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Home My WebLink About203-210STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS w+.aA�s•,c+�p waw x�a P t y JAN 06�'� 1. Operations Abandon Plug Perforations LJ Fracture StimulatELJ Pull Tubing LvJ e ion sd wn Li Performed: Suspend ❑ Perforate ❑ Other Stimulat Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ �rforate New Pool ❑ Repair Wel❑ Re-enter Susp Well ❑ Other: Convert to Jet Pump ❑✓ 2. Operator Hilcorp Alaska LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑✓ Stratigmphic❑ Exploratory ❑ Service ❑ 203-210 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-029-23189-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025518 /ADL0025906 MILNE PT UNIT G-16 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 9,561 feet Plugs measured N/A feet true vertical 4,453 feet Junk measured N/A feet Effective Depth measured 9,561 feet Packer measured 5,782 feet true vertical 4,453 feet true vertical 4,320 feet Casing Length Size MD TVD Burst Collapse Conductor 86' 20" 120' 120' N/A N/A Surface 2,491' 10-3/4" 2,526' 2,465' 5,210psi 2,470psi Intermediate 6,227' 7-5/8" 6,260' 4,390' 6,750psi 6,890psi OA Liner 4,348' 4-1/2" 9,991' 4,400' 8,430psi 7,500psi OB Liner 3,203' 4-1/2" 8,978' 4,443' 8,430psi 7,500psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# / L-80 / IBT 5,468' 4,217' Baker ZXP LTP 7 - Packers and SSSV (type, measured and true vertical depth) 5/8" x 5-1/2" 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: 0 0 0 220 1 0 Subsequent to operation: 69 109 0 219 11,663 14. Attachments (required per20AAC 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 ❑✓ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-532 Authorized Name: Chad Helgeson Contact Name: David Haakinson Authorized Title: I Operations Manager dhkinsonlaZhilcoro.com Contact Email: aa Authorized Signatu A-- C/ Cl / v� Date: 1/6/2020 Contact Phone: 777-8343 I\iRBDMS ±' JAN 0 y 2020 -ZoF Form 10-404 Revised 4/2017 llk�eo Submit Original Only K earn Alaska. LLC Ng. KB Elev.: 62.90'/ Orig. GL Bed.: 29.5' RKB-Hanger: 22.60' (Doyon N16) 1 S Milne Point Unit Well: MPU G-16 Last Completed: 12/09/2019 PTD: 203-210 TREE & WELLHEAD Tree 4-1/2" -YM Cameron Wellhead 5M Gen 511"x11"w/4-1/2"TC-II Top T&B Hanger 4.5" CIW'H' BPV Profile OPEN HOLE/ CEMENT DETAIL 20" 260 sx of Arcticset (Approx) in 42" Hole 30-3/4" 450 sx PF'L', 260 sx Class "G" in 13-1/2" Hole 7-5/8" 670 sx Class "G"in 9-7/8" Hole CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92/H-40/Welded N/A Surface 120- 10-3/4' Surface 45.5 / L-80 / BTC 9.950 Surface 2,527' 7-5/8" Production 29.7/L-80/BTC-MOD BTC,.-MOD 6.875 Surface 6,260' 4-1/2" Liner "OA" 12.6 / L-80 / 3.958 5,643' 9,991' 4-1/2" Liner"OB" 12.6/L-80/IBT 3.958 5,775' 8,978' TUBING DETAIL Tubing 9.2/L-80 /EUE 8rd 2.992 Surface ±5,550' WELL INCLINATION DETAIL KOP @ 200' MD 60+ deg From 3,800' Max Wellbore Angle =66.0 deg @ 5,550' MD JEWELRY DETAIL No Top (MD) Item 1 66' ) Crossover (4-1MDG 2 2,266' 3-1/2" Gas Liftet DGLV on 12/14/19)3 5,368' XD Sliding SleeSet 6B jet pump on 12/14/19)4 5,379' Lower Suction 5 5,392' Retrievable Pax 3-1/2")6 5,415' XN Nipple (2.77 5,515' WLEG- Bottom 8 5,643' OA Lateral Hook Wall, Hanger above 7-5/8" Window 9 5,660' OA Lateral Hook Wall, Hanger below 7-5/8" Window 10 5,775' OR Lateral Tie Back Sleeve 11 5,782' OB Lateral ZXP Liner Top Packer 5,788' O- Lateral 7-5/8" x5-1/2" HMC Liner Hanger ff 9,991' OA Lateral 4-1/2" Btm of Guide Shoe $978' OB Lateral 4-1/2" Btm of Guide Shoe "dY Lateral Slotted Liner 13 K 70 72 '0B` Lateral Slotted Liner 14 7-5/S TD =9,561' (M®) /TD=4,453'(ND) PBTD=9,561' (MD) /TD = 4,453'M) LATERAL WINDOW GENERAL WELL INFO API: 50-029-23189-00-00 Drilled and Completed by Doyon 14-2/03/2004 Convert to TTC-ESP by Doyon 16 —5/25/2013 Convert to jet pump by ASR —12/14/2019 Revised By: TDF 1/6/2020 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP G-16 ASR#1 50-029-23189-00-00 203-210 12/5/2019 12/10/2019 12/4/2019- Wednesday No operations to report. 12/5/2019 - Thursday MIRU ASR on G-16, Install rig floor, begin all line ty-ins and insulating. Take on 50 bbls F/W for BOP testing, BOP's torqued, install jumper lines from carrier to pits, install rig pump and hoses to pits and carrier. IA pressure is at 40 psi. Attempt to get BOPE Body Test. AOGCC waived witness (Adam Earl 12/5/2019). Lines are frozen outside. Attempt to locate frozen lines. Bring tarps and 5 more heaters to thaw lines. BOPE Test to 250 psi low and 2,800 psi high. Test #1 Blinds, C12, C14, C16. Test #2 Pipe Rams w/ 4-1/2" Joint, IBCP, C1, K1. Test #3 Pipe Rams w/ 3-1/2" Joint, TIW, HCR, K2. Test #4 Pipe Rams w/ 3-1/2" Test Joint, TIW, C5, C6, C9, K3. Test #5 Pipe Rams w/ 3-1/2" Test Joint, TIW, C4, C7, C11, K3. Test #6 Pipe Rams w/ 3-1/2" Test Joint, TIW, C8, C10, C13, C14, C15, K3. Test #7 Annular with 3-1/2" Test Joint, C8, C9, C10, K3 12/6/2019 - Friday Crew swaps and Continue with and complete BOP testing. Start to blow down BOP and lines. In attempt to blow down lines rig losing air pressure. Trace air lines and find leak, repair an continue to blow down BOP and lines. Weight up test water to 9.5 ppg w/ NaCl . Take on 220 bbls 9.5 brine from storage tank. Check backside on well and find well dead. Check BPV and tubing dead. Pull BPV and prep to pull hanger. Continue to weight up fluid in pits to 9.5 Move out heaters and move in pipe racks. P/U landing joint and make up. BOLDS. Check backside for no pressure, pull hanger free @ 71K up and steady upweight @ 67K. De -terminate hanger from ESP Power cable. Connect ESP cable to rope/spooler - Breakout and lay down hanger. Swap elevators to slip type. Start POOH. POOH laying down 4-1/2" 12.6# L-80 IBT tubing. Pumping single to 1-1/2 displacement of 9.5 # NaCl brine. Tubing is in good condition with minor scaling on the joints near the ESP,.Break Crossover and Ported TTC Tubing. Allow pressure to bleed off from Upper Tandem Seal. L/D Upper Seal, Lower Seal, Motor, and Centralizer. Severe corrosion on Flat guards and Protectolizers around pump assembly. Move 4-1/2" Tubing to Pipe Tub. Load and strap 3-1/2" 9.5# Workstring Remove Centrilift equipment from Rig Floor. P/U 7-5/8" Scraper and Crossover. Repair hydraulic leak on Tongs. Change out Slips and Elevators. RIH w/ 7-5/8" Casing Scraper on 3-1/2" Workstring while pumping displacement every 15 Joints. 12/7/2019 -Saturday Crew swap fluid checks. Continue to RIH w/ 3.5" 10.4# work -string and casing scraper. RIH w/ 135 joints putting casing scraper at 5,458'. Reciprocated scraper on area between 5,387' and 5,458'. Line up to pump down tubing and take returns from backside to tiger tank. Pump 15 bbls @ 3bpm and break circulation. Pump 20 bbls to tiger tank @ 3bpm and S/D. Line up to pump reverse and pump 8 bbls and catch returns to tiger tank. Pump xx bbls to tiger tank and then swap to take returns to the pits. Pump 1.4 bottoms up @ 3.5bpm (68bbls). S/D and let well settle out. Blow down lines. Flow check well. Start POOH w/ 3.5" 10.4# work -string and casing scraper. Pump single displacement volume with 9.5ppg brine when POOH. Scraper on surface @ 1700 hours. Break out and lay down scraper. P/U and make up 7-5/8" Baker test packer. Start RIH w/ 7-5/8'test packer and 3.5" 10.4 # work -string. Catwalk/ pipe handler started having mechanical issues. Work on pipe handler. Catwalk down. PCH w/ 1 joint and Test Packer. Close Blind Rams. Troubleshoot hydraulics on Catwalk w/ SRI. Travel to D Pad and shovel out spare Catwalk. Change out Catwalks.. Take non functioning Catwalk to A -Pad to warm up and continue to troubleshoot w/ SRI in the morning. RIH w/ 7-5/8' test packer on 3.5" 10.4 # work -string. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP G-16 ASR#1 50-029-23189-00-00 203-210 12/5/2019 12/10/2019 12/8/2019 -Sunday Crew swaps and check fluids. Continue to RIH w/ 3.5" 10.4# work -string and Baker test packer - packer set once on @ 111 joints in, picked up and reset and continue to RIH. Packer on depth and set @ 5426'. Set packer with 20K down. Pump 14 bbls 9.5ppg brine to load backside. Pressure up to 2700 psi and chart test for 30 minutes for a good test. Bleed off, equalize packer, release packer, Blow down all lines, start to POOH. POOH w/ 3.5" 10.4# work -string pumping single displacement of 9.5ppg NaCl brine every 15 joints and blowing down lines accordingly. Remove 3-1/2" workstring and put in Pipe Tub. Hang SLB Sheave. Load Pits with 100 bbls of 9.5 ppg brine. Lift SLB tools to Rig Floor in Basket. Spot Spooler and R/U to Air Compressor. M/U 3.5" 9.2# Muleshoe Joint, 3 Joints of 3.5" 9.2# Tubing. 3.5" XN Nipple (2.75" ID), TriPoint 7 5/8" x 3-1/2" Retrievable Packer, 3.5" SLB Lower Suction Gauge, and 3.5" XD SSD Sliding Sleeve. Feed Cable over Sheave and connect to Port for Gauge. Install Gauge. Test Gauge to 5,000 psi. Good test. RIH w/ 3-1/2" 9.2 L-80 8rd EUE Tubing while clamping cable the first ten Joints and every other Joint thereafter. Pumping 9.5ppg NaCl brine displacement every 12/9/2019 - Monday Crew swaps and fluid checks. Continue RIH w/3-1/2" EUE 8rnd 9.2# tubing and jet pump completion. Pumping single displacement of 9.5ppg brine every 15 joints. Completed running tubing. 174 joints plus completion jewelry in hole. Begin make up landing joint, lost 30OKW generator, continue to make up landing joint, and pick up hanger. SLB start terminating I -wire thru hanger. Land TBG Hanger, RILDS. RU to Reverse Circulate 80 Bbls of Packer Fluid Followed by 100 bbls of 9.6# Brine. Reverse Circulate 80 Bbls of Packer fluid. Took 35 Bbls to Fill the I.A. @ 2 BPM. Blow Lines Dry. Fill pits with Brine and dust up to proper 9.6#. Finish spotting Packer Fluid 100 Bbls clean Brine. Bleed off and drop Ball and Rod wit 1.25" Ball, 1.99 rollers. Let ball settle fill and the Tbg with 9.6# Brine to 3000Psi and chart 20 Min. Test good Bleed tbg off to 1700 PSI and swap to the I.A. Took 7 Bbls to fill then another 3 Bbls to bring test pressure to 2650PSL Chart for 30 Min Good. Bleed off the TBG and watch shear valve open dropping pressure on I.A. RU Little Red to I.A. to Pump Freeze protect. 94 Bbls down the I.A. RD Little Red. 12/10/2019 - Tuesday Crw Swaps -Complete circulating in freeze protect. Monitor tubing and Install BPV. End of well work for G-16 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Chad Helgeson Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Pool, MPU G-16 Permit to Drill Number: 203-210 Sundry Number: 319-532 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, Je y Chair DATED this�j;day of November, 2019. 1BDMS �� NOV 2 7 2019 RECEIVED NOV 2 0 2Q19 op STATE OF ALASKA AOGCG ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS on eer a ocn I. Type of Request: Abandon El Plug Perforations El Fracture Stimulate ❑ Repair Well ❑ Operations shutdown El Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑✓ Change Approved Program El Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Convert to Jet Pump ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development Q Stratigraphic ❑ Service ❑ 203-210 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-23189-00-00 ' 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 MILNE PT UNIT G-16 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0025518 / ADL0025906 MILNE POINT / SCHRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD: Effective Depth ND: MPSP (Psi) Plugs Plugs (MD): Junk (MD): 9,561' 4,453' 9,561' 4,453' N/A N/A Casing Length Size MD D Burst Collapse Conductor 86' 20" 120' 120' N/A N/A Surface 2,491' 10-3/4" 2,526' 2,465' 5,210psi 2,470psi Intermediate 6227' 7-5/8" 6,260' 4,390' 6,750psi 6,890psi OA Liner 4,348' 4-1/2" 9,991' 4,400' 8,430psi 7,500psi OB Liner 3,203' 4-1/2" 8,978' 4,443' 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 / IBT 5,468' Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft): Baker ZXP LTP 7-5/8" x 5-1/2" and N/A 5,782 MD/ 4,320 ND and N/A 12. Attachments: Proposal Summary �j Wellbore schematic ED 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: 12/7/2019 OIL WINJ ❑ WDSPL ❑ Suspended ❑ 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 prior written approval. Authorized Name: Chad Helgeson Contact Name: David Haakinsonr Authorized Title: Operations Manager Contact Email: dhaakinson hit Or .Coln 7 Contact Phone: 777-8343 Authorized Signature: Date: 11/20/2019 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test 1f Mechanical Integrity Test El Location Clearance F12-. nt Other: a �®'i� ,(� 5' 6 !.. NRDMS.d ^ NAV 2 7 2019 Post Initial Injection MIT Req'd? Yes [JNo ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: APPROVED BY Approved by: �� COMMISSIONER THE COMMISSION Date: v r 6l z+ +5 rr"/ Submit Form and (I '2�1 //II a � (/y,/ Foyrc1D-403 Revis 4/201v 1 l Approved appli� rsv�lillbr�nOm the date of approval. ' Attachments in Duplicate Ff'[• V ` ivR r l /%.,) U Ililc ra Alaska, LLQ RWO — ESP to JP Conversion Well: MPU G-16 11/20/19 Well Name: MPU G-16 API Number: 50-029-23189-00 Current Status: S/I — ESP Failure Rig: ASR #1 Estimated Start Date: December 7, 2019 Estimated Duration. 5 Days Reg.Approval Req'std? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 203-210 First Call Engineer: David Haakinson (907) 777-8343 (0) (307) 660-4999 (M) Second Call Engineer: I Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) AFE: WeIIEZ Entry Required: Yes Current Bottom Hole Pressure: 1,787 psi @ 4,211' TVD 8.22 PPGE I Downhole Gauge 11/14/19 Maximum Expected BHP: 1,830 psi @ 4,211' TVD 8.36 PPGE 130 -day PBU Extrapolation Max. Anticipated Surface Pressure: 1409 psi Gas Column Gradient (0.1 psi/ft) Original RKB: 50'(Doyon 14) Max Inc. (Within Work Interval): 85° @ 5,646' MD Max DLS: 6.5°/100 ft @ 3,151' MD BPV Type: 4" CIW "H" Brief Well Summary: Milne Point producer G-16 was drilled in 2004, and completed as a dual lateral Schrader Bluff OA and OB producer. The well was last worked over in May 2013 and has been a stable 100 BOPD producer until Q2 2019, when the well developed a tubing leak. Attempts were made to patch the 4-1/2" tubing, but were unsuccessful due to a long interval of under -deposit corrosion. The cause of the corrosion is likely due to too large of fluid. Due to the fact that the well has never received a fill cleanout, combined with historical ESP wear, a jet pump completion is proposed to offer better economics. A lateral entry module was never installed on the well and thus it is only expected that a single lateral will be cleaned out. Notes Regarding the Well & Design: • The 7-5/8" production casing has not been pressure tested since its initial completion in 2004. The production casing will be tested in this RWO. • Offset Injector Support: o G-03: Shut-in o G-19: Shut-in RWO Objective: 1. Pull ESP completion 2. Cleanout Run and Test Packer run. 3. Run a new 3-1/2" tubing completion with jet pump jewelry 4. Obtain passing MIT -IA Pre -Rig Procedure 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services Pump. Setup reverse out skid, returns tank, and additional upright tanks as needed. 4. Pressure test lines to 3,000 psi. 5. Bullhead 8.5 ppg weighted source water down tubing to formation. �'w'f a. Tubing volume to top of OA lateral: 100 bbls n tiilava Alaska, LU RWO — ESP to JP Conversion Well: MPU G-16 11/20/19 6. Bullhead 8.5 ppg weighted source water down the IA to formation. 7. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 8. RD Little Red Services Pump and reverse out skid. 9. RU crane. Set BPV. ND Tree. NU 11" BOPE. RD crane. $� a. Make scribe mark on tree for orientation for re -installation. b. Function test all prior to arrival of AOGCC inspectors. 10. NU BOPE house. Spot mud boat. Workover Procedure: 11. MIRU ASR #1 Workover rig, ancillary equipment and lines to returns tank. 12. Pull BPV after confirming zero surface wellhead pressure. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/ 8.5 ppg weighted source -water ppgr to pulling BPV. Set TWC. 13. Test BOPE to 250psi Low/ 2,500 psi High, annular to 250psi Low/ 24u0 psi High (hold each ram/valve and test for 5 -min). Record accumulator pre -charge pressures and 6art tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hrs in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR rams on 2-7/8" & 4-1/2" test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 14. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down -hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 15. Bleed any pressure off casing to returns tank. Pull TWC. 16. RU spooler to pull #2 ESP cable. 17. MU 4-1/2" landingjoint and BOLDS. 18. Unseat hanger and pull over string weight on tubing and confirm free. a. The 2013 RWO (Doyon 16) PU weight was 108 Klbs with a slack -off weight of 72 Klbs. PY i. 40 Klb Top drive weight included. PCb. Once hanger becomes free check for flow to insure well is dead. LD Tubing hanger. RWO - ESP to JP Conversion ff Well: MPU G-16 11/20/19 IIamm Alaska. LL, c. 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. 19. Pull the 4-1/2" tubing from ±5,468' MD. Note that the through tubing ESP was pulled prior to the RWO. a. Total Clamp Count: i. 135 Cannon Clamps ii. 3 Protectolizers iii. 2 Flat Guards b. Send tubing to G&I for cleaning and disposal. c. Inspect XN Nipple and 2 GLMs. Clean and plan to re -stock in materials inventory. i. Note condition of pipe in report. Denote depths of any external corrosion, solids, or scale. ii. Photograph and file pictures. 20. MU 7-5/8" casing scraper assembly and TIH to ±5,600' MD. 21. Reciprocate from ±5,400' to ±5,450' and circulate 2x bottoms up from ±5,450' MD. 22. POOH and lay down casing scraper BHA assembly. 23. PU serviced 7-5/8" test packer and RIH to ±5,420' MD. 24. Pressure Test 7-5/8" casing to 2,500 psis for 30 minutes a. If pressure test fails, begin moving up -hole and testing in intervals to determine possible leak point. 25. POOH w/ test packer and lay down equipment. 26. Call out Baker Hughes to run downhole gauges on completion. 27. PU 3-1/2" tubing completion and space out as followed: a. WLEG @ ±5,550' MD b. -3 joints of 3-1/2" tubing c. Pup Joint: 3-1/2" L-80 tubing d. 3-1/2" XN Nipple (2.75" ID) w/ RHC plug body e. Pup Joint: 3-1/2" L-80 tubing f. Retrievable Packer (7-5/8" x 3-1/2" Packer) @ ±5,420' MD g. Pup Joint: 3-1/2" L-80 tubing h. Suction Gauge i. Pup Joint: 3-1/2" L-80 tubing j. 3-1/2" XD Sliding Sleeve (Closed Position) @ ±5,390' MD k. Pup Joint: 3-1/2" L-80 tubing .� I. "'99 joints of 3-1/2" tubing m. 3-1/2" GLM with SOV @ ±2,270' MD n. -73 joints 3-1/2" L-80 tubing o. 3-1/2" to 4-1/2" crossover p. Tubing hanger 28. Run tubing completion in hole, spacing out to set packer @ ±5,420' MD H llilwra Alaska, Lb RWO — ESP to JP Conversion Well: MPU G-16 11/20/19 29. Prior to seating overshot, reverse circulate 17 bbls of 1% CRW (or equivalent corrosion inhibitor) 8.5 ppg weighted source water, followed by 172 bbls of untreated 8.5 ppg source water down IA. a. This will spot corrosion inhibited fluid between packer and sliding sleeve. 30. Obtain pick-up and slack -off weights and note band/clamp summary. 31. Land the tubing hanger. Terminate downhole gauge wire. 32. Drop ball and rod and allow to fall on seat in RHC plug body in XN nipple. 33. Set packer per packer setting procedure. 34. Increase the tubing pressure and test the tubing to 3,000 psig. i 35. Bleed down the tubing to 1,500 psig. vl� 6 36. Pressure IA up to 2.800 psig and perform a Charted MIT -IA for a minimum target pressure of 2 S00 psi for 30 min (charted). a. Noti{ ntion to the AOGCC for witsed test needs to be su rnitted 24 hrs prior to conducting test. / L---�, Nowl< 4,o 37. Bleed tubing pressure to shear out the shear -out GLV in the GLM at ±2,270' 38. Pump 94 bbls of diesel down the IA and U-tube to the tubing to freeze protect the well. 39. Bleed tubing and inner -annulus pressures to zero. 40. RILDS and LD landingjoint. 41. Set BPV. 42. Test tubing hanger void to 500 psig low / 5000 psig high. 43. RD Hilcorp ASR #1 WO Rig, ancillary equipment and lines to returns tank. Post WorkoverProcedure: 44. RD mud boat. RD BOPE house. 45. RU crane. ND BOPE. Pull BPV. Set TWC. 46. NU 4-1/16" s 09QUIcee and adapter flange and test to 500 psi low/5,000 psi high. 47. Pull TWC. RD crane. 48. Move returns tank and rig mats. 49. Turn well over to wells team for post rig slickline work. 50. RU Slickline a. Pull Ball & Rod from XN-Nipple b. Set Catcher in XN-Nipple c. Pull SOV from GLM @ ±2,270' MD d. Set DV in GLM @ ±2,270' MD e. Shift open XD Sliding Sleeve f. Install jet pump in XD sliding sleeve. g. RD Slickline. h. Turn well over to operations. Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOP Schematic n Hfleo,p Alaska, LLC Orig. KB Elev.: 62.90'/ Orig. GL Elev.: 29.5' RKB-Hanger: 22.60' (Doyon#16) 163/4" 2B 1 2 3 4&5&6 7 8 9 10 711 I r i12 I 13&14 15 :16 SCHEMATIC Milne Point Unit Well: MPU G-16 Last Completed: 5/25/2013 PTD: 203-210 TRFF R VJFI I HFOn Tree 4-1/2"-%M Cameron Wellhead SM Gen 511"x11"w/4-1/2"TC-II T&B Hanger 4.5" CIW'H' BPV Profile OPEN HOLE / CEMENT DETAIL 20" 260 sx of Arcticset (Approx) in 42" Hole 10-3/4" 1 450 sx PF'L', 260 sx Class "G" in 13-1/2" Hole 7-5/8" 1 670 sx Class "G" in 9-7/8" Hole CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 20" Conductor 92/H-40/Welded N/A Surface 120' 10-3/4" Surface 45.5/L-80/BTL 9.950 Surface 2,527' 7-5/8" Production 29.7/L-80/BTC-MOD 6.750 Surface 6,260' 4-1/2" Liner 12.6/L-80/IBT 3.833 5,643' 9,991' 4-1/2" Liner "OB" 12.6 / L-80 /IBT 3.833 5,775' 8,978' TUBING DETAIL 4-1/2" Tubing 12.6/L-80/IBT 3.833 Surf 5,468' WELL INCLINATION DETAIL FOP @ 200' MD 60+deg From 3,800' Max Wellbore Angle= 66.0 deg @ 5,550' MD JEWELRY DETAIL No Top (MD) Item 1A 155'Sta #2: GLM - Camco KBG-2 4-1/2" x 1" - OGLV set 7/31/2004 BK Latch 2B 5,203' Sta#1: GLM -Camco KBG-2 4-1/2" x 1" - DGLV set 7/31/2004 BK Latch 1-6 5,403' TTC-ESP Removed with Slickline 8-16-19 7 5,415' Discharge Head: 380 PUMP 8 5,416' Pump: 116-P18 P2P 9 5,436' Intake: 380 GSVTHV XM (High Volume) 10 5,440' Pump Eye: TTCESP 11 5,422' Crossover: 4-1/2" IBT Box X, 4-1/2" NSTC Pin, 12.6 # 12 5,432' TTC Drilled Tubing Crossover: TTC 4-1/2" NSTC BOX 13 5,442' Upper Tandem Seal: GSB3 DB HL H6 PFS 14 5,449' Lower Tandem Seal: GS63 DB HL H6 PFS 15 5,456' Motor: CL -5, MSPS-250-210Hp/2,380V/53A 16 5,464' Sensor: Pheonix XT150 Type 17 5,466' Centralizer: Six Fin - BTM @ 5.468' 18 5,643' OA Lateral Hook Wall, Hanger above 7-5/8" Window 19 5,660' OA Lateral Hook Wall, Hanger below 7-5/8" Window 20 5,775' OB Lateral Tie Back Sleeve 5,782' OB Lateral ZXP Liner Top Packer a2324 5,788' OB Lateral 7-5/8" x 5-1/2" HMC Liner Hanger 9,991' OA Lateral 4-1/2" Btm of Guide Shoe 8,978' OB Lateral 4-1/2" Btm of Guide Shoe 'e "OA"Later Slotted Liner 23 :w 20 22 �OB'Laleal Slotted Liner 2q TD = 9,561' (MD) / TD = 4,453'(TVD) PBTD=9,561' (Mi /TD=4,453'(TVD) LATERAL WINDOW DETAIL GENERAL WELL INFO API: 50-029-23189-00-00 Drilled and Completed by Doyon 14-2/03/2004 Convert to TTC-ESP by Doyon 16 - 5/25/2013 Revised By: W.Kruskie 8/20/2019 K Uilcorn Alaeka. LLC Orig. KB Elev.: 62.90'/ Orig. GL Eley.: 29.5' RKB— Hanger- 22.60' (Doyon 016) 1U/4" i I NA 2 7 10 PROPOSED Milne Point Unit Well: MPU G-16 Last Completed: 5/25/2013 PTD: 203-210 TREE & WELLHEAD Tree 4-1/2" -%MCameron Wellhead SM Gen511"x11"w/4-1/2"TC-II Top T&B Hanger 4.5" CIW'H' BP/Profile OPEN HOLE / CEMENT DETAIL 20" 260 sx of Arcticset (Approx) in 42" Hole 30-3/4" 450 sx PF'L', 260 sx Class "G" in 13-1/2" Hole 7-5/8" 670 sx Class "G" in 9-7/8" Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 92/H-40/Welded N/A Surface 120' 10-3/4" Surface 45.5/L-80/BTC 9.950 Surtace 2,527' 7-5/8" Production 29.7/L-80/BTC-MOD 6.875 Surface 6,260' 4-1/2" Liner"OA" 12.6/L-80/IBT 3.958 5,643' 9,991' 4-1/2" Liner "OB" 12.6/L-80/IBT 3.958 5,775' 5,978' TUBING DETAIL 3-1/2" Tubing 9.2/L-80 /EUE Srd 3.992 Surface ±5,550' WELL INCLINATION DETAIL KOP @ 200' MD 60+ deg From 3,800' Max Wellbore Angle = 66.0 deg @ 5,550' MD JEWELRY DETAIL No Top (MD) Item 1 332' Crossover (4-1/2" x 3-1/2") 2 ±2,270' 3-1/2" Gas Lift Mandrel 3 ±5,390' XD Sliding Sleeve 4 ±5,404' Lower Suction Gauge 5 ±5,420' Retrievable Packer (7-5/8" x 3-1/2"J 6 ±5,446' XN Nipple 7 ±5,550' WLEG-Bottom@±5,550 8 5,643' OA Lateral Hook Wall, Hanger above 7-5/8" Window 9 5,660' OA Lateral Hook Wall, Hanger below 7-5/8" Window 10 5,775' OB Lateral Tie Back Sleeve 11 5,782' OB Lateral ZXP Liner Top Packer 12 5,788' 08 Lateral 7-5/8" x 5-1/2"HMC Liner Hanger 13 9,991' OALatemI4-1/2" Btm of Guide Shoe 14 8,978' OB Lateral4-1/2" Btm of Guide Shoe Window LATERAL WINDOW DETAIL I Top of "OB" Window @ 5,775' MD; Bottom @ 5,788' MD; Angle @ top of window is 77 dee —1 13 GENERAL WELL INFO 4 API: 50-029-23189-00-00 Drilled and Completed by Doyon 14 — 2/03/2004 5 Convert to TTC-ESP by Doyon 16 — 5/25/2013 8 -tea Slotted Liner 13 w.77ex. 12 'WLallod Slotted Liner 14 73/8' \ TO=9,561' (MD)/TD= 4ASY(TVD) PRrD=9,561'(MD)/TD=4,453'(FVD) Revised By: TDF 11/14/2019 Milne Point ASR Rig 1 BOPE 2019 11" BOPE Updated 5/14/2018 2-7/8" x 5" VBR lind es STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ,�- n :� rte. rIj AUG ',I,.^ ' � C_tJ' 1. Operations Abandon Plug Perforations Fracture Stimulat Pull Tubing Operations shutdownLi Performed: Suspend ❑ Perforate ❑ Other Stimulat Alter Casin g ❑ Change Approved Program ❑ Plug for Redrill ❑ :rforate New Pool ❑ Repair Wel❑ Re-enter Susp Well ❑ Other: Tubing Patch2. ❑� Hilcorp Alaska LLC 4. Well Class Before Work:5. Permit to Drill Number: Nameerator Development ❑� Slratigraphic ❑ Exploratory ❑ Service ❑ 203-2 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-029-23189-00-00 lilCr� 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025518 / ADL0025906 MILNE PT UNIT G-16 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 9,561 feel Plugs measured N/A feel true vertical 4,453 feet Junk measured N/A feet Effective Depth measured 9,561 feet Packer measured 5,782 feet true vertical 4,453 feet true vertical 4,320 feet Casing Length Size MD TVD Burst Collapse Conductor 86' 20" 120' 120' N/A N/A Surface 2,491' 10-3/4" 2,526' 2,465' 5,210psi 2,470psi Intermediate 6,227' 7-5/8" 6,260' 4,390' 6,750psi 6,890psi OA Liner 4,348' 4-1/2" 9,991' 4,400' 8,430psi 7,500psi OB Liner 3,203' 4-1/2" 8,978' 4,443' 8,430psi 7,500psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# / L-80 / IBT 5,468' 4,217' Baker ZXP LTP 7 - Packers and SSSV (type, measured and true vertical depth) 5/8" x 5-1/2" 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: 10 0 0 300 1 0 Subsequent to operation: 0 0 0 620 10 14. Attachments (required per 20 AAC 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory[] Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Q Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-236 Authorized Name: Chad Helgeson Contact Name: David Haakinso Authorized Title: Operations Manager Contact Email: dhaakinSon(hilcorD.co Authorized Signature: Date: 8/20/2019 Contact Phone: 777-8343 Form 10-004 Revised 4/2017 -1BDMS AUG 2 6 2019 Submit Original Only _) 0 Hilmm Alaeke, Ii.0 Or!& KB Elev.: 62.90'/ Orig. GL Bev.: 29.5' SCHEMATIC Milne Point Unit Well: MPU G-16 Last Completed: 5/25/2013 PTD: 203-210 TREE & WELLHEAD Tree 4-1/2"-%M Cameron Wellhead SM Gen 511"x11"w/4-1/2"TC-II Size Type Wt/ Grade/ Conn Drift ID Top Btm T&B Hanger 4.5" CI W 'H' BPV Profile OPEN HOLE/ CEMENT DETAIL _ 20" 260sxof Arcticset(Approx) in42"Hole l_ 10-3/4" 450 sx PFT, 260 sx Class "G" in 13 -1/2 -Role 1 7-5/8" 670 sx Class "G" in 9-7/8" Hole CASING DETAIL 10-3/4' Top(MD) Item t Size Type Wt/ Grade/ Conn Drift ID Top Btm 20" Conductor 92/H-40/Welded N/A Surface 120' 10-3/4" Surface 45.5/L-80/BTC 9.950 Surface 2,527' 7-5/8" Production 29.7/L-80/BTC-MOD 6.750 Surface 6,260' 4-1/2" Liner"OA" 12.6/L-80/IBT 3.833 5,643' 9,991' 4-1/2" Liner "OB" 12.6/ L-80 / IBT 3.833 5,775' 8,978' TUBING DETAIL @ 4-1/2" Tubing 12.6/L-80/IBT 1 3.833 1 Surf 5,468' 4.o7ssMs5mis WELL INCLINATION DETAIL KD @ 200' MD 60+deg From 3,800' 28 Max Wellbore Angle =66.Odeg @5,550'MO JEWELRY DETAIL &5&6 13&14 15 :16 17 ;18 No Top(MD) Item 3A 155' Sta #2: GLM -Camco KBG-2 4-1/2" x 1" - OGLV set 7/31/2004 BK Latch 2B 5,203' Sta #1: GLM -Camco KBG-2 4-1/2" x 1" -DGLV set 7/31/2004 BK Latch 1 5,403' D&D Tubing Stop: AA w/ 4" GS FN 2 5,405' D&D Pack -off: DDIC Hi -Flow w/ Peek Rings D&D Kobe Knockout 6 5,413' Hanger Receptacle: 4"'G' Fishing Neck, 4-1/2" X 2-3/8" EUE 8RD Pin 12.6/12.75# 7 5,415' Discharge Head: 380 PUMP 8 5,416' Pump: 116-P18 P2P 9 5,436' 1 Intake: 380 GSVTHV XM (High Volume) 30 5,440' Pump Eye: TrCESP 11 5,422' Crossover: 4-1/2" IBT Box X, 4-1/2" NSTC Pin, 12.6 # 12 5,432' TTC Drilled Tubing Crossover: TTC 4-1/2"NSTC BOX 13 5,442' Upper Tandem Seal: GSB3 OR HL H6 PFS 14 5,449' Lower Tandem Seal: GSB3 DB HL H6 PFS 15 5,456' Motor: CL -5, MSPI-250- 21011p/ 2,38OV/ 53A 16 5,464' Sensor: Pheonix XT150 Type 0 17 5,466' Centralizer: Six Fin - BTM @ 5.468' 18 5,643' OA Lateral Hook Wall, Hanger above 7-5/8" Window 19 5,660' OA Lateral Hook Wall, Hanger below 7-5/8" Window 20 5,775' OB Lateral Te Back Sleeve 21 5,782' OB Lateral ZXP Liner Top Packer 22 5,788' OB Lateral 7-5/8" x5-1/2" HMC Liner Hanger 23 9,991' OA Lateral 4-1/2" Btm of Guide Shoe 24 8,978' OB Lateral 4-1/2" Btm of Guide Shoe LATERAL WINDOW DETAIL Top of "OA" Window @ 5,648' MD; Bottom @ 5,673' MD; Angle @ [op of window is 72 deg Top of "OB" Window @ 5,775' MD; Bottom @ 5,788' MD; Angle @ top of window is 77 deg 'QV Lateral Slotted Liner 23 .n 20 71 "�'�� Slotted liner 24 7-5/8' TD=9,561' (ND)/TD=4,45TCM) PBTD=9,561' (ND)/TD=4,453'(TVD) GE NERAL WELL INFO API: 50-029-23189-00-00 Drilled and Completed by Doyon 14-2/03/2004 Convert to TTC-ESP by Doyon 16 -5/25/2013 Revised By: TDF 8/20/2019 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP G-02 Slickline 50-029-21926-00-00 189-028 6/2/2019 8/17/2019 Daily Operations, 5/29/2019- Wednesday No operations to report. 5/30/2019 -Thursday No operations to report. 5/1/2019 - Friday No operations to report. 6/1/2019 -Saturday No operations to report. 