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Home My WebLink About202-241CAUTION: 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: Produced Water Injector MPS-20 (PTD# 202-241) Anomalous IA Pressure Date:Tuesday, March 21, 2023 2:07:55 PM Attachments:image001.png image002.png From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Friday, March 17, 2023 10:04 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov>; David Haakinson <dhaakinson@hilcorp.com> Subject: NOT OPERABLE: Produced Water Injector MPS-20 (PTD# 202-241) Anomalous IA Pressure Mr. Wallace, Produced Water Injector MPU S-20 (PTD# 202-241) was made UNDER EVALUATION due to an Anomalous IA Pressure on February 16th. A failing MIT-IA was conducted on February 17 with a LLR of 0.45 bpm and was immediately shut in. Further diagnostics and repair are currently being evaluated. The well is now classified as NOT OPERABLE and will remain shut in until an appropriate repair is completed. Please respond with any questions or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 From: Jerimiah Galloway Sent: Thursday, February 16, 2023 2:55 PM To: 'Wallace, Chris D (CED' <chris.wallace@alaska.gov>; 'Regg, James B (CED' <jim.regg@alaska.gov>; David Haakinson <dhaakinson@hilcorp.com> Subject: UNDER EVALUATION: Produced Water Injector MPS-20 (PTD# 202-241) Anomalous IA Pressure Mr. Wallace, Produced Water Injector MPU S-20 (PTD# 202-241) is currently a dual string injector only injecting down one string. The inner annulus was bled on 2/16/2023 in order to establish a differential between the tubing and annulus. The annulus was bled to ~300 psi and after being shut in, quickly returned to the pre-bleed pressure. This repressurization indicates a possible tubing by annulus leak and requires additional diagnostics. The well is now classified asUNDER EVALUATION. The well is to remain online in steady state while initial diagnostics are conducted. It is now on a 28 day clock for diagnostics and resolution. Plan Forward: 1. PPPOT-T 2. MIT-IA 3. Engineer to evaluate additional diagnostics as needed. Please respond with any questions or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intendedrecipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error,please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message andany 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 itconsiders appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Produced Water Injector MPS-20 (PTD# 202-241) Anomalous IA Pressure Date:Thursday, February 16, 2023 3:32:55 PM Attachments:image001.png image002.png From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Thursday, February 16, 2023 2:55 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov>; David Haakinson <dhaakinson@hilcorp.com> Subject: UNDER EVALUATION: Produced Water Injector MPS-20 (PTD# 202-241) Anomalous IA Pressure Mr. Wallace, Produced Water Injector MPU S-20 (PTD# 202-241) is currently a dual string injector only injecting down one string. The inner annulus was bled on 2/16/2023 in order to establish a differential between the tubing and annulus. The annulus was bled to ~300 psi and after being shut in, quickly returned to the pre-bleed pressure. This repressurization indicates a possible tubing by annulus leak and requires additional diagnostics. The well is now classified as UNDER EVALUATION. The well is to remain online in steady state while initial diagnostics are conducted. It is now on a 28 day clock for diagnostics and resolution. Plan Forward: 1. PPPOT-T 2. MIT-IA 3. Engineer to evaluate additional diagnostics as needed. Please respond with any questions or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intendedrecipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error,please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message andany 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 itconsiders appropriate. MEMORANDUM TO: Jim Regg GG�� P.I. Supervisor V\ qj 31-26l/!j FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, March 22, 2019 SUBJECT: Mechanical Integrity Tests HILCOP-P ALASKA LLC S-20 MILNE PT UNIT S-20 Src: Inspector Reviewed By: P.I. Supry J `-- Comm Well Name MILNE PT UNIT S-20 API Well Number 50-029-23132-00-00 Inspector Name: Lou Laubenstein Permit Number: 202-241-0 Inspection Date: 3/16/2019 ' IBsp Num: mi[LOLI90316160540 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well i S-20 Type Inj u TVD - 4125 - Tubing 540 540-- 539 - 539 — PTD 2022410 Type Test sPT Test psi 1500 IA 215 1646 1609 1599 BBL Pumped: I BBL Returned:OA 183 266 239 222 Interval r avlcTST p/F P Notes: Friday, March 22, 2019 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Regg DATE: Wednesday,April 01,2015 P.I.Supervisor 'I t (el t7 SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC S-20 FROM: John Crisp MILNE PT UNIT SB S-20 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry JW-- NON-CONFIDENTIAL • Comm Well Name MILNE PT UNIT SB S-20 API Well Number 50-029-23132-00-00 Inspector Name: John Crisp Permit Number: 202-241-0 Inspection Date: 3/19/2015 Insp Num: mrtJCr150325123101 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min S-20 J w"TVD 4125 I Tubing', 700 _ 700 700 - it Well� 700- , 'Type a In' PTD i 2022410 -jTypeTestLSPT Test; psi I 1500 IA IT 346 i 1746 - ,. 1690 - 1688 Interval 14YRTST PAF ! P / OA 1 200 -1 300 -- 300 ' 300 •I Notes: Dual injector with 700 psi on SS and LS 1 16 bbls pumped for test SCANNED Wednesday,April 01,2015 Page 1 of 1 . RECEIVED STATE OF ALASKA A,_ ,.iKA OIL AND GAS CONSERVATION COMMISSION DEC 0 6 2013 REPORT OF SUNDRY WELL OPERATIONS OGCC 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U MBE Treatment ' Performed: Alter Casing ❑ Pull Tubing0 Stimulate-Frac ❑ Waiver ❑ Time ExtensionE 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 Development Exploratory ❑ 202-241-0 • 3.Address: P.O.Box 196612 Stratigraphic❑ Service 0 6.API Number: 00 Anchorage,AK 99519-6612 50-029-23132:84;00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0380109 • SBL MPS-20SS 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): MILNE POINT,SCHRADER BLFF OIL . 11.Present Well Condition Summary: Total Depth measured 7190 feet Plugs measured None feet true vertical 4344.31 feet Junk measured None feet I Effective Depth measured 7104 feet Packer measured See Attachment feet true vertical 4279.44 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None ' Conductor 78 20"X 34"215.5#A53 34-112 34-112 0 0 Surface 2957 9-5/8"40#L-80 33-2990 33-2525.85 5750 3090 Intermediate None None None None None None Production 7157 7"26#L-80 32-7189 32-4343.56 7240 5410 Liner None None None None None None I Perforation depth Measured depth 6934-6964 feet True Vertical depth 4152.41-4174.39 feet SCANNED •A N 2 ,7 2014 Tubing(size,grade,measured and true vertical depth) 2-3/8"4.7#L-80 31-6922 Gi 31-411143.74 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): 6934'-6964' Treatment descriptions including volumes used and final pressure: 15 Bbls 15.8 ppg Acid Soluble Cement,493 psi;5 Bbls 15.8 ppg Acid Soluble Cement,500 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 404 0 493 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development❑ Service la • Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ GSTOR ❑ WINJ 0 • WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-484,4g2- Contact Garry Catron Email Garry.Catron(a�BP.Com Printed Name Garry Catron Title PDC PE Signature ikf 1/%1 1.., Phone 564-4424 Date 12/6/2013 r VL r RBI MS DEC 16 20N i //c /iq Form 10-404 Revised 10/2012 44. 'yliY Submit Original Only Packers and SSV's Attachment ADL0380109 SW Name Type MD TVD Depscription MPS-20SS PACKER 6896 4052.79 2-3/8" Baker GT Dual Packer MPS-20SS PACKER 6974 4109.42 7 X 2.375 Baker FH Ret Packer II -o a) a) ✓T Q) c N Q N CO T� O• a) E O -o Q U 0) D N LO (a O CL U �' - _ Q. N o * O C Q LL - D _c LL 7 — N a _ O (d O O (6 Q) c O 7 = C) N . O O c O) C'CO N N y o N Q 11 .y n O N N 2 N Y 0 --1 u) w .= U) Q L Q E .Q o a) c_ E * O a) N cr)_ '� m 0 U U) Q O L o Ca * C a) N• - Q t Ca rn Q _ _ fl (N 3 co y o 3 o Q, > o c o _o co U a) co a -Q °v o E E °c) E 0) C oo uj Q O c •E b_ E >, >, d O CO c Q v -0 '-I II-o -a co ° 3 = o _o `_' v Chu a) ° � o °o a) C 0) co p .� c C -t (d C 0 N O Q CO > Q U) c u_. 0) m U) U O O O 0) 0 ca C U) D -0 2 o Q c (n a) o N in O > C cn N 0 co CU 3 II O ° •b e 0) c 0 (3(.0 * o) U) c a�'i ° _ "U c a) O o o Q o * c a) C c6 a > O > W O N O . E E N * O L c p N L L * Q CC .) Q Q o Q co _� 2 aa)) * ° o U ccoo Q a) a -D C N- o a) U) - E o v ° u)•rA Q ' O) t°'/) ° * V) U U N Q E t>- O C d O O V) c a) * Cr Q 2 a) a N ° ° DcoO5 CI-0 -0 � � � � QQ aoi a � U � m O C 0) � c C � - CO a) a>) o) a) C ' m p -6 ° C TD a, Q E o c E c © 9 Q I` Q•U n O Q Q O U Q n (_, F a) OU Q u)• d � Q o a) O � � c Eo E ° � � Cl UO y c) Q- 0 01 CL V) +� a) v C U) a) 7 O c in o co rn ° °) m a J E a o a) U Q 0-. 3- E a) •.- a)) ° C N d p ° ° O �_ o o Q O 10 a) o o CO = (n Q c m c O a) p)E c . m 3 N a) CL ca d3 0 a, c O a) (1) --9N- c...) O `F' O C Q N O O 0 _ co .0 O E N U) U) U O N U) ~ a CL > E (n O CIO ° t 1 L U Q cn Q O m CU _C C CL N > > U 4_ Cl c o O Q (ten in � m u) � .� O c°a o f .c D Q -o E C C E . 5 L .c .° o c N CO .- u) * Q 2 C o-2 m C O u) o m W N N O Q O C O o m O W U) U C < 0 Q O` '' I I o J C 0 +`-. 0 Q O CV O > (II A 0t-0 ( � .'c CO c0• - ,_ oo EO u) E om a -0 (D E x o QNn� 0) .� N a) (N c �, C U) O C t N C) a, Ca O (ti J U Q Q Lo -0 0 O S Q a CI (n C ' U) Q w C Q 0 a, N I- F- O " c U) D N u) `- (Dc Q V O a) 2 aoID°m CD D-C ■ . Q.0 E c000 ° ° 0) °o ~ a) a25 _1 � u°, (o � ii) � � c°"JIL CO -0 N o .0 co U) tf) -o ,- O O c U) N N D p) o a) -0 a) -O U) -O D () o p +`' C Q( m `- c .c N ,- , C o o- U) W C o U) L.0 D U) O J Q 2 a) O a, o o p o ° > o° —) CO 0) (ti 00 C) (n o w o o° N .F u) u) w _, 0-o D Q- " o cn 0 0� o °' ou) a m Qa) vo o = O 0) oou) Q0 r Qy (°n a) cn -o °) E o _ rn O o C 'O c D '-. • N W I I O c O 7 L c O �O CD _O O— p 4- I I a, U N ---I O E 3 -0 Q(n Q Q C I I CO 11 J a) ?� c3,•- 11 L › 11 U d o > c D Q-a+ Q U 0 U) 11 7 o a) 15045a--- = O a ,._ .