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Home My WebLink About201-075CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: MITs for Milne Point wells F-99 and I-13 Date:Tuesday, August 30, 2022 12:19:21 PM MPU F-99 (PTD 2061560) MPU I-13 (PTD 2010750) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Darci Horner - (C) <dhorner@hilcorp.com> Sent: Tuesday, August 30, 2022 12:14 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Christiana Chigbu <Christiana.Chigbu@hilcorp.com>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Cc: Alaska NS - Milne - Wellsite Supervisors <AlaskaNS-Milne-WellsiteSupervisors@hilcorp.com>; Alaska NS - Wells Foreman <PBWellsForeman@hilcorp.com>; Taylor Wellman <twellman@hilcorp.com>; Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com>; Brian Glasheen <Brian.Glasheen@hilcorp.com> Subject: MITs for Milne Point wells F-99 and I-13 All, Milne Point wells F-99 (PTD # 2061560) and I-13 (PTD # 2010750) and were not brought on line in time for their regularly scheduled MITs this month. They have been shut in since June 2020 and Sept 2018, respectively. Tags were hung on the well heads, they are classified as inoperable, and will be tested prior to returning to injection. Please call myself or Jerimiah Galloway (907-564-5005) with any questions. Regards, Darci Horner Technologist Office: (907) 777-8406 Cell: (907) 227-3036 Email: dhorner@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. STATE OF ALASKA AL/IL OIL AND GAS CONSERVATION COM SSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations Li Fracture Stimulate U Pull Tubing Li CT FCO U Performed: Suspend ❑ Perforate ❑ Acid Stimulate ❑., Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Coil-Nitrogen Q 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska LLC Development ❑ Exploratory E 201-075 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic El Service ❑✓ 6.API Number: AK 99503 50-029-23012-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025517&ADL0025906 MILNE PT UNIT 1-13 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 11,418 feet Plugs measured N/A true vertical 3,745 feet Junk measured 11,313(Fill) RECEIVEDt 9,732, 10,585& JUL 2 0 2017 Effective Depth measured 11,313(CTMD) feet Packer measured 11,052 feet 3,502,3,613& GCC true vertical 3,726 feet true vertical 3,678 feet �J1slti.J Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Production 11,397' 7" 11,397' 3,741' 7,240psi 5,410psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 2-3/8"(Long) 4.6/L-80/IBT 11,103' 3,686' Tubing(size,grade,measured and true vertical depth) 2-3/8"(Short) 4.6/L-80/IBT 10,626' 3,619' Baker GT Dual x(2) Packers and SSSV(type,measured and true vertical depth) &Baker FH N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A SCANNEV Aki& Treatment descriptions including volumes used and final pressure: N/A 1 6'2017 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 0 1,935 SS Subsequent to operation: 0 0 197 560 1,231 LS Subsequent to operation: 0 0 223 560 1,231 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 2Exploratory❑ Development❑ Service 2 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas l 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: 317-055 Si;rp Authorized Name: Bo York Contact Name: Stan Porhola Authorized Title: Operations Manager Contact Email: Sporhola@hilcorp.com Authorized Signature: r Dab 7/20/2017 Contact Phone: 777-8412 Form 10 404 Revised 4/2017 re.,, 1 /7 RBDMS V,' JUL 2 7 2017 7 Submit Original Only • II Milne Point Unit Well: MP 1-13 SCHEMATIC Last Completed: 7/14/2010 liken)Alaska.LLC PTD: 201-075 TREE&WELLHEAD Tree 2-1/16"- 5M Dual McEvoy Orig.KB Elev.=64.12/04 GL Elev.=35.10 11"x 2-3/8"5M FMC Dual w/2.375"EUE T&B Thread ,� — Wellhead FMC Tubing Hanger 2.0"CIW"H"BPV Profile 20" r I OPEN HOLE/CEMENT DETAIL 20" 260 sx Arcticset in a 30"Hole 0 0 TAM Port Collar 7" 1445 sx Class'G',485 sx Permafrost'L'in a 9-7/8"Hole @1,416' WELL INCLINATION DETAIL KOP @ 405' Max hole angle=85 deg.at 3,686'MD Hole angle thru perfs=84 deg at 10,260'MD CASING DETAIL Size Type Wt/Grade/Conn ID Drift Top Btm BPF 1 14 20" Conductor 92/H-40/N/A 19.124" 18.936" Surface 112' 0.3553 8i A 7" Production 26/L-80/Hydril 521 6.276" 6.151" Surface 11,397' 0.0383 TUBING DETAIL 2-3/8" Tubing(Long) 4.7/L-80/EUE(SCC) 1.995" 1.901" Surf 11,103' 0.0039 2-3/8" Tubing(Short) 4.7/L-80/EUE(SCC) 1.995" 1.901" Surf 10,626' 0.0039 TUBING DETAIL No Top Depth Item LONG STRING 1 2,353' HES 2-3/8"'X'Nipple 2 9,683' HES 2-3/8"'X'Nipple 3 9,732' Baker Model'GT'Retrievable Dual Packer 40K Shear 4 10,585' Baker Model'GT'Retrievable Dual Packer 40K Shear 5 10,616' HES 2-3/8"'X'Nipple 6 11,052' Baker FH Packer 40K ROT Release 7 11,079' 2-3/8"'XN'Nipple 1.795"No Go TOC @7150' 8 11,091' Baker Model'E'Hydro-Trip Sub CBL8I26/01 9 11,102' 2-3/8"WLEG–Bottom @ 11,103' SHORT STRING B A 2,390' HES 2-3/8"'X'Nipple 2 Ci B 9,681' HES 2-3/8"'X'Nipple c 9,730' Baker Model'GT'Retrievable Dual Packer 40K Shear D 10,583' Baker Model'GT'Retrievable Dual Packer 40K Shear E 10,602' 2-3/8"'XN'Nipple 1.795"No Go 3 C F 10,613' Baker Model'E'Hydro-Trip Sub N Saids G 10,624' 2-3/8"WLEG–Bottom @ 10,626' — PERFORATION DETAIL a _r I, D Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT SPF Size Date Status ' N 9,800' 9,820' 3,513' 3,516' 20 6 2.5" 8/27/2001 Isolated �,k 5 4:4IA E 95"@5867; OA 10,710' 10,870' 3,630' 3,651' 160 5 4.5" 7/05/2010 Open F Minimum ICOB 11,100' 11,200' 3,685' 3,704' 100 5 4.5" 7/05/2010 Open TCF @10,880 G I Ref Log:Sperry MWD–7/31/2001–Perf Guns 2.5"/6 spf;Perf Guns 4.5"/38.6 gram 5 spf MD-6n7n7 GENERAL WELL INFO OA Sands API:50-029-23012-00-00 s, * 6 Drilled&Cased by Nabors 22E–8/19/2001 Mfimum II . 1.795"@5,976' ■ e' Perf&Run Dual String by Nabors 4ES–7/14/2010 0. 7 CT FCO&Acid Stimulation–6/28/2017 TOF@11,303 — OB Sands CTN1D-6"28/17=' " 7'44,, '*' <* TD(MD)=11,418'/ TD(TVD)=3,745' PBTD(MD)=11,313'/PBTD(TVD)=3,726' Revised By:TDF 7/20/2017 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP 1-13 CTU 50-029-23012-00-00 217-075 6/27/17 6/28/17 Daily Operations: 6/21/2017-Wednesday No activity to report. 6/22/2017-Thursday No activity to report. 6/23/2017- Friday No activity to report. 6/24/2017-Saturday No activity to report. 6/25/2017-Sunday No activity to report. 6/26/2017- Monday No activity to report. 6/27/2017-Tuesday SLB CTU #8 w/ 1.5" CT MIRU yesterday and tested BOPE-4 hours. PUMP IN FLANGE ON WELL LINED UP TO SHORT STRING. Today-On site at 6:00. PJSM. MU 1.5" CTC, checks, stingers, DJN - 12' long. On well. PT 300/3600 psi. Open well -T/I/O = 263/0/0. RIH with returns to tank. Able to reach 10,880' with no tag. Bottom perf at 10,870'. Perform FCO with 5 bbl gel sweep from TT to 10,877'. Unable to get deeper due to stacking wt-snubbing-9000lbs while pumping. Pump BU. Post FCO pump with nozzle at 10,877', pump 30 baraklean hot (130 deg) treatment. SD after baraklean out of coil to soak. Close choke. WHP walked up to 1200 psi. Post soak, open choke and circulate OOH while POOH.Tag up at surface. Stand injector back and cap BOPE. MIRU Halliburton acid and pumping equipment. PJSM with all about acid job and hazards/ mitigations. PT surface lines low and high. Line up to pump acid trtmt down tubing. Get pre-treatment injection rates pumping NH4CL fluid. .2 bpm -780 psi WHP. .5 bpm -995 psi WHP. 1 bpm - 1220 psi WHP. 1.5 bpm - 1410 psi WHP. 2.0 bpm - 1600 psi WHP. Pump K-Spar acid treatment. 35 bbls NH4CL. 35 bbls 12% HCL.A4570 bbls 9:1 Kspar mud acid. 61.5 bbls NH4CL overflush. 20 bbls water. 10 bbls 60/40 FP Acid treatment pumped away at 1.8-2 bpm at 1750 psi WHP. No significant breakdown seen during entire treatment. Post inj rates pumping the 60/40 were: .2 bpm - 1190 psi WHP. .5 bpm - 1230 psi WHP. 1 bpm - 1400 psi WHP. 1.5 bpm - 1690 psi WHP. Shut down pumping. Shut in and secure well. Pull pump in sub flange and re install to line up flange TO LONG STRING. SDFN. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP 1-13 CTU 50-029-23012-00-00 217-075 6/27/17 6/28/17 Daily Operations: 6/28/2017-Wednesday On location. PJSM. MU BHA . On well. PT to 400/4,100psi_ Lined up to LONG STRING. Open well to 323psi SITP. IA=Opsi/ OA=Opsi RIH with 1.5" DJN taking returns to tank. Wt Cks at 5,270' -8k, 8,620' - 12k, 10985'- 16k. Soft dry tag at 11,133' ctmd. PU and unable to RIH. Coil in lockup. Had to POOH to 10,200' and RBIH to keep coil sliding down. Keep pipe moving and able to reach 11,303' ctmd. (Bottom perf at 11,200'). Perform FCO with gel sweeps. Pump 30 bbl BaraKlean trtmt. Able to maintain returns. Pump rate 1.6 bpm/3460psi CTP/280psi WHP. Start POOH chasing returns and BaraKlean. Pulled heavy from 11,033'to 10,850'. 14k overpull continuous. Either metal friction or some solid slug around pipe. At 10,930', Wt started falling off and resume POOH normal weight.Tag up at surface. Pump down backside to ensure injectivity. Achieved .5 bpm at 1036psi WHP inj rate. Standback injector. RU HAL acid equip. PJSM. PT surface lines to 4,100psi. 2,000psi is MAX WHP Pump Schedule = 32 bbls NH4CL- 32 bbls 12% HCL-64 bbls 9:1 HF acid - 58 bbls NH4CL. Initial inj rate test with NH4CL .5 bpm - 1,020psi WHP 1 bpm - 1,245psi WHP 1.5 bpm - 1,450psi WHP 2 bpm - 1,650psi WHP 2.5 bpm - 1,950psi WHP Pumped acid treatment as per program. Average rate of 2 bpm/Average WHP- 1,950psi. No significant pressure drop with acid seen. FP well with 15 bbls 60/40. RDMO CTU and Acid equip.Job Complete. post inj rates were: .5 bpm - 1,256psi WHP 1 bpm - 1,486psi WHP 1.5 bpm - 1,715psi WHP 2 bpm - 2,060psi WHP 6/29/2017-Thursday No activity to report. 6/30/2017- Friday No activity to report. 7/1/2017 Saturday No activity to report. 7/2/2017-Sunday No activity to report. 7/3/2017- Monday No activity to report. 7/4/2017-Tuesday No activity to report. • • ,. Ty 4,,OF y ". THE STATE Alaska Oil and Gas d, ofA TT ®® S KA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER "" `"" "Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager SCANNED k F' �lk' Hilcorp Alaska, LLC �� 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU I-13 Permit to Drill Number: 201-075 Sundry Number: 317-055 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 1. Foerster Chair DATED this 4-day of February,2017. RBDMS L L_F. - 3 2017 RECEIVED STATE OF ALASKA • JAN 2017 ALASKA OIL AND GAS CONSERVATION COMMISSIONtZ,,,��7 APPLICATION FOR SUNDRY APPROVALS (( 20 MC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulatett ❑ Repair Well El " CT FCO 2Suspend ❑ Perforate ❑ Other 5ttrulate ❑ • Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Coil-Nitrogen Q 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑ 201-075 ' 3.Address: 6.API Number: Stratigraphic ❑ Service ❑✓ . 3800 Centerpoint Dr,Suite 1400 50-029-23012-00-00 . 7.If perforating: 8.Well Name and Number: hr!1� 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)61-13 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025906 &ADL0025517 ' MILNE POINT/SCHRADER BLUFF OIL' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,418' ' 3,745' , 11,313' . 3,726' • 1,935 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Production 11,397' 7" 11,397' 3,741' 7,240psi 5,410psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 2-3/8"(Long) 4.6#/L-80/IBT 11,103 See Attached Schematic I See Attached Schematic 2-3/8"(Short) 4.6#/L-80/IBT 10,626 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker GT Dual;Baker GT Dual;Baker FH and N/A 9,732(MD)/3,502(TVD),10,585(MD)/3,613(TVD)&11,052(MD)/3,678(TVD)and N/A 12.Attachments: Proposal Summary ❑l Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑., Exploratory ❑ Strati ra hic❑ Development❑ Service ❑ • 14.Estimated Date for 15.Well Status after proposed work: 2/10/2017 Commencing Operations: OIL ❑ WINJ 0 • WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: N/A GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Stan PorholaSTP Email sporhola(a�hilcorp.com Printed Name Bo York Title Operations Manager go Signature Signature / Phone 777-8345 Date 1 x/2017 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry I Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ }"t5 F 2-1-2-Ip Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ J Spacing Exception Required? Yes ❑ No I" Subsequent Form Required: I U —'y Ci Li RBDMS L�r - 3 2017 /Q /7l / APPROVED BY Approved by/` COMMISSIONER THE COMMISSION Date: 2 -2— Submit Form and Form 10-403}2 yised 11/2015 OFTGINAL 0d aalid for months from the date of approval. Attachments in Duplicate P l y a —/—/ . -,•14, • • Well Prognosis Well: MPU 1-13 Hilcorp Alaska,LL' Date:1/27/2017 Well Name: MPU 1-13 API Number: 50-029-23012-00 Current Status: Dual String Water Injector Pad: Milne Point I-Pad Estimated Start Date: February 10th, 2017 Rig: Coil Tubing Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 201-075 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) SAFE Number:„ , ..„dryType,:Job 7 suo1 Abid Cleanout Current Bottom Hole Pressure: 2,335 psi @ 4,000' TVD (Last BHP measured 6/26/2016) Maximum Expected BHP: 2,335 psi ©4,000' TVD (No new perfs being added, EMW= 11.22 ppg),/ MPSP: 1,935 psi (Based on 0.10 psi/ft gas gradient) Brief Well Summary: MPU 1-13 was drilled in 2001 using Nabors 22E and perforated in the Schrader Bluff NB sands. The well was left suspended until 2010 when a workover with Nabors#4ES added perforations in the Schrader Bluff OA and OB sands, isolated the NB sands between packers and ran a dual completion.The well is currently a Shut-in water injector due to limited connectivity with its offset producers (MPU I-11 and MPU 1-12) and high injection pressures. Notes Regarding Wellbore Condition • Max deviation (max angle 85.0° @ 3,686'). • Casing last tested to 2,000 psi for 30 min down to 9,732'on 8/15/2014. • Deviation at perfs is 79.0°—83.0°. • Dual string 2-3/8". Min ID is 1.795"thru XN profiles. • Last Fill Depth: Unknown. Objective: The purpose of this work/sundry is to clean any debris in the tubing (both strings separately), cleanout fill using foamed nitrogen to lift any fill/debris in the casing (cleanout down both strings separately) and spotting acid across the OA and OB perfs using 9:1 K-Spar acid (9:1 ratio of HCI/HF) and 12% Hydrochloric acid (acidize perfs in both strings separately). ✓ 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 3,500 psi Hi 250 Low,5 min each test. a. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. b. No AOGCC notification required. c. Submit 10-424 form within 5 days. '._ • • Well Prognosis Well: MPU 1-13 lcurAlaska, � ��/5/1Date: 1/27/2017 3. RIH w/1.50" coil w/ 1.5"to 1.75" max OD wash nozzle and cleanout BHA and cleanout to PBTD at+/- 11,313' MD(Long String) and 11,052' MD(Short String). POOH. a. Circulate 40 bbl of heated diesel with Barascrub or Baraklean (to remove schmoo) and displace w/ 8.5 ppg seawater to surface. ,,bb. Circulate out fill using 8.5 ppg seawater w/friction reducer. Pump 5-10 bbl Gel Sweeps to help remove solids from the 7" casing. c. Contingency: If unable to wash down with nozzle, RIH w/1.5"to 1.75" reverse circ BHA and reverse circulate (see Reverse Circulating diagram)to PBTD at+/- 11,313' MD(Long String) and 11,052' MD(Short String). POOH. d. Contingency: If unable to wash down with nozzle, RIH w/1.5"to 1.75" mill and cleanout BHA and cleanout to PBTD at+/- 11,313' MD (Long String) and 11,052' MD (Short String). POOH. 4. RIH w/1.50" coil w/1.5"to 1.75" max OD wash nozzle and cleanout BHA and cleanout to PBTD at+/- 11,313' MD (Long String) and 11,052' MD (Short String). POOH. a. Circulate out fill using 8.5 ppg seawater w/liquid foamer and mix with Nitrogen (see Nitrogen procedure and diagram). Utilize defoamer for returns in Kill Tank. rc: b. Contingency: If unable to wash down with nozzle, RIH w/1.5"to 1.75" mill and cleanout BHA and cleanout to PBTD at+/- 11,313' MD(Long String) and 11,052' MD (Short String) using 8.5 ppg seawater w/liquid foamer and mix with Nitrogen. POOH. . RIH w/1.50" coil w/1.5"to 1.75" max OD wash nozzle and cleanout BHA and cleanout to PBTD at+/- 11,313' MD(Long String) and 11,052' MD(Short String). 6. Spot 30-40 bbl of 9:1 K-Spar acid (9:1 ratio of HCI/HF) and 12% Hydrochloric acid across the perfs, displace w/5% NH4CI (Ammonium Chloride) and allow to soak up to 4 hours. 5,A g- 7. Circulate out any acid and ammonium chloride in the well w/8.5 ppg seawater to surface. 8. RU to test injectivity into the perfs. Do not exceed 1,500 psi. POOH. 9. Contingency: If unable to establish injectivity, repeat steps#5-#8. 10. PU to 2,200' and freeze protect well. POOH w/coil. 11. RD Coiled Tubing and ancillary equipment. 12. Turn well over to production. Attachments: 1. As-built Schematic 2. Coil BOPE Schematic 3. Nitrogen Operations Procedure 4. Nitrogen&Foam Flow Diagram 5. Reverse Circulating Flow Diagram 6. Acidizing Flow Diagram • • Mime PointMP Unit. fir 1-13 We SCHEMATIC Last Completed: 7/14/2010 Mean)Alaska,LLC PTD: 201-075 TREE&WELLHEAD Tree 2-1/16"- 5M Dual McEvoy Orig.KB Elev.=64.12/Orig.GL Elev.=35.10 11"x 2-3/8"5M FMC Dual w/2.375"EUE T&B Thread Wellhead FMC Tubing Hanger 2.0"OW"H"BPV Profile 20" k ,' OPEN HOLE/CEMENT DETAIL ,;+ r' 20" 260 sx Arcticset in a 30"Hole V. •p,,f TAM Port Collar 7" 1445 sx Class`G',485 sx Permafrost'L'in a 9-7/8"Hole @ 1,416' WELL INCLINATION DETAIL KOP @ 405' Max hole angle=85 deg.at 3,686'MD Hole angle thru perfs=84 deg at 10,260'MD CASING DETAIL 1 -' Size Type Wt/Grade/Conn ID Drift Top Btm BPF >I! A 20" Conductor 92/H-40/N/A 19.124" 18.936" Surface 112' 0.3553 7" Production 26/L-80/Hydril 521 6.276" 6.151" Surface 11,397' 0.0383 TUBING DETAIL 2-3/8" Tubing(Long) 4.7/L-80/EUE(SCC) 1.995" 1.901" Surf 11,103' 0.0039 2-3/8" Tubing(Short) 4.7/L-80/EUE(SCC) 1.995" 1.901" Surf 10,626' 0.0039 TUBING DETAIL No Top Depth Item LONG STRING 1 2,353' HES 2-3/8"'X'Nipple 2 9,683' HES 2-3/8"'X'Nipple 3 9,732' Baker Model'GT'Retrievable Dual Packer 40K Shear 4 10,585' Baker Model'GT'Retrievable Dual Packer 40K Shear 5 10,616' HES 2-3/8"'X'Nipple tI•' TOC©7,150' 6 11,052' Baker FH Packer 40K ROT Release ft,„ 1, CBL 8/26/01 7 11,079' 2-3/8"`XN'Nipple 1.795"No Go ,,; 8 11,091' Baker Model'E'Hydro-Trip Sub ,. =t B ;': 9 11,102' 2-3/8"WLEG—Bottom @ 11,103' 2.Z' , SHORT STRING A 2,390' HES 2-3/8"'X'Nipple B 9,681' HES 2 3/8"'X'Nipple I / s & :_ ; •�` 'C C 9,730' Baker Model'GT'Retrievable Dual Packer 40K Shear .. ' i D 10,583' Baker Model'GT'Retrievable Dual Packer 40K Shear NSands _- E 10,602' 2-3/8"'XN'Nipple 1.795"No Go (�� F 10,613' Baker Model'E'Hydro-Trip Sub 4 * D G 10,624' 2-3/8"WLEG—Bottom @ 10,626' Mnimum ID f PERFORATION DETAIL 1.795"@5,867' 1 Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT SPF Size Date Status - A N 9,800' 9,820' 3,513' 3,516' 20 6 2.5" 8/27/2001 (Isolated �) OA Sands .. ,. OA 10,710' 10,870' 3,630' 3,651' 160 5 4.5" 7/05/2010 Open 2, OB 11,100' 11,200' 3,685' 3,704' 100 5 4.5" 7/05/2010 Open Ref Log:Sperry MWD—7/31/2001—Perf Guns 2.5"/6 spf;Perf Guns 4.5"/38.6 gram 5 spf 'S � ,1 � � 61ati MnimumID= ,;' - si �1uS� D 1.795"@5,976 GENERAL WELL INFO 7 8 API:50-029-23012-00-00 OB Sands ._, 9 Drilled&Cased by Nabors 22E—8/19/2001 ' Perf&Run Dual String by Nabors 4ES—7/14/2010 TD(MD)=11,418'/ TD(TVD)=3,745' PBTD(MD)=11,313'/PBTD(TVD)=3,726' Revised By:STP 2/07/2016 Milne Point Unit COIL BOPE MPU I-13 1/27/2017 rihI. n,n i.ka,LL( To injection head I 1.50"Single Stripper I MPU 1-13 20 X 7 X 2%(Dual) ,i , Coil Tubing BOP Lubricator o I . Baa INN flit Blind 4 1/16 15 Blind L'.'• 1 EMI `l•',I, Shear -.11111_ Shear' �I■I•( -mom 0011Slip11= ® ■� Slip *Ill -MINN =Me • III Pipe :. MIU Ma 1 Pipe 101° 0i e Crossover spool z=, 4 1/16 15M X 4 1/16 10M lip Crossover spool 4 1/16 10M X 4 1/16 5M rea .sin.. Pump-In Sub . j.� ��, .J� 4 1/16 5M • .• ' AP •11. ° g '�111 1502 Union Manual Gate Manual Gate Crossover spool r 2 1/8 5M 2 1/8 5M in;4 1/16 5M X 2 3/8 5M 1►� Valve,Swab,WKM-M, � 2 3/8 5M FE(Long-String) � i 4-; Valve,Swab,WKM-M, �l/t4 0 2 3/8 5M FE(Short-String) ., 0, IIIII OL cne ' ''''' '- ° n'' iip I I 111;e011111 ,12,\'''',,'0 ,/et' ,64 1 liv&";Oil 10111 a, it ii-ii, -: ji Jr ' Valve,Upper Master,Baker, 2 3/8 5M FE,w/Hydraulic ,:. 0 `} Valve,Upper Master,Baker, (Long String) 2 3/8 5M FE,w/Hydraulic �� (Short-String) o'` Valve,Lower Master,WKM-M, r".".1-Aern 2 3/8 5M FE(Long-String) 1�,, �s '* Valve,Lower Master,WKM-M, ® " ' 2 3/8 5M FE(Short String) NII II 4 es4 mils f gilAl It Tubing Adapter,11 x 7 �� >i 4 � x23/8dual5M _ • • STANDARD WELL PROCEDURE il,!carp 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/CO2/02 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 0 0 , I I T r:::"..... .. • -cs 0 0 0 E c.-:::••••• .••••••••. •-, >) > g E •: . 2 74 7F-d 0 ct d CC z ce d ce 2 cc w o L=., u, o ti ---2 c[ r- 4'-' ,s•-•2 re P 2 4.= V8I 3 < ouL.... E 0034ouo. n . 0 ro_ —Nee,,. z., . izzo / .. . W 2 = a- 2 2 w a z : •°m 1.) > 74 0 m -E)-1, :V i'' :...-*: 9 4 8- 0 ?."•. w . 0 >,., t -6 .• ' = T.0 0 CO CO 2 -.1—i N : 'i '•• '. ' • rc 2 6 Em = E r..• ._ ..T... (.7 rEi 0 4 .3 a a •IS ar . _ -4 ; #791111111i 1 -0 z '2 M g El , w (..) l' ..v o u A i ,,,,,,.. .... 110111 OM wo- viersi Z-40.4>. ,- w V - 1 a 0 0 ,,,...„ .-,,_.. ,,,,, r It § .---.17,-37; 1 III 11 1111 111 ° T "'" 'P a , °..j .*9 11 umallop i• 111111Elli- -1111011:'-' _1.. ,.. ---,- ._.____ i um tutu ini I 0 0 0 1 . . 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O r 0 ,t ® n r F O r- �.7.:, .+ In 11 31 lin ° . ,.. i ,�� i ins H ii, -l , : iI� r- Iii, ldi 1 � fii '� 'i O O O W Y d N a W 6 `S `u x W V .ti. 0 o o m F m Um a V Y Q F J Y 00 m 0 0 41 AI 4 i t • • r 1 x I 2 C7 z ac7 u m m G a o E > o w ix 'a e Z' 4 ae z 4 cc z w > R1 U G:Q Q O m a co f W W ,,, v) hit II --.1111101i--- • ugZzo a 2 0 C) Q QI. : W T4 , s °' TOPiliki 2' . w , '' , c to 2 l s (o *At':?. ct' , t U mu IF 41 °t V ( $71 lL 9 O O F- 0 q' f t 1 ,4 w+ t illi 11 3/1 ILII . i 4mitai! a N OO O W Y W N Z W .:4 R 0 0 O O m F J W m N2 0. D Y 2 Q F J Y J a m O O LA 0 4 L • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 M December 30, 2011 , l D FEES ;l! . Z Mr. Tom Maunder Q 1 — 7 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue nA 3 Anchorage, Alaska 99501 ' " Subject: Corrosion Inhibitor Treatments of MPI -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPI -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator i 0 BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) MPI -Pad 10/9/2011 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft gal MPI -01 1900900 50029220650000 0.1 NA 0.1 NA 8.5 9/5/2011 MPI-02 1900910 50029220660000 Sealed coductor NA NA NA NA NA MPI-03 1900920 50029220670000 Sealed coductor NA NA NA NA NA MPI -04A 2010920 50029220680100 Sealed coductor NA NA NA NA NA MPI-05 1951200 50029225830000 2.7 NA 2.7 NA 27.2 11/2/2009 MPI-06 1971950 50029228220000 Open Flutes - Treated NA NA MPI -07 1951510 50029226020000 1.7 NA 1.7 NA 16.2 8/21/2011 MPI-08 1971920 50029228210000 1.3 NA 1.3 NA 15.3 11/2/2009 MPI-09 2001030 50029229640000 1.3 NA 1.3 NA 13.6 11/1/2009 MPI -10 2001090 50029229660000 Open Flutes - Treated NA NA MPI -11 2011370 50029230330000 1.3 NA 1.3 NA 10.2 8/19/2011 MPI -12 2011630 50029230380000 0.2 NA 0.2 NA 7.7 10/9/2011 -> MPI -13 2010750 50029230120000 0.85 NA 0.85 NA 8.5 9/5/2011 MPI -14 2041190 50029232140000 1.9 NA 1.9 NA 16.2 8/23/2011 MPI -15 2021520 50029231060000 1 NA 1 NA 9.4 8/19/2011 MPI -16 2041580 50029232210000 1.75 NA 1.75 NA 17.0 8/19/2011 MPI -17 2040980 50029232120000 1.75 NA 1.75 NA 13.6 8/23/2011 MPI -19 2041350 50029232180000 1.4 NA 1.4 NA 10.2 8/19/2011 STATE OF ALASKA RECEIVED ALASKA AND GAS CONSERVATION COMMISSIOI• REPORT OF SUNDRY WELL OPERATIONS {I` 1. Operations Abandon U Repair Well U Plug Perforations U Stimulate U k kW. CiJAaneissio Performed: Alter Casing p Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time ExtensionnChcra Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended We 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development 0 Exploratory p 201 -075 -0 • 3. Address: P.O. Box 196612 Stratigraphic❑ Service 0 6. API Number: Anchorage, AK 99519 -6612 • 50- 029 - 23012 -00 -00 ' 7. Property Designation (Lease Number): 8. Well Name and Number: ADLO- 025517 / 025906 3� MPI -13LS • 9. Field /Pool(s): gi r :. iI 9' Y � MILNE POINT, SCHRADER BLFF OIL • 10. Present Well Condition Summary: Total Depth measured 11418 • feet Plugs measured None feet true vertical 3745 feet Junk measured None feet Effective Depth measured 11313 • feet Packer measured 9730 10582 11052 feet true vertical 3726 • feet true vertical 3502 3612 3677 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 91.1# H-40 22 - 102 22 - 102 1530 520 Surface None None None None None None Intermediate None None None None None None Production 11376 7" 26# L -80 21 - 11397 21 - 3741 7240 5410 l Liner None None None None None None Perforation depth Measured depth 11100 - 11200 feet 1 q True Vertical depth 3621.2 - 3640.4 feet ` MAR `� Tubing (size, grade, measured and true vertical depth) 2 -3/8" 4.7# L -80 20 - 11103 20 - 3686 Packers and SSSV (type, measured and true vertical depth) 7 "X2 -3/8" BAKER GT 9730 3502 Packer 7 "X2 -3/8" BAKER GT 10582 3612 Packer 7 "X2 -3/8" BAKER GT 11052 3677 Packer 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 250 1777 Subsequent to operation: 268 1780 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run Exploratory Development Service • Stratigraphic ❑ Daily Report of Well Operations 15. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ 112 • WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310 -402 Contact Joe Lastufka Prepared by Joe Lastufka 564 -4091 Printed am. Joe La m Title Data Manager Signatu - IL V I . _ Phone 564 -4091 Date 2/25/2011 I GI NAL z • Form 10-404 Revised 10/2010 Q 7a 2• / / Sub mit O ' ' nal Only ■ MPI -13 201 -075 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPI -13 8/27/01 PER 9,800. 9,820. 3,513.73 3,517.05 MPI -13 3/26/10 BPS 9,750. 9,800. 3,505.42 3,513.73 MPI -13 3/28/10 BPS 9,210. 9,800. 3,394.39 3,513.73 MPI -13 6/22/10 BPS 2,500. 9,800. 2,185.31 3,513.73 MPI -13 7/1/10 BPP 2,500. 9,800. 2,185.31 3,513.73 MPI -13 7/5/10 APF 10,710. 10,870. 3,630.72 3,651.08 MPI -13 7/5/10 APF 11,100. 11,200. 3,685.32 3,704.52 MPI -13 7/9/10 MIS 9,800. 9,820. 3,513.73 3,517.05 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER • BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • MPI -13LS DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY r 2/7/2011 TSS/TLS /I /0= 1800/1750/0/0 (Pre Acid Treatment Injectivity Test) Pump 5 bbls 60/40 meth down SS Tbg @ 0.40 bpm 1950 psi injectivity. Pump 5 bbls 60/40 meth down LS Tbg @ 0.65 bpm, 2000 psi injectivity. FWHP= 1800/1750/0/0. Operator notified. Both LS and SS back on Injection. LS /SS Swabs closed. LS /SS Wings, Mst., IA, OA ;open. 2/9/2011 T/I = 1500/0 Acid treatment on both Long and Short Strina, Pumped 3bbls 60/40, 10bbls produced water, 20bbls 12 /o DAD acid, 3bbls 60/40, 12bbls P produced water, P 3bbls 60/40 down each string. FWHP's = 1500/0. Swab, Wing, Lateral, SSV = shut. Master, IA = open. i ! FLUIDS PUMPED BBLS 20 12% DAD ACID 14 60/40 METH 22 PRODUCED WATER 56 TOTAL • • Tree: McEvoy 2- 1/16 "5M Dual String Wellhead: UH -60, 11 x 2 -3/8 UPTBG MPU 1 - 13i Orig. DF elev. = 64.12' (Nabor 22 -E) top, , 200 -4 PKT TOP, CIW H BPVT Orig. GL. elev.