6/2/2019 -Sunday **WELL S/I ON ARRIVAL, NOTIFY PAD -OP, PT PCE 200L/2,500H**. FIND HOLE AT 4,079' SLM WITH ROPE LEAK DETECT WITH LRS PUMPING DOWN TBG (flag). PULL D&D PACKOFF TEST TOOL FROM 5,403' SLM/5,403' MD AND SET D&D TBG STOP AT SAME DEPTH. SET D&D PACKOFF PATCH BETWEEN 4,059' SLM AND 4,087' SLM. ***D&D PACKOFF PATCH: SLIP STOP= 21", D&D PACKOFF/ 2-7/8" TBG/STINGER= 278", D&D PACKOFF= 34", SLIP STOP= 21"*** 6/3/2019 - Monday No operations to report. 6/4/2019 -Tuesday No operations to report. 5 d Pt-- Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig I API Number Well Permit Number Start Date End Date MP G-16 Slickline 1 50-029-21926-00-00 189-028 6/2/2019 8/17/2019 Daily Operations. 6/12/2019- Wednesday No operations to report. 6/13/2019 -Thursday Freeze Protect (PT surface equip to 250/2500 psi) Pump 15 bbls Dsl down Tbg. 6/14/2019 -Friday No operations to report. 6/15/2019 -Saturday No operations to report. 6/16/2019 -Sunday No operations to report. 6/17/2019 - Monday No operations to report. 6/18/2019 -Tuesday No operations to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP G-16 Slickline 50-029-21926-00-00 189-028 6/2/2019 8/17/2019 Daily Operations. 6/19/2019- Wednesday No operations to report. 6/20/2019 -Thursday No operations to report. 6/21/2019 - Friday No operations to report. 6/22/2019 -Saturday No operations to report. 6/23/2019 -Sunday No operations to report. 6/24/2019 - Monday No operations to report. 6/25/2019 -Tuesday Fluid level shot G-16 T/I/O 320/340/0 Fluid level at .5 on tubing and .6 on IA. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP G-16 Slickline 50-029-21926-00-00 189-028 1 6/2/2019 8/17/2019 Daily Operations. 6/26/2019- Wednesday T/1/0=300/260/0 Freeze Protect Tbg (PT surface equip to 250/1000 psi) Pump 25 bbls diesel down tbg. 6/27/2019 - Thursday No operations to report. 6/28/2019 - Friday No operations to report. 6/29/2019 -Saturday No operations to report. 6/30/2019 -Sunday No operations to report. 7/1/2019 - Monday No operations to report. 7/2/2019 -Tuesday No operations to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MPG -16 Slickline 50-029-21926-00-00 189-028 6/2/2019 8/17/2019 Daily Operations. 8/14/2019- Wednesday No operations to report. 8/15/2019 -Thursday No operations to report. 8/16/2019 - Friday PULL D&D TBG STOP AT4057' SUM. TEST UPPER PACK -OFF AND TBG ABOVE PATCH W/D&D PACKOFF TEST TOOL. HAVE LRS PRESSURE UP ON TBG 1000#, MONITOR FOR 15min, UPPER PACK -OFF AND TBG ABOVE PATCH HOLDING SOLID. PULL D&D PACK -OFF/ PATCH AND LOWER PACK -OFF @ 4060' SUM. PULL D&D TBG STOP AT4088' SUM. PULL D&D TBG STOP AT 5403' SUM. 8/17/2019 -Saturday WELL S/1 ON ARRIVAL, NOTIFY PAD -OP, PT PCE 200L/2000H. RUN PDS 40 ARM CALIPER TOOL PER PROCEDURE, GOOD DATA. 8/18/2019 -Sunday No operations to report. 8/19/2019 - Monday No operations to report. 8/20/2019 -Tuesday No operations to report. CJ�r THE STATE °fALASKA 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 G-16 Permit to Drill Number: 203-210 Sundry Number: 319-236 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 w .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, 01)� Daniel T. Seamount, Jr. Commissioner DATED this q day of May, 2019. RBDm MAY 0 9 IM RECEIVED STATE OF ALASKA MAY 0 8 2019 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 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: Tubing Patch ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development 0 - Stratigraphic ❑ Service ❑ 203-210 - 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-23189-00-00 ' 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 G-16 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0025518 / ADL00259( I 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): 9,561' 4,453' - 9,561' 4,453' 991 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor W. 20" 120' 120' N/A N/A Surface 2,491' 10-3/4" 2,526' 2,465' 5,210psi 2,470psi Intermediate 6,227' 7-5/8" 6,260' 4,390' 6,750psi 6,890psi OA Liner 4,348' 4-1/2" 9,991' 4,400' 8,430psi 7,500psi OB Liner 3,203' 4-1/2" 8,978' 4,443' 8,430psi 7,500psi 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-8-/ IBT 5,468' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker ZXP LTP 7-5/8" x 5-1/2" and N/A 5,782 MD/ 4,320 TVD and N/A 12. Attachments: Proposal Summary Wellbore schematic ❑✓ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 5/15/2019 OIL 0 WINJ ❑ WDSPL ❑ Suspended ❑ 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 prior written approval. Authorized Name: Chad Helgeson Contact Name: David Haakinson Authorized Title: Operations Manager Contact Email: dhaakinson hllcor .Colli Contact Phone: 777-8343 Authorized Signature: Date: 5/8/2019 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31q -23U Plug Integrity ❑ BOP Test E]Mechanical Integrity Test E]Location Clearance ❑ Other: RBDMSN� MAY 0 9 2019 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: / 0 — 4ilf 4) U APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 51W1 7 Submit Form and rm 10-403 Revised 4M1017 Approved application is veli or months rom date of approval. Attachments'n Duplicate L9/gl% i • 7iY U Hilcaru Alaska, LU Tubing Patch Well: MPU G-16 Date: 05-07-19 Well Name: MPU G-16 API Number: 50-029-23189 Current Status: Online- ESP Producer Pad: G -Pad Estimated Start Date: May 15th, 2019 Rig: SL Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: N/A Regulatory Contact: Tom Fouts Permit to Drill Number: 203-210 First Call Engineer: David Haakinson (907) 777-8343 (0) (307) 660-4999 (M) Second Call Engineer: Wyatt Rivard (907) 777-8547 (0) (509) 670-8001 (M) AFE Number: Job Type: Tubing Patch Current Bottom Hole Pressure: 1377 psi @ 4,294' TVD 3 -day ESP Shutdown (6/27/16) 16.17 PPG Maximum Expected BHP: 1420 psi @ 4,294' TVD PBU in next 3 -weeks 16.35 PPG MPSP: 991 psi Gas Column Gradient (0.1 psi/ft) Max Inclination 63° @ 4,110' MD Max Dogleg: 6.5'/100ft @ 3,152' MD Brief Well Summary: MPU G-16 was drilled and completed as a Schrader OA and OB dual lateral producer in January 2004. A RWO was completed in May 2013 to convert the producer to a through -tubing retrievable ESP producer. The first TTC-ESP ran for approximately five months before shut -down in what appears to be a solids production event. The previous ESP was installed in December 2013 and achieved a 5.3 year run life. Over the last six months, the pump appears to have been wearing. On 4/12/19, the pump lost complete head generation in what now appears to be due to a tubing leak. i Notes Regarding Wellbore Condition • TTC-ESP Installed on 4/30/19. Subsequently failed tubing tests afterward. • Tubing Leak identified at 4,079' SLM utilizing rope. • Tight spot in tubing @ 3,760' SLM w/ 3.84" OD tools. Objective: • Set D&D tubing patch (Sundry Approval Required) • Backup Contingency: o Memory Caliper o Memory Spinner Log o E -line Paragon packer patch Procedure Slickline 1. MIRU SL. PT lubricator to 200 psig low, 2000 psig high. 2. Set junk catcher on top of D&D pack -off @ 5,402' MD a. Prevent tubing solids/scale from landing on top of ESP. 3. Brush and Flush tubing at patch setting interval (+/- 20' up/down from leak point). 4. RIH w/ rope leak detect to leak interval and locate leak depth. Flag wire and POOH. 5. Pull junk catcher from depth @ 5,402' MD. H Hil.n, Alaska, LLI 6. Pull D&D pack -off test tool from pack -off @ 5,402' MD. 7. Set D&D tubing stop on top of D&D pack -off @ 5,402' MD. 8. RIH with tubing slip -stop to 10' below leak depth. 9. Set D&D pack -off on slip -stop. 10. RIH with stinger, 20' spacer pipe (2-7/8" tubing), and upper D&D pack -off. 11. Land in lower D&D pack -off and set upper D&D pack -off. 12. RIH with D&D test tool and land in upper packer. Tubing Patch Well: MPU G-16 Date: 05-07-19 13. PT tubing to 1000 psig to confirm upper packer and up -hole tubing integrity. 14. After passing test, RIH w/ 4.5" tubing stop and set on top of upper D&D pack -off. 15. RDMO Slick -line and LRS. Leave well SI. Contingency Tubing Patch Set (If D&D patch is unsuccessful) Slickline 1. MIRU SL. PT lubricator to 200 psig low, 2000 psig high. 2. Pull D&D tubing patch. 3. Set D&D pack -off test tool in D&D pack -off @ 5,402' MD 4. RIH with 24 -arm memory caliper to 30' above D&D pack -off @ 5,402' MD. S. POOH @ 50 fpm to surface for caliper survey. 6. Confirm good caliper data. 7. RU LRS 8. RIH with memory full -bore spinner, pressure, temperature, and GR/CCL. a. Come online with pump rate at 0.5 to 0.8 BPM (previous leak rate). b. Please utilize source -water for the leak detect. c. GR/CCL will be utilized for future depth correlation if E -line is used. d. Perform down -pass at 60 fpm to 5,350' MD 9. Perform 60 fpm up -pass from 5,350' MD to surface. 10. Pull D&D pack -off test tool from D&D pack -off @ 5,402' MD E -line 1. MIRU EL. PT lubricator to 200 psig low, 2000 psig high. 2. RIH with GR/CCL and 4.5" paragonk� nd set packer mid -element @ +/-4,090' MD a. Correlate to SL Memory Spinner/GR/CCL. b. Note that final depth will be determined post spinner log completion. Slickline 3. MIRU SL. PT lubricator to 200 psig low, 2000 psig high. 4. RIH with latch seal assembly, +/- 20' of 2-3/8" spacer pipe, and top 4.5" paragon packer. 0 flilcnq� AI.A., LL, 5. Land in lower paragon packer and set top packer mid -element @ +/- 4,070' MD 6. RIH with 4.5" paragon packer test tool and land in upper packer. 7. PT tubing to 1000 prig to confirm upper packer and up -hole tubing integrity. 8. RDMO Slick -line Tubing Patch Well: MPU G-16 Date: 05-07-19 0 cora Alaska. LLC Orig. KB Elev.: 62.90'/ Orig. GL Elev.: 29.5' RKB- Hanger: 22.60' (Doyon #16) 10-3/4" -eakdetected @ 11,079'S-10562019 SCHEMATIC Milne Point Unit Well: MPU G-16 Last Completed: 5/25/2013 PTD: 203-210 TREE & WELLHEAD Tree 4-1/2" -%M Cameron 10-3/4" SM Gen 511" x 11"w/4-1/2" TC -II Wellhead T&B Hanger 4.5" CIW'H' BPV Profile OPEN HOLE / CEMENT DETAIL 20" 260 sx of Arcticset (Approx) in 42" Hole 10-3/4" 450 sx PF V, 260 sx Class "G" in 13-1/2" Hole 7-5/8" 670 sx Class "G" in 9-7/8" Hole CASING DETAIL Size Type Wt/Grade/Conn Drift I Top Btm 20" Conductor 92/H-40/Welded N/A Surface 120' 10-3/4" Surface 45.5 / L-80 / BTC 9.950 Surface 2,527' 7-5/8" Production 29.7/L-80/BTC-MOD 6.750 Surface 6,260' 4-1/2" Liner"OA" 12.6 / L-80 / IBT 3.833 5,643' 9,991' 4-1/2" Liner"OB" 12.6 / L-80 / IBT 3.833 5,775' 8,978' TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / IBT 1 3.833 1 Surf 1 5,468' WELL INCLINATION DETAIL KOP @ 2MD 60F deg 00' From 3,800' 2 Max Wellbore Angle =66.0 deg @5,550'MD 10 4&s&6 13 & 14 JEWELRY DETAIL No Top (MID) Item 155' Ste #2: GLM - Carrico KBG-2 4-1/2" x 1" -OGLV set 7/31/2004 BK Latch 5,203' Ste #1: GLM -Carrico KBG-2 4-1/2" x I" - DGLV set 7/31/2004 BK Latch 1 5,403' D&D Tubing Stop: AA w/4" GS FN 2 5,405' D&D Pack -off: DDIC Hi -Flow w/ Peek Rings D&D Kobe Knockout 6 5,413' Hanger Receptacle: 4"'G' Fishing Neck, 4-1/2" X 2-3/8" EUE 8RD Pin 12.6/12.75# 7 5,415' Discharge Head: 380 PUMP 8 5,416' Pump: 116-P18 P2P 9 5,436' Intake: 380 GSVTHV XM (High Volume) 10 5,440' Pump Eye: TTCESP 11 5,422' Crossover: 4-1/2" IBT Box X, 4-1/2" NSTC Pin, 12.6 # 12 5,432' TTC Drilled Tubing Crossover: TFC 4-1/2" NSTC BOX 13 5,442' Upper Tandem Seal: GSB3 DB HL H6 PFS 14 5,449' Lower Tandem Seal: GSB3 DB HL H6 PFS 15 5,456' Motor: CL -5, MSP1-250- 210Hp/ 2,380V/ 53A 16 5,464' Sensor: Pheonix XT150 Type O 17 5,466' Centralizer: Six Fin - BTM @ 5.468' 18 5,643' OA Lateral Hook Wall, Hanger above 7-5/8" Window 19 5,660' OA Lateral Hook Wall, Hanger below 7-5/8" Window 20 5,775' OB Lateral Tie Back Sleeve 21 5,782' OB Lateral ZXP Liner Top Packer 22 5,788' OB Lateral 7-5/8" x 5-1/2" HMC Liner Hanger 23 9,991' OA Lateral 4-1/2" Btm of Guide Shoe 24 8,978' OB Lateral 4-1/2" Btm of Guide Shoe LATERAL WINDOW DETAIL Top 0::" f "OA" Window @ 5,648' MO; Bottom @ 5,673' MD; Angle @ top of window is 72 deg Top of "OB" Window @ 5,775' MD; Bottom @ 5,788' MD; Angle @ top of window is 77 deg "` '� ,•a4° Lateal Slotted Liner 23 20 . . 22 "OB' Baal Slotted Liner 24 7-5/rii TD=9,561' (ND)/TD=4,453'(TVD) P8TD=9,561' (MD)/TD=4,453'(ND) GENERAL WELL INFO AP50-029-23189-00-00 DrillI: ed and Completed by Doyon 14 - 2/03/2004 Convert to TTC-ESP by Doyon 16-5/25/2013 Revised By: TDF 5/8/2019 Orig. KB Elev.: 62.90'/ Orig. GL Elev.: 29.5' RKB-Hanger: 22.60' (Doyon#16) 10-3/4" Popo Tubing Padhfr=A,065to ±4,089.� Milne Point Unit Well: MPU G-16 PROPOSED Last Completed: 5/25/2013 PTD: 203-210 TREE & WELLHEAD Tree 1 4-1/2" - %M Cameron Wellhead 5M Gen 511"x11"w/4-1/2"TC-II T&B Hanger 4.5" CIW'H' BPV Profile OPEN HOLE / CEMENT DETAIL 20" 260 sx of Arcticset (Approx) in 42" Hole 30-3/4" 450 sx PF'L', 260 sx Class "G" in 13-1/2" Hole 7-5/8" 670 sx Class "G" in 9-7/8" Hole CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 20" Conductor 92/H-40/Welded N/A Surface 1267-- 10-3/4" Surface 45.5 / L-80 / BTC 9.950 Surface 2,527' 7-5/8" Production 29.7 / L-80 / BTC -MOD 6.750 Surface 6,260' 4-1/2" Liner "OA" 12.6 / L-80 / IBT 3.833 5,643' 9,991' 4-1/2" Liner "OB" 12.6/L-80/IBT 3.833 5,775' 8,978' TUBING DETAIL 4-1/2" Tubing 12.6/L-80/I13T 3.833 1 Surf 1 5,468' WELL INCLINATION DETAIL KOP @ 200' MD 60+deg From 3,800' 2 Max Wellbore Angle = 66.0 deg @ 5,550' MD 4&5&6 13&14 15 16 JEWELRY DETAIL No Top (MD) Item 155' Sta #2: GLM - Camco KBG-2 4-1/2" x 1" - OGLV set 7/31/2004 BK Latch 5,203' Sta#1: GLM -Camco KBG-24-1/2"x1"-DGLV set 7/31/2004 BK Latch 1 5,403' D&D Tubing Stop: AA w/ 4" GS FN 2 5,405' D&D Pack -off: DDIC Hi -Flow w/ Peek Rings D&D Kobe Knockout 6 5,413' Hanger Receptacle: 4"'G' Fishing Neck, 4-1/2" X 2-3/8" EUE 8RD Pin 12.6/12.75# 7 5,415' Discharge Head: 380 PUMP 8 5,416' Pump: 116- P38 P2P 9 5,436' Intake: 380 GSVTHV XM (High Volume) 30 5,440' Pump Eye: TTCESP 11 5,422' Crossover: 4-1/2" IBT Box X, 4-1/2" NSTC Pin, 12.6 # 12 5,432' TTC Drilled Tubing Crossover: TTC 4-1/2" NSTC BOX 13 5,442' Upper Tandem Seal: GSB3 DB HL H6 PFS 14 5,449' Lower Tandem Seal: GSB3 DB HL H6 PFS 15 5,456' Motor: CL -S, MSPS-250-21OHp/2,380V/53A 16 5,464' Sensor: Pheonix X7350 Type O 17 5,466' Centralizer: Six Fin - BTM @ 5.468' 18 5,643' OA Lateral Hook Wall, Hanger above 7-5/8" Window 19 5,660' OA Lateral Hook Wall, Hanger below 7-5/8" Window 20 5,775' OB Lateral Tie Back Sleeve 21 5,782' OB Lateral ZXP Liner Top Packer 22 5,788' OB Lateral 7-5/8" x 5-1/2" HMC Liner Hanger 23 9,991' OA Lateral 4-1/2" Btm of Guide Shoe 24 8,978' OB Lateral 4-1/2" Btm of Guide Shoe LATERAL WINDOW DETAIL Top of "OA" Window @ 5,648' MD; Bottom @ 5,673' MD; Angle @ top of window is 72 deg Top of "OB" Window @ 5,775' MD; Bottom @ 5,788' MD; Angle @ top of window is 77 deg G e N 19 "OA" latera Slotted Liner 23 20 22 'OB'Lalerai Slotted Liner 24 7-5/8" TD=9,561' (MD)/TD=4,453'(TVD) PBTD=9,561' (MD)/TD=4,453'(TVD) GENERAL WELL INFO API: 50-029-23189-00-00 Drilled and Completed by Doyon 14-2/03/2004 Convert to TTC-ESP by Doyon 16 - 5/25/2013 Revised By: TDF 5/8/2019 i STATE OF ALASKA AOSKA OIL AND GAS CONSERVATION CAISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: ❑ Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Stimulate - Frac ❑ Waiver ® Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Stimulate - Other ❑ Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 203 -210 • p ( ) 0 0 3. Address: . 0 Development ❑ Service 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50.029 23189 - 00 - 00 • 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 025518 MPG -16 9. Logs (list logs and submit electronic and printed data per 20AAC25.071): 10. Field / Pool(s): Milne Point Unit / Schrader Bluff - 11. Present well condition summary: Total depth: measured • 9561' feet Plugs:(measured) None feet true vertical 4453' feet Junk: (measured) None feet Effective depth: measured 9561' feet Packer: (measured) None feet true vertical 4453' feet Packer: (true vertical) None feet Casing Length Size MD TVD Burst Collapse Structural Conductor 86' 20" 34' - 120' 34' - 120' Surface 2492' 10 -3/4" 35' - 2527' 35' - 2466' 5210 2480 Intermediate 6227' 7 -5/8" 33' - 6260' 33' - 4390' 6890 4790 Production Liner 3203' 4- 1/12" 5775' - 8978' 4319' - 4443' 8430 7500 Perforation Depth: Measured Depth: Slotted Liner: 6054' - 8976' feet True Vertical Depth: Slotted Liner: 4361' - 4444' feet Tubing (size, grade, measured and true vertical depth): 4 - 1/2 ", 12.6# L - 5468' 4217' Packers and SSSV (type, measured and true vertical depth): None None None 12. Stimulation or cement squeeze summary: Intervals treated (measured): SCANNED JUN 2 8 2013 Treatment description including volumes used and final pressure: 13 Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 220 206 Subsequent to operation: 139 46 191 320 200 14. Attachments: ❑Copies of Logs and Surveys run 15. Well Class after work: ❑ Exploratory ❑ Stratigraphic 0 Development ❑ Service 0 Daily Report of Well Operations 16. Well Status after work: • 0 Oil ❑ Gas ❑ WDSPL 0 Well Schematic Diagram ❑ 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: Sean McLaughlin, 564 -4387 N/A Email: Sean.McLaughlin @bp.com Printed Na x Joe Lastufka Title: Drilling Technologist Signature: f� yk___, Phone: 564 -4091 Date: (0/161 I1. Form 10-404 Re sed 10/2 r LF 112 7 RBD1j 2013 4 ubmit Original Only Tree: 4 -1/2" - 5M Camero. i l O,F elev. = 62.90' (Doyon 14) Wellhead: 5M Gen 5 MPG -1 1 6 ' fr Or GL. elev.= 29.20' (Doyon 14) 11"X 11" w/ 4 1/2" TC -I I T &B Hanger 4.5" CIW "H" BPV profile L 20' 178 #/ft .875 thick Driven conductor I 120' I Camco 4 -1/2" x 1 "w/ BK latch I 155' I ) sidepocket KBG -2 GLM 10 3/4" L -80 Float Shoe 1 2,526' IA ■ Camco 4 -1/2" x 1 " w/ BK latch 5,203' J sidepocket KGB -2 GLM KOP © 200' 60+ degree from 3,800' Max hole angle = 66 degree @ 5,550' D & D Tbg. Stop 5,404' D & D Packoff w /Kobe Knockout 5,406' I TTC ESP 380 SXD 116 P18 1 5,413` 10 3/4" 45.5 ppf L -80 BTRC (Drift ID = 9.794, cap. = .0961 bpf) J TTC Drilled Tbg. Crossover 5,432' 7 5/8" 29.7 ppf, L -80, BTRC -mod production casing �� 4 1/2" IBT Box X 4 1/2" NSCT Pin ( drift ID = 6.750 ", cap. = 0.0459 bpf) IM Centrilift tandem seal section 5,442' 4.5 ", 12.6 #, L-80 IBT tbg. liner GSB3DBUT / GSB3DBLT ( cap. = .0152 bpf, id = 3.958) I 1 4.5" 12.6# L - IBT tubing i` Motor - MPS1 -250 / 84 HP 2210 volt / 23 amp 5,456' (drift ID = 3.958 ", cap. = 0.0152 bpf) Rerated to - 325 / 60 HP 2050 volt / 18 amp j 5 Centrilift Pump mate sensor 5,464' [l Op 6 Fin Motor centrilizer 1 5,466` Baker Hook Wall Hanger inside 7" Window 5,643' Baker Hook Wall Hanger outside 7" Window 5,600' Window in 7" Casing @ 5,648' - 5673' Well Angle @ window = 72° 6 1/8" Hole td @ 10,030' 4— 103 jts. - 4 1/2" Slotted Liner Rat O Hole OA Upper Lateral 12.6# L - 80 IBT (5,711` 9,947') Btm Baker 4 1/2" Guide Shoe 9,990' Baker Tie Back Sleeve 5,775' Baker ZXP Liner Top Packer 5,782' Baker 7 -5/8" x 5 -1/2" HMC Liner Hanger 5,788' A 7 5/8" Halliburton Float Collar 6,175' 6 1/8" Hole td @ 9,561' 7 5/8" Halliburton Float Shoe 6,260' OB Lower Lateral 76 jts. 4 1/2 ", 12.6# L -80, IBT Rat Hole ` Slotted Liner (6,054'- 8,976') 583' iiii Btm Baker 4 1/2" Float Shoe 8,978' — DATE REV. BY COMMENTS M I LN E POINT UNIT 02/03/04 MDO Drilled & Completed Doyon 14 WELL G -16 05/25/13 B. Bixby Doyon 16 RWO Conversion to TTC ESP API NO: 50-029-23189-60 L1 API NO: 50- 029 - 23189 -00 BP EXPLORATION (AK) • • • North America - ALASKA - BP 1 of 8 Operation Summary Report Common Well Name: MPG -16 AFE No Event Type: WORKOVER (WO) Start Date: 5/17/2013 End Date: 5/22/2013 X4- 00XMN- E:DRILL (2,090,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/21/2004 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @62.90usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth ! Phase Description of Operations (hr) (usft) 5/17/2013 04:00 - 06:00 2.00 MOB P PRE PJSM, MOVE OFF OF MPL -20 - POSITION RIG ON PAD TO LAY DERRICK OVER AND WORK ON BOP STACK 06:00 - 14:00 8.00 MOB P i PRE PJSM, RE- CONFIGURE BOP STACKAND LAY DERRICK OVER RIG IS ON EDGE OF L -PAD. RE- CONFIGURE BOP FROM 4- PREVENTER TO 13- PREVENTER STACK REMOVE BOP FROM CELLAR AND SECURE ION FRAME BRIDLE UP DERRICK !LAY DERRICK OVER. !JACK UP RIG AND GET READY TO MOVE. 14:00 18:00 4.00 MOB P PRE MOVE RIG OFF L -PAD, TRAVEL DOWN L -PAD ACCESS ROAD - RIGHT ON MILNE POINT ROAD, - STAGE RIG AT A -PAD ENTRANCE - TURN RIG AROUND TO BACK DOWN MILNE PT ROAD TO G -PAD ACCESS ROAD TO MAKE TURN. 18:00 - 21:30 3.50 MOB P PRE RIGHT ON G -PAD ACCESS ROAD - MOVE DOWN ACCESS ROAD TO G -PAD - POSITION RIG ON PAD TO RAISE DERRICK 1 21:30 - 22:30 1.00 MOB P PRE i PJSM TO RAISE DERRICK RAISE DERRICK AND PIN IN PLACE - R/U FLOOR TUGGERS AND EQUIPMENT - RAISE CATTLE CHUTE 22:30 - 00:00 1.50 MOB P j PRE LAY MATS AROUND WELL - STAGE WELL KILL EQUIPMENT AND TREE BEHIND WELL - BRIDLE DOWN - PLACE BOP IN CELLAR AND SECURE 5/18/2013 00:00 - 01:00 1.00 MOB P PRE PJSM, PERFORM SPCC AND EQUIPMENT CHECKS LAY RIG MATS 01:00 - 03:00 2.00 MOB P PRE I PJSM, SPOT RIG OVER WELL MPG -16 - SHIM RIG, LOWER DOORS, SECURE ALL STAIRS - SPOT CUTTINGS TANK AND FUEL TRAILER - PREP PITS TO TAKE ON FLUID 1- ACCEPT RIG AT 0300 HRS 03:00 - 06:00 3.00 MOB P DECOMP RIG UP CELLAR WELL KILL MANIFOLD AND CIRCULATING LINES TO TREE AND FLOW BACK TANK - R/U FLOOR MUD MANIFOLD AND EQUIPMENT - SPOT CREW TRAILER AND MUD PRODUCTS HOT SHACK - LOAD PITS WITH 120 DEGREE, 8.5 PPG SEA WATER - TEST ALL CIRCULATING LINES, 250 / 3500 PSI, 5 MIN, CHARTED 06:00 - 06:30 0.50 MOB P DECOMP RIG EVAC DRILL FOR FIRE. ALL PERSONNEL MUSTER, HEAD COUNT IS GOOD. CONDUCT AAR. Printed 6/3/2013 10:36:03AM • • • North America - ALASKA - BP page 2 of 8 Operation Summary Report Common Well Name: MPG -16 AFE No Event Type: WORKOVER (WO) Start Date: 5/17/2013 End Date: 5/22/2013 , X4- 00XMN- E:DRILL (2,090,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name /No.: DOYON 16 Spud Date /me: 1/21/2004 12:00:00AM ' Rig Release: Rig Contractor: DOYON DRILLING INC. � UWI: Active datum: Kelly Bushing / Rotary Table @62.90usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase 1 Description of Operations (hr) (usft) 06:30 - 07:30 1.00 WHSUR P DECOMP LOAD BPV LUBRICATOR TO RIG FLOOR. PREP TO PULL BPV. 07:30 - 09:00 1.50 WHSUR P DECOMP PJSM THEN PRESSURE TEST BPV LUBRICATOR 250 / 3500 PSI AGAINST CLOSED SSV AND MASTER VALVE. GOOD TEST. PULL BPV THEN CLOSE MASTER AND SSV TO RE- ESTABLISH 2 BARRIERS. TUBING PRESSURE IS 150 PSI. 1 09:00 - 09:30 0.50 KILLW P DECOMP I PJSM FOR WELL KILL. 1 09:30 - 11:00 1.50 KILLW P DECOMP 1 START WELL KILL. BLEED GAS FROM IA. 'PRESSURE DROPS FROM 160 PSI TO 0 IN 4 I MIN. 1 PUMP DOWN TUBING, TAKE RETURNS FROM IA. PUMP 35 BBLS AT 3 BPM DOWN TUBING. NO RETURNS WITH WIDE OPEN CHOKE, NO PRESSURE ON IA. 11:00 - 12:00 1.00 KILLW P DECOMP DISCUSS WITH ODE, DECIDE TO BULLHEAD DUE TO NO RETURNS. BULLHEAD 400 BBLS DOWN TUBING AND IA TOGETHER AT 8 BPM. SHUT DOWN AND MONITOR PRESSURE. !BOTH IA AND TUBING ON A VAC WITHIN 10 I MIN. 12:00 - 13:00 1.00 KILLW P DECOMP RIG DOWN CIRC SKID AND RIG UP HOLE FILL LINE. START FILLING WELL DOWN IA. 13:00 - 15:00 r 2.00 WHSUR P ' DECOMP RIG UP TWC LUBRICATOR AND PT 250 / 3500 PSI. SET TWC. 15:00 - 16:30 1.50 WHSUR P DECOMP !ROLLING TEST TWC FROM BELOW, 250 PSI 'AT 8 BPM DOWN IA. CONFIRM NO LEAKS PAST TWC BY GAUGE ON TREE CAP. PRESUSRE TEST FROM ABOVE, 250 / 3500 PSI, GOOD. 16:30 - 17:30 I 1.00 WHSUR P DECOMP PJSM, N/D TREE AND ADAPTER FLANGE 1- FMC HAND INSPECTED HANGER THREADS, 8.5 RH TURNS, 2 7/8" EUE 8RD - LOAD, STRAP AND RABBIT 4 1/2" 12.6# L -80 IBT TUBING INTO PIPE SHED - MAINTAIN CONTINUOUS HOLE FILL TO IAAT 25 BPH 8.5 PPG SEAWATER WITH NO RETURNS 17:30 - 21:00 3.50 BOPSUR P DECOMP NM 3 PREVENTOR BOP STACK !- INSTALL RISER AND TURNBUCKLES, MOUSE ( HOLE M/U CHOKELINE AND KILL LINES TO STACK 21:00 - 22:30 1.50 BOPSUR P DECOMP PJSM, INSTALL BLIND SHEAR RAMS IN STACK - M/U ACCUMULATOR HYD LINES TO BOP 22:30 - 23:30 1.00 BOPSUR P DECOMP R/U BOP TEST EQUPMENT AND M/U FLOOR VALVES FOR TESTING FILL STACK AND AND CHOKE MANIFOLD Printed 6/3/2013 10:36:03AM • • • North America - ALASKA - BP Page 3 of 8 Operation Summary Report Common Well Name: MPG -16 AFE No Event Type: WORKOVER (WO) Start Date: 5/17/2013 End Date: 5/22/2013 I X4- 00XMN- E:DRILL (2,090,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/21/2004 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @62.90usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 23:30 - 00:00 0.50 BOPSUR P DECOMP PJSM, TEST THREE PREVENTER BOPE AND RELATED EQUIPMENT - BOP CONFIGURATION = ANNULAR, BLIND SHEAR RAMS, MUD CROSS, 2 7/8" X 5" VBR LOWER PIPE RAMS - TEST BOPE ACCORDING TO AOGCC • REGULATIONS AND DOYON PROCEDURES - TEST ANNULAR WITH 2 7/8" TEST JOINT TO 250 PSI LOW, 3500 PSI HIGH, 5 MIN, CHARTED � I I - JEFF JONES OF AOGCC WAIVED STATES RIGHT OF WITNESS TO THE BOP TEST 5/19/2013 00:00 - 04:30 4.50 BOPSUR P DECOMP i PJSM, TEST THREE PREVENTER BOPE AND RELATED EQUIPMENT - BOP CONFIGURATION = ANNULAR, BLIND SHEAR RAMS, MUD CROSS, 2 7/8" X 5" VBR LOWER PIPE RAMS - TEST BOPE ACCORDING TO AOGCC REGULATIONS AND DOYON PROCEDURES - TEST ANNULAR WITH 2 7/8" TEST JOINT TO 250 PSI LOW, 3500 PSI HIGH, 5 MIN, CHARTED - TEST LOWER 2 7/8" X 5" VARIABLE RAMS WITH 2 7/8" AND 4 1/2" TEST JOINTS, 250 PSI, 3500 PSI, 5 MIN, CHARTED - TEST BLIND RAMS, FLOOR VALVES, AND CHOKE MANIFOLD TO 250 PSI, 3500 PSI, 5 MIN, CHARTED - TEST WITH FRESH WATER - PERFORM ACCUMULATOR DRAW DOWN TEST - JEFF JONES OF AOGCC WAIVED STATES RIGHT OF WITNESS TO THE BOP TEST 04:30 - 07:00 2.50 BOPSUR P DECOMP R/D TEST EQUIPMENT R/U WELL SUPPORT LUBRICATOR AND TEST 250 / 3500 PSI, 5 MIN, CHARTED - PULL TWC, TUBING IS ON A VAC. 07:00 - 08:00 1.00 PULL P DECOMP PJSM THEM MAKE UP LANDING JOINT TO HANGER. FMC BACK OUT LDS. PULL HANGER TO RIG FLOOR, 82K UP WEIGHT. (INCLUDES 40K BLOCK WEIGHT) 'CUT CABLE OFF JUST BELOW HANGER AND I REMOVE CLAMP. PICK UP ANOTHER 30 FT AND RE- INSTALL CLAMP, THEN CUT ESP CABLE AGAIN JUST ABOVE THIS CLAMP. RUN BACK IN AND PLACE CLEAN PIPE ACROSS BOP STACK 08:00 - 08:30 0.50 PULL P DECOMP CLOSE ANNULAR, BULLHEAD 31 BBLS DOWN TUBING AT 3 BPM, 140 PSI. CHECK PRESSURE UNDER ANNULAR THEN OPEN IT. MONITOR WELL. 08:30 - 11:00 2.50 PULL P , DECOMP PJSM THEN HANG ESP SHEAVE AND TRUNK CONTINUE PULLING SINGLES FROM WELL. RUN CABLE UP THROUGH SHEAVE AND OUT TO SPOOLING UNIT, SECURE IT TO SHIPPING DRUM. Printed 6/3/2013 10:36:03AM • • • North America - ALASKA - BP Page 4 of 8 Operation Summary Report Common Well Name: MPG -16 AFE No Event Type: WORKOVER (WO) Start Date: 5/17/2013 End Date: 5/22/2013 f X4- 00XMN- E:DRILL (2,090,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/21/2004 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @62.90usft (above Mean Sea Level) Date From - To Hrs Task Code NPT F NPT Depth Phase Description of Operations (hr) (usft) ! 11:00 - 12:00 1.00 PULL P DECOMP PULL SINGLES OUT OF WELL, L /D. INSTALL THREAD PROTECTORS ON BOTH ENDS. I CONTINUE HOLE FILL AT 20-25 BBL/HR, WELL IS NOT STAYING FULL AT THAT RATE. POH F/ 5467' T/ 4490', PUWT = 75K, SOWT = 70K 12:00 - 12:30 0.50 PULL P DECOMP I PERFORM SPCC AND EQUIPMENT CHECKS - SREVICE DRAWWORKS AND RIG FLOOR 1 EQUIPMENT 12:30 - 17:00 4.50 PULL P DECOMP POOH, 2 7/8" EUE 8RD TUBING ESP COMPLETION - F/ 4490' T/ ESP MOTOR BHA - WELL IS STILL ON A VAC 17:00 - 20:00 3.00 PULL P , DECOMP MONITOR WELL BEFORE PULLING BHA TO ! I SURFACE - L/D ESP PUMP AND MOTOR ASSY I - TOTAL JTS L/D = 171 2 7/8" EUE 8RD - LASALLE CLAMPS = 92 - PROTECTOLIZERS = 5 - FLAT GUARDS = 3 20:00 - 21:30 1.50 - PULL j P DECOMP CLEAN AND CLEAR RIG FLOOR OF ALL CENTRILIFT CLAMPS AND EQUIP - R/D ESP SHEAVE AND TRUNK ASSY 21:30 - 22:30 1.00 EVAL P DECOMP PJSM, SPOT SWS WIRELINE TRUCK - INSTALL TEST PLUG AND DUTCH RISER 22:30 - 00:00 1.50 EVAL P DECOMP I MOBILIZE SWS SHEAVES AND TOOLS TO RIG FLOOR R/U FOR FULL PRESSURE CONTROL - OA =OPSI - 24 HOUR FLUID LOSS = 605 BBLS, 8.5 PPG SEA WATER - MAINTAIN CONTINUOUS HOLE FEED TO IA @ 25 BPH 8.5 PPG SEAWATER 5/20/2013 00:00 - 03:00 3.00 EVAL P DECOMP PERFORM SPCC AND EQUIPMENT CHECKS - PJSM WITH NEW CREW AND SWS FOR R/U OF WIRELINE TOOLS R/U FULL PRESSURE CONTROL LUBRICATOR TO DUTCH RISER I- MAINTAIN CONTINUOUS HOLE FEED TO IA 25 BPH 8.5 PPG SEA WATER 03:00 - 03:30 0.50 EVAL P DECOMP TEST SWS LUBRICATOR AGAINST TEST PLUG, 250 / 3500 PSI, 5 MIN, CHARTED, GOOD TEST - BREAK LUBRICATOR AT QUICK TEST SUB - STAND BACK LUBRICATOR 03:30 - 04:00 i 0.50 EVAL P DECOMP ; PULL DUTCH RISER AND PULL TEST PLUG - RE- INSTALL DUTCH RISER 04:00 - 06:00 2.00 EVAL P DECOMP I M/U PDS CALIPER (MEMORY) LOGGING TOOLS TO DETERMINE IF THERE IS EVIDENCE OF BUCKLING OF CASING - M/U AND TEST QUICK TEST SUB - RIH WITH PDS CALIPER AND LOG FROM 1000' TO SURFACE. 06:00 - 06:30 0.50 EVAL P DECOMP PDS DOWNLOAD AND CHECK DATA, DATA IS GOOD. NO ANOMALIES SEEN IN CALIPER LOG ON INITIAL LOOK AT DATA. Printed 6/3/2013 10:36:03AM • North America - ALASKA - BP Page 5 of s Operation Summary Report Common Well Name: MPG -16 AFE No Event Type: WORKOVER (WO) Start Date: 5/17/2013 End Date: 5/22/2013 X4- o0XMN- E:DRILL (2,090,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name/No.: DOYON 16 Spud Date/Time: 1/21/2004 12:00:00AM I Rig Release: Rig Contractor DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @62.90usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:30 - 07:30 1.00 RUNCOM P RUNCMP PJSM THEN START RIG DOWN SWS PRESSURE CONTROL EQUIPMENT AND LUBRICATORS. 07:30 - 09:30 2.00 RUNCOM P � RUNCMP MOBILISE CENTERLIFT, FMC AND BAKER PERSONNEL. PREP RIG FLOOR TO RUN THROUGH TUBING I ESP. j CENTERLIFT SPOT SPOOLING UNIT BACK INTO POSITION AND LOAD CABLE INTO UNIT !WHILE RIG FLOOR GETTING CLEARED. 1 09:30 - 12:30 3.00 RUNCOM P RUNCMP PJSM FOR M/U ESP MOTOR. PICK UP ESP MOTOR AND SERVICE ON RIG FLOOR. _ 12:30 - 13:30 1.00 RUNCOM P RUNCMP PICKUP 1 JT OF 4 -1/2 TUBING. MAKE UP DUMMY HANGER AND LANDING JT, LAND HANGER AND RUN IN LDS. 13:30 - 14:30 1.00 RUNCOM P RUNCMP LOWER IN FIRST PUMP COMPONENT. MAKE UP 2 -7/8 WORK STRING AND CEMENT I LINE. 14:30 - 15:00 0.50 RUNCOM P RUNCMP PUMP OFF GS SPEAR. UNSUCCESSFUL FIRST TIME AT 1 BPM, WORKS BETTER AT 2 BPM. 15:00 - 16:30 1.50 RUNCOM P RUNCMP RIH WITH PACKOFF ASSEMBLY AND PUMP OFF. RIH WITH PACKOFF TEST ASSEMBLY AND PUMP OFF. PULL WORK STRING UP AND CLOSE BLINDS, ATTEMPT A PT. 16:30 - 17:00 0.50 RUNCOM P RUNCMP NOTABLE TO PT WITH TEST PUMP. TRY WITH MUD PUMP, SAME RESULT. TRY JARRING DOWN AGAIN, NO SUCCESS. 