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202-137
New Plugback Esets 7/31/2024 Well Name API Number PTD Number ESet Number Date CD2-15 PB1 50-103-20386-70-00 201-159 T39326 4-26-2002 CD2-15 PB2 50-103-20386-71-00 201-159 T39327 4-26-2002 1D-42L1 PB1 50-029-22979-70-00 205-078 T39328 8-3-2005 2N-304 PB1 50-103-20382-70-00 201-130 T39329 9-12-2001 Mitre 1 PB1 50-103-20409-70-00 202-026 T39330 7-23-2002 C-26L1 PB1 50-029-22634-70-00 203-076 T39331 9-17-2003 C-26L1 PB2 50-029-22634-71-00 203-076 T39332 9-17-2003 C-26L1 PB3 50-029-22634-72-00 203-076 T39333 9-17-2003 MPU E-32 PB1 50-029-23261-70-00 205-065 T39334 7-7-2005 S-04L1 PB1 50-029-23148-70-00 203-053 T39335 7-14-2005 S-04L1 PB2 50-029-23148-71-00 203-053 T39336 7-14-2005 MPU S-05 PB1 50-029-23100-70-00 202-137 T39337 6-2-2003 B-03 PB1 50-883-20095-70-00 198-059 T39338 11-6-2003 07-28B PB1 50-029-21770-70-00 209-037 T39339 6-29-2009 16-23A PB1 50-029-22050-70-00 201-054 T39340 6-2-2003 W-34A PB1 50-029-21867-70-00 203-058 T39341 2-6-2004 SP30-W01 PB1 50-629-23476-70-00 212-142 T39342 11-14-2012 V-207L4 PB1 50-029-23390-71-00 208-070 T39343 9-11-2008 W-215 PB1 50-029-23172-70-00 203-131 T39344 9-12-2003 MPU S-05 PB1 50-029-23100-70-00 202-137 T39337 6-2-2003 STATE OF ALASKA �KA OIL AND GAS CONSERVATION COOSION RECENED REPORT OF SUNDRY WELL OPERATIONS MAY 1 8 2018 1.Operations Abandon U Plug Perforations H Fracture StimulateH Pull Tubing LJ Or-r.gn H Performed: Suspend ❑ Perforate ❑ Other Stimulate❑ Alter Casing ❑ Remove an =1151 � El Plug for Redrill ❑ srforate New Pool ❑ Repair Well❑ Re-enter Susp Well ❑ Other: CT Fill Clean-out w/Nitrogen ❑., 2. Name: 4.Well Class Before Work: '5.Permit to Drill Number: Hilcorp Alaska LLC Development 0 Exploratory ❑ 202-137 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-23100-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0380110 MILNE PT UNIT S-05 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 8,810 feet Plugs measured N/A feet true vertical 4,118 feet Junk measured 8,323(Fill) feet Effective Depth measured 8,810 feet Packer measured 5,018&5,272 feet true vertical 4,118 feet true vertical 4,073&4,159 feet Casing Length Size MD TVD Burst Collapse Conductor 84' 20" 112' 112' N/A N/A Production 5,342' 7-5/8" 5,370' 4,175' 6,890psi 4,790psi Liner 3,156' 4-1/2" 8,332' 4,050' Slotted Liner N/A ' Liner 3,432' 4-1/2" 8,807' 4,119' Slotted Liner N/A Perforation depth Measured depth See Schematic feet SCOW) JUN 2 1 Lli'� True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80/IBT-M 5,070' 4,095' 7-5/8"x 4.5"S-3 Hyd. Packers and SSSV(type,measured and true vertical depth) ZXP Liner Top 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: 76 45 211 3,464 225 Subsequent to operation: 442 218 578 3,469 229 14.Attachments(required per 20 AAC 25.07o,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 - Exploratory Development 2 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas H WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 318-186 Sif Authorized Name: Bo York Contact Name: Stan Porhola Authorized Title: Operations Manager Contact Email: sporhola@hilcorp.Com Authorized Signature: 7, Date: 5/16/2018 Contact Phone: 777-8412 ,/ G .,t_ /1 A 64/4 RBDMS1 MAY 2 4 20111 Form 10-404 Revised 4/2017 Submit Original Only • • Well: MPU S-05 Milne Point Unit II • SCHEMATIC Last Completed: 7/29/2002 H lcurp Alaska,LLC PTD: 202-137 TREE&WELLHEAD Tree 4-1/16"—5M FMC Wellhead 11"x 4.5"5M Gen.6 w/4.5"TC-IIT&B Orig.KB=28' Tubing Hanger CIW"H"BPV Profile OPEN HOLE/CEMENT DETAIL 20" I 20" Cmt w/260 sx of Arcticset(Approx)in 42"Hole 7" Cmt w/1,060 sx Class PF"L",280sx Glass"G"in 9-7/8"Hole 4-1/2" Uncemented Liner in a 6-1/8"Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20"x 34" Conductor 215/A-53-Insulated N/A Surface 112' N/A 7-5/8" Production 29.7/L-80/Btc-Mod 6.276 Surface 5,370' 0.0459 1 4-1/2" Slotted Liner"OA" 12.6/L-80/IBT 3.958 5,083' 8,332' N/A 4-1/2" SlottedLiner"OB" 12.6/L-80/IBT 3.958 5,265' 8,807' N/A TUBING DETAIL € 4-1/2" Tubing 12.6/L-80/IBT-M 3.958 Surface 5,004' 0.0152 3-1/2" Tubing 9.2/L-80/NS-CT 2.992 5,004' 5,070' 0.0087 WELL INCLINATION DETAIL KOP @ 250'MD 30 to 50 Deg.1,200'—4,800' Max Hole Angle=99 deg. @ 8,810'MD 57 Deg.@ Sliding Sleeve JEWELRY DETAIL No Depth Item 1 2,010 Camco 4.5"x 1"KGB-2 GLM w/RP valve BK-5 Latch I: 2 4.953' Phoenix Discharge Pressure Gauge—ID=3.850" 3 4,970' HES 4.5"'XD'Dura Sliding Sleeve,Opens Down—10+3.813" 4 4,990' Phoenix Sensor 4-1/2"Casing—ID Change to 2.840" 5 5,004' XO 4.5"NSCT Box x 3.5"NSCT Pin 6 5,016' XO 3.5"NSCT Pin x 4.5"NSCT Pin 7 5,018' Baker 7-5/8"x 4-1/2"S-3 Hyd set Packer—ID=3.875" 8 5,022' XO 4.5"NSCT Box x 3.5"NSCT Pin 9 5,066' HES 3.5"XN-Nipple—2.750"No Go 1 10 5,068 3.5"NSCT WLEG—Bottom @ 5,070'/TVD=4,094 _ 11 5,089' Baker 6"Tie Back Sleeve 12 5,097' Baker Hook Wall,Hanger above 7"Window 13 5,123' Baker Hook Wall,Hanger outside 7"Window 14 5,265' Baker 7-5/8"Tie Back Sleeve 15 5,272' Baker ZXP Liner Top Packer 16 5,279' Baker 7-5/8"x 5"HMC Liner Hanger Mn IDthrutubing ' r 1 2 2841"@4,990 ,ri 1'0'. 3 LATERAL WINDOW DETAIL " Window in 7-5/8"Casing @ 5,111'to 5,123' t« r 4 , Well Angle @ Window=70 Deg. s a GENERAL WELL INFO I. API:50-029-23100-00-00 6 Drilled and Completed by Doyon 141 -7/29/2002 "r41,`8 7 CTCO&R&R Jet Pump—12/27/2016 MnlDthruXN 9 CTCO&R&R Jet Pump—5/12/2018 2.750'@5,066' ka 10 Y NOTE: 4‘,,,*� X 11&12 ,, t 13One or both lateral sections contain fill. 6-1/8"Hole TD @ 8,745' i ., r 413'Rat Hole 14 OA„ era '; Lateral 81 its Slotted Liner 5,136'to 8,292' Tag 8,326'CTMD 7/1/2017 15 -c° t " 16 K._ 6-1/8"Hole TD @ 8,810' a 3'Rat Hole 0I3 Lateral 90 its Slotted Liner 5,373'to 8,�5' Tag 8,320'CTMD 1/10/2018 7-5/8" TD=8,810'(MD)/TD=4,118'(TVD) PBTD=8,810'(MD)/PBTD=4,118'(TVD) Revised By:TDF 5/16/2018 • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP 5-05 CTU #6 50-029-23100-00-00 202-137 5/9/18 5/12/18 Daily OOperations: 5/9/2018-Wednesday MIRU CTU 6 w/2" coil. BOPE Test to 250psi low and 3,500psi high. No failures during test. MU BHA: 2.375" external dimple connector, 2.18" DBPV,4 x 2.18" Weight bars, 2.18"jars, 2.18" hydraulic dsconnect,4" GS. OAL= 14.91'. Install Fusible cap on SSV. M/U lubricator to BOPE. PT low 285psi/High 3800psi.,Open well and RIH with BHA#1.WHP=20psi. Weight check at 4,900' is 19,000-lbs. Begin pumping at 2 bpm. RIH and set down at jet pump at 4,960'. POH 20' and RBIH while pumping and tag again while washing down at 4,962'. P/U and repeat tag at 4,962' Stop pumping. P/U to check latch. 23k-lbs up weight seen. Latch is good. Pull Jet Pump free with 5,000-lbs. over pull. POH to surface. At surface.Jet Pump not recovered. Keep BHA#1: 2.375" external dimple connector, 2.18" DBPV,4 x 2.18" Weight bars, 2.18"jars, 2.18" hydraulic dsconnect,4" GS. OAL= 14.91'. M/U lubricator to BOPE. Open well. WHP = 135psi. RIH w/BHA#1. Weight check at 4,900' is 16,000-lbs. Begin pumping at 2 bpm. RIH and set down at jet pump at 4,962'. POH 20' and RBIH while pumping and tag again at 4,964'. Stop pumping. P/U to check latch. 23k-lbs seen. Latch is good. Pull Jet Pump free with 10,000-lbs. over pull. POH to surface. Experiencing 8,000-lb over pull all the way to surface.JP recovered. L/D Jet Pump and M/U BHA#2: 2.375" external dimple connector, 2.18" DBPV, 1 x 2.18" Weight bars, 2.18"jars, 2.18" hydraulic dsconnect, ported XO to 3/4" SR,4-1/2" BO42 shifting tool set to shift SS up to close. OAL= 14.61'. FP IA and Tubing to 2,500'. SDFN. 5/10/2018-Thursday CTU#6: M/U BHA#2: 2.375" external dimple connector, 2.18" DBPV, 1 x 2.18" Weight bars, 2.18"jars, 2.18" hydraulic dsconnect, ported XO to 3/4" SR,4-1/2" BO42 shifting tool set to shift SS up to close. OAL= 14.61'. M/U lubricator to BOPE. RIH w/BHA#2 to 4,990'. POH from 4,990' at 30 fpm and watch for overpull spike to indicate sleeve is closed. See no overpull. RBIH to 4,990'. POH at 3 fpm again and see no overpull at sliding sleeve. POH to 4,900' P/T IA to 3,400psi for 5 minutes. Good test. Sliding sleeve is closed. Bleed IA to 400psi. POH w/BHA#2 to surface. L/D BO42 shifting tool and M/U BHA#3: 2" CTC, 2.1" DFCV, 2.2" 2x stinger, 2.0" xo, 2.3" SJN Stab on well and NU lubricator. Halliburton N2 MIRU. PJSM for N2 pumping. Fluid pack and PT-300psi low/4,175psi High. Bleed down to 2500psi. Dump coil pressure and verify coil check valves hold. All good. Open well. WHP=Opsi. RIH with BHA#3. Choke closed. Start cool down N2 pumps. PT N2 lines to 4,500psi. Bleed N2 lines to 1,200psi. Pump N2 at 750 scf. RIH w/BHA#3 while circulating 1% KCI at 1 bpm and 750 scf/min of N2. Start seeing returns at surface. RIH at 43 fpm, 1.5 bpm fluid rate/750 scf/m. Swap to GEL. Cleanout to 5,400. Cleanout to 8,323' and tag hard (Same tag as previous coil cleanout). Repeated tag several times. Send 15 bbl sweep and chase sweep to surface. L/D BHA#3. FP well and tree. RDMO to MPF-86A. 5/11/2018-Friday No activity to report. 5/12/2018-Saturday PT PCE 250L/2500H (good). RUN 4280 (keys down)AND OPEN XD-SS AT 4,970' MD WITH LRS PUMPING DOWN TBG. SET 3"JET PUMP (serial# BP-1067, ratio: 9C, sec lock down) IN XD-SS AT 4,790' MD. 5/13/2018-Sunday No activity to report. 5/14/2018-Monday No activity to report. 5/15/2018-Tuesday No activity to report. INMNION • Ziti • �j,�,v THE S E Alaska Oil and Gas Of TASKA. Conservation Commission _x_= _ - 333 West Seventh Avenue . • T F GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 of *' Main: 907.279.1433 si ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager %WO Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU S-05 Permit to Drill Number: 202-137 Sundry Number: 318-186 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this day of May, 2018. RBDMSI MAY 0 3 2018 0 0 RECEIVED MAY 01 201 STATE OF ALASKA p J S sf 3 r1 cS 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 ❑ Remove and Replace Jet Pump Q. Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: CT Fill Clean-out B. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: W/H' z Hilcorp Alaska LLC Exploratory ❑ Development ❑✓ • 202-137 • 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic 111Service ❑ 6.API Number: Anchorage Alaska 99503 50-029-23100-00-00 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 S-05 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0380110 • 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): 8,810 . 4,118 • 8,810 4,118 1,700 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 84' 20" 112' 112' N/A N/A Production 5,342' 7-5/8" 5,370' 4,178' 6,890 psi 4,790 psi Liner A 3,156' 4-1/2" 8,292' 4,050' Slotted Liner Liner B 3,432' 4-1/2" 8,805' 4,119' Slotted Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 4-1/2" 12.6/L-80/IBT-M 5,070' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 7-5/8"x 4.5"Premier Pkr/ZXP Liner Top Pkr and N/A 5,018(MD)/4,073(TVD)&5,272(MD)/4,159(TVD)and N/A 12.Attachments: Proposal Summary ❑i Wellbore schematic ❑i 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: 5/8/2018 Commencing Operations: OIL 0 • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York Contact Name: Stan Porhola Authorized Title: Operations Manager Contact Email: spOrhOla hilCOrp.COm Contact Phone: 777-8412 Authorized Signature: 707-2Date: 5/1/2018 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 311.. 1 0,I�i Q Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No d', Subsequent Form Required: to- '1 o LI APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: /-5 h e) RIG1NAL si A 04( ,.: -.<, 4--, / BDMS 4 k Subs int Form and Form 10-403 Revised ppraapplaZ is valid for 12 months from the date of approval. Attachments in Duplicate �UU • • Well Prognosis Well: MPS-05 Hilcorp Alaska,Lb Date:5/01/18 Well Name: MPU S-05 API Number: 50-029-23100-00 Current Status: Oil Well [Jet Pump] Pad: Milne Point S-Pad Estimated Start Date: May 8th, 2018 Rig: Coil Tubing Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 202-137 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) ITypo ii rIuI hI w1.01, oiLlal. i'i' I Current Bottom Hole Pressure: 2,100 psi @ 4,000' TVD (Last BHP measured 12/10/2015) Maximum Expected BHP: 2,100 psi @ 4,000' TVD (No new perfs being added, EMW= 10.1 ppg) MPSP: 1,700 psi (Based on 0.10 psi/ft gas gradient) Brief Well Summary: MPU S-05 was drilled in 2002 using Doyon 141 and completed as a dual-lateral in the Schrader Bluff OA and OB sands with a Jet Pump. The well has had several jet pump change-outs but still has the original completion. Notes Regarding Wellbore Condition • Deviation atum is 57.0°. p p • Deviation at upper window into the OA lateral is 71.0°. • Deviation at liner hanger into the OB lateral is 76.0°. • Casing last tested to 4,200 psi for 30 min down to 5,018' on 6/09/2014. • Tubing last tested to 4,200 psi for 30 min down to 4,970' on 6/09/2014. • Tubing Grade is L-80. Min ID is 2.84" in the 4-1/2" and 2.75" in the 3-1/2". Objective: The purpose of this work is to pull the existing Jet Pump, cleanout one of the laterals, and run a new Jet Pump on slickline. tI-C° Work Procedure: Coiled Tubing Procedure: 1. MIRU Coiled Tubing Unit and spot ancillary equipment. Fill source tank w/8.5 ppg 1% KCI. ,,,/ 2. Pressure test BOPE to 3,500 psi Hi 250 Low, 10 min Hi, 5 min Low each test. a. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. b. No AOGCC notification required. c. Record BOPE test results on 10-424 form. 3. RIH w/2.00" coil and cleanout to jet pump at+/-4,970' MD (if not pulled by slickline). POOH. PAY 4. RIH w/2.00" coil and pull jet pump at+/-4,970' MD (if not pulled by slickline). POOH. • • Well Prognosis Well: MPS-05 Flacon)Alaska,LL Date:5/01/18 5. RU pumping lines to inner annulus (4-1/2" x 7-5/8"). Pressure test to 3,500 psi Hi 250 Low to confirm no leaks. Bullhead filtered 8.5 ppg seawater down inner annulus (4-1/2"x 7-5/8"; at least 1 casing volume, 130.0 bbl), lifting sand/solids up the 2.0" coil x 4.5" tubing annulus. Freeze protect inner annulus (4-1/2" x 7-5/8") with 20-30 bbl of diesel before closing sleeve. a. Keep pumping down coil tubing and moving coil while bullheading thru the sliding sleeve. 6. RIH w/2.00" coil and shift sliding sleeve closed at+/-4,970' MD (if not closed by slickline). 7. Test backside to 3,500 psi for 5 min to confirm closed (if shifted closed by coil). POOH. 8. RIH w/2.00" coil w/2.5" max OD wash nozzle and extended reach cleanout BHA and cleanout to PBTD at+/-8,807' MD. POOH. a. Multi-lateral is a Baker Hughes Level 2 Hook Hanger that does not provide selective entry of the fL `, laterals, so the lateral that will be entered is unknown. b. Circulate out fill using 8.5 ppg 1% KCI w/friction reducer. Pump 5-10 bbl Gel Sweeps to help remove solids from the liner. c. Contingency: If unable to wash down with nozzle, RIH w/2.5" mill and extended reach cleanout BHA and cleanout to PBTD at+/-8,807' MD. POOH. 9. RIH w/2.00" coil w/2.5" max OD wash nozzle and extended reach cleanout BHA and cleanout to PBTD at / 8,807' MD. POOH. a. Circulate out fill using 8.5 ppg 1% KCI w/liquid foamer and mix with Nitrogen (see Nitrogen procedure and diagram). Utilize defoamer for returns in Kill Tank. fE� b. Contingency: If unable to wash down with nozzle, RIH w/2.5" mill and extended reach cleanout BHA and cleanout to PBTD at+/-8,807' MD using 8.5 ppg 1% KCI w/liquid foamer and mix with Nitrogen. POOH. 10. RIH and shift sliding sleeve open at+/-4,970' MD (if not to be opened by slickline). 11. Pump 8.5 ppg 1% KCI or 8.4 ppg power fluid to confirm open (if shifted open). POOH. 12. PU to 2,500' and freeze protect well. POOH w/coil. 13. RD Coiled Tubing and ancillary equipment. 14. Turn well over to production. Wireline Procedure: 15. MIRU Slickline. PT lubricator to 2,000 psi Hi 250 Low. 16. RIH and se115Dump in sliding sleeve profile at+/-4,970' MD. POOH. 17. RD Slickline. Attachments: 1. As-built Schematic 2. Coil BOPE Schematic 3. Nitrogen Operations Procedure 4. Nitrogen & Foam Flow Diagram Ill Milne Point Unit 14 • Well: MPU S-05 SCHEMATIC Last Completed: 7/29/2002 Hilcorp Alaska,LLC PTD: 202-137 TREE&WELLHEAD Tree 4-1/16"—5M FMC Wellhead 11"x 4.5"5M Gen.6 w/4.5"TC-II T&B Orig.KB=28' Tubing Hanger CIW"H"BPV Profile i . OLE/CEMENT DETAIL 20' 20" Cmt wOPEN/260 sxHof Arcticset(Approx)in 42"Hole 6 7" Cmt w/1,060 sx Class PF"L",280sx Glass"G"in 9-7/8"Hole 4-1/2" Uncemented Liner in a 6-1/8"Hole CASING DETAIL s Size Type Wt/Grade/Conn ID Top Btm BPF 20"x 34" Conductor 215/A-53-Insulated N/A Surface 112' N/i4 1= i 7-5/8" Production 29.7/L-80/Btc-Mod 6.276 Surface 5,370' 0.0459 1 4-1/2" Slotted Liner"OA" 12.6/L-80/IBT 3.958 5,083' 8,332' N/A 4-1/2" SlottedLiner"OB" 12.6/L-80/IBT 3.958 5,265' 8,807' N/A TUBING DETAIL 4-1/2" Tubing 12.6/L-80/IBT-M 3.958 Surface 5,004' 0.0]52 3-1/2" Tubing 9.2/L-80/NS-CT 2.992 5,004' 5,070' 0.0087 WELL INCLINATION DETAIL KOP @ 250'MD 30 to 50 Deg.1,200'—4,800' Max Hole Angle=99 deg. @ 8,810'MD 57 Deg.@ Sliding Sleeve JEWELRY DETAIL No Depth Item 1 2,010 Camco 4.5"x 1"KGB-2 GLM w/RP valve BK-5 Latch 2 4.953' Phoenix Discharge Pressure Gauge—ID=3.850" 3 4,970' HES 4.5"'XD'Dura Sliding Sleeve,Opens Down—ID+3.813" 4 4,990' Phoenix Sensor 4-1/2"Casing—ID Change to 2.840" 5 5,004' XO 4.5"NSCT Box x 3.5"NSCT Pin 6 5,016' XO 3.5"NSCT Pin x 4.5"NSCT Pin 7 5,018' Baker 7-5/8"x 4-1/2"S-3 Hyd set Packer—ID=3.875" 8 5,022' XO 4.5"NSCT Box x 3.5"NSCT Pin 9 5,066' HES 3.5"XN-Nipple-2.750"No Go 10 5,068 3.5"NSCT W LEG—Bottom @ 5,070'/ ND=4,094' 11 5,089' Baker 6"Tie Back Sleeve 12 5,097' Baker Hook Wall,Hanger above 7"Window } ( a 13 5,123' Baker Hook Wall,Hanger outside 7"Window d* t 14 5,265' Baker 7-5/8"Tie Back Sleeve �t 15 5,272' Baker ZXP Liner Top Packer 16 5,279' Baker 7-5/r x 5”HMC Liner Hanger Mn ID thru tubing zsa0'@a,990 IM 4 ‘,...--i LATERAL WINDOW DETAIL im ,i iWindow in 7-5/8"Casing @ 5,111'to 5,123' IF s 4 Well Angle @ Window=70 Deg. �pp GENERAL WELL INFO rI API:50-029-23100-00-00 S. 6 7 Drilled and Completed by Doyon 141 -7/29/2002 8 k. CTCO&R&R Jet Pump—12/27/2016 Min ID thru XN 2.75@5,066' ' = s 0" NOTE: 10 X11&12 One or both lateral sections contain fill. '' ‘11; 6-1/8"Hole TD @ 8,745' i i 413'Rat Hole P. 14 "OA"Lateral 81 jts Slotted Liner 5,136'to 8,292' Tag 8,326'CTMD 7/1/2017 L______ 6-1/8"Hole TD @ 8,810' 3'Rat Hole "06 Lateral 90 jts Slotted Liner 5,373'to 8,805' Tag 8,320'CTMD 1/10/2018 7-5/8" No TD=8,810'(MD)/TD=4,118'(TVD) PBTD=8,810'(MD)/PBTD=4,118'(TVD) Revised By:TDF 1/11/201: • • COIL BOPE MILNE POINT UNIT MPU S-05 Hileorp Alaska,LLC 5/01/2018 MPU S-05 20 X 7% X 4/2 Coil Tubing BOP ' 2 S { Lubricator to injection head 0 i F111 n 2.00"Single Stripper �1•111.1 Blind/Shear M, 1/16 10 �a Blind/Shear 11�� il • 1111111111111 .',I, Blind/Shear -- --Blind/Shearl.�®'•il Mk 4 11 0'1111 "IBM Slip — Mi SlipMall.. — IIIIIIIIIIIIII— Jiiii Pipe 1= S ANDARD WELL PROCEDURE t ikorp.Alaska,LLC NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 . . 0 • . ... ; • <::: 7,:c6 :...' g4>: 1'2:3; Dial :::........: i,..; •,. •• : LT- > Po ,- _. z cc __. z ce ce -.• .• E '' Ef, o t.., '',... = 2 tu) EiFz • .•••• ce 2 ce I.: D '— 20I— D -'111 Z 6. ,... ..... 2 -. E a , = 7:1 R. -•• •E v„.... 0 E.9 Fc a- u • i a. a. ia ., --, u : , , ni ll111111i rir".- :g 2 co oi t z 7•-• ,- '' > Ci co 2 11.41111-- co Ex. o • o En- 40 x LE Gz.CE 4 1- -o o ...- tz c ro 2 6 u .c • , ''''( A jIXJ t.1 'TM/ A. 1 - o §_ ... ...... _I g' '-- '.1-*7 7.7: `,1 ill mai 11111m 11',14.41111 mt ill EliAll'',,i ri 0:(011''.i i 1... ..* m, ,I 111H111 MI Mil o., ......-- 000e i. O2 i w 0 cc o .0 o 0 Le ail cl. V CC W L.1.1 ..... 1- 2 .,E...... , 0 z 4 LL• 4 'iii CI 1- 1- co = 03 0 c-e 8 a. .-, m cl co 8 -4- 23 r = RECEIVED • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO•SSION REPORT OF SUNDRY WELL OPERATIONS MAY o 1 2018 1.Operations Abandon U Plug Perforations U Fracture Stimulate[ Pull Tubing U AOGGeitdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate❑ Alter Casing El Remove and Replace Jet Pump Q Plug for Redrill ❑ srforate New Pool ❑ Repair Well❑ Re-enter Susp Well ❑ Other: CT Fill Clean-out w/Nitrogen ❑✓ 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development ❑✓ Exploratory El 202-137 3.Address: Stratigraphic Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-23100-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0380110 MILNE PT UNIT S-05 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 8,810 feet Plugs measured N/A feet true vertical 4,118 feet Junk measured 8,320(Fill) feet Effective Depth measured 8,810 feet Packer measured 5,018&5,272 feet true vertical 4,118 feet true vertical 4,073&4,159 feet Casing Length Size MD TVD Burst Collapse Conductor 84' 20" 112' 112' N/A N/A Production 5,342' 7-5/8" 5,370' 4,175' 6,890psi 4,790psi Liner 3,156' 4-1/2" 8,332' 4,050' Slotted Liner N/A Liner 3,432' 4-1/2" 8,807' 4,119' Slotted Liner N/A Perforation depth Measured depth See Schematic feet SCANNED :F True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80/IBT-M 5,070' 4,095' 7-5/8"x 4.5"S-3 Hyd. Packers and SSSV(type,measured and true vertical depth) ZXP Liner Top 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 0 300 0 Subsequent to operation: 199 118 405 3,451 222 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations D Exploratory Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL U Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 318-002 Authorized Name: Bo York Contact Name: Stan Porhola Authorized Title: Operations Manager Contact Email: sporhola@hilcorp.com Authorized Signature: 71,ZDate: 5/1/2018 Contact Phone: 777-8412 2i RBDAII$,,, 'MAY Q 1 1018 Form 10-404 Revised 4/2017 Submit Original Only H . Milne Point Unit . Well: MPU 5-05 SCHEMATIC Last Completed: 7/29/2002 uifeorp Alaska,LLC PTD: 202-137 TREE&WELLHEAD Tree 4-1/16"—5M FMC Wellhead 11"x 4.5"5M Gen.6 w/4.5"TC-II T&B Orig.KB=28' Tubing Hanger CIW"H"BPV Profile . 1 11 j 20' iii OPEN HOLE/CEMENT DETAIL 4 20" Cmt w/260 sx of Arcticset(Approx)in 42"Hole 7" Cmt w/1,060 sx Class PF"L",280sx Glass"G"in 9-7/8"Hole 4-1/2" Uncemented Liner in a 6-1/8"Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20"x 34" Conductor 215/A-53-Insulated N/A Surface 112' N/A ,. 7-5/8" Production 29.7/L-80/Btc-Mod 6.276 Surface 5,370' 0.0459 1 4-1/2" Slotted Liner"OA" 12.6/L-80/IBT 3.958 5,083' 8,332' N/A 4-1/2" SlottedLiner"OB" 12.6/L-80/IBT 3.958 5,265' 8,807' N/A TUBING DETAIL 4-1/2" Tubing 12.6/L-80/IBT-M 3.958 Surface 5,004' 0.052_ 3-1/2" Tubing 9.2/L-80/NS-CT 2.992 5,004' 5,070' 0.0087 WELL INCLINATION DETAIL KOP@250'MD 30 to 50 Deg.1,200'—4,800' Max Hole Angle=99 deg. @ 8,810'MD 57 Deg.@ Sliding Sleeve JEWELRY DETAIL No Depth Item 1 2,010 Camco 4.5"x 1"KGB-2 GLM w/RP valve BK-5 Latch 2 4.953' Phoenix Discharge Pressure Gauge—10=3.850" 1 3 4,970' HES 4.5"'XD'Dura Sliding Sleeve,Opens Down—10+3.813" 4 4,990' Phoenix Sensor 4-1/2"Casing—ID Change to 2.840" 5 5,004' XO 4.5"NSCT Box x 3.5"NSCT Pin 6 5,016' XO 3.5"NSCT Pin x 4.5"NSCT Pin 7 5,018' Baker 7-5/8"x 4-1/2"S-3 Hyd set Packer—ID=3.875" 8 5,022' XO 4.5"NSCT Box x 3.5"NSCT Pin 9 5,066' HES 3.5"XN-Nipple—2.750"No Go 10 5,068 3.5"NSCTWLEG—Bottom @ 5,070'/ TVD=4,094' 11 5,089' Baker 6"Tie Back Sleeve i; 12 5,097' Baker Hook Wall,Hanger above 7"Window , 13 5,123' Baker Hook Wall,Hanger outside 7"Window 14 5,265' Baker 7-5/8"Tie Back Sleeve 15 5,272' Baker ZXP Liner Top Packer [An IDthrutubing 2 16 5,279' Baker 7-5/8"x 5"HMC Liner Hanger 2.840"@4,994 $ $ 3 LATERAL WINDOW DETAIL '4 Window in 7-5/8"Casing @ 5,111'to 5,123' is 5 }e Well Angle @ Window=70 Deg. .� I GENERAL WELL INFO 1; 4 API:50-029-23100-00-00 6 Drilled and Completed by Doyon 141 -7/29/2002 NSnIDttlruXN e°; 8 CTCO&R&R Jet Pump—12/27/2016 il 2.750"@5,066' s l NOTE: M.x 1D w 4,11&12 One or both lateral sections contain fill. ° "13 6-1/8"Hole TD @ 8,745' i F = - 413'Rat Hole 14 ii 15o�n4 81 jts Slotted Liner 5,136'to 8,2`' Tag 8,326'CTMD 7/1/2017 16 6-1/8"Hole TD @ 8,810' 3'Rat Hole ` "OB'Lateral 90 jts Slotted Liner 5,373'to 8,805' Tag 8,320'CTMD 1/10/2018 7-5/8" \ Nu TD=8,810'(MD)/TD=4,118'(TVD) PBTD=8,810'(MD)/PBTD=4,118'(TVD) Revised By:TDF 1/11/201: Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP S-05 CTU 50-029-23100-00-00 202-137 1/9/18 1/10/18 Daily Operations: 1101941M-----=4-'7, - 1/3/2018 10G94IM 1/3/2018 -Wednesday No activity to report. 1/4/2018-Thursday No activity to report. 1/5/2018- Friday No activity to report. 1/6/2018-Saturday No activity to report. 1/7/2018-Sunday No activity to report. 1/8/2018- Monday No activity to report. 1/9/2018-Tuesday MIRU SLB CTU #6- 2" CT. MU C/O BHA with 2.25" OD DJN. Stab on well. NU BOPE. Function test BOPE. MIRU HAL N2. Fluid pack and PT PCE, coil, surface lines to 300 psi low/4,175 psi high.Test check valves. Open well. Install fusible cap. T/I/0 114 psi/0 psi/ NA. RIH with BHA#1. PT N2 surface lines to 4,000 psi. On line with SLK 1%at 1.2 bpm/ N2 at 750 scf/m t 2,500' while RIH. Returns at surface with N2 at 4,800' while RIH. Start Clean out Clean out to 7,000', make short trip pumping 5 bbl gel sweeps followed by 30 bbls SLK 1%and repeat. Clean out to 7,616', make short trip. Liquid rate at 1.5 bpm/ N2 at 850 scf/m. Lost returns with 2nd bite at surface. PUH to 4,700', regain returns. RBIH, and take shorter bites. e- Cleaned out to 6,000'. POOH, pump 10 bbls 60/40 and displace coil with N2. At surface. Pump 15 bbls 60/40 down the tubing. Close SV. Stand injector back. Night Cap the BOPE. Remove fusible cap. SDFN Haul off returns. Reload N2 pumper. Reload gel for tomorrow • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP S-05 CTU 50-029-23100-00-00 202-137 1/9/18 1/10/18 Daily Operations: 1/10/2018-Wednesday CTU crew arrive on location. PJSM. Prepare for BOP test. Fluid pack coil with 41 bbls 60/40 Full BOP test to 250psi/ 4,000psi. Record on 10-424. MU BHA- 2" OD CTC, 2.11" OD DBPV, Stinger,Stinger,XO, 2.25" OD DJN. OAL= 10.96'. Get on well. PT low-285psi/high -4,180psi. Open well.T/I/O= 210psi/ 137psi/ N/A. RIH with choke closed. Start cool down N2 pump. At—2500' start pumping 1 bpm with SLK 1%and 750 scf/m N2 down coil. CTP= 2,000psi/WHP at 7psi. No returns with choke FO. Establish good returns. Clean out to 8,320' ctmd in 500' bites with 1,000'to 1,500' short trips. Pump 5-10 bbls sweeps after every 30 bbls SLK 1% pumped. Maintained full returns throughout. Pumped final sweep off bottom and chase returns out of hole. Make U/D/U pass across sliding sleeve at 4,970'. Swap to 60/40 meth. Pump 10 bbls and displace coil with N2 at 1,000 scf/min. SD N2 at 2,500' while POOH.Tag up at surface. Pump 30 bbls 60/40 down tubing. Close SV. BD. RDMO. Well secure. 1/11/2018-Thursday No activity to report. 1/12/2018- Friday No activity to report. 1/13/2018 Saturday No activity to report. 1/14/2018-Sunday No activity to report. 1/15/2018- Monday No activity to report. of Tye • 5 THE STATE Alaska Oil and Gas ���:.