOVE TO ARRIVE AT MPI PAD IN PROPER ORDER. PRE MOVE RIG COMPONENTS FROM MPL PAD TO MPI PAD. TRUCK WITH SUB SPUN OUT ON TRACT 14 INTERSECTION. WAITED 20 MINUTES ON GRAVEL FOR TRACTION AND RESUMED MOVE. ARRIVED ON MPI PAD AT 09:00-HRS. PRE SPOT SUB, PIPE SHED AND PITS. PREPARE TO RAISE rnrneu. ~viu<wa a.ca.w.vn • • Legal Well Name: MPI-04 Common Well Name: MPI-04 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 4ES Date From - To Haurs Task C ~---- ~ 10/25/2009 09:00 - 12:00 3.00 RIGU P 12:00 - 12:30 0.50 RIGU P 12:30 - 16:30 I 4.00 I RIGU I P 16:30-17:00 I 0.50IWHSURIP 17:00 - 18:30 1.50 WHSUR P 18:30 - 19:00 ~ 0.50 ~ KILL ~ P 19:00 - 21:30 ~ 2.50 ~ KILL ~ P 21:30 - 22:00 I 0.50I KILL I P 22:00 - 23:30 1.50 WHSUR P 23:30 - 00:00 0.50 WHSUR P 10/26/2009 00:00 - 01:00 1.00 WHSUR P 01:00 - 03:00 ~ 2.00 ~ BOPSUF{ P 03:00 - 04:00 I 1.001 BOPSUF~ P Start: 10h 6/2009 Rig Release: 10/30/2009 Rig Number: 4ES Spud Date: 11 h 5h 990 End: Phase ' Descrip#ion of Operations PRE DERRICK. DEPLOYED CoW SIGN AT ENTRANCE TO PAD. PRE PJSM: REVIEWED RAISING DERRICK AND SCOPING DERRICK PROCEDURES WITH ALL CREW. PRE RAISE DERRICK TO HALF MAST. SCOPE DERRICK TOP SECTION UP AND PIN IN PLACE. HOOK UP CIRCULATING LINES BETWEEN PITS AND SUB. HOOK UP CIRCULATING LINES FROM CHOKE TO TIGER TANK, " ACCEPTED RIG AT 15:00-HRS. " DECOMP ALL CREW: REVIEWED PLAN FORWARD AND PULL BPV PROCEDURE. LOAD LUBRICATOR INTO PiPE SHED. DECOMP PUMU LUBRICATOR AND MAKEUP TO SWAB VALVE. PRESSURE TESTED LUBRICATOR AGAINST CLOSED SSV TO 500-PSI WITH DIESEL. -PULL CAMERON 2-1/2" TYPE "H" BPV. -TUBING PRESSURE 300 PSI, IA PRESSURE 300 PSI AND OA PRESSURE 200 PSI. ~ DECOMP R/U LINESTO KILL WELL. -CIRULATING LINES WERE PRESSURE TESTED TO 3,500 PSI. RETURN LINE TO TIGER TANK WAS TESTED TO 120 PSI. DECOMP KILL WELL BY PUMPING 120 DEGREE SEAWATER DOWN THE TUBING TAKING RETURNS OUT THE IA THROUGH THE CHOKE MANIFOLD TO THE TIGER TANK. PUMP TUBING VOLUME OF 25 BBLS AT 4 BPM WITH 500 PSI. LINE UP AND BULLHEAD 25 BBLS AT 3 BPM WITH 1,000 PSI DROPPING TO 350 PSI. LINE UP AND PUMP DOWN THE TUBING TAKING RETURNS THROUGH THE CHOKE TO THE TIGER TANK AT 4 BPM WITIi 350 PSI. HEAVY CRUDE RETURNS CLEANING UP TO CLEAN 8.5 PPG SEAWATER RETURNS. 40 -45 PERCENT RETURNS DURING WELL KILL. DECOMP MONITOR WELL, 0 PSI ON TUBING, 0 PSI ON IA. -BOTH TUBING AND IA ARE ON A VAC. DECOMP INSTALL CAMERON 2-1/2" TYPE "H" TWC WITH CAMERON WELlHEAD TECH AND TEST FROM ABOVE TO 3,500 PSI FOR 10 CHARTED MINUTES. TEST FROM BELOW BY PUMPING AT 4 BPM WITH 300 PSI FOR 10 MINUTES ON THE CHART. DECOMP WD 2-9/16" 5M WKM TREE AND ADAPTOR FLANGE. DECOMP N/D 2-9/16" 5M WKM TREE AND ADAPTOR FLANGE AND REMOVE FROM CELLAR. -INSPECT AND FUNCTION LDS. -INSPECT HANGER THREADS, 2-7/8" EUE, 9 TURNS TO MAKE UP IN HANGER. DECOMP N/U 13-5/8" 5M HYDRIL BOP STACK. -HOOK UP CHOKE AND KILL LINES. -HOOK UP KOOMEY LINES AND TURNBUCKLES. INSTAL FLOW RISER. DECOMP M/U BOP TEST ASSEMBLY. - FILL BOPE WITH WATER AND PURGE AIR FROM SYSTEM. DECOMP TEST BOPE TO 250 PSI LOW AND 3,500 PSI HIGH. TEST BLINDS, CHOKE MANIFOLD VALVES, CHOKE AND KILL 04:00 - 10:00 I 6.00 I BOPSUF~ P ~ ~ BP' EXPI.~RA-TIC)N Page,3 of 7 aperatic~ns ~umrr~ary R~epor~ Legal Well Name: MPI-04 Common Well Name: MPI-04 Spud Date: 11/15/1990 Event Name: WORKOVER Start: 10/16/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/30/2009 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Haurs Task Code NPT Phase Description afi Operations 10/26/2009 04:00 - 10:00 6.00 BOPSU P DECOMP LINE VALVES, FLOOR VAWES, 2-7/8" X 5" VBR'S, ANNULAR PREVENTER. TEST VBR'S AND ANNULAR PREVENTER WITH 2-7/8" TEST JOINT. PERFORM DRAWDOWN TEST ON KOOMEY. -AOGCC WITNESS OF TEST WAS WAIVED BY JOHN CRISP. ALLTESTING WITNESSED BY NABORS TOOLPUSHER AND BP WSL. -UNABLE TO OBTAIN GOOD TEST OF 2-7/8" X 5" VBR'S, AND ANNULAR PREVENTER WITH 2-7/8" TEST JOINT. LAYED DOWN 2-7/8" TEST JOINT, CLOSED BLIND RAMS, KILL AND CHOKE HCR VALVES. PRESSURED UP BOPE TO 3500-PSI AND DISCONNECTED TEST HOSE TO ISOLATE TEST PUMP. PRESSURE BLED OFF -200-PSI IN 10-MINUTES. INSPECTED BOPE STACK VISUALLY AND OBSERVED NO LEAKS. MADE DECISION TO CHANGE OUT TWC. 10:00 - 18:00 8.00 WHSUR C DECOMP PUMU DUTCH LUBRICATOR LOCKDOWN MANDREL. PUMU MPU WELL SUPPORT LUBRICATOR AND MADE UP TO LUBRICATOR LOCKDOWN MANDREL. PRESSURE TESTED LUBRICATOR TO 500-PSI WITH DIESEL. UNABLE TO OBTAIN PRESSURE TEST. FOUND DUTCH LUBRICATOR LOCKDOWN MANDREL EXTENSION SEAL LEAKING. LAYED LUBRICATOR AND DUTCH LUBRICATOR LOCKDOWN MANDREL DOWN. SEPARATED LOCKDOWN MANDREI EXTENSION AND FOUND INTERNAL STOP RING NOT SET HIGH ENOUGH TO ALLOW PROPER MAKEUP OF JOINT. ADJUSTED STOP RING TO PROPER DEPTH AND REASSEMBLED LOCKDOWN MANDREL. PICKED UP AND RESET LOCKDOWN MANDREL AND LUBRICATOR. SUCCESSFULLY PRESSURE TESTED LUBRICATOR TO 500-PSI. PULL AND INSPECT TWC. OBSERVED DISPLACED AND CREASED O-RING ON TWC. , WELL ON VACUUM. LAYED DOWN LUBRICATOR AND ' DUTCH LUBRICATOR LOCKDOWN MANDREL. MPU WELL SUPPORT SET NEW TWC WITH T-BAR. ATTEMPTED TO PRESSURE TEST SECOND TWC. UNABLE TO OBTAIN SUCCESSFUL PRESSURE TEST. -PUMU DUTCH LUBRICATOR LOCKDOWN MANDREL. PUMU MPU WELL SUPPORT LUBRICATOR AND MADE UP TO LUBRICATOR LOCKDOWN MANDREL. PRESSURE TESTED LUBRICATOR TO 500-PSI WITH DIESEL. MPU WELL SUPPORT PULLED SECOND TWC. NO APPARENT DAMAGE TO TWC OBSERVED. 18:00 - 22:00 4.00 WHSUR C DECOMP -WAITING ON WEATHERFORD WIRLE LINE RETRIEVABLE PLUG AND SLB WiRE LINE UNIT. RIG CREW HUNG ESP CABLE TRUNK. KEEPING THE HOLE FULL W/ 20 BLM. 22:00 - 23:00 1.00 WHSUR C DECOMP -WEEKLY SAFETY MEETING DISCUSSION INVOLVED SLIPS TRIPS AND FALLS, RECENT SLB VEHICLE ACCIDENT. WENT THROUGH SAFETY STATS WITH NAD SAFETY TRAINER JOHN SMITH. INCLUDED RIGS 4, 7 AND 9 • • BP' EX Op~ratic~r~s Legal Weil Name: MPI-04 Common Well Name: MPI-04 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 4ES Date` From - To Hours Task Code NPT 10/26/2009 22:00 - 23:00 1.00 WHSUR C 23:00 - 00:00 1.00 WHSUR C I 10/27/2009 100:00 - 03:00 I 3.00 ~ WHSUR ~ C 03:00 - 06:00 I 3.00 ~ WHSUR ~ C 06:00 - 12:00 I 6.001 WHSUR IC 12:00 - 16:30 I 4.50I WHSUR I C 16:30 - 17:30 I 1.00 I WHSUR I C QRA710N ' Page 4 of 7 i~~nary Repor# Spud Date: 11 /15/1990 Start: 10/16/2009 End: I Rig Release: 10/30/2009 Rig Number: 4ES Phase Description o# Opera#ions D~COMP DECOMP -SPOTTING SLB WIRLE LINE EQUIPMENT, PJSM WITH SLB WIRLE LINE CREW AND RIG CREW, WIRELINE WSLJOHN PERL. DECOMP -PJSM WITH SLB WIRE LINE AND RIG CREW, WIRELINE UNIT WSL-JOHN PEARL PUMU WIRELINE TOOLS, SHEAVES, PUMP SUB, LUBRICATROR AND WIRELINE BOP. PRESSURE TEST SLB IUBRICATOR TO 500 PSI AGAINST BLIND RAMS. DECOMP -MAKE UP WEATHERFORD 2-7/8" WIRELINE RETRIEVABLE PLUG. -RIH TO 135' (MIDDLE OF FIRST FULL JNT ABOVE GLM AT 160'). -FIRST AND SECOND ATTEMPTS TO SET PLUG UNSUCCESSFUL. -SET WRP SUCCESSFULLY ON THIRD ATTEMPT. DECOMP PRESSURE TEST BOPE AND WRP TO 3500-PSI FOR ' 10-CHARTED MINUTES. -UNABLE TO GET STABLE PRESSURE TEST. PRESSURE BLED OFF 250-PSI IN 30-MINUTES. BLED OFF AND REPRESSURED SEVERAL TIMES WITH SAME RESULTS. -MADE DECISION TO REMOVE CHOKE LINE AND KILL LINE FROM BOPE STACK TO VISUALLY VERIFY THAT MANUAL CHOKE AND KILL VALVES AND HCR CHOKE AND KILL VALVES ARE NOT LEAKING. DRAINED BOP STACK. REMOVED LINES. REFILLED STACK WITH WATER. -HELD PJSM FOR SAFE ROMAVAL OF THE CHOKE AND KII:L tINES TO VISUAL CNECK. -ALSO CALLED OUT CAMERON WELLHEAD TECH. TO RE-VERIFY THAT LOCKDOWN SCREWS ARE ALL PROPERLY TORQUED. -RESEARCH ALSO INDICATES THAT ADAPTER FLANGE API RING AND TUBING HANGER AND PENETRATOR SEALS WERE NOT PRESSURE TESTED AND VERIFIED PRIOR TO MOVING RIG ON WELL. CAMERON VERIFIED LOCKDOWN SCREWS ARE ' PROPERLY TORQUED. CAMERON HAND TORQUED THE LOCK DOWNS TO 620 FOOT PUNDS A PIECE. -RE-TEST BOPE AND WRP AFTER VERIFIYING LOCKDOWN SCREWS WERE PROPERLY TORQUED. -STILL UNABLE TO GET STABLE.PRESSURE TEST. PRESSURE BLED OFF 250-PSI IN 45 MIN. DECOMP -COMMUNICATED THE RESULTS WITH ADW RWO ENGINEERING IN 70WN. WAITING FOR A RETURN CALL FOR PLAN FORWARD. -RECONNECTING THE CHOKE AND KILL LINES TO THE BOPE STACK. DECOMP PRESSURE TEST TBG HANGER AND WRP -CLOSE BLIND-RAMS -TEST 1,500 PSI -10 CHARTED MINUTES. -GOOD TEST • • BP' E~PLC3RAT10~1 Page 5 of 7 4~eratic~ns Su~r~~ry Report Legal Well Name: MPI-04 Common Well Name: MPI-04 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 4ES ' D t F m- To Hours Task Code I NPT I l Spud Date: 11 /15/1990 Start: 10/16/2009 End: Rig Release: 10/30/2009 Rig Number: 4ES a e ro ._~se ' Description of Operations 10/27/2009 17:30 - 19:00 1.50 WHSUR C 19:00 - 19:30 I 0.50I WHSUR C 19:30 - 21:30 2.00 WHSUR C 21:30 - 22:00 I 0.50I WHSUR ~ C 22:00 - 00:00 I 2.00 I 10/28/2009 I 00:00 - 01:30 ~ 1.50 01:30 - 03:30 I 2.001 WHSUR 03:30 - 05:00 1.50 WHSUR 05:00 - 06:00 1.00 WHSUR 06:00 - 07:30 ~ 1.50 ~ WHSUR DECOMP PRESSURE TEST TBG HANGER -SCREW 2-7/8" TEST JOINT INTO HANGER. -CLOSE ANNULAR ON 2-7/8" TEST JOINT. -TEST 1,500 PSI -LD DUTCH LOCK OOWN MANDRIL SYSTEM -PU NEW HANGER DECOMP RD SLB WIRELINE IUBRICATOR AND SHEAVES. -FILL HOLE ~ 20 BPH DECOMP RU 2-7/8" ELEVATORS, INSTALLED LANDING JNT. -SUCK OUT THE BOPE STACK -BACKED OUT LOCK DOWN SCREWS, PULLED 2-7/8" TUBING HANGER TO RIG FLOOR, CUT AND SUCURE ESP CABLE. -C/O HANGER , FOUND THE PENETRATOR TO BE LOOSE. P/U WEIGHT 38(K) DECOMP RUN IN AND LAND NEW BLANKED OFF TUBING HANGER -RUN IN LOCK DOWN SCREWS , PUW (35 (K), SOW-30 (K). DECOMP TEST BOPE TO 250 PSI LOW AND 3,500 PSI HIGH. TEST BLINDS, CHOKE MANIFOLD VALVES, CHOKE AND KILL LINE VALVES, FLOOR VALVES, 2-7/8" X 5" VBR'S, ANNULAR PREVENTER. TEST VBR'S AND ANNULAR PREVENTER WITH 2-7/8" TEST JOINT. PERFORM DRAWDOWN TEST ON KOOMEY. -AOGCC WITNESS OF TEST WAS WAIVED BY JOHN CRISP. ALL TESTING WITNESSED BY NABORS TOOLPUSHER AND BP WSL. DECOMP TEST BOPE TO 250 PSI LOW AND 3,500 PSt HIGH. TEST BLINDS, CHOKE MANIFOLD VALVES, CHOKE AND KILL LINE VALVES, FLOOR VALVES, 2-7/8" X 5" VBR'S, ANNULAR PREVENTER. TEST VBR'S AND ANNULAR PREVENTER WITH 2-7/8" TEST JOINT. PERFORM DRAWDOWN TEST ON KOOMEY. -AOGCC WITNESS OF TEST WAS WAIVED BY JOHN CRISP. ALL TESTING WITNESSED BY NABORS TOOLPUSHER AND BP WSL. DECOMP PUMU DUTCH LUBRICATOR LOCKDOWN MANDREL. -PUMU SLB WIRELINE LUBRICATOR AND WIRLELINE VALVE, MAKE UP TO DUTCH LOCK DOWN SYSTEM -PRESSURE TEST TO 500 PSI WITH DIESEL, GOOD TEST. -PULL WEATHERFORD WIRELINE RETRIEAVABLE PLUG. DECOMP RD SLB WIRELINE LUBRICATOR,SHEAVES. -RD DUTCH MANDRAL LOCK DOWN SYSTEM DECOMP CIRCULATING BU -STAGING UP PUMPS, STARTING AT 3 BBPM LINED UP TO THE TIGER TANK TO AVOID INTRODUCING CRUDE TO THE ACTIVE DECOMP FINISHED CIRCULATION -CAMERON BACKED OUT LOCK DOWN SCREWS -PULLED 2-7/8" TUBING HANGER -PU WT 38 (K) -BREAK OUT LAY DOWN HANGER o_...ea. ,,,,~,~~~o o•~~•~ e~ • • BP EXPL~RA710N Page 6 of 7 C~perati+~n~ Su~nma~ry Report Legal Well Name: MPI-04 Common Well Name: MPI-04 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 4ES Date ~ From - To I Hours I Task , Code I NPT ( 10/28/2009 ~ 07:30 - 11:00 ~ 3.50 ~ PULL 11:00 - 13:00 I 2.00 I PULL 13:00 - 14:00 1.00 I PULL 14:00 - 15:00 1.00 RUNC 15:00 - 19:00 ~ 4.00 19:00 - 21:00 ~ 2.00 21:00 - 23:00 I 2.00 23:00 - 00:00 I 1.00 1 oi2si2oos I oo:oo - ~ 2:00 ~ 12.00 12:00 - 13:00 I 1.00 13:00 - 16:30 I 3.50 Spud Date: 11 /15/1990 Start: 10/16/2009 End: Rig Release: 10/30/2009 Rig Number: 4ES Phass ' Description of Operations DECOMP POH W/ 2-7/8" TBG, ESP & CABLE. -STANDING BACK 43 STANDS OF 2-7/8° TBG IN DERRICK,LD 3 SINGLES -LD 3 SINGLES LD 2 GLMS AND 4 PUP JTS. -CONTROLLING WELL WITH 20-BPH HOLE FILL. -ESP PULLED TO SURFACE AT 11:00-HRS. -RECOVERED 129 JTS. 2-7/8" 8RD. TUBING, 1- XN NIPPLE, 2 EA. OF 2-7/8" X 1° GLM'S AND PUPS, LASALLE CROSS COUPLING CABLE CLAMPS, DECOMP BREAK OUT AND LAY DOWN ESP BHA. -DETACH ESP CABLE FROM MOTOR. -CENTRI~IFT DISASSEMBLED ESP BHA SECTION BY SECTION INSPECTING EACH SECTION. -SPOOLED UP CABLE INTO CABLE SPOOLER. -RECOVERED 74 LASALLE CLAMPS. DECOMP CLEAN AND CLEAR RiG FLOOR RUNCMP -R/D ELEPHANT TRUNK. -R/U TO RUN ESP. RUNCMP PJSM TO RUN COMPLETION -PU/MU ESP PUMP AND MOTOR ASSEMBLY. RUNCMP RUN I-WIRE TO SENSOR AND PUMP. -TEST ESP AND ESP CABLE CONNECTION -CREW MEETING WITH OPS SUPERINTENDANT, DISCUSS SAFE WORK PLAN WITH CREW. RUNCMP RIH WITH ESP COMPLETION, RUN ESP ON 2-7/8" 6.5#, L-80, EUE 8 ROUND TUBING. -USE BEST-O-LIFE 2000 PIPE DOPE, AVERAGE MAKE UP TORQUE OF 2,300 FT/LBS. -ATTACH ESP CABLE TO TUBING WITH LASALLE CLAMPS. RUNCMP RIH WITH ESP COMPLETION, WITH HEATTRACE. RUN ESP ON 2-7/8" 6.5#, L-80, EUE 8 ROUND TUBING. -USE BEST-O-LIFE 2000 PIPE DOPE, AVERAGE MAKE UP TORQUE O~ 2,300 FTILBS. -ATTACH ESP CABLE AND HEAT 7RACE TO TUBING USING CANNON CLAMPS. RUNCMP RIH WITH ESP COMPLETION, WITH HEATTRACE. RUN ESP ON 2-7/8" 6.5#, L-80, EUE 8 ROUND TUBING. -USE BEST-O-LIFE 2000 PIPE DOPE, AVERAGE MAKE UP TORQUE OF 2,300 FT/IBS. -ATTACH ESP CABLE AND HEAT TRACE TO TUBING USING CANNON CLAMPS. -CHECKING CONNECTIVITY EVERY 2000' , PUMPING 1 BMP ~ 1750 PSI -FLUSHED ESP WITH 10 BBLS PUMPING 11 SPM ~ 1750 PSI -RAN 133 JOINTS 2-7/8" TBG •30 LASALLE CLAMPS , 2- SM CANNON CLAMPS, 9-PUMP CLAMPS, 12- TWO FOOT CLAMPS, 84- CROSS COUPLING CLAMPS, 519 FIVE FOOT CLAMPS, 2- STAINLESS BANDS RUNCMP CREW MEETING WITH NABORS DRILING SUPERINTENDENT ON RECENT HSE EVENT AND SAFE WORK PLAN. RUNCMP RIH WITH ESP COMPLETION, WITH HEAT TRACE. RUN ~ ~ A BP EXPL(jRAT1~N ' Page 7 of 7: : ~perations Sumrnary Repor# Legal Well Name: MPI-04 Common Well Name: MPI-04 Spud Date: 11/15/1990 Event Name: WORKOVER Start: 10/16/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/30/2009 Rig Name: NABORS 4ES Rig Number: 4ES Da#e` Frorn - To Hours Task Cade NPT Phase Description of Operations 10/29/2009 13:00 - 16:30 3.50 RUNCO RUNCMP ESP ON 2-7/8" 6.5#,1.