- o m m y > O CU c O O o ? .o o w rn a)m o o Oa) o aa) c sH 3 > H D U * O ,_ (n � � H 3U - -O n.11 * QU Q� o (n QZ _c 1- Cl_ .Eco _c co co co M CO CO CO M O O O O O ,_ T N N N N N O O O M 00 O N N N N N N N Cr) O O O O O r H w O O H w J z N cn O ++ N L CDp Q� 7 Q v p C) o co O r p Q.' w LL1 It O J — <- 0 < 7 � -W' a * v az < 0 *, v Q W w Q U cn W in > ZCDUZ C Hosw � O ' w > 7, 000w J O W J A c W' J W A - 5 W • Z cc 5 * A < A C H CY) 0 N 0) Tree: CIW 2 1/16"5M Dual_ MPS-20i Orig. KB Elev. =72.40' Wellhead:11"x 2 3/8"5M FMC dual string Hanger thread 2 3/8"EUE top and IBT bottom 1 Orig. GL Elev. =38.40' 2"CIW-H BPV profile i [ 20"x 34"insulated,215#/ft A-53 112' Short String Long String 3015' 2-3/8"HES X-Nipple(1.875"pkg.bore) _ ;" 2-3/8"HES X-Nipple(1.875"pkg.bore) 3013' KOP @ 750' Max. hole angle=70 deg @ 4000' Hole angle thru perfs =45 deg 2990' 9 5/8"HOWCO Float Shoe , 1 9 5/8"40#L-80 BTRC Casing (drift id=8.679,cap.=.0282 bpf) 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) 6851' 2-3/8"HES X-Nipple(1.875"pkg.bore) 2-3/8"HES X-Nipple(1.875"pkg.bore) 6851'it 7"x 2-3/8"Baker"GT"Ret.dual pkr. 6896' L....� 1.945"ID. 6910' 2-3/8"HES XN-Nipple(1.875"pkg.bore) ci No-Go 1.791" 6922' Tubing tail/WLEG 7 Perforation Summary miummi 1(T(f J 7"x 2-3/8"Baker"FH"Ret.pkr. 6974' 2.41"ID. Size Spf Interval (TVD) OA sands XN 2-3/8"HES XN-Nipple(1.875"pkg.bore) 6985` No-Go 1.791" 4 5/8" 5 6934'-6964' 4153'-4175' II OB sands - 2-3/8"Baker'E'Hydro Trip Sub 4 5/8" 5 7002'-7027' 4203'-4222' ; w/6'muleshoe pup(bottom depth) 6995' (1.97"bore) NN Hydro Trip Sub ELMD 6988' 1.75"Delrin Ball. 7104' 7"HES Float Collar PBTD 7189' 7"HES Float Shoe A DATE REV. BY COMMENTS 11/13/02 J.Jones MILNE POINT UNIT Drilled by Cased Doyon 141 WELL No.: S-20i 03/21/03 Lee Hulme Completion Rig 4ES API : 50-029-23132-00 BP EXPLORATION (AK) v,\ �V7,cv THE STATE Alaska Oil and Gas 1 1 1 1 S Kl 1 Conservation Commission am_ - - Th GOVERNOR SEAN PARNELL 333 West Seventh Avenue pF C SY'.- Anchorage, Alaska 99501-3572 ALA Main: 907.279.1 433 3 kJ Fax: 907.276.7542 Alecia Wood Petroleum Engineer �r n BP Exploration(Alaska), Inc. 6 Q d� P.O. Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Field, Schrader Bluff Oil Pool, SBL MPS-20SS Sundry Number: 313-482 Dear Ms. Wood: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair DATED this 13 day of September, 2013. Encl. • C.-- �� E, E1VED • STATE OF ALASKA �`,�\� SEP 0 9 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGG 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well Stimulate❑ Alter Casing❑ Other: MBE Treatment 0 ' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Development ❑ Exploratory ❑ 202-241-0 . 3.Address: 6. PI Number.. i2'r' l_3/„..32_ '�' Stratigraphic ❑ Service ,�`, c"�, 5--0 P.O.Box 196612,Anchorage,AK 99519-6612 2313241-06 'J.it 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? AA447.05 SBL MPS-20SS - Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0380109. MILNE POINT,SCHRADER BLFF OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 7190 . 4344 - 7104 4279 None None Casing Length Size MD 7VD Burst Collapse Structural Conductor 78 20"X 34"215.5#A53 34-112 34-112 Surface 2957 9-5/8"40#L-80 33-2990 33-2525.85 5750 3090 Intermediate None None None None None None Production 7157 7"26#L-80 32-7189 32-4343.56 7240 5410 Liner None None None None None None Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(It): 6934-6964 4152.41-4174.39 2-3/8"4.7#L-80 L-80 31-6922 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and TVD(It): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development ❑ Service 0 . 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 9/16/13 Oil ❑ Gas ❑ WDSPL ❑ Suspended 16.Verbal Approval: Date: WINJ 0 • GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Alecia Wood Email Alecia.Wood( IBP.com Printed Name Alecia Wood Title PE Signature ,` `� Phone Date -t' Ul./i 564-5492 9/5/2013 COMMISSION USE ONLY 1 Conditions of approval: Notify Commission so that a representative may witness Sundry Number 'L.'S"' 4. Z Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ `- ) OCT 1 0 20.3 Other: �� Spacing Exception Required? Yes ❑ No d Subsequent Form Required: / 0— D 4 r APPROVED BY Approved by:O COMMISSIONER THE COMMISSION Date:C7 / 3 - / 3 v1 -- 4/130/3 l Form 10-403 Revised 1/2010 Approv i -s id orn12 onths from the date of approval. ``�� it in Duplicate i�1(�� • by • To: Mark O'Malley/Rob Handy Date: September 05, 2013 MPU Ops Team Leaders From: Alecia Wood, MPU Schrader Pad Engineer 907-564-5492 Subject: MPS-20SS MBE Treatment Step Unit Operation 1 F Shut in all offset producers. Bullhead water into MPS-20SS 2 F Bullhead treatment down MPS-20SS (OA sand). Keep well and offset producers and injectors shut in for the duration of the treatment and flow producers to a tank before returning to production if necessary. 3 C Pending the post cement injectivity tests, perform a fill clean out and possible (Pending) 15bbl HCL acid soak to attempt to regain injectivity. _ Objective: Divert water by sealing the preferential path of injection with a cement acting fluid and a rigid gel. Should the cement or gel lock up the wellbore, a contingent acid job will be performed. Measure of success: 1. Treatments are displaced into formation. 2. Post injection is adequate to achieve injection rate target at below target pressure. 3. Decrease of watercut over time in offset producers is observed. Critical Issues: 1. Ensure pumping pressure during gel stage is not above the fracture gradient. 2. Ensure cleanliness of pump equipment and hard line (pre and post job) & properly dispose of remnant fluid per guidance from the Environmental Team. Background MPS-20 is a dual completed injector with two strings of 2-3/8" tubing in the OA and OB sands of the Schrader Bluff reservoir. This injector was completed in June 2003 to support offset producers MPS- 17, MPS-19A, and MPH-08B. MPS-20SS had extremely high injectivity and could not inject without the help of a downhole choke to reduce the injection rate and supply back pressure. An MBE between MPS-17 and this injection string was confirmed with a red dye tracer. It was believed that this well may also have an MBE to MPS-19A in this zone but it was not confirmed. MPS-20SS had an MBE treatment pumped in August 2011 which was successful until June 2012. The MBE treatment reduced the injectivity in the short string so that it no longer required a downhole choke. Red dye tracer tests in early 2013 confirmed that there is an active MBE between MPS-20SS and MPS-17. A positive Red dye tracer test in the LS lead to the confirmation of pressure communication between the long and short strings. It is believed to be communicating not through an OB MBE, but rather from the LS through a channel to the SS, and to MPS-17 through the existing OA MBE. This treatment will be pumped fullbore through the short string. The purpose of this treatment is to reduced water cycling to the producer and increase sweep and VRR in the hydraulic unit. Additionally, this treatment will attempt to plug the string communication from the SS to the LS. 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 or methanol displacement. Allow setup time. 7. Perform injectivity test following cement stage. Should well exhibit zero injectivity, perform CT fill clean out with possible 15bbl HCL acid soak to attempt to regain injectivity into the wellbore. 8. Pump produced water pre-flush followed by a second stage of cement acting fluid treatment, holding pressure on the offset Producer connected by the Matrix Bypass Event. Attempt to squeeze second stage of cement and displace with diesel or methanol. Allow setup time. 9. Perform injectivity test following cement stage. Should well exhibit zero injectivity, perform CT fill clean out with possible 15bbl HCL acid soak to attempt to regain injectivity into the wellbore. 10. Pump produced water or KCL pre-flush followed by high volume gel treatment and diesel or methanol over flush. 11. Capture a gel sample at surface and suspend in a warm water bath (to simulate downhole conditions) to monitor actual setting time. 12. Rig down all equipment and hold post job assessment meeting to capture leamings to be incorporated into future jobs. 13. Forward all post job assessments (w/all rheology test summary)and continuous pressure and rate data from job to Pad Engineer. Tree:c(VV 2 vitr 5M Dual siring W9191ead:11"x 2 3/8°5M FMC dual string MPS-20i Orig.KB Elev.=72.413' Hanger thread 2 3/8"EUE top and IBT bottom Orig.GL Elev.=MAO' 2"CIW-H BPV profile 1 1 20"it se insulated,215*lb A-53 112' Short Strina Long Strina 311-15a 2-318°HES X-48ppte(1.875°pkg.bore) 1 n 2-18'HES X-Napple(1.875'pkg.bore) 3013' KOP I 750' Max.hole angle=70 deg 4000' Hole angle tiro perfs=45 deg 2990 9 5/8"HOWCO Float Shoe I I 9 518°40#L-80 BTRC Casing (daft id=8.679,cap.=.0282 bpf) 7"26#,L-80,BTRC Casing (drift id=13.151.cap.=.0383 bpf) 2-318",4.7#81 1-80.IBT tubing (drrft id=1.801,cap.