� 7 of L A SKA Conservation Commission Wet _ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 pA ak Main: 907.279.1433 ALAS* Fax: 907.276.7542 www.aogcc.alaska.gov Bo YorkSf hNNE� „AN 1 72.318 Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU S-05 Permit to Drill Number: 202-137 Sundry Number: 318-002 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair 9 DATED this day of January, 2018. =7:3 • RECEIVED • STATE OF ALASKA JAN 2 18 ALASKA OIL AND GAS CONSERVATION COMMISSION / APPLICATION FOR SUNDRY APPROVALS A GCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate El Repair Well ❑ Operations shutdown❑ Suspend El Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Remove and Replace Jet Pump❑✓ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing El Other: CT Fill Clean-out 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: iv/it;L Hilcorp Alaska LLC , Exploratory ❑ Development D , 202-137, 3.Address: 3800 Centerpoint Dr,Suite 1400 ❑ 6.API Number: Stratigraphic ❑ Service Anchorage Alaska 99503 50-029-23100-00-00 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 ' Will planned perforations require a spacing exception? Yes ❑ No El / MILNE PT UNIT S-05 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0380110 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): 8,810 ` 4,118 ' 8,810 ° 4,118 ' 1,700 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 84' 20" 112' 112' N/A N/A Production 5,342' 7-5/8" 5,370' 4,178' 6,890 psi 4,790 psi Liner A 3,156' 4-1/2" 8,292' 4,050' Slotted Liner Liner B 3,432' 4-1/2" 8,805' 4,119' Slotted Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic • See Schematic 4-1/2" 12.6/L-80/IBT-M 5,070' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 7-5/8"x 4.5"Premier Pkr/ZXP Liner Top Pkr and N/A - 5,018(MD)/4,073(TVD)&5,272(MD)/4,159(TVD)and N/A 12.Attachments: Proposal Summary Q Wellbore schematic El 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Stratigraphic❑ Development❑✓ • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 1/9/2018 Commencing Operations: OIL WINJ ❑ WDSPL El Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG El GSTOR ❑ SPLUG ❑ Commission Representative: GINJ El Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York Contact Name: Stan Porhola Authorized Title: Operations Manager Contact Email: sporholac hilcorp.com .v Contact Phone: 777-8412 Authorized Signature Date: 1/2/2018 COMMISSION USE ONLY Conditions of approval: otify Commission so that a representative may witness Sundry Number: 173 ' ( U2. Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: W ' APPROVED BY I Approved by: COMMISSIONER THE COMMISSION Date: I LI 1 1'rj 0( 9m 11318 ,r,vo, 1 \ 1 l J Submit Form and XS) Form10-403 Revised 4/2017 Approved application is vali o 1R I o s( 1 Y M r'A\mAL f approval. Attachments in Duplicate • S Well Prognosis Well: MPS-05 IIilcorn Alaska,Lb Date: 1/02/18 Well Name: MPU S-05 API Number: 50-029-23100-00 Current Status: Oil Well [Jet Pump] Pad: Milne Point S-Pad Estimated Start Date: January 9th, 2018 Rig: Coil Tubing Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 202-137 First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFI=Number: :, i b`TYPe:T G000aniticieihoica, Current Bottom Hole Pressure: 2,100 psi @ 4,000' TVD (Last BHP measured 12/10/2015) Maximum Expected BHP: 2,100 psi @ 4,000' TVD (No new perfs being added, EMW= 10.1 ppg) MPSP: 1,700 psi (Based on 0.10 psi/ft gas gradient) Brief Well Summary: MPU S-05 was drilled in 2002 using Doyon 141 and completed as a dual-lateral in the Schrader Bluff OA and OB sands with a Jet Pump. The well has had several jet pump change-outs but still has the original completion. Notes Regarding Wellbore Condition • Deviation at pump is 57.0°. • Deviation at upper window into the OA lateral is 71.0°. • Deviation at liner hanger into the OB lateral is 76.0°. • Casing last tested to 4,200 psi for 30 min down to 5,018' on 6/09/2014. • Tubing last tested to 4,200 psi for 30 min down to 4,970' on 6/09/2014. • Jet Pump currently inactive. Well plugged off below jet pump. • Tubing Grade is L-80. Min ID is 2.84" in the 4-1/2" and 2.75" in the 3-1/2". Objective: The purpose of this work is to pull the existing Jet Pump, cleanout one of the laterals, and run a new Jet Pump on slickline. ""- Work Procedure: Coiled Tubing Procedure: 1. MIRU Coiled Tubing Unit and spot ancillary equipment. Fill source tank w/8.5 ppg 1% KCI. 2. Pressure test BOPE to 3,500 psi Hi 250 Low, 10 min Hi, 5 min Low each test. �v a. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. b. No AOGCC notification required. c. Record BOPE test results on 10-424 form. RIH w/2.00" coil and cleanout to jet pump at+/-4,970' MD(if not pulled by slickline). POOH. ,Sv 4. RIH w/2.00" coil and pull jet tpu p at+/-4,970' MD (if not pulled by slickline). POOH. S • • H Well Prognosis Well: MP S-05 IIilcorp Alaska,LL Date:1/02/18 5. RU pumping lines to inner annulus (4-1/2" x 7-5/8"). Pressure test to 3,500 psi Hi 250 Low to confirm no leaks. Bullhead filtered 8.5 ppg seawater down inner annulus (4-1/2"x 7-5/8"; at least 1 casing volume, 130.0 bbl), lifting sand/solids up the 2.0" coil x 4.5"tubing annulus. Freeze protect inner annulus (4-1/2" x 7-5/8") with 20-30 bbl of diesel before closing sleeve. a. Keep pumping down coil tubing and moving coil while bullheading thru the sliding sleeve. 6. RIH w/2.00" coil and shift sliding sleeve closed at+/-4,970' MD (if not closed by slickline). 7. Test backside to 3500 psi for 5 min to confirm closed (if shifted closed by coil). POOH. 8. RIH w/2.00" coil w/2.5" max OD wash nozzle and extended reach cleanout BHA and cleanout to PBTD at+/-8,807' MD. POOH. 0 L 47-eR4L- - a. Multi-lateral is a Baker Hughes Level 2 Hook Hanger that does not provide selective entry of the laterals, so the lateral that will be entered is unknown. b. Circulate out fill using 8.5 ppg 1% KCI w/friction reducer. Pump 5-10 bbl Gel Sweeps to help remove solids from the liner. c. Contingency: If unable to wash down with nozzle, RIH w/2.5" mill and extended reach cleanout BHA and cleanout to PBTD at+/-8,807' MD. POOH. 9. RIH w/2.00" coil w/2.5" max OD wash nozzle and extended reach cleanout BHA and cleanout to PBTD at+/-8,807' MD. POOH. a. Circulate out fill using 8.5 ppg 1% KCI w/liquid foamer and mix with Nitrogen (see Nitrogen procedure and diagram). Utilize defoamer for returns in Kill Tank. b. Contingency: If unable to wash down with nozzle, RIH w/2.5" mill and extended reach cleanout BHA and cleanout to PBTD at+/-8,807' MD using 8.5 ppg 1% KCI w/liquid foamer and mix with Nitrogen. POOH. 10. RIH and shift sliding sleeve open at+/-4,970' MD (if not to be opened by slickline). 11. Pump 8.5 ppg 1% KCI or 8.4 ppg power fluid to confirm open (if shifted open). POOH. 12. PU to 2,500' and freeze protect well. POOH w/coil. 13. RD Coiled Tubing and ancillary equipment. 14. Turn well over to production. Wireline Procedure: 15. MIRU Slickline. PT lubricator to 2,000 psi Hi 250 Low. 16. RIH and set jet pump in sliding sleeve profile at+/-4,970' MD. POOH. 17. RD Slickline. Attachments: 1. As-built Schematic 2. Coil BOPE Schematic 3. Nitrogen Operations Procedure 4. Nitrogen &Foam Flow Diagram • H . . e Well:MilnMPointPU 5Unit 05 . ti SCHEMATIC Last Completed: 7/29/2002 'Bleary Alaska,LLC PTD: 202-137 TREE&WELLHEAD Tree 4-1/16"—5M FMC Wellhead 11"x 4.5"5M Gen.6 w/4.5"TC-IIT&B Orig.KB=28' Tubing Hanger CIW"H"BPV Profile 4 I OPEN HOLE/CEMENT DETAIL 20, r 20" Cmt w/260 sx of Arcticset(Approx)in 42"Hole 7" Cmt w/1,060 sx Class PF"L",280sx Glass"G"in 9-7/8"Hole 4-1/2" Uncemented Liner in a 6-1/8"Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20"x 34" Conductor 215/A-53-Insulated N/A Surface 112' N/A 7-5/8" Production 29.7/L-80/Btc-Mod 6.276 Surface 5,370' 0.0459 1 4-1/2" Slotted Liner"OA" 12.6/L-80/IBT 3.958 5,083' 8,332' N/A 4-1/2" Slotted Liner"OB" 12.6/L-80/IBT 3.958 5,265' 8,807' N/A TUBING DETAIL 4-1/2" Tubing 12.6/L-80/IBT-M 3.958 Surface 5,004' 0.0152 3-1/2" Tubing 9.2/L-80/NS-CT 2.992 5,004' 5,070' 0.0087 WELL INCLINATION DETAIL i KOP @ 250'MD i 30 to 50 Deg.1,200'—4,800' Max Hole Angle=99 deg. @ 8,810'MD 57 Deg.@ Sliding Sleeve JEWELRY DETAIL No Depth Item 1 2,010 Camco 4.5"x 1"KGB-2 GLM w/RP valve BK-5 Latch 2 4.953' Phoenix Discharge Pressure Gauge—ID=3.850" 3 4,970' HES 4.5"'XD'Dura Sliding Sleeve,Opens Down—ID+3.813" 4 4,990' Phoenix Sensor 4-1/2"Casing—ID Change to 2.840" 5 5,004' XO 4.5"NSCT Box x 3.5"NSCT Pin 6 5,016' XO 3.5"NSCT Pin x 4.5"NSCT Pin 7 5,018' Baker 7-5/8"x 4-1/2"S-3 Hyd set Packer—ID=3.875" 8 5,022' XO 4.5"NSCT Box x 3.5"NSCT Pin 9 5,066' HES 3.5"XN-Nipple—2.750"No Go 10 5,068 3.5"NSCT WLEG—Bottom @ 5,070'/ TVD=4,094' 11 5,089' Baker 6"Tie Back Sleeve 12 5,097' Baker Hook Wall,Hanger above 7"Window 13 5,123' Baker Hook Wall,Hanger outside 7"Window 14 5,265' Baker 7-5/8"Tie Back Sleeve 15 5,272' Baker ZXP Liner Top Packer Nin IDthrutubing y 2 16 5,279' Baker 7-5/8"x 5"HMC Liner Hanger 2.840 @4,990 j , 3 LATERAL WINDOW DETAIL ' 1111 4 Window in 7-5/8"Casing @ 5,111'to 5,123' 5 Well Angle @ Window=70 Deg. GENERAL WELL INFO API:50-029-23100-00-00 r . • 6 Drilled and Completed by Doyon 141 -7/29/2002 _ 7 CTCO&R&R Jet Pump—12/27/2016 MniDthruXN _ 9 ', 2.750"@5,066' • '� 9 z' NOTE: 1,0 i10 _11&12 One or both lateral sections contain fill. ..rs **13 6 1/8"Hole TD @ 8,745' + A- 413'Rat Hole 'mei „0A Lateral81 jts Slotted Liner 5,136'to 8,292' 15 ..o. Tag 8,326'CTMD 7/1/2017 ii 16 6-1/8"Hole TD @ 8,810' 4- "OB"Lateral 90 jts Slotted Liner 5,373'to 8,805' 3'Rat Hole 7-5/8" TD=8,810'(MD)/TD=4,118'(TVD) PBTD=8,810'(MD)/PBTD=4,118'(]VD) Revised By:TDF 7/7/2017 . 111 • • COIL BOPE MILNE POINT UNIT MPU S-05 Hilcorp Alaska,LLC 1/02/2018 MPU 5-05 20 X 7% X 4%: Coil Tubing BOP 3 Lubricator to injection head e 0 2.00"Single Stripper - 1/16 10 r €= Blind/Shear _ J -- on. --_� _ - ) __ €= Blind/Shear_- Blind/Shear =) - - illill0 — — 0O I __T.__-III = a _ -/ €_ __ Pipe Pipe __ = J 1 I- 1 Crossover spool 4 1/16 10M X 4 1/16 5M € 1 =1 Pump-In Sub 11 ®� ( ;�0 e `` 4 1/16 5M . \° I l k°4} 111111 1502 Union g Manual Gate Manual Gate Valve,Swab,WKM-M, •--• ,4 2 1/8 5M 2 1/8 5M 4 1/16 5M FE , ��°� �\L°- Fac imodo '...le'� �'y6 i €_ \a IN '• Valve,Upper Master,Baker, O 4 1/16 5M FE,w/Hydraulic .spar I.I Valve,Lower Master,WKM-M, P_7:0- 4.. 4 1/16 5M FE Tubing Adapter,4 1/16 5M jjj • fi • STANDARD WELL PROCEDURE fkorp-tla ka.HA* NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/02 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 • 411 Pill r , T > x T., ___i_ 111 N O > U ,n > > O > F. C \u+ � O V YAW � Ou .. w > W a ; o3ao � o o3ao ,r, o ...4 an . .. '" gig J T •L .a m Z O a a °' > w G Co. U J a m .G O m m N % U :... O y... W v > X E 7Gz 0 m m .9 • K . 0 > N t- e .:I- (., r.U 411111r v Z M m J g OU C Y O L P i — A V A w1- LL V C n r n n v a n. i 1111 1111 1111 MI e . 11=11111 II11 11 1.411 !'0 44 4 _,I —__1.�, . .." 'u 1111 1111 1111 1111 0000 W, C O I Ili N Z W ai',,, r a C p C C m WV m Lc a V X cr.:>- .3.' Z > F K C W W r g a�a 330 co O H J_ I' Y I m U' m C a a D aa 0 0 v gl. . STATE OF ALASKA ALOA OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing Li Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Remove and Replace Jet Pump ❑., Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: CT Fill Clean-out w/Nitrogen 0 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development ❑., Exploratory ❑ 202-137 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-23100-0 7.Property Designation(Lease Number): 8.Well Name and Number: RECEIVED ADL0380110 MILNE PT UNIT S-05 JUL1 0 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): J 2017 N/A MILNE POINT/SCHRADER BLUFF OIL 11.Present Well Condition Summary: ADCC Total Depth measured 8,810 feet Plugs measured N/A feet true vertical 4,118 feet Junk measured N/A feet Effective Depth measured 8,810 feet Packer measured 5,018&5,272 feet true vertical 4,118 feet true vertical 4,073&4,159 feet Casing Length Size MD TVD Burst Collapse Conductor 84' 20" 112' 112' N/A N/A Production 5,342' 7-5/8" 5,370' 4,175' 6,890psi 4,790psi Liner 3,156' 4-1/2" 8,332' 4,050' Slotted Liner Liner 3,432' 4-1/2" 8,807' 4,119' Slotted Liner Perforation depth Measured depth See Schematic feet ANNE® JULI ,Z017, True Vertical depth See Schematic feet SCA Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80/IBT-M 5,070' 4,095' 7-5/8"x 4.5"S-3 Hyd. Packers and SSSV(type,measured and true vertical depth) ZXP Liner Top 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: 27 21 416 3,449 239 Subsequent to operation: 191 99 1,053 3,435 241 14.Attachments(required per 20 AAC 25.070,25.071,&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 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-290 , Authorized Name: Bo York Contact Name: Stan Porhola Authorized Title: Operations Manager Contact Email: sporhola@hilcorp.com Authorized Signature: Dat" 7/10/2017 Contact Phone: 777-8412 yt 7—/1-17 RBDMS l,i/ "" 1 2 2017 A / /7 / Form 10-404 Revised 4/2017 e 2� i Submit Original Only • • Milne Well: MPU S-05 II SCHEMATIC Last Completed:PointUnit 7/29/2002 flacon)Alaska.LLC. PTD: 202-137 TREE&WELLHEAD Tree 4-1/16"-5M FMC Wellhead 11"x 4.5"5M Gen.6 w/4.5"TC-II T&B Orig.KB=28' Tubing Hanger CIW"H"BPV Profile OPEN HOLE/CEMENT DETAIL i a 20" «1 20' Cmt w/260 sx of Arcticset(Approx)in 42"Hole 7" Cmt w/1,060 sx Class PF"L",280sx Glass"G"in 9-7/8"Hole 4-1/2" Uncemented Liner in a 6-1/8"Hole i4 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20"x 34" Conductor 215/A-53-Insulated N/A Surface 112' N/A 7-5/8" Production 29.7/L-80/Btc-Mod 6.276 Surface 5,370' 0.0459 1 4-1/2" Slotted Liner"OA" 12.6/L-80/IBT 3.958 5,083' 8,332' N/A 4-1/2" SlottedLiner"OB" 12.6/L-80/IBT 3.958 5,265' 8,807' N/A TUBING DETAIL 4-1/2" Tubing 12.6/L-80/IBT-M 3.958 Surface 5,004' 0.0152 3-1/2" Tubing 9.2/L-80/NS-CT 2.992 5,004' 5,070' 0.0087 WELL INCLINATION DETAIL KOP@250'MD 30 to 50 Deg.1,200'—4,800' Max Hole Angle=99 deg. @ 8,810'MD 57 Deg.@ Sliding Sleeve JEWELRY DETAIL No Depth Item 1 2,010 Camco 4.5"x 1"KGB-2 GLM w/RP valve BK-5 Latch 2 4.953' Phoenix Discharge Pressure Gauge—ID=3.850" 3 4,970' HES 4.5"'XD'Dura Sliding Sleeve,Opens Down—ID+3.813" 4 4,990' Phoenix Sensor 4-1/2"Casing—ID Change to 2.840" 5 5,004' XO 4.5"NSCT Box x 3.5"NSCT Pin 6 5,016' XO 3.5"NSCT Pin x 4.5"NSCT Pin 7 5,018' Baker 7-5/8"x 4-1/2"S-3 Hyd set Packer—ID=3.875" 8 5,022' XO 4.5"NSCT Box x 3.5"NSCT Pin 9 5,066' HES 3.5"XN-Nipple—2.750"No Go 10 5,068 3.5"NSCT WLEG—Bottom @ 5,070'/ TVD=4,094' 11 5,089' Baker 6"Tie Back Sleeve w 12 5,097' Baker Hook Wall,Hanger above 7"Window 13 5,123' Baker Hook Wall,Hanger outside 7"Window x? 14 5,265' Baker 7-5/8"Tie Back Sleeve 15 5,272' Baker ZXP Liner Top Packer A r 16 5,279' Baker 7-5/8"x 5"HMC Liner Hanger Z84OKiln @4,9thru 0' ;z 2 LATERAL WINDOW DETAIL 2840"@4,990' ��� ,+3 s. 4 Window in 7-5/8"Casing @ 5,111'to 5,123' 5 r� Well Angle @ Window=70 Deg. GENERAL WELL INFO $ API:50-029-23100-00-00 , , , 6• ''n 7 Drilled and Completed by Doyon 141 -7/29/2002 8 ,- CTCO&R&R Jet Pump—12/27/2016 MinIDthruXN 9 . 2.750"@5,066' NOTE: ' , 10 4 .11812 One or both lateral sections contain fill. P . I.*=13 r" 6-1/8"Hole TD @ 8,745' °til -}`°'' 413'Rat Hole 14 t "CIA"Lateral 81 jts Slotted Liner 5,136'to 8,292' Tag 8,326'CTMD 7/1/2017 ,4` 16 K.. 6-1/8"Hole TD @ 8,810' i "OB'Later 90 jts Slotted Liner 5,373'to 8,805' 3'Rat Hole 7-5/8" Ns TD=8,810'(MD)/TD=4,118'(TVD) PBTD=8,810'(MD)/PBTD=4,118'(TVD) Revised By:TDF 7/7/2017 • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP 5-05 Coil 50-029-029231-00-00 202-137 7/1/17 7/1/17 Daily Operations: 6/28/2017 -Wednesday No activity to report. 6/29/2017 -Thursday No activity to report. 6/30/2017 - Friday No activity to report. 7/1/2017-Saturday Road SLB CTU #8 (1.5" CT), o Kuparuk. Road back to Milne with SLB CTU #11 (2" CT). MIRU SLB CTU#11 with 15,670' of 2" CT. CV=42.2 bbls. Perform BOPE Test. MU WFD BHA. 2.125" OD int dimple con, MHA (11/16" ball for disconnect), 2.13" OD WT x 2, 2.125" OD NOV agitator, 2.2" OD XO, 2.5"JSN. OAL= 17.85'. 9. PJSM. On well with injector. PT to 324psi/ 4,000psi. Open well to 41psi SITP. IAP = 788psi. RIH to 3500' ctmd. Wait for SLB N2 pump unit to arrive SLB N2 pump and HAL N2 Transport arrive. PJSM. RU surface and PT surface line. Start pumping N2 only at 1000 scf/m, slowly RIH. Pump 20,000 scf. Start pumping SLK 1%at 1.5 bpm/ N2 at 750 scfm and cont to RIH to TT. Establish good returns pumping 1 bpm fluid/750 scfm N2/3,600psi CTP/200psi WHP. Clean out from TT to 8,326' ctmd. (OA lateral runs to 8,332' MD).Tag at 8,326' 3 times. Maintained 1-1.5 bpm fluid rate and 750 scfm N2 rate. WHP was 260-360psi throughout with FOC. Pumped 3 x 10 bbl gel sweeps. POOH pumping same. SD fluid pump at 3,500'. SD N2 at 1,500'.Tag up at surface. L/D nozzle and MU 4-1/2" B042 shifting tool. Set up shift SS down to open. RIH and open sleeve at 4,970' MD. Good indication. IA pressure dropped from 1,000psi to Opsi. Made 3 passes to confirm full open. POOH Tag up at surface. Secure well. Remove fusible cap. L/D tools. Shifting tool not sheared. RDMO.Job Complete 252 bbls fluid pumped (60 bbls GEL)/267 bbls returns in tanks recovered with solids. 264,000 scf N2 pumped. 7/2/2017-Sunday No activity to report. 7/3/2017=Monday No activity to report. 7/4/2017-Tuesday No activity to report. • • 41,1" �//7,4. THE STATE Alaska Oil and Gas rw --s��--�� of�LAS KA Conservation Commission —-- 333 West Seventh Avenue 1. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 T4 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager SCANNED .I U 1. 0 6 20 Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU S-05 Permit to Drill Number: 202-137 Sundry Number: 317-290 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, OF Daniel T. Seamount, Jr. 1 Commissioner r. DATED this V"day of June,2017. RBDMS UvJUll 1 6 2017 • • RECEIVED STATE OF ALASKA JUN 2 0 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate El Pull Tubing ❑ Remove and Replace Jet Pump Q Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: CT Fill Clean-out❑✓ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: t Ali waltz:AJ Hilcorp Alaska LLC Exploratory ❑ Development Q ' 2.01.-/37 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic EIService ❑ 6.API Number: Anchorage Alaska 99503 50-029-23100-00-00 , 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 Q .( MILNE PT UNIT S-05 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0380110 ' 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): 8,810 ` 4,118 • 8,810 " 4,118 ' 1,700 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 84' 20" 112' 112' N/A N/A Production 5,342' 7-5/8" 5,370' 4,178' 6,890 psi 4,790 psi Liner A 3,156' 4-1/2" 8,292' 4,050' Slotted Liner Liner B 3,432' 4-1/2" 8,805' 4,119' Slotted Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic . See Schematic 4-1/2" 12.6/L-80/IBT-M 5,070' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 7-5/8"x 4.5"Premier Pkr/ZXP Liner Top Pkr and N/A . 5,018(MD)/4,073(TVD)&5,272(MD)/4,159(TVD)and N/A 12.Attachments: Proposal Summary ❑� Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development❑2 ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 6/26/2017 Commencing Operations: OIL ID WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. �Q Authorized Name: Bo York Contact Name: Stan Porhola Ste e Authorized Title: Operations Manager Contact Email: sporholatU7hilcorp.com , Contact Phone: 777-8412 Authorized Signatur-: / Date: 6/19/2017 _ COMMISSION USE ONLY Conditions of approval. otify Commission so that a representative may witness Sundry Number: 31-7- 2... .0 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ 44S j- Co t 2-1-t k l Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No ®' Subsequent Form Required: r a.- /0it RBDMS (/l- Jvi.4 L b 2017 0dr APPROVED BY (e)22. l Z Approved byj COMMISSIONER THE COMMISSION Date: ?I 6., ---)t-i7 Submit Form and OPR4/641N0A Form 10-403 Revised 4/2017f ,id for 12 months from the date of approval. Attachments in Duplicate • • Well Prognosis Well: MP S-05 EIilcari)Alaska,LL1 Date: 6/19/17 Well Name: MPU S-05 API Number: 50-029-23100-00 Current Status: Oil Well [Jet Pump] Pad: Milne Point S-Pad Estimated Start Date: June 26th, 2017 Rig: Coil Tubing Reg.Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 202-137 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: fk, Job Type: ; , rCoil Foam Cleanout Current Bottom Hole Pressure: 2,100 psi @ 4,000' TVD (Last BHP measured 12/10/2015) Maximum Expected BHP: 2,100 psi @ 4,000' TVD (No new perfs being added, EMW= 10.1 ppg) MPSP: 1,700 psi (Based on 0.10 psi/ft gas gradient) Brief Well Summary: MPU S-05 was drilled in 2002 using Doyon 141 and completed as a dual-lateral in the Schrader Bluff OA and OB sands with a Jet Pump. The well has had several jet pump change-outs but still has the original completion. Notes Regarding Wellbore Condition • Deviation at pump is 57.0°. • Deviation at upper window into the OA lateral is 71.0°. • Deviation at liner hanger into the OB lateral is 76.0°. • Casing last tested to 4,200 psi for 30 min down to 5,018'on 6/09/2014.V' • Tubing last tested to 4,200 psi for 30 min down to 4,970' on 6/09/2014.'° • Jet Pump currently inactive. Well plugged off below jet pump. • Tubing Grade is L-80. Min ID is 2.84" in the 4-1/2" and 2.75" in the 3-1/2". Objective: The purpose of this work is to pull the existing Jet Pump, cleanout one of the laterals, and run a new Jet Pump on slickline. Work Procedure: Coiled Tubing Procedure: 1. MIRU Coiled Tubing Unit and spot ancillary equipment. Fill source tank w/8.5 ppg 1% KCI. 2. Pressure test BOPE to 3,500 psi Hi 250 Low, 10 min each test. C{ a. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. b. No AOGCC notification required. c. Record BOPE test results on 10-424 form. 3. RIH w/2.00" coil and cleanout to jet pump at+/-4,970' MD (if not pulled by slickline). POOH. 4. RIH w/2.00" coil and pull jet pump at+/-4,970' MD (if not pulled by slickline). POOH. e • Well Prognosis Well: MPS-05 FIilcorp Alaska,LLI Date:6/19/17 5. RU pumping lines to inner annulus (4-1/2" x 7-5/8"). Pressure test to 3,500 psi Hi 250 Low to confirm no leaks. Bullhead filtered 8.5 ppg seawater down inner annulus (4-1/2" x 7-5/8"; at least 1 casing volume, 130.0 bbl), lifting sand/solids up the 2.0" coil x 4.5" tubing annulus. Freeze protect inner annulus (4-1/2" x 7-5/8") with 20-30 bbl of diesel before closing sleeve. a. Keep pumping down coil tubing and moving coil while bullheading thru the sliding sleeve. 6. RIH w/2.00" coil and shift sliding sleeve closed at+/-4,970' MD (if not closed by slickline). 7. Test backside to 3,500 psi for 5_min to confirmclosed,(if shifted closed by coil). POOH. 8. RIH w/2.00" coil w/2.5"to 3.5" max OD wash nozzle and extended reach cleanout BHA and cleanout to PBTD at+/-8,807' MD. POOH. a. Multi-lateral is a Baker Hughes Level 2 Hook Hanger that does not provide selective entry of the laterals, so the lateral that will be entered is unknown. V's 0 b. Circulate out fill using 8.5 ppg 1% KCI w/friction reducer. Pump 5-10 bbl Gel Sweeps to help remove solids from the liner. c. Contingency: If unable to wash down with nozzle, RIH w/3.0" to 3.5" mill and extended reach cleanout BHA and cleanout to PBTD at+/-8,807' MD. POOH. 9. RIH w/2.00" coil w/2.5"to 3.5" max OD wash nozzle and extended reach cleanout BHA and cleanout to PBTD at+/-8,807' MD. POOH. a. Circulate out fill using 8.5 ppg 1% KCI w/liquid foamer and mix with Nitrogen (see Nitrogen it/ procedure and diagram). Utilize defoamer for returns in Kill Tank. � J b. Contingency: If unable to wash down with nozzle, RIH w/3.0"to 3.5" mill and extended reach cleanout BHA and cleanout to PBTD at+/-8,807' MD using$.5 ppg 1% KCI w/liquid foamer and mix with Nitrogen. POOH. 10. RIH and shift sliding sleeve open at+/-4,970' MD (if not to be opened by slickline). 11. Pump 8.5 ppg 1% KCI or 8.4 ppg power fluid to confirm open (if shifted open). POOH. 12. PU to 2,500' and freeze protect well. POOH w/coil. �`�- te ui 13. RD Coiled Tubing and ancillary equipment. 14. Turn well over to production. -s Wireline Procedure: 4*✓S. 15. MIRU Slickline. PT lubricator to 2,000 psi Hi 250 Low. 16. RIH and set jet.pump in sliding sleeve profile at+/-4,970' MD. POOH. 17. RD Slickline. Attachments: 1. As-built Schematic 2. Coil BOPE Schematic 3. Nitrogen Operations Procedure 4. Nitrogen &Foam Flow Diagram H . • Milne Point Unit Well: MPU S-05 SCHEMATIC Last Completed: 7/29/2002 Ililcorp Alaska,LLC PTD: 202-137 TREE&WELLHEAD Tree 4-1/16"—5M FMC Wellhead 11"x 4.5"5M Gen.6 w/4.5"TC-II T&B Orig.KB=28' Tubing Hanger CIW"H"BPV Profile 20 I OPEN HOLE/CEMENT DETAIL 20" Cmt w/260 sx of Arcticset(Approx)in 42"Hole 7" _ Cmt w/1,060 sx Class PF"L",280sx Glass"G"in 9-7/8"Hole 4-1/2" Uncemented Liner in a 6-1/8"Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20"x 34" Conductor 215/A-53-Insulated N/A Surface 112' N/A 7-5/8" Production 29.7/L-80/Btc-Mod 6.276 Surface 5,370' 0.0459 1 4-1/2" Slotted Liner"OA" 12.6/L-80/IBT 3.958 5,083' 8,332' N/A 4-1/2" SlottedLiner"OB" 12.6/L-80/IBT 3.958 5,265' 8,807' N/A E TUBING DETAIL 4-1/2" Tubing 12.6/L-80/IBT-M 3.958 Surface 5,004' 0.0152 ' p5' 3-1/2" Tubing 9.2/L-80/NS-CT 2.992 5,004' 5,070' 0.0087 1 P ,t Z WELL INCLINATION DETAIL � � / /o `'lI ��"'� KOP @ 250'MD VGIi� •Y� 30 to 50 Deg.1,200'—4,800' '1 Max Hole Angle=99 deg. @ 8,810'MD 57 Deg.@ Sliding Sleeve JEWELRY DETAIL No Depth Item 1 2,010 Camco 4.5"x 1"KGB-2 GLM w/RP valve BK-5 Latch 2 4.953' Phoenix Discharge Pressure Gauge—ID=3.850" 3 4,970' HES 4.5"'XD'Dura Sliding Sleeve,Opens Down—ID+3.813" E 4 4,990' Phoenix Sensor 4-1/2"Casing—ID Change to 2.840" 5 5,004' XO 4.5"NSCT Box x 3.5"NSCT Pin 6 5,016' XO 3.5"NSCT Pin x 4.5"NSCT Pin 7 5,018' Baker 7-5/8"x 4-1/5"S-3 Hyd set Packer—ID=3.875" 8 5,022' XO 4.5"NSCT Box x 3.5"NSCT Pin i 9 5,066' HES 3.5"XN-Nipple—2.750"No Go 10 5,068 3.5"NSCT WLEG—Bottom @ 5,070'/ TVD=4,094' 11 5,089' Baker 6"Tie Back Sleeve 12 5,097' Baker Hook Wall,Hanger above 7"Window 13 5,123' Baker Hook Wall,Hanger outside 7"Window 14 5,265' Baker 7-5/8"Tie Back Sleeve 15 5,272' Baker ZXP Liner Top Packer Min IDthrutubing a' 2 16 5,279' Baker 7-5/8"x 5"HMC Liner Hanger 2.840"@4,990 4' hoo,t 3 LATERAL WINDOW DETAIL Window in 7-5/8"Casing @ 5,111'to 5,123' '± wow 4 Well Angle @ Window=70 Deg. N7 5 GENERAL WELL INFO API:50-029-23100-00-00 Drilled and Completed by Doyon 141 -7/29/2002 '8 CTCO&R&R Jet Pump—12/27/2016 Kin IDthru XN 2.750"@5,066' i-- • NOTE: 10 11&12 One or both lateral sections contain fill. 13 6-1/8"Hole TD @ 8,745' 14 "0A Lateral 81 jts Slotted Liner 5,136'to 8,292' 413'Rat Hole 15 ` G-l1 16 1 0 6-1/8"Hole TD @ 8,810' /K._ I %B.Litera 90 jts Slotted Liner 5,373'to 8,805' 3'Rat Hole 7-5/8" \ Ns TD=8,810'(MD)/TD=4,118'(TVD) PBTD=8,810'(MD)/PBTD=4,118'(TVD) Revised By:TDF 1/21/2016 • • II Milne Point Unit COIL BOPE MPU S-05 6/19/2017 ltik.wp 'tia.ka.11A, MPU 5-05 20 X 7% X 4'% Coil Tubing BOP Amon. ILubricator to injection head EIIIIIIIIIIIIIIIII —M 2.00"Single Stripper •',I, Blind/Shear 4 1/16 10 =-Blind/Shear ,I, a .',I,I Blind/Sheaini- Blind/Shear 111E1 11„,11 G. 042Mg �� E_ ——_ Slip -- Slip .'114 r €= -— Pipe -® Pipe 1111 fos •1. Crossover spool 4 1/16 10M X4 1/16 5M .