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Home My WebLink About202-014MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, November 25, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC S-31 MILNE PT UNIT S-31 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 11/25/2025 S-31 50-029-23066-00-00 202-014-0 W SPT 3857 2020140 1500 874 877 875 877 OTHER P Kam StJohn 10/12/2025 Monobore well. 2 Year MIT-IA been SI and missed its due date of 04/13/25 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:MILNE PT UNIT S-31 Inspection Date: Tubing OA Packer Depth 400 1688 1642 1632IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS251012104605 BBL Pumped:1.1 BBL Returned:1.1 Tuesday, November 25, 2025 Page 1 of 1           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: MPS-31 (PTD# 2020140) - Return to Injection Date:Monday, October 6, 2025 11:22:06 AM From: Ryan Thompson <ryan.thompson@hilcorp.com> Sent: Friday, October 3, 2025 11:07 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: OPERABLE: MPS-31 (PTD# 2020140) - Return to Injection Mr. Wallace – PWI well MPS-31 (PTD# 2020140) is not operable due to being shut in for its AOGCC MIT- IA. The surface constraints mentioned below have been resolved and we will now be bringing the well back on water injection. The well is re-classified as Operable and an online AOGCC witnessed MIT-IA will be performed once on stable injection. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Monday, September 15, 2025 10:57 AM To: 'Wallace, Chris D (OGC)' <chris.wallace@alaska.gov>; jim.regg <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: NOT OPERABLE: MPS-31 (PTD# 2020140) - Well Remains Shut In Mr. Wallace, In May 2025, MPS-31 (PTD# 2020140) was re-classified to Operable with the intent to place the well on injection. The well has remained shut in since the below date due to surface constraints with no current plan to place on injection. The well is now classified as NOT OPERABLE and will remain shut in. A witnessed MIT-IA will be scheduled once the well is returned to injection. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Friday, May 23, 2025 9:26 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; jim.regg <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: OPERABLE: MPS-31 (PTD# 2020140) - Place on Injection Mr. Wallace – PWI well MPS-31 (PTD# 2020140) is not operable due to being shut in for its AOGCC MIT-IA. We will now be bringing the well back on water injection. The well is re-classified as Operable and an online AOGCC witnessed MIT-IA will be performed once on stable injection. Please respond with any questions. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Monday, April 28, 2025 2:33 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; jim.regg <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: NOT OPERABLE: MPS-31 (PTD# 2020140) - Shut in for 2 year AOGCC MIT-IA Mr. Wallace – PWI well MPS-31 (PTD# 2020140) is currently shut in and will not be brought online for its scheduled 2 year MIT-IA due this month. The well is now classified as NOT OPERABLE and will remain shut in. A witnessed MIT-IA will be scheduled once the well is returned to injection. Please respond with any questions. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately 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 theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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: NOT OPERABLE: MPS-31 (PTD# 2020140) - Well Remains Shut In Date:Monday, September 15, 2025 11:09:45 AM From: Ryan Thompson <ryan.thompson@hilcorp.com> Sent: Monday, September 15, 2025 10:57 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: NOT OPERABLE: MPS-31 (PTD# 2020140) - Well Remains Shut In Mr. Wallace, In May 2025, MPS-31 (PTD# 2020140) was re-classified to Operable with the intent to place the well on injection. The well has remained shut in since the below date due to surface constraints with no current plan to place on injection. The well is now classified as NOT OPERABLE and will remain shut in. A witnessed MIT-IA will be scheduled once the well is returned to injection. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Friday, May 23, 2025 9:26 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; jim.regg <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: OPERABLE: MPS-31 (PTD# 2020140) - Place on Injection Mr. Wallace – PWI well MPS-31 (PTD# 2020140) is not operable due to being shut in for its AOGCC MIT-IA. We will now be bringing the well back on water injection. The well is re-classified as Operable and an online AOGCC witnessed MIT-IA will be performed once on stable injection. Please respond with any questions. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Monday, April 28, 2025 2:33 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; jim.regg <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: NOT OPERABLE: MPS-31 (PTD# 2020140) - Shut in for 2 year AOGCC MIT-IA Mr. Wallace – PWI well MPS-31 (PTD# 2020140) is currently shut in and will not be brought online for its scheduled 2 year MIT-IA due this month. The well is now classified as NOT OPERABLE and will remain shut in. A witnessed MIT-IA will be scheduled once the well is returned to injection. Please respond with any questions. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 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 herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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: MPS-31 (PTD# 2020140) - Place on Injection Date:Friday, May 23, 2025 10:14:39 AM From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, May 23, 2025 9:26 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: OPERABLE: MPS-31 (PTD# 2020140) - Place on Injection Mr. Wallace – PWI well MPS-31 (PTD# 2020140) is not operable due to being shut in for its AOGCC MIT-IA. We will now be bringing the well back on water injection. The well is re-classified as Operable and an online AOGCC witnessed MIT-IA will be performed once on stable injection. Please respond with any questions. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Monday, April 28, 2025 2:33 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; jim.regg <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: NOT OPERABLE: MPS-31 (PTD# 2020140) - Shut in for 2 year AOGCC MIT-IA Mr. Wallace – PWI well MPS-31 (PTD# 2020140) is currently shut in and will not be brought online for its scheduled 2 year MIT-IA due this month. The well is now classified as NOT OPERABLE and will remain shut in. A witnessed MIT-IA will be scheduled once the well is returned to injection. Please respond with any questions. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 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, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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: NOT OPERABLE: MPS-31 (PTD# 2020140) - Shut in for 2 year AOGCC MIT-IA Date:Monday, April 28, 2025 4:25:36 PM From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Monday, April 28, 2025 2:33 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: NOT OPERABLE: MPS-31 (PTD# 2020140) - Shut in for 2 year AOGCC MIT-IA Mr. Wallace – PWI well MPS-31 (PTD# 2020140) is currently shut in and will not be brought online for its scheduled 2 year MIT-IA due this month. The well is now classified as NOT OPERABLE and will remain shut in. A witnessed MIT-IA will be scheduled once the well is returned to injection. Please respond with any questions. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified 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 theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, May 12, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC S-31 MILNE PT UNIT S-31 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/12/2023 S-31 50-029-23066-00-00 202-014-0 W SPT 3857 2020140 1500 1136 1139 1135 1136 OTHER P Sully Sullivan 4/13/2023 2 year cycle, monobore well. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:MILNE PT UNIT S-31 Inspection Date: Tubing OA Packer Depth 120 1761 1706 1692IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS230413162300 BBL Pumped:1.6 BBL Returned:1.6 Friday, May 12, 2023 Page 1 of 1            MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO:Jim R�'��14,'ZLrLI DATE: Thursday, July 1, 2021 1 l SUBJECT: Mechanical Integrity Tests P.I. Supervisor Hilcorp Alaska, LLC S-31 FROM: Jeff Jones MILNE PT UNIT S-31 Petroleum Inspector Sre: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name MILNE PT UNIT S-31 Insp Num: mitJJ210627155706 Rel Insp Num: API Well Number 50-029-23066-00-00 Inspector Name: Jeff Jones Permit Number: 202-014-0 Inspection Date: 4/24/2021 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well S-31 Type Inj w TVD1 3857 Tubing 287 297 292 295 Type p P t 2020140 T e Test SPT Test Si[ 1500 IA 853 1678 1641 1636 — ti - - BBL Pumped:0.7 ' BBL Returned: 0.7 OA Intervale OTHER P/F P Notes' Monobore injector; no OA. Long term S/I ; returning to service & 2 year test cycle. I well inspected, no exceptions noted.'' I— Thursday, July 1, 2021 Page 1 of I Wallace, Chris D (CED) From: David Haakinson <dhaakinson@hilcorp.com> Sent: Monday, April 5, 2021 3:07 PM To: Wallace, Chris D (CED); Alaska NS - Milne - Wellsite Supervisors; Alaska NS - Wells Foreman Cc: Regg, James B (CED); Brooks, Phoebe L (CED); Dard Horner - (C); Tom Fouts; David Haakinson Subject: LTSI Injector MPS -31 (PTD # 2020140) Ready For Injection All, Long Term Shut-in Milne Point water injector MPS -31 (PTD # 2020140) had a passing pre -MIT on 3/31/2021. The well has been shut in for reservoir management since 7/28/2019 and lapsed its historic 2 year MIT interval (well is a monobore) in April 2020. There are no known integrity issues and the well is ready to return to injection for stabilization and compliance testing. Plan Forward - Milne Operations 1) Place well on injection. Use caution, annuli are fluid packed. 2) AOGCC MIT -IA once well is on injection and thermally stable. Thank You, David Haakinson Operations Engineer I North Slope Asset Team Hilcorp Alaska, LLC Office: (907) 777-8343 1 Cell: (307) 660-4999 dhaakinsonAhilcorp.com The Information contained in this email message is confidential and maybe 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 noted 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. Yil....... I IA/ -11 -IP .Ine mTn n nnnn4M I Q; -IA ln,iiCmnqi M 1000 2000 3000 4000 W 5000 O1 4 v 0 6000 t y 7000 0 6000 9000 10000 11000 Pressure (psia) 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 12000 1 1 11 ' i I' i ' i I I ' i ' i i' ism 30 40 50 60 70 80 90 100 110 120 130 140 150 160 170 Temperature (Deg. F) —RIHPressure21 — Perfs 16" —133/8" —95/8" —TBG LS —TBG SS x Pkr x Pkr —RIH 2021 Temp —RIH 2019 Temp MEMORANDUM • •tate of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Friday,April 20,2018 � P.I.Supervisor ' efq `I/f n ( 1Ce2 SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC S-31 FROM: Lou Laubenstein MILNE PT UNIT S-31 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry Jo 2-- NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT S-31 API Well Number 50-029-23066-00-00Inspector Name: Lou Laubenstein Permit Number: 202-014-0 Inspection Date: 4/16/2018 /" Insp Num: mitLOL180418165915 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well T S-31 Type Inj W-TVD 3857 " 'Tubing 451 - 457 - 448 - 445 - PTD 2020140 ' Type Test, SPT Test psi 1500 ' IA 285 1724 - 1672 - 1662 - T-- BBL Pumped: 13 "IBBL Returned: 1 1.3 - OA Interval ' OTHER - P/F P v Notes: Monobore well,no OA SCAMS 7. f; Friday,April 20,2018 Page 1 of 1 OFT • ,§,.. \\111//>:,v, THE STATE Alaska Oil and Gas of LAsKA Conservation Commission Critt: _-_= 333 West Seventh Avenue - GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 p Q. Main: 907.279.1433 ALAs� Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager same) NOV 1 3 au", Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU S-31 Permit to Drill Number: 202-014 Sundry Number: 317-492 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, A?Egs . Hollis S. French Chair DATED this 26 day of October, 2017. REDI-3160`+1 - Ltu! • 2:-;1',, STATE OF ALASKA V-1 S (o (44 /12 ALASKA OIL AND GAS CONSERVATION COMMISSION - G.,.:' ,,, .' APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: MBE Treatment ❑✓ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC • Exploratory ❑ Development ❑ 202-014 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑� , 6.API Number: Anchorage Alaska 99503 50-029-23066-00-00 , 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 Will planned perforations require a spacing exception? Yes ❑ No 0/ MILNE PT UNIT S-31 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0380109 ' MILNE POINT/SCHRADER BLUFF OIL , 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 8,143' s 4,287' 8,032' % 4,197' A 1,780 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 135' 9-5/8" 135' 135' 6,870psi 4,760psi Production 8,133' 7" 8,133' 4,279' 7,240psi 5,410psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic ' See Attached Schematic 3-1/2" 9.2/L-80/TC-II 7,931' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): . v (3)7"x 3-1/2"Premier Packers and N/A 7,599MD/3,857TVD,7,725MD/3,952TVD&7,878MD/4,072 and N/A 12.Attachments: Proposal Summary 2 Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic❑ Development❑ Service E. 14.Estimated Date for 15.Well Status after proposed work: 10/30/2017 Commencing Operations: OIL ❑ WINJ a WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York Contact Name: Stan Porhola Authorized Title: Operations Manager Contact Email: sporholaahilcorp.com Contact Phone: 777-8412 Authorized Signature: 45.. Date: 10/16/2017 YKk• COMMISSION USE ONLY Conditions of approva ti Commission so that a representative may witness Sundry Number: 3 / -7- y9.2 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No E Subsequent Form Required: !0 y v y APPROVED BY Z_L ` Approved by: COMMISSIONER THE COMMISSION Date: 1 U 11' fKa i°Iii III- / ii.) .�ti_,7 4( A /D�ln, ORIGINAL !� Submit Form and `Q' Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. RPD IVIS ‘Z'\'14,11 1 meat i2®tlblicate • S • Well Prognosis Well: MPU S-31 lliicon)Alaska,LLI Date:10/13/2017 Well Name: MPU S-31 API Number: 50-029-23066-00 Current Status: Water Injector Pad: Milne Point S-Pad Estimated Start Date: October 30th 2017 Rig: N/A Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 202-014 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AAE Number Job.Tylie. MB,E Treatment „;, Current Bottom Hole Pressure: 2,180 psi @ 4,000' TVD (SBHPS 1/24/2013/ 10.48 ppg EMW) Maximum Expected BHP: 2,180 psi @ 4,000' TVD (No new perfs being added, EMW= 10.48 ppg) ✓ MPSP: 1,780 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPU S-31 was drilled with Nabors#27E in 2002 as a deviated injector in the Schrader Bluff NB, OA, and OB sands and provides support in hydraulic unit 10 for offset producer MPU S-27 (PTD 202-085). The well was initially completed by Doyon #141 in 2002. Perfs were added to the NB sand in 2003 and the surface casing was repaired by Doyon 14 in 2008.The well has developed an MBE (Matrix By-pass Event) with offset producer MPU S-27 (PTD 202-085). Notes Regarding Wellbore Condition • Well is a deviated water injector(max hole angle 78° @ 4,039'). • Last MIT-IA to 1,750 psi on 5/31/2014. • Confirmed MBE between MPU S-27 (Jet Pump Oil Producer) based on red dye test. Objective: The purpose of this work/sundry is to pump an MBE treatment (into both the OA sand and into the OB sand) and place well back on water injection. / Brief Procedure: V ✓ Pumping Procedure (STEPS#1-#30 to be completed for both the OA sand @ 7,844'&the OB sand @ 7,894'): 1. Production to SI offset producers up to 5 days prior to treatment(S-27/S-25). 2. Production to SI offset injectors up to 2 days prior to treatment(S-30i). ?06 3. MIRU Cement Pumping Unit and Little Red Pumping Unit. PT lines to 4,000 psi. [TREATMENT#1] P6 a. Setup fluid manifold to allowing switching over from Cement Unit to Little Red. Lel,•- av--4. Perform injectivity test w/8.5 ppg fresh water. a. Inject at 1.0 bpm or a max 1,000 psi for injectivity test. Do not exceed 1,250 psi. Com` 5. Mix and bullhead the following fluids with the Cementing Unit: a. +/- 10 bbl of 100 ppt HEC (hydroxy ethyl cellulose) lead spacer pill. b. +/- 15 bbl of 15.8 ppg acid soluble cement. c. +/-5 bbl of 100 ppt HEC(hydroxy ethyl cellulose)tail spacer pill. • • Well Prognosis Well: MPU S-31 Hilcarp Alaska,LL Date: 10/13/2017 d. Drop foam ball. 6. Mix and bullhead the following fluids with the Little Red Pumping Unit: a. +/-46.0 bbl of 1% KCL water. b. +/-20.0 bbl of diesel (freeze protection). i. Volumes above will over-displace cement into formation by 2.0 bbl. ii. Injection pressure may be increased to prevent leaving cement in tubing. 7. SD Pumps. Monitor wellhead pressures for 15 min (T/I/0). 8. RDMO Cement Pumping Unit and Little Red Pumping Unit. 9. WOC 48 hours. 10. MIRU Little Red Pumping Unit. PT lines to 4,000 psi. [INJECTIVITY TEST#1] 11. Mix and bullhead the following fluids: a. +/-5 bbl of 60/40 McOH/Water(to ensure injectivity). b. +/-54 bbl of 8.5 ppg sea water or until injection rate stabilizes (same rate as injectivity test). c. ***Contingency*** If unable to establish injectivity. i. Increase injection pressure, do not exceed 1,250 psi. d. +/-20 bbl of 60/40 McOH/Water(freeze protection; after stable injection achieved). 12. RDMO Little Red Pumping Unit. 13. Contingency: If unable to establish injectivity: a. MIRU Slickline. PT lubricator to 4,000 psi Hi 250 psi Low. b. RIH and tag cement top. POOH. c. RIH and bail cement. POOH. d. RIH w/dump bailer and spot 15% HCI acid to dissolve cement in tubing. e. Wait on acid minimum 4 hours (to dissolve calcium carbonate based cement). f. RIH and bail cement. POOH. g. RD Slickline. 14. Contingency: If residual cement exists: a. MIRU Coiled Tubing Unit and spot ancillary equipment. Fill source tank w/8.5 ppg seawater. b. Pressure test BOPE to 4,000 psi Hi 250 psi Low, 10 min each test. i. Test using 60/40 methanol or 8.5 ppg seawater. ii. Each subsequent test of the lubricator will be to 4,000 psi Hi 250 psi Low to confirm no leaks. c. RIH w/2.00" coil w/2-1/8" wash nozzle to cement top. Circulate well w/8.5 ppg seawater. d. Continue to RIH and cleanout cement to +/-7,923 MD(PBTD). e. RU to test injectivity thru the tubing tail. Do not exceed 3,500 psi. POOH. 15. Contingency: If unable to cleanout cement w/wash nozzle. a. RIH w/2.25" OD mill, 2-1/8" motor, and oil jars and cleanout cement to+/-7,923 MD (PBTD). b. RU to test injectivity thru the tubing tail. Do not exceed 3,500 psi. POOH. 16. Contingency: If able to cleanout cement but unable to establish injectivity. a. RIH w/2-1/8" wash nozzle to+/-7,923 MD (PBTD). b. RU acid pumping unit. RU lines to pump down coil tubing. PT lines to 4,000 psi. c. Mix and pump 5-10 bbl of 15% HCI acid. Displace acid w/8.5 ppg seawater. POOH. d. RD acid pumping unit. RU return lines to acid returns tank. e. Wait on acid minimum 4 hours (to dissolve calcium carbonate based cement). f. Circulate acid out of well pumping 8.5 ppg seawater. g. RU to test injectivity thru the tubing tail. Do not exceed 3,500 psi. POOH. 17. Contingency: If unable to establish injectivity test after HCI soak, repeat Step#16[a-g]. 18. MIRU Cement Pumping Unit. PT lines to 4,000 psi. [TREATMENT#2] 19. MIRU Little Red Pumping Unit. PT lines to 4,000 psi. • • Well Prognosis Well: MPU S-31 Hileorp Alaska,LI) Date: 10/13/2017 20. Fluid-pack and maintain tubing pressure on offset wells (MPU S-27 & MPU S-25). 21. Mix and bullhead the following fluids with the Cementing Unit: a. +/-5 bbl of 100 ppt HEC(hydroxy ethyl cellulose) lead spacer pill. b. +/- 10 bbl of 15.8 ppg acid soluble cement. c. +/-5 bbl of 100 ppt HEC(hydroxy ethyl cellulose)tail spacer pill. d. Drop foam ball. 22. Mix and bullhead the following fluids with the Little Red Pumping Unit: a. +/-46.0 bbl of 1% KCL water. b. +/-20.0 bbl of diesel (freeze protection). i. Volumes above will over-displace cement into formation by 2.0 bbl. ii. Injection pressure may be increased to prevent leaving cement in tubing. 23. Discontinue maintaining tubing pressure on offset wells (MPU S-27 & MPU 5-25). 24. SD Pumps. Monitor wellhead pressures for 15 min (T/I/O). 25. RDMO Cement Pumping Unit and Little Red Pumping Unit. 26. WOC 48 hours. 27. MIRU Little Red Pumping Unit. PT lines to 4,000 psi. [INJECTIVITY TEST#2] 28. Mix and bullhead the following fluids: a. +/-5 bbl of 60/40 McOH/Water(to ensure injectivity). b. +/-54 bbl of 8.5 ppg sea water or until injection rate stabilizes (same rate as injectivity test). c. ***Contingency*** If unable to establish injectivity. i. Increase injection pressure, do not exceed 1,250 psi. d. +/-20 bbl of 60/40 McOH/Water(freeze protection; after stable injection achieved). 29. RDMO Little Red Pumping Unit. 30. Turn well over to production. Attachments: 1. As-built Schematic 2. Coil BOPE Schematic 3. Fluid Flow Diagram-Acidizing • • Mime PointMP5-31 Unit • fli We : SCHEMATIC Last Completed: 5/15/2008 Hileora Alaska,LLC PTD: 202-014 Orig KB Elev.:73.54'/Orig GL Elev.:39.0TREE&WELLHEAD RKB Elev=29.68'(Do on 14) Tree 4-1/16"- 5M s Wellhead FMC 11"Gen 5 casing hanger.TBG Hanger:4-1/2" 20 .; _ f TC-II threads on top w/4"CIW'H'BPV Profile "4 Ili,9-5/8 W L ' .e, , = OPEN HOLE/CEMENT DETAIL 20" 260 sx Arctic Set(Approx.)in a 42"Hole 9-5/8" 62 bbls 10.7 ppg CemCrete in 7"x 9-5/8"annulus 7" 1,250 sx Class'G'in a 9-7/8" CASING DETAIL sao 1 Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 215/A-53/N/A N/A Surface 112' N/A 9-5/8" Intermediate 47/L-80/BTC 8.681" Surface 135' 0.0732 7" Production 26/L-80/BTC 6.276" Surface 8,133' 0.0383 TUBING DETAIL 3-1/2" Tubing 9.2/L-80/TC-II 2.992" Surface 7,931' 0.0152 WELL INCLINATION DETAIL KOP @ 571'to 941' Max Hole Angle=77.8 deg.@ 4,039' Hole Angle thru Perfs=40 deg. JEWELRY DETAIL No Depth Item 1 2,351' 3.5"HES'X'Nipple–ID=2.813 2 GLM DETAIL: MMG 3.5"X 1.5" 2 7,486' STA 6:Camco MMG 410 SS RK Latch w/DGLV(Set 5/22/08) 3 7,578' 3.5"HES'X'Nipple–ID=2.813 4 7,599' Baker 7"x 3.5"Premier Packer (Assembly C)-ID=2.88 iiti 3 5 7,625' STA 5:Camco MMG 410 SS RK Latch w/DGLV(Set 6/17/09) t:,...-I ?.1 4 6 7,663' STA 4:Camco MMG-W RK Latch w/DGLV(Set 11/21/13) = 7 7,725' Baker 7"x 3.5"Premier Packer (Assembly B)-ID=2.88 8 7,816' STA 3:Camco MMG-W RK Latch w/DGLV 9 7,844' STA 2:Camco MMG-W P-15 19/64"500 bwpd&RK Latch(Set 11/21/13) 5 10 7,878' Baker 7"x 3.5"Premier Packer (Assembly A)-ID=2.88 11 7,894' STA 1:Camco MMG-W P-15 19/64"500 bwpd&RK Latch(Set 8/07/15) 12 7,923' 3.5"HES'XN'Nipple w/PXN(Set 5/23/08)–Min ID=2.75 6 13 7,929' WLEG-Bottom @7,931' =NB s PERFORATION DETAIL RA Tag @ 1 I I 7 Sand Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Size 7,743--0‘qNB 7,679' 7,681' 3,843' 3,844' 2 7/22/2003 Open 2-1/2" OA 7,846' 7,876' 4,311' 4,331' 30 8/13/2002 Open 2-1/2" OB 7,900' 7,920' 4,364' 4,384' 20 8/13/2002 Open 2-1/2" 8 GENERAL WELL INFO r API:50-029-23066-00-00 E 9 (vt-(- Drilled by Nabors 27E-2/19/2002 1 =OA Sands Initial Completion by Doyon 141-8/14/2002 at Add NB Sand Perf-7/22/2003 "" Surface Casing Repair&Completion by Doyon 14 5/15/2008 "fit- 10 1 i i"7 fvt)3i OB Sands 1—'12 a,...... 13 7 L. .S ' `1 TD=8,143(MD)/TD=4,287'(TVD) PBTD=8,049'(MD)/PBTD=4,211'(1VD) Revised By:TDF 10/4/2017 • S • ll MILNE POINT UNIT COIL BOPS MPU S-31 I'demi)Alu-ku.LLC 10/13/2017 MPU S-31 20 X 9s% X 7 X 3% Coil Tubing BOP £-2 Lubricator to injection head 0 r l 2.00"Single Stripper II fI 41/1610M 3 _ — Blind/Shear Blind/Shear __ _4 y_ — -_ P 3 —___ � €= Blind/Shear Blind/Shear =5 --—_@ 0C ---i €= __ Slip Slip = / J e 3 —— - \/- -__ _—// €//_ _ Pipe Pipe _ _3 1 — - t Crossover spool 4 1/16 10M X 4 1/16 SM ,-t - -- ,E Pump-In Sub & ��• o J.( l � � 1502 Union I, t G x Manual Gate Manual Gate Crossover spool _ 2 1/8 5M 2 1/8 5M TIla 4 1/16 5M X 3 1/8 5M Valve,Swab,WKM-M, '" �`" �� 3 1/8 SM FE �r° Sl•`�� SFE ..OI�11411S. Ja'�e 31�$� i n NI :1:C°7•11 Valve,Upper Master,Baker, 3 1/8 5M FE,w/Hydraulic 0,0 Mt alS. 1111111111.1111111, S.1017=4 IS Valve,Lower Master,WKM-M, Pr o 3 1/8 5M FE is ii.Mi Tubing Adapter,3 1/8 5M 11 • . F. VI 8 W COX F.r- -1 1 D Z x L p G 1 W W o 0 0 n 0 R 'C 1 F > > > w D m2 N4m a x m 90 0 a .« NN R gg 10 © to47 f r r MI I j f z- o ,17 3 O_ tiE ■ ...3 r ' Rillitio_ii J... J s y y y m 'Q, $ o < m N C X w PSI < `°C a p O g a a 3 O3. ai g . —E,.E~ �.rigii, �, u, m m _ , ,,i ...,,, co > 73 3 0 w o to w .. .. _ ,... , . 0 • m 70 m m xi m p;C. o C m % 7 Q Q, Ocro N N a N ..:,... W C F. co cra o. A 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO Jim Regg � • l DATE: Wednesday,April 20,2016 P.I.Supervisor (� 9I 1/(& SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC S-31 FROM: Bob Noble MILNE PT UNIT SB S-31 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT SB S-31 API Well Number 50-029-23066-00-00 Inspector Name: Bob Noble Permit Number: 202-014-0 Inspection Date: 4/16/2016 Insp Num: mitRCNl60416170448 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well S-31 (Type Inj W lTVD 3857 ' Tubing 1170 1170 _ 1168 - 1168- PTD 2020140 _ Type Testi SPT Test psi i 1500 IA 307 2009 - 1969 _ 1960 . Interval °TSR - P/F j P ✓ OA 3 4 4 5 - Notes: Well on a 2 year test cycle. SCANNED SEP 2 7 2016 Wednesday,April 20,2016 Page 1 of 1 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 $ December 30, 2011 'FEB 4 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission Q 9- 0 H I; 333 West 7 Avenue O� Anchorage, Alaska 99501 S'. Subject: Corrosion Inhibitor Treatments of MPS -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPS -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPS -Pad 10/11/2011 Corrosion • Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft gal MPS-01A 2070340 50029231410100 0.25 NA 0.25 NA 5.1 9/6/2011 MPS-02 2031270 50029231690000 2.5 NA 2.5 NA 23.8 7/30/2011 MPS-03 2021460 50029231050000 Open Flutes - Treated MPS-04 2030520 50029231480000 1.7 NA 1.7 NA 17.0 7/30/2011 MPS-05 2021370 50029231000000 Open Flutes - Treated MPS-06 2031090 50029231630000 1.7 NA 1.7 NA 17.0 7/30/2011 MPS-07 2020720 50029230790000 1 NA 1 NA 13.6 11/3/2009 MPS-08 2031230 50029231680000 1.3 NA 1.3 NA 10.2 7/30/2011 MPS -09 2020200 50029230670000 0.5 NA 0.5 NA 5.1 11/3/2009 MPS-10A 2051250 50029231520100 1.3 NA 1.3 NA 11.9 7/29/2011 MPS -11 2021130 50029230920000 1 NA 1 NA 10.2 7/29/2011 MPS -12 2030230 50029231390000 0.6 NA 0.6 NA 6.8 7/29/2011 MPS -13 2021240 50029230930000 1 NA 1 NA 11.9 11/3/2009 MPS-14 2031040 50029231620000 1.8 NA 1.8 NA 22.1 7/29/2011 MPS -15 2012450 50029230610000 9.6 NA 9.6 NA 88.4 7/31/2011 MPS-16 2030650 50029231510000 1.2 NA 1.2 NA 10.2 7/29/2011 MPS -17 2021730 50029231150000 Open Flutes - Treated MPS-18 2022420 50029231330000 1.3 NA 1.3 NA 11.9 7/29/2011 MPS -19A 2022330 50029231210100 1.8 NA 1.8 NA 23.8 7/29/2011 MPS-20 2022410 50029231320000 1.3 NA 1.3 NA 11.9 7/29/2011 MPS-21 2020090 50029230650000 1.8 NA 1.8 NA 22.1 11/3/2009 MPS -22 2031470 50029231760000 9.1 NA 9.1 NA 83.3 7/28/2011 MPS-23 2021320 50029230980000 Open Flutes - Treated MPS-24 2030380 50029231420000 1.3 NA 1.3 NA 10.2 7/28/2011 MPS -25 2021030 50029230890000 Open Flutes - Treated MPS -26 2030610 50029231500000 1 NA 1 NA 8.5 7/28/2011 MPS-27 2020850 50029230840000 0.9 NA 0.9 NA 8.5 728/2011 MPS -28 2030940 50029231580000 1.1 NA 1.1 NA 11.9 7/28/2011 MPS -29 2021950 50029231190000 Open Flutes - Treated MPS-30 2022360 50029231310000 1.2 NA 1.2 NA 11.9 7/28/2011 - -' -) MPS -31 2020140 50029230660000 Open Flutes - Treated MPS-32 2030920 50029231570000 0.8 NA 0.8 NA 6.8 7/28/2011 MPS-33A 2061720 50029231230100 1 NA 1 NA 6.8 7/28/2011 MPS-34 2031300 50029231710000 6 NA 6 NA 49.3 7/28/2011 MPS-35 2031430 50029231750000 1.2 NA 1.2 NA 11.9 7/28/2011 MPS-37 2070520 50029233550000 13.9 Need top job NA MPS-39 2081830 50029234050000 0.7 NA 0.7 NA 4.3 8/18/2011 MPS -41A 2081610 50029234010100 Sealed NA NA NA NA NA MPS-43 2081760 50029234040000 Dust Cover NA NA NA 6.8 10/112011 MPS-90 2051350 50029232760000 0.6 NA 0.6 NA 3.4 9/6/2011 MPSB-04 500299990799 0.6 NA 0.6 NA 3.4 7/30/2011 MEMORANDUM To: Jim Regg ~~,~~ ' 3~ P.I. Supervisor ~~ 7 Z !Q FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, July 02, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 5-31 MILNE PT lJNIT SB S-31 Src: Inspector NON-CONFIDENTIAL Reviewed By: sn P.I. Suprv _J ~~ Comm Well Name: MILNE PT UNIT SB S-31 API Well Number: 50-029-23066-00-00 Inspector Name: Bob Noble Insp Num: mitRCN100607114316 Permit Number: 202-014-0 Inspection Date: 6/5/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min, 45 Min. 60 Min. --- - - Well 5-31 Type In~W ' TVD I P.T.D~ zozolao ~TypeTest I SPT' Test psi - ~-----L-----~ ~ -1 InterVal OTHER __ _ __ p/Ii _ - 3857 ~ IA zo zozo zozo OA ~ -~ P '~ TUbing 1300 ! 1300 190 - 1300 __ - 1970 1300 ~ -- Notes: 2 yr monobore UIC ./ ~j) Friday, July 02, 2010 Page 1 of 1 MEMORANDUM To: Jim Regg P.I. Supervisor ~~' ~'~~~~~~ FROM: Bob Noble Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Thursday, June 10, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 5-31 MILNE PT iJNIT SB 5-31 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~ Comm Well Name: MILNE PT UNIT SB 5-31 Insp Num: mitRCN100607114316 Rel Insp Num: API Well Number: 50-029-23066-00-00 Inspector Name: Bob Noble permit Number: 202-014-0 Inspection Date: 6/5/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well S31 'Type Inj. ' w ' TVD ~- -~- 2020140~i SPT P.T.DI. ~TypeTest~_Testpsi - sass ~ IA ~ ~ 2020 I OA _~ g zo zozo ~~ 19~o I ls7o ~- - i __ __ i_ Interval OTHER p~ P '' Tubin ~-- 1300 ~ 1300 1300 1300 -- ~-- Notes: 2 yr monobore UIC ~,:.:~~~1'w:;.p,. „Eli .)~`',f, Thursday, June 10, 2010 Page 1 of 1 • Page 1 of 1 Maunder, Thomas E (DOA) From: McLellan, Bryan J [Bryan.McLellan@bp.com] Sent: Thursday, June 19, 2008 1:27 PM To: Reem, David C; Maunder, Thomas E (DOA) Subject: RE: MPS-31 (202-014) Tom, The rig tested to the minimum required by the regs, which in this well is 1500 psi. The well TD is only 4287' TVD. This test pressure was reflected in the Scope of Work on the Sundry application, Sundry # 308-157. When the rig tested above the RBP to 2000 psi, it was to provide a bit of extra comfort room to be sure it would pass to 1500 for the final MITIA. I assume the AOGCC witnessed test to 1750 psi was just to provide an extra margin above the minimum required by the Sundry, however I am not certain about the reasoning behind that. When the application for Sundry was submitted, the condition of the casing below the casing repair was uncertain, hence the desire not to have an excessive test pressure. During the RWO, a USIT log was run to determine external metal loss on the casing. From the log data, the remaining casing looks to be in relatively good shape. Feel free to give me a call to discuss Thanks Bryan McLellan 564-5516 440-7964 cell ~~,~,~ ~uN ~ a Zoos From: Reem, David C Sent: Thursday, June 19, 2008 11:06 AM To: McLellan, Bryan J Subject: FW: MPS-31 (202-014) Bryan, please help answer Tom's questions below. Thanks. From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, June 19, 2008 10:10 AM To: Reem, David C Subject: MPS-31 (202-014) Dave, Not sure this was "your" well, but I am reviewing the 404. When the new completion was run (5/15/08), the packers were set and tubing tested to 4200 psi. The IA was only tested to 1500 psi. Subsequently the witnessed MIT was done to 1750 psi. Based on reviewing prior injection completions, I thought that IA pressure tests were to a minimum of 3500 psi. When the few new joints of 7" were run, the casing above the RBP was tested to 2000 psi. It seems that there are a variety of test pressure values. Could you comment? Thanks in advance. Tom Maunder, PE AOGCC 6/19/2008 STATE OF ALASKA 6'~~'~~ ALA OIL AND GAS CONSERVATION COM~SION SUN ~ ~ Z~U~ REPORT OF SUNDRY WELL OPERATIONS Alaska Oi! ~ Gas Cons. Cafnl-nission 1. Operations Performed: ^ Abandon ®Repair Well ~ ^ Plug Perforations ^ Stimulate ®Re-Enter Suspended Well ® Alter Casing ®Pull Tubing ~ ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 202-014' 3. Address: ®Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23066-00-00 7. KB Elevation (ft): 73.54 9• Well Name and Number: MPS-31- 8. Property Designation: 10. Field /Pool(s): ADL 380109 Milne Point Unit / Schrader Bluff 11. Present well condition summary Total depth: measured 8173 feet true vertical 4287 ~ feet Plugs (measured) N/A Effective depth: measured 8132 feet Junk (measured) N/A true vertical 4278 feet Casing Length Size MD ND Burst Collapse Structural Conductor 78' 20" 112' 112' 1490 470 Surface 135' 9-5/8" 135' 135' 6870 4760 Intermediate Production 8133' 7" 8133' 4279' 7240 5410 Liner ~~~1ii~E®JUN 2 0 200$ Perforation Depth MD (ft): 7679' - 7920' Perforation Depth TVD (ft): 3916' - 4106' 3-1/2", 9.2# L-80 7931' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 3-1/2" Baker Premier Packers 7599'; 7725'; 7878' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Pull Tubing, Cut 7" casing -119'. Run 9-5/8" Surface ca sing to -135'. Run 7" tieback & cement both annuli w/ 62 Bbls DeepCrete 348 cu ft / 91 sx . Run new tubin . 