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197-117
1 Regg, James B (OGC) From:Darci Horner - (C) <dhorner@hilcorp.com> Sent:Friday, April 1, 2022 7:38 AM To:Regg, James B (OGC) Cc:Brooks, Phoebe L (OGC) Subject:RE: [EXTERNAL] RE: MIT-IAs for Milne Point wells G-05, G-09 and H-15 Attachments:MIT MPU G-09 3-10-2022 pre injection.xlsx Yes, I found this one done on Mar 10, Jim. From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Thursday, March 31, 2022 6:38 PM To: Darci Horner ‐ (C) <dhorner@hilcorp.com> Subject: [EXTERNAL] RE: MIT‐IAs for Milne Point wells G‐05, G‐09 and H‐15 Was there a pre‐injection MIT done? Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907‐793‐1236 From: Darci Horner <dhorner@hilcorp.com> Sent: Wednesday, March 16, 2022 3:31 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Cc: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com>; Jon Arend <Jon.Arend@hilcorp.com>; David Gorm <dgorm@hilcorp.com>; Alaska NS ‐ Milne ‐ Wellsite Supervisors <AlaskaNS‐Milne‐WellsiteSupervisors@hilcorp.com>; Alaska NS ‐ Wells Foreman <PBWellsForeman@hilcorp.com> Subject: MIT‐IAs for Milne Point wells G‐05, G‐09 and H‐15 All, Milne Point wells G‐05 (PTD # 1910230), G‐09 (PTD # 1971170) and H‐15 (PTD # 2051590) successfully passed routine MIT‐IAs on March 8 and 13, 2022. G‐05 and G‐09 are both recently returned to injection after being shut in. Please call myself or Jerimiah Galloway (907‐564‐5005) with any questions. Regards, Darci Horner Technologist CAUTION: 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. MPU G-09 PTD 1971170 2 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. 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. Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1971170 Type Inj W Tubing 78 82 82 83 Type Test P Packer TVD 4035 BBL Pump 3.0 IA 0 1765 1723 1721 Interval 4 Test psi 1500 BBL Return 2.0 OA Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Hilcorp Alaska, LLC Milne Point / MPU / G PAD Derek Weglin 03/10/22 Notes:Returning to injection. G-09 is a monobore. Notes: Notes: Notes: G-09 Form 10-426 (Revised 01/2017)2022-0310_MIT_MPU_G-09 J. Regg; 4/1/2022 CAUTION: 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:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Injector MPU G-09 (PTD# 197-1170) Date:Monday, March 14, 2022 3:03:49 PM Attachments:image001.png image002.png From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Tuesday, March 8, 2022 2:24 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov>; David Haakinson <dhaakinson@hilcorp.com> Subject: OPERABLE: Injector MPU G-09 (PTD# 197-1170) Mr. Wallace, PW Injector MPU G-09 (PTD# 197-1170) is currently shut in with plans to return to injection. The well was shut in July 2016 and has remained shut in since. The last witnessed MIT passed to 2010 psi in March 2013. Since the well has been shut in, it missed the last scheduled MIT. The well is classified as OPERABLE. Plan Forward 1. AOGCC Pre-Injection MIT-IA 2. AOGCC Post Injection MIT-IA (Upon stabilization) Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 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, thenpromptly 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. • • Brooks, Phoebe L (DOA) PfDi . M i t IV From: AK, D &C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator @bp.com] Sent: Tuesday, March 12, 2013 3:39 PM To: Brooks, Phoebe L (DOA) Subject: RE: Under Evaluation: Injector MPG -09 (PTD #1971170) Ready For Water Injection Attachments: Injector MPG -09 (PTD #1971170) MIT Form.xls; Injector MPG -09 (PTD #1971170) Wellbore Schematic.pdf Phoebe, The wellbore schematic is attached, as well as the revised MIT form with the corrected Type Inj field. I also changed the packer TVD on the form, as our system had the incorrect depth. The well was worked over in August of 2008, and our system still had the old packer depth. I verified the schematic packer depth (7788' MD, 4035' TVD) is correct from the rig workover tubing tally. I apologize for the oversight. Thank you for catching the mistakes. Please let me know if there is anything else you need. Thank you, SCANNED APR 0 9 2013 Jack Disbrow GWO Well Integrity Coordinator 907 - 659 -5102 From: Brooks, Phoebe L (DOA) [mailto:phoebe.brooks@alaska.gov] Sent: Tuesday, March 12, 2013 12:04 PM To: AK, D &C Well Integrity Coordinator Subject: RE: Under Evaluation: Injector MPG -09 (PTD #1971170) Ready For Water Injection Jack /Laurie, Will you please send a recent schematic for MPU G -09? It appears the Packer TVD we have in our database differs from the one included on the report. Also, the Type Inj. field can only reflect the codes included in the legend (D, G, 1, N, W)...please advise so I can update the report. Thank you, Phoebe Phoebe Brooks Statistical Technician 11 Alaska Oil and Gas Conservation Commission Phone: 907 - 793 -1242 Fax: 907 - 276 -7542 From: Regg, James B (DOA) Sent: Monday, March 11, 2013 9:26 AM To: Brooks, Phoebe L (DOA) Subject: FW: Under Evaluation: Injector MPG -09 (PTD #1971170) Ready For Water Injection MIT 1 • • Tree:4- 1/16 " - 5M FMC Q _ Orig. KB elev. = 58.20 (N22E) Wellhead: 11"-5M Monobore 0 " Orig. GL elev. = 29.20 (N22E) w/ 4.5" FMC Tbg. Hng , NSCT lift threads,4.5" CIW H BPV profile 20 ", 91.1 #,H -40 conductor 112' 0 7" HES cementer 1931' KOP @ 500' 3.5" HES "X" Nipple 2304' Max. hole angle = 70 to 78 deg. 2.81" ID. f/ 3300' to 8250' / Hole angle thru' perfs = 72 deg riN Val °' ,rt SPM /AN: , - ::Arla i:• Me tit s o 8 3.5 ", 9.3 #, L -80 8rd EUE Tubing ID= 2.992, Cap =.0087 bpf 7 ", 26 #, L -80, BTC casing Casing ID= 6.276, Cap = .0264 bpf X 7 "x 21' Marker joint. 7588' L 1 3.5" HES "X" Nipple 7736' SBHP % 2.813" ID. NB sands on 10/2/08 @ 4053' TVD was 2106 psi. 7" Baker Premier Packer 7788' 2.870" ID OA sands on 11/29/08 @ 4254' TVD was 1976 psi. 3 x 1 1/2" MMG GLM 7907' NOTE The P -15 set r@ 7968` on A ngle @ SPM 77° 8/21/0:9 has a check valve Perforation Summary: ` , 3.5" x 1 1/2" MMG -W GLM 7968' Tie in log: SWS USIT 2/20/98 u Angle @SPM — 77° r a _ 7" Baker Premier Packer 8057' Size SPF Interval (TVD) 2.870" ID NB Sands 3.5" x 1 1/2" MMG -W GLM 8146' 2" 4 7870' -7890' 4053' -4058' Angle @ SPM — 74 4.5" 5 7890' -7980' 4058' -4077' 3.5" HES "XN" Nipple OA Sands 2.750" No -Go ID 8206' 2" 6 8420' -8460' 4202' -4215' 2" 4 8440' -8460' 4209' -4215' a WLEG 8250' 2" 6 8500' -8536' 4227' -4239' 2" 4 8500' -8520' 4227' -4234' 1 1 TD Tag with CTU 3/23/08 @ 8570' 4.5" 5 8659' -8739' 4275' -4300' CIBP set @ 8580' Q IBT pushed to 8615' 2" Powerjet guns, 60 deg. phasing 4 -sp 7 ", landing collar 8863' deep penetrating charges 7 ", 26# L -80 Buttress 8945' DATE REV. BY COMMENTS 07/06/97 M. Linder Nabors 22 -E MILNE POINT UNIT 02/22/98 M. Linder Nabors 4 -ES WELL: MPU -G -09i 7/25/02 MDO CTU Baker IBP W/ Gel and Cement cap. API NO: 50 - 22779 11/8/08 L. Hulme Recomplete & Add Perfs w/ Nabors 3S. • BP EXPLORATION (AK) 3/24/09 L. Hulme Add Perf/Formation Acid with CTU • • c p c _\ ) AIRE [][F nII,ASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMIIIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Alecia Wood Production Engineer BP Exploration (Alaska), Inc. � P.O. Box 196612 r �` Anchorage, AK 99519 -6612 Re: Milne Point Field, Schrader Bluff Oil Pool, MPG -09 Sundry Number: 312 -303 5044ED Air G . 3 2 Dear Ms. Wood: 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, ate Cathy . Foerster Chair `- DATED this 7 - day of August, 2012. Encl. • 0 Av/ RECEIVED /LA STATE OF ALASKA llik ALASKA OIL AND GAS CONSERVATION COMMISSION AUG 0 6 2012 APPLICATION FOR SUNDRY APPROVALS nnnn 20 AAC 25.280 A ®GCC 1. Type of Request: Abandon ❑ Plug for Redrill ❑ P rforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations J t .ePerforate ❑ Pull Tubing Q Tj('ne_Exxe sio�❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ 4 Stimulate 1:1 Alter Casing ❑ Other. t5 " D4 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 197 -117 -0 • 3. Address: Stratigraphic ❑ Service © 6. API Number: P.O. Box 196612, Anchorage, AK 99519 -6612 50 -029- 22779 -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: Spacing Exception Required? Yes ❑ No El MPG -09 - 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL0025518 • MILNE POINT, SCHRADER BLFF OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8970 • 4370 . 8580 4252 8580 8614 Casing Length Size MD TVD Burst Collapse Structural Conductor 83 20" 91.1# H -40 29 - 112 29 - 112 Surface None None None None None None Intermediate None None None None None None Production 8917 7" 26# L -80 28 - 8945 28 - 4362.23 7240 5410 Liner None None None None None None Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment See Attachment 3 -1/2" 9.3# L -80 L -80 27 - 8250 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD (ft) and TVD (ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12. Attachments: Description Summary of Proposal 12 13. Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Development n Service n • 14. Estimated Date for 15. Well Status after proposed work: 8/21/12 Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ 0 • 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 Prepared by Garry Catron 564 -4424 Printed Name Alecia Wood 564 -5492 Title Production Engineer Signature Phone Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 2. -303 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 1 Subsequent Form Required: / b® No4 � ' APPROVED BY Approved by: 6 f � j ,7 � COMMISSIONER THE COMMISSION Date: 8 • (- l �. Form 10 -403 R RB MS AUG 10 20 Vii' y am- g•8� �L S i Duplicate r �,w OR IGINAL ��' • • Perforation Attachment ADL0025518 Well Date Perf Code MD Top MD Base TVD Top TVD Base MPG -09 4/1/09 STO 7870 7890 4053 4058 MPG -09 4/1/09 STO 7890 7980 4058 4077 MPG -09 4/1/09 STO 8420 8440 4202 4209 MPG -09 4/1/09 STO 8440 8460 4209 4215 MPG -09 4/1/09 STO 8500 8520 4228 4234 MPG -09 4/1/09 STO 8520 8536 4234 4239 MPG -09 11/4/08 BPS 8659 8679 4276 4282 MPG -09 11/4/08 BPS 8679 8699 4282 4288 MPG -09 11/4/08 BPS 8699 8719 4288 4294 MPG -09 11/4/08 BPS 8719 8739 4294 4300 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BRIDGE BPS PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL . STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • • Packers and SSV's Attachment ADL0025518 Well Facility Type MD Top Description TVD Top MPG -09 PACKER 7788 3 -1/2" Baker Premier Packer 4035 MPG -09 PACKER 8057 3 -1/2" Baker Premier Packer 4096 • bP To: Mark O'Malley /Rob Handy Date: July 06, 2012 MPU Ops Team Leaders From: Alecia Wood, MPU Schrader Pad Engineer 907 - 564 -5492 Subject: MPG -09 MBE Treatment Step Unit Operation 1 F Shut in all offset producers. Bullhead water into MPG -09 2 F Bullhead treatment down MPG -09 (NB sand). Keep well and offset producers and injectors shut in for the duration of the treatment and flow producers to a tank before returning to production if necessary. Objective Divert water by sealing the preferential path of injection with a cement acting fluid and a rigid gel. - Measure of success 1. Treatments are displaced into formation. 2. Post injection is adequate to achieve injection rate target at below target pressure. 3. Decrease of watercut over time in offset producers is observed. Critical Issues 1. Ensure pumping pressure is not above the fracture gradient. . 2. Ensure cleanliness of pump equipment and hard line (pre and post job) & properly dispose of remnant fluid per guidance from the Environmental Team. Background MPG -09i was drilled as an injector in July 1997 by Nabors 22E, but was not completed until February 1998. The OB sands were perforated for a PFO study, with the N and OA perforations added in September 1999. In July 2002 the OA and OB were isolated for N sand only injection. In 2008 the well was recompleted as a regulated injector in the N and OA sands. The cement cap over the OA and OB was drilled out and the IBP pushed to bottom. A CIBP was set to isolate the OB, 90' of additional N -sand perfs were added, and a selective completion was run. In December 2008 an unsuccessful attempt was made to clear any obstruction in the tubing and valves by increasing the injection pressure to 1,500 psig. In March 2009, the OA zone was re- perforated and acidized. This work increased the injectivity of the OA zone to suitable levels to support MPH -19. This injector supports MPH -13 (75 bopd) in the N sand and MPH -19 (100 bopd) in the OA. MPH -13 is SI due to solids production and lack of support. MPG -09 is the only injector that supports MPH -13 and is SI due to the MBE connection between the two, confirmed by a positive pulse test and water cut increase in May 2011. MPH -19 is SI for a failed ESP. • • PROCEDURE S ° Stage 1. Injection Test O rds-d 1. RU, hold pre -job safety meeting, PT surface lines 2. Ensure offset producers are SI. 3. Spear in with Methanol, followed by produced water. Attempt to hold injection rate constant while adjusting pressure as needed. 4. Contact Engineering to discuss the injection pressure /rate trends. Once consensus is achieved that the fluid can be successfully placed into formation at acceptable rate /pressure continue with remainder of program. Stage 2. Treatment 5. Ensure offset producers are offline 6. Pump produced water pre -flush followed by cement acting fluid treatment and diesel displacement. Allow setup time. 7. Pump produced water pre -flush followed by high volume gel treatment and diesel over flush. 8. Capture a gel sample at surface and suspend in a warm water bath (to simulate downhole conditions) to monitor actual setting time. 9. Rig down all equipment and hold post -job assessment meeting to capture (earnings to be incorporated into future jobs. 10. Forward all post job assessments (w/ all rheology test summary) and continuous pressure and rate data from job to Pad Engineer. • • Tree4-1116"- 5MFMC M P U G -09 Ong KB elev, = 58.20 (N22E) Wellhead: 11"-5MMonotiore Orig. GL. elev. = 29_20 (N22E) w! 4.5" FMC Tbg. Hng , NSCT lift threads,4.5" OW H BPV profile 20", 91.1 #,H-40 conductor i 12 I] 7" HES cementer I 1931' 3.5' Kop 500' HES *X' NOpie I 2304' a 2.81' la Max hole angle = 70 to 78 deg 5 3300 to 8250' Hole angle thru' perfs = 72 deg Valves in SPM / XN: Arrangement as of 8/21A19 3.5", 9•3#, L-80 8rd EUE Tubing ID= 2.992, Cap =0087 bpf T, 26#, L-80, BTC casing 7"x 21 Marker joint I 7588 Casing ID= 6.276. Cap = 0264 bpf 3.5' HES "X" Nipple I 7736' SBHP 2.813" ID. NB sands on 10/2(08 4053' -1 '','0 was 2106 psi 7" Baker Premier Packer 7788' wwwwwwww■w4 2.870 ID OA sands on 11/29/08 a) 4254 T:: al was 1976 poi I • I A 3.9" e x a 1 5 112 :1 ki i7. NIG GL, 7907' 4 NOTE The P-15 set a 7968' on I np 8 8/21/09 has a check valve - -----__ 4 6 Perforation Summary: 1 112" M'i . W GLM I Angle a SPM - 17 Tie in log: SWS USIT 2/20/98 IIII _ , 7 Size SPF Interval (TVD) 1146 II 2 : 8 8 70 ate e r Premier Packer 805T NFI Sands 3 5" x 1 1/2" MMG-W GLM 2 4 7870'-7890" 4053-4058 Angle a SPM - 74. I 8146' 4.5" 5 7890'-7980' 4058'-4077' 3.5 I-4ES "MT ttippee (3A Sands 2150' No-Go ID I 8206' 2° 6 8420'-8460' 4202'.41215 2" 4 8440'-8460' 4209-4215 NI I 8250' 2" 6 8500 I . -8536' 422T-4239' I 2" 4 8500'-8520' 4227-4234s I 1 TD Tag with CTU 3123/08 © 8570' 4.5" 5 8659.-8739 4275-4300' - . . - CIBP set a 11680` - 1 ---- IBT pushed to 8615' 2" Powerjet guns, 60 deg. phasing 4-p I I 7", landing collar 8863 deep penetrating charges 7", 26# L-80 Buttress 8945' i. il7E REV BY COMMENTS MILNE POINT UNIT M Linder Nat0f5 ,11-t 02122 'A Linos' Nabors 4-ES WELL: MPU-G-09i 7/2902 MDO CTU Baker 1BP Wi Gel and Cement cap. API NO: 50 11/8/08 _ Hulme Recorriplete & Add Pels wi Nabors 3S. BP EXPLORATION (AK) a 9 .. Hahne Add Perf1Fomvation Acid with CTU • bp BP Exploration (Alaska) Inc. 0 Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 S' [ ED FEB 9 ti IZ Mr. Tom Maunder I / I C I t V Alaska OiI and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 ( 1 Subject: Corrosion Inhibitor Treatments of MPG -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPG -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • 0 . BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10.404) MPG -Pad 10/10/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal MPG -01 1890290 50029219270000 Tanko conductor NA NA NA NA NA MPG -02 1890280 50029219260000 Tanko conductor NA NA NA NA NA MPG -03A 2042190 50029219420100 Tanko conductor NA NA NA NA NA MPG-04 1890450 50029219410000 Tanko conductor NA NA NA NA NA MPG -05 1910230 50029221380000 1.1 NA 1.1 NA 5.1 8/14/2011 MPG -07 1910250 50029221400000 0.1 NA 0.1 NA 3.4 9/4/2011 MPG -08A 1930480 50029221410100 0.2 NA 0.2 NA 2.6 10/10/2011 ' 3' MPG -09 1971170 50029227790000 1.3 NA 1.3 NA 15.3 10/30/2009 MPG -10 1971180 50029227800000 2.1 NA 2.1 NA 20.4 10/30/2009 MPG -11 1971190 50029227810000 0.8 NA 0.8 NA 5.1 8/14/2011 MPG -12 1971420 50029227920000 1.3 NA 1.3 NA 8.5 8/14/2011 MPG -13 1971200 50029227820000 1.2 NA 1.2 NA 10.2 10/30/2009 MPG -14 2011330 50029230310000 0.8 NA 0.8 NA 4.3 9/4/2011 MPG -15 1971220 50029227840000 2.9 NA 2.9 NA 34.0 10/30/2009 MPG -16 2032100 50029231890000 1.8 NA 1.8 NA 17.0 8/15/2011 MPG -17 2040130 50029231920000 1.6 NA 1.6 NA 14.5 8/15/2011 MPG -18 2040200 50029231940000 1.6 NA 1.6 NA 13.6 8/15/2011 MPG -19 2041920 50029232280000 1.6 NA 1.6 NA 13.6 8/15/2011 WELL LOG �. TRANSMITTAL PwActiw DiAgNOSTic S ERVICES, INC. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793 -1225 RE: Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following: BP Exploration (Alaska), Inc. Petrotechnical Data Center _ Attn: Joe Lastufka LR2 -1 900 Benson Blvd. Anchorage, Alaska 99508 n c7 ®� - o (o G aU 3 6 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road NO 2 Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 ff2)l nilection Profile 29- Au g -10 MPU G09 BL / ED E " 50 -029 22779 -00 Profile 01-Sep-10 MPU H -17 BL / EDE 0 9 -2335 0 Signed: - Date : " Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAx: (907)245 -88952 E- MAIL: pd1sanchorageamemoryloa.com WESSITE : www.memorylog.com C1Documents and Settinp\Diane Williams \Desktop \Transmit_BP.docx ~ ~ _-~=-_--~-.,~ ~ ~ ~ ~ ~eoAcrive ~iaqnosTic Seevic~s, ~rvc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907] 793-'1225 RE : Cased Hole/Open Hole/Mechanical Logs and/orTubing Inspection(Caliper/ MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : BP Exploration (Alaskaj, Inc. Petrotechnical Data Center Attn: Joe Lastuflca LR2-1 900 Bensan Blvd. Anchorage, Alaska 99508 and ~ ~°r~ -t ~~` i~33~ ~~ v~~C ( Qi~--l~~ C ~~~~ ProActn+e Diagnostic Services, lnc. Attn: Robert A. Richey 130 West International Airport Road r z~ ~ t~'~ + A~ ~'s ( 7 ~ , Suite C ~~ . _ . ' f.~~~ Anchorage, AK 99518 Fa~c (907) 245-8952 1) Injection Profile 03-Jun-09 MPG13 BL / E~ 50-029-22782-00 2J Injection Profile 05,JuF09 MPG09 BL / EDE;-- , 50-0~~2~779-00 z - ~ F Signed : Date : - __ -- Print Name: PROACTIVE DIA6NOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUtTE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-88952 E-MAIL : °„ - - WEBSITE ° ' C:~Documen~ and Settings\Owner~Desktop\Transmi[_BP.docx • To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 and RE : Cased Hoie/Open Hole/Mechanical Logs and/or7ubing Inspection[Caliper/ MTTj The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastulfka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 ProActive Diagnostic Services, Inc. ~~ ~ c7c~ ~ j ~ ~ ~ 3 Attn: Robert A. Richey 130 West International Airport Road Anchorage, AK 99518 ~°~""~" ~`t~ Fax: (907j 245-8952 1 ~ Coil Flag 22-Mar~09 MP G09 Color Log / Eft 50-029-22779 2) Leak DEtection - STP 22-Mar09 MPS-19A ,~ Signed : ~~ Print Name: Color Log / EDE 50-029-23121.-01 Date : ,' PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-RAAIL : _- ---_-~ - ~ > __ ~~. WEBSRE _ _~ ,__ C:\Documents and Settings\[7wner\Desktop\Transmit_BP.docx STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS -z~ -~ X09' ~~ ~~~. 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated Other ~ "7 ~,- ,.; Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Ext Change Approved Program ~ Operat. Shutdown ~ Perforate Q - Re-enter Suspended Well fi ~ t ar; '' 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: fiu;±: Name: Development r Exploratory ~ 197-1170 - 3. Address: P.O. Box 196612 StratlgraphiC SerVICe - 6. API Number: Anchorage, AK 99519-6612 50-029-22779-00-00- 7. KB Elevation (ft): 9. Well Name and Number: 58.2 KB - MPG-09 8. Property Designation: 10. Field/Pool(s): _ ADLO-025518 - MILNE POINT UNIT Field/ SCHRADER BLUFF OIL Pool 11. Present Well Condition Summary: Total Depth measured 8970 ' feet Plugs (measured) 8615 true vertical 4369.69 ~ feet Junk (measured) None Effective Depth measured 8863 feet true vertical 7338 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.1# H-40 SURFACE - 112' SURFACE - 112' 1490 470 Production 8915 7" 26# L-80 SURFACE - 8945' SURFACE - 4362' 7240 5410 ~~,.vr~`j~rllf~ f~~~P4 ~~ ~1JU~1 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 3-1 /2" 9.3# L-80 SURFACE - 7575' 0 0 - Packers and SSSV (type and measured depth) 7" BAKER S-3 7788' 7" BAKER S-3 8057' 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 742 710 Subsequent to operation: 1245 748 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory Development " Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas ~ WAG ~ GINJ ~ WINJ ~'- WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309-040 Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 4/7/2009 Form 10-404 Revised 04/2006 ~ ( ~ . p y ~ '~ ~ y ~=} ~1"'~ ~ ~~~~ `' Submit Oyig~~nly _L(J//7 MPG-09 197-117 PFRF OTTOCHMF_NT • Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPG-09 2/20/98 PER 8,699. 8,719. 4,287.96 4,294.13 MPG-09 2/20/98 PER 8,719. 8,739. 4,294.13 4,300.27 MPG-09 2/21/98 PER 8,659. 8,679. 4,275.7 4,281.8 MPG-09 2/21/98 PER 8,679. 8,699. 4,281.8 4,287.96 MPG-09 9/1/99 RPF 7,870. 7,890. 4,053.43 4,057.78 MPG-09 9/1199 RPF 8,440. 8,460. 4,208.72 4,215.03 MPG-09 9/1/99 RPF 8,500. 8,520. 4,227.55 4,233.75 MPG-09 7/24/02 BPS 8,310. 8,320. 4,168.42 4,171.42 MPG-09 7/25/02 BPS 8,160. 8,243. 4,123.81 4,148.28 MPG-09 11/1/08 BPP 8,160. 8,243. 4,123.81 4,148.28 MPG-09 11/2/08 BPP 8,310. 8,320. 4,168.42 4,171.42 MPG-09 11/2/08 BPS 8,615. 8,620. 4,262.46 4,263.95 MPG-09 11/6/08 PER 7,890. 7,980. 4,057.78 4,077.47 MPG-09 3/23/09 APF 8,440. 8,460. 4,208.72 4,215.03 MPG-09 3/23/09 APF 8,500. 8,536. 4,227.55 4,238.67 MPG-09 3/24/09 APF 8,420. 8,440. 4,202.37 4,208.72 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED 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 ~ i MPG-09 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 3/23/2009 CTU #5 w/ 1.75" OD CT. Objective: adperfs. Job continued from WSR 03/22/09. Log memory GR/CCL from 8570' - 7450' ctmd. Pull to surface, ,confirm good data. Log has 0' correction (Ref: SLB USIT:GR/TENS/CCLU, Feb - 20 - 1998). MU and RIH with gun run #1:36' of 2.0" OD PJ Omega 2006, 6 spf, 60 degree phasing SLB TCP perforating guns. Correct to bottom shot .depth at flag. Fire guns from 8500' to 8536' MD. At surface, all shots fired. i MU and RIH wi gun run o J Omega 2006, 6 spf, 60 degree phasing SLB TCP perforating guns. Correct to bottom shot depth at flag. Fire guns from 8440' to 8460' MD. At surface, all shots fired. MU and RIH with gun ~ ;run o .0" OD PJ Omega 2006, 6 spf, 60 degree phasing SLB TCP {perforating guns. Job continued on WSR 03/24/09. _ ~~__..__.~_.~.. 3/24/2009~CTU #5 w/ 1.75" OD CT. Objective: adperfs. Job continued from WSR 03/23/09. Correct depth and fire guns from 8420' - 8440' MD (ref: SLB USIT: I j GR/TENS/CCLU, Feb-20-19 u o su ace, all shots fired. Conduct jweekly BOPE test. MU and RIH with 2.15" side jet nozzle. Tag and correct to ' I~CIBP. Jet 12.4 bbls DAD acid while reciprocating across interval 8540'to X8420'. No increase in infectivity noted during acid stage. Overdisplace acid ,with 74 bbls 2% KCL. Freeze protect coil with 35 bbls 60/40 methanol. POOH. OOH. Notify operator of well status. RDMO. *'"*Job Complete'"** FLUIDS PUMPED BBLS 77 60/40 METH 74 2% KCL 12.4 DAD ACID 163.4 Total STATE OF ALASKA R ~ 1 2~C1~ ~~9 ALASK~L AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OP~~'c~Si Cony. Cammission ~ ~[~~9 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated her ACIDIZE Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ - Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory ~~ 197-1170- 3. Address: P.O. Box 196612. Stratigraphic ~ Service ~- 6. API Number: Anchorage, AK 99519-6612 50-029-22779-00-00 . 7. KB Elevation (ft): 9. Well Name and Number: 58.2 KB - MPG-09 - 8. Property Designation: 10. Field/Pool(s): ADLO-025518 - Milne Point Unit Field/ Schrader Bluff Oil Pool 11. Present Well Condition Summary: Total Depth measured 8970 ' feet Plugs (measured) 8615 true vertical 4369.69 - feet Junk (measured) None Effective Depth measured 8863 feet true vertical 7338 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 Surface - 112 Surface - 112 1490 470 Production 8915 7" 26# L-80 Surface - 8945 Surface - 4362 7240 5410 .31i `ii ~i :~:c ~ ~ ~ t 1 f ~ . , , Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 3-1 /2" 9.3# L-80 SURFACE - 7575' 0 0 - Packers and SSSV (type and measured depth) 7" BAKER S-3 7788' 7" BAKER S-3 8057' 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 742 710 Subsequent to operation: 490 928 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory r Development 6~° Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas Ta WAG GINJ WINJ WDSPL 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: 309-040 Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 3/31/2009 ~ ~ Form 10-404 Revised 04/2006 ~'~, ~?'