-80, EUE 8 ROUND TUBING. 16:30 -18:00 1.50 RUNCO RUNCMP ANU 2-7/8° TBG HANGER -CAMERON SET TWC IN TUBING HANGER. -SPACE OUT FOR SPLICES -INSTALL ESP/HT PINETRATORS. -CUT ESP/HEAT TRACE CABLE. -PULL CABLES OVER SHEAVE. -FEED WELL AT 20 BPH SEAWATER. 18:00 - 20:00 2.00 RUNCO RUNCMP CENTRILIFT SERVICE TECH. ATTACHED LOWER FIELD ATTACHABLE CONNECTOR AND MADE CONNECTION TO WELLHEAD PENETRATOR. -ATTACH ESP CONNECTION TO PENETRATOR AND TEST CONNECTIONS. 20:00 - 20:30 0.50 RUNCO RUNCMP LAND TUBING HANGER. P/U WEIGHT 35K, S/O WEIGHT , 30K. -RUN IN LOCK DOWN SCREWS. TORQUE LOCK DOWN SCREWS TO 450 FT/LBS. -BACK OUT AND VD LANDING JOINT. 20:30 - 21:30 1.00 RUNCO RUNCMP TEST CAMERON 2-1/2" TYPE "H" TWC FROM ABOVE TO 3,500 PSI FOR 10 MINUTES ON THE CHART, TEST FROM BELOW BY INJECTING AT 4 BPM WITH 200 PSI FOR 10 MINUTES.(CHARTED) BH 40 BBLS 21:30 - 23:00 1.50 WHSUR P RUNCMP UNHOOK CHOKE AND KILL LINES. UNHOOK KOOMEY LINES. -N/D 13-5/8" 5M, HYDRIL BOP STACK AND STAND BACK ON STAND. 23:00 - 00:00 ~ 1.00 ~ WHSUR ~ P 10/30/2009 ~ 00:00 - 02:00 ~ 2.00 ~ WHSUR ~ P 02:00 - 03:00 I 1.00 I WHSUR ~ P 03:00 - 06:00 ~ 3.00 ~ W HSUR ~ P RUNCMP INSPECT WELLHEAD. -N/U ADAPTOR FLANGE AND 2-9/16" 5M TREE. -TEST HANGER VOID TO 5,000 PSI FOR 30 MINUTES, GOOD TEST. -TEST TREE TO 5,000 PSI WITH DIESEL FOR 10 MINUTES. GOOD TEST. RUNCMP RiU WELL SUPPORT LUBRICATOR AND TEST TO 500 PSI WITH DIESEL. PULL 2-1/2" CAMERON TYPE "H" BPV RUNCMP INSTALL CAMERON 2-1/2" TYPE "H" BPV WITH WELLHEAD TECH. TEST FROM BELOW TO 1,000 PSI FOR 10 MINUTES BY INJECTING AT 4 BPM. RUNCMP BLOW DOWN AND RIG DOWN LINES. SECURE WELL AND CELLAR. *"RIG RELEASED AT 06:00 HOURS ON 10/30/2009'* -AFTER ACTION REVIEW WITH CREW , \t:L;t:/VE STATE OF ALASKA 0 ALASKAL AND GAS CONSERVATION C&ISSION JAN 0,3 2006 REPORT OF SUNDRY WELL OPERATI0Yt9oi1&GasCons COtr/fTJ' . . ISSIOO Anchorage 1. Operations Performed: Ché!~_ Out ESP o Abandon o Suspend o Operation Shutdown o Perforate 1m Other o Alter Casing 1m Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program 1m Pull Tubing o Perforate New Pool o Waiver o Time Extension 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 1m Development o Exploratory 201-093 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22068-60-00 7. KB Elevation (ft): 70 9. Well Name and Number: MPI-04AL1 8. Property Designation: 10. Field / Pool(s): ADL 025906 Milne Point Unit / Schrader Bluff 11. Present well condition summary Total depth: measured 7207 feet true vertical 4070 feet Plugs (measured) None Effective depth: measured 7207 feet Junk (measured) None true vertical 4070 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 115' 115' 2730 1130 Surface 2564' 9-5/8" 2599' 2354' 3520 2020 Intermediate Production 4475' 7" 4510' 3975' 7240 5410 Liner 2685' 2-3/8" 4499' - 7184' 3965' - 4069' 11200 11780 . ,,,,,,,..,,., ;.."v ,. \,--.', 'J~ Perforation Depth MD (ft): 4560' - 7207' Perforation Depth TVD (ft): 4016' - 4070' Tubing Size (size, grade, and measured depth): 2-7/8", 6.5# L-80 4273' Packers and SSSV (type and measured depth): 7" Halliburton 23-29# VTL Versa-trieve 4338' 7" Baker "SLZXP" 4483' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: iRBOMS 8Ft JAI\) 04: 2006 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casino Pressure Tubino Pressure Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: 1m Daily Report of Well Operations o Exploratory 1m Development o Service 1m Well Schematic Diagram 16. Well Status after proposed work: 1m Oil o Gas o WAG DGINJ DWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 Printed ~ Sondra Stewman Title Technical Assistant Sig~re })VU ,.ð¡: ~ Phone ) ~_ ~ I /'" Prepared By Name/Number: V>~ 564-4750 Date ,- iJSSondra Stewman, 564-4750 Form 10-404 Revised 04/2004 Of<fGINAI Submit Original Only TREE: 2-9/16" - 5M WKM WELLHEAD: 11" 5M WKM wI .. 2-118" 8rd TREE TOP CONNECTI~ 133/8",54.5#/ft,K-55 Weld Set 115' 95/8", $6#1ft, K-55 Butt 2599' 27/8" 6,5 ppf, L-80, 8 rd EUE tbg. (drift ID = 2,347", cap. = 0.00592 bpf) 7" 26 ppl, L-80, Btrc, production casing ( drift 10 = 6.151", cap. = 0.0383 bpI) KOP @ 600 ' Max well bore Angle: 38° @ 2200' MD Hole angle trough perfs = 90 deg. N SAND PERFORATION SUMMARY Size SPF Interval (TVD) 24 gm 24 4,383' - 4392' 3860' - 3868' 24 gm 24 4,411' - 4428' 3885' - 3901' 24 gl11 24 4,443' - 4451' 3914' - 3921' 4" Deployment Sleeve top of liner Baker 3S FL4S x 2-3/8" FL4S Top of window @ 4510' MP I-04À\L \ 4" Deployment Sleeve top of liner 4,531' Baker 3.5" FL4S x 2-318" FL4S Top of window @ 4536' o SAND PERFORATION SUMMARY (SQUEEZED OFF, BELOW CEMENT RETAINER) Size' SPF Interval (TVD) 37 gm 5 4,554' - 4,588' 4,015' - 4,045' 37 gm 5 4,624' - 4,655' 4,078' - 4,106' DATE REV. BY 7/13/01 MDO 7/22/01 B. Hasebe 118//05 Lee Hulme 7", 26#1ft, L-80 Butt Shoe 4,881' COMMENTS 3/9/95 RWO - INSTALL ESPCP 8-29-96 ESP RWO POLAR #1 Nabors 3S CTU Drilling sidetrack Nabors 4ES Completion Nabors 4ES Completion .KB - SL = 52' (NABORS 27E) KB - GL = 35' (NABORS 27E) Camco 2-7/8" x 1" side pocket KBMM GLM I 160' 1 RA Tag @ 3,623' Camco 2-7/8" x 1" side pocket KBMM GLM I 4,040' 1 14,176' 1 14,231' I 14,244' 1 GRSFTX AR H6 Intake 4,244' MD = 3,734' TVD Tandem Seal Section I 1 Model GSB3 DB UT/L T IL 4,249' H6 PFS Aflas/HSN Motor, 83 HP, 2330 volt, 14,262' I 30 amp, Model KMH-A 2-7/8" XN nipple (102250") Centrilift, 130 Stg, 400P8 Model - SSD Tandem Gas Separator PumpMate w/6 fin Centralizer I 4,273' PumpMate = 3,760' TVD 7" Halliburton 23-29# "VTL" Versa-trieve Packer H-S 3-1/2" X-O H-S 3-1/2" 250 micron "Poroplus" Screen (81' total, 4371' - 4458') Baker Seal Assembly 1" Baker "SLZXP" Packer (4.5" ID) 4-1/2" Halliburton X Nipple (3.813" 10) @ 4475' Tubing Tail @ 4477.5' I-OdA ! 1 Hole td @ 7173' En jts, 01 ;:'rt~-Drill¡¡iJ 2-3 B" :,-1.550' - /,151 ') 2-318" 4.61f, L-80 STL tubing. Baker Guide shoe @ 7,184' 1-04A .. Hole td @ 6895' 69 jts. of Pre-Drilled 2-3/8" (4,583' - 6,794') 2-3/8 "4.6#, L-80 STL tubing, Baker Guide shoe @ 6,834' BP EXPLORATION (AK) '.. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: BP EXPLORATION Operations Summary Report MPI-04 MPI-04 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: ! Phase i I I _m ..__...._.____ __ I Date I From - To Hours Task Code NPT 11/7/2005 18:00 - 20:00 2.00 MOB P 20:00 - 21 :00 1.00 MOB P 21 :00 - 23:00 2.00 MOB P 23:00 - 00:00 1.00 RIGU P 00:00 - 00:30 0.50 RIGU P 00:30 - 02:00 1.50 RIGU P 02:00 - 04:00 2.00 WHSUR P 04:00 - 06:00 2.00 WHSUR P 06:00 - 06:30 0.50 WHSUR P 06:30 - 08:30 2.00 KILL P 11/8/2005 08:30 - 10:00 1.50 WHSUR P 10:00 - 12:30 2.50 BOPSU P 12:30 - 17:30 5.00 BOPSU P 17:30 - 00:00 6.50 PULL P 11/9/2005 00:00 - 02:30 2.50 PULL P 02:30 - 03:30 1.00 PULL P 03:30 - 06:00 2.50 06:00 - 06:30 0.50 06:30 - 09:00 2.50 09:00 - 14:30 5.50 14:30 - 17:00 2.50 17:00 - 18:00 1,00 18:00 - 19:00 19:00 - 21:30 19:30 - 22:30 3.00 22:30 - 00:00 1.50 BOPSU N 11/10/2005 00:00 - 03:00 3.00 WHSUR P PRE PRE PRE PRE PRE PRE DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP HMAN RUNCMP HMAN RUNCMP HMAN RUNCMP RUNCMP Page 1 of 1 1 0/31/2005 11/10/2005 Spud Date: 11/15/1990 End: 11/10/2005 Description of Operations -----.---. Lower & Scope down derrick. RID rig equip. Rig Down rig & prepare to move rig. Move lrom MPH-14 to MPI -04. Layout herculite & matting boards. Spot rig over MPI-04 wellhead. Con't to spot in sub, pits & pipe shed. Spot camp. Rig up rig. Raise & scope up derrick. Con't to R/U. ACCEPTED RIG @ 0200 hrs.. R/U lines to X-mas tree & tiger tank, Take on seawater. P/U lubricator & pull BPV. UD lubricator. Con't to Take on seawater. PJSM, Pressure test lines @ 1000 I 3500 psi, OK. PJSM. Circulate heated seawater down tubing @ 4.5 bpm I 50 psi., no returns up backside. Bullhead down II A @ 4.5 bpm. Monitor well, well dead. PJSM, Set two way check valve & test @ 3500 psi, OK. N/D tree & check threads in hanger, OK. PJSM. NIU 135/8" x 5M BOPE. PJSM. Conduct full test on BOPE. State Rep Chuck Sheve witnessed test 01 all components. Test successful, no issues, Pull TWC. BOLDS, pull hanger to floor and lay down same. POH w/ESP completion laying down tubing 1 x 1. POH w/ESP completion laying tubing down 1 x 1, Layed down 131 jts. 2-7/8" 6.5#/1t. L80 tubing, 2 GLM's, 2 x 10 It. 2-7/8" L80 pup joints. UD ESP assembly. Clean & clear rig Iloor. Swap cable reels in spooler. Remove ESP assembly and old tubing from pipe shed. Load pipe shed w/new tubing and ESP assembly. Tally new tubing and ESP assembly. Lube & service rig. PJSM. Pick up & service ESP assembly. PJSM. Pick up & RIH wI ESP assembly and cable on 2 7/8" EUE 8 rnd, L80, 6.5# tbg. Make up tubing hanger & ESP penetrator, check ESP cables lor continuity and insulation resistance to ground. Tested good. PJSM. Land hanger. P/U wt = 43K, Down wt = 35K. Set two way check & test to 3500 psi, OK. PJSM. NID BOPE. PJSM. Attempt to N/U production tree. Tubing hanger misaligned. Alignment pin not screwed in all the way. UD tree. N/U BOPE. PIT body and break to 3500 psi. Test O.K. BOLDS. Unland tubing hanger, screw alignment pin in all the way, and reland same with proper allignment. RILDS. N/D BOPE. N/U production tree. PIT tree and packoff to 5000 psi. Test O.K. P/U lubricator, pull TWC, set BPV. UD lubricator. Final check ESP cable for continuity and resistance to ground. Clear and clean cellar. Secure well. RELEASED RIG at 0300 hrs. Printed: 11/11/20052:11:16 PM DATA SUBMITTAL COMPLIANCE REPORT Permit to Drill 2010930 Well Name/No. MILNE PT UNIT SB 1-04AL1 Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-22068-60-00 MD 7207 j' 'I'VD 4070 - Completion Dat 7/19/2001 ~ Completion Statu 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log N._9 Sample N_.9.o Directional Survey L~o ., - DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital T_y_pe_~-Fmt (data taken from Logs Portion of Master Well Data Maint) Interval Log Log Run OH / Dataset Name Scale Media No Start Stop CH Received Number Comments j- 4516 7207 Open 9/24/2001 r1-0~7 4516-7207 ,---Dfl'ectional Survey FINAL 201 92 ch 9/7/2001 Directional Survey Digital Data (201-092 PTD INC) Directional Survey FINAL ch 9/7/2001 Directional Survey 10327 FINAL 4516 7207 OH 9/24/2001 .~)~27 4516-7207 Digital Data MDWellbore Profile/ 2/5 FINAL 4521 7207 OH 9/24/2001 4521-7207 BL, Sepia GR ~.