= 35.10'(Nabor 22 - __,,,...,_ 20" 91.1 ppf, H -40 ( 7 ` 0 TAM port collar at 1416` KOP 0 405' Max. hole angle = 85 deg. ;i ` Note: Hole angle through pens = 82 deg. Short string would not drift with anything larger than 1.920 OD. ''i A 1.920 drift was used on long string also. ,m, 2 -3/8" X Nipple 1.875" iD I 2353' I X ,4 1 ' X 2 -3/8" X Nipple 1.875 ID I 2390' S ri 7 ", 26# L -80, HYD521 production casing (drift ID= 6.151 ", cap. = .0383 bbls/ ft) 2 -3/8 ", 4.7 #, L -80, EUE 8rd Tbg (Drift ID = 1.901 ", Cap= .00387 bpf ri. ® © 2 -3/8" X Nipple 1.875" iD 9680' 2 -3/8" X Nipple 1.875" ID I 9683' I .T-. 7" x 2 -3/8" Baker GT Dual Pkr. 9730' .7 M '-'-': 1 1 7" x 2 -3/8" Baker GT Dual Pkr. 10,582' 2 -3/8" XN w/ 1.87" pkg. bore 10,602' 2 -3/8" X Nipple 1.875" ID I 10,615' I Ell Model E -Hydro trip sub1.906" ID ( 10,613' O 2 -3/8" WLEG 1.75" drift ID I 10,626' Perforation Summary Al Ref log: 7" x 2 -3/8" Baker FH Pkr. 11,052' Size SPF Interval (TVD) 2 -3/8" XN 1.87" pkg. bore 11,079' N sand 2.5" 4 9800'-9820' 3513`-3516' Model E -Hydro trip sub 1.906" ID I 11,091' OA sand g 2 -3/8" WLEG 1.75" drift ID I 11,103' 4.5" 5 10,710' - 10,870' 3630' -3651' OB sand - // 4.5" 5 11,100' - 11,200' 3685' -3704' 7" float collar (PBTD) I 11313' 4E- zk 7" casing shoe 1 11397' 1 DATE REV. BY COMMENTS MILNE POINT UNIT 08/19/01 M.Linder Initial completion Nabors 22 -E WELL 1 -13i 7/14/10 REH Pert and run Dual String completion - N4ES API NO: 50 - 23012 - BP EXPLORATION (AK) RECEIVED STATE OF ALASKA • ALASKA OAND GAS CONSERVATION COMMISSION FEB 2 8 7 34 REPORT OF SUNDRY WELL OPERATIONS Alaska Gil lit Gas Cons: Commission 1. Operations Abandon U Repair Well U Plug Perforations U Stimulate U Other Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool El Waiver ❑ Time Extensio ❑ *r Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended We❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development ❑ Exploratory ❑ 201 -075 -0 • 3. Address: P.O. Box 196612 Stratigraphic Service ISI 6. API Number: • j / Anchorage, AK 99519 -6612 50- 029 - 23012 Z •7S6 • J! 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025517 • q � ,Qp�,. G'2`gF' MPI -13SS 9. Field /Pool(s): / z. . 2g: MILNE POINT, SCHRADER BLFF OIL • 10. Present Well Condition Summary: Total Depth measured 11418 • feet Plugs measured None feet true vertical 3745 • feet Junk measured None feet Effective Depth measured 11313 • feet Packer measured 9730 10582 11052 feet true vertical 3726 • feet true vertical 3502 3612 3677 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 91.1# H -40 22 - 102 22 - 102 1530 520 Surface None None None None None None Intermediate None None None None None None Production 11376 7" 26# L -80 21 - 11397 21 - 3741 7240 5410 Liner None None None None None None Perforation depth Measured depth SEE ATTACHED feet True Vertical depth feet StAKINED 201 r Tubing (size, grade, measured and true vertical depth) 2 -3/8" 4.7# L -80 20 - 10626 20 - 3619 Packers and SSSV (type, measured and true vertical depth) 7 "X2 -3/8" BAKER GT 9730 3502 Packer 7 "X2 -3/8" BAKER GT 10582 3612 Packer 7 "X2 -3/8" BAKER GT 11052 3677 Packer 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 262 1841 Subsequent to operation: 408 1396 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run Exploratory Development ServiceQ • Stratigraphic ❑ Daily Report of Well Operations 15. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ Q" WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310 -403 Contact Joe Lastufka Prepared by Joe Lastufka 564 -4091 Printed N oe Lastufka Title Data Manager Signature Phone Date 2/25/2011 3 - Nt /� g: 2 -20 Form 10 -404 Revised 10/2010 Su b mit Original J RIGINAL r MPI -13 201 -075 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPI -13 8/27/01 PER 9,800. 9,820. 3,513.73 3,517.05 MPI -13 3/26/10 BPS 9,750. 9,800. 3,505.42 3,513.73 MPI -13 3/28/10 BPS 9,210. 9,800. 3,394.39 3,513.73 MPI -13 6/22/10 BPS 2,500. 9,800. 2,185.31 3,513.73 MPI -13 7/1/10 BPP 2,500. 9,800. 2,185.31 3,513.73 MPI -13 7/5/10 APF 10,710. 10,870. 3,630.72 3,651.08 MPI -13 7/5/10 APF 11,100. 11,200. 3,685.32 3,704.52 MPI -13 7/9/10 MIS 9,800. 9,820. 3,513.73 3,517.05 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER • BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • 1 1 1 I • • MPI -13SS DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 2 /7/20 11 TSS/TLS /I /0= 1800/1750/0/0 (Pre Acid Treatment Injectivity Test) Pump 5 bbls 60 /40 meth down SS Tbg @ 0.40 bpm 1950 psi injectivity. Pump 5 bbls 60/40 meth down B LS Tbg FWHP= 1800/1750/0/0. Operator notified. 9@ 0.65 bpm, 2000 psi injectivity. Y O P I Both LS and SS back on Injection. LS /SS Swabs closed. LS /SS Wings, Mst., IA, OA ' ✓ open. 2/9/2011 T/I = 1500/0. Acid treatment on both Long and Short String. Pumped 3bbls 60/40, 10bbls produced water, 20bbls 12% DAD acid, 3bbls 60/40, 12bbls produced water, 13bb 60/40 down each string. FWHP's = 1500/0. Swab, Wing, Lateral, SSV = shut. Master, IA = open. E � t I t FLUIDS PUMPED BBLS 20 12% DAD ACID 14 60/40 METH 22 PRODUCED WATER 56 TOTAL • Tree: McEvoy 2- 1/16 "5M Dual Siring Wellhead: UH -60, 11 x 2 -3/8 UPTBG MPU 1 -13i Orig. DF elev. = 64.12' ( Nabor 22 -E) top, 200-4 PKT TOP, CIW H BPVT 1 „ Orig. GL. elev.= 35.10'(Nabor 22 - x / 1 v1 Mrs 20" 91.1 ppf, H -40 I I diiii _ � O TAM port collar at 1416' KOP 0 405' Max. hole angle = 85 deg. '' l '• Note: Hole angle through perfs = 82 deg. short string wain IrrrtftWith an ythi ng larger. than 1.920 OD. A 1 drift wasuused on long string,also 2 -3/8" X Nipple 1.875" iD I 2353' I Q I 2 -3/8" X Nipple 1.875 ID I 2390' 7 ", 26# L -80, HYD521 production casing = (drift ID= 6.151 ", cap. = .0383 bbls/ ft) 2 -3/8 ", 4.7 #, L -80, EUE 8rd Tbg J 1� (Drift ID = 1.901", Cap= .00387 bpf ' 1. © 2 -3/8" X Nipple 1.875" iD 9680' 2 -3/8" X Nipple 1.875" ID I 9683' El 7" x 2 -3/8" Baker GT Dual Pkr. ( 9730' n _..1., r , i , - 7" x 2 -3/8" Baker GT Dual Pkr. 10,582' $ 2 -3/8" XN w/ 1.87" pkg. bore 10,602' 2 -3/8" X Nipple 1.875" ID I 10,615' I Model E -Hydro trip sub1.906" ID 10,613' r . ii," m 2 -3/8" WLEG 1.75" drift ID 10,626' Perforation Summary _ 55 Ref log: 1 7" x 2 -3/8" Baker FH Pkr. 11,052' Size SPF Interval (TVD) 2 -3/8" XN 1.87" pkg. bore 11,079' I N sand 2.5" 4 9800'-9820' 351T-3516' Model E -Hydro trip sub 1.906" ID 11,091' I i r ; OA sand 2 -3/8" WLEG 1.75" drift ID ( 11,103' I 4.5" 5 10,710' - 10,870' 3630' -3651' LS OB sand 4.5" 5 11,100' - 11,200' 3685' -3704' 7" float collar (PBTD) I 11313' • �.' 7" casing shoe I 11397' I DATE REV. BY COMMENTS MILNE POINT UNIT 08/19/01 M .Linder Initial completion Nabors 22 -E WELL 1 - 13i 7/14/10 REH Perf and run Dual String completion - N4ES API NO: 50 - 23012 - BP EXPLORATION (AK) SEAN PARNELL, GOVERNOR ALASKA OIL A" GAS 333 W. 7th AVENUE, SUITE 100 CONSERTATION COPOUSSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Keith Lopez Petroleum Engineer _ Bp Exploration (Alaska), Inc. ©� P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Milne Point Unit Field, Schrader Bluff Pool, MPI -13SS Sundry Number: 310 -403 Dear Mr. Lopez: u . r 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, Daniel T. Seamount, Jr. q � Chair DATED this / day of December, 2010. Encl. STATE OF ALASKA l.n ' �, ALASKOL AND GAS CONSERVATION COMMISSIO 1Z , G1 ,,4 � r! �� APPLICATION FOR SUNDRY APPROVALS ti ' 20 AAC 25.280 l 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate❑ Alter Casing ❑ Other: ACID 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 201 -0750 3. Address: P.O. Box 196612 Stratigraphic ❑ Service 0 6. API Number: 00 Anchorage, AK 99519 -6612 50- 029- 2301t" 00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: ❑ MPI -13SS ` Spacing Exception Required? Yes ❑ No ,-- 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 025517 / 025906 MILNE POINT UNIT Field / SCHRADER BLUFF Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11418 3745 11313 3726 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 81' 20" SURFACE 112 SURFACE 112 Surface Intermediate Production 11367' 7" 26# L -80 SURFACE 11397 SURFACE 3741 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 2 -3/8" 4.7# L -80 URFACI 10626 Packers and SSSV TVDe: 7" X 2 -3/8" BAKER GT DUAL PKR Packers and SSSV MD and TVD fft): 9730 3502 7" X 2 -3/8" BAKER GT DUAL PKR 10582 3612 7" X 2 -3/8" BAKER FH PKR 11052 3677 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12/21/2010 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Keith Lopez Printed Name Keith Lopez Title PE Signature Phone Date > 564 -5718 12/7/2010 Prepared by Gary Preble 564 -4944 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: R EC EI VED DEC 0 7 2010 Subsequent Form Required: / 0 — y 0 y Alaska Oil & Gas Cons COnv4ss1® Anchorage APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 2' , G RBDNIS 6 EC 10 SO 7 `4 �Z• � �- � ��_ Form 10-403 Revised 1/2010 ORIGINAL S ubmit in rcate odoox MPI -13 201 -075 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPI -13 8/27/01 PER 9,800. 9,820. 3,513.73 3,517.05 MPI -13 3/26/10 BPS 9,750. 9,800. 3,505.42 3,513.73 MPI -13 3/28/10 BPS 9,210. 9,800. 3,394.39 3,513.73 MPI -13 6/22/10 BPS 2,500. 9,800. 2,185.31 3,513.73 MPI -13 7/1/10 BPP 2,500. 9,800. 2,185.31 3,513.73 MPI -13 7/5/10 APF 10,710. 10,870. 3,630.72 3,651.08 MPI -13 7/5/10 APF 11,100. 11,200. 3,685.32 3,704.52 MPI -13 7/9/10 MIS 9,800. 9,820. 3,513.73 3,517.05 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL I SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE by 0 BP Exploration Alaska Milne Point To: Rob Handy/Mark O'Malley Date: December 6, 2010 MPU Well Operations Supervisor From: Keith Lopez IOR: 0 bopd Tract 14 PE AFE: AMSIPDWL13 COST: $15M Suhiect: MPI- 13SS/LS Acid Stimulation OBJECTIVES: Pump HCl acid stimulation in the SS and LS. PROPOSED STEPS: Category Step Description F 1 Pump 20 bbls 12% DAD acid in SS and LS WELL DATA Current Status: Dual string injector with 2 -3/8" tubing Max Deviation: 84.6 degrees at 3686' MD Min ID: SS — 1.87" XN nipple @ ~io,602' LS — 1.87" XN nipple @ 11,079' Last TD tag: Last downhole ops: Swab well for GeoChem samples Latest H2S level: N/A — SBL have minimal H2S <io ppm Latest SBHP: Tb cs size: Dual String 2- 8 # L -8o tubing g/ g g 3/ " 4 7 g 7 " 26# prod csg BACKGROUND MPI -13 was drilled and cased as an injector to support the MPI -11 and MPI -12 producers in 2001. This well was never completed due to unreliable production from the two producers but perforations were shot in the N sand (20'X 4 SPF) to get a pressure reading. These perforations will be isolated with a packer in the completion with plans to only inject into the deeper OA and OB zones. A CBL was run on 8/26/01 with coil but could not get lower then 10,814' due to suspected helical buckling. A second CBL was run on 10/18/09 from 11,222' to 8,000' ctmd. This log verified that there was sufficient cement for zonal isolation. r In July 2010, the well was completed as a dual string injector with 2 -3/8" tubing. The well has shown very poor injectivity despite having a very large perforated section. This stimulation attempt is needed to inject minimum rates to avoid freezing under fracture initiation pressure. DETAILED PROCEDURE: FB — MPI -13SS 1. MIRU LRS. 2. Spear in with 3 bbls MEOH. 3. Inject 10 bbls of produced water to ensure the well will take 0.5 bpm without exceeding 2,000 psig. 4. Inject 20 bbls of 12% DAD acid at 0.5 bpm with maximum injection pressure of 2,000 psig. 5. Swap to produced water and displace acid with an additional 15 bbls at 0.5 bpm with maximum injection pressure of 2,000 psig (the intent is to displace the acid near the perfs 5 ( 0 at frac pressures and then put the well on normal injection to put the acid away at matrix rates and pressures) 6. Put well on injection at current targets of 300 bwpd without exceeding 1750 psig (this will be done after the LS pump job is completed) FB — MPI -13LS 7. RU to LS. 8. Spear in with 3 bbls MEOH. 9. Inject 10 bbls of produced water to ensure the well will take 0.5 bpm without exceeding 2,000 psig. 10. Inject 20 bbls of 12% DAD acid at 0.5 bpm with maximum injection pressure of 2,000 psig. 11. Swap to produced water and displace acid with an additional 15 bbls at 0.5 bpm with maximum injection pressure of 2,000 psig (the intent is to displace the acid near the perfs at frac pressures and then put it on normal injection to put the acid away at matrix injection) 12. Put well on injection at current targets of 300 bwpd without exceeding 1750 psig. POINTS OF CONTACT: Production Engineer: Keith Lopez Office: 564 -5718 Cell: 903 -5432 ree - McEvoy 2-1116'5M Dual String MPU I -13i Orig. DF elev. = 64-12'(Nabor 22-E) Wellhead: UH-60, 11 x 2-3/8 UPTBG top, 200-4 PKT TOP, CfW H BPVT Drig. GL. elev.= 35 22-E) 20 91 . 1 ppf, H-40 TAM port collar at 141• KOP % 406' Nfax, hole angle - W deg Note: Hole angle through pct-fa - G2 dog. Short siring would not drift w anything larger than 1.920 OD. A 11.920 drift was used on long string also. 2 -118' X Nippe 1.275' iD 2-3V X Nipple 1,875 ID 7', 269 L-80, HYD521 production casing (drift 1D= 6.151% cap. = -0383 bbis/ ft) 2-318 4.7#, L-80, EUE 8rd Tbg (Drift ID = 1.901 Cap= .00387 bpf 2 -3'P' X NTple 1.875' D 2-2 N cola 7' x 2-318* Baker GT Du3I F kr x 2-3W Baker GT Dual Pkr, 2-34 XN wif 117* pkg. bore Nipple 1.575' IL) Model E-Hydro UV sub 1.906' la 6A 2-3i'8' WILEG 1,75drgl 11) Perforation Summary Ref Ion X Bak er FH Pkr. 23. 1.87* pkg. bore - GPF Interval (71"D 'l - F 11 079 ?d aaxl Model E44ydro trip sub 1.906" 0 11.691 5 9800'-98 35113'45116' 2—W WILEG 1-75' dr ID QA sand 10.7 -10,870 3830' -3851 013 nand 11266' 3686-3704 7" floss collar (PSTD) 7" caving shoe F -113971 CA REV BY COMMEN7Z MILNE POINT UNIT I—: 1 1� j V Linder Initial completion Nabors 22 WELL I -13i 7 14 P= Flerf and run Dal Siting comcfetor - WES API NO: SM29-23012-00 BP EXPLORATION (AK) v ` ALASKA SEAN PARNELL, GOVERNOR ALASKA OIL A" GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COM USSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Keith Lopez Petroleum Engineer Bp Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Milne Point Unit Field, Schrader Bluff Pool, MPI -13LS Sundry Number: 310 -402 Dear Mr. Lopez:) 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, 07 Daniel T. Seamount, Jr. Chair DATED this I day of December, 2010. Encl. STATE OF ALASKA IG t- ALASK* AND GAS CONSERVATION COMMISSI� APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate❑ Alter Casing ❑ Other: ACID 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 201 -0750 3. Address: P.O. Box 196612 Stratigraphic ❑ Service Q 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 23012- -06 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: MPI -13LS Spacing Exception Required? Yes ❑ No ❑ 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 025517 / 025906 MILNE POINT UNIT Field / SCHRADER BLUFF Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11418 3745 11313 3726 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 81' 20" SURFACE 112 SURFACE 112 Surface Intermediate Production 11367' 7" 26# L -80 SURFACE 11397 SURFACE 3741 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 2 -3/8" 4.7# L -80 URFACI 11103 Packers and SSSV Tvpe: 7" X 2 -3/8" BAKER GT DUAL PKR Packers and SSSV MD and TVD (ft): 9730 3502 7"X 2 -3/8" BAKER GT DUAL PKR 10582 3612 7" X 2 -3/8" BAKER FH PKR 11052 3677 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service ❑� 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12/21/2010 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WIND Q GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Keith Lopez Printed Name Keith Lopez Title PE Signature � � Phone Date 564 -5718 12/7/2010 Prepared by Gary Preble 564 -4944 l' COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 1 O' `1 (/ c Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RECEIVED DEC 0 7 2010 Subsequent Form Required: �^ � I Alaska Oil & Gas Cons CORY NS$i ®n Anchorage APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: L 2 ums DEC x 0 "A �z- g ORIGIN Form 10 -403 Revised 1/2010 ��uplicate MPI -13 201 -075 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPI -13 8/27/01 PER 9,800. 9,820. 3,513.73 3,517.05 MPI -13 3/26/10 BPS 9,750. 9,800. 3,505.42 3,513.73 MPI -13 3/28/10 BPS 9,210. 9,800. 3,394.39 3,513.73 MPI -13 6/22/10 BPS 2,500. 9,800. 2,185.31 3,513.73 MPI -13 7/1/10 BPP 2,500. 9,800. 2,185.31 3,513.73 MPI -13 7/5/10 APF 10,710. 10,870. 3,630.72 3,651.08 MPI -13 7/5/10 APF 11,100. 11,200. 3,685.32 3,704.52 MPI -13 7/9/10 MIS 9,800. 9,820. 3,513.73 3,517.05 AB ABANDONED PER PERF APF ADD PERF RPF REPERF • BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL I SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • by 0 BP Exploration Alaska Milne Point To: Rob Handy/Mark O'Malley Date: December 6, 2010 MPU Well Operations Supervisor From: Keith Lopez IOR: 0 bopd Tract 14 PE AFE: AMSIPDWL13 COST: $15M Subject: MPI- 13SS/LS Acid Stimulation OBJECTIVES: Pump HCl acid stimulation in the SS and LS. PROPOSED STEPS: Category Step Description F 1 Pump 20 bbls 12% DAD acid in SS and LS WELL DATA Current Status: Dual string injector with 2 -3/8" tubing Max Deviation: 84.6 degrees at 3686' MD Min ID: SS — 1.8 XN nipple —io 602 7 @ , PP LS — 1.87" XN nipple @ — 11 , 0 79' Last TD tag: Last downhole ops: Swab well for GeoChem samples Latest H level: N/A — SBL have minimal H2S «0 ppm Latest SBHP: Tbg /csg size: Dual String 2 -3/8" 4.7# L -8o tubing 7" 26# prod csg BACKGROUND MPI -13 was drilled and cased as an injector to support the MPI -11 and MPI -12 producers in 2001. This well was never completed due to unreliable production from the two producers but perforations were shot in the N sand (20'X 4 SPF) to get a pressure reading. These perforations will be isolated with a packer in the completion with plans to only inject into the deeper OA and OB zones. A CBL was run on 8/26/01 with coil but could not get lower then 10,814' due to suspected helical buckling. A second CBL was run on 10/18/09 from 11,222' to 8,000' ctmd. This log verified that there was sufficient cement for zonal isolation. 1 In July 2010, the well was completed as a dual string injector with 2 -3/8" tubing. The well has shown very poor injectivity despite having a very large perforated section. This stimulation attempt is needed to inject minimum rates to avoid freezing under fracture initiation pressure. DETAILED PROCEDURE: FB — MPI -13SS 1. MIRU LRS. 2. Spear in with 3 bbls MEOH. 3. Inject 10 bbls of produced water to ensure the well will take 0.5 bpm without exceeding 2,000 psig. 4. Inject 20 bbls of 12% DAD acid at 0.5 bpm with maximum injection pressure of 2,000 psig. 5. Swap to produced water and displace acid with an additional 15 bbls at 0.5 bpm with maximum injection pressure of 2,000 psig (the intent is to displace the acid near the perfs at frac pressures and then put the well on normal injection to put the acid away at matrix rates and pressures) 6. Put well on injection at current targets of 300 bwpd without exceeding 1750 psig (this will be done after the LS pump job is completed) FB — MPI -13LS 7. RU to LS. 8. Spear in with 3 bbls MEOH. 9. Inject 10 bbls of produced water to ensure the well will take 0.5 bpm without exceeding 2,000 psig. 10. Inject 20 bbls of 12% DAD acid at 0.5 bpm with maximum injection pressure of 2,000 psig. 11. Swap to produced water and displace acid with an additional 15 bbls at 0.5 bpm with maximum injection pressure of 2,000 psig (the intent is to displace the acid near the perfs at frac pressures and then put it on normal injection to put the acid away at matrix injection) 12. Put well on injection at current targets of 300 bwpd without exceeding 1750 psig. POINTS OF CONTACT: Production Engineer: Keith Lopez Office: 564 -5718 Cell: 903 -5432 Tree: McEvoy 2-1/165M Dual String Wellhead: UH-60, 11 x 2-a UPTBG MPU I -13i trig. DIF elev. = 64.12'(Nabor 22-Ei lop, 2DO-4 PKT TOP, CFW H BP Qrig. GL. elev.= 35 22-E; 20 91.1 ppf, H-20 TAM port collar at 14165 KOP A? 406' Max, holy anglo - e6 dog. Note- Holo anglo through per - 3Z clog. Short strft would not drift wAh anything larger tm 1.920 00 A 1.920 drift was used on long string also. 2-18' X Nipple 1 AW iD 2-31!6 X Nipp 7', 26# L-80, HYD521 production casing (drift ID= 6.151', cap. = -0383 bblsl M 2-318 4.7#, L-80, EUE 8rd Tbg (Drift ID = 1.901', Cap= .00387 bpf 2 -318 X Nipple 1 2319' X Npple 1.875' ID 9 88 -s x 2-18' Baker GT Dual Pkr T x 2-318' Baker GT Dual Pkr. 2-N6' XN wl 1 -Sr pkg. bore 2-3'E'X Nipple 1.� 75' 10 1 D,815 tilodell E-Hydro trip su61.906' ID o-A 2-'-VS'WLEG 1.75' drift ID Perforation Summary R-?f I':';1 7'x 23W Baker FH Pkr. F - 110 - 62 - � S z� SPF Interval (TVD) XN 2-3W XN 1.87' pkg- bore 7 - 679' N aav Vodel E-Hydro trip sub I.9M ID F 1 1 - .5 9800 -9820' 3513'-3516' OA sand 2319'WLEG 1.75' drift ID 10,7 -10,670 3630' -'s681 OB sand 4,1 5 1 t, I 0C - 11 2DO' 368f'-3704 7' float Dollar (PSTD) A L 7" casing shoe CA - E REV BY COMMENM MILNE POINT UNIT V -,: er Initial completion Nabors -'-E WELL I -13i 7 - 4 F = F Pl e4 and run Dual String complelon - NXIES API NO: 50-029-23012-00 I BP EXPLORATION (AK) • ~S~Q~~ 0~ Q~Q~~{Q /,~....,E«w~.~. David Reem BP Exploragion (Al ska)e Inc. ~~'~~~'~"'~~"'' ~~ ~ ~a ~~ ~ ~ ~~~~ P.O. Box 196612 Anchorage, AK 99519-6612 ~©~ - ~ ~/~ Re: Milne Point Field, Schrader Bluff Pool, MPI-13 Sundry Number: 310-132 Dear Mr. Reem: 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 Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. q ~ Chair DATED this ~ % day of April, 2010. Encl. STATE OF ALASKA ' p `~'~~ ALASK~ AND GAS CONSERVATION COMMIS~J ~,~q', ~ APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ~ECEI~E® APR 1~ 6 2010 1. Type of Request: '~ aS ^ Abandon ^ Plug for Redrill ^ Perforate New Pool ^ Repair Well ^ Change Approved PrografiY ^ Suspend ^ Plug Perforations ®Perforate ^ Pull Tubing ^ Time Extension ^ Operations Shutdown ®Re-Enter Suspended Well ^ Stimulate ^ Aker Casing ®Other Complete Well 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 201-075 3. Address: ®Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23012-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Welt Name and Number: property line where ownership or landownership changes: '~^ » MT ~ M~1~4.~ • ..L' ~~ Spacing Exception Required? ^ YeS ®No ~ ~ /~ 9. Property Designation: • 10. Field /Pool(s): ADL 025906 & 025517 Milne Point Unit / Schrader Bluff 11 • ' -PRESENT t4VELL`CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11418' 3745' 11313' 3726' ' None None Casin Len Size MD ND Burst Coda Structural Conductor 1 4 Surface Intermediate Production 7" 7 4 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9800' - 9820' 3514' - 3517' None Installed N/A N/A Packers and SSSV Type: None Packers and SSSV None MD (ft) and TVD (ftj: 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Detailed Operations Program ' ^ Exploratory ^ Development ®Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: May 15, 2010 ^ Oil ^ Gas ^ WDSPL ^ GSTOR ^ Abandoned 16. Verbal Approval: Date: ®WINJ , ^ GINJ ^ WAG ^ Plugged ^ SPLUG Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mehrdad Nadem 564-5941 Printed Name vid Re Title Engineering Team Leader i Prepared By Name/Number. Si nature Phone 564-5743 Date ~ ., ,, Terris Hubble, 564-4628 g~~. ~T.'/~~~~~i~ Commission Use Oni Conditions of approval: N tify Commission so that a representative may witness ~~ Sundry Number: t ^ Plu Int BOP Test g egrity Mechanical Integrity Test ^ location Clearance -* 3 Soo ~os~ g p~ 5 (-- Other. ~~ ,. ~/r=~'n.tsse..~/ N~ (T - ~ a. ~'~e.~ j•~t. d; ~; z ~.0 ; nJ cc~fii'c+~ . /~ rte ~ ~0 C ~ ~ ` . w - ~,cl fi ti., Qp er•, tre~ r ~ ~tcGo r~, i Subsequent Form Required: ~Q • ~~ APPROVED BY q~ ~ 1 Approved By: COMMISSIONER THE COMMISSION Date Form 10-403 1 Submit In Duplicate PR 2 0 Z0~ ~ ~/ ~ ~ • !o Ts ^ • by G MPI-13 Rig Workover Scope of Work: Pull 7" RBP from 9,750'. Make a cleanout run on DP. Rig up and run 2-3/8" dual string . completion. This completion allows zonal injection isolation in ~ OA and OB sands. . SC1'U' w d2 a r ~,~. ~~ ~ ~. t o The attached area of review discusses the wells within'/a mile of well's entry point into the Schrader bluff formation to the bottom of well bore completion. Engineer: Mehrdad Nadem MASP: 1366 psi Well Type: Producer -will be converted to an injector Estimated Start Date: May 15, 2010 Pre-Rig Work Reauest: E 1 RIH and seta 7" RBP and test 2,500 si at 9,750' MD. Done C 2 Freeze rotect the well bore to 4,250'. Done W 3 Set a BPV in the tubin han er. Proaosed Procedure 1. MIRU. ND tree. NU and test BOPE (consisting of annular, 2-7/8" x 5" VBRs, and blind rams) to 250 4 psi low and 3,500 psi high. Test annular to 3,500 psi. 2. PU false bowl landing joint. RIH and pull the false bowl to surface though the BOP stack. 3. PU 7" retrieval tool on DP. RIH to 9,000' and test the RBP to 1,000 psi for 10 minutes. 4. PU storm packer and set one joint below surface. Test the storm packer to 1,000 psi for 10 minutes. . 5. ND BOP. ~,( s~-ap ~r pp~ni 6. Install dual tubing spool with isolating sleeve. 7. NU BOP and test breaks to 250 psi low and 3,500 psi high' 8. RIH and engage storm packer. POOH and LD storm packer. • ~~ ~ 08 9. Continue to RIH and latch onto the RBP. POOH and LD RBP. 10. PU perf guns on drillpipe and perforate the well at the following intervals: 10,710'-10,870', 11,100'- 11,200'. POOH LD perf guns 11. PU and RIH with cleanout assembly to PBTD. POOH LD cleanout BHA. 12. Set test plug. Install 2-3/8" dual rams and test to 250 psi low and 3,500 psi high. - 13. RU Dual elevators, Dual Air Slips, and Tong Equipment. 14. RU to run single 2-3/8" long string tail pipe section below dual GT packer. 15. Pick up GT packer and short string tail pipe section and make up to the long string.. 16. RIH with completion balancing string weights every 1,000'. 17. Space out each completion string as required. 18. Land the hanger halves in the bowl. Run in all lock down screws. 19. Rig up to 7" x 2-3/8" annulus. Test all surface lines to 5,000-psi. Mix and pump clean seawater with corrosion inhibitor followed with diesel, circulate at 3-bbl/min max, taking returns up both strings. 20. Drop 1-3/4" ball down Long String. When ball is seated, shut down and let annulus pressure bleed off into formation to less than 500-psi. • 21. Pressure down Long String to 1,900-psi differential pressure to start the setting sequence on the "GT" Dual Packer. Increase pressure to 2,200-psi to trip "FH" single string_packer. Increase pressure to 2,500-psi and hold for 5-min to completely set "GT" Dual Packer. 22. Continue to pressure up Long String to 3,000-psi for 30-min to test Long String. Monitor annulus and long String and record test on chart. 23. Pressure annulus to 2,000-psi for 30-min to test "GT" packer while watching for returns on the short string. Record test on a chart. 24. Close annulus. With rig pump and seawater, pressure down Short String to 1,500-psi to test "FH" . isolation packer while watching for returns on the Long String and the annulus. 25. Drop 1-3/4" ball down short String. When ball is seated, shut down and let annulus pressure bleed off into formation to less than 500-psi. 26. Continue to pressure up short String to 3,000-psi for 30-min to test short String. Monitor annulus and Short String and record test on chart. 