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation:. 0 Subsequent to operation: 708 (Prod Wtr) 850 0 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 if C.O. Exempt: Contact Bryan McLellan, 564-5516 ^QCjs 308-157 Printed Na Sondra Stewman Title Drilling Technologist ~-~ Prepared By Name/Number: -~ ignature Phone 564-5743 Date 1~i ondra Stewman 564-4750 Form 10 Revised 0412006 Submit Original Only oRi~oNA~ ~' ~~JUN19100B ~~~ Tree:Cameron 4-1/16",`~I Wellhead: FMC 11" gen 5 casing hanger. TBG Hanger - 4-1/2" TCII Threads on top w/ 4" CIW "H"BPV Profile 20"x 34" insulated, 215 #/ft A-53 113' 9-5/8" 47 ppf, L-80 BTC csg 135' MPU S-31i Orig. DF Elev. = 73.54` Orig. GL Elev. = 39.00` 7" x 9-5/8" annulus and 9-5/8" x 20" annulus' Both fully cemented 3.5" HES X-Nipple (2.813") 2351' ' KOP C~3 571 ` to 941' Max. hole angle = 77.8 deg C~ 4039 Hole angle thru' perfs = . 3.5" x 1.5" MMG 410 SS GLM 7487' 3.5", 9.2 ppf, L-80 IBT but. Tbg. (cap. = 0.0087 bpf, drift = 2.867") 7" 26#, L-80, BTRC Casing (drift ID = 6.151, cap.= .0383 bpf) 3.5" HES X-Nipple (2.813") 7578' 7" x 3.5" Baker Premier packer 7599` 3.5" x 1.5" MMG 410 SS GLM 7625' 3.5" x 1.5" MMG-W GLM 7663' I 7" x 3.5" Baker Premier packer 7725' I 3.5" x 1.5" MMG 410 SS GLM 7816' I 3.5" x 1.5" MMG-W GLM 7844' I I Perforation Summary ~ SWS Slim Cement bond log dated 8 March 02 Size Spf Interval (TVD) NB Sands 2.5" 2.5 7679`-7681' 3,843' - 3,844' OA Sands 2.5" 4 7,846'-7,876' 4,311' - 4,331' OB Sands 2.5" 4 7,900'-7,920' 4,364' - 4,384' 7" x 3.5" Baker Premier packer 7878' ' 3.5" x 1.5" MMG-W GLM 7894' Irte ,~ 3.5" HES XN-Nipple 2.813 Pkg. 7623' (No-Go 2.75" id ) 3.5" WELG 7929' 2.5" 2506 Powerjet, HMX 4spf deep penetrating chg 7" H II'b rt n Float Collar 8049` a I u o 7" Halliburton float shoe 8133` DATE REV. BY COMMENTS ILNE POINT UNIT 02/20/02 M. Linder Drilled by Nabors 27-E M WELL No.: S-31 i 8/16/02 MDO Initial Completion Doyon 141 / Perfs API : 50-029-23066-00 Lind r M Add NB d rt i t l 7/22/03 . e san pe n erva 5/15/08 REH Surface Csg Repair/ re-complete by Doyon-14 BP EXPLORATION (AK) Digital Well File • Well: MPS-31 Well History Well Date Summary MPS-31 3/27/2008 ***ARRIV ON LOC WELL S/I*** RIH W/ 2.65 CENT 2 'WB AND GS CORE AND EO. PRONG TAG PLUG @ 7643 SLM EO.PLUG. RIH W/ 3.5 GR W/ STEEL PIN ***CONT ON 3/28/08*** MPS-31 3/28/2008 ***CONT FROM 3/27/08*** PULLED XXN PLUG FROM 7643 SLM GOT BACK SAND IN PLUG RAN BHPS MADE 3 HOURS STOP C~ 7886 TAG. TD. ~ 7893 MADE 30 MIN STOP C~ 7374 RAN 2.813 XXN PLUG SET @ 7643 SLM PRESSURE UP 1000 PSI FOR MIT-T GOOD TEST BLEED OFF TUBING TO 100 PSI. ***JOB COMPLETED WELL S/I *** MPS-31 3/28/2008 (Assist Wireline) T/1= 0/0 Pump 70 bbls diesel down TB to displace for Wireline. FWHP= 600/0 (Wireline on well ~ departure ) MPS-31 3/29/2008 ***CONT FROM 3/28/08***PULL AND SET PLUG MlT-T GOOD TEST R/D EQUIPMENT MORE OVER TO NEXT WELL. ***WELL S/I *** MPS-31 3/30/2008 INITIAL WHP 0/0/0. CORRELATE TO TUBING SUMMARY 08/14/2008. 2.5" POWER CUTTER SF~„QT 7' ABOVE X-NIP. CCL DEPTH 7594.7' FOR CUT AT 7601' LOG ADDITIONAL COLLARS AND POOH. COULD NOT DESCEND PAST XNIP AT 7608,. USED PDS LOG TO CONFIRM DEPTH AND COMMUNICATED PERMISSION TO SHOOT KNOWING THAT NO JEWELRY WAS TIED INTO. FINAL WHP 250/0/0. MPS-31 3/31/2008 Well Support Techs set BPV, pulled well house and flow line. ***NOTE*** BPV left in hole MPS-31 4/6/2008 T/IA= SSV/0 Temp=cold PPPOT-T (PASS) (Pre RWO) PPPOT-T RU 2 HP bleed tools onto THA 100 psi to 0 psi, flush void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 5000/ 15 minutes, 5000/ 30 minutes. Bleed void to 0 psi, RD test equipment, re installed Alemite caps. Cycle and torque LDS "ET style" all moved with no problems. MPS-31 4/17/2008 (Heat source water to thaw ice in tank) Pumped 90 bbls produced water into tank to thaw ice. Performed shut down drill with PE. MPS-31 4/18/2008 Freeze Protect (Post Rig) -Pumped tbg w/67 bbls diesel to freeze protect for rig. MPS-31 4/27/2008 T/1=BPV/0. (CMIT TxIA post RWO IA patch).~MIT TxIA to 500 osi. Passed. Tba has BPV installed. Lost 40 psi in first 15 minutes due to thermal. Lost 10 psi in second 15 minutes & 10 psi in third 15 minutes. Total loss for 30 minute MIT is 20 psi. Bleed IA pressure down to 0 psi. FWHP=BPV/0. MPS-31 5/15/2008 T/I/0=0/0/0 (Freeze protect post RWO) Pumped 85 bbls Diesel down IA while taking returns up the tubing to rig pits. U-tubed IA to tubing for 1 hour. Continued on 05-16-08 WSR. MPS-31 5/16/2008 Continued from 05-15-08 WSR. (Freeze protect post RWO) Pumped 1 bbl to pressure test BPV. TEST GOOD. FWHP=O/0/0 MPS-31 5/18/2008 The Well Support Techs rigged up and set the foundation, flowline and the wellhouse. They then pulled the BPV and leak tested the flowline to NOTE: The BPV was left OUT and the leak test was GOOD. MPS-31 5/21/2008 ****WELL S/I ON ARRIVAL**** (post rig) TREE CAP SCAFFOLDING LADDER TO SHORT AFTER RWO. SUPPORT TECHS FIX, RUNNING IN HOLE W/ 2.60 BELLGUIDE W/ 2" JDC FOR BALL AND ROD ***CONT ON WSR 5-22-08*** MPS-31 5/22/2008 ***CONT FROM WSR 5-21-08*** (post rwo) PULL BALL AND ROD FROM 7923' MD , _ PULL RK-DCR-SHEAR VALVE FROM STA #6 @ 7486' MD, SET RK-DGLV IN SAME. RAN 2.78" CENT, SS, DUAL SPARTEK GAUGES, 2 HOUR STOP C~3 7907' SLM (7922' MD), 15 MIN STOP C~3 7522' MD. PULL RK-DGLV, SET RK-P-15 IN STA #1 C~3 7894' MD ***CONT ON WSR 5-23-08*** Page 1 of 2 http://digitalwellfile.bpweb.bp.coin/WIInfo/Reports/ReportViewer.aspx 6/16/2008 Digital Well File Page 2 of 2 MPS-31 5/23/2008 MPS-31 5/27/2008 MPS-31 6/1 /2008 Print Date: 6/16/2008 ***CONT FROM WSR 5-22-08*** (post rwo) PULL RK-DGLV, SET RK-P-15 (395 BWPD) IN STA #2 C~3 7844' MD. rn iii n o~ni~ nun ~ ~nnn~ non o~T n o~n~~ ovni of i in onnv ~ ~nnn~ *** WELL LEFT S/I *** ««««««2.813" PXN SET C~ 7924' MD»»»»»»»»» T/1= 680/260. AOGCC MIT IA to 1700 psi PASSED (witnessed by B. Noble). Lost 50 psi in first 15 minutes & 20 psi in second 15 minutes. Bleed IA pressure down to 230 psi. FWHP=680/230. IA Bleed. New Injector. Beginning T/I/O 720/500/NA Well Support Techs bled the IA down from 500 psi to 100 psi in about 2 minutes. < 1/2 bbl diesel returned to the surface. Ending T/I/O 720/100/NA Page 1 of 1 http://digitalwellfile.bpweb.bp.com/WIInfo/Reports/ReportViewer.aspx 6/16/2008 BP EXPLORATION Page 1 of 22 Operations Summary Report Legal Well Name: MPS-31 Common W ell Name: MPS-31 Spud Date: 2/13/2002 Event Nam e: WORKO VER Start : 4/30/2008 End: Contractor Name: DOYON DRILLIN G INC . Rig Release: 5/16/2008 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours Task ' Code NPT Phase Description of Operations 4/10/2008 14:00 - 16:30 2.50 RIGD P PRE -RD rig floor -Skid rig floor to moving position. -Move rig off well B-10 -Install boosters 16:30 - 19:00 2.50 MOB N WAIT PRE Wait on Security 19:00 - 19:30 0.50 MOB N WAIT PRE Waiting and PJSM w/ Security 19:30 - 00:00 4.50 MOB P PRE Moving rig f/ well B-10. -Rig passed Frontier Corner at report closing. 4/11/2008 00:00 - 12:00 12.00 MOB P PRE Cont. moving rig f/ Frontier Corner to 1 mile into Milne Point road. 12:00 - 17:00 5.00 MOB P PRE Cont. moving rig to Milne Point S-pad 17:00 - 19:00 2.00 MOB P PRE -Spot rig over well MPS-31 -Shim rig 19:00 - 22:00 3.00 RIGU P PRE -Skid rig floor -RU rig floor -Spot and berm rock washer -Spot tiger tank Acce t ri C~3 19:00 hr 3 hours earlier to compensate for NPT waiting on security 22:00 - 00:00 2.00 WHSUR P DECOMP -RU lubricator. Test to 500 six min -Pull BPV 4/12/2008 00:00 - 01:00 1.00 WHSUR P DECOMP RU tree to displace freeze protect: install pump in flanges, low torque valves and high pressure hoses 01:00 - 03:00 2.00 WHSUR P DECOMP Wait on Support Crew to RU hard line to tiger tank. -Support Crew pulling TWC at rig N-3S -Take on seawater in pits 03:00 - 04:00 1.00 WHSUR P DECOMP RU hard line to tiger tank 04:00 - 05:00 1.00 WHSUR P DECOMP -Blow air and steam through hard line. -Test hard line to 3,500 psi. Good test -Blow down hard line 05:00 - 06:30 1.50 WHSUR P DECOMP -Pump 40 bbls soap pill down tubing taking returns out annulus to tiger tank -Cont. circulating down tubing taking returns out annulus to tiger tank w/ seawater, displacing freeze protect out. Circulate total 280 bbls seawater. 6 bpm / 2130 psi 06:30 - 08:00 1.50 WHSUR P DECOMP -Allow diesel to migrate for 30 min. Pump additional 20 bbls of seawater. -Blow down lines. RD lines to tree 08:00 - 09:00 1.00 WHSUR P DECOMP Verif w II 09:00 - 10:00 1.00 WHSUR P DECOMP -RU to test TWC -Test TWC f/ above to 3 500 six 10 min on chart. -RD testing equipment 10:00 - 11:00 1.00 WHSUR P DECOMP -ND tree -Get RKbs. Check XO on top of tubing hanger 11:00 - 12:00 1.00 WHSUR P DECOMP Hold ATP meeting w/ Milne Point personnel, rig crews and rig management. 12:00 - 15:30 3.50 BOPSU P DECOMP NU BOP. Install extension spool on choke line 15:30 - 16:30 1.00 BOPSU P DECOMP RU to test BOP 16:30 - 20:30 4.00 BOPSU P DECOMP Test BOP and related equipment per BP / AOGCC procedures and regulations. Test all components to 250 psi low - 3,500 psi high x 5 min each on chart. Test w/ 4" test joint. Test top rams w/ 4" and 3-1/2" test joints. Perform koomey test. Test witnessed by WSL and Tool / Tourpusher. Chuck Scheve, Printed: 6/10/2008 11:46:23 AM ~~ ~~ BP EXPLORATION Page 2 of 22 Operations Summary Report Legal Well Name: MPS-31 Common Well Name: MPS-31 Spud Date: 2/13/2002 Event Name: WORKOVER Start: 4/30/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 5/16/2008 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours Task Code NPT Phase Description of Operations 4/12/2008 16:30 - 20:30 4.00 BOPSU P DECOMP AOGCC rep, waived witness of test 20:30 - 21:00 0.50 BOPSU P DECOMP RD testing equipment 21:00 - 22:00 1.00 WHSUR P DECOMP Wait for XO needed for lubricator extension 22:00 - 00:00 2.00 WHSUR P DECOMP RU lubricator and lubricator extension to pull TWC 4(13(2008 00:00 - 01:00 1.00 WHSUR P DECOMP -Finish RU lubricator and lubricator extensions. Screw into tubing hanger -Test to 500 six 5 min on chart 01:00 - 01:30 0.50 WHSUR P DECOMP Pull TWC 01:30 - 02:30 1.00 WHSUR P DECOMP RD lubricator and lubricator extensions. 02:30 - 03:00 0.50 PULL P DECOMP PU 1 jt 4" DP and MU XOs 03:00 - 04:00 1.00 PULL P DECOMP -RIH and screw into tubing hanger -Back out LDS -Pull tubin han er to ri floor. Pull free w/ PUW 90k (block weight 50k) 04:00 - 05:00 1.00 PULL P DECOMP CBU 338 gpm / 850 psi. -Mobilize equipment to LD tubing to rig floor. 05:00 - 06:00 1.00 PULL P DECOMP -LD tubing hanger, 1 jt 4" DP and XOs -RU equipment to LD 3-1/2" tubing 06:00 - 14:00 8.00 PULL P DECOMP POOH and LD 3-1/2" 9.2# L-80 IBT tubin .Total jts LD: 249 + 3.31' cut off jt. -Flare ~ cut: 4 1/16" -4 1/8". Cut uniform. 14:00 - 15:00 1.00 PULL P DECOMP -RD tubing handling equipment and clear rig floor -Mobilize BHA tools to rig floor 15:00 - 15:30 0.50 WHSUR P DECOMP Install wear bushing 15:30 - 16:00 0.50 CLEAN P DECOMP MU BHA w/ 6-1/8" bit and 7" casing scraper 16:00 - 18:30 2.50 CLEAN P DECOMP RIH w/ 4" DP 1 x 1 to +/- 2,100' 18:30 - 19:00 0.50 CLEAN P DECOMP CBU, 210 gpm / 360 psi 19:00 - 21:00 2.00 CLEAN P DECOMP -PU and MU RTTS packer -Set RTTS acker ~ 64' COE +/- 30' below well head -PJSM on testing below packer. Secure area and access points around cellar and mezzanine. -Test below acker to 1,500 six 30 min on chart. Good test 21:00 - 22:00 1.00 CLEAN P DECOMP -Pull RTTS acker and LD same -Cont. POOH 22:00 - 22:30 0.50 DHB P DECOMP -LD bit and casing scraper -MU RBP 22:30 - 00:00 1.50 DHB P DECOMP -RIH w/ RBP -Set RBP: To ~ 1 996' / COE 2 -Rack back 1 stand 4" DP. -PUW 83k /SOW 83k 4114!2008 00:00 - 01:30 1.50 DHB P DECOMP Dum 24 sxs 1 200# of 20140 river n 01:30 - 02:00 0.50 DHB P DECOMP -Screw in top drive and pump 15 bbls ~ 42 gpm. -PU 1 stand 4" DP and tag sand ~ 1,944' 02:00 - 03:30 1.50 DHB P DECOMP -POOH f/ 1,944' to surface. -LD running tool. Clear rig floor 03:30 - 05:30 2.00 BOPSU P DECOMP -PJSM -Pull wear bushing -ND flow line and riser -ND BOP & choke line 05:30 - 06:00 0.50 W HSUR P DECOMP -Rackoff lock ring -Pull speed head loose 06:00 - 07:30 1.50 WHSUR P DECOMP -MU Wach's cutter -Cut casing head flange internally C~3 40" below speed head Printed: 6/10/2008 11:46:23 AM • BP EXPLORATION Page 3 of 22 Operations Summary Report Legal Well Name: MPS-31 Common Well Name: MPS-31 Spud Date: 2/13/2002 Event Name: WORKOVER Start: 4/30/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 5/16/2008 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours Task Code NPT Phase Description of Operations 4/14/2008 07:30 - 08:30 1.00 WHSUR P DECOMP -PU speed head -RD Wach's cutter -LD mandrel hanger and speed head 08:30 - 14:30 6.00 WHSUR P DECOMP -Attempt to PU 20" riser in one piece from behind cellar but it is too long. Hang riser inside cellar -Install diverter connectionx20" BOP flange and XO. Cut bottom 5' off riser, pull riser to rig floor -Install bottom 5' of riser on diverter connection XO, lower riser down to cut -Weld riser back together. -Install new cement line and flow line 14:30 - 15:00 0.50 FISH P DECOMP Mobilize BHA tools to rig floor 15:00 - 16:30 1.50 FISH P DECOMP MU washover BHA er Baker re : 12-1/4" x 10-3/4" washover shoe + 1 jt 11-3/4" washpipe + 11-3/4" Washover boot basket + 1 jt 8" DC. 16:30 - 18:30 2.00 FISH P DECOMP RIH and w shover rand 7" casin to I r 70' below rota table . -PUW 60k /SOW 60k / ROTW 60k -410 gpm/60-130 psi -40 RPM / 0-5k TO. WOB 5-8k 18:30 - 20:00 1.50 FISH P DECOMP -POOH and add one more jt 11-3/4" washpipe -Clean washover boot basket. Larae amount of cement 20:00 - 20:30 I 0.501 FISH I P I I DECOMP -PUW 62k /SOW 62k / ROTW 62k -510 gpm / 70-140 psi -40 RPM / 2-7k TO. WOB 5-8k 20:30 - 22:30 2.00 FISH P DECOMP Circulate hole clean. Pump a total of 7 Hi-vis sweeps with return of large amount of cement cuttings (last 2 pills show clean) -400-500 gpm / 6-70 psi. 40 RPM 22:30 - 23:30 1.00 FISH P DECOMP POOH and LD washover BHA. Boot basket cleaner than first run. 23:30 - 00:00 0.50 FISH P DECOMP Clear rig floor 4/15/2008 00:00 - 00:30 0.50 FISH P DECOMP Mobilize tools for next BHA to rig floor 00:30 - 01:00 0.50 FISH P DECOMP -MU ca in c : 5-1/2" Multi-string cutter + 6-1/8" stabilizer -MU 1 stand 4" DP 01:00 - 01:30 0.50 FISH P DECOMP -RIH to 79' elow r t to I 4 ' -Cut 7" casin 60 RPM. 195 gpm / 250 psi while cutting. 420 gpm / 250 psi after cutting. 01:30 - 02:00 0.50 FISH P DECOMP -Rack back stand 4" DP -LD casing cutter assy. -MU spear assy. 02:00 - 03:00 1.00 FISH P DECOMP -PU 1 jt 4" DP and RIH w/ spear assy. to +/-35' below rotary table -En a e fish (work couple of attempts) -Pull fish to ri floor 03:00 - 03:30 0.50 FISH P DECOMP -Release spear -LD fish: recover total 44.43' of 7" casing (1.17' top cut off + 40.93' full jt + 2.33' bottom cut off). Top cut clean, no flare (Wach's cutter). Bottom cut clean, flare to 7-1/4" (casing Printed: 6/10/2008 11:46:23 AM BP EXPLORATION Operations Summary Report Legal Well Name: MPS-31 Common Well Name: MPS-31 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date .From - To Hours ' Task Code NPT 4/15/2008 03:00 - 03:30 0.50 FISH P 03:30 - 04:00 I 0.50 I CLEAN I P 04:00 - 05:00 I 1.001 CLEAN I P Page 4 of 22 Spud Date: 2/13/2002 Start: 4/30/2008 End: Rig Release: 5/16/2008 Rig Number: 14 Phase ~, Description of Operations DECOMP cutter). Fish recovered shows small hole in middle of full it. DECOMP -Clear rig floor -Mobilize tools for next BHA to rig floor DECOMP -M 17-1/ " e i + bit sub + (3) 8" DCs -RIH while MU BHA to 77' (2' above casing 05:00 - 06:00 1.00 CLEAN P DECOMP -POOH. Break bit and bit sub -Rack back stand 8" DC -Mobilize tools for dress off BHA 06:00 - 08:30 2.50 FISH P DECOMP -MU dress off BHA: PU (2) 4-3/4" DCs + XOs + Washover Boot Basket. -Attempt to MU Washpipe extension. It has bad threads 08:30 - 09:30 1.00 FISH N WAIT DECOMP Wait for new washpipe extension 09:30 - 10:30 1.00 FISH P DECOMP Cont. MU dress off BHA 10:30 - 11:00 0 50 FISH P DECOMP k . -80 RPM / 1 k TO -PUW 52k /SOW: 55k / ROTW 55k 11:00 - 14:00 3.00 FISH P DECOMP -LD Dress off BHA tools. -Install XO assy on top of 8" DC stand so top drive can screw into the stand, in preparation for casing patch run. Rack back 8" DC stand. 14:00 - 14:30 0.50 FISH P DECOMP Clear rig floor 14:30 - 15:30 1.00 CLEAN P DECOMP -MU blank plug to bottom of 4" DP stand -RIH 15 stands of 4" DP with blind end to +/- 1,470' to displace seawater (aprox. 20 bbls) in preparation for casing patch run). 15:30 - 16:00 0.50 CLEAN P DECOMP POH and rack back 4" DP. Did not fill the hole while POH, leaving hole empty from surface to top of 7" casing stump ~ 45' below ground level 16:00 - 18:00 2.00 WHSUR P DECOMP ND 20" riser. -Vac out remaing seawater around 7" casing stump. 18:00 - 19:00 1.00 CASE P DECOMP RU to run 7" casing patch. 19:00 - 21:00 2.00 CASE P DECOMP -MU 7" casin patch + 7" 26# L-80 BTC casing pup jt + 7" 26# 21:00 - 21:30 I 0.501 CASE I P 21:30 - 23:00 I 1.501 WHSUR I P 23:00 - 00:00 1.00 WHSUR P 4/16/2008 00:00 - 02:00 2.00 WHSUR P -RIH casing patch assy. on one stand 8" DC for weight to top of 7" casing stump. PUW: 60k /SOW: 60k -Rotate on top of casing stump and swallow 3' in casing patch. Bottom out casing patch and slack off 25k -Pull 50k over PUW and confirm casin atch en a ed. Slack off back to neutral -Test casin atch to 1,500 six 10 min on chart. Good test. DECOMP Install 1" x 31' long tubing in 20" x 7" annulus for later cement top job DECOMP -Install emergency slips and set with 20k overpull on casing. -Cut & bevel 7" casing with Wach's cutter. Pull 5.02' cut off to rig floor. -Bottom of casing patch ~ 82' (48' below ground level). Top of DECOMP Prepare stump to weld transition nipple DECOMP -Position transition nipple -Burn HOT HED and heat welding area. Insulate Printed: 6/10/2008 11:46:23 AM BP EXPLORATION Page 5 of 22 Operations Summary Report Legal Well Name: MPS-31 Common Well Name: MPS-31 Spud Date: 2/13/2002 Event Name: WORKOVER Start: 4/30/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 5/16/2008 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours Task Code. NPT Phase Description of Operations 4/16/2008 00:00 - 02:00 2.00 WHSUR P DECOMP -Weld transition nipple using GBR welding services. -Burn second HOT HED and reheat welding. Insulate 02:00 - 10:00 ~ 8.00 WHSUR ~ P 10:00-12:00 I 2.001 WHSURIP 12:00 - 14:30 2.50 WHSUR P 14:30 - 15:00 0.50 WHSUR P 15:00 - 15:30 0.50 WHSUR P 15:30 - 16:30 1.00 WHSUR P 16:30 - 19:00 2.501 BOPSUp P 19:00 - 20:30 1.501 BOPSUp P 20:30 - 21:00 I 0.501 WHSUR I P 21:00 - 22:00 1.001 WHSUR ~ P 22:00 - 00:00 I 2.001 WHSUR I P 4/17/2008 100:00 - 06:00 I 6.001 WHSUR I P DECOMP Allow welding to cool down prior to installing starting head. -While waiting: strap and drift tubing for completion. Rig service and cleaning. DECOMP -Attempt to test transition nipple weld wl nitroaen per FMC -Wait on GBR welder to repair weld. Cont. rig service DECOMP GBR welder repair weld on transition nipple. DECOMP -Safety meeting with crew, Toolpusher, WSL, Operations Superintendent (J. Willingham) and Wells Manager (S. Rossberg). -GBR welder cont. working on transition nipple DECOMP Test weld on transition nipple w/.nitroaen to 2.200 psi x 1! DECOMP ~-Install tubing spool -Test void to 1,000 psi x 10 min per FMC DECOMP -NU BOP -Remove 1' extension spool f/ choke line. Install choke line DECOMP -RU to test BOP breaks -Test BOP breaks to 250 si w - x 5 min each on chart. -RD testing equipment. Pull test plug -Install wear bushing DECOMP -MU mule shoe on stand of 4" DP and RIH -Circulate hot seawater w/ charge pumps prior to cement top job DEGOMP -PJSM w/ Schlumberger on top job -Schlumberger batch mix 21 ~J~1,~15.8 ppa class G cement -Schlumberger pump 21 bbls 15.8 ppg class G cement down 1" x 30' i e installed in 20" x 7" annulus to 'ob . 5 bbls cement return to surface. Received cement return in receptacle while sucking at the same time from it with super sucker. No fluids drained to cellar. -Cont. circulating hot seawater in 7" casing while pumping top job. -CIP ~ 22:00 DECOMP -Cont. circulating hot seawater in 7" casing while waiting on cement to cure to 500 psi compressive strength. Estimated time to cure: 8 hrs 14 min per Schlumberger lab test -Cont rig service while waiting on cement. DECOMP Cont. waiting on cement to cure to 500 psi compressive -Cont. rig service while WOC. 06:00 - 06:30 0.50 WHSUR P DECOMP Rack back stand of 4" DP. LD mule shoe 06:30 - 07:00 0.50 WHSUR P DECOMP RU to test 7" casing and casing patch 07:00 - 09:30 2.50 WHSUR P DECOMP Attem t to test 7" casin and casin atcf -1st: pressure uo to 1.500 psi. Pressure Y then started to bleed off. Bled off 200 psi at the end of 30 min -2nd: pressure up to 1,500 psi. Pressure held for 7 min and then started to bleed off. Bled off 300 psi at the end of 30 min 09:30 - 10:00 0.50 WHSUR P DECOMP -RU to test casino patch from. ann_u_lus. Printed: 6/10/2008 11:46:23 AM BP EXPLORATION Page 6 of 22 Operations Summary Report Legal Well Name: MPS-31 Common Well Name: MPS-31 Spud Date: 2/13/2002 Event Name: WORKOVER Start: 4/30/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 5/16/2008 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours Task ', Code' NPT Phase Description of Operations 4/17/2008 09:30 - 10:00 0.50 WHSUR P DECOMP -Pressure u to 1 500 si f/ annulus. Pressure held for 5 r and then bled off 200 si at the end of 15 min. 10:00 - 10:30 0.50 WHSUR P DECOMP RD testing equipment. Blow down choke and kill line 10:30 - 11:30 1.00 WHSUR P DECOMP -Verify next steps with Workover team. -Wait on RTTS packer 11:30 - 12:00 0.50 WHSUR P DECOMP -Mobilize RTTS to rig floor -RIH 2 stands 4-3/4" DCs and 5 stands 4" DP to 657' 12:00 - 15:00 3.00 WHSUR P DECOMP -MU RTTS and set C~_82'_~COE), +/- 4' below initial casino -Pull RTTS and set ~~ `~ ~ Test below RTTS tc 15:00 - 16:00 1.00 WHSUR P 16:00 - 16:30 0.50 WHSUR P 16:30 - 17:00 0.50 WHSUR P 17:00 - 18:00 1.00 WHSUR P 18:00 - 18:30 0.50 WHSUR P -Bleed off ressure below RTTS. Kee RTTS t 7 ' (COE). Close to rams and test above RTTS to 1 500 si x min. Good test DECOMP -Pull RTTS to rig floor -POOH and rack back 4" DP and 4-3/4" DCs DECOMP MU mule shoe. RIH w/ 4" DP to 1,920' DECOMP CBU 2x, 210 gpm / 180 psi. Check seawater temperature in returns: 1.- 63 F at begining of circualtion 2.- 66 F at first bottoms up. 3.- 70 F at second bottoms up DECOMP POOH and rack back 4" DP DECOMP Pull wear bushing. 18:30 - 21:00 2.50 TA P SURE -Pull 3-1/2" tubing for completion and 4" DP out of pipe shed. -Shuffle 4" DP and 4-3/4" DC stands in derrick in preparation for rig move to well MPS-11 21:00 - 23:00 2.00 TA P SURE RU to run 3-1/2" kill strin 23:00 - 00:00 1.00 TA P SURE -Receive and load in pipe shed 3-1/2" 9.2# L-80 NSCT cond B tubing, pup jts, WLEG and X nipple for kill string -Drift and strap tubing 4/18/2008 00:00 - 03:00 3.00 TA P SURE -Cont drifting and strapping 3-1/2" 9.2# L-80 NSCT cond B tubing (kill string) -Strap jewelry: WLEG, X nipple, pup jts, tubing hanger 03:00 - 07:00 4.00 TA P SURE -MU tail pipe assy: WLEG + 3-1/2" 9.2# L-80 TCII pup jt + X nipple + 3-1/2" 9.2# L-80 TCII pin x NSCT box pup jt. -MU and RIH 3-1/2" 9.2# L-80 NSCT cond B tubing. Total jts run: 60 07:00 - 07:30 0.50 TA P SURE -MU tubing hanger, landing joint and XOs -Land tubing hanger. RILDS -LD landing joint and XOs -WLEG @ 1,934'. X ni le ~ 1,921' 07:30 - 09:00 1.50 WHSUR P SURE -In t I -Test f/ top to 3,500 psi x 10 min on chart. Test f/ below to 1 000 si on ch rt 09:00 - 10:30 1.50 BOPSU P SURE -Blow down lines to BOP stack. Suck out fuids f/ stack -ND BOP 10:30 - 13:30 3.00 WHSUR P SURE -NU adapter flange and tree (same original tree) -Test adapter flange to 5,000 psi x 15 min per FMC -Test tree w/diesel to 5,000 psi x 5 min per FMC 13:30 - 14:30 1.00 WHSUR P SURE -RU lubricator. Test to 500 psi x 5 min Printed: 6/10/2008 11:46:23 AM BP EXPLORATION Operations Summary Report Legal Well Name: MPS-31 Common Well Name: MPS-31 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To Hours Task Code NPT - _ _ ~- _-- 4/18/2008 13:30 - 14:30 1.00 WHSUR P 14:30 - 16:30 2.00 WHSUR P 16:30 - 17:00 0.501 WHSUR ~ P Page 7 of 22 Spud Date: 2/13/2002 Start: 4/30/2008 End: Rig Release: 5/16/2008 Rig Number: 14 Phase Description of Operations SURE -Pull TWC. Install BPV SURE -RU Little Red. Test lines to 2,200 psi -Pump 67 bbls of diesel down tubing, taking returns out IA. 2 bpm / 550 psi. Tubing and IA w/diesel from surface to 1,934' -Test BPV f/ below to 1,500 psi x 10 min w/diesel. Pressure bleeds slowly, but no fluid passing by BPV. SURE -Suck back lines. RD Little Red -Secure tree -Release rip ~ 17:00 4/30/2008 00:00 - 01:30 01:30 - 02:30 02:30 - 03:00 03:00 - 04:30 4:30 - 06:00 1.50 1.00 0.50 1.50 .50 MOB RIGU RIGU WHSUR HSUR P P P P P SURE PRE PRE WHDTRE HDTRE Move over well MPS -31 i. -Shim Rig in place. Skid Rig floor into position. Spot & berm Rockwasher. ~ 03:00 hrs accept Rig. -Call for: DSM to RU hardline, Choke & Tiger tank. -DSM to RU Lubricator & Pull BPV. -Hot Seawater on the way -RU in cellar. Install double IA valve DSM: Install and test Lubricator to 500 si / m n - -Pull BPV. RD Lubricator. 06:00 - 08:00 2.00 WHSUR P WHDTRE RU to circulate out freeze protect diesel. -Take on 8.5 ppg Seawater. Spot circ out tank. 08:00 - 10:00 2.00 WHSUR P WHDTRE Hard line crew: RU hardline, Choke & Tank. -Test lines w/Air - no leaks. Outside Choke manifold frozen. -Thaw out Choke manifold -steam hardline & manifold. -Blow down & tset lines to 3500 psi. -Test Gas alarms. Load 4" D. P. in pipe shed. 10:00 - 11:30 1.50 WHSUR P WHDTRE Pump 25 bbl Safe-kleen (soap) pill. -Pump 65 bbls of 8.5 ppg Seawater to circ out diesel. -Pump down Tbg up IA outside to Tiger tank. -Pump rate: 168 gpm / 330 psi. Wait 10 minutes. -Pump an additional 10 bbls out to Tiger tank. -Pump rate: 168 gpm / 350 psi. 11:30 - 12:00 0.50 WHSUR P WHDTRE RD circulating lines, valves & hoses. 12:00 - 13:00 1.00 WHSUR P WHDTRE RU to set TWC. Set TWC. RD running tool. 13:00 - 14:00 1.00 WHSUR P WHDTRE RU to test TWC. -T t TW fr v t si / 10 in t - -RD test equipment. 14:00 - 20:00 6.00 WHSUR P WHDTRE ND Tree & Adaptor flange. -Test run 4 1/2" IF X 4 1/2" TCII XO to landing jt = 8 turns. -NU 13 5/8" 5000# Stack. -C/O Choke hose extension to 18" from 24". -Install Riser, Hole fill line, Bleed off line & Turn buckles. ----BOP Configuration: -Hydril GK 13 5/8" 5000. -3 1/2" X 6" Variables. -Blind Rams. -Drilling Spool. -2 7/8" X 5" Variables. 20:00 - 22:00 2.00 WHSUR P WHDTRE RU to erform BOP Bod test. -Attempted Body test several times -Fail. -RD test equipment. LD test jt. -Prepare to C/O Hydril Bag element. Printed: 6/10/2008 11:46:23 AM • • BP EXPLORATION Operations Summary Report Page 8 of 22 ~ Legal Well Name: MPS-31 Common Well Name: MPS-31 Spud Date: 2/13/2002 Event Name: WORKOVER Start: 4/30/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 5/16/2008 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours Task Code ~ NPT - - _ _- 4/30/2008 22:00 - 00:00 2.00 WHSUR P 5/1/2008 100:00 - 12:00 12.001 WHSUR P 12:00 - 14:30 I 2.50 I W HSUR I P 14:30 - 15:30 I 1.001 WHSUR I P 15:30-16:30 I 1.OOIWHSURIP 16:30 - 17:00 0.50 WHSUR P 17:00 - 20:30 3.50 WHSUR P 20:30 - 22:30 I 2.001 WHSUR I P Phase Description of Operations WHDTRE ND Riser, Flow line, Hole fill line, Bleed off line. -Held PJSM on C/O Hydril Element. -MU Potato Masher, XO & 1 jt 4" D.P. WHDTRE Continue to attempt to change out Hydril element. -Attempting to break seal on bonnet without success. -Decison made to C/O Hydril. WHDTRE Remove Stack yolk. Label & remove Koomey lines. -Remove lower Choke connection & Annulus valve. -Remove Kill line. -Disconnect: Hydraulic lines, Hole fill line & Bleed off line. -Disconnect lines under Rig floor: Mud bucket line, -Steam, Water & Air lines. Unload 4" D.P. from pipe shed. -Remove all fluid from pits. Unplug Top Drive & Pason. -Prepare to skid Rig floor. WHDTRE PJSM on skidding Rig floor. Skid Rig floor. -Empty and move Rock washer. WHDTRE Move Rig off well MPS-31 i. C/O Hydril. -Remove Old Tree from cellar. -Spot Rig back over well MPS-31 i. WHDTRE Skid Rig floor back into position. Re-spot Rock washer. WHDTRE NU Hydril. -Install: Yolk on Stack, Bell nipple, Riser, Flow line, -Bleed off line, Hole fill & Turn buckles. -Hook up: All Koomey lines, Kill line & Choke line. -Connect all service lines to and under Rig floor. -Load pipe shed with 4" D.P. -Take on fluids back into Pits.. -Install Annulus valve & energize Koomey. WHDTRE Install 4" test jt. Fill all lines with water. -RU test equipment. Flex Hydril element to break in. -Perform BOP body test. 22:30 - 00:00 1.501 WHSUR ~ P -Test witness waived by AOGCC Lou Grimaldi. -Test witnessed by T.P. & W.S.L. -All tests are 250 psi low pressure / 3500 psi high pressure. -All tests were charted. -BOP configuration: ---BOP Configuration: -Hydril GK 13 5/8" 5000. -3 1/2" X 6" Variables. -Blind Rams. -Drilling Spool. -2 7/8" X 5" Variables. 5/2/2008 100:00 - 03:30 3.501 BOPSUp P -Test with 4" test jt: -Test Bag, Upper & Lower Rams & Choke valves. DECOMP Continue to test BOP's. -Test IBOP's & Floor valves. -Test Upper & Lower Rams with 3 1/2" test jt. -Koomey test was: 32 seconds for 200 psi increase. -Total pressure build back to 3050 psi was 2 min 46 seconds. -4 bottles ~ 2200 psi. Printed: 6/10/2008 11:46:23 AM • BP EXPLORATION Page 9 of 22 Operations Summary Report Legal Well Name: MPS-31 Common Well Name: MPS-31 Spud Date: 2/13/2002 Event Name: WORKOVER Start: 4/30/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 5/16/2008 Rig Name: DOYON 14 Rig Number: 14 Date i From - To ~ Hours Task Code NPT Phase Description of Operations 5/2/2008 ~ 00:00 - 03:30 3.501 BOPSU P DECOMP -All test were 250 psi low psi / 3500 psi high pressure. 