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201-137
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: Nitrogen Fill Clean-out 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 13,170 feet N/A feet true vertical 3,644 feet 12,038 -Fill feet Effective Depth measured 12,038 OB feet feet true vertical 3,654 feet feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 3-1/2" 9.3# / L-80 / Hyd 563 & EUE 3,563' 2,454' Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# / L-80 / NS-CT 3,586' 2,458' 7"x4.5" Baker Prem. 7"x4.5" Baker S-3 Perm. Packers and SSSV (type, measured and true vertical depth) Baker ZXP LTP 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: 10,072, 10,215 & 10,567 3,530, 3,565 & 3,647 323-368 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 100 3,644' 3,695' 7,500psi 7,500psi 3,580psi 7,240psi 8,430psi 8,430psi 3,676' BurstMD 101' 0 Size 101' 2,730' 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 00 0 3,2970 3,387 TVD 4-1/2" 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 201-137 50-029-23033-00-00 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 ADL0025517 & ADL0025906 MILNE POINT / SCHRADER BLUFF OIL MILNE PT UNIT I-11 Plugs Junk measured measured Length Liner "B" 2,593' 2,364' Casing Conductor 13,124' 13,170' 10,748' 2,730'Surface Intermediate Liner "A" 10,748' 20" 10-3/4" 7" 101' 2,730' N/A Collapse N/A 2,090psi 5,410psi Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 11:52 am, Feb 27, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.02.23 13:45:03 - 09'00' Taylor Wellman (2143) DSR-2/28/24WCB 2024-07-08 RBDMS JSB 022924 _____________________________________________________________________________________ Updated By: TDF 1/30/2024 SCHEMATIC Milne Point Unit Well: MPU I-11 Last Completed: 9/17/2022 PTD: 201-137 TD =13,170’(MD) / TD =3,644’(TVD) 20” Orig. DF Elev. = 64.70’ / Orig. GL Elev.= 34.70’ 7” 2 3 4 8 5 & 6 7 “OA” Lateral PBTD =13,170’(MD) / PBTD =3,644’(TVD) 1 “OB”Lateral 10-3/4” ID = 3.725” 9 10 11 12 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 94 / H-40 19.124 Surface 101' 0.355 10-3/4” Surface 45.5 / L-80 / BTC 9.950 Surface 2,730’ 0.0960 7" Intermediate 26 / L-80 / Hydril 521 6.276 Surface 10,748’ 0.0383 4-1/2” Slotted Liner “A” 12.6 / L-80 / IBT 3.958 10,406’ 12,999’ N/A 4-1/2” Slotted Liner “B” 12.6 / L-80 / IBT 3.958 10,761’ 13,125’ N/A TUBING DETAIL 3-1/2” Tubing 9.3 / L-80 / Hydril 563 2.992 Surface 4,312’ 0.0087 3-1/2” Tubing 9.3 / L-80 / EUE 8rd 2.992 4,312’ 10,204’ 0.0087 4-1/2” Tubing 12.6 / L-80 / NS-CT 3.958 10,184’ 10,303’ 0.0152 JEWELRY DETAIL No Depth Item 1 9,964’ Champion X Forward Circulating Ported Pup (min ID: 2.668”)87 bbls 2 10,019’ BHP Gauge 3 10,072’ 7” x 4.5” Baker Premier Packer 4 10,136’ 2.875” XN Nipple (2.250” No-Go) 5 10,191’ 4.5” Northern Solutions Production Overshot Guide –Btm @ 10,204’ 6 10,191’ Top of 4-1/2” TBG Cut 7 10,215’ Baker S-3 Permanent Packer 7” x 4.5” 8 10,239’ 4.5” XN-Nipple –3.725” No Go 9 10,302’ 4.5” TC-II WLEG –Bottom @ 10,303’ 10 10,336’ Baker Hook Wall, Hanger above 7” Window 11 10,360’ Baker Hook Wall, Hanger outside 7” Window 12 10,567’ Baker ZXP Liner Top Packer Notes: Nabors 22E RKB to THF = 28.1’; Nabors 3S RKB to THF = 21.5’' = 6.6’ All depths are corrected back to original RKB. OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset (Approx) in 30” Hole 10-3/4” Cmt w/ 600 sx of PF “L”, 440 sx Class “G” in 13-1/2” Hole 7” Cmt w/ 1,400sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 500’ MD 75 to 85 Deg. 2,900’ – 10,300’ Max Hole Angle = 86 deg. @ 4,806’ MD GENERAL WELL INFO API: 50-029-23033-00-00 Drilled and Completed by Nabors 22E - 10/06/2001 Conversion to Jet Pump (Nabors 3ES) – 02/02/2009 ESP Install by ASR – 11/15/2020 Convert to FC Jet Pump by ASR#1 – 9/17/2022 Nitrogen Fill Clean-out by Coil – 8/23/2023 LATERAL WINDOW DETAIL Window in 7” Casing @ 10,345’ to 10,357’ Well Angle @ Window =77 Deg. WELLHEAD DETAIL Tree 2-9/16” – 5M FMC Wellhead 11” x 4.5” 5M Gen. 6 w/ 4.5” TC-II T&B Tubing Hanger CIW “H” BPV Profile Hole Last Tag:OB FCO Tag: 12,038’ on 8/16/23 OA has never been FCO Well Name Rig API Number Well Permit Number Start Date End Date MP I-11 Slickline 50-029-23033-00-00 201-137 8/5/2023 1/22/2024 No operations to report. ATTEMPT TO PULL CHECK VALVE FROM 9,964' MD, SIT DOWN HIGH @ 9,924' SLM (no recovery, collett slightly bent in). WELL S/I ON DEPARTURE. 8/5/2023 - Saturday T/I/O = 200/200/120 Freeze Protect, Pumped 125 bbls criesel down Tubing up IA to production, U-Tube TxIA, FWP = 500/225/140. 8/8/2023 - Tuesday 8/6/2023 - Sunday No operations to report. 8/7/2023 - Monday 8/4/2023 - Friday No operations to report. 8/2/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 8/3/2023 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP I-11 Slickline 50-029-23033-00-00 201-137 8/4/2023 1/22/2024 8/11/2023 - Friday CTU#9 1.75" CT. Job Scope: Pull Check Valve & CSV / FCO w/ N2. Rig up CTU. PT CTC to 3400 psi. MU FCO tools. Function Test BOPE. Troubleshooting hardline certification issues. 8/9/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 8/10/2023 - Thursday No operations to report. Hydraulic P-14 Pump Replaced. RIH w/ 1.75" Slim DJN. Able to RIH w/ closed choke at ~ 25psi whp. See bobbles at 10340' (upper window) and 10360' (upper window). Drift down to 10500' with no issues. Puh and unable to pass 10358' (lower window). After multiple attempts, finally got past pumping down the Coil surging the pump. Tag high at 10435' like were pumping fill downhole. Park at 10400'. Establish circulation with Slick KCL. Getting ~ 68% - 78% returns. Rig up N2 pump & transport. Come online w/ N2 starting at 600 scf/min + 1.5 bpm staying below 10358'. Return rate increased to over 100%. Attempt to RIH and start FCO from 10400'. Unable to RIH due to Coil lock up. Get btms up volume returned. Shut down N2. Still unable to RIH. Puh to 9900'. RBIH. Tag at 10358' (lower window junction). Unable to pass. Weights are ~ 3k heavier and ~ 3k lighter when Rih. Seeing more drag after pumping N2. Chase ooh w/ Slick KCL. Order Safelube fluids. Nozzle has metal mark on face of nozzle. Run 1.75" JSN (more of a beveled nozzle). Circulate well out with safelube. RIH and stack weight @ 11287'. Able to work down to 11397' appears we are frictioning out not tagging fill. PT PCE & Hardline 250psi Low / 4000psi High. Test DHCV's. RIH w/ 1.75" Down Jet Nozzle. Take pipe displacement returns while Rih. Tag at 9968'. Establish circulation at 1.7bpm. Tag same depth at 9968', not making any hole. Appear to be on the gutless check valve. Reciprocate on top of check valve. Pump 5.5 bbl gel pill. Chase ooh. 1:1 returns. Make up Baker 3" G- Spear Fishing BHA + Slickline Bait Sub Bar-bell Assy w/ Collet Pulling Tool. Tag at 9972'. Re-Tag same depth. Pooh. Did not retrieve gutted check vlave. RIH w/ 1.69" venturi mule shoe. 8/12/2023 - Saturday Finish BOP's. RIH w/ 1.80" JSN. Take returns while RIH. Tag at 10066' (packer). Bobble through. Tag Cat Standing Valve at 10130'. Jet on Cat SV. Pump 6 bbl gel pill. Chase ooh. RIH w/ 2" G-Spear Fishing BHA. Tag/Latch at 10127'. Pull ~ 3k over, pull free. Pump Slick KCL down backside. Whp increased to 600psi then broke over at 1bpm. Pooh. Recovered Cat Standing Valve w/ Slotted Screen Sub. Screen Sub packed off with fine sand. Remove Baker Tools. RIH w/ 1.75" DJN. Coil unit unable to RIH due to issues with hydraulic pump. POOH, mechanics to come replace pump. 8/15/2023 - Tuesday 8/13/2023 - Sunday POOH w/ Venturi. Venturi empty. Re-run Baker 3" G-Spear Fishing BHA + Slickline Bait Sub Bar-bell Assy w/ Collet Pulling Tool. Tag at 9964'. Appear to be at higher depth due to pipe stretch on new Coil. Tag fish3 times. Pooh. Did not recover blank check valve. One collet badly bent. Appears the Kobe Knockout is in the check valve body. RIH w/ 3" G-Spear Fishing BHA + Slickline Bait Sub Bar-bell Assy w/ Kobe Knockout Prong. Tag at 9964'. RIH 100fpm and stack down on check valve 5 times. Pooh. At surface, Tattle Tail pin not sheared. Metal marks on one side of bottom of prong. Appears there maybe trash inside the check valve preventing getting deep enough. Discuss w/ OE. Re-run Collet Pulling Tool (last attempt). Retrieved Gutless check valve (Had Kobe Knockout Installed and was not sheared) Stack down and begin BOP testing. 8/14/2023 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP I-11 Slickline 50-029-23033-00-00 201-137 8/4/2023 1/22/2024 8/18/2023 - Friday No operations to report. 8/16/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Bullhead Safelube down backside. Work Coil down to 11,458'. Fighting Coil lock up. Pump Gel sweep and chase ooh. Pump down backside and work Coil down to 11,500'. Come online with N2 and Slick KCL. Pump Gel pill and circulate btms up returns. Shut down N2 and circulate Safelube back around. Drift down while pumping down the backside. Coil fighting lock up trying to Rih. Rih weights ~ - 3k to -5k. Stack out at 11,502'. Increase rate down backside to 2.8 bpm at 900psi Whp. RIH to 11,630', swap to pumping down Coil. Wiper up to 9,900'. RBIH. Able to Dry Drift to 12,033'. Lock up. Pump Gel Sweep wiper up to 9,000'. Circulate gel out. RBIH dry to12,033', stack weight, likely lock up. Pump Gel Sweep and wiper up to 9,000'. Getting 80% to 100% returns with fluid only, no N2. Re-drift. Weights worse this time. Pumping down backside helps prevent lock up. Lock up at a final depth of 12,038'. Discuss with OE, decide to call this depth good. Pump N2 at 600 scf/min + 1.9 bpm ( 2.5 bpm equivalent) through Liner. Reduce liquid rate to 1.2 bpm + 600 scf/min inside Tbg. Chase out to surface. Change Pack-offs Chain Inj - found Lower Idler Sprocket Barring bad. FP well w/ 33 bbls diesel. RDMO CTU 9 to SLB Yard. 8/17/2023 - Thursday No operations to report. No operations to report. MIRU. MU BOT Tool and Cat Standing valve. RIH and tagged 8,332' ctmd. Attempted to pump down the backside, no luck, POOH. Cat left in hole. RBIH w/ BOT fishing tools to recover the cat. Thru 8,332'. Tag @ 10,075' twice. POOH w/ CSV - seals good. RIH w/ 2.2" JSN. 8/19/2023 - Saturday No operations to report. 8/22/2023 - Tuesday 8/20/2023 - Sunday Cont RIH w/ 2.2" JSN clean to 10,160'. PUH Jet thru Jewelry from 9,950' to 10,290' (stacked @ 10,110', 10,131', & 10,233' CTM). Dry Drift to 10,170' clean. POOH. BD 2.2" JSN. MU BOT 2"GS w/ CSV. RIH. Tag XN @ 10,129' CTM / 10,140' Mech. Pump off CSV. Pressures indicate it's set. POOH. Drop gutted check on the swab, MU SLB 2.2 JSN and chase check in hole. Tag 8287' ctmd. Tried jetting, putting the well on injection down the tubing up the IA, pressuring the full system up and dumping the tubing to tank (try to fluff) with no success. POOH. RDMO so the rig can come in. Well not freeze protected. 8/21/2023 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP I-11 Slickline 50-029-23033-00-00 201-137 8/5/2023 1/22/2024 No operations to report. No operations to report. 8/26/2023 - Saturday No operations to report. 8/29/2023 - Tuesday 8/27/2023 - Sunday No operations to report. 8/28/2023 - Monday 8/25/2023 - Friday No operations to report. 8/23/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary T/I/O=100/104/100 Freeze protect (Drill on MPI-32) Pumped 125 bbls criesel down IA up TBG taking returns to production. U- Tube for 1 hour. Pumped 3 bbls criesel down prod lat and 3 bbls criesel down test lat. Freeze protected power fluid lat with 3 bbls criesel.Lats open per DSO. Final Whps=360/360/225. 8/24/2023 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP I-11 Slickline 50-029-23033-00-00 201-137 8/5/2023 1/22/2024 1/19/2024 - Friday No operations to report. 1/17/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 1/18/2024 - Thursday No operations to report. No operations to report. No operations to report. 1/20/2024 - Saturday WELL S/I ON ARRIVAL. BEGIN R/U .125 CARBON, 1-7/8'' RS, 6' X 2-1/8'' RS (2.60'' wheels), QC, KJ, 5' X 2-1/8'' RS (2.60'' wheels), QC, OJ, QC, KJ, LSS, CHECK ALL ROLL PINS, TIGHTEN ALL CONN. w/ WRENCHES, PT= 250L / 3500H. RAN 2.75'' BLIND BOX, TOOLS STOP FALLING @ 2,410' SLM, LRS PUMP CRIESEL @ 1.5 bbl min, TOOLS FALLING 30 - 40 fpm, PUMPED 42 bbls, TOOLS STOP FALLING @ 3905' SLM, PULLING HEAVY 1200# @ 50 fpm. WELL S/I ON DEPARTURE. 1/23/2024 - Tuesday 1/21/2024 - Sunday No operations to report. 1/22/2024 - Monday 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: Nitrogen Fill Clean-out 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): 13,170'N/A Casing Collapse Conductor N/A Surface 2,090psi Intermediate 5,410psi Liner "A"7,500psi Liner "B"7,500psi 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: 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: 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 3-1/2" 9.3# / L-80 / Hyd 563 & EUE 3,563' 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Brian.Glasheen@hilcorp.com 907-564-5277 Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: 12.6# / L-80 / NS-CT 3,586' 7/15/2023 7” x 4.5” Baker Premier, 7” x 4.5” Baker S-3 Perm. & Backer ZXP LTP and N/A 10,072 MD/ 3,530 TVD, 10,215 MD/ 3,565 TVD & 10,567 MD/ 3,647 TVD and N/A See Schematic See Schematic 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025517 & ADL0025906 201-137 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23033-00-00 Hilcorp Alaska LLC SCHRADER BLUFF OIL N/A C.O. 477.05 MILNE PT UNIT I-11 Length Size Proposed Pools: 101' 101' TVD Burst PRESENT WELL CONDITION SUMMARY 3,644' 13,170' 3,644' 1,095 N/A 101' 20" MILNE POINT 8,430psi MD N/A 8,430psi 3,580psi 7,240psi 2,730' 3,676' 3,644' 2,730' 10,748' 3,695'13,170' 13,124' Perforation Depth MD (ft): 4-1/2"2,593' 2,364' 4-1/2" 10-3/4" 7" 2,730' 10,748' Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:27 pm, Jun 30, 2023 323-368 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.06.30 14:50:01 - 08'00' Taylor Wellman (2143) MDG 7/12/2023MGR06JULY23 DSR-7/6/23 10-404 GCW 07/13/2023 07/13/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.07.13 15:23:16 -05'00' RBDMS JSB 071323 N2 FCO Well: MPU I-11 Well Name:MPU I-11 API Number:50-029-23033-00-00 Current Status:SI Oil Well Pad:I-Pad Estimated Start Date:July 15th, 2023 Rig:CT Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:201-137 First Call Engineer:Brian Glasheen 9075451144 Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) AFE Number:TBD Job Type:Coil N2 FCO Current Bottom Hole Pressure:1,450 psi @ 3,547’ TVD Downhole Gauge:|7.9 PPG Maximum Expected BHP:1,450 psi @ 3,547’ TVD Downhole Gauge:|7.9 PPG MPSP:1,095 psi Gas Column Gradient (0.1 psi/ft) Max Inclination 86° @ 4,806’ MD High Inclination begins at 2,400’ MD Max Dogleg:8.6°/100ft @ 1,988’ MD Brief Well Summary: MPU producer I-11 was drilled in 2001 and completed as a Schrader Bluff dual lateral in the Schrader Bluff OB and OA sands. From the initial well development, the productivity index of the sands was not as expected. The first two ESP completions were planning for 1,500 to 3,000 BPD of initial rate; however, the production was less than 500 BPD, leading to shaft breaks and overheating of the oversized ESPs. In 2009, the completion was changed to a reverse circulating jet pump design, but due to the extended reach and high deviation of the well, coiled tubing was required for all jet pump change-outs. In November 2020 the well was converted to an ESP. The ESP was unable to lift fluids and the shaft is suspected to have sheared. In 2022 ASR converted well from a ESP to a forward circulating JP. Notes Regarding the Well & Design x Converted to forward circulating JP in 2022 x Well has likely sanded off below rock screens. Procedure: SL: 1. Attempt to RIH and pull gutted check valve at 9964’ MD while pumping down prior to coil arrival. a. This will be a test to see if we can retrieve the JP via SL and avoid using a check valve to allow us to backflush. COIL TUBING: 1. MIRU 1.75” Coiled Tubing Unit and spot ancillary equipment. 2. Pressure test BOPE to 4,000 psi Hi 250 Low, 10 min Hi, 5 min Low each test. a. if within the standard 7-day test BOPE test period for Milne Point, a full body test and function test of the rams is sufficient. b. Each subsequent test of the lubricator will be to 4,000 psi Hi 250 Low to confirm no leaks. 3. RIH and pull gutted check valve from 9964’ MD ( Assuming SL could not get down) 4. RIH pull Cat standing valve at 10,136’ MD 5. RIH with 1.75’’ JSN and GR/CCL and perform a FCO using N2 to 13,120’ taking returns to tanks or portable separator. N2 FCO Well: MPU I-11 a. Note the IA will be in communication with TBG during the job. Add a N2 cap to the IA to allow pressure monitoring during the entirety of the job. b. Target no more than 1000 TGLR during the job. c. RIH and dry tag sand. Its likely built up just below the rockscreen. d. Follow the PE manual best practices for FCO. e. Start taking bites with 500 mmscf/d and increase/ decrease to target 1000 TGLR. f. In March Coil reached mechanical lock up at 12059’ However we were not using N2 and could have been stacking fill infront of coil. 6. Set CAT standing valve with no screens at 10,136’ MD. 7. Set gutted check valve 9964’ MD 8. Drop 12B Jet pump and confirm a good set. If JP does not land in BHA call OE to troubleshoot. 9. POOH with coil freeze protecting the TBG from 2,500’ MD to surface. 10. RD Coil. 11. Turn well over to production via handover form. Attachments: 1. As-built Schematic 2. Coil BOPE Schematic 3. Nitrogen Operations Procedure _____________________________________________________________________________________ Updated By: TDF 10/11/2022 SCHEMATIC Milne Point Unit Well: MPU I-11 Last Completed: 9/17/2022 PTD: 201-137 TD =13,170’(MD) / TD =3,644’(TVD) 20” Orig. DF Elev. = 64.70’ / Orig. GL Elev.= 34.70’ 7” 2 3 4 8 5 & 6 7 “OA” Lateral PBTD =13,170’(MD) / PBTD =3,644’(TVD) 1 “OB”Lateral 10-3/4” ID = 3.725” 9 10 11 12 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 94 / H-40 19.124 Surface 101' 0.355 10-3/4” Surface 45.5 / L-80 / BTC 9.950 Surface 2,730’ 0.0960 7" Intermediate 26 / L-80 / Hydril 521 6.276 Surface 10,748’ 0.0383 4-1/2” Slotted Liner “A” 12.6 / L-80 / IBT 3.958 10,406’ 12,999’ N/A 4-1/2” Slotted Liner “B” 12.6 / L-80 / IBT 3.958 10,761’ 13,125’ N/A TUBING DETAIL 3-1/2” Tubing 9.3 / L-80 / Hydril 563 2.992 Surface 4,312’ 0.0087 3-1/2” Tubing 9.3 / L-80 / EUE 8rd 2.992 4,312’ 10,204’ 0.0087 4-1/2” Tubing 12.6 / L-80 / NS-CT 3.958 10,184’ 10,303’ 0.0152 JEWELRY DETAIL No Depth Item 1 9,964’ Champion X Forward Circulating Valve w/ Blanking Sleeve (min ID: 2.668”) 2 10,019’ BHP Gauge 3 10,072’ 7” x 4.5” Baker Premier Packer 4 10,136’ 2.875” XN Nipple (2.250” No-Go) 5 10,191’ 4.5” Northern Solutions Production Overshot Guide –Btm @ 10,204’ 6 10,191’ Top of 4-1/2” TBG Cut 7 10,215’ Baker S-3 Permanent Packer 7” x 4.5” 8 10,239’ 4.5” XN-Nipple –3.725” No Go 9 10,302’ 4.5” TC-II WLEG –Bottom @ 10,303’ 10 10,336’ Baker Hook Wall, Hanger above 7” Window 11 10,360’ Baker Hook Wall, Hanger outside 7” Window 12 10,567’ Baker ZXP Liner Top Packer Notes: Nabors 22E RKB to THF = 28.1’; Nabors 3S RKB to THF = 21.5’' = 6.6’ All depths are corrected back to original RKB. OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset (Approx) in 30” Hole 10-3/4” Cmt w/ 600 sx of PF “L”, 440 sx Class “G” in 13-1/2” Hole 7” Cmt w/ 1,400sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 500’ MD 75 to 85 Deg. 2,900’ – 10,300’ Max Hole Angle = 86 deg. @ 4,806’ MD GENERAL WELL INFO API: 50-029-23033-00-00 Drilled and Completed by Nabors 22E - 10/06/2001 Conversion to Jet Pump (Nabors 3ES) – 02/02/2009 ESP Install by ASR – 11/15/2020 Convert to FC Jet Pump by ASR#1 – 9/17/2022 LATERAL WINDOW DETAIL Window in 7” Casing @ 10,345’ to 10,357’ Well Angle @ Window =77 Deg. WELLHEAD DETAIL Tree 2-9/16” – 5M FMC Wellhead 11” x 4.5” 5M Gen. 6 w/ 4.5” TC-II T&B Tubing Hanger CIW “H” BPV Profile Hole Last Tag:OB FCO Tag: 12,904’ on 4/17/18 OA has never been FCO SLB Stack Drawing Not Drawn To Scale--- For Reference Only BOP rams dressed for 1.75" Coiled Tubing. Blind/Shear ram blades: Texas Oil Tools NOV – 4.06" Shear seal Rams w/ Viton Seals, H2S -50F Flanged Plug Valve (Manual) Flanged Plug Valve (Manual) Kill Port Manual ram locking wheel CT BOP’s controlled by Coiled Tubing Unit with ~100 gal accumulator system Well Floor HR 580 Injector Head with 72" Gooseneck 4.06" 10K Top Door Stripper – 1.75" Swab Valve 4.06" 10K Quad BOP C/W 2.06" 10K Flanged Plug Valves x 2" 1502 SSV 5K x 10K C062/CB44 Crossover Master Valve 7.06" 5K /4.06"10K Lubricator Section (Manual)(Manual) Slip & Pipe Ram dressed with 1.75" Inserts IA and OA Gate Valves Blind & Shear Ram Slip Ram Kill Port Blind & Shear Ram Pipe Ram Pump In Sub with 2 Flanged Gate Valves 2' 10K to 5K Crossover Provided by client STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) 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^WƐŚĞĂǀĞ͕ ƌŝŐƵƉƚĞĐŚǁŝƌĞƐŚĞĂǀĞĨŽƌƵƉĐŽŵŝŶŐĐŽŵƉůĞƚŝŽŶƌƵŶ͘^ĞƌǀŝĐĞƌŝŐ͕ĐŚĞĐŬĨůƵŝĚƐΘWĞƌĨŽƌŵŝŶƐƉĞĐƚŝŽŶƐ͘ůĞĂƌƌŝŐĨůŽŽƌŽĨĚĞďƌŝƐ ĨƌŽŵ ^WĚĞͲĐŽŵƉůĞƚŝŽŶ͕ĐůĞĂŶĐƌƵĚĞƐŽĂŬĞĚƌŝŐƚŽŽůƐΘĞƋƵŝƉŵĞŶƚ͘ŚĂŶŐĞŚĂŶĚůŝŶŐĞƋƵŝƉŵĞŶƚĨŽƌϯͲϭͬϮΗǁŽƌŬƐƚƌŝŶŐ͘ZĂĐŬ ΘƚĂůůLJǁŽƌŬƐƚƌŝŶŐ͘Wͬh,ĂƐƉĞƌĨŝƐŚŝŶŐƌĞƉ͘DͬhƐŚŝƌƚĞĚĚƌĞƐƐŽĨĨŵŝůů͕ϰͲϯͬϰΗďƵŵƉĞƌƐƵď͕ϰͲϯͬϰΗŽŝůũĂƌƐΘϲdžϰͲϯͬϰΗ ĚƌŝůůĐŽůůĂƌƐ͘dͬϮϯϬΖ͘Z/,ǁͬĚƌĞƐƐŽĨĨĂƐƐLJ͘ŽŶϯͲϭͬϮΗW&ͬϮϯϬΖdͬϲ͕ϳϭϱΖ͘WĞƌĨŽƌŵŬŝĐŬǁŚŝůĞƚƌŝƉƉŝŶŐĚƌŝůůΘŚŽůĚĂĨƚĞƌĂĐƚŝŽŶ ƌĞǀŝĞǁ͘ŽŶΖƚZ/,͘ tĞůů<ŝůů;WƌĞZtKͿ;WƌĞƐƐƵƌĞƚĞƐƚĞƋƵŝƉŵĞŶƚƚŽϮϱϬͬϮϱϬϬƉƐŝͿůĞĞĚŐĂƐŽĨĨǁĞůů;ůů&ůƵŝĚͿWƵŵƉϭϬϭϬϬΎƐůĂŶĚϰϱϬďďůƐ ϭϰϬΎǁĂƚĞƌĚŽǁŶdďŐƵƉ/ƚŽƚĂŶŬ͘;'ĞƚƚŝŶŐKŶĞƚŽKŶĞƌĞƚƵƌŶƐͿƵůůŚĞĂĚϭϬ͘ϯďďůƐǁĂƚĞƌĚŽǁŶdďŐĂŶĚϱϬďďůƐĚŽǁŶ/͘ WƵŵƉϭďďůƐůĚŽǁŶK͘&ůƵƐŚ,WůŝŶĞƚŽƚĂŶŬǁͬϯďďůƐϲϬͬϰϬ͘;tĞůůŶŽƚĞĂĚͿ ϵͬϭϬͬϮϬϮϮͲ^ĂƚƵƌĚĂLJ &ŝŶŝƐŚƚĞƐƚŝŶŐKW ǁͬϮͲϯͬϴΗŽŶĨŝdžĞĚƌĂŵƐ͕ϮͲϳͬϴΗĂŶĚϯͲϭͬϮΗŽŶƚŚĞsZƐĂƐƉĞƌĂƉƉƌŽǀĞƐƵŶĚƌLJ͕ůůƚĞƐƚƐƉĞƌĨŽƌŵϮϱϬƉƐŝ ůŽǁϮϱϬϬƉƐŝŚŝŐŚ&ͬϱͬϱĐŚĂƌƚĞĚŵŝŶƐ͘^ƚĂƚĞŝŶƐƉĞĐƚŽƌƉƌĞƐĞŶƚ͘ZŝŐĚŽǁŶƚĞƐƚĞƋƵŝƉŵĞŶƚ͘ůŽǁůŝŶĞƐ͘ƌŝŐƵƉƐŚĞĂǀĞĂŶĚ ĞůĞƉŚĂŶƚƚƌƵŶŬ͘ƉƵůůd^ƉůƵŐĂŶĚWs͘WͬhDͬhůĂŶĚŝŶŐũŽŝŶƚ͘K>^͘WƵůů,ĂŶŐĞƌƚŽƚŚĞĨůŽŽƌ͘KĨĨƐĞĂƚĂƚϯϳ<͘ďƌŽŬĞŽǀĞƌĂƚ ϰϯ<͘hƉǁĞŝŐŚƚǁĂƐϯϴ<͘ƵƚĐĂďůĞĂƚƚĂĐŚƚŽƌŽƉĞ͘>ĂLJĚŽǁŶŚĂŶŐĞƌ͘ŚĂŶŐĞĞůĞǀĂƚŽƌƐƚŽϮͲϯͬϴ͘ƐƚĂƌƚƚŽWKK,͘&ͬϵ͕ϲϮϯΖdͬ ϵ͕ϰϱϴΖ͘ZŝŐƐĞƌǀŝĐĞ͘ĐŚĞĐŬĂůůĨůƵŝĚƐĂŶĚĞƋƵŝƉŵĞŶƚ͘dƌŽƵďůĞƐŚŽŽƚƐůŝƉƐ͘ƌĞƉůĂĐĞƐŽůĞŶŽŝĚŽŶǀĂůǀĞďĂŶŬ͘ŽŶΖƚƚͬWKK,ǁͬϮͲ ϯͬϴΗϰ͘ϳηĞƵĞ ^WĐŽŵƉůĞƚŝŽŶ&ͬϵ͕ϰϱϴΖdͬϯϳϬϬΖ ϵͬϭϯͬϮϬϮϮͲdƵĞƐĚĂLJ ϵͬϭϭͬϮϬϮϮͲ^ƵŶĚĂLJ t >>, ͗WsƐĞƚǁͬĚƌLJƌŽĚ͕ďůĞĚŽĨĨƚďŐŚŐƌǀŽŝĚĂŶĚEƚƌĞĞͬĂĚĂƉƚĞƌ͘ůĞĂŶǀŽŝĚ͕ŝŶƐƚĂůůZϱϰĂŶĚŝŶƐƚĂůůd^ƉůƵŐ͘dĞƐƚ ƉůƵŐƚŽϱϬϬϬ;W^^Ϳ͕ŚĞĐŬƵƉƉĞƌůŽĐŬƐĐƌĞǁƐ͕ŵŽǀĞĚĨƌĞĞůLJ͘EhKWƐƚĂĐŬĂŶĚZh^Z͘ZŝŐƵƉĂůůůŝŶĞƐĨƌŽŵĂĐĐƵŵƵůĂƚŽƌƚŽ KW ΘĨƵŶĐƚŝŽŶƚĞƐƚ͘&ŝŶŝƐŚĐŽŶŶĞĐƚŝŶŐũƵŵƉĞƌŚŽƐĞƐĨƌŽŵƉŝƚƐƚŽƌŝŐ͘&ŝůůKW ͕ƉƵƌŐĞĂŝƌ͕WͬhΘDͬhϮͲϯͬϴΗƚĞƐƚŵĂŶĚƌĞů͘ ŚĂƐĞůĞĂŬƐŽŶƐƚĂĐŬ͘ƉƉůLJƉƌĞƐƐƵƌĞĨŽƌƐŚĞůůƚĞƐƚ͘ĐŚŝĞǀĞŐŽŽĚƐŚĞůůƚĞƐƚ͘hƉĚĂƚĞƐƚĂƚĞƌĞƉ͘dĞƐƚKW ĂƐƉĞƌĂƉƉƌŽǀĞĚ ƐƵŶĚƌLJϯϮϮͲϯϮϱ͕tŝƚŶĞƐƐďLJ<ƐƚĂƚĞŝŶƐƉĞĐƚŽƌ͕ĚĂŵ Ăƌů͘dĞƐƚŝŶŐKW ĞƋƵŝƉŵĞŶƚƚŽϮϱϬƉƐŝůŽǁΘϮϱϬϬƉƐŝŚŝŐŚ&ͬϱͬϱ ĐŚĂƌƚĞĚŵŝŶƐ͘dĞƐƚηϭΘϮĐŽŵƉůĞƚĞĚ͘ ϵͬϭϮͬϮϬϮϮͲDŽŶĚĂLJ tĞůůEĂŵĞ ZŝŐ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ DW/Ͳϭϭ >ZΘ^Zηϭ 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ĨƌŽŵƌŝŐĨůŽŽƌ͘WƌĞƉĨŽƌZDK͘ZŝŐƌĞůĞĂƐĞĚĂƚϮϯ͗ϱϵ ϵͬϭϳͬϮϬϮϮͲ^ĂƚƵƌĚĂLJ ϵͬϭϲͬϮϬϮϮͲ&ƌŝĚĂLJ ^ĞƌǀŝĐĞƌŝŐ͕ ƋƵŝƉŵĞŶƚŝŶƐƉĞĐƚŝŽŶΘĐŚĞĐŬĨůƵŝĚƐ͘ŽŶΖƚƚŽĐŽŶŶĞĐƚƚĞĐŚůŝŶĞƚŽnjĞŶŝƚŚŐĂƵŐĞ͘WͬhΘDͬhũƚ͕ΘƐůŝĚŝŶŐƐůĞĞǀĞ͘Z/, ǁͬ:WĐŽŵƉůĞƚŝŽŶŽŶϯͲϭͬϮΗϵ͘ϯη>ͲϴϬ h ƚƵďŝŶŐ͕&ͬϮϰϵΖdͬϱ͕ϭϯϵΖdĞƐƚĚŽǁŶŚŽůĞŐĂƵŐĞĞǀĞƌLJϭϬϬϬΖ͖^ĞƌǀŝĐĞƌŝŐ͕ ƋƵŝƉŵĞŶƚ ŝŶƐƉĞĐƚŝŽŶΘĐŚĞĐŬĨůƵŝĚƐ͘Z/,ǁͬ:WĐŽŵƉůĞƚŝŽŶŽŶϯͲϭͬϮΗϵ͘ϯη>ͲϴϬ h ƚƵďŝŶŐ͕&ͬϱ͕ϭϯϵΖdͬϱ͕ϴϵϭΖ͖ŚĂŶŐĞŚĂŶĚůŝŶŐ ĞƋƵŝƉŵĞŶƚĨŽƌ,LJĚƌŝůϱϲϯƌƵŶ͘/ŶƐƚĂůůƐůŝƉƐƚLJƉĞĞůĞǀĂƚŽƌƐ͘ŚĂŶŐĞŽƵƚŝŶƐĞƌƚƐ͘^ǁŝƚĐŚŽǀĞƌd/tĐƌŽƐƐŽǀĞƌ͘Z/,ǁͬ:WĐŽŵƉůĞƚŝŽŶ ŽŶϯͲϭͬϮΗϵ͘ϯη>ͲϴϬ h ƚƵďŝŶŐ͕&ͬϱ͕ϴϵϭdͬϭϬϭϴϰΖDŽŶŝƚŽƌĚŝƐƉůĂĐĞŵĞŶƚĚƵƌŝŶŐƚƌŝƉ͕ϭϱďďůƐůŽƐƚĨŽƌƚŚĞĐŽŵƉůĞƚŝŽŶƌƵŶ͘dĂŐ ŽǀĞƌƐŚŽƚŽŶƚƵďŝŶŐƐƚƵďĂƚϭϬ͕ϭϴϰΖ͕ƐĞƚϭϬ<ĚŽǁŶƐŚĞĂƌďƌĂƐƐŝŶĚŝĐĂƚŽƌƐ͕ĐŽŶƚŝŶƵĞŝŶΕϴΖƚŽŶĞdžƚŝŶĚŝĐĂƚŽƌƐ͘^ĞƚϭϬ<ĚŽǁŶΘ ƐŚĞĂƌŽƵƚ͘>ŽǁĞƌƐƚƌŝŶŐΘEKͲ'K&ͬƚŽƚĂůĚĞƉƚŚŽĨϭϬ͕ϭϵϳΖWƵůůŽƵƚƚǁŽ:dƐΘƉƌĞĨŽƌŵƐƉĂĐĞŽƵƚ͘ ϵͬϭϰͬϮϬϮϮͲtĞĚŶĞƐĚĂLJ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞĞŬůLJKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌLJ ŽŶƚŝŶƵĞƚƌŝƉŝŶŚŽůĞǁŝƚŚƌĞƐƐŽĨĨŵŝůůĂƐƐĞŵďůLJ͘KďƐĞƌǀĞĚǁĞůůƚĂŬŝŶŐƉƌŽƉĞƌŚŽůĞĨŝůů͘dĂŐƚŽƉŽĨƚƵďŝŶŐƐƚƵŵƉĂƚϭϬϭϳϱΖ 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&HQWHUSRLQW'U6XLWH$QFKRUDJH$. +LOFRUS$ODVND//& 0,/1(3781,7, 0,/1(32,176&+5$'(5%/8))2,/ &2 /HQJWK 6L]H /(8(UG 79' %XUVW SVL 0' 1$ SVL SVL SVL 3HUIRUDWLRQ'HSWK0' IW 6HH6FKHPDWLF 6HH6FKHPDWLF 6 =;3/LQHU7RS3DFNHUDQG1$ 0' 79' 0' 79' DQG1$ U\ 6WDWX )RUP5HYLVHG$SSURYHGDSSOLFDWLRQLVYDOLGIRUPRQWKVIURPWKHGDWHRIDSSURYDO By Anne Prysunka at 3:43 pm, Oct 03, 2022 'LJLWDOO\VLJQHGE\'DYLG +DDNLQVRQ '1 FQ 'DYLG+DDNLQVRQ RX 8VHUV 'DWH 'DYLG+DDNLQVRQ 6)''65 %23(WHVWWRSVL $SSURYHGIRUIRUZDUGFLUFXODWLQJMHWSXPS ,QMHFWLRQWXELQJ669KLJKSUHVVXUHWULSQRWWRH[FHHGSVL ,QMHFWLRQWXELQJ669ORZSUHVVXUHWULSQRWWREHORZHUWKDQSVL ,$669KLJKSUHVVXUHWULSQRWWREHORZHUWKDQSVL 669FORVXUHRQ,$ZLOOLQLWLDWHZLWKLQPLQXWHVRIFORVXUHRQ669RQLQMHFWLRQWXELQJDQGYLVDYHUVD 4XDGUHQQLDO0,7,$WRSVL $SSURYHGYDULDQFHWR$$& F 669RQSURGXFLQJ,$ZLOOQRWEHLQYHUWLFDOUXQRIWKHWUHH 0*52&7*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2022.10.04 14:58:42 -08'00' RBDMS JSB 100622 ŽŶǀĞƌƚƚŽ:W tĞůů͗DWh/Ͳϭϭ tĞůůEĂŵĞ͗DWh/Ͳϭϭ W/EƵŵďĞƌ͗ϱϬͲϬϮϵͲϮϯϬϯϯͲϬϬͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗^/KŝůtĞůů;ĨĂŝůĞĚ ^WͿ WĂĚ͗/ͲWĂĚ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗:ƵŶĞϭϲƚŚ͕ϮϬϮϮ ZŝŐ͗^Zηϭ ZĞŐ͘ƉƉƌŽǀĂůZĞƋ͛Ě͍zĞƐ ĂƚĞZĞŐ͘ƉƉƌŽǀĂůZĞĐ͛ǀĚ͗ ZĞŐƵůĂƚŽƌLJŽŶƚĂĐƚ͗dŽŵ&ŽƵƚƐ WĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϮϬϭͲϭϯϳ &ŝƌƐƚĂůů ŶŐŝŶĞĞƌ͗ƌŝĂŶ'ůĂƐŚĞĞŶ ϵϬϳϱϰϱϭϭϰϰ ^ĞĐŽŶĚĂůů ŶŐŝŶĞĞƌ͗dĂLJůŽƌtĞůůŵĂŶ ;ϵϬϳͿϳϳϳͲϴϰϰϵ;KͿ ;ϵϬϳͿϵϰϳͲϵϱϯϯ;DͿ & EƵŵďĞƌ͗d:ŽďdLJƉĞ͗ŽŶǀĞƌƚƚŽ:W ƵƌƌĞŶƚŽƚƚŽŵ,ŽůĞWƌĞƐƐƵƌĞ͗ϭ͕ϰϱϬƉƐŝΛϯ͕ϱϰϳ͛ds ŽǁŶŚŽůĞ'ĂƵŐĞ͗ͮϳ͘ϵWW' DĂdžŝŵƵŵ džƉĞĐƚĞĚ,W͗ϭ͕ϰϱϬƉƐŝΛϯ͕ϱϰϳ͛ds ŽǁŶŚŽůĞ'ĂƵŐĞ͗ͮϳ͘ϵWW' DW^W͗ϭ͕ϬϵϱƉƐŝ 'ĂƐŽůƵŵŶ'ƌĂĚŝĞŶƚ;Ϭ͘ϭƉƐŝͬĨƚͿ DĂdž/ŶĐůŝŶĂƚŝŽŶ ϴϲΣΛϰ͕ϴϬϲ͛D ,ŝŐŚ/ŶĐůŝŶĂƚŝŽŶďĞŐŝŶƐĂƚϮ͕ϰϬϬ͛D DĂdžŽŐůĞŐ͗ϴ͘ϲΣͬϭϬϬĨƚΛϭ͕ϵϴϴ͛D ƌŝĞĨtĞůů^ƵŵŵĂƌLJ͗ DWhƉƌŽĚƵĐĞƌ/ͲϭϭǁĂƐĚƌŝůůĞĚŝŶϮϬϬϭĂŶĚĐŽŵƉůĞƚĞĚĂƐĂ^ĐŚƌĂĚĞƌůƵĨĨĚƵĂůůĂƚĞƌĂůŝŶƚŚĞ^ĐŚƌĂĚĞƌůƵĨĨK ĂŶĚKƐĂŶĚƐ͘&ƌŽŵƚŚĞŝŶŝƚŝĂůǁĞůůĚĞǀĞůŽƉŵĞŶƚ͕ƚŚĞƉƌŽĚƵĐƚŝǀŝ ƚLJŝŶĚĞdžŽĨƚŚĞƐĂŶĚƐǁĂƐŶŽƚĂƐĞdžƉĞĐƚĞĚ͘dŚĞ ĨŝƌƐƚƚǁŽ ^WĐŽŵƉůĞƚŝŽŶƐǁĞƌĞƉůĂŶŶŝŶŐĨŽƌϭ͕ϱϬϬƚŽϯ͕ϬϬϬWŽĨŝŶŝƚŝĂůƌĂƚĞ͖ŚŽǁĞǀĞƌ͕ƚŚĞƉƌŽĚƵĐƚŝŽŶǁĂƐůĞƐƐ ƚŚĂŶϱϬϬW͕ůĞĂĚŝŶŐƚŽƐŚĂĨƚďƌĞĂŬƐĂŶĚŽǀĞƌŚĞĂƚŝŶŐŽĨƚŚĞŽǀĞƌƐŝnjĞĚ ^WƐ͘/ŶϮϬϬϵ͕ƚŚĞĐŽŵƉůĞƚŝŽŶǁĂƐ ĐŚĂŶŐĞĚƚŽĂƌĞǀĞƌƐĞĐŝƌĐƵůĂƚŝŶŐũĞƚƉƵŵƉĚĞƐŝŐŶ͕ďƵƚĚƵĞƚŽƚŚĞĞdžƚĞŶĚĞĚƌĞĂĐŚĂŶĚŚŝŐŚĚĞǀŝĂƚŝŽŶŽĨƚŚĞǁĞůů͕ ĐŽŝůĞĚƚƵďŝŶŐǁĂƐƌĞƋƵŝƌĞĚĨŽƌĂůůũĞƚƉƵŵƉĐŚĂŶŐĞͲŽƵƚƐ͘/ŶEŽǀĞŵďĞƌϮϬϮϬƚŚĞǁĞůůǁĂƐĐŽŶǀĞƌƚĞĚƚŽĂŶ ^W͘ dŚĞ ^WǁĂƐƵŶĂďůĞƚŽůŝĨƚĨůƵŝĚƐĂŶĚƚŚĞƐŚĂĨƚŝƐƐƵƐƉĞĐƚĞĚƚŽŚĂǀĞƐŚĞĂƌĞĚ͘ EŽƚĞƐZĞŐĂƌĚŝŶŐƚŚĞtĞůůΘĞƐŝŐŶ x dŚĞϳ͟ƉƌŽĚƵĐƚŝŽŶĐĂƐŝŶŐƉĂƐƐĞĚĂD/dͲ/ƚŽϯ͕ϱϬϬƉƐŝŐΛϭϬ͕Ϯϭϱ͛ŽŶϲͬϯϬͬϭϲ͘ x KŶϭͬϬϮͬϮϬϮϭʹ<Ͳ'>sƐĞƚŝŶ'>DΛϭϴϯ͛D KďũĞĐƚŝǀĞ͗ x WƵůůϯͲϭͬϮ͟ ^WĐŽŵƉůĞƚŝŽŶ͘ x ZƵŶŶĞǁϯͲϭͬϮ͟&ŽƌǁĂƌĚŝƌĐƵůĂƚŝŶŐ:WĐŽŵƉůĞƚŝŽŶƚŽĂůůŽǁ:WƐǁĂƉƐǀŝĂƉƵŵƉŝŶƉƵŵƉŽƵƚ͘ x ,ŝůĐŽƌƉůĂƐŬĂ͕>>ƌĞƋƵĞƐƚƐĂǀĂƌŝĂŶĐĞƚŽϮϬϮϱ͘Ϯϲϱ;ĐͿ;ϭͿƚŽŽƉĞƌĂƚĞĂƐƵƌĨĂĐĞƐĂĨĞƚLJǀĂůǀĞ;^^sͿ ƚŚĂƚŝƐŶŽƚůŽĐĂƚĞĚŝŶƚŚĞǀĞƌƚŝĐĂůƌƵŶŽĨƚŚĞƚƌĞĞŽŶDŝůŶĞWŽŝŶƚhŶŝƚ;DWhͿǁĞůů/Ͳϭϭ;WdηϮϬϭͲϭϯϳϬͿ o ĐŽŶǀĞŶƚŝŽŶĂůĨŽƌǁĂƌĚĐŝƌĐƵůĂƚŝŽŶũĞƚƉƵŵƉŝƐďĞŝŶŐƌƵŶŝŶƚŚŝ ƐǁĞůůĚƵĞƚŽŚŝŐŚĚĞǀŝĂƚŝŽŶƚŚĂƚŝƐ ƵŶƌĞĂĐŚĂďůĞďLJƐůŝĐŬůŝŶĞĨŽƌũĞƚƉƵŵƉĐŚĂŶŐĞŽƵƚƐ͘ WƌĞͲZŝŐWƌŽĐĞĚƵƌĞ͗ ϭ͘ Zh>Z^ƉƵŵƉƚƌƵĐŬĂŶĚWdůŝŶĞƐƚŽϮ͕ϱϬϬƉƐŝ͘ Ϯ͘ ŽŶƚĂĐƚƚŚĞŽƉĞƌĂƚŝŽŶƐ ŶŐŝŶĞĞƌƚŽƌĞǀŝĞǁƚŚĞǁĞůů<ŝůůƉůĂŶǁŝƚŚƵƉĚĂƚĞĚd'ĂŶĚ/ƉƌĞƐƐƵƌĞƐ͘/ŶŝƚŝĂů ƉůĂŶǁŝůůďĞƚŽďƵůůŚĞĂĚĂƚůĞĂƐƚϴϬ>^ŽĨϭϮϬΣŚĞĂƚĞĚƐŽƵƌĐĞǁĂƚĞƌ ϴ͘ϯƉƉŐ ǁŝƚŚďĂƌĂĐůĞĂŶĚŽǁŶƚŚĞ ƚƵďŝŶŐĂŶĚƚĂŬŝŶŐƌĞƚƵƌŶƐƵƉƚŚĞ/ƚŽĂϱϬϬďďůƌĞƚƵƌŶƚĂŶŬ͘^ŚƵƚŝŶƚŚĞd'ĂŶĚƐǁĂƉƚŽƉƵŵƉŝŶŐ ĚŽǁŶƚŚĞ/ĂŶĚďƵůůŚĞĂĚϰϬϬ>͛ƐĚŽǁŶƚŚĞ/ƚŽƚŚĞĨŽƌŵĂƚŝŽŶ;>ŝŵŝƚƵůůŚĞĂĚƐƵƌĨĂĐĞƉƌĞƐƐƵƌĞƚŽ ϳϬϬƉƐŝǁŝƚŚϴ͘ϯƉƉŐĨůƵŝĚͿ͘ŽŶƚĂĐƚƚŚĞŽƉĞƌĂƚŝŽŶƐ ŶŐŝŶĞĞƌǁŝƚŚƌĞƐƵůƚƐ͘ Ă͘ dƵďŝŶŐsŽůƵŵĞс͘ϬϬϯϵďƉĨΎϵ͕ϲϬϱ͛сϯϳďďůƐ ď͘ ŶŶƵůĂƌsŽůƵŵĞс͘ϬϯϮϴďƉĨΎϵ͕ϲϬϱ͛сϯϭϱďďůƐ ϯ͘ ŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚ͘ ŽŶǀĞƌƚƚŽ:W tĞůů͗DWh/Ͳϭϭ Ă͘ &ƌĞĞnjĞƉƌŽƚĞĐƚŝƐƵƉƚŽƚŚĞĚŝƐĐƌĞƚŝŽŶŽĨƚŚĞtĞůůƐŝƚĞ^ƵƉĞƌǀŝƐŽƌĚĞƉĞŶĚŝŶŐŽŶƚŝŵŝŶŐĨŽƌĂƌƌŝǀĂůŽĨ ƚŚĞ^Z͘;EŽƚĞ͗/ĨƚŚĞǁĞůůŝƐĨƌĞĞnjĞƉƌŽƚĞĐƚĞĚƚŚĞǁĞůůŬŝůůƉƵƚŝŶƉůĂĐĞǁŝůůďĞůŽƐƚ͘Ϳ ϰ͘ Z>Z^͘ ϱ͘ ůĞĂƌĂŶĚůĞǀĞůƉĂĚĂƌĞĂŝŶĨƌŽŶƚŽĨǁĞůů͘^ƉŽƚƌŝŐŵĂƚƐĂŶĚĐŽŶƚĂŝŶŵĞŶƚ͘ ϲ͘ ZǁĞůůŚŽƵƐĞĂŶĚĨůŽǁůŝŶĞƐ͘ůĞĂƌĂŶĚůĞǀĞůĂƌĞĂĂƌŽƵŶĚǁĞůů͘ ϳ͘ ZhĐƌĂŶĞ͘^ĞƚWs͘EdƌĞĞ͘^Ğƚd^WůƵŐ͘/ŶƐƉĞĐƚƚŚĞƚƵďŝŶŐŚĂŶŐĞƌůŝĨƚƚŚƌĞĂĚĂŶĚŶŽƚĞĂŶLJĚĂŵĂŐĞ͘ ϴ͘ Ehϭϭ͟KW ǁŝƚŚĂŶĂĚĚŝƚŝŽŶĂůϮͲϯͬϴĨŝdžĞĚƌĂŵ͘ZƌĂŶĞ͘ ϵ͘ ^ƉŽƚŵƵĚďŽĂƚ͘ ZtKWƌŽĐĞĚƵƌĞ͗ ϭϬ͘ D/Zh,ŝůĐŽƌƉ^Zηϭ͕ĂŶĐŝůůĂƌLJĞƋƵŝƉŵĞŶƚ͕ĂŶĚůŝŶĞƐƚŽƌĞƚƵƌŶƐƚĂŶŬ͘ ϭϭ͘ dĞƐƚϭϭ͟KW ƚŽϮϱϬͬϮ͕ϱϬϬƉƐŝĂŶĚĂŶŶƵůĂƌƚŽϮϱϬͬϮ͕ϱϬϬƉƐŝ͘ Ă͘ EŽƚŝĨLJƚŚĞK'ϮϰŚŽƵƌƐŝŶĂĚǀĂŶĐĞŽĨKWƚĞƐƚ͘ ď͘ ŽŶĨŝƌŵƚĞƐƚƉƌĞƐƐƵƌĞƐƉĞƌƚŚĞ^ƵŶĚƌLJŽŶĚŝƚŝŽŶƐŽĨĂƉƉƌŽǀĂů͘ Đ͘ dĞƐƚZĂŵ͛ƐĂŶĚĂŶŶƵůĂƌǁŝƚŚϮͲϯͬϴ͟ΘϯͲϭͬϮ͟ƚĞƐƚũŽŝŶƚƐ͘ Ě͘ ^ƵďŵŝƚƚŽK'ĐŽŵƉůĞƚĞĚϭϬͲϰϮϰĨŽƌŵǁŝƚŚŝŶϱĚĂLJƐŽĨKW ƚĞƐƚ͘ ϭϮ͘ ZhƚŽƉƵůůϮͲϯͬϴ͟ ^WĐŽŵƉůĞƚŝŽŶ͘ ϭϯ͘ WƵůůƚŚĞd^ƉůƵŐ͕ĐŚĞĐŬĨŽƌƉƌĞƐƐƵƌĞƵŶĚĞƌƚŚĞWs͕ŝĨŶĞĞĚĞĚŬŝůůƚŚĞǁĞůůǁŝƚŚ<t&ĂŶĚƉƵůůƚŚĞWs͘ ϭϰ͘ DhƚŚĞůĂŶĚŝŶŐũŽŝŶƚƚŽƚŚĞƚƵďŝŶŐŚĂŶŐĞƌ͕K>^ĂŶĚƵŶƐĞĂƚƚŚĞƚƵďŝŶŐŚĂŶŐĞƌ͘ Ă͘ ^ƚƌŝŶŐ^Kсϴ<ǁŚĞŶůĂŶĚĞĚďLJ^ZϮϬϮϬ͕ŶŽƌĞĐŽƌĚĞĚĨŝŶĂůWhǁĞŝŐŚƚƐ͘ ď͘ WhtƚĚƌLJ͘сΕϰϱ͘ϰ<ůď ϭϱ͘ WƵůůƚŚĞŚĂŶŐĞƌƚŽƚŚĞƌŝŐĨůŽŽƌ͘>ĂLJĚŽǁŶƚŚĞůĂŶĚŝŶŐũŽŝŶƚĂŶĚƚƵďŝŶŐŚĂŶŐĞƌ͘ZhƚŽƉƵůů ^WĐĂďůĞ ŽǀĞƌƐŚĞĂǀĞƐƚŽƐƉŽŽůŝŶŐƵŶŝƚ͘ Ă͘ /ŶƐƉĞĐƚƚŚĞƚƵďŝŶŐŚĂŶŐĞƌĂŶĚŶŽƚĞĂŶLJĐŽƌƌŽƐŝŽŶŽƌĚĂŵĂŐĞ͘ ϭϲ͘ WKK,ůĂLJŝŶŐĚŽǁŶƚŚĞϮͲϯͬϴ͟ƚƵďŝŶŐƐƉŽŽůŝŶŐ ^WĐĂďůĞĂŶĚƌĞ ŵŽǀŝŶŐĂůůũĞǁĞůƌLJĂƐŝƚƉƌĞƐĞŶƚƐŝƚƐĞůĨ͘ ĂďůĞ^ƉůŝĐĞĂƚϴ͕ϭϭϮ͛D͘ Ă͘ EŽƚĞĂŶLJĐŽƌƌŽƐŝŽŶ͕ƐĂŶĚ͕ƐĐĂůĞ͕ĚĂŵĂŐĞŽƌŽǀĞƌƚŽƌƋƵĞĚĐŽŶŶĞĐƚŝŽŶƐŽŶƚŚĞƚƵďŝŶŐǁŝƚŚĂƐƐŽĐŝĂƚĞĚ ĚĞƉƚŚƐĂŶĚ ^WĐŽŵƉŽŶĞŶƚƐŽŶƚŚĞŵŽƌŶŝŶŐƌĞƉŽƌƚ͘ 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EhƚŚĞƚƵďŝŶŐŚĞĂĚĂĚĂƉƚĞƌĂŶĚEhϱDƚƌĞĞƚŽĂĐĐŽŵŵŽĚĂƚĞĂĨŽƌǁĂƌĚĐŝƌĐƵůĂƚŝŶŐũĞƚƉƵŵƉ͘ ϯϮ͘ WdƚŚĞƚƵďŝŶŐŚĂŶŐĞƌǀŽŝĚƚŽϱϬϬͬϱ͕ϬϬϬƉƐŝ͘WdƚŚĞƚƌĞĞƚŽϮϱϬͬϱ͕ϬϬϬƉƐŝ͘ Ă͘ WƵŵƉϱϱďďůĚŝĞƐĞůĨƌĞĞnjĞƉƌŽƚĞĐƚĚŽǁŶƚŚĞ/ƉƌŝŽƌƚŽƐĞƚƚŝŶŐƉĂĐŬĞƌ͘ ϯϯ͘ WƵůůƚŚĞd^ƉůƵŐĂŶĚWs͘ ϯϰ͘ ^ĞĐƵƌĞƚŚĞǁĞůů͘ WŽƐƚͲZŝŐWƌŽĐĞĚƵƌĞ͗ K/>dh/E'͗ ϯϱ͘ /ĨĂďƵƌƐƚĚŝƐĐǁĂƐƌƵŶ͕D/ZhƉƵŵƉƚƌƵĐŬƚŽƚŚĞƚƵďŝŶŐĂŶĚƉƌĞƐƐƵƌĞƵƉƚŚĞƚƵďŝŶŐƚŽƐĞƚƚŚĞƉĂĐŬĞƌ͘ Ă͘ WƌĞƐƐƵƌĞƵƉĂŶĚƚĞƐƚƚŚĞƚƵďŝŶŐƚŽϯϳϱϬƉƐŝĨŽƌD/dͲdǁŝƚŚϭϬϬϬƉƐŝŽŶƚŚĞ/;dŚŝƐǁŝůů ƐĞƌǀĞĂƐƚŚĞW&DK^WƉƌĞƐƐƵƌĞƚĞƐƚͿ͘ůĞĞĚŽĨĨƚŚĞƚƵďŝŶŐƚŽϭϬϬϬƉƐŝ͘dĞƐƚƚŚĞ/ƚŽϮϬϬϬ ƉƐŝĨŽƌD/dͲ/͘ZĞĐŽƌĚĂŶĚŶŽƚĂƚĞĂůůƉƌĞƐƐƵƌĞƚĞƐƚƐ;ϯϬŵŝŶƵƚĞƐͿŽŶĐŚĂƌƚ͘ ϯϲ͘ D/Zhϭ͘ϱ͟ŽŝůĞĚdƵďŝŶŐhŶŝƚĂŶĚƐƉŽƚĂŶĐŝůůĂƌLJĞƋƵŝƉŵĞŶƚ͘ ϯϳ͘ WƌĞƐƐƵƌĞƚĞƐƚKW ƚŽ ϰ͕ϬϬϬƉƐŝ,ŝϮϱϬ>Žǁ͕ϭϬŵŝŶ,ŝ͕ϱŵŝŶ>ŽǁĞĂĐŚƚĞƐƚ͘ Ă͘ ŝĨǁŝƚŚŝŶƚŚĞƐƚĂŶĚĂƌĚϳͲĚĂLJƚĞƐƚKW ƚĞƐƚƉĞƌŝŽĚĨŽƌDŝůŶĞWŽŝŶƚ͕ĂĨƵůůďŽĚLJƚĞƐƚĂŶĚ ĨƵŶĐƚŝŽŶƚĞƐƚŽĨƚŚĞƌĂŵƐŝƐƐƵĨĨŝĐŝĞŶƚ͘ ď͘ ĂĐŚƐƵďƐĞƋƵĞŶƚƚĞƐƚŽĨƚŚĞůƵďƌŝĐĂƚŽƌǁŝůůďĞƚŽ ϰ͕ϬϬϬƉƐŝ,ŝϮϱϬ>ŽǁƚŽĐŽŶĨŝƌŵŶŽůĞĂŬƐ͘ ϯϴ͘ /ĨZ,WůƵŐǁĂƐƌƵŶŝŶyEEŝƉƉůĞ͕Z/,ǁŝƚŚďĂůůĂŶĚƌŽĚĂŶĚƐĞƚŝŶϮͲϳͬϴ͛͛yEŶŝƉĂƚΕϭϬϭϯϵ͛D͘ Ă͘ WƌĞƐƐƵƌĞƵƉdďĂĐŬƐŝĚĞĂŶĚŚLJĚƌĂƵůŝĐĂůůLJƐĞƚƚŚĞƉĂĐŬĞƌĂƐƉ ĞƌĂŬĞƌƐƐĞƚƚŝŶŐƉƌŽĐĞĚƵƌĞ͘ ď͘ WƌĞƐƐƵƌĞƵƉĂŶĚƚĞƐƚƚŚĞƚƵďŝŶŐƚŽϯϳϱϬƉƐŝĨŽƌD/dͲdǁŝƚŚϭϬϬϬƉƐŝŽŶƚŚĞ/;dŚŝƐǁŝůů ƐĞƌǀĞĂƐƚŚĞW&DK^WƉƌĞƐƐƵƌĞƚĞƐƚͿ͘ůĞĞĚŽĨĨƚŚĞƚƵďŝŶŐƚŽϭϬϬϬƉƐŝ͘dĞƐƚƚŚĞ/ƚŽϮϬϬϬ ƉƐŝĨŽƌD/dͲ/͘ZĞĐŽƌĚĂŶĚŶŽƚĂƚĞĂůůƉƌĞƐƐƵƌĞƚĞƐƚƐ;ϯϬŵŝŶƵƚĞƐͿŽŶĐŚĂƌƚ͘ ϯϵ͘ /ĨďƵƌƐƚĚŝƐĐǁĂƐƌƵŶĂŶĚĚŝĚŶŽƚďƵƌƐƚ͕Z/,ǁͬƐƉĞĂƌƚŽďƌĞĂŬďƵƌƐƚĚŝƐĐ͘ ϰϬ͘ WKK,͘ ϰϭ͘ Z/,ǁŝƚŚϭ͘ϱ͛͛:^EĂŶĚ'Zͬ>ĂŶĚƉĞƌĨŽƌŵĂ&KƵƐŝŶŐEϮƚŽϭϯϭϮϬƚĂŬŝŶŐƌĞƚƵƌŶƐƚŽƚĂŶŬƐŽƌƉŽƌƚĂďůĞ ƐĞƉĂƌĂƚŽƌ͘ Ă͘ EŽƚĞD/E/ŽĨϭ͘ϳϭϴ͟ƚŚƌŽƵŐŚŝƐŽůĂƚŝŽŶƐůĞĞǀĞ͘ ϰϮ͘ Z/,ĂŶĚƉƵůůďůĂŶŬŝŶŐƐůĞĞǀĞĨƌŽŵĨŽƌǁĂƌĚĐŝƌĐƵůĂƚŝŶŐ,͕WKK, ŽŶǀĞƌƚƚŽ:W tĞůů͗DWh/Ͳϭϭ ϰϯ͘ WƵŵƉŝŶ:WƐƚĂŶĚŝŶŐǀĂůǀĞ͘/Ĩ,ĚŽĞƐŶŽƚƐĞƚ͕Z/,ĂŶĚƐĞƚƚŚĞ:WƐƚĂŶĚŝŶŐǀĂůǀĞŝŶƚŚĞ:W,͘WƌĞƐƐƵƌĞ ƚĞƐƚƚŽϭϱϬϬƉƐŝ͘WKK,͘ ϰϰ͘ ƌŽƉϭϮ:ĞƚƉƵŵƉĂŶĚĐŽŶĨŝƌŵĂŐŽŽĚƐĞƚ͘/Ĩ:WĚŽĞƐŶŽƚůĂŶĚŝŶ,ĐĂůůK ƚŽƚƌŽƵďůĞƐŚŽŽƚ͘ ϰϱ͘ WKK,ǁŝƚŚĐŽŝůĨƌĞĞnjĞƉƌŽƚĞĐƚŝŶŐƚŚĞd'ĨƌŽŵϮ͕ϱϬϬ͛DƚŽƐƵƌĨĂĐĞ͘ ϰϲ͘ ZŽŝů͘ ϰϳ͘ dƵƌŶǁĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶǀŝĂŚĂŶĚŽǀĞƌĨŽƌŵ͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƐͲďƵŝůƚ^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘ ^ZKWƐƚĂĐŬƐŬĞƚĐŚ ϰ͘ ϮϬϮϱ͘Ϯϲϱ;ĐͿǀĂƌŝĂŶĐĞƌĞƋƵĞƐƚ ϱ͘ 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ŝƐĐŚĂƌŐĞ,ĞĂĚ͗ŽůƚŽŶΘWŽƌƚĞĚĞŶŝƚŚ ϱ ϵ͕ϲϬϳ͛ WƵŵƉ͗ϰϬϬWD^^&> yϳ ZϭϬϵ,ϲ ϲ ϵ͕ϲϮϲ͛ 'ĂƐ^ĞƉĞƌĂƚŽƌĂŶĚǀŽŝĚĞƌ͗ϰϬϬ'^ sDd,ϲͬϰϬϬ'Zs/dzhW ϳ ϵ͕ϲϯϮ͛ hƉƉĞƌdĂŶĚĞŵ^ĞĂů͗'^,ϲ^ͬW&^ ϴ ϵ͕ϲϯϵ͛ >ŽǁĞƌdĂŶĚĞŵ^ĞĂů͗'^,ϲ^ͬW&^ ϵ ϵ͕ϲϰϲ͛ DŽƚŽƌ͗ ϱϲϮdžƉϭϬϬ,Ɖͬϭ͕ϴϮϬsͬϯϰ ϭϬ ϵ͕ϲϱϰ͛ DŽƚŽƌ'ĂƵŐĞĂŶĚĞŶƚƌĂůŝnjĞƌ͗ĞŶŝƚŚʹŽƚƚŽŵΛϵ͕ϲϱϴ͛ ϭϭ ϭϬ͕Ϯϭϱ͛ ĂŬĞƌ^ͲϯWĞƌŵĂŶĞŶƚWĂĐŬĞƌϳ͟džϰ͘ϱ͟ ϭϮ ϭϬ͕Ϯϯϵ͛ ϰ͘ϱ͟yEͲEŝƉƉůĞʹ ϯ͘ϳϮϱ͟EŽ'Ž ϭϯ ϭϬ͕ϯϬϮ͛ ϰ͘ϱ͟dͲ//t> 'ʹ ŽƚƚŽŵΛϭϬ͕ϯϬϯ͛ ϭϰ ϭϬ͕ϯϯϲ͛ ĂŬĞƌ,ŽŽŬtĂůů͕,ĂŶŐĞƌĂďŽǀĞϳ͟tŝŶĚŽǁ ϭϱ ϭϬ͕ϯϲϬ͛ ĂŬĞƌ,ŽŽŬtĂůů͕,ĂŶŐĞƌŽƵƚƐŝĚĞϳ͟tŝŶĚŽǁ ϭϲ ϭϬ͕ϱϲϳ͛ ĂŬĞƌyW>ŝŶĞƌdŽƉWĂĐŬĞƌ ϭϳ ϭϬ͕ϱϴϮ͛ ĂŬĞƌϳ͟džϱ͟,D>ŝŶĞƌ,ĂŶŐĞƌ EŽƚĞƐ͗EĂďŽƌƐϮϮ Z<ƚŽd,&сϮϴ͘ϭ͖͛EĂďŽƌƐϯ^Z<ƚŽd,&сϮϭ͘ϱ͛'сϲ͘ϲ͛ ůůĚĞƉƚŚƐĂƌĞĐŽƌƌĞĐƚĞĚďĂĐŬƚŽŽƌŝŐŝŶĂůZ<͘ KW E,K> ͬ D Ed d/> ϮϬΗ ŵƚǁͬϮϲϬƐdžŽĨƌĐƚŝĐƐĞƚ;ƉƉƌŽdžͿŝŶϯϬ͟,ŽůĞ ϭϬͲϯͬϰ͟ ŵƚǁͬϲϬϬƐdžŽĨW&͞>͕͟ϰϰϬƐdžůĂƐƐ͞'͟ŝŶϭϯͲϭͬϮ͟,ŽůĞ ϳ͟ ŵƚǁͬϭ͕ϰϬϬƐdžůĂƐƐ͞'͟ŝŶϵͲϳͬϴ͟,ŽůĞ t >>/E>/Ed/KE d/> <KWΛϱϬϬ͛D ϳϱƚŽϴϱĞŐ͘Ϯ͕ϵϬϬ͛ʹϭϬ͕ϯϬϬ͛ DĂdž,ŽůĞŶŐůĞсϴϲĚĞŐ͘Λϰ͕ϴϬϲ͛D ' E Z>t >>/E&K W/͗ϱϬͲϬϮϵͲϮϯϬϯϯͲϬϬͲϬϬ ƌŝůůĞĚĂŶĚŽŵƉůĞƚĞĚďLJEĂďŽƌƐϮϮ ͲϭϬͬϬϲͬϮϬϬϭ ŽŶǀĞƌƐŝŽŶƚŽ:ĞƚWƵŵƉ;EĂďŽƌƐϯ ^ͿʹϬϮͬϬϮͬϮϬϬϵ ^W/ŶƐƚĂůůďLJ^ZʹϭϭͬϭϱͬϮϬϮϬ >d Z>t/EKt d/> tŝŶĚŽǁŝŶϳ͟ĂƐŝŶŐΛ ϭϬ͕ϯϰϱ͛ƚŽϭϬ͕ϯϱϳ͛ tĞůůŶŐůĞΛtŝŶĚŽǁсϳϳĞŐ͘ t >>, d/> dƌĞĞ ϮͲϵͬϭϲ͟ʹϱD&D tĞůůŚĞĂĚ ϭϭ͟džϰ͘ϱ͟ϱD'ĞŶ͘ϲǁͬϰ͘ϱ͟dͲ//dΘdƵďŝŶŐ,ĂŶŐĞƌ/t͞,͟WsWƌŽĨŝůĞ,ŽůĞ >ĂƐƚdĂŐ͗K&KdĂŐ͗ϭϮ͕ϵϬϰ͛ŽŶϰͬϭϳͬϭϴ KŚĂƐŶĞǀĞƌďĞĞŶ&K BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚLJ͗d&ϱͬϮϰͬϮϬϮϮ WZKWK^ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWh/Ͳϭϭ >ĂƐƚŽŵƉůĞƚĞĚ͗ϭϭͬϭϱͬϮϬϮϬ Wd͗ϮϬϭͲϭϯϳ dс ϭϯ͕ϭϳϬ͛ ;DͿͬdсϯ͕ϲϰϰ͛;dsͿ ϮϬ ´ KƌŝŐ͘& ůĞǀ͘сϲϰ͘ϳϬ͛ͬKƌŝŐ͘'> ůĞǀ͘сϯϰ͘ϳϬ͛ ϳ͟ ³2$´/DWHUDO Wdс ϭϯ͕ϭϳϬ͛ ;DͿͬWdсϯ͕ϲϰϰ͛;dsͿ ³2%´ /DWHUDO ϭϬͲϯͬϰ´ 0LQ,' ´ ^/E' d/> ^ŝnjĞ dLJƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ W& ϮϬΗ ŽŶĚƵĐƚŽƌ ϵϰͬ,ͲϰϬ ϭϵ͘ϭϮϰ ^ƵƌĨĂĐĞ ϭϬϭΖ Ϭ͘ϯϱϱ ϭϬͲϯͬϰ͟ ^ƵƌĨĂĐĞ ϰϱ͘ϱͬ>ͲϴϬͬd ϵ͘ϵϱϬ ^ƵƌĨĂĐĞ Ϯ͕ϳϯϬ͛ Ϭ͘ϬϵϲϬ ϳΗ /ŶƚĞƌŵĞĚŝĂƚĞ Ϯϲͬ>ͲϴϬͬ,LJĚƌŝůϱϮϭ ϲ͘Ϯϳϲ ^ƵƌĨĂĐĞ ϭϬ͕ϳϰϴ͛ Ϭ͘Ϭϯϴϯ ϰͲϭͬϮ͟ ^ůŽƚƚĞĚ>ŝŶĞƌ͟͞ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϭϬ͕ϰϬϲ͛ ϭϮ͕ϵϵϵ͛ Eͬ ϰͲϭͬϮ͟ ^ůŽƚƚĞĚ>ŝŶĞƌ͟͞ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϭϬ͕ϳϲϭ͛ ϭϯ͕ϭϮϱ͛ Eͬ dh/E' d/> ϯͲϭͬϮ͟ dƵďŝŶŐ ϰ͘ϳͬ>ͲϴϬͬ h ϴƌĚ ϭ͘ϵϵϱ ^ƵƌĨĂĐĞ ϭϬ͕ϭϳϴ͛ ϰͲϭͬϮ͟ dƵďŝŶŐ ϭϮ͘ϲͬ>ͲϴϬͬE^Ͳd ϯ͘ϵϱϴ 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tͬ &KD Z dZ/W> y STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________MILNE PT UNIT I-11 JBR 11/04/2022 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 Good test Test Results TEST DATA Rig Rep:C.Greub/D.ShulzeOperator:Hilcorp Alaska, LLC Operator Rep:Aarron Haberthur Rig Owner/Rig No.:Hilcorp ASR 1 PTD#:2011370 DATE:9/12/2022 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopSTS220918164855 Inspector Sully Sullivan Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 6.0 MASP: 1095 Sundry No: 322-325 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 16 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 n/a NA Annular Preventer 1 11"P #1 Rams 1 2 3/8"P #2 Rams 1 2 7/8" x 5"P #3 Rams 1 blind P #4 Rams 0 n/a NA #5 Rams 0 n/a NA #6 Rams 0 n/a NA Choke Ln. Valves 1 2 1/16"P HCR Valves 1 2 1/16"P Kill Line Valves 2 2 1/16"P Check Valve 0 n/a NA BOP Misc 0 n/a NA System Pressure P3100 Pressure After Closure P1750 200 PSI Attained P7 Full Pressure Attained P57 Blind Switch Covers:Pall stations Bottle precharge P Nitgn Btls# &psi (avg)P4/2250 ACC Misc NA0 NA NATrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P25 #1 Rams P6 #2 Rams P6 #3 Rams P6 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill NA0 9 9 9 9 9 9 9 9 9 9 9 7\SHRI5HTXHVW $EDQGRQ 3OXJ3HUIRUDWLRQV )UDFWXUH6WLPXODWH 5HSDLU:HOO 2SHUDWLRQVVKXWGRZQ 6XVSHQG 3HUIRUDWH 2WKHU6WLPXODWH 3XOO7XELQJ &KDQJH$SSURYHG3URJUDP 3OXJIRU5HGULOO 3HUIRUDWH1HZ3RRO 5HHQWHU6XVS:HOO $OWHU&DVLQJ 2WKHU &RQYHUWWR)&-HW3XPS 2SHUDWRU1DPH &XUUHQW:HOO&ODVV 3HUPLWWR'ULOO1XPEHU ([SORUDWRU\ 'HYHORSPHQW $GGUHVV 6WUDWLJUDSKLF 6HUYLFH $3,1XPEHU ,ISHUIRUDWLQJ :HOO1DPHDQG1XPEHU 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&ƌĞĞnjĞƉƌŽƚĞĐƚŝƐƵƉƚŽƚŚĞĚŝƐĐƌĞƚŝŽŶŽĨƚŚĞtĞůůƐŝƚĞ^ƵƉĞƌǀŝƐŽƌĚĞƉĞŶĚŝŶŐŽŶƚŝŵŝŶŐĨŽƌĂƌƌŝǀĂůŽĨ ƚŚĞ^Z͘;EŽƚĞ͗/ĨƚŚĞǁĞůůŝƐĨƌĞĞnjĞƉƌŽƚĞĐƚĞĚƚŚĞǁĞůůŬŝůůƉƵƚŝŶƉůĂĐĞǁŝůůďĞůŽƐƚ͘Ϳ ϰ͘ Z>Z^͘ ϱ͘ ůĞĂƌĂŶĚůĞǀĞůƉĂĚĂƌĞĂŝŶĨƌŽŶƚŽĨǁĞůů͘^ƉŽƚƌŝŐŵĂƚƐĂŶĚĐŽŶƚĂŝŶŵĞŶƚ͘ ϲ͘ ZǁĞůůŚŽƵƐĞĂŶĚĨůŽǁůŝŶĞƐ͘ůĞĂƌĂŶĚůĞǀĞůĂƌĞĂĂƌŽƵŶĚǁĞůů͘ ϳ͘ ZhĐƌĂŶĞ͘^ĞƚWs͘EdƌĞĞ͘^Ğƚd^WůƵŐ͘/ŶƐƉĞĐƚƚŚĞƚƵďŝŶŐŚĂŶŐĞƌůŝĨƚƚŚƌĞĂĚĂŶĚŶŽƚĞĂŶLJĚĂŵĂŐĞ͘ ϴ͘ Ehϭϭ͟KW ǁŝƚŚĂŶĂĚĚŝƚŝŽŶĂůϮͲϯͬϴĨŝdžĞĚƌĂŵ͘ZƌĂŶĞ͘ ϵ͘ ^ƉŽƚŵƵĚďŽĂƚ͘ ZtKWƌŽĐĞĚƵƌĞ͗ ϭϬ͘ D/Zh,ŝůĐŽƌƉ^Zηϭ͕ĂŶĐŝůůĂƌLJĞƋƵŝƉŵĞŶƚ͕ĂŶĚůŝŶĞƐƚŽƌĞƚƵƌŶƐƚĂŶŬ͘ ϭϭ͘ dĞƐƚϭϭ͟KW ƚŽϮϱϬͬϮ͕ϱϬϬƉƐŝĂŶĚĂŶŶƵůĂƌƚŽϮϱϬͬϮ͕ϱϬϬƉƐŝ͘ Ă͘ EŽƚŝĨLJƚŚĞK'ϮϰŚŽƵƌƐŝŶĂĚǀĂŶĐĞŽĨKWƚĞƐƚ͘ ď͘ ŽŶĨŝƌŵƚĞƐƚƉƌĞƐƐƵƌĞƐƉĞƌƚŚĞ^ƵŶĚƌLJŽŶĚŝƚŝŽŶƐŽĨĂƉƉƌŽǀĂů͘ Đ͘ dĞƐƚZĂŵ͛ƐĂŶĚĂŶŶƵůĂƌǁŝƚŚϮͲϯͬϴ͟ΘϯͲϭͬϮ͟ƚĞƐƚũŽŝŶƚƐ͘ Ě͘ ^ƵďŵŝƚƚŽK'ĐŽŵƉůĞƚĞĚϭϬͲϰϮϰĨŽƌŵǁŝƚŚŝŶϱĚĂLJƐŽĨKW ƚĞƐƚ͘ ϭϮ͘ ZhƚŽƉƵůůϮͲϯͬϴ͟ ^WĐŽŵƉůĞƚŝŽŶ͘ ϭϯ͘ WƵůůƚŚĞd^ƉůƵŐ͕ĐŚĞĐŬĨŽƌƉƌĞƐƐƵƌĞƵŶĚĞƌƚŚĞWs͕ŝĨŶĞĞĚĞĚŬŝůůƚŚĞǁĞůůǁŝƚŚ<t&ĂŶĚƉƵůůƚŚĞWs͘ ϭϰ͘ DhƚŚĞůĂŶĚŝŶŐũŽŝŶƚƚŽƚŚĞƚƵďŝŶŐŚĂŶŐĞƌ͕K>^ĂŶĚƵŶƐĞĂƚƚŚĞƚƵďŝŶŐŚĂŶŐĞƌ͘ Ă͘ 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ƐĞƌǀĞĂƐƚŚĞW&DK^WƉƌĞƐƐƵƌĞƚĞƐƚͿ͘ůĞĞĚŽĨĨƚŚĞƚƵďŝŶŐƚŽϭϬϬϬƉƐŝ͘dĞƐƚƚŚĞ/ƚŽϮϬϬϬ ƉƐŝĨŽƌD/dͲ/͘ZĞĐŽƌĚĂŶĚŶŽƚĂƚĞĂůůƉƌĞƐƐƵƌĞƚĞƐƚƐ;ϯϬŵŝŶƵƚĞƐͿŽŶĐŚĂƌƚ͘ ϯϲ͘ D/Zhϭ͘ϱ͟ŽŝůĞĚdƵďŝŶŐhŶŝƚĂŶĚƐƉŽƚĂŶĐŝůůĂƌLJĞƋƵŝƉŵĞŶƚ͘ ϯϳ͘ WƌĞƐƐƵƌĞƚĞƐƚKW ƚŽ ϰ͕ϬϬϬƉƐŝ,ŝϮϱϬ>Žǁ͕ϭϬŵŝŶ,ŝ͕ϱŵŝŶ>ŽǁĞĂĐŚƚĞƐƚ͘ Ă͘ ŝĨǁŝƚŚŝŶƚŚĞƐƚĂŶĚĂƌĚϳͲĚĂLJƚĞƐƚKW ƚĞƐƚƉĞƌŝŽĚĨŽƌDŝůŶĞWŽŝŶƚ͕ĂĨƵůůďŽĚLJƚĞƐƚĂŶĚ ĨƵŶĐƚŝŽŶƚĞƐƚŽĨƚŚĞƌĂŵƐŝƐƐƵĨĨŝĐŝĞŶƚ͘ ď͘ ĂĐŚƐƵďƐĞƋƵĞŶƚƚĞƐƚŽĨƚŚĞůƵďƌŝĐĂƚŽƌǁŝůůďĞƚŽ ϰ͕ϬϬϬƉƐŝ,ŝϮϱϬ>ŽǁƚŽĐŽŶĨŝƌŵŶŽůĞĂŬƐ͘ ϯϴ͘ /ĨZ,WůƵŐǁĂƐƌƵŶŝŶyEEŝƉƉůĞ͕Z/,ǁŝƚŚďĂůůĂŶĚƌŽĚĂŶĚƐĞƚŝŶϮͲϳͬϴ͛͛yEŶŝƉĂƚΕϭϬϭϯϵ͛D͘ Ă͘ WƌĞƐƐƵƌĞƵƉdďĂĐŬƐŝĚĞĂŶĚŚLJĚƌĂƵůŝĐĂůůLJƐĞƚƚŚĞƉĂĐŬĞƌĂƐƉ ĞƌĂŬĞƌƐƐĞƚƚŝŶŐƉƌŽĐĞĚƵƌĞ͘ ď͘ WƌĞƐƐƵƌĞƵƉĂŶĚƚĞƐƚƚŚĞƚƵďŝŶŐƚŽϯϳϱϬƉƐŝĨŽƌD/dͲdǁŝƚŚϭϬ ϬϬƉƐŝŽŶƚŚĞ/;dŚŝƐǁŝůů ƐĞƌǀĞĂƐƚŚĞW&DK^WƉƌĞƐƐƵƌĞƚĞƐƚͿ͘ůĞĞĚŽĨĨƚŚĞƚƵďŝŶŐƚŽϭϬϬϬƉƐŝ͘dĞƐƚƚŚĞ/ƚŽϮϬϬϬ ƉƐŝĨŽƌD/dͲ/͘ZĞĐŽƌĚĂŶĚŶŽƚĂƚĞĂůůƉƌĞƐƐƵƌĞƚĞƐƚƐ;ϯϬŵŝŶƵƚĞƐͿŽŶĐŚĂƌƚ͘ ϯϵ͘ /ĨďƵƌƐƚĚŝƐĐǁĂƐƌƵŶĂŶĚĚŝĚŶŽƚďƵƌƐƚ͕Z/,ǁͬƐƉĞĂƌƚŽďƌĞ ĂŬďƵƌƐƚĚŝƐĐ͘ ϰϬ͘ WKK,͘ ϰϭ͘ Z/,ǁŝƚŚϭ͘ϱ͛͛:^EĂŶĚ'Zͬ>ĂŶĚƉĞƌĨŽƌŵĂ&KƵƐŝŶŐEϮƚŽϭϯϭϮϬƚĂŬŝŶŐƌĞƚƵƌŶƐƚŽƚĂŶŬƐŽƌƉŽƌƚĂďůĞ ƐĞƉĂƌĂƚŽƌ͘ Ă͘ EŽƚĞD/E/ŽĨϭ͘ϳϭϴ͟ƚŚƌŽƵŐŚŝƐŽůĂƚŝŽŶƐůĞĞǀĞ͘ ϰϮ͘ Z/,ĂŶĚƉƵůůďůĂŶŬŝŶŐƐůĞĞǀĞĨƌŽŵĨŽƌǁĂƌĚĐŝƌĐƵůĂƚŝŶŐ,͕WKK, ŽŶǀĞƌƚƚŽ:W tĞůů͗DWh/Ͳϭϭ ϰϯ͘ WƵŵƉŝŶ:WƐƚĂŶĚŝŶŐǀĂůǀĞ͘/Ĩ,ĚŽĞƐŶŽƚƐĞƚ͕Z/,ĂŶĚƐĞƚƚŚĞ:WƐƚĂŶĚŝŶŐǀĂůǀĞŝŶƚŚĞ:W,͘WƌĞƐƐƵƌĞ ƚĞƐƚƚŽϭϱϬϬƉƐŝ͘WKK,͘ ϰϰ͘ ƌŽƉϭϮ:ĞƚƉƵŵƉĂŶĚĐŽŶĨŝƌŵĂŐŽŽĚƐĞƚ͘/Ĩ:WĚŽĞƐŶŽƚůĂŶ ĚŝŶ,ĐĂůůK ƚŽƚƌŽƵďůĞƐŚŽŽƚ͘ ϰϱ͘ WKK,ǁŝƚŚĐŽŝůĨƌĞĞnjĞƉƌŽƚĞĐƚŝŶŐƚŚĞd'ĨƌŽŵϮ͕ϱϬϬ͛DƚŽƐƵƌĨĂĐĞ͘ ϰϲ͘ ZŽŝů͘ ϰϳ͘ dƵƌŶǁĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶǀŝĂŚĂŶĚŽǀĞƌĨŽƌŵ͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƐͲďƵŝůƚ^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘ ^ZKWƐƚĂĐŬƐŬĞƚĐŚ ϰ͘ ϮϬϮϱ͘Ϯϲϱ;ĐͿǀĂƌŝĂŶĐĞƌĞƋƵĞƐƚ ϱ͘ WƌŽƉŽƐĞĚdƌĞĞŽŶĨŝŐƵƌĂƚŝŽŶ ϲ͘ ŽŝůĞĚdƵďŝŶŐEŝƚƌŽŐĞŶŝĂŐƌĂŵ 3DVVLQJ 1RIORZWHVWSULRUWR323:HOOWEHVKXWLQIRUPLQLPXPRIKRXUSULRUWR QRIORZ WHVWPJU BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚLJ͗d&ϮͬϴͬϮϬϮϭ ^, Dd/ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWh/Ͳϭϭ >ĂƐƚŽŵƉůĞƚĞĚ͗ϭϭͬϭϱͬϮϬϮϬ Wd͗ϮϬϭͲϭϯϳ dсϭϯ͕ϭϳϬ͛;DͿͬdсϯ͕ϲϰϰ͛;dsͿ ϮϬ´ KƌŝŐ͘& ůĞǀ͘сϲϰ͘ϳϬ͛ͬKƌŝŐ͘'> ůĞǀ͘сϯϰ͘ϳϬ͛ ϳ͟ ³2$´/DWHUDO Wdсϭϯ͕ϭϳϬ͛;DͿͬWdсϯ͕ϲϰϰ͛;dsͿ ³2%´/DWHUDO ϭϬͲϯͬϰ´ 0LQ,' ´ ^/E' d/> ^ŝnjĞ dLJƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ W& ϮϬΗ ŽŶĚƵĐƚŽƌ ϵϰͬ,ͲϰϬ ϭϵ͘ϭϮϰ ^ƵƌĨĂĐĞ ϭϬϭΖ Ϭ͘ϯϱϱ ϭϬͲϯͬϰ͟ ^ƵƌĨĂĐĞ ϰϱ͘ϱͬ>ͲϴϬͬd ϵ͘ϵϱϬ ^ƵƌĨĂĐĞ Ϯ͕ϳϯϬ͛ Ϭ͘ϬϵϲϬ ϳΗ /ŶƚĞƌŵĞĚŝĂƚĞ Ϯϲͬ>ͲϴϬͬ,LJĚƌŝůϱϮϭ ϲ͘Ϯϳϲ ^ƵƌĨĂĐĞ ϭϬ͕ϳϰϴ͛ Ϭ͘Ϭϯϴϯ ϰͲϭͬϮ͟ ^ůŽƚƚĞĚ>ŝŶĞƌ͟͞ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϭϬ͕ϰϬϲ͛ ϭϮ͕ϵϵϵ͛ Eͬ ϰͲϭͬϮ͟ ^ůŽƚƚĞĚ>ŝŶĞƌ͟͞ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϭϬ͕ϳϲϭ͛ ϭϯ͕ϭϮϱ͛ Eͬ dh/E' d/> ϮͲϯͬϴ͟ dƵďŝŶŐ ϰ͘ϳͬ>ͲϴϬͬ h ϴƌĚ ϭ͘ϵϵϱ ^ƵƌĨĂĐĞ ϵ͕ϲϱϴ͛ Ϭ͘ϬϬϯϴϳ ϰͲϭͬϮ͟ dƵďŝŶŐ ϭϮ͘ϲͬ>ͲϴϬͬE^Ͳd ϯ͘ϵϱϴ ϭϬ͕ϭϴϰ͛ ϭϬ͕ϯϬϯ͛ Ϭ͘ϬϭϱϮ : t >Zz d/> EŽ ĞƉƚŚ /ƚĞŵ ϭ ϯϵ͛ ϮͲϳͬϴ͟džϮͲϯͬϴ͟ƌŽƐƐŽǀĞƌ Ϯϭϴϯ͛^ƚĂηϭ͗ϮͲϯͬϴ͟džϭ͟'>DǁͬKƌŝĨŝĐĞsĂůǀĞ ϯ ϵ͕ϱϱϴ͛ ϮͲϯͬϴ͟yEͲEŝƉƉůĞ;ϭ͘ϴϳϱEŽͲŐŽ/Ϳ ϰ ϵ͕ϲϬϱ͛ ŝƐĐŚĂƌŐĞ,ĞĂĚ͗ŽůƚŽŶΘWŽƌƚĞĚĞŶŝƚŚ ϱ ϵ͕ϲϬϳ͛ WƵŵƉ͗ϰϬϬWD^^&> yϳ ZϭϬϵ,ϲ ϲ ϵ͕ϲϮϲ͛ 'ĂƐ^ĞƉĞƌĂƚŽƌĂŶĚǀŽŝĚĞƌ͗ϰϬϬ'^ sDd,ϲͬϰϬϬ'Zs/dzhW ϳ ϵ͕ϲϯϮ͛ hƉƉĞƌdĂŶĚĞŵ^ĞĂů͗'^,ϲ^ͬW&^ ϴ ϵ͕ϲϯϵ͛ >ŽǁĞƌdĂŶĚĞŵ^ĞĂů͗'^,ϲ^ͬW&^ ϵ ϵ͕ϲϰϲ͛ DŽƚŽƌ͗ ϱϲϮdžƉϭϬϬ,Ɖͬϭ͕ϴϮϬsͬϯϰ ϭϬ ϵ͕ϲϱϰ͛ DŽƚŽƌ'ĂƵŐĞĂŶĚĞŶƚƌĂůŝnjĞƌ͗ĞŶŝƚŚʹŽƚƚŽŵΛϵ͕ϲϱϴ͛ ϭϭ ϭϬ͕Ϯϭϱ͛ ĂŬĞƌ^ͲϯWĞƌŵĂŶĞŶƚWĂĐŬĞƌϳ͟džϰ͘ϱ͟ ϭϮ ϭϬ͕Ϯϯϵ͛ ϰ͘ϱ͟yEͲEŝƉƉůĞʹ ϯ͘ϳϮϱ͟EŽ'Ž ϭϯ ϭϬ͕ϯϬϮ͛ ϰ͘ϱ͟dͲ//t> 'ʹ ŽƚƚŽŵΛϭϬ͕ϯϬϯ͛ ϭϰ ϭϬ͕ϯϯϲ͛ ĂŬĞƌ,ŽŽŬtĂůů͕,ĂŶŐĞƌĂďŽǀĞϳ͟tŝŶĚŽǁ ϭϱ ϭϬ͕ϯϲϬ͛ ĂŬĞƌ,ŽŽŬtĂůů͕,ĂŶŐĞƌŽƵƚƐŝĚĞϳ͟tŝŶĚŽǁ ϭϲ ϭϬ͕ϱϲϳ͛ ĂŬĞƌyW>ŝŶĞƌdŽƉWĂĐŬĞƌ ϭϳ ϭϬ͕ϱϴϮ͛ ĂŬĞƌϳ͟džϱ͟,D>ŝŶĞƌ,ĂŶŐĞƌ EŽƚĞƐ͗EĂďŽƌƐϮϮ Z<ƚŽd,&сϮϴ͘ϭ͖͛EĂďŽƌƐϯ^Z<ƚŽd,&сϮϭ͘ϱ͛'сϲ͘ϲ͛ ůůĚĞƉƚŚƐĂƌĞĐŽƌƌĞĐƚĞĚďĂĐŬƚŽŽƌŝŐŝŶĂůZ<͘ KW E,K> ͬ D Ed d/> ϮϬΗ ŵƚǁͬϮϲϬƐdžŽĨƌĐƚŝĐƐĞƚ;ƉƉƌŽdžͿŝŶϯϬ͟,ŽůĞ ϭϬͲϯͬϰ͟ ŵƚǁͬϲϬϬƐdžŽĨW&͞>͕͟ϰϰϬƐdžůĂƐƐ͞'͟ŝŶϭϯͲϭͬϮ͟,ŽůĞ ϳ͟ ŵƚǁͬϭ͕ϰϬϬƐdžůĂƐƐ͞'͟ŝŶϵͲϳͬϴ͟,ŽůĞ t >>/E>/Ed/KE d/> <KWΛϱϬϬ͛D ϳϱƚŽϴϱĞŐ͘Ϯ͕ϵϬϬ͛ʹϭϬ͕ϯϬϬ͛ DĂdž,ŽůĞŶŐůĞсϴϲĚĞŐ͘Λϰ͕ϴϬϲ͛D ' E Z>t >>/E&K W/͗ϱϬͲϬϮϵͲϮϯϬϯϯͲϬϬͲϬϬ ƌŝůůĞĚĂŶĚŽŵƉůĞƚĞĚďLJEĂďŽƌƐϮϮ ͲϭϬͬϬϲͬϮϬϬϭ ŽŶǀĞƌƐŝŽŶƚŽ:ĞƚWƵŵƉ;EĂďŽƌƐϯ ^ͿʹϬϮͬϬϮͬϮϬϬϵ ^W/ŶƐƚĂůůďLJ^ZʹϭϭͬϭϱͬϮϬϮϬ >d Z>t/EKt d/> tŝŶĚŽǁŝŶϳ͟ĂƐŝŶŐΛ ϭϬ͕ϯϰϱ͛ƚŽϭϬ͕ϯϱϳ͛ tĞůůŶŐůĞΛtŝŶĚŽǁсϳϳĞŐ͘ t >>, d/> dƌĞĞ ϮͲϵͬϭϲ͟ʹϱD&D tĞůůŚĞĂĚ ϭϭ͟džϰ͘ϱ͟ϱD'ĞŶ͘ϲǁͬϰ͘ϱ͟dͲ//dΘdƵďŝŶŐ,ĂŶŐĞƌ/t͞,͟WsWƌŽĨŝůĞ,ŽůĞ >ĂƐƚdĂŐ͗K&KdĂŐ͗ϭϮ͕ϵϬϰ͛ŽŶϰͬϭϳͬϭϴ KŚĂƐŶĞǀĞƌďĞĞŶ&K BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚLJ͗d&ϱͬϮϰͬϮϬϮϮ WZKWK^ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWh/Ͳϭϭ >ĂƐƚŽŵƉůĞƚĞĚ͗ϭϭͬϭϱͬϮϬϮϬ Wd͗ϮϬϭͲϭϯϳ dс ϭϯ͕ϭϳϬ͛ ;DͿͬdсϯ͕ϲϰϰ͛;dsͿ ϮϬ´ KƌŝŐ͘& ůĞǀ͘сϲϰ͘ϳϬ͛ͬKƌŝŐ͘'> ůĞǀ͘сϯϰ͘ϳϬ͛ ϳ͟ ³2$´/DWHUDO Wdс ϭϯ͕ϭϳϬ͛ ;DͿͬWdсϯ͕ϲϰϰ͛;dsͿ ³2%´ /DWHUDO ϭϬͲϯͬϰ´ 0LQ,' ´ ^/E' d/> ^ŝnjĞ dLJƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ W& ϮϬΗ ŽŶĚƵĐƚŽƌ ϵϰͬ,ͲϰϬ ϭϵ͘ϭϮϰ ^ƵƌĨĂĐĞ ϭϬϭΖ Ϭ͘ϯϱϱ ϭϬͲϯͬϰ͟ ^ƵƌĨĂĐĞ ϰϱ͘ϱͬ>ͲϴϬͬd ϵ͘ϵϱϬ ^ƵƌĨĂĐĞ Ϯ͕ϳϯϬ͛ Ϭ͘ϬϵϲϬ ϳΗ /ŶƚĞƌŵĞĚŝĂƚĞ Ϯϲͬ>ͲϴϬͬ,LJĚƌŝůϱϮϭ ϲ͘Ϯϳϲ ^ƵƌĨĂĐĞ ϭϬ͕ϳϰϴ͛ Ϭ͘Ϭϯϴϯ ϰͲϭͬϮ͟ ^ůŽƚƚĞĚ>ŝŶĞƌ͟͞ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϭϬ͕ϰϬϲ͛ ϭϮ͕ϵϵϵ͛ Eͬ ϰͲϭͬϮ͟ ^ůŽƚƚĞĚ>ŝŶĞƌ͟͞ ϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϭϬ͕ϳϲϭ͛ ϭϯ͕ϭϮϱ͛ Eͬ dh/E' d/> ϯͲϭͬϮ͟ dƵďŝŶŐ ϰ͘ϳͬ>ͲϴϬͬ h ϴƌĚ ϭ͘ϵϵϱ ^ƵƌĨĂĐĞ ϭϬ͕ϭϳϴ͛ ϰͲϭͬϮ͟ dƵďŝŶŐ ϭϮ͘ϲͬ>ͲϴϬͬE^Ͳd ϯ͘ϵϱϴ ϭϬ͕ϭϴϰ͛ ϭϬ͕ϯϬϯ͛ Ϭ͘ϬϭϱϮ : t >Zz d/> EŽ ĞƉƚŚ /ƚĞŵ ϭ ϭϬ͕ϭϭϭ͛ &ŽƌǁĂƌĚŝƌĐƵůĂƚŝŶŐ:W;ŵŝŶ/͗Ϯ͘ϲϲϴ͟Ϳ Ϯ ϭϬ͕ϭϭϱ͛ 'ĂƵŐĞĂƌƌŝĞƌ ϯ ϭϬ͕ϭϱϱ͛ ĂŬĞƌWƌĞŵŝĞƌWĂĐŬĞƌ ϰ ϭϬ͕ϭϲϱ Ϯ͘ϴϳϱ͟yEEŝƉƉůĞ;Ϯ͘ϮϱϬ͟EŽͲ'ŽͿ ϱ ϭϬ͕ϭϳϴ͛ ϰͲϭͬϮ͟KǀĞƌƐŚŽƚ^ŚŽĞ ϲ ϭϬ͕ϭϳϴ͛ dŽƉŽĨϰͲϭͬϮ͟d'Ƶƚ ϳ ϭϬ͕Ϯϭϱ͛ ĂŬĞƌ^ͲϯWĞƌŵĂŶĞŶƚWĂĐŬĞƌϳ͟džϰ͘ϱ͟ ϴ ϭϬ͕Ϯϯϵ͛ ϰ͘ϱ͟yEͲEŝƉƉůĞʹ ϯ͘ϳϮϱ͟EŽ'Ž ϵ ϭϬ͕ϯϬϮ͛ ϰ͘ϱ͟dͲ//t> 'ʹ ŽƚƚŽŵΛϭϬ͕ϯϬϯ͛ ϭϬ ϭϬ͕ϯϯϲ͛ ĂŬĞƌ,ŽŽŬtĂůů͕,ĂŶŐĞƌĂďŽǀĞϳ͟tŝŶĚŽǁ ϭϭ ϭϬ͕ϯϲϬ͛ 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Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Convert to ESP Hilcorp Alaska 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 13,170 feet N/A feet true vertical 3,644 feet N/A feet Effective Depth measured 13,170 feet 10215 & 10,567 feet true vertical 3,644 feet 3,565 & 3,647 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)2-3/8" 4.7# / L-80 / EUE 8rd 9,658' 3,434' Packers and SSSV (type, measured and true vertical depth)S-3 & ZXP LTP 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 13. Prior to well operation: Subsequent to operation: 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: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: WINJ WAG 10 Water-Bbl MD 101' 2,730' 10,748' TVD 101' 0 Oil-Bbl measured true vertical Packer 4-1/2" 13,124' 13,170' Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 27 Representative Daily Average Production or Injection Data 2140 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 201-137 50-029-23033-00-00 Plugs ADL0025517 & ADL0025906 5. Permit to Drill Number: MILNE POINT / SCHRADER BLUFF OIL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-112 245 Authorized Signature with date: Authorized Name: David Gorm dgorm@hilcorp.com Size 100 MILNE PT UNIT I-11 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 2,421 Casing Pressure Tubing Pressure 0 N/A measured 2,593' 2,364' N/A Liner "A" Liner "B" Casing Conductor Length 101' 2,730' 10,748' Surface Intermediate 20" 10-3/4" 7" 4-1/2" 8,430psi 2,730' 3,676' 3,644' 5,410psi 7,500psi Burst N/A 3,580psi 7,240psi 8,430psi 7,500psi 777-8333 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse N/A 2,090psi 3,695' Form 10-404 Revised 3/2020 Submit Within 30 days of Operations Chad Helgeson (1517) 2021.02.09 17:49:08 - 09'00' By Samantha Carlisle at 8:41 am, Feb 10, 2021 DSR-2/10/21MGR19FEB2021 RBDMS HEW 2/10/2021 SFD 2/10/2021 _____________________________________________________________________________________ Updated By: TDF 2/8/2021 SCHEMATIC Milne Point Unit Well: MPU I-11 Last Completed: 11/15/2020 PTD: 201-137 TD =13,170’(MD) / TD =3,644’(TVD) 20” Orig. DF Elev. = 64.70’ / Orig. GL Elev.= 34.70’ 7” 1 3 4 5 13 6 7 & 8 12 9 11 “OA” Lateral PBTD =13,170’(MD) / PBTD =3,644’(TVD) 2 “OB” Lateral 10-3/4” Min ID = 3.725” 10 14 15 16 17 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 94 / H-40 19.124 Surface 101' 0.355 10-3/4” Surface 45.5 / L-80 / BTC 9.950 Surface 2,730’ 0.0960 7" Intermediate 26 / L-80 / Hydril 521 6.276 Surface 10,748’ 0.0383 4-1/2” Slotted Liner “A” 12.6 / L-80 / IBT 3.958 10,406’ 12,999’ N/A 4-1/2” Slotted Liner “B” 12.6 / L-80 / IBT 3.958 10,761’ 13,125’ N/A TUBING DETAIL 2-3/8” Tubing 4.7 / L-80 / EUE 8rd 1.995 Surface 9,658’ 0.00387 4-1/2” Tubing 12.6 / L-80 / NS-CT 3.958 10,184’ 10,303’ 0.0152 JEWELRY DETAIL No Depth Item 1 39’ 2-7/8” x 2-3/8” Crossover 2183’Sta #1: 2-3/8” x 1” GLM w/ Orifice Valve 3 9,558’ 2-3/8” XN-Nipple (1.875 No-go ID) 4 9,605’ Discharge Head: Bolt on & Ported Zenith 5 9,607’ Pump: 400PMSSD FLEX7 ER 109 H6 6 9,626’ Gas Seperator and Avoider: 400GSEV MT H6 / 400 GRAVITY CUP 7 9,632’ Upper Tandem Seal: GSBDB H6 SB/AB PFSA 8 9,639’ Lower Tandem Seal: GSBDB H6 SB/AB PFSA 9 9,646’ Motor: 562xp 100Hp / 1,820V / 34A 10 9,654’ Motor Gauge and Centralizer: Zenith – Bottom @ 9,658’ 11 10,215’ Baker S-3 Permanent Packer 7” x 4.5” 12 10,239’ 4.5” XN-Nipple –3.725” No Go 13 10,302’ 4.5” TC-II WLEG –Bottom @ 10,303’ 14 10,336’ Baker Hook Wall, Hanger above 7” Window 15 10,360’ Baker Hook Wall, Hanger outside 7” Window 16 10,567’ Baker ZXP Liner Top Packer 17 10,582’ Baker 7” x 5” HMC Liner Hanger Notes: Nabors 22E RKB to THF = 28.1’; Nabors 3S RKB to THF = 21.5’' = 6.6’ All depths are corrected back to original RKB. OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset (Approx) in 30” Hole 10-3/4” Cmt w/ 600 sx of PF “L”, 440 sx Class “G” in 13-1/2” Hole 7” Cmt w/ 1,400sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 500’ MD 75 to 85 Deg. 2,900’ – 10,300’ Max Hole Angle = 86 deg. @ 4,806’ MD GENERAL WELL INFO API: 50-029-23033-00-00 Drilled and Completed by Nabors 22E - 10/06/2001 Conversion to Jet Pump (Nabors 3ES) – 02/02/2009 ESP Install by ASR – 11/15/2020 LATERAL WINDOW DETAIL Window in 7” Casing @ 10,345’ to 10,357’ Well Angle @ Window =77 Deg. WELLHEAD DETAIL Tree 2-9/16” – 5M FMC Wellhead 11” x 4.5” 5M Gen. 6 w/ 4.5” TC-II T&B Tubing Hanger CIW “H” BPV Profile Hole Last Tag:OB FCO Tag: 12,904’ on 4/17/18 OA has never been FCO Well Name Rig API Number Well Permit Number Start Date End Date MP I-11 CTU 50-029-23033-00-00 201-137 9/6/2020 1/22/2021 No operations to report. No operations to report. 9/5/2020 - Saturday CTU #6 - MU TBG Cutter BHA and RIH. Correct depth to EOP Flag, RIH past cut depth then PU to 10,184'. Pump 1/2" Ball, fired cutter and POOH. At surface LD the BHA and RD 9/8/2020 - Tuesday 9/6/2020 - Sunday CTU #6 - MIRU, MU Fishing BHA and RIH. Tag Jet Pump at 10,153', PU and paint EOP Flag, straight pull 10k to verify we are latched on and pulled free 8k over at 29k. PUH and WHP increasing from tight tolerance on seals, RIH then PU, WHP dropping off and stabilized at ~250psi, POOH FP down the backside with diesel. OOH PU injector and LD Jet Pump. 9/7/2020 - Monday 9/4/2020 - Friday No operations to report. 9/2/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 9/3/2020 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP I-11 CTU 50-029-23033-00-00 201-137 9/6/2020 1/22/2021 11/13/2020 - Friday PJSM, Current weather -7 with 10-15mph winds. Continued MIRU ASR and ancillary equipment. Set Stairs, Spotted pump and Glycol Unit. Hooked up circulating lines and winterized. Make Final toque on Stack. Connected koomey hoses to BOP Stack. Loaded pits with 200bbls of 8.6 Brine and 30bbls of FW for testing. Replaced starter on the 300K Gen. Waiting on Glycol unit to heat up before flooding lines. Set containment and cat walk. 100k gen died call VMS and replaced fuel pump. VMS also working on portable gen for the crew changeout shack. Organized rig floor, PU BOPE Testing Equipment;Pressured up koomey and functioned BOP's MU the 2-3/8" Test Joint. Flooded Stack, manifolds and lines with fresh water. Circulated air out off system. Preformed Shell Test 250 L/ 2,500psi H. Tested BOPE per sundry as following: Annular 250 L/ 2,500psi H, Rams 250 L/ 2,500psi H, Valves 250 L/ 2,500psi H. 2 F/P Function and grease K2 and C5 re-test for good test. Blow stack dry and complete Draw down. Witness waived via email by AOGCC Inspector Matt Herrera on 11/13/20 @ 14:53 hrs. Check IA Pressure on a Vac., Pull test Plug and BPV tbg on a vac.as well. BOLDS. Install 4.5" TC-II Landing Jnt 8.5 rounds to make up. Pick up on TBG hanger off seat @ 51K. slowly pull up to 175K. TBG not showing signs of being free. Last up wt. was 75K in 2009. Work String From 80K to 150K not showing any signs of coming free. Verify that well was not freezing due to temp. Circulate 2BPM at 135psi caught pressure 100psi at 1.5 Bbls away. caught returns at 6 Bbls away. Called town engineer to discuss plan forward. Cont. to work TBG from 80K to 150K while line up E-line to re-cut tbg. 11/11/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary R/U LRS. Pressure test lines to 250 psi low and 2,500 psi high. T/I/O = 143/18/157 psi. FL shot on Tubing is at Surface. FL shot on IA is at 60'. Begin circulating at 1 BPM and 275 psi with 20 bbls of 180 degree diesel down the tubing while taking returns out of the IA and to the Tiger Tank on a wide open choke. T/I/O = 306/30/171 psi. Lost 13 bbls to formation. Begin circulating at 5 BPM and 615 psi with 155bbls of 85 degree Source Water down the tubing while taking returns out of the IA and to the Tiger Tank on a wide open choke. T/I/O = 615/100/196 psi. Reduced rate from 5 BPM to 4 BPM and then to 3 BPM in order to reduce losses. Choke was open full. (155 bbls away with 72 bbls of losses);Shut down and monitor pressures when Tubing full of Source water (155 bbls away with 72 bbls of losses). T/I/O = 156/286/248 psi. Continue to circulating at 3 BPM and250 psi with 85 degree Source Water down the tubing while taking returns out of the IA and to the Tiger Tank on a wide open choke. IA pressure starts to slowly increase to 500 psi yet returns to tank start to slowly reduce. Troubleshoot. Discover choke is frozen. Bypass that choke and continue pumping. Continue to circulating at 4 BPM and300 psi with 85 degree Source Water down the tubing while taking returns out of the IA and to the Tiger Tank on a wide open choke. Shut down when 390 bbls of returns had been recovered out the IA. This required 544 bbls of circulation. A total of 135 bbls was lost to formation.T/I/O = 267/93/215 psi. Monitor well. T/I/O = 132/132/200 psi and holding rock steady. Pump 3 bbls of 60/40 down IA and Tubing and in lines. Bullhead 100 bbls of Source Water down tubing at 1-3 BPM at 400- 690 psi. Shut down and monitor well. T/I/O 698/687/326 psi. After 30 minutes of monitoring T/I/O 312/316/330 psi and slowly falling. FP Tubing and surface lines with 6 bbls of 60/40. RDMO. 11/12/2020 - Thursday ND Well Head, NU 11" Yellow Jacket BOPE, Spot In Mud Boat and Well Hut. Begin moving and Staging Equipment on location from L-14. Start spotting in Equipment. Move Pits, BOPE accumulator to location. Spot in. Spot in ASR rig. Level out rig .Crane ops Fly the Work floor, Lay out BOPE lines, Set work floor stairs. Stand the Rig in the air. Well Name Rig API Number Well Permit Number Start Date End Date MP I-11 CTU 50-029-23033-00-00 201-137 9/6/2020 1/22/2021 Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. Held PJSM and discussed daily ops. Checked fluids and serviced rig. Continued working pipe From Hanger depth 51k to PU @ 150k. Contacted HAL EL and Well Tec to make tbg cut. While waiting on HAL EL and Well Tec to arrive from Prudhoe L/D 4- 1/2" 40' Landing Joint. PU/MU 4-1/2" TC-11 x 4-1/2" IF XO Sub and 19' 5" Drill Pipe Pup into hanger. This will allow more clearance for spacing out EL Tools and the Tractor. Screwed in Power Swivel to landing jt. Worked pipe while circulating well @ 4.5bpm/500psi with PU to 150k. Was unsuccessful. Waiting on EL and Well Tec to arrive;EL on location. Spotted EL. Set pipe in slips 103k (20k over calculated string weight). Leave stump 38' of room to PU WL Tools. Well Tec arrived at 14:30pm. Held PJSM and discussed EL and Tractor operation with all parties involved. Continued RU MU 4-1/2" Pump-in Sub and Pack- off, MU 3.625 Jet Cutter and 2-1/8" CCL, MU 3-1/8" Tractor. Total tool string 35'. PU tool could not get high enough to stab the tool in the stump. had to rig up to the winch lines to get high enough. once high enough tried to stab the cutter in the stump but could not get past tool jnt.. after investigating found that the tool jnt on the 5" drill pipe was a 3.23" ID. Cutter @ a 3.652"OD. RD HES, Land tbg hanger, LD 5" landing jnt. RILDS, UD flow spool, NU Shooting flange with 7" Ottis head. RU HES. RIH with EL cutter with Tractor start tracking at 2,700'MD-10,152' Correlate depth with CCL to Cutter 10.33' at sliding sleeve at 10,118'. Cut depth @ 10,178' MD. POOH with EL. 11/14/2020 - Saturday No operations to report. 