---4 af; E.Pump-In Sub a' c = � ; 4 1/16 5M ilV°., ; - g l° i ; MIN� 1502 Union 1 Manual Gate Manual Gate "lrValve,Swab,WKM-M, ,,( -,04if 2 1/8 5M 2 1/8 5M 4 1/16 5M FE • \le 77 �_, ...v. a1� C1--k 1N— C ) Valve,Upper Master,Baker, 4 1/16 5M FE,w/Hydraulic 1.411. Valve,Lower Master,WKM-M, �p e..'7'.?„4. ' 4 1/16 5M FE 111 �MW Tubing Adapter,41/16 5Mz • STANDARD WELL PROCEDURE ilikorp Alaska,LLC NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 • • T1414 1JasMI h•. . • O > L , .' > 9 F F E ...1 w 0 u Y w g cc i w > ai a° Y W 83400E ° 3a0u2 IF!LL ' LL � La19illXZZO a : .1":)Z j co co b d • a rd ° Ua 0 tel i•• w > Cai r aUWC) "I r 10111ka Q. r - r x v tt D3x ta L L I, •• V '. ç4i �'. .e,'�' ° °t o 1 'Nhillirk‘'' • t 11 IIUI1111111 o a • C m.. 4�. .,.iii 1- 4 fit .I. . 11 4+ VAI^�� j11Yii..1 Ill iiiiiij CC N Z w Q H i w U ii O C m m ~w O K LP -.2 a V 01 Z No- ce ce z w w Q Q Q 0 Z w w Q 0 r F- Y I m _V 0 K O a o D in 0 0 0 0 V. STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations Li Fracture Stimulate ❑ Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change-out Jet Pump ❑✓ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑., Re-enter Susp Well ❑ Other: CT Fill Clean-out ❑Q 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development 0 Exploratory ❑ 202-137 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-23100-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0380110 MILNE PT UNIT SB S-05 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL JAN 2 ✓ 2016 11.Present Well Condition Summary: OGCC Total Depth measured 8,810 feet Plugs measured N/A feet true vertical 4,118 feet Junk measured N/A feet 5,018' Effective Depth measured 8,810 feet Packer measured 5,272 feet 4,073 true vertical 41,148 feet true vertical 4,159 feet Casing Length Size MD TVD Burst Collapse Conductor 84' 20" 112' 112' N/A N/A Production 5,342' 7-5/8" 5,370' 4,175' 6,890psi 4,790psi Liner A 3,156' 4-1/2" 8,298' 4,050' Slotted Liner Liner B 3,432' 4-1/2" 8,805' 4,119' Slotted Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80/IBT-M 5,070' 4,095' 7-5/8"x 4.5"Premier Packers and SSSV(type,measured and true vertical depth) ZXP Liner Top 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: 129 292 132 3,231 235 Subsequent to operation: 495 209 162 3,202 232 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory': Development LI Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas Li WDSPL Li Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-751 Contact Ted Kramer deo- Email tkramer(cDhilcorp.com Printed Name Bo York Title Operations Engineer Signature 7 / Phone 777-8345 Date 1/21/2016 74- /—;ZS—R 4' Form 10-404 Revised 5/2015 AAM L'- JAN 2 2 2014 Submit Original Only /moi 2f�1�6 . fir • • Milne Point Unit Well: MPU S-05 SCHEMATIC Last Completed: 7/29/2002 Mean)Alaska,LLC PTD: 202-137 TREE&WELLHEAD Tree 4-1/16"—5M FMC Wellhead 11"x 4.5"5M Gen.6 w/4.5"TC-II T&B Orig.KB=28' Tubing Hanger CIW"H"BPV Profile tir OPEN HOLE CEMENT DETAIL 20' ; ( 20" Cmt w/260 sx of Arcticset(Approx)in 42"Hole 7" Cmt w/1,060 sx Class PF"L",280sx Glass"G"in 9-7/8"Hole 4-1/2" Uncemented Liner in a 6-1/8"Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20"x 34" Conductor 215/A-53-Insulated N/A Surface 112' N/A 7-5/8" Production 29.7/L-80/Btc-Mod 6.276 Surface 5,370' 0.0459 4-1/2" Slotted Liner"OA" 12.6/L-80/IBT 3.958 5,083' 8,332' N/A 4-1/2" SlottedLiner"OB" 12.6/L-80/IBT 3.958 5,265' 8,807' N/A TUBING DETAIL 4-1/2" Tubing 12.6/L-80/IBT-M 3.958 Surface 5,004' 0.0152 3-1/2" Tubing 9.2/L-80/NS-CT 2.992 5,004' 5,070' 0.0087 WELL INCLINATION DETAIL KOP@250'MD 30 to 50 Deg.1,200'—4,800' Max Hole Angle=99 deg. @ 8,810'MD 57 Deg.@ Sliding Sleeve JEWELRY DETAIL No Depth Item 1 2,010 Camco 4.5"x 1"KGB-2 GLM w/RP valve BK-5 Latch 2 4.953' Phoenix Discharge Pressure Gauge—ID=3.850" 3 4,970' HES 4.5"'XD'Dura Sliding Sleeve,Opens Down—ID+3.813" 4 4,990' Phoenix Sensor 4-1/2"Casing—ID Change to 2.840" 5 5,004' XO 4.5"NSCT Box x 3.5"NSCT Pin 6 5,016' XO 3.5"NSCT Pin x 4.5"NSCT Pin 7 5,018' Baker 7-5/8"x 4-1/5"S-3 Hyd set Packer—ID=3.875" 8 5,022' XO 4.5"NSCT Box x 3.5"NSCT Pin 9 5,066' HES 3.5"XN-Nipple—2.750"No Go 10 5,068 3.5"NSCT WLEG—Bottom @ 5,070'/ TVD=4,094' 11 5,089' Baker 6"Tie Back Sleeve 0 0 12 5,097' Baker Hook Wall,Hanger above 7"Window `; 13 5,123' Baker Hook Wall,Hanger outside 7"Window . 14 5,265' Baker 7-5/8"Tie Back Sleeve ," '' 15 5,272' Baker ZXP Liner Top Packer Mn IDthrutubing"� 2 16 5,279' Baker 7-5/8"x 5"HMC Liner Hanger 2.840"@4,990' v, ,,, +'3 LATERAL WINDOW DETAIL r air Window in 7-5/8"Casing @ 5,111'to 5,123' t a # 4 5 Well Angle @ Window=70 Deg. GENERAL WELL INFO 1,' API:50-029-23100-00-00 6 l 7 Drilled and Completed by Doyon 141 -7/29/2002 8 u CTCO&R&R Jet Pump—12/27/2016 AM10Misoll N 9 g NOTE: s7l/over 10 11&12 One or both lateral sections contain fill. , !;13 6-1/8"Hole TD @ 8,745' E }<114 "OA"Lateral 81 jts Slotted Liner 5,136'to 8,292' 413'Rat Hole '+ 15 16 6-1/8"Hole TD @ 8,810' L tor Wird 90 jts Slotted Liner 5,373'to 8,805' 3'Rat Hole 7-5/8 TD=8,810'(MD)/TD=4,118'(TVD) PBTD=8,810'(MD)/PBTD=4,118'(TVD) Revised By:TDF 1/21/2016 • . Hilcorp Alaska, LLC HiIcorj,Alaska,LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MPS 05 Coil 50-029-23100-00-00 202-137 12/23/2015 12/27/2015 -+s- w 12/23/15' ednesday 40 afi� ';� � - Fire equipment. Hold safety meeting. Discuss job procedure/steps and review SLB JSA.RDMO from S-34 and move to S-05. Unload 300 bbls of sea water from upright tank to vac truck. Move uprights,choke,return and 50 bbl meth tank. Rig up CTU#4. -55 with windchill. Hot oil will heat our 300 bbls of water tomorrow. BOPE test in AM. Wellsite secure. Crews off location. 124/15-Thursday .= d„' " a ""` 7,1r iia Fire equipment. Hold safety meeting. Review SLB JSA. -27 degrees,-54 with windchill.Pick injector head and stab 10'lubricator. Make up dimple connector,pull test 20k. Make up no-go nozzle.Stab on well. Start PT.Small leak in pack off. Blow down stack. Pop off well. Change pack offs. Packs off changed. Stab 10'lubricator. Stab on well. Back to Starting BOP test.2.5 hrs NPT taken off ticket for the day.Fluid pack coil. Start BOPE test. AOGCC 24 hr notification sent 12/22/15 @ 19:34. Witness waived by Jeff Jones on 12/22/15 @ 19:48. Start low PT on full body,inner reel valve at 268 psi. 260 psi after 10 minutes. GOOD test. Coming up for high PT full body/inner reel valve,bypass choke valve and rear gate valves on choke. High PT 4600 psi end 10 minutes 4502 psi. Close Top set B/S. Low PT Top set B/S 298 psi.287 psi after 10 minutes. Coming up for high PT. 4600 psi end 10 minutes 4487 psi. Bleed down. Close second set B/S. Low PT. 292 psi after 10 minutes 283 psi. Coming up for hi PT. 4900 psi end 4825 psi after 10 minutes. Low PT pipe rams 277 end 267 after 10 min. High PT pipe rams.4630 psi 4555 psi after 10 minutes. All EQ ports tested. Bleed down pop off.Popping off injector head. Pressure tested MHA to 3500 psi. No leaks. Bleed down. BHA: 2.0"Internal Dimple connector,2.13"DFCV,2.15"Jars,2.125"Hyd Disco,2.7"X over,3.625"Hyd GS pulling tool. Total BHA length 11.83'. Stab on well. Pressure test lubricator 250/3500 psi.Circulate out diesel and 60/40 with 150 degree water at surface. Master swab open RIH. Wt check 4500' 18k weight. 57 bbls away. Coming online at max rate. Well is holding column of fluid. Pumping 1.7 bbls/min @ 3500 psi. Tagged at 4950'. Pump total 80 bbls away. PU weight 21k up weight. Clean. Did not tag fill. Pump from upright until 156 bbls for bottoms up.5k overpull. Latched into Jet pump. Stack back down to circulate freeze protect. 120 total bbls of seawater pumped. Online with diesel/methanol from methanol tank.POOH. Coil is freeze protected. PU to 31k 17k over pull to release GS. At surface. Swab closed 23.5 turns. Blow down stack. Popping off. Pump retrieved. Swap GS with B042 shifting tool. Stabbed on well. Low PT 250. High PT 3800 psi. Open well and RIH. Online with little red down back side. CT depth 4500'. 5 bbls 60/40 then 30 bbls diesel. Weight check 4800',14.5K. Stacking weight at 4961'. Pick up. Online with Little red down. IA. 2 bbls min with diesel. IA and tubing pressure 3000 psi. Believed to be sanded up right below jet pump profile and sleeve. Bleed down tubing through choke. LRS back online for freeze protect IA. Picking up from 4974'.PU to shift sleeve from 4974'. Picked up to 27k, weight broke back to 18k. POOH. Online down backside. Sleeve is closed. 1500 psi and climbing. 3600 psi on IA. Down on pump. Closing in wing valve at tree. Start 10 minute test 3628 psi @ 20:18. 10 minute test 20:30 end pressure 3643 psi. Bleeding back to LRS. Pressure increased due to variations of fluid temperature.Tagged up at surface. LRS hooked up to CTS unit on back side line. PT lines to 250/4500 psi. Online down tubing for freeze protect. 13 bbls of 60/40 pumped down tubing for freeze protect. Close master swab. Blow down stack. Pop off well. Rig up BHA motor mill with 2.73 Mill. 156 bbls pumped for job. Set injector head on back deck. Install night cap. Location secure n l �i 1 � 12/25/15 Friday y a y �' 3P1'' "i Pi° l j') Power pack won't start. Hold safety meeting. Disucss JSA and job procedure. Power pack fired up.Check for no flow. Remove night cap. Pick injector head. Stab on well. Pressure test stack. 250/3500 psi.RIH with following BHA. 2.0"Internal Dimple Connector,2.125"DFCV,2.125"DA Hyd jar,2.125" Hyd Disconnect,2.125"Circ Sub,2.125"titan Motor,2.72"Junk mill. Total BHA 22.91'.Wt check at 4500'15.2k. Still circulating freeze protect out of coil at 0.5 bbls/min. Down on pump. RIH to dry tag. Tagged 4k down at 5100'. PU 20.5k. Online with water at 1.75 bbls/min to obtain free spin. 2800 psi free spin motor work at 5378'2950 psi.Getting 1.75 bbls/min back to return tank. Made it to 7000'. Returns stopped. Pulling up to tubing tail. Circ pressure dropped from 2800 psi at 1.75 bbls/min to 2200 psi at 1.75 bbls min when returns stopped. Parked at 4800'.Online with water down backside 4 1/2 in tubing. 4.8 bbls/min down backside. No increase in WHP. Attempt injection down back side at 5 bbls min. No increase in WHP. Freeze protect coil while POOH.45 bbls of 60/40 pumped. Tagged up at surface. RD motor and Mill. Install weight bar and Abrado nozzle. Pigging tank in place. 322 bbls of seawater pumped for FCO. • • Hilcorp Alaska, LLC leorp Alaska,LU: Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MPS-05 Coil 50-029-23100-00-00 202-137 12/23/2015 12/27/2015 i2/2015 LL Saturday hl4 9 191 4; � m Fire equipment. Hold safety meeting. Discuss job steps and review SLB JSA. No flow night cap. Pop off. Stab on well.Low PT 250/High PT 3500. Good test. Bleed down. Open to 50 bbl meth tank. Circulate out freeze protect with slick urn. BHA conisists of following: 2.0"Internal Dimple,2.125"DFCV, 2.125"DA hyd jar,2.125 Hyd Disco,2.125 Circ Sub,2.125"weight bar,2.0 x over,2.65"Centralizer,1.5"Abrado Oscillator. Circulate out 60/40 to open top tank with Seawater/slickum. Having problems with power end knocking.Not able to pump fluid. 10 bbls of water in reel. Swapped back to 60/40 to freeze protect.Pump back up working. (Tightened pony rods on power end)4hrs NPT SLB time. Master swab open 23.5 turns. RIH at 5200'. Lined up on water. 18k. RIH at 8335'.Picked up 100'. RIH tag at 8335'. Not washing off. Wash at 2.5 bbls min up to 7000'.156 bbls of water pumped. Tagged up at surface. Swab master closed 23.5 turns. Blow down stack. Pop off. Rig down nozzle. Make up Shifting tool. Shoulder facing down to open.Stab on well. PT 250/3500. PU weight 16.5K @ 4950'. RIH to shift sleeve. Tag sleeve at 4980'. IA pressure 56 psi. Sleeve shifted IA went to-40 psi.POOH. At surface. Bleed down. Blow down. Pop off. Change out BO42 sleeve shifting tool. Make up jet pump. Serial#BP-1069 Pump size 8-A. Stab on well. PT 250/3500 psi. Swab open 23.5 turns.RIH.PU wt 4850'. 14k. RIH stack weight at 4974'stack weight. Stack to 4976.1'. Pick up 11.3k. Back down. 4976.1'. PU stack back down to 4977.6'. 20k down. 4977.7'. Stack again-10k. Pick up to neutral weight. Come online with pump to stroke jars open. 1.7 bbls/min 17 bbls pump. Down on pump. Stack to-10. Wait for jar lick. Pick up to 4973.8'. Online to open jars. 2 bbls pumped.Down to-20k for jar lick. 4978.8' jar lick down. 2nd jar lick online with water at 2 bbls/min for hammer. 4974.5'stall hammer 4950psi. Pick up neutral. Online with pump to stroke jars open. 2 great down jars. Pick up to 32k. Wait for up lick. Bottom sub set. 37 bbls away swapped water down back side. Pooh jet pump set. Freeze protect coil. 5 bbl/min backside WHP increase. Indicates pump set.Tagged up at surface. Close master. Pressure up to see if wing valve ism holding. Informed operator 1800 psi applied. He will look at trending to confirm PT. Bleed down.Blow down. Pop off. No jet pump at surface. Break down tools. Night cap installed. Lubricator on deck. Injector head on deck. Welliste secure. Crews off location. Will RDMO to S-08 in AM. 210 bbls pumped for day. 12/27/15-Sunda �« p� y ;�;,' I. I Fire equipment. Hold safety meeting. Discuss job procedure and review JSA. Pick injector head.Stab 30'lubricator. Make up BHA as following. 2.0" Internal Dimple,2.125 DFCV,2.125"accelerator,2.125"weight bar,2.125 Hyd jars,2.125 Disco,2.125 4in GS. Total tool lenght 22'. Stab on well. PT 250/3500 psi. LRS load pups with 60 bbls of 60/40 methanol. Pressure test good. Bleed down to 50 bbl meth tank. Open well master and swab and RIH. When RIH we had 100 psi WHP. Bleed down to tank and it was all gas. Shut in P-sub and continue RIH to 4805'.PU wt 17k. RIH to latch fish. RIH weight 8870 lbs. 4970'is where jet pump should be. Stack weight at 4972'. Set down 8k. Pick up. Not latched. Stack down 18k. Pick up 20k. 3k over pull. Not much over pull but looks like we have fish. POOH.At surface. Master swab closed 23.5 turns. Blow down pop off. Fish recovered. Redress Jet Pump. Remove Hammers from tool string. Make up Jet pump. Stab on well. PT 250/3500 psi. Good test.Bleed down. Pump 60/40 to meth holding tank. Open well RIH. Online with pump for fluid pack at 4900'. Fluid pack. 21k wt. RIH at 50 ft/min. Tagged at 4974'. Stack to-15k. Wait for jar lick. No lick. Pick up to cock jars. Pick up to 4975.1'recock jars. 2800 psi. RIH stack weight. Pick up to 21.5k. Online 2800 psi 2.5 bbls/min attempt to reset jars. Stack down to-20k. Wait on 3rd jar lick attempt.Work pipe up and down waiting on fluid. Stacked down to 4979.4'. Vac truck here giving us 80 bbls of water. Perform 4 good down jar licks. Attempt to over pull on bottom steel pin. Only 4k over pull. Feels like we still have pump. Continue to RIH and stack 30k down. PU. Online with fluid 2.5 bbls min. Reset jars. 4 good down jar licks. Pick up no overpull. Decided to POOH to see what we have.Attempt to bullhead down tubing to see if we can catch fluid. 30 bbls pumped and WHP increase to 500 psi. Down on pump. WHP bleeds right off. POOH at surface. Close swab. Blow down pop off. No jet pump on bottom of SL setting tool. (z-line setting tool). Looks like all pins sheared. Contact pad op to bring well on. Stack down lubricator. Injector head on deck. Crews off location. Wellsite secure. ER - iI 12/28/15 I( Iuii a s ' _ 11041, ,md'P No Operations to Report. 12/29/15-Tuesday p .. . , i li ii II Ilt ilii 'it 1(ii II No Operations to Report. OF T • • �w\"�\����,S THE STATE Alaska Oil and Gas • of LASKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 .,;, Main: 907.279.1433 OF ALAS' Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager B Aet 2—VWOOD I �-- 137 Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB S-05 Sundry Number: 315-751 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this /S day of December, 2015 Encl. RBDMSLADEC 211015 • RECEIVED • STATE OF ALASKA DEC 15 Z,015 ALASKA OIL AND GAS CONSERVATION COMMISSION 05 L 2//if /5--- APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well El- Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. CT Fill Clean-out❑✓ • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC , Exploratory ❑ Development Q, 202-137 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK,99503 50-029-23100-00-00• 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 SB S-05 . 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL03801 10 - 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): 8,810 4,118 - 8,810 4,118 ' 1,700 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 84' 20" 112' 112' N/A N/A Surface Production 5,342' 7-5/8" 5,370' 4,178' 6,890 psi 4,790 psi Liner A 3,156' 4-1/2" 8,292' 4,050' Slotted Liner Liner B 3,432' 4-1/2" 8,805' 4,119' Slotted Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 4-1/2" 12.6/L-80 I IBT-M 5,070' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 7-5/8"x 4.5"Premier Pkr/ZXP Liner Top Pkr and N/A 5,018(MD)/4,073(TVD)&5,272(MD)/4,159(TVD)and N/A 12.Attachments: Proposal Summary ❑✓ Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic ❑ Development 2 , Service ❑ 14.Estimated Date for 15.Well Status after proposed work: , 12/28/2015 ❑ ❑ WDSPL ❑ Suspended ❑ Commencing Operations: OIL - WINJ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact STAN PORHOLA Email sporholata hilcorp.com Printed Name BO YORK Title OPERATIONS MANAGER _ is i';')ti., I„ Signature,,,rn7t- Phone 907-777-8345 Date 1204/-2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. '5 Cr Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: ;IL L{50e..), p 1$O F' ( EE'- J 1--- ( j S23 Z) P C S, ,b.a ee '-•--4A-4--) Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Le Subsequent Form Required: /0 4/ 0 5/ (1) APPROVED BY Approved by: P J � COMMISSIONER THE COMMISSION Date: /2 -{ p �i L 1/20 5` .7-0 Rj8aIitc1ti � Submit Form and Form 1003 Revised 11/2015 r valid for 12 onths from the date of approval. Attachments in Duplicate RBDMS LAIEC 11X1015 / �/�rr • • Well Prognosis Well: MPU S-05 Hilcorp Alaska,LL) Date: 12/14/2015 Well Name: MPU S-05 API Number: 50-029-23100-00 Current Status: SI Oil Well [Jet Pump] Pad: Milne Point S-Pad Estimated Start Date: December 28th, 2015 Rig: Coil Tubing Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 202-137 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: Current Bottom Hole Pressure: 2,100 psi @ 4,000' TVD (Last BHP measured 12/10/2015) Maximum Expected BHP: 2,100 psi @ 4,000' TVD (No new perfs being added, EMW= 10.1 ppg), MPSP: 1,700 psi (Based on 0.10 psi/ft gas gradient) Brief Well Summary: MPU S-05 was drilled in 2002 using Doyon 141 and completed as a dual-lateral in the Schrader Bluff OA and OB sands with a Jet Pump. The well has had several jet pump change-outs but still has the original completion. Notes Regarding Wellbore Condition • Deviation at pump is 57.0°. • Deviation at upper window into the OA lateral is 71.0°. • Deviation at liner hanger into the OB lateral is 76.0°. • Casinglt tested to 4,200 psi for 30 min down to 5,018' on 6/09/2014. • Tubing last tested to 4,200 psi for 30 min down to 4,970' on 6/09/2014. • Jet Pump currently inactive. Well plugged off below jet pump. • Tubing Grade is L-80. Min ID is 2.84" in the 4-1/2" and 2.75" in the 3-1/2". Objective: The purpose of this work is to pull the existing Jet Pump, cleanout one of the laterals, and run a new Jet Pump on slickline. Brief Procedure: Coiled Tubing Procedure: 1. MIRU Coiled Tubing Unit and spot ancillary equipment. Fill source tank w/8.5 ppg seawater. 2. Pressure test BOPE to 4,500 psi Hi 250 Low, 10 min each test. —''l /Jt' i :j„sem e a. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. 0K-- 3. Contingency:: If jet pump not previously pulled on slickline. a. RIH w/2.00" coil w/wash nozzle and cleanout fill down to Jet Pump at+/-4,970' MD. POOH. b. RIH w/2.00" coil w/GS pulling tool and pull Jet Pump at+/-4,970' MD. POOH. 4. RIH w/2.00" coil w/shifting tool and spot tools below sliding sleeve at+/-4,970' MD. l' is to-�� • • Well Prognosis Well: MPU S-05 Ililcurp Alaska,LL1 Date: 12/14/2015 5. RU pumping lines to inner annulus (4-1/2" x 7-5/8"). Pressure test to 4,500 psi Hi 250 Low to confirm no leaks. Bullhead filtered 8.5 ppg seawater down inner annulus (4-1/2" x 7-5/8"; at least 1 casing volume, 130.0 bbl), lifting sand/solids up the 2.0" coil x 4.5" tubing annulus. Freeze protect inner annulus (4-1/2" x 7-5/8") with 20-30 bbl of diesel before closing sleeve. a. Keep pumping down coil tubing and moving coil while bullheading thru the sliding sleeve. 6. Shift sliding sleeve closed at+/-4,970' MD.Test casing to 3,500 psi for 10 min. POOH. 7. RIH w/2.00" coil w/2.5" to 2.75" max OD wash nozzle and extended reach cleanout BHA and cleanout to PBTD at+/-8,807' MD. POOH. L� a. Multi-lateral is a Baker Hughes Level 2 Hook Hanger that does not provide selective entry of the laterals, so the lateral that will be entered is unknown. b. Min ID is 2.750" (3-1/2" XN-Nipple) in tubing tail. c. Circulate out fill using 8.5 ppg seawater w/friction reducer. Pump 5-10 bbl Gel Sweeps to help remove solids from the liner. d. Contingency:_If unable to circulate fluid to surface without significant losses (<50% returns or little N E) to no solids circulated to surface). Circulate out fill using 8.5 ppg seawater w/liquid foamer and mix Z) with Nitrogen (see Nitrogen procedure and diagram). 8. Contingency: If unable to cleanout fill w/wash nozzle, RIH w/2.00" coil w/2.5" to 2.75" max OD motor and mill and extended reach cleanout BHA and cleanout to PBTD at+/-8,807' MD. POOH. a. Circulate out fill using 8.5 ppg seawater w/friction reducer. Pump 5-10 bbl Gel Sweeps to help remove solids from the liner. b. Contingency: If unable to circulate fluid to surface without significant losses (<50% returns or little to no solids circulated to surface). Circulate out fill using 8.5 ppg seawater w/liquid foamer and mix with Nitrogen (see Nitrogen procedure and diagram). 9. RIH w/2.00" coil w/shifting tool and shift sliding sleeve open at+/-4,970' MD. 10. PU to 2,500' and freeze protect well. POOH w/coil. 11. RD Coiled Tubing and ancillary equipment. 12. Turn well over to production. Wireline Procedure: 13. MIRU Slickline. PT lubricator to 2,000 psi Hi 250 Low. 14. RIH and Set iet pump in sliding sleeve profile at+/-4,970' MD. POOH. 15. RD Slickline. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. Coil BOPE Schematic 4. Nitrogen Operations Procedure 5. Fill Cleanout w/ Nitrogen Diagram H . • Milne Point Unit Well: MPU S-05 SC H E M ATI C Last Completed: 7/29/2002 nl Ita• t,� .�>>:�,t.t.c PTD: 202-137 TREE&WELLHEAD Tree 4-1/16"-5M FMC Wellhead 11"x 4.5"5M Gen.6 w/4.5"TC-II T&B Orig.KB=28' Tubing Hanger CIW"H"BPV Profile OPEN HOLE/CEMENT DETAIL 20" Cmt w/260 sx of Arcticset(Approx)in 42"Hole 2O"-j , : 7" Cmt w/1,060 sx Class PF"L",280sx Glass"G"in 9-7/8"Hole 4-1/2" Uncemented Liner in a 6-1/8"Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20"x 34" Conductor 215/A-53-Insulated N/A Surface 112' N/A 7-5/8" Production 29.7/L-80/Btc-Mod 6.276 Surface 5,370' 0.0459 it 1 4-1/2" Slotted Liner"OA" 12.6/L-80/IBT 3.958 5,083' 8,332' N/A 4-1/2" SlottedLiner"OB" 12.6/L-80/IBT 3.958 5,265' 8,807' N/A TUBING DETAIL 4-1/2" Tubing 12.6/L-80/IBT-M 3.958 Surface 5,004' 0.0152 3-1/2" Tubing 9.2/L-80/NS-CT 2.992 5,004' 5,070' 0.0087 i WELL INCLINATION DETAIL [ KOP @ 250'MD 30 to 50 Deg.1,200'—4,800' Max Hole Angle=99 deg. @ 8,810'MD 57 Deg.@ Sliding Sleeve JEWELRY DETAIL No Depth Item 1 2,010 Camco 4.5"x 1"KGB-2 GLM w/RP valve BK-5 Latch 2 4.953' Phoenix Discharge Pressure Gauge—ID=3.850" 3 4,970' HES 4.5"'XD'Dura Sliding Sleeve,Opens Down—ID+3.813" 4 4,990' Phoenix Sensor 4-1/2"Casing—ID Change to 2.840" 5 5,004' XO 4.5"NSCT Box x 3.5"NSCT Pin 6 5,016' XO 3.5"NSCT Pin x 4.5"NSCT Pin 7 5,018' Baker 7-5/8"x 4-1/5"S-3 Hyd set Packer—ID=3.875" 8 5,022' XO 4.5"NSCT Box x 3.5"NSCT Pin 9 5,066' HES 3.5"XN-Nipple—2.750"No Go 10 5,068 _ 3.5"NSCT WLEG—Bottom @ 5,070'/ TVD=4,094' 11 5,089' Baker 6"Tie Back Sleeve 12 5,097' Baker Hook Wall,Hanger above 7"Window 13 5,123' Baker Hook Wall,Hanger outside 7"Window 14 5,265' Baker 7-5/8"Tie Back Sleeve 15 5,272' Baker ZXP Liner Top Packer Mn IDthrutubing 2 16 5,279' Baker 7-5/8"x 5"HMC Liner Hanger mi 2840"@4,990' ; H . . Milne Point Unit Well: MPU S-05 • PROPOSED Last Copleted: 7/29/2002 nilcorp Alaska,LLf.. PT : 202m137 TREE&WELLHEAD Tree 4-1/16"–5M FMC _ Wellhead 11"x 4.5"5M Gen.6 w/4.5"TC-II T&B Orig.KB=28' Tubing Hanger CIW"H"BPV Profile 4 : ki OPEN HOLE/CEMENT DETAIL 22., 20" Cmt w/260 sx of Arcticset(Approx)in 42"Hole 7" Cmt w/1,060 sx Class PF"L",280sx Glass"G"in 9-7/8"Hole l 4-1/2" Uncemented Liner in a 6-1/8"Hole ` CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF r r 20"x 34" Conductor 215/A-53-Insulated N/A Surface 112' N/A 7-5/8" Production 29.7/L-80/Btc-Mod 6.276 Surface 5,370' 0.0459 1 4-1/2" Slotted Liner"OA" 12.6/1-80/IBT 3.958 5,083' 8,332' N/A 4-1/2" SlottedLiner"OB" 12.6/L-80/IBT 3.958 5,265' 8,807' N/A TUBING DETAIL 4-1/2" Tubing 12.6/L-80/IBT-M 3.958 Surface 5,004' 0.0152 3-1/2" Tubing 9.2/L-80/NS-CT 2.992 5,004' 5,070' 0.0087 WELL INCLINATION DETAIL KOP@250'MD 30 to 50 Deg.1,200'–4,800' Max Hole Angle=99 deg. @ 8,810'MD 57 Deg.@ Sliding Sleeve JEWELRY DETAIL No Depth Item 1 2,010 Camco 4.5"x 1"KGB-2 GLM w/RP valve BK-5 Latch 2 4.953' Phoenix Discharge Pressure Gauge–ID=3.850" _ 3 4,970' HES 4.5"'XD'Dura Sliding Sleeve,Opens Down–ID+3.813" 4 4,990' Phoenix Sensor 4-1/2"Casing–ID Change to 2.840" 5 5,004' XO 4.5"NSCT Box x 3.5"NSCT Pin 6 5,016' XO 3.5"NSCT Pin x 4.5"NSCT Pin 7 5,018' Baker 7-5/8"x 4-1/5"S-3 Hyd set Packer–ID=3.875" 8 5,022' XO 4.5"NSCT Box x 3.5"NSCT Pin 9 5,066' HES 3.5"XN-Nipple–2.750"No Go 10 5,068 3.5"NSCT WLEG–Bottom @ 5,070'/ TVD=4,094' 11 5,089' Baker 6"Tie Back Sleeve 12 5,097' Baker Hook Wall,Hanger above 7"Window 10 13 5,123' Baker Hook Wall,Hanger outside 7"Window 14 5,265' Baker 7-5/8"Tie Back Sleeve s r 15 5,272' Baker ZXP Liner Top Packer Mn IDthrutubing a 2 16 5,279' Baker 7-5/8"x 5"HMC Liner Hanger 2.840"@4,990' ' I,0 1043 New Jet Pump LATERAL WINDOW DETAIL $# Im` 1,4 Window in 7-5/8"Casing @ 5,111'to 5,123' {r -' 5 is Well Angle @ Window=70 Deg. �' GENERAL WELL INFO 1' I.,I API:50-029-23100-00-00 6 7 Drilled and Completed by Doyon 141 -7/29/2002 MinIDthruXN 8 2.750'@5,066' 9 a 10 44 4 141 ,,,,, 11 612 kn 6-yr Hole TD @ 8,745' L t fit , " •Ok Lateral 81 jts Slotted Liner 5,136'to 8,292' 413'Rat Hole 14 15 , 16 r 6-1/8"Hole TD @ 8,810' r "08'Later 90 jts Slotted Liner 5,373'to 8,805' 3'Rat Hole 7-5/8" NE TD=8,810'(MD)/TD=4,118'(TVD) PBTD=8,810'(MD)/PBTD=4,118'(1VD) Revised By:TDF In Progress • • Milne Point Unit COIL BO PE MPU S-05 12/10/2015 Ho,.,I, ‘3,.1.:, Tic MPU S-05 20 X7% X 4% Coil Tubing BOP ms's Lubricator to injection head 0 # l i J 2.00"Single Stripper l 1 1 f _ (� J•'��� Blind/Shear= 1/1610 !:6hmnd/5h ear ,','•.'] –00100 11101101111, •',I,I Blind/Shear 11. !