03:30 - 04:00 0.50 BOPSUF~ P 04:00 - 05:30 1.50 PULL P 05:30 - 10:30 I 5.00 I PULL I P 10:30 - 11:30 1.001 PULL P 11:30 - 13:00 I 1.501 PULL I P 13:00 - 14:00 I 1.00 I PULL I P 14:00 - 17:30 3.50 PULL P 17:30 - 18:30 1.00 PULL P 18:30 - 00:00 5.50 PULL P 5/3/2008 100:00 - 03:00 I 3.001 PULL I P 03:00 - 04:30 1.50 PULL P 04:30 - 05:30 1.00 PULL P 05:30 - 06:30 1.00 PULL P 06:30 - 07:00 0.50 PULL P 07:00 - 08:00 1.00 PULL P -All tests were charted for 5 minutes. -All test were a Pass. -Tests witnessed by T.P & W.S.L. -Witness waived by AOGCC -Lou Grimaldi. DECOMP RD all BOP test equipment. DECOMP RU to cut drilling line. Cut off 59.5' of drilling line. -Service Rig. - RD, clean up. DECOMP DSM RU 6" Lubricator. -DSM could not retrieve TWC through 6" lubricator. -RD lubricator. -RU Lhaso Apso and 5 1/2" extensions. -Pressure test to 500 psi -Good test. -Attem t to ull TWC - No success. _Channo ratriavinn tnnl - Pnll TWC_ DECOMP LD lubricator extensions -PU 4" DP w/ TCII XO. -Screw in to hanger w/ 8 turns. -Check pressures -BOLDS. -Pull hanger free w/ 65k. -Pull to rig floor w/ 64k up wt. DECOMP Screw in Top Drive. -Circulate surface to surface w/ 168 gpm / 40 psi. -Mobilize tubing equipment to rig floor. DECOMP RU to LD 3 1/ N T t in . -Change Elevators & Bales: -RU compensator. -Seawater wt= 8.5 ppg. DECOMP PJSM on LD Tbg. -LD 3 1/2' NSCT tubing -Recovered 60 jts + 2-Pups (9.78' & 2.0') & W LEG (1.31'). -Hole fill= 8.5 bbls. Calc hole fill= 6.5 bbls. DECOMP RD & LD Csg equipment & Tongs. C/O Bales & Elevators. -PU Extensions for Lubricator. DECOMP PJSM on RU & run USIT log. -PU & RU Extensions, Pump-in sub & Lubricator. -PU Preventers. -PU & RU Line wiper packoff. -Test to 500 psi -Pass. -Attempt to get tool communication from 21:30 to 23:30. --Run USIT log. DECOMP Lo USIT from 1 920' -Apply 200 psi on 7" Csg while to in from 400' u to surface. -Repeat run in Hi resolution from 1,100' and to surface. -Apply 200 psi on 7" Csg while logging from 400' up to surface. -Complete USIT logs. DECOMP RD SLB E-line equipment (Tools, Sheaves &Preventers). DECOMP Blow down & Nipple down Riser, Flow line & BOP's. DECOMP Back off Lock Ring. Remove Wellhead. DECOMP Weld 20" X 7" slip segments together. Weld Slips to 7" Csg. DEGOMP Install Conductor adaptor X 20" flange. Printetl: 6/10/2008 11:46:23 AM • '~ BP EXPLORATION Page 10 of 22 Operations Summary Report Legal Well Name: MPS-31 Common Well Name: MPS-31 Spud Date: 2/13/2002 Event Name: WORKOVER Start: 4/30/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 5/16/2008 Rig Name: DOYON 14 Rig Number: 14 Date From - To i Hours ' Task Code NPT Phase Description of Operations 5/3/2008 07:00 - 08:00 1.00 PULL P DECOMP -MU Riser flange to Conductor adaptor. 08:00 - 09:00 1.00 PULL P DECOMP Lower & align Riser. Install Flow line. Weld riser. -PU 8" D.C's. 09:00 - 10:00 1.00 PULL P DECOMP MU two 8" D.C's w/ 4" HT 38 single on Top. -Rack back in derrick. 10:00 - 10:30 0.50 PULL P DECOMP MU 7" Multi-Strina cutter assv. MU Too Drive. 10:30 - 11:00 0.50 PULL P DECOMP Make cut ~ 40' below RKB: ~ 40 RPM. -Stage pumps up from 105 gpm / 170 psi to 189 gpm / 710 psi -Saw pressure decrease from 710 psi to 300 psi. -POH LD cutter. 11:00 - 12:00 1.00 PULL P DECOMP MU Spear, Engage stub. -Attem t to ull 10k over - No-go. -Release, POH, LD Spear. Blow down Top Drive. 12:00 - 14:00 2.00 PULL P DECOMP PJSM. Knock Ice from derrick. -ND flow line, Turnbuckles, Hole fill line, Bleed off line & Riser. -Attem t to ull cut with Brid a crane - No- o. -Re-nipple up Riser, Flow line, Hole fill & Bleed off line. -Hook up Turnbuckles. 14:00 - 17:30 3.50 PULL P DECOMP MU Spear, Engage stub. Attemp to pull cut. -PU 10k to 50k - No- o. Attem t t release from S -Work Spear & release. Disengage and turn Spear. -Spear grabs when picking up. -Work & rotate Spear until release. POH. LD Spear. 17:30 - 18:30 1.00 PULL P DECOMP MU cutter. RIH. Find same cut. Cut larger section. -b0-6- RPM / 105 gpm / 120 psi. Stage up pumps to 710 psi. -Observe pressure decrease to 220 psi. POH w/cutter. 18:30 - 20:30 2.00 PULL P DECOMP ND Flow line, Riser, Hole fill, Bleed off line & Turnbuckles. -Cut lifting holes in Transition bowl. -Pull bowl & Stub with Brid a crane & LD Stu -Cut 't len th 5.80' with trace cement rin on 4.7' on Stub. 20:30 - 22:30 2.00 PULL P DECOMP NU Riser, Flow line, Hole fill, Bleed off line & Turnbuckles. -PU Baker BHA to Rig floor. 1 jt Washpipe, Drive sub, two 8" D.C's. -PU one jt of 4" D.P. PU & Install false bowl. 22:30 - 00:00 1.50 PULL P DECOMP Start washin over ~ 35' to u . -300 gpm / 80 psi. PUW 60k, SOW 60k, ROT wt 60k. -Free tq ~ 40 RPM= 0. 5/4/2008 00:00 - 00:30 0.50 PULL P DECOMP Continue to Washover from 36' to 37' md. -RPM 60, Tq 1 k. 300 gpm / 80 psi. 00:30 - 01:30 1.00 PULL P DECOMP Pull up. LD one 8" D.C. & 4" D.P. Assy. -MU 5" pup on 8" D.C. 01:30 - 02:30 1.00 PULL P DECOMP RIH, continue to washover from 37' to 43' md. -PUW 56k, SOW 56k. 300 gpm / 80 psi. 02:30 - 03:00 0.50 PULL P DECOMP Pull up. -PU one more 8" D.C. for stabilization and weight transfer. 03:00 - 05:30 2.50 PULL P DECOMP Continue to washover 7" casin from 43' to 47' m -Pump Hi Vis Sweep (YP-39). -PUW 60k, SOW 60k. 05:30 - 06:00 0.50 PULL P DECOMP POH & change shoe to 12 1/4" x 9 5/8". 06:00 - 09:00 3.00 PULL P DECOMP Continue to wash over 7" c in ' -Pump Hi-Vis Sweep (YP-39). 09:00 - 10:00 1.00 PULL P DECOMP POH - -PU 2nd joint washpipe. Printed: 6/10/2008 11:46:23 AM • BP EXPLORATION Page 11 of 22 Operations Summary Report Legal Well Name: MPS-31 Common Well Name: MPS-31 Spud Date: 2/13/2002 Event Name: WORKOVER Start: 4/30/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 5/16/2008 Rig Name: DOYON 14 Rig Number: 14 I I Phase Description of Operations Date From - To Hours Task Code I NPT 5/4/2008 10:00 - 11:00 1.00 PULL P DECOMP Cotinue to wash down f/ 75' to 81' and casin atch . -Tag patch. -Noted Torque increase. 11:00 - 11:30 0.50 PULL P DECOMP Pull up 1' to 80' md. -Pump Hi Vis Sweep (41-YP) surface to surface. 11:30 - 12:00 0.50 PULL P DECOMP Attempt to get washpipe over 7" casing stub. No-go. 12:00 - 13:00 1.00 PULL P DECOMP Stand back 2 DC's and 1 jt wash pipe. -Break off shoe and inspect. -LD 1 joint washpipe in shed. 13:00 - 14:30 1.50 PULL P DECOMP Clear Rig floor. Remove False table. C/O Elevators. -Suck out Stack. MU cutter BHA. -6 1/8" Stab, XO PXP, Cutter, XO, XO, 1 jt of 4" D.P. 14:30 - 15:00 0.50 PULL P DECOMP RIH locate 7" collar C~3 +/- 119' and PU 35' to 84' md. -Stage up pumps to 310 gpm / 710 psi. 60 RPM. -Cut casing, pressure dropped off to 130 psi. 15:00 - 16:30 1.50 PULL P DECOMP Break out & LD 4" D. P. LD XO & cutter. -PU Spear BHA: -Spear, Stop sub, XO,XO,X0,4 3/4" Bumper sub & XO. 16:30 - 18:30 2.00 PULL P DECOMP RIH..Engage 7" casing cut. -Sta e u ull 125k 150k 175 k 190k, 210k,250k re eatedl . 18:30 - 19:30 1.00 PULL P DECOMP Release from Fish. POH, LD Spear. -MU Cutter, RIH to 65' md. 19:30 - 20:00 0.50 PULL P DECOMP RIH with Cutter. Locate collar C~ 68' md. Pull up 2' to 66' md. -Make cut ~ 66' md. 297 gpm / 690 psi. 60 RPM. -After cut a pressure decrease to 100 psi was noted. 20:00 - 20:30 0.50 PULL P DECOMP POH. LD Cutter. MU Spear. -PU 7" casing handling Tools. 20:30 - 21:30 1.00 PULL P DECOMP RIH. En a e Fish ~ 66' md. Pull Fish to floor. -LD 7" Fish (26.37'). 21:30 - 23:00 1.50 PULL P DECOMP LD 1 Std of 4 3/4" D.C's. from derrick. -PU accelerators, Jars, Bumper sub, sub, 2-XO's & Spear. -PU 2 4 3/4" D.C's. and 1 jt of 4" D. P. 23:00 - 00:00 1.00 PULL P DECOMP En a e Fish at 66' and ttem t to ull. -Work /Jar Fish. Pull up to 125k. 5/5/2008 00:00 - 01:00 1.00 PULL P DECOMP Fishing at 66' and and attempt to pull. -Work /Jar Fish. Pull up to 125k. -Jars failed after approximately 10 Hits. -Attempt to pull Fish free - No-go. 01:00 - 01:30 0.50 PULL P DECOMP Stand back 4 3/4" D.C's. LD Spear Assy. -LD: Spear, Stop sub, Xo, XO, XO, 4 3/4" Bumper sub, -LD: 4 3/4" Oil Jar, 4 3/4" Accelerator & XO. 01:30 - 02:00 0.50 PULL P DECOMP LD 4 3/4" Jars, Accelerators & Bumper sub. -PU 6 1/4" Jars, Accelerators & Bumper sub. 02:00 - 03:00 1.00 PULL P DECOMP Latch up 8" D.C's. with 11 3/4" Wash pipe. RU False bowl. -LD Wash pipe, RD False bowl. 03:00 - 04:30 1.50 PULL P DECOMP MU Spear Assembly BHA with 6 1/4" jars, -Acceleratos and Bumper sub on 8" D.C's. -RIH to en a e Fish. No- o. POH check Bull nose. -RIH work string. PUW 60k, SOW 60k. -En a e Fish. 7" 26# L-80 Cs . 04:30 - 11:30 7.00 PULL P DECOMP Jar on Fish (7" Csg &Csg patch) C~3 66' md. -Maximum overpull ~ 240k. -Work Gra le out of Fish. Printed: 6/10/2008 11:46:23 AM ~ ~ BP EXPLORATION Page 12 of 22 Operations Summary Report Legal Well Name: MPS-31 Common Well Name: MPS-31 Spud Date: 2/13/2002 Event Name: WORKOVER Start: 4/30/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 5/16/2008 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours Task Code NPT Phase Description of Operations 5/5/2008 11:30 - 12:00 0.50 PULL P DECOMP Pull up. LD Spear assembly. -1 of 4 Grapples pieces left in hole. 12:00 - 14:00 2.00 PULL P DECOMP LD two 8" D.C's. Blow down Top Drive. -Perform Derrick inspection (Phase 2 weather). -PJSM-Change out Swivel packing and service Top Drive. Wait on 16" Wash pipe. Test Swivel packing-good. 14:00 - 17:30 3.50 PULL P DECOMP PU 16" handling Tools to Rig floor. -PJSM on steps of the job. -Remove Iron Roughneck rail tracks. -Change out Elevators, Hang Tongs. -PU 1 jt of 16" wash pipe. -MU: Mill /Shoe, Wash pipe, Drive sub, Bit sub & 1 jt of 8" D.C's. andf XO. 17:30 - 00:00 6.50 PULL P DECOMP RIH. Start washing over 7" Csg stub at 41' md. -70 RPM ~ 1 k Tq. 500 gpm / 50 psi. -Wash down to 79' md. -Washing with Seawater. 5/6/2008 00:00 - 03:00 3.00 PULL P DECOMP Continue washing over 7", 26#, L-80, Csg from 79' md. -Washing over with 16" Washover assembly. -Encountered missing Grapple ~ 79.5' to 81' md. -Noted torquing up (1-15k) and screwing in. -Continue washing down to 95' md. -PUW 63k, SOW 63k, 486 gpm / 120 psi. 03:00 - 03:30 0.50 FISH P DECOMP Pump Hi Vis Sweep surface to surface (YP-62). -500 gpm / 110 psi. -Continue to circulate hole clean. 03:30 - 05:00 1.50 FISH P DECOMP Pull up. LD 16" Wash over BHA. -LD 8" D.C's, X-O's, Bit sub, Drive sub & 16" Wash pipe w / Shoe. 05:00 - 06:00 1.00 FISH P DECOMP Clear floor of all 16" equipment -Mobilize spear assembly to rig floor 06:00 - 07:00 1.00 FISH P DECOMP MU spear, B.S., oil jar, accelerator -PU 8" DC's -install new grapple (6.220 nom. catch) 07:00 - 09:00 2.00 FISH P DECOMP RIH to 66' -Several attempts before entering 7" casing w/spear -(Laying over against 20") 09:00 - 10:00 1.00 FISH P DECOMP Pull fish to surface -Release and LD spear, jars and DC's -LD fish -Recovered 2' cut piece on top, 5'- 7" pup jt, casing patch w/ 11 3/4" guide and 2' piece below patch -Total len th recovered = 16.50' 10:00 - 10:30 0.50 FISH P DECOMP Clear floor -Change dies in T.D. pipe handler 10:30 - 13:30 3.00 FISH P DECOMP Change elevators to 11 3/4' -MU 12 1/4" x 10 3/4" shoe on 3 jts 11 3/4" washpipe -Change elevators to 5" -PU drive sub, 2 8" DC's and xo's 13:30 - 14:00 0.50 FISH P DECOMP PJSM -Pump 35 bbls spacer -Displace well to 8.5 ppg spud mud (300 visc) 14:00 - 15:30 1.50 FISH P DECOMP Wash over 7" casin from 95' -4-7 bpm / 70-110 psi Printed: 6/10/2008 11:46:23 AM C7 1.00 FISH P 1.00 FISH P BP EXPLORATION Page 13 of 22 Operations Summary Report Legal Well Name: MPS-31 Common Well Name: MPS-31 Spud Date: 2/13/2002 Event Name: WORKOVER Start: 4/30/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 5/16/2008 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours Task Code' NPT Phase Description of Operations 5/6/2008 14:00 - 15:30 1.50 FISH P 15:30 - 16:00 0.50 FISH P 16:00 - 16:30 ~ 0.50 ~ FISH ~ P 16:30 - 20:30 I 4.001 FISH I P 20:30 - 00:00 I 3.501 FISH I P 5/7/2008 ~ 00:00 - 08:30 ~ 8.501 FISH ~ P 08:30 - 10:00 ~ 1.501 FISH ~ P 10:00 - 11:00 11:00 - 12:00 12:00 - 13:00 13:00 - 15:30 • DECOMP Pull up to 90' (inside conductor) -Mix mud -Mix medium nutplug pill at 10#'s per bbl DECOMP RIH slowly to 145' -Spot 40 bbl nuplug pill w/ 2.5 bpm -Slight returns observed DECOMP Pull up to 90' -Allow nutplug pill to soak -Continue to build spud mud volume -Wait on LCM from Deadhorse (Phase 2 weather) DECOMP -Mix 40 bbls LCM pill: 10 ppb MIX II med. + 5 ppb M-I Seal + 5 ppb Nut Plug coarse -RIH slowly to 145'. Spot 20 bbls LCM pill w/ 2.5 bpm. No returns observe -Pull to 90'. Allow pill to soak for 1 hr -RIH again to 145'. Spot additional 20 bbls LCM pill w/ 2.5 bpm. No returns observed -Pull to 90'. Allow pill to soa for 1 hr -RIH to 145'. Pump 25 bbls spud mud w/ 2.5 bpm without returns -Pull to 90' DECOMP -Mix 2nd 40 bbl LCM pill: 10 ppb MIX II coarse + 5 ppb M-I seal + 5 ppb Nut Plug med. -Total 20 ppb -RIH to 140'. Spot 20 bbls LCM pill w/ 2.5 bpm. No returns -Pull to 90'. Let pill soak for 3 hrs. -RIH to 140'. Pump 22 bbls of spud mud w/ 2.5 bpm. Slight returns -Spot 15 bbls LCM pill w/ 2.5 bpm. Slight returns -POH to 90' -Observe well -Fluid in riser fell ap roximatel 6' in 3 hrs. -Mix 85 bbl t_CM pill w/ 60 ppb while waiting - Mix II coarse and medium (Fiber), Nutplug coarse and MI Seal. DECOMP RIH -Taking weight at 110' -Begin pumping LCM w/ 2.5 bpm, 90 psi -Rotate down to 145' _ -Returns observed at 36 bbls um ed awa -Pump total of 50 bbls LCM pill w/ approx 50% returns DECOMP POH -Change shoe to 12 1/4" x 9 5/8" DECOMP RIH to 90' -Begin pumping 30 bbls 60 ppb LCM pill w/ 2.5 bpm 90 psi -Rotate down to clean 7" OD to ensure 9 5/8' casing will go over -Observed full returns (22% in flowline indicator) while 1.00 FISH P DECOMP POH. Stand back 8" DC's -LD 3 jts 11 3/4" washpipe, shoe and drive sub 2.50 CASE P DECOMP -Clean washpipe handling tools and LD same. -C/O inserts in false table for 9-5/8" casing Printed: 6/10/2008 11:46:23 AM ~ ~ BP EXPLORATION Page 14 of 22 Operations Summary Report Legal Well Name: MPS-31 Common Well Name: MPS-31 Spud Date: 2/13/2002 Event Name: WORKOVER Start: 4/30/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 5/16/2008 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours Task Code !, NPT ' Phase. Description of Operations '_ __ 5/7/2008 13:00 - 15:30 2.50 CASE P DECOMP -RU to run 9-5/8" casing tongs, elevators, slips -Make dummy run w/ mandrel hanger and landing joint to landing ring 15:30 - 16:30 1.00 CASE P DECOMP MU and run 9-5/8" casin ass : 9-5/8" 47# L-80 BTC pup joint w/ cutlip + 2 jts 9-5/8" 47# L-80 BTC casing + mandrel hanger. -Land w/ landing joint in landing ring. Back out landing joint and LD same -B tt -5 sin ~ 135'. 16:30 - 18:00 1.50 FISH P DECOMP -Clean casing equipment and false table -Clear rig floor of tools not needed for upcoming operations 18:00 - 19:00 1.00 FISH P DECOMP MU BHA: 6-1/8" bit + bit sub + XO + 9 4-3/4" DCs 19:00 - 20:00 1.00 FISH P DECOMP RIH and to to of fill/sand C~ 1 934'. PU 30' 20:00 - 20:30 0.50 FISH P DECOMP Displace fluid in 7" casin f/ 1,904' to 84' w/ 9.5 brine -4 bpm, 30 psi. Good returns during displacement 20:30 - 22:30 2.00 FISH P DECOMP POOH 4" DP to 282' (top of 4-3/4" DCs). Keep BHA in hole to make up back off tools on top of it -Well started taking fluid. Lost+/- 100 b_bls while pulling out 4" -Top off w/ spud mud to keep fluid column on back side when backing off 7" casing -Total lost: 142 bbls. Losses slowed after topping with spud 22:30 - 00:00 1.501 FISH P 5/8/2008 ~ 00:00 - 01:00 1.00 ~ FISH ~ P 01:00 - 04:30 I 3.501 FISH I P DECOMP -Mobilize tools to rig floor -MU back off tools in BHA DECOMP -Finish MU backoff BHA -Position back off tool: lower anchor ~ 130', upper anchor ~ 109'. Middle section of tool accross connection ~ +/-119' DECOMP -RU head pin to cement line. -Pressure test lines w/ 4,000 psi. Good test -Pressure up to 500 psi to set lower anchor. Slack off 10k and verify anchor set. Bleed off pressure -Pressure up to 2,500 psi to set upper anchor. Slack off string weight and set slips. Bleed off pressure success. Bleed otf pressure and wait 10 min -Attempt to back off again, pressuring up to 3,500 psi w/ no succes. Bleed off pressure and wait for 15 min -Make 3rd attempt. Pressure up to 1,750 psi and back off 1/8 t ru n• Bleed pressure and wait for 15 min -Pressure up to 1,500 psi and back off 1/8 turn. Bleed off pressure and wait for 20 min. -Pressure up to 1,200 psi and back off 1/8 turn. Bleed off pressure and wait 2 min. Prresure up again to 1,200 psi and back off 1/8 turn. Bleed off pressure and wait 2 min. -Attempted again 2x pressuring up to 3,500 psi w/no success 04:30 - 05:30 I 1.001 FISH I P 05:30 - 06:00 I 0.501 FISH I P 06:00 - 06:30 I 0.501 FISH I P DECOMP -Blow down cement line. RD line and head pin. -PU to release anchors. -Stand back 8" DC's -LD back off BHA DECOMP Clear floor of equip. not needed -Mobilize spear assembly DECOMP MU spear w/ 6.220 nom. catch grapple Printed: 6/10/2008 11:46:23 AM BP EXPLORATION Page 15 of 22 Operations Summary Report Legal Well Name: MPS-31 Common Well Name: MPS-31 Spud Date: 2/13/2002 Event Name: WORKOVER Start: 4/30/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 5/16/2008 Rig Name: DOYON 14 Rig Number: 14 Date I~From - To Hours ~, Tas~Code NPT Phase Description of Operations 5/8/2008 06:00 - 06:30 0.50 FISH P DECOMP -RIH and engage T.O.F. at 84' 06:30 - 07:30 1.00 FISH P DECOMP PU slight overpull -Back out 7" from connection at 119' w/ 5 -1/2 turns left -POH -Release spear -LD 7" casing (collar looking uo down hole) -Recovered 34.37' 07:30 - 08:00 0.50 FISH P DECOMP Clear/clean rig floor 08:00 - 10:30 2.50 WHSUR P DECOMP PJSM - ND flowline -Cut riser - LD same -LD conductor adapter flange -MU starting head to adapter -FMC test to 1000 psi 10:30 - 11:30 1.00 CASE P DECOMP PJSM - RU to run 7" casin 11:30 - 12:30 1.00 CASE P DECOMP PU 7" triple connection bushing w/ 5' 7" pup jt, 10' pup jt -2 jts 7" 26# L-80 BTC casing -2 XO's and 1 jt 4" DP 12:30 - 13:30 1.00 CASE P DECOMP MU T.D. to 4" DP -Ta 7" collar at 119' -Obtain parameters -Screw into 7" w/ 11 turns -Torque to 8k ft/Ibs - PU to 15k over and work torque -Repeat process 13:30 - 15:30 I 2.001 CASE I P 15:30 - 18:00 I 2.501 WHSUR I P 18:00 - 19:30 1.50 W HSU R P 19:30 - 23:00 3.501 BOPSUFtP 23:00 - 00:00 I 1.001 BOPSUFi P 5/9/2008 100:00 - 05:00 I 5.001 BOPSUR P 05:00 - 06:00 I 1.001 BOPSUR P DECOMP RU to test casing -Presure test casing to 2000 psi f/ 30 min_on chart - OK, -RD test equipment DECOMP -PU 20k over and set on emergency slips -Cut 7" casing w/ Wach's cutter per FMC. Cutoff length: 11.22' DECOMP -Set packoff per FMC -LD 1 jt 4" DP and XOs used to land 7" casing. -Install tubing head. -Test packoff to 4,300 psi x 30 min per FMC DECOMP -NU BOP. -Install double annulus valve in IA -Remove extension spool in choke line SIM OPS: RU lines to 7" x 9-5/8" and 9-5/8" x 20" annuli -Circulate and condition spud mud, pumping down 7" x 9-5/8" annulus, taking returns out 9-5/8" x 20" annulus, in preparation for upcoming cement job. 1.5 - 2.0 bpm / 50 - 100 psi. Good returns. Got returns after 13 bbls pumped away. DECOMP -RU to test BOP -Fill stack and choke manifold SIM OPS: continue circulating spud mud down 7" x 9-5/8" annulus, taking returns out 9-518" x 20" annulus. 1.8 bpm / 70 psi DECOMP Test BOP and related equipment per BP / AOGCC procedures and regulations. Test to 250 psi low - 3,500 psi high x 5 min each on chart. Test w/ 4" test joint. Test upper and lower rams w/ 4" and 3-1 /2" test joint. Perform koomey test. Test witnessed by WSL and Tourpusher. Bob Noble, AOGCC rep, waived witness of test. -SIM OPS: cont. circulating spud mud down 7" x 9-5/" annulus, taking returns out 9-5/" x 20" annulus. 1.8 bpm / 70 psi DECOMP -RD testing equipment -Install wear bushing SIM OPS: Printed: 6/10/2008 11:46:23 AM i BP EXPLORATION Page 16 of 22 Operations Summary Report Legal Well Name: MPS-31 Common Well Name: MPS-31 Spud Date: 2/13/2002 Event Name: WORKOVER Start: 4/30/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 5/16/2008 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours Task 'Code NPT 'Phase Description of Operations 5/9/2008 05:00 - 06:00 1.00 BOPSU P DECOMP -RD circulating lines to 7" x 9-5/8" and 9-5/8" x 20" annuli -RU Schlumberger to 7" x 9-5/8" annulus 06:00 - 08:00 2.00 CLEAN P DECOMP MU 6 1/8' bit, bit sub, 4 3/4"junk basket, 10 4 3/4" DC's -RIH on 4" DP to 1925' -SIMOPS - RU Schlumberger cementers to 9 5/8" x 7" annulus while RIH 08:00 - 08:30 0.50 CLEAN P DECOMP Screw in TD -Break circulation w/ 5 bpm 250 psi -PJSM w/ rig crew, cementers, truck drivers and Mud Man while circulating 08:30 - 09:30 1.00 REMCM P DECOMP Continue circulating w/ 70 degree seawater -.Begin pumping w/ Schlumberger down 7" x 9 5/8" annulus takin returns throw h 20" x 9 5/8" annulus -Pump 3 bbls H2O to fill lines -Test lines to 1000 psi -24 bbls 10.0 ppg Mudpush w/ 2 ppb Cemnet LCM -First 20 bbl 10.7 ppg CemCrete cement w/ 2 ppb Cemnet LCM -42 additional bbls of 10.7 ppg Cemcrete cement w/ 1/4 ppb of Celloflake LCM -Cement returns at surface w/ 35 bbls um ed -Total of 62 bbls pumped, 27 bbls to surface - CIP at 09:15 hrs. 09:30 - 10:30 1.00 CLEAN P DECOMP PU single DP -Tag Fill at 1934' -PU and rotate down w/ 70 rpm, 5 bpm 250 psi - 5k WOB -Weight fell off at 1940' (sand) -Clean out to 1945' - No indications of junk - Work junk basket by stopping pumps f/ 2-3 min and bring back up to 5 bpm -Repeat several times -Returns register 77 degrees 10:30 - 11:30 1.00 CLEAN P DECOMP POH f/ 1945' -Stand back DC's -Break bit - LD and clean boot basket (full of cement chunks, some iron cuttings) 11:30 - 12:00 0.50 CLEAN P DECOMP MU 6 1/8" OD Reverse Circulating Junk Basket 12:00 - 13:00 1.00 CLEAN P DECOMP RIH w/ DC's -RIH w/ 4" DP to 1944' 13:00 - 14:00 1.00 CLEAN P DECOMP Screw in TD -Obtain parameters -Tag Fill /Sand at 1944' -Dry drill 2', begin pumping while on bottom w/ 8 bpm, 1370 psi -Rotate down w/ 40-50 rpm to 1950' -Returns register 77 degrees 14:00 - 16:00 2.00 CLEAN P DECOMP POOH -Clean out RCJB. Bottom part was packed w/ cement and few metal slivers. -Make up RCJB again 16:00 - 16:30 0.50 CLEAN P DECOMP RIH to 1,940' 16:30 - 17:30 1.00 CLEAN P DECOMP -Screw in top drive. Establish circulation ~ 125 GPM. Rot. 30 RPM -Tag top of sand ~ 1~ -Wash down to 1962' -Turn pump rate up to 520 GPM. Wash down to 1967' -Circulate 30 min. 17:30 - 19:00 1.50 CLEAN P DECOMP POOH Printed: 6/10/2008 11:46:23 AM i r: BP EXPLORATION Page 17 of 22 Operations Summary Report Legal Well Name: MPS-31 Common Well Name: MPS-31 Spud Date: 2/13/2002 Event Name: WORKOVER Start: 4/30/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 5/16/2008 Rig Name: DOYON 14 Rig Number: 14 Date ', From - To .Hours !I Task Code NPT "~ Phase Description of Operations 5/9/2008 17:30 - 19:00 1.50 CLEAN P DECOMP -LD RCJB. RCJB was clean -MU RBP retrievin tool 19:00 - 20:00 1.00 DHB P DECOMP RIH to 1967' 20:00 - 21:00 1.00 DHB P DECOMP -Wash down w/ retrieving tool to top of RBP ~ 1996'. 336 GPM, no rotation -CBU 1.5x -Retrieve RBP er Halliburton re .PUW: 82k /SOW: 80k 21:00 - 22:00 1.00 DHB P DECOMP POOH -LD retrieving tool and RBP 22:00 - 00:00 2.00 FISH P DECOMP -Mobilize tools for packer milling assy. -MU acker millin BHA w/ 6-1/8" x 4-3/4" shoe, 5-3/4" x 5' washover pipe ext., 5-3/4" washpipe and boot baskets per Baker rep. 5/10/2008 00:00 - 00:30 0.50 FISH P DECOMP RIH w/ 3 stands 4-3/4" DCs 00:30 - 01:30 1.00 FISH P DECOMP RIH w/ 4" DP f/ derrick to 2280' 01:30 - 06:30 5.00 FISH P DECOMP Cont. RIH w/ 4" DP from pipe shed 1x1 to 7592' 06:30 - 13:00 6.50 FISH P DECOMP MU stand -Screw in TD -Obtain parameters -PUW 130k, SOW 90k, ROW 110k w/ 6k tq -Wash down & tap T.O.F. at 7600' -Rotate and work over top -Wash down and taa packer at 7629' . -Mill acker f/ 7629' to 7631', when packer dropped free. -203 GPM / 590 psi. 50 RPM / 6-9k TO. 13:00 - 13:30 0.50 FISH P DECOMP CBU 338 GPM / 1230 psi. No rotation 13:30 - 14:30 1.00 FISH P DECOMP -Chase acker to bottom to f ck '. 50 RPM / 5-7k TO, 212 GPM / 550 psi. t ff -1/2" u 't ~ 7984' -Well stable, no losses obe 14:30 - 16:30 2.00 FISH P DECOMP ircu a e sweep surface-surface. -340 GPM / 1790 psi. 120 RPM / 7k TO -No losses observed 16:30 - 19:30 3.00 FISH P DECOMP POOH to BHA. -Proper hole fill. No losses observed 19:30 - 21:00 1.50 FISH P DECOMP LD packer milling BHA 21:00 - 21:30 0.50 FISH P DECOMP -Clear rig floor of tools not needed for next operation -Mobilize tools for next BHA to rig floor 21:30 - 22:30 1.00 FISH P DECOMP MU spear BHA to fish on 3-1/2" tubing per Baker rep._ 22:30 - 00:00 1.50 FISH P DECOMP RIH to +/- 4000'. 5/11/2008 00:00 - 01:30 1.50 FISH P DECOMP Cont. RIH f/ 4000' to 7928'. PU 2 singles. -Check parameters: PUW 165K /SOW 80k 01:30 - 03:00 1.50 FISH P DECOMP -Screw in top drive. Establish circulation w/ 84 GPM ~ 380 psi -Run down and to T.O.F ~ 798 ' -En a e fish. Overpull 50k over PUW. Jar loose and observe drag of 20k over PUW. -Drop dart to open pump out sub. Attempt to shear open pump out sub by pressuring up to 3000 psi. No indication of shear. -MU additional single and stand back one stand. 03:00 - 08:00 5.00 FISH P DECOMP -Blow down top drive -Observe well -POOH w/fish. Observed overpulls of 5k-50k across perforations -Observe wash out in DP C~ 6222'. C/O bad jt. -Attempt to shear open pump out sub. No success -Cont. POOH f/ 6222' to 3000'. Open pump of sub. Printed: 6/10/2008 11:4623 AM BP EXPLORATION Page 18 of 22 Operations Summary Report Legal Well Name: MPS-31 Common Well Name: MPS-31 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Spud Date: 2/13/2002 Start: 4/30/2008 End: Rig Release: 5/16/2008 Rig Number: 14 Date From - To Hours Task Code I NPT 5/11/2008 03:00 - 08:00 5.00 FISH P 08:00 - 10:30 2.50 FISH P 10:30 - 12:00 I 1.501 FISH I P 12:00 - 13:00 1.00 CLEAN P 13:00 - 16:00 3.00 CLEAN P 16:00 - 18:00 2.00 CLEAN P 18:00 - 20:00 2.00 CLEAN P 20:00 - 21:30 1.50 CLEAN P 21:30 - 00:00 2.50 CLEAN P 5/12/2008 00:00 - 01:00 1.00 CLEAN P 01:00 - 02:30 1.50 CLEAN P 02:30 - 03:00 I 0.50 I CLEAN I P 03:00 - 05:00 I 2.00 05:00 - 14:00 I 9.00 14:00 - 16:30 ~ 2.50 16:30 - 18:00 I 1.50 18:00 - 19:30 I 1.50 I R Phase Description of Operations DECOMP -Finish POOH to BHA DECOMP -LD accelerator. Rack back 3 stands of 4 3/4" DCs. -LD jars and bumper sub. Set slips on fish -Attempt to disengage spear. No success. Break out w/ rig tongs below X nipple. -Observed possible pressure between upper X nipple and packer - Punrtura halnw unnar X-ninnle Release pressured crude -PU fish past packer. Puncture pup jt below packer, above lower XN-nipple and below lower XN-nipple -LD packer assy. PU bottom pup jts and cut same w/ handsaw (Baker-locked) LD. Cut upper X-nipple and return to Milne Point to recover XXN plug (found plug set in X-nipple above acker and not in XN-ni le DECOMP -Clear and clean rig floor -Clean all pieces recovered w/fish and wrap them in plastic before sending them out. -Mobilize tools for next BHA to rig floor DECOMP MU BHA w/ 7" casing scraper DECOMP Displace well w/ clean seawater -Pump 35 bbls Hi-vis sweep. -Follow w/ 360 bbls clean seawater -300 GPM / 1000 psi. R&R 60 RPM / 7k TO DECOMP POOH and LD 4" DP to +/-3000' DECOMP -Cut and slip drilling line (59.5') -Service top drive DECOMP Cont. POH and LD 4" DP to +/-1000' DECOMP Cont. POOH and LD 4" DP DECOMP LD BHA: (9) 4-3/4" DCs, jars, bumper sub, boot basket, 7" scraper and bit DECOMP LD 1 stand of 8" DCs from derrick. -Pull wear bushing RUNCMP -Mobilize equipment to handle 3-1/2" tubing to rig floor -RU to run 3-1/2" tubing and completion: C/O bales and elevators, RU tongs, compensator and torque turn equipment RUNCMP MU and run 3 1/2" 9.2# L-80 TCII completion to 4215' -PU and rotate 1 turn right - No progress -Attempt 1 more time- - No progress RUNCMP LD jt # 123 -install head pin in same -Attem t to circ -Pie lu ed . -Pressure to 1200 psi -Pipe unplugged -Break circ w/ 2 bpm, 70 psi -Wash down to 4225' -Mix and pump H.V. sweep -Recovered 2 handfulls of black and red rubber, sand and small chunks of cement. RUNCMP Continue to run 3 1/2" 9.2# L-80 TCII completion to 4661' where taking weight RUNCMP LD jt #137-install pin head in same -Break circulation w/ 3 bpm / 120 psi. Wash down and attempt to pass 4661'. Could not et b -Slack 5k ~ 4661' and circulate 3 bpm / 120 psi, attempting to Printed: 6/10/2008 11:46:23 AM • • BP EXPLORATION Page 19 of 22 Operations Summary Report Legal Well Name: MPS-31 Common Well Name: MPS-31 Spud Date: 2/13/2002 Event Name: WORKOVER Start: 4/30/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 5/16/2008 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours Task Code NPT Phase Description of Operations 5/12/2008 18:00 - 19:30 1.50 BUNCO RUNCMP clean debris. -Decision was made to POOH and LD comoletion 19:30 - 00:00 4.50 BUNCO DPRB RUNCMP POOH and LD 3-12/" 9.2# L-80 TCII tubing f/ 4661' to 2400' -Using compensator while breaking out and LD tubing. 5/13/2008 00:00 - 04:00 4.00 BUNCO DPRB RUNCMP Cont. POOH and LD 3-1/2" 9.2# L-80 TCII completion f/ 2400'. -Inspect packers. Middle packer brought a couple of pieces of black and red rubber behind slips. 3 smal nieces of same 04:00 - 05:00 ~ 1.00 ~ WHSUR ~ N ~ DPRB ~ CLEAN 05:00 - 06:00 ~ 1.00 CLEAN N DPRB CLEAN 06:00 - 07:30 1.50 CLEAN N CLEAN 07:30 - 08:00 0.50 CLEAN N DPRB CLEAN -RD tongs and compensator. C/O bales. -Stand back in derrick the following assy: W LEG + pup jt + XN nipple + 2 pup jts +GLM + 2 pup jts + bottom packer + 2 pup jts +GLM + pup jt (connections below bottom packer Bakerlocked). -C/O elevators -Install wear bushing -Mobilize tools for cleanout BHA to rig floor MU cleanout BHA w/ 6 1/8" bit,.7" scraper and 2 boot baskets and 6- 4 3/4" DC's RIH w/ 4" DP 1x1 from shed to 3000' Screw in TD -Circulate H.V. sweep surface to surface -13.5 bpm, 750 psi -R&R DP 80 rpm, 90' strokes -Some rubber recovered -Blow down TD 08:00 - 10:30 2.50 CLEAN N DPRB CLEAN ,ontinue RIH 1x1 from shed to 8003' 10:30 - 11:30 1.00 CLEAN N DPRB CLEAN Screw in TD -Obtain parameters - PUW 140k, SOW 90k, ROW 107k w/ 6k tq, 80 RPM -Pump H.V. sweep S.S. w/ 14 bpm, 3200 psi -R&R DP w/ 80 rpm, 90' strokes -Recovered several pieces of black rubber (possibly packer 11:30 - 14:00 ~ 2.50 ~ CLEAN ~ N ~ DPRB ~ CLEAN 14:00 - 16:00 2.00 CLEAN N DPRB CLEAN 16:00 - 16:30 0.50 CLEAN N DPRB CLEAN 16:30 - 18:00 1.50 CLEAN N DPRB CLEAN 18:00 - 19:00 1.00 CLEAN N DPRB CLEAN 19:00 - 22:30 3.50 CLEAN N DPRB CLEAN 22:30 - 23:00 I 0.501 WHSUR I N I DPRB I CLEAN -Blow down TD RU to reverse circulate -Reverse circ. H.V. sweep S.S. w/ 5.5 bpm 540 psi -Sweep came back clean -RD lines -Screw in TD -Break circ. and observe well for losses (None) Observe well -Blow down POH LD 4" DP to 5000' Pump H.V sweep S.S. w/ 14.5 bpm 2200 psi -R&R DP as before -Returns clean POH LD 4" DP to 3000' -Pump Hi-vis sweep to the bit -Pump out of the hole 6 stands to +/-2400' -9 bpm / 540 psi -Returns clean -Cont. POOH and LD 4" DP -RIH 6 stands 4" DP f/ derrick. POOH and LD -LD BHA -Clear rig floor -Pull wear bushing Printed: 6/10/2008 11:46:23 AM • BP EXPLORATION Page 20 of 22 Operations Summary Report Legal Weli Name: MPS-31 Common Well Name: MPS-31 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC Rig Name: DOYON 14 Start: 4/30/2008 Rig Release: 5/16/2008 Rig Number: 14 Spud Date: 2/13/2002 End: Date From - To Hours Task Code 5/13/2008 23:00 - 00:00 1.00 5/14/2008 00:00 - 01:00 1.00 01:00 - 07:00 6.00 07:00 - 08:30 1.50 08:30 - 09:30 1.00 RU 09:30 - 11:00 1.50 RU 11:00 - 11:30 0.50 RU 11:30 - 13:30 2.00 RU 13:30 - 14:30 1.00 RU 14:30 - 16:00 1.50 RUN 16:00 - 16:30 0.50 RUN 16:30 - 20:00 3.50 RUN 20:00 - 21:00 I 1.00 NPT Phase Description of Operations _ _ __ __ DPRB RUNCMP (-Run stand of completion assy (WLEG - XN nipple -GLM - Packer -GLM) f/ derrick -RU to run completion: C/O bales, install compensator, RU tongs and torque turn equipment DPRB RUNCMP Finish RU to run 3-1/2" completion DPRB RUNCMP Run 3-1/2" 9.2# L-80 TCII com letion -Torque turn all connections -Connections below bottom packer Bakerlocked -Taking weight at 4949' WLEG depth RUNCMP LD jt # 146 -RU Circ. head in same -Break circ. w/ 2.5 bpm, 100 psi -Wash down f/ 4929' to 4959' -RD circ. head RUNCMP Continue run 3-1/2" 9.2# L-80 TCII completion to 5410' -Torque turn all connections -Taking weight but able to w RUNCMP RU circ. head -As precaution, break circulation to avoid too much build up below packer -Pump 50 bbls at 3 bpm, 140 psi -RD head pin -Continue run 3-1/2" 9.2# L-80 TCII completion to 5955" -Torque turn all connections -Taking weight but able to work joint down RUNCMP RU circ. head -As precaution, break circulation to avoid too much build up below packer -Pump 50 bbls at 3 bpm, 160 psi -RD head pin RUNCMP Continue run 3-1/2" 9.2# L-80 TCII completion to 6320' -Torque turn all connections RUNCMP RU circ. head -As precaution, break circulation to avoid too much build up below packer -Pump 100 bbls at 3 bpm, 160 psi -SIMOPS -Knock ice from derrick while circulating -Safety/RLG closeout discussion w/ Workover Ops. Supt. -RD head pin RUNCMP Continue run 3-1/2" 9.2# L-80 TCII completion to 6893' -Torque turn all connections -Taking weight. RUNCMP RU circ. head -Break circulation -Wash down to 6913' -Pump 50 bbls at 3 bpm, 160 psi -RD head pin RUNCMP Continue run 3-1/2" 9.2# L-80 TCII completion to 7909'. -Circulate ~ 7000' and 7065'. 