11/17/2020 - Tuesday 11/15/2020 - Sunday Held PJSM, checked fluids and serviced rig. Finished RD HAL EL. ND the 7-1/16" Shooting Flange. NU 11' Flow spool and 6" Flowline. PU 4-1/2" handling tools, PU/MU 4-1/2" Landing Joint. BOLDS, Pulled Tbg Hanger off seat @ 51k and PU to Rig Floor. Clean PUW of 75k. BO/LD Landing Joint and Tbg Hanger. Filled hole w/ 7bbls of 8.6 Brine. POH L/D 30 joints of 4-1/2" 12.6/L-80/NS-CT . Spooling Tech-wire and removing Canon Clamps. PUW 65k. No drag or overpull encountered during trip. Pumping over pipe displacement due to the tbg string being oily, pit lose of 22bls. Total of 30 joints L/D. POH L/D 45 Joints of 4-1/2" 12.6/L-80/NS-CT Tbg. Spooling Tech-wire and removing Canon Clamps. PUW 54k. No drag or overpull encountered during trip. Pumping over pipe displacement due to the tbg string being oily,pit lose of 10 bbls. Total of 75 joint L/D. POH L/D 50 Joints of 4-1/2" 12.6/L-80/NS-CT Tbg . Spooling Tech-wire and removing Canon Clamps. PUW 40k. No drag or overpull encountered during trip. Pumping over pipe displacement due to the tbg string being oily, pit lose of 54bbls. Total of 150jts L/D. POH L/D 60 Joints of 4-1/2" 12.6/L-80/NS-CT Tbg . Spooling Tech-wire and removing Canon Clamps. PUW 18k. No drag or over pull encountered during trip. Pumping over pipe displacement due to the tbg string being oily, pit loss of 55bbls. 210 total jnts LD;PJSM Discuss plan forward. Service and inspect rig and Equipment. Reset computer on the rig to adjust Tool Carrier Encoder. POH L/D 40 Joints of 4-1/2" 12.6/L-80/NS-CT Tbg , LD Sliding Sleeve and SPM Gauge + 20.73' of cut jnt. . Spooling Tech-wire and removing Canon Clamps.No drag or over pull encountered during trip. Pumping over pipe displacement due to the tbg string being oily, pit loss of 35bbls. L/D 250 Full Joints + One 20' Cut Joint. Tbg was in good condition, clean of debris. Fluid loss to formation during trip=176bbls of 8.6 Brine;Swap over to 2 3/8" Handling equipment, Un-load all 4.5" tbg and BHA. Prep work floor to RIH with New ESP, Load Prep and tally new ESP Completion and TBG. PU and service New ESP completion, connect Down Hole Gauge,String #2 Cable over Sheave and connect, Make up 2 3/8" discharge head with Pup sub, 1 jnt, XN assembly (no-go 1.875") Make final checks. Test Good. RIH/w ESP completion on 2 3/8" 4.7# EUE 8Rnd TBG. From 139'MD to 2,613' MD DW 11K, Clamping every collar for first 10 then every other collar there after. testing cable integrity every 2,000'. Cable test good. RDMO. 11/16/2020 - Monday From 139'MD to 2,613' MD DW 11K, Clamping every collar for first 10 then every other collar there after. testing cable integrity every 2,000'. Cable test good. RDMO. . Cut depth @ 10,178' MD. Well Name Rig API Number Well Permit Number Start Date End Date MP I-11 CTU 50-029-23033-00-00 201-137 9/6/2020 1/22/2021 AOGCC SVS test post re-connect - Passed (Bob Noble) No operations to report. 11/21/2020 - Saturday No operations to report. 11/24/2020 - Tuesday 11/22/2020 - Sunday No operations to report. 11/23/2020 - Monday 11/20/2020 - Friday No operations to report. 11/18/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 11/19/2020 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP I-11 CTU 50-029-23033-00-00 201-137 9/6/2020 1/22/2021 11/27/2020 - Friday No operations to report. 11/25/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 11/26/2020 - Thursday (Pressure test surface lines 250/ 2,500psi) Pumped 16 bbls diesel down TBG. Pumped 3 bbls 60/40 down Test lateral and 3 bbls 60/40 down Prod. Lateral. Tags hung. No operations to report. No operations to report. 11/28/2020 - Saturday (Pressure test surface lines 250/ 2,500psi) Pumped 40 bbls of 120° criesel down TBG. Freeze protected Prod lat with 3 bbls 60/40 and Test lat with 3 bbls 60/40. Tags hung. 12/1/2020 - Tuesday 11/29/2020 - Sunday (Pressure test surface lines 250/ 2,500psi) Pumped 50 bbls of 130° criesel down IA and pad-op started pump, continued to pump 50 bbls of 130° criesel down IA. 11/30/2020 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP I-11 SL / LRS 50-029-23033-00-00 201-137 9/6/2020 1/22/2021 No operations to report. IA Flush (Pressure test surface lines 250/2,500psi) Pump 597 bbls Produced water and 5 bbls 60/40 down IA. WELL S/I ON ARRIVAL, OPEN PERMIT W/PAD-OP, PT PCE 250L/1,500H. SET SLIP STOP CATCHER AT 582' SLM. PULL BKP-DPSOGLV (valve looks good) FROM GLM AT 150' SLM/183' MD. SET BK-DGLV IN GLM AT 150' SLM/183' MD. PULL SLIP STOP CATCHER FROM 582' SLM. RDMO, CLOSE PERMIT W/PAD-OP. 1/2/2021 - Saturday No operations to report. 1/5/2021 - Tuesday 1/3/2021 - Sunday No operations to report. 1/4/2021 - Monday 1/1/2021 - Friday IA FL Shot 1 second, 600' 12/30/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 12/31/2020 - Thursday Freeze Protect (ESP not lifting)(Pressure test surface lines 250/2,500psi) Pump 2 bbls 60/40 down Production Lat. 16 bbls 60/40 down Tbg and 2 bbls 60/40 down Test Lateral. Well Name Rig API Number Well Permit Number Start Date End Date MP I-11 LRS 50-029-23033-00-00 201-137 9/6/2020 1/22/2021 1/8/2021 - Friday No operations to report. 1/6/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Hot Flush Tbg (ESP Problems) (Pressure test surface lines 250/ 2,500psi) Pump 3 bbls 60/40 down Prod Latural. Pump 40 bbls 140° Cresal down Tbg. Pump 3 bbls 60/40 down Test Lateral. 1/7/2020 - Thursday No operations to report. No operations to report. No operations to report. 1/9/2021 - Saturday No operations to report. 1/12/2021 - Tuesday 1/10/2021 - Sunday No operations to report. 1/11/2021 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP I-11 LRS 50-029-23033-00-00 201-137 9/6/2020 1/22/2021 No operations to report. No operations to report. 1/16/2021 - Saturday No operations to report. 1/19/2021 - Tuesday 1/17/2021 - Sunday No operations to report. 1/18/2021 - Monday 1/15/2021 - Friday No operations to report. 1/13/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Freeze Protect (ESP problems)(Pressure test surface lines 250/ 2,500psi) Pump 90 bbls Crude down IA. Pump 16 bbls 60/40 down Tbg. Pump 2 bbls 60/40 Prod. Latural and 2 bbls 60/40 down Test Latural. Bleed both Laturals to zero. IA fluid level shot 1.5 sec- 400 psi ~975'. 1/14/2020 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP I-11 LRS 50-029-23033-00-00 201-137 9/6/2020 1/22/2021 1/22/2021 - Friday (Pressure test surface lines 250/ 2,500psi) Pumped 90 bbls criesel down IA and 16 bbls criesel down TBG. Pumped 3 bbls 60/40 down Prod lat and Test lat each. Tags hung. 1/20/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 1/21/2020 - Thursday No operations to report. No operations to report. No operations to report. 1/23/2021 - Saturday No operations to report. 1/26/2021 - Tuesday 1/24/2021 - Sunday No operations to report. 1/25/2021 - Monday THE STATE 01ALASKA GOVERNOR MIKE DUNLEAVY Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU I-11 Permit to Drill Number: 201-137 Sundry Number: 320-112 Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, n sie L. Chmielowski Commissioner DATED this 13 day of March, 2020. iB[7MSL46�4 MAR 162020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 280 RECEIVED MAR 11 2020 075 31/31X? AOGCC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Convert to ESP 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: :, S Hilcorp Alaska LLC Exploratory ❑ Development ❑✓ Stratigraphic Service El❑ 201-137 P 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-23033-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 ' Will planned perforations require a spacing exception? Yes ❑ No El MILNE PT UNIT 1-11 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0025517• AbL. 007-S-li(V MILNE POINT/ SCHRADER BLUFF OIL + 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 13,170' 3,644' 13,170' 3,644' 1,095 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 101' 20" 101' 101' N/A N/A Surface 2,730' 10-3/4" 2,730' 2,730' 3,580psi 2,090psi Intermediate 10,748' 7" 10,748' 3,676' 7,240psi 5,410psi Liner "A" 2,593' 4-1/2" 13,124' 3,644' 8,430psi 7,5OOpsi Liner"B" 2,364' 4-1/2" 13,170' 3,695' 8,430psi 71500psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 4-1/2" 12.6# / L-80 / NS -CT 10,303 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): S-3 & ZXP Liner Top Packer and N/A 10,215(MD)/ 3,565(TVD) & 10,567'(MD) & 3,647'(TVD) and N/A 12. Attachments: Proposal Summary El Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Exploratory ❑ Stratigraphic ❑ Development Q Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 3/25/2020 Operations: OIL WINJ ❑ F]WDSPL EJ Suspended ElCommencing GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without priorwritten approval. Authorized Name: Chad Helgeson Contact Name: David Haakinson Authorized Title: Operations ManagerContact Email: dhaakinson hil r .Com Contact Phone: 777-8343 Authorized Signature: Date: 3/11/2020 yK'p✓ C440f Htho0w COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Numb�-e77r: Plug Integrity F-1BOPTest My Mechanical Integrity Test ❑L Location Clearance ❑ Other: ' Z soo r 1.. r Post Initial Injection MIT Req'd? Yes ❑ No ❑ 3BDMS!fL' Spacing Exception Required? Yes ❑ No Q/ Subsequent Form Required: j (D —,-I O W MAR 1 6 2020 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 03/j3� ORIGINAL �',j�%lb Submit Form and Form 10 403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. �� Anaclhl1me—ntsI in Duplicate �I'S All1�'Lf n it il..m Alaska, LL RWO: JP to ESP Well: MPU 1-11 Date: 03-11-2020 Well Name: MPU 1-11 API Number: 50-029-23033-00 Current Status: JP Producer [ONLINE] Pad: I -Pad Estimated Start Date: March 25th, 2020 Rig: ASR #1 Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 201-137 First Call Engineer: David Haakinson (907) 777-8343 (0) (307) 660-4999 (M) Second Call Engineer: Wyatt Rivard (907) 777-8434 (0) (509) 670-8001 (M) AFE Number: Job Type: ESP Swap Current Bottom Hole Pressure: 1,395 psi @ 3,547' TVD Maximum Expected BHP: 1,450 psi @ 3,547' TVD MPSP: 1,095 psi Max Inclination 86" @ 4,806' MD Max Dogleg: 8.6°/100ft @ 1,988' MD BPV Profile: 4-1/16" CIW Type H Downhole Gauge: 17 day PBU (3/27/19) 17.56 PPG PBU Extrapolation 17.86 PPG Gas Column Gradient (0.1 psi/ft) High Inclination begins at 2,400' MD Brief Well Summary: MPU producer 1-11 was drilled in 2001 and completed as a Schrader Bluff dual lateral in the Schrader Bluff OB and OA sands. From the initial well development, the productivity index of the sands was not as expected. The first two ESP completions were planning for 1,500 to 3,000 BPD of initial rate; however, the production was less than 500 BPD, leading to shaft breaks and overheating of the oversized ESPs. In 2009, the completion was changed to a jet pump design, but due to the extended reach and high deviation of the well, coiled tubing is required forjet pump change -outs. Unfortunately, the economic payout forjet pump replacements is not competitive. Now that MPU I -pad will be converted to source water injection, high pressure power fluid will no longer be available, and thus a RWO is necessary to convert the well to ESP. Notes Regarding Wellbore Condition • The 7" production casing passed an MIT -IA to 3.500 psis on 6/30/16. • Open OA shoe • Offset Injection Support: o 1-12: Shut-in Objective: • Coiled Tubing: Cut 4.5" tubing directly above Permanent S3 Packer. • ASR: Pull 4-1/2" Jet Pump Completion. • Install new Baker Hughes 150 HP motor, 109 -stage Flex 7ER, and new 2-3/8" tubing. Pre -Rig Procedure: ,,�V 'Coiled Tubing (No 10-403 Required, Propose 10-404 Requirement with Final 10-404 Closeout) 1. Shut in and freeze protect tubing and Inner -Annulus. Confirm SBHP with downhole gauge. 2. MIRU Coiled Tubing Unit with 1.75" or 2" CT and ancillary equipment. 3. If BOP test was not completed within the last 7 days, perform BOPE test to 2,500 psig High, 250 psig Low. 4. RIH w/ 4" GS and pull JP from XD sleeve @ 10,118' MD. RU LRS and PT lines to 3,000 psi. 5. RIH and tag 3.725" XN Nipple @ 10,232' MD. Flag pipe and prep for cut. B Hile.p Alaska, LLi a. Tie into Tubing Tally Dated 2/21/2009 6. POOH and PU 4.5" tubing jet cutter. a. RIH to pipe Flag Depth. b. Pick up 55' and perform tubing cut at —10,178' RKB. 7. RDMO Coiled Tubing Unit. Pumping Unit: Well Kill RWO: JP to ESP Well: MPU 1-11 Date: 03-11-2020 8. Pump TxIA volume (350 bbls) down tubing, taking returns to tank via the IA with 8.3 ppg source -water. a. After gas is circulated out of well, close IA and finish tubing kill. 9. Pump 2x Tubing Volume (320 bbls) down Tubing, taking returns to formation to finish well kill with 8.3 ppg source -water 10. Clear and level pad area in front of well. Spot rig mats and containment. 11. RD well house and flowlines. Clear and level area around well. 12. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH. a. Freeze protect is up to the discretion of the Wellsite Supervisor depending on timing for arrival of the ASR. 13. RD Little Red Services. �✓ 14. RU crane. Set BPV. ND Tree. N_U_BOPE. RD Crane, 15. NU BOPE house. Spot mud boat. Brief RWO Procedure: !; 04- 16. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines to returns tank. 17. 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/ 8.3 ppg source -water prior to pulling BPV. 18. Set TWC. 19. Test BOPE to 250 psi Low/ 2,500 psi High, and annular to 250 psi Low/ 2,000 psi High (hold each w ram/valve and test for 5 -min). Record accumulator pre -charge pressures and chart tests. a. Notify AOGCC 24 hours in advance of BOP test. O_Z, b. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. C. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 2-3/8" and 4-1/2" test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 20. Contingency: If BOPE test fails 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. H Hilcorp M.A., LL, RWO: JP to ESP Well: MPU 1-11 Date: 03-11-2020 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. 21. MIRU spooler for gauge tech -wire. 22. Bleed any pressure off casing to returns tank. Pull TWC. Kill well w/ 8.3 ppg source -water as needed 23. MU 4-1/2" landing joint and PU on the tubing hanger. a. The Nabors 3ES PU weight during the 2009 completion was 73K lbs /SOP= 15K lbs. G b. Note that the un -buoyed string weight is —129K lbs. c. If needed, circulate (long or reverse) pill with lubricant, source -water, and/or baraclean pill prior to laying down the tubing hanger. 24. 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. a. Evaluate pulled tubing hanger for possible thread damage. If any damage is found, dispose of tubing hanger and contact well head specialist for replacement. 25. POOH and lay down the 4-1/2" tubing. a. Keep tubing for future kill string use. b. Dispose of sliding sleeve and gauge mandrel. c. Note any sand or scale inside/outside of tubing on the morning report. d. Look for over -torqued connections from previous tubing runs. e. The completion has the following amount of clamps/guards/cap-string. Send to G&I for cleaning and re -use on future wells. i. 132 Cannon Clamps ii. 1 Half Cannon Clamp 26. PU new ESP and RIH on 2-3/8" 4.7# L-80 tubing. Set base of ESP assembly at ±9,680' MD. a. 2-7/8" x 2-3/8" Hanger crossover b. Upper 2-3/8"x 1" Side -pocket GLM @ ± 200' MD with 0.25" OV c. 2-3/8" tubing d. 2-3/8" XN (1.791" No -Go) Nipple e. 1 joint of 2-3/8" tubing f. 2-3/8" x 2-7/8" Crossover g. Downhole gauge for discharge temperature and pressure. i. Connected with a jumper from the lower sensor. Does not require a separate tech -wire. h. Baker Hughes 109 stage Flex7ER ESP i. Gas Separator j. 150 HP Baker Hughes 562XP Motor k. Motorgauge I. Base of ESP centralizer @ ± 9,680' MD. 0 Hilcorp Alaska, LU RWO: JP to ESP Well: MPU 1-11 Date: 03-11-2020 27. Land tubing hanger. RILDS. Lay down landing joint. Note Pick-up and slack -off weights on tally. 28. Set BPV. Post -Rig Procedure: 29. RD mud boat. RD BOPE house. Move to next well location. 30. RU crane. ND BOPE. 31. NU new 2-9/16" 5,000# tree. Test tubing hanger void to 500 psi low/5,000 psi high. 32. Pull BPV. 33. RD crane. Move returns tank and rig mats to next well location. 34. Replace gauge(s) if removed. 35. Turn well over to production. RU well house and flowlines. Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOP Schematic Milne Point Unit Well: MPU I-11 SCHEMATIC Last Completed: 2/02/2009 HJlcoro Alaska, LLC PTD: 201-137 WELLHEAD Orig. DF Elev. = 64.70' / Orig. GL Elev. 34.70' Tree -1/16"-5M FMC"x4.5"5M ID Top Gen. 6w/4.5"TC-IIT&B F4 Prior to setting or pulling4.5"BPV Wellhead bing Hanger ClW"H"B PV Profile Hole or TWC, notify FMC 4.5"TC11 thread Surface 101' profile compatibility issue exists. TD=13,170' (MD) /TD =3,644'(TVD) PBTD = 13,170' (MD) / PBTD = 3,644'(TVD) OPEN HOLE / CEMENT DETAIL Cmt w/ 260 sx of Arcticset (Approx) in 30" Hole Coot w/ 600 sx of PF "L", 440 sx Class "G" in 13-1/2" Hole Cmt w/ 1,400sx Class "G" in 9-7/8" Hole CASING DETAIL )e Wt/Grade/Conn ID Top Btm BPF ictor 94/H-40 19.124 Surface 101' 0.355 ice 45.5/L-80/BTC 9.950 Surface 2,730' 0.0960 �diate 26/L-80/Hydri1521 6.276 Surface 10,748' 0.0383 ner"A" 12.6/L-80/IBT 3.958 10,406' 12,999' N/A ner"B" 12.6./L-80/IBT 3.958 10,761' 13,125' N/A TUBING DETAIL ng 12.6/L-80/NS-CT 1 3.958 1 Surface 10,303' 0.0152 WELL INCLINATION DETAIL KOP @ 500' MD 75 to 85 Deg. 2,900' —10,300' Max Hole Angle = 86 deg. @ 4,806' MD 76 Deg. @ Sliding Sleeve JEWELRY DETAIL epth Item 525' HES4.5"'XD' Dura Sliding Sleeve -9C Jet Pum 3/27/19 ),149' Schlumberger 5 P M Gauge— ID Change to 3.879" ),215' Baker 5-3 Packer 7"x4.5" ),239' 4.5" XN-Nipple-3.725" No Go ),302' 4.5" TC -II WLEG— Bottom @ 10,303' ),336' Baker Hook Wall, Hanger above 7" Window ),360' Baker Hook Wall, Hanger outside 7" Window ),56T Baker ZXP Li ner Top Packer ),582' Baker 7"x5" HMC Liner Hanger ibors 22E RKB to THF = 28.1; Nabors 35 RKB to THF= 21.5' A= 6.6' are corrected back to original RKB. LAIERAL WINDOW DETAIL Window in 7" Casing @ 10,345'to 10,357' Well Angle @ Window =77 Deg. GENERAL WELL INFO API: 50-029-23033-00-00 Drilled and Completed by Nabors 22E - 10/06/2001 Conversion to Jet Pump (Nabors BES) — 02/02/2009 NOTES: N/A OA has never been FCO Last Tag: OB FCO rag: 12,904' on 4/17/18 Updated By: D.Haakinson 3/28/19 (JP Changeout) u HilcorP Alaska, L Orig. DF Elev. = 64.79 / Drig. GL Elev. 34.79 10.3/4" Mn ID=3.723' 2 3 4 5 6 7 PROPOSED Milne Point Unit Well: MPU 1-11 Last Completed: 2/02/2009 PTD: 201-137 Tree 2-9/16"—SM FMC 10-3/4' Wellhead it"x4.5"SM Gen.6w/4.5"TC-IIT&B Prior to setting or pulling 4.5"7PV 7" Tubing Hanger CIW "H" BPV Profile Hole or PNC, notify FMC. 4.5" TCII thread 94/H-40 19.124 profile compatibility issue exists. Ur EIV RULE/ ULIVICIVI UC IHIL 20" Cmt w/ 260 sx of Arcticset (Approx) in 30" Hale 10-3/4' Cmt w/ 600 sx of PF "L", 440 sx Class "G" in Top 13-1/2" Hole 7" 1 Cmt w/ 1,400sx Class "G" in 9-7/8" Hole Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 94/H-40 19.124 Surface 101' 0.355 10-3/4" Surface 45.5/L-80/BTC 9.950 Surface 2,734 0.0960 7" Intermediate 26/L-80/Hydri1521 6.276 Surface 10,748' 0.0383 4-1/2" Slotted Liner "A" 12.6 / L-80/IBT 3.958 10,406' 12,999' N/A 4-1/2" Slotted Liner "8" 12.6/ L-80/ IBT 3.958 10,761' 13,125' N/A TUBING DETAIL WELL INCLINATION DETAIL KOP @ 500' MD 75 to 85 Deg. 2,900' —10,300' Max Hole Angle=86deg. @4,806'MD JEWELRY DETAIL No Depth Item H ±28' 2-7/8" x 2-3/8" Crossover 1 ±200' GLM #1: 2-3/8" x 1" GLM w/ 0.25" OV 2 ±9,590' 2-3/8" XN-Nipple (S.xxx No-go ID) 3 ±9,628' 2-7/8" Discharge Head 4 ±91630' Pump: 109 Stage Flex7(400 Series) 5 ±9,650' Tandem Seal Section 6 ±91670' Motor: 150 HP (562 Series) 7 ±9,680' ESP Sensor & Centralizer 8 ±10,178' 4.5" Tubing Cut 9 10,215' Baker S-3 Permanent Packer 7"x4.5" 10 10,239' 4.5" XN-Nipple — 3.725" No Go 11 10,302' 4.5- TC -11 WLEG — Bottom @ 10,303' 12 10,336' Baker Hook Wall, Hanger above 7" Window 13 10,360' Baker Hook Wall, Hanger outside 7" Window 14 10,567' Baker ZXP Liner Top Packer 15 1 10,582' 1 Baker 7" x 5" HMC Liner Hanger Notes: Nabors 21E RKB to THF= 28.1;, Nabors 35 RKB to THF = 21.5, A= 6.6' AM depths are corrected back to original RKB. 8 s GENERAL WELL INFO LATERAL WINDOW DETAIL API: 50-029-23033-00-00 W indoor in 7" Casing @ 10 Drilled and Completed by Nabors 22E -10/06/2001 10,345'to 10,357' 11 Conversion to Jet Pump (Nabors 3ES)-02/02/2009 Well Angle @ Window =77 Deg. .ate 'Qq OA has never been FCO r= x' 1- "OB" Lateral Last Tag: OB FCO Tag: 12,904' on 4/17/18 7' TD=13,179 (MD)/TD=3,644'(TVD) PBTD =13,179 (MD) / PBTD = 3,644(T7D) Updated By: DAH 3-6-2020 Milne Point ASR 11" BOP (Triple) 3/10/2020 IlilrvlUaAx. Li 1. 11" BOPE Updated 3/10/2020 STATE OF ALASKA RECEIVED AOA OIL AND GAS CONSERVATION COMItION ��, q REPORT OF SUNDRY WELL OPERATIONS 2018 1.Operations Abandon LJ Plug Perforations U Fracture Stimulate] Pull Tubing LI AGGCCr, L I Performed: Suspend ❑ Perforate ❑ Other Stimulate❑ Alter Casing ❑ CT FCO w/N2 Q Plug for Redrill ❑ .rforate New Pool ❑ Repair Wel❑ Re-enter Susp Well ❑ Other:Jet Pump Change-out' Q 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska LLC Development ❑., Exploratory ❑ 201-137 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic❑ Service ❑ 6.API Number: AK 99503 50-029-23033-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025517 MILNE PT UNIT I-11 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL 11.Present Well Condition Summary: Total Depth measured 13,170 feet Plugs measured N/A feet true vertical 3,644 feet Junk measured N/A feet Effective Depth measured 13,170 feet Packer measured 10,215&10,567 feet true vertical 3,644 feet true vertical 3,565&3,647 feet Casing Length Size MD TVD Burst Collapse Conductor 101' 20" 101' 101' N/A N/A Surface 2,730' 10-3/4" 2,730' 2,730' 3,580psi 2,090psi Intermediate 10,748' 7" 10,748' 3,674' 7,240psi 5,410psi Liner"A" 2,593' 4-1/2" 13,124' 3,644' 8,430psi 7,500psi Liner"B" 2,364' 4-1/2" 13,170' 3,695' 8,430psi 7,500psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet S#A►Nl&ED JUN 1 1201 Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80/NS-CT 10,303' 3,586' S-3 Packer Packers and SSSV(type,measured and true vertical depth) ZXP Liner Top Packer N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A 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: 48 56 0 2,615 203 Subsequent to operation: 117 24 72 2,649 197 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations CI Exploratory Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil ❑✓ Gas ❑ WDSDL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I herebycertifythat the foregoing is true and correct totheof myknowledge. SundryNumber or N/A if C.O.Exempt: g g best p 318-010 Authorized Name: Bo York Contact Name: Stan Porhola- Authorized Title: Operations Manager Contact Email: sporhola@hilcorp.com Authorized Signature: Date: 5/7/2018 Contact Phone: 777-8412 rri- 66/10//f< / 1- � RBDMSL MAY g t 'W Form 10-404 Revised 4/2017 Submit Original Only II • • Milne Point Unit Well: MPU I-11 SCHEMATIC Last Completed: 2/2/2009 Hilcorp Alaska,LL€ PTD: 201-137 WELLHEAD Tree 4-1/16"-5M FMC Wellhead 11"x 4.5"5M Gen.6 w/4.5"TC-II T&B Orig.DF Elev.=64.70'/Orig.GL Elev.=34.70' Tubing Hanger CIW"H"BPV Profile Hole f OPEN HOLE/CEMENT DETAIL 20 r ( , 20" Cmt w/260 sx of Arcticset(Approx)in 30"Hole 10 3/4" Cmt w/600 sx of PF"L",440 sx Class"G"in 13-1/2"Hole 7" Cmt w/1,400sx Class"G"in 9-7/8"Hole CASING DETAIL ,+ Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 94/H-40 19.124 Surface 101' 0.355 i 10-3/4" Surface 45.5/L-80/BTC 9.950 Surface 2,730' 0.0960 !# 7" Intermediate 26/L-80/Hydril 521 6.276 Surface 10,748' 0.0383 4-1/2" Slotted Liner"A" 12.6/L-80/IBT 3.958 10,406' 12,999' N/A 4-1/2" Slotted Liner"B" 12.6/L-80/IBT 3.958 10,761' 13,125' N/A TUBING DETAIL 4-1/2" Tubing 12.6/1-80/NS-CT 3.958 Surface 10,303' 0.0152 10-3/4" ' k WELL INCLINATION DETAIL KOP@500'MD 75 to 85 Deg.2,900'—10,300' Max Hole Angle=86 deg. @ 4,806'MD 76 Deg.@ Sliding Sleeve JEWELRY DETAIL No Depth Item 1 10,125' HES 4.5"'XD'Dura Sliding Sleeve—5C Jet Pump 4/18/18 2 10,149' Schlumberger SPM Gauge—ID Change to 3.879" 3 10,215' Baker S-3 Packer 7"x 4.5" 4 10,239' 4.5"XN-Nipple—3.725"No Go 5 10,302' 4.5"TC-II WLEG—Bottom @ 10,303' 6 10,336' Baker Hook Wall,Hanger above 7"Window 7 10,360' Baker Hook Wall,Hanger outside 7"Window 8 10,567' Baker ZXP Liner Top Packer 9 10,582' Baker 7"x 5"HMC Liner Hanger .# r : Notes:Nabors 22E RKB to THE=28.1';Nabors 35 RKB to THE=21.5'A=6.6' ! All depths are corrected back to original RKB. I LATERAL WINDOW DETAIL VI Window in 7"Casing @ 10,345'to 10,357' 4 Well Angle @ Window=77 Deg. 5C Jet Purrp '° .1• , 1 IM 4 GENERAL WELL INFO 2 API:50-029-23033-00-00 Drilled and Completed by Nabors 22E -10/06/2001 I r I k Convert to Jet Pump by Nabors 35—2/2/2009 NOTE: Nin ID=3.725' 1 4 Prior to setting or pulling 4.5"BPV or TWC,notify FMC. t0-. 5 4.5"TCII thread profile compatibility issue exists. , „ n'r 6 4 _ CLEANOUT: 7 CTU Cleaned out to TD 4/17/2018 J 411— p, "OA'L aterd 4ea ql "OB"Latera 41 7 TD=13,170'(MD)/TD=3,644'(TVD) PBTD=13,170'(MD)/PBTD=3,644'(TVD) Updated By:TDF In Progress I Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP 1-11 CTU 50-029-23033-00-00 201-137 4/14/18 4/18/18 Daily Operations: 4/11/2018-Wednesday No activity to report. 4/12/2018 Thursday No activity to report. 4/13/2018-Friday No activity to report. 4/14/2018-Saturday MIRU SLB CTU #6 with 1.75" CT. Perform full BOP test to 250psi/3,500psi. NU BOPE on well. Install night cap.SDFN. 4/15/2018-Sunday CTU and WFD on site-Start equip- PJSM -MU BHA#1-2" OD int CTC(Pull test to 25k), 2.13" DBPV, Wt bar, Wt bar, 2.25" OD Jars, Hyd disco (9/16" ball).(PT tools to 3,500psi). 2.84" OD XO, 3.56" OD 4" GS. OAL= 19.83' Stab on well,fluid pack, pump 1 bbl down IA and 5 down the flowline of 60/40. PT to 300/4,000psi.Test downhole checks- good. Open well to 80/7/129psi. RIH with BHA#1 to pull Jet Pump-Set down at 10,115' ctmd, PU to 21k and wt broke over. Set down same 2 more times. Pump while set down and saw no further movement. POOH. Pump 10 bbls 60/40 down backside. OOH and no pump recovered. GS looked to be in the release position. Call out for another GS MU different 4" GS to BHA. On well- PT 250/3,500psi. CTU tractor went down. Call out for another tractor. Open well and RIH. Set down same at 10,115' ctmd. PU to 20k. Same as 1st run, no real overpull to indicate pump is pulled.WHP did drop 150psi after 1st PU. Went to RBIH again from 10,000' and began to stack weight. POOH. Recovered Jet pump Serial#BP-1080/5C ratio. MU B042 shifting tool for run tomorrow.SDFN. 4/16/2018- Monday CT Crew on location. Check equip. PJSM. Head to well with injector and BHA#2-2" OD int CTC(Pull test to 25k), 2.13" DBPV, Wt bar,Wt bar, 2.25" OD Jars, Hyd disco (9/16" ball), 2.13" OD XO to ported SR,4-1/2" BO42 shifting tool set to shift up to close SS. OAL= 18.54'. On Well. Fusible cap on. PT low and high -320psi/2,400psi. Open well and RIH with shifting tool.T/I/O=23/7/169 SS at 10,125' MD. Run past SS to 10,141' ctmd. PUH through SS at 20 fpm. See 1000#overpull at 10,111' ctmd. Repeat and see no overpull. Pressure up against SS to 1,800psi with power fluid. Took 5 bbls. Hold good. POOH. Bleed IA from 1,773psi to Opsi. Bled down too quick. May have ice plug in IA. Pressure up IA to 500psi with 60/40 and took.3 bbls. Hold 500psi on IA. At surface. Close SV, BD and POP off well. MU BHA#3 for Nitrified FCO-2" OD int CTC(Pull test to 25k), 2.13" DBPV,Wt bar,Wt bar, 2.84" OD XO, 2.88" OD DH filter, 2.88" OD Tempress, 3.12" OD, XO, 3.1" OD XO, 2" OD XO,3" OD JSN -OAL= 16.31'. On Well. Fusible cap on. PT low and high-300psi/2,500psi. Open well and RIH.T/I/O=22 /521/173psi Start SLK 1%down coil at 1.5 bpm taking returns to tanks. Start N2 at 500 scf/m. Coil depth =5,422' ctmd. Coil depth at 7,500'start getting returns to surface. 1.6 bpm fluid/500 scf/m N2/2,606psi CTP/84psi WHP. Continue RIH jetting,taking returns to tanks Exit tubing tail at 10,303' md.Then,set down at 10,337' ctmd. PU clean at 16k. RBIH tag same several times.Jet with weight down and unable to make hole. Setting down on Baker hook wall hanger. Unable to pass. POOH. Pumped 2 gel sweeps (15 bbls), 200 bbls SLk 1%, and 50,000 scf/N2. Send N2 unit to top off with N2. Call out for more SLK 1%. FP coil while POOH.Top well off with 10 bbls 60/40.Tag up at surface. Close SV, BD and POP off well. Change out BHA to all 2-1/8" OD. Secure well. Stand injector back.SDFN. Return tomorrow for ECO restart. • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MPI 11 CTU 50 029 23033 00 00 201-137 4/14/18 4/18/18 Dail CQ' :ratior1s = hLG Y :`p. 4/17/2018-Tuesday CTU #6: SLB Crew on location. Check equip. PJSM. Open SSV and install fusible cap. BHA#4= 2" OD int CTC(Pull test to 25k), 2.13" DBPV, Wt bar, Wt bar, 2.12" OD DH filter,Tempress tool, 2" OD XO, 2.125" OD JSN -OAL= 13.76'. Head to well. Stab on. PT to 270psi/2,600psi. Open well to 558psi SITP. Pressure up IA to 500psi with 60/40. R/U SLB N2 and cool down. RIH with coil. Park coil at 5,250' until pumping can commence. Start bleeding WHP off. PT N2 hardline to 4,000psi -good. Come on line with with SLK 1%down coil taking returns to tanks. RIH w/coil. Start FCO at 10,340'.Take 300' bites then perform 200'wiper trips to TD. Cleanout to 12,904'. Perform final wiper trip to 12,700' prior to cleaning out to TD. Unable to RBIH due to lockup. Cleanout performed 1,000' deeper than CoilCade predicted. POH to surface. Make 3 up/down passes across sliding sleeve to ensure it is clean for the opening tomorrow. Shut down N2 at 1,000'Tag up at surface. Close SV, BD and POP off well. FP well and tree with 10 bbls of 60/40. SDFN. • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP 1-11 CTU 50-029-23033-00-00 201-137 4/14/18 4/18/18 Daily Operations �1,i'i �� � ' .I 11Il;1l,ili i.. . ; 4/18/2018-Wednesday CTU 6: CT Crew on location. Check equip. PJSM. Head to well with injector and BHA#5- 2" OD int CTC(Pull test to 25k), 2.13" DBPV,Wt bar, Wt bar, 2.25" OD Jars, Hyd disco (9/16" ball), 2.13" OD XO to ported SR,4-1/2" BO42 shifting tool set to shift up to close SS. OAL= 18.54' On Well. Fusible cap on. PT low and highA-320psi/2,400psi. Open well and RIH with shifting tool. WHP is 610psi.Tag sliding sleeve at 10,115' and partially open. See IA pressure decrease from 880psi to 70 psi. P/U and attempt to open sliding sleeve completely by RIH and tagging it at 100 fpm. RIH past sliding sleeve to 10,140'. Sliding sleeve is open. POH to surface.At surface. Close SV, BD and POP off well. L/D BHA#5. MU BHA#6 for setting Jet Pump-2"OD int CTC (Pull test to 25k), 2.13" DBPV, 2.12" HD Disconnect, 2.12"Accelerator, 2.12" OD SAU Hammer, 2.12"SAD Hammer, 2.84" OD XO, 3.67"TMX Hyd X-Line Tool, 3.8"Jet pump assembly-OAL= 22.47'. On Well. Fusible cap on. PT low and high - 300psi/2,500psi. Open well and RIH w/BHA#6.At 10,075', Pump 60/40 McOH down coil at 0.3 bpm to position TMX in locate position. Pressure up to 2,000psi. Stop pumping and allow pressures to stabilize. Coil pressure bled to Opsion its own. RIH and locate nipple. Pass through nipple to 10,144'. Never latched into profile. POH to 10,075'. Pressure up to 2,000psi at 0.3 bpm. Allow pressure to equalize. Pressure bled to 100psi. RIH and attempt to engage profile with lock. Pass through to 10,145'. Still not finding profile. POH to 10,100'. Pressure up to 2,000psi at 0.3 bpm. RIH while maintaining 2,000psi. Engaged profile with lock at 10,109'. Reduce rate to 0.25 bpm. P/U to verify lock is set. See 2k-overpull. Increase rate to 0.3 bpm and increase overpull to 27,000-lbs and shear off.Turn on power fluid to jet pump.Take returns from JP production to the tanks. Shut in choke and monitor pressure build.Jet Pump is installed and operational. Shut off power fluid. POH to surface.At surface. Close SV, BD and POP off well. RDMO to MPJ-09A. 4/19/2018-Thursday No activity to report. 4/20/2018-Friday No activity to report. 4/21/2018-Saturday No activity to report. 4/22/2018-Sunday No activity to report. 4/23/2018'- Monday No activity to report. THE STAT• Alaska Oil and Gas Vtti ofA Conservation Commission :-- - 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF * 1i"Q' Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager Hilcorp Alaska, LLC SCANNED ``'�` Vii'` 2 6 '0I6 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU I-11 Permit to Drill Number: 201-137 Sundry Number: 318-010 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 Commissioner DATED this YLday of January, 2018. • , 2 I. 318 • • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JAN 10 20)8 APPLICATION FOR SUNDRY APPROVALS q�S I I/ 9 / 9r 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ I utdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ v/ T O w/N2 Elf Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Jet Pump Change-out E 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development 2 . 201-137 ` 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-029-23033-00-00 ' 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05' Will planned perforations require a spacing exception? Yes ❑ No E✓ MILNE PT UNIT 1-11 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025517 _MILNE POINT/SCHRADER BLUFF OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 13,170' 3,644' 13,170' 3,644' 1,211 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 101' 20" 101' 101' N/A N/A Surface 2,730' 10-3/4" 2,730' 2,730' 3,580psi 2,090psi Intermediate 10,748' 7" 10,748' 3,676' 7,240psi 5,410psi Liner"A" 2,593' 4-1/2" 13,124' 3,644' 8,430psi 7,500psi Liner"B" 2,364' 4-1/2" 13,170' 3,695' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic u" See Schematic 4-1/2" 12.6#/L-80/NS-CT 10,303 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): S-3&ZXP Liner Top Packer and N/A r 10,215(MD)/3,565(TVD)&10,567'(MD)&3,647'(TVD)and N/A 12.Attachments: Proposal Summary ❑✓ Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development Q ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 12/11/2017 Commencing Operations: OIL El w WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York Contact Name: Stan Porhola Authorized Title: Operations Manager Contact Email: sporhola Cr hilcorp.com Contact Phone: 777-8412 Authorized Signature: ,-----7 Date: 1/10/2018 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3q . 610 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes D No 111 Subsequent Form Required: y11)Li nr•-..,/,!...r... ✓ ".: 2 I. 2:18 APPROVED BY Approved by: 4a-Q-4-.6L. COMMISSIONER THE COMMISSION Date: /--/q-/ g Pkiialt7/0„fris. n ® Submit Form and Form 10-403 Revised 4/2017 Approved application is valid fo 1 RmitNatikftproval. Attachments in Duplicate • • Well Prognosis Well: MPU 1-11 Ili corp yin,Lt) Date:11/20/2017 Well Name: MPU 141 _ API Number: 50-029-23033-00 __ Current Status: Oil Well [Jet Pump] Pad: Milne Point I-Pad Estimated Start Date: December 11th,2017 Rig: Coil Tubing Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 201-137 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) AFE Number: Job Type: Coil Foam Cleanout Current Bottom Hole Pressure: 1,611 psi @ 4,000'TVD (Last BHP measured 6/30/2015) Maximum Expected BHP: 1,611 psi @ 4,000'TVD (No new pens being added, EMW= 7.8 ppg) MPSP: 1,211 psi (Based on 0.10 psi/ft gas gradient) Brief Well Summary: MPU I-11 was drilled in 2001 using Nabors 22E and completed as a dual-lateral in the Schrader Bluff OA and OB sands with a Jet Pump. The completion was pulled and the ESP completion changed out in 2001 using Nabors#4ES.The completion was pulled and changed out in 2009 using Nabors#3S to replace the 2-7/8"tubing ESP completion with a 4-1/2"tubing Jet Pump completion. Notes Regarding Wellbore Condition • Deviation down to pump section (max angle 85.8° @ 4,806'). • Casing last tested to 3,500 psi for 30 min down to 10,209'on 12/15/2015.' t r • Jet Pump currently active, performance continues to degrade (likely solids or pump wear). • Deviation at pump is 76.0°. • Deviation at upper window into the OA lateral is 76.0°. • Deviation at liner hanger into the OB lateral is 77.0°. • Tubing Grade is L-80. Min ID is 3.813" in the 4-1/2"and 3.725"thru XN profile. • Last Fill Depth: 12,975' MD tagged on 1/08/2017. Objective: F.-Co ...I Ai The purpose of this work/sundry is to pull the existing Jet Pump, perform a foam cleanout of the lateral and run a new Jet Pump. Brief Procedure: Coiled Tubing Procedure: 1. MIRU Coiled Tubing Unit and spot ancillary equipment. Fill source tank w/8.5 ppg 1%KCI. 2. Pressure test ROPE to 3,500 psi Hi 250 Low,10 min each test. a. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. b. No AOGCC notification required. c. Record ROPE test results on 10-424 form. 3. RIH w/2.00" coil and pull jet pump in sliding sleeve profile at+/- 10,118' MD. POOH. • Well Prognosis Well: MPU 1-11 llileara Alaska.LI) Date:11/20/2017 4. RII-1 w/2.00"coil and shift sliding sleeve closed at+/-10,118'MD. 5. Test backside to 3,500 psi for 5 min to confirm closed. POOH. 6. RIH w/2.00" coil w/2.5"to 3.5"max OD wash nozzle and extended reach cleanout BHA and cleanout to PBTD at+/-13,125' MDjin OB lateral).POOH. a. This multi-lateral is a Baker Hughes Level 3 Hook Hanger with no Lateral Entry Modules (LEM)so selective entry into the OA lateral is not possible. b. Circulate out fill using 8.5 ppg 1%KCI w/friction reducer. Pump 5-10 bbl Gel Sweeps to help remove solids from the liner. c. Contingency: If unable to wash down with nozzle,RIH w/3.0"to 3.5" mill and extended reach yy6�I,- cleanout BHA and cleanout to PBTD at+/-13,125'MD(in 08 lateral). POOH. ��1")4 7. RIH w/2.00"coil w/2.5"to 3.5"max OD wash nozzle and extended reach cleanout BHA and cleanout to PBTD at+/-13,125' MD(in OB lateral). POOH. a. Circulate out fill using 8.5 ppg 1%KCl w/liquid foamer and mix with Nitrogen(see Nitrogen procedure and diagram).Utilize defoamer for returns in Kill Tank. b. Contingency: If unable to wash down with nozzle, RIH w/3.0"to 3.5"mill and extended reach cleanout BHA and cleanout to PBTD at+/-13,125'MD(in 08 lateral) using 8.5 ppg 1%KCI w/liquid foamer and mix with Nitrogen. POOH. 8. RIH and shift sliding sleeve open at+/-10,118' MD. 9. Pump 8.5 ppg 1%KCI or 8.4 ppg power fluid to confirm open.POOH. 10. RIH and set jet pump in sliding sleeve profile at+1-10,118' MD. � 11. PU to 2,500' and freeze protect well. POOH w/coil. 12. RD Coiled Tubing and ancillary equipment. 13. Turn well over to production. Attachments: 1. As-built Schematic 2. Coil BOPE Schematic 3. Nitrogen Operations Procedure 4. Nitrogen &Foam Flow Diagram • 0 II Milne Point Unit Well: MPU I-11 SCHEMATICLast Completed: 2/02/2009 !Morn Ala,ka,l.l.t: PTD:201 137 WELLHEAD Tree 4-1/16"-5M FMC _ Wellhead 11"x 45"5M Gen.6 w/4.5"TC-lI T&B Orig.Of Etev.=64.70`/Orig.GL Elev.=34.70' Tubing Hanger CIW"H"BPV Profile Hole j : OPEN HOLE/CEMENT DETAIL t, t 20' re 20" Cmt w/260 sx of Arcticset(Approx)in 30"Hole Cmt w/600 sx of PF"1",440 sx Class"G"in 10-3/4" 13-1/2"Hole 7" Cmt w/1,400sx Class"G"in 9-7/8"Hole i �` CASING DETAIL ' Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 94/11-40 19.124 Surface 101' 0.355 ;s 10-3/4" Surface 45.5/L-80/BTC 9.950 Surface 2,730' 0.0960 r' 7" Intermediate 26/L-80/Hydril 521 6.276 Surface 10,748' 0.0383 4-1/2" Slotted Liner"A" 12.6/L-80/IRT 3.958 10,406' 12,999' N/A 4-1/2" Slotted Liner"B" 12.6/L-80/18T 3.958 10,761' 13,125' N/A 1 TUBING DETAIL • 4-1/2" Tubing ! 12.6/1-80/NS-CT 3.958 I Surface I 10,303' I 0.0152 103/ A WELL INCLINATION DETAIL KOP@500'MD 75 to 85 Deg.2,900'—10,300' Max Hole Angle=86 deg. @ 4,806'MD 76 Deg.@ Sliding Sleeve JEWELRY DETAIL No Depth Item 1 10,125' HES 4.5"'XD`Dora Sliding Sleeve—SC Jet Pump 5/10/17 2 10,149' Schlumberger SPM Gauge—ID Change to 3.879" 3 10,215' Baker S-3 Packer 7"x 4.5" 4 10,239' 4.5"XN-Nipple—3.725"No Go 5 10,302' 4.5"TC-Il WLEG—Bottom @ 10,303' 6 10,336' Baker Hook Wall,Hanger above 7"Window 7 10,360' Baker Hook Wall,Hanger outside 7"Window _8_ 10,567' Baker ZXP Liner Top Packer 9 10,582' Baker 7"x 5"HMC Liner Hanger u i ' Notes:Nabors 22E RKB to THE=28.1';Nabors 35 RKB to THE=21.5'A=6.6' 4' All depths are corrected back to original RKB. LATERAL WINDOW DETAIL p' Window in 7"Casing @ , m'— !—qilly t.44 10,345'to 10,357' is7 Well Angle @ Window=77 Deg. IGENERAL WELL INFO I- '.i API:50-029-23033-00-00 —� br s sem'i t Drilled and Completed by Nabors 226 10/06/2001 4i woo=3.725" a ( e= '`4 NOTE: ME • Prior to setting or pulling 4.5"BPV or TWC,notify FMC. rs 5 ) 4.5"TCII thread profile compatibility issue exists. ai <i6 v,( 'a'04"talo-4 41 8 CLEANOUT: : � Cleaned out w/2.30"jet swirl nozzle to 7" e i :i....c t 12,975'CTM using N2/Foam on 1/08/17. 1D=13,170'(IvO)/TD=3,644'(TVD) PBTD=13,170'(We)/PBTD=3,644'(TVD) Updated By:STP 11/20/2017 • ! II COIL BOPE MILNE POINT UNIT MPU 1-11 uih orp Akan,LIX 11/20/2017 MPU 1-11 20 X 10% X 7 X4'''/ Coil Tubing BOP Lubricator to injection head ' o 2.00"Single Stripper 0• I I Blind/Shea®= 1/16 10 =i Blind/Shear,I I. —i� Mi /0111 Blind/Shear i= •#Blind/Shear Intl : * �` iii _ ®� • -- i •0 III Slip �� �.1 Slip Ill 3a 1111111111111- 1 ).' ISI Pipe 111 MIMM! Pipe I I. 1.. 1 Crossover spool 4 1/16 10M X 4 1/16 5M ' ; ter um s Pump-In Sub s .f r Rt. 4 1/16 5M r r_,: 'q °.~j:I �.i c ��:',1+1 #i 1502 Union Manual Gate Manual Gate Valve,Swab,WKM-M, 2 1/8 5M 21/8 5M 4 1/16 SM FE � ° ,444.0 E \, .4a.\,1 'fx'.0.."c,.tib I(:(l Valve,Upper Master,Baker, 4 1/16 SM FE,w/Hydraulic 0 ..r Valve,Lower Master,WKM-M, A tip 4 1/16 SM FE 6.0",,711117.'"—"" .� Tubing Adapter,41/16 5M "–ilile M 1 • STANDARD WELL PROCEDURE llilrorp Alaa4n,LIA- 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets(formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines,adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.)Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure),whichever is higher.Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.)When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit an. bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 0 • 164 < Ell § °P § NM L. :: 1 ::.... •::.• "E I' r4 T.3 -i-o F 7-t E d co 2 cr d ce 2 cc .. ...2 4 0 eCOLia 2 Fl 'k-' 2 E.7 Lot v [IC 0 — 2 'VI 4 X Z C) c 0 ..• I- ill 6- I a. 2 ...-: a ot, x x .., _ 2F- — ..-• ,c, r. 'ia, 0 =- = 7. ;.-' a. a.. • E t) ° ,..-. .---. )., •• n c‘ '. . - b a .- .. t, ...* z g 0 74 >'. > V- 4?-‘-' _ _, ri LI ,-..., .. 0 -.. co CO 03 0 • . e4 : ..„ : .s.,:. Z F•... -1 11, > ocrtc3 ..... .3- . 1 4. 1, 2 Z g..... C . 4) * .1C 0 -C U 4, , it` -coari4itoo-- * tr. . y....i.....,±, .. / f 5 1. , A ° , . — Li,t I t.4 i lOrlf14.11—CUI 4 i II. _ 11($1L3411lle , ,..," i". ;47 , rz.! .-:-.. - 1 w •i . i re =, 1 1 1 I a. e .0 0 0 w . _ V 0., r›- f-7- . w . . 2 8 . < ... 2 v. c. I- -1 ci 1- 2 ...) 0 at 03 ia . 8 D in -.. CC co 8 v., - 0 t • • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Monday, December 18, 2017 10:48 AM To: 'Tom Fouts' Cc: Stan Porhola;samantha.carlisle@alaska.gov Subject: RE: PTD#201-137 MP I-11Sundry 317-551 Withdrawal Request Tom, AOGCC will withdraw sundry 317-551 as requested ...the scope of work was to pull a jet pump and do a FCO. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From:Tom Fouts[mailto:tfouts@hilcorp.com] Sent: Monday, December 18,2017 8:46 AM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc:Stan Porhola<sporhola@hilcorp.com> Subject: PTD#201-137 MP I-11Sundry 317-551 Withdrawal Request SCANNED 2. ( "' Guy, Hilcorp Alaska LLC requests to withdraw the approved sundry 317-551. Please feel free to contact me with any questions you may have. Regards, Tom Fouts I Senior Ops/Reg Tech Hilcorp Alaska, LLC tfouts@hilcorp.com Direct: (907)777-8398 Mobile: (907)351-5749 1 • ti of � Alaska Oil and Gas �wP7„ �y/, s THE STATE ALAsKA. Conservation Commission s _ 333 West Seventh Avenue GOVERNOR BILL WALKER" Anchorage, Alaska 99501-3572 . Main: 907.279.1433 �FALAS,tP Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager r . r:r y G 4318 Hilcorp Alaska, LLC } 3 800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU I-11 Permit to Drill Number: 201-137 Sundry Number: 317-551 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, CCX Hollis S. French Chair DATED this -3° day of November, 2017. [RBDrJS L ,.�' ,' r L17 111 11111 RECEIVED NSI , 0 2017 STATE OF ALASKA OTS Ai/;11/7 ALASKA OIL AND GAS CONSERVATION COMMISSION AOGC i APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown 0 Suspend 0 Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ CT FCO w/N2 Q Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing ❑ Other: Jet Pump Change-out 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development Q . 201-137 t 3.Address: 3800 Centerpoint Dr,Suite 14000 6.API Number: Stratigraphic ❑ Service Anchorage Alaska 99503 50-029-23033-00-00 . 7. If perforating: 8.Well Name and Number: y($ What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05' �l Will planned perforations require a spacing exception? Yes ❑ No 0 - MILNE PT UNIT(` I-11' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025517• MILNE POINT/SCHRADER BLUFF OIL ' 11. PRESENT WELL CONDITION SUMMARY 1 Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 13,170' s 3,644' • 13,170' . • 3,644' 1,211 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 101' 20" 101' 101' N/A N/A Surface 2,730' 10-3/4" 2,730' 2,730' 3,580psi 2,090psi Intermediate 10,748' 7" 10,748' 3,676' 7,240psi 5,410psi Liner"A" 2,593' 4-1/2" 13,124' 3,644' 8,430psi 7,500psi Liner"B" 2,364' 4-1/2" 13,170' 3,695' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic / See Schematic 4-1/2" 12.6#/L-80/NS-CT 10,303 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): S-3&ZXP Liner Top Packer and N/A 10,215(MD)/3,565(TVD)&10,567'(MD)&3,647'(TVD)and N/A 12.Attachments: Proposal Summary ❑✓ Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Stratigraphic ❑ Development❑✓ • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 12/11/2017 OIL ❑✓ F WINJ ❑ WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York Contact Name: Stan Porhola Authorized Title: Operations Manager Contact Email: sporhola(a�hilcorp.com Contact Phone: 777-8412 Authorized Signatur / Date: 11/20/2017 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: , I�. 