17:00 - 19:00 2.00 RUNCOM N DFAL RUNCMP PULL TEST TOOL OUT AND PACKOFF ASSEMBLY OUT. FIND PACKOFF ASSEMBLY SLIDING SLEEVE HAS NOT SLID DOWN TO EXPAND THE SEALS. APPEARS TO BEAN INTERNAL OBSTRUCTION. I GET NEW PACKOFF ASSEMBLY FROM MPU SLICKLINE SHOP. 19:00 - 20:30 1.50 RUNCOM N DFAL RUNCMP M/U AND INSTALL NEW PACK-OFF IN THRU TUBING COMPLETION ASSY - PACK -OFF PREMATURELY SET TWICE - FIRST TIME, SLIGHT HANG -UP WHILE STABBING INTO HANGER SET THE TOOL SECOND TIME, REASON UNKNOWN RE -SET PACK -OFF AND RE -RUN BOTH TIMES - SET PACK-OFF ON DEPTH, SET 5K DOWN I i i WEIGHT = GOOD SET - PUMP OFF GS SPEAR AND POH 20:30 - 21:00 0.50 RUNCOM P RUNCMP RIH AND SET PACK-OFF TEST TOOL 1- PUMP OFF GS SPEAR AND POH FILL STACK, CLOSE BLIND RAMS - TEST PACK -OFF, 250 / 1000 PSI, 5 MIN, CHARTED. GOOD TEST 21:00 - 23:00 � 2.00 RUNCOM P I RUNCMP RETRIEVE TEST TOOL AND INSTALL SLIP STOP ASSY WITH 5K DOWN WEIGHT - R/D 2 7/8" RUNNING TOOLS, L/D 2 7/8" PAC PIPE - CLEAR RIG FLOOR OF BAKER TOOLS Printed 6/3/2013 10:36:03AM • • North America - ALASKA - BP Page 6 of 8 Operation Summary Report Common Well Name: MPG -16 AFE No Event Type: WORKOVER (WO) Start Date: 5/17/2013 End Date: 5/22/2013 ,X4- 00XMN- E:DRILL (2,090,000.00 ) — I Project: Milne Point Site: M Pt G Pad Rig Name/No.: DOYON 16 Spud Date/Time: 1/21/2004 12:00:00AM 'Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @62.90usft (above Mean Sea Level) Date I From - To Hrs Task Code NPT NPT Depth Phase ; Description of Operations (hr) (usft) 23:00 - 00:00 1.00 RUNCOM P RUNCMP ; P/U LANDING JOINT AND M/U TO DUMMY HANGER FMC REP BACK OUT LDS PULL DUMMY HANGER TO RIG FLOOR L/D LANDING JTAND HANGER OA = 0 PSI - 24 HOUR FLUID LOSS = 725 BBLS, 8.5 PPG SEA WATER - MAINTAIN CONTINUOUS HOLE FEED TO IA @ 25 BPH 8.5 PPG SEA WATER 5/21/2013 00:00 - 01:30 1.50 RUNCOM P RUNCMP PJSM, PERFORM SPCC AND EQUIPMENT CHECKS - R/U CENTRILIFT EQUIPMENT - HANG SHEAVE, STRING FLAT ESP LEAD CABLE TO RIG FLOOR 01:30 - 03:30 2.00 RUNCOM P RUNCMP PJSM FOR RUNNING 4 1/2" COMPLETION - CENTRILIFT REP, TIE IN MLE, ESP CABLE TO MOTOR ASSY 03:30 - 06:00 2.50 RUNCOM P RUNCMP , RIH WITH 4 1/2" 12.6# L -80 IBT ESP TT COMPLETION - FROM SURFACE TO 1102' - PERFORM CONDUCTIVITY TEST EVERY 1000' I- FILL PIPE AND BRK CIRCULATION AT .5 BPM EVERY 1000' - MAKE -UP TUBING TO TQ -STAMP ON PIPE = 3600 FT /LBS - INSTALL CANNON CLAMPS ON EVERY COLLAR - MAINTAIN CONTINUOUS HOLE FEED ON KILL LINE @ 25 BPH 8.5 PPG SEA WATER 06:00 - 12:00 6.00 RUNCOM P RUNCMP 'RIH WITH 4 1/2" 12.6# L -80 IBT ESP TT 'COMPLETION FROM 1102 FT. 1 AROUND 2500 FT PERFORM KICK WHILE TRIPPING DRILL WITH AD ON THE BRAKE. ALL PERSONNEL GO TO ASSIGNED POSITIONS. SIMULATED CUTTING THE CABLE AND SHUTTING IN WELL. CON DUCT MR AFTERWARDS. CONTINUE M/U COMPLETION. - RIH WITH 4 1/2" ESP TT COMPLETION F/ _ 11102' T/ 3705' MD 1 12:00 - 16:00 1 4.00 RUNCOM P RUNCMP PJSM WITH NEW CREW FOR RUNNING ESP COMPLETION I- RIH WITH 4 1/2" 12.6# L80 IBT ESP TT COMPLETION - F/ 3705' T/ 5463' MD - PERFORM CONDUCTIVITY TEST EVERY 1000' - FILL PIPE AND BRK CIRCULATION AT .5 BPM EVERY 1000' - MAKE -UP TUBING TO TQ -STAMP ON PIPE = 3600 FT /LBS INSTALL CANNON CLAMPS ON EVERY COLLAR I I CLAMPS USED -FLAT GUARDS =2 - PROTECTOLIZERS = 3 - 2' CANNON CLAMPS = 135 Printed 6/3/2013 10:36:03AM S Notch America - ALASKA - BP Page 7 of 8 Operation Summary Report Common Well Name: MPG -16 AFE No Event Type: WORKOVER (WO) Start Date: 5/17/2013 End Date: 5/22/2013 4X4- OOXMN- E:DRILL (2,090,000.00 ) _ I Project: Milne Point Site: M Pt G Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/21/2004 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @62.90usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:00 - 20:00 4.00 RUNCOM P RUNCMP M/U 10" X4 1/2" HANGER WITH 4 1/2" TC -2 TOP AND BOTTOM THREADS, 4" "H" PROFILE - INSTALL TWC IN HANGER - M/U LANDING JOINT TO HANGER - TERMINATE ESP CABLE AT HANGER AND TEST CONDUCTIVITY, GOOD TEST DAY WSL PERFORM FACE TO FACE HAND OVER FROM MPU OPS COORDINATOR FOR NEXT WELL MPJ -10. 20:00 - 20:30 0.50 RUNCOM P RUNCMP LAND HANGER IN TUBING SPOOL I- FMC REP RUN IN LOCK DOWN SCREWS - B/O LANDING JOINT AND L/D 20:30 - 21:00 0.50 RUNCOM P RUNCMP PERFORM ROLLING TEST ON TWC FROM BELOW I- 6.5 BPM = 150 PSI, 10 MIN, 66 BBLS PUMPED AWAY, 0 BBLS BLEED BACK - TEST TWC FROM ABOVE, 250 / 3500 PSI, 5 MIN, CHARTED - R/D TEST EQUIPMENT 21:00 - 22:00 1.00 BOPSUR P RUNCMP PJSM, REMOVE BLIND SHEAR RAMS FROM BOP STACK FOR RE- CONFIGURE - PULL MOUSE HOLE, CLEAR RIG FLOOR 22:00 - 00:00 2.00 BOPSUR P RUNCMP 1 N/D BOP STACK AND STAND BACK ON PEDESTAL PULL RISER, REMOVE TURNBUCKLES I- POWER DOWN ACCUMULATOR AND DISCONNECT LINES TO BOP - OA = 0 PSI - 24 HOUR FLUID LOSS = 687 BBLS, 8.5 PPG SEA WATER - MAINTAIN CONTINUOUS HOLE FEED TO IA @ 25 BPH 8.5 PPG SEAWATER WITH NO RETURNS 5/22/2013 00:00 - 02:00 2.00 WHSUR P RUNCMP PJSM, PERFORM SPCC AND EQUIPMENT CHECKS - N/U 11" X 4 1/16" ROTATING FLANGE TUBING HEAD ADAPTER WITH ESP PENETRATOR PORT - FMC REP. TESTED TO 250 PSI LOW 5 MIN, 5000 PSI HIGH 30 MIN, GOOD TEST WSL HAVE FACE TO FACE WITH PAD OPS TO OPEN "WELL WORK TRANSFER PERMIT' ON MPJ -10. 02:00 - 03:30 1.50 WHSUR P RUNCMP N/U 4 1/16" 5K CAMERON TREE - FMC VERIFY TREE ALIGNMENT - TEST, 250 PSI LOW, 5000 PSI HIGH 5 MIN, CHARTED, GOOD TEST Printed 6/3/2013 10:36:03AM • • North America - ALASKA - BP Page 8 of 8 Operation Summary Report Common Well Name: MPG -16 AFE No Event Type: WORKOVER (WO) Start Date: 5/17/2013 End Date: 5/22/2013 X400XMN- E:DRILL (2,090,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/21/2004 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table ©62.90usft (above Mean Sea Level) Date From - To Firs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:30 - 07:00 3.50 WHSUR P RUNCMP R/U DSM LUBRICATOR TO TREE TO PULL TWC - TEST LUB 250 / 3500 PSI, 5 MIN, CHARTED, PULL TWC - TEST LUB 250 / 3500 PSI, 5 MIN, CHARTED, INSTALL BPV - R/D DSM LUBRICATOR AND CLEAR RIG FLOOR - PERFORM ROLLING TEST FROM BELOW BPV 6 BPM = 150 PSI, 10 MIN, 80 BBLS PUMPED AWAY, 0 BBLS BLEED BACK - FILL TREE WITH DIESEL. RIG RELEASED AT 07:00 HRS 5/22/2013 FROM LMPG -16 FOR MOVE TO MPJ -10. Printed 6/3/2013 10:36:03AM • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 tit,MNEVEB 1 ; 2.(i$a Mr. Tom Maunder 3 10 Alaska Oil and Gas Conservation Commission rad 333 West 7 Avenue Anchorage, Alaska 99501 l3 Subject: Corrosion Inhibitor Treatments of MPG -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPG -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 • 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) MPG -Pad 10/10/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal MPG -01 1890290 50029219270000 Tanko conductor NA NA NA NA NA MPG -02 1890280 50029219260000 Tanko conductor NA NA NA NA NA MPG -03A 2042190 50029219420100 Tanko conductor NA NA NA NA NA MPG -04 1890450 50029219410000 Tanko conductor NA NA NA NA NA MPG -05 1910230 50029221380000 1.1 NA 1.1 NA 5.1 8/14/2011 MPG -07 1910250 50029221400000 0.1 NA 0.1 NA 3.4 9/4/2011 MPG -08A 1930480 50029221410100 0.2 NA 0.2 NA 2.6 10/10/2011 MPG -09 1971170 50029227790000 1.3 NA 1.3 NA 15.3 10/30/2009 MPG -10 1971180 50029227800000 2.1 NA 2.1 NA 20.4 10/30/2009 MPG -11 1971190 50029227810000 0.8 NA 0.8 NA 5.1 8/14/2011 MPG -12 1971420 50029227920000 1.3 NA 1.3 NA 8.5 8/14/2011 MPG -13 1971200 50029227820000 1.2 NA 1.2 NA 10.2 10/30/2009 MPG -14 2011330 50029230310000 0.8 NA 0.8 NA 4.3 9/4/2011 MPG -15 1971220 50029227840000 2.9 NA 2.9 NA 34.0 10/30/2009 - I A' MPG -16 2032100 50029231890000 1.8 NA 1.8 NA 17.0 8/15/2011 MPG -17 2040130 50029231920000 1.6 NA 1.6 NA 14.5 8/15/2011 MPG -18 2040200 50029231940000 1.6 NA 1.6 NA 13.6 8/15/2011 MPG -19 2041920 50029232280000 1.6 NA 1.6 NA 13.6 8/15/2011 • • -~,__ '.,.p,~,,.- . 1_ 03~o~~zoog DO NOT PLACE :~; ;~"" ~~ ~_: ,~,.., :- 4.iF ANY NEW MATERIAL UNDER THIS PAGE F: \LaserFiche\C`vrPgs_Inserts\Microfilm_Marker. doc . . WELL LOG TRANSMITTAL jD2J~~ID To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 I 35lB RE: MWD Formation Evaluation Logs MPG-16 + PB1 + PB2, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 MPG-16 + PBI + PB2: LAS Data & Digital Log Images: 50-029-23189-00, 70, 71 1 CD Rom Q;foMw:¡ P19~ 100 :s M.~"t~ DATA SUBMITTAL COMPLIANCE REPORT 2/6/2006 Permit to Drill 2032100 MD 9561 / TVD Well Name/No. MILNE PT UNIT SB G-16 / Completion Date 2/3/2004 ~ 4453 -----. REQUIRED INFORMATION Mud Log No ~-~,~._-,,- DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, ABI, IFRlCASANDRA Well Log Information: Electr Digital Dataset Med/Frmt Number Log/ Data Type I I fÆ6 ¡ Rpt i--5Ð . Rpt ß) Rpt ..EØ Rpt µÐ Rpt E'D ! Rpt FD RPt ED· D Name D --P(# 1\1t D I2EIf yt.( t D Pge ~(.. D Pe.t.. tf\, i C D PQfIf~iC D Pdf¡/i",f L Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey 12465 Induction/Resistivity IndUGtivi)/Re,,¡::olivi1.1 ìJ ~r;&~(..,t\ 12465 Rate of Penetration 1\ +, Rate: of f'cn~tr8tion . \J l,;¡~tMV ...-f'{pt ~ D Rpt ---ED D ~t "...ED D 12466 I nd uction/Resistivity IIIJu,-li("\II1e:~;,,lrvity \J tv' U ~ t: R Rate of Penetration . I, ',-, Rate of 8oniitr:atiol1'" \S VV Ii {~%G 12467 Induction/Resistivity 12466 Operator BP EXPLORATION (ALASKA) INC 5p t¿¿ ^ I J /1"'- ÀOO'1 API No. 50-029-23189-00-00 Completion Status 1-01L Cu rrent Status 1-01 L UIC N Samples No Directional surv~ -~ (data taken from Logs Portion of Master Well Data Maint . Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments ~._-----"--~- _._-~.._-- 7527 9561 3/16/2004 7527 9561 3/16/2004 7527 9561 3/16/2004 MWD 7527 9561 3/16/2004 MWD 0 7498 3/16/2004 PB1 0 7498 3/16/2004 PB1 0 7498 3/16/2004 PB1 - MWD 0 7498 3/16/2004 PB1 - MWD 7045 7936 3/16/2004 PB2 7045 7936 3/16/2004 PB2 . 7045 7936 3/16/2004 PB2 - MWD 7045 7936 3/16/2004 PB2 - MWD 1-5 62 9506 3/18/2004 GR, EWR4, ROP 1-5 62 9506 3/18/2004 GR, EWR4, ROP 1-5 62 9506 3/18/2004 GR, EWR4, ROP 1-5 62 9506 3/18/2004 GR, EWR4, ROP 1-3 7050 7498 3/18/2004 GR, EWR4, ROP - PB1 1-3 7050 7498 3/18/2004 GR, EWR4, ROP - PB1 1-3 7050 7498 3/18/2004 GR, EWR4, ROP - PB1 1-3 7050 7498 3/18/2004 GR, EWR4, ROP - PB1 1-4 7548 7936 3/18/2004 GR, EWR4, ROP - PB2 DATA SUBMITTAL COMPLIANCE REPORT 2/6/2006 Permit to Drill 2032100 Well Name/No. MILNE PT UNIT SB G-16 MD 9561 LvR~t --EEr D Rpt TVD 4453 Completion Date 2/3/2004 Indu..tiulI/Rt::::oi"Livity Ut....~S ,\~ 12467 Rate of Penetration Rate of ~liInetrc;tiulI- \J '\r\ ~ .' ~~ Well CoresfSamples Information: Name Interval Start Stop ADDITIONAL INFORMATION Well Cored? y~ Chips Received? ~ Analysis Received? 3FJ:::ff== Comments: Compliance Reviewed By: ~ Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23189-00-00 Completion Status 1-01L Cu rrent Status 1-01L UIC N 1-4 7548 7936 3/18/2004 GR, EWR4, ROP - PB2 1-4 7548 7936 3/18/2004 GR, EWR4, ROP - PB2 1-4 7548 7936 3/18/2004 GR, EWR4, ROP - PB2 Sample Set Sent Received Number Comments . Daily History Received? 0N ~ Formation Tops Date: '; r::;& Jv~ <p ---~ . ~ .. , I STATE OF ALASKA · ALASKÄ IL AND GAS CONSERVATION COM~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG " 1a. Well Status: BOil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1990' NSL, 3443' WEL, SEC. 27, T13N, R10E, UM / Top of Productive Horizon: ø~ 2077' NSL, 323' WEL, SEC. 27, T13N, R10E, (OB) Total Depth~Jtl>- ~NSL,~EL, SEC. 26, T13N, R10E, (OB) 4b. Location of Well (Sta~ Base Plane C~ordinates): Surface: x- 557160 y- 6014426 Zone- APS4 TPI: x- 560279 y- 6014537 Zone- APS4 Total Depth: x- 563756'¡ y- 6014804/ Zone- APS4 18. Directional Survey BYes 0 No 21. Logs Run: MWD , GR , RES, ABI , IFRlCASANDRA 22. One Other 5. Date Comp., Susp., or Aband. 2/3/2004 ./ 6. Date Spudded 1/21/2004 ./ 7. Date T.D. Reached 1/28/2004 ./ 8. KB Elevation (ft): KBE = 62.90' 9. Plug Back Depth (MD+ TVD) 9561 + 4453; 10. Total Depth (MD+TVD) .; 9561 + 4453' 11. Depth where SSSV set NIA MD 19. Water depth, if offshore N/ A MSL WT. PER FT. 92# 45.5# 29.7# 12.6# CASING, liNER AND CEMENTING RECORD SETTING DEF'THMD SE'tnNGDEÞTH TVD Top BOTTOM Top BOTTOM 34' 120' 34' 120' 35' 2527' 35' 2466' 33' 6260 33' 4390' 5775' 8978' 4319' 4443' 20" 10-3/4" 7-5/8" 4-112" H-40 L-80 L-80 L-80 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 4-12" Slotted Liner MD TVD MD 6054' - 8976' 4361' - 4444' 26. Date First Production: March 3, 2004 Date of Test Hours Tested PRODUCTION FOR 3/3/2004 1 TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED .. Press. 24-HoUR RATE 42" 13-112" 9-7/8" 6-1/8" 24. SIZE 2-7/8", 6.5#, L-80 TVD 1b. Well Class: B Development 0 Exploratory o Stratigraphic Test 0 Service 12. Permit to Drill Number 203-210 13. API Number 50- 029-23189-00-00 14. Well Name and Number: MPG-16 15. Field I Pool(s): Milne Point Unit / Schrader Bluff Ft Ft 16. Property Designation: ADL 025518 17. Land Use Permit: 20. Thickness of Permafrost 1800' (Approx.) CEMENTINGREGORD 260 sx Arctic Set (Approx.) 450 sx PF 'L', 260 sx Class 'G' 670 sx Class 'G' Uncemented Slotted Liner AMOUNT PULLED DEPTH SET (MD) 5468' PACKER SET (MD) At:II:>, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 87 Bbls of Dry Crude PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Electric Submersible Pump Oll-Bsl GAs-McF WATER-BsL 33 6.87 .33 Oll-Bsl 789 GAs-McF 165 WATER-BsL 8 I GAS-OIL RATIO 209 Oil GRAVITY-API (CORR) CHOKE SIZE CORE DATA Brief description of lithology, porosity, fraçtures,apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none".. ···...·....··,Ö:q rTìf\R 2 î LOOA . ;)\,;2 \ None ; 2:-::.$:.0 11' ¡ \7JD ! L;.::".. .._~:::. · 27. Oq':G\~\L~t- CONTINUED ON REVERSE SIDE Form 10-407 Revised 12/2003 ~$tk~. MAN ., (,? ¿d. . GEOLOGIC MARKERS 29. 'WI' FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". SBF2-NA SBF21 SBF24-MF SBF1-NB SBF12 SBE4-NC SBE41 SBE3-ND SBE2-NE SBE1-NF TSBD-OA TSBC TSBB-OB 5222' 5267' 5290' 5301' 5343' 5355' 5367' 5379' 5407' 5532' 5643' 5897' 6279' 4099' 4120' 4131' 4137' 4157' 4163' 4168' 4174' 4188' 4246' 4286' 4339' 4393' None 4-- 30. List of Attachments: Summary of Daily Drilling Reports, Surveys, Well Schematic Diagram and a Leak-Off Test Summary. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed sondr~~---..J.itle Technical Assistant Date 03,w ..~ MPG-16 203-210 Prepared By Name/Number: Sondra Stewman, 564-4750 Well Number Drilling Engineer: Matt Green, 564-5581 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". O~). ",,+ , t L~" ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 '" . e . Page 1 of? BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date MPG-16 MPG-16 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 1/19/2004 1/20/2004 From- To Hours Task Code NPT Phase 16:00 - 00:00 8.00 MOB P PRE 00:00 - 04:30 4.50 MOB P PRE 04:30 - 06:30 2.00 RIGU P PRE 06:30 - 10:30 4.00 RIGU P PRE 10:30 - 23:30 13.00 DRILL P SURF 23:30 - 00:00 0.50 DRILL P SURF 00:00 - 01 :00 1.00 DRILL P SURF 01 :00 - 03:00 2.00 DRILL P SURF 03:00 - 04:00 1.00 RIGU P PRE 1/21/2004 04:00 - 05:00 1.00 DRILL P SURF 05:00 - 05:30 0.50 DRILL P SURF 05:30 - 06:30 1.00 DRILL P SURF 06:30 - 00:00 17.50 DRILL P SURF 1/22/2004 00:00 - 01 :00 1.00 DRILL P SURF 01 :00 - 02:30 1.50 CASE P SURF 02:30 - 04:00 1.50 CASE P SURF 04:00 - 04:30 0.50 CASE P SURF 04:30 - 06:30 2.00 CASE P SURF 06:30 - 07:30 1.00 CASE P SURF 07:30 - 09:30 2.00 CASE P SURF 09:30 - 10:30 1.00 CASE P SURF 10:30 - 13:00 2.50 CASE P SURF 13:00 - 14:00 1.00 CASE P SURF 14:00 - 16:30 2.50 CASE P SURF 16:30 - 19:00 2.50 CEMT P SURF Start: Rig Release: Rig Number: 1/20/2004 2/4/2004 Spud Date: 1/21/2004 End: Description of Operations Moving rig and camp to MPG-16 Moving rig to MPG-16, spotting over well, skid floor over well, rig accepted @ 04:30 1/20/2004 Nipple up Diverter - Take on H20 - Mixing spud mud Load pipe shed with 4" Drill pipe - Mix spud mud - Change equipment over to 4" Drill pipe Pick up 4" drill pipe stand in derrick 315 joints - Snow packed - Steam each joint - rabbit each joint - Stand back in derrick Change out 4" handling equipment to 5" handling equipment - Pick up 5" HWT - stand back in derrick Pick up 5" HWT drill pipe Pick up BHA to rig floor - Make up bit - motor - MWD - Orient same - Rig up Sperry Sun Gyro survey equipment Function test Divertor - Preform Accumulator test - John Spaulding with AOGCC wavied witness of Divertor Function Test - Pre Spud Meeting with all personnel - Surface test circ system - Fill conductor - check for leaks Drill Ice from 61' to 120' - Drill from 120' to 185' Run Gyro survey Pull out hole - Make up Flex DC's - RIH Directional Drill from 185' to 2355' - WOB 30K - RPM 90 - TQ on 6K - oft 3K - GPM 540 - PP on 2730 - oft 2480 - PU 1 02K - SO 97K - ROT 100K Directional Drill 13.5" Hole to T.D. - 2534' MD 2472 TVD- WOB 35K - RPM 100 - TQ on 7K - oft 3.5K - GPM 540 - PP on 2730 - oft 2400 - PU 1 05K - SO 1 OOK - ROT 105K CBU X 3 - RPM 100 - TQ 3.5K - GPM 540 - PP 2300 Pump out from 2534' to 725' 5" HWT - Pump at full drilling rate 540 gpm - Hole in good shape RIH from 726' to 2534' - Bridge @ 1900 - fell through - Pick up and run back through no problems CBU X 3 - RPM 100 - TQ 3.5K - GPM 540 - PP 2500 Pump out from 2534' to 725' to 5" HWT - Pump at drlg rate 550 gpm - No problems Stand back 5" HWT - Lay down Flex DC's - Stabilizers - MWD - Motor - Bit Rig up casing tools to run 10.75" casing - PJSM Run 60 joints 103/4" L-80 45.5# BTC casing to 2492' Make up FMC casing hanger - Land casing @ 2534' - Rig down Franks fill up tool - Make up Schlumberger cementing head Break circulation - staging up pump rate from 2 bpm to 10 bpm final circulation pressure 810 psi - Circulate and condition mud for cement job Give to Schlumberger - Pump 5 bbls CW 100 wash - Test lines to 3500 psi - Pump 15 bbls CW 100 wash @ 5 bpm 120 psi - Pump 60 bbls of 10.2 ppg Mud Push spacer @ 6 bpm 120 psi- Drop btm plug last 5 bbls of spacer - (added one gallon dye in first 5 bbls slurry pumped) - Mix and pump 450 sxs Type 'ASL' - Yield 4.45 cf/sx 356 bbls of 10.7 ppg @ 7 bpm 430 psi - Mix and pump 260 sxs Class 'G' cement with .7% S-001 accelaerator + .4% D-167 Fluid Loss + .3% D-065 Dispersant + .2% D-046 Antifoam - Yield 1.17 cu/sx - 54 bbls of slurry mixed @ 15.8 ppg @ 5 bpm 470 psi - DISPLACEMENT - Kick out top ,printed: 21912004 9:10:31 AM . . e e BP EXPLORATION Operations Summary Report Page 2 of 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPG-16 MPG-16 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 Start: Rig Release: Rig Number: 1/20/2004 2/4/2004 Spud Date: 1/21/2004 End: Date From- To Hours Task Code NPT Phase Description of Operations 1/22/2004 16:30 - 19:00 2.50 CEMT P SURF plug with 30 bbls water with Schlumberger - Turn to rig - Displace with mud 204 bbls @ 8.5 bpm 650 psi - Bump plug with 1700 psi 1000 psi over circulating pressure - Bleed off pressure - Check floats - Floats holding - 149 bbls cement back to surface 19:00 - 20:00 1.00 CASE P SURF Flush Annular and flow line - Rig down Schlumberger cement head & cement lines - Back out & Lay down landing joint 20:00 - 21 :00 1.00 CASE P SURF Rig down casing equipment - Lay down tools - Rig down Divertor line 21 :00 - 22:00 1.00 CASE P SURF Nipple down Divertor Annular - Knife valve 22:00 - 23:00 1.00 CASE P SURF Nipple up FMC speed head - Test metal to metal seal to 1000 psi for 10 mins - ok 23:00 - 00:00 1.00 CASE P SURF Nipple up BOP's 1/23/2004 00:00 - 01 :00 1.00 CASE P SURF Nipple up BOP's 01 :00 - 02:00 1.00 CASE P SURF Open annulus valve - Install test plug - Rig up testing equipment 02:00 - 05:30 3.50 CASE P SURF Testing BOP's - 250 low 2500 high Annular - 5 mins each test - 250 low 3500 - Pipe rams - Blind rams - Choke manifold - HCR choke / HCR kill - Manual Choke / Manual Kill - Upper / Lower IBOP - Floor safety valves - 5 mins each test - Test good - John Spaulding with AOGCC waived witness of BOP test 05:30 - 06:30 1.00 CASE P SURF Rig down testing equipment - Pull test plug - Installed wear ring - Close annulus valve 06:30 - 08:30 2.00 CASE P SURF Made up BHA: 9-7/8" Smith GFXiVC bit jetted with 3-15s and 1-10 center jet. Picked up adjustable motor and set at 1.22 degrees. Made up MWD/GRlRes. 08:30 - 09:00 0.50 CASE P SURF Run in hole with 4" drill pipe to 2430' (Float collar at 2441 ') 09:00 - 10:00 1.00 CASE P SURF Slip and cut drill line. Service top drive. 10:00 - 11 :00 1.00 CASE P SURF Rigged up to test casing with cementing line. Pressure tested 10-3/4" casing to 2500 psi for 30 minutes. Recorded test on chart. Good test. 11:00 - 12:00 1.00 DRILL P SURF Drill float collar, shoe track float shoe and 20' of new hole to 2554' 12:00 - 12:30 0.50 CASE P SURF Displaced mud in hole with new 8.9 ppg mud 12:30 -13:30 1.00 CASE P SURF Performed FIT on 10-3/4" casing shoe. Mud weight 8.9 ppg, 2465' TVD and 350 psi. 11.6 ppg EMW. 13:30 - 00:00 10.50 DRILL P INT1 Directional Drill from 2554' to 4173' - WOB 30 - RPM 120 - TQ on 8K - off 4K - GPM 500 - PP on 2700 - off 2400 - PU 122K- SO 96K - ROT 107K 1/24/2004 00:00 - 23:00 23.00 DRILL P INT1 Directional Drill from 4173' to 6267' - TD 9 7/8" hole - WOB 35K - RPM 120 - TQ on 8K - off 5K - GPM 500 - PP on 3320- off 3120 - PU 125K - SO 100K - ROT 105K 23:00 - 00:00 1.00 CASE P INT1 CBU 3 X - RPM 120 - TQ 5K - GPM 550 - PP 3600 1/25/2004 00:00 - 01 :30 1.50 CASE P COMP Continue CBU 3 X - GPM 550 - RPM 120 - TQ 5K 01 :30 - 04:00 2.50 CASE P COMP Pump out hole @ drlg rate to 5020' - Mad Pass from 5020' to 4720' and 4420' to 4220' - Log at 400' per hour - No rotation 04:00 - 05:00 1.00 CASE P COMP Continue pump out to shoe from 4200' to 2526' 05:00 - 06:00 1.00 CASE P COMP Monitor welt - Run in hole with no problems 06:00 -10:00 4.00 CASE P COMP Broke circulation. Lots of clay baits blinding scalpers. Circulated 3 bottoms up - GPM 550 - RPM 120 - TQ 5K 10:00 - 12:00 2.00 CASE P COMP Pump out of hole @ full drilling rate to shoe at 2526'. 12:00 -12:30 0.50 CASE P COMP Circulate bottoms up at shoe to assure hole is clean. 550 GPM. Monitor well. Pump slug. Printed: 21912004 9:10:31 AM e e BP EXPLORATION Operations.SummaryReport Page 3 of 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/25/2004 1/26/2004 MPG-16 MPG-16 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 Spud Date: 1/21/2004 End: Start: 1/20/2004 Rig Release: 2/4/2004 Rig Number: From - To Hours Task Code NPT Phase Description of Ope rations 12:30 - 13:30 1.00 CASE P COMP Pulled out of hole with 4" drill pipe. Stand collars in derrick. Laid down MWD and motor. 13:30 - 14:00 0.50 CEMT P COMP Stand back 5" HWT - Flex DC's 14:00 - 15:30 1.50 CASE P COMP Lay down MWD - Motor - Bit - Clear rig floor 15:30 - 16:00 0.50 CASE P COMP Rig up Schlumberger E-Une for Side Wall cores 16:00 -17:30 1.50 CASE P COMP RIH with SWC on E-Une - Tools would not pass 3332' - Pull out hole - Rig down Schlumberger E-Une tools 17:30 - 19:00 1.50 CASE P COMP Run Flex DC's - 5 HWT in hole - Lay down Same 19:00 - 22:00 3.00 CASE P COMP Change Top rams to 7 5/8" - Test door seals to 1500 psi - Rig up casing tools 22:00 - 00:00 2.00 CASE P COMP PJSM (Running casing) - Pick up float joints - Check floats - Run 7 5/8" L-80 29.7# BTC-M casing To 1270' 00:00 - 01 :00 1.00 CASE P COMP Con't Run 7 5/8" casing to 2465' (59 jts) 01 :00 - 01 :30 0.50 CASE P COMP Circulate 1 casing volume 1150 stks (115 bbls) - 6 bpm 375 psi 01 :30 - 04:00 2.50 CASE P COMP Con't Run 7 5/8" casing from 2465' to 6185' - Break circulation - Precauctionary wash from 6183' to 6225' 04:00 - 04:30 0.50 CASE P COMP Make up hanger / Landing joint - Land on hanger - (Shoe 6260' - Float collar 6175' - Ran 151 joints 7 5/8" L-80 29.7# BTC-M casing with 2 space out pup joints) - Lay down Franks fill up tool - Make up Schlumberger cementing head / Unes 04:30 - 07:00 2.50 CASE P COMP Break circulation - Stage up pump from 3 bpm to 6 bpm @ 350 - circulate / condition mud for 7 5/8" cement job 07:00 - 08:00 1.00 CEMT P COMP Pump 5 bbls of water - test lines to 3500 psi - pump 15 bbls of CW 100 chemical wash - pump 50 bbls of 10.8 ppg mud push- dropped bottom plug - mixed and pumped 143 bbls of Class G cement w/ .3% 0065 Dispersant + .7% S001 Accelerator + .4% D167 Fluid Loss + 3% D174 Expanding CE + .2% D046 Anti-Foam mixed in a 15.8 ppg slurry with a yield of 1.2 cftIsx. Kicked out top plug with 20 bbls of water. 08:00 - 09:00 1.00 CEMT P COMP Displaced cement with rig pumps at 6 bpm. Initial circulating pressure 110 psi and increased to 700 psi before bumping plug. Bumped plug at 0853 hrs 1/26/2004 with 1700 psi. Held pressure 5 minutes. Bled off pressure - floats held. 09:00 - 09:30 0.50 CEMT P COMP Rigged down cementing head and laid out landing joint. 09:30 - 10:30 1.00 CASE P COMP Install 7-5/8" casing packoff and test to 5000 psi. Good test. Laid down casing tools and remove long bales. 10:30 - 12:00 1.50 CASE P COMP Removed 7-5/8" rams and installed 2-7/8" X 5" VBR. Tested to 2000 psi. Installed wear ring. 12:00 -13:30 1.50 CASE P COMP Make up BHA - Test MWD 5.5 bpm @ 870 psi - @ 13:00 hrs freeze protected 103/4" X 7 5/8" annulus with 80 bbls diesel 2 bpm @ 1100 psi 13:30 - 16:00 2.50 CASE P COMP RIH from 204' to 6150' 16:00 - 16:30 0.50 CASE P COMP Circulate 1 Drill pipe volume - 5.5 bpm @ 1650 psi 16:30 - 17:00 0.50 CASE P COMP Test 7 5/8" casing for 30 mins @ 3500 psi - Good test - Recorded on chart 17:00 -18:00 1.00 CASE P COMP Drill float equipment - cement - Clean out to 6267' Drill 20 new hole to 6287' - 60 rpm - TQ 5K - 5.5 bpm 1700 psi 18:00 -19:30 1.50 CASE P COMP Displace well with 9 ppg FloPro - 60 rpm TQ 5K - 5.5 bpm - 1500 psi 19:30 - 20:00 0.50 CASE P COMP Perform FIT - MD 6260' - TVD 4391' - Mud weight 9 ppg - Surface pressure 480 psi = 11.1 ppg EMW 20:00 - 00:00 4.00 DRILL P PROD1 Directional Drill from 6287' to 6650' - WOB 5K to 7K - RPM 90 - Printed: 2/912004 9:10:31 AM - e BP EXPLORATION Operations Summary Report Page4 of 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/26/2004 1/27/2004 1/28/2004 1/29/2004 1/30/2004 MPG-16 MPG-16 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 Start: 1/20/2004 Rig Release: 2/4/2004 Rig Number: Spud Date: 1/21/2004 End: From- To Hours Task Code NPT Phase Descriptionof Operations 20:00 - 00:00 4.00 DRILL P PROD1 TQ on 6K - off 5K - GPM 250 PP on 1500 - off 1450 - PU 120K - SO 97K - ROT 11 OK 00:00 - 10:30 10.50 DRILL P PROD1 Directional Drill from 6650' to 7498' - 10:30 - 11 :00 0.50 DRILL N DPRB PROD1 Pull back to 7050' for side track 11 :00 - 17:00 6.00 DRILL N DPRB PROD1 Open hole side track @ 7050' - 4414 TVD - ST 1 - (180 low side) Directional Drill from 7050' to 7498' MD 17:00 - 22:00 5.00 DRILL P PROD1 Directional Drill from 7498' to 7936' MD - TVD 4351' 22:00 - 23:00 1.00 DRILL N DPRB PROD1 Pull back to 7548' for side track - Pump out at drlg rate 23:00 - 00:00 1.00 DRILL N DPRB PROD1 Open hole side track @ 7548' MD - 4392 TVD - ST 2 - (180 low side) 00:00 - 04:00 4.00 DRILL N DPRB PROD1 Directional Drill ST 2 - From 7548' to 7936' 04:00 - 20:00 16.00 DRILL P PROD1 Directional Drill ST 2 - From 7936' to 9561' - WOB 5K - RPM 90 - TQ on 5K - off 4.5K - GPM 250 - PP on 2030 - off 1850- PU 117 - SO 82 - ROT 103 20:00 - 22:00 2.00 CASE P COMP CBU 3 X - GPM 275 - PP 2010· RPM 100 - TQ 5K 22:00 - 00:00 2.00 CASE P COMP Pump out to 6961' - Drlg rate 250 gpm 00:00 - 00:30 0.50 CASE P COMP Pump out to shoe from 6961' to 6214' 00:30 - 01 :00 0.50 CASE P COMP CBU - GPM 275 - PP 1400 - Monitor well - Well static - Pump Dry job 01 :00 - 03:00 2.00 CASE P COMP POH to BHA from 6214' to 205' 03:00 - 04:00 1.00 CASE P COMP Stand back Flex DC's - Flush BHA with water - Lay down MWD - Motor - BIT 04:00 - 04:30 0.50 CASE P COMP Clear Floor - Rig up casing tools to run 4.5" Slotted Liner 04:30 - 06:30 2.00 CASE P COMP PJSM - PU 76 joints L-80 12.6# 4.5" IBT Slotted Liner - Baker Hanger - Liner top packer 06:30 - 09:00 2.50 CASE P COMP RIH with 4.5" Liner to 8977' (Shoe depth 8977') (Top liner 5775') 09:00 - 09:30 0.50 CASE P COMP Drop ball set Baker Hanger and Liner top packer - Test backside to 1000 psi - Release off Liner 09:30 - 10:00 0.50 CASE P COMP Monitor well - Well stable - Pump dry job 10:00 - 11 :30 1.50 CASE P COMP POH with Baker Running Tool 11:30-12:00 0.50 CASE P COMP Lay down Baker Running tool - Clear Rig floor 12:00 - 14:00 2.00 STWHIP P PROD2 Pick up 4 3/4" DC's - 31/2" HWT from pipe shed 14:00 - 14:30 0.50 STWHIP P PROD2 Pump string vol to make sure BHA is clear and clean - 8 to 10 bpm @ 200 psi 14:30 - 15:00 0.50 STWHIP P PROD2 Stand back DC's / HTW 15:00 - 15:30 0.50 STWHIP P PROD2 Bring BHA up V-door slide to rig floor 15:30 - 17:00 1.50 STWHIP P PROD2 Make up Baker Whipstock BHA - Orient same - Surface test MWD @ 333' - 6.5 bpm - 500 psi 17:00 - 17:30 0.50 STWHIP P PROD2 RIH with DC's - HWT - Whipstock assembly 17:30 - 20:00 2.50 STWHIP P PROD2 RIH to 5648' - 20:00 - 20:30 0.50 STWHIP P PROD2 Orient Baker Whipstock - Set whipstock @ 5648' (Straight up 7 degree R) 20:30 - 00:00 3.50 STWHIP P PROD2 Mill window at 5648' - 5664' - RPM 100 - TQ 4 to 5 - GPM 280- PP 1350- 00:00 - 00:30 0.50 STWHIP P PROD2 Milling window from 5664' to 5673' - RPM 100 - TQ 4 to 5 - GPM 280 - PP 1400 - WOM 2 to 5 00:30 - 01 :00 0.50 STWHIP P PROD2 Work through window with mills - Pump sweep - Circulate 01 :00 - 02:00 1.00 STWHIP P PROD2 Circulate hole while - Cutting drJg line - Top Drive service - Rig service 02:00 - 02:30 0.50 STWHIP P PROD2 Flow check - Pump Dry job 02:30 - 04:00 1.50 STWHIP P PROD2 POH to Milling assembly 04:00 - 04:30 0.50 STWHIP P PROD2 lay down Milling assembly - Make up stack washer - Flush Printed: 21912004 9:10:31 AM e e BP EXPLORATION OperationsSumm.ary Report Page 5 of? legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPG-16 MPG-16 DRill +COMPlETE DOYON DRilLING INC. DOYON 14 Start: 1/20/2004 Rig Release: 2/4/2004 Rig Number: Spud Date: 1/21/2004 End: Date From- To Hours Task Code NPT Phase Description of Operations 1/30/2004 04:00 - 04:30 0.50 STWHIP P PROD2 BOP's - Lay down stack washer 04:30 - 05:30 1.00 BOPSUR.P PROD2 Pull wear ring - Install test plug - Open annulus valves - Rig up testing equipment 05:30 - 08:30 3.00 BOPSUR. P PROD2 Test BOP's - Annular 250 low 2500 high 5 mins each test - Top / Btm Rams / Choke Manifold / HCR Choke / HCR Kill/ Manual Choke / Manual Kill/ Upper / Lower IBOP / Floor Safety Valves / Blind Rams 250 low 3500 high 5 mins each test - Accumulator test - One failure - Upper IBOP valve would not test 08:30 - 11 :00 2.50 BOPSUR N RREP PROD2 Change out Upper IBOP valve 11:00 -12:00 1.00 BOPSURN RREP PROD2 Retest Upper IBOP valve - Test good - John Crisp with AOGCC waived witness of BOP test 12:00 - 12:30 0.50 BOPSUR P PROD2 Rig down Testing equipment - Pull Test plug - Set wear ring- close annulus valves 12:30 -13:30 1.00 STWHIP P PROD2 Make up 61/8" BHA - Motor set 1.5 - (ABI/ RES / GR / MWD) - Surface test MWD - 240 gpm - @ 820 psi 13:30 - 15:00 1.50 STWHIP P PROD2 RIH to 5673' - No Problem going thru window - TOW 5648' BOW 5660' 15:00 - 00:00 9.00 DRILL P PROD2 Directional Drill from 5673' to 6441' - WOB 5K - RPM 90 - TQ on 4 - off 3 - GPM 250 PP on 1670 off 1500 - PU 112K - SO 95K - ROT 105K 1/31/2004 00:00 - 00:00 24.00 DRILL P PROD2 Directional Drill from 6441' to 9320' - WOB 5K - RPM 90 - TQ on 5K - off 5K - GPM 250 - PP on 2130 - off 1930 - PU 123K- SO 78K - ROT 101K 2/1/2004 00:00 - 03:30 3.50 DRILL P PROD2 Directional Drill from 9320' to 9657' - WOB 5K - RPM 90 - TQ on 5K - off 5K - GPM 250 - PP on 2300 - off 2100 - PU 123K- SO 80K - ROT 100K 03:30 - 04:00 0.50 DRILL P PROD2 Circulate while Geologist consults with town - GPM 254 - PP 2120 - RPM 90 - TQ 5K 04:00 - 08:30 4.50 DRILL P PROD2 Directional Drill from 9657' to 10030' - TO 6 1/8" hole (OA Lateral) - WOB 5K - RPM 90 - TQ on 5K - off 5K - GPM 275 - PP on 2300 off 2060 - PU 125K - SO 80K - ROT 100K 08:30 - 11 :00 2.50 CASE P COMP Circulate 3 X - RPM 100 - GPM 275 - PP (ICP 2350 - FCP 2020) - SO weight without pump 80K 11 :00 - 14:30 3.50 CASE P COMP Pump out from 10030' to shoe 5690' - Pump out at drlg rate 250 GPM - Shut pump off 30' below bottom of window@ - No problems pulling through window 14:30 - 15:00 0.50 CASE P COMP CBU @ 5585' - GPM 250 - PP 1420 - RPM 60 - TQ 2K 15:00 - 17:30 2.50 CASE P COMP Flow check - Pump dry job - POH from 5585' to 205' @ BHA 17:30 - 18:00 0.50 CASE P COMPo Lay down BHA 18:00 - 19:00 1.00 CASE P COMP Down Load - Up Load MWD - Orient tool 19:00 - 19:30 0.50 CASE P COMP Make up Baker whipstock BHA 19:30 - 21:30 2.00 CASE P COMP RIH to 5640' 21 :30 - 22:00 0.50 CASE P COMP Orient hook to 7 DEG right - RIH to 5653' - Latch onto Baker whipstock - Pull 40K over PU weight - Jars fired once - Whipstock free - Stand one stand back @ 5585' - Flow check well - well stable 22:00 - 22:30 0.50 CASE P COMP CBU - GPM 250 - PP 1110 - Flow check - Well stable - Pump dry job 22:30 - 00:00 1.50 CASE P COMP POH - Hole swabbing - Pull slowty out of hole from 5585' to 4113' 2/2/2004 00:00 - 01 :30 1.50 CASE P COMP Con't POH with Baker Whipstock - Hole taking proper fill - POH to BHA Printed: 219/2004 9:10:31 tw. e e BP EXPLORATION Operations Summary Repôrt Page 6 of. 