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Home My WebLink About202-113CAUTION: 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-11 (PTD# 2021130) - Shut in for 2 year AOGCC MIT-IA Date:Friday, March 28, 2025 3:43:42 PM From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, March 28, 2025 3:35 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-11 (PTD# 2021130) - Shut in for 2 year AOGCC MIT-IA Mr. Wallace – PWI well MPS-11 (PTD# 2021130) 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:Wednesday, April 26, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC S-11 MILNE PT UNIT S-11 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/26/2023 S-11 50-029-23092-00-00 202-113-0 W SPT 3940 2021130 1500 668 661 658 658 OTHER P Austin McLeod 3/19/2023 Two year. No AIO. Monobore. 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-11 Inspection Date: Tubing OA Packer Depth 103 1725 1658 1662IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230320093631 BBL Pumped:1.1 BBL Returned:1.2 Wednesday, April 26, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9James B. Regg Digitally signed by James B. Regg Date: 2023.04.26 13:09:50 -08'00' Wallace, Chris D (CED) From: Darci Horner - (C) <dhorner@hilcorp.com> Sent: Monday, April 12, 2021 12:16 PM To: Regg, James B (CED); Brooks, Phoebe L (CED); Wallace, Chris D (CED); DOA AOGCC Prudhoe Bay Cc: Alaska NS - Milne - Wellsite Supervisors; Josh McNeal; Derek Weglin; Jon Arend; David Haakinson; Grant Encelewski; Alaska NS - Wells Foreman Subject: Shut-in injector Milne Point S-11 due for AOGCC MIT -IA All, Milne Point water injector MP S-11 (PTD # 2021130) has been shut in since October 2019. The well is due for an AOGCC witnessed MIT -IA this month. The well will not be brought online in time for the test and will remain shut-in for the foreseeable future. A tag has been hung on the well and it has been added to the Quarterly North Slope LTSI injector report. Once the well is ready to be brought online an MIT -IA will be performed. Regards, Darci Horner Technologist Office: (907) 777-84o6 Cell: (907) 227-3036 Email: dhorner@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or fi you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg2 DATE: Wednesday, May I, 2019 P.t. Supervisor v� slt 9 SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC S-11 FROM: Matt Herrera MILNE PT UNIT S-11 Petroleum Inspector See: Inspector Reviewed By: P.I. Supry -Ap— NON-CONFIDENTIAL Comm I Well Name MILNE PT UNIT S -1I IInsp Num: mitMFH190429123918 Rel Insp Num: API Well Number 50-029-23092-00-00 Inspector Name: Matt Herrera Permit Number: 202-113-0 - Inspection Date: 4/29/2019 Packer Depth Well s -H Type Inj w "TVD 3940 Tubing PTD 2021130 Type Test SPT Test psi 1500 IA BBL Pumped_ _ 0.2 ' BBL Returned: 0.2 OA Interval OTHER P/F P Notes: MIT -IA performed on a 2 year cycle per Operator for Monbore Completion M:Prdw- 11 qle ` 5Lu.�m SErY— P 1 �!j Ilq Pretest Initial I5 NIin 30 Min 45 Min 60 Min IOF 107 109 116 �677 '051 2023 - 2021 4 - 1 4 1 4 4 Wednesday, May I, 2019 Page I of I Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Friday, April 26, 2019 1:38 PM To: Wallace, Chris D (DOA); Alaska NS - Milne - Wellsite Supervisors; Alaska NS - Wells Foreman Cc: Regg, James B (DOA); Brooks, Phoebe L (DOA); Darci Horner - (C); Ian Toomey - (C) Subject: LTSI Injector MPS -11 (PTD #.2021130) Ready For Injection ON Long Term Shut-in Milne Point water injector MPS -11 (PTD # 2021130) had a passing preMIT on 4/26/19. The well has been shut in for reservoir management since 8/9/2018 and lapsed its historic 2 year MIT interval (well is a monobore) in November 2018. There are no know 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, Wyatt Rivard I Well Integrity Engineer IHilcorp Alaska, LLC 0: (907) 777-85471 C: (509)670-80011 wrivard0hilcor .Rom 3800 Centerpoint Drive, Suite 1400 1 Anchorage, AK 99503 • 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg / Z-1/4,, DATE: Tuesday,November 22,2016 P.I.Supervisor �(2.6q. it`ZSUBJECT: Mechanical Integrity Tests l I-IILCORP ALASKA LLC S-11 FROM: Bob Noble MILNE PT UNIT SB S-11 Petroleum Inspector Src: Inspector Reviewed By:,_ P.I.Supry ,)8e— NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT SB S-11 API Well Number 50-029-23092-00-00 Inspector Name: Bob Noble Permit Number: 202-113-0 Inspection Date: 11/13/2016 Insp Num: mitRCN161113165951 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min ---------------- Well 5-11 Type Ini W(TVD 3940 .. Tubing 794 795 . 795 . 795 PTD 2021130 Type Test SPT Test psi 1500 - IA 1544 2216 -I 2187 . ( 2186 — - Interval OTHER P/F P ✓ OA Notes: Mono-bore well.Conductor annulus 5/4/4/4 ,./ S �OD Ari-1'. 1 I i 1 Tuesday,November 22,2016 Page 1 of 1 • �-- Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Wednesday, October 12, 2016 8:54 AM To: Regg,James B (DOA);Alaska NS - Milne -Wel!site Supervisors Cc: Ted Kramer;Wallace, Chris D (DOA) Subject: Injector MPS-11 (PTD#2021130) Ready For Injection All, Milne Point injector MPS-11 (PTD#2021130) had a passing preMIT-IA on 10/11/2016. Well has been shut in for reservoir management and was out of its historic 2 year MIT cycle as of 9/5/16.The well is a monobore injector with no known integrity issues.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 when well is on injection and thermally stable. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 IIitemp tia4 a. 1.i.t. SCANNED FEB 2 1201' 1 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. aD.2- J L3 Well History File Identifier Organizing (done) 0 Two-sided 1111111111111111111 0 Rescan Needed 11IIIIIII1111111111 RESCAN DIGITAL DATA ~ettes, No. 9- 0 Other, No/Type: OVERSIZED (Scannable) 0 Maps: 0 Color Items: 0 Greyscale Items: 0 Other Items Scannable by a Large Scanner 0 Poor Quality Originals: OVERSIZED (Non-Scannable) 0 Other: 0 Logs of various kinds: NOTES: 0 Other:: Scanning Preparation ~ x 30 = b6 f; 'Jf) Date:/O ~ b't /s/ VVtr-' # 1111111111111111111 f " Date I ~ J-: °'t Is/ Vtf. () + E?' = TOTAL PAGES b~ (Count d...oes ~ot i~clude cover s.leet...~() Date: It; :J- iOG /s/ IV( r , \ \ \111111 \ 1\ " I \ I BY: Helen ~ Project Proofing BY: Helen" ~ BY: Helen ~ Production Scanning Stage 1 Page Count from Scanned File: b Q (Count does include cover sheet) Page Count Matches Number in scannfng Preparation: / YES HeleéÐa) Date I ~ ',j OLf If NO in stage 1 page(s) discrepancies were found: YES NO BY: NO IfJ mp Stage 1 BY: Helen Maria Date: Isl I I ¡ III Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Helen Maria Date: /s/ Comments about this file: Quality Checked 1111111111111111111 8/24/2004 Well History File Cover Page.doc RECEIVED • STATE OF ALASKA t NOV 2 2013 AL .ACA OIL AND GAS CONSERVATION COMM.__.ON REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other Ld MBE Treatment Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Developments Exploratory ❑ 202-113-0 • 3.Address: P.O.Box 196612 Stratigraphk❑ Service 0 6.API Number: Anchorage,AK 99519-6612 50-029-23092-00-00 . 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0380110 • SBL MPS-11 • ' 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): I 10.Field/Pool(s): MILNE POINT,SCHRADER BLFF OIL ' 11.Present Well Condition Summary: 1 Total Depth measured 5939 feet Plugs measured None feet true vertical 4485.51 feet Junk measured 5833 feet Effective Depth measured 5843 feet Packer measured See Attachment feet true vertical 4401.33 feet true vertical See Attachment feet Casing Length Size MD ND Burst Collapse Structural None None None None None None Conductor 84 20"91.5#H-40 28-112 28-112 1490 470 Surface None None None None None None I Intermediate 97 9-5/8"47#L-80 38-135 38-135 6870 4760 Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner None None None None None None Perforation depth Measured depth 5385-5405 feet 5500-5502 feet 5535-5550 feet 5600-5615 feet True Vertical depth 4011.32-4026.94 feet 4104.12-4105.79 feet 4133.67-4146.47 feet 4189.46-4202.45 feet Tubing(size,grade,measured and true vertical depth) 3-1/2"9.2#L-80 28-5619 28-4205.92 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): 5573'-5843' Treatment descriptions including volumes used and final pressure: SCANNED JAN "A 7 (1;,i4 404 Bbls CrystalSeal, 1030 psi. SCANNED Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 382 0 1045 • Subsequent to operation: 0 0 354 0 570 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development❑ Service 0 • Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil U Gas U WDSPLU GSTOR ❑ WINJ El • WAG ❑ GINJ ❑ SUSP ❑ SPLUCS 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: 313-389 Contact Garry Catron Email Garry.Catronc BP.Com Printed Name Garry Catron Title PDC PE Signature Phone 564-4424 Date 11/11/2013 Vt-F 1/6 9 `/`f FIBE;WS NOV 2 1. " Form 10-404 Revised 10/2012 //, (/f( Submit Original Only Packers and SSV's Attachment ADL0380110 SW Name Type MD ND Depscription MPS-11 PACKER 5289 3872.67 3-1/2" Baker Premier Ret. Pkr MPS-11 PACKER 5435 3984.2 3-1/2" Baker Premier Ret. Pkr MPS-11 PACKER 5566 4093.57 3-1/2" Baker Premier Ret. Pkr m Q.p000M W N- CO ; ; to Vto t� Oa • Oo o 3 00 N N M r CON- — CO N CO O Nr N Nr 0 000000000 N CM N '- N (1) NLOOWM r r r 0 V a 00 00 00 00 c Co N N M N � J OD CO C7 � 0°O0°0 C N 4 J J N •N 't (0 (0 O) (7 00 N N & N Q) A t — 00 C 0(0 0) ON) 000 U) GI to to J W w H Z Z 000 = 00 CI- u• 1.1HH 0• ocOOZ 0I- ooD El 0 ? d a H Q Q J Q W 0 II p O O -0 O J > J O a) U) CO U N D O D �t .E N 2 .—- -0 o U _ a LL � � Q U .0 a o � H W 6 m t N D a 0 W C Q a ea E (� 00 Z J it p w a LWi Uj Lj m v) m E .Q- _ •• Q O 0 ° ,_- " �i _03 0 -4- m O N- F 2 O 0 m - 0.-; T °- E o N O_ Q 0 J > m aa) ° ° ° o 0 `p W H D l0 a_ C) ,_ ) T C _ C0 �.- F- _ LL \ m a) a) U p 0C4- (I) J (n N C 0 a) m 0 N- C Q co w U i� 6 0 'c. 0L- °- E H W b 0 b 0' C ~ Cn Q w 'Q c O W H J r` 0 ) C .n ▪ �0 a V� Q O Q co LE O . C0 w to z .-' 0 a) ?� a) `r) E u> O z H U Q 0 C 0 a U)) Q � • a Fs L LIS O co J Q U Q I- O V p U i O N Q �? W UU ' CMr) J s- �s 0 o (00 a Q m Q a) c0 0 N Oa 4- J Un C0 z S? C0 -o CO CO u) 73 L C E a. U) O -c 0 .LAWN D © •m QOQ N o me nUE c2a ma o U Q ..-. 2w U a j o � J M W c 0_ 0 : ° `0 c0 CCa rUn _c j `� O X00 co- * g0 0Q * 10Q W -0 E C 0 0o m U p J u) ' co H 222 /3 pp 0 * Q) •O O L - U � Y N �-+ Q J Un u) M O (0 I� Z * 2 f Q Q a co 0 O U•v> o - Oct vz m z * T I-D T 'n O * TOW H E O E E T Qo -E 0 ID co 0. * Q �`�l a LL Q Q a N C 't w LO I- o - N. co Ce J Q Un 1- 7 d7 W ©V X '- 60 - W in p a a) p N rn >+ > 2 D 07 ° -i101U a7 ° z co > ? (1) .4.E. oo M � � mm Z ° 0UW WD Z ° Ozg O > a) 3 Q � a 0 ° 0-00 o QQQH DO0OZZ -10D0 Iao W a) ca > cow n Q ca 'I-0 - Zowcn a QLJL » QOn Q - > - C a a) f- c6 a) c_n Or- U J W W JJa W W '- - YLL Qi) > cn > Eo o � Q UNJ � WZZ4- 100 > T WZ Z °0Q WJZZ > m U) "' CY Q- .- J O o Q 0 a z Z Q Q Q w w a Z Z Q N 2 J 0 O > _ 0 L'102 "0 Ewm 22 m - 7 Un W> N Q - Q w O o LL' , X W O O � N � w II m II > !Z0 a Qa � � > ZQcr = LPHUUQWWQ = HU UDQ = iO = O C n 92 CO E u) 'o + CC _1 TQ : : aUU2f Q + : Q- H *K HSHE a ) a 00 .20P. co co co M ch co T co T T T T O O O O O O O N N N N N N N \ \ \ O N CO M T T o a o O O O O T T O CO -6 U) O L Q O � L O � � O 0_(• ""‘j II E ^w z LL • o C E as Q IL L ID to k N c _ N + O > Q -c p O O C O C O a) L O (0 CD U u) 2 Q N C p • O O r a a 0_-0 O N Q C • E a� • J �� o t Q La Q -- II CD _� >+(6 0 • U O 0 O Q' N ✓sue 't_ C U) Q f— Z C \O O O Q O � 3 E M N N N Tree: 3 1/8"5M Wellhead:Gen 5A USH 9 5/8 x 11 M P U S-11 i Orig. KB Elev. =66.60 11"x 3 1/8"5M FMC Adapter - Orig. GL Elev. = 39.00 3"CIW-H BPV profile w/TC-II T&B thread Minimum ID in Tbg=2.750" 20"x 34"insulated,215#/ft A-53 112' Triple Connect for the tie in @ 116' I MI 1 3.5"HES X-Nipple(2.813"Profile) 2399' Valve Configuration as of 09-05-10 KOP @ 410' Max. hole angle =56 deg @ 3758' Hole angle thru perfs=31 DEG. DV p 3.5"x 1.5" Camco MMG 5176' 3.5"HES X-Nipple(2.813"Profile) 5270' 7"26#,L-80,BTRC Casing (drift id=6.151,cap.=.0383 bpf) 3 1/2",9.3#/ft L-80,TC-U tubing 7"x 3.5"Baker Premier Pkr 5290' (drill id=2.867,cap=.0087 bpf) F S. 3.5"x 1.5' Camco MMG 53'7' NB sand psi on 8/4/12 was—2057 psi OA sand psi on 5/24109 was—1380 psi 08 sand psi on 10/09/09 was-972 psi I I 3.5"x 1.5' Campo MMG-W 5375 7'x 3.5'Baker Premier Pkr 5436' Perforation Summary !PP 3.5"x 1.5' Camco MMG 5463 Si:e Spf Interval (T1/1:1) NB sands 338' 6 5385'-5405' 4011'-4026' !JA sands WI'I' " 3.5"x 1.5' Camco MMG-W 55" 3 3/8' 4 5500'-5507 Squeezed 4 5535'-5550' 4134'-4147' ..^`° 5567 3-3/8" 6 5530'-5540' 4129'-4137' 7"x 3.5"Baker Premier Pkr 3 3/8' 6 5550-5560' 4146'-4155' ' (DR s & , le 3.5"x 1.5' Camco MMG-W 5584' 3 3/8" 4 5600'-5615' 4189'-4202' r.r 3.5"HES XN-topple(2.813'Profile) 5613' Ii (2.750"NoGo)MU 3.5"WLEG 5619 0,,n14.1."ts51 mtiSIM I ELMD y�n14,x>rs,a,aici - Fish:EZSV miffed and pushed to 5833' 1 5843 I 7'haliburfan Float Collar PBTD 0 1 5928 I 7"Hal lib urton fioatshoe 4 • DATE REV BY COMMENTS MILNE 06/22!02 MDO Driledby Cased Doycn 141 POINT UNIT WELL No.:S-11i 08/31/02 Lee Hulme Completion Rig 4ES /API: 60-02S-23092-I• 05/13,06 M DO RWO to Add Puts Doyon-14 0427,08 LH RWO&Re-complete as 3 12"Doyon-14 BP EXPLORATION (AK) • Wallace, Chris D (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator ©bp.com] Sent: Sunday, August 12, 2012 7:16 AM To: Regg, James B (DOA); Schwartz, Guy L (DOA); Wallace, Chris D (DOA); AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Wells Ops Coord 2; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, OPS MPU Control Room; Wermager, Chad R Cc: Arend, Jon (NORTHERN SOLUTIONS LLC); AK, D &C DHD Well Integrity Engineer Subject: OPERABLE: Injector MPS -11 (PTD #2021130) AOGCC MIT -IA Passed Attachments: MIT MPU S -11 08- 11- 12.xls • All, Water Injector MPS - 11 (PTD #2021130) passed the AOGCC witnessed MIT -IA. The well now meets all UIC compliance requirements and is reclassified as Operable. The MIT -IA form is attached for reference: «MIT MPU S -11 08- 11- 12.xls» SCANNED t AY 0 7 2013 Thank you, Mehreen Vazir BPXA Well Integrity Coordinator From AK, D &C Well Integrity Coordinator Sent: Wednesday, August 08, 2012 2:11 PM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; Chris Wallace (chris.wallace()alaska.gov); AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Wells Ops Coord 2; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, OPS MPU Control Room; Wermager, Chad R Cc: Arend, Jon (NORTHERN SOLUTIONS LLC); AK, D &C DHD Well Integrity Engineer Subject: UNDER EVALUATION: Injector MPS -11 (PTD #2021130) Place on Injection for AOGCC MIT -IA All, Monobore water injector MPS -11 (PTD #2021130) passed a pre- injection MIT -IA to 2000 psi confirming competent barriers. The well is reclassified as Under Evaluation so it can be placed on injection. Once thermally stable, an AOGCC witnessed MIT -IA will be performed. The MIT -IA form is attached for reference: « File: MIT MPU S 08 » Thank you, Mehreen Vazir 1 • • BP Alaska - Well Integrity Coordinator « OLE Object: Picture (Device Independent Bitmap) » WIC Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator PBP.com Direct Cell: 832.651.5253 Direct Email: Mehreen.VazirPBP.com From: AK, D &C Well Integrity Coordinator Sent: Tuesday, June 05, 2012 10:46 AM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Wells Ops Coord 2; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, OPS MPU Control Room; Wermager, Chad R Cc: AK, D &C Well Integrity Coordinator; Arend, Jon (NORTHERN SOLUTIONS LLC); Clingingsmith, Mike 3; Walker, Greg (D &C); LeBaron, Michael 3 Subject: NOT OPERABLE: Injector MPS -11 (PTD #2021130) Injector Due For AOGCC MIT -IA Compliance Testing Not Online All, Monobore water injector MPS -11 (PTD #2021130) is currently due for its 2 year monobore MIT -IA compliance testing to continue injection. The well is currently shut in and is not expected to be returned to injection in the near term. The well is reclassified as Not Operable and will be added to the AOGCC Quarterly Not Operable report until such time as an MIT -IA is performed. Plan forward: 1. Fullbore: Perform MIT -IA prior to resuming injection 2. Fullbore: Once on injection and thermally stable, perform AOGCC MIT -IA A copy of the TIO and Injection plot and a wellbore schematic are included for reference. « File: MPS -11 (PTD #2021130) TIO and Injection Plot.doc » « File: MPS -11 (PTD #2021130) wellbore schematic.pdf» Please call if you have any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 2 Cell (907) 752 -0755 • • Email: AKDCWeIIIntegrityCoordinator (a7BP.com 3 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 SANE OFEB 2 4 2O1a December 30, 2011 per. -(13 Mr. Tom Maunder 1 I Alaska Oil and Gas Conservation Commission (� S 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPS -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPS -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, (.. Mehreen Vazir BPXA, Well Integrity Coordinator III • 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/ l 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 7/3012011 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 7/302011 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 7129/2011 MPS -13 2021240 50029230930000 1 NA 1 NA 11.9 11/312009 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 10.2 729/2011 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 7292011 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 7282011 MPS-23 2021320 50029230980000 Open Flutes - Treated MPS-24 2030380 50029231420000 1.3 NA 1.3 NA 10.2 728/2011 MPS -25 2021030 50029230890000 Open Flutes - Treated MPS -26 2030610 50029231500000 1 NA 1 NA 8.5 728/2011 MPS -27 2020850 50029230840000 0.9 NA 0.9 NA 8.5 7282011 MPS-28 2030940 50029231580000 1.1 NA 1.1 NA 11.9 7282011 MPS -29 2021950 50029231190000 Open Flutes - Treated MPS-30 2022360 50029231310000 1.2 NA 1.2 NA 11.9 728/2011 MPS -31 2020140 50029230660000 Open Flutes - Treated MPS-32 2030920 50029231570000 0.8 NA 0.8 NA 6.8 7282011 MPS -33A 2061720 50029231230100 1 NA 1 NA 6.8 728/2011 MPS-34 2031300 50029231710000 6 NA 6 NA 49.3 7/28/2011 MPS -35 2031430 50029231750000 1.2 NA 1.2 NA 11.9 7/28/2011 MPS-37 2070520 50029233550000 13.9 Need top job NA MPS-39 2081830 50029234050000 0.7 NA 0.7 NA 4.3 8/18/2011 MPS -41A 2081610 50029234010100 Sealed NA NA NA NA NA MPS -43 2081760 50029234040000 Dust Cover NA NA NA 6.8 10/11/2011 MPS -90 2051350 50029232760000 0.6 NA 0.6 NA 3.4 9/6/2011 MPSB -04 500299990799 0.6 NA 0.6 NA 3.4 7/30/2011 • • SEAN PARNELL, GOVERNOR Keith Lopez Well Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Field, Schrader Bluff Pool, MPS-11 Sundry Number: 310-274 .. f 4t ;i Dear Mr. Lopez: M Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. ~ Chair h DATED this ~ day of September, 2010. Encl. STATE OF ALASKA ~~',p ALASK~ AND GAS CONSERVATION COMMISSI~ ~ ' ~~ APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ^ Plug for Redrill ^ Pertorate New Pool ^ Repair Well ^ Change Approved Program ^ Suspend ^ Plug Perforations ^ Perforate ^ Pull Tubing ^ Time Extension ^ Operation Shutdown ^ Re-enter Susp. Well ^ Stimulate^ Alter Casing ^ - Other: MBE TREATMENT 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ^ Exploratory ^ 202-1130 3. Address: P.O. Box 196612 Stratigraphic ^ Service a , 6. API Number: Anchorage, AK 99519-6612 50-029-23092-00-00 . 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ^ MPS-11 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-380110 MILNE POINT Field / SCHRADER BLUFF Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 5939 4485.51 5927 4474.98 NONE 5833' Casing Length Size MD TVD Burst Collapse Structural Conductor 112 20" 215# A-53 SURFACE 112 SURFACE 112 1490 470 Surface 138 9-5/8" 47# L-80 SURFACE 138 SURFACE 138 6870 4760 Intermediate Production 5900 7" 26# L-80 ' SURFAC 5928 SURFACE 4476 7240 5410 Liner Pertoration Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 3-1/2" 9.2# L-80 URFACI 5620 Packers and SSSV Tvpe: 7"x3-1/2" baker premier pkrs Packers and SSSV MD and TVD (ft): 5290 3940 7"x3-1/2" baker premier pkrs 5436 4052 7"x3-1/2" baker premier pkrs 5567 4161 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ ' 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 9/13/2010 Oil ^ Gas ^ WDSPL ^ Suspended - 16. Verbal Approval: Date: WINJ ^~ - GINJ ^ WAG ^ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Keith Lopez Printed Name Keith Lopez Title Well Engineer Signature Phone Date 564-5718 8/30/2010 Prepared by Ga Preble 564-4944 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 ° ~~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ O 1 ,~y i l f~'r ther: . ire ~ ~ 201~~' ~ `' ~ .r ~ ~ ~ ya ~~4"~~4'iNSS10~ Subsequent Form Required: _ ~ ~ ~ ~ ~.il..lt f?~, APPROVED BY ~ ~~ `~ Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 1/2010 ~ R ~ Submi ' I' " ~ ~~/~ MPS-11 202-113 DFDF ATTA(_NMFNT Sw Name Perf Operation Code Operation Date Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPS-11 PER 8/28/02 5,500. 5,502. 4,104.12 4,105.79 MPS-11 APF 8/29/02 5,535. 5,550. 4,133.67 4,146.47 MPS-11 APF 8/29/02 5,600. 5,615. 4,189.46 4,202.45 MPS-11 SQZ 8/29/02 5,500. 5,502. 4,104.12 4,105.79 MPS-11 APF 5/13/06 5,385. 5,405. 4,011.32 4,026.94 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • i • kip To: Mark O'Malley/Nathan Leonard Date: August 30, 2010 MPU Well Operations Supervisor From: Keith Lopez, MPU Schrader Pad Engineer 907-564-5718 Subject: MPS-11 MBE Treatment Step Unit Operation 1 F Shut in all offset producers. Bullhead water into MPS-11. 2 F Bullhead treatment down MPS-11 (OB sand . Keep well and offset producers and injectors shut in for minimum o 2 days and flow producers to a tank before returning to production. OBJECTIVE 1. Divert water by sealing the preferential path of injection with a cement acting fluid and a rigid gel. Measure of success 1. Treatments are fully displaced into formation. 2. Post injection is adequate to achieve injection rate target at below target pressure. 3. Decrease of watercut over time in offset producers is seen. CRITICAL ISSUES • Ensure pumping pressure is not above the fracture gradient. • Ensure cleanliness of pump equipment and hard line (pre and post job) & properly dispose of remnant fluid per guidance from the Environmental Team. PROCEDURE Stage 1. Injection Test 1. RU, hold pre-job safety meeting, PT surface lines 2. Ensure offset producers are SI. 3. Spear in with Methanol, followed by produced water. Attempt to hold injection rate constant while adjusting pressure as needed. 4. Contact Engineering to discuss the injection pressure/rate trends. Once consensus is achieved that the fluid can be successfully placed into formation at acceptable rate/pressure continue with remainder of program. • Stage 2. Treatment 5. Ensure offset producers are offline 6. Pump produced water pre-flush followed by cement acting fluid treatment and diesel displacement. Allow setup time. 7. Pump produced water pre-flush followed by high volume gel treatment and diesel over flush. 8. Capture a gel sample at surface and suspend in a warm water bath (to simulate downhole conditions) to monitor actual setting time. 9. Rig down all equipment and hold post-job assessment meeting to capture learnings to be incorporated into future jobs. 10. Forward all post job assessments (w/all rheology test summary) and continuous pressure and rate data from job to Pad Engineer. Tree:. 3 1 ~ B" -°_~A U"Se~lhead: Gen 5~,11~H S 5,"B x i 1 €1" x 3 1 s B' S1A FMC Adapter 3` Clbh`-H BP~J pro~tle wt TC-II T&~B thread 20'x34' r<sulated, 24 5 #'ft A-53 11 Triple Connect fcr the tie in 11 D F,'8" 4 ra*, BTC. L-8D Casing "~9' vr," eut lip guide ~~' ~ "~ 1 N:t7P ~' 411' fulax. hole angle = 5t1 deg ,'~ 375fi' Hose angle three perfs = 31 C1EG. 7" #, L-8D.. BTR~ Easing (drift ~1= 8a15L cap.= .D383 bpk5 31a~ , 8.3;.r~ L-BD. TC-li 2ubirrg tdrit id = 2.88?, cap.=..DDB? bpf4 Sfae JISf lnterral ~°T'r°~3~ B sands 3 3"'?r" 8 93.9x` - 5~4D5' '" 4Q'' °' - #D_8' 3 ~.~` 4 , .,A sands 55fYD' - 9942' Squ~zed ¢ `.935' - 5990' 4+34' - 4147' 3-~r8, 8 9930" - 5543' 412€+" - 4137' 3 3i?' $ 559D' - 555D' 4146' - 4155' ~3 sands 3,~8' ~ 55DD~ - 98 ~€• 4180• - 42x2° 9a4~.• 7' Ha ~~~~ Float Canar Para ~, - 9g~9' T" -~alliburton flcaa shae ~ ~ '~~~~~ ~ _ C?rig. K13 E:ev. = P,i3.+9Q CSr~. GL Elev. = 3°~.~[l 3.9' HE5 X-Hippie ~ 2.81 ?° Profile ~3~G, Valwe Gsanfigurat?ran as of 111-24-10 3.5' x '.5' Camx hfMG 5178` 3.5' HEM X-Paipple f e.813` Prof"Ie 9 527iJ` 7` x 3.5' Baker Premier Pkr 5290", 3.9" x 1.5' Carncc h1MG 5317' 3.,5' x 1.9` Camc€a Mh1^3-"Vs" 5'75' 7' x 3.5' Baker fyrerwe~r Pkr 54x8' 3.5' x 1.9' Camx hfMG 5483' 3.5` x 1.5' Camcs7 MhfG-'+1f 5` ~ 1 • r x 3.5' Baker Premier Pkr 5587' 3.5` x 1.5 Camca 141hfG-+r'~` 5584` C~.ATE REV. BY ~.C~th4ENT5 D8 ~ ;~~~2 hfQCa Lrilled by Casey: G:oycr" 141 DBia1,4}L LeP T?L1Irr°$' ttonT~leucr* Rfg 4Ev D5" t3f08 h+i1a~ R1h"~7 ~ Add Perfs Qc+ycn-?~4 4,~27"'D8 H MILNE PGtINT UNIT WErLyL~yNy(ay~,:yryS~y-~'iy+1y /~ ~~1 : rJO-Q2El-231192'-44 ~bV'v 8 Re-camplete as 3 1t2' ;7c}~n-td g,,,., ~~,,,nr rln wTrr-~wr J A • MEMORANDUM TO: Jim Regg ~ b~ Z5'~o 4~ 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 5-11 MILNE PT UNIT SB S-11 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~ Comm Well Name: MILNE PT UNIT SB S-11 API Well Number: 50-029-23092-00-00 Inspector Name: Bob Noble Insp Num: mitRCN100607113713 Permit Number: 202-113-0 Inspection Date: 6/5/2010 Rel Insp Num: Pretest Initial Packer Depth 15 Min. 30 Min. 45 Min. 60 Min. /ell i S-11 / Type Inj. W TVD _ 3940 / P.T.D 2o211so TypeTest SPT' Test psi 2000 -- ~I,~ 20 OA 2000 1940 1940 Interval OTHER P~F P ,/ Tllbing 1280 i 1300 1300 1300 Notes: 2 yr monobore UIC ~ ` 's ~ l ZD~^ ~~l r_e ~~ s ~ (~ rs r Thursday, June 10, 2010 Page 1 of 1 STATE OF ALASKA • ~-90~ ALA OIL AND GAS CONSERVATION COMMISSION R E ~..r E l Y U REPORT OF SUNDRY WELL OPERATIONS ~uN o ~ 2oaa 1. Operations Performed: ^ ® ^ ~A~eC~i ~~ ~0~~ ~~~~ . Abandon Re air Well , p Plug Perforations ^ Stimulate e- ntgr ~spe e l~tiC, ~C31'8g6 ® Alter Casin g ®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 202-113 , 3. Address: ®Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23092-00-00 7. KB Elevation (ft): 66.6' ~ 9• Well Name and Number: MPS-11 i 8. Property Designation: 10. Field /Pool(s): ADL 380110 Milne Point Unit / Schrader Bluff 11. Present well condition summary Total depth: measured 5939' ~ feet true vertical 4486' - feet Plugs (measured) None Effective depth: measured 5843' feet Junk (measured) 5833' true vertical 4401' feet - Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20" 112' 112' 1490 470 Surface 138' 9-5/8" 138' 138' 6870 4760 Intermediate Production 5900' 7" 5928' 4476' 7240 5410 Liner ~~1~ED JUL ~. ~ 200 Perforation Depth MD (ft): 5385' - 5615' Perforation Depth TVD (ft): 4011' - 4202' 3-1 /2", 9.2# L-80 5620' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): (3) 7" x 3-1/2" Baker Premier Packers 5290; 5436' & 5567' S~S~~~~res~ ~'~ 12. Stimulation or cement squeeze summary: ~ ~ Intervals treated (measured): Its-C~ Treatment description including volumes used and final pressure: Cut & pull dual-string completion. Set BP at 2500' & w/ sand on top, run USIT. Cut 7" casing & mill to -117'. Run 9-5l8" Surface casing to 138'. Run 7" tieback & cmt both annuli w/ 62 Bbls DeepCrete (348 cu ft / 91 sx). CO sand & pull RBP. Push EZSV to bottom at 5833'. Run new tubing. 