27. Lay down the landing joint. Install TWCs and test to 3,500 psi from above. TWC can not be tested from below. 28. ND BOPE. 29. N/U 2-1/6" dual 5 M tree and test tree and hanger to 5,000 psi. . 30. Pull TWC. 31. Increase pressure down Long String to 3,950-psi to shear Model "E" Hydro-Trip. Freeze protect short string. Bleed pressure off Long String. ~:k~ 5~ •~ 3"~"• 32. Increase pressure down short String to 3,950-psi to shear Model "E" Hydro-Trip. Freeze protect long string. Bleed pressure off short String. 33. Install BPV in both strings and test. 34. Secure well. RDMO. ~" Frac tree - 5M M P U I - ~„ f~: 7" 5M FMC GEN 6 Monobore w/ False Bowl 20" 91.1 ppf, H-40 KOP @ 405' Max. hole angle = 85 deg. Hole angle through perfs = 82 deg. 7", 26# L-80, HYD521 production casing (drift ID= 6.151", cap. _ .0383 bbls/ ft) TAM port collar at 1416` 9,750` - HES 7" RPB Perforation Summary Ref loa: Size SPF Interval (TVD) 2.5" 4 N sand 9800`-9820' 3513`-3516' OA sand OB sand 2010 RWO Orig. DF elev. = 64.12' (Na~22-E) -~ Orig. GL. elev.= 35.10' (Nabor 22-E) `~ ~' 1 DATE REV. BY COMMENTS 08/19/01 M.Linder Initial completion Nabors 22-E 7" float collar (PBTD) 11313' 7" casing shoe 11397' MILNE POINT UNIT WELL I -13i API NO: 50-029-23012-00 BP EXPLORATION i;lw 2-3/s° 5M Dual string IVIPU I - i~s 11" x 2 3/9" SM FMC dual string Hanger thread 2 3/9" IBT top and bottom 2"CIW-H BPV profile 20" 91.1 ppf, H-40 ~ KOP @ 405' Max. hole angle = 85 deg. Hole angle through perfs = 82 deg. 7", 26# L-80, HYD521 production c (drift ID= 6.151", cap. _ .0383 bbls Perforation Summary Ref loss: Size SPF Interval (T` N sand 2.5" 4 9800`-9820' 3513`-3 OA sand F... 10,710'-1 M( OB sand 11,100` - M 2010 RWO Orig. DF elev. = 64.12' (Nab~22-E) Orig. GL. elev.= 35.10' (Nabor 22-E) DATE REV. BY COMMENTS 08/19/01 M.Linder Initial comoletion Nabors 22-E JI port collar at 1416` 93' - 2-3/8" X Nipple - ID =1.875" 96` - 2-3/8" X Nipple - ID =1.875" 756` - 2-3/8" X Nipple - ID =1.875" 759` - 2-3/8" X Nipple - ID =1.875" 769' - 7" x 2-3/8" Baker GT Dual Packer, ID=1.945" 1,613' - 7" x 2-3/8" Baker GT Dual Packer, ID=1.945" 0,631' - 2-3/8, L-80, EUE, 8RD, 4.7# 0,633' -Baker Hydro Trip with WLEG A 11,060` - 7" x 2-3/8" Baker FH Packer 11,068' - 2-3/8" XN Nipple ID=1.795" 11,078` - 2-3/8, L-80, EUE, 8RD, 4.7# 11,080` -Baker Hydro Trip with WLEG ~~ 7" float collar (PBTD) 11313` 7" casing shoe 11397` MILNE POINT UNIT WELL 1 -13i API NO: 50-029-23012-00 7" Frac tree - 5M ~ ~ ~a~i: 7" 5M FMC Gen. 6 MPU I -13i Orig. DF elev. = 64.12' (Nabor 22-E) monobore w/ false bowl I I Orig. GL. elev.= 35.10'(Nabor 22-E) 20" 91.1 ppf, H-40 KOP @ 405' Max. hole angle = 85 deg. Hole angle through perfs = 82 deg. 7", 26# L-80, HYD521 production casing (drift ID= 6.151", cap. _ .0383 bbls/ ft) Perforation Summary Ref loo: Size SPF Interval (TVD) 2.5" 4 N sand 9800'-9820' 3513`-3516' OA sand OB sand t TAM port collar at 1416` 7" float collar (PBTD) 11313` 7" casing shoe 11397' DATE REV. BY COMMENTS 08/19/01 M.Linder Initial completion Nabors 22-E MILNE POINT UNIT WELL I -13i API NO: 50-029-23012-00 C~ Area of Review -Milne Point I-1:; (2010'Z,rj) Prior to the completion of well MPI-13 to a water injector an Area of Review (AOR) is required. This AOR discuss the wells within 1/4 mile of the well's entry point into the Schrader Bluff Formation to the bottom of well bore completion. Two other wellbores enter the Schrader Bluff formation in the AOR. The following table illustrates the well within the AOR, its distance from MPI-13, completions detail, and any annulus integrity comments based on an in-depth review of each well. Well Name PTD Distance Ft Annulus Inte ri MPI-i 2oio75 TOC calculated to be above in'ection zone at ,u2' MD MPI-ii 2oii i,o i' TOC calculated to be above in'ection zone at 4, ' MD MPI-12 2oii6 i, o' TOC calculated to be above in'eetion zone at 5,2 i' MD Figure ~: Wells within AOR Well Name Casing Size Hole Size Vol Cement Schrader Bluff De th MPI-i 8" 2 6 bbls ' MD MPI-ii 8" 28 bbls MD MPI-12 7" 8" 24o bbls 9,10 ' MD Figure 2: Completion Detail Well MPI-11 (PTD 2oii37) _was completed in October 2001. The completion crossed the Schrader Bluff formation at 9,747' MD. A ~" casing string was run to io,747' MD and cemented with 287 bbls of class G cement. Two laterals were drilled out of this wellbore into the Schrader Bluff sands. The OA lateral window is at 10,345'-10,357' MD and the OB lateral is drilled out of the mother-bore. Well MPI-12 (PTD 201163) was completed in November 2001. The completion crossed the Schrader Bluff formation at 9,io9' MD. A 7" casing string was run to 10,347' MD and cemented with 24o bbls of class G cement. Two laterals were drilled out of this wellbore into the Schrader Bluff sands. The OA lateral window is at 9,916'-9,928' and the OB lateral is drilled out of the mother-bore. Top Schrader Bluff Formafion Structure Map illustrafing the AOR - - ~~~ 1 MPI-1211 _~ .._ ' MPI-12 _--.: _.„~..-___ ~ __ ._- _. . D MPI-'1~; ,~ _ _ . ~ P41 F ~~~ ~,1 Sp _.. MPI-11 -~__',._" _ MPI-0~ MPI-11 L1 i 1000 0 '1000 2000 R Top Schrader Bluff Formation Struchre grid (feet) -5024 -4550 -d0~ -3610 -3125 k- Top Schrader Bluff Formation Intercept with well Quarter mile distance around M PI-13 /at top of Sctrader BIuB Formation \~~ • • Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, November 10, 2009 3:01 PM To: 'Lopez, Keith' Subject: RE: MPI-13i (PTD 201-075) Keith, I don't see any issues with the proposed completion in regards to UIC regulations. The liner packer is 50' feet from the N sand. Although you are squeezing this zone off and pe~ng only the OA and OB sand, the distance from the packer to the OA sand will be 960' md. We can grant a variance from the 200' limit in this case. You would be straddling the N zone anyway with two packers so the top packer depth would essentially be the same depth and thus the monitor-able annulus would still be the same whether you run a liner or set straddle packers. Are you still planning on running the CBL to determine cement quality behind the 7" casmg between the __--__....._ _.M. Schrader sands before running the 4.5" liner.? G' ~z ~ ~ ~~:Q, .~... C~'~ z~~ . Regards, ~ ll~~.v ~ Guy Schwartz ,~',~ /~~s~'~ ~ ~ ~` ! ~= ~,l~v~ Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) _ _ _ _ _ _ _ _ __ From: Lopez, Keith [mailto:lopek3@BP.com] Sent: Tuesday, November 10, 2009 1:21 PM To: Schwariz, Guy L (QOA) Cc: Maunder, Thomas E (DOA) Subject: RE: MPI-13i (PTD 201-075) Hi Guy, We are updating our completion strategy for the MPI-13 injector. We would like to run a 4-1/2" liner with liner top packer and cement it across fhe Schrader Bluff pooi (this is to isoiate the N sand perforations we do not want to inject into). We would then run a 4-1/2" tubing string with seals and stab into the polished bore run with the liner. We woufd da this to A) keep a 4-1/2" monobore for future interventions and B) placing a second packer on the tubing string could make the spacing difficult to get both packers between the top of the Schrader Bluff pool and the 100' above requirement. Would this be an acceptable completion far annulus isolation for the injector from the AOGCC standpoint? Attached is a proposed schematic (sorry for the crude drawing). Keith Lopez Wells & Subsurface Enqineer Milne Point - Alaska BP Exp/oration A/aska, Inc. Office (907)-564-5728 Cell (907)-903-5432 11/10/2009 • • Page 2 of 2 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday, October 05, 2009 10:44 AM To: Lopez, Keith Cc: Maunder, Thomas E (DOA) Subject: MPI-13i (PTD 201-075) Keith, As per our phone conversation regarding the sundry request for MPI-31 i. A sundry to convert MPI-13i to water injection is not needed. The well has always been permitted as a service wetl. I am returning the permit request as not needed. Please re-submit the AOR summary when you apply for the sundry10-403 requesting the rig completion. You could also add the new cement bond log data to the AOR to make it more complete. Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 11/10/2009 ~V ~ ~ 7" Frac tree - 5M >ad: 7" 5M FMC Gen. 6 monobore wl false bowi 20" 93.1 ppf, H-40 ~ KOP @ 405' Max. hole angle = 85 deg_ Nole angle through per~s = 82 deg. 7", 26# L-8Q, HYD521 production c (drift ID= 6.151", cap. _ .03$3 bbis, ~ ~t~ ~ ~'~°f Perforation Summarv Re_..,_,.. f log,: Size SPF Interval (Ti~ N sand 2.5" 4 9800'-9820' 3513'-3: OA sand tCr,7 ~o - io~7~o lotY3e " t E OB sand It, tbe- f t+~bo DA7E REV. BY COMMEfVTS 08l18r'01 1N.Li~der Inifiai completion Nabors 22-E brig. DF elev. = 64.12' (Nabar 22-E) Orig. GL_ etev.- 35.1~'(~abor22-E) U part coIlar at 1416' , p o~' Sv4~~ter 81~{~ ~~j jKR ~ Q75~~ seal A~ss~~•ety ;~s~e Pet~t~ SS ~,( ~a ~~ ~t»~r Ce~6«~ 7" ftoat collar (PBTD) 11313' 7" casing shoe 11397' MILNE POENT Uf~EtT W~LL E -13; Ai~E IUG: 50-029-23012-00 ~ ~73y MPU I -13i MItSKd un a uas {.ions liomm Anchorage, AK 99503 -2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job Log Description Date 81 Color CD MPI -13 AWJI -00055 SCMT nuoranawavinwm 10/18/09 1 1 MPC -07 AXBD -00057 MEM PROD PROFILE i 10/24/09 1 1 04 -11A AWL8 -00040 INJECTION PROFILE O —L 10/24/09 1 1 V -220 AYS4 -00100 INJECTION PROFILE ()T (t_ b SS 10/04/09 1 1 L 220 B1JJ -00035 MEM INJ PROFILE (REVISED) T.. /t 07/30/09 1 1 V -221 AXBD -00037 MEM INJ PROFILE (REVISED) ().0_.. a(� -bi3 /09 .,G 07/28/09 1 1 L -214A AP3Q -00064 INJ PROFILE/RST (j-r(t 06 (N a- 9, Q 10/06/09 1 1 S -22B AYTU -00052 INJECTION PROFILE "3-- `d9" i 10/27/09 1 1 14 -07 8581 -00016 PROD PROFILE -d) i 10/27/09 1 1 07 -05 AYS4 -00105 SCMT -Q 1 4)/ 10/28/09 1 1 R -28 AWL8 -00041 USIT fy p_l�S �f 10/26/09 1 1 2- 08/K -16 AZCM -00046 PRODUCTION PROFILE /'?f 0/ /A 10/30/09 1 1 PSI -05 B14B -00080 TEMP WARMBACK SURVEY ()TA, 3 -!Ac) /1390 A 11/03/09 1 1 C -12B B2WY -00030 MCNL i-) Qg 151_4 a 09/19/09 1 1 U -05A 09AKA0074 OH MWD /LWD EDIT UT(' c g O (b )d 4- 08/19/09 2 1 01 -18A 09AKA0151 OH MWD/LWD EDIT 1 4_ c StiO 08/27/09 4 1 H -09 ANHY -00110 RSTuuj t PM 4/ 09/20/09 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 4 t{ 1 r.a✓• L I, • • ~ }~ ~~ - ~f~ R -~ ~ ~. R~ ~ -~ ~ ~~; k- ~~ ~ ~~~r~ ~~ ~ ~~~ ~~ ~~~ ~~ ~~~ ~~~ ~~ ~~~ r ~ ~ ~ z f € ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~' ~~ ~ ~ ~ ~ ~, ~ ' ' ~'~ ~ ~ x p SEAN PARNELL, GOVERNOR ~~ ~ ~ `_,~ `~ 3: ~ ~ ~' ~ ~~ ~ ~~_x ~.~"~~ ~ ~ ~ ~ ~~ ~~~~ ~~ ~ ~.n~~~~ ~ tZaat~S~ ~IL ~~ tllni.7 a'~ 333 W. 7th AVENUE, SUITE 100 COI~SERQATIOl~T COMDIISSIOl~ ~ ANCHORAGE, ALASKA 99501-3539 ,, _ .._._~~ •. PHONE (907) 279-1433 p FAX (907) 276-7542 Mr. Keith Lopez BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 ~'~~~~{~~~ ~'(f; ,? ~'; ~a ~~~'~ Re: Milne Point Unit, Schrader Bluff Oil Pool, Well MPI-13 Sundry Number: 309-345 Dear Mr. Lopez: The Commission is returning the enclosed Application for Sundry Approval relating to the above-referenced well. The reason for returning this sundry is that well MPI-13 is already permitted for water in;ection. MPI-13 was drilled and classified as a Service well as per the original PTD~201-075 The current suspended well status does not change the service type. Thus a 10-403 Sundry is not required to allow water injection. DATED this ~ day of October, 2009 Encl. ~ ~.o°l ~~, STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMM~N APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ~~~~~~~ L~' ''~~~ ia~a-~ OCT ~ ~ 2~Q9% ; 1. Type of Request: ^ ^ Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Re-Enter Suspen~~~~~~ ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ~ Other ~ Specify: ; ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Time Extension Convert to Water Inje ion - 2. Operator Name: 4. Current Well Class: 5. Permit T~f Drill Number BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 201-0~J5 ~ 3. Address: ~ Service- ^ Stratigraphic 6. AP~FNumber: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23012-00-00 ~ 7, !f perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and I~imber: property line where ownership or landownership changes: ; % MPt-13 ' Spacing Exception Required? ^ Yes ~ No 9. Property Designation: ~s'~O( ~aSS/ 10. Field / Pool(s): _ ADL 2~894~6 &~3694Z-~ Milne Point Unit / Schrader Bluff ~~•' PRESENT WELL CONDITION SUMMARY ~ Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effectiv Depth TVR~'`jft): Plugs (measured): Junk (measured): 11418' ~ 3745' - 11313' ~ 726' -, ~ None None Casin Len th Size MD D Burst Colla e Structural Conductor ~' 2" 4 47 Surface Intermediate Production 1 7' 11 74 ' 7 4 ~iner Perforation Depth MD (ft): Perforation Depth ND (: ubing Size: Tubing Grade: Tubing MD (ft): 9800' - 9820' 3514' - 3517' ~' None Installed N/A N/A Packers and SSSV Type: None '~ Packers and SSSV None ~ % MD (ft) and TVD (ft): ~ 12. Attachments: 13. Well Class after proposed work: ~ Description Summary of Proposal ^ B~ P Sketch ^ Detailed Operations Program ' ^ Exploratory ^ Development ~ Service 14. Estimated Date for ' 15. Well Status after proposed work: Commencing Operations: As Soon Approved ^ Oil ^ Gas ^ WDSPL ^ GSTOR ^ Abandoned 16. Verbal Approval: D te: ,~ WINJ ^ GINJ ^ WAG ^ Plugged ^ SPLUG Commission Representative: 17. I hereby certify that the foregoing is true ~rSd correct to the best of my knowledge. Contact Printed Name Keith Lopez ~~ Titie Milne Point Petroleum Engineer / (~ ~( ' 7 ~ Prepared By Name/Number Terrie Hubble 564-4628 Si ~ ~ , gnature Phone 564-~ Date ~~j~~~p~ Commission Use Onl Conditions of approval: Notify Co mission so that a representative may witness 2/~ ~?!~~ ~ i Sundry Number: ,/v / ^ Plug Integrity ^ BOP T~st ^ Mechanical Integrity Test ^ Location Clearance / Other: / Subsequent Form equired: APPROVED BY Approved By: COMMlSSlONER THE COM !SSlON Date Form 10-40 Revised 07/2000 ~ fi ~~ y ~~~ '7 ~~ ~~"~ Submit In Duplicate ~R~GINAL ` ..`~p~~' ~ • • Milne Point I-13 (PTD 2oio7~) Current Status The MPI-i3 is a suspended well originally drilled and permitted as an injector in 2001. This well was never completed due to inconsistent production from the offset producers. Perforations were shot in the Schrader Bluff N sands on 8/2~/0l but no injection ever took place. A cement bond log was run to ~0,814' and showed the well to have the required 50' of cement over the Schrader Bluff pool. The well currently has no tubing. The MPI-li (an offset producer) was recompleted as a jet pump producer on 2/2i/o9 and has since proven to produce reliably with this lift mechanism. The plan forward is to complete the MPI-13 as an injector to support the MPI-11 production in the OA and OB sands of the Schrader Bluff formation. An additional cement bond log will be run to evaluate the cement between the sands of the Schrader Bluff pool and provide information for the completion design. Additional perforations will be shot in the OA and OB sands and a MIT-IA to 2,50o psi will be conducted. Completion The Milne Point I-13 crossed the Schrader Bluff formation at 9~734' MD. The ~" casing was run from surface to TD at 11,397' MD. It was cemented with 2g6 bbls of ~5.8 ppg class "G" cement with no recorded losses. A Bond Log run on 8/26/oi shows a minimum of 5o ft of isolating cement behind the ~" casing above the proposed injection pool. A second bond log will be run to evaluate the bond between the sands of the pool before the completion is run. The well currently has perforations in the N sand at 9,800'-9,820'. These perforations will be isolate with a straddle packer as no injection into this interval is planned. Perforations will be added and injection is planned in the OA sand (io,~io'- io,75o' & ~0,850'-10,8~0) and the OB sand (~~,i3o'-11,190'). Plan Forward• 1) Obtain Sundry for conversion to water injection 2) Run cement bond log to evaluate inter-pool cement 3) Perforate OA and OB sands (sundry to re-enter the suspended well and perforate submitted 9/29/09) 4) MIT-IA to 2,50o psi 5) Run dual string completion to isolate zones for injection (separate sundry to be submitted for rig operations) 6) Place well on water injection (confirm AOGCC approval prior to injection) ~) AOGCC witnessed MITIA once injection has stabilized • • Area of Review - Milne Point I-1~ (2oio7~) Prior to the completion of well MPI-13 to a water injector an Area of Review (AOR) is required. This AOR discuss the wells within 1/4 mile of the well's entry point into the Schrader Bluff Formation to the bottom of well bore completion. Two other wellbores enter the Schrader Bluff formation in the AOR. The following table illustrates the well within the AOR, its distance from MPI-13, completions detail, and any annulus integrity comments based on an in-depth review of each well. Figure ~: Wells within AOR ~,~ '~~~~~~'~ `t8 5. F % ' ~ ~~ . ~~ ~ "~ R ~~ ~, f~.. ~ ~ ~ ~ ~ ~~ r3'X~.~' ~n~? ~ ~'~• ~ i'~:a~e~'k"Ty.+ ~ ~ 3°' ~ s~ ~.~a, §~..~. ~ d ,p~~ ;~ y~,~ ~~e~~:~ ~I ~'3 $ t i'~3~R~ .~ ~ .E.~ i ~ n~~`*x'~, ~• ' €'s~''~ :. " ' ~ ~ ~~ ?. ~ . k ~.~~ jd i~ `~ { ',. ~ q ; . ~..r~ # ~ k~. ~ ) 3~ ~ " f ~ ~~~~ ;~:~ ,~, £ ~: ~, ~ Y ~ ~ ~~~ ~~ ~ 1 Y;nx` ;~ ~ ~ ~ ~ e . E~~ 4 Pt.~3~+ 3.. YSe~... d ~ ~ •'u~~~ ;~, ~.. MPI-i3 ~" ~ 8" 296 bbls 9~734~ MD MPI-ii ~" ~ 8" 28~ bbls ,747 MD MPI-i2 ~" 9 7 g° 24o bbls 9,io9' MD Figure 2: Completion Detail Well MPI-11 (PTD 2oii37) was completed in October 2001. The completion crossed the Schrader Bluff formation at 9,747' MD. A ~" casing string was run to 10,747' MD and cemented with 28~ bbls of class G cement. Two laterals were drilled out of this wellbore into the Schrader Bluff sands. The OA lateral window is at 10,345'-10,357' MD and the OB lateral is drilled out of the mother-bore. Well MPI-~2 (PTD 201163) was completed in November 2001. The completion crossed the Schrader Bluff formation at 9,iog' MD. A ~" casing string was run to io,347' MD and cemented with 24o bbls of class G cement. Two laterals were drilled out of this wellbore into the Schrader Bluff sands. The OA lateral window is at g,9i6'-g,928' and the OB lateral is drilled out of the mother-bore. s • Top Schrader Bluff Formation Structure Map illustratinq the AOR N ~ ~ - - - ' ~ MPI-12L1 - ' ~- .- _ _ MPI-12~ - - d.__ __ -_ -- _~_ _ ` ~ ~ - - - ~` . O ~~ II O ~ \ M PI-'f~ ~ --~ -- - -_ ...- -- - - M MPI-1~ r MPI-11 L1 ~•-~-----~----------~------ MPI-06 iooo o ,oo0 200o rt Top Schrader Bluff Formation Structtre grid ( feet) -5024 -4550 -4080 -3610 3125 Top Schrader Bluff Formation Intercept with well Q~arter mile cistance aand MPI-13 al top of ScFrader BIiJf Famalian ` `~ ' ~~ ~ ~s ~- o ~--.~ , ___~- , _ -~='~-°~~ ~ ~ ~, • , 7" Frac tree - 5M ~" :a~i~. 7" 5M FMC Gen. 6 monobore w/ false bowl MPU I -13i Orig. DF elev. = 64.12' (Nabor 22-E) Orig. GL. elev.= 35.10'~Nabor 22-E) 20" 91.1 ppf, H-40 ~ KOP @ 405' Max. hole angle = 85 deg. Hole angle through perfs = 82 deg. 7", 26# L-80, HYD521 production casing (drift ID= 6.151", cap. _.0383 bbls/ ft) Perforation Summary Ref loct: Size SPF Interval (TVD) 2.5" 4 N sand 9800`-9820' 3513`-3516' OA sand OB sand DATE REV.BY COMMENTS 08/19/01 M.Linder Initial comoletion Nabors 22-E TAM port collar at 1416` 7" float callar (PBTD} 11313` 7" casing shoe 11397` MILNE POINT UNIT WELL I -13i API NO: 50-029-23012-00 I I I I BP EXPLORATION (AK) ~ • i --~ # G~ ~ ~; } ~..._ . , , ~ ~~r~;~Eg ~ ~ °~~ ~ ~ ~ ~ ~~ ~ ~` L ~ ~ ~ ~ ~ ~ ~ ~ W a ~ @ ~? y f k '~ ~~= tt ~ ~ ~ p ;f.~ ~ ~ ~ { ~ ~ ~ t~ ~" ~ ~ "G ~ ~ f $ ~ ~g 4 -~` ~ f, ~ ~ ~ ~ ~~ ~ ~ f ~ i ~ ~ ~ ~ b aE- ~ ~°~ ~ ~ @ ~'~~ ~g, .~~~ ~ ~~ ~~ ~ d ~ ~ n~ SEAN PARNELL, GOVERNOR ~~~ ~--'~ ~" ~~ ~:~ ~. ~`-~ =v,~ ~E _.~ ~~~ N_~ M=~ " ~ ~,~'`.'~-' ~ G~ ~ ~.~~~ ~v d" r ~-7~ ~I~ tusi/ t]r~,7 ~ z 333 W. 7th AVENUE, SUITE 100 C01~5ER~A7`IO1~T COMI~IIS51O1~T ~ pHONERA( 07A2~9K4339501-3539 , FAX (907)276-7542 Mr. Keith Lopez Production Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 ~ ~~~~ ~ Re: Milne Point Unit Field, Schrader Bluff Pool, 1VIPI-13 Sundry Number: 309-342 Dear Mr. Lopez: ~'"~~~~~~ ~~~';l ~ ~ 2~~~ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commissicn grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ~ Chair h DATED this~ day of October, 2009 Encl. , STATE OF ALASKA ~]r ALA~OIL AND GAS CONSERVATION COMMIS~ APPLICATION FOR SUNDRY APPROVALS ~n eer ~~ ~un .. ~ECEIVEQ~ SFP 2 9 zao~ 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^~ Re-enter Sus en e e~ Alter casing [] Repair well ~ Plug Perforations ^ Stimulate ^ Other ^ ~~ .~e Change approved program ~ Pull Tubing ~ Perforate New Pool ^ Time Extension ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ~ Exploratory ~ 201-0750' 3. Address: P.O. Box 196612 Stratigraphic ~ Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-23012-00-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: 0 Spacing Exception Required? Yes ^ No MPI-13 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-025517 ~ Milne Point Unit Field / Schrader Bluff Pool ~ ~• PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth 7VD (ft): Plugs (measured): Junk (measured): 11418 ~ 3745.06 ~ 11313 - 3726.19 - NONE NONE Casing Length Size MD ND Burst Collapse Structural Conductor 112' 20" 91.1# H-40 31' 112' 31' 112' Surtace Intermediate Production 11397' 7" 26# L-80 30' 11397' 30' 3741' 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth NO (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9800 - 9820 3513.73 - 3517.05 NONE NONE NONE - Packers and SSSV Tvpe: NONE Packers and SSSV MD and ND (ft): NONE 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ~ Exploratory ~ Development ^ Service ^~ . 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/5/2009 Oil ^ Gas ^ WDSPL ^ Piugged ^ 16. Verbal Approval: Date: WINJ ^~ - GINJ ^ WAG ^ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. i hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Keith Lopez Printed Name Keith Lopez Title production Engineer Signature Phone Date 564-5718 9/29/2009 Prepared by Gary Preble 564-4944 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~O ~"~ ~~"' Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other. n ~~~e~ ~~.,~ L o O GG - ~arwarX ~ ~ ~- ~ ~ ~t Subsequent Form Required: ~O" t{ ~K APPROVED BY A d b ~ Q pprove y: COMMISSIONER THE COMMISSION Date: / Form 10-403 Revised 07/2009 ~~~~~~~IAL ~-~~~~~ ~~~ 4 ~: ~ ~ ~: zaoy ~ io•~_a~ Submit in Duplicate • ~ bp BP Exploration Alaska Milne Point To: Jerry Sharp/Mark O'Malley Date: September 23, 2009 MPU Well Operations Supervisar From: Keith Lopez IOR: 235 bopd Tract 14 PE AFE: MS 1133984 COST: $330M Sub_iect: MPI-13 CTU CBL, Perforate, Secure (pre-RWO) - Requires 2" Coil OBJECTIVES: To run CBL, perforate, set WRP, and pressure test casing in prep for RWO injection conversion. PROPOSED STEPS: Cate or Ste Descri tion S 1 Run SBHP Surve C 2 Memory log & perf. Set 7" plug and MTT casing. Circulate FP (Requires 2" Coil) WELL DATA Current Status: Suspended well w/ open N sand perfs. Well is freeze protected w/ diesel Max Deviation: 84.6 degrees at 3686' MD Min ID: ~" 26# production casing to TD Last TD tag: Deepest CT has been able to get is io,8i4' due to suspected helical buckling Last downhole ops: Drift for E-line to 3656' w/ roller stem and 2.75" swedge. Stopped due to deviation on i/i6/o2. Latest H2S level: N/A - SBL have minimal H2S <io ppm Latest SBHP: i742 psi @ 4ooo'TVDSS 9/5/oi Tbg/csg size: ~" 26# prod csg, no casing BACKGROUND MPI-13 was drilled and cased as an injector to support the MPI-11 and MPI-12 producers in 2001. This well was never completed due to unreliable production from the two producers but perforations were shot in the N sand (20' X 4 SPF) to get a pressure reading. These perforations will be isolated with a packer in the completion with plans to only inject into the deeper OA and OB zones. A CBL was run on coil but could not get lower then 10,814' due to suspected helical buckling. In 2009, the MPI-11 was converted to a Jet Pump (JP) and has produced reliably for 4 • • months (+/- 250 bopd). The MPI-11 is currently SI waiting the MPI-13 injector completion. The conversion will also allow the completion of the MPI-12 with a similar JP lift mechanism. The plan is to convert this well to a dual string injector in the OA and OB sands to support the MPI-11 and MPI-12. A deeper CBL is requested to provide information for the injection completion. If CBL shows no cement across perforation intervals, a remedial cement job may be considered. DETAILED PROCEDURE: NOTE: Bowl ID thru tree is 6.8i2". Two ~" Baker Wireline Set Retreivable Bridge Plugs are available on the slope. SL i. Run SBHP as deep a deviation allows. CTU: 1. MIRU CTU w/ 2" coil. 2. RIH and drift for perf and plug runs 3. RIH w/ memory GR/CCL/CBL and log from PBTD (11,313') to 8,000'. Flag Coil. (If CBL shows at least 20' of good cement bond between 10,780' and 11,130', then continue with perforating. If not we will plan a remedial cement job. If there are any questions please contact Keith Lopez 907-903-5432 or Jennifer Julian 907-240- 8037.) 4. RIH w/ 4-1/2" perforating guns loaded with 5 spf 38.6 gram PowerJet 4505 charges and 72° phasing. Perforate the following depths tied into Sperry-Sun MWD log dated 7/31/O1 To Perf (MD) Bottom Perf (MD) Gross Foota e 10710' 10750' 40' 10850' 10870' 20' 11130' 11190' 60' ~ 5. RIH w/ 7" Baker WRP and set @ 9750'. Load and test IA to 2,500 psig (MIT). (Plan to run memory LDL if MIT-IA fails). 6. Circulate FP (diesel) @ 2300'. 7. RDMO CTU . POINTS OF CONTACT: Production Engineer: Keith Lopez Office:564-5718 Ce11:903-5432 ~ 7" Frac tree - 5M ~ M P U I-13 i Orig. DF elev. = 64.12' (Nabor 22-E) I ~ad: 7" 5M FMC Gen. 6 monobore w/ false bow! ~ ~ Orig. GL. elev.= 35.10'~Nabor 22-E) 20" 91.1 ppf, H-40 ~ TAM port collar at 1416' KOP @ 405' Max. hole angle = 85 deg. Hole ang~e through perfs = 82 deg. 7", 26# L-80, HYD521 production casing (drift ID= 6.151", cap. _.0383 bbls/ ft) Pertoration Summarv Ref loa: Size SPF Interval (ND) 2.5" 4 N sand 9800`-9820' 3513`-3516' OA sand OB sand 7" float collar (PBTD) 11313` 7" casing shoe 11397' DATE REV. BY COMMENTS 08/19/01 M.Linder Initial comoletion Nabors 22-E MILNE POINT UNIT WELL I -13i API NO: 50-029-23012-00 · .7~ 'ff4( ...'1 ' WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 13, 2006 RE: MWD Formation Evaluation Logs: MPK-09, MPS-12 PB1 L1, MPI-13, MPS-18 PBl. - - - The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 MPK-09: ÐD~~blL../ -tf: /43CJ1f Digital Log Images: 1 CD Rom 50-029-23247-00 MPS-12 PB1 L1: ;,;)6'3 -og'3 1:1 /4401 903 -Ode..¡ tJ ILfL./D'd - - ( Digital Log Images: 1 CD Rom 50-029-23133-00, 70, 60 MPI-13: U:t~ eo! -ö-:r~ \:t: ·L.I(3C]CJ Digital Log Images: 1 CD Rom 50-029-23012-00 MPS-18_PBl: UIC- dOd _(/_/;;) I:t 1<-I'-¡DO Digital Log Images: 50-029-23133-00, 70 1 CD Rom SCANNED FEB 0 1 2007 (0 e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs MPI-13, e OIG 201- O-l~) February 16, 2006 f3!:::J 7"7 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 MPI-13: LAS Data & Digital Log Images: 50-029-23012-00 C Q' 1 CD Rom l\Lr·ì ~J)Lrì 2'/DJJ/Olo e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LascrFiche\CvrPgs _Inscrts\Microfilm _ Marker. doc To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MMD Formation Evaluation Logs MPI- 13, AK-MM- 11130 September 23, 2003 1 LIS formatted CD rom with verification listing. API#: 50-029-23012-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO TI-IE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 RECEIVED SEP 24 200 Permit to Drill 2010750 MD 11418 ~ TVD DATA SUBMITTAL COMPLIANCE REPORT 8~25~2003 Well Name/No. MILNE PT UNIT SB 1-13 Operator BP EXPLORATION (ALASKA) INC 3745 ,~'~ Completion Dar 8/19/2001~'" Completion Statu SUSP Current Status SUSP APl No. 50-029-23012-00-00 UIC Y REQUIRED INFORMATION Mud Log N_.