~ (~ ~`~ r~i)G Submit Ori~al O~ MPG-09 197-117 PERF ATTOrNMFNT n U Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPG-09 2/20/98 PER 8,699. 8,719. 4,287.96 4,294.13 MPG-09 2/20/98 PER 8,719. 8,739. 4,294.13 4,300.27 MPG-09 2/21/98 PER 8,659. 8,679. 4,275.7 4,281.8 MPG-09 2/21/98 PER 8,679. 8,699. 4,281.8 4,287.96 MPG-09 9/1/99 RPF 7,870. 7,890. 4,053.43 4,057.78 MPG-09 9/1/99 RPF 8,440. 8,460. 4,208.72 4,215.03 MPG-09 9/1/99 RPF 8,500. 8,520. 4,227.55 4,233.75 MPG-09 7/24/02 BPS 8,310. 8,320. 4,168.42 4,171.42 MPG-09 7/25102 BPS 8,160. 8,243. 4,123.81 4,148.28 MPG-09 11/1/08 BPP 8,160. 8,243. 4,123.81 4,148.28 MPG-09 11/2/08 BPP 8,310. 8,320. 4,168.42 4,171.42 MPG-09 11/2/08 BPS 8,615. 8,620. 4,262.46 4,263.95 MPG-09 11/6/08 PER 7,890. 7,980. 4,057.78 4,077.47 MPG-09 3/23/09 APF 8,440. 8,460. 4,208.72 4,215.03 MPG-09 3/23/09 APF 8,500. 8,536. 4,227.55 4,238.67 MPG-09 3/24/09 APF 8,420. 8,440. 4,202.37 4,208.72 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED 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 MPG-09 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 3/22/2009 CTU #5 w/ 1.75" OD CT. MIRU CTU. Job Scope Add Perf./Acid Wash. Make up and RIH with WFD MHA and PDS GR/CCL in 2.20" OD carrier. Job continued on WSR 03/23/09. 3/23/2009CTU #5 w/ 1.75" OD CT. Objective: adperfs. Job continued from WSR 03/22/09. 'Log memory GR/CCL from 8570' - 7450' ctmd. Pull to surface, confirm good data. ;Log has 0' correction (Ref: SLB USIT:GR/TENS/CCLU, Feb - 20 - 1998). MU and 'RIH with gun run #1:36' of 2.0" OD PJ Omega 2006, 6 spf, 60 degree phasing SLB TCP perforating guns. Correct to bottom shot depth at flag. Fire guns from 8500' to 8536' MD. At surface, all shots fired. MU and RIH with gun run #2: 20' of 2.0" SOD PJ Omega 2006, 6 spf, 60 degree phasing SLB TCP perforating guns. Correct ~ to bottom shot depth at flag. Fire guns from 8440' to 8460' MD. At surface, all shots fired. MU and RIH with gun run #3: 20' of 2.0" OD PJ Omega 2006, 6 spf, i60 degree phasing SLB TCP perforating guns. Job continued on WSR 03/24/09. 3/24/2009`CTU #5 w/ 1.75" OD CT. Objective: adperfs. Job continued from WSR 03/23/09. Correct depth and fire guns from 8420' - 8440' MD ref: SLB USIT: GR/TENS/CCLU, Feb-20-1998. u to surface, all shots fired. Conduct weekly BOPE test. MU and RIH with 2.15" side jet nozzle. Tag and correct to CIBP. Jet 12.4 bbls DAD acid while reciprocating across interval 8540' to 8420'. No increase in infectivity noted during acid stage. Overdisplace acid with 74 bbls 2% KCL. Freeze protect coil with 35 bbls 60/40 methanol. POOH. OOH. Notify operator of well status. RDMO. **"Job Complete'`** FLUIDS PUMPED BBLS 12.4 DAD ACID 74 2% KCL 35 60/40 METH 121.4 Total WELL LOG TRANSMITTAL To: State of Alaska February 19, 2009 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Data MPG-09 AK-MW-70189 1 LIS formatted CD with verification listing. API#: 50-029-22779-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 s ~-~ ~ ~- ~` 1! Date: Signed: Bryan.Burinda@halliburton.com WELL LOG TRANSMITTAL • To: State of Alaska February 6, 2009 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Data MPG-09 AK-MW-70189 1 LIS formatted CD with verification listing. API#: 50-029-22779-00 ~`. ~~~~~.~~ ~.~~ ~, 4~ ~~~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 1`3«-a~ lurton.com ~` ~ :~ BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: Signed: l ~ ~~ l °f~.- ~ I ~ ~~.~~ I WELL LOG TRANSMITTAL To: State of Alaska January 16, 2009 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: MPG-09 AK-MW-70189 MPG-09: _. 2" x 5" MD Resistivity & Gamma Ray Logs: 1 Color Logs 50-029-22779-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 1 Color Logs 50-029-22779-00 -- ~- ~, € Digital Log Images: 1 CD Rom 50-029-22779-00 RE-ISSUE, THIS REPLACES THE ORIGINAL LOG AND MERGED DIGITAL DATA SET ISSUED 09-SEP-1997. THE ORGINAL DATA SET UTILIZED MWD AS PRIMARY DEPTH CONTROL AS PER MARK VANDERGON OF BP EXPLORATION (ALASKA), INC TO ALI TURKER OF SPERRY-SUN DRILLING SERVICES 08-SEP-1997. RE-ISSUED LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED HOLE GAMMA RAY LOG RUN ON 20-FEB-1998. THESE DIGITAL DATA WERE PROVIDED BY D. DORTCH (SAIC/BP) ON 18-DEC-2008. LOG HEADER AND ANNOTATION DATA RETAIN ORIGNAL DEPTH REFERENCES. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 Bryan.~u~nda~libu~ton.com ~---~ Date: ` .- _ r Signed: `~~~ !~}~ - 1 !~' 1~-5( ~` ~ ~ L~L['s-7I~A OIII ~ GA5 333 W. 7th AVENUE, SUITE 100 COI~TSERQA'1'IO1~T COMDII3SIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Keith Lopez P.E. BP Exploration Alaska Inc. PO Box 196612 ~, Anchorage AK 99519-6612 ~~ Re: Milne Point Unit, Schrader Bluff Oil Pool, MPG-09 Sundry Number: 309-040 .J ~.lt."I~. 4 4rrr _ - 6, V FJ v 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, r~ Daniel T. Seamount, Jr. Chair DATED this ~ day of February, 2009 Encl. p ~~~ ~ STATE OF ALASKA ~+ 7 ~E~ ~` .~1 ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~~ ~ APPLICATION FOR SUNDRY APPROVA3 JAN ~ 9 2~~5 20 AAC 25.280 1. Type of Request: Abandon Suspend Operational shutdown Pertorate ~ aS I ~ ',S Us i ~bt Alter casing ^ Repair well ^ Plug Pertorations^ Stimulate ^ Time Extension ~ChOf~@IDIZE Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Developmenl^ Exploratory ^ 197-1170 ' 3. Address: P.O. Box 196612 Stratigraphic^ Service ^~ 6. API Number: Anchorage, AK 99519-6612 50-029-22779-00-00 ' 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: MPG-09 , Spacing Exception Required? Yes ^ No ^~ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ~~ \ ADLO-025518 - 58.2 KB MILNE POINT UNIT Field / SCHRADER BLUFF Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8970 4369.69 ~ 8863 7338 8615 NONE Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.1# H-40 Surface 112 Surface 112 1490 470 Production 8915 7" 26# L-80 Surface 8945 Surtace 4362 7240 5410 Pertoration Depth MD (ft): Pertoration Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 3-1/2" 9.3# L-80 SURFACE - 7575' Packers and SSSV Type: 7" BAKER S-3 Packers and SSSV MD (ft): 7788' 7" BAKER S-3 8057 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service Q 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/12/2009 OIL ^ GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ Q WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Keith Lopez Printed Name Keith Lopez Title P.E. Signature ' Phone 564-5718 Date 1/29/2009 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~C~/ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form fired: ~t~ APPROVED BY /~ ~ ~] ~ Approved by: COMMISSIONER THE COMMISSION Date: / 14f~ ,,o ,. Form 10-403 R vised 06/ 00~ ~ Submit in Duplicate MPG-09 197-1170 PERF OTTOrHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPG-09 2/20/98 PER 8,699. 8,719. 4,287.96 4,294.13 MPG-09 2/20/98 PER 8,719. 8,739. 4,294.13 4,300.27 MPG-09 2/21/98 PER 8,659. 8,679. 4,275.7 4,281.8 MPG-09 2/21/98 PER 8,679. 8,699. 4,281.8 4,287.96 MPG-09 9/1/99 RPF 7,870. 7,890. 4,053.43 4,057.78 MPG-09 9/1/99 RPF 8,440. 8,460. 4,208.72 4,215.03 MPG-09 9/1/99 RPF 8,500. 8,520. 4,227.55 4,233.75 MPG-09 7/24/02 BPS 8,310. 8,320. 4,168.42 4,171.42 MPG-09 7/25/02 BPS 8,160. 8,243. 4,123.81 4,148.28 MPG-09 11/1/08 BPP 8,160. 8,243. 4,123.81 4,148.28 MPG-09 11/2/08 BPP 8,310. 8,320. 4,168.42 4,171.42 MPG-09 11/2/08 BPS 8,615. 8,620. 4,262.46 4,263.95 MPG-09 11/6/08 PER 7,890. 7,980. 4,057.78 4,077.47 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED 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 by BP Exploration Alaska Milne Point To: Jerry Sharp/Mark O'Malley Date: Jan 29 2009 MPU Well Operations Supervisor REVISION 1 From: Keith Lopez IOR: 150 bopd Tract 14 PE AFE: MSGPDWL09 COST: Subject: MPG-09i CTU OA Re-perf and Acidize OBJECTIVES: Re-perf OA intervals on coil. Spot acid pill across perfs and pump away. PROPOSED STEPS: Cate or Ste Descri tion SL 1 Dumm N & Pull PX Pron and body. Drift XN ni le and Ta CTU 2 Run GR/CCL tie-in run CTU 3 Re- erf & add erfs to OA sands CTU 4 Spot acid pill across perforated zone and pump away. O 5 Injection test into OA zone SL 6 Install PX Pron & WFRV's BACKGROUND MPG-09i was drilled in July 1997 by Nabors 22E, but was not completed until February 1998. Initially, only the OB sands were perforated for a PFO study, but the N and OA perforations were added in September 1999. In July 2002 a decision was made to set an IBP with mud viscous pill and 2.5 bbls of Crete above the OA/OB perforation to only inject into the N sand. The MPG-09i was recently converted to a regulated injector in the N and OA sands. During the RWO the Crete top was found where expected and drilled out. The IBP was not tagged and trip made to 8614' without indications of the plug. A CIBP was set to isolate the OB, 90' of additional N-sand perfs were added, and completion ran. After putting on injection, the injectivity of the combined zones post-workover was significantly lower then pre-workover N- sand only injection. An injection test into the OA zone was conducted and found that it had no injectivity. It is believed that the IBP used to isolate the OA/OB intervals in 2002 was not holding and the viscous pill and Crete damaged the zone and the OA will need to be re-perforated and acidized. • Measured De~~th 0 1000 2oao 3aoo 400o Saoo BOOO 7aao sooo sooo 10000 This well supports the MPH-13 (300 bopd) which is fighting high GOR. There is a possibility that the MPH-13 may be shut in for reservoir management if the GOR can not be controlled by injection in the MPG-09i. MPG-09i also supports MPH-19 which was drilled in 12/07. CURRENT PLAN Current plan is to re-perforate and add perfs to the OA sand on CT using 2" guns loaded with PowerJet Omega 2006 HMX 7.3 gram charges with 6 spf and 60° phasing. A 10 bbl HCl DAD acid pill will be spotted across the re-perforated zone and pumped away. a Soo 1000 1500 • 2000 D 2500 3000 3500 4000 4500 5000 WELL DATA MPG-09 Directional Survey Current Status: On water injection in N sand only. 466 bwpd @ 598 psi Max Deviation: 77.65 degrees at '794i' MD Min ID: 2.750" at 8206' MD (3-i/2" HES XN Nipple) Last TD tag: Set CIBP @ 8580' Last downhole ops: Injection test in OA and set flow sleeve in N on i/i3/o9 Latest HZS level: N/A - SBL have minimal H2S «o ppm Latest SBHP: 1877 psi @ 4ooo'TVDSS ii/29/o8 (i4 day SI) Tbg/csg size: 3.5" tbg, ~" prod csg Max hole ankle • • DETAILED PROCEDURE: Slickline i. MIRU SL z. RIH & pull flow sleeve @ 7968' and dummy off N sand. 3. RIH & pull PX prong and body @ 8206' . 4. Drift with 2.6" gauge ring and sample bailer to TD (or as deep as possible). Rollers are required, pump truck assistant maybe required. CTU: 1. MIRU Coil unit. 2. RIH w/ GR/CCL memory tool and make tie-in pass 3. RIH w/ 2" guns loaded with PowerJet Omega HMX 7.3 gram charges w/ 6 spf and 60° phasing. Perforate the OA sand tied into Schlumberger USIT log dated 2/20/98. (Avg. csg. EH diam. 0.18-in, Avg. formation penetration 19.21-in. Note the swell in water for these guns is 2.29-in and 2.31-in gas. Make sure that all burrs are worn off before attempting to POH. The guns can be left down-hole, although it is not the preferred option) To Perf (MD) Bottom Perf (MD) Gross Foota e 8420' 8460' 40' 8500' 8536' 36' 4. RIH w/ JSN and spot 10 bbls of 10°Io DAD HCl acid across previously perforated zones. Pump acid away flushing with at least 30 bbls produced water. Operations 1. Place well back on injection into the OA zone at 500 bwpd with max pressure of 1200 psig until SL can return and set WFRV's. Slickline 2. MIRU SL 3. RIH & install PX prong and body @ 8206' . 4. RIH & pull dummy @ 8146' and replace with WFRV set for S00 bwpd. 5. RIH & pull dummy @ 7968' and replace with WFRV set for 750 bwpd. POINTS OF CONTACT: Production Engineer: Keith Lopez Office: 564-5718 Ce11:903-5432 • PERFORATING PROCEDURE rers~ra~s Well: MPG-09i API #: 5002922779 1/29/2009 Date : Prod Engr Keith Lopez......... ........ Office Ph:.,.-.-.-. .....,....,..907-564-5718 ..-..,..-,...,...,.. ........................ .,., Home Ph: ......... .............................................. Cel I/Pager: ......... 907-903-5432 .............................................. CC or AFE: MSGPDWL09 ........................................................... ..... ........ WBL Entries H2S Level: .............No Data............ Well Ob~ectives and Pertoratin Notes: Note: Min ID = 2.75" ~ 8206' md. Gun swell in liquid = 2.29" Gun swell in Gas = 2.31" These OA perfs have no infectivity and may have been damaged by a visous mud pill or Crete. Attachment: See tie-in log with proposed perfs annotated with the program Reference Log Log: GR/CCL ..................... Date: 2120/19£ ..................... Company: Schlumt Depths (from-to) Depths (from-to) Feet SPF 8,420' - 8,440' 20' 6 8,440'......... " .....8,460'...... ....20' ...... .........._6........... 8,500'......... - ...._8,520'..... .....~~~ ...... .........._6........... .8,520'......... - ...._8,536'...... ......16 ....... .........._6........... Add/Subtract ............................................ feet ...... from the tie-in log to be on depth with the reference log. Orient. Phasing Zone Ad/Re/Iperf .. .... ......... s~ ~ ...... 1 ._OA....... ............._Ad.................... . ....... . ..... ............................... ..... 60° OA Re .. 6Q ~ ...... .. ~A....... .............. Re................... . ............ ................................ .................._ - --.. ..............._60.x_............ ...... .. ~.:°..`........ .._.......... Ad.................... ............................. - .................................I I................................... - ........................... .................... .......................... .............................................. ................................................. ............................................................. Requested Gun Size: 2" HMX Charge: .2006 PowerJet.Ome~a Is Drawdown Necessary/Desired/Unnecessary During Perforating Unnecessary ......................................................................................................................................................... Preferred Amount of Drawdown/Suggestions to Achieve Drawdown . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Last Drift : ..................................ft MD on .,................,.,...... Est Res. Pres. ~ 4,000 MD is ....,..,........,........,....,,.,..1877 psi Well: MPG-09i ------------------- Date: 1 /29/2009 API #: .................................. General Comments: ................................ ................................................................ Depths Balance Referenced to BRCS O/B/U - ........................................................... O/B/U - ........................................................... O/B/U - O/B/U - ........................................................... O/B/U - ........................................................... O/B/U - ........................................................... O/B/U - ........................................................... O/B/U - Perforation Summary 5002922779 Prod Engr: Keith PBTD 8580' Gun Dia. Orient. SPF Phasing Zone immary Dist awn: ich Prod Engr D. Center Adperf/Reperf SPAN Perforating Analysis Company : BP Exploration Alaska Well :MPG-09 Field :Prudhoe Bay Engineer :Todd Sidoti Date :January 26, 2009 Schlumherger Results are based on API and other test data of Schlumberger perforating systems as well as computer modeling of perforated completions. Results are provided in good faith without warranty SPAN Version 8.0 ra__~t+_u.. ~__--_tnnn~~ n nu ILITITI rr~ c+no r1 /~......~:.. L.a 7/~Ao Company: BP Exploration Alaska Penetration Report Completion Borehole Diameter: 8.5 in Wellbore Fluid: Perforated Depth: 4200.0 ft Fluid Density: Tubular(s) • Well: MPG-09 Brine 8.44 ppg Casing Outer Weight Grade Inner Tubing Stand-off Annulus Annulus Csg Str # Diameter Diameter Position Material Density Remain (in) (Ibm/ft) (in) (ppg) (%) 1 7 26.00 L80 6.276 Centralized Cement 15.86 99/99/98 Formation Rock Type: Porosity: Bulk Density: Formation Fluid Sandstone 25.0 2.24 g/cm3 Water Perforating System(s) Rock Strength (UCS): 1621 psi Vertical Stress: 4200 psi Pore Pressure: 1877 psi Wellbore Damage: 8 in Perf Phasing Shot Gun Stand Total Pen Form Pen Form Dia EH Dia AOF # Angle Density Position Off Average Average Average Average (deg) (spf) (in) (in) (in) (in) (in) (in2/ft) 1 60 6.00 Eccentered 0 20.32 19.21 0.56 0.18 0.15 2 60 6.00 Eccentered 0 15.21 14.10 0.50 0.15 0.11 3 60 6.00 Eccentered 0 19.20 18.09 0.81 0.26 0.32 1. 2" High Shot Density, PowerJet Omega 2006, HMX,7.3 g(API:Pen 21.80 in,EH Dia 0.22 in,196 1st Ed.) Charge performance for 1 of 6 charges have been extrapolated from test data 2. 2" High Shot Density, PowerJet 2006, HMX,6.5 g(API:Pen 18.60 in,EH Dia 0.20 in,RP43 5th Ed.) Charge performance for 1 of 6 charges have been extrapolated from test data 3. 2-1/2" High Shot Density, PowerJet 2506, HMX,10.5 g(API:Pen 18.70 in,EH Dia 0.34 in,19B 1st Ed.) Charge performance for 3 of 6 charges have been extrapolated from test data Results are based on API and other test data of Schlumberger perforating systems as well as computer modeling of perforated completions. Results are provided in good faith without warranty SPAN Version 8.0 ._C:Il...\C'.L,1~. L,....,'..\C~AAI A n\1 IAITITI Crl CDS2 n r~.,~~~~~t,+ ~nnu Company: BP Exploration Alaska • Well: MPG-09 Perforating System #1 2" High Shot Density, PowerJet Omega 2006, HMX, 7.3 g 60° Phasing, 6.00 spf Clearance Avg 1.74 in Total Pen Avg 20.32 in Formation Pen Avg 19.21 in Formation Dia Avg 0.56 in Casing EH Avg 0.18 in AOF (at 6.00 spfj ~~~ "5 ins/ft API: Pen 21.80 in, EH Dia 0.22 in, 19B 1st Ed. Perforating System #2 2" High Shot Density, PowerJet 2006, HMX, 6.5 g 60° Phasing, 6.00 spf Clearance Avg 1.74 in Total Pen Avg 15.21 in Formation Pen Avg 14.10 in Formation Dia Avg 0.50 in Casing EH Avg 0.15 in AOF (at 6.00 spf) 0.11 in2/ft API: Pen 18.60 in, EH Dia 0.20 in, RP43 5th Ed. 0 deg Perforating System #3 2-1/2" High Shot Density, owerJet 2506, HMX, 10.5 g 60° Phasing, 6.00 spf Clearance Avg 1.60 in Total Pen Avg 19.20 in Formation Pen Avg 18.09 in Formation Dia Avg 0.81 in Casing EH Avg 0.26 in AOF (at 6.00 spf) 0.32 ins/ft API: Pen 18.70 in, EH Dia 0.34 in, 196 1st Ed. Rock Type: Sandstone Brine Rock UCS: 1620 psi C Cement Vertical Stress: 4200 psi Damaged Zone Pore Pressure: 1877 psi ~ Formation Results are based on API and other test data of Schlumberger perforating systems as well as computer modeling of perforated completions. Results are provided in good faith without warranty SPAN Version 8.0 ~ ~ilcc\Crhlii hcmcr\CP~t~I R n\I INTITI Ffl SPR Cc~ Cnnvrinht 200ti Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, January 26, 2009 10:19 AM To: 'West, Howard J'; Stewman, Sondra D Subject: MPG-09 (197-117) Howard and Sondra, I am reviewing the 404 submitted for the recent workover and have some questions/observations. 1. The drawing provided is not correct. ABP was set at 8580' on 11/4. It would appear that depth should be entered as the effective depth and also listed on the plug line. 2. Setting the BP also has isolated the perforations from 8659 - 8739'. 3. I am curious about the "junk depth" entry on the 404. Is this the prong mentioned on 11/30 in the well history summary? It appears that a new drawing and 404 will be needed. Call or message with any questions. Tom Maunder, PE AOGCC ~C tv C~ ~1 C~~ ~--~~ ~~ 1 /26/2009 r STATE OF ALASKA RACE A~ OIL AND GAS CONSERVATION CO SION REP6RT OF SUNDRY WELL OPE TIONS ,Q(~ n ,,~ Resubmital: Wel~Sch ~ti~aifcYC~rrections 1. Operations Performed: '"' i1S 8 ~~ & G9S COt1S. ~01`I1C'r"i18S ^ Abandon ®Repair Well i ^ Plug Perforations ^ Stimulate ^ Re-Er~~ed Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ®Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 197-117 3. Address: ®Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22779-00-00 7. KB Elevation (ft): 58 20' 9. Well Name and Number: ' MPG-09 8. Property Designation: 10. Field /Pool(s): ADL 025518. Milne Point Unit / Schrader Bluff . 11. Present well condition summary Total depth: measured 8970 feet true vertical 4370 feet Plugs (measured) 8580 Effective depth: measured 8580 feet Junk (measured) None true vertical 4252 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 112' 112' 1490 470 Surface Intermediate Production 8915' 7" 8945' 4362' 7240 5410 Liner Perforation Depth MD (ft): BelowPiua: esss =s~as~ Perforation Depth TVD (ft): saa~ P40 a: airs ' aaaa 3-1/2", 9.3# L-80 8250' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): ~~~ x 3-1/2" Baker Premier Packers 7788' & 8057' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: , ^ Exploratory ^ Development ®Service ® Daily Report of Well Operations 16. Well Status after work: , ® Well Schematic Diagram ^ Oil ^ Gas ^ WAG ^ GINJ ®WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A ff C.O. Exempt: Contact Howard West, 564-5471 308-346 Printed Name Sondra Stewman Title Drilling Technologist ,r-°"~~" ~ © Prepared By Name/Number. Z~ ~ ~~ ature S Phone 564-4750 Date C3 ondra Stewman 56a-x750 ors Form 10-404 Revised 04/200'-'~ Submit Original Only Tree:4-1/16"- 5M FMC Wellhead: 11"-5M Monobore w/ 4.5" FMC Tbg. Hng , NSCT lift threads,4.5" CIW H BPV profile 120", 91.1 #,H-40 conductor 112' KOP @ 500` Max. hole angle = 70 to 78 deg. f/ 3300' to 8250' Hole angle thru' perfs = 72 deg Perforation Summary: Tie in log: SWS USIT 2/20/98 Size SPF Interval (TVD) NB Sands 2" 4.5° 4 5 7870'-7890' 7890'-7980' OA Sands 4053'-4058' 4058`-4077' 2° 2" 4.5" 4 4 5 8440'-8460' 8500'-8520" 8659'-8739' 4209'-4215' 4227'-4234' 4275'-4300' 2" Powerjet guns, 60 deg. phasing 4-sp deep penetrating charges Orig. KB elev. = 58.20 (N22E) Orig. GL elev. = 29.20 (N22E) 7" HES cementer 3.5" HES "X" Nipple 2.81" ID. 7"x 21' Marker joint. 3.5" HES "X" Nipple 2.813" ID. 1931' I 2304' I 7588' 7736' 7" Baker Premier Packer r 7788, I 2.870" ID L 3.5" x 1 1/2" MMG GLM 7947' Angle @SPM - 77° " " 7968 MMG-W GLM 3.5 x 1 1/2 Angle @SPM - 77° 7" Baker Premier Packer 8057, 2.870" ID 3.5" x 1 1/2" MMG-W GLM ° 8146' Angle @SPM - 74 3.5" HES "XN" Nipple " 8206 2.750 No-Go ID WLEG 8250' CIBP set Ca 8580` ~ -IBT oushed to 8615` 7", landing collar 8863' 7", 26# L-80 Buttress 8945' DATE REV. BY COMMENTS MILNE POINT UNIT 07/06/97 M. Linder Nabors 22-E WELL: MPU-G-09i 02/22/98 M. Linder Nabors 4-ES API NO: 50-029-22779 7/25/02 MDO CTU Baker IBP W/ Gel and Cement cap. BP EXPLORATION (AK) 11/8/08 L. Hulme Recomplete & Add Perfs w/ Nabors 3S. MPU G-09 ~~~~ ~)~ STATE OF ALASKA /ati'~0~ ALA OIL AND GAS CONSERVATION COM~SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations erformed: ^ Abandon ®Repair Well • ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing - ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approv Program ^ Operation Shutdown ®Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) c. ^ Development ^ Exploratory 197-117 - 3. Address: ®Service ~ ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorag Alaska .99519-6612 50-029-22779-00-00 7. KB Elevation (ft): 58 20' ~ 9• Well Name and Number: . MPG-09 8. Property Designation: 10. Field /Pool(s): _ ADL 025518 Milne Point Unit / Schrader Bluff 11. Present well condition summary Total depth: measured 8970 - feet true vertical 4370 - et Plugs (measured) Effective depth: measured 8863 fe Junk (measured) 7588' true vertical 4338 feet Casing Length Size MD Burst Collapse Structural Conductor 80' 20" 112' 112' 1490 470 Surface Intermediate Production 8915' 7" 8945' 4362' 7240 5410 Liner C~ 4~~~~' a Perforation Depth MD (ft): 7870' - 8739' ~ ~ ~ `~r v L- ~" ~ , Perforation Depth TVD (ft): 4053' - 4300' 3-1/2", 9.3# L-80 8250' Tubing Size (siae, grade, and measured depth): Packers and SSSV (type and measured depth): T' x 3-1/2" Baker Premier Packers 7788' and 8057' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ecti Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pre ure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ^ Development Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ^ Oil ^ Gas ^ WAG ^ GINJ ®WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA ff .Exempt: Contact Howard West, 564-5471 308-346 Print Name Sondra Stewman Title Drilling Technologist - Prepared By Name/Number. S Phone 564-4750 Date ~ ol-Ca$'~~Sondra Stewman 564-4750 Form 10-404 Revised 04/2006 Submit Original Only Tr :4-1/16"- 5M FMC M PU G-09 Ilh a : 11"-5M Monobore w .5" FMC Tbg. Hng , NSCT I lift reads,4.5" CIW H BPV profile 120", 91.1H-40 conductor 112' KOP @ 500' Max. hole angle 70 to 78 deg. f( 3300' to 8250' Hole angle thru' perf = 72 deg Orig. KB elev. = 58.20 (N22E) Orig. GL elev. = 29.20 (N22E) 7" HES cementer 1931' 3.5" HES "X" Nipple 2304' 2.81" ID. 3.5", 9.3#, L-80 8rd EUE Tubing ID= 2.992, Cap =.0087 bpf 7", 26#, L-80, BTC casing Casing ID= 6.276, Gap = .0264 bpf SBHP NB sands on 10/2/08 @ 4053' TVD was 2106 psi. OA sands on 11/29/08 @ 4254' TVD was 1976 psi. Perforation Summary: Tie in log: SWS USIT 2/20/98 Size SPF Interval (TVD) 2" 4 fV6 Sands 7870'-7890' 4053'-4058' 4.5" 5 7890`-7980' OA Sands 4058`-4077' 2" 4 8440'-8460' 4209'-4215' 2" 4 8500'-8520" 4227'-4234' 4.5" 5 $65g°_873g~ 4275'-4300' ~! 7"x 21' Marker joint. 