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: None Subsequent to operation: 1,066 (Produced Wtr) 540 1,206 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ^ Development ®Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ^ Oil ^ Gas ^ WAG ^ GINJ ®WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A ff C.O. Exempt: Contact Bryan McLellan, 564-5516 308-124 Printed Name Terrie Hubble Title Drilling Technologist ~ Prepared By NameMumber: / O Signature Phone 564-4628 Date ~ Q 7~v Terrie Hubble, 564-4628 IQfT Form 10-404 Revised 04/2006 Submit Original Only ~ ~F~ JUt~ 1 6 20D6 ~j-'tile, Digital Well File ~ Page 1 of 1 Well: MPS-11 Well History Well Date Summary MPS-11 3/29/2008 ***ARRIV ON LOC WELL S/I «««LONG STRING»»> PULL PLUG BHPS RESET PLUG AND MIT- T .PULL PRONG Q 2223 SLM PULL PLUG BODY ~ 2223 SLM RAN 1.73 CENT SOFT SET SPARTEK GAUGES L.OC.END OF TUBING ~ 5456' SLM = +19 CORR. TO MD. TAG TD. @ 5548' SLM / 5567' MD. MADE 3 HR STOP. MADE 30 MIN STOP @ 4956' SLM / 4975' M RAN 2' X-LINE AND 2 3/8 XXN PLUG SET@ 5445 SLM. RECOVERED ALL PINS DID MIT-T TO 1000 ,~bT-~~$ «««SHORT STRING »»> PULL XX PLUG C~ 2166 SLM RAN 1.85 CENT SOFT SET SPARTEK GAUGES TO 5346 SLM / 5360' MD FOR 3 HOURS MADE 30 MIN STOP @ 4845' SLM / 4859' MD. ***CONT ON 3/30/08*** MPS-11 3/30/2008 *** CONT FROM 3/29/08 *** «««<SHORT STRING»»»> SET PXN PLUG /8 PXN PLUG SETC~ 5,345' SLM BLEED DOWN TO 0 PSI MIT-T TO 1000 PSI PASSE BG LOST 45 PSI IN FI 15 ECOND 15 MINS AND 0 PSI IN THIRD 15 MINS FOR A TOTAL LOST OF 50 PSI IN 45 MINS. BLED TBG DOWN TO 32 PSI. *** JOB COMPLETE *** MPS-11 4/1(2008 CUT BOTH STRINGS OF 2-3l8" TUBING WITH 1-11116" SLB POWER CUTTER. »»SHORT STRING«« CUT SHORT STRING AT 5343, MIDDLE OF 6.2' PUP JOINT ABOVE PACKER. »» «« CUT LONG STRING AT 5230', MIDDLE OF 3RD FULL JOINT ABOVE X-NIPPLE. MPS-11 4/6/2008 T/IA/=SSV x 2 /0 Temp=cold PPPOT-T (PASS) (PRE RWO) PPPOT-T RU 2 HP bleed tools onto THA 50 psi to 0 psi, flush void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 5000/ 15 minutes, 4950/ 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-11 4/9/2008 The Well Support Techs rigged up and set a BPV in each the long and the short string; They removed the wellhouse, flowlines and the grating. The handrails were removed on S-09 and S-10 and S-12 wellhouse will still need to be removed later so the rig will fit on the well. Print Date: 6/4/2008 Page 1 of 1 http://digitalwellfile.bpweb.bp.com/Wllnfo/Reports/ReportViewer.aspx 6/4/2008 • BP Operations Summary Report Legal Well Name: MPS-11 Common Well Name: MPS-11 (Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 i Date From - To Hours Task ,Code NPT 4/18/2008 117:00 - 19:00 I 2.001 RIGD I P 19:00 - 21:00 I 2.00 I MOB I P 21:00 - 00:00 I 3.00 I MOB I P Start: 4/18/2008 Rig Release: 4/30/2008 Rig Number: 14 Page 1 of 10 ~ Spud Date: End: 4/30/2008 I Phase Description of Operations PRE -RD rig floor. Blow down same -Skid rig floor to moving position PRE -Move rig off well MPS-31 -Move down pad towards well MPS-11 PRE Spread herculite and LD rig mats around well MPS-11. Stage tools behind well (tree, tubing spool, etc) 4/19/2008 00:00 - 01:00 1.00 MOB N WAIT PRE Finished LD rig mats to position rig. 01:00 - 02:00 1.00 MOB N WAIT PRE Wait on Pad Operator, who requested to be present when moving rig over well 02:00 - 03:00 1.00 MOB P PRE -Move rig over well MPS-11 -Shim rig 03:00 - 04:00 1.00 RIGU P PRE Skid rig floor to drilling position 04:00 - 05:00 1.00 RIGU P PRE -RU rig floor -Spot and berm rock washer -Accept rig ~ 02:00 4-19-2008 - Rig acceptance adjusted back 3 hours due to waiting on well site preparation to set mat boards and waiting on pad operator 05:00 - 07:00 2.00 WHSUR P DECOMP -Take on 8.7 ppg brine in pits -Spot tiger tank and RU hard line -RU lines to tree to circulate out freeze protect -Install double annulus valve. -Test gas alarms 07:00 - 08:30 1.50 WHSUR P DECOMP -RU DSM lubricator. Test to 500 psi x 5 min. Pull BPVs 08:30 - 09:30 1.00 WHSUR P DECOMP -Check hard line for leaks w/ air. -Pressure up to 3,500 psi w! water. Good test -RU to displace freeze protect. 09:30 - 14:00 4.50 WHSUR P DECOMP -Pump 10 bbls soap pill down short string and follow w/ 25 bbls 8.7 ppg brine taking returns out annulus to tiger tank. 3 bpm / 740 psi. -Close in short string. Pump 30 bbls soap pill down long string. -Circulate down long string w/ 170 bbls of 8.7 ppg brine taking returns out annulus to tiger tank. 2-3 bpm / 450-900 psi. Adjust pump rate since observed leaking out through conductor. Suck with vac truck f/ conductor while cont. displacing. -Wait 20 min for diesel migration. Pump additional 20 bbls of 8.7 ppg brine down long string, taking returns out annulus to tiger tank. Verify well dead. 14:00 - 15:30 1.50 WHSUR P DECOMP -Install TWC valves in short string and long string -Test each TWC to 3,500 psi x 10 min f/above. Chart tests. 15:30 - 16:30 1.00 WHSUR P DECOMP ND tree 16:30 - 18:30 2.00 BOPSU P DECOMP NU BOP stack 18:30 - 19:30 1.00 BOPSU P DECOMP Install extension on choke line 19:30 - 20:30 1.00 BOPSU P DECOMP C/O top rams to 2-3/8" dual rams 20:30 - 21:30 1.00 BOPSU P DECOMP RU to test BOP. Install 2-3/8" dual test joint in top rams 21:30 - 00:00 2.50 BOPSU P DECOMP Test BOP and related equipment per BP / AOGCC procedures and regulations: -Test top rams, choke manifold, HCR kill, manual kill, 2-3/8" TIW valves (2), and 2-3/8" dart valves (2) with 2-3/8" dual test joint in top rams -Test to 250 psi low - 3,500 psi high x 5 min each on chart. -Test witnessed by WSL and Tourpusher. Bob Noble, AOGCC rep, waived witness of test Printed: 5/15/2008 9:20:19 AM g p Page 2 of 10 Operations Summary Report Legal Well Name: MPS-11 Common Well Name: MPS-11 Spud Date: Event Name: WORKOVER Start: 4/18/2008 End: 4/30/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 4/30/2008 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours ' Task ;Code NPT Phase Description of Operations _ 4/20/2008 __ 00:00 - 03:30 3.50 BOPSU P DECOMP _ Cont. testing BOP and related equipment per BP / AOGCC procedures and regulations: -Cont. testing IBOP, manual IBOP, HCR choke and manual choke w/ 2-3/8" dual test joint in top rams. Test to 250 psi low - 3,500 psi high x 5 min each on chart -Pull 2-3/8" dual test joint. Run 5" test joint w/ bottom donut. -Test bottom rams and annular preventer. Test to 250 psi low - 3,500 psi high x 5 min each on chart -Perform koomey test. -Test blind rams to 250 psi low - 3,500 psi high x 5 min each on chart. -Test witnessed by W SL and Tourpusher. Bob Noble, AOGCC rep, waived witness of test 03:30 - 04:00 0.50 BOPSU P DECOMP -RD testing equipment -Blow down lines -Suck out stack 04:00 - 07:30 3.50 WHSUR P DECOMP -RU lubricator and lubricator extension (OPSO-LOPSO). crew into hanger. Test to 500 psi x 5 min -Attempt to back off lubricator. It backed off at connection above sub screwed in tubing hanger (on lubricator extension). Attem t to MU and back 07:30 - 08:00 0.50 WHSUR N SFAL DECOMP -Reset TWC. Test f/ top to 1,000 psi x 10 min 08:00 - 09:30 1.50 WHSUR N SFAL DECOMP -ND flow line. -Break BOP stack above tubing spoof and lift. -Back out lubricator extension from tubing hanger. -NU BOP stack and flow line. Tighten connections on lubricator extension 09:30 - 10:30 1.00 WHSUR N SFAL DECOMP -RU to test break. -Close blind rams. Test break on stack to 250 psi low - 3,500 psi high x 5 min each. -RD testing equipment. Suck out stack 10:30 - 11:30 1.00 WHSUR N SFAL DECOMP -RU lubricator and lubricator extension. Screw into tubing hanger and test to 500 psi x 5 min. -Pull TWC from one string. Repeat and pull TWC from second ~strin -RD lubricator. Break off pup jts and XOs 11:30 - 13:00 1.50 PULL P DECOMP -Mobilize tools to handle dual string to rig floor -RU to ull 2-3/8"dual strip com letion 13:00 - 14:00 1.00 PULL P DECOMP -Screw 2-3/8" pulling joints into tubing hanger -Backout LDS. Pull tubing hanger to rig floor w/ PUW 94k (blocks weight: 50k). LD tubing hanger and pulling joints. 14:00 - 22:30 8.50 PULL P DECOMP POOH and LD 2-3/8" 4.7# L-80 IBT tubing and completion equipment f/ long string. -Leave +/-3 jts hanging on slips before LD short string for well control contingency w/dual rams 22:30 - 00:00 1.50 PULL P DECOMP POOH and LD 2-3/8" 4.7# L-80 IBT tubing and completion equipment f/short string. 4/21/2008 00:00 - 05:00 5.00 PULL P DECOMP -Cont. POOH and LD 2-3/8" 4.7# L-80 IBT tubing and completion equipment f/short string. -LD joints left on slips ff long string. -Total jts LD: 167 jts + 15.4' cutoff (long string) ; 171 jts + 4.0' cutoff (short string) Printed: 5/15/2008 9:20:19 AM • • gP Page 3 of 10 Operations Summary Report Legal Well Name: MPS-11 Common Well Name: MPS-11 Spud Date: Event Name: WORKOVER Start: 4/18/2008 End: 4/30/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 4/30/2008 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours ' Task Code NPT Phase Description of Operations 4/21/2008 00:00 - 05:00 5.00 PULL P DECOMP -Cuts clean w/flare 2-7/8" OD on both strings -Estimated top of long string: +/- 5,230' 05:00 - 05:30 0.50 PULL P DECOMP RD dual string handling equipment. Clear rig floor 05:30 - 08:00 2.50 BOPSU P DECOMP -Install test plug -C/O to rams to 3-1/2" x 6" VBR 08:00 - 08:30 0.50 BOPSU P DECOMP RU to test 08:30 - 09:30 1.00 BOPSU P DECOMP Test annular preventer, top rams and bottom rams w/ 4" test joint. Test also 4" dart and TIW valves. All tests to 250 psi low - 3,500 psi high x 5min each on chart. 09:30 - 10:00 0.50 BOPSU P DECOMP -RD testing equipment. -Pull test plug -Install wear bushing 10:00 - 10:30 0.50 CLEAN P DECOMP Mobilize BHA tools and 7" RTTS packer to rig floor 10:30 - 11:00 0.50 CLEAN P DECOMP MU cleanout BHA: 6-1/8" bit + 7" casing scraper + bit sub + XO + (6) 4-3/4" DCs 11:00 - 13:30 2.50 CLEAN P DECOMP RIH w/ 4" DP to +/- 2,650' 13:30 - 15:30 2.00 CLEAN P DECOMP -MU 7" RTTS packer on top of string -Set RTTS ~ 64' COE below rota table +/- 3 ' round level ., -Test 7" casing below RTTS to 2,000 six 30 min on chart. Good test 15:30 - 16:30 1.00 CLEAN P DECOMP -Release and pull RTTS packer to rig floor. LD same. -POOH w/ cleanout BHA 16:30 - 17:00 0.50 CLEAN P DECOMP -Stand back 4-3/4" DCs. LD rest of BHA -MU 7" RBP 17:00 - 19:00 2.00 DHB P DECOMP -RIH w/ 7" RBP -Set 7" RBP ~ 2,500' (COE . To of tool ~ 2,496'. -Pull one stand. Dump 1,200 lbs. 20/40 river sand on top of lu -Run one stand back in hole. T a sand l~ 2.448' 19:00 - 21:00 2.00 DHB P DECOMP -POOH w/ RBP running tool -LD RBP running tool. Clear rig floor 21:00 - 22:00 1.00 EVAL P DECOMP -ND flow line and riser. -NU shooting flange 22:00 - 00:00 2.00 EVAL N WAIT DECOMP Wait on Schlumberger a-line equipment -Crane truck had mechanic problems while on its way to rig. Schlumberger crew had to turn back to base to change crane truck. 4/22/2008 00:00 - 00:30 0.50 EVAL N WAIT DECOMP Cont. waiting on Schlumberger a-line equipment 00:30 - 04:30 4.00 EVAL P DECOMP Spot Schlumberger unit and stage tools -RU lubricator extension, pump in sub, lubricator and packoff. -Test to 500 psi x 5min. Good test -MU USIT tools and test. 04:30 - 09:00 4.50 EVAL P DECOMP RIH w/ USIT - -Log up in 7" casing on cement and corrosion mode f/ 2,000' md. 09:00 - 10:30 1.50 FISH P DECOMP RD USIT Tool. Rehead f/ String shot. -RU String shot 10:30 - 11:00 0.50 FISH P DECOMP RIH w/ Strin shot to 76' md. Make shot. 11:00 - 11:30 0.50 FISH P DECOMP RD SLB Tools, Sheaves & Lubricator. 11:30 - 12:00 0.50 FISH P DECOMP ND Shooting flange. NU Picture nipple. 12:00 - 14:00 2.00 FISH P DECOMP ND BOP's. 14:00 - 15:00 1.00 FISH P DECOMP Cut 7" Csa head int rnally 40" ~IPIO~^! ~DP.P.d I'lAad ~!/ ~~!ACH$ Printed: 5/15/2008 9:20:19 AM r BP Operations Summary Report Page 4 of 10 '.Legal Well Name: MPS-11 Common Well Name: MPS-11 Spud Date: Event Name: WORKOVER Start: 4/18/2008 End: 4/30/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 4/30/2008 Rig Name: DOYON 14 Rig Number: 14 Date. From - To ', Hours Task Code NPT Phase Description of Operations 4/22/2008 114:00 - 15:00 I 1.001 FISH I P 15:00 - 18:00 3.00 CLEAN P 18:00 - 19:30 1.50 CLEAN P 19:30 - 20:00 0.50 CLEAN P 20:00 - 21:30 1.50 CLEAN P 21:30 - 22:30 I 1.00 I CLEAN I P 22:30 - 00:00 1.50 CLEAN P 4/23/2008 00:00 - 00:30 0.50 CLEAN P 00:30 - 02:30 2.00 CLEAN P 02:30 - 04:00 1.50 CLEAN P 04:00 - 04:30 0.50 CLEAN P 04:30 - 06:00 1.50 CLEAN P 06:00 - 08:00 ~ 2.00 ~ CLEAN ~ P 08:00 - 09:00 1.00 CLEAN P 09:00 - 09:30 0.50 CLEAN P 09:30 - 10:00 0.50 CLEAN P 10:00 - 10:30 0.50 CLEAN P DECOMP cutter. -Pull cut jt. LD Mandrell hanger and Speed head. DECOMP NU new 20" Riser (weld 2 pieces together). DECOMP Hook up Turnbuckles, Flow line & Fill up line. -Fill stack & check for leaks. DECOMP PU BHA to Rig floor. DECOMP MU Washover BHA: -Rotary shoe, 1 jt of 11 3/4" Wash pipe, Drive sub Boot basket, -1-8" D.C. & XO. DECOMP Tag Cmt ~ 36' md. Wash over & Mill over 7" Csg to 66' md. -620 gpm / 140 psi. 2-4k WOB, 40 RPM @ 0-2k Tq. -PUW, SOW & ROT wt =55k. DECOMP POH. Add 2nd jt of Wash pipe to BHA. -Clean out Boot basket (1- 5 gal bucket of cuttings). DECOMP Wash over & Mill Cmt from 66' to 86' md. -630 gpm / 130 psi. RPM 40 ~ 0-2k Tq. -PUW, SOW & ROT wt= 70k. WOB 2-4k. DECOMP Pump 4 Hi Vis Sweeps (YP 36). Circulate hole clean. -Recip & rotate while circulating. DECOMP LD D.C's. Rotary shoe & Wash pipe. -Clean out Boot basket (1- 5 gal bucket of cuttings). -Suck out Stack. DECOMP Clear Rig floor of vendor Tools. DECOMP MU Rackoff BHA: -7" Type "B" Csg Spear, Stop sub 8 1/2" OD Ring, -XO sub, Bumper sub & XO sub. DECOMP Rig up to back off. Establish depth. -Set bottom anchor with 500 psi. -Slack off, set top anchor with 1700 psi. -Back off 7" casin 4 rounds. DECOMP Lay down back off assembly. DECOMP Clear floor of vendor tools. DECOMP Make up spear assembly. DECOMP RIH 42', engage 7" casing. -Pick up to 75K. Slack off to 58K. 10:30 - 11:00 0.50 CLEAN P DECOMP POH with one joint of 7" casing (41.33'). -Lay down spear. -Lay down 7" casing. - 7" casing description - (2 holes 1/4" diameter 26' from ground level -entire joint heavily corroded - +/-12" split +/-3' from bottom of joint where backoff tool anchor was set) 11:00 - 14:00 3.00 CLEAN P DECOMP Nipple down flow line and 20" riser. -Suck out water in 20" conductor. -Cut riser to facillitate removal and remove same. 14:00 - 14:30 0.50 CLEAN P DECOMP Rig up to run 7" 26# casing. 14:30 - 16:00 1.50 CLEAN P DECOMP Make u 2 joints of 7" casin 10' u 'oint and Tri le c n -Make up on 7" casing stump at 76' md. -Fill casing with water for casing prep. -Water leaking out around casing stump. 16:00 - 17:00 1.00 CLEAN P DECOMP Back out and lav down casing assembly. Printed: 5/15/2008 9:20:19 AM • • BP Operations Summary Report (Legal Well Name: MPS-11 Common Well Name: MPS-11 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To Hours Task. Code NPT 4/23/2008 117:00 - 21:30 I 4.50 I CLEAN I P 21:30 - 23:30 I 2.00 I CLEAN I P 23:30 - 00:00 I 0.501 CLEAN I P 4/24/2008 00:00 - 02:30 2.50 CLEAN P 02:30 - 03:00 0.50 CLEAN P 03:00 - 12:00 I 9.001 CLEAN I P Page 5 of 10 ~ Spud Date: Start: 4/18/2008 End: 4/30/2008 Rig Release: 4/30/2008 Rig Number: 14 Phase Description of Operations DECOMP Make up surface Stack flange and install Riser. -Weld Riser together. -Install Fillup and Flow line. DECOMP Make up BHA: Rotary shoe, 2 joints 11 3/4" Washpipe, -Drive Sub Boot Basket, 3 8" DC, X-O Sub, 4 1/2" IF Pup joint, -X-O Sub DECOMP Mix Spud Mud: Gel & water (300 sec/qt + 38 degrees F). -Screen down on shakers. (100s & 120s). DECOMP Continue to mix Spud mud (300 sec/qt). DECOMP Tag up on 7" Cs slum . -Fill conductor with 8.6+ ppg, 300 sec/qt "Spud Mud". DECOMP Wash over 7" Cs slum & drill Cmt f/ 86' to 138' md. -PUW, SOW & ROT wt= 68k.Tq= 5k ~ 40 RPM. -300 gpm / 120 psi. WOB 2-5k. -Mud returns dropped off. -Total losses of 20 bbls then full returns were acquired. 12:00 - 13:00 I 1.00 I CLEAN I P 13:00 - 14:00 1.001 CLEAN P 14:00 - 15:00 1.00 CLEAN P 15:00 - 15:30 I 0.501 CLEAN I P 15:30 - 17:00 1.50 CLEAN P 17:00 - 18:00 1.00 CLEAN P 18:00 - 19:00 1.00 CLEAN P 19:00 - 20:30 1.50 CLEAN P 20:30 - 21:30 1.00 CLEAN P 21:30 - 22:30 1.00 CLEAN P 22:30 - 00:00 1.50 CLEAN P 4/25/2008 100:00 - 01:30 I 1.501 CLEAN I P 01:30 - 02:30 1.00 CLEAN P 02:30 - 03:00 0.50 CLEAN P 03:00 - 03:30 0.50 CLEAN P -Partial loss of returns noted ~ +/- 10 bph. DECOMP Circulate to clean and condition hole. -310 gpm / 90 psi. 1 k Tq at 70 rpm. -Partial loss of returns noted while drilling. DECOMP POH. Change out 12.25"x10.75" mill. -PU new 12.25" X 9.625" mill DECOMP RIH, tag bottom with shoe assembly. 1' of fill noted. -1 k Tq at 20 rpm, 84 gpm / 40 psi. Circulate hole clean. -Pick up above bottom of conductor. DECOMP Thin mud in pits with Desco and water for rheological control. -Lower YP from 60 to 27. -Run back to bottom without pumps or rotation; no fill noted. -Displace well to thin mud. -250 gpm / 60 psi. DECOMP POH. Lay down BHA. DECOMP Clean and clear Rig floor of vendor tools. DECOMP Ri u to run 9 5/8" casin . DECOMP Run 9 5/8" casing to 135' and RKB. -Land Hanger. Back out Landing jt. -Lay down landing joint. DECOMP Clean and clear Rig floor of vendor tools. DECOMP PU Backoff Tools to Rig floor. DECOMP MU Backoff tools. RIH to Top anchor setting depth of 110' and RKB. -Pressure up on Backoff tool to 1800 psi. -1800 psi = 12k Tq to break connection. Total mud losses = 100 bbls. DECOMP Continue to pressure up and bleed off to back off 7" Csg. -Repeat until) 7" Csg jt is backed off 3 turns. -Final pressure 500 psi, 3.2k Tq. DECOMP POH, LD Back off Tools. DECOMP Clear Rig floor of vendor Tools. DECOMP MU Spear Assy & 1 Std of D. P. R1H. -Engage 7" Csg. Stop Ring @ 76' md. -Back off 7" Csq 10 turns. Printed: 5/15/2008 9:20:19 AM ~J gp Page 6 of 10 Operations Summary Report Legal Well Name: MPS-11 Common Well Name: MPS-11 Spud Date: Event Name: WORKOVER Start: 4/18/2008 End: 4/30/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 4/30/2008 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours I Task Code NPT Phrase Description of Operations - _ 4/25/2008 - 03:30 - 04:30 _ 1.00 CLEAN P ~ - _ DECOMP _ __ - --__ POH w1 Fish. Stand back 1 Std of D.P. -Make service breaks. LD Spear. LD 1 jt of 7" Csg. -7" Csg description: -2" split +/-1' below collar - 6" split +/- 3' below collar. -Several small pit holes. -Heavily corroded down to within +/-6' from bottom of joint. 04:30 - 06:30 2.00 CLEAN P DECOMP Nipple down flow line & Riser. -Cut Riser in half to facilitate removal. -Remove Riser & 20" Starting head from cellar. 06:30 - 08:30 2.00 CLEAN P DECOMP Mobilize 9 5/8" Starting head &Tbg spool to cellar. -MU Starting head (valve alignment verified by Pad op). -FMC test Starting head to 1000 psi / 10 minutes -Pass. 08:30 - 10:00 1.50 CLEAN P DECOMP Suck out 9 5/8" Csg & RU to run 7" Csg. 10:00 - 11:00 1.00 CASE P TIEB1 Change out Cut lip guide. -Run 7" 26# L-80 BTC Csg on 1 jt of 4" D.P. as follows: -Run 10' pup w/ centralizer & cut lip guide. -Run 2 full jts of 7" w/ 1-centralizer each. -Taa Csa stump ton ~ 11T md.. 11:00 - 12:00 1.00 CASE P 12:00 - 14:00 2.00 CASE P 14:00 - 16:30 I 2.501 CASE I P 16:30 - 18:00 I 1.501 CASE I P 18:00 - 21:00 I 3.001 CASE I P 21:00 - 22:30 I 1.501 CASE I P 22:30 - 23:00 0.50 CASE P 23:00 - 00:00 1.00 CASE P 4/26/2008 100:00 - 00:30 0.501 CASE P 00:30 - 02:00 I 1.501 CEMT I P -Test Csg to 500 psi - OK. -Torque up Tie back to 4.5k Tq. TIE61 RU & T t 7" T' k to 200 si / 30 minutes -Pass. TIEB1 Blow down Top Drive. -Suck out D.P. & 7" Csg. Remove Choke line extension. TIEB1 Pull up 20k over on 7". Set "E-Slips". -RU WACHS cutter & cut 7" Csg. TIEBi LD 7" Csg cut jt, XO & 1 jt of D.P. -RU to set Packoff. Set Packoff. Energize LDS. -MU Tbg spool & test to 4000 psi / 10 minutes-Pass. TIEB1 NU BOP Stack. RU to wellhead to circulate. -Install Riser, Flow line, Fill up line, Bleed off line & Turnbuckles. TIEB1 RU to test connection splits on Stack & Choke line. -Test to 250 psi low pressure / 3500 psi high pressure. -For 5 minutes each on chart -Pass. TIE61 Set Wear bushing. TIEB1 RU to circulate 90 de ree F 8.7 NaCI inside the 7" Cs . -RU to circulate lightly dispersed Gel mud. - Pump Gel mud down 7" X 9 5/8" up 9 5/8" X 20" conductor. -Pump 84 gpm / 100 psi. Got returns after 9 bbls away. TIEBi Continue circulating down 7" X 9 5/8" annulus, -Taking returns up 9 5/8" X 20" annulus. -Pump until mud in annulus is swapped to dispersed Mud (YP-12). -Pump rate 84 gpm / 80 psi. Stop pumping Mud. -Continue to pump 8.7 ppg NaCI down 4" D.P. up 7" annulus C«~ 90 degrees F. TIEB1 PJSM w/ Cementers, Truck drivers & Rig crew. -Batch up Mud Push. Pump down 7" X 9 5/8" annulus. -Taking returns up 9 5/8" X 20" annulus out conductor ports. -Pump as follows: 3 bbls of water & test lines to 1000 psi -Pass. -Pump 14 bbls of 10 ppg Mud Push. Printed: 5/15/2008 9:20:19 AM g p Page 7 of 10 Operations Summary Report Legal Well Name: MPS-11 Common Well Name: MPS-11 Spud Date: Event Name: WORKOVER Start: 4/18/2008 End: 4/30/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 4/30/2008 Rig Name: DOYON 14 Rig Number: 14 ~ Date ! From - To Hours Task Code NPT Phase Description of Operations 4/26/2008 00:30 - 02:00 1.50 CEMT P TIEB1 -Pum 62 bbls of 10.7 Crete Cmt. CIP ~ 02:00 hrs. -22 bbls of cement returns to surface noted. , - us mes with water through "T" to cuttings bbl. -Continue to pump 8.7 ppg NaCI down 4" D. P. up 7" annulus C~ 90 degrees F. -NOTE: -Will continue to ump warm 8.7 NaCI until Cmt UCA reaches 1000 si. 02:00 - 03:00 1.00 CEMT P TIE61 RD cementers. Remove conductor valves & Bull plug ports. -C/O Flange on lower annulus valve. 03:00 - 18:30 15.50 CEMT P TIEB1 Wait on cement until Cmt UCA reaches 1000 psi. -Clean Rig. Prep for Csg test. Clean Pits. -Prep to PU BHA & RIH to 2,448' and for clean out. -NOTE: Change in scope: Still waiting on cement UCA to get to 1000 psi. -UCA presently 472 psi after 14 hrs. -Discuss BOP test w/ town. -Called Chuck Scheve, he waived witness of test. 18:30 - 19:00 0.50 CEMT P TIEBi Continuing to pump 8.7 ppg NaCI down 4" D.P. up 7" annulus C~ 95 degrees F. -Stop circulation of warm brine. RD circulating equipment. -Rack back 2 Stds of 4" D. P. 19:00 - 19:30 0.50 CLEAN P TIEB1 Pull Wear bushing. 19:30 - 20:00 0.50 CLEAN P TIEB1 PJSM. RU to test BOP's. 20:00 - 00:00 4.00 CLEAN P TIEB1 Test BOP's. --BOP Configuration: -Hydril GK 13 5/8" 5000. -3 1/2" X 6" Variables. -Blind Rams. -Drilling Spool. -2 7/8" X 5" Variables. -Test Hydril Bag -Test Valves: 1,2,3,4,5,6,7,8,9,10,11,12,13 &14. -Test Manual valve, Kill, Choke, HCR Choke & Kill, -Upper & Lower IBOP. -TIW & Dart valves. -Pass -Perform Koomey test. -200 psi build up = 33 seconds. -Total pressure build back to 3050 psi =2 min 45 seconds. -Test upper & lower Rams w/ 4" -Pass. -Test 250 low psi & 3,500 psi High psi. -Hold each test for 5 minutes. Chart all tests. -Test witnessed by T.P. & WSL. -Test witness waived by Chuck Scheve AOGCC. 4/27/2008 00:00 - 01:30 1.50 CLEAN P TIE61 Continue to test BOP's. --BOP Configuration: -Hydril GK 13 5/8" 5000. -3 1/2" X 6" Variables. -Blind Rams. -Drilling Spool. -2 7/8" X 5" Variables. Printed: 5/15/2008 9:20:19 AM • • gp Page 8 of 10 ~ Operations. Summary Report Legal Well Name: MPS-11 Common Well Name: MPS-11 Spud Date: Event Name: WORKOVER Start: 4/18/2008 End: 4/30/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 4/30/2008 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours rr Task i CodeT' NPT Phase - ~ ICLEAN P I 4/27/2008 00:00 - 01:30 1.50 TIEB1 01:30 - 02:00 I 0.501 CLEAN I P I ITIEBI 02:00 - 02:30 0.50 CLEAN P TIEB1 02:30 - 04:30 2.00 CLEAN P TIEB1 04:30 - 05:00 I 0.501 CLEAN I P I I TIEB1 05:00 - 05:30 0.50 CLEAN P TIEBi 05:30 - 06:00 0.50 CLEAN P TIEB1 06:00 - 06:30 0.50 CLEAN P TIEB1 06:30 - 07:00 0.50 CLEAN P TIEB1 07:00 - 07:30 0.50 CLEAN P TIEB1 07:30 - 08:00 0.50 CLEAN P TIEB1 08:00 - 09:00 1.00 CLEAN P TIEB1 09:00 - 09:30 0.50 CLEAN P TIE61 09:30 - 10:00 0.50 CLEAN P TIE61 10:00 - 10:30 0.50 CLEAN P TIE61 10:30 - 12:30 2.00 CLEAN P TIE61 12:30 - 13:30 I 1.001 CLEAN I P 13:30 - 15:00 1.50 CLEAN P 15:00 - 16:00 1.00 CLEAN P 16:00 - 17:00 I 1.001 DHB I P 17:00 - 20:00 I 3.00 I CLEAN I P 20:00 - 20:30 I 0.501 CLEAN I P Description of Operations -Test upper & lower Rams w/ 3 1/2" test jt -Test Blind Rams. -Test 250 low psi & 3,500 psi High psi. -Pass. -Hold each test for 5 minutes. Chart all tests. -Test witnessed by T.P. & WSL. -Test witness waived by Chuck Scheve AOGCC. RD test equipment. Pull test plug. -Install Wear bushing. MU Reverse circulating junk basket (RCJB) BHA. Single 4" D. P. in hole with RCJB BHA from 110' and to 1,525' md. Circulate hot NaCI brine ~ 1,525' and to warm up wellbore. -Initial: Brine temp in is 95 F, out 65 F. -Final: Brine temp in is 85 F, out 88 F. -Pump rate 211 gpm / 250 psi. Single in hole from 1,525' to 2,400' md. Establish circulation & parameters: -PUW 85k, SOW 80k, Rot wt 80k, 211. gpm / 250 psi. -RIH, Tag sand ~ 2,446' md. PU drop ball. -Wash out sand f/ 2,446' to 2,451' and - 423 gpm / 1600 psi. Circulate hole clean. 423 gpm / 1600 psi. POH w/ Reverse Circulating Junk Basket (RCJB). Stand back D.C's. Make service breaks. -Clean out Junk basket: -(Small slivers of metal shavings & some cement bits). -LD RCJB. Clear Rig floor. PU RBP retrieval Tools. MU Retrieval tool &RIH-(single in) PU 33 jts to 1,060' md. Continue to RIH from derrick to 2,385' md. Wash out sand down to RBP ~ 2,496' md. -PUW 80k, SOW 78k, 343 gpm / 380 psi. Pump HV Sweep (Duo-vis ~ YP-40) surface to surface. -Circulate hole clean. -LD: RBP & Haliburton Tools. -PU Baker Tools to Rig floor. TIE61 MU Baker BHA: Hollow mill container, Overshot, Upper extension, -Bumper sub, Oil jar, XO, D.C's., XO, Accelorator, Pump out sub, XO. TIEB1 RIH w/ Overshot f/ 229' to 5,061' and w/ 4" D.P. DECOMP RU to circulate & test 7" Csg. -Test 7" Csg to 1500 qsi / 30 minutes -Pass. -Blow down lines. RD test equipment. TIEB1 RIH w/ 2 Stds from 5,061' to tag up (~ 5,232' md. -Screw in top Drive. obtain parameters. -PUW 118k, SOW 98k,ROT wt 107k. -212 gpm / 250 psi, Tq 3k. -Pulled 40k over. Packer sheared. Stand 1 std back to 5,155' md. TIEB1 Blow down Top Drive. -POH from 5,155' to 229' md. TIEB1 LD: Pump out sub, accelorator, XO. Printed: 5/15/2008 9:20:19 AM CJ gp Page 9 of 10 Operations Summary Report Legal Well Name: MPS-11 Common Well Name: MPS-11 Spud Date: Event Name: WORKOVER Start: 4/18/2008 End: 4/30/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 4/30/2008 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours Task Code I NPT ' Phase Description of Operations 4/27/2008 20:00 - 20:30 0.50 CLEAN P TIE61 -Rack back D.C's. -LD: Oil jar, Bumper sub, Extension & Overshot. -PU "GBR" handling Tools. 