1 Plug Integrity ❑ BOP Test 0 Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No 0 SpacingException Required? L-101- Approved r E r7`�� �— f "7 p q Yes ❑ No 21 Subsequent Form Required: I0 --Y0 L L. r ��ii APPROVED BY Approved by: tka: COMMISSIONER THE COMMISSION Date: t 1..5% k...4 OHO- A ` ``(ii aRIGINAL i' Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate w Well Prognosis Well: MPU I-11 Ililearp Alaska,LL Date: 11/20/2017 Well Name: MPU I-11 API Number: 50-029-23033-00 Current Status: Oil Well [Jet Pump] Pad: Milne Point I-Pad Estimated Start Date: December 11th, 2017 Rig: Coil Tubing Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 201-137 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) AI=E Number: Job,Type: Coil Foam Cleanout Current Bottom Hole Pressure: 1,611 psi @ 4,000' TVD (Last BHP measured 6/30/2015) Maximum Expected BHP: 1,611 psi @ 4,000' TVD (No new perfs being added, EMW= 7.8 ppg) MPSP: 1,211 psi (Based on 0.10 psi/ft gas gradient) Brief Well Summary: MPU I-11 was drilled in 2001 using Nabors 22E and completed as a dual-lateral in the Schrader Bluff OA and OB sands with a Jet Pump. The completion was pulled and the ESP completion changed out in 2001 using Nabors#4ES.The completion was pulled and changed out in 2009 using Nabors#3S to replace the 2-7/8"tubing ESP completion with a 4-1/2" tubing Jet Pump completion. Notes Regarding Wellbore Condition • Deviation down to pump section (max angle 85.8° @ 4,806'). • Casing last tested to 3,500 psi for 30 min down to 10,209'on 12/15/2015. i„ • Jet Pump currently active, performance continues to degrade (likely solids or pump wear). • Deviation at pump is 76.0°. • Deviation at upper window into the OA lateral is 76.0°. • Deviation at liner hanger into the OB lateral is 77.0°. • Tubing Grade is L-80. Min ID is 3.813" in the 4-1/2" and 3.725" thru XN profile. • Last Fill Depth: 12,975' MD tagged on 1/08/2017. Objective: The purpose of this work/sundry is to pull the existing Jet Pump, perform a foam cleanout of the lateral and run a new Jet Pump. v ( CA) Brief Procedure: Coiled Tubing Procedure: 1. MIRU Coiled Tubing Unit and spot ancillary equipment. Fill source tank w/8.5 ppg 1% KCI. 2. Pressure test BOPE to 3,500 psi Hi 250 Low, 10 min each test. a. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. b. No AOGCC notification required. c. Record BOPE test results on 10-424 form. 3. RIH w/2.00" coil and pull jet pump in sliding sleeve profile at+/- 10,118' MD. POOH. • Well Prognosis Well: MPU 1-11 //'2'1'1 Ililean)Alaska,Lia Date: 11/20/2017 4. RIH w/2.00" coil and shift sliding sleeve closed at+/- 10,118' MD. i5. Test backside to 3,500 psi for `nintoconfirm closed. POOH. tC" 6. RIH w/2.00" coil w/2.5"to 3.5" max OD wash nozzle and extended reach cleanout BHA and cleanout to PBTD at+/- 13,125' MD(in OB lateral). POOH. a. This multi-lateral is a Baker Hughes Level 3 Hook Hanger with no Lateral Entry Modules (LEM)so selective entry into the OA lateral is not possible. b. Circulate out fill using 8.5 ppg 1% KCI w/friction reducer. Pump 5-10 bbl Gel Sweeps to help remove solids from the liner. c. Contingency: If unable to wash down with nozzle, RIH w/3.0"to 3.5" mill and extended reach cleanout BHA and cleanout to PBTD at+/- 13,125' MD(in OB lateral). POOH. 7. RIH w/2.00" coil w/2.5" to 3.5" max OD wash nozzle and extended reach cleanout BHA and cleanout to PBTD at+/- 13,125' MD(in OB lateral). POOH. a. Circulate out fill using 8.5 ppg 1% KCI w/liquid foamer and mix with Nitrogen (see Nitrogen procedure and diagram). Utilize defoamer for returns in Kill Tank. b. Contingency: If unable to wash down with nozzle, RIH w/3.0" to 3.5" mill and extended reach cleanout BHA and cleanout to PBTD at+/- 13,125' MD(in OB lateral) using 8.5 ppg 1% KCI w/liquid foamer and mix with Nitrogen. POOH. 8. RIH and shift sliding sleeve open at+/- 10,118' MD. 9. Pump 8.5 ppg 1% KCI or 8.4 ppg power fluid to confirm open. POOH. 10. RIH and set jet pump in sliding sleeve profile at+/- 10,118' MD. 11. PU to 2,500' and freeze protect well. POOH w/coil. 12. RD Coiled Tubing and ancillary equipment. 13. Turn well over to production. Attachments: 1. As-built Schematic 2. Coil BOPE Schematic 3. Nitrogen Operations Procedure 4. Nitrogen &Foam Flow Diagram • Milne Point Unit •II Well: MPU I-11 SCHEMATIC Last Completed: 2/02/2009 Hilcora Alaska,LLC PTD: 201-137 WELLHEAD Tree 4-1/16"-5M FMC Wellhead 11"x 4.5"5M Gen.6 w/4.5"TC-II T&B Ong.DF Elev.=64.70'/Orig.GL Elev.=34.70' Tubing Hanger CIW"H"BPV Profile Hole T �' OPEN HOLE/CEMENT DETAIL 20 20" Cmt w/260 sx of Arcticset(Approx)in 30"Hole x Cmt w/600 sx of PF"L",440 sx Class"G"in 10-3/4" 13-1/2"Hole 7" Cmt w/1,400sx Class"G"in 9-7/8"Hole ;; CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 94/H-40 19.124 Surface 101' 0.355 ( ,� 10-3/4" Surface 45.5/L-80/BTC 9°950 Surface 2,730' 0°0960 # 7" Intermediate 26/L-80/Hydril 521 6.276 Surface 10,748' 0.0383 4-1/2" Slotted Liner"A" 12.6/L-80/IBT 3.958 10,406' 12,999' N/A °i 4-1/2" Slotted Liner"B" 12.6/L-80/IBT 3.958 10,761' 13,125' N/A TUBING DETAIL 4-1/2" Tubing 12.6/L-80/NS-CT 3.958 Surface 10,303' 0.0152 1. 13/4" 4 0 / , WELL INCLINATION DETAIL KOP @ 500'MD 75 to 85 Deg.2,900'—10,300' Max Hole Angle=86 deg. @ 4,806'MD 76 Deg.@ Sliding Sleeve JEWELRY DETAIL No Depth Item 1 10,125' HES 4.5"'XD'Dura Sliding Sleeve—5C Jet Pump 5/10/17 2 10,149' Schlumberger SPM Gauge—ID Change to 3.879" 3 10,215' Baker S-3 Packer 7"x 4.5" 4 10,239' 4.5"XN-Nipple—3.725"No Go 5 10,302' 4.5"TC-II WLEG—Bottom @ 10,303' 6 10,336' Baker Hook Wall,Hanger above 7"Window 7 10,360' Baker Hook Wall,Hanger outside 7"Window 8 10,567' Baker ZXP Liner Top Packer 9 10,582' Baker 7"x 5"HMC Liner Hanger Notes:Nabors 22E RKB to THF=28.1';Nabors 35 RKB to THF=21.5'A=6.6' All depths are corrected back to original RKB. LATERAL WINDOW DETAIL Window in 7"Casing @ 5C Jet Pump ---� 0 1 10,345'to 10,357' Well Angle @ Window=77 Deg. 2 GENERAL WELL INFO API:50-029-23033-00-00 i MUM` Drilled and Completed by Nabors 22E -10/06/2001 .,0, .--11- 1f-g— 3 AMID=3.725' —g' •-4 NOTE: iI C. Prior to setting or pulling 4.5"BPV or TWC,notify FMC. '= 5 "e 4.5'TCII thread profile compatibility issue exists. r ' i IA• "M"Lateral 8 ,- 41 1:15111.= (.....„.,_ a CLEANOUT: d Cleaned out w/2.30"jet swirl nozzle to OB Latey 7 12,975'CTM using N2/Foam on 1/08/17. 7" TD=13,170'(MD)/TD=3,644'(TVD) PBTD=13,170'(MD)/PBTD=3,644'(TVD) Updated By:STP 11/20/2017 • • • II COIL BOPE MILNE POINT UNIT MPU 1-11 liileorp Alaska,LLC 11/20/2017 MPU I-11 20 X 103/4 X 7 X 4% Coil Tubing BOP Lubricator to injection head 0 2.00"Single Stripper 1 lialliiii 4 1/16 lOM Blind/Shear Blind/Shear __ =� c_ —— Blind/Shear — Blind/Shear��E1 • i3 1 OD 0110 Shp 1 slip _ c= Pipe -- Pipe :J i� _ -- — --_ AI 101-11:1 9111 MI Crossover spool 4 1/16 10M X 4 1/16 5M 101 101 Pump-In Sub � 1 r ° IIO o 1502 Union ®1 101 'e : `-. ,.,,,® Manual Gate Manual Gate •Valve,Swab,WKM-M, 2 1/8 5M 2 1/8 5M -ter 0, 41/16 5M FE �� o \LO ,MI �e,�‘654E • / — �a0 X11 i0 1 i / N---, II Valve,Upper Master,Baker, 4 1/16 5M FE,w/Hydraulic 40 Nis Valve,Lower Master,WKM-M, illte 41/165MFE Tubing Adapter,41/16 5M v�Y, _ • • STANDARD WELL PROCEDURE Hileorp Alaska.LAA: NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/02 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wel!site Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 • • OM < ■ K § D -0 ` - \ ) ! J ) * \ / E & � — ` § � U § m _ » ; \ \3� o ) ) ) 3 / ce O \ § | } ' / 272 § ■ c . -,...A. .� § '4 ■ U Z O .w � / r = all— _ ! � ' ae= _ - E// -w0 �«{ £ ) § - » ) e. § (� ( 5 ; J \ J )} ; CO . . § { • § •: \ \ / \ / { § �� B \ \ � L (: g / 7 J g / } Z3c ` . . ( _ 411111 . ] § £ cHo a Z � » l ° � aiosic:>. A fa) Liteasil— / V 5 7 ? f•AL }f ! < ƒ ` = ƒ . k , 0 ° . ; �� ` ill » * \ OlioMOH.! _ , ■ ## B , . ^/' ] i @ # #®iiiis i * £ -. } ƒ § § \ ! ! 0 1 -I § CO 9 ) � —/ D � 1- § 4 LL2 w § § / ED RECE STATE OF ALASKA I °` All OIL AND GAS CONSERVATION COM ION MAR 0 6 2017 REPORT OF SUNDRY WELL OPERATIONS + �~'� C1.Operations Abandon PlugPerforationsAOG C U U Fracture Stimulate U Pull Tubing u Operations shutdown Li Performed: Suspend ❑ Perforate ❑ Other Stimulate 0 Alter Casing ❑ CT FCO 0 Plug for Redrill ❑ 3rforate New Pool ❑ Repair Well 0 Re-enter Susp Well❑ Other: Coil Jet Pump Change Q 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development 0 Exploratory ❑ 201-137 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400,Anchorage,AK 99503 50-029-23033-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025517 MILNE PT UNIT I-11 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL 11.Present Well Condition Summary: Total Depth measured 13,170 feet Plugs measured N/A feet true vertical 3,644 feet Junk measured N/A feet Effective Depth measured 13,170 feet Packer measured 10,215&10,567 feet true vertical 3,644 feet true vertical 3,565&3,647 feet Casing Length Size MD TVD Burst Collapse Conductor 101' 20" 101' 101' N/A N/A Surface 2,730' 10-3/4" 2,730' 2,730' 3,580psi 2,090psi Intermediate 10,748' 7" 10,748' 3,674' 7,240psi 5,410psi Liner"A" 2,593' 4-1/2" 12,999' 3,644' 8,430psi 7,500psi Liner"B" 2,364' 4-1/2" 13,125' 3,644' 8,430psi 7,500psi Perforation depth Measured depth See Attached Schematic SCANNED APR 0 3 2017 True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80/NS-CT 10,303' 3,586' S-3 Packer Packers and SSSV(type,measured and true vertical depth) ZXP Liner Top Packer N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A 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: 37 7 0 2,695 251 Subsequent to operation: 49 10 0 2,484 242 14.Attachments(required per 20 PAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory[3 Development❑ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas ❑ WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-516�,,i1 Contact Stan Porhola S►r Email sporholaahilcorp.com Printed Name Bo York Title Operations Manager Signature Jni1 6 _ V So 777-8345 Date (, 7 _ 3_,347 7 RBDrifiS 1 v ,:, ��R Form 10-404 Revised 5/2015 ,// 7 /�� J7 - 6 �� Submit Original Only . H H . • Milne Point Unit Well: MPU I-11 SCHEMATIC Last Completed: 2/02/2009 Hilcorp Alaska,LLC PTD: 201-137 WELLHEAD Tree 4-1/16"—5M FMC Wellhead 11"x 4.5"5M Gen.6 w/4.5"TC-II T&B Orig.DF Elev.=64.70'/Orig.GL Elev.=34.70' Tubing Hanger CIW"H"BPV Profile Hole OPEN HOLE/CEMENT DETAIL 20' 20" Cmt w/260 sx of Arcticset(Approx)in 30"Hole 10 3/4" Cmt w/600 sx of PF"L",440 sx Class"G"in 13-1/2"Hole 7" Cmt w/1,400sx Class"G"in 9-7/8"Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top BtmBPF 20" Conductor 94/H-40 19.124 Surface 101' 0.355 10-3/4" Surface 45.5/L-80/BTC 9.950 Surface 2,730' 0.0960 7" Intermediate 26/L-80/Hydril 521 6.276 Surface 10,748' 0.0383 4-1/2" Slotted Liner"A" 12.6/L-80/IBT 3.958 10,406' 12,999' N/A 4-1/2" Slotted Liner"B" 12.6/L-80/IBT 3.958 10,761' 13,125' N/A TUBING DETAIL 4-1/2" Tubing 12.6/L-80/NS-CT 3.958 Surface 10,303' 0.0152 10-3/4* WELL INCLINATION DETAIL KOP @ 500'MD 75 to 85 Deg.2,900'—10,300' Max Hole Angle=86 deg. @ 4,806'MD 76 Deg.@ Sliding Sleeve JEWELRY DETAIL No Depth Item 1 10,125' HES 4.5"'XD'Dura Sliding Sleeve—4D Jet Pump 1/10/17 2 10,149' Schlumberger SPM Gauge—ID Change to 3.879" 3 10,215' Baker S-3 Packer 7"x 4.5" 4 10,239' 4.5"XN-Nipple—3.725"No Go 5 10,302' 4.5"TC-II WLEG—Bottom @ 10,303' 6 10,336' Baker Hook Wall,Hanger above 7"Window 7 10,360' Baker Hook Wall,Hanger outside 7"Window 8 10,567' Baker ZXP Liner Top Packer 9 10,582' Baker 7"x 5"HMC Liner Hanger I, r" Notes:Nabors 22E RKB to THF=28.1';Nabors 3S RKB to THF=21.5'4=6.6' i" All depths are corrected back to original RKB. it r'' LATERAL WINDOW DETAIL D14.; Window in 7"Casing @ 4OJPu ,,• It t i- tL 10,345'to 10,357' Well Angle @ Window=77 Deg. 2 , 1 GENERAL WELL INFO API:50-029-23033-00-00 F 4 3 Drilled and Completed by Nabors 22E -10/06/2001 Mn 0.371! -- * m. 4 NOTE: t` ' Prior to setting or pulling 4.5"BPV or TWC,notify FMC. 5 5 4.5"TCII thread profile compatibility issue exists. V, 1 s. �� t "OA"Lateral G)A le 44 8%.... 9CLEANOUT: r' I Cleaned out w/2.30"jet swirl nozzle to 7„ ` 'ClErWaal d13 r L" 12,975'CTM using N2/Foam on 1/08/17. TD=13,170'(MD)/TD=3,644'(TVD) PBTD=13,170'(MD)/PBTD=3,644'(1VD) Updated By:STP 3/01/2017 . • • IIHilcorp Alaska, LLC MP I-11 Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date M P 141 CTU 50-029-23033-00-00 201-137 1/6/17 1/11/17 Daily Operations: 1/06/2017-Friday HES CTU crew arrive on location. Hold safety meeting and discuss job procedure. MIRU CTU with 2.0"CT x.125 wall.Start BOPE test. Test all rams and valves to 250 low and 3500 high for 10 minutes each. Draw down test performed on accumulators. BOPE test complete. No 1/07/2017-Saturday Fire equipment. Hold safety meeting and discuss JSA and job procedure. Pick injector head stab 20'lubricator. Make up external slip coil connector. OD 3.13" Pull test 25k. Make up DFCV 3.13" , 3.13"OD Jars,3,13"OD disco, Pressure test MHA to 250/3500 psi. Bleed ei down and instal 4"Hydraulic GS spear. Total BHA length 13.19'.Shut in power fluid and flow line. Open swab. RIH. Intial WHP 125 psi. '4 3 Weight check at 10,050'. 22.5k. RIH stack 5k down on Jet pump at 10122'. Increase IA pressure with power fluid. 320 psi. Picked up to 34k straight pull jet pump. IA pressure dropped to zero. POOH to surface with pump. Tagged up at surface. Close swab valve. Pop off. Break down Jet pump. Jet pump pulled was Serial#BP-1090, 3'RC,Ratio 4D. Jet pump was installed previously on 7-5-16. Make up x over to sucker rod. Install 8042 sleeve shifting tool. Stab on well. PT stack 250/3500 psi. Bleed down to zero. Open swab.RIH. Stop at 10,145' POOH at 7 ft/min. Saw 1500 lb weight bobble at 10124' Good indication sleeve is closed. Open IA up to power fluid. 800 psi shut down power fluid and use field triplex pump to pressure IA up to 3500 psi. Chart and record for 30 minutes. Bleed down IA to 500 psi. POOH to surface. Tagged up. Pop off and inspect shifting tool. Pin intact.RD Baker tools. Install coil connector,check vavles,2x stinger and wash nozzle. Install night cap on BOPE. wellhead secure. Crews off location. 1/08/2017-Sunday Hold safety meeting. Discuss job procedure and SIMOPS with N2 crew. Rig up N2. Pick injector head. Install BHA.2.13"OD CC, 2.13" OD DFCV,2.13"Hydraulic disconnect, 2.0"weight bar x2. 2.3"Jet swirl nozzle. 13.57' long. Stab on well. Pt stack 250/3500 psi. Circulate 60/40 out of reel with 1%KCL.Open swab valve. RIH and attempt dry tag. Electronic counter at injector head slipping. Using back up mechanical counter for depth. Perform weight checks every 3000'. Clean weights. No indication of fill until set down weight at 12,718' Start cooling down N2. Pick up to tubing tail at 10,300'. Pump 5 bbls of gel. Online with N2 only at 1000 scf/min. Returns to surface. Continue with only n2 to unload 1/2 tubing volume or 58 bbls. start pumping 1%KCI and foam at 1.2 bbls/min. Wash in hole at 30 ft/min. At 12,548' send another 5 bbl gel sweep mixed with foam.Clean out to 12,975' and start stacking weight. Increase fluid rate to 2.2 bbls/min and 1000 scf/min. Circ pressure 4000 psi. Annular velocity 169 ft/min. Pick up and RIH stacking weight at same depth. Could possibly be in OA lateral. Send Gel sweep. Gel sweep out of coil. Chase OOH at 35 ft/min.@ 11,675' drop N2 rate to 700 scf/min, 11,000'drop N2 rate to 700 scf/min. Slow down to 15 ft/min in the 7"liner from 10,761'-10,400'. Continue OOH Make 4 passes across sliding sleeve at 10,125'. Continue OOH at 4000'shut down N2. and swap to 60/40. Noticed small amounts of solids in each gel sweep. Well bore fairly clean. Stacked on solids at 12,718'to 12,975'.Tagged up at surface. Close master and swab. Blow down stack to open top tank. Pop off well. BHA clean. break down tools. Install night cap on BOPE. Stack injector back. Well site secure. 254,500 scf pumped and 570 bbls of 1%KCI pumped mixed with foam. 2x10 bbls of N-Vis gel sweeps pumped. 680 bbls of fluid returned to surface. • • Hilcorp Alaska, LLC MP I-11 Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP 1-11 CTU 50-029-23033-00-00 201-137 1/6/17 1/11/17 Daily Operations: 1/09/2017-Monday Hold safety meeting. Discuss job procedure. Pick injector head. Make up 3.13"CC, 3.13"DFCV, 3.13"G force jars,3.13"disco,3.06"x over,2.86"hip tripper, 2.88"x over,3.92"B042 shifting tool. Total BHA length 18.44'. Stab on well. Pressure test stack 250/3500 psi. Install fusible cap. Open swab 23.5 turns. RIH, WHP60 psi. 10,100' wt check 19500 lbs. IA pressure 530 psi. RIH at 15 ft/min. Stack 5k at Q 10122' weight broke over and IA pressure dropped to zero.POOH to surface. Tagged up at surface. Close swab. Bleed down blow down v,(.7 stack. Pop off well. RD shifting tool. Make up Jet pump installed on x-line running tool. Stab on well. Pt stack 250/3500 psi . Load 150 47 bbls in upright tank. Open master swab and RIH.Rlh saw small weight stack at 9474'. Pick up and RIH. No weight stack at depth. CIH, 10,050' wt check 15k. Rlh at 30 ft/min attempt to set jet pump. Stack weight at 10125'. Come online with 1%KCL down coil. Hip tripper stalled. Pick up off stall. Good action on hip tripper at 10124'. Slack off weight to-4k rih wt. Good visual of hip tripper working. pump 15 bbls while continuing to slack weight,Stall hip tripper 3500 psi. Pick up and pressure broke over. Increase fluid rate to.75 bbls/min free hip trip pressure 1680 psi. Continue in hole. Hip tripper starts working at 10125'. Hammer down for 10 bbls and hip tripper stalled. Shut down pump. Stack 8k down to-12k. wait on jar lick. Jars Hit. Pick up and start hip tripper. at 1.5 bbls/min. Good action. 10125'„10125' Hammering with hip tripper for 15 minutes at 1.5 bbls/min. Good action at surface. Slack of to-5k. Stall hip tripper. Shut down pump. Slack off to-12k. jars fired down. Attempt pick up looking for over pull. Normal up weight 17.2k Pick up and overpull to 30k. 12.8k over pull. Wait on jars to fire. Jars hit after 4 minutes. Pick up clean 15 to 17k. Pull up 100' Attempt to turn on power fluid,Pad operator working rates. No indication if IA pressuring up. Attempt to stack back down on pump at 10125'. No increase in IA pressure. POOH to surface to check for jet pump. Tagged up at surface. Close swab. Blow down. Pop off well. No hip tripper at surface. la pressure still 230 psi no increase. Open to tank. Good flow at tank.Continue to flow throughout the night. Stack back injector head. 85 bbls of 1%KCL pumped. 1/10/2017-Tuesday ,-;.)M Hold safety meeting. Discuss job procedure. Make up BHA 3.13"OD Coil connector,3.13"DFCV,3.13"G force Jars,3.13"Disconnect, �` 3.5"OD G spear. Stab on well. PT stack 250/3500 psi. Open well.Rlh 299 psi WHP. IA 99 psi. Shut in power fluid and production wing. Continue RIH. Perform weight checks as needed. Clean rih and pick up weights. Pick up weight at 10,050'16,800 lbs. Stack 8k down at 10,125'.Pick up on jet pump. 17k normal weight over pull to 21,613 lbs latched into pump. POOH to surface,Tagged up.Close swab blow down stack. Pop off. Break down jet pump. Bottom packing torn apart. chunk of metal stuck in top metal packing ring. Looks like metal chunk wedged in the side of packing tearing it apart. Bring to SL to re pack jet pump. Install Jet pump. Stab on well. PT stack 250/3500 psi. re Open swab. RIH,RIH at 60 ft/min. RIH weight clean. Pick up weight at 10,050' 17k. RIH stack weight deeper than previous sleeve tag f- (10125') Stack at 10,133'. 1000 lbs down. stack down to-5k. Come online with 1%KCL at.5 bbls/min. Hipp tripper is stalled. pick up until (L�j ri i, pressure breaks over. Increase to 1 bbl/min. slack off. Good hammer on jet pump. Jet pump stall. Slack of to-15k down jar. repeat 3x. -v Continue to stay stacked out with 10k down on pump. Open IA and send power fluid. 6 minutes pressure increased to 500 psi. Looks set. T Shut down power fluid. Wait for IA to bleed down.Pickup to shear bottom steel pin on x-line running tool. PU to 25k 8k over. jars fired. repeat 3x. 4th jar lick picked up to 40k. Jars fired weight broke back to 17k. POOH to surface. Open power fluid and production wing. IA pressuring up to 2400 psi. choke back to a flow rate of 175 bbls/day. IA pressure dropping. Tagged up. Close swab. Pop off break down tools.N2 crew on location. Cooling down. Stab back on well. Blow down coil for spooling off 2"and installing 1.5". Reel blown down. Stack back inj head. Install night cap. Well site walk around complete. Location secure.35 bbls of 1%KCL pumped. 40,000 scf of N2 for reel blow down. Pump details: 3"mac OM Jet Pump 4.5"Tubing<_Pump BP-1076,Ratio:4D. Pump identification tag installed on master valve handle. 1/11/2017-Wednesday Rig down HES CTU. Return to yard and spool off 2.0"Ct and install 1.5"string. • • y®F T� Alaska Oil and Gas y*s�\��\�y/,�s� THE STATE F �� ofALASKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 pF ,SSP Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager SCAN Hilcorp Alaska, LLC S� 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB I-11 Permit to Drill Number: 201-137 Sundry Number: 316-516 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, /Z)1779c,s/--z____ Cathy . Foerster Chair DATED this it day of October, 2016. RBDMS WOL j 1 2 2016 STATE OF ALASKA 0 0 5 2:j15 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS �. .)C.4 + z.-- 20 20 AAC 25.280 Al 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑., CT FCO Q Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill El Perforate New Pool El Re-enter Susp Well ❑ Alter Casing ❑ Other Coil-Jet Pump Change❑Q 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska LLC Exploratory ❑ Development ❑✓ , 201-137 3.Address: ❑ 6.API Number: Stratigraphic ❑ Service 3800 Centerpoint Dr,Suite 1400 50-029-23033-00-00 , 7.If perforating: 8,Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 i Will planned perforations require a spacing exception? Yes ❑ No ❑✓ / MILNE PT UNIT SB I-11 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025517 • MILNE POINT/SCHRADER BLUFF OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): '' 13,170' ., 3,644' , 13,170' , 3,644' 1,473 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 101' 20" 101' 101' N/A N/A Surface 2,730' 10-3/4" 2,730' 2,730' 3,580psi 2,090psi Intermediate 10,748' 7" 10,748' 3,676' 7,240psi 5,410psi Liner"A" 2,593' 4-1/2" 13,124' 3,644' 8,430psi 7,500psi Liner"B" 2,364' 4-1/2" 13,170' 3,695' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic/ See Attached Schematic 4-1/2" 12.6#/L-80/NS-CT 10,303 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): ZXP Liner Top Packer and N/A - 10,567'(MD)&3,647'(TVD)and N/A 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Stratigraphic ❑ Development Q ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 10/18/2016 Commencing Operations: OIL Q • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: N/A GAS ❑ WAG 0 GSTOR ❑ SPLUG ❑ Commission Representative: N/A GINJ 0 Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Stan Porhola Email sporholaCcr7hilcorD.com Printed Name Bo York Title Operations Manager Signature r Phone 777-8345 Date 10/472.6165- 0/47 6 _ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry I _ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Esc' 1O(„ I10 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No V Subsequent Form Required: IQ „y RBDMS L('' hi 1 2 2016 /() APPROVED BY / Approved by:( //, r { � COMMISSIONER THE COMMISSION Date: /0 ,,/- / 1� fiG I D /Y ^ ii„./.40-/G. �/0,6�`VSubmit Form and Form 10-403 Revised 11/2015 Of tt �Qpli n�V lid2 months from the date of approval. Attachments in Duplicate Inr • • Well Prognosis Well: MPU I-11 Ili!cora Alaska.LLQ Date: 10/04/2016 Well Name: MPU I-11 API Number: 50-029-23033-00 Current Status: Oil Well [Jet Pump] Pad: Milne Point I-Pad Estimated Start Date: October 18th, 2016 Rig: Coil Tubing Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 201-137 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) AFE Number: Job Type: r Coil Foam Cleanout Current Bottom Hole Pressure: 1,611 psi @ 4,000' TVD (Last BHP measured 6/30/2015) Maximum Expected BHP: 1,611 psi @ 4,000' TVD (No new perfs being added, EMW= 7.8 ppg) / MPSP: 1,211 psi i/ (Based on 0.10 psi/ft gas gradient) Brief Well Summary: MPU I-11 was drilled in 2001 using Nabors 22E and completed as a dual-lateral in the Schrader Bluff OA and OB sands with a Jet Pump. The completion was pulled and the ESP completion changed out in 2001 using Nabors #4ES. The completion was pulled and changed out in 2009 using Nabors #3S to replace the 2-7/8" tubing ESP completion with a 4-1/2" tubing Jet Pump completion. Notes Regarding Wellbore Condition • Deviation down to pump section (max angle 85.8° @ 4,8061. • Casing last tested to 3,500 psi for 30 min down to 10,209'on 12/15/2015. --- • Jet Pump currently active, performance continues to degrade (likely solids or pump wear). • Deviation at pump is 76.0°. • Deviation at upper window into the OA lateral is 76.0°. • Deviation at liner hanger into the OB lateral is 77.0°. • Tubing Grade is L-80. Min ID is 3.813" in the 4-1/2" and 3.725" thru XN profile. • Last Fill Depth: 12,496' MD tagged on 7/02/2016. Objective: The purpose of this work/sundry is to pull the existing Jet Pump, perform a foam cleanout of the lateral and run a new Jet Pump. ✓ Brief Procedure: Coiled Tubing Procedure: 1. MIRU Coiled Tubing Unit and spot ancillary equipment. Fill source tank w/8.5 ppg 1% KCI. 2. Pressure test BOPE to 3,500 psi Hi 250 Low, 10 min each test. a. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. b. Notify AOGCC 24 hours prior to testing BOPE. c. Submit 10-424 form within 5 days. 3. RIH w/2.00" coil and pull jet pump in sliding sleeve profile at+/- 10,118' MD. POOH. • • Well Prognosis Well: MPU I-11 Itileorp Alaska,LL Date: 10/04/2016 4. RIH w/2.00" coil and shift sliding sleeve closed at+/- 10,118' MD. 5. Test backside tq 3,500 psi for 5min to confirm closed. POOH. 6. RIH w/2.00" coil w/2.5"to 3.5" max OD wash nozzle and extended reach cleanout BHA and cleanout to PBTD at+/- 13,125' MD (in OB lateral). POOH. a. This multi-lateral is a Baker Hughes Level 3 Hook Hanger with no Lateral Entry Modules (LEM) so selective entry into the OA lateral is not possible. b. Circulate out fill using 8.5 ppg 1% KCI w/friction reducer. Pump 5-10 bbl Gel Sweeps to help remove solids from the liner. c. Contingency: If unable to wash down with nozzle, RIH w/3.0" to 3.5" mill and extended reach cleanout BHA and cleanout to PBTD at+/- 13,125' MD(in OB lateral). POOH. 7. RIH w/2.00" coil w/2.5" to 3.5" max OD wash nozzle and extended reach cleanout BHA and cleanout to PBTD at+/- 13,125' MD (in OB lateral). POOH. a. Circulate out fill using 8.5 ppg 1% KCI w/liquid foamer and mix with Nitrogen (see Nitrogen procedure and diagram). Utilize defoamer for returns in Kill Tank. =� — fr`" �`` -� b. Contingency: If unable to wash down with nozzle, RIH w/3.0" to 3.5" mill and extended reach cleanout BHA and cleanout to PBTD at+/- 13,125' MD (in OB lateral) using 8.5 ppg 1% KCI w/liquid foamer and mix with Nitrogen. POOH. 8. RIH and shift sliding sleeve open at+/- 10,118' MD. 9. Pump 8.5 ppg 1% KCI or 8.4 ppg power fluid to confirm open. POOH. 10. RIH and set,. ._21,imp in sliding sleeve profile at+/- 10,118' MD. 11. PU to 2,500' and freeze protect well. POOH w/coil. 12. RD Coiled Tubing and ancillary equipment. 13. Turn well over to production. Attachments: 1. As-built Schematic 2. Coil BOPE Schematic 3. Nitrogen Operations Procedure 4. Nitrogen & Foam Flow Diagram • • Milne Point Unit II Well: MPU I-11 SCHEMATIC Last Completed: 2/02/2009 Ililcara Alaska.1,1A: PTD: 201-137 WELLHEAD Tree 4-1/16"-5M FMC Wellhead 11"x 4.5"5M Gen.6 w/4.5"TC-II T&B Orig.DF Elev.=64.70'/Orig.GL Elev.=34.70' Tubing Hanger CIW"H"BPV Profile Hole 20 j OPEN HOLE/CEMENT DETAIL 20" Cmt w/260 sx of Arcticset(Approx)in 30"Hole 'I Cmt w/600 sx of PF"L",440 sx Class"G"in :E E 10-3/4" 13-1/2"Hole 7' Cmt w/1,400sx Class"G"in 9-7/8"Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 94/H-40 19.124 Surface 101' 0.355 10-3/4" Surface 45.5/L-80/BTC 9.950 Surface 2,730' 0.0960 7" Intermediate 26/L-80/Hydril 521 6.276 Surface 10,748' 0.0383 4-1/2" Slotted Liner"A" 12.6/L-80/IBT 3.958 10,406' 12,999' N/A 4-1/2" Slotted Liner"B" 12.6/L-80/IBT 3.958 10,761' 13,125' N/A TUBING DETAIL 4-1/2" Tubing 12.6/L-80/NS-CT 3.958 Surface 10,303' 0.0152 10-3/4° , I WELL INCLINATION DETAIL KOP@500'MD 75 to 85 Deg.2,900'—10,300' Max Hole Angle=86 deg. @ 4,806'MD 76 Deg.@ Sliding Sleeve JEWELRY DETAIL I No Depth Item 1 10,125' HES 4.5"'XD'Dura Sliding Sleeve—4D Jet Pump 7/05/16 2 10,149' Schlumberger SPM Gauge—ID Change to 3.879" 3 10,215' Baker S-3 Packer 7"x 4.5" 4 10,239' 4.5"XN-Nipple—3.725"No Go 5 10,302' 4.5"TC-II WLEG—Bottom @ 10,303' 6 10,336' Baker Hook Wall,Hanger above 7"Window 7 10,360' Baker Hook Wall,Hanger outside 7"Window 8 10,567' Baker ZXP Liner Top Packer 9 10,582' Baker 7"x 5"HMC Liner Hanger Notes:Nabors 22E RKB to THF=28.1';Nabors 3S RKB to THF=21.5'zl=6.6' All depths are corrected back to original RKB. LATERAL WINDOW DETAIL Window in 7"Casing @ poi 1 10,345'to 10,357' Well Angle @ Window=77 Deg. 2 GENERAL WELL INFO API:50-029-23033-00-00 lrir Drilled and Completed by Nabors 22E -10/06/2001 MnID=3.725 ':•4 NOTE: Prior to setting or pulling 4.5"BPV or TWC,notify FMC. 5 4.5"TCII thread profile compatibility issue exists. 6 4 t' ..� 4— "QA"Lateral r. #FA3? q 8 ' A "OBLateral 7" TD=13,170'(MD)/TD=3,644'(TVD) PBTD=13,170'(MD)/PBTD=3,644'(TVD) Downhole Revised:7/05/2016 Updated By:STP 9/15/2016 is • • Milne Point Unit COIL BOPE MPU I-I1 9/15/2016 Tine rp,iln•kao.LLA: MPU I-11 20 x 10% x 7 x 4%2 Coil Tobin. BOP , To injection head mom 2.00"Double Stripper MI Lubricator I1.uu1i Blind 1/1615 .111111 M.-i '',. 111111111110 Blind .I,'•1 HIIII 7..r. 1 (The 1111111.11=1111.1.1 —— Slip _ Slip .I,'. )i.i.i — Pipe ,, ... Pipe .I,'.: ......, IIIII— er i i Crossover spool one 4 1/16 15M X 4 1/16 10M 461 1111 MN Crossover spool a-° 4 1/16 10M X 4 1/16 5M Cu Pum In Sub " j "j R' ° ' '- p- 4 1/16 5M - i n. °)n i it t ° .lh -II�iii 1502 Union „.u. Manual Gate Manual Gate Valve,Swab,WKM-M, '4 21/8 5M 2 1/8 5M 4 1/16 5M FE -Comte•� ���� l\ ) • ee OA)c c / N At Valve, Upper Master,Baker, 4 1/16 5M FE,w/Hydraulic jetValve,Lower Master,WKM-M, '444 4 1/16 5M FEt.":® .,loon Tubing Adapter,41/16 5M ( 1�� • ! STANDARD WELL PROCEDURE llikorpAlaska.IA, NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/02 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 • 0 P , ON 1M1 P4 U '• > U d zz , ,: zz H fi�g-++ c, Y \u O Y\ K 1.0 O 7 1L •• .... •• .... , > Pa .-a /. cz, oaoV o o3aoV o 0 L w 3 o LL ' 1 E d - • e •••..•.2 Z ¢ O a a i3 gi Q D O a a qq aCi > > • C7 m _, • N •••• y > N H m CO O •v 7 2 I' r`��L 5. piR ? J 7Uo- u a a ^ •• w > CCI UWU '-' ..r r _ : rTT c m i O • Y O I • V A .•. v — V O '• h0- I 0 '4 i@ i? I P, R" R a. i q ,•, i III 1111 1111 •R .� 111 a l:.:. ';I a -E 11111�11�{ �}I �14: +�r _ it 11111 IIID r l_ OO Z w Z O 00 O . LU,..,H K a V 101 Z R► z cc w w a a 330 z LL z vn o a H Y x m l7 m K O a m o m m 0 0 a 0 4 z , STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMIllkION ` REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Li Plug Perforations Li Fracture Stimulate u Pull Tubing Li Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ CT FCO w/N2 0 Plug for Redrill ❑ 8rforate New Pool ❑ Repair Well Q Re-enter Susp Well❑ Other: Coil Jet Pump Change ❑✓ 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development Q Exploratory ❑ 201-137 3.Address: Stratigraphic Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-029-23033-00-0� 7.Property Designation(Lease Number): 8.Well Name and Number: ECEIVED ADL0025517 MILNE PT UNIT SB I-11 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): SEP 2 0 2016 N/A MILNE POINT/SCHRADER BLUFF OIL �� `(.,,t�� 11.Present Well Condition Summary: Total Depth measured 13,170 feet Plugs measured N/A feet true vertical 3,644 feet Junk measured N/A feet Effective Depth measured 13,170 feet Packer measured 10,215&10,567 feet true vertical 3,644 feet true vertical 3,565&3,647 feet Casing Length Size MD TVD Burst Collapse Conductor 101' 20" 101' 101' N/A N/A Surface 2,730' 10-3/4" 2,730' 2,730' 3,580psi 2,090psi Intermediate 10,748' 7" 10,748' 3,674' 7,240psi 5,410psi Liner"B" 2,593' 4-1/2" 13,124' 3,644' 8,430psi 7,500psi Liner"A" 2,364' 4-1/2" 13,170' 3,695' 8,430psi 7,500psi Perforation depth Measured depth See Attached Schematic 120174 True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80/NS-CT 10,303' 3,586' S-3 Packer Packers and SSSV(type,measured and true vertical depth) ZXP Liner Top Packer N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A 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: 63 16 0 2,560 239 Subsequent to operation: 36 8 0 2,517 230 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 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 El Gas U WDSPL7 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-329 Contact Stan Porhola Email sporhola(c�hilcorp.com Printed Name Bo York Title Operations Engineer Signature 71 `> 3-----1 Phone 777-8345 Date 9/16/2016 Form 10-404 Revised 5/2015 (o to « RBDMS v SEP 2 2 2016.ubmit Original Only . • • Milne Point Unit Well: MPU 111 SCHEMATIC Last Completed: 2/02/2009 Hikorp Alaska.ilkPTD: 201-137 WELLHEAD Tree 4-1/16"-5M FMC Wellhead 11"x 4.5"5M Gen.6 w/4.5"TC-Il T&B Orig.DF Elev.=64.70'/Orig.GL Elev.=34.70' Tubing Hanger CIW"H"BPV Profile Hole za: OPEN HOLE/CEMENT DETAIL 4 4 20" Cmt w/260 sx of Arcticset(Approx)in 30"Hole ,. Cmt w/600 sx of PF"L",440 sx Class"G"in f 10-3/4' 13-1/2"Hole 7" Cmt w/1,400sx Class"G"in 9-7/8"Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF , 20" Conductor 94/H-40 19.124 Surface 101' 0.355 10-3/4" Surface 45.5/L-80/BTC 9.950 Surface 2,730' 0.0960 7" Intermediate 26/L-80/Hydril 521 6.276 Surface 10,748' 0.0383 4-1/2" Slotted Liner"A" 12.6/L-80/IBT 3.958 10,406' 12,999' N/A 4-1/2" Slotted Liner"B" 12.6/L-80/IBT 3.958 10,761' 13,125' N/A TUBING DETAIL 4-1/2" Tubing 12.6/L-80/NS-CT 3.958 Surface 10,303' 0.0152 10-3/4° ILi WELL INCLINATION DETAIL �� as KOP@500'MD • 75 to 85 Deg.2,900'—10,300' Max Hole Angle=86 deg. @ 4,806'MD 76 Deg.@ Sliding Sleeve JEWELRY DETAIL No Depth Item 1 10,125' HES 4.5"'XD'Dura Sliding Sleeve—4D Jet Pump 7/05/1.6 2 10,149' Schlumberger SPM Gauge—ID Change to 3.879" 3 10,215' Baker S-3 Packer 7"x 4.5" 4 10,239' 4.5"XN-Nipple—3.725"No Go 5 10,302' 4.5"TC-II WLEG—Bottom @ 10,303' 6 10,336' Baker Hook Wall,Hanger above 7"Window 7 10,360' Baker Hook Wall,Hanger outside 7"Window 8 10,567' Baker ZXP Liner Top Packer ,I 1 9 10,582' Baker 7"x 5"HMC Liner Hanger Notes:Nabors 22E RKB to THF=28.1';Nabors 3S RKB to THF=21.5'A=6.6' All depths are corrected back to original RKB. LATERAL WINDOW DETAIL Window in 7"Casing @ •es 1 10,345'to 10,357' vit 91 Well Angle @ Window=77 Deg. 2 GENERAL WELL INFO ' _..._ API:50-029-23033-00-00 IRAK! , Drilled and Completed by Nabors 22E -10/06/2001 i- - 3 MnID=3.725' -- ",•4 NOTE: Prior to setting or pulling 4.5"BPV or TWC,notify FMC. 5 4.5"TCII thread profile compatibility issue exists. 6 `st4",7 n "OA"Lateral • :ii443Q m 8/ . 9 A "OB"Lateral 7" TD=13,170'(MD)/TD=3,644'(TVD) PBTD=13,170'(MD)/PBTD=3,644'(TVD) Downhole Revised:7/05/2016 Updated By:STP 9/15/2016 • • fit Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP 1-11 CTU 50-029-23033-00-00 201-137 6/28/16 7/5/16 Daily Operations: 6/22/2016-Wednesday No activity to report. 6/23/2016-Thursday No activity to report. 6/24/2016- Friday No activity to report. 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 HES CTU arrive on location. Hold safety meeting. MIRU. Wind gusts of 30 mph. Crane shut down. Stab pipe. SDFN. 24 hr BOPE test witness notification sent 6/27/16 @ 1941. Lou Gramaldi will be on location for witness. • • Hilcorp Alaska, LLC HiiheorpAlaska,LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MPI-11 CTU 50-029-23033-00-00 201-137 6/28/2016 7/5/2016 r' !nu:,-,. ��. - n.F ma `,7 )YI. ®��" !.; �Phahrii��$, ��i�iyi wihihiwl^,,•,�i _��1i,. v���{ai�� �����kOIC��' _ 30_ ,� s4; i�ik�uw��IP'i xKt ash` a.s 6/29/16-Wednesday ,.a ..._ Hold safety meeting. Discuss JSA and review BOPE test procedure. Stab BOPE on well. Pick injector head. Stab Injector head on BOPE.Fluid pack CTU reel with 50 bbls of seawater.Start BOPE test. Lou Gramaldi on location for BOPE test witness. First test had backside line isolation valve for inner reel valve pt gauge leaking internally. Bleed down and Grease valve. Continue with BOPE test. Test all rams and valves to 250/3500 psi for 10 minutes. Draw down test complete. BOPE test complete.Blow down stack. rig back injector head. close all ground valves. Well site secure. 6/30/16 Thursday Hold safety meeting. Discuss JSA and job procedure.Pick injector head. Stab 30'of lubricator.make up Coil Connector. External slip. Pull test to 30k. Tighten CC. make up following BHA. 2.875"MHA 7/8 ball drop disco,3.0"X over,3.13"Slinger,3.56"weight bar,3.13 Fishing jar(up only), 3.13"0 over, 2.82 Hyd disco, 3.13"x over,4"GS spear. Pressure tested tool string to 250/3500 psi.Stab on well. Fluid pack. Low pt 250 high 3500 psi. Pad op shut in Power fluid. Fusible cap installed on SSV. Open swab valve. IA 93 psi,OA 150 psi,WHP 0. RIH, 6000°wt chk 18.7k,8000'wt chk 22k,9000;10000'wt chk 25k. stacked 5k at 10115',Pu off jet pump 27k 2k over pull then break back to 25k normal OOH wt. Pick up 50' Come online with pump 2.3 bbls/min at 3600 psi. Rlh to stack on fishing neck to wash profile. stack weight at 10111'. Wash with 5 bbls of seawater. Pick up off jet pump while circulating. Shut down pump. 0 psi ct pressure. Rlh at 60 ft/min. stack-10k.PU 28k or 3k over pull. Pulled heavy again at 10000'. Good indication,Fish looks latched. POOH to surface. Close swab valve. Blow down stack. Pop off well Fish recovered. Noticed wash out marks between seals. Looks as if jet pump was set and sleeve was not all the way open creating more turbulent flow and washing out jet pump body.Break down 4"GS spear. Make up xover and install 42B0 shifting tool. shoulders up to close. Stab on well. PT stack 250/3500 psi. bleed down. Open swab. Rlh. 0 psi WHP. No change in IA or OA.RIH. Litte red on location to Fluid pack IA with diesel and perform PT. 9000'CT depth come online down IA at 2 bbls/min. After 5 bbls caught fluid pump psi 450 psi. 20 bbls away started getting returns to surface. Well bore will hold a column of fluid. Rlh past sleeve parked at 10187'. Continue pumping until 40 bbls away IA fluid packed to 2500' Pick up,still pumping down IA with LRS. at.25 bbls/min and 500 psi. Pulled up and overpulled at 10112'CTMD. 4k over pull. LRS pump pressure increasing. POOH at 100 ft/min. Walk IA pressure up to 3530 psi. Shut down and 5 minute test ending at 3485 psi. Cont.POOH. Bleed back IA to 250 psi and shut in. Pressure needed on IA to help indicated sleeve opening on future runs.POOH. At surface. Master swab closed. Blow down. Pop off wellhead. Inspect shifting tool. Pins did not shear. Sleeve closed. Stack back for the night. All ground valves and BOP rams closed. Location secure. 7/1/16 Friday 4-111!-P Safety meeting. Discuss Job procedure.Pick injector head.Stab 30'of lubricator. Make up MHA as follows. 2.875"MHA,3.05 x over 3.35"weight bar, 3.13 Vibratory tool,3.13x over,2.5"nozzle. BHA length 11.23' Stab on well. Pressure test stack to 250/3500 psi.Open master swab. RIH 10332'start stacking weight. RIH wt-3k. stack to-13k,10k down. Pick up come online with 1%KCL. Online at 2.5 bbls/min Pick up and stack at same depth 10,333' Keep 10k down. Not washing off. Pick up and try 8 different times running slow and fast. Stacked 15k. And shut down pump trying to pop through hard spot. No luck.Hanging up in Baker Hook Hanger at 10336'. Deviation survey shows severe dog leg at depth. POOH to surface to swap BHA. Master swab closed. Bleed down pop off.Break down BHA and install BI-DI jars 3.13",Motor 3.13",Button head tapered smooth mill 3.7"OD. BHA lenght 32.64' Stab on well. PT stack 250/3500 psi.Open well and RIH. Perform weight checks. Stacking weight at 10340'CTMD. PU to 10300' online 1.6 bbls/min . Caught fluid. RIH. No luck spinning off possible shoulder at 10340'. Pick up and Attempt RIH at 5 ft/min,again at 30,60 and 120 ft/min. No luck. Normal IH WT-5000. Continue to stack to-25k. 20k down. Start making hole at 3-10 ft/min. No indication of motor work. Stacking 20k weight from 10330'-10530'weight broke back 10k rapidly. Starting RIH at 30 ft/min no motor work. Made it through tight spot.Cleaned out to 11000' and decided to wiper trip up through tight spot before making any more hole. Needed to ensure we could pull through. 10523' Over pulled 5k then broke free. Stopped at 10523' Tried to RIH. Stacked instantly. Pick up to 10400' RIH stacking 10k. Made it back to 10525' Couldn't make any more hole. Picked up to 10300'. RIH stacking weight from 10330'to 10525'.Continue PU to 10300'. Attempted runs not pumping. Pumping 1.5-3.5 bbls/min. Running in at 5 ft/min,30,60,100 ft/min. could not get past 10525'. Weight broke back at 10530'previously. No indication of solids in return . Believed to be tight in dog leg. POOH to surface.POOH. Tagged up at surface. Master swab closed. Blow down.Pop off. Break down tools. No indication of excessive wear on mill. Most marks on outside of mill. All buttons remain intact. Stack back for the night. Well site secure. Crews off locaiton. 365 bbls pumped. • Hilcorp Alaska, LLC HikorpAlaska,r_.1_.0 Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MPI-11 CTU 50-029-23033-00-00 201-137 6/28/2016 7/5/2016 7/2/16-Saturday Hold safety meeting and discuss job procedures.Pick injector head and stab 10'lubricator. Make up MHA CC,DFCV,DISCO,all 3.13", P3 extended reach tool. Install x over,Knuckle joint,and 3.5"nozzle. BHA lenght 6'. Stab on well. PT stack 250/3500 psi.Open well and RIH. PU wt at 10,000'18.5K. CIH, slight weight stack of 2k in tight spot from 10330 to 10535' Cotninue in hole at 50 ft/min to 11000'. Pick up up clean 21.5k. Online at 2.5 bbls/min CIH, taking 500'bites 11500'pu wt 23k. Wiper trip back to 11000'. CIH send gel sweep of 5 bbls.Cleaned out to 12496'. Started stacking weight. Pick 500' Rlh at 80 ft/min. Can't make it past 12496'. Start stacking weight slowly from 12450-12496'. Looks like friction. Pick up to 12000' Rlh at 45 ft/min . stacking again at 12450'-12496'. No luck. Gel sweep at surface. Pull sample. trace of solids. Send 10 bbl gel sweep. Gel at nozzle start chasing bottoms up of 150 bbls to surface. AV=277 ft/min.POOH to surface while chasing 10 bbl gel sweep. Slow down while passing sliding sleeve. Wash at 10 ft/min from 10150'-10100'up down up. Continue OOH to surface.Tagged up. Master swab closed. Break down Nozzle and extended reach tool. Install 42BO sleeve shifting tool shoulder down onto Knuckle joint. Stab on well. PT stack 250/3500 psi.Open master swab.Rlh. PU wt at 10100'16.5k. RIH wt-5k @ 20 ft/min. IA pressure 280 psi. Start stacking weight at 10120' Stacked down to-25k Need to hit sleeve at faster speed. PU to 10000'. Rlh at 50 ft/min. Stack weight at 10120'5k bobble continue RIH. IA pressure instantly dropped to 0 psi. PU and run past sleeve 5 ft/min. No weight stack.Sleeve open.POOH to surface. Tagged up. Master swab closed. Blow down pop off well. 4280 shifting tool pins still intact. Sleeve is open.Break down tool string. Stack back injector head. SDFN. Location secure. Walk around complete. 7/3/16-Sunday ° ` dr- IA Hold safety meeting and discuss JSA and daily job procedure.Pick injector head. Stab 30'of lubricator. Install MHA,Up Jars,BAKKE accelerator,BAKKE hammer,x over,knuckle joint,x over,Jet pump. Pressure test stack 250/3500 psi.RIH. Started stacking weight at 8200'. 12k down. Pick up clean. Halliburton Fluid pump engines won't fire. Get battery charger from Mechanics. Pump running. 1 hr down time.8100' Online down CT at 1.5 bbls/min. Stacked weight at 8216. Pick up,RIH to 8103'stacking 5k not washing off like sand/fill. Pick up 50' RIH stack weight at 8254'. Pick up,RIH stacking weight at 8293',again at 8331'Feels like on metal ledge. Continue working in hole stacking at 8373',8481',8494',8448'. Over pull on last pick up 10k and then again 10k. Decided to POOH and look at Jet pump.Tagged up. Master swab closed. Pop off well. bottom seals and metal ring on Jet pump damaged. Hot shot Weatherford for Ventrui run.Waiting on Tools.make up 3.125"venturi junk basket with Finger Grapples. Stab on well. PT stack 250/3500 psi. RIH. Come online down CT @ 6000'. 2 bbls/min 4300 psi circ pressure. RIH at 40 ft/min to 10,304'. Pick up to 7000'. Rlh again at 3 bbls/min 4200 psi. to 10300'. Shut down pump. POOH to surface.Tagged up. Break down Venturi. Secondary lock tab from setting tool recovered in venturi. 4 rocks,and metal shavings from CT and Tubing. Break down tools. Stack down injector head. SDFN. 7/4/16-Mondayi ' E. 'r- Hold safety meeting. Discuss job procedure.Pick injector head. Stab 30'lubricator. Make up BHA as follows. MHA,Up jars,BAKKE accelerator,BAKKE hammer,Knuckle joint,X over,X-line running tool,Jet pump. BHA OD 3.125" Jet pump OD 3.8". BHA length 29.8' Stab on well. Pt stack 250/3500 psi. Rlh, stack 3k at 8057' Close choke. Come online down CT at.5 bbls/min. CIH, stack weight 3k at 9307' Pick up and CIH. Increase RIH speed from 30 ft/min to 40 ft/min. OH to 10050'. Shut down fluid pump. Weight check 21k. Rlh weight-1500 lbs. Rlh and stack weight at 10122' Continue to set down to-20k.Come online with BAKKE hammer at 2.5 bbls/min. Stalled out at 4500 psi. Drop rate to 1.5 bbls/min 3800 psi. Start picking up off-20k stack in 5k increments until off stall. -10k pressure dropped off stall. Hammer effect felt in ops cab. Continue pu 5k increments to 15,000 lbs. 5k under pu weight. Slack of stacking in 5k increments back to-20k. -10 k sweet spot on hammer. shut down pump.PU OOH. Over pull from 21k to 40k. wait on jar lick.Jars fired. Bottom pin should be sheared. POOH to surface. Production online with power fluid. Not noticing build up of pressure. Indicating jet pump not set.Master swab closed.Pop off. Break down jet pump. Bring to HES Slick line trailer for inspection. Pull apart lock. Full of sand. Redress. Make up 3.5"jet swirl nozzle on BHA. Stab on well. Ordered 580 bbls of 1%KCL. PT stack 250/2500. Open well and RIH.Clean RIH parked at 10300'. Load upright tanks. Start Pumping at 2.7 bbls/min 4200 psi. Wash OOH at 35 ft/min. from 10300'to 9000'. RIH to 10300' Circulate 8 bbl gel sweep. Gel at nozzle Start washing OOH at 35 ft/min to 7000'. Pumped 3x more gel sweep while washing OOH. At 7000'last gel sweep at surface continue pumping 2.7 bbls/min and POOH at 100'/min.master swab closed. 586 bbls of KCL pumped. 30 bbls of gel pumped. (xanthan gel) Break down tools. Stack back injector head. SDFN. Location secure. Will RIH with jet pump in the AM. • Hilcorp Alaska, LLC Hileorp Alaska,LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MPI-11 CTU 50-029-23033-00-00 201-137 6/28/2016 7/5/2016 Hold safety meeting and discuss JSA.Pick injector head. Stab 30'of lubricator. Make up tools as follows. MHA,Up jars,BAKKE accelerator,BAKKE hammer,Knuckle joint,X over, X-line running tool and Get pump. BHA OD 3.125". Max OD of Jet pump 3.8". Stab on well. Pt stack to 250/3500 psi. Open well RIH.Rlh. Didn't stack any weight will RIH. Stop at 10,050' Perform weight check 20k.RIH at 5 ft/min. stack weight at 10121.9' Stack out to- 20k. Looking for seal engagement. Online down CT at.7 bbls/min 1700 psi. Wait to catch fluid. Pick up in 5k increments to 15k. Shut down pump Slack of to-20k two times. Pick up to right below up weight at 19k. Online down CT at 1.7 bbls/min 3800 psi circ pressure. Feel hammers hitting in ops cab. slack off in 5k increments to stall hammer.Pick up to 17k continue hammer down in 5k increments to shear top brass pins of jet Pump. -20k. Shut down fluid pump. Pick up looking for over pull.10,115'over pull30k. Wait 5 minutes. no jar hit. RIH to reset jars. Pick up to 35k. jars fired after 3 minutes. POOH free at 20 up.POOH to surface. Production turn on power fluid. IA pressuring up. Looks like jet pump is set.Master swab closed. Bleed down stack. Pop off injector head. confirm Jet pump is in hole. Rig down Tools. Stack back. RDMO move to E-12.74 bbls of 1%KCL pumped to Set jet pump.New jet pump 3"RC OM Jet pump/4-1/2.PUMP#BP-1090 Ratio 4D Jet pump information tagged and bagged zip tied to tree. • • .. or To `;w"-' 1 y/��s. THE STATE Alaska Oil and Gas i ce,,.isQs•• 1,, ofA e KL Conservation Commission ' ==ter ki,;F= 333 West Seventh Avenue 4'4 -ti - ' GOVERNOR BILL WALKER ... , , p Anchorage, Alaska 99501-3572 9A, ~~+'�" Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager SCIIIPIEJUN 2 7 2016 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Pool, MPU SB I-11 Permit to Drill Number: 201-137 Sundry Number: 316-329 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, P Cathy . Foerster sc Chair DATED this 23 day of June, 2016. RBDMS VV Jul L 4 2016 • • RECEIVED STATE OF ALASKA JUN 10 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION Z3( �6 APPLICATION FOR SUNDRY APPROVALS G� 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well J CT FCO 0 Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. Coil-Jet Pump Change 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: t`_i =7`/k• -4 Hilcorp Alaska LLC Exploratory ❑ Development 0 201-137 ' 3.Address. Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-029-23033-00-00 . 