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPG-16 MPG-16 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 Start: 1/20/2004 Rig Release: 2/4/2004 Rig Number: Spud Date: 1/21/2004 End: Date From - To Hours Task Code NPT Phase Description of Operations 2/2/2004 01 :30 - 04:00 2.50 CASE P COMP Lay down 3 1/2" HWT - Lay down 4 3/4" Spiral DC's 04:00 - 04:30 0.50 CASE P COMP Lay down Tailpipe assembly 04:30 - 05:00 0.50 CASE P COMP Clear rig floor - Lay down MWD - Baker Tools 05:00 - 08:30 3.50 CASE P COMP Rig up casing tools to run 4 1/2" slotted liner - PJSM - Run 4.5" L-80 12.6# IBT Slotted liner - Change out elevators to 3 1/2" - Pick up / Make up Baker Hook Wall Liner Hanger 08:30 - 09:00 0.50 CASE P COMP RIH with Liner on 4" DP to Window @ 5654' 09:00 - 09:30 0.50 CASE P COMP Attempt exit window @ 5654' - Rotate 1 1/2 turns to right - Tag window top - Pull back - Rotate 1 turn to right - Tag window top - Pull back to 5656' - Rotate 1/2 turn to right - exit through window 09:30 - 11 :00 1.50 CASE P COMP RIH from 5656' to 9990' 11 :00 - 11 :30 0.50 CASE P COMP Orient Hook Wall Hanger to Hook window @ 5662' Drill pipe measurement - Verify Hook depth by unhooking - Rotating - going down to 5670' DP measured depth - Pull back - Re-hook Hook on window @ 5662' - Liner shoe depth 9992' 11 :30 - 12:30 1.00 CASE P COMP Drop ball- pump ball down - Pump rate 127 gpm @ 380 psi- Slow rate to 42 gpm @ 220 psi - Ball on seat - Pressure up to 3000 psi to release hanger - Pull running tool out of hanger - Pressure up to 4200 psi to blowout ball of running tool 12:30 - 13:00 0.50 CASE P COMP Pump dry job - Stand back 12 stands 13:00 -16:00 3.00 CASE P COMP Lay down 26 stands of 4" drill pipe 16:00 - 16:30 0.50 CASE P COMP Lay down running tool and make up circ sub 16:30 -18:30 2.00 CASE P COMP RIH to 5630' 18:30 - 21 :00 2.50 CASE P COMP Displace well from 9.2 Flo Pro to 8.5+ Seawater - Pump sweep - Chase with new seawater surface to surface until clean - RPM 120 - TQ 2K - 10 BPM @ 1300 psi - PU 110K - SO 100K - ROT 105K 21 :00 - 22:30 1.50 CASE P COMP Cut Drlg Line - Rig Service - Top Drive service 22:30 - 23:30 1.00 CASE P COMP POH - Standing 40 stands in derrick 23:30 - 00:00 0.50 CASE P COMP Lay down 4" drill pipe 2/3/2004 00:00 - 01 :00 1.00 CASE P COMP Con't Laying down 4" Drill Pipe 01 :00 - 02:30 1.50 RUNCOt./P COMP Pull wear ring - Clear rig floor - Rig Up to Run 2 7/8" ESP completion 02:30 - 06:00 3.50 RUNCOt./P COMP PJSM with Doyon Crew - Centrilift Tech - Co Man - Pick up ESP pump - Fill with oil - Make up pump and motor assy - Tie ESP cable to motor / pump assembly - Test 06:00 - 13:00 7.00 RUNCOt./P COMP Picking up 2 7/86.5# L-80 tubing to 4,749 13:00 - 14:00 1.00 RUNCOfIIN SFAL COMP Repair ESP line spool trailer 14:00 - 15:00 1.00 RUNCOt./P COMP Picking up 2 7/8 Tubing to 5,435, total of 171 jts. 15:00 -17:30 2.50 RUNCOt./P COMP Make up Hanger, install ESP cable into hanger, land tubing @ 5,467 171 HP motor @ 5,447, Tandem gas separator 5,428, pump type 1225,407, XN nipple 5,364, KBMM-2 GLM 5,255,KBMM-2 GLM w/ dual orfice valve 107, use 192 Lasalle clamps 17:30 -18:00 0.50 RIGD P COMP Lay down landing jt. test two way check to 1000 psi from top 18:00 - 19:00 1.00 RIGD P COMP Nipple down Bops 19:00 - 20:30 1.50 RIGD P COMP Nipple up adapter flange and 2 9/16 5000# tree, test adapter and tree to 5000 psi, test the integrity of ESP cable 20:30 - 21 :00 0.50 RIGD P COMP Pull TWC and Install BPV in tree 21 :00 - 23:00 2.00 RIGD P COMP Rig up First Energy, test lines to 3,500 psi, Bull head down annulus 75 bbls dry crude 1.5 bbls min 1100 psi, bull head down tubing 12 bbls dry crude 1 bbls min 1250 psi, move 20 Printed: 21912004 9:10:31 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: e e Page? of 7 BP EXPLORATION Operations Summary Report MPG-16 M PG-16 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 Start: 1/20/2004 Rig Release: 2/4/2004 Rig Number: Spud Date: 1/21/2004 End: Dätè From - To Hours Task Code NPT Phäse Description of Operations 2/3/2004 21 :00 - 23:00 23:00 - 00:00 2.00 RIGD P 1.00 RIGD P COMP sds of pipe in derrick to drillers side COMP Secure well, remove double annulus valve, bull plug valves, suck out cellar. Rig release to move @ 2400 hrs 2/3/2004 Printed: 21912004 9:10:31 AM Tree: 2-9/16" - 5M FMC Wellhead: 5M Gen 5 .. 11"x 11" wI 2-7/8" 8rd T&B-' Hanger 2.5" CIW "H" BPV profile .. 20' 178 #/ft .875 thick Driven conductor ~ 103/4" L-80 Float Shoe 12,526' ,.... KOP @ 200' 60+ degree from 3,800' Max hole angle = 66 degree @ 5,550' 103/4" 45.5 ppf L-80 BTRC (Drift 10 = 9.794, cap. = .0961 bpf) 75/8" 29.7 ppf, L-80, BTRC-mod production casing ( drift 10 = 6.750", cap. = 0.0459 bpf ) 4.5",12.6#, L-80 IBTtbg. (cap. = .0152 bpf, id =3.958 ) 2-7/8" 6,5# L-80 EUE 8rd tubing 10 =: 2.347", Gnp. =: OJJ058 bpf ) Window in 7" Casing @ 5,648' - 5673' Well Angle @ window = 72° Baker Tie Back Sleeve 5,775' Baker ZXP Liner Top Packer 5.782' Baker 7-5/8" x 5-1/2" HMC Liner Hanger 5,788' 7 5/8" Halliburton Float Collar 6,175' 7 5/8" Halliburton Float Shoe 6,260' DATE REV. BY 02/03/04 MDO Drilled & Completed Doyon 14 COMMENTS MPG-16\LI l ª ? ~ ~ ~ ~ ~ 'aDF eí8v. '" 62.90' (Doyon ~lL. 2H.2U¡ (Doycln 4) Cameo 2-7/8" x 1" w/ BK latch side pocket KBMM-2 GLM ~ Cameo 2-7/8" x 1" w/ BK latch side pocket KBMM-2 GLM 2-7/8" HES XN-Nipple 2.313" bore (2 .250"no-go) Centrìlìft GC2200 ESP GPMTAR 1:1 122 Centrìlìft tandem gas sep. GRSFTXAR Centrìlìft tandem s8al section GSB30BUTILH6PFS GSB30BLTH6 Centriiift KMH 562 series 171 hp. motor, 2390 v!44 amp Centrilift Pump mate sensor 6 Fin Motor centrílizor Baker Hook Wall Hanger inside 7" Window 5,643' Baker Hook Wall Hanger outside 7" Window 5,600' OA Upper Lateral ~ ::: ~ ~",../..>., ,1 ~ ~ ~ 61/8" Hole td @ 10,030' 103 jts. - 4 1/2" Slotted Liner 12.6# L-80 IBT (5,711 '- 9,947') I 108' I 15.255' I 15,365' I 15,408' 1 I 5,428' I 15,433' I , 5,447' I I 5,462' I I 5,468' I III Rat Hole 40' Btm Baker 4 1/2" Guide Shoe 9,990' 61/8" Holetd @ 9,561' ~ OB Lower Lateral 76 jts, - 41/2", 12.6# L-80, IBT Slotted Liner (6,054'- 8,976') Btm Baker 4 1/2" Float Shoe 8,978' ,.r . Rat Hole 583' MILNE POINT UNIT WELL G-16\ll API NO: 50-029-23189-60 L1 API NO: 50-029-23189-00 BP EXPLORATION (AK) Legal Name: MPG-16 Common Name: MPG-16 Test Date 1/23/2004 1/26/2004 Test Type FIT FIT "~stDepth(TMD) 2,526.0 (ft) 6,260.0 (ft) BPEXPl..ORA'T'ION Leak;.Off Test Summary Test Depth (TVD) 2,465.0 (ft) 4,391.0 (ft) AMW 8.90 (ppg) 9.00 (ppg) Surface Pressure 350 (psi) 480 (psi) Leak Off Pressure (BHP) 1 ,490 (psi) 2,533 (psi) Page 1 of 1 EMW 11.63 (ppg) 11.10 (ppg) e e Printed: 2/912004 9:10:21 AM . . &03 -¿y \U 17-Feb-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPG16 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 7,527.55' MD 7,548.00' MD 9,561.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED , 1 6 2004 ¿\ïa$Ka OIl & Gas Cons. Commission Anchorage ~~~(\\~ DEFINITIVE Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPG MPG-16 e Job No. AKZZ2878275, Surveyed: 28 January, 2004 Survey Report 9 February, 2004 Your Ref: API 500292318900 Surface Coordinates: 6014425.88 N, 557159.78 E (70027' 00.1771" N, 149032'01.1652" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 e Surface Coordinates relative to Project H Reference: 1014425.88 N, 57159.78 E (Grid) Surface Coordinates relative to Structure Reference: 2693.37 N, 783.27 E (True) Kelly Bushing Elevation: 62.90ft above Mean Sea Level Kelly Bushing Elevation: 62.90ft above Project V Reference Kelly Bushing Elevation: 62.90ft above Structure Reference sper-ar-ay-sul'1 DRILLING SeRVrc:eS A Halliburton Company Survey Ref: svy1337 Halliburton Sperry-Sun Survey Report for Milne Point MPG - MPG-16 Your Ref: AP/500292318900 Job No. AKZZ2878275, Surveyed: 28 January, 2004 BPXA Milne Point Unit 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) 7527.55 90.990 102.420 4329.33 4392,23 20.57 N 4736.22 E 6014482.78 N 561895.70 E 4703.42 Tie On Point 7548.00 89.190 101.960 4329.29 4392.19 16.25 N 4756.21 E 6014478.61 N 561915.72 E 9.085 4722.73 Window Point 7577.36 86.600 102.360 4330.37 4393.27 10.07 N 4784.88 E 6014472.65 N 561944.45 E 8.926 4750.45 7622.28 86.410 103.450 4333.11 4396.01 0.06 N 4828.59 E 6014462.97 N 561988.23 E 2.459 4792.60 7672.09 86.910 102.870 4336.01 4398.91 11.26 S 4877.01 E 6014452.02 N 562036.73 E 1.536 4839.28 e 7717.86 89.010 103.940 4337.64 4400.54 21.87 S 4921.50 E 6014441.76 N 562081.30 E 5.149 4882.15 7767.85 89.070 103.630 4338.48 4401.38 33.78 S 4970.04 E 6014430.22 N 562129.93 E 0.632 4928.88 7812.76 89.070 102.880 4339.21 4402.11 44.07 S 5013.75 E 6014420.26 N 562173.72 E 1.670 4971.01 7862.00 86.850 103.660 4340.96 4403.86 55.37 S 5061.64 E 6014409.34 N 562221.70 E 4.778 5017.16 7909.12 87.280 103.970 4343.37 4406.27 66.60 S 5107.34 E 6014398.45 N 562267.48 E 1.124 5061.15 7960.11 87.160 103.600 4345.85 4408.75 78.74 S 5156.80 E 6014386.70 N 562317.03 E 0.762 5108.77 8005.16 86.170 104.630 4348.47 4411.37 89.71 S 5200.42 E 6014376.06 N 562360.73 E 3.168 5150.72 8057.59 86.360 105.130 4351.88 4414.78 103.14S 5250.98 E 6014363.02 N 562411.40 E 1.018 5199.27 8101.44 85.300 104.270 4355.07 4417.97 114.24 S 5293.28 E 6014352.24 N 562453.78 E 3.110 5239.90 8154.51 85.490 105.090 4359.33 4422.23 127.64 S 5344.45 E 6014339.23 N 562505.05 E 1.581 5289.06 8197.59 87.720 104.670 4361.88 4424.78 138.69 S 5386.01 E 6014328.51 N 562546.70 E 5.267 5328.96 8247.28 88.090 103.880 4363.70 4426.60 150.93 S 5434.13 E 6014316.63 N 562594.91 E 1.755 5375.24 8292.60 86.970 99.780 4365.65 4428.55 160.21 S 5478.44 E 6014307.69 N 562639.29 E 9.370 5418.08 8343.73 87.720 95.630 4368.02 4430.92 167.06 S 5529.04 E 6014301.23 N 562689.94 E 8.239 5467.47 8389.00 88.330 91.520 4369.58 4432.48 169.88 S 5574.19 E 6014298.76 N 562735.11 E 9.173 5511.94 8440,77 90.120 89.240 4370.28 4433.18 170,22 S 5625.95 E 6014298.81 N 562786.87 E 5.599 5563.27 8484.82 88.150 82.700 4370.95 4433.85 167.13 S 5669.86 E 6014302.24 N 562830.75 E 15.503 5607.23 e 8534.37 86.230 81.560 4373.38 4436.28 160.35 S 5718.88 E 6014309.40 N 562879.72 E 4.505 5656.71 8580.97 89.440 84.140 4375.14 4438.04 154.56 S 5765.07 E 6014315.54 N 562925.87 E 8.835 5703.27 8630.66 89.380 81.370 4375.65 4438.55 148.29 S 5814.36 E 6014322.19 N 562975.11 E 5.576 5752.95 8677.54 88.080 75.920 4376,69 4439.59 139.07 S 5860.29 E 6014331.76 N 563020.97 E 11.949 5799.66 8728.75 87.900 69.120 4378.49 4441.39 123.71 S 5909.08 E 6014347.50 N 563069.63 E 13.275 5849.96 8773.68 88.270 64.540 4379.99 4442.89 106.04 S 5950.35 E 6014365.48 N 563110.77 E 10.221 5893.07 8824.28 89.070 61.620 4381.17 4444.07 83.14 S 5995.45 E 6014388.73 N 563155.69 E 5.982 5940.63 8870.06 89.200 61.660 4381.86 4444.76 61.40 S 6035.73 E 6014410.78 N 563195.80 E 0.297 5983.26 8918.69 90.000 60.910 4382.20 4445.10 38.03 S 6078.38 E 6014434.47 N 563238.27 E 2.255 6028.44 8966.33 92.660 62.170 4381.09 4443.99 15.34 S 6120.24 E 6014457.48 N 563279.96 E 6.178 6072.76 9017.79 92.350 62.450 4378.84 4441.74 8.55 N 6165.77 E 6014481.72 N 563325.30 E 0.811 6120.85 9061.92 92.040 61.130 4377.15 4440.05 29.39 N 6204.63 E 6014502.86 N 563364.00 E 3.070 6161.96 9109.63 84.250 61.140 4378.70 4441.60 52.40 N 6246.36 E 6014526.18 N 563405.55 E 16.328 6206.18 9 February, 2004 - 16:26 Page 2 of 4 DrillQuest 3.03.05.005 · , Halliburton Sperry-Sun Survey Report for Milne Point MPG - MPG-16 Your Ref: API 500292318900 Job No. AKZZ2878275, Surveyed: 28 January, 2004 BPXA Milne Point Unit 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) 9155.63 83.750 61.590 4383.50 4446.40 74.32 N 6286.51 E 6014548.41 N 563445.53 E 1 .459 6248.71 9205.91 83.440 61.340 4389.11 4452.01 98.19 N 6330.40 E 6014572.62 N 563489.24 E 0.790 6295.18 9251.78 86.970 59.440 4392.95 4455.85 120.77 N 6370.13 E 6014595.51 N 563528.80 E 8.732 6337.37 9301.46 89.380 52.220 4394.53 4457.43 148.64 N 6411.19 E 6014623.69 N 563569.64 E 15.313 6381.51 9347.56 87.530 45.210 4395.78 4458.68 179.02 N 6445.79 E 6014654.34 N 563604.01 E 15.721 6419.56 e 9394.89 91.360 45.840 4396.23 4459.13 212.18 N 6479.56 E 6014687.75 N 563637.52 E 8.201 6457.12 9443.72 92.160 45.850 4394.73 4457.63 246.17 N 6514.57 E 6014722.01 N 563672.27 E 1.638 6496.02 9491.39 92.040 45.870 4392.99 4455.89 279.35 N 6548.76 E 6014755.45 N 563706.21 E 0.255 6533.99 -9561.00 92.040 45.870 4390.51 4453.41 327.79 N 6598.69 E 6014804.27 N 563755.76 E ~. 0.000 6589.45 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 83.000° (True). Magnetic Declination at Surface is 25.034° (20-Jan-04) Based upon Minimum Curvature type calculations, at a Measured Depth of 9561.00ft., The Bottom Hole Displacement is 6606.83ft., in the Direction of 87.156° (True). Comments e Measured Depth (ft) Stat ion Coo r din at e 5 TVD Northings Eastings (ft) (ft) (ft) Comment 7527.55 7548.00 9561.00 4392.23 4392.19 4453.41 20.57 N 16.25 N 327.79 N 4736.22 E 4756.21 E 6598.69 E Tie On Point Window Point Projected Survey 9 February, 2004 - 16:26 Page 3 of4 DrillQuest 3.03.05.005 Milne Point Unit Survey tool proøram for MPG-16 From Measured Vertical Depth Depth (ft) (ft) 0.00 639.00 0.00 637.31 9 February, 2004 - 16:26 To Measured Vertical Depth Depth (ft) (ft) 639.00 9561.00 637.31 4453.41 .~ Halliburton Sperry-Sun Survey Report for Milne Point MPG - MPG-16 Your Ref: AP/500292318900 Job No. AKZZ2878275, Surveyed: 28 January, 2004 BPXA Survey Tool Description Tolerable Gyro (MPG-16PB1) AK-6 BP _IFR-AK (MPG-16PB1) e e Page 4 of 4 Dri/lQuest 3.03.05.005 · .~03-01\O 17-Feb-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPG-16 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 7,527.55' MD 7,548.00' MD 9,561.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED r'~" 1 6 2004 AJaskaOiI & Gas Cons. Cornrniuion Anchorage ~ß~N\~ Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPG MPG-16 MWD e Job No. AKMW2878275, Surveyed: 28 January, 2004 Survey Report 9 February, 2004 Your Ref: API 500292318900 Surface Coordinates: 6014425.88 N, 557159.78 E (70027' 00.1771" N, 149032' 01.1652" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 e Surface Coordinates relative to Project H Reference: 1014425.88 N, 57159.78 E (Grid) Surface Coordinates relative to Structure Reference: 2693.37 N, 783.27 E (True) Kelly Bushing Elevation: 62.90ft above Mean Sea Level Kelly Bushing Elevation: 62.90ft above Project V Reference Kelly Bushing Elevation: 62.90ft above Structure Reference SpE!I""'I""'Y-SUI'1 Þ AlL L..t NS ····S SAVlceS A Halliburton Company Survey Ref: svy1338 Halliburton Sperry-Sun Survey Report for Milne Point MPG - MPG-16 MWD Your Ref: API 500292318900 Job No. AKMW2878275, Surveyed: 28 January, 2004 BPXA Milne Point Unit 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) 7527.55 90.990 102.210 4329.40 4392.30 39.60 N 4734.90 E 6014501.80 N 561894.24 E 4704.43 Tie On Point 7548.00 89.190 101.960 4329.37 4392.27 35.32 N 4754.89 E 6014497.67 N 561914.26 E 8.886 4723.76 Window Point 7577.36 86.600 102.130 4330.44 4393.34 29.20 N 4783.59 E 6014491.77 N 561943.00 E 8,840 4751.49 7622.28 86.410 103.140 4333.18 4396.08 19.39 N 4827.34 E 6014482.30 N 561986.83 E 2.284 4793.72 7672.09 86.910 102.850 4336.09 4398.99 8.21 N 4875.79 E 6014471.49 N 562035.36 E 1.160 4840.45 e 7717.86 89.010 103.400 4337.71 4400.61 2.18 S 4920.33 E 6014461.44 N 562079.98 E 4.743 4883.39 7767.85 89.070 103.140 4338.55 4401.45 13.65 S 4968.98 E 6014450.34 N 562128.72 E 0.534 4930.28 7812.76 89.070 102.390 4339.28 4402.18 23.57 S 5012.77 E 6014440.76 N 562172.59 E 1.670 4972.54 7862.00 86.850 103.460 4341.03 4403.93 34.58 S 5060.73 E 6014430.12 N 562220.63 E 5.004 5018.80 7909.12 87.280 103.620 4343.45 4406.35 45.59 S 5106.48 E 6014419.45 N 562266.46 E 0.974 5062.86 7960.11 87.160 102.670 4345.92 4408.82 57.18 S 5156.08 E 6014408.25 N 562316.14 E 1.876 5110.68 8005.16 86.170 103.740 4348.54 4411.44 67.45 S 5199.86 E 6014398.32 N 562360.01 E 3.233 5152.88 8057.59 86.360 104.490 4351.96 4414.86 80.21 S 5250.60 E 6014385.95 N 562410.84 E 1.473 5201.69 8101.44 85.300 103.650 4355.14 4418.04 90.84 S 5293.02 E 6014375.64 N 562453.34 E 3.081 5242.50 8154.51 85.490 104.470 4359.40 4422.30 103.69 S 5344.33 E 6014363.18 N 562504.75 E 1.581 5291.86 8197.59 87.720 103.950 4361.96 4424.86 114.25 S 5386.02 E 6014352.95 N 562546.52 E 5.315 5331.95 8247.28 88.090 102.920 4363.77 4426.67 125.78 S 5434.32 E 6014341.78 N 562594.90 E 2.201 5378.48 8292.60 86.970 98.350 4365.73 4428.63 134.14 S 5478.80 E 6014333.77 N 562639.45 E 10.373 5421.62 8343.73 87.720 94.680 4368.10 4431.00 139.93 S 5529.54 E 6014328.36 N 562690.23 E 7.319 5471.27 8389.00 88.330 91,100 4369.66 4432.56 142.21 S 5574.72 E 6014326.43 N 562735.43 E 8.017 5515.83 8440.77 90.120 88.650 4370.36 4433.26 142.10 S 5626.48 E 6014326.94 N 562787.18 E 5.860 5567.22 8484.82 88.150 82.380 4371.02 4433.92 138.66 S 5670.36 E 6014330.72 N 562831.04 E 14.918 5611.20 e 8534.37 86.230 80.780 4373.45 4436.35 131.41 S 5719.32 E 6014338.34 N 562879.94 E 5.041 5660.67 8580.97 89.440 83.920 4375.21 4438.11 125.22 S 5765.46 E 6014344.89 N 562926.03 E 9.632 5707.22 8630.66 89.380 81.170 4375.72 4438.62 118.77 S 5814.72 E 6014351.71 N 562975.24 E 5.535 5756.90 8677.54 88.080 75.550 4376.76 4439.66 109.32 S 5860.61 E 6014361.52 N 563021.05 E 12.301 5803.60 8728.75 87.900 68.850 4378.56 4441 .46 93.68 S 5909.31 E 6014377.53 N 563069.63 E 13.080 5853.84 8773.68 88.270 64.280 4380.06 4442.96 75.83 S 5950.50 E 6014395.70 N 563110.68 E 10.199 5896.90 8824.28 89.070 61.500 4381.24 4444.14 52.78 S 5995.52 E 6014419.09 N 563155.53 E 5.716 5944.40 8870.06 89.200 61.790 4381.93 4444.83 31.04 S 6035.80 E 6014441.14 N 563195.64 E 0.694 5987.03 8918.69 90.000 61.000 4382.27 4445.17 7.76 S 6078.50 E 6014464.75 N 563238.16 E 2.312 6032.24 8966.33 92.660 62.290 4381.16 4444.06 14.86 N 6120.40 E 6014487.68 N 563279.89 E 6.205 6076.59 9017.79 92.350 62.600 4378.91 4441.81 38.64 N 6165.98 E 6014511.82 N 563325.28 E 0.852 6124.73 9061.92 92.040 61.300 4377.22 4440.12 59.38 N 6204.90 E 6014532.85 N 563364.04 E 3.026 6165.89 9109.63 84.250 61.060 4378.77 4441.67 82.35 N 6246.65 E 6014556.14 N 563405.61 E 16.336 6210.12 9 February, 2004 - 16:27 Page 2 of 4 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for Milne Point MPG - MPG-16 MWD Your Ref: AP/500292318900 Job No. AKMW2878275, Surveyed: 28 January, 2004 BPXA Milne Point Unit 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) 9155.63 83.750 61.700 4383.58 4446.48 104.26 N 6286.80 E 6014578.36 N 563445.60 E 1.760 6252.65 9205.91 83.440 61.260 4389.19 4452.09 128.12 N 6330.71 E 6014602.55 N 563489.32 E 1.066 6299.13 9251.78 86.970 59.490 4393.02 4455.92 150.71 N 6370.43 E 6014625.45 N 563528.87 E 8.603 6341.31 9301.46 89.380 52.330 4394.60 4457.50 178.52 N 6411.52 E 6014653.58 N 563569.75 E 15.199 6385.49 9347.56 87.530 45.380 4395.85 4458.75 208.83 N 6446.20 E 6014684.14 N 563604.19 E 15.595 6423.60 e 9394.89 91.360 45.960 4396.31 4459.21 241.89 N 6480.05 E 6014717.47 N 563637.79 E 8.184 6461.23 9443.72 92.160 46.090 4394.81 4457.71 275.78 N 6515.18 E 6014751.62 N 563672.65 E 1.660 6500.22 9491.39 92.040 46.180 4393.06 4455.96 308.79 N 6549.52 E 6014784.90 N 563706.74 E 0.315 6538.33 9561.00 92.040 46.180 4390.58 4453.48 356.96 N 6599.71 E 6014833.45 N 563756.56 E 0.000 6594.02 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 83.000° (True). Magnetic Declination at Surface is 25.034° (20-Jan-04) Based upon Minimum Curvature type calculations, at a Measured Depth of 9561.00ft., The Bottom Hole Displacement is 6609.36ft., in the Direction of 86.904° (True). Comments e Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 7527.55 7548.00 9561.00 4392.30 4392.27 4453.48 39.60 N 35.32 N 356.96 N 4734.90 E 4754.89 E 6599.71 E Tie On Point Window Point Projected Survey 9 February, 2004 - 16:27 Page 3 of 4 DrillQuest 3.03.05.005 Milne Point Unit Halliburton Sperry-Sun Survey Report for Milne Point MPG - MPG-16 MWD Your Ref: API 500292318900 Job No. AKMW2878275, Surveyed: 28 January, 2004 BPXA Survey tool program for MPG-16 MWD From Measured Vertical Depth Depth (ft) (ft) 0.00 639.00 0.00 637.31 9 February, 2004 - 16:27 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 639.00 9561.00 e 637.31 Tolerable Gyro (MPG-16PB1 MWD) 4453.48 MWD Magnetic (MPG-16PB1 MWD) e Page 4 of4 DrillQuest 3.03.05.005 . . @..O,3 r¿} I C, 17 -Feb-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITVE Re: Distribution of Survey Data for Well MPG-16PB1 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 7,498.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED ..!. 1 6 ')i"ln A ," ,,' .:._Uv....~ Alaska Oil & Gas Cons" Commilmn Anchorage "'--. ..,. ~~~{\{\ ~ D EFI N ITIVE Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPG MPG-16PB1 e Job No. AKZZ2878275, Surveyed: 27 January, 2004 Survey Report 9 February, 2004 Your Ref: API 500292318970 Surface Coordinates: 6014425.88 N, 557159.78 E (70027'00.1771" N, 149032'01.1652" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 e Surface Coordinates relative to Project H Reference: 1014425.88 N, 57159.78 E (Grid) Surface Coordinates relative to Structure Reference: 2693.37 N, 783.27 E (True) Kelly Bushing Elevation: 62.90ft above Mean Sea Level Kelly Bushing Elevation: 62.90ft above Project V Reference Kelly Bushing Elevation: 62. 90ft above Structure Reference SpE!ï'ï'Y-SUr, D Rlt.:.. 1...1 N GS e R VI c:es A Halliburton Company Survey Ref: svy1329 Halliburton Sperry-Sun Survey Report for Milne Point MPG - MPG-16PB1 Your Ref: AP/500292318970 '. Job No. AKZZ2878275, Surveyed: 27 January, 2004 BPXA Milne Point Unit 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) 0.00 0.000 0.000 -62.90 0.00 0.00 N 0.00 E 6014425.88 N 557159.78 E 0.00 Tolerable Gyro 82.00 0.750 102.000 19.10 82.00 0.115 0.52 E 6014425.77 N 557160.31 E 0.915 0.51 186.00 2.000 71.000 123.07 185.97 0.34 N 2.91 E 6014426.24 N 557162.68 E 1.357 2.93 275.00 2.750 61.000 211.99 274.89 1.88 N 6.24 E 6014427.81 N 557166.01 E 0.960 6.42 365.00 3.400 70.000 301.86 364.76 3.84 N 10.64 E 6014429.80 N 557170.39 E 0.898 11.03 e 455.00 4.450 82.000 391.65 454.55 5.24N 16.60 E 6014431.24 N 557176.34 E 1.475 17.12 550.00 6.000 90.000 486.25 549.15 5.75N 25.22 E 6014431.82 N 557184.95 E 1.799 25.73 639.00 9.800 108.000 574.41 637.31 3.41 N 37.08 E 6014429.57 N 557196.83 E 5.045 37.22 AK-6 BP _IFR-AK 759.13 13.180 108.090 692.11 755.01 4.01 S 59.83 E 6014422.33 N 557219.64 E 2.814 58.90 855.13 13.410 108.550 785.54 848.44 10.95 S 80.79 E 6014415.55 N 557240.65 E 0.264 78.85 952.15 13.730 106.650 879.85 942.75 17.825 102.48 E 6014408.84 N 557262.40 E 0.566 99.55 1047.25 14.080 109.310 972.16 1035.06 24.88 S 124.21 E 6014401.95 N 557284.18 E 0.766 120.26 1141.66 14.520 111.610 1063.65 1126.55 33.04 S 146.05 E 6014393.96 N 557306.08 E 0.761 140.94 1239.10 15.110 110.810 1157.85 1220.75 42.05 S 169.28 E 6014385.13 N 557329.38 E 0.641 162.90 1335.02 15.860 110.720 1250.29 1313.19 51.13 S 193.23 E 6014376.23 N 557353.40 E 0.782 185.56 1430.49 16.220 113.250 1342.04 1404.94 61.01 S 217.68 E 6014366.54 N 557377.92 E 0.824 208.62 1525.18 13.770 113.590 1433.50 1496.40 70.74 S 240.16 E 6014356.98 N 557400.48 E 2.589 229.75 1622.22 13.850 111.850 1527.74 1590.64 79.68 S 261.53 E 6014348.20 N 557421.91 E 0.436 249.87 1719.53 13.510 113.190 1622.28 1685.18 88.49 5 282.79 E 6014339.56 N 557443.24 E 0.478 269.89 1815.26 13.960 107.080 1715.28 1778.18 96.29 5 304.10 E 6014331.93 N 557464.61 E 1.586 290.10 1912.44 14.270 106.510 1809.53 1872.43 103.14S 326.79 E 6014325.25 N 557487.35 E 0.350 311.79 2008.18 14.420 107.540 1902.28 1965.18 110.085 349.47 E 6014318.48 N 557510.09 E 0.309 333.45 e 2103.74 14.860 108.070 1994.74 2057.64 117.47 S 372.47 E 6014311.27 N 557533.14 E 0.481 355.37 2200.37 15.100 107.990 2088.09 2150.99 125.20 S 396.22 E 6014303.72 N 557556.95 E 0.249 378.01 2296.97 15.150 108.610 2181.34 2244.24 133.11 S 420.15 E 6014295.99 N 557580.94 E 0.175 400.79 2393.60 15.540 109.270 2274.53 2337.43 141.42S 444.33 E 6014287.88 N 557605.19 E 0.442 423.79 2474.14 15.910 109.000 2352.05 2414.95 148.57 S 464.96 E 6014280.88 N 557625.86 E 0.468 443.38 2576.54 17.970 111.330 2450.00 2512.90 158.89 S 492.94 E 6014270.78 N 557653.93 E 2.118 469.91 2673.63 21.610 111 .160 2541 .34 2604.24 170.79 S 523.58 E 6014259.11 N 557684.65 E 3.750 498.86 2771.77 25.400 109.880 2631.32 2694.22 184.48 5 560.24 E 6014245.70 N 557721.42 E 3.896 533.58 2866.92 29.630 104.200 2715.71 2778.61 197.205 602.26 E 6014233.31 N 557763.53 E 5.227 573.74 2960.87 34.360 98.280 2795.38 2858.28 206.72 S 651.05 E 6014224.16 N 557812.39 E 6.036 621.00 3056.45 37.850 92.030 2872.62 2935.52 211.645 707.08 E 6014219.67 N 557868.46 E 5.305 676.02 3151.93 42.240 85.200 2945.73 3008.63 209.99 S 768.40 E 6014221.78 N 557929.76 E 6.500 737.08 3247.74 46.750 81.970 3014.07 3076.97 202.42 S 835.08 E 6014229.87 N 557996.39 E 5.266 804.19 9 February, 2004 - 16:26 Page 2 of5 Dril/Quest 3.03.05.005 Halliburton Sperry-Sun Survey Report for Milne Point MPG - MPG-16PB1 Your Ref: API 500292318970 Job No. AKZZ2878275, Surveyed: 27 January, 2004 BPXA Milne Point Unit 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) (a/100ft) 3342.27 50.550 78.000 3076.52 3139.42 190.02 S 904.91 E 6014242.81 N 558066.12 E 5.107 875.01 3437.78 53.060 75.940 3135.58 3198.48 173.07 S 978.02 E 6014260.31 N 558139.10 E 3.127 949.64 3534.80 55.580 74.430 3192.16 3255.06 152.91 S 1054.20 E 6014281.06 N 558215.12 E 2.889 1027.70 3631.89 58.490 74.100 3244.99 3307.89 130.82 S 1132.59 E 6014303.75 N 558293.34 E 3.011 1108.21 3727.68 58.140 74.030 3295.30 3358.20 108.44 S 1210.97 E 6014326.73 N 558371.55 E 0.371 1188.73 e 3824.14 60.080 77.280 3344.83 3407.73 87.96 S 1291.15 E 6014347.83 N 558451.57 E 3.522 1270.81 3919.67 61.780 82.780 3391.27 3454.17 73.54 S 1373.35 E 6014362.87 N 558533.65 E 5.337 1354.15 4015.16 62.820 86.640 3435.67 3498.57 65.76 S 1457.51 E 6014371.30 N 558617.75 E 3.741 1438.63 4110.87 63.450 86.560 3478.92 3541.82 60.70 S 1542.74 E 6014377.01 N 558702.94 E 0.662 1523.84 4207.93 61.870 85.890 3523.50 3586.40 55.03 S 1628.77 E 6014383.35 N 558788.92 E 1.740 1609.92 4303.96 60.070 85.630 3570.10 3633.00 48.82 S 1712.50 E 6014390.20 N 558872.60 E 1.889 1693.78 4399.64 60.880 86.570 3617.25 3680.15 43.16 S 1795.56 E 6014396.49 N 558955.62 E 1.203 1776.92 4495.58 61.750 86.290 3663.30 3726.20 37.92 S 1879.56 E 6014402.38 N 559039.58 E 0.942 1860.93 4592.08 60.220 85.170 3710.10 3773.00 31.64 S 1963.71 E 6014409.30 N 559123.68 E 1.882 1945.22 4687.77 59.780 84.210 3757.95 3820.85 23.98 S 2046.22 E 6014417.60 N 559206.13 E 0.983 2028,05 4784.18 60.630 84.130 3805.85 3868.75 15.48 S 2129.46 E 6014426.74 N 559289.29 E 0.885 2111.70 4879.96 56.160 83.730 3856.04 3918.94 6.86S 2210.55 E 6014435.98 N 559370.32 E 4.680 2193.24 4976.67 56.200 84.070 3909.86 3972.76 1.68 N 2290.44 E 6014445.13 N 559450.14 E 0.295 2273.57 5072.42 58.570 84.820 3961.47 4024.37 9.48 N 2370.71 E 6014453.54 N 559530.35 E 2.562 2354.19 5167.53 61.060 83.460 4009.29 4072.19 17.88N 2452.48 E 6014462.57 N 559612.05 E 2.895 2436.38 5262.65 61.220 82.720 4055.20 4118.10 27.91 N 2535.18 E 6014473.23 N 559694.67 E 0.702 2519.69 5356.79 61.030 82.920 4100.66 4163.56 38.21 N 2616.97 E 6014484.16 N 559776.38 E 0.274 2602.12 e 5453.97 61.280 83.700 4147.54 4210.44 48.12 N 2701.51 E 6014494.72 N 559860.85 E 0.749 2687.24 5550.42 66.240 84.100 4190.17 4253.07 57.31 N 2787.51 E 6014504.57 N 559946.77 E 5.156 2773.72 5646.16 72.060 84.680 4224.24 4287.14 66.04 N 2876.51 E 6014513.98 N 560035.70 E 6.105 2863.12 5742.81 77.260 84.750 4249.80 4312.70 74.62 N 2969.29 E 6014523.28 N 560128.41 E 5.381 2956.25 5839.11 81.630 85.990 4267.43 4330.33 82.26 N 3063.63 E 6014531.63 N 560222.69 E 4.711 3050.82 5934.72 82.010 85.070 4281.04 4343.94 89.63 N 3157.98 E 6014539.73 N 560316.98 E 1.032 3145.36 6031.46 81.950 84.930 4294.53 4357.43 97.98 N 3253.41 E 6014548.81 N 560412.34 E 0.156 3241 .1 0 6126.35 81.520 83.590 4308.17 4371.07 107.37 N 3346.84 E 6014558.92 N 560505.70 E 1 .469 3334.98 6201.70 81 .450 83.210 4319.33 4382.23 115.94 N 3420.86 E 6014568.05 N 560579.65 E 0.507 3409.49 6277.98 83.130 86.340 4329.57 4392.47 122.82 N 3496.13 E 6014575.51 N 560654.86 E 4.624 3485.04 6320.06 87.100 88.740 4333.15 4396.05 124.61 N 3538.00 E 6014577.63 N 560696.73 E 11.013 3526.82 6374.51 86.230 92.090 4336.32 4399.22 124.22 N 3592.35 E 6014577.65 N 560751.07 E 6.346 3580.71 6421.81 87.160 93.040 4339.05 4401.95 122.11 N 3639.53 E 6014575.90 N 560798.26 E 2.808 3627.28 9 February, 2004 - 16:26 Page 3 of 5 DriflQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for Milne Point MPG - MPG-16PB1 Your Ref: AP/500292318970 Job No. AKZZ2878275, Surveyed: 27 January, 2004 BPXA Milne Point Unit 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) 6469.60 87.590 93.220 4341.23 4404.13 119.50 N 3687.19E 6014573.66 N 560845.95 E 0.975 3674.27 6517.26 87.960 93.800 4343.09 4405.99 116.58 N 3734.73 E 6014571.11 N 560893.50 E 1 .443 3721.10 6566.42 87.960 93.240 4344.84 4407.74 113.57 N 3783.76 E 6014568.47 N 560942.56 E 1.138 3769.40 6615.23 85.120 92.120 4347.78 4410.68 111.29 N 3832.43 E 6014566.56 N 560991.24 E 6.253 3817.42 6662.04 86.230 93.260 4351.31 4414.21 109.10 N 3879.05 E 6014564.73 N 561037.88 E 3.394 3863.43 e 6711.75 86.100 92.670 4354.64 4417.54 106.53 N 3928.58 E 6014562.54 N 561087.43 E 1.213 3912.28 6758.11 91.170 94.550 4355.74 4418.64 103.61 N 3974.82 E 6014559.98 N 561133.69 E 11.663 3957.82 6808.18 91.610 93.040 4354.53 4417.43 100.30 N 4024.76 E 6014557.05 N 561183.66 E 3.140 4006.99 6853.64 91.850 92.530 4353.15 4416.05 98.09 N 4070.15 E 6014555.19 N 561229.06 E 1.239 4051.77 6905.02 90.800 91.650 4351.96 4414.86 96.22 N 4121.48 E 6014553.71 N 561280.40 E 2.666 4102.49 6949.25 90.120 91.550 4351.61 4414.51 94.99 N 4165.69 E 6014552.81 N 561324.62 E 1.554 4146.22 7000.44 89.940 90.220 4351.58 4414.48 94.20 N 4216.87 E 6014552.42 N 561375.81 E 2.622 4196.92 7045.68 89.440 92.310 4351.83 4414.73 93.20 N 4262.10 E 6014551.76 N 561421.04 E 4.750 4241.69 7096.02 90.310 96.300 4351.94 4414.84 89.42 N 4312.29 E 6014548.37 N 561471.25 E 8.112 4291.04 7141.67 90.990 99.850 4351.42 4414.32 83.01 N 4357.47 E 6014542.31 N 561516.49 E 7.917 4335.11 7192.89 88.460 102.870 4351.67 4414.57 72.92 N 4407.68 E 6014532.61 N 561566.77 E 7.691 4383.71 7238.14 85.610 1 02.790 4354.01 4416.91 62.89 N 4451.74 E 6014522.91 N 561610.90 E 6.301 4426.22 7288.54 83.810 102.360 4358.65 4421.55 51.96 N 4500.72 E 6014512.36 N 561659.97 E 3.671 4473.50 7333.80 83.570 103.020 4363.63 4426.53 42.08 N 4544.60 E 6014502.81 N 561703.93 E 1.543 4515.86 7383.28 83.320 102.810 4369.28 4432.18 31.09 N 4592.52 E 6014492.20 N 561751.92 E 0.658 4562.07 7430.32 82.940 102.960 4374.90 4437.80 20.68 N 4638.04 E 6014482.13 N 561797.53 E 0.868 4605.99 7498.00 82.940 102.960 4383.22 4446.12 5.61 N 4703.50 E 6014467.57 N 561863.10 E 0.000 4669.12 Projected Survey e All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 83.000° (True). Magnetic Declination at Surface is 25.035° (20-Jan-04) Based upon Minimum Curvature type calculations, at a Measured Depth of 7498.00ft., The Bottom Hole Displacement is 4703.50ft., in the Direction of 89.932° (True). 