�Blind/Shearl,L'•o �r owe 1( C_ —— Slip MinSlip111 -- ski 11111 Pipe �� st- 5 Pipe 'I i• i1 1C i ii Crossover spool 4 1/16 10M X4 1/16 5M ii rft.1, r> Pump In Sub si MI 5 s c 5.. �; 14 4 1/16 5M e ct° , (° . 00 1502 Union 77- Manual Gate Manual Gate Valve,Swab,WKM M, '��t�.,,,�. 2 1/8 5M 2 1/8 5M 4 1/16 5M FE = \14\(0-\''' is 55,;: \14‘C‘5,,c,° tt- Valve,Upper Master,Baker 4 1/16 5M FE,w/Hydraulic © °° Valve,Lower Master,WKM-M, <; 4 1/16 5M FE C 01111tni Tubing Adapter,41/16 5M S . • STANDARD WELL PROCEDURE Hilcorp Alaska,LLC NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing - and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 0 0 1- = 2 l7 C aa 0. 0. II b .G o U a` •. 0 = w e w a w -g 7 > F 'gnu a�2 a�g ri- g w > a U w U a 3 •,:c a LL ww g l l a a i- f9 c' v 0 ^-r p, C N cid W '" ~ r•• ~ WW N `moi a Y 2 Z c7 :2 > N Z d E T—•-- O ?• • N w 6 W U Ct', r • 2u • Y ..„,,c O • w L —00410T0004-- COI © V Q Ol A C 3 D LL @• o ITIX 1c. III SII I II 4 P� fi=_} 1111 11111 11111 V 17. I N N Z Iti w a LL a `a `w `u O ` V O O O m W m o O K V Z a H CA co O O N gl L ( Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. do~ - L3 7- Well History File Identifier 0 Two-sided 1111111111111111111 Page Count from Scanned File: 'if b (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~YES NO Date: Cf, ?Þ /0 If Isl t11fJ YES NO Organizing (done) RESCAN ~color Items: D Greyscale Items: DIGITAL DATA ~iskettes, No. Ll- D Other, No/Type: D Poor Quality Originals: D Other: NOTES: BY: Helen~ Project Proofing BY: Helen ~ (~IVlélll~/ Scanning Preparation '- 106 x 30 = BY: Helen (§~~ Production Scanning Stage 1 BY: Helen ~ If NO in stage 1 page(s) discrepancies were found: Stage 1 BY: Helen Maria Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: ~escan Needed 1111111111111111111 OVERSIZED (Scannable) 0 Maps: 0 Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) D Logs of various kinds: 0 Other:: , Date cr. 'J-lf, Dlj I~ mP 111111111111111111 , P Date Cf ~r ðlf I~ lM . , , + ~5 = TOTAL PAGES 8lÇ ~~~~1''¡s not b'if co~~r ShVf1- '0 1JIIj, IIIIIIIIIIII~ 11111 Date: /s/ - 1- . III r 1111111111 Date: /s/ Quality Checked 1111111111111111111 8/24/2004 Well History File Cover Page.doc • • • bp BP Exploration Alaska p (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 ��yY,,, i 2K �riM1� D FEB 4 � t� E L December 30, 2011 Mr. Tom Maunder ao , _ 1 3 Alaska Oil and Gas Conservation Commission P S - QS 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPS -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPS -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, (7 ) Mehreen Vazir BPXA, Well Integrity Coordinator 0 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) MPS -Pad 10/11/2011 Corrosion • Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft gal MPS-01A 2070340 50029231410100 0.25 NA 0.25 NA 5.1 9/6/2011 MPS-02 2031270 50029231690000 2.5 NA 2.5 NA 23.8 7/30/2011 MPS-03 2021460 , 50029231050000 Open Flutes - Treated MPS-04 2030520 50029231480000 1.7 NA 1.7 NA 17.0 7/30/2011 ---->- MPS-05 2021370 50029231000000 Open Flutes - Treated MPS-06 2031090 50029231630000 1.7 NA 1.7 NA 17.0 7/30/2011 MPS-07 2020720 50029230790000 1 NA 1 NA 13.6 11/3/2009 MPS-08 2031230 50029231680000 1.3 NA 1.3 NA 10.2 7/30/2011 MPS -09 2020200 50029230670000 0.5 NA 0.5 NA 5.1 11/3/2009 MPS -10A 2051250 50029231520100 1.3 NA 1.3 NA 11.9 7/29/2011 MPS-11 2021130 50029230920000 1 NA 1 NA 10.2 7/29/2011 MPS-12 2030230 50029231390000 0.6 NA 0.6 NA 6.8 7/29/2011 MPS-13 2021240 50029230930000 1 NA 1 NA 11.9 11/3/2009 MPS-14 2031040 50029231620000 1.8 NA 1.8 NA 22.1 7/29/2011 MPS-15 2012450 50029230610000 9.6 NA 9.6 NA 88.4 7/31/2011 MPS-16 2030650 50029231510000 1.2 NA 1.2 NA 10.2 7/29/2011 MPS -17 2021730 50029231150000 Open Flutes - Treated MPS -18 2022420 50029231330000 1.3 NA 1.3 NA 11.9 7/29/2011 MPS -19A , 2022330 50029231210100 1.8 NA 1.8 NA 23.8 7/29/2011 MPS -20 2022410 50029231320000 1.3 NA 1.3 NA 11.9 7/29/2011 MPS-21 2020090 50029230650000 1.8 NA 1.8 NA 22.1 11/3/2009 MPS -22 2031470 50029231760000 9.1 NA 9.1 NA 83.3 7/28/2011 MPS-23 2021320 50029230980000 Open Flutes - Treated MPS-24 2030380 50029231420000 1.3 NA 1.3 NA 10.2 7/28/2011 MPS -25 2021030 50029230890000 Open Flutes - Treated MPS -26 2030610 50029231500000 1 NA 1 NA 8.5 7/28/2011 MPS -27 2020850 50029230840000 0.9 NA 0.9 NA 8.5 7/28/2011 MPS -28 2030940 50029231580000 1.1 NA 1.1 NA 11.9 7/28/2011 MPS -29 2021950 50029231190000 Open Flutes - Treated MPS-30 2022360 50029231310000 1.2 NA 1.2 NA 11.9 7/28/2011 MPS -31 2020140 50029230660000 Open Flutes - Treated MPS-32 2030920 50029231570000 0.8 NA 0.8 NA 6.8 7/28/2011 MPS -33A 2061720 50029231230100 1 NA 1 NA 6.8 7/28/2011 MPS-34 2031300 50029231710000 6 NA 6 NA 49.3 7/28/2011 MPS-35 2031430 50029231750000 1.2 NA 1.2 NA 11.9 7/28/2011 MPS-37 2070520 50029233550000 13.9 Need top job NA MPS-39 2081830 50029234050000 0.7 NA 0.7 NA 4.3 8/18/2011 MPS -41A 2081610 50029234010100 Sealed NA NA NA NA NA MPS -43 2081760 50029234040000 Dust Cover NA NA NA 6.8 10/11/2011 MPS -90 2051350 50029232760000 0.6 NA 0.6 NA 3.4 9/6/2011 MPSB-04 _ 500299990799 0.6 NA 0.6 NA 3.4 _ 7/30/2011 11 /05/07 Schlumberger t~aii ft~I NO. 4360 Alaska Data & Consulting Services ~~- iY~~ ~ ~ ~4IV~ Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Niakuk, Milne Pt., Pt. Mac, Prince C Woll _Inh i! Inn ^eecrintinn Date BL Color CD S-400A 11855508 USIT (REVISED) C 09/18/07 1 C-30 11695080 LDL 10/16/07 Z-226 11594525 SBHP SURVEY 10106/07 1 14-31 11890316 LDL 10/18/07 1 NK-22A 11855822 DRIFT TD/LDL (- 10/25/07 1 MPG-07 NIA CORRELATION/DDL (_ 09108107 1 - MPG-07 11628799 MEM INJ PROFILE C - 10/20107 1 MPF-10 11767140 MEM INJ PROFILE U= 09/15/07 1 MPS-05 11745237 MEM PPROF SUPPLEMENT LOG -'_ 3'~-- 10/09/07 1 P2-19A 11649963 MCNL '} - ~(, - 04/22/07 1 1 OWDW-SW 11221548 RST ~ 03/05/06 1 1 W-17A 11588701 MCNL _ ~ 'tL 12/26/06 1 1 14-30A 11485775 MCNL --6 O 11/22/06 1 1 L-51 40013624 OH MWD/LWD EDIT 06/26/06 2 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE DOPY EACH ~V,: BP Exploration (Alaska) Inc. - ~ ~;i Petrotechnical Data Center LR2-1 ~ ° ' 900 E. Benson Blvd. Anchorage, Alaska 99508 ~Ig•~~•,, ~~ t~ ~~~~ Date Delivered: .~1 ;r,r%+ rlh ,;d~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~ Received by: • ~Y . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marlœr.doc ~") (~ ~,~v1 DATA SUBMITTAL COMPLIANCE REPORT 8/2/2004 Permit to Drill 2021370 Well Name/No. MILNE PT UNIT SB S-05 Operator BP EXPLORATION (ALASKA) INC MD 8810---- TVD 4118.~ Completion Date 7/27/2002'--- Completion Status 1-01L Current Status 1-01L REQUIRED INFORMATION )11 ,A ¿ // 'c) (lj )'-l!\)~, API No. 50-029-23100-00-00 UIC N ~-~--_.------~~ -,-_."---------- Mud Log No Samples No Directional survey( y~-~~) ~ ~~~~~_.------- DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, ABI/IFR, CASANDRA Well Log Information: ---- -- ----- (data taken from Logs Portion of Master Well Data Maint) Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments ----- 1 5132 8810 Open 8/23/2002 A Directional Survey Log is required to be submitted. This record automatically created from Permit to Drill Module on: 7/1/2002. Rpt Directional Survey 5132 8810 Open 8/23/2002 ~ D Directional Survey 5132 8810 Open 8/23/2002 ~-D Directional Survey 0 5528 Open 8/23/2002 (.§.P'-L> Directional Survey 0 5528 Open 8/23/2002 Rpt Directional Survey 5132 8810 Open 8/23/2002 Rpt LIS Verification 60 5477 Case 12/3/2002 ~,EÐ D é 11334 LIS Verification 60 5477 Case 12/3/2002 Rpt Directional Survey 0 5528 Open 8/23/2002 ~/'D -1'1333 LIS Verification 60 8756 Case 12/3/2002 Rpt Directional Survey 0 5528 Open 8/23/2002 Rpt LIS Verification 60 8756 Case 12/3/2002 tED C Asc 01966 LIS Verification 1,2,3,4, 60 8810 Open 6/2/2003 ;ÆD C Pdf 11966 Induction/Resistivity 25 Final 110 8810 Open 6/2/2003 v' ED C Pdf 11966 Induction/Resistivity 25 Final 110 4118 Open 6/2/2003 ED C Asc 11966 LIS Verification 1,2,3 60 5528 Open 6/2/2003 ,ED C Pdf 11966 I nduction/Resistivity 25 Final 110 5528 Open 612/2003 Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ~ Directional Survey MWD PB1 PB1 MWD MWD PB1 PB1 PB1 PB1 MWD MWD - ROP, DGR, EWR - MD MWD - DGR, EWR - TVD PB1 MWD - ROP, DGR, EWR - MD - PB1 -~---~------ DATA SUBMITTAL COMPLIANCE REPORT 8/2/2004 Permit to Drill 2021370 MD 8810 - / ~Ç.,/'Pdf I Well Name/No. MILNE PT UNIT SB S-05 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23100-00-00 TVD 4118 Completion Date 7/27/2002 11966 Induction/Resistivity Completion Status 1-01L UIC N ----_._-----~-_.._-_._-- 4176 Open 6/2/2003 MWD - DGR, EWR - TVD - PB1 Current Status 1-01L 25 Final 110 Well Cores/Samples Information: -~._--_._~_._---_._--- Name Interval Start Stop Sample Set Number Comments Sent Received -- Well Cored? ADDITIONAL INFORMATION Y@ Daily History Received? '~/N @N Chips Received? ~o Compliance Reviewed By: Analysis Received? Comments: Formation Tops ~-' --~------- ------- ~~ ~ Date: (;j.~ J-1~~) 4'" \1'. ~1 ---~. " WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 April 22, 2003 RE: MWD FOffilation Evaluation Logs: MPS-05, MPS-05 PB 1 & L 1, AK-MW-22118 MPS-05: Digital Log Images: 50-029-23100-00 d-o~-\3l 1 CD Rom =It ) \9' LoLo MPS-05 PBl: Digital Log Images: 50-029-23100-70 ~~~'f'l'\~ 1 CD Rom MPS-05 Ll: Digital Log Images: 50-029-23100-60 ðOd, ,-l '3 'ß 1 CD Rom B: \ \<i (s;'1 ~ß~'^-~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES 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 99508 RECEIVED D~N 02 2003 Signed~o~ ~'-\,~ Alaska OH & Gas Coos. Co~n Aft<,t\Of4gc éXOð-/3/ 113'3cf WELL LOG TRANSMITfAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 22, 2002 RE: MWD Formation Evaluation Logs MPS-05 PBl, AK-MW-22118 1 LIS formatted Disc with verification listing. llPI#: 50-029-23100-70 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 99648 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: Sign~(~ RECEIVED DEC 06 2002 AIasIca Oii & Gas Cons. Comm- , AnChorage -n ¿)Õè)- /3 J / I 333 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 J\nchorage,Alaska 99501 November 27, 2002 RE: MWD Formation Evaluation Logs MPS-05, AK-MW-22118 1 LIS formatted Disc with verification listing. API#: 50-029-23100-00 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. J\nchorage, Alaska 99648 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. J\nchorage, Alaska 99649-6612 Date: Sign~~~ RECEIVED DEC 0:) 2002 Alaska Oö & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised 10/03/02, Start Production ( ( ( 1. Status of Well IBI Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3360' NSL, 4772' WEL, SEC. 07, T12N, R11E, UM ~ ,,- At top of productive interval \ ,_Z~,_.~~-,?z.- 3592' NSL, 3238' WEL, SEC. 07, T12N, R11 E, UM (OB),::: : At total depth : _-.A/)- 642' NSL, 4732' WEL, SEC. 07, T12N, R11 E, UM (OB) , 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 66.8' ADL 380110 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 7/11/2002 7/21/2002 7/27/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 8810 4118 FT 8810 4118 FT 0 Yes IBI No 22. Type Electric or Other Logs Run MWD , GR , RES, ABIIIFR I CASANDRA 23. CASING SIZE 20" 7-5/8" 4-1/2" Classification of Service Well 7. Permit Number 202-137 8. API Number 50- 029-23100-00 9. Unit or Lease Name Milne Point Unit 10. Well Number MPS-05 11. Field and Pool Milne Point Unit I Schrader Bluff 15. Water depth, if offshore 16. No. of Completions NI A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost NIA MD 1800' (Approx.) WT. PER FT. 94# 29.7# 12.6# GRADE H-40 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE 28' 112' 42" 28' 5370' 9-7/8" 5265' 8805' 6-1/8" CEMENTING RECORD 260 sx Arctic Set (Approx.) 1060 sx PF 'L', 280 sx Class 'G' Uncemented Slotted Liner AMOUNT PUllED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 4-1/2" Slotted Liner 25. TUBING RECORD SIZE DEPTH SET (MD) 4-1/2", 12.6#, L-80 5022' 3-1/2'" 9.2#, L-80 5022' - 5070' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 35 Bbls of Diesel and 45 Bbls of MeOH. PACKER SET (MD) 5017' MD TVD MD TVD 5372' - 8805' 4178' - 4119' 27. Date First Production September 8, 2002 Date of Test Hours Tested 9/22/2002 12 Flow Tubing Casing Pressure Press. PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR Oll-BBl TEST PERIOD 1908 CALCULATED 24-HoUR RATE Oll-BBl GAs-McF 710 GAs-McF WATER-BBl 2822 WATER-BBl CHOKE SIZE 176 I 64ths Oil GRAVITy-API (CORR) GAS-Oil RATIO 372 ?8. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. SR!~lr", E D No core samples were taken. nr;T q '1 n ~4 5 B F l -' '-, ,OCT 0 4 2002 Alaska OiJ& Gas Qons. Commission I. \'---' Anchorage L9 Form 10-407 Rev. 07-01-80 Submit In Duplicate ( ( I ,~ 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. SBF2-NA 4810' 3957' SBF1-NB 4855' 3985' SBE4-NC 4907' 4015' SBE2-NE 4928' 4028' SBE1-NF 5033' 4080' TSBD-OA 5106' 4109' TSBC 5205' 4141' TSBB-OB 5450' 4183' RECEIVED OCT 0 4 2002 AlasKa Oß&Gas Oons. Commission Anchorage 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ s...;.,~~ Title. Technical Assistant ~ M PS-05 202-137 Prepared By Name/Number: Well Number Permit No. I Approval No. Drilling Engineer: Date {O-C15 '~OJ-.Þ Sondra Stewman, 564-4750 Matt Green, 564-5581 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well 1m Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface~,_"___. ~ 3360' NSL, 4772' WEL, SEC. 07, T12N, R11 E, UM t COMPLETION 1: I .' .' . . ;, At top of productive interval 1 ûlt.TE. ~r ~':" 3592' NSL, 3238' WEL, SEC. 07, T12N, R11 E, UM (OB) .t7..2 7. t> '~l :;S~--?'r) . -; At total depth . VERlF1ED ~~&. " ~.'-. 642' NSL, 4732' WEL, SEC. 07, T12N, R11 E, UM (OB) .'/5P t~.,;.-"J';(~:"":...:.~ 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designãtiön- and Serial No. KBE = 66.8' ADL 380110 12. Date Spudded 13. Date,.!.:2' Reached 14. Date Comp., Susp., or Aband. 7/11/2002 7 ~_~002Âb 7/27/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 8810 4118 FT 8810 4118 FT 1m Yes 0 No 22. Type Electric or Other Logs Run MWD , GR , RES, ABIIIFR I CASANDRA 23. CASING SIZE 20" 7-5/8" 4-1/2" Classification of Service Well 7. Permit Number 202-137 8. API Number 50- 029-231 00-00 9. Unit or Lease Name Milne Point Unit 10. Well Number MPS-05 11. Field and Pool Milne Point Unit I Schrader Bluff 15. Water depth, if offshore 16. No. of Completions NI A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost NIA MD 1800' (Approx.) WT. PER FT. 94# 29.7# 12.6# CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE 28' 112' 42" 28' 5370' 9-7/8" 5265' 8805' 6-1/8" CEMENTING RECORD 260 sx Arctic Set (Approx.) 1060 sx PF 'L', 280 sx Class 'G' Uncemented Slotted Liner TUSING RECORD SIZE DEPTH SET (MD) 4-1/2", 12.6#, L-80 5022' 3-1/2",9.2#, L-80 5022' - 5070' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED GRADE H-40 L-80 L-80 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 4-1/2" Slotted Liner 25. MD TVD TVD MD 5372' - 8805' 4178'>4119' 26. 27. Date First Production Not on Production Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) NIA PRODUCTION FOR OIL-BsL TEST PERIOD GAs-McF WATER-BsL Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL-BsL GAs-McF WATER-BsL AMOUNT PULLED PACKER SET (MD) 5017' CHOKE SIZE GAS-OIL RATIO OIL GRAVITY-API (CORR) 28. CORE DATA .,. . . Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. S~brrlÌt cQrechipsi No core samples were taken. Form 10-407 Rev. 07-01-80 & 0 M 5 u tl AIJ] 2 8 ~mitln Duplicate (' 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. SBF2-NA 4810' 3957' SBF1-NB 4855' 3985' SBE4-NC 4907' 4015' SBE2-NE 4928' 4028' SBE1-NF 5033' 4080' TSBD-OA 5106' 4109' TSBC 5205' 4141' TSBB-OB 5450' 4183' 31. List of Attachments: SUlTlmary of Daily Drilling Reports, Surveys and a Leak-Off Test Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed so~ Stewm~ Title Technical Assistant M PS-05 202-137 Well Number Permit No. I Approval No. Date C8$" J..7 ~ 07--- Prepared By Name/Number: Sandra Stew man, 564-4750 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Legal Name: MPS-05 Common Name: MPS-05 Test Date 7/18/2002 Test Type FIT Test Depth (TMD) 5,410.0 (ft) BP Leak-Off Test Summary Test Depth (TVD) 4,180.0 (ft) AMW 9.00 (ppg) Surface Pressure 450 (psi) Leak Off Pressure (BHP) 2,404 (psi) Page 1 of 1 EMW 11.07 (ppg) ~" Printed: 7/29/2002 4:40:55 PM ( BP Operations Summary Report Page 1 of 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-05 MPS-05 DRILL +COMPLETE DOYON DOYON 141 Start: 7/11/2002 Rig Release: 7/27/2002 Rig Number: 141 Spud Date: 7/11/2002 End: Date From - To Hours Task Code NPT Phase Description of Operations 7/11/2002 00:00 - 03:30 3.50 MOB P PRE MOVE SUB - UTILITY MODULES - PIPE SHEDS - ROCKWASHER - FROM MPS-23 TO MPS -05 03:30 - 04:00 0.50 MOB P PRE RIG UP ALL UTILITY SERVICES - PREFORM RIG ACCEPTANCE LIST - (ACCEPT RIG AT 04:00 HRS) 04:00 - 08:00 4.00 RIGU P PRE NIPPLE UP DIVETER RISER TO FLOW LINE - LOAD PIPE SHED WITH 4" DRILL PIPE - MIX SPUD MUD 08:00 - 17:30 9.50 DRILL P INT1 PICK UP 93 STANDS OF 4" DRILL PIPE - STANDING IN DERRICK - PU 5" HWDP - 6" FLEX DC'S - JARS STANDING IN DERRICK 17:30 - 20:00 2.50 DRILL P INT1 PICK UP BHA - MAKE UP BIT - MOTOR - MWD - UP LOAD MWD 20:00 - 20:30 0.50 DRILL P INT1 PRE SPUD MEETING WITH CREW, MUD ENGINEER, DIRECTIONAL DRILLER, MWD PERSONNEL, - FUNCTION TEST DIVERTER - ACCUMULATOR DRILL - (WITNESS OF FUNCTION TEST OF DIVERTER SYSTEM WAIVED BY JOHN CRISP WITH AOGCC) - FILL HOLE, RISER, AND FLOW LINE - SURFACE TEST OF MUD SYSTEM - OK 20:30 - 00:00 3.50 DRILL P INT1 SPUD IN WELL MPS-05 - DRILL FROM 110' TO 259' - WOB 0 TO 5K - RPM 60 - TO 0 - GPM 393 - PP 1020 - PU 50 - SO 50 - ROT 50 7/12/2002 00:00 - 17:30 17.50 DRILL P INT1 DIRECTIONAL DRILL FROM 259' TO 2462' - WOB 30K TO 35K - RPM 80 - TO 5k ON BTM - 3K OFF BTM - GPM 425 - PP ON BTM 2140 - OFF BTM 1740 - PU 80 - SO 65 - ROT 75 17:30 - 18:30 1.00 DRILL P INT1 CIRC 3 X BTM UP - GPM 425 - PP 1750 - RPM 90 - TO 3K 18:30 - 21 :00 2.50 DRILL P INT1 PUMP OUT FROM 2462' TO HWDP 811' - FULL RATE 400 GPM - CON'T POH TO MWD 21 :00 - 22:30 1.50 DRILL P INT1 DOWN LOAD MWD - LAY DOWN BHA - MOTOR 22:30 - 00:00 1.50 DRILL P INT1 PICK UP GEO-PILOT - MWD - UP LOAD MWD - PU BHA 7/13/2002 00:00 - 00:30 0.50 DRILL P INT1 CON'T PICK UP GEO-PILOT BHA 00:30 - 01 :00 0.50 DRILL P INT1 TEST SPERRY SUN GEO-PILOT MANIFOLD TO 3000 PSI - TEST MWD 01 :00 - 02:00 1.00 DRILL P INT1 RIH FROM 811' TO 2410' - TIGHT FROM 2190' TO 2210' (20k) - WORK THROUGH SECTION WITHOUT PUMP OR ROTATION 02:00 - 03:00 1.00 DRILL P INT1 NO DOWN LINK COMMUNICATION TO SPERRY SUN MWD TOOL - TROUBLE SHOOT SPERRY SUN GEO-PILOT SYSTEM - FOUND ERROR IN UP LOAD - CONSISTED OF ENGINEER FAILED TO ENABLE UP LINK TELEMENTRY 03:00 - 04:00 1.00 DRILL P INT1 DIRECTIONAL DRILL FROM 2462' TO 2594' - CAN NOT KEEP CONSISTENCE TOOL FACE DUE TO HOUSING ROLL 04:00 - 04:30 0.50 DRILL N DPRB INT1 CIRC FOR TRIP 2 X BOTTOMS UP 04:30 - 06:30 2.00 DRILL N DPRB INT1 OBSERVE WELL - PUMP OUT TO HWDP - CON'T POH TO MWD 06:30 - 08:30 2.00 DRILL N DPRB INT1 DOWNLOAD MWD - LAY DOWN GEO-PILOT BHA 08:30 - 09:30 1.00 DRILL N DPRB INT1 PICK UP 1.5 DEGREE MOTOR - BHA - UP LOAD MWD 09:30 - 11 :00 1.50 DRILL N DPRB INT1 RIH TO 2490' - PRECAUCTIONARY WASH TO 2594' - (TIGHT 20K DOWN FROM 1720' TO 1750' WORK THROUGH WITHOUT PUMP) 11:00-21:30 10.50 DRILL P INT1 DIRECTIONAL DRILL FROM 2594' TO 4055' - WOB 10K TO 20K - RPM 80 - GPM 504 - PP ON BTM 3060 - PP OFF BTM 2850 - TO ON BTM 6K OFF BTM 5K - PU 110K - SO 77K- Printed: 7/29/2002 4:41 :08 PM ( ( BP Operations Summary Report Page 2 of 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-05 MPS-05 DRILL +COMPLETE DOYON DOYON 141 Start: 7/11/2002 Rig Release: 7/27/2002 Rig Number: 141 Spud Date: 7/11/2002 End: Date From - To Hours Task Code NPT Phase Description of Operations 7/13/2002 11 :00 - 21 :30 10.50 DRILL P INT1 ROT 95K 21 :30 - 23:00 1.50 DRILL P INT1 CIRC 3 X BTMS UP 23:00 - 00:00 1.00 DRILL P INT1 PRECAUCTIONARY SHORT TRIP - PUMP OUT TO 2900' 7/14/2002 00:00 - 01 :00 1.00 DRILL P INT1 PUMP OUT FROM 2900' TO 2055' - CON'T TP POH TO HWDP 811' - NO TIGHT SPOTS NOTED ON TRIP OUT 01 :00 - 01 :30 0.50 DRILL P INT1 RIG SERVICE - TOP DRIVE SERVICE - OBSERVE WELL 01 :30 - 03:00 1.50 DRILL P INT1 RIH FROM 811' TO 4000' - (TIGHT SPOTS ON TRIP IN 1715' TO 1727' 15K -1745' TO 1760' 20K WORK THROUGH WITH OUT PUMP) - WASH FROM 4000' TO 4055' 03:00 - 18:30 15.50 DRILL P INT1 DIRECTIONAL DRILL FROM 4055' TO 5528' - T.D. @ 5528'- WOB 30K TO 35K - RPM 80 - TO 8K ON BTM 7K OFF BTM - GPM 500 - PP ON BTM 33500 - PP OFF BTM 3200 - PU 120K - SO 76K - ROT 94K 18:30 - 20:30 2.00 CASE P INT1 CBU 3 X BTMS FOR HOLE OPENER TRIP - GPM 500 -140 RPM'S - TO 7K 20:30 - 22:00 1.50 CASE P INT1 PUMP OUT FROM 5250' TO TO 3988' - PULL FROM 3988' TO 3708' 22:00 - 00:00 2.00 CASE P INT1 PUMP DRY JOB - OBSERVE WELL - POH 7/15/2002 00:00 - 01 :00 1.00 CASE P INT1 CON'T POH TO MWD 01 :00 - 01 :30 0.50 CASE P INT1 DOWN LOAD MWD 01 :30 - 02:00 0.50 CASE P INT1 LAY DOWN BHA # 3 02:00 - 02:30 0.50 CASE P INT1 MAKE UP HOLE OPENING BHA # 4 02:30 - 03:30 1.00 CASE P INT1 RIG SERVICE - CUT DRLG LINE 03:30 - 04:00 0.50 CASE P INT1 RIH FROM 204' TO 1550' 04:00 - 10:00 6.00 CASE P INT1 OPENING HOLE FROM 1550' TO 5187' - COULD NOT PASS 5187' - RPM 150 - TO 8K - GPM 500 - PP 2200 - PU 130K- SO 80K ROT 95K - 10:00 - 11 :00 1.00 CASE N DPRB INT1 ATTEMPT TO PASS 5187' - COULD NOT GET PASSED 5187 - RUN UP TO 40K ON OPENER - NO PROGRESS - 11 :00 - 14:00 3.00 CASE N DPRB INT1 OBSERVE WELL - PUMP DRY JOB - POH WITH HOLE OPENER FOR INSPECTION - BULL NOSE WORN - EVERYTHING ELSE IN GOOD SHAPE ON HOLE OPENER AND BHA#4 14:00 - 15:30 1.50 CASE N DPRB INT1 PICK UP NEW HOLE OPENER - MOVE TOP STAB UP HOLE 30' - STABLlZERS AT 74' /140' - PICK UP 5" HWDP ON TOP OF HOLE OPENER TO LIMBER UP ASSEMBLY - BHA # 5 15:30 - 18:00 2.50 CASE N DPRB INT1 RIH WITH 2 ND HOLE OPENER TO 5164' - BREAK CIRC 18:00 - 19:00 1.00 CASE N DPRB INT1 ATTEMPT TO REAM PASS 5187' - NO PROGRESS - RUN UP TO 43K ON HOLE OPENER - GPM 500 - PP 2400 - RPM 50 TO 150 - TO 8K TO 10K - PU 130K - SO 80 K ROT 95K 19:00 - 22:00 3.00 CASE N DPRB INT1 OBSERVE WELL - PUMP DRY JOB - POH FOR BHA # 6 - HOLE OPENER HAD CUTS / GOUGES ON BOTTOM 6" OF SNUB NOSE - NOSE WAS PLUGGED - BOTTOM OF NOSE HAND CRACKS GOING OUT FROM JET HOUSING TO OUTTER EDGE OF NOSE - LAY DOWN HOLE OPENER BHA # 5 22:00 - 23:00 1.00 CASE N DPRB INT1 PICK UP BHA # 6 23:00 - 00:00 1.00 CASE N DPRB INT1 RIH WITH (DRLG ASSEMBLY) BHA # 6 TO 1520' - SHALLOW TEST MWD 7/16/2002 00:00 - 01 :30 1.50 CASE N DPRB INT1 RIH WITH (DRLG ASSEMBLY) - BHA # 6 5164 - BREAK CIRC - CON'T IN TO 5187' TAG UP 01 :30 - 04:30 3.00 CASE N DPRB INT1 ORIENT TOOL FACE TO LOW SIDE - SLIDE 15' - ROLL TOOL FACE TO HIGH SIDE - SLIDE 20' - ROTATE AHEAD- Printed: 7/29/2002 4:41 :08 PM (, ( BP Operations Summary Report Page 3 of7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-05 MPS-05 DRILL +COMPLETE DOYON DOYON 141 Start: 7/11/2002 Rig Release: 7/27/2002 Rig Number: 141 Spud Date: 7/11/2002 End: Date From - To Hours Task Code NPT Phase Description of Operations 7/16/2002 01 :30 - 04:30 3.00 CASE N DPRB INT1 CON'T DIRECTIONAL DRILLING TO T.D. @ 5380' - 30' MEASURED DEPTH INTO OB SAND - ANGLE ON BOTTOM PROJECTED AT 82 DEGREE'S 04:30 - 05:00 0.50 CASE N DPRB INT1 CIRCULATE HOLE 05:00 - 05:30 0.50 CASE N DPRB INT1 SHORT TRIP TO 5100' - RIH WITHOUT PUMPS - NO PROBLEMS 05:30 - 06:00 0.50 CASE N DPRB INT1 CIRCULATE / CONDITION HOLE 06:00 - 09:30 3.50 CASE N DPRB INT1 OBSERVE WELL - PUMP DRY JOB - POH FOR HOLE OPENER - LAY DOWN BHA # 6 09:30 - 12:00 2.50 CASE N DPRB INT1 MAKE UP HOLE OPENER ASSEMBLY BHA # 7 - RIH TO 5137' 12:00 - 14:00 2.00 CASE N RREP INT1 TROUBLE SHOOT TOP DRIVE - FAILURE ON ENCODER TEMP BY PASS 14:00 - 14:30 0.50 CASE P INT1 WASH AND REAM FROM 5137' TO BOTTOM 5187' 14:30 - 16:00 1.50 CASE P INT1 CIRCULATE AND CONIDITION MUD / HOLE FOR RUNNING 7 5/8" CASING - 3 X BOTTOMS UP - GPM 550 - PP 2500 - RPM 150 - TQ 7K 16:00 - 18:30 2.50 CASE P INT1 OBSERVE WELL - PUMP DRY JOB - POH TO BHA 18:30 - 19:00 0.50 CASE P INT1 LAY DOWN 5" HWDP 19:00 - 20:00 1.00 CASE P INT1 LAY DOWN BHA # 7 - CLEAR FLOOR 20:00 - 21 :30 1.50 CASE P INn R/U CSG. CREW -PJSM - (RUNNING CASING) 21 :30 - 00:00 2.50 CASE P INT1 PICK UP AND RUN 7 5/8" 29# L-80 CASING - 66 JTS. IN HOLE 85K P/U WT 63 S/O 7/17/2002 00:00 - 03:00 3.00 CASE P INT1 RUN 75/8" 29# L-80 CASING FROM 2700' TO 5370' - (TOTAL JOINTS RUN 128 JTS) - LANDED CSG. ON LANDING RING 250 P/U - 85 S/O 03:00 - 06:00 3.00 CASE P INT1 CIRCULATE / CONDITION HOLE AND MUD FOR CEMENT JOB - CIRC 1 CSG. VOLUME (3100 STKS ) 324 GPM @ 400 PSI- LAY DOWN FRANKS FILL TOOL -INSTALLHOWCO CEMENTING HEAD - CON'T CIRC / COND MUD FOR CEMENT JOB - PJSM FOR CEMENTING - AIR UP HOWCO TANKS PREPARE TO CEMENT 06:00 - 10:30 4.50 CASE P INT1 PUMP 10 BBLS WATER - TEST LINES TO 3500 PSI - DROP BOTTOM PLUG - PUMP 40 BBLS WATER - MIX AND PUMP 50 BBLS ALPHA WEIGHTED SPACER 10.2 - MIX AND PUMP 990 BBLS 10.7 LEAD CEMENT - CEMENT TO SURFACE (160) -100 BBLS OF 10.3 TO 10.4 CONTAINMENTED CEMENT - 60 BBLS OF GOOD 10.7 CEMENT - GOOD RETURNS - SWITCHED TO TAIL - MIX AND PUMP 43 BBLS OF TAIL 15.8 - SURGE TANK RELEASE VALVE CUT OUT RELEASING ALL AIR ON SURGE TANK - WHICH WOULD NOT ALLOW CEMENT TO TRANSFER TO MIX TANK - OPERATION SHUT DOWN FOR 15 MINS - TRANSFERED CEMENT MANUALLY TO MIX TANK - CONTINUE MIX AND PUMP 15.8 TAIL CEMENT 19 BBLS - DID NOT REGAIN RETURNS 10:30 - 11 :00 0.50 CASE P INT1 DROP TOP PLUG - DISPLACE WITH 30 BBLS WATER - 243 BBLS MUD - NO RETURNS - PUMPED TOTAL 262 BBLS WITHOUT RETURNS (19 BBLS TAIL + 243 BBLS MUD)- BUMPED PLUG WITH 2100 PSI (1000 PSI OVER PUMP PRESSURE DISPLACING) - BLEED OFF FLOATS - FLOATS HELD - CIP 11 :00 HRS Printed: 7/29/2002 4:41 :08 PM ( BP Operations Summary Report Page 4 of 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-05 MPS-05 DRILL +COMPLETE DOYON DOYON 141 Start: 7/11/2002 Rig Release: 7/27/2002 Rig Number: 141 Spud Date: 7/11/2002 End: Date From - To Hours Task Code NPT Phase Descri ptionof Operations 7/17/2002 11 :00 - 12:00 1.00 CASE P INT1 FLUSH DIVERTER SYSTEM - RIG DOWN HOWCO CEMENT HEAD 12:00 - 13:00 1.00 CASE P INT1 UD LANDING JOINT - CASG TOOLS - CHANGE OUT BALES - CLEAR FLOOR 13:00 - 16:00 3.00 CASE P INT1 NIPPLE DOWN DIVERTER SYSTEM 16:00 - 16:30 0.50 CASE P INT1 ORIENT AND NIPPLE UP FMC GEN 6 CASG HEAD - TEST TO 1000 PSI FOR 10 MINS OK 16:30 - 19:30 3.00 CASE P INT1 NIPPLE UP 13 5/8" BOP'S 19:30 - 00:00 4.50 CASE P INT1 TEST BOPE (WITNESS WAIVED BY J. SPAULDING ----WITH AOGCC ) UPPER & LOWER RAMS --CHOKE MANIF.HCR.