126 GPM / 120 psi -Torque turn all connections. -Total jts run: 237 RUNCMP -MU tubing hanger and landing joint -Land completion. ___ Printed: 6/10/2008 11:46:23 AM BP EXPLORATION Page 21 of 22 Operations Summary Report Legal Well Name: MPS-31 Common Well Name: MPS-31 Spud Date: 2/13/2002 Event Name: WORKOVER Start: 4/30/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 5/16/2008 Rig Name: DOYON 14 Rig Number: 14 Date ! From - To Hours Task Code NPT Phase Description of Operations 5/14/2008 20:00 - 21:00 1.00 BUNCO RUNCMP -WLEG ~ 7940'. Top of bottom packer ~ 7888' , 21:00 - 00:00 3.00 BUNCO RUNCMP -MU XO and TIW valve on top of landing joint -RU Schlumberger wireline pressure control: pup in sub, wireline BOP, lubricator and packoff. -Test wireline well control to 500 psi. 5/15/2008 00:00 - 01:00 1.00 BUNCO RUNCMP Finish RU Schlumberger equipment 01:00 - 05:30 4.50 BUNCO RUNCMP RIH w/ GR/CCL log to 7920' WLM -Take GR/CCL log to 7100' and correlate_G_ R and bottom -LUI~J JIIUW UGlbt'i VI UVllVlll ~./Gl+nG1 G QuvVG rJCI 05:30 - 06:30 1.00 BUNCO RUNCMP RD SW#S -LD lubricator ext's, W.L. BOP's, XO's and tools 06:30 - 07:00 0.50 BUNCO RUNCMP RU tbg equip to spaceout -Compensator, elev, etc. 07:00 - 08:30 1.50 BUNCO RUNCMP Pull hanger to rig floor -LD 4 1/2" landing jt, hanger -Change elevators -LD joint # 237 and 10' pup -MU jt. # 237 and hanger 08:30 - 09:00 0.50 BUNCO RUNCMP Wait on town team to verify correlation logs 09:00 - 09:30 0.50 BUNCO RUNCMP Land tubing -RILDS (RKb Doyon-14 to ULDS: 29.68') Middle packer C~ 7724'. Upper packer ~ 7598'. X-nipple ~ 7577'. X-nipple ~ 2350'. #1 @ 7894' #2 C~? 7844' #3 ~ 7815' #4 C~ 7663' #5 ~ 7625' #6 ~ 7486' 09:30 - 10:00 0.50 BUNCO RUNCMP RU to pump down IA, taking returns out tubing -Close TIW valve on tubing 10:00 - 12:00 2.00 BUNCO RUNCMP Perform infectivity test -In'ect 6 bbls awa w/ 2.8 b m 690 si -Open tubing -Reverse circ. w/ 100 bbls clean seawater and 210 bbls clean seawater w/ corrosion inhibitor -3 bpm 320 psi 12:00 - 13:00 1.00 BUNCO RUNCMP Dro ball & Rod w/ rollers -RU to pump down tubing, set packers and test 13:00 - 15:00 2.00 BUNCO RUNCMP Pum down tubin and ressure u to 4200 si to set acker: -Indications at 2300 and 3500 si -Hold ressure f/ 30 min. on chart -Bleed tubing to 1000 psi -Pressure up on annulus to 1500 psi - o pressure f/ 30 min on chart -All tests good -Jeff Jones w/ AOGCC waived witness of tests -Bleed off pressure on tubing and observe S.V shear -Pump down tubing: 2 bpm ~ 240 psi. Pump down IA 3 bpm ~ 300 psi. 15:00 - 15:30 0.50 BUNCO RUNCMP Clear ice out of derrick 15:30 - 17:00 1.50 WHSUR P RUNCMP -Install TWC Printed: 6/10/2008 11:46:23 AM • BP EXPLORATION Page 22 of 22 Operations Summary Report Legal Well Name: MPS-31 Common Well Name: MPS-31 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To Hours Task Code ~ NPT - -- - 5/15/2008 15:30 - 17:00 1.50 W HSUR I P 17:00 - 18:30 1.50 BOPSU P 18:30 - 21:00 2.50 WHSUR P 21:00 - 21:30 0.501 WHSUR P 21:30 - 23:00 I 1.501 WHSUR I P 23:00 - 00:00 1.00 WHSUR ~ P 5/16/2008 ~ 00:00 - 01:00 ~ 1.00 ~ WHSUR ~ P 01:00-01:30 I 0.501 WHSURIP 01:30 - 03:30 I 2.001 WHSUR I P Spud .Date: 2/13/2002 Start: 4/30/2008 End: Rig Release: 5/16/2008 Rig Number: 14 Phase Description of Operations RUNCMP- -Test TWC f/ bottom to 1000 psi x 10 min. Test f/ top to 3500 -Blow down lines to stack. Suck out fluid from stack RUNCMP ND BOP RUNCMP -NU adapter flange and tree -Test adapter flange void to 5000 psi x 30 min per FMC rep. Test tree to 5000 psi w/diesel per FMC rep. All tests good. RUNCMP -RU DSM lubricator -Test lubricator to 500 psi -Pull TWC. RD lubricator RUNCMP -RU Little Red Svcs to pump down IA for freeze protect. Test lines to 3500 psi -Pump 82 bbls diesel down IA, taking returns out tubing -2 bpm / 750 psi ~ 8 bbls away, 2 bpm / 900 psi ~ 44 bbls away, 2 bpm / 1000 psi FCP. RUNCMP -Jump IA to tubing -Let diesel U-tube RUNCMP -Shut IA and master valve -Blow down return line. Drain tree -RU lubricator and install BPV RUNCMP Test BPV f/ bottom to 1000 psi x 10 min. Use diesel f/ test w/ Little Red. Chart test. -Little Red suck back all lines RUNCMP Secure tree: -RD low torque valves -Remove pump in flange on wing valve. Install blank -Remove secondary IA valve. Install blank and gauge -Remove pump in flange in OA. Install blank and gauge. -Clear cellar -OA=O psi, IA=O psi, TBG=O psi Release riq ~ 03:30 5-16-2008 Printed: 6/10/2008 11:46:23 AM MElVIORANDLTM • Toy Jim Regg ~~ r~, P.I. Supervisor~~~~~ 51 ~~~~- FROM: Bob Noble Petroleum Inspector LJ State of Alaska Alaska Oil and Cas Conservation Commission DATE: Wednesday, May 28, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 5-31 MILNE PT UNIT SB S-31 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.[. Suprv ~' >~? ~ ~n~~ci Comm Well Name• MILNE PT UNIT sB s-3 t API Well Number: 50-029-23066-00-00 Inspector Name: Bob Noble Insp Num• mitRCN080527160335 Permit Number: 202-014-0 ~ Inspection Date: 5~27~2oos Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. S-31 Well ~ 2o2olao T e In'. sPT TVD /I z6o ' 17zo ~ 1670 1650 --i P.T. ~ ,TypeTest w Test psi . _ 3ss7- -IA -- -i ----- ---- i- -- ~ - ---- -- nzo pA -__ _- - Interval INITAL P/F P Tubing ', 6ao 7o0 ! 700 700 Notes: Mono Bore well ~~~~ JUN ~ '~ 200 Wednesday, May 28, 2008 Page I of I 05/13/08 ~ch[uml~erg~r Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well .Inh !t NO. 4702 Company: State of Alaska ~(~ Ji )r~ ~ ~ Alaska Oil & Gas Cons Comm sd ~~~~ Attn: Christine Mahnken 333 West 7th Ave, Suite 1(10 Anchorage, AK 99501 ~ n.. MPS-11 12017492 CEMENT & CORROSION LOG 7t5~ -/ ~ ~ // 04/22/08 ~.vw~ 1 vv 1 1-21lK-25 12061694 Q PRODUCTION LOG ~~ °fjf~ ~ - r~ ~ 04/18/08 1 1 GNI-04 12057606 ~.X-~ a STEP RATE INJECTIVfi r I tS I U'LG / ~jCF 04/23/08 1 1 L-220 11975763 USIT 04/22/08 1 1 MPS-31 11962598 USIT ~ ~ 05/03/08 1 1 X-17 12034894 USIT - / • f (o ~ ~ 05/03/08 1 1 04-47 11978458 MEM LDL ~9L(~-6 3 ~ 05/01/08 1 1 Y-07A 11966254 TEMP & PRESS LOG ,~V'~- / 05/02/08 1 1 L5-36 11975768 PRODUCTION PROFILE W/FSI -p f 04/28/08 1 1 Z-112 40016350 OH MWD/LWD EDIT °~- 02/15/08 2 1 Z-112 PB 40016350 OH MWD/LWD EDIT p'~ - ~ 02/11/08 2 1 Y-07A 11962781 CH EDIT PDC GR (SCMTI ~~ /(~~ f(p~~~-( 02/03/08 1 L2-16 11975760 RST ~~ (~ "~~~'}- ~ ~~~a~ 03/31/08 1 1 L2-33 11998999 RST ! 04/01/08 1 1 Li-14 11999000 RST ~ ,- 04/02/08 1 1 D-26B 40016518 OH MWDlLWD EDIT - rv° 02/21/08 1 1 PI FGSF ACKNANV~ Fnrc oc rnoT nv c~r•_~ uun ALI11 [9GTIII7\OU~ ~..~ w~e~.v ~..... ~w BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 _ -- Date Delivered: „It ,i , a Alaska Data & Consulting Services 2525 Gambell Street, Suite 40 , Anchorage, AK 99503-2838 j ATTN: Beth Received by: • ~l0 • ``~ ~ 1 ~-~ ~~ ~ ~-1 9~,..~ ~.,3~ SARAH PALIN, GOVERNOR c..~ ~ ~~ COI~TSERQ~ ATIpH C ~ Ip~ David Reem Engineering Team Leader BP Exploration Alaska Inc. ~~~ AP PO Box 196612 Anchorage, AK 99519-6612 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 R 2 9 2008 Re: Milne Point Unit, Schrader Bluff Oil Pool, MPS-31 Sundry Number: 308-157 \ a'~ ~O ~~ 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 tine 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 ff the 23rd day falls on a holiday or weekend. A person may not appeal a Comrriission decision to Superior Court unless rehearing has been requested. Sincerely, ~~ Daniel T. Seamount, Jr. Chair 7~ DATED this 2 day of April, 2008 Encl. (~~~~~•Q$ STATE OF ALASKA `~~~p ~~'`"" ~' ~ ,~j K'A~ OIL AND GAS CONSERVATION COMSION 0 "' ~. APR 2 5 APPLICATION FOR SUNDRY APPROVAL ~~~ t~'~'° 20 AAC 25.280 Alaska Oil & Gas Cons. Commission 1. Type of Request: ^ Abandon ®Suspend ^ Operation Shutdown ^ Perforate ^ Time Extensi~nchorage ^ 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 202-014 (308-095 & 308-149) 3. Address: ®Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23066-00-00 ' 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: MPS-31 Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 380109 " 73.54 - Milne Point Unit / Schrader Bluff 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8173 4287 - 8132 4278 2000 None Casin Len th Size MD TVD Burst Colla se Structural Conduct r 78' 20" 112' 112' 1490 470 Surface 8099' 7" 8133' 4279' 7240 5410 Intermediate Prod ti n Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7679' - 7920' 3916' - 4106' 3-1/2", 9.2# L-80 1930' & 7601' - 7668' Packers and SSSV Type: 7" Halliburton RBP; Packers and SSSV MD (ft): 2000'; 7" x 3-1/2" S-3 Perm Packer 7630' 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: May 3, 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 Bryan McLellan, 564-5516 Printed Name D vid Reem Title Engineering Team Leader r Prepared By Name/Number: Signature Phone 564-5743 Date e//2N1~~ Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: I Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ~OP Test ~.pAechanical Integrity Test ^ Location Clearance Other: 3~Q>~5.~ 3~~ ~~5~ G.S ~~ct..n~LcJ t S ~F~=. APR ~l ~ 200 Subsequent Form Required: w APPROVED BY ~/ l~ ~ A roved B ~ COMMISSIONER THE COMMISSION Date ~ V Form 10-403 Revisetf06/2006 -- Submit In Duplicate ORIGINAL ` MPS-31 RWO Sundry -Change of plans • Maunder, Thomas E (DOA) From: McLellan, Bryan J [Bryan.McLellan@bp.com] Sent; Monday, April 28, 2008 10:27 AM To: Maunder, Thomas E (DOA) Cc: Reem, David C; Stewman, Sondra D; Hubble, Terrie L Subject: MPS-31 RWO Sundry -Change of plans Page 1 of ~ • f~ Tom, As a follow up #o our conversation over the phone this morning, I'm writing to request a rush on the Sundry application review for MPS-31. This well was recently suspended (sundry # 308-149) because the original plan failed to repair the surface casing leak. Late last week, the decision was made to return to MPS-31 with a plan to run an intemal gsing patch to repair the 7" surface casing leak. The Sundry application was submitted on Friday morning, April 25th. Since then, the workover on Doyon 14's current well, MPS-11, is about 5 days ahead of schedule and they wiEl be ready to move to MPS-31 late tonight or tomorrow. Would it be possible to review the Sundry for approval by the end of business today, Monday April 28th? We have made a change to the planned RWO scope based on the leamings and successes on our current well, MPS-11. Instead of running an intemal casing patch to repair the teak, we plan to bum over the 7" casing outside the conductor shoe, swallow the 7" casing s#ub with new 9-518" casing to --154', run new 7" casing and cement both the 7" x 9-518" annulus and the 9-5/8" x 20" annulus to surface.. The planned scope of work is as follows: 1. MIRU rig Doyon 14. ND tree. NU and test BOPE to 3540 psi. Circulate out freeze protection fluid and circulate well to the bottom of the tubing at 1934' with clean kill weight fluid. 2. Pull and LD 3.5" tubing kill string. Note that there are 2 barriers in the well, ?" RBP at 2©OQ' and and Production packer with tubing tail plug at 7655' md. 3. ND BOP stack. Remove wellhead from 7" surface casing. 4. Burn over 7A surface casing to ~50' below conductor shoe. Anticipated bum over depth is 150-160' and RKB. 5. Run new 9-5/8" casing and make up to starting head landed on the 24" conductor. b. Mechanically cut or back off 7" casing below area of bad external corrosion (probably 116' and RKB). Pull 7" casing out of the hole. 7. Run new 7" casing and land in the wellhead. Pressure test the 7" casing to at least 1500 psi. 8. NU BOP stack and test the body and wellhead break to 3544 psi. 9. Pump 10.7 ppg Deepcrete cement down 7" x 9-518" annulus, taking returns up 9-5/8" x 20" annulus. Leave both annuli full of cement and allow it to set up. 10. Pull 7" RBP. 11. Mill up and remove 7" x 3-1/2" Baker S3 production packer at 7630' md. 12. Clean ou# fill to below bottom pert at 7920' md. 13. Run 3-'/z° L-80 completion with packers set at 7614' md, 7754' and and 7888' md. The completion will have water flow regulator valves between the packers to regulate injection into each zone. 14. Displace the IA to packer fluid. Set the packer. 15. Pressure test tubing and iA to at least 1544 psi. lb. Set BPV. ND BOPS. NU and test tree. RDMO. 4/28/2008 by Milne Pont 5~ MPS-31 Rig Workover Resuming Operations (Surface Casing Leak Repair) Scope of Work: Expense RWO -Pull 3-~/z" L-80 kill string, mill/retrieve 3-1/2" packer and tailpipe, run new 3-1/2" production packers, run 7" internal casing patch and run 3-'h" L-80 completion tubing. MASP: 1240 psi Well Type: Schrader Bluff Water Injector Estimated Start Date: May 3rd, 2008 Production Engineer: Mark Sauve Intervention Engineer: Bryan McLellan Original Sundry for this Workover was 308-095. Suspension Sundry for this Workover was 308-149 Proposed Procedure IRU rig Doyon 14. ND tree. NU and test BOPE to 35®( a protection id an ~ culate well to clean kill weight fluid. 2. Pull an 3.5" tubing string. ~-{ I~ 3. Pull 7" RBP a 0' md. 4. Mill up and remove 3-1/2" Baker S3 production er at 7630' md. 5. Clean out fill to below bot erf at 7920' md. 6. Run 3-%z" L-80 completion pac and se 7610' md, 7750' and and 7888' md. The upper packer will have a seal receptacle on top to ive the tubing. The completion will have water flow regulator valves between the packers to ulate ink n into each zone. 7. Run Internal casing patc ross 7" casing leak 45' below ground level (79' md). 8. Pressure test 7" ca ' to 1500 psi. 9. Run 3-'/z" L-8 ing. 10. Displac a IA to packer fluid. Stab seals into packer receptacle. 11. P ure test IA to at least 1500 psi. . Set BPV. ND ROPE. NU and test tree. RDMO. Tree: Cameron 7-1 /16", 5M W le Ihead: FMC 11 " gen 5 casing hanger. Bowen External 7" Casing Patch 20"x 34" insulated, 215 #/ft A-53 80' BGL 3.5", 9.2 ppf, L-80 NSCT Tbg. (cap. = 0.0087 bpf, drift = 2.867") KOP @ 571 ` to 941 ' Max. hole angle = 77.8 deg @ 4039' Hole angle thru' perfs = . 7" 26#, L-80, BTRC Casing (drift ID = 6.151, cap.= .0383 bpf) I Perforation Summary SWS Slim Cement bond log dated 8 March 02 Size Spf Interval (TVD) NB Sands 2.5" 2.5 7679'-7681' 3,843' - 3,844' OA Sands 2.5" 4 7,846'-7,876' 4,311' - 4,331' OB Sands 2.5" 4 7,900'-7,920' 4,364' - 4,384' 2506 Poweryet, HMX 4spf deep penetrating chg. 3.5" HES X-Nipple (2.813" ) 3.5" W LEG Halliburton 7" RBP 1920' 1930' 2,000' Jet Cut in the Tubing 7,so1' 3.5" HES X-Nipple (2.813") 7,so8' 7" x 3.5" Baker "S-3" Perm. packer 7,630' 3.5" HES XN-Nipple 2.813" Pkg. 7,655' (No-Go 2.75" id ) 3.5" WELG 7,668' \ ELMD 7,670' XXN plug set and tested to 1500 psi Short joints 7703'-7725' 7" Halliburton Float Collar 8049' 7" Halliburton float shoe 8133' MILNE POINT UNIT WELL No.: S-31 i API : 50-029-23066-00 BP EXPLORATION DATE REV. BY COMMENTS 02/20/02 M. Linder Drilled by Nabors 27-E 8/16/02 MDO Initial Completion Doyon 141 / Perfs 7/22/03 M. Linder Add NB sand pert interval 4/18/08 B. McLellan Suspension of workover operations U S-31 i Orig. DF Elev. = 3.54' Orig. GL Elev. = 39.00` Free: Cameron4-1 /16", 5M M F Ilh ad: FMC 11 " gen 5 casing hanger. Bowen External 7" Casing Patch 45' BGL 7" Homco Casing Patch 35' - 55' BGL 20"x 34" insulated, 215 #/ft A-53 80' r KOP @ 571 ` to 941' Max. hole angle = 77.8 deg @ 4039' Hole angle thru' perfs = . 3.5", 9.2 ppf, L-80 TC-II. Tbg. (cap. = 0.0087 bpf, drift = 2.867") 7" 26#, L-80, BTRC Casing (drift ID = 6.151, cap.= .0383 bpf) -31 i Proposed Orig. DF Elev. X3.54' Orig. GL Elev. = 39.00' 3.5" HES X-Nipple (2.813") -2200' I 3.5"x1.5"GLM 7500' ' 3.5" HES X-Nipple (2.813") 7soo' PBR 7" x 3.5" Baker Premier packer 7,610' 3.5" x 1.5" GLM's 0~ 7" x 3.5" Baker Premier packer 7,750' ' 3.5" x 1.5" GLM's 0 I Perforation Summary SWS Slim Cement bond log dated 8 March 02 Size Spf Interval (TVD) NB Sands 2.5" 2.5 7679'-7681' 3,843' - 3,844' OA Sands 2.5" 4 7,846'-7,876' 4,311' - 4,331' OB Sands 2.5" 4 7,900`-7,920' 4,364' - 4,384' 2506 Powerjet, HMX 4spf deep penetrating Short csg joints 7703'-7725' I 7" x 3.5" Baker Premier packer 7,885' 3.5"x1.5"GLM 0 3.5" HES XN-Nipple 2.813" Pkg. (No-Go 2.75" id) 7940 3.5" WELG 7" Halliburton Float Collar 8049' ~ 7" Halliburton float shoe MILNE POINT UNIT 02/20/02 M. Linder Drilled by Nabors 27-E WELL No.: S~1 i 8/16/02 MDO Initial Completion Doyon 141 / Perfs API : 50-029-23066-00 M Lind r l rt i t Add NB d 7/22/03 . e san n erva pe 4/17/08 B. McLellan Proposed RWO BP EXPLORATION (AK) • y, fie. ~ F ~ 1 i ~ 4y ~~,.,..~ Y ~~ ~ ~ P~ ~{ ~~ ~ y~ ALASSA OII, AHD GAS COH5ERQA7`IOAT COI-II-IIS5IOI~T David Reem Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 SARAH PAL/N, GOVERNOR 333 W. 7thAVENUE,.SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~,~o~~ Anchorage, AK 99519-6612 ~D Re: Milne Point Unit, Schrader Bluff Oil Pool, MPS-31 Sundry Number: 308-149 ~~I~ ~,PR ~ ~ 200$ 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 unless rehearing has been requested. DATED this ~,~c ay of April, 2008 • Encl. Sincerely, ,~' ate"'` 1. Type of Request: ^ Abandon ®Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ~ orage ^ 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 202-014 - ' Q - CIS 3. Address: ®Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23066-00-00 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: MPS-31 Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 380109 73.54 ' Milne Point Unit / Schrader Bluff 12_ PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8173 ~ 4287 - 8132 4278 ~ None None asin Len h Siz MD ND Burst Colla se Structur I n r 78' 20" 112' 12' 1490 470 Surface 8099' 7" 8133' 4279' 7240 5410 Intermediate Produ i n Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7846' - 7920' 4046' - 4106' 3-1/2", 9.2# L-80 1930' & 7601' - 7668' Packers and SSSV Type: 7" Halliburton RBP, 7" x 3-1/2" S-3 Perm Packer Packers and SSSV MD (ft): 2000', 7630' 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: April 17, 2008 ^ Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: 4/17/2008 ^ WAG ^ GINJ ®WINJ ^ WDSPL Commission Representative: Tom Maunder 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Bryan McLe-lan, 56a-5516 Printed Name aid Reem Title Engineering Team Leader Prepared By NamelNumber: Signature Phone 564-5743 Date y j ~ (~ Sondra Stewman, 564-x750 Commission Use Onl Sundry Number: ~ Conditions of approval: Notify Commission so that a representative may witness - ^ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: Subsequent Form Required: ~Q ' ~ ~~ ~ APPROVED BY ~ ~ ~ f/ Q - A roved B OMMISSIONER THE COMMISSION Date Form 10-403 Revised 06/2006 ~~~ ~ECEtVEC~ STATE OF ALASKA ~~//ti ~('RLA OIL AND GAS CONSERVATION COM SION MFR ~ $ ZOO$ APPLICATION FOR SUNDRY APPROVAL,giaska Oil & Gas Cans. Comm' 'pR 20 AAC 25.280 V ~ F i t ; _~* f 4 ~4 ~ ~~ ~ w-: Submit In Duplicate 1 ~a ivIPS-3 i Notice of operations shut down ~ Page 1 of 1 • Stewman, Sondra D From: Maunder, Thomas E (DOA) [tom.maunder@alaska.gov] Sent: Friday, April 18, 2008 11:54 AM To: McLellan, Bryan J Cc: Hubble, Terrie L; Stewman, Sondra D; Reem, David C Subject: RE: MPS-31 (202-014) Notice of operations shut down Brian, confirm our conversation and have informed Commissioner Foerster of your plan. She is in agreement with the proposal. A 403 is needed. The well should be considered suspended. Call or message with any questions. Tom Maunder, PE AOGCC From: McLellan, Bryan) [mailto:Bryan.McLellan@bp.com] Sent: Friday, April 18, 2008 11:44 AM To: Maunder, Thomas E (DOA) Cc: Hubble, Terrie L; Stewman, Sondra D; Reem, David C Subject: MPS-31 Notice of operations shut down Tom, As we discussed last night on the phone, we are planning to shut down operations on MPS-31 (Sundry # 308-095). The original scope of work was to repair a shallow surface casing leak. Work completed so far is as follows: 1. Pull 3-1/2" tubing down to the tubing cut at 7601' md. 2. Set RBP at 2000' md. 3. Remove ~45' of 7" surface casing. 4. Run new 7" surface casing and install wellhead. 5. Pump cement top job to fill up 7" x 20" conductor annulus. 6. Pressure test casing to 1500 psi FAILED. Identify casing leak between 73' and 82' and (at the casing patch). 7. Run 3.5" kill string to 1930' md. Freeze protect with diesel to 1930' md. The plan is to rig down, move off and develop a new plan to repair the leak in the 7" casing. The well is secured with 2 barriers: 1. 7" x 3.5" Baker S-3 production packer at 7630' and with a XXN plug in the tubing tail at 7655' md. 2. 7" RBP at 2000' md. I've attached a wellbore schematic of the current condition of the well. «MPS-31 Ops Shut Down,pdf» Please call if you have any questions or concerns regarding this well. Thank you, Bryan McLellan BP Exploration, Alaska 564-5516 4/18/2008 Tree: Cameron 7-1 /16", 5M r ellhead: FMC 11 " gen 5 casing hanger. Bowen External 7" Casing Patch 45' BGL 20"x 34" insulated, 215 #/ft A-53 80' BGL 3.5", 9.2 ppf, L-80 NSCT Tbg. (cap. = 0.0087 bpf, drift = 2.867") KOP @ 571' to 941' Max. hole angle = 77.8 deg @ 4039' Hole angle thru' perfs = . 7" 26#, L-80, BTRC Casing (drift ID = 6.151, cap.= .0383 bpf) 3.5" HES X-Nipple (2.813") 1920' 3.5" WLEG 1930' Halliburton 7" RBP 2,000' Jet Cut in the Tubing 7,601` 3.5" HES X-Nipple (2.813") 7,so8` 7" x 3.5" Baker "S-3" Perm. packer 7,630` ' I Pertoration Summary SWS Slim Cement bond log dated 8 March 02 Size Spf Interval (TVD) NB Sands 2.5" 2.5 7679'-7681' 3,843' - 3,844' OA Sands 2.5" 4 7,846`-7,876' 4,311' - 4,331' OB Sands 2.5" 4 7,900'-7,920' 4,364' - 4,384' 3.5" HES XN-Nipple 2.813" Pkg. 7,655` (No-Go 2.75" id ) " 668` 7 WELG 3.5 , ELMD 7,670' ~ XXN plug set and tested to 1500 psi Short joints 7703'-7725' 12.5" 2506 Powerjet, HMX 4spf deep penetrating chg. 02/20/02 M. Linder 8/16/02 MDO 7/22/03 M. Linder 4/18/08 B. McLell Drilled by Nabors 27-E Initial Completion Doyon 141 / Perfs Add NB sand pert interval Suspension of workover operations 7" Halliburton Float Collar 8049` 7" Halliburton float shoe 8133' MILNE POINT UNIT WELL No.: S-31i API : 50-029-23066-00 BP EXPLORATION U S-31 i I ~ Orig. DF Elev. = 73.54` Orig. GL Elev. = 39.00` • • BP EXPLORATION Page 1 of 6 Operations Summary Report Legal Well Name: MPS-31 Common Well Name: MPS-31 Spud Date: 2/13/2002 Event Name: WORKOVER Start: 4/9/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours i Task Code NPT Phase Description of Operations 4/10/2008 14:00 - 16:30 2.50 RIGD P PRE -RD rig floor -Skid rig floor to moving position. -Move rig off well B-10 -Install boosters 16:30 - 19:00 2.50 MOB N WAIT PRE Wait on Security 19:00 - 19:30 0.50 MOB N WAIT PRE Waiting and PJSM w/ Security 19:30 - 00:00 4.50 MOB P PRE Moving rig f/ well B-10. -Rig passed Frontier Corner at report closing. 4/11/2008 00:00 - 12:00 12.00 MOB P PRE Cont. moving rig f/ Frontier Corner to 1 mile into Milne Point road. 12:00 - 17:00 5.00 MOB P PRE Cont. moving rig to Milne Point S-pad 17:00 - 19:00 2.00 MOB P PRE -Spot rig over well MPS-31 -Shim rig 19:00 - 22:00 3.00 RIGU P PRE -Skid rig floor -RU rig floor -Spot and berm rock washer -Spot tiger tank Accept rig C~ 19:00 hrs 3 hours earlier to compensate for NPT waiting on security 22:00 - 00:00 2.00 WHSUR P DECOMP -RU lubricator. Test to 500 psi x 5 min -Pull BPV 4/12/2008 00:00 - 01:00 1.00 WHSUR P DECOMP RU tree to displace freeze protect: install pump in flanges, low torque valves and high pressure hoses 01:00 - 03:00 2.00 WHSUR P DECOMP Wait on Support Crew to RU hard line to tiger tank. -Support Crew pulling TWC at rig N-3S -Take on seawater in pits 03:00 - 04:00 1.00 W HSUR P DECOMP RU hard line to tiger tank 04:00 - 05:00 1.00 WHSUR P DECOMP -Blow air and steam through hard line. -Test hard line to 3,500 psi. Good test -Blow down hard line 05:00 - 06:30 1.50 WHSUR P DECOMP -Pump 40 bbls soap pill down tubing taking returns out annulus to tiger tank -Cont. circulating down tubing taking returns out annulus to tiger tank w/ seawater, displacing freeze protect out. Circulate total 280 bbls seawater. 6 bpm / 2130 psi 06:30 - 08:00 1.50 WHSUR P DECOMP -Allow diesel to migrate for 30 min. Pump additional 20 bbls of seawater. -Blow down lines. RD lines to tree 08:00 - 09:00 1.00 WHSUR P DECOMP Verify well dead. Install TWC 09:00 - 10:00 1.00 WHSUR P DECOMP -RU to test TWC -Test TWC f/ above to 3,500 psi x 10 min on chart. -RD testing equipment 10:00 - 11:00 1.00 WHSUR P DECOMP -ND tree -Get RKbs. Check XO on top of tubing hanger 11:00 - 12:00 1.00 WHSUR P DECOMP Hold ATP meeting w/ Milne Point personnel, rig crews and rig management. 12:00 - 15:30 3.50 BOPSU P DECOMP NU BOP. Install extension spool on choke line 15:30 - 16:30 1.00 BOPSU P DECOMP RU to test BOP 16:30 - 20:30 4.00 BOPSU P DECOMP Test BOP and related equipment per BP / AOGCC procedures and regulations. Test all components to 250 psi low - 3,500 psi high x 5 min each on chart. Test w/ 4" test joint. Test top rams w/ 4" and 3-1/2" test joints. Perform koomey test. Test witnessed by WSL and Tool / Tourpusher. Chuck Scheve, Printed: 4/18/2008 1:43:03 PM • BP EXPLORATION Page 2 of 6 Operations Summary Report Legal Well Name: MPS-31 Common Well Name: MPS-31 Spud Date: 2/13/2002 Event Name: WORKOVER Start: 4/9/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: Rig Name: DOYON 14 Rig Number: 14 Date ,From - To Hours , Task Code NPT Phase Description of Operations - -- 4/12/2008 16:30 - 20:30 4.00 BOPSU P DECOMP AOGCC rep, waived witness of test 20:30 - 21:00 0.50 BOPSU P DECOMP RD testing equipment 21:00 - 22:00 1.00 WHSUR P DECOMP Wait for XO needed for lubricator extension 22:00 - 00:00 2.00 WHSUR P DECOMP RU lubricator and lubricator extension to pull TWC 4/13/2008 00:00 - 01:00 1.00 WHSUR P DECOMP -Finish RU lubricator and lubricator extensions. Screw into tubing hanger -Test to 500 psi x 5 min on chart 01:00 - 01:30 0.50 WHSUR P DECOMP Pull TWC 01:30 - 02:30 1.00 WHSUR P DECOMP RD lubricator and lubricator extensions. 02:30 - 03:00 0.50 PULL P DECOMP PU 1 jt 4" DP and MU XOs 03:00 - 04:00 1.00 PULL P DECOMP -RIH and screw into tubing hanger -Back out LDS -Pull tubing hanger to rig floor. Pull free w/ PUW 90k (block weight 50k) 04:00 - 05:00 1.00 PULL P DECOMP CBU 338 gpm / 850 psi. -Mobilize equipment to LD tubing to rig floor. 05:00 - 06:00 1.00 PULL P DECOMP -LD tubing hanger, 1 jt 4" DP and XOs -RU equipment to LD 3-1/2" tubing 06:00 - 14:00 8.00 PULL P DECOMP POOH and LD 3-1/2" 9.2# L-80 IBT tubing. Total jts LD: 249 + 3.31' cut off jt. -Flare ~ cut: 4 1/16" -4 1/8". Cut uniform. 14:00 - 15:00 1.00 PULL P DECOMP -RD tubing handling equipment and clear rig floor -Mobilize BHA tools to rig floor 15:00 - 15:30 0.50 WHSUR P DECOMP Install wear bushing 15:30 - 16:00 0.50 CLEAN P DECOMP MU BHA w/ 6-1/8" bit and 7" casing scraper 16:00 - 18:30 2.50 CLEAN P DECOMP RIH w/ 4" DP 1 x 1 to +/- 2,100' 18:30 - 19:00 0.50 CLEAN P DECOMP CBU, 210 gpm / 360 psi 19:00 - 21:00 2.00 CLEAN P DECOMP -PU and MU RTTS packer -Set RTTS packer C~3 64' (COE), +/- 30' below well head -PJSM on testing below packer. Secure area and access points around cellar and mezzanine. -Test below packer to 1,500 psi x 30 min on chart. Good test 21:00 - 22:00 1.00 CLEAN P DECOMP -Pull RTTS packer and LD same -Cont. POOH 22:00 - 22:30 0.50 DHB P DECOMP -LD bit and casing scraper -MU RBP 22:30 - 00:00 1.50 DHB P DECOMP -RIH w/ RBP -Set RBP: Top ~ 1,996' / COE @ 2,000' -Rack back 1 stand 4" DP. -PUW 83k /SOW 83k 4/14/2008 00:00 - 01:30 1.50 DHB P DECOMP Dump 24 sxs (1,200#) of 20/40 river sand on top of RBP. 01:30 - 02:00 0.50 DHB P DECOMP -Screw in top drive and pump 15 bbls C~3 42 gpm. -PU 1 stand 4" DP and tag sand ~ 1,944' 02:00 - 03:30 1.50 DHB P DECOMP -POOH f/ 1,944' to surface. -LD running tool. Clear rig floor 03:30 - 05:30 2.00 BOPSU P DECOMP -PJSM -Pull wear bushing -ND flow line and riser -ND BOP & choke line 05:30 - 06:00 0.50 WHSUR P DECOMP -Backoff lock ring -Pull speed head loose 06:00 - 07:30 1.50 WHSUR P DECOMP -MU Wach's cutter -Cut casing head flange internally ~ 40" below speed head Printed: 4/18/2008 1:43:03 PM • BP EXPLORATION Operations Summary Report Page 3 of 6 Legal Well Name: MPS-31 Common Well Name: MPS-31 Spud Date: 2/13/2002 Event Name: WORKOVER Start: 4/9/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: Rig Name: DOYON 14 Rig Number: 14 Date 'From - To I Hours Task Code NPT Phase Description of Operations _~ 4/14/2008 07:30 - 08:30 1.00 WHSUR P DECOMP -PU speed head -RD Wach's cutter -LD mandrel hanger and speed head 08:30 - 14:30 6.00 WHSUR P DECOMP -Attempt to PU 20" riser in one piece from behind cellar but it is too long. Hang riser inside cellar -Install diverter connectionx20" BOP flange and XO. Cut bottom 5' off riser, pull riser to rig floor -Install bottom 5' of riser on diverter connection XO, lower riser down to cut -Weld riser back together. -Install new cement line and flow line 14:30 - 15:00 0.50 FISH P DECOMP Mobilize BHA tools to rig floor 15:00 - 16:30 1.50 FISH P DECOMP MU washover BHA per Baker rep: 12-1/4" x 10-3/4" washover shoe + 1 jt 11-3/4" washpipe + 11-3/4" Washover boot basket + 1 jt 8" DC. 16:30 - 18:30 2.00 FISH P DECOMP RIH and washover around 7" casing to 36' below ground level (70' below rotary table). -PUW 60k /SOW 60k / ROTW 60k -410 gpm / 60 - 130 psi -40 RPM / 0-5k TO. WOB 5-8k 18:30 - 20:00 1.50 FISH P DECOMP -POOH and add one more jt 11-3/4" washpipe -Clean washover boot basket. Large amount of cement cuttings in basket 20:00 - 20:30 0.50 FISH P DECOMP RIH and cont. washover around 7" casing to 55' below ground level (89' below rotary table). -PUW 62k /SOW 62k / ROTW 62k -510 gpm / 70-140 psi -40 RPM / 2-7k TO. WOB 5-8k 20:30 - 22:30 2.00 FISH P DECOMP Circulate hole clean. Pump a total of 7 Hi-vis sweeps with return of large amount of cement cuttings (last 2 pills show clean) -400-500 gpm / 6-70 psi. 40 RPM 22:30 - 23:30 1.00 FISH P DECOMP POOH and LD washover BHA. Boot basket cleaner than first run. 23:30 - 00:00 0.50 FISH P DECOMP Clear rig floor 4/15/2008 00:00 - 00:30 0.50 FISH P DECOMP Mobilize tools for next BHA to rig floor 00:30 - 01:00 0.50 FISH P DECOMP -MU casing cutter BHA: 5-1/2" Multi-string cutter + 6-1/8" stabilizer -MU 1 stand 4" DP 01:00 - 01:30 0.50 FISH P DECOMP -RIH to 79' below rotary table (45' below ground level) -Cut 7" casing. 60 RPM. 195 gpm / 250 psi while cutting. 420 gpm / 250 psi after cutting. 01:30 - 02:00 0.50 FISH P DECOMP -Rack back stand 4" DP -LD casing cutter assy. -MU spear assy. 02:00 - 03:00 1.00 FISH P DECOMP -PU 1 jt 4" DP and RIH w/ spear assy. to +/-35' below rotary table -Engage fish (work couple of attempts) -Pull fish to rig floor 03:00 - 03:30 0.50 FISH P DECOMP -Release spear -LD fish: recover total 44.43' of 7" casing (1.17' top cut off + 40.93' full jt + 2.33' bottom cut off). Top cut clean, no flare (Wach's cutter). Bottom cut clean, flare to 7-1/4" (casing Printed: 4/18/2008 1:43:03 PM • BP EXPLORATION Page 4 of 6 Operations Summary Report Legal Well Name: MPS-31 Common Well Name: MPS-31 Spud Date: 2/13/2002 Event Name: WORKOVER Start: 4/9/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours Task Code NPT Phase Description of Operations 4/15/2008 03:00 - 03:30 0.50 FISH P DECOMP cutter). Fish recovered shows small hole in middle of full jt. Estimated depth of hole when in the ground: +/- 20' below well head. 03:30 - 04:00 0.50 CLEAN P DECOMP -Clear rig floor -Mobilize tools for next BHA to rig floor 04:00 - 05:00 1.00 CLEAN P DECOMP -MU 17-1/2" used bit + bit sub + (3) 8" DCs -RIH while MU BHA to 77' (2' above casing stump). Did not observe any obstruction in the run 05:00 - 06:00 1.00 CLEAN P DECOMP -POOH. Break bit and bit sub -Rack back stand 8" DC -Mobilize tools for dress off BHA 06:00 - 08:30 2.50 FISH P DECOMP -MU dress off BHA: PU (2) 4-3/4" DCs + XOs + Washover Boot Basket. -Attempt to MU Washpipe extension. It has bad threads 08:30 - 09:30 1.00 FISH N WAIT DECOMP Wait for new washpipe extension 09:30 - 10:30 1.00 FISH P DECOMP Cont. MU dress off BHA 10:30 - 11:00 0.50 FISH P DECOMP RIH to top of stump ~ 79' (below rotary table). Work over stump and dress off 5" on same. -80 RPM / 1 k TO -PUW 52k / SOW: 55k / ROTW 55k 11:00 - 14:00 3.00 FISH P DECOMP -LD Dress off BHA tools. -Install XO assy on top of 8" DC stand so top drive can screw into the stand, in preparation for casing patch run. Rack back 8" DC stand. 