9 February, 2004 - 16:26 Page 4 of5 DrillQuest 3.03.05.005 .. .... Halliburton Sperry-Sun Survey Report for Milne Point MPG - MPG-16PB1 Your Ref: AP/500292318970 Job No. AKZZ2878275, Surveyed: 27 January, 2004 Milne Point Unit BPXA Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 7498.00 4446.12 5.61 N 4703.50 E Projected Survey e Survey tool program for MPG-16PB1 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 639.00 0.00 637.31 639.00 7498.00 637.31 Tolerable Gyro 4446.12 AK-6 BP _IFR-AK e 9 February, 2004· 16:26 Page 5 of 5 DrillQuest 3.03.05.005 . . 80,3- (9 \U 17 -Feb-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPG-16PB1 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 7,498.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED . 1 6 2004 ß~aska Oil & Gas Cons. CommiS8lon Anchorage ~~Dr'\'\:~ Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPG MPG-16PB1 MWD e Job No. AKMW2878275, Surveyed: 27 January, 2004 Survey Report 9 February, 2004 Your Ref: API 500292318970 Surface Coordinates: 6014425.88 N, 557159.78 E (70027'00.1771" N, 149032' 01.1652" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 e Surface Coordinates relative to Project H Reference: 1014425.88 N, 57159.78 E (Grid) Surface Coordinates relative to Structure Reference: 2693.37 N, 783.27 E (True) Kelly Bushing Elevation: 62. 90ft above Mean Sea Level Kelly Bushing Elevation: 62.90ft above Project V Reference Kelly Bushing Elevation: 62.90ft above Structure Reference SpE!i"i"Y-SUi1 tfFHCLtNGm seRVrc:es A Halliburton Company Survey Ref: svy1335 Halliburton Sperry-Sun Survey Report for Milne Point MPG - MPG-16PS1 MWD Your Ref: AP/500292318970 Job No. AKMW2878275, Surveyed: 27 January, 2004 BPXA Milne Point Unit 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) 0.00 0.000 0.000 -62.90 0.00 0.00 N 0.00 E 6014425.88 N 557159.78 E 0.00 Tolerable Gyro 82.00 0.750 102.000 19.10 82.00 0.11 S 0.52 E 6014425.77 N 557160.31 E 0.915 0.51 186.00 2.000 71.000 123.07 185.97 0.34 N 2.91 E 6014426.24 N 557162.68 E 1.357 2.93 275.00 2.750 61.000 211.99 274.89 1.88 N 6,24 E 6014427.81 N 557166.01 E 0.960 6.42 365.00 3.400 70.000 301.86 364.76 3.84 N 10.64 E 6014429.80 N 557170.39 E 0.898 11.03 e 455.00 4.450 82.000 391.65 454.55 5.24 N 16.60 E 6014431.24 N 557176.34 E 1.4 75 17.12 550.00 6.000 90.000 486.25 549.15 5.75 N 25.22 E 6014431.82 N 557184.95 E 1.799 25.73 639.00 9.800 108.000 574.41 637.31 3.41 N 37.08 E 6014429.57 N 557196.83 E 5.045 37.22 MWD Magnetic 759.13 13.180 108.380 692.11 755.01 4.07 S 59.81 E 6014422.27 N 557219.62 E 2.814 58.87 855.13 13.410 108.800 785.54 848.44 11.11 S 80.73 E 6014415.39 N 557240.59 E 0.260 78.78 952.15 13.730 106.870 879.85 942.75 18.08 S 1 02.40 E 6014408.59 N 557262.32 E 0.571 99.43 1047.25 14.080 109.040 972.16 1035.06 25.13 S 124.14E 6014401.71 N 557284.10 E 0.660 120.15 1141.66 14.520 112.020 1063.65 1126.55 33.31 S 145.96 E 6014393.69 N 557305.99 E 0.908 140.82 1239.10 15.110 110.220 1157.85 1220.75 42.28 S 169.21 E 6014384.90 N 557329.30 E 0.768 162.79 1335.02 15.860 110.420 1250.29 1313.19 51.17 S 193.22 E 6014376.19 N 557353,39 E 0.784 185.54 1430.49 16.220 113.340 1342.04 1404.94 61.01 S 217.69 E 6014366.54 N 557377.93 E 0.925 208.63 1525.18 13.770 112.750 1433.50 1496.40 70.61 S 240.23 E 6014357.12 N 557400.54 E 2.592 229.83 1622.22 13.850 111.590 1527.74 1590.64 79.35 S 261.68 E 6014348.54 N 557422.06 E 0.297 250.06 1719.53 13.510 113.290 1622.29 1685.19 88.13 S 282.95 E 6014339.93 N 557443.40 E 0.541 270,10 1815.26 13.960 107.460 1715.28 1778.18 96.01 S 304.24 E 6014332.20 N 557464.74 E 1,520 290.27 1912.44 14.270 107.120 1809.53 1872.43 103.06 S 326.86 E 6014325.33 N 557487.42 E 0.330 311.87 2008.18 14.420 109.740 1902.28 1965.18 110.56S 349.36 E 6014318.01 N 557509.98 E 0.696 333,28 e 2103.74 14.860 110.170 1994.74 2057.64 118.80 S 372.06 E 6014309.94 N 557532.74 E 0.474 354.81 2200.37 15.100 109.310 2088.09 2150.99 127.23 S 395.57 E 6014301.68 N 557556.32 E 0.339 377.12 2296.97 15.150 110.220 2181.34 2244.24 135.76 S 419.29 E 6014293.34 N 557580.10 E 0.251 399.62 2393.60 15.540 110.070 2274.53 2337.43 144.56 S 443.30 E 6014284.72 N 557604,17 E 0.406 422.38 2474.14 15.910 109.150 2352.05 2414.95 151.89 S 463.86 E 6014277.55 N 557624.79 E 0.554 441.89 2576.54 17.970 112.010 2450.01 2512.91 162.41 S 491.77 E 6014267.24 N 557652.78 E 2.170 468.31 2673.63 21.610 108.940 2541.35 2604.25 173.83 S 522.57 E 6014256.06 N 557683.67 E 3.898 497.49 2771.77 25.400 109.640 2631.33 2694.23 186.78 S 559.51 E 6014243.40 N 557720.70 E 3.872 532.57 2866.92 29.630 106.000 2715.70 2778.60 200.13 S 601.36 E 6014230.37 N 557762.65 E 4.782 572.48 2960.87 34.360 100.580 2795.38 2858.28 211.41S 649.78 E 6014219.46 N 557811.16 E 5.886 619.17 3056.45 37.850 94.110 2872.62 2935.52 218.46 S 705.58 E 6014212.83 N 557867.01 E 5.404 673.70 3151.93 42.240 84.300 2945.76 3008.66 217.37 S 766.82 E 6014214.39 N 557928.25 E 8.041 734.62 3247.74 46.750 82.200 3014.09 3076.99 209.44 S 833.48 E 6014222.84 N 557994.84 E 4.951 801.74 9 February, 2004 - 16:26 Page 2 of 5 DrillQuest 3.03.05.005 , . Halliburton Sperry-Sun Survey Report for Milne Point MPG - MPG-16PB1 MWD Your Ref: AP/500292318970 Job No. AKMW2878275, Surveyed: 27 January, 2004 BPXA Milne Point Unit 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) 3342.27 50.550 79.340 3076.54 3139.44 198.01 S 903.48 E 6014234.81 N 558064.76 E 4.616 872.62 3437.78 53.060 77.980 3135.60 3198.50 183.23 S 977.07 E 6014250.15 N 558138.23 E 2.856 947.46 3534.80 55.580 74.080 3192.19 3255.09 164.18 S 1053.51 E 6014269.79 N 558214.51 E 4.172 1025.64 3631.89 58.490 73.730 3245.02 3307.92 141.59S 1131.76E 6014292.97 N 558292.59 E 3.012 1106.07 3727.68 58.140 75.080 3295.33 3358.23 119.68 S 1210.27 E 6014315.49 N 558370.93 E 1.254 1186.66 e 3824.14 60.080 79.180 3344.87 3407.77 101.27 S 1290.94 E 6014334.51 N 558451.46 E 4.165 1268.98 3919.67 61.780 81.100 3391.28 3454.18 86.99 S 1373.20 E 6014349.43 N 558533.61 E 2.500 1352.36 4015.16 62.820 85.560 3435.69 3498.59 77.19 S 1457.14 E 6014359.87 N 558617.47 E 4.276 1436.88 4110.87 63.450 85.860 3478.94 3541.84 70.80 S 1542.28 E 6014366.91 N 558702,56 E 0.715 1522.16 4207.93 61.870 80.580 3523.54 3586.44 60.66 S 1627.86 E 6014377.71 N 558788.05 E 5.098 1608.33 4303.96 60.070 83.650 3570.15 3633.05 49.12 S 1711.01 E 6014389.88 N 558871.11 E 3.365 1692.27 4399.64 60.880 84.840 3617.30 3680.20 40.78 S 1793.84 E 6014398.86 N 558953.88 E 1.374 1775.50 4495.58 61.750 87.000 3663.35 3726.25 34.80 S 1877.79 E 6014405.49 N 559037.78 E 2.173 1859.55 4592.08 60.220 87.250 3710.16 3773.06 30.56 S 1962.07 E 6014410.37 N 559122.02 E 1.602 1943.72 4687.77 59.780 85.380 3758.01 3820.91 25.24 S 2044.76 E 6014416.32 N 559204.67 E 1.754 2026.44 4784.18 60.630 84.800 3805.91 3868.81 18.08 S 2128.12E 6014424.13 N 559287.97 E 1.025 2110.05 4879.96 56.160 83.700 3856.09 3918.99 9.92 S 2209.26 E 6014432.90 N 559369.05 E 4.768 2191.58 4976.67 56.200 85.860 3909.93 3972.83 2.62 S 2289.26 E 6014440.82 N 559449.00 E 1.856 2271.88 5072.42 58.570 84.350 3961.53 4024.43 4.28 N 2369.61 E 6014448.33 N 559529.29 E 2.809 2352.47 5167.53 61.060 84.080 4009.35 4072.25 12.57 N 2451.40 E 6014457.25 N 559611.01 E 2.629 2434.66 5262.65 61.220 82.750 4055.26 4118.16 22.12 N 2534.15 E 6014467.44 N 559693.69 E 1.236 2517.96 5356.79 61.030 81.160 4100.73 4163.63 33.66 N 2615.77 E 6014479.60 N 559775.22 E 1 .493 2600.38 e 5453.97 61.280 82.610 4147.61 4210.51 45.67 N 2700.04 E 6014492.26 N 559859.39 E 1.332 2685.48 5550.42 66.240 83.910 4190.24 4253.14 55.80 N 2785.93 E 6014503.05 N 559945.20 E 5.283 2771.96 5646.16 72.060 83.180 4224.31 4287.21 65.87 N 2874.79 E 6014513.79 N 560033.98 E 6.121 2861.39 5742.81 77.260 82.570 4249.87 4312.77 77.43 N 2967.24 E 6014526.06 N 560126.34 E 5.415 2954.56 5839.11 81.630 84.410 4267.50 4330.40 88.15 N 3061.28 E 6014537.50 N 560220.29 E 4.911 3049.20 5934.72 82.010 85.150 4281 .11 4344.01 96.76 N 3155.52 E 6014546.84 N 560314.47 E 0.863 3143.79 6031 .46 81.950 85.120 4294.60 4357.50 104.88 N 3250.97 E 6014555.69 N 560409.85 E 0.069 3239.52 6126.35 81.520 83.120 4308.25 4371.15 114.50 N 3344.38 E 6014566.03 N 560503.18 E 2.134 3333.40 6201.70 81 .450 83.440 4319.40 4382.30 123.22 N 3418.38 E 6014575.32 N 560577.12 E 0.430 3407.92 6277.98 83.130 87.710 4329.64 4392.54 129.05 N 3493.73 E 6014581.72 N 560652.41 E 5.968 3483.41 6320.06 87.100 88.660 4333.22 4396.12 130.37 N 3535.62 E 6014583.37 N 560694.30 E 9.699 3525.16 6374.51 86.230 91.900 4336.39 4399.29 130.11 N 3589.97 E 6014583.52 N 560748.65 E 6.151 3579.07 6421.81 87.160 92.980 4339.12 4402.02 128.10 N 3637.15 E 6014581.87 N 560795.84 E 3.010 3625.65 9 February, 2004 - 16:26 Page 3 of5 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for Milne Point MPG - MPG-16PB1 MWD Your Ref: AP/500292318970 Job No. AKMW2878275, Surveyed: 27 January, 2004 BPXA Milne Point Unit 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) 6469.60 87,590 93.030 4341.31 4404.21 125.59 N 3684.83 E 6014579.73 N 560843.53 E 0.906 3672.67 6517.26 87.960 93.450 4343.16 4406.06 122.90 N 3732.37 E 6014577.41 N 560891.10 E 1.174 3719.53 6566.42 87.960 92.870 4344.91 4407.81 120.19 N 3781.43 E 6014575.07 N 560940.17 E 1.179 3767.89 6615.23 85.120 91.620 4347.85 4410.75 118.28 N 3830.10 E 6014573.54 N 560988.86 E 6.355 3815.97 6662.04 86.230 92.620 4351.38 4414.28 116.56 N 3876.75 E 6014572.17 N 561035.52 E 3.188 3862.06 e 6711.75 86.100 91.500 4354.71 4417.61 114.77 N 3926.31 E 6014570.77 N 561085.10 E 2.263 3911.04 6758.11 91.170 93.380 4355.81 4418,71 112.80 N 3972.60 E 6014569.15 N 561131.40 E 11.663 3956.74 6808.18 91.610 92.110 4354.60 4417.50 110.40N 4022.60 E 6014567.13 N 561181.41 E 2.684 4006.07 6853.64 91.850 91.800 4353.23 4416.13 108.85 N 4068.01 E 6014565.93 N 561226.84 E 0.862 4050.95 6905.02 90.800 90.610 4352.04 4414.94 107.77 N 4119.36E 6014565.25 N 561278.20 E 3.088 4101.79 6949.25 90.120 90.860 4351.68 4414.58 107.21 N 4163.59 E 6014565.02 N 561322.42 E 1.638 4145.62 7000.44 89.940 89.500 4351.66 4414.56 107.05N 4214.78 E 6014565.25 N 561373.61 E 2.680 4196.41 7045.68 89.440 90.870 4351.90 4414.80 106.90 N 4260.02 E 6014565.45 N 561418.85 E 3.224 4241.29 7096.02 90.310 95.420 4352.01 4414.91 104.14 N 4310.27 E 6014563.08 N 561469.12 E 9.202 4290,83 7141.67 90.990 99.400 4351.49 4414.39 98.25 N 4355.52 E 6014557.54 N 561514.42 E 8.844 4335.03 7192.89 88.460 101.820 4351.74 4414.64 88.82 N 4405.86 E 6014548.49 N 561564.83 E 6.835 4383.84 7238.14 85.610 100.910 4354.08 4416.98 79.92 N 4450.16 E 6014539.93 N 561609.19 E 6.611 4426.73 7288.54 83.810 100.760 4358.72 4421.62 70.49 N 4499.44 E 6014530.87 N 561658.55 E 3.584 4474.50 7333.80 83.570 101.520 4363.70 4426.60 61.79 N 4543.58 E 6014522.52 N 561702.76 E 1.751 4517.25 7383.28 83.320 102.080 4369.35 4432.25 51.74 N 4591.70 E 6014512.84 N 561750.95 E 1.233 4563.78 7430.32 82.940 101.170 4374.97 4437.87 42.33 N 4637.44 E 6014503.78 N 561796.76 E 2.084 4608.04 7498.00 82.940 101.170 4383.29 4446.19 29.32 N 4703.34 E 6014491.27 N 561862.76 E 0.000 4671.85 Projected Suvey e All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 83.000° (True). Magnetic Declination at Surface is 25.034° (20-Jan-04) Based upon Minimum Curvature type calculations, at a Measured Depth of 7498.00ft., The Bottom Hole Displacement is 4703.43ft., in the Direction of 89.643° (True). 9 February, 2004 - 16:26 Page 4 of 5 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for Milne Point MPG - MPG-16PB1 MWD Your Ref: API 500292318970 Job No. AKMW2878275, Surveyed: 27 January, 2004 BPXA Milne Point Unit Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 7498.00 4446.19 29.32 N 4703.34 E Projected Suvey e Survey tool program for MPG-16PB1 MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 639.00 0.00 637.31 639.00 7498.00 637.31 Tolerable Gyro 4446.19 MWD Magnetic e 9 February, 2004 -16:26 Page 5 of5 DrillQuest 3.03.05.005 . . /90,,3 -(~ \D 17 -Feb-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPG-16PB2 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 7,045.68' MD 7,050.00' MD 7,936.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager AUachment(s) RECEIVED t·; '~ 1 6 2004 F~ì3~kaOiI& Gas Cons. Comm~" Anchorage ~~~ f1\\b DEFINITIVE Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPG MPG-16PB2 e Job No. AKZZ2878275, Surveyed: 27 January, 2004 Survey Report 9 February, 2004 Your Ref: API 500292318971 Surface Coordinates: 6014425.88 N, 557159.78 E (70027' 00.1771" N, 149032'01.1652" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 e Surface Coordinates relative to Project H Reference: 1014425.88 N, 57159.78 E (Grid) Surface Coordinates relative to Structure Reference: 2693.37 N, 783.27 E (True) Kelly Bushing Elevation: 62.90ft above Mean Sea Level Kelly Bushing Elevation: 62.90ft above Project V Reference Kelly Bushing Elevation: 62.90ft above Structure Reference SI::JE!r'r'Y-SUI'1 DRILLING SSAV'IESS A Halliburton Company Survey Ref: svy1330 Halliburton Sperry-Sun Survey Report for Milne Point MPG - MPG-16PB2 '., Your Ref: API 500292318971 Job No. AKZZ2878275, Surveyed: 27 January, 2004 BPXA Milne Point Unit 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) 7045.68 89.440 92.310 4351.83 4414.73 93.20 N 4262.10 E 6014551.76 N 561421.04 E 4241.69 Tie On Point 7050.00 89.520 92.650 4351.87 4414.77 93.01 N 4266.42 E 6014551.61 N 561425.36 E 8.085 4245.95 Window Point 7096.00 87.350 92.400 4353.12 4416.02 90.98 N 4312.35 E 6014549.94 N 561471.31 E 4.749 4291.30 7142.62 93.580 94.350 4352.74 4415.64 88.24 N 4358.86 E 6014547.55 N 561517.84 E 14.002 4337.13 7191.16 96.000 94.080 4348.69 4411.59 84.69 N 4407.10 E 6014544.37 N 561566.10 E 5.016 4384.57 e 7238.37 94.570 96.830 4344.34 4407.24 80.22 N 4453.89 E 6014540.26 N 561612.92 E 6.543 4430.4 7 7286.72 94.140 99.710 4340.67 4403.57 73.28 N 4501.59 E 6014533.69 N 561660.68 E 6.006 4476.97 7335.01 93.890 102.670 4337.29 4400.19 63.94 N 4548.84 E 6014524.70 N 561708.00 E 6.136 4522.73 7382.87 94.270 103.340 4333.88 4396.78 53.19 N 4595.36 E 6014514.32 N 561754.59 E 1.606 4567.59 7431.18 91.420 103.560 4331.49 4394.39 41.97 N 4642.28 E 6014503.46 N 561801.60 E 5.917 4612.79 7480.11 91.360 102,670 4330.30 4393.20 30.87 N 4689.92 E 6014492.72 N 561849.32 E 1.823 4658.72 7527.55 90.990 102.420 4329.33 4392.23 20.57 N 4736.22 E 6014482.78 N 561895.70 E 0.941 4703.42 7575.31 95.570 104.100 4326.59 4389.49 9.64 N 4782.61 E 6014472.20 N 561942.18 E 10.212 4748.14 7622.74 95.750 102.850 4321.92 4384.82 1.36 S 4828.51 E 6014461.55 N 561988.16 E 2.650 4792.36 7670.74 95.560 102.590 4317.19 4380.09 11.88 S 4875.11 E 6014451.39 N 562034.83 E 0.669 4837.32 7718.79 96.120 102.540 4312.30 4375.20 22.28 S 4921.76 E 6014441.35 N 562081.57 E 1.170 4882.36 7766.31 95.810 101.860 4307.36 4370.26 32.26 S 4967.96 E 6014431.72 N 562127.84 E 1.566 4926.99 7813.63 95.070 102.760 4302.87 4365.77 42.31 S 5013.98 E 6014422.03 N 562173.94 E 2.456 4971.45 7861.92 97.500 102.350 4297.59 4360.49 52.74 S 5060.83 E 6014411.96 N 562220.86 E 5.102 5016.68 7936.00 97.500 102.350 4287.92 4350.82 68.45 S 5132.57 E 6014396.80 N 562292.73 E 0.000 5085.98 Projected Suvey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. e Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 83.000° (True). Magnetic Declination at Surface is 25.035° (20-Jan-04) Based upon Minimum Curvature type calculations, at a Measured Depth of 7936.0Oft., The Bottom Hole Displacement is 5133.03ft., in the Direction of 90.764° (True). 9 February, 2004·16:26 Page 2 of 3 DrillQuest 3.03.05.005 Milne Point Unit Comments Measured Depth (ft) 7045.68 7050.00 7936.00 Halliburton Sperry-Sun Survey Report for Milne Point MPG - MPG-16PB2 Your Ref: AP/500292318971 Job No. AKZZ2878275, Surveyed: 27 January, 2004 BPXA Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 4414.73 4414.77 4350.82 Comment 93.20 N 93.01 N 68.45 S e 4262.10 E 4266.42 E 5132.57 E Tie On Point Window Point Projected Suvey Survey tool program for MPG-16PB2 From Measured Vertical Depth Depth (ft) (ft) 0.00 639.00 9 February, 2004 - 16:26 0.00 637.31 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 639.00 7936.00 637.31 Tolerable Gyro (MPG-16PB1) 4350.82 AK-6 BP _IFR-AK (MPG-16PB1) e Page 3 of 3 DrillQuest 3.03.05.005 . . ÐC'3-29 \0 17 -Feb-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPG-16PB2 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 7,045.68' MD 7,050.00' MD 7,936.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager AUachment(s) RECEIVED '-~ 1 6 2004 .Alaska Oil & Gas Cons. Commisalon Anchorage ~~~N\\.b '" Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPG MPG-16PB2 MWD e Job No. AKMW2878275, Surveyed: 27 January, 2004 Survey Report 9 February, 2004 Your Ref: API 500292318971 Surface Coordinates: 6014425.88 N, 557159.78 E (70· 27' 00.1771" N, 149· 32' 01.1652" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 e Surface Coordinates relative to Project H Reference: 1014425.88 N, 57159.78 E (Grid) Surface Coordinates relative to Structure Reference: 2693.37 N, 783.27 E (True) Kelly Bushing Elevation: 62. 90ft above Mean Sea Level Kelly Bushing Elevation: 62.90ft above Project V Reference Kelly Bushing Elevation: 62.90ft above Structure Reference spaf""'f""'Y-su.., CFUL...L...ING SeRvrceS A Halliburton Company Survey Ref: svy1336 .... ':I Halliburton Sperry-Sun Survey Report for Milne Point MPG - MPG-16PB2 MWD ..... Your Ref: AP/500292318971 Job No. AKMW2878275, Surveyed: 27 January, 2004 BPXA Milne Point Unit 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) 7045.68 89.440 90.870 4351.90 4414.80 106.90 N 4260.02 E 6014565.45 N 561418.85 E 4241.29 Tie On Point 7050.00 89.520 92.650 4351.94 4414.84 106.77 N 4264.33 E 6014565.35 N 561423.17 E 41 .244 4245.56 Window Point 7096,00 87.350 91.410 4353.20 4416.10 105.14 N 4310.28 E 6014564.07 N 561469.13 E 5.433 4290.97 7142.62 93.580 93.690 4352.82 4415.72 103.07 N 4356.83 E 6014562.36 N 561515.69 E 14.229 4336.91 7191.16 96.000 93.500 4348.76 4411.66 100.03 N 4405.10 E 6014559.70 N 561563.98 E 5.001 4384.46 e 7238.37 94.570 96.100 4344.42 4407.32 96.10 N 4451.94 E 6014556.12 N 561610.85 E 6.265 4430.47 7286.72 94.140 98.890 4340.74 4403.64 89.81 N 4499,73 E 6014550.20 N 561658.69 E 5.822 4477.14 7335.01 93.890 101.780 4337.36 4400.26 81.17 N 4547.12 E 6014541.92 N 561706.14 E 5.992 4523.12 7382.87 94.270 102.590 4333.96 4396.86 71.09 N 4593.78 E 6014532.20 N 561752.88 E 1.866 4568.20 7431.18 91.420 103.160 4331.56 4394.46 60.34 N 4640.81 E 6014521.82 N 561799.99 E 6.016 4613.58 7480.11 91.360 102.170 4330.37 4393.27 49.62 N 4688.54 E 6014511.46 N 561847.80 E 2.026 4659.64 7527.55 90.990 102.210 4329.40 4392.30 39.60 N 4734.90 E 6014501.80 N 561894.24 E 0.784 4704.43 7575.31 95.570 103.860 4326.67 4389.57 28.85 N 4781.34 E 6014491.40 N 561940.76 E 10.191 4749.22 7622.74 95.750 102.790 4321.99 4384.89 17,98 N 4827.27 E 6014480.88 N 561986.77 E 2.277 4793.47 7670.74 95.560 102.870 4317.26 4380.16 7.37 N 4873.84 E 6014470.63 N 562033.42 E 0.429 4838.41 7718.79 96.120 103.410 4312.37 4375.27 3.50 S 4920.39 E 6014460.12 N 562080.05 E 1.615 4883.29 7766.31 95.810 102.850 4307.43 4370.33 14.23 S 4966.42 E 6014449.74 N 562126.16 E 1.341 4927.66 7813.63 95.070 103.770 4302.94 4365.84 25.08 S 5012.26 E 6014439.25 N 562172.08 E 2.488 4971.84 7861.92 97.500 102.580 4297.66 4360.56 36.02 S 5058.99 E 6014428.66 N 562218.90 E 5.597 5016.89 7936.00 97.500 102.580 4287.99 4350.89 52.02 S 5130.67 E 6014413.22 N 562290.70 E 0.000 5086.09 Projected Suvey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. e Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 83.000° (True). Magnetic Declination at Surface is 25.034° (20-Jan-04) Based upon Minimum Curvature type calculations, at a Measured Depth of 7936.00ft., The Bottom Hole Displacement is 5130.93ft., in the Direction of 90.581 ° (True). 9 February, 2004 - 16:27 Page 2 of 3 DrillQuest 3.03.05.005 Milne Point Unit Comments Measured Depth (ft) 7045.68 7050.00 7936.00 , . ". " Halliburton Sperry-Sun Survey Report for Milne Point MPG - MPG-16PB2 MWD Your Ref: API 500292318971 Job No. AKMW2878275, Surveyed: 27 January, 2004 .... BPXA Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Fro m Measured Vertical Depth Depth (ft) (ft) 4414.80 4414.84 4350.89 0.00 637.31 Comment 106.90 N 106.77 N 52.02 S 4260.02 E 4264.33 E 5130.67 E Tie On Point Window Point Projected Suvey e Survey too/program for MPG-16PB2 MWD 0.00 639.00 9 February, 2004 - 16:27 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 639.00 7936.00 637.31 Tolerable Gyro (MPG-16PB1 MWD) 4350.89 MWD Magnetic (MPG-16PB1 MWD) e Page 3 of 3 DrillQuest 3.03.05.005 . f)03~Ð là . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 March 2, 2004 RE: MWDFormationEvaluationLogs MPG-16, AK-MW-2878275 1 LIS formatted Disc with verification listing. J () J.../ tfl.5 API#: 50-029-23189-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: Sign~\.~~~~~ RECEIVED r:; '1 R ~nn ¡í .. \ i OJ 1.._I.:Vf.-} & Gas GOf)$. Commission .~.. r·w\.r.r'2il'-" .' ~;L-,,'j'~i:t"0\Q~\~ RBDMS R'" MAR 3 0 2004 . . Ð03-ð. ') a WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Ok1and 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 March 2, 2004 RE: MWDFonnationEvaIuationLogs MPG-16PB1, AK-MW-2878275 1 LIS fonnatted Disc with verification listing. ) <?:\ LI , _ f _ ~I#: 50-029-23189-70 C) . 1 LQ\[J PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: Signed~~~~ JY\.~'-O ~~ RECEIVED '. . ,< () lV',:,\ ., ~\~,: , t c (~Ul1 ¿} Gas GOfl$, Comm¡~on RBDMS R~ MAR 3 0 2004 . 803-'&IÒ . WELL LOG TRANSMI'ITAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 March 2, 2004 RE: MWDFormationEvaluationLogs MPG-16PB2, AK-MW-2878275 1 LIS formatted Disc with verification listing. API#: 50-029-23189-71 1 a J- ÚJ '"=f PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling SeIVÌces Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: Signe~\~ /Y"\~\..~ RECEIVED f;) \ ~l;J 200.d RBDMS Rr' MAR ~ n 1ft04 - ~~fÆ=I ffiJl fÆ~fÆ~~~ e / / / FRANK H. MURKOWSKI, GOVERNOR ^ I#ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Matt Green Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, Alaska 99519 Re: Milne Point Unit MPG-16 BP Exploration (Alaska), Inc. Permit No: 203-210 Surface Location: 1990; NSL, 3443' WEL, Sec. 27, T13N, RlOE, UM Bottomhole Location: 2810' NSL, 2022' WEL, Sec.26, T13N, RlOE, UM Dear Mr. Green: Enclosed is the approved application for permit to drill the above development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sarah Palin Chair BY ORDER OF THE COMMISSION DATED thisJ4- day of December, 2003 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. _ STATE OF ALASKA _ ALASKA _ AND GAS CONSERVATION CO~SSION PERMIT TO DRILL 20 MC 25.005 1b. Current Well Class 0 Exploratory o Stratigraphic Test 0 Service 5. Bond: 181 Blanket 0 Single Well Bond No. 2S100302630-277 6. Proposed Depth: MD 10077' . TVD 4489' 7. Property Designation: ,1>'9 ADL 025518/)2-f'7ð(; I 8. Land Use Permit: 13. Approximate Spud Date: 01/01/2004 II Drill 0 Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1990' NSL, 3443' WEL, SEC. 27, T13N, R10E, (As Staked) . Top of Productive Horizon: 2053' NSL, 335' WEL, SEC. 27, T13N, R10E, (OB) Total Depth: 2810' NSL, 2022' WEL, SEC. 26, T13N, R10E, (OB) 4b. Location of Well (State Base Plane Coordinates): Surface: X-557160 . y-6014426' Zone'ÂPS4 16. Deviated Wells: Kickoff Depth ~8.CasirigPÌ'()grarrl Size CasinQ 20" 10-3/4" 7-5/8" 4-1/2" 250' ft Maximum Hole Angle Hole 42" 13-1/2" 9-7/8" 6-1/8" Grade H-40 L-80 L-80 L-80 CouplinQ Welded BTC-M BTC-M BTC WeiQht 92# 45.5# 29.7# 12.6# Ádf5' II Development Oil 0 Multiple Zone o Development Gas II Single Zone 11. Well Name and Number: MPG-16 12. Field I Pool(s): Milne Point Unit / Schrader Bluff 9. Acres in Property: 2560 14. Distance to Nearest Property: 8950' 89° 10. KB Elevation 15. Distance to Nearest Well Within Pool (H . ht b GL)' PLANNED KBE & t 200' from Schrader Sand Penetration in MPG-{)6 elg a ove . = 63.8' lee 17. Anticipated pressure (see 20 Me; 25.035) Max. Downhole Pressure: 1966 psig. Max. Surface Pressure: 1545 psig Quantity of Cement (c.f. or sacks) (includinQ staQe data) 260 sx Arctic Set (Approx.) 469 sx PF 'L', 261 sx Class 'G' 567 sx Class 'G' Uncemented Slotted Liner LenQth 112' 2490' 5882' 4295' Top MD TVD Surface Surface Surface Surface Surface Surface 5782' 4326" MD 112' 2490' 5882' 10077' TVD 112' 2434' 4346' 4489' Total Depth MD (ft): Total Depth TVD (ft): 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Matt Green . / Title Drilling Engineer ;ØhkP~ 7 Commission Use Only Permit To Drill,Ó ~ ?n--.API Number: . 3 OQ Number: h..:...J- rtV 50- D2- <7.- 2. , 0 I·... 0 b Conditions of Approval: Samples Required D Yes ,~No Hydrogen Sulfide Measures D Yes ~ No Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 20. Attachments 181 Filing Fee 0 BOP Sketch o Property Plat 0 Diverter Sketch Signature Other: ~5CX) ~\ ~O? -\-<!:">~ OriginS' Sig~ BY sarah pab" Approved Bv: Form 10-401 Revised 3/2003 IPerfOration Depth TVD (ft): 181 Drilling Program 0 Time vs Depth Plot o Seabed Report 181 Drilling Fluid Program o Shallow Hazard Analysis 181 20 MC 25.050 Requirements Date: Contact Matt Green, 564-5581 Phone 564-5581 Date 1~ !kúO;; Prepared By Name/Number: Sondra Stewman, 564-4750 I Permit APprova~/1. ~. I See cover letter for Date: :1\ L O,? other requirements Mud Log Requir (" ¡:: nln; ~ No Directional Surve WJ- j){~ '!JNo DEC - 3 2003 COMMISSIO~~ (J !~~ 1 (J t ~.I /-\ L Alaska Oil & Gas Cons. Commission BY ORDER OF Anchorage 'lìl' I /? THE COMMISSION Date 1.