~o Sample N__o Directional Survey ~_~//.~, DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type ~edia Fmt (data taken from Logs Portion of Master Well Data Maint) Log Log Run Name Scale Media No Interval Start Stop OH I Dataset CH Received Number Comments Ver LIS Verification Directional Survey MWD Cement Mapping Log 5 Directional Survey Gamma Ray Collar Log 5 Directional Survey MWD Directional Survey FINAL FINAL 7000 10783 FINAL FI NAL 7000 10783 1 72 11372 FINAL FINAL OH 9/7/2001 ch 9/14/2001 OH 9/7/2001 ch 9/14/2001 Open 2/20/2002 '-f1~90 OH 9/7/2001 OH 9/7/2001 Directional Survey MWD 7000-10783 Color Print Directional Survey 7000-10783 BL, Sepia Directional Survey MWD Directional Survey DIGITAL DATA Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y Chips Received? Analysis R~.c.~.iv~.d ? Start Interval Stop Sent Received Dataset Number Comments Daily History Received? ~_~/N Formation Tops Y~ N Permitto Drill 2010750 DATA SUBMITTAL COMPLIANCE REPORT 8~25~2003 Well Name/No. MILNE PT UNIT SB 1-13 Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-23012-00-00 MD 11418 TVD Compliance Reviewed By: 3745 pletion Dat 8/19/2001 Completion Statu SUSP Current Status SUSP UIC Y To: RE: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lisa Weepie 333 West 7~ Avenue, Suite 100 Anchorage, Alaska 99501 MWD Formation Evaluation Logs: MPI-13, June 19, 2003 AK-MM-Ill30 MPI-13: Digital Log Images: 50-02%23012-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL iLETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. T':'% [?~"," ,,¢'%, ! ....... !!" ~! '?!~ ..... :,' :'~' ~¢hbrage;:.. ~ka 99518 D. ate:,~ . . BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 STATE OF ALASKA i" ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-075 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23012-00 4. Location of well at surface , ~ .... 9. Unit or Lease Name 2346' NSL, 1253' EWL, SEC. 33, T13N, R10E"'~'t ~L-,'"" ,~,~,~'~/~/.ii .il YEI~J'E[~'~:~,~-~JI" ~ [ Milne Point Unit At top of productive interval .; i ~'~"~ 2089' NSL, 2885' EWL, SEC. 31, T13N, R10E At total depth ,~?'~ ..... ~:' ,.-~,~. 10. Well Number ,!~,.t~ MPI-13i 2102' NSL, 2159' EWL, SEC. 31, T13N, R10E ..................... .,,,..~, ....... ~,, ,5. Elevation in feet (indicate KB, DF, etc.) '6. Lease Designation and Serial No. 11. Field and Pool Milne Point Unit / Schrader Bluff RKB = 64.12' ADL025517 12. Date Spudded 7/31/2001 113' Date T'D' Reached 114' Date C°mp'' Susp'' °r Aband' 8/7/2001 8/19/2001 I15' water depth' if °fish°re N/A MSL II 16' N°' °f C°mpleti°ns One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where S$SV set121. Thickness of Permafrost 11418 3745 ETI 11313 3726 FTI []Yes []NoI N/AMDI 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, DIR, GR, PWD, RES 23. CASING~ LINER AND CEMENTING RECORD CASING SE'I=I'ING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 92# H-40 31' 112' 30" 260 sx Arctic Set (Approx.) 7" 26# L-80 30' 11397' 9-7/8" 1445 sx Class 'G', 485 sx PF 'L' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) NONE N/A N/A MD TVD MD TVD 26. AcD, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' ;reeze Protected' with 75 Bbls of Diesel 27. PRODUCTION TEST , Date First Production Method of Operation (Flowing, gas lift, etc.) Not on Production N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I #l°w Tubing Casing Pressure CALCULATED !OIL-EEL GAS-MCF WATER-DEL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA '::- .................. : ...... .......... " Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or Water. Submit Core chips. No core samples were taken. ; .... "; "i..i i.:. ~ ".' Form 10-407 Rev. 07-01-80 Submit In Duplicate ~P, ~ 7 2002 /~. 29. Geologic Markers 30. Formation Tests · Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Top of Schrader OA 10682' 3627' Base of Schrader OA 10901' 3655' Top of Schrader OB 11107' 3687' Base of Schrader OB 11290' 3722' i' · , , , 31. List of Attachments: Summary of Daily Drilling Reports, Surveys, Leak-Off Test Summary , 32. I hereby certify that the fore~loing is true and correct to the best of my knowledge Signed TerrieHubble~.~,~.~~. ~ Title Technical Assistant Date ~"~,,,~ MPI- 13i 201-075 Prepared By Name/Number: Sondra Stewman, 564-4750 Well Number Permit No. /Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM '1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 2~1: 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 ~.. ~ ~.~..: .. ~ .?,'i~.~. Hubble, Terrie L From - Sent: To: Subject: Steve McMains [steve_mcmains @ admin.state.ak.us] Thursday, March 14, 2002 6:16 AM Hubble, Terrie L Re: MPI-13, 201-075, 50-029-23012-00 Talked to Winton, and he thinks you should suspend the well and then when BP wants to complete it, just submit the 10-403 and finish the well. Steve "Hubble, Terrie L" wrote: > Hi Steve, > I have another problem for you to make a determination on. Well MPI-13i was > permitted, drilled and perf'd with the Rig Release being 08/19/01. BP's > plans were to then move N~4ES over the well to run completion tubing. > However, since then the plans to complete this well have been put on hold; > firstly for the fact that the wells this injector will support have not yet > been drilled and secondly, they have been waiting on some kind of completion > equipment. > > We have been holding off on the Completion Report for this well because in > our view it is not completed without the completion tubing. Do you agree? > It is possible though, that this well may not be completed for quite a long > time, or even ever. What would you like to see. > Thanks! > Terrie Hubble > GPB Drilling & Wells > 564-4628, MB8-1, Cube 830 Legal Name: MPI-13i Common Name: MPI-13i ~TestlDa~: :; ~ :TeSt:Type ~:~: ~ :~: ;:::::Te~t Depth(~D}:~ :~ : ~ AMW: ~:: sUrface Pressure Leak Off Pressure (BHP) EMW Printed: 812112001 4:01:38 PM BP AMOCO Page 1 of 9 Operations Summary Report Legal Well Name: MPI-13i Common Well Name: MPI-13i Spud Date: 7/31/2001 Event Name: DRILL+COMPLETE Start: 7/30/2001 End: 7/31/2001 Contractor Name: NABORS Rig Release: 8/19/2001 Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours Activity Code NPT Phase Description of Operations 7/29/2001 00:00 - 00:00 24.00 MOB ~ PRE Rig down pipe shed, pump module, sub-structure/derrick, engine module, and auxiliary equipment. In the process of moving 6.3 miles to I-pad. 7/30/2001 !00:00 - 02:30 2.50 MOB P PRE Move rig to I pad & set to re-position wheels to wide spacing. 02:30 - 05:00 2.50 MOB P PRE Set crane and move wheels out. 05:00 - 06:00 1.00 MOB P PRE Move substructure/derrick module down pad and spot over 1-13 conductor. 06:00 - 07:00 1.00 MOB P PRE Set cattle chute over pipe skate. 07:00 - 09:00 2.00 MOB P PRE Set mats and move pipe shed into postion. 09:00 - 10:30 1.50 MOB P PRE Set mats and move pit module into position. 10:30 - 11:00 0.50 MOB I p PRE Set mats and move rock washer into position. 11:00 - 12:00 1.00 MOB P PRE Move motor complex to I-pad. 12:00 - 14:00 2.00 MOB P PRE Move motor complex into position. 14:00 - 17:00 3.00 MOB P PRE Set fuel tank, transfer pump, satellite camp, shop, & parts house into position. 17:00 - 20:00 3.00 MOB P PRE Construct containment berms around rig. RU fuel tank. Clean up location. 20:00 - 00:00 4.00 MOB P PRE RU pipe skate rails, torque up diverter bolts. Hook up accumulator lines. Load 5 in drillpipe into pipeshed. 7/31/2001 00:00 - 01:30 1.50 RIGU P PRE Accepted Rig @ 00:01 7/31/2001 Torque up Hydril bolts and install 4 in valves on conductor outlet. Continue to load and strap DP in to shed. 01:30 - 03:30 2.00 RIGU P PRE NU 20 in riser and flowline. Install hydraulic lines to hydril and divert valve. 03:30 - 04:30 1.00 DRILL P PROD1 PU 5in handling tools, xo's, slips, & elevators. 04:30 - 11:00 6.50 DRILL P PROD1 PU 180 jts 5 in DP and stand back in derrick. (rabbited). Function test 20" hydril and 16" divert valve. AOGCC John Crisp waived witnessing diverter function test. 11:00 - 12:00 1.00 DRILL P PROD1 PU HWDP & stand back. 12:00- 13:00 1.00 DRILL P PROD1 MU 7 jts HWDP and jars. 13:00 - 15:00 2.00 DRILL P PROD1 MU bit, motor, FS, stabilizer, MWD, GR, RES, PWD. Orient :motor & scribe tools. Load tools in hang-off collar (HOC). MU HOC, ACAL, and UBHO. 15:00 - 16:00 1.00 DRILL P PROD1 'Initialize MWD. 16:00 - 18:00 2.00 DRILL P PROD1 Condition mud. Inspect all berms, valves, & review pre-spud ~checklist. Install 4 turnbuckles on riser. Conduct rig floor pre-spud safety and operations meeting with rig crew, Sperry, ;and Baroid personnel. 18:00 - 19:00 1.00 DRILL P PROD1 Spud well 1800 hrs 7/31/2001. Drill-out conductor w/ bicarbonate treated water and sw tch over to mud. Drill 110-188'. 19:00 - 20:00 1.00 DRILL N SFAL PROD1 : Un-plug clogged flowlines & line up flowline jets. 20:00 - 21:00 1.00 DRILL P PROD1 Drill ahead 188-267'. 21:00 - 22:00 1.00 DRILL P PROD1 POOH & stand back 2 HWDP. Mu 3 flex collars and jars. TIH. 22:00 - 00:00 2.00 DRILL P 'PROD1 Drill 267-448' 8/1/2001 00:00 - 07:30 7.50 DRILL P I PROD1 Drilling 9 7/8" hole 448-1097'. 07:30 - 09:00 1.50 DRILL N SFAL PROD1 PU off btm 60 ft, slow circulate, repair Sperry stroke counter. !09:00 - 16:30 7.50 DRILL P PROD1 Drill 1097-2037. MW 8.9 ppg. ECD-PWD 10 ppg. 447 gpm, 950 psi on btm, 1050 psi off btm, 50 rpm top drive, 132 rpm motor, 2k ft-lbf on btm, lk ft-lbf off btm, 30k WOB, 118K PUW, 114K SOW, 118K ROTW. 16:30 - 17:00 0.50. DRILL P PROD1 CBU for 10 mins. . ,, Printed: 8/21/2001 4:01:47PM BP AMOCO Page 2 of 9 Operations Summa Report Legal Well Name: MPI-13i Common Well Name: MPI-13i Spud Date: 7/31/2001 Event Name: DRILL+COMPLETE Start: 7/30/2001 End: 7/31/2001 Contractor Name: NABORS Rig Release: 8/19/2001 Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours Activity Code NPT Phase Description of Operations 8/1/2001 17:00 - 17:30 0.50 DRILL = PROD1 POH to 1566. Monitor well. OK(no flow, no swab, no losses). 17:30 - 18:00 0.50 DRILL ~ PROD1 Pump weighted 30 bbl pill for dry job. Blow down top drive & mudline. 18:00 - 19:30 1.50 DRILL P PROD1 POOH to jars. Clear and clean rig floor. Adjust drawworks clutch. 19:30 - 20:30 1.00 DRILL P PROD1 Service top drive & grease crown. 20:30 - 22:30 2.00 DRILL P PROD1 Slip & cut 98' of drilling line. Adjust brakes. 22:30 - 23:30 1.00 DRILL P PROD1 TIH wash to btm 1943-2037. 23:30 - 00:00 0.50 DRILL P PROD1 Drill from 2037' to 2070'. 8/2/2001 00:00 - 16:00 16.00 DRILL P PROD1 Drill from 2070' to 4011'. MW 9.1 ppg. ECD-PWD 10.2 ppg. 444 gpm, 1350 psi on btm, 1275 psi off btm, 80 rpm top drive, 132 rpm motor, 4k ft-lbf on btm, 2k ft-lbf off btm, 10k WOB, 132K PUW, 108K SOW, 120K ROTW. 16:00 - 17:00 1.00 DRILL P PROD1 CBU & monitor well for 10 rains. 17:00 - 19:00 2.00 DRILL P PROD1 TOH to 1849'. Hole started swabbing. Pump out from 2710' to 1849'. 19:00 - 20:30 1.50 DRILL P PROD1 TIH. String taking weight at 2400' - 2700'. Wash down 3070 to 4011. 20:30-00:00 3.50 DRILL P pROD1 Dril14011to 4637'. MW9.1 ppg. ECD-PWD10.2 ppg. 524 gpm, 1900 psi on btm, 1650 psi off btm, 60 rpm top drive, 165 rpm motor, 5k ff-lbf on btm, 3k ft-lbf off btm, 20k WOB, 132K PUW, 98K SOW, 118K ROTW. 8/3/2001 00:00 - 11:00 11.00 DRILL P PROD1 Dril14637' to 6076'. WOB 15-25. PUW 155K, SOW88K, ROTW 122K, GPM 547, PSI-on 2250, PSI-off 1956, TQ-on 8k, TQ-off 6k, 80 RPM rotary, 180 RPM motor, 260 RPM bit, MW 9.2, Vis 66, PWD 10.7. 25 barrel viscous sweep pumped - increased cuttings over shakers observed. 11:00 - 13:30 2.50 DRILL P PROD1 CCM. 15 barrel weighted (11.9 ppg) slug pumped prior to TOOH. 13:30 - 17:00 3.50 DRILL P PROD1 POOH W/pumps on 6076-3531 (hole swabbing). 17:00 - 18:00 1.00 DRILL P PROD1 POOH to 628'. 18:00 - 19:00 1.00 DRILL P PROD1 Lay-down 12jts HWDP. 19:00 - 20:00 1.00 DRILL N SFAL PROD1 Level rig. 20:00 - 21:30 1.50 DRILL P PROD1 POOH & stand back 2 HWDP, jars, DC's. LD UBHO, ACAL, bit. MU new bit & BHA. Orient 1.22 degree bent motor. Clear . rig floor. 21:30 - 22:30 1.00 DRILL P PROD1 Download MWD. 22:30 - 23:30 1.00 DRILL P PROD1 LD HOC. Change-out pulser. MU HOC & ACAL. 23:30 - 00:00 0.50 DRILL P PROD1 Initialize MWD & ACAL. 8/4/2001 00:00 - 00:30 0.50 DRILL P PROD1 Continue initializing MWD on surface. 00:30 - 01:00 0.50 DRILL P PROD1 I RIH W/flex DC's, jars. Surface test MWD. 01:00 - 09:00 8.00 DRILL P PROD1 PU 180 jts & RIH w/5 in DP. Work through tight spots 2700, 13530, 3810, 4218, 4437, 4480. 09:00 - 10:00 1.00 DRILL P PROD1 Wash & ream 5370-6076'. ! 10:00 - 12:00 2.00 DRILL P I PROD1 Drill 6076-6373'. 70 RPM, 20-25 WOB, 2200 psi on btm, 60 : spin, 60 spm, 504 gpm. PUW 165K, SOW 95K, ROTVV 120K, TQON 7K, TQoff 5K. Lubricant initiated at 1%. 12:00 - 00:00 12.00 DRILL P I PROD1 Drill 6373-7782'. 170 PUW, 95 SOW, 128K ROtW, 9K TQon, 7k TQoff, 65 spm, 60 spm, 525 gpm. 2245 psi on., 2200 psi off. Lubricant increased to 2% after encountering problems w/ weight transfer to bit on slide. Next slide executed w/out problems. Printed: 8/21/2001 4:01:47 PM BP AMOCO Page 3 of 9 Operations Summary Report Legal Well Name: MPI-13i Common Well Name: MPI-13i Spud Date: 7/31/2001 Event Name: DRILL+COMPLETE Start: 7/30/2001 End: 7/31/2001 =Contractor Name: NABORS Rig Release: 8/19/2001 Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours IActivity Code NPT Phase Description of Operations 8/5/2001 00:00 - 03:30 3.50 DRILL P PROD1 Drill 7782-8250. PUW 190k, SOW 95k, ROTW 125k, TQon 1 lk, TQoff 9k, 70rpm, 18-20 WOB, 2400 psi on btm, 2325 psi off btm. 520 GPM. Lost 41 bbls mud. 03:30 - 05:30 2.00 DRILL P 'PROD1 Hole packing off while reaming connection. Lost returns, picked up off btm 45'. Slowed pump rate and worked pipe. . Re-established circulation. Circulate high vis weighted sweep. CBU. 05:30 - 06:00 0.50 DRILL P PROD1 POOH 2 stds. Hole swabbing. Monitor well. 06:00 - 11:00 5.00 DRILL P PROD1 Back-ream out 8064-5621'. 11:00 - 12:00 1.00 DRILL P PROD1 RIH 5621-7501. 12:00 - 13:00 1.00 DRILL !P PROD1 RIH to 8064. Wash and ream to 8252. 13:00 - 20:30 7.50 DRILL P PROD1 Drill 8252-9193'. PUW 210k, SOW 88k, ROTW 137k, TQon 13, TQoff 12K, 80-90 rpm, 10-20 WOB, 2400 psi on btm, 2225 psi off. 555 GPM. 20:30 - 21:30 1.00 DRILL P PROD1 Attempt to slide. Could not get weight transfer to bit. Start circulating an additional 1% lubricant into mud system. 21:30 - 22:00 0.50 DRILL P PROD1 Pump out 5 stands and stand back same. Continue lube additions. 22:00 - 22:30 0.50 DRILL P PROD1 CCM Move 15 jts HWDP into pipe shed and strap. 22:30 - 23:30 1.00 DRILL P PROD1 PU & RIH w/15 jts HWDP to 9193. 23:30 - 00:00 0.50 DRILL P PROD1 Slide drill for inclination correction (75 deg to 80 deg build needed). Sliding at 20-40 fph. (drilling assembly was previously stacking out with no ability to get weight to the bit). Slide drill 9193-9200'. 8/6/2001 00:00 - 10:00 10.00 DRILL P PROD1 Drill from 9200' to 9917'. 80 rpm, 20-25k WOB, 2750 psi on btm, 2500 psi off btm, 546 GPM, 245K PUW, 90k SOW, 148K ROTW. 10:00 - 12:00 2.00 DRILL P PROD1 Pumped high viscosity, weighted sweep. Circulate & condition mud. 12:00 - 12:30 0.50 DRILL P PROD1 Circulate. Stop pumps & monitor well. 12:30 - 15:00 2.50 DRILL P PROD1 Pump off bottom & POH w/DP to 8063'. Clear rig floor. 15:00 - 16:00 1.00 DRILL P PROD1 RIH to 8910' until excessive drag conditions encountered and pipe stacking out weight. 16:00 - 17:30 1.50 DRILL P PROD1 Wash and rotate to overcome hole friction back to bottom 8910-9919'. 17:30 - 18:00 0.50 DRILL P PROD1 Drill 9919- 9943. 18:00 - 19:00 1.00 DRILL N RREP PROD1 Repair clutch 19:00 - 00:00 5.00 DRILL N PROD1 Drill 9943-10388'. 2350 psi on btm, 2275 psi off btm, TQon 16k, TQoff 15k, PUW 245k, SOW 90k, ROTW 150k, 20-25 WOB, 90 rpm, 550 GPM. 8/7/2001 00:00 - 10:00 10.00 DRILL P PROD1 Drill 10388-11186'. 2350 psi on btm, 2275 psi off btm, TQon 16k, TQoff 15k, PUW 250k, SOW 90k, ROTW 150k, 20-25 WOB, 100 rpm, 529 GPM. 10:00 - 12:00 2.00 DRILL N PROD1 Circulated and work pipe while repair #3 motor (cio thermostat) 12:00 - 15:00 3.00 DRILL P PROD1 PJSM. Drill 11186-11418' TD. 2650 psi on btm, 2600 psi off btm, TQon 16k, TQoff 15k, PUW 245k, SOW 92k, ROTW 153k, 20-25 WOB, 100 rpm, 529 GPM. 15:00 - 19:00 4.00 DRILL P PROD1 Circulate and condition mud. 19:00 - 23:00 4.00 DRILL P PROD1 Pull out of hole. SLM. Well swabbing on first stand. Pulled to 7876' pumping out. Take Torque & Drag readings every 10 stands. 23:00 - 00:00 1.00 DRILL P PROD1 Pull out of the hole. SLM. Pumping out and back-reaming from 7876' to 7595'. Take torque and drag readings every 10 Printed: 8/21/2001 4:01:47 PM BP AMOCO Page 4 of 9 Operations Summary Report ,, Legal Well Name: MPI-13i Common Well Name: MPI-13i Spud Date: 7/31/2001 Event Name: DRILL+COMPLETE Start: 7/30/2001 End: 7/31/2001 Contractor Name: NABORS Rig Release: 8/19/2001 Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours Activity Code NPT Phase Description of Operations .......................... 8/7/2001 23:00 - 00:0o 1.00 DRILL P PROD1 stands. 8/8/2001 00:00 - 00:30 0.50 DRILL P PROD1 Pull out of the hole. SLM. Pumping out and back-reaming from 7595' to 7500'. Take torque and drag readings every 10 stand. 00:30 - 01:00 0.50 DRILL P PROD1 Work pipe and circulate hole clean at 7500'. Cuttings on the shakers. 01:00 - 12:00 11.00 DRILL P PROD1 Continue pump out of hole from 7500'. Back-ream as necessary to 2149'. POH from 2149' to MWD. No change in SLM. '12:00 - 13:30 1.50 DRILL P PROD1 PJSM. Download MWD tool and change out Acoustic Caliper logging tool. 13:30 - 14:30 1.00 DRILL P PROD1 PJSM. RIH to 2055'. Fill pipe and test MWD. 14:30 - 17:30 3.00 DRILL P PROD1 RIH to 7501'. Ream 7501 -7698'. Well not taking correct displacement. Indications of flowing as RIH. Approx 2-4 bbl ~excess per 5 stands. 17:30 - 18:30 1.00 DRILL P PROD1 Circulate bottoms up at 7698' 18:30 - 20:00 1.50 DRILL P PROD1 !RIH to 8970'. 20:00 - 20:30 0.50 DRILL P PROD1 Ream from 8970-9099'. 20:30 - 22:00 1.50 DRILL P PROD1 RIH to 11232'. Drill string stacking out. Work pipe into hole. 22:00 - 22:30 0.50 DRILL P PROD1 Ream 11232-11418'. 22:30 - 00:00 1.50 DRILL P PROD1 Circulate and condition mud. 3 bottoms up. 8/9/2001 00:00 - 01:30 1.50 DRILL P PROD1 Continue circulation and condition hole. 01:30 - 07:00 5.50 DRILL P PROD1 Pump out from 11418-7220'. 07:00 - 08:00 1.00 DRILL P PROD1 Circulate bottoms up and monitor well. 08:00 - 11:30 3.50 DRILL P PROD1 RIH 7720-9005'. Fill pipe and work through tight spots. Continue to RIH 9005-11418'. 11:30 - 23:00 11.50 DRILL N DPRB PROD1 Circulate and work pipe by recipricating and rotating. Recipricating 90ft and rotating 40rpm. Raise mud weight from 9.3 to 11.1ppg with barite at approx 150 sx/hr. Initial salt water influx at approx 30 bbl/hr slowing to 0bbl. Chlorides increased from 2400 to 3900. Maximum ECD 12.2ppg. 23:00 - 00:00 1.00 DRILL N PROD1 Circulate and condition mud. 8/10/2001 00:00 - 05:00 5.00 DRILL P PROD1 Circulate and condition mud. Lose 8 bbl per hr while circulating. 05:00 - 05:30 0.50 DRILL P PROD1 Monitor well. No losses with well static. 05:30 - 07:30 2.00 DRILL P PROD1 POH 11418'-11324'. Work through tight spot on first stand. Continue to POH to 10388' without pumping, normal drag. 07:30 - 08:30 1.00 DRILL P PROD1 RIH to 11418'. Hole is in good condition. 08:30 - 13:30 5.00 DRILL P PROD1 Circulate and condition mud. Add lubricants (5%) and adjust properties. Lose 2 bbl per hr while circulating. 13:30 - 14:30 1.00 DRILL P PROD1 Spot "Stick Less" glass beads at 10 Ibs/bbl from 11326'-6418'. 14:30 - 15:00 0.50 DRILL P PROD1 Monitor well. PJSM. Pump dry job. 15:00 - 19:00 4.00 DRILL P PROD1 POH without pumping. No excess drag. Record PU/SO/ROT every 10 stands. Hole taking correct fill. 19:00 - 20:00 1.00 DRILL P PROD1 PJSM. Spot "Stick Less" glass beads at 101bs/bbl from 6400' to surface. 20:00 - 22:30 2.50 DRILL P PROD1 PJSM. Continue POH. Taking PU/SO/ROT every 10 stands. Stand all drill pipe in derrick. 22:30-23:30 1.00 DRILL P PROD1 PJSM. LD BHA. 23:30 - 00:00 0.50 DRILL P PROD1 Clear rig floor and prepare to rig up to run 7" casing. ' 8/11/2001 00:00 - 00:30 0.50 DRILL P PROD1 Clear Rig Floor Of Sperry Sun Tools 00:30 - 01:00 0.50 CASE P PROD1 Level Up Rig Over Hole In Order To Run Casing 01:00 - 02:30 1.50 CASE 'P PROD1 Change Out Bales To Long Set - Rig Up Casing Tools'l-o Run Printed: 8/21/2001 4:01:47 PM BP AMOCO Page 5 of 9 Operations Summary Report ,P Legal Well Name: MPI-13i Common Well Name: MPI-13i Spud Date: 7/31/2001 Event Name: DRILL+COMPLETE Start: 7/30/2001 End: 7/31/2001 Contractor Name: NABORS Rig Release: 8/19/2001 Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours Activity Code NPT Phase Description of Operations ....... 8/11/2001 01:00 - 02:30 1.50 CASE 3 PROD1 7" Long String 02:30 - 03:00 0.50 CASE 3 PROD1 Hold Pre-Job Safety Meeting With All Personal Reguarding Casing Job 03:00 - 08:30 5.50 CASE ~ PROD1 Pick Up And RIH With 7" 261b. L-80 Hydril 521 Casing To 2,987' Break Circulation At 3 BPM Step Up To 7 BPM - Monitor Gains And Losses (No Problems Good Returns And No Losses) 08:30 - 13:30 5.00 CASE 3 PROD1 Continue To Pick Up And RIH With 7" 261b. L-80 Hydril 521 Casing To 6,018'. 13:30 - 00:00 10.50 CASE N DPRB PROD1 Attempt To Break Circulation (NO GOOD) - POH Laying Down 7" Casing Attempt To Break Circulation When Pulling Every 10 Joints (NO GOOD) Total Of 85 Joints At Midnight Layed Down 64 Joints Left In Hole Depth At 2,585' - Total Mud Losses At 107 Barrels. 8/12/2001 00:00 - 03:30 3.50 CASE N DPRB PROD1 Continue To POH Laying Down 7" Hydril 521 Casing -Attempt To Regain Circulation When Pulling 10 Joints - Circulation Established At 1,826' 03:30 - 04:30 1.00 CASE N DPRB PROD1 Circulate @ 4 BPM While Monitoring Well Bore For Losses - Pump Dry Job 04:30 - 10:30 6.00 CASE N DPRB PROD1 Continue To POH Laying Down 7" Casing 10:30 - 11:00 0.50 CASE N DPRB PROD1 Heat And Break Baker Lock Connections On Shoe Track And Lay Down 11:00 - 12:00 1.00 CASE N DPRB PROD1 Clean Casing Equipment And Tools - Rig Down And Clear Rig Floor 12:00 - 13:00 1.00 CASE N DPRB PROD1 Service Varco Top Drive, Crown Sheaves, Traveling Blocks, And Swivel Wash Pipe 13:00 - 14:00 1.00 CASE N DPRB PROD1 Slip And Cut 117' Of 1 3/8" Drilling Line 14:00 - 15:30 1.50 CASE N DPRB PROD1 Make Up 9 7/8" Hole Opener & BHA - RIH To 2,280' - Taking Weight 15:30 - 16:00 0.50 CASE N DPRB PROD1 Wash And Ream From 2,280' To 2,923' 16:00 - 17:00 1.00 CASE N ~DPRB PROD1 Continue To RIH To 4,424' 17:00 - 18:00 1.00 CASE N DPRB PROD1 Circulate Bottoms Up & Condition Mud 18:00 - 19:00 1.00 CASE N I DPRB PROD1 Continue To RIH To 5,080' - Break Circulation - Continue To RIH To 5,832' - Break Circulation - Continue To RIH To 6,206' -Taking Weight 19:00 - 21:30 2.50 CASE N DPRB PROD1 Wash And Ream From 6,206' To 7,242' - Mud Weight Coming Out Increased Due To Reaming With Hole Opener- Started To Have Losses. 21:30 - 23:00 1.50 CASE N DPRB PROD1 Circulate And Condition Mud - Unload Hole To Reduce ECD 23:00 - 00:00 1.00 CASE N DPRB PROD1 Wash And Ream From 7,242' To 7,803' 8/13/2001 00:00 - 08:00 8.00 CASE N DPRB PROD1 Continue To Wash And Ream To Bottom From 7,803' To 11,418' (NO Fill & NO Problems) 08:00 - 10:30 2.50 CASE N DPRB PROD1 Lay Down One Single Of 5" Drill Pipe And Circulate Bottoms Up Monitor Well Bore For Losses (Lost 60 Total Barrels) Reduce Pumping Rate And Treat Mud - Losses Stabilized 10:30 - 12:00 1.50 CASE N DPRB PROD1 Stand Back One Stand - Circulate Bottoms Up And Continue To Treat Mud As Needed 12:00 - 16:00 4.00 CASE N DPRB PROD1 RIH With One Stand From Mast And Continue To Circulate And Treat Mud 16:00 - 17:30 1.50 CASE N DPRB PROD1 Spot Glass Bead Pill From 11,418' To 6,400' 17:30 - 22:00 4.50 CASE N DPRB PROD1 Monitor Well (Static) POH Slow Due To Swabbing - Rotate Drill String As Needed To Keep From Swabbing And For Correct Pipe Displacement - Pull A Total Of 12 Stands Of 5" Drill Pipe Printed: 8/21/2001 4:01:47 PM BP AMOCO Page 6 of 9 Operations Summary Report Legal Well Name: MPI-13i Common Well Name: MPI-13i Spud Date: 7/31/2001 Event Name: DRILL+COMPLETE Start: 7/30/2001 End: 7/31/2001 Contractor Name: NABORS Rig Release: 8/19/2001 Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours Activity Code NPT Phase Description of Operations ., 8/13/2001 17:30 - 22:00 4.50 CASE N DPRB PROD1 And 2 Stands Of 5" HWDP - Monitor Well Bore (Static) - Pump Dry Job And POH To 6,400' *NOTE* Well Taking 6 Barrels Of Fluid For 5 Stands Pulled (DRY) 22:00 - 23:30 1.50 CASE N DPRB PROD1 Monitor Well Bore (Static) - Circulate At 6,400' - Mix And Spot Glass Bead Pill From 6,400' To Surface ~ Pump Dry Job 23:30 - 00:00 0.50 CASE N DPRB PROD1 Continue To POH With 5" Drill Pipe 8/14/2001 00:00 - 02:30 2.50 CASE N DPRB PROD1 Continue To POH With 5" Drill Pipe Standing Back In Mast - Monitor Well Losses Close With Pipe Displacement - Average Displacement For 5 Stands Of Drill Pipe At 6 Barrels. Well Bore Taking 3 To 4.5 Barrels Per Hour 02:30 - 03:30 1.00 CASE N DPRB PROD1 Lay Down 9 7/8" Hole Opener, 9 5/8" Stab, Jars, And Flex Collars 03:30 - 04:00 0.50 CASE N DPRB PROD1 Clear Rig Floor Of BHA Tools And Equipment 04:00 - 05:30 1.50 CASE N DPRB PROD1 Hold Pre-Job Safety Meeting - Rig Up Casing Tools And Equipment 05:30 - 00:00 18.50 CASE N DPRB PROD1 Pick Up And RIH With 7" Hydril 521 26 lb. L-80 Casing - Take Torque And Drag Data Every 10 Joints - Break Circulation Every Ten Joints Or As Well Dictates - Tag Ledge At 4,220' Work Through Same Continue Picking Up Casing To 4,500' Working Centrilizers Through This Problem Area - Tag Bridge At 5,935' *NOTE* (Previous Casing Run Stoping Point) - Joint No.149 Work Thru Area And Continue To Work Casing In The Hole. Monitor Returns Very Close - Treat Mud While Staging In The Hole During Circulation. 8/15/2001 00:00 - 09:00 9.00 CASE P PROD1 Continue To Pick Up And RIH With 7" Casing Per Well Program Casing Starting To Float And Clear Elevators On Joint No. 136 Circulate And Fill Every 5 Joints - Run 199 Joints Before Having To Install Drive Subs And Rotate Casing Down On Every Joint - NOTE Back To Productive Time At 00:00 Hours 8/15/01 09:00 - 10:00 1.00 CASE P PROD1 Circulate Bottoms Up Rotate And Reciprocate Casing 10:00 - 11:00 1.00 CASE N RREP PROD1 Repair Yarco Top Drive Torque Arrestor Plate And Install Bolts 11:00 - 00:00 13.00 CASE P PROD1 Continue To Pick Up And RIH W/7" Hydril 521 261b. L-80 Casing 274 Total Joints Ran At Midnight. 