=.00387 bpf) " x 2-a.s.HES X-Nipple(1.875"pkg bore) my j 6851 2-3/8"HES X-Nipple(1.875'pkg.bore) 7"it 2-3/8"Baker"CT Ret dust pkr. 689(y 1_945'ID 2-3/8"HES XN-Nipple(1275°pkg.bore) 6G10" XN No-Go 1.791" 6927 I Tubing tall a'WLEG 'II Perforation Summary 0 i 7°x 2-18"Baker"FH"Ret.pkr. 6074" • 2.4r ID_ Size Spf interval (TVD) go 2-318"HES XN-Nipple(1.875"pkg.bore) r ag—T-15. OA sands 1 No-Go 1.781" 45/8" 5 6934'-681134' 1 4153'-4175 08 sands 2-318*Baker'E'Hydra Trip Sub 4 5/8" 5 7007-7027" 1 4203'-4222' vr/er rouleshoe pup(bottom depth) 8"45 (1.97-bore) ' I 11:1 Hydro Trip Sub ELMD [6s8 1.75"Deakin Ball. 7104' 7"HES Float Collar PBTD 7189' r HES Float Shoe DATE REV.BY COMMENTS MILNE POINT UNIT 11/13102 J.Jones Drilled by Cased Doyon 141 WELL No.:S-201 03121/03 Lee 14ulme Completion Rig 4ES API:50-029-23132-00 , . BP EXPLORATION (AK) , ....... Packers and SSV's Attachment ADL0380109 Well Facility Type MD Top Description TVD Top MPS-20SS PACKER 6896 2-3/8" Baker GT Dual Packer 4125 MPS-20SS PACKER 6974 7 X 2.375 Baker FH Ret Packer 4182 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 " Anchorage, Alaska 99519 -6612 4 SS,. N EP FEB 2 4 2017 December 30, 2011 Mr. Tom Maunder Oa - 3 4' I Alaska Oil and Gas Conservation Commission 333 West 7 Avenue O Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPS -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPS -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, (7 9 • Mehreen Vazir BPXA, Well Integrity Coordinator 0 • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) MPS -Pad 10/11/2011 I Corrosion - Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft gal MPS-01A 2070340 50029231410100 0.25 NA 0.25 NA 5.1 9/6/2011 MPS -02 2031270 50029231690000 2.5 NA 2.5 NA 23.8 7/30/2011 MPS-03 2021460 50029231050000 Open Flutes - Treated MPS-04 2030520 50029231480000 1.7 NA 1.7 NA 17.0 7/30/2011 MPS-05 2021370 50029231000000 Open Flutes - Treated MPS-06 2031090 50029231630000 1.7 NA 1.7 NA 17.0 7/30/2011 MPS-07 2020720 50029230790000 1 NA 1 NA 13.6 11/3/2009 MPS -08 2031230 50029231680000 1.3 NA 1.3 NA 10.2 7/30/2011 MPS -09 2020200 50029230670000 0.5 NA 0.5 NA 5.1 11/3/2009 MPS -10A 2051250 50029231520100 1.3 NA 1.3 NA 11.9 7/29/2011 MPS -11 2021130 50029230920000 1 NA 1 NA 10.2 7/29/2011 MPS-12 2030230 50029231390000 0.6 NA 0.6 NA 6.8 7/29/2011 MPS -13 2021240 50029230930000 1 NA 1 NA 11.9 11/3/2009 MPS -14 2031040 50029231620000 1.8 NA 1.8 NA 22.1 7/29/2011 MPS-15 2012450 50029230610000 9.6 NA 9.6 NA 88.4 7/31/2011 MPS -16 2030650 50029231510000 1.2 NA 1.2 NA 102 7/29/2011 MPS-17 2021730 50029231150000 , Open Flutes - Treated MPS -18 2022420 50029231330000 1.3 NA 1.3 NA 11.9 7/29/2011 MPS -19A 2022330 50029231210100 1.8 NA 1.8 NA 23.8 7/29/2011 sy MPS-20 2022410 50029231320000 1.3 NA 1.3 NA 11.9 7/29/2011 MPS-21 2020090 50029230650000 1.8 NA 1.8 NA 22.1 11/3/2009 MPS -22 2031470 50029231760000 9.1 NA 9.1 NA 83.3 7/28/2011 MPS -23 2021320 50029230980000 Open Flutes - Treated MPS -24 2030380 50029231420000 1.3 NA 1.3 NA 10.2 7/28/2011 MPS -25 2021030 50029230890000 Open Flutes - Treated MPS -26 2030610 50029231500000 1 NA 1 NA 8.5 7/28/2011 MPS -27 2020850 50029230840000 0.9 NA 0.9 NA 8.5 7/28/2011 MPS-28 2030940 50029231580000 1.1 NA 1.1 NA 11.9 7/28/2011 MPS -29 2021950 50029231190000 Open Flutes - Treated MPS-30 2022360 50029231310000 1.2 NA 1.2 NA 11.9 7/28/2011 MPS -31 2020140 50029230660000 Open Flutes - Treated MPS -32 2030920 50029231570000 0.8 NA 0.8 NA 6.8 7/28/2011 MPS -33A 2061720 50029231230100 1 NA 1 NA 6.8 7/28/2011 MPS-34 2031300 50029231710000 6 NA 6 NA 49.3 7/28/2011 MPS-35 2031430 50029231750000 1.2 NA 1.2 NA 11.9 7/28/2011 MPS -37 2070520 50029233550000 13.9 Need top job NA MPS -39 2081830 50029234050000 0.7 NA 0.7 NA 4.3 8/18/2011 MPS -41A 2081610 50029234010100 Sealed NA NA NA NA NA MPS-43 2081760 50029234040000 Dust Cover NA NA NA 6.8 10/11/2011 MPS-90 2051350 50029232760000 0.6 NA 0.6 NA 3.4 9/6/2011 MPSB-04 _ 500299990799 0.6 NA 0.6 NA 3.4 7/30/2011 STATE OF ALASKA ALASKA. AND GAS CONSERVATION COMMISSIO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other Ei MBE TREATMENT Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver"' Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory ❑ , 202 -2410 3. Address: P.O. Box 196612 Stratigraphic❑ Service El 6. API Number: 00`' 00 Anchorage, AK 99519 -6612 50-029-2313200.- 8. Property Designation (Lease Number) : .. 9. Well Name and Number: ADLO- 380109 MPS -20 10. Field /Pool(s): , MILNE POINT FIELD / SCHRADER BLUFF POOL 11. Present Well Condition Summary: Total Depth measured 7190 feet Plugs (measured) None feet true vertical 4344.31 feet Junk (measured) None feet Effective Depth measured 7104 feet Packer (measured) 6896 6974 feet true vertical 4279.44 feet (true vertical) 4125 4182 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 82' 20 "X34 "215.5# A -53 34 - 112 34 - 112 Surface 2957' 9 -5/8" 40# L -80 33 - 2990 33 - 2526 5750 3090 Production 7157' 7" 26# L -80 32 - 7189 32 - 4344 7240 5410 Production Liner Liner ,y 1 "� rs 6 -[ 2,011 Perforation depth: Measured depth: 0 6934 - 6964 _ ' " _ _ - _ True Vertical depth: 0 4152.41 - 4174.39 _ - _ Tubing: (size, grade, measured and true vertical depth) 2 -3/8" 4.7# L -80 31 - 6922 31 - 4144 Packers and SSSV (type, measured and true vertical depth) 2 -3/8" Baker GT Dual Packer — 6896 4125 7 X 2.375 Baker FH Ret Packer 6974 4182 RECEIVED' r 12. Stimulation or cement squeeze summary: 7 Intervals treated (measured): G 3 1 2.011 Treatment descriptions including volumes used and final pressure: v tame OK & Gas Coos. G®11111hi AnthRrlelgt 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 561 450 Subsequent to operation: 597 775 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 ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ El WAG0 GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -196 Contact Joe Lastufka Printed Na - oe Lastufk Title Petrotechnical Data Technologist ■ Signat FE Phone 564-4091 Date 8/31/2011 IP d1612°L, Form 10 -404 Revised 10/2010 R BDMS SEP 0 1 2011 1. 1 1 V v Submit Original Only • MPS -20SS DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY � E Y! JA *T. 3' "'.`i x�.'1:. °° '.°.��.^�r d " �s� ::' 'a';;'s v ":' i.. �' 8 • 9 r. .4A ,, 8/7/2011.: Pre - injection test / Thermatek on MPS- 20SS * ** T /IA/OA 500/0/180. * ** Per injection test, lead in with 1 bbl's 50/50 meth water, 33 bbl's PW, 4.6 bbl's X- linked K -max gel, :followed by PW. Leading edge of K -max gel hit perfs 0.7 bbl's early at 26.6 bbl's away. Continued pumping 38 additional bbl's PW while mixing the Thermatek. Thematek treatment- Pumped 2 bbl's K -max gel, 6.5 bbl's Thermatek, 2 bbl's K -mat 4 bbl's Thematek, 2 bbl K -max, Displace to MBE with 8 bbl's PW & 18.7 bbl's diesel. ;Over displaced Thematek with 1 bbl of K -max gel, leaving 1 bbl gel in Inr. T /IA/OA i ;940/0/180 ** *Job complete * ** 8/8/2011 Post Thermatek injectivity test on MPS- 20SS * ** T /IA/OA 0/0/180. Pumped 3 bbl's diesel confirmed injectivity at —950 psi post Termatek treatment, will return to well for H2Zero treatment. ** *Job Complete * ** 8/12/2011; ** *Pump H2Zero treatment MPS- 20SS * ** T /IA/OA 645/0/175 Lead in with 13 bbl's diesel, 411 bbl's H2Zero averaging 0.75 to 0.60 bpm at —950 psi treating pressure. Note: Found the PH probe was not reading correctly, switched to using PH strips mid; job. Displace treatment with 30 bbl's diesel. T /IA/OA 945/0/200 ** *Continued on '8/13/11*** 8/13/2011 ** *H2Zero treatment continued on MPS- 20SS * ** Finish pumping remaining 12 bbl's Idiesel over flush, secure location. ** *Thermatek / H2Zero treatment complete * ** FLUIDS PUMPED BBLS 2 50/50 METH 10.6 K -MAX GEK 95 PW 10.5 THERMATEK 84 DIESEL 411 H2ZERO 613.1 TOTAL . • Tree: CIW 2 1/16" 5M Dual string Wellhead:11" x 2 3/8" 5M FMC dual string MPS-20i Orig. KB Elev. = 72.40' Hanger thread 2 3/8" EUE top and IBT bottom Orig. GL Elev. = 38.40' 2" CIW -H BPV profile 20" x 34" insulated, 215 #/ft A -53 1112' Short String Long String 1 3015' 1 2-3/8" HES X- Nipple (1.875" pkg. bore) 2 -3/8" HES X- Nipple (1.875" pkg. bore)I 3013' KOP @ 750' Max. hole angle = 70 deg @ 4000' Hole angle thru perfs = 45 deg 2 990` 9 5/8" HOWCO Float Shoe 9 5/8" 40# L -80 BTRC Casing (drift id = 8.679, cap. = .0282 bpf) 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) 6851' 12 -3/8" HES X- Nipple (1.875" pkg. bore) 2 -3/8" HES X- Nipple (1.875" pkg. bore)! 6851' 111 11111 7" x 2 -3/8" Baker "GT" Ret. dual pkr. 1 6896' I 1.945" ID. 6910' 2-3/8" HES XN- Nipple (1.875" pkg. bore) M No -Go 1.791" ■ 6922' I Tubing tail / WLEG Perforation Summary 7" x 2 -3/8" Baker "FH" Ret. pkr. 1 6974` 2.41" ID. Size Spf Interval (TVD) OA sands �' 2 -3/8" HES XN- Nipple (1.875" pkg. bore) 6985` I ® No -Go 1.791" 4 5/8" 5 6934' - 6964' 4153' - 4175' OB sands 2 -3/8" Baker 'E' Hydro Trip Sub 4 5/8" 5 7002' - 7027' 4203' - 4222' ® w/ 6' muleshoe pup (bottom depth) 6995` (1.97" bore) Hydro Trip Sub ELMD I 6988' 1 1.75" Delrin Ball. 1 7104' I 7" HES Float Collar PBTD 1 7189` 1 7" HES Float Shoe DATE REV. BY COMMENTS 11/13/02 J. Jones MILNE POINT UNIT Drilled by Cased Doyon 141 WELL No.: S -20i 03/21/03 Lee Hulme Completion Rig 4ES API : 50 -029- 23132 -00 BP EXPLORATION (AK) • • S _ , LA11 SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Keith Lopez Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 9,D Anchorage, AK 99519 -6612 Re: Milne Point Field, Schrader Bluff Pool, MPS -20SS Sundry Number: 311 -196 S ` Dear Mr. Lopez: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. !‹ Chair DATED this 0 day of June, 2011. Encl. STATE OF ALASKA I i. i % 6 ' • ALASKA AND GAS CONSERVATION COMMISSION" t i i O ti APPLICATION FOR SUNDRY APPROVALS � r 20 AAC 25.280 b 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pooi❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate❑ Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate0 Alter Casing ❑ Other: MBE TREATMENT - 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development r Exploratory V 202 -2410- 3. Address: P.O. Box 196612 Stratigraphic 0 Service 6. API Number: Anchorage, AK 99519 -6612 7 _ G •7 -ii 50- 029 - 23132- 81 -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 20SS ' 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 380109 - 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): 7190 ' 4344.31 - 7104 _ 4279.44 - NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 82' 20 "X34" 215.5# A -53 34 112 34 112 Surface 2957' 9 -5/8" 40# L -80 33 2990 33 2526 5750 3090 Production 7157' 7" 26# L -80 32 7189 32 4344 7240 5410 Liner Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): O 6934 - 6964 O 4152.41 - 4174.39 2 -3/8" 4.7# L -80 31 6922 Packers and SSSV Tvoe: 2 -3/8" Baker GT Dual Packer Packers and SSSV MD and TVD (ft): 6896 4125 7 X 2.375 Baker FH Ret Packer 6974 4182 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: 7 4 6.7- 11 Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ,- Service [1r 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 6/14/2011 Oil ❑ Gas ❑ WDSPL ❑ Suspended _ !, 16. Verbal Approval: Date: WINJ [Er GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: IL. G •? q 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 PE Signature ,ti��J Phone Date -` l 21 564-5718 COMMISSION USE ONLY 5/31/2011 Prepared by Joe Lastufka 564-4091 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ; l ` 9 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ RCEIVED other: jflt'10 “'" r3" CADS, [" ii,.i11S Subsequent Form Required: � t'/D l 6@ilrtltat3 /04 APPROVED BY Approved by: 2) r I COMMISSIONER THE COMMISSION Date: 6/g t RPir S JUN a 9 2011 G •7•i/ 7 /i RIG1NaL Form 10 -403 Revised 1/2010 Submit uplicate • • by 0 To: Mark O'Malley /Rob Handy Date: May 31, 2011 MPU Ops Team Leaders From: Keith Lopez, MPU Schrader Pad Engineer 907 - 564 -5718 Subject: MPS -20SS MBE Treatment Step Unit Operation 1 F Shut in all offset producers. Bullhead water into MPS -20SS. 2 F Bullhead treatment down MPS -20SS (OA sand). Keep well and offset producers and injectors shut in for minimum of 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 !earnings to be incorporated into future jobs. 10. Forward all post job assessments (w/ all rheology test summary) and continuous pressure and rate data from job to Pad Engineer. • • Tree ..2O 2 1.16' EAl Duo. sttirtg 'i lel Mead:' 1' x 2 3 SN FMC dual sung MPS-20i Orig. KB Elev. = 72.40 ialpe thread 2 3'`v' EUE top and IBT bo to' — . Orig. GL Elev. = 38.40 C l ": -H EPV Droilte . 