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 ' Will planned perforations require a spacing exception'? Yes ❑ No 0 / MILNE PT UNIT SB I-11 • 9. Property Designation(Lease Number): 10. Field/Pool(s): ADL0025517 MILNE POINT/SCHRADER BLUFF OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 13,170' 3,644' 13,170' 3,644' - 1,473 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 101' 20" 101' 101' N/A N/A Surface 2,730' 10-3/4" 2,730' 2,730' 3,580psi 2,090psi Intermediate 10,748' 7" 10,748' 3,676' 7,240psi 5,410psi Liner"A" 2,593' 4-1/2" 13,124' 3,644' 8,430psi 7,500psi Liner"B" 2,364' 4-1/2" 13,170' 3,695' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic : See Attached Schematic 4-1/2" 12.6#/L-80/NS-CT 10,303 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): ZXP Liner Top Packer and N/A • 10,567'(MD)&3,647'(TVD)and N/A 12.Attachments: Proposal Summary ❑ Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic ❑ Development ❑✓ ' Service ❑ 14. Estimated Date for 15.Well Status after proposed work: 6/28/2016 Commencing Operations: OIL ❑✓ • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: N/A GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Stan Porhola '1�-' Email sporhola(ahilcorp.com Printed Name Bo Bo York Title Operations Manager Signaturei���i�" Phone 777-8345 Date 6/10/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry I 1 _ 2_9 t. Cr Plug Integrity ❑ BOP Test Tff Mechanical Integrity Test ❑ Location Clearance ❑ Other: DOP Post Initial Injection MIT Req'd? Yes ❑ No ❑ t/ f / 1 L Spacing Exception Required? Yes ❑ No WI Subsequent Form Required: l d l 0 Li RBDMS Jt JUN 2016 APPROVED BY Approved by: a iaCOMMISSIONER THE COMMISSION Date: G - 23-1, , 9146 61316, Submit Form and Form 10-403 Revised 11/20150ARTGlitrAt:IforXec77(omthe date of approval. G.,37/4gttachments in Duplicate • • Well Prognosis . 11 Well: MPU I-11 Ilileorn Alaska,LL$ Date: 6/09/2016 Well Name: MPU I-11 API Number: 50-029-23033-00 Current Status: Oil Well [Jet Pump] Pad: Milne Point I-Pad Estimated Start Date: June 28th, 2016 Rig: Coil Tubing Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 201-137 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) AFE Number: Current Bottom Hole Pressure: 1,611 psi @ 4,000' TVD (Last BHP measured 6/30/2015) Maximum Expected BHP: 1,611 psi @ 4,000' TVD (No new perfs being added, EMW= 7.8 ppg) MPSP: 1,211 psi (Based on 0.10 psi/ft gas gradient) Brief Well Summary: MPU I-11 was drilled in 2001 using Nabors 22E and completed as a dual-lateral in the Schrader Bluff NE and OA sands with a Jet Pump. The completion was pulled and the ESP completion changed out in 2001 using Nabors #4ES. The completion was pulled and changed out in 2009 using Nabors #3S to replace the 2-7/8" tubing ESP completion with a 4-1/2" tubing Jet Pump completion. Notes Regarding Wellbore Condition • Deviation down to pump section (max angle 85.8° @ 4,806'). • Casing last tested to 3,500 psi for 30 min down to 10,209'on 12/15/2015. • Jet Pump currently active, performance continues to degrade (likely solids). • Deviation at pump is 76.0°. • Deviation at upper window into the OA lateral is 76.0°. • Deviation at liner hanger into the OB lateral is 77.0°. • Tubing Grade is L-80. Min ID is 3.813" in the 4-1/2" and 3.725" thru XN profile. • Last Fill Depth: 12,023' MD tagged on 12/16/2015. Objective: The purpose of this work/sundry is to pull the existing Jet Pump, cleanout the lateral and run a new Jet Pump. Brief Procedure: Coiled Tubing Procedure: 1. MIRU Coiled Tubing Unit and spot ancillary equipment. Fill source tank w/8.5 ppg 1% KCI. 2. Pressure test BOPE to 3,500 psi Hi 250 Low, 10 min each test. a. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. b. Notify AOGCC 24 hours prior to testing BOPE. c. Submit 10-424 form within 5 days. 3. RIH w/2.00" coil and pull jet pump in sliding sleeve profile at+/- 10,118' MD. POOH. 4. RIH w/2.00" coil and shift sliding sleeve closed at+/- 10,118' MD. Tai • Well Prognosis Well: MPU I-11 Ilikora Alaska,LU Date: 6/09/2016 5. Test backside to 3,500 psi for 5 min to confirm closed. POOH. 6. RIH w/2.00" coil w/2.5"to 3.5" max OD wash nozzle and extended reach cleanout BHA and cleanout to PBTD at+/- 13,125' MD (in OB lateral). POOH. a. This multi-lateral is a Baker Hughes Level 3 Hook Hanger with no Lateral Entry Modules (LEM) so selective entry into the OA lateral is not possible. b. Circulate out fill using 8.5 ppg 1% KCI w/friction reducer. Pump 5-10 bbl Gel Sweeps to help remove solids from the liner. c. Contingency: If unable to wash down with nozzle, RIH w/3.0"to 3.5" mill and extended reach cleanout BHA and cleanout to PBTD at+/- 13,125' MD (in OB lateral). POOH. d. Contingency: If unable to circulate fluid to surface without significant losses (<50% returns or little to no solids circulated to surface). Circulate out fill using 8.5 ppg 1% KCI w/liquid foamer and mix with Nitrogen (see Nitroge procedure and dia ra 7. Contingency: If unable to cleanout fill w/wash nozzle, RIH w/2.00" coil w/2.88"to 3.5" max OD motor and mill and extended reach cleanout BHA and cleanout to PBTD at+/- 13,125' MD. POOH. a. Circulate out fill using 8.5 ppg 1% KCI w/friction reducer. Pump 5-10 bbl Gel Sweeps to help remove solids from the liner. b. Contingency: If unable to circulate fluid to surface without significant losses (<50% returns or little to no solids circulated to surface). Circulate out fill using 8.5 ppg 1% KCI w/liquid foamer and mix with Nitrogen (see Nitrogen procedure and diagram). 8. RIH and shift sliding sleeve open at+/- 10,118' MD. 9. Pump 8.5 ppg 1% KCI or 8.4 ppg power fluid to confirm open. POOH. 10. RIH and set jet pump in sliding sleeve profile at+/- 10,118' MD. 11. PU to 2,500' and freeze protect well. POOH w/coil. 12. RD Coiled Tubing and ancillary equipment. 13. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. Coil BOPE Schematic 4. Nitrogen Operations Procedure 5. Nitrogen Flow Diagram H . • Milne Point Unit • Well: MPU I-11 • niSCHEMATIC Last Completed: 2/02/2009 eikoro Alaska.ILL PTD: 201-137 WELLHEAD Tree 4-1/16"-5M FMC Wellhead 11"x 4.5"5M Gen.6 w/4.5"TC-II T&B Orig.DF Elev.=64.70'/Orig.GL Elev.=34.70' Tubing Hanger CIW"H"BPV Profile Hole 2aa iOPEN HOLE/CEMENT DETAIL , . 20" Cmt w/260 sx of Arcticset(Approx)in 30"Hole 10-3/4" Cmt w/600 sx of PF"L",440 sx Class"G"in 13-1/2"Hole 7" Cmt w/1,400sx Class"G"in 9-7/8"Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 94/H-40 19.124 Surface 101' 0.355 10-3/4" Surface 45.5/L-80/BTC 9.950 Surface 2,730' 0.0960 7" Intermediate 26/L-80/Hydril 521 6.276 Surface 10,748' 0.0383 4-1/2" Slotted Liner"A" 12.6/L-80/IBT 3.958 10,406' 12,999' N/A 4-1/2" Slotted Liner"B" 12.6/L-80/IBT 1 3.958 10,761' 13,125' N/A TUBING DETAIL 4-1/2" Tubing 12.6/L-80/NS-CT 3.958 Surface 10,303' 0.0152 10-3/4° i 4 WELL INCLINATION DETAIL KOP @ 500'MD 75 to 85 Deg.2,900'—10,300' Max Hole Angle=86 deg. @ 4,806'MD 76 Deg.@ Sliding Sleeve JEWELRY DETAIL No Depth Item 1 10,125' HES 4.5"'XD'Dura Sliding Sleeve—Opened 12/17/2016 2 10,149' Schlumberger SPM Gauge—ID Change to 3.879" 11 ` 3 10,215' Baker S-3 Packer 7"x 4.5" 4 10,239' 4.5"XN-Nipple—3.725"No Go 5 10,302' 4.5"TC-II WLEG—Bottom @ 10,303' 6 10,336' Baker Hook Wall,Hanger above 7"Window 7 10,360' Baker Hook Wall,Hanger outside 7"Window 1 8 10,567' Baker ZXP Liner Top Packer 1 9 10,582' Baker 7"x 5"HMC Liner Hanger Notes:Nabors 22E RKB to THF=28.1';Nabors 35 RKB to THF=21.5'A=6.6' All depths are corrected back to original RKB. I LATERAL WINDOW DETAIL Window in 7"Casing @ ttt 1 10,345'to 10,357' Well Angle @ Window=77 Deg. 2 GENERAL WELL INFO I ' API:50-029-23033-00-00 IMILAIN I Drilled and Completed by Nabors 22E -10/06/2001 4.:f, 3 a NOTE: Prior to setting or pulling 4.5"BPV or TWC,notify FMC. 5 a� 4.5"TCII thread profile compatibility issue exists. Oi Ar- "CA Latera i "OB"Latera 7" TD=13,170'(MD)/TD=3,644'(TVD) PBTD=13,170'(MD)/PBTD=3,644'(TVD) Downhole Revised:2/21/2009 Updated By:TDF 1/16/2015 H . • Milne Point Unit • Well: MPU I-11 • PROPOSED Last Completed: 2/02/2009 l{ileoep Alaska.Ll.c PTD: 201 137 WELLHEAD Tree 4-1/16"-5M FMC Wellhead 11"x 4.5"SM Gen.6 w/4.5"TC-II T&B Orig.DF Elev.=64.70'/Orig.GL Elev.=3470' Tubing Hanger CIW"H"BPV Profile Hole 2D )k., OPEN HOLE/CEMENT DETAIL 20" Cmt w/260 sx of Arcticset(Approx)in 30"Hole 10-3/4" Cmt w/600 sx of PF"L",440 sx Class"G"in 13-1/2"Hole 7" Cmt w/1,400sx Class"G"in 9-7/8"Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 94/H-40 19.124 Surface 101' 0.355 10-3/4" Surface 45.5/L-80/BTC 9.950 Surface 2,730' 0.0960 , 7" Intermediate 26/L-80/Hydril 521 6.276 Surface 10,748' 0.0383 4-1/2" Slotted Liner"A" 12.6/L-80/IBT 3.958 10,406' 12,999' N/A 4-1/2" Slotted Liner"B" 12.6/L-80/IBT 3.958 10,761' 13,125' N/A TUBING DETAIL 4-1/2" Tubing 12.6/L-80/NS-CT 3.958 Surface 10,303' 0.0152 10-3/4" 1 k WELL INCLINATION DETAIL KOP @ 500'MD 75 to 85 Deg.2,900'—10,300' Max Hole Angle=86 deg. @ 4,806'MD 76 Deg.@ Sliding Sleeve JEWELRY DETAIL No Depth Item 1 10,125' HES 4.5"'XD'Dura Sliding Sleeve—New Jet Pump 2 10,149' Schlumberger SPM Gauge—ID Change to 3.879" -- 3 10,215' Baker S-3 Packer 7"x 4.5" 4 10,239' 4.5"XN-Nipple—3.725"No Go 5 10,302' 4.5"TC-II WLEG—Bottom @ 10,303' 6 10,336' Baker Hook Wall,Hanger above 7"Window _ 7 10,360' Baker Hook Wall,Hanger outside 7"Window 8 10,567' Baker ZXP Liner Top Packer 1 9 10,582' Baker 7"x 5"HMC Liner Hanger Notes:Nabors 22E RKB to THF=28.1';Nabors 35 RKB to THF=21.5'.4=6.6' f All depths are corrected back to original RKB. a LATERAL WINDOW DETAIL Window in 7"Casing @ f;.oYll 1 10,345'to 10,357' `_, Well Angle @ Window=77 Deg. `i' a . 2 GENERAL WELL INFO ,, API:50-029-23033-00-00 taalLut Drilled and Completed by Nabors 22E -10/06/2001 t' ,.4 NOTE: Prior to setting or pulling 4.5"BPV or TWC,notify FMC. 5 4.5"TCII thread profile compatibility issue exists. - 6 iys4 OB Lateral > Cleaned Out a,.1) `'-).....' _ r 014 Lateral 8 ' 9 "OB'Lateral 7 TD=13,170'(MD)/TD=3,644'(1VD) PBTD=13,170'(MD)/PBTD=3,644'(TVD) Downhole Revised:2/21/2009 Updated By:STP 6/09/2016 • • Milne Point Unit COIL BOPE MPU I-11 1 l.-n�rp�th t4.*.1.1.t. 6/09/2016 MPU 1-11 20 x 103/4x7x4/2 Coil Tubing BOP Lubricator to injection head 2.00"Single Stripper I I _ 1 1 _ •I,. Blind 1/1615 MNI =� Blind iii •il 1)11111 Shear lin =; Shear 1E10 - _ .0 - . C_ Slip =a Slip uIiI MINNIMMO Oil! I 2.111. Pipe _on ��. Pipe OKI Crossover spool i I� 4 1/16 15M X 4 1/16 10M a e Crossover spool estMI 41/16 10M X 4 1/16 5M i` € Pump In Sub ese e e . T.• ,� 4 1/16 5ME�.) ■ .(01• I� Mill 1502 Union ewe > •,i Manual Gate Manual Gate Valve,Swab,WKM-M, � 2 1/8 5M 2 1/8 5M ,� 4 1/16 5M FE 'v c 1110 ���� 1 Zr ( )j NIa p,1� 13),,1 kit r / Valve,Upper Master,Baker, Oo 4 1/16 5M FE,w/Hydraulic J ( / It g Valve,Lower Master,WKM M, ,: 41/16 5M FE «. illi Tubing Adapter,41/16 5M ,..,‘,-,,,,,,.. _11,111_ �� _ y • STANDARD WELL PROCEDURE Uileorp Alaska,LLC NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 • • I- Ia w O. 2 'C bL t.+ m 0:1 •D. b ✓Q z O� OO '� XO p 3-- ex `� ... v o > > V 3 CG U ro Q. _ �?W o ac d > o G W 1 W d' • > F C 'a v Q�� ¢�� .. cam. > W a vwv Q3o Qo W LL W LL I , g O h ,4 _.CO 7 Q W W Q ; C7 6 N > > ro C7 E II riiilibk ...r r R -O 1 111 w c naW O t 1. V � V © `' A 3 V 00 u . 21 0 lkshi, 11 [Hi' V c„ i II ill Il1il IIli , I�o fT 1. Om d l W Y WQW H i. C re LL C. V N G m W m ~ LA z a V Y Z Q F- Y CO m 0 0 STATE OF ALASKA AIL OIL AND GAS CONSERVATION CO SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ CT FCO ❑Q Plug for Redrill ❑ arforate New Pool ❑ Repair Well ❑✓ Re-enter Susp Well ❑ Other: Coil Jet Pump Change Q 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development 0 Exploratory ❑ 201-137 3.Address: Stratigraphic El Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-029-23033-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025517 MILNE PT UNIT SB I-11 IVED 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): w'� N/A MILNE POINT/SCHRADER BLUFF OIL 11.Present Well Condition Summary: JAS! � � Total Depth measured 13,170 feet Plugs measured N/A fee , 0 CC true vertical 3,644 feet Junk measured N/A feet Effective Depth measured 13,170 feet Packer measured 10,567 feet true vertical 3,644 feet true vertical 3,647 feet Casing Length Size MD TVD Burst Collapse Conductor 101' 20" 101' 101' N/A N/A Surface 2,730' 10-3/4" 2,730' 2,730' 3,580psi 2,090psi Intermediate 10,748' 7" 10,748' 3,674' 7,240psi 5,410psi Liner"B" 2,593' 4-1/2" 13,124' 3,644' 8,430psi 7,500psi Liner"A" 2,364' 4-1/2" 13,170' 3,695' 8,430psi 7,500psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80/NS-CT 10,303' 3,586' 10,567'MD Packers and SSSV(type,measured and true vertical depth) ZXP Liner Top Packer N/A 3,647'TVD N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A 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: 74 28 0 2,451 204 Subsequent to operation: 121 25 0 2,500 213 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑ Exploratory❑ Development ID Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas U WDSPL U Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: Contact Stan Porhola Email 4527TP sporhola(a�hilcorp.com Printed Name Bo York Title Operations Engineer Signature Phone 777-8345 Date 1/15/2016 ,- z —/—/" 2.Form 10-404 Revised 5/2015 / //� RBDMS Li.. JAN 2 2016 Submit Original Only iii� l9/,/'v H . Milne Point Unit : MPU I-11 SCHEMATIC Last Completed: Well2/02/2009 Hikwrp Alaska,LLC PTD: 201 137 WELLHEAD Tree 4-1/16"-5M FMC Wellhead 11"x 4.5"5M Gen.6 w/4.5"TC-II T&B Orig.DF Elev.=64.70'/Orig.GL Elev.=34.70' Tubing Hanger CIW"H"BPV Profile Hole OPEN HOLE/CEMENT DETAIL 20' 20" Cmt w/260 sx of Arcticset(Approx)in 30"Hole di i 10-3/4" Cmt w/600 sx of PF"L",440 sx Class"G"in 13-1/2"Hole a 4 7' Cmt w/1,400sx Class"G"in 9-7/8"Hole rl" CASING DETAIL , t 1. Size Type Wt/Grade/Conn ID Top Btm BPF it 20" Conductor 94/H-40 19.124 Surface 101' 0.355 Sri *4 10-3/4" Surface 45.5/L-80/BTC 9.950 Surface 2,730' 0.0960 7" Intermediate 26/L-80/Hydril 521 6.276 Surface 10,748' 0.0383 , t. 4-1/2" Slotted Liner"A" 12.6/L-80/IBT 3.958 10,406' 12,999' N/A 4-1/2" Slotted Liner"B" 12.6/L-80/IBT 3.958 10,761' 13,125' N/A l TUBING DETAIL p 4-1/2" Tubing 12.6/L-80/NS-CT 3.958 Surface 10,303' 0.0152 10-3/4" WELL INCLINATION DETAIL KOP@500'MD 75 to 85 Deg.2,900'—10,300' Max Hole Angle=86 deg. @ 4,806'MD 76 Deg.@ Sliding Sleeve JEWELRY DETAIL No Depth Item 1 10,125' HES 4.5"'XD'Dura Sliding Sleeve—Opened 12/17/2016 2 10,149' Schlumberger SPM Gauge—ID Change to 3.879" 3 10,215' Baker S-3 Packer 7"x 4.5" 3> 4 10,239' 4.5"XN-Nipple—3.725"No Go 5 10,302' 4.5"TC-II WLEG—Bottom @ 10,303' 6 10,336' Baker Hook Wall,Hanger above 7"Window 7 10,360' Baker Hook Wall,Hanger outside 7"Window 8 10,567' Baker ZXP Liner Top Packer 9 10,582' Baker 7"x 5"HMC Liner Hanger Notes:Nabors 12E RKB to THE=28.1';Nabors 3S RKB to THE=21.5'A=6.6' All depths are corrected back to original RKB. k £ LATERAL WINDOW DETAIL Window in 7"Casing @ 10,345'to 10,357' Mr Well Angle @ Window=77 Deg. 2if GENERAL WELL INFO API:50-029-23033-00-00 fi 1 i ? 3 Drilled and Completed by Nabors 22E -10/06/2001 Ik+ It '4 NOTE: v Prior to setting or pulling 4.5"BPV or TWC,notify FMC. "p 5 '; 4.5"TCII thread profile compatibility issue exists. '6 o- 1,r7 I' ; "CA Lateral 8i rAI "OB"Lateral 7" Ng TD=13,170'(MD)/TD=3,644'(TVD) PBTD=13,170'(MD)/PBTD=3,644'(TVD) Downhole Revised:2/21/2009 Updated By:TDF 1/16/2015 • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP 1-11 CTU 50-029-23033-00-00 201-137 12/13/15 12/19/15 Daily Operations: 12/9/2015 -Wednesday No activity to report. 12/10/2015-Thursday No activity to report. 12/11/2015 - Friday No activity to report. 12/12/2015-Saturday No activity to report. 12/13/2015-Sunday Mobe CTU and equipment from S pad. Held PJSM. MIRU SLB CTU #4. Spotted tanks and associated equipment. Made up Hardline and hoses. Filled up rights with Hot seawater. MU 5' 4-1/16" 5M spool on top of tree to clean offset Wellhouse. MU P sub and BOPs connected hard line to choke skid. 12/14/2015- Monday Prep for BOPE Testing. Found Packoff leaking from the weep hole. SD 5 Hours for repair on Unit Time. Pack-Off Repaired, Stabbed on Injector Head and circulated 5 bbls of 60/40 and broke cir to OT. Prep to Test BOPE.Tested BOPE as follows: Function and Draw down, Full Body 250psi low/4,500psi high. Rams 250psi low/4,500psi high.Valves 250psi low/ 4,500psi high. Held test for 5mins and charted. No failures recored. LD Injector and Cut 50' of coil. MU BHA as follows. 2.88" Ext STC, 2.88 DFCV, 2.88 BiDi Jars, 2.88 Hyd Disconnect, 2.88 Side and Down Wash Nozzle. Stabbed Injector PT 4,500psi-Test good. Circulated 60/40 out of coil with hot seawater taking returns to the 50bbl OT. Opened well and RIH Washing down 2bpm to top of Jet Pump @ monitoring returns. Opened well and RIH 130fpm pumping .3bpm, Increased rate to 2bpm @ 9,500'. CIH to top of Jet Pump @ 10,126' returns crude 2bbl in/1.5bbls out. Circulated 40bbI slug of BaraKlean down coil with 2bbls of Surfactant out of coil. PUH @ 50fpm washing tbg at 2bpm until returns were clean. POOH. Freeze protected well and Coil. Bumped and SI well. LD Injector. Night Capped BOPs, secured location and SDFN. 12/15/2015 -Tuesday Held PJSM. Discussed Operation. LD 2.88" Wash Nozzle. MU 4" Flow Release Pulling Tool. Stabbed Injector PT 4,500-Test Ok. Opened well and RIH 130fpm, Pickup WK 19k @ 10,000'. CIH and latched Jet Pump and 10,112'ctm. PU 12k over and released Jet Pump. POOH. CI4ose swab and master. RD Injector. LD Jet Pump and and 4" Flow Release Pulling Tool..MU/PU 4.5" Shifting Tool. Stabbed Injector Head PT to 4,500psi-Test ok. Opened well and RIH to Sliding Sleeve. RU Iron to pump down IA and PT to 3,500psi-Test Ok. Pumped 120bbIs of PW down IA taking returns 5/3.5 up the 2" coil x 4-1/2" tubing annulus, swapped to 60/40 pumping 45bbls for freeze protection. Closed Sliding_Sleeve and MIT IA to 3,500psi charted for 30mins- Good Test. POOH Freeze protected well and CT. Closed Swab and Master Valves. RD Injector LD Tools. Serviced Packoff and Injector Head. Secured CT Unit and SDFN. • Hilcorp Alaska, LLC HileorpAlaska,IAA: Weekly Operations Summary Well Name Rig API Number Well Permit Number Start DateEnd Date MPI-11 Coil 50-029-23033-00-00 201-137 12/13/2015 12/19/2015 miipmNi "M3,_ �= 12/1-Q35-Wednesday ;''' 414 Held PSJM. MU BHA and Tallied 2" Ext STC,2.88 DFCV, 2.88 Bi-Di Jar, 2.88 Hyd. Disconnect, 2.88 XRV, 2.88 Wash Nozzle. Stabbed Injector Head. PT 4,500psi-Test Ok. Circulated 60/40 out of the coil with Hot seawater to 50bb1 OT. Opened well and RIH 0.5bpm w/ck closed WH 250psi. Tagged hard at 10,313'ctm. Opened ck and increased rate to 2bpm. Could not wash thru 10,313'. Made several attempts pumping 1, 2,3bpm with no luck. RU pump down backside, pumped 5bpm down the backside and counld not work thru 10,313'. Discussed with engineer and decided to POOH and PU Motor and Mill. POOH. Closed Master and Swab. RD Injector LD Wash Nozzle. PU/MU 2.88 Titan Motor and 3.66 Junk Mill. Stabbed Injector and could not get Mill thru BOP's. RD Injector and LD Junk Mill.With 30 degF seawater in Coil MU Pull Test Plate and circulated 43bb1 of 60/40 in coil. PU/MU 3.25 Junk Mill. Stabbed Injector Head and PT 4,500psi-Test ok. Opened well and RIH 0.5bpm. Made it thru 10,313'and CIH pumping 2.5bpm and set down at 12,003'at set down. PU 20'and could not go down `) made 100' PU and could not go down. Continued PUH to 8,800'. Stopped coil could not go up or down due to Lubircator freezing up. Pumped 0.5bbls Methonal into Lubricator and freed coil. RIH pumping 2bpm to 10,500 and started fighting friction down to 12,023'. Call engineer and decided to pump Safe Lube. PU to 10,000 and parked coil. Waiting on Safe Lube to Arrive on location. Spotted 290bbl Peak Vac truck and RU to Pump. RIH pumping 0.9%SafeLube at 2bpm returns 1/1(no solids). Passing 10,300'as Safe Lube was exiting the coil. CIH and kicked out at 11,500 due to friction. PU to 11,000'tried but could not go down. PU to 7,500'and RIH hope to gain momentum. RIH to 8,100' run weight is 6k lighter that the first trip. PUH weight is 3k more than previous trips 7,500'. PUH to 5,000'. Tried RIH weight 4k lighter. Returns Trace Of Sand Swapped back to seawater at 2bpm. PUH to vertical section at 2,000'trying to sweep any solids to surface (Returns clean w/trace of sand). POOH freeze protected Well and Coil. Bumped up and closed Swab and Master Valve. RD Injector Head. MU Night Cap and Secured Location. SD Waiting on SLB Crew Change. 12/3.7/15;; Thursday 34 r IN Crew Orientation. Held PJSM. Discussed Work Scope and Expectations. Prep and warmed Unit. LD Motor and Mill. PU/MU Shifting Tool. Stabbed Injector and PT 4,500psi-Test Ok. Opened Well and RIH w/P-Subs Closed. Wt ck 10,000'/24k.CIH and tagged Sleeve @ 10,100'ctm. Pushed thru to 10,150'and Opened Sliding Sleeve. Pumped 5bbls of 60/40 down IA with communitcation tbg and confirm Sliding_SIeeve is opened. POOH. Closed Master and Swab Valves. RU Injector Head. LD Shifting Tool. PU/MU Set Tool and Jet Pump. Capped BOPs. Secured Location and SDFN. 12/1.8/3.5-Friday R ' 19th i C . `11lilG GI' Held PJSM. Prep Unit. Stabbed Injector PT 4,500psi-Test Ok. Circulated 40 bbls of seatwater into the coil returning 40bbls of 60/40 to 50bbl OT. Opened Well and RIH w/Jet Pump. PU Weight Ck at 10,000/22k. CIH and tagged profile at 10,109'ctm. Push 3k down to lock in pump and jarred down on Pump(minimal jar action). Rolled over CT Pump at 1.7bpm to Hammer down on Jet pump to ensure set. POOH. Closed swab and master valve. RD Injector. Jet Pump was still latched on setting tool. LD same. Pulled Running tool apart and found sand and paraffin in the mandrel sleeve. Dressed X-Lock Running tool and Pinned with brass and aluminum. PU X-Lock Running Tool. Jet Pump and Ashman Single Impact Jet Hammer. Stabbed Injector PT 4,500psi-Test OK. RIH w/Jet Pump made PU Weight ck at 10,000'/22k. CIH and tagged Profile @ 10,109'. Set 3k down and Hammer on Pump at 2bpm for 10 min to set pump. PU 15k over and jarred off Jet Pump. POOH. Closed Master and Swab. RD Injector LD BHA. Capped BOPs. Secured Unit and SDFN. Turn well over to Production. Flow test well overnight. 12/19/15.4'g5t4r•a �� yil� i � ii � i5„`�imZi�"' '� �Ii rd�Ii ami �� Iii4 i iii ii B'`tikN� Held PJSM. RDMO SLB CTU#4 and associated equipment. 12 2U '" Vii �i' ` $ i(II�II�illi, 71w _ ..6�l�" 13„�"5un�lay i Ii�����°�,i'Wliii� i �'I` ti� id, No operations to report. 12/21 .5-Monday ��It4�, 44444441',1Iti � =r No operations to report. 12/22/15 Tuesday �I J'F'' _ ly I' No operations to report. . 0 V OF T�� ' �w\\\II/j;,v THE STATE Alaska Oil and Gas �w --s��-9a of T Conservation Commission F�=�- M A 1 .AS :A ,• friti 333 West Seventh Avenue a If GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 0.0., Main: 907 279.1433 ALASY' Fax 907.276 7542 www aogcc alaska gov CA- 'V Stan Porhola Operations Engineer Hilcorp Alaska, LLC 0 1:-______1-3 7 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB I-11 Sundry Number: 315-481 Dear Mr. Porhola: 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 timelyif pP 4 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 7 Foerster Chair DATED this �3 day of August, 2015 Encl. ` ` ' , 7 ' STATE OF ALASKA H 0 6 ,,, ALASKA OIL AND GAS CONSERVATION COMMISSION ors 8`1.3 Ii $ APPLICATION FOR SUNDRY APPROVALS / 6,4 4- (';. 20 MC 25.280 1.Type of Request: Abandon❑ Plug Perforations❑ Fracture Stimulate p Pull Tubing ❑ Operations shutdown ❑ Suspend❑ Perforate 0 Other Stimulate ❑ Alter Casing 0 Change Approv�lTogram ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well 2 C enter Susp Well 0 other. Coil Pump Change 2• 2.Operator Name: 4.Current Well Class: 5.Permit to Dril Number. ET Fc.. /J� Hilcorp Alaska,LLC • Exploratory ❑ Development 2' 201-137 ' 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-23033-00-00. tzJS 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O.477.05 / Will planned perforations require a spacing exception? Yes ❑ No 11/ MILNE PT UNIT SB 1-11 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025517 , MILNE POINT/SCHRADER BLUFF OIL . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 13,170' 3,644 - 13,170 - 3,644 - N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 101' 20" 101' 101' N/A N/A Surface 2,730' 10-3/4" 2,730' 2,730' 3,580psi 2,090psi Intermediate 10,748' 7" 10,748' 3,676' 7,240psi 5,410psi Liner"A" 2,593' 4-1/2" 13,124' 3,644' 8,430psi 7,500psi Liner"B" 2,364' 4-1/2" 13,170' 3,695' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 4-1/2" 12.6#/L-80/NS-CT 10,302 Packers and SSSV type: Baker S-3 Packer ✓ Packers and SSSV MD(ft)and ND(ft): 10,215'MD/3,565'ND N/A 7 N/A 12.Attachments: Description Summary of Proposal 0 '13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 2 Exploratory ❑ Stratigraphic❑ Development 0 k Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 8/20/2015 Commencing Operations: OIL ❑✓ ' WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: N/A GAS ❑ WAG 0 GSTOR ❑ SPLUG ❑ Commission Representative: N/A GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Email sporholaCa�hilcoro.com Printed Name Stan Porhola // Title Operations Engineer G Signature ��r� Phone 777-8412 Date D/o6As-- COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No U Subsequent Form Required: /G -" Q LI I APPROVED BY Approved by: agi P COMMISSIONER THE -COMMISSION Date: 8 —/5— /g- 3" a 1� nPiniMA � g/H/I Cihmd Fnrm enii • Well Prognosis Well: MPU I-11 Ilileorp Alaska.LL Date:8/05/2015 Well Name: MPU I-11 API Number: 50-029-23033-00 Current Status: Oil Well [Jet Pump] Pad: I-Pad Estimated Start Date: August 20th, 2015 Rig: Coil Tubing Reg.Approval Req'd? Yes _ Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 201-137 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) AFE Number: Current Bottom Hole Pressure: 1,873 psi @ 4,000' TVD (Last BHP measured 7/02/2014) Maximum Expected BHP: 1,873 psi @ 4,000' TVD (No new perfs being added) A Max.Allowable Surf Pressure: 388 psi (Based on SBHP taken 7/02/2014 and water cut of 50% (0.385psi/ft)with an added safety factor of 1,000' TVD of oil cap) Brief Well Summary: MPU I-11was drilled in 2001 using Nabors 22E and completed as a dual-lateral in the Schrader Bluff NE and OA sands with a Jet Pump. The completion was pulled and the ESP completion changed out in 2001 using Nabors #4ES. The completion was pulled and changed out in 2009 using Nabors #3S to replace the 2-7/8" tubing ESP completion with a 4-1/2"tubing Jet Pump completion. Notes Regarding Wellbore Condition • Deviation down to pump section (max angle 85.8° @ 4,806'). Deviation at pump is 76°. • Casing last tested to 250/3,500 psi for 30 min down to 10,209' on 3/12/2009. • Jet Pump currently active, performance continues to degrade (likely solids). Objective: The purpose of this work/sundry is to pull the existing Jet Pump, cleanout the lateral and run a new Jet Pump. / Brief Procedure: Coiled Tubing Procedure: 1. MIRU Coiled Tubing, PT BOPE to 4,SOOpsi Hi 250 Low. 2. RIH w/2.00" coil w/3.5"wash nozzle and cleanout to top of Jet Pump+/- 10,118' MD. POOH. a. Min ID is 3.813"thru Sliding Sleeve. 3. RIH w/2.00" coil w/GS pulling tool and pull Jet Pump+/- 10,118' MD. POOH. 4. RIH w/2.00" coil w/3.5" wash nozzle to sliding sleeve at+/- 10,118' MD. 5. Bullhead filtered 8.4 ppg produced water down annulus, lifting sand/solids up the 2.0" coil x 4.5" tubing annulus. POOH. 6. RIH w/2.00" coil w/shifting tool and shift sliding sleeve closed at+/- 10,118' MD. POOH. 7. RIH w/2.00" coil w/3.5"wash nozzle and cleanout to PBTD at+/- 13,125' MD. POOH. a. Min ID is 3.725"thru XN Nipple. 8. RIH w/2.00" coil w/shifting tool and shift sliding sleeve open at+/- 10,118' MD. POOH. 9. RIH w/2.00" coil w/GS running tool and run Jet Pump+/- 10,118' MD. 10. PU to+/- 10,100' MD. Displace well over to 8.4 ppg produced water. • Well Prognosis Well: MPU I-11 llilcorp Alaska.LL Date:8/05/2015 a. Estimated volume (w/o coil in hole) is 154 bbl. 11. POOH w/coil. LD GS running tool. 12. RD Coiled Tubing. 13. Turn well over to production. Attachments: 1. As-built Schematic 2. Coil BOPE Schematic Milne Point Unit Well: MPU I-11 SCHEMATIC Last Completed: 2/02/2009 «ac:,r,::u::..k:,LIC., 201-137 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 94/H-40 19.124 Surface 101' Orig.DF Elev.=64.70'/Orig.GL Elev.=34.70' 10-3/4" Surface 45.5/L-80/BTC 9.950 Surface 2,730' 7" Intermediate 26/L-80/Hydril 521 6.276 Surface 10,748' 20' 4-1/2" Slotted Liner"A" 12.6/L-80/IBT 3.958 10,406' 12,999' 4-1/2" Slotted Liner"B" 12.6/L-80/IBT 3.958 10,761' 13,125' TUBING DETAIL 4-1/2" Tubing 12.6/L-80/NS-CT 3.958 Surface 10,296' JEWELRY DETAIL No Depth Item 1 10,125' HES 4.5"'XD'Dura Sliding Sleeve 2 10,149' Schlumberger SPM Gauge—ID Change to 3.879" 3 10,215' Baker S-3 Packer 7"x 4.5" 4 10,239' 4.5"XN-Nipple—3.725"No Go 5 10,302' 4.5"TC-II WLEG—Bottom @ 10,303' 6 10,336' Baker Hook Wall,Hanger above 7"Window 7 10,360' Baker Hook Wall,Hanger outside 7"Window 1Q3/4" , 8 10,567' Baker ZXP Liner Top Packer 9 10,582' Baker 7"x 5"HMC Liner Hanger Notes:Nabors 22E RKB to THF=28.1';Nabors 35 RKB to THF=21.5'.1=6.6' All depths are corrected back to original RKB. OPEN HOLE/CEMENT DETAIL 20" Cmt w/260 sx of Arcticset(Approx)in 30"Hole LATERAL WINDOW DETAIL 10-3/4" Cmt w/600 sx of PF"L",440 sx Class"G"in Window in 7"Casing @ 13-1/2"Hole • • 10,345'to 10,357' 7" Cmt w/1,400sx Class"G"in 9-7/8"Hole • • Well Angle @ Window=77 Deg. WELL INCLINATION DETAIL WELLHEAD e 1KOP @ 500'MD Tree 4-1/16"-5M FMC 2 75 to 85 Deg.2,900'—10,300' Wellhead 11"x 4.5"5M Gen.6 w/4.5"TC-IIT&B Max Hole Angle=86 deg. @ 4,806'MD Tubing Hanger CIW"H"BPV Profile Hole 76 Deg.@ Sliding Sleeve fi ` 3 .' 4 GENERAL WELL INFO 5 API:50-029-23033-00-00 • Drilled and Completed by Nabors 22E -10/06/2001 6 NOTE: .oA'LLac Prior to setting or pulling 4.5"BPV or TWC,notify FMC. 8 gni4.5"TCII thread profile compatibility issue exists. � ' "CB"Lateral 7" TD=13,170'(MD)/TD=3,644(TVD) PBTD=13,170'(MD)/PBTD=3,644'(ND) Downhole Revised:2/21/2009 Updated By:STP 8/05/2015 r II Milne Point Unit COIL BOPE MPU I-11 08/05/2015 Ililrotp 11a•ka.t.t.l: MPU I-11 20 X 10%X7X4% Coil Tubing BOP 7Lubricator to injection head � U I �i'� f7—__I 1.75"Tandem Stripper i� 11:Bhnd/Shear 1 •I,I, Blind/Shea==' 1/1610 ,','• 11)111I1Bhnd/Shear Wei Blind/Shearl,I,I•I( t = __ Slip =� Slip .11111 MINN 011111 Pipe _I Pipe OF Mud Cross MI �i 4 1/16 1OM X 4 1/16 10M Outlet dil w/2-2 1/16 10M full ! opening FMC valves e. 1111-1 III ; 41401 ( 1 M.M ( 1ot [ T 0 11111 Manual Manual Manual Manual 2 1/16 10M 2 1/16 10M it 2 1/16 10M 2 1/16 10M Crossover spool 1 4 1/16 10M X 4 1/16 5M LLU L �0' Valve,Swab,WKM-M, IIN7A \r���0FE 4 1/16 5M FE ,61-"S a;Je 116' ammii • A lriT,':i / N I Valve, Upper Master,Baker, 41/165M FE,w/Hydraulic Valve,Lower Master,WKM-M, Leo V 4 1/16 5M FE Tubing Adapter,4 1/16 SM i il • ,,,��\i%� H , STATS i--,_,_,=;_C. ,1 wsdy " - .� - v ,T, / i ,'2 1 K,,,„,,,,„a� � -- --- 333 Wag Sevenih Avenue • x `= ` G 0VF RNOR ` I- v N 1'.F \R1,I q r ( qq Anchorage Alas<a 99501-3572 V " w' �� ��+b , Iv 4m n 907_�/ 1433 Aaron Ramirez Well Intervention Engineer11 BP Exploration (Alaska), Inc. aol f1 1 P.O. Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Field, Schrader Bluff Oil Pool, SBL MPI-11 Sundry Number: 314-039 Dear Mr. Ramirez: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, f, -/Zr .--- Cathy P. oerster Chair DATED this�day of January, 2014. Encl. ces \ 5 1 r STATE OF ALASKA AI/ II,"y <; vl ALASKA OIL AND GAS CONSERVATION COMMISSION \ 127-5 4(2r((4- APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑Q • Change Approved Program❑ Suspend❑ Plug Perforations Perforate❑ Pull Tubing 0 Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Exploratory ❑ Development 0. 201-137-0 3.Address: Stratigraphic ❑ Service EI6.API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-23033-00-00 7.If perforating: 8.Well Name and Number. ?Alb What Regulation or Conservation Order governs well spacing in this pool? SBL MPI-11/MPI-1-1-L-1. Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025517 . MILNE POINT, SCHRADER BLFF OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 13170 . 3644 • 13170 - 3644 - None None Casing Length Size MD TVD Burst Collapse Structural Conductor 83 20"94#H-40 29-112 29-112 Surface 2701 10-3/4"45.5#L-80 28-2729 28-2278.09 5210 2480 Intermediate None None None None None None Production 10719 7"26#L-80 29-10748 29-3675.44 7240 5410 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(It): See Attachment • See Attachment 4-1/2"12.6#L-80 L-80 25-10300 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and TVD(ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development [ ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 9/15/14 Commencing Operations: Oil Q - Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Aaron Ramirez Email Aaron.Ramirez©BP.Com Printed Name Aaron Ramirez Title Well Intervention Engineer Signature Phone 564-5943 Date Jfr io Prepared by Garry Catron 564-4424 COMMISSION USE ONLY Q Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3 \44. – d 3_ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ p Other: RBDMS MAY 09 2014 Pho7'o Giacvrnenf r>°pCyti Spacing Exception Required? Yes ❑ No Er Subsequent Form Required: / O — 401- APPROVED BY (/ F. 64„)ii_____ Approved by: COMMISSIONER THE COMMISSION Date: /- 2 2- // i3(A ihreilif Form 10-403 Revised 10/2012 Ar v �pti¢n�tal f 12 months from the date of approval. Submit Form and Attachments in Duplicate V1 -F ! l17 /!4' U 1V11V At00y -0 0 0 0 0 0 0 co � 0aoaoaoao = J J J J J u) 0_ 000 _0 0 0 CO LLo Tr Tr in p N- N- Ln N 1- U 1000000 M (r) M Cr) 7 to Tr V' N N m •- CO CO N Ln CO a) N 03 (r) Tr in co co " TrV r- co (O O (O N Ln M cc. M M a O Q) O) Q) co Ln Q N M M N N N CO r N c Cl) Tr O co O O m N N CC) 1 O — Co) M O o O Q N pp 2 Q 0 CO H O M (O to 00 In U Q N O O N N N 2 O O O O Oo 00 ' 00 J J o J N = J O co • Nr r r r O N N • M N N r r 4 4 O 4 t.. OM O M Oo O O a co N- N O N O J � � z O W O 0ZW0LiiZ ZMWOCCE O , Zci 0 _1M0- (/) • , Perforation Attachment ADL0025517 Well Date Perf Code MD Top MD Base TVD Top TVD Base MPI-11 9/25/01 SL 10761 13125 3677 3643 MPI-11L1 10/3/01 SL 10406 13079 3608 3562 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF by 0 Date: January 2, 2014 To: AOGCC n_ From: Aaron J. Ramirez, Well Intervention Engineer aM Subject: Sundry Notice 10-403 Approval Request BPXA Milne Point I Pad, Well 11 (MPI-11)/ This application for Sundry approval for BPXA Well MPI-11 is for the inspection and repair of surface casing. Currently, part of the surface casing on this well is exposed to atmosphere, most likely due to corrosion. Well MPI-11 has been determined to have a surface casing leak at an unknown depth from surface. BPXA requests approval to inspect and repair the surface casing. With approval, inspection and repair of the surface casing will follow the general, outlined procedure below: 1. Secure the well from the reservoir with plug(s), kill weight fluid and BPV. 2. Remove the cellar, wellhouse, tree, flowline and other equipment necessary for repair. 3. Survey existing utilities and other critical infrastructure, including the wellhead. 4. Drive piles to support the wellhead and well support frame. Drive sheet piling for excavation around well. 5. Install wellhead and well support frame. 6. Excavate inside the parameters of the sheet piling, to an estimated bottom depth of 20 feet. 7. Install nitrogen purge equipment for conductor (and OA if needed) so that hot work may be conducted in a safe manner. 8. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. Remove additional conductor as necessary. Notify AOGCC inspector for opportunity to inspect. 9. Install repair patch needed to return the casing to operational integrity. 10.Patch will be inspected for acceptance. 11.Perform MIT-OA. 12.Install external wrap on casing to safeguard against future, potential corrosion. 13.Backfill and compact around well and install cellar. 14.Demobilize wellhead and well support frame. 15.Reinstall tree, flowline and wellhouse. Remove plug(s), BPV and hand well over to well integrity for evaluation. 16.File 10-404 with AOGCC post repair, complete with pictures demonstrating repair. 1 Tree: 4 1/16"-5M CIW I\/IPI 1 1 0' IF Elev. =64.12'(Nabors 22-E) Wellhead: 11"5M Gen 5 w/- a 6" O. L. Elev.=35.10'(Nabors 22E) Tubing Hanger TC-II T&B threads • with CIW"H"BPV profile 20",92#/ft H-40 Welded 112' Max well bore Angle:84°@ 4994'MD +60°past 2554'MD Hole angle trough perfs=90°+ 10.75",45.5#/ft BTC L-80 2730' A 4.5" 12.6#L-80 IBT-M tubing (ID=3.958",cap=.0152 BPF) 7"26 ppf,L-80, BTC-mod production casing (drift ID=6.151",cap.=0.0383 bpf) (Capacity with 4.5"tbg= 0,0186 bpf) KOP @ 300' "Reverse Circulation"Jet Pump Configuration LL ProdumdFuld s • HES 3.813" "XD"Dura sliding sleeve (Opens down) 101 18' 4.5"SLB'NDPG'Gauge Mandrel 10142' (3.879 ID) (3547'tvd) N Baker 7"x 4.5"S-3 Pkr 3.875"ID 10209' HES 3.813"XN-Nipple 10232' ReservarFwm (3.725"No Go ID) WLEG btm 10296' Baker Hook Wall Hanger above 7"Window 10336' Baker Hook Wall Hanger below 7"Window"10345' Baker Down Swivel-up lock sub 10360' 6 1/8"Hole TD @ 13190' Window in 7" Casing @ 6508'-6520' -- Well Angle @ window= 76° OA Lateral 66 jts-4 1/2"Slotted Liner 12.6#L-80 IBT(10406'-12999') Baker Tie Back Sleeve 7028' Baker.4 1/2"Packoff Bushing 13079' Baker ZXP Liner Top Packer 10567' Baker 4 1/2"Guide Shoe 13124' Baker 7"x 5" HMC Liner Hanger 10582' 7" Halliburton Float Collar 10665' 6 1/8"Hole TD @ 13170' 7" Halliburton Ream Shoe 10747' OB Lateral 61 jts-4 1/2", 12.6#/ft.Slotted Liner 12.6#L-80 IBT(10761'-13125') Baker 4 1/2"Packoff Bushing 13125' Baker 4 1/2"Guide Shoe 13170' DATE REV. BY COMMENTS M I LN E POINT UNIT Nabors 22E Drill Multilateral& WELL I-11 10/6/01 GMH ESP Completion 12/06/01 M. Linder RWO Nabor 4-ES API NO: 50-029-23033 2/2/09 L. Hulme Conversion to Jet Pump N-3ES API NO: 50-029-23033-60 L1 BP EXPLORATION (AK) • 1 bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 December 30, 2011 Sto -= P FER 1 7 'AWL Mr. Tom Maunder a0 ✓ - Alaska Oil and Gas Conservation Commission P 1 ` 1 333 West 7 Avenue f ►' 4 Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPI -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPI -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10404) MPI -Pad 10/9/2011 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft gal MPI -01 1900900 50029220650000 0.1 NA 0.1 NA 8.5 9/5/2011 MPI -02 1900910 , 50029220660000 Sealed coductor NA NA NA NA NA MPI-03 1900920 50029220670000 Sealed coductor NA NA NA NA NA MPI -04A 2010920 50029220680100 Sealed coductor NA NA NA NA NA MPI -05 1951200 50029225830000 2.7 NA 2.7 NA 27.2 11/2/2009 MPI-06 1971950 50029228220000 Open Flutes - Treated NA NA MPI -07 1951510 50029226020000 1.7 NA 1.7 NA 16.2 8/21/2011 MPI-08 1971920 50029228210000 1.3 NA 1.3 NA 15.3 11/2/2009 MPI-09 2001030 50029229640000 1.3 NA 1.3 NA 13.6 11/1/2009 MPI -10 2001090 50029229660000 Open Flutes - Treated NA NA ----> MPI -11 2011370 50029230330000 1.3 NA 1.3 NA 10.2 8/19/2011 MPI -12 2011630 50029230380000 0.2 NA 0.2 NA 7.7 10/9/2011 MPI -13 2010750 50029230120000 0.85 NA 0.85 NA 8.5 9/5/2011 MPI -14 2041190 50029232140000 1.9 NA 1.9 NA 16.2 8/23/2011 MPI -15 2021520 50029231060000 1 NA 1 NA 9.4 8/19/2011 MPI -16 2041580 50029232210000 1.75 NA 1.75 NA 17.0 8/19/2011 MPI -17 2040980 50029232120000 1.75 NA 1.75 NA 13.6 8/23/2011 MPI -19 2041350 50029232180000 1.4 NA 1.4 NA 10.2 8/19/2011 ~.~~~ STATE OF ALASKA~9 ~, OIL AND GAS CONSERVATION COM~SSION r~~~ ~ ~ ~ ~•~' '"~`~~ OF SUNDRY WELL OPERATIONS ~~~~ar~ 1. Operations Performed: ^ Abandon ®Repair Well - ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other . ^ Change Approved Program ^ Operation Shutdown Jet Pump Conversion ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. -® Development ^ Exploratory 201-137 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23033-00-00 - 7. KB Elevation (ft): 63 55' ~ 9• Well Name and Number: . MPI-11 S. Property Designation: 10. Field /Pool(s): - ADL 025517 ~ Milne Poi nt Unit / Schrader Bluff 11. Present well condition summary Total depth: measured 13170 feet true vertical 3644 feet Plugs (measured) None Effective depth: measured 13170 feet Junk (measured) None true vertical 3644 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 72' 20" 101' 101' ......1530 520 Surface 2702' 10-3/4" 2730' 2278' 5210 2480 Intermediate Production 10719' 7" 10748' 3675' 7240 5410 Liner 2603' 4-1/2" 10567' - 13170' 3647' - 3644' 8430 7500 :. ~ ~ ~` ~;x* ~..1~i r Perforation Depth MD (ft): Slotted 10761' - 13125' Perforation Depth TVD (ft): Slotted 3677' - 3643' 4-1/2", 12.6# L-80 10296' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker S-3 Packer 10209' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 400 0 Subsequent to operation: 138 31 0 1853 263 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ~ ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: Contact Aras Worthington, 564-4102 N/A Printed Name So ra Stewman Title Drilling Technologist 1I 11it ,, Prepared By Name/Number: ` ~ ~ Si ure Phone 564-4750 Date V ~ ondra Stewman, 56a-4750 1 Form 10-404 Revised 04/2006 ~ , Submit Original Only ~ ~~~ ~ ~ 4~0~ ~`~r 11 Tree: 4 1/16" - 5M CIW Wellhead: 11" 5M Gen 5 w/ ~" Tubing Hanger TC-II T&B threads with CIW "H" BPV profile 20", 92 #/ft H-40 Welded 112' Max well bore Angle: 84° ~ 4994' MD + 60° past 2554' MD Hole angle trough perfs = 90°+ 10.75", 45.5#/ft BTC L-80 2730 4.5" 12.6# L-80 IBT-M tubing (ID = 3.958", cap = .0152 BPF) 7" 26 ppf, L-80, BTC-mod production casing (drift ID = 6.151 ", cap. = 0.0383 bp0 (Capacity with 4.5" tbg = 0.0186 bpf) KOP C~3 300 ' ~ 'Reverae Grculatlon' Jet Pump Conflguratlon \ I - I sI I LL I Produced Fluitl 81 ~I f LLI o. I ~I I ~ ~ °I ~ T -, ~i i ~ ,,,,.., Reservoir Fluid I HES 3.813" "XD" Dura sliding sleeve (Opens down) 4.5" SLB 'NDPG' Gauge Mandrel (3.879 1D) (354T tvd) 10118' 10142` Baker 7" x 4.5" S-3 Pkr 3.875" ID 10209' HES 3.813" XN-Nipple 10232` (3.725" No Go ID) WLEG btm 10296` Window in 7" Casing @ 6508` - 6520' Well Angle @ window = 76° Baker Tie Back Sleeve 7028` Baker ZXP Liner Top Packer 10567' Baker 7" x 5" HMC Liner Hanger 10582' 7" Halliburton Float Collar 10665` 7" Halliburton Ream Shoe 10747' DATE I REV. BY I COMMENTS Baker Hook Wall Hanger above 7° Window 10336' Baker Hook Wall Hanger below 7" Window" 10345' Baker Down Swivel-up lock sub 10360' 6 118" Hole TD @ 13190' OA Lateral 66 jts - 4 1/2" Slotted Liner 12.6# L-80 IBT (10406' - 12999') _, Z Baker. 41/2" Packoff Bushing 13079' Baker 4 1/2" Guide Shoe 13124' 6 1/8" Hole TD @ 13170' OB Lateral 61 jts - 4 1/2", 12.6#/ft. Slotted Liner 12.6# L-80 IBT (10761'-13125') 10/6/01 GMH ESP Completion 12/06/01 M. Linder RWO Nabor 4-ES 2/2/09 L. Hulme Conversion to Jet Pump N-3ES Baker 4 1/2" Packoff Bushing 73125' Baker 4 1/2" Guide Shoe 13170' MILNE POINT UNIT WELL I-11 API NO: 50-029-23033 API NO: 50-029-23033-60 L1 BP EXPLORATION {AK) M P 111 Orig. DF Elev. =64.12' (Nabors 22-E) Or~. Elev. = 35.10' (Nabors 22E) BP AMOCO Operations Summary Report Page 1 of 5 Legal Well Name: MPI-11 Common Well Name: MPI-11 Spud Date: 9/8/2001 Event Name: WORKOVER Start: 2/6/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/21/2009 Rig Name: NABOBS 3S Rig Number: N3S Date From - To Hours I Task I Code ~ NPT Phase 2/13/2009 111:00 - 20:00 20:00 - 00:00 9.001 RIGD I C 4.00 MOB P 12/14/2009 00:00 - 01:00 1.00 MOB P 01:00 - 12:00 11.00 RIGU P 12:00 - 16:00 1 4.00 ~ KILL ~ P 16:00 - 17:00 1.001 WHSUR I P 17:00 - 19:30 1 2.50 ~ KILL ~ P 19:30 - 20:30 1.001 KILL 1 P 20:30 - 21:30 1.00 I KILL I P 21:30 - 00:00 2.50 ~ KILL ( P 12/15/2009 100:00 - 02:00 I 2.001 KILL ~ P 02:00 - 06:00 4.00 KILL P 06:00 - 06:30 I 0.501 KILL 1 P 06:30 - 07:30 I 1.00 I KILL I P Description of Operations PRE Wait on pad prep and site prep around well slot MPI-11 due to last minute change from Milne Point Management in Anchorage on new location for the Rig. Hold safety focus meeting with day crew since it is their first day back on the Slope. Perform pad prep on MPI-Pad for the Rig and Camp. PRE Trucks on location. Hold PJSM with crews. Connect trucks to camp and modules. Call pad-op to witness moving carrier off well slot. Sign off permits and post rig. Move carrier and modules from C-43 to I-11. Notify Milne Pt. security of move. Calf heavy equipment to blade drifts between C-pad access road and 1-pad. PRE Continue moving rig from C-43 to I-11. PRE Lay mats around well, lay down herculite. Set BOPE, tree and kill manifold behind well. Spot carrier over well slot with pad-op witness. Set mats for pipe shed and pit mod. Set camp on edge of pad. Raise and scope the Derrick at 0900 hrs. The Ri was acce ted at 1200 hrs on 02/14/2009. DECOMP Start RU of circulating lines to the Kill Manifold and Tree. Spot the Upright Tank and Little Red. Spot and hook up lines to the Tiger Tank. Re-install pallet lift on mud pits complex. Take on heated, 140 degF seawater to the Pits. DECOMP RU Lubricator to the Tree with Well Su rt Techs. Pressure test to 500 osi. Pull 2-1/2" Tvge "H" BPV. OA = 200 psi., DECOMP Pressure test surface lines to 2000 psi. Pressure test downstream line to the Tiger Tank to 500 psi. DECOMP Initial pressures on wellhead: TBG = 110 psi, IA = 420 psi, OA = 140 psi. Bleed IA thru choke to Tiger tank from 420 psi to 70 psi, tubing pressure fell from 110 psi to 40 psi during bleed. Break circulation at 2 BPM / 260 psi and circulate 70 bbls the long way. Circulate thru choke to Tiger tank, retums are gas and crude. FCP is 3.5 BPM / 850 psi. Returned 36 bbls to Tiger tank, 51 % returns. DECOMP Bullhead 150 bbls down tubing into formation at 3.5 BPM / 1470 psi. Monitor well for 15 min, tubing fell to 350 psi and IA fell to 400 psi in that time period. DECOMP Open well and break circulation at 2 BPM / 420 psi down the tubing taking retums thru the choke to Tiger tank. Circulate 515 bbls at 3.5 BPM / 920 psi. Circulation returns were gas and heavy crude throughout. Fluid cleaned up to weigh 8.5 ppg in retums. Returned 475 bbls to Tiger tank,_81 %retums. DECOMP Monitor well for 30 min. Tubing and IA stabalized at 130 psi. Calculated kill weight fluid off surface pressure + 100 psi overbalance to equal 9.66 ppg. Order 3 trucks of 9.8 ppg brine from MI mud plant. Blow down lines and monitor well. DECOMP Wait on trucks and monitor well. Evacuate all fluids from Tiger tank with vac trucks. 