7588' 3.5" HES "X" Nipple 7736' 2.813" ID. 7" Baker Premier Packer 7788; 2.870" ID .5" x 1 1/2" MMG GLM 7907' A le @SPM - 77° I 3.5' 1 1/2" MMG-W GLM 7968 Angle SPM - 77° 7" Bake Premier Packer 8057' 2.870" ID ~' ( 3.5" x 1 1/2" MG-W GLM Angle @SPM - ° $146' 3.5" HES "XN" fipple 8206, 2.750" No-Go ID WLEG 8250' 2" Powerjet guns, 60 deg. phasing 4-sp ~ 7", landing collar 8863' deep penetrating charges 7", 26# L-80 Buttress 8945' DATE REV. BY COMMENTS MILNE POINT UNIT 07/06/97 M. Linder Nabors 22-E WELL: MPU-G-09i 02122(98 M. Linder Nabors 4-ES API NO: 50-029-22779 7/25/02 MDO CTU Baker IBP W/ Gel and Cement cap . 11/8/08 L. Hulme Recomplete & Add Perfs w/ Nabors 3S. BP EXPLORATION (AK) • BP EXPLORATION Page 1 of 9 ..Operations Summary Report Legal Well Name: MPG-09 Common Well Name: MPG-09 Spud Date: Event Name: WORKOVER Start: 10/24/2008 End: 11/9/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/9/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task j Code NPT Phase 10/25/2008 03:00 - 06:00 3.00 RIGD P PRE 06:00 - 11:00 I 5.001 RIGD I P 11:00 - 12:30 1.50 MOB P 12:30 - 21:00 8.50 RIGU P 21:00 - 23:00 I 2.001 KILL I P 23:00 - 00:00 I 1.001 KILL ~ P 10/26/2008 100:00 - 01:00 I 1.001 KILL I P 01:00 - 06:00 ~ 5.00 ~ KILL ~ P PRE PRE PRE Description of Operations RD /Blow down steam and water lines. Disconnect Pipe Shed from Carrier. Prepare the Camp for mobilizing. Having trouble with getting the Derrick to scope. Continue troubleshooting the problem with the Derrick. Find ice plugs in the hydraulic lines to the rams. Turn on steam and thaw out the lines. Scope and lower the Derrick down at 0830 hrs. Pull off of well slot MPL-03 at 1000 hrs. Spot for moving. Move the Rig and all components from MPL-Pad to MPG-Pad. Arrive on MPG-Pad at 1230 hrs. Spot the Camp, Shop, Generator and Parts Trailer. Position the Pits, Pipe Shed and Carrier on the back side of the Pad. Spot the BOPE behind well slot MPG-09 at 1400 hrs. Line up and back the Carrier over well slot MPG-09 at 1500 hrs. Pull off and begin laying rig mats and herculite. Back up over well slot MPG-09i final time with Pad Operator and Toolpusher. Back the Pipe Shed and mate up with the Carrier. Back the Pits and mate up with the Carrier. Raise and scope Derrick at 19:00 hrs. Set upright tank and set berming around tank. "'Rig accepted at 21:00 DECOMP Install double annulus on IA. RU lines from choke to Tiger Tank. Spot LRS unit on pit side. RU lines and LRS lines to tree, connect choke line. Take on 200 bbls of 10.35 ppg at 113 degF brine into pits. Spot 290 bbls vac truck, weight off truck is 10.35 ppg at 105 degF. DECOMP PJSM with crew and DSM. RU lubricator to tree /test to 500 psi. _ PuII 4"-CIW-"H" BPV LD lubricator Tubing pressure-Q si, IA ressure = 0 si. DECOMP PJSM. Pressure test lines to 3500 psi, pressure test downstream line to Tiger Tank to 500 psi. Notified MP radio about venting gas. DECOMP Tubing = 0 psi, IA = 0 psi. Open well thru choke, no pressure or flow to tiger tank. Break circulation with 10.35 ppg / 105 degF with LRS at 1 BPM / 200 psi, increase to 2.25 BPM / 2500 psi. Reduce rate to FCP = 2400 psi at 1.5 BPM. Shut down pump at 296 bbls away, and 9.9 ppg on returns. Blow down LRS lines. Swap to rig pump at 1.5 BPM / 2400 psi. Circulate 26 bbls from pits, getting 10.4 ppg / 77 degF. Circulated a total of 322 bbls. Returned 279 bbls to Tiger Tank via stra 290 bbls in Truck with 8 bbls left in Tank afterwards). 06:00 - 06:30 0.50 KILL P DECOMP Open well and monitor for 30 minutes. Both the Tubing and IA are static at 0 psi. 06:30 - 07:00 0.50 WHSUR P DECOMP Dry rod 4" Tvoe "H" TWC with FMC rep. RU Test Equipment. 07:00 - 08:00 1.00 WHSUR P DECOMP Pressure testa ainst the to of the TWC to 3 500 si for 10 charted mins - ood test. Pr the TWC to 1.000 asi for 10 charted mins -good test.. RD Test 08:00 - 10:30 2.50 WHSUR P DECOMP ND Tree and Adapter Flange with FMC rep. Screw into the Hanger top threads with a 4-1/2" NSCT XO to check the threads -good (7-1/2 turns to MU). Remove the Tree from the Cellar and prepare to send in to Drill Site Maintenance for inspection. 10:30 - 16:00 5.50 BOPSU P DECOMP NU 11" x 13-5/8" DSA. PU the BOP Stack off the Cradle and Printed: 11/25/2008 11:02:01 AM • BP EXPLORATION Operations Summary Report Legal Well Name: MPG-09 Common Well Name: MPG-09 Event Name: WORKOVER Start: 10/24/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/9/2008 Rig Name: NABORS 3S Rig Number: r i i i Date I. From - To Hours ' Task Code NPT 10/26/2008 16:00 - 20:00 ~ 4.00 BOPSU P 20:00 - 22:00 2.00 PULL P 22:00 - 00:00 I 2.001 PULL I P 10/27/2008 100:00 - 02:00 I 2.001 PULL I P 02:00 - 11:30 I 9.501 PULL I P 11:30 - 13:30 2.00 FISH P 13:30 - 15:30 I 2.001 FISH I P 15:30 - 20:00 4.501 FISH P 20:00 - 21:00 1.00 WHSUR P 21:00 - 23:00 2.00 FISH i P 23:00 - 00:00 I 1.001 FISH I P 10/28/2008 00:00 - 02:30 2.50 FISH P 02:30 - 04:00 1.50 FISH P 04:00 - 17:00 13.00 FISH P 17:00 - 21:00 4.00 BOPSU P Page 2 of 9 Spud Date: End: 11 /9/2008 Phase j Description of Operations DECOMP stab on the DSA. NU the 13-5/8" BOPE. DECOMP Pressure test BOPE to 250 si low and 3,500 si hi h er BP / AOGCC Regulations. Tested against the TWC. Tested the Annular to 3,500 psi with 3-1/2" Test Joint. The test was witnessed by the BP WSL and Nabors Toolpusher. The State's right to witness the test was waived by John Crisp at 1330 hrs on 10/26/2008. Will test Kelly valves once we PUMU Kelly with Drill Pipe in the hole. DECOMP PJSM with crew and DSM. MU Opso-Lopso and 4-1/2" NSCT XO. MU pump-in sub XO. RU Lubricator and pressure test to 500 si - ull TWC. Tubing and IA 0 psi. LD Lubricator and Opso-Lopso. Clean and clear rig floor. Monitor well for 15 min - no change. DECOMP PJSM. MU TIW to landing joint and 4-1/2" NSCT XO. Screw into hanger with 7-1/2 turns and back-out LDS with FMC rep. Pull han er to floor with 47K. LD hanger, landing joint and XO. MU XO for 3-1/2" 8rd EUE to floor safety valve. DECOMP MU circulating pin to tubing. Break circulation at 3.5 BPM / 310 psi, reciprocate pipe 40' thru circulation. ~'culated 209 bbls without an losses. Fluid weight consistantly between 10.4+ to 10.5 ppg throughout circulation. Fluid returns clean back to pits. DECOMP PJSM. POOH LD 3-1/2" completion. Inspect pipe, clean threads and put thread protector on before laying down. 100 joints out at 06:00 hrs. 170 Joints out at 0900 hrs. Recovered a total of 239 Joints of Tubing, 1 X Nipple Assembly and a cut upp joint strap = 4.20'. DECOMP Clear and clean Rig Floor. RD 3-1/2" Tubing Handling Equipment. RU 3-1/2" Drill Pipe Handling Equipment. DECOMP PUMU Kelly, Kelly Shuck and Swivel. Stand back in Rat Hole. Load Joints of 3-1/2" Drill Pipe in the Pipe Shed. DECOMP Slip and cut drilling line. At 1630 hrs, find hydraulic fluid leak coming out of hinge seal on blind ram door Notify MPU Environmental and Workover Superintendent. Find repair kit and re air the hin a seal. Hang blocks with drilling line. Function test Blind rams, no leaks. Finish loading pipe and collars in pipe shed. DECOMP Set 11"wear ring in tubing spool. PU BHA handling equipment. RU spinners and tongs. DECOMP PJSM with crew and Baker. PUMU BHA #1 with Baker rep as follows: Packer Mill, 3 ea Junk Baskets, Bit Sub, Bumper Sub, Jar, 8 ea 4-3/4" Drill Collars and Pump Out Sub. OAL = 279.77'. DECOMP PJSM. Single. in hole with 3.5" - 15.5#/ft DP from shed from 280' to 1050' at 24:00 hrs. Fluid weight in pits = 10.5 ppg, 60 degF. DECOMP Continue to RIH from 1050' to 2442'. DECOMP PJSM. Perform stripping drill with crew. Alternate hands on choke, maintaining 100 psi back on casing. Conduct post drill review and discuss learnings. Blow down choke and recover iBOP and TIW valve. DECOMP Single in hole with 3.5" DP from 2442' to 4143' at 06:00 hrs. DECOMP Mix 30 Bbls of Hi-Vis Pill in pill pit. 231 joints picked up. Nrinted: niz5izoue 11:UL:UI AM • BP EXPLORATION Page 3 of 9 Operations Summary Report Legal Well Name: MPG-09 Common Well Name: MPG-09 Spud Date: Event Name: WORKOVER Start: 10/24/2008 End: 11/9/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/9/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task I Code ~ NPT Phase Description of Operations 10/28/2008 17:00 - 21:00 4.00 BOPSU P DECOMP PUMU Kelly. Test to 250 / 3500 psi. Chart both tests. Lower Kelly valve failed. Break off and MU new valve -retest. 21:00 - 22:00 1.00 FISH P DECOMP Stand back Kelly in rat hole. RU to RIH with 3.5" DP. Conduct KSAR with crew on milling operation. 22:00 - 23:00 1.00 FISH P DECOMP Single in hole from shed and tag top of tubing stub at 751 , (appox 32' correction from 7543' ELM jet cut depth). LD tag joint and MU 10' pup. 23:00 - 00:00 1.00 FISH P DECOMP PUMU Kelly to DP. Establish milling parameters: PU, SO, Rot weight = 75K, 55K, 62K. 3.5 BPM / 580 psi, 65 RPM / 4K ft-Ibs free torque. Mill with 5-20K WOB with 65 RPM / 4-6K ft-Ibs torque, 3 BPM / 380 psi (10.5 ppg in and 10.5 ppg out at 70 degF). Milled from 7512' to 7513.5' at 24:00 hrs. 10/29/2008 00:00 - 06:00 6.00 FISH P DECOMP Continue milling from 7513.5' with 5-20K WOB, 65 RPM / 4-6K ft-Ibs. Circulate 15 bbls hi-vis sweep surface to surface. Recovered schmoo and small metal shavings.. Put dirty vac truck hose in cuttings box and suck out intermittently. Milled tubing stub from 7513.5' to 7515.5' at 0:600 hrs. 06:00 - 14:30 8.50 FISH P DECOMP Mill tubin stub and acker varying pump rate, rotary speed and torque, and WOB. Mill to 7519' 14:30 - 16:00 1.50 FISH P DECOMP Start losin circulation indicatin mill thru acker elements. Continue milling, varying rates, WOB, rotary speed, etc. 1 hour losses of 9.5 Bbls. 16:00 - 19:30 3.50 FISH P DECOMP Push packer to 7530'. Circulate 30 Bbls of Hi-Vis sweep surface to surface ~ 4 BPM, 711 psi. Losses ~ -10 Bbls/Hr. Sweep did not recover much of anything. Set Kelly in rat hole. Clear rig floor and RU to run singles. 19:30 - 21:00 1.50 FISH P DECOMP PJSM. PUW = 73K, SOW = 50K. RIH with singles pushing packer from 7530' to 7621: Unable to stack more than 5K down on packer. 21:00 - 22:00 1.00 FISH P DECOMP Change out power supply to skate buggy with electrician. Function test. Monitor well, minimal losses. 22:00 - 00:00 2.00 FISH P DECOMP RIH with sin les ushin acker from 7621' to 7878'. Stack 15K down on acker at 7878' (top of NB perfs). Rotate 5 turns without torque. Sit back down with 15K. 10/30/2008 00:00 - 07:00 7.00 FISH P DECOMP PJSM. Flow check well - 4 bbls/hr loss rate. POH with BHA #2 standing back DP. Flow check well at 2258' -well static. 07:00 - 08:00 1.00 FISH P DECOMP BOLD packer mill, clean junk baskets. Recovered -3 gals of metal shavings and milling debris. A couple small pieces from jet cutter. Wear on mill face showed expected markings from milling on packer. No abnormalities. 08:00 - 08:30 0.50 FISH P DECOMP Clean and clear rig floor. 08:30 - 14:00 5.50 FISH P DECOMP PUMU 2-3/8" Itco s ear with 4-3/4" bum er sub, oil jars, 8 ea 4-3/4" DC's, 4-3/4" intensifier, 3-1/2" PO sub. RIH on 3-1/2" DP from derrick. Maintaining continuous hole fill with losses ~ -5 Bbls/Hr. 14:00 - 15:30 1.50 FISH P DECOMP 122 stands from derrick in hole. PUMU 2 singles from pipe shed. MU head pin and circulation lines. PUW of 77K, SOW of 48K. Pump 2.8 BPM, 1320 psi. RIH, see pump pressure increase to 1550 psi. Jet and work spear into packer-fish , Plant spear and push to 7885'. PU 30' and see 40K overpull. RBIH to 7885'. 15:30 - 16:00 0.50 FISH P DECOMP Drop ball and rod for shear sub. Pump 60 Bbls with no sign of ball on seat. RD circ lines and head pin. Blow down. Printed: 11/25/2008 11:02:01 AM • BP EXPLORATION Page 4 of 9 Operations Summary Report Legal Well Name: MPG-09 Common Well Name: MPG-09 Spud Date: Event Name: WORKOVER Start: 10/24/2008 End: 11/9/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/9/2008 Rig Name: NABOBS 3S Rig Number: Date From - To 'Hours Task Code NPT Phase Description of Operations 10/30/2008 16:00 - 17:00 1.00 FISH P DECOMP Flowcheck well. Slowly taking fluid. POH dry for 5 stands. Flowcheck well, losses as expected. Continue POH with packer dragging occasionally . Work pipe when overpull ~ 40K overpull. Continue POH until pipe pulled wet ~ 8 stands. Necessary to use jars one time as could not go up or down. 17:00 - 00:00 7.00 FISH P DECOMP PUMU Head pin and pressure to 3500 psi and attempt to shear circ sub. Bleed and surge with pressure to 3800 to try to shear circ sub. Unable to shear. POH wet from 7885' to 3500'. MU head pin and shear pump out sub at 3500 psi. Circulate 25 bbls to clear air from DP at 2 BPM / 2500 psi. Continue to POH with dry DP. Losses = 4 BPH. 10/31/2008 00:00 - 02:30 2.50 FISH P DECOMP Continue pulling out of hole with packer assembly. 02:30 - 06:00 3.50 FISH P DECOMP PJSM on BHA lay down and tubing punch operations. LD BHA #2 down to spear. Tubing punch below packer and above plug_ - no trapped pressure. Finish LD spear and tubing tail. 06:00 - 07:00 1.00 FISH P DECOMP Clean and clear rig floor. Load used tools from rig floor, get new BHA to rig floor. 07:00 - 08:30 1.50 FISH P DECOMP PUMU BHA #3 - 6-1/8" x 4-1/4" FB shoe, 5-3/4" RCJB, 3 ea 4-3/4" boot baskets, bit sub, bumper jar, oil jar, and 8es 4-3/4" DC's, 3-1/2" Pump out sub. Run RCJB with ball on seat. 08:30 - 14:00 5.50 FISH P DECOMP RIH on 3-1/2" DP from derrick. Losses @ - 4 Bbl/Hr. 09:30 have 30 stands in the hole. Run total of 123 stands out of derrick. 14:00 - 15:30 1.50 FISH P DECOMP Stab mousehole. PUMU kelly. PUW of 80K, SOW of 50K. Circulation rate of 4 BPM at 1150 psi. Rotate ~ 60 - 80 rpm. Work RCJB thru perforations ~ 7870' - 7890'. Ve rabb " thru perfs. Rotate and reciprocate until working freely. Jars tripped one time with 40 K overpull prior to cleaning up. 15:30 - 20:00 4.50 FISH P DECOMP Work RCJB with Kelly making mousehole connections with 20' pup joints. With RCJB ~ 8000' ,after making connection, pump pressure decreased by 300 psi to 850 psi circulation pressure at 4 BPM. Continue working RCJB to fill at 8145: 20:00 - 21:00 1.00 FISH P DECOMP PUW = 84K, SOW = 53K, Rot wt. = 65K. Free torque = 40 RPM / 5800 ft-Ibs, circuating 3.5 BPM / 860 psi. Tag up on fill at 8145', rotate and wash down to TOC at 8156' (torque increased to 7500 ft-Ibs). Reciprocate Kelly several times to confirm depth at 8156'. 21:00 - 23:00 2.00 FISH P DECOMP Circulate 30 bbls of hi-vis sweep at 3.5 BPM / 860 psi while reciprocating and rotating pipe - no overpull while working pipe. Sweep recovered small debris. Use vac truck to discard sweep. Fluid weight returns showing 10.2 ppg at 50 degF. Continue to circulate and condition hole. Fluid weight in pits = 10.3 ppg. -Line up pits to LRS pump truck and warm pits to 60 degF, continue warming unit) pits and returns are 60 degF. -Take on 100 bbls from upright tank (10.5 ppg / 55 degF). -Start adding Naar to pits to weight up with mud engineer. 23:00 - 00:00 1.00 FISH P DECOMP Set back Kelly in rat hole. POH with 20' joints used to wash down. Pump across hole while POH. Continue to build up brine weight in pits. Fluid loss rate = 4 BPH. 11/1/2008 00:00 - 02:30 2.50 FISH P DECOMP Continue LD pup joints to first stand. PUW = 82K, SOW = 50K. Hang up at 7890', pulling 50K over. RU circulating head. Circulate at 2 BPM / 400 psi and work pipe out of hole, Printed: 11!2512008 11:02:01 AM • BP EXPLORATION Page 5 of 9 Operations Summary Report Legal Well Name: MPG-09 Common Well Name: MPG-09 Spud Date: Event Name: WORKOVER Start: 10/24/2008 End: 11/9/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/9/2008 Rig Name: NABOBS 3S Rig Number: Date II From - To Hours ~ Task Code NPT Phase Description of Operations _ -_ ___ 11/1/2008 00:00 - 02:30 2.50 FISH P DECOMP -_ dragging from 7890' to 7772' (-100' above pert interval). Continue to build up brine weight to 10.4+ ppg. 02:30 - 04:30 2.00 FISH P DECOMP PUMU Kelly to DP, Rotate wt. = 65K. Mix 25 bbl hi-vis sweep. Break circulation at 3.5 BPM / 1050 psi with hi-vis sweep. Rotate and reciprocate pipe from 7770' to 7796' while circulating (torque = 60 RPM / 6000 ft-Ibs). Build fluid weight with Naar on the fly, 10.4+ ppg in. Circulate total 420 bbls, 10.4+ ppg out. Flow check well -static. 04:30 - 10:30 6.00 FISH P DECOMP Set back Kelly rat hole. POH with RCJB standing back in Derrick, pulling without overpull. Occasionally catching every collar, with packer debris as POH. (very slight bobble). Pull cleanly with 55 stands OOH. 10:30 - 12:00 1.50 FISH P DECOMP Stand back 4 stands of 4-3/4" collars. Break out and inspect BHA. 3 boot baskets full of -1-1/2 gallons of metal shavings, the odd Chun o s ip or pac er ring and -1/2 gal of frac sand. 2 larger pieces recoverd in fingers of RCJB. Outside of RCJB grooved and scarred from debris. 12:00 - 13:00 1.00 FISH P DECOMP Clean and clear rig floor. EPOCH calibrate instrumentation on Rig. ie: rotary speed, torque, hook load, pressure transducers, block height. 13:00 - 14:00 1.00 FISH P DECOMP PU single of 3-1/2" DP with wear ring pulling tool. Pull wear rin clean do a and r - 14:00 - 15:00 1.00 CLEAN P DECOMP PUMU 6-1/8" bit no'ets , 3 ea 4-3/4" boot baskets, 4-3/4" bumper sub and jars, 8 ea 4-3/4" DC's, 3-1/2" shear sub. 15:00 - 20:30 5.50 CLEAN P DECOMP RIH on 3-1/2" drill pipe from derrick to tag depth at 8156'. 20:30 - 00:00 3.50 CLEAN P DECOMP PUMU Kelly. Establish drilling parameters: PUW, SOW, Rot wt. = 83K, 45K, 62K and 55 RPM / 6200 ft-Ibs. Circulating parameters at 3 BPM / 480 psi, 6 BPM / 1400 psi. Drill cement making mousehole connections with 20' pup joints. Drib I with 5-10K WOB, no torque increase or pump pressure change. Change out screens in shakers. Circulate 15 bbl sweeps at 6 BPM / 1400 psi. Recovering cement chunks and fines over shakers. Use vac truck to capture sweeps. Fluid loss rate = 3 BPH. Drilled from 8156' to 8212' at 24:00 hrs. 11/2/2008 00:00 - 03:30 3.50 CLEAN P DECOMP Continue making mouse hole connections with 20' pup joints and drill with same parameters. Circulate 20 bbl hi-vis sweep at 6 BPM / 1380 psi, recovering cement over shakers. Drilled cement from 8212' to 8300'. WOB fell off to rotaing wt. - 65K, wash down with Kell from 8300' to 8348' 38' dee er than Coil IBP set depth of 8310'). Pick up to 8320', shut down pumps an monitor well -static. Confer with day man. 03:30 - 07:30 4.00 CLEAN P DECOMP Single in hole making mouse hole connections with 20' pup joints. Wash down every joint with 3 BPM / 450 psi. Wash from 8348' to 8614' without obstruction -IBP one (64' past proposed EZSV setting depth). 07:30 - 09:00 1.50 CLEAN P DECOMP Circulate 20 bbls hi-vis sweep at 6 BPM / 1450 psi. Reciprocate and rotate pipe while circulating from 8580'-8605'. Displace 400 Bbls (hole volume of 230 DP in). Flowecheck well, stable 09:00 - 11:30 2.50 CLEAN P DECOMP Stand back Kelly. POH laying down 20 ea 20' 3-1/2" pup joints. POH standing back in Derrick, pumping across brine across the top. POH t o 7800' (above top perfs) and flowcheck the well for 15 minutes -stable Printed: 11/25/2008 11:02:01 AM • BP EXPLORATION Page 6 of 9 Operations Summary Report Legal Well Name: MPG-09 Common Well Name: MPG-09 Spud Date: Event Name: WORKOVER Start: 10/24/2008 End: 11/9/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/9/2008 Rig Name: NABORS 3S Rig Number: Date 'From - To Nours Task Code NPT I Phase Description of Operations ----- -- 11/2/2008 11:30 - 16:00 4.50 CLEAN P DECOMP Continue POH with bit BHA, standing back in Derrick. Pumping brine across the top and keeping trip sheet. 16:00 - 18:00 2.00 CLEAN P DECOMP Stand back 4-3/4" DC's. Break off 6-1/8" bit, clean boot baskets. PUMU 7" Csg scraper with 6-1/8" bit on bottom, 4-3/4" jars, bumper sub, DC's and shear out sub. 18:00 - 19:00 1.00 CLEAN P DECOMP Clean and clear rig floor. Crew change, check PVT's, derrick and cellar. 19:00 - 20:00 1.00 CLEAN P DECOMP PJSM. PUMU 6-1/8" bit, 7" scraper, 3 ea. boot baskets, bit sub, bumper sub, jars, 8 ea. drill collars and pump out sub; OAL = 280.31'. 20:00 - 21:00 1.00 CLEAN P DECOMP RIH with BHA #5 with 3-1/2" DP out of Derrick to 3368'. 21:00 - 22:00 1.00 BOPSU P DECOMP PJSM. PUMU 7" RTTS as per Halliburton. RIH with 1 stand from Derrick and set RTTS 62.5' below table. Back out stand, set back in Derrick. Shut blinds and test RTTS to 1000 psi for,. 10 charted min. 22:00 - 23:00 1.00 BOPSU P DECOMP PJSM. Suck out stack. Pull wear ring. Set test plug. Line up lines to test BOPE. 23:00 - 00:00 1.00 BOPSU P DECOMP Test BOPE 250 psi low / 3500 psi high. Test witnessed by WSL Vincent Volpe and NAD Toolpusher Rick Bjorhus. AOGCC rep Chuck Sheave waived witness at 12:00 hrs on 11 /2/08. 11/3/2008 00:00 - 02:30 2.50 BOPSU P DECOMP Finish BOPE test. Test 2-7/8" x 5" VBR with 3-1/2" test joint. Pull test plug, set wear ring. LD test joint and RD test equipment. 02:30 - 04:30 2.00 BOPSU P DECOMP PJSM. PUMU Halliburton pulling tool with stinger. RIH to top of RTTS, unable to sting into storm valve. RU head pin, kick on char a um and circulate 12 bbls. Unable to sting in, unable to screw in. Circulate with mud pump at 3 BPM. Still unable to sting into valve. POH and remove stinger. RIH and screw into RTTS with 21 turns. Shut annular and ull RTTS u hole 2' - no pressure underneath acker. Open bag and monitor, fluid level visibly dropping. POH and LD RTTS and pulling tool. Clear rig floor. 04:30 - 08:00 3.50 CLEAN P DECOMP PJSM. RIH with 7" scraper on 3-1/2" DP. Reciprocate scraper over packer setting depths of 7850', 8010', and 8550'.., 08:00 - 09:00 1.00 CLEAN P DECOMP Single in the hole with additional singles from pipe shed. RIH to 8600' 09:00 - 11:00 2.00 CLEAN P DECOMP Reciprocate DP while pumping 25 Bbls Hi-Vis sweep, displace with 350 Bbls of brine, using LRS and rig pump at 6 BPM / 1550 psi. 10.4 #/gal brine in and out. 11:00 - 11:30 0.50 CLEAN P DECOMP POH above top perfs to 7800'. Flowcheck well while blow down LRS pump and lines. 11:30 - 16:30 5.00 CLEAN P DECOMP POH with bit and scraper, standing back DP in the derrick. 16:30 - 18:30 2.00 CLEAN P DECOMP Stand back DC's. BOLD bit and Baker BHA. 18:30 - 19:30 1.00 CLEAN P DECOMP Clean and clear rig floor. Crew change, check PVT's, fluid weight, cellar and Derrick. 19:30 - 20:00 0.50 CLEAN P DECOMP PUMU Champ 4 packer on 8 ea. 4-3/4" drill collars. OAL = 24 .6 . 20:00 - 23:30 3.50 CLEAN P DECOMP RIH with packer on 3-1/2" DP from Derrick to 7850'. RU LRS lines from upright tank to IA. 23:30 - 00:00 0.50 CLEAN P DECOMP Set Cham 4 acker at 7850'. Set 15K down to confirm set. 11/4/2008 00:00 - 01:30 1.50 CLEAN P DECOMP PJSM with crew, Halliburton and LRS. Pressure test lines to 4500 psi -charted. Stab open TIW valve in DP. Shut VBR Printed: 11/25/2008 11:02:01 AM • • BP EXPLORATION Page 7 of 9 Operations Summary Report Legal Well Name: MPG-09 Common Well Name: MPG-09 Spud Date: Event Name: WORKOVER Start: 10/24/2008 End: 11/9/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/9/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task Code ~ NPT ~ Phase Description of Operations 11/4/2008 00:00 - 01:30 1.50 CLEAN P DECOMP rams. Pressure test casing to 4000 psi for 15 charted min. Bleed down casing and blow down lines, RD LRS. Open VBR rams. Pull and release Champ 4 packer and monitor well. fluid visibly dropping. LD TIW valve. 01:30 - 06:00 4.50 CLEAN P DECOMP PJSM. POH with packer standing back in Derrick. Pump across top of the hole while tripping. Call for 200 bbls of 10.5 ppg brine and dirty truck. 06:00 - 07:00 1.00 CLEAN P DECOMP BOLD RTTS, Crew change, clean and clear rig floor. 07:00 - 08:00 1.00 ZONISO P DECOMP Service rig. PUMU 7" 26# EZSV bridge plug with mechanical setting tool. 08:00 - 14:00 6.00 ZONISO P DECOMP RIH w/CIBP, pumping across the top with 10.4 #/gal brine. 14:00 - 15:00 1.00 ZONISO P DECOMP PU 2 singles from pipe shed. RIH to 8590'. PU wt of 105K, SOW of 40K. PU and position top of CIBP ~ 8580', Rotate DP 37 turns to right, trap torque. PU to 50K overpull (in 10K increments) to shear and set CIBP. Work pipe up and down to release torque. Slack off and set 25K down on CIBP 15:00 - 20:00 5.00 ZONISO P DECOMP RU circulation lines with returns through choke to Tiger tank. RU LRS to pump with rig pump. Pump 20 Bbl sweep and displace well with 300 Bbl clean 10.5 #/gal brine. Displace C~ 6 BPM, 1550 psi. Circulate 65 Bbl down DP taking returns to Pits. Recovered fine metal shavings when sweep came to surface. 20:00 - 21:30 1.50 ZONISO P DECOMP Flowcheck well while blow down and rig down LRS. Load pits with clean brine. 21:30 - 00:00 2.50 ZONISO P DECOMP POH from 8,580' with setting tool and stand 3-1/2" DP in Derrick. Pump across top of the hole while tripping. 70 stands out at 00:00 hours. 11/5/2008 00:00 - 02:00 2.00 ZONISO P DECOMP Continue to POH with bridge plug setting tool from _4,170' to BHA. 02:00 - 03:00 1.00 ZONISO P DECOMP UD 4-3/4" DC's and setting tool. 03:00 - 03:30 0.50 ZONISO P DECOMP Service Rig. 03:30 - 04:00 0.50 PERFO P OTHCMP Clean and clear rig floor. 04:00 - 05:00 1.00 PERFO P OTHCMP PU/MU 90' of 4-1/2" 5 s f 4505 PJ - erf un assembl 05:00 - 10:00 5.00 PERFO P OTHCMP RIH from Derrick with pert guns on 3-1/2" DP. Pumping 10.4 #/gal brine across the top, keeping trip sheet. RIH BHA on 126 stands (doubles) and 1 single. 10:00 - 12:00 2.00 PERFO P OTHCMP MU head pin. Continue pumping brine across the top. SLB arrive on location. PJSM w/ all crews. Spot SLB unit, load pipe shed with SLB pressure control equipment. 12:00 - 14:00 2.00 PERFO P OTHCMP RU SLB equipment to DP, XO, pu sub, BOPE, MU sections of lubricator in the mousehole. MU lifting bridle to lubricator. Stab rope socket, 1 weight bar into lubricator. PU and make up additional weight bar and GR/CCL. (1-11/16" toolstring). 