20:30 - 22:30 2.00 CLEAN P TIEB1 RU Csg tongs, Slips & Crummies. -LD: +/- 210' of 2 3/8" Tbg & 2-Packers (cut Jt= 15.36'). -5 bbl brine losses while POH w/ Pkrs. 22:30 - 23:30 1.00 CLEAN P TIEB1 LD: Csg equipment, Baker Tools & 2 pup jts. -Break out 2-X nipples & 2-XN nipples. 23:30 - 00:00 0.50 CLEAN P TIEB1 MU Baker BHA: Mill, Bit sub, 2-Junk baskets, -7" Csg Scraper & D.C's. Total Brine losses for day 10 bbls. 4/28/2008 00:00 - 02:00 2.00 CLEAN P TIE61 RIH w/ 4" D. P. from 201' to 5,505' md. 02:00 - 04:30 2.50 CLEAN P TIE61 Obtain Parametrs: PUW 125k, SOW 98k, ROT wt 110k, -250 gpm / 580 gpm, Tq 3k ~ 70 rpm. -Ta EZ Drill lu C~ 5 583' md. -Drill EZ Drill plu w/ 10-18k WOB. - ush plug to bottom C~ 5,833' md. - q 2-6k ~ 100 rpm, 310 gpm / 930 psi. 04:30 - 05:30 1.00 CLEAN P TIEB1 Circulate the hole clean. 310 gpm / 960 psi. -Sand and oil /tar in returns. 05:30 - 06:30 1.00 CLEAN P TIE61 Monitor well for 10 minutes -Static. -Pump dry job. Blow down Top Drive -POH with Milling BHA to 5,033' md. -Rack back 20 Stds of 4" D. P. in derrick for rig move. 06:30 - 09:00 2.50 CLEAN P TIE61 Continue to POH, LD 4" D. P. f/ 5,033' and to BHA ~ 210' md. 09:00 - 09:30 0.50 CLEAN P TIE61 Rack back 2 Stds of 4 3/4" D.C's. for Rig move. -LD Mill, Scraper & XO's. Clean out Boot baskets. -Sand & metal slivers in boot baskets. -LD Boot baskets. 09:30 - 10:00 0.50 CLEAN P TIEB1 Clear Rig floor of vendor Tools. 10:00 - 10:30 0.50 CLEAN P TIEB1 Pull Wear bushing. 10:30 - 12:30 2.00 BUNCO RUNCMP RU to Run 3 1/2" L-80, 9.3 Ib/ft, TCII Tb with Torque turn. -Utilize "Jet Lube Seal Guard" thread compound. -Optimum torque 2300 ft/Ibs. 12:30 - 21:00 8.50 BUNCO RUNCMP PJSM on PU & running TCII Tbg. -Run 3 1/2" TCII Tbg per running order. -Run Tbg to 5,620' and per program. 21:00 - 21:30 0.50 BUNCO RUNCMP Clear Rig floor, clean Csg equipment. 21:30 - 00:00 2.50 BUNCO RUNCMP PJSM, w/ SLB - E-liners. RU E-line. -Run E-line in hole for correlation Tie in logs. 4/29/2008 00:00 - 01:00 1.00 BUNCO RUNCMP Continue to run tie-in correlation Log. 01:00 - 01:30 0.50 BUNCO RUNCMP RD SLB E-line equipment. 01:30 - 02:00 0.50 BUNCO RUNCMP RU compensator and power tongs. 02:00 - 03:00 1.00 BUNCO RUNCMP LD 2 jts. Space out according to SLB Logs: -Added 3.8' pup jt. -MU Tbg hanger. Land Tbg RILDS. 03:00 - 05:30 2.50 BUNCO RUNCMP RU & reverse circulate: -Pump 100 bbls of 8.7 ppg NaCI brine. -210 bbls of 8.7 ppg NaCI brine w/ corrosion inhibitor. -Pump rate 126 gpm / 320 psi. 05:30 - 06:00 0.50 BUNCO RUNCMP RU to Drop Ball & Rod and set Packers. Printed: 5/15/2008 9:20:19 AM • • g p Page 10 of 10 Operations Summary Report Legal Well Name: MPS-11 Common Well Name: MPS-11 Spud Date: Event Name: WORKOVER Start: 4/18/2008 End: 4/30/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 4/30/2008 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours I Task i Code I NPT I Phase Description of Operations 4/29/2008 106:00 - 08:30 I 2.50 08:30 - 09:00 0.50 09:00 - 09:30 0.50 09:30 - 11:00 1.50 11:00 - 12:00 1.00 12:00 - 12:30 0.50 12:30 - 15:30 3.00 15:30 - 16:30 1.00 16:30 - 19:00 2.50 19:00 - 21:00 2.00 21:00 - 22:30 1.50 22:30 - 00:00 I 1.50 RUNCMP Drop Ball & Rod. -Set Packers & test Tb to 4 000 si / 30 minutes-OK. -Bleed off Tb to 1000 si. Test IA to 1500 si / 30 minu -Bleed off Tbg, Shear DCR-1 shear valve C~ 1800 psi. -Establish circulation rate down Tbg up IA. -42 gpm / 500 psi. RUNCMP RD test equipment. Suck out stack. RUNCMP FMC set TWC & test from to to 1000 si / 10 minute. RUNCMP ND Flow line, Riser, Choke line & BOP's. RUNCMP Remove old Tree from cellar. RUNCMP Bring in Adaptor flange and new Tree into cellar. RUNCMP NU adaptor flange and Tree per FMC. -Test Packoff to 5000 psi / 15 minutes -OK. -Test Tree to 5000 psi / 15 minutes - OK. RUNCMP MU Lubricator and test to 500 psi - OK. -Pull TWC. RUNCMP RU circulating equipment. RU & test Hot Oil to 3000 psi. -Pump 85 bbls of diesel ~ 84 gpm / 500 psi. -Well Head pressure 150 psi during pumping. RUNCMP Let diesel in well U-tube. RUNCMP RU & test Lubricator to 500 psi - OK. -Set BPV, had to pump open SSV to set BPV. -Test BPV to 1000 psi / 5 minutes - OK. RUNCMP RD all lines, T's, Valves. -Change out pump-in flanges to blanks. -Install gauges. Secure well. -Pressures at release time: T-0 psi, IA-0 psi, OA-0 psi. Release rig C~3 midnight 00:00 hrs. Printed: 5/15/2008 9:20:19 AM Digital Well File ~ Page 1 of 1 Well: MPS-11 Well History Well Date Summary MPS-11 5/9/2008 T/I/0=50/40/0 (MIT IA to 2000 psi.) Pumped 1.4 bbls diesel down IA to bring pressure up to 2000 psi. First test lost 60 psi. in 1st 15 minutes, lost 40 psi. in 2nd 15 minutes.Started 2nd test. Continued on next day wsr. MPS-11 5/9/2008 ***ARRIV ON LOC WELL S/I *** (Post RWO) WELL SUPPORT PULLED BPV PULLED BALL AND ROD FROM 5600' SLM PULLED 1.5" RK-DCR FROM 5176' MD, SET 1.5" RK-DGLV PULLED 1.5" RK-DGLV FROM 5584' MD, SET 1.5" RK-SPMG (05-09-08, 19:00) PULLED 3.5" RHC-M FROM 5613' MD. LRS PERFORMED MIT-IA TO 2000#, PASSED ***JOB COMPLETE, RDMO*** MPS-11 5/10/2008 (MIT IA to 2000 psi.) ** Passed** Continued from previous day wsr. Bumped pressure up to 2000 psi. for 2nd test. Lost 20 psi. in 1st 15 min. Lost 0 psi. in 2nd 15 min. Bleed pressure down to 0 psi. FWHP= 50/0/0 MPS-11 5/11/2008 T/I/0=0/0/0 (Freeze Protect) Pumped 5 bbls Neat Methanol and 23 bbls 60/40 methanol down tubing from divert shelter. FWHP= 0/0/0 MPS-11 5/13/2008 *** WELL S/I ON ARRIVAL *** (Profile Modification) SET 2.81 PXN PLUG BODY ~ 5613' MD, RUN CHECK SET GOOD SET RUNNING "P" PRONG (DIAGRAM IN WELL FILE 95" OAL, 1.75" FN) ***CONT ON WSR 5-14-08*** MPS-11 5/14/2008 ***CONT FROM WSR 5-13-08*** WFRV's SET PRONG 95" OAL W/ 1 3/4" FN C~3 5613' MD. PULL RK-DGLV FROM STA #2 C~3 5511' MD, SET RK-P-i5 (1000 BBLID). PULL RK-DGLV FROM STA #4 ~ 5375' MD, SET RK-P-15 (500 BBL/D). RUN 2.30 LIB TO 5596' SLM, RECOVERED IMPRESSION OF PRONG. *** WELL LEFT S/I *** MPS-11 5/19/2008 T/I/0=1320/290/0. AOGCC MIT IA to 2000 psi PASSED (witnessed by C. Scheve). Lost 70 psi in first 15 minutes & 10 psi in second 15 minutes. Bleed IA pressure down to 290 psi. FWHP=13201290/0. Print Date: 6/4/2008 Page 1 of 1 http://digitalwellfile.bpweb.bp.com/Wllnfo/Reports/ReportViewer.aspx 6/4/2008 Tree: 3-1/8" 5M Wellhead: 11" 5M FMC Gen 6 20" x 34" insulated, 215 #/ft A-53 112' 9 5i8" 47# casing cemented to surf. 138: KOP @ 410` Max. hole angle = 56 deg @ 3758` Hole angle thru perfs = 31 DEG. 7" 26#, L-80, BTRC Casing (drift id = 6.151, cap.= .0383 bpf) 3.5", 9.2 ppf, L-80 TC-II. Tbg. (cap. = 0.0087 bpf, drift = 2.861 Perforation Summary Size Spf Interval (TVC 3 3/8" 6 NB sands 5385' - 5405' 4011 ` - 40~ 3 3/8" 4 OA sands 5500' - 5502' Squeezec 4 5535' - 5550' 4134' - 41 ~ Add 6 5550' - 5560' 4146' - 41 3-3/8" 6 5530' - 5540' 4129' - 41 i 5600` - 5615' 4189' - 42( 5843` 7" Halliburton Float Collar PBTD 5928' 7" Halliburton float shoe DATE REV. BY COMMENTS 08/31/02 Lee Hulme Completion Rig 4ES 05/13/06 MDO RWO to Add Perfs Doyon-14 04/03/08 BJM Proposed RWO to repair surface csg 04!29%08 J. Haberthur Casing repaired -completed 06r'05i08 T. Holbrook Drawing update -EZSV fish added Orig. KB Elev. = 66.60 Orig. GL Elev. = 39.00 HES X-Nipple (2.813")2399' 1.5" GLM 5,176' iES X-Nipple (2.813") 5;269' 3.5" Baker Premier packer 5,290' 1.5" GLM's 5317' >< 1.5" GLM 375` i.5" Baker Premier packer 5436" 1.5" GLM's c 1.5" GLM 5463' 5511` .5" Baker Premier packer 5,567' x 1.5" GLM's 5584` ES XN-Nipple 2.813" Pkg. o-Go 2.75" id) X613' NELG 5619' EZSV PLUG PUSHED TO BTM 5833` MILNE POINT UNIT WELL No.: S-11 i API : 50-029-23092-00 BP EXPLORATION (AK) '~VI P U S-11 i MPS-11 Workover modification to procedure Page 1 of 2 • • Maunder, Thomas E (DOA) From: McLellan, Bryan J [Bryan.McLellan@bp.com] Sent: Thursday, April 24, 2008 10:07 AM To: Maunder, Thomas E (DOA) Cc: Reem, David C ~©1 ` ` Subject: MPS-11 Workover modification to procedure d- Tom As we discussed yesterday afternoon on the phone, our plans on the Workover for MPS-11 (Sundry # 308-124) have been adjusted based on what we are learning about the well's condition. Work completed to date: 1. Pulled 2-3/8" dual completion tubing down to the production packer at 5350' md. 2. Ran RTTS inside 7" casing. Pressure tested casing from 64' RKB down to packer at 5350' and to 2000 psi for 30 minutes. Test passed. 3. Ran USIT log in corrosion and cement evaluation mode. Ind+cation of some corrosion on the first two joints of 7" surface casing below the wellhead. The 7" casing appeared to have little if any corrosion below the 2nd joint of casing. 4. Shot string shot across first 7" coupling below the wellhead, ~74' RKB. 5. ND BOP stack, NU 20" riser to take returns down flowline. 6. Back off first joint of 7" casing. Entire joint had external corrosion. Found holes at ~25' down. Found split in casing just above connection, ~37' down. The casing that had the split had been pressure tested to 2000 psi in step #2 above, so the split must have been caused by string shot or back-off tool anchors. The next 7" connection (where good casing begins) is outside the 20" conductor shoe. If we wash down past this connection and back off the 7" casing, running gravel could prevent us from tying back into the casing. To minimize this risk, the following change in plans has been made: Plan forward: 1. Burn over 7" surface casing to 137' RKB, which is past the next 7" connection and ~25' outside of conductor shoe. 2. Run 9-5/8" casing to 137' RKB swallowing the 7" casing stub. Land the 9-5/8" casing on a new starting head. 3. Now that the next 7" casing connection is protected from hole collapse by the 9-5/8" casing, we will back off the next 7" connection and pull another joint of 7" casing out of the hole. 4. Run new 7" casing and land in the wellhead. Pressure test 7" casing to 1500 psi minimum. 5. NU BOP stack and pressure test BOP bottom flange to 3500 psi. 6. Pump cement down the 7" x 9-5/8" casing annulus, taking returns up the 9-5/8" x 20" annulus. Stop pumping when good cement returns are seen at surface. If no cement returns can be achieved, a top job may be attempted. 7. After cement sets up, we will be back to step #12 of the original plan on the Sundry application (pull 7" RBP and retrieve production packers, etc... ). We are currently in the process of burning over the 7" casing. Feel free to contact me if you would like to discuss this plan in any more detail. ~~~~ e 7/16/2008 MPS-11 Workover modification to procedure Page 2 of 2 • Thank you, Bryan McLellan 907-564-5516 office 907-440-7964 cell 7/16/2008 05/13/08 Schlumberg~r Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth wau r„ti ~ MPS-11 12017492 CEMENT & CORROSION LOG 7h7-( /'~ ~~ 04/22/08 ~.vwr 1 vv 1 1-21/K-25 12061694 , PRODUCTION LOG ~~ ,bJ ~ ,_~(~~ 04/18/08 1 1 GNI-04 12057606 STEP RATE INJECTIVI'r r 1 tS t V~ / ~jCf 04/23/08 1 1 L-220 11975763 USIT 04/22/08 1 1 MPS-31 11962598 USIT G 05/03/08 1 1 X-17 12034894 USIT - / • /(p ~ 05/03/08 1 1 04-47 11978458 MEM LDL ~`jL(--(s 3 05/01/08 1 1 Y-07A 11966254 TEMP & PRESS LOG app- - ~ 05/02!08 1 1 L5-36 11975768 PRODUCTION PROFILE W/FSI - , 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 fSCMT) _'M~ /(~~ ~~~~~-( 02/03/08 1 L2-16 11975760 RST ~ `~~'~---~~ (~ ~~'a~ 03/31/08 1 1 L2-33 11998999 RST r _ 04/01/08 1 1 L1-14 11999000 RST ~ r 04/02/08 1 1 D-266 40016518 OH MWD/LWD EDIT - rv° 02/21/08 1 1 Pt FACE ACKNfIINI Cr1!]C QC !`Cro7 ttv crr_~ usv_ nr.~n n~rn n.u.~.... GJ~P'C19~ yJ V ~ '/~ ,SF L~Ut3 ~,b~= ~ ~ 3 fps" ~~ NO. 4702 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 1(10 Anchorage, AK 99501 BP Exploration (Alaska) Inc. _ v...-..-M ....~ vv, ~^v~ ~ ~ v. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ,,.. ,,,. ~~; ~ I is Alaska Data & Consulting Services 2525 Gambell Street, Suite 40 , Anchorage, AK 99503-2838 ATTN: Beth ~~_ Received by: r ~ `~ I' MEMORANDUM `~'' State of Alaska ``°~"` Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 2l, 2008 To: Jim Regg ~~~~ 5 ~21`~~ P.I. Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 5-11 FROM: Chuck Scheve MILNE PT UNIT SB S-] 1 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv '^ _- Comm Well Name: MILNE PT UNIT SB S-11 API Well Number: 50-029-23092-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS080519163522 Permit Number: zoz-l 13-0 ~~ Inspection Date: 5/19/2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. e In T ----- -- - Well ! _1-__ _•_ ~ W I T~ 3940 IA 290 l 2010 1940 ~ 1930 s-i 1 ITYP J. P.T TypeTest-,--~ -- ------ ~--- - _ _._ ------ __--- --- - -- zozii3o j sPT ~ Test psi 1500 ,-'OA o o 0 0 - - -- --- ~I Interval wRKOVR p~F P Tubing 13zo 13zo 13zo 13zo ' --- --- --- ------------ - ----------------- --- -- _ _.. - ----- _ ~-- -- -1-- Notes: ~ ~ MAY ~ Zoa~ Wednesday, May 21, 2008 Page I of 1 MPS-11 Sundry # 308-124 Page 1 of 1 • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, April 18, 2008 3:51 PM To: 'McLellan, Bryan J' Cc: Reem, David C Subject: RE: MPS-11 (202-113) Sundry # 308-124 Bryan, I don't see this as an issue. You are attempting to remove the casing regardless. Better luck this time. I will put a copy of this message in the #ile. Tom Maunder, PE AOGCC From: McLellan, Bryan J [mailto:Bryan.McLellan@bp.comj Sent: Friday, April 18, 2008 3:49 PM To: Maunder, Thomas E (DOA} Cc: Reem, David C ~~~~~~~ pPR ~, ~ ~~~~ Subject: MPS-li Sundry # 308-124 Tom, We have changed our plans slightly on the planned MPS-11 RWO, Sundry # 308-124. The changes are to steps #7 & 8 of our proposed procedure on the approved Sundry. Instead of cutting the 7" casing and then running an external casing patch, we might try to back off the 7" connection below the leak and screw back in with new 7" casing. The remainder of the program will be the same. Please let me know if you require additional papenivork to approve this change in procedure. Thank you, Bryan 4/18/2008 MPS-11 Sundry #308-124 Maunder, Thomas E (DADA) • From: Maunder, Thomas E (DOA) Sent: Monday, April 14, 2008 2:03 PM To: 'McLellan, Bryan J' Cc: Hubble, Terrie L; Stewman, Sondra D Subject: RE: MPS-11 Sundry #308-124 Bryan, et al, You are correct there was an incorrect reference in the letter. The correct reference should be Schrader Bluff Oil Pool. Thanks for notifying us. Making the hand correction is acceptable. We will do the same over here. Tom Maunder, PE AOGCC From: McLellan, Bryan J [mailto:Bryan.McLellan@bp,com] Sent: Monday, April 14, 2008 1:35 PM To: Maunder, Thomas E (DOA) Cc: Hubble, Terrie L; Stewman, Sondra D Subject: MPS-11 Sundry #308-124 ~~,~t~~C~ APR 1 6 2008 Page 1 of 1 Tam, As we discussed on the phone, there is a typo on the MPS-11 Sundry Approval letter. In the "Re:" line, it refers to the welt as "Milne Point Unit, Kuparuk River Oil Pool, MPS-11'r". This well is completed in the Schrader Bluff Oil Pool. Please let me know if the paperwork should be re-issued, or if 1 should just change my copy by hand. Thank you, Bryan McLellan 4/14/2008 • • ~~ ; 1 ~ p ~ ~ ~ f ~ E { ' ~ SARAH ... _ .. . ~ ../ ~.~ L."s ~ `~~3 1 ~ eJ r ~. ~ : ~ 1. °~ ~ 1'~.1~~4....~ PAL/N, GOVERNOR ~ ~~ ~~ ~ ~ ~f 333 W. 7th AVENUE, SUITE 100 C01~5ERQA7`IO1~T COl-'II~iI5SI0IQ ANCHORAGE, ALASKA 99501-3539 ~ PHONE (907) 279 1433 FAX (907) 276-7542 David Reem Engineering Team Leader BP Exploration Alaska, Inc. PO Box 196612 b~f I ~~ Anchorage, AK 99519-6612 a, Re: Milne Point Unit, Kuparuk River Oil Pool, MPS-1li Sundry Number: 308-124 G~~~ App ~. ~~ 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 $eld 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. (,~ /9~ STATE OF ALASKA ,~ ALA OIL AND GAS CONSERVATION COMM~ION APPLICATION FOR SUNDRY APPROVAL ~S 20 AAC 25.280 ~ ~-~ a 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ® Alter Casing ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 202-113 3. Address: ®Service ^ Stratigraphic 6. API Number: ' P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23092-00-00 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-11 i . Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 380110 66.60 • 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): 5939 4486 5580 4172 N/A Approx. 5843' Casin Len th Siz MD TVD Burst Colla se Structural on r 112' 20" 112' 112' 1490 470 Surface 5900' 7" 5928' 4476' 7240 5410 Intermediate Pr du i n Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5385' - 5560' 4011' - 4155' Long String 2-3/8", 4.6# Short Strin 2-318" 4.7# L-80 5476' Packers and SSSV Type: 7" x 2-3/8" Baker'GT' Ret. Dual Packer Packers and SSSV MD (ft): 5350' 7" x 2-38" BaKer'FH' Ret. Packer 5451' 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 21, 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 vid Ree Title Engineering Team Leader Prepared By Name/Number: Signature Phone 564-5743 Date Lf a ~!i Sondra Stewman, 564-4750 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity `~.~OP Test ,Mechanical Integrity Test ^ Location Clearance p c/~'~ ~ Other: ? ~~~ if CD ~~ 1ZCl S . .~~~Q ~ ~~~ ~y~C~~p~~~' APR 0 7 2008 ~~~~~~'~~~ .~. ~~r6 F n/ [~~{~ L ~~V ~ Subsequent Form Required: ~ ~ Alaska alb & Gas C4nS. CommISSIOCi Anchorage APPROVED BY O A roved B ~ COMMISSIONER THE COMMISSION Date Form 10-403 Re ed 06!2006 S~mit Ir~Duplicate ~~I~i~IAL ~~~~~~- ~~~ • by Milne Point MPS-11 Rig Workover (Surface Casing Leak Repair) Scope of Work: Expense RWO -Pull Dual 2-3/8" 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 single completion. MASP: 1362 psi Well Type: Schrader Bluff Water Injector ~ Estimated Start Date: April 21st, 2008 Production Engineer: Mark Sauve Intervention Engineer: Bryan McLellan Pre-Ria Work Request: S 1 On the long string, pull XX plug from 2247' md, run SBHPS and then set XXN plug at 5462' md. On short string, pull XX plug from 2186' and and set XXN plug at 5360' md. MIT-T both strin s to 1000 si. Drift both strin s for 'et cutters if XXN lu s were not sufficient as drift. E 2 Do not cut tubing if the MIT-T failed on either string. Contact Bryan McLellan at 564- 5516 if either test fails. Power jet cut 2-3/8" L-80 tubing in short string at 5343' md, in the middle of the 6.2' long pup joint above the packer. Jet cut 2-3/8" L-80 tubing in long string at 5230' md, in the middle of the 3`d full joint above the X-nipple C«~ 5306' md. Reference tubing tallys dated 05/13/06 (note that tbg tallys on the web are from a 2002 completion, not the existin 2006 com letion . F 3 Circulate well with seawater or 2% KCI and diesel freeze rotect thru the cuts. 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's in the tubin han er. O 6 Remove the wellhouse & flow line. Level the pad as needed for the rig. Install liner in cellar to contain fluids comin from surface casin x conductor annulus. Proposed Procedure 1. MIRU rig Doyon 14. Circulate out freeze protection fluid and circulate well to clean kill weight fluid through the tubing cuts. ND tree. NU and test BOPE to 3500 psi. BOP stack to include dual 2-3/8" pipe rams. 2. Pull and LD 2-3/8" tubing strings 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. 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 112'. 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. The 2-3/8" dual rams will be replaced with variable bore pipe rams which will be tested to 3500 psi. 12. Pull 7" RBP. 13. Pull remaining production tubing and retrievable production packers from 5350' and 5450' md. 14. Mill up plug at 5580', exposing perfs from-4666~.r8~i~' md. ~toQO - ,~(~ ~ 5 ~ ~~ ~ `l C 15. Run 3-'h" L-80 completion with packers set at 5300' md, 5440' and and 5570' md. Note that if~- 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: C1W 2 1/16" 5M Dual string U S 11 i Orig. K 66.60 Wellhead:ll" x 2 3/8" 5M FMC dual string Hanger thread 2 3/8" EUE top and IBT bottom Orig. GL v. = 39.00 2" CIW-H BPV profile 20" x 34" insulated, 215 #/ft A-53 112` Short String 2,186` 2-3/8" HES X-Nipple (1.875" pkg. bore) KOP @ 410` Max. hole angle = 56 deg @ 3758` Hole angle thru perfs = 31 DEG. 7" 26#, L-80, BTRC Casing (drift id = 6.151, cap.= .0383 bpf) 2-3/8", 4.7 #/ft L-80, IBT tubing (drift id = 1.901, cap.=.00387 bpf) 5,306' 2-3/8" HES X-Nipple (1.875" pkg. bore) 5,360' 2-3/8" HES XN-Nipple (1.875" pkg. bore) No-Go 1.791" 5,372' Tubing tail / WLEG Perforation Summary Size Spf Interval (TVD) 3 3/8" 6 NB sands 5385' - 5405' 4011 ` - 4026' 3 3/8" 4 OA sands 5500` - 5502' Squeezed 4 5535` - 5550' 4134' - 4147` Add 6 5550' - 5560' 4146' - 4155' 3-3/8" 6 5530' - 5540' 4129' - 4137' I A „. 5843` 7" Halliburton Float Collar PBTD 5928` 7" Halliburton float shoe DATE REV. BY COMMENTS 06/22/02 MDO Drilled by Cased Doyon 141 08/31/02 Lee Hulme Completion Rig 4ES 05/13/06 MDO RWO to Add Perfs Doyon-14 2-318" HES X-Nipple (1.875" pkg. bore) 2,247` 2-3/8" HES X-Nipple (1.875" pkg. bore) 5,307` 7" x 2-3/8" Baker "GT" Ret. dual pkr. 5,350' 1.945"ID. 7" x 2-3/8" Baker "FH" Ret. pkr. 5,450` 2.41" ID. 2-3/8" HES XN-Nipple (1.875" pkg. bore) 5,462' No-Go 1.791" 2-3/8" Baker `E' Hydro Trip Sub 5,470' (2.00" pkg. bore) Tubing tail 5,475` ELMD EZ Plug @ 5580' Isolated perfs 5,600`-5,615' / 5,600`-5,615' MILNE POINT UNIT WELL No.: S-11 i API : 50-029-23092-00 BP EXPLORATION (AK) ,Tree: 31/8" 5M Wellhead: 11" 5M FMC Gen 6 20" x 34" insulated, 215 #/ft A-53 112' KOP @ 410` Max. hole angle = 56 deg @ 3758` Hole angle thru perfs = 31 DEG. 7" 26#, L-80, BTRC Casing (drift id = 6.151, cap.= .0383 bpf) 3.5", 9.2 ppf, L-80 TC-II. Tbg. (cap. = 0.0087 bpf, drift = 2.867 Perforation Summary Size Spf Interval (TVD 3 3/8" 6 NB sands 5385` - 5405' 4011 ` - 402 3 3/8" 4 OA sands 5500' - 5502' Squeezec 4 5535' - 5550' 4134` - 414 Add 6 5550' - 5560' 4146` - 41 3-3/8" 6 5530' - 5540' 4129' - 41 5600` - 5615' 4189` - 42C 5843' 7" Halliburton Float Collar PBTD 5928' 7" Halliburton float shoe DATE REV. BY COMMENTS 06/22/02 MDO Drilled by Cased Doyon 141 08/31/02 Lee Hulme Completion Rig 4ES 05/13/06 MDO RWO to Add Perfs Doyon-14 04/03/08 BJM Proposed RWO to repair surface csg Orig. KB~. = 66.60 Orig. GL v. = 39.00 HES X-Nipple (2.813") -2200' 1.5" GLM 5,200' IES X-Nipple (2.813") 5,280` 1.5" Baker Premier packer 5,300` 1.5" GLM's 0 .5" Baker Premier packer 5,440` 1.5" GLM's 0 5" Baker Premier packer 5,570` x 1.5" GLM's .S XN-Nipple 2.813" Pkg. ~-Go 2.75" id) JELG MILNE POINT UNIT WELL No.: S-71 i API : 50-029-23092-00 BP EXPLORATION (AK) MPS-14 (PTD #2031040) Rec~sified as Operable Page 1 of 1 • Maunder, Thomas E (DOA) From: NSU, ADW WeN integrity Engineer [NSUADWWeIIMtegrityEngineer@BP.com] Sent: Wednesday, Apri109, 2008 3:00 PM To: Maunder, Thomas E {DOA); MPU, Weil Operations Supervisor, Sauve, Mark A; MPU, WeNs Ops Coord; MPU, Wells Ops Coord2; MPU, Fietd Lead Tech Cc: Regg, James 8 (DOA); Reem, David C Subject: RE: MPS-~ ~- Attachments: RE: MPS-11 (PTD #2021130) Request to place on injection for diagnostic work Hi Tom, The following summary is from the work conducted on MPS-11 (PTD #2021130) on July 21-22, 2007. The information is reported for each string separately. »»SHORT STRING««< Pulled TTP, placed well on injection down short string, freeze protected short string, set TTP at 2186' MD, MIT-T on short string passed to 1000 psi. »»LONG STRING«« Pulled TTP, ran in hole with pressure gauges, placed well on injection down short string from 09:30 am to 11:30 am. Freeze protected long string. Set TTP at 2247' MD, MIT-T on long string passed to 1000 psi. This interference test showed no communication between the short and long strings. The pressure test data was not fully documented as to be able to submit the data on a MIT form. Please let me know if you need any additional information. Thank you, Anna ~u6e, ~ E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 ~~I~~NE~ A P R Q ~ ~~ From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, April 09, 2008 10:57 AM To: NSU, ADW Well Integrity Engineer; MPU, Well Operations Supervisor; Sauve, Mark A; MPU, Wells Ops Coord; MPU, Wells Ops Coord2; MPU, Field Lead Tech Cc: Regg, James B (DOA); Reem, David C Subject: MPS-11 (202-113} Andrea or Anna, I am reviewing a workover proposal for this injection well. Looking at the file, the last message from July 20, 2007 authorized returning the well to operation for diagnostics. Results of the diagnostics were to be provided to the Commission. If the diagnostics are available, please submit them. Call or message with any questions. Tom Maunder, PE AOGCC 4/9/2008 MPS-11 (PTD #2021130) Reon~st to place on injection for diagnostic work Page 1 of2 Maunder, Thomas E (DOA) _..._~._~_.~.,_·.~~____.__.__..u~.____~m ...~_____".,..._..,,_._.__....._. "~._.._~~._.,_.,_.".." ,.,,_.....,...." ..~".,,__"..,__ .._.__,..."..__._........,.'» ...._...._".__..._...._.~,....__,.......,,__._ m.. ,__..~,_ ._..' ..~". _..~," _" _"·"'_'_'·_"....__n' ."......_.___ From: Regg, James 8 (DOA) Sent: Friday, July 20,20073:35 PM To: NSU, ADW Well Integrity Engineer; Maunder, Thomas E (DOA) Cc: MPU, Well Operations Supervisor; Handy, Rob E; Iveson, Mel R (Orbis) Subject: RE: MPS-11 (PTD #2021130) Request to place on injection for diagnostic work The Commission concurs with your plans to place MPU S-11 on injection as described to perform diagnostics. Please provide results when you have evaluated the diagnostics. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWellIntegrityEngineer@BP.com] Sent: Friday, July 20, 20073:17 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: MPU, Well Operations Supervisor; Handy, Rob E; Iveson, Mel R (Orbis); NSU, ADW Well Integrity Engineer Subject: MPS-11 (PrD #2021130) Request to place on injection for diagnostic work Jim and/or Tom, Well MPS-11 (PTD #2021130) failed an MITIA for 2-year UIC compliance testing on 04/08/07. Diagnostics on 06/15/07 to evaluate a potential packer leak noted a leak in the cellar when a sustained pump pressure of 2450 psi was achieved on the IA. The leak stopped as soon as the pumping was shut down and it took only a couple of minutes for the pressure to bleed down after the leak stopped. There are currently tubing plugs in both strings of the completion. Our current plans are to diagnose whether communication exists between the short and long strings. Our plan forward is as follows: 1. S: Run pressure gauges down the long string 2. S: Pull tubing plug in short string and put on produced water injection for 2 hours. 