8/16/2001 00:00 - 04:00 4.00 CASE P PROD1 Continue To Pick Up 286 Joints Of 7" Hydril 521 L-80 261b. Casing - Install Drive Subs And Rotate To Bottom - Bottom Of Reaming Shoe W/NO Float At 11,396' - 25K Foot Pounds Torque On Bottom - Rotating Weight 120K - Slack Off Weight 70K - Pick Up Weight 310K+ - Circulation Rate 5 To 7.5 BPM At 350 Psi. 04:00 - 07:00 3.00 CASE P PROD1 Circulate And Condition Mud 07:00 - 08:00 1.00 CEMT P PROD1 Rig Up Haliburton Cement Equipment - Hold Pre Job Safety Meeting With All Involved Personal Reguarding Up Coming Cement Job. 08:00 - 11:00 3.00 CEMT P PROD1 Rig Circulating At 6 BPM With 250 Psi. - Shut Down And Turn Over To Haliburton Equipment Services - Break Circulation And Pump 10 Barrels Water - Test Lines At 3,500 Psi. (OK) - Pump 70 Barrels 12.0 ppg Alpha Spacer - Drop Bottom Plug - Mix And Pump 1,450 Sacks 15.8 ppg Cement With The Following Additives .3% Halad 344, .2% CPR-3, And .13% NR-5 - 296 Barrels Cement Slurry Pumped With A Yield Of 1.15 Per Sack - Shut Down Close Valves On Cement Head Flush Out Cement Surface Lines With 5 Barrels Water - Drop . Printed: 8/21/2001 4:01 :,47 PM , i, BP AMOCO Page 7 of 9 Operations Summary Report .,, Legal Well Name: MPI-13i Common Well Name: MPI-13i Spud Date: 7/31/2001 Event Name: DRILL+COMPLETE Start: 7/30/2001 End: 7/31/2001 Contractor Name: NABORS Rig Release: 8/19/2001 Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours Activity Code NPT Phase Description of Operations ,, 8/16/2001 08:00 - 11:00 3.00 CEMT ~ PROD1 Top Plug And Chase With 5 Barrels Water - Turn Over To Rig I For Displacement To Top Of Float Collar At 11,313' - Pump 427 Barrels At 6.5 BPM At 300 Psi. - Slow Pump Rate To 3.0 BPM To Bump Plug Final Circulating Pressure At 650 Psi. - Increase Pressure To 2,500 Psi. And Hold For 5 Minutes - Bleed Off Pressure And Check Float Equipment (OK) - Rig Down Cementing Head And Cement Lines - Ist Stage Cement In Place At 10:30 Hours. - *NOTE* 1st Stage Cement Job Completed With Full Returns Also Notified AOGCC Representive John Crisp Of Upcoming Cement Job And He Waived The Witness Of The Job. 11:00 - 11:30 0.50 CEMT P PROD1 Clear Rig Floor Of Haliburton Tools And Equipment 11:30 - 12:00 0.50 CEMT P PROD1 Rig Up False Table, Bowl, And Hand Slips To Pick Up 3 1/2" Drill Pipe For 2nd Stage Cement Job 12:00 - 15:00 3.00 CEMT P PROD1 Make Up Tam Port Collar Shifting Tool - Pick Up 46 Joints Of 3 1/2" Drill Pipe - Rabbit And RIH 15:00 - 15:30 0.50 CEMT P PROD1 Latch In To Tam Port Collar At 1,415' And Test Shifting Tool Cups At 1,000 Psi. 15:30 - 16:00 0.50 CEMT P PROD1 Circulate And Condition Mud With Rig - Hold Pre-Job Safety Meeting 16:00 - 18:00 2.00 CEMT P PROD1 Shut Down And Turn Over To Haliburton Equipment Services - Pump 5 Barrels Of Water - Test Surface Lines At 2,000 Psi. - Pump 5 Barrels Water - Mix And Pump 485 Sacks 10.7 ppg Permafrost Type "L" Cement - Pumping Rate At 5 BPM With 650 Psi. - 358 Barrels Cement Slurry Pumped With A Yield Of 4.15 Cu/Ft Per Sack - Shut Down Cement - Pump 5 Barrels Water - Turn Over To Rig - Pump 8 Barrels 11.1 ppg Mud - Final Circulating Pressure At 650 Psi. 2nd Stage Cement In Place At 17:30 Hours. - *NOTE* 2nd Stage Cement Job Completed With Full Returns - Ten Barrels Cement Returns To Surface Also Notified AOGCC Representive John Crisp Of Upcoming Cement Job And He Waived The Witness Of The Job. - Shift Tam Port Collar To Closed Position - Pressure Up To 1,000 Psi. For Verification - Bleed Pressure Off And Release Shifting Tool From Port Collar. 18:00 - 19:00 1.00 CEMT P !PROD1 Rig Down Head Pin And Cement Line - POH With 3 1/2" Drill Pipe Stand Back In Mast - Lay Down Tam Port Collar Shifting Tool - Clear Rig Floor 19:00 - 21:00 2.00 BOPSUF. P COMP Nipple Down 16" Diverter Line - Remove Flow Line And Fill Up Lines - UnLatch FMC Quick Connect - Pick Up 21 1/4"Annular And Diverter Spool 21:00 ~ 22:00 1.00 BOPSUF. P COMP Set Emergengy Slips In Profile - Pull 145K Up Weight Indicator Thus Placing 80K Up Weight On 7" Casing String Inconjuction With 65K Top Drive Weight 22:00 - 22:30 0.50 BOPSUF.P COMP Make Rough Cut On 7" Casing String And Lay Down Cut Off Section - Set Diverter System Down On To Quick Connect 22:30 - 23:30 1.00 BOPSUF:P COMP Continue To Nipple Down - Remove Drip Pans, 20" Riser, Pick Up Annular And Diverter Spool Move Off Well And Seperate 23:30 - 00:00 0.50 BOPSUF:P COMP Make Final Cut On 7" Casing And Dress Up Stub - Install Transition Nipple On To Casing And Ensure That It Is Level, Tack Weld In To Place - Pre Heat Per Welding Procedure 8/17/2001 00:00 - 08:00 8.00 BOPSUFiP COMP Continue To Pre Heat Transition Nipple And Weld Out Per FMC Procedure - Allow Transition Nipple To Cool Down For Printed: 812112001 4:01:47 PM BP AMOCO Page 8 of 9 Operations Summar Report Legal Well Name: MPI-13i Common Well Name: MPI-13i Spud Date: 7/31/2001 Event Name: DRILL+COMPLETE Start: 7/30/2001 End: 7/31/2001 Contractor Name: NABORS Rig Release: 8/19/2001 Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours ActivityCode NPT Phase Description of Operations 8/17/2001 !00:00 - 08:00 8.00 BOPSUF:P COMP Testing - During Cool Down Period Clean Mud Pits And Load 3 1/2" Drill Pipe Into Pipe Shed - Change Out Upper Top Drive IBOP Valve Dress Top Drive With 3 1/2 Clamping Heads And End Bell Guide 08:00 - 09:00 1.00 BOPSUF',P COMP Install FMC Gen 6 Monobore Tbg. Head Assembly - Install The 11" 5M X 13 5/8 5M DSA 09:00 - 11:00 2.00 BOPSUF P COMP Pick Up 13 5/8 5M BOP And Place On Well Head Assembly - i~ Test FMC Metal To Metal Seal At 1,000 Psi. With Nitrogen. 11:00- 13:00 2.00 BOPSU P COMP Continue To Nipple Up Bop And Related Equipment- Torque Up Bolts, Install Riser & Hook Up Flow Line, Secure With Turnbuckles - Install Double Valve On Lower Annulus 13:00 - 14:00 1.00 BOPSUR P COMP Pick Up Test Joint & Rig Up Testing Equipment 14:00 - 19:30 5.50 BOPSUR P COMP Test BOP & Related Equipment - Test Choke Manifold, Upper And Lower Pipe Rams, Blind Rams, Top Drive Upper And Lower IBOP Valves, Full Opening Safety Floor Valve, Dart Valve, HCR And Manual Valves On Choke And Kill Lines At 250 Psi. Low Pressure For 5 Minutes And 5,000 Psi. High Pressure For 10 Minutes - Perform Accumulator Test - Test Annular At 250 Psi. Low Pressure For 5 Minutes And 3,500 Psi. High Pressure For 10 Minutes. 19:30 - 20:00 0.50 BOPSUI; P COMP Rig Down BOP Test Equipment - Install FMC Wear Ring And Energize Lock Down Studs. 20:00 - 00:00 4.00 CLEAN P COMP Break Down Stands From Mast Into Mouse Hole And Lay Down With Hydraulic Hoist. 8/18/2001 00:00 - 11:00 11.00 CLEAN P COMP Break Down Stands Of 5" Drill Pipe From Mast Into Mouse Hole And Lay Down With Hydraulic Hoist. 11:00 - 12:30 1.50 CLEAN P COMP Clear Rig Floor - Rig Up To Pick Up 3 1/2" Drill Pipe - Change Out Drill Pipe Elevators And Change Out Heads On Iron Ruffneck 12:30 - 13:00 0.50 CLEAN P COMP Make Up BHA And RIH W/15 Stands Of 3 1/2" Drill Pipe From Mast. 13:00 - 22:00 9.00 CLEAN P COMP Pick Up And Rabbit 320 Joints Of 3 1/2" Drill Pipe & RIH - Watch For Cement At Tam Port Collar (NONE) - Fill Pipe Every 3,000' During Trip. Tag Cement Plugs On 7" Float Collar At 11,311' 22:00 - 23:00 1.00 CLEAN P COMP Circulate Bottoms Up While Rotating And Reciprocating Drill I String. 23:00 - 00:00 1.00 CLEAN P COMP Shut In Well And Test 7" Casing At 4,500 Psi. For 30 Minutes, Record On Circle Chart, Bleed Pressure Off And Prepare To Displace Well With Sea Water Per Program. 8/19/2001 00:00 - 01:30 1.50 CLEAN P COMP Circulate And Wait On Vaccum Trucks 01:30 - 02:00 0.50 CLEAN P COMP Pump 38 Barrel Sweep And Fresh Water Spacer - Shut Down To Fill Pit With Sea Water. 02:00 - 03:30 1.50 CLEAN P COMP Circulate Seawater Thru Kill Line Across Mud Cross Up Thru Choke Manifold And To Poor Boy Degasser To Clean Lines Of Mud. U-Tube On Bottom Of Poor Boy Degasser Restricted Allowing Spill Out Top Of Vent Pipe On Poor Boy Degasser. *NOTE* See LCIR No. 2001-1R-109904 03:30 - 06:00 2.50 CLEAN P COMP Displace Well To Sea Water While Rotating And Reciprocating Drill String. 06:00 - 13:00 7.00 CLEAN P COMP Lay Down Pup Joint - Blow Down Varco Top Drive - POH Laying Down 293 Joints Of 3 1/2" Drill Pipe. Printed: 8/21/2001 4:01:47 PM BP AMOCO Page 9 of 9 Operations Summary Report Legal Well Name: MPI-13i Common Well Name: MPI-13i Spud Date: 7/31/2001 Event Name: DRILL+COMPLETE Start: 7/30/2001 End: 7/31/2001 !Contractor Name: NABORS Rig Release: 8/19/2001 Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours Activity Code NPT Phase Description of Operations 8/19/2001 13:00 - 14:00 1.00 CLEAN = COMP Rig Up HB&R And Pump 75 Barrels Of Diesel For Freeze Protection To 2,200' 14:00 - 17:00 3.00 CLEAN P COMP Continue To POH Laying Down 72 Joints Of 3 1/2" Drill Pipe - Break Down BHA And Lay Down - Pull Wear Ring 17:00 - 17:30 0.50 CLEAN P COMP Top Off Well With 15 Barrels Of Diesel With HB&R 17:30 - 18:00 0.50 CLEAN P COMP Clear Rig Floor Of Cross Over's, Slips, Elevators, Etc. 18:00 - 19:00 1.00 CLEAN P COMP Install False Bowl And Back Pressure Valve 19:00 - 20:00 1.00 CLEAN P COMP Remove Flow Line And Turnbuckles - Clean Out Drip Pans 20:00 - 22:00 2.00 CLEAN P COMP Nipple Down BOP And Related Equipment - Remove Double Studded Adaptor - Set Back BOP Stack 22:00 - 00:00 2.00 WHSUR P COMP Nipple Up Tree And Secure Master Valves .' Printed: 8/21/2001 4:01:47 PM DEFINITIVE Milne Point Unit Alaska Drilling & Wells Milne Point MPI, Slot MPI-13 MPi-13 Job No. AKZZ11130, Surveyed: 7 August, 2001 · SURVEY REPORT 28 August, 2001 Your Ref: APi500292301200 Surface Coordinates: 6009459.34 N, 551345.51 E (70° 26' 11.7450" N, Kelly Bushing: 64.12ft above Mean Sea Level 149° 34' 52.9338" W) DRILLING 'SERVICE=: Survey Ref: svy9929 A Halliburton Company Sperry-Sun Drilling Services Survey Report for MPI-13 Your Reft APi500292301200 Job No. AKZZ11130, Surveyed: 7August, 2001 Milne Point Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 0.00 0.000 0.000 -64.12 0.00 230.69 0.740 20.310 166.56 230.68 315.21 0.800 344.830 251.08 315.20 405.04 1.280 297.330 340.89 405.01 495.74 1.730 289.790 431.56 495.68 584.69 4.180 262.690 678.26 5.170 259.810 771.66 7.340 263.940 864.76 8.110 267.760 958.59 9.990 267.690 520.39 613.65 706.49 798.74 891.40 984.71 1076.77 1165.80 1253.25 1340.13 1053.70 12.290 270.330 1148.72 16.300 272.080 1242.94 21.800 271.390 1337.33 22.410 271.110 1431.49 22.950 270.870 584.51 677.77 770.61 862.86 955.52 1048.83 1140.89 1229.92 1317.37 1404.25 1525.26 24.680 270.100 1425.91 1490.03 1619.00 28.950 270.230 1509.55 1573.67 1711.80 29.400 269.540 1590.58 1654.70 1806.45 30.980 269.010 1672.39 1736.51 1901.36 33.800 267.850 1752.52 1816.64 1994.81 40.020 268.350 1827.21 2087.39 44.580 268.140 1895.66 2182.24 49.780 268.570 1960.11 2275.91 55.640 268.370 2016.84 2369.62 61.060 268.210 2065.99 2107.20 2140.25 2165.35 2185.74 2206.89 2463.20 66.670 267.560 2556.14 71.650 267.670 2650.62 77.530 268.340 2744.90 77.480 267.920 2838.90 76.520 267.170 1891.33 1959.78 2024.23 2080.96 2130.11 2171.32 .2204.37 2229.47 2249.86 2271.01 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 0.00 N 0.00E 6009459.34 N 551345.51E 1.40 N 0.52 E 6009460.74 N 551346.02 E 2.48 N 0.55 E 6009461.82 N 551346.05 E 3.54 N 0.50W 6009462.88 N 551344.98 E 4.47 N 2.69W 6009463.79 N 551342.79 E 4.52 N 7.17W 6009463.81 N 551338.31 E 3.34 N 14.70W 6009462.57 N 551330.78 E 1.96 N 24.78W 6009461.13 N 551320.72E 1.08 N 37.26W 6009460.16 N 551308.25 E 0.49 N 52.00W 6009459.47 N 551293.51 E 0.22 N 70.37W 6009459.07 N 551275.14 E 0.76 N 93.82W 6009459.45 N 551251.69 E 1.66 N 124.55W 6009460.15 N 551220.96 E 2.44 N 160.06W 6009460.67 N 551185.44 E 3.06 N 196.36W 6009461.05 N 551149.14 E 3.37 N 234.22W 6009461.10 N 551111.28 E 3.50 N 276.49W 6009460.94 N 551069.00 E 3.41 N 321.73W 6009460.53 N 551023.76 E 2.80 N 369.32W 6009459.60 N 550976.18 E 1.39 N 420.14W 6009457.83N 550925.37 E 0.46 S 476.20W 6009455.61 N 550869.32 E 2.37 S 538.46W 6009453.27 N 550807.08 E 4.35 S 607.98W 6009450.80 N 550737.57 E 6.35 S 682.44W 6009448.29 N 550663.13 E 8.73 S 762.15W 6009445.36 N 550583.44 E 11.84 S 846.07W 6009441.67 N 550499.54 E 15.45 S 932.83W 6009437.47 N 550412.81 E 18.61 S 1023.82W 6009433.68 N 550321.85 E 21.62 S 1115.81W 6009430.04 N 550229.87 E 25.54S 1207.32W 6009425.49 N 550138.40 E Alaska Drilling & Wells Milne Point MPI Dogleg Vertical Rate Section Comment (°/100ft) 0.00 0.321 -0.55 0.559 -0.61 1.053 0.43 0.541 2.59 3.097 7.07 1.087 14.63 2.371 24.73 0.994 37.22 2.004 51.98 2.476 70.35 4.244 93.78 5.842 124.48 0.656 159.97 0.582 196.24 1.874 234.09 4.556 276.35 0.605 321.58 1.693 369.17 3.042 420.01 6.664 476.10 4.928 538.39 5.492 607.93 6.258 682.42 5.786 762.16 6.027 846.13 5.359 932.94 6.261 1023.98 0.438 1116.02 1.284 1207.59 AK-6 BP_IFR-AK 28 August, 2001 - 5:45 Page 2 of 7 DrillQuest 2. 00.08.005 Sperry-Sun Drilling Services Survey Report for MPI-13 Your Ref: AP!500292301200 Job No. AKZZ11130, Surveyed: 7August, 2001 Milne Point Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (fi) Vertical Depth (ft) 2932.67 76.080 266.890 2229.10 2293.22 3026.82 75.640 266.880 2252.10 2316.22 3121.44 76.840 267.910 2274.60 2338.72 3214.48 80.100 268.630 2293.20 2357.32 3308.34 77.280 269.590 2311.60 2375.72 2332.37 2350.52 2364,03 2374.59 2383.69 3402,84 77.340 271.940 3498.28 80.730 273.010 3591,47 82.590 273.720 3686.41 84.640 273.310 3780.59 84.270 273,400 2396.49 2414,64 2428.15 2438.71 2447.81 3874.89 84.390 273.270 2393.01 2457.13 3969.47 82.590 271.430 2403.73 2467.85 4062.31 82.350 270.920 2415,90 2480.02 4156.11 82.720 271.000 2428.08 2492.20 4249.72 81.790 268,320 2440.70 2504.82 4343.83 81.230 265.840 2454.60 2518,72 4435.99 81.160 265.770 2468.71 2532.83 4530.82 81.530 265.950 2482.98 2547.10 4624.52 82.160 265,070 2496.27 2560.39 4718.30 80.740 264.710 2510,21 2574.33 4811.52 81.730 264.750 4906.08 81.980 264.210 5000.51 80.410 264.710 5093.34 80.410 264.190 5187.51 79.670 266.840 2524.41 2537.81 2552.27 2567.73 2584.02 2588.53 2601.93 2616,39 2631.85 2648.14 5280.53 80.480 269,180 2600.06 2664.18 5374.89 81.040 269.200 2615.21 2679.33 5469.29 81.290 269.000 2629.71 2693.83 5562.86 79.420 270.090 2645.38 2709.50 5656.73 80.360 269.790 2661.86 2725.98 Local Coordinates Global Coordinates . Northlngs Eastings Northings Eastlngs (ft) (ft) (ft) (fi) 30.26 S 1298.30W 6009420.14 N 550047.45 E 35.22 S 1389,46W 6009414,55 N 549956.32 E 39.40 S 1481.27W 6009409.75 N 549864.55 E 42.14 S 1572.38W 6009406.37 N 549773.46 E 43.58 S 1664.39W 6009404.30 N 549681.46 E 42.35 S 1756.57W 6009404.90 N 549589.28 E 38.30 S 1850.16W 6009408.31N 549495.66 E 32.88 S 1942.20W 6009413.09 N 549403.58 E 27.10 S 2036,37W 6009418.22 N 549309.37 E 21.61 S 2129.95W 6009423.06N 549215.76 E 16.15 S 2223.63W 6009427.88 N 549122.04 E 12.30 S 2317.51W 6009431.09N 549028.14 E 10.41 $ 2409.53W 6009432.34 N 548936.11 E 8.85 S 2502.52W 6009433.26 N 548843.11 E 9.40 S 2595.27W 6009432.07 N 548750.37 E 14.14 S 2688.22W 6009426.69 N 548657.45 E 20.80 S 2779.05W 6009419.40 N 548566.67 E 27.57 S 2872.55W 6009411,99 N 548473.21 E 34.83S 2965.02W 6009404.09 N 548380.80 E 43.09 S 3057.39W 6009395.20 N 548288.49 E 51.55 S 3149.13 W 6009386.11 N 548196.81 E 60.56 S 3242.30 W 6009376.46 N 548103.70 E 69.57 S 3335.18 W 6009366.81 N 548010.89 E 78.42 S 3426.28 W 6009357.33 N 547919.85 E 85.68 $ 3518.74 W 6009349.44 N 547827.45 E 88.85 S 3610.30 W 6009345.63 N 547735.90 E 90.17 S 3703.43 W 6009343.67 N 547642.79 E 91.64 S 3796.70 W 6009341.57 N 547549.53 E 92.37 $ 3888.94 W 6009340.20 N 547457.30 E 92.47 S 3981.35 W 6009339.46 N 547364.89 E Dogleg Rate (°/100fi) 0.552 0.467 1.651 3.585 3.167 2.427 3.719 2.134 2.201 0.404 0.187 2.713 0.603 0.403 3.006 2.673 0.107 0.433 1.147 1.561 1.063 0.624 1.743 0.552 2.881 2.626 0.594 0.338 2.305 1.050 Alaska Drilling & Wells Milne Point MPI Vertical Section Comment 1298.65 1389.90 1481.77 1572.92 1664.94 1757.07 1850.56 1942.46 2036.48 2129.92 2223.46 2317.24 2409.19 2502.13 2594.86 2687.89 2778.85 2872.48 2965.08 3057.60 3149.51 3242.85 -3335.9O 3427.18 3519.77 3611.38 3704.51 3797.79 3890.02 3982.42 28 August, 2001 - 5:45 Page 3 of 7 DrillQuest 2.00. 08.005 Sperry-Sun Drilling Services Survey Report for MPI-13 Your Ref: AP!500292301200 Job No. AKZZ11130, Surveyed: 7 August, 2001 Milne Point Unit Measured Depth Incl. Azlm. 5749.60 77.610 269.110 5845.30 77.360 268.320 5938.87 77.410 267.750 6035.16 78.050 266.990 6139.49 76.640 267.280 Sub-Sea Depth (~t) 2679.60 2700.34 2720.78 2741.24 2764.10 Vertical Depth (fi) 2743.72 2764.46 2784.90 2805.36 2828.22 6235.68 75.630 266.920 2787.15 2851.27 6328.81 75.390 267.180 2810.45 2874.57 6424.78 74.440 267.900 2835.43 2899.55 6519.33 78.050 267.350 2857.90 2922.02 6612.71 80.550 267.850 2875.24 2939.36 6706.33 80.230 267.860 2890.87 2954.99 6801.09 80.110 267.680 2907.05 2971.17 6894.66 80.620 267.970 2922.71 2986.83 6987.97 81.230 268.040 2937.43 3001.55 7082.65 80.980 268.250 2952.07 3016.19 7175.07 81.600 268.540 2966.06 3030.18 7271.43 82.220 268.590 2979.62 3043.74 7364.87 82.100 268.710 2992.37 3056.49 7458.61 82.530 269.240 3004.90 3069.02 7552.22 82.420 268.730 3017.16 3081.28 7645.67 81.040 267.890 3030.60 3094.72 7739.23 80.740 267.590 3045.42 3109.54 7831.42 80.480 266.860 3060.46 3124.58 7927.02 81.040 267.050 3075.81 3139.93 8021.39 79.730 268.640 3091.57 3155.69 8116.02 79.230 268.060 8209.86 78.930 266.580 8302.59 78.790 266.570 8396.59 78.170 266.220 8490.26 78.350 266.080 3108.85 3126.63 3144.54 3163.32 3182.38 3172.97 3190.75 3208.66 3227.44 3246.50 Local Coordinates Global Coordinates Northings Eastlngs Northings Eastings (ft) (ft) (fi) (ft) 93.34 S 4072.49W 6009337.96 N 547273.76E 95.44S 4165.89W 6009335.23 N 547180.37 E 98.57 S 4257.15W 6009331.47 N 547089.14 E 102.88 S 4351.14W 6009326.50 N 546995.18 E 107.97 S 4452.81W 6009320.71N 546893.55 E 112.70 S 4546.07W 6009315.35 N 546800.32 E 117.34 S 4636.12W 6009310.09 N 546710.31 E 121.32 S 4728.70W 6009305.47 N 546617.76 E 125.12 $ 4820.44W 6009301.03 N 546526.04 E 128.97 S 4912.11W 6009296.56 N 546434.40 E 132.42 S 5004.35W 6009292.47 N 546342.19 E 136.05 S 5097.65W 6009288.19 N 546248.92 E 139.55 S 5189,83W 6009284.06N 546156.76 E 142.76 S 5281.92W 6009280.22 N 546064.70 E 145.79 $ 5375.41W 6009276.55 N 545971.23 E 148.35 S 5466.73 W 6009273.36 N 545879.93 E 150.74 S 5562.10 W 6009270.31 N 545784.58 E 152.92 S 5654.64 W 6009267.50 N 545692.06 E 154.58 S 5747.52 W 6009265.19 N 545599.19 E 156.22 S 5840.31 W 6009262.91 N 545506.41 E 158.95 S 5932.75 W 6009259.55 N 545414.00 E 162.59 S 6025.05 W 6009255.27 N 545321.72 E 167.00 S 6115.90 W 6009250.24 N 545230.90 E 172.01 $ 6210.13 W 6009244.58 N 545136.71 E 175.51 S 6303.10 W 6009240.44 N 545043.77 E 178.19 S 6396.10 W 6009237.12 N 544950.79 E 182.50 S 6488.14 W 6009232.18 N 544858.78 E 187.93 S 6578.96 W 6009226.12 N 544768.00 E 193.72 $ 6670.88 W 6009219.70 N 544676.12 E 199.88 S 6762,38 W 6009212.91 N 544584.66 E Dogleg Rate (°/100fi) 3.047 0.847 0.597 1.o18 1.378 1.111 0.373 1.227 3.860 2.728 0.342 0.226 0.625 0.658 -0.343 O.739 0.645 0.181 0.724 0.553 1.724 0.451 0.831 0.618 2.165 0.801 1.581 0.151 0.754 0.242 Alaska Drilling & Wells Milne Point MPI Vertical Section Comment 4073.56 4166.98 4258.29 4352.35 4454.1o 4547.45 4637.58 4730.22 4822.02 4913.75 5006.04 5099.40 5191.64 5283.77 5377.31 5468.66 5564.06 5656.62 5749.52 5842.32 5934.80 6027.16 6118.08 6212.39 6305.42 6398.46 6490.57 6581.48 6673.51 6765.13 28 August, 2001 - 5:45 Page 4 of 7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPI-13 Your Reh API500292301200 Job No. AKZZ11130, Surveyed: 7August, 2001 Milne Point Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (fi) 8576.08 78.920 265.250 3199.29 3263.41 8679.44 79.740 264.750 3218.42 3282.54 8773.71 78.040 267.500 3236.59 3300.71 8865.86 78.860 267.870 3255.04 3319.16 8958.79 78.740 266.410 3273.09 3337.21 9056.21 77.230 266.220 3293.37 3357.49 9147.08 75.320 266.610 3314.93 3379.05 9210.18 76.470 267.780 3330.31 3394.43 9313.99 78.170 268.710 3353.10 3417.22 9401.37 78.040 268.610 3371.11 3435.23 9496.19 77.480 269.200 3391.21 3455.33 9593.15 77.420 268.600 3412.28 3476.40 9689.05 80.110 268.880 3430.96 3495.08 9783.18 80.480 268.540 3446.83 3510.95 9876.70 80.360 269.770 3462.39 3526.51 9902.43 80.980 270.590 3466.56 3530.68 9992.73 83.280 271.880 3478.93 3543.05 10080.77 82.970 270.930 3489.47 3553.59 10169.72 83.530 270.880 3499.92 3564.04 10260.20 83.900 270.500 3509.83 3573.95 10349.73 83.590 269.610 3519.58 3583.70 10440.49 83.410 268.880 3529.86 3593.98 10531.87 82.160 271.350 3541.34 3605.46 10627.87 81.730 270.220 3554.79 3618.91 10721.87 81.730 270.410 3568.31 3632.43 10815.23 83.530 272.220 3580.29 3644.41 10907.88 81.730 272.790 3592.17 3656.29 11002.76 82.100 272.050 3605.51 3669.63 11096.94 79.420 271.470 3620.63 3684.75 11190.86 78.540 270.670 3638.59 3702.71 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (~) (~) (~) (~) 206.24 S 6846.28W 6009205.97 N 544500.81 E 215.09 S 6947.47W 6009196.42 N 544399.69E 221.35S 7039.74W 6009189.53 N 544307.46 E 225.00 S 7129.95W 6009185.26 N 544217.27 E 229.54 S 7221.00W 6009180.09 N 544126.26 E 235.67 S 7316.08W 6009173.31N 544031.22 E 241.19 S 7404.18W 6009167.18 N 543943.16 E 244.18 S 7465.30W 6009163.77N 543882.06 E 247.28 S 7566.53W 6009159.97 N 543780.86 E 249.28 S 7652.01W 6009157.38 N 543695.40 E 251.05 S 7744.66 W 6009154.98 N 543602.77 E 252.87 S 7839.28 W 6009152.51 N 543508.16 E 254,94 S 7933.31 W 6009149.79 N 543414.14 E 257.02 S 8026.07 W 6009147.06 N 543321.40 E 258.38 S 8118.28 W 6009145.07 N 543229.21 E 258.30 S 8143.66W 6009144.98 N 543203.82 E 256.37 S 8233.09W 6009146.29 N 543114.38 E 254.23 S 8320.46W 6009147.83 N 543026.99 E 252.84S 8408.79W 6009148.62 N 542938.66 E 251.75S 8498.72W 6009149.08 N 542848.73E 251.67 S 8587.71W 6009148.56 N 542759.73 E 252.86 S 8677.88W 6009146.75N 542669.58 E 252.68 S 8768.53W 6009146.30 N 542578.93 E 251.37 S 8863.57W 6009146.95 N 542483.88 E 250.86 S 8956.59W 6009146.82 N 542390.86 E 248.73 S 9049.15W 6009148.31N 542298.29 E 244.72 S 9140.94W 6009151.69 N 542206.47 E 240.75S 9234.79W 6009155.01N 542112.59 E 237.90 S 9327.70W 6009157.23 N 542019.67 E 236.17 S 9419.87W 6009158.32 N 541927.49 E Dogleg Rate (onooft) 1.158 0.925 3.383 0.973 1.547 1.562 2.143 2.560 1.856 0.186 0.848 0.607 2.820 0.530 1.303 3.962 2.914 1.128 0.632 0.584 1.047 0.823 3.010 1.249 0.200 2.723 2.036 0.865 2.910 1.256 Alaska Drilling & Wells Milne Point MPI Vertical Section Comment 6849.14 6950.49 7042.89 7133.15 7224.27 7319.47 7407.67 7468.84 7570.11 7655.61 7748.28 7842.92 7936.97 8029.75 8121.97 8147.35 8236.71 8324.02 8412.29 8502.17 8591.15 8681.32 8771.94 8866.93 8959.92 9052.41 9144.09 9237.84 9330.66 9422.77 28 August, 2001 - 5:45 Page 5 of 7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPI-13 Your Ref: API500292301200 Job No. AKZZ11130, Surveyed: 7 August, 2001 Milne Point Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 11285.02 79.110 269.490 3656.84 3720.96 236.05 S 9512.24 W 6009157.81 N 541835.12 E 11379.15 79.800 269.220 3674.06 3738.18 237.09 S 9604.77 W 6009156.13 N 541742.60 E 11418.00 79.800 269.220 3680.94 3745.06 237.61 S 9643.01 W 6009155.35 N 541704.37 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. Magnetic Declination at Surface is 26.188° (26-Jul-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 268,760" (True), Based upon Minimum Curvature type calculations, at a Measured Depth of 11418.00ft., The Bottom Hole Displacement is 9645.93ft., in the Direction of 268.588° (True). Dogleg Rate (°/100ft) 1.370 O.785 0.000 Alaska Drilling & Wells Milne Point MPI Vertical Section Comment 9515.12 9607.66 9645.89 Projected Survey Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 11418.00 3745.06 237.61 S 9643.01W Comment Projected Survey 28 August, 2001 - 5:45 Page 6 of 7 DrillQuest 2.00.08. 005 Sperry-Sun Drilling Services Survey Report for MPI-13 Your Ref: API500292301200 Job No. AK2~11130, Surveyed: 7 August, 2001 Milne Point Unit Alaska Drilling & Wells Milne Point MPI Survey tool program for MPI-13 From To Measured Vertical Measured Depth Depth Depth (fi) (ft) (ft) 0.00 0.00 11418.00 Vertical Depth (ft) 3745.06 Survey Tool Description AK-6 BP_IFR-AK 28 August, 2001 - 5:45 Page 7of7 DrillQuest 2.00.08.005 Milne Point Unit Alaska Drilling & Wells Milne Point MPI, Slot MPI-13 MPI- 13 M WD Job No. AKMM11130, Surveyed: 7 August, 2001 SURVEY REPORT 5 September, 2001 Your Reft API500292301200 Surface Coordinates: 6009459.34 N, 551345.51 E (70° 26' 11.7450" N, 149° 34' 52.9338" W) Kelly Bushing: 64.12ft above Mean Sea Level ~) R'i L'L I N G S IERV I C iE'~ A Halliburton Company Survey Ref: svy9916 Sperry-Sun Drilling Services Survey Report for MPI-13 MWD Your Ref: API500292301200 Job No. AKMM11130, Surveyed: 7 August, 2001 Milne Point Unit Measured Depth Incl. Azim. 0.00 0.000 0.000 230.69 0.740 20.420 315.21 0.800 344.860 405.04 1.280 297.240 495.74 1.730 289.830 584.69 4.180 263.140 678.26 5.170 260.410 771.66 7.340 264.130 864.76 8.110 267.930 958.59 9.990 267.590 1053.70 12.290 269.920 1148.72 16.300 272.070 1242.94 21.800 271.510 1337.33 22.410 271.740 1431.49 22.950 271.430 Sub-Sea Depth (ft) -64.12 166.56 251.08 340.89 431.56 520.39 613.65 706.49 798.74 891.40 984.71 1076.77 1165.80 1253.25 1340.13 Vertical Depth (fi) 0.00 230.68 315.20 405.01 495.68 584.51 677.77 770.61 862.86 955.52 1048.83 1140.89 1229.92 1317.37 1404.25 1525.26 24.680 270.220 1425.91 1490.03 1619.00 28.950 270.190 1509.55 1573.67 1711.80 29.400 269.620 1590.58 1654.70 1806.45 30.980 269.530 1672.39 1736.51 1901.36 33.800 268.190 1752.52 1816.64 1994.81 40.020 268.920 1827.21 1891.33 2087.39 44.580 269.590 1895.67 1959.79 2182.24 49.780 268.890 1960.11 2024.23 2275.91 55.640 268.570 2016.84 2080.96 2369.62 61.060 269.080 2065.99 2130.11 2463.20 66.670 268.510 2556.14 71.650 268.330 2650.62 77.530 266.930 2744.90 77.480 268.050 2838.90 76.520 267.360 2107.20 2140.25 2165.35 2185.75 22O6.89 2171.32 2204.37 2229.47 2249.87 2271.01 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft)- (ft) 0.00 N 0.00 E 6009459.34 N 551345.51 E 1.40 N 0.52 E 6009460.74 N 551346.02 E 2.48 N 0.56 E 6009461.82 N 551346.05 E 3.54 N 0.50 W 6009462.88 N 551344.99 E 4.47 N 2.69 W 6009463.79 N 551342.79 E 4.54 N 7.17W 6009463.83N 551338.31 E 3.43N 14.71W 6009462.67 N 551330.77E 2.12 N 24.80W 6009461.29 N 551320.70E 1.27 N 37.28W 6009460.35 N 551308.22 E 0.69 N 52.03W 6009459.67 N 551293.48 E 0.33 N 70.39 W 6009459.18 N 551275.12 E 0.80 N 93.84 W 6009459.49 N 551251.67 E 1.74 N 124.57 W 6009460.22 N 551220.93 E 2.74 N 160.07 W 6009460.98 N 551185.42 E 3.75 N 196.36 W 6009461.74 N 551149.12 E 4.28 N 234.22W 6009462.01 N 551111.27 E 4.43 N 276.50W 6009461.87 N 551068.99 E 4.35 N 321.74W 6009461.48 N 551023.75 E 4.00 N 369.33W 6009460.80 N 550976.16 E 2.96 N 420.15W 6009459.41N 550925.35 E 1.58 N 476.23W 6009457.64N 550869.28 E 0.78 N 538.51W 6009456.41 N 550807.00E 0.16 S 608.05W 6009455.00N 550737.47 E 1.82 S 682.53W 6009452.82 N 550663.01E 3.44S 762.25W 6009450.65 N 550583.30 E 5.22 S 846.21W 6009448.30 N 550499.36 E 7.61S 933.01W 6009445.30 N 550412.57 E 11.40 S 1023.97W 6009440.90 N 550321.64E 15.43S 1115.93W 6009436.23 N 550229.71 E 19.09 S 1207.44W 6009431.93 N 550138.23 E Dogleg Rate (°/100ft) 0.321 0.560 1.055 0.540 3.088 1.084 2.362 0.992 2.004 2.464 4.256 5.841 0.653 0.587 1.917 4.555 0.570 1.670 3.066 6.672 4.949 5.509 6.262 5.802 6.020 5.361 6.385 1.161 1.247 Alaska Drilling & Wells Milne Point MPI Vertical Section Comment 0.00 -0.55 -0.61 0.42 2.59 7.07 14.64 24.75 37.24 52.00 70.37 93.80 124.50 159.98 196.24 234.07 276.34 321.57 369.16 419.99 476.08 538.37 607.92 682.40 762.15 846.13 932.96 1023.98 1116.00 1207.57 MWD Magnetic 5 September, 2001 - 12:19 Page 2 of 7 Dr#/Quest 2. 00. 