14:00 - 14:30 0.50 PERFO P OTHCMP MU to BOPE. Zero on top of closed TIW valve. Test lubricator to 1000 psi with rig test pump. No visible leaks. 14:30 - 17:00 2.50 PERFO P OTHCMP RIH w/ GR/CCL to 3260'. Unable to et an dee er. POH. Change configuration of logging tools and rollerstem. 17:00 - 00:00 7.00 PERFO P OTHCMP MU to BOPE and test to 1000 psi with rig test pump. Open TIW valve and RIH with GR/CCL. Tool string stops l~-6,750'. POH and make adjustment to rollerstem, RIH, can not get down past -6,700'. POH w / E-line. RD lubricator and W -B P. 11/6/2008 00:00 - 06:00 6.00 PERFO P OTHCMP RD lubricator and WL BOP, PU 5 ft pup and set drill string in Printed: 11/25/2008 11:02:01 AM • BP EXPLORATION Page 8 of 9 Operations Summary Report Legal Well Name: MPG-09 Common Well Name: MPG-09 Spud Date: Event Name: WORKOVER Start: 10/24/2008 End: 11/9/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/9/2008 Rig Name: NABOBS 3S Rig Number: .Date From - To Hours .Task Code NPT ~ Phase Description of Operations 11/6/2008 00:00 - 06:00 6.00 PERFO P OTHCMP up stroke ~ 7,980' md. Repair failed E-line connection. MU WL BOP and lubricator, RIH to 7,000' and pump tool string down to 7767' 2 bpm ~ 3~psi.~ a two oggmg runs to tie in with PDS CCL/GR dated 12/31/98. Tle in to marker joints and correlate depth. 06:00 - 07:30 1.50 PERFO P OTHCMP POH w/ SLB a-line GR/CCL. At 200' have PJSM on rig down. 07:30 - 09:00 1.50 PERFO P OTHCMP Rig down SLB ROPE and pressure control equipment. 09:00 - 11:00 2.00 PERFO P OTHCMP Review logs and consult with town engineers to confirm depth shift required for firin of uns. Shift uns 27' in hole. Position pert guns on the up stroke to perforate interval 789_ 0'-79= 11:00 - 11:30 0.50 PERFO P OTHCMP Drop 5/8" ball and circulate ~ 1 BPM, 20 Bbls to ball on seat. Flre guns C~? 2650 psi. Great indication of guns firing. PU 1 __ joint and observe fluid fallin in hol Flowcheck well. 11:30 - 14:00 2.50 PERFO P OTHCMP POH laying down 5 singles of DP with charge pump keeping hole full. Flowcheck well again. Losses ~ -4 Bbls/Hr~ 14:00 - 15:30 1.50 PERFO P OTHCMP POH to 6880' laying down singles. Wellbore bubbling with erforation/tri as. Stab head pin. Circulate bottoms up and fowcheck well. Circulate additional 100 Bbls. Flowcheck well. 15:30 - 17:00 1.50 PERFO P OTHCMP POH laying down DP as pump across the top with 10.5 #/gal brine. Loses ~ -4 Bbls/hr. 17:00 - 17:30 0.50 PERFO P OTHCMP RIH with 8 stands remaining in derrick. Inspect and service skate. 17:30 - 00:00 6.50 PERFO P OTHCMP POH laying down DP as pump across the top with 10.5 #/gal brine. Loses C~ -4 Bbls/hr. P/U Kelly and make service breaks. 235 joints LD at 00:00 hours. 11/7/2008 00:00 - 06:00 6.00 PERFO N OTHCMP Troubleshoot electrical malfunction on pipe handler. With Nabors electricians from Rig 9-ES and 3-S. 06:00 - 07:30 1.50 PERFO P OTHCMP Continue POH with DP laying down. Pumping across the top. Losses C~ -6 Bbls/Hr. 07:30 - 09:00 1.50 PERFO C OTHCMP BOLD SLB perforating BHA. All shots confirmed to have fired. Clean and clear rig floor for running completion. 09:00 - 10:30 1.50 BUNCO RUNCMP Load pipe shed with completion assembly. Prep rig floor. 10:30 - 13:00 2.50 BUNCO RUNCMP PUMU straddle acker com letion with MMG-W mandrels for in'ection . Connections below lowermost packer Baker-Lok'd. 3-1/2" completion: WLEG, XN nipple, MMG-W, Premier packer, MMG-W, MMG, Premier packer, X nipple, 3-1/2", 9.3#-L-80 tubing and pup joints. 13:00 - 18:00 5.00 BUNCO RUNCMP RIH on 3-1/2", 9.3#, L-80, EUE 8 rd tubing. Picking up singles from pipe shed. Continuous hole fill with losses of -6 Bbl/hr. Ran to joint #140. 18:00 - 19:00 1.00 BUNCO RUNCMP Make electrical repair to pipe handler. 19:00 - 00:00 5.00 BUNCO RUNCMP Continue RIH on 3-1/2", 9.3#, L-80, EUE 8 rd tubing. Picking up singles from pipe shed. Continuous hole fill with losses of -6 Bbl/hr. Ran to joint #240 at 00:00 hours. 11/8/2008 00:00 - 02:00 2.00 BUNCO RUNCMP Continue RIH on 3-1/2", 9.3#, L-80, EUE 8 rd tubing. Picking up singles from pipe shed. Continuous hole fill with losses of -6 Bbl/hr. MU two pups below joint # 255 and ran last joint #255. New seal rings installed and, all connections torqued to 3000 ft-Ibs, all components were drifted. 02:00 - 03:00 1.00 BUNCO RUNCMP MU 3-1/2" DP landing joint and tubing hanger, land and RILDS with FMC well head tech. SOW = 34 K, POW = 55 K. Dron ball and rod on roller steam. 03:00 - 03:30 0.50 BUNCO RUNCMP on irm ball and rod on seat with 950 psi. Printed: 11/25/2008 11:02:01 AM • BP EXPLORATION Page 9 of 9 Operations Summary Report Legal Well Name: MPG-09 Common Well Name: MPG-09 Spud Date: Event Name: WORKOVER Start: 10/24/2008 End: 11/9/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/9/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task: Code NPT Phase Description of Operations 11/8/2008 103:30 - 07:00 3.501 R 07:00 - 08:30 1.50 RU 08:30 - 10:30 2.00 RU 10:30 - 11:30 1.001 WHSUR P 11:30 - 15:30 4.00 WHSUR P 15:30 - 20:00 4.50 WHSUR P 20:00 - 21:00 1.00 WHSUR P 21:00 - 22:30 1.50 WHSUR P 22:30 - 23:00 0.50 WHSUR P 23:00 - 23:30 0.50 WHSUR P 23:30 - 00:00 0.50 WHSUR P 11 /9/2008 00:00 - 01:00 1.00 WHSUR P RUNCMP RU RLS and pump 120 bbls 8.6 ppg inhibited seawater (packer fluid) down the IA ~ 3 BPM 650 psi. Blow down lines, RD and move LRS unit S-2. MIRU LRS unit S-64 to pump 55 Bbls diese freeze protect down IA. RUNCMP Test lines to IA w/ LRS to 3750 psi. Open IA and pump 55 Bbls of diesel C~3 1/2 BPM / 700 psi. RUNCMP Isolate IA with 700 psi. _Pressure tubing with 10.5 #/gal brine to set ackers at 4200 si. Chart tubin test for 30 minutes. Bleed Tbg to 1000 psi. Pressure IA to 3500 osi. Chart_IA / s. Bleed all pressures to 0 psi. Blow down all lines, RD LRS. RUNCMP BOLD landing joint and hanger XO, TIW valve. Dry rod TWC. Test from above to 3500 si for 10 minutes and chart. RUNCMP Clean and clear rig floor. Lay down Kelly, swivel, etc. OTHCMP ND BOPE and !ay over in shipping cradle. Perform pre-tour checks at crew change, 18:00 hours. WHDTRE Move new 4-1/8" Cameron tree components into cellar. WHDTRE N/U tubing head adaptor, wing valve and production tree, remove second annulus valve. WHDTRE FMC well head tech tested tubing head adaptor to 5,000 psi for 30 minutes. WHDTRE Test tree to 5,000 psi with no visible leaks. WHDTRE PU / MU and test lubricator to 500 psi. WHDTRE Well support techs pulled TWC and set BPV (Caneron 4" t e 'H' . LD lubricator. Pump -15 gal diesel through BPV to 1,000 psi and secure all valves. Rig released at 01:00 hours 11/09/08 for move to F-87. Printed: 11/25/2008 11:02:01 AM • Well History Well Date Summary MPG-09 10/15/2008 T/1=500/0. (RWO prep) (Brush & flush). Ramp Diesel crude rrix as directed dow n TBG. Awgers continued on 10-16-08 MPG-09 10/15/2008 *** WELL S/I ON ARRNAL *** (pre rw o) B&F'd TBG W/ 3 1/2" BRUSH & 2.63" G-RING. UNABLE TO PASS 7501' SLM .RAN 3 1/2" BRUSH & 2.50" G-RING. UNABLE TO PASS 7549' SLM LRS PUMPED A TOTAL OF 119 bbls HOT DIESEL RAN 5' x 2.25" DD-BAILER SEVERAL TIMES, WORKED FROM 7565' SLM TO 7621' SLM RECOVERED 1 GAL OF WHAT APPEARS TO BE SANDY DIRT & SCHMOO. ± *** CONT ON 10/16/08 *** MPG-09 10/16/2008 *** CONT FROM 10/15/08 *** TAGGED XN NIPPLE @ 7524' SLM W/ 2.805" G-RING VERIFIED XN DEPTH W/ 3 1/2" X-LINE RAN 3 1/2" XXN PLUG W/ 2.80" NOGO TO 7543' SLM. OOH W/ PLUG. RAN 2.25" CENT, TEL, S-BAILER TO 7619' SLM, SAMPLE OF SAND, COULD NOT LOC TT. RAN 2.805" GAUGE RING TO 7524' SLM. RAN 3 1/2" XXN PLUG TO 7524' SLM, COULD NOT WORK PAST COULD NOT SET. ***WELL LEFT S/I OPER NOTIFIED* MPG-09 10/16/2008 (Assist Slickline /Brush and Flush / MIT x IA) T/0= 500/0 Pump Diesel crude mix dow n TBG as directed. Press. IA up to 2500 Psi. MITx IA= Intial Press= 800/2500. 15 Mn Press. = 800/2500. 30 Mn. press. _ 800/2500 (MIT x IA is a Pass.) Slickline on w ell @ time of depature. IA open to gauges. MPG-09 10/17/2008 WELL SHUT IN ON ARRNAL INITIAL T/VO = 450/0/0 MASTER OPEN, WING CLOSED,SSV OPEN SET HALLIBURTON 3.5" FASDRILL PLUG CCL STOP DEPTH: 7551.2', CCL TO MID ELEMENT: 7.2', SET DEPTH: 7559', HAD DIFFICULTY GETTING THROUGH DEVIATION WITH JETCUTTER STRING. POOH, MODIFIED GEMCOS TO GET PAST DEVIATION. fr rr "TUBING USIN H 1MB R ,FJ2 POWERCUTTER AT 7543'. CCL TO CUT DEPTH 8.5', CCL STOP DEPTH 7534.5'. WELL LEFT SHUT IN, SWAB CLOSm, MASTER OPEN, SSV OPEN CASING VALVES OPEN TO GUAGES. DSO NOTIFIED. ***JOB COMPLETE'** MPG-09 10/18/2008 MPU Well Suport Techs set BPV in well . NPG-09 10/24/2008 T/IA= BW/0 Temp=cold PPPOT-T (PASS) (Pre RWO) PPPOT-T RU 2 HP BT onto THA test void, 0 psi on void, flush void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 5000/ 15 minutes, 4950/ 30 minutes. Bled void to 0 psi RD test equipment, cycle LDS "ET style" out 3/4" ran in and torqued. MPG-09 10/24/2008 T/1=0/0. (Pre RWO). ~CMrf T x IAA, CMIT T x IA to 10 0 psi. Passed. Lost no pressure in 30 minutes. Bleed pressures dow n to 0 psi. FWHP=O/0. MPG-09 11/8/2008 Freeze PI'otecUPacker Test (Post RWO) -Freeze protect IA w /55 bbls 65*F diesel. Rig set packer & tested tbg. Purno 2.6 bbls diesel to pressure up IA to 3500 psi for 30 min test (rig charted test). Bled IAP to 0 psi all fluid --3 bbls. Pog still on w ell. MPG-09 11/9/2008 ***WELLS/IONARRNAL*** PULL BALL & ROD FROM 8205' MD «<RHC BODY LEFT IN HOLE»> ***WELL S/I ON DEPART*** MPG-09 11/10/2008 T/1=0/0 Freeze Protect (Post RWO) -Pump 5 bbls neet meth followed by 22 bbls 60/40 meth down TBG to freeze protect. W open to gauge. Master, wing, ssv 8 swab closed. Tag well & notify operator. FWHP=100/0 Safety Drill Conducted -Man Dow n/Unit ESD MPG-09 11/28/2008 ***WELLS/IONARRNAL*** FUNCTION CLOSURE TEST WLV RUNNING IN HOLE W/ 3.5 GR ***CONT ON WSR 11-29-08*** MPG-09 11/29/2008 T/1=200/0. (Assist slickline) Pump as directed to assist slickline w/setting plug. FWHP=300/0. Print Date: 12/8/2008 Page 1 of 2 M a o Well Date Summary MPG-09 11/29/2008 ***CONT FROM WSR 11-28-08*** R III 3 5" RH I BODY FROM 8 n6' Ntr] RUN SPARTEK GAUGES MAKE 15 MIN STOPS @ 7691' SLM, 7966' SLM AND 1 HR @ 8191' SLM SET 2.813" PXN (c~ 8206' MD. (4 x 3/16 EO HOLES. PRONG- 1 3/8" FN. 1 7/8" BODY. 40" OAL ) WILL NOT HOLD PRESSURE, TROUBLE SHOOTING ***CONT ON WSR 11-30-08*** MPG-09 11/30/2008 ***CONT FROM WSR 11-29-08*** «««««««< PX PRONG IN TUBING »»»»»»»»»» ATTEMPT TO FISH PX PRONG IN TUBING ********W~L S/I ON DEPART`******** MPG-09 12/1/2008 MPU w ell ST did a leak test w ith the triplex on the source w ater injection line to 3600 PSI for 10 min w ith diesel .Passed. Paper w ork signed off. Print Date: 12/8/2008 Page 2 of 2 STATE C)F ALASKA 11/14/07 OIL AND GAS CONSERVATION COINAAISSI{3N BDt'E Test Report Submit to: Contractor: Nabors Rig Na.: 3S DATE: 11 /3/2008 Rig Rep.: J.Greco / R.Bjorls Rig: Phone: 659-4487 Rig Fax: 659-4486 Operator: Bp Op. Phone: 659-4485 Op. Fax: 659-4628 Rep.: W. HoffrnanN.Volpe Field/Unit & Well No.: MPG-0St PTI3 ~ 1379~Tf3 Operation: Drlg: Workover: X E~ior.: Test: initial: X Weekly: Bi-Weeky Test Pressure: Rams: 250/350Q Anr~.~ar: 250/35011 Valves: 250/3500 TEST DATA MISC. INSREGTIONS: Test Result Test Result Location Gen.: P Wei Sign P Housekeeping: P t3rl. Rig P PTD On Locatian P Haaard Sec.. P Standing Order Posted P BOP STACK:. Quantity Size Test Result. Annular Preventer 1 135!8 5000 P Pipe Rams 1 2 718 X 5 P Lower Pipe Rams 0 NA Blind Rams 1 Blkrd P Choke Ln. Valves 1 3118" 5000 P HCR Valves 2 3118" 5000 P Kill Line Valves 1 2 1f16" 5000 P Check Valve 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P FLOOR SAFETY VALVES: Quantity Test Result Upper Kelly 0 NA Lower Kelly 0 NA BaU Type 1 P Inside BOP 1 P GHOKE MANIFOLD: Quantity Test Result No. Naives 13 P Manual Chokes 1 P HydraulCC Chokes 7 P ACCUMULATOR SYSTEM: Time/Pressure Test R System Pressure 3100 P Pressure After Closure 1700 P 200 psi Attained 30 sec P Full Pressure. Attained 2min 55 sec P Btir-d Switch. Covers: All stations P Nitgn. Bottles (avg}: 2025 Test Results Number of Failures: 0 Test Tune:. 3.5 Hours Repair or replacement of eq~tmerrt w~ be made within Inspector 659-3607, fo~aw with written confkmati€m to Superviser at: Remarks: Tested with 3 112 test ioirrt askainst test 24 YES X NO Date ~ 1102108 Time 16:012 est start 23:00 hrs Finish BOP Test (for rigs) ,.,,"'~~~, ~ ~'ti ~ ~~fl~ BFL 11/14/07 Cornpanerrts tested ALL days. Notify the North Slope By Chuck Sheve Witness R Nabors 3s BOP Test MPG-09i 11-2-2008.x1s • ~- STATE OF ALASKA 11!14107 OIL AND GAS CONSERVATION COMMISSION BOPS Test Report Submit to: Contractor: Nabors Rig No.. 3S Rig Rep.: J.Greco / E.Potter Rig Phone: 659-4487 Operator: Bp Op. Phone: 659-4485 Rep.: W. Hoffman/V.Volpe Field/Unit 8~ Well No.: MPG-09i PTD # '1979'170 Operation: Drlg: Test: Initial: X Test Pressure: Rams: 250/3500 MISC. INSPECTIONS: Workover: X Weekly: Annular: 250/3500 TEST DATA Test Result Test Result Location Gen.: P Well Sign P Housekeeping: P Drl. Rig P PTD On Location P Hazard Sec. P Standing Order Posted P BOP STACK: Quantify Size Test Result Annular Preventer 1 13 5!8 5000 P Pipe Rams 1 2 718 X 5 P Lower Pipe Rams 0 NA Blind Rams 1 Blind P Choke Ln. Valves 1 3 1/8" 5000 P HCR Valves 2 3 1/8" 5000 P Kill Line Valves 1 2 1/16" 5000 P Check Vabe 0 NA MUD SYSTEM: Visual Test Trip Tank P Pit Level indicators P Flow Indicator P Meth Gas Detector P H2S Gas Detector P Alarm Test P P_ P P_ P T esi rcesuitrs CHOKE MANIFOLD: Quantity Test Result No. Valves 13 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 3100 P Pressure After Closure 1700 P 200 psi Attained 20 sec P Full Pressure Attained 2min 03 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 2025 ivumoer of i=aiiures: a Test Time: ~ i-iours components Tested AFL Repair or replacement of equipment will be .~,ade wit#!i€a D ~ ~~: _. _ ~. . ' -. =' ..-.- 1nsnQrtnr 65Q_~~(17 inllgw with yyrrfFgn rnnfirrna~!t~~ ~~ ~!!r~~:,33~~ --- ~ ' ~rV!rarkc; Toctas~ eneitte ? 71? tc+et er~int ' ~!__~_4 f~~y~ iVVTE~~fE G1~f EN YES X NO DATE: 10/26/2008 Rig Fax: 659-4486 Op. Fax: 659-4628 Explor.: Bi-Weekly Valves: 250/3500 FLOOR SAFETY VALVES: Quantity Test Result Upper Kelly 0 NA Lower Kelly 0 NA Batt Type 1 P Inside BOP 1 P ~~ ;.1aT.e -i eD%L^,':t~ : Imo "=•$^ -_.. j ---; I- 1 NNItneSS .1.GreGO ! t/lf. HOttman 1 'BOP Test {for rigs} MP G-09i ;sundry # 308-346 ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, October 10, 2008 9:52 AM To: 'West, Howard J' Subject: RE: MP G-09i {197-117) ;sundry # 308-346 Howard, I acknowledge our conversation. Adding the perforations is not an issue. Nothing further is needed. I will place a copy of this message in the file. Tom Maunder, PE AOGCC ...., ......_. From: West, Howard J [mailto:Howard.West@bp.com] Sent: Friday, October 10, 2008 9:35 AM To: Maunder, Thomas E (DOA) ra „~~ Subject: MP G-09i ;sundry # 308-346 _ ~, ~~ ~~,; ~~, . ~ - ~> Tom- I am writing in regards to the sundry for Milne Point injector, G-09i. The Milne asset team would like to add 70' of perforations in the N sand during the workover. The additional perfs would from 7900' MD to 7970' MD. The additional perforations should not affect our packer placement or any other part of our completion. Please let me know if you have any questionslcomments, Howard West BP RWO Engineer 907-564-5471 10/10/2008 ~ ~ ~ ~~~ ~ a~ ~ f ~.~ ~ ~_ .~ ~., ~ ALASSA OIL Ar1TD GAS C01~T5ERQATI011T COD'II~'II55IO1~T David Reem SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Engineering Team Leader BP Exploration Alaska. Inc. PO Box 196612 ~~~~~ SEP ~ ~; 2D08 Anchorage, AK 99519-6612 ~ ` 1~~ Re: Milne Point Unit, Schrader Bluff Oil Pool, MPG-09 Sundry Number: 308-346 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager), As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unl°ss rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ?sday of September, 2008 Encl. ~~ r STATE OF ALASKA ~ J~9 (~ ALASKA OIL AND GAS CONSERVATION COMMISSION !°6I °r ' ' ~ N APPLICATION FOR SUNDRY APPROVAL, ~~ ~ 20 AAC 25.280 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ^ Alter Casing ®Repair Well ~ ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing - ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 197-117 3. Address: ®Service , ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22779-00-00 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: MPG-09 Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 025518 ~ 58.20' Milne Point Unit / Schrader Bluff 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (tt): Total Depth TVD (ft): Effective Depth MD (tt): Effective Depth TVD (tt): Plugs (measured): Junk (measured): 8970 - 4370 - 8863 4338 8310' 7588' in i cur 1 rf I rm i Pr 7 4 1 Li er Perforation Depth MD (tt): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): ~a~o~ - Faso', Below Plug 8440' - 8739 ao53~ -4058', eaioW Pius a2o9' - a3o0' 3-1 /2", 9.3# L-80 7575' Packers and SSSV Type: 7" Baker'S-3" Packer Packers and SSSV MD (ft): 7547' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch , ^ Exploratory ^ Development ®Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: October 6, 2008 ^ Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ - ®WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Howard West, 564-5471 Printed Name id Reem Title Engineering Team Leader Prepared By NameMumber. Signature ~ Phone 564-5743 Date ~ ~ ~,$ Sondra Stewman, 564-4750 'Commission Use Onl Sundry Number: I Conditions of approval: Notify Commission so that a representative may witness ^ Plug .Integrity ~OP Test Mechanical Integrity Test ^ Location Clearance ~~\\ ~'"S ~ ~~~"~S~ Other: ~ W S c ~~7 .~5~ C3,S ~C3,v~'~~~ Subsequent Form Re wired: `"C~ ~j 1 ~ APPROVED BY ~ U A roved B : COMMISSIONER THE COMMISSION Date Form 10-403 Revised 06/2006 '~ `, `~ ~ _ . ~-: SFP ~ ~ 2008 Submit In Duplicate • • by Milne Point G-O9i Rig Workover Scope of Work: Pull existing 3 1/2"tubing completion, Mill and retrieve 3'/z"x 7" Baker S-3 packer ,Mill up 2.5 bbl cement plug @ 8160', Set CIBP above OB perforations C~ 8550', Run selective single completion on 3 1/2", 9.2 #, L-80, tubing. MASP: 1210 psi Well Type: Schrader Injector Estimated Start Date: Oct. 6, 2008 Pre-ri re work• F 1 CMIT-TxIA to 2500 si. S 2 Drift for 3 1/2" TTP & ~et cutter. Set 3'/z" TTP in XN-Ni le at 7563. E 3 Power Jet cut 3 1/2" L-80 tubing at 1' above the bottom of the 6' pup joint above the Baker acker F 4 Circulate well with kill wei ht fluid and diesel thru the cut. CMIT TxIA to 1000 si W 5 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka a check one at a time . PPPOT-T & IC. W 6 Set a BPV in the tubin han er. O 7 Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure: 1. MIRU Nabors 3S. 2. Circulate out freeze protection fluid and circulate well with warm seawater. Measure SITP. 3. Kill well with clean kill weight fluid. 4. ND tree. NU and test BOPE to 4000 psi, test annular to 3500 psi. Stack will consist of 2 7/8" x 5" VBRs, blind rams, and annular preventer. 5. POOH with existing 3'/z" completion down to the cut. 6. Mill and retrieve 3'h"x 7" Baker S-3 packer 7. Mill up 2.5 bbl cement plug C~ 8160' 8. Retrieve Baker IBP C 8310' 9. Set CIBP above OB perforations C~ 8550'. 10. Run selective single completion on 3 1/2", 9.2 #, L-80, tubing. 11. Test the IA to 4000 psi. 12. Freeze protect to 2200' MD w/diesel. 13. ND BOPE. Set & test BPV. 14. Install tree, test to 5000 psi. 15. RDMO. Tree:4-1/16"- 5M FMC Wellhead: 11"-5M Monobore w/ 4.5" FMC Tbg. Hng , NSCT lift threads,4.5" CIW H BPV profile 20", 91.1 #,H-40 conductor 11~ KOP @ 500' Max. hole angle = 70 to 76 deg. f/ 3300' to 8100' Hole angle thru' perfs = 72 deg 3.5", 9.3#, L-80 8rd E U E Tubing ID= 2.992, Cap =.0087 bpf 7", 26#, L-80, BTC casing Casing ID= 6.276; Cap = .0264 bpf Perforation Summary: Tie in log: SWS USIT 2/20/98 Size SPF Interval (NC NB Sands 2" 4 7870'-7890' 4053'-40 OA Sands 2" 4 8440'-8460' 4208'-42 2" 4 8500'-8520' 4227'-42: 4.5" 5 8659'-8739' 4275'-4~ 2" Powerjet guns, 60 deg, phasing 4-: deep penetrating charges DATE REV. BY C,oMMENTS 07/06/97 M. Linder Nabors 22-E 02/22/98 M. Linder Nabors 4-ES 7/25/02 MDO CTU Baker IBP W/ Gel and Cement cap. Orig. IZ' elev. = 58.20 (N22E) Orig. GL elev. = 29.20 (N22E) HES cementer 5" HES "X" Nipple 81" ID. 1931' I 2220' I Baker S-3 Packer " 7547, I D 375 i" HES "XN" Nipple 7563' 31" packing bore ID '5 No-Go. " 7575' WLEG 5 '"x 21' Marker joint. 7588 bl 12 ppg Crete 8160' - 8243' 13 ppg Mud viscous pill r MHA/2.5" IBP @ 8310' 7", landing collar T', 26# L-80 Buttress 8863' I 8945' MILNE POINT UNIT WELL: MPU-G-09i API NO: 50-029-22779 BP EXPLORATION (AK) MPU G-09 Tree:4-1/16"- 5M FMC Wellhead: 11"-5M Monobore w/ 4.5" FMC Tbg. Hng , NSCT lift threads,4.5" CIW H BPV profile 120", 91.1 #,H-40 conductor 112 KOP @ 500' Max. hole angle = 70 to 76 deg. f/ 3300' to 8100' Hole angle thru' perfs = 72 deg 3.5", 9.3#, L-80 8rd EUE Tubing ID= 2.992, Cap =.0087 bpf 7", 26#, L-80, BTC casing Casing ID= 6.276, Cap = .0264 bpf Perforation Summary: Tie in log: SWS USIT 2/20/98 Size SPF Interval (ND NB Sands 2" 4 7870'-7890' 4053'-40: OA Sands 2" 4 8440'-8460' 4208'-42' 2" 4 8500'-8520' 4227'-42~ 4.5" 5 8659'-8739' 4275'-43 2" Powerjet guns, 60 deg. phasing 4-s deep penetrating charges DATE REV. BY COMMENTS 07/06/97 M. Linder Nabors 22-E 02/22/98 M. Linder Nabors 4-ES 7/25/02 MDO CTU Baker IBP W/ Gel and Cement cap. Orig. KB elev. = 58.2 E) Orig. GL elev. = 29.20 2E) GAS LET MANDRELS ST MD ND DEV TYPE S¢E ST 7750 MMG .5"x1.5" ST 7900 MMG .5"x1.5° ST 7950 MMG .5"x1.5" ST 8050 MMG .5"x1.5" DES cementer 1931' 5" HES "X" Nipple 2220' "x 21' Marker joint. 7588' " HES "XN" Nipple Baker S-3 Packer 7850' Baker S-3 Packer 8010' .5" HES "XN" Nipple i' WLEG D 8550` '", landing collar 8863' I "', 26# L-80 Buttress 8945' MILNE POINT UNIT WELL: MPU-G-09i API NO: 50-029-22779 BP EXPLORATION (AN G-09i MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commissl TO: Jim Regg P.I. Supervisor Ret1' '3/ ":;i!JDy . I DATE: Wednesday, August 30, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC G-09 MILNE PT UNIT SB G-09 \ q1 ~ \ \ '1 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv. íPlZ- Comm Well Name: MILNE PT UNIT sa G-09 API Well Number 50-029-22779-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS0608250749 I 8 Permit Number: 197-117-0 Inspection Date: 8/24/2006 Rei Insp N um Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well G-09 Type Inj. w TVD 3979 IA 0 2040 2000 2000 P.T. 1971170 TypeTest SPT Test psi 1500 OA Interval 4YRTST PIF P /' Tubing 750 750 750 750 Notes Well is a single casing strind design. NON-CONFIDENTIAL S(;ANNED SEP 0 8200B Wednesday, August 30, 2006 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor Chair THRU: Tom Maunder P.I. Supervisor FROM: jeff Jones Petroleum Inspector NON- CONFIDENTIAL DATE: September 2, 2002 SUBJECT: Mechanical Integrity Tests BPXA G, K, L Pads. G-09i, G~13i, K-21i, L-15i MPU Milne Point Field Packer. Depth Pretest Initial 15 Min. 30 Min. WellI G-09i Type lnj.I S I T.V.D. I 3985 I Tubingl 1300 J 1300 J 1300 I 1300 I lntervall 4 P.T.D.I 1971170 Typetestl ' P ITestpsil 1500 I CasingI 850 1152O11505115051 P/F I P Notes: Pre-test press, monitored & stable. -'--" WellI G-13i I Typelnj. I S I T.V.D. I 3902 I Tubing I 1450 I 1450 I 1450 I '1450 I lntervall 4 P.T.D.! 1971200 Typetest} P ITestpsil 1500 ICasingI 580 J 1960I 1910I 1900I P/F I P Notes: Pre-test press, monitored & stable. ----- WellI K-21i. ITypelnj. I S I T.V.D. I 6945 I Tubingl 1100 I 1100 I 1100 j 1100 IlnterVall 4 I P....T.D.J 1961760 TYpetestJ P JTestpsiI 1736 JCasingJ 8~25 I S°°l 1780J 1780J P/F I P I Notes: Pre-test press, monitored & stable. I WellI L-15i I Typelnj.I N I T.V.D. I~,~, I Tubing 14450 14450 14450 14450 J lntervalI 4 P.T.D.I 1940620 ITypetestl P ITestpsil 1737 I CasingI zero I 1800 I 1760 I 1760 I P/F iP Notes: Pre-test press, monitored & stable. ----, Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = S-~!-" WATER INJ. N: . .~ECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= .Other (describe in notes) Test's Details September 2, 2002: I traveled to BPXA's Milne Point Field to witness 4 year MIT's on water injeCtion wells G-09i, G- 13i, K-21i and L-15i. Jeff Jones was the BPXA representative in charge of the tests. The pre-test pressures were monitored for 15 minutes and the standard annulus pressure test was then performed on each well, with all four wells passing the MIT. I inSpected each well house during the tests and no exceptions were noted. Summary: I witnessed successful MIT's on BPXA's Milne Point Field injection wells G'09i, G-13i, K-21i and 1-15i. Four well houses inspected, no exceptions noted. M.I.T.'s performed: _4 Attachments: Number of Failures: 0 Total Time during tests: 4.5 hrs. cc: OCT'o 4 2DL)2 MIT repcA form 5/12t00 L.G. MIT MP'U G-09i,G-13i, K-21 i, L-15i 9-2-02 JJ.xls 9/10/2002 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED · ON OR BEFORE JANUARY 03 2001 P L E W M ATE IA L U N D ER TH IS M ARK ER C:LORBMFILM.DOC ........................................................................ '~'~'~P0~T'~"SB '~'0'~ .......................... 50L' 029~22779Lo0 BP EXPLORATION 197-117-0 MD 08970" TVD 04369 ~ ~ietionDate: 2/23/98 ~CompletedStatus: 1WINJ Current: T Name Interval Sent Received T/C/D L COMP RCD ~ 8495-8830 CH 5 3/6/98 3/13/98 L DGR/CNP/SLD-MD ~;-~112-8970 OH 9/17/97 9/17/97 L DGR/CNP/SLD-TVD 1124370 OH 9/17/97 9/17/97 L DGPdEWR4-MD ~f~A.'L 112-8970 OH 9/17/97 9/17/97 L DGR/EWR4-TVD ~AL 1124370 OH 9/17/97 9/17/97 L GR/CCL(PDC) ~~ 3000-8844 CH 5 11/6/98 11/6/98 L INJP ~300-8715 CH 5 1/5/99 1/6~/99 L RFT ~'I~AL 7883-8723 CH 11/5/97 11/5/97 L USIT ~q'A~l~ BL(C)3000-8844 CH 5 3/23/98 3/25/98 t~ SPERRY MPT/GRC/EWR OH 9/10/97 9/10/97 · .... T 8902 : ~ SCHLUM PDC-GR/CCL CH 11/6/99 11/6/98 Daily Well Ops ~/~ ~' '~ .