~, ~ Resistivity / GR 2/5 FINAL 4521 7207 OH 9/23/2001 4521-7207BL, Sepia '~~Resistivity / GR 2 FINAL 4521 7207 OH 9/23/2001 4521-7207 BL, Sepia -L'lS~rificaiton FINAL OH 9/24/2001 LIS Verification Well Cores/Samples Information: Name Interval Dataset Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y Chips Received? ----Y-hN'-'-- Analysis R P.r.P. ivP. d ? Daily History Received? (~ N Formation Tops /~/N Comments: Permit to Drill 2010930 DATA SUBMITTAL COMPLIANCE REPORT 713012003 Well Name/No. MILNE PT UNIT SB 1-04AL1 Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-22068-60-00 MD 7207 TVD Compliance Reviewed By: 4070 Completion Dat 7/19/2001 Completion Statu 1-OIL Current Status Date: 1-OIL UIC N Transmittal Form BAKER HUGHES Baker Atlas Canada GEOSciences Centre To: State of Alaska, Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Attention: Lisa Weepie Reference · Milne Point Unit MPI-04A-L1 Contains the following: 1 LAS Format disk 1 Film 1 Measured Depth GR print 1 TVD-GR print 1 Borehole Profile Sent By: Jo~sef Be g Date: Sept 18, 2001 Received ~,"1~'_ ~----~~'~t Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING A COPY TO BP EXPLORATION (ALASKA) PETROCHEMICAL DATA CENTER 900 E. BENSON BLVD. ANCHORAGE, ALASKA 99508 Baker Atlas #1300, 401-9th Ave. S.W. Calgary, Albert a, Canada T2P 3C5 Direct: (403) 537-3752 FAX: (403) 537-3767 RECEIVED .... .! 8EP 2 4 2001 i:::4'"~!!!?l:i!!i:"'~ i ............ ~ .......... ' ............... Alaska Oil & Gas Cons. Commission Anchorage · . ~ ...~..., ~:..{. ,;.:. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service [] TSUSP 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-093 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22068-60 4. Location of well at surface -' ' LOCATION.~ 9. Unit or Lease Name 2942' SNL, 3876' WEL, SEC. 33, T13N, R10E, UM i '~ :"~?"?L1// :' ~ Milne Point Unit At top of productive interval 1464' SNL, 2769' WEL, SEC. 33, T13N, R10E, UM At total depth '~, ~ -- i i ~.~~.~ 10. Well Number 58' SNL, 1334' WEL, SEC. 33, T13N, R10E, UM MPI-04AL1 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Milne Point Unit / Schrader Bluff KBE = 70' ADL 025906 12. Date Spudded7/7/2001113' Date T'D' Reached 114' Date c°mp'' susp'' °r Aband'7/9/2001 7/19/2001 115' wate~ depth' if °ffsh°reN/A MSL 116''' N°' 0f' C°mpleti°nsOne 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set121. Thickness of Permafrost 7207 4070 FTI 7207 4070 FTI ~ Yes [] NoI N/A MDI 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 54.5# K-55 35' 115' 30" 485 SX Permafrost 'C' 9-5/8" 36# J-55 35' 2599' 12-1/4" 1111 sx PF 'E', 244 sx Class 'G' 7" 26# L-80 35' 4510' 8-1/2" 260 sx Class 'G' 2-3/8" 4.6# L-80 4499' 7184' 3-3/4" Uncemented Slotted Liner 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 2-3/8" Slotted Section 3-3/4" Open Hole 2-7/8", 6.5#, L-80 4299' None MD TVD MD TVD 4560' - 7151' 4016' - 4068' 7184' - 7207' 4069' - 4070' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. ... DEF,'rH. IN'r.ERVAL' (MD) ........... AMOU~T & KIND OF MATERIAL USED .. MPI-04 Original PerlE 4338' - 4483' Poroplus 250 Micron Screen Assembly ,,, 4383' - 4392' 3860' - 3868' 4411' - 4428' 3886' - 3901 ........................ 4443'- 4451' 3915'- 3922' . ................................ 27'. ........................... PRODUCTION TEST ........................... Date First Production Method of Operation (Flowing, gas lift, etc.) .......... July 26, 2001 Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL'BBL ..... GAs'M'cF ' WATER'BBL CHOKE SiZE I GAs-O~L RATIO ................... 8/16/2001 6 TEST PERIOD 764 854 64I 1119 Flow Tubing Casing Pressure CALCULATED OIL'BBL GAS'MCF WATER'BBL OIL GRAVITY'API (CORR) Press. 24-HOUR RATE ~8~ CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. SI~c Ei~VE D AUG 2 8 Z001 ,Alaska Oil & Gas Cons. Commission Anchorage ~ , Form 10-407 Rev. 07-01-80 ORIGINAL · . Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Top of Schrader OA 4564' 4018' Base of OA / TSBC 4613' 4046' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foreJ;Ioing is true and correct to the best of my knowledge 28.Ol Signed Terrie Hubble Title Technical Assistant Date , MPI-04AL1 201-093 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL.' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1 .' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 · , BP EXPLORATION . . Page'1 of 6 · ., , ' 'Operati°ns'Summary Report I Legal Well Name: MPI-04 Common Well Name: MPI-04 Spud Date: 11/15/1990 Event Name: REENTER+COMPLETE Start: 6/30/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 3S Rig Number: . · F't ~:Hours:. ACtivity COde NPT,~·Phase "i' ,= ,i:DeSCri ti°n'°fO ,~= ~.", ' /:'~' ~..: ~:~:..,~ : '~ ' ~'~':. i', perati°ns' ~' 6/29/2001 00:00 - 19:30 19.50 P,IGU P PP,E Move to MPU I - 4^and rig up accept rig 1900 19:30 - 21:00 1.50 RIGU N PRE Wait on ring gasket 21:00 - 12:59 15.98 RIGU P PRE NU BOP 6/30/2001 00:00 - 10:30 10.50 STWHIP P WEXIT NU BOP change out rams 3-1/2 10:30 - 12:40 2.17 STWHIP P WEXIT slack management e-line coil 27' coil cut. 12:40 - 16:00 3.33 STWHIP P WEXIT Head up OXP, Pull test 20K, Change packoff and PT the connection. 16:00 - 19:30 3.50 STWHIP P WEXlT RIH tie in and cleanout to PBTD 4548.6 Hard spot at 4499. Pump sweeps make multiple passes thru tight spot to PBTD. 19:30 - 19:50 0.33 STWHIP N WEXlT P,epair counter on injector. 19:50 - 20:10 0.33 S'I'WHIP N WEXlT Log down 7" liner 20:10 - 22:30 2.33 STWHIP N WEXlT POH 22:30 - 23:59 1.48 STWHIP N WEXIT P,IH with dummy whipstock to PBTD. 7/1/2001 00:00 - 00:30 0.50 STWHIPJ P WEXlT LD dummy whipstock drift assembly 00:30 - 02:00 1.50 STWHIPi P WEXIT PU whipstock 02:00 - 04:00 2.00 STWHIP P WEXlT P,IH tie in -5.5' tag PBTD. 04:00 - 04:10 0.17 STWHIP P WEXIT Close EDC and set whipstock 04:10 - 04:25 0.25 STWHIP, P WEXIT , Tag whipstock & Change well over to mud 04:25 - 05:35 1.17 STWHIP P WEXIT POH 05:35 - 06:00 0.42 STVVHIP P WEXIT PU off well 06:00 - 06:30 0.50~ STWHIP P WEXIT PJSM 06:30 - 07:30 1.001 STWHIP P WEXIT RIH 07:30 - 08:15 0.75 STWHIP P WEXIT tie in 08:15 - 14:00 5.75 STWHIP P WEXIT ' Mill window 4,536' to 4,542.5'Time drill WeB initially 500# increasing to 3000~ at .05 fpm 14:00 - 14:55 0.92 STVVHIP P WEXlT POH mill in gauge. Window clean. 14:55 - 15:20 0.42 STWHIP P PP,OD1 Change out milling assembly for build asSembly. 15:20 - 15:35 0.25 STWHIP P PROD1 Stab on to well and test tools. 15:35 - 16:48 1.22 STWHIP P PP,OD1 RIH and tie in. correction -6'. 16:48 - 20:20 3.53 STVVHIP= P PP,OD1 Drill to 4690 end of build 20:20 - 21:20 1.00 STWHIP P PP,OD1 POH for planned BHA change. 21:20 - 22:20 1.00 STWHIP: P PROD1 Change out BHA 22:20 - 22:48 0.47 STWHIP P PROD1 MU tools to injector and surface test OXP 22:48 - 23:59 1.18 STWHIP P PP,OD1 RIH 7/2/2001 00:00 - 01:00 1.00 STWHIP~ P PROD1 RIH to 4440' tie in -4.5' 01:00 - 02:52 1.87 STVVHIP P PROD1 Drill to 4850 02:52 - 03:14 0.37 STWHIP: P PROD1 Wiper trip 300' 03:14-05:25 2.18 STWHIP P PROD1 Drillto 5138 05:25 - 06:00 0.58 STVVHIP P PROD1 wiper trip 590' 06:00 - 07:15 1.25 STWHIPi P PROD1 Drill to 5350 07:15 - 08:05 0.83 STWHIP P PROD1 Wiper trip 800'. 08:05 - 09:45 1.67 STWHIP P PP,OD1 Drill to 5530 09:45 - 10:20 0.58 STWHIP P PROD1 Wipe trip 973'. 10:20 - 11:44 1.40 STVVHIP N DF^L PP,OD1 POH for down hole short in EDC 11:44 - 14:00 2.27 STWHIP N DFAL PROD1 Change out BHA 14:00 - 16:00 2.00 STWHIP N DFAL PP,OD1 P,IH and drill to 5627 16:00 - 17:20 1.33 STWHIP N DPP,B PP,OD1 Circulate and prep for open hole side track. Dip less than anticipated. 17:20- 18:30 1.17 STWHIP N :DPRB PP,OD1 Close EDC and check computers 18:30 o 19:00 0.50 STWHIP N DPRB PROD1 P, IH and taking survey every 10' for 50' preparing for open hole sidetrack. 19:00 - 22:00 3.00 STWHIP N DPRB PROD1 Build side tracking trough 4860 - 4890 three passes Printed: 7116/2001 1:41:32 PM ~' BP EXPLORATION page 2 of 6 Operations Summary Report ".,, -," , Legal Well Name: MPI-04 Common Well Name: MPI-04 Spud Date: 11/15/1990 Event Name: REENTER+COMPLETE Start: 6/30/2001 End: Contractor Name: NABORS Rig Release: Rig Name: N^BORS 3S Rig Number: · :i:,!:i'i:ii:Oate ,From.To iHours ,ACtivity. ': '~..NPT .:Phase Description 0fOperati6ns: .: :, Code~ · 7/2/2001 22:00 - 23:59 1.98 STWHIP N DPRB PROD1 Directionally drill to 4908 7/3/2001 00:00 - 01:30 1.50 STWHIP N DPRB PROD1 Directionally drill to 5093 01:30 - 01:44 0.23 STWHIP N DPRB PROD1 Wiper trip 550' 01:44 - 02:55 1.18 STWHIP N DPRB PROD1 Log section for Gamma 02:55 - 04:00 1.08 STWHIP N DPRB PROD1 Directionally drill to 5300 BHP = 2892 psi, annular pressure 2280 psi, pump pressure 3450 psi @ 2.3 bpm ROP 214' ECD 10.9 04:00- 04:30 0.50 STWHIP N DPRB PROD1 Wiper trip 750'. 04:30 - 06:12 1.70 STWHIP N DPRB PROD1 Directionaqlly drill to 5500 06:12 - 07:00 0.80 STWHIP N DPRB PROD1 Wiper trip 950'. 07:00- 09:45 2.75 STWHIP N DPRB PROD1 Directionally drill to 5627 09:45 - 17:00 7.25 STWHIP P PROD1 Directionally drill 17:00 - 19:40 2.67 S'I'WHIP P PROD1 Drill to 6270', wiper trip to shoe. 19:40 - 20:25 0.75 STWHIP P PROD1 6270', back on bottom, no problems seen on wiper. Drilling 2.3 bpm in, 3460 psi CTP, 2.3 bpm out, ROP 230 fph. 20:25 - 21:45 1.33 STWHIP P PROD1 6460', Wiper trip to shoe. 21:45 - 00:00 2.25 STWHIP P PROD1 Drill ahead, 2.5 in/2.5 out, 3700 CTP, 150 fph. 7/4/2001 00:00 - 01:30 1.50 STWHIP PROD1 6630', Wiper trip to shoe. 01:30 - 04:00 2.50 S'I'WHIP PROD1 Resume drilling, wiper trip smooth. 04:00 - 05:50 1.83 STWHIP PROD1 6830', Drilling ROP slowed significantly. 800' on this mud system in last 12 hours. May need to swap mud again! Wipe to shoe. 05:50 - 06:30 0.67 S'I'WHIP PROD1 Resume drilling 2.5 in, 2.5 out, 3400 psi CTP. Not getting good weight transfer. 06:30 - 11:30 5.00 STWHIP PROD1 6886'. Drilling difficult. Hard to get weight to bit. Also need to build 6' TVD to get back to good 20 ohm rock as per geo. Not worth doing a mud swap for 114 more feet of poor rock. Will Call this TD and begin conditioning hole. Make 2 wiper passes up to shoe, everything looks clean, but difficult to get down lask 200' of hole (Lockup/mud). PUH for tie in pass. 11:30 - 11:45 0.25 STWHIP PROD1 Log tie in pass in 7" liner. Make +2' correction. 11:45 - 13:10 1.42 STWHIP PROD1 Run back to bottom to confirm TD, and lay in new mud. 13:10 - 15:15 2.08 STWHIP PROD1 Tag bottom at 6888', consistent with the +2' correction we made at the shoe. Lay in new mud from TD. Using 9.0+ ppg mud with 6% lubtex. Other properties same as proceedure. While POOH, flagged pipe at 4000' and 1500', FOP. 15:15- 16:10 0.92 STWHIP PROD1 Lay down drilling BHA#7. 16:10 - 16:30 0.33 CASE COMP Standback injector prior to picking up liner. Note, had to set injector on CTU back deck using legs. Could not rig down CTC-UQC without having to rehead. (Several hours). Disassembled UQC partially in order to set on back deck. Need improved system in future if we are going to do this proceedure with wire. 16:30 - 17:00 0.50 CASE COMP Safety meeting prior to picking up liner. Rig crew, CTU crew, OXP, BP, Tool pusher. 17:00 - 17:15 0.25 CASE COMP Repair 2 items identified in safety meeting. 17:15 - 18:00 0.75 CASE COMP Begin picking up float eq. and pre perfed liner. Using 2-3/8" blank liner as safety joint. 18:00 - 18:25 0.42 CASE COMP Shut down operations for crew change out. 18:25- 19:00 0.58 CASE COMP Hold PJSM with new crew. 1 new hand for DS, on his first liner job. Instructed new hand to observe, but not participate in activities. Printed: 7/16/2001 1:41:32 PM BP ,EXPLORATION ' Page 3 of 6 , .Operations Summary'Report . ., Legal Well Name: MPI-04 Common Well Name: MPI-04 Spud Date: 11/15/1990 Event Name: REENTER+COMPLETE Start: 6/30/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 3S Rig Number: :'!::iDate :From., TO..'H°urs~ Activi~ COde: 'NPT phase'il..;'..:::I : DescriPti°n'of.iOperati°ns::!:~:i, li.~.!: .:::i: 7/4/2001 19:00 - 21:00 2.00 CASE COMP Continue with running 2-3/8" per perfed liner. 21:00 - 22:00 1.00 CASE COMP Finish running liner and deployment eq. Pickup 2-3/8" drill collar and crossovers to use as safety jt while running 3-1/8" drill collars. Deploy 12 3-1/8" drill collars, and 1 2-3/8" drill collar. 22:00 - 22:45 0.75' CASE COMP Make up OXP LQC, EDC, UQC. 22:45 - 23:40 0.92 CASE COMP Make up injecter. 23:40 - 23:55 0.25 CASE COMP RIH with liner. Made up as per proceedure. 23:55 - 00:00 0.08 CASE COMP Stop at 1500' EOP flag from previous tied in run, found 3.5' shallow. Add +3.5' correction. Continue RIH. 7/5/2001 00:00 - 00:40 0.67 CASE COMP Continue RIH with liner. Check up wt at shoe=28klbs. RIH in ;open hole. clean through window, clean through OH sidetrack at 4890', Started to loose weight while RIH. 10,000~ RIH ~weight at shoe, 8500# at 5500', 8000~ at 6000', 7000# at 6500'. Checked EOP flag at 4000', EOP which was 6708' with BHA, on within 2', continued RIH without slowing. Stacked out at 6730', up weight clean at 38klbs. Work to get moving again, finally got it down to 6834'. TD=6888', Top of liner at 4530.5', slightly shallow to whipstock top (about 1'). Intentionally left 54' of uncased hole below liner. 