3. WIE: Monitor long string pressure gauges for signs of communication 4. S: Re-run tubing plug in short string after 2 hours of injection The cellar has been lined and all diagnostic work will be shutdown if any signs of communication to surface exist. Is this a viable diagnostic plan? Is it acceptable to place this well on injection for 2 hours? Please call with any questions or concerns. Thank you, Sr;¡:¡NN!;,{) JUL 2 3 Z007 Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 7/23/2007 MPS-ll (P'ID #2021130) ~ to place on injection for diagnostic irk Pager: (907) 659-5100 x1154 Page 2 of2 7/23/2007 MPS-11 (PTD #2021130) Post-Failed MITlA Update . Tom and Jim, I have included the original message sent for well MPS-11 (PTD #2021130) on 04/08/07. During a recent (06/15/07) diagnostic test to evaluate a potential packer leak while pumping on the lA, a leak was noted in the cellar when a sustained pump pressure of 2450 psi was achieved. Immediately after the leak was noted the pump was shut down and the annulus bled to zero. The leak stopped as soon as the pumping was shut down and it only took a couple of minutes for the pressure to bleed down after the leak stopped. A XX Plug was pulled from 2247' in the long string prior to the diagnostic test to enable wireline leak detect tools to be able to traverse the wellbore. A TIP has now been set and pressure tested in the XN nipple at 5462' of the long completion string. Currently, the well is being "swung" to the short completion string to ensure that a competent plug is set at 5360' within that string. Such that, the well will remain shut-in and secured with tubing plugs in both completion strings. A current TIO plot has been included for reference. «MPS-11 TIO Plot.ZIP» Please call with any questions. Thank you, Paul Austin for Anna Dube Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 5'~ JUN 2 6 2007 .. ..... From: NSU, ADW Well Integrity Engineer Sent: Sunday, April 08, 2007 3:48 PM To: 'Thomas Maunder'; 'James Regg'; 'john_crisp@admin.state.ak.us' Cc: NSU, ADW Well Operations Supervisor; NSU, ADW Well Integrity Engineer; MPU, Well Operations Supervisor Subject: MPS-11 (PTD #2021130) Failed MTIlA Tom and Jim, Well MPS-11 (PTD #2021130) failed an MITIA on 04/06/07. The inner annulus was pressured to 1700 psi and the IA lost 1300 psi in the first five minutes of the test. There was no pressure response noted in either tubing strings. No fluid was found in the temporary cellar liner during the failure. After the test, the cellar liner was removed and no fluid was found in the cellar. The well has been shut-in and is scheduled for tubing plugs. The plan forward is as follows: 1. WIC: Shut-in well- DONE 2. SL: Set TIP in each completion string - In Progress A wellbore schematic and TIO plot have been included for reference. «MPS-11.ZIP» «MPS-11 TIO Plot.ZIP» Please call with any questions. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 TIO Content-Description: MPS-ll TlO Plot.ZIP Content-Type: application/x-zip-compressed 10f2 6/18/20073:03 PM MPS-11 (PTD #2021130) Post-Failed MITlA Update . . Content-Encoding: base64 Content-Description: MPS-Il.ZIP Content-Type: application/x-zip-compressed Content-Encoding: base64 Content-Description: MPS-11 TIO Plot.ZIP Content-Type: application/x-zip-compressed Content-Encoding: base64 20f2 6/18/20073:03 PM Tree: CIW 2 1/16" 5M Dual st Wellhead: 11" x 2 3/8" 5M FM al string Hanger thread 2 3/8" EUE top and IBT bottom 2" CIW-H BPV profile 20" x 34" insulated, 215 #/ft A-53 Œ!Ð Short String ~ 2-3/8" HES X-Nipple (1.875" pkg. bore) KOP @ 410' Max. hole angle = 56 deg @ 3758' Hole angle thru perfs = 31 DEG. 7" 26#, L-80, BTRC Casing (drift id = 6.151, cap.= .0383 bpf) 2-3/8",4.7 #/ft L-80, IBT tubing (drift id = 1.901, cap.=.00387 bpf) I 5,306' I 2-3/8" HES X-Nipple (1.875" pkg. bore) I 5,360' I 2-3/8" HES XN-Nipple (1.875" pkg. bore) No-Go 1.791" I 5,372' I Tubing tail / WLEG Peñoration Summary Size Spf Interval (TVD) NB sands 33/8" 6 5385' - 5405' 4011' - 4026' OA sands 33/8" 4 5500' - 5502' Squeezed 4 5535' - 5550' 4134' - 4147' Add 6 5550' - 5560' 4146' - 4155' 3-3/8 " 6 5530' - 5540' 4129' - 4137' ~ 7" Halliburton Float Collar PBTD ~ 7" Halliburton float shoe MPUS-11i DATE REV. BY COMMENTS 06/22/02 MDO Drilled by Cased Doyon 141 08/31/02 Lee Hulme Completion Rig 4ES 05/13/06 MDO RWO to Add Perfs Doyon-14 . Orig. KB Elev. = 66.60 Orig. GL Elev. = 39.00 Long String 2-3/8" HES X-Nipple (1.875" pkg. bore) I 2,247' I 2-3/8" HES X-Nipple (1.875" pkg. bore) I 5,307' I 7" x 2-3/8" Baker "GT" ReI. dual pkr. 1.945" ID. I 5,350' I 7" x 2-3/8" Baker "FH" ReI. pkr. 2.41" ID. I 5,450' I 2-3/8" HES XN-Nipple (1.875" pkg. bore) I 5,462' I No-Go 1.791" 2-3/8" Baker 'E' Hydro Trip Sub I 5,470' I (2.00" pkg. bore) Tubing tail I 5,475' I ELMD c:=J EZ Plug @ 5580' Isolated perfs 5,600'-5,615' / 5,600'-5,615' MILNE POINT UNIT WELL No.: S-11 i API: 50-029-23092-00 BP EXPLORATION (AK) . MEMORANDUM State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ~1 4(Z0{v 7 DATE: Monday, April 23, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S-ll MILNE PT UNIT SB Sol I ~.1--~U3 FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv $/2-- Comm NON-CONFIDENTIAL Well Name: MILNE PT UNIT SB S-II API Well Number: 50-029-23092-00-00 Inspector Name: John Crisp Insp Num: mitJCr070410092542 Permit Number: 202-113-0 Inspection Date: 4/6/2007 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well S-II Type Inj. w TVD 3985 IA 0 1700 80 1 P.T.D 202t 130 TypeTest SPT Test psi 1500 OA I Interval 4YRTST P/F F /' Tubing 1100 1100 1100 I Notes: Monobore injector. Failed PT. Equipment being mobilized for shut in & fTeeze protect. ;/' SCANNED þ,PR 3 0 2007 Monday, April 23, 2007 Page I of I MPS-11 (PTD #2021130) Failed MITlA . . Tom and Jim, Well MPS-11 (PTD #2021130) failed an MITIA on 04/06/07. The inner annulus was pressured to 1700 psi and the IA lost 1300 psi in the first five minutes of the test. There was no pressure response noted in either tubing strings. No fluid was found in the temporary cellar liner during the failure. After the test, the cellar liner was removed and no fluid was found in the cellar. The well has been shut-in and is scheduled for tubing plugs. The plan forward is as follows: 1. WIC: Shut-in well - DONE 2. SL: Set TTP in each completion string - In Progress A wellbore schematic and TIO plot have been included for reference. «MPS-11.zIP» «MPS-11 TIO Plot.ZIP» Please call with any questions. .~...~ ..........."..~ Thank you, Andrea Hughes öeANiMED APR 1 02007 Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 Content-Description: MPS-ll.ZIP Content-Type: application/x -zip-compressed Content-Encoding: base64 Content-Description: MPS-ll no Plot.ZIP MPS-ll TIO Plot.ZIP Content-Type: application/x-zip-compressed Content-Encoding: base64 1 of 1 4/9/2007 8:01AM Tree: CIW 21/16" 5M Dual str Wellhead:11"x23/8" 5M FMC string MPU 5-11 i Hanger thread 2 3/8" EUE top and IBT bottom 2" CIW-H BPV profile . Orig. KB Elev. = 66.60 Orig. GL Elev. = 39.00 20" x 34" insulated, 215 #/ft A-53 ~ Short String ~ 2-3/8" HES X-Nipple (1.875" pkg. bore) KOP @ 410' Max. hole angle = 56 deg @ 3758' Hole angle thru perfs = 31 DEG. T' 26#, L-80, BTRC Casing (drift id = 6.151, cap.= .0383 bpf) 2-3/8",4.7 #/ft L-80, IBT tubing (drift id = 1.901, cap.=.00387 bpf) I 5,306'1 2-3/8" HES X-Nipple (1.875" pkg. bore) I 5,360' I 2-3/8" HES XN-Nipple (1.875" pkg. bore) No-Go 1.791" I 5,372' I Tubing tail I WLEG Perforation Summary Size Spf Interval (TVD) NB sands 33/8" 6 5385' - 5405' 4011' - 4026' OA sands 33/8" 4 5500' - 5502' Squeezed 4 5535' - 5550' 4134' - 4147' Add 6 5550' - 5560' 4146' - 4155' 3-3/8" 6 5530' - 5540' 4129' - 4137' ~ 7" Halliburton Float Collar PBTD ~ T' Halliburton float shoe DATE REV. BY COMMENTS 06/22/02 MDO Drilled by Cased Doyon 141 08/31/02 Lee Hulme Completion Rig 4ES 05/13/06 MDO RWO to Add Perfs Doyon-14 Long String 2-3/8" HES X-Nipple (1.875" pkg. bore) I 2,247' I 2-318" HES X-Nipple (1.875" pkg. bore) I 5,307' I 7" x 2-3/8" Baker "GT" Ret. dual pkr. 1.945" ID. I 5,350'1 7" x 2-3/8" Baker "FH" Ret. pkr. 2.41" ID. 1 5,450' I 2-318" HES XN-Nipple (1.875" pkg. bore) I 5,462' I No-Go 1.791" 2-3/8" Baker 'E' Hydro Trip Sub I 5,470' I (2.00" pkg. bore) Tubing tail I 5,475'1 ELMO c=J EZ Plug @ 5580' Isolated perfs 5,600'-5,615' 15,600'-5,615' MILNE POINT UNIT WELL No.: S-11i API : 50-029-23092-00 BP EXPLORATION (AK) Page 1 of 1 Maunder, Thomas E (DOA) From: Lou Grimaldi [lou~rimaldi@admin.state.ak.us] Sent: Monday, April 02, 2007 1:11 AM To: MPU, Wells Ops Coord Gc: jim_regg@admin.state.ak.us; Tom Maunder Subject: Re: MPS-11 MIT ~~~_~ ~~ Hi Rob, Sorry for the late reply, been running some crazy hours lately. I support this plan as we saw the alternative. I will CC: this a-mail to Jim Regg and Tom Maunder in my office who will contact you if there are any stipulations other than expedite the process at all opportunity's. Good luck, Lou Grimaldi' aPR 2D0£~ MPU, Wells Ops Coord wrote: Good Morning Lou, In light of our MIT failure yesterday an our monobore injection well MPS-31 1 would like to request a time extension for the MIT on MPS-11 as this is a monobore as well. We would like some time to install liners in the cellar to make sure if there is a failure on surface we will be able to provide containment to prevent fluids from spilling on the ground. This job will be top priority so I don't anticipate it would take too long to be ready to do an MIT on MPS-11. Thank you, Rob Handy MPU Welt Operations Coordinator (907) 670-3387 (907) 670-3390 Fax MPUWeIIsOpsCoord.@bp.com ~~~ ~~~~ Q ~-~ 4/9/2008 !4¿ G/)Lj)C7ß REGt::IVt:U _ STATE OF ALASKA I ALA_ Oil AND GAS CONSERVATION COM SION jUL 1 4 2006 REPORT OF SUNDRY WELL OPERA TI~AWiOiI & Gas Cons. Commission . 1. Operations Performed: o Abandon o Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing 181 Pull Tubing o Perforate New Pool o Waiver 181 Other o Change Approved Program o Operation Shutdown 181 Perforate o Time Extension Isolate 08 with CI8P 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. o Development D Exploratory 202-113 3. Address: o Stratigraphic 181 Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23092-00.00 7. KB Elevation (ft): 66.60 9. Well Name and Number: MPS-11i 8. Property Designation: 10. Field 1 Pool(s): ADL 380110 Milne Point Unit 1 Schrader Bluff 11. Present well condition summary Total depth: measured 5939 feet true vertical 4486 feet Plugs (measured) N/A Effective depth: measured 5580 feet Junk (measured) Approx. 5843' true vertical 4172 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20" 112' 112' 1490 470 Surface 5900' 7" 5928' 4476' 7240 5410 Intermediate Production Liner Perforation Depth MD (ft): 5385' - 5560' Perforation Depth TVD (ft): 4011'-4155' Long String 2-3/8", 4.6# L-80 5476' Tubing Size (size, grade, and measured depth): Short Strinn ?-::!/R" 4 7# I-RO "i~7?' Packers and SSSV (type and measured depth): 7" x 2-3/8" Baker 'GT' Ret. Dual Packer 5350' 7" x 2-38" BaKer 'FH' Ret. Packer 5451' 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment description including volumes used and final pressure: 13. Representative Daily Averaç¡e Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl CasinQ Pressure Tubinç¡ Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: 181 Daily Report of Well Operations D Exploratory o Development 181 Service 16. Well Status after proposed work: 181 Well Schematic Diagram DOil DGas o WAG DGINJ 181 WINJ o 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 Paul Chan, 564-5254 306-157 Printed Name Sondra Stewman Title Technical Assistant Prepared By Name/Number: Signature Phone 564-4750 Date Sandra Stewman, 564-4750 ~"., if . . Form 1 0-404 Revised 04/2006 ORjGlr~AL c,þ":"'./:J.--_..····.RBNK' "Ft.... III! 1 1 ?OO(' r'-.......',~ UMv D. U ~'" ./ Submit Onglnal Only Tree: CIW 21/16" 5M Dual striA Wellhead:11" x 23/8" 5M FMcW string Hanger thread 2 3/8" EUE top and IBT bottom 2" CIW-H BPV profile 20" x 34" insulated, 215 #/ft A-53 ŒÐ Short String ~ 2-3/8" HES X-Nipple (1.875" pkg. bore) KOP @ 410' Max. hole angle = 56 deg @ 3758' Hole angle thru perfs = 31 DEG. 7" 26#, L-80, BTRC Casing (drift id = 6.151, càp.= .0383 bpf) 2-3/8", 4.7 #/ft L-80, IBT tubing (drift id = 1.901, cap.=.00387 bpf) I 5,306' , 2-3/8" HES X-Nipple (1.875" pkg. bore) I 5,360' I 2-3/8" HES XN-Nipple (1.875" pkg. bore) No-Go 1.791" I 5,372' I Tubing tail I WLEG Peñoration Summary Size Spf Interval (TVD) NB sands 3 3/8" 6 5385' - 5405' 4011' - 4026' OA sands 33/8" 4 5500' - 5502' Squeezed 4 5535' - 5550' 4134' - 4147' Add 6 5550' - 5560' 4146' - 4155' 3-3/8" 6 5530' - 5540' 4129' - 4137' I 5843' , 7" Halliburton Float Collar PBTD I 5928' I 7" Halliburton float shoe MPU S-11i DATE REV. BY COMMENTS 06/22/02 MOO Drilled by Cased Doyon 141 08/31/02 Lee Hulme Completion Rig 4ES 05/13/06 MOO RWO to Add Perfs Doyon-14 e Orig. KB Elev. = 66.60 Orig. GL Elev. = 39.00 Long String 2-3/8" HES X-Nipple (1.875" pkg. bore) I 2,247' I 2-3/8" HES X-Nipple (1.875" pkg. bore) I 5,307' I 7" x 2-3/8" Baker "GT' Ret. dual pkr. 1.945" 10. I 5,350' I 7" x 2-3/8" Baker "FH" Ret. pkr. 2.41"10. I 5,450' I 2-3/8" HES XN-Nipple (1.875" pkg. bore) I 5,462'1 No-Go 1.791" I 5,470' I 2-3/8" Baker 'E' Hydro Trip Sub (2.00" pkg. bore) Tubing tail 5,475" ELMO c=J EZ Plug @ 5580' Isolated perfs 5,600'-5,615' 15,600'-5,615' MILNE POINT UNIT WELL No.: S-11i API: 50-029-23092-00 BP EXPLORATION (AK) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-11 MPS-11 RECOMPLETION DOYON DRILLING INC. DOYON 14 Start: 5/5/2006 Rig Release: Rig Number: Spud Date: End: 5/4/2006 12:00 - 14:00 2.00 RIGD P PRE Remove cellars doors and heaters 14:00 - 15:00 1.00 RIGD P PRE UD Top Drive 15:00 - 19:30 4.50 RIGD P PRE Raise C section - Prepare to skid floor 19:30 - 20:30 1.00 RIGD P PRE Skid rig floor 20:30 - 22:30 2.00 MOB P PRE Move rig off well #09-35A 22:30 - 00:00 1.50 RIGD P PRE Prepare rig to UD derrick 5/5/2006 00:00 - 01 :00 1.00 RIGD P PRE Continue prepare to UD derrick 01 :00 - 02:30 1.50 RrGD P PRE UD derrick 02:30 - 06:00 3.50 RIGD P PRE Install Boosters - UD A-Legs 06:00 - 00:00 18.00 MOB P PRE Move rig from Drill site 9 to BOC @ 00:00 hrs 5/6/2006 00:00 - 18:00 18.00 MOB P PRE Continue moving rig from BOC to MP S-11 i 18:00 . 00:00 6.00 RIGU P PRE Raise A-Legs, derrick, & wind walls - Lower C-Section - Jack floor to move position - Remove front boosters and frame - Hang front stairs and cellar doors 5/7/2006 00:00 - 02:00 2.00 RIGU P PRE PJSM - Spot conveyer on rig 02:00 - 06:00 4.00 RIGU P PRE Spot and shim rig over MP S-11 i 06:00 - 07:00 1.00 RIGU P PRE PJSM - Skid rig floor 07:00 - 19:00 12.00 RIGU P PRE Pick up Top Drive - RlU Top Drive and prepare rig for acceptance 19:00 - 00:00 5.00 RIGU P PRE Accepted rig @ 1900 hrs - Spot bleed off tank - RlU to displace well to heated seawater - Test lines to 3500 psi - Test surface lines to 3500 psi - Tested gas alarms 5/8/2006 00:00 - 01 :00 1.00 RIGU P PRE PJSM - Install double valve on annulus - RID test equipment 01 :00 - 02:00 1.00 CLEAN P DECOMP RlU and displace short string with heated seawater (25 bbls, 3 BPM @ 940 psi) 02:00 - 03:00 1.00 CLEAN P DECOMP RlU and pump 30 bbl soap pill down long string (1 BPM @ 630 psi) 03:00 - 05:00 2.00 CLEAN P DECOMP Displace well with 140 degree seawater (268 bbl total, 3 BPM @ 970 psi) 05:00 - 05:30 0.50 CLEAN DECOMP Check flow - Blow down and RID circulating lines 05:30 - 06:00 0.50 BOPSU DECOMP RlU lubricator and pull BPV's 06:00 - 07:30 1.50 BOPSU DECOMP Set TWC's - Test to 3500 psi - RID test equip 07:30 - 08:30 1.00 BOPSU DECOMP NID tree and adapter flange 08:30 - 11 :00 2.50 BOPSU DECOMP N/U adapter flange and BOP stack 11 :00 - 15:00 4.00 BOPSU DECOMP CIO upper rams to dual 2 3/8" rams, N/U choke line and bell nipple 15:00 - 17:00 2.00 BOPSU DECOMP RlU test equipment and floor valves 17:00 - 00:00 7.00 BOPSU DECOMP Test BOPE - 250 psi low, 3500 psi high for 5 minutes per test - Witness of test waived by AOGCC rep Jeff Jones 5/9/2006 00:00 - 01 :30 1.50 BOPSU DECOMP Continue testing BOPE- RD test equip.- Blow down all lines 01 :30 - 03:00 1.50 BOPSU DECOMP Drain BOP's- Clear floor- PJSM on lubricator. 03:00 - 05:00 2.00 BOPSU DECOMP Mobilize lubricator, extension rods to rig floor- PU landing joint- Pull TWC- Well static- Pull TWC #2- LD equipment 05:00 - 07:00 2.00 MOB P DECOMP Moblize dual equipment to rig floor- RU same 07:00 - 07:30 0.50 PULL P DECOMP PJSM on pulling dual strings- MU landing joints wI safety valves in top. 07:30 - 08:30 1.00 PULL P DECOMP BOLDS- Pull on tubing and unseat hanger- Pull to 130k (including blocks), attempt to release packer at 5480' wI no success. 08:30 - 15:00 6.50 PULL C DECOMP Continue working string to 130k while waiting on Schumberger E-Line. 15:00 - 16:00 1.00 RIGU C DECOMP PJSM wI all personnel involved- RU Schlumberger W.L. on long string side- Install floor safety valve on short side. Printed: 5/22/2006 11 :55:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-11 MPS-11 RECOMPLETION DOYON DRILLING INC. DOYON 14 Start: 5/5/2006 Rig Release: Rig Number: Spud Date: End: 5/9/2006 16:00 - 22:00 6.00 PULL C DECOMP RIH w/1 strand string shot- Locate "X" nipple at 2237'- Continue in hole- Locate collar at 5394' W.L.M.- Pull up and fire string shot across area to be chemical cut ( approx. 5379')- POH wI W.L.- LD S.S. assembly- RU Chem. cutter. PJSM- RIH wI chem. cutter - Taking weight @ 500 to 700' - 1500' - Could not pass 2761' - Jar string up from 2761' pass 2687' - POH with no other tight spots seen - LD chemical cutter - Inspect wire line tools - No visual problems - String shot 1.6875" 00 - Chemical cutter 1.75" 00 - (Anchor - Severing head) 22:00 - 22:30 0.50 PULL C DECOMP RU pump in sub I circulating lines - Circulate two tubing volumes - 40 bbls - 2 bpm @ 430 psi - RD circulating line 22:30 - 00:00 1.50 PULL C DECOMP RU wire line lubricator head - MU 1.6875 00 sinker bars - CCL - Jars - RIH to 5384' with No obstructions - POH 5/10/2006 00:00 - 00:30 0.50 PULL C DECOMP LD - Sinker bars, Jars, CCL 00:30 - 02:00 1.50 PULL C DECOMP PJSM - (Running chemical cutter with Schlumberger personnel) - Make up 1.6875 00 chemical cutter 02:00 - 04:00 2.00 PULL C DECOMP RIH with cutter to 5404' WLM - Correlate cutter on depth - Cut long string @ 5379' WLM - Collar 5394' WLM - Shot fired - String jumped - Indicating tubing cut - POH 04:00 - 04:30 0.50 PULL C DECOMP LD cutter assy 04:30 - 05:00 0.50 PULL C DECOMP Make up lubricator to short string - MU string shot. 05:00 - 06:00 1.00 PULL C DECOMP RIH- Spot string shot across area to be cut (approx. 5355')-Fire S.S.- POH 06:00 - 07:00 1.00 PULL C DECOMP RU and pump down short string 2x pipe vol. (40 bbls)- 3 bpm, 800 psi. 07:00 - 07:30 0.50 PULL C DECOMP RD circ. lines- RU fl Chem. cutter 07:30 - 08:30 1.00 PULL C DECOMP RIH wI Chem. cutter- Spot cutter at 5355'- Fire shot- Good indication 08:30 - 10:00 1.50 PULL C DECOMP POH wI W.L.- RD same. 10:00 - 11 :00 1.00 PULL P DECOMP Pull on dual string- pulling free wI 95k up wt.- Pull hanger to rig floor- Observe well & clear floor of SWS equip. 11 :00 - 12:00 1.00 PULL P DECOMP PJSM- RU to pull long string- 12:00 - 18:00 6.00 PULL P DECOMP LD long string side of 2 318" 4.7# L-80 IBT tubing- Recovered 171 jts. + cut jt. (15.15'). 18:00 - 23:00 5.00 PULL P DECOMP LD short string side of 23/8" 4.7 # L-80 IBT tubing - Recovered 172 jts + cut jt (10.40') 23:00 - 00:00 1.00 PULL P DECOMP PJSM - Clear rig floor - LD power tongs - Tubing equipment - Drain stack - Install test plug - Ru testing equipment - Change dual 2 3/8" rams to 2 7/8" x 5" VBR's 5/11/2006 00:00 - 02:30 2.50 EVAL P DECOMP Change out dual rams to 2 7/8" X 5" VBR's - Test to 250 low 3500 high for 5 mins each - RD testing equip - Pull test plug - Install wear ring - 02:30 - 03:00 0.50 PULL P DECOMP PJSM - Moblize BHA to rig floor - MU Fishing assy 03:00 - 04:00 1.00 PULL P DECOMP PU 4 3/4" DC's from pipe shed. 04:00 - 05:30 1.50 PULL P DECOMP Cut & slip drlg line- Service rig. 05:30 - 10:30 5.00 PULL P DECOMP PU 4" DP from pipe shed to 5336'- PU 130k- SO 100k 10:30 - 12:00 1.50 PULL P DECOMP Screw in top drive- Obtain parameters- Circ. down wI 3 bpm 180 psi & tag fish at 5341 '- Engage fish (observe 40 psi increase)- PU to 30k over & bleed jars- Pull to 40k over wI no movement- Pull to 60k over & Packer sheared, lost 10k weight- Pull back to 60k over wI no movement- Work to 60k over several times wI no success· Jarring wI 50k over f/1 0 min.- Jarring wI 60k over fl 20 min.- Pull t070k over- Pulled free- let Printed: 5/22/2006 11 :55:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-11 MPS-11 RECOMPLETION DOYON DRILLING INC. DOYON 14 Start: 5/5/2006 Rig Release: Rig Number: Spud Date: End: 5/11/2006 10:30 - 12:00 1.50 PULL P DECOMP packer elements relax f/10 min.- Pull free- Dragging 30k over. 12:00 - 13:00 1.00 PULL P DECOMP Circ. bottoms up- Full returns- Observe well f/10 min.- Pump dry job 13:00 - 16:00 3.00 PULL P DECOMP POH from 5341' - to 308' @ BHA 16:00 - 19:30 3.50 PULL P DECOMP Stand back DC's - LD Jars - Break out overshot - LD "GT" packer - Cut off joint 16.02' below packer (long string) - Tail pipe - mule shoe - 2 318" XN nipple - 10' pup joint - XO pup below packer (short string) - Packer slips intact - Top metal ring on packer rubber loose - Packer rubber ok - Bottom metal ring bent 19:30 - 20:00 0.50 PULL P DECOMP RD Dual equipment - Clear floor - RU to run overshot assy 20:00 - 20:30 0.50 PULL P DECOMP Make up overshot assy - # 2 20:30 - 00:00 3.50 PULL P DECOMP RIH from 308' to 5480' - Screw into top drive - Obtain parameters - Circ down w 3 bpm 170 psi - PUW 135 - SOW 105 - Engage fish @ 5506' - PU to 170K - bleed jars - PU to 180K Packer free - Work string up 10' - SO 15' - CBU 2114 X- 3 to 6 bpm - @ 350 to 700 psi - No losses - Gas I Oil back on bottoms up - Heavy oil tar - tar balls 5/12/2006 00:00 - 01 :00 1.00 PULL P DECOMP Pump 20 bbl Safe-surfo sweep - 7 BPM @ 900 psi - 90 bbls pumped - Pressure up to 1400 psi - Lost returns - Shut down pump - PU string, tight - Pull 30'- String weight normal - Pump 1 to 2 bpm - @ 300 psi establish returns - attempt to slack off - 10K down taking weight - PU additional 30' - Pump 2 bpm 325 psi with returns - Well swabbing when picking up - Heavy oil - tar balls back - Stand back stand - Circulate additional 90 bbls to clean sweep out of hole - 3 bpm 330 dropping to 220 psi 01 :00 - 01 :30 0.50 PULL P DECOMP Blow down Top Drive - Monitor well - Well static 01 :30 - 05:00 3.50 PULL P DECOMP POH with packer - from 5420' to 308' @ BHA 05:00 - 06:00 1.00 PULL P DECOMP Stand back DC's- LD jars etc.- Release fish 06:00 - 06:30 0.50 PULL P DECOMP RU GBR tubing equipment. 06:30 - 07:30 1.00 PULL P DECOMP Clean parafin and oil from recovered tubing & packer- LD same- Recovered cut jt (16.10')- 1 full jt- packer & muleshoe. 07:30 - 08:30 1.00 PULL P DECOMP RD tubing equipment- Clean rig floor 08:30 - 09:30 1.00 PULL P DECOMP MU 7" scraper BHA & DC's. 09:30 - 11 :30 2.00 PULL P DECOMP RIH to 5400' 11 :30 - 12:00 0.50 PULL P DECOMP Screw in top drive- Break circulation- Obtain parameters- PU 125k- SO 105k- ROT 11 Ok- Wash down fl 5400' to 5711 '- 260 gpm 780 psi- 60 RPM 12:00 - 15:00 3.00 PULL P DECOMP Pump 40 bbl H.V. sweep- 50 bbl hot seawater- 50 bbl "Safe Surf 0" pill- 50 bbl hot seawater- 50 bbl "Safe Surf 0" pill- 200 bbls 140 degree seawater- 380 gpm 1440 psi- Rotate 60 rpm- Reciprocate 80' strokes throughout operation- Monitor well f/10 min. (lost 1 bbl)- Pump dry job 15:00 - 17:00 2.00 PULL P DECOMP POH from 5711' to 307' 17:00 - 17:30 0.50 PULL P DECOMP Stand back DC's - Break bit - LD BHA 17:30 - 19:00 1.50 PERF P DECOMP PJSM - RD Flow line - RU Shooting flange 19:00 - 23:30 4.50 PERF P DECOMP PJSM - RU Schlumberger Pressure control equipment - E-line - PU HES EZDrill- Test pressure control eqipment to 1500 psi - Test good 23:30 - 00:00 0.50 PERF P DECOMP RIH with EZ Drill 5/13/2006 00:00 - 02:00 2.00 PERF P DECOMP RIH wI EZ Drill - Correlate on depth - (SCMT Primary Depth Control July 1, 2002 log) - Set @ 5580' - POH - LD HES running tool Printed: 5/22/2006 11 :55:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-11 MPS-11 RECOMPLETION DOYON DRILLING INC. DOYON 14 Start: 5/5/2006 Rig Release: Rig Number: Spud Date: End: 5/13/2006 02:00 - 02:30 0.50 PERF P DECOMP Make up perforating gun for 1 st run - 3 3/8" HSD - 6 spf 60 degree phasing 3406 Power jet HMX charge - PU same - Test lubricator connection to 1500 psi using quick test sub 02:30 - 04:30 2.00 PERF P DECOMP RIH to 5580' tag EZ Drill - Correlate on depth at 5550' - Perforate from 5550' to 5560' - Monitor well - POH - LD gun 04:30 - 05:00 0.50 PERF P DECOMP Make up perforating gun for 2nd run - 3 3/8" HSD - 6 spf 60 degree phasing 3406 Power jet HMX charge - PU same - Test lubricator connection to 1500 psi using quick test sub 05:00 - 06:00 1.00 PERF P DECOMP RIH to 5580' tag EZ Drill - Correlate on depth at 5530' - Perforate from 5530' to 5540' - Monitor well - POH - LD gun 06:00 - 07:00 1.00 DECOMP Change out firing head. 07:00 - 07:30 0.50 PERF P DECOMP Make up perforating gun for 3rd run - 3 3/8" HSD - 6 spf 60 degree phasing 3406 Power jet HMX charge - PU same - Test lubricator connection to 1500 psi using quick test sub 07:30 - 09:00 1.50 PERF P DECOMP RIH to 5580' tag EZ Drill - Correlate on depth at 5385' - Perforate from 5385' to 5405' - Monitor well - POH - LD gun 09:00 - 10:00 1.00 RIGD P DECOMP RD Schlumberger pressure control equipment· E-line. 10:00 - 10:30 0.50 RIGD P DECOMP NO shooting flange. 10:30 - 11 :30 1.00 RIGU P DECOMP NU pitcher nipple flange- Riser- Flowline- Fill up line. 11 :30 - 12:30 1.00 RUNCO RUNCMP PJSM- PU BHA- DC's 12:30 - 15:00 2.50 RUNCO RUNCMP RIH f/314' to 5300' 15:00 - 16:00 1.00 RUNCO RUNCMP Screw in Top Drive- Wash down f/5300' to 5500'- Pump H.V. sweep- 140 degree seawater 16:00-18:00 2.00 RREP RUNCMP Repair Iron roughneck spinner motor 18:00 - 22:00 4.00 RUNCMP LD 4" DP 1 X 1 from 5500' to 314' @ BHA 22:00 - 23:00 1.00 RUNCMP LD DC's - Scraper - Junk baskets - Bit sub - Bit - PU Overshot - Service breaks 23:00 - 00:00 1.00 RUNCMP Clear rig floor - Pull wear bushings - Install test plug - Change 2 7/8" X 5" VBR to 2 3/8" Dual rams 5/14/2006 00:00 - 03:00 3.00 RUNCMP Change top rams to 2 3/8" duals - RU test equipment - Test Dual rams to 250 low· 3500 high 5 mins each test - Test good - Pull test plug - RD I LD test equipment 03:00 - 04:00 1.00 RUNCMP PJSM - RU Dual completion equipment 04:00 - 17:00 13.00 RUNCMP PU 2 3/8" Dual Completion and run 172 jts on each side to 5447' lower packer depth. 