14:00 - 14:30 0.50 FISH P DECOMP Clear rig floor 14:30 - 15:30 1.00 CLEAN P DECOMP -MU blank plug to bottom of 4" DP stand -RIH 15 stands of 4" DP with blind end to +/- 1,470' to displace seawater (aprox. 20 bbls) in preparation for casing patch run). 15:30 - 16:00 0.50 CLEAN P DECOMP POH and rack back 4" DP. Did not fill the hole while POH, leaving hole empty from surface to top of 7" casing stump C~ 45' below ground level 16:00 - 18:00 2.00 WHSUR P DECOMP ND 20" riser. -Vac out remaing seawater around 7" casing stump. 18:00 - 19:00 1.00 CASE P DECOMP RU to run 7" casing patch. 19:00 - 21:00 2.00 CASE P DECOMP -MU 7" casing patch + 7" 26# L-80 BTC casing pup jt + 7" 26# L-80 BTC casing jt. -RIH casing patch assy. on one stand 8" DC for weight to top of 7" casing stump. PUW: 60k (SOW: 60k -Rotate on top of casing stump and swallow 3' in casing patch. Bottom out casing patch and slack off 25k -Pull 50k over PUW and confirm casing patch engaged. Slack off back to neutral -Test casing patch to 1,500 psi x 10 min on chart. Good test. 21:00 - 21:30 0.50 CASE P DECOMP Install 1" x 31' long tubing in 20" x 7" annulus for later cement top job 21:30 - 23:00 1.50 WHSUR P DECOMP -Install emergency slips and set with 20k overpull on casing. -Cut & bevel 7" casing with Wach's cutter. Pull 5.02' cut off to rig floor. -Bottom of casing patch C~ 82' (48' below ground level). Top of casing patch CQ? 78' (44' below ground level). 23:00 - 00:00 1.00 WHSUR P DECOMP Prepare stump to weld transition nipple 4/16/2008 00:00 - 02:00 2.00 WHSUR P DECOMP -Position transition nipple -Burn HOT HED and heat welding area. Insulate Printed: 4/18/2008 1:43:03 PM • BP EXPLORATION Page 5 of 6 Operations Summary Report Legal Well Name: MPS-31 Common Well Name: MPS-31 Spud Date: 2/13/2002 Event Name: WORKOVER Start: 4/9/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: Rig Name: DOYON 14 Rig Number: 14 Date ~ From - To Haurs ~ Task +Code ~ NPT ~ Phase Description of Operations 4/16/2008 00:00 - 02:00 2.00 WHSUR P DECOMP -Weld transition nipple using GBR welding services. -Burn second HOT HED and reheat welding. Insulate 02:00 - 10:00 8.00 WHSUR P DECOMP Allow welding to cool down prior to installing starting head. -While waiting: strap and drift tubing for completion. Rig service and cleaning. 10:00 - 12;00 2.00 WHSUR P DECOMP -Attempt to test transition nipple weld w/ nitrogen per FMC. Test failed ~ 350 psi. -Wait on GBR welder to repair weld. Cont. rig service 12:00 - 14:30 2.50 WHSUR P DECOMP GBR welder repair weld on transition nipple. 14:30 - 15:00 0.50 WHSUR P DECOMP -Safety meeting with crew, Toolpusher, WSL, Operations Superintendent (J. Willingham) and Wells Manager (S. Rossberg). -GBR welder cont. working on transition nipple 15:00 - 15:30 0.50 WHSUR P DECOMP Test weld on transition nipple w/ nitrogen to 2,200 psi x 15 min per FMC. Good test 15:30 - 16:30 1.00 WHSUR P DECOMP -Install tubing spool -Test void to 1,000 psi x 10 min per FMC 16:30 - 19:00 2.50 BOPSU P DECOMP -NU BOP -Remove 1' extension spool f/ choke line. Install choke line 19:00 - 20:30 1.50 BOPSU P DECOMP -RU to test BOP breaks -Test BOP breaks to 250 psi low - 3,500 psi high x 5 min each on chart. -RD testing equipment. Pull test plug -Install wear bushing 20:30 - 21:00 0.50 WHSUR P DECOMP -MU mule shoe on stand of 4" DP and RIH -Circulate hot seawater w/ charge pumps prior to cement top 21:00 - 22:00 1.00 WHSUR P DECOMP -PJSM w/ Schlumberger on top job -Schlumberger batch mix 21 bbls 15.8 ppg class G cement -Schlumberger pump 21 bbls 15.8 ppg class G cement down 1" x 30' pipe installed in 20" x 7" annulus (top job). 5 bbls cement return to surface. Received cement return in receptacle while sucking at the same time from it with super sucker. No fluids drained to cellar. -Cont. circulating hot seawater in 7" casing while pumping top -CIP C~ 22:00 22:00 - 00:00 2.00 WHSUR P DECOMP -Cont. circulating hot seawater in 7" casing while waiting on cement to cure to 500 psi compressive strength. Estimated time to cure: 8 hrs 14 min per Schlumberger lab test -Cont rig service while waiting on cement. 4/17/2008 00:00 - 06:00 6.00 WHSUR P DECOMP Cont. waiting on cement to cure to 500 psi compressive strength /circulating hot seawater in 7" casing C~3 90'. -Cont. rig service while WOC. 06:00 - 06:30 0.50 WHSUR P DECOMP Rack back stand of 4" DP. LD mule shoe 06:30 - 07:00 0.50 WHSUR P DECOMP RU to test 7" casing and casing patch 07:00 - 09:30 2.50 WHSUR P DECOMP Attempt to test 7" casing and casing patch to 1,500 psi: -1st: pressure up to 1,500 psi. Pressure held for 8 min and then started to bleed off. Bled off 200 psi at the end of 30 min -2nd: pressure up to 1,500 psi. Pressure held for 7 min and then started to bleed off. Bled off 300 psi at the end of 30 min 09;30 - 10:00 0.50 WHSUR P DECOMP -RU to test casing patch from annulus. Printed: 4/18/2008 1:43:03 PM 'u BP EXPLORATION Page 6 of 6 Operations Summary Report Legal Well Name: MPS-31 Common Well Name: MPS-31 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date ~ From - To ~ Hours ~ Task Code NPT 4/17/2008 09:30- 10:00 0.50 WHSUR P 10:00 - 10:30 0.50 WHSUR P 10:30 - 11:30 1.00 WHSUR P 11:30 - 12:00 I 0.501 WHSUR I P 12;00 - 15:00 I 3.001 WHSUR I P 15:00-16:00 ~ 1.OO~WHSUR~P 16:00 - 16:30 0.50 WHSUR P 16:30 - 17:00 0.50 WHSUR P 17:00 - 18:00 1.00 WHSUR P 18:00 - 18:30 0.50 WHSUR P 18:30 - 21:00 i 2.50 ~ TA ~ P 21:00 - 23:00 2.00 TA P 23:00 - 00:00 1.00 TA P 4/18/2008 100:00 - 03:00 I 3.00 I TA I P 03:00 - ~ 21.00 TA i P Spud Date: 2/13/2002 Start: 4/9/2008 End: Rig Release: Rig Number: 14 Phase Description of Operations DECOMP -Pressure up to 1,500 psi f/ annulus. Pressure held for 5 min, and then bled off 200 psi at the end of 15 min. DECOMP RD testing equipment. Blow down choke and kill line DECOMP -Verify next steps with Workover team. -Wait on RTTS packer DECOMP -Mobilize RTTS to rig floor -RIH 2 stands 4-3/4" DCs and 5 stands 4" DP to 657' DECOMP -MU RTTS and set @ 82' (COE), +/- 4' below initial casing cut. Test below RTTS to 1,500 psi x 30 min. Good test. -Pull RTTS and set @ 73' (COE), +/- 5' above casing patch. Test below RTTS to 1,500 psi. Bled off 400 psi in 23 min. -Bleed off pressure below RTTS. Keep RTTS set ~ 73' (COE). Close top rams and test above RTTS to 1,500 psi x 15 min. Good test DECOMP -Pull RTTS to rig floor -POOH and rack back 4" DP and 4-3/4" DCs DECOMP MU mule shoe. RIH w/4" DP to 1,920' DECOMP CBU 2x, 210 gpm / 180 psi. Check seawater temperature in returns: 1.- 63 F at begining of circualtion 2.- 66 F at first bottoms up. 3.- 70 F at second bottoms up DECOMP POOH and rack back 4" DP DECOMP Pull wear bushing. -Decision was made to run kill string and suspend operations to move to well MPS-11 SURE -Pull 3-1/2" tubing for completion and 4" DP out of pipe shed. -Shuffle 4" DP and 4-3/4" DC stands in derrick in preparation for rig move to well MPS-11 SURE RU to run 3-1/2" kill string SURE -Receive and load in pipe shed 3-1/2" 9.2# L-80 NSCT cond B tubing, pup jts, WLEG and X nipple for kill string -Drift and strap tubing SURE -Cont drifting and strapping 3-1/2" 9.2# L-80 NSCT cond B tubing (kill string) -Strap jewelry: WLEG, X nipple, pup jts, tubing hanger SURE -MU tail pipe assy: WLEG + 3-1 /2" 9.2# L-80 TCI I pup jt + X nipple + 3-1/2" 9.2# L-80 TCII pin x NSCT box pup jt. -MU and RIH 3-1/2" 9.2# L-80 NSCT cond B tubing. Printed: 4/18/2008 1:43:03 PM MPS-31 Notice of operations shut down Maunder, Thomas E (DOAj From: Maunder, Thomas E (DOA} Sent: Friday, April 18, 2008 11:54 AM To: 'Mcleiian, Bryan J' Cc: Hubble, Terrie L; Stewman, Sondra D; Reem, David C Subject: RE: MPS-31 (202-014) Notice of operations shut down Brian, I confirm our conversation and have informed Commissioner Foerster of your plan. She is in agreement with the proposal. A 403 is needed. The well should be considered suspended. Call or message with any questions. Tom Maunder, PE AOGCC From: McLellan, Bryan ] jmailto:Bryan.McLellan@bp.com] Sent: Friday, April 18, 2008 11:44 AM To: Maunder, Thomas E (DOA) Cc: Hubble, Terrie L; Stewman, Sondra D; Reem, David C Subject: MPS-31 Notice of operations shut down Page 1 of 1 Tom, As we discussed last night on the phone, we are planning to shut down operations on MPS-31 {Sundry # 308- 095). The original scope of work was to repair a shallow surtace casing leak. Work completed so far is as follows: 1. Pull 3-1/2" tubing down to the tubing cut at 7601' md. 2. Set RBP at 2000' md. 3. Remove ~45' of 7" surface casing. 4. Run new 7" surface casing and install wellhead. 5. Pump cement top job to fill up 7" x 20" conductor annulus. 6. Pressure test casing to 1500 psi FAILED. Identify casing teak between 73' and 82' and (at the casing patch). 7. Run 3.5" kill string fio 1930' md. Freeae protect with diesel to 1930' md. The plan is to rig down, move off and develop a new plan to repair the leak in the 7" casing. The well is secured with 2 barriers: 1. 7" x 3.5" Baker S-3 production packer at 7630' and with a XXN plug in the tubing tail at 7655' md. 2. 7" RBP at 2000' md. 1've attached a wellbore schematic of the current condition of the well. «MPS-31 Ops Shut Down.pdf» Please call if you have any questions or concerns regarding this well. Thank you, Bryan McLellan BP Exploration, Alaska 564-5516 4/22/2008 • • ~.~ ~~ mm.~„ L .,~ ~.„g ,,,~ I„~ ~~ ~.. L`_M1 ~~~ ~~ ~ ~ SARAH PALlN, GOVERNOR °~~ OII, SID G.~S 333 W. 7th AVENUE, SUITE 100 C011T5ERQATIOI~T CO.1-II-IISSI019T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907j 276-7542 David Reem Engineer Team Leader BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 ~'~ ~~k ~ SOD Re: Milne Point Unit, Schrader Bluff Oil Pool, MPS-31 Sundry Number: 308-095 ~ O , ~~ 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 unless rehearing has been requested. Sincerely, ~~ Daniel T. Seamount, Jr. Chair DATED this ~ day of April, 2008 Encl. ~~~ STATE OF ALASKA / f~ ~~~ ~ n q,/ ALAS~IL AND GAS CONSERVATION COMM N ~j„ MAR 2 6 ~~~"d APPLICATION FOR SUNDRY APPR VA`~"~~ ~' 20 AAC 25.280 Oil & GaS COt1S. ~ISSIOf1 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Exte ®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 202=t'4a-OJ 3. Address: ®Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23066-00-00 ' 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: MPS-31 Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 380109 - 73.54 ~ Milne Point Unit / Schrader Bluff 12: PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8173 4287 8132 ~ 4278 ` None None n h 'z M r c r I 7 ' 1 2' 1 8 7" 1 4 7 ' 7240 410 t rm i in r Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7846' - 7920' 4046' - 4106' 3-1 /2", 9.2# L-80 7668' Packers and SSSV Type: 7" x 3-1/2" S-3 Perm Packer Packers and SSSV MD (ft): 7630' 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: April 11, 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, 564-5a71 Printed Name D vi Reem Title Engineering Team Leader Prepared ey Name/Number: Signature Phone 564-5743 Date.3~L ~ ~Jj3 Sondra Stewman, 564-x750 Commission Use Onl Sundry Number: 3 g- Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity BOP Test `~~Aechanical Integrity Test ^ Location Clearance Other: 3~®® ~~ µ`~\ ~v~Q~~ ~S~ Subsequent Form Required: 1-'~0~\ A roved B COMMISSIONER THE COMMISSION Date Form 10-403 Revised~6/2006 / Submit In-Duplicate ORIGINAL ~.1;~~~ M~~o • • by Milne Point MPS-31 Rig Workover (Surface Casing Leak Repair) Scope of Work: Expense RWO -Pull 3-'h" L-80 completion, cut and pull 7" surface casing within the conductor pipe, tie-back w/ new 7" surface casing and wellhead, and run 3-'/z" L-80 completion. MASP: 1240 psi Well Type: Schrader Bluff Water Injector Estimated Start Date: April 11th, 2008 Production Engineer: Mark Sauve Intervention Engineer: Howard West Pre-Riq Work Reauest: S 1 Pull XXN plug from XN Nipple C~3 7655' md. Obtain SBHPS data. Re-run XXN plug to 7655' md. MIT-T to 1000 psi to confirm plug is competent as a barrier. Drift tubing for Jet cutter throu h the acker if lu is considered insufficient as a drift. E 2 Power jet cut 3-1/2" L-80 tubing at 7627' md, approximately 1 foot above the x/o directly above the acker. Reference tubin tall dated 08/14/02. F 3 Circulate well with seawater or 2% KCI and diesel thru the cut. W 4 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. W 5 Set a BPV in the tubin han er. O 6 Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU rig Doyon 14. ND tree. NU and test ROPE to 3500 psi. Circulate out freeze protection fluid and circulate well to clean kill weight fluid through the tubing cut. 2. Pull and LD 3.5" tubing string to the cut. 3. Run and set 7" RTTS to ~30' below ground level. Test 7" casing from below the RTTS to the production packer at 7630' and to 3500 psi. Pull RTTS test packer. 4. Run 7" RBP and set below the 7" casing leak (leak thought to be at ~12 feet below ground level). Stack ~50 ft of sand on RBP. 5. ND BOP stack. Remove wellhead from 7" surface casing. 6. Wash over 7" surface casing to below leak depth. Will not wash below conductor at 80'. 7. Mechanically cut 7" casing below leak (~20 - 50' below ground level). Pull 7" casing out of the hole. Dress off 7" casing stub in preparation of running 7" casing patch. 8. Run new 7" casing and overshot the existing 7" casing stub with an external casing patch. 9. Install new wellhead on 7" surface casing. 10. Perform cement top job on 7" x conductor annulus. Cement to surface. 11. NU BOP stack and test the body to 3500 psi. 12. Pull 7" RBP. 13. Mill up and remove 7" x 3-1/2" Baker S3 production packer at 7630' md. • 14. Clean out fill to below bottom pert at 7920' md. 15. Run 3-'/z" L-80 completion with packers set at --7610' md, 7750' and and 7888' md. Note that if 3- 1/2" tubing is not readily available, 4-1/2" tubing will be run instead. The completion will have water flow regulator valves between the packers to regulate injection into each zone. 16. Displace the IA to packer fluid. Set the packer. 17. Pressure test tubing and IA to at least 1500 psi. 18. Set BPV. ND BOPE. NU and test tree. RDMO. Tree: Cameron 7-1 /16", 5M Ilhead: FMC 11 " gen 5 casing hanger. 20"x 34" insulated, 215 #/ft A-53 80` KOP @ 571 ` to 941' Max. hole angle = 77.8 deg @ 4039 'i Hole angle thru' perfs = . ~I 3.5", 9.2 ppf, L-80 IBT but. Tbg. (cap. = 0.0087 bpf, drift = 2.867") 7" 26#, L-80, BTRC Casing (drift ID = 6.151, cap.= .0383 bpf) Perforation Summary SWS Slim Cement bond log dated 8 March Size Spf Interval (TV[ NB Sands 2.5" 2.5 7679'-7681' 3,843' - 3,8 OA Sands 2.5" 4 7,846'-7,876' 4,311 ` - 4,3 OB Sands 2.5" 4 7,900`-7,920' 4,364' - 4,3 2506 Powerjet, HMX 4spf deep penetratii Orig. DF Elev. = 73.54` Orig. GL Elev. = 39.00` HES X-Nipple (2.813") 2,220` HES X-Nipple (2.813") 7,so8° 1.5" Baker "S-3" Perm. packer 7,630' I IES XN-Nipple 2.813" Pkg. 7,655' to-Go 2.75" id ) 3.5" WELL 7,668` ELMD 7,670' joints 7703'-7725' 7" Halliburton Float Collar 8049' 7" Halliburton float shoe 8133' 02/20/02 M. Linder Drilled by Nabors 27-E 8/16/02 MDO Initial Completion Doyon 141 / Perfs 7/22/03 M. Linder Add NB sand pert interval MILNE POINT UNIT WELL No.: S-31 i API : 50-029-23066-00 I~PU S-31 i -31 i Proposed Orig. DF Elev. = 73.54` Orig. GL Elev. = 39.00` 20"x 34" insulated, 215 #/ft A-53 80' KOP @ 571' to 941' Max. hole angle = 77.8 deg @ 4039 Hole angle thru' perfs = . 3.5", 9.2 ppf, L-80 TC-II. Tbg. (cap. = 0.0087 bpf, drift = 2.867") 7" 26#, L-80, BTRC Casing (drift ID = 6.151, cap.= .0383 bpf) ' Perforation Summary SWS Slim Cement bond log dated 8 March Size Spf Interval (TVI NB Sands 2.5" 2.5 7679'-7681' 3,843' - 3,£ OA Sands 2.5" 4 7,846'-7,876' 4,311' - 4,: OB Sands 2.5" 4 7,900'-7,920' 4,364' - 4,: ~2.5" 2506 Powerjet, HMX 4spf deep penetrate 02/20/02 M. Linder Drilled by Nabors 27-E 8/16/02 MDO Initial Completion Doyon 141 / PerFs 7/22/03 M. Linder Add NB sand pert interval 3/24/08 B. McLellan Proposed RWO HES X-Nipple (2.813") '2200' I 1.5" GLM 7500' iES X-Nipple (2.813") 7600' 3.5" Baker "S-3" Perm. packer 7,610` 1.5" GLM's ~ I 1.5" Baker "S-3" Perm. packer 7,750' I 1.5" GLM's 0 sg joints 7703'-7725' I .5" Baker "S-3" Perm. packer 7888' 1.5" GLM's 1ES XN-Nipple 2.813" Pkg. Jo-Go 2.75" id) NELG 7" Halliburton Float Collar 8049` 7" Halliburton float shoe 8133' MILNE POINT UNIT WELL No.: S-31 i API : 50-029-23066-00 BP EXPLORATION (AK) RE: MPS-31 (PTD #2020140) Failed MITIA • L J Subject: RE: MPS-3L(PTD #2020140) Failed MITIA From: "NSU, ADW Well Inteblty Engineer" <NSUADWWeIIIntegrityEn~ineer@BP.coin> Date: Mon, 02 Apr 2007 10:06:36 -0800 To: Thom~is ~~laundcr <tom maunder(~admin.~tat~.ak.us ~, "?NSU, ADW Well lnt~~~rity f_;il~incer„ <NSUAD~~~ ~~'cl lintc~rily~n~~inc~r!u':BP.com~>~ CC: jim Re~~`~r <_limre~~~~'u'aclmi~i.state.ak.us> Tom, I'm sorry about that. I have attached a TIO plot as well as an injection plot for further reference. Thank you, Andrea Hughes -----Original Message----- From: Thomas Maunder [mailto;tom ma;~i:der_~~?admin.state,ak.us] Sent: Monday, April 02, 2007 9:40 AM To: NSU, ADW Well Integrity Engineer Cc: jim Regg Subject: Re: MPS-31 (PTD #2020140) Failed MITIA Andrea, Do you have a TIO plot for this well? Thanks, Tom Maunder, PE AOGCC NSU, ADW Well Integrity Engineer wrote, On 4/1/2007 4:14 PM: Hello Tom and Jim, ', Well MPS-31 (PTD #2020140) failed an MITIA on 03/31/07. The inner ', annulus was pressured to 1600 psi when fluid was observed flowing from the conductor into the cellar. The well has been shut-in and is scheduled for a tubing plug. The plan forward is as follows: 1. WIC: Shut-in well - DONE i 2. SL: Set TTP A wellbore schematic has been included for reference. «MPS-31-1.ZIP » ', Please call with any questions. Thank you, *Andrea Hughes* Well Integrity Coordinator Office: {907) 659-5102 Pager: (907) 659-5100 x1154 ,~ ~~~ ~~ `s . F+ Content-Description: MPS-31 TIO.ZIP 'MPS-31 TIO.ZIP Content-Type: application/x-zip-compressed Content-Encoding: base64 1 of ~ ~ 4/2/2007 10:11 AM Tree: Cameron 7-1116", 5M „'~' Wellhead: FIYtC 11" gen 5 casing prig. ni= Elev. = 73.54` hanger. ~~-~1 ~ prig. GL Elev. = 39.fl0` 20"x 34" insulated, 215 #/ft A-53 80' KOP @ 571 ` to 941 ` Max. hole angle = 77.8 deg ~ 4039° Hole angle thru' perfs = . 3.5"': 9.2 ppf, L-80 IBT but. Tbg. {cap. _ {3.0087 bpf, drift = 2.667°) 7" 26#, L-80, BTRC Casing (drift ID = 6.151, cap.= .0383 bpf) Perfaration Summary SWS Slim Cement bond log dated 8 March 02 Size Spfi Interval (TVD) NB Sands 2.5" 2.5 7679'-7681' 3,843' - 3,844' OA Sands 2.5" 4 7,846`-7,876' 4,311' - 4,331' OB Sands 2.5" 4 7,900`-7,920' 4,364' - 4,384' (2.5" 2506 Powerjet, HMX 4spf deep penetrating I ` .»: , L rt I~ _ _~ 3.5" HES X-Nipple (2.813") 2,220` 3.5" HES X-Nipple (2.813") 7,6os' 7" x 3.5" Baker "S-3" Perm. packer 7,630' 3.5" HES XN-Nipple 2.813" Pkg. 7,655` (No-Go 2.75" id ) 3.5" WELG 7,668` ELMD 7,670` Short joints 7703'-7725' DATE REV. BY COMMENTS 02/20/02 M. Linder Drilled by Nabors 27-E 8/16/02 MDO Initial Completion Doyon 141 / Perfs 7/22/03 M. Linder Add NB sand pert interval __ _ . ~,oao _ _ _ MP'I TI~PIot _. o,ooa a,aaa ~__r:~7,~,,,~,_~, ~ ,aoa a ~JcJLUU4 4! I lLUV4 -~. a u ~' a Q N1P~~31 daily Alloc~#ed Inj~c#ion Plo# a Q ~r~r~oas sr~rzoas s~r~oos ~arrzaas ~ ~r~r~oas ~r~r~oo~ arzrzao~ Q ~ a~ i . . ·····r·······,·'··,··,·'·· .~ '- ., ,"M'1'" " MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc })~ ~i DATA SUBMITTAL COMPLIANCE REPORT 9/7/2004 Sr ~ I 3 Fl 4.tJ:L- API No. 50-029-23066-00-00 Permit to Drill 2020140 Well Name/No. MILNE PT UNIT SB S-31 Operator BP EXPLORATION (ALASKA) INC // ' ~ U I C 'L:::'.) ----------,--~-~---- MD 8143 ~ TVD 4287 /' Completion Date 8/13/2002 / Completion Status ~~~~/ ~--- ------~--'---- REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name L.E6 C ..Æ1403 See Notes c..ÆÔ/ D ~/ C~ ~/ ~D D Las ED D Las ~ /ED D Las V I ED D Las \ ED D Las (./ L~/ c..Jnje"Ction Profile Well Cores/Samples Information: Log Log Run Scale Media No 1 ~3 LIS Verification c...ro913 See Notes L-eément Evaluation r; 2379 Injection Profile 12379 Spinner I 12379 Temperature 12379 Casing collar locator --12379 Pressure 5 Col 5 8M Name Interval Start Stop Received Sent Well Cored? ADDITIONAL INFORMATION yQ Daily History Received? Chips Received? ---rrfF~ Analysis Received? Formation Tops ~> Current Status 1WINJ /,,~ Directional surve~D~~_~,t ~U:-.', (data taken from Logs Portion of Master Well Data Maint) Interval OHI Start Stop CH Received Comments 113 8143 Case 12/13/2002 Digital Well Logging Data / Rate of Penetration, Dual Gamma Ray, Electromagnetic Wave Resistivity 77 8094 Open 5/9/2002 7100 8026 Case 6/4/2002 SCMT GR, HTEN, CCL 7100 8026 Case 6/4/2002 7550 7950 Case 1/20/2004 Injection Profile 7550 7950 Case 1/20/2004 Injection Profile 7550 7950 Case 1/20/2004 Injection Profile 7550 7950 Case 1/20/2004 Injection Profile 7550 7950 Case 1/20/2004 Injection Profile ~, 7550 7950 Case 1/20/2004 Injection Profile --~--------~-------~ -- Sample Set Number Comments WN G/N -----~---_.._-'--.----'--"--------- DATA SUBMITTAL COMPLIANCE REPORT 9/7/2004 Permit to Drill 2020140 Well Name/No. MILNE PT UNIT SB S-31 Operator BP EXPLORATION (ALASKA) INC MD 8143 Completion Status 1WINJ Current Status 1WINJ TVD 4287 Completion Date 8/13/2002 Comments: 1 ;J~ Date: Compliance Reviewed By: API No. 50-029-23066-00-00 UIC Y -______m."____- - ----.--.-----"-- '3 Ö Jy;j--~~Y-------"- ids ~ II' '( WtlL LOG TRANSMITTAL §Oé9 -Cq ~I ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7th Street Suite 700 3001 Porcupine St. Anchorage, Alaska 99501 RE: Distribution - Final Print( s) 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 : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1389 Stafford, TX 77497 BP Exploration(Alaska), Inc. Petro-Technical Data Center LR2-1 900 East Benson Blvd. Anchorage, Alaska 99508 WELL DATE LOG TYPE DIGITAL OR CD-ROM 1 MYLAR / SEPIA FILM 1 BLUE LINE PRINT(S) REPORT OR BLUELINE Open Hole 1 MPU &31i 11-28-03 Res. Eva!. CH 1 Jê93i-9 1 1 Mech. CH 1 Caliper Survey Signed: ~"~~'~GQb~^,\ Date: RECEIVED Print Name: !,A, f" 2 O. Lf)Q04 ...;,,\,, ' Alaska Oil & Gas Cons.Commi8aton Anchorage PRoACTivE DiAGNOSTic SERVicES, INC., PO Box 1 }69 STAffoRd IX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com ~~~\~ i I i I ~ i I - .j. (' dOd-- C) \~ MECHANICAL INTEGRITY REPORT' '.... ::?UD DA':E: ?-J \ ~ ~'O :) -ß~ M? 0 ~-~ \ ~ OPER & FIELD :.IG RELEJ..S='::. d k~ -CJ d- w~LL NUMBER ~ ~ ~ <..0 \'\ \>.~~ \- 0 -r'\. <ò l ,"')- - ù ';}- <'is \ \ \..,- C ':> ~~LL DATA TD: ~\l-\)HD.. 4d£>\TVD; :?BTD: ~\~~MD 4ð~<6TVD Ca.siTIg: ",\ \ TVD¡ DV: \J~ HI) Shoe: <6\~~ MD .Tvu .:....:"':1e'!:": ~~ HD :"'¡TJ Shoe: till TVD j :OP: :'-loi;:-;g: ~l(d\' P acke:!:" '\<0 ~O HI) '\<o<oß to f\ <6Co 9=' '\<;';>-'0 TVD; Set a. t: ::ole Size S~[)<' anå Perfs ~'6~ ~ "\~ 0 Û ::-::EC?J...NICl-J... INTEGRITY - P .tŒT ¡ 1 Annulus Press Test: 30 min "ZP ¡ 15 min COIIiI:1ents: ,...- HECHJÜ\{ICÞ~ INTEGRITY - PART 42\:J~~~\ç Cement: Volumes:. þ..mt. Liner ~~-; CSg ~~Qt.\( DV \-)~ . , Cmt vol to cover perfs ~~\~'I'-~Œ-IK-\ C~~-\ ~ ~i>~ð Theoretical TOe cg~,,-~~... ~~,,,,--.)\o.. 4'J Cement Bond Log. <Yes or No) 'irt<? ; :rnA.OGCC.~il~ 'i.~~ d-~~ \ðc:...~ ~~~"'~ ~ ~~~\\ d<O . (\. CBL ~valuation, z.~neabovt! ~erfs ~~\a~ ~~\.\..1~([\.'i\~'~':fö'""\: , ~Jt~<t '" ~ l ~...) ~ o.~, \ \; ~ So' o..~ ~a: ~\.::J '<'t\~. "" (C)... ~~ ç: '\ c; c,Q. . <.:.0' \~,-o'\t N~t-.~ l'\\\-~<:''' ~()?~~lt5>~J ~s~~. !S\è.. ~...~\\~ ~~.Y{C('.\;"-L.~ \o~ \~ \("j~(H-'\\---.cH' ~~. ~CL<è <L~'Nt.<t, <é~ \ Proåuc.tion Log: Typ,e Evaluation , ~ CONCLUSIONS: ? ar t: f 1 : ?ar~ ;'2: ~À '\ '"> \I\<L \'1 '. . III 'IyI// ~ (\ q -0 ~ - . - - -- c< RE: Injection Well Request and MPS-30i Subject: RE: Injection Well Request and MPS-3Oi Date: Wed, 18 Jun 2003 12:28:23 -0500 From: "Mathews, William L" <MathewWL@BP.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> Hi Tom, No, Matt didn't forward the note regarding "contruction information on injectors". I'll visit with him to get a copy or if you have time you can copy me on it. The changes we've made to our cementing practices, primarily reciprocating the pipe have helped tremendously in getting good cement...........no big surprise. Hopefully, we won't have another marginal job. Bill -----Original Message----- From: Tom Maunder [mailto:tom maunder@admin.state.ak.usl Sent: Wednesday, June 18, 2003 8:24 AM To: Mathews, William L Subject: Re: Injection Well Request and MPS-30i Hi Bill. Thanks for providing your assessment of MPS-31. When we get a bond log presentation such as this, it is informative to have the assessment of the engineer responsible for the project area. I suspect that you (like me) would have preferred to see a better bond and the rig team is likely striving to achieve that better bond, but what the log shows is likely adequate for the isolation. Did Matt forward the note I sent with regard to providing "construction" information on injectors?? If not, I can forward the note. Best wishes, call with any questions. Tom "Mathews, William L" wrote: > Tom, > I spoke with Gary Elmore at Schlumberger, he is printing off another > copy of the SCMT log run on MPS-30. Hopefully, I'll have it by tomorrow > to send over to you. > > The SCMT log that was run on MPS-31 (March 8, 2002) showed very spotty > cement from TO to surface as evidenced by the amplitudes and casing > collar arrivals. However, fair cement is indicated from 7804' md to > 7898' md and again from 7918' md to 7939' md (compare these intervals to > 7750' md and 7660' md.) This should provide adequate isolation from the > overlying N sand, isolation between the OA and OB, and fair isolation > below the base OB. > > 7778' md (base N sand) > 7804' md (top fair cement interval #1) > 7841' md (top OA sand) > 7873' md (base OA sand) > 7892' md (bottom of fair cement interval#1) 1 of 3 6/19/2003 8:42 AM . RE: Inj~ction Well Request and MPS-30i > 7898' md (top OB sand) > 7918' md (top of fair cement interval #2) > 7939' md (bottom of fair cement interval #2) > > In my opinion, while cement quality is not great, it does appear to be > sufficient for zonal isolation. > > Bill Mathews > Lead Schrader PE > 564-5476 > > -----Original Message----- > From: Green, Matt D > Sent: Thursday, June 12, 2003 1:31 PM > To: 'Tom Maunder' > Cc: Archey, Pat; Mathews, William L > Subject: RE: Injection Well Request and MPS-30i > > Tom, > > We have requested that Schlumberger submit the SCMT log for MPS-30 since > we have only a single copy here. Hopefully, you should receive that > shortly. > > We will re-examine the bond log on MPS-31 and you should have our > interpretation in the near future. > > Cheers, > > Matt. > > -----Original Message----- > From: Tom Maunder [mailto:tom maunder@admin.state.ak.usl > Sent: Thursday, 12 June 2003 8:51 AM > To: Green, Matt D > Cc: Archey, Pat > Subject: Injection Well Request and MPS-30i > > Matt and Pat, > Did you get my email yesterday regarding a procedure for submitting > injection well information and in particular a bond log for MPS-30?? > > I have been looking at MPS-31 and wanted your interpretation of the bond > logs. 2 logs are available in our files, March 8 and April 26, 2002. > The logs are similar in presentation with the more recent log showing > slightly poorer quality cement. It does appear that that the cement is > best in the OA, OB intervals, however the first arrival appears evident > throughout and the collars can be seen though that signal looks > "suppressed" (not ringing loudly). > > Based on the job log, all appears to have gone well with a lot of cement > circulated and I can see why no remedial operations were proposed. > There likely wasn't anywhere to put more cement. I believe Matt > indicated that reciprocation is being practice out there now and the > bond logs have improved. > 2of3 ( 6/19/2003 8:42 AM . RE: Inj~ction Well Request and MPS-30i > As I said, I'd be interested in your interpretation. Thanks. > > Tom Maunder 30f3 6/19/2003 8:42 AM aOèJ-O/<j 1 ('1 ð3 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 July 30, 2002 RE: MWD Fonnation Evaluation Logs: MPS-31, AK-MW-22028 MPS-31: Digital Log Images: 50-029-23066-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNJNG AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: s~~ú~ DEC 1 3 2002 ÞJa~~a & Gas Gcmmïælfm }'\r~chOf¡ge , STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised 10/03/02, Start Injection 1. Status of Well 0 Oil 0 Gas 0 Suspended 0 Abandoned 181 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3263' NSL, 369' WEL, SEC. 12, T12N, R10E, UM At top of productive interval 3269" NSL, 618' WEL, SEC. 11, T12N, R10E, UM At total depth 2366' NSL, 799' WEL, SEC. 11, T12N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 73.54' ADL 380109 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 2/13/2002 2/17/2002 8/13/2002 17. Total Depth (MD+ TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 8143 4287 FT 8132 4278 FT 181 Yes 181 No 22. Type Electric or Other Logs Run MWD, CALIPER, GR, RES, PWD 23. CASING SIZE 20" 7" C. .:J ;'\l~ F t, ~:~!.~ 0 N Classification of Service Well Water Injection 7. Permit Number 202-014 302-247 8. API Number 50- 029-23066-00 9. Unit or Lease Name Milne Point Unit V-S;¡ífìEiJ 10. Well Number MPS-31 i 11. Field and Pool Milne Point Unit 1 Schrader Bluff 15. Water depth, if offshore 16. No. of Completions NIA MSL One 20. Depth where SSSV set 21. Thickness of Permafrost NIA MD 1800' (Approx.) WT. PER FT. 92# 26# GRADE H-40 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD 34' 112' 42" 260 sx Arctic Set (Approx.) 34' 8133' 9-7/8" 1250 sx Class 'L', 350 sx Class 'G' AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 3-3/8" Gun Diameter, 4 SPF MD TVD 25. SIZE 3-1/2", 9.2#, L-80 TUBING RECORD DEPTH SET (MD) 7668' PACKER SET (MD) 7630' MD TVD 7846' - 7866' 7900' - 7920' 4047' - 4062' 4090' - 4106' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 75 Bbls of Diesel 27. Date First Production September 6, 2002 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Water Injection PRODUCTION FOR Oil -BBl TEST PERIOD GAs-McF WATER-BBl CHOKE SIZE GAS-Oil RATIO Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE Oll-BBl GAs-McF WATER-BBL OIL GRAVITY-API (CORR) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. 1tftCË iV"E D OCT 0 4 2002 No core samples were taken. Form 10-407 Rev. 07-01-80 Alaska Oil & Gas Gons. Commission Ancho~ Submit In Duplicate 29. Geologic Markers Marker Name Measured Depth SBF2_NA 7633' SBF1_NB 7665' SBE4_NC 7708' SBE2_NE 7727' SBE1_NF 7790' TSBD_OA 7834' TSBC 7868' TSBB_OB 7896' SBA5 7927' 31. List of Attachments: ( 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 3882' 3906' 3938' 3953' 4002' 4037' 4064' 4086' 4111' RIt!~IVED OCT 0 4 2002 Alaska OiJ& Gas Gons. Commission Anchorage 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Son~~ Title Technical Assistant Date LO~O'3~02. MPS-31i 202-014 302-247 Prepared By Name/Number: Sandra Stewman, 564-4750 Well Number Permit No. I Approval No. Drilling Engineer: Robert Odenthal, 564-4387 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well 0 Oil 0 Gas 0 Suspended 0 Abandoned 181 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O.,BOX 196612, Anchorage, Alaska 9~9519-6612 ;-;:',,;,',.'-''''-, .,",-,~ t7(~"~:":~a""'¡" 4. Location of well at surface !~",,' . I..KI 1 I~-~. ".-::." ~:P~!E~~~~t~tl~~.~~',:~::,:~::,~: i,:,', ~c~,:';';~, ;2.jl"., t';~";' j At total depth , ~ ,,--. ,.~~ 2366' NSL, 799' WEL, SEC. 11, T12N, R10E, UM 1- ""..."""."\,'::,1" 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 73.54' ADL 380109 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 2/13/2002 2/17/2002 8/13/2002 17. Total Depth (MD+ TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 8143 4287 FT 8132 4278 FT 181 Yes 0 No 22. Type Electric or Other Logs Run MWD , CALIPER, GR , RES, PWD Classification of Service Well Water Injection 7. Permit Number 202-014 302-247 8. API Number 50- 029-23066-00 9. Unit or Lease Name Milne Point Unit 10. Well Number MPS-31 i 11. Field and Pool Milne Point Unit 1 Schrader Bluff 15. Water depth, if offshore 16. No. of Completions NIA MSL One 20. Depth where SSSV set 21. Thickness of Permafrost NIA MD 1800' (Approx.) 