-~ '-~. ' . ~' - Are Dry Ditch Samples Required? yes~.~.~ao~ And Receivedg~-.-ye~mo Was the well cored? yes ~.~_~_ Analysis Description Receiv.ed_d~-yes~no~ .... Sample~S~-# ......... Comments: Thursday, February 03, 2000 Page 1 of 1 ALASKA dU. AND GAS CONSERVATION CO/~.~,¢ISSION REPC ,' OF SUN-DRYWELL OPERA 3NS 1. Operations performed: I--] Operation Shutdown I--IStimulate [~ Plugging 6~ Perforate [~] Pull Tubing I--]Alter Casing E~ Repair Well E~Other 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 5. Type of well: I--I Development F-i Exploratory E~ Stratigraphic ~] Service 4. Location of well at surface 1605' NSL, 3342' WEL, SEC. 27, T13N, R10E, At top of productive interval N/A At effective depth 2631' SNL, 3442' EWL, SEC. 35, T13N, R10 At total depth 2693' SNL, 1924' EWL, SEC. 35, T13N, R10E 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural ConductOr Surface Intermediate Production Liner 8970' feet 4369' feet 8863' feet 4338' feet Length Size 83' 20" 8909' 7" Plugs (measured) Junk (measured) Cemented 250 sx Arcticset I (Approx.) 1200 sx PF 'E', 240 sx Class 'G' 6. Datum Elevation (DF or KB) KBE= 58.20 7. Unit or Property Name Milne Point Unit 8. Well Number MPG-09 9. Permit Number / Approval No. 97-117 10. APl Number 50-029-22779 11. Field and Pool Milne Point Unit/Schrader Bluff MD TVD 112' 112' 8945' 4353' PeRoration depth: measured 7870'-7890';8440'-8460';8500'-8520';8659'-8739' true vedical 4053'-4053';4208'-4215';4227'-4233"4276'-4300' Tubing (size, grade, and measured depth) 3-1/2", 9.2#, L-80 @ 7575' ORIGINAL Packers and SSSV (type and measured depth) Packer @ 7547' 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure ' [ -..! :.,;. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments [~] Copies of Logs and Surveys run I--I Daily Report of Well Operations 17. I hereby certify that the foregcj, ng is true and correct to the best of my knowledge Signed PATRICK&COLLINS[)k~_______¢~ ~ ((`q'' t~ Title Production Engineer 16. Status of well classifications as: E~ Oil F-I Gas i~ Suspended Prepared By Name/Number: Service Water Injection Date Michael Williams, 564-46~7 Form 10-404 Rev. 06/15/88 Submit In Duplic_~ 09/01/99 - MPG-09 DESCRIPTION OF WORK COMPLETEb REPERF SUMMARY The following additional interval were reperforated using 2" guns, 4 SPF, zero orientation and 60° phasing. 787O-789O MD 8440-8460 MD 85O0-852O MD RECEIVED f',.: 0V 0 5 1999 0il & Gas Cons, Commi~si0n An~0r~e BP EXPLORATION Date: 01-05-99 Trans# 90087 BP/MILNE POINT CASED HOLE LOGS Enclosed are the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4166 Sw Name Rec Type Rec Date Company Code Comments MPG-09 CH 31-Dec-98 PDS INJECTION PROFILE 'MPG-09 CH 31-Dec-98 PDS JEWELRY LOG Please' sign and return one copy of this transmittal. Thank-you, Carla H. Mclntosh Petrotechnical Data Center CH LOGS OXY AOGCC Bonnie Kloth MB4-2 RECEIVED JAN 0 6 199 Alaska Oil & Gas Cons. Com~ Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND 1. Status of Well Classification ot~-~t{~'~e~as C0rls. C0~'II~I r--IOil [] Gas []Suspended [~]Abandoned [~Service Water Iniection Anchorage 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 97-117 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22779 4. Location of well at surface ~'~,~.~_~ ~";~:~,:. '::" ~ ' ~~!~,~miir~ ~i~ 9. Unit or Lease Name 1605' NSL, 3342' WEL, SEC. 27, T13N, R10E, UM ; ..... .~. :...: ,,~. ~,.~. 7 Milne Point Unit .. Attop of productive interval i~~ ' 10. We,I Number 2508' SNL, 1693' EWL, SEC. 35, T13N, R10E, UM ! MPG-09i i "..;;~'...~:~,~, ~ 11 Field and Pool At total depth i. ;~-! ~ : . 2693' SNL, 1924' EWL, SEC. 35, T13N, R10E, UM Milne Point Unit / Schrader Bluff 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease DesignatiOn` and Serial No. KBE = 58.20'I ADL 025518 12. Date Spudded I 13. Date I.D. Reached t 14. Date Comp., Susp., or Aband.115. Water depth, if offshore 116. No. of Completions 6/27/97 7/2/97 2/23/98 N/A MSLI One 17. Total Depth (MD+TVD)8970 4369 FT1118' Plug Back Depth (MD+TVD)I19' Directi°nal Survey 120' Depth where SSSV set121' Thickness °f Permafr°st8863 4338 F-rI [~Yes [~No N/A MD 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, LWD, RFT, USIT, MFCT, GR/JB 23. CASING~ LINER AND CEMENTING RECORD CASING I SE-I-rING DEPTH HOLE SIZEI WT. PER FT. GRADE TOP BO-FrOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 32' 112' 24" 250 sx Arcticset I (Approx.) 7" 26# L-80 30' 8945' 8-1/2" 1200 sx PF 'E', 240 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Gun Diameter, 5 spf 3-1/2", 9.2#, L-80 7575' 7547' MD TVD MD TVD 8659'-8739' 4276'-4300' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 80 bbls diesel 27. PRODUCTION TEST Date First Production t Method of Operation (Flowing, gas lift, etc.) March 9, 1998! Water Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAs-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL 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. ORIGINAL Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. - Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. TSBD 8424' 4203' TSBC 8545' 4241' TSBB 8659' 4276' 3i". List of Attachments Summary of Daily Drilling Reports, Surveys 32. I here~ the fore--rue and cor.[ect to the best of my knowledge Sign~~J.~_.~~~/ Title Drilling Engineering Supervisor Date MPG-09i 97-117 Prepared By Name/Number: Kathy Campoamor, 564-5122 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Facility M Pt G Pad Progress Report Well MPG-09 Page 1 Rig Nabors 4F~~ Date 04 May 98 Date/Time 26 Jun 97 27 Jun 97 28 Jun 97 29 Jun 97 30 Jun 97 01 Jul 97 02 Jul 97 06:00-14:30 14:30-16:30 16:30-17:00 17:00-17:30 17:30-02:00 02:00-05:00 05:00-06:00 06:00-08:00 08:00-09:00 09:00-10:00 10:00-00:30 00:30-01:00 01:00-02:00 02:00-03:00 03:00-04:00 04:00-06:00 06:00-12:30 12:30-13:30 13:30-14:30 14:30-15:30 15:30-16:00 16:00-06:00 06:00-07:30 07:30-09:00 09:00-15:00 15:00-15:30 15:30-16:00 16:00-17:30 17:30-20:30 20:30-22:30 22:30-03:00 03:00-04:00 04:00-06:00 06:00-06:30 06:30-16:30 16:30-18:00 18:00-18:30 18:30-19:00 19:00-06:00 06:00-07:30 07:30-09:00 09:00-10:00 10:00-11:00 11:00-12:30 12:30-13:30 13:30-01:30 01:30-03:00 03:00-04:00 04:00-04:30 04:30-06:00 06:00-08:00 08:00-09:00 09:00-10:30 10:30-14:00 Duration 8-1/2 hr 2hr 1/2 hr 1/2 hr 8-1/2 hr 3hr lhr 2hr lhr lhr 14-1/2 hr 1/2 hr lhr lhr lhr 2hr 6-1/2 hr lhr lhr lhr 1/2 hr 14hr 1-1/2 hr 1-1/2 hr 6hr 1/2 hr 1/2 hr 1-1/2 hr 3hr 2hr 4-1/2 hr lhr 2hr 1/2 hr 10hr 1-1/2 hr 1/2hr 1/2 hr llhr 1-1/2 hr 1-1/2 hr lhr lhr 1-1/2 hr lhr 12 hr 1-1/2 hr lhr 1/2 hr 1-1/2 hr 2hr lhr 1-1/2 hr 3-1/2 hr Activity Installed Divertor Serviced Service lines Racked back Drillpipe Tested Divertor Racked back Drillpipe Racked back HWDP Made up BHA no. 1 Made up BHA no. 1 Circulated at 0.0 ft Rigged up Divertor Drilled to 2118.0 ft Circulated at 2118.0 ft Pulled out of hole to 740.0 ft Serviced Top drive R.I.H. to 2118.0 ft Drilled to 2578.0 ft Drilled to 3687.0 ft Circulated at 3687.0 ft Pulled out of hole to 1657.0 ft Serviced Top drive R.I.H. to 3687.0 ft Drilled to 5780.0 ft Drilled to 5874.0 ft Circulated at 5874.0 ft Pulled out of hole to 0.0 ft Pulled BHA Downloaded MWD tool Made up BHA no. 2 Serviced Top drive R.I.H. to 3909.0 ft Washed to 5874.0 ft Circulated at 5874.0 ft Pulled out of hole to 3600.0 ft R.I.H. to 5800.0 ft Drilled to 6960.0 ft Circulated at 6960.0 ft Pulled out of hole to 5800.0 ft R.I.H. to 6960.0 ft Drilled to 7914.0 ft Drilled to 8009.0 ft Circulated at 8009.0 ft Pulled out of hole to 6386.0 ft Serviced Top drive motor Serviced Top drive R.I.H. to 8009.0 ft Drilled to 8970.0 ft Circulated at 8970.0 ft Pulled out of hole to 6000.0 ft R.I.H. to 6760.0 ft Logged hole with LWD: Formation evaluation (FE) from 6760.0 ft to 8£ Logged hole with LWD: Formation evaluation (FE) from 6760.0 ft to 721 R.I.H. to 8970.0 ft Circulated at 8970.0 ft Pulled out of hole to 0.0 ft )0.0 ft 18.0 fl Progress Report Facility M Pt G Pad Well MPG-09 Rig Nabors ~ $t,¢~ Page 2 Date 04 May 98 Date/Time 14:00-15:00 15:00-16:00 16:00-16:30 16:30-18:00 18:00-18:30 18:30-01:30 03 Jul 97 01:30-03:30 03:30-06:00 06:00-09:00 09:00-10:00 10:00-11:30 11:30-14:30 14:30-15:00 15:00-16:30 16:30-17:30 17:30-18:30 18:30-19:00 19:00-22:30 22:30-23:00 23:00-01:30 04 Jul 97 01:30-05:00 05:00-06:00 06:00-06:30 06:30-07:00 07:00-07:30 07:30-08:30 08:30-19:30 19:30-21:00 21:00-23:00 23:00-00:00 05 Jul 97 00:00-01:30 01:30-03:00 03:00-06:00 06:00-07:30 07:30-09:00 09:00-14:00 14:00-17:00 Duration lhr lhr 1/2 hr 1-1/2 hr 1/2 hr 7hr 2hr 2-1/2 hr 3hr lhr 1-1/2 hr 3hr 1/2 hr 1-1/2 hr lhr lhr 1/2 hr 3-1/2 hr 1/2 hr 2-1/2 hr 3-1/2 hr lhr 1/2 hr 1/2 hr 1/2 hr lhr llhr 1-1/2 hr 2hr lhr 1-1/2 hr 1-1/2 hr 3hr 1-1/2 hr 1-1/2 hr 5hr 3hr Activity Downloaded MWD tool Pulled BHA Removed Drillfloor / Derrick Installed Production logging tools Held safety meeting R.I.H. to 7797.0 ft Functioned Downhole measurement tools Conducted electric cable operations Conducted electric cable operations Pulled out of hole to 8000.0 ft Rigged down Logging/braided cable equipment Pulled out of hole to 100.0 ft Rigged down sub-surface equipment - Formation logs Made up BHA no. 4 Serviced Top drive Serviced Block line Held safety meeting R.I.H. to 8770.0 ft Washed to 8970.0 ft Circulated at 8970.0 ft Pulled out of hole to 550.0 ft Pulled BHA Pulled BHA Installed Casing handling equipment Held safety meeting Installed Casing handling equipment Ran Casing to 8764.0 ft (7in OD) Washed to 8944.0 ft Mixed and pumped slurry - 204.000 bbl Circulated at 8944.0 ft Mixed and pumped slurry - 401.000 bbl Rigged down Casing handling equipment Removed Divertor Installed Accessories Installed Tubing head spool Installed Tubing hanger Fill pits with Water Facility Date/Time 18 Feb 98 19 Feb 98 20 Feb 98 21 Feb 98 22 Feb 98 23 Feb 98 Progress Report M Pt G Pad Well MPG-09 Page 1 Rig Nabors 4ES Date 05 May 98 16:00-00:00 00:00-01:30 01:30-06:00 06:00-06:30 06:30-11:00 11:00-12:00 12:00-16:30 16:30-17:00 17:00-01:30 01:30-03:30 03:30-06:00 06:00-07:30 07:30-08:00 08:00-12:00 12:00-13:00 13:00-15:00 15:00-18:00 18:00-22:30 22:30-23:00 23:00-03:00 03:00-04:30 04:30-06:00 06:00-06:30 06:30-10:30 10:30-12:00 12:00-16:00 16:00-16:30 16:30-00:00 00:00-06:00 06:00-06:30 06:30-13:30 13:30-15:30 15:30-19:00 19:00-20:00 20:00-01:00 01:00-06:00 06:00-07:00 07:00-08:00 Duration 8hr 1-1/2 hr 4-1/2 hr 1/2 hr 4-1/2 hr lhr 4-1/2 hr 1/2 hr 8-1/2 hr 2hr 2-1/2 hr 1-1/2 hr 1/2 hr 4hr lhr 2hr 3hr 4-1/2 hr 1/2 hr 4hr 1-1/2 hr 1-1/2 hr 1/2hr 4hr 1-1/2 hr 4hr 1/2hr 7-1/2 hr 6hr 1/2 hr 7hr 2hr 3-1/2 hr lhr 5hr 5hr lhr lhr Activity Rigged up Drillfloor / Derrick Functioned Xmas tree Rigged up BOP stack Held safety meeting Tested BOP stack Made up BHA no. 1 R.I.H. to 1916.0 ft Drilled installed equipment - DV collar R.I.H. to 8855.0 ft Reverse circulated at 8855.0 ft Circulated at 8855.0 ft Circulated at 8855.0 ft Tested Other sub-surface equipment - Via annulus and string Pulled out of hole to 0.0 ft Worked on BOP - Lubricator Conducted electric cable operations Conducted electric cable operations Perforated from 8719.0 ft to 8739.0 ft Perforated Fished at 20.0 ft Conducted electric cable operations Perforated from 8699.0 ft to 8719.0 ft Conducted electric cable operations Perforated from 8659.0 ft to 8679.0 ft Installed Bell nipple R.I.H. to 8659.0 ft Reverse circulated at 8659.0 ft Laid down 8659.0 ft of 3-1/2in OD drill pipe Ran Tubing to 2430.0 ft (3-1/2in OD) Held safety meeting Ran Tubing to 7547.0 ft (3-1/2in OD) Rigged down BOP stack Installed Xmas tree Tested Xmas tree Circulated at 7547.0 ft Set Permanent packer at 7547.0 ft with 4000.0 psi Set Permanent packer at 7547.0 ft with 4000.0 psi Removed High pressure lines S PERR% BP EXPLORATION MILNE POINT / MPG-09 500292277900 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/17/97 TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH .00 .00 -58.20 112.00 112.00 53.80 201.76 201.76 143.56 293.98 293.98 235.78 383.80 383.80 325.60 474.85 474.83 416.63 567.77 567.68 509.48 657.76 657.50 599.30 750.49 749.84 691.64 842.56 841.25 783.05 933.99 931.77 873.57 1026.98 1023.44 965.24 1118.70 1113.21 1055.01 1209.71 1201.56 1143.36 1301.02 1289.52 1231.32 1393.50 1377.37 1319.17 1488.28 1465.57 1407.37 1581.37 1550.97 1492.77 1674.04 1635.56 1577.36 1766.98 1719.64 1661.44 1859.41 1801.90 1743.70 1949.53 1880.37 1822.17 2040.63 1957.96 1899.76 2130.71 2034.67 1976.47 2222.94 2112.90 2054.70 2313.73 2187.38 2129.18 2407.40 2261.65 2203.45 2500.35 2331.86 2273.66 2591.42 2396.03 2337.83 2684.72 2456.97 2398.77 2776.82 2512.17 2453.97 2868.65 2563.50 2505.30 2961.84 2611.77 2553.57 3054.97 2655.34 2597.15 3147.31 2694.68 2636.48 UN DRILLING SERVICES ~-~NCHOR3AGE ALASKA COURS COURSE INCLN DIRECTION DG MN DEGREES DATE OF SURVEY: 070297 MWD SURVEY JOB NUMBER: AK-MM-70~_~8,~. ,, KELLY BUSHING ELE~.''~'' o TOR: BP X O TION DLS TOTAL RECT~GULAR COORDINATES VERT. DG/100 NORTH/SOUTH EAST/WEST SECT. 0 0 N .00 0 0 N .00 0 22 N 11.38 0 10 N 66.01 0 22 S 59.35 E .00 .00N .00E .00 E .00 .00N .00E .00 W .42 .29N .06W -.23 E .41 .65N .01E -.41 E .34 .55N .38E -.06 1 17 S 53.65 2 52 S 51.48 4 9 S 47.44 6 10 S 40.57 7 26 S 42.28 E 1.01 .20S 1.46E 1.26 E 1.71 2.28S 4.12E 4.63 E 1.45 5.89S 8.30E 10.15 E 2.27 11.96S 14.02E 18.42 E 1.39 20.13S 21.25E 29.20 8 42 S 43.67 10 33 S 48.94 13 4 S 51.29 14 40 S 52.92 16 24 S 54.82 E 1.41 29.52S 30.02E 41.92 E 2.19 40.21S 41.30E 57.42 E 2.80 52.21S 55.72E 76.19 E 1.81 65.59S 72.95E 97.99 E 1.99 80.00S 92.71E 122.41 19 56 S 53.92 22 58 S 52.22 23 56 S 52.79 24 16 S 52.80 26 8 S 50.34 E 3.83 96.81S 116.14E 151 E 3.26 117.67S 143.83E 185 E 1.07 140.22S 173.23E 222 E .36 163.10S 203.37E 260 E 2.31 187.72S 234.35E 300 .20 .83 .86 .68 24 28 5 S 48.84 30 47 S 47.75 32 24 S 45.51 30 48 S 44.23 33 7 S 43.86 E 2.24 215.03S 266.41E 342 E 3.05 244.51S 299.46E 386 E 2.19 277.29S 334.13E 434 E 1.92 310.74S 367.44E 481 E 2.52 345.83S 401.38E 529 35 .60 19 .15 64 36 35 S 45.58 38 28 S 48.39 43 21 S 48.27 47 1 S 48.30 51 24 S 50.52 E 3.97 382.68S 437.91E 581 E 2.71 421.57S 479.64E 638 E 5.25 462.04S 525.11E 698 E 4.02 505.03S 573.33E 763 E 5.04 550.94S 626.98E 834 24 .17 98 .52 12 54 55 S 51.22 57 7 S 54.05 60 28 S 53.01 63 43 S 52.40 65 51 S 54.30 E 3.86 597.44S 684.16E 907 E 3.51 643.63S 744.69E 983 E 3.71 691.01S 808.77E 1063 E 3.54 740.88S 874.23E 1145 E 2.97 790.73S 941.26E 1229 83 .92 .52 .76 .21 SPERR[ UN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPG-09 500292277900 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/17/97 DATE OF SURVEY: 070297 MWD SURVEY JOB NUMBER: AK-MM-70189 KELLY BUSHING ELEV. = 58.20 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATE DEGREES DG/100 NORTH/SOUTH EAST/WEST S VERT. SECT. 3240.49 2730.20 2672.00 3333.36 2760.43 2702.23 3425.69 2787.37 2729.17 3517.81 2814.75 2756.55 3609.66 2843.12 2784.92 69 18 72 41 73 22 72 2 71 58 S 54.02 E 3.71 841.16S 1011.08E S 52.79 E 3.85 893.51S 1081.56E S 53.51 E 1.06 946.47S 1152.22E S 51.81 E 2.28 999.81S 1222.15E S 51.17 E .67 1054.20S 1290.50E 1315.18 1402.88 1491.11 1579.01 1666.36 3703.75 2869.91 2811.71 3797.14 2893.52 2835.32 3889.20 2916.31 2858.11 3984.78 2941.15 2882.95 4079.51 2966.95 2908.75 74 75 75 74 74 55 46 33 18 4 S 49.67 E 3.49 1111.67S 1360.00E S 50.12 E 1.02 1169.87S 1429.11E S 50.50 E .47 1226.84S 1497.75E S 50.57 E 1.31 1285.50S 1569.00E S 50.51 E .25 1343.42S 1639.37E 1756.54 1846.88 1936.07 2028.36 2119.51 4174.86 2992.42 2934.22 74 55 4270.20 3017.12 2958.92 75 2 4366.35 3041.57 2983.37 75 30 4460.40 3066.80 3008.60 73 22 4556.49 3093.93 3035.73 73 49 S 49.81 E 1.14 1402.29S 1709.92E S 52.38 E 2.61 1460.10S 1781.56E S 50.85 E 1.61 1517.84S 1854.44E S 51.36 E 2.32 1574.72S 1924.94E S 49.51 E 1.91 1633.43S 1995.99E 2211.38 2303.44 2396.41 2487.00 2579.16 4652.07 3121.20 3063.00 73 4747.14 3148.91 3090.71 73 4841.66 3176.26 3118.06 73 4938.14 3204.88 3146.68 72 5033.54 3233.54 3175.34 72 1 5 16 12 49 S 51.25 E 1.94 1691.84S 2066.55E S 49.15 E 2.11 1750.04S 2136.41E S 47.26 E 1.92 1810.34S 2203.85E S 47.13 E 1.11 1872.94S 2271.44E S 46.51 E .90 1935.20S 2337.79E 2670.76 2761.68 2852.06 2944.01 3034.79 5127.67 3261.30 3203.10 72 52 5225.03 3290.99 3232.79 71 37 5322.45 3321.73 3263.53 71 35 5417.53 3351.94 3293.74 71 21 5510.10 3380.92 3322.72 72 9 S 49.23 E 2.76 1995.53S 2404.49E S 50.06 E 1.52 2055.57S 2475.14E S 48.91 E 1.12 2115.62S 2545.42E S 50.95 E 2.05 2173.65S 2614.40E S 52.06 E 1.42 2228.37S 2683.20E 3124.61 3217.31 3309.73 3399.86 3487.76 5605.56 3409.83 3351.63 5701.53 3438.68 3380.48 5798.73 3469.36 3411.16 5898.68 3502.64 3444.44 5967.56 3525.51 3467.31 72 35 72 25 70 46 70 19 70 53 S 52.23 E .49 2284.19S 2755.03E S 52.37 E .23 2340.17S 2827.45E S 53.67 E 2.11 2395.64S 2901.12E S 55.02 E 1.35 2450.58S 2977.69E S 57.34 E 3.28 2486.73S 3031.66E 3578.71 3670.20 3762.35 3856.40 3921.06 6031.57 3546.57 3488.37 70 41 6127.51 3578.41 3520.21 70 32 6223.05 3610.66 3552.46 70 0 6318.55 3643.63 3585.43 69 36 6414.13 3675.58 3617.38 71 19 S 55.87 E 2.19 2520.00S 3082.12E S 56.83 E .96 2570.14S 3157.46E S 55.44 E 1.48 2620.25S 3232.13E S 55.59 E .43 2671.00S 3306.00E S 53.66 E 2.62 2723.14S 3379.43E 3981.19 4071.25 4160.77 4250.09 4339.94 SPERR% 3N DRILLING SERVICES ANCHOR_AGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPG-09 500292277900 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/17/97 DATE OF SURVEY: 070297 MWD SURVEY JOB NUMBER: AK-MM-70189 KELLY BUSHING ELEV. = 58.20 OPEKATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS INCLN DIRECTION DG MN DEGREES DG/10 TOTAL RECTANGULAR COORDINATES 0 NORTH/SOUTH EAST/WEST VERT. SECT. 6509.59 3706.13 3647.93 71 20 S 52.13 E 1.52 2777.70S 3451.55E 6605.14 3735.05 3676.85 73 24 S 50.79 E 2.55 2834.43S 3522.76E 6700.71 3760.40 3702.20 75 49 S 50.23 E 2.58 2893.01S 3593.85E 6795.74 3783.04 3724.84 76 37 S 48.95 E 1.56 2952.84S 3664.12E 6891.66 3806.03 3747.83 75 38 S 48.09 E 1.34 3014.52S 3733.89E 4430.31 4521.35 4613.47 4705.74 4798.78 6984.76 3830.04 3771.84 74 28 S 48.51 E 1.33 3074.35S 3801.04E 7082.57 3856.99 3798.79 73 32 S 46.79 E 1.94 3137.68S 3870.52E 7178.40 3883.91 3825.71 73 49 S 47.65 E .91 3200.14S 3938.02E 7274.87 3909.96 3851.76 74 50 S 48.60 E 1.41 3262.14S 4007.18E 7370.16 3934.39 3876.19 75 26 S 47.96 E .90 3323.43S 4075.93E 4888.65 4982.52 5074.32 5167.10 5259.12 7465.29 3958.25 3900.05 75 30 S 49.86 E 1.93 3383.95S 4145.32E 7559.48 3981.73 3923.53 75 37 S 50.12 E .30 3442.59S 4215.19E 7655.04 4004.64 3946.44 76 37 S 50.31 E 1.05 3501.96S 4286.48E 7750.01 4026.52 3968.32 76 44 S 50.62 E .34 3560.78S 4357.75E 7846.14 4048.05 3989.85 77 22 S 51.10 E .82 3619.92S 4430.42E 5351.15 5442.36 5535.12 5627.54 5721.22 7941.00 4068.63 4010.43 77 33 S 50.42 E .73 3678.50S 4502.13E 8035.65 4090.53 4032.33 75 40 S 50.72 E 2.01 3736.97S 4573.25E 8130.24 4115.28 4057.08 73 58 S 50.37 E 1.84 3794.98S 4643.73E 8225.21 4142.73 4084.53 72 25 S 50.50 E 1.63 3852.88S 4713.81E 8320.59 4171.40 4113.20 72 34 S 50.67 E .23 3910.64S 4784.09E 5813.82 5905.89 5997.17 6088.08 6179.05 8414.58 4200.46 4142.25 71 24 S 50.86 E 1.26 3967.18S 4853.32E 8509.13 4230.20 4172.00 71 55 S 51.50 E .84 4023.44S 4923.25E 8604.55 4259.16 4200.96 72 44 S 51.28 E .89 4080.17S 4994.29E 8700.01 4288.08 4229.88 71 59 S 50.44 E 1.15 4137.59S 5064.85E 8794.75 4317.02 4258.82 72 25 S 52.03 E 1.66 4194.07S 5135.18E 6268.43 6358.17 6449.08 6540.05 6630.25 8891.99 4346.21 4288.01 72 38 S 51.36 E .69 4251.56S 5207.96E 8905.84 4350.34 4292.14 72 37 S 51.13 E 1.58 4259.83S 5218.27E 8970.00 4369.50 4311.30 72 37 S 51.13 E .00 4298.26S 5265.95E 6722.99 6736.21 6797.44 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 6797.45 FEET AT SOUTH 50 DEG. 46 MIN. EAST AT MD = 8970 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 129.27 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 8,970.00' MD SPERR1 GIN DRILLING SERVICES ANCHOP~AGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPG-09 500292277900 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/17/97 DATE OF SURVEY: 070297 JOB NUMBER: AK-MM-70189 KELLY BUSHING ELEV. = 58.20 OPERATOR: BP EXPLOP~ATION FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -58 1000.00 996.91 938 2000.00 1923.66 1865 3000.00 2630.19 2571 4000.00 2945.27 2887 .20 .71 .46 .99 .07 .00 N .00 E 36.96 S 37.57 E 262.04 S 318.60 E 711.18 S 835.42 E 1294.80 S 1580.31 E .00 3.09 3.09 76.34 73.26 369.81 293.47 1054.73 684.92 5000.00 3223.64 3165 6000.00 3536.14 3477 7000.00 3834.12 3775 8000.00 4081.71 4023 8970.00 4369.50 4311 · 44 1913.15 S 2314.55 E .94 2503.28 S 3057.46 E .92 3084.08 S 3812.04 E .51 3715.10 S 4546.51 E .30 4298.26 S 5265.95 E 1776.36 721.63 2463.86 687.50 3165.88 702.02 3918.29 752.41 4600.50 682.21 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERR. 3UN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 BP EXPLORATION MILNE POINT / MPG-09 500292277900 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/17/97 DATE OF SURVEY: 070297 JOB NUMBER: AK-MM-70189 KELLY BUSHING ELEV. = 58.20 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -58 58.20 58.20 158.20 158.20 100 258.20 258.20 200 358.20 358.20 300 .20 .00 .00 .00 .00 .00 N .00 E .00 .00 N .00 E .00 .00 .02 N .00 W .00 .00 .60 N .09 W .00 .00 .64 N .24 E .00 .00 458.21 458.20 400 558.27 558.20 500 658.46 658.20 600 758.90 758.20 700 859.65 858.20 800 .00 .00 .00 .00 .00 .02 N 1.15 1.98 S 3.75 5.93 S 8.33 12.65 S 14.61 21.77 S 22.74 E .01 .01 E .07 .06 E .26 .19 E .70 .44 E 1.45 .75 960.73 958.20 1062.40 1058.20 1164.91 1158.20 1268.37 1258.20 1373.17 1358.20 90O 1000 1100 1200 1300 .00 .00 .00 .00 .00 32.45 S 32.81 44.62 S 46.46 58.79 S 63.98 74.68 S 85.17 92.83 S 110.66 E 2.53 1.08 E 4.20 1.67 E 6.71 2.51 E 10.17 3.46 E 14.97 4.79 1480.28 1458.20 1589.28 1558.20 169-8.88 1658.20 1809.99 1758.20 1923.83 1858.20 1400 1500 1600 1700 1800 .00 .00 .00 .00 .00 115.77 S 141.37 142.16 S 175.78 169.27 S 211.50 199.91 S 248.99 235.80 S 289.82 E 22.08 7.11 E 31.08 9.00 E 40.68 9.60 E 51.79 11.12 E 65.63 13.84 2040.91 1958.20 2158.10 2058.20 2277.71 2158.20 2403.01 2258.20 2537.04 2358.20 1900 2000 2100 2200 2300 .00 .00 .00 .00 .00 277.40 S 334.24 320.79 S 377.22 367.81 S 422.91 419.76 S 477.61 479.04 S 544.18 E 82.71 17.08 E 99.90 17.19 E 119.51 19.61 E 144.81 25.30 E 178.84 34.04 2686.74 2458.20 2858.93 2558.20 3061.45 2658.20 3325.98 2758.20 3660.61 2858.20 2400 2500 2600 2700 2800 .00 .00 .00 .00 .00 551.95 S 628.22 638.82 S 738.11 744.42 S 878.84 889.27 S 1075.95 1084.99 S 1328.19 E 228.54 49.69 E 300.73 72.19 E 403.25 102.52 E 567.78 164.53 E 802.41 234.63 4047.61 2958.20 4430.34 3058.20 4779.09 3158.20 5117.15 3258.20 5437.12 3358.20 2900.00 3000.00 3100.00 3200.00 3300.00 1323.91 S 1615.69 1556.74 S 1902.45 1770.04 S 2159.53 1988.94 S 2396.91 2185.34 S 2628.82 E 1089.41 287.00 E 1372.14 282.73 E 1620.89 248.75 E 1858.95 238.06 E 2078.92 219.97 SPERR_ 3UN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLOR~ATION MILNE POINT / MPG-09 500292277900 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/17/97 DATE OF SURVEY: 070297 JOB NUMBER: AK-MM-70189 KELLY BUSHING ELEV. = 58.20 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 5764.83 3458.20 3400.00 2376.68 S 2875.33 E 6066.76 3558.20 3500.00 2538.63 S 3109.61 E 6360.40 3658.20 3600.00 2693.18 S 3338.36 E 6691.72 3758.20 3700.00 2887.44 S 3587.16 E 7086.84 3858.20 3800.00 3140.49 S 3873.51 E 2306.63 227.71 2508.56 201.92 2702.20 193.64 2933.52 231.32 3228.64 295.12 7465.08 3958.20 3900.00 3383.82 S 4145.17 E 35 7892.67 4058.20 4000.00 3648.47 S 4465.73 E 38 8276.50 4158.20 4100.00 3883.98 S 4751.55 E 41 8601.31 4258.20 4200.00 4078.24 S 4991.88 E 43 8932.16 4358.20 4300.00 4275.60 S 5237.83 E 45 06.88 278.23 34.47 327.59 18.30 283.83 43.11 224.81 73.96 230.85 8960.00 4366.51 4308.31 4292.27 S 5258.52 E 4593.49 19.53 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS 11/6/98 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12029 Company Field: Alaska Oil & Gas Cons Comm Attn: Lorl Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) Well Job # Log Description Date BL Sepia LIS Tape MPG-09 ~ ~t c~O,~__.... 98562 USIT (PDC GR) 980220 1 i 1 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: Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK Received by: ~l~LllllleI:~[:~l GeoQuest 500 W. International Airport Road Anchorage, AK 99518~1199 ATTN: Sherrie NO. 11950 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 3/23/98 Field: Milne Point (Cased Hole) Colored Well Job # Log Description Date Print RF Sepia LIS Tape MPB-25 981 47 USIT 9801 01 1 1 MPC-36 981 47 'USIT 980205 I 1 MPC-39 98147 USlT 980118 I 1 MPG-09 981 47 USlT 980220 1 1 MPJ-17 98147 USIT 971119 1 1 MPL-33 981 47 USlT 971 008 I 1 MPL-42 981 47 USlT 980224 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: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received ~ GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11894 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) 3/6/98 Well Job # Log Description Date BL RF Sepia LIS Tape MPG-09 COMPLETION RECORD 9 8 0 2 2 0 I 1 M P L-42 GPJCCL CORRELATION 9 8 0 2 2 4 I 1 MPL-42 PERFORATING RECORD 9 8 0 2 2 4 I 1 -- ,,, ..... 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: Schlumberger GeoQuest 500 W, International Airport Road Anchorage, Alaska 99618-1199 Received b~~t.