-KILL LINE -CHOKE VAVLES TO 250 PSI LOW, F / 5 MIN.- 4000 PSI HIGH, F / 5 MIN. ANNULAR 250 PSI & 2500 PSI, F / 5 MIN. EACH - FULL ACCUMULATOR TEST--5 BOTTLE AVE. 2150 PSI-ACC. 3000 PSI--5 FUNCTION, DEPLETION 1850 PSI --200 PSI ELEC. RECOVERY 37 SEC.--O.A. RECOVERY 3 MIN. 16 SEC. 7/18/2002 00:00 - 07:00 7.00 CASE N RREP INT1 TROUBLE SHOOT TOP DRIVE - CHANGE OUT BRAKE PADS - ENCODER - CONT. TROUBLE SHOOT TOP DRIVE - FOUND SHORT IN LINE CAUSING ENCODER TO BURN OUT - REPAIRED SHORT AND REPLACED ENCODER 07:00 - 08:00 1.00 CASE P INT1 FINISH TESTING BOPE - BLIND RAMS, UPPER & LOWER TOP DRIVE INSIDE BOPS-TEST TO 250 PSI LOW -4000 PSI HIGH FOR 5 MIN. 08:00 - 08:30 0.50 CASE P INT1 INSTALL WEAR RING 08:30 - 12:00 3.50 CASE N RREP INT1 CONT. TO TROUBLE SHOOT TOP DRIVE-FOUND INTERMITEN OPEN THAT WAS BURNING OUT DECODERS 12:00 - 18:30 6.50 CASE N RREP INT1 REPAIR TOP DRIVE & TEST SAME-OK 18:30 - 19:30 1.00 CASE P INT1 CHANGE OUT WORN SAVER SUB 19:30 - 21 :30 2.00 CASE P INT1 PICK UP BHA #8- MAKE UP BIT-MOTOR-MWD-UP LOAD MWD 21 :30 - 23:30 2.00 CASE P INT1 RUN IN HOLE -PERFORMED SHALLOW TEST ON MWD 23:30 - 00:00 0.50 CASE P INT1 BREAK CIRC. -TEST CSG. TO 4000 PSI (37 STK.) FOR 30 MIN.& RECORD SAME @5203 FT. 7/19/2002 00:00 - 00:30 0.50 CASE P INT1 CON'T RECORD & TEST CSG - TO 4000 PSI FOR 30 MIN @ 5203 FT. 00:30 - 03:00 2.50 CASE P INT1 DRLG - CEMENT - FLOAT COLLAR - SHOE - SLIDE 30 FT NEW HOLE TO 5410 FT 03:00 - 04:00 1.00 CASE P INT1 CIRC / COND - MUD FOR FIT 04:00 - 04:30 0.50 CASE P INT1 PERFORM FIT - PRESS UP TO 520 PSI WITH 9 # MUD - PRESS BELD BACK TO 450 PSI IN 10 MIN (EMW = 11.06# MUD) 04:30 - 08:00 3.50 CASE P INT1 MAD PASS FROM 5045 FT. TO 5410 FT. 08:00 - 09:00 1.00 CASE P INT1 DISPLACE WELL BORE WITH 9.1# FLOPRO MUD 09:00 - 00:00 15.00 DRILL P PROD1 DIRECTIONAL DRILL FROM 5410 FT. TO 6850 FT. ( CROSS FAULT @ 6797 FT. )RPM 60-70 --P/U WT.115K --S/O 73 K--RW 83 K---TQ ON BOT 6 K-- OFF BOT 5.5 K 7/20/2002 00:00 - 21 :30 21.50 DRILL P PROD1 DIRECTIONAL DRILL FROM 6850 FT. TO 8810 FT.TD. FOR OB LATERAL (BACK IN SAND @ 7020 FT. AFTER CROSSING FAULT @ 6797 FT.) RPM 60-70 - P / U WT. 120 K--S/O 73K-ROT 85K-TQ ON BOT. 6K --OFF BOT.5K 21 :30 - 00:00 2.50 CASE P COMP CIRC. & CONDo HOLE @8810 FT. ( TD ) PREPARE TO RUN 4 1/2" SLOTED LlNER-CIRC 4 BOT UP @80 STKS(280 GPM) Printed: 7/29/2002 4:41 :08 PM ( BP Operations Summary Report Page 5 of 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-05 MPS-05 DRILL +COMPLETE DOYON DOYON 141 Start: 7/11/2002 Rig Release: 7/27/2002 Rig Number: 141 Spud Date: 7/11/2002 End: Date From - To Hours Task Code NPT Phase Description of Operations 7/20/2002 21 :30 - 00:00 2.50 CASE P COMP ROT @ 100 RPM WHILE CIRC. 7/21/2002 00:00 - 00:30 0.50 CASE P COMP FINISH CIRC.HOLE CLEAN BEFORE POOH FOR 41/2" SLOTED LINER 00:30 - 06:00 5.50 CASE P CaMP PUMP OUT OF HOLE FROM 8810 FT.( TD )BACK TO SHOE @ 5370 FT./ OBSERVE WELL-PUMP DRY JOB CONT. POH 06:00 - 07:00 1.00 CASE P COMP DOWN LOAD MWD 07:00 - 07:30 0.50 CASE P COMP LAY DOWN BHA 07:30 - 08:00 0.50 CASE P COMP RU CASG TOOLS TO RUN 4.5" SLOTTED LINER - PJSM ON RUNNING LINER 08:00 - 10:30 2.50 CASE P COMP PU I RUN 90 JTS 41/2" SLOTTED LINER - 2 JTS 41/2" SOLID LINER - PU BAKER HANGER AND MAKE UP SAME 10:30 - 13:00 2.50 CASE P COMP CON'T RIH WITH 4.5" SLOTTED LINER ON 4" DRILL PIPE TO 8810'-P/U WT. 115 K-S/O 65 K 13:00 - 14:00 1.00 CASE P CaMP DROP BALL - BALL ON SEAT PRESSURE UP TO 2500 SET HANGER - SLACK OFF 35K DP WEIGHT - PRESSURE UP TO 3100 SHEAR OUT - HANGER SET - TOL 5265' - BTM LINER 8807' - LOSS OF 30K WEIGHT WHEN PICKED UP 14:00 - 16:00 2.00 CASE P CaMP STAND BACK ONE STAND - PUMP DRY JOB - POH WITH LINER RUNNING TOOL - LID SAME 16:00 - 19:00 3.00 STWHIP P PROD2 PJSM ON RUNNING WHIPSTOCK- PU BAKER WHIPSTOCK ASSY. MWD & ORIENT-9 DC,S +15 H W D 19:00 - 22:00 3.00 STWHIP P PROD2 SHALLOW TEST MWD - RIH WITH WHIPSTOCK TO 5265' AND STING INTO TIE BACK-TOP OF WHIPSTOCK @5111' PIU WT.105K -S/O 81 K 22:00 - 23:00 1.00 STWHIP P PROD2 SET WHIPSTOCK 7 DEGREES RIGHT OF HIGH SIDE-TOP OF WINDOW @5111' 23:00 - 00:00 1.00 STWHIP P PROD2 MILL WINDOW FROM 5111' TO 5113' -WOB 2K-70 RPM TQ 6 -P/U 1 05K- SIO 81 - RIW 87 7/22/2002 00:00 - 04:30 4.50 STWHIP P PROD2 FINISH MILLING WINDOW FROM 511' TO 5143' 12' WINDOW &20 FT. OUT SIDE-80 RMP-TQ 5K TO 8 K --P/U 105K -S/O 81K- ROT 87K-72 STK SPP 1000 04:30 - 06:00 1.50 STWHIP P PROD2 CIRC & CLEAN HOLE -AFTER MILLING WINDOW 06:00 - 07:30 1.50 STWHIP P PROD2 OBSERVE WELL - PUMP DRY JOB - POH FOR MILLING BHA 07:30 - 08:30 1.00 STWHIP P PROD2 STAND BACK 3.5" HWDP I 4.75" DC'S - LAY DOWN MILLING ASSEMBLY 08:30 - 09:30 1.00 STWHIP P PROD2 RIG UP AND WASH OUT STACK WITH WASH TOOL 09:30 - 10:30 1.00 STWHIP P PROD2 PU DRILLING BHA # 10 - ORIENT - UP LOAD MWD - SHALLOW TEST MWD 10:30 - 12:00 1.50 STWHIP P PROD2 TIH WITH BHA # 10 TO 4900' 12:00 - 13:30 1.50 STWHIP P PROD2 SLIP & CUT 98' DRILL LINE-IN SPECT & ADJUST BRAKES SERVICE TOP DRIVE 13:30 - 14:00 0.50 STWHIP P PROD2 CONT.TIH TO TOP OF WINDOW @5111'-ORIENT THRU WINDOW 14:00 - 00:00 10.00 DRILL P PROD2 DIRECTIONAL DRILL FROM 5143' TO 6150'-P/U WT. 103K SIO 74K ROT. WT.83-TQ ON BOT 4 K-OFF BOT 3 K- WOB 2TO 12 K-RPM 80 -72 STKS ,250 GPM DROPED OUT BASE OF SAND @5205' (4138' TVD) REENTER SAND @ 5395' (4137 TVD) --FAULT @ 5920' (4113 TVD ) FAULTED TO LOWER PART OF SAND Printed: 7/29/2002 4:41 :08 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ( BP Operations Summary Report Page 6 of 7 MPS-05 MPS-05 DRILL +COMPLETE DOYON DOYON 141 Start: 7/11/2002 Rig Release: 7/27/2002 Rig Number: 141 Spud Date: 7/11/2002 End: Date From - To Hours Task Code NPT Phase Description of Operations 7/22/2002 14:00 - 00:00 10.00 DRILL P PROD2 7/23/2002 00:00 - 00:00 24.00 DRILL P PROD2 DRILL FROM 6150' TO 8600' -WOB 2-12 K--ROT 80 PI U 120K-S/060K-RW 80 K-TO 7/7500 K AST 5.5 ART 9.5, CROSS FAULT @ 8330 DRILLED SHALE TO 8590 BACK IN SAND @ 8590 7/24/2002 00:00 - 01 :00 1.00 DRILL P PROD2 DRILL FROM 8600' TO 8745' TO -WOB 2-12 K--ROT 80,250 GPM 1800 PSI, PI U 120K-S/060K-RW 80 K-TO 7/7500 K ART. 75 AST 0 01 :00 - 03:30 2.50 CASE P COMP CIRC UP BOTTOMS FOUR TIMES WITH 280 GPM, 2100 PSI, 100 RPMS 03:30 - 08:00 4.50 CASE P COMP PUMP OUT TO CSG SHOE AND DISPLACING OPEN HOLE WITH NEW MUD, MONITOR WELL, SLUG PIPE 08:00 - 09:30 1.50 CASE P COMP TRIPPING OUT TO BHA 09:30 - 11 :00 1.50 CASE P COMP LAYING DOWN BHA 11 :00 - 12:30 1.50 CASE P COMP PICK UP WHIPSTOCK RETRIVING TOOL 12:30 - 14:00 1.50 CASE P COMP TRIPPING IN WITH WHIPSTOCK RETRIVING TOOL TO 5050' 14:00 - 14:30 0.50 CASE P COMP ORIENT AND LATCH ON TO WHIPSTOCK PULL FREE WITH 50,000# OVER PULL 14:30 -19:30 5.00 CASE P COMP TRIPPING OUT WITH WHIPSTOCK AND LAYDOWN WHIPSTOCK AND SPACE OUT TOOLS 19:30 - 20:30 1.00 CASE P COMP RIG UP CSG TOOLS AND PJSM 20:30 - 23:00 2.50 CASE P COMP PICK UP 1 JT OF 4.5 LINER AND 81 JTS OF 4.5 12.6 L-80 SLOTTED LINER AND HOOK WALL HANGER 3249' 23:00 - 00:00 1.00 CASE P COMP TRIPPING IN WITH LINER 7/25/2002 00:00 - 02:00 2.00 CASE P COMP TRIPPING IN WITH LINER WENT THRU WINDOW ON FIRST TRY, TRIPPED IN TO OPEN HOLE WITH NO PROBLEMS, STRING WT. 60,000# TOOK THREE TRYS TO HOOK LINER HANGER, SHOE IS @ 8332' TOP OF LINER 5088' 02:00 - 03:00 1.00 CASE P CaMP DROP BALL PUMP DOWN @ 1 BBL MIN RELEASE FROM LINER WITH 3000 PSI, PULL UP AND SHEAR BALL WITH 4,000# 03:00 - 08:00 5.00 CASE P COMP SLUG PIPE AND TRIP OUT STANDING BACK A TOTAL OF 55 STANDS, LAYING DOWN EXCESS PIPE, LINER RUNNING TOOL 08:00 - 10:00 2.00 RUNCOrvP CaMP TRIP IN WITH MULE SHOE, OPEN ENDED TO 5060 10:00 - 12:00 2.00 RUNCOrvP COMP DISPLACE WELL WITH 220 BBLS 8.8 SEAWATER FOLLOW WITH 27 BBLS HI-VIS SPACER, 172 BBLS 8.8 SEAWATER, 255 BBLS 9.9 NACL 12:00 - 15:00 3.00 RUNCOrvP COMP LAYING DOWN DRILL PIPE 15:00 - 15:30 0.50 RUNCOrvP CaMP PULL WEAR RING 15:30 - 16:30 1.00 RUNCOrvP COMP RIG UP CSG CREWS AND I WIRE SPOOL, PJSM 16:30 - 00:00 7.50 RUNCOrvP COMP PICKING UP COMPLETION PACKER AND TOOLS, RUN IN ON 4.5, 12.6, L-80, IBT, TUBING PIU WT 88,000 SIO WT 66,000 RUN WITH 66 I-WIRE CLAMPS WIRE ENTRY GUIDE 5069, XN NIPPLE 5066, BAKER 5-3 PACKER 5021, PHOENIX JET PUMP GAUGE SENSOR 4994', XD SLIDING SLEEVE 4974', PHOENIX DISCHARGE PRESSURE GAUGE 4954', CAMCO KGB-2 GLM W/RP VALVE 2016' Printed: 7/29/2002 4:41 :08 PM ( BP Operations Summary Report Page 7 of7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-05 M PS-05 DRILL +COMPLETE DOYON DOYON 141 Start: 7/11/2002 Rig Release: 7/27/2002 Rig Number: 141 Spud Date: 7/11/2002 End: Date From - To Hours Task Code NPT Phase Description of Operations 7/26/2002 00:00 - 01 :30 1.50 RUNCOrvP COMP RIGGING UP TO LAND TUBING, LANDED SAME 01 :30 - 02:00 0.50 RIGD P COMP TEST TWO WAY CHECK TO 1,000 PSI 02:00 - 04:00 2.00 RIGD P COMP NIPPLE DOWN BOPS 04:00 - 05:30 1.50 RIGD P COMP NIPPLE UP TREE AND TEST TO 5,000 PSI 05:30 - 07:30 2.00 RIGD P COMP RIG UP LUBRICATOR AND PULL TWC HAD TROUBLE PULLING TWC 07:30 - 11 :30 4.00 RIGD N SFAL COMP ATTEMPT TO SET BPV WOULDN'T GO, TRY TWC AND IT WOULDN'T GO 11 :30 - 13:30 2.00 RIGD N SFAL COMP RIG UP HALIBURTON SLICK LINE UNIT 13:30 - 16:00 2.50 RIGD N SFAL COMP RIH WITH PLUG AND SET @ 4972' AND PULL OUT OF HOLE 16:00 - 16:30 0.50 RIGD N SFAL COMP TEST PLUG WITH 2000 PSI FOR 15 MIN., NIPPLE DOWN TREE 16:30 - 17:30 1.00 RIGD N SFAL COMP REPAIR TWC SEAL AREA OF HANGER, HONE SEAL -INSPECT AND DRY RUN TWC AND BPV THREE TIMES AND THEY WENT IN OK 17:30 - 18:00 0.50 RIGD N SFAL COMP NIPPLE UP TREE AND TEST HANGER VOID TO 5000 PSI FOR 10 MIN. 18:00 - 20:00 2.00 RIGD N SFAL COMP RUN IN WITH SLICK LINE AND RETRIEVE PLUG, RIG DOWN HALIBURTON UNIT 20:00 - 20:30 0.50 RIGD N SFAL COMP SET TWC AND TEST 41/16 TREE TO 5000 PSI10MIN 20:30 - 00:00 3.50 RIGD N SFAL COMP RIG UP LUBRICATOR AND PULL TWC AND A TTEMP TO INSTALL BPV WOULDN'T GO BUT A HALF TURN, TRY TWO DIFFERENT BPV, THE SAME ONES THAT SCREW IN WITHOUT TREE ON, TRYED TWC AND IT WENT IN, TEST CHECK TO 2,000# 7/27/2002 00:00 - 01 :00 1.00 RIGD N SFAL COMP NIPPLE DOWN TREE 01 :00 - 02:30 1.50 RIGD N SFAL COMP NIPPLE UP BOPS 02:30 - 03:00 0.50 RIGD N SFAL COMP TEST BOPS TOP RAMS AND SERVICE BREAKS TO 250-3500 PSI FOR 10 MIN. 03:00 - 04:30 1.50 RIGD N SFAL COMP RIG UP LUBRICATOR AND PULL TWC, RIG DOWN LUBRICATOR 04:30 - 06:00 1.50 RIGD N SFAL COMP RIG UP TO PULL TUBING HANGER, PULLED HANGER WITH 85,000#, CHANGING OUT HANGER 06:00 - 08:00 2.00 RIGD N SFAL COMP DRY RUN BPV AND TWC IN NEW HANGER, INSTALL I-WIRE,LAND TUBING 08:00 - 08:30 0.50 RIGD N SFAL COMP TEST TWC 1000# FOR TEN MIN. 08:30 - 09:30 1.00 RIGD N SFAL COMP NIPPLE DOWN BOPS 09:30 - 10:30 1.00 RIGD N SFAL COMP NIPPLE UP TREE AND TEST TO 5000# 10:30 - 11 :30 1.00 RIGD N SFAL COMP RIG UP LUBRICATOR A TTEMP TO PULL TWC LOST BOTTOM PART OF RETRIVEING TOOL IN TREE, RIG DOWN LUBRICATOR 11 :30 - 13:00 1.50 RIGD N SFAL COMP NIPPLE DOWN TREE AND RETRIVE TOOLS AND RENIPPLE UP TREE 13:00 - 14:00 1.00 RIGD N SFAL COMP TEST VOID AND TREE TO 5000# FOR 10 MIN. 14:00 - 14:30 0.50 RIGD P COMP PULL TWC AND SET BPV AND SECURE WELL RIG RELEASE FOR RIG MOVE 14:307/27/2002 Printed: 7/29/2002 4:41 :08 PM 8,Od-/37 14-Aug-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPS-05 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 5,132.78' MD Window / Kickoff Survey 5,189.53' MD (if applicable) Projected Survey: 8,810.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment( s) REceiVED AUG 2 3 2002 Alaska 011 & Gas Cons Go ' Anchorage rnmI&ion BP EXPLORA TION (ALASKA) INC. 0 EF' f\C-:-~V= Milne Point Unit BPXA Milne Point MPS,S/ot MPS-05 MPS-05 Job No. AKZZ22118, Surveyed: 20 July, 2002 ^-, SURVEY REPORT 13 August, 2002 Your Ref: API 500292310000 Surface Coordinates: 6000029.59 N, 566018.85 E (70024' 37.8645" N, 149027' 44.7176" W) Kelly Bushing: 66.80ft above Mean Sea Level ^- spe'-''-'Y-IIUI1 DAtL.L.ING SERVlc::es A Halliburton Company Survey Ref: svy10157 Sperry-Sun Drilling Services . Survey Report for MPS-05 Your Ref: API 500292310000 Job No. AKZZ22118, Surveyed: 20 July, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS 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) 5132.78 71.000 178.350 4052.52 4119.32 542.26 N 1540.50 E 6000585.44 N 567554.50 E -651.27 Tie On Point 5189.53 72.690 181.590 4070.21 4137.01 488.34 N 1540.52 E 6000531.53 N 567555.00 E 6.188 -597.50 Window Point 5285.53 76.420 181.480 4095.77 4162.57 395.86 N 1538.04 E 6000439.03 N 567553.34 E 3.887 -505.07 5318.73 78.850 180.620 4102.88 4169.68 363.44 N 1537.45 E 6000406.60 N 567553.03 E 7.744 -472.69 5366.40 81.960 181.230 4110.82 4177.62 316.45 N 1536.69 E 6000359.61 N 567552.68 E 6.645 -425.77 5415.51 86.430 181.860 4115.79 4182.59 267.62 N 1535.37 E 6000310.77 N 567551.80 E 9.191 -376.97 5460.08 92.090 184.050 4116.36 4183.16 223.13 N 1533.08 E 6000266.26 N 567549.89 E 13.616 -332.44 5508.63 91.970 183.590 4114.64 4181.44 174.72 N 1529.84 E 6000217.83 N 567547.09 E 0.979 -283.92 5553.63 91.910 183.790 4113.12 4179.92 129.84 N 1526.95 E 6000172.92 N 567544.59 E 0.464 -238.94 5601.88 91.480 185.290 4111.69 4178.49 81.76 N 1523.13 E 6000124.81 N 567541.20 E 3.233 -190.72 5645.71 93.330 185.830 4109.85 4176.65 38.18 N 1518.89 E 6000081.19 N 567537.34 E 4.397 -146.94 5694.90 92.960 188:240 4107.16 4173.96 10.56 S 1512.87 E 6000032.40 N 567531.76 E 4.949 -97.89 5741.52 92.830 187.880 4104.80 4171.60 56.66 S 1506.35 E 5999986.24 N 567525.64 E 0.820 -51.45 5792.05 90.680 190.290 4103.25 4170.05 106.53 S 1498.37 E 5999936.31 N 567518.10 E 6.390 -1.14 5835.30 90.000 189.310 4103.00 4169.80 149.15 S 1491.01 E 5999893.63 N 567511.12 E 2.758 41.90 5885.73 90.180 191.430 4102.92 4169.72 198.75 S 1481.93 E 5999843.95 N 567502.48 E 4.219 92.03 5928.91 90.000 192.960 4102.85 4169.65 240.95 S 1472.81 E 5999801.66 N 567493.73 E 3.568 134.78 5979.56 91.290 195.190 4102.28 4169.08 290.08 S 1460.50 E 5999752.44 N 567481.85 E 5.086 184.65 -- 6022.49 91.230 194.360 4101.34 4168.14 331.58 S 1449.55 E 5999710.84 N 567471.28 E 1.938 226.83 6073.79 92.460 196.740 4099.68 4166.48 380.97 S 1435.81 E 5999661.33 N 567457.97 E 5.220 277.08 6116.58 92.400 196.670 4097.87 4164.67 421.92 S 1423.52 E 5999620.27 N 567446.04 E 0.215 318.80 6167.14 90.740 197.870 4096.48 4163.28 470.18 S 1408.52 E 5999571.88 N 567431.47 E 4.051 368.02 6209.76 90.680 197.400 4095.96 4162.76 510.79 S 1395.60 E 5999531.16 N 567418.91 E 1.112 409.45 6261.73 90.920 198.820 4095.23 4162.03 560.18 S 1379.45 E 5999481.63 N 567403.20 E 2.771 459.87 6304.10 91.600 199.020 4094.30 4161.10 600.25 S 1365.72 E 5999441.44 N 567389.82 E 1.673 500.82 6351.62 91.540 200.820 4093.00 4159.80 644.91 S 1349.53 E 5999396.64 N 567374.03 E 3.789 546.53 6396.80 89.200 200.540 4092.70 4159.50 687.17 S 1333.58 E 5999354.23 N 567358.45 E 5.216 589.83 6446.30 88.640 200.560 4093.64 4160.44 733.51 S 1316.21 E 5999307.74 N 567341.49 E 1.132 637.29 6490.16 88.340 203.490 4094.79 4161.59 774.16 S 1299.77 E 5999266.95 N 567325.41 E 6.713 679.01 6539.14 88.340 203.110 4096.21 4163.01 819.128 1280.40 E 5999221.82 N 567306.44 E 0.776 725.25 13 August, 2002 - 11:27 Page 20'5 DrillQllest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for MPS-05 Your Ref: API 500292310000 Job No. AKZZ22118, Surveyed: 20 July, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inel. Azim. Depth Depth Northings Eastings Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 6583.26 87.350 206.150 4097.87 4164.67 859.19 S 1262.03 E 5999181.59 N 567288.42 E 7.242 766.53 6626.07 88.640 207.440 4099.37 4166.17 897.38 S 1242.74 E 5999143.23 N 567269.48 E 4.260 806.01 6677.06 89.630 211.880 4100.14 4166.94 941.67 S 1217.52 E 5999098.71 N 567244.65 E 8.920 851 .99 6725.78 91.230 214.480 4099.77 4166.57 982.45 S 1190.86 E 5999057.71 N 567218.35 E 6.266 894.57 6770.02 90.740 219.050 4099.01 4165.81 1017.87 S 1164.39 E 5999022.05 N 567192.19E 1 0.388 931 .80 6820.74 89.940 219.480 4098. 71 4165.51 1057.14 S 1132.29 E 5998982.50 N 567160.44 E 1.791 973.27 6862.55 87.410 220.440 4099.68 4166.48 1089.17 S 1105.45 E 5998950.23 N 567133.88 E 6.4 72 1007.14 6907.05 84.140 219.620 4102.96 4169.76 1123.15 S 1076.91 E 5998916.00 N 567105.64 E 7.575 1043.08 6955.80 83.840 219.550 4108.06 4174.86 116Ö.51 S 1046.02 E 5998878.37 N 567075.08 E 0.632 1082.56 6998.67 83.650 219.220 4112.73 4179.53 1193.45 S 1018.97 E 5998845.19 N 567048.33 E 0.884 1117.35 7049.90 79.600 217.870 4120.19 4186.99 1233.08 S 987.40 E 5998805.29 N 567017.11 E 8.324 1159. 14 7101.56 85.380 217.320 4126.94 4193.74 1273.65 S 956.17 E 5998764.45 N 566986.24 E 11.238 1201.84 7143.46 88.890 217.020 4129.04 4195.84 1306.99 S 930.89 E 5998730.88 N 566961.25 E 8.408 1236.91 7191.35 92.150 216.930 4128.60 4195.40 1345.24 S 902.09 E 5998692.38 N 566932.79 E 6.810 1277. 13 7236.05 89.750 215.820 4127.86 4194.66 1381.225 875.58 E 5998656.16 N 566906.61 E 5.915 1314.91 7286.85 92.280 215.290 4126.96 4193.76 1422.54 S 846.05 E 5998614.58 N 566877.44 E 5.088 1358.24 7330.49 91.660 215.630 4125.46 4192.26 1458.065 820.75 E 5998578.84 N 566852.46 E 1.620 1395.49 7377.18 90.250 214.230 4124.68 4191.48 1496.34 5 794.02 E 5998540.33 N 566826.07 E 4.255 1435.58 ~. 7422.70 91.720 213.620 4123.90 4190.70 1534.105 768.62 E 5998502.34 N 566801.00 E 3.496 1475.07 7471.71 93.140 212.660 4121.82 4188.62 1575.10 S 741.85 E 5998461.11 N 566774.60 E 3.496 1517.88 7516.22 92.590 210.690 4119.60 4186.40 1612.93 S 718.51 E 5998423.07 N 566751.59 E 4.590 1557.29 7565.43 91.790 209.860 4117.72 4184.52 1655.40 S 693.72 E 5998380.39 N 566727.18 E 2.342 1601.42 7609.24 92.950 209.570 4115.90 4182.70 1693.41 S 672.02 E 5998342.18 N 566705.81 E 2.729 1640.89 7657.94 92.400 208.910 4113.63 4180.43 1735.86 S 648.26 E 5998299.53 N 566682.43 E 1.763 1684.94 7703.48 92.520 208.320 4111.68 4178.48 1775.80 S 626.47 E 5998259.40 N 566660.99 E 1.321 1726.33 7751.95 91.730 210.790 4109.88 4176.68 1817.93 S 602.58 E 5998217.06 N 566637.48 E 5.347 1770.07 7796.76 93.450 211.520 4107.85 4174.65 1856.24 S 579.42 E 5998178.55 N 566614.66 E 4.169 1809.94 7847.37 92.650 211.030 4105.16 4171.96 1899.43 S 553.19 E 5998135.12 N 566588.80 E 1.853 1854.90 7889.39 94.430 211.480 4102.57 4169.37 1935.28 S 531.43 E 5998099.08 N 566567.36 E 4.369 1892.22 7937.84 94.370 213.260 4098.85 4165.65 1976.08 S 505.56 E 5998058.05 N 566541.86 E 3.665 1934.77 13 August, 2002 - 11:27 Page 3 of5 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for MPS-05 Your Ref: API 500292310000 Job No. AKZZ22118,Surveyed: 20 July, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 7983.06 94.370 212.870 4095.40 4162.20 2013.87 S 480.97 E 5998020.05 N 566517.60 E 0.860 1974.22 .- 8032.74 92.650 212.930 4092.36 4159.16 2055.50 S 454.03 E 5997978.18 N 566491.03 E 3.464 2017.67 8076.74 92.400 212.290 4090.42 4157.22 2092.53 S 430.34 E 5997940.95 N 566467.67 E 1.560 2056.30 8124.93 92.400 211.330 4088.41 4155.21 2133.44 S 404.96 E 5997899.81 N 566442.66 E 1.990 2098.93 8170.19 91.050 212.110 4087.04 4153.84 2171.93 S 381.18 E 5997861.12 N 566419.21 E 3.444 2139.02 8221.71 91.230 211.910 4086.02 4152.82 2215.60 S 353.88 E 5997817.20 N 566392.30 E 0.522 2184.54 8263.91 92.890 212.190 4084.50 4151.30 2251.35 S 331.50 E 5997781.26 N 566370.23 E 3.989 2221.80 8315.84 91.910 212.590 4082.33 4149.13 2295.16 S 303.70 E 5997737.21 N 566342.83 E 2.038 2267.49 8357.50 91 .600 212.120 4081.05 4147.85 2330.33 S 281.42 E 5997701.83 N 566320.86 E 1.351 2304.17 8406.90 91.480 212.160 4079.72 4146.52 2372.15 S 255.15 E 5997659.79 N 566294.96 E 0.256 2347.76 8450.87 91.540 211.980 4078.57 4145.37 2409.40 S 231.81 E 5997622.34 N 566271.95 E 0.431 2386.59 8500.60 91.540 211.380 4077.23 4144.03 2451.70 S 205.70 E 5997579.80 N 566246.22 E 1.206 2430.65 8545.03 90.370 209.900 4076.49 4143.29 2489.92 S 183.06 E 5997541.38 N 566223.92 E 4.246 2470.40 8595.19 92.220 209.690 4075.35 4142.15 2533.44 S 158.15 E 5997497.65 N 566199.39 E 3.712 2515.59 8637.69 91.720 209.520 4073.89 4140.69 2570.37 S 137.16 E 5997460.54 N 566178.73 E 1.243 2553.93 8687.66 95.920 210.040 4070.57 4137.37 2613.63 S 112.41 E 5997417.05 N 566154.36 E 8.469 2598.85 8730.81 99.760 210.460 4064.68 4131.48 2650.55 S 90.88 E 5997379.95 N 566133.15 E 8.951 2637.22 8745.43 99.770 210.280 4062.20 4129.00 2662.98 S 83.59 E 5997367.45 N 566125.98 E 1.215 2650.14 .-0 8810.00 99.770 210.280 4051.24 4118.04 2717.93 S 51.51 E 5997312.22 N 566094.38 E 0.000 2707.25 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 184.110° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8810.00ft., The Bottom Hole Displacement is 2718.42ft., in the Direction of 178.914° (True). 13 August, 2002 - 11:27 Page 4 of5 Dril/Quest 2.00.08.005 BP EXPLORATION (ALASKA) INC. Milne Point Unit Comments Measured Depth (ft) 5132.78 5189.53 8810.00 Sperry-Sun Drilling Services Survey Report for MPS-05 Your Ref: AP/500292310000 Job No. AKZZ22118, Surveyed: 20 July, 2002 . BPXA Milne Point MPS Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 4119.32 4137.01 4118.04 542.26 N 488.34 N 2717.93 S Survey tool program for MPS-05 From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 13 August, 2002 - 11:27 ~-" Comment 1540.50 E 1540.52 E 51.51 E Tie On Point Window Point Projected Survey Survey Tool Description 0.00 8810.00 4118.04 AK-6 BP _IFR-AK (MPS-05PB1) - Page 5 0'5 DrillQlIest 2.00.08.005 14-Aug-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPS-05 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 5,132.78' MD Window / Kickoff Survey 5,189.53' MD (if applicable) Projected Survey: 8,810.00 I MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ~oa-/87 BP EXPLORA TION (ALASKA) INC. Milne Point Unit BPXA Milne Point MPS, Slot MPS-05 MPS-05 MWD Job No. AKMW22118, Surveyed: 20 July, 2002 -~~ SURVEY REPORT 13 August, 2002 Your Ref: API 500292310000 Surface Coordinates: 6000029.59 N, 566018.85 E (70024' 37.8645" N, 149027' 44.7176" W) Kelly Bushing: 66.80ft above Mean Sea Level /~-- !lp&!ra..,y-su., DAILLfNG SEAVtc:e;s A Halliburton Company Survey Ref: svy10158 Sperry-Sun Drilling Services . Survey Report for MPS-05 MWD Your Ref: API 500292310000 Job No. AKMW22118, Surveyed: 20 July, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 5132.78 71 .000 178.120 4052.52 4119.32 542.57 N 1541.46 E 6000585.77 N 567555.46 E -651.66 Tie On Point ,-~~-'" 5189.53 72.690 181.590 4070.21 4137.01 488.66 N 1541.59E 6000531.86 N 567556.06 E 6.529 -597.89 Window Point 5285.53 76.420 182.380 4095.77 4162.57 396.20 N 1538.38 E 6000439.37 N 567553.67 E 3.966 -505.44 5318.73 78.850 181.150 4102.88 4169.68 363.79 N 1537.39 E 6000406.95 N 567552.96 E 8.165 -473.04 5366.40 81 .960 181.230 4110.82 4177.62 316.80 N 1536.41 E 6000359.96 N 567552.40 E 6.526 -426.10 5415.51 86.430 181.860 4115.79 4182.59 267.97 N 1535.09 E 6000311 .12 N 567551.51 E 9.191 -377.31 5460.08 92.090 184.080 4116.37 4183.17 223.49 N 1532.78 E 6000266.62 N 567549.60 E 13.640 -332.77 5508.63 91.970 183.280 4114.65 4181.45 175.07 N 1529.67 E 6000218.17 N 567546.91 E 1.665 -284.25 5553.63 91.910 183.780 4113.12 4179.92 130.18 N 1526.90 E 6000173.26 N 567544.54 E 1.118 -239.28 5601.88 91.480 185.590 4111.69 4178.49 82.11 N 1522.96 E 6000125.16 N 567541.03 E 3.854 -191.06 5645.71 93.330 185.940 4109.86 4176.66 38.55 N 1518.56 E 6000081.56 N 567537.01 E 4.296 -147.28 5694.90 92.960 188.290 4107.16 4173.96 10.19 S 1512.48 E 6000032.77 N 567531.36 E 4.829 -98.24 5741.52 92.830 187.910 4104.80 4171.60 56.28 S 1505.92 E 5999986.62 N 567525.21 E 0.860 -51 .79 5792.05 90.680 190.290 4103.25 4170.05 106.15 S 1497.93 E 5999936.69 N 567517.66 E 6.346 -1 .48 5835.30 90.000 189.120 4103.00 4169.80 148.78 S 1490.64 E 5999893.99 N 567510.75 E 3.129 41.56 5885.73 90.180 191.110 4102.92 4169.72 198.42 S 1481.78 E 5999844.27 N 567502.33 E 3.962 91.71 5928.91 90.000 191.580 4102.85 4169.65 240.76 S 1473.29 E 5999801.87 N 567494.21 E 1.166 134.55 5979.56 91.290 194.470 4102.28 4169.08 290.09 S 1461.88 E 5999752.43 N 567483.23 E 6.248 184.57 _. 