08.005 Sperry-Sun Drilling Services Survey Report for MPI-13 MWD Your Ref: API500292301200 Job No. AKMM11130, Surveyed: 7 August, 2001 Milne Point Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 2932.67 76.080 266.030 2229.10 2293.22 3026.82 75.640 265.740 2252.10 2316.22 3121.44 76.840 267.640 2274.61 2338.73 3214.48 80.100 268.140 2293.20 2357.32 3308.34 77.280 268.580 2311.61 2375.73 3402.82 77.340 271.350 2332.37 2396.49 3498.28 80.730 272.060 2350.52 2414.64 3591.47 82.590 274.370 2364.04 2428.16 3686.41 84.640 272.760 2374.60 2438.72 3780.59 84.270 272.730 2383.70 2447.82 3874.89 84.390 273.440 2393.02 2457.14 3969.47 82.590 271.980 2403.74 2467.86 4062.31 82.350 272.900 2415.91 2480.03 4156.11 82.720 273.070 2428.09 2492.21 4249.72 81.790 271.360 2440.71 2504.83 4343.83 81.230 266.840 2454.61 2518.73 4435.99 81.160 266.270 2468.72 2532.84 4530.82 81.530 266.210 2482.99 2547.11 4624.52 82.160 265.000 2496.28 2560.40 4718.30 80.740 264.420 2510.22 2574.34 4811.52 81.730 264.870 2524.43 2588.55 4906.08 81.980 264.390 2537.82 2601.94 5000.51 80.410 264.680 2552.28 2616.40 5093.34 80.410 265.020 2567.74 ' 2631.86 5187.51 79.670 266.540 2584.03 2648.15 5280.53 80.480 269.360 2600.07 2664.19 5374.89 81.040 267.810 2615.22 2679.34 5469.29 81.290 267.230 2629.72 2693.84 5562.86 79.420 269.280 2645.40 2709.52 5656.73 80.360 268.650 2661.87 2725.99 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 24.34 S 1298.39W 6009426.06N 550047.32 E 30.90 S 1389.45W 6009418.88 N 549956,30 E 36.20 S 1481.20W 6009412.95 N 549864.59 E 39.55 S 1572.29W 6009408.97 N 549773.53 E 42.19 S 1664.28W 6009405.70 N 549681.56 E 42.24 S 1756.44W 6009405.01 N 549589.40 E 39.45 S 1850.10W 6009407.15 N 549495.72 E 34.28 S 1942.15W 6009411.69 N 549403.64 E 28.41S 2036.31W 6009416.91 N 549309.44 E 23.92 S 2129.94W 6009420.75 N 549215.78 E 18.87 S 2223.64W 6009425.16 N 549122.05 E 14.43 S 2317.50W 6009428.96 N 549028.16 E 10.51S 2409.46W 6009432.24 N 548936.18 E 5.67 $ 2502.34W 6009436.45 N 548843.27 E 2.08 $ 2595.02W 6009439.39 N 548750.57 E 3.54 S 2688.06 W 6009437.29 N 548657.54 E 9.01 S 2778.97 W 6009431.20 N 548566.67 E 15.16 S 2872.52 W 6009424.40 N 548473.17 E 22.27 S 2964.99 W 6009416.66 N 548380.74 E 30.82 $ 3057.33 W 6009407.47 N 548288.46 E 39.42 S 3149,06W 6009398.25 N 548196.79 E 48.18 S 3242.26W 6009388.84N 548103.66 E 57.06S 3335.15W 6009379.32 N 548010.83 E 65.28 $ 3426.31W 6009370.47 N 547919.73E 72.11 S 3518.81W 6009363.01 N 547827.28 E 75.38 S 3610.36 W 6009359.11 N 547735.75 E 77.68 S 3703.47 W 6009356.16 N 547642.66 E 81.72 S 3796.66 W 6009351.49 N 547549.50 E 84.53 S 3888.86 W 6009348.04 N 547457.33 E 86.20 S 3981.25 W 6009345.73 N 547364.95 E Dogleg Rate (°/100ft) 1.456 0.555 2.326 3.543 3.039 2.861 3.625 3.162 2.739 0.394 0.760 2.444 1.016 0.433 2.065 4.787 0.616 0.395 1.444 1.633 1.164 0.568 1.690 0.361 1.773 3.111 1.727 0.662 2.943 1.200 Alaska Drilling & Wells Milne Point MPI Vertical Section Comment 1298.62 1389.80 1481.64 1572.78 1664.80 1756.94 1850.52 1942.44 2036.45 2129.96 2223.53 2317.27 2409.12 2501.87 2594.46 2687.51 2778.51 2872.17 2964.78 3057.29 3149.18 3242.54 3335.60 3426.92 3519.54 3611.15 3704.28 3797.54 3889.77 3982.18 5 September, 2001 - 12:19 Page 3 of 7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPI-13 MWD Your Ref: API500292301200 Job No. AKMM11130, Surveyed: 7August, 2001 Milne Point Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (f~) (ft) (ft) 5749.60 77.610 268.660 2679.62 2743.74 5845.30 77.360 267.930 2700.35 2764.47 5938.87 77.410 266.310 2720.79 2784.91 6035.16 78.050 266.150 2741.25 2805.37 6139.49 76.640 264,570 2764.11 2828.23 6235.68 75.630 266,020 2787.16 2851.28 6328.81 75.390 266.480 2810.47 2874.59 6424.78 74.440 267.580 2835.44 2899.56 6519.33 78.050 266.760 2857.92 2922.04 6612.71 80.550 268.150 2875.26 2939.38 6706.33 80,230 268.170 2890.89 2955.01 6801.09 80.110 268,290 2907.06 2971.18 6894.66 80.620 268.540 2922.72 2986.84 6987.97 81.230 268.070 2937.44 3001.56 7082.65 80,980 268.380 2952.08 3016.20 7175.07 81.600 268.820 2966.08 3030.20 7271.43 82.220 269.700 2979.64 3043.76 7364.87 82.100 268.400 2992.38 3056.50 7458.61 82.530 270.370 3004.92 3069.04 7552.22 82.420 269,830 3017.18 3081.30 7645,67 81.040 266.930 3030.62 3094.74 7739.23 80.740 267.390 3045.44 3109.56 7831.42 80.480 267.260 3060.48 3124.60 7927.02 81.040 266.710 3075.83 3139.95 8021.39 79.730 266.210 3091.59 3155.71 8116.02 79.230 265.870 3108.87 3172.99 8209,86 78.930 264.610 3126.65 3190.77 8302.59 78.790 266.010 3144.56 3208.68 8396.59 78.170 266.020 3163.34 3227.46 8490,26 78.350 265.830 3182.40 3246.52 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 88.34 S 4072.38 W 6009342.96 N 547273.84 E 91.12 S 4165.76 W 6009339.54 N 547180.48 E 95.71 S 4256.95 W 6009334.33 N 547089.32 E 101.89 S 4350.84 W 6009327.49 N 546995.48 E 110.12 S 4452.30 W 6009318.57 N 546894.08 E 117.79 S 4545.36 W 6009310.26 N 546801.06 E 123.68 S 4635.34 W 6009303.75 N 546711.13 E 128.49 S 4727.87 W 6009298.31 N 546618.63 E 133.03 $ 4819.58 W 6009293.14 N 546526.96 E 137.10 $ 4911.24 W 6009288.44 N 546435.33 E 140.06 S 5003.50 W 6009284.84 N 546343.09 E 142.94 S 5096.82 W 6009281.31 N 546249.79 E 145.49 S 5189.04 W 6009278.12 N 546157.60 E 148.22 $ 5281.14 W 6009274.76 N 546065.52 E 151.12 S 5374.63 W 6009271.22 N 545972.04 E 153.35 S 5465.96 W 6009268.36 N 545880.73 E 154.58 S 5561.35 W 6009266.47 N 545785.35 E 156.12 $ 5653.90 W 6009264.30 N 545692.81 E 157.11 S 5746.79 W 6009262.67 N 545599.94 E 156.95 $ 5839.60 W 6009262.19 N 545507.13 E 159.56 S 5932.02 W 6009258.94 N 545414.72 E 164.14 S 6024.29 W 6009253.73 N 545322.49 E 168.38 $ 6115.15 W 6009248.86 N 545231.67 E 173.35 S 6209.37 W 6009243.25 N 545137.48 E 179.09 S 6302.24 W 6009236.87 N 545044.65 E 185.51 S 6395.06 W 6009229.80 N 544951.88 E 193.16 S 6486.88 W 6009221.52 N 544860.12 E 200.60 S 6577.55 W 6009213.46 N 544769.49 E 207.00 S 6669.44 W 6009206.43 N 544677.66 E 213.52 $ 6760.91 W 6009199.28 N 544586.23 E Dogleg Rate (°/100ft) 2.961 0.789 1.690 O.684 2,002 1.801 0.543 1.485 3.910 3.051 0.342 0.178 0.605 0.821 0.418 0.819 1.110 1.384 2.133 0.584 3.408 0.582 0.314 0.816 1.483 0.636 1.357 1,489 0.660 0.276 Alaska Drilling & Wells Milne Point MPI Vertical Section Comment 4O73.33 4166.76 4258.03 4352.O3 4453.64 4546.85 4636.93 4729.55 4821.33 4913.06 5005.36 5O98.72 5190.97 5283.11 5376.65 5468.00 5563.40 5655.96 5748.85 5841.62 5934.09 6026.43 6117.36 6211.67 6304.64 6397.57 6489.54 6580.35 6672.35 6763.95 5 September, 2001 - 12:19 Page 4 of 7 DrillQuest Z00,08,005 Sperry-Sun Drilling Services Survey Report for MPI-13 MWD Your Ref: AP!500292301200 Job No. AKMM11130, Surveyed: 7August, 2001 Milne Point Unit Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 8576.08 78.920 264.990 3199.31 3263.43 8679.44 79.740 264.230 3218.45 3282.57 8773.71 78.040 266.470 3236.61 3300.73 8865.86 78.860 267.890 3255.06 3319.18 8958.79 78.740 266.990 3273.11 3337.23 3293.39 3314.96 3330,33 3353.12 3371.13 9056.21 77.230 265.540 9147.08 75.320 267.810 9210.18 76.470 267.170 9313.99 78.170 269.150 9401.37 78.040 267.360 3357.51 3379,08 3394.45 3417.24 3435.25 9496.19 77.480 267.500 3391.24 3455.36 9593.15 77.420 268.880 3412.31 3476.43 9689.05 80.110 266.960 3430.99 3495.11 9783.18 80.480 261.970 3446.87 3510.99 9876.70 80.360 268.930 3462.45 3526.57 9902.43 80.980 271,130 3466.62 3530.74 9992.73 83.280 274.420 3478.99 3543.11 10080.77 82.970 271.070 3489.53 3553.65 10169.72 83,530 272.300 3499.99 3564.11 10260.20 83.900 272.000 3509.89 3574.01 10349.73 83.590 269.080 3519.65 3583.77 10440.49 83.410 265,680 3529.92 3594.04 10531.87 82.160 269.240 3541.40 3605.52 10627.87 81.730 268.240 3554.86 3618.98 10721.87 81.730 269.320 3568.38 3632.50 10815.23 83.530 270.240 3580.35 3644.47 10907.88 81.730 270.880 3592.24 3656.36 11002.76 82.100 270.330 3605.58 3669.70 11096.94 79.420 269.560 3620.70 3684.82 11190.86 78.540 270.120 3638.66 3702,78 Local Coordinates Global Coordinates Northings Eastings Northlngs Eastings (ft) (ft) (ft) (ft) 220.25 S 6844.78 W 6009191.97 N 544502.41 E 229.79 S 6945.90 W 6009181.73 N 544401.35 E 237.30 S 7038.09 W 6009173.59 N 544309.22 E 241.74 S 7128.26 W 6009168.53 N 544219.08 E 245.81 $ 7219.33 W 6009163.84 N 544128.04 E 252.01S 7314.41W 6009156.98 N 544033.01E 257.14 S 7402.52W 6009151.24 N 543944.93 E 259.82 $ 7463.66W 6009148.14 N 543883.81E 263.06 S 7564.88W 6009144.20 N 543782.62 E 265.67 $ 7650.34W 6009141,01 N 543697.18 E 269.82 S 7742.91 W 6009136.22 N 543604.64 E 272.81 S 7837.50 W 6009132,58 N 543510.07 E 276.23 $ 7931.49 W 6009128.51 N 543416.11 E 285.18 $ 8023.81 W 6009118.92 N 543323,85 E 292.49 S 8115.67 W 6009110.98 N 543232.04 E 292.48 S 8141.06W 6009110.82 N 543206.65 E 288.14 S 8230.39W 6009114.54 N 543117.30 E 283.96 S 8317.68W 6009118.13 N 543029.98 E 281.36 S 8405.97W 6009120.12 N 542941.67 E 277.98 S 8495.65W 6009122.87 N 542851.78 E 277.15 S 8584,83 W 6009123.10 N 542762.79 E 281.27 S 8674.90 W 6009118.36 N 542672.75 E 285.29 $ 8765.45 W 6009113.71 N 542582.23 E 287.38 S 8860.48 W 6009110.97 N 542487.22 E 289.36 S 8953.48 W 6009108.35 N 542394.24 E 289.71 S 9046.06W 6009107.36 N 542301.66 E 288.81S 9137.94W 6009107.62 N 542209.78 E 287.82 S 9231.87W 6009107.97N 542115.84 E 287.91 $ 9324.82W 6009107.24 N 542022.90E 288.17 S 9417.00W 6009106.35 N 541930.71E Dogleg Rate (°/100ft) 1.167 1.073 2.948 1.752 0.959 2.126 3.210 2.071 2.479 2.010 0.608 1.391 3.424 5.240 7.339 8,775 4.417 3.794 1.511 0.525 3.260 3.727 4.100 1.124 1.137 2.162 2.060 0.694 2.958 1.105 Alaska Drilling & Wells Milne Point MPI Vertical Section Comment 6847.94 6949.25 7041.58 7131.82 7222.96 7318.15 7406.36 7467.54 7568.80 7654.30 7746.94 7841.57 7935.61 8028.1o 8120.10 8145.49 8234.70 8321.88 8410.10 8499.87 8588.82 8678.95 8769.57 8864.62 8957.64 9050.21 9142.05 9235.94 9328.86 9421.03 5 September, 2001 - 12:19 PageSof7 DrillQuest 2. 00.08.005 Sperry-Sun Drilling Services Survey Report for MPI-13 MWD - Your Reft AP!500292301200 Job No. AKMM11130, Surveyed: 7 August, 2001 Milne Point Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (fi) Local Coordinates Global Coordinates Northlngs Eastinga Northinga Eastings (ft) (ft) (fi) (ft) 11285.02 79.110 268.010 3656.91 3721.03 289.68 S 9509.36 W 6009104.20 N 541838.37 E 11379.15 79.800 268.900 3674.13 3738.25 292.17 S 9601.87 W 6009101.07 N 541745.88 E 11418.00 79.800 268.900 3681.01 3745.13 292.90 S 9640.09 W 6009100.07 N 541707.66 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. Magnetic Declination at Surface is 26.187° (26-Jul-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 268.760° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11418.00ft., The Bottom Hole Displacement is 9644.54ft., in the Direction of 268.260° (True). Dogleg Rate (°/100ft) Alaska Drilling & Wells Milne Point MPI Vertical Section Comment 2.280 9513.40 1.184 9605.94 0.000 9644.18 Projected Survey Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 11418.00 3745.13 292.90 S 9640.09W Comment Projected Survey 5 September, 2001 - 12:19 Page 6of7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPI-13 MWD Your Reft API500292301200 Job No. AKMM11130, Surveyed: 7 August, 2001 Milne Point Unit Alaska Drilling & Wells Milne Point MPI Survey tool program for MPI-13 MWD From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) 0.00 0.00 11418.00 Vertical Depth (ft) 3745.13 Survey Tool Description MWD Magnetic 5 September, 2001 - 12:19 Page 7 of 7 DrillQuest 2.00. 08.005 WELL LOG TRANSMITTAL To: State of Alaska February 19, 2002 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs MPI-13, AK-MM- 11130 1 LIS formatted Disc with verification listing. API#: 50-029-23012-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99648 BP iExploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: RECEIVED FEB 2 E 2002 Alaska Oil & Gas Cons. Commission Anchorage 9/12/2001 GeoQuest 3940 Arctic BIvd Anchorage, AK 99503 ATTN: Sherrie NO. 1438 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Milne Point (Cased Hole) Well Job # Log Description Date Color Sepia BL MPI-13 2t389 SCMT 08/27/01 2 MPI-13 GR COLLAR W/PRESS/TEMPIDEV 08/27/01 I '1 i I I I I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: RECEIVED SEP 1 4 2001 Alaska Oil & Gas Cons. Commission Anchor~e Schlumberger GeoQuest 3940 Arctic BIvd Anchorage, AK 99503 ATTN: Sherde 23-Aug-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPI-13 Dear Dear Sir/Madam: Enclosed are two survey hard copies and I disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 'MD 11,418.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED SEP 0 7 2.001 Alaska 0il & Gas Cons. Commis,~ion Anchorage 23-Aug-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPI-13 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 'MD 11,418.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ['?' STATE OF ALASKA ~(', ALASKA oIL AND GAS CONSERVATION COM,v,,~SION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Vadance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate '2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2346' NSL, 1253' EWL, SEC. 33, T13N, R10E (As Planned) At top of productive interval 2216' NSL, 641' EWL, SEC. 32, T13N, R10E (As Planned) At effective depth N/A At total depth 2128' NSL, 2119' EWL, SEC. 31, T13N, R10E (As Planned) 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) Planned RKB = 64' 7. Unit or Property Name Milne Point Unit 8. Well Number MPI-13i 9. Permit Number 201-075 10. APl Number 50- 029-23012-00 11. Field and Pool Milne Point Unit / Schrader Bluff 12. Present well condition summary Total depth: measured 11418 feet true vertical 3745 feet Effective depth: measured feet true vertical feet Casing Length Structural Conductor Surface Intermediate Production Liner 80' Size 20" Plugs (measured) Junk (measured) Cemented MD TVD 260 sx Arctic Set (Approx) 112' 112' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) RECEIVED AUG 13 2001 ~laska Oil & Gas CONS. C0fftmJssior Anchorage 13. Attachments [] Description Summary of Proposal [] Detailed Operations Program [] BOP Sketch 14. Estimated date for commencing operation August 10, 2001 16. If proposal was verbally approved Jane Williamson Name of approver 8/10/2001 Date Approved Contact Engineer Name/Number: Steve Shultz, 564-5491 I15. Status of well classifications as: [] Oil [] Gas I-1 Suspended Service Water Injection Prepared By Name/Number: Sondra Stewman, 564-4750 17. I hereby certify that the/'0t¢~loing i~t~e arid correct to the best of my knowledge / / / Signed SteveShutz .~'-~ /~'\.~,, ~ Title Senior Drilling Engineer Date ........................ .......................... · ........ . .................... . ........ .../. .... ....: c°nditi°ns °f Appr°vah N°tify c°mmissi°n s° representative may witness Approval No. ~,~/~.r,~ ~ i Plug integrity BOP Test Location clearance I Mechanical Integrity Test Subsequent~ required ~ IApproved by order of the Commission ORIGINAL ~D [~',, , A , Commissioner Date Form 10-403 Rev. 06/15/88 J.M. I'~sjs~rI b t J~ A L. Submit Ir~Tripficate ADIII BP ALASKA gnlLUqe & w~us MIlne Point Unit MPI-13i Tail Alternate OptiCem 7 in Cement Production Casing Prepared for: James Franks August 10, 2001 Version 1.40 Prepared by: Eric Dompeling Halliburton Energy Services 6900 Arctic Blvd Anchorage, Alaska 907-275-2633 O~:~'~[LiBURToN The Future Is Working Together. mpi-13i 3 production.doc HALLIBURTON 2 Cement Recommendation 7"Surface/Production Casing MPI-13i Assumptions (TWO STAGE CEMENT ,lOB) 1. Bottom hole circulating temperature is +/- 65° F. (based on a BHST of 95° F at 3745' TVD) 2. The hole may be washed out to 30% excess over gauge hole from TD to 1774' md and 250% excess over gauge hole from 1775' md to surface. 3. Casing will be cemented in a two stages, TAM Port Collar located as contingency @ 2100', for two stage. Cement and Spacer Design First Stage Spacer 10 bbl 3 % KCL Water Spacer 70 bbls. Alpha Spacer (weighted to 12 ppg over mud weight, no viscosifier) Lead Cement NONE Tail Cement Premium Cement 0.2 % CFR-3 (Dispersant) 0.25 % HALAD 344 (Fluid Loss Control) Approx. Volume 1,262.5 sx (258.6 bbls) Density 15.8 ppg Yield 1.15 cuft/sack Water 5.0 gal/sack Fluid Loss (CC/30 min) 122 @ 68°F Thickening Time 3:50 + hrs @ 65°FBHCT Cement Volume Tail Cement (Tail Volume) 4170' of Open Hole + 30% excess+80' shoe joint., (Lead Volume = 0 Alaska Drilling and Wells MPI- 13i Tail Only 8/13/2001 HALLIBURTON 3 Cement Recommendation Surface Casing (2nd Stage) Preflush 25 bbls. of Alpha Spacer (weighted to 12.0 ppg over mud weight) Lead Cement) Type "L" Permafrost Cement2 gal Cement Dye in the 1st 5bbls Approx. Volume 234 sx ( 100 bbis) Density 11.1 ppg Yield 4.15 cu ft/sack Water 20.3 gal/sack Thickening Time 6+ hrs @ 50°F Tail Slurry None Cement Volume Permafrost Cement 1400' of Open Hole + 50% excess below permafrost + 250% excess to surface +casing capacity. RIH with 3 ¥2" drill pipe to float collar and change over to seawater Pull pipe to 2200 feet and freeze protect to surface with diesel POOH with drill pipe and lay down same NU wellhead and tree RDMO Alaska Drilling and Wells MPI-13i Tail Only 8/13/2001 Page 1 of 3 Stewman, Sondra D From: Shultz, Steve M Sent: Monday, August 13, 2001 2:16 PM To: Stewman, Sondra D Subject: FW: FW: Request for waiver - MPI-13i FYI ..... Original Mlessage ..... From: Jane Williamson [mailto:Jane_Williamson@admin.state.ak. us] Sent: Friday, August 10, 2001 8:56 PM To: Franks, James D; Shultz, Steve M Cc: Hiller, Hike E; AOGCC Prudhoe Bay (E-mail); Julie IVl Heusser; Thomas E Mlaunder Subject: Re: FW: Request for waiver- MtPT-13i Steve and James, In addition to your e-mail we have received your fax summarizing the results of your discussion with Tom Maunder. We understand and appreciate the need, first and foremost, to ensure continuing control of the MPU well I-13i drilling operations. We see a three step process as follows: Phase I: Bring well under control and eliminate flow. Case and cement the well as initially described in the e-mail below and further refined in your phone conversation with Tom Maunder. Your subsequent fax details the changes you discussed with Tom Maunder. You have AOGCC approval to proceed with your plans as outlined. A 10-403 summarizing these changes to the approved program needs to be received in the AOGCC office no later than the end of the work day, Monday, August 13. Phase II: BP investigation of the high pressure encountered and subsequent fluid influx. In addition BP intends to perform an assessment of the cementing operations via USIT or other appropriate means. The complete results of the investigation and cement assessment will provided to the AOGCC for their review prior to Phase III. Phase III: Discussion between BP and the AOGCC regarding the determination of ultimate fate of the well (i.e. will the well be approved by the AOGCC for injection service). Sincerely Jane Williamson AOGCC Engineer "Franks, James D" wrote: Jane, The more information you required. To answer your questions: 8/13/2001 Page 2 of 3 1. Can we place another port collar in the well at a deeper depth and circulate another cement stage? The answer to this one is unfortunately no. One reason for this is that we only have one port collar with threads cut for the Hydril 521. Another reason is that by the time we can run the drill pipe in to activate this, we fear that the gel strength of the mud would be too high and we may not be able to regain circulation. A third reason is that we cannot run two port collars in the well due to them being activated by drillpipe. 2. Can we use another port collar with a different thread type? Again the answer is unfortunately no. We need to be able to rotate the casing to TD to be able to get the casing into the ground. By adding another port collar, we will not be able to get the casing in the ground and will complicate things even further. 3. Can we lower the port collar to the base of the permafrost? The answer to this is that from previous experience we feel that the additional time required to activate the tool at the extra 1000' would again cause the mud to get cold and thicken up even faster than what we would experience in the answer to question 1. I hope this answers all the questions you had. Let me know if there is anything else. james ..... Original Message ..... From: Franks, James D Sent: Friday, August 10, 2001 4:26 PM To: 'j ane_williamson @ admin.state.ak.us' Cc: Shultz, Steve M; Miller, Mike E Subject: Request for waiver - MPI-13i Jane, Per the conversation on the phone a few minutes ago, here is the request to the AOGCC for a waiver for the cementing of the MPI-13i well. This waiver request is for the requirement of having cement in the surface hole from shoe to TD. While drilling the MPI-13i wellbore, we encountered a fault at around 8250' md. This fault caused us to lose about 40 bbls of mud, but nothing more than that. We continued to drill the well to TD not noticing any further losses. We came out of the hole on a trip for MWD. While we were running back in the hole, we found that the well was taking some fluid. 8/13/2001 The chlorides were increasing and therefore leads us to believe that the influx was due to water. There are a few possibilities for where the water is coming from - Ugnu sands, N Sands or fault. We had to increase the mud weight up to 11.1 ppg to control the influx. With the 11.1 ppg fluid the ECD is about 11.8 ppg and we are currently losing fluid at around 8 bph. As the formation shoe historically has shown a frac gradient of about 12.5 ppg and the permafrost an 11.8 ppg or less, we feel that it will not be possible to cement the well as described in the Permit to Drill (401). As shown in the drawing faxed to you this afternoon, we would like to receive a wavier for pumping the cement on the surface casing in 2 stages. The first stage is to be a slurry to develop compressive strengths rapidly, 15.8 to 15.9 ppg slurry as described in the Permit to Drill. The top of this cement will be at 7250' which is approximately 600' above the top of the Ugnu, the shallowest potential hydrocarbon bearing zone. The second stage will be pumped through a TAM port collar located at 1000' MD and will isolate the annulus at the surface - the lead slurry in the Permit to Drill. > > > > > > > > > > > > > > > > > Scope of work: * Run in the hole with the 7" casing * Circulate and condition the mud * Pump the 15.8 ppg slurry until we bump the plug - designed top of cement 7250' md * Pick up 1000' of 3.5" drillpipe with TAM opening tool * Run in the hole to activate the collar * Pump 10.7 ppg Permafrost L cement until we get returns to surface * Set the 7" casing slips and pull 100,000# over * Nipple up the x-mas tree * Rig down 27E and move off the well We are currently developing an investigation plan for finding the location of the water influx after the drilling rig moves off and prior to completion. Also, we will be running a bond log to determine the top of cement. > > > > > > As far as the completion goes, we will be setting the packer at 9900' md when we get the tubing run following our investigation. If you require more information, please give me a shout. > james > > James Franks > BP Alaska Drilling & Wells > office: 907-564-4468 > cell: 907-440-0187 Page 3 of 3 8/13/2001 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, Commissioner Tom Maunder, P. I. Supervisor FROM: John Crisp, SUBJECT: Petroleum Inspector DATE: August 11, 2001 Milne Point Unit 1-13 Schrader BlUff Well PTD 201'0750 Auaust. !..1,..20.01: I traveled to Nabors Rig 22E in BP's Milne Point Field to witness running casing & cementing of SB Well 1-13. BP requested a variance for a change in cementing procedures that were submitted to obtain their Permit to Drill for SB Well 1-13 due to abnormal formation pressures encountered on this well. The well is presently TD w/a MD of 11,418' ( 3,744 TVD). Past normal mud weights to control SB wells has been in the 9,5to 9i7 ~ppg~:range, Mud weight to control. MPU~SB M 3 is presently 11,1 ppg, NO Seconda~' :wel I c0ntrol :'equiPment.is being used on MPU I- 13, When I arrived on location on well MPU !-13 they were RIH w/7" casing to approximately 5700' MD attempting to establish circulation w/no success. ! witnessed POOH w/7" casing to approximately 5000' MD & attempt to establish circulation ( no success ). The hole was static with. or without attempting to circulate. Their plan was to POOH w/casing until they could circulatel SUMMARY: @ 0800 hrs. 8/13/01 Rig 22E on well MPU 1-13 is presently in the hole w/Hole Opener on Drill String circulating & conditioning mud to POOH & attempt to run 7" casing. Mud weight is 11.1 ppg. Attachments: none. CC; . NON-CONE!DENT,!AL Well Control MPU 1-13 8-11-Oljc.doc ALASKA OIL AND GAS CONSERVATION COPI~XISSION l/ TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Steve Shultz Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519 Re: Milne Point Unit BP Exploration (Alaska) Inc. Permit No: 201-075 Sur. Loc. 2346' NSL 1253' EWL, Sec. 33, T13N, R10E (As Planned) Btmhole Loc. 2128' NSL, 2119' EWL, Sec. 31, T13N, R10E Dear Mr. Shultz: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exemPt you from obtaining additional Permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other reqUired permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient. notice (approximately 24 hours) of the MI test before operation, and 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 tests. Notice may be given bY contacting the Commission petroleum field inspector on the North SloPe pager at 659-3607. Daniel T. Seamount, Jr. Commissioner BY ORDER OF. FtzTHE COMMISSION DATED this q'/"day of May, 2001 j jo/EnclOsures cc: Department offish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Re: Contingency well Subject: Re: Contingency well Date: Tue, 24 Apr 2001 09:46:28 -0700 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Franks, James 0" <FranksJD@BP.com> CC: "Shultz, Steve Mil <ShultzSM@BP.com> James and Steve, I appreciate the heads up on this. The procedure as I know it is... 1-..Drill MPI..13i (that is I and L isn't it) as planned. If successful, no problems. 2--lf MPI-13i is not successful, the successor well is MPI-13A. To get the ball rolling on that well, we would need a sundry (403) filed to P&A the unsuccessful weltbore and a new APD (401) to drill the sidetrack. 3--lf you are doing a multi-lateral, you will also need a permit for the lateral which would be known as MPI-13AL 1. ~() \ '-Ó't S- We can handle the sundry pretty easily, I can verbal if necessary and the paperwork can follow soon after. The 401 s present a little more difficulty. We can move relatively quickly, but 2 Commissioners have to review the program before it can be signed. The time crunch is really only on the A weltbore. It may be appropriate to have a permit application sitting and ready to go or even to file for a permit that if you don't need it, you can cancel it. It sounds like you have a lot of you contingency planning already done, likely including intended sidetrack depth, angles and TO. Discuss with Steve, I don't see a problem having the A permit already approved and then cancel it. That is likely the best thing to do for another reason...1 will be on vacation from June 20 to July 4, so the more unusual items we can clear off the board the better. Hope these thoughts help. One other thought, if the sidetrack(s) are going to be 'producers, having the "in designation might prove inconvenient. But then, maybe note. Give a call and we can talk. Tom "Franks, James D" wrote: > Tom, > > I apologize for not returning your calls, but / was in communication with > Steve Shultz and he was keeping me in the loop and I thought you were > probably busy enough to not answer the same questions twice.. > > I have a question that is not too important at this time, but might come up > in the future. We have a well that is permitted as MPI-13i scheduled to be > drilled in July. In this well there is a possibility that we might hit > water and if we do, we would like to plug the well back and sidetrack to a > different location we are calling MPI-X1 which is in a different fault block > and is 8 multilateral completion. I realize that we need to get a permit > for the new locations, but I was wondering about the best way and the most > efficient way to do this with respect to time 8S there might not be a lot of > time between determination and sidetrack. > > What do you think? 