17:00 - 17:30 0.50 RUNCMP RU & circ. 1 1/2 x pipe volume (33 bbls) down long string. - POW 92 - SOW 75 17:30 - 20:30 RUNCMP PJSM- RU Schlumberger on long string- RIH wI GRlCCL to 5469' - Correlate packers on depth - POH - RD Schlumberger 20:30 - 22:00 1.50 RUNCMP Space out - Balance string weights - MU hangers - Land hangers - RILDS 22:00 - 00:00 2.00 RUNCMP RU to pump 170 bbls seawater through annulus taking returns uo tubing strings - Test lines to 1000 psi - Pump 70 bbls seawater - 100 bbls inhibited seawater - 5/15/2006 00:00 - 01 :30 RUNCMP PJSM - RU Hot oil to annulus - Test lines to 4000 psi - Freeze protect with diesel 60 bbls - 2 bpm 700 psi - Taking returns out long I short strings 01 :30 - 02:00 0.50 RUNCO RUNCMP Drop ball on long string - RU to set packers I test long string 02:00 - 03:00 1.00 RUNCO RUNCMP Chart recorder not working - Wait on chart recorder 03:00 - 07:00 4.00 RUNCO RUNCMP Pressure up to 3200 psi set packers on long string - Hold for 30 mins - Test good - Bleed off - Pressure up to 3500 psi on Annulus - Hold for 30 mins . Test good - Bleed off - Pressure up to 2500 psi on Short string - Pressure bleedig off 200 to 250 Printed: 5/22/2006 11 :55:42 AM .. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-11 MPS-11 RECOMPLETION DOYON DRILLING INC. DOYON 14 Start: 5/5/2006 Rig Release: Rig Number: Spud Date: End: 07:00 - 08:30 1.50 psi in 15 to 20 mins mins - Pressure up to 1000 psi on Annulus - Pressure up to 2500 on tubing - No Increase in pressure on annulus - Same drop rate on tubing - Possible leak through ball I seat RUNCMP Lay down landing joints - Install TWC - Test from top 1000 psi - Test good RUNCMP NO BOP stack RUNCMP NU adapter I tree RUNCMP Test adapter I tree to 5000 psi for 10 mins - Test good - Test tree - Long side - Short side 5000 psi for 30 mins - each test - test good - RD test equipment - Lines RUNCMP Pull TWC with lubricator - Install BPV - Test 1000 psi - Secure well 08:30 - 10:00 10:00 - 11 :30 11 :30 - 13:00 1.50 1.50 1.50 13:00 - 15:00 Printed: 5/22/2006 11 :55:42 AM e e p ij ì ~~ Ir b FRANK H. MURKOWSKI, GOVERNOR AlfASIiA OILAl'fD GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 PaulChan Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 ~D~ i 13 Re: Milne Point Unit, Schrader Bluff Oil Pool, MPS-1li Sundry Number: 306-157 SCANNED o 9 2008 Dear Mr. Chan: 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-iday of May, 2006 Encl. Þ17S 5/~~ Cf4, þ ( . STATE OF ALASKA 5M it._ ALASKA OIL AND GAS CONSERVATION CO~ISSION -...., APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 P"FO § \I ,,:.. () 1. 2005 1. Type of Request: 0 Abandon o Alter Casing o Change Approved Program o Suspend 0 Operation Shutdown 181 Perforate 181 Other IsolatJt:lì!fWMìêÎBP o Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well 181 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well Class: o Development 0 Exploratory o Stratigraphic ~ Service . 5. Permit To Drill Number 202-113 . 6. API Number: 50-029-23092-00-00 . 99519-6612 66.60 9. Well Name and Number: MPS-11 i 8. Property Designation: " 10. Field / Pool(s): 11. Total Depth MD (ft): 5939 Casing Structural Conductor Surface Intermediate Production Liner ADL 380110 ........................> ..'..,. Total Depth TVD (ft):1 Effective Depth MD (ft): 4486 I Length Size MD Milne Point Unit / Schrader Bluff . _ -- -- . . Effective Depth TVD (ft) Plugs (measured): Junk (measured): 4475 N/A Approx.5843' TVD Burst Collapse 112' 5900' 20" 7" 112' 5928' 112' 4476' 1490 7240 470 5410 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: 5500' - 5615' 4104' - 4202' 2-3/8",4.7# Packers and SSSV Type: 7" x 2-3/8" Baker 'GT' Ret. Dual Packer 7' X2-38" Baler 'FH' Ret. Packer Tubing Grade: I Tubing MD (ft): L-80 5506' & 5590' Packers and SSSV MD (ft): 5480' 5560' 12. Attachments: ~ Description Summary of Proposal 0 BOP Sketch o Detailed Operations Program 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: o Exploratory 0 Development ~ Service , 16. Verbal Approval: Commission Representative: 17. I hereby c~at the fore~g is true and correct to the best of my knowledge. Printed NarÌ1f ~ ~ I I Title Drilling Engineer Signature ~ ~ ( I Phone 564-5254 '- '--- Commission Use Only 05/05/06 Date: 15. Well Status after proposed work: OOil o Gas o WAG 0 GINJ o Plugged ~ WINJ . o Abandoned o WDSPL Contact Paul Chan, 564-5254 Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity ~OP Test ~chanicallntegrity Test 0 Location Clearance Date ç I, /Ot. -r Sundry Number: 1,(){ D -1f51 Prepared By Name/Number: Sondra Stewman, 564-4750 Other. 3SDO,><;;:. ""-"" '''''''''' ~C)Y' 7: .- WA"",-,,>~,", ~ "",,-,<-,,- --,,,-,I.. """'.......~" · Subsequent Form Required: l..\b Wen 1/A'1 RBDMS BFl MAYO 8 2006 !JII (" if! ð APPROVED BY _ r. Approved By: ) Mlf COMMISSIONER THE COMMISSION Date 5, tf-....VO Form 10-403 Revised 07/2005 0 R \../'\G \ ~ Ç(.A L '- --- s~n P'U~I!C:t¿ \~AI ~jÞ/~ e e bp M··')· P· 'j "'1 ,'4', '~, " ,\ iì1 !ns' :!~, :j ·)0: ,1·\n( "t' .·0 .i : f .:.; .:\.{ .0'0 ; )Jjj: ~/ '," ..' - 5-11 proposed Ria Workover Procedure 1. MIRU. ND tree. NU and test BOPE to 3500 psi. Circulate out freeze protection fluid and circulate well to clean brine through the cut. 2. Pull and LD 2-3/8" dual completion and Baker GT packer. 3. RIH with drill pipe and retrieve Baker FH packer and tailpipe. 4. RU e-line and isolate OB sands with CIBP set at -5590' MD. 5. Perforate NB sands (5385 - 5405' MD) and OA sands (5530 - 5540' MD and 5550 - 5560' MD) with 3-3/8" 6 SPF 60° phasing guns. 6. Run 2-38" L-80 BTC dual string completion with Baker GT at - 5350' MD and FH packer at -5450' MD. 7. Displace the IA to packer fluid, freeze protect the well, and set the packer. 8. Test tubing to 3500 psi, test annulus to 3500 psi. 9. Set BPV. ND BOPE. NU and test tree. RDMO. Tree: CIW 21/16" 5M Dual stri Wellhead:11"x23/8"5MFMCdualstring MPU 5-11 i Hanger thread 2 3/8" EUE top and IBT bottom 2" CIW-H BPV profile 20" x 34" insulated, 215 #/ft A-53 ~ Short Strina ~ 2-3/8" HES X-Nipple (1.875" pkg. bore) KOP @ 410' Max. hole angle = 56 deg @ 3758' Hole angle thru perfs = 31 DEG. 7" 26#, L-80, BTRC Casing (drift id = 6.151, cap.= .0383 bpf) 2-3/8",4.7 #/ft L-80, IBT tubing (drift id = 1.901, cap.=.00387 bpf) I 5446' I 2-3/8" HES X-Nipple (1.875" pkg. bore) I 5495' I 2-3/8" HES XN-Nipple (1.875" pkg. bore) No-Go 1.791" I 5506' I Tubing tail/ WLEG Perforation Summary Size Spf Interval (TVD) OA sands 33/8" 4 5500' - 5502' Squeezed 4 5535' - 5550' 4134' -4147' OB sands 33/8" 4 5600' - 5615' 4190'-4203' I 5843' I 7" Halliburton Float Collar PBTD I 5928' I 7" Halliburton float shoe DATE REV. BY 06/22/02 08/31/02 MOO Lee Hulme Drilled by Cased Doyon 141 Completion Rig 4ES COMMENTS Orig. KB Elev. = 66.60 Orig. GL Elev. = 39.00 Long String 2-3/8" HES X-Nipple (1.875" pkg. bore) I 2238' I 2-3/8" HES X-Nipple (1.875" pkg. bore) I 5446' I 7" x 2-3/8" Baker "GT" Ret. dual pkr. 1.945" 10. I 5480' I 7" x 2-318" Baker "FH" Ret. pkr. 2.41" ID. I 5560' I 2-3/8" HES XN-Nipple (1.875" pkg. bore) I 5577' I No-Go 1.791" ELMD c::J I 5585' I 2-3/8" Baker 'E' Hydro Trip Sub (2.00" pkg. bore) 1.75" ball. MILNE POINT UNIT WELL No.: S-11i API: 50-029-23092-00 BP EXPLORATION (AK) e e Tree CIW 21/16" 5M Dual siring Welihead:11" X 2 318" 5M FMC dual string Hanger thread 2 318" EVE top and IBT bottom 2' CIW-H BPV profile MPU S-11i Olig. KB Elev. = 66_60 o rig. G L Elev_ = 39.00 PROPOSED COMPLETION 20" x 34" insulated. 2151#11 ,A -53 G2:Ð Short StrInQ Long StrlnQ ~ 2·318' HES X-Nipple (1875" pkg. bore) 2·318" HES X·Nipple (1,875" pkg, ore) I 2238' I KOP @ 410' Max hole angle = 56 deg @ 3758' Hole angle tlHlI perts = 31 DEG 7" 26#, L·80, BTRC Casing (drift id = 6.151, cap.= .0383 bpI) 2-318',4.7 #1ft L-60, tubing (drift id = 1.901, cap_=_00367 bpI) 2·318" HES X·Nipple (1.675' pkg. bore) 2-318" HES X-Nipple (1675' pkg. bore) I 5350' I 7" x 2·318'· Saker 'GT' Ret dual pkr 1.945" 10. Tubing tail ¡ WLEG I 5450' I 7" x 2-318' Baker "FH' Ret. pkr. 2.41·ID Sí-e Spf 2·318' HES XN·Nipple (1.875" pkg. bore) No·Go 1791" 3 318" 6 4007'·4038' 2-318" Baker 'E' Hydro Trip Sub (2.00" pkg. bore) 3 318" 4 4Æ Squeezed 4129,,4155· Abandoned ./ 08 perforations abandoned 7" Halliburton Float Collar PBTD 7" Halliburton float shoe REV. e V MDO COMMENTS Drilled by Cased Doyon 141 Complelion Rig 4ES MILNE POINT UNIT WELL No.: 5-111 API: 60..029·23092..00 Lee Hulme BP EXPLORATION (AKa e e MPS-ll Sundry e e Tom BP Milne Point would like to isolate the OB sands in the MPS-11 well and re-complete the well in the Nand OA sands as a dual injector. The OB sands in this well currently "short circuit" to the producer. A CIBP will be used to isolate the sands and preserve any future utility for this interval. I have also enclosed an updated proposed wellbore schematic for this completion. Thanks Paul x5254 -----Original Message----- From: Chan, Paul (PRA) Sent: Wednesday, May 03, 2006 2:16 PM To: I tom maunder@admin. stat:e. ak. us I Subject: RE: MPS-11 Sundry Tom In reference to your questions: 1) We would like to isolate the OB from injected fluids with a CIBP and preserve any future utility in the OB interval. 2) The pre-rig prep consists of setting a plug in each of the tubing strings above the packer and chemical cutting the long string between the packers. We will also tubing punch above the plugs for drain holes while tripping. Thanks Paul x5254 -----Original Message----- From: Thomas Maunder lto:tom maunder@admin.state.ak. Sent: Tuesday, May 02, 006 3:45 PM To: Stewman, Sondra D Subject: MPS-11 Sundry Sondra, Would you mind forwarding this to Paul Chan, for some reason I don't have his eddress. Paul, Looking at your application. A couple of requests... 1. Could you provide a statement of why the work will abandon the OB sands? 2. Is there pre-rig work being done? If so, that should also be covered in the application. Call or message with any questions. 10f2 5/4/20062:20 PM MPS-ll Sundry e e Tom Maunder, PE AOGCC Content-Description: MPS-ll Proposed completion.ZIP MPS-ll Proposed completion.ZIP Content-Type: application/x -zip-compressed Content-Encoding: base64 2 of2 5/4/20062:20 PM e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfihn _ Marker.doc ;21 J~ .(~~ DATA SUBMITTAL COMPLIANCE REPORT 9/7/2004 Permit to Drill 2021130 Well Name/No. MILNE PT UNIT SB S-11 MD 5939 v' TVD 4486 ~ Completion Date 8/29/2002 ~comPletion Status 1WINJ Operator BP EXPLORATION (ALASKA) INC ~--~ curL~ ~~I_~~/ REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, PWD, CCl, SCMT Well Log Information: Log/ Electr Data . igital Dataset Type Med/Frmt NUr:!JÞer Name D ¿..A1216 LIS Verification Log Log Run Scale Media No 1 Rpt Rpt ¿)-og 0g Rpt ~ ~.C ~C Directional Survey LIS Verification ). 9 4-'-'( )Jj-Ð L- a! j (j~ M ~ ).- Cement Evaluation Cement Evaluation 5 5 Col Col Directional Survey J Directional Survey 111}1 Cement Evaluation c1A'398 See Notes ~D Directional Survey Well Cores/Samples Information: Name Interval Start Stop Received Sent ADDITIONAL INFORM~(. ION Well Cored? Y(l~ Chips Received? _/YIN=---- Daily History Received? Formation Tops Analysis Received? ~ )¡1~J ~'1 JWi'<- ~ i API No. 50-029-23092-00-00 .- UIC Y (~-~--------- ~:-~_._- ---".- Directional Surve~ ~_::=~-- ~~-~_._._---~--._-~------- (data taken from logs Portion of Master Well Data Maint) Interval Start Stop 338 5891 0 5939 338 5891 5200 5780 0 5822 0 5939 0 5939 2 5803 388 5939 0 ~., OH/ CH Received Comments Open 1 0/17/2002 Open 7/25/2002 Open 10/17/2002 Case 1 0/14/2002 Case 8/30/2002 Primary Depth control Open 7/25/2002 MWD Open 7/25/2002 MWD Case 10/1/2002 Open 12/18/2002 5939 Open 7/25/2002 Sample Set Number Comments ~ ~/N -~-~-~------------ Digital Well logging Data / Rate of Penetration, Dual Gamma Ray, Electromagnetic Wave Resistivity II I::-~ ~_._+------~--~-_.-----~---_._- - ---_.~~-- --~-._-_.~---~-'- --- DATA SUBMITTAL COMPLIANCE REPORT 9/7/2004 Permit to Drill 2021130 Well Name/No. MILNE PT UNIT 5B 5-11 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23092-00-00 MD 5939 TVD 4486 Completion Date 8/29/2002 Completion Status 1WINJ Current Status 1WINJ UIC Y ------~----_u_._---_.~-_.-.- Comments: Compliance Reviewed By: ~-'O Date: '> '0,~'{ dl\ ~-~ .....~.....cc..... 0Ü0-- l( ~ MECHANICAL INTEGRITY REPORT' '.... :. I G R E L E J... S::: : ~ ~~~-O ~_. . (þ ,. ò:--..-- -r\ \. . r-:;--~ '-I~' OPER & FIELD -rJD Ù."\ \? (' \.\\ \-"\, ,~~- Ù,V\~J-- M?~-- \ \ 5?UD DA':Z: "W""ELL NUH:B ER :~ ~LL DATA " ,-"... "-; IQ.. \ ' \-t "'A TVD ...._",1) TD ~ I~~,).~, MD. iÎ'.- ..I~,..~" '.."-. TVD TD :.-J ì) tHD" '-\. \. D\-P - ; .û -- <.J, - . Casing: \'\ Shoe: S~dS< MD TVD i DV: MD .T\tu .:...::"':1e;:-: Shoe: MD TVD j :OP: HD :~rD :ubi!;g: Packe:;: . till 1'\71)¡ Set a.t ::ole Size s '~ ('-f, t., anå 'N~ P er£ s ~. t"".. ~ , .J '-~ ,-~.~ to ~55T) s~oo ,s~ ( S- ::-::ECèI.Al-1IC;'.L INTEGRITY - PART f 1 Annulus Press Test: :î.P 15 min 30 min COtIiIIlents: ~ MECHÞ_1\fICÞ~ INTEGRITY - PART /2 \'ó-';O "S'f ~ y.\\~ -so rJ <;;''i .~ \\ \, ~-, Cement Volumes:" Amt. Liner ~Þ\; Csg $YS'~~$\~j DV \-Jt\ Cwt -"01 to cove:;: perf s d'''1 s,,+ ~\- "~\ \ ~-..J~\~'<U\"\- \ö C'~0\<: t-- ~ ~~~'> SCù( . Theoretical TOC ~~~CSC ~ i i ~ ~ iI I I j ~ Cement Bond Log (Yes or No) \(c¿ ~ :In AOGCC File i~s. d- ç'\\~~ Ct'BL :valâtion, zone above perfs'll'-.hú.\ b~ ~~-\ v~'t. 'J~~a ~~~~0~e":?k ~~.\ a~~'(\'ß( ~N:JS~\\ tM\,,~~- Proåuc..tion Log: Type Evaluation I . > ~ CONCLUSIONS: ? ar t : 1 : ? ar t: i 2 : \-\:L. \s \~CL~a,. 'k9~S¡(¥6~~ , , :- ¡ j - -... -- ( WELL LOG TRANSMIITAL State of Alaska Alaska Oil and Gas Conservation Cotnm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 To: RE: MWD Formation Evaluation Logs: MPS-ll: Digital Log Images: 50-029-23092-00 December 17, 2002 MPS-II, AK-MW-22101 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 --" \~~ Sì~--þ- (~ C~/V~ . DfC 'D 18 " i"", <Va? v4'& C < 4nCf¡o;'Ott$, ca age '!ì¡1.111.#¡... . ""i110n ~ D~ - J ) 3 113g'ö ( ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised: 11/05/02, Put on 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 3338' NSL, 79' WEL, SEC. 12, T12N, R10E, UM At top of productive interval 879' NSL, 2818' WEL, SEC. 07, T12N, R11E, UM At total depth 721' NSL, 2693' WEL, SEC. 07, T12N, R11E, UM 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. KBE = 66.6' ADL 380110 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 6/24/2002 6-26-2002 8-28-2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 5939 4486 FT 5927 4475 FT 181 Yes 0 No 22. Type Electric or Other Logs Run MWD,GR,RES,PWD,CCL,SCMT 23. CASING SIZE 20" 7" Classification of Service Well Water Injection 7. Permit Number 202-113 302-260 8. API Number 50- 029-23092-00 9. Unit or Lease Name Milne Point Unit 10. Well Number MPS-11 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 Surface 112' 42" 260 sx Arctic Set (Approx.) 28' 5928' 9-7/8" 1322 sx PF 'L', 376 sx Class 'G' AMOUNT PULLED TUBING RECORD SIZE DEPTH SET (MD) 2-3/8",4.7#, L-80 5506' 2-3/8",4.7#, L-80 5590' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 80 Bbls of Diesel. Sqzd. with 17 Bbls Class 'G' 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 OA Sands OA Sands 25. MD TVD 26. 5535' - 5550' 4134' - 4147' OB Sands OB Sands 5500' - 5502' 5600' - 5615' 4190' - 4203' 27. Date First Production October 13, 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 Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL-BBL GAs-McF W ATER-BBL PACKER SET (MD) 5480' 5560' CHOKE SIZE GAS-OIL RATIO OIL GRAVITY-API (CORR) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. sU~iic€ EilsV ~ D No core samples were taken. Form 10-407 Rev. 07-01-80 NOV 0 6 2002 Alaska Oil.& Gas Gons. Commission Anchorage C> (c Submit In Duplicate 29. Geologic Markers Marker Name Measured True Vertical Depth Depth SBF2-NA 5339' 3976' SBF1-NB 5380' 4008' SBE4-NC 5413' 4034' SBE2-NE 5426' 4044' SBE1-NF 5486' 4093' TSBD-OA 5529' 4129' TSBC 5562' 4157' TSBB-OB 5593' 4183' SBA5 5624' 4210' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 30. Formation Tests Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Rl!efrVED NOV 0 6 2002 Alaska on & Gas Oons. Commission Anchorage 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed son~)\.~~.ritle Technical Assistant Date \ l- 0(0'- 02...- MPS-11 i 202-113 302-260 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 WELL LOG TRANSMITIAL To: State of Alaska Alaska Oil and Gas Conservation COtnm. Attn.: Lisa Weepie 33 3 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs MPS-ll, 1 LIS formatted Disc with verification listing. PùPI#: 50-029-23092-00 ë;(oa-/13 II alto October 15, 2002 AK-MW-22101 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99648 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: Sign~ t.JJ Oop, ) RECEIVED OCT 1 7 2002 AJ88kaOii & Gas Cons. Commiaeion Anchorage Sc~lulR~ePDep GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 A TTN: Beth Well PSI-08 ~r.Jà...fJ.~ MPS-11 c9-CB.- JJ 3 D.S. 3-09 I ,9 - rJri ~ 2-14/0-16 1 ~<O-/LJ 't Job# Log Description 22448 USIT 22447 SCMT 22019 CNTG(REPROCESSED) 22407 RST -SIGMA 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 RECE\VED OCT 1 4 2.002. ...J,. ~'I & i"".-ft\'i.. Con~ Ccrnmi!tÎOn þJi:IUI\8 u.¡ \.J0óI' AnchOœge Date 09/21/02 08/29/02 12/19/01 07/31/02 NO. 2462 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Endicott P Bay, M. Point BL CD Sepia Color 2 2 1 Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 A~- ~~~. 10/2/2002 /",II;IIiII$._>-_, ~ Sc~lunIblPgep Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Well Job# Log Description MPS-11 ¿;}Oò\- II ~ ~PS-13 dO d-JJt..j D-08A aOd-}~ ~ D-17B ~~- J II D.S. 14-33 I <6' ~-I d S 22443 SCMT (PDC) 22444 SCMT (PDC) 22434 GRlCCL (PDC) 22433 GRlCCL (PDC) 22386 RST -SIGMA PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 -~ . Date Delivered: ~ ~ (Á Oco ~ Date 07/01/02 07/02/02 07/15/02 07/12/02 07/21/02 Blueline NO. 2449 Company: 09/30/02 State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Sepia Color Prints ~'-~ CD ~- Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth RECEIVED Received by: OCT 0 1 2002 AlIIke Oil & Gal ConI. CommJuilln AndIcnge 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 99519-6612 4. Location of well at surface 3338' NSL, 79' WEL, SEC. 12, T12N, R10E, UM At top of productive interval 879' NSL, 2818'WEL, SEC. 07, T12N, R11E, UM At total depth 721' NSL, 2693' WEL, SEC. 07, T12N, R11E, UM 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. KBE = 66.6' ADL 380110 12. Date Spudded 13. Date T.D. Reached 14. Date Comp...;,¿;Susp., or Aband. 6/24/2002 '" 6-26-2002 ~002 )þ 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 5939 4486 FT 5927 4475 FT 181 Yes 0 No 22. Type Electric or Other Logs Run MWD,GR,RES,PWD,CCL,SCMT 23. CASING SIZE 20" 7" Classification of Service Well Water Injection 7. Permit Number 202-113 302-260 8. API Number 50- 029-23092-00 9. Unit or Lease Name Milne Point Unit { . ." -<... l~~ 10. Well Number MPS-11i 11. Field and Pool Milne Point Unit I Schrader Bluff 15. Water depth, if offshore 16. No. of Completions N/A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost N/A 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 Surface 112' 42" 260 sx Arctic Set (Approx.) 28' 5928' 9-7/8" 1322 sx PF 'L', 376 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 OA Sands OA Sands 25. 26. TUBING RECORD SIZE DEPTH SET (MD) 2-3/8",4.7#, L-80 5506' 2-3/8",4.7#, L-80 5590' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 80 Bbls of Diesel. Sqzd. with 17 Bbls Class 'G' PACKER SET (MD) 5480' 5560' MD TVD 5535' - 5550' 4134' - 4147' 08 Sands 08 Sands 5500' - 5502' 5600' - 5615' 4190' - 4203' 27. Date First Production Not on Injection Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) N/A PRODUCTION FOR Oll-BBl TEST PERIOD GAs-McF WATER-BBl CHOKE SIZE GAS-Oil RATIO Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE 28. CORE DATA ~IUJ.:" D Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water KÛ\\ 111 ~~ . Oll-BBl GAs-McF WATER-BBl Oil GRAVITY-API (CORR) No core samples were taken. nrT ! n SEP 2 7 2002 Alaska on & Gas Cons. COmmission Anchorage RBDMS 8FL Form 10-407 Rev. 07-01-80 L Submit In Duplicate ( 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. SBF2-NA 5339' 3976' SBF1-NB 5380' 4008' SBE4-NC 5413' 4034' SBE2-NE 5426' 4044' SBE1-NF 5486' 4093' TSBD-OA 5529' 4129' TSBC 5562' 4157' TSBB-OB 5593' 4183' SBA5 5624' 4210' REceIVED SEP 2 7' 2002 Alaska Oi~& Gas Oons. COmmtsslon Anchorage 31. List of Attachments: Summary of Daily Drilling Reports, Surveys Date QC) - êÀfo -ore: MPS-11 i Well Number Permit No. I Approval No. Sondra Stewman, 564-4750 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 (OF, 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 OperatiionsSummary <Rep.ort Paget of3 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-11 MPS-11 DRILL +COMPLETE DOYON DOYON 141 Start: 6/24/2002 Rig Release: 6/29/2002 Rig Number: 141 Spud Date: 6/24/2002 End: 6/29/2002 Date From - To Hours Task Code NPT Phase Description of Operations 6/23/2002 12:00 - 13:00 1.00 MOB P PRE MOVE PIPE SHEDS - ROCKWASHER - 4 UTILITY MODULES OFF MPS 13 13:00 - 13:30 0.50 MOB P PRE MOVE SUB OFF WELL MPS 13 - WITH 40 STANDS OF 4" DP - BHA IN DERRICK 13:30 - 14:30 1.00 MOB P PRE FILL IN AND LEVEL SUBSIDE AREA AROUND WELL MPS-11 14:30 - 15:00 0.50 MOB P PRE LAY HERCULlTE - SUB MATTS 15:00 - 16:00 1.00 MOB P PRE MOVE SUB OVER WELL MPS-11 16:00 - 18:00 2.00 MOB P PRE MOVE 4 UTILITY MODULES IN PLACE - START SERVICE HOOK-UPS 18:00 - 18:30 0.50 MOB P PRE SET ROCKWASHER - BERM AROUND ROCKWASHER 18:30 - 19:00 0.50 MOB P PRE SET AND LEVEL PIPE SHEDS 19:00 - 20:00 1.00 MOB P PRE WORK ON RIG ACCEPTANCE LIST - GENERAL RIG UP - (ACCEPT RIG AT 20:00 HRS) 20:00 - 23:00 3.00 RIGU P PRE NIPPLE UP 21" DIVERTER SYSTEM - WHILE NIPPLE UP DIVERTER -TAKE ON 600 BBLS OF MUD FROM M /1 PLANT - MIX 140 BBLS ON RIG 23:00 - 00:00 1.00 RIGU P PRE LOAD PIPE SHED WITH 57 JOINTS 4" DP - 20 JOINTS 5" HWDP - CHANGE OUT SAVER SUB - STRAP DP / HWDP 6/24/2002 00:00 - 00:30 0.50 RIGU P PRE CON'T CHANGE OUT SAVER SUB 00:30 - 01 :30 1.00 RIGU P PRE CUT DRLG LINE 01 :30 - 02:00 0.50 RIGU P PRE FUNCTION TEST DIVERTOR - ACCUMULATOR TEST - WITNESS OF TEST WAIVED BY JOHN CRISP WITH AOGCC 02:00 - 04:00 2.00 DRILL P INT1 PICK UP 57 JOINTS 4" DRILL PIPE - 20 JOINTS 5" HWDP - STAND BACK IN DERRICK 04:00 - 04:30 0.50 DRILL P INT1 MAKE UP BHA 04:30 - 05:00 0.50 DRILL P INT1 FILL STACK WITH MUD - CIRC MUD DOWN FLOW LINE CHECK FOR LEAKS - ALL OK - HELD PRE SPUD MEETING WITH CREW AND SERVICE PERSONNEL 05:00 - 05:30 0.50 DRILL P INT1 RIG UP HOWCO SLICK LINE FOR RUNNING OF GYRO 05:30 - 10:30 5.00 DRILL N RREP INT1 PREPARE TO SPUD. TOP DRIVE FAILED. TROUBLE SHOOT PROBLEM. 10:30 - 14:00 3.50 DRILL P INT1 SPUD WELL MPS-11 i-DRILL FROM 112' TO 200' - SINGLE SHOT GYRO 160' - DRILL FROM 200' TO 377' - (KOP 250')- WOB 15K - RPM 60 - TO 2K ON BTM 2K OFF BTM - GPM 400 - PP ON BTM 1000 OFF BTM 900 - PU 45K - SO 45K - ROT 45K 14:00 - 14:30 0.50 DRILL P INT1 POH - STAND BACK 3 STANDS HWDP - PU 1 FLEX COLAR - MAKE UP TOO FLEX COLLARS - STAND BACK IN DERRICK 14:30 - 17:30 3.00 DRILL P INT1 PU MWD FROM DERRICK - SCRIBE - PROGRAM -INITIATE - PJSM - LOAD RA SOURCES - SHALLOW PULSE TEST - ORIENT - MAKE UP UBHO SUB - PU 2 IBS - TRIP IN HOLE TO 377' 17:30 - 00:00 6.50 DRILL P INT1 DIRECTIONAL DRILL FROM 377' TO 1024' - WOB 25K TO 30K - RPM 60 - TO 2K ON BTM 2K OFF BTM - GPM 400 - PP ON BTM 1450 OFF BTM 1250 - PU 60K - SO 60K - ROT 60K 6/25/2002 00:00 - 11 :30 11.50 DRILL P INT1 DIRECTIONAL DRILL FROM 1024' TO 2800' - WOB 30K - RPM 60 TO ON BTM 4K OFF BTM 1K - GPM 410 - PP ON BTM 1700 OFF BTM 1500 - PU 74K - SO 70K - ROT 74K ART 2.75 AST 4.5 11 :30 - 13:00 1.50 DRILL P INT1 CIRC BOTTOMS UP 3 TIMES, STANDING BACK ONE Printed: 7/10/2002 12:17:25 PM (' Page 2 of 3 SF' Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date MPS-11 MPS-11 DRILL +COMPLETE DOYON DOYON 141 6/25/2002 6/26/2002 6/27/2002 Start: 6/24/2002 Rig Release: 6/29/2002 Rig Number: 141 Spud Date: 6/24/2002 End: 6/29/2002 From - To Hours Task Code 11 :30 -13:00 1.50 DRILL P INT1 13:00 - 15:00 2.00 DRILL P INT1 15:00 - 16:00 1.00 DRILL P INT1 16:00 - 17:30 1.50 DRILL P INT1 17:30 - 19:00 1.50 DRILL P INT1 19:00 - 19:30 0.50 DRILL P INT1 19:30 - 20:30 1.00 DRILL P INT1 20:30 - 22:00 1.50 DRILL N SFAL INT1 22:00 - 00:00 2.00 DRILL P INT1 00:00 - 19:30 19.50 DRILL P INT1 19:30 - 20:30 1.00 CASE P INT1 20:30 - 21 :00 0.50 CASE P INT1 21 :00 - 00:00 3.00 CASE P INT1 00:00 - 04:30 4.50 CASE P INT1 04:30 - 05:30 1.00 CASE P INT1 05:30 - 06:30 1.00 CASE P INT1 06:30 - 08:00 1.50 CASE P INT1 08:00 - 10:30 2.50 CASE P INT1 10:30 - 14:30 4.00 CASE P INT1 14:30 - 17:30 17:30 - 20:30 3.00 CASE P 3.00 EVAL P 20:30 - 00:00 3.50 CASE P INT1 6/28/2002 00:00 - 03:30 3.50 CASE P INT1 03:30 - 06:30 3.00 CASE P INT1 06:30 - 07:30 1.00 CASE N CEMT INT1 07:30 - 10:00 2.50 CASE N CEMT INT1 INT1 INT1 STAND PER BOTTOMS UP PUMPING OUT TO HWP, FULL DRILLING RATE PULL BHA RUN IN BHA, PJSM, REMOVE RA SOURCES, RE INSTALL RA AND TEST MWD TRIP IN, WIPE TIGHT SPOTS @ 1320 AND 1900 WASH AND REAM 90 FT. TO BOTTOM DIRECTIONAL DRILL FROM 2800' TO 2984' - WOB 30K - RPM 80 500 GPM 2500 PSI PULL 5 SDS. AND CHANGE OUT SAVER SUB ON TOP DRIVE, TRIP IN. DIRECTIONAL DRILL FROM 2894' TO 3264 - WOB 30K - RPM 80, 500 GPM 2600 PSI TO 5000 ART 1 AST .25 DIRECTIONAL DRILL FROM 3264' TO TD 5939' - WOB 30K - RPM 100, 500 GPM 3200 PSI TO 6000 CIRC ONE BOTTOMS UP PUMP OUT TO 5640 WITH FULL DRLG RATE MAD PASS FROM 5380 TO 5640 @ 100 FT PER HR, 100 RPMS, 500 GPM, 3200 PSI PUMPING OUT TO HWDP WITH 500 GPM TRIPPED IN HOLE WITH DRILLING ASSEMBLY AND SAT DOWN AT 1900'. HAD TO WASH AND REAM WITH 300 GPM AND 70 ROTARY FROM 1900' TO 2300'. TAKING 20K DOWN WEIGHT RUNNING IN WITHOUT PUMP. CIRCULATED BOTTOMS UP. HAD 2 INCHES OF SAND ACROSS SHAKERS FROM 2300'. RAN IN HOLE TO 5939' WITH NO PROBLEMS. CIRCULATED 3 BOTTOMS UP. 520 GPM AT 3800 PSI AND 100 RPM. PUMPED 2 HIGH VIS SWEEPS AND CIRCULATED HOLE CLEAN. PULLED 5 STANDS WET. MONITORED HOLE. SLUG DRILL PIPE AND PULLED OUT OF HOLE. HAD ONE PULL TO 10K AT 1600'. WORKED THROUGH TIGHT SPOT AND FINISHED PULLING OUT OF HOLE. LD BHA AND RA SOURCES, DOWNLOAD MWD RIG UP SCHLUMBERGER AND RUNNING SIDE WALL CORES LOGGING TOOLS STOPPED @ 1,700 FT PULL AND LAY DOWN TOOLS PJSM, RIG UP AND RUNNING 7" 26# L-80 CSG TO 2600' RUNNING 7" 26# L-80 CSG FROM 2600' TO 5929, TOTAL JTS RUN 147, LANDED ON HANGER WITH 85,000#, RIG DOWN FRANKS TOOL, RIG UP CEMENTING HEAD CIRC CSG WITH 282 GALS MIN 400 PSI, REDUCE VIS FOR CEMENT JOB. HELD PJSM ON CEMENTING. PUMPED 10 BBLS WATER-TEST LINES TO 3500 PSI-PUMP 40 BBLS WATER-PUMPED 31 BBLS OF 10.2 PPG ALPHA SPACER. LOST HYRAULlC PRESSURE IN HALLIBURTON PUMP TRUCK. TROUBLE SHOOT PROBLEM. UNABLE TO CONTINUE JOB. SWITCHED BACK TO RIG PUMPS AND CIRCULATED WATER AND ALPHA SPACER OUT OF HOLE. CIRCULATED AND CONDITIONED MUD WAITING ON HALLIBURTON TO Printed: 7/10/2002 12:17:25 PM ( Page.3.of3 Operations Summary Rep.ort Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-11 MPS-11 DRILL +COMPLETE DOYON DOYON 141 Start: 6/24/2002 Rig Release: 6/29/2002 Rig Number: 141 Spud Date: 6/24/2002 End: 6/29/2002 Date From.;. To Hours Task Code NPT Phase Description of Operations 6/28/2002 07:30 - 10:00 2.50 CASE N CEMT INT1 REPAIR PUMP TRUCK AND SEND OUT NEW ALPHA SPACER. AFTER ALPHA SPACER WAS CIRCULATED OUT OF HOLE, LOTS OF SAND CONTINUED ACROSS SHAKER. 