00:40 - 01:10 0.50 CASE COMP POH with liner deployment eq. 01:10 - 01:45 0.58 CASE COMP Tag up at surface, stand back injector, stand back drill collars. 01:45 - 02:30 0.75 CASE COMP Continue strapping CS hydrill. 02:30 - 03:00 0.50 CASE COMP Safety meeting prior to picking up CS hydrill. 03:00 - 07:45 4.75 CASE COMP Pick up 1" CS hydrill wash string with 1.5" OD bullnose JSN, to do bleach job on MPI-04A leg. 07:45 - 09:00 1.25 CASE COMP Make up OXP BHA, LQC, UQC. 09:00 - 10:45 1.75 CASE COMP RIH with CS hydrill BHA, no problems RIH through top of liner. Tag bottom at 6790', uncorrected CTM. Expected at 6795' ELM. Yesterday our flag correction was +3.5', so liner appears to be on depth within 1.5'. 10:45 - 16:44 5.98 CASE COMP Pumped 50 bbls of 3% KCL brine weighted to 9.2 ppg with NACL. displaced mud from liner. Followed with bleach mixture as per proceedure. 6 ppb lithium hypochlorite, at 160 degf and weighted to 9.4 ppg. Pumped 50 bbls, washed vac truck with 20 bbls and chased bleach with dilute mix. Followed with same 3% KCL brine pulled up above liner top and circulated at minimum rate. 16:44 - 18:00 1.27 CASE COMP RIH to displace bleach. 55 bbl spacer of KCL in coil, follow with Baroid drilling mud; BaradriI-N mud with 6% KCL and 31 ppb sized CaCO3, as per proceedure, weighted to 9.3 ppg. 18:00 - 20:00 2.00 CASE COMP POOH, laying in drilling mud in liner interval. Chase excess mud OOH with KCL. 20:00 - 20:45 0.75 CASE COMP Tag up at top of hydrill, stand back OXP eq, set injector down. 20:45 - 22:30 1.75 CASE COMP Standback 1" CS hydril work string. 22:30 - 23:30 1.00 STWHIP WEXIT At surface, start rigging up Baker 7" whipstock and OXP tool to orient and set. 23:30 - 00:00 0.50 STWHIP WEXIT RIH with Baker 7" retrievable whipstock. 7/6/2001 00:00 - 01:20 1.33 STWHIP WEXIT Continue RIH with whipstock. 01:20 - 01:45 0.42 STWHIP WEXIT Log tie in, make -2' correction at 4430'. 01:45 - 02:00 0.25 STWHIP WEXIT RIH, tag up at 4526.5', pick up re position bottom of whipstock at 4522'. close EDC, pressure up coil. Expected whipstock to set at 2700 psi, got good indication of set at 3200 psi. Printed: 7/16/2001 1:41:32 PM BP, EXPLORATION Page 4 of 6 OperatiOns· summaryReport · · Legal Well Name: MPI-04 Common Well Name: MPI-04 Spud Date: 11/15/1990 Event Name: REENTER+COMPLETE Start: 6/30/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 3S Rig Number: ,, Date ,'Fr°m~.~°:i:: Hou:rs ACtivitY cOde NPT, i PhaS:~ DescriPtion of operations: 7/6/2001 01:45 - 02:00 0.25 STWHIP WEXIT Whipstock set with bottom at 4522', top at 4505'. RA tag at 4515'. 02:00 - 02:20 0.33 STVVHIP WEXIT Open EDC circ sub, circ new fie pro into hole. 02:20 - 03:25 1.08 STVVHIP WEXIT POOH, laying in new fie pro mud. 03:25 - 04:15 0.83 STWHIP WEXIT Tag up at surface with setting tool. Indicated whipstock set properly. MU milling BHA with straight motor, diamond mill and string reamer. 04:15 - 05:00 0.75 STWHIP WEXIT RIH with BHA #8 to mill window. 05:00 - 06:00 1.00 STWHIP WEXIT Log tie in pass. 06:00 - 13:15 7.25 STWHIP WEXIT RIH, tag top of whipstock at 4506' (Set at 4505'). Solid tag. RIH to pinch point. Begin milling from 4510'. Mill to 4515', Drill open hole to 4521'. 13:15 - 14:00 0.75 STWHIP WEXlT Ream/backream window. Make 3 passes through window, able to pull through dry 2 times. 14:00 - 14:45 0.75 STWHIP WEXIT POOH with BHA #8 14:45 - 15:45 1.00 STWHIP WEXIT Lay down BHA #8. Mill and string reamer recovered in gauge, and mill had swirl pattern on face. 15:45 - 23:30 7.75 DRILL PROD1 Weekly BOP pressure test. 23:30 - 00:00 0.50 DRILL PROD1 MU BHA #9, to drill build section of L1 lateral. 7/7/2001 00:00 - 00:15 0.25 DRILL PROD1 Continue making up BHA #9 to drill lateral section L1. 00:15 - 00:45 0.50 DRILL PROD1 PU Injector. 00:45 - 01:45 1.00 DRILL PROD1 RIH with BHA #9.2.5 deg mud motor, flex joint, M09 bit. (Same bit as used on A lateral section) 01:45 - 02:00 0.25 DRILL PROD1 Log tie in pass. 02:00 - 07:45 5.75 DRILL PROD1 Begin drilling build section. 2.0 bbls in/2.0 bbls out, 3400 psi CTP, drilling slow, hitting calcite stringers. Getting 41 deg build at window. Able to stay on plan. 07:45 - 08:50 1.08 DRILL PROD1 4841', Build section completed, POOH 08:50 - 09:50 1.00 DRILL PROD1 Tag up at surface with build section BHA #9. Change out for lateral section BHA. Use 1.2 deg motor, Resistivity tool, DS49 bit. (Same bit used on A lateral horizontal section.) 09:50 - 11:30 1.67 DRILL PROD1 RIH with BHA #10. 11:30 - 12:10 0.67 DRILL PROD1 Log MAD pass over build section. 12:10 - 12:50 0.67 DRILL PROD1 4841', Back on bottom, drill directionally. 2.3 in, 2.3 out. 1 for 1 returns. 3200 psi, Drilling at 200 + fph with occasional calcite stringers. 12:50 - 13:05 0.25 DRILL PROD1 4900', Short trip. 13:05 - 14:00 0.92 DRILL PROD1 Return to drilling. 14:00 - 14:45 0.75 DRILL PROD1 Drill - Simulated high level H2S release in the cellar. Rig evacuation. Drill complicated by having brown bear near muster area. Debrief drill. Drill completed satisfactorily. 14:45 - 15:00 0.25 DRILL PROD1 !Wiper trip to shoe. 15:00 - 16:20 1.33 DRILL PROD1 :5070', Resume drilling. 2 bpm in, 2 bpm out. 3000 psi, 261 fph 'REP. 16:20 - 17:00 0.67 DRILL PROD1 .5220', Sticky pickup off bottom, net getting good weight to bit. Wiper trip to shoe. 17:00 - 17:45 0.75 DRILL PROD1 Resume drilling, 2.2 in/out, no losses. 3100 psi, 231 fph ReP. 17:45 - 18:20 0.58 DRILL PROD1 5380', Wiper trip to window. 18:20 - 20:45 2.42 DRILL PROD1 Resume drilling. 20:45 - 21:30 0.75 DRILL PROD1 5600', wiper trip to window. 21:30 - 23:00 1.50 DRILL PROD1 Resume drilling, swapping to new mud. 23:00 - 23:40 0.67 DRILL PROD1 5821', wiper trip to window. 23:40 - 00:00 0.33 DRILL PROD1 Resume drilling. Midnight nepth=5930'. Printed: 7/16/2001 1:41:32 PM BP EXPLORATION Page 5.of 6 Operations Summary Report Legal Well Name: MPI-04 Common Well Name: MPI-04 Spud Date: 11/15/1990 Event Name: REENTER+COMPLETE Start: 6/30/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 3S Rig Number: .?il ~From~"T° :'HOUrs ACtiVity COde NPT Phase Description of Operations:: :.~ ,:: i7/8/2001 00:00 - 00:35 0.58 DRILL P PROD1 Drilling ahead at 5930'. 00:35 - 01:25 0.83 DRILL P PROD1 6050', wiper trip to shoe. 01:25 - 03:00 1.58 DRILL P PROD1 Resume drilling. 03:00 - 04:10 1.17 DRILL P PROD1 6280'. Wiper trip to shoe. 04:10 - 06:00 1.83 DRILL P PROD1 Resume drilling. 06:00 - 07:00 1.00 DRILL P PROD1 6479', Wiper trip to shoe. 07:00 - 07:30 0.50 DRILL N RREP PROD1 Rig pumps down, Dowell tracter out of fuel, so can't pump. Standby at shoe for repairs. 07:30 - 08:20 0.83 DRILL N FLUD PROD1 RIH, mud getting bad, can't make it back to bottom. Can only make it to 6350'. Call for new mud. 08:20 - 12:00 3.67 DRILL N ,FLUD PROD1 POH to shoe to wait for mud. 12:00 - 12:50 0.83 DRILL N ;FLUD PROD1 RIH to spot new mud, and resume drilling. 12:50 - 14:30 1.67 DRILL P PROD1 6480', tag bottom and resume drilling. 2.3 in, 2.3 out, 3600 psi, 335 fph ReP. 14:30 - 16:10 1.67 DRILL P PROD1 6700', Short trip to shoe. 16:10 - 18:00 1.83 DRILL P PROD1 Resume drilling, 2.3 in, 2.3 out, 3600 psi, 290 fph. 18:00 - 19:10 1.17 DRILL P PROD1 6897', Wiper trip to shoe. 19:10 - 21:25 2.25 DRILL P PROD1 Resume drilling, snubbing at surface in order to get weight to bit. Drilling with -14000 lbs at surface.2.3 in/out, 3700 psi. 21:10-21:30 0.33 DRILL P PROD1 7054', Short wiper trip. 21:30 - 22:30 1.00 DRILL P PROD1 Resume drilling. Midnight depth=7100' 22:30 - 00:00 1.50 DRILL P PROD1 Wiper trip to shoe. 7/9/2001 00:00 - 00:45 0.75 DRILL P PROD1 Continue wiper trip to shoe. 00:45 - 02:00 1.25 DRILL P PROD1 Resume drilling, hitting occasional hard streaks, ReP slowing due to weight transfer. Drill to 7200', TD well. 02:00 - 02:45 0.75 DRILL N DFAL PROD1 Start conditioning trips to window. During first wiper trip bit plugged off. 02:45 - 04:00 1.25 DRILL N DFAL PROD1 Open Electronic circ sub, POOH to inspect. 04:00 - 06:45 2.75 DRILL N DFAL PROD1 Change out motor. Found plugged bit, and shucked stator in motor. Rig back on well. EDC put in a bind during RU process. (Poor comunication to hand running injector) Changed out EDC. Continued RU. No apparent damage to EDC after it was removed from BHA. 06:45 - 08:30 1.75 DRILL N DFAL PROD1 RIH with BHA #11. 08:30 - 09:00 0.50 DRILL P PROD1 At casing shoe, resume wiper trips to condition hole. Saw a ledge at each hard stringer. Probably gauge hole at the calcite stringers, with washed out sands above and below. Will try to knock off the corners w/o washing out the sands any more. 09:00 - 10:30 1.50 DRILL P PROD1 Wiper trip from TD to shoe. Make tie in pass. 10:30 - 11:00 0.50 DRILL P PROD1 At window. Park coil, SI pumping, Hold safety stand down to discuss incident on rig with EDC. Potential for harm to personnel or equipment was a real possibility. Discussed with crews that since they change out tommorrow and the next day, they need to keep their eye on the ball for the next couple of days. 11:00 - 14:15 3.25 DRILL P PROD1 Run back in hole to condition for liner. Hole looked good to bottom, swap to new mud with 6% lubtex. Final on depth tag, TD=7207'. Spot new mud on bottom and lay in. 14:15 - 15:15 1.00 DRILL P PROD1 At liner. No problems on last trip up. Tie in again. Log 'l-rail and packer. 15:15 - 16:30 1.25 DRILL P PROD1 POOH, flag at EOP 4000, 1400. 16:30- 17:45 1.25 DRILL P PROD1 Tag up with BHA #11, Lay down motor and MWD. Stand back injector. Printed: 7/16/2001 1:41:32 PM ' BP ,EXPLORATION ' ,' page 6of 6 ,.' .... '. , Operations_ SummaryReport__. · Legal Well Name: MPI-04 Common Well Name: MPI-04 Spud Date: 11/15/1990 Event Name: REENTER+COMPLETE Start: 6/30/2001 End: Contractor Name: NABORS Rig Release: Rig Name: N^BORS 3S Rig Number: ,oat~: FrOm?!!~ :R0il? ACtivitycOde NPT ·Phase: : ~ ::,::: ~':'.i?'DeSCriPtion°f operatiOns 7/9/2001 17:45 - 18:15 0.50 DRILL P PROD1 Standby for crews tour change out. 18:15 - 18:45 0.50 DRILL P PROD1 Safety meeting prior to picking up liner. 18:45 - 19:05 0.33 DRILL P PROD1 Make up 2-3/8" STL safety joint. 19:05 - 00:00 4.92 DRILL =P PROD1 Make up 2-3/8" pre perforated liner as per proceedure. 7/10/2001 00:00 - 00:40 0.67 DRILL P PROD1 Continue picking up 2-3/8" liner. 00:40 - 01:30 0.83 DRILL 'P PROD1 Set final 2-3\8 drill collar in 2-3/8" combi pipe slip rams. Close both sets of rams. PU injector, and MU OXP tool. '01:30 - 02:25 0.92 DRILL P PROD1 RIH with liner assembly. Weight check at shoe = 28klbs. Stop at flag at 1400' EOP. Found at 4640', shoud be at 4638.5', make -1.5' correction. Continue RIH depth vs wt; 4500'=10000#, 5000'=8000#, 5500'=6000#, 6000'=4000#, 6500'=0-2000", 7000'=0-2000#. Stop @ 7183.5', shut EDC, pump to release GS deployment tool. PU at 26klbs. Liner deployed ok, as per proceedure. (8' deeper than plan, but still above window, and below TTail) 02:25 - 03:15 0.83 DRILL P PROD1 Pull out of hole with coil. 03:15 - 07:00 3.75 DRILL P PROD1 Tag up at surface, set back injector, lay down drill collars and eXP. 07:00 - 10:20 3.33 DRILL P PROD1 Pick up CS hydril work string to bleach slotted liner. 10:20 - 11:00 0.67 DRILL P PROD1 Pick up injector and OXP to bleach slotted liner. 11:00 - 11:40 0.67 DRILL P PROD1 RIH with coil to bleach liner. 11:40 - 13:00 1.33 DRILL P PROD1 Tag TD, spot 50 bbls bleach accross slotted liner interval while PUH. Chase with 20 bbls of brine rinse out of bleach vac truck. 13:00 - 17:00 4.00 DRILL P PROD1 Circulate above liner top while waiting for bleach to work. 17:00 - 19:00 2.00 DRILL P PROD1 Displace bleach in liner with brine while POOH. 19:00 - 19:30 0.50 DRILL P PROD1 Safety meeting 19:30 - 00:00 4.50 DRILL P PROD1 Standback injector. Hole staying full. LD CSH in singles. 