23. CASING SIZE 20" 7" GRADE H-40 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD 34' 112' 42" 260 sx Arctic Set (Approx.) 34' 8133' 9-7/8" 1250 sx Class 'L', 350 sx Class 'G' AMOUNT PULLED WT. PER FT. 92# 26# 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 3-3/8" Gun Diameter, 4 SPF MD TVD 25. SIZE 3-1/2", 9.2#, L-80 MD TVD TUBING RECORD DEPTH SET (MD) 7668' PACKER SET (MD) 7630' 7846' - 7866' 7900' - 7920' 4047' - 4062' 4090' - 4106' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 75 Bbls of Diesel 26. 27. Date First Production Not on Injection Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) NIA PRODUCTION FOR OIL-BBL TEST PERIOD GAs-McF WATER-BBL Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL-BBL GAs-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO OIL GRAVITY-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. !;~ur!'}~::fr, ~h'~ No core samples were taken. . . 28. Form 10-407 Rev. 07-01-80 GY: R B 0 I~ S B Ft' AUG 2 7S~t In Duplicate 29. Geologic Markers Marker Name Measured Depth SBF2_NA 7633' SBF1_NB 7665' SBE4_NC 7708' SBE2_NE 7727' SBE1_NF 7790' TSBD_OA 7834' TSBC 7868' TSBB_OB 7896' SBA5 7927' 31. List of Attachments: 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 3882' 3906' 3938' 3953' 4002' 4037' 4064' 4086' 4111' Summary of Daily Drilling Reports, Surveys and Leak off Test Summary MPS-31 i Well Number Technical Assistant Date 08 - ~~ "0""2..- Permit No. / Approval No. Prepared By Name/Number: Sandra Sfewman, 564-4750 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ( BP EXPLORATION Operations Summary Report Page 1 of 3 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-31 MPS-31 DRILL +COMPLETE NABORS NABORS 27ES Start: 2/11/2002 Rig Release: 2/19/2002 Rig Number: 27E Spud Date: 2/13/2002 End: 2/19/2002 Date From - To Hours Activity Code NPT Phase Description of Operations 2/11/2002 12:00 - 16:30 4.50 MOB P PRE PJSM WITH PEAK AND NABORS PERSONNEL. MOVE PUMP ROOM AND MOTOR COMPLEX. 16:30 - 18:00 1.50 MOB P PRE MOVE PIPE SHED MATS OUT OF THE WAY. PULL SUB OFF MPS-21i AND MOVE SUB TOWARD MPS-31i. 18:00 - 19:30 1.50 MOB P PRE PICK UP SUB MATS. SPREAD HERCULlTE AND SPOT MATS ON MPS-31i. CLEAN UP OLD HERCULlTE FROM AROUND MPS-21 i. 19:30 - 21 :00 1.50 MOB P PRE SPOT SUB ON MPS-31 i. 21 :00 - 00:00 3.00 MOB P PRE SET MATS FOR PIPE SHEDS AND SPOT FIRST SECTION. SPOT PITS AND SET MATS. SPREAD HERCULlTE. HOOKED UP INTERCONNECT BEFORE RELEASING TRUCK F/ PITS. 2/12/2002 00:00 - 01 :30 1.50 MOB P PRE SPOT MOTOR COMPLEX. 01 :30 - 03:00 1.50 MOB P PRE SPOT PUMP COMPLEX. 03:00 - 05:00 2.00 MOB P PRE SET MATS AND SPOT PIPE SHED HALF. 05:00 - 10:00 5.00 RIGU P PRE HOOK UP ALL UTILITY LINES. SET ALL STAIRS DOWN AND SECURE. REPAIR STEAM VALVE @ MOTOR ROOM INTERCONNECT. START STEAM AROUND. HOOK UP FLOWLINE AT HALLWAY. BERM AROUND RIG. SET CUTTING TANK IN BERM. SET FUEL STORAGE TANK. 10:00 - 11 :30 1.50 RIGU P PRE THAW STEAM RETURN IN CELLAR. ACCEPT RIG AT 11 :30 HRS 2/12/2002 11 :30 - 16:00 4.50 BOPSURP SURF NIPPLE UP 20-1/4" DlVERTER, KNIFE VALVE, DIVERTER LINE AND RISER. BEGAN LOADING PIPE SHED WITH 5" DRILL PIPE. 16:00 - 18:00 2.00 DRILL P SURF FINISHED LOADING PIPE SHED WITH 5" DRILL PIPE. LOADED SPERRY SUN TOOL ON RIG FLOOR. 18:00 - 19:30 1.50 DRILL P SURF FUNCTION TEST DIVERTER. PERFORMED ACCUMULATOR TEST AND TEST ALARMS. TEST WITNESSED BY AOGCC INSPECTOR, LOU GRIMALDI. 19:30 - 00:00 4.50 DRILL P SURF PICKED UP 5" DRILL PIPE FROM THE SHED.. 2/13/2002 00:00 - 02:00 2.00 DRILL P SURF FINISH P/U 5" 168 JTS DRLG PIPE AND STAND IN DERRICK 02:00 - 02:30 0.50 DRILL P SURF PRE SPUD MEETING 02:30 - 06:30 4.00 DRILL P SURF P/U AND MAKE UP BHA #1 SMITH TWIST AND SHOUT WI 3-18 1-12, SPERRY MOTOR WITH 1.5, GAMM/RES. PWD,PM, CALIPER MWD 06:30 - 07:30 1.00 DRILL P SURF CHARGE MUD LINES AND TEST TO 3500 # Printed: 2/20/2002 11 :30:48 AM ( BP.EXPLORA TION Operations Summary Report Page 2 of 3 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-31 MPS-31 DRILL +COMPLETE NABORS NABORS 27ES Start: 2/11/2002 Rig Release: 2/19/2002 Rig Number: 27E Spud Date: 2/13/2002 End: 2/19/2002 Date From - To Hours Activity Code NPT Phase Description of Operations 2/13/2002 07:30 - 00:00 16.50 DRILL P SURF DIRECTIONAL DRILL FROM 112 TO 1759 WITH 80 RPMS, 10-25,000 BIT WT., 410 GALS MIN., 1200 PSI ART 6.75 AST 4.25 ECD 9.9 AV. ROP 150 FT. PER HR. WOOD AT 1,000 FT , GRAVEL THUMB SIZE 2/14/2002 00:00 - 12:30 12.50 DRILL P SURF DIRECTIONAL DRILL FROM 1759 TO 3330 WITH 100 RPMS, 25,000 - 35,000 BIT WT., 500 GALS MIN., 1850 PSI ART 3.5 AST 3.25 ECD 9.9 AV. ROP 220 FT. PER HR. 12:30 - 13:00 0.50 DRILL P SURF CIRC. ONE BOTTOMS UP 13:00 - 16:30 3.50 DRILL P SURF PUMP OUT OF HOLE FROM 3330 TO 1200 NO PROBLEMS 16:30 - 17:30 1.00 DRILL P SURF TRIP OUT WITH BHA 17:30 - 18:30 1.00 DRILL P SURF CHANGE OUT BHA , BIT # 2 SMITH TWIST AND SHOUT WITH 3-141-10 SPERRY MOTOR WITH 1.22 BEND, RES-GAM-PWD-PM-MWD 18:30 - 20:00 1.50 DRILL P SURF DOWN LOAD MWD AND UPLOAD MWD 20:00 - 20:30 0.50 DRILL P SURF SERVICE TOP DRIVE 20:30 - 23:00 2.50 DRILL P SURF TRIP IN HOLE NO PROBLEMS, WASH 60 FT. TO BOTTOM 23:00 - 00:00 1.00 DRILL P SURF DIRECTIONAL DRILL FROM 3330 TO 3456 WITH 120 RPMS, 10-25,000 BIT WT., 500 GALS MIN., 1850 PSI ART 1 AST 0 ECD 9.9 AV. ROP 126 FT. PER HR. 2/15/2002 00:00 - 21 :30 21.50 DRILL P SURF DIRECTIONAL DRILL FROM 3456 TO 6144 WITH 120 RPMS, 20-35,000 BIT WT., 510 GALS MIN., 2200 PSI ART 7.8 AST 2 ECD 9.9 AV. ROP 271 FT. PER HR. 21 :30 - 23:30 2.00 DRILL P SURF CIRC. TWO BOTTOMS UP, SET BACK ONE STAND EVERY 30 MIN. 23:30 - 00:00 0.50 DRILL P SURF SHORT TRIP, PUMPING OUT WITH 400 GALS MIN, 1400 PSI, NO PROBLEMS 2/16/2002 00:00 - 04:30 4.50 DRILL P SURF FINISH SHORT TRIP, PUMPED OUT TO 1900 PULLED OUT TO 1500, NO PROBLEMS, 04:30 - 07:30 3.00 DRILL P SURF TRIP IN , TIGHT SPOT @ 4858 WORKED TRU NO PROBLEM, WASH 60 FT TO BOTTOM 07:30 - 11 :00 3.50 DRILL P SURF DIRECTIONAL DRILL FROM 6144-6828 WITH 120 RPMS, 20-35,000 BIT WT., 510 GALS MIN., 2400 PSI. 11 :00 - 11 :30 0.50 DRILL P SURF CIRC. 11 :30 - 00:00 12.50 DRILL P SURF DIRECTIONAL DRILL FROM 6828 TO 7765 WITH 100 RPMS, 20-35,000 BIT WT., 510 GALS MIN., 2400 PSI ART5.15 AST 9.60 ECD 9.9 AV. ROP 110 FT. PER HR. 2/17/2002 00:00 - 04:30 4.50 DRILL P SURF DIRECTIONAL DRILL FROM 7765 TO 8143 WITH 100 RPMS, 20-35,000 BIT WT., 510 GALS MIN., 2400 PSI ART 2.25 AST 1 ECD 9.9 AV. ROP 116 FT. PER HR. 04:30 - 08:00 3.50 DRILL P SURF CIRC THREE BOTTOMS UP WI 550 GALS MIN, 120 RPM, 2750 PSI. STAND BACK ONE STAND EVERY 30 MINS 08:00 - 12:00 4.00 DRILL P SURF TRIPPING OUT TO 823 NO PROBLEMS 12:00 - 12:30 0.50 DRILL P SURF SERVICE RIG 12:30 - 17:00 4.50 DRILL P SURF TRIP TO BOTTOM @ 8143 NO PROBLEMS 17:00 - 20:00 3.00 DRILL P SURF CIRC THREE BOTTOMS UP W/ 550 GALS MIN, 120 RPM, 2750 PSI. 20:00 - 00:00 4.00 CASE P SURF TRIPPING OUT FOR CSG @ 823 2/18/2002 00:00 - 04:00 4.00 CASE P SURF LAY DOWN MWD TOOLS AND DOWN LOAD MWD TOOL (HAD TROUBLE REMOVING PLUG FROM MWD TOOL THAT IS USED FOR DOWN LOADING) 04:00 - 06:30 2.50 CASE P COMP CLEAR FLOOR AND RIG UP CSG TOOLS 06:30 - 07:00 0.50 CASE P COMP PJSM ON RUNNING CSG 07:00 - 15:30 8.50 CASE P COMP PICK UP AND RUN 199 JTS 7" 26# L-80 BTC CSG TO 8133. - Printed: 2/20/2002 11 :30:48 AM ( ( Bf> . EXPLORATION Operations..SummaryReport Page 30f3 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-31 MPS-31 DRILL +COMPLETE NABORS NABORS 27ES Start: 2/11/2002 Rig Release: 2/19/2002 Rig Number: 27E Spud Date: 2/13/2002 End: 2/19/2002 Date From - To Hours Activity Code NPT Phase Description of Operations 2/18/2002 07:00 - 15:30 8.50 CASE P COMP LAND ON LANDING RING WITH 85,000# 15:30 - 16:30 1.00 CASE P COMP CIRC TRU FRANKS FILLUP TOOL - STAGE UP TO 8 BBLS MIN. 600 PSI 16:30 - 17:00 0.50 CEMT P COMP RIG DOWN FRANKS TOOL AND RIG UP CEMENTING HEAD 17:00 - 18:00 1.00 CEMT P COMP CIRC FOR CEMENTING JOB- PRE JOB SAFETY MEETING ON CEMENTING 18:00 - 23:00 5.00 CEMT P COMP CMT 7"- TEST LINES TO 3000 PSI- PUMP SPACER- DROP PLUG MIX AND PUMP 10.7 PPG TYPE L LEAD CMT 1250 SX- FOLLOWED W/350 SX 15.8 TAILCMT- DROP TOP PLUG DISPLACE WITH 192 BBLS BRINE 11.0 FOLLOW WITH 120 BBLS DIESEL, BUMP PLUG WITH 2,000 # AND FLOATS OK, GOT BACK 312 BBLS OF GOOD CEMENT TO SURFACE, MIX LEAD CEMENT @ 6 BBLS MIN., TAIL@ 5 BBLS MIN, DISPLACE @ 5.5 BBL MIN. 23:00 - 00:00 1.00 CEMT P COMP FLUSH RISER AND RIG LINES, RIG DOWN CEMENTING HEAD 2/19/2002 00:00 - 01 :30 1.50 CASE P COMP RIG DOWN - LAY DOWN LANDING JOINT - CLEAN RIG FLOOR OF CASG EQUIPMENT - BLOW DOWN ALL MUD LINES 01 :30 - 04:00 2.50 CASE P COMP NIPPLE DOWN BELL NIPPLE - DIVERTER SYSTEM 04:00 - 08:00 4.00 CASE P COMP NU FMC GEN 6 WELL HEAD - ENERGIZE WELLHEAD WITH 1 STD OF HEAVY WEIGHT AND TOP DRIVE 30K ON HEAD - TEST VOID 1000 PSI FOR 10 MINS - TEST ADAPTER FLANGE VOID 1000 PSI 10 MINS - CLEAN CELLER OF ALL TOOLS TRASH - SUCK OUT WITH SUPER SUCKER 08:00 - 13:00 5.00 CASE P COMP RIG UP TO LD 5" DP IN MOUSE HOLE FROM DERRICK - LAYING DOWN 5" DP - PREPARED MUD PITS FOR RIG MOVE - SUCKING FLUID FROM PITS 13:00 - 14:00 1.00 CASE P COMP PJSM WITH HB&R - RIG UP AND TEST CASG TO 4500 PSI - RIG DOWN 14:00 - 16:30 2.50 CASE P COMP CON'T LAY DOWN 5" DP FROM DERRICK- 34 STANDS / BHA IN DERRICK - CON'T PREPARE PITS FOR MOVE 16:30 - 18:00 1.50 CASE P COMP FINISH CLEANING PITS - PREP RIG FLOOR - PREPARE PIPË SHED TO MOVE - PREPARE CELLER FOR RIG MOVE - RELEASE RIG AT 18:00 HRS 02/19/2002 Printed: 2/20/2002 11 :30:48 AM BP EXPLORATION Operations Summary Report Page 1.of2 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-31 MPS-31 COMPLETION DOYON DOYON 141 Start: 8/11/2002 Rig Release: 8/14/2002 Rig Number: 141 Spud Date: 2/13/2002 End: 8/14/2002 Date From - To Hours Task Code NPT Phase Description of Operations 8/11/2002 18:00 - 20:00 2.00 MOB P PRE PREPARE TO MOVE RIG FROM MPS-03 TO MPS-31I - SET MATTS - MOVE MODULES APART - MOVE SUB OFF MPS-03 20:00 - 00:00 4.00 MOB P PRE MOVE SUB AND SPOT OVER MPS-31 - MOVE UTILITY MODULES IN PLACE - SPOT ROCK WASHER - PIPE SHEDS 8/12/2002 00:00 - 01 :00 1.00 RIGU P PRE SET PIPE SHED - HOOK UP SERVICE LOOPS TO UTILITY MODULES - ACCEPT RIG @ 01 :00 HRS 01 :00 - 02:30 1.50 RIGU P PRE PULLED 71/16" VALVE - 7" ISA BPV - FALSE BOWL - HOLD DOWN FLANGE 02:30 - 04:00 1.50 RIGU P PRE NIPPLE UP BOP'S 04:00 - 09:00 5.00 BOPSUR P COMP RIG UP TESTING EQUIPMENT - TEST BOP'S - ANNULAR 250 LOW 2500 HIGH 5 MINS EA - TOP RAMS I BTM RAMS 250 LOW 3500 HIGH 5 MINS EA - CHOKE MANIFOLD I CHOKE MANUAL I HYD - KILL MANUAL I HYD 250 LOW 3500 HIGH 5 MINS EA - FLOOR SAFETY VALVES I LOWER IBOP 250 LOW 3500 HIGH 5 MINS EA - UPPER IBOP FAILED 09:00 - 16:30 7.50 BOPSURN SFAL COMP CHANGING OUT UPPER IBOP VALVE - TOP DRIVE FAILURE POSSIBLE LOCKED UP BRAKES - TROUBLE SHOOT TOP DRIVE - WIRING PROBLEMS MOVED TO DIFFERENT LEG 16:30 - 19:30 3.00 BOPSURP COMP CHANGE OUT UPPER IBOP VALVE 19:30 - 20:00 0.50 BOPSUR P COMP TEST IBOP VALVE THAT WAS CHANGED OUT 250 LOW 3500 HIGH 5 MINS EA. 20:00 - 20:30 0.50 BOPSURP COMP INSTALL WEAR RING 20:30 - 22:30 2.00 CLEAN P COMP PU 3.5" DRILL PIPE - RUN IN HOLE TO 3200' 22:30 - 23:30 1.00 CLEAN P COMP DISPLACE 130 BBLS DIESEL FROM WELL WITH FRESH WATER - AT 6 TO 3 BPM 340 PSI 23:30 - 00:00 0.50 CLEAN P COMP CON'T PU 3.5" DRILL PIPE 8/13/2002 00:00 - 03:00 3.00 CLEAN P COMP CON'T RIH PICKING UP SINGLES 3.5" DRILL PIPE FROM 3540' TO 8041 03:00 - 04:00 1.00 CLEAN P COMP DISPLACE WELL TO 9.2 BRINE FROM 11# BRINE AND FRESH WATER - GPM 357 - PP 2150 - RPM 100 04:00 - 05:00 1.00 CLEAN P COMP TEST CASING TO 3500 FOR 30 MINS - TEST GOOD 05:00 - 07:30 2.50 CLEAN P COMP POH FOR HOWCO PERFORATING GUNS 07:30 - 11 :00 3.50 PERF P COMP PJSM - PICK UP HOWCO 3 3/8" HSD GUNS - LOADED WITH 4 SPF RANDOM PHASE RDX SHOT - RIH TO 8010' 11 :00 - 17:00 6.00 PERF P COMP PJSM - RIG UP SCHLUMBERGER - RUN CORRELATION LOG (SCMT) FOR PERFORATING ON DEPTH - LOG SHOWED GUNS OFF DEPTH 92' LOW - PULL WORK STRING UP HOLE 92' - RERUN CORRELATION LOG - OFF DEPTH 3' LOW - PULL WORK STRING UP HOLE 3' - RERUN CORRELATION LOG - ON DEPTH - RA TAG 7743'- RA TAG TO TOP SHOT 103' - TOP SHOT 7846' - PULL E-LlNE OUT OF HOLE - RIG DOWN SCHLUMBERGER 17:00 - 17:30 0.50 PERF P COMP LINE UP ON CHOKE - CLOSE TOP RAM - FIRE GUNS WITH 3500 PSI- PERFORATED 7846' TO 7866' AND 7900' TO 7920' 17:30 - 18:00 0.50 CLEAN P COMP MONITOR GAIN I LOSS - 10 MINS - NO GAIN OR LOSS- CIRC 3300 STKS 277 BBLS 18:00 - 23:00 5.00 PULL P COMP MONITOR WELL - WELL STATIC - LAY DOWN 3.5" DRILL PIPE WORK STRING - HOLE TOOK PROPER FILL Printed: 8/19/2002 10:42:21 AM BP EXPLORATION Operations Summary Report Page 20f 2 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 8/13/2002 8/14/2002 MPS-31 MPS-31 COMPLETION DOYON DOYON 141 Spud Date: 2/13/2002 End: 8/14/2002 Start: 8/11/2002 Rig Release: 8/14/2002 Rig Number: 141 From-To Hours. .. Task Code NPT Phase Descri ption of Operations 23:00 - 23:30 0.50 PULL P CaMP PJSM - LAY DOWN GUNS AND TOOLS -100% FIRED ALL 162 SHOTS 23:30 - 00:00 0.50 RUNCOrvP CaMP PULL WEAR RING - RIG UP DOYON CASING TOOLS FOR RUNNING 3.5" TUBING 00:00 - 00:30 0.50 RUNCOrvP CaMP PJSM (ON RUNNING 3.5" COMPLETION) 00:30 - 06:00 5.50 RUNCOrvP CaMP PICK UP AND RUN 3.5" COMPLETION - MAKE UP TUBING HANGER- 06:00 - 06:30 0.50 RUNCOrvP CaMP LAND TUBING ON HANGER - RILD - BACK OUT LANDING JOINT 06:30 - 07:00 0.50 RUNCOrvP CaMP TEST TWC TO 1000 PSI 07:00 - 08:00 1.00 BOPSURP CaMP NIPPLE DOWN BOP'S 08:00 - 09:30 1.50 WHSUR P CaMP NIPPLE UP ADAPTER FLANGE AND TREE 09:30 - 10:00 0.50 WHSUR P CaMP TEST FLANGE - TREE TO 5K FOR 10 MINS EACH 10:00 - 10:30 0.50 WHSUR P CaMP PULL TWC WITH LUBRICATOR 10:30 - 12:00 1.50 CHEM P CaMP RIG UP HB&R - CIRCULATE 3 BPM -ADD CORRISION INHIBITIOR 25 GAL/'100 BBL ON BACK SIDE 12:00 - 12:30 0.50 CLEAN P CaMP FREEZE PROTECT ANNULUS WITH 75 BBLS DIESEL DOWN BACK SIDE - TAKING RETURNS UP TUBING 12:30 - 13:00 0.50 CLEAN P CaMP DROP BALL DOWN TBG - U-TUBE DIESEL WHILE BALL FALLING ON SEAT 13:00 - 14:00 1.00 DHEQP P CaMP SET BAKER PACKER S-3 - TEST - RECORD TUBING 4000 PSI FOR 30 MINS - BLEED TUBING TO 1500 PSI- TEST ANNULUS TO 3500 PSI FOR 30 MINS - ALL OK - BLEED OF PRESSURE - 80 PSI ON TUBING WHEN TREE SHUT IN 14:00 - 15:00 1.00 CLEAN P CaMP RIG DOWN HB&R - SPOOL UP LINES TEST LINES 15:00 - 15:30 0.50 WHSUR P CaMP SET BPV WITH LUBRICATOR 15:30 - 16:30 1.00 WHSUR P CaMP REMOVE ANNULUS COMPANION VALVE -1502 TUBING FLANGE - SECURE WELL 16:30 - 17:00 0.50 CLEAN P CaMP PICK UP CELLAR - PUMP OUT ALL FLUID 17:00 - 20:00 3.00 CLEAN P CaMP CLEAN MUD PITS - ROCK WASHER - RELEASE RIG @ 20:00 HRS Printed: 8/19/2002 10:42:21 AM Legal Name: MPS-31 Common Name: MPS-31 Test Date Test Type Test Depth (TMD) BP EXPLORATION Leak-Off Test Summary Test Depth (TVD) AMW Surface Pressure Leak Off Pressure (BHP) Page 1 of 1 EMW Printed: 2/20/2002 11 :30:42 AM qVð~DILf 22-Feb-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Re: Distribution of Survey Data for Well MPS-31 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD , M 0 (if applicable) 8,143.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager ecelVE Attachment(s) r,.~ . ~ D ¡'î Þ t¡ "0'/ . ,'~i' L'.; ., r f . ., ", L.... ... Alaska Oil & Gas Cons. CommìSSiof¡ Anchorage DEFNTVE BP EXPLORA TION (ALASKA) INC. Milne Point Unit BPXA MPS-Pad, Slot MPS-31 MPS-31 Job No. AKZZ22018, Surveyed: 17 February, 2002 SURVEY REPORT 22 February, 2002 -, Your Ref: 500292306600 Surface Coordinates: 5999928.39 H, 565642.14 E (10024' 36.9018" H, 149027' 55.7860" W) Surface Coordinates relative to Project H Reference: 999928.39 H, 65642.14 E (Grid) Surface Coordinates relative to Structure: 40.43 S, 703.24 W (True) Kelly Bushing: 73.54ft above Mean Sea Level Si~"'''Y-~ '1'1 DFtILLING seAVlce,. A Halliburton Company Survey Ref: svy10065 Sperry-Sun Drilling Services . Survey Report for MPS-31 Your Ref: 500292306600 Job No. AKZZ22018, Surveyed: 17 February, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit MPS-Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northlngs Eastings Rate Section Comment (It) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 0.00 0.000 0.000 -73.54 0.00 O.OON 0.00 E 5999928.39 N 565642.14 E 0.00 AK-6 BP ,IFR-AK 211 .77 0.180 168.010 138.23 211.77 0.338 0.07E 5999928.07 N 565642.21 E 0.085 -0.01 301.05 0.290 146.280 227.51 301.05 0.65S 0.22 E 5999927.74 N 565642.37 E 0.156 -0.11 391.05 0.480 166.120 317.51 391.05 1.21 S 0.44 E 5999927.19 N 565642.59 E 0.255 -0.24 482.46 0.800 218.480 408.91 482.45 2.088 0.14 E 5999926.31 N 565642.29 E 0.693 0.21 571.50 2.140 228.41 0 497.92 571.46 3.67S 1.49W 5999924.71 N 565640.68 E 1.526 2.08 663.60 3.870 233.930 589.89 663.43 6.64S 5.29W 5999921.70 N 565636.91 E 1.902 6.31 754.96 5.360 232.780 680.95 754.49 11.04 S 11.18W 5999917.26 N 565631.05 E 1.634 12.84 847.71 6.920 233.890 773.17 846.71 16.958 19.15 W 5999911.27 N 565623.14 E 1.687 21.67 941.10 11 .650 232.240 865.31 938.85 26.04 8 31.15 W 5999902.07 N 565611.22 E 5.072 35,00 1034.68 13.560 233.510 956.63 1030.17 38.35 S 47.45 W 5999889.62 N 565595.03 E 2.062 53.09 1127.12 15.000 234.430 1046.21 1119.75 51.76 S 65.89 W 5999876.05 N 565576.71 E 1.577 73.48 1223.52 16.760 237.580 1138.93 1212.47 66.47 S 87.77W 5999861.15 N 565554.96 E 2.032 97.48 1315.31 19.080 235.620 1226.26 1299.80 82.04 S 111 .33 W 5999845.38 N 565531.54 E 2.611 123.27 1410.22 21.970 231.980 1315.14 1388.68 101.748 138.12 W 5999825.44 N 565504.91 E 3.327 152.93 1501.70 23.030 229.070 1399.66 1473.20 124.008 165.13 W 5999802.94 N 565478.11 E 1.680 183.21 1596.29 26.800 228.050 1485.43 1558.97 150.39 S 194.98 W 5999776.29 N 565448.49 E 4.011 216.98 1689.85 26.120 227.540 1569.19 1642.73 178.39 S 225.86 W 5999748.02 N 565417.86 E 0.766 252.03 1784.77 28.940 231.260 1653.36 1726.90 206.88 S 259.19 W 5999719.24 N 565384.77 E 3.478 289.59 1878.57 29.240 232.410 1735.33 1808.87 235.05 S 295.05 W 5999690.75 N 565349.17 E 0.676 329.57 "-0 1972.56 28.930 232.520 1817.46 1891.00 262.89 S 331.28 W 5999662.60 N 565313.18E 0.335 369.88 2065.55 31.310 232.520 1897.89 1971.43 291.28 S 368.31 W 5999633.88 N 565276.41 E 2.559 411 .05 2159.66 32.880 236.780 1977.63 2051 .17 320.16 S 409.09 W 5999604.65 N 565235.88 E 2.926 456.02 2253.45 35.360 239.650 2055.27 2128.81 347.83 S 453.82 W 5999576.59 N 565191.40 E 3.152 504.67 2347.67 39.010 242.970 2130.33 2203.87 375.09 S 503.78 W 5999548.89 N 565141.67 E 4.420 558.43 2438.37 43.090 247.240 2198.73 2272.27 400.07 S 557.81 W 5999523.44 N 565087.87 E 5.456 615.82 2535.84 47.390 250.450 2267.36 2340.90 424.96 S 622.35 W 5999497.97 N 565023.55 E 4.992 683.57 2630.76 53.340 253.270 2327.88 2401.42 447.63 S 691.80 W 5999474.69 N 564954.30 E 6.672 755.79 2725.58 59.830 255.460 2380.08 2453.62 468.90 S 767.98 W 5999452.76 N 564878.31 E 7.110 834.43 2819.27 66.170 256.990 2422.59 2496.13 488.73 S 849.02 W 5999432.21 N 564797.45 E 6.921 917.62 -- ----~-~-- ---_._._---_._~--~ 22 February, 2002 - 15: 15 Page2of5 Dri/lQuest 2.00.09.008 Sperry-Sun Drilling Services . Survey Report for MPS-31 Your Ref: 500292306600 Job No. AKZZ22018, Surveyed: 17 February, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit MPS-Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eøstlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 2915.31 72.810 258.080 2456.22 2529.76 508.12 S 936.81 W 5999412.06 N 564709.83 E 6.995 1007.40 3011.78 76.740 260.850 2481.56 2555.10 525.11 S 1028.30 W 5999394.26 N 564618.50 E 4.926 1100.44 3105.24 76.380 263.780 2503.29 2576.83 537.27 S 1118.37 W 5999381.31 N 564528.53 E 3.073 1191.29 ~ 3200.05 76.450 265.090 2525.56 2599.10 546.20 S 1210.09 W 5999371.57 N 564436.89 E 1.345 1283.23 3292.34 76.510 265.930 2547.13 2620.67 553.23 S 1299.55 W 5999363.76 N 564347.50 E 0.887 1372.63 3387.65 76.390 265.820 2569.46 2643.00 559.89 S 1391.97 W 5999356.28 N 564255.15 E 0.169 1464.89 3481.60 76.400 265.640 2591.56 2665.10 566.69 S 1483.03 W 5999348.69 N 564164.15 E 0.187 1555.83 3573.79 75.590 266.680 2613.87 2687.41 572.68 S 1572.27 W 5999341.91 N 564074.96 E 1 .404 1644.86 3665.92 74.160 266.970 2637.91 2711.45 577.61 S 1661.07 W 5999336.20 N 563986.21 E 1.582 1733.26 3759.07 73.980 266.690 2663.48 2737.02 582.56 S 1750.51 W 5999330.46 N 563896.82 E 0.348 1822.30 3852.89 75.950 266.480 2687.81 2761.35 587.96 S 1840.95 W 5999324.27 N 563806.43 E 2.111 1912.41 3944.91 77.130 265.780 2709.23 2782.77 594.00 S 1930.24 W 5999317.45 N 563717.20 E 1 .480 2001.48 4038.57 77.840 265.250 2729.53 2803.07 601.15 S 2021.39 W 5999309.49 N 563626.11 E 0.938 2092.57 4129.28 77.310 265.620 2749.05 2822.59 608.20 S 2109.69 W 5999301.67 N 563537.87 E 0.707 2180.83 4222.49 77.110 265.100 2769.68 2843.22 615.56 S 2200.29 W 5999293.52 N 563447.34 E 0.585 2271.41 4316.55 76.510 265.840 2791.14 2864.68 622.79 S 2291.58 W 5999285.48 N 563356.12 E 0.997 2362.66 4410.98 76.220 265.860 2813.40 2886.94 629.43 S 2383.11 W 5999278.04 N 563264.65 E 0.308 2454.04 4503.34 77.080 266.430 2834.73 2908.27 635.47 S 2472.77 W 5999271.21 N 563175.05 E 1.108 2543.47 4598.94 76.950 266.020 2856.21 2929.75 641.61 S 2565.73 W 5999264.26 N 563082.15 E 0.439 2636.18 4693.23 77.440 266.310 2877.11 2950.65 647.76 S 2657.46 W 5999257.30 N 562990.47 E 0.600 2727.68 ,~, 4788.61 75.810 265.240 2899.17 2972.71 654.59 S 2750.00 W 5999249.66 N 562898.00 E 2.028 2820.09 4884.87 75.810 265.010 2922.77 2996.31 662.52 S 2842.99 W 5999240.91 N 562805.09 E 0.232 2913.12 4977.41 75.820 264.720 2945.45 3018.99 670.55 S 2932.34 W 5999232.09 N 562715.80 E 0.304 3002.58 5071.94 75.630 265.130 2968.76 3042.30 678.65 S 3023.60 W 5999223.19 N 562624.63 E 0.466 3093.93 5164.76 76.230 263.910 2991.32 3064.86 687.25 S 3113.22 W 5999213.80 N 562535.08 E 1.429 3183.75 5260.04 77.080 263.600 3013.31 3086.85 697.34 S 3205.37 W 5999202.91 N 562443.02 E 0.947 3276.31 5353.84 75.130 263.260 3035.84 3109.38 707.75 S 3295.83 W 5999191.70 N 562352.66 E 2.108 3367.25 5448.95 74.920 263.120 3060.41 3133.95 718.65 S 3387.06 W 5999180.00 N 562261.53 E 0.263 3459.03 5540.65 76.230 262.450 3083.26 3156.80 729.80 S 3475.16 W 5999168.07 N 562173.53 E 1.594 3547.77 5635.30 77.080 262.550 3105.10 3178.64 741.82 S 3566.47 W 5999155.25 N 562082.33 E 0.904 3639.81 - ~---_._~- ----~._---_._- -- 22 February, 2002 - 15:15 Page 3 of5 Dril/Quesf 2.00.09.008 Sperry-Sun Drilling Services . Survey Report for MPS-31 Your Ref: 500292306600 Job No. AKZZ22018, Surveyed: 17 February, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit MPS-Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 5722.42 75.590 263.290 3125.69 3199.23 752.26 S 3650.47 W 5999144.08 N 561998.42 E 1.899 3724.39 5819.33 76.670 262.760 3148.92 3222.46 763.69 S 3743.86 W 5999131.83 N 561905.14 E 1.234 3818.39 5917.24 74.570 262.900 3173.23 3246.77 775.52 S 3837.95 W 5999119.17 N 561811.15 E 2.149 3913.15 6014.22 72.790 262.640 3200.48 3274.02 787.24 S 3930.28 W 5999106.64 N 561718.93 E 1.853 4006.15 6102.58 73.440 263.080 3226.15 3299.69 797.74 S 4014.18 W 5999095.40 N 561635.13 E 0.876 4090.64 6191.35 73.350 263.300 3251.51 3325.05 807.83 S 4098.64 W 5999084.57 N 561550.75 E 0.258 4175.61 6296.80 73.080 264.770 3281.97 3355.51 818.32 S 4199.05 W 5999073.19 N 561450.44 E 1.359 4276.38 6389.13 73.380 265.430 3308.61 3382.15 825.87 S 4287.13 W 5999064.87 N 561362.43 E 0.758 4364.51 6483.56 73.440 266.210 3335.57 3409.11 832.47 S 4377.39 W 5999057.48 N 561272.24 E 0.794 4454.63 6577.09 74.610 266.620 3361.31 3434.85 838.09 S 4467.13 W 5999051.07 N 561182.55 E 1.320 4544.08 6667.49 75.690 266.120 3384.48 3458.02 843.63 S 4554.33 W 5999044.77 N 561095.40 E 1.309 4631.01 6758.00 76.180 266.110 3406.48 3480.02 849.57 S 4641.93 W 5999038.05 N 561007.86 E 0.541 4718.40 6852.74 75.630 266.190 3429.55 3503.09 855.74 S 4733.61 W 5999031.08 N 560916.24 E 0.586 4809.85 6947.73 73.010 266.580 3455.22 3528.76 861.51 S 4824.87 W 5999024.51 N 560825.03 E 2.786 4900.82 7039.42 69.710 267.350 3484.52 3558.06 866.12 S 4911.62 W 5999019.14 N 560738.32 E 3.686 4987.15 7134.16 65.920 268.070 3520.29 3593.83 869.63 S 4999.26 W 5999014.86 N 560650.72 E 4.062 5074.18 7227.27 61.590 267.030 3561.45 3634.99 873.18 S 5082.67 W 5999010.57 N 560567.34 E 4.757 5157.05 7320.82 57.900 267.130 3608.58 3682.12 877.30 S 5163.36 W 5999005.74 N 560486.69 E 3.945 5237.32 7411.70 53.220 267.470 3659.96 3733.50 880.84 S 5238.21 W 5999001.55 N 560411.88 E 5.159 5311.74 7505.64 48.460 267.730 3719.27 3792.81 883.89 S 5310.96 W 5998997.86 N 560339.15 E 5.072 5384.01 ~,. 7600.86 44.090 268.040 3785.07 3858.61 886.44 S 5379.71 W 5998994.71 N 560270.43 E 4.595 5452.25 7695.71 40.340 268.390 3855.30 3928.84 888.43 S 5443.40 W 5998992.15 N 560206.76 E 3.961 5515.40 7789.86 37.960 268.230 3928.31 4001.85 890.18 S 5502.81 W 5998989.88 N 560147.37 E 2.530 5574.30 7882.11 36.490 268.800 4001.76 4075.30 891.63 S 5558.59 W 5998987.94 N 560091.60 E 1.637 5629.57 7978.31 35.700 269.930 4079.50 4153.04 892.26 S 5615.26 W 5998986.81 N 560034.94 E 1.074 5685.57 8071.22 35.220 269.320 4155.18 4228.72 892.61 S 5669.16 W 5998985.98 N 559981.04 E 0.642 5738.80 8143.00 35.220 269.320 4213.82 4287.36 893.11 S 5710.55 W 5998985.13 N 559939.66 E 0.000 5779.71 Projected Survey -'---------~----'------------"-'-'-"-'---~- -.- --"---'_~_'n-'_.__- -.. -- _---n--_- --.----_~_.__n_~-__~_._-'-~ ------.------..--.-- .." 22 February, 2002 - 15: 15 Page4of5 Dri/lQuesI2.00.09.008 Sperry-Sun Drilling Services Survey Report for MPS-31 Your Ref: 500292306600 Job No. AKZZ22018, Surveyed: 17 February, 2002 . BP EXPLORATION (ALASKA) INC. Milne Point Unit BPXA MPS-Pad All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.060° (17-Feb-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 260.570° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8143.0Oft., The Bottom Hole Displacement is 5779.97ft., in the Direction of 261.111 ° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastlngs (ft) (ft) (ft) Comment 8143.00 4287.36 893.11 S 5710.55 W Projected Survey Survey tool program for MPS-31 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description '~" 0.00 0.00 8143.00 4287.36 AK-6 BP _IFR-AK - --------___-__n"__- --~._- ------------~~--_._-- 22 February, 2002 - 15: 15 PageS of5 Drll/QlJest 2.00.09.008 a~ðl1.{ 22-Feb-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPS-31 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD , MD (if applicable) 8,143.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, Definitive Survey Manager Attachment( s) RECEIVED L;,~ n n t t1í'O? r' ¡:..~\~..~ U' L~ L tJ -- ,Alaska Oil & Gas Ccns. Commission An_e BP EXPLORA TION (ALASKA) INC. Milne Point Unit BPXA MPS-Pad, Slot MPS-31 MPS-31 MWD Job Ho. AKMW22018, Surveyed: 17 February, 2002 SURVEY REPORT 22 February, 2002 ..-,., Your Ref: 500292306600 Surface Coordinates: 5999928.39 H, 565642.14 E (70024'36.9018" H, 149027' 55.7860" W) Surface Coordinates relative to Project H Reference: 999928.39 H, 65642.14 E (Grid) Surface Coordinates relative to Structure: 40.43 5, 703.24 W (True) Kelly Bushing: 73.54ft above Mean Sea Level ~I'::~-'."V-~. .'1'1 D~ILLII\I.a SIiAv,ç:es A Halliburton Company' Survey Ref: svy10068 Sperry-Sun Drilling Services . Survey Report for MPS-31 MWD Your Ref: 500292306600 Job No. AKMW2201B, Surveyed: 17 February, 2002 ~ BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit MPS-Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 0.00 0.000 0.000 -73.54 0.00 O.OON O.OOE 5999928.39 N 565642.14 E 0.00 MWD Magnetic 211.77 0.180 167.860 138.23 211.77 0.33S 0.07E 5999928.07 N 565642.21 E 0.085 -0.02 301.05 0.290 146.500 227.51 301.05 0.65S 0.22 E 5999927.74 N 565642.37 E 0.155 -0.11 391.05 0.480 166.570 317.51 391.05 1.21 S 0.44 E 5999927.19 N 565642.59 E 0.256 -0.23 482.46 0.800 218.460 408.91 482.45 2.08S 0.13 E 5999926.31 N 565642.29 E 0.689 0.21 571.50 2.140 228.530 497.92 571.46 3.67S 1.50W 5999924.71 N 565640.67 E 1.527 2.08 663.60 3.870 234.060 589.89 663.43 6.63S 5.31 W 5999921.71 N 565636.89 E 1.902 6.32 754.96 5.360 233.010 680.95 754.49 11.01 S 11.21 W 5999917.28 N 565631.02 E 1.633 12.86 847.71 6.920 234.090 773.17 846.71 16.89 S 19.20 W 5999911.33 N 565623.09 E 1.686 21.71 941.10 11 .650 232.350 865.31 938.85 25.96 S 31.23 W 5999902.16 N 565611 .14 E 5.073 35.06 1034.68 13.560 233.670 956.63 1030.17 38.23 S 47.55 W 5999889.75 N 565594.93 E 2.064 53.17 1127.12 15.000 234.570 1046.21 1119.75 51.58 S 66.03 W 5999876.23 N 565576.57 E 1.576 73.59 1223.52 16.760 237.700 1138.93 1212.47 66.24 S 87.94 W 5999861.38 N 565554.78 E 2.030 97.61 1315.31 1 9.080 235.790 1226.26 1299.80 81.75 S 111.54 W 5999845.66 N 565531.32 E 2.607 123.43 1410.22 21.970 232.160 1315.14 1388.68 101.37 S 138.40 W 5999825.81 N 565504.64 E 3.326 153.13 1501.70 23.030 229.170 1399.66 1473.20 123.57 S 165.45 W 5999803.37 N 565477.78 E 1.705 183.46 1596.29 26.800 228.130 1485.43 1558.97 149.91 S 195.34 W 5999776.77 N 565448.12 E 4.012 217.26 1689.85 26. 120 227.650 1569.19 1642.73 177.86 S 226.27 W 5999748.55 N 565417.44 E 0.762 252.35 1784.77 28.940 231.360 1653.36 1726.90 206.28 S 259.66 W 5999719.83 N 565384.30 E 3.476 289.95 1878.57 29.240 232.620 1735.33 1808.87 234.36 S 295.59 W 5999691.44 N 565348.62 E 0.727 329.99 1972.56 28.930 232.880 1817.46 1891.00 262.02 S 331.96 W 5999663.46 N 565312.50 E 0.356 370.40 2065.55 31.310 232.530 1897.89 1971.43 290.30 S 369.07 W 5999634.86 N 565275.63 E 2.566 411 .65 2159.66 32.880 236.800 1977.63 2051.17 319.178 409.86 W 5999605.63 N 565235.10 E 2.931 456.62 2253.45 35.360 239.650 2055.27 2128.81 346.82 S 454.60 W 5999577.58 N 565190.61 E 3.145 505.28 2347.67 39.010 242.650 2130.33 2203.87 374.24 8 504.48 W 5999549.74 N 565140.97 E 4.325 558.98 2438.37 43.090 247.030 2198.73 2272.27 399.46 S 558.40 W 5999524.04 N 565087.28 E 5.502 616.30 2535.84 47.390 250.370 2267.36 2340.90 424.51 S 622.87 W 5999498.42 N 565023.02 E 5.037 684.01 2630.76 53.340 252.930 2327.88 2401.42 447.45 S 692.24 W 5999474.88 N 564953.86 E 6.603 756.19 2725.58 59.830 255.230 2380.08 2453.62 469.08 S 768.31 W 5999452.57 N 564877.98 E 7.137 834.79 2819.27 66.170 256.480 2422.59 2496.13 489.45 S 849.22 W 5999431.50 N 564797.25 E 6.870 917.94 -------- ~--_.,- -----_..~- - - - - 22 February, 2002 - 14:13 Page2of5 DrillQuest 2.00.09.008 Sperry-Sun Drilling Services . Survey Report for MPS-31 MWD Your Ref: 500292306600 Job No. AKMW22018, Surveyed: 17 February, 2002 - BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit MPS-Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 2915.31 72.810 257.460 2456.22 2529.76 509.70 S 936.81 W 5999410.47 N 564709.84 E 6.979 1007.67 3011.78 76.740 260.470 2481.56 2555.10 527.49 5 1028.15 W 5999391.88 N 564618.66 E 5.065 1100.68 3105.24 76.380 263.340 2503.28 2576.82 540.29 S 1118.14 W 5999378.29 N 564528.80 E 3.011 1191.55 3200.05 76.450 264.050 2525.55 2599.09 550.41 5 1209.73 W 5999367.37 N 564437.29 E 0.732 1283.57 3292.34 76.510 265.420 2547.13 2620.67 558.65 S 1299.09 W 5999358.35 N 564348.01 E 1 .445 1373.06 3387.65 76.390 265.740 2569.46 2643.00 565.79 5 1391.47 W 5999350.40 N 564255.70 E 0.350 1465.36 3481.60 76.400 265.410 2591.56 2665.10 572.83 5 1482.51 W 5999342.55 N 564164.72 E 0.342 1556.33 3573.79 75.590 265.870 2613.87 2687.41 579.63 5 1571.70 W 5999334.97 N 564075.60 E 1.003 1645.43 3665.92 74.160 266.550 2637.91 2711.45 585.51 S 1660.44 W 5999328.31 N 563986.91 E 1.708 1733.93 3759.07 73.980 267.170 2663.48 2737.02 590.42 5 1749.88 W 5999322.61 N 563897.52 E 0.669 1822.97 3852.89 75.950 265.850 2687.82 2761.36 595.94 5 1840.31 W 5999316.30 N 563807.14 E 2.501 1913.08 3944.91 77. 130 265.170 2709.23 2782.77 602.95 5 1929.53 W 5999308.51 N 563717.99 E 1 .4 70 2002.24 4038.57 77 .840 264.640 2729.53 2803.07 611.07 S 2020.60 W 5999299.59 N 563626.99 E 0.938 2093.41 4129.28 77.310 264.870 2749.05 2822.59 619.175 2108.81 W 5999290.71 N 563538.85 E 0.635 2181.76 4222.49 77.110 265.020 2769.68 2843.22 627.17 S 2199.36 W 5999281.91 N 563448.38 E 0.266 2272.39 4316.55 76.510 265.080 2791.14 2864.68 635.08 S 2290.59 W 5999273.21 N 563357.22 E 0.641 2363.69 441 0.98 76.220 263.980 2813.41 2886.95 643.82 S 2381.94 W 5999263.66 N 563265.95 E 1.173 2455.24 4503.34 77.080 266.040 2834.73 2908.27 651.645 2471.46 W 5999255.06 N 563176.50 E 2.361 2544.83 4598.94 76.950 265.180 2856.21 2929.75 658.77 S 2564.34 W 5999247.11 N 563083.69 E 0.887 2637.62 4693.23 77.440 265.300 2877.11 2950.65 666.40 S 2655.97 W 5999238.68 N 562992.13 E 0.534 2729.26 "-'. 