+ \d--¡p? Sub it In Duplicate e Milne paMPG-16 Well Permit IWell Name: MPG-16 Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Multi Lateral Producer "OA" & "OB" Surface Location: Target Location: TOP "OA" Target Location: BHL "OA" Well TD Target Location: TOP "OB" Target Location: BHL "OB" Well TD 3289' FNL, (1990' FSL), 3443' FEL, (1836' FWL), SEC. 27, T13N, R10E E=557159.63 N=6014425.59" 3201' FNL, (2078' FSL), 4264' FEL, (1015' FWL), SEC. 26, T13N, R1 DE E=561617 N=6014549 Z=4295'TVD 2469' FNL, (2810' FSL), 2022' FEL, (3257' FWL), SEC. 26, T13N, R1 DE E=563852 N=6015300 Z=4360' TVD 3226' FNL, (2053' FSL), 335' FEL, (4944' FWL), SEC. 27, T13N, R10E E=560267 N=6014513 Z=4282' TVD 2469' FNL, (2810' FSL), 2022' FEL, (3257' FWL), SEC. 26, T13N, R10E E=563852 N=6015300 Z=4425' TVD I AFE Number: I TBD I Estimated Start Date: 1-Jan-2004 I MD: 110,0771 I TVD: 14,489 I I Rig: I Doyon 14 I I Operating days to complete: 114.3 I I Max Inc: 189 I I KOP: 1250 I I KBE: 163.8 I I I I Well Design (conventional, slim hole, etc.): I Conventional Grass Roots ML Producer I Objective: I Schrader Bluff OA & OB Sand / Mud Program: 13.5-in Surface Hole Mud Properties: Spud - LSND Freshwater Mud Density (ppg) I Funnel Vis I yp I HTHP pH I API Filtrate I LG Solids 8.6 - 9.2 75 -150 25 - 60 N/A 9.0 - 9.5 < 12 < 6.5 9.875-in Intermediate Hole Mud Properties: LSND Freshwater Mud Density (ppg) I PV YP HTHP pH I API Filtrate I LG Solids 8.8 - 9.2 10 - 20 25 - 30 10 - 11 9.0 - 9.5 < 6 < 15 6.125-in Production Hole Mud Properties: KCI-CaCOs FloPro Density (ppg) PV YP I HTHP pH API Filtrate I MBT 9.0 - 9.2 10 - 20 25 - 30 10- 11 9.0 - 9.5 < 6 < 7 LCM Restrictions: No Organic LCM products in the Schrader Bluff formation Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to 08-4 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 lR. 1 e Milne P.MPG-16 Well Permit Cement Program: Casing 10.75-in 40-lb/ft L-80 BTC surface casing Size Basis 175% excess over gauge hole in permafrost interval. 40% excess over gauge hole below permafrost. Top of tail cement 500-ft MD above casing shoe. Total Cement Wash 20-bbl Water Spacer Vol: 401-bbl Spacer 50-bbI10.3-lb/gal un-viscosified Alpha spacer Lead 347-bbl, 469-sx 10.7-lb/gal Permafrost L - 4.15 fe/sx (cement to surface) Tail 54-bbl, 261-sx 15.8-lb/gal Premium G - 1.15 fe/sx of tail at 1 Temp BHST :::: 55°F from SOR, BHCT 60°F estimated by Schlumberger Casing Size Basis 7.625-in 29.7-lb/ft L-80 BTC intermediate casing Top of lead cement 500-ft above top of Ugnu-sand. 0% excess over gauge. Top of tail cement 500-ft MD above top of N-sand. 40% excess over gauge. Total Cement Wash 5-bbl Water Vol: 124-bbl Spacer 30-bbl 10.3-lb/gal un-viscosified Alpha Spacer Tail 124-bbl, 567-sx 15.6-lb/gal Premium G -1.15 fe/sx of tail at Temp BHST:::: 80°F from SOR, BHCT 70°F estimated by Schlumberger Evaluation Program: 13.5-in Hole Section: Open Hole: MWD/GR,IFR/CASANDRA Cased Hole: N/ A 9.875-in Hole Section: Open Hole: MWD/GRlRES, IFRlCASANDRA, Sidewall Cores Cased Hole: N/A 6.125-in Hole section: Open Hole: MWD/GRlRES, ABI/IFRlCASANDRA Cased Hole: N/A ./ 2 e Milne P_MPG-16 Well Permit Formation Markers Formation Tops MOrkb TVDrkb Pore Pressure Estimated EMW (ft) (ft) (psi) (Ib/gal)* Base Permafrost 1902 1864 TUZC 4154 3574 1524 8.35 NA 5177 4084 1608 7.69 NB 5258 4124 1624 7.69 NC 5320 4154 1636 7.69 NE 5382 4184 1648 7.69 NF 5505 4239 1669 7.69 Top OA 5627 4284 1687 7.69 Base OA 5769 4324 1703 7.69 - .. Top OB 5882 4346 1712 7.69 ... "1 ~/8. Base OB 6326 4374 1723 7.69 * Based on 55 depths CasinglTubing Program Hole Size Csg/ Wt/Ft Grade Conn Length Top Bottom Tbg O.D. MD / TVDrkb MD/TVDrkb 42-in 20-in* 92# H-40 Welded 80' 0' 112' / 112' 13.5-in 10.75-in 45.5# L-80 BTC-M 2,490-ft 0' 2,490-ft / 2,434-ft 9.875-in 7.625-in 29.7# L-80 BTC-M 5,882-ft 0' 5,882-ft / 4,346-ft 6.125-in 4.5-in 12.6# L-80 BTC 4,195-ft 5,782-ft / 10,077-ft/ OB Slotted 4,326-ft 4,489-ft 6.125-in 4.5-in 12.6# L-80 BTC 4,443-ft 5,627-ft/ 1 0,070-ft / OA Slotted 4,284-ft 4,424-ft * The 20-in conductors are insulated. Recommended Bit Program BHA Hole Size Depth (MD) Bit Type 1 13.5-in O-ft - 2,490-ft Hughes MX-C1 2 9.875-in 2,490-ft - 5,882-ft Smith FGXiCPS 3 6.125-in 5,882-ft - TO Security FM2643 4 6.125-in 5,627-ft - TO Security FM2643 Nozzle/Flow rate 3-15 & 1-1 0 3-15 & 1-1 0 3-12 3-12 3 e Milne P.MPG-16 Well Permit Well Control: Surface hole will be drilled with a diverter. Intermediate hole: · Maximum anticipated BHP: · Maximum surface pressure: Kick tolerance: · Planned completion fluid: 1,966-psi @ 4,202-ft TVDrkb - Top of "OA" j 1 ,545-psi @ surface (Based on BHP and a full column of gas from TD @ 0.1-psi/ft) 3,500-psi. An FIT to 11.5-lb/gal will be made on the 1 0.75-in casing shoe. 89-bbl with 9.2-lb/gal mud. 9.7-lb/gal brine / 7.0-lb/gal Diesel (1 ,800-ft MD). · Planned BOP test pressure: · Integrity test: Drilling Hazards & Contingencies: Hydrates ,/ . Light to moderate hydrates were encountered on several of the previous G-Pad wells. No drilling problems related to the hydrates were reported. ./. Hydrates generally occur just below the Permafrost (+/- 1800 ss) but may be present in shallower SV sands and also as deep as 3000 ft. Be alert for the possibility of shallow gas and/or hydrates. Use recommended practices for drilling hydrates. Increase mud wt; Maintain cool mud « 60 deg F); Limit ROP and reduce pump rate while drilling hydrates; Circulate connections thoroughly. See Well Program and Recommended Practices for specific information. · Another item to watch out for is deeper gravels below the Permafrost or gravels that calve off within the permafrost and will tend to drop out when the aerated hydrate gas cut mud is being circulated out. Maintain adequate viscosity. In the past several Milne Pt wells have experienced stuck pipe from this situation. Lost Circulation · We do not expect losses while drilling this well. · Offset wells encountered losses while running and cementing casing and only one well had losses while running a hole opener. Below is a list of the wells and the lost circulating problems associated with them. H-06 (1995): Lost 100 bbls running 9-5/8" casing, good returns during cementing except no returns for last 20 bbls, contaminated cement to surface, cement 12 ft down, no top job. 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. Expected Pressures · It is unlikely there will be unexpected overpressure when drilling to the Schrader Bluff formation. Reservoir pressure is expected to be (7.69 Ib/gal EMW). In this well, the Schrader Bluff ;/ formation will be drilled with 9.1-lb/gal mud. 4 e Milne P_MPG-16 Well Permit Pad Data Sheet · Please Read the G-Pad Data Sheet thoroughly. Breathing · N/A Hydrocarbons · Hydrocarbons will be encountered in the Ugnu through the Schrader Bluff. Faults · NA Hydrogen Sulfide · MPG Pad is not designated as an H2S Pad. All G-Pad wells had <2-ppm H2S on the 2001 report. v Anti-collision Issues · MPG-16 surface location is 5-ft from the abandoned MPG-06 wellbore and will parallel that well bore prior to the kick-off at 250-ft. . Distance to Nearest Property · MPG-16 is 8,950-ft from the nearest Milne Point property line. Distance to Nearest Well Within Pool · MPG-16 is 200-ft from the Schrader-sand penetration in MPG-06. 5 e Milne PAtMPG-16 Well Permit DRILL & COMPLETION PROCEDURE Pre-Rig Operations 1 . The 20-in insulated conductor is installed 2. NU diverter Procedure 1. MI/RU Doyon 14 2. Function test diverter, PU 4.0-in drill pipe 3. Drill 13.5-in surface hole 4. Run and cement 1 O.75-in casing 5. ND diverter, install wellhead, NU BOPE and test 6. Drill 9.875-in intermediate hole 7. Run and cement 7.625-in casing 8. Set whipstock and mill window for OB 9. Drill 6.125-in OB horizontal production hole 10. Run 4.5-in slotted liner 11. Run whipstock and mill window for OA lateral 12. Drill 6.125-in OA horizontal production hole 13. Retrieve whipstock 14. Run 4.5-in slotted liner and hang off in 7.625-in casing 15. Displace drilling mud to brine 16. Run 4.5-in jet pump completion 17. ND BOPE / NU tree 18. Freeze protect well 19. RD/MO 6 TREE: Cameron 2-9/16" 5 WELLHÊAD: FMC Gen 5 11".5M Tubing Head: FMC 11-in x 2.875-in ~UPUS~lJ c..;UMPL~IIU~ .. \LP.~-13 ,. I KB. ELEV =63.8-ft I Cellar Box ELEV = 29.5-ft ~ §. 7.625" Casing Shoe @ 5,882-ft MD, 4,346-ft TVD ~' ~ Well Inclination @ Shoe = 81 Degrees ¡ ¡ . ~ \ ".. " '- -- - 114' ~ 20" 92 Iblft. H-40 Welded Insulated 10-3/4" 45.5#, L-80, BTC-M Casing Drift: 9.875 Casing 10: 9.950 Coupling 00: 11.75" Burst: 5,210 psi Collapse: 2,480 psi .... 2.875-in 6.5-lb/ft, L-80, 8rd, EUE Tubing 10: 2.441-in Tubing Capacity: O.00579-bbl/ft Tensile (100%): 145-k.lbf Burst: 10,570-psi Collapse: 13,870-psi 7-5/8" 29.7#, L-80, BTC-M Casing Drift: 6.75 Casing 10: 6.875 Coupling 00: 11.75" Burst: 6,890 psi Collapse: 4,790 psi Window in 7-5/8" casing @ 5,627-ft Mo Well Inclination @ Window = 71 Degrees 4.5-in liner top @ 5,732-ft MD (150-ft lap) DATE 2 Dee 2003 REV. BY MDG COMMENTS Level 3 Multi-Lateral, 4-1/2" Jet Pump Completion ... 42" Hole 2.875-in x 1.0-in Gas Lift Mandrel @ 2,OOO-ft TVD .... 10-3/4"@ 2,490' MD, 2,434' TVDrkb 2 7/8" 'XU' Sliding Sleeve I I opens up (102.313") 2-7/8" XN nipple I I (ID 2.205") Pump, 122 stg. GC2200 I I Tandem Gas Separator I I Tandem Seal Section I I GSB3 DB UT/L T IL H6 PFS Aflas/HSN Motor, 114 HP KMH I 2330 volt, 30 amp 450 Series Phoenix MS 1 w/6 fin Centralizer L__5,500-fU \' ~ -- 6.125-in OA Lateral 110,070-ft MO I - - - - - -- r- - -- - - - - -- 4.5-in Slotted Liner w/Hookwall hanger 9.875-in Hole 6.125-in OB Lateral 10,076-ftMD./ - - - - - -I -- -- -_.~ , 4.5-in Slotted Liner & Hanger Milne Point Unit WF' , : MPG-16 API NO: BP Exploration (Alaska) COMPANYDETAll.S REFERENCE INFORMATION SURVEY PROGRAM Plan: MPG-Curly wp09 (plan Curly G-I6IPlan Curly) :~N: .~~ BP Amoco bp C~~te8m~== ij.i]~~:+~~rÖ~~~8~ True North Depth Fm Depth To Surwy/Plan Tool Created By: Ken AJlen Date: 11/17/2003 Cakulatkm Method; Minimum Curvature Se<:tkm (VS) Relèrenœ: Slot· (O.OON,O.OOE) 34.30 900.00 Planned: MPG.curty wp09 VJ7 CB-GYRo..SS Checked: Date:_ ~= ~~=~ ~;V~~~nder Nortb Meas~~~= ~~t:;~GL) 63.80 900.00 10076.68 Planned: MPG-Curly wp09 V37 MWD+IFR+MS Error Surface: Elliptical + Casing Reviewed: Date· WaminR Method: Rules Based FORMATION TOP DETAILS WEll. DETAll.S No... +,.,.s +FJ·W -mg Eu1Ing La_ Lon,_ Slot No. TVDPath MDPath Formation Plan CurlyQ..16 2693.84 78218 6014426.00 557159.00 70"27'OO.178N 149"J2'OLl88W "'A 0- I 1863.80 1901.95 BPRF TARGET DETAILS 2 3573.80 4153.95 ruzc Start Djr 3/100' : 250' MD, 250'TVD 3 3831.80 4671.38 Ugnu-MA No... TVD +,.,.s +FJ·W """"'mg Eu1Ing s..... 4 3846.80 4701.47 Ugnu-MBI CudyF1t#J 3401!.80 1292.68 1758.14 601573200 558907.00 Polygon 5 3908,80 4825.81 Ugnu-MB2 CurlyF1t#2 3843.80 712.47 2166.74 6015155.00 559320.00 Polygon 6 4053.80 5116.62 Ugnu-MC Curly Poly 4339.80 '.03 429858 6014464.00 561457.00 Polygon CurlyTI Rev. 5 4345.80 63.16 JI08.88 6014513.00 560267.00 Point 7 4083.80 5176.79 SBF2-NA CurIyFh#J 4373.80 275.06 351755 6014728.00 560674.00 Polygon 8 4123.80 5258.04 SBFI-NB C"""TI 4418.80 88.81 4460." 6014549.00 561617.80 PoIut 9 4153.80 5319.92 SBE4-NC Curly Fh#4 4418.80 34754 449923 6014808.00 561655,01) Polygon CurlyTJ Rev. 3 4453.80 -170.05 5740.42 6014300.00 562900.00 PoIot End Djr : 797.77' MD, 792.42' TVD 10 4183.80 5381. 79 SBE2-NE CurlyT4Rev.1 4480.80 276.85 6543.95 6014753.00 563700.00 Point II 4238.80 5504.92 SBEI-NF CurlyT5 4488.80 822.72 6700.15 6015JOO.00 563852.00 Point 12 4283.80 5627.00 TSBD-Top OA 13 4323.80 5769.13 TSBC-Base OA SECTION DETAILS 14 4345.80 5881.88 TSBB-Top OB 15 4373.80 6326.10 SBA5-Base OB See MD Ine Azi TVD +N/-S +EI-W DLeg TFace VSee Target I 34.30 0.00 0.00 34.30 0.00 0.00 0.00 0.00 0.00 . 2 250.00 0.00 0.00 250.00 0,00 0.00 0.00 0.00 0.00 3 416.67 5.00 60.00 416.46 3.63 6.29 3.00 60.00 6.69 4 797.77 14.00 110.00 792.42 -3.85 64.19 3.00 69.21 63.24 5 1784.66 14.00 110.00 1750.00 -85.51 288.54 0.00 0.00 275.97 6 2434.66 14.00 110.00 2380.69 -139.29 436.31 0.00 0.00 416.08 7 3627.83 60.09 84.24 3311.47 -136.61 1126.85 4.00 -30.60 1101.80 8 5209.17 60.09 84.24 4099.95 0.91 2490.68 0.00 0.00 2472.22 1/ 9 5231. 79 61.00 84.25 4111.07 2.89 2510.28 4.00 0.46 2491.92 I 10 5381.79 61.00 84.25 4183.80 16.03 2640.81 0.00 0.00 2623.07 II 5881.88 81.00 84.25 4345.80 63.16 3108.88 4.00 0.00 3093.40 Curly TI Rev. 5 I 12 5901.88 81.00 84.25 4348.93 65.14 3128.53 0.00 0.00 3113.15 'ë' .I 13 5962.12 87.07 88.20 4355.19 69.07 3188.28 12.00 33.15 3172.93 14 7039.78 87.07 88.20 4410.29 102.87 4264.00 0.00 0.00 4244,75 ~ I 15 7236.86 88.00 100.00 4418.80 88.81 4460.04 6.00 85.76 4437.62 Curly T2 0 0 I 16 7299.66 88.48 103.74 4420.73 75.90 4521.45 6.00 82.69 4497.00 eo? 17 8235.93 88.48 103.74 4445.51 -146.38 5430.62 0.00 0.00 5372.30 .<: , .,/ 18 8548.13 88.50 85.00 4453.80 -170.05 5740.42 6.00 -90.20 5676.90 Curly T3 Rev. 3 '" ~ Start Dir4/100': 2434.66' MD, 2380.69'TVD 19 8674.03 87.99 76.20 4457.66 -149.51 5864.45 7.00 -93.45 5802,51 , 20 8845.22 87.99 76.20 4463.67 -108.69 6030.60 0.00 0,00 5972.39 '" " "~/ 21 9505.19 89.20 30.00 4480.80 276.85 6543.95 7.00 -89.18 6528.90 Curly T4 Rev, 1 " '€ , ø 22 9832.68 89,20 10.35 4485.41 582.72 6656.33 6.00 -90.13 6677.73 > " ,"~ 23 10076.68 89.20 10.35 4488.80 822.72 6700.15 0.00 0.00 6750.47 Curly T5 " " ¡-.. CASING DETAILS MD Name Size FT COpy ONLY No. TVD 2433.80 4345.80 4488.80 2489.64 103/4" 5881.88 75/8" 10076.67 41/2" 10.750 7.625 4.500 Curly FI1# I e Ugnu-MS I Curly FIt#2 . 5000 Start Dir4/100': 5209.17' MD, 4099.95'TVD , / End Djr : 5231.79' MD. 4111.07' TVD .......~,/""".~ SI<I" 1)11 ·1 1:)0'. 5.~~ I -I)' ~ID. H 1'1:; S'T\'D SBFI-\;fI 'Ì'"x<t" ~ 7 \ ~.. SBE.I-'< ' / Ì'''~ .J,' ¿; 1:11I1 Dlr : 59(:~: I~' \H'>'4J~~ It1 i \,D >II;~¡:~~':~I~'(:\' / 7·~t ;::::,;~.::::J~;.;. .~: ..... ····....·....~;;;I() \"\ ,// j ~ . ~B.\5-BII~l· Oi1 '':'snc:-nas\:''OA I : : ~ lS:m-it'pOB (url) 1lI1I~ \ ../ End Dir : 7299.66' MD. 4420. 73~::ir 6/100' : 8235.93' MD, 4445.51 'TVD I Start Djr 7/100' : 8548.13' MD,4453.8'TVD ! I F.nd I')lr . fi(,"4.()J' MD. 445".M' TVD / / S,,," I)" 7 11'1': X~·I;.22· ~tl). "·163.67'TVD i ····_·_--~-..._..·.í-.......· " ~ .~. \ \ Curly FIr.':.1 ~n()O ! . Curly 1'2 . Cull)' T~ Rc...; 3 3200 Vertical Section at 83.00° [800ft/in] 4800 , I I 7200 41/2".. .. ~.~- Cllrly 1'11,·4 -: S",rt Dir (, LOO' 9505.19' \11>. 44~o.nZ>\'D ' : CmlyTI R~~·~_~..._ ,';. f'" .' ..-. I ~ ......~"'/......,.- - .. _....'$J: i __._.........._._....._. <·"'lyfl~··_I_;..__.. ..."-.... . "._._" ". ./'.... /' CllrlyT4 R.\.1 4'(-)()",)'- '-''''''.~,.'-'-T "9 ,- I - "- .. .--.... .." ~II--' -./ : .......~,',:~:... :--, -~ ("IIJ"I\'T~ R~~-:.l -.... ....- -' i....~..~ :..... . -..::.. ~ / i' ..........;..·-·..·..·...-_.:-7-..-·+\-\// I ¡ ..·f....·-..· i \ / SlIIrt Dir. 7 100' : R~45.22· \), 4·163 (,''TVD TVD : i -.-..¡....-...) top'i. 82.. 3~:93'MD;444~:5I'tVtJL+¡...+......EnctPir,,'8674,03'MP.4457.6611:\1D Start DidflOO':"8548;WMD' vþ' spIIIl"'I"V-m.n ':r.tŒ:;:~~~;!:;~~!~vrlt.·.·. COMPANY DETAILS BP Amoco bp REFERENCE INFORMA. TION r"_ _.....'-;¡-._ "l/C' oQ..-.........-õ· '~'_" r~-'_· fY'__ ~-·...·G.I6, True North '''M,' 63.80 ", '" ~ " 63" .. .. ,. FORMATIONTOPDETA~S Size No. TVDPath MDPath Formation 10.750 1 1863.80 1901.95 BPRF 7.625 2 3573.80 4153.95 TUZC 4.500 3 3831.80 4671.38 Ugnu-MA 4 3846.80 4701.47 Ugnu-MBl 5 3908.80 4825.81 Ugnu-MB2 6 4053.80 5116.62 Ugnu-MC 7 4083.80 5176.79 SBF2-NA 8 4123.80 5258.04 SBFI-NB 9 4153.80 5319.92 SBE4-NC 10 4183.80 5381.79 SBE2-NE 11 4238.80 5504.92 SBEI-NF 12 4283.80 5627.00 TSBD-Top OA 13 4323.80 5769.13 TSBC-Base OA 14 4345.80 5881.88 TSBB-Top OB 15 4373.80 6326.10 SBA5-Base OB Calculation Method: Minimum Curvature =~et~~ ¥,;v~~AinderNorth Error Surface: Elliptical + Casing Wami~ Method: Rules Based CASING DETAILS No. TVD 2433.80 4345.80 4488.80 MD Name 2489.64 103/4" 5881.88 7 5/8" 10076.67 41/2" l 1/ ,I I {I I .#" ~.# .#' , 0 -# , '/~ '2 ~ ~ +' :c 1:: ~ :c g '" ];00 " SURVEY PROGRAM PI..: MPG-Curly wp09 (PI.. Curly G·I6IPI.. Curly) Depth Fm Depth To SurveyIPlan Too' Created By: Ken Allen Date: 11/11/2003 34JO 900.00 Planned: MPG-Curly wp09 V37 CB-GYlm-SS Checked: Date:_ 900.00 10076.68 Planned: MPG.curly wp09 V37 MWD+lFR+MS Reviewed: Date:~ WELL DETAR.S Non. +NI-S +FJ·W Northing - Lotitudo LoogI- Slot PlanCurIyG-16 2693.84 18218 6014426.00 557159.00 70"27'00.178N 149"32'01.188W WA TARGET DETAll.S Non. 1VD +N/-S +fj.W Nortlring """"" Sh... CurlyFlt#1 3408.80 1292.68 1758.14 6015732.00 558907.00 Polygon CurlyFlt#2 3843.80 712.47 2166.74 6015155.00 559320.00 I'o'ygoo ""lyl'oly 4339.80 5.03 4298.58 6014464.00 561457.00 Polygon Curly TI Rev. 5 4345.80 63.16 3]08.88 6014513.00 560267.00 Pomt CurlyF1t#3 4373.80 275.06 3517.55 6014728.00 560674.00 Polygon CurlyT2 4418.80 88.81 4460.04 6014549.00 561611.80 Poi", CurlyFlt#4 4418.80 347.54 4499.23 6014808.00 561655.00 Polygon CurlyTJRev.3 4453" -110.05 5740.42 6014300.00 562900.00 Poi", CurIyT4Rev.1 4480.80 276.85 6543.95 6014753.00 563700.00 Point Curly T5 4488.80 822.72 6700.1~ 6015300.00 ~63852.00 Point SECTION DETAILS Sec MD Inc Azi TVD +N/-S +FJ-W DLeg TFace VSee Target 1 34,30 0.00 0.00 34.30 0.00 0.00 0.00 0.00 0.00 e 2 250.00 0.00 0.00 250.00 0.00 0.00 0.00 0.00 0.00 3 416.67 5.00 60.00 416.46 3.63 6.29 3.00 60.00 6.69 4 797.77 14.00 110.00 792.42 -3.85 64.19 3.00 69.21 63.24 5 1784.66 14.00 110.00 1750.00 -85.51 288.54 0.00 0.00 275.97 6 2434.66 14.00 110.00 2380.69 -139.29 436.31 0.00 0.00 416.08 7 3627.83 60.09 84.24 3311.47 -136.61 1126.85 4.00 -30.60 1101.80 8 5209.17 60.09 84.24 4099.95 0.91 2490.68 0.00 0.00 2472.22 9 5231.79 61.00 84.25 4111.07 2.89 2510.28 4.00 0.46 2491.92 10 5381.79 61.00 84.25 4183.80 16.03 2640.81 0.00 0.00 2623.07 11 5881.88 81.00 84.25 4345.80 63.16 3108.88 4.00 0.00 3093.40 Curly Tl Rev. 5 12 5901.88 81.00 84.25 4348.93 65.14 3128.53 0.00 0.00 3113.15 13 5962.12 87.07 88.20 4355.19 69.07 3188.28 12.00 33.15 3172.93 14 7039.78 87.07 88.20 4410.29 102.87 4264.00 0.00 0.00 4244,75 15 7236.86 88.00 100.00 4418.80 88.81 4460.04 6.00 85.76 4437.62 Curly 1'2 16 7299.66 88.48 103.74 4420.73 75.90 4521.45 6.00 82.69 4497.00 17 8235.93 88.48 103.74 4445.51 -146.38 5430.62 0.00 0.00 5372.30 18 8548.13 88.50 85.00 4453.80 -170.05 5740.42 6.00 -90.20 5676.90 Curly T3 Rev. 3 19 8674.03 87.99 76.20 4457.66 -149.51 5864.45 7.00 -93.45 5802.51 20 8845.22 87.99 76.20 4463.67 -108.69 6030.60 0.00 0.00 5972.39 21 9505.19 89.20 30.00 4480.80 276.85 6543.95 7.00 -89.18 6528.90 Curly T4 Rev. 1 22 9832.68 89.20 10.35 4485.41 582,72 6656.33 6.00 -90.13 6677. 73 23 10076.68 89.20 10.35 4488.80 822.72 6700.15 0.00 0.00 6750.47 Curly T5 DRAFT COpy 0 y tit -800 ".11" D" : )c,2".Hr \11>. 1111.47' 1"\'1> t s\a~" ~:6l~o. ~:~~~~:i~. ~,I.~;9¡.~J. ;~, d.i/+l,. . Enct Dír : 52~1.79' IMD. 411r.07!TVD ·,11 mmm St"!t ~ìr4/t oq' : 53~1.791 IMD!4\83:ß'¡n Dim! I I I I I j I I I I I I I I , I I I 1600 2400 I 3200 4000 West(-)/East(+) [800ft/in] 6400 4800 I 5600 j I I I j I I I I I ' 7200 spe........y-sun þRILLUIIG $ERVICE$ A, KULllIllMON (":()Mf'N'<Y e Compan)': '''ield: Site: Well: Wellpath: BP Amoco Milne Point MPtGPad Plan Curly G-16 Plan Curly .-.--..,. .. . ----..-----.----... Plan: MPG-Curly wp09 Principal: Yes Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: M Pt G Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Well: Plan Curly G-16 Sperry-Sun KW A Planning _ ,__".. ..______._,_'_.'__n. .,.., ,... ,m ,. e bp ---... - ------------. Date: 11/17/2003 Time: 09:36:45 IJage: Cu-urdinale('\jE) I~ererence: Well: Plan Curly G-16, True North Vertical (n'I» Reference: 0-14 ( 34.3 + 29.5 GL ) 63.8 Section (VS) Reference: Well (0.00N,O.00E,83.00Azi) Survey Calculatiun '1ethod: Minimum Curvature Db: Oracle . ---.. . .. Date Composed: Version: Tied-to: Map Zone: Coordinate System: Geomagnetic Model: 6011726.58 ft 556397.19 ft Latitude: 70 26 Longitude: 149 32 North Reference: Grid Convergence: Slot Name: Well Position: +N/-S 2693.84 ft Northing: 6014426.00 ft +E/-W 782.28 ft Easting: 557159.00 ft Position Uncertainty: 0.00 ft WelIpath: Plan Curly Current Datum: Magnetic Data: Field Strength: Vertical Section: 0-14 ( 34.3 + 29,5 GL ) 6/23/2003 57512 nT Depth From (TVD) ft 34.30 Latitude: Longitude: Height 63.80 ft Drilled From: Tle-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 +N/-S ft 0.00 Casing Points I MD TVI) Diallleter lIoll' Si.f.e :'Iiame i I ft ft in in I 2489.64 2433.80 10.750 12.250 103/4" 5881.88 4345.80 7.625 9.875 7 5/8" 1 0076.67 4488.80 4.500 6.000 4 1/2" Formations ,MD '.TVD. Formations ft ft 1901.95 1863.80 BPRF 4153.95 3573.80 TUZC 4671.38 3831.80 Ugnu-MA 4701.47 3846.80 Ugnu-MB1 4825.81 3908.80 Ugnu-MB2 5116.62 4053.80 Ugnu-MC 5176.79 4083.80 SBF2-NA 5258.04 4123.80 SBF1-NB 5319.92 4153.80 SBE4-NC 5381.79 4183.80 SBE2-NE 5504.92 4238.80 SBE1-NF 5627.00 4283.80 TSBD-Top OA 5769.13 4323.80 TSBC-Base OA 5881.88 4345.80 TSBB-Top OB 6326.10 4373.80 SBA5-Base OB 11/13/2003 37 From Well Ref. Point Alaska, Zone 4 Well Centre bggm2003 33.685 N 24.162 W True 0.43 deg 70 27 0.178 N 149 32 1.188 W Well Ref. Point 34.30 ft Mean Sea Level 25.44 deg 80.83 deg Direction deg 83.00 .... ..____n __ _ _ . __ _ _ _ - -.. - -------------- Lithology . Dip Angle deg 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Dip Dirëctioll deg,,;" . 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Spe!J""1J""1Y-sun CRII......ING SERVICES "KU.LII"'~CONI>~ Company: Field: Site: Well: Wellllath: Targets BP Amoco Milne Point M pt G Pad Plan Curly G-16 Plan Curly Name Ueseription Uip. )ir. . .. -------------- Curly FIt#1 -Polygon 1 ·Polygon 2 -Plan out by 1486.25 at Curly FIt#2 -Polygon 1 -Polygon 2 -Plan out by 765.56 at Curly Poly -Polygon 1 -Polygon 2 ·Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 -Polygon 7 -Polygon 8 -Polygon 9 -Polygon 10 -Plan out by 1225.80 at Curly T1 Rev. 5 -Plan hit target Curly FIt#3 -Polygon 1 -Polygon 2 Curly T2 Curly FIt#4 -Polygon 1 -Polygon 2 Curly T3 Rev. 3 Curly T4 Rev. 1 Curly T5 e e Sperry-Sun KW A Planning bp --....-------.------ -..-...-----.---..... . - - ---- --------------. --------.-.-. ------.... Date: 11/17/2003 Time: 09:36:45 J'age: 2 Co-ordillate(;'iiE) I~efel'enee: Well: Plan Curly G-16, True North Vertical (TVD) I~eferenee: 0-14 (34.3 + 29.5 GL) 63.8 Seelioll (VS) I~eferellee: Well (0.00N,O.00E,83.00Azi) Survey Caleulalion Method: Minimum Curvature 1)b: Oracle .....,....-----..... ··._..n._... . -----.----. -......- - .. . . -.. --..-- .- ----I 'lap Map <--- Latitllde --> <- Lon¡:itude ---> I TVn Hil/-S +E/-W :\orlhing Eastill¡: ne¡: Mill See Ue¡: M in See : ft ft fl ft ft ------ -- --. -.- . ..------ i 3408.80 1292.68 1758.14 6015732.00 558907.00 70 27 12.890 N 149 31 9.547 W 3408.80 1292.68 1758.14 6015732.00 558907.00 70 27 12.890 N 149 31 9.547 W 3408.80 -36.77 1142.86 6014398.00 558302.00 70 26 59.816 N 149 31 27.625 W 3408.80 -119.64 1295.20 6014316.31 558454.96 70 26 59.001 N 1493123.152W 3843.80 712.47 2166.74 6015155.00 559320.00 70 27 7.182 N 149 3057.550 W 3843.80 712.47 2166.74 6015155.00 559320.00 70 27 7.182 N 149 3057.550 W 3843.80 -262.80 1925.23 6014178.00 559086.00 70 26 57.591 N 149 31 4.651 W 3843.80 -43.76 2047.62 6014397.95 559206.70 70 26 59.745 N 149 31 1.054 W 4339.80 5.03 4298.58 6014464.00 561457.00 70 27 0.216 N 149 29 54.949 W 4339.80 5.03 4298.58 6014464.00 561457.00 70 27 0.216 N 149 29 54.949 W 4339.80 -422.26 5894.50 6014049.00 563056.00 70 26 56.003 N 149 29 8.090 W 4339.80 158.02 6650.05 6014635.00 563807.00 70 27 1.703 N 149 28 45.887 W 4339,80 816.71 6831.12 6015295.00 563983.00 70 27 8.180 N 149 28 40.552 W 4339.80 880.63 6581.58 6015357.00 563733.00 70 27 8.811 N 149 28 47.879 W 4339.80 278.82 6416.95 6014754.00 563573.00 70 27 2.893 N 149 28 52.730 W 4339.80 -17.40 5789.59 6014453.00 562948.00 70 26 59.985 N 149 2911.161 W 4339.80 244.05 4300.41 6014703.00 561457.00 70 27 2.566 N 149 29 54.891 W 4339.80 145.03 2736.46 6014592.00 559894.00 70 27 1.600 N 149 30 40.823 W 4339.80 -122.03 2739.41 6014325.00 559899.00 70 26 58.973 N 149 30 40.739 W 4339.80 59.65 3073.99 6014509.22 560232.15 70 27 0.759 N 149 30 30.911 W 4345.80 63.16 3108.88 6014513.00 560267.00 70 27 0.793 N 149 30 29.887 W 4373.80 275.06 3517.55 6014728.00 560674.00 70 27 2.875 N 149 30 17.882 W 4373.80 275.06 3517.55 6014728.00 560674.00 70 27 2.875 N 149 30 17.882 W 4373.80 -287.78 3487.23 6014165.00 560648.00 70 26 57.340 N 149 30 18.780 W 4418.80 88.81 4460.04 6014549.00 561617.80 70 27 1.039 N 149 29 50.205 W 4418.80 347.54 4499.23 6014808.00 561655.00 70 27 3.583 N 149 29 49.050 W 4418.80 347.54 4499.23 6014808.00 561655.00 70 27 3.583 N 149 29 49.050 W 4418.80 -204.81 4536.00 6014256.00 561696.00 70 26 58.150 N 149 29 47.980 W 4453.80 -170.05 5740.42 6014300.00 562900.00 70 26 58.484 N 149 29 12.609 W 4480.80 276.85 6543.95 6014753.00 563700.00 70 27 2.873 N 149 2849.000 W 4488.80 822.72 6700.15 6015300.00 563852.00 70 27 8.240 N 149 28 44.398 W Plan Section Information 'MD .' Incl 'i::::\Azim TVD . +N/,S:< ,....,..,...., E/W" DLS Build TUi'n" ',' i'\."·TFO . Target """/,',:::+ ..,. . . ... - . ft dèg" ":':d~g ft .,' .ft:.":'>· ft deg/100ft deg/100ft deg/10Oft :.' deg 34.30 0.00 0.00 34.30 0.00 0.00 0.00 0.00 0.00 0.00 250.00 0.00 0.00 250.00 0.00 0.00 0.00 0.00 0.00 0.00 416.67 5.00 60.00 416.46 3.63 6.29 3.00 3.00 0.00 60.00 797.77 14.00 110.00 792.42 -3.85 64.19 3.00 2.36 13.12 69.21 1784.66 14.00 110.00 1750.00 -85.51 288.54 0.00 0.00 0.00 0.00 2434.66 14.00 110.00 2380.69 -139.29 436.31 0.00 0.00 0.00 0.00 3627.83 60.09 84.24 3311.47 -136.61 1126.85 4.00 3.86 -2.16 -30.60 5209.17 60.09 84.24 4099.95 0.91 2490.68 0.00 0.00 0.00 0.00 5231.79 61.00 84.25 4111.07 2.89 2510.28 4.00 4.00 0.04 0.46 5381.79 61.00 84.25 4183.80 16.03 2640.81 0.00 0.00 0.00 0.00 5881.88 81.00 84.25 4345.80 63.16 3108,88 4.00 4.00 0.00 0.00 Curly T1 Rev. 5 5901.88 81.00 84.25 4348.93 65.14 3128.53 0.00 0.00 0.00 0.00 5962.12 87.07 88.20 4355.19 69.07 3188.28 12.00 10.07 6.56 33.15 7039.78 87.07 88.20 4410.29 102.87 4264.00 0.00 0.00 0.00 0.00 7236.86 88.00 100.00 4418.80 88.81 4460.04 6.00 0.47 5.99 85.76 Curly T2 7299.66 88.48 103.74 4420.73 75.90 4521.45 6.00 0.77 5.95 82.69 8235.93 88.48 103.74 4445.51 -146.38 5430.62 0.00 0.00 0.00 0.00 8548.13 88.50 85.00 4453.80 -170.05 5740.42 6.00 0.01 -6.00 -90.20 Curly T3 Rev. 3 8674.03 87.99 76.20 4457.66 -149.51 f,i864.45 7.00 -0.41 -6.99 -93.45 8845.22 87.99 76.20 4463.67 -108.69 8030.60 0.00 0.00 0.00 0.00 spei'i'y-sun e Sperry-Sun e DRU,..L.ING SERVICES bp AIt.U.U...".,TOf(COMI''''''''- KW A Planning ._--"._--,-_.,-----".- Company: BP Amoco Date: 11/1712003 Time: 09:36:45 l'age: J Field: Milne Point Co-ordinatef\E) nderence: Well: Plan Curly G-16. True North Site: MPIGPad Vertical (TVI) I{dercncc: 0-14 ( 34.3 + 29.5 GL ) 63.8 Wcll: Plan Curly G-16 Section (VS) Reference: Well (0.00N,O.00E,83.00Azi) Wcllpath: Plan Curly Survcy Calculation Method: Minimum Curvature Db: Oracle . n. _ ..~.. ..... . .__..._. _.__.. ..,n .. ---,..,,-----, --.--... ... -.. .,.-- .--.- Plan Section Information -,-,." --.".,----,--.---..--,.-,. .,_'.____m ".__.. ... ._0._____--- ]\11> Ine! A1.im TVU +">I-S +E/-W ])LS Build Turn ''''''0 Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg ---. ------..----...-- __n ____ _____u" . ...-- 9505.19 89.20 30.00 4480.80 276.85 6543.95 7.00 0.18 -7.00 -89.18 CurlyT4 Rev. 1 9832.68 89.20 10.35 4485.41 582.72 6656.33 6.00 0.00 -6.00 -90.13 10076.68 89.20 10.35 4488.80 822.72 6700.15 0.00 0.00 0.00 0.00 Curly T5 Survey ._,--, ."...-."". .. MI> Ine! Adm TVD Sys TVI) Map"> :\lapE VS m.s T"'O Tool ft deg deg ft ft ft ft ft deg/100ft deg .. 34.30 0.00 0.00 34.30 -29.50 6014426.00 557159.00 0.00 0.00 0.00 CB-GYRO-SS 100.00 0.00 0.00 100.00 36.20 6014426.00 557159.00 0.00 0.00 0.00 CB-GYRO-SS 200.00 0.00 0.00 200.00 136.20 6014426.00 557159.00 0.00 0.00 0.00 CB-GYRO-SS 250.00 0.00 0.00 250.00 186.20 6014426.00 557159.00 0.00 0.00 0.00 CB-GYRO-SS 300.00 1.50 60.00 299.99 236.19 6014426.33 557159.56 0.60 3.00 0.00 CB-GYRO-SS 400.00 4.50 60.00 399.85 336.05 6014428.98 557164.08 5.42 3.00 0.00 CB-GYRO-SS 416.67 5.00 60.00 416.46 352.66 6014429.68 557165.27 6.69 3.00 0.00 CB-GYRO-SS 500.00 6.33 81.70 499.39 435.59 6014432.22 557172.94 14.63 3.00 69.21 CB-GYRO-SS 600.00 8.64 96.60 598.54 534.74 6014432.25 557185.86 27.45 3.00 47.62 CB-GYRO-SS 700.00 11.28 104.95 697.03 633.23 6014428.99 557202.80 43.83 3.00 32.83 CB-GYRO-SS 797.77 14.00 110.00 792.42 728.62 6014422.64 557223.21 63.24 3.00 24.62 CB-GYRO-SS 800.00 14.00 110.00 794.59 730.79 6014422.46 557223.72 63.72 0.00 0.00 CB-GYRO-SS 900.00 14,00 110.00 891.61 827.81 6014414.36 557246.51 85.28 0.00 0.00 MWD+IFR+MS 1000.00 14.00 110.00 988.64 924.84 6014406.26 557269.30 106.83 0.00 0.00 MWD+IFR+MS 1100.00 14.00 110.00 1085.67 1021.87 6014398.16 557292.10 128.39 0.00 0.00 MWD+IFR+MS 1200.00 14.00 110.00 1182.70 1118.90 6014390.06 557314.89 149.94 0.00 0.00 MWD+IFR+MS 1300.00 14.00 110.00 1279.73 1215.93 6014381.96 557337.69 171.50 0.00 0.00 MWD+IFR+MS 1400.00 14.00 110.00 1376.76 1312.96 6014373.87 557360.48 193.05 0.00 0.00 MWD+IFR+MS 1500.00 14.00 110.00 1473.79 1409.99 6014365.77 557383.27 214.61 0.00 0.00 MWD+IFR+MS 1600.00 14.00 110.00 1570.82 1507.02 6014357.67 557406.07 236.16 0.00 0.00 MWD+IFR+MS 1700.00 14.00 110.00 1667.85 1604.05 6014349.57 557428.86 257.72 0.00 0.00 MWD+IFR+MS 1784.66 14.00 110.00 1750.00 1686.20 6014342.71 557448.16 275.97 0,00 0.00 MWD+IFR+MS 1800.00 14.00 110.00 1764.88 1701.08 6014341.47 557451.66 279.27 0.00 0.00 MWD+IFR+MS 1900.00 14.00 110.00 1861.91 1798.11 6014333.37 557474.45 300.83 0.00 0.00 MWD+IFR+MS 1901.95 14.00 110.00 1863.80 1800.00 6014333.21 557474.89 301.25 0.00 0.00 BPRF 2000.00 14.00 110.00 1958.94 1895.14 6014325.27 557497.24 322.38 0.00 0.00 MWD+IFR+MS 2100.00 14.00 110.00 2055.97 1992.17 6014317.17 557520.04 343.94 0.00 0.00 MWD+IFR+MS 2200.00 14.00 110.00 2153.00 2089.20 6014309.07 557542.83 365.49 0.00 0.00 MWD+IFR+MS 2300.00 14.00 110.00 2250.03 2186.23 6014300.98 557565.62 387.05 0.00 0.00 MWD+IFR+MS 2400.00 14.00 110.00 2347.06 2283.26 6014292.88 557588.42 408.60 0.00 0.00 MWD+IFR+MS 2434.66 14.00 110.00 2380.69 2316.89 6014290.07 557596.32 416.08 0.00 0.00 MWD+IFR+MS 2489.64 15.93 105.92 2433.80 2370.00 6014285.83 557609.86 428.95 4.00 329.40 103/4" 2500.00 16.30 105.26 2443.76 2379.96 6014285.08 557612.63 431.61 4.00 333.34 MWD+IFR+MS 2600.00 19.97 100.12 2538.78 2474.98 6014278.62 557643.05 460.93 4.00 333.98 MWD+IFR+MS 2700.00 23.75 96.53 2631.57 2567.77 6014273.61 557679.91 496.84 4.00 338.86 MWD+IFR+MS 2800.00 27.58 93.89 2721.70 2657.90 6014270.07 557723.05 539.17 4.00 342.19 MWD+IFR+MS 2900.00 31.45 91.86 2808.71 2744.91 6014268.03 557772.26 587.70 4.00 344.57 MWD+IFR+MS 3000.00 35.35 90.22 2892.17 2828.37 6014267.50 557827.28 642.19 4.00 346.35 MWD+IFR+MS 3100.00 39.27 88.88 2971.70 2907.90 6014268.47 557887.86 702.40 4.00 347.71 MWD+IFR+MS 3200.00 43.20 87.74 3046.89 2983.09 6014270.94 557953.71 768.01 4.00 348.78 MWD+IFR+MS 3300.00 47.13 86.76 3117.39 3053.59 6014274.90 558024.49 838.72 4.00 349.63 MWD+IFR+MS 3400.00 51.08 85.90 3182.84 3119.04 6014280.33 558099.86 914.17 4.00 350.33 MWD+IFR+MS 3500.00 55.03 85.13 3242.93 3179.13 6014287.21 558179.46 994.00 4.00 350.89 MWD+IFR+MS 3600.00 58.99 84.43 3297.36 3233.56 6014295.49 558262.91 1077.82 4.00 351.36 MWD+IFR+MS 3627.83 60.09 84.24 3311.47 3247.67 6014298.04 558286.76 1101.80 4.00 351.74 MWD+IFR+MS 3700.00 60.09 84.24 3347.46 3283.6t? 6014304.80 558348.94 1164.34 0.00 180.00 MWD+IFR+MS spe........y-sun e Sperry-Sun e DRILLING seRVices þp "mwa1lltTON C,OMP~ KW A Planning Company: BP Amoco Datc: 11/17/2003 Tillie: 09:36:45 I'age: 4 Field: Milne Point Co-ordlnate(:\E) I~efcrcnce: Well: Plan Curly G-16, True North Site: M pt G Pad Vertical (TV) Hderenee: 0-14 ( 34.3 + 29.5 GL ) 63.8 Well: Plan Curly G-16 Sectlou (VS) I~efereuce: Well (0.00N,0.00E,83.00Azi) Wellpath: Plan Curly Survey Calculation Method: Minimum Curvature Db: Oracle Survey 1\11) IlIcl A1.im TVD Sys TVD Map:\ MapE VS m,s 1'1'0 Tool ft deg deg ft ft ft ft ft deg/100ft deg ------.