10f2 3116/026:20 AM . Re: Contingency well > > As I said, this is a little ways off, but I wanted to ask the question > early. > > Thanks for your time, > > james > > James Franks > BP Alaska Drilling & Wells > office: 907-564-4468 > cell: 907-440-0187 ITO~ Maunder <tom maunder(â¡admìn.state.ak.us> I Petroleum Engineer I -- Alaska Oil and Gas ~onservation Commission -- 20f2 3/16/02 6:20 AM , STATE OF ALASKA ~.. ALASKA 0 .,ND GAS CONSERVATION ~,,..,,v,,v,,oc..)N PERMIT TO DRILL 20 AAC 25.005 I [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [][] DrilIRe_Entry [][] DeepenRedrill lb. Type of well [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Planned RKB = 64' Milne Point Unit / Schrader 3. Address 6. Property Designation Bluff P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL025517 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 2O AAC 25.025) 2346' NSL, 1253' EWL, SEC. 33, T13N, R10E (As Planned) Milne Point Unit At top of productive interval 8. Well Number 2216' NSL, 641' EWL, SEC. 32, T13N, R10E MPI-13i Number 2S100302630-277 At total depth :9. Approximate spud date 2128' NSL, 2119' EWL, SEC. 31, T13N, R10E 07/01/2001 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025628, 2128' MDI No Close Approach 2560 11446' MD / 3754' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 700' MD Maximum Hole Angle 80 ° Maximum surface 1315 psig, At total depth (TVD) 3754' / 1688 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casin,q Wei,qht Grade Couplin.q Len,qth MD TVD MD TVD (include stare data) 30" 20" 92# H-40 Welded 80' 30' 30' 113' 113' 260 sx Arctic Set (Approx.) 9-7/8" 7" 26# L-80 HYD 521 10500' 30' 30' 11446' 3754' 1138 sx Arctic Set III, 494 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface ....... Intermediate ........ ~ .......... :" ~::,,.: '"":'::',, ':'~' .... ,!*I ' I,.=' ~ ',' Production '''/''' ".......'.: "!.': .......... " ~. '~,. Liner · Perforation depth: measured ) ...... t-~,~ I ', ~..t~ ",. true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Steve Shult.~, 564-5491~ Prepared By Name/Number: Sondra Stewman, 564-4750 21.1 hereby certify that the foregoi.~s true an(~.orre~Yto the best of my knowledge Signed Steve Shultz .... 4Z""'-~ ;..~'~~.U Title Senior Drilling Engineer Date y/Z¢/~'///'~ / 1 "' .' i"": ' :.:.i:..: :'::'.. :."..'.. ".:"ii. i." :"~'i~:, :,:'"'. :': ""? ::':"."~',.~~~°m:m'isS'ib,h' u:Se:iOh:lY': :;':':'~''''.: "'iSermit Number ........'I'A'"Pi·Numb;';"" '" ..... ' .... """'" '""""'" '1'"' Xi;~'0~/~'Date' '""1~ee'(~over letter .... I =- 3o/.z_ I~"'7U')/~ / If°r °ther requirements Conditions of Approval: Samples Required [] Yes ,~ No Mud Eog/R-" '-e~l~ired' [] Yes [] No Hydrogen Sulfide Measures ~ Yes [] No Directional Survey Required I~ Yes [] No Required Working Pressure for BOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K [] 3.5K psi for CTU Other: ORIGINAL SIGNED BY by order of ~,~...---"//~ /~_ Approved By D Taylor Seamount Commissioner the commission Date ' / Form 10-401 Rev. 12-01-85 ~icate 1. Well Plan Summary Schrader Bluff Tract 14 2001 Program MPI-13i Drillin~l Permit I Well Name: IMPI-13i I I Type of Well (producer or iniector): I Grassroots Water Injector Surface Location: 2346' FSL, 1253' FWL, SEC. 33, T13N, R10E X = 551,345.04 Y = 6,009,459.54 Target #1 2216' FSL, 641' FWL, SEC. 32, T13N, R10E X= 545,454.24 Y=6,009,291.75 1:13i Target(B0tt0m HOle ~1~28, FSLi21i9;:FWL, SEC,: 31,T13N' R10E Location): I AFE Number: X = 541,663 Y = 6,009,182 Estimated Start Date: I July 1, 2001 I ~" 11,446'I I TVDrkb (TD) I 3754"1 I I Ri~l: Nabors22E I Operatin~l days to complete: I 14.5 Max. Inc. ~0oI I RKBE 64' Well Design (conventional, slim hole, etc.): I Conventional Grassroots Injector Well Scope: Drill and Complete an Injector Well to support the future Multi-Lateral Producers MPI- 11 and MPI-12. This well is designed for water injection initially into the Schrader Bluff OA and OB sands. The completion design will allow further re-completion in the Schrader Bluff N sands. 2.0 Current Well Information 2.1 General 2.2 2.3 Well Name: Well Type: Current Status: BHP: BHT: MPI-13i Development - Schrader Bluff Water Injector Conductor Set 1657 psi @ 3683' TVDss Schrader Bluff 'OB' sand. Normal pressure gradient. 80°F @ 4020' TVDss Estimated (SOR) Current Mechanical Condition MPI-13i: Doyon 22E: Conductor: Cellar Box above MSL = 34' KB / MSL = 64' 20", 92 Ib/ft, H-40 Welded set at 113' RKB Target Estimates Estimated Reserves: Injector to sweep: 1.0 Mstbo Version #1, 4/12/2001 Schrader Bluff Tract 14 2001 Program MPI-13i Drilling Permit Expected Initial Rate: Injection rate: 3000 bwpd Expected 6 month avg: Injection rate: 1500 bwpd Schrader Bluff Tract 14 2001 Pro~lram MPI-13i Drilling Permit 3. Drillin Hazards and Contin_ encies 3.1. Well Control MANDATORY WELL CONTROL DRILLS: Drill Type Frequency Comments D1 Tripping (1) per week, per crew Conducted only inside casing. D2 Drilling (1) per week, per crew Either in cased or open hole. DO NOT shut-in well in open hole. D3 Diverter N/A N/A D4 Accumulator Prior to spud or RWO Approx. every 30 days, thereafter at convenient times. D5 Well Kill Prior to drill out, Prior to drill out the intermediate and production strings. Never per crew carry out this drill when open hole sections are exposed. 3.2. Lost Circulation 3.2.1. Lost circulation has not been encountered while drilling this interval on previous I-Pad wells. 3.2.2. Follow the LOST CIRCULATION DECISION MATRIX in the well plan if fluid losses occur while drilling. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. 3.3. Unexpected High Pressures 3.3.1. It is unlikely there will be unexpected overpressure when drilling to the Schrader Bluff formation. Reservoir pressure is expected to be 1688 psi (8.65 lb/gal). In this well, the Schrader Bluff formation will be drilled with 9.1 ppg mud. 3.4. Stuck Pipe 3.4.1. Good drilling practices to avoid differential sticking are required. Minimum mud weights and proper mud properties as outlined in the Baroid mud program must be closely followed. 3.4.2. Stuck Pipe: Go immediately to SURE manual, determine stuck pipe mechanism, follow recommendations in the SURE manual. DO NOT JAR UP if packed-off! 3.5. Pad Data Sheet 3.5.1. Please Read the E-Pad Data Sheet thoroughly. 3.6. Hydrates 3.6.1. Have not seen any indications of hydrates on previous wells drilled in the same area as this well will be drilled. 3.7. Breathing 3.7.1. No breathing problems are expected drilling the Ugnu or the Schrader Bluff formations. 3.8. Hydrocarbons 3.8.1. Hydrocarbons will be encountered in the Ugnu and Schrader Bluff intervals. Hydrogen Sulfide 3.8.2. Schrader Bluff Tract 14 2001 Program MPI-13i Drilling P_ermit MPI Pad is not designated as an H2S Pad. Below is a summary of the most recent H2S readings: Well I- Well Type H2S Status Date taken 1 Long Term Shut In Feb 2000 2 SBF Prod <2.00 Apr 2000 3 SBF Prod <2.00 Feb 2000 4 SBF Prod <2.00 Feb 2000 5i SBF Inj Injector Apr 2000 6 SBF Prod <2.00 Feb 2000 7 SBF Prod <2.00 Feb 2000 8 SBF Prod <2.00 Feb 2000 Schrader Bluff Tract 14 2001 Program MPI-13i Drilling Permit Drillin_ Pro_qram Overview 4.1. Surface and Anti-Collision Issues Surface Shut-in Wells: No wells need to be shut-in for the rig move on and off MPI-13i Close Approach Wells: There are no close approach wells Well Name Current Production Precautions Status Priority N/A N/A N/A N/A 4.2. Well Control Expected BHP Max Exp Surface Pressure BOPE Retinal Planned BOPE Test Pres. 1688 psi @ 3754' TVD 1315 psi 21-1/4" 2000 psi WP *Function test only (estimated) /0.1 psi/ft ~las ~lradient) Diverter * Note: The wellbore will be drilled from surface to TD with a diverter. The diverter will also be used in running the 3 1/2" tubing for production since the well will not be perforated at that time. 4.3. Mud Program 9 ¥8" Surface Hole Mud Properties: Density (ppg) lFunnelvis I YP 8.6 - 9.6 50 - 150 25 - 40 HTHP N/A Spud - LSND Freshwater Mud pH APl Filtrate LG Solids 9.0 - 9.5 < 6 < 6.5 NOTE: See attached Baroid mud recommendation LCM Restrictions: No Organic LCM products in the Schrader Bluff formation Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1R. 4.4. Formation Markers Formation Tops ft MD ft TVDss Pore psi EMW (ppg) Base Permafrost 1774 1809 SV1 Top Ugnu 7798 3184 1416 8.65 Top Ugnu M 9230 3384 1508 8.65 NA 9700 3464 1544 8.65 NB 9880 3492 1556 8.65 NC 10055 3522 1570 8.65 NE 10195 3545 1580 8.65 NF 10500 3596 1603 8.65 Top OA 10705 3635 1620 8.65 Base OA 10910 3668 1635 8.65 Top OB 11099 3699 1649 8.65 Base OB 11214 3717 1657 8.65 4.5. Casing/Tubing Program Schrader Bluff Tract 14 2001 Program MPI-13i Drilling Permit Hole Size Csg / Wt/Ft Grade Conn Length Top Bottom Tb~l O.D. MD / TVDrkb MD / TVDrkb 30" 20" 92# H-40 Welded 80' 30' / 30' 113' / 113' 9 %" 7" 26# L-80 HYD 521 10500' 30' / 30' 11,446.' / 3754' Tubin~l 2 %" 6.3# L-80 EUE-Mod 9560' 30' / 30' 11,000' / 3680' 4.6. Cement Calculations Casin9 Size I 7" 26 Ib/ft L-80 Hydril 521 BasisI 250% excess over gauge hole in permafrost interval, 50% excess over gauge hole below permafrost A TAM Port Collar will be placed at 1000' MD as a contingency for cement not displacing to surface in one stage The cement volumes will be confirmed by the acoustic caliper to be run whilst drillin~ the 9 %/." hole section Total Cement Volume: I Wash 50 bbl of Newtonian Chemical Wash (CWl00) weighted to 8.32 ppg I Spacer 75 bbl of Viscosified Spacer (Mudpush XL Design) weighted to 10.50 ppg I Lead 900 bbl 10.7 lb/gal Class G Arctic Set III Light (Yield:4.44sk/cuft) I Temp BHST = 80° F from SOR, BHCT 85° F estimated by Dowell 4.6.1. Casing Spaceout a) Emergency 7" casing slips can be used instead of the 7" mandrel hanger if required to achieve the required space out. 4.6.2. 7" String Centralizer Placement a) 8 ¼" x 7" straight blade rigid centralizers should be run floating in the middle of each joint of casing from the 7" casing shoe up to 9300' MD. 4.7. Survey and Logging Program 9 ¥8" Hole Section: Open Hole: Surface: MWD/DIR/GR/PWD Production: MWD/DIR/RESlGR/PWD Cased Hole: Cement Bond Log 4.8. Bit Recommendations BHA Hole Size Depths (MD) Bit Type Nozzles Max. Hours Number and Section K-Revs 1 & 2 9 %" 0, _ 11446' Smith 3x20, 1x10 800 ~ 4.9. Motors and Required Doglegs Drilling Motor Size and Motor Required Flow Rate RPMs Required Doglegs BHA No. 1 6 3,4" Sperrydrill 7/8, 3 stg Slow Speed, 1.15° adj. 300 - 500 170 2.5°/100, initial build with 9.6" sleeve gpm (max.) 6°/100' final build Schrader Bluff Tract 14 2001 Program MPI-13i Drilling Permit 5. MPI-13i Nabors 22E Operations Summary 5.1. Pre-Rig Operations 1. Grade and level pad 5.2. Procedure 1. MIRU Nabors 22E, NU diverter on 20" conductor, PU 5" drill pipe 2. MU BHA with 9 %" milltooth bit, 6 3,4" Sperry MWD/LWD(GR-Res)/PWD and 5" drill pipe 3. Drill 9 %" surface hole as per directional plan Tangent angle 81° 4. POOH. Reamer trip with Hole opener to TD 5. Condition mud with lubes and spot casing running lube pill prior to 7" casing run. POOH laying down DP 6. Run 7" casing to TD, Cement casing to surface, TAM Port Collar as contingency should cement not get to surface 7. Install FMC 11" 5m horizontal wellhead 8. N/U and test 13 %" 5m BOP 9. Run 3 1/2" tubing and packer completion 10. Freeze protect tubing and annulus 11. Space out packer with the tailpipe 100' MD above N sand interval 12. Drop ball and set packer 13. Set blanking plug then TWC 14. N/D BOP 15. Install and test 3 1/16" tree 16. RD/MO 5.3. Post Rig Work 1. Retrieve TWC, blanking plug, ball and RHC plug 2. Record initial static pressure 17. R/U Schlumberger e-line 18. NU wireline lubricator 19. Run cement bond log 20. Perforate well on wireline 3. N/D wireline lubricator Lewis, Wanda M From: Sent: To: Cc: Subject: Bitar, Fawaz K (SUN) Wednesday, February 28, 2001 5:20 AM Minett, Lee (Contractor) Bitar, Fawaz K (SUN) RE: Letter and Sunbury Report IMPORTANT AND URGENT Message from the Upstream Surface Staff Network Leaders Dear Colleague, You have been identified as a member of the Surface Community (Projects/Engineering/Operations/Corrosion). We are currently in the process of compiling a global surface database which is an essential foundation of the Staff Development and Deployment Process. Some of you may have already received a webpage and enrolled, please treat this as a prompt to look at your data to amend or update it if necessary. There is an urgent need to complete this database so that we can: · understand the population and demographics of the community on a global basis · develop a regional and global resourcing strategy · facilitate your development and deployment. Please take the time to complete your details on the attached web page (the web shortcut) and no later than May 25, 2001. This web page will give you the ability to view and update your data within the network as and when required. Please save this shortcut and use it to keep your details current. If you have any questions regarding this database or the Surface network, please contact: ~,-,,,,-,;o w,-,u; .... u _ ~,o.~.~ ~,~ ..... ~, ~ ,~o,4,~ ~ ~,-,o, .... - ~ -Pro!et*s Mark Berman - Staff Network Leader, Upstream Engineering The Alaska · ACT! · GAS · AND · SST · GPB · HSE · Alaska Surface Staff Development and Deployment Network includes: Phil Aldis (Network Leader), Dan Blanchard, Wayne Kuykendall, Bill Blosser and Greg Cooke Dave Calvin and Shane O'Leary Pete Flones Nancy Foust, lan Livett and Dave McDowell Jack Fritts, Ruth Germany-Bice, Terry Golden and Roger Reddin Floyd Hoffer Surface SDDN Coordinator (fulltime) Wanda Lewis x5019 Below (the web shortcut) you will find your own Web page. Please give the page.a few moments to completely display. if you have a CV (career summary) or Personal Development Plan/Profile available, please forward it to Wanda Lewis as a 'Word Document' attached to an e-mail. Thank you for your time and support in this matter. Phil Aldis Alaska Surface Staff Development & Deployment Network Leader Wellhead: FMC Gen 6 11" 5M, 3 112" tbg hanger CIW "H" BPV EUE threads pin x box MPI-13i PROPOSED COMPLETION Note: The completion tubing will be used for water injection 3-1/2", 9.3#, L-80, EUE Coupling OD: 4.25 .... Drift/ID: 2.992/2.797 7", 26#, L-80, Hyd 521 Casing Drift: 6.151" Casing ID: 6.276" DIRECTIONAL PLAN (PROPOSED PLAN wp03) Grass Roots Conventional Injector KOP = 700' MD, BR - 4°/100' Max. hole angle = 80° , EOB @ 2800' MD Hole angle thru perf zone = 80° 20", 92#, H-40, Welded @ 113' MD/RKB I 1,000' I 7" TAM Port Collar 2,600' I 3 1/2" 'X' nipple ID= 2.838" Rig RKB Elevation: 64' Hole Size -- 9-7/8" Top of Tail Cmt. @ 9100' MD Top of N sand @ 9500' MD, 3430' TVD 10540' MD I 3 1/2" 'X' nipple ID = 2.838 7" x 3 1/2" Baker Packer with Anchor 3 112" 'XN' nipple ID -- 2.750 110,630' Mq Tubing Tail (WLEG) Schrader 'OA' SANDS PERFORATION ZONES: ~,,Schrader ,OB, SANDS HOLE ANGLE at TD: 80 I 11.446' MD 3754' TVE)/RKB FINAL MUD WEIGHT = 9.2 PPG DATE REV. BY COMMENTS MILNE POINT UNIT 04/11/01 SMS Proposed Completion Well I-~ 3i APl No: BP EXPLORATION (AK) COMPANY DETAI ES BP Amoco Calculation Metho& M~m~n C~'ah~ Error System: ISCWSA Scan Metho& High Side + Azimulh Error Smfaee: Ellipli~al ~ Cas~g Wamin[~ Method: Rules Based REFERENCE INFOR~L&TION Co-ordinate (N,E) Refo'ence: Well Centre:. Plan MPI-IN5, Trt~ North Ve~ical (TVD) Reference:. 12: 08 9115/1997 16:09 64.0 Section (Vb) Refenmce: Slot - (0.00,0.00) Measured D~p th Re fo",nlce: 12: 089/15/1997 16:09 64_0 Calculation M,~aod: M&fimum ~ SURVEY PROGRAbt Depth Fm Depth To Survey/Plan 64.00 500.00 Plalmed: btPl-IN5 vq~03 V i 500.00 11446.62 Planned: MPI-IN5 v,'pO3 VI Tool CB43YRO-SS MWD*IFR+MS Plan: I'.tPI-IN5 v,~)3 0'lan Ml'l-IN5/l'lan MI'I-INS) Creeled By: Ken Allen Dale: 4/4/2¢R) 1 Checked: Dale: __ Reviewed: ])ale: ANNOTATIONS No. TVD MD Annotation 1 300.00 300.00 Start Dir 1°/100': 300' MD, 300'TVD 2 699.68 700.00 Start Dir 2°/100': 700' MD, 699.68'TVD 3 898.54 900.00 Start Dir 3°/100': 900' MD, 898.54'TVD 4 1782.121866.67 EndDir : 1866.67'MD, 1782.12'TVD 5 1950.002076.88 Start Dir 6°/100': 2076.88' MD, 1950TVD 6 2316.962800.75 End Dir : 2800.75' MD, 2316.96' TVD 7 3754.0011446.61Total Depth: 11446.62' MD, 3754' TVD WELL DI;q~AILS iNlatl]e +N/-S *E/-W lN~.~'thJ n~ F~astingLatitudela,ngimdc SIo! Plan MPI-IN~4.g7 1076.4.7 6009460.00 551315.00 70'26'11.754N 149034'53.829W TARGEI I)EI'AII~q Name TVD -N;-S~ 'E/-W N~thing I~a~n~ Shape MPI-IN5 TI3754.00 -211.00 -9654.5g (~09182.61 541663.O1 I'*,inl MPI-IN5 Tla 3640.~0 -17g.47 -958435 6OO9215.62 54173~.03 Ih,in! SECTION DETAILS Sec MD Inc Azi TVD N/S E/W DLeg TFace VSec Target 1 64.00 0.00 0.00 64.00 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 3 700.00 4.00 268.75 699.68 -0.30 -13.95 1.00 268.75 13.95 4 900.00 8.00 268.75 898.54 -0.76 -34.85 2.00 0.00 34.86 5 1866.67 37.00 268.75 1782.12 -8.74 -400.75 3.00 360.00 400.85 6 2076.88 37.00 268.75 1950.00 -11.50 -527.23 0.00 0.00 527.36 7 2800.75 80.43 268.75 2316.96 -24.69 -1131.01 6.00 0.00 1131.28 8 11446.6280.43 268.75 3754.00 -211.00 -9654.58 0.00 0.00 9656.89 MPI-IN5 TI Siart Dir 1°/100': 300' MD, 100q'VD ~art Dir 2°/100': 700' MD, 699.68'TVD ~tart..Dir 3°/100': 900' MD, 898.54'TVD i".~- ~nd Dir: 1866.67' MD, 1782.12' TVD 20;0'% Start Dir 6VI00': 2076.88' MD 1950qWD i i .... Dir i: 28fi0.75' MD, 5~ [~._96' T~tD ............... ~ i 3000 i i 4000 i ~ ~ i sooo ~ 8~oo i ~ i i ~ ~0001 All TVD depths are ssTVD plus 64' for RKBE. i : : ~ : 10o0o -4-. } i ! 11~00,~4-- Total Depth: 11446.62' MD, 3754' TVD ~ " i .! ..... i ....... i ................. i .... I 1447~ 500 3000 4500 6000 7500 9000 10500 12000 13500 Vertical Section at 268.75° [1500ft/in] COMPANY DETAILS BP Amoco Calculation IMetho& MMimmn Error System: [SCWSA Scan Method: High Side + ~zimuth Error Sm-face: Elliptical + CaSing Wamin~l Method: Rules Bazed ANNOTATIONS No. TVD MD Annotation 1 300.00 300.00 Start Dir l°/100': 300' MD, 300~FVD 2 699.68 700.00 Start Dir 2°/I00': 700' MD, 699.68'TVD 3 898.54 900.00 Start Dir 3°/100': 900' MD, 898.54'TVD 4 1782.121866.67 EndDir : 1866.67'MD, 1782.12'TVD 5 1950.002076.88 Start Dir 6°/100': 2076.88' MD, 1950'TVD 6 2316.962800.75 End Dir : 2800.75' MD, 2316.96' TVD 7 3754.0011446.61Total Depth: 11446.62' MD, 3754' TVD REFERENCE INFORI~LATION Coordinate (N~E) Reference: Well Cent. Plan MPMN5, Tree North Vertical (TVD) Refelenc< 12: 08 9/15/199'/ 16:09 64.0 .Section Q/S) Reference: Slot - (0.00,0.00) Me~.~d Depth R~feren~e: 12: Q8 91151199'/ 16:09 64.0 Calculation Me.od: Minimum C'm'vamre All TVD depths are ssTVD plus 64' for RKBE. SURVEY PROGRAM D~pth Fm Depth To SurveyJPlan 64.00500.00 Plamaed: btPI-IN5 v,]~03 Vl 500.00 11446.62 Planned: MPI-FN5 v,~O3 V1 Tool CB-GYRO.S btWI~-IFR'q',IS Plan: MPI-IN5 v,'p03 (Plan Ml*l-INS/l'lan MPI-INS) Crealed By: Ken Allen Dale: 4/4/2001 Checked: Date: Reviewed: ])ale: WEI_L DF. TAILS Name 4q/-S * -~'-w Northing F~sting l.alitudc l.ongimd,.. Plan MPI-I]~.IO 1076.47 6009460.00 551315.00 70°26'11.754N 149~34'53.829W TARGET I)ETAII2; Name IYD -N'-S-FJ-W Nl~thing1.3~ng Shap~ MPI-IN5 113754.00 -211.00 -9654.58 6009182.61 541663.04 Poinl MPI-IN5 Tla 3640.00 -178.47 -9584.35 60O9215.62 541733.03 I'oml SECTION DETAILS Sec MD Inc Azi TVD N/S E/W DLeg TFace VSec Target 1 64.00 0.00 0.00 64.00 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 3 700.00 4.00 268.75 699.68 -0.30 -13.95 1.00 268.75 13.95 4 900.00 8.00 268.75 898.54 -0.76 -34.85 2.00 0.00 34.86 5 1866.67 37.00 268.75 1782.12 -8.74 -400.75 3.00 360.00 400.85 6 2076.88 37.00 268.75 1950.00 -I 1.50 -527.23 0.00 0.00 527.36 7 2800.75 80.43 268.75 2316.96 -24.69 -1131.01 6.00 0.00 1131.28 8 11446.6280.43 268.75 3754.00 -211.00 -9654.58 0.00 0.00 9656.89 MPI-IN5 TI Total D~pth :ii 144~.62' : 3734 i i 3560 i i i :3000 Start Dir 1°/100': 300' MD, 300q'VD Start Dir 2°/100.: 700' MD, 699.68'TVD I i Start Dir 3°/100': 900' MD, 898.54'TVD \ ~ En~lDiri:t 866.67' MD, Start Dir 6°/100': 2076.88' MD 1950~FVD ",.. ~ i25oo i / ! 2ooo ~5oo End Dir : 2800.75' MD, 2316.96' TVD -12000 -10500 -9000 -7500 -6000 -4500 -3000 - 1500 West(-)/East(+) [1500fl/in] I 1500 BP Amoco Planning Report- Geographic Company: BP Amoco Date: 4/4/2001 Time: 09:18:28 Page: 1 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPI-IN5, True North Site: M Pt I Pad Vertical (TVD) Reference: 12 ' 08 9/15/1997 16:09 64.0 Well: Plan MPI-IN5 Section (VS) Reference: Well (0.00E,0.00N,268.75Azi) Wellpath: Plan MPI-IN5 Plan: MPI-IN5 wp03 "r ~-~-~- :.- --.: :::~:. ,.-- Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: BGGM2000 Site: M Pt I Pad TR-13-10 UNITED STATES · North Slope Site Position: Northing: 6008388.01 ft Latitude: 70 26 1.282 N From: Map Easting: 550245.83 ft Longitude: 149 35 25.422 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.39 de§ Well: Plan MPI-IN5 Slot Name: Surface Position: +N/-S 1064.87 ft Northing: 6009460.00 ft Latitude: 70 26 11.754 N +E/-W 1076.47 ft Easting: 551315.00 ft Longitude: 149 34 53.829 W Position Uncertainty: 0.00 ft Reference Point: +N/-S 1064.87 ft Northing: 6009460.00 ft Latitude: 70 26 11.754 N +E/-W 1076.47 ft Easting: 551315.00 ft Longitude: 149 34 53.829 W Measured Depth: 64.00 ft Inclination: 0.00 deg Vertical Depth: 64.00 ft Azimuth: 0,00 deg Wellpath: Plan MPI-IN5 Drilled From: Well Ref. Point Tie-on Depth: 0.00 ft Current Datum: 12 ' 08 9/15/1997 16:09 Height 64.00 ft Above System Datum: Mean Sea Level Magnetic Data: 2/22/2001 Declination: 26.32 deg Field Strength: 57438 nT Mag Dip Angle: 80.76 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 268.75 :~ ~:::: :-'-: :.: ,--' '_'; :.~:::: '-"__':"_'_ _----'__~' _-~ :::_-_~.-_7_¥-_:_~ _-. ::::.7_~:,:':~ ,7:.:: :: ~: L"::: ~ :'_:: :': :"_~: .~ ::-_;"'_~':::'x ::'::-_ :~: :'::': ...-~"~:: :":~-'~ ~-~."::7_::: :_-_:: :,':,: :: ~:-_:':::::':::-£T: ~'~,~ '"~'£ ~" :: :: :: :~_-;- '_-:~,::..-.:::: .~.,_--'_:'_-.;:_T_':~ Plan: MPI-IN5 wp03 Date Composed: 2/22/2001 Version: 1 Principal: Yes . Tied-to: From Well Ref. Point Plan Section Information MD Incl ft deg deg ft '64'.00 "' 0'.00' .... ~.00 '" 64.00 300.00 0.00 0.00 300.00 700.00 4.00 268.75 699.68 900.00 8.00 268.75 898.54 1866.67 37.00 268.75 1782.12 2076.88 37.00 268.75 1950.00 2800.75 80.43 268.75 2316.96 11446.62 80.43 268.75 3754.00 Section MD ft Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft ft deg/100ft deg/100ft deg/100ft deg "o.o0 0.o'o ....... 0.0'6" o.oo 0.0o ............. 0.06 .................................. 0.00 0.00 0.00 0.00 0.00 0.00 -0.30 -13.95 1,00 1.00 0.00 268.75 -0.76 -34,85 2.00 2,00 0.00 0.00 -8,74 -400,75 3,00 3.00 0,00 360.00 -11.50 -527.23 0.00 0.00 0.00 0.00 -24,69 -li31.01 6.00 6,00 0.00 0,00 -211.00 -9654.58 0.00 0.00 0.00 0.00 MPI-IN5 T1 1 : Start lncl Azim TVD +N/-S +E/-W deg deg ft ft ft "'64.00 ' ''0.00 .... 0:0'0 ' "64.00" 0.00 .... 0100' 100.00 0.00 0.00 100.00 0.00 0.00 200.00 0.00 0.00 200.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 VS DLS Build Turn TFO ft deg/100ft deg/100ft deg/100ft deg ............................... 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Section 2: Start ............ :h'6 ............... ii;;i .............. X;i';,- ............. ~:v-6'''~ ..... ;:~;:~": ........ ;~)~ ................. ¥~- ................ 6i~ .......... ii;ii;i'....... Turn ....... '~'F-~---' · . . . .. ft deg'' deg. ft ft . 'ft ft deg/100ft deg/100ft'deg/100ft · deg 400.00 i .00 268.75 399.99 -0.02 -0,87 0.87 1.00 1.00 0.00 0.00 500,00 2.00 268.75 499.96 -0,08 -3.49 3,49 1.00 1.00 0.00 0.00 600.00 3,00 268.75 599,86 -0,17 -7,85 7.85 1.00 1.00 0.00 0.00 i' BP Amoco Planning Report- Geographic Company: BP Amoco Date: 4/4/2001 Time: 09:18:28 Page: Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPI-IN5, True North Site: M Pt I Pad Vertical (TVD) Reference: 12 ' 08 9/15/1997 16:09 64.0 Well: Plan MPI-IN5 Section (VS) Reference: Well (0.00E,0.00N,268.75Azi) Wellpath: Plan MPI-IN5 Plan: MPI-IN5wp03 Section 2: Start MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ft deg/100ft deg/100ft deg , 700.00 4.00 268.75 699.68 -0.30 - 13.95 13.95 1.00 1.00 0.00 0.00 Section 3: Start MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/lOOft deg/lOOft deg/lOOft deg 800.00 6,00 268.75 799.29 -0.49 -22.66 22.67 2.00 2.00 0.00 0,00 900.00 8.00 268.75 898.54 -0.76 -34.85 34.86 2.00 2.00 0.00 0.00 Section 4: Start MD lncl :Azim TVD +N/-S +E/-W : DLS Build Turn: TFO 1000.00 11.00 268.75 997.16 -1.12 -51.35 51.36 3.00 3.00 0.00 0,00 1100.00 14.00 268.75 1094.78 -1.59 -72.99 73.00 3,00 3.00 0.00 0.00 1200.00 17.00 268.75 1191.13 -2.18 -99.70 99.72 3.00 3.00 0.00 0.00 1300.00 20.00 268.75 1285.95 -2.87 -131,42 131.45 3.00 3.00 0.00 0.00 1400.00 23.00 268,75 1378.98 -3.67 -168,06 168.10 3.00 3,00 0.00 0.00 1500.00 26.00 268.75 1469.97 -4.57 -209,51 209.56 3.00 3.00 0.00 0.00 1600.00 29.00 268.75 1558.66 -5.58 -255.67 255.73 3.00 3.00 0.00 0,00 1700.00 32.00 268.75 1644.81 -6.69 -306.41 306.48 3.00 3.00 0,00 0.00 1800.00 35.00 268.75 1728.19 -7.89 -361.58 361.67 3,00 3.00 0.00 0.00 1866.67 37.00 268.75 1782.12 -8.74 -400,75 400.85 3.00 3.00 0.00 0.00 Section 5: Start I:MI): · ·· · Azim · 'ft ' :'deg ' '.deg' ..... [2000.00 37.00 268.75 2076 88 37 00 268 75 L. .............. ..vw .......... ,~. ............ -..__ TVD +N/-S +E/-W VS DLS Build Turn TFO ft .ft ft ft degl100ft, deg/l 00ft' deg/100ft deg ' Section 6: Start 1808.74 -9.18 -420,80 420.90 0.00 0,00 0.00 180.00 1888.60 -10.49 -480,97 481.09 0.00 0.00 0.00 180.00 1950.00 -11.50 -527.23 527,36 0.00 0.00 0.00 180.00 MD Incl Azim TVD +N/-S +E/-W' VS DLS · BUild· Turn TFO ft deg . deg . ft ft .' ft ft deg/lOOft deg/lOOft deg/lOOft 'deg 2100.00 38,39 268.75 1968,29 -11.81 -541.36 541.49 6.00 6.00 0.00 0.00 2150.00 41,39 268.75 2006.66 -12.51 -573.42 573,55 6.00 6.00 0.00 0.00 2200.00 44.39 268.75 2043.29 -13.25 -607.43 607.58 6.00 6.00 0.00 0.00 2250.00 47.39 268.75 2078.09 -14.03 -643.32 643.47 6.00 6.00 0.00 0.00 2300.00 50.39 268.75 2110.96 -14.85 -680.97 681.14 6.00 6,00 0.00 0.00 2350.00 53.39 268.75 2141.82 -15.71 -720.30 720.47 6.00 6.00 0.00 0.00 2400.00 56,39 268.75 2170.57 -16.60 -761.19 761.37 6.00 6.00 0,00 0.00 2450.00 59.39 268.75 2197.15 -17.53 -803.52 803,71 6.00 6.00 0.00 0.00 2500.00 62.39 268.75 2221.47 -18.48 -847.19 847.39 6.00 6.00 0.00 0.00 2550.00 65.39 268,75 2243.48 -19.46 -892.07 892.28 6.00 6.00 0.00 0.00 2600.00 68,39 268.75 2263.10 -20.46 -938.04 938.26 6.00 6.00 0.00 0.00 2650.00 71.39 268.75 2280.29 -21.49 -984.98 985.21 6.00 6.00 0.00 0.00 2700.00 74.39 268.75 2295.00 -22.53 -1032.75 1032.99 6,00 6.00 0.00 0,00 2750.00 77.39 268.75 2307.19 -23.59 -1081.22 1081.48 6.00 6.00 0.00 0.00 2800.75 80.43 268.75 2316.96 -24.69 -1131.01 1131.28 6.00 6.00 0.00 0.00 Section 7: Start · MD.. ' lncl Azim · TVD · +N/-S · +EI-W VS DLS Build Turn TFO .. ft. deg · . deg · .ft ft ft ft deg/lOOft degllOOft deg/lOOft deg ... 