7/11/2001 00:00 - 01:30 1.50 DRILL P PROD1 Set BPV. 01:30 - 04:30 3.00 DRILL P PROD1 ND BOPE. NU tree cap. Release rig 04:30 hrs 7/11/01. Printed: 7/16/2001 1:41:32 PM .. · BP EXPLORATION Page1 of 1 . , · Operations '.,:Summary Report -' ;. Legal Well Name: MPI-04 Common Well Name: MPI-04 Spud Date: 11/15/1990 Event Name: COMPLETION Start: 7/17/2001 End: 7/19/2001 Contractor Name: NABORS Rig Release: 7/19/2001 Rig Name: NABORS 4ES Rig Number: .::':Date From-To HoUrs: ActivityCOde. NPT:' )iPhase::: · ' DescriptiOn of Operations . 7/17/2001 03:00 - 08:00 5.00 MOB P PRE RDMO FROM MPC-41. 08:00 - 12:00 4.00 MOB P PRE RIGGED UP 100%, RIG ACCEPTED AT 1200 NOON 12:00 - 00:00 12.00 KILL P DECOMP BULL HEAD ANNULUS WITH 100 BBL 10.4 PPG BRINE, PUMP AT 2 BPM AT 750 PSI SHUT DOWN PUMP PRESSURE DROPPED TO 300 PSI, BLED BACK 30 BBL 10.4 PPG BRINE. BULL HEAD 100 BBL 10.9 PPG BRINE DOWN ANNULUS AT 700 PSI SHUT IN FOR 15 MIN AT 0000 HOURS MONITER WELL 7/18/2001 00:00 - 03:30 3.50 KILL ~P DECOMP BLED OFF & MONITORED ANNULUS. PRESS. BUILT TO 40 PSI IN 15 MIN. WT. UP FROM 10.9 TO 11.3 PPG. BULLHEAD 100 BBLS. 11.3 PPG DN ANNULUS 4 1/2 BPM @ 950 PSI. 03:30 - 04:30 1.00 KILL P DECOMP PRESS.VVENT TO 0 PSI IN 30 MIN, MONITOR WELL. 04:30 - 06:00 1.50 KILL P DECOMP ANNULIS DEAD. BULLHEAD VV/60 BBLS.11.0 PPG DN TBG 4 1/2 BPM @ 750 PSI. MONITOR WELL. WELL DEAD. 06:00 - 07:00 1,00 WHSUR P DECOMP ND TREE. I07:00 - 09:00 2.00 BOPSUF P DECOMP NU BOPE. 09:00 - 12:00 3.00 BOPSUF P DECOMP PT BOPE. LP 250 PSI. HP 2500 PSI. ANNULAR TEST 1500 PSI. TEST OK. VVITNESSING VVAIVED BY CHUCK SHEVE AOGCC. 12:00- 13:00 1.00 BOPSUF P DECOMP PULLTVVC. 13:00 - 14:30 1.50 PULL P DECOMP UNLAND TBG. HANGER. OVERPULL 34K. PUMPED 40 BBLS.11.0 PPG DN TBG. MONITOR WELL 30 MINS. 14:30 - 20:00 5.50 PULL P DECOMP PULL & LD 4 1/2 TBG. & AND SEAL ASSM. 20:00 - 00:00 4.00 REST P DECOMP MADE UP SEAL ASSM. SCREENS & VTL PACKER. RIH P/U 2 7/8 TBG. 7/19/2001 00:00 - 01:00 1.00 RUNCO~ F' COMP COMPLETE RIH VV/HALCO VTL PACKER, SCREENS & SEAL ASSM 01:00 - 03:00 2.00 RUNCOt P COMP STING INTO BAKER PACKER. SPACE' OUT. FILL TBG. DROP BALL. SET VTL PACKER @ 4337'. TEST ANNULUS 1000 PSI. TESTED GOOD. 03:00 - 05:00 2.00 RUNCOt I:) COMP STING OUT OF VTL PACKER. POOH. 05:00 - 09:00 4.00 RUNCO~ F) COMP OOH. CLEAR FLOOR. PJU TO RUN ESP. PULL CABLE AND SECURE TO ESP. 09:00 - 11:30 2.50 RUNCO~ P COMP RIH W/2 7/8 TBG. & ESP. TEST ESP @ 2000' TESTED OK. 11:30 - 14:00 2.50 RUNCO~ I:) COMP SPACE OUT. SPLICE EFT CONNECTOR. TESTED OK. 14:00 - 15:00 1.00 RUNCOr P COMP PU WT. 38 K. SO WT.32K. LAND HANGER. RILDS. INSTALL AND TEST TVVC. 15:00 - 16:30 1.50 BOPSUF P COMP ND BOPE. 16:30 - 18:00 1.50 WHSUR P COMP NU TREE. TEST HANGER AND TREE TO 5000 PSI. TESTED GOOD. 18:00 - 19:00 1.00 VVHSUR P COMP RU LUBRICATOR. PULL TWC. SET BPV. RELEASE RIG. Printed: 7/2312001 11:09:09 AM Obp BP Amoco Baker Hughes INTEQ Survey Report INT~Q Company: BP Amoco FleM: Milne Point Site: M Pt I Pad Well: MPI-04 Wellpnth: MPI-O4AL1 Date: 8/1/2001 Time: 16:10:41 Page: 1 co~rdlaate(NE) Reference: Well: MPI-04, True North Vertical (TVD) Reference: MPI-04 70.0 Section (VS) Reference: Well (0.00N,0.00E,40.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Geomagnetic Model: BGGM2001 Site: M Pt I Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 6008388.01 ft 550245.83 ft Latitude: 70 26 1.282 N Longitude: 149 35 25.422 W North Reference: True Grid Convergence: 0.39 deg Well: M PI-04 Slot Name: 04 MPI-04 Well Position: +N/-S 1056.45 ft Northing: 6009452.79 ft Latitude: 70 26 11.670 N +E/-W 1255.97 ft Easttng: 551494.53 ff Longitude: 149 34 48.561 W Position Uncertainty: 0.00 ff Wellpath: MPI-04AL1 Drilled From: MPI-04 500292206860 Tie-on Depth: 4505.00 ft Current Datum: MPI-04 Height 70.00 ff Above System Datum: Mean Sea Level Magnetic Data: 5/11/2001 Declination: 26.25 deg Field Strength: 57440 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ff ff ff deg 0.00 0.00 0.00 40.00 Survey: MWD Start Date: 7/9/2001 Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path : , , Annotation , 'MD ' :TVD:" , -~0 ~--~ 3970.65 KOP [ 7207.00 4069.68 TD Survey :' MD InCl,: Azim SSTYD': : 'N/$': : ,E/W ':' MaPN: ' MaPE ' DLS : VS: fi:,,': '~ deg: 'deg ,, '"::;',ff~'"~ : ::: ,,, ":ff:~ ' ' ,:R d~ll00ff ft= 4505.00 25.23 51.68 3970.65 3900.65 1509.69 1145.52 6010970.21 552629.49 0.00 1892.81 4530.00 33.20 50.00 3992.45 3922.45 1517.41 1154.95 6010977.99 552638.87 32.05 1904.79 4560.00 45.50 47.00 4015.61 3945.61 1530.03 1169.13 6010990.71 552652.95 41.48 1923.57 4590,00 55.60 44.80 4034.65 3964.65 1546,15 1185.72 6011006.95 552669.43 34.14 1946.59 4620.00 66.60 43.90 4049.12 3979.12 1564.91 1204,04 6011025.83 552687.62 36.76 1972.73 4651.00 78.20 42.80 4058.48 3968.48 1586.37 1224.28 6011047.42 552707.71 37.57 2002.18 4681,00 88,70 40.80 4061.90 3991.90 1608,56 1244.11 6011069.75 552727.39 35.62 2031.93 4711.00 99.40 39.70 4059.78 3989.78 1631.36 1263.42 6011092.68 552746.54 35.85 2061.81 4742,00 98.00 28.00 4055.08 3985.08 1656.77 1280,46 6011118.20 552763.39 37.58 2092.22 4770.00 99.50 19.40 4050,81 3980.81 1682,08 1291,57 6011143.59 552774.33 30.82 2118.76 4801.00 97.50 7.30 4046.21 3976.21 1711.86 1298.63 6011173,41 552781,18 39,14 2146.10 4630.00 90.50 359.20 4044.19 3974.19 1740.70 1300.26 6011202.26 552782.61 36.85 2169.24 4861.00 89.90 353.40 4044.08 3974.08 1771.62 1298.26 6011233.16 552780.40 18.81 2191.64 4897.00 89.60 349.90 4044.24 3974.24 1807,23 1293.03 6011268.73 552774.93 9.76 2215.56 4936.00 90.10 345.00 4044.34 3974.34 1 645,29 1284.56 6011306.73 552766.20 12.63 2239.27 4966.00 90.40 342.30 4044.21 3974.21 1874.07 1276.12 6011335,45 552757,55 9,06 2255.89 5002.00 89.40 336,30 4044,27 3974.27 1907,73 1263.40 6011369.02 552744.60 16.90 2273.50 5032.00 88.90 334.10 4044.71 3974.71 1934.'96 1250.81 6011396,15 552731,64 7.52 2286.27 BP Amoco Baker Hughes INTEQ Survey Report Company: BP Amoco Date: 8/1/2001 l'l~e: 16:10:41 Page: 2 Field: Milne Point Co-o~llmate(NE) Refem,~ce: Well: MPI-04, True North Site: M Pt I Pad Vertical fi'VD) Reference: MPI-O4 70.0 Well: MPI-04 Section (VS) Reference: Well (0.00N,0.00E,40.00Azi) Wellpath: MPI-O4AL1 Snrvey Calculation Method: Minimum Curvature Db: Oracle Survey MD IBcl Azim TVD SSTVD N/S E/W MIpN MapE DLS VS ff deg deg ft ff ff ff ff ff deg/100ff 5064,00 88,90 329,90 4045,33 3975.33 1963.20 1235,80 6011424.29 552716.63 13.12 2298,26 5092,00 90,80 327,80 4045.40 3975,40 1987,16 1221,32 6011448,15 552701,98 10,11 2307,30 5120.00 91.80 326.80 4044.77 3974.77 2010,72 1206.19 6011471.60 552686.70 5.05 2315.63 5154.00 89.70 330.30 4044.32 3974.32 2039.72 1188.46 6011500.47 552668.76 12.00 2326.44 5180.00 89.40 333,50 4044.53 3974.53 2062.65 1176.21 6011523.31 552656,36 12.36 2336.14 5210.00 89.40 338.20 4044.84 3974.84 2090,01 1163,94 6011550.59 552643,91 15.67 2349.21 5241.00 91,10 340.80 4044.71 3974.71 2119.05 1153.09 6011579.54 552632.85 10.02 2364.48 5271.00 89.90 ' 343.40 4044.44 3974.44 2147.59 1143.87 6011608.02 552623.44 9.54 2380.41 5300.00 90.40 347.20 4044.37 3974.37 2175.64 1136.51 6011636.01 552615.89 13.22 2397.17 5337.00 91.60 353.60 4043.72 3973.72 2212.09 1130.35 6011672.42 552609.47 17.60 2421.13 5367.00 91.70 351.10 4042.86 3972.86 2241,81 1126,35 6011702.11 552605.27 8.34 2441.33 5407.00 92.20 356.80 4041.49 3971.49 2281.55 1122.14 6011741.81 552600.79 14,30 2469.07 5437.00 92.50 1,30 4040.26 3970.26 2311,51 1121.65 6011771.77 552600,08 15.02 2491.70 5470,00 90.00 2.70 4039.54 3969.64 2344.48 1122.80 6011804.74 552601.01 8,68 2517.70 5506.00 89.00 7.90 4039.86 3969.86 2380.31 1126.12 6011640,59 552604.08 14.71 2547.28 5535.00 90,00 10.50 4040.11 3970,11 2408.93 1130.76 6011869.24 552608,52 9.61 2572.19 5565.00 89.30 15,10 4040.29 3970.29 2438.18 1137.40 6011898,53 552614.96 15.51 2598.86 5598,00 90,60 17,30 4040,32 3970,32 2469,87 1146,61 6011930,28 552623,95 7,74 2629,05 5634,00 89,80 22,10 4040,20 3970,20 2503,751158,74 6011964,24 552635,84 13,52 2662,81 5686,00 89.50 26,50 4040,39 3970,39 2532,91 1171.90 6011993,48 552648,81 13,78 2693,60 5696,00 89,40 28,60 4040,68 3970,68 2559,50 1185,78 6012020,17 552662,50 7,01 2722,90 5740,00 89, 50 32,20 4041,10 3971,10 2597,44 1208,04 6012058,26 552684,49 8,18 2766,27 5770.00 90.60 36.10 4041.08 3971.08 2622.27 1224.88 6012083.20 552701,16 13.51 2798.11 5806,00 89.60 39.00 4041.02 3971.02 2650.80 1246,81 6012111,88 552722.89 8.52 2832.07 5837,00 89.60 41.40 4041.23 3971.23 2674.48 1266,82 6012135.70 552742.74 7.74 2863.07 5868.00 90.50 45.30 4041.20 3971.20 2697.02 1288.10 6012158.38 552763.85 12.91 2894.01 5900.00 90.40 48.80 4040,95 3970.95 2718.82 1311.52 6012180.34 552787.12 10.94 2925.76 5931.00 90.70 52.50 4040.66 3970.66 2738.47 1335.48 6012200.15 552810.95 11.97 2956.22 5965.00 89.90 55,20 4040.48 3970.48 2758,52 1362.93 6012220.39 552838,25 8,28 2989.23 5998.00 88.80 58.80 4040.85 3970.85 2776,49 1390.60 6012238.55 552865.80 11.41 3020.78 6034.00 88.80 62,70 4041.61 3971.61 2794,08 1422.00 6012256.35 552897.07 10.83 3054.43 6075.00 88.80 66.30 4042.46 3972.46 2811.72 1458.99 6012274.24 552933.93 8.78 3091.72 6108.00 87.30 70.00 4043.59 3973.59 2823.99 1489.60 6012286.73 552964.45 12.09 3120.80 6137.00 86.60 73.30 4045.13 3975.13 2833.11 1517.08 6012296.03 552991.87 11.62 3145.45 6171.00 86.60 76.10 4047.15 3977,15 2842.06 1549.81 6012305.21 553024.53 8.22 3173,35 6201,00 87.40 79.20 4048.72 3978.72 2848.47 1579,07 6012311.82 553053.75 10.66 3197,06 6239.00 86.70 83.20 4050.68 3980.68 2854.27 1616,57 6012317.68 553091.20 10.67 3225.61 6269,00 87,60 87,10 4052,17 3982,17 2856,81 1646,42 6012320,62 553121,03 13,33 3246,74 6301.00 87,70 90,50 4053,48 3983,48 2857,48 1678,38 6012321,51 553152,98 10,62 3267,80 6335,00 88.20 93,70 4054,70 3984,70 2856,23 1712.33 6012320,50 553186,94 .9,52 3288,67 6364,00 87,60 96,80 4055,76 3985,76 2853,58 1741,19 6012318,05 553215,81 10,88 3305,18 6394,00 91,40 101,40 4056,02 3986,02 2648,64 1770,79 6012313,51 553245,44 19,89 3320,58 6424,00 90,60 105,80 4055,50 3985,50 2641,79 1799,94 6012306,68 553274,64 14.90 3333.91 6450,00 89,30 109,90 4055,52 3985,52 2833,82 1824,68 6012298,87 553299,43 16,54 3343,71 6481,00 88,40 111,00 4056,14 3986,14 2822,99 1853,72 6012288,24 553328,54 4,58 3354,09 6517,00 88,90 117,30 4056,99 3986,99 2808,27 1886,55 6012273,75 553361,46 17,55 3363.91 6548,00 89,30 114,30 4057,48 3987,48 2794,78 1914,45 6012260,45 553389,45 9,76 3371,51 6560.00 87.90 109.90 4058.26 3988.26 2782.75 1944,08 6012248.63 553419.17 14.43 3381,34 6610,00 87,00 107.10 4059.60 3989.60 2773,24 1972,50 6012239.32 553447.65 9.79 3392.32 6640.00 88.80 105.70 4060.70 3990.70 2764.78 2001.26 6012231.05 553476.46 7.60 3404.33 6673.00 89.20 101.50 4061.27 3991.27 2757,02 2033,32 6012223.52 553508.57 12.78 3418.99 6700.00 89.80 98.40 4061.51 3991.51 2752.36 2059,91 6012219.04 553535.19 11.69 3432.51 BP Amoco Baker Hughes INTEQ Survey Report Compaay: BP Amoco D~te: 8/1/2001 Time: 16:10:41 Page: 3 FIeM: Milne Point Co-ordlaate(NE) l~eference: Well: MPI-04, True North Site: M Pt I Pad Vertical (TVD) Reference: MPI-04 70.0 Well: MPI-04 Section (VS) Reference: Well (0.00N,0.00E,40.00~zi) Wellpa~: MPI-04AL1 Sar~ey CalcMatlon Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD SSTVD NIS E/W MapN MapE DLS VS ff deg deg ff ff ff ff ff ff deg/100ff ff 6732.00 90.30 95.50 4061.48 3991.48 2748.48 2091.67 6012215.39 553566.97 9.20 3449.96 6760.00 88.90 92.10 4061.67 3991.67 2746.63 2119.60 6012213.72 553594.92 13.13 3466.50 6790.00 91.40 89.90 4061.60 3991.60 2746.11 2149.60 6012213.41 553624.91 11.10 3485.37 6820.00 92.40 85.90 4060.60 3990.60 2747.20 2179.55 6012214.71 553654.85 13.74 3505.47 6868.00 90.90 82.30 4059.22 3989.22 2752.14 2227.27 6012219.97 553702.53 8.12 3539.92 6898.00 91.00 79.80 4058.72 3988.72 2756.80 2256.90 6012224.84 553732.12 8.34 3562.54 6929.00 87.70 77.90 4059.07 3989.07 2762.79 2287.31 6012231.04 553762.49 12.28 3586.68 6962.00 86.60 75.70 4060.71 3990.71 2770.32 2319.39 6012238.79 553794.52 7.45 3613.06 6996.00 88.30 71.90 4062.23 3992.23 2779.80 2352.00 6012248.49 553827.06 12.23 3641.28 7030.00 87.70 68.10 4063.41 3993.41 2791.41 2383.93 6012260.33 553858.90 11.31 3670.71 7064.00 86.80 64.20 4065.05 3995.05 2805.14 2414.98 6012274.27 553889.85 11.76 3701.18 7098.00 88.40 59.30 4066.47 3996.47 2821.22 2444.89 6012290.55 553919.65 15.15 3732.73 7128.00 88.10 57.00 4067.39 3997.39 2837.04 2470.36 6012306.54 553945.01 7.73 3761.22 7160.00 88.40 