~ ~ GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrle NO. 11525 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) 11/5/97 Well Job # Log Description Date BL RF Sepia LIS Tape MPC-6 {,,~1 C_. WATER FLOW LOG/TDTP-GR/CCL 970615 I 1 MPU C-8 ~, k~, ~ TDT WATER FLOW LOG 970927 1 1 MPU C-10 [ ~Lt ~ WATER FLOW LOG W/RST INVERTED 970911 I 1 MPE-10 , TUBING PUNCHER 970928 I 1 MPU E-22 ~ TUBING LEAK DETECTION LOG 970702 I 1 MPU E-22 ~ TUBING PATCH RECORD 97071 9 I 1 MPU F-09 ~ PERFORATING RECORD 97071 2 I 1 MPU F-09, STATIC TEMP/PRESS SURVEY 97071 2 I 1 MPU F-09' PERFORATING RECORD 97071 9 I 1 F-41, CHEMICAL CU'I-rER 970820 I 1 F-41 · CHEMICAL CUTTER 970829 I 1 MPU F-73 ' PERFORATION RECORD 9 70815 I 1 MPG-09 ~ RFT 970702 I 1 MPH-11 ~ RFT 970903 I 1 MPU J-2 [,J, [(.~ WATER FLOW LOG/TDT-GR 970726 I 1 MPU J-09 ~[(.~- JETCUl-rER RECORD 970807 I 1 M P K-43A · GAMMA RAY CORRELATION LOG 971 024 I 1 MPU L-9 ~ (.~ WATER FLOW LOG/TDTP-GR/CCL 97061 4 I 1 MPU L-32 ~ GAMMA RAY CCL TCP CORRELATION LOG 97051 5 I 1 MPL-33 ~ :TUBING CONVEYED PERF TIE-IN GR-CCL 97101 0 I 1 MPL-33 ' TIE-IN GR-CCL 97101 4 I 1 el'"/. ~1' i1'1 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: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 CI I::! I I--I-- I I~ G S I=: !::! %~ I C I= S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 q'~ RE: MWD Formation Evaluation Logs - MPG-09, AK-MM-70189 September 17, 1997 The technical data listed below is being submitted herewith. Please acknowledge receipt by remming a signed copy of this transmittal letter to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2" x 5" MD Resistivity and Gamma Ray Logs: 50-029-22779-00 1 Blueline 1 Rev. Folded Sepia 2"x 5" TVD Resistivity and Gamma Ray Logs: 50-029-22779-00 1 Blueline 1 Rev. Folded Sepia 2"x 5"MD Neutron and Density Logs: 50-029-22779-00 1 Blueline 1 Rev. Folded Sepia 2"x 5" TVD Neutron and Density Logs: 50-029-22779-00 1 Blueline 1 Rev. Folded Sepia SE? ] 7 1997 Aia~ka Oil & Gas ,.'2~s, 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company WELL LOG TRANSM1TFAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.- Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - MPG-09 AK-MM-70189 September 10, 1997 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, ~G, Anchorage, AK 99518 1 LDWG formatted LIS Tape with verifimfion listing. APl#: 50-029-22779-00 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, inc. Company TONY KNOWLE$, GOVERNOR ALASK& OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 June 19, 1997 Tim Schoficld Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re; Milne Point MPG-09i BP Exploration (Alaska), Inc. Permit No. 97-I 17 Sur. Loc: 1605'NSL.3342'WEL.SEC 27,TI3N.RIOE.UM Btmhoic Loc: 2687'NSL.3498'WEL. SEC 35.T13N.RIOE.UM Dear Mr. Schoficld: Enclosed is the approved application for permit to drill thc above rcfcrcnccd ~vcll. The permit to drill docs not cxcmpt you from obtaining additional pcnnits rcquircd by law from other govcrnmcntal agcncics, and does not authorize conducting drilling opcrations until all other required permitting determinations arc made. The blowout prcvcntion cquipmcnt (BOPE) must bc tcstcd in accordancc with 20 AAC 25.035: and the mechanical integrity (MI) of thc injection wells must bc dcmonstratcd under 20 AAC 25.412 and 20 25.030(g)(3). Sufficicnt noticc (approximatcly 24 hours) of thc MI tcst bcforc operation, and of thc BOPE tcst pcrformcd before drilling bclov¢ thc surfacc casing shoc. must bc given so that a rcprcscntativc of thc Commission may witncss thc tcsts. Notice may bc givcn by contacting the Commission petroleum ficld inspector on thc North Slope pager at 659-3607. David Chairman BY ORDER OF )MMISSION dlf/Enclosurc CC: Department of Fish & Game. Habitat Section w/o cncl. Dcpartmcnt of Environmcntal Conscrvation ',v/o cncl. ~- STATE OF ALASKA ' ' ALASKA O,._ AND GAS CONSERVATION COMN,,dSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entr7 [] Deepenl [] 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. Plan RTE = 58.7' Milne Point Unit / Schrader Bluff 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025518 4. Location of well at surface !7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1605' NSL, 3342' WEL, SEC. 27, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 3335' NSL, 4289' WEL, SEC. 35, T13N, R10E, UM MPG-09i At total depth ;9. Approximate spud date Amount $200,000.00 2687' NSL, 3498' WEL, SEC. 35, T13N, R10E, UM 06/23/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025906, 1782'I No Close Approach 2560 8830' MD / 4341' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 400' Maximum Hole Angle 73.63° Maximum surface 1400 psig, At total depth (TVD) 4000' / 1800 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 8-1/2" 7" 26# L-80 Btc-Mod 8799' 31' 31' 8830' 4341' 748 sx PF 'E', 309 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 I oerd cetCli 'oante R E C E IV E D OP, IGINAL Liner Alaska Oil & Gas Cons. Commingle', Perforation depth: measured Anchorage true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Mark Brofka, 564-4809 Prepared By Name/Number: Kathy Campoarnor, 564-5122 the foregging is true ~nd corrt~qt to the best of my knowledge 21. I hereby certify that .. Signed ~ Tim Schofield Title Senior Drilling Engineer Date ~' '7 Commission Use Only Permit Number I APl Number J Appr0~l%a~,,~ I See cover letter .~ - ,z'Z],~ 50-~.;~. ~--~ ~---- ~7 7 c~ r~d t~ for other requirements Conditions of Approval: Samples Required []Yes [] No Mud Log Requi []Yes [] No Hydrogen Sulfide Measures []Yes [] No Directional Survey Required []Yes [] No Required Working Pressure for BOPE J~M; I-]3M; 1--15M; EI10M; I-'115M Other: Origina! Signe0 By by order of (~ /o~ Approved By David W. Johnston Commissioner the commission Date /~ "~ . . . Form 10-401 Rev. 12-01-85 'iplicate Shared Services Drilling Contact: I Well Name: Mark J. Brofka I MPG-09i Well Plan Summary IType of Well (producer or injector): SCHRADER BLUFF INJECTOR 564-4809 Surface Location: 1605 FSL, 3342 FEL, S27 T13N R10E UM Target Location: 3335 FSL, 4289 FEL, S35 T13N R10E UM Bottom Hole Location: 2687 FSL, 3498 FEL, S35 T13N R10E UM I AFE Number: 1337080 I Rig: I Nabors22E Estimated Start Date: 123 June 97 I I Operating days to complete: I 10 MD: I8830' I ITVD: I4341' I IKBE: 158'7 I Well Design: Formation Markers: 7" Schrader Bluff Injector Formation Tops MD' TVDSS TVD (bkb) KOP 400 400 459 Base of Permafrost 1798 1700 1759 Top of Ugnu 5904 3458 3517 Top M Sand 6962 3756 3815 Top NA (Target) 7764 3982 4041 Top of Schrader Bluff Sands (EMW 8.6 ppg) NB 7860 4009 4068 NCND 7970 4040 4099 NE 8034 4058 4117 NF 8200 4105 4164 OA 8334 4137 4196 OA4 8428 4169 4228 OB 8538 4200 4259 Top of Seabee 8630 4226 4285 Base of Schrader Bluff Sands (EMW 8.3 ppg) TD 8830 4283 4342 TD at 200' MD past base of Schrader Casing/ruE lng Program: Hole §ize Csg~ Wt/Ft Grade Conn. Length Top Bottom Tbg O.D. MD/TVD MDrrVD (bkb) 24" 20" 91.1# H-40 Weld 80' 32'/32' 112' / 112' 8-1/2" 7" 26# L80 BTC-Mod 8799' 31'/31' 8830/4341' Internal yield pressure of the 7" 26# casing is 7240 psi. With a full column of gas (0.10 psi/fi) to the reservoir at +4000' TVDSS, the maximum anticipated surface pressure assuming a reservoir pressure of 1800 psi (8.65 ppg EMW), is 1400 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: Open Hole Logs: Cased Hole Logs: Mudloggers are NOT rec MWD from surface to TD LWD (GR/Resistivity/Neutron Density) from top of Ugnu to TD with a controlled drilling speed of no more than 180 ft/hr from 5904 - 8830' MD. Drop ESS survey tool at TD to correlate with MWD surveys. MAD pass with LWD while tripping out through the Ugnu from 7764 - 5904' MD a.t speed of no more than 180 ft/hr. RFT Icg, drillpipe-conveyed (specific RFT program will be submitted to the rig prior to logging operations) NONE GR/CCL and CBL with completion rig) uired for this well. Mud Program: Spud Mud ISpecial design considerations ISee "Drilling Hazards and Risks" section about dealing with the possibility of hydrates SPUD TO TOP OF SCHRADER BLUFF: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.5 80 15 8 10 9 10-15 (initial) to to to to to to to 9.0 100 35 15 30 10 8-10 (final) TOP OF SCHRADER BLUFF TO TD: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 50 10 3 7 9.0 4 to to to to to to to 9.3 80 20 10 20 9.5 6 (as required) Well Control: Well control equipment consists of: Drilling Rig (Nabors 22E) 21-1/4", 2000 psi W.P. Diverter with 10" Diverter Line. ^ Completion/Workover Rig with 5000 psi W.P. pipe rams, blind/shear rams, and annular preventer will be used for the completion and is capable of handling maximum potential surface pressures. Diverter, BOPE, and drilling fluid system schematics on file with AOGCC. Directional: I KOP: 1400', Phased Build and Hold t Maximum Hole Angle: t73.63° Close Approach Well: NONE RECEIVED Alaska 0il & (~a$ Cons. Anchorage Waste Management: Cuttings Handling: All cuttings will be hauled to the CC-2A facility. In the event that the bridges are not usable due to breakup, all cuttings will be placed in the Milne Point A-Pad reserve pit. Fluids Handling: All drilling and completion fluids will be hauled to CC-2A for injection. If the bridges over the rivers are not usable because of breakup, class 2 waste fluids will be hauled to the Kuparuk injection well and class 1 fluids will be transferred to storage tanks for future disposal after breakup. Annular Injection: No wells on G-Pad have been permitted for annular injection. MP G-09i Proposed Summary of Operations 1. Drill and Set 20" Conductor. Weld a starting head and top job nipple on conductor. 2. Prepare location for rig move. 3. MIRU Nabors 22E drilling rig. 4. N/U and function test 21-1/4" Hydril MSP 2M diverter system. Build Spud Mud. 5. Drill a 8-1/2" surface hole as per directional plan to 8830' MD / 4341' 'rvD. Run Directional MWD from surface to TD and run LWD GR/Resistivity/Neutron Density from the top of the Ugnu to TD, or 5904' to 8830' MD. 6. Keep the same BHA when tripping for the second bit. If tool problems are experienced, or battery life or operating hours are a concern, then replace the MWD or motor as deemed necessary. 7. Drill at a controlled rate of no more than 180 fi/hr through the Ugnu and Schrader Bluff sands to ensure good LWD readings. 8. At TD, make a wiper trip to the last bit trip depth and condition the hole, making sure to record any tight spots. 9. Before POOH, drop ESS survey tool at TD. (If two MWD tools were run while drilling, then the ESS will not be required.) 10. MAD pass from while tripping out through the Ugnu from 7764' to 5904' MD at a speed of no more than 180 ft/hr. POOH and LD BHA. 11. Make a drillpipe-conveyed RFT logging run according to the detailed logging prognosis. 12. Run and cement 7", 26#, L-80, BTC-Mod casing. Cement job will be performed in two (2) stages, as per the cement program, with an ES cementer set at least 200' MD below the permafrost. 13. N/D Diverter. N/U FMC Gen 6 Wellhead and Tree. RDMO Nabors 22E drilling rig to' drill next well. (End of Nabors 22E operations) 14. MIRU completion rig. 15. N/U & Test BOPE. 16. Drill out ES cementer and clean out the well. 17. Run GR/CCL and CBL. 18. Perform completion job. MPG-9i will be an injector. 19. Complete well with 3-1/2" L-80, EUE tubing. 20. Set BPV. N/D BOP stack and N/U X-mas tree. 21. RDMO with completion rig. 22. Install Surface Lines and Wellhouse and tum well over to production. DRILLING HAZARDS AND RISKS: The well is planned as a Schrader Bluff single casing string injector. The well will be drilled, cased, and cemented with Nabors 22E which will then suspend the well and move on. The well will be completed at a later date by a completion rig.' See the latest Milne Point G-Pad Data Sheet prepared by Pete Van Dusen for information on G pad. The MPU PE group MAY be perforating, hydraulic fracturing and cleaning out wells shortly after the rig drills and completes them. This will make the near rig area congested and as a result potentially hazardous. Ensure personnel use caution moving around adjacent production activities. .1. Hydrates: Hydrates have occurred on nearby E and H and there is a possibility that hydrates may be encountered in the drilling of MPG-09i. In the eight wells previously drilled on G-pad, only G-08 encountered gas, but only a minor amount and probably due to a small gas pocket rather than hydrates. If hydrates are encountered, mud weights will be increased to 10.2 ppg, or heavier if required, and lecithin (DrillTreat) will be added to the mud system. The cement program includes an ES cementer set below the permafrost. Should hydrates be encountered while drilling, the cement program will be modified to include a Permafrost C tail on the second stage to ensure a high quality cement seal above the hydrate zones. Also, weighted spacers will be used during the cement displacement to maintain the hydrostatic head on the formation so as to minimize the movement of hydrates into the wellbore. 2. Close Approach: There are no close approach problems with MPG-09i. 3. Lost Circulation: Lost circulation has been experienced when drilling the Schrader sands and can be countered by having LCM on hand. To date, losses seen on past wells in the area have been minor. 4. Stuck Pipe Potential: No stuck pipe incidents have occurred on G Pad to date, but the rig crew should remain attentive and take precautions to prevent stuck pipe from occurring. If heavy gravels are encountered, operations should be immediately stopped while the mud funnel viscosity is increased to 150 cp and maintained through the gravel section. 5. Formation Pressure: The expected pore pressure for this well is 8.6 ppg EMW in the Schrader Bluff NA and NB sands, and 8.3 ppg EMW at TD just past the OB sands. 6. Directional Drillinc~ Concerns Also, due to the relatively shallow depth of the Schrader Bluff wells and the large stepouts, some directional drilling will have to be done in the permafrost. The rig crew should be particularly attentive to the wellbore trajectory to ensure that the target objectives are met. Note that care must be taken when drilling through the base of the permafrost as severe doglegs may develop. 8. Cement Because of the single casing string, the cement jobs will be cdtical to the success of the Schrader wells. Also, the relatively small 8-1/2" by 7' annulus will require extra attention to pump rates and pressures. Ensure that copies of all of the strip charts from the cement job are sent to the Operations Ddlling Engineer. 7. Other There have been only a handful of wells drilled on the North Slope with an 8-1/2" surface hole and it is important that bit and directional performance is closely monitored and reported so that lessons learned can be included in the next well program. None of the drilling hazards and risks identified above are expected to be magnified by the change in hole size. MPG-9i 7" SURFACE/INJECTION CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 7" CIRC. TEMP: ~ 80°F SPACER: 50 bbls fresh water spacer (1307' in 7" casing). STAGE1 LEAD: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST FLOCELE (0.25 #/sk) 12.0 ppg YIELD: 2.17 ft3/sk MIX WATER: 11.63 gal/sk 339 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM THE GREATER OF EITHER 100' TVD OR 500' MD ABOVE THE TOP OF THE UGNU "M" SANDS (6462' MD) TO THE ES CEMENTER STAGE TOOL (2000' MD > 200' MD BELOW BASE OF PERMAFROST) + 30% EXCESS. STAGE1 TAIL CEMENT TYPE: ADDITIVES: WEIGHT: APPROX #SACKS: FLUID LOSS: PREMIUM SILICATE (15 #/sk), CFR-3 (0.2%), HALAD-344 (0.75%) 13.1 ppg YIELD:2.05 ft3/sk MIX WATER: 11.0 gal/sk 199 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. 0-55 cc/30 mins @ 80°F FREE WATER: TAIL CEMENT FROM TD (8830' MD) TO THE GREATER OF EITHER 100' TVD OR 500' MD ABOVE THE TOP OF THE UGNU "M" SANDS (6462' MD) + 30% EXCESS + 80' OF 7" 26# CASING CAPACITY FOR SHOE TRACK. STAGE2: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST Retarder 12.0 ppg 409 SACKS YIELD:2.17 ft3/sk MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. PUMP UNTIL RETURNS ARE OBSERVED AT SURFACE BEFORE DROPPING CLOSING PLUG. +/-250% EXCESS IS EXPECTED FROM THE ES CEMENTER (2000' MD) TO SURFACE. WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE: ADDITIVES: Retarder WELLHEAD STABILITY CEMENT WILL BE PUMPED ONLY THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.0 ppg YIELD:2.17 ft3/sk MIX WATER: 11.63 gal/sk APPROX NO SACKS: 150 RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL CENTRALIZER PLACEMENT: 1. Centralize the casing from TD to 100' MD above Ugnu "M" Sands with 7-1/8" x 8-1/4" Rigid Straight Blade Centralizers - two (2) per joint on the bottom fifty (50) joints of 7" casing (100 Rigid Straight Blade Centralizers). 2. Run two (2) Rigid Straight Blade Centralizers on either side of the ES cementer tool. OTHER CONSIDERATIONS: Perform any necessary laboratory tests on samples of the water to be used in the cement job to ensure that it is adequate. Also perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 6 bpm - pump rates are crucial to keep ECD's Iow. Mix slurry on the fly ~- batch mixing is not necessary. CEMENT VOLUME: 1st Stage: 1. The lead slurry volume is calculated to cover from the ES cementer tool (200' MD below base of permafrost) to the top of the tail slurry, at the greater of either 500' MD or 100' TVD above the top of the Ugnu "M" Sands, with 30% excess. 2. The tail slurry volume is calculated to cover the greater of either 500' MD or 100' TVD above the top of the Ugnu "M" Sands to TD with 30% excess. 3. 80' of 7", 26# capacity for the float joints (baffle collar, float collar, and float shoe). 2nd Stage: 1. The slurry volume is calculated to cover from the ES cementer to sudace with an excess of 250% expected to be required. Ensure that additional sacks of cement are onsite and available for use The slurry' will be pumped until cement returns are seen at surface. Note that in the event that hydrates are encountered, the Operations Drilling Engineer should be notified and a modified cement program will be submitted to ensure isolation of the hydrate zone. DISPLACEMENT OF CEMENT: Because Nabors 22E will be moving off of the well after the cement job, displacement fluid is an important consideration as the fluid will be left in the hole for some time. The proposed displacement procedure is as follows: 1. Pump away first stage as per the detailed cement program and displace with seawater a volume equal to the capacity of the 7" casing from TD up to surface. 2. After bumping the plug, quickly check to ensure that the floats are holding and then shear the ES cementer to the open position. 3. Circulate seawater through the ES cementer for two hours to clean and condition contaminated cement. 4. Pump the second stage as per the detailed cement program, circulating the water through the ES cementer and across the permafrost to surface. When cement returns are seen at surface, drop the second stage plug and displace with diesel. The completion rig will recover the diesel freeze protection fluid for reuse on another well. Anadrill Schlumberger Alaska District 1111 Hast BOth Avenue Anchora~e, AK 99518 (907) 349-4511 Fa~ 344-2160 D£RECTIONAL ~I.~ PI,AN for SHARHD SHRV~CHS D~ILL~NG WeLl ......... : MPG-0g(P02) Pield ........ : Milne Point, G-Pad Co~utatios..: Minimu~ Curvature Units ........ : PHHT Surface Lat.-: 70.44899728 N Surfaee Long.: 149.53282601 ~ Lc~al Oescrtption Surface ...... : 1605 FSL 3342 FHL S27 T13N TAROT ....... : 3335 F~L 4289 FEL 835 T13N R10H BH~ .......... : 2687 FSL 3498 FEb S35 T1]N R10H LOCATIONS - ALASKA Zone: 4 X-Coord Y-Coord 557264.59 6014041.66 561631.00 6010527.00 562427,62 6009885.77 S~ATION M~.J~ INCLN DZR. HCTION IDENTIFICATION DEPTH ANGLE AZfMUTH K~ 0.00 0.0~ 0.00 KO~/B~ILD 1/100 400.00 0.00 0.00 B00.00 1.00 129.27 BO=LD 1.~/100 600.00 2.00 129.27 700.00 3.50 L29.27 PROPOSED ,~ mmmmmmml VERTICAL-DHPTHS SECTION T~D SUB-SEA 0.00 -58.70 400.00 ~41.30 499.99 441.29 599.9B ~41.~6 699.84 641.14 Prepared ..... : 05 Jun 1997 Vert sect az.= 129.27 KB elevation.: 58,q0 ft ~agnetic Dcln: +28.045 Scale Factor.: 0.9999037~ APPROVED FOR PERMITTING ONLY PLAN CDORDINATES-FROM ALASKA Zone DHPART ~L~ 0.00 0.00 H 0.00 E 557264.59 6014041.66 0.00 0.00 N 0.00 E ~57264.59 601404~.66 0.89 0.55 ~ 0.68 E 5~7265.27 6014041.1L 3.49 2.21 S 2.70 H 557267.3~ 6014039.47 8,29 5,25 S 6.42 ~ 557271.05 6014036,46 BUI~ 2/100 BOQ.00 5,00 129,27 9O0.0O 7,00 229.27 ~000.00 9.00 129.27 llO0.OO LL.00 129.27 1200.00 L3.0O 129.27 799,56 740.86 15.70 899.01 840.31 26.15 998.03 939.33 40.07 1096.51 1037.BL 57.43 1194.32 1135.62 ~8.22 9.94 16.55 25.36 36.35 49.51 12,15 H 557276.82 601403L.82 20.24 H 557284,96 6014025.26 31.02 E 557295.80 6014016.54 44.46 E 557309.32 6014005,65 60.56 E 557325.52 6013992.62 TOdL DL/ PACE ~00 HS 0.00 129R 0.00 129R 1,00 129R 1.on 129R 1.50 L29R 1.50 HS 2.00 HS 2.00 xs 2;00 HS 2.00 Z C~ 1300.00 35.00 129.27 1291.34 ~232.64 102.41 64-B3 S 1400.00 ~7,00 129.27 1187.46 1328.76 129.97 82.27 S 79.28 E 557344.36 6013977.45 HS 2.00 L00.62 H 557565.83 6013960.17 HS 2.00 (Anadrill (e) 97 MPG09P02 3.aC 11:37 AM P) ~C MPG-09 (P02] 05 Jun 1997 Pa~e 2 PROPOSED ~ELL PROF3LH STATION MEASURED DEPTH INCI~ D£RECTION V]{~T~CAL-DH~THS $~CTION TV]) SUB-S~A DHPART 1482.56 1423.86 160.88 101.83 1576.53 1517.83 [95.08 £23.48 1669.24 1610.5% 232.5~ [47.19 1731,52 1672.82 259.84 ~64.48 1758.70 1700.00 272.15 172.27 BND 2/100 BU3~D BASH PHI~AFROST ~ 3/~O0 Bullm TOP U~NU TOP M SAND8 1500.00 19.00 1600.00 21.00 1700.00 23.00 [768.00 24.36 1797,84 24.36 3828.00 24.36 1900.00 26.52 2000,00 29.52 2100.00 32.52 2200.00 35.52 2300.00 38.52 2400.00 41.52 2500.00 44.52 2600.00 47.52 2700.00 50.52 2800.00 53.52 2900.00 56.52 3000.00 59.52 3~00.00 62.52 3200.00 65.52 3300.00 68.52 3400.00 71.52 3470.45 73,63 5904.3[ 73.63 6961.B7 73.63 ~ 7763.91 73.63 TARGET 7763.9] 73.63 TOP SCHRADER 7763.9~ 73.63 129,27 [29-27 L29.27 129.27 129.27 129.2~ 129.27 129.27 129.27 129.27 L786.17 1727.47 L851.19 L792,49 1939.46 1880.76 2025.15 1966.45 2108.02 2049.32 COORDINATES-FROM ASASKA Zone 4 TOOL D~/ N~LLHHAD X Y ~ACH 12q.54 E 657389,90 6013940~80 HS 2.00 151.02 E 557416.54 60~3919.35 {-IS 2.00 180.02 H 557~45.7£ 6013895.87 HS 2.00 201.16 B 557466,99 6013878.74 HS 2.00 210.69H 557476,5~ 60138~.03 HS 0.00 284,59 '180,L5 S 220.32 B 557486.26 60/3863.23 HS 0.00 3L5.52 199,92 S 244,26 E 5575L0,35 60/3843,84 I-IS 3.00 362.49 229.46 S 280-62 E 559546.94 6013814-39 HS 3,00 414.02 262.07 $ 320.51 H 557587.08 6013782.08 HS 3.00 469.96 ~97.49 S 363.82 H 557630.65 6013747.01 HS ~.00 129.29 2187.85 2129.15 530.16 335.59 129.2~ 2264.45 2205.7~ 594.46 376.30 129.2~ 2337.~ 22?8.83 662.68 419.48 ~29.27 2406.96 2348.26 734,63 465,02 ~29.2~ 2472.54 2413.84 8L0.~1 512.80 129,27 2534.07 2475.37 888.93 562.69 129.27 2591.39 2532.69 970.85 6/4.55 129,27 2644.35 2505.67' 3055,67 668.24 129.27 2692.79 2634-O9 1143.[4 723.6[ 129.27 2736.59 2677-89 1233.02 780.$0 (Anadrill (c) 97 MPG09P02 3.0C 11:37 AM P) 129.27 2775.6~ 27[6.93 1325.07 838.77 S [29.27 2809.79 2751.09 14[9.05 898.26 S ~29.2~ 2830,89 2772.£9 1486.26 940.80 S 129,27 3716.~0 3458.00 382~.49 24L9.01 S ~29.27 38£4.70 3756.00 4836.20 3061.32 S 129.27 4040.70 3982.00 5605.75 3548,45 129.27 4040.70 3982.00 5605.35 3548.45 129.27 4040.70 3982.00 5605.75 3548.45 430.43 H 557677.54 60L3709.26 HS 3.00 460.20 H 557727.63 6013668.95 IlS 3.00 513.0£ ~ 557780.76 60L3626.£8 }IS 3.00 568.7[ i 557836.81 603358[,07 Hi 3,00 627.L5 E 557895.60 6013533.74 HS 3.00 688.16 B 557956.99 6013484.33 KS 3.00 751.59 B 558020.80 6013432.96 HS 3.00 817.25 H 550086.87 60[3379.78 HS 3.00 884.96 H 558155.00 6013324.94 HS 3.00 954.54 H 578225.01 6033268.59 HS 3.00 1025.81 E 558296,71 6013210.89 HS 3.00 1098.55 E 558369,91 6013151.96 HS 3.00 1150.$9 E 558~22.26 6013L09.81 HS 3.00 2958.41 H 560241.22 6011645.68 HS 0.00 3743.9~ H 561031.59 60LL009.48 I-IS 0.00 4339,69 B S61631.00 60L052$.00 HS 0.00 4339.69 H 561631.00 6010527.00 HS 0.00 4339.69 H 561631.00 6010527.00 HS 0.00 Z ~TAT XOH I'DHNT£F~CAT l O~ OA4 RASE SCHRADHR 7'" CASING POrXT~ TD MHASURBD INCLN DHL:~H 7969.75 73.63 8033.63 73.63 0~00~42 8313.99 73.63 8427.B5 73.63 8537.57 73.63 8629.84 73.63 8829.fl4 73.63 8829.84 73.63 PROPOSBD WHLL PROFXL~ DIRItCTIO~ 1/I~RTICAL-DEPTHS AZ[~4DTH TVD ~IIB-SHA 129.27 4067.70 4009.00 129.29 ~098.70 4040.00 ~29_27 4116.70 4058.00 £29.27 4L6~.70 4105.00 L29.27 4L95.70 4137.00 SHCT£ON D~ART 5697.68 ~803.24 ~864.5~ 6024.57 6L33-53 L29.27 4227.70 i169.00 '62~2.~9 L29.27 4258.70 4200.00 6~48.0~ 329.27 4284.~0 ~226.00 6136.58 ~29.27 4341.06 4282.36 6628,48 ~29.27 4341.06 4~82.36 6628.48 05 Jun 1997 Page 3 C00tlDINATBS-~ROM AI.J~SKA Zone 4 TOOb DL/ WELLIfll~D X Y FACH 3606,64 $ 44£0.07 H 561902.6£ 6010469.36 }IS 0.00 3693.46 S 4492-58 R 561784-83 6010403.18 HS 0.00 3712.26 ~ 4540.03 H 561839.57 60L0~64.75 HS 0.00 3813.56 $ 4663,93 ~ 561957.23 60~0264.41 ~S 0.00 3882.~3 S 4748.28 E 662042.10 601~196-09 HS 0-O0 3953.51 S 4832.63 B 562126.97 6010127.78 RS 0.00 40~8.32 S 49£4.35 H $~2209.~9 6010061,~9 H$ 0.00 4074.37 $ 4982.89 H 562278.~5 60L0006.09 HS 0.00 419~.84 S 5[~1.44 H 56242~.62 6009885.7? 0,00 4195.8~ $ 5151.44 H 562427.62 6009885.97 0,O0 I ANADRILL .:APPROVED I i FOR PERMITTING i ONLY ! .... PLAN AKA-DPt-! I : Z (Anadril3 (c) 9'/ MPG09P02 3.0C 11:37 AM P) a "' SHARED SERVIuES DRILLING ii i ~ i ! j ANADRtLL AKA-DPC ! i il i i Anadri ]] SchJumberger ii PG-09 (PO2) VEFtTICAL SECIION VIEN .....jlVo Scale,:. J inch: 800 feet ' :OR ~ERN~ITT NG : IOeo Sca]e.: ! inch = BO0 feet I i'"1 H Y ,' '- ~ . ,~ ~.,,m..