3 =d. 215241A-53 1 112 Short String Lang String 1 3015' 12 NE;,; X- Nipple i 1 .575' pkg. (] - __ - - hple( t.E75' pkg. bore l -- I KOP ri 750' Max_ hole angle = 70 deg i 40C3' Hole angle thri Derr: = 45 deg 1 2990' I 95VFIC iCO FIOa:CYDe 9 5+71' 401r L-80 BTRC C asng ;drti kt -13.679. Cap. - .2282 bpr+ 7 25kr. L-80. BTRC Casing (drrt Id - 6.151, cap.- .0383 bar; 2 - 315% 4.7 era L IBT 1ubIng (drill Id - 1.901, cap.-.0038.7 bpi) -I 6E51' 1 2 -3 +1' NES X -fipple (1.E75 pkg. bore t I = " tt S X Npple 11 -675' pkg. Dore; 16E51' I x 2 -? S Baker'GT• Ret moral pkr I r =;r 1 691 I -dor HES XN - Ntpple 11.875' pig. boi'? 1 No-Go 1.791' A p 1 6.22' I Tubing tai ;14LEG A d S/4 N n C 4 1tl Perforation Summary J J 1 2-W Baker 'FH' Ret. pkr. I - I 2 21' I:I?. Spt Interval Ti O A. sar ^s 0 2 -3 HES XH- Nlppie ;1.575' pig No-Go 1.0 4 5'$' E 6934' - 59E1 4153' - < 17 F OB sancl6 2 - 3+�8' Bake T - 2 Dut 4 5'8' 5 7292' - 7027 1 4243` -4222 *,r o' r l esnee pip (solos) deotr: (E99E' I •.97'oore Hydro Trip Sub ELMO 1 6E38' 13 1.7r DOM Ea 1 7104 I 7' HES Float Co:+ar �ETP • 1 1 7- -1ES Foal Shoe Cs ?EV. CC MME t4TO r' J Jones MILNE POINT UNIT Dllkdop . Cast] 7o1or. 11- WELL No_: S - 20i 21 s - eeHulme CCrrpletlar Rig 4_0 API : 50 - 23132 - BP EXPLORATION (AK) , . - Page 1 of 2 Schwartz, Guy L (DOA) From: Lopez, Keith [Iopek3 @BP.com] Sent: Thursday, June 02, 2011 3:24 PM To: Schwartz, Guy L (DOA) Cc: Lastufka, Joseph N (SAIC); McEntyre, Scott R; Igbokwe, Chidiebere; Lopez, Keith Subject: RE L4P- 26 Mom 203 . Guy, /Vt - 20 F 7_ — 2YI You will be receiving a total of 4 sundry requests for MBE treatments this summer. Here is some more details on the need for these jobs. MPS -26SS - Is an OA injector supporting MPS -23 & MPS -25. This well has shown a steady increase in injectivity since '03 and currently has very high injectivity for the Schrader Bluff (1060 bwpd @ 459 psig). An MBE was confirmed with MPS -23 via a red dye tracer in '09. A successful treatment will decrease the injectivity of the well and lower the water cut in MPS -23 (currently 80 -90 %). MPS -26LS - Is an OB injector supporting MPS -23 and MPS -25. The injectivity of this string showed a dramatic increase in '09 until it was SI due to low injection pressure. A red dye test confirmed that this string had developed an MBE with MPS -23 also. A successful treatment will decrease injectivity of the well to allow for bringing it back on injection and lower the water cut in MPS -23 (currently 80 -90 %). MPS -16LS - Is an OA injection string supporting MPH -08, MPS -19A, and MPS -17. This string also showed a dramatic increase in injectivity in '09 that continued until it was SI due to low injection pressure (1000 bwpd @ 610 psig). Subsequent red dye tests showed the string to have an MBE with both MPS -19A and MPS -17. A successful treatment will decrease the injectivity of the string to allow for bringing it back on injection and lower the WC of MPS -19A (98 %) and of MPS -17 (93 %). MPS -20SS - Is an OA injection string supporting MPH -08 and MPS -17. This well also has extremely high injectivity and can not inject without the help of a downhole choke to reduce the injection rate and supply back pressure. An MBE between it and MPS -17 was confirmed with a red dye tracer. It is believed that this well may also have an MBE to MPS -19A in this zone but this has not been tested. A successful treatment would decrease the injectivity to not need the downhole choke to keep online and decrease the WC in MPS -17 (and potentially MPS -19A). Let me know if you need any additional info_ Keith Lopez Wells & Subsurface Engineer Milne Point - Alaska BP Exploration Alaska, Inc. Office (907)- 564 -5718 Cell (907)- 903 -5432 From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] 6/7/2011 Page 2 of 2 Sent: Thursday, June 02, 2011 1:19 PM To: Lopez, Keith Subject: MPS -26 MBE (PTD 203 -061) Keith, Can you elaborate on the MBE operation planned for this MPS -26 ?? I see you are pumping into both SS and LS .... Is there an MBE in both sands ( OB and OA) ?? Which producers are affected ... etc. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 6/7/2011 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, March 21, 2011 TO: Jim Regg P.I. Supervisor I ,.. 31 Z Z' // SUBJECT: Mechanical Integrity Tests ( I BP EXPLORATION (ALASKA) INC S -20 FROM: Matt Herrera MILNE PT UNIT SB S -20 Petroleum Inspector Src: Inspector Reviewed By P.I. Supry - NON- CONFIDENTIAL Comm Well Name: MILNE PT UNIT SB S -20 API Well Number: 50- 029 - 23132 -00 -00 Inspector Name: Matt Herrera Insp Num: mitMFH110320151255 Permit Number: 202 -241 -0 Inspection Date: 3/20/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1 s -20 ' 1 Type Inj. W - TVD 4125 IA 0 2010 - 1960 1940 - P.T.D 2022410 ' ITypeTest SPT 1 Test psi 1500 ' OA 180 270 220 200 Interval 4YRTST P/F P - Tubing 900 900 900 900 Notes: ':1 +'° 'APR13 2tin Monday, March 21, 2011 Page 1 of 1 . MEMORANDUM State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ~~ft{41 Z(,!ð 7 DATE: Monday, Apri123, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S-20 MILNE PT UNIT SB S-20 Src: Inspector / ?-\{\ d.,b'r FROM: John Crisp Petroleum Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ..:J"ß~ Comm Well Name: MILNE PT UNIT SB S-20 API Well Number: 50-029-23132-00-00 Inspector Name: John Crisp Insp N um: miUCr0704I0093555 Permit Number: 202-241-0 Inspection Date: 4/6/2007 Rei Insp N um: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well S-20 Type Inj. , w ITVD 4125 IA 0 2000 1920 1920 I P.T.D 2022410 TypeTest SPT I Test psi 1500 OA 180 220 190 185 I I Interval 4YRTST P/F P v Tubing 1050 I 1050 1050 1050 I Notes: 1.9 bbl's pumped for test. sCANNEI> APR 3 0 2007 Monday, April 23, 2007 Page 1 of I · WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th A venue, Suite 100 Anchorage, Alaska 99501 November 13, 2006 RE: MWD Formation Evaluation Logs: MPS-20, MPS-22, MPS-30, MPS-90. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 MPS-20: U "IC- Qó:;;) - d'-/ f it IL(3<6L( Digital Log Images: 50-029-23132-00 I CD Rom fI:. .- MPS-22: dO"3 -/l.../9 7L13155 Digital Log Images: 50-029-23176-00 SCANNED FEB 0 1 2007 1 CD Rom MPS-30: u:rc- 868 -d-3Go ¢ 1L.(3~1- Digital Log Images: 50-029-23131-00 1 CD Rom MPS-90: f)öS- - 135'" *-fif 315c::' Digital Log Images: 50-029- 232 7 6-00 1 CD Rom --- () e e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 February 20,2004 /3Ú?t~O RE: MWD Formation Evaluation Logs: MPS-20, AK-MW-2277345 MPS-20: Digital Log Images: 50-029-23132-00 JiJ ~.. ^ :J --4-/ 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~ Date:~ Signed: ~J ,t /51Jiål'1r e 1-- (~ - V ) e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marker.doc Î\ I fJp J\~J 0 ,- DATA SUBMITTAL COMPLIANCE REPORT 4/1/2005 MD 7190 ~ TVD 4344 /' Completion Date 3/21/2003 -~ComPletion Status 1WINJ Current Status 1WINJ Sf! t.tcL l (j F,J ~ > API No. 50-029-23132-00-00 ~~ -,) Cé Ulcy Permit to Drill 2022410 Well Name/No. MILNE PT UNIT SB S-20 Operator BP EXPLORATION (ALASKA) INC REQUIRED INFORMATION Mud log No Samples No .. \I~"" DIrectional su(~ 'y'e~ DATA INFORMATION Types Electric or Other Logs Run: MWD, GYRO, CCl, GR, RES, SCMT Well Log Information: (data taken from Logs Portion of Master Well Data Maint) Log/ Electr Data Digital Dataset Type Med/Frmt Number : Rpt ~D ~ I Name Directional Survey ~3 LIS Verification ~ification Log Log Run Interval OH/ -~ Scale Media No Start Stop CH Received Comments 1 359 7190 Open 4/17/2003 MWD 2 42 7158 Open 6/25/2003 2 42 7158 Open 6/25/2003 Name Interval Start Stop Sent 359 7190 Open 4/17/2003 359 7190 Open 4/17/2003 0 359 Open 4/17/2003 GYRO 0 359 Open 4/17/2003 GYRO 359 7190 Open 4/17/2003 MWD 6050 7086 Case 10/8/2003 Slim Cement Mapping Tool- SCMT GRlCCl 6050 7086 Case 10/8/2003 Slim Cement Mapping Tool- SCMT GRlCCl Sample Set Number Comments ¥fr D Directional Survey : Rpt Directional Survey I ¡ Rpt Directional Survey I .{tED D Directional Survey tfËD D Directional Survey )(09 uicement Evaluation 5 Col Col y.og Casing collar locator 5 l__ Well Cores/Samples Information: Received DATA SUBMITTAL COMPLIANCE REPORT 4/1/2005 Permit to Drill 2022410 Well Name/No. MILNE PT UNIT SB S-20 MD 7190 TVD 4344 Completion Date 3/21/2003 ADDITIONAL INFORMAJ1P\N Well Cored? Y 1 'fi) Chips Received? ~- Y I N Analysis Received? ~ Comments: --- Compliance Reviewed By: ~ Operator BP EXPLORATION (ALASKA) INC Completion Status 1WINJ Daily History Received? Formation Tops API No. 50-029-23132-00-00 Current Status 1WINJ ~N ÐN Date: UIC Y .--- )tJ ~~i- ----~ ) ) MECHANICAL INTEGRITY REPORT' " :. I G R E L E J.. S ~: ~ ;;J./\C -0 ~. ~<::»M.Ç>~ "S (d-.\-() ~ OPER & FIELD -ß,? k~ \~ \>~ M \' <:> - dO ~ð-Ò'-\ \) ~?UD DA':E: : WEll NU1{BER ~\, C ê.. S i~ g : I I'D: "\ \<\Ò ,HD.. '-\S~\.