52.70 4068.36 3998.36 2855.45 2496.51 6012325.13 553971.02 13.46 3792.13 7207.00 88.40 52.70 4069.68 3999.68 2883.92 2533.88 6012353.86 554008.20 0.00 3837.96 REFERENCF INFORMATION C~ordu~ste (N/E) Reference We~tCenlre MP~ 04 True Ve(bcal ( J VD) Refe pence SI ;tern: Mean Sea Level SeCtion (VS) F~eference Slot 04 )O0N 0 0OE~ Measured Dep01ReJerence MPI O4 7O O0 Calculabon Method M~mmum 3u~amre 3000 3100 3200 E8500 4200 430O 4400 45OO 3100 3000 2900 2700 ~2100 Azimuths to True Nod ',~pP 0044 (~¢?p 7944~1(,. ..... Il'\ ¢' ~889,,¢U0 North: 2820' 1300 1400 1500 1600 1700 1800 1900 2OOO 2100 22OO 23OO 240O 250O 26OO 2700 2800 2900 3000 3100 8200 330O 3400 3500 3600 3700 3800 3900 4000 4100 4200 4300 4400 4500 46OO 47O0 48OO 4900 50OO 5100 52OO 8/112001 4;~4 PM AI,ASKA OIL AND GAS CONSERVA~I~ION COPl~I~SSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mark Johnson CT Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519 Re: Milne Point Unit MPI-04AL1 BP Exploration (Alaska) Inc. Permit No: 201-093 Sur Loc: 2942' SNL, 3876' WEL, Sec. 33, T13N, R10E, UM Btmhole Loc. 303' SNL, 1731' WEL, Sec. 33, T13N, R10E, UM Dear Mr. Johnson: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt yOu from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other, required permitting determinations .are made. .. The permit is for a new wellbore segment of existing well MPI-04A, Permit No, 20'1-092, API 50-029-22068-01. Production should continue to be reported as a function of the .original AP1 number stated above. Blowout prevention' equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hoUrs) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field insPector on the NOrth. Slope pager at 659-3607. Commissioner By ORDER OF THE COMMISSION DATED this~3~ay~ of May, 2001 jjc/Enclosures CC: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA COMMie( ALASKA Or,_ .~ND GAS CONSERVATION . PERMIT TO DRILL 20 AAC 25.005 I [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work B Ddll [] Redrill lb. Type of well [] Service [] Development Gas [] Single Zone [] Multiple Zone Re-Entry [] Deepen 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE - 70' Milne Point Unit / Schrader 3. Address ,6. Property Designation Bluff P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025906 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2942' SNL, 3876' WEL, SEC. 33, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number 1464' SNL, 2769' WEL, SEC. 33, T13N, R10E, UM MPI-04AL1 Number 2S100302630-277 At total depth 9. Approximate spud date 303' SNL, 1731' WEL, SEC. 33, T13N, R10E, UM 06/08/01 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025517, 3547' MDI No Close Approach 2560 6655' MD / 4010' TVDss 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 4515' MD Maximum Hole Angle 100 o Maximum surface 1400 psig, At total depth (TVD) 3860' / 1775 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include sta,qe data) 3-3/4" 2-7/8" 6.16# L-80 ST-L 2160' 4495 3892' 6655 4010' Uncemented Slotted Liner ! ~1,.. ~,.~B-----B v 19.'To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary MAY -'[ 6 ~001 Total depth: measured 4900 feet Plugs (measured) true vertical 4329 feet Alaska Oil & Gas Cons. Commission Effective depth: measured 4795 feet Junk (measured) Anchorage true vertical 4234 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 13-3/8" 485 sx Permafrost 'C' 115' 115' Surface 2564' 9-5/8" 1111 sx Permafrost 'E', 244 sx 'G' 2599' 2354' Intermediate Production 4846' 7" 260 sx Class 'G' 4881' 4312' Liner Perforation depth: measured 4383' - 4392', 4411' - 4428', 4443' - 4451', 4554' - 4588', 4624' - 4655' true vertical 3860' - 3868', 3886' - 3901', 3915' - 3922', 4015' - 4046', 4078' - 4107' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program I~1 Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Mark Johnson, 564-5666 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the~.~oregoing is true/an~ correct to the best of my knowledge / ! Signed Mark Johnson f~~//~. ~'~_/~,~Title CT Drilling Engineer Date ~'//~//~/ : .:"i, ;' .' ::.:.':.:..." .... '.' '"',~' :.:i: ::,;"';:::,'.i:;': ',:';',"'".:'".::i;'"'": :""' "' :":' "'~'"mrniSSiPh''~:Ose':Only'!''':''';:::'':::''' ".; '; :':':':"":';:",';"; :,':. "':."":::' ":. ,;,,,,.'.:.:i::'..:.:':. ':,.'. ~: :.. ',',.;i': ':..'i:! i:':,, "! .'.::: ': :: ...'.!;:,,,,.;, :' ,, Permit Number _I N erI ,-.App;,ov~,Dat¢ ISee cover letter .~.<::)/'- ~/~ 50- 029-22068-60 ~u~_ .f~ I' (...") ! for other requirements Conditions of Approval: Samples Required [] Yes ~ No Mud Log Required [] Yes J~ No Hydrogen Sulfide Measures J~ Yes [] No Directional Survey Required I~Yes [] No Required Working Pressure for BOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K ]Z~.,3.5K psi for CTU Other: ORIGINAL SIGNED BY by order of~. ~l I~ Approved By D Taylor Seamount Commissioner the commission Date \l' ' ,., Form 10-401 Rev. 12-0.1-85 ORI61k AL Submit In Triplicate BPX Milne Point MPI-O4A & L1 Sidetracks - Coiled Tubing Drilling Summary of Operations: MPI-04 will be sidetracked with two horizontal wellbores (MPI-04A and L_i) to target Schrader Bluff OB and CA reserves respectively. Coiled Tubing Ddlling (CTD) will perform the sidetracks. Pdor to CTD arrival, Nabors 4ES will pull the existing ESP completion and abandon the Schrader CA & OB perforation intervals (sundry form 10-403 to be submitted by 4ES drilling engineer). CTD Drill and Complete 1-04A pro.qram: Planned for May 29, 2001 1) Set whipstock at ~4540' (in 7" casing at 25° wellbore inclination) 2) Mill window through 7" and mill 10' of openhole. 3) Ddll horizontal sidetrack 1-04_A from window to 6696' TD targeting Schrader Bluff OB sand interval as per attached directional plan. 4) Complete with slotted liner from TD to ~20' inside of 7" casing. CTD Drill and Complete 1-04A L1 Lateral pro,qram: Planned for June 8,2001 5) CTD set flowthrough whipstock at ~4515' (in 7"casing at 25° wellbore inclination) 6) Mill window through 7" and mill 10' of openhole 7) Drill horizontal lateral 1-04A L_11 from window to 6655' TD targeting Schrader Bluff CA sand interval as per attached directional plan. 8) Complete with slotted liner from TD to -20' inside of 7"casing Mud Program: · Steps l& 2:8.5 ppg KCL/NaCI biozan brine · Steps 3-8: FIo-Pro (9.3 - 9.9 ppg) Disposal: · No annular injection on this well. · Class II liquids to KRU 1R Pad Class II disposal well · Class II drill solids to PBU DS-4 Grind & Inject · Class I wastes will go to Pad 3 for disposal. Casing Program: · 1-04A - 2 7/8", 6.16~, L-80, STL slotted/pre perforated liner will be run from 6696' TD to approximately 4520' · 1-04A L1 - 2 7/8", 6.16#, L-80, STL slotted/pre perforated liner will be run from 6655' TD to approximately 4495' Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2000 psi. Directional · See attached directional plans for 1-04A__ & 1-04A L__!.1. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray Icg will be run over all of the open hole section. · Resistivity logging in sections of the openhole Hazards · No significant faults are expected to be crossed, lost circulation risk is Iow. Res. pressure is 8.8 ppg. 1-04 had an H2S reading of <2 ppm 2/01. Milne Point production has historically been sweet. Highest H2S on the pad is <2 ppm. Reservoir Pressure · Res. pressure is approx. 1775psi @ 3860ss (8.8 ppg). Max. surface pressure with gas (0.1 psi/ft) to surface is 1400 psi. 1-04A and 1-04A L1 Potential Drilling Hazards Post on Rig 1. Please perform pre-job Hazard ID and Safety meetings prior to every change in work scope during the operation. Also, if things don't feel right shut down the operation and discuss the situation before making the next operational move. SAFETY FIRST. 2. H2S is not expected on this well. 1-04 had an H2S reading of <2 ppm 2/01. Miine Point production has historically been sweet. Highest H2S on the pad is <2 ppm. 2. BHP is expected to be approx. 1775psi (8.8ppg) @ 3860'ss. 3. Maximum anticipated well head pressure w/full column of gas is 1400psi. 4. Lost circulation risk is Iow with no significant faults expected to be penetrated. TREE: 2-9/16"- ,,, ~/KM WELLHEAD: 11" 5M WKM w/ 2-7/8" 8rd TREE TOP CONNECTION 2.1/2" "H" Profile. 1-04 O~,u. KB - SL = 52' (NABORS 27E) Odg. KB - GL = 35' (NABORS 27E) 13 318"' 54'~' I ""5' I K-55 Weld Set KOP @ 500' Max Hole Angle: 38.9° @ 2100' MD 95/8", 36~/ft, 12599' I K-55 Butt Raychem Heat Trace Camco 2 7/8" x 1" I 1 35' sidepocket KBMM GLM [ RA Tag @ 3,623' 2-718" 6.5~ L-80 EUE 8rd tbg .00579 bbls/ft. 7" 26~ L-80 buttress casing .0383 bbls/ft. I Camco 2 7/8" x 1" I 4076' sidepocket KBMM GLM Pump Intake @ 3668' TVD N SAND PERFORATION SUMMARY TVD I24 I 4,383'-4,392' J24 J 4,411'-4,428' j24 J 4,443'-4,451' J 124spf'24gm 3,860' - 3,868' 3,885' - 3,901' 3,914' - 3,921' O SAND, PERFORATION SUMMARY ~ INTERVAL [TVD 4,624' - 4,655'J 4,078' - 4,106' 5spf,37gm J DATE 3/9/95 iii REV. BY COMMENTS RW0 - I'NSTALL ESPCP 8-29-96 MDO ESP rwo POLAR #1 Centdliff KUDU, PCP, I 4165' 60 TP 1300 I Centrilift I 4188' GSTDBILAFLASHSNPFS, seal section Centrilift series, GMF r 50 hp motor, 1170 v./27 ~ 4202' amps. Centrilift PHD I 4209' 7" OTIS "VST" VERSA-TRIEVE PkrI 6 H-S 3-1/2" Blank Pipe (73') 4,2 0' H-S 12 Guage H-S Screen (100', 2.99" ID) 4359' Frac Pack (N-sands) 20~40 Mesh Gravel O-Ring Seal Bore (2.75" ID) J 4~458' 3-1/2" H-S 12 Gauge Tell-Tale I Screen (11', 2.99") J 4,47,!' 7" OTIS "AWD" Sump Pkr (4.0" ID) ~ 3-1/2" X NIPPLE (2.313"19) I ~,, ,~,,1,(,,.1 ~,~ I W~re, ne Er, tr~ Gu~de12.44" ~1 [ 4,497', I PBTD I 4,795' I 7", 26#/ft, L-80 Butt I 4.881' I Shoe ii i ii i i , MIL. NE POINT UNIT WELL 1-04a APl NO: $0-029-22068 i i BP EXPLORATION {AK) -,-,~.: ~_.,.,,.,.. ~,~ w,~. 104 o,~..,~.- ~.= ~. ~,.,^.o.s~..i WELLHEAD: 11" 5M WKM w/ ~ Odg. KB - GL = 35' (NABORS 27E) -- - -' - - K-55 Weld Set ~o.~oo, ~ ~ ~// I M~ Hole Angle: 38.9 ~2100'MD / 9..555/8",~.~3~, ~, -- ~ ~/~ Frac pack of N sands I ~ ~ ~ and ESP installation RATag ~ 3,823'~; ~ ~ ~ I / after CTD sidetrack 24 4,383' - 4,392' 3,860' - 3,868' ~ ~ 24 4,411'- 4,428' 3,885,-3,9Ol, ~ ~ ~ : "'"~""'"~' ~'"~"~'"~' I ! ~__. 24 spf, 24 gm ~ ~'"'"~ ~'"'"~ / I OB whipstock at 4540' md Cement retainer at 4550' md ~ OB Sand horizontal ~ ~ °~e~ n~T ~e~~t~ e r SIZE SPF INTERVAL TVD ~ , , ~ .~.,-~,.o~.,-~0.~, ~"~ I 4,795'1 5 4,624'-4,655' 4,078'-4,106' 7", 26~R, L-80 Bu~ ~ 4.881' 5 spf, 37 gm Shoe , , DATE REV. BY COMMENTS MILNE POINT UNIT 3~9~95 DBR RWO -INSTALL ESPCP WELL 1-048 .... 8-29-96 MDO ESP RWO PO~R ~1 APl NO: 50-029-22068 5/14/01 MOJ Proposed post CTD sidetrack ..... , BP EXPLO~TION I BP Amoco REFERENCE INFORMATION Co~ordinate (N/E) Reference: Well Centre: MPI-O4, True Nodh VedJcal (TVD) Reference: System: Mean Sea Level Secth~n (VS) Reference: Slot - 04 (0.0ON,O.0OE) Measured D~pth Reference: MPI-04 70.00 Calculation Method: Minimum Curvature AH NOTATIONS 31~4.f~ 4800,OO TiP ~.4~ 4~IK,O~ ~KOP ~.T0 4701~t2 ~1'~71 48Ol.t3 ~mJ1 ~eaS.4~ 'i ObP Azimuths to True North Magnetic North: 26.25° Magnetic Field Strength: 57440nT Dip Angle: 80.77° Date: 5/11/2001 Model: BGGM2000 Plan: Plan #1 (MPI.O4/Plan~I (CTD) MPI.O4AL1) Created By: Brtj Potnis Date: 5/! 1/2001 Contact Information: Direcl: (907) 267-6613 E-maih brij.potnis @ inteq.com Baker Hughes INTEQ: (907) 267-6600 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 West(-)lEast(+) [lOOft/in] i. .1 - -- i .! ~d .... i .... i,,,','~'-~~:'"~,,'i .... ; i I ' ~ .... I .... t .... t,,,,1~,,,I,,,' i I t I I I I I 18~ 1~0 1~ 1950 2~ 2050 21~ 21'50 22~ =50 2300 23~0 24~ 2450 25~ 25~ 2~0 2650 27~ 2¢50 28~ 2850 29~ 2950 3~ 30~ 3100 31~ 32~ 3250 33~ ~50 ~00 ~50 35~ 3550 36~ 36~ 37~ Ve~ical Sectio. at 4~,0~' [S~in] 5/11/2001 3:09 PM ObP - BP Amoco ,, Bake(r rIughes INTEQ Planning RepO~ ~ BAKER HUGHES INTEQ Field: . Milne Point" Site:' · M PtlPad ' W~iI: .,!' MpI~4. .. WellPath:'~. Plan#1 (CTD) MPI-04AL1 Date: .1:5/11/2001 ~'. Time: 14:57:10 ' Pa~e: 1 Co-ordinate(N~) Reference: Well: MPI-04, TrueNorth Vertkal (TVD).Reference: . SyStem: Mean Sea. Level Section (VS) Reference: Well (0,00N,0.00E~40:00Azi) ' Survey CalculatiOn Method: MinimUm Curvature'.'>'..'