4788,61 75.810 264.520 2899.18 2972.72 674.63 S 2748.39 W 5999229.63 N 562899.78 E 1.885 2821.78 4884.87 75.810 264.070 2922.77 2996.31 683.90 S 2841.25 W 5999219.54 N 562807.01 E 0.453 2914.91 4977.41 75.820 263.230 2945.45 3018.99 693.83 S 2930.42 W 5999208.84 N 562717.93 E 0.880 3004.50 5071.94 75.630 264.280 2968.76 3042.30 703.79 S 3021.49 W 5999198.07 N 562626.96 E 1.095 3095.97 5164.76 76.230 263.320 2991.33 3064.87 713.52 S 3110.99 W 5999187.56 N 562537.54 E 1.193 3185.86 5260.04 77.080 263.260 3013.32 3086.86 724.35 5 3203.06 W 5999175.92 N 562445.57 E 0.894 3278.46 5353.84 75.130 262.290 3035.84 3109.38 735.80 S 3293.39 W 5999163.68 N 562355.34 E 2.309 3369.44 5448.95 74.920 262.340 3060.42 3133.96 748.08 S 3384.45 W 5999150.59 N 562264.40 E 0.227 3461.28 5540.65 76.230 262.060 3083.26 3156.80 760.14 S 3472.43 W 5999137.76 N 562176.52 E 1.459 3550.05 5635.30 77.080 262.180 3105.11 3178.65 772.76 S 3563.66 W 5999124.34 N 562085.41 E 0.906 3642.11 . ---_u__._------~- ------------~-_. ----~-_._'--"---'- - -"~ ------"'--~-'-~-' 22 February, 2002 - 14:13 Page30f5 DrillQuest 2.00.09.008 Sperry-Sun Drilling Services . Survey Report for MPS..31 MWD Your Ref: 500292306600 Job No. AKMW22018, Surveyed: 17 February, 2002 , BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit MPS-Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (It) (ft) (ft) (It) (It) (o/100ft) 5722.42 75.590 263.130 3125.69 3199.23 783.59 S 3647.61 W 5999112.78 N 562001.56 E 2.012 3726.70 5819.33 76.670 262.440 3148.92 3222.46 795.40 S 3740.95 W 5999100.14 N 561908.33 E 1.311 3820.72 5917.24 74.570 261.840 3173.24 3246.78 808.37 S 3834.89 W 5999086.35 N 561814.50 E 2.225 3915.52 6014.22 72.790 261.970 3200.49 3274.03 821.48 S 3927.04 W 5999072.43 N 561722.48 E 1.840 4008.56 6102.58 73.440 261.620 3226.15 3299.69 833.54 S 4010.72 W 5999059.63 N 561638.90 E 0.828 4093.09 6191.35 73.350 260.090 3251.52 3325.06 847.06 S 4094.70 W 5999045.37 N 561555.04 E 1.655 4178.15 6296.80 73.080 263.560 3281.98 3355.52 861.42 S 4194.62 W 5999030.14 N 561455.26 E 3.161 4279.07 6389.13 73.380 264.730 3308.62 3382.16 870.44 S 4282.56 W 5999020.35 N 561367.40 E 1.256 4367.30 6483.56 73.440 265.680 3335.58 3409.12 878.00 S 4372.74 W 5999011.99 N 561277.29 E 0.966 4457.50 6577.09 74.610 266.240 3361.32 3434.86 884.33 S 4462.43 W 5999004.87 N 561187.65 E 1.377 4547.02 6667.49 75.690 265.570 3384.49 3458.03 890.58 S 4549.59 W 5998997.86 N 561100.56 E 1.393 4634.02 6758.00 76.180 265.180 3406.49 3480.03 897.66 S 4637.10 W 5998990.02 N 561013.11 E 0.684 4721.51 6852.74 75.630 265.510 3429.56 3503.10 905.11 S 4728.68 W 5998981.75 N 560921.60 E 0.672 4813.08 6947.73 73.010 265.660 3455.23 3528.77 912.15 S 4819.86 W 5998973.91 N 560830.49 E 2.762 4904.17 7039.42 69.710 267.290 3484.53 3558.07 917.51 S 4906.56 W 5998967.80 N 560743.84 E 3.974 4990.58 7134.16 65.920 267.810 3520.30 3593.84 921.26 S 4994.19 W 5998963.27 N 560656.24 E 4.033 5077.64 7227.27 61.990 265.390 3561.18 3634.72 926.19 S 5077.67 W 5998957.61 N 560572.81 E 4.823 5160.80 7320.82 57.900 266.860 3608.03 3681.57 931.68 S 5158.43 W 5998951.41 N 560492.09 E 4.578 5241.38 7411 .70 53220 266.660 3659.41 3732.95 935.91 S 5233.24 W 5998946.52 N 560417.32 E 5.153 5315.87 7505.64 48.460 266.830 3718.71 3792.25 940.05 S 5305.95 W 5998941.74 N 560344.66 E 5.069 5388.26 7600.86 44.090 267.770 3784.51 3858.05 943.31 S 5374.66 W 5998937.88 N 560275.98 E 4.644 5456.59 7695.71 40.340 267.700 3854.75 3928.29 945.83 S 5438.33 W 5998934.80 N 560212.33 E 3.954 5519.81 7789.86 37.960 267.090 3927.76 4001.30 948.52 S 5497.71 W 5998931.58 N 560152.98 E 2.561 5578.82 7882.11 36.490 268.220 4001.21 4074.75 950.82 S 5553.46 W 5998928.80 N 560097.25 E 1.757 5634.20 7978.31 35.740 268.680 4078.93 4152.47 952.35 S 5610.14 W 5998926.77 N 560040.58 E 0.829 5690.37 8071.22 35.220 268.790 4154.58 4228.12 953.54 S 5664.06 W 5998925.10 N 559986.68 E 0.564 5743.75 8143.00 35.220 268.790 4213.22 4286.76 954.42 S 5705.44 W 5998923.87 N 559945.30 E 0.000 5784.72 Projected Survey ----_..------ 22 February, 2002 - 14: 13 Page 4 0'5 DrillQuest 2.00.09.008 Sperry-Sun Drilling Services Survey Report for MPS-31 MWD Your Ref: 500292306600 Job No. AKMW22018~ Surveyed: 17 February~ 2002 " BP EXPLORATION (ALASKA) INC. Milne Point Unit All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.054° (17~Feb~02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 260.570° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8143.00ft., The Bottom Hole Displacement is 5784.72ft., in the Direction of 260.503° (True). Comments Measured Depth (ft) Station Coordinates TVD Northlngs Eastings (ft) (ft) (ft) Comment 8143.00 4286.76 954.42 S 5705.44 W Projected Survey Survey too/ program for MPS-31 MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 0.00 8143.00 4286.76 MWD Magnetic 22 February, 2002 - 14: 13 Page50f5 --------~-'--------'-"--------- . BPXA MPS-Pad '-'. ."-'" - --- -- +__n-_---'_-".- - -. __n.'-__------_.-~ DrillQuest 2.00.09.008 STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL ~GÆ- --ð {7/D 1- f g(?/ov v~ if'/o~ 1. Type of Request: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Name of Operator BP Exploration (Alaska) Inc. 0 Suspend 0 Plugging 0 Time Extension II Perforate 0 Repair Well 0 Pull Tubing gvariance II Other 0 Operation Shutdown 0 Re-Enter Suspended Well 0 Stimulate Completion of Well 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: 0 Development 0 Exploratory 0 Stratigraphic H Service 6. Datum Elevation (DF or KB) KBE = 73.54' 7. Unit or Property Name Milne Point Unit 4. Location of well at surface 3263' NSL, 369' WEL, SEC. 12, T12N, R10E, UM At top of productive interval 3269" NSL, 618' WEL, SEC. 11, T12N, R10E, UM At effective depth 2366' NSL, 7931 WEL, SEC. 11, T12N, R10E, UM At total depth 2366' NSL, 7991 WEL, SEC. 11, T12N, R10E, UM 12. Present well condition summary Total depth: measured true vertical 8. Well Number MPS-31 i 9. Permit Number 202-014 10. API Number 50- 029-23066-00 11. Field and Pool Milne Point Unit 1 Schrader Bluff Effective depth: measured true vertical 8143 feet 4287 feet 8132 feet 4278 feet Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD 781 80991 2011 711 260 sx Arctic Set (Approx.) 1250 sx Class ILl, 350 sx Class IG' 112' 8133' 112' 4279' Perforation depth: measured NIA f"~ E. , ('" '''"" .1 \ ¡ r: ~;I(;~ ... .". . V !' ~~, . .~ t. 1/;) [ true vertical N/A . ! ,,"\ (' I. I'V\f1? f.~:!'! 1(°'1 ¡ ¡ì ..dId, ',;...... 'vJ .. v (.- ~ 'W u-~ Tubing (size, grade, and measured depth) N/A Alaska Oil & f~mHm¡S9Im: Anchoracw Packers and SSSV (type and measured depth) N/A 13. Attachments H Description Summary of Proposal 0 Detailed Operations Program 15. Status of well classifications as: 0 Oil 0 Gas 0 Suspended 0 BOP Sketch 14. Estimated date for commencing operation August 12,2002 16. If proposal was verbally approved Service Water Injection Name of approver Date Approved Contact Engineer Name/Number: Robert Odenthal, 564-4387. 17. I hereby certifY that tne 1ò~oing ~r e.n rrect t the best of my knowledge Signed RoberÍÔdenthal Ì'J ì....-1' ~ Title Drilling Engineer Prepared By Name/Number: Sondra Stewman, 564-4750 Date 8'~o s-. ù Z- Conditions of Approval: Notify Commission so representative m~ witness A roval No. 3D"2 - 2. t. 7 Plug integrity - BOP Test Location clearance - pp Mechanicallnte~rity Test Þ-. Subsequent form required 10- tf. 0 '7lëc; f- lso PE. fc~5 00 r'1. , M.rt t. ~t Ó~ þ.,. lð'1 ~ll~.N:(L p~ ~~ rt~u..iN~ (2-0A/r(.tS"'',td~~. ~~'!,eA' Approved by order of the Commission Onglnål SIgn~ Bn n I. G I f\ . A Lv CommiSSioner Date -j \~ b;J- Form 10-403 Rev. 06/15/88 Cammy Qechsh Tae ,\. . I \ Submit In riplicate , , S-31 1. MIRU N-4ES. 2. NO tree and valve. NU BOPE. 3. Pressure test casing to 3500 psi 4. RIH and perforate using TCP guns on 3 Y2" tubing. 3/8/02 ) (Reference log SCMT Perforated interval will be 7846-7866' MO OA sand 7900-7920' MO OB sand Perforation guns will be 3 3/8" HSO, 4 SPF, random phasing, 34B HJ II, ROX (21.9" pen, .4" eh) . 5. Run 7" packer on 3-1/2" tubing. .... 'I.t(¿¡ 6. Set packer -7620' MO. (Waiver applied to set more than 200' above top perforations) 7. NO BOPE/NU 4 %" 5M CIW Tree. 8. Freeze protect well. 9. Set BPV. 10. ROMO N-4ES. Tree:Cameron 7-1/16", 5M Wellhead: 20" 92# ppf, H-40 I 113' I KOP @ 571' to 941' Max. hole angle = 77.8 deg @4039' Hole angle thru' perfs = . 7" 26#, L-80, BTRC Casing (drift 10 = 6.151, cap.= .0383 bpf) Perforation Summary Size Spf Interval (TVO) MPU 5-31 i . 0 3000' of diesel 11.0# Brine ~"." .' é. _..-.~ DATE 02120102 REV. BY M. Linder COMMENTS Drilled by Nabors 27-E Orig. OF Elev. = 73.54 Orig. GL Elev. = 39.00 7" Tam Port Collar I 1006' I Short joints 7703'-7725' 7" Halliburton Float Collar I 8049' 1 7" Halliburton float shoe I 8133' I MILNE POINT UNIT WELL No.: S-31i API: 50-029-23066-00 BP EXPLORATION (AK) M . ( < I : '.~.:.'. 1. tot! , .1~ : 'f . ";1 i- ¡i ~ :1. J ;j!: t~ ~ . it ~ .~. .. II "~ '.~ ¡;! ~~ ~g ¡ i~ 'I '..,.~J ,,~ i! il 11 ,.1"..,.: f I fJ .. II: .~-. ,~ ._-. .0' l 'I if OA Perfs 7846-7866 OB Perfs 7900-7920 - ..~ 8-31 Injector comJ....tion Diagram (PROPOSED 6-6-02) .. Tubing hanger connection 4-1/2" NSCT pin x-over pup 4-1/2" NSCT box X 3-1/2" 1ST pin 3-1/2" 9.3# L80 1ST tubing 3-1/2" 'X' nipple (2.813') set at -2200' md 3-1/2" 9.3# L80 1ST tubing 3-1/2" IBT box X 4-1/2" NSCT Pin x-over 7" x 4-1/2" packer - Baker 8-3 (set at -7620' md) 4-1/2" NSCT box X 3-1/2" IBT pin x-over 3-1/2"" 9.3# L80 pup jt (-10') 3-1/2" 'XN' nipple with 2.75" no-go 3-1/2" 9.3# L80 pup jt (-10') Re-entry guide 7", 26#, L-80, STC-M R3 Note to File Well MPS-31 i PTD 202-014 Sundry 302-247 The Area of Review around well MPS-31 i was checked by H. Okland and W. Aubert on 817/02. AOGCC's GeoFrame planimeter measurement function was calibrated in feet. No wells in the AOGCC GeoFrame database pass within one quarter mile of MPS-31 i's injection interval. \lJ4Æ ~lfLlb l Winton Aubert Petroleum Engineer Jl" l ", O~ ,...... C) ,"', Cl -,,- ::.,. ~-"~ ". [> t> g 'oJ .:>- ~V :; TI 3 ... ...\lr.,." ..'~ ~~.. .-."~ ~..-. .....~ - .,.,.. " bp To: Winton Aubert, AOGCC Date: August 2, 2002 From: Robert Odenthal Subject: Waiver of 20 AAC 25.412 (b) Under the captioned item it states, "The packer must be placed within 200' measured depth above the top perforations, unless the commission approves a different placement depth of as the commission considers appropriate given the thickness and depth of the confining zone I would like a waiver of the 200' policy for wells S-21 and S-31, which we will be completing later this month (~ August 20, 2002). We will be running a single packer completion string to inject in the OA and OB sands. We will have ~20' of tailpipe below the packers. The OA sand in both instances is roughly ~220-260' below the proposed setting depth. We would like to be able to set the packers here because the N sands are ~ 50' below the tailpipe. We would like to keep open the possibility of being able to come back later and perforate those N sands and be able to inject into that formation. The tables below show the depths for these wells. 8-31 Item Packer setting depth Tail Pipe Depth N sand (not to be perforated at this time) OA sand (to be perforated) OB sand (to be perforated) Depth (MD) 7620' 7640 ' 7690' 7846-7866' 7900-7920' 8-21 Item Packer setting depth Tail Pipe Depth N sand (not to be perforated at this time) OA sand (to be perforated) OB sand (to be perforated) Depth (MD) 8875' 8895' 8945' 9140-9160' 9214-9234 ' If you have any questions or need for any additional Information please call me at 564-4387 or 440-0185. Sincerely, ~~~ Robert Odenthal ACT W orkover Engineer 564-4387 ( .,. ,"f.,II, -......~ ~...- ~~- ~..-- ~.~ -$~'" .'j'~~I\~ ". bp To: Winton Aubert, AOGCC Date: August 2, 2002 From: Robert Odenthal Subject: Waiver of 20 AAC 25.412 (b) Under the captioned item it states, "The packer must be placed within 200' measured depth above the top perforations, unless the commission approves a different placement depth of as the commission considers appropriate given the thickness and depth of the confining zone I would like a waiver of the 200' policy for wells S-21 and S-31, which we will be completing later this month (- August 20, 2002). We will be running a single packer completion string to inject in the OA and OB sands. We will have -20' of tailpipe below the packers. The OA sand in both instances is roughly -220-260' below the proposed setting depth. We would like to be able to set the packers here because the N sands are - 50' below the tailpipe. We would like to keep open the possibility of being able to come back later and perforate those N sands and be able to inject into that fonnation. The tables below show the depths for these wells. 8-31 Item Packer setting depth Tail Pipe Depth N sand (not to be perforated at this time) OA sand (to be perforated) OB sand (to be perforated) Depth (MD) 7620' 7640 ' 7690' 7846-7866 ' 7900-7920' 8-21 Item Packer setting depth Tail Pipe Depth N sand (not to be perforated at this time) OA sand (to be perforated) OB sand (to be perforated) Depth (MD) 8875' 8895' 8945' 9140-9160' 9214-9234 ' ,j If you have any questions or need for any additional Infonnation please call me at 564-4387 or 440-0185. Sincerely, /---- hd:;¡~~~ Robert Odenthal ACT W orkover Engineer 564-4387 ~ GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie Well MPS-9 rl~...oaO MPS-31 aO~-O J t..f MPE-13B ~O~-OYLI Job # Log Description 22219 CH EDIT SCMT (PDC) 22218 CH EDIT SCMT (PDC) 22217 CH EDIT SCMT (PDC) PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnlcal Data Center MB3-3 900 E. Benson Blvd. RECEIVED Anchorage, Alaska 99519-6612 . . Date Delivered: JUN 0 ¡¡ 2002 Al88kaOiI & Gas Cons. Commission Anehoraae Date 04/26/02 04/26/02 04/24/02 5/22/2002 NO. 2095 Company Alaska Oil & Gas Cons Comm Aftn: Lisa Weeple 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Milne Point CD 1 1 1 Sepia BL Color 2 2 2 Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie ReceiVedbY:~~ a oa.oJ~ 101:03 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 3 33 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 April 29, 2002 RE: MWD Formation Evaluation Logs MPS-31, AK-MW-22028 1 LIS formatted Disc with verification listing. API#: 50-029-23066-00 PLlASE ACKNOWLEDGE RECEJPT BY SIGNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99648 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: Si~~~ RECEIVED t.' ::.)' 0 9 ') nO? L" .... ~laSk& \.Jtt '" ~! :nn" . 1.. \flY Q I..#DmtmSSiOr , ~Ntör;¡gê ~ GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie '~/ Well MPS-31 doa-Oltl ~"'~~ Job # 22133 SCMT Log Description PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: RECEIVED r;"~ .~ p f) (} 0002 .r,., L:-y L AlaskaOiJ & Gas Cons.Com41iuion Anchorage Date 03/09/02 3/28/2002 NO. 1940 Company Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Milne Point CD Color 2 Sepia BL Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie Received~~ K~: t-'Ulllng V::5tJ on ::5-paa ( ( Subject: Re: Pulling VSP on S-pad . Date: Tue, 19 Mar 2002 17:06:41 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Campbell, Steve K" <CampbeIS@BP.com> CC: AOGCC North Slope Office <aogcc_prudhoe_bay@admin.state.ak.us> Steve, Thanks for the additional information regarding the VSP surveys. I had some questions from the inspectors regarding the work. You had described the work in the original permit to drill applications for the S pad wells. This message gives further details regarding the operation. It is interesting that there are individual BOP stacks on the wells. Regardless, the wells are still unperforated and will remain so until4ES completes the wells. You have approval to proceed with the operations as you describe. I will copy this message and place it in the respective well files. You do not need to provide a 403 for the operations. Please call if you have any questions. Tom Maunder, PE AOGCC "Campbell, Steve K" wrote: \ '" d-Q d - 0\ '-\ > Reference wells: MPS-15, 21, 31 & 9 > > Tom, > > In the original permits for the above mentioned wells, I did not include the > pulling of the VSP from the wells using the Klondike rig which will already > be over one of the wells waiting on the completion of the surveys. After > the surveys have been completed the plan is to have the Klondike rig pull > the VSP from each of the wells leaving the well as it was when the drilling > rig left it. Nabors 4es will be coming out to run the completions at a > later date. . >, '. , . "'. , ,> Pro.cedure for pulling the VSP's: >' .' .' > 1. Run survey's > 2. Move Klondike rig on to well > 3. Pull VSP from the well > 4. Install BPV > 4. Close master valve and Nipple down the BOP's > 5. Install tree cap and secure well > 6. Move Klondike rig off > > Can you give me a verbal to do this work and we could send you a 10403 to > follow it up for each well? > > Thanks for your consideration! > > Steve Campbell > BP Drilling Engineer > 907-564-4401(0) > 907-564-4441 (f) > campbels@bp.com 1of2 3/20/02 12:31 PF\ ~e: JUlllng V:::W on ::s-pac 20f2 ( (" I Tom Maunder <tom maunder~admin.state.ak.us> I Sr. Petroleum Engineer . Alaska Oil and Gas Conservation Commission i 3/20/0212:31 PM I @9Itr'~ t~!1: ~ r. ~ @~fl fl1\ / @ '- Lru -' ~ 0 J W .=.[TÙ @ ..ïlÆ / ALASKA OIL AND GAS CONSERVATION COMMISSION / TONY KNOWLES, GOVERNOR 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Pat Archey Senior Drilling Engineer BP Exploration (Alaska), Inc. . PO Box 196612 Anchorage AK 99519-6612 Re: Milne Point Unit MPS-31i BP Exploration (Alaska), Inc. Pennit No: 202-014 Sur. Loc. 3262' NSL, 368' WEL, Sec. 12, TI2N, RI0E, UM Btmhole Loc. 2317' NSL, 761' WEL, Sec. 11, TI2N, RI0E, UM Dear Mr. Archey: Enclosed is the approved application for pennit to drill the above referenced well. The pennit to drill does not exempt you from obtaining additional pennits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennitting detenninations are made. Annular disposal has not been requested as part of the Permit to Drill application for Milne Point Unit MPS-31i. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test perfonned before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, (~~.~ C~y (ßchsli Taylor.. Chair BY ORDER OF THE COMMISSION DATED this 31st day of January, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ë STATE OF ALASKA. ALASKA (I.-IL AND GAS CONSERVATION COM~, PERMIT TO DRILL 20 AAC 25.005 jlON \tJGÁ II~ÎloL A-- \(~ \ 1 a. Type of work II Drill 0 Redrill 0 Re.Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3262' NSL, 368' WEL, SEC. 12, T12N, R10E, UM At top of productive interval f1Z. 2329' NSL, 599' WEL, SEC. 11, T12N, Ry. OE, UM At total depth hv 2317' NSL, 761' WEL, SEC. 11, T12N, R10E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 025637,2317' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 500' MD Maximum Hole Angle 18. Casin9 Program Specifications Size Casina Weiqht Gr~de CouDlina Lenqth 20" 92# H-40 Welded 80' 7" 26# L-80 BTC 8055' 1 b. Type of well 0 Exploratory 0 Stratigraphic Test 0 Development Oil II Service 0 Development Gas G]/Single Zone,.gp 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Planned KBE = 68.00' Milne Point Unit / Schrader 6. Property Designation Bluff ADL 380109 7. Unit or Property Name Milne Point Unit 8. Well Number MPS-31 i 9. Approximate spud date 02109/02 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 8055' MD / 4246' TVD 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 75 0 Maximum surface 1460 psig, At total depth (TVD) 4246' 11877 psig Setting Depth Tqp Bottom MD TVD MD TVD Surface Surface 113' 113' Surface Surface 8055' 4246' 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 Hole 42" 9-7/8" Quantitv of Cement (include staae data) -260 sx Arctic Set (Approx.) 878 sx Class 'L', 357 sx Class 'G' 19. To be completed for Redrill, Re.entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical feet feet feet feet Junk (measured) Plugs (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD RECEIVED JAN 2 3 2002 Perforation depth: measured true vertical Alaska Oil & Gas Cons. Commission Anchorage 20. Attachments ø Filing Fee 0 Property Plat 0 BOP Sketch [ã1>rilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis Contact Engineer Name/Number: Steve Campbell, 564-4401 James Franks, 564-4468 21. I hereby certify that true and correct to the best of my knowledge Signed Pat Archey Title Senior Drilling Engineer j 0 Diverter Sketch iii Drilling Program 0 Seabed Report [g' JR Me 25.050 Requirements Prepared By Name/Number: Sondra Stewman, 564-4750 Permit ~umber -- . i I API Number '. . . APP'~~j.. ~Iíl?ðe See cover letter ~ Z. Ô 17 50- D 2-9- ?-.?D?:lr~ -rx::> \ /JI Uþ\ for other requirements Conditions of Approval: Samples Required 0 Yes lit No Mud Log Required 0 Yes (ia No Hydrogen Sulfide Measures 0 Yes ¡gÑo Directional Survey Required .~es 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU . Other: A OC1¡ l:C.L ¥ IM,ÌJ~ \. <;, t\.;; \( l'-V+e.y .eu......{iov-- t~ t , w~ Â;; MJ.-r ~d «.eM- ~riHiNáT~ riéM BlO) re1J~( ~d: by order of l 11 Approved By ., g . Y Commissioner the commission Date \ 3' ó I Form 10-401 Rev. 12-01-85 Canllll~ DIIL'IIslI 0 RIG I N A L ubrlJit ¡:triPlicate Milne p( ~ MPS-31 i Well Permit I Well Name: I MPS-31 i Drill and Complete Plan Summary I Type of Well (service / producer / injector): I S-Shaped Water Injector 20171 FNL, (32621 FSL), 3681 FEL, (49101 FWL), SEC. 12, T12N, R10E X=565,642.14 Y=5,999,928.39 Target Start Location: 29491 FNL, (23291 FSL), 5991 FEL, (46791 FWL), SEC. 11, T12N, R1 DE "OA" X=560, 140.07 Y=5,998,949.37 Target Start Location: 29531 FNL, (23251 FSL), 6491 FEL, (46291 FWL), SEC. 11, T12N, R1 DE "OB" X=560,090.22 Y=5,998,945.04 Bottom Hole Location: 2962' FNL, (23171 FSL), 761' FEL, (45181 FWL), SEC. 11, T12N, R10E X=559,978.61 Y=5,998,935.39 I AFE Number: I TBD I RiQ: I Nabors 27E // I Estimateq Start Date: 1 Feb. 9, 2002 1 I OperatinQ days to complete: 18 v ~ ~ I MD: 18055 1 I TVD: 14246 1 1 Max Inc: 175 I Surface Location: I KOP: 1500 I I I I KBE: 168 I I I I Well DesiQn (conventional, slim hole, etc.): I Conventional Grass Roots Injector ./ I Objective: I Schrader "OA" & "DB" Mud Program: 9-7/8" Production Hole Mud Properties: Density (ppg) Funnel visc VP HTHP Spud - LSND Freshwater Mud pH API Fi Itrate LG Solids < 6.5 8.6 - 9.20 75 -150 25 - 60 N/A 9.0 - 9.5 < 8 LCM Restrictions: No Organic LCM products in the Schrader Bluff formation Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to 08-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU lR. Cement Program: Casing Size }7" 26lb/ft L-80 BTC Surface casing Basis 250% excess over gauge hole in permafrost interval, 40% excess over gauge hole below permafrost Total Cement Volume: Wash 50 bbl of Newtonian Wash weighted to 8.32 ppg Spacer 50 bb~of Viscosified Spacer (Alp,a Design) weighted to 10.50 ppg Lead 878 Sp'S 10.7Ib/gal Class L 4.15 çuft/sx (cement to surface) Tail 357sxs 15.8 Prem G 1.15 "éuft/sx of tail at 6603' Temp BHST ~ 80° F from SOR, BHCT 85° F estimated by Halliburton 1 t Milne P( ~ MPS-31 i Well Permit Evaluation Program: 97/8" Hole Section: Open Hole: MWD/GRlRES Cased Hole: USIT (post rig) Formation Markers: Formation Tops MD kb (ft) TVDrkb Pore Pressure Estimated EMW r (ft) (Psi) (ppg) Base Permafrost 1899 1750 SVl Top Ugnu 6221 3354 1477 8.65 Top Ugnu M 7420 3765 1662 8.65 NA 7494 3814 1716 8.65 NB 7627 3911 1728 8.65 NC 7672 3945 1743 8.65 NE 7677 3949 1745 8.65 NF 7755 4008 1771 8.65 Top OA 7788 4034 1783 8.65 Base OA 7829 4006 1794 8.65 Top OB 7868 4097 1811 8.65 Base OB 7902 4124 1823 8.65 TD 8055 4246 1878 8.65 CasinglTubing Program: Hole Size Csg/ WtlFt Grade Conn Length Top Bottom Tbg O.D. MD / TVDrkb MD / TVDrkb 42" 20" 92# H-40 Welded 80' 0' 113' /113' / 9 7/8" 7" 26# L-80 BTC 8055' 0' 8055' / 4246' ./ Recommended Bit Program: BHA Hole Depth (MD) Bit Type Size 9 7/8" 0' - 6000' 97/8" 6000' - 8055' 1 2 MXC-l MXC-l Nozzle/Flow rate 3-13 & 1-10 3-13 & 1-10 2 Milne P( .. MPS-31 i Well Permit Well Control: . Production hole will be drilled with a diverter. Surface Interval . Maximum anticipated BHP: . Maximum suñace pressure: 1877 psi @ 4246' TVDrkb - Top of "OB" 1460 psi @ surface (Based on BHP and a full column of gas from TD @ 0.1 psi/ft) function test diverter / N/ A yt/ 8.6 ppg KCL I 6.8 ppg Diesel . Planned BOP test pressure: . Kick tolerance: . Planned completion fluid: Drilling Hazards & Contingencies: Hydrates . Hydrates have been encountered in the surface holes on other pads, especially nearby H-Pad. Hydrates generally occur just below the Permafrost (+/- 1800 ss) but may be present in shallower SV sands and also as deep as 3000 ft. Be alert for the possibility of shallow gas and/or hydrates. Use recommended practices for drilling hydrates. Pretreat mud with DrilTreat; Increase mud wt; Maintain cool mud « 60 deg F); Limit Rap and Reduce pump rate while drilling hydrates; Circulate connections thoroughly. See Well Program and Recommended Practices for specific information. . Another item to watch out for is deeper gravels below the Permafrost or gravels that calve off within the permafrost and will tend to drop out when the aerated hydrate gas cut mud is being circulated out. Maintain adequate viscosity. In the past several Milne Pt wells have experienced stuck pipe from this situation. Lost Circulation . Offset wells encountered losses while running and cementing casing and only one well had losses while running a hole opener. Be~w is a list of the wells and the lost circulating problems associated with them. We do not expect losses while drilling this well. . H-06 (1995): Lost 100 bbls running 9-5/8" casing, good returns during cementing except no returns for last 20 bbls, contaminated cement to surface, cement 12 ft down, no top job. . H-05 (1995): Lost returns drilling at 5360 (3700 tvd), 40 bph to keep full, treated wI LCM pills for two days, total losses 838 bbls, made hole opener run with some continued losses. . H-05 (1995): Ran 9-5/8" casing, lost 46 bbls conditioning mud. . H-07 (1995): Lost 50 bbls running 9-5/8" casing. . E-24 (1998): Made hole opener run, worked tight spots 1965, 2620, 3465, 5900 and 6000, lost 72 bbls while circulating. . H-08A (1997): Had some minor losses while running 4-1/2" liner. . Follow the LOST CIRCULATION DECISION MATRIX in the well plan if fluid losses occur while drilling. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. 3 Milne P( 'MPS.31 i Well Permit Expected Pressures . It is unlikely there will be unexpected overpJ:essure when drilling to the Schrader Sluff formation. Reservoir pressure is expected to be (8.65 Ib/gal EMW). In this well, the Schrader Sluff formation will be drilled with 9.1 ppg mud. This well we be drilled in the undrained portion of the MPH-07 fault block. Offset injectors that have above normal shut-in pressures will be shut-in prior to drilling this well. Some of the wells on H-pad have experienced sever gas cut mud well below the permafrost. Have gas detector installed prior to drilling on S-pad. Pad Data Sheet . Please Read the S-Pad Data Sheet thoroughly. Breathing . N/A Hydrocarbons /' . Hydrocarbons will be encountered in the Ugnu through the Schrader Sluff. Free Gas maybe encountered below the Upper Ugnu. Faults . -30' fault at or around the Ugnu to the west. The well plan was designed to stay away from the fault. Hydrogen Sulfide /. . MPS Pad is not designated as an H2S Pad. Anti-collision Issues // . MPS-31 i has no anti-collision issues. Integrity Testing ..,/' . MPS-31 i will be drilled on diverter and no FIT/LOT is required. 4 (' Milne P( 'MPS-31i Well Permit ,DRILL & COMPLETION PROCEDURE Drillinq 1. 2. 3. 4. 5. 6. 7. 8. 9. Prior to moving rig onto location, complete a pre-rig inspection with Pad operator. Ensure that the landing ring has been welded on the 20" conductor and check the height of the conductor for correct space out for the rig and diverter line. MIRU drilling rig. Conduct spud meeting and HSE compliance briefing with all personnel on board rig. /. ,// Nipple up 21-1/4", 2000 psi diverter system with 16" outlet on existing 20" landing ring. Ensure diverter setup conforms to diagram posted with ~GCC, and that any flowlines that may be in the path of the diverte~re protected. Function test diverter, and record it on the IADC and morning report. Notify the AOGCC prior to conducting the function test on the diverter and provide them with a written copy of the test after it is completed. PU enou~" drill pipe to drill to 8.055' MD. PU 9-7/8" MXC-1, Sperry Motor, MWD/GR/Res. Drill 9-7/8" hole to KOP @ :t500. TVD/MD RKB. Start building angle at 2°/100' up to 3°/100' with an azimuth of 230° to end of initial build @ 1.814' MD. 1.750' TVD and 32° as per mud and directional plan and hold to 2.040' MD. Begin build and turn to 264.5° azimuth and 74.8° inclination at 5°/100' to 3.000' MD. 2.511' TVD and hold. At 6.927' MD start to build and turn at 5°/100' to 40.2° inclination, 266.4° azimuth and 7.619' MD. 3.904' TVD and hold At 7.750' MD begin to turn and drop to 265.5° azimuth and 38.5° inclination and 7.869' MD. 4.097' TVD. Begin drop to 36.7° inclination and 7911' MD and hold until TD. . 400 - 500 gpm flow rate Make a conditioning trip. Circulate and condition the mud as per mud program for cementing the 7" casing. Circulate until clean. Rig up 7" casing running equipment. Ensure the cross over with safety valve is on the rig floor and has been function tested. 10. /' Run 7" 26#, L-80, BT&C surface casing to total depth. (See "detailed casing section" for centralizer placement) Circulate and condition the mud as per mud program for cementing the 7" casing. Circulate 1- 1/2" open hole volume. Mix and pump cement as per Halliburton Cement program and ADW recommended practices (RP) for surface Interval Cementing. Follow the recommended pump schedule to ensure not to exceeding anticipated formation fractyre pressure. Continue reciprocating the pipe as long as practical. Bump the plug with 1,000 psi over circulating pressure. Check float equipment to make sure it's holding. Note that the cement will be displaced with KCL and Diesel for freeze protection. See casing and cement section for details. Nipple down diverter system, pick up and install FMC 20" x 11" 5M Gen 6 wellhead system. Have FMC service hand on location to supervise installation and testing of wellhead. Test wellhead system as per FMC. Nipple up 11" x 7-1/16" 5M FMC hold down flange, FMC 7-1/6" 5M/gate valve and Tree cap (with gauge). Rig up HBR. Test wellhead and 7" casing to 4500 psi for 30 min on a chart. Install BPV & Secure well. 11. 12. 13. 5 14. Milne P~ MPS-31 i Well Permit Rig down and release the rig. Complete a post rig inspection with the Pad operator prior to the rig moving off of the well. Fill out well handover form. POST RIG 1. 2. 3. 4. Rig up coil and perform clean out run , Rig up wireline and run USIT Move in Klondike #1 work platform ..,./ NU 7-1/16" 5M BOP stack and test blind/shear rams 250 psi low; 4,000 psi high and test the annular to 250 psi low and 1,000 psi high. Pull BPV 5. 6. .,f/ Rig up and run 1-1/2", 2.4ppf, N-BO, 10 rd EUE, with Seismic cable and Geophones strapped to the outside of the tubing to TD. Land tubing in split bowl on top of the annular. Install valve in top of 1-1/2" tubing and test same with nitrogen to 90 psi RD Klondike and support equipment and move off 7. 8. 9. NOTE: Completion for final iniection will be done at a later date and permitted as reauired. 