\ TVD; :?BTD: '\ \Ö~ 21I? l-\dl~ TVD Shoe:\\~~ HD TVD¡ DV: W~ MD \0~ ·!vu ~~~LL DATA :...:":1e'!" : ~ ~ Shoe: HD ~. . . __ ~"'\ ~J. . <O~ t, ~ U 0 l.;, ; g : ~... (7 Ib Pac K e!:" <0 ~ '\ "=\- till :: ole S:"z e ?:s \/ :J-- a.n å ~. ~ TVD¡ :-OP : HD <.øc:;,~d TVD¡ Set ê.t ~ 'i~ ç Perf's <o~S'-\ to ~q<øL; "'\00 d lìOè)\ ;:7Ð ,", ~CHÞ1-{IC;'~ INTEGRITY - PART 11 Annulus Press Test: :,p \<;~tJ ¡ 15 min \~àÕ ¡ 30 min \<;00 . Co=ents: \4. \\' ~~%~ ~\ c..$\J~\(5~~~w: \...V~¥..-(J3,. , ~ M:ECRJ:Ü;¡ICf-J... INTEGRITY PART /2 \ 't" '\ \..,,\ ~ 'D \-:, 'ÖOs"'\ E Cement: Volumes :', þ...mt. Liner \-.)þ,.. Cs~ \~d<>~<:':' ; DV ~~, Clilt ~J'ol to cover perfs Q~~ 'is d~'o'o\~()~~_~~>\.j~r -k C~~~ ~~ . f"\ Theoret:ical Toe C& 3>'020 'f.~ \'0<- ~<O \ \' \DC 11-0-\- \nJJcJ . , ~ Cement Bond Log (Yes or No)'4.EC7 ;:In AOGCC File ·'-tES CEL :Svaluation, ::one a.bove perfs \. ~/s~O~) \(\ ~ "\~~ ~~$(è'l CpÞ~~~"'-\ ç,<o 30 ~ Produc:..tion Log: Typ,e ; Evaluation CONCLUSIONS: . ~ ?art ;1: ~~ \~~~~~k~J ? ar:: :z: \-A.:S:- \"> "\ ..Sh-cú... ~ ') ... ~ t?"} /I . .' ,. ~~"vr\d-ll~-ù3> . " Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Well P2-11 1~-15~/ GNI-01 -é). Ó--;r D.S.130271· 10 -I~ \: D.S. 6-21A ~() D.S.14-32. g ~~.. ~. ~ C-23B ~ ~ -DloL S F-13A 1. Tó"'l:6-~ F-11A ~t"J()-(,)ljÎ& .cr? ,.;. . M:~:~~_ go~- ~ '-=t- ¡~ MPS-20 ~ðL\ \ Job# Log Description Date SBH TEMP & PRESSURE SURVEY TEMP & PRESS SURVEY LDL LDL LDL MEM PPROF & IPROF LOG MEM PPROF & IPROF LOG MEM PPROF & IPROF LOG INJECTION PROFILE 10559234 CH EDIT SCMT (PDC) 10559234 SCMT 10/03/07 10/04/03 10/01/07 10/01/03 10/03/03 09/01/03 09/08/03 09/09/03 10/04/03 03/03/03 03/03/03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: R~~W\~ ,;;='".::="" r. jF'" I\qr= ~~ " ß. ¡{ _!!::=~"jf¡:=,¡¡ ~ r\~'~b~ V ä-U ^ ,,-;- (\ tî f)t!r\~ Vl, I v U L"''',;- ÞJS$Ka Oil &. Gas. Con~,. Gommì3Sion Anchor~e Blueline NO. 2984 10/07/03 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Prints 1 1 1 1 1 1 1 1 1 2 CD '~ ~\') ('>'. ~ ~ ..-..-'( Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Received ~'\.~ ,,::\~.O~~Af\ ') ) ~o(}-d4 , \ \ <3 33 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 June 20, 2003 RE: MWDFormation Evaluation Logs MPS-20, AK-MW-2277345 1 LIS fonnatted Disc with verification listing. API#: 50-029-23132-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO mE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. ~cþPI3;g~'r¡~f\.~~t}.995,,~ 8 !\ii:: ii',', ;(. i,·q, ¡:) "~)i "...., t~ .1;1 BP Exploration (Alaska) Inc. Petro-technical ,Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 f:\. ~ (,!J r.:. [J /"i d Signed: ¿?~ i\t'.;,~at~;¡ ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well o 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 3304' NSL, 209' W'EL, SEC. 12, T12N, R10E, UM At top of productive interval 1499' NSL, 3422' WEL, SEC. 01, T12N, R10E, UM X = 562558, Y = 6003418 10. Well Number At total depth 1617' NSL, 3549' WEL, SEC. 01, T12N, R10E, UM X = 562430, Y = 6003535 11. Field and Pool 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. Milne Point Unit 1 Schrader Bluff KBE = 72.4' ADL 380109 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 2-10-2003 2-14-2003 3-21-2003 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 7190 4344 FT 7104 4279 FT 181 Yes 0 No 22. Type Electric or Other Logs Run MWD,GYRO,CCL,GR,RES,SCMT Classification of Service Well X = 565801, Y = 5999971 7. Permit Number 202-241 8. API Number 50- 029-23132-00 9. Unit or Lease Name Milne Point Unit MPS-20i 15. Water depth, if offshore 16. No. of Completions NIA MSL One 20. Depth where SSSV set 21. Thickness of Permafrost NIA MD 1800' (Approx.) 23. CASING SIZE 20" 9-5/8" 7" WT. PER FT. 92# 40# 26# GRADE H-40 L-80 N-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 112' 42" 34' 2990' 12-1/4" 32' 7189' 8-1/2" CEMENTING RECORD 260 sx Arctic Set (Approx.) 770 sx PF 'L', 222 sx Class 'G' 100 sx PF 'E', 172 sx Class 'G' AMOUNT PUllED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 4-5/8" Gun Diameter, 5 SPF MD TVD 25. MD TVD SIZE 2-3/8",4.7#, L-80 (Short String) 2-3/8",4.7#, L-80 (Long String) TUSING RECORD DEPTH SET (MD) 6922' 6995' PACKER SET (MD) 6896' 6974' .'" ....,.., ,,~ " ".'" ,"-. ~·····~'····"·:I:t·-,'·r,'..'...'..,' ..... J...:;', . oj" '. ~'y~;~ :~ '~~~Jrf:~\, "r 1~ ··'",::~:.,~~11d~:i 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 1300' Freeze Protected with 75 Bbls of Diesel 6934' - 6964' 7002' - 7027' 4153' - 4175' 4203' - 4222' ~,..........",",..... """'¡IWo....,"·w_-··,·~....~...~ ¡ W¡~\J~]~" \ j, ª.:.kl~,J3i ~ \/ :t:: ::; i ;"',: j ~',: :;,. ¡._,-Áli 27. Date First Production April 20, 2003 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Water Injection PRODUCTION FOR Oll-BSl GAs-McF WATER-BSl TEST PERIOD CHOKE SIZE GAS-Oil RATIO I=low Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE ::>8. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. SUb~et IVE D Oll-Bsl GAs-McF WATER-Bsl Oil GRAVITY-API (CORR) No core samples were taken. APR 3 0 2003 IRBDMS BFl GF MAY 7 2003 Alaska Oil & Gas Cons. Commission Anchorage I 'Ii t, I ORIGINAL Submit In Duplicate Form 10-407 Rev. 07-01-80 " /) ) 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. Top Ugnu Zone C Top Ugnu Zone B Top Ugnu Zone BLower SBF2-NA SBF21 SBF24-MF SBF1-NB SBF1-NBR SBF12 SBE4-NC 3BE41 SBE2-NE SBE1-NF TSBO-OA TSBC TSBB-OB SBA5 5894' 6289' 6407' 6719' 6723' 6754' 6761' 6771' 6793' 6806' 6812' 6829' 6895' 6932' 6966' 6999' 7032' 3639' 37931 3844' 4009' 4012' 4031' 4036' 4042' 4056' 4064' 4068' 4079' 4124' 4152' 4176' 4201' 4225' RECEIVED APR 3 0 2003 Alaska Oil & Gas Cons. Commission Anchorage 31. List of Attachments: Summary of Daily Drilling Reports, Surveys and a Leak-Off Integrity Test Summary. 32. I hereby certify that the for~9ing is true Signed sondr~wma; M PS-20i Well Number D- 202-241 Permit No. I Approval No. Title Technical Assistant Date D~-1-q-o~ Prepared By Name/Number: Drilling Engineer: Sandra Stewman, 564-4750 Steve Campbell, 564-4401 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, illjection 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 ORIGINAL .....,...¡ ) ) BP EXPLORATION Operê1tiönsSummary Report Page 1 of 5 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-20 MPS-20 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 Start: 2/7/2003 Rig Release: 3/21/2003 Rig Number: 14 Spud Date: 2/9/2003 End: 3/21/2003 Date From ~ To Hours Task Code NPT Phase Description of Operations 2/912003 09:00 - 16:00 7.00 MOB P PRE Move rig from MPS-30, spot rig over on MPS-20i and rig up 16:00 - 20:00 4.00 RIGU P PRE NIU Diverter, riser, flowlines, rig accept @ 1600 hrs. 2/9/2003 20:00 - 21 :00 1.00 DRILL P SURF Pre-Spud meeting with crews and service people 21 :00 - 23:30 2.50 DRILL P SURF Pick up bit, 8" BHA, Orientate same, rig up slickline unit 23:30 - 00:00 0,50 RIGU P PRE Function test Diverter and knife valve, fill hole with water check for leaks, Witness of DiverterTest waived by John Crisp, AOGCC. 2/10/2003 00:00 - 00:00 24.00 DRILL P SURF Spud well, picking up BHA, Directional Drill from 112' to 2150' Pumping with 430 gpm at 1,800 psi 80 rpm. TO 4-5,000 P/U 105,000 S/O 97,000 R/T 97,000, AST 3.25, ART 4.5, Run single shot Gyro's every 100' to 360' 2/11/2003 00:00 - 07:00 7.00 DRILL P SURF Directional Drill from 2150' to 3,000' TD Pumping with 450 gpm at 1,850 psi 80 rpm. TO 4-5,000 P/U 11 O,Slo 90, R/T 100 07:00 - 08:30 1.50 CASE P SURF Circ. pump high vis sweep, cir,c. two bottoms with 500 gpm, 1900 psi, 100 rpms 08:30 - 10:30 2.00 CASE P SURF Pump out to HW pipe with full drilling rate 10:30 - 12:00 1.50 CASE P SURF RIH, had tight spot @ 1,555, wash and ream to 1655, finish trip to bottom 12:00 - 14:00 2.00 CASE P SURF Circ three bottoms up with 500 gpm, 1900 psi, 100 rpms 14:00 - 16:00 2,00 CASE P SURF Pump out to HWP with full drilling rate 16:00 - 18:00 2.00 CASE P SURF Stand back flex dc. lay down BHA 18:00 - 18:30 0.50 CASE P SURF Clear floor, made dummy run with 9 5/8 hanger 18:30 - 20:00 1.50 CASE P SURF Rig up to run csg, PJSM 20:00 - 23:00 3.00 CASE P SURF Running 9 5/840# L-80 BTC csg to 2,989', Total jts 71 P/U wt 170,000, S/O 110,000 Shoe @2,989, Float 2,903 23:00 - 23:30 0.50 CASE P SURF Rig down, Franks tool, pick up cement head 23:30 - 00:00 0,50 CASE P SURF Circ csg and thin mud for cement job with 7 bbls min 300 psi 2/12/2003 00:00 - 02:00 2,00 CASE P SURF Circ. Thin mud for cement job. with 7 bbls min 300 psi 02:00 - 04:00 2.00 CEMT P SURF Cement with halliburton, pump 10 water, tested lines to 3,500 psi, pumped 10 water drop bottom plug, pump 50 bbls ALPHA Spacer @ 10.2, Pumped 570 bbls 770 sxs Permafrost L @ 10.7,7 bbls min. pump 45 bbls, 222 sxs Premium @ 15,8 , 7 bbls min,drop top plug, pumped 10 water 04:00 - 05:00 1,00 CEMT P SURF Displace with rig pumps, 7 bbls min. slow pumps to 2 bbls min on last 10 bbls 600 psi, bump plug with 1600 psi, check floats ok, full return thu out job 250 bbls good 10.7 cement to surface. 05:00 - 09:30 4.50 BOPSURP SURF Flush Diverter, flow lines, lay down landing jt., nipple down 20 diverter 09:30 - 11 :30 2.00 BOPSUR P SURF Nipple up FMC Gen 5 well head, test to 1000 psi for 10 min. 11 :30 - 14:00 2.50 BOPSUR P SURF Nipple, 13 3/8 5M bop stack 14:00 - 19:30 5.50 BOPSUR P SURF Rig up , testing BOPS and manifold 250-3,500 psi for 5 min. per test, Annular 250-2,500 psi for 5 min per. test, install wear ring, (witness of BOP test was wavier by John Spalding AOOGC.) 