~. _ - ~ ~ , . Marken Identification MO BKB SEClM INCL} A) KB 0 0 0 0.0~ El) K§P/BUi[LO ~/t00 401] 400 0 0.0[ C] BUILD t.5/~lO0 600 600 3 2.0i --- D) BUILD 2/100 800 800 El END ~/'lO0 BUILD t768 1732 260 24.31 F) BUILD 3/tO0 tB28 t786 285 24.31 3470 2631 ~486 73.E , G) END 3/~00 BUILD -F~ H) IARGE1 7764 404! 5606 73.B ....... -E 1A~¢B~f'-I'~ I) 7" CASING POINT 8830 4341 66~8 73.B _ J) lD 8830 4341 6628 73.6: .... ~- ., ...... :__-:__. =__-==__= ~-=~ .... ~-- _ 0 400 ~00 ~00 looo ~000 2400 ~800 3~.00 36~0 4000 4400 4800 5200 5500 600o 6400 Section Oe~ ture lanadr~ll] 0::197 ~OZ 3.OC 6800 z i ": SHARE. D sER.',9' . .... ' ICES DRIELiNG i i · iii I~rker fden~ifica~ion MD BKB SECIN [NcLI~ A] 'lARGEr 7764 4041 5606 73.63 BI 7" CASING POINT 6830 4341 6628 73.63 C) TD B~30 4341 6626 73.63 ANADRILL AKA-DPC APPROVED FOR PERMITTING ONLY ii ii iii iii TVD Scale.' ] ~ncb = ~0~ Oep Scale · :1 inch = t00 feet I)ra~n. .... : 05 Jun 1997 mi i 4nadrj ]1 Sch]umberger ii -- ii i MPG-09 (pO2) VERTICAL SECTION VIEW 5800 5850 5900 5950 6000 6050 6too 6t50 6~0o 6250 6300 535o 6400 6450 6500 6550 6600 6650 6700 Section Departuee i iii i i i i ii I,Anadr't)] (c197 1,4PGQ~Q2 3.0C ti:-17 ,M,,I P) z H SHAR SERV,TCE, S RILLZN6, i! iiiii i ii i~ Anadri ] ] SchJumberger i MPG-09 (PO2) PLAN VIE~ [ ANADRILL AKA-DPC ' CLOSURE ' 6626 feet at Azimuth ]29 27 i FO : PER,~ITI'ING : ISCALE ....... : ~mch: 800 feet - ~ . - -- ' Rarke~ ]denL t f ic~k ton ~ N/S E/N ........... ' ............ ] ~) K8 0 0 ~ 0 E B) XOP/~U]LO ~/IQ~ 400 0 ~ 0 E END 2/~00 BUILD t768 ~64S 201 E L F) BUILD 3/~OO ~B~ ,80 5 220E ~ G) END 3/tO0 BUILD 3470 94~5 ~5tE H) TARGEI 7764 3548 S 4340E I) 7' CASI,G POIN[ 6830 4196 S 513tE ~ J) 1D ~30 4t~ S 5t33 E - ., ~ . __ ._ ;EI I~ad~ us 100 f,~et ) ~ . . , 400 0 400 800 t200 1600 2000 2400 2800 3200 3600 4000 4400 4600 5~0 5600 6000 6400 61100 <- HEST' EAST -> IAr~dri]l (c)97 ~P60~1~)2 3.~C i1:38 AN PI z WELL PERMIT CHECKLISToo Y FIE ,D, POO . INIT CLASS PROGRAM: expr] dev [] redrl[] serv.~ wellbore seg[] ann disp para req[] UNIT, ADMINISTRATION 1 2 3 4 5 6 7 8 9 10 11. 12. 13. Permit fee attached ................... ~Y\ N Lease number appropriate ............... Ii1 N Unique well name and number· N Well located in a defined pool ............. N Well located proper distance from drlg unit boundary. . .~Y ~ N Well located proper distance from other wells ....../x ~ N Sufficient acreage available in drilling unit ...... N Operator only affected party. ~ N Operator has appropriate bond in force· N Permit can be issued without conservation order .... N Permit can be issued without administrative approval. N Can permit be approved before 15-day wait ....... N ENGINEERING 14 15 16 17 18 19 2O 21 22 23 24 25 26 27 28 29 Conductor string provided ............... ~_~ N Surface casing protects all known USDWs ........ .~ N CMT vol adequate to circulate on conductor & surf csg. N CMT vol adequate to tie-in long string to surf csg . . ~ N CMT will cover all known productive horizons ...... ~ N Casing designs adequate for C, T, B & permafrost .... ~ N Adequate tankage or reserve pit ............. ~ N · If a re-drill, has a 10-403 for abndnmnt been approved· · Adequate wellbore separation proposed .......... O N . If diverter required, is it adequate .......... ~ N ~-'~ Drilling fluid program schematic & equip list adequate .~ N . BOPEs adequate ..................... %~f N · N · Choke manifold complies w/API RP-53 (May 84) ...... · Work will occur without operation shutdown ....... ~N · Is presence of H2S gas probable ............ 30. 31. Permit can be issued w/o hydrogen sulfide measures .... Y N/ Data presented on potential overpressure zones ..... Y/~ Seismic analysis of shallow gas zones .......... Y// N /[ /, Seabed condition survey (if off-shore) ........ /Y N ' Contact name/phone for weekly progress reports . . . //. Y N [exploratory only] GEOLOGY 32. 33. 34. REMARKS GEO~Y: ENGINEERING: COMMISSION: ~EW~ 6/r? Comments/Instructions: HOW/dlf- A:\FORMS\cheklist rev 01/97 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. Sperry-Sun Drilling Services LIS Scan Utility Tue Sep 09 14:33:57 1997 Reel Header Service name ............. LISTPE Date ..................... 97/09/09 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 ..................... 97/09/09 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: Date__Ol - o 3, - OI MPG-09 500292277900 F ECE VP-D $ EP 1 0 1997' AJa~a Oi,! & Gas Cons. Commission Anchorage BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 09-SEP-97 MWD RUN 1 MWD RUN 2 MWD RUN 2 AK-MM-70189 AK-MM-70189 AK-MM-70189 G. TOBIAS G. TOBIAS G. TOBIAS J. NEW J. NEW J. NEW 27 13N 10E 1605 3342 .00 58.20 29.20 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 20.000 112.0 8.500 8970.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN I IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS. 3. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED NEUTRON POROSITY (CNP) AND STABILIZIED LITHO DENSITY (SLD). 4. A MEASURED AFTER DRILLING (MAD) PASS WAS PERFORMED FROM 6760'MD, 3775'TVD TO 7288'MD, 3914'TVD ON MWD RUN 2. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN MARK VANDERGON OF BP EXPLORATION (ALASKA), INC. AND ALI TURKER OF SPERRY-SUN DRILLING SERVICES ON 09/08/97. 6. ALL MWD RUNS REPRESENT MPG-09 WITH API# 50-029-22779-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8970'MD, 4370'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PAHSE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESIfTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME FOR RESISTIVITY SENSOR. SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY (SANDSTONE MATRIX-FIXED HOLE SIZE). SNNA = SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATES. SNFA = SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES. SBDC = SMOOTHED BULK DENSITY-COMPENSATED . SCOR = SMOOTHED STANDOFF CORRECTION. SFPE = SMOOTHED FAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ENVIRONMENTAL PARAMETERS USED IN PROCESSING NEUTRON LOG DATA: HOLE SIZE: 8.5" MUD FILTRATE SALINITY: 800 PPM. MUD WEIGHT: 9.1 PPG. FO~Z~ATION WATER SALINITY: 14545 PPM. FLUID DENSITY: 1.0 G/CC. LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/09 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. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE FCNT NCNT NPHI FET RPD RPM START DEPTH 5758.0 5758.0 5758.0 5782.5 5782.5 5782.5 RPS 5782.5 RPX 5782.5 PEF 5793.0 DRHO 5793.0 RHOB 5793.0 GR 5803.0 ROP 5874.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: STOP DEPTH 8852.5 8852.5 8852.5 8878 5 8878 5 8878 5 8878 5 8878 5 8887 0 8887 0 8887 0 8898 0 8970 0 EQUIVALENT uNSHIFTED DEPTH -- BIT RUN NO MERGE TOP MERGE BASE 1 112.0 5872.0 2 5872.0 8970.0 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 GR MWD AAPI 4 1 ROP MWD FT/H 4 1 RPX MWD OHMM 4 1 RPS MWD OHMM 4 1 RPM MWD OHMM 4 1 RPD MWD OPIMM 4 1 NPHI MWD P.U. 4 1 FET MWD HOUR 4 1 FCNT MWD CTS/ 4 1 NCNT MWD CTS/ 4 1 RHOB MWD G/CC 4 1 DRHO MWD G/CC 4 1 PEF MWD BARN 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 68 32 9 68 36 10 68 40 11 68 44 12 68 48 13 68 52 14 Name Min Max DEPT 49.5 8970 GR 6.2704 119.418 ROP 6.3575 4514.06 RPX 2.6464 175.215 RPS 2.7785 144.928 RPM 3.0138 165.28 RPD 3.4732 168.37 NPHI 11.9768 64.6334 FET 0.3588 23.994 FCNT 416.685 1182.23 NCNT 2131.54 4058.28 RHOB 1.5458 2.661 DRHO -0.078 0.4376 PEF 1.4173 13.9983 First Last Mean Nsam Reading Reading 4509.75 17842 49.5 8970 59.2333 17698 49.5 8898 247.022 17719 111 8970 12.9904 6193 5782.5 8878.5 13.9549 6193 5782.5 8878.5 14.9495 6193 5782.5 8878.5 16.1337 6193 5782.5 8878.5 38.4853 6190 5758 8852.5 1.94115 6193 5782.5 8878.5 616.145 6190 5758 8852.5 2731.79 6190 5758 8852.5 2.18179 6189 5793 8887 0.0794928 6189 5793 8887 2.21561 6189 5793 8887 First Reading For Entire File .......... 49.5 Last Reading For Entire File ........... 8970 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/09 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 ....... 97/09/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH FCNT 6634.0 NCNT 6634.0 NPHI 6634.0 FET 6658.5 RPD 6658.5 RPM 6658.5 RPS 6658.5 RPX 6658.5 PEF 6668.5 DRHO 6668.5 RHOB 6668.5 GR 6679.0 RAT 6756.5 $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: STOP DEPTH 7173.5 7173.5 7173.5 7200.0 7200.0 7200.0 7200.0 7200.0 7208.5 7208.0 7208.0 7219.5 7292.5 MAD RUN NO. MAD PASS NO. 2 MERGED MAD 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MERGE TOP 6756.5 MERGE BASE 7292.5 Name Service Order Units DEPT FT 4 1 68 RAT MAD FT/H 4 1 68 GR MAD AAP I 4 1 68 RPX MAD OHMM 4 1 68 RP S MAD OHMM 4 1 68 RPD MAD OHMM 4 1 68 FET MAD HOUR 4 1 68 NPHI MAD P.U. 4 1 68 NCNT MAD CTS/ 4 1 68 Size Nsam Rep Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 FCNT MAD CTS/ 4 1 68 RHOB MAD G/CC 4 1 68 DRHO MAD G/CC 4 1 68 PEF MAD BARN 4 1 68 RPM MAD OHIO4 4 1 68 36 40 44 48 52 10 11 12 13 14 Name Min Max Mean Nsam DEPT 6634 7292.5 6963.25 1318 RAT 25.5056 1194.43 174.048 1072 GR 22.5863 93.6682 46.8702 1082 RPX 3.5258 48.2229 16.1509 1084 RPS 3.3447 53.863 19.7323 1084 RPD 3.3485 108.184 25.9148 1084 FET 34.2315 38.9253 36.7774 1084 NPHI 19.3415 62.7412 41.6302 1080 NCNT 2256 3546.03 2623.91 1080 FCNT 435.5 865.511 566.458 1080 RHOB 1.0111 2.6797 2.12004 1080 DRHO -0.641 0.4165 0.0125078 1080 PEF 1.3386 5.5118 2.02813 1081 RPM 3.1931 79.1185 22.9792 1084 First Reading 6634 6756.5 6679 6658.5 6658.5 6658.5 6658.5 6634 6634 6634 6668.5 6668.5 6668.5 6658.5 Last Reading 7292.5 7292.5 7219.5 7200 7200 7200 7200 7173.5 7173.5 7173.5 7208 7208 7208.5 7200 First Reading'For Entire File .......... 6634 Last Reading For Entire File ........... 7292.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/09 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 ....... 97/09/09 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: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 49.5 ROP 111.0 $ LOG HEADER DATA DATE LOGGED: S O FTWARE 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 5812.0 5872.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S): MUD PH: MUD CHLORIDES PPM): FLUID LOSS (C3 : RESISTIVITY (OHMS4) 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 29-JUN-97 5.06 5.46 MEMORY 5872.0 112.0 5872.0 .2 75.8 TOOL NUMBER P0758CG6 8.500 8.5 SPUD 8.80 92.0 9.5 8OO 5.6 .000 .000 .000 .000 26.7 Max frames per record ............. Undefined Absent value ...................... -999.25 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 GR MWD 1 AAPI 4 1 68 4 2 ROP MWD 1 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 49.5 5872.5 2961 11647 49.5 GR 6.2704 119.418 59.0275 11526 49.5 ROP 31.1101 2383.92 290.236 11524 111 Last Reading 5872.5 5812 5872.5 First Reading For Entire File .......... 49.5 Last Reading For Entire File ........... 5872.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 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 FCNT 5758.0 NCNT 5758.0 NPHI 5758.0 FET 5782.5 RFD 5782.5 STOP DEPTH 8852.5 8852.5 8852.5 8878.5 8878.5 RPM 5782.5 RPS 5782.5 RPX 5782.5 PEF 5793.0 DP, HO 5793.0 RHOB 5793.0 GR 5803.0 ROP 5874.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 8878.5 8878.5 8878.5 8887.0 8887.0 8887.0 8898.0 8970.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) I~JD 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: $ 02-JUL-97 5.06 5.46 MEMORY 8970.0 5872.0 8970.0 69.6 77.6 TOOL NUMBER P0766CRDGP6 P0766CRDGP6 P0766CRDGP6 P0766CRDGP6 8.500 8.5 SPUD 9.10 69.0 9.0 800 4.6 3.000 2.500 2.200 3.200 32.8 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 2 AAPI 4 1 68 RPX MWD 2 OHN~4 4 1 68 RPS MWD 2 OHMM 4 1 68 RPM MWD 2 OHMM 4 1 68 RPD MWD 2 OHMM 4 1 68 NPHI MWD 2 P.U. 4 1 68 ROP MWD 2 FT/H 4 1 68 FET MWD 2 HOUR 4 1 68 FCNT MWD 2 CTS/ 4 1 68 NCNT MWD 2 CTS/ 4 1 68 RHOB MWD 2 G/CC 4 1 68 DRHO MWD 2 G/CC 4 1 68 PEF MWD 2 BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max Mean DEPT 5758 8970 7364 GR 11.1091 118.184 59.6644 RPX 2.6464 175.215 12.9904 RPS 2.7785 144.928 13.9549 RPM 3.0138 165.28 14.9495 RPD 3.4732 168.37 16.1337 NPHI 11.9768 64.6334 38.4853 ROP 6.3575 4514.06 166.649 FET 0.3588 23.994 1.94115 FCNT 416.685 1182.23 616.145 NCNT 2131.54 4058.28 2731.79 RHOB 1.5458 2.661 2.18179 DRHO -0.078 0.4376 0.0794928 PEF 1.4173 13.9983 2.21561 Nsam 6425 6191 6193 6193 6193 6193 6196 6192 6193 6190 6190 6189 6189 6189 First Reading 5758 5803 5782.5 5782.5 5782.5 5782.5 · 5758 5874.5 5782.5 5758 5758 5793 5793 5793 Last Reading 8970 8898 8878.5 8878.5 8878.5 8878.5 8852.5 8970 8878.5 8852.5 8852.5 8887 8887 8887 First Reading For Entire File .......... 5758 Last Reading For Entire File ........... 8970 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NUMBER: FILE SUMMARY .5000 2 VENDOR TOOL CODE START DEPTH STOP DEPTH FCNT 6634.0 7173.5 NCNT 6634.0 7173.5 NPHI 6634.0 7173.5 FET 6658.5 7200.0 RPD 6658.5 7200.0 RPM 6658.5 7200.0 RPS 6658.5 7200.0 RPX 6658.5 7200.0 PEF 6668.5 7208.5 DRHO 6668.5 7208.0 RHOB 6668.5 7208.0 GR 6679 . 0 7219 . 5 RAT 6756.5 7292.5 ' $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 CNP ELECTROMAG. RESIS. 4 COMPENSATED NEUTRON 02-JUL-97 5.06 5.46 MEMORY 8970.0 5872.0 8970.0 69.6 77.6 TOOL NUMBER P0766CRDGP6 P0766CRDGP6 P0766CRDGP6 SLD $ STABILIZED LITHO DEN BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHF~4) 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 ............. Undefine'd Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type.,.0 P0766CRDGP6 8.500 8.5 SPUD 9.10 69.0 9.0 80O 4.6 3.000 2.500 2.200 3.200 32.8 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD 2 FT/H 4 1 68 4 2 GR MAD 2 AAP I 4 1 68 8 3 RPX MAD 2 OHM~ 4 1 68 12 4 RPS MAD 2 OH~M 4 1 68 16 5 RPM MAD 2 OHMM 4 1 68 20 6 RPD MAD 2 OHMS4 4 1 68 24 7 FET MAD 2 HOUR 4 1 68 28 8 NPHI MAD 2 P.U. 4 1 68 32 9 NCNT MAD 2 CTS/ 4 1 68 36 10 FCNT MAD 2 CTS/ 4 1 68 40 11 RHOB MAD 2 G/CC 4 1 68 44 12 DRHO MAD 2 G/CC 4 1 68 48 13 PEF MAD 2 BARN 4 1 68 52 14 Name Min Max Mean Nsam DEPT 6634 7292.5 6963.25 1318 RAT 25.5056 1194.43 174.048 1072 GR 22.5863 93.6682 46.8702 1082 RPX 3.5258 48.2229 16.1509 1084 RPS 3.3447 53.863 19.7323 1084 RPM 3.1931 79.1185 22.9792 1084 RPD 3.3485 108.184 25.9148 1084 FET 34.2315 38.9253 36.7774 1084 NPHI 19.3415 62.7412 41.~6302 1080 NCNT 2256 3546.03 2623.91 1080 FCNT 435.5 865.511 566.458 1080 RHOB 1.0111 2.6797 2.12004 1080 DRHO -0.641 0.4165 0.0125078 1080 PEF 1.3386 5.5118 2.02813 1081 First Reading 6634 6756.5 6679 6658.5 6658.5 6658.5 6658.5 6658.5 6634 6634 6634 6668.5 6668.5 6668.5 Last Reading 7292.5 7292.5 7219.5 7200 7200 7200 7200 7200 7173.5 7173.5 7173.5 7208 7208 7208.5 First Reading For Entire File .......... 6634 Last Reading For Entire File ........... 7292.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/09/09 ' Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 97/09/09 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File * ALASKA COMPUTING CENTER * . * . ............................ * * ....... SCHLUMBERGER ....... * . ............................ * COMPANY NAM~ : BP EXPLORATION WELL NAME : MPG-09 FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : AK API NLrM~ER : 500292277900 REFERENCE NO : 98562 Date Ot - o $ - o t L,IS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 10:38 PAGE: **** REEL HEADER **** SERVICE NAM~ : EDIT DATE : 98/11/ 4 ORIGIN : FLIC REEL NAME : 98562 CONTINUATION # : PREVIOUS REEL : COM~EA~f : BP EXPLORATION, MILNE POINT, MPG-09, API #50-029-22779-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/11/ 4 ORIGIN : FLIC TAPE NAME : 98562 COA~fINUATION # : 1 PREVIOUS TAPE : COf4PIENT : BP FJ~PLORATION, MILNE POINT, MPG-09, API #50-029-22779-00 TAPE HEADER MILNE POINT CASED HOLE WIRELINE LOGS WELL NAME: MPG-09 API NUMBER: 500292277900 OPERATOR: BP EXPLORATION LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 4-NOV-98 JOB AU3?4~ER : 98562 LOGGING ENGINEER: OLTMANNS OPERATOR WITNESS: THACKERY SURFACE LOCATION SECTION: 27 TOWNSHIP: 13N RANGE: 10E FNL: FSL: 1605 FEL: 3342 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 58.70 DERRICK FLOOR: 58.20 GROUND LEVEL: 29.20 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8. 500 7. 000 8945.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 10:38 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH $ RENARKS: .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH ....... CONTAINED HEREIN IS THE GR/TENS/CCLU DATA ACQUIRED ON BP EXPLORATION WELL MPG-09 ON 20-FEB-98 WITH THE ULTRA- SONIC CEMF_2VT IMAGING TOOL (USIT). NO DEPTH SHIFTS WERE APPLIED TO THIS DATA AS IT IS THE PRIMARY DEPTH CONTROL FOR THIS WELL. $ PAGE: **** FILE H~ER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 98/11/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE1VOPIBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUAiBER: 1 DEPTH INCREMENT: 0.5000 FILE SLT4NARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 8813.0 3106.0 CET 8846.0 3106.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NIk4~ER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CET L~S Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 10:38 PAGE: REM_ARKS: THIS FILE CONTAINS THE CLIPPED GR/TENS/CCLU DATA FROM THE USIT MAIN PASS. NO DEPTH CORRECTIONS WERE APPLIED TO THIS DATA AS IT IS THE PRIMARY DEPTH CONTROL DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1206671 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CET GAPI 1206671 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CET LB 1206671 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CET V 1206671 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 8846.000 GRCH. CET -999.250 TENS.CET 3082.000 CCL.CET DEPT. 3106.000 GRCH. CET 29.388 TENS. CET 1345.000 CCL.CET 0.205 -0. 073 ** END OF DATA ** biS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 10:38 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE lVVJMBER 2 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INC~: O. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH USIT 8847.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~iA RAY USIT CEMiENT EVALUATION $ BOREHOLE AND CASING DATA OPEN MOLE BIT SIZE (IN): STOP DEPTH 3104.5 20-FEB-98 8B1-129 1813 20-FEB-98 8900.0 8845.0 3000.0 8844.0 NO TOOL NUMBER SGT-L USIT-A 8.500 biS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 10:38 PAGE: DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8945.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE {DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : BRINE 8,80 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: USIT LOGGED AS PRIMARY DEPTH CONTROL LOG. MAX DEVIATION: 77.56 DEGREES AT 7941'. SOME CHANNELING EVIDENT FOR MOST OF LOGGED INTERVAL. PROPOSED PERF INTERVAL: 8660-8770. NO REPEAT PASS AS PER CLIENT REQUEST DUE TO WELL DEVIATION. THIS FILE CONTAINS THE RAW GR/TENS/CCLU DATA FOR THE MAIN PASS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 i~.IS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 10:38 PAGE: 6 TYPE REPR CODE VALUE 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1206671 O0 000 O0 0 2 1 1 4 68 0000000000 GR PS1 GAPI 1206671 O0 000 O0 0 2 1 1 4 68 0000000000 TENS PS1 LB 1206671 O0 000 O0 0 2 1 1 4 68 0000000000 CCL PSl 1206671 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 8847.500 GR.PS1 DEPT. 3104.500 GR.PS1 64.962 TENS.PSi 2825.000 CCL.PS1 29.611 TENS.PSi 1350.000 CCL.PS1 -0.076 -0. 005 ** END OF DATA ** * * * * FILE TRAILER * * * * FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE ~IS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 10:38 PAGE: **** TAPE TRAILER **** SERVICE NAM~ : EDIT DATE · 98/11/ 4 ORIGIN · FLIC TAPE NAM~ : 98562 CONTINUATION # : 1 PREVIOUS TAPE : COf~iTT · BP EXPLORATION, MILNE POINT, MPG-09, API #50-029-22779-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE · 98/11/ 4 ORIGIN : FLIC REEL NAME : 98562 CONTINUATION # : PREVIOUS REEL COMP~T : BP EXPLORATION, MILNE POINT, MPG-09, API #50-029-22779-00 • i • mpg-09.tapx Sperry-Sun Drillin Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Jan 15 11:18:01 2009 Reel Header ~~'" " Service name .............LISTPE Date . ...................09/01/15 Ori gin ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS writing Library. Tape Header Service name .............LISTPE Date . ...................09/01/15 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: MPG-09 API NUMBER: 500292277900 OPERATOR: BP Exploration (Alaska), INC. LOGGING COMPANY: Sperry Sun TAPE CREATION DATE: 15-JAN-09 JOB DATA MWD RUN 1 MWD RUN 2 MAD RUN 2 JOB NUMBER: AK-MM-70189 AK-MM-70189 AK-MM-70189 LOGGING ENGINEER: G. TOBIAS G. TOBIAS G. TOBIAS OPERATOR WITNESS: J. NEW J. NEW J. NEW SURFACE LOCATION SECTION: 27 TOWNSHIP: 13N RANGE: l0E FNL: FSL: 1605 FEL: FwL: 3342 ELEVATION (FT FROM MSL O) KELLY BUSHING: .00 DERRICK FLOOR: 58.20 GROUND LEVEL: 29.20 WELL CASING RECORD Page 1 ' } 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: mpg-09.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 20.000 112.0 ATTENTION: RE-ISSUE, THIS REPLACES THE ORIGINAL LOG AND MERGED DIGITAL DATA SET ISSUED 09-SEP-1997. THE ORGINAL DATA SET UTILIZED MWD AS PRIMARY DEPTH CONTROL AS PER MARK VANDERGON OF BP EXPLORATION (ALASKA), INC TO ALI TURKER OF SPERRY-SUN DRILLING SERVICES 08-SEP-1997. RE-ISSUED LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED HOLE GAMMA RAY LOG RUN ON 20-FEB-1998. THESE DIGITAL DATA WERE PROVIDED BY D. DORTCH (SAIC/BP) ON 18-DEC-2008. LOG HEADER AND ANNOTATION DATA RETAIN ORIGNAL DEPTH REFERENCES. 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS. 4. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED NEUTRON POROSITY (CNP) AND STABILIZIED LITHO DENSITY (SLD). 5. A MEASURED AFTER DRILLING (MAD) PASS WAS PERFORMED FROM 6760'MD, 3775'TVD TO 7288'MD, 3914'TVD ON MWD RUN 2. 6. ALL MWD RUNS REPRESENT MPG-09 WITH API# 50-029-22779-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8970'MD, 4370'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA S HALLOW SPACING). SESP = SMOOTHED PAHSE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). P age 2 • mpg-09.tapx SFXE = SMOOTHED FORMATION EXPOSURE TIME FOR RESISTIVITY SENSOR. SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY CTNA = SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATES. CTFA = SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES. SBDC = SMOOTHED BULK DENSITY-COMPENSATED . SCOR = SMOOTHED STANDOFF CORRECTION. SFPE = SMOOTHED FAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ENVIRONMENTAL PARAMETERS USED IN PROCESSING NEUTRON LOG DATA: HOLE SIZE: 8.5" MUD FILTRATE SALINITY: 800 PPM. MUD WEIGHT: 9.1 PPG. FORMATION WATER SALINITY: 14545 PPM. FLUID DENSITY: 1.0 G/CC. LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, AND A GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header service name... .......sTSLI6.001 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/01/15 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 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 STOP DEPTH GR 49.5 8892.5 RoP 99.0 8964.5 FCNT 5747.0 8847.0 NPHI 5747.0 8847.0 NCNT 5747.0 8847.0 RPM 5772.0 8873.0 RPD 5772.0 8873.0 FET 5772.0 8873.0 RPS 5772.0 8873.0 RPx 5772.0 8873.0 DRHO 5783.0 8881.5 PEF 5783.0 8881.5 RHOB 5783.0 8881.