10:00 - 14:00 4.00 CASE P INT1 PUMPED 10 BBLS WATER-TEST LINES TO 3500 PSI-PUMP 40 BBLS WATER-50 BBLS OF 10.2 PPG ALPHA SPACER-DROPPED BOTTOM PLUG-1290 SXS (953 BBLS) OF PERMAFROST L CEMENT MIXED AT 10.7 PPG WITH A YIELD OF 4.14 CFT/SX. PUMPED LEAD CEMENT UNTIL 10.7 PPG LEAD RETURNED TO SURFACE. FOLLOWED LEAD SLURRY WITH 500 SXS (112 BBLS) OF PREMIUM CEMENT + 1 % CALCIUM CHLORIDE + .3% HALAD 344 + .2% CFR-3 MIXED IN A 15.8 PPG SLURRY WITH A YIELD OF 1.15 CFT/SX. WASHED CEMENTING LINES. HEAVY AMOUNTS OF SAND CONTINUED ACROSS SHAKER. 14:00 - 15:00 1.00 CASE P INT1 KICKED OUT BOTTOM PLUG WITH 30 BBLS OF DIESEL AND DISPLACED CEMENT WITH 194 BBLS OF 9.2 PPG BRINE. BUMPED PLUG WITH 2300 PSI (1000 PSI OVER CIRCULATING PRESSURE) AT 1500 HRS. BLED OFF PRESSURE AND FLOATS HELD. HAD FULL RETURNS THROUGH OUT JOB AND CIRCULATED 336 BBLS OF CEMENT TO SURFACE. 15:00 - 16:00 1.00 CASE P INT1 RIG DOWN LANDING JT. AND CEMENTING HEAD,CLEAR FLOOR 16:00 - 18:30 2.50 RIGD P COMP NIPPLE DOWN DIVERTER 18:30 - 20:00 1.50 RIGD P COMP NIPPLE UP GEN VI DUAL STRING HEAD AND TEST TO 1000# 20:00 - 20:30 0.50 RIGD P COMP RUN 4.5 GUIDE SHOE, 1 JT 4.5 TUBING, TUBING HANGER AND BACK PRESSURE VALVE. 20:30 - 22:30 2.00 RIGD P COMP NIPPLE UP 4.5 TREE, TEST ADAPER VOID TO 5000#, TEST TREE & BPV TO 500 PSI FOR 10 MIN. 22:30 - 00:00 1.50 CASE P INT1 LAYING DOWN DRILL PIPE OUT OF DERRICK 6/29/2002 00:00 - 02:00 2.00 CASE P INT1 FINISH LAYING DOWN PIPE OUT OF DERRICK RIG RELEASE @ 02:006/29/2002 Printed: 7/10/2002 12:17:25 PM Page 1 of 2 BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-11 MPS-11 COMPLETION DOYON DOYON 141 Task Code N PT Phase 8/27/2002 06:00 - 12:00 6.00 RIGU P 12:00 - 13:00 1.00 WHSUR P 13:00 - 15:00 2.00 BOPSURP 15:00 - 18:30 3.50 BOPSUR P 18:30 - 19:30 1.00 CLEAN P 19:30 - 20:00 0.50 CLEAN P 20:00 - 20:30 0.50 CLEAN P 20:30 - 00:00 3.50 CLEAN P 00:00 - 01 :00 1.00 CLEAN P 01 :00 - 01 :30 0.50 CLEAN P 01 :30 - 03:00 1.50 CLEAN P 03:00 - 06:00 3.00 ZONISO P 06:00 - 10:30 4.50 ZONISO P 10:30 - 12:00 1.50 ZONISO P PRE COMP COMP COMP 8/28/2002 COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP 12:00 -13:00 1.00 ZONISO P COMP 13:00 - 14:30 1.50 ZONISO P COMP 14:30 - 21 :00 6.50 CLEAN P COMP 21 :00 - 21 :30 0.50 CLEAN P COMP 21 :30 - 22:30 1.00 CLEAN P COMP 22:30 - 00:00 1.50 CLEAN P COMP 8/29/2002 00:00 - 00:30 0.50 CLEAN P COMP 00:30 - 01 :00 0.50 EVAL P COMP 01 :00 - 06:00 5.00 EVAL P COMP 06:00 - 07:00 1.00 EVAL P COMP 07:00 - 11 :30 4.50 PERF P COMP 11 :30 - 12:00 0.50 PERF P COMP 12:00 - 14:00 2.00 EVAL P COMP 14:00 -15:00 1.00 EVAL P COMP 15:00 - 18:30 3.50 EVAL P COMP 18:30 - 19:30 1.00 BOPSURP COMP 19:30 - 00:00 4.50 RUNCOrvP COMP Start: Rig Release: Rig Number: 141 Spud Date: End: 8/31/2002 8/26/2002 Description....of.Operations MI/RU SAFE OUT EQUIPMENT/ACCEPT RIG @ 1200 HRS. 8/27/2002 CHECK FOR PRESSURE & NIPPLE DN TREE NIPPLE UP BOP TEST BOP TO 250/3500 (TEST WAIVED BY JOHN CRISP WITH AOGC. MU 6" BIT & SCRAPER & RIH TO 750' TAG ICE. CIRC DIESEL CAP OFF WELLBORE ROTATE & WASH THROUGH ICE PLUG 750' TO 847' CONTINUE TO RIH WITH BIT & SCRAPER TO 5838' CIRC WELL BORE WITH 9.1 PPG. BRINE TEST CSG. TO 3500 PSI. POOH & LAY DN SCRAPER & BIT RIG SWS & RIH & GET ON DEPTH WITH SCMT LOG & ADD SQZ. PERF. AT 5500--5502' POOH & RIG DN SWS. MU HES CMT. RETAINER & RIH & SET @ 5475' & ESTABLISH INJECTION RATE UP TO 4-BPM 1550 PSI. RIG HES & MIX & PUMP 16-3/8" BBL. CL. "G" PUMPED FIRST 10 BBL. AT 4-BPM AVG. PSI. 1250 PSI. CMT. AT PERFS. PSI. INCREASE TO 1350 PSI. LAST 5-BBL. CMT. WAS DONE IN A HESITATION SQZ. METHOD THAT AT THE END GAVE A STATIC SQZ. PSI. OF 925 PSI. CLOSE ANNULAR & PSI. ANNULUS TO 600 & STING OUT OF RETAINER & REVERSE CIRC. 2-BOTTOMS UP CIRC APP. 1/2 BBL. CMT. TO PITS. & TEST RETAINER TO 2500 PSI. & CHART FOR 10-MINUTES. OK POOH & LAY DN RETAINER SETTING TOOL. MU BIT +SCRAPER+2-JUNK BASKETS & RIH @ TAG RETAINER @ 5472' & DRILL OUT SAME TO 5478' FREE PIPE RIH TO 5831' CIRC WELL BORE CLEAN POOH WITH BIT & SCRAPER POOH & LD BIT & SCRAPER REMOVE FLOW NIPPLE & RIG UP SHOOTING FLG. RIG SWS & RIH & RUN SCMT LOG 5700--5200' & TRANSFER INFORMATION TO TECH REPS IN SWS OFFICE & BP ODE MU LUB & TEST TO 500 PSI. & RIH & CORRELATE GUN#1 IN & PERF. 5600--5615' & RUN GUN #2 & CORRELATE IN & PERF 5535'--5550' 4-SPF POOH & RIG DOWN SWS. & RUN 6" GR/JB TO 5650' NIPPLE DN SHOOTING FLG. & NU FLOW NIPPLE. MU HES CHAMP PKR & RIH TO 5475' SET PKR & ESTABLISH INJECTION RATE IN "OA" SAND AT 2-BPM 1050 PSI. FOR 10-BBL. NO COMMUNICATION & INJECT INTO "OB" SANDS UP TO 4-BPM 1500 PSI. & SEEN NO COMMUNICATION. RELEASE PKR & POOH LAYING DN 3.5" DP & CHAMP PKR. SET TEST PLUG & CHG. RAMS TO 2-3/8" & TEST TO 250/2500 PSI. RIG TBG. TOOLS & MU & RIH WITH 174-JTS. 2-3/8" 1ST Printed: 9/4/2002 10:58:04 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ( (' Page 2 of2 BP Operations Summary Rep,ort MPS-11 MPS-11 COMPLETION DOYON DOYON 141 Hours.. . Task Code N PT Phase 8/29/2002 19:30 - 00:00 4.50 RUNCOfvP COMP 8/30/2002 00:00 - 01 :30 1.50 RUNCOfvP COMP 01 :30 - 06:00 4.50 RUNCOfvP COMP 06:00 - 07:00 1.00 RUNCOfvP COMP 07:00 - 08:00 1.00 BOPSUR P COMP 08:00 - 09:00 1.00 BOPSURP COMP 09:00 - 14:30 5.50 RUNCOfvP COMP 14:30 - 20:30 6.00 RUNCOfvP COMP 20:30 - 23:00 8/31/2002 23:00 - 00:00 00:00 - 02:30 02:30 - 04:00 04:00 - 05:00 05:00 - 06:00 06:00 - 07:00 07:00 - 08:00 2.50 RUNCOfvP COMP 1.00 BOPSURP 2.50 WHSUR P 1.50 CHEM P COMP COMP COMP 1.00 RUNCOfvP COMP 1.00 RUNCOfvP COMP 1.00 RUNCOfvP COMP 1.00 RUNCOfvP COMP Start: Rig Release: Rig Number: 141 Spud Date: End: 8/31/2002 8/26/2002 TBG. POOH & STAND 58- STDS. IN DERRICK RIH WITH 174 JTS. FROM SHED POOH STANDING 58 STDS. IN DERRICK SET TEST PLUG & CHG. RAMS TO DUAL 2-3/8" & TEST TO 250/2500 PULL TEST PLUG. RIH WITH DUAL COMPLETION TO SETTING DEPTH @ 5589' RIG SWS & HAD PROBLEM WITH GR/CCL GETTING STARTED HAD TO RE-ORDER GR/CCL FROM PRUDHOE & RIH & CORRELATE PKRS INTO POSITION USING SCMT LOG. & RIG DOWN SWS. SPACE OUT & LAND HANGER (HAD TROUBLE GETTING DUAL HANGER TO GO DOWN CHG ENEGERIZING ELEMENT & CLEAN FREE OF PIPE DOPE AND HANGER LANDED GOOD. SET TWC & TEST & NIPPLE DN BOP NIPPLE UP & TEST TREE TO 250/5000 (OK) RIG LINES TO TREE & TEST TO 4200 PSI. & PUMP 100 BBL. 9.1 PPG. BRINE TREATED WITH COREXIT 25 GA./100 BBL. FLUID & REVERSE IN & FOLLOW WITH 80 BBL DIESEL. DROP PACKER SETTING BALL ON LONG STRING &U-TUBE DIESEL TO LONG & SHORT STRING & WHEN BALL ON SEAT PSI. LONG STRING TO 2500 PSI. & MONITOR FOR 30-MIN (OK) & SHEAR BALL OUT @ 4100 PSI. BLEED TBG. TO 0 & PSI. ANNULUS TO 2000 PSI. & MONITOR FOR 30- MIN GOOD TEST. INJECT ON SHORT STRING @ 2-BPM 1400 PSI. NO COMMUNICATIONS & DROP BALL & PSI. TBG. TO 2500 PSI. FOR 30-MIN MONITOR SAME (OK) SHEAR BALL OUT @ 3600 PSI. SET TWC'S IN BOTH STRINGS & RIG DN LINES & SECURE CELLAR AREA. RIG RELEASED @ 0800 HRS. 8/31/2002 Printed: 9/4/2002 10:58:04 AM AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPS-11 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: O?Od-/f3 22-Jul-02 0.00' MD , MD (if applicable) 5,939.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. ,Allen Survey Manager Attachment( s) RECEIVED JUL 252002 Alaska Oil & Gas cons. CommiStion And\orage BP EXPLORATION (ALASKA) IN2E.r:.I~' iT!V,: Milne Point Unit BPXA Milne Point MPS, Slot MPS-11 MPS-11 Job No. AKZZ22101, Surveyed: 26 June, 2002 SUR VE Y R E PO R T 22 July, 2002 Your Ref: API 500292309200 Surface Coordinates: 6000006.08 N, 565931.74 E (70024' 37.6408" N, 149027'47.2771" W) Kelly Bushing: 66. 60ft above Mean Sea Level sper-'I''.:J-SUI! D Rf~ ~ I ¡\ftf . S IS RVI c: S$ A Halliburton Company Survey Ref: svy10147 Sperry-Sun Drilling Services Survey Report for MPS-11 Your Ref: API 500292309200 Job No. AKZZ22101, Surveyed: 26 June, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-5ea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inel. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 0.00 0.000 0.000 -66.60 0.00 0.00 N 0.00 E 6000006.08 N 565931.74 E 0.00 Tolerable Gyro 110.00 0.300 244.000 43.40 110.00 0.138 0.26W 6000005.95 N 565931.48 E 0.273 -0.07 195.00 0.100 180.000 128.40 195.00 0.308 0.46 W 6000005.78 N 565931.28 E 0.319 -0.06 AK-6 BP _IFR-AK 319.57 0.930 102.620 252.96 319.56 0.638 0.53 E 6000005.46 N 565932.27 E 0.733 0.82 409.51 1.660 113.100 342.88 409.48 1.308 2.44 E 6000004.80 N 565934.19 E 0.850 2.55 498.53 2.520 112.170 431.84 498.44 2.548 5.44 E 6000003.59 N 565937.20 E 0.967 5.42 588.73 4.070 128.090 521.89 588.49 5.278 9.79 E 6000000.90 N 565941.58 E 1.980 10.30 680.12 6.200 139.790 612.91 679.51 11.04 8 15.53 E 5999995.18 N 565947.37 E 2.585 18.40 769.55 9.160 143.250 701.53 768.13 20.438 22.91 E 5999985.85 N 565954.83 E 3.349 30.34 864.52 11 . 190 148.220 795.00 861.60 34.32 8 32.29 E 5999972.04 N 565964.33 E 2.327 47.02 957.85 15.310 150.060 885.83 952.43 52.71 8 43.21 E 5999953.76 N 565975.41 E 4.437 68.15 1051.81 20.260 151.000 975.27 1041.87 77.708 57.30 E 5999928.89 N 565989.72 E 5.277 96.39 1144.79 21.740 149.580 1062.07 1128.67 106.63 8 73.82 E 5999900.11 N 566006.50 E 1.683 129.22 1238.10 21.140 147.670 1148.93 1215.53 135.758 91.57 E 5999871.14 N 566024.51 E 0.986 162.98 1331.59 22.330 139.250 1235.79 1302.39 163.468 112.19 E 5999843.62 N 566045.37 E 3.566 197.47 1424.94 25.510 131.100 1321.13 1387.73 190.128 138.92 E 5999817.19 N 566072.34 E 4.906 235.05 1518.62 25.120 130.950 1405.82 1472.42 216.41 8 169.14 E 5999791.17 N 566102.79 E 0.422 274.57 1612.22 24.550 132.120 1490.76 1557.36 242.48 8 198.57 E 5999765.37 N 566132.45 E 0.804 313.41 1705.48 25.240 138.770 1575.37 1641.97 270.43 8 226.05 E 5999737.66 N 566160.17 E 3.090 352.46 1798.57 25.760 139.130 1659.39 1725.99 300.658 252.37 E 5999707.67 N 566186.76 E 0.583 392.52 -~~../ 1892.89 27.680 141.960 1743.64 1810.24 333.41 8 279.29 E 5999675.15 N 566213.96 E 2.442 434.92 1986.56 31.690 142.080 1825.00 1891.60 369.97 8 307.83 E 5999638.84 N 566242.82 E 4.281 481.28 2080.30 37.510 140.870 1902.13 1968.73 411.57 S 341.00 E 5999597.54 N 566276.36 E 6.252 534.48 2173.53 41.950 141.500 1973.81 2040.41 458.00 8 378.33 E 5999551.44 N 566314.09 E 4.782 594.05 2266.57 43.140 141.850 2042.36 2108.96 507.35 8 417.34 E 5999502.43 N 566353.54 E 1.304 656.94 2359.60 45.250 143.070 2109.06 2175.66 558.788 456.84 E 5999451.36 N 566393.49 E 2.445 721.75 2453.29 48.940 142.630 2172.83 2239.43 613.468 498.28 E 5999397.04 N 566435.42 E 3.953 790.30 2546.67 54.030 141.860 2230.96 2297.56 671.208 543.01 E 5999339.70 N 566480.66 E 5.489 863.30 2640.17 55.190 142.700 2285.11 2351.71 731.498 589.64 E 5999279.82 N 566527.82 E 1.441 939.49 2732.14 53.170 143.250 2338.93 2405.53 791.02 8 634.55 E 5999220.69 N 566573.25 E 2.249 1013.98 22 July, 2002 - 13:25 Page 2 of4 DrillQuest 2.00.09.003 Sperry-Sun Drilling Services Survey Report for MPS-11 Your Ref: API 500292309200 Job No. AKZZ22101, Surveyed: 26 June, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/1 OOft) 2823.83 53.280 143.370 2393.82 2460.42 849.92 8 678.43 E 5999162.19 N 566617.65 E 0.159 1087.33 2918.33 53.970 140.900 2449.87 2516.47 909.97 8 725.13 E 5999102.55 N 566664.88 E 2.227 1163.38 3010.58 55.650 139.010 2503.04 2569.64 967.67 8 773.64 E 5999045.28 N 566713.90 E 2.474 1238.76 3104.16 55.570 138.650 2555.89 2622.49 1025.80 8 824.48 E 5998987.60 N 566765.24 E 0.329 1315.95 ~- 3197.18 54.750 139.320 2609.03 2675.63 1083.41 8 874.58 E 5998930.44 N 566815.85 E 1.061 1392.27 3290.86 54.110 139.490 2663.53 2730.13 1141.278 924.17 E 5998873.02 N 566865.95 E 0.699 1468.46 3384.27 54.590 140.400 2717.97 2784.57 1199.368 973.01 E 5998815.35 N 566915.30 E 0.944 1544.36 3477.47 55.070 140.140 2771.65 2838.25 1257.968 1021.71 E 5998757.19 N 566964.51 E 0.563 1620.54 3570.92 55.120 140.440 2825.13 2891.73 1316.91 8 1070.67 E 5998698.67 N 567013.99 E 0.269 1697.18 3664.57 55.150 139.940 2878.66 2945.26 1375.94 8 1119.87 E 5998640.08 N 567063.71 E 0.439 1774.02 3757.98 55.720 140.130 2931.66 2998.26 1434.898 1169.27 E 5998581.56 N 567113.64 E 0.633 1850.94 3851.23 53.610 138.780 2985.59 3052.19 1492.708 1218.71 E 5998524.19 N 567163.58 E 2.552 1926.99 3944.90 53.500 138.690 3041.23 3107.83 1549.34 8 1268.41 E 5998468.00 N 567213.78 E 0.141 2002.31 4038.17 54.580 138.360 3096.00 3162.60 1605.90 8 1318.41 E 5998411.88 N 567264.27 E 1.193 2077.76 4131.61 55.100 137.610 3149.81 3216.41 1662.66 8 1369.54 E 5998355.58 N 567315.90 E 0.860 2154.08 4224.55 53.760 137.560 3203.87 3270.4 7 1718.478 1420.53 E 5998300.22 N 567367.38 E 1.442 2229.58 4317.78 52.200 140.150 3260.01 3326.61 1774.508 1469.51 E 5998244.62 N 567416.86 E 2.778 2303.98 4411.49 52.330 139.790 3317.36 3383.96 1831.258 1517.18E 5998188.29 N 567465.02 E 0.334 2378.09 4505.24 52.040 139.150 3374.84 3441.44 1887.54 8 1565.30 E 5998132.43 N 567513.65 E 0.622 2452.14 4598.12 51.490 140.270 3432.32 3498.92 1943.198 1612.48 E 5998077.20 N 567561.31 E 1.117 2525.08 4692.07 52.760 140.130 3490.00 3556.60 2000.168 1659.95 E 5998020.65 N 567609.28 E 1.357 2599.24 4785.69 54.010 140.530 3545.84 3612.44 2058.00 8 1707.92 E 5997963.23 N 567657.76 E 1.379 2674.38 4878.59 54.820 138.980 3599.90 3666.50 2115.668 1756.73 E 5997906.01 N 567707.08 E 1.613 2749.93 4972.29 51.560 138.550 3656.04 3722.64 2172.088 1806.17 E 5997850.03 N 567757.01 E 3.499 2824.90 5065.25 48.200 138.000 3715.93 3782.53 2225.138 1853.47 E 5997797.40 N 567804.78 E 3.643 2895.93 5159.06 45.690 137.990 3779.97 3846.57 2276.06 8 1899.33 E 5997746.88 N 567851.09 E 2.676 2964.41 5252.35 44.040 138.590 3846.09 3912.69 2325.188 1943.12 E 5997698.14 N 567895.31 E 1.826 3030.17 5345.22 41.320 141.050 3914.36 3980.96 2373.258 1983.76 E 5997650.43 N 567936.37 E 3.435 3093.10 5439.40 36.270 141.830 3987.74 4054.34 2419.368 2020.54 E 5997604.65 N 567973.56 E 5.387 3152.08 5532.57 31.640 142.410 4065.00 4131.60 2460.41 8 2052.50 E 5997563.88 N 568005.88 E 4.982 3204.09 22 July, 2002 - 13:25 Page 30f4 DrillQuestLOQO~003 BP EXPLORATION (ALASKA) INC. Milne Point Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 5625.57 29.610 141.440 4145.03 4211.63 5718.89 29.200 141.320 4226.32 4292.92 5812.22 29.150 141.650 4307.81 4374.41 5871.17 28.700 141.300 4359.41 4426.01 ~- 5939.00 28.700 141.300 4418.91 4485.51 Sperry-Sun Drilling Services Survey Report for MPS-11 Your Ref: API 500292309200 Job No. AKZZ22101, Surveyed: 26 June, 2002 BPXA Milne Point MPS Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (0/100ft) 2497.71 S 2081.71 E 5997526.84 N 568035.41 E 2.246 3251.44 2533.51 S 2110.30 E 5997491.30 N 568064.33 E 0.444 3297.25 2569.11 S 2138.63 E 5997455.95 N 568092.97 E 0.180 3342.74 2591.42 S 2156.39 E 5997433.80 N 568110.92 E 0.816 3371.25 2616.84 S 2176.76 E 5997408.56 N 568131.51 E 0.000 3403.82 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 140.440° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 5939.00ft., The Bottom Hole Displacement is 3403.84ft., in the Direction of 140.245° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 5939.00 4485.51 2616.84 S 2176.76 E Survey tool program for MPS-11 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 195.00 0.00 195.00 195.00 5939.00 195.00 Tolerable Gyro 4485.51 AK-6 BP _IFR-AK 22 July, 2002 - 13:25 Comment Projected Survey Page 4 of4 DrillQuest 2.00.09.003 QtÞl-113 22-Jul-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPS-11 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 , M D (if applicable) 5,939.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED JUL 2 5 2002 Alaska Oil & Gas Cons. ColllfDÌ8ÎOn Anchorage BP EXPLORA TION (ALASKA) INC. '~' Milne Point Unit BPXA Milne Point MPS, Slot MPS-11 MPS-11 MWD Job No. AKMW22101, Surveyed: 26 June, 2002 SUR VE Y R E PO R T 22 July, 2002 Your Ref: API 500292309200 Surface Coordinates: 6000006.08 N, 565931.74 E (70024' 37.6408" N, 149027'47.2771" W) Kelly Bushing: 66. 60ft above Mean Sea Level "!:~. spe""Y-SUf1 [fA. L CTNG sêfAV I c: e's A Halliburton Company Survey Ref: svy10148 Sperry-Sun Drilling Services Survey Report for MPS-11 MWD Your Ref: API 500292309200 Job No. AKMW22101, Surveyed: 26 June, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates. Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 0.00 0.000 0.000 -66.60 0.00 0.00 N 0.00 E 6000006.08 N 565931.74 E 0.00 Tolerable Gyro 110.00 0.300 244.000 43.40 110.00 0.138 0.26W 6000005.95 N 565931.48 E 0.273 -0.07 195.00 0.100 180.000 128.40 195.00 0.308 0.46 W 6000005.78 N 565931.28 E 0.319 -0.06 MWD Magnetic 319.57 0.930 102.690 252.96 319.56 0.638 0.53 E 6000005.46 N 565932.27 E 0.733 0.82 .~~. 409.51 1.660 113.160 342.88 409.48 1.308 2.44 E 6000004.80 N 565934.19 E 0.850 2.56 498.53 2.520 112.320 431.84 498.44 2.558 5.43 E 6000003.58 N 565937.20 E 0.967 5.43 588.73 4.070 128.270 521.89 588.49 5.298 9.78 E 6000000.88 N 565941.57 E 1.981 10.31 680.12 6.200 139.860 612.91 679.51 11.078 15.51 E 5999995.15 N 565947.35 E 2.581 18.41 769.55 9.160 143.380 701.53 768.13 20.48 8 22.87 E 5999985.81 N 565954.79 E 3.350 30.35 864.52 11. 190 148.290 795.00 861.60 34.39 8 32.22 E 5999971.98 N 565964.27 E 2.323 47.03 957.85 15.310 150.280 885.83 952.43 52.80 8 43.10 E 5999953.66 N 565975.30 E 4.441 68.15 1051.81 20.260 151.240 975.27 1041.87 77.858 57.08 E 5999928.74 N 565989.51 E 5.277 96.37 1144.79 21.740 149.810 1062.07 1128.67 106.858 73.49 E 5999899.89 N 566006.17 E 1.684 129.18 1238.10 21.140 147.950 1148.93 1215.53 136.05 8 91.11 E 5999870.84 N 566024.05 E 0.972 162.91 1331.59 22.330 139.450 1235.79 1302.39 163.84 8 111.61 E 5999843.23 N 566044.79 E 3.596 197.39 1424.94 25.510 132.660 1321.13 1387.73 190.958 137.93 E 5999816.36 N 566071.35 E 4.501 235.06 1518.62 25.120 131.860 1405.81 1472.41 217.898 167.57 E 5999789.68 N 566101.23 E 0.554 274.71 1612.22 24.550 132.590 1490.76 1557.36 244.30 8 196.69 E 5999763.52 N 566130.58 E 0.691 313.61 1705.48 25.240 139.390 1575.37 1641.97 272.52 8 223.90 E 5999735.55 N 566158.04 E 3.156 352.70 1798.57 25.760 139.150 1659.39 1725.99 302.88 8 250.05 E 5999705.42 N 566184.45 E 0.570 392.76 1892.89 27.680 142.280 1743.64 1810.24 335.728 276.86 E 5999672.82 N 566211.55 E 2.523 435.16 .<-. 1986.56 31.690 142.270 1825.00 1891.60 372.40 8 305.24 E 5999636.38 N 566240.26 E 4.281 481.51 2080.30 37.510 140.490 1902.13 1968.73 413.938 338.49 E 5999595.15 N 566273.87 E 6.301 534.71 2173.53 41.950 140.940 1973.81 2040.41 460.05 8 376.21 E 5999549.37 N 566311.99 E 4.772 594.28 2266.57 43.140 141.360 2042.35 2108.95 509.05 8 415.67 E 5999500.72 N 566351.88 E 1.315 657.19 2359.60 45.250 142.690 2109.05 2175.65 560.17 8 455.55 E 5999449.95 N 566392.22 E 2.477 722.00 2453.29 48.940 142.840 2172.82 2239.42 614.80 8 497.07 E 5999395.69 N 566434.22 E 3.940 790.56 2546.67 54.030 141.830 2230.96 2297.56 672.60 8 541.72 E 5999338.28 N 566479.37 E 5.516 863.56 2640.17 55.190 142.790 2285.10 2351.70 732.92 8 588.32 E 5999278.38 N 566526.50 E 1.497 939.74 2732.14 53.170 142.980 2338.93 2405.53 792.39 8 633.31 E 5999219.31 N 566572.02 E 2.203 1014.25 22 July, 2002 - 13:27 Page 20f4 DrillQuest 2.00.09.003 Sperry-Sun Drilling Services Survey Report for MPS-11 MWD Your Ref: API 500292309200 Job No. AKMW22101, Surveyed: 26 June, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 2823.83 53.280 143.570 2393.82 2460.42 851.25 S 677.23 E 5999160.84 N 566616.46 E 0.529 1087.60 2918.33 53.970 141.430 2449.87 2516.47 911.61S 723.55 E 5999100.90 N 566663.31 E 1.964 1163.63 3010.58 55.650 139.350 2503.03 2569.63 969.67 S 771.62 E 5999043.26 N 566711.89 E 2.591 1239.01 3104.16 55.570 139.010 2555.89 2622.49 1028.11 S 822.10 E 5998985.27 N 566762.88 E 0.312 1316.21 3197.18 54.750 139.570 2609.03 2675.63 1085.98 S 871.90 E 5998927.84 N 566813.19 E 1.011 1392.54 3290.86 54.110 139.730 2663.52 2730.12 1144.05 S 921.23 E 5998870.20 N 566863.04 E 0.697 1468.74 3384.27 54.590 140.770 2717.97 2784.57 1202.41 S 969.77 E 5998812.28 N 566912.08 E 1.040 1544.64 3477.47 55.070 140.420 2771.65 2838.25 1261.28 S 1018.13 E 5998753.84 N 566960.96 E 0.600 1620.82 3570.92 55.120 140.570 2825.12 2891.72 1320.41 S 1066.88 E 5998695.14 N 567010.24 E 0.142 1697.46 3664.57 55.150 140.330 2878.66 2945.26 1379.66 S 1115.81 E 5998636.33 N 567059.69 E 0.213 1774.30 3757.98 55.720 140.570 2931.65 2998.25 1438.97 S 1164.79 E 5998577.45 N 567109.19 E 0.646 1851.22 3851.23 53.610 139.170 2985.58 3052.18 1497.13 S 1213.80 E 5998519.72 N 567158.71 E 2.573 1927.28 3944.90 53.500 138.990 3041.23 3107.83 1554.07 S 1263.16 E 5998463.22 N 567208.57 E 0.194 2002.61 4038.17 54.580 138.650 3096.00 3162.60 1610.89 S 1312.87 E 5998406.84 N 567258.78 E 1.195 2078.08 4131.61 55.100 137.970 3149.81 3216.41 1667.93 S 1363.68 E 5998350.25 N 567310.09 E 0.815 2154.41 4224.55 53.760 138.020 3203.87 3270.47 1724.11 S 1414.27 E 5998294.52 N 567361.17 E 1.442 2229.94 4317.78 52.200 140.730 3260.01 3326.61 1780.58 S 1462.74 E 5998238.48 N 567410.14 E 2.861 2304.35 4411.49 52.330 140.420 3317.36 3383.96 1837.83 S 1509.80 E 5998181.65 N 567457.71 E 0.296 2378.46 4505.24 52.040 140.360 3374.84 3441.44 1894.89 S 1557.02 E 5998125.01 N 567505.43 E 0.313 2452.52 4598.12 51.490 140.900 3432.32 3498.92 1951.29 S 1603.30 E 5998069.02 N 567552.20 E 0.748 2525.48 4692.07 52.760 140.890 3490.00 3556.60 2008.83 S 1650.07 E 5998011.89 N 567599.48 E 1.352 2599.63 '- 4785.69 54.010 142.690 3545.84 3612.44 2067.88 S 1696.54 E 5997953.26 N 567646.4 7 E 2.041 2674.75 4878.59 54.820 139.910 3599.90 3666.50 2126.82 S 1743.78 E 5997894.73 N 567694.23 E 2.585 2750.28 4972.29 51.560 139.280 3656.04 3722.64 2183.95 S 1792.39 E 5997838.04 N 567743.34 E 3.521 2825.28 5065.25 48.200 138.520 3715.93 3782.53 2237.51 S 1839.11 E 5997784.89 N 567790.53 E 3.668 2896.33 5159.06 45.690 137.920 3779.97 3846.57 2288.63 S 1884.77 E 5997734.18 N 567836.64 E 2.716 2964.82 5252.35 44.040 138.520 3846.09 3912.69 2337,70 S 1928.62 E 5997685.50 N 567880.92 E 1.826 3030.58 5345.22 41.320 141.000 3914.36 3980.96 2385.72 S 1969.30 E 5997637.83 N 567922.03 E 3.443 3093.51 5439.40 36.270 142.080 3987.74 4054.34 2431.89 S 2006.01 E 5997591.99 N 567959.14 E 5.410 3152.49 5532.57 31.640 142.740 4065.01 4131.61 2473.11 S 2037.76 E 5997551.06 N 567991.26 E 4.985 3204.48 22 July, 2002 - 13:27 Page 30f4 DrillQuest20~0~003 BP EXPLORATION (ALASKA) INC. Milne Point Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 5625.57 29.610 141.750 4145.03 4211.63 5718.89 29.200 141.590 4226.33 4292.93 5812.22 29.150 142.070 4307.82 4374.42 5871.17 28.700 141.670 4359.41 4426.01 5939.00 28.700 141.670 4418.91 4485.51 Sperry-Sun Drilling Services Survey Report for MPS-11 MWD Your Ref: API 500292309200 Job No. AKMW22101, Surveyed: 26 June, 2002 BPXA Milne Point MPS Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (°/1 OOft) 2510.57 S 2066.76 E 5997513.86 N 568020.58 E 2.249 3251.83 2546.51 S 2095.17 E 5997478.17 N 568049.31 E 0.447 3297.64 2582.28 S 2123.29 E 5997442.65 N 568077.74 E 0.256 3343.12 2604.71 S 2140.89 E 5997420.37 N 568095.54 E 0.831 3371.62 2630.26 S 2161.10E 5997395.00 N 568115.97 E 0.000 3404.19 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 140.440° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 5939.00ft., The Bottom Hole Displacement is 3404.20ft., in the Direction of 140.592° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 5939.00 4485.51 2630.26 S 2161.10E '- Survey tool program for MPS-11 MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description Comment Projected Survey 0.00 195.00 0.00 195.00 195.00 5939.00 195.00 Tolerable Gyro 4485.51 MWD Magnetic 22 July, 2002 - 13:27 Page 4 of4 DrillQuest 2.00.09.003 Sc~lullbepgep Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth r-, Well MPL-32 J <17- 0 to S MPS-11 dO~'" JJt. MPS-13 dDa..- /I PSI-01 dO a - 14 - D.S.18-09B ¡qW-ol CJ C-16 J ~ 0 - 0 /0 W-20 J ~~... OL~ BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Job# Log Description Date 22374 SCMT 22371 SCMT 22375 SCMT 22373 USIT 22370 SCMT 22359 RST-SIGMA 22361 RST-SIGMA 06/25/02 07/01/02 07/02/02 08/05/02 07/06/02 07/23/02 07/28/02 RECEIVED AUG .Be 2002 Alaska Oil &Z= Commission Blueline 08/21/02 NO. 2343 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Sepia Color Prints CD 2 2 2 2 2 Schlumberger GeoQuest 3940 Arctic Blvd I Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Receive& 6Jb,pA ~ ~ STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL VJ6Å- '~l h( OL ~ ~/&¡/~l- ~ P/¿<- 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 0 Variance II Other / 0 Operation Shutdown 0 Re-Enter Suspended Well 0 Stimulate Completion of Well 5. Type of well: 0 Development 0 Exploratory 0 Stratigraphic III Service 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3338' NSL, 79' WEL, SEC. 12, T12N, R10E, UM At top of productive interval 879' NSL, 2818' WEL, SEC. 07, T12N, R11E, UM At effective depth 725' NSL, 2696' WEL, SEC. 07, T12N, R11E, UM At total depth 7211 NSL, 2693' WEL, SEC. 07, T12N, R11E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 5939 feet 4486 feet 5927 feet 4475 feet Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented 80' 5900' 20" 7" 260 sx Arctic Set (Approx.) 1290 sx PF IL', 547 sx Class 'G' Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth) 4-1/2" Tubing Killstring to 74'. Packers and SSSV (type and measured depth) None 13. Attachments III Description Summary of Proposal 6. Datum Elevation (DF or KB) KBE = 66.6' 7. Unit or Property Name Milne Point Unit 8. Well Number MPS-11i ,- 9. Permit Number 202-113 10. API Number 50- 029-23092-00 11. Field and Pool Milne Point Unit / Schrader Bluff MD TVD 112' 5928' 112' 4476' (1 14. Estimated date for commencing operation August 27, 2002 / 16. If proposal was verbally approved 0 Detailed Operations Program 15. Status of well classifications as: 0 Oil 0 Gas 0 Suspended Service Water Injection Name of approver Date Approved Contact Engineer Name/Number: Robert Odenthal, 564-4387 17. I hereby certify th~'theJo~~irntru. d corre Signed (i., ) J Robert Odenthal JI~ ~ . ~ 0 BOP Sketch Prepared By Name/Number: Sondra Stewman, 564-4750 Conditions of Approval: Notify Commission so representative may witness Plug integrity - BOP Test -X- Location clearance - Mechanical Integrity Test ~ Subsequent form required 10- 1./07 NtXT¡ ~L -r~~~ d ., Approved by order of the Commission Form 10-403 Rev. 06/15/88 @K~'~1~A L Approval No. 30 ê...... 2.. to 0 T«r toPE to ;~O J7~' ~ Date '1 b~ JV8 Submit I~ q{¡~icate Commissioner ( S-ll (YV"\~V'--) Date of Starting Operations: 8/27/2002 Scope of Work: 1. MIRU N4ES./ 1. ND Tree. NU BOP. There are no open peñs in the well. 2. RIH to -2000' md and displace out diesel to kill weight brine. 3. RIH and perforate 2' interval using e-line conveyed guns. Intervals (Ref SCMT log dated 7/1/02): 5500-5502' md Guns: 3-3/8" RDX DP Vanngun, 4 spf, 60 0 phasing, 21.5" pen, 0.41" eh 4. Set retainers and block squeeze interval. / 5. Drill out cement retainer. 6. WOC. , 7. Run SCMT log from 5700-5200'MD to confirm isolation. / 8. RIH and perforate using e-line conveyed guns. / Intervals (Ref SCMT log dated 7/1/02): 5535:5550 & 5600-5615' md Guns: 3-3/8" RDX DP Vanngun, 4 spf, Random phasing, 21.5" pen, 0.41" eh 9. RIH with bit and scraper to TD to condition hole for completion. 