6022.49 91.230 193.940 4101.34 4168.14 331.70 S 1451.35 E 5999710.73 N 567473.07 E 1.242 226.83 6073.79 92.460 196.550 4099.68 4166.48 381.175 1437.86 E 5999661.15 N 567460.03 E 5.622 277.13 6116.58 92.400 197.000 4097.87 4164.67 422.10 S 1425.53 E 5999620.11 N 567448.05 E 1.060 318.84 6167.14 90.740 197.200 4096.49 4163.29 470.405 1410.67 E 5999571.67 N 567433.62 E 3.307 368.09 6209.76 90.680 196.480 4095.96 4162.76 511.195 1398.32 E 5999530.78 N 567421.63 E 1.695 409.66 6261.73 90.920 197.670 4095.23 4162.03 560.87 S 1383.06 E 5999480.97 N 567406.82 E 2.336 460.30 6304.10 91.600 198.960 4094.30 4161.10 601.08 S 1369.75 E 5999440.64 N 567393.86 E 3.441 501.36 6351.62 91.540 200.740 4093.00 4159.80 645.76 S 1353.62 E 5999395.82 N 567378.13 E 3.747 547.08 6396.80 89.200 200.300 4092.71 4159.51 688.07 S 1337.79 E 5999353.38 N 567362.67 E 5.270 590.42 6446.30 88.640 200.740 4093.64 4160.44 734.42 S 1320.44 E 5999306.87 N 567345.73 E 1 .439 637.89 6490.16 88.340 202.680 4094.79 4161.59 775.155 1304.22 E 5999266.00 N 567329.87 E 4.474 679.68 6539.14 88.340 202.840 4096.21 4163.01 820.30 S 1285.28 E 5999220.69 N 567311.33 E 0.327 726.07 13 August, 2002 - 11:27 Page 2 of5 Dr-il/Quest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for MPS-05 MWD Your Ref: API 500292310000 Job No. AKMW22118, Surveyed: 20 July, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS 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) 6583.26 87.350 205.990 4097.87 4164.67 860.44 S 1267.06 E 5999180.39 N 567293.46 E 7.4 79 767.41 ~» 6626.07 88.640 207.040 4099.37 4166.17 898.72 S 1247.96 E 5999141.94 N 567274.70 E 3.884 806.97 6677.06 89.630 212.310 4100.14 4166.94 943.00 S 1222.73 E 5999097.43 N 567249.86 E 10.515 852.94 6725.78 91,230 214.850 4099.78 4166.58 983.58 S 1195.78 E 5999056.61 N 567223.28 E 6.161 895.35 6770.02 90.740 219.080 4099.01 4165.81 1018.92 S 1169.19E 5999021.05 N 567197.00 E 9.624 932.50 6820.74 89.940 219.710 4098.71 4165.51 1058.11 S 1137.00 E 5998981.57 N 567165.16 E 2.008 973.90 6862.55 87.410 220.360 4099.68 4166.48 1090.11 S 1110.12 E 5998949.33 N 567138.56 E 6.248 1007.75 6907.05 84.140 219.620 4102.96 4169.76 1124.11 S 1081.60 E 5998915.08 N 567110.34 E 7.533 1043.70 6955.80 83.840 219.460 4108.06 4174.86 1161.50 S 1050.74 E 5998877.42 N 567079.81 E 0.697 1083.20 6998.67 83.650 219.210 4112.73 4179.53 1194.46 S 1023.72 E 5998844.23 N 567053.09 E 0.730 1118.02 7049.90 79.600 218.150 4120.19 4186.99 1234.01 S 992.05 E 5998804.39 N 567021.77 E 8.166 1159.74 7101.56 85.380 217.580 4126.94 4193.74 1274.43 S 960.63 E 5998763.70 N 566990.71 E 11.242 1202.30 7143.46 88.890 217.440 4129.04 4195.84 1307.62 S 935.15 E 5998730.28 N 566965.53 E 8.384 1237.24 7191.35 92.150 216.860 4128.60 4195.40 1345.79 S 906.24 E 5998691.87 N 566936.95 E 6.914 1277.37 7236.05 89.750 215.780 4127.86 4194.66 1381.79 S 879.77 E 5998655.63 N 566910.80 E 5.887 1315.19 7286.85 92.280 215.300 4126.96 4193.76 1423.12 S 850.25 E 5998614.04 N 566881.64 E 5.069 1358.52 7330.49 91.660 215.710 4125.46 4192.26 1458.63 S 824.92 E 5998578.31 N 566856.63 E 1.703 1395.75 7377.18 90.250 214.290 4124.68 4191.48 1496.86 S 798.14 E 5998539.84 N 566830.19 E 4.286 1435.81 7422.70 91.720 213.660 4123.90 4190.70 1534.61 S 772.71 E 5998501.87 N 566805.09 E 3.513 1475.28 >'-c 7471.71 93.140 212.750 4121.82 4188.62 1575.58 S 745.89 E 5998460.67 N 566778.64 E 3.440 1518.06 7516.22 92.590 210.510 4119.60 4186.40 1613.42 S 722.58 E 5998422.62 N 566755.67 E 5.176 1557.49 7565.43 91.790 209.680 4117.72 4184.52 1655.97 S 697.93 E 5998379.86 N 566731.39 E 2.342 1601.69 7609.24 92.950 209.430 4115.91 4182.71 1694.04 S 676.33 E 5998341.59 N 566710.13 E 2.708 1641.21 7657.94 92.400 208.670 4113.63 4180.43 1736.57 S 652.71 E 5998298.86 N 566686.89 E 1.925 1685.32 7703.48 92.520 207.990 4111.68 4178.48 1776.62 S 631.12 E 5998258.62 N 566665.65 E 1.515 1726.82 7751.95 91.730 210.290 4109.88 4176.68 1818.92 S 607.54 E 5998216.11 N 566642.44 E 5.014 1770.70 7796,76 93.450 210.960 4107.86 4174.66 1857.44 S 584.74 E 5998177.39 N 566619.98 E 4.119 1810.76 7847.37 92.650 210.100 4105.16 4171.96 1900.97 S 559.06 E 5998133.63 N 566594.69 E 2.319 1856.01 7889.39 94.430 210.910 4102.57 4169.37 1937.11 S 537.77 E 5998097.31 N 566573.73 E 4.652 1893.58 7937.84 94.370 212.440 4098.85 4165.65 1978.22 S 512.41 E 5998055.98 N 566548.73 E 3.151 1936.40 13 August, 2002 - 11:27 Page 30f5 DrillQlIest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for MPS-05 MWD Your Ref: API 500292310000 Job No. AKMW22118, Surveyed: 20 July, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 7983.06 94.370 212.360 4095.41 4162.21 2016.28 S 488.25 E 5998017.70 N 566524.90 E 0.176 1976.11 8032.74 92.650 212.410 4092.36 4159.16 2058.16 S 461.69 E 5997975.59 N 566498.72 E 3.464 2019.77 8076.74 92.400 211.710 4090.43 4157.23 2095.41 S 438.36 E 5997938.14 N 566475.71 E 1.688 2058.60 8124.93 92.400 210.930 4088.41 4155.21 2136.54 S 413.33 E 5997896.78 N 566451.05 E 1.617 2101.42 8170.19 91.050 211.030 4087.04 4153.84 2175.33 S 390.05 E 5997857.80 N 566428.11 E 2.991 2141.78 8221.71 91 .230 210.760 4086.02 4152.82 2219.53 S 363.60 E 5997813.36 N 566402.05 E 0.630 2187.76 8263.91 92.890 211.410 4084.50 4151.30 2255.64 S 341.82 E 5997777.06 N 566380.60 E 4.224 2225.34 8315.84 91.910 212.000 4082.33 4149.13 2299.78 S 314.56 E 5997732.68 N 566353.72 E 2.202 2271.33 8357.50 91.600 212.110 4081.05 4147.85 2335.08 S 292.46 E 5997697.19 N 566331.94 E 0.790 2308.11 8406.90 91.480 212.020 4079.72 4146.52 2376.92 S 266.24 E 5997655.11 N 566306.09 E 0.304 2351.73 8450.87 91.540 211.680 4078.57 4145.37 2414.26 S 243.05 E 5997617.57 N 566283.23 E 0.785 2390.63 8500.60 91.540 211.180 4077.23 4144.03 2456.68 S 217.12 E 5997574.93 N 566257.68 E 1.005 2434.80 8545.03 90.370 210.100 4076.49 4143.29 2494.90 S 194.48 E 5997536.51 N 566235.38 E 3.583 2474.54 8595.19 92.220 209.640 4075.36 4142.16 2538.38 S 169.51 E 5997492.80 N 566210.79 E 3.800 2519.71 8637.69 91.720 209.690 4073.89 4140.69 2575.29 S 148.49 E 5997455.71 N 566190.10 E 1.182 2558.03 8687.66 95.920 210.360 4070.57 4137.37 2618.45 S 123.55 E 5997412.33 N 566165.54 E 8.511 2602.86 8730.81 99.760 210.500 4064.68 4131.48 2655.30 S 101.90 E 5997375.29 N 566144.22 E 8.905 2641 .17 8745.43 99.770 210.330 4062.20 4129.00 2667.73 S 94.61 E 5997362.80 N 566137.03 E 1.148 2654.09 ,,-" 8810.00 99.770 210.330 4051.24 4118.04 2722.65 S 62.47 E 5997307.60 N 566105.39 E 0.000 2711.17 Projected Survey l All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 184.110° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8810.00ft., The Bottom Hole Displacement is 2723.37ft., in the Direction of 178.686° (True). - --'------.--------- 13 August, 2002 - 11:27 Page 4 0'5 DrillQlIest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPS-05 MWD Your Ref: API 500292310000 Job No. AKMW22118, Surveyed: 20 July, 2002 . BP EXPLORATION (ALASKA) INC. Milne Point Unit BPXA Milne Point MPS Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 5132.78 5189.53 8810.00 4119.32 4137.01 4118.04 542.57 N 488.66 N 2722.65 S 1541.46 E 1541.59 E 62.47 E Tie On Point Window Point Projected Survey Survey tool program for MPS-05 MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 8810.00 4118.04 MWD Magnetic (MPS-05PB1 MWD) -'. 13 August, 2002 - 11:27 Page 50f5 DrillQlIest 2.00.08.005 dOd- /3 f 14-Aug-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPS-05PB 1 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD , M D (if applicable) 5,528.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 'Ì-,. / " ...~ \../ /ù~~.~ .:.[;. ":, '}(. ::: (".~ ',- ",." BP EXPLORATION (ALASKA) INC. .)=Ff.\ 'T1VE Milne Point Unit BPXA Milne Point MPS, Slot MPS-05 MPS-05PB1 Job No. AKZZ22118, Surveyed: 14 July, 2002 ~- SURVEY REPORT 13 August, 2002 Your Ref: API 500292310070 Surface Coordinates: 6000029.59 N, 566018.85 E (700 24' 37.8645" N, 1490 27' 44. 7176" W) Kelly Bushing: 66.80ft above Mean Sea Level --", sr--""'Y-!lU" t1AILLING SERVICES A Halliburton Company Survey Ref: 5vy10144 Sperry-Sun Drilling Services . Survey Report for MPS-05PB1 Your Ref: API 500292310070 Job No. AKZZ22118, Surveyed: 14 July, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 0.00 0.000 0.000 -66.80 0.00 0.00 N O.OOE 6000029.59 N 566018.85 E 0.00 AK-6 BPJFR-AK 98.00 0.250 7.790 31.20 98.00 0.21 N 0.03E 6000029.80 N 566018.88 E 0.255 -0.21 176.98 0.490 7.790 110.18 176.98 0.72N 0.10 E 6000030.31 N 566018.94 E 0.304 -0.72 203.31 0.490 23.880 136.51 203.31 0.93N 0.16E 6000030.52 N 566019.00 E 0.521 -0.94 292.01 1.230 4.370 225.20 292.00 2.23N 0.39E 6000031.82 N 566019.22 E 0.885 -2.25 380.06 2.220 8.250 313.21 380.01 4.86N 0.70E 6000034.45 N 566019.51 E 1.132 -4.90 470.80 3.440 20.110 403.83 470.63 9.15 N 1.89 E 6000038.76 N 566020.66 E 1 .484 -9.27 559.70 5.640 27.650 492.45 559.25 15.53 N 4.83E 6000045.16 N 566023.55 E 2.559 -15.84 647.32 9.540 32.360 579.29 646.09 25.48 N 10.72 E 6000055.16 N 566029.35 E 4.504 -26.18 738.93 13.990 35.360 668.95 735.75 40.93 N 21.20 E 6000070.71 N 566039.69 E 4.902 -42.35 .' 833.4 7 17.680 39.570 759.89 826.69 61.32 N 36.96 E 6000091.24 N 566055.27 E 4.085 -63.82 927.87 19.350 37.740 849.40 916.20 84.74 N 55.67 E 6000114.82 N 566073.77 E 1.873 -88.52 1021.09 23.050 33.870 936.30 1003.10 112.12 N 75.30 E 6000142.37 N 566093.16 E 4.242 -117.23 1114.61 26.610 32.920 1021.16 1087.96 144.91 N 96.89 E 6000175.35 N 566114.46 E 3.830 -151.49 1208.23 29.160 31.290 1103.91 1170.71 182.01 N 120.14E 6000212.66 N 566137.37 E 2.843 -190.15 1301.10 32.450 29.380 1183.67 1250.47 223.07 N 144.12 E 6000253.92 N 566160.99 E 3.695 -232.82 1393.22 36.790 30.160 1259.46 1326.26 268.48 N 170.11 E 6000299.56 N 566186.59 E 4.736 -279.98 1487.73 39.980 30.380 1333.53 1400.33 319.15N 199.70 E 6000350.49 N 566215.72 E 3.378 -332.64 -, 1581.32 41.300 30.810 1404.55 1471.35 371.62 N 230.72 E 6000403.23 N 566246.28 E 1.442 -387.20 1676.24 41.050 30.450 1475.99 1542.79 425.39 N 262.56 E 6000457.28 N 566277.64 E 0.363 -443.11 1769.13 42.490 32.890 1545.28 1612.08 478.03 N 295.06 E 6000510.21 N 566309.67 E 2.338 -497.95 1863.34 41.970 34.670 1615.04 1681.84 530.66 N 330.26 E 6000563.15 N 566344.40 E 1.385 -552.97 1955.74 43.100 35.570 1683.12 1749.92 581.75 N 366.20 E 6000614.56 N 566379.89 E 1.389 -606.50 2048.84 42.690 35.640 1751.33 1818.13 633.27 N 403.09 E 6000666.40 N 566416.33 E 0.443 -660.54 2142.30 42.390 35.980 1820.19 1886.99 684.52 N 440.06 E 6000717.97 N 566452.84 E 0.404 -714.30 2236.42 44.710 35.680 1888.40 1955.20 737.09 N 478.02 E 6000770.88 N 566490.33 E 2.475 -769.46 2329.41 46.270 36.540 1953.59 2020.39 790.66 N 517.10 E 6000824.79 N 566528.94 E 1.803 -825.69 2424.52 46.260 36.710 2019.34 2086.14 845.81 N 558.10 E 6000880.30 N 566569.45 E 0.130 -883.64 2514.52 45.030 37.020 2082.26 2149.06 897.30 N 596.70 E 6000932.13 N 566607.60 E 1.389 -937.76 2609.65 42.900 39.340 2150.73 2217.53 949.22 N 637.50 E 6000984.40 N 566647.93 E 2.807 -992.46 13 August, 2002 - 11:27 Page 20f5 Dri/lQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for MPS-05PB1 Your Ref: AP/500292310070 Job No. AKZZ22118, Surveyed: 14 July, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 2703.07 43.060 39.410 2219.07 2285.87 998.45 N 677.90 E 6001033.99 N 566687.90 E 0.179 -1044.47 2796.33 43.630 38.730 2286.90 2353.70 1048.15 N 718.24 E 6001084.04 N 566727.80 E 0.790 -1096.93 2890.36 43.940 42.590 2354.79 2421.59 1097.48 N 760.63 E 6001133.75 N 566769.74 E 2.859 -1149.17 2983.32 43.160 46.340 2422.18 2488.98 1143.18 N 805.46 E 6001179.85 N 566814.18 E 2.903 -1197.97 3076.80 42.600 49.860 2490.69 2557.49 1185.66 N 852.78 E 6001222.74 N 566861.12 E 2.631 -1243.73 3169.77 39.050 51.770 2561.03 2627.83 1224.08 N 899.86 E 6001261.57 N 566907.85 E 4.047 -1285.42 3263.61 35.800 54.340 2635.55 2702.35 1258.38 N 945.39 E 6001296.28 N 566953.08 E 3.842 -1322.90 3357.47 32.250 61.180 2713.36 2780.16 1286.48 N 989.67 E 6001324.76 N 566997.11 E 5.557 -1354.10 3449.85 28.610 69.950 2793.04 2859.84 1305.96 N 1032.08 E 6001344.62 N 567039.34 E 6.208 -1376.57 3544.23 28.360 80.730 2876.05 2942.85 1317.32 N 1075.46 E 6001356.37 N 567082.62 E 5.448 -1391.01 3637.35 29.200 89.070 2957.70 3024.50 1321.26N 1120.02 E 6001360.69 N 567127.14 E 4.402 -1398.13 3731.13 30.330 97.660 3039.14 3105.94 1318.47 N 1166.38 E 6001358.32 N 567173.53 E 4.700 -1398.67 3824.04 32.580 106.810 3118.44 3185.24 1308.10 N 1213.61 E 6001348.37 N 567220.85 E 5.675 -1391.72 3918.18 33.420 114.750 3197.43 3264.23 1289.91 N 1261.44 E 6001330.60 N 567268.84 E 4.677 -1377.00 4010.65 34.210 123.620 3274.30 3341.10 1264.84 N 1306.24 E 6001305.93 N 567313.86 E 5.402 -1355.21 4104.65 35.220 134.000 3351.64 3418.44 1231.35 N 1347.78 E 6001272.80 N 567355.69 E 6.373 -1324.78 4198.32 36.520 144.050 3427.61 3494.41 1189.98 N 1383.60 E 6001231.76 N 567391.88 E 6.432 -1286.09 4291.89 36.760 152.090 3502.73 3569.53 1142.67 N 1413.07 E 6001184.71 N 567421.77 E 5.132 -1241.01 4385.05 36.440 158.600 3577.55 3644.35 1092.26 N 1436.23 E 6001134.50 N 567445.36 E 4.179 -1192.39 4478.83 39.030 160.170 3651.71 3718.51 1038.54 N 1456.41 E 6001080.97 N 567466.02 E 2.946 -1140.25 4572.53 41.210 162.110 3723.36 3790.16 981.41 N 1475.90 E 6001024.00 N 567486.02 E 2.682 -1084.66 4664.87 43.850 165.200 3791.41 3858.21 921.52 N 1493.42 E 6000964.27 N 567504.07 E 3.645 -1026.18 4759.42 47.910 168.550 3857.23 3924.03 855.43 N 1508.76 E 6000898.33 N 567519.99 E 4.990 -961.37 4851.94 51.920 171.410 3916.80 3983.60 785.74 N 1521.02 E 6000828.75 N 567532.87 E 4.937 -892.74 4944.88 57.550 174.680 3970.45 4037.25 710.46 N 1530.13 E 6000753.54 N 567542.64 E 6.703 -818.30 5038.65 63.790 176.320 4016.36 4083.16 629.00 N 1536.50 E 6000672.15 N 567549.73 E 6.827 -737.51 5132.78 71.000 178.350 4052.52 4119.32 542.26 N 1540.50 E 6000585.44 N 567554.50 E 7.914 -651.27 5225.84 79.790 181.200 4075.97 4142.77 452.30 N 1540.81 E 6000495.49 N 567555.60 E 9.898 -561.57 5319.31 84.450 182.510 4088.78 4155.58 359.79 N 1537.81 E 6000402.96 N 567553.42 E 5.175 -469.08 5412.93 84.080 182.740 4098.13 4164.93 266.74 N 1533.54 E 6000309.87 N 567549.97 E 0.465 -375.96 13 August, 2002 - 11:27 Page 3 0'5 Dri/lQuesf 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPS-05PB1 Your Ref: API 500292310070 Job No. AKZZ22118, Surveyed: 14 July, 2002 . BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs . Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 5459.63 84.640 182.550 4102.72 4169.52 220.31 N 1531.40 E 6000263.43 N 567548.24 E 1.266 -329.51 ~.. 5528.00 84.640 182.550 4109.11 4175.91 152.31 N 1528.37 E 6000195.40 N 567545.81 E 0.000 -261.46 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 184.110° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 5528.00ft., The Bottom Hole Displacement is 1535.94ft, in the Direction of 84.309° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 5528.00 4175.91 152.31 N 1528.37 E Projected Survey 13 August, 2002 - 11:27 Page 4 0'5 DrillQIIp.st 2.00.08.005 BP EXPLORATION (ALASKA) INC. Milne Point Unit Survey tool program for MPS-05PB1 '-- From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) Sperry-Sun Drilling Services Survey Report for MPS-05PB1 Your Ref: API 500292310070 Job No. AKZZ22118, Surveyed: 14 July, 2002 . ." BPXA Milne Point MPS Survey Tool Description 0.00 0.00 5528.00 4175.91 AK-6 BP _IFR-AK 13 August, 2002 - 11:27 Page 50'5 DrillQuest 2.00.08.005 a~,.Jt3 7 14-Aug-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPS-05PB 1 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00 I MD , M D (if applicable) 5,528.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED 1"1""\ 2 .... ~U(J J 2002 AlækaOlJ & Gas Cons. CommíaøIo Anchorage n ~ . ex) ---< \ r() -0 l(J BP EXPLORA T/ON (ALASKA) INC. Milne Point Unit BPXA Milne Point MPS, Slot MPS-05 MPS-05PB1MWD Job No. AKMW22118, Surveyed: 14 July, 2002 SURVEY REPORT 13 August, 2002 Your Ref: API 500292310070 Surface Coordinates: 6000029.59 N, 566018.85 E (70024' 37.8645" N, 149027' 44.7176" W) Kelly Bushing: 66.80ft above Mean Sea Level Spe==I......."Y-!8Uf1 DRILLING SE,..v.c:es A Halliburton Company Survey Ref: 5vy10156 Sperry-Sun Drilling Services . Survey Report for MPS.05PB1 MWD Your Ref: API 500292310070 Job No. AKMW22118, Surveyed: 14 July, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 0.00 0.000 0.000 -66.80 0.00 O.OON 0.00 E 6000029.59 N 566018.85 E 0.00 MWD Magnetic 98.00 0.250 196.390 31.20 98.00 0.21 S 0.06W 6000029.38 N 566018.79 E 0.255 0.21 176.98 0.490 7.980 110.18 176.98 0.048 0.06W 6000029.55 N 566018.79 E 0.935 0.04 203.31 0.490 24.190 136.51 203.31 0.18 N O.OOE 6000029.77 N 566018.85 E 0.525 -0.18 292.01 1.230 6.150 225.20 292.00 1.47 N 0.26E 6000031.06 N 566019.09 E 0.878 -1.49 380.06 2.220 9.010 313.21 380.01 4.09N 0.63 E 6000033.69 N 566019.44 E 1.128 -4.13 470.80 3.440 20.980 403.83 470.63 8.37N 1.88 E 6000037.98 N 566020.65 E 1 .487 -8.49 559.70 5.640 27.690 492.45 559.25 14.73 N 4.86E 6000044.36 N 566023.58 E 2.542 -15.04 647.32 9.540 32.540 579.29 646.09 24.67 N 10.77 E 6000054.35 N 566029.40 E 4.507 -25.38 738.93 13.990 35.530 668.95 735.75 40.09 N 21.29 E 6000069.87 N 566039.79 E 4.901 -41.51 833.47 17.680 39.540 759.89 826.69 60.47 N 37.08 E 6000090.38 N 566055.39 E 4.069 -62.97 927.87 19.350 37.530 849.40 916.20 83.93 N 55.73 E 6000114.01 N 566073.84 E 1.894 -87.70 1021.09 23.050 33.840 936.30 1003.10 111.34 N 75.31 E 6000141.59 N 566093.17 E 4.218 -116.45 1114.61 26.610 32.430 1021.16 1087.96 144.24 N 96.75 E 6000174.68 N 566114.32 E 3.859 -150.80 1208.23 29.160 30.250 1103.91 1170.71 181.64N 119.48 E 6000212.28 N 566136.72 E 2.933 -189.74 1301.10 32.450 29.350 1183.67 1250.47 222.92 N 143.10 E 6000253.76 N 566159.98 E 3.577 -232.60 1393.22 36.790 30.040 1259.46 1326.26 268.36 N 169.04 E 6000299.43 N 566185.51 E 4.730 -279.79 1487.73 39.980 30.290 1333.53 1400.33 319.09 N 198.53 E 6000350.42 N 566214.55 E 3.379 -332.50 1581.32 41.300 30.770 1404.55 1471.35 371.59 N 229.49 E 6000403.20 N 566245.05 E 1.449 -387.08 1676.24 41.050 30.370 1475.99 1542.79 425.40 N 261.28 E 6000457.28 N 566276.35 E 0.383 -443.03 1769.13 42.490 33.050 1545.28 1612.08 478.02 N 293.81 E 6000510.18 N 566308.42 E 2.469 -497.84 1863.34 41.970 34.650 1615.04 1681.84 530.60 N 329.07 E 6000563.08 N 566343.22 E 1.268 -552.82 1955.74 43.100 35.760 1683.12 1749.92 581.64 N 365.09 E 6000614.43N 566378.78 E 1 .468 -606.31 2048.84 42.690 35.840 1751.33 1818.13 633.03 N 402.16 E 6000666.15 N 566415.40 E 0.444 -660.23 2142.30 42.390 36.330 1820.19 1886.99 684.10 N 439.37 E 6000717.55 N 566452.16 E 0.478 -713.83 2236.42 44.710 35.930 1888.40 1955.20 736.4 7 N 477.60 E 6000770.26 N 566489.92 E 2.482 -768.81 2:~29.41 46.270 36.570 1953.59 2020.39 789.95 N 516.82 E 6000824.07 N 566528.66 E 1.748 -824.96 2424.52 46.260 37.070 2019.34 2086.14 844.96 N 558.00 E 6000879.45 N 566569.36 E 0.380 -882.78 2!514.52 45.030 37.340 2082.26 2149.06 896.21 N 596.91 E 6000931.04 N 566607.82 E 1.383 -936.69 2ß09.65 42.900 38.940 2150.73 2217.53 948.16 N 637.68 E 6000983.35 N 566648.12 E 2.525 -991.42 -.- .. --..------ ------- --- - 13 August, 2002 - 11:28 Page 20f5 DrillQlIest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for MPS-05PB1 MWD Your Ref: API 500292310070 Job No. AKMW2211B, Surveyed: 14 July, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 2703.07 43.060 39.090 2219.07 2285.87 997.64 N 677.77 E 6001033.19 N 566687.78 E 0.203 -1043.66 2796.33 43.630 38.330 2286.89 2353.69 1047.60 N 717.80 E 6001083.49 N 566727.36 E 0.829 -1096.35 '~ 2890.36 43.940 42.360 2354.79 2421.59 1097.16 N 759.91 E 6001133.42 N 566769.03 E 2.984 -1148.80 2983.32 43.160 46.010 2422.18 2488.98 1143.08 N 804.52 E 6001179.74 N 566813.24 E 2.832 -1197.80 3076.80 42.600 49.630 2490.69 2557.49 1185.79 N 851.64 E 6001222.86 N 566859.97 E 2.702 -1243.78 3169.77 39.050 51.570 2561.03 2627.83 1224.38 N 898.57 E 6001261.87 N 566906.56 E 4.054 -1285.64 3263.61 35.800 54.340 2635.55 2702.35 1258.77 N 944.04 E 6001296.65 N 566951.73 E 3.900 -1323.19 3357.47 32.250 61.140 2713.36 2780.16 1286.88 N 988.31 E 6001325.15 N 566995.74 E 5.540 -1354.40 3449.85 28.610 69.950 2793.04 2859.84 1306.38 N 1030.71 E 6001345.02 N 567037.97 E 6.225 -1376.89 3544.23 28.360 80.770 2876.05 2942.85 1317.73 N 1074.09 E 6001356.76 N 567081.25 E 5.468 -1391.32 3637.35 29.200 89.070 2957.70 3024.50 1321.64 N 1118.65 E 6001361.07 N 567125.77 E 4.382 -1398.42 3731.13 30.330 97.710 3039.14 3105.94 1318.84 N 1165.01 E 6001358.67 N 567172.16 E 4.726 -1398.94 3824.04 32.580 106.790 3118.44 3185.24 1308.46 N 1212.24 E 6001348.71 N 567219.47 E 5.639 -1391.97 3918.18 33.420 114.760 3197.43 3264.23 1290.27 N 1260.07 E 6001330.95 N 567267.46 E 4.694 -1377.26 4010.65 34.210 123.780 3274.30 3341 .10 1265.13 N 1304.83 E 6001306.21 N 567312.44 E 5.491 -1355.40 4104.65 35.220 134.180 3351.64 3418.44 1231.52 N 1346.27 E 6001272.96 N 567354.18 E 6.385 -1324.84 4198.32 36.520 143.950 3427.61 3494.41 1190.12 N 1382.07 E 6001231.88 N 567390.35 E 6.262 -1286.12 4291.89 36.760 152.280 3502.73 3569.53 1142.80 N 1411.50 E 6001184.82 N 567420.19 E 5.316 -1241.02 4385.05 36.440 158.910 3577.55 3644.35 1092.29 N 1434.43 E 6001134.51 N 567443.57 E 4.256 -1192.29 4478.83 39.030 160.240 3651.71 3718.51 1038.50 N 1454.44 E 6001080.91 N 567464.05 E 2.895 -1140.07 4572.53 41.210 162.050 3723.36 3790.16 981.36 N 1473.93 E 6001023.94 N 567484.05 E 2.638 -1084.48 4664.87 43.850 165.210 3791.41 3858.21 921.48 N 1491.47 E 6000964.22 N 567502.12 E 3.677 -1026.01 4 '159.42 47.910 168.170 3857.23 3924.03 855.45 N 1507.03 E 6000898.32 N 567518.26 E 4.846 -961.26 4851.94 51.920 170.850 3916.80 3983.60 785.86 N 1519.87 E 6000828.85 N 567531.71 E 4.867 -892.77 4944.88 57.550 173.900 3970.45 4037.25 710.68 N 1529.86 E 6000753.77 N 567542.37 E 6.623 -818.50 5038.65 63.790 175.970 4016.36 4083.16 629.29 N 1537.03 E 6000672.45 N 567550.26 E 6.927 -737.84 5132.78 71.000 178.120 4052.52 4119.32 542.57 N 1541.46 E 6000585.77 N 567555.46 E 7.944 -651.66 5225.84 79.790 181.030 4075.97 4142.77 452.62 N 1542.09 E 6000495.82 N 567556.88 E 9.917 -561.98 5319.31 84.450 182.700 4088.78 4155.58 360.11 N 1539.07 E 6000403.29 N 567554~67 E 5.290 -469.49 5412.93 84.080 182.970 4098.14 4164.94 267.07 N 1534.46 E 6000310.22 N 567550.89 E 0.488 -376.36 13 August, 2002 - 11:28 . Page 3 0'5 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPS-OSPB1 MWD Your Ref: API 500292310070 Job No. AKMW22118, Surveyed: 14 July, 2002 BP EXPLORATION (ALASKA) INC. Milne Point Unit Measured Depth (ft) Sub-Sea Vertical Depth Depth (ft) (ft) local Coordinates Northlngs Eastlngs (ft) (ft) Incl. Azim. 5459.63 84.640 182.590 5528.00 84.640 182.590 4102.73 4109.11 4169.53 4175.91 220.66 N 152.65 N 1532.21 E 1529.13 E Global Coordinates Northlngs Eastlngs (ft) (ft) 6000263.78 N 6000195.75 N 567549.05 E 567546.57 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 184.110° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 5528.00ft., The Bottom Hole Displacement is 1536.73ft., in the Direction of 84.299° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 5528.00 4175.91 152.65 N 1529.13 E Projected Survey 13 August, 2002 - 11:28 Page 4 0'5 Dogleg Vertical Rate Section (0/100ft) 1 .447 0.000 . BPXA Milne Point MPS Comment -329.90 -261.86 Projected Survey DrillQuest 2.00.08.005 BP EXPLORATION (ALASKA) INC. Milne Point Unit Survey tool program for MPS-05PB1 MWD ~~~- From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 5528.00 4175.91 MWD Magnetic 13 August, 2002 ~ 11:28 Sperry-Sun Drilling Services Survey Report for MPS-05PB1 MWD Your Ref: API 500292310070 Job No. AKMW22118~ Surveyed: 14 July~ 2002 . BPXA Milne Point MPS Survey Tool Description Page 5 0'5 Dril/Qflest 2.00.08.005 ~7~1fŒ I rTIì~ !þ ~~ ( Æ\ ~ /À\ ~J,« Æ\ IJ1J \ "-, lJìJ @ U~. ùu TONY KNOWLES, GOVERNOR AT,ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Pat Archey Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Milne Point Unit IvIPS-05 BP Exploration (Alaska), Inc. Permit No: 202-137 Surface Location: 3360' NSL, 4772' WEL, Sec. 07, T12N, RIlE, UM Bottomhole Location: 636' NSL, 186' WEL, Sec. 12, TI2N, R10E, UM Dear Mr. Archey: Enclosed is the approved application for permit to drill the above development well. The 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. Blowout prevention equipment (BOPE) must be tested in accordance with 20AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, r¡¡~MALA/t:1LL .~ ~~~~-&6chsli Taylor Chair BY ORDER OF THE COMMISSION DATED thisM day of July, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA( -'- AND GAS CONSERVATION COMJ ,ION PERMIT TO DRILL 20 MC 25.005 1 a. Type of work III Drill 0 Redrill 1 b. Type of well 0 Exploratory 0 Stratigraphic Test III Development Oil 0 Re-Entry 0 Deepen 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Planned KBE = 681 Milne Point Unit I Schrader 3. Address 6. Property Designation Bluff P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 380109 4. Location of well at surface 7. Unit or Property Name 33601 NSL, 47721 WEL, SEC. 07, T12N, R11 E, UM Milne Point Unit At top of productive interval 8. Well Number 35001 NSL, 3217' WEL, SEC. 07, T12N, R11E, UM (OB) MPS-05 At total depth 9. Approximate spud date 6361 NSL, 1861 WEL, SEC. 12, T12N, R10E, UM (OB) July 12, 2002 :/ Amount $200,000.00 12. Distance to nearest property line 13. Distance to nearest weill 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 380110,1861 MD (Approx.) No Close Approach 2560 90151 MD 142461 TVD 16. To be completed for deviated wells 17. Anticipated pressure {s,e 20 MC 25.035 (e) (2)} Kick Off Depth 3001 MD Maximum Hole Angle 900 Maximum surface 1488 psig, At total depth (TVD) 42561 11914 psig 18. Casin~ Program Specifications Setting Depth $Ize T<,p Botom Hole Casino WeiQht Grade Couplint~ LenQth ~D TVD Mn TVD 42" 20" 92# H-40 Welded 821 301 30' 1121 1121 9-7/8" 7-5/811 29.7# L-80 BTC 5550' 30' 30' 5580' 42171 6-1/8" 4-1/2" 12.6# L-80 IBT 34351 55801 4217' 9015' 42461 ilJCA- 7/JIOL ~ 7!r 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 Quantity of Cement (include staçse data) ,260 sx Arctic Set (Approx.) 966 sx PF ILl, 285 sx Class IG' Uncemented Slotted Liner ./ 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical feet feet feet feet Junk (measured) Plugs (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD RECEIVED 12002 true vertical -¡a Oil & Gas Cons. Commission - - Anchorage ORIGINAL Perforation depth: measured 20. Attachments III Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch B Drilling Program III Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Matt Green, 564-5581 Steve Campbell, 564-4401 Prepared By Name/Number: Sondra Stewman, 564-4750 21. I hereby certtfy that the regoi~S true and correct to the best of my knowledge Date I ~ I""'). /}}¡:/J ~') -=5 u..--JY1P"-- Title Senior Drilling Engineer (¿) I <-~/ (/ ~ Permit Number ..zaG --/27 Conditions of Approval: API Number 3. ) 50- 0<..9- Z 00 Samples Required 0 Yes 11 No Hydrogen Sulfide Measures 0 Yes 13 No Required Working Pressure for BOPE 0 2K 0 3K Other:T~ f ß~ P E +ø t{OOO f Ll . 0ngiOal Signed By Cammy Oœhsli T ayl~( Commissioner ~l£a I te See cover letter .. I_I '11.,1/ ", for other reauirements Mud LoglÁ'êq ired 0 Yes .II No Directional Survey Required §I Yes 0 No D4K D5K D10K D15K 0 3.5K psi forCTU Date 7h6~ ~~f:~riPlicate by order of the commission Approved By Form 10-401 Rev. 12-01-85 ( IWell Name: IMPS-05 Drill and Complete Plan Summary Milne P~ MPS-05 Well Permit I Type of Well (service / producer / injector): I Multi Lateral Producer "OA" & "DB" Surface Location: 19191 FNL, (33601 FSL), 47721 FEL, (81 FWL), SEC. 7, T12N, R11 E E=566018.85 N=6000029.59 15731 FNL, (37061 FSL), 3216 FEL, (15631 FWL), SEC. 7, T12N,R11 E E=567570.46 N=6000389.85 Z=4176' TVD 46421 FNL, (6361 FSL), 186 FEL, (50921 FWL), SEC. 12, T12N,R1 DE E=565847.00 N=5997304.00 Z=4192' TVD 1778' FNL, (35001 FSL), 3217' FEL, (15621 FWL), SEC. 7, T12N,R11E E=567571.37 N=6000184.33 Z=4223' TVD 46421 FNL, (6361 FSL), 186 FEL, (50921 FWL), SEC. 12, T12N,R1 OE E=565847.00 N=5997304.00 Z=4246' TVD 46421 FNL, (6361 FSL), 186 FEL, (50921 FWL), SEC. 12, T12N,R1 DE E=565847.00 N=5997304.00 Z=4246' TVD I AFE Number: I MSD337291 / I Rig: I Doyon 141 / I 1 Estimated Start Date: 112 Jul 2002 1 I Operating days to complete: 117.1 I 1 MD: 19015 1 I TVD: 14246 1 I Max Inc: 190 I I KOP: 1300 I I KBE: 168 I 1 Well Design (conventional, slim hole, etc.): I Conventional Grass Roots ML Producer I I Target Location: TOP "OA" Target Location: BHL "OA" Well TO Target Location: TOP "OB" Target Location: BHL "OB" Well TD TOTAL DEPTH 1 Objective: 1 Schrader DB Sand Mud Program: 9-7/8" Surface Hole Mud Properties: Density (ppg) Funnel visc VP 8.6 - 9.20/ 75 - 150 25 - 60 Spud - LSND Freshwater Mud pH API Filtrate LG Solids < 6.5 HTHP N/A 9.0-9.5 <8 6-1/8" Production Hole Mud Properties: Density (ppg) Funnel visc VP HTHP KCL-CaC03 Flow Pro pH API Filtrate LG Solids <12 8.6 - 9.20 40 55 22 - 27 <10 8.0 - 8.5 4 - 6 LCM Restrictions: No Organic LCM products in the Schrader Bluff formation Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to D8-4 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 ( Cement Program: Milne Pt( MPS-05 Well Permit Casing Size 17.625-in 29.7-lb/ft L-80 BTC Intermediate Casing B . 