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 2999.5 3011.5 Page 3 3056.0 3069.5 3080.5 3085.0 3160.5 3317.5 3372.5 3397.5 3500.0 3522.5 3547.0 3679.5 3862.0 4009.0 4157.5 4319.5 4450.5 4522.5 4547.0 4567.5 4640.0 4778.5 4809.0 4849.5 5026.5 5053.0 5317.0 5406.0 5441.5 5472.5 5563.5 5581.5 5661.0 5703.0 5719.5 5848.0 5874.0 6001.0 6076.0 6126.5 6477.5 7068.0 7157.0 7187.5 7258.5 7707.0 7767.5 7871.0 7946.0 8139.5 8156.5 8306.5 8433.5 8542.0 8659.5 8726.5 8811.5 MERGED DATA SOURCE PBU TOOL CODE MWD MWD 3068.5 3081.5 3094.5 3097.0 3177.5 3330.5 3381.5 3410.0 3509.0 3534.0 3557.0 3693.0 3874.0 4020.5 4171.0 4331.5 4466.0 4533.0 4557.0 4578.5 4652.5 4785.5 4821.0 4862.0 5038.5 5062.5 5331.0 5420.0 5451.5 5485.0 5572.5 5593.0 5671.5 5715.5 5731.0 5856.5 5882.0 6012.0 6083.5 6135.5 6485.5 7073.5 7164.0 7193.5 7267.5 7714.0 7777.0 7876.5 7953.5 8146.0 8161.5 8313.0 8440.5 8548.5 8664.0 8735.0 8817.0 mpg-09.tapx BIT RUN NO MERGE TOP MERGE BASE 1 49.5 5872.0 2 5872.0 8970.0 Page 4 • $ mpg-09.tapx REMARKS: 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 Code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD CP30 4 1 68 4 2 NCNT MWD CP30 4 1 68 8 3 RHOB MWD G/CC 4 1 68 12 4 DRHO MWD G/CC 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 PEF MWD B/E 4 1 68 36 10 FET MWD HR 4 1 68 40 11 GR MWD API 4 1 68 44 12 NPHI MwD Pu 4 1 68 48 13 ROP MWD FPH 4 1 68 52 14 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 49.5 8964.5 4507 17831 49.5 8964.5 FCNT MWD CP30 416.685 1182.23 616.179 6201 5747 8847 NCNT MwD CP30 2131.54 4058.28 2731.54 6201 5747 8847 RHOB MwD G/CC 1.5458 2.661 2.18177 6198 5783 8881.5 DRHO MWD G/CC -0.078 0.4376 0.0795454 6198 5783 8881.5 RPD MWD OHMM 3.4732 168.37 16.1199 6203 5772 8873 RPM MWD OHMM 3.0138 165.28 14.9356 6203 5772 8873 RPS MWD OHMM 2.7785 144.928 13.9459 6203 5772 8873 RPX MWD OHMM 2.6464 175.215 12.9865 6203 5772 8873 PEF MWD B/E 1.4173 13.9983 2.21574 6198 5783 8881.5 FET MWD HR 0.3588 23.994 1.95646 6203 5772 8873 GR MWD API 6.2704 119.418 59.3578 17687 49.5 8892.5 NPHI MwD Pu 11.9768 64.6334 38.4897 6201 5747 8847 ROP MWD FPH 6.3575 4514.06 246.851 17732 99 8964.5 First Reading For Entire File..........49.5 Last Reading For Entire File...........8964.5 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/01/15 Maximum Physical Record..65535 Page 5 mpg-09.tapx File Type ................L0 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.......09/01/15 Maximum Physical Record..65535 File Type. ...........LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MAD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE FCNT NCNT NPHI RPS RPX RPD FET RPM RHOB DRHO PEF GR RAT MERGED DATA SOURCE PBU TOOL CODE MWD 2 clipped curves; all MAD runs merged using earliest passes. .5000 START DEPTH STOP DEPTH 6632.0 7164.0 6632.0 7164.0 6632.0 7164.0 6657.0 7192.5 6657.0 7192.5 6657.0 7192.5 6657.0 7192.5 6657.0 7192.5 6667.0 7200.0 6667.0 7200.0 6667.0 7200.5 6677.5 7211.0 6755.0 7282.0 MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE 2 1 5758.0 8970.0 REMARKS: MERGED MAD 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 code offset channel DEPT FT 4 1 68 0 1 FCNT MAD CP30 4 1 68 4 2 Page 6 mpg-09.tapx NCNT MAD CP30 4 1 68 8 3 RHOB MAD G/CC 4 1 68 12 4 DRHO MAD G/CC 4 1 68 16 5 RPD MAD OHMM 4 1 68 20 6 RPM MAD OHMM 4 1 68 24 7 RPS MAD OHMM 4 1 68 28 8 RPX MAD OHMM 4 1 68 32 9 PEF MAD B/E 4 1 68 36 10 FET MAD HR 4 1 68 40 11 GR MAD API 4 1 68 44 12 NPHI MAD PU 4 1 68 48 13 RAT MAD FPH 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6632 7282 6957 1301 6632 7282 FCNT MAD CP30 435.5 865.511 567.517 1065 6632 7164 NCNT MAD CP30 2256 3546.03 2626.27 1065 6632 7164 RHOB MAD G/CC 1.0111 2.6797 2.12264 1067 6667 7200 DRHO MAD G/CC -0.641 0.4165 0.0129186 1067 6667 7200 RPD MAD OHMM 3.3485 90.5831 25.5119 1072 6657 7192.5 RPM MAD OHMM 3.1931 74.4582 22.6423 1072 6657 7192.5 RPS MAD OHMM 3.3447 53.863 19.4597 1072 6657 7192.5 RPX MAD OHMM 3.5258 48.2229 15.9425 1072 6657 7192.5 PEF MAD B/E 1.3386 5.5118 2.03542 1068 6667 7200.5 FET MAD HR 34.2315 38.9253 36.7529 1072 6657 7192.5 GR MAD API 22.5863 93.6682 47.1351 1068 6677.5 7211 NPHI MAD PU 19.3415 62.7412 41.5601 1065 6632 7164 RAT MAD FPH 25.5056 1194.43 174.213 1054 6755 7282 First Reading For Entire File..........6632 Last Reading For Entire File...........7282 File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/01/15 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.......09/01/15 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Page 7 Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH SGRC 49.5 SROP 111.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR Dual Gamma BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): Ray STOP DEPTH 5812.0 5872.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Log~iny Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Page 8 mpg-09.tapx header data for each bit run in separate files. 1 .5000 29-~uN-97 5.06 5.46 Memory 5872.0 112.0 5872.0 .2 75.8 TOOL NUMBER P0758CG6 8.500 112.0 Native/Spud Mud 8.80 92.0 9.5 800 5.6 .000 .0 .000 80.0 .000 .0 .000 .0 • ! mpg-09.tapx 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 GR MWDO10 API 4 1 68 4 2 ROP MWDO10 FPH 4 1 68 8 3 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 49.5 5872 2960.75 11646 49.5 5872 GR MWDO10 API 6.2704 119.418 59.0275 11526 49.5 5812 ROP MWDO10 FPH 31.1101 2383.92 290.258 11523 111 5872 First Reading For Entire File..........49.5 Last Reading For Entire File...........5872 File Trailer service name... .......STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/01/15 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/01/15 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH CTFA 5758.0 SPSF 5758.0 CTNA 5758.0 SEDP 5782.5 SEXP 5782.5 SFXE 5782.5 SESP 5782.5 header data for each bit run in separate files. 2 .5000 STOP DEPTH 8852.5 8852.5 8852.5 8878.5 8878.5 8878.5 8878.5 Page 9 • mpg-09.tapx SEMP 5782.5 8878.5 SFPE 5793.0 8887.0 SCOR 5793.0 8887.0 SBDC 5793.0 8887.0 SGRC 5812.5 8898.0 SROP 5872.5 8970.0 LOG HEADER DATA DATE LOGGED: 02-JUL-97 SOFTWARE SURFACE SOFTWARE VERSION: 5.06 DOWNHOLE SOFTWARE VERSION: 5.46 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 5872.0 TOP LOG INTERVAL (FT): 5872.0 BOTTOM LOG INTERVAL (FT): 8970.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 69.6 MAXIMUM ANGLE: 77.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray P0758CG6 EWR4 EWR Phase-4 P0766CRDGP6 CNP Comp Neutron Porosit P0764NP6 SLD stabilized Litho Den P0766CRDGP6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 112.0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S): 69.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 800 FLUID LOSS (C3): 4.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 3.000 75.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.509 91.0 MUD FILTRATE AT MT: 2.200 75.0 MUD CAKE AT MT: 3.200 75.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Page 10 ' ~ • mpg-09.tapx 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 FONT MWD020 CP30 4 1 68 4 2 NCNT MWD020 CP30 4 1 68 8 3 RHOB MWD020 G/CC 4 1 68 12 4 DRHO MWD020 G/CC 4 1 68 16 5 RPD MWD020 OHMM 4 1 68 20 6 RPM MWD020 OHMM 4 1 68 24 7 RPS MWD020 OHMM 4 1 68 28 8 RPX MWD020 OHMM 4 1 68 32 9 PEF MWD020 B/E 4 1 68 36 10 FET MWD020 HR 4 1 68 40 11 GR MWD020 API 4 1 68 44 12 NPHI MWD020 Pu 4 1 68 48 13 ROP MWD020 FPH 4 1 68 52 14 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 5758 8970 7364 6425 5758 8970 FCNT MWD020 CP30 416.685 1182.23 616.145 6190 5758 8852.5 NCNT MWD020 CP30 2131.54 4058.28 2731.79 6190 5758 8852.5 RHOB MWD020 G/CC 1.5458 2.661 2.18179 6189 5793 8887 DRHO MWD020 G/CC -0.078 0.4376 0.0794928 6189 5793 8887 RPD MWD020 OHMM 3.4732 168.37 16.1337 6193 5782.5 8878.5 RPM MWD020 OHMM 3.0138 165.28 14.9495 6193 5782.5 8878.5 RPS MWD020 OHMM 2.7785 144.928 13.9549 6193 5782.5 8878.5 RPX MWD020 OHMM 2.6464 175.215 12.9904 6193 5782.5 8878.5 PEF MWD020 B/E 1.4173 13.9983 2.21561 6189 5793 8887 FET MWD020 HR 0.3588 23.994 1.94115 6193 5782.5 8878.5 GR MwD020 API 11.1091 118.184 59.6176 6172 5812.5 8898 NPHI MWD020 Pu 11.9768 64.6334 38.4853 6190 5758 8852.5 ROP MWD020 FPH 6.3575 4514.06 166.614 6196 5872.5 8970 First Reading For Entire File..........5758 Last Reading For Entire File...........8970 File Trailer Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/01/15 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.005 Physical EoF File Header Service name... .......STSLI6.005 service sub Level~Name... Page 11 . • • mpg-09.tapx version Number. ........1.0.0 Date of Generation.......09/01/15 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 2 MAD PASS NUMBER: 1 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SPSF 6634.0 7173.5 CTFA 6634.0 7173.5 CTNA 6634.0 7173.5 SFXE 6658.5 7200.0 SEXP 6658.5 7200.0 SESP 6658.5 7200.0 SEMP 6658.5 7200.0 SEDP 6658.5 7200.0 SFPE 6668.5 7208.5 SCOR 6668.5 7208.0 SBDC 6668.5 7208.0 SGRC 6679.0 7219.5 SRAT 6756.5 7292.5 LOG HEADER DATA DATE LOGGED: 02-JUL-97 SOFTWARE SURFACE SOFTWARE VERSION: 5.06 DOWNHOLE SOFTWARE VERSION: 5.46 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8970.0 TOP LOG INTERVAL (FT): 5872.0 BOTTOM LOG INTERVAL (FT): 8970.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 69.6 MAXIMUM ANGLE: 77.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray P0758CG6 EWR4 EWR Phase-4 P0766CRDGP6 CNP Comp Neutron Porosit P0764NP6 SLD Stabilized Litho Den P0766CRDGP6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 112.0 BOREHOLE CONDITIONS MUD TYPE: Native/spud Mud MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (5): 69.0 MUD PH: 9.0 Page 12 ,. ~ i i MUD CHLORIDES (PPM): mpg-09.tapx 800 FLUID LOSS (C3): 4.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 3.000 75.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.509 91.0 MUD FILTRATE AT MT: 2.200 75.0 MUD CAKE AT MT: 3.200 75.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....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 Code offset Channel DEPT FT 4 1 68 0 1 FONT MAD021 CP30 4 1 68 4 2 NCNT MAD021 CP30 4 1 68 8 3 RHOB MAD021 G/CC 4 1 68 12 4 DRHO MAD021 G/CC 4 1 68 16 5 RPD MAD021 OHMM 4 1 68 20 6 RPM MAD021 OHMM 4 1 68 24 7 RPS MAD021 OHMM 4 1 68 28 8 RPx MAD021 oHMM 4 1 68 32 9 PEF MAD021 B/E 4 1 68 36 10 FET MAD021 HR 4 1 68 40 11 GR MAD021 API 4 1 68 44 12 NPHI MAD021 PU 4 1 68 48 13 RAT MAD021 FPH 4 1 68 52 14 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 6634 7292.5 6963.25 1318 6634 7292.5 FCNT MAD021 CP30 435.5 865.511 566.458 1080 6634 7173.5 NCNT MAD021 CP30 2256 3546.03 2623.91 1080 6634 7173.5 RHOB MAD021 G/CC 1.0111 2.6797 2.12004 1080 6668.5 7208 DRHO MAD021 G/CC -0.641 0.4165 0.0125078 1080 6668.5 7208 RPD MAD021 OHMM 3.3485 108.184 25.9148 1084 6658.5 7200 RPM MAD021 OHMM 3.1931 79.1185 22.9792 1084 6658.5 7200 RPS MAD021 OHMM 3.3447 53.863 19.7323 1084 6658.5 7200 RPx MAD021 OHMM 3.5258 48.2229 16.1509 1084 6658.5 7200 PEF MAD021 B/E 1.3386 5.5118 2.02813 1081 6668.5 7208.5 FET MAD021 HR 34.2315 38.9253 36.7774 1084 6658.5 7200 GR MAD021 API 22.5863 93.6682 46.8702 1082 6679 7219.5 Page 13 mpg-09.tapx NPHI MAD021 PU 19.3415 62.7412 41.6302 RAT MAD021 FPH 25.5056 1194.43 174.048 First Reading For Entire File..........6634 Last Reading For Entire File...........7292.5 File Trailer Service name... .......STSLI6.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......09/01/15 Maximum Physical Record..65535 File TyL~e ................L0 Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................09/01/15 Origin ...................STS Tape Name. .... ........UNKNOWN continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS writing Library. Reel Trailer Service name .............LISTPE Date . ...................09/01/15 Ori 9in ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library Physical EOF Physical EOF End Of LIS File 1080 6634 7173.5 1072 6756.5 7292.5 Scientific Technical Services scientific Technical services Page 14 } ~ • mpg-09.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Jan 15 11:18:01 2009 Reel Header Service name .............LISTPE .~ ~~ ~~~~~ L Date . ...................09/01/15 Ori in ...................STS Ree~ Name. .... ........UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS writing Library. Scientific Technical Services Tape Header Service name .............LISTPE Date . ...................09/01/15 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: MPG-09 API NUMBER: 500292277900 OPERATOR: BP Exploration (Alaska), INC. LOGGING COMPANY: Sperry Sun TAPE CREATION DATE: 15-JAN-09 JOB DATA MWD RUN 1 MWD RUN 2 MAD RUN 2 JOB NUMBER: AK-MM-70189 AK-MM-70189 AK-MM-70189 LOGGING ENGINEER: G. TOBIAS G. TOBIAS G. TOBIAS OPERATOR WITNESS: J. NEW J. NEW J. NEW SURFACE LOCATION SECTION: 27 TOWNSHIP: 13N RANGE: l0E FNL: FSL: 1605 FEL: FWL: 3342 ELEVATION (FT FROM MSL O) KELLY BUSHING: .00 DERRICK FLOOR: 58.20 GROUND LEVEL: 29.20 WELL CASING RECORD Page 1 vs ~ t ~ `~ - I l ~ U~~ ~'~ (~3~ i OPEN HOLE BIT SIZE (IN) 1ST STRING 8.500 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: mpg-09.tapx CASING DRILLERS SIZE (IN) DEPTH (FT) 20.000 112.0 • ATTENTION: RE-ISSUE, THIS REPLACES THE ORIGINAL LOG AND MERGED DIGITAL DATA SET ISSUED 09-SEP-1997. THE ORGINAL DATA SET UTILIZED MWD AS PRIMARY DEPTH CONTROL AS PER MARK VANDERGON OF BP EXPLORATION (ALASKA), INC TO ALI TURKER OF SPERRY-SUN DRILLING SERVICES 08-SEP-1997. RE-ISSUED LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED HOLE GAMMA RAY LOG RUN ON 20-FEB-1998. THESE DIGITAL DATA WERE PROVIDED BY D. DORTCH (SAIC/BP) ON 18-DEC-2008. LOG HEADER AND ANNOTATION DATA RETAIN ORIGNAL DEPTH REFERENCES. 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS. 4. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED NEUTRON POROSITY (CNP) AND STABILIZIED LITHO DENSITY (SLD). 5. A MEASURED AFTER DRILLING (MAD) PASS WAS PERFORMED FROM 6760'MD, 3775'TVD TO 7288'MD, 3914'TVD ON MWD RUN 2. 6. ALL MWD RUNS REPRESENT MPG-09 WITH API# 50-029-22779-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8970'MD, 4370'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA S HALLOW SPACING). SESP = SMOOTHED PAHSE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). Page 2 • ~~ J mpg-09.tapx SFXE = SMOOTHED FORMATION EXPOSURE TIME FOR RESISTIVITY SENSOR. SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY CTNA = SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATES. CTFA = SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES. SBDC = SMOOTHED BULK DENSITY-COMPENSATED . SCOR = SMOOTHED STANDOFF CORRECTION. SFPE = SMOOTHED FAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ENVIRONMENTAL PARAMETERS USED IN PROCESSING NEUTRON LOG DATA: HOLE SIZE: 8.5" MUD FILTRATE SALINITY: 800 PPM. MUD WEIGHT: 9.1 PPG. FORMATION WATER SALINITY: 14545 PPM. FLUID DENSITY: 1.0 G/CC. LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, AND A GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/01/15 Maximum Physical Record..65535 File Type.. ............LO Previous File Name.......STSLI6.000 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 STOP DEPTH GR 49.5 8892.5 ROP 99.0 8964.5 FCNT 5747.0 8847.0 NPHI 5747.0 8847.0 NCNT 5747.0 8847.0 RPM 5772.0 8873.0 RPD 5772.0 8873.0 FET 5772.0 8873.0 RPS 5772.0 8873.0 RPX 5772.0 8873.0 DRHO 5783.0 8881.5 PEF 5783.0 8881.5 RHOB 5783.0 8881.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 2999.5 3011.5 Page 3 3056.0 3069.5 3080.5 3085.0 3160.5 3317.5 3372.5 3397.5 3500.0 3522.5 3547.0 3679.5 3862.0 4009.0 4157.5 4319.5 4450.5 4522.5 4547.0 4567.5 4640.0 4778.5 4809.0 4849.5 5026.5 5053.0 5317.0 5406.0 5441.5 5472.5 5563.5 5581.5 5661.0 5703.0 5719.5 5848.0 5874.0 6001.0 6076.0 6126.5 6477.5 7068.0 7157.0 7187.5 7258.5 7707.0 7767.5 7871.0 7946.0 8139.5 8156.5 8306.5 8433.5 8542.0 8659.5 8726.5 8811.5 MERGED DATA SOURCE PBU TOOL CODE MWD MWD L_ J 3068.5 3081.5 3094.5 3097.0 3177.5 3330.5 3381.5 3410.0 3509.0 3534.0 3557.0 3693.0 3874.0 4020.5 4171.0 4331.5 4466.0 4533.0 4557.0 4578.5 4652.5 4785.5 4821.0 4862.0 5038.5 5062.5 5331.0 5420.0 5451.5 5485.0 5572.5 5593.0 5671.5 5715.5 5731.0 5856.5 5882.0 6012.0 6083.5 6135.5 6485.5 7073.5 7164.0 7193.5 7267.5 7714.0 7777.0 7876.5 7953.5 8146.0 8161.5 8313.0 8440.5 8548.5 8664.0 8735.0 8817.0 mpg-09.tapx BIT RUN NO MERGE TOP MERGE BASE 1 49.5 5872.0 2 5872.0 8970.0 Page 4 $ mpg-09.tapx REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loggin 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 FCNT MWD CP30 4 1 68 4 2 NCNT MWD CP30 4 1 68 8 3 RHOB MWD G/CC 4 1 68 12 4 DRHO MWD G/CC 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 PEF MWD B/E 4 1 68 36 10 FET MWD HR 4 1 68 40 11 GR MWD API 4 1 68 44 12 NPHI MwD Pu 4 1 68 48 13 ROP MWD FPH 4 1 68 52 14 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 49.5 8964.5 4507 17831 49.5 8964.5 FCNT MWD CP30 416.685 1182.23 616.179 6201 5747 8847 NCNT MWD CP30 2131.54 4058.28 2731.54 6201 5747 8847 RHOB MWD G/CC 1.5458 2.661 2.18177 6198 5783 8881.5 DRHO MWD G/CC -0.078 0.4376 0.0795454 6198 5783 8881.5 RPD MWD OHMM 3.4732 168.37 16.1199 6203 5772 8873 RPM MWD OHMM 3.0138 165.28 14.9356 6203 5772 8873 RPS MWD OHMM 2.7785 144.928 13.9459 6203 5772 8873 RPX MWD OHMM 2.6464 175.215 12.9865 6203 5772 8873 PEF MWD B/E 1.4173 13.9983 2.21574 6198 5783 8881.5 FET MWD HR 0.3588 23.994 1.95646 6203 5772 8873 GR MWD API 6.2704 119.418 59.3578 17687 49.5 8892.5 NPHI MWD Pu 11.9768 64.6334 38.4897 6201 5747 8847 ROP MWD FPH 6.3575 4514.06 246.851 17732 99 8964.5 First Reading For Entire File..........49.5 Last Reading For Entire File...........8964.5 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/01/15 Maximum Physical Record..65535 Page 5 • mpg-09.tapx 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.......09/01/15 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSL26.001 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MAD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE FCNT NCNT NPHI RPS RPX RPD FET RPM RHOB DRHO PEF GR RAT MERGED DATA SOURCE PBU TOOL CODE MWD 2 • clipped curves; all MAD runs merged using earliest passes. .5000 START DEPTH STOP DEPTH 6632.0 7164.0 6632.0 7164.0 6632.0 7164.0 6657.0 7192.5 6657.0 7192.5 6657.0 7192.5 6657.0 7192.5 6657.0 7192.5 6667.0 7200.0 6667.0 7200.0 6667.0 7200.5 6677.5 7211.0 6755.0 7282.0 MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE 2 1 5758.0 8970.0 REMARKS: MERGED MAD 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 Code offset Channel DEPT FT 4 1 68 0 1 FCNT MAD CP30 4 1 68 4 2 Page 6 • mpg-09.tapx NCNT MAD CP30 4 1 68 8 3 RHOB MAD G/CC 4 1 68 12 4 DRHO MAD G/CC 4 1 68 16 5 RPD MAD OHMM 4 1 68 20 6 RPM MAD OHMM 4 1 68 24 7 RPS MAD OHMM 4 1 68 28 8 RPX MAD OHMM 4 1 68 32 9 PEF MAD B/E 4 1 68 36 10 FET MAD HR 4 1 68 40 11 GR MAD API 4 1 68 44 12 NPHI MAD PU 4 1 68 48 13 RAT MAD FPH 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6632 7282 6957 1301 6632 7282 FCNT MAD CP30 435.5 865.511 567.517 1065 6632 7164 NCNT MAD CP30 2256 3546.03 2626.27 1065 6632 7164 RHOB MAD G/CC 1.0111 2.6797 2.12264 1067 6667 7200 DRHO MAD G/cc -0.641 0.4165 0.0129186 1067 6667 7200 RPD MAD OHMM 3.3485 90.5831 25.5119 1072 6657 7192.5 RPM MAD OHMM 3.1931 74.4582 22.6423 1072 6657 7192.5 RPS MAD OHMM 3.3447 53.863 19.4597 1072 6657 7192.5 RPX MAD OHMM 3.5258 48.2229 15.9425 1072 6657 7192.5 PEF MAD B/E 1.3386 5.5118 2.03542 1068 6667 7200.5 FET MAD HR 34.2315 38.9253 36.7529 1072 6657 7192.5 GR MAD API 22.5863 93.6682 47.1351 1068 6677.5 7211 NPHI MAD PU 19.3415 62.7412 41.5601 1065 6632 7164 RAT MAD FPH 25.5056 1194.43 174.213 1054 6755 7282 First Reading For Entire File..........6632 Last Reading For Entire File...........7282 File Trailer Service name... .......sTSLI6.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/01/15 Maximum Physical Record..65535 File Type ................L0 Next File Name...........sTSLIB.003 Physical EOF File Header Service name... .......STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/01/15 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSL26.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Page 7 • • mpg-09.tapx Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DE PTH INCREMENT: .5000 FI LE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SGRC 49.5 5812.0 SROP 111.0 5872.0 LOG HEADER DATA DATE LOGGED: 29-7UN-97 SOFTWARE SURFACE SOFTWARE VERSION: 5.06 DOWNHOLE SOFTWARE VERSION: 5.46 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 5872.0 TOP LOG INTERVAL (FT): 112.0 BOTTOM LOG INTERVAL (FT): 5872.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .2 MAXIMUM ANGLE: 75.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray P0758CG6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 112.0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S): 92.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 800 FLUID LOSS (C3): 5.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 80.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O 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 Page 8 • • mpg-09.tapx 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 GR MwD010 API 4 1 68 4 2 ROP MwD010 FPH 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 49.5 5872 2960.75 11646 49.5 5872 GR MwD010 API 6.2704 119.418 59.0275 11526 49.5 5812 ROP MWDO10 FPH 31.1101 2383.92 290.258 11523 111 5872 First Reading For Entire File..........49.5 Last Reading For Entire File...........5872 File Trailer service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......09/01/15 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......09/01/15 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 comment Record FILE HEADER FILE NUMBER: 4 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 STOP DEPTH CTFA 5758.0 8852.5 SPSF 5758.0 8852.5 CTNA 5758.0 8852.5 SEDP 5782.5 8878.5 SEXP 5782.5 8878.5 SFXE 5782.5 8878.5 SESP 5782.5 8878.5 Page 9 • • mpg-09.tapx SEMP 5782.5 8878.5 SFPE 5793.0 8887.0 SCOR 5793.0 8887.0 SBDC 5793.0 8887.0 SGRC 5812.5 8898.0 ROP 5872.5 8970.0 $ LOG HEADER DATA DATE LOGGED: 02-JUL-97 SOFTWARE SURFACE SOFTWARE VERSION: 5.06 DOWNHOLE SOFTWARE VERSION: 5.46 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 5872.0 TOP LOG INTERVAL (FT): 5872.0 BOTTOM LOG INTERVAL (FT): 8970.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 69.6 MAXIMUM ANGLE: 77.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray P0758CG6 EWR4 EWR Phase-4 P0766CRDGP6 CNP Comp Neutron Porosit P0764NP6 SLD Stabilized Litho Den P0766CRDGP6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 112.0 BOREHOLE CONDITIONS MUD TYPE: Native/spud Mud MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S): 69.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 800 FLUID LOSS (C3): 4.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 3.000 75.0 MUD AT MAX CIRCULATING TERM PERATURE: 2.509 91.0 MUD FILTRATE AT MT: 2.200 75.0 MUD CAKE AT MT: 3.200 75.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Page 10 • mpg-09.tapx 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 FCNT MWD020 CP30 4 1 68 4 2 NCNT MWD020 CP30 4 1 68 8 3 RHOB MWD020 G/CC 4 1 68 12 4 DRHO MWD020 G/CC 4 1 68 16 5 RPD MwD020 OHMM 4 1 68 20 6 RPM MWD020 OHMM 4 1 68 24 7 RPS MWD020 OHMM 4 1 68 28 8 RPX MWD020 OHMM 4 1 68 32 9 PEF MwD020 B/E 4 1 68 36 10 FET MWD020 HR 4 1 68 40 11 GR MWD020 API 4 1 68 44 12 NPHI MWD020 PU 4 1 68 48 13 ROP MWD020 FPH 4 1 68 52 14 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 5758 8970 7364 6425 5758 8970 FCNT MWD020 CP30 416.685 1182.23 616.145 6190 5758 8852.5 NCNT MWD020 CP30 2131.54 4058.28 2731.79 6190 5758 8852.5 RHOB MWD020 G/CC 1.5458 2.661 2.18179 6189 5793 8887 DRHO MWD020 G/CC -0.078 0.4376 0.0794928 6189 5793 8887 RPD MWD020 OHMM 3.4732 168.37 16.1337 6193 5782.5 8878.5 RPM MWD020 OHMM 3.0138 165.28 14.9495 6193 5782.5 8878.5 RPS MWD020 OHMM 2.7785 144.928 13.9549 6193 5782.5 8878.5 RPX MWD020 OHMM 2.6464 175.215 12.9904 6193 5782.5 8878.5 PEF MwD020 B/E 1.4173 13.9983 2.21561 6189 5793 8887 FET MwD020 HR 0.3588 23.994 1.94115 6193 5782.5 8878.5 GR MWD020 API 11.1091 118.184 59.6176 6172 5812.5 8898 NPHI MwD020 Pu 11.9768 64.6334 38.4853 6190 5758 8852.5 ROP MWD020 FPH 6.3575 4514.06 166.614 6196 5872.5 8970 First Reading For Entire File..........5758 Last Reading For Entire File...........8970 File Trailer Service name... .......STSL2B.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/01/15 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLIB.005 service sub Level Name... Page 11 • • mpg-09.tapx version Number. ........1.0.0 Date of Generation.......09/01/15 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.004 comment Record FILE HEADER FILE NUMBER: 5 RAW MAD Curves and log header data for each pass of ea ch run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 2 MAD PASS NUMBER: 1 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SPSF 6634.0 7173.5 CTFA 6634.0 7173.5 CTNA 6634.0 7173.5 SFXE 6658.5 7200.0 SEXP 6658.5 7200.0 SESP 6658.5 7200.0 SEMP 6658.5 7200.0 SEDP 6658.5 7200.0 SFPE 6668.5 7208.5 SCOR 6668.5 7208.0 SBDC 6668.5 7208.0 SGRC 6679.0 7219.5 RAT 6756.5 7292.5 $ LOG HEADER DATA DATE LOGGED: 02-JUL-97 SOFTWARE SURFACE SOFTWARE VERSION: 5.06 DOWNHOLE SOFTWARE VERSION: 5.46 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8970.0 TOP LOG INTERVAL (FT): 5872.0 BOTTOM LOG INTERVAL (FT): 8970.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 69.6 MAXIMUM ANGLE: 77.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray P0758CG6 EWR4 EWR Phase-4 P0766CRDGP6 CNP Comp Neutron Porosit P0764NP6 SLD Stabilized Litho Den P0766CRDGP6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 112.0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S): 69.0 MUD PH: 9.0 Page 12 • mpg-09.tapx MUD CHLORIDES (PPM): 800 FLUID LOSS (C3): 4.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 3.000 75.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.509 91.0 MUD FILTRATE AT MT: 2.200 75.0 MUD CAKE AT MT: 3.200 75.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Log~iny 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 FCNT MAD021 CP30 4 1 68 4 2 NCNT MAD021 CP30 4 1 68 8 3 RHOB MAD021 G/CC 4 1 68 12 4 DRHO MAD021 G/CC 4 1 68 16 5 RPD MAD021 OHMM 4 1 68 20 6 RPM MAD021 OHMM 4 1 68 24 7 RPS MAD021 OHMM 4 1 68 28 8 RPX MAD021 OHMM 4 1 68 32 9 PEF MAD021 B/E 4 1 68 36 10 FET MAD021 HR 4 1 68 40 11 GR MAD021 API 4 1 68 44 12 NPHI MAD021 PU 4 1 68 48 13 RAT MAD021 FPH 4 1 68 52 14 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 6634 7292.5 6963.25 1318 6634 7292.5 FCNT MAD021 CP30 435.5 865.511 566.458 1080 6634 7173.5 NCNT MAD021 CP30 2256 3546.03 2623.91 1080 6634 7173.5 RHOB MAD021 G/CC 1.0111 2.6797 2.12004 1080 6668.5 7208 DRHO MAD021 G/CC -0.641 0.4165 0.0125078 1080 6668.5 7208 RPD MAD021 OHMM 3.3485 108.184 25.9148 1084 6658.5 7200 RPM MAD021 OHMM 3.1931 79.1185 22.9792 1084 6658.5 7200 RPS MAD021 OHMM 3.3447 53.863 19.7323 1084 6658.5 7200 RPX MAD021 OHMM 3.5258 48.2229 16.1509 1084 6658.5 7200 PEF MAD021 B/E 1.3386 5.5118 2.02813 1081 6668.5 7208.5 FET MAD021 HR 34.2315 38.9253 36.7774 1084 6658.5 7200 GR MAD021 API 22.5863 93.6682 46.8702 1082 6679 7219.5 Page 13 NPHI MAD021 PU 19.3415 62.7412 09 t 41 6302 RAT MAD021 FPH 25.5056 1194.43 174.048 First Reading For Entire File..........6634 Last Reading For Entire File...........7292.5 File Trailer service name... .......STSLI6.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/01/15 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................09/01/15 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date . ...................09/01/15 0ri9in ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Physical EoF End Of LIS File 1080 6634 7173.5 1072 6756.5 7292.5 Scientific Technical Services Scientific Technical Services Page 14