--.--. ...-..- .------.. ------------.--- ------------- - - 3800.00 60.09 84.24 3397.32 3333.52 6014314.16 558435.11 1251.01 0.00 180.00 MWD+IFR+MS 3823.03 60.09 84.24 3408.80 3345.00 6014316.31 558454.96 1270.97 0.00 180.00 Curly FIt#1 3900.00 60.09 84.24 3447.18 3383.38 6014323.51 558521.28 1337.67 0.00 180.00 MWD+IFR+MS 4000.00 60.09 84.24 3497.04 3433.24 6014332.87 558607.45 1424.33 0.00 180.00 MWD+IFR+MS 4100.00 60.09 84.24 3546.90 3483.10 6014342.23 558693.61 1510.99 0.00 180.00 MWD+IFR+MS 4153.95 60.09 84.24 3573.80 3510.00 6014347.28 558740.10 1557.75 0.00 180.00 TUZC 4200.00 60.09 84.24 3596.76 3532.96 6014351.58 558779.78 1597.66 0.00 180.00 MWD+IFR+MS 4300.00 60.09 84.24 3646.62 3582.82 6014360.94 558865.95 1684.32 0.00 180.00 MWD+IFR+MS 4400.00 60.09 84.24 3696.48 3632.68 6014370.30 558952.12 1770.98 0.00 180.00 MWD+IFR+MS 4500.00 60.09 84.24 3746.35 3682.55 6014379.66 559038.28 1857.64 0.00 180.00 MWD+IFR+MS 4600.00 60.09 84.24 3796.21 3732.41 6014389.01 559124.45 1944.30 0.00 180.00 MWD+IFR+MS 4671.38 60.09 84.24 3831.80 3768.00 6014395.69 559185.96 2006.17 0.00 180.00 Ugnu-MA 4695.45 60.09 84.24 3843.80 3780.00 6014397.95 559206.70 2027.02 0.00 180.00 Curly FIt#2 4700.00 60.09 84.24 3846.07 3782.27 6014398.37 559210.62 2030.97 0.00 180.00 MWD+IFR+MS 4701.47 60.09 84.24 3846.80 3783.00 6014398.51 559211.88 2032.24 0.00 180.00 Ugnu-MB1 4800.00 60.09 84.24 3895.93 3832.13 6014407.73 559296.79 2117.63 0.00 180.00 MWD+IFR+MS 4825.81 60.09 84.24 3908.80 3845.00 6014410.14 559319.03 2140.00 0.00 180.00 Ugnu-MB2 4900.00 60.09 84.24 3945.79 3881.99 6014417.09 559382.95 2204.29 0.00 180.00 MWD+IFR+MS 5000.00 60.09 84.24 3995.65 3931.85 6014426.44 559469.12 2290.95 0.00 180.00 MWD+IFR+MS 5100.00 60.09 84.24 4045.51 3981.71 6014435.80 559555.29 2377.61 0.00 180.00 MWD+IFR+MS 5116.62 60.09 84.24 4053.80 3990.00 6014437.36 559569.61 2392.02 0.00 180.00 Ugnu-MC 5176.79 60.09 84.24 4083.80 4020.00 6014442.99 559621.46 2444.16 0.00 180.00 SBF2-NA 5209.17 60.09 84.24 4099.95 4036.15 6014446.02 559649.36 2472.22 0.00 180.00 MWD+IFR+MS 5231.79 61.00 84.25 4111.07 4047.27 6014448.14 559668.94 2491.92 4.00 0.46 MWD+IFR+MS 5258.04 61.00 84.25 4123.80 4060.00 6014450.62 559691.76 2514.87 0.00 0.00 SBF1-NB 5300.00 61.00 84.25 4144.14 4080.34 6014454.57 559728.24 2551.56 0.00 0.00 MWD+IFR+MS 5319.92 61.00 84.25 4153.80 4090.00 6014456.45 559745.56 2568.97 0.00 0.00 SBE4-NC 5381.79 61.00 84.25 4183.80 4120.00 6014462.28 559799.35 2623.07 0.00 0.00 SBE2-NE 5400.00 61.72 84.25 4192.53 4128.73 6014464.01 559815.24 2639.05 4.00 0.00 MWD+IFR+MS 5500.00 65.72 84.25 4236.79 4172.99 6014473.67 559904.36 2728.68 4.00 0.00 MWD+IFR+MS 5504.92 65.92 84.25 4238.80 4175.00 6014474.15 559908.81 2733.16 4.00 0.00 SBE1-NF 5600.00 69.72 84.25 4274.68 4210.88 6014483.65 559996.33 2821.18 4.00 360.00 MWD+IFR+MS 5627.00 70.80 84.25 4283.80 4220.00 6014486.38 560021.59 2846.58 4.00 0.00 TSBD-Top OA 5700.00 73.72 84.25 4306.04 4242.24 6014493.88 560090.70 2916.09 4.00 360.00 MWD+IFR+MS 5769.13 76.49 84.25 4323.80 4260.00 6014501.08 560157.10 2982.87 4.00 0.00 TSBC-Base OA 5800.00 77.72 84.25 4330.69 4266.89 6014504.33 560187.02 3012.96 4.00 360.00 MWD+IFR+MS 5846.31 79.58 84.25 4339.80 4276.00 6014509.22 560232.15 3058.35 4.00 0.00 Curly Poly 5881.88 81.00 84.25 4345.80 4282.00 6014513.00 560267.00 3093.40 4.00 360.00 Curly T1 Rev. 5 5901.88 81.00 84.25 4348.93 4285.13 6014515.13 560286.64 3113.15 0.00 0.00 MWD+IFR+MS 5925.00 83.33 85.78 4352.08 4288.28 6014517.29 560309.44 3136.04 12.00 33.15 MWD+IFR+MS 5950.00 85.85 87.41 4354.44 4290.64 6014518.96 560334.27 3160.88 12.00 32.94 MWD+IFR+MS 5962.12 87.07 88.20 4355.19 4291.39 6014519.52 560346.35 3172.93 12.00 32.79 MWD+IFR+MS 6000.00 87.07 88.20 4357.13 4293.33 6014520.99 560384.15 3210.60 0.00 0.00 MWD+IFR+MS 6100.00 87.07 88.20 4362.24 4298.44 6014524.90 560483.93 3310.06 0.00 0.00 MWD+IFR+MS 6200.00 87.07 88.20 4367.35 4303.55 6014528.80 560583.71 3409.52 0.00 0.00 MWD+IFR+MS 6300.00 87.07 88.20 4372.47 4308.67 6014532.70 560683.50 3508.98 0.00 0.00 MWD+IFR+MS 6326.10 87.07 88.20 4373.80 4310.00 6014533.72 560709.53 3534.93 0.00 0.00 SBA5-Base OB 6400.00 87.07 88.20 4377.58 4313.78 6014536.60 560783.28 3608.44 0.00 0.00 MWD+IFR+MS 6500.00 87.07 88.20 4382.69 4318.89 6014540.50 560883.06 3707.89 0.00 0.00 MWD+IFR+MS 6600.00 87.07 88.20 4387.81 4324.01 6014544.40 560982.85 3807.35 0.00 0.00 MWD+IFR+MS 6700.00 87.07 88.20 4392.92 4329.12 6014548.30 561082.63 3906.81 0.00 0.00 MWD+IFR+MS 6800.00 87.07 88.20 4398.03 4334.23 6014552.20 561182.41 4006.27 0.00 0.00 MWD+IFR+MS 6900.00 87.07 88.20 4403.14 43~9.34 6014556.10 561282.20 4105.73 0.00 0.00 MWD+IFR+MS Spe!l""'l""'y-sun e Sperry-Sun e DRIL.L.IIIIG seRVices bp AHAILI81Ilt1'OM«IMPAH\' KW A Planning Company: BP Amoco Uatc: 11/1712003 Tilllc: 09:36:45 I'agc: 5 Hcld: Milne Point Co-ordinateC\E) Rcfcl'cncc: Well: Plan Curly G-16, True North Sitc: M Pt G Pad "crtical (I'VD) I~cfcrcncc: 0-14 ( 34.3 + 29.5 GL ) 63.8 Wcll: Plan Curly G-16 Scction <VS) Refercncc: Well (0.00N,0.00E,83.00Azi) Wcllpath: Plan Curly Survcy Calculation Mcthod: Minimum Curvature Ub: Oracle SUl'\lcy --------.--- ..--- .. -.------.-. - 1\1D Ine! Azlm TVD Sys TVD MapN MnpE \'S m.s U'O Tool ft deg deg ft ft ft ft ft degf100ft deg .- . . ------ . .... --.-.----.-..- -. .---- _ __ n __on 7000.00 87.07 88.20 4408.26 4344.46 6014560.00 561381.98 4205.18 0.00 0.00 MWD+IFR+MS 7039.78 87.07 88.20 4410.29 4346.49 6014561.56 561421.67 4244.75 0.00 0.00 MWD+IFR+MS 7050.00 87.11 88.81 4410.81 4347.01 6014561.90 561431.87 4254.91 6.00 85.76 MWD+IFR+MS 7100.00 87.34 91.81 4413.23 4349.43 6014562.01 561481.80 4304.44 6.00 85.72 MWD+IFR+MS 7150.00 87.58 94.80 4415.45 4351.65 6014559.52 561531.68 4353.58 6.00 85.58 MWD+IFR+MS 7200.00 87.82 97.79 4417.45 4353.65 6014554.42 561581.37 4402.19 6.00 85.45 MWD+IFR+MS 7236.86 88.00 100.00 4418.80 4355.00 6014549.00 561617.80 4437.62 6.00 85.33 Curly T2 7250.00 88.10 100.78 4419.25 4355.45 6014546.73 561630.73 4450.15 6.00 82.69 MWD+IFR+MS 7299.66 88.48 103.74 4420.73 4356.93 6014536.56 561679.30 4497.00 6.00 82.66 MWD+IFR+MS 7400.00 88.48 103.74 4423.38 4359.58 6014513.49 561776.91 4590.81 0.00 180.00 MWD+IFR+MS 7500.00 88.48 103.74 4426.03 4362.23 6014490.50 561874.19 4684.30 0.00 180.00 MWD+IFR+MS 7600.00 88.48 103.74 4428.68 4364.88 6014467.51 561971.46 4777.78 0.00 180.00 MWD+IFR+MS 7700.00 88.48 103.74 4431.32 4367.52 6014444.51 562068.74 4871.27 0.00 180.00 MWD+IFR+MS 7800.00 88.48 103.74 4433.97 4370.17 6014421.52 562166.01 4964.76 0.00 180.00 MWD+IFR+MS 7900.00 88.48 103.74 4436.62 4372.82 6014398.53 562263.29 5058.25 0.00 180.00 MWD+IFR+MS 8000,00 88.48 103.74 4439.26 4375.46 6014375.54 562360.56 5151.73 0.00 180.00 MWD+IFR+MS 8100.00 88.48 103.74 4441.91 4378.11 6014352.54 562457.84 5245.22 0.00 180.00 MWD+IFR+MS 8200.00 88.48 103.74 4444.56 4380.76 6014329.55 562555.11 5338.71 0.00 180.00 MWD+IFR+MS 8235.93 88.48 103.74 4445.51 4381.71 6014321.29 562590.06 5372.30 0.00 180.00 MWD+IFR+MS 8250.00 88.48 102.89 4445.88 4382.08 6014318.16 562603.77 5385.49 6.00 269.80 MWD+IFR+MS 8300.00 88.47 99.89 4447.21 4383.41 6014308.66 562652.83 5432.91 6.00 269.82 MWD+IFR+MS 8350.00 88.47 96.89 4448.54 4384.74 6014301.75 562702.33 5481.10 6.00 269.90 MWD+IFR+MS 8400.00 88.47 93.89 4449.88 4386.08 6014297.43 562752.11 5529.91 6.00 269.98 MWD+IFR+MS 8450.00 88.48 90.89 4451.21 4387.41 6014295.73 562802.05 5579.22 6.00 270.06 MWD+IFR+MS 8500.00 88.49 87.89 4452.53 4388.73 6014296.65 562852.02 5628.88 6.00 270.14 MWD+IFR+MS 8548.13 88.50 85.00 4453.80 4390.00 6014300.00 562900.00 5676.90 6.00 270.22 Curly T3 Rev. 3 8550.00 88.49 84.87 4453.85 4390.05 6014300.18 562901.86 5678.77 7.00 266.55 MWD+IFR+MS 8600.00 88.28 81.37 4455.26 4391.46 6014306.54 562951.42 5728.74 7.00 266.55 MWD+IFR+MS 8650.00 88.08 77.88 4456.84 4393.04 6014315.92 563000.50 5778.63 7.00 266.65 MWD+IFR+MS 8674.03 87.99 76.20 4457.66 4393.86 6014321.48 563023.86 5802.51 7.00 266.76 MWD+IFR+MS 8700.00 87.99 76.20 4458.58 4394.78 6014327.87 563049.01 5828.28 0.00 0.00 MWD+IFR+MS 8800.00 87.99 76.20 4462.09 4398.29 6014352.45 563145.87 5927.52 0.00 0.00 MWD+IFR+MS 8845.22 87.99 76.20 4463.67 4399.87 6014363.57 563189.67 5972.39 0.00 0.00 MWD+IFR+MS 8850.00 87.99 75.86 4463.84 4400.04 6014364.76 563194.30 5977.13 7.00 270.82 MWD+IFR+MS 8900.00 88.05 72.36 4465.57 4401.77 6014378.80 563242.24 6026.49 7.00 270.83 MWD+IFR+MS 8950.00 88.11 68.86 4467.24 4403.44 6014395.75 563289.24 6075.30 7.00 270.95 MWD+IFR+MS 9000.00 88.18 65.36 4468.86 4405.06 6014415.53 563335.11 6123.35 7.00 271.07 MWD+IFR+MS 9050.00 88.25 61.86 4470.42 4406.62 6014438.09 563379.70 6170.49 7.00 271.18 MWD+IFR+MS 9100.00 88.34 58.36 4471.91 4408.11 6014463.32 563422.82 6216.52 7.00 271.29 MWD+IFR+MS 9150.00 88.43 54.86 4473.32 4409.52 6014491.14 563464.33 6261.28 7.00 271.40 MWD+IFR+MS 9200.00 88.52 51.36 4474.66 4410.86 6014521.44 563504.06 6304.61 7.00 271.50 MWD+IFR+MS 9250.00 88.62 47.86 4475.90 4412.10 6014554.12 563541.87 6346.34 7.00 271.59 MWD+IFR+MS 9300.00 88.72 44.36 4477.06 4413.26 6014589.04 563577.62 6386.31 7.00 271.68 MWD+IFR+MS 9350.00 88.83 40.86 4478.13 4414.33 6014626.08 563611.17 6424.37 7.00 271.76 MWD+IFR+MS 9400.00 88.95 37.36 4479.10 4415.30 6014665.10 563642.39 6460.40 7.00 271.83 MWD+IFR+MS 9450.00 89.07 33,86 4479.96 4416.16 6014705.96 563671.18 6494.24 7.00 271.90 MWD+IFR+MS 9500.00 89.19 30.36 4480.73 4416.93 6014748.49 563697.43 6525.77 7.00 271.96 MWD+IFR+MS 9505.19 89.20 30.00 4480.80 4417.00 6014753.00 563700.00 6528.90 7.00 272.01 Curly T4 Rev. 1 9550.00 89.19 27.31 4481.43 4417.63 6014792.47 563721.18 6555.02 6.00 269.87 MWD+IFR+MS 9600.00 89.19 24.31 4482.13 4418.33 6014837.64 563742.60 6582.11 6.00 269.91 MWD+IFR+MS 9650.00 89.19 21.31 4482.84 4419.04 6014883.86 563761.62 6606.96 6.00 269.95 MWD+IFR+MS 9700.00 89.19 18.31 4483.55: 4419.75 6014931.01 563778.20 6629.51 6.00 269.99 MWD+IFR+MS spel""'l""'y-sun CRI\..\..ING SeRVices A ßU.UØlIImJtõ «MI'~ e Sperry-Sun KW A Planning e bp ____.o..___..__n_ ._._ .__.. _ Company: Field: Site: Well: Wellpath: Survey BP Amoco Milne Point M Pt G Pad Plan Curly G-16 Plan Curly Date: 11/17/2003 Time: 09:36:45 I'age: 6 Cu-urdinateC\E) Refel'elll:e: Well: Plan Curly G-16, True Norlh Vertical (TVI» Reference: 0-14 ( 34.3 + 29.5 GL) 63.8 Section (VS) Reference: Well (0.00N,0.00E,83.00Azi) SUI'ny Calculation Method: Minimum Curvature 1>11: Oracle ., ..--.... .. __ _ __. ___._n.n. _ n... ...,._._ _n__ _____________._.______.._.. .. .-----.--- .__ _ __.n. . .--..-. M1) Ine! /\:r.im 1'\'1> Sys TVI) MapS MllpJo: VS nLS 1'...0 Tool ft deg deg ft ft ft ft ft deg/100ft deg -.. .. _n..______.. _ __n . .- . n... .--------- ....-- .----- 9750.00 89.19 15.31 4484.25 4420.45 6014978.97 563792.29 6649.69 6.00 270.04 MWD+IFR+MS 9800.00 89.20 12.31 4484.95 4421.15 6015027.60 563803.85 6667.45 6.00 270.08 MWD+IFR+MS 9832.68 89.20 10.35 4485.41 4421.61 6015059.69 563810.02 6677.73 6.00 270.12 MWD+IFR+MS 9900.00 89.20 10.35 4486.34 4422.54 6015125.99 563821.60 6697.80 0.00 0.00 MWD+IFR+MS 10000.00 89.20 10.35 4487.73 4423.93 6015224.48 563838.81 6727.61 0.00 0.00 MWD+IFR+MS 10076.68 89.20 10.35 4488.80 4425.00 6015300.00 563852.00 6750.47 0.00 0.00 Curly T5 /.-------~" e e p055168 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS 10/6/2003 INV# PR100103H PERMIT TO DRILL =EE I l'YP(~ -l ~ ç,-(Y)~ L(øL1 THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL .. NATIONAL CITY BANK Ashland, Ohio BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGe:, AK99519-6612 PAY: TO THE ORDER OF: DATE I I CHECK NO. 10/6/2003 055168 VENDOR DISCOUNT NET H RECEIVED DEC - 3 2003 Alaska Jil & Gas Cons. Commission Anchorage 56-389 412 No. p 055168 CONSOLIDATED COMMERCIAL ACCOUNT AMOUNT OCtøber6,2003 **;!2t;$iÖO.00*******! NQ'f>,ALI~AFrEÂY'C\ ~~y~. '" .. . .C' ':', jk'].;;\":%.~¡;;;f.'~~::.;:~!.~~:;!..~~~;~;1 ,...". ...... ....r?:.~:....¡..... \...,."1..... ...... '..... ..... <.:.... ::'.- ::-.', .:.... :··"·:"'f··\~··fl-'¡;~';:;"':·';"··'.ß :.::;' 1180 5 5 ¡. b 8118 I: 0... ¡. 20 :I 8 q 51: 0 ¡. 2 78 q b 118 e e TRANSMJT AL LETTER CHECKLIST CIRCLE APPROPRIATE LETTERIP ARA GRAPH S TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /ÎÎ ¡::;; d-' ~ -/þ PTD# '2-tJ 3 - 2/() CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API num ber last two (2) digits are between 60-69) "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. HOLE In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API Dum ber (50 70/80) from records, data and logs acquired for well (name on permit). P~OT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to tbe spacing exception that may occur. All dry ditcb sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from wbere samples are first caught and 10' sample intervals through target zones. Field & Pool MILNE POINT, SCHRADER BLFF OIL - 525140 Well Name: MILNE PT UNIT SB G-16 ~Program DEV Well bore seg D PTD#: 20321 00 Company BP EXPLORATION (ALASKA) INC Initial ClasslType DEV / PEND GeoArea 890 Unit 11328 On/Off Shore On Annular Disposal D Administration 1 P~(mit fe~ attached ~ - - - - - - - - - - - - - - - - - - - - ~ ~ ~ ~ ~ Y~s ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 2 ~Leas~ numb~r aPRropriat~ ~ ~ ~ - - - - - - - - - - - - - - - - - - - Np~ ~ CQrœçt~d: Surfa~ an~:\JQP~ prQd iotelYaj1l ~OL Q259Q6; TD inAQL~ 025518 ~ ~ ~ ~ - - - - 3 ~UniJu~ well~n~a(Tl~ ~aod rwmb~( ~ ~ _ _ ~ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ - - - - - - - - Y~s __ - - . ~ - - - - - - - - - - - - - - - . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 4 WeJI Jocat~d in ~a~ d~tined pOQI _ _ ~ - - - - - - - - - - Y~s _ ~ CQnservC!tioo Ord~( NQ. An: _Sch(ader~BJu~ff~QiU'ool ~ ~ ~ ~ ~ - - - - 5 WeJI Jocat~d prop~r distaoce_ from driJliog unitbpundal)' _ _ ~ Y~$ - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 6 WeJI Jo~cat~d prop~r distaoce_ from Qther wells_ _ _ _ _ - - - - - - - - - - - ~ ~ ~ ~ - Y~s ~ CQnj¡ervC!tioo Ord~( NQ. An: _No_minaJ 1Q-acr~ drUling ulJits~noJ1Jioi(Tlumw~ell s~pa(ationdi&tanJ:e._ ~ ~ ~ _ ~ 7 ~ufflcielJt acreC!9-e _ayC!ilable in _drilJilJ9- unit _ _ ~ ~ ~ ~ _ _ _ _ - - - - - - ~ ~ - ~ ~ - ~ ~ Y~s _ _ Nearby~Mf'U G-ßproducer is being abandQn~d._SFD ~ ~ _ _ _ ~ ~ ~ _ _ _ ~ ~ ~ ~ _ _ _ 8 J(d~viated, iSJ,yeJlbore plaUncJuded ~ ~ _ ~ _ _ _ ~ ~ ~ ~ _ _ ~ - - - - - - Y~s - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - 9 Operator onJy C!ff~cfed party ~ _ _ _ - - - - - - - - - - - - -- Y~s _ _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 10 Operator has_appropriate_b90d in JQrce_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - Y~$ __ - - - - - - - - - - - - - - - - - - . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - .- 11 P~(mitcao be IS$u_ed witho_ut conservation order ~ _ _ _ _ _ ~ - - - - - - - Y~$ - ~ - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - ~ ~ - - - - - - - - -- Appr Date 12 P~(mitcao be issu~ed witho_ut C!dmini&tr_ative~approvaJ _ ~ ~ ~ _ _ _ - ~ - - ~ ~ ~ - Y~s ~ ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - SFD 12/9/2003 13 Can permit be approved before 15-day wait Yes 14 WeJI Jocat~d within area and_strata authorized byJojectioo O(d~(fl (putlO# in_com(Tl~ot$Ufor NA _ - - - - - - - - - - - ~ - - - - ~ - - - - - ~ - - - - - - - - - - - - - - - - - - - - ~ - - - - - ~ - - - - .. 15 All wells_within V4J1JìI~_are_a_of(eyiew id~otified (FO($.erviCßw~1J onl~>- _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ - - - - - - - - - - - - - - - - - - - -. - - - - - - - - - - - - - - - - - - - - - - - - -. - - - - - - - - - - - - - - - -- 16 Pre_-produçed iojeGtor; dur¡¡tio_n _of pre-p(oduGtiolJ I~$s_ than:1 months (for ~selYiçe weit Qnly) ~ NA_ - - - - - - - ~ - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - 17 ACMPFJndingof CQn$i$t~ocyha$ been Jssued_ forJbis proieGt_ ~ ~ ~ _ _ _ _ - - - - - - - NA Well will be drilled from exjstiog driJI $ite.. _ _ ~ ~ - - - - - ~ - - - - - - - - ~ - - - - - Engineering 18 _Cooduçtp( &t(ingprovided _ ~ _ - - - - ~ ~ - - - - ~ ~ ~ ~ ~ - - ~ ~ - - - - - ~ ~ ~ - ~ - - ~ ~ ~ ~ Y~s ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 19 ~urfC!Cß ~ca&ingprQtects_ all known USQWs ~ - - - - - - - ~ NA AIt aquifer~ex~mpt~d, AOCFRJ <47.1 Q2{b)(3) ~ ~ - - - - - ~ - - - - - - - - - - - - ~ - - - - - 20 ÇMTvpla_dequateJo Circulate on ~condJJctoc& su~rfcsg _ _ _ - - - - - ~ Y~$ __ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - 21 _CMT vol a~d~quateJo tie-iIl Jong striog to surf CS-9_ _ - - - - - - - - - - - ~ _ ~ ~ _ _ _Np~ - - - - - ~ - - - - - - - - - - - - - - - - ~ ~ - - - - - ~ - - - - - - - - ~ - - - - - - ,22 ÇMJ~will Goyer all !l.nownprod\,lGtiye borizQns_ ~ ~ ~ _ _ _ _ - - - - - - - - - - - - - - No_ _ Slotted JioerpJaOlJed ~ - - - - - - - - - - ~ - - - - - - - - - - - - - - - 23 ~Ca$iog desi90& ad~quate. fo( C, T~ B ~&~p~ermaJrp$t _ _ ~ ~ ~ ~ _ _ _ ~ - - - - - ~ ~ ~ ~ Y~$ - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - ~ - - - - - ~ - 24 Adequ¡¡t~JC!nJ<age~orreserve pit _ ~ _ ~ ~ ~ ~ _ _ _ ~ ~ ~ ~ _ _ _ ~ ~ ~ _ _ _ ~ Y~$ Rig ieequippe~d-'^lith $t~e'-pits. No r~$eJ\le~pitplaOlJed, All waste to~CJass ]I w~IJ($), _ ~ - - - - 25 Jta_re-d(ÎlI~ hC!s_a_ 10-4~03 for abandonment beeo approved ~ _ ~ ~ ~ ~ ~ _ _ _ _ ~ ~~~~_NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 26 Adequat~-,^~e!lbore_&eparationpropO$.ed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~$ _ _ prOximity_analysis pe.rfp(me.d, Closest welU$ abaIldQn~d MPG:0_6_5~ C!way at&urface, _DireGtiC;>lJaJ (Tlitigatipo 27 Ifdiver1er re.quire.d. do_es jt m_eet reguJations_ _ - - - - - - - - - - - ~ ~ Y~$ ~ ~ ~ mea_sur~s a,,-ailab!e~ _ _ ~ ~ ~ _ _ _ ~ _ _ _ _ _ ~ ~ ~ ~ _ _ _ - - - - - - Appr Date 28 DrilJiog f!uidpJQgram $chematic_& equip Ji$tadequ¡¡t~ _ _ ~ ~ ~ _ _ _ ~ ~ _ _ _ ~ ~ ~ ~ ~ _ ~ _ _ ~ ~ Yes _ Expected BH~ 7.7 EMW. j'lanIled mud weight 9.'1 ppg. _ _ ~ ~ ~ ~ _ _ _ _ TEM 12/5/2003 29 _BOPEs,dp _they m~eetreguJation _ _ ~ ~ - - - - - - - Y~$ - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - ~ . 30 BOPE _press ratiog C!pp(op(iate; test tp(put psig in ~commelJts) _ _ _ ~ - - - - - - - - - - - - - Y~$ ~ CC!lcuJatedMASP_ 15<45 psi. 35~OO psiapprORriate, - - - - - - 31 ÇhokemanlfQld compJies w/.t\PLR~-53~ (May 84>- _ _ _ _ ~ ~ _ _ _ ~ ~ ~ ~ ~ _ _ ~ _ ~ ~ ~ _ _ . ~ ~ _ Y~$ ~ - - - - - ~ - - - - - - ~ - - - -- 32 Work will OGC\.Ir_ withc;>ut ~operation sbutdown ~ ~ ~ ~ _ _ _ ~ ~ ~ ~ ~ - - . - ~ ~ - - - - ~ ~ ~ ~ Y~s ~ - - - - - - - - - - - - - - - - - - - - - - - 33 JS_Rres_eoceoJ H2S 9C!s~Rrob_able ~ - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - ~ ~ ~ _ Np ~ Rig iseJuippe_dwJth sensors aod C!lar(Tl~k _ ~ - - - - - - - - 34 MechanlcaLcC;>lJdJtioo c;>t weJls withjn AOR y~rified (For_s~rvice w~1J only) ~ ~ ~ _ _ _ ~ ~ ~ _ _ _ ~ NA _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Geology 35 P~(mit c_ao be iS$u~ed wlo hydrpgen s~ulfid~ meC!suœs _ _ ~ - - - - - - - - - - - - - Y~$ - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 36 Data_preseoted Qn_ pote~ntial ovefRressur~ _zones - - - - - - - - - - - - ~ - ~ ~ - - Y~s ~ Expected r~ser\loir p(e$sur~ is 7IPP9 EMW; willÞ~ drilled with 9.1 ppg m\,ld_. Appr Date 37 ~~ismic~analysis of shaJlow gas_zolJe.s ~ ~ _ _ _ ~ ~ ~ _ _ _ ~ NA - - - - - - -- SFD 12/9/2003 38 ~S~abedconditiolJ survey !if Qff-sho(e) _ _ ~ ~ NA - - - - - - - - - - 39 Co~ntaçt na(Tl~/phon_eJor weekl~ progres~s Jeport$ le~RIQratory ~ooly] ~ ~ ~ ~ ~ ~ _ _ ~ ~ ~ NA_ Geologic Date: Engineering Pobl;, 5fJ 1 Commissioner: 1~\'2r 3 Commissioner: Date Commissioner Oat ~t5 I¿ ¡Z- e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infomlation, information 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. Sperry-Sun Dr~ng Servic~s LIS sca~ility d03-~'O . $Revision: 3 $ LisLib $Revision: 4 $ Mon Mar 01 14:43:50 2004 -- J J &(~ s Reel Header Service name............ .LISTPE Date.................... .04/03/01 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.................... .04/03/01 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 MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPG-16 500292318900 B.P.Exploration (Alaska) Inc. Sperry-Sun Drilling Services 01-MAR-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002878275 T. MCGUIRE E _ VAUGHN MWD RUN 2 MW0002878275 T. MCGUIRE E. VAUGHN MAD RUN 2 MW0002878275 T. MCGUIRE E _ VAUGHN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 MW0002878275 T. MCGUIRE E. VAUGHN MWD RUN 4 MW0002878275 R. FRENCH E. VAUGHN MWD RUN 5 MW0002878275 C.A. DEMOSKI C. DIXON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 27 l3N 10E 1990 3443 RECEI\/ED MSL 0) 62.90 29.20 \ i~~ r","\: .'" c~ ¡ ) # WELL CASING RECORD OPEN HOLE CASING DRILLERS ~\8DMS RD MAR 3 0 2~D4 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING BIT S. (IN) 13.500 9.875 6.125 SIZE (IN) 20.000 10.750 7.625 DEPTH (FT) 112.0 2526.0 6260.0 . # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 4. MWD RUNS 2 - 5 COMPRISED DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RUNS 3 - 5 ALSO INCLUDED AT-BIT INCLINATION (ABI). 5. A MAD PASS WAS PERFORMED AFTER REACHING TD OF RUN 2. THE INTERVALS PRESENTED ARE 4970'MD/3969'TVD TO 4670'MD/3812'TVD AND 4370'MD/3665'TVD TO 4170'MD/3569'TVD. THESE INTERVALS DO NOT COINCIDE WITH THOSE OF THE DRILLERS (5044'MD - 4175'MD, BIT DEPTHS) DUE TO DATA EDITING NECESSITATED BY EXCESSIVE SRATS OVER PARTS OF THE OVERALL MAD INTERVAL. 6. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM K. COONEY (SIS/BP), DATED 2/24/04, QUOTING AUTHORIZATION FROM MIKIE SMITH (BP GEOLOGIST). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1 - 5 REPRESENT WELL MPG-16 WITH API#: 50-029-23189-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9561'MD/4453'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SRAT SMOOTHED TOOL SPEED WHEN NOT DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS. RESISTIVITY (EXTRA RESISTIVITY (SHALLOW RESISTIVITY (MEDIUM RESISTIVITY (DEEP AN 'M' SUFFIX ON CURVE MNEMONICS DENOTES MAD PASS DATA. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/01 Maximum Physical Record. .65535 File Type............... I Previous File Name....... SLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP RPM RPX RPS FET RPD $ 1 . and clipped curveSj all bit runs merged. .5000 START DEPTH 62.0 114.5 2510.0 2510.0 2510.0 2510.0 2510.0 STOP DEPTH 9506.5 9560.5 9513.5 9513.5 9513.5 9513.5 9513.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ # REMARKS: BIT RUN NO 1 2 3 4 5 MERGED MAIN PASS. $ MERGE TOP 62.0 2534.0 6267.0 7051.0 7548.0 MERGE BASE 2534.0 6267.0 7051. 0 7548.0 9560.5 # 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 62 9560.5 4811.25 18998 62 9560.5 ROP MWD FT/H 0.51 31693.5 300.508 18893 114.5 9560.5 GR MWD API 14.15 137.51 70.2046 18890 62 9506.5 RPX RPS RPM RPD FET 0.. 0.67 0.06 0.1 0.0547 10.6094 13.8519 15.7512 19.5414 0.840556 2000 2000 2000 2000 45.4094 MWD MWD MWD MWD MWD OHMM OHMM OHMM OHMM HOUR First Reading For Entire File......... .62 Last Reading For Entire File.......... .9560.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/01 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...... .04/03/01 Maximum Physical Record. .65535 File Type... ............ .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MAD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE SGRC SEMP SEDP SESP SEXP SFXE SRAT $ 2 14008 14008 14008 14008 14008 . 2510 2510 2510 2510 2510 9513.5 9513.5 9513.5 9513.5 9513.5 and clipped curves; all MAD runs merged using earliest passes. .5000 START DEPTH 4162.5 4171.5 4171.5 4171.5 4171.5 4171.5 4216.0 STOP DEPTH 4990.5 5002.0 5002.0 5002.0 5002.0 5002.0 5042.0 # MERGED DATA SOURCE PBU TOOL CODE MWD $ MAD RUN NO. MAD PASS NO. MERGE TOP 2 1 2488.5 # REMARKS: MERGED MAD 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 MERGE BASE 6267.0 Depth Units............ .4IIÞ...... 4IIÞ Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4162.5 5042 4602.25 1760 4162.5 5042 RAT MAD FT/H 0.5 477.28 345.531 1152 4216 5042 GR MAD API 23.91 109.49 54.5236 1159 4162.5 4990.5 RPX MAD OHMM 3.08 55.43 17.5679 1185 4171.5 5002 RPS MAD OHMM 3.09 94.43 22.7207 1185 4171.5 5002 RPM MAD OHMM 3.27 170.41 28.0416 1185 4171.5 5002 RPD MAD OHMM 3.95 251.94 34.8927 1185 4171.5 5002 FET MAD HOUR 20.71 28.18 24.5608 1185 4171.5 5002 First Reading For Entire File......... .4162.5 Last Reading For Entire File.......... .5042 File Trailer Service name............ .STSLIB.002 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .04/03/01 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.... ...04/03/01 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 GR ROP $ 3 header data for each bit run in separate files. 1 .5000 START DEPTH 62.0 114.5 STOP DEPTH 2488.0 2534.0 # 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 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # 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): 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 Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD010 GR MWD010 Units FT FT/H API Nsam Rep 1 68 1 68 1 68 Code Size 4 4 4 Name Service Unit DEPT FT Min 62 Max 2534 22-JAN-04 . Insite 66.37 Memory 2534.0 62.0 2534.0 .0 16.2 TOOL NUMBER 61497 13.500 .0 SPUD MUD 9.40 110.0 7.5 200 6.4 .000 .000 .000 .000 Offset o 4 8 Channel 1 2 3 Mean Nsam 1298 4945 .0 68.0 .0 .0 First Reading 62 Last Reading 2534 ROP MWD010 FT/H GR MWD010 API 12.4. 31693.5 17.02 116.62 424.231 4840 .114.5 62.994 4853 62 2534 2488 First Reading For Entire File......... .62 Last Reading For Entire File.......... .2534 File Trailer Service name............ .STSLIB.003 service Sub Level Name.. . Version Number......... ..1.0.0 Date of Generation... ... .04/03/01 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...... .04/03/01 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 GR RPM RPX RPS FET RPD ROP $ 4 header data for each bit run in separate files. 2 .5000 START DEPTH 2488.5 2510.0 2510.0 2510.0 2510.0 2510.0 2534.5 STOP DEPTH 6217.0 6227.0 6227.0 6227.0 6227.0 6227.0 6267.0 # 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: 24-JAN-04 Insite 66.37 Memory 6267.0 2534.0 6267.0 21. 6 82.0 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER 124724 136749 # CASING DATA. BIT SIZE (IN): CASING DEPTH (FT): BOREHOLE AND OPEN HOLE DRILLER'S # BOREHOLE CONDITIONS MUD TYPE: 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 9.875 2526.0 LSND 9.20 55.0 9.0 350 6.0 4.000 2.330 5.000 2.400 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 Name DEPT ROP GR RPX RPS RPM RPD FET Service Unit FT MWD020 FT/H MWD020 API MWD020 OHMM MWD020 OHMM MWD020 OHMM MWD020 OHMM MWD020 HOUR Mean 4377.75 300.017 69.819 10.8647 11.8918 16.3116 19.5635 0.628967 Min 2488.5 0.51 14 .15 0.93 1. 03 0.86 1. 58 0.0547 Max 6267 2394.89 119.71 250.06 762.75 2000 2000 36.9391 First Reading For Entire File......... .2488.5 Last Reading For Entire File.......... .6267 Nsam 7558 7466 7458 7435 7435 7435 7435 7435 . 65.0 116.6 65.0 65.0 First Reading 2488.5 2534.5 2488.5 2510 2510 2510 2510 2510 Last Reading 6267 6267 6217 6227 6227 6227 6227 6227 . File Trailer Service name............ .STSLIB.004 Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .04/03/01 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .04/03/01 Maximum Physical Record. .65535 File Type................LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPX RPS RPM RPD ROP $ 5 . header data for each bit run in separate files. 3 .5000 START DEPTH 6217.5 6227.5 6227.5 6227.5 6227.5 6227.5 6267.5 # 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 7050.0 7050.0 7050.0 7050.0 7050.0 7050.0 7051.0 27-JAN-04 Insite 66.37 Memory 7050.0 6267.0 7050.0 83.1 91. 9 BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 TOOL NUMBER 129046 162742 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: 6.125 6260.0 FLO-PRO MUD DENSITY (LB/G): 4IÞ 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 9.00 56.0 9.5 24000 5.0 4IÞ .100 .080 .150 .130 70.0 95.1 74.0 68.0 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 6217.5 7051 6634.25 1668 6217.5 7051 ROP MWD030 FT/H 0.57 563.48 182.979 1568 6267.5 7051 GR MWD030 API 39.8 109.3 65.6088 1666 6217.5 7050 RPX MWD030 OHMM 0.5 2000 15.3818 1646 6227.5 7050 RPS MWD030 OHMM 0.67 2000 35.9773 1646 6227.5 7050 RPM MWD030 OHMM 0.06 2000 30.7387 1646 6227.5 7050 RPD MWD030 OHMM 0.1 2000 46.5512 1646 6227.5 7050 FET MWD030 HOUR 0.2181 45.4094 2.79106 1646 6227.5 7050 First Reading For Entire File......... .6217.5 Last Reading For Entire File......... ..7051 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/01 Maximum Physical Record. .65535 File Type................... Next File Name......... .