. -Db: Oracle Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Gee Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Alaska. Zone 4 Coordinate System: Well Centre Geomagnetic Model: BGGM2000 /_./ Site: M Pt I Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ff 6008388.01 ft 550245.83 ft Latitude: 70 26 1.282 N Longitude: 149 35 25.422W North Reference: True Grid Convergence: 0.39 deg IWell: MPI-04 Slot Name: 04 MPI-04 Well Position: +N/-S 1056.45 ft Northing: 6009452.79 ft Latitude: 70 26 11.670 N +E/-W 1255.97 ft Easting: 551494.53 ft Longitude: 149 34 48.561 W Position Uncertainty: 0.00 ft Wellpath: Plan#1 (CTD) MPI-04AL1 Drilled From: MPI-04 500292206860 Tie. on Depth: 4515.00 ff Current Datum: MPI-04 Height 70.00 ft Above System Datum: Mean Sea Level Magnetic Data: 5/11/2001 Declination: 26.25 deg Field Strength: 57440 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ff ff ff deg 0.00 0.00 0.00 40.00 Plan: Plan #1 Date Composed: 5/11/2001 Version: 1 Principal: Yes Tied-to: From: Definitive Path Targets .'. '. . ?/ '.':? ~:i,'.~?:i',?"i!~ii?.:~.:'.':;i."?~?.,.=.i::!:..../.':::?..'~?.:. :.¥. "', :" :":.':" .. '.(".'.'.."..:'.:':~./':'..'..'.'":...".?:!ii i'.'..i'...'..,.' :..,.,.'",7':;'.;/:.:~/??:~' (~' ;/?;i'-:~:,~' ~. Map' > ~'.,. MPI-04AL1 Polygon1.1 0.00 1296.80 974.42 6010756.16 552459.88 70 26 24.424 N 149 34 19.959 W -Polygon I 0.00 1296.80 974.42 6010756.16 552459.88 70 26 24.424 N 149 34 19.959 W -Polygon 2 0.00 3358.48 1057.92 6012818.17 552529.14 70 26 44.700 N 149 34 17.499 W -Polygon 3 0.00 3250.46 1653.66 6012714.28 553125.55 70 26 43.636 N 149 34 0.008 W -Polygon 4 0.00 2937.08 2446.64 6012406.41 553920.60 70 26 40.552 N 149 33 36.728 W -Polygon 5 0.00 2510.29 2259.85 6011978.38 553736.78 70 26 36.355 N 149 33 42.216 W -Polygon 6 0.00 2569.64 1614.17 6012033.27 553090.77 70 26 36.941 N 149 34 1.172 W -Polygon7 0.00 2302.76 1443.45 6011765.24 552921.91 70 26 34.316 N 149 34 6.185 W -Polygon 8 0.00 1522.14 1373.59 6010984.23 552857.45 70 26 26.639 N 149 34 8.241 W -Polygon 9 0.00 1340.23 1059.22 6010800.17 552544.37 70 26 24.851 N 149 34 17.469 W -Polygon 10 0.00 1296.80 974.42 6010756.16 552459.88 70 26 24.424 N 149 34 19.959 W MPI-04AL1 T1.1 3973.00 1726.09 1236.24 6011187.21 552718.71 70 26 28.645 N 149 34 12.271 W MPI-04AL1 T1.2 3985.00 2336.56 1147.84 6011796.99 552626.11 70 26 34.649 N 149 34 14.863 W MPI-04AL1 T1.3 3995.00 2943.08 1511.17 6012405.95 552985.20 70 26 40.614 N 149 34 4.193 W MPI-04AL1 T1.4 4004.00 2786.17 1792.75 6012251.00 553267.83 70 26 39.070 N 149 33 55.927 W MPI-04AL1 T1.5 4007.00 2825.43 2066.35 6012292.15 553541.12 70 26 39.455 N 149 33 47.895 W MPI-04AL1 T1.6@TD 4010.00 2756.25 2166.59 6012223.66 553641.83 70 26 38.774 N 149 33 44.952 W BAICER BP Amoco bp Baket .tughes INTEQ Planning Repoi INTEQHUGHES ~7 .Company: BP Amoco . ~,;i:, · .~. ~ ' Date: '5/1'1/2001 . "Time: i4:57:10 Page: 2 Field: Milne Point '"~" . "' '.",'i,i ' :i, ,: i"'ii":' .., Coordinate(NE) Reface: ii Well:,MPl-04, True North 1 Site: M Pt I Pad ., VeraCa] ('rYD) P,~a'~ace: System:. Mean Sea, LeVel Well: .'MPI-04 ". ~,,, ,: : ":., :-: ,' '.,,,Well (0,00N,0.00E,40.00Azi) WellFa~:' plan#1.(CTD) MPI-04AL1 · ',, · · .':,,:.i'."?,i", !,':.' :.'.' "~.' :Sur~e~ Calcalatioa Method: ",Minimum Cun/ature ' ' Db; ', Oracle Annotation 3896.13 TIP 3909.70 KOP ~r701.92 3989.70 1 4801.92 3973.71 2 4855.49 3970.11 3 5055.49 3973.12 4 6055.49 3995.82 5 6655.49 4010.04 TD Plan Section Information MD Ind Azim TVD +N/-S ' ~+F/-W DIS Build': Turn TFO Target ft "deg' deg . ff ff . '~'i~,,. ff deg/100ff deg/100ff deg/100ff, deg 4500.00 25.23 51.68 3896.13 '4515.00 25.23 51.68 3909.69 4701.92 100.00 51.68 3989.70 4801.92 97.64 11.25 3973.71 4855.49 90.00 351.17 3970.11 5055.49 88.29 331.24 3973.12 6055.49 89.80 71.25 3995.81 6655.49 87.74 131.23 4010.00 1508.37 1143.64 0.00 0.00 0.00 0.00 1512.33 1148.86 ~ 0.00 0.00 0.00 1608.10 1270.03 ~ 40.00 0.00 0.00 1690.61 1320.39 40.00 -2.36 -40,43 -90.00 1743.73 1321.47 40.00 -14.27 -37.48 -110.00 1932.09 1257.38 10.00 -0.85 -9.96 -95.00 2749.89 1575.60 10.00 0.15 10.00 90.50 2638,34 2137.41 10.00 -0,34 10.00 92.50 Survey , '.".MD' '. '"': Ina','..."' .'"i. i';:Azim .': :,: ,'/.. S`S~:`~i~`~:~:~:~:;N~?:i~:?~!!~;:~`~/~:~i~::~?~?~::::~:~:~::~:I..:':'~pNI · .'".".":?'.!: ':'.M~E;'?~.".",:.;.;:::.':.'~.:i:...:DLS.i:' ,',';:',i,,:,'" ?,Vs ," ".' ,,':,.'i :F0,.'::: ",,.,: :'.:'"',T~I,,,',,' .:' i ,, · . ".' ft' ':.'." '.' .: deg.. :':"i'"' .deg.'."..... i.":.:....'.:~::.'::.'::.;....;:','.~..'..· ~;~/~?:~:~:~ft~i`:~i~`~:;?i~!?`ft...~;::i??~ :,:.:'.:.,;.:.. ~:.':.':.'ft'...::'.:..:"".:' '!i.::.' .::,~.:: ,Till.'.,.;'...:.':,. ':;?.i.::d~g/1,,.00fti::.::"' :' 'ft: '.' '....'.'; ":':.: 'deg. i:.":'.' 4500.00 25.23 51.68 3896.13 1508.37 1143.84 6010968.88 552627.82 0.00 1890.72 0.00 TIP 4515.00 25.23 51.68 3909.69 1512.33 1148.86 6010972.87 552632.81 0.00 1896.98 0.00 KOP 4525.00 29.23 51.68 3918.58 1515.17 1152.45 6010975.73 552636.38 40.00 1901.46 0.00 MWD 4550.00 39.23 51.68 3939.22 1523.88 1163.47 6010984.52 552647.34 40.00 1915.22 360.00 MWD 4575.00 49.23 51.68 3957.11 1534.67 1177.13 6010995.41 552660.93 40.00 1932.27 360.00 MWD 4600.00 59.23 51.68 3971.71 1547.24 1193.03 6011008.08 552676.73 40.00 1952.11 0.00 MWD 4602.56 60.25 51.68 3973.00 1548,61 1194.76 6011009.46 552678.46 40.00 1954.28 0.00 MPI-04 4625.00 69.23 51.68 3982.56 1561.18 1210.67 6011022.14 552694.27 40.00 1974.13 360.00 MWD 4632.37 72.18 51.68 3985.00 1565.49 1216.13 6011026.49 552699.70 40.00 1980.95 360.00 MPI-04 4650.00 79.23 51.68 3989.35 1576.08 1229.52 6011037.17 552713.02 40.00 1997.66 0.00 MWD 4675.00 89.23 51.68 3991.86 1591.48 4700.00 99.23 51.68 3990.02 1606.92 4701.92 100.00 51.68 3989.70 1608.10 4725.00 99.87 42.31 3985.71 1623.59 4750.00 99.44 32.17 3981.51 1643.18 4775.00 98.72 22.07 3977.55 4800.00 97.73 12,02 3973.97 4801.92 97.64 11.25 3973.71 4825.00 94,41 2.55 3971.28 4850.00 90.79 353.22 3970.15 4855.49 90.00 351.17 3970.11 4875.00 89.83 349.23 3970.14 4900.00 89.61 346.74 3970.26 4925.00 89.40 344,25 3970.48 4950.00 89.18 341.75 3970.79 4975.00 88.97 339.26 3971.19 5000.00 88.75 336.77 3971.69 5025.00 88.54 334.28 3972.28 5050.00 88.34 331.79 3972.96 5055,49 88.29 331.24 3973.12 5075.00 88.27 333.19 3973.70 5100.00 88.26 335.69 3974.46 1249.01 6011052.70 552732.40 40.00 1268.54 6011068.28 552751.83 40.00 1270.03 6011069.47 552753.31 40.10 1286.64 6011085.07 552769.80 40.00 1301.53 6011104.76 552784.56 40.00 2021.99 0.00 MWD 2046.38 360.00 MWD 2048.24 0.00 1 2070.77 270.00 MWD 2095.36 268.38 MWD 1665.13 1688.75 1690.61 1713.37 1738.30 1312.77 6011126.78 552795.64 40.00 2119.39 266.68 MWD 1320.01 6011150.45 552802.72 40.00 2142.14 265.08 MWD 1320.39 6011152.31 552803.09 39.90 2143.81 263.30 2 1323.14 6011175.09 552805.68 40.00 2163.02 250.00 MWD 1322.22 6011200.01 552804.59 40.00 2181.52 249.09 MWD 1743.73 1762.95 1787.40 1811.60 1835.51 1321.47 6011205.43 552803.80 40.00 2185.20 248.79 3 1318.15 6011224.63 552800.35 10.00 2197.79 265.00 MWD 1312.94 6011249.04 552794.98 10.00 2213.17 265,00 MWD 1306.68 6011273.20 552788.55 10.00 2227.69 265.02 MWD 1299.37 6011297.05 552781.07 10,00 2241.30 265.04 MWD 1859.07 1882.25 1904.99 1927.26 1932.09 1291.03 6011320.55 552772.57 10.00 2253.99 265.07 MWD 1281.68 6011343.66 552763.06 10.00 2265,73 265.11 MWD 1271,32 6011366.33 552752.55 10.00 2276.50 265.16 MWD 1259.99 6011388.52 552741.07 10.00 2286.28 265,22 MWD 1257,38 6011393.33 552738.42 10.00 2288.30 265.10 4 1949.34 1248.29 6011410.52 552729.21 10.00 2295.67 1971.88 1237.51 6011432.98 552718.28 10.00 2306.01 90.50 MWD 90.44 MWD ObP BP Amoco Bake~ dughes INTEQ Planning Repo~ ~ BAKER HUGHES INTEQ IlCo~lmay: BP Amooo {. Field:. ,' Milne Point [' :Sit~:: . M :pt I Pad "' IWell: ~" MPI-04 . ~ W~..llpath: . Plangl. (CTD) MPI-O4AL1 ])ate: 5/11/2001 Time: 14:57:10 ]~age: 3 Co-Ordb~te(NE) Eefa'eaCe: Well: MPI-04, True North Vertical' (T CD) ]~efereace: System: Mean Sea Level · SectiOn (V$) Reference:. Well (0.00N,0.00E,40.00Azi) , , ,' smw~Caladation.Metbo&. Minimum Curvature Db: oracle Sur~ey ,:' ,':; MD ' Ind ~im . SSTVD N/S ~ E/W . MapN MapE DIS VS TFO ' Tool ' :"j. ,"ff .. deg deg · ft ". ft · ~ft ft ft deg/100ft ft . deg 5125.00 88.24 338.19 3975.23 1994.87 1227.72 6011455.90 552708.34 10.00 2317.33 90.37 MWD 5150.00 88.23 340.70 3976.00 2018.27 1218.95 6011479.23 552699.40 10.00 2329.61 90.29 MWD 5175.00 88.22 343.20 3976.77 2042.03 1211.21 6011502.93 552691.50 10.00 2342.83 90.21 MWD 5200.00 88.22 345.70 3977.54 2066.10 1204.51 6011526.95 552684.63 10.00 2356.96 90.13 MWD 5225.00 88.22 348.20 3978.32 2090.44 1198.87 6011551.25 552678.82 10.00 2371.98 90.06 MWD 5250.00 88.22 350.70 3979.10 2115.00 1194.29 6011575.78 552674.08 10.00 2387.86 89.98 MWD 5275.00 88.23 353.20 3979.87 2139.74 1190.79 6011600.49 552670.41 10.00 2404.56 89.90 MWD 5300.00 88.24 355.70 3980.65 2164.61 1188.38 6011625.34 552667.82 10.00 2422.06 89.82 MWD 5325.00 88.25 358.20 3981.41 2189.56 1187.05 6011650.28 552666.32 10.00 2440.32 89.75 MWD 5350.00 88.27 0.70 3982.17 2214.55 1186.81 6011675.26 552665.91 10.00 2459.31 89.67 MWD 5375.00 88.28 3.21 3982.93 2239.52 1187.66 6011700.24 552666.59 10.00 2478.99 89.59 MWD 5400.00 88.31 5.71 3983.67 2264.43 1189.60 6011725.16 552668.36 10.00 2499.32 89.52 MWD 5425.00 88.33 8.21 3984.40 2289.23 1192.63 6011749.98 552671.21 10.00 2520.26 89.44 MWD 5450.00 88.36 10.71 3985.12 2313.88 1196.74 6011774.66 552675.15 10.00 2541.78 89.37 MWD 5475.00 88.39 13.21 3985.83 2338.33 1201.91 6011799.13 552680.16 10.00 2563.84 89.30 MWD 5500.00 88.43 15.71 3986.52 2362.52 1208.15 6011823.37 552686.23 10.00 2586.38 89.23 MWD 5525.00 88.47 18.21 3987.20 2386.42 1215.44 6011847.32 552693.35 10.00 2609.38 89.16 MWD 5550.00 88.51 20.71 3987.86 2409.99 1223.77 6011870.94 552701.51 10.00 2632.78 89.09 MWD 5575.00 88.55 23.21 3988.50 2433.16 1233.11 6011894.17 552710.70 10.00 2656.54 89.03 MWD 5600.00 88.60 25.71 3989.12 2455.91 1243.46 6011916.99 552720.89 10.00 2680.62 88.96 MWD 5625.00 88.65 28.21 3989.72 2478.18 1254.79 6011939.34 552732.06 10.00 2704.97 88.90 MWD 5650.00 88.70 30.71 3990.30 2499.94 1267.09 6011961.18 552744.20 10.00 2729.54 88.84 MWD 5675.00 88.75 33.21 3990.86 2521.15 1280.32 6011982.47 552757.29 10.00 2754.28 88.78 MWD 5700.00 88.81 35.71 3991.39 2541.75 1294.46 6012003.18 552771.28 10.00 2779.16 88.73 MWD 5725.00 88.87 38.21 3991.89 2561.72 1309.49 6012023.25 552786.17 10.00 2804.12 88.67 MWD 5750.00 88.93 40.71 3992.37 2581.02 1325.37 6012042.65 552801.92 10.00 2829.11 88.62 MWD 5775.00 89.00 43.21 3992.83 2599.60 1342.08 6012061.35 552818.50 10.00 2854.09 88.57 MWD 5800.00 89.06 45.71 3993.25 2617.44 1359.59 6012079.31 552835.89 10.00 2879.01 88.53 MWD 5825.00 89.13 48.21 3993.65 2634.50 1377.86 6012096.49 552854.03 10.00 2903.82 88.49 MWD 5850.00 89.20 50.71 3994.01 2650.75 1396.85 6012112.87 552872.91 10.00 2928.47 88.45 MWD 5875.00 89.27 53.21 3994.35 2666.15 1416.54 6012128.40 552892.49 10.00 2952.92 88.41 MWD 5900.00 89.34 55.71 3994.65 2680.68 1436.88 6012143.07 552912.73 10.00 2977.13 88.38 MWD 5925.00 89.41 58.21 3994.93 2694.31 1457.83 6012156.84 552933.59 10.00 3001.04 88.35 MWD 5950.00 89.48 60.71 3995.17 2707.02 1479.36 6012169.69 552955.02 10.00 3024.61 88.32 MWD 5975.00 89.56 63.21 3995.38 2718.77 1501.42 6012181.60 552977.00 10.00 3047.79 88.29 MWD 6000.00 89.63 65.70 3995.55 2729.55 1523.98 6012192.53 552999.48 10.00 3070.55 88.27 MWD 6025.00 89.71 68.20 3995.69 2739.33 1546.98 6012202.47 553022.41 10.00 3092.83 88.26 MWD 6050.00 89.79 70.70 3995.80 2748.11 1570.39 6012211.41 553045.75 10,00 3114.60 88.24 MWD 6055.49 89.80 71.25 3995.81 2749.89 1575.60 6012213.23 553050.96 9.99 3119.31 88.72 5 6075.00 89.72 73.20 3995.89 2755.85 1594,18 6012219.31 553069.49 10.00 3135.82 92.50 MWD 6100.00 89.61 75.70 3996.04 2762.55 1618.26 6012226.18 553093.52 10.00 3156.43 92.49 MWD 6125.00 89.50 78.19 3996.24 2768.19 1642.61 6012231.99 553117.83 10.00 3176.41 92.48 MWD 6150.00 89.39 80.69 3996.48 2772.77 1667.18 6012236.74 553142.37 10.00 3195.71 92.46 MWD 6175.00 89.29 83.19 3996.77 2776.28 1691.93 6012240.42 553167.09 10.00 3214.31 92.43 MWD 6200.00 89.18 85.69 3997.10 2778.70 1716.81 6012243.01 553191.95 10.00 3232.15 92.40 MWD 6225.00 89.08 88.19 3997.48 2780.04 1741.77 6012244.52 553216.90 10.00 3249.22 92.37 MWD 6250.00 