1st 9.8 ppg brine truck on location at 03:30 hrs, load pits. Second truck on location at 05:00 hrs. Continue to wait on 3rd truck. DECOMP Pre-tour checks and service the Rig. The Tubing pressure has fallen to slight amount of blowing but not enough to register on the gauge, the IA is at 20 psi and the OA is at 120 psi. DECOMP Continue waiting on the third truck to arrive. It broke down on the road and they are sending another one to take on its load rnntea::vwe~~a i:wc:cv nn BP AMOCO Operations Summary Report Page 2 of 5 Legal Well Name: MPI-11 Common Well Name: MPI-11 Spud Date: 9/8/2001 Event Name: WORKOVER Start: 2/6/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/21/2009 Rig Name: NABOBS 3S Rig Number: N3S Date From - To Hours Task Code NPT Phase Description of Operations 2/15/2009 106:30 - 07:30 I 1.001 KILL ~ P 07:30 - 08:30 I 1.00 I KILL I P 08:30 - 12:00 I 3.501 KILL I P 12:00 - 12:30 0.50 KILL P 12:30 - 13:00 0.50 KILL P 13:00 - 13:30 0.50 WHSUR P 13:30 - 15:00 1.50 WHSUR P 15:00 - 15:30 I 0.501 WHSUR P 15:30 - 17:00 1.50 I W HSU R I P 17:00 - 22:00 5.00 BOPSU~ P 22:00 - 00:00 2.00 BOPSU P 12/16/2009 100:00 - 03:00 I 3,00 I BOPSUp P 03:00 - 04:00 1.00 BOPSUf~ P 04:00 - 06:00 2.00 BOPSU P 06:00 - 07:00 I 1.00 I PULL I P DECOMP and come to location. Third truck arrives on location at 0730 hrs. DECOMP Hold pre-kill safety meeting and blow air through all lines to ensure clear and properly lined up. DECOMP Initial WHPs of Tubing = 10 psi , IA = 30 psi , OA = 120 psi. Break circulation down the Tubing with 9.8 ppg brine taking returns up the IA, through the Choke to the Tiger Tank. Circulate 70 bbls with full returns at a rate of 4 bpm / 930 psi and 60 psi on the IA. Close the Choke and bullhead 150 bbls of 9.8 ppg brine down the Tubing at a rate of 3 bpm / 1,100 psi with the IA rising up to 750 psi. Open the Choke and resume circulating the long way with 9.8 ppg brine at a rate of 4 bpm with final pressures of 1,200 psi on the Tubing and 70 psi on the IA. Weight of fluid in = 9.7 ppg heavy and weight of returns 9.6 ppg heavy. Circulated 385 bbls. Total losses for the whole kill were 170 bbls 150 bbls of which were t e ull ea Circulated a total of 455 bbls with 435 bbls of returns in the Tiger Tank = 95% retums. DECOMP Monitor the well for 30 minutes. Both the Tubing and IA are on a vacuum. DECOMP Blow down lines and RD circulating equipment. Finish emptying out Tiger Tank. DECOMP PU T-bar and set 2-1/2" Type "H" TWC with FMC rep. RU Test DECOMP Pressure test TWC from above to 3,500 psi for 10 charted mins. Line uo and pressure test from below with Little Red a total of 55 bbls. DECOMP Bleed pressure off the IA. IA on a vac. Blow down and RD Test Equipment. DECOMP Remove Kill Manifold from the Cellar. ND 2-9/16" Tree and Adapter Flange with FMC rep. Screw in 2-7/8" EUE 8rd pup and get 7-3/4 turns. Threads are OK. Break apart Tree and Adapter Flange and remove both from the Cellar. Attempt to fill IA but taking pressure to do so. Monitor and it is on a vacuum. DECOMP PJSM. Pull BOPE into cellar. NU BOPE. DECOMP Test BOPE 250 si low / 3,500 si high as per state and BP regulation. Test witnessed by NAD Tourpusher and BP WSL. AOGCC rep Chuck Sheave waived the state's right to witness at 6:40 hrs on 2-15-09. Tested 2-7/8" x 5" VBR with 4-1/2" test joint. DECOMP Continue ROPE test. Test 2-7/8" test joint in 2-7/8" x 5" VBR. Complete Koomey draw down test. Gravity fed 53 bbls to backside throughout test at 20 BPH. DECOMP Suck out stack. LD test joint and clear rig floor. RD Little Red from IA, blow down all surface lines. IA on vacuum. DECOMP PUMU Opso-Lopso, XO and lo-torque. Screw into Hanger profile with 7-3/4 turns. MU lubricator and pressure test to 500 si. Pull TWC. Tubin ~ and IA on vacuum. LD lubricator, lo-torque and Opso-Lopso. DECOMP Pick up and make up 2-7/8" EUE 8rd Landing Joint and TIW valve. Screw into the Hanger with 7-3/4 turns. BOLDS with Printetl: 3/6/L009 1:42:20 PM BP AMOCO Page 3 of 5 ~ Operations Summary Report Legal Well Name: MPI-11 Common Well Name: MPI-11 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 3S Date From - To Hours Task (Code NPT Spud Date: 9/8/2001 Start: 2/6/2009 End: Rig Release: 2/21/2009 Rig Number: N3S Phase Description of Operations 2/16/2009 106:00 - 07:00 I 1.001 PULL I P 07:00 - 07:30 0.501 PULL I P 07:30 - 09:30 I 2.001 PULL I P 09:30 - 10:30 I 1.00 PULL I P 10:30 - 11:30 1.00 I PULL I P 11:30 - 22:00 I 10.501 PULL I P 22:00 - 23:00 1.00 I PULL I P 23:00 - 00:00 1.00 PULL P 2/17/2009 00:00 - 01:00 1.00 PULL P 01:00 - 04:00 3.00 PULL P 04:00 - 06:00 2.00 PULL P 06:00 - 06:30 0.50 EVAL P 06:30 - 07:30 1.00 EVAL P 07:30 - 14:30 i 7.00 EVAL I P 14:30 - 17:30 I 3.00 I EVAL I P 17:30 - 00:00 6.50 EVAL P 2/18/2009 00:00 - 01:30 1.50 EVAL P 01:30 - 10:30 I 9.001 EVAL I P 10:30 - 13:00 I 2.50 EVAL I P 13:00 - 16:00 I 3.001 EVAL I P DECOMP FMC rep. Check the IA through the 2" valve and it is on a vacuum. DECOMP Pull the Han er off seat and to the floor.with a PUW = 45K. Fill the backside and visually observe the fluid level dropping. DECOMP Circulate surface to surface with 9.8 ppg brine at a rate of 4 bpm / 1,000 psi. It took 8 bbls to get returns. Losing 11 bbls every 15 minutes for hourly loss rate of 44 bbls per hour (18% losses . RU Elephant Trunk and containment to the Spooler. Pumped a total of 465 bbls with crude in returns. Shut down and monitor. The fluid level is visibly dropping. DECOMP RD circulation equipment and blow down. Pull Hanger to the Floor and observe that the ESP Cable was not plugged into the Penetrator. It had fallen out of its connection on the underside of the Hanger. Remove Penetrator with Centrilift rep. String PUW = 45K ,SOW = 20K. Break out and lay down Hanger. DECOMP RU 2-7/8" Handling Equipment. Prepare floor for pulling out of the hole. Snake rope over Sheave and tie off to Spooler. DECOMP POOH with existing ESP Completion standing back 2-7/8" Tubing in the Derrick. Maintain continuous hole fill with 9.8 ppg brine with losses approx at 22 bbls per hour. Visually inspecting each Joint as POOH. 140 stands out at 2200 hrs. DECOMP Swap spools in spooling unit. Tie ESP cable to spool. Pump across top of hole, loss rate = 20 BPH. DECOMP Continue POH with ESP completion. Pump across top of hole, loss rate = 22 BPH. DECOMP Continue to POH with 2-7/8" tubing standing back in Derrick. Pump across top of hole, loss rate = 22 BPH. Pulled a total of 321 joints of 2-7/8" tubing, 2 GLM assemblies, 169 LaSalle clamps, 7 protectalizers, and 3 flat guards. DECOMP _ LD ESP assembl as er Centrilift re . DECOMP Clean and clear rig floor of ESP tools and equipment. LD 2 bad joints from string. DECOMP Pre-tour checks and service the Rig. DECOMP PUMU BHA #1 with Baker rep as follows: 6" Bit, 7" Casing Scra er, Boot Basket, Boot Basket, Bit Sub. OAL = 13.99'. DECOMP TIH with BHA #1 on 2-7/8" Tubing from the Derrick. Maintain continuous hole fill with 9.8 ppg brine while TIH. DECOMP Reci rocate scra er across interval, 10200' - 10300'. Circulate surface to surface ~ 4 BPM / 1030 psi. Circulated 357 bbls and lost 40 bbls on circulation. DECOMP PJSM. POH with 2-7/8" tubing standing back in Derrick. DECOMP BOLD 7" scraper/bit assembly as per Baker fishing rep, junk baskets empty. Clean and clear rig floor. DECOMP PJSM. PUMU 7" RTTS as er Halliburton re RIH with RTTS on 2-7/8" tubing out of Derrick. Pump across top of hole, loss rate = 14.5 H DECOMP MU TIW valve. Set RTTS ~ 10296' w/ 18K down. (Tbg free in elevators). Unable to pressure up on Csg. (suspect problem with packer bvnassl Repeat at 10280' / 10260' unsuccessful b ass. Test Cs to 3500 si for 30 charted minutes. Unseat RTTS maintain well control by pumping across the top. DECOMP Rig down ESP shieve, elephant trunk, and drain hose from Printed: 3/6/2009 1:42:20 PM BP AMOCO Operations Summary Report Page 4 of 5 Legal Well Name: MPI-11 Common Well Name: MPI-11 Spud Date: 9/8/2001 Event Name: WORKOVER Start: 2/6/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/21/2009. 'Rig Name: NABOBS 3S Rig Number: N3S Date From - To Hours Task Code NPT Phase Description of Operations 2/18/2009 13:00 - 16:00 3.00 EVAL P DECOMP Derrick. RU stabbing board. 16:00 - 00:00 8.00 EVAL P DECOMP POH laving down 2-7/8" tubing. Losses ~ 15 Bbls / Hr. 255 2/19/2009 100:00 - 02:00 2.001 EVAL P 02:00 - 02:30 0.50 EVAL ~ P 02:30 - 06:00 3.50 BUNCO 06:00 - 08:00 1 2.00 08:00 - 11:00 3.001 RU 11:00 - 00:00 I 13.001 RUN 2/20/2009 00:00 - 03:00 3.00 03:00 - 17:00 I 14.00 17:00 - 19:30 2.501 RU 19:30 - 20:30 I 1.00 20:30 - 22:00 I 1.50 I RU 22:00 - 23:00 I 1.00 23:00 - 00:00 I 1.00 12/21 /2009 100:00 - 01:30 I 1.50 01:30 - 07:30 I 6.00 I RU 07:30 - 10:30 I 3.00 joints out at 24:00 hrs. DECOMP Continue to LD 2-7/8" tubing. Fluid loss rate = 15 BPH. Called out SLB and Baker completions. LD total of 329 joints. DECOMP LD 7" RTTS and set in pickup. Clear rig floor. RUNCMP RU torque tum equipment, single joint elevators, compensator and YC elevators. RUNCMP Load SLB I wire spooler to rig floor, instal shieve in derrick. Inspect completion equipment. PJSM RUNCMP PUMU 4-1/2" jet pump completion assembly. WLEG, XN w/ RHC-M Plug, Baker S-3 packer, SLB SPM gauge, HES XD Duro Sliding Sleeve. Pressure test SPM wire to 5000 psi. RUNCMP RIH with 4-1/2", 12.6# L-80 NSCT tubin .Pumping 9.8 #/gal brine across the top with losses of - 13 Bbls/Hr. Each joint weight compensated, and connections inspected and torque turned to 3975 ft-Ibs. SLB checking conductivity of I-Wire every 1000'. Install 1 ea Cannon clamp on first 10 jts and then 1 ea every other joint. Ran a total of 133 jts at 24:00 hrs. RUNCMP Pipe shed empty. Stab safety valve and pump across top of hole. Load and strap additional joints of tubing in shed needed to finish completion. Finalize tally and distribute to personnel. RUNCMP PJSM. Continue running 4.5", 12.6#, L-80 completion as per running order. Torque to 3,975 ft-Ibs and run Cannon clamp every other joint to secure 1-Wire. SLB checking conductivity every 1,000'. Loss rate = 12 BPH. Run total of 252 joints of 4-1/2" tubing. RUNCMP PUMU FMC 11" 4- .Make penetration with I wire and packoff. PUW of 73K and 27K SOW. Land tubing hanger. RILDS. BOLD landing joint. Close blind rams. RUNCMP RU LRS lines to IA. Connect Methanal/Water pup to LRS unit. P/T lines to 3,500 psi. RUNCMP Line flow path thru choke. Reverse circulate with LRS with inhibited 9.8 ppg brine taking returns thru choke back to pits. Circulate 195 bbls at 2.25 BPM / 210 psi, chase with 5 bbls of methanol cap. Lost 60 bbls during circulation. RUNCMP MU Opso-Lopso with TCII crossover. Screw into hanger. Dr_ oL_ Modified Ball and Rod with rubber cups (1-7/8" Ball, 2.5" GS profile on top, 16' 10" OAL). LD Opso-Lopso. Close blinds and line up rig pump. Picture of ball and rod included in handover folder. RUNCMP Break circulation and um 9.8 brine to chase Ball and Rod to bottom. Pump at 2.5 BPM / 610 psi. RUNCMP Continue pumping at 2.5 BPM / 610 psi. Pump a total of 226 bbls (1.5 tubing volume), unable to catch Ball and Rod on seat. Shut down pump and discuss with day man. Tubing pressure fell to 340 psi after shutting down pump. RUNCMP Call for 290 bbls of 9.8 ppg brine. RD stabbing board, clean out pits and upright tank with dirty vac truck. Load pipe shed with equipment in preparation for rig move. RU LRS pump unit to spool below rams to bullhead down tubing. RUNCMP Pum 9.8#/ al brine down tubin varying rates from .5 BPM to 3.5 BPM. Surging fluid by varying rates in attempt to place_ YIIr1LBO: J/b(LW}! 1:4L:GU YM BP AMOCO Operations Summary Report Legal Well Name: MPI-11 Page5of5~ Common Well Name: MPI-11 Spud Date: 9/8/2001 Event Name: WORKOVER Start: 2/6/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/21!2009 Rig Name: NABOBS 3S Rig Number: N3S Date From - To Hours Task Code NPT Phase 2/21 /2009 107:30 - 10:30 3.00 10:30 - 12:00 I 1.50 12:00 - 14:00 I 2.001 WHSUR I P 14:00 - 19:00 I 5.001 WHSUR I P 19:00 - 21:30 I 2.501 WHSUR I P 21:30 - 23:30 I 2.00 I WHSUR I P 23:30 - 00:00 I 0.501 WHSUR I P Description of Operations RUNCMP 1-7/8" ball with rubbler cups on seat. Pump 160 Bbls in 2nd attempt to set packer. Max pressure of 580 psi while pumping. Flow check well and U-tube tubing to IA. RUNCMP Flowcheck well and bleed 40 bbls of brine back from charging formation. Well stable. 0 psi on Tbg and IA. RUNCMP Dry rod TWC. Test from above to 1000 psi and chart for 10 minutes. Pump 10 Bbls in IA and pressure to 400 psi belo_ w TWC with no leak. Flush and drain stack. Confer with colleagues in Anchorage regarding plan forward. RUNCMP ND ROPE. LRS pumping 9.8 #/gal brine in IA every hour. Set BOP's in cradle and pull out of cellar. RUNCMP NU adapter flange and tree. Verify tree alignment with Pad operator. FMC install new SPMS seal. Schlumberger completed final test on I-Wire (BHP = 1753 psi, BHT = 65.3). Terminate I-Wire in tubing head adapter. FMC tested tubing hanger void to 5,000 psi for 30 min. Test tree to 5,000 psi for 5 min -charted. RUNCMP PUMU lubricator, test to 500 psi with diesel. Pull TWC, (Tbg on vacuum set BPV. Pump 5 bbl methanol cap down IA and 5 bbl down tubing. Release LRS to complete unit maintenance in Deadhorse. RUNCMP Normal up tree and secure cellar. ***R~ released on 2-21-09 at 24:00 hrs*** YfInt80: :3/li2UUy 1:4Z:2U YM MPI-11 / L1 Well History Date Summary 03/03/09 MPU Well Support Techs SET BPV in I-11 after Slick line was completed. 03/08/09 MPU Well Support Tech «« PULLED THE BPV »» on I-11 for Coil to rig up. 03/10/09 CTU #5 w/1.75 coil Job Scope: Set Baker S-3 production packer & Install Jet pump 03/11/09 CTU #5 w/1.75 coil Job Scope: Set Baker S-3 production packer & Install Jet pump <> ...Cont from WSR 3/10/2009... Attempted to R/U mast would not raise due to segment pump going out. Had to swap the hydraulic pump. Considerable amount of down time involved (12 hrs NPT). Raised mast and continue rigging up 03/12/09 CTU #5 w/1.75" Coil ,Job Scope: Set Baker S-3 production packer & Install Jet pump . <> ...Continued from WSR 3/11/2009... RIH while circ hot XS 1 % KCL to heat expand tbg before setting packer, park coil ~ 10,000' &circ 580 bbls XS 1 %KCL Continue in hole and set down with Ball & Rod in RHC-M series plug body. Bring tubing pressure up to 3800 psi, set Baker Series 3 PKR and perform MIT-T for 30 min (Passed) Perform MIT-IA to 3500 psi and hold for 30 min (Passed) POOH and changed BHA configuration to pull RHC-M Series plug body C«~ 10232' CTM OOH w. RHC RIH w. 4 1/2" 6042 Shifting tool. SD and run into Dura sliding sleeve and open. Varified open by seeing response on IAP falling. Also pumped a few bbls from IA through SS to see response on WHP. RIH w. 4 1/2" jet pump, set Weatherford - 3" RC Jet Pump sn BP 1065 w/A10-B ratio: 10 nozzle,#11 throat in HES 3.813" XD profile C~ 10,118' 03/13/09 CTU #5 w/1.75" Coil, Job Scope -Set Jet Pump <> ...Continued from WSR 3/12/2009... RD CTU from MPI-11 Freeze protected well w/60/40 Meth, IA & Tbg. 03/17/09 The Well Support Techs rigged up and pressure tested teh flowlines to 1150 psi and the powerfluid line to 3600 psi. All test were good and the well is ready to POP. 03/29/09 ASRC Test Unit #5, 6 hour test 03/30/09 ASRC Test Unit #5, 6 hour test RDMO 04/12/09 ASRC Test Unit #5, MIRU MPI-Pad Test header, Page 1 of 1 "' STATE OF ALASKA 11/14/07 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: i}~ _rP~~~~~~1<.~,~i;~v ~o~a.an t;r. ¢u+~E;ori.Sa~; ~~:I~rska.guv ~~€7,fat_€t~rr~~33_~~?~~~_€~_~, cif ~r Contractor: Nabors Rig No.: 3S DATE: 2!16/2009 Rig Rep.: J.Greco / E. Potter Rig Phone: 659-4487 Rig Fax: 659-4486 Operator: BP Op. Phone: 659-4485 Op. Fax: 659-4628 Rep.: W. Hoffman/V. Volpe Field/Unit & Well No.: MPI-11 PTD # 201137 / 201138 ~~, Operation: Drlg: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly Test Pressure: Rams: 250/3500 Annular: 250/3500 Valves: 250/3500 TEST DATA MISC. INSPECTIONS: FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Re Location Gen.: P Well Sign P Upper Kelly 0 NA Housekeeping: P Drl. Rig P Lower Kelly 0 NA PTD On Location P Hazard Sec. P Ball Type 1 P Standing Order Posted P BOP STACK: Quantity Size Test Result Annular Preventer 1 13 5/8 5000 P Pipe Rams 1 2 7/8 X 5 P Lower Pipe Rams 0 NA Blind Rams 1 Blind/Shear P Choke Ln. Valves 1 3 1/8" 5000 P HCR Valves 2 3 1/8-2 1/16" P Kill Line Valves 1 2 1/16" 5000 P Check Valve 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P Test Results Inside BOP 1 P CHOKE MANIFOLD: Quantity Test Result No. Valves 13 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 3000 P Pressure After Closure 1700 P 200 psi Attained 27 sec P Full Pressure Attained 2 min P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 1900 Number of Failures: Test Time: 5 Hours Components tested ALL Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Supervises at: ~ir::.: eg ~:~l~tska... uv Remarks: Tested against 2 wav ck -test with 2 7/8" and 4 1/2" test its 24 HOUR NOTICE GIVEN YES X NO Date Time Test start 23:00 Finish Waived By Chuck Sheve Witness V. Volpe / E.Potter BOP Test (for rigs) w ~s BFL 11/14/07 D~~' ~Eg ,~ ~~~;~ Nabors 3s BOP Test MPI-11 2-16-2009.x1s • • ~~ .~ ~ _ d SARAH PALIN, GOVERNOR CO1~S~,1tQ~ A,1I01~ ~c I~H 333 W. 7th AVENUE, SUITE 100 •s-7 ~AA~~iiii ~il~~='~~~uuu~~'aaaiii-a ANCHORAGE, ALASKA 99501-3539 «-• PHONE (907) 279-1433 FAX (907) 276-7542 Ali Husain Well Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 APR ~ 9 200$ Re: Milne Point Unit, Schrader Bluff Oil Pool, MPI-11 Sundry Number: 308-117 O ~ . `3 Dear Mr. Husain: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing, A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. O~ ~ Chair DATED this ! day of April, 2008 Encl. ~ ~ -~ ~ ~~~Eiv ~ ~ ~~ATE OF ALASKA ~Q ALASKA OIL AND GAS CONSERVATION COMMISSION APR 0 APPLICATION FOR SUNDRY APPROV~4~L a C~(~ Gas Cons. CommC ' 20 AAC 25.280 SSIOn 1. Type of Request: Abandon Suspend Operational shutdown Perforate Q Othe ~ Alter casing ^ Repair well ^ Plug Perforations^ Stimulate ^ Time Extension ^ flowback - Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Developmenl0 Exploratory ^ 201-1370 - 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-23033-00-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: MPI-11 Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-025517 63.55 KB . Milne Point Unit Field / Schrader Bluff Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13170 3643.52 13170 3644 NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 72' 20" 92# H-40 Surface 101' Surface 101' Surface 2702' 10-3/4"45.5# L-80 Surface 2730' Surface 2730' 5210 2480 Production 10719' 7" 26# L-80 Surface 10748' Surface 3675' 7240 5410 Liner 2603' 4-1/2" 12.6# SL L-80 10567' 13170' 3647' 3644' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): OA Lateral SL 10406' - 12999' 3610' - 3643' - OB Lateral SL 10761' - 13125' 3695' - 3643' 2-7/8" 6.5# L-80 Surface - 10196' Packers and SSSV Type: BAKER ZXP LINER TOP PACKER Packers and SSSV MD (ft): 10567' 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/16/2008 OIL Q GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ali Husain Printed Name Ali Husain Title Well Engineer Signature Phone 564-4152 Date 4/2/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: .3~~f / / Plug Integrity ^ BO P Test ^ Mechanical Integrity Test ^ Location Clearance ^ (~ t Other: ~'~ ~G.C \~1 ~C MuS~ ~ tC ~S~ ~ r~Q ~ LO ~ v~ hSVJ ~~<+ rC 'SC,~~ Cc~ ~ V CJ . I ~ 'lvo~~ ~-~ ~hSQ~~~-or-, OQ~.r-alt-Zo~S a.~r~l~ociz~~ ~or ~~'\ c~ a~S Subsequent Form Required: ~~~ ~ ._; ;~ ~ HOC ,. _ APPROVED BY ~ n O S O `~ ~ Approved b MMI SI N Date: C I THE C ~~/ 4J ! ~ 1 if 1 l v 1 ~ ~.~. Form 10-4 3 Re ised 06/2006 Submit in >Dyu~plicLate ,.'i .J ~l 7. t33 • Proposed work on MPI-11 and MPI-12 4/2/08 History: MPI-11 and MPI-12 are both drilled as multi-lateral wells in the OA and OB zone Schrader Bluff formation. Both were completed with ESP in late 2001. The two wells came online with 1000 bopd but the rate dropped dramatically a few days later with suspect plugging in the ESP. Several attempts were done to rescue the ESP's with either RWO or coil tubing cleanouts but it was clear that was due to high viscous materials the ESP would get plugged and stop surfacing fluids and the two wells were declared LTSI for poor oil quality in early 2003. Proposal: There is a plan this year to re-evaluate the situation on both MPI-11 and MPI-12 and come up with a plan forward to bring them online. The two ESP's were checked if they are functioning electrically and the results showed that MPI-12 to have a functioning ESP and MPI-11 ESP was declared dead. Unfortunately all of the ESP surface equipment has been demobilized and removed. The good news is that the SBHP in the area is relatively high and close to virgin reservoir pressure (1800 psi). So we think we can free flow MPI-11 and MPI-12 (if we can't find a portable unit to start the ESP). . The reasoning behind a temporary flow to tanks is to capture some oil samples for API, SG and ~ composition analysis to help us choosing the new lifting mechanism for the wells. The job scope will be to rig up flow back tanks to the wells and try to flow MPI-12 with the ESP or free flow it if we can't start the ESP. The plan for MPI-11 is to attempt to free flow the well to a / tank. 4., ~, Tree: 2-9/16" - 5M FMC Wellhead: 11" 5M Gen 5 w/2-7/8" NSCT T&B Tubing Hanger with ''' CIW "H" BPV profile 20", 92 #/ft H-40 Welded 112' M ~'-~ ~ F elev. = 64.12' (Nabors 22-E) O L. elev.= 35.10' (Nabors 22E) Camco 2-7/8" x 1" 165` sidepocket KBMM GLM 10.75", 45.5#!ft BTC L-80 2730 2 7/8" 6.5 ppf, L-80, 8 rd, EUE production tubing (drift ID = 2.347", cap. = 0.00592 bpf ) 7" 26 ppf, L-80, Btc-mod production casing ( drift ID = 6.151", cap. = 0.0383 bpf ) KOP @ 300 ' Max wellbore Angle: 84° @ 4994' MD 60°+ past 2554' MD Hole angle trough perfs = 90°+ Baker Hook Wall Hanger above 7" Window 10336' Baker Hook Wall Hanger below 7" Window" 10345' Baker Down Swivel-up lock sub 10360' 6 1/8" Hole td @ 13190' Tandem Gas Separator 10163' GRSTXBARH6 (400 Internals) Intake 10163` MD = 3552' TVD Tandem Seal Section 10168` Model GSB3DB UT/LT H^PFS AFLAS/HSN Motor, 114 HP, 2330 volt, 10182` 30 amp, Model KMH Rerated to 138 hp KMH-J 2435 v/36amp PumpMate w/6 fin Centralizer 10196` Window in 7" Casing @ 6508` - 6520' Well Angle @ window = 76° Baker Tie Back Sleeve 7028` Baker ZXP Liner Top Packer 10567' Baker 7"x 5" HMC Liner Hanger 10582' 7" Halliburton Float Collar 10665' 7" Halliburton Ream Shoe 10747' DATE REV. BY COMMENTS Nabors 22E Drill Multilateral & 10/6/01 GMH ESP Completion 12/06/01 M. Linder RWO Nabor 4-ES 6 118" Hole td @ 13170' 61 jts - 4 1/2", 12.6#lft. Slotted Liner 12.6# L-80 IBT (10761`-13125') Bttm. Baker 4 112" Packoff Bushing 13125' Bttm. Baker 4 1/2" Guide Shoe 13170' MILNE POINT UNIT WELL I-1'I API NO: 50-029-23033 API NO: 50-029-23033-60 L1 BP EXPLORATION (AKA OA Lateral Camco 2-7/8" x 1° 2533' sidepocket KBMM GLM Tandem Pump, 81/27/16 Stg. GC1700/2200/GCNPSH 10138` Model - GPMTAR 1:1 66 jts. - 4 1 /2" Slotted Liner 12.6# L-80 IBT (10406' - 12999') Bttm. 4 1/2" Packoff Bushing 13 Bttm. 4 1/2" Guide Shoe 13124' OB Lateral e e .\"-' ........"..... i;r>....' .,' .- ... :-' MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc t ~ t.}\1 ~6 tj) DATA SUBMITTAL COMPLIANCE REPORT 10/22/2003 Permit to Drill 2011370 Well Name/No. MILNE PT UNIT 58 1-11 Operator 8P EXPLORATION (ALASKA) INC 5pGul ß ~ ~, API No. 50-029-23033-00-00 MD 13170 ---- NO 3644 .r Completion Date 10/6/2001 / Completion Status 1-01L Current Status 1-01L UIC N ---- - - REQUIRED INFORMATION Mud Log No Samples No Directional Survey We- Y JJJ . ----- --- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) ------ - , Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments 1 160 13116 Open 2/20/2002 1 108 13170 Open 5/9/2002 ----- --- Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? ~ Y f N- Formation Tops WN (]yN Daily History Received? -~-- Analysis Received? ~ Comments: Compliance Reviewed By: ~ Date: '04fT) . \ 1\ -~ ' =--ccc- - ! {~/ ~ J \ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 March 15, 2002 RE: MWD Fonnation Evaluation Logs - MPI-ll & MPI-ll Ll, AK-MM-11151 MPI-ll: aOJ~/.3-," J a ~K3-3.. ,; Digital Log Images: ()9~dÎ-O 1 1 CD Rom J o~- /3110 50-029-23033-00 ~5ù MPI-ll Ll: c@D/-J3 ~ J D ð3L} Digital Log Images: 1 CD Rom la-Oj-OJ 50-029-23033-60 lo~"J5/'10 103 D PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE A TT ACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 signe~ ~ Date: RECEIVED MfiY 0 9 20Ðl :;¡aska Oil & Gas Cons. Commission ~ochorage • • Maunder, Thomas E (DOA) From: Jack Hartz [jack hartz@admin.state.ak.usj Sent: Wednesday, Aprif 03, 2002 5:49 PM To: Mathews, William L Cc: Thomas E Maunder Subject: Milne Pt. I-11, I-12 and E-30A -annular water circulation ao~-~3`~ ~---~ Attachments: jack hartz.vcf ~ a~ 1- p t ~ 301-\c~3 jack hartr.vtf (2 KB) Bill, I reviewed the proposal regarding circulation of water through the annuli of wells at MPU and found it to be a reasonable approach to handle the problems that were outlined. The type of completion employed in these wells did not require a packer, so there were no regulatory issues that required a permit. We agree with your proposal to circulate water to improve pump efficiency. It looks like a novel approach to an unexpected problem. Let us know if you have any questions. Jack Hartz ~~~~~~ NQ1/ ~ ~0~7 "Mathews, William L" wrote: > Morning Jack, > I don't have any velocity concerns with what we are proposing. At 750 > bwpd in the 7" x 2-7/8" annulus we are moving water at 17.25 ft/min. > Compare this to some of our current jet pump applications where we are > moving up to 2000 bwpd down a 7" x 3-112" annulus (well MPJ-23). This ft/min. > Flow rates at S-pad will be even higher as we plan to use up to 4000 > bwpd down a 7-5/8" x 4-1/2" annulus giving us 106 ft/min. > Bill > -----Original Message----- > From; Jack Hartz [mailto:jack hartz@admin.state.ak.us) > Sent: Tuesday, April 02, 2002 8:43 AM > To: Mathews, Bill > Subject: [Fwd: [Fwd: Milne Pt. We11 I-12]] > Bill, > I left a message on your machine earlier this a.m., regarding the > proposal to circulate water thru the well annuli. My only question is > are there any velocity issues or concern about erosion? The rates you > suggest appear nominal. I don't think there are any other questions > from here. > Thanks, > Jack Hartz > 793-1232 ~~~~~ ,~~,~~ 1 ~~\: ~`~ equates to 52.5 • • Maunder, Thomas E (DOA) From: Jack Hariz [jack harfz@admin.state.ak.us] Sent: Tuesday, April 02, 2002 11:08 AM To: Daniel T Seamount JR; Camille Taylor Cc: Thomas E Maunder Subject: Adjudication Meeting 4/2/2002 -MPU I-11, I-12 and E-30A Attachments: jack hartz.vcf jack hartr.vcf (2 KB) Subject: Milne Pt. Unit - Schrader Bluff - Water circulation down annuli of wells to provide heat and volume to pumped fluids. BPX has requested approval to circulate water down the annulus of 3 MPU Schrader Bluff wells. The purpose of the water circulation is to heat wellbore produced fluids and increase the efficiency of the ESPs installed in these wells. Lower API gravity in this area has caused lower rate compounded by higher viscosity making the pumps oversized for the rates being produced. No heat trace was installed initially because they anticipated higher gravity and higher rates (warmer production conditions). The circulating water substitutes as a different type of heat trace. Circulating water down the annulus will increase the pump efficiency by heating the fluids and adding volume to the pump. The Schrader Bluff wells will not flow on their own and have been completed without packers to allow more efficient separation of the gas from the well stream. There are no mechanical, velocity, erosion or reservoir issues to inhibit their doing this procedure. Recommendation: I recommend we acknowledge their proposal and indicate our agreement. In my opinion, they don't need approval to conduct this operation. Let me know if there are any questions, etc. Jack (Following is a copy of the Emails from BPX on the subject. I'll bring the mechanical diagrams to the meeting.) -jdh »»»»»»»»»»»»»»»»»»»»»»»»» »»»» »»»»» Subject: RE: [Fwd: [Fwd: Milne Pt. Well I-12]] Date: Tue, 2 Apr 2002 12:07:50 -0600 From: "Mathews, William L" <MathewWL@BP.com> To: "'Jack Hartz"' <jack hartz@admin.state.ak.us> Morning Jack, I don't have any velocity concerns with what we are proposing. At 750 bwpd in the 7" x 2-7/8" annulus we are moving water at 17.25 ft/min. Compare this to some of our current jet pump applications where we are moving up to 2000 bwpd down a 7" x 3-1/2" annulus (well 1 MPJ-23). This equates to 52.5 ft/min. Flow rates at S-pad will be even higher 4-1/2" annulus giving us 106 ftlmin. Bill as we plan to use up to 4000 bwpd down a 7-5/8" x -----Original Message----- From: Jack Hartz [mailto:jack hartz@admin.state.ak.us] Sent: Tuesday, April 02, 2002 8:43 AM To: Mathews, Bill Subject: [Fwd: [Fwd: Milne Pt. Well I-12J] Bill, I left a message on your machine earlier this a.m., regarding the proposal to circulate water thru the well annuli. My only question is: are there any velocity issues or concern about erosion? The rates you suggest appear nominal. I don't think there are any other questions from here. Thanks, Jack Hartz 793-1232 »»»»»»»»»»»»»»»»»»»»»» »»» »» » »» »»»» Subject: [Fwd: Milne Pt. Well I-12] Date: Fri, 22 Mar 2002 16:10:47 -0900 From: Tom Maunder <tom maunder@admin.state.ak.us> To: John D Hartz <jack hartz@admin.state.ak.us> Jack, FYI. I think this is a good idea. Water should be less problematic than heat trace. What do you think? Tom Subject: Milne Pt. Well I-12 Date: Fri, 22 Mar 2002 13:45:38 -0600 From: "Mathews, William L" <MathewWL@BP.com> To: "'tom maunder@admin.state.ak.us "' <tom maunder@admin.state.ak.us> Tom, Milne Pt. well I-12 was drilled and completed in December of 2001 as a multi-lateral producer in the Schrader Bluff OA and OB sands. The well was expected to come on line at >1500 bopd, but due to poorer than anticipated oil quality (17 deg API/200+cp versus an expected 21 deg API/22 cp), has failed to produce up to expectation. Initial rates were around 800 bopd and quickly fell off to less than 300 bopd. Since the well completion was designed around the higher rates, heat trace was not installed in the well. As rates fell, wellbore fluids cooled off; making it difficult to keep the well on production. The well would have eventually died due to the high viscosity and cooler temperture of the crude. To prevent this, a temporary water line was installed to allow operations to slip stream 500-1000 bwpd down the annulus in an effort to warm up the well and improve the ESP efficiency. This was successful, allowing the well to stay on production at -350 bopd. The well was shut in pending an acid stimulation and appraisal for a more permanent water installation. A foam divert acid stimulation was performed in 2 early March. The well came back on line and has so far bee able to sustain an oil rate of 500-700 bopd with a water slip stream of 750 bwpd. BP is requesting approval to permanently tie-in this well to the injection water header to allow us to continue to slip-stream water down the annulus at 500-1000 bwpd. A more permanent installation will provide a cost effective way to keep this well on line. In addition to well I-12, there are two more wells that may benefit from a similar installation. These are well I-11 (recently drilled well adjacent to I-12 and now shut in) and well E-30A which was drilled last year along the northern periphery of the Schrader Bluff field. BP is requesting approval to permanently tie these wells in should it be necessary to maintain their ability to produce at economical rates. I've attached wellbore schematics and a production plot for MPI-12 for your consideration. Please give me a call if you would like to discuss this in more detail or have any questions. Bill Mathews Schrader Bluff Completion Engineer 564-5476 440-8496 cell «MPI-12 Schematic.ZIP» «MPI-11 Schematic.ZIP» «MPE-30A Schematic.pdf» «MPI-12 Well Tests.doc» 3 ,/ STATE OF ALASKA t ALASK~ VI L AND GAS CONSERVATION COMMI.::>"ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: 0 Operation Shutdown 0 Stimulate II Pull Tubing 0 Alter Casing 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 0 Plugging 0 Perforate II Repair Well II Other 5. Type of well: 181 Development 0 Exploratory 0 Stratigraphic 0 Service Change Out ESP 6. Datum Elevation (OF or KB) KBE = 63.55' 7. Unit or Property Name Milne Point Unit 4. Location of well at surface 2343' NSL, 3966' WEL, SEC. 33, T13N, R10E, UM At top of productive interval 914' NSL, 3022' EWL, SEC. 31, T13N, R10E, UM At effective depth 637' NSL, 577' EWL, SEC. 31, T13N, R10E, UM At total depth 637' NSL, 577' EWL, SEC. 31, T13N, R10E, UM 12. Present well condition summary Total depth: measured 8. Well Number MPI-11 9. Permit Number / Approval No. 201-137 10. API Number 50- 029-23033-00 11. Field and Pool Milne Point Unit / Schrader Bluff true vertical 13170 feet 3644 feet 13170 feet 3644 feet Plugs (measured) true vertical Effective depth: measured Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD 72' 2702' 20" 10-3/4" 260 sx Arcitcset (Approx.) 600 sx PF 'L', 440 sx Class 'G' 101' 2730' 101' 2730' 107191 2603' 7" 1400 sx Class 'G' Uncementd Slotted Liner 10748' 10567' - 13170' 3675' 3647' - 36441 4-1/2 Perforation depth: measured Slotted Liner: 10761' - 13125' R CEIVED true vertical Slotted Liner: 3695' - 3643' Tubing (size, grade, and measured depth) 2-7/8",6.5#, L-80 tubing to 10196'. J.~N 2 3 2002 Alaska Oil & Gas Cons C '. Anchorag~ ommlsSlon Packers and SSSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data œ~~ ~~d w~~~ Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 0 Copies of Logs and Surveys run 181 Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge - .-----~ SiQned ~Stew~ -!,9/r-T :\. O\A Title Technical Assistant 16. Status of well classifications as: 181 Oil 0 Gas 0 Suspended Service Form 1 0-404 Rev. 06/15/88 Date 0 l ~ '2 '2 - 02 ~ Prepared By Name/Number: Sondra Stewman, 564-4750 .. tiJ""\~ L~~, ~ II,~':.:,' ~ r\).I,~ ð\ ~ Submit In Duplicate , ~'ì\~~.,,)~~~#\L I BP AMOCO Page 1 of 3 Operations Summary Report Legal Well Name: MPI-11 Common Well Name: MPI-11 Spud Date: 9/8/2001 Event Name: WORKOVER Start: 11/30/2001 End: 12/6/2001 Contractor Name: NABORS Rig Release: 12/6/2001 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/30/2001 12:00 -18:00 6.00 REST P DECOMP CREWS BEGIN ARRIVED TO LOCATION FROM ANCHORAGE (CHARTER DELAYED DUE TO MECHANICAL PROBLEMS). HOLD PRE START-UP AND RIG MOVE SAFETY MEETING. 18:00 - 21:00 3.00 REST P DECOMP RIG DOWN FROM WARM-STACK LOCATION ON H PAD AND MOVE RIG TO LOCATION AT MPI-11. 21 :00 - 00:00 3.00 REST P DECOMP SPOT AND BERM RIG AND EQUIPMENT. RAISE AND SCOPE DERRICK. RU LINES. ACCEPT RIG AT 00:00 HRS. 12/1/2001 00:00 - 01 :00 1.00 REST P DECOMP FINISH RU REMAINING LINES TO NEW KILL TANK. 01 :00 - 02:00 1.00 REST P DECOMP RU LUBRICATOR AND PULL BPV. LD LUBRICATOR. 02:00 - 04:00 2.00 REST P DECOMP RU HCR VALVE TO ANN AND LINES TO TREE. TEST TO 2,500 PSI GOOD. 04:00 - 06:00 2.00 REST P DECOMP TAKE ON HOT SEA WATER IN PITS. PREP RIG FLOOR. 06:00 - 07:00 1.00 REST P DECOMP HOLD PRE-JOB OPERATIONS AND SAFETY MEETING. 07:00 - 09:30 2.50 REST P DECOMP CIRCULATED WELL WITH 120 DEG SEA WATER. 09:30 - 10:00 0.50 REST P DECOMP MONITOR WELL. TBG = 80 PSI. ANN = 40 PSI. 10:00 - 13:00 3.00 REST P DECOMP WEIGHT UP TO 8.7 #/GAL. CIRCULATE WELL. 13:00 - 13:30 0.50 REST P DECOMP MONITOR WELL. WELL ON SLIGHT VAC. 13:30 - 14:30 1.00 REST P DECOMP INSTALL AND TEST TWC 14:30 - 15:30 1.00 REST P DECOMP REMOVE X-MASS TREE. 15:30 - 18:00 2.50 REST P DECOMP INSTALL ADAPTOR SPOOL AND BOPE. PREPARE FOR BOPE TEST. 18:00 - 21:30 3.50 REST P DECOMP PERFORM BOPE TEST ACCORDING TO AOGCC AND BP REQUIREMENTS. TEST WITNESSED BY STATE REP...J. JONES. 21 :30 - 22:30 1.00 REST P DECOMP RU LUBRICATOR AND PULL TWC. LD LUBRICATOR. 22:30 - 00:00 1.50 REST P DECOMP RU FLOOR FOR 2 7/8" TBG. MU LANDING JT. BOLDS. PULL HANGER TO FLOOR (60k). LD HANGER AND LANDING JT. 12/2/2001 00:00 - 02:00 2.00 PULL P DECOMP START POOH W/2 7/8" TBG AND ESP ASSY. 02:00 - 02:30 0.50 PULL P DECOMP STOP TO CHANGE ESP CABLE SPOOL. 02:30 - 06:00 3.50 PULL P DECOMP CONTINUE TO POOH WITBG AND ESP ASSY. CREW CHANGE. 06:00 - 07:00 1.00 PULL P DECOMP FINISH OUT OF HOLE WITBG. ESP ASSY TO SURFACE. 07:00 - 09:30 2.50 PULL P DECOMP INSPECT AND LD ESP ASSY. 09:30 - 10:00 0.50 CLEAN P DECOMP RU FLOOR TO PU 2 7/8" PAC DP. INSTAL WEAR RING. 10:00 -13:30 3.50 CLEAN P DECOMP MU 31/2". PU 90 JTS 27/8" PAC DP. TALLY AND DRIFT. 13:30 - 14:30 1.00 CLEAN P DECOMP RU FLOOR TO PU 3 1/2" DP. FINISH LOADING PIPE SHED WITH DP. 14:30 - 18:00 3.50 CLEAN P DECOMP START PICKING UP 31/2" DP. TALLY AND DRIFT. CREW CHANGE. 18:00 - 22:00 4.00 CLEAN P DECOMP CONTINUE RIH W/31/2" DP TO 10,300-FT. RECORD PUW = 85K AND SOW = 20K. 22:00 - 00:00 2.00 CLEAN P DECOMP TAGGED AT 10,350-FT. ATTEMPT TO REV CIR...NO~GO. ATTEMPT TO PUMP DOWN DP...PLUGGED. WORKED FREE. REV CIRC DOWN TO 10,413-FT WITH A FLUID LOSS OF 1.8 BPM. CBU...SAW NO SOLIDS. CONTINUE RIH WITH DP. 12/3/2001 00:00 - 04:30 4.50 CLEAN P DECOMP CONTINUE RIH WITH 3 1/2" DP. BREAK CIRCULATIONS EVERY 20 JTS. SAW NO FILL. TAG BTM @ 13,075-FT. 04:30 - 06:00 1.50 CLEAN P DECOMP REV CIRC. 3 BPM/250 PSI. FLUID LOSS 1 BPM. CREW CHANGE. 06:00 - 09:00 3.00 CLEAN P DECOMP CONT W/REV CIRC UNTIL CLEAN. MONITOR WELL (' .( ( Printed: 12/10/2001 11:18:17 AM BP AMOCO Page 2 of 3 Operations Summary Report Legal Well Name: MPI-11 Common Well Name: MPI-11 Spud Date: 9/8/2001 Event Name: WORKOVER Start: 11/30/2001 End: 12/6/2001 Contractor Name: NABORS Rig Release: 12/6/2001 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 12/3/2001 09:00 - 11 :00 2.00 CLEAN P DECOMP START POOH TO 10,350-FT. STOP TO CIRCULATE AND RECIP PIPE TO CLEAN DIVERTER TOOL AREA. 11 :00 - 14:00 3.00 CLEAN P DECOMP FINISH POOH WITH REMAINING 3 1/2" DP. 14:00 - 16:00 2.00 CLEAN P DECOMP CHANGE OVER TO 2 7/8" HANDLING EQUIPMENT. POOH WITH 2 7/8" PAC TBG AND 31/2" MILL. 16:00 -17:00 1.00 CLEAN P DECOMP MU BAKER LATERAL DIVERTER TOOL AND GS RUNNING TOOL. CHANGE OVER TO 31/2" HANDLING TOOLS. CLEAR FLOOR 17:00 - 18:00 1.00 CLEAN P DECOMP START TIH WITH 3 1/2" DP. CREW CHANGE. 18:00 - 21:00 3.00 CLEAN P DECOMP FINISH TIH WITH 3 1/2" DP. 21 :00 - 22:00 1.00 CLEAN P DECOMP TAG AND SET LATERAL DIVERTER IN BAKER HOOK HANGER AT 10,366-FT. 22:00 - 23:00 1.00 CLEAN P DECOMP CUT AND SLIP DRILL LINE. 23:00 - 00:00 1.00 CLEAN P DECOMP START TOOH WITH 3 1/2" DP. 12/4/2001 00:00 - 02:30 2.50 CLEAN P DECOMP FINISH TIH W/3 1/2" DP. LD GS RUNNING TOOL. 02:30 - 03:30 1.00 CLEAN P DECOMP CLEAN AND CLEAR RIG FLOOR CO TO FOR 2 7/8" PAC. 03:30 - 06:00 2.50 CLEAN P DECOMP MU 3 1/2" MILL. TIH W/2 7/8" PAC. CO TO 31/2" AND START TIH W/3 1/2" DP. CREW CHANGE. 06:00 - 06:30 0.50 CLEAN P DECOMP LUB RIG. 06:30 - 08:30 2.00 CLEAN P DECOMP TIH W/31/2" DP TO LATERAL DIVERTER AT 10,336-FT. 08:30 - 10:00 1.50 CLEAN P DECOMP WORK THROUGH DIVERTER CIRCULATE AND WARM UP HOLE. 10:00 - 11 :30 1.50 CLEAN P DECOMP CONTINUE TIH TO 12,980-FT. FOUND NO FILL. 11 :30 - 13:30 2.00 CLEAN P DECOMP REV CIRC CLEAN AT 3 BPM/250 PSI. SD PUMP AND MONITOR. 13:30 - 17:00 3.50 CLEAN P DECOMP TOOH W/3 1/2" DP. 17:00 - 18:00 1.00 CLEAN P DECOMP CHANGE OVER TO 2 7/8" PAC. START LD 2 7/8" PAC. CREW CHANGE. 18:00 - 20:30 2.50 CLEAN P DECOMP FINISH LD PAC AND 3 1/2" MILL. 20:30 - 21 :00 0.50 CLEAN P DECOMP CLEAR FLOOR AND CHANGE OVER FOR 3 1/2" DP. 21 :00 - 00:00 3.00 CLEAN P DECOMP MU GS PULLING TOOL AND TIH W 31/2" DP. 12/5/2001 00:00 - 00:30 0.50 CLEAN P DECOMP SET DOWN ON LATERAL DIVERTERAND LATCH IN WITH GS PULLING TOOL. 00:30 - 06:00 5.50 CLEAN P DECOMP RELEASE LATERAL DIVERTER START TOH LAYING DOWN 31/2" DP. 06:00 - 08:00 2.00 CLEAN P DECOMP FINISH TOH WITH 3 1/2" DP. LAY DOWN LATERAL DIVERTER AND GS PULLING TOO. 08:00 - 09:00 1.00 RUNCO~ IP COMP CLEAR FLOOR AND PREP TO PU ESP ASSY. 09:00 - 14:00 5.00 RUNCO~ IP COMP PU AND SERVICE ESP ASSY. TEST SAME. 14:00 - 18:00 4.00 RUNCO~ IP COMP START RIH W/ESP ASSY AND 2 7/8" TBG. FLUSH PUMP AT 1 BPM EVERY 18 STDS. CREW CHANGE. 18:00 - 20:00 2.00 RUNCO~ IP COMP CONTINUE TIH W/ 2 7/8" TBG AND ESP ASSY. 20:00 - 23:00 3.00 RUNCO~ IP COMP STOP TO SPLICE CABLE AND TEST. 23:00 - 00:00 1.00 RUNCO~ IP COMP CONTINUE TIH W2 7/8" TBG AND ESP ASSY. 12/6/2001 00:00 - 03:00 3.00 RUNCO~ IP COMP MU HANGER & INSTALL PENETRATORS & ATTACH FIELD CONNECTORS & TEST SAME & LAND HANGER & RILDS. 03:00 - 03:30 0.50 BOPSUF P COMP SET TWC & TEST TO 3000 PSI. 03:30 - 05:00 1.50 BOPSUR P COMP NIPPLE DN BOP 05:00 - 07:00 2.00 WHSUR P COMP NIPPLE UP TREE & TEST TREE & HANGER SEALS TO 5000 PSI. & MAKE FINAL CHECK ON ESP CABLE. 07:00 - 08:00 1.00 WHSUR P COMP MU LUBRICATOR & PULL TWC & SET BPV. 08:00 - 10:00 2.00 CHEM P COMP RU HB& R AND FREEZE PROTECT WELL WITH 15-BBL. DIESEL DN TBG. & 80 -BBL. DEAD CRUDE DN ANNULUS ( (" Printed: 12/10/2001 11:18:17 AM . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ( (' BP AMOCO Operations Summary Report MPI-11 MPI-11 WORKOVER NABORS NABORS 4ES Start: 11/30/2001 Rig Release: 12/6/2001 Rig Number: 12/6/2001 08:00 - 10:00 From - To Hours Activity Code NPT Phase caMP AND SECURE TREE & RELEASE RIT @ 1000 HRS. 12-06-01 Description of Operations 2.00 CHEM P Page 3 of 3 Spud Date: 9/8/2001 End: 12/6/2001 Printed: 12/10/2001 11:18:17 AM \ ( ,'~,:.,1':\"~_,),,, ø.. 7 ,:-~",~,I"¡"", " ""'\':",',""'\1,' ~"i',I.I~I" ",',,'~""'i-I,,"I\ ,"',', , " "',:" """, , '",~:i;;:~,,\¡¡¡"i:.ì;a"':;'~:;:":'!'ii:i:,""ê'I', , ' ' WELL LOG TRANSMTIT AL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 i\nchorage,Alaska 99501 February 7, 2002 RE: MWD Foffi1ation Evaluation Logs 1\1PI-ll, AK-MM-11151 1 LIS fonnatted Disc with verification listing. API#: 50-029-23033-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. i\nchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 ~ÇE'VED FE8 2 0 2002 Alaska Oil & Gas f'..- f'-. , An. "'VII.'.lIOn Sign~ (, OQ.o p.... 1 ( STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSJON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well 181 Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-137 3. Address 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-23033-00 -, -U 4. Location of well at surface . ,. -., . 9. Unit or Lease Name 2343' NSL, 3966'.W~L, SEC. 33, T13N, R10E, UM; ,~t. >6- ('" ."""""_~: ~ Milne Point Unit I ~. -' At top of productive Interval : .../-6. - '_H_. - i~Æ. )~, 914' NSL, 3022' EWL, SEC. 31, T13N, R10E, UM ! '¡<i';;'.':",'~" .a.H..p~. 10. Well Number At total depth; ,-,~-Æ.... ,.-:. . -~'-;>" ',"", \ MPI-11 637' NSL, 577' EWL, SEC. 31, T13N, R10E, UM""'---'- "'-""0."".' ""."O ~,..",...,... ,c...,'. 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Milne Point Unit 1 Schrader Bluff KBE = 63.55' ADL 025517 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 15. Water depth, if offshore 16. No. of Completions 9-08-2001 9-23~2001 1 0~6-2001 NIA MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 13170 3644 FT 13170 3644 FT 181 Yes ONo NIA MD 1800' (Approx.) 22. Type Electric or Other Logs Run DIR, GR, PWD, RES, ABI, ABGR 23. CASING LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 29' 101' 3011 '60 sx Arctic Set (ADDrox.) 10-3/4" 45.5# L-80 28' 2730' 13-1/211 600 sx PF 'L' 440 sx Class 'G' 7" 26# L-80 29' 10748' 9-7/8" 1400 sx Class 'G' 4-1/2" 12.6# L-80 10567' 13170' 6-1/8" Uncemented Slotted Liner 24. Perforations open to Production (MD+ TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Section 2-718", 6.5#, L-80 10213' N/A MD TVD MD TVD 10761' - 13125' 3695' - 3643' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2500' Freeze Protected with 85 bbls of Diesel. 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) October 17, 2001 Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO 10/16/2001 6 TEST PERIOD 1178 87 12 74 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-API (CORR) Pres:s~ 24-HoUR RATE 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or waterr~,U"bTt';qr:~' ~~iPS:~"':-,;::: c._"..,."., .,'"""~ U""""",.~"",, ~, r (~, II ,1 1 Ii,! 2 r; (1'1 ! c Ul \f ..¿ ';,: - ,,' .'" þ~~'r':'-"O¡¡")I",...",A, c,'," ',i.....~,"",,: ; ,,, l~: L :.~, '. -.oœ5, v[ir;¡,TI:SS!Cfi A,~ ~c;¡ ¡ut;U;L,e ,; Form 10-407 Rev. 07-01-80 0 R ! GIN A L (2ßf)7115 ð/L Submit In Duplicate (J) ~ ( 29. Geologic Markers Measured True Vertical Depth Depth 10034' 3520' 10235' 3570' 10388' 3605' 1 0529' 3639' 10706' 3671' 13170' 3644' Marker Name Schrader NE Schrader NF Top of Schrader OA Base OwrSBC Top of Schrader 08 Base OB/SBA5 31. List of Attachments: f 30. Formation Tests Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 'c " -, " ":".e' ,,1' ~, :" I ,',el' ,; [,~::""r "';, /,~ ?f¡jf'I"¡ " ""-,, ¡) .:'- ,,',. c., ~-" d ') ,. , ,-" r. I"" "":'""~'¡C!n'1 (,~"w~",;,r)¡,I, ("I ,\ ::':'.i'"j:I"-;.../J,\U\h~"::;;' ,~, ,'"", ..,'."V' \., ,II .', "' . ,.'-:,:~,I? Summary of Daily Drilling Reports, Surveys, Leak off Test Summary 32. I hereby certify that the foregoing is true and cor ect to the best of my knowledge Signed Terrie Hubble Title Technical Assistant Date Il- /flrO MPI-11 Well Number 201-137 Permit No. / A roval No. INSTRUCTIONS Prepared By Name/Number: Sandra Stewman, 564-4750 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 (OF, 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 28: If no cores taken, indicate 'none', ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. Form 10-407 Rev. 07-01-80 OR'1GtN' ^ l. , " ":,' ,! ¡,~~, ' , \' ~,I', "I \. ' .~ Legal Name: MPI-11 Common Name: MPI-11 9/12/2001 9/22/2001 9/26/2001 2,729.0 (ft) 10,748.0 (ft) 10,345.0 (ft) 2,282.0 (ft) 3,675.0 (ft) 3,602.0 (ft) 9.30 (ppg) 9.60 (ppg) 9.30 (ppg) FIT FIT FIT Surface Pressure (psi) 280 (psi) 450 (psi) Leak Off Pressure (8HP) 1,1 02 (psi) 2,113 (psi) 2,190 (psi) Page 1 of 1 .- EMW 9.30 (ppg) 11.07 (ppg) 11.70 (ppg) --~ --=~c Printed: 10/8/2001 1 :35:52 PM (' ( BP AMOCO ,;. Page 1 of 13 Operations Summary Report Legal Well Name: MPI-11 Common Well Name: MPI-11 Spud Date: 9/8/2001 Event Name: DRILL +COMPLETE Start: 917/2001 End: 10/5/2001 Contractor Name: NABORS Rig Release: 10/6/2001 Rig Name: NABORS 22E Rig Number: Date' From -:To Hours Activity Code NPT Phåse , Descri ptionof Operations 917/2001 20:00 - 22:00 2.00 BOPSUF P SURF Install 20" Riser On Annular - Install Flow Line - Hook Up Turnbuckles On 21 1/4" Annular And Center, Install Hole Fill Line, And Bleed Off Line - Pick Up Cellar Area- 22:00 - 00:00 2.00 BOPSUF P SURF Function Test 21 1/4" Diverter System - Perform Accumulator Test - Check LEL & H2S Gas Detection System . NOTE. All Tests Were Witnessed By AOGCC Representive Jeff Jones 9/8/2001 00:00 - 05:00 5.00 BOPSUF P SURF Hold Pre-Job Safety Meeting With Crew Coming On Tour- Pressure Test Mud Line Swivel Packing And Top Drive IBOP Valves Back To Mud Pumps At 3,800 Psi. For 10 Minutes While Recording On Circle Chart - Fill 20" Riser And Circulate Water Back To Mud Pits & Check For Leaks - Pick Up Mousehole - Bring Cross Over Subs And Safety Valves To Rig Floor. 05:00 - 13:00 8.00 BOPSUF P SURF Pick Up And Make Up In Mouse Hole 145 Joints Of 5" Drill Pipe And 14 Joints Of 5" HWDP With Jars And Stand Back In Mast. 13:00 - 14:00 1.00 BOPSUF P SURF Hold Pre-Spud Meeting With All Personal 14:00 -15:00 1.00 BOPSUF P SURF Pick Up And Make Up BHA With Sperry Sun Directional Driller 15:00 - 16:30 1.50 DRILL P SURF Spud Well MPI-11 At 15:00 Hours With Bit No.1 - Clean Out 20" Conductor Pipe - Drill Ahead From 101' To 222' - Circulate To Clean Hole. 16:30 -17:00 0.50 DRILL P SURF POH To Pick Up Sperry Sun MWD & BHA Equipment 17:00 -18:00 1.00 DRILL P SURF Pick Up BHA No.1 ~ Change Bend On Mud Motor To 1.5 AKO - Pick Up MWD Tool, Hang Off Sub, UBHO And Orient To Motor. 18:00 -18:30 0.50 DRILL P SURF Initalize And Load Spery Sun MWD Tool 18:30 -19:00 0.50 DRILL P SURF Pick Up Flex Collars 19:00 - 20:30 1.50 DRILL P SURF Surface Test MWD Tool - Rig Up And Run Gryo - Rig Down Gryo Equipment 20:30 - 00:00 3.50 DRILL P SURF Directional Drill Ahead From 222' To 540' - Weight On Bit 25K To 30K With Pump Rate At 120 Strokes Or 500 GPM - Off Bottom Pump Pressure At 1000 Psi. & On Bottom Pump Pressure At 1150 Psi. Top Drive RPM At 60 Off Bottom Torque At 1 K & On Bottom Torque At 3K String Rotating Weight At 1 OOK - With Pump On Drag Up At 1 OOK And Drag Down At 100K. 9/9/2001 00:00 - 23:30 23.50 DRILL P SURF Directional Drill Ahead From 540' To 2,743' Surface Casing TD - Weight On Bit 25K To 30K With Pump Rate At 125 Strokes Or 526 GPM - Off Bottom Pump Pressure At 1200 Psi. & On Bottom Pump Pressure At 1350 Psi. Top Drive RPM At 80 Off Bottom Torque At 6K & On Bottom Torque At 10K String Rotating Weight At 125K ~ With Pump On Drag Up At 135K And Drag Down At 120K. 23:30 - 00:00 0.50 DRILL P SURF Circulate And Condition Mud While Pumping Hi-Vis Sweeps 9/10/2001 00:00 - 01 :00 1.00 DRILL P SURF Continue With Mud Maintenance As Directed By Baroid While Pumping Hi-Vis Sweeps. 01 :00 - 03:00 2.00 DRILL P SURF Hold Pre-Job Safety Meeting - Monitor Well Bore (Static) - POH (SLM & Wet) Short Trip - Work Hole Section At 1,910' And 1,726' Continue On With Short Trip To Top Of HWDP At 723' 03:00 - 05:00 2.00 DRILL P SURF Monitor Well Bore (Static) - Clean Rig Floor - RIH To 1,475' Printed: 10/812001 1:16:10 PM (' (' . ,f, BP AMOCO -,' Page 2 of 13 Operations 'Sumrnary;"R~port ,. Legal Well Name: MPI-11 Common Well Name: MPI-11 Spud Date: 9/8/2001 Event Name: DRILL +COMPLETE Start: 917/2001 End: 10/5/2001 Contractor Name: NABORS Rig Release: 10/6/2001 Rig Name: NABORS 22E Rig Number: Date FrQm - To Holjrs Activity COde NPT Phase Description of Operations .' - 9/10/2001 03:00 - 05:00 2.00 DRILL P SURF Work Thru Tight Hole Section To 1,850' - Continue To RIH To 131/2" TD At 2,743' 05:00 - 06:00 1.00 DRILL P SURF Circulate And Clean Up Hole Pumping Hi-Vis Sweeps While Rotating And Reciprocating Drill String - *NOTE* Pump Rate Increased To 600 GPM And Standing Back 5" Drill Pipe To Keep Hole In Gauge During Circulation Process. 06:00 - 08:00 2.00 DRILL P SURF Monitor Well Bore (Static) - POH 3 Stands Check For Swabing - Pump Dry Job And POH (No Problems And Good Fill) 08:00 - 11 :00 3.00 DRILL P SURF Lay Down BHA And Clear Rig Floor 11:00 -13:00 2.00 CASE P SURF Hold Pre Job Safety Meeting - Rig Up Franks Fill Up Tool - Casing Tools And Equipment. 13:00 -13:30 0.50 CASE P SURF Hold Pre-Job Meeting With All Personal Reguarding Up Coming 10 3/4" Surface Casing Plan And Operation. 13:30 -17:30 4.00 CASE P SURF Pick Up Shoe Track And Install Centrilizers Per Well Plan - Pump Thru Shoe Track And Verify Floats Operational - Continue To Pick Up A Total Of 65 Joints Of 10 3/4" L-80 45.5 lb. BTC Casing Per Procedure And RIH - Work Thru Tight Spot From 1,670' To 1,700' - Continue Picking Up Casing Wash Last Two Joints To Bottom From 2,614' To 2,729' 17:30 -19:30 2.00 CASE P SURF Circulate With Franks Fill Up Tool At 7 BPM With 350 Psi. - Remove 350 Ton Slips - Land 103/4" Casing On Fluted Hanger Rig Down Casing Tongs And Pick Up Sling - Clear Rig Floor - Pump Pit Volume Down While Conditioning Mud Properties - Make Up Haliburton Cementing Head And Circulating Surface Lines - Hold Pre Job Meeting With All Personal Reguarding Up Coming Cement Operation. 19:30 - 23:30 4.00 CEMT P SURF Reciprocate Casing String 170K Up Weight And 145K Down Weight - Turn Over To Haliburton Energy Services - Pump 10 BBL. Fresh Water - Test Surface Equipment @ 3000 Psi. - Continue To Pump Additional 10 BBL. Water - Mix & Pump 50 BBLS. 10.2 PPG Alpha Spacer @ 5.2 BPM & 370 PSI. With Red Dye Added - Drop Bottom Wiper Plug - Batch Up & Mix Type ilL" Permafrost 10.7 PPG Lead Cement w/ Yield Of 4.15 ft3/sk - Pump @ 7.4 BPM w/550 PSI. - Total Lead Cement Slurry Pumped 443 BBLS Or 600 sacks - Follow Up Lead Cement w/ Surface Tail Design Class "G" Premium 15.8 PPG. Tail Cement w/ Yield Of 1.15 ft3/sk - Tail Cement Job Was Pumped @ 5.9 BPM Circulating Pressure @ 697 Psi. ~ Total Tail Cement Pumped 91 BBLS. Or 440 Sacks - Drop Top Wiper Plug -Haliburton Pumped 10 BBLS. Behind To Clear Lines Turned Over To Rig For Displacement - Displaced @ 10.4 BPM w/9.3 PPG. Spud Mud - Pumped 245 BBLS. Or 2,418 Strokes To Bump Plug - Total Cement Back To Surface 220 BBLS. - Final Circulation Pressure During Displacement @ 640 PSI. - Continue To Pressure Up To 1,700 PSI. After Bumping Plug And Hold For 5 Min. - Bleed Pressure To 0 PSI. Check Floats (OK) Cement In Place @ 2330 Hours. 