250% excess over gauge hole in permafrost interval, 40% excess over gauge hole below aSlS permafrost Pump lead to surface before switching to tail. Have additional 300-sx lead cement on location. Total Cement Volume: 772-bbl Wash 50 bbl of Newtonian Wash weighted to 8.32 ppg 50 bbl of Viscosified Spacer (Alpha Design) weighted to 10.50 ppg / // 966-sx (714-bbl) 10.7Ib/gal Class L - 4.15 cuft/sx (cement to surface,) // 285-s-X (58-bbl) 15.8 lb/gal Prem G - 1.15 cuft/sx (top of tail at 4046 ' Spacer Lead Tail Temp BHST ~ 80° F from SOR, BHCT 85° F estimated by Halliburton Evaluation Program: 9 7/8" Hole Section: Open Hole: Cased Hole: 6-1/8" Hole section: Open Hole: MWD/GR/RES IFR/CASANDRA N/a MWD/GRlRES ABI/IFR/CASANDRA Formation Markers: MDrkb (ft) Base Permafrost 1,985 Top U gnu 4,224 Top U gnu M 4,828 Bottom U gnu 4,959 NA 5,058 NB 5,106 NC 5,171 NE 5,208 NF 5,326 Top OA 5,406 Base OA 5,501 Top OB 5,617 TD 6,894 *Based on sub-surface depths. Formation Tops TVDŒb . (ft) Pore Pressure (pSI) 1,816 817 3,491 1,570 3,926 1,766 3,999 1,799 4,048 1,821 4,070 1,831 4,097 1,843 4,111 1,849 4,151 1,867 4,176 1,878 4,201 1,890 4,223 1,900 4,238 1,906 2 Estimated EMW (lb/gal)* 8.65 8.65 8.65 8.65 8.65 8.65 8.65 8.65 8.65 8.65 8.65 8.65 8.65 /' (' Milne P~ tv1PS-05 Well Permit 1914 psi @ 4256' TV9'kb - Top of ¡¡OB" 1488 psi @ surface (Based on BHP and a full column of gas from TO @ 0.1 psi/ft) Diverter will be function tested. BOP's:Test annular 250 psi low/ and 2500 psi high, and rams to 250 psi low and 4,000 psi high. N/A 9.2 ppg NaCI / 6.8 ppg Diesel CasinglTubing Program: WtIFt Grade Conn Hole Csg I Size Tbg O.D. 42-in 20-in* 92# H-40 Welded 82-ft 9.875-in 7.625-in 29.7# L-80 BTC 5,550-ft Length Top MD I TVDrkb 30-ft 30- ft 6.125-in 4.5-in 12.6# L-80 fiT 3,435-ft 5,580-ft / 4,217-ft (OB) 6.125-in 4.5-in 12.6# L-80 IBT 3,637 -ft 5,370-ft / 4,165-ft (OA) *The 20" casing is insulated Recommended Bit Program: BHA Hole Depth (MD) Bit Type NozzlelFlow Size rate 1 9.875-in 0 - 2,000-ft Hughes MXC-1 3-15 & 1-10 2 9.875-in 2,000 - 5,580-ft Security Rotary TBD Steerable Bit 3 6.125-in 5,580-ft - TD Security FM2643 3 -12 Well Control: . Production hole will be drilled with a diverter. Surface Interval . Maximum anticipated BHP: . Maximum surface pressure: . Planned BOP test pressure: . . Kick tolerance: . Planned completion fluid: Drilling Hazards & Contingencies: Hydrates Bottom MD I TVDrkb 112-ft /112..ft 5,580..ft I 4,217 -ft 9,015-ft / 4,246-ft 9,007 -ft I 4,192..ft . Hydrates have not been seen on S pad, but has been encountered in the surface holes on other pads, especially nearby H-Pad. 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 3 ( Milne P~: . MPS-05 Well Permit hydrates. Pretreat mud with DrilTreat; 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 (8.65 Ib/gal EMW). In this well, the Schrader Bluff formation will be drilled with 9.1 ppg mud. Pad Data Sheet . Please Read the S-Pad Data Sheet thoroughly. Breathing . N/A Hydrocarbons . Hydrocarbons will be encountered in the NA through the Schrader Bluff. Faults . NA Hydrogen Sulfide . MPS Pad is not designated as an H2S Pad. Anti-collision Issues . MPS-05 has no anti-collision issues. 4 Milne PO( \liPS-OS Well Permit DRILL & COMPLETION PROCEDURE Pre- Rig Operations 1. The 20" insulated conductor is installed Procedure / 1. MIRU, NU diverter on 20" conductor and function test, PU 4" drill pipe 2. Drill 9-7/8" surface hole as per directional plan. Maximum angle 840 3. Condition mud prior to 7 5/8" casing run. POOH 4. Run and cement 7 5/8" casing from TD to surface. 5. ND Diverter 6. Install FMC 11" 5m horizontal wellhead 7. N/U and test 13 %" 5myoP and test annular to 250 low and 2500 high. Test the rams to 250 low and 4000 psi high 8. Drill 6-1/8" OB horizontal production hole as per directional plan. 9. Run 4-1/2" slotted liner and hang off 100' inside 7-5/8" casing. 10. Make up Baker Window Master milling assembly with bottom trip anchor and MWD. a. RIH. Orient and set whipstock to place window at top of the OA interval. b. Shear off and mill window thru 7-5/8" casing. 11. Drill 6-1/8" OA lateral geosteering and short tripping as required. Maintain FloPro mud properties and POOH. 12. MU whipstock retrieving tool and pull whipstock 13. Run 4 Y2" slotted liner with Baker Hook Hanger and hang off in 7-5/8" casing 14. POOH 15. TIH and displace out drilling mud with 9.2 ppg N aCl / 16. POOH 17. Run in hole with 4-1/2" jet pump completion as per schematic 18. Land tubing hanger and test 19. Set BPV 20. ND BOP 21. Install and test tree 22. Pull BPV 23. Drop ball and set production packer 24. Test 7-5/8" x 4-1/2" annulus and packer to 3500 psi 25. Freeze protect thru GLM 26. Install BPV and secure the well 27. RDIMO 5 TREE: Ca~eron4-1/16" 5M PROPOSED COMPLETION WELLHEAD:FMCGen611",5M (...,. ~Ps-n5 0- 1\11.,......... P~-n5('.'.- 1 Tubing Head: 11" x 4-1/2", '. ~,-~.. ' FMC Tubing Hanger ~ ~X* 20" 92 Ib/ft, H-40 Welded .... ./ .' ... 42" Hole Insulated / 4-1/2" X 1" Gas Lift Mandrel @ 2,000' MD , 2000' TVD, Diesel Freeze protect to " RP shear valve open position 750' MD KB. ELEV =67.5' Cellar Box ELEV = 39.3' 1121 / Jet Pump Installed in Sliding Sleeve Post rig! 4-1/2", 12.6 I bItt, L-80, IBT-M Coupling 00: 5.2" OriftllO: 3.833" Burst: 8,430, 80% 6,744 psi Collapse: 7,500, 80%=6,000 psi 9.2 KCI with corrosion inhibitor as packer fluid .~ "" . BIW 1- Wire Phoenix Pressure Gauge (3.850" ID, W/BIW 1- wire down to lower sensor) III Halliburtion Dura Sleeve XD W/X Nipple (3.813" ID) Phoenix Pressure Gauge (2.840" ID) 7-5/8" 29.7#, L-80, BTC-M Casing Drift: 6.75 Casing 10: 6.875 Coupling 00: 8.5" Burst: 6,890 psi Collapse: 4,790 psi 7-5/8" X 4-1/2" S-3 Packer set @ 5,356' MD, 4161' TVD I 3-1/2" HES 'XN' nipple 2.750" ID No Go W/RHC ball & rod Wireline Entry Guide Window in 1" casing @ 5,370' MD Well Inclination @ Window = 72 Degrees \~ Multi-Lateral Junction 5,3701 6-1/8" OA Lateral TD 9,007' 6-1/8" OB Lateral TD 9,015' // ........ """'-- - - - - - - - OA Horizontal 6-1/8" hole r...... ...... - - - - - - - - 4-1/2" Slotted Liner W/Hookwall hanger 1" Casing Shoe @ 5,580' MD Well Inclination @ Shoe = 80 Degrees ~ '.~ " 9-7/8" Hole -. - - - - - - OB Horizontal 6-1/8" hole - - - - -- PBTD TD 4-1/2" Slotted Liner & Hanger DATE 27 Jun 02 REV. BY MDG COMMENTS Level 3 Multi-Lateral, 4-1/2" Jet Pump Completion Milne Point Unit WF : MPS-05 API NO: (. BP EXPLORATION Milne Point Unit MPS-OS & MPS-OS L 1 Field: Milne Point Well: MPS-05 ENG: Steve Campbell I Matthew Green RIG: Doyon 141 MSL 39.3-ft RKB: 68' 112' 112' HOLE CASING MUD INFO TOC SIZE SPECS PIT INFO INFORMATION Wellhead 20" 91.5# FMC Gen 6 20" x 11"5M H-40 Insulated N/A 42" Welded DIRECTIONAl LWD OPEN HOLE LOGGING FORMATION DEPTH MD I TVD TOC NONE NONE \ í Top of Lead Cement Surf Surf Dir/GRlRES NONE ~Ii' i';i¡' Il' r' ' g ,ì I ,', J 'Ull! í I:~': ¡1,[!,"!~ ~~i I, KOP @ 300' MD EOB @ 2461' MD Base of Permafrost 1 ,933' 1 ,822' . '~~ Top of N sand 5,058' 4,048' Top ofTail Cement 4,558' --..-..-..-..-. ..--..-..-..-..'-. ..- ..--..-1 ~~ ", ABIIGR NONE OA sand 5,370' 4,165' .... .... 9,007' 4,192' .... ... .... --..-..-..--.-..- ..-..-..-.. -..- ..-.-..- 6-1/8" Hole - 4-1/2", 12.6#, L-80 Slotted Liner 7-5/8" Surface casing 5,580' 4,217' Suñace Casing 7 5/8" 29.733# L-80 BTC MW = 9.2 9-7/8" - - Di~/R;s. . - . . - . . - . . _.. . - . . - . . - .. -.. - . . - . -. - ABIIGR NONE 08 sand 5,580' 4,217' 9,015' 4,246' --..-..-..-..-..- ..-..-.--.. -..- ..-. --.--.. 6-1/8" Hole - 4-1/2",12.6#, L-80 Slotted Liner / J 6/28/2002 MPS-05ML WBD.xls 1600 = ~ 0 ~ .d ë- 0 B 2400 'E Q,) > 2 ¡... 3200 4000 4800 bp COMPANY DETAILS SURVEY PROGRAM REFERENCE INFORMATION Plan: MPS-050B wpOI (Plan MPS-05/Plan MPS-05 (OB» BP Amoco Co-ordinate (NIB) Reference: Well Cen1re: Plan MPS-05. True North Vertical (fVD) Reference: S-pad D-141 66.40 Section (VS) Reference: Slot - (OJ)ON,O.OOE) Measured Depth Reference: S-pad D-141 66.40 Calculation Melhod: Minimwn Onvature Depth Fm Depth To SmveylPlan 66.40 1200.00 Planned: MPS-050B wpOl VI 1200.00 9015.39 Planned: MPS-050B wpOl VI Tool Date: 6/24/2002 Created By: Ken Allen Checked: Calculation Melhod: Minimwn Curvature ~= ~=: ~~W~~der North Error Surface: Elliptical + Casing Wamin¡¡ Melhod: Rules Based CB-GYRO-SS MWD+IFR+MS Date: Date: Reviewed: 0 A FORMATION TOP DETAILS No. TVDPath MDPath Formation 1 I" If..40 1985.23 BPRF 2 1 N 1.40 4224.16 TUgnu 3 1')~f;.40 4827.85 BM80 4 \' 'N.40 4958.77 BUgnu 5 .W3".40 5057.94 SBF2-NA 6 .'111 711.40 5106.71 SBFI-NB 7 .w'n.40 5171.47 SBE4-NC 8 J 111.40 5207.75 SBE2-NE 9 J 1"1.40 5325.88 SBEI-NF 10 J I 7t..40 5406.25 TSBD-OA II J~" 1.40 5501.26 TSBC 12 J!~\.40 5617.32 TSBB-OB 13 .3 ~ 1".40 6893.53 SBA5 (base OB) WELL DETAILS Start Dir 151100': 300' M'), 3'J01VD ~ Start Dír 3(.00' : 4:: 3.3J' WD, L33.31"CVD ............... Nmne +N/-S +EI-W Northing Basting . Latitude Longitude Slot Plan MPS-05 54.49 -325.71 6000029.59 566018.85 70024'37.864N 149°27'44.718W N/A T ARGRT DETAILS Name TVD +Ni-S +EI-W Northing Easting Shape MPS-05L1 goo 4217.40 -2828.38 -405.90 5997198.00 565638.00 Polygon MPS-05 OBI 4218.40 172.69 1554.88 6000216.00 567572.00 Point MPS-05 OB2 4226.40 -599.53 1342.03 5999442.00 567366.00 Point MPS-05 OB3 4241.40 -1125.27 965.33 5998913.00 566994.00 Point MPS-05 0B4 4246.40 -2724.22 -195.95 5997304.00 565847.00 Point SECTION DETAILS See MD Inc Azi TVD +N/-S +Fl-W DLeg TFace VSec Target 1 66.40 0.00 0.00 66.40 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 3 433.33 2.00 30.00 433.31 2.02 1.16 1.50 30.00 -2.09 4 1533.33 35.00 30.00 1462.10 300.13 173.28 3.00 0.00 -311.79 5 1935.42 41.00 31.00 1778.81 513.25 298.98 1.50 6.26 -533.38 6 2162.25 41.00 31.00 1950.00 640.80 375.63 0.00 0.00 -666.10 7 2460.89 55.87 32.88 2147.60 829.64 493.85 5.00 6.05 -862.94 8 2688.57 55.87 32.88 2275.36 987.91 596.17 0.00 0.00 -1028.14 9 5301. 73 71.66 180.00 4143.80 445.87 1554.88 4.55 143.94 -556.28 10 5376.73 71.66 180.00 4167.40 374.68 1554.88 0.00 0.00 -485.27 11 5585.24 80.00 180.00 4218.40 172.69 1554.88 ~:gg 0.00 -283.80 MPS-05 OBI 12 5745.68 90.53 196.19 4231.71 15.17 1532.30 57.76 -125.07 13 6242.64 90.53 196.19 4227.09 -462.05 1393.70 0.00 0.00 360.87 14 6389.66 90.00 205.00 4226.40 -599.53 1342.03 6.00 93.44 50 I. 70 MPS-05 OB2 15 6813.29 87.66 221.79 4235.13 -951.87 1109.80 4.00 98.07 869.80 16 6884.26 87.66 221. 79 4238.03 -1004.75 1062.54 0.00 0.00 925.93 17 7039.21 89.86 215.99 4241.40 -1125.27 965.33 4.00 -69.30 1053.12 MPS-05 OB3 18 9015.39 89.86 215.99 4246.40 -2724.22 -195.95 0.00 0.00 2731.26 MPS-05 OB4 80 800 CASING DETAILS No. TVD MD Name Size I 4217.40 5579.55 7 518" 7.625 2 4246.40 9015.39 41/2" 4.500 !)n 1~00 """ Ok 1."'00 , "".n' ,10. 1<62.1 lV' J f<. y~ .42' MD, 1778.81' TVD Start Dir 5/1(,10' : r¡-25' MJ, 1950'TVD Sõ \ Erv1 D-r : 2460.89' M..>, 2 $' TVD All TVD depths are ssTVD plus 66.4'for RKBE. ~. 75.36'TVD 32' '00(' SB'2-NA SBE4- 'i/C ,EnJDU .53(H.7?'IvD,4143.8'TVD SIà1I Dh 4flOO .5376.73' MD, 4167.4'TVD ",14 1 so. ).Ð.'\. BM8( 0 Tmc Bl'gnu. - ~ f.¡ 4 TS3B-OB EndDir : 5745.68'MD,4131.71'-=VD TotalJepth:9015.39'M':>,4'!46A'TVD 5(00 ~. Sf g., ~ 0 1 S.1::;&IIP ~ÌI 00 ~ \0 \- \ ' \ I ~ 800 Ii? ; - 'I ,>Ou')o 700U" 0 9UUl' 41.'2" SREI-NF 75/8" '::nd Dir : 7039..71' MD. 42..1.4'TVD Start Dir 12/10)' : 5585.24 MD,4218.4'TVD Start .Jir 4/lC~' : 6884.2t" M.J, 4238 03rvD \ Em.Di- :681329'MD,4a5.3'~'VD \ Stat1 Dir 4/IJU' : 6389.6':>' !'lV, '"22<>.4' f vu ~\¡llLDÌt MilO' . 6~.6L' M.J, i>227.09"':VD -1600 -800 0 800 Vertical Section at 184.11 0 [800ft/in] 1600 2400 ö :s ~ 0 0 ~ i 0 ~ -800 oS 6 en -1600 -2400 -3200 COMPANY DETAILS REFERENCE INFORMATION Co-ordinate (NIE) Referwce: Wen Centre: Plan MPS-05, True North Vertical (TVD) Reference: S-pad D-141 66.40 Section (VS) Reference: Slot - (O.OON,O.OOE) Measured Depth Reference: S-pad D-141 66.40 Calculation Method: Minimum On'Vature BP Amoco Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav Cylinder North Error Surface: El1ipIical + Casing Warning Method: Rules Based 1600- 30\>0 800 End D. r : 2460.&9' MD. 21<17.11;)' TVD A. 11)0 'TVD 0 . 1935.L2'MD,l778.ßl' TV End Dir : 5301.73' MD, 4143.8' TVD I r-:: Start Dir 4/100' : 5376.73' MD, 4167.4'TVD MPS-(150B1 ,/ 7 Sl8" '\J .Il Start Dir 12/100' : 5585.24' MD 4218.4'TVD lWO/ \ . - - - ' 500 / f .1 EndDir : 5745_68'MD, 4231.71' TVD Start'Jir 1.5'.100': .533.3j' W-D, 1 62.1"r\lO Star: Vlf j/lUl . : "'jj jj'MD, 4:ß..H "-' D S:art VII 1.~/1(Q' : 300' 1\I:.V, 30VT\iV /, 3tart Dir 6/100' : 6242.64' MD, 4227.09'TVD Start Dir4/100' : 6389.66' MD, 4226.4'TVD ~ ~PS-05 OB2 Sne Di: : 6813.29' MD, 4235.13' TVD -"tA" r:ir t./l 00' : 6884.26' MD, 4238.03'TVD All TVD depths are ssTVD plus 66.4'for RKBE. I I I I I I I I 1 I I I I 2400 3200 0 800 1600 W est( - )Æast( +) [800ft/in] SURVEY PROGRAM Depth Fm Depth To SwveylPlan Plan: MPS-050B wpOI (Plan MPS.05/Plan MPS-05 (DB)) Created By: Ken Allen Date: 6/24/2002 Tool 66.40 1200.00 Planned: MPS-050B wp01 VI 1200.00 9015.39 Planned: MPS-050B wp01 VI CB-GYRO-SS MWD+lFR+MS Checked: Date: Date: Reviewed: WELL DETAILS Name +N/-S +FJ-W Northing Easting Latitude Longitude Slot Plan MPS-05 54.49 -325.71 6000029.59 566018.85 70024'37.864N 149°27'44.718W N/A TARGET DETAILS Name TVD +NI-S +FJ.W Northing Easting Shape MPS-05L1 goo 4217.40 -2828.38 -405.90 5997198.00 565638.00 PolY8on MPS-05 OBI 4218.40 172.69 1554.88 6000216.00 567572.00 Point MPS-05 OB2 4226.40 .599.53 1342.03 5999442.00 567366.00 Point MPS-05 OB3 4241.40 -1125.27 965.33 5998913.00 566994.00 Point MPS-05 0B4 4246.40 -2724.22 -195.95 5997304.00 565847.00 Point SECTION DETAILS See MD Ine Azi TVD +N/-S +E/-W DLeg TFaee VSee Target 1 66.40 0.00 0.00 66.40 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 3 433.33 2.00 30.00 433.31 2.02 1.16 1.50 30.00 -2.09 4 1533.33 35.00 30.00 1462.10 300.13 173.28 3.00 0.00 -311.79 5 1935.42 41.00 31.00 1778.81 513.25 298.98 1.50 6.26 -533.38 6 2162.25 41.00 31.00 1950.00 640.80 375.63 0.00 0.00 -666.10 7 2460.89 55.87 32.88 2147.60 829.64 493.85 5.00 6.05 -862.94 8 2688.57 55.87 32.88 2275.36 987.91 596.17 0.00 0.00 -1028.14 9 5301.73 71.66 180.00 4143.80 445.87 1554.88 4.55 143.94 -556.28 10 5376.73 71.66 180.00 4167.40 374.68 1554.88 0.00 0.00 -485.27 11 5585.24 80.00 180.00 4218.40 172.69 1554.88 -1i:88 0.00 -283.80 MPS-05 DB 1 12 5745.68 90.53 196.19 4231.71 15.17 1532.30 57.76 -125.07 13 6242.64 90.53 196.19 4227.09 -462.05 1393.70 0.00 0.00 360.87 14 6389.66 90.00 205.00 4226.40 -599.53 1342.03 6.00 93.44 501.70 MPS-050B2 15 6813.29 87.66 221.79 4235.13 -951.87 1109.80 4.00 98.07 869.80 16 6884.26 87.66 221.79 4238.03 -1004.75 1062.54 0.00 0.00 925.93 17 7039.21 89.86 215.99 4241.40 -1125.27 965.33 4.00 -69.30 1053.12 MPS-05 OB3 18 9015.39 89.86 215.99 4246.40 -2724.22 -195.95 0.00 0.00 2731.26 MPS-05 084 CASING DETAILS FORMATION TOP DETAILS No. TVD MD Name Size No. TVDPath MDPath Fonnation 1 4217.40 5579.55 75/8" 7.625 1 1816.40 1985.23 BPRF 2 4246.40 9015.39 41/2" 4.500 2 3491.40 4224.16 TUgnu 3 3926.40 4827.85 BM80 4 3999.40 4958.77 BUgnu 5 4048.40 5057.94 SBF2-NA 6 4070.40 5106.71 SBFI-NB 7 4097.40 5171.47 SBE4-NC 8 4111.40 5207.75 SBE2-NE 9 4151.40 5325.88 SBEI-NF 10 4176.40 5406.25 TSBD-OA 11 4201.40 5501.26 TSBC .~ 12 4223.40 5617.32 TSBB-OB 13 4238.40 6893.53 SBA5 (base OB) ~/ # ' ~,' , ",' ( BP My Planning Report MAP (' ç~jp~J,ly;Be~_- Itreld: . Mime POint- Site: - MPtS Pad - WeD: Plan MPS-05 WeUpatb: Plan MPS-05 (08) - - . .~.,:1<?~~ -- -.-~09:24:40. Pige: ~~'Referënee:WeU:Ptån MPS..Q5. True North V.~{1'VI}):Refer.enœ:-- -$;.padD-14166.4 - Semon- (VS) Re(erenee: Well (O.OON.O.OOE. 184. 11Azi) SuneYCalcuJation Method: Minimum Curvature Db: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Field: Map Zone: Coordinate System: Geomagnetic Model: Site: M Pt S Pad 1 Oracle Alaska. Zone 4 Well Centre BGGM2002 Site Position: Nortbing: 5999978.00 ft Latitude: 70 24 37.329 N From: Map Easting: 566345.00 ft Longitude: 149 27 35.171 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.51 deg Well: Plan MPS-05 Slot Name: Well Position: +N/-S 54.49 ft Northing: 6000029.59 ft Latitude: 70 24 37.864 N +E/-W -325.71 ft Easting: 566018.85 ft Longitude: 149 27 44.718 W Position Uncertainty: 0.00 ft Wellpath: Plan MPS-05 (OB) Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Plan: S-pad D-141 6/21/2002 57498 nT Depth From (TVD) ft 0.00 MPS-050B wp01 Date Composed: Version: Tied-to: Current Datum: Magnetic Data: Field Strength: Vertical Section: Height 66.40 ft +N/-S ft 0.00 Principal: Yes Casing Points Well Ref. Point 0.00 ft Mean Sea Level 25.84 deg 80.80 deg Direction deg 184.11 6/21/2002 1 From Well Ref. Point 5579.55 4217.40 9015.39 4246.40 7.625 4.500 9.875 6.125 75/8" 41/2" Formations 1985.23 1816.40 BPRF 0.00 0.00 4224.16 3491.40 TUgnu 0.00 0.00 4827.85 3926.40 BM80 0.00 0.00 4958.77 3999.40 BUgnu 0.00 0.00 5057.94 4048.40 SBF2-NA 0.00 0.00 5106.71 4070.40 SBF1-NB 0.00 0.00 5171.47 4097.40 SBE4-NC 0.00 0.00 5207.75 4111.40 SBE2-NE 0.00 0.00 5325.88 4151.40 SBE1-NF 0.00 0.00 5406.25 4176.40 TSBD-OA 0.00 0.00 5501.26 4201.40 TSBC 0.00 0.00 5617.32 4223.40 TSBB-OB 0.00 0.00 6893.53 4238.40 SBA5 (base OB) 0.00 0.00 0.00 Top OBd 0.00 0.00 0.00 Base OBd 0.00 0.00 BP My Planning Report MAP (' MPS-05 OB2 MPS-05 OB3 Co-ordiuate(NE) Reference: Well: Plan MPS-05, True Vertical (TVD) Refereuee: s..pad 0-141 66.4 SeetiOD (VS) Refereaee: Well (O.OON,O.00E,184.11Azi) Survey Calculation Method: Minimum Curvature Db: Oracle _.__.__.~---------,_._- ----.. ..--- l\taP. Map <-- Latitude --> <- Longitude -> TVD +N/-S +EI-W Northiøg Easting Deg MiD See Deg MiD See Dir. ft ft ft ft ft 4217.40 -2828.38 -405.90 5997198.00 565638.00 70 24 10.048 N 149 27 56.610 W 4217.40 -2828.38 -405.90 5997198.00 565638.00 70 24 10.048 N 149 27 56.610 W 4217 .40 -2832.00 3.12 5997198.00 566047.00 70 24 10.012 N 149 27 44.626 W 4217.40 -687.66 1468.27 5999355.00 567493.00 70 24 31.100 N 149 27 1.685 W 4217.40 185.32 1710.02 6000230.00 567727.00 70 24 39.685 N 149 26 54.594 W 4217.40 189.10 1283.00 6000230.00 567300.00 70 24 39.723 N 149 27 7.111 W 4217 .40 -476.37 1212.11 5999564.00 567235.00 70 24 33.178 N 149 27 9.192 W 4218.40 172.69 1554.88 6000216.00 567572.00 70 24 39.561 N 149 26 59.142 W 4226.40 -599.53 1342.03 5999442.00 567366.00 70 24 31.967 N 149 27 5.385 W 4241.40 -1125.27 965.33 5998913.00 566994.00 70 24 26.797 N 149 27 16.427 W 4246.40 -2724.22 -195.95 5997304.00 565847.00 70 24 11.072 N 149 27 50.459 W Targets MPS-05L 1 geo -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 MPS-050B1 MPS-05 OB4 Plan Section Information ,MQ '" ,'Inçr, 'Ailm rv»: ",t~l~:,'. *EFW,' '.'nt$:, "BUiJd'... :;tû:rn .TFO " Target, ft :~~" 4èg.' , ft - - ,it.:' , ", :'fÍ _~~19()ff~~1100fJ~Ø9~1ØQtt '-, -- døg 66.40 0.00 0.00 66.40 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 433.33 2.00 30.00 433.31 2.02 1.16 1.50 1.50 0.00 30.00 1533.33 35.00 30.00 1462.10 300.13 173.28 3.00 3.00 0.00 0.00 1935.42 41.00 31.00 1778.81 513.25 298.98 1.50 1.49 0.25 6.26 2162.25 41.00 31.00 1950.00 640.80 375.63 0.00 0.00 0.00 0.00 2460.89 55.87 32.88 2147.60 829.64 493.85 5.00 4.98 0.63 6.05 2688.57 55.87 32.88 2275.36 987.91 596.17 0.00 0.00 0.00 0.00 5301.73 71.66 180.00 4143.80 445.87 1554.88 4.55 0.60 5.63 143.94 5376.73 71.66 180.00 4167.40 374.68 1554.88 0.00 0.00 0.00 0.00 5585.24 80.00 180.00 4218.40 172.69 1554.88 4.00 4.00 0.00 0.00 MPS-050B1 5745.68 90.53 196.19 4231.71 15.17 1532.30 12.00 6.57 10.09 57.76 6242.64 90.53 196.19 4227.09 -462.05 1393.70 0.00 0.00 0.00 0.00 6389.66 90.00 205.00 4226.40 -599.53 1342.03 6.00 -0.36 5.99 93.44 MPS-05 OB2 6813.29 87.66 221.79 4235.13 -951.87 1109.80 4.00 -0.55 3.96 98.07 6884.26 87.66 221.79 4238.03 -1004.75 1062.54 0.00 0.00 0.00 0.00 7039.21 89.86 215.99 4241.40 -1125.27 965.33 4.00 1.42 -3.74 -69.30 MPS-05 OB3 9015.39 89.86 215.99 4246.40 -2724.22 -195.95 0.00 0.00 0.00 0.00 MPS-05 OB4 Survey 0.00 CB-GYRO-SS 100.00 0.00 CB-GYRO-SS 200.00 0.00 CB-GYRO-SS 300.00 0.00 Start Oir 1.5/100' : 300' MO, 399.99 1.50 CB-GYRO-SS 433.33 2.00 30.00 433.31 366.91 6000031.62 566020.00 -2.09 1.50 Start Oir 3/100' : 433.33' MD, 500.00 4.00 30.00 499.88 433.48 6000034.65 566021.71 -5.23 3.00 CB-GYRO-SS 600.00 7.00 30.00 599.41 533.01 6000042.99 566026.43 -13.85 3.00 CB-GYRO-SS 700.00 10.00 30.00 698.30 631.90 6000055.86 566033.71 -27.15 3.00 CB-GYRO-SS 800.00 13.00 30.00 796.28 729.88 6000073.20 566043.52 -45.08 3.00 CB-GYRO-SS 900.00 16.00 30.00 893.08 826.68 6000094.99 566055.84 -67.61 3.00 CB-GYRO-SS 1000.00 19.00 30.00 988.44 922.04 6000121.16 566070.65 -94.66 3.00 CB-GYRO-SS 1100.00 22.00 30.00 1082.10 1015.70 6000151.64 566087.88 -126.16 3.00 CB-GYRO-SS 1200.00 25.00 30.00 1173.79 1107.39 6000186.34 566107.51 -162.03 3.00 CB-GYRO-SS 1300.00 28.00 30.00 1263.28 1196.88 6000225.17 566129.47 -202.17 3.00 MWD+IFR+MS 1400.00 31.00 30.00 1350.30 1283.90 6000268.02 566153.71 -246.47 3.00 MWD+IFR+MS (, BP My Planning Report MAP ( Survey Azim TVD Sys TVD MapN MapE VS DLS ToolIConJJneDt deg ft ft ft ft ft degJ100ft 1500.00 30.00 1434.63 1368.23 6000314.78 566180.16 -294.80 3.00 MWD+IFR+MS 1533.33 30.00 1462.10 1395.70 6000331.21 566189.45 -311.79 3.00 Start Dir 1.5/100' : 1533.33' 1600.00 30.19 1516.38 1449.98 6000364.87 566208.56 -346.58 1.50 MWD+IFR+MS 1700.00 30.45 1596.51 1530.11 6000416.76 566238.30 -400.25 1.50 MWD+IFR+MS 1800.00 38.98 30.69 1675.06 1608.66 6000470.32 566269.30 -455.66 1.50 MWD+IFR+MS 1900.00 40.47 30.92 1751.97 1685.57 6000525.49 566301.54 -512.75 1.50 MWD+IFR+MS 1935.42 41.00 31.00 1778.81 1712.41 6000545.41 566313.26 -533.38 1.50 End Dir : 1935.42' MD, 1778.8 1985.23 41.00 31.00 1816.40 1750.00 6000573.56 566329.84 -562.52 0.00 BPRF 2000.00 41.00 31.00 1827.55 1761.15 6000581.91 566334.75 -571.16 0.00 MWD+IFR+MS 2100.00 41.00 31.00 1903.02 1836.62 6000638.44 566368.04 -629.68 0.00 MWD+IFR+MS 2162.25 41.00 31.00 1950.00 1883.60 6000673.63 566388.76 -666.10 0.00 Start Dir 5/100' : 2162.25' MD 2200.00 42.88 31.29 1978.08 1911.68 6000695.33 566401.62 -688.57 5.00 MWD+IFR+MS 2300.00 47.85 31.98 2048.32 1981.92 6000756.21 566438.41 -751.65 5.00 MWD+IFR+MS 2400.00 52.83 32.56 2112.12 2045.72 6000821.64 566478.93 -819.50 5.00 MWD+IFR+MS 2460.89 55.87 32.88 2147.60 2081.20 6000863.49 566505.30 -862.94 5.00 End Dir : 2460.89' MD, 2147.6 2500.00 55.87 32.88 2169.55 2103.15 6000890.83 566522.64 -891.31 0.00 MWD+IFR+MS 2600.00 55.87 32.88 2225.66 2159.26 6000960.73 566566.95 -963.87 0.00 MWD+IFR+MS 2688.57 55.87 32.88 2275.36 2208.96 6001022.64 566606.20 -1028.14 0.00 Start Dir 4.55/100' : 2688.57' 2700.00 55.45 33.25 2281.80 2215.40 6001030.59 566611.28 -1036.40 4.55 MWD+IFR+MS 2800.00 51.83 36.67 2341.10 2274.70 6001096.99 566656.77 -1105.53 4.55 MWD+IFR+MS 2900.00 48.31 40.45 2405.28 2338.88 6001157.37 566703.96 -1168.77 4.55 MWD+IFR+MS 3000.00 44.94 44.65 2473.97 2407.57 6001211.37 566752.56 -1225.72 4.55 MWD+IFR+MS 3100.00 41.74 49.37 2546.71 2480.31 6001258.63 566802.24 -1276.02 4.55 MWD+IFR+MS 3200.00 38.75 .54.69 2623.05 2556.65 6001298.87 566852.71 -1319.36 4.55 MWD+IFR+MS 3300.00 36.05 60.71 2702.51 2636.11 6001331.82 566903.65 -1355.45 4.55 MWD+IFR+MS 3400.00 ~3.68 67.51 2784.59 2718.19 6001357.28 566954.72 -1384.08 4.55 MWD+IFR+MS 3500.00 31.73 75.13 2868.77 2802.37 6001375.09 567005.62 -1405.06 4.55 MWD+IFR+MS 3600.00 30.28 83.51 2954.52 2888.12 6001385.14 567056.02 -1418.26 4.55 MWD+IFR+MS 3700.00 29.41 92.49 3041.30 2974.90 6001387.36 567105.60 -1423.59 4.55 MWD+IFR+MS 3800.00 29.16 101.79 3128.57 3062.17 6001381.74 567154.05 -1421.03 4.55 MWD+IFR+MS 3900.00 29.56 111.04 3215.77 3149.37 6001368.31 567201.06 -1410.59 4.55 MWD+IFR+MS 4000.00 30.58 119.90 3302.35 3235.95 6001347.16 567246.34 -1392.34 4.55 MWD+IFR+MS 4100.00 32.16 128.11 3387.77 3321.37 6001318.43 567289.61 -1366.38 4.55 MWD+IFR+MS 4200.00 34.22 135.53 3471.49 3405.09 6001282.29 567330.59 -1332.89 4.55 MWD+IFR+MS 4224.16 34.78 137.20 3491.40 3425.00 6001272.48 567340.11 -1323.69 4.55 TUgnu 4300.00 36.67 142.13 3552.98 3486.58 6001238.97 567369.01 -1292.07 4.55 MWD+IFR+MS 4400.00 39.45 147.98 3631.73 3565.33 6001188.75 567404.65 -1244.18 4.55 MWD+IFR+MS 4500.00 42.50 153.15 3707.25 3640.85 6001131.94 567437.27 -1189.53 4.55 MWD+IFR+MS 4600.00 45.74 157.73 3779.04 3712.64 6001068.90 567466.68 -1128.46 4.55 MWD+IFR+MS 4700.00 49.15 161.82 3846.68 3780.28 6001000.02 567492.67 -1061.35 4.55 MWD+IFR+MS 4800.00 52.69 165.50 3909.71 3843.31 6000925.74 567515.10 -988.62 4.55 MWD+IFR+MS 4827.85 53.70 166.46 3926.40 3860.00 6000904.16 567520.69 -967.43 4.55 BM80 4900.00 56.34 168.85 3967.76 3901.36 6000846.54 567533.81 -910.75 4.55 MWD+IFR+MS 4958.77 58.52 170.68 3999.40 3933.00 6000797.89 567543.03 -862.77 4.55 BUgnu 5000.00 60.07 171.92 4020.46 3954.06 6000762.90 567548.70 -828.20 4.55 MWD+IFR+MS 5057.94 62.26 173.59 4048.40 3982.00 6000712.62 567555.53 -778.45 4.55 SBF2-NA 5100.00 63.86 174.77 4067.46 4001.06 6000675.36 567559.66 -741.51 4.55 MWD+IFR+MS 5106.71 64.12 174.95 4070.40 4004.00 6000669.36 567560.26 -735.57 4.55 SBF1-NB 5171.47 66.60 176.69 4097.40 4031.00 6000610.71 567565.06 -677.33 4.55 SBE4-NC 5200.00 67.70 177.43 4108.48 4042.08 6000584.46 567566.63 -651.23 4.55 MWD+IFR+MS 5207.75 68.00 177.63 4111.40 4045.00 6000577.29 567567.01 -644.10 4.55 SBE2-NE 5301.73 71.66 180.00 4143.80 4077.40 6000489.14 567569.59 -556.28 4.55 End Dir : 5301.73' MD, 4143.8 5325.88 71.66 180.00 4151.40 4085.00 6000466.22 567569.79 -533.41 0.00 SBE1-NF ( BP ( My Planning Report MAP ÇOlÛpåDy-:,,~AaJoc;O' .' '.~:';":,ßJ2~..:.. ..' TJöae:' . 