19:30 - 22:30 3.00 CASE P SURF Picking up BHA #2, DS79 bit wI 6-11 jets,7" SperryDrill1 ,22 bend, flaot sup,6 3/4 Gaqmma/res, 6 3/4 HOC,Stab,2 flex dC.,stab,9 HWP,jars,11 HWP,stab 22:30 - 00:00 1.50 CASE P SURF Tripping in picking single jts 4" pipe 2/13/2003 00:00 - 01 :00 1.00 CASE P SURF Tripping in picking up 4" single pipe to 2,850' 01 :00 - 02:00 1.00 CASE P SURF Cut drilling line, circ well 02:00 - 03:00 1,00 CASE P SURF Test csg to 2,500 for 30 min. 03:00 - 04:30 1,50 CASE P SURF Drill float@ 2903' and shoe @ 2,989,20 ft. of new hole to 3020' Printed: 312412003 9:12:51 AM ) ) BP EXPLORATION Operations Summary Report Page 2 of 5 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-20 MPS-20 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 Start: 2/7/2003 Rig Release: 3/21/2003 Rig Number: 14 Spud Date: 2/9/2003 End: 3/21/2003 Date From - To Hours Task Code NPT Phase Description of Operations 2/13/2003 04:30 - 05:00 0.50 CASE P SURF Circ for fit test 05:00 - 05:30 0.50 CASE P SURF Fit test with 9.0 mud 2528 tvd 330 psi=11.5 EMW 05:30 - 15:30 10.00 DRILL P INT1 Drilling 3,020 to 5,091' with 120 rpms 550 gals min, 3500 psi 15:30 - 18:00 2.50 DRILL P INT1 Circ, three bottoms up with 550 gals min. 3300 psi, 120 rpms, pump sweep 18:00 - 20:30 2.50 DRILL P INT1 Pump out to csg shoe, with full drilling rate 20:30 - 21 :00 0.50 DRILL P INT1 Service topdrive 21 :00 - 21 :30 0,50 DRILL P INT1 Trip to bottom, wash 90 ft. 21 :30 - 00:00 2.50 DRILL P INT1 Drilling 5,091' to 5409' with 120 rpms 550 gals min, 3500 psi, TO 7,000, AST 1.9, ART 4.3, P/U 132K S/O 80K, R/T 98K 2/14/2003 00:00 - 12:00 12.00 DRILL P INT1 Drilling 5409' to 7190' TD' with 120 rpms 550 gals min, 3500 psi, AST 2.75, ART 4.5 TO 8,000 P/U 155K, S/O 95K, R/T 115K 12:00-14:00 2.00 CASE P INT1 Circ three bottoms up, with 550 gals min. 3900 psi 120 rpms 14:00 - 16:30 2.50 CASE P INT1 Short trip to csg shoe @ 2989, pumped out to 5700' with full drilling rate, no drag pumping, tripped from 5700' to 2989' wlo pumping, av, drag 5-10K max. 20K 16:30 - 18:00 1.50 CASE P INT1 Trip to bottom no problems 18:00 - 20:00 2.00 CASE P INT1 Circ three bottoms up, with 550 gals min, 3900 psi 120 rpms 20:00 - 23:00 3.00 CASE P INT1 Slug pipe, Tripping out, standing back 40 stands drill pipe in derrick, laying down excess pipe. 23:00 - 00:00 1.00 CASE P INT1 Stand HWP in derrick, laying down BHA 2/15/2003 00:00 - 02:00 2.00 CASE P INT1 Finish laying down BHA, down load MWD tool 02:00 - 03:30 1.50 CASE P INT1 Pull wear ring, change top rams to 4.5 X 7, test door seals to 1,500 03:30 - 05:00 1.50 CASE P INT1 Rig up to run csg, 200 ton elevators, 7" hand slips, franks fillup tool, PJSM 05:00 - 11 :00 6.00 CASE P INT1 Picking up 7" 26# L-80 BTC-Mod, csg to 7,190' P/U 21 OK S/O 95K, Total Jts 175, shoe @ 7,188', float 7,104' 11:00-11:30 0.50 CASE P INT1 Rig down Franks tool and rig up cement head 11 :30 - 14:30 3.00 CASE P INT1 Circ and reciprocate csg, with 5 bbls min 500 psi, PJSM on cementing 14:30 - 16:00 1.50 CEMT P INT1 Cement with Halliburton, pump 5 bbls water, test lines 3,500, pump 15 bbls water,30 bbls Alpha spacer mixed @ 10.2#, drop bottom plug on fly, pumped 100 sxs class E mixed 12.0#, 38 bbls, tail with 175 sxs 38 bbls class G mixed @ 15.6#, wash lines, drop top plug displace with 272 bbls 9.7 brine displace @ 6 bbls min. full return thu out job, bump plug with 1500#, check floats, Reciprocate 20 ft strokes until 1 0 bbls before plug was bump 16:00 - 16:30 0.50 CEMT P INT1 Rig down cement head 16:30 - 18:00 1.50 CASE P INT1 Broke tubing head, and csg head, raise BOPS, and set slips with 125,000 # string wt. 18:00 - 19:30 1.50 CASE P INT1 Rig up blow down nipple and 90 ft, of one in. pipe, displace csg of brine @ 90 ft,,rought cut csg, UD cut jt., final cut and dress csg at 7.5" 19:30 - 20:30 1.00 RIGD P COMP Install 7" pack off, N/U tbg spool, test packoff 3,800 psi for 15 min.(70% of csg collapse) 20:30 - 22:30 2.00 RIGD P COMP Change top rams to 2 7/8 x 5" N/D bops & set back,install false bowl (with no BPV), install 11" x 7 1/16 adapter with master valve, test packoff to 5,000 psi for 10 min. 22:30 - 23:00 0.50 RIGD P COMP Rig up HB&R Freeze protect 7' by 9 5/8 annulus with 60 bbls Printed: 3/24/2003 9:12:51 AM ) ) BP EXPLORATION Operations Summary Report Page 3 of 5 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-20 MPS-20 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 Start: 2/7/2003 Rig Release: 3/21/2003 Rig Number: 14 Spud Date: 2/9/2003 End: 3/21/2003 Date From~ To Hours Task . Code NPT Phase Description of Operations 2/15/2003 22:30 - 23:00 0.50 RIGD P CaMP diesel 23:00 - 00:00 1.00 RIGD P CaMP Clean cellar, secure pipe in derrick, remove flow line,blow down rig floor,PJSM 2/16/2003 00:00 - 01 :30 1,50 RIGD P CaMP Skid rig floor back, prepare for move 01 :30 - 03:00 1.50 RIGD P CaMP Move rig off MPS-20 to in front of MPS-17 03:00 - 06:30 3.50 RIGD P CaMP Wait on Production to install Flow lines and well house on MPS-19a 06:30 - 09:00 2.50 RIGD P CaMP Remove lights on back of sub, rig up diverter line on MPS-18, spot rig in front of MPS-18, Rig release for rig move @ 09:00 2/16/2003 3/17/2003 22:00 - 00:00 2.00 RIGU P CaMP Moving from MPS-30i to MPS-20i 3/18/2003 00:00 - 02:30 2,50 RIGU P CaMP Move from MPS30i, R/U on MPS-20 02:30 - 03:30 1.00 RUNCOIVP CaMP Rig accepted @ 02:30 Hrs, Nipple down 7" master valve, remove 11 x 7" false bowl, make dummy runs with Dual hanger, and mark landing jts. RT to LDS 30.30'. 03:30 - 05:30 2.00 RUNCOIVP CaMP Nipple Up BOPE. 05:30 - 09:00 3.50 RUNCOIVP CaMP R/U & Test BOPE to 250 - 3500 psi. Annular to 250 - 2500 psi. Witness waived by Chuck Scheve, AOGCC. 09:00 - 10:00 1.00 RUNCOIVP CaMP Slip & Cut Drilling Line, Service Top Drive, 10:00 - 11 :00 1.00 RUNCOIVP CaMP RIH wI 5 Stands 2 7/8" Tubing. Displace Diesel Freeze Protect wI 9.1 ppg, Brine. 11 :00 - 12:00 1.00 RUNCOIVP CaMP Test 7" Casing to 3500 psi for 30 Minutes, 12:00 - 13:30 1.50 RUNCOIVP CaMP PJSM wI HES and Rig Crew, M/U Perf. Guns. 13:30 - 17:00 3.50 RUNCOIVP CaMP RIH w/4 5/8" Perf Guns on 2 7/8" Work String to 7078'. 17:00 - 19:00 2.00 RUNCOIVP CaMP PJSM, M/U Head pin assy, & displace well bore to 9,1 ppg. Brine @ 3 BPM - 490 psi. 19:00 - 20:00 1.00 RUNCOIVP CaMP PJSM wI SWS & Rig Crew. R/U SWS Grease Injector Lubricator & Pump Down Sub. 20:00 - 22:30 2.50 RUNCOIVP CaMP RIH wI CCLI GR on E-line to 2900'. Pump down to 6900' Correlate wI SCMT log to position Guns, POH wI Logging Tools & RID SWS, 22:30 - 23:30 1,00 PERF P CaMP PJSM wI HES & Rig Crew. Pull up 36' to Position Guns. M/U TIW & Pump In Sub. Break Circulation Close Pipe Rams & Pump through Choke Line. Close Choke & pressure up to 3500 psi. Bleed off pressure & wait 6 Minutes. Guns Fired. Well not flowing. Open Rams & Monitor well - 1 Bbl. Loss then Stable. Perforated from 6934' to 6964' and form 7002' to 7027' wI HES 4 5/8" Millennium Guns, 5 spf, 72 Degree Phasing, 0.36" Diameter. 23:30 - 00:00 0.50 RUNCOIVP CaMP Circulate Bottoms Up. Stage up Pumps to 6 BPM @ 1390 psi. Closely monitor Returms. 3/19/2003 00:00 - 00:30 0.50 RUNCOIVP CaMP Complete CBU after perforating. Minimal Gas. Losses - 1 Bbl. while CBU. No Static losses. 00:30 - 03:00 2.50 RUNCOIVP CaMP POH Standing back 2 7/8" Tubing Work String. 03:00 - 03:30 0.50 RUNCOIVP CaMP PJSM, LID HES Spent Perforating Guns. All Shots Fired. 03:30 - 06:00 2.50 RUNCOIVP CaMP P/U 7" Scraper Assy. & RIH to 7040', 06:00 - 08:30 2.50 RUNCOIVP CaMP POH, LID Scraper Assy. 08:30 - 10:00 1.50 RUNCOIVP CaMP Change out Top Rams to 2 3/8" Duals. Test to 250 I 3500 psi. 10:00 - 11 :00 1.00 RUNCOIVP CaMP R/U to Run Dual 2 3/8" Completion String. 11 :00 - 11 :30 0.50 RUNCOIVP CaMP PJSM with Rig Crew & all Service Hands. 11 :30 - 23:30 12.00 RUNCOIVP CaMP Run 2 3/8", 4.6#, L-80, IBT-M Dual String as per program. 219 Jts. Each - Long & Short string, P/U 1 extra Jt + @ pups to place Lower Packer @ 6970'. Printed: 3/24/2003 9:12:51 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 3/19/2003 3/20/2003 3/21/2003 ) ) BP EXPLORATION Operations Summary Report MPS-20 M PS-20 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 Page 4 of 5 Start: 2/7/2003 Rig Release: 3/21/2003 Rig Number: 14 Spud Date: 2/9/2003 End: 3/21/2003 From - To Hours Task Code NPT Phase Description of Operations 23:30 - 00:00 00:00 - 03:00 03:00 - 09:00 09:00 - 15:00 0.50 RUNCOI\tP 3.00 RUNCOI\tP COMP COMP 6.00 RUNCOIVN DPRB COMP 6.00 RUNCOIVN DPRB COMP 15:00 - 17:00 2.00 RUNCOI\tP COMP 17:00 - 18:00 1.00 RUNCOI\tP COMP 18:00 - 19:00 1.00 BOPSURP COMP 19:00 - 20:00 1,00 BOPSURP COMP 20:00 - 21 :00 1.00 WHSUR P COMP 21 :00 - 22:00 1,00 RUNCOI\tP COMP 22:00 - 23:30 1,50 RUNCOI\tP COMP 23:30 - 00:00 0,50 RUNCOI\tP COMP 00:00 - 05:00 5,00 RUNCOI\tP COMP R/U SWS to run GR I CCL. RIH, in Long String, wI SWS GR I CCL, Had to Pump down from 4220'. Pumped @ 0.6 BPM - 90 psi. Correlate Packer Depth to SCMT I Perforating Log, Packer 2 Ft. Shallow, POH. GR / CCL Pulled tight @ 5086'. Attempt to Free GRI CCL. Pulled 1300 Ibs tension- No Movement up or down. . Pumped down @ 1.5 BPM - 450 psi. - no success. Worked String while attempting to free tool - no success. After discussion wI Anc, Team, pulled out of rope socket wI 3400 Lbs. RID SWS E-Line, R/U HES Slick Line, RIH wI 1 1/2" RB Pulling Tool, Spang Jars, Oil Jars & weight Bars. Latch GR/CCL @ 5086'. Work down 2 ft. & then Jarred up Two licks - Free, POH wI GR/CCL & LID. M/U 1,77" Guage Ring & RIH, Set Down @ 5130', 5245', & 5336'. Worked through all points. Set down on Hydro Trip Sub @ 6990. POH '- No Problem, RID HES, Space out both Strings with pups one Jt Below Hangers. M/U Split hanger wI TWC's installed & Land Dual String. Top Of "GT" Packer @ 6896'. Top of" FH" Packer @ 6973', R.ILD.S. Back out landing Jts, Close Blind rams & Test TWC's to 1000 psi. RID Tubing Equipment. Change out Top Rams to 27/8" X 5". N/D BOPE N/U 7 1/16", 5000 psi Dual tree wI 2 1/16" dual bores. Test adapter flange & both sides of Tree to 5000 psi. PJSM N/U Circulating I Testing Manifold & lines Test to 3000 psi. Reverse Circulate 200 Bbls, 9.1 ppg Brine wI corrosion inhibitor taking returns up both strings. Pump @ 2,5 BPM & 350 psi. R/U HB&R, PJSM, Test lines to 3000 psi, Pump 65 Bbls Diesel down annulus @ 2.5 Bblsl Min @ 900 psi. taking returns up both strings. Shut down - Annular pressure bled down to 300 psi. Drop 1 3/4" Ball down Long String. Bullhead down wI 20 Bbls. 9.7 ppg. Brine @ 1 BPM & 1050 psi. Ball seated w 1500 psi. Let Annulus Bleed off to 500 psi. Switch to HB&R & pressure up on Long string wI diesel to 3000 psi. Chart test for 30 Minutes. Pressure up to 3600 psi to shear Hydro sub. Pump additional 5 bbls diesel to freeze protect to 1300'. Switch to Annulus & pressure test w/ diesel to 2000 psi Chart test for 30 minutes. With Rig, pump Down Short string wI 9.7 ppg Brine while monitoring Long string, Formation broke down @ 1500 psi after pumping 3 Bbls, Pump additional 5 Bbls @ 900 psi. No communication between strings. Drop ball down Short String. Bullhead down wI 17 Bbls. 9.7 ppg. Brine. Pressure up wI diesel to 3000 psi while monitoring annulus. No Communication. Hold & Chart test for 30 Minutes. After test, shear ball wI 3800 psi. Pump additional 5 Bbls diesel to freeze protct to 1300'. Shut in Tree. RID HB&R. Printed: 3/24/2003 9:12:51 AM ) ) BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-20 MPS-20 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 Start: 2/7/2003 Rig Release: 3/21/2003 Rig Number: 14 Spud Date: 2/9/2003 End: 3/21/2003 Date From - To Hours ·Task Code NPT Phase Description of Operations 3/21/2003 05:00 - 06:00 1.00 WHSUR P COMP R/U MPU Well Suppot Lubricato & Install BPV in both Long & Short Strings. 