23:30 - 00:00 0.50 CEMT P SURF Rig Down Surface Circulating Line And Haliburton Cementing Head - Remove Adaptor Swedge - Clear Rig Floor 9/11/2001 00:00 - 02:30 2.50 CEMT P SURF Rig Down Casing Tools And Equipment - Clear Rig Floor - Lay Down Landing Joint And Mouse Hole ~ Change Out Bails And Elevators - Blow Down Top Drive And Surface Lines - Clean Mud System - Drain And Flush Diverter System Printed: 10/812001 1:16:10PM ( ( .' , ' BP'AMOCO Page 3 of 13 - 0 perati onsS urn rnary Report Legal Well Name: MPJ-11 Common Well Name: MPI-11 Spud Date: 9/8/2001 Event Name: DRILL +COMPLETE Start: 917/2001 End: 10/5/2001 Contractor Name: NABORS Rig Release: 10/6/2001 Rig Name: NABORS 22E Rig Number: ,Date From - To Hours Activity Code ,NPT Phase ' Description of Operations 9/11/2001 02:30 - 06:00 3.50 BOPSU¡:; P SURF Hold Pre-Job Safety Meeting - Remove 16" Hydraulic Knife Valve And Diverter Line - Nipple Down 21 1/4 2M Annular, Diverter Spool, And FMC Quick Connect 06:00 - 15:00 9.00 BOPSU¡:; P SURF Install FMC Casing Head And Tubing Spool - Install Double Studded Adaptor And Set BOP Stack On Well Head - Test Metal To Metal Seal At 1000 Psi. For 10 Minutes (OK)- Continue To Nipple Up 135/8 5M BOP And Related Equipment - Install Double Valves On Casing Head - Install Turnbuckles, Flow Nipple, And Flow Line. 15:00 - 16:00 1.00 BOPSUF P SURF Hold Pre-Job Safety Meeting -Install Test Plug And Test Joint - Open Up Lower Annulus Valve - Rig Up Testing Equipment 16:00 - 21 :30 5.50 BOPSUF P SURF Test BOP And Related Equipment - Test Annular At 250 Low For 5 Minutes And 2,500 Psi High For 5 Minutes - Test Upper And Lower Pipe Rams, Blind Rams, Manual And HCR Valves On Choke And Kill Line, Choke Manifold, Upper And Lower IBOP Valves On Top Drive, Dart Valve And Full Opening Safety Valve At 250 Psi. Low For 5 Minutes And 3500 Psi. High For 5 Minutes - Preform Accumulator Test - Test All LEL And H2S Gas Detectors - Test Pit And Flow Line Alarms - All Tests Were Witnessed By AOGCC Representive Jeff Jones. *NOTE* Two Failures: 1) H2S Alarm System Was Found To Be Turned Off - When Haliburton Cementers Keyed There Head Sets It Will Set Off Alarms. 2) Lower IBOP Valve Failed To Test At 250 Psi. 21 :30 - 00:00 2.50 BOPSUF N RREP SURF Change Out Lower Top Drive IBOP Valve - Work On Pipe Handler Torque Wrench 9/12/2001 00:00 ~ 01 :30 1.50 BOPSUF P SURF Pull Test Plug - Install Wear Ring And Energize Lock Down Studs On Tubing Head - Circulate Water Thru Choke Manifold To Poor Boy Degasser And Verify All Lines Clear Of Any Obstructions - Blow Down Surface Lines 01 :30 - 04:30 3.00 DRILL P INn Pick Up 25 Stands Of 5" Drill Pipe And Stand Back In Mast 04:30 - 05:30 1.00 DRILL P INn Service Top Drive, Traveling Blocks, And Crown Sheaves 05:30 - 09:00 3.50 DRILL P INT1 Pick Up 9 7/8" Bit And BHA No.2 - Initalize MWD Tool ~ Shallow Test MWD Tool And Mud Motor (OK) 09:00 -11:00 2.00 DRILL P INT1 Pick Up 10 Stands Of 5" Drill Pipe And Stand Back In Mast 11:00 -13:30 2.50 DRILL P INT1 Pick Up Singles Of 5" Drill Pipe And RIH To Top Of Float Collar 13:30 - 14:00 0.50 DRILL P INT1 Circulate And Condition Mud 14:00 - 15:00 1.00 DRILL P INn Pressure Test 10 3/4" Surface Casing At 1500 Psi. For 30 Minutes 15:00 - 16:30 1.50 DRILL P INT1 Tag Cement Wiper Plugs At 2,641' - Float Collar At 2,643'- Drill Float Collar And Cement To Top Of Float Shoe At 2,727- Drill Float Shoe To 2,729' - Ream Out 13 1/2" Rat Hole To 2,743' - Drill 9 7/8" New Hole To 2,768' 16:30 -18:30 2.00 DRILL P INn Citrculate And Condition Mud 18:30 - 22:30 4.00 DRILL P INn Perform Formation Integrity Test And Leak Of Test With 8.9 ppg Mud - Equivalent Mud Weight With 550 Psi. At Leak Off 13.5 ppg. 22:30 - 00:00 1.50 DRILL P INT1 Drill Ahead From 2,768' To 2,964' - Weight On Bit 10K To 15K With Pump Rate At 130 Strokes Or 550 GPM - Off Bottom Pump Pressure At 1500 Psi. & On Bottom Pump Pressure At 1650 Psi. Top Drive RPM At 70 Off Bottom Torque At 4K & On Printed: 10/812001 1:16:10 PM " --, Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 9/12/2001 9/13/2001 9/14/2001 9/15/2001 9/16/2001 -( (" . , " " " " , BPAM0CO p"" ':Operations' summa..y-:Report MPI-11 MPI-11 DRILL +COMPLETE NABORS NABORS 22E 22:30 - 00:00 From - To HoUrs Activity Code NPT 1.50 DRILL P 00:00 - 00:00 00:00 - 03:30 03:30 - 05:00 05:00 -11:00 11 :00 - 12:00 12:00 -13:00 13:00 -15:30 15:30 - 00:00 00:00 - 09:30 09:30 -11:00 11:00 -15:00 15:00 -16:00 16:00 - 18:30 18:30 - 00:00 00:00 - 03:00 24.00 DRILL P 3.50 DRILL P 1.50 DRILL P 6.00 DRILL P 1.00 DRILL P 1.00 DRILL 2.50 DRILL P P 8.50 DRILL P 9.50 DRILL P 1.50 DRILL P 4.00 DRILL P 1.00 DRILL P INT1 2.50 DRILL N RREP INn 5.50 DRILL 3.00 DRILL N N RREP INT1 RREP INn Pagð4 of 13 Start: 9n/2001 Rig Release: 1 0/6/2001 Rig Number: Spud Date: 9/8/2001 End: 10/5/2001 Phase, Description ,of Operations: " INT1 Bottom Torque At 5K String Rotating Weight At 120K - With Pump On Drag Up At 125K And Drag Down At 105K. Drill Ahead From 2,964' To 6,292' - Weight On Bit 5K To 20K With Pump Rate At 130 Strokes Or 550 GPM - Off Bottom Pump Pressure At 1700 Psi. & On Bottom Pump Pressure At 1900 Psi. Top Drive RPM At 70 Off Bottom Torque At 8K & On Bottom Torque At 10K String Rotating Weight At 120K - With Pump On Drag Up At 175K And Drag Down At 95K. Slide and rotate for directional control. Drill Ahead From 6,292' To 6,722' - Weight On Bit 10K To 15K With Pump Rate At 135 Strokes Or 555 GPM - Off Bottom Pump Pressure At 2150 Psi. & On Bottom Pump Pressure At 2300 Psi. Top Drive RPM At 80 Off Bottom Torque At 10K & On Bottom Torque At 12K String Rotating Weight At 120K- With Pump On Drag Up At 180K And Drag Down At 95K. Slide And Rotate For Directional Control. Circulate Hole Clean While Pumping Sweeps Rotate And Recipricate Drill String Hold Pre-Job Safety Meeting - Monitor Well Bore (Static) - POH 2 Stands Well Swabbing And Pulling 20K To 30K Above Normal Upward Drag - Make Up Top Drive And Pump Out Of The Hole To 10 3/4" Casing Shoe Service Top Drive, Traveling Blocks, And Crown Sheaves - Change Out Saver Sub And Short Top Drive Blower Hose Pick Up 30 Joints Of 5" Drill Pipe RIH From 2,700' To 6,629' - Break Circulation And Wash To Bottom At 6,722' (No Fill) Drill Ahead From 6,722' To 7,849' - Weight On Bit 10K To 15K With Pump Rate At 135 Strokes Or 555 GPM ~ Off Bottom Pump Pressure At 2150 Psi. & On Bottom Pump Pressure At 2300 Psi. Top Drive RPM At 80 Off Bottom Torque At 1 OK & On Bottom Torque At 12K String Rotating Weight At 120K - With Pump On Drag Up At 180K And Drag Down At 95K. Drill Ahead From 7,849' To 8,978' - Weight On Bit 10K To 15K With Pump Rate At 130 Strokes Or 550 GPM - Off Bottom Pump Pressure At 2250 Psi. & On Bottom Pump Pressure At 2450 Psi. Top Drive RPM At 80 Off Bottom Torque At 14K & On Bottom Torque At 15K String Rotating Weight At 130K - With Pump On Drag Up At 205K And Drag Down At 75K. Pump Weighted Sweep Around While Reciprocating And Rotating Drill String Hold Pre-Job Safety Meeting - Monitor Well Bore (Static) - POH To 8,530' (Pulling Tight) - Connect Top Drive And Pump Out To 6,723' - Pull One Stand To 6,630' With No Excess Drag RIH To 7,476' - While Inspecting Fluid End On No.2 Mud Pump Center Pot Was Found To Be Washed Out Behind Valve Seat INT1 INT1 INT1 INT1 INn INT1 INT1 INT1 INT1 INT1 INn POH From 7,476' To 103/4" Casing Shoe -Install Full Opening Safety Valve In Drill String And Monitor Well Bore While Circulating Across Top Of Hole Into Trip Tank. Change Out Fluid End On No.2 Mud Pump Continue To Change Out Fluid End On No.2 Mud Pump - Test Mud Pump At 4,000 Psi. - Repair Pulsation Damp Leak And Printed: 10/812001 1:16:10 PM ~r (' '- BPAMOCO Page 5 of 13 - . Operations'S ùmmaryReport Legal Well Name: MPI-11 Common Well Name: MPI-11 Spud Date: 9/8/2001 Event Name: DRILL +COMPLETE Start: 9n/2001 End: 10/5/2001 Contractor Name: NABORS Rig Release: 10/6/2001 Rig Name: NABORS 22E Rig Number: Date' From- To Hours Activity Code NPT Phase'" . Description of Operations - ' .' .' .' 9/16/2001 00:00 - 03:00 3.00 DRILL N RREP INn Retest To 4,000 Psi. (OK) 03:00 - 04:00 1.00 DRILL N RREP INn Service Top Drive, Traveling Blocks, And Crown Sheaves 04:00 - 10:00 6.00 DRILL N RREP INn RIH From 103/4" Casing Shoe To 7,476'- Fill Pipe Every 15 Stands - Hit Tight Spot At 3,700' Break Circulation And Wash Thru Area (NO Problem) - Continue To RIH Washing Every Third Stand Down. 10:00 - 11 :00 1.00 DRILL P INT1 *NOTE* Continue With Planned Operations - Continue To RIH From 7,476' To 8,509' - Wash To Bottom From 8,509' To 8,979' 11 :00 - 18:00 7.00 DRILL P INT1 Drill Ahead From 8,978' To 9,550' Lost 25 BBLS. Drilling Mud - Monitor Well - Reduce Pump Rates And Drill To 9,570' - Mud Losses 75 Barrels Per Hour Shut Down - Weight On Bit 2K To 1 OK With Pump Rate At 130 Strokes Or 550 GPM - Off Bottom Pump Pressure At 2400 Psi. & On Bottom Pump Pressure At 2550 Psi. Top Drive RPM At 90 Off Bottom Torque At 15K & On Bottom Torque At 17K String Rotating Weight At 130K - With Pump On Drag Up At 225K And Drag Down At 75K. 18:00 - 19:30 1.50 DRILL P INT1 POH To Get Above Thief Zone - Pull 2 Stands - Well Swabbing - Pump Out At Very Slow Rate To Keep Hole Full To 8,700' 19:30 - 21 :00 1.50 DRILL P INn Work Pipe And Reduce Mud Weight To 9.5 PPG. From 10.0 PPG. And Mix Up 20 lb. Per Bbl. LCM Pill - Hole Standing Full With No Circulation - Losses At 36 Barrel Per Hour During Circulation. 21 :00 - 00:00 3.00 DRILL P INT1 Pump LCM Pill And Stage In The Hole While Increasing Pump Rates On Each Stand To Previous Circulation Rates. Continue To String In LCM While Staging In The Hole. 9/17/2001 00:00 - 01 :30 1.50 DRILL P INn Continue To Stage In The Hole To 9,570' Increasing Pump Rates On Each Stand To Previous Circulation Rates While Monitoring Fluids. String In LCM While Staging In The Hole. 01 :30 - 16:00 14.50 DRILL P INT1 Drill Ahead From 9,570' To 10,767' - Weight On Bit 5K To 10K With Pump Rate At 125 Strokes Or 525 GPM - Off Bottom Pump Pressure At 2100 Psi. & On Bottom Pump Pressure At 2150 Psi. Top Drive RPM At 100 Off Bottom Torque At 13K & On Bottom Torque At 15K String Rotating Weight At 140K- With Pump On Drag Up At 210K And Drag Down At 90K. Fluid Losses At 2 To 3 Barrels Per Hour. 16:00 - 17:30 1.50 DRILL P INT1 Circulate And Condition Mud - Circulate Sweeps Around 17:30 - 22:30 5.00 DRILL P INn Monitor Well Bore (Static) - POH 5 Stands No Swabbing - Pump Dry Job - Continue To POH To 9,650' Pulling Tight And Swabbing - Connect Top Drive Pump Out Of The Hole To 9,500' - Pull Pipe To 8,700' (No Problems) ~ Pump Second Dry Job And POH To 103/4" Casing Shoe 22:30 - 00:00 1.50 DRILL P INT1 Slip And Cut 102' Of 1 3/8" Drilling Line 9/18/2001 00:00 - 00:30 0.50 DRILL P INn Finish cutting and slipping drill line. 00:30 - 01 :30 1.00 DRILL P INn Service top drive and crown 01 :30 - 05:30 4.00 DRILL P INT1 Trip in hole. No problems. Reamed last stand to bottom. 05:30 -11:00 5.50 DRILL P INT1 Pump sweep and circulate hole clean. Add lube-tex to bring the concentration up to 4%. Spot glass beads. 11 :00 - 14:30 3.50 DRILL P INT1 Monitor well and pull five stands-no swabbing. Pump pill and stand back 60 stands 5" drill pipe in derrick. Record up. down and rotating wts every 5 stands in open hole. 14:30 - 18:00 3.50 DRILL P INT1 Turn elevators and continue pooh laying down 53 stands of 5 Printed: 10/812001 1:16:10 PM . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 'Date ( ( , " BP AMOCO Operations Summary Report MPI-11 MPJ-11 DRILL +COMPLETE NABORS NABORS 22E ,. From ~To Hours Activity Code NPT . 9/18/2001 14:30 - 18:00 18:00 - 20:00 20:00 - 22:00 22:00 - 23:00 23:00 - 00:00 9/19/2001 00:00 - 05:00 05:00 - 06:00 06:00 -14:00 14:00 - 22:30 22:30 - 00:00 9/20/2001 00:00 - 08:30 08:30 - 10:30 10:30 - 13:00 13:00 -14:00 14:00 -15:00 15:00 -16:00 16:00 - 18:00 18:00 - 19:00 19:00 - 00:00 3.50 DRILL 2.00 DRILL 2.00 DRILL 1.00 DRILL 1.00 CASE 5.00 CASE 1.00 CASE 8.00 CASE 8.50 CASE 1.50 CASE 8.50 CASE 2.00 CASE 2.50 CASE 1.00 CASE 1.00 CASE 1.00 CASE 2.00 CASE 1.00 CASE 5.00 CASE Phase p p p INT1 INT1 INT1 p P INn INn P INT1 p INT1 P INT1 N RREP INT1 P INT1 P INn P INT1 P INT1 P P INT1 INT1 P P INT1 INT1 P P INT1 INT1 . Page 6 of 13 Start: 917/2001 Rig Release: 10/6/2001 Rig Number: Spud Date: 9/8/2001 End: 10/5/2001 Description" of Operations drill pipe. Lay down BHA. Clear rig floor. Pull wear bushing. Change top rams from 3 112" to 7". Test ram gates to 1000 psi. RU casing running tools & elevators. PJSM. RIH wI guide/reaming shoe, 2 jts, and float collar(Baker locked shoe track). Start running in hole w/7 inch. Monitoring mud volume displaced by pipe & filling casing every 5 jts. Continue running in hole with 7" 26# L-80 521 Hydril casing to the casing shoe. Circulate bottoms up at the casing shoe with 1 % EP mud lub. Record torque readings. 15 rpms -2000 ft Ibs torque. No losses Continue running in hole with 7" 26# L-80 521 Hydril casing to the casing shoe. On jt # 187 while slacking off the jt of casing the casing got wedged inside the pipe handler. Evaluated situation and removed the springs from the inside of the pipe guide and freed up the jt of casing. Pulled jt #187 out of the hole and laid it out. Laid down the pipe handler. Installed crossover with tiw valve. Circulate and reciprocate casing while pipe handler was being repaired. Pumped at 6 bpm with 240 psi. No losses. Removed, repaired, & re-installed damaged pipe handler on top drive. Continue running in hole with 7" 26# L-80 521 Hydril casing to the casing shoe. Recording PUW, SOW, & ROTW on data trend sheet. Circulating at 5 bpm, & rotating casing down on each joint using top drive & drive bushings. Hole condition is stable. Casing at 8013 at midnight report close-out time. Finish running 268jts 7" 26# L-80 521 Hydril casing. Make up hanger and land same. Shoe at 10,748'. Install cement head and break circulation slow. Increase rate to 8 bpm with 600 psi. No losses. Pumped 2 bottoms up. PJSM with all personnel. Pump 10 bbls water, test lines 3500 psi, followed by 10 more bbls of water. Mix and pump 50 bbls 10.5 ppg spacer. Mix and pump 1400 sxs(287bbls) Class"G"@15.8ppg. Pump 5 bls water and displace with rig pumps. Bump plug 3000 psi. CIP @ 1300. Lost returns 30 bbls before bumping plug. Check floats and rig down casing equipment. LD landing jt. Drain BOP stack. PU stand DP & RIH wI pack-off, install, & test to 5000 psi. Change 7 in. rams to 3112 x 6" variable. Change top drive saver sub & stabbing guide to 31/2" DP. Change out iron roughneck to 31/2" equipment. RU test equipment. Conduct BOP test. Witnessing waived by AOGCC inspector. Test top pipe rams, choke manifold valves 1-18, floor valves, dart valves to 250 psi low for 5 mins and 3500 psi high for 10 mins. Test annular preventer to 250 psi low and 2500 psi high. Test HCR valve, choke manual valves, blind rams, lower pipe rams to 250 psi low 7 3500 psi high. Test accumulator hydraulics to 3000 psi. Test inside BOP (top drive) to 250/3500psi. Printed: 10/812001 1:16:10 PM ,- . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . Date 9/21/2001 9/22/2001 9/23/2001 9/24/2001 ( , ( , , Page 7 of13 BP'AMOCO'-", Operations-Summary Report MPI-11 MPJ-11 DRILL +COMPLETE NABORS NABORS 22E '.' From -To Hòurs Activity Code :NPT Phase 00:00 - 02:00 02:00 - 02:30 02:30 - 05:30 05:30 - 07:00 07:00 - 10:30 10:30 - 00:00 00:00 - 02:00 02:00 - 02:30 02:30 ~ 03:30 03:30 - 07:00 07:00 ~ 08:00 08:00 - 08:30 08:30 - 12:00 12:00 - 23:00 23:00 - 00:00 00:00 - 01 :30 01 :30 ~ 02:30 02:30 - 03:00 03:00 - 04:00 04:00 - 06:30 06:30 ~ 07:30 07:30 - 12:00 12:00 - 23:00 23:00 - 00:00 00:00 - 01 :00 01 :00 - 08:30 08:30 - 10:30 10:30 - 12:00 12:00 - 16:30 2.00 CASE 0.50 CASE 3.00 CASE 1.50 CASE 3.50 DRILL 13.50 DRILL 2.00 DRILL 0.50 DRILL 1.00 DRILL 3.50 DRILL 1.00 DRILL 0.50 DRILL 3.50 DRILL 11.00 DRILL 1.00 DRILL 1.50 DRILL 1.00 DRILL 0.50 DRILL 1.00 DRILL 2.50 DRILL 1.00 DRILL 4.50 DRILL 11.00 DRILL 1.00 DRILL 1.00 DRILL 7.50 DRILL 2.00 DRILL 1.50 DRILL 4.50 DRILL P INT1 P P P P INT1 INT1 INT1 PROD1 P PROD1 P PROD1 P P P P P PROD1 PROD1 PROD1 PROD1 PROD1 P PROD1 P PROD1 P P P PROD1 PROD1 PROD1 P P P PROD1 PROD1 PROD1 P P PROD1 PROD1 P PROD1 P P P PROD1 PROD1 PROD1 P PROD1 P PROD1 P PROD1 Start: 917/2001 Rig Release: 10/6/2001 Rig Number: Spud Date: 9/8/2001 End: 10/5/2001 'Description of Operations .' Continue testing- upper & lower leap valves to 250 psi low & 3500 psi high. Laydown test equipment & blow down mud line, choke line, kill line, & gas buster lines. Install wear ring & run in 4 lock down screws. PU 81 jts 31/2", 13.31bf/ft drillpipe. Rabbit and RIH. Stand back 27 stands drillpipe(for open hole section drilling). Clear drill floor. Pick-up and make-up BHA per Sperry directional. Pick-up 31/2" DP, rabbit, and RIH wI singles. Shallow test MWD. RIH to 10499 ft. Pipe "floating" into wellbore due to frictional drag. Start taking on new Baradril mud into rig pit system. Continue tripping in hole with directional bha. Picking up and rabbitting 3-1/2" drill pipe. Tag float collar@ 10,665'. Circulate bottoms up. Test 7" casing 3500 psi for 30 minutes on chart. good test. Drill float equipment and 30' new formation to 10, 797'. Circulate bottoms up before performing FIT. 9.6 ppg in and out. Perform FIT with 9.6 ppg mud. Did not break down formation with 280 psi. held pressure for 10 minutes. EMW=11.0 ppg Circulate and displace well with 9.2 ppg BARADRILN mud. Shakers blinding off. Shear mud & change shaker screens. Drill 6 1/8" horizontal borehole from 10797'-11917' in OB lateral. Circulate 25 bbl viscous sweeps at 11580' & 11911'. PUW 140,000. SOW 95,000, ROTW 112,000. 2300 psi on btm. 2100 psi off btm. 4000 ~OOO ft-Ibf torque offlon btm. 80 RPM, 233 GPM. 9.2 ppg MW. ECD 11.2-12.3 ppg EMW. Circulate viscous sweep to clean hole. Prepare for short trip. Circulate & conditon mud to lower ECD Short tip to 7" casing at 10700'. Hole in good shape wI no adverse drag or tight spots. Blow down top drive & service rig. TIH from 10700 to 11917'. Wash & ream last stand to bottom. 11917-12100. Replace old mud wI 800 bbls new BaradrilN while drilling ahead. CBU to lower ECD. Drill 12100 to 12383'. PUW 130k, SOW 80k, ROTW 105k, TQon 7000, TQoff 5000, 100 rpm, PSlon 2600, PSloff 2450, 59 spm, 248 gpm, 5-8k woe. ECD 11.6-12.3 range. Drill 12383 to 13170' TD in the OB lateral. PUW 145000, SOW 85000, ROTW 112000, TQon-5k, TQoff 4k, 100 rpm, 55 spm, 250 gpm, 2600 PSI on, 2450 PSI off. 5-8k WeB. ECD 11.6-12.3. Circulate 2 btms up prior to POOH for hole opener run. Continue pumping sweep & CBU x2. Monitor wellbore 10 mins. POOH to 10716. Pump dry job. Blow down top drive. POOH to BHA. Monitor well, clear floor. PU 2 jt drillpipe & stand back wI jars & flex NMDC's. Lay down HOC, MWD, float, motor, bit. Download MWD data in pipe shed. Pick up 2 stabilizers & pony collar. MU BHA porcupine hole opener. RIH to 11769 & stack out weight. Printed: 10/8/2001 1:16:10 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 9/24/2001 9/25/2001 9/26/2001 I" ( (' " BP'AMOCO " -"- 0 perati onsS~ mmary Rep,o,rt MPI-11 MPI-11 DRILL +COMPLETE NABORS NABORS 22E Pag~ Sot 13 ", "' Start: 9n/2001 Rig Release: 10/6/2001 Rig Number: Spud Date: 9/8/2001 End: 10/5/2001 ". From:-- To HourS Activity Code NPT phase 12:00 - 16:30 16:30 - 17:00 17:00 - 00:00 00:00 - 00:30 00:30 - 03:30 03:30 ~ 06:00 06:00 - 10:30 10:30 - 11 :00 11 :00 - 12:00 12:00 - 21 :00 21 :00 - 22:30 22:30 - 00:00 00:00 - 01 :30 01 :30 - 04:30 04:30 - 05:00 05:00 - 10:00 10:00 -15:30 15:30 -16:30 16:30 - 20:30 4.50 DRILL 0.50 DRILL 7.00 DRILL PROD1 PROD1 PROD1 P P P 0.50 DRILL 3.00 DRILL 2.50 DRILL 4.50 DRILL PROD1 PROD1 PROD1 PROD1 P P P P 0.50 DRILL 1.00 DRILL 9.00 DRILL PROD1 PROD1 PROD1 P P P 1.50 DRILL PROD1 P 1.50 DRILL PROD1 P 1.50 DRILL 3.00 DRILL 0.50 DRILL PROD1 PROD1 PROD1 P P P 5.00 DRILL PROD2 P 5.50 DRILL PROD2 P 1.00 DRILL PROD2 P 4.00 DRILL PROD1 P Description ot Operations. ." POOH to 10747. Wash & ream to 13125. ROTW 102k, PUW 130K, SOW 70k. TQon-5k, TQoff-4k. PSI 2900, 300 gpm, 12 0 spm. Wash down wI 2-6k weight on btm. Continue to wash & ream to btm. 13125-13170'. CBU x2. Spot 100 bbls new mud in OA lateral. Monitorwell. POOH to 7 in shoe at 10748. Monitorwell. Pump dry job, blow down top drive & mud line. POOH 10748' to 216'. Monitor well. LD BHA #4(hole opener). Clear floor. RU 4 1/2" liner running tools. Run 41/2",12.6#, L80 BTC: guide shoe, solid joint, pack off bushing, 61 jts slotted, 4 jts solid, pup, XO, HMC LH, ZXP packer in hole. See casing report for details. MU liner hanger & RIH. Break circulation at 10748'. RIH to 13170 & tag TD. Set liner hanger/packer as follows: Drop 7/8" brass ball & pump to seat. Pressure to 2000 psi. Hanger set at 1450 psi. Slack off 20K weight to set hanger. Pressure to 2000 psi to release setting tool. PU 5' to open setting dogs. Bleed pressure. Slack off 3X to weight set packer(25K needed at liner top). Rotate & spud on liner top. Blow ball seat wI 3800 psi. Rotate & spud 6X to ensure setting weight reached packer. Pump dry job. Blow down top drive & mud line. POOH to 9666' CUT AND SLIP DRILLING LINE. POOH FROM 9666' TO LINER RUNNING TOOL. MONITOR WELL. LAY DOWN RUNNING TOOL. CLEAR FLOOR. PU MILLS, XO, HANG~OFF SUB, BUMPER SUB,. PU SEAL ASSEMBLY, UNLOADER SUB, 6- 31/2" DP, 1-HWDP. MU MILLS TO HWDP. PU BAKER BOTTOM TRIP WHIPSTOCK. RIH. PU MWD, HOS. SCRIBE & ALIGN WHIPSTOCK TO MWD. UPLOAD MWD. MU BUMPER SUB & 9- 4 3/4" DC's, 18 HWDP. RIH 1 STAND & SHALLOW TEST MWD. BLOW DOWN TOP DRIVE & MUD LINE. RIH WI WHIPSTOCK AT 1.5 MIN TO 2 MIN PER STAND. SEAL ASSEMBLY AT 10542'. ORIENT & SET WHIPSTOCK 9 DEG RIGHT OF HIGH SIDE AT 10345'. RECORD 135K PUW, 95k SOW. SLACK OFF TO STING IN WI SEAL ASSEMBLY INTO LINER TOP. (7' INTO TIEBACK RECEPTACLE). STING IN & OUT 3X. TO VERIFY SEALS LANDED. SLACKOFF 20k WEIGHT TO SET BOTTOM TRIP ANCHOR. WHIPSTOCK SET AT 10345'. DID NOT SEE WEIGHT FALL OFF. PU TO VERIFY OVERPULL OF 10K. SET DOWN TO SHEAR BOLT AND WEIGHT INDICATOR DID NOT INDICATE BOLT SHEAR. USE BUMPER SUB TO SHEAR BOLT 3X. PU TO NEUTRAL AND BEGIN SLOW ROTATION. OBSERVED THAT SHEAR HAD OCCURRED. MILL 6.151 INCH WINDOW IN 7 INCH CASING FROM 10345' TO 10357'. MILL FORMATION 10357' TO 10373'. WORK Printed: 10/812001 1:16:10 PM (" (' , BP AMOCO Page 9.of 13 0 pe rati ens Sum mil ryReport Legal Well Name: MPI-11 Common Well Name: MPI-11 Spud Date: 9/8/2001 Event Name: DRILL +COMPLETE Start: 917/2001 End: 10/5/2001 Contractor Name: NABORS Rig ReJease: 10/6/2001 Rig Name: NABORS 22E Rig Number: Date ..'... From -To Hours Activity Code NPT Phase .. . Description of Opera~ions. .. . 9/26/2001 16:30 - 20:30 4.00 DRILL P PROD1 MILLS MULTIPLE PASSES ACROSS WINDOW DEPTH. 20:30 - 23:30 3.00 DRILL P PROD2 PUMP 25 BBL VISCOUS SWEEP & CIRCULATE BOTTOMS UP. CONDUCT F.I.TTO 13 PPG EMW. CLOSED ANNULAR PREVENTER AROUND 3 1/2" DP. PUMPED DOWN DP AND ANNULUS- PRESSURED UP 5 SPM INCREMENTALLY TO 690 PSI(9.3 PPG, 3600 TVD). SHUT PUMPS IN. PRESSURE FELL OFF IMMEDIA TEL YTO 450 PSI FOR AN F.I.T. OF 11.7 PPG EMW. 23:30 - 00:00 0.50 DRILL P PROD2 START DISPLACING 260 BBLS HOLE VOLUME WI FRESH BARADRILN MUD. 900 BBLS NEW MUD ON LOCATION. DISPLACE OLD MUD TO VAC TRUCKS FOR HAUL-OFF TO DISPOSAL 9/27/2001 00:00 - 01 :30 1.50 DRILL P PROD2 POOH FROM 10773' TO 10221'. PUMP DRY JOB, BLOW DOWN TOP DRIVE & MUD LINE. CONTINUE POOH TO 8172'. 01 :30 - 02:30 1.00 DRILL P PROD2 SERVICE RIG & TOP DRIVE. 02:30 - 03:30 1.00 DRILL N RREP PROD2 REPAIR BYPASS VALVE ON IRON ROUGHNECK. 03:30 - 06:00 2.50 DRILL N PROD2 CONTINUE TO POOH 8172 TO 930'. 06:00 - 07:30 1.50 DRILL N PROD2 STAND BACK 6 STANDS HWDP. LD STEEL DC'S. 07:30 - 09:00 1.50 DRILL N PROD2 DOWNLOAD MWD. LD MILLS & HWDP. MU MOTOR TO MWD & STAND BACK. 09:00 - 10:00 1.00 DRILL N PROD2 CLEAR FLOOR. MU BOP WASH-OUT TOOL TO 1 STAND DP. FLUSH BOP STACK OF ANY MILL CUTTINGS. BLOW-DOWN TOP DRIVE & MUD LINE. LAY DOWN WASH TOOL 10:00 - 18:30 8.50 DRILL P PROD2 PULL WEAR RING. RU FOR BOP TEST. START BOP TEST 250 PSI LOW & 3500 PSI HIGH. AOGCC'S JOHN SPAULDING VERBALLY WAIVED WITNESSING THE TEST. TESTED ANNULAR, MANUAL CHOKE, HCR CHOKE, LOWER PIPE RAMS, BLIND RAMS, CHOKE VALVES, UPPER IBO. LOWER IBOP FAILED TEST. PRESSURE TEST ACCUMULATOR HYDRAULICS. REMOVE TEST PLUG & INSTALL WEAR RING. BLOW-DOWN CHOKE & KILL LINE. 18:30 - 22:00 3.50 DRILL N RREP PROD2 CHANGE-OUT LOWER IBOP. 22:00 - 22:30 0.50 DRILL P PROD2 FINISH BOP TEST ON LOWER IBOP. 22:30 - 00:00 1.50 DRILL P PROD2 MU BIT, STABILIZER, ADJ MOTOR(1.5 BEND). ORIENT HIGH SIDE TO MWD. LAY-OUT HOC & INSTALL NEW PULSER. MU HOC. 9/28/2001 00:00 - 01 :00 1.00 DRILL P PROD2 LOAD MWD. MU 3 STEEL FLEX DC'S. PU JARS. 01 :00 - 05:30 4.50 DRILL P PROD2 RIH W/1 STD DP AND SHALLOW TEST MWD OK. RIH, FILLING DP EVERY 30 STANDS TO 10251'. 05:30 - 06:00 0.50 DRILL P PROD2 ORIENT TO HIGH SIDE & LOWER BHA ACROSS WHIPSTOCK AND OUT CASING WINDOW WI PUMPS OFF. NO PROBLEMS ACROSS WINDOW. 06:00 - 08:30 2.50 DRILL P PROD2 DRILL 10367'-10529'. 08:30 - 10:30 2.00 DRILL N RREP PROD2 REPAIR OIL PUMP ON TOP DRIVE 10:30 - 00:00 13.50 DRILL P PROD2 DRILL 10529' TO 11546'. 25 BBL VISCOUS SWEEP PUMPED TO LOWER ECD FROM 12.2 TO 11.8 EMW. 9/29/2001 00:00 - 10:30 10.50 DRILL P PROD2 DRILL 11546' TO 12383'. AT APPROX 0130 HRS DISPLACED HOLE & MUD SYSTEM WITH NEW BARADRILN MUD. MUD AIRED UP AND CAUSED PROBLEMS WITH MWD COMMUNICATIONS. PUW 125K, SOW 90K, ROTW Printed: 101812001 1:16:10 PM ( (' , . BP AMOCO Page 10 of 13 ., Operations' Summary Report ,,' Legal Well Name: MPI-11 Common Well Name: MPI-11 Spud Date: 9/8/2001 Event Name: DRILL +COMPLETE Start: 9n/2001 End: 10/5/2001 Contractor Name: NABORS Rig Release: 10/6/2001 Rig Name: NABORS 22E Rig Number: ; Date ,', From - To Hours Activity Code NPT .Phase" Description of Operations. ' 9/29/2001 00:00 - 10:30 10.50 DRILL P PROD2 105K, PSI-ON BTM 2600, PSI OFF BTM 2450, RPM 80-90, woe 5K-8K, 58 SPM, 247 GPM, 12.6 ECD MAX. 10:30 -11:30 1.00 DRILL P PROD2 FINISHED CIRCULATING VISCOUS SWEEP & JETTED TO VAC TRUCKS. 11 :30 - 12:30 1.00 DRILL P PROD2 DRILL 12383' TO 12477'. MUD AIRED UP AND CAUSED PROBLEMS WITH MWD COMMUNICATIONS. PUW 125K, SOW 90K, ROTW 105K, PSI-ON BTM 2600, PSI OFF BTM 2450, RPM 80-90, WOB 5K-8K, 58 SPM, 247 GPM, 12.6 ECD MAX. 12:30 - 13:00 0.50 DRILL N PROD2 CHECKED PUMP SUCTION SCREENS AND FOUND THEY WERE NOT PLUGGED. CONTINUE ADDING DEFOAMER TO MUD SYSTEM TO ELIMINATE ENTRAINED AIR. 13:00 - 22:00 9.00 DRILL P PROD2 PUMPED 25 BBL VISCOUS SWEEP AT 1630HRS. DRILLED TO 13190' TD AT 2200 HRS. 22:00 - 00:00 2.00 DRILL P PROD2 PUMPED 25 BBLS VISCOUS SWEEP, RECIPROCATED, & ROTATED WHILE CIRCULATING PRIOR TO SHORT TRIP TO CASING. 9/30/2001 00:00 - 01 :00 1.00 DRILL P PROD2 CIRCULATE & CONDITION MUD. MONITOR WELL FOR 10 MINS. STABLE. 01 :00 - 04:30 3.50 DRILL P PROD2 POOH WI 5 STANDS SLOWLY & MONITOR FOR SWABBING. PUMP OUT OF HOLE EVERY 3RD STAND DUE TO SWABBING. PULL BHA INTO CASING & CIRCULATE BOTTOMS UP. 04:30 ~ 07:30 3.00 DRILL P PROD2 TIH 10251'-12550'. WORK PIPE TO 12575' & BEGIN STACKING OUT WEIGHT. WASH & REAM 12575'-12845'. TIH TO 13090'. WASH & REAM TO 13190'. TORQUE 3-4K FT-LBF. PUW 130K, SOW 90K, ROTW 105KAT 80 RPM, 245 GPM. 07:30 - 12:00 4.50 DRILL P PROD2 CCM MUD & PUMP VISCOUS, WEIGHTED SWEEP. PUMP 2ND SWEEP DUE TO EXCESS CUTTINGS OBSERVED ACROSS SHAKER SCREENS. 12:00 - 12:30 0.50 DRILL P PROD2 CIRCULATE. SHUT DOWN PUMPS & MONITOR WELL F/10 MINS. 12:30 - 16:30 4.00 DRILL P PROD2 POOH TO 12662'. PUMP OUT TO 10215' DUE TO SWABBING. POOH TO 9787'. 16:30 -17:00 0.50 DRILL P PROD2 PUMP DRY JOB. BLOW DOWN TOP DRIVE & MUD LINE. 17:00 - 21 :00 4.00 DRILL P PROD2 POOH & STAND BACK DC'S & JARS. 21 :00 - 23:30 2.50 DRILL P PROD2 DOWN LOAD MWD & PWD DATA. REMOVE PULSER, LD HOC, RES-GAMMA, ABI, PWD, FLOAT, MUD MOTOR, & BIT. 23:30 - 00:00 0.50 DRILL P PROD2 INSTALL NEW MASTER BUSHINGS ON RIG FLOOR. 10/1/2001 00:00 ~ 01 :30 1.50 DRILL P PROD2 PU HOLE OPENER BHA CONSISTING OF 6 1/8" STRAIGHT BLADED, BUTTON INSERT, HOLE OPENER, NM PONY COLLAR, las, FS, NMDC, las, 2 NMDC, JARS, 1 STD HWDP. 01 :30 - 02:30 1.00 DRILL P PROD2 SERVICE RIG TOP DRIVE, CROWN, BLOCKS, IRON ROUGHNECK. 02:30 - 07:30 5.00 DRILL P PROD2 TIH WI HOLE OPENER ASSEMBLY 10500'. RECORDING EVERY 1000'. OFF BTM: PUW 132K, SOW 90K, ROlW 112K, 4000 FT-LBF TORQUE. 07:30 - 16:00 8.50 DRILL P PROD2 WASH & REAM 10500' TO 13190' AT 300 GPM, 120 RPM, 900 FPH. NO HOLE PROBLEMS ENCOUNTERED. FREEZE PROTECTED 10 3/4" X 7" ANNULUS WITH 130 BBLS DIESEL OIL AT 1-2 BPM, 2000 PSI. Printed: 10/812001 1:16:10 PM (' ( . '. ap'AMOCO Page 11 of 13 Operations-Summary Report Legal Well Name: MPI-11 Common Well Name: MPI-11 Spud Date: 9/8/2001 Event Name: DRILL +COMPLETE Start: 917/2001 End: 10/5/2001 Contractor Name: NABORS Rig Release: 10/6/2001 Rig Name: NABORS 22E Rig Number: Date From - To Hours Activity COde NPT Phase Description of Operations 1011/2001 16:00 - 17:30 1.50 DRILL P PROD2 CIRCULATE BOTTOMS UP & PUMP 25 BBLS WEIGHTED SWEEP. CONTINUE TO CARRY CUTTINGS, SAND, SLUDGE OVER SHAKERS AFTER SWEEP REACH SURFACE. 17:30 - 22:00 4.50 DRILL P PROD2 PUMP 2ND 25 BBL WEIGHTED SWEEP. SPOT 100 BBL LINER RUNNING PILL WI 4% LUBE-TEX CONC. IN OPEN HOLE. 22:00 - 00:00 2.00 DRILL P PROD2 TOOH WI HOLE OPENER ASSEMBLY to 10841'. 10/2/2001 00:00 - 00:30 0.50 DRILL P PROD2 POH TO WINDOW MONITOR WELL BORE (STATIC) 00:30 - 05:30 5.00 DRILL P PROD2 PUMP DRY JOB AND CONTINUE TO POH - RECORD UP, DOWN, AND ROTATING WEIGHTS EVERY 1000 FEET IN CASED HOLE 05:30 - 06:30 1.00 DRILL P PROD2 LAY DOWN BHA AND CLEAR RIG FLOOR 06:30 - 07:30 1.00 DRILL P PROD2 SERVICE TOP DRIVE, TRAVELING BLOCKS, AND CROWN SHEAVES 07:30 - 10:30 3.00 DRILL P PROD2 PICK UP BHA ORIENT FIXED LUG RETRIEVING TOOL WITH MWD AND SURFACE TEST SAME 10:30 - 14:30 4.00 DRILL P PROD2 HOLD PRE-JOB SAFETY MEETING - RIH WITH 31/2" DRILL PIPE FROM MAST TO 10,290' 14:30 -15:30 1.00 DRILL P PROD2 ORIENT BAKER RET. TOOL - JET WHIPSTOCK FACE AND RETRIEVAL SLOT - LATCH ONTO WINDOW MASTER WHIPSTOCK AND CONFIRM LUG LANDED IN SLOT - JAR FREE TO COMPLETE RECOVERY OPERATION - MONITOR WELL BORE (STATIC) 15:30 - 17:00 1.50 DRILL P PROD2 SPOT BAROID E.P. MUD LUBE - PUMP DRY JOB AND BLOW DOWN TOP DRIVE AND MUD LINE 17:00 - 20:30 3.50 DRILL P PROD2 HOLD PRE-JOB SAFETY MEETING - POH WITH WHIPSTOCK ASSEMBLY TO 5,931 - PULL SLOW TO OBTAIN PROPER HOLE FILL 20:30 - 22:00 1.50 DRILL P PROD2 SLIP AND CUT 121' OF 1 3/8" DRILLING LINE 22:00 - 00:00 2.00 DRILL P PROD2 CONTINUE TO POH TO 550' 10/3/2001 00:00 - 03:00 3.00 DRILL P PROD2 CONTINUE TO POH WITH 31/2" DRILL PIPE - LAY DOWN 4 3/4" DRILL COLLARS, BAKER FISHING TOOLS, AND WINDOW MASTER WHIPSTOCK ASSEMBLY (FULL RECOVERY) 03:00 - 05:00 2.00 DRILL P PROD2 CUT AND SLIP DRILLING LINE DUE TO BAD SPOT ON LINE. RESTRING BLOCK HANGING LINE 05:00 - 06:00 1.00 DRILL P PROD2 SERVICE TOP DRIVE, TRAVELING BLOCKS, AND CROWN SHEAVES 06:00 - 07:00 1.00 DRILL P PROD2 CLEAR RIG FLOOR OF BAKER FISHING TOOLS AND WHIPSTOCK ASSEMBL Y 07:00 - 07:30 0.50 CASE P COMP RIG UP CASING TOOLS AND EQUIPMENT. HOLD PRE-JOB SAFETY MEETING. 07:30 -11:00 3.50 CASE P COMP PICK UP 70 JOINTS OF 12.6 LB. L-80 IBT 41/2" SLOTTED LINER AND BAKER WALL HOOK HANGER RIH PER WELL PROGRAM 11 :00 - 11 :30 0.50 CASE P COMP RIG DOWN CASING TOOLS AND EQUIPMENT - CLEAR RIG FLOOR 11:30 -15:30 4.00 CASE P COMP RIH WITH 41/2" LINER ON 31/2" DRILL PIPE FROM MAST (SLM) TO 10,357'. PULL BACK TO MIDDLE OF WINDOW. 15:30 -17:00 1.50 CASE P COMP ORIENT BENT JOINT AND WORK THRU WINDOW OF UPPER LATERAL - CONTINUE TO RIH TO 13,090' - CHECK AND RECORD UP AND DOWN WEIGHTS - CONTINUE TO Printed: 10/8/2001 1:16:10 PM .' Bp: AMOCO' ,e Page 12 of 13 -"",' Operations Summary Report Legal Well Name: MPI-11 Common Well Name: MPI-11 Spud Date: 9/8/2001 Event Name: DRILL +COMPLETE Start: 917/2001 End: 10/5/2001 Contractor Name: NABORS Rig Release: 10/6/2001 Rig Name: NABORS 22E Rig Number: 'Date From - To Hours Activity Code NPT Phåsff' ,,: Description of Operations " ' 10/3/2001 15:30 -17:00 1.50 CASE P COMP RIH TO 13,120' AND ENGAGE HOOK HANGER IN WINDOW - SLACK OFF LINER WEIGHT PLUS 16,000 LBS. SETTING HANGER 17:00 - 18:00 1.00 CASE P COMP BREAK CIRCULATION - DROP BALL - PUMP 77 BARRELS AND PREASURE UP TO 3,000 PSI. TO RELEASE SETTING TOOL AND SHEAR BALL SEAT - PICK UP AND VERIFY THAT TOOL RELEASED - RECORD UP AND DOWN WEIGHTS 18:00 - 20:30 2.50 CASE P COMP CIRCULATE AND DISPLACE WELL TO 9.2 PPG BRINE - ROTATE AT 50 RPM AND RECIPROCATE WORK STRING 20:30 - 00:00 3.50 CASE P COMP MONITOR WELL BORE (STATIC) - BLOW DOWN TOP DRIVE AND MUD LINE - HOLD PRE-JOB SAFETY MEETING - POH LAYING DOWN 31/2" DRILL PIPE AND LINER RUNNING ASSEMBl Y 10/4/2001 00:00 - 03:00 3.00 CASE P COMP POH AND LAY DOWN 31/2" DRILL PIPE 03:00 - 04:00 1.00 CASE N RREP COMP REPAIR HYDRAULIC LEAK ON VARCO IRON RUFFNECK 04:00 - 06:00 2.00 CASE P COMP CONTINUE TO LAY DOWN 31/2" DRILL PIPE AND BAKER LINER RUNNING TOOLS 06:00 - 07:00 1.00 CASE P COMP CLEAR AND CLEAN RIG FLOOR - PICK UP TUBING RUNNING EQUIPMENT 07:00 - 11 :00 4.00 CASE P COMP LAY DOWN 31/2" DRILL PIPE FROM MAST IN MOUSE HOLE 11 :00 - 12:00 1.00 BOPSUR P COMP PULL WEAR RING - INSTALL TEST PLUG 12:00 - 14:00 2.00 BOPSUR P COMP REMOVE 31/2" X 6" VARIBLE RAMS FROM TOP GATE AND INSTALL 2 718" RAMS. *NOTE* BOP TEST DUE ON 10/04/2001 WAS EXTENDED BY AOGCC REPRESENTIVE CHUCK SCHEVE 14:00 - 15:00 1.00 BOPSUF P COMP MAKE UP PUMP IN SUB AND FLOOR VALVE - RIG UP TESTING EQUIPMENT - TEST DOOR SEALS AT 1,800 PSI.- RIG DOWN TEST EQUIPMENT 15:00 - 17:00 2.00 RIGU P COMP HOLD PRE-JOB SAFETY MEETING WITH NABORS ALASKA DRILLING AND CENTRILIFT PERSONAL - RIG UP SPOOLING UNIT AND HANG SHEAVE FOR ESP CABLE 17:00 - 19:00 2.00 RUNCOf P COMP PICK UP AND SERVICE BAKER HUGHES CENTRILIFT MODEL GPDIS PUMP 19:00 - 20:00 1.00 RUNCO~ fP COMP RIG UP TUBING TONGS AND BACK UPS - MAKE UP CROSS OVER TO FULL OPENING SAFETY VALVE 20:00 - 00:00 4.00 RUNCO~ fp COMP PICK UP AND RIH WITH 2 7/8" 6.5 lB. L-80 (EUE 8-ROUND) COMPLETION STRING PER WELL PROGRAM (116 JOINTS RAN AT 00:00 HOURS) 10/5/2001 00:00 - 06:00 6.00 RUNCO~ fP COMP RIH WITH 2 7/8" COMPLETION STRING. 06:00 - 10:00 4.00 RUNCO~ fP COMP INSTALL NEW REEL OF ESP CABLE AND SPLICE SAME. 10:00 - 15:30 5.50 RUNCO~ fp COMP CONTINUE TO RIH WITH BAKER HUGHES CENTRILIFT ESP PER WELL PROGRAM - RUN 321 JOINTS OF 2 7/8" 6.5 LB. l-80 TUBING WITH EUE (8 ROUND) COUPLINGS - INSTALL TWC IN FMC TUBING HANGER AND MAKE UP - INSTALL PENETRATOR ON FMC HANGER. 15:30 - 16:00 0.50 RUNcor fP COMP RIG DOWN TUBING TONGS AND EQUIPMENT - CLEAR RIG FLOOR. 16:00 - 18:00 2.00 RUNCor fp COMP CUT ESP CABLE - MAKE UP EFT LOWER CONNECTION - CHECK ESP CONDUCTIVITY PHASE TO PHASE TO ( (' Printed: 10/812001 1:16:10 PM - Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: { ( Page 13 of 13 BP AMOCO . , " . Operations' Summary: Report MPJ-11 MPI-11 DRILL +COMPLETE NABORS NABORS 22E - Start: 9n/2001 Rig Release: 10/6/2001 Rig Number: Spud Date: 9/8/2001 End: 10/5/2001 10/5/2001 16:00 - 18:00 From - To Hours Activity Code' NPT Phase Description of Operations , Rate 18:00 -19:30 19:30 - 21:30 21 :30 - 23:30 10/6/2001 23:30 - 00:00 00:00 - 01 :00 01:00 - 01:30 01 :30 - 02:30 02:30 - 06:00 2.00 RUNCO~ P COMP 1.50 RUNCO~ P COMP 2.00 RUNCO~P COMP 2.00 RUNCO~P COMP 0.50 RUNCO~P 1.00 RUNCO~fp 0.50 RUNCO~fp 1.00 RUNCO~fp COMP COMP COMP COMP 3.50 RUNCO~/P COMP GROUND ON ALL THREE PHASES AND CONFIRM BALANCED CONDUCTIVITY WITH CENTRILIFT REPRESENTIVE. DRAIN BOP STACK - RECORD COMPLETION STRING UP WEIGHT AT 1 02K AND DOWN WEIGHT AT 80K - LAND TUBING HANGER AND ENERGIZE LOCK DOWN STUDS - RIG UP TESTING EQUIPMENT AND TEST TWC AT 2,500 PSI. RIG DOWN TEST EQUIPMENT - BACK OUT AND LAY DOWN LANDING JOINT - CLEAR RIG FLOOR BLOW DOWN MUD LINE AND SURFACE EQUIPMENT - CHANGE PIPE RAMS IN TOP GATE TO 3 1/2" X 6" VARIABLES - NIPPLE DOWN BOP AND RELATED EQUIPMENT NIPPLE UP FMC TUBING HEAD ADAPTOR AND TEST TUBING HANGER TO 5,000 PSI. (OK) - NIPPLE UP FMC 2 9/16" 5M TREE REMOVE MANUMATIC WING VALVE AND INSTALL MANUAL WING VALVE. RIG UP TO PRESSURE TEST FMC TREE HOLD PRE-JOB SAFETY MEETING - TEST FMC TREE TO 5,000 PSI. (OK) MAKE FINAL ESP CONDUCTIVITY TEST (OK) RIG UP LUBRICATOR PULL TWO WAY CHECK VALVE AND INSTALL BACK PRESSURE VALVE CLEAN MUD SYSTEM - PUMP OUT CELLAR - CHANGE TOP DRIVE END BELL GUIDE AND SAVER SUB TO ACCEPT 5" DRILL PIPE - LAY DOWN 2 7/8" AND 31/2" COMPLETION EQUIPMENT TOOLS - PICK UP 5" HANDLING EQUIPMENT - INSTALL TREE CAP AND NEEDLE VALVES - CLOSE ALL VALVES SECURE WELLHEAD AND TREE. *NOTE* RIG RELEASED FROM MPI-11 AT 06:00 HOURS Printed: 10/812001 1:16:10 PM ..1, 'I'i 't ( 06-Nov-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definative Surveys Re: Distribution of Survey Data for Well MPI-11 aOI- /37 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 0.00' MD Window / Kickoff Survey , MD Projected Survey: 13,170.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager ~, , [I"~P'E:' .. , t, ~ . '\ '~<..."., " ~~4 (~~l:-~ 1/ i .. '< C n ~l i~l')' /¡,I(];/ '"""""i , if 0-..,. I~ ,9. . : / ') ¡} .J¡:1$ffa l~, Iß ' .( U 01 ..,/(;1 I~ ro ! ~"u;:'"" 'I. 'i<!';;¥ ('l.fl ,4,~ ~ w.,i!JS, C': ", ' ('*'Üt--"'4" 01)"//"'." " q",,~ st~}"'\'¡"'1 "',;.;. '-"'(8 Attachment(s) D EFI N ITIVE ..- Milne Point Unit Alaska Drilling & Wells Milne Point MPI, Slot MPI-11 MPI-11 Job No. AKZZ11151, Surveyed: 23 September, 2001 - SURVEY REPORT 5 November, 2001 ! Your Ref: API 500292303300 Surface Coordinates: 6009456.78 N, 551405.11 E (70026' 11.7158" N, 149034' 51.1850" W) Kelly Bushing: 63.55ft above Mean Sea Level ..~--- spe""""v-sUI! DRIL-LING SEAVIc:es A Halliburton Company Survey Ref: svy9932 Sperry-Sun Drilling Services Survey Report for MPI-11 Your Ref: API 500292303300 Job No. AKZZ11151, Surveyed: 23 September, 2001 . Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth' Northings Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 DOft) 0.00 0.000 0.000 -63.55 0.00 O.OON O.OOE 6009456.78 N 551405.11 E 0.00 AK-6 BP IFR-AK 222.70 0.690 142.460 159.14 222.69 1.06 S 0.82E 6009455.72 N 551405.93 E 0.310 -0.65 .',~ 312.91 1.130 188.370 249.34 312.89 2.37 S 1.02 E 6009454.41 N 551406.14 E 0.906 -0.66 402.27 2.010 203.430 338.67 402.22 4.68 S 0.27E 6009452.10 N 551405.41 E 1.079 0.43 488.74 2.890 227.580 425.06 488.61 7.55 S 1.95W 6009449.22 N 551403.22 E 1.548 3.04 579.93 5.740 244.450 515.99 579.54 11.06 S 7.76W 6009445.66 N 551397.43 E 3.388 9.31 671.54 6.400 244.460 607.08 670.63 15.24 S 16.50 W 6009441.43 N 551388.72 E 0.720 18.57 765.54 8.370 246.860 700.30 763.85 20.19 S 27.52 W 6009436.40 N 551377.73 E 2.121 30.20 858.10 10.800 247.180 791.56 855.11 26.20 S 41.71 W 6009430.29 N 551363.58 E 2.626 45.12 956.21 12.210 249.330 887.70 951.25 33.43 S 59.89 W 6009422.94 N 551345.45 E 1.502 64.16 1049.90 13.170 251.120 979.10 1042.65 40.38 S 79.26 W 6009415.86 N 551326.13 E 1.107 84.35 1143.54 16.410 255.950 1069.63 1133.18 47.04 S 102.19 W 6009409.03 N 551303.25 E 3.699 108.01 1236.84 20.740 260.690 1158.05 1221.60 52.92 S 131.29 W 6009402.96 N 551274.19 E 4.911 137.66 1329.10 24.600 261.350 1243.17 1306.72 58.45 S 166.41 W 6009397.18 N 551239.11 E 4.193 173.21 1424.23 23.820 261.720 1329.93 1393.48 64.20 S 205.00 W 6009391.17 N 551200.56 E 0.835 212.22 1517.80 25.040 261.970 1415.12 1478.67 69.68 S 243.30 W 6009385.42 N 551162.29 E 1.309 250.92 1613.23 29.450 260.950 1499.94 1563.49 76.20 S 286.49 W 6009378.61 N 551119.15 E 4.647 294.60 1707.31 30.370 261.290 1581.49 1645.04 83.44 S 332.84 W 6009371.05 N 551072.85 E 0.994 341.51 1800.17 31 .380 261.220 1661.19 1724.74 90.68 S 379.94 W 6009363.48 N 551025.81 E 1.088 389.16 1895.09 32.350 260.090 1741.81 1805.36 98.83 S 429.38 W 6009355.00 N 550976.42 E 1.200 439.26 .~".,.. 1988.50 40.310 261.270 1817.00 1880.55 107.73 S 483.95 W 6009345.72 N 550921.91 E 8.554 494.55 2082.98 45.870 262.690 1885.97 1949.52 116.69 S 547.84 W 6009336.32 N 550858.09 E 5.973 559.06 2177.29 52.040 263.200 1947.87 2011.42 125.41 S 618.40 W 6009327.12 N 550787.59 E 6.555 630.13 2270.74 57.400 263.840 2001.82 2065.37 134.00 S 694.17 W 6009318.00 N 550711.88 E 5.763 706.34 2364.87 59. 180 263.680 2051.30 2114.85 142.70 S 773.77 W 6009308.75 N 550632.34 E 1.897 786.36 2458.98 59.950 262.420 2098.97 2162.52 152.52 S 854.31 W 6009298.37 N 550551.87 E 1.415 867.47 2554.04 62.260 261.420 2144.90 2208.45 164.23 S 936.70W 6009286.10 N 550469.56 E 2.599 950.68 2646.77 66.780 259.200 2184.79 2248.34 178.34 S 1019.19W 6009271.42 N 550387.18 E 5.332 1034.35 2694.25 69.110 258.490 2202.62 2266.17 186.86 S 1062.36 W 6009262.60 N 550344.07 E 5.099 1078.30 2732.73 70.920 259.150 2215.77 2279.32 193.87 S 1097.83 W 6009255.35 N 550308.64 E 4.972 1114.42 ..-.--- 5 November, 2001 - 16:43 Page 2 of 8 Dri/lQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPI-11 Your Ref: API 500292303300 Job No. AKIZ11151, Surveyed: 23 September, 2001 . Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth' Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 2829.83 76.130 260.760 2243.30 2306.85 210.09 S 1189.49 W 6009238.50 N 550217.10 E 5.596 1207.46 2924.39 79.740 259.950 2263.06 2326.61 225.58 S 1280.63 W 6009222.38 N 550126.06 E 3.'908 1299.90 -. 3016.92 78.600 259.070 2280.45 2344.00 242.13 S 1369.99 W 6009205.22 N 550036.82 E 1.546 1390.72 3101.45 77.910 258.820 2297.65 2361.20 257.99 S 1451.22 W 6009188.79 N 549955.70 E 0.866 1473.40 3207.14 75.110 261.690 2322.31 2385.86 275.40 S 1552.48 W 6009170.68 N 549854.56 E 3.740 1576.13 3297.26 79.040 262.080 2342.46 2406.01 287.80 S 1639.42 W 6009157.69 N 549767.71 E 4.381 1663.95 3395.85 79.030 261.740 2361.22 2424.77 301.42 S 1735.25 W 6009143.41 N 549671.98 E 0.339 1760.73 3490.42 80.480 263.020 2378.04 2441.59 313.75 S 1827.49 W 6009130.44 N 549579.83 E 2.031 1853.78 3583.26 79.420 261.080 2394.24 2457.79 326.39 S 1918.02 W 6009117.17 N 549489.39 E 2.353 1945.19 3677.40 82.040 261.990 2409.40 2472.95 340.07 S 2009.91 W 6009102.87 N 549397.59 E 2.942 2038.09 3771.40 79.290 261.320 2424.65 2488.20 353.53 S 2101.67 W 6009088.78 N 549305.92 E 3.009 2130.83 3865.80 79.480 263.520 2442.04 2505.59 365.76 S 2193.64 W 6009075.91 N 549214.04 E 2.299 2223.60 3960.06 80.230 261.830 2458.64 2522.19 377.59 S 2285.67 W 6009063.44 N 549122.10 E 1.936 2316.36 4052.26 80.850 260.940 2473.80 2537.35 391.22 S 2375.58 W 6009049.20 N 549032.28 E 1.166 2407.31 4148.36 79.800 263.020 2489.95 2553.50 404.44 S 2469.38 W 6009035.33 N 548938.57 E 2.397 2502.03 4242.59 80.850 263.080 2505.79 2569.34 415.68 S 2561.59 W 6009023.46 N 548846.45 E 1.116 2594.88 4336.46 80.290 264.410 2521.17 2584.72 425.77 S 2653.64 W 6009012.73 N 548754.47 E 1.520 2687.41 4430.53 82.470 263.750 2535.27 2598.82 435.36 S 2746.14 W 6009002.50 N 548662.03 E 2.419 2780.32 4524.44 82.780 263.920 2547.32 2610.87 445.36 S 2838.74 W 6008991.86 N 548569.51 E 0.376 2873.38 4618.19 83.030 262.540 2558.90 2622.45 456.33 S 2931.12W 6008980.26 N 548477.21 E 1.485 2966.37 ..~. 4711.68 82.350 262.750 2570.80 2634.35 468.20 S 3023.08 W 6008967.75 N 548385.33 E 0.761 3059.08 4806.17 85.810 263.270 2580.54 2644.09 479.63 S 3116.36 W 6008955.68 N 548292.13 E 3.702 3153.02 4899.91 84.950 263.110 2588.09 2651.64 490.71 S 3209.13 W 6008943.96 N 548199.44 E 0.933 3246.41 4993.69 84.210 260.690 2596.95 2660.50 503.87 S 3301.55 W 6008930.17 N 548107.11 E 2.687 3339.76 5087.19 81.600 260.380 2608.50 2672.05 519.12 S 3393.07 W 6008914.28 N 548015.70 E 2.811 3432.53 5181.09 82.530 258.500 2621.46 2685.01 536.17 S 3484.49 W 6008896.61 N 547924.40 E 2.217 3525.46 5273.71 81.910 256.890 2634.00 2697.55 555.72 S 3574.14 W 6008876.44 N 547834.88 E 1.848 3617.02 5366.96 81 .790 257.850 2647.22 2710.77 575.91 S 3664.22 W 6008855.63 N 547744.95 E 1.027 3709.09 5461.16 80.290 258.680 2661.89 2725.44 594.83 S 3755.32 W 6008836.08 N 547653.98 E 1.815 3801.98 5555.4 7 79.850 258.530 2678.15 2741.70 613.18 S 3846.38 W 6008817.10 N 547563.04 E 0.492 3894.76 -~--~ 5 November, 2001 - 16:43 Page 3 of 8 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPI-11 Your Ref: API 500292303300 Job No. AKZZ11151, Surveyed: 23 September, 2001 . Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub~Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth' Northings Eastlngs Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) , 5647.15 79.040 258.480 2694.95 2758.50 631.15 S 3934.70 W 6008798.53 N 547474.85 E 0.885 3984.76 5742.44 79.230 259.350 2712.91 2776.46 649.14 S 4026.54 W 6008779.90 N 547383.14 E 0.919 4078.25 .~- 5837.65 78.720 261.140 2731.12 2794.67 664.97 S 4118.64 W 6008763.44 N 547291.15 E 1.922 4171.67 5931.89 76.570 262.060 2751.28 2814.83 678.42 S 4209.70 W 6008749.36 N 547200.19 E 2.473 4263.72 6024.15 76.830 263.250 2772.51 2836.06 689.90 S 4298.75 W 6008737.27 N 547111.22E 1.286 4353.49 6117.25 77.980 263.810 2792.81 2856.36 700.14 S 4389.03 W 6008726.41 N 547021.01 E 1.368 4444.29 6210.77 78.220 264.030 2812.09 2875.64 709.83 S 4480.02 W 6008716.09 N 546930.09 E 0.345 4535.72 6300.76 79.660 262.830 2829.36 2892.91 719.94 S 4567.76 W 6008705.38 N 546842.43 E 2.067 4623.99 6399.02 82.030 259.410 2844.99 2908.54 734.92 S 4663.58 W 6008689.74 N 546746.71 E 4.198 4720.97 6489.52 81.600 259.230 2857.88 2921.43 751.52 S 4751.60 W 6008672.53 N 546658.80 E 0.514 4810.48 6587.38 81.220 259.240 2872.49 2936.04 769.59 S 4846.66 W 6008653.80 N 546563.87 E 0.388 4907.17 6677.61 80.610 258.300 2886.74 2950.29 786.94 S 4934.05 W 6008635.85 N 546476.60 E 1.231 4996.16 6772.73 80.600 258.880 2902.27 2965.82 805.51 S 5026.04 W 6008616.65 N 546384.74 E 0.602 5089.88 6866.55 80.550 258.730 2917.63 2981.18 823.48 S 5116.84 W 6008598.05 N 546294.07 E 0.166 5182.33 6960.48 80.730 259.410 2932.91 2996.46 841.05 S 5207.83 W 6008579.85 N 546203.20 E 0.740 5274.93 7053.05 79.420 259.810 2948.86 3012.41 857.49 S 5297.52 W 6008562.79 N 546113.63 E 1.478 5366.06 7148.90 79.030 259.990 2966.78 3030.33 874.01 S 5390.22 W 6008545.64 N 546021.04 E 0.447 5460.18 7242.08 78.660 260.190 2984.81 3048.36 889.74 S 5480.28 W 6008529.29 N 545931.10 E 0.449 5551.57 7340.96 80.600 259.250 3002.61 3066.16 907.10 S 5575.97 W 6008511.27 N 545835.52 E 2.173 5648.78 7434.38 80.110 259.530 3018.26 3081.81 924.06 S 5666.50 W 6008493.69 N 545745.12 E 0.602 5740.82 ".- 7527.68 79.660 259.430 3034.65 3098.20 940.83 S 5756.80 W 6008476.30 N 545654.93 E 0.494 5832.61 7620.93 79.920 259.720 3051.18 3114.73 957.43 S 5847.06 W 6008459.07 N 545564.79 E 0.414 5924.33 7713.08 79.740 259.700 3067.45 3131.00 973.64 S 5936.31 W 6008442.25 N 545475.66 E 0.196 6014.99 7806.81 81.790 261.250 3082.49 3146.04 988.94 S 6027.54 W 6008426.32 N 545384.53 E 2.729 6107.48 7896.86 81.840 261.340 3095.31 3158.86 1002.43 S 6115.64 W 6008412.22 N 545296.52 E 0.113 6196.61 7998.82 82.590 261.030 3109.12 3172.67 1017.91 S 6215.47 W 6008396.05 N 545196.80 E 0.795 6297.63 8092.92 81.840 261.200 3121.87 3185.42 1032.31 S 6307.58 W 6008381.02 N 545104.79 E 0.817 6390.86 8187.99 81.790 260.270 3135.40 3198.95 1047.46 S 6400.46 W 6008365.23 N 545012.03 E 0.970 6484.95 8280.90 81.970 261.270 3148.53 3212.08 1062.21 S 6491.24 W 6008349.85 N 544921.34 E 1.083 6576.92 8374.74 82.100 260.620 3161.53 3225.08 1076.84 S 6583.02 W 6008334.59 N 544829.67 E 0.700 6669.85 _. -. - --_n__' 5 November, 2001 - 16:43 Page 4 of 8 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPI-11 Your Ref: API 500292303300 Job No. AKZZ111516 Surveyed: 23 September6 2001 . Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth' Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 8468.24 81.100 262.940 3175.19 3238.74 1090.07 S 6674.56 W 6008320.73 N 544738.22 E 2.678 6762.34 8562.57 81.780 262.430 3189.23 3252.78 1101.94 S 6767.08 W 6008308.22 N 544645.79 E 0:897 6855.60 .~ 8656.53 81.910 261.890 3202.56 3266.11 1114.63 S 6859.22 W 6008294.90 N 544553.74 E 0.585 6948.60 8750.83 81.540 261.450 3216.13 3279.68 1128.15 S 6951.55 W 6008280.74 N 544461.50 E 0.606 7041.92 8843.55 81.290 261.500 3229.97 3293.52 1141.74S 7042.22 W 6008266.53 N 544370.93 E 0.275 7133.60 8935.79 80.230 260.960 3244.78 3308.33 1155.62 S 7132.19 W 6008252.03 N 544281.05 E 1.286 7224.64 9029.53 80.480 260.890 3260.49 3324.04 1170.20 S 7223.45 W 6008236.82 N 544189.89 E 0.277 7317.05 9124.16 80.670 260.300 3275.98 3339.53 1185.45 S 7315.55 W 6008220.93 N 544097.90 E 0.647 7410.39 9218.25 80.600 260.240 3291.30 3354.85 1201.14 S 7407.05 W 6008204.61 N 544006.51 E 0.097 7503.21 9312.25 80.720 259.640 3306.55 3370.10 1217.34 S 7498.38 W 6008187.78 N 543915.30 E 0.643 7595.92 9405.42 80.540 259.490 3321.72 3385.27 1233.99 S 7588.78 W 6008170.51 N 543825.01 E 0.250 7687.80 9499.44 78.610 260.420 3338.73 3402.28 1250.12 S 7679.83 W 6008153.75 N 543734.08 E 2.272 7780.23 9592.11 78.160 259.890 3357.39 3420.94 1265.64 S 7769.26 W 6008137.62 N 543644.75 E 0.741 7870.97 9686.70 78.590 259.180 3376.45 3440.00 1282.47 S 7860.37 W 6008120.16 N 543553.76 E 0.864 7963.57 9781.16 77.850 258.290 3395.73 3459.28 1300.53 S 7951.06 W 6008101.47 N 543463.20 E 1.210 8055.93 9875.13 76.210 257.810 3416.83 3480.38 1319.49 S 8040.64 W 6008081.90 N 543373.75 E 1.815 8147.33 9968.87 75.000 259.670 3440.13 3503.68 1337.238 8129.69 W 6008063.55 N 543284.83 E 2.315 8238.01 10063.~6 75.330 262.610 3464.38 3527.93 1351.328 8220.12 W 6008048.83 N 543194.50 E 3.022 8329.53 10156.74 76.090 263.760 3487.38 3550.93 1362.03 8 8309.77 W 6008037.50 N 543104.92 E 1.448 8419.79 10251.03 75.560 263.520 3510.47 3574.02 1372.16 S 8400.63 W 6008026.75 N 543014.14 E 0.614 8511.14 ~ 10343.66 76.910 263.610 3532.51 3596.06 1382.24 S 8490.03 W 6008'016.05 N 542924.81 E 1.460 8601.05 10438.22 76.200 263.630 3554.50 3618.05 1392.46 S 8581.43 W 6008005.20 N 542833.48 E 0.751 8692.96 10531.96 77.020 263.050 3576.20 3639.75 1403.04 S 8672.00 W 6007994.00 N 542742.98 E 1.062 8784.10 10626.91 79.670 263.250 3595.38 3658.93 1414.138 8764.32 W 6007982.28 N 542650.74 E 2.799 8877.05 10721.16 83.830 263.450 3608.91 3672.46 1424.93 S 8856.95 W 6007970.84 N 542558.19 E 4.419 8970.26 10786.23 82.780 264.300 3616.49 3680.04 1431.82 S 8921.21 W 6007963.50 N 542493.98 E 2.071 9034.83 10834.62 89.630 266.460 3619.69 3683.24 1435.71 S 8969.30 W 6007959.29 N 542445.92 E 14.839 9082.97 10879.40 93.630 266.740 3618.42 3681.97 1438.36 8 9013.98 W 6007956.32 N 542401.26 E 8.954 9127.55 10925.69 93.700 266.970 3615.46 3679.01 1440.89 S 9060.10 W 6007953.47 N 542355.15 E 0.518 9173.54 10971.56 93.880 266.330 3612.43 3675.98 1443.578 9105.79 W 6007950.48 N 542309.48 E 1.446 9219.13 __n- ---. 