88.98 90.68 3997.90 2780.28 1766.77 6012244.94 553241.89 10.00 3265.47 92.33 MWD 6275.00 88.88 93.18 3998.37 2779.44 1791.74 6012244.26 553266.87 10.00 3280.88 92.29 MWD 6300.00 88.78 95.68 3998.88 2777.51 1816.66 6012242.50 553291.80 10.00 3295.42 92.24 MWD 6325.00 88.69 98.18 3999.43 2774.49 1841.47 6012239.66 553316.63 10.00 3309.06 92.19 MWD 6350.00 88.60 100.68 4000.02 2770.40 1866.13 6012235.74 553341.30 10.00 3321.77 92.14 MWD 6375.00 88.51 103.18 4000.65 2765.23 1890.58 6012230.74 553365.79 10.00 3333.53 92.08 MWD 6400.00 88.42 105.68 4001.32 2759.00 1914.78 6012224.68 553390.03 10.00 3344.31 92.02 MWD ' Obp BP Amoco Bake ' flughes INTEQ Planning RepO '. BAKER HUGHES INTEQ C~y: BP Amoco Field:. : Milne Point, Site:. ' M Pt I Pad Well: MPI-04 ' , " '.Wellpath~ Plan#1 (CTD) MPI-04AL1 Bate: 5/11/2001 ,-i:,': ' Time:~, 14i57:10 Page: 4 ' Co-ordinate(NE) Reference: Well: MPI-04, True North, Yer~eal ('IW'I)) Re~ereaee::' . ', System: Mean Sea Level ' · SectiOn' (VS) Reference::: ,' · ',' '~::W~il (0;00N,0.00E,40.00Azi) Sum, eyCalCu]ationMe~o& ',MinimumCu~vatum .,. ,, Db: Oracle · Sum, ey 'MI) ' · lad A~m · SSTVD N/S F_./W .MaPN MapE ..' DLS VS. ',TFO Tool "it ... deg deg ft ft" It ft ft . :deg/100ft ff .deg 6425,00 88,34 108,18 4002,03 2751,73 1938,68 6012217,57 553413,98 10,00 3354,11 91,95 MWD 6450,00 88,26 110,68 4002,77 2743,42 1962,25 6012209,42 553437,60 10,00 3362,89 91,88 MWD 6475,00 88,18 113,18 4003,55 2734,09 1985,42 6012200.25 553460,84 10,00 3370,64 91,80 MWD 6500,00 88,11 115,68 4004,36 2723,75 2008,17 6012190,08 553483,66 10,00 3377,34 91,73 MWD 6525,00 88,04 118,18 4005,20 2712,44 2030,45 6012178,92 553506,01 10,00 3382,99 91.65 MWD 6550,00 87,97 120,68 4006,07 2700,16 2052,21 6012166,80 553527,85 10,00 3387,58 91,56 MWD 6575,00 87,91 123,18 4006,97 2686,95 2073,41 6012153,73 553549,14 10,00 3391,09 91,47 MWD 6600,00 87,85 125,68 4007,90 2672,83 2094,01 6012139,75 553569,84 10,00 3393,51 91,38 MWD 6625,00 87,80 128,18 4008,85 2657,82 2113,98 6012124,88 553589,91 10.00 3394,85 91,29 MWD 6650,00 87,75 130,68 4009,82 2641,95 2133,27 6012109,15 553609,31 10,00 3395,09 91,20 MWD 6655,49 87,74 131,23 4010,00 2638,34 2137,41 6012105,57 553613,47 9,94 3394,99 90,59 TD 3S CTD BOP Detail ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure -- 7" Riser Methanol Injection Otis 7" WLA Quick Connect ----- 7-1/16" ID, 5000 psi working pressure Ram Type Dual Gate BOPE Manual over Hydraulic TOT Flanged Fire Resistant Kelly Hose to Dual Choke Manifold HCR Annular BOP (Hyddl),7-1/16" ID 5000 psi working pressure IBlindlShear 12 3/8" Combi Pipe/Slil~ Kill line check valve Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpip, manifold 7-1/16" ID, 5000 psi working pressure Ram Type Dual Gate BOPE Manual over Hydraulic 2" Side outlets 2 718" Combi Pipe/Slip 2 318" Combi Pipe/Slip MOJ 12/29/00 Single Manual Master Valve XO Spool as necessary \ I THA I ' Tubing Spool 2 flanged gate valves 7" Annulus 9 5/8" Annulus H 1 881:5:5' o4,,~,~xo~ 00188133 VEN[X3R ALASKAO I LA CC DATE INVOICE ! CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET __ 041801 CKO41801H 100. O0 100. O0 PYMT ;OMMENTS' Pe~it to D~ill --ee HANDL: NO INST' S/H - Teeeie Hub)le X4&28 ~A~l-OqAq NE ATTACHED CHECK IS I" PAYMENT FOR ITEMS DESCRIBED ABOVE. ~ 100.O0 100. O0 B FIRST NATIONAL BANK OF ASHLAND No. H 1 881,'T~ P.:O;: A. A~mLIAT~ oF ITY BANK CONSOLIDATED COMMERCIAL ACCOUNT, : ,~2 ' ':':: ~i'.: ;'"'".'?00'" 1.88:1':33 PA' WELL PERMIT CHECKLIST FIELD & POOL .., , COMPANY ADMINISTRATION APPR D T WELL NAME/-,~ ~','~/-,/' PROGRAM: exp INIT CLASS ,c::~/~/*_.././ /" o/~2 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from ddlling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available-in ddlling unit ............ 8. If deviated, is wellbore plat included ............. ... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can.be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor string.provided ................... dev ~ redrll .X' serv wellbore seg ~' ann. disposal para req GEOL AREA ~'~::~ UNIT# ~ ///$z.{~ ON/OFF SHORE N GEOLOGY 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to.tie-in long string to surf csg .... .... 18. CMT will cover all known productive horizons ..... ' ..... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate weilbore separation proposed ....... ~ ...... 23. If diverter required, does it meet regulations .......... 24. 25. 26. 27. 28. 29. AEPR DATE 30. 31. Data presented on potential overpressure zones ....... Y ~ 32. Seismic analysis of shallow gas zones... .......... YiN 33. Seabed condition survey (if off-shore) ........... . . /Y N 34. Contact name/phone for weekly progress reports [exploratory onl/y] Y N Drilling.fluid program schematic & equip list adequate.. ~ . . ~ N . . BOPEs, do they meet regulation . ._.....<~,. .... ~ N ' ' ,.. ' ~ ~.~~--~ ,. BOPE press rating appropriate; test to Choke manifold complies w/APl RP-53 (May 845 ........ Work will occur without operation shutdown ........... Is presence of H2S gas probable ................. Y e.>~ 5, ~,,~::33~- ~.~e.C-~~, ~?,-~ .'~ \ % ~v.~' ~>~:~c._J ~/' ~ ~ % ~ c~ ~,G ~-~'-~ P~rmit can be issued wlo hydrogen sulfide measures ...... Y N ,/ . ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... Y N APPR DATE (B) will not contaminate freshWater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the Well used for diSposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) .will n0.t circumvent 20 AAC 25.252 or 20 AAC 25.412, Y N GEOLOGY: ENGINEERING: UICIAnnular COMMISSION: c:~msoffice\wordia n~iana\checklist (rev. 11/01fl00) ,. Comments/Instructions: -/,' " Well Histo.ry File APPENDIX Information of detailed nature that is not 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 file under APPENDIXi No 'special'effort has been made to chronologically organize this category of information. ,. **** REEL HEADER **** MWD 01/09/18 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD Ol/O9/17 168201 01 1.75" NaviGamma - Gamma Ray Slim *** LIS COMMENT RECORD *** Remark File Version 1.000 Extract File: glen.las -Version Information VERS. 1.20: WRAP. NO: -Well Information Block #MNEM.UNIT Data Type STRT.FT 4516.0000: STOP.FT 7207.0000: STEP.FT 0.5000: NULL. -999.2500: COMP. COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY.. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NYUMBER: -Parameter Information Block #MNEM.UNIT Value SECT. 33 : TOWN.N Ti 3N : RANG. R1 0E : PDAT. MSL : EPD .F 0 : LMF . RKB : FAPD.F 70 : DMF . KB : EKB .F 70 : EDF .F N/A : EGL .F N/A : CASE.F N/A : OS1 . DIRECTIONAL : -Remarks CWLS log ASCII Standard -VERSION 1.20 One line per frame Information Starting Depth Ending Depth Level Spacing Absent Value BP Exploration, Inc. MPI-04A-L1 Milne Point UNit 2942' SNL, 3876' WEL North Slope Alaska Baker Hughes INTEQ 1.75" NaviGamma - Gamma Ray 09-Jul-01 500292206860 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) Ail depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) and Resistivity data (RACLX,RPCHX,RACHX, RPCLX) presented is realtime data. (3) Well MPI-04A-L1 was drilled as a sidetrack off Well MPI-04. (4) The sidetrack began on MWD Run #1 at 4516' MD (3910' SSTVD). (4) Baker Hughes INTEQ on Run #1 and #2 utilized the Orient Express with Ultra Multiple Propagation Resistivity (USMPR) services from 4516' MD (3910' SSTVD) to 7207' MD (4000' SSTVD) . (5) The interval from 7180' MD (3999' SSTVD) to 7207' MD (4000' SSTVD) was not logged due to sensor to bit offset. (6) The data presented here is final. Gamma Ray MWD is the PDC (Primary Depth Control) curve for this borehcle, as per BPX instructions.No depth shift has been applied. (7) A Magnetic Declination correction of 26.25 degrees has been applied to the Directional Surveys. MNEMONICS: GR3IX ROPS TVD TCDX PJtCLX RPCLX RACHX RPCHX = Gamma Ray MWD-API [MWD] (MWD-API units) = Rate of Penetration, feet/hour = Subsea True Vertical Depth (SSTVD), (feet) = Downhole Temperature [MWD], (deg F) = Resistivity Compensated 400 kHz Attenuation Resistivity Borehole Corrected [MWD], (ohm-m) = Resistivity Compensated 400 kHz Phase Difference Resistivity Borehole Corrected [MWD], (ohm-m) = Resistivity Compensated 2 MHz Attenuation Resistivity Borehole Corrected [MWD], (ohm-m) = Resistivity Compensated 2 MHz Phase Difference Resistivity Borehole Corrected [MWD], (ohm-m) BOREHOLE AND ENVIRONMENTAL CORRECTIONS: Gamma Ray: Normalized for tool size and sensor type.No correction has been applied for bit size or mud potassium content. Resistivity: Normalized for tool size and mud resistivity. Compensated for temperature.No correction has been applied for formation dielectric properties. SENSOR OFFSETS: RUN GAMMA DIRECTIONAL N/A N/A N/A N/A N/A N/A CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT N/A, N/A, ~ N/A No Depth Shift applied. Gamma Ray MWD is the PDC. Tape Subfile: 1 88 records... Minimum record length: 8 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN BP Exploration, Inc. WN MPI-04A-L1 FN Milne Point Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented is the field raw data. 2. The data has been not depth shifted. 3. Gamma Ray MWD is the Primary Depth Control curve *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP .................................................... 1 GR GRAX 0 0 2 ROP ROPS 0 0 3 RACH RACHX 0 0 4 RACL RACLX 0 0 5 RPCH RPCHX 0 0 6 TCD RPCLX 0 0 7 TCDX TCDX 0 0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 31 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 2 ROP MWD 68 1 3 RACH COMP 68 1 4 RACL COMP 68 1 5 RPCH COMP 68 1 6 TCD COMP 68 1 7 TCDX COMP 68 1 API F/HR Total Data Records: 174 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 4 4 ....... 28 Tape File Start Depth = 4516.000000 Tape File End Depth = 7207.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 188 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 0~/0s/17 168201 01 **** REEL TRAILER **** MWD o1/o9/1s BHI 01 Tape Subfile: 3 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes Tape Subfile 2 DEPTH RPCH 4516.0000 3.4440 4516.5000 3.4880 4600.0000 10.6380 4700.0000 6.6390 4800.0000 36.1800 4900.0000 34.9520 5000.0000 31.0790 5100.0000 28.8240 5200.0000 12.2230 5300.0000 12.5410 5400.0000 18.1820 5500.0000 32.4090 5600.0000 31.0240 5700.0000 34.6920 5800.0000 28.0700 5900.0000 39.7150 6000.0000 23.5120 6100.0000 16.1530 6200.0000 23.7730 6300.0000 32.9840 6400.0000 25.5170 6500.0000 29.5630 6600.0000 28.5780 6700.0000 is type: LIS GR TCD -999.2500 5.9400 -999.2500 4.3060 74.1260 9.9170 91.5570 6.8100 72.8030 31.2440 72.3080 29.8600 70.9030 28.3220 67.2050 26.6240 87.0670 13.3300 68.7160 12.9730 87.2780 18.5970 78.3990 29.5000 67.6340 26.3330 68.2110 31.9660 70.5900 25.7640 81.1720 35.4720 80.8980 25.3720 85.4270 15.5420 77.3060 24.0800 69.4190 31.5000 78.6340 23.8370 75.9000 27.6740 75.0210 28.9980 69.5670 ROP TCDX -999.2500 -999.2500 -999.2500 -999.2500 102.7050 69.8000 128.2230 73.4000 139.5000 75.2000 193.6230 73.4000 213.8710 77.0000 147.6380 77.0000 261.4020 78.8000 334.7250 78.8000 235.1620 78.8000 146.4180 82.4000 147.0250 82.4000 236,2200 82.4000 21!.5950 78.8000 294.0500 78.8000 296.4910 78.8000 231.5890 78.80O0 264.3770 80.6000 259.2980 80.6000 163.0730 82.4000 197.3080 78.8000 283.9190 80.6000 48.7930 RACH 2.8280 3.1380 9.5190 7.0180 29.4600 28.5360 28.3560 29.8390 15 6100 14 7960 22 2700 31 7270 23 8040 34 6640 25 9280 34 5500 29 8500 13 6300 25 2730 31 4290 22 5890 28 5720 36 2380 32 4980 RACL 1610 6920 9 6370 6 7420 20 9310 20 6690 20 9730 19 2660 14 3220 12 9110 16 8840 20 3170 17 6340 21 8880 19 2410 23 1410 26 2300 17 0750 21 7770 23 0990 19 3740 22 1870 24 9640 22 2360 35.1000 32.0310 79.1600 6800.0000 70.2780 294.0550 39.0290 34.7040 82.4000 6900.0000 100.5760 8.7090 15.9350 18.8620 82.4000 7000.0000 64.3430 143.2190 40.7340 36.8030 84.2000 7100.0000 51.9540 10.8010 52.1640 32.6470 83.9750 7200.0000 -999.2500 114.4690 -999.2500 -999.2500 86.0000 7207.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 4516.000000 Tape File End Depth = 7207.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet 36 5650 27 3120 36 5670 23 6940 -999 2500 -999 2500 24 2940 24 3910 24 9690 17 3960 -999 2500 -999 2500