06:00 - 07:00 1.00 RIGD P COMP Clear Cellar, Secure Well. RELEASE RIG @ 07:00 Hrs, Printed: 3/24/2003 9:12:51 AM Legal Name: Common Name: Test Date 2/13/2003 FIT MPS-20 MPS-20 Test Type Test Depth (TMD) 3,020.0 (ft) BPEXPLORATION Leak-Off Test Summary Test Depth (TVD) 2,528.0 (ft) AMW 9.00 (ppg) Surfàce Pressure LeakOffPressllrelBHP) 330 (psij 1,512 (psij EMW 11.51 (ppg) --' - Printed: 3/24/2003 9:12:45 AM ) ) aDa~a '1 } 26-Mar-03 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPS-20 Gyro Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00 I MD 0.00' MD (if applicable) 0.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RECEIVED Attachment(s) APR 1 7 2003 Alaska œ & Gas Cons. CommÎS!ÍOn Anchorage Sperry-Sun Drilling Services Milne Point Unit BPXA Milne Point MPS MPS-20 Gyro "--- Job No. AKF02277345, Surveyed: 14 February, 2003 Survey Report 19 March, 2003 Your Ref: 500292313200 Surface Coordinates: 5999971.00 N, 565801.26 E (70° 24' 37.3071" N, 149027' 51.1109" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 999971.00 N, 65801.26 E (Grid) Surface Coordinates relative to Structure: 0.79 N, 543.75 W (True) Kelly Bushing: 72AM above Mean Sea Level Elevation relative to Project V Reference: 72.400 Elevation relative to Structure: 72AOft "~ spe""r'y-sufl DRILL.ING SERVices A Halliburton Company Survey Ref: svy1137 Sperry-Sun Drilling Services Survey Report for Milne Point MPS . MPS·20 Gyro Your Ref: 500292313200 Job No. AKF02277345, Surveyed: 14 February, 2003 BP EXPLORA nON (ALASKA) INC. Milne Point Unit 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) (0/100ft) 0.00 0.000 0.000 -72.40 0,00 0.00 N 0.00 E 5999971.00 N 565801.26 E 0.00 Tolerable Gyro 87,00 0,500 240.000 14.60 87.00 0,19 S 0.33W 5999970.81 N 565800.93 E 0.575 0.08 177.00 0,750 238.000 104.59 176.99 0,70S 1.17W 5999970.29 N 565800.10 E 0.279 0.28 270.00 0.750 245.000 197.59 269.99 1.28 S 2,24W 5999969.70 N 565799.04 E 0.098 0.58 359.00 0.400 245.000 286.58 358.98 1.66 S 3.05W 5999969.32 N 565798.23 E 0.393 0.86 All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 317.190° (True). Magnetic Declination at Surface is 25,599°(09-Feb-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 359.00ft., The Bottom Hole Displacement is 3.47ft., in the Direction of 241.473° (True). Survey tool program for MPS-20 Gvro Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0,00 359.00 358,98 Tolerable Gyro 0.00 19 March, 2003 - 10:43 Page20f2 BPXA .~ ~. DrillQuest 3.03.02.004 ) AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 26-Mar-03 Re: Distribution of Survey Data for Well MPS-20 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00 I MD 7,190.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED APR 1 7 2003 Af~ Ot~ & Gas Cons. GommiMton And10rage aDd--JVl Sperry-Sun Drilling Services Milne Point Unit BPXA Milne Point MPS MPS-20 ~ Job No. AKZZ2277345, Surveyed: 14 February, 2003 Survey Report 18 March~ 2003 Your Ref: 5002923113200 Surface Coordinates: 5999971.00 N, 565801.26 E (70024' 37.3071" H, 149027' 51.1109" W) Grid Coordinate System: HAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 999971.00 H, 65801.26 E (Grid) Surface Coordinates relative to Structure: 0.79 N, 543.75 W (True) Kelly Bushing: 72.400 above Mean Sea Level Elevation relative to Project V Reference: 72.400 Elevation relative to Structure: 72.400 -- speI'I'Y-su,! CRIL.L.ING sERVIc:es A Halliburton Company SlIrvey Ref: svy1139 DríllQllest 3.03.02.004 Page 2 of4 18 March, 2003 - 9:49 Sperry-Sun Drilling Services Survey Report for Milne Point MPS . MPS·20 Your Ref: 5002923113200 Job No. AKZZ2277345, Surveyed: 14 February, 2003 BP EXPLORA TlON (ALASKA) INC. BPXA Milne Point Unit 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) (0/100ft) 359.00 0.400 245.000 286.58 358.98 1.66 S 3.05W 5999969.32 N 565798.23 E 0.86 AK-6 BP _IFR-AK 480.86 0.770 257.510 408.43 480.83 2.01 S 4.23W 5999968.95 N 565797.05 E 0.319 1.40 570.74 0.530 70.820 498,31 570.71 2,01 S 4.43 W 5999968.95 N 565796.85 E 1 .444 1.54 659.95 1.960 346.680 587.50 659.90 0.39S 4,39W 5999970.58 N 565796.87 E 2.217 2.70 750.22 4.360 328.640 677.63 750.03 4,05 N 6,53W 5999974.99 N 565794.69 E 2.846 7.41 84993 6.000 326.720 776,93 849.33 11.64 N 11 .36 W 5999982.54 N 565789.79 E 1.654 16.26 944.65 8.610 323.990 870,87 943.27 21,52 N 18.25 W 5999992.35 N 565782.82 E 2.779 28.19 1039.57 9.770 324.610 964.57 1036.97 33,83 N 27.09 W 6000004.59 N 565773.87 E 1.227 43.23 1134.47 12, 1 00 320.120 1057.75 1130.15 48.03 N 38.13 W 6000018.69 N 565762.70 E 2.612 61.15 -. 1230.53 14.500 317.650 1151 .22 1223.62 64,64 N 52.69 W 6000035.18 N 565748.00 E 2.567 83.23 1327.26 18.110 316.250 1244.05 1316.45 84.46 N 71.25 W 6000054.83 N 565729.27 E 3.754 110.38 1423.27 22.160 314.970 1334.17 1406.57 108.05 N 94.39 W 6000078.21 N 565705.92 E 4.243 143.41 1519.34 22.970 316.860 1422.89 1495.29 134.53 N 120.03 W 6000104.47 N 565680.05 E 1.132 180.26 1616.06 25.930 316.170 1510.92 1583.32 163.56 N 147.58 W 6000133.26 N 565652.24 E 3.075 220.29 1711.34 26,860 315.930 1596.27 1668.67 194.06 N 176.98 W 6000163.49 N 565622.58 E 0.982 262.63 1808.30 27,750 317.840 1682.43 1754.83 226.53 N 207.37 W 6000195.69 N 565591.90 E 1.288 307.11 1901.04 30.630 321.110 1763.39 1835.79 260.93 N 236.70 W 6000229.84 N 565562.27 E 3.549 352.28 1997.16 32,030 320.140 1845.49 1917.89 299.56 N 268.41 W 6000268.18 N 565530.22 E 1.548 402.16 2092.36 35.320 317.320 1924.71 1997.11 339.18 N 303.26 W 6000307.50 N 565495.02 E 3.826 454.91 2188.57 39.540 318.840 2001.09 2073.49 382.70 N 342.29 W 6000350.67 N 565455,61 E 4.490 513.36 2284.72 43,830 316.150 2072.89 2145.29 429.78 N 385.52 W 6000397.37 N 565411.97 E 4.833 577 .28 2380.56 47.360 314.790 2139.94 2212.34 478.56 N 433.54 W 6000445.73 N 565363.52 E 3.820 645.70 2475.54 53.170 314.260 2200.63 2273.03 529.75 N 485.60 W 6000496.45 N 565311.01 E 6.132 718.63 2571.26 56.320 315.110 2255.88 2328.28 584.72 N 541.16 W 6000550.93 N 565254.97 E 3.370 796.71 2666.20 58.030 314.740 2307.34 2379.74 641.05 N 597.65 W 6000606.76 N 565197.99 E 1.831 876.43 2761.36 61.940 316.210 2354.93 2427.33 699.80 N 655.40 W 6000665.00 N 565139.72 E 4.321 958.77 2859.02 64.240 318.440 2399.13 2471.53 763.83 N 714.41 W 6000728.50 N 565080.15 E 3.113 1045.84 2931.77 66.130 319.760 2429.67 2502.07 813.74 N 757.63 W 6000778.03 N 565036.49 E 3.076 1111 .83 3049.36 65.200 321.410 2478.12 2550.52 896.50 N 825.66 W 6000860,19 N 564967.73 E 1.503 1218.78 314580 64.420 322.790 2519.17 2591.57 965.36 N 879.27 W 6000928.58 N 564913.52 E 1.527 1305.73 3242.36 67.150 319.590 2558.78 2631.18 1033.95 N 934.47 W 6000996.67 N 564857.72 E 4.138 1393.55 3337.28 67.020 320.260 2595.74 2668.14 1100.85 N 990.76 W 6001063.08 N 564800.84 E 0.664 1480.88 3434.04 67.280 322.030 2633,32 2705.72 1170.28 N 1046.69 W 6001132.02 N 564744.30 E 1.707 1569.83 3531.11 69.800 321.650 2668.83 2741.23 1241.31 N 1102.51 W 6001202,55 N 564687.86 E 2.621 1659.87 3625.59 68.140 321.990 2702.73 2775.13 1310.63N 1157.02W 6001271.38 N 564632.74 E 1.789 1747.76 3722.14 68.610 319.110 2738.32 2810,72 1379.92 N 1214.04 W 6001340,17 N 564575.11 E 2.815 1837.35 3817.01 69.200 318.890 2772.46 2844.86 1446.72 N 1272.11W 6001406.46 N 564516.45 E 0.658 1925,82 3913.63 70.130 315.550 2806.05 2878.45 1513.20 N 1333.64 W 6001472,39 N 564454.34 E 3.381 2016.40 4010.13 70.000 315.410 2838.95 2911.35 1577.88 N 1397.25 W 6001536.51 N 564390.17 E 0.192 2107.08 4107.55 69.790 316.390 2872.44 2944.84 1643.58 N 1460.91 W 6001601.64 N 564325.93 E 0.969 2198.54 DrillQuest 3.03.02.004 Page 3 of 4 18 Marcil, 2003 - 9:49 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-20 Your Ref: 5002923113200 Job No. AKZZ2277345, Surveyed: 14 February, 2003 BP EXPLORA TION (ALASKA) INC. BPXA Milne Point Unit 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) (0/100ft) 4203.25 69.530 316.440 2905.70 2978.10 1708.58 N 1522.78 W 6001666.09 N 564263.49 E 0.276 2288.26 4298.33 69,140 316.160 2939.26 3011.66 1772,89 N 1584.24 W 6001729.87 N 564201.46 E 0.494 2377.21 4394.32 69.150 316,900 2973.43 3045.83 1837.99 N 1645.95 W 6001794.42 N 564139.18 E 0.720 2466.91 4490.47 GU.280 315.980 3008.33 3080.73 1902.91 N 1707.68 W 6001858.80 N 564076.88 E 1.270 2556.49 4585.44 68.670 313,730 3043.18 3115.58 1965.22 N 1770.31 W 6001920.55 N 564013.71 E 2.242 2644.76 4681.71 68.930 313.920 3078.00 3150.40 2027.37 N 1835.06 W 6001982.13 N 563948.41 E 0.327 2734.36 4775.81 66.410 313.770 3113.75 3186.15 2087.66 N 1897.83 W 6002041.86 N 563885.11 E 2.682 2821.24 4871.78 66.290 313.460 3152.24 3224.64 2148.30 N 1961.48 W 6002101.94 N 563820.93 E 0.321 2908.98 4968.60 65.730 313.410 3191.61 3264.01 2209,12 N 2025.71 W 6002162.19 N 563756.16 E 0.580 2997.25 .