6 BP EXPLORA TION (ALASKA) INC. Milne Point Unit Alaska Drilling & Wells MPS-Pad Dev Working, Slot MPS-31 MPS-30 Slot 31 - MPS-31 Wp03 Revised: 16 January, 2002 PRO Surface Coordinates: 5999928.39 N, 565642.14 E (70024' 36.9018" N, 149027' 55.7860" W) Surface Coordinates relative to Project H Reference: 999928.39 N, 65642.14 E (Grid) Surface Coordinates relative to Structure: 40.43 S, 703.24 W (True) Kelly Bushing: 72.00ft above Mean Sea Level Proposal Ref: pro 10039 \;perry-sun Drilling ServicJ~ Proposal Report for MPS-30 Slot 31 - MPS-31Wp03 Revised: 16 January, 2002 BP EXPLORATION (ALASKA) INC. Alaska Drilling & Wells Milne Point Unit MPS-Pad Dev Working Measured Vertical Vertical Dogleg Build Turn Toolface Depth Incl. Azim. Depth Northings Eastings Section Rate Rate Rate Azimuth (ft) (ft) (ft) (ft) (ft) (0/100ft) (0/10Oft) e/10Oft) 72.00 0.000 0.000 72.00 O.OON 0.00 E 0.00 100.00 0.000 0.000 100.00 O.OON 0.00 E 0.00 200.00 0.000 0.000 200.00 O.OON 0.00 E 0.00 300.00 0.000 0.000 300.00 O.OON 0.00 E 0.00 400.00 0.000 0.000 400.00 0.00 N 0.00 E 0.00 500.00 0.000 0.000 500.00 O.OON 0.00 E 0.00 600.00 2.000 230.000 599.98 1.128 1.34W 1.50 2.000 2.000 0.000 230.000 700.00 4.000 230.000 699.84 4.498 5.35W 6.01 2.000 2.000 0.000 0.,990 800.00 6.000 230.000 799.45 10.09 S 12.02 W 13.51 2.000 2.000 0.000 Ö:OÖO 900.00 8.564 230.000 898.64 18.23 S 21.73 W 24.43 2.564 2.564 0.000 0.000 1000.00 11 .128 230.000 997.16 29.23 8 34.83 W 39.15 2.564 2.564 0.000 0.000 1100.00 13.692 230.000 1094.81 43.04 S 51.29 W 57.65 2.564 0.000 0.000 1200.00 16.256 230.000 1191.41 59.658 71 .08 W 79.90 2.564 i;v9JpoO>,,~,1WP¡V 0.000 1300.00 18.821 230.000 1286.75 79.01 S 94.17 W 105.84 2.5Q~ni 'wÖ.OOO'> 0.000 1400.00 21.385 230.000 1380.65 101.11 S 120.49 W 135.43 2.564 0.000 0.000 1500.00 23.949 230.000 1472.92 125.878 2.564 2. 0.000 0.000 1600.00 26.513 230.000 1563.37 153.27 8 2.564 2.564 0.000 0.000 1700.00 29.077 230.000 1651.83 183.24 S 4 2.564 0.000 0.000 1800.00 31.641 230.000 1738.11 215.738 2.64 2.564 0.000 0.000 1814.00 32.000 230.000 1750.00 220.47 S 2.564 2.564 0.000 0.000 1900.00 32.000 230.000 1822.93 2000.00 32.000 230.000 1907.74 2040.52 32.000 230.000 1942.10 2100.00 34.230 233.941 1991 .92 427.21 5.209 3.748 6.626 45.664 2200.00 38.220 239.616 20i~t60 481.27 5.209 3.991 5.675 42.362 ;3:#:::~:~::;:\' 244.344 2148.84 486.90 W 542.60 5.209 4.219 4.728 37.780 248.354 2220.00 551.25 W 610.68 5.209 4.384 4.010 34.172 251.820 2285.50 622.28 W 684.95 5.209 4.505 3.465 31.316 254.870 2344.80 699.40 W 764.80 5.209 4.595 3.051 29.044 257.604 2397.41 781.97 W 849.56 5.209 4.663 2.734 27.233 .~<:t%' 260.097 2442.89 494.198 869.32 W 938.54 5.209 4.713 2.492 25.793 262.406 2480.87 508.228 960.72 W 1031.00 5.209 4.752 2.310 24.658 264.580 2511.03 519.008 1055.41 W 1126.19 5.209 4.780 2.174 23.780 264.580 2537.20 528.11 8 1151.50 W 1222.46 264.580 2563.37 537.23 S 1247.58 W 1318.74 3300.00 74.830 264.580 2589.54 546.35 S 1343.67 W 1415.02 3400.00 74.830 264.580 2615.71 555.46 8 1439.75 W 1511.30 3500.00 74.830 264.580 2641 .87 564.58 8 1535.83 W 1607.58 3600.00 74.830 264.580 2668.04 573.708 1631.92 W 1703.86 3700.00 74.830 264.580 2694.21 582.81 S 1728.00 W 1800.14 3800.00 74.830 264.580 2720.38 591.93 S 1824.08 W 1896.42 3900.00 74.830 264.580 2746.55 601.05 8 1920.17 W 1992.70 4000.00 74.830 264.580 2772.72 610.16 S 2016.25 W 2088.98 4100.00 74.830 264.580 2798.88 619.28 8 2112.34 W 2185.26 4200.00 74.830 264.580 2825.05 628.40 8 2208.42 W 2281.53 16 January, 2002 - 10:02 Page2of5 DrillQuest 2.00.09.008 ( J. '~perry-Sun Drilling Servic ..~ Proposal Report for MPS-30 Slot 31 - MPS-31Wp03 Revised: 16 January, 2002 BP EXPLORATION (ALASKA) INC. Alaska Drilling & Wells Milne Point Unit MPS-Pad Dev Working Measured Vertical Vertical Dogleg Build Turn Toolface Depth Incl. Azim. Depth Northings Eastings Section Rate Rate Rate Azimuth (ft) (ft) (ft) (ft) (ft) (o/10Oft) e/10Oft) (o/10Oft) 4300.00 74.830 264.580 2851.22 637.51 S 2304.50 W 2377.81 4400.00 74.830 264.580 2877.39 646.63 S 2400.59 W 2474.09 4500.00 74.830 264.580 2903.56 655.74 S 2496.67 W 2570.37 4600.00 74.830 264.580 2929.73 664.86 S 2592.76 W 2666.65 4700.00 74.830 264.580 2955.89 673.98 S 2688.84 W 2762.93 4800.00 74.830 264.580 2982.06 683.09 S 2784.92 W 2859.21 4900.00 74.830 264.580 3008.23 692.21 S 2881.01 W 2955.49 5000.00 74.830 264.580 3034.40 701 .33 S 2977.09 W 3051.77 5100.00 74.830 264.580 3060.57 710.44 S 3073.17 W 3148.05 5200.00 74.830 264.580 3086.74 719.56 S 3169.26 W 3244.33 5300.00 74.830 264.580 3112.90 728.68 S 3265.34 W 3340.60 5400.00 74.830 264.580 3139.07 737.79 S 3361.43 W 3436.88 5500.00 74.830 264.580 3165.24 746.91 S 3457.51 W 3533.16 5600.00 74.830 264.580 3191.41 756.03 S 3553.59 W 3629.44 5700.00 74.830 264.580 3217.58 765.14 S 3649.68 W 3725.72 5800.00 74.830 264.580 3243.75 774.26 S 5900.00 74.830 264.580 3269.92 783.37 S 6000.00 74.830 264.580 3296.08 792.49 S 6100.00 74.830 264.580 3322.25 801.61 S 6200.00 74.830 264.580 3348.42 810.72 S 6300.00 74.830 264.580 3374.59 6400.00 74.830 264.580 3400.76 6500.00 74.830 264.580 3426.93 6600.00 74.830 264.580 3453.09 6700.00 74.830 264.580 34 26 6800.00 74.830 264.580 3505.43 865.42 S 4706.60 W 4784.79 6900.00 74.830 264.580 3531.60 874.54 S 4802.68 W 4881.07 6926.94 74.830 264.580 3538.65 877.00 S 4828.57 W 4907.01 7000.00 71.180 264.725 3560.00 883.51 S 4898.12 W 4976.69 5.000 -4.996 0.198 177.848 7100.00 66.183 264.934 3596.34 891 .90 S 4990.87 W 5069.56 5.000 -4.996 0.209 177.805 ,<:;:::,:::;:::,.~, lŒM 61 .188 265.160 3640.66 899.64 S 5080.15 W 5158.89 5.000 -4.996 0.226 177.729 56:'92"w 265.408 3692.61 906.67 S 5165.27 W 5244.02 5.000 -4.995 0.249 177.629 51.197 265.688 3751.80 912.93 S 5245.58 W 5324.27 5.000 -4.995 0.280 177.500 46.203 266.010 3817.78 918.37 S 5320.49 W 5399.06 5.000 -4.994 0.322 177.334 41.210 266.390 3890.05 922.96 S 5389.41 W 5467.80 5.000 -4.993 0.381 177.121 7619.28 40.248 266.472 3904.65 923.75 S 5401.96 W 5480.31 5.000 -4.992 0.426 176.846 7700.00 40.248 266.472 3966.27 926.95 S 5454.02 W 5532.19 7750.56 40.248 266.472 4004.86 928.96 S 5486.62 W 5564.68 7788.25 38.458 265.539 4034.00 930.63 S 5510.46 W 5588.47 5.000 -4.747 -2.476 -162.061 7800.00 38.458 265.539 4043.20 931.19 S 5517.75 W 5595.75 7868.70 38.458 265.539 4097.00 934.52 S 5560.35 W 5638.32 7900.00 37.206 265.558 4121.72 936.01 S 5579.49 W 5657.45 4.000 -4.000 0.059 179.486 7911.67 36.740 265.565 4131.04 936.55 S 5586.48 W 5664.44 4.000 -4.000 0.062 179.472 8000.00 36.740 265.565 4201.83 940.64 S 5639.16 W 5717.07 8055.12 36.740 265.565 4246.00 943.19 S 5672.04 W 5749.92 16 January, 2002 -10:02 Page30f5 DrillQuest 2.00.09.008 (' \;perry-Sun Drilling ServicJ", Proposal Report for MPS-30 Slot 31 - MPS-31Wp03 Revised: 16 January, 2002 BP EXPLORATION (ALASKA) INC. Milne Point Unit Alaska Drilling & Wells MPS-Pad Dev Working All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 260.570° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8055.12ft., The Bottom Hole Displacement is 5749.92ft., in the Direction of 260.559° (True). Penetration Poi n t Sub-Sea Depth Northings Eastings Formation Name (ft) (ft) (ft) 1898.90 1822.00 1750.00 249.39 S 297.21 W Base Permafrost 6221.32 3354.00 3282.00 812.67 S 4150.58 W Top Ugnu 7420.83 3765.00 3693.00 914.13S 5261.65 W Top Ugnu M 7594.61 3886.00 3814.00 922.74 S 5385.86 W Schrader NA 7627.59 3911.00 3839.00 924.08 S 5407.32 W Schrader NB 3873.00 0.000 180.000 7672.14 3945.00 3873.00 925.85 S 5436.05 W Schrader NC 3877.00 0.000 180.000 7677.38 3949.00 3877.00 926.06 S 5439.43 W Schrader NE 3936.00 0.000 180.000 7754.67 4008.00 3936.00 929.13 S 5489.27 W Schrader NF 3962.00 0.000 180.000 7788.25 4034.00 3962.00 930.63 S 5510.46 W TSBD-OA 3994.00 0.000 180.000 7829.11 4066.00 3994.00 932.60 S 5535.80 W TSBC (base OA) 4025.00 0.000 180.000 7868.70 4097.00 4025.00 934.52 S 5560.35 W TSBB-OB 4052.00 0.000 180.000 7902.86 4124.00 4052.00 936.14 S 5581.21 W SBA5 (base 08) 4174.00 0.000 180.000 8055.12 4246.00 4174.00 943.19 S 5672.04 W TD Comments Measured Depth (ft) 500.00 800.00 1814.00 2040.52 3000.00 5000.00 6926.94 7619.28 7750.56 7788.25 7868.70 7911.67 8055.12 16 January, 2002 -10:02 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 500.00 O.OON 0.00 E KOP : Start Dir @ 2.0000/100ft : 500.00ftMD,500.00ftTVD 799.45 10.09 S 12.02 W Dir Rate Increase @ 2.564°/100ft: 800.00ftMD,799.45ftTVD 1750.00 220.47 S 262.75 W End Dir, Start Sail @ 32.000° : 1814.00ftMD,1750.00ftTVD 1942.10 297.63 S 354.70 W Begin Dir @ 5.209°/100ft : 2040.52ft Mo, 1942.1 Oft TVD 2511.03 519.00 S 1055.41 W End oir, Start Sail @ 74.830° : 3000.00ftMD,2511.03ftTVD 3034.40 701.33 S 2977.09 W SailA Ie = 74.8300Inc. on 264.5800Azi. 3538.65 877.00 S 4828.57 W @ 5.00 : 6926.94ft MD, 3538.65ft TVD 3904.66 923.75 S 5401.96 W art Sail @ .248° : 7619.28ftMD,3904.66ftTVo 4004.86 928.96 S 5486.62 W .0000/100ft : 7750.56ft MD, 4004.86ft TVD 4034.00 930.63 S 5510.46 Sail @ 38.458° : 7788.25ftMD,4034.00ftTVD 4097.00 934.52 S In Dir @ 4.0000/100ft: 7868.70ft MD, 4097.00ft TVD 4131.04 936.55 S End Dir, Start Sail @ 36.740° : 7911.67ftMD,4131.04ftTVD 4246.00 943.19 S Total Depth: 8055.12ftMD,4246.00ftTVD Page 4 of 5 DrillQuest 2.00.09.008 ~perry-sun Drilling ServictL Proposal Report for MPS-30 Slot 31 - MPS-31Wp03 Revised: 16 January, 2002 BP EXPLORATION (ALASKA) INC. Milne Point Unit Casing details From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Casing Detail 72.00 8055.12 72.00 Targets associated with this wellpath Target Name MPS-31 TD Mean Sea Level/Global Coordinates: Geographical Coordinates: MPS-31 Top OA Mean Sea LeveVGlobal Coordinates: Geographical Coordinates: MPS-31 Top OB Mean Sea Level/Global Coordinates: Geographical Coordinates: 16 January, 2002 - 10:02 4246.00 7" Casing Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) Alaska Drilling & Wells MPS-Pad Dev Working Target Target Shape Type 4246.00 4174.00 943.19 S 5672.04 W "Æ~:oint 5998935.39 N 559978.61 E 70024' 27.6037" N 149030'42.0308" W 4034.00 3962.00 5510.46 W 560140.07 E 1490 30' 37.2953Þ W 4097.00 4025.00 w~~~:~:#::,;~. "~4VW' 5565.35 W 560090.22 E 30' 38.7574" W Page 5 of 5 Point Point DrillQuest 2.00.09.008 -.. ~ " '1/--...., BPXA Q:~8ii._JUUVLl¡;"lUi M .1 P. t U .t .. ,I~~r.'S...~( 1 ne oln nl Scale: 1 inch = 1 0000 -5000 I Eastings (Well) -3000 I ~PS-3~~j!g~ DrillQuest' -2000 I -1000 I 0 -4000 I 0 Begin Dir @ S.ooo'/100ft : 6926.9411 MD, 3538.6511 ìVD KOP . Start Dir @ 2 ooo'/100ft . SOO OOftMD 500 00ft~ End Dir, Start Sail @ 40.258' : 7619.28ftMD,3904A9flìVD . . .... Begin Dir @ S.ooo'/100ft : 7750.5611 MD, 4004.77117 Dir Rate Increase @ 2.S64'/100ft : Soo.OOftMD,799A511 E~ Dir, Start Sail @ 38ASS' : 77SS.2SIIMD,4034.00ftìVD End Dir. Start Sail @ 32.000' : 1S14.00ftMD,17S0.00ft Begin Dir @ 4.000'/100ft : 786S]OII MD, 4097.00ft TVD . , End Dir, Start Sail @ 36.740' : 7911.67I1MD,4131.04I1ìVD . Sta~ Dir @ S.2O; /100ft : 2040.S2ftMD,1942.1011 Total Depth: 805S.12ftMD,4246.00ftl'lD End Du, Start Sail @ 74.830 : 3ooo.00llMD,2S11.03:ìVD ~500.00 . 2700.00 .MP5-31Wp03 "00.00 2900.00 ::~ ~\....-""",.~Þ>S¡i¡[0::: ""'"" Q) ~ C/) C) c: :.c t 0 Z 0 1000 - - Q) ~ ~000 - Q) 0 -æ (.) t: Q) > 3000 - -= 0 0 0 II -8000 - .5 åj ãi (,) en DrillQuest 2.00.09.008 :$'~?2;s S. ~~6"2,:";6 '.N I -5000 Scale: 1 inch = 1000ft I -4000 I -3000 Eastings (Well) 0 ø -=~ §a ...c: 1I:.c £t - -1000~ ~ åj ãi (,) en I -2000 I -1000 0 Reference is True North .~'i;;~' .~ ~'~" . ~:/~~ Well: Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure: Ref. Geographical Coordinates: RKB Elevation: Current Well Properties MPS-31 W P-03 5999928.39 N, 565642.14 E 40.33 S, 703.22 W 70° 24' 36.9028" N, 149° 27' 55.7854" W 000.00 . Begin Dir @ S.000'/10011 : 6926.9411 MD, 3S3S.6Sft lVD End Dir, Start Sail @ 40.258°: 7619.28ftMD,3904.49ft~ MPS.31 TürjOA Begin Dir@5.0000/lOOft:7750.56ftMD, 4004.77ft ~~~ ~ ~~=... ~.~.g~.::~;()sTXi;OA') w g End Dir, Start Sail @ 38.458° : 7788.25ftMD,4034.00ftTVD " . / / ~ Begin Dir @ 4.000'/10011: 7868.7011 MD, 4097.00ft TVO ~7' C"'"9 - 4000 ~ End Dir, Start Sail @ 36.740° :.7911.67ftMD,4131.04ftTVD ,!()97<)" ,vc":.."".',,." ~~¡~:6~~JD ~ Total Depth. 8055.12ftMD,4246.00ftTVD ,,34 ,)<: s. é;&6(¡:nw ~~ åj ãi (,) en .~:r- ,..~\~~ ¡¡>¡¡j.'r" ...' "~~~!~ .' ~;:,~: :";: ;t. h "..4v.(;". ~-;;~. North Reference: Units: Scale: 1 inch = 1000ft 0 Vertical Section (Well) 3000 I 4000 I 1000 I 2000 I /KOP : Start Dir @ 2.000'/10011 : 500.ooftMD,500.00IlTVD ¡00.00 /ir Rate Increase @ 2.S64'/100ll: SOO.00llMD,799ASIIlVD 0 Scale: 1 inch = 1000ft I 1000 I 4000 I 2000 I 3000 Vertical Section (Well) 72.00ft above Mean Sea Level 72.0Oft above Structure T rue North Feet (US) Section Azimuth: 260.570° (True North) 5000 6000 I I 0 - 1000 - Q) ~ - 2000 :s. Q) 0 -æ (.) t: Q) > - 3000 TD 42,t¡3.00 TVD. 5000 6000 Section Azimuth: 260.570° (True North) , - . '1/.....-, BPXA ø:mt..IJ1;(~ Milne Point Unit 1!.~~rf (' ~PS-~P~-~-~~ DrillQuesf Well: Horizontal Coordinates: Ref. Global Coordinates : Ref. Structure: Ref. Geographical Coordinates : RKB Elevation: Current Well Properties MPS-31 5999928.39 N, 565642.14 E 40.43 S, 703.24 W 70024' 36.9018" N, 149027' 55.7860. W North Reference: Units: 72.0Oft above Mean Sea Level 72.0Oft above Structure True North Feet (US) Proposal Data for MPS-31Wp03 Vertical Or~in: Well Horizontal rigin: Well Measurement Units: ft North Reference: True North Dogleg severity : Degrees per 100 feet (US) Vertical Section Azimuth: 260.570° Vertical Section Description: Well Vertical Section Origin: 0.00 N,O.OO E Measured Inct Azim. Vertical Northings Easti ngs Vertical Dogleg Depth Depth Section Rate 72.00 0.000 0.504 72.00 O.OON O.OOE O.()O 500.00 0.000 0.504 500.00 O.OON O.OOE 0.00 0.000 800.00 6.000 230.000 799.45 10.09 S 12.02 W 13.51 2.000 1814.00 32.000 230.000 1750.00 220.47 S 262.75 W 295.32 2.564 2040.52 32.000 230.000 1942.10 297.63 S 354.70 W 398.67 0.000 3000.00 74.830 264.580 2511.03 519.00 S 1055.41 W 1126.19 5.209 6926.94 74.830 264.580 3538.65 877.00 S 4828.57 W 4907.01 0.000 7619.28 40.248 266.472 3904.65 923.75 S 5401.96 W 5480.31 5.000 7750.56 40.248 266.472 4004.86 928.96 S 5486.62 W 5564.68 0.000 7788.25 38.458 265.539 4034.00 930.63 S 5510.46 W 5588.47 5.000 7868.70 38.458 265.539 4097.00 934.52 S 5560.35 W 5638.32 0.000 7911.67 36.740 265.565 4131.04 936.55 S 5586.48 W 5664.44 4.000 8055.12 36.740 265.565 4246.00 943.19 S 5672.04 W 5749.92 0.000 Proposal Data for MPS-31Wp03 Vertical Origin: Horizontal Origin : Measurement Units : North Reference: Well Well It True North [i.:.IJI.c.'::I :-:-..,;.i:f¥ D~grees per 100 feet (US) 'J.;.ri"bl ':..;..:".:.n A,zlmu1n ,,"(, 570' Vi:r1.: :.1-=io:I..:.r, C,..;.:.:r'¡:.T,orVV'-:-11 Vertical Section Origin: 0.00 N,O.OO E Measured Incl. Azlm. Vertical Northlngs Eastlngs Vertical Dogleg Depth Depth Section Rate 72.00 0.000 0.504 72.00 0.00 N O.OOE 0.00 soo.()() O.(X)() 0504 SOO.()() O.OON O.OOE 0.00 0.000 SOO.OO 6.!X)() 230.000 799.45 IOÆS 12.02W 1351 2.000 1814.00 32.000 230.000 1750.00 220.47 S 262.75 W 295.32 2564 204052 32.000 230.000 1942.10 297.63 S 354.70 W 398.67 0.000 3000.00 74.830 264580 2511.03 519.00S 1055.41 W 1126.19 5.209 6926.94 74.830 264580 3538.65 877.00S 482857W 4907.01 0.000 7619.28 40.248 266.472 3904.65 923.75 S 5401.96 W 548031 5.000 7750.56 40.248 266.472 4004.86 928.96 S 5486.62 W 5564.68 0.000 7788.25 38.458 265539 4034.00 93Q.63 S 5510.46 W 5588.47 5.000 7868.70 38.458 265539 4097.00 93452 S 556035 W 563832 0.000 7911.67 36.740 265565 4131.04 93655 S 5586.48 W 5664.44 4.000 8055.12 36.740 265565 4246.00 943.19 S 5672.04 W 5749.92 0.000 MPS-31 Wp03 Formations Measured Vertical Sub-Sea Depth Depth Depth Dip D(~~)" Formation Name (ft) (ft) (ft) (Deg) 1898.90 1822.00 1750.00 0.000 0.000 Base Permafrost 6221.32 3354.00 3282.00 0.000 0.000 Top Ugnu 7420.83 3765.00 3693.00 0.000 0.000 Top Ugnu M 749452 3814.00 3742.00 0.000 0.000 Schrader NA 762759 3911.00 3839.00 0.000 0.000 Schrader NB 7672.14 3945.00 3873.00 0.000 0.000 Schrader NC 7677.38 3949.00 3877.00 0.000 0.000 Schrader NE 7754.67 4008.00 3936.00 0.000 0.000 Schrader NF 7788.25 4034.00 3962.00 0.000 0.000 TSBD-OA 7829.11 4066.00 3994.00 0.000 0.000 TSBC (base OA) 7868.70 4097.00 4025.00 0.000 0.000 TSBB-OB 7902.86 4124.00 4052.00 0.000 0.000 SBA5 (base OB) 8055.12 4246.00 4174.00 0.000 0.000 TD Single Well Target Data for MPS-31 Measurement Un~s : Coordinate Target Point TVD SSTVD Northlngs Eastlngs ASP-4 Northlngs ASP-4 Eastlngs Target Name Type Shape MPS.31 Gee.Poly Entry Point 4034.00 3962.00 930.63 S 5510.46 W 5998949.37 N 560140.07 E Polygon Boundary Point A 4034.00 3962.00 1202.08 S 6067.20 W 5998673.03 N 559585.74 E B 4034.00 3962.00 1206.48 S 5567.22 W 5998673.03 N 560085.74 E C 4034.00 3962.00 706.50 S 5562.82 W 5999173.03 N 560085.74 E D 4034.00 3962.00 702.1 ° S 6062.80 W 5999173.03 N 559585.74 E MPS.31 TO Entry Point 4246.00 4174.00 943.19 S 5672.04 W 5998935.39 N 559978.61 E Point MPS.31 TopOA Entry Point 4034.00 3962.00 93Q.63 S 5510.46 W 5998949.37 N 560140.07 E Point MPS-31 Top OB Entry Point 4097.00 4025.00 93452 S 5560.35 W 5998945.04 N 560090.22 E Point Drill Quest 2.00.09.008 Field: Milne Point Well: S-31i DIRECTIONAL LWD OPEN HOLE LOGGING NONE NONE MWD/GR/RES IFR/CAS 1/17/2002 FORM 250 % Excess Base of Permafrost 40 % Excess Top of Tail Cement Top of N sand OA sand OB sand Total Depth BP EXPLORATION Milne Point Unit MPS-31 i ( ENG: Steve Campbell RIG: Nabors 27E Actual Surface Location: 3262' FSL & 368' FEL Bottom Hole Location: 2317' FSL & 761' FEL Status: not drilled DEPTH MD I TVD 110' 1,899' 1,750' 6,994' 7,494' 3,814' 7,788' 4,034' 7,868' 4,097' 8,055' 4,246' 110' I I i i I 1'( - I I I I ~~ I ~~ I I ;f~ I ~j ø ffl~ ~¡~ ~~~ ~i I :;It .~~ t$J ~;i RKB: 68' HOLE CASING MUD INFO SIZE SPECS PIT INFO INFORMATION Wellhead 20" 92# H-40 FMC Gen 6 20" x 11" 5M Welded 42 Insulated Lead Cement Volume 649.7 bbls 878 Sacks KOP @ 500' EOB @ 3059' AA=75 VS=1126' Tail Cement Volume 73.1 bbls 357 Sacks SOD @ 6908' EOD @ 7854' AA=37 VS=5664' 97/8" MXC-1 Production Casing 7" 26# L -80 BT&C MW = 9.2 not done MPS-31 i well plan schematic.xls H 202457 DATE l~/OI/Ol CHECK NO. UO~O~4~1 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS 100.00 VENDOR DISCOUNT ALASKAOILA NET 100.00 00 120501 CK120501G PYMT COMMENTS: HANDLING INST: Per nit to Drill ~ee S/H - Terrie HubJle X4628 ~ECE'VED '-Am 1YS- ~ t \ JAN 2 3 Z002 Alaska Oil & Gas Cons. Commission Anchorage rHE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ 100.00 100.00 BP EXPLORATION, (ALASKA) INC. P.o. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND. OHIO No.H2 02 45 7 CONSOLIDATED COMMERCIAL ACCOUNT 56.389 412 00202457 PAY ONE HUNDRED. & 00/100olf**~********************************* US DDLLAR ALASKA OIL AND GAS CONSERVATION COMMISSION 333 <WEST. 7TH AVENUE SUITE 100 ANCHORAGE CATE 12/07/01 AMOUNT $1 OO~.OO To The ORDER Of NOTVALlD AFTER 120 DAYS . ...' AK 99501 ç¿~~GÞ~~~ III 2 0 2 ~ 5 ';1 III I: 0 1. ~ 2 0 :i a ti 5 I: 0 0 a ~ ~ ~ 11111 TRANSMlT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ¡f/¡::;d 6 ~ 31 í- CHECK 1 STANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL EXPLORATION INJECTlO7/ INJECTION WELL REDRILL CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-(9) rD...OT HOLE (PH) ANNUL# ANNULAR DISPOSAL L.J YES ANNULAR DISPOSAL THIS WELL. "CLUE" The permit is for a new wellbore segment of existing well ------' Permit No, - . API No. '. Production should continue to be reported as a function of the original API number stated above. . In accordance with 20 AAC 25.005(f), all records, data and logs acquired for' the pilot bole must be dearly differentiated in both name (name on permit plus PH) . and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has ~ot been requested. . . Annular Disposal of drilling wastes will not be approved.. . Annular Disposal of drilling wastes will not be approved .. . DISPOSAL INTO OTHER Please note that an disposal of fluids generated... . ANNULUS <..---> YES + SP ACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved .súbject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. ;11pÚ WELL PERMIT CHECKLIST. COMPANY f)P~ WELL. NAME ó ---31¿ FIELD & POOL S'J-Ç/'ID INIT CLASS \.. SE"f<. I U//A/J ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. .. . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . N 6. Well located proper distance from other wells.. . . . . . . . . N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y . N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . N 10. Operator has appropriate bond in force. . . . . . . . . . . . . N 11. Permit can be issued without conservation order. . . . . . . . N A~ D~ n: 12. Permit can be issued without administrative approval.. . . . . N ßU I- ~. 07,/ 13. Can permit be approved before 15-day wait.. . . . . . . . . . N ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . ~.. N~Æ- ~ 1i5; T\I Þ , 15. Surface casing protects all known USDWs. . . . . . . . . . . . N A j " 4-" -4-. 16. CMT vol adequate to circulate on conductor & surf csg. . . . . N oe-1 CtÆ/lÆ €A[ Cél;. Ç. c'¿""t/\.. ,-!:.i.A./L .- 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . . N '2 rJ/A ~ I,A (~ . t<;c.. Ð-ñ.lv¡ 18. CMT will cover all known productive horizons. . . . . . . . . . Y N S t ( . ~~: ~~:~~a~:~~~~~:~~i~:~~~~ ;¡t:: ~ ~ ~~r~~fr~~t.. ~ ~ ~ ~ ~ .. ~~ tJtt bø~~ 1.1 ~ 21. If a re-drill, has a 10-403 for abandonment been approved. . . ~N folIA 22. Adequate wellbore separation proposed.. . . . . . . . . . . . . N 23. If diverter required, does it meet regulations. . . . . . . . . . N M A ~ \> ~ I q.tao p ~ . 24. Drilling fluid program schematic & equip list adequate.. . . . . "to N '. I 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N NfA:. - ~ v ~v t""~V °''11' ~ L Y1. - d 26. BOPE press rating appropriate; test to . psig. Y N MAs p:: ¡q¿, 0 f ~. fVCl f,JOp,= rhPY't1~ . 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . fi1 N 28. Work will occur without operation shutdown.. . . . . . . . . . 6? ~.... 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y t¿V jJ.. íJ 30. Permit can be issued w/o .hydrogen sulfide measures. . . . .& N Ofl <R..r ;1- ß ~£ ~k PV~. ~ tL~.! 7~.. ~J?( It.s 31. Data presented on potential overpressure zones. . . . . . . Y ß' t~ú . /' ' I /. /'. / / f 7(/ . /. ~Æ 32. Seismic analysis of shallow gas zones. . . . . . . . . . . .. leX N lb~bf¡:.j;¿e:hZ1-"- ~ J &b 0. 3~ . rvÞ>"'- o.:fft:..<hÆ> . A~R .~ATE .33. Seabedconditionsurvey(ifoff-shore)......... ~.:~;J y N ~~ ' .~¡/¿p;,r.~ .J!.fpÎ("'~..,6k R..~.s:-~..I7?1... t<.J. þb /.2-q .ó2-- 34. Contact namelphone for weekly progress reports {expl9'fiory only] Y N (/ V V VI/ . ANNULAR DISPOSAL35. With proper cementing records, this plan / /~ (A) will contain waste in a suitable receiving zone; . . . . . . . Y N (B) will not contaminate freshwater; or cause drilling waste. .. Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: RPC---r:-~. _--.TEM ~~) COT SFD~ WGA VJ~ DTS JMH \:tfwH- ,J"31 J Ó 2- APPR DATf ~A- il ~il O'L !:t~ \/"3 ,-~:) GEOLOGY APPR DATE PROGRAM: exp - dev - redrll - serv /'wellbore seg ---ann. disposal para req - iAREA gq/j UNIT# O/(3Z1f ON/OFFSHORE ðP1 "'-( P Cf.;&V/¿d;{ [e¿ (/ J¿~ f,j 5 Cv t . Comments/Instructions: G:\geology\permits\checklist.doc (' 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. ðtOé)~OJV 10<603 Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Apr 25 10:41:33 2002 Reel Header Service name.. . . . . . . . . . . .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 02/04/25 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 Da te. . . . . . . . . . . . . . . . . . . . . 02/04/25 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 MPS-31 500292306600 B.P. Exploration (Alaska) Inc. Sperry-Sun Drilling Services 25-APR-02 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 AK-MW-22028 T. GALVIN E. VAUGHN MWDRUN 2 AK-MW-22028 T. GALVIN C. DIXON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 12 12N 10E 3262 368 MSL 0) 73.54 39.00 # WELL CASING RECORD 1ST STRING 2ND STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 20.000 113.0 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3 . MWD RUNS 1 AND 2 WERE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); PRESSURE WHILE DRILLING (PWD); AND ACOUSTIC CALIPER (ACAL). THERE IS AN UNEXPLAINED GAP IN SROP DATA BETWEEN 2559.5' AND 2575' MD. 4. LOG AND DIGITAL DATA ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY RUN ON 3/8/02. THESE DATA WERE PROVIDED TO SSDS BY DEWAYNE SCHNORR ON 4/8/02. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 5. MWD RUNS 1 AND 2 REPRESENT WELL MPS-31 WITH API#: 50-029-23066-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8144.5'MD/4288.58'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS. $ File Header Service name............ .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/04/25 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE 1 clipped curves; all bit runs merged. .5000 START DEPTH STOP DEPTH GR FET RPD RPM RPS RPX ROP $ 77.5 86.5 86.5 86.5 86.5 86.5 127.5 8094.0 8103.5 8103.5 8103.5 8103.5 8103.5 8144.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --- BASELINE 7.5 126.5 148.5 173.5 182.0 209.5 211.5 215.5 231.5 237.0 255.5 262.5 288.5 296.5 312.0 408.5 419.5 431.5 455.5 460.5 490.5 511.0 530.0 552.0 571.5 583.5 586.5 621.0 656.0 660.0 675.0 694.0 709.0 734.5 748.5 784.5 791.0 798.5 850.0 856.5 871.0 894.0 928.0 1051.5 1061.5 1079.5 1110.0 1123.0 1135.5 1144.5 1154.0 1210.5 DEPTH GR 75.0 124.0 147.0 172.5 181.5 208.5 211.0 214.5 231.0 236.0 255.0 263.5 287.5 295.5 310.5 407.0 417.5 430.0 455.0 461.0 490.5 509.0 527.5 549.0 569.5 582.0 586.0 620.0 655.0 659.0 673.0 692.5 707.0 732.5 747.5 783.0 789.5 797.5 849.0 856.0 868.5 894.0 926.5 1050.0 1059.5 1077.5 1108.5 1120.5 1133.5 1143.0 1151.5 1208.5 1213.0 1222.0 1224.5 1240.0 1256.0 1319.5 1398.0 1504.0 1546.0 1560.0 1569.0 1592.5 1610.5 1614.0 1642.0 1649.0 1672.5 1694.5 1735.5 1757.0 1775.0 1802.5 1824.5 1860.5 1887.0 1898.0 1922.5 1948.0 1976.5 1995.5 2002.5 2014.0 2065.5 2074.0 2088.5 2123.0 2138.5 2150.5 2164.5 2180.5 2184.5 2218.5 2224.0 2231.5 2237.5 2242.0 2265.0 2283.0 2342.0 2365.0 2386.5 2392.5 2423.0 2451.0 2533.5 2561.5 2602.0 2611.5 2641.0 2646.0 2653.0 2665.0 2692.0 2714.0 2745.0 1211.5 1219.5 1224.0 1238.5 1255.0 1316.5 1397.5 1507.0 1542.5 1556.0 1566.5 1589.0 1607.5 1611.5 1639.0 1645.5 1671.0 1693.0 1733.0 1755.5 1774.0 1802.0 1823.5 1859.0 1884.5 1897.0 1919.5 1944.0 1973.0 1993.0 2001.5 2012.5 2062.5 2071.5 2084.0 2120.0 2134.5 2147.5 2160.5 2176.0 2181.5 2215.0 2221.5 2229.5 2236.0 2239.5 2263.5 2278.0 2339.0 2361.5 2382.0 2389.0 2423.5 2453.5 2533.5 2560.5 2597.5 2607.5 2635.5 2641.5 2648.0 2661.0 2687.5 2712.0 2742.5 2762.0 2807.0 2835.5 2856.0 2951.0 3110.5 3117.0 3136.0 3173.5 3190.0 3228.0 3252.5 3283.5 3289.5 3312.5 3332.5 3345.0 3444.0 3464.5 3509.0 3520.0 3533.0 3545.5 3571.0 3576.0 3593.0 3622.0 3625.5 3661.5 3756.5 3785.5 3823.0 3880.5 3936.5 3961.5 3980.5 3998.5 4022.5 4059.5 4124.5 4166.5 4178.5 4214.0 4218.0 4223.5 4235.5 4258.5 4280.5 4289.0 4296.0 4310.5 4318.0 4348.5 4364.5 4377.5 4387.5 4391.5 4397.0 4404.5 4407.0 4418.0 4432.0 4438.5 4441.0 4457.5 2758.5 2805.5 2830.5 2852.0 2946.0 3108.0 3114.0 3131.0 3170.0 3186.0 3223.5 3247.0 3279.0 3285.0 3307.5 3327.5 3340.5 3435.0 3460.5 3504.0 3515.5 3527.0 3539.5 3566.0 3570.0 3588.0 3615.5 3619.5 3654.5 3752.5 3783.5 3816.0 3874.0 3927.5 3955.0 3974.5 3992.5 4015.5 4051.0 4115.0 4155.0 4167.5 4205.5 4209.5 4214.5 4228.0 4250.5 4272.5 4282.5 4287.0 4303.5 4311.0 4342.5 4360.0 4371.5 4382.5 4386.0 4393.5 4401.0 4403.5 4414.5 4426.5 4432.5 4434.5 4453.5 4486.0 4505.5 4528.0 4563.5 4621.5 4636.0 4674.5 4692.5 4714.5 4742.0 4771.0 4796.5 4809.5 4831.5 4846.0 5014.0 5158.5 5181.0 5280.5 5313.5 5327.0 5337.0 5358.0 5409.5 5476.5 5500.0 5578.0 5652.0 5764.0 5781.0 5853.0 5916.0 5924.5 5969.5 6005.5 6025.5 6081.5 6185.5 6204.5 6206.5 6299.5 6326.0 6335.5 6354.0 6401.5 6408.5 6429.0 6491.5 6517.0 6559.5 6726.0 6728.5 6745.5 6752.0 6779.5 6818.0 6826.0 6843.0 6869.5 6893.5 6934.5 7000.5 7093.0 7132.5 7160.5 4481.0 4502.0 4523.5 4556.0 4616.5 4630.5 4668.5 4687.0 4709.0 4737.5 4766.0 4786.0 4807.0 4825.0 4841.5 5006.0 5150.5 5175.0 5276.0 5309.5 5320.0 5331.0 5353.5 5402.0 5468.0 5490.5 5566.5 5643.5 5750.0 5765.5 5837.5 5902.0 5912.0 5956.5 5995.0 6016.0 6074.0 6177.5 6196.5 6198.5 6292.0 6320.0 6329.0 6346.5 6394.0 6401.5 6419.0 6480.5 6508.0 6552.5 6717.5 6720.5 6735.0 6743.0 6769.5 6809.0 6816.0 6832.0 6857.0 6884.0 6928.5 6991.5 7084.5 7125.5 7155.0 7199.5 7268.0 7273.5 7287.0 7303.0 7318.0 7371.5 7377.0 7385.0 7396.0 7418.0 7431.0 7433.5 7515.5 7529.5 7552.5 7574.5 7595.0 7608.0 7641.5 7651.5 7684.5 7693.5 7720.0 7749.0 7783.0 7791.5 7800.5 7843.5 7867.0 7913.5 7928.5 7976.0 7985.0 8011.5 8103.5 $ 7192.5 7259.0 7264.0 7280.0 7293.0 7311.5 7362.5 7368.5 7376.5 7387.5 7410.5 7423.0 7425.5 7506.5 7522.5 7544.5 7567.0 7587.5 7600.5 7632.5 7643.5 7678.0 7687.0 7712.5 7741.5 7775.0 7785.5 7794.5 7835.5 7857.5 7912.0 7926.0 7971.0 7985.0 8010.0 8102.0 # MERGED DATA PBU TOOL MWD MWD $ SOURCE CODE BIT RUN NO MERGE TOP 1 75.0 2 3330.0 MERGE BASE 3330.0 8143.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD RPD MWD FET MWD 4 4 4 OHMM OHMM HOUR 1 68 1 68 1 68 20 24 28 6 7 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 77.5 8144.5 4111 16135 77.5 8144.5 ROP MWD FT/H 2.18 2470 307.504 16003 127.5 8144.5 GR MWD API 8.48 130.05 67.0487 16034 77.5 8094 RPX MWD OHMM 0.1 1588.71 34.1235 16035 86.5 8103.5 RPS MWD OHMM 0.14 2000 44.1433 16035 86.5 8103.5 RPM MWD OHMM 0.08 2000 61.2521 16035 86.5 8103.5 RPD MWD OHMM 0.06 2000 47.3306 16035 86.5 8103.5 FET MWD HOUR 0.04 11.08 0.477668 16035 86.5 8103.5 First Reading For Entire File......... .77.5 Last Reading For Entire File.......... .8144.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/04/25 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/04/25 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX FET RPD RPS RPM ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 75.0 84.0 84.0 84.0 84.0 84.0 125.0 # LOG HEADER DATA DATE LOGGED: STOP DEPTH 3279.5 3289.5 3289.5 3289.5 3289.5 3289.5 3330.0 14-FEB-02 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Insite 66.37 Memory 3330.0 75.0 3330.0 .2 76.7 TOOL NUMBER PB02417HWGR6 PB02417HWGR6 9.875 SPUD 9.00 122.0 8.5 500 10.2 1.940 1.828 2.400 3.000 65.0 69.4 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 FET MWD010 OHMM HOUR 4 4 1 68 1 68 24 28 7 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 75 3330 1702.5 6511 75 3330 ROP MWD010 FT/H 2.78 792.47 220.73 6381 125 3330 GR MWD010 API 16.23 130.05 66.285 6410 75 3279.5 RPX MWD010 OHMM 0.1 1588.71 61.0957 6412 84 3289.5 RPS MWD010 OHMM 0.14 2000 84.1036 6412 84 3289.5 RPM MWD010 OHMM 0.08 2000 122.764 6412 84 3289.5 RPD MWD010 OHMM 0.06 2000 90.6295 6412 84 3289.5 FET MWD010 HOUR 0.06 2.59 0.385 6412 84 3289.5 First Reading For Entire File......... .75 Last Reading For Entire File.......... .3330 File Trailer Service name............ .STSLIB.002 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .02/04/25 Maximum Physical Record. .65535 F i 1 e Type.. . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/04/25 Maximum Physical Record. .65535 File Type... . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 3280.0 3290.0 3290.0 3290.0 3290.0 3290.0 3330.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE STOP DEPTH 8092.5 8102.0 8102.0 8102.0 8102.0 8102.0 8143.0 17-FEB-02 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Insite 66.37 Memory 8143.0 3330.0 8143.0 35.2 77.8 TOOL NUMBER PB02417HWGR6 PB02417HWGR6 9.875 LSND 9.30 102.0 8.5 500 12.0 2.100 1.549 2.600 2.900 65.0 90.5 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3280 8143 5711.5 9727 3280 8143 ROP MWD020 FT/H 2.18 2470 363.541 9626 3330.5 8143 GR MWD020 API 8.48 122.42 67.7076 9626 3280 8092.5 RPX MWD020 OHMM 0.67 237.07 15.9053 9625 3290 8102 RPS MWD020 OHMM 0.77 263.73 17.2553 9625 3290 8102 RPM MWD020 OHMM 1.23 2000 19.3293 9625 3290 8102 RPD MWD020 OHMM 1.63 1323.02 18.0161 9625 3290 8102 FET MWD020 HOUR 0.04 11.08 0.537912 9625 3290 8102 First Reading For Entire File......... .3280 Last Reading For Entire File.......... .8143 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/04/25 Maximum Physical Record. .65535 File Type.. . . . . . . . . . . . . . .LO Next File Name.......... .STSLIB.004 Physical EOF Tape Trailer Service name. . . . . . . . . . . . .LISTPE Date.................... .02/04/25 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name. . . . . . . . . . . . .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 02/04/25 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File