10. Run the dual 2-3/8" completion as per attached schematic (top packer at -5474' md, bottom packer at -5560' md.) 11. ND BOP. NU dual 2-1/16" 5M CIW Tree. 12. Freeze protect the well 13. RDMO Tree:4 1/16" ( Wellhead: 20" X 11" FMC dual string Gen 6 WI 4.5" hanger wI full joint MPU 5-11i A 20" x 34" insulated, 215 #/ft A-53 00 KOP @400' Max. hole angle = 55 degree @ 3500' Hole angle thru perfs = 29 degree 750' of diesel 7" 26#, L-80, IBT-MOD Casing (drift 10 = 6.151, cap.= .0383 bpf) 9.2# Brine Perforation Summary Size Spf I nte rval (TVD) ~ ~ DATE 6/ 29/02 REV. BY MOO COMMENTS Drilled and Cased Doyon 141 Orig. OF Elev. = 66.60 Orig. GL Elev. = 39.10 7" Halliburton Float Collar I 5843' I 7" Halliburton float shoe I 5928' I MILNE POINT UNIT WELL No.: S-11 i API: 50-029-23092-00 BP EXPLORATION (AK) Squeeze Perfs 5500- 5502' md OA Perfs 5535- 5550' md OB Perfs 5600- 5615' md M II ~ ;; Ð~ trf li.I,ì~..'__:.- ¡ '; " ..~ <' " : ~ " ~' . -' ¡ '~ ~~ ~ LJ 'i ,~ '! I ~ 'I " r ,', ~ .: 'I. ;, m ~... j, ~ ~.'" 'f i 't;; ¡;§ ~;. ~ .;' l!¡ š;' ,it ,.' ¡~ ~;_. ~~ ':' ;~ 1 :..1 ~. r~ ~- .j ;' ;t ~1' ~1; ~;' (.~ ~;: } ~ t;î" ~ rrJ: :Æ! ~. - ¡~ 't.~ !¿ '~ î~' ¡)f l ~ ~'- ~r î ;1 I~. ;~ *,~.à. \',:~~ II i~ If ,~i'.' ~'_. ~ ,~, J ~ '~ ~4 ~" ;1 It ;,1 i: I' - ,-- l ~ j¡ ; ~... "1:1 ~. ~...~: .¡ ..- Proposed -MPS11l....j string completion ~ 2-3/8" 'X' nipples (set at - 2200' md) 2-3/8" 4.7# L80 IBT tubing strings 7" x 2-3/8" Baker GT dual packer (set at - 5474' md) /' 2-3/8" 4.7# L80 IBT pup jt (-10') 2-3/8" 'X' nipple with 1.875" no-go 2-3/8" 4.7# L80 IBT pup jt (-10') Re-entry guide 7" x 2-3/8" Baker FH packer (set at -5560' md) ,/ 2-3/8" 4.7# L80 IBT pup jt (-10') 2-3/8" 'X' nipple with 1.875" no-go 2-3/8" 4.7# L80 IBT pup jt (-10') Re-entry guide 2-3/8" Dual Strings with dedicated OA and 08 injection. Re: MPS-ll Hole Size Change From 9.875-in to 8.5-in ( Subject: Re: MPS-ll Hole Size Change From 9.875-in to 8.5-in Date: Thu, 20 lun 2002 15:23:56 -0800 From: Winton Aubert <Winton_Aubert@admin.state.ak.us> Organization: AOGCC To: "Green, Matt D" <GreenMD@BP.com> Matt, AOGCC will now disregard your proposed changes, dated 6/19/02, to the MPS-11 drilling program. Good luck with the well. Winton Aubert AOGCC 793-1231 "Green, Matt D" wrote: > Winton, > > After re-examining the risks involved in drilling 8.5-in hole, we have now > decided to revert to the original plan of drilling 9.875-in hole. Please can > you cancel the previous request to change the well plan. > > Our apologies for the change in decision. > > Cheers, > > Ma tt. > > -----Original Message----- > From: Winton Aubert [mailto:,.,fi~nton Aubert@admin.state.ak.usJ > Sent: Wednesday, 19 June 2002 5:17 PM > To: Green, Matt D > Subject: Re: MPS-11 Hole Size Change From 9.875-in to 7.0-in > > Ma t t, > > AOGCC hereby approves changes to your MPS-11 drilling program as proposed > below. All other permit stipulations remain in effect. > > Win ton Aubert > AOGCC > 793-1231 > > "Green, Matt D" wrote: > > > Winton, > > > > It is proposed to change the hole size for the MPS-11 injector from > 9.875-in > > to 8.5-in. The 7.0-in casing will remain unchanged. As discussed in our > > telephone conversation today, the cement volumes will change (using same > > basis of design - 250% excess in permafrost, 40% excess in open hole, pump > > lead until 10.2-lb/gal cement observed on surface). Cement volumes will > be: > > > > Lead: 839-bbl, 1134-sx > > Tail: 77-bbl, 375-sx > > Total: 916-bbl > > > > Any further questions, please let me know. > > > > Cheers, > > > > Matt Green > > > > Matthew D Green > > Drilling Engineer Re: MPS-ll Hole Size Change From 9.875-in to 8.5-in > > BP Exploration Alaska, ME 4-1 > > PO Box 196612 > > Anchorage AK 99519-6612 > > (W) +1 (907) 564 5581 > > (M) +1 (907) 529 8501 > > (F) +1 (907) 564 4189 ( ~7!Æ~! :} !Æl!Æ~&!Æ ( AI¡ASKA OIL AND GAS CONSERVATION COMMISSION / I I f f / I I i ! f f I 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 Re: Milne Point Unit MPS-11 i BP Exploration (Alaska), Inc. Pennit No: 202-113 Surface Location: 3338' NSL, 78' WEL, Sec. 12, T12N, R10E, UM Bottomhole Location: 673' NSL, 2670' WEL, Sec. 07, T12N, RIlE, UM Dear Mr. Archey: Enclosed is the approved application for pennit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. 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 prior to drilling new hole 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~yibechsli Tayldf Chair BY ORDER OF THE COMMISSION DATED thisS1b- day of June, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation wlo encl. t' ( ALAS~ STATE OF ALASKA" .JIL AND GAS CONSERVATION corl.. ,SSION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test 0 Development Oil II Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Planned KBE = 68' Milne Point Unit / Schrader 6. Property Designation Bluff ADL 380110 7. Unit or Property Name Milne Point Unit 8. Well Number MPS-11i /' 9. Approximate spud date 07/02/02 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 6103' MD / 4595' TVD 0 17. Anticipated pressure {s~,e 20 AAC 25.035 (e) (2)} 56 , Maximum surface 1457 psig, At total depth (TVD) 4250' / 1882 psig Setting Depth Top Bottom Lenqth MD TVD MD TVD 80' Surface Surface 112' 112' 6073' Surface Surface 6103' 4595' IN6 A- '5/~ II '0'- crfÇ Hole 42" \9 ,~, !..-r J6F.~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 3338' NSL, 78' WEL, SEC. 12, T12N, R10E, (As Planned) At top of productive interval 856' NSL, 2821' WEL, SEC. 07, T12N, R11E, (As Planned) At total depth 673' NSL, 2670' WEL, SEC. 07, T12N, R11 E, (As Planned) 12. Distance to nearest property line 13. Distance to nearest well ADL 047446,6731 MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 500' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Casinq Weiqht Grade Couplinq 20" 92# H-40 Welded 7" 26# L-80 BTC 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 Quantitv of Cement ÐV" (include staqe data) 260 sx Arctic Set (Approx.) ~sx PF 'L', 376 sx Class 'G' ~ \.UGA- 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 R:ECEIVED f'! ilV "":"1 O002 Ii¡g' '~t \ L ' &I ,I \...' V Perforation depth: measured Alaska Oil & Gas Cons, CommisSIon AnchorafJe true vertical 20. Attachments II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 020 AAC 25.050 Requirements Contact Engineer Name/Number: Matt Green, 564-5581 21. I hereby certify that and correct to the best of my knowledge Signed Pat Archey Title Senior Drilling Engineer Prepared By Name/Number: Sondra Stewman, 564-4750 Date Permit Number, / API Number A~rova D?je See cover letter :z. ð 2.. - // -3 50- <:::) 2... 7 - Z 30 9' L CS 0 0\ for other requirements Conditions of Approval: Samples Required 0 Yes S No Mud Log equ'red 0 Yes m No Hydrogen Sulfide Measures 0 Yes JS No Directional Survey Required ~ Yes 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 8~ ~l~~ t ~l~tt~ P J~ n--. ro ..., 1M.- 10 - £10 š " A Approved By c~iTry'J¡~~ìr~~ lo~ O~t>D ~~,or.. ~~ L ~:eO:~~;:SSion Date UL J7,ð!J . Form 10-401 Rev. 12-01-85 . r\ I I i'J 1--\ Sl!Jbm In Tnpllcate Schrader Bt . S-Pad ProQram MPS-11i Permit \Well Name: I MPS-11 i Drill and Complete Program Summary I Type of Well (service I producer I injector): 1 S-Shaped Injector Surface Location: 19421 FNL, (33381 FSL), 781 FEL, (52011 FWL), SEC. 12, T12N, R10E X=565,931.91 Y=6,000,006.13 44231 FNL, (8561 FSL), 28211 FEL, (19711 FWL), SEC. 7, T12N, R11 E X=568,003 Y=5,997,544 2=4,124 TVDss 46061 FNL, (6731 FSL), 26701 FEL, (21221 FWL), SEC. 7, T12N, R11 E X=568, 156 Y=5,997,362 2 = 4,529 TVDss ('" Target Start Location: "OA" Bottom Hole Location: I AFE Number: 1 TBD 1 Estimated Start Date: I 8 Jul 2002 I MD: 16,103 I I TVD: 14,595 I I Rig: I Doyon 141 ",," ' I Operating days to complete: 17.5 I Max Inc: 156 I I KOP: 1500 I I I I KBE: 168 I I I 1 Well Design (conventional, slimhole, etc.): I Conventional Grass Roots Injector I Objective: I Schrader "OA", "OB" & "OBD" Mud Program o\l- ~ ~in Production Hole Mud Properties: Density (ppg) Funnel visc YP HTHP 8.6 - 9.20 75 - 150 25 - 60 N/A LCM Restrictions: None 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 1 R. Spud - LSND Freshwater Mud pH API Filtrate LG Solids 9.0 - 9.5 < 8 < 6.5 Cement Program Casing 7.0-in 26-lb/ft L-80 BTC surface casing Size Basis 250% excess over gauge hole in permafrost interval, 40% excess over gauge hole below permafrost. Top of tail cement 500-ft TVD above top of N-sand. Total Cement Wash 20-bbl Water Spacer Vol: 1054-bbl Spacer 50-bbl Viscos~f!ed Spacer (Alpha Design) we~hted to 10.5-lb/gal Lead 977-bbl, ~..-sx 10.7-lb/gal Class L - 4.15 ft /sx (cement t<Ysl)rface) Tail 77-bbl, 375-sx 15.8-lb/gal Prem G - 1.15 fe/sx of tail at Temp BHST == 85°F from SOR, BHCT 85°F estimated by Halliburton 1 ( M{ Point MPS-11 Well ProQram Evaluation Program rJ~ ~~-in Hole Section: Open Hole: MWD/GRlRES/PWD IFRlCASANDRA Sidewall Cores Cased Hole: SCMT (post rig) Formation Markers Formation Tops MOrkb TVDrkb TVOss Pore Pressure Estimated EMW (ft) (ft) (ft) (psi) (ppg)* Base Permafrost 1898 1818 1750 788 Top Ugnu 4764 3543 3475 1564 8.65 NA 5484 4054 3986 1794 8.65 NB 5512 4078 4010 1805 8.65 NC 5551 4112 4044 1820 8.65 NF 5609 4162 4094 1842 8.65 Top OA 5644 4192 4124 1856 8.65 Base OA 5677 4221 4153 1869 8.65 Top OB 5710 4250 4182 1882 8.65 Base OB 5737 4273 4205 1892 8.65 Top OBO 5880 4398 4330 1949 8.65 Base OBO 5955 4464 4396 1978 8.65 TO 6103 4595 4527 2038 8.65 OWC 5818 4344 4276 * Based on 88 depths CasinglTubing Program Hole Size Csg/ WtlFt Grade Conn Length Top Bottom Tbg O.D. MD/TVDrkb MD / TVDrkb ~ ~.. 42-in 20-in* 92# H-40 Welded 80' 0' 112' / 112' V~-in 7.0-in 26# L-80 BTC 6,073' 0' 6,103' / 4,595' * The 20-in conductors are insulated! Recommended Bit Program BHA Hole Size Depth (MD) Bit Type Nozzle/Flow rate 1 ~-in O'-TO Hughes MXC-1 3-15 & 1-1 0 B . Ç' II 2 M{ 'Point MPS-11 Well Proaram Well Control: Production hole will be drilled with a diverter. . Maximum anticipated BHP: 1,882-psi @ 4,250-ft TVDrkb - Top of "DB" . Maximum surface pressure: 1,457 -psi @ surface !' (Based on BHP and a full column of gas from TD @ 0.1-psi/ft) . Planned BOP test pressure: Function test diverter . Kick tolerance: N/ A . Planned completion fluid: 10.0-lb/gal brine / 7.0-lb/gal Diesel (2,000-ft MD) Drilling Hazards & Contingencies: Hydrates . Hydrates have not yet been seen on S pad, but have been encountered in the surface holes on other pads, especially nearby H-Pad. Hydrates generally occur just below the permafrost (+/- 1 ,800-ft TVDss) but may be present in shallower SV sands and also as deep as 3,000-ft. Be alert for the possibility of shallow gas and/or hydrates. Use recommended practices for drilling hydrates. . Watch out for deeper gravels below the permafrost or gravels that calve off within the permafrost and 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. Below is a list of the wells and the lost circulating problems associated with them. We do not expect losses while drilling this well. . MPS-27: Lost returns cementing 7.0-in casing at approx. 800-ft MD. SuccessfuI1.0-in top job. . MPS-21: Lost returns cementing 7.0-in casing. Used TAM port collar at 1 ,OOO-ft with still no returns. SuccessfuI1.0-in top job. . H-06 (1995): Lost 100-bbl running 9-5/8" casing, good returns during cementing except no returns for last 20-bbl, contaminated cement to surface, cement 12 ft down, no top job. . H-05 (1995): Lost returns drilling at 5,360-ft (3,700-ft TVD), 40-bph to keep full, treated w/ LCM pills for two days, total losses 838-bbl, made hole opener run with some continued losses. . H-05 (1995): Ran 9-5/8" casing, lost 46-bbl conditioning mud. . H-07 (1995): Lost 50-bbl running 9-5/8" casing. . E-24 (1998): Made hole opener run, worked tight spots 1965, 2620, 3465, 5900 and 6000, lost 72-bbl while circulating. . H-08A (1997): Had some minor losses while running 4-1/2" liner. 3 ( M(.... ~ Point MPS-11 Well Proqram . Follow the LOST CIRCULATION DECISION MATRIX in the well program if fluid losses occur while drilling. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. Expected Pressures . It is unlikely there will be unexpected overpressure when drilling to the Schrader Bluff formation. Reservoir pressure is expected to be (8.65 Ib/gal EMW). In this well, the Schrader Bluff formation will be drilled with 9.1 to 9.2-lb/gal mud. . There is a possibility of overpressure from MPE-29i via transmissive faults. However, MPS-07 and MPS-09 were drilled into fault blocks between the MPS-11 location and the MPE-29 injector and both MPS-07 and MPS-09 were normally pressured. . Flow-check the well when the reservoir is entered. Pad Data Sheet . Please read the MPU S-Pad Data Sheet thoroughly. Breathing . N/A Hydrocarbons . Hydrocarbons will be encountered in the Ugnu through the Schrader Bluff. Free Gas may be encountered below the Upper Ugnu. Faults . No faults are predicted to be crossed along the well trajectory. . The well will be drilled into the graben between two faults. . There is a chance of a faulted OBD section; the well is placed to minimise risk. Hydrogen Sulfide . Milne Point S-Pad is not designated as an H2S Pad. Anti-collision Issues . None, except for consideration of planned wells. Integrity Testing . Will be drilled on diverter and no FIT/LOT is required. 4 { \ M( '\ Point MPS-11 Well PrOQram DRILL & COMPLETION PROCEDURE Drillina 1. 2. 3. 4. MIRU Doyon 141, NU diverter. Drill~nO~~le to TD as per directional plan. Obtain sidewall cores from reservoir sands. /' Rig up and run 7.0-in 26-lb/ft, L-80, BT&C casing to total depth and cement in place. Install tubing head and Christmas tree. / RD Doyon 141. 5. 6. 5 Field: Milne Point Well: MPS-11 DIRECTIONAL LWD NONE MWD/GR/RES IFRlCAS PWD 28-5-2002 OPEN HOLE LOGGING NONE SIDEWALL CORES BP EXPLORATION Milne Point Unit MPS-11 Actual Surface Location: 1942' NSL & 5201' FWL SEC 12,T12N, R10E Bottom Hole Location: 3606' FSL & 2122' FWL SEC 7,T12N, R11E (' ENG: Steve Campbell, Matthew Green RIG: Doyon 141 RKB: 68.ft Status: Not Drilled FORM DEPTH HOLE CASING MUD INFO MD I TVD SIZE SPECS PIT INFO INFORMATION Wellhead Permafrost 20" 92# H-40 FMC Gen 6 20" x 11" 5M Welded 112' 112' 42 Insulated 250 % Excess Permafrost 40 % Excess Top of Tail Cement Top of N sand OA sand OB sand Total Depth 1,898' 1,818' 4,984' 5,484' 4,054' 5,644' 4,192' 5,710' 4,250' 6,103' 4,595' 97/8" Hughes MXC-1 Production Casing 7" 26# L-80 BT&C 6.276-in ID Lead Cement Volume 747.4 bbl 1010 Sacks KOP @ 500' EOB @ 2633' AA=56 VS=886' Cement to Surface 230.5 bbl 312 Sacks Tail Cement Volume 76.9 bbl 375 Sacks SOD @ 4826' EOD @ 6103' AA=28 VS=3456' MW = 9.2 MPS-11 Well Plan Schematic.xls op SURVEY PROGRAM Tool Created By: Ken Allen Checked: Plan: MPS-II wp02 (Plan MI'S-II/I'lan MPS-I!) Date: COMPANY DETAILS REFERENCE INFORMATION Depth Fm Depth To SUIVeylPlan 66AO 600.00 Planned: MPS-II wp02 VI 600,00 6103.02 Planned: MPS-II wp02 VI Co-ordinate (NÆ) Reference: Wen Centre: Plan MPS-II, Tme North Vertical (fYD) Reference: S-pad D-141 66.40 SectIon (VS) Reference: Slot - (O.OON,O.OOE) Measured Depth Reference: S-pad D-141 66AO Calculation Method: Minimmn Cmvature BP Amoco CB-GYRO-SS MWD+lFR+MS Calculation Method: Minimmn Curvature Error System: ISCWSA Scan Method: Trav Cylinder North EITar Surface: Elliptical + Casing Warnin! Method: . Rules Based Reviewed: 0- .,"u."",¡¡\-u,- FORMATION TOP DETAILS No. TVDPath MDPath Formation 1 1816.40 1"".98 BPRF 2 3531.40 ,pj <.06 TUZC 3 4052.40 ' j S ~.53 SBF2-NA 4 4067.40 ,J"".85 SBF1-NB 5 4110.40 -. ,j".50 SBE4-NC 6 4123.40 ',", j,.51 SBEl-NF 7 4161.40 ...11'.39 TSBD-OA 8 4190.40 ",j 1.85 TSBC 9 4247.40 ,,711 7.45 TSBB-OB 10 4271.40 .7;".01 SBA5 (base OB) 11 4396.40 .;; i 7.94 TOBD 12 4462.40 ,"" ;.02 BOBD WELL DETAILS +Ni-S Basting Latitude +EI-W Northing Name Plan MPS-II 31.80 -412.86 6000006,13 565931.91 70"24'3H>4IN 149"27'47.272W NlA TARGET DETAILS Northing E:>sting Shape 568003.00 Circle (R:ulhl<: 120) 568111.00 Circle (R:ulhl<: 1(0) 1VD +N/-S +EI-W Name . ~I.J" n" ~;IOO': 500' MD. 500'TVD ~I.]" n" ~ '/100' : 600' MD, 599.98'TVD MPS-II TI 4161.40 -2480.55 2049A7 5997544.00 MPS-II BOBd 4462-40 -2609,91 2156.34 5997415.60 700- _"m SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace 1 r....40 0.00 0.00 66.40 0.00 0.00 0.00 0.00 2 '"".00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 3 r.III'.OO 2.00 140.44 599.98 -1.35 1.11 2.00 0.00 4 177';'.74 31.47 140.44 1716.40 -260.12 214.91 2.50 0.00 5 ::1111.23 31.47 140.44 1916.40 -354.48 292.88 0.00 0.00 6 ::,.: 1.30 56.27 140.44 2359.94 -683.19 564.46 4.00 0.00 7 .j;';>.74 56.27 140.44 3577.31 -2088.86 1725.87 0.00 0.00 8 ,J':.53 30.00 140.44 4052.40 -2432.04 2009.39 4.00 180.00 9 -"''''.39 30.00 140.44 4161.40 -2480.55 2049.47 0.00 0.00 10 "J,I.02 28.28 140.44 4462.40 -2609.92 2156.34 0.50 180.00 11 ,.1111.02 27.53 140.44 4594.96 -2664.03 2201.04 0.50 180.00 : S. 111111' ! ~ \h' 1400-- - -"- - -~-~-----~---- -~..~-- ! . l'''\ - ~~- --¥No '¡:¡' ~ 25 2100--'.' t:. ..c:: ~ Ö , ;"End D'I 177x 74' MD, 1716.4' TVD ,,'\. BPIIF' ~""I~ St~~ D'I1/l00': 2013.23' MD, 1916.4'TVD '_n,,", '.... ~'-J_u,,- I !.;f 4594.96 6103.01 7" CASING DETAILS All TVD depths are ssTVD plus 66.4'for RKBE. No. TVD MD :>(,111' MD, 2359.94' TVD ~ End Dir " '" 3000 ' '" <.) '€ > Q) =' þ I i i j ! , __b "1,, I ! I I I j I ! , i ; ; ! i - -----.!--------.------- ! , -~tJZ("-'---'- 2800-_m__- "'---'-'-~'''- '-~ ¡ 6f?/I ~:~7¡!- (:(103.1I!' MD "¡"'¡ 'Jñ' IT'YD ; i r- ~- ¡ 2800 3500 ~ ,.0 ~..< ..,.~/./ "'.' '... "I'---~~ .". -"'- ,/ "'J' '/.. ~ .Q/..,.~~. ,../"" ~ ~ /'..",/ , .# ""', "" 3500~ =-::: ' - -.----.-.. - - ------- SI..)n Dar 4.'PIl..l" '"~ ::::..:.::..._- --- ----- ~ --- m.. - I i ! i -- - ¡ --------- --- ---1 - m_- - , . ----------f---- I " 'f ¡ ! ,,) iJ>' -:. SBF2-NA ~! "'\. MD, j,),:.tTVD Y.....'." SB.F1-NB "- ,i /L SBE4-NC ""f\1D,H61A'j\'D ',,//'1',' SBE1-NF ,- '-'~:':;::::':::::::;:~:~:~,::~~-~~~ TS~~~:B-OB 'T:...-n ~m SBA5 (base OB) L\ ' ¡ TOBD : BOBD m..... ' ---- -- -- .;. 4200- ='= ,u '" u- , '''''1- ~ ! - -,~ - - --. - ---~ -----. -- --- .....". I 7uu ¡ ! I 1400 2100 Vertical Section at 140.44° [700ft/in] r,,'~1 [¡<p'h Date: 5/2/2)O2 Date: I.ongitude Slut VSec Target 0.00 0.00 1.75 337.41 459.82 886.20 2709.61 3]54.75 3217.68 3385.48 3455.67 MPS-II MPS-l1 Tl Name Size 7.000 Æ ~ 0 ~ +' ::E" t: ~ ::E" :5 0 en tip COMPANY DETAILS REFERENCE INFORMATION SURVEY PROGRAM I'lan: MPS-II wp02(l'lan MPS-II/)'Ian MI'S-II) Toot Depth Fm Depth To SurveylPlan 66.40 600,00 Planned: MPS-ll wp02 VI 600.00 6103.02 Planned: MPS-II wp02 VI Co-ordinate (NÆ) Refereoce: Well Centre: Plan MPS-II, True North Vertical (lVD) Reference: S-pad D-141 66.40 Section (VS) Reference: Slot - (O,ooN,O.ooE) Measured Depth Reference: S-pad D-141 66.40 Calculation Method: Minimum Curvature BP Amoco Cre-dted By: Ken AlIc'ß Checked: Date: 512/2002 CB-GYRO-SS MWD+IFR+MS Calculation Method: Minimmn Cwvature Enor System: ISCWSA Scan Method: Trav Cylinder North Error Surface: Elliptical + Casing Warnjn~ Method: Rules Based Date: Reviewed: Date: WELL DETAILS 500- Name +EI-W LungÎtudc Slut Northing f:.a.o;¡ting Latitude +NI-S Plan MPS-Il 565931.91 70"24'37.64IN 149"27'47.272W N/A 31,80 412,86 6000006,13 TARGET DETAILS Northing I~sting Shapu ~~~m:~ g~:~ ¡:t:::~:: :~¡ Name TVD +N/-S +EI-W MPS-II TI 4161,40 -248055 2049.47 5997544.00 MPS-11 BOBd 4462.40 -2609.91 2156.34 5997415.60 -1500- I 3000 : 1778.74'MD, 1716.4'TVD Dir 41100': 2013.23' MD, 1916.4'TVD SECTION DETAILS See MD Ine Azi TVD +N/-S +EI-W DLeg TFaee VSee Target 1 r.r..40 0.00 0.00 66.40 0.00 0.00 0.00 0.00 0.00 2 '1111.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.00 3 ,.,1111.00 2.00 140.44 599.98 -1.35 1.11 2.00 0.00 1.75 MPS-II T 4 177".74 31.47 140.44 1716.40 -260.12 214.91 2.50 0.00 337.41 5 '':''1 \.23 31.47 140.44 1916.40 -354.48 292.88 0.00 0.00 459.82 6 .:..\ \.30 56.27 140.44 2359.94 -683.19 564.46 4.00 0.00 886.20 7 ';,;':-.74 56.27 140.44 3577.31 -2088.86 1725.87 0.00 0.00 2709.61 8 ,;,;.:.53 30.00 140.44 4052.40 -2432.04 2009.39 4.00 180.00 3154.75 9 '1''''.39 30.00 140.44 4161.40 -2480.55 2049.47 0.00 0.00 3217.68 MPS-ll TI 10 ,'" \.02 28.28 140.44 4462.40 -2609.92 2156.34 0.50 180.00 3385.48 11 ..11> 1.02 27.53 140.44 4594.96 -2664.03 2201.04 0.50 180.00 3455.67 End Dir : 2633.3' MD, 2359.94' TVD CASING DETAILS FORMATION TOP DETAILS No. TVD MD Name Size No. TVDPath MDPath Formation 4594.96 6103.01 7" 7.000 1 1816.40 1895.98 BPRF 2 3531.40 4743.06 TUZC 3 4052.40 5482.53 SBF2-NA 4 4067.40 5499.85 SBFI-NB 5 4110.40 5549.50 SBE4-NC 6 4123.40 5564.51 SBEI-NF 7 4161.40 5608.39 TSBD-OA 8 4190.40 5641.85 TSBC 9 4247.40 5707.45 TSBB-OB 10 4271.40 5735.01 SBA5 (base OB) II 4396.40 5877.94 TOBD 12 4462.40 5953.02 BOBD AllTVD depths are ssTVD plus 66.4'.for -2000- - ' -2500 wp02 : 6103.02' MD, 4594.96' TVD I 2500 500 1000 1500 W est( - )/East( +) [500ft/in] 2000 BP My Planning Report MAP Company: Field: Site: Well: Wellpath: Field: BP Amoco Milne Point M PtS Pad Plan MPS-11 Plan MPS-11 Date: 5/2/2002 Time: 09:19:47 Page: Co-ordinate(NE) Reference: Well: Plan MPS-11, True North Vertical (TVD) Reference: S-pad 0-141 66.4 Section (VS) Reference: Well (0.00N,O:00E,140.44Azi) Survey Calculation Method: Minimum Curvature Db: 1 Oracle Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2001 Site: M Pt S Pad Site Position: Northing: 5999978.00 ft Latitude: 70 24 37.329 N From: Map Easting: 566345.00 ft Longitude: 149 27 35.171 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.51 deg Well: Plan MPS-11 Slot Name: Well Position: +N/-S 31.80 ft Northing: 6000006.13 ft Latitude: 70 24 37.641 N +E/-W -412.86 ft Easting: 565931.91 ft Longitude: 149 27 47.272 W Position Uncertainty: 0.00 ft Wellpath: Plan MPS-11 Current Datum: Magnetic Data: Field Strength: Vertical Section: S-pad D-141 6/29/2001 57460 nT Depth From (TVD) ft 0.00 MPS-11 wp02 Height 66.40 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Well Ref. Point 0.00 ft Mean Sea Level 26.28 deg 80.78 deg Direction deg 140.44 +N/-S ft 0.00 Plan: Date Composed: Version: Tied-to: 4/29/2002 1 From Well Ref. Point Principal: Yes Casing Points !\'ID TVD Diameter Hole Size Name ft ft in in 6103.01 4594.96 7.000 9.875 7" Formations !\'ID TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 1895.98 1816.40 BPRF 0.00 0.00 4743.06 3531.40 TUZC 0.00 0.00 5482.53 4052.40 SBF2-NA 0.00 0.00 5499.85 4067.40 SBF1-NB 0.00 0.00 5549.50 4110.40 SBE4-NC 0.00 0.00 5564.51 4123.40 SBE1-NF 0.00 0.00 5608.39 4161.40 TSBD-OA 0.00 0.00 5641.85 4190.40 TSBC 0.00 0.00 5707.45 4247.40 TSBB-OB 0.00 0.00 5735.01 4271.40 SBA5 (base OB) 0.00 0.00 5877.94 4396.40 TOBD 0.00 0.00 5953.02 4462.40 BOBD 0.00 0.00 Targets Map Map <-- Latitude ---> <- Longitude --> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg !\Iin Sec Dip. Dir. ft ft ft ft ft MPS-11 T1 4161.40 -2480.55 2049.47 5997544.00 568003.00 70 24 13.243 N 149 26 47.221 W -Circle (Radius: 120) -Plan hit target MPS-11 BOBd 4462.40 -2609.91 2156.34 5997415.60 568111.00 70 24 11.970 N 149 26 44.090 W -Circle (Radius: 100) Company: BPAmoco Fi~ld: Milne Point Site: M Pt S Pad Well: Plan MPS-11 Wellpath: Plan MPS-11 Targets Name Description Dip. Dir. -Plan hit target Plan Section Information MD ft 66.40 500.00 600.00 1778.74 2013.23 2633.30 4825.74 5482.53 5608.39 5953.02 6103.02 Survey 1\10 ft 66.40 100.00 200.00 300.00 400.00 500.00 600.00 700.00 800.00 900.00 Incl deg 0.00 0.00 2.00 31.47 31.47 56.27 56.27 30.00 30.00 28.28 27.53 Azim deg 0.00 0.00 140.44 140.44 140.44 140.44 140.44 140.44 140.44 140.44 140.44 Incl deg 0.00 0.00 0.00 0.00 0.00 Azim deg 0.00 0.00 0.00 0.00 0.00 0.00 0.00 2.00 140.44 4.50 140.44 7.00 140.44 9.50 140.44 1000.00 12.00 140.44 1100.00 14.50 140.44 1200.00 17.00 140.44 1300.00 19.50 140.44 1400.00 22.00 140.44 1500.00 24.50 140.44 1600.00 27.00 140.44 1700.00 29.50 140.44 1778.74 31.47 140.44 1800.00 31.47 140.44 1895.98 31.47 140.44 1900.00 31.47 140.44 2000.00 31.47 140.44 2013.23 31.47 140.44 2100.00 34.94 140.44 2200.00 38.94 140.44 2300.00 42.94 140.44 2400.00 46.94 140.44 2500.00 50.94 140.44 2600.00 54.94 140.44 2633.30 56.27 140.44 2700.00 56.27 140.44 2800.00 56.27 140.44 2900.00 56.27 140.44 TVD ft 66.40 500.00 599.98 1716.40 1916.40 2359.94 3577.31 4052.40 4161.40 4462.40 4594.96 TVD ft 66.40 100.00 200.00 300.00 400.00 500.00 599.98 699.81 799.30 898.26 BP My Planning Report MAP TVD ft +N/-8 ft 0.00 0.00 -1.35 -260.12 -354.48 -683.19 -2088.86 -2432.04 -2480.55 -2609.92 -2664.03 Svs TVD . ft 0.00 33.60 133.60 233.60 333.60 Date: 5/2/2002 Thne:>09:19:47 Pagè: Co-ordinate(NE) Reference: Well: Plan MPS-11 , True North V~rtical ([VD) Reference: S-pad 0-141 66.4 Section (V8) Reference: Well (0.00N,O.00E,140.44Azi) Survey Calculation Method: Minimum Curvature Db: Oracle +N/-S ft +E/-W ft +E/- W ft 0.00 0.00 1.11 214.91 292.88 564.46 1725.87 2009.39 2049.47 2156.34 2201.04 MapN ft 6000006.13 6000006.13 6000006.13 6000006.13 6000006.13 433.60 6000006.13 533.58 6000004.79 633.41 6000000.46 732.90 5999992.79 831.86 5999981.81 996.49 930.09 5999967.54 1093.82 1027.42 5999950.00 1190.06 1123.66 5999929.24 1285.02 1218.62 5999905.27 1378.53 1312.13 5999878.17 1816.40 1819.83 1905.12 1916.40 1988.99 1404.00 5999847.96 1494.07 5999814.72 1582.15 5999778.51 1650.00 5999747.94 1668.13 5999739.45 1750.00 5999701.11 1753.43 5999699.51 1838.72 5999659.56 1850.00 5999654.28 1922.59 5999617.92 2068.91 2002.51 5999571.95 2144.43 2078.03 5999521.82 2215.20 2148.80 5999467.78 2280.87 2214.47 5999410.09 2341.13 2274.73 5999349.05 2359.94 2293.54 5999328.02 2396.97 2330.57 5999285.57 2452.50 2386.10 5999221.93 2508.02 2441.62 5999158.30 Map Map Northing Easting ft ft <- Latitude. --> <.....:. Longitude -> Deg. Min Sec Deg. Min See DLS Build Turn deg/100ft deg/100ft deg/10OO 0.00 0.00 0.00 0.00 0.00 0.00 2.00 2.00 0.00 2.50 2.50 0.00 0.00 0.00 0.00 4.00 4.00 0.00 0.00 0.00 0.00 4.00 -4.00 0.00 0.00 0.00 0.00 0.50 -0.50 0.00 0.50 -0.50 0.00 MapE ft 565931.91 565931.91 565931.91 565931.91 565931.91 565931.91 565933.03 565936.68 565943.13 565952.37 565964.37 565979.12 565996.59 566016.75 566039.55 566064.96 566092.92 566123.38 566149.09 566156.23 566188.49 566189.83 566223.44 566227.88 566258.46 566297.14 566339.30 566384.76 566433.28 566484.64 TFO deg 0.00 0.00 0.00 0.00 0.00 0.00 0.00 180.00 0.00 180.00 180.00 MPS-11 T1 Target MPS-11 T1 VS ft 0.00 0.00 0.00 0.00 0.00 DLS deg/10OO 0.00 CB-GYRO-SS 0.00 CB-GYRO-SS 0.00 CB-GYRO-SS 0.00 CB-GYRO-SS 0.00 CB-GYRO-SS Tool/Comment 1470.40 1560.47 1648.55 1716.40 1734.53 0.00 0.00 Start Dir 2/100' : 500' MD, 50 1.75 2.00 MPS-11 T1 7.41 2.50 MWD+IFR+MS 17.43 2.50 MWD+IFR+MS 31.78 2.50 MWD+IFR+MS 50.43 2.50 MWD+IFR+MS 73.35 2.50 MWD+IFR+MS 100.49 2.50 MWD+IFR+MS 131.81 2.50 MWD+IFR+MS 167.23 2.50 MWD+IFR+MS 206.70 2.50 MWD+IFR+MS 250.14 2.50 MWD+IFR+MS 297.47 2.50 MWD+IFR+MS 337.41 2.50 End Dir : 1778.74' MD, 1716.4 348.51 0.00 MWD+IFR+MS 398.62 0.00 BPRF 400.72 0.00 MWD+IFR+MS 452.92 0.00 MWD+IFR+MS 459.82 0.00 Start Dir 4/100' : 2013.23' MD 507.34 4.00 MWD+IFR+MS 567.42 4.00 MWD+IFR+MS 632.93 ,4.00 MWD+IFR+MS 703.55 4.00 MWD+IFR+MS 778.94 4.00 MWD+IFR+MS 858.72 4.00 MWD+IFR+MS 566502.33 886.20 4.00 End Dir : 2633.3' MD, 2359.94 566538.03 941.68 0.00 MWD+IFR+MS 566591.56 1024.84 0.00 MWD+IFR+MS 566645.09 1108.01 0.00 MWD+IFR+MS BP My Planning Report MAP Company: BP Amoco Field: Milne Point Site: M Pt S Pad Well: Plan MPS-11 Wellpath: Plan MPS-11 Survey MD Incl Azim TVD Svs TVD MapN ft deg deg ft . ft ft . .... ._____n . .. ____m........ .... 3000.00 56.27 140.44 2563.55 2497.15 5999094.66 3100.00 56.27 140.44 2619.08 2552.68 5999031.02 3200.00 56.27 140.44 2674.60 2608.20 5998967.38 3300.00 56.27 140.44 2730.13 2663.73 5998903.74 3400.00 56.27 140.44 2785.65 2719.25 5998840.10 3500.00 56.27 140.44 2841.18 2774.78 5998776.46 3600.00 56.27 140.44 2896.70 2830.30 5998712.83 3700.00 56.27 140.44 2952.23 2885.83 5998649.19 3800.00 56.27 140.44 3007.76 2941.36 5998585.55 3900.00 56.27 140.44 3063.28 2996.88 5998521.91 4000.00 56.27 140.44 3118.81 3052.41 5998458.27 4100.00 56.27 140.44 3174.33 3107.93 5998394.63 4200.00 56.27 140.44 3229.86 3163.46 5998330.99 4300.00 56.27 140.44 3285.39 3218.99 5998267.35 4400.00 56.27 140.44 3340.91 3274.51 5998203.72 4500.00 56.27 140.44 3396.44 3330.04 5998140.08 4600.00 56.27 140.44 3451.96 3385.56 5998076.44 4700.00 56.27 140.44 3507.49 3441.09 5998012.80 4743.06 56.27 140.44 3531.40 3465.00 5997985.39 4800.00 56.27 140.44 3563.01 3496.61 5997949.16 4825.74 56.27 140.44 3577.31 3510.91 5997932.78 4900.00 53.30 140.44 3620.12 3553.72 5997886.36 5000.00 49.30 140.44 3682.63 3616.23 5997826.66 5100.00 45.30 140.44 3750.43 3684.03 5997770.43 5200.00 41.30 140.44 3823.19 3756.79 5997717.96 5300.00 37.30 140.44 3900.56 3834.16 5997669.50 5400.00 33.30 140.44 3982.16 3915.76 5997625.29 5482.53 30.00 140.44 4052.40 3986.00 5997592.16 5499.85 30.00 140.44 4067.40 4001.00 5997585.53 5500.00 30.00 140.44 4067.53 4001.13 5997585.47 5549.50 30.00 140.44 4110.40 4044.00 5997566.53 5564.51 30.00 140.44 4123.40 4057.00 5997560.79 5608.39 30.00 140.44 4161.40 4095.00 5997544.00 5641.85 29.83 140.44 4190.40 4124.00 5997531.23 5700.00 29.54 140.44 4240.92 4174.52 5997509.19 5707.45 29.50 140.44 4247.40 4181.00 5997506.38 5735.01 29.37 140.44 4271.40 4205.00 5997496.02 5800.00 29.04 140.44 4328.13 4261.73 5997471.75 5877.94 28.65 140.44 4396.40 4330.00 5997442.98 5900.00 28.54 140.44 4415.77 4349.37 5997434.90 5953.02 28.28 140.44 4462.40 4396.00 5997415.60 6000.00 28.04 140.44 4503.82 4437.42 5997398.63 6103.00 27.53 140.44 4594.95 4528.55 5997361.89 6103.02 27.53 140.44 4594.96 4528.56 5997361.88 Date: 5/2/2002 TilDe: 09:19:47 Page: Co-ordinate{NE) Reference: Well: Plan MPS-11, True North Vertical (TVD) Reference: S~padD-141 66.4 Section (VS) Reference: Well (O.00N,O.00E.140.44Azi) Survey Calculation Method: Minimum Curvature Db: Oracle 3 ._..._"~'::I/CO~,:::~-,-_..J MapE VS DLS ft ft deg/10att 566698.63 1191.18 0.00 MWD+IFR+MS 566752.16 1274.35 0.00 MWD+IFR+MS 566805.69 1357.51 0.00 MWD+IFR+MS 566859.22 1440.68 0.00 MWD+IFR+MS 566912.76 1523.85 0.00 MWD+IFR+MS 566966.29 1607.02 0.00 MWD+IFR+MS 567019.82 1690.19 0.00 MWD+IFR+MS 567073.35 1773.35 0.00 MWD+IFR+MS 567126.88 1856.52 0.00 MWD+IFR+MS 567180.42 1939.69 0.00 MWD+IFR+MS 567233.95 2022.86 0.00 MWD+IFR+MS 567287.48 2106.03 0.00 MWD+IFR+MS 567341.01 2189.19 0.00 MWD+IFR+MS 567394.55 2272.36 0.00 MWD+IFR+MS 567448.08 2355.53 0.00 MWD+IFR+MS 567501.61 2438.70 0.00 MWD+IFR+MS 567555.14 2521.86 0.00 MWD+IFR+MS 567608.67 2605.03 0.00 MWD+IFR+MS 567631.73 2640.85 0.00 TUZC 567662.21 2688.20 0.00 MWD+IFR+MS 567675.99 2709.61 0.00 Start Dir 4/100' : 4825.74' MD 567715.03 2770.27 4.00 MWD+IFR+MS 567765.26 2848.30 4.00 MWD+IFR+MS 567812.55 2921.78 4.00 MWD+IFR+MS 567856.68 2990.35 4.00 MWD+IFR+MS 567897.44 3053.67 4.00 MWD+IFR+MS 567934.63 3111.45 4.00 MWD+IFR+MS 567962.50 3154.75 4.00 SBF2-NA 567968.07 3163.41 0.00 SBF1-NB 567968.12 3163.48 0.00 MWD+IFR+MS 567984.05 3188.24 0.00 SBE4-NC 567988.88 3195.74 0.00 SBE1-NF 568003.00 3217.68 0.00 MPS-11 T1 568013.74 3234.37 0.50 TSBC 568032.28 3263.17 0.50 MWD+IFR+MS 568034.64 3266.84 0.50 TSBB-OB 568043.36 3280.38 0.50 SBA5 (base OB) 568063.77 3312.09 0.50 MWD+IFR+MS 568087.97 3349.70 0.50 TOBD 568094.76 3360.26 0.50 MWD+IFR+MS 568111.00 3385.48 0.50 MPS-11 BOBd 568125.27 3407.65 0.50 MWD+IFR+MS 568156.17 3455.67 0.50 7" 568156.17 3455.67 0.50 MWD+IFR+MS H 206710 DATE 04/11/02 CHECK NO. 00206710 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT ALASKAOILA NET iDO. OÕ H 00 040902 CK040902L PYMT COMMENTS: HANDL:NG INST: iOO.OO PERMIT TO DRILL FEE S/H - TERRIE HUBBLE X4628 R t'" ".. F. , '.! r "..''''' l . ~¡ ".. ! ~ ti . 'if . . . v.~: ~ÆI 'V t~ L) -YYr~-s - II ; M /".'V ":-r {'\ ? Ur; U(\ r, j I......,¡ ....' U '- t.. Alaska Oil & Gas Cons. GOff íP.ISSIO., Anchorage THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ 100. 00 100.00 BPEXPLORATION, (ALASKA) INC. P.O. BOXJ 96612 ANCHORAG.E,ALASKA99519-6612 FIRST NATIONAL BANK OF ASHLAND ANAFFlUATE OF NATIONAl CITY BANK CLEVELAND, OHIO No. H 206710 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 412 00206710 PAY OI~E'.HUNDRED & 00/100************************************* US DOLLAR DATE 04/11/02 AMOUNT $100. 00 To The ORDER Of ALASlkÂ OIL AND GAS c;ONSERV"TIOI)iCOMMISSION 338t,JES] 7TH AVENUE SU.ITE...\l.ØO ANCHORAG.E NOTVALlD AFTER 120 DAYS AK 99501 \2- ~~;l/t,:l~ II. 2 0 b ? . 0 118 I: 0... . 2 0 :18 g 51: 0 0 8 ...... . g 118 , "" ''', ~ '" -'-"" "'" . ..... ~"-"'..', . ...-. .. ~ . ~ . .. CHECK 1 ST ANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL EXPLORATION INJECTION WELL INJECTION WELL REDRILL Rev: 5/6/02 C\jody\templates , , ... TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~'p¿' /1/('- /)" , CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT HOLE (PH) v "CLUE" The permit is for a new wellbore segment of existing well ---' Permit No, API No. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). ANNULAR DISPOSAL Please note that an disposal of fluids generated. . . INTO ANNULUS OF ANOTHER WELL ON SAME PAD L-> SPACING EXCEPTION Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. WELLPERMITCHECKLlST COMPANY APÀ WELLNAM~4 h/.f"~'; PROGRAM: Exp- Dev- Redrll- Se~'X- Wellboreseg- Ann. disposal para req- FIELD & POOL -Ç<..~/o/ð INITCLASS /-~LÅ~T GEOLAREA I??O UNIT# I/.~/-~ ON/OFFSHORE ~~ ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . ~ . . . . . 1'0 N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. .. . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is well bore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N AiYR 9}\ TEl 12. Permit can be issued without administrative approval.. . . . . Y N /<Ie 5j.?ð/ ó2- 13. Can permit be approved before 15-day wait.. . . . . . . . . . ~ N ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . él2~N 'Z-<? If <p 112.. í 15. Surface casing protects all known USDWs. . . . . . . . . . . N 16. CMT vol adequate to circulate on conductor & surf csg. . . . . N 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . .y N ,,\J/A 18. CMT will cover all known productive horizons. . . . . . . . . . & N 19. Casing designs adequate for C, T, B & permafrost. . . . . . . c¡¿~. N . ' ¡ 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N ~ ~ ll.fl 21. If are-drill,. has a 10-403 for abandonment been approved. . . 1''' /1\;- 22. Adequate wellbore separation proposed~~~ ... . . . . . . . .-. . ~N 23. If diverter required, does it meet regulations. . . . . . . . . . . N 24, Drilling fluid program schematic & equip list adequate. . . . . " N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . Y N - tL/f- APPRA- DATE? 26. BOPE press rating appropriate; test to psig.. Y N' ,~ \tJGf1 sl ~(01" 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . QN 28. Work will occur without operation shutdown. . . . . . . . . . . éi) N 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y @ 30. Permit can be issued w/o hydrogen sulfide measures. . . . . CJ> N 31. Data presented on potential overpressure zones. . . . . .. Æ /J / LJ 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . N / V ýn. APPR 9~T_E¡ 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . Y N ~ f.~ II 2. 34. Contact name/phone for weekly progress reports [exploratory 0 y] Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: RPy/{¿ GEOLOGY ) APPR DATE 11~. ~~Ä>Z Y N/ Y /u, /1.., Commentsllnstructions: JDH WGA VJ41t- 011- COT DTS 0 dID_rf~ G:\g eology\permits \checklist. doc Well History File APPENDIX Infonnation of detailed nature that is not particularly germane to the Welt Pennitting Process but is part of the history file. To improve the readabiHty of the Well History file and to simpltfy finding information, information of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronologically organize this category of infonnation. d?C9 ..//3 II;} lip Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Oct 14 16:29:54 2002 Reel Header Service name............ .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 02 /10/14 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 t e. . . . . . . . . . . . . . . . . . . . . 02 /10/14 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-11 500292309200 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 14-0CT-02 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 AK-MW-22101 B. HENNINGSE E. VAUGHN MWDRUN 2 AK-MW-22101 B. HENNINGSE E. VAUGHN MAD RUN 2 AK-MW-22101 B. HENNINGSE E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 12 12N 10E 3338 79 66.60 39.10 # WELL CASING RECORD 1ST STRING ')'\Tfì C"'T'T"IT1\T(" OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 20.000 111.0 ( 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1 & 2 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS¡ ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4)¡ COMPENSATED NEUTRON POROSITY (CNP) ¡ STABILIZED LITHO-DENSITY (SLD). 4. MAD PASS DATA WERE ACQUIRED OVER THE INTERVAL 5380'MD-5640'MD. THESE DATA WERE ACQUIRED DURING A SHORT TRIP AFTER REACHING TD. 5. LOG AND DIGITAL DATA ONLY WERE SHIFTED TO A SCHLUMBERGER CASED- HOLE GAMMA RAY LOG RUN IN MPS-11 ON 1 JULY 2002. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. THESE PDC LOG DATA WERE PROVIDED BY DEWAYNE SCHNORR ON 7 OCTOBER 2002. 6. MWD RUNS 1 & 2 REPRESENT WELL MPS-11 WITH API#: 50-029-23092-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 5939'MD/4485'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SRAT = SMOOTHED RUNNING SPEED WHILE NOT 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. SPSF = SMOOTHED NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) . SNFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. SNNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (T,OW-C'OTThI'T' T"lT"T\ ( HOLE SIZES: 9.875" MUD WEIGHT: 8.7 - 9.3 PPG MUD SALINITY: 800 - 1000 PPM CHLORIDES FORMATION WATER SALINITY: 25,000 PPM CHLORIDES FLUID DENSITY: 1.0 GICC MATRIX DENSITY: 2.65 GICC LITHOLOGY: SANDSTONE $ File Header Service name............ .STSLIB.001 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .02/10/14 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 ROP FCNT NCNT NPHI PEF RHOB DRHO GR RPX FET RPS RPM RPD $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 109.5 299.0 299.0 299.5 309.0 309.0 309.0 338.0 348.0 348.0 348.0 348.0 348.0 STOP DEPTH 5941.0 5852.0 5852.0 5852.0 5861.0 5861.0 5861.0 5891.0 5901.0 5901.0 5901.0 5901.0 5901.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ----- BASELINE 109.5 343.5 351.0 366.5 428.5 456.5 471.5 ¡:; /11 ¡:; DEPTH GR 111.5 345.5 351.5 367.0 429.0 457.0 470.0 753.5 763.0 779.5 790.0 796.5 807.0 827.0 832.5 848.5 859.5 872.5 878.0 891.0 949.5 1009.5 1041.0 1095.5 1103.5 1118.5 1131.5 1150.0 1157.0 1175.0 1182.0 1189.5 1220.0 1226.0 1254.0 1263.5 1278.0 1283.0 1288.0 1350.5 1358.0 1382.0 1393.0 1460.0 1543.5 1585.0 1632.5 1640.0 1673.5 1698.5 1829.0 1862.5 1869.5 1894.5 1915.5 1922.5 1959.5 1970.0 2003.0 2030.5 2063.5 2095.5 2099.5 2111.5 2120.5 2133.0 2157.5 2182.0 2220.0 2271.5 2279.5 2299.0 754.5 763.5 780.0 790.5 797.5 807.0 828.5 834.0 850.0 860.5 873.0 879.0 892.0 950.0 1010.0 1042.0 1096.5 1104.5 1119.5 1132.5 1151.5 1158.5 1176.0 1183.5 1189.5 1221.0 1226.5 1256.5 1264.5 1279.0 1284.0 1288.0 1349.5 1358.5 1383.0 1394.0 1461.5 1544.0 1586.5 1632.5 1641.0 1674.5 1700.0 1830.5 1863.5 1870.0 1895.5 1916.0 1923.5 1960.5 1971.0 2004.5 2031.5 2065.0 2097.0 2101.0 2112.5 2122.0 2134.5 2160.5 2183.0 2222.0 2273.5 2279.5 2299.5 2331.0 2344.5 2373.5 2384.5 2398.5 2418.5 2465.0 2486.5 2496.0 2558.5 2563.0 2576.0 2629.0 2651.5 2669.0 2694.5 2698.5 2744.5 2758.5 2789.0 2816.5 2919.0 2932.0 2937.0 2943.5 2950.0 2968.0 2984.0 2999.0 3017.5 3037.0 3080.5 3082.5 3086.5 3112.5 3120.5 3151.0 3161.0 3175.0 3183.0 3189.5 3199.0 3209.5 3236.5 3265.5 3290.5 3295.5 3301.5 3311.0 3331.0 3350.0 3361.0 3367.5 3408.0 3428.5 3465.5 3490.5 3495.0 3545.0 3564.5 3581.5 3587.0 3601.0 3606.5 2332.0 2343.5 2372.5 2385.0 2397.5 2419.5 2463.0 2486.0 2493.0 2557.5 2562.5 2574.0 2626.5 2651.0 2666.0 2694.0 2700.0 2746.0 2758.5 2788.0 2816.0 2918.0 2930.0 2935.5 2942.0 2948.5 2967.5 2984.0 2998.5 3018.5 3038.0 3079.0 3081.5 3084.5 3111.5 3120.0 3150.0 3159.5 3174.5 3182.0 3188.5 3198.0 3209.5 3233.5 3265.0 3290.0 3294.5 3299.5 3309.5 3331.5 3349.0 3359.5 3365.0 3407.0 3427.5 3463.0 3490.0 3496.0 3543.5 3562.5 3579.5 3585.5 3601.5 3606.0 ""1"'""''' r'\ 3623.5 3648.0 3681.0 3698.5 3714.5 3718.0 3727.5 3765.0 3776.5 3788.0 3791.5 3801.0 3809.0 3863.5 3886.5 3893.5 3942.0 3958.5 3985.5 3997.0 4015.0 4029.0 4048.5 4069.0 4120.0 4126.0 4138.5 4144.0 4148.5 4187.0 4215.0 4255.0 4262.0 4269.0 4284.5 4297.0 4357.0 4360.5 4380.0 4382.5 4392.0 4394.5 4410.5 4435.5 4445.0 4465.5 4486.5 4528.0 4533.0 4538.0 4554.0 4570.5 4591.5 4608.5 4619.0 4629.0 4640.5 4645.0 4653.5 4670.0 4678.5 4687.5 4699.0 4718.5 4711 n 3622.5 3646.0 3679.5 3697.5 3713.0 3716.5 3725.5 3762.5 3776.5 3786.0 3790.5 3798.5 3808.5 3863.0 3885.5 3892.0 3940.0 3956.0 3982.5 3996.0 4013.5 4028.5 4045.5 4067.0 4117.5 4124.5 4135.5 4141.0 4145.5 4185.5 4213.0 4252.5 4260.5 4267.5 4283.0 4293.5 4353.5 4358.0 4377.5 4380.0 4391.0 4394.0 4407.5 4434.5 4442.5 4461.5 4483.0 4525.5 4530.0 4535.0 4550.0 4569.0 4589.5 4607.5 4616.5 4626.0 4638.0 4643.0 4651.5 4670.0 4677.0 4684.5 4695.5 4716.5 1~,..,'7 - 4742.5 4748.0 4764.0 4773.5 4779.0 4787.0 4800.5 4816.5 4825.5 4878.0 4910.5 4936.0 4961.5 4970.0 5004.5 5018.0 5043.0 5096.0 5110.0 5118.5 5125.0 5143.5 5168.5 5205.0 5214.0 5228.5 5250.5 5272.0 5281.5 5299.5 5308.0 5312.0 5320.5 5337.0 5345.5 5376.5 5392.0 5402.5 5418.0 5434.5 5474.0 5490.0 5507.5 5528.0 5564.0 5586.5 5606.0 5621.0 5652.0 5681.0 5690.0 5702.5 5735.0 5762.5 5772.5 5780.0 5794.0 5941.0 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ 4739.0 4746.0 4761.5 4770.0 4774.5 4785.5 4799.0 4815.0 4822.0 4876.5 4906.5 4932.0 4959.0 4968.0 5001.0 5015.5 5040.5 5092.5 5107.0 5116.0 5122.5 5141.5 5166.5 5202.5 5212.0 5225.5 5249.0 5269.0 5279.5 5296.5 5305.0 5308.5 5317.5 5333.5 5342.0 5374.0 5388.5 5398.5 5415.5 5432.0 5471.0 5486.0 5506.0 5528.5 5560.5 5583.5 5601.5 5618.0 5648.5 5676.0 5687.5 5701.5 5735.0 5760.5 5770.5 5778.0 5792.0 5939.0 BIT RUN NO MERGE TOP 1 111.5 2 2800.0 MERGE BASE 2800.0 5939.0 ( # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type... ...............0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point.... "'."'" .Undefined Frame Spacing.... ................ .60 .1IN Max frames per record............ . Undefined Absent value.. . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 109.5 5941 3025.25 11664 109.5 5941 ROP MWD FT/H 0.9 5889.07 337.124 11664 109.5 5941 GR MWD API 13.16 120.81 67.5373 11107 338 5891 RPX MWD OHMM 0.13 331.53 31.5941 11107 348 5901 RPS MWD OHMM 0.18 2000 50.3284 11107 348 5901 RPM MWD OHMM 0.23 2000 88.7829 11107 348 5901 RPD MWD OHMM 0.14 2000 113.435 11107 348 5901 FET MWD HOUR 0.03 8.31 0.39716 11107 348 5901 NPHI MWD PU-S 12.82 68.44 43.3202 11052 299.5 5852 FCNT MWD CNTS 403 807 500.693 11076 299 5852 NCNT MWD CNTS 2008 3304 2401.59 11107 299 5852 RHOB MWD G/CM 1.12 2.73 2.09302 11082 309 5861 DRHO MWD G/CM -0.31 0.72 0.099316 11082 309 5861 PEF MWD BARN 0.15 4.72 1.70329 11082 309 5861 First Reading For Entire File... ...... .109.5 Last Reading For Entire File......... ..5941 File Trailer Service name.. .......... .STSLIB.001 Service Sub Level Name... Version Number... "'...' .1.0.0 Date of Generation...... .02/10/14 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...... .02/10/14 Maximum Physical Record..65535 File Type......... ...... .LO Previous File Name. ... ...STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MAD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE FCNT NCNT NPHI PEF DRHO RHOB GR FET RPD RPM RPS RPX RAT $ # MERGED PBU MWD $ DATA SOURCE TOOL CODE # REMARKS: 2 clipped curves; all MAD runs merged using earliest passes. .5000 START DEPTH 5303.5 5303.5 5303.5 5306.0 5306.0 5306.0 5336.0 5346.5 5346.5 5346.5 5346.5 5346.5 5384.5 STOP DEPTH 5553.5 5553.5 5553.5 5564.0 5564.0 5564.0 5592.5 5603.5 5603.5 5603.5 5603.5 5603.5 5652.5 MAD RUN NO. MAD PASS NO. MERGE TOP 2 1 2711.5 MERGE BASE 5939.0 MERGED MAD PASS. $ # Data Format Specification Record Data Record Type.......... ..... ...0 Data Specification Block Type.. ...0 Logging Direction............. ....Down Optical log depth units... ....... .Feet Data Reference Point...... ..... ...Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD HOUR 4 1 68 28 8 NPHI MAD PU-S 4 1 68 32 9 FCNT MAD CNTS 4 1 68 36 10 NCNT MAD CNTS 4 1 68 40 11 RHOB MAD G/CM 4 1 68 44 12 DRHO MAD G/CM 4 1 68 48 13 PEF MAD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5303.5 5652.5 5478 699 5303.5 5652.5 RAT MAD FT/H 1.41 107.26 75.7247 537 5384.5 5652.5 GR MAD API 46.74 105.5 77.4145 514 5336 5592.5 RPX MAD OHMM 2.84 36.73 9.77934 515 5346.5 5603.5 RPS MAD OHMM 2.83 37.92 10.5786 515 5346.5 5603.5 RPM MAD OHMM 2.59 39.91 11.122 515 5346.5 5603.5 RPD MAD OHMM 2.3 35.41 11.0787 515 5346.5 5603.5 FET MAD HOUR 5.25 11.67 8.31984 515 5346.5 5603.5 NPHI MAD PU-S 20.26 40.84 33.931 501 5303.5 5553.5 FCNT MAD CNTS 503 724 593.649 501 5303.5 5553.5 NCNT MAD CNTS 2281 2995 2480.01 501 5303.5 5553.5 RHOB MAD G/CM 1.76 2.67 2.2822 517 5306 5564 DRHO MAD G/CM -0.04 0.31 0.0705996 517 5306 5564 PEF MAD BARN 0.94 2.73 1.80785 517 5306 5564 First Reading For Entire File......... .5303.5 Last Reading For Entire File.......... .5652.5 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number..... ..... .1.0.0 Date of Generation...... .02/10/14 Maximum Physical Record. .65535 File Type... ............ .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name........ .... .STSLIB.003 Service Sub Level Name... Version Number... ....... .1.0.0 Date of Generation. ..... .02/10/14 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 ROP 3 header data for each bit run in separate files. 1 .5000 START DEPTH 111.5 STOP DEPTH 2800.0 ( ( FCNT 301.0 2711.0 NCNT 301.0 2711.0 NPHI 301.5 2711.0 PEF 311.0 2720.0 DRHO 311.0 2720.0 RHOB 311.0 2720.0 GR 340.0 2750.0 FET 349.0 2760.0 RPD 349.0 2760.0 RPM 349.0 2760.0 RPS 349.0 2760.0 RPX 349.0 2760.0 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CNP SLD $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMPENSATED NEUTRON STABILIZED LITHO DEN # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) 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 25-JUN-02 Insite 66.37 Memory 2800.0 111.0 2800.0 .9 55.2 TOOL NUMBER PB00230HWGVR6 PB0023 0 HWGVR 6 PB0023 0 HWGVR6 PB00230HWGVR6 9.875 Spud Mud 9.00 178.0 8.0 1000 10.4 2.200 1.980 1.900 2.600 67.0 75.2 67.0 67.0 (' Data Record Type..................O Data Specification Block Type.....O Logging Direction........... .,. ...Down Optical log depth units..... "'" .Feet Data Reference Point............. . Undefined Frame Spacing............. ""'" .60 .1IN Max frames per record. ........... . Undefined Absent value....... ........... ....-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 NPHI MWD010 PU-S 4 1 68 32 9 FCNT MWD010 CNTS 4 1 68 36 10 NCNT MWD010 CNTS 4 1 68 40 11 RHOB MWD010 G/CM 4 1 68 44 12 DRHO MWD010 G/CM 4 1 68 48 13 PEF MWD010 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 111.5 2800 1455.75 5378 111.5 2800 ROP MWD010 FT/H 14.34 5889.07 308.597 5378 111.5 2800 GR MWD010 API 14.91 118.09 64.4602 4821 340 2750 RPX MWD010 OHMM 0.13 331.53 51.3325 4823 349 2760 RPS MWD010 OHMM 0.18 2000 91.9612 4823 349 2760 RPM MWD010 OHMM 0.23 2000 178.094 4823 349 2760 RPD MWD010 OHMM 0.14 2000 236.595 4823 349 2760 FET MWD010 HOUR 0.03 4.14 0.373651 4823 349 2760 NPHI MWD010 PU-S 31.03 64.92 47.3065 4820 301.5 2711 FCNT MWD010 CNTS 403 591 483.057 4821 301 2711 NCNT MWD010 CNTS 2008 2680 2302.07 4821 301 2711 RHOB MWD010 G/CM 1.21 2.62 2.05187 4819 311 2720 DRHO MWD010 G/CM -0.11 0.72 0.0936398 4819 311 2720 PEF MWD010 BARN 0.08 4.72 1.85119 4819 311 2720 First Reading For Entire File..... .... .111.5 Last Reading For Entire File... ....... .2800 File Trailer Service name........... ..STSLIB.003 Service Sub Level Name... Version Number........ ...1.0.0 Date of Generation...... .02/10/14 Maximum Physical Record..65535 File Type. . . . . . . . . . . . . . . .LO Next File Name.......... .STSLIB.004 Physical EOF T:1il (' Service name............ .STSLIB.004 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation.. .... .02/10/14 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NCNT FCNT NPHI PEF DRHO RHOB GR RPD FET RPM RPS RPX ROP $ 4 header data for each bit run in separate files. 2 .5000 START DEPTH 2711.5 2711.5 2711.5 2720.5 2720.5 2720.5 2750.5 2760.5 2760.5 2760.5 2760.5 2760.5 2800.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CNP SLD $ STOP DEPTH 5850.0 5850.0 5850.0 5859.0 5859.0 5859.0 5889.0 5899.0 5899.0 5899.0 5899.0 5899.0 5939.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMPENSATED NEUTRON STABILIZED LITHO DEN # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: '''TTn ("'ITTT""" 26-JUN-02 Insite 66.37 Memory 5939.0 2800.0 5939.0 28.7 55.7 TOOL NUMBER PB00230HWGVR6 PB0023 0 HWGVR 6 PB0023 0 HWGVR 6 PB00230HWGVR6 9.875 Spud Mud 9.25 134.0 R () ( 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: 10.8 4.500 3.490 3.500 4.000 82.0 107.6 82.0 82.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type... ..0 Logging Direction... ............. . Down Optical log depth units.......... .Feet Data Reference Point......... .., ..Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absen t value...................... - 9 9 9 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP 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 NPHI MWD020 PU-S 4 1 68 32 9 FCNT MWD020 CNTS 4 1 68 36 10 NCNT MWD020 CNTS 4 1 68 40 11 RHOB MWD020 G/CM 4 1 68 44 12 DRHO MWD020 G/CM 4 1 68 48 13 PEF MWD020 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2711.5 5939 4325.25 6456 2711.5 5939 ROP MWD020 FT/H 0.9 1276.14 361.605 6278 2800.5 5939 GR MWD020 API 13.16 120.81 69.8Rq ñ?7R ')7¡::;n ,... RP" MT.Tn n ') (\ ("\TT'I\ Ir1\fr First Reading For Entire File...... ... .2711.5 Last Reading For Entire File...... ... ..5939 File Trailer Service name.... ........ .STSLIB.004 Service Sub Level Name. . . Version Number.... ..... ..1.0.0 Date of Generation...... .02/10/14 Maximum Physical Record. .65535 File Type.... ....... ... ..LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number..... ..... .1.0.0 Date of Generation...... .02/10/14 Maximum Physical Record..65535 File Type................LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MAD Curves and log DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NUMBER: # FILE SUMMARY VENDOR TOOL CODE NPHI NCNT FCNT RHOB PEF DRHO GR RPX RPS RPM RPD FET RAT $ 5 header data for each pass of each run in separate files. .5000 2 1 START DEPTH 5300.5 5300.5 5300.5 5303.0 5303.0 5303.0 5332.5 5343.0 5343.0 5343.0 5343.0 5343.0 5381.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: STOP DEPTH 5551.0 5551.0 5551.0 5560.5 5560.5 5560.5 5589.0 5599.0 5599.0 5599.0 5599.0 5599.0 5649.0 11-0CT-02 Insite 66.37 Memory 5640.0 5380.0 5640.0 28.7 MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CNP SLD $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMPENSATED NEUTRON STABILIZED LITHO DEN # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.... ...... ........0 Data Specification Block Type. ....0 Logging Direction.... ...... ..... ..Down Optical log depth units.. ........ .Feet Data Reference Point... .... ..... ..Undefined Frame Spacing......... ..... ..... ..60 .1IN Max frames per record... ..... .... . Undefined Absent value......... ...... ..... ..-999 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 55.7 TOOL NUMBER PB00230HWGVR6 PB00230HWGVR6 PB0023 0 HWGVR 6 PB0023 0 HWGVR 6 9.875 Spud Mud 9.25 134.0 8.0 800 10.8 4.500 3.490 3.500 4.000 82.0 107.6 82.0 82.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD021 FT/H 4 1 68 4 2 GR MAD021 API 4 1 68 8 3 RPX MAD021 OHMM 4 1 68 12 4 RPS MAD021 OHMM 4 1 68 16 5 RPM MAD021 OHMM 4 1 68 20 6 RPD MAD021 OHMM 4 1 68 24 7 FET MAD021 HOUR 4 1 68 28 8 NPHI MAD021 PU-S 4 1 68 32 9 FCNT MAD021 CNTS 4 1 68 36 10 NCNT MAD021 CNTS 4 1 68 40 11 RHOB MAD021 G/CM 4 1 68 44 12 DRHO MAD021 G/CM 4 1 68 48 13 PEF MAD021 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5300.5 5649 5474.75 698 5300.5 5649 RAT MAD021 FT/H 1.41 107.26 75.3345 536 5381.5 5649 GR MAD021 API 46.74 107.53 77.6832 514 5332.5 5589 RPX MAD021 OHMM 2.84 36.73 9.53877 513 5343 5599 RPS MAD021 OHMM 2.83 37.92 10.2984 513 5343 5599 RPM MAD021 OHMM 2.59 39.91 10.8151 513 5343 5599 RPD MAD021 OHMM 2.3 35.41 10.7851 513 5343 5599 FET MAD021 HOUR 5.25 11.67 8.35365 513 5343 5599 NPHI MAD021 PU-S 20.26 40.84 33.9403 502 5300.5 5551 FCNT MAD021 CNTS 503 724 594.116 502 5300.5 5551 NCNT MAD021 CNTS 2281 2995 2479.6 502 5300.5 5551 RHOB MAD021 G/CM 1.76 2.67 2.28471 516 5303 5560.5 DRHO MAD021 G/CM -0.04 0.31 0.0706977 516 5303 5560.5 PEF MAD021 BARN 0.94 2.73 1.80938 516 5303 5560.5 First Reading For Entire File. ...... ...5300.5 Last Reading For Entire File.......... .5649 File Trailer Service name........... ..STSLIB.005 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .02/10/14 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Next File Name.......... .STSLIB.006 Physical EOF Tape Trailer Service name...... ...... .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 02 / 10/ 14 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 t e. . . . . . . . . . . . . . . . . . . . . 02 /10 / 14 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name. ... ........... . UNKNOWN Continuation Number.... ..01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF ar~d 81'1 JO PU3: )