~ 5063.08 66.420 315.660 3229.93 3302.33 2269.69 N 2087.27 W 6002222.21 N 563694.08 E 2.296 3083.51 5160.27 66.870 317 ,000 3268.46 3340.86 2334.23 N 2148.87 W 6002286.20 N 563631.91 E 1.348 3172.72 5256.45 66.280 317.100 3306.69 3379.09 2398.82 N 2209.01 W 6002350.27 N 563571.21 E 0.621 3260.98 5352.82 65.860 317.080 3345.78 3418.18 2463.34 N 2268.98 W 6002414.25 N 563510.67 E 0.436 3349.06 5447.32 65.730 317,050 3384,53 3456.93 2526.44 N 2327.69 W 6002476.84 N 563451.40 E 0.141 3435.25 5544.57 65.470 316.830 3424,70 3497.10 2591.15 N 2388.16 W 6002541.01 N 563390.37 E 0.338 3523.82 5640.70 65,940 317.020 3464.26 3536.66 2655.15 N 2448.00 W 6002604.48 N 563329.97 E 0,521 3611.43 5736.67 66.280 316.900 3503.12 3575.52 2719.28 N 2507.88 W 6002668.08 N 563269.52 E 0,372 3699.18 5832.92 66,330 316.840 3541 .80 3614.20 2783.61 N 2568.14 W 6002731.87 N 563208.70 E 0.077 3787.31 5928.72 66,560 317.370 3580.09 3652.49 2847.94 N 2627.91 W 6002795.68 N 563148.36 E 0.561 3875.13 6024.96 67.160 317.180 3617.91 3690.31 2912.95 N 2687.96 W 6002860.16 N 563087.75 E 0.649 3963.63 6119.16 67.130 316,810 3654.49 3726.89 2976.43 N 2747.16 W 6002923.11 N 563027.98 E 0.363 4050.43 6216.08 67.350 317.340 3691.99 3764.39 3041.87 N 2808.03 W 6002988.02 N 562966.54 E 0.553 4139.80 6311.75 65.740 317.960 3730.07 3802.4 7 3106.73 N 2867.15 W 6003052.35 N 562906.85 E 1 .785 4227.56 6407.35 62,980 316.520 3771.43 3843.83 3170.01 N 2925.65 W 6003115.11 N 562847.80 E 3,190 4313.74 6503.38 59.580 315.320 3817.57 3889.97 3230.51 N 2984.21 W 6003175,09 N 562788.70 E 3.706 4397.92 6599.28 57.030 315.810 3867.95 3940.35 3288.76 N 3041.34 W 6003232.84 N 562731.06 E 2,694 4479.48 6696.00 53.420 317.520 3923.11 3995.51 3346.52 N 3095.87 W 6003290.11 N 562676.03 E 4.005 4558.90 6792.05 50.030 317.680 3982.60 4055.00 3402.19 N 3146.70 W 6003345,34 N 562624.70 E 3.532 4634.29 _/ 6889.28 45.310 317.050 4048.06 4120.46 3455.07 N 3195.37 W 6003397.78 N 562575.58 E 4.878 4706,15 6984.88 41.440 313.510 4117.54 4189.94 3501.75N 3241.49 W 6003444.05 N 562529.05 E 4.779 4771.74 7080.83 41.210 313.640 4189.60 4262.00 3545.42 N 3287.39 W 6003487.32 N 562482.76 E 0.256 4834.97 7133.59 41.020 312.790 4229.35 4301.75 3569.17 N 3312.67 W 6003510.85 N 562457.27 E 1.119 4869.58 7190.00 41.020 312.790 4271.91 4344,31 3594.32 N 3339.84 W 6003535,76 N 562429.88 E 0.000 4906.49 Projected Survey Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-20 Your Ref: 5002923113200 Job No. AKZZ2277345, Surveyed: 14 February, 2003 BP EXPLORA HON (ALASKA) INC. Milne Point Unit BPXA All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 317 .190° (True). Magnetic Declination at Surface is 25.599°(09-Feb-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 7190.00ft, The Bottom Hole Displacement is 4906.50ft, in the Direction of 317.102° (True). -- Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 7190.00 4344.31 3594.32 N 3339,84 W Projected Survey Survey tool proqram for MPS-20 Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0,00 359.00 0.00 358.98 359.00 7190.00 358.98 Tolerable Gyro(MPS-20 Gyro) 4344.31 AK-6 BP ....-'FR-AK(MPS-20) -" 18 March, 2003 - 9:49 Page 4 of4 DrillQuest 3.03.02.004 ) AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 ) 26-Mar-03 Re: Distribution of Survey Data for Well MPS-20 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 0.00' MD 7,190.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECE\\1ED ~PR ,,( LOO~ ø 0\\ &. GaS Cons. CQmffi\5S\Of\ þja. Md1tØ96 qOadL)/ Sperry-Sun Drilling Services Milne Point Unit BPXA MPS-20 MWD -" Job No. AKMW2277345, Surveyed: 14 February, 2003 Survey Report 25 March, 2003 Your Ref: 500292313200 Surface Coordinates: 5999971.00 N, 565801.26 E (70024'37.3071" N, 149027' 51.1109" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing: 72.40ft above Mean Sea Level .~ spe.....I'\{-sufl DRILLING seRVices A Halliburton Company Survey Ref: svy1138 Sperry-Sun Drilling Services Survey Report for MPS·20 MWD Your Ref: 500292313200 Job No. AKMW2277345, Surveyed: 14 February,2OO3 BP EXPLORA TION (ALASKA) INC. BPXA Milne Point Unit 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) C/100ft) 359.00 0.400 245,000 286.58 358.98 1.66 S 3.05W 5999969.32 N 565798.23 E 0.86 MWD Magnetic 480.86 0.770 257,570 408.43 480.83 2.01 S 4.23W 5999968.95 N 565797.05 E 0.320 1.40 570.74 0.530 71 ,120 498.31 570.71 2.01 S 4.43 W 5999968.95 N 565796.85 E 1 .444 1.54 659.95 1.960 346,390 587.50 659.90 0.39 S 4.40 W 5999970.57 N 565796.87 E 2.223 2.70 750.22 4.360 328.670 677.63 750.03 4.04 N 6.54W 5999974.98 N 565794.68 E 2.840 7.41 849.93 6.000 327,020 776.93 849.33 11.65 N 11.35 W 5999982.55 N 565789.81 E 1.651 16.26 -'" 944.65 8,610 324,340 870.87 943.27 21.57 N 18.18 W 5999992.41 N 565782.89 E 2.778 28.18 1039.57 9.770 324.960 964.57 1036.97 33.93 N 26.95 W 6000004.69 N 565774.01 E 1.227 43.21 1134.47 12.100 320.650 1057.75 1130.15 48.22 N 37.88 W 6000018.88 N 565762.96 E 2.600 61.12 1230.53 14.500 318.130 1151.22 1223.62 64.96 N 52.29 W 6000035.50 N 565748.40 E 2.570 83.19 1327.26 18.110 316.850 1244.05 1316.45 84.96 N 70.66 W 6000055.33 N 565729.85 E 3.750 110.34 1423.27 22,160 315.540 1334.17 1406.57 108.78 N 93.56 W 6000078.95 N 565706.75 E 4.244 143.38 1519.34 22.970 317.400 1422.89 1495.29 135.51 N 118.94 W 6000105.45 N 565681.13 E 1.124 180.24 1616.06 25.930 317.160 1510.92 1583.32 164.91 N 146.10 W 6000134.62 N 565653.72 E 3.062 220.26 1711.34 26.860 317.070 1596.27 1668.67 195.95 N 174.92 W 6000165.40 N 565624.62 E 0.977 262.62 1808.30 27,750 318.920 1682.43 1754.83 229.00 N 204.68 W 6000198.19 N 565594.57 E 1 .268 307.09 1901.04 30.630 322.120 1763.39 1835.79 263.93 N 233.38 W 6000232.87 N 565565.57 E 3.531 352.22 1997.16 32.030 321.180 1845.49 1917.89 303.12 N 264.39 W 6000271.78 N 565534.21 E 1.543 402.05 2092.36 35.320 317.950 1924.71 1997.11 343.24 N 298.66 W 6000311.59 N 565499.59 E 3.934 454.77 2188.57 39.540 320.130 2001.10 2073.50 387.42 N 336.94 W 6000355.43 N 565460.92 E 4.597 513.19 2284,72 43,830 317.200 2072.89 2145.29 435.36 N 379.20 W 6000403.00 N 565418.23 E 4.899 577.08 2380.56 47.360 315.410 2139.95 2212.35 484.83 N 426.52 W 6000452.06 N 565370.49 E 3.917 645.53 2475.54 53,170 314.600 2200,64 2273.04 536.45 N 478.15 W 6000503.21 N 565318.40 E 6.152 718.48 _/ 2571.26 56.320 315.350 2255.88 2328.28 591.69 N 533.43 W 6000557.97 N 565262.64 E 3.352 796.58 2666.20 58.030 314.460 2307.34 2379.74 648.00 N 589.94 W 6000613.78 N 565205.63 E 1.966 876.29 2761,36 61.940 316.780 2354.94 2427.34 706.90 N 647.53 W 6000672.17 N 565147.53 E 4.619 958.63 2859.02 64,240 318.750 2399.14 2471.54 771.38 N 706.05 W 6000736.13 N 565088.44 E 2.963 1045.70 2931.77 66.130 320.030 2429,67 2502.07 821.51 N 749.02 W 6000785.88 N 565045.03 E 3.049 1111.68 3049.36 65.200 322.010 2478.13 2550.53 904.79 N 816.42 W 6000868.56 N 564976.90 E 1.726 1218.58 3145.80 64.420 323,160 2519,1 8 2591.58 974.10 N 869.44 W 6000937.40 N 564923.27 E 1.349 1305.46 25 March, 2003 - 11 :15 Page 2 of 5 DrillQuest 3.03.02.002 : -- Sperry-Sun Drilling Services Survey Report for MPS-20 MWD Your Ref: 500292313200 Job No. AKMW2277345, Surveyed: 14 February, 2003 BP EXPLORA TION (ALASKA) INC. BPXA Milne Point Unit 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) C/100ft) 3242.36 67.150 320.030 2558.79 2631.19 1043.07 N 924.15 W 6001005.89 N 564867.95 E 4.090 1393.24 3337.28 67.020 320.880 2595.75 2668.15 1110.49 N 979.82 W 6001072.82 N 564811.70 E 0.836 1480.52 3434.04 67.280 322.390 2633.32 2705.72 1180.40 N 1035.16 W 6001142.24 N 564755.74 E 1 .463 1569.42 3531 .11 69.800 321.950 2668.84 2741.24 1251.75 N 1090.56 W 6001213.09 N 564699.71 E 2.630 1659.41 3625.59 68,140 322.290 2702.74 2775.14 1321.35 N 1144.71 W 6001282.22 N 564644.95 E 1.789 1747.27 3722.14 68,610 319.340 2738.33 2810.73 1390.91 N 1201.42 W 6001351.27 N 564587.64 E 2.882 1836.83 .~ 3817.01 69.200 319.080 2772.47 2844.87 1457.92 N 1259.24 W 6001417.77 N 564529.22 E 0.672 1925.29 3913.63 70,130 315.840 2806.06 2878.46 1524.66 N 1320.49 W 6001483.97 N 564467.39 E 3.288 2015.87 4010.13 70.000 316.070 2838.96 2911.36 1589.87 N 1383.56 W 6001548.61 N 564403.75 E 0.261 2106.57 4107.55 69.790 316.010 2872.45 2944.85 1655.72 N 1447.06 W 6001613.90 N 564339.67 E 0.223 2198.03 4203.25 69.530 316.720 2905.71 2978.11 1720.66 N 1508.98 W 6001678.30 N 564277.18 E 0.747 2287.75 4298.33 69,140 316.280 2939.26 3011.66 1785.19 N 1570.22 W 6001742.29 N 564215.37 E 0.596 2376.71 4394.32 69.150 317.300 2973.44 3045.84 1850.57 N 1631.63 W 6001807.12 N 564153.39 E 0.993 2466.41 4490.47 68.280 316.720 3008,34 3080.74 1916.10 N 1692.72 W 6001872.12 N 564091.72 E 1.065 2556.00 4585.44 68.670 314.210 3043.19 3115.59 1979.07 N 1754.68 W 6001934.53 N 564029.21 E 2.493 2644.29 4681.71 68.930 314.500 3078.00 3150.40 2041.82 N 1818.86 W 6001996.71 N 563964.49 E 0.390 2733.94 4775.81 66.410 313.460 3113.76 3186.16 2102.26 N 1881.48 W 6002056.60 N 563901.33 E 2.866 2820.84 4871,78 66,290 313.310 3152.25 3224.65 2162.65 N 1945.37 W 6002116.42 N 563836.91 E 0.190 2908.55 4968,60 65.730 313.480 3191.62 3264.02 2223.42 N 2009.64 W 6002176.63 N 563772.11 E 0.600 2996.82 5063,08 66.420 315.630 3229.94 3302.34 2284.01 N 2071.17 W 6002236.67 N 563710.04 E 2.205 3083.08 5160.27 66,870 317.690 3268.47 3340.87 2348.90 N 2132.41 W 6002301.02 N 563648.24 E 2.000 3172.30 5256.45 66.280 317.160 3306.71 3379.,11 2413.89 N 2192.11 W 6002365.48 N 563587.96 E 0.795 3260.55 5352,82 65,860 317.530 3345.80 3418.20 2478.67 N 2251.80 W 6002429.73 N 563527.71 E 0.560 3348.63 5447,32 65.730 317,520 3384.54 3456.94 2542.24 N 2310.00 W 6002492.79 N 563468.95 E 0.138 3434.82 --- 5544.57 65.4 70 317,770 3424.71 3497.11 2607.69 N 2369.67 W 6002557.71 N 563408.71 E 0.355 3523.38 5640.70 65.940 317.370 3464.27 3536.67 2672.36 N 2428.78 W 6002621.86 N 563349.03 E 0.619 3611.00 5736,67 66.280 316.570 3503.13 3575.53 2736.50 N 2488.66 W 6002685.47 N 563288.59 E 0.840 3698.74 5832.92 66.330 316.250 3541,81 3614.21 2800.34 N 2549.43 W 6002748.77 N 563227.26 E 0.309 3786.87 5928.72 66,560 316,160 3580.10 3652.50 2863.72 N 2610.21 W 6002811.62 N 563165.92 E 0.255 3874.68 6024.96 67.160 316.970 3617.92 3690.32 2927.99 N 2671.05 W 6002875.34 N 563104.52 E 0.994 3963.17 25 March, 2003 - 11:15 Page30f5 DrillQuest 3.03.02.002 · - Sperry-Sun Drilling Services Survey Report for MPS-20 MWD Your Ref: 5.00292313200 Job No. AKMW2277345, Surveyed: 14 February, 2003 BP EXPLORA TlON (ALASKA) INC. BPXA Milne Point Unit 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) r/100ft) 6119.16 67,130 317.290 3654.51 3726.91 2991.61 N 2730.11 W 6002938.44 N 563