2900.00 80.43 268.75 2333.46 -26.82 -1228.86 1229.15 0.00 0.00 0.00 0.00 3000.00 80.43 268.75 2350.09 -28.98 -1327.44 1327.76 0.00 0.00 0.00 0.00 3100,00 80.43 268,75 2366.71 -31.13 -1426.03 1426.36 0.00 0.00 0.00 0.00 3200.00 80.43 268.75 2383.34 -33.28 -1524.61 1524.97 0.00 0.00 0.00 0.00 3300.00 80.43 268.75 2399.96 -35.43 -1623.19 1623.58 0.00 0.00 0.00 0.00 3400.00 80.43 268.75 2416.59 -37,58 -1721.78 1722.19 0.00 0.00 0.00 0.00 3500.00 80.43 268.75 2433.21 -39.73 -1820.36 1820.80 0.00 0.00 0.00 0.00 3600.00 80.43 268.75 2449.84 -41.88 -1918.95 1919.41 0.00 0.00 0.00 0.00 ',i, BP Amoco Planning Report- Geographic Company: BP Amoco Date: 4/4/2001 Time: 09:18:28 Page: Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPI-IN5, True North Site: M Pt I Pad Vertical (TVD) Reference: 12: 08 911511997 16:09 64.0 Well: Plan MPI-IN5 Section (VS) Reference: Well {0.00E,0.00N,268.75Azi) Weilpath: Plan MPI-IN5 Plan: MP-IN5 wp03 Section 7: Start MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft dog/100ft des/100ft deg/100ft deg 3700.00 80.43 268.75 2466.46 -44.03 -2017.53 2018.01 0.00 0.00 0.00 0.00 3800.00 80.43 268.75 2483.09 -46.19 -2116.12 2116.62 0.00 0.00 0.00 0.00 3900.00 80.43 268.75 2499.71 -48.34 -2214.70 2215.23 0.00 0.00 0.00 0.00 4000.00 80.43 268.75 2516.34 -50.49 -2313.29 2313.84 0.00 0.00 0.00 0.00 4100.00 80.43 268.75 2532.96 -52.64 -2411.87 2412.45 0.00 0.00 0.00 0.00 4200.00 80.43 268.75 2549.59 -54.79 -2510.46 2511.06 0.00 0.00 0.00 0.00 4300.00 80.43 268.75 2566.21 -56.94 -2609.04 2609.66 0.00 0.00 0.00 0.00 4400.00 80.43 268.75 2582.84 . -59.09 -2707.63 2708.27 0.00 0.00 0.00 0.00 4500.00 80.43 268.75 2599.46 -61.24 -2806.21 2806.88 0.00 0.00 0.00 0.00 4600.00 80.43 268.75 2616.09 -63.39 -2904.80 2905.49 0.00 0.00 0.00 0.00 4700.00 80.43 268.75 2632.72 -65.55 -3003.38 3004.10 0.00 0.00 0.00 0.00 4800.00 80.43 268.75 2649.34 -67.70 -3101.97 3102.71 0.00 0.00 0.00 0.00 4900.00 80.43 268.75 2665.97 -69.85 -3200.55 3201.31 0.00 0.00 0.00 0.00 5000.00 80.43 268.75 2682.59 -72.00 -3299.14 3299.92 0.00 0.00 0.00 0.00 5100.00 80.43 268.75 2699.22 -74.15 -3397.72 3398.53 0.00 0.00 0.00 0.00 5200.00 80.43 268.75 2715.84 -76.30 -3496.31 3497.14 0.00 0.00 0.00 0.00 5300.00 80.43 268.75 2732.47 -78.45 -3594.89 3595.75 0.00 0.00 0.00 0.00 5400.00 80.43 268.75 2749.09 -80.60 -3693.48 3694.36 0.00 0.00 0.00 0.00 5500.00 80.43 268.75 2765.72 -82.75 -3792.06 3792.96 0.00 0.00 0.00 0.00 5600.00 80.43 268.75 2782.34 -84.91 -3890.65 3891.57 0.00 0.00 0.00 0.00 5700.00 80.43 268.75 2798.97 -87.06 -3989.23 3990.18 0.00 0.00 0.00 0.00 5800.00 80.43 268.75 2815.59 -89.21 -4087.82 4088.79 0.00 0.00 0.00 0.00 5900.00 80.43 268.75 2832.22 -91.36 -4186.40 4187.40 0.00 0.00 0.00 0.00 6000.00 80.43 268.75 2848.84 -93.51 -4284.99 4286.01 0.00 0.00 0.00 0.00 6100.00 80.43 268.75 2865.47 -95.66 -4383.57 4384.61 0.00 0.00 0.00 0.00 6200.00 80.43 268.75 2882.09 -97.81 -4482.16 4483.22 0.00 0.00 0.00 0.00 6300.00 80.43 268.75 2898.72 -99.96 -4580.74 4581.83 0.00 0.00 0.00 0.00 6400.00 80.43 268.75 2915.34 -102.11 -4679.33 4680.44 0.00 0.00 0.00 0.00 6500.00 80.43 268.75 2931.97 -104.27 -4777.91 4779.05 0.00 0.00 0.00 0.00 6600.00 80.43 268.75 2948.59 -106.42 -4876.50 4877.66 0.00 0.00 0.00 0.00 6700.00 80.43 268.75 2965.22 -108.57 -4975.08 4976.26 0.00 0.00 0.00 0.00 6800.00 80.43 268.75 2981.85 -110.72 -5073.66 5074.87 0.00 0.00 0.00 0.00 6900.00 80.43 268.75 2998.47 -112.87 -5172.25 5173.48 0.00 0.00 0.00 0.00 7000.00 80.43 268.75 3015.10 -115.02 -5270.83 5272.09 0.00 0.00 0.00 0.00 7100.00 80.43 268.75 3031.72 -117.17 -5369.42 5370.70 0.00 0.00 0.00 0.00 7200.00 80.43 268.75 3048.35 -119.32 -5468.00 5469.31 0.00 0.00 0.00 0.00 7300.00 80.43 268.75 3064.97 -121.47 -5566.59 5567.91 0.00 0.00 0.00 0.00 7400.00 80.43 268.75 3081.60 -123.63 -5665.17 5666.52 0.00 0.00 0.00 0.00 7500.00 80.43 268.75 3098.22 -125.78 -5763.76 5765.13 0.00 0.00 0.00 0.00 7600.00 80.43 268.75 3114.85 -127.93 -5862.34 5863.74 0.00 0.00 0.00 0.00 7700.00 80.43 268.75 3131.47 -130.08 -5960.93 5962.35 0.00 0.00 0.00 0.00 7800.00 80.43 268.75 3148.10 -132.23 -6059.51 6060.96 0.00 0.00 0.00 0.00 7900.00 80.43 268.75 3164.72 -134.38 -6158.10 6159.56 0.00 0.00 0.00 0.00 8000.00 80.43 268.75 3181.35 -136.53 -6256.68 6258.17 0.00 0.00 0.00 0.00 8100.00 80.43 268.75 3197.97 -138.68 -6355.27 6356.78 0.00 0.00 0.00 0.00 8200.00 80.43 268.75 3214.60 -140.84 -6453.85 6455.39 0.00 0.00 0.00 0.00 8300.00 80.43 268.75 3231.22 -142.99 -6552.44 6554.00 0.00 0.00 0.00 0.00 8400.00 80.43 268.75 3247.85 -145.14 -6651.02 6652.61 0.00 0.00 0.00 0.00 8500.00 80.43 268.75 3264.47 -147.29 -6749.61 6751.21 0.00 0.00 0.00 0.00 8600.00 80.43 268.75 3281.10 -149.44 -6848.19 6849.82 0.00 0.00 0.00 0.00 8700.00 80.43 268.75 3297.72 -151.59 -6946.78 6948.43 0.00 0.00 0.00 0.00 8800.00 80.43 268.75 3314.35 -153.74 -7045.36 7047.04 0.00 0.00 0.00 0.00 8900.00 80.43 268.75 3330.98 -155.89 -7143.95 7145.65 0.00 0.00 0.00 0.00 9000.00 80.43 268.75 3347.60 -158.04 -7242.53 7244.26 0.00 0.00 0.00 0.00 9100.00 80.43 268.75 3364.23 -160.20 -7341.12 7342.86 0.00 0.00 0.00 0.00 9200.00 80.43 268.75 3380.85 -162.35 -7439.70 7441.47 0.00 0.00 0.00 0.00 9300.00 80.43 268.75 3397.48 -164.50 -7538.29 7540.08 0.00 0.00 0.00 0.00 9400.00 80.43 268.75 3414.10 -166.65 -7636.87 7638.69 0.00 0.00 0.00 0.00 9500.00 80.43 268.75 3430.73 -168.80 -7735.46 7737.30 0.00 0.00 0.00 0.00 9600.00 80.43 268.75 3447.35 -170.95 -7834.04 7835.91 0.00 0.00 0.00 0.00 9700.00 80.43 268.75 3463.98 -173.10 -7932.63 7934.51 0.00 0.00 0.00 0.00 9800.00 80.43 268.75 3480.60 -175.25 -8031.21 8033.12 0.00 0.00 0.00 0.00 9900.00 80.43 268.75 3497.23 -177.40 -8129.80 8131.73 0.00 0.00 0.00 0.00 10000.00 80.43 268.75 3513.85 -179.56 -8228.38 8230.34 0.00 0.00 0.00 0.00 BP Amoco Planning Report- Geographic Company: BP Amoco Date: 4/4/2001 Time: 09:18:28 Page: 4 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPI-IN5, True North Site: M Pt I Pad Vertical (TVD) Reference: 12 · 08 9/15/1997 16:09 64.0 Well: Plan MPI-IN5 Section (VS) Reference: Well (0.00E,0.00N,268.75Azi) _We?pa?h:_...PlanMP.!.iN5 ....................................................... p!a.n: MP!.-_IN5 wp03. section 7: Start MD lncl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ft deg/100ft deg/100ft deg 10100.00 80.43 268.75 3530.48 -181.71 -8326.97 8328.95 0.00 0.00 0.00 0.00 10200.00 80.43 268.75 3547.10 -183.86 -8425.55 8427.56 0.00 0.00 0.00 0.00 10300.00 80.43 268.75 3563.73 -186.01 -8524.13 8526.16 0.00 0.00 0.00 0.00 10400.00 80.43 268.75 3580.35 -188.16 -8622.72 8624.77 0.00 0.00 0.00 0.00 10500.00 80.43 268.75 3596.98 -190.31 -8721.30 8723.38 0.00 0.00 0.00 0.00 10600.00 80.43 268.75 3613.60 -192.46 -8819.89 8821.99 0.00 0.00 0.00 0.00 10700.00 80.43 268.75 3630.23 -194.61 -8918.47 8920.60 0.00 0.00 0.00 0.00 10800.00 80.43 268.75 3646.86 -196.76 -9017.06 9019.21 0.00 0.00 0.00 0.00 10900.00 80.43 268.75 3663.48 -198.92 -9115.64 9117.81 0.00 0.00 0.00 0.00 11000.00 80.43 268.75 3680.11 -201.07 -9214.23 9216.42 0.00 0.00 0.00 0.00 11100.00 80.43 268.75 3696.73 -203.22 -9312.81 9315.03 0.00 0.00 0.00 0.00 11200.00 80.43 268.75 3713.36 -205.37 -9411.40 9413.64 0.00 0.00 0.00 0.00 11300.00 80.43 268.75 3729.98 -207.52 -9509.98 9512.25 0.00 0.00 0.00 0.00 11400.00 80.43 268.75 3746.61 -209.67 -9608.57 9610.86 0.00 0.00 0.00 0.00 11446.62 80.43 268.75 3754.00 -211.00 -9654.58 9656.89 0.00 0.00 0.00 0.00 Survey ~' ':~:~i-':w-:'-::ii'-i~ :--:':!'-':i: : Map:: :Map=:::: ~, 'Latitude ~=::<~ :LOngitude MD lncl ::= ~im: ::,:::: TVD ::::; : :¢N/~S:: :::=::: :+:E/~W :Nm.~:i=n~::::: :E~Sting:: : :De:g :Mi=n::; sec:=:: ::D~g Mi~:= sec:::=:::=:: ; ff · deg deg' ft ft' ft ff ff 64.00 0,00 0.00 64.00 0.00 0.00 6009460.00 551315.00 70 26 11.754 N 149 34 53.829 W 100.00 0.00 0.00 100.00 0.00 0.00 6009460.00 551315.00 70 26 11.754 N 149 34 53.829 W 200.00 0.00 0.00 200.00 0.00 0.00 6009460.00 551315.00 70 26 11.754 N 149 34 53.829 W 300.00 0.00 0.00 300.00 0.00 0.00 6009460.00 551315.00 70 26 11.754 N 149 34 53.829 W 400.00 1.00 268.75 399.99 -0.02 -0.87 6009459.97 551314.13 70 26 11.753 N 149 34 53.855 W 500.00 2.00 268.75 499.96 -0.08 -3.49 6009459.90 551311.51 70 26 11.753 N 149 34 53.932W 600.00 3.00 268.75 599.86 -0.17 -7.85 6009459.77 551307.15 70 26 11.752 N 149 34 54.060W 700.00 4.00 268.75 699.68 -0.30 -13.95 6009459.60 551301.05 70 26 11.751 N 149 34 54.239W 800.00 6.00 268.75 799.29 -0.49 -22.66 6009459.35 551292.34 70 26 11.749 N 149 34 54.494W 900.00 8.00 268.75 898.54 -0.76 -34.85 6009459.00 551280.16 70 26 11.746 N 149 34 54.852W 1000.00 11.00 268.75 997.16 -1.12 -51.35 6009458.53 551263.66 70 26 11.743 N 149 34 55.336W 1100.00 14.00 268.75 1094.78 -1.59 -72.99 6009457.91 551242.03 70 26 11.738 N 149 34 55.971 W 1200.00 17.00 268.75 1191.13 -2.18 -99.70 6009457.14 551215.33 70 26 11.732 N 149 34 56.755W 1300.00 20.00 268.75 1285.95 -2.87 -131.42 6009456.23 551183.62 70 26 11.725 N 149 34 57.686W 1400.00 23.00 268.75 1378.98 -3.67 -168.06 6009455.18 551146.99 70 26 11.717 N 149 34 58.761W 1500.00 26.00 268.75 1469.97 -4.57 -209.51 6009453.99 551105.55 70 26 11.709 N 149 34 59.978W 1600.00 29.00 268.75 1558.66 -5.58 -255.67 6009452.66 551059.40 70 26 11.699 N 149 35 1.333W 1700.00 32.00 268.75 1644.81 -6.69 -306.41 6009451.21 551008.68 70 26 11.688 N 149 35 2.822W 1800.00 35.00 268.75 1728.19 -7.89 -361.58 6009449.62 550953.52 70 26 11.676 N 149 35 4.441W 1866.67 37.00 268.75 1782.12 -8.74 -400.75 6009448.50 550914.36 70 26 11.667 N 149 35 5.590W 1900.00 37.00 268.75 1808.74 -9.18 -420.80 6009447.93 550894.31 70 26 11.663 N 149 35 6.179W 2000.00 37.00 268.75 1888.60 -10.49 -480.97 6009446.20 550834.16 70 26 11.650 N 149 35 7.945W 2076.88 37.00 268.75 1950.00 -11.50 -527.23 6009444.87 550787.91 70 26 11.640 N 149 35 9.302W 2100.00 38.39 268.75 1968.29 -11.81 -541.36 6009444.47 550773.78 70 26 11.637 N 149 35 9.717W 2150.00 41.39 268.75 2006.66 -12.51 -573.42 6009443.55 550741.74 70 26 11.630 N 149 35 10.658W 2200.00 44.39 268.75 2043.29 -13.25 -607.43 6009442.57 550707.73 70 26 11.623 N 149 35 11.656W 2250.00 47.39 268.75 2078.09 -14.03 -643.32 6009441.54 550671.86 70 26 11.615 N 149 35 12.709W 2300.00 50.39 268.75 2110.96 -14.85 -680.97 6009440.46 550634.21 70 26 11.607 N 149 35 13.815W 2350.00 53.39 268.75 2141.82 -15.71 -720.30 6009439.33 550594.89 70 26 11.599 N 149 35 14.969W 2400.00 56.39 268.75 2170.57 -16.60 -761.19 6009438.16 550554.02 70 26 11.590 N 149 35 16.169W 2450.00 59.39 268.75 2197.15 -17.53 -803.52 6009436.95 550511.69 70 26 11.581 N 149 35 17.411 W 2500.00 62.39 268.75 2221.47 -18.48 -847.19 6009435.69 550468.04 70 26 11.571N 149 35 18.693W 2550.00 65.39 268.75 2243.48 -19.46 -892.07 6009434.40 550423.17 70 26 11.562 N 149 35 20.010W 2600.00 68.39 268.75 2263.10 -20.46 -938.04 6009433.08 550377.21 70 26 11.552 N 149 35 21.359W 2650.00 71.39 268.75 2280.29 -21.49 -984.98 6009431.74 550330.29 70 26 11.542 N 149 35 22.736W 2700.00 74.39 268.75 2295.00 -22.53 -1032.75 6009430.37 550282.53 70 26 11.531 N 149 35 24.138W H 1_ 8 4 3 5 5 o~,,~/o, VENDOR AL~SK~O ! LA O0 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 012~01 CKO12901P 100. O0 100. O0 PYMT :OMMENTS: Pee~nit To D~ill --ee HANDL[N~ INST: S/H - Teeei Hubb[e X46~8 'IE ATTACHED CHECK IS IN PAYMENT FOR Ill=alS DESCRIED ABOVE. ~[e]~r-*l~ ~ '~ OO, 00 '~ Oo. OD PAY T O. :"The;,,' :ORDER ,: · '~?i!: iii i!i:.:' '~;ii::'.//.i: "",'.i~ii',,<.:i:!iii:~:' i',i;".,": ?'.::!:!?.?: DATE '::::?i'.:?:!!'" :':i!! : ,, :.,:i:.?: '" ,,~':,'.t. r .i:!i':ii~'~oU"T' . : ANCHORAGE AK 99501 · , ,' , WELL PERMIT CHECKLIST COMPANY WELL NAME/ - ,/3/ PROGRAM: exp dev redrll serv ~ wellbore seg . ann. disposal para req FIELD & POOL ..~-z~-- ,~'//~7~:~ INIT CLASS /' ~,~, ,~ ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from ddlling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available' in ddlling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can.be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor string.provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons ..... ..... 19. Casing designs adequate for C, T, B & permafrost ....... Gl ~)L AREA Y' N ~' N Y ~1 Y ~1 Y ~1 Y ~1 Y N. Y N Y N Y N Y N Y N Y N 20. 21. 22. 23. 24. 25. 28. 2~. GEOLOGY 30. 31. 32. UNIT# Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved... ~ ~,~ ~,. . Adequate wellbore separation proposed ....... ; ...... ~ N .... If diVerter required, does it meet regulations ....... .... ' (~ N Drilling .fluid program schematic & equip list adequate .... . ~J N A_ ~ . _ . BOPEs, do they meet regulation .............. '... (~ N _ , ~ . i ' BOPE press rating appropriate; test to Choke manifold complies w/APl RP-53~May 84) ........ (~ N ~ ! ', Work will occur without operation shutdown ........ · · · ~ H_.., . . ' ' Is presence of H2S gas probable ................. Y ~)~-~3c'> ~ '~'""'~'\ ~'-~'"'1 ~, ~'' '' r,~,.~.,~ ~..~,~.%~ ~,.~_~,~ . Permit can be issued wlo hydrogen sulfide measures ..... Y N,/ ' Data presented on potential overpressure zones ....... Y ~ ~ ~, /) ' . Seismic analysis of shallow gas zones... ....... . . . Y/N /L/~,/~ ~ . Seabed condition survey (if off-shore) ............. Contact name/phone for weekly progress reports [exploratory only,] Y N · ON/OFF SHORE ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a Suitable receiving zonei ....... Y N APPR DATE (B) will not contaminate freshwater; or cause ddlling waste Y N to surface; ' ' (C) will not impair mechanical integrity of the well used for disposal; Y" N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circu..mvent 20 AAc 25.252 or 20 AAC 25.412. Y N GEO[_oGY:' ENGINEERIN.~G.:. UlC~nnular COMMISSION: TEbi~ ., c:~msoffice\wordian~diana\checklist (rev. 111011/00) Comments/Instructions: O Z O 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 APPENDIx. ,, No special'effort has been made to chronologically organize this category of information. MP!13008072001SSN.tx~ Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Mon Feb 18 13:18:56 2002 Reel Header Service name ............. LiSTPE Date ..................... 02/02/18 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 02/02/1.8 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MPI-13 500292301200 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 18-FEB-02 MW[) RUN 1 MWD RUN 2 AK-MM-ii130 AK-MM-ii130 M. HANIK M. HANIK D. FERGUSON D. FERGUSON 33 13N 10E 2346 4025 64.12 35.10 OPEN HOLE CASING DRILLERS BIT SIZE {IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 20.000 113.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). Page 1 MP!13008072001SSN.txt MWD RUNS 1 AND 2 WERE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); PRESSURE WHILE DRILLING (PWD); AND ACOUSTIC CALIPER (ACAL). DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED PER E-MAIL FROM D.SCHNORR (GEOQUEST/BP) TO B. BRYANT (SSDS), DATED 2/06/02. MWD DATA ARE CONSIDERED PDC. 5. MWD RUNS 1 AND 2 REPRESENT WELL MPI-13 WITH API#: 50-029-23012-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF l1418'MD/3745'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIV'ED RESISTIVITY SPACING/. SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS. $ EXTRA SHALLOW MEDIUM DEEP File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted al~d clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH CALA 64 0 11334 5 GR 72 0 11372 0 RPD 97 0 11364 5 RPM 9'7 0 11364 5 RPS 97 0 11364 5 RPX 97 0 11364 5 FET 113 5 11364 5 ROP 118 5 11418 0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 64.0 6074.0 2 6074.0 11418.0 Page 2 MPI13008072001SSN. txt $ # REMAR?(S: HERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Tpe ..... Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin 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 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 CALA MWD IN 4 1 68 32 9 Name Service Unit Min Max DEPT FT 64 11418 ROP MIND FT/H 0.6 985.96 GR MWD API 8.19 134.19 RPX MWD OHMM 0.13 1700.95 RPS MWD OHMM 0.14 2000 RPM MWD OHMM 0.16 2000 RPD MWD OHMM 0.13 2000 FET MWD HOUR 0.0875 23.2628 CALA MWD IN 8.8045 19.5256 First Mean Nsam Readi, ng 5741 22709 64 251.633 22600 1.18.5 67.4249 22601 72 18.2879 22536 9'7 22.075 22536 97 27.8662 22536 97 26.1851 22536 97 0.789749 22503 113.5 1.0.7679 20567 64 First Reading For Entire File .......... 64 Last Reading For Eh'tire File ........... 11418 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ...... . .... 1.0.0 Date of Generation ....... 02/02/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Last Reading 11418 11418 11372 1].364 5 11364 5 11364 5 11364 5 11364 5 11334 5 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Page 3 MPI13008072001SSN.t~.~t Curves and log header data for each bit run in separate files. BIT RUN NUMBER: ! DEPTH INCREMENT: .5000 FI LE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CALA 64.0 5992.5 GR 72 0 6027.5 RPX 97 0 6020.5 RPD 97 0 6020.5 RPS 97 0 6020.5 RPM 97 0 6020.5 FET 113 5 6020.5 ROP 118 5 6074.0 $ LOG HEADER DATA DATE LOGGED: 03-AUG-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 6074.0 TOP LOG INTERVAL (FT): 113.0 BOTTOM LOG INTERVAL /FT): 6074.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .7 MAXIMUM ANGLE: 84.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOl, NUMBER DGR DUAL GAMMA 1;tA~ PB02104HWRGV6 EWR4 ELECTROMAG. RESIS. 4 PB02104HWRGV6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (liN): 9.875 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: SPUD MUD DENSITY (LB/G): 9.40 MUD VISCOSITY (S): ].12.0 MUD PH: 9.6 MUD CHLORIDES (PPM): 600 FLUID LOSS (C3): 9.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 7.000 64.0 MUD AT MAX CIRCULATING TERMPERATURE: 5.556 82.4 MUD FILTRATE AT MT': 6.000 64.0 MUD CAKE AT MT: 7.000 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Speci, fication Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical. ].og depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Page 4 Depth Units ....................... Datum Specification Block sub-type.. Name Service Order Units Size Nsam Rep DE PT ET 4 1 68 ROP MWD010 FT/H 4 1 68 GR MWD010 API 4 1 68 RPX MWDOiO OHbiM 4 1 68 RPS MWD010 OHMM 4 1 68 RPM ~D010 OHMM 4 1 68 RPD MWD010 OHMM 4 1 68 FET MWD010 HOUR 4 1 68 CALA MWD010 IN 4 1 68 MPi13008072001SSN. t~.;t .0 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 Name Service Unit Min Max DEPT FT 64 6074 ROP MWD010 FT/H 0.6 803.94 GR MWDO10 API 8.19 134.19 RPX MWD010 OHMM 0.13 1700.95 RPS MWD010 OHMM 0.14 2000 RPM MWDO10 OHMM 0.16 2000 RPD MWDOiO OHMM 0.13 2000 FET MWD010 HOUR 0.1192 7.8036 CALA MWD010 IN 9.0044 1.9.5256 First Reading For Entire File .......... 64 Last Reading For Entire File ........... 6074 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 First Mean Nsam Reading 3069 12021 64 239.985 11912 118.5 62.1864 11912 72 25.2672 11848 97 32.1393 11848 97 42.8362 11848 97 39.4161 11848 97 0.590293 11815 113.5 10.9601 1].858 64 Last Reading 6074 6074 6027 5 6020 5 6020 5 6020 5 6020 5 6020 5 5992 5 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH CALA 5993.0 FET 6021.0 RPD 602]...0 RPM 6021.0 RPS 6021.0 RPX 6021.0 GR 6028.0 ROP 6074.5 STOP DEPTH 11334 5 11364 5 11364 5 11364 5 11364 5 11364 5 113'72.0 11418.0 Page 5 S 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 DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): MPI13008072001SSN.txt 0U-AUG-01 Insite 66.16 Memory 11418.0 6074.0 11418.{i 74.4 83.9 TOOL NUMBER PB02104HWRGV6 PB02104HWRGV6 9.875 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 9.20 MUD 'VISCOSITY (S): 55.0 MUD PH: 8.5 MUD CHLORIDES (PPM): 500 FLUID LOSS (C3): 6.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 5.000 MUD AY' MAX CIRCULATING TERMPERATURE: 3.673 MUD FILTRATE AT MT: 4.500 MUD CAKE AT MT: 4.500 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 .iIN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Units Size Nsam Rep Code Offset Channel Name Service Order 0 1 4 2 8 3 12 4 16 5 2O 6 24 7 28 8 32 9 DEPT FT 4 1 68 ROP MWD020 FT/H 4 1 68 GR MWD020 API 4 1 68 RPX MWD020 OHMM 4 1 68 RPS MWD020 OHMM 4 1 68 RPM MWD020 OHMM 4 1 68 RPD MWD020 OHMM 4 1 68 FET MWD020 HOUR 4 1 68 CALA MWD020 IN 4 1 68 68.0 95.0 68.0 68.0 Page 6 MPI13008072001SSN.txt Name Service Unit Min Max DEPT FT 5993 11418 ROP MWD020 FT/H 1.14 985.96 GR MWD020 API 16.1 128 RPX F~D020 OHMM 1.86 44.82 RPS MWD020 OHMM 1.2 430.29 RPM MWD020 OHMM 0.37 603.99 RPD MWD020 OHMM 0.73 1276.02 PET MWD020 HOUR 0.0875 23.2628 CALA MWD020 IN 8.8045 15.6929 First Mean Nsam Reading 8705.5 10851 5993 264.613 10688 6074.5 73.2628 10689 6028 10.5512 10688 6021 10.9183 10688 6021 11.2715 10688 6021 11.518 10688 6021 1.01024 10688 6021 10.5062 8709 5993 Last Reading !141~ 11417 11371 11364 5 11364 5 11364 5 11364 5 11364 5 11334 5 First Reading For Entire File .......... 5993 Last Reading For Entire File ........... 11418 File Trailer Service name ............. STSL!B.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 02/02/18 Origin ................... STS Tape Name ................ UNKNOWN Continuation Nu~er ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 02/02/18 Origin ................... STS Reel Name ................ UNKNOWN Continuation Nu~er ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scien. tific Technical Services Physical EOF Physical EOF End Of LIS File Page 7 Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Mon Feb 18 13:18:56 2002 Reel Header Service name ............. LISTPE Date ..................... 02/02/18 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 02/02/18 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MM-ii130 M. HANIK' D. FERGUSON 1ST STRING 2ND STRING MPI-13 500292301200 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 18-FEB-02 MWD RUN 2 AK-MM-ii130 M. HANIK D. FERGUSON 2346 4025 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 20.000 113.0 33 13N 10E 64.12 35.10 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1 AND 2 WERE DIRECTIONAL WITH DUAL GAlVIMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); PRESSURE WHILE DRILLING (PWD); AND ACOUSTIC CALIPER (ACAL). 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED PER E-MAIL FROM D.SCHNORR (GEOQUEST/BP) TO B. BRYANT (SSDS), DATED 2/06/02. MWD DATA ARE CONSIDERED PDC. 5. MWD RUNS 1 AND 2 REPRESENT WELL MPI-13 WITH API#: 50-029-23012-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF l1418'MD/3745'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. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH CALA 64.0 GR 72.0 RPD 97.0 RPM 97.0 STOP DEPTH 11334.5 11372.0 11364.5 11364.5 RPS 97.0 RPX 97.0 FET 113.5 ROP 118.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: 11364.5 11364.5 11364.5 11418.0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 64.0 6074.0 2 6074.0 11418.0 MERGED MAIN PASS. $ # 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 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 CALA MWD IN 4 t 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 2O 6 24 7 28 8 32 9 Name Service Unit Min Max DEPT FT 64 11418 ROP MWD FT/H 0.6 985.96 GR MWD API 8.19 134.19 RPX MWD OHMM 0.13 1700.95 RPS MWD OHMM 0.14 2000 RPM MWD OHMM 0.16 2000 RPD MWD OHMM 0.13 2000 FET MWD HOUR 0.0875 23.2628 CALA MWD IN 8.8045 19.5256 Mean Nsam 5741 22709 251.633 22600 67.4249 22601 18.2879 22536 22.075 22536 27.8662 22536 26.1851 22536 0.789749 22503 10.7679 20567 First Reading 64 118.5 72 97 97 97 97 113.5 64 Last Reading 11418 11418 11372 11364 5 11364 5 11364 5 11364 5 11364 5 11334 5 First Reading For Entire File .......... 64 Last Reading For Entire File ........... 11418 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CALA 64 0 5992 5 GR 72 0 6027 5 RPX 97 0 6020 5 RPD 97 0 6020 5 RPS 97 0 6020 5 RPM 97 0 6020 5 FET 113 5 6020 5 ROP 118 5 6074 0 $ LOG HEADER DATA DATE LOGGED: 03 -AUG- 01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 6074.0 TOP LOG INTERVAL (FT) : 113.0 BOTTOM LOG INTERVAL (FT) : 6074.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: .7 MAXIMUM ANGLE: 84.6 TOOL STRING (TOP TO BOTTOM) 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 TOOL NUMBER PB02104HWRGV6 PB02104HWRGV6 9.875 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 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 SPUD 9.40 112.0 9.6 6OO 9.6 7.000 5.556 6.000 7.000 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 CALA MWD010 IN 4 1 68 32 9 64.0 82.4 64.0 70.0 Name Service Unit DEPT FT ROP MWD010 FT/H GR MWD010 API RPX MWD010 OHMM RPS MWD010 OHMM RPM MWD010 OHMM RPD MWD010 OHMM FET MWD010 HOUR CALA MWD010 IN Min Max Mean Nsam 64 6074 3069 12021 0.6 803.94 239.985 11912 8.19 134.19 62.1864 11912 0.13 1700.95 25.2672 11848 0.14 2000 32.1393 11848 0.16 2000 42.8362 11848 0.13 2000 39.4161 11848 0.1192 7.8036 0.590293 11815 9.0044 19.5256 10.9601 11858 First Reading 64 118.5 72 97 97 97 97 113.5 64 Last Reading 6074 6074 6027 5 6020 5 6020 5 6020 5 6020 5 6020 5 5992 5 First Reading For Entire File .......... 64 Last Reading For Entire File ........... 6074 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH CALA FET RPD RPM RPS RPX GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 5993 0 6021 0 6021 0 6021 0 6021 0 6021 0 6028 0 6074 5 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 11334 5 11364 5 11364 5 11364 5 11364 5 11364 11372 11418 TOOL STRING (TOP TO BOTTOM) 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) : 07-AUG-01 Insite 66.16 Memory 11418.0 6074.0 11418.0 74.4 83.9 TOOL NUMBER PB02104HWRGV6 PB02104HWRGV6 9.875 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 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 LSND 9.20 55.0 8.5 500 6.4 5.000 3.673 4.500 4.500 Name Service Order Units Size Nsam Rep Code Offset DEPT FT 4 1 68 ROP MWD020 FT/H 4 1 68 GR MWD020 API 4 1 68 RPX MWD020 OHMM 4 1 68 RPS MWD020 OHMM 4 1 68 RPM MWD020 OHMM 4 1 68 RPD MWD020 OHMM 4 1 68 FET MWD020 HOUR 4 1 68 CALA MWD020 IN 4 1 68 Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 68.0 95.0 68.0 68.0 Name Service Unit Min Max DEPT FT 5993 11418 ROP MWD020 FT/H 1.14 985.96 GR MWD020 API 16.1 128 RPX MWD020 OHMM 1.86 44.82 RPS MWD020 OHMM 1.2 430.29 RPM MWD020 OHMM 0.37 603.99 RPD MWD020 OHMM 0.73 1276.02 FET MWD020 HOUR 0.0875 23.2628 CALA MWD020 IN 8.8045 15.6929 Mean Nsam 8705.5 10851 264.613 10688 73.2628 10689 10.5512 10688 10.9183 10688 11.2715 10688 11.518 10688 1.01024 10688 10.5062 8709 First Reading 5993 6074.5 6028 6021 6021 6021 6021 6021 5993 Last Reading 11418 11418 11372 11364 5 11364 5 11364 5 11364 5 11364 5 11334 5 First Reading For Entire File .......... 5993 Last Reading For Entire File ........... 11418 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 02/02/18 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Reel Trailer Service name ............. LISTPE Date ..................... 02/02/18 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File