~SLIB.006 Physical EOF File Header Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/01 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPX RPS ROP $ 6 . header data for each bit run in separate files. 4 .5000 START DEPTH 7050.5 7050.5 7050.5 7050.5 7050.5 7050.5 7051.5 STOP DEPTH 7548.0 7548.0 7548.0 7548.0 7548.0 7548.0 7548.0 # 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 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # 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): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 27-JAN-04 Insite 66.37 Memory 7548.0 7050.0 7548.0 87.4 97.5 TOOL NUMBER 129046 162742 6.125 6260.0 FLO-PRO 9.10 50.0 9.5 26000 4.4 .140 65.0 MUD AT MAX CIRCULA4IIb TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: .110 .180 .180 . 65.0 # 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 MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7050.5 7548 7299.25 996 7050.5 7548 ROP MWD040 FT/H 22.17 3119.08 213.488 994 7051.5 7548 GR MWD040 API 53.3 123.27 91.9205 996 7050.5 7548 RPX MWD040 OHMM 3 16.06 5.991 996 7050.5 7548 RPS MWD040 OHMM 3.14 19.54 6.49884 996 7050.5 7548 RPM MWD040 OHMM 3.21 20.02 6.77915 996 7050.5 7548 RPD MWD040 OHMM 3.38 20.36 7.07811 996 7050.5 7548 FET MWD040 HOUR 0.1967 8.287 0.673008 996 7050.5 7548 First Reading For Entire File......... .7050.5 Last Reading For Entire File......... ..7548 File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .04/03/01 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.007 Physical EOF File Header ... Service name........... .~SLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.... ...04/03/01 Maximum Physical Record..65535 File Type............... .LO Previous File Name...... .STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ 7 . header data for each bit run in separate files. 5 .5000 START DEPTH 7494.5 7548.5 7548.5 7548.5 7548.5 7548.5 7548.5 STOP DEPTH 9506.5 9513.5 9513.5 9513.5 9513.5 9513.5 9560.5 # 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 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # 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): 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; 28-JAN-04 Insite 66.37 Memory 9561.0 7548.0 9561.0 83.4 92.7 TOOL NUMBER 129046 162742 6.125 6260.0 FLO-PRO 9.10 47.0 9.0 23500 5.5 .210 .170 .160 .280 79.0 96.6 83.0 77.0 # HOLE CORRECTION (IN):4IÞ TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 4IÞ # 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 MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7494.5 9560.5 8527.5 4133 7494.5 9560.5 ROP MWD050 FT/H 1. 91 686.89 219.919 4025 7548.5 9560.5 GR MWD050 API 42.88 137.51 76.4586 4022 7494.5 9506.5 RPX MWD050 OHMM 2.94 39.62 9.2984 3931 7548.5 9513.5 RPS MWD050 OHMM 3.13 36.3 10.1579 3931 7548.5 9513.5 RPM MWD050 OHMM 3.26 28.8 10.6887 3931 7548.5 9513.5 RPD MWD050 OHMM 3.47 26.68 11.3481 3931 7548.5 9513.5 FET MWD050 HOUR 0.1628 6.775 0.466481 3931 7548.5 9513.5 First Reading For Entire File......... .7494.5 Last Reading For Entire File.......... .9560.5 File Trailer Service name............ .STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/01 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.008 Physical EOF File Header Service name........... ..STSLIB.008 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/01 Maximum Physical Record. .65535 File Type................LO Previous File Name..... .~LIB.007 Comment Record FILE HEADER FILE NUMBER: RAW MAD Curves and log DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NUMBER: # FILE SUMMARY VENDOR TOOL CODE SGRC SFXE SEDP SEMP SESP SEXP SRAT $ 8 . for each pass of each run in separate files. header data .5000 2 1 START DEPTH 4162.5 4171.5 4171.5 4171.5 4171.5 4171.5 4216.0 STOP DEPTH 4990.5 5002.0 5002.0 5002.0 5002.0 5002.0 5042.0 # 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 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # 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): 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: 24-JAN-04 Insite 66.37 Memory 5042.0 4171.0 5042.0 21. 6 82.0 TOOL NUMBER 124724 136749 9.875 2526.0 LSND 9.20 55.0 9.0 350 6.0 4.000 2.330 5.000 2.400 65.0 116.6 65.0 65.0 $ . . # Data Format Specification Record Data Record Type................ ..0 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 RAT MAD021 FT/H 4 1 68 4 2 GR MAD021 API 4 1 68 8 3 RPX MAD021 OHMM 4 1 68 12 4 RPS MAD021 OHMM 4 1 68 16 5 RPM MAD021 OHMM 4 1 68 20 6 RPD MAD021 OHMM 4 1 68 24 7 FET MAD021 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4162.5 5042 4602.25 1760 4162.5 5042 RAT MAD021 FT/H 0.5 477.28 345.531 1152 4216 5042 GR MAD021 API 23.91 109.49 54.5236 1159 4162.5 4990.5 RPX MAD021 OHMM 3.08 55.43 17.5679 1185 4171.5 5002 RPS MAD021 OHMM 3.09 94.43 22.7207 1185 4171.5 5002 RPM MAD021 OHMM 3.27 170.41 28.0416 1185 4171.5 5002 RPD MAD021 OHMM 3.95 251. 94 34.8927 1185 4171.5 5002 FET MAD021 HOUR 20.71 28.18 24.5608 1185 4171.5 5002 First Reading For Entire File......... .4162.5 Last Reading For Entire File. ......... .5042 File Trailer Service name............ .STSLIB.008 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/01 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.009 Physical EOF Tape Trailer Service name... . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/03/01 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name...... . . . . . . .LISTPE Date.................... .04/03/01 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.............. .~TOWN 4IIÞ Continuation Number.... .~~' Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Sperry-Sun DrAIIÞng Services LIS Scan Utility é903 -d- ) 0 1 . pv~/~~ $Revision: 3 $ LisLib $Revision: 4 $ Mon Mar 01 09:57:44 2004 Reel Header Service name............ .LISTPE Date.................... .04/03/01 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. . . . . . . . . . . . . . . . . . . . .04/03/01 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 MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPG-16 PB1 500292318970 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 01-MAR-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002878275 T. MCGUIRE E. VAUGHN MWD RUN 2 MW0002878275 T. MCGUIRE E. VAUGHN MAD RUN 2 MW0002878275 T. MCGUIRE E. VAUGHN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 MW0002878275 T.MCGUIRE E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 27 13N 10E 1990 3443 RECEI\/ED .00 62.90 29.20 # WELL CASING RECORD OPEN HOLE CASING DRILLERS .RBfJMS RD MAR 3 0 ,2Dß4 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING BIT S. (IN) 13.500 9.875 6.125 SIZE (IN) 20.000 10.750 7.625 DEPTH (FT) 112.0 2526.0 6260.0 . # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 4. MWD RUNS 2 & 3 COMPRISED DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RUN 3 ADDITIONALLY INCLUDED AT-BIT INCLINATION (ABI). 5. THE MAIN WELLBORE EXITS THIS SECTION AT 7050'MD. THIS SECTION WAS PLUGGED-BACK FOR GEOLOGICAL REASONS - THE TARGET SANDS WERE FAULTED OUT. 6. A MAD PASS WAS PERFORMED AFTER REACHING TD OF RUN 2. THE INTERVALS PRESENTED ARE 4970'MD/3969'TVD TO 4670'MD/3812'TVD AND 4370'MD/3665'TVD TO 4170'MD/3569'TVD. THESE INTERVALS DO NOT COINCIDE WITH THOSE OF THE DRILLERS (5044'MD - 4175'MD, BIT DEPTHS) DUE TO DATA EDITING NECESSITATED BY EXCESSIVE SRATS OVER PARTS OF THE OVERALL MAD INTERVAL. 7. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM K. COONEY (SIS/BP), DATED 2/24/04, QUOTING AUTHORIZATION FROM MIKIE SMITH (BP GEOLOGIST). MWD DATA ARE CONSIDERED PDC. 8. MWD RUNS 1-3 REPRESENT WELL MPG-16 PB1 WITH API#: 50-029-23189-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7498'MD/4446'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SRAT SMOOTHED TOOL SPEED WHEN NOT DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). SLIDE = NON-ROTATED INTERVALS. RESISTIVITY ( EXTRA RESISTIVITY ( SHALLOW RESISTIVITY (MEDIUM RESISTIVITY (DEEP AN 'M' SUFFIX ON CURVE MNEMONICS DENOTES MAD PASS DATA. $ File Header Service name........... .~LIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..04/03/01 Maximum Physical Record. .65535 File Type.. . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP RPS RPX FET RPM RPD $ 1 ~ and clipped curves; all bit runs merged. .5000 START DEPTH 62.0 114.5 2510.0 2510.0 2510.0 2510.0 2510.0 STOP DEPTH 7444.0 7498.0 7451.0 7451.0 7451.0 7451.0 7451.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ # REMARKS: BIT RUN NO 1 2 3 MERGED MAIN PASS. $ MERGE TOP 62.0 2534.0 6267.0 MERGE BASE 2534.0 6267.0 7498.0 # 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 Name Service Unit Min Max Mean Nsam First Reading Last Reading DEPT FT O.~~ 7498 3780 14873 . 62 7498 ROP MWD FT/H 31693.5 318.371 14768 114.5 7498 GR MWD API 14.15 128.2 68.7157 14765 62 7444 RPX MWD OHMM 0.5 2000 11.1693 9883 2510 7451 RPS MWD OHMM 0.67 2000 15.3954 9883 2510 7451 RPM MWD OHMM 0.06 2000 17.8607 9883 2510 7451 RPD MWD OHMM 0.1 2000 22.9569 9883 2510 7451 FET MWD HOUR 0.0547 45.4094 0.988052 9883 2510 7451 First Reading For Entire File......... .62 Last Reading For Entire File.......... .7498 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/01 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...... .04/03/01 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MAD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPS FET RPM RPX RPD RAT $ 2 and clipped curves; all MAD runs merged using earliest passes. .5000 START DEPTH 4162.5 4171.5 4171.5 4171.5 4171.5 4171.5 4216.0 STOP DEPTH 4990.5 5002.0 5002.0 5002.0 5002.0 5002.0 5042.0 # MERGED DATA SOURCE PBU TOOL CODE MWD $ MAD RUN NO. MAD PASS NO. MERGE TOP 2 1 4171.0 MERGE BASE 5042.0 # REMARKS: MERGED MAD 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...........4IIÞ..... .60 .1IN Max frames per record............ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . Service Order Units FT FT/H API OHMM OHMM OHMM OHMM HOUR Size 4 4 4 4 4 4 4 4 Nsam 1 1 1 1 1 1 1 1 Code Offset o 4 8 12 16 20 24 28 Channel 1 2 3 4 5 6 7 8 Name DEPT RAT GR RPX RPS RPM RPD FET MAD MAD MAD MAD MAD MAD MAD Rep 68 68 68 68 68 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4162.5 5042 4602.25 1760 4162.5 5042 RAT MAD FT/H 0.5 477.28 345.531 1152 4216 5042 GR MAD API 23.91 109.49 54.5236 1159 4162.5 4990.5 RPX MAD OHMM 3.08 55.43 17.5679 1185 4171.5 5002 RPS MAD OHMM 3.09 94.43 22.7207 1185 4171.5 5002 RPM MAD OHMM 3.27 170.41 28.0416 1185 4171.5 5002 RPD MAD OHMM 3.95 251.94 34.8927 1185 4171.5 5002 FET MAD HOUR 20.71 28.18 24.5608 1185 4171.5 5002 First Reading For Entire File......... .4162.5 Last Reading For Entire File....... ... .5042 File Trailer Service name........... ..STSLIB.002 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .04/03/01 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...... .04/03/01 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 GR ROP 3 header data for each bit run in separate files. 1 .5000 START DEPTH 62.0 114.5 STOP DEPTH 2488.0 2534.0 $ . # 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 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # 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): 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 Name Service Order DEPT ROP MWD010 GR MWD010 Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code Units FT FT/H API . 22-JAN-04 Insite 66.37 Memory 2534.0 62.0 2534.0 .0 16.2 TOOL NUMBER 61497 13.500 .0 SPUD MUD 9.40 110.0 7.5 200 6.4 .000 .000 .000 .000 .0 68.0 .0 .0 Offset o 4 8 Channel 1 2 3 Mine .st Last Name Service Unit Max Mean Nsam ading Reading DEPT FT 62 2534 1298 4945 62 2534 ROP MWDOI0 FT/H 12.42 31693.5 424.231 4840 114.5 2534 GR MWDOI0 API 17.02 116.62 62.994 4853 62 2488 First Reading For Entire File......... .62 Last Reading For Entire File.......... .2534 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/01 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...... .04/03/01 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 GR RPX RPS RPM RPD FET ROP $ 4 header data for each bit run in separate files. 2 .5000 START DEPTH 2488.5 2510.0 2510.0 2510.0 2510.0 2510.0 2534.5 STOP DEPTH 6217.0 6227.0 6227.0 6227.0 6227.0 6227.0 6267.0 # 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: 24-JAN-04 Insite 66.37 Memory 6267.0 2534.0 6267.0 21.6 82.0 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR EWR4 $ DU~MMA RAY ELE~~G. RESIS. 4 # 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): 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 124724 136749 . 9.875 2526.0 LSND 9.20 55.0 9.0 350 6.0 4.000 2.330 5.000 2.400 65.0 116.6 65.0 65.0 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 2488.5 6267 4377.75 7558 2488.5 6267 ROP MWD020 FT/H 0.51 2394.89 300.017 7466 2534.5 6267 GR MWD020 API 14.15 119.71 69.819 7458 2488.5 6217 RPX MWD020 OHMM 0.93 250.06 10.8647 7435 2510 6227 RPS MWD020 OHMM 1. 03 762.75 11.8918 7435 2510 6227 RPM MWD020 OHMM 0.86 2000 16.3116 7435 2510 6227 RPD MWD020 OHMM 1. 58 2000 19.5635 7435 2510 6227 FET MWD020 HOUR 0.0547 36.9391 0.628967 7435 2510 6227 First Reading For Entire Fi4llÞ........ .2488.5 Last Reading For Entire File.......... .6267 4IIÞ File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/01 Maximum Physical Record. .65535 File Type................ LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/01 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPX RPS ROP $ 5 header data for each bit run in separate files. 3 .5000 START DEPTH 6217.5 6227.5 6227.5 6227.5 6227.5 6227.5 6267.5 STOP DEPTH 7444.0 7451.0 7451.0 7451.0 7451.0 7451.0 7498.0 # 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: 27-JAN-04 Insite 66.37 Memory 7498.0 6267.0 7498.0 83.1 91. 9 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 TOOL NUMBER 129046 162742 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.125 6260.0 BOREHOLE CONDITIONS MUD TYPE: 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: . . # FLO-PRO 9.00 56.0 9.5 24000 5.0 .100 .080 .150 .130 70.0 95.1 74.0 68.0 # 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 6217.5 7498 6857.75 2562 6217.5 7498 ROP MWD030 FT/H 0.57 563.48 165.923 2462 6267.5 7498 GR MWD030 API 39.8 128.2 76.6779 2454 6217.5 7444 RPX MWD030 OHMM 0.5 2000 12.0942 2448 6227.5 7451 RPS MWD030 OHMM 0.67 2000 26.0363 2448 6227.5 7451 RPM MWD030 OHMM 0.06 2000 22.5655 2448 6227.5 7451 RPD MWD030 OHMM 0.1 2000 33.2633 2448 6227.5 7451 FET MWD030 HOUR 0.2181 45.4094 2.07865 2448 6227.5 7451 First Reading For Entire File........ ..6217.5 Last Reading For Entire File.......... .7498 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... version Number......... ....0.0 Date of Generation..... .~/03/01 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/01 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MAD Curves and log DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NUMBER: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS FET RPX RAT $ 6 . for each pass of each run in separate files. header data .5000 2 1 START DEPTH 4162.5 4171.5 4171.5 4171.5 4171.5 4171.5 4216.0 # 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 4990.5 5002.0 5002.0 5002.0 5002.0 5002.0 5042.0 24-JAN-04 Insite 66.37 Memory 5042.0 4171.0 5042.0 21. 6 82.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER 124724 136749 # 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): MUD PH: 9.875 2526.0 LSND 9.20 55.0 9.0 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: 350 . 6.0 4.000 65.0 2.330 116.6 5.000 65.0 2.400 65.0 # 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 Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD021 FT/H 4 1 68 4 2 GR MAD021 API 4 1 68 8 3 RPX MAD021 OHMM 4 1 68 12 4 RPS MAD021 OHMM 4 1 68 16 5 RPM MAD021 OHMM 4 1 68 20 6 RPD MAD021 OHMM 4 1 68 24 7 FET MAD021 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4162.5 5042 4602.25 1760 4162.5 5042 RAT MAD021 FT/H 0.5 477.28 345.531 1152 4216 5042 GR MAD021 API 23.91 109.49 54.5236 1159 4162.5 4990.5 RPX MAD021 OHMM 3.08 55.43 17.5679 1185 4171.5 5002 RPS MAD021 OHMM 3.09 94.43 22.7207 1185 4171.5 5002 RPM MAD021 OHMM 3.27 170.41 28.0416 1185 4171.5 5002 RPD MAD021 OHMM 3.95 251.94 34.8927 1185 4171.5 5002 FET MAD021 HOUR 20.71 28.18 24.5608 1185 4171.5 5002 First Reading For Entire File......... .4162.5 Last Reading For Entire File.......... .5042 File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/01 Maximum Physical Record. .65535 File Type................ LO Next File Name.......... .STSLIB.007 . . Physical EOF Tape Trailer Service name............ .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 04/03/01 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number.. ... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name... . . . . . . . . . .LISTPE Date.................... .04/03/01 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Sperry-Sun Dr"'ng Services LIS sca~ility . 903-(9..\Ö )J.L{~7 $Revision: 3 $ LisLib $Revision: 4 $ Mon Mar 01 10:58:51 2004 Reel Header Service name...... . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/03/01 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.................... .04/03/01 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 MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPG-16 PB2 500292318971 B.P.Exploration (Alaska) Inc. Sperry-Sun Drilling Services 01-MAR-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002878275 T. MCGUIRE E. VAUGHN MWD RUN 2 MW0002878275 T. MCGUIRE E. VAUGHN MAD RUN 2 MW0002878275 T. MCGUIRE E. VAUGHN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 MW0002878275 T.MCGUIRE E. VAUGHN MWD RUN 4 MW0002878275 C.A. DEMOSKI E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 27 13N 10E 1990 3443 RECEIVED '\ r~'\ i ¡ 62.90 29.20 # WELL CASING RECORD OPEN HOLE CASING DRILLERS ReDMS ;=<D MAR ~ (j 7rtM 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING BIT S. (IN) 13.500 9.875 6.125 SIZE (IN) 20.000 10.750 7.625 DEPTH (FT) 112.0 2526.0 6260.0 . # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 4. MWD RUNS 2 - 4 COMPRISED DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RUNS 3 & 4 ALSO INCLUDED AT-BIT INCLINATION (ABI). 5. THE MAIN WELLBORE EXITS THIS SECTION AT 7548'MD. THIS SECTION WAS ALSO PLUGGED-BACK BECAUSE THE TARGET SANDS WERE FAULTED OUT. 6. A MAD PASS WAS PERFORMED AFTER REACHING TD OF RUN 2. THE INTERVALS PRESENTED ARE 4970'MD/3969'TVD TO 4670'MD/3812'TVD AND 4370'MD/3665' TVD TO 4170'MD/3569'TVD. THESE INTERVALS DO NOT COINCIDE WITH THOSE OF THE DRILLERS (5044'MD - 4175'MD, BIT DEPTHS) DUE TO DATA EDITING NECESSITATED BY EXCESSIVE SRATS OVER PARTS OF THE OVERALL MAD INTERVAL. 7. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM K. COONEY (SIS/BP), DATED 2/24/04, QUOTING AUTHORIZATION FROM MIKIE SMITH (BP GEOLOGIST). MWD DATA ARE CONSIDERED PDC. 8. MWD RUNS 1 - 4 REPRESENT WELL MPG-16 PB2 WITH API#: 50-029-23189-71. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7936'MD/4351'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SRAT SMOOTHED TOOL SPEED WHEN NOT DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). SLIDE = NON-ROTATED INTERVALS. RESISTIVITY ( EXTRA RESISTIVITY ( SHALLOW RESISTIVITY (MEDIUM RESISTIVITY (DEEP AN 'M' SUFFIX ON CURVE MNEMONICS DENOTES MAD PASS DATA. $ File Header Service name............ .STSLIB.001 Service Sub Level Name..~ Version Number......... .~o.o Date of Generation...... .04/03/01 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP RPS RPX RPM FET RPD $ 1 . and clipped curveSj all bit runs merged. .5000 START DEPTH 62.0 114.5 2510.0 2510.0 2510.0 2510.0 2510.0 STOP DEPTH 7882.0 7936.0 7889.0 7889.0 7889.0 7889.0 7889.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ # REMARKS: BIT RUN NO 1 2 3 4 MERGED MAIN PASS. $ MERGE TOP 62.0 2534.0 6267.0 7051. 0 MERGE BASE 2534.0 6267.0 7051.0 7936.0 # 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 Name Service Unit Min Max First Reading Last Reading Mean Nsam DEPT FT O.;~ 7936 3999 15749 . 62 7936 ROP MWD FT/H 31693.5 316.337 15644 114.5 7936 GR MWD API 14.15 140.42 69.8016 15641 62 7882 RPX MWD OHMM 0.5 2000 10.8329 10759 2510 7889 RPS MWD OHMM 0.67 2000 14.7701 10759 2510 7889 RPM MWD OHMM 0.06 2000 17.0693 10759 2510 7889 RPD MWD OHMM 0.1 2000 21.7871 10759 2510 7889 FET MWD HOUR 0.0547 45.4094 0.957648 10759 2510 7889 First Reading For Entire File......... .62 Last Reading For Entire File.......... .7936 File Trailer Service name............ .STSLIB.001 service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/01 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...... .04/03/01 Maximum Physical Record. .65535 File Type..... .......... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MAD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPS FET RPM RPX RPD RAT $ 2 and clipped curves; all MAD runs merged using earliest passes. .5000 START DEPTH 4162.5 4171.5 4171.5 4171.5 4171.5 4171.5 4216.0 STOP DEPTH 4990.5 5002.0 5002.0 5002.0 5002.0 5002.0 5042.0 # MERGED DATA SOURCE PBU TOOL CODE MWD $ MAD RUN NO. MAD PASS NO. MERGE TOP 2 1 4171.0 MERGE BASE 5042.0 # REMARKS: MERGED MAD 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.......... .4IÞ...... .60 .1IN Max frames per record..... . . . . . . . .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 4IÞ Service Order Units FT FT/H API OHMM OHMM OHMM OHMM HOUR Size 4 4 4 4 4 4 4 4 Nsam 1 1 1 1 1 1 1 1 Code Offset o 4 8 12 16 20 24 28 Channel 1 2 3 4 5 6 7 8 Name DEPT RAT GR RPX RPS RPM RPD FET MAD MAD MAD MAD MAD MAD MAD Rep 68 68 68 68 68 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4162.5 5042 4602.25 1760 4162.5 5042 RAT MAD FT/H 0.5 477.28 345.531 1152 4216 5042 GR MAD API 23.91 109.49 54.5236 1159 4162.5 4990.5 RPX MAD OHMM 3.08 55.43 17.5679 1185 4171.5 5002 RPS MAD OHMM 3.09 94.43 22.7207 1185 4171.5 5002 RPM MAD OHMM 3.27 170.41 28.0416 1185 4171.5 5002 RPD MAD OHMM 3.95 251.94 34.8927 1185 4171.5 5002 FET MAD HOUR 20.71 28.18 24.5608 1185 4171.5 5002 First Reading For Entire File......... .4162.5 Last Reading For Entire File.......... .5042 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/01 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...... .04/03/01 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 GR ROP 3 header data for each bit run in separate files. 1 .5000 START DEPTH 62.0 114.5 STOP DEPTH 2488.0 2534.0 $ . # 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 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # 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): 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 Name Service Order DEPT ROP MWD010 GR MWD010 Units FT FT/H API Nsam Rep 1 68 1 68 1 68 Code Size 4 4 4 . 22-JAN-04 Insite 66.37 Memory 2534.0 62.0 2534.0 .0 16.2 TOOL NUMBER 61497 13.500 .0 SPUD MUD 9.40 110.0 7.5 200 6.4 .000 .000 .000 .000 .0 68.0 .0 .0 Offset o 4 8 Channel 1 2 3 Min- .st Last Name Service Unit Max Mean Nsam ading Reading DEPT FT 62 2534 1298 4945 62 2534 ROP MWD010 FT/H 12.42 31693.5 424.231 4840 114.5 2534 GR MWD010 API 17.02 116.62 62.994 4853 62 2488 First Reading For Entire File......... .62 Last Reading For Entire File.......... .2534 File Trailer Service name..... ....... .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/01 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...... .04/03/01 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 GR RPD FET RPS RPX RPM ROP $ 4 header data for each bit run in separate files. 2 .5000 START DEPTH 2488.5 2510.0 2510.0 2510.0 2510.0 2510.0 2534.5 STOP DEPTH 6217.0 6227.0 6227.0 6227.0 6227.0 6227.0 6267.0 # 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: 24-JAN-04 Insite 66.37 Memory 6267.0 2534.0 6267.0 21.6 82.0 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR EWR4 $ DUAAMMA RAY ELE~~AG. RESIS. 4 # 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): 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 124724 136749 . 9.875 2526.0 LSND 9.20 55.0 9.0 350 6.0 4.000 2.330 5.000 2.400 65.0 116.6 65.0 65.0 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 2488.5 6267 4377.75 7558 2488.5 6267 ROP MWD020 FT/H 0.51 2394.89 300.017 7466 2534.5 6267 GR MWD020 API 14.15 119.71 69.819 7458 2488.5 6217 RPX MWD020 OHMM 0.93 250.06 10.8647 7435 2510 6227 RPS MWD020 OHMM 1. 03 762.75 11.8918 7435 2510 6227 RPM MWD020 OHMM 0.86 2000 16.3116 7435 2510 6227 RPD MWD020 OHMM 1. 58 2000 19.5635 7435 2510 6227 FET MWD020 HOUR 0.0547 36.9391 0.628967 7435 2510 6227 First Reading For Entire Fi4IÞ........ .2488.5 Last Reading For Entire File......... ..6267 4IÞ File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/01 Maximum Physical Record. .65535 File Type.......... . . . . . .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/01 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPM RPD RPS RPX FET ROP $ 5 header data for each bit run in separate files. 3 .5000 START DEPTH 6217.5 6227.5 6227.5 6227.5 6227.5 6227.5 6267.5 STOP DEPTH 7050.0 7050.0 7050.0 7050.0 7050.0 7050.0 7051.0 # 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: 27-JAN-04 Insite 66.37 Memory 7050.0 6267.0 7050.0 83.1 91. 9 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 TOOL NUMBER 129046 162742 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.125 6260.0 BOREHOLE CONDITIONS MUD TYPE: 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: . . # FLO-PRO 9.00 56.0 9.5 24000 5.0 .100 .080 .150 .130 70.0 95.1 74.0 68.0 # 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 Uni ts . . . . . . . . . . . . . . . . . . . . . . . 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 6217.5 7051 6634.25 1668 6217.5 7051 ROP MWD030 FT/H 0.57 563.48 182.979 1568 6267.5 7051 GR MWD030 API 39.8 109.3 65.6088 1666 6217.5 7050 RPX MWD030 OHMM 0.5 2000 15.3818 1646 6227.5 7050 RPS MWD030 OHMM 0.67 2000 35.9773 1646 6227.5 7050 RPM MWD030 OHMM 0.06 2000 30.7387 1646 6227.5 7050 RPD MWD030 OHMM 0.1 2000 46.5512 1646 6227.5 7050 FET MWD030 HOUR 0.2181 45.4094 2.79106 1646 6227.5 7050 First Reading For Entire File......... .6217.5 Last Reading For Entire File.......... .7051 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... version Number......... .~.O Date of Generation..... .~03/01 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/01 Maximum Physical Record. .65535 File Type......... . . . . . . .LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ 6 . header data for each bit run in separate files. 4 .5000 START DEPTH 7050.5 7050.5 7050.5 7050.5 7050.5 7050.5 7051.5 # 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: # STOP DEPTH 7889.0 7889.0 7889.0 7889.0 7889.0 7882.0 7936.0 27-JAN-04 Insite 66.37 Memory 7936.0 7050.0 7936.0 87.4 97.5 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 TOOL NUMBER 129046 162742 # 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): MUD PH: MUD CHLORIDES (PPM): 6.125 6260.0 FLO-PRO 9.10 50.0 9.5 26000 FLUID LOSS (C3): , RESISTIVITY (OHMM) AT EMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 4.0 . .140 65.0 .110 88.9 .180 65.0 .180 65.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.. ................0 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 MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7050.5 7936 7493.25 1772 7050.5 7936 ROP MWD040 FT/H 22.17 3119.08 208.284 1770 7051.5 7936 GR MWD040 API 53.3 140.42 93.7754 1664 7050.5 7882 RPX MWD040 OHMM 3 21.7 6.22979 1678 7050.5 7889 RPS MWD040 OHMM 3.14 20.57 6.72036 1678 7050.5 7889 RPM MWD040 OHMM 3.21 20.02 7.01784 1678 7050.5 7889 RPD MWD040 OHMM 3.38 20.36 7.34769 1678 7050.5 7889 FET MWD040 HOUR 0.1967 8.287 0.615542 1678 7050.5 7889 First Reading For Entire File....... ...7050.5 Last Reading For Entire File.......... .7936 File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/01 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.007 Physical EOF . File Header Service name............ .STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/01 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MAD Curves and log DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NUMBER: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX RAT $ 7 . for each pass of each run in separate files. header data .5000 2 1 START DEPTH 4162.5 4171.5 4171.5 4171.5 4171.5 4171.5 4216.0 STOP DEPTH 4990.5 5002.0 5002.0 5002.0 5002.0 5002.0 5042.0 # 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 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # 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): 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: 24-JAN-04 Insite 66.37 Memory 5042.0 4171.0 5042.0 21.6 82.0 TOOL NUMBER 124724 136749 9.875 2526.0 LSND 9.20 55.0 9.0 350 6.0 4.000 2.330 5.000 2.400 65.0 116.6 65.0 65.0 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 RAT MAD021 FT/H 4 1 68 4 2 GR MAD021 API 4 1 68 8 3 RPX MAD021 OHMM 4 1 68 12 4 RPS MAD021 OHMM 4 1 68 16 5 RPM MAD021 OHMM 4 1 68 20 6 RPD MAD021 OHMM 4 1 68 24 7 FET MAD021 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4162.5 5042 4602.25 1760 4162.5 5042 RAT MAD021 FT/H 0.5 477.28 345.531 1152 4216 5042 GR MAD021 API 23.91 109.49 54.5236 1159 4162.5 4990.5 RPX MAD021 OHMM 3.08 55.43 17.5679 1185 4171.5 5002 RPS MAD021 OHMM 3.09 94.43 22.7207 1185 4171.5 5002 RPM MAD021 OHMM 3.27 170.41 28.0416 1185 4171.5 5002 RPD MAD021 OHMM 3.95 251.94 34.8927 1185 4171.5 5002 FET MAD021 HOUR 20.71 28.18 24.5608 1185 4171.5 5002 First Reading For Entire File......... .4162.5 Last Reading For Entire File.......... .5042 File Trailer Service name............ .STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..04/03/01 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.008 Physical EOF Tape Trailer Service name............ .LISTPE Date.................... .04/03/01 Origin..................~ 4IIÞ Tape Name............... ~KNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/03/01 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File