5 November, 2001 . 16:43 Page 5 of 8 Dri/lQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MP/.11 Your Ref: API 500292303300 Job No. AKZZ11151, Surveyed: 23 September, 2001 . Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth' Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 11015.89 92.280 262.970 3610.05 3673.60 1447.70 S 9149.86 W 6007946.05 N 542265.45 E 8.385 9263.32 -.- 2.363 11063.31 92.220 261.850 3608.18 3671.73 1453.96 S 9196.83 W 6007939.47 N 542218.52 E 9310.69 11106.18 90.430 261.690 3607.19 3670.74 1460.09 S 9239.24 W 6007933.04 N 542176.15 E 4.192 9353.55 ,.~ 11152.73 90.800 261.270 3606.69 3670.24 1466.99 S 9285.28 W 6007925.83 N 542130.17 E 1.202 9400.10 11198.48 87.780 261.890 3607.26 3670.81 1473.68 S 9330.52 W 6007918.82 N 542084.97 E 6.739 9445.84 11243.34 89.140 262.310 3608.4 7 3672.02 1479.85 S 9374.94 W 6007912.35 N 542040.59 E 3.173 9490.68 11291.13 89.380 261.930 3609.08 3672.63 1486.40 S 9422.28 W 6007905.47 N 541993.30 E 0.940 9538.46 11383.63 92.770 262.850 3607.35 3670.90 1498.64 S 9513.93 W 6007892.59 N 541901.74 E 3.797 9630.92 11434.19 93.200 261.990 3604.71 3668.26 1505.31 S 9563.98 W 6007885.59 N 541851.73 E 1.900 9681.41 11475.38 93.510 261.820 3602.30 3665.85 1511.10 S 9604.69 W 6007879.52 N 541811.06 E 0.858 9722.52 11568.32 93.140 263.270 3596.91 3660.46 1523.13 S 9696.69 W 6007866.85 N 541719.15 E 1.608 9815.29 11617.88 92.090 262.390 3594.65 3658.20 1529.31 S 9745.81 W 6007860.33 N 541670.08 E 2.763 9864.78 11661.46 92.030 263.030 3593.09 3656.64 1534.84 S 9789.01 W 6007854.51 N 541626.92 E 1.474 9908.33 11709.93 90.060 263.600 3592.20 3655.75 1540.48 S 9837.14 W 6007848.53 N 541578.83 E 4.231 9956.76 11753.20 90.000 263.460 3592.18 3655.73 1545.36 S 9880.13 W 6007843.36 N 541535.87 E 0.352 10000.01 11846.46 89.820 263.980 3592.33 3655.88 1555.56 S 9972.83 W 6007832.52 N 541443.24 E 0.590 10093.20 11940.02 90.620 264.140 3591.97 3655.52 1565.24 S 10065.89 W 6007822.20 N 541350.25 E 0.872 10186.66 11988.61 90.980 264.080 3591.29 3654.84 1570.23 S 10114.21 W 6007816.88 N 541301.96 E 0.751 10235.20 12033.20 91.050 263.980 3590.50 3654.05 1574.86 S 10158.56 W 6007811.94 N 541257.65 E 0.274 10279.74 12074.61 90.000 262.830 3590.12 3653.67 1579.62 S 10199.69 W 6007806.90 N 541216.55 E 3.760 10321.12 -- 12124.92 90.000 261.320 3590.12 3653.67 1586.55 S 10249.52 W 6007799.62 N 541166.77 E 3.001 10371.43 12171.52 90.250 261.080 3590.02 3653.57 1593.68 S 10295.57 W 6007792.17 N 541120.77 E 0.744 10418.03 12220.07 90.000 260.940 3589.91 3653.46 1601.27 S 10343.52 W 6007784.25 N 541072.87 E 0.590 10466.57 12267.01 90.000 261.380 3589.91 3653.46 1608.48 S 10389.90 W 6007776.72 N 541026.54 E 0.937 10513.51 12313.04 91.730 257.150 3589.22 3652.77 1617.05 S 10435.11 W 6007767.84 N 540981.39 E 9.927 10559.49 12358.49 93.140 262.050 3587.28 3650.83 1625.25 S 10479.76 W 6007759.34 N 540936.80 E 11.209 10604.86 12407.43 94.560 263.990 3584.00 3647.55 1631.18 S 10528.22 W 6007753.07 N 540888.38 E 4.905 10653.67 12454.80 94.130 265.290 3580.41 3643.96 1635.60 S 10575.25 W 6007748.33 N 540841.39 E 2.883 10700.83 12498.55 90.120 266.820 3578.79 3642.34 1638.60 S 10618.86 W 6007745.03 N 540797.80 E 9.809 10744.40 12542.00 89.750 266.430 3578.84 3642.39 1641.16 S 10662.23 W 6007742.17 N 540754.45 E 1.237 10787.68 -_u.-- -------- , u_- - 5 November, 2001 - 16:43 Page 6 of 8 Dri/lQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPI-11 Your Ref: API 500292303300 Job No. AKZZ11151, Surveyed: 23 September, 2001 . Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inel. Azim. Depth Depth' Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) " 12591.86 89.820 266.200 3579.02 3642.57 1644.36 S 10711.99 W 6007738.62 N 540704.71 E 0.482 10837.37 12640.55 90.000 265.580 3579.10 3642.65 1647.85 S 10760.55 W 6007734.80 N 540656.17 E 1.326 10885.91 -~- 12684.73 92.280 266.950 3578.22 3641.77 1650.73 S 10804.62 W 6007731.62 N 540612.12 E 6.020 10929.93 12731.85 90.000 266.340 3577.28 3640.83 1653.49 S 10851.65 W 6007728.54 N 540565.11 E 5.009 10976.85 12775.41 89.320 265.840 3577.54 3641.09 1656.46 S 10895.11 W 6007725.27 N 540521.68 E 1.938 11020.27 12822.87 89.510 264.300 3578.03 3641.58 1660.54 S 10942.39 W 6007720.86 N 540474.43 E 3.269 11067.63 12868.16 89.450 263.120 3578.44 3641.99 1665.50 S 10987.40 W 6007715.59 N 540429.45 E 2.609 11112.89 12915.13 89.510 263.230 3578.86 3642.41 1671.08 S 11034.04 W 6007709.69 N 540382.85 E 0.267 11159.83 12960.62 89.320 263.370 3579.33 3642.88 1676.39 S 11079.22 W 6007704.07 N 540337.71 E 0.519 11205.30 13052.91 90.000 264.650 3579.88 3643.43 1686.02 S 11171.00W 6007693.81 N 540246.00 E 1.570 11297.50 13100.86 89.940 264.620 3579.90 3643.45 1690.50 S 11218.74 W 6007688.99 N 540198.29 E 0.140 11345.38 13170.00 89.940 264.620 3579.97 3643.52 1696.98 S 11287.57 W 6007682.04 N 540129.50 E 0.000 11414.42 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.155° (01-Sep-01) The Dogleg Severity is in Degrees per 100 feet (US). ~- Vertical Section is from Well and calculated along an Azimuth of 261.515° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13170.000., The Bottom Hole Displacement is 11414.42ft., in the Direction of 261.450° (True). -------_u_----- ------- 5 November, 2001 - 16:43 Page 7 of 8 DrillQuest 2.00.08.005 . . Milne Point Unit Comments "-. - Measured Depth (ft) -, c ="" 13170.00 Sperry-Sun Drilling Services Survey Report for MPI-11 Your Ref: API 500292303300 Job No. AKZZ11151, Surveyed: 23 September, 2001 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 3643.52 1696.98 S Survey tool program for MPI-11 From Measured Vertical Depth Depth (ft) (ft) 0.00 --o~~-- ---- 5 November. 2001 - 16:43 To Measured Vertical Depth Depth (ft) (ft) 0.00 13170.00 3643.52 AK-6 BP _IFR-AK Comment 11287.57 W Projected Survey . Alaska Drilling & Wells Milne Point MPI ----- -- OrillQuest 2.00.08.005 Survey Tool Description Page 8 of 8 --- ---_u_-- It AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 :~ 06-Nov-01 Re: Distribution of Survey Data for Well MPI-11 MWD é)OI-/37 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: ' MD Window / Kickoff Survey , MD Projected Survey: 13,170.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ("E' ;. !~-. . , 'fi" 1\\ , ..;...... " ~ ~ ¡ ,""",..I ~i El) . NOV 0 7 2001 Aff.~~~ (~" "~ ~'\'$Ka is ~ ""0 , ,is ~ bas t~'"t ,'""Vns (\" " A,!'\),¡'\,". ""or. . " ...un~m¿tY~!,'t"';-, ;:I'.,¡.~\, '~t'i¡;;, ,. VI' Q";:;1"~ -~ Milne Point Unit Alaska Drilling & Wells Milne Point MPI, Slot MPI-11 MPI-11 MWD Job No. AKMM11151, Surveyed: 23 September, 2001 SURVEY REPORT 5 November, 2001 Your Ref: API 500292303300 Surface Coordinates: 6009456.78 N, 551405.11 E (70026' 11.7158" N, 149034' 51.1850" W) Kelly Bushing: 63.55ft above Mean Sea Level ---- Sf:lE!r"I'V-SUf! DRIL~c:es A Halliburton Company Survey Ref: svy9974 Sperry-Sun Drilling Services Survey Report for MPI-11 MWD Your Ref: API 500292303300 Job No. AKMM11151, Surveyed: 23 September, 2001 . Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth' Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) eft) (ft) eft) (ft) (ft) (ft) (°/1 OOft) ' -- 0.00 0.000 0.000 -63.55 0.00 0.00 N O.OOE 6009456.78 N 551405.11 E 0.00 MWD Magnetic 222.70 0.690 142.510 159.14 222.69 1.06 S 0.82E 6009455.72 N 551405.93 E 0.310 -0.64 312.91 1.130 188.460 249.34 312.89 2.37 S 1.02 E 6009454.41 N 551406.14 E 0.907 -0.64 -"""'- 402.27 2.010 203.410 338.67 402.22 4.685 0.26E 6009452.10 N 551405.41 E 1.078 0.46 488.74 2.890 227.640 425.06 488.61 7.555 1.95W 6009449.22 N 551403.21 E 1.550 3.09 579.93 5.740 244.900 515.99 579.54 11.03 S 7.78W 6009445.70 N 551397.41 E 3.400 9.39 671.54 6.400 244.670 607.08 670.63 15.16 S 16.54 W 6009441.51 N 551388.67 E 0.721 18.68 765.54 8.370 247.050 700.30 763.85 20.07 5 27.58 W 6009436.52 N 551377.67 E 2.120 30.35 858.10 10.800 247.220 791.56 855.11 26.05 S 41.78 W 6009430.44 N 551363.51 E 2.625 45.30 956.21 12.210 249.420 887.70 951.25 33.26 S 59.97 W 6009423.11 N 551345.37 E 1.505 64.38 1049.90 13.170 251.060 979.10 1042.65 40.21 S 79.34 W 6009416.03 N 551326.05 E 1.094 84.60 1143.54 16.410 255.910 1069.63 1133.18 46.89 S 102.27 W 6009409.19 N 551303.17 E 3.701 108.28 1236.84 20.740 260.700 1158.05 1221.60 52.77 S 131.37 W 6009403.10 N 551274.11 E 4.917 137.94 1329.10 24.600 261.420 1243.17 1306.72 58.28 S 166.49 W 6009397.36 N 551239.03 E 4.195 173.49 1424.23 23.820 261.810 1329.93 1393.48 63.97 S 205.08 W 6009391.40 N 551200.47 E 0.837 212.50 1517.80 25.040 262.060 1415.12 1478.67 69.40 5 243.40 W 6009385.71 N 551162.19 E 1.309 251.19 1613.23 29.450 261.030 1499.94 1563.49 75.85 5 286.60 W 6009378.96 N 551119.04 E 4.647 294.87 1707.31 30.370 261.480 1581.49 1645.04 82.98 S 332.96 W 6009371.51 N 551072.73 E 1.007 341.78 1800.17 31.380 261.390 1661.19 1724.74 90.07 S 380.08 W 6009364.09 N 551025.66 E 1.089 389.43 1895.09 32.350 260.190 1741.81 1805.36 98.10 S 429.54 W 6009355.72 N 550976.25 E 1.221 439.54 .CFc-,./ 1988.50 40.310 261.460 1817.00 1880.55 106.86 S 484.14 W 6009346.59 N 550921.72 E 8.559 494.83 2082.98 45.870 263.880 1885.97 1949.52 115.02 S 548.13 W 6009337.98 N 550857.79 E 6.139 559.31 2177.29 52.040 263.330 1947.87 2011.42 122.95 S 618.78 W 6009329.56 N 550787.20 E 6.557 630.34 2270.74 57.400 264.550 2001.83 2065.38 130.98 S 694.61 W 6009321.02 N 550711.42 E 5.834 706.50 2364.87 59.180 264.660 2051.30 2114.85 138.51 S 774.33 W 6009312.94 N 550631.75 E 1.894 786.43 2458.98 59.950 263.070 2098.98 2162.53 147.18 S 855.00 W 6009303.71 N 550551.14 E 1.671 867.47 2554.04 62.260 262.360 2144.91 2208.46 157.74 S 937.55 W 6009292.58 N 550468.67 E 2.516 950.66 2646.77 66.780 260.390 2184.79 2248.34 170.325 1020.28 W 6009279.43 N 550386.03 E 5.238 1034.34 2694.25 69.110 259.650 2202.62 2266.17 177.94 S 1063.62 W 6009271.51 N 550342.74 E 5.115 1078.34 2732.73 70.920 259.150 2215.77 2279.32 184.60 5 1099.16W 6009264.61 N 550307.25 E 4.860 1114.48 5 November, 2001 - 16:42 Page 2 of 8 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPI-11 MWD Your Ref: API 500292303300 Job No. AKMM11151, Surveyed: 23 September, 2001 . Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 2829.83 76.130 263.530 2243.31 2306.86 198.56 S 1191.16W 6009250.01 N 550215.34 E 6.891 1207.54 2924.39 79.740 261.540 2263.08 2326.63 210.58 S 1282.83 W 6009237.36 N 550123.76 E 4.337 1299.96 -- 3016.92 78.600 258.420 2280.47 2344.02 226.39 S 1372.31 W 6009220.94 N 550034.39 E 3.533 1390.81 3101.45 77.910 258.590 2297.67 2361.22 242.88 S 1453.41 W 6009203.89 N 549953.41 E 0.840 1473.48 3207.14 75.110 262.740 2322.34 2385.89 259.57 S 1554.79 W 6009186.50 N 549852.15 E 4.647 1576.22 3297.26 79.040 262.540 2342.49 2406.04 270.82 S 1641.88 W 6009174.65 N 549765.13 E 4.366 1664.01 3395.85 79.030 260.910 2361.24 2424.79 284.75 S 1737.66 W 6009160.06 N 549669.45 E 1.623 1760.79 3490.42 80.480 263.820 2378.07 2441.62 297.11 S 1829.89 W 6009147.07 N 549577.32 E 3.394 1853.82 3583.26 79.420 259.860 2394.27 2457.82 310.07 S 1920.36 W 6009133.48 N 549486.94 E 4.352 1945.20 3677 .40 82.040 262.730 2409.44 2472.99 324.12 S 2012.18 W 6009118.79 N 549395.21 E 4.098 2038.09 3771.40 79.290 259.950 2424.69 2488.24 338.08 S 2103.86 W 6009104.21 N 549303.63 E 4.132 2130.83 3865.80 79.480 264.240 2442.09 2505.64 350.84 S 2195.74 W 6009090.82 N 549211.84 E 4.471 2223.58 3960.06 80.230 262.050 2458.69 2522.24 361.91 S 2287.86 W 6009079.11 N 549119.80 E 2.421 2316.30 4052.26 80.850 259.300 2473.85 2537.40 376.65 S 2377.59 W 6009063.75 N 549030.17 E 3.018 2407.23 4148.36 79.800 261.480 2490.00 2553.55 392.46 S 2470.99 W 6009047.29 N 548936.89 E 2.489 2501.95 4242.59 80.850 261.310 2505.84 2569.39 406.36 S 2562.83 W 6009032.76 N 548845.14 E 1.128 2594.84 4336.46 80.290 261.810 2521.22 2584.77 419.95 S 2654.43 W 6009018.54 N 548753.64 E 0.795 2687.44 4430.53 82.470 263.450 2535.31 2598.86 431.88 S 2746.66 W 6009005.98 N 548661.49 E 2.888 2780.40 4524.44 82.780 264.900 2547.37 2610.92 441.33 S 2839.31 W 6008995.89 N 548568.91 E 1.566 2873.40 4618.19 83.030 262.960 2558.95 2622.50 451.17 S 2931.81 W 6008985.41 N 548476.48 E 2.071 2966.32 <----- 4711.68 82.350 261.880 2570.85 2634.40 463.40 S 3023.73 W 6008972.55 N 548384.64 E 1.357 3059.02 4806.17 85.810 262.750 2580.59 2644.14 475.96 S 3116.86 W 6008959.34 N 548291.61 E 3.775 3152.97 4899.91 84.950 262.500 2588.14 2651.69 487.96 S 3209.52 W 6008946.71 N 548199.03 E 0.955 3246.37 4993.69 84.210 260.090 2597.00 2660.55 502.09 S 3301.80 W 6008931.95 N 548106.85 E 2.677 3339.73 5087.19 81.600 261.270 2608.55 2672.10 517.11 S 3393.35 W 6008916.29 N 548015.41 E 3.059 3432.50 5181.09 82.530 258.870 2621.51 2685.06 533.15 S 3484.95 W 6008899.62 N 547923.92 E 2.718 3525.48 5273.71 81.910 256.870 2634.05 2697.60 552.43 S 3574.66 W 6008879.72 N 547834.34 E 2.242 3617.09 5366.96 81.790 258.490 2647.27 2710.82 572.13 S 3664.84 W 6008859.41 N 547744.30 E 1.725 3709.23 5461.16 80.290 259.070 2661.94 2725.49 590.23 S 3756.11 W 6008840.67 N 547653.16 E 1.705 3802.20 5555.4 7 79.850 259.330 2678.21 2741.76 607.64 S 3847.36 W 6008822.64 N 547562.03 E 0.540 3895.04 --------~ 5 November, 2001 - 16:42 Page 3 of 8 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPI-11 MWD Your Ref: API 500292303300 Job No. AKMM11151, Surveyed: 23 September, 2001 . Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth' Northings Eastings Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) "'---- 5647.15 79.040 258.170 2695.00 2758.55 625.22 S 3935.75 W 6008804.44 N 547473.76 E 1.526 3985.09 5742.44 79.230 258.740 2712.96 2776.51 643.95 S 4027.44 W 6008785.08 N 547382.20 E 0.B20 4078.57 -~- 5837.65 78. 720 260.580 2731.17 2794.72 660.73 S 4119.37 W 6008767.68 N 547290.39 E 1.971 4171.99 5931.89 76.570 261.230 2751.34 2814.89 675.28 S 4210.27 W 6008752.50 N 547199.60 E 2.379 4264.04 6024.15 76.830 263.010 2772.56 2836.11 687.59 S 4299.20 W 6008739.58 N 547110.75 E 1.899 4353.81 6117.25 77.980 264.130 2792.86 2856.41 697.76 S 4389.49 W 6008728.78 N 547020.54 E 1.704 4444.58 6210.77 78.220 263.690 2812.15 2875.70 707.47 S 4480.48 W 6008718.45 N 546929.61 E 0.527 4535.98 6300.76 79.660 262.720 2829.41 2892.96 717.92 S 4568.17 W 6008707.39 N 546841.99 E 1.918 4624.24 6399.02 82.030 259.030 2845.05 2908.60 733.31 S 4663.93 W 6008691.34 N 546746.35 E 4.423 4721.22 6489.52 81.600 258.970 2857.93 2921.48 750.40 S 4751.86 W 6008673.64 N 546658.53 E 0.480 4810.74 6587.38 81.220 259.610 2872.55 2936.10 768.38 S 4846.94 W 6008655.01 N 546563.58 E 0.754 4907.45 6677.61 80.610 257.770 2886.80 2950.35 785.86 S 4934.30 W 6008636.93 N 546476.34 E 2.124 4996.47 6772.73 80.600 259.410 2902.33 2965.88 804.42 S 5026.29 W 6008617.73 N 546384.49 E 1.701 5090.22 6866.55 80.550 258.990 2917.69 2981.24 821.76 S 5117.20W 6008599.77 N 546293.70 E 0.445 5182.72 6960.48 80.730 260.110 2932.97 2996.52 838.57 S 5208.34 W 6008582.33 N 546202.67 E 1.192 5275.36 7053.05 79.420 260.760 2948.92 3012.47 853.73 S 5298.26 W 6008566.56 N 546112.86 E 1.575 5366.54 7148.90 79.030 260.420 2966.84 3030.39 869.12 S 5391.15W 6008550.52 N 546020.08 E 0.536 5460.69 7242.08 78.660 261.720 2984.87 3048.42 883.31 S 5481.46 W 6008535.71 N 545929.87 E 1.425 5552.11 7340.96 80.600 258.920 3002.67 3066.22 899.67 S 5577.32 W 6008518.69 N 545834.12 E 3.407 5649.35 7434.38 80.110 260.420 3018.32 3081.87 916.19 S 5667.92 W 6008501.55 N 545743.63 E 1.668 5741.42 -~=' 7527.68 79.660 260.340 3034.71 3098.26 931.53 S 5758.48 W 6008485.58 N 545653.18 E 0.490 5833.26 7620.93 79.920 260.070 3051.24 3114.79 947.15 S 5848.92 W 6008469.34 N 545562.86 E 0.399 5925.02 7713.08 79.740 260.570 3067.51 3131.06 962.40 S 5938.33 W 6008453.47 N 545473.56 E 0.569 6015.71 7806.81 81.790 261.860 3082.55 3146.10 976.52 S 6029.75 W 6008438.72 N 545382.23 E 2.575 6108.22 7896.86 81.840 260.280 3095.37 3158.92 990.36 S 6117.80 W 6008424.28 N 545294.28 E 1.738 6197.35 7998.82 82.590 260.750 3109.18 3172.73 1007.01 S 6217.44 W 6008406.94 N 545194.76 E 0.866 6298.36 8092.92 81.840 260.380 3121.93 3185.48 1022.29 S 6309.41 W 6008391.03 N 545102.90 E 0.887 6391.59 8187.99 81.790 258.270 3135.47 3199.02 1039.72 S 6401.88 W 6008372.96 N 545010.55 E 2.197 6485.64 8280.90 81.970 261.700 3148.59 3212.14 1055.71 S 6492.44 W 6008356.34 N 544920.10 E 3.660 6577.59 8374.74 82.100 259.680 3161.60 3225.15 1070.75 S 6584.15 W 6008340.68 N 544828.50 E 2.136 6670.51 ---- - ---- - ---- _n- 5 November, 2001 - 16:42 Page 4 of 8 DrillQuest 2.00.08.005 -. . Sperry-Sun Drilling Services Survey Report for MPI-11 MWD Your Ref: API 500292303300 Job No. AKMM11151, Surveyed: 23 September, 2001 Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-Sea Vertical . Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth' Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) ,-. 8468.24 81 .100 260.890 3175.26 3238.81 1086.36 S 6675.31 W 6008324.44 N 544737.44 E 1.668 6763.00 8562.57 81.780 261.930 3189.30 3252.85 1100.29 S 6767.54 W 6008309.87 N 544645.31 E 1.307 6856.27 8656.53 81.910 260.520 3202.63 3266.18 1114.48 S 6859.46 W 6008295.05 N 544553.49 E 1.492 6949.28 .- 3279.75 1129.96 S 6951.49 W 6008278.93 N 8750.83 81.540 260.380 3216.20 544461.58 E 0.419 7042.59 8843.55 81.290 260.690 3230.04 3293.59 1145.03 S 7041.92 W 6008263.24 N 544371.25 E 0.427 7134.27 8935.79 80.230 258.120 3244.85 3308.40 1161.77 S 7131.40 W 6008245.88 N 544281.88 E 2.980 7225.26 9029.53 80.480 261.230 3260.56 3324.11 1178.33 S 7222.31 W 6008228.70 N 544191.09 E 3.282 7317.64 9124.16 80.670 259.260 3276.06 3339.61 1194.15 S 7314.31 W 6008212.25 N 544099.21 E 2.063 7410.97 9218.25 80.600 260.450 3291.37 3354.92 1210.50 S 7405.69W 6008195.27 N 544007.94 E 1.250 7503.78 9312.25 80.720 258.700 3306.63 3370.18 1227.28 S 7496.91 W 6008177.85 N 543916.84 E 1.841 7596.50 9405.42 80.540 260.320 3321.80 3385.35 1244.02 S 7587.30 W 6008160.49 N 543826.57 E 1.726 7688.39 9499.44 78.610 260.940 3338.81 3402.36 1259.07 S 7678.53 W 6008144.81 N 543735.44 E 2.153 7780.85 9592.11 78.160 260.800 3357.4 7 3421.02 1273.48 S 7768.15 W 6008129.79 N 543645.92 E 0.508 7871.62 9686.70 78.590 258.150 3376.53 3440.08 1290.40 S 7859.23 W 6008112.24 N 543554.96 E 2.781 7964.22 9781.16 77.850 258.900 3395.82 3459.37 1308.80 S 7949.85 W 6008093.22 N 543464.47 E 1.104 8056.60 9875.13 76.210 256.290 3416.91 3480.46 1328.46 S 8039.28 W 6008072.94 N 543375.18 E 3.220 8147.98 9968.87 75.000 259.550 3440.22 3503.77 1347.47 S 8128.05 W 6008053.32 N 543286.55 E 3.607 8238.62 10063.56 75.330 261.880 3464.47 3528.02 1362.23 S 8218.37 W 6008037.93 N 543196.32 E 2.404 8330.15 10156.74 76.090 263.680 3487.47 3551.02 1373.58 S 8307.95 W 6008025.97 N 543106.83 E 2.042 8420.40 10251.03 75.560 262.560 3510.56 3574.11 1384.53 S 8398.71 W 6008014.40 N 543016.14 E 1.282 8511.76 '-c-- 10343.66 76.910 264.170 3532.60 3596.15 1394.92 S 8488.07 W 6008003.39 N 542926.86 E 2.230 8601.66 10438.22 76.200 263.840 3554.59 3618.14 1404.52 S 8579.54 W 6007993.16 N 542835.46 E 0.824 8693.51 10531.96 77.020 261.430 3576.30 3639.85 1416.21 S 8669.97 W 6007980.84 N 542745.11 E 2.650 8784.66 10626.91 79.670 261.610 3595.48 3659.03 1429.93 S 8761.93 W 6007966.50 N 542653.24 E 2.797 8877.64 10721.16 83.830 262.300 3609.00 3672.55 1442.97 S 8854.27 W 6007952.81 N 542561.00 E 4.473 8970.89 10786.23 82.780 265.270 3616.59 3680.14 1449.97 S 8918.51 W 6007945.37 N 542496.81 E 4.812 9035.43 10834.62 89.630 268.570 3619.79 3683.34 1452.56 S 8966.69 W 6007942.45 N 542448.65 E 15.705 9083.44 10879.40 93.630 267.810 3618.51 3682.06 1453.97 S 9011.42 W 6007940.73 N 542403.93 E 9.092 9127.85 10925.69 93.700 268.610 3615.55 3679.10 1455.41 S 9057.59W 6007938.97 N 542357.77 E 1.731 9173.69 10971.56 93.880 266.490 3612.52 3676.07 1457.37 S 9103.31 W 6007936.70 N 542312.06 E 4.628 9219.17 --- -- --- 5 November, 2001 - 16:42 Page 5 of 8 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPI-11 MWD Your Ref: API 500292303300 Job No. AKMM11151, Surveyed: 23 September, 2001 . Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth' Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 11015.89 92.280 260.810 3610.14 3673.69 1462.27 8 9147.29 W 6007931.50 N 542268.12 E 13.293 9263.37 11063.31 92.220 260.020 3608.28 3671.83 1470.168 9194.01 W 6007923.29 N 542221.45 E 1.669 9310.75 - 11106.18 90.430 262.710 3607.29 3670.84 1476.598 9236.38 W 6007916.56 N 542179.13E 7.535 9353.60 -'o~ 11152.73 90.800 260.490 3606.79 3670.34 1483.39 8 9282.42 W 6007909.45 N 542133.13 E 4.835 9400.15 11198.48 87.780 261.750 3607.35 3670.90 1490.458 9327.61 W 6007902.07 N 542087.99 E 7.152 9445.89 11243.34 89.140 263.490 3608.56 3672.11 1496.21 8 9372.08 W 6007896.01 N 542043.56 E 4.922 9490.71 11291.13 89.380 263.160 3609.18 3672.73 1501.768 9419.55 W 6007890.13 N 541996.14 E 0.854 9538.46 11383.63 92.770 262.150 3607.44 3670.99 1513.588 9511.26 W 6007877.67 N 541904.51 E 3.824 9630.90 11434.19 93.200 263.550 3604.81 3668.36 1519.878 9561.35 W 6007871.04 N 541854.46 E 2.893 9681.37 11475.38 93.510 261.610 3602.40 3665.95 1525.188 9602.13 W 6007865.45 N 541813.72 E 4.762 9722.47 11568.32 93.140 261.870 3597.01 3660.56 1538.51 S 9693.95 W 6007851.49 N 541722.00 E 0.486 9815.25 11617.88 92.090 263.950 3594.74 3658.29 1544.62 8 9743.07 W 6007845.04 N 541672.91 E 4.697 9864.73 11661.46 92.030 264.200 3593.18 3656.73 1549.11 S 9786.39 W 6007840.25 N 541629.63 E 0.590 9908.22 11709.93 90.060 265.340 3592.29 3655.84 1553.53 S 9834.65 W 6007835.50 N 541581.40 E 4.696 9956.58 11753.20 90.000 263.820 3592.27 3655.82 1557.628 9877.73 W 6007831.12 N 541538.35 E 3.516 9999.77 11846.46 89.820 263.570 3592.42 3655.97 1567.868 9970.42 W 6007820.23 N 541445.73 E 0.330 10092.94 11940.02 90.620 264.940 3592.06 3655.61 1577.23 S 10063.51 W 6007810.23 N 541352.71 E 1.696 10186.35 11988.61 90.980 263.650 3591.38 3654.93 1582.05 S 10111.85 W 6007805.07 N 541304.40 E 2.756 10234.86 12033.20 91.050 262.4 70 3590.59 3654.14 1587.44 8 10156.11 W 6007799.37 N 541260.19 E 2.651 10279.42 12074.61 90.000 261.710 3590.21 3653.76 1593.14 S 10197.12 W 6007793.39 N 541219.21 E 3.130 10320.82 --c~ 12124.92 90.000 255.260 3590.21 3653.76 1603.18 S 10246.39 W 6007783.02 N 541170.01 E 12.821 10371.05 12171.52 90.250 255.510 3590.11 3653.66 1614.948 10291.48 W 6007770.95 N 541125.00 E 0.759 10417.42 12220.07 90.000 258.800 3590.00 3653.55 1625.73 S 10338.81 W 6007759.83 N 541077.75 E 6.796 10465.85 12267.01 90.000 261.880 3590.00 3653.55 1633.60 S 10385.08 W 6007751.63 N 541031.54 E 6.562 10512.78 12313.04 91.730 258.970 3589.31 3652.86 1641.26 S 10430.46 W 6007743.67 N 540986.21 E 7.354 10558.79 12358.49 93.140 259.610 3587.38 3650.93 1649.70 S 10475.07 W 6007734.92 N 540941.65 E 3.406 10604.17 12407.43 94.560 264.130 3584.09 3647.64 1656.60 8 10523.40 W 6007727.68 N 540893.38 E 9.661 10652.99 12454.80 94. 130 264.040 3580.50 3644.05 1661.478 10570.38 W 6007722.49 N 540846.43 E 0.927 10700.16 12498.55 90.120 267.510 3578.88 3642.43 1664.698 10613.97 W 6007718.97 N 540802.87 E 12.116 10743.72 12542.00 89.750 264.670 3578.93 3642.48 1667.65 S 10657.31 W 6007715.71 N 540759.55 E ,6.591 10787.00 --'------ 5 November, 2001 - 16:42 Page 6 of 8 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPI-11 MWD Your Ref: API 500292303300 Job No. AKMM11151, Surveyed: 23 September, 2001 . Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth' Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (It) (ft) (ft) (0/100ft) 12591.86 89.820 267.120 3579.11 3642.66 1671.22 S 10707.04 W 6007711.80 N 540709.84 E 4.916 10836.68 12640.55 90.000 267.410 3579.19 3642.74 1673.54 S 10755.67 W 6007709.14 N 540661.23 E 0.701 10885.09 ~-~ 12684.73 92.280 265.040 3578.31 3641.86 1676.45 S 10799.74 W 6007705.93 N 540617.18 E 7.443 10929.08 12731.85 90.000 265.020 3577.37 3640.92 1680.53 S 10846.67 W 6007701.53 N 540570.28 E 4.839 10976.08 12775.41 89.320 265.560 3577.63 3641.18 1684.11 S 10890.09 W 6007697.65 N 540526.89 E 1.993 11019.52 12822.87 89.510 265.770 3578.12 3641.67 1687.69 S 10937.41 W 6007693.74 N 540479.60 E 0.597 11066.83 12868.16 89.450 264.590 3578.53 3642.08 1691.50 S 10982.53 W 6007689.62 N 540434.50 E 2.609 11112.00 12915.13 89.510 264.550 3578.96 3642.51 1695.94 S 11029.29 W 6007684.86 N 540387.77 E 0.154 11158.89 12960.62 89.320 263.900 3579.42 3642.97 1700.52 S 11074.55 W 6007679.97 N 540342.55 E 1.489 11204.31 13052.91 90.000 263.960 3579.97 3643.52 1710.28 S 11166.32 W 6007669.58 N 540250.84 E 0.740 11296.49 13100.86 89.940 264.320 3579.99 3643.54 1715.18 S 11214.02 W 6007664.35 N 540203.18 E 0.761 11344.37 13170.00 89.940 264.320 3580.06 3643.61 1722.02 S 11282.82 W 6007657.03 N 540134.43 E 0.000 11413.40 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.135° (23-Sep-01) -- The Dogleg Severity is in Degrees per 100 feet (US). "-- Vertical Section is from Well and calculated along an Azimuth of 261.120° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13170.00ft., The Bottom Hole Displacement is 11413.47ft., in the Direction of 261.322° (True). ---p-- ---- 5 November, 2001 - 16:42 Page 7 of 8 DriflQuest 2.00.08.005 Milne Point Unit Comments Measured Depth (ft) ~~~ 13170.00 Sperry-Sun Drilling Services Survey Report for MPI-11 MWD Your Ref: API 500292303300 Job No. AKMM11151, Surveyed: 23 September, 2001 . 1722.02 S Survey tool program for MPI-11 MWD From Measured Vertical Depth Depth (ft) (ft) 0.00 -- c-~--- 5 November, 2001 - 16:42 Alaska Drilling & Wells Milne Point MPI Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 3643.61 To Measured Vertical Depth Depth (ft) (ft) 0.00 13170.00 3643.61 Comment 11282.82 W Projected Survey Survey Tool Description MWD Magnetic Page 8 of 8 DrillQuest 2.00.08.005 fFwd: MPI-11ML 10-314" surface casing! (PTO 201-137)] \ ( I~ Subject: [Fwd: MPI..11 ML 10..3/4" surface casing! (PTD 201-137)] Date: Fri, 24 Aug 2001 14:35:00 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Cammy Oechsli <Cammy_Oechsli@admin.state.ak.us>, DanieJ T Seamount JR <dan_seamount@admin.state.ak.us>, Julie Heusser <julie_heusser@admin.state.ak.us>, Bob Crandall <bob_crandall@admin.state.ak.us>, Steve Davies <steve_davies@admin.state.ak.us>, John D Hartz <jack_hartz@admin.state.ak.us>, Jane Williamson <Jane_Williamson@admin.state.ak.us> All, Enclosed is BP response to my email. Tom Subject: RE: MPI..11 ML 10-3/4" surface casing! (PTO 201-137) Date: Fri, 24 Aug 2001 17:28: 18 -0500 From: "Campbell, Steve K" <CampbeIS@BP .com> To: 'IITom Maunder'" <tom_maunder@admin.state.ak.us> Thanks for your prompt attention.. I Have forwarded this message to both the light and heavy oil groups and have asked them to be ready late next week for a meeting with the commission. We will call you when we are ready.. Have a great weekend! Steve Campbell 907-564-4401 (0) 907-564-4441 (f) campbels@bp.com ----..Original Message----- From: Tom Maunder [mailto:tom maunder@admin.state.ak.us) Sent: Friday, August 24, 2001 11 :04 AM To: Campbell, Steve K Cc: Shultz, Steve M; Franks, James D; Julie Heusser; Cammy Oechsli; Daniel T Seamount JR; Bob Crandall; AOGCC North Slope Office Subject: Re: MPI-11 ML 10-3/4" surface casing! (PTD 201-137) Steve(s), et ai, Your proposed addition of 10-3/4" surface casing to the subject wellbore has been reviewed. Your proposed change is approved. Adding a surface casing string to the well design is a prudent response to the water influx problem that was encountered on 1-13i. Any other wells planned from MP I pad should be revised to include a surface casing string similar to that approved here. Regardless of targeting the Schrader Bluff or Kuparuk, all wells at Milne 1of3 8/28/0111:13AM [Fwd: MPI-11ML 10-314" surface casing! (PTD 201-137)] ~ ( Point must drill sections of the Schrader. There are a number of wells planned to be drilled shortly in Milne Point. Although the situation encountered in 1-13i may only be unique to that area of the earth, unanticipated pressure events have been encountered on several recent wells in the Milne Point Unit. We request that BP plan to brief the Commission as soon a practical on their understanding of subsuñace pressures and injection fluid movement at Milne Point. The briefing should in particular address and document where, in BP's opinion, suñace casing strings such as incorporated in 1-11 shouJd or should not be included. Since there are several wells presently planned to be drilled on G and F pads, it would seem that your briefing would particularly address these wells. Your early attention to this issue is requested. Tom Maunder, PE Petroleum Engineer AOGCC "Campbell, Steve K" wrote: > Tom, > Attached for your review and approval is a brief change in scope and a > revised wellbore schematic. I visited with the production department about > MPI-13i and their plans are to run a CBL log and then perforate the "N" > sand. They are rounding up crews and equipment to hopefully perform the > work this weekend. The rig (22E) is currently down due to summer maintence. > If things go well with maintence, the rig should be back up and running > about August 29th. Thanks for your prompt attention. > . > «sundrynotice.doc» > «MPI-11 ML WBD2.ZIP» > > Steve Campbell > 907-564-4401 (0) > 907-564-4441 (f) > campbels@bp.com > > ------------------------------------------------------------------------ > > > > > Name: MPI-11 ML WBD2.ZIP > MPI-11 ML WBD2.ZIP Type: Zip Compressed Data ( application/x-zip-compressed) > Encodmg:base64 Name: sundrynotice.doc sundrynotice.doc Type: WINWORD File (application/msword) Encoding: base64 2 of3 ~' 8/28/01 11:13 AM '\, ( II INTEROFFICE MEMORANDUM TO: FROM: TOM MAUNDER STEVE CAMPBELL ~O \ - \ ~ '{ SUBJECT: MPI-11 ML SURFACE CASING DATE: CC: 8/23/01 Due to the higher than anticipated mud weights after drilling the MPI-13, we have decided to add a shallow set surface casing to the MPI-11 well. We could be moving on to this well by August 29,2001. Your prompt attention in this matter is appreciated. Changes to the original well plan are as follows: Dill13..1/2~~ surface hole to 2795~ MD~ 2,300~ TVD with a 9.0 ppg mud weight Run and cement a full string of 10..3/4" 45.5# L-80 BTC~ Cement with 718 sxs lead (artic) and 544 sxs tail (class G) (cement to surface) 3SOCJ ~~o\"'~"'~\ ~\Q.1\ Nipple down the diverter and Nipple up and test BOP~s 250~ psi low/high Test 10-3/4" casing to 1500 psi. drill out float equipment and 20~ of new formation and perform a FIT to 13 ppg with a 9.0 ppg mud. Drill 9-7/8)' hole to TD (11,077' MD, 3,710' TVD) as per the original well plan Run and cement the 7" 26# 1-80 Hydril 521 production pipe, Cement with 794 sxs tail cement (class G) estimated top of cement at 8821~ MD~ 3295~ TVD. Lead cement will not be pumped on this string. The 7" x 10-3/4" annulus will be freeze protected down to the 10..3/4" shoe at the end of the well. Finish well as originally permitted ß().~~o~ -\""-t: ~~~,,~ ~C1.~\r&'f. ~,,~'?~ - \i\ \ !J~ ~~ ~~~~Q:~ ~ ~~ \()~('-\\\ ~~~c:...~ ~'t~ CQ ~~CJa tT'l \> ~ sao' "t.~~\ 'ot.\()~ ~~ ~ ø~~~t: F~~~C;~. ,", ~ ~~f(O~~ c-~~~ ~\\.t)~~ ~~ ~~ ~o.~~ ~ ~~~c~-\~ ~~\.\ ~~\~~~~(t.~~~ ~'-'Cè~~~'~~ \ 0 \S'. ~ ~ ~ <...1;::)" ~ \ . (\ ; ~Cè. -\-~ ~ \\.~" It-O-\- ~ ~~~<t:cJ c?-Ð þ., ~ ~ &. S , ~ ç' <..~ '> ~ o.\"o~~ -\-~ ~1t"'~'I\.'\. ~ ?~'-.:)"'~~ ~~ t)ð\\<::":'~ ð~~ ~F . c...\.ö.~Q: ~ c.... '---' ~ ~ ~ ~ ~ ~ ~ '.) '\ ~ ') c... ~ 'ð ~ V ~ > ~ C)..~ ~~~ \, J:: ~LÐ ~~ ~fctJ~ \-- Á!- ~~ <6 b ~-O\ \, '" Field: Milne Point Well: 1-11 ML DIRECTIONAL LWD OPEN HOLE LOGGING NONE ( SP EXPLORATION Milne Point Unit 1-11 & 1-11 L 1 Actual Surface Location: 2343' FSL 3966' FEL EOL BHL OA:676' FSL 674' FWL See 31 T13N R10E EOL BHL OB:576' FSL 674. FWL See 31 T13N R10E FORMATION DEPTH MD NONE 108' 108' Top of Lead Cement Surf Surf NONE Base of Permafrost 1,947' 1840' Bit #1 - Dir/GR Bit #2: Dir/GR/PWD/Res 2,795' 2,300' Top of Tail Cement 8,821' 3,295' TVD TOC Top of N sand 9,821' 3460' --.-..- .-..-..-..-..-..-.. ..- .-.. Dir/PWD/Res ABI/ABGR NONE OA sand 10,439'~ 3,609'- 13,190' 3,601' .-..-..-..-..-..-.. ..- .-.. , ... , " "'- D'irlPWõ'tRås - .-..-.. ..-..-..-.. ..- .-.. .. ABI/ABGR NONE 11,077'- 3,711'- 13,196' 3,661' .-..-.. ..-..-..-.. ..- .-.. ..-..- 8/23/01 TOC HOLE SIZE 13-1/2" ~ . .: ,'~I!;!',!;:F'-<,,~, I'~I f~'~;r,"I\""'H¡I,I,I"", I '1"~~¡,;'~;,1,'4""";)"1',,, 1):-,';¡~\n:'("J~"'-~ -"':'¡"~I i~:\';,',_,'~~ ,', I:!; .' , "1 RDIU .PILIIIA ..WIIG & _lLS ENG: Steve Campbell RIG: Nabors 22E MSL 34.7' RKB: 64.7' CASING SPECS 30" 20" 91.5#, H-40 Welded MUD INFO PIT INFO N/A 9.0 ppg 6-1/8" Hole - 4-1/2", 12.6#, L-80 Slotted Liner 10-314" 45.5# L-80 BTC 9-7/8" Production Casing 7" 26# L-BO HYDRIL 521 INFORMATION Wellhead FMC Gen 5 20" x 11" 5M Cameron 3", 5K KOP #1 @ 250' - 1°/100' KOP #2 @ 650' - 2°/100' KOP #3 @ 901' - 3°/100' KOP #4 @ 2086' - 6°/100' EOB @ 2796' 7000' MD @ 80.5° Tangent MW::: 10.0 Land 7" Csg @ 90° 6-1/8" Hole - 4-1/2", 12.6#, L-80 Slotted Liner MPI-11ML WBD21.xl$ If ~V~VŒ (ID~ ~~~~[(~ ( ¡¡ l AlAS IiA 0 IL AND GAS CONSERVATI ON COMMISSION TONY KNOWLES, GOVERNOR 333 w. "JTH AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Patrick Archey Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Milne Point Unit :MPI-ll BP Exploration (Alaska) Inc. Permit No: 201-137 Sur Loc: 2343' NSL, 3966' WEL, SEC. 33, TI3N, RI0E, UM Btmhole Loc. 571' NSL, 578' EWL, SEC. 31, T13N, RI0E, UM Dear Mr. Archey: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional pennits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Pennit to Drill application for Milne Point Unit MPI-ll. 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. Sincerely, ~~ . -t\,~ , U-e-£{,/Y}(?~ Julie M. Heusser Commissioner - BY ORDER OF THE COMMISSION DA TED this "2--1 <"'- day of July, 2001 jj c/Enc1osures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. (' STATE OF ALASKA ~' ALAS".. JIL AND GAS CONSERVATION cOJIlVIISSION PERMIT TO DRILL 20 AAC 25.005 k~~ 1 a. Type of work 181 Drill 0 Redrill 1 b. Type of well 0 Exploratory 0 Stratigraphic Test 181 Development Oil 0 Re-Entry 0 Deepen 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 2. Name of Operator 5. Datum Elevation (OF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Planned KBE = 64.7' Milne Point Unit 1 Schrader 3. Address 6. Property Designation Bluff P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025517 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2343' NSL, 39661 WEL, SEC. 33, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number 900' NSL, 2670' EWL, SEC. 31, T13N, R10E, UM MPI~11 Number 2S 100302630-277 At total depth 9. Approximate spud date 571' NSL, 578' EWL, SEC. 31, T13N, R10E, UM 08/01/01 Amount $200,000.00 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVO) ADL 025628, 571' MD No Close Approach 2560 13197' MD /3661' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 250' MD Maximum Hole Angle 0 Maximum surface 1245 psig, At total depth (TVD) 3714' 11672 93.6 psìg 18. Casing Program Specifications Setting Depth Ouantitv of Cement Size Too Bottom Hole Casino Weiaht Grade Couolina Lenath MD TVD MD TVD (include staae data) 3011 20" 91.5# H-40 WLD 78' 30' 30' 108' 108' 60 sx Arctic Set (APprox.) 9-7/8" 7" 26# L-80 Hvdril 521 11047' 30' 30' 11077' 3711' 1114 sx PF 'L', 794 sx Class 'G' 6~1/811 4-1/2" 12.6# L-80 IBT-Mod 2220' 10977' 3708' 13197' 3661' Uncemented Slotted Liner 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate RECEIVED Production Liner JUL 1 0 2001 Perforation depth: measured Alaska Oil & Gas Cons. Commission Anchorage true vertical 20. Attachments 181 Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 181 Drilling Program a Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements ConœctEngmeerNamelNumbe~ Robert Tirpack, 564-4166 Prepared By Name/Number: Sandra Stewman, 564-4750 21, I hereby certify that the foregoing is true and CO2 to the best of my knowledge '7/9/0/ Signed r,d"W'\Gk År(.l.,ey-Pi al ...- Title Senior Drilling Engineer Date '- ' " , '/ ", "" " " ' , , " " ',,:Cbtrlmissi()n:UseQ'hly> Permit Num,~ /' API Number ~~ ~v II: ~Je} See cover letter 20/- J 50- 0 z <t - 23033 for other reQuirements Conditions of Approval: Samples Required DYes ~No Mud Log' ~qufçé'1 ( DYes 8 No Hydrogen Sulfide Measures DYes &:I No DirectionAl Survey Required ÆI Yes 0 No Required Working Pressure for BOPE D2K D3K D4K D5K D10K 0 15K VJ.3'5~PSi~ -.':- Other: by order of Date 1 ¡iX 1 /¡f) Approved By ;:-"",~ Commissioner the commission Form 1 0-401 Rev. 12-01-85v~ -,."".- ,j R;\\Y spt mit I~ '-triplicate J. M. Hausser ORIGINAL ( ( MPI-11 Drilline Permit 1. Well Plan Summar'l ¡Well Name: I MPI-11 l.!ïPe of Well (producer or injector): I Schrader Bluff Multilateral producer - Lower leg Surface Location: 2343' FSL, 3966' FEL, Sec. 33, T13N,R10E X = 551,405.11 Y = 6,009,456.78 1-11 Target: 900' FSL,2670' FVVL,Sec.31,T13N, R10E X = 542,220.46 Y = 6,007,956.92 Z = 3646' TVDss 1-11 Target (Bottom Hole 571' FSL, 578'FVVL,Sec.31,T13N,R10E Location): X = 540,129.71 Y = 6,007,616.10 Z = 3596' TVDss l!!!s.J Nabors 22E I I Estimated Start Date: I~ust 1, 2001 I I MDrkb 113197' I I TVDrkb (TD) 1 3661' I I KOP: I 250' I 30 I 64.7' I I I ~eratin~s to complete: I Max. Inc. 193.6° I I KBE: I I Well Desi~(conventional, slim hole, etc.): I Multilateral Producer ~e: I Drill and Complete a Multilateral Producer in the Schrader Bluff OA and OB sands. (' (' MPI-11 Drilling Permit 2. Current Well Information 2.1 General Well Name: MPI-11 API Number: Well Type: Current Status: BHP: BHT: MPI-11 Development - Schrader Bluff Multilateral Producer - lower leg Conductor Set 1672psi @ 3714' TVDrkb - 8.65 ppg - Schrader Bluff OB Sands. 80°F @ 4020' TVDss Estimated (SOR) 2.2 Current Mechanical Condition MPI-11 : Nabors 22E: Conductor: 2.3 Target Estimates Estimated Reserves: Expected Initial Rate: Expected 6 month avg: Cellar Box above MSL = 34.7' KB = 30' 20", 92 Ibltt, H-40 Welded set at 78' MD 1.6MMBBL 3000 BO P D 1493 BOPD 2 ( (' MPI-11 Drilline Permit 3. Drillinq Hazards and Contin~encies 3.1. Well Control MANDATORY WELL CONTROL DRILLS: Drill 01 02 03 04 05 Type Tri in Orillin Oiverter Accumulator Well Kill Comments Conducted onl inside casin . Either in cased or 0 en hole. 00 NOT shut-in well in 0 en hole. N/A A rox. eve 30 da s, thereafter at convenient times. Prior to drill out the intermediate and production strings. Never car out this drill when 0 en hole sections are ex osed. 3.2. Hydrates 3.2.1. Hydrates are not expected. However, 1-05 experienced 'gas cut' mud at the base of the permafrost. Mud weight was raised and no additional problems were reported. In addition, hydrates have been encountered on Hand E Pads. Mud returns should be monitored to determine if hydrates are encountered on this well. 3.3. Kick Tolerance 3.3.1. With the 7" casing set into the Schrader Bluff OB reservoir, the kick tolerance for the 6-1/8" horizontal open hole section is infinite assuming an influx at 13,197' in the Schrader OB formation. This is a worst case scenario based on a 8.7 ppg pore pressure gradient in the top of the production section and a minimum fracture gradient of 12.0 Ib/gal at the 7" casing shoe with a 9.1 ppg mud in the hole. 3.4. Lost Circulation 3.4.1. Lost circulation has not been encountered while drilling these intervals on previous I-Pad wells. 3.4.2. Follow the LOST CIRCULATION DECISION MATRIX in the well plan if fluid losses occur while drilling. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. 3.5. Unexpected Pressures 3.5.1. It is unlikely there will be unexpected overpressure when drilling to the Schrader Bluff formation. This well is in an undrained fault block with no offtake or injection support. Reservoir pressure is expected to be 1672 psi (8.65 Ib/gal). In this well, the Schrader Bluff formation will be drilled with 9.2 ppg mud. 3.6. Stuck Pipe 3.6.1. The MPI-11 directional plan has a 7000' MD interval of high angle (80.5°) in the surface hole with 12500 feet to drill for each lateral in the OAfOB sands. All these hole intervals have massive permeable sand intervals, which can lead to differential sticking of the drill string. Good drilling practices to avoid differential sticking are required in all hole sections. Minimum mud weights and proper mud properties as outlined in the Baroid mud program must be closely followed. 3.6.2. Wells 1-01, 1-02, 1-03, and 1-05 have experienced tight hole situations around the base of the 3 ( ,{ ( MPI-11 Drillin~ Permit permafrost. Additional reaming runs have been required through this section on other I-Pad wells. Be prepared for tight hole in 1-11. Short trip as necessary to keep the hole clean. Monitor trends, mud properties and hole cleaning. 3.6.3. Good drilling practices to avoid differential sticking are required. Minimum mud weights and proper mud properties as outlined in the M-I mud program must be closely followed. Stuck Pipe: Go immediately to SURE manual, determine stuck pipe mechanism, follow recommendations in the SURE manual. DO NOT JAR UP if packed-off! 3.6.4. There is a risk of differentially sticking the 4 ¥2" slotted liners. The 9.2 Ib/gal mud will be 0.55 Ib/gal overbalanced to the 8.65 Ib/gal OAlOB sand reservoir pressure (106 psi differential pressure @ 3714' TVD). The liner should be kept moving as much as possible while running in the open hole. In order to combat differential sticking, solid stand off centralizers will be run on the liner (two per joint) to ensure the casing will not contact the wellbore wall and allowing the casing to become differentially stuck. 3.7. Pad Data Sheet 3.7.1. Please Read the I-Pad Data Sheet thoroughly. 3.8. Hydrocarbons 3.8.1. Hydrocarbons will be encountered in the Ugnu and Schrader Bluff intervals. 3.9. Hyrdrogen Sulfide 3.9.1. MPI Pad is not designated as an H2S Pad. Listed below are the latest H2S readings from I-Pad Wells: Well Number Well T e Ma , 2001 2 SBF Prod <2.00 m 3 SBF Prod <2.00 m 4 SBF Prod <2.00 m 5i SBF In' <2.00 m 6 SBF Prod <2.00 m 7 SBF Prod <2.00 m 8 SBF Prod <2.00 m 3.10. Faults 3.10.1. The directional plan has been specifically built to cross Fault #1 in the Ugnu formation. This fault should not be crossed in the Schrader Bluff NA sand. The high tangent angle (80.5°) allows the MPI-11 wellpath to sail over top of the SB NA sands while crossing the fault. If the wellpath starts to fall behind the directional plan, corrections must be made before 9827' MD 1 3461' TVD. After this fault is crossed, start to drop angle according to the directional plan in preparation for the landing the 9-7/8" hole in the DB sand. See attached geologic and Seismic cross section. There is no history of lost circulation when crossing faults in the Ugnu formation in this area. Number Formation MDKB TVD KB Throw Direction Comments #1 Ugnu 9200' 3359' 210 East Definite #2 - OA Schrader OA 11200' 3650' -20 East Probably not, but possible #3 - OA Schrader OA 13000' 3603' -25 West Probable #2 - DB Schrader DB 11200' 3711' -20 East Probably not, but possible #3 - DB Schrader DB 13000' 3665' -25 West Probable 4 (' (' MPI-11 Drillin!¡l Permit 4.0 Drillinq ProQram Overview 4.1. Surface and Anti-Collision Issues Surface Shut-in Wells: No wells need to be shut-in for the rig move on and off MPI-11 Close Approach Wells: There are no close approach wells Well Name Cu rrent Production Precautions Status Priority N/A N/A N/A N/A 4.2. Well Control Expected BHP 1672 psi @ 3714' TVDrkb estimated BOPE Ratin 135/8" 5M Planned BOPE Test Pres. Rams & Valves: 3500 psi/250 psi Annular: 2500 si 1250 si 4.3. Mud Program 9-7/8" Surface Hole Mud Properties: Spud - LSND Freshwater Mud Density 1 .\ Funnel visc YP HTHP pH API Filtrate LG Solids 9.0- 9.2 45 -150 18 - 40 N/A 9.0- 9.5 <5 < 6.0 6-1/8" Production Hole Mud Properties: CAleB KCI-CaCO3 Baradril N Density 1___\ Funnel visc YP HTHP pH API Filtrate LG Solids 9.2 40 - 55 22 - 27 <10 8.0- 8.5 4-6 ALAP LCM Restrictions: No Organic LCM products in the Schrader Bluff formation Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1 R. 5 {' " ( MPI-11 Drillin~ Permit 4.4. Formation Markers Formation Tops MDKB TVD KB Est. EMW I .\ Comments Base Permafrost 1947' 1840' 8.65 Top Ugnu 8326' 3214' 8.65 Top Ugno M 9335' 3380' 8.65 Top SB NA 9821' 3460' 8.65 Top SB NB 9967' 3489' 8.65 Top SB NC 10098' 3522' 8.65 Top SB NE 10168' 3540' 8.65 Top SB NF 10352 3587' 8.65 Top SB OA 10489 3622' 8.65 Top SB C (Base OA) 1 0632' 3658' 8.65 Top SB B-OB 10812' 3692' 8.65 Top SB A5 (Base OS) N/A 3717' 8.65 TD OA Lateral 13190' 3601' 8.65 TD OB Lateral 13197' 3661' 8.65 4.5. Casing Program Hole Size Csg WtlFt Grade Conn Top Bottom Length Drift ID O.D. MDKB MDKB 30" 20" 91.5# H-40 WLD 30' 108' 78' 19.124" 9-7/8" 7" 26# L-80 Hydril 521 30' 11,077' 11047' 6.151" 6~1/8" 4-1/2" OB Lateral Slotted 12.6# L-80 IBT -Mod 10,977' 13,197' 2220' 3.833" Liner* * \In' Every 10 Jt will be unslotted, solid liner. 4.6. Cement Calculations Surface Interval- Shoe Depth 11077' MD KB Design Basis 80' Shoe jt; 50% excess in open hole; 250% excess in permafrost (12-1/4" open hole) , cement to surface Design Temp BHST -800 F from SOR, BHCT 650 F estimated by Halliburton Volume Wash 50 bbls fresh water; 8.4 ppg; 6 BPM Spacer 75 bbls Hivis Alpha Spacer; 10.2 ppg; 6 BPM Lead Slurry 823 bbls Permafrost L; 10.7 ppg; 8 BPM Tail Slurry 163 bbls Tail; 15.8 ppg; 6 BPM Displacement 4201 bbls LSND mud; 9.6 ppg; 8 - 2 BPM Notes Place dye in Alpha spacer. If dye comes back early, continue with programmed cement job. If dye is late, pump additional Lead Slurry until dye is seen in the returns, then continue with program. Lost Circulation Finish pumping entire cement program. RIH with inner string and Port Collar shifting tool. Engage port collar and pump secondary cement job to obtain cement to surface. See attached TAM Procedures. 6 { (, MPI-11 DrillinfJ Permit Accessories . 7", 26#, Hydril 521 Reamer float shoe . 7", 26#, Hydril 521 float collar . 7", 26# wiper plug . Radioactive casing tag for marking OA Top . (26) Straight Blade Rigid Centralizers - 7" X 9-5/8" . (26) Stop Collars for Straight Blade Rigid Centralizers . lU TAM Port Collar Production Interval- Shoe Depth N/A Design Basis N/A Design Temp N/A Volume N/A Notes The 4-1/2" slotted liner placed in the DB Lateral will not be cemented. Lost Circulation N/A Accessories DB Lateral 94 Straight Blade Rigid Centralizers - 4-5/8" X 5-3/4" X 8" 47 Stop Rings 4.7. Survey and Logging Program Surface Hole - First Bit Run Drilling: Dir 1 GR 1 PWD Open Hole: None Cased Hole: NI A Surface Hole - Second Bit Run Drilling: Dir 1 GA 1 PWD 1 Res Open Hole: None Cased Hole: None Production Hole Drilling: Dir 1 PWD 1 ABI 1 ABGA 1 Res Open Hole: None Cased Hole: N/A NOTE: IFA, CASANDAA, and Insite Anywhere required at all times. 7 l . .~ :( MPI-11 DrillinQ Permit 5. MPI-11 Operations Summar'l 5.1. Pre-Rig Operations 1. 2. Grade and level pad. Install 20" Conductor. 5.2. Procedure 1. 2. 3. 4. 5. MIRU, NU and function test diverter on 20" conductor. PU 5" drill pipe. Drill 9-7/8" surface hole as per directional plan. Maximum tangent angle 90° Condition mud with lubes and spot casing running lube pill in openhole. POOH laying down 5" DP. Run and cement 7" casing from TD to surface. TAM Port Collar @ 1000' as contingency should cement not reach the surface. 6. ND Diverter. 7. Install FMC 11" 5M wellhead. 8. N/U and test 13 %" 5M BOP. PU 3-1/2" DP. 9. Drill 6-1/8" OB horizontal production hole as per directional plan. 10. Run 4-1/2" slotted liner with 2~7/8" inner sting and hang off 100' inside 7" casing. 11. Continue with MPI-11 ML Drilling Permit/Procedure. 8 5 pe"""" y - 5U .., DRILLING seRVIc:es A Halliburton Company Milne Point Unit Alaska Drilling & Wells Proposal Data for MPI-11 WpO5 Vertical Origin: Wen Hoñzonlal Oñ¡jn: Wen MeasuremenlUnils: ft North Reference: True North Dogleg seveñty : Degrees per 100 feel (US) Vertical Section Azimuth: 261.123" Vertical Section Descñplion:Wen Vertical Section Origin: 0.00 N,O.oo E Measured Incl. Azm. Vertical Northings Eastings Vertical Dogleg Depth Depth Section Rate 0.00 OJ)OO 0.395 0.00 O.OON O.OOE 0.00 250.00 0.000 0.395 250.00 O.OON O.OOE 0.00 0.000 650.00 4.000 245.000 649.68 5.905 12.65W 13.41 1.000 901.36 9.000 250.000 899.34 16.335 39.09 W 4U4 2.000 1875.37 38.000 261.310 1783.36 89.285 415.25 W 424.06 3.000 2086.84 38.000 261.310 1950.00 108.95 5 543.95 W 554.25 0.000 2795.71 80.532 261.309 2304.01 198.925 1132.53 W 1149.66 6.000 9827.50 80.532 261.309 3460.70 1247.00 5 7988.89 W 8085.62 0.000 10005.65 75.187 261.299 3498.15 1273.325 8161.00 W 8259.73 3.000 10589.14 75.187 261.299 3647.33 1358.66 5 8718.60 W 8823.83 0.000 11050.96 89.000 260.210 3710.70 1432.05 5 9168.97 W 9280.13 3.000 11076.49 89.763 260.144 3710.98 1436.41 5 9194.13 W 9305.66 3.000 11708.11 89.763 260.144 3713.58 1544.525 9816.42 W 9937.18 0.000 11764.18 90 . 000 261.810 3713.70 1553.315 9871.80W 9993.25 3.000 11884.50 93.607 261.931 3709.91 1570.315 9990.83 W 10113.48 3.000 12349.10 93.607 261.931 3680.68 1635.405 10449.91 W 10577.11 0.000 12442.85 91.260 260.380 3676.70 1649.805 10542.46 W 10670.77 3.000 12476.65 91.215 261.393 3675.97 1655.155 10575.82 W 10704.55 3.000 13196.92 91.215 261.393 3660.70 1762.925 11287.82 W 11424.66 0.000 Begin Di, @ 1.000./10011 : 250.00II MD, 250.00ft TVD 0 : 2086.84ft MD, 1950.00ft TVD Di, Rale I"",ease @ 2.000"/100ft : 650.00ftMD,649.68ftTVD Di, Rale I""'ease @ 3.ooo"/100ft : 9O1.36ItMD,899.34ftTVD ;; 1500 a. Q) 0 -æ (,,) t Q) > Erd Di', Star! Sail @ 80.532": 2795.71ftMD,2304.0IftTVD 200.00 .00 .00 600.00 3000 -= 0 0 IJ) .... II .c u .S åi ~ 4500 ( ) 0 Scale: 1 inch = 1500ft DriliQuest 2.00.09.001 1500 3000 Milne Point MPI MPI-11 WpO5 DrillQuest~ Single wen Ta,get Data for MP '11 WpOS M9asu-erroer-i Ltils: " Coord.lo Torgo! - 1VD 1VDoo Nort '*>go EM'" Nort... E..Ungo Torgo! - Typo ASPY ASPX Shope ~ß'~II DrlrPoly Fntry Poi.. 3710.70 3646.00 6OO796U7 S 5-<22~6,2J E IH2,O~ S 9168'17 1'1 "ol)yon Bo<n<bry Point A 3710.70 3646.00 6OOKlB.OOS ~428~HO E I22UI S 8~~9.76 1'1 B 3710.70 3646.00 60081>4 1.00 S 5-<1773.00E IH9.36S ')641.64 1'1 C 3710.70 3646.DO 6OO798~.00 S 5-<0767.00 E 139OA2 S 106".001'1 D 3710.70 3646.00 6OO793~.00 S 5-<0167.00E 14.~.1. S 11148."1'1 E 3710.70 3646.00 6OO7612.00S 5-<0127.00 E 1167.69S 111'JO.~6W F 3710.70 3646.00 6007706.00 S ~.081LooE 1677.79 S IOJ9.'"", 1'1 G 3710.70 3646.00 6001763.00 N 5-<IY2J.ooE 16176'JS 9~9L'6 1'1 H 3710.70 3646.DO 6OO1712.00N 5-<1020.00 E I 686.1.1S 8096.931'1 !&~II <koPol)' Entry Poi.. 3710.70 3646.00 6OO796U7 N 5-<22.6.2J E 1.J2.0~ S 9168'17 1'1 I'ul><-,'" Bo<n<bry Point A 3710.70 3646.00 6008270.00 S 5-<2'))~.00 E 1128.16S 8479.001'1 B 3710.70 3646.DO 6OOW72.IO S 5-<0129.71 E 1306,9) S 1121""81'1 C 3710.70 3646.00 6OO7616.ION 5<0129.71 I; 1762.')1 S 11287-"21'1 D 3710.70 1646.00 6007616.10 S 5<3000.00 E 1182-70S 8"71001'1 ~ß'~II 11 Fntry. Poi.. J-I60.70 ))96.DO 6OO81~O~ N qH2~,OOE 1141.00 S 7908.8') 1'1 "uin! ~ß'~II12 Fntry Poi.. 3710.70 3646.00 6OO796L~7 N ~022.6.n E 1.J2.0~ s 9168!J7 1'1 Po," ~ß'~II 1'3 Fntry, Poin< 3713.70 3649-00 6OO783H6 S 5< 1 ~H.2,' E I~H.)I S 987L'O 1'1 po"" ~ß'~ II T4 Fntry. Poin< 3676.70 3612.00 6OO17H.3~ S 5<0K7'-27E IMHOS IO,14H6W "oi.. ~ß'~II s<wm fnlryPoin< 3660.70 H96.DO 6007616.10 S ~40129.71 E I 762.'!1 S 11287.811'1 Po." ~~ MPI-11 WpO5 Formations Measured Vertical Sub-Sea Depth Depth Depth Formation Name (It) (ft) (It) 1946.87 1839.70 1775.00 Base Pennafrost 8325.93 3213.70 3149.00 Top Ugnu 9335.08 3379,70 3315,00 Top Ugnu M 9821.42 3459.70 3395.00 Schrader NA 9967.21 3488.70 3424.00 Schrader NB 10097.75 3521.70 3457.00 Schrader NC 10168.16 3539.70 3475.00 SchraderNE 10352.00 3586.70 3522.00 Schrader NF 10488.90 3621.70 3557.00 Schrader OA 10631.49 3657.70 3593.00 TSBC (base OA) 10812.30 3691.70 3627.00 TSBB-OB Current Well Properties Well: Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure Reference: Ref. Geographical Coordinates: RKB Elevation: MPI-11 Wp05 6009456.78 N, 551405.11 E 330.38 S, 772.84 W 70026' 11.7158' N, 149034' 51.1850. W 64.7OfI above Mean Sea Level 64.7Oft above Structure Reference North Reference : Unils: True North Feet (US) pproved Well Design ,!J!'!-¡] TI ,UtdN liT> !~4!.'lf'-'. 798,'.8'1 If ~Q Q <::,~ ~.f ,AQ I':> .# ".' ~. #' ~"'ß "'.:tl':> nJ' ":f' " - <::,' ~'P' .:.~' .". ,p. .;<> 4' ,-"..' o.!> ~ ~. ,- ~. ,po , ~ -#' " #",;:-' .:" ,l' ,.$';.f' $" ,¡>,?' ,8 ,.' ~.. ,~ .,.." ,~" .ø # ,4 h' / ,<f' ",- "" ~.' ~<' .< ". '" ,~ .,'. .,'. " -, ... . .' .. ...'¡" .' . ... ,. <# # . ,0" ,,' " ,# "," or .,' ... .,' o' "" " ,,¡'." "" '" <f .:" ~... .#' . ".'" ~~ .~ "f'" "',þ' . . "'. <J'. <J' ",'.$' .--- , e <Ý .- 0" v. .. . f / "// 1'ò0~~bQ~' "èçfif .0() / Ij / ~;20000 L. ~ ' "-"0. 00.00 200.00 .00 .00 r Casi1g 11077.14ftMD 3710.981\ TVD ,'--... 4112"Li'1e, ~13196.92ItMD 3660.7011 TVD 11/'1-11 v,.' II> .I^t"-¡,¡n'l> liPI.UTI 1'^2.92s.1I~\',,\"" .;t;t.;" 11"/1 I"I?,,<"'. ¡"5;:.;" II 4500 6000 Vertical Section 7500 9000 10500 Section Azimuth: 261,123° (True North) 5 peI'""I"'" \/- 5U" DRILLING seRVIc:es A Hamburlon Company en C> .!: ..r:::. t 0 Z -1500 .::: 0 0 LO ,.... II ..c: 0 .S ¡¡¡ -3000 c;¡ 0 (f) DrillQuest 2.00.09.001 Milne Point Unit Alaska Drilling & Wells Milne Point MPI MPI-11 WpO5 DrillQuest~ Proposal Data for MPI-11 WpO5 ~~o~~"8~~: Well Well Measurement Units: ft North Reference: True North Dogleg severity : Degrees per 100 feet (US) Vertical Section Azinuth: 261.123. Vertical Section Description:Well Vertical Section Origin: 0.00 N,O.oo E Messured Incl. Azlm. Vertical Northlngs Easllngs Vertical Dogleg Depth Depth Section Rale 0.00 0.000 0.395 0.00 '.'J -.; O.OOE 0.00 250.00 0.000 0.395 250.00 ,.",-.; O.OOE 0.00 0.000 650.00 4.000 245.000 649.68 - .., 12.65W 13.41 1.000 901.36 9.000 250.000 899.34 I'. ., , 39.09 W 41.14 2.000 1875.37 38.000 26\.310 1783.36 ," '" 415.25 W 424.06 3.000 2086.84 38.000 26\.310 1950.00 ¡;. ,., 543.95 W 554.25 0.000 2795.71 80.532 261.309 2304.01 ,""'" 1132.53W 1149.66 6.000 9827.50 80.532 261. 309 3460.70 1" . OJ" 7988.89 W 8œ5.62 0.000 10005.65 75.187 261.299 3498.15 ."" , 8161.00 W 8259.73 3.000 10589.14 75.187 261.299 3647.33 . .-.,. , 8718.6OW 8823.83 0.000 11050.96 89.000 260.210 3710.70 ,'.."., 9168.97 W 9280.13 3.000 11076.49 89.763 260.144 3710.98 I' ."- II ' 9194.13 W 9305.66 3.000 11708.11 89.763 260.144 3713.58 I ". , 9816.42 W 9937.18 0.000 11764.18 90.000 261.810 3713.70 I"" '1' 987I.80W 9993.25 3.000 11884.50 93.607 261.931 37œ.91 I- ,- 'I , 9990.83 W 10113.48 3.000 12349.10 93.607 261.931 3680.68 ."" '--, 10449.91 W 10577.11 0.000 12442.85 91.260 260.380 3676.70 ',,"-.- , 10542.46 W 10670.77 3.000 12476.65 91.215 261.393 3675.97 ,.',' I', 10575.82 W 10704.55 3.000 131%.92 91.215 26 \.393 3660.70 , .,", 11287.82 W 11424.66 0.000 Single Well Target Data for MPI-11 WpO5 Meas..ement Urils: II Coordlna1e Target Point TVD TVDss Northlngs Ea81lngs Northlngs Ea81lngl Target Name Type ASPY ASPX Shape MPI-ll Drlr Poly Entry Poin! 3710.70 3646.00 6007%1.57 N 542246.23 E 1432.0.~ S '1IM.97W Polygon Bourxlary Poin! A 3710.70 3646.00 6008173.00 N 542854.00 E 1224.81 S 8~5'1.76 W B 3710.70 3646.00 6008041.00 N 541773.00 E 1349.36 S 964I.64W C 3710.70 3646.00 6007985.00 N 540767.00 E 1398.42 S IOM8.00W 0 3710.70 3646.00 6007934.00 N 540167.00 E 1445.28 S 11248.34 W E 3710.70 3646.00 6007612.00 N 540227.00 E 1767.1>9 S 11190.56 W F 3710.70 3646.00 6007706.00 N 540821.00 E 1677.79 S 10595.93 W G 3710.70 3646.00 6007763.00 N 541823.00E 1627.1>9 S 9593.56 W H 3710.70 3646.00 6007712.00N 542920.00 E IM6.25 S 8496.93 W MPI-tl GeoPoly Entry Point 3710.70 3646.00 6007961.57 N 542246.23 E 1432.05 S 'IM.97 W P"ly!,->n Bourxlary Poin! A 3710.70 3646.00 6008270.00 N 542934.00 E 1128.36 S 8479.O'J W B 3710.70 3646.00 6008072.10 N 540129.71 E 1306.93 S 11284.M W C 3710.70 3646.00 6007616.10 N 540129.71 E 1762.92 S 11287.82 W 0 3710.70 3646.00 6007616.10 N 543000.00 E 1782.70S 8417.60 W MPI-ll TI Entry Point 3460.70 3396.00 6008154.75 N 543425.00 E 1247.00 S 7988.89 W Poin! MPI-11TI Entry Point 3710.70 3646.00 6007961.57 N 542246.23 E 1432.05 S 9168.97 W P"in! MPI-II 1"3 Entry Point 3713.70 3649.00 6007835.46 N 541544.25 E 1553.31 S 9871.80 W P"in! MPI-ll T4 Entry Point 3676.70 3612.00 6007734.35 N 540874.27 E 16.1'1.80 S 10542.46 W Poin! MPI-11 NewID Entry Point 3660.70 3596.00 6007616.ION 540129.71 E 1762.92 S 11287.82 W Poi.. ~~, d II .. ppr V esign -12000 -10500 -9000 -7500 -6000 ~ 1500 -4500 -3000 -1500 0 0 -3000 1500 Begin Dj, @ 1.000"10011 ; 250.OOIt MD, 250.0011 TVD Dir Rale Increase @ 2.000.'10011 ; 650.OOItMD,649.68ftTVD [Ñ Rale Increasa @ 3.000"1100II ; 9O1.3611MD,899.34tITVD Erd of BLiId - 1875.3711 Begin Oir @ 6.000."0011 : 2086.8411 MD, 1950.0011 TVD Erd Dir, S1art Sail @ 80.532' : 2795.71ftMD,2304.01ftTVD ""' (j) (f¡ ~ (,) .... ~ 0 Q q¡ r: ::¡ ~ q, -J 0 ~'- 2400.00 2600.00 2800.00 .00 MP¡.11 V/pOS .00.00 Mi'l-I!f1 -1500 Current Well Properties MPI-11 Wp05 6009456.78 N, 551405.11 E 330.38 S. 772.84 W 70' 26'11.7158. N,149' 34' 51.1850. W Lease Line: DO NOT CROSS!!! Well: Horizontal Coordinates: Ref. Global Coordinates : Ref. Structure Reference : Ref. Geographical Coordinates : RKB Elevation: 64.7Oft above Mean Sea Level 64.7Oft above Structure Reference ,!!i'!.¡¡;\,...TlJ -'7i!J.7IJTHJ U.;].85 -'. 9[b,~.97;j' 366'1.70 tl'l> iS53..>! .'. 'lh";U;,'!'" i 76:.'1: s. lJlxi."" it' North Reference: Units: True North Feel (US) -12000 Scale: 1 inch = 15000 -10500 -9000 -7500 -6000 Eastings -4500 -3000 -1500 0 Reference is True North 07/24/01 TtŒ 05:31 FAX 907 "pR" 4441 l@UU1/UUJ t .. ~ .,..'1"'" ,/'. ¡"\'~~I,¡,t\..II"',,""~'" .' , ,'I¡\ 11,1 'r. '~, "11 ,J':~1b.h,¡\~J\~:~¡'i, ;¡, ,~itl: I¡;¡¡~ "'" ",~-::a1 :- ;~b~:('.. " ::, .. "\~, , . , ,.' ' \ II . ',.'\', I ROlli BP~IIBBWUN8&MŒUS TO: Jane Williamson DATE: 7/20/01 COMPANY: Alaska Oil and Gas Conservation Conunission FAX: 276- 7542 PHONE: FROM: James Franks - FAX: (907)564-4441 PHONE: Ii (90])564- 4468 " ' , " , ,I MESSJ;\GE:; i ~ fT"W l..\: L '" , ' : . Attaøh,ed tb:this ~~~~r sh'~~t.ar~ d~awlngs fÓr.:'th~ MPG-1:4,:andMPI:~t1 JV'ultilat.~ral W~U,~ as wê':pian to compl~te the:m. ' ' " :1', '; , :"', I " ' " , . "" I' I ' , 'II "I :~' : , ' , 'i . ' '::, : ~ Ii' : I ",;' I,' ," ' , T"",anks! ',',' Ii "I' I , I,.! . , ii , " , , p r.;- r ! , ' 9""~) JUL 2 4 2001 ~ loll! 6 uas Cons. C~ Anchorage , ' Number of attachments not including fax cover: 2 07/24/01 TUE 05: 32 FAX 907 564 4441 t"'KUt""U~t:U vUIVIt"'U:: I lVI'll TRËE: Cameron 3", 5M J I 11 L1 WELLHEAD, FMCGen6,11",5M \. MPI-11 & - 108.MOI 20" 92 Iblft. H-4D Welded 7", 26#, L-80. Hydril 521 Casing Drift: 6.151" Casing ID: 6.276" Baker Hughes Hook Hanger system Level 3 Multi-Lateral Junction Window In 7" casing @ 10.427'-10,439' MD Wel1lncllnatlon @ Window;;: 80.4 Degrees Baker Hughes Conventional Hanger 7'1 Casing Shoe @ 11,077' MD Well Inclination @ Shoe = 89 Degrees DATE REV. BY COMMENTS 6/28/2001 RB Tlrpack Lovel 3 Multi-Lateral, 3-1/2" tbg with RPB \ " \ ""'--------------- ! , , " " oa HOl'izon'al ,j --~~-------------- 1 " .. . , 0 I I&J UU~I UUJ f "" K8. ELEV = 64.7' GL ELEV. 34." dol- !61 d-Ol-13~ I 150" 2.7/8" X 1" Gas Lift Mandrel 2-7/8", 6.3 Ib/ft. L-BO. EUE-M Coupling aD: 3.5" DriftllD: 2.34711/2.441" o. 2-7/8~ x 1" Gas Lift Mandrel r 1 0227. I X Nipple 2.313" ID RECEIVED Centrilift Electric s~si2e4'~1 11 0277. I AIasIca Oil:& Gas Cons. COmß}lSSIOl~ Anchorage r 1 0327" I Centrilift Pressure Gauge -~---------------, OA Horizontal 'I ~ - -- - - - - - - - - - - - - - _.~ - 6.1/8" OA Lateral 4-112" Slotted Liner and Hook Hanger 113,190' MD I 6.1/8" OB Lateral 4~1/2" Slotted Liner & Hanger 113,197' MD I Milne Point Unit WELL: MPJ.11 API NO: BP Exploration (Alaska) ~. f TREE: Cameron 3., 5101 WELLHEAD:FMCOen6."",SM PROPOSED COMPLETION MPI-11 & 1-11 L1 Ke. ELEV = 64.7' OLELEV=34.7' I 108' MD I 20. 92 Ibln, H.40 Welded 7",26#, L-80. Hydril521 Casing Drift: 6.151" Casing ID: 6.276" Baker Hughes Hook Hanger system Level3 Multi-Lateral Junction Window in 7' casing @ 10,427'-10,439' MD Wellinclination @ Window = BO.4 Degrees Baker Hughes Conventional Hanger 7' Casing Shoe @ 11,077' MD Wellinclination@ Shoe = B9 Degrees DATE REV. BY COMMENTS L8Ve13 Munl-Leter8l, 3-112M tbg with RPB 8/2812001 RB Tlrpack 2-718" X 1" Gas Lift Mandrel 150' 2-7/8",6.3 Ib/ft. L-80, EUE-M Coupling 00: 3.5" DriftllD: 2.347"/2.441" 2-718Mx 1" Gas LIft Mandrel 110227' I X Nipple 2.313.ID CentrUIft Electric Submersible Pump I 10277'1 Centrllm Pressure Gauge 110327' I -~--------------_. OA Horizontal --- -- --- - ----- ---,;. 113,190' MD I 6-1/B' OA Letera I 4-112. Slotted LIner and Hook Hanger \ " \ .-..--------------- ¡1 " , - OB Horizontal ----------------- RECE1'V.ED JUL 2 0 2001 Alaska OU & Gas Cons. commission ~ 6-1/8' 08 Lateral 4-1128 Slotted LIner & Hanger 113,197' MD I Milne Point Unit WELL: MPI-11 API NO: BP Exploration (Alaska) (ìR¡('!~lr! Milne Point Unit Alaska Drilling & I Milne p~l{! MPI-11~, ~i,"" ~ ~-- SAL REPORT 5 June, 2001 Surface Coordinates: 6009456.78 N, 551405.11 E (70026'11.7158" N, 149034' 51.1850" W) Kelly Bushing: 64.70ft above Mean Sea Level -~- 5pE!~V-5UI! DRIL-LING seAVIc:es A Halliburton Company Proposal Ref: pro9843 Milne Point Unit Measured Depth (ft) 0.00 100.00 200.00 250.00 300.00 400.00 500.00 600.00 650.00 700.00 800.00 900.00 901.36 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1700.00 1800.00 1875.37 1900.00 1946.87 2000.00 2086.84 2100.00 2200.00 2300.00 Incl. 0.000 0.000 0.000 0.000 0.500 1.500 2.500 3.500 4.000 4.990 6.979 8.973 9.000 11 .890 14.847 17.818 20.797 23.782 26.769 29.759 32.751 35.744 38.000 38.000 38.000 38.000 38.000 38.790 44.790 50.790 Azim. 0.000 0.000 0.000 0.000 245.000 245.000 245.000 245.000 245.000 246.789 248.843 249.988 250.000 253.553 255.752 257.231 258.299 259.110 259.749 260.268 260.700 261.067 261.310 261.310 261.310 261.310 261.310 261.310 261.310 261.310 Sub-Sea Depth (ft) -64.70 35.30 135.30 185.30 235.30 335.28 435.22 535.08 584.98 634.82 734.27 833.30 834.64 931.64 1028.92 1124.87 1219.24 1311.76 1402.17 1490.24 1575.72 1658.37 171 8.66 1738.07 1775.00 1816.87 1885.30 1895.61 1970.14 2037.30 Vertical Depth (ft) 0.00 100.00 200.00 250.00 300.00 399.98 499.92 599.78 649.68 699.52 :'?Ø8~t 8~ê.¡ $00. 996.34 1093.62 1189.57 1283.94 1376.46 1466.87 1554.94 1640.42 1723.07 1783.36 1802.77 1839.70 1881.57 1950.00 1960.31 2034.84 2102.00 Sperry-Sun Drilling Services Proposal Report for MPI-11 Wps - MPI-11 Wp05 Local Coordinates Northings Eastings (ft) (ft) O.OON 0.00 N 0.00 N 0.00 N 0.09 S 21.85 S 27.92 S 34.46 S 41.44 S 48.85 S 56.67 S 64.88 S 73.45 S 82.36 S 89.28 S 91.57 S 95.93 S 100.87 S 108.95 S 110.19 S 120.25 S 131.44 S 0.00 E 0.00 E 0.00 E 0.00 E 16.23 W 25.89 W 38.89 W 39.09 W 56.09 W 78.39 W 105.73 W 138.05 W 175.24 W 217.21 W 263.84 W 315.01 W 370.57 W 415.25 W 430.24 W 458.77 W 491.10 W 543.95 W 552.03 W 617.88 W 691 .06 W Global Coordinates Northings Eastings (ft) (ft) 09455.94 N 6009454.44 N 6009452.20 N 6009450.79 N 6009449.18 N 6009445.20 N 6009440.25 N 6009440.18 N 6009434.54 N 6009428.32 N 6009421.59 N 6009414.39 N 6009406.72 N 6009398.61 N 6009390.09 N 6009381.16 N 6009371.87 N 6009364.64 N 6009362.25 N 6009357.69 N 6009352.52 N 6009344.08 N 6009342.79 N 6009332.27 N 6009320.58 N 551405.11 E 551405.11 E 'p1405.11 E 1405.11 E 551404.91 E 551403.34 E 551400.18 E 551395.46 E 551392.50 E 551388.93 E 551379.30 E 551366.34 E 551366.14 E 551349.18 E 551326.92 E 551299.62 E 551267.35 E 551230.21 E 551188.30 E 551141.72 E 551090.62 E 551035.12 E 550990.48 E 550975.51 E 550947.02 E 550914.71 E 550861 .92 E 550853.85 E 550788.08 E 550714.97 E Dogleg Rate (O /100ft) 0.000 0.000 0.000 1.000 1.000 1.000 1.000 1.000 2.000 2.000 2.000 2.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 0.000 0.000 0.000 0.000 6.000 6.000 6.000 Vertical Section 1.89 5.24 10.27 13.41 17.19 27.34 40.93 41.14 58.79 81.76 109.78 142.79 180.68 223.35 270.69 322.57 378.84 424.06 439.22 468.07 500.79 554.25 562.42 629.03 703.07 Alaska Drilling & Wells Milne Point MPI Comment 0.00 0.00 0.00 0.00 Begin Dir @ 1.0000/100ft : 250.00~. MD, 250.00ft TVD 0.21 Dir Rate Increase @ 2.0000/100ft 650.0OftMD,649.68ftTVD Dir Rate Increase @ 3.0000/100ft 901.36ftMD,899.34ftTVD .- End of Build - 1875.37ft Base Permafrost Begin Dir @ 6.0000/100ft : 2086.84f MD, 1950.00ft TVD 5 June, 2001- 18:50 DrillOuest 2.00.09.001 Page 2 of 12 Sperry-Sun Drilling Services Proposal Report for MPI-11 Wps - MPI-11 Wp05 Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 0 Oft) 2400.00 56.790 261 .309 2096.34 2161.04 143.62 S 770.78 W 6009307.85 N 550635.33 E 6.000 783.71 2500.00 62.790 261 .309 2146.64 2211.34 156.67 S 856.17 W 6009294.21 N ,~50550.04 E 6.000 870.09 2600.00 68.790 261.309 2187.63 2252.33 170.45 S 946.29 W 6009279.81 N ~~0460.02 E 6.000 961.26 2700.00 74.790 261.309 2218.86 2283.56 184.80 S 1040.15W 6q09264.82 N 550366.26 E 6.000 1056.20 ~" 2795.71 80.532 261.309 2239.31 2304.01 198.92 S 1132.53W j@iSOO9250.06 N 550273.98 E 6.000 1149.66 End Dir, Start Sail @ 80.532° : 2795.71 ftMD ,2304.01 ftTVD 2800.00 80.532 261 .309 2240.01 2304.71 550269.80 E 0.000 1153.89 2900.00 80.532 261.309 2256.46 2321.16 550172.40 E 0.000 1252.53 3000.00 80.532 261.309 2272.91 2337.61 550075.00 E 0.000 1351.17 3100.00 80.532 261 .309 2289.36 2354.06 549977.60 E 0.000 1449.81 3200.00 80.532 261 .309 2305.81 2370.51 549880.20 E 0.000 1548.44 3300.00 80.532 261.309 2322.26 1624.24 W 6009171.51 N 549782.80 E 0.000 1647.08 3400.00 80.532 261.309 2338.71 1721.75 W 6009155.93 N 549685.40 E 0.000 1745.72 3500.00 80.532 261 .309 2355.16 1819.25 W 6009140.36 N 549588.00 E 0.000 1844.35 3600.00 80.532 261.309 2371.61 1916.76 W 6009124.78 N 549490.60 E 0.000 1942.99 3700.00 80.532 261 .309 2388.06 2014.26 W 6009109.20 N 549393.20 E 0.000 2041.63 3800.00 80.532 261.309 2404.51 2469.21 348.61 S 2111.77 W 6009093.63 N 549295.80 E 0.000 2140.27 3900.00 80.532 261.309 2420.96 2485.66 363.51 S 2209.27 W 6009078.05 N 549198.40 E 0.000 2238.90 4000.00 80.532 261.309 2437.41 2502.11 378.42 S 2306.78 W 6009062.47 N 549101 .00 E 0.000 2337.54 4100.00 80.532 261 .309 2453.86 2518.56 393.32 S 2404.28 W 6009046.90 N 549003.60 E 0.000 2436.18 4200.00 80.532 261 .309 2470.31 2535.01 408.23 S 2501.79 W 6009031.32 N 548906.20 E 0.000 2534.82 ---'- 4300.00 80.532 261 .309 2486.76 2551.46 423.13 S 2599.29 W 6009015.74 N 548808.80 E 0.000 2633.45 4400.00 80.532 261.309 2503.21 2567.91 438.04 S 2696.80 W 6009000.17 N 548711 .40 E 0.000 2732.09 4500.00 80.532 261 .309 2519.66 2584.36 452.94 S 2794.30 W 6008984.59 N 548614.00 E 0.000 2830.73 4600.00 80.532 261 .309 2536.11 2600.81 467.85 S 2891.81 W 6008969.01 N 548516.60 E 0.000 2929.36 4700.00 80.532 261.309 2552.55 2617.25 482.75 S 2989.31 W 6008953.44 N 548419.20 E 0.000 3028.00 4800.00 80.532 261.309 2569.00 2633.70 497.66 S 3086.82 W 6008937.86 N 548321.80 E 0.000 3126.64 4900.00 80.532 261.309 2585.45 2650.15 512.56 S 3184.32 W 6008922.28 N 548224.39 E 0.000 3225.28 5000.00 80.532 261.309 2601.90 2666.60 527.47 S 3281.83 W 6008906.71 N 548126.99 E 0.000 3323.91 5100.00 80.532 261.309 2618.35 2683.05 542.37 S 3379.33 W 6008891 .13 N 548029.59 E 0.000 3422.55 5200.00 80.532 261 .309 2634.80 2699.50 557.28 S 3476.84 W 6008875.55 N 547932.19 E 0.000 3521.19 5 June, 2001-18:50 Page 3 of 12 DrillOuest 2.00.09.001 Sperry-Sun Drilling Services Proposal Report for MPI-11 Wps - MPI-11 Wp05 Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 5300.00 80.532 261 .309 2651.25 2715.95 572.18 S 3574.34 W 6008859.98 N 547834.79 E 0.000 3619.83 5400.00 80.532 261.309 2667.70 2732.40 587.09 S 3671 .85 W 6008844.40 N ?47737.39 E 0.000 3718.46 5500.00 80.532 261.309 2684.1 5 2748.85 601.99 S 3769.35 W 6008828.82 N 547639.99 E 0.000 3817.10 5600.00 80.532 261 .309 2700.60 2765.30 616.90 S 3866.86 W 6008813.25 N 547542.59 E 0.000 3915.74 .-"-. 5700.00 80.532 261 .309 2717.05 2781.75 631.80 S 3964.37 W 008797.67 N 547445.19 E 0.000 4014.37 5800.00 80.532 261.309 2733.50 2798.20 646.71 S 08782.09 N 547347.79 E 0.000 4113.01 5900.00 80.532 261 .309 2749.95 2814.65 661.61 S 08766.52 N 547250.39 E 0.000 4211.65 6000.00 80.532 261 .309 2766.40 2831.10 676.51 S 6008750.94 N 547152.99 E 0.000 4310.29 6100.00 80.532 261.309 2782.85 2847.55 691. 6008735.36 N 547055.59 E 0.000 4408.92 6200.00 80.532 261.309 2799.30 2864.00 7 6008719.79 N 546958.19 E 0.000 4507.56 6300.00 80.532 261 .309 2815.75 2880.45 4549.40 W 6008704.21 N 546860.79 E 0.000 4606.20 6400.00 80.532 261 .309 2832.20 2896.90 4646.90 W 6008688.63 N 546763.39 E 0.000 4704.84 6500.00 80.532 261.309 2848.64 2913.3 4744.41 W 6008673.06 N 546665.99 E 0.000 4803.47 6600.00 80.532 261.309 2865.09 2929.7 4841.91 W 6008657.48 N 546568.59 E 0.000 4902.11 6700.00 80.532 261 .309 2881 .54 2946.24 4939.42 W 6008641.90 N 546471.19 E 0.000 5000.75 6800.00 80.532 261 .309 2897.99 2962.69 795.75 S 5036.92 W 6008626.33 N 546373.79 E 0.000 5099.38 6900.00 80.532 261 .309 2914.44 2979.14 810.66 S 5134.43 W 6008610.75 N 546276.39 E 0.000 5198.02 7000.00 80.532 261.309 2930.89 2995.59 825.56 S 5231 .93 W 6008595.17 N 546178.99 E 0.000 5296.66 7100.00 80.532 261.309 2947.34 3012.04 840.47 S 5329.44 W 6008579.60 N 546081.59 E 0.000 5395.30 7200.00 80.532 261.309 2963.79 3028.49 855.37 S 5426.94 W 6008564.02 N 545984.19 E 0.000 5493.93 7300.00 80.532 261.309 2980.24 3044.94 870.28 S 5524.45 W 6008548.44 N 545886.79 E 0.000 5592.57 .-", 7 400.00 80.532 261.309 2996.69 3061 .39 885.18 S 5621.95 W 6008532.87 N 545789.39 E 0.000 5691.21 7500.00 80.532 261 .309 3013.14 3077.84 900.09 S 5719.46 W 6008517.29 N 545691 .99 E 0.000 5789.85 - 7600.00 80.532 261.309 3029.59 3094.29 914.99 S 5816.96 W 6008501.71 N 545594.59 E 0.000 5888.48 7700.00 80.532 261.309 3046.04 3110.74 929.90 S 5914.47 W 6008486.14 N 545497.19 E 0.000 5987.12 7800.00 80.532 261.309 3062.49 3127.19 944.80 S 6011.97W 6008470.56 N 545399.79 E 0.000 6085.76 7900.00 80.532 261 .309 3078.94 3143.64 959.71 S 6109.48 W 6008454.98 N 545302.39 E 0.000 6184.39 8000.00 80.532 261.309 3095.39 3160.09 974.61 S 6206.98 W 6008439.41 N 545204.99 E 0.000 6283.03 8100.00 80.532 261 .309 3111.84 3176.54 989.52 S 6304.49 W 6008423.83 N 545107.59 E 0.000 6381.67 8200.00 80.532 261.309 3128.29 3192.99 1 004.42 S 6401.99 W 6008408.25 N 545010.19 E 0.000 6480.31 5 June, 2001 - 18:50 Page 4 of 12 DrillOuest 2.00.09.001 Sperry-Sun Drilling Services Proposal Report for MPI-11 Wps - MPI-11 Wp05 Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 8300.00 80.532 261.309 3144.74 3209.44 1019.338 6499.50 W 6008392.68 N 544912.79 E 0.000 6578.94 8325.93 80.532 261 .309 3149.00 3213.70 1023.19 S 6524.78 W 6008388.64 N .544887.54 E 0.000 6604.52 Top Ugnu 8400.00 80.532 261 .309 3161.18 3225.88 1 034.23 S 6597.00 W 6008377.10 N ~4815.39 E 0.000 6677.58 8500.00 80.532 261.309 3177.63 3242.33 1049.148 6694.51 W 6q08361.52 N 544717.99 E 0.000 6776.22 ~~ 8600.00 80.532 261.309 3194.08 3258.78 1064.04 8 6792.01 W 008345.95 N 544620.59 E 0.000 6874.86 8700.00 80.532 261.309 3210.53 3275.23 1078.95 S 08330.37 N 544523.19 E 0.000 6973.49 8800.00 80.532 261.309 3226.98 3291 .68 1093.85 S 08314.79 N 544425.79 E 0.000 7072.13 8900.00 80.532 261.309 3243.43 3308.13 1108.768. 6008299.22 N 544328.39 E 0.000 7170.77 9000.00 80.532 261.309 3259.88 3324.58 1123.668 6008283.64 N 544230.99 E 0.000 7269.41 9100.00 80.532 261 .309 3276.33 3341 .03 1138.578 6008268.06 N 544133.59 E 0.000 7368.04 9200.00 80.532 261.309 3292.78 3357.48 1153.47 S 7377.05 W 6008252.49 N 544036.19 E 0.000 7466.68 9300.00 80.532 261.309 3309.23 3373.93 1168.38 8 7474.55 W 6008236.91 N 543938.79 E 0.000 7565.32 9335.08 80.532 261 .309 3315.00 3379.7 1173.61 S 7508.75 W 6008231.45 N 543904.62 E 0.000 7599.92 Top Ugnu M 9400.00 80.532 261 .309 3325.68 3390.3 1183.28 S 7572.06 W 6008221.33 N 543841 .39 E 0.000 7663.95 9500.00 80.532 261.309 3342.13 3406.83 1198.198 7669.56 W 6008205.76 N 543743.99 E 0.000 7762.59 9600.00 80.532 261.309 3358.58 3423.28 1213.09 S 7767.07 W 6008190.18 N 543646.59 E 0.000 7861.23 9700.00 80.532 261 .309 3375.03 3439.73 1228.00 S 7864.57 W 6008174.60 N 543549.19 E 0.000 7959.87 9800.00 80.532 261.309 3391.48 3456.18 1242.90 S 7962.08 W 6008159.03 N 543451.79 E 0.000 8058.50 9821.42 80.532 261.309 3395.00 3459.70 1246.09 S 7982.96 W 6008155.69 N 543430.93 E 0.000 8079.63 Schrader NA 9827.50 80.532 261.309 3396.00 3460.70 1247.00 S 7988.89 W 6008154.75 N 543425.01 E 0.000 8085.62 Begin Dir @ 3.0000/100ft : 9827.5Ot MD, 3460.7Ott TVD Target - MPI-11 T1, Geological ~- 9900.00 78.357 261.305 3409.28 3473.98 1257.77 S 8059.34 W 6008143.49 N 543354.63 E 3.000 8156.90 9967.21 76.341 261.301 3424.00 3488.70 1267.698 8124.16 W 6008133.13 N 543289.88 E 3.000 8222.47 Schrader NB 10000.00 75.357 261.299 3432.02 3496.72 1272.50 8 8155.59 W 6008128.10 N 543258.48 E 3.000 8254.27 10005.65 75.187 261 .299 3433.45 3498.15 1273.32 8 8161.00 W 6008127.23 N 543253.09 E 3.000 8259.73 End Dir, Start 8ail @ 75.187° : 1 0005.65ftMD,3498.15ftTVD 10097.75 75.187 261.299 3457.00 3521.70 1286.798 8249.01 W 6008113.16 N 543165.17 E 0.000 8348.77 Schrader NC 10100.00 75.187 261.299 3457.57 3522.27 1287.12 S 8251.16 W 6008112.82 N 543163.02 E 0.000 8350.94 10168.16 75.187 261.299 3475.00 3539.70 1297.09 S 8316.29 W 6008102.40 N 543097.96 E 0.000 8416.84 Schrader NE 10200.00 75.187 261 .299 3483.14 3547.84 1301.75 S 8346.72 W 6008097.53 N 543067.56 E 0.000 8447.62 10300.00 75.187 261 .299 3508.71 3573.41 1316.37 S 8442.28 W 6008082.25 N 542972.10 E 0.000 8544.30 10352.00 75.187 261.299 3522.00 3586.70 1323.98 S 8491 .98 W 6008074.30 N 542922.46 E 0.000 8594.57 Schrader NF 5 June, 2001-18:50 Page 5 of 12 DrillQuest 2.00.09.001 Sperry-Sun Drilling Services Proposal Report for MPI-11 Wps - MPI-11 Wp05 Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 10400.00 75.187 261.299 3534.27 3598.97 1331.00S 8537.85 W 542876.64 E 0.000 8640.97 10488.90 75.187 261 .299 3557.00 3621.70 1344.00 S 8622.80 W 542791 .77 E 0.000 8726.92 Schrader OA 10500.00 75.187 261 .299 3559.84 3624.54 1345.63 S 8633.41 W 2781.18 E 0.000 8737.65 10589.14 75.187 261 .299 3582.63 3647.33 1358.66 S 8718.60 W 2696.08 E 0.000 8823.83 Begin Dir @ 3.0000/1O0ft : 10589.1Á~ MD, 3647.33ft TVD 10600.00 75.512 261.272 3585.37 3650.07 1360.26 S 542685.71 E 3.000 8834.33 10631.49 76.454 261.195 3593.00 3657.70 1364.91 S 08031.53 N 542655.55 E 3.000 8864.88 TSBC (base OA) 10700.00 78.503 261 .030 3607.85 3672.55 1375.24 S 6008020.74 N 542589.55 E 3.000 8931.76 10800.00 81 .494 260.792 3625.22 3689.92 1390. 6008004.51 N 542492.42 E 3.000 9030.23 10812.30 81 .862 260.763 3627.00 3691.70 1 6008002.48 N 542480.42 E 3.000 9042.40 TSBB-OB 10900.00 84.485 260.559 3637.42 3702.12 1 6007987.76 N 542394.61 E 3.000 9129.47 11000.00 87.476 260.327 3644.43 9118.77 W 6007970.52 N 542296.36 E 3.000 9229.20 11050.96 89.000 260.210 3646.00 9168.97 W 6007961.57 N 542246.23 E 3.000 9280.13 Target - MPI-11 GeoPoly, Geological 11 076.49 89.763 260.144 3646.28 9194.13 W 6007957.04 N 542221.10 E 3.000 9305.66 End Dir, Start Sail @ 89.763° : 11076.49ftMD,3710.98ftTVD 11077.14 89.763 260.144 3646.28 3710.98 1436.52 S 9194.77 W 6007956.92 N 542220.46 E 0.000 9306.31 7" Casing 11100.00 89.763 260.144 3646.37 3711 .07 1440.43 S 9217.29 W 6007952.85 N 542197.97 E 0.000 9329.16 11200.00 89.763 260.144 3646.79 3711.49 1457.55 S 9315.82 W 6007935.06 N 542099.56 E 0.000 9429.15 11300.00 89.763 260.144 3647.20 3711 .90 1474.66 S 9414.34 W 6007917.26 N 542001.16 E 0.000 9529.13 11400.00 89.763 260.144 3647.61 3712.31 1491.78S 9512.86 W 6007899.47 N 541902.76 E 0.000 9629.12 11500.00 89.763 260.144 3648.02 3712.72 1508.90 S 9611.39 W 6007881.67 N 541804.35 E 0.000 9729.10 11600.00 89.763 260.144 3648.44 3713.14 1526.01 S 9709.91 W 6007863.88 N 541705.95 E 0.000 9829.09 --. 11700.00 89.763 260.144 3648.85 3713.55 1543.13 S 9808.43 W 6007846.08 N 541607.55 E 0.000 9929.07 11708.11 89.763 260.144 3648.88 3713.58 1544.52 S 9816.42 W 6007844.64 N 541599.57 E 0.000 9937.18 Begin Dir @ 3.0000/100ft : 11708.11 MD, 3713.58ft TVD 11764.18 90.000 261.810 3649.00 3713.70 1553.31 S 9871.80 W 6007835.46 N 541544.25 E 3.000 9993.25 Target - MPI-11 T3, Geological 11800.00 91 .074 261.846 3648.66 3713.36 1558.40 S 9907.25 W 6007830.13 N 541508.84 E 3.000 10029.06 11884.50 93.607 261.931 3645.21 3709.91 1570.31 S 9990.83 W 6007817.64 N 541425.34 E 3.000 10113.48 End Dir, Start Sail @ 93.607° : 11884.5OftMD,3709.91ftTVD 11900.00 93.607 261.931 3644.24 3708.94 1572.48 S 10006.14 W 6007815.36 N 541410.04 E 0.000 10128.95 12000.00 93.607 261.931 3637.95 3702.65 1586.49 S 10104.96 W 6007800.67 N 541311.33 E 0.000 10228.74 12100.00 93.607 261.931 3631.65 3696.35 1600.50 S 10203.77 W 6007785.98 N 541212.61 E 0.000 10328.53 12200.00 93.607 261.931 3625.36 3690.06 1614.51 S 10302.59 W 6007771 .30 N 541113.90 E 0.000 10428.32 12300.00 93.607 261.931 3619.07 3683.77 1628.52 S 1 0401 .40 W 6007756.61 N 541015.18 E 0.000 10528.11 5 June, 2001- 18:50 Page 6 of 12 DrillQuest 2.00.09.001 Sperry-Sun Drilling Services Proposal Report for MPI-11 Wps - MPI-l1 Wp05 Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Com ment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 12349.10 93.607 261.931 3615.98 3680.68 1635.40 S 10449.91 W 6007749.39 N 540966.72 E 0.000 10577.11 Begin Dir @3.0000/1O0ft : 12349.10 MD, 3680.68ft TVD 12400.00 92.333 261 .088 3613.34 3678.04 1642.90 S 10500.19 W 6007741.54 N ;~0916.49 E 3.000 1 0627.94 12442.85 91 .260 260.380 3612.00 3676.70 1649.80 S 10542.46 W 6007734.35 N 540874.27 E 3.000 10670.77 Target - MPI-11 T4, Geological /--~ 12476.65 91.215 261.393 3611.27 3675.97 1655.15 S 10575.82 W tlpO07728.77 N 540840.95 E 3.000 10704.55 End Dir, Start Sail @ 91.215° : 12476.65ftMD,3675.97ftTVD 12500.00 91 .215 261.393 3610.78 3675.48 1658.65 S 540817.89 E 0.000 10727.90 12600.00 91.215 261.393 3608.65 3673.35 1673.61 S 6007709.48 N 540719.14 E 0.000 1 0827.88 12700.00 91 .215 261.393 3606.53 3671 .23 1688.57 S 6007693.83 N 540620.40 E 0.000 1 0927.86 12800.00 91 .215 261.393 3604.41 3669.11 1703.53 S 6007678.19 N 540521 .65 E 0.000 11027.83 12900.00 91 .215 261.393 3602.29 3666.99 1718A9 S ;~ 6007662.55 N 540422.90 E 0.000 11127.81 13000.00 91 .215 261.393 3600.17 3664.87 +ii 1733.46 S ' 6007646.90 N 540324.16 E 0.000 11227.79 13100.00 91 .215 261 .393 3598.05 3662. 7¡'lib" 1748.42 S 11192.02 W 6007631.26 N 540225.41 E 0.000 11327.76 13196.92 91 .215 261.393 3596.00 3660.7 1762.92 S 11287.82 W 6007616.10 N 540129.71 E 0.000 11424.66 Total Depth: 13196.92ftMD,3660.7OftTVD 4 1/2" Liner Target - MPI-11 New TO, Geological All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 261.123° (True). ~-, Based upon Minimum Curvature type calculations, at a Measured Depth of 13196.9211., The Bottom Hole Displacement is 11424.66ft., in the Direction of 261.123° (True). 5 June, 2001-18:50 Page 7 of 12 DrillQuest 2.00.09.001 Milne Point Unit Comments Measured Station Coordinates Depth TVD Northings Eastings (It) (It) (ft) (It) 250.00 250.00 O.OON 0.00 E 650.00 649.68 5.90S 12.65 W 901 .36 899.34 16.33 S 39.09 W 1875.37 1783.36 89.28 S 415.25 W 2086.84 1950.00 108.95 S 543.95 W 2795.71 2304.01 198.92 S 1132.53 W 9827.50 3460.70 1247.00 S 7988.89 W 10005.65 3498.15 1273.32 S 8160.99 10589.14 3647.33 1358.66 S 8718 11076.49 3710.98 1436.41 S 9194. 11708.11 3713.58 1544.52 S 981 11 884.50 3709.91 1570.31 S 9990. 12349.10 3680.68 1635.40 S 10449.91 W 12476.65 3675.97 1655.15S "10575.82 W 13196.92 3660.70 1762.92 S 11287.82 W Formation Tops Formati on Plane (Below Well Origin) Sub-Sea Dip Dip Dir. (It) Deg. Deg. Profile Measured Vertical Depth Depth (ft) (It) 1775.00 0.000 0.395 1946.87 1839.70 1775.00 3149.00 0.000 0.395 8325.93 3213.70 3149.00 3315.00 0.000 0.395 9335.08 3379.70 3315.00 3395.00 0.000 0.395 9821.42 3459.70 3395.00 3424.00 0.000 0.395 9967.21 3488.70 3424.00 Sperry-Sun Drilling Services Proposal Report for MPI-11 Wps - MPI-11 Wp05 Alaska Drilling & Wells Milne Point MPI Comment Begin Dir @ 1.0000/100ft : 25 Dir Rate Increase @ 2.000°. Dir Rate Increase @ 3.ØGO° End of Build - 1 Begin Dir - - TVD ':649.68ftTVD .36ftM D ,899 .34ftTVD ..--~. 86.84ft MD, 1950.000 TVD ~:~i~~~"~lkrt'"."~"..."'"i rt 3~~~;~Oå~32; ~~;i.;~ ~~~ î:~~~;~g End Dlrl!~ii~:sa,' @ 75.187°: 10005.65ftMD,3498.15ftTVD Begin ¡¡Jìr @ 3.0000/1O0ft : 10589.14ft MD, 3647.33ftTVD ". End Dir, Start Sail @ 89.763° : 11076.49ftMD,3710.98ftTVD Begin Dir @ 3.0000/100ft : 11708.11ft MD, 3713.58ft TVD End Dir, Start Sail @ 93.607° : 11884.5OOMD,3709.91ftTVD Begin Dir @3.0000/100ft : 12349.1 Oft MD, 3680.68ft TVD End Dir, Start Sail @ 91.215° : 12476.65ftMD,3675.97ftTVD Total Depth: 13196.92ftMD,3660.70ftTVD Penetration Point Sub-Sea Depth Northings Eastings (ft) (ft) (It) ~ Formation Name 95.93 S 1023.19 S 1173.61 S 1246.09 S 1267.69 S 458.77 W 6524.78 W 7508.75 W 7982.96 W 8124.16 W Base Permafrost Top Ugnu Top Ugnu M Schrader NA Schrader NB 5 June,2001-18:50 Page 8 of 12 DrillQuest 2.00.09.001 Sperry-Sun Drilling Services Proposal Report for MPI-11 Wps - MPI-11 Wp05 Milne Point Unit Alaska Drilling & Wells Milne Point MPI Formati on Plane (Below Well Origin) Sub-Sea Dip Dip Dir. (ft) Deg. Deg. Profile Measured Vertical Depth Depth (ft) (ft) Penetration Point Sub-Sea Depth Northings Eastings (ft) (ft) (ft) Formation Name 3457.00 0.000 0.395 10097.75 3521.70 3457.00 3475.00 0.000 0.395 10168.16 3539.70 3475.00 3522.00 0.000 0.395 10352.00 3586.70 3522.00 3557.00 0.000 0.395 10488.90 3621.70 3557.00 3593.00 0.000 0.395 10631.49 3657.70 3593.00 3627.00 0.000 0.395 10812.30 3691.70 3652.00 0.000 0.395 Casing details From To Measured Vertical Measured Vertical Depth Depth Depth Depth Casing Detail (ft) (ft) (ft) (ft) <Surface> <Surface> 11077 .14 3710.98 7" Casing <Surface> <Surface> 13196.92 3660.70 4 1/2" Liner --, Formation Tops (Continued) ~ er NC Schrader NE Schrader NF Schrader OA TSBC (base OA) 8934.50 W TSBB-OB SBA5 (base OS) -~ 5 June, 2001-18:50 Page 9 of 12 DrillQuest 2.00.09.001 Sperry-Sun Drilling Services Proposal Report for MPI-11 Wps - MPI-11 Wp05 Milne Point Unit Targets associated with this wellpath Target Name MPI-11 Drlr Poly Mean Sea Level/Global Coordinates: Geographical Coordin Level/Global Coordinates #1 #2 #3 #4 #5 #6 #7 #8 Geographical Coordinates #1 #2 #3 #4 #5 #6 #7 #8 3710.70 3710.70 3710.70 3710.70 3710.70 3710.70 3710.70 3710.70 3646.00 3646.00 3646.00 3646.00 3646.00 3646.00 3646.00 3646.00 Entry Coordinates Northings Eastings (ft) (ft) 1432.05 S 9168.97 W 6007961.57 N 542246.23 E 70025' 57.5751" N 149039' 20.2533" W 1224.81 S 8559.76 W 1349.36 S 9641.64 W 1398.42 S 10648.00 W 1445.28 S 11248.34 W 1767.69 S 11190.56 W 1677.79 S 10595.93 W 1627.69 S 9593.56 W 1686.25 S 8496.93 W 6008173.00 N 542854.00 E 6008041 .00 N 541773.00 E 6007985.00 N 540767.00 E 6007934.00 N 540167.00 E 6007612.00 N 540227.00 E 6007706.00 N 540821 .00 E 6007763.00 N 541823.00 E 6007712.00 N 542920.00 E 700 25' 59.6206" N 149039' 02.3826" W 700 25' 58.3826" N 149039' 34.1272" W 700 25' 57.8865" N 1490 40' 03.6577" W 70025' 57.4169" N 1490 40' 21 .2729" W 700 25' 54.2467" N 149040' 19.5631" W 70025' 55.1395" N 149040' 02.1178" W 700 25' 55.6455" N 149039' 32.7057" W 700 25' 55.0826" N 149039' 00.5236" W Target Shape Polygon Alaska Drilling & Wells Milne Point MPI Target Type Drillers .-c_- -- 5 June, 2001 - 18:50 Page 100f12 DrillQuest 2.00.09.001 Milne Point Unit Target Name Targets associated with this well path (Continued) MPI-11 GeoPoly MPI-11 NewTD MPI-11 T1 MPI-11 T2 Sperry-Sun Drilling Services Proposal Report for MPI-11 Wps - MPI-11 Wp05 Alaska Drilling & Wells Milne Point MPI Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) Target Shape Target Type Mean Sea LeveVGlobal Coordinates: Geographical Coordin 1432.05 S 9168.97 W Polygon Geological 6007961 .57 N 542246.23 E 70025' 57.5751" N 149039' 20.2533" W 1128.36 S 8479.09 W 1306.93 S 11284.68 W 1762.92 S 11287.82 W 1782.70 S 8417.60 W 6008270.00 N 542934.00 E 6008072.10 N 540129.71 E 6007616.10 N 540129.71 E 6007616.10 N 543000.00 E 700 26' 00.5701" N 149039' 00.0185" W 700 25' 58.7772" N 149040' 22.3454" W 700 25' 54.2921" N 149040' 22.4174" W 700 25' 54.1348" N 149038'58.1923" W .,-~-- al Coordinates #1 #2 #3 #4 3646.00 3646.00 3646.00 3646.00 Geographical Coordinates #1 #2 #3 #4 3660.70 1762.92 S 11287.82 W Point Geological Mean Sea LeveVGlobal Coordinates: 3596.00 6007616.10 N 540129.71 E .- Geographical Coordinates: 700 25' 54.2921" N 149040' 22.4174" W 3460.70 1247.00 S 7988.89 W Point Geological Mean Sea LeveVGlobal Coordinates: 3396.00 6008154.75 N 543425.00 E Geographical Coordinates: 700 25' 59.4086" N 1490 38' 45.6292" W 3710.70 1432.05 S 9168.97 W Point Geological Mean Sea LeveVGlobal Coordinates: 3646.00 6007961.57 N 542246.23 E Geographical Coordinates: 70025' 57.5751" N 1490 39' 20.2533" W 5 June, 2001- 18:50 Page 11 of 12 DrillQuest 2.00.09.001 Milne Point Unit Target Name Targets associated with this well path (Continued) MPI-11 T3 MPI-11 T4 Sperry-Sun Drilling Services Proposal Report for MPI-11 Wps - MPI-11 Wp05 Alaska Drilling & Wells Milne Point MPI Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) Target Shape Target Type Mean Sea Level/Global Coordinates: Geographical Coordin 1553.31 S 9871 .80 W Point Geological ~~~ 6007835.46 N 541544.25 E 70025' 56.3735" N 1490 39' 40.8736" W 1649.80 S 10542.46 W Point Geological 6007734.35 N 540874.27 E 700 25' 55.4154" N 1490 40' 00.5501" W _c 5 June, 2001-18:50 DrillQuest 2.00.09.001 Page 12 of 12 (' TREE: Cameron 3", 5M .. WELLHEAD: FMC Gen 6,11", 5M (' PROPOSED COMPLETION MPI-11 & 1-11 L 1 11081 MDI 20" 92 Ibltt, H-40 Welded 7", 26#, L-80, Hydril 521 Casing Drift: 6.151" Casing 10: 6.276" Baker Hughes Hook Hanger system Level 3 Multi-Lateral Junction Window in 7" casing @ 10,427'-10,439' MD Wellinclination @ Window = 80.4 Degrees Baker Hughes Conventional Hanger 7" Casing Shoe @ 11,077' MD Wellinclination @ Shoe = 89 Degrees DATE REV. BY COMMENTS 6/2812001 RB Tirpack Level 3 Multi-Lateral, 3-112" tbg with RPB KB. ELEV = 64.7' GL ELEV = 34.7' 3-1/2", 9.3 Iblft, L-80, EUE Coupling 00: 4.5" DrifUlD: 2.867"/2.992" 7",26# RBP @ 10,327' MD -- ~--------------_, OA Horizontal ------------------. 6-1/8" OA Lateral 4-1/2" Slotted Liner and Hook Hanger 113,190' MD I \ " \ ~--------------- "" " - 08 Horizontal ----------------- 6-1/8" OB Lateral 4-1/2" Slotted Liner & Hanger 113,197' MD I Milne Point Unit WELL: MPI-11 API NO: BP Exploration (AJaska) { H 191157 DATE INVOICE / CREDIT MEMO 060101 CKO60101M PYMT OMMENTS: HANDL NG INST: DESCRIPTION PER IT TO DRILL EE 5tH - TERRIE HUB LE yY¡pr- II 'HE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. p.o. BOX 196612 ANCHORAGE, ALASKA 99519-6612 PAY To The ORDER O-f O~EHUIMDR ED 8< 00/ 1 OO~~*~~************~**~~;~*~,~********** U.siDeLLAR ALAS~A oiL ANI) GAS, CONsERv~jr I ON:~QMMI SSJON 3:33WESf> 7TH AVENUE SUITE 100 ",,', ,'i' ANCHORAGE TOTAL ~ AK 995,01 ~, GROSS 100.00 X4628 FIRST NATIONAL BANK OF ASHLAND " AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO 56.389 412 , ' , , :i DATE:, """, ,",', Ql:/I 04/ 0 1 III ¡. g ¡. ¡. 5 ? III I: 0 ~ ¡. 2 0 :I a q 5 I : 0 0 a ~ ~ ¡. g III ~ 001 DATE 06/04/01 VENDOR DISCOUNT ALASKAOILA NET 100.00 00 No.H 191157 CONSOLIDATED COMMERCIAL ACCOUNT 00191157 .I»:>.:,i,i,i,,! ' 'ii; , 'i,',' ' ,AMOUNT ~ #i oo,,()p: NQYVALIDAFTER12ÒDAYS i" , .. ,. ' , , ' , " ~'...";'.i,.,."..,..""",,',i.',.,..,....,...,',~ '.f n"'i.....",.,.'...'.i..'";1~,"";~A",!'(' '~~~i,;Il""~ "i:. 'i.'., :,i',':.i:: " ,:': ,'-10. rT -...':: /' í ~. ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPRO PRIA TE LETTER/P ARA GRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME M r T - l.' CHECK 1 STANDARD LETTER DEVELOPMENT V DEVELOPMENT REDRILL EXPLORATION INJECTION WELL INJECTION WELL REDRILL CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNUL~L ANNULAR DISPOSAL <-> YES ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new wellbore segment of existing well . Permit No, API No. . Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS <-> YES + SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The. permit is approved subject to full compliance with 20 MC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. . WELL PERMIT CHECKLIST COMPANY WELL NAME J11.Pf- / / PROGRAM: exp - dev .x.. redrll FIELD & POOL .:5'25/<7/0 INITCLASS Óf?/c/ / -0// G OLAREA Y 7r) ADMINISTRA TIOH 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . Y N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. .. . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. ... Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available'in drilling unit.. . . . . . . . . . . Y N, 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can,be issued without administrative approval.. . . . . ,y} N 13. Can permit be approved before 15-day wait.. . . . . . . . . . \(: N 14. Conductor string provided . . . . . . . . . . . . . . . . . . . éJJ N 15. Suñace casing protects all known USDWs. . . . . . . . . . . Y N ~ fl . '11 n 16. CMT vol adequate to circulate on conductor & suñ csg. . . . . N f;)'ro éX. v e....~ ~ 0 V\. ,--C<.. 5 t &.1. ~ , c... t' ~ e ~ f'd 17. CMT vol adequate to tie-in long string to suñ csg. . . . . . . . N U 18. CMT will cover all known productive horizons. . . . . '. . . . . Y N -1J ~ ~ -e po.. ,r ~ ~ ¡) r ~ <:-f' c.. (0 ~ : \It ð " 19. Casing designs adequate for C, T, B & permafrost. . . . . . . Y N (I 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N ---"^- P u .:s Q l,....trt'.,..ç 't"..- fA V\ Ò' -V~'. '::;;:. r. {, 21. If a re-drill, has a 10-403 for abandonment been approved. . . Y N 22. Adequate wellbore separation proposed.. . . . . . . . . . . . N 23. If diverter required, does it meet regulations. . . . . . . . . . Y N 24. Drilling ,fluid program schematic & equip list adequate. . ~ . . Y N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . Y N APPR DATE 26. BOPE press rating appropriate; test to psig. Y N ,~=." /. ÎIQ~b. ,. 27. Ch. oke manifold compliesw/API RP-53 (May 84). . . . . . . . Y N " ") i 28. Work will occur without operation shutdbwn. . . . . . . . . . . N. ',. . ß '!{,»-"r<î\ 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y rQj GEOLOGY 30. Permit can be issued wlo hydrogen sulfide measures. . . .' Y N 31. Data presented on potential overpressure zones. . . . . . . Y 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y. N APPR ø~ 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . N . ¿P! 34. Contact name/phone for weekly progress reports (exploratory 0 1 Y N ANNULAR DISPOSAL35. With proper cementing records, this plan. /" (A) will contain waste in a suitable receiving zone; . . . . . ../ Y APPR DATE " (B) will not contaminate frèshwater; or cause drilling waste ..v--:~ Y ~~~ce. " '/ , / (C) will not impair mechanical integrity of the well us,~d'for disposal; (D) will not damage producing formation or impair/récovery from a ~;~ / E will not circumvent 20 AAC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: ~þ~ WM 8~s tø1 JMH A PR 'p~TE ./ ~O) ENGINEERING serv well bore sag _ann. disposal para req - //3ZQ ON/OFF SHORE (;A) UNIT# c 0 Z 0 -t ~ ::u ( +ð soracC'( TO P )(c(~ \ Q (') v1-1. (J ( .pl-t W7j)' - -t m -' Z -t :I: - /V.A. en :Þ :xl m :Þ ( ~~!A Y N . ! Y N Com ments/lnstructions: c:\msoffice\wordian\diana\checklist (rev. 11/01/100) ~. ( Well History File APPENDIX , Information of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. . To improve the readability of the Well History file and to simplify finding information. infonnation. of this nature is accumulated at the end of the file under APPENDIX. No special' effort has been made to chronologically , . organize this category of information. (' dtil!'o'~l:C7'"37 " I{ Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Feb 07 11:37:51 2002 Reel Header Service name............ .LISTPE Date.....................02/02/07 Origin...................STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date.....................02/02/07 Origin...................STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point Unit MWD / MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPI-ll 500292303300 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 07-FEB-02 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 AK-MM-11151 TIM GALVIN D. FERGUSON MWD RUN 2 AK-MM-11151 TIM GALVIN D. FERGUSON MWD RUN 3 AK-MM-11151 DENIS LABREC J. PYRON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 33 13N 10E 2343 3966 MSL 0) 63.55 34.70 # WELL CASING RECORD 1ST STRING 2ND STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 13.500 20.000 108.0 9.875 10.750 2729.0 (' ( 3RD STRING PRODUCTION STRING 6.125 7.000 10747.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1, 2, AND 3 WERE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUN 2 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD). AT-BIT INCLINATION (ABI) AND PWD WERE ALSO INCLUDED IN MWD RUN 3. 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED PER E-MAIL FROM D.SCHNORR (GEOQUEST/BP), DATED 2/05/02. MWD DATA ARE CONSIDERED PDC. 5. MWD RUNS 1-3 REPRESENT WELL MPI-11 WITH API#: 50-029-23033-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13170'MD/3644'TVD. SROP = SMOOTHED SGRC = SMOOTHED SEXP = SMOOTHED SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE SLIDE = NON-ROTATED INTERVALS $ RATE OF PENETRATION WHILE DRILLING. GAMMA RAY COMBINED. PHASE SHIFT-DERIVED RESISTIVITY (EXTRA RESISTIVITY (SHALLOW RESISTIVITY (MEDIUM RESISTIVITY (DEEP TIME. File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/07 Maximum Physical Record. .65535 File Type................LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE ROP FET 1 clipped curves; all bit runs merged. .5000 START DEPTH 108.5 152.5 STOP DEPTH 13170.0 13124.0 il.' .~ l j~ RPD RPM RPS RPX GR $ 152.5 152.5 152.5 152.5 160.0 13124.0 13124.0 13124.0 13124.0 13116.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO 1 2 3 MERGE TOP 108.5 2743.0 10767.0 MERGE BASE 2743.0 10767.0 13170.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 108.5 13170 6639.25 26124 108.5 13170 ROP MWD FT/H 0.62 799.41 208.685 26124 108.5 13170 GR MWD API 10.77 128.58 69.2639 25914 160 13116.5 RPXI MWD OHMM 0.23 1611.44 15.3719 25850 152.5 13124 RPS MWD OHMM 0.23 2000 18.6108 25850 152.5 13124 RPM MWD OHMM 0.06 2000 24.7828 25850 152.5 13124 RPD MWD OHMM 0.16 2000 37.2365 25850 152.5 13124 FET MWD HOUR 0.0866667 116.094 1.59701 25944 152.5 13124 First Reading For Entire File......... .108.5 Last Reading For Entire File.......... .13170 File Trailer Service name............ .STSLIB.001 1\ Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/07 Maximum Physical Record. .65535 File Type................LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/07 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP RPD RPM RPS RPX FET GR $ 2 ¡I' 1\ header data for each bit run in separate files. 1 .5000 START DEPTH 108.5 152.5 152.5 152.5 152.5 152.5 160.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ STOP DEPTH 2743.0 2681.5 2681.5 2681.5 2681.5 2681.5 2689.0 09-SEP-01 Insite 66.16 Memory 2743.0 108.0 2743.0 .7 69.1 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER PB02139HRGF8 PB02139HRGF8 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: 13.500 108.0 SPUD MUD {' lIt MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O (' 8.80 145.0 8.8 400 16.0 7.000 6.813 1.930 4.500 66.0 68.0 66.0 66.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 108.5 2743 1425.75 5270 108.5 2743 ROP MWD010 FT/H 0.62 342.77 153.586 5270 108.5 2743 GR MWD010 API 21.34 113.6 65.9807 5059 160 2689 RPX MWD010 OHMM 0.23 1611.44 25.9683 5059 152.5 2681.5 RPS MWD010 OHMM 0.23 2000 38.1236 5059 152.5 2681.5 RPM MWD010 OHMM 0.17 2000 55.0319 5059 152.5 2681.5 RPD MWD010 OHMM 0.22 2000 104.089 5059 152.5 2681.5 FET MWD010 HOUR 0.2244 4.5793 0.757522 5059 152.5 2681.5 First Reading For Entire File......... .108.5 Last Reading For Entire File.......... .2743 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... ( Version Number.......... .1.0.0 Date of Generation...... .02/02/07 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/07 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET GR RPD RPM RPS RPX ROP $ 3 ~. header data for each bit run in separate files. 2 .5000 START DEPTH 2682.0 2689.5 2729.0 2729.0 2729.0 2729.0 2743.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ STOP DEPTH 10713.5 10721.0 10713.5 10713.5 10713.5 10713.5 10767.0 17-SEP-01 Insite 66.16 Memory 10768.0 2743.0 10768.0 75.0 85.8 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER PB02157HWRGVF6 PB02157HWRGVF6 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): 9.875 2729.0 LSND 10.00 ( ,( ( MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 50.0 9.5 300 6.4 3.600 2.979 3.900 3.100 70.0 86.0 70.0 70.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2682 10767 6724.5 16171 2682 10767 ROP MWD020 FT/H 5.39 799.41 234.41 16048 2743.5 10767 GR MWD020 API 10.77 128.58 68.6304 16064 2689.5 10721 RPX MWD020 OHMM 0.37 49.77 11.3316 15970 2729 10713.5 RPS MWD020 OHMM 0.37 49.77 11.3316 15970 2729 10713.5 RPM MWD020 OHMM 0.32 2000 13.3011 15970 2729 10713.5 RPD MWD020 OHMM 0.45 2000 15.3604 15970 2729 10713.5 FET MWD020 HOUR 0.0866667 71.4696 1.32902 16064 2682 10713.5 First Reading For Entire File......... .2682 Last Reading For Entire File......... ..10767 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 ~r :~ Date of Generation...... .02/02/07 Maximum Physical Record. .65535 File Type................LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/07 Maximum Physical Record. .65535 File Type................LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 4 { header data for each bit run in separate files. 3 .5000 START DEPTH 10714.0 10714.0 10714.0 10714.0 10714.0 10721.5 10767.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ STOP DEPTH 13124.0 13124.0 13124.0 13124.0 13124.0 13116.5 13170.0 23-SEP-01 Insite 66.16 Memory 13170.0 10768.0 13170.0 82.8 94.6 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER PB02164HAGR4 PB02164HAGR4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): 6.125 10747.0 Bara-Dril N 9.30 49.0 "I :~ 'II" , MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 8.4 26000 5.2 .100 .084 .190 .210 72.0 87.4 72.0 72.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10714 13170 11942 4913 10714 13170 ROP MWD030 FT/H 1.81 426.99 183.204 4806 10767.5 13170 GR MWD030 API 35.63 104.69 74.8547 4791 10721.5 13116.5 RPX MWD030 OHMM 3.01 51.4 17.6364 4821 10714 13124 RPS MWD030 OHMM 3.93 2000 22.2476 4821 10714 13124 RPM MWD030 OHMM 0.06 2000 31.0748 4821 10714 13124 RPD MWD030 OHMM 0.16 2000 39.5502 4821 10714 13124 FET MWD030 HOUR 0.1669 116.094 3.3709 4821 10714 13124 First Reading For Entire File......... .10714 Last Reading For Entire File.......... .13170 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/07 (" Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name............ .LISTPE Date.....................02/02/07 Origin...................STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Reel Trailer Service name............ .LISTPE Date.....................02/02/07 Origin...................STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File (' Scientific Technical Services Scientific Technical Services