09~4:40. ..' ~âge: 4 Field: Milne Point c~Ì'dhiåte(NE).RefereDee:' . Wetl::Plan MPS-OS. True North Site: MPtS'Pad' . VertiCål(TVD),Itef6,aiu: 'SiJad[).;.14166.4 '.' Well: Plan MPS-OS Sediòìa'(VS)Ref~' We1l(O.00N.O.OOE.184.11Azi) Wellpath: Plan UPS-OS (OS) SUl'Vey£akalationMetbed: '. Minirnt.lfriCurvature Db: Oracte Survey 5376.73 71.66 180.00 4167.40 4101.00 6000417.96 567570.21 -485.27 0.00 Start Dir 4/100' : 5376.73' MD 5400.00 72.59 180.00 4174.54 4108.14 6000395.82 567570.41 -463.18 4.00 MWD+IFR+MS 5406.25 72.84 180.00 4176.40 4110.00 6000389.85 567570.46 -457.23 4.00 TSBD-OA 5500.00 76.59 180.00 4201.11 4134.71 6000299.45 567571.26 -367.04 4.00 MWD+IFR+MS 5501.26 76.64 180.00 4201.40 4135.00 6000298.23 567571.27 -365.82 4.00 TSBC 5579.55 79.77 180.00 4217.40 4151.00 6000221.61 567571.95 -289.39 4.00 MPS-05L 1 geo 5585.24 80.00 180.00 4218.40 4152.00 6000216.00 567572.00 -283.80 4.00 MPS-05 OB1 5600.00 80.95 181.52 4220.84 4154.44 6000201.45 567571.94 -269.27 12.00 MWD+IFR+MS 5617.32 82.07 183.29 4223.40 4157.00 6000184.33 567571.37 -252.15 12.00 TSBB-OB 5625.00 82.57 184.07 4224.43 4158.03 6000176.73 567570.95 -244.54 12.00 MWD+IFR+MS 5650.00 84.20 186.60 4227.31 4160.91 6000151.99 567568.86 -219.72 12.00 MWD+IFR+MS 5675.00 85.85 189.12 4229.47 4163.07 6000127.30 567565.67 -194.87 12.00 MWD+IFR+MS 5700.00 87.50 191.63 4230.93 4164.53 6000102.71 567561.39 -170.06 12.00 MWD+IFR+MS 5725.00 89.16 194.13 4231.65 4165.25 6000078.31 567556.04 -145.37 12.00 MWD+IFR+MS 5745.68 90.53 196.19 4231.71 4165.31 6000058.30 567550.81 -125.07 12.00 End Dir : 5745.68' MD, 4231.7 5800.00 90.53 196.19 4231.20 4164.80 6000006.02 567536.12 -71.96 0.00 MWD+IFR+MS 5900.00 90.53 196.19 4230.27 4163.87 5999909.76 567509.09 25.83 0.00 MWD+IFR+MS 6000.00 90.53 196.19 4229.34 4162.94 5999813.49 567482.05 123.61 0.00 MWD+IFR+MS 6100.00 90.53 196.19 4228.41 4162.01 5999717.23 567455.01 221.39 0.00 MWD+IFR+MS 6200.00 90.53 196.19 4227.48 4161.08 5999620.97 567427.98 319.17 0.00 MWD+IFR+MS 6242.64 90.53 196.19 4227.09 4160.69 5999579.92 567416.45 360.87 0.00 Start Dir 6/100' : 6242.64' MD 6250.00 90.51 196.64 4227.02 4160.62 5999572.85 567414.43 368.05 6.00 MWD+IFR+MS 6300.00 90.33 199.63 4226.66 4160.26 5999525.21 567399.29 416.56 6.00 MWD+IFR+MS 6350.00 90.14 202.62 4226.45 4160.05 5999478.42 567381.69 464.36 6.00 MWD+IFR+MS 6389.66 90.00 205.00 4226.40 4160.00 5999442.00 567366.00 501.70 6.00 MPS-05 OB2 6400.00 89.94 205.41 4226.41 4160.01 5999432.61 567361.68 511.35 4.00 MWD+IFR+MS 6500.00 89.38 209.37 4227.00 4160.60 5999343.44 567316.48 603.19 4.00 MWD+IFR+MS 6600.00 88.82 213.33 4228.56 4162.16 5999257.62 567265.23 692.07 4.00 MWD+IFR+MS 6700.00 88.27 217.29 4231.10 4164.70 5999175.57 567208.18 777.57 4.00 MWD+IFR+MS 6800.00 87.73 221.26 4234.59 4168.19 5999097.67 567145.62 859.25 4.00 MWD+IFR+MS 6813.29 87.66 221.79 4235.13 4168.73 5999087.65 567136.91 869.80 4.00 End Dir : 6813.29' MD, 4235.1 6884.26 87.66 221.79 4238.03 4171.63 5999034.37 567090.13 925.93 0.00 Start Dir 4/100' : 6884.26' MD 6893.53 87.79 221.44 4238.40 4172.00 5999027.39 567084.04 933.27 4.00 SBA5 (base OB) 6900.00 87.88 221.20 4238.64 4172.24 5999022.50 567079.81 938.42 4.00 MWD+IFR+MS 7000.00 89.30 217.46 4241.11 4174.71 5998944.63 567017.17 1020.09 4.00 MWD+IFR+MS 7039.21 89.86 215.99 4241.40 4175.00 5998913.00 566994.00 1053.12 4.00 MPS-05 OB3 7100.00 89.86 215.99 4241.55 4175.15 5998863.51 566958.72 1104.73 0.00 MWD+IFR+MS 7200.00 89.86 215.99 4241.81 4175.41 5998782.09 566900.68 1189.65 0.00 MWD+IFR+MS 7300.00 89.86 215.99 4242.06 4175.66 5998700.67 566842.64 1274.57 0.00 MWD+IFR+MS 7400.00 89.86 215.99 4242.31 4175.91 5998619.25 566784.59 1359.49 0.00 MWD+IFR+MS 7500.00 89.86 215.99 4242.57 4176.17 5998537.83 566726.55 1444.41 0.00 MWD+IFR+MS 7600.00 89.86 215.99 4242.82 4176.42 5998456.41 566668.51 1529.33 0.00 MWD+IFR+MS 7700.00 89.86 215.99 4243.07 4176.67 5998374.99 566610.47 1614.25 0.00 MWD+IFR+MS 7800.00 89.86 215.99 4243.32 4176.92 5998293.57 566552.43 1699.17 0.00 MWD+IFR+MS 7900.00 89.86 215.99 4243.58 4177.18 5998212.15 566494.39 1784.09 0.00 MWD+IFR+MS 800Q.00 89.86 215.99 4243.83 4177.43 5998130.73 566436.35 1869.01 0.00 MWD+IFR+MS 8100.00 89.86 215.99 4244.08 4177.68 5998049.31 566378.30 1953.93 0.00 MWD+IFR+MS 8200.00 89.86 215.99 4244.34 4177.94 5997967.89 566320.26 2038.84 0.00 MWD+IFR+MS 8300.00 89.86 215.99 4244.59 4178.19 5997886.47 566262.22 2123.76 0.00 MWD+IFR+MS 8400.00 89.86 215.99 4244.84 4178.44 5997805.05 566204.18 2208.68 0.00 MWD+IFR+MS 8500.00 89.86 215.99 4245.10 4178.70 5997723.63 566146.14 2293.60 0.00 MWD+IFR+MS 8600.00 89.86 215.99 4245.35 4178.95 5997642.21 566088.10 2378.52 0.00 MWD+IFR+MS ( BP My Planning Report MAP ( Survey Ind Azim TVD 81$ TVD MapN MapE VS DLS Tool/Comment deg deg ft ft ft ft ft degJ100ft 8700.00 89.86 215.99 4245.60 4179.20 5997560.79 566030.06 2463.44 0.00 MWD+IFR+MS 8800.00 89.86 215.99 4245.86 4179.46 5997479.37 565972.01 2548.36 0.00 MWD+IFR+MS 8900.00 89.86 215.99 4246.11 4179.71 5997397.95 565913.97 2633.28 0.00 MWD+IFR+MS 9000.00 89.86 215.99 4246.36 4179.96 5997316.53 565855.93 2718.20 0.00 MWD+IFR+MS 9015.37 89.86 215.99 4246.40 4180.00 5997304.01 565847.01 2731.25 0.00 Total Depth: 9015.39' MD, 424 9015.39 89.86 215.99 4246.40 4180.00 5997304.00 565847.00 2731.26 0.00 MPS-05 084 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS DATE CHECK NO. OS/28/02 H206929 VENDOR DISCOUNT NET $100.00 t H 206929 OS/23/02 CK05'2302L Permit To Drill Fee PIs call Terri6 :Hubble X4628 jf11?5-05 ¿, L I THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ $100.00 BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFIUATE OF NATIONAL CITY BANK CLEVELAND, OHIO No. H 20S929 CONSOLIDATED COMMERCIAL ACCOUNT ~ 56-389 412" PAY B'.,."...., .::..f.,'.:.":':',.".' ,', C.-...,..',.'"."",.:.."'."'., f'.W.' .,,: I.dfll¡,. ,,''''1',''''.11(1.1,' ... .. .;. - -. -to ."-: - f -:: It,,: - i 1..ff 1..,' .,.~ .,'..,', ...... ..:~.1,,1It, 'm' ,UtHt -u¡. ,,¡Ú AlaskaOild&.Gas CÒnservationComfui$sion 333 Wi 7thdAv~ , Ste AfichÓJfag~, AK '99501 DATE AMOUNT TO THE ORDER OF ***~ay 28, 2002** *****$100.00******* NOT VALID AFTER 120 DAYS ~-.ßß/tÂLl .._~-'. .\..~~ 118 2 0 b q 2 g 118 I: 0... ~ 2 0 j a q 51: 0 0 a ...... ~ g 118 CHECK 1 STANDARD LETTER DEVELOPMENT x DEVELOPMENT REDRILL EXPLORATION INJECTION WELL INJECTION WELL REDRILL Rev: 5/6/02 C\jody\templates ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME 11/~ ,-<) - 0', t) CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL (If API number last two (2) digits are between 60-69) PILOT HOLE (PH) "CLUE" The permit is for a new wellbore segment of existing well --' Permit No, API No. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(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 number (50 -70/80) from records, data and logs acquired for well (name on permit). ANNULAR DISPOSAL Please note that an disposal of fluids generated. . . INTO ANNULUS OF ANOTHER WELL ON SAME PAD <-> SPACING EXCEPTION Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST COMPANY ðfJ)( WELL NAME#.P_S' - c>.s PROGRAM: Exp - Dev )( Redrll- Se~ - Wellbore seg - Ann. disposal para req - FIELD & POOL. -ç"? S /-7 d INIT CLASS¡/~ ¿/ !-ð// GEOL AREA ff?,ð UNIT# 1/32 <2 ON/OFF SHORE <::YJ ~ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . ~N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. .. . . . . . . . . . . . . . . . Y N . 4. Well located in a defined poot.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is well bore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . .. . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N .. A~R DATE; 12. Permit can be issued without administrative approval.. . . . . Y N /f7'r- 7/.lÞ.z... 13. Can permit be approved before 15-day wait.. . . . . . . . . . ~ N I ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . PO N to II @ . iI~ 15. Surface casing protects all known USDWs. . . . . . . æ N .!Å 16. CMT vol adequate to circulate on conductor & surf csg. . . . . æì N P+'de~.tf...4,./-Q. ~tP<'Ç, 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . -¥-N- ^' /Pf- 18. CMT will cover all known productiv.e horizons. . . . . . . . . . ~ N 19. Casing designs adequate for C, T, B & permafrost. . . . . . . .... N {) 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N . ~1 /J'V'- I 'f I 21. If a re-drill,. has a 10-403 for abandonment been approved. . . ...¥-No ^' / M 22. Adequate well bore separation proposed.. . . . . . . . . .-.. 1 N 23. If diverter required, does it meet regulations. . . . . . . . . . - -.N 24, Drilling fluid program schematic & equip list adequate. . . . . N 25. BOPEs, do they meet regulation. . . . ~ ¡ . . . . . . . . . . .. N Pi I 52 () , AE~RA u D{AT1E 26. BOPE press rating appropriate; test to ,+000 psig. N JIll, Ç. 1('-0 "() fÇ. ( . \oN C;,., 7 ,. Q 'L 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N 28. Work will occur without operation shutdown. . . . . . . . . . . éi? N 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y @ 30. Permit can be issued w/o hydrogen sulfide measures. .. . . J(@N 31. Data presented on potential overpressure zones. . . . . . . Y N /I /, ./J. 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y / v j n . APPR Dj\JE 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . N ,R¡è::.. Z?/Ó7. 34. Contact name/phone for weekly progress reports [exploratory only' Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; (0) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: RP#. JDH...n.- COT- WGA \;J6¡r- DTS cr 7 P2-1~ GEOLOGY APPR DATE ~ 7Ó~?- G:\geology\permits\checklist.doc ) ) Comments/Instructions: 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 information, information of this nature is accumulated at the end of the file under APPEN.DIX. No special. effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Nòv 25 09:04:57 2002 Reel Header Service name........... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . . 02 / 11/25 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name. ...... ........ .UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments........ ........ .STS LIS C1 o~~13J 1l33-3 Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 02 /11/ 2 5 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 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 AK-MW-22118 J. STRAHAN C. DIXON JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 4 AK-MW-22118 J. STRAHAN L. BROWN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MPS-05 500292310000 BP Exploration (Alaska) Sperry-Sun Drilling Services 25-NOV-02 . MWDRUN 2 AK-MW-22118 J. STRAHAN C. DIXON MWDRUN 5 AK-MW-22118 J. STRAHAN L. BROWN 7 12N 11E 3360 4772 66.80 39.30 MWDRUN 3 AK-MW-22118 J. STRAHAN C. DIXON # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 20.000 112.0 6.125 7.625 5370.0 # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1-3, and 5 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 4. MWD RUN 4 WAS DIRECTIONAL ONLY, TO SIDETRACK THE PB 1 WELLBORE AT 5189'MD/4137'TVD AND DRILL TO 7 5/8" CASING POINT AT 5380'MD/4179'TVD. SGRC DATA WERE ACQUIRED OVER THE INVERVAL 5032'MD/4080'TVD TO 5380'MD/ 4179'TVD WHILST RIH FOR MWD RUN 5. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. SCHNORR, BP ALASKA, INC., DATED 8/29/02. MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-3, AND 5 REPRESENT WELL MPS-05 WITH API#: 50-029-23100-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8810'MD/4118'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.... ...... .1.0.0 Date of Generation...... .02/11/25 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX ROP $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 60.0 70.0 70.0 70.0 70.0 70.0 110.5 STOP DEPTH 8756.0 8763.0 8763.0 8763.0 8763.0 8763.0 8810.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD MWD MWD MWD $ DATA SOURCE TOOL CODE # REMARKS: BIT RUN NO 1 2 3 4 5 MERGED MAIN PASS. $ MERGE TOP 60.0 2462.0 2594.0 5189.5 5380.0 MERGE BASE 2462.0 2594.0 5189.0 5380.0 8810.0 # Data Format Specification Record Data Record Type. . . . . . . . . . . . . . . . . .0 Data Specification Block Type... ..0 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 60 8810 4435 17501 60 8810 ROP MWD FT/H 0.16 1297.46 236.155 17400 110.5 8810 GR MWD API 11.73 126.49 69.189 17393 60 8756 RPX MWD OHMM 0.06 2000 48.4195 17096 70 8763 RPS MWD RPM MWD RPD MWD FET MWD OHMM OHMM OHMM HOUR 0.06 0.06 0.04 0.04 2000 2000 2000 76.68 59.114 17096 78.4244 17096 235.46 17096 0.93555 17096 First Reading For Entire File......... .60 Last Reading For Entire File.......... .8810 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation. ..... .02/11/25 Maximum Physical Record. .65535 File Type.. ............ ..LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name........ .... .STSLIB.002 Service Sub Level Name... Version Number.. ....... ..1.0.0 Date of Generation...... .02/11/25 Maximum Physical Record..65535 F i 1 e Type. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPS RPX RPM RPD FET ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 60.0 70.0 70.0 70.0 70.0 70.0 110.5 # 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 2411.5 2421.5 2421.5 2421.5 2421.5 2421.5 2462.0 12-JUL-02 Insite 66.37 Memory 2462.0 112.0 2462.0 .3 46.3 70 70 70 70 8763 8763 8763 8763 ( TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER 155789 136749 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 9.875 112.0 # 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: Spud Mud 8.90 217.0 8.0 1000 15.0 2.900 2.430 2.100 4.200 66.0 80.0 66.0 66.0 # 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 MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 60 2462 1261 4805 60 2462 ROP MWD010 FT/H 2.76 1297.46 236.359 4704 110.5 2462 GR MWD010 API 17.6 126.49 64.7016 4704 60 2411.5 RPX MWD010 OHMM 0.06 2000 122.545 4704 70 2421.5 RPS MWD010 OHMM 0.06 2000 154.327 4704 70 2421.5 RPM MWD010 OHMM RPD MWD010 OHMM FET MWD010 HOUR 0.06 0.04 0.05 2000 2000 1.8 211.871 4704 772.566 4704 0.362358 4704 First Reading For Entire File......... .60 Last Reading For Entire File........ ...2462 File Trailer Service name......... ... .STSLIB.002 Service Sub Level Name... Version Number........ ...1.0.0 Date of Generation...... .02/11/25 Maximum Physical Record. .65535 File Type............ ... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name.. ........ ...STSLIB.003 Service Sub Level Name... Version Number.. ...... ...1.0.0 Date of Generation.... ...02/11/25 Maximum Physical Record..65535 File Type....... ...... ...LO Previous File Name.... ...STSLIB.002 Conunent Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX FET RPD RPM RPS ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 2412.0 2422.0 2422.0 2422.0 2422.0 2422.0 2462.5 # 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 BOTTOM) STOP DEPTH 2559.0 2552.0 2552.0 2552.0 2552.0 2552.0 2594.0 13-JUL-02 Insite 66.37 Memory 2594.0 2462.0 2594.0 45.0 46.3 70 70 70 2421.5 2421.5 2421.5 VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 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: $ # 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 TOOL NUMBER 124724 151812 9.875 112.0 Spud Mud 9.00 101.0 9.8 500 10.0 2.900 2.760 2.100 4.200 66.0 69.8 66.0 66.0 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 2412 2594 2503 365 2412 2594 ROP MWD020 FT/H 4.78 749.41 276.069 264 2462.5 2594 GR MWD020 API 27.43 81.88 46.6262 295 2412 2559 RPX MWD020 OHMM 11.26 77.84 22.2593 261 2422 2552 RPS MWD020 OHMM 10.57 50.46 20.3559 261 2422 2552 RPM MWD020 OHMM 10.66 37.05 19.8074 261 2422 2552 RPD MWD020 OHMM FET MWD020 HOUR 11.44 0.17 33.42 9.71 20.0538 3.38571 261 261 First Reading For Entire File........ ..2412 Last Reading For Entire File.......... .2594 File Trailer Service name........ .... .STSLIB.003 Service Sub Level Name... Version Number. ........ ..1.0.0 Date of Generation...... .02/11/25 Maximum Physical Record..65535 File Type. ....... ....... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name..... ....... .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/11/25 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 RPX RPS RPM FET RPD GR ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 2552.5 2552.5 2552.5 2552.5 2552.5 2559.5 2594.5 # 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE STOP DEPTH 5189.0 5189.0 5189.0 5189.0 5189.0 5189.0 5189.0 14-JUL-02 Insite 66.37 Memory 5189.0 2594.0 5189.0 28.4 84.6 TOOL NUMBER 2422 2422 2552 2552 DGR EWR4 $ 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: $ # 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 155789 136749 9.875 112.0 Spud Mud 9.20 108.0 8.0 300 9.4 4.500 3.450 5.200 4.000 74.0 98.6 74.0 74.0 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 2552.5 5189 3870.75 5274 2552.5 5189 ROP MWD030 FT/H 6.62 1244.34 297.936 5190 2594.5 5189 GR MWD030 API 11.73 123.13 67.1117 5260 2559.5 5189 RPX MWD030 OHMM 3.44 242.85 18.29 5274 2552.5 5189 RPS MWD030 OHMM 3.26 347.94 18.9292 5274 2552.5 5189 RPM MWD030 OHMM 3.57 463.05 19.7279 5274 2552.5 5189 RPD MWD030 OHMM 3.57 450.63 20.4676 5274 2552.5 5189 FET MWD030 HOUR 0.04 7.24 0.53329 5274 2552.5 5189 First Reading For Entire File........ ..2552.5 Last Reading For Entire File.......... .5189 File Trailer Service name... ..... .... .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation. ..... .02/11/25 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.... ...02/11/25 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 START DEPTH ROP 5189.5 $ 5 header data for each bit run in separate files. 4 .5000 STOP DEPTH 5380.0 # 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: 16-JUL-02 Insite 4.3 Memory 5380.0 5189.0 5380.0 72.7 78.9 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ TOOL NUMBER # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 9.875 112.0 # 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: # 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... ..0 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. ..0 Spud Mud 9.20 108.0 8.0 300 4.8 .000 .000 .000 .000 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 Name Service Unit DEPT FT ROP MWD040 FT/H Min 5189.5 5.53 Max 5380 973.09 First Reading For Entire File......... .5189.5 Last Reading For Entire File...... .... .5380 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation.'..... .02/11/25 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF File Header Mean Nsam 5284.75 382 201.724 382 .0 74.4 .0 .0 First Reading 5189.5 5189.5 Last Reading 5380 5380 Service name...... ..... ..STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. .... .02/11/25 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 RPD RPM RPS RPX FET ROP $ 6 header data for each bit run in separate files. 5 .5000 START DEPTH 5189.5 5335.0 5335.0 5335.0 5335.0 5335.0 5380.5 # 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 8756.0 8763.0 8763.0 8763.0 8763.0 8763.0 8810.0 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 20-JUL-02 Insite 66.37 Memory 8810.0 5380.0 8810.0 79.6 99.8 TOOL NUMBER 151107 156401 6.125 5370.0 Flo Pro 9.15 53.0 9.3 25000 5.8 .120 .090 .160 .180 68.0 92.0 68.0 68.0 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 Absen t value... . . . . . . . . . . . . . . . . . . . - 9 9 9 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 5i89.5 8810 6999.75 7242 5189.5 8810 ROP MWD050 FT/H 0.16 635.45 189.654 6860 5380.5 8810 GR MWD050 API 33.73 118.48 74.6125 7134 5189.5 8756 RPX MWD050 OHMM 0.33 2000 21.7378 6857 5335 8763 RPS MWD050 OHMM 0.39 2000 26.1797 6857 5335 8763 RPM MWD050 OHMM 0.06 2000 34.2554 6857 5335 8763 RPD MWD050 OHMM 0.04 2000 40.5564 6857 5335 8763 FET MWD050 HOUR 0.2048 76.68 1.5449 6857 5335 8763 First Reading For Entire File......... .5189.5 Last Reading For Entire File........ ...8810 File Trailer Service name......... ....STSLIB.006 Service Sub Level Name... Version Number... ....... .1.0.0 Date of Generation...... .02/11/25 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.007 Physical EOF Tape Trailer Service name............ .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 02 / 11/25 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............. ...UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments...... ....... ....STS LIS Writing Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . . 02/11/25 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.. ............. . UNKNOWN Continuation Number..... .01 Next Reel Name....... ....UNKNOWN Comments. ...... .... ..... .STS LIS Writing Physical EOF Physical EOF End Of LIS File Library. Scientific Technical Services Library. Scientific Technical Services ( Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Nov 21 08:18:29 2002 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . . 02 111/21 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name. .............. . UNKNOWN Continuation Number.... ..01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS aOê)-/3/ ll3 3 G{ Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . . 02/11/21 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 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 AK-MW-22118 J. STRAHAN C. DIXON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MSL 0) # WELL CASING RECORD MPS-05 PB1 500292310070 BP Exploration (Alaska) Sperry-Sun Drilling Services 21-NOV-02 MWDRUN 2 AK-MW-22118 J. STRAHAN C. DIXON MWDRUN 3 AK-MW-22118 J. STRAHAN C. DIXON 7 12N 11E 3360 4772 66.80 39.30 1ST STRING 2ND STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 20.000 112.0 ( 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1, 2, AND 3 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 4. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. SCHNORR, BP ALASKA, INC., DATED 8/29/02. MWD DATA ARE CONSIDERED PDC. 5. MWD RUNS 1, 2, AND 3 REPRESENT WELL MPS-05 PB1 WITH API#: 50-029- 23100-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 5528'MD/4176'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..02/11/21 Maximum Physical Record..65535 File Type....... ........ .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX 1 clipped curves; all bit runs merged. .5000 START DEPTH 60.0 70.0 70.0 70.0 70.0 70.0 STOP DEPTH 5477.5 5487.0 5487.0 5487.0 5487.0 5487.0 ROP $ 110.5 5528.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA PBU TOOL MWD MWD MWD $ SOURCE CODE BIT RUN NO MERGE TOP 1 60.0 2 2462.0 3 2594.0 MERGE BASE 2462.0 2594.0 5528.0 # REMARKS: MERGED MAIN PASS. $ # 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 Abs en t va 1 ue. . . . . . . . . . . . . . . . . . . . . . - 9 9 9 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 60 5528 2794 10937 60 5528 ROP MWD FT/H 2.76 1297.46 263.725 10836 110.5 5528 GR MWD API 11.73 126.49 66.5221 10836 60 5477.5 RPX MWD OHMM 0.06 2000 63.209 10835 70 5487 RPS MWD OHMM 0.06 2000 77.2962 10835 70 5487 RPM MWD OHMM 0.06 2000 102.715 10835 70 5487 RPD MWD OHMM 0.04 2000 346.555 10835 70 5487 FET MWD HOUR 0.04 9.71 0.5251 10835 70 5487 First Reading For Entire File. ........ .60 Last Reading For Entire File... ..... ...5528 File Trailer Service name............ .STSLIB.001 Service Sub Level Name. . . Version Number.... ... ... .1.0.0 Date of Generation...... .02/11/21 Maximum Physical Record. .65535 File Type................LO Next File Name......... ..STSLIB.002 Physical EOF File Header Service name........... ..STSLIB.002 Service Sub Level Name. . . Version Number....... ....1.0.0 Date of Generation...... .02/11/21 Maximum Physical Record. .65535 File Type................LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 60.0 70.0 70.0 70.0 70.0 70.0 110.5 # 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 2411.5 2421.5 2421.5 2421.5 2421.5 2421.5 2462.0 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): 12-JUL-02 Insite 66.37 Memory 2462.0 60.0 2462.0 .3 46.3 TOOL NUMBER 155789 136749 9.875 112.0 Spud Mud 8.90 217.0 8.0 1000 ( 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: 15.0 2.900 2.430 2.100 4.200 66.0 80.0 66.0 66.0 # 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 MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 60 2462 1261 4805 60 2462 ROP MWD010 FT/H 2.76 1297.46 236.359 4704 110.5 2462 GR MWD010 API 17.6 126.49 64.7016 4704 60 2411.5 RPX MWD010 OHMM 0.06 2000 122.545 4704 70 2421.5 RPS MWD010 OHMM 0.06 2000 154.327 4704 70 2421.5 RPM MWD010 OHMM 0.06 2000 211.871 4704 70 2421.5 RPD MWD010 OHMM 0.04 2000 772.566 4704 70 2421.5 FET MWD010 HOUR 0.05 1.8 0.362358 4704 70 2421.5 First Reading For Entire File........ ..60 Last Reading For Entire File......... ..2462 File Trailer Service name.... ........ .STSLIB.002 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation..... ..02/11/21 Maximum Physical Record..65535 File Type............... .LO ( Next File Name.... .......STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number. ......... .1.0.0 Date of Generation..... ..02/11/21 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 FET RPD RPM RPS RPX ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 2412.0 2422.0 2422.0 2422.0 2422.0 2422.0 2462.5 # 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 2559.0 2552.0 2552.0 2552.0 2552.0 2552.0 2594.0 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): 13-JUL-02 Insite 66.37 Memory 2594.0 2462.0 2594.0 45.0 46.3 TOOL NUMBER 124724 151812 9.875 112.0 Spud Mud 9.00 101.0 9.8 500 10.0 ( RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 2.900 2.760 2.100 4.200 66.0 69.8 66.0 66.0 # 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... ..0 Logging Direction..... ... ....... ..Down Optical log depth units.... ...... .Feet Data Reference Point............. . Undefined Frame Spacing................... ..60 .1IN Max frames per record.... ...... ...Undefined Absen t value. . . . . . . . . . . . . . . . . . . . . . - 9 9 9 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2412 2594 2503 365 2412 2594 ROP MWD020 FT/H 4.78 749.41 276.069 264 2462.5 2594 GR MWD020 API 27.43 81.88 46.6262 295 2412 2559 RPX MWD020 OHMM 11.26 77.84 22.2593 261 2422 2552 RPS MWD020 OHMM 10.57 50.46 20.3559 261 2422 2552 RPM MWD020 OHMM 10.66 37.05 19.8074 261 2422 2552 RPD MWD020 OHMM 11.44 33.42 20.0538 261 2422 2552 FET MWD020 HOUR 0.17 9.71 3.38571 261 2422 2552 First Reading For Entire File......... .2412 Last Reading For Entire File....... ... .2594 File Trailer Service name..... ....... .STSLIB.003 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation...... .02/11/21 Maximum Physical Record. .65535 File Type........ .... ... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name... .... ... ...STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..02/11/21 Maximum Physical Record..65535 File Type.. ............. .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 2552.5 2552.5 2552.5 2552.5 2552.5 2559.5 2594.5 # 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 5487.0 5487.0 5487.0 5487.0 5487.0 5477.5 5528.0 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) 14-JUL-02 Insite 66.37 Memory 5528.0 2594.0 5528.0 28.4 84.6 TOOL NUMBER 155789 136749 9.875 112.0 Spud Mud 9.20 108.0 8.0 300 9.4 MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 4.500 3.450 5.200 4.000 74.0 98.6 74.0 74.0 # 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. ..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 2552.5 5528 4040.25 5952 2552.5 5528 ROP MWD030 FT/H 3.35 1244.34 285.106 5868 2594.5 5528 GR MWD030 API 11.73 123.13 68.9948 5837 2559.5 5477.5 RPX MWD030 OHMM 3.44 242.85 17.48 5870 2552.5 5487 RPS MWD030 OHMM 3.26 347.94 18.0984 5870 2552.5 5487 RPM MWD030 OHMM 3.57 463.05 18.9282 5870 2552.5 5487 RPD MWD030 OHMM 3.57 450.63 19.683 5870 2552.5 5487 FET MWD030 HOUR 0.04 7.24 0.528324 5870 2552.5 5487 First Reading For Entire File......... .2552.5 Last Reading For Entire File.. ........ .5528 File Trailer Service name...... ...... .STSLIB.004 Service Sub Level Name... Version Number. ........ ..1.0.0 Date of Generation...... .02/11/21 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Next File Name. ........ ..STSLIB.005 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . . 02 / 11/21 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.............. ..UNKNOWN Continuation Number..... .01 Next Tape Name......... ..UNKNOWN Comments... ...... ""'" .STS LIS Reel Trailer Service name............ .LISTPE Date.................... .02/11/21 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name...... .....,... . UNKNOWN Continuation Number.. ....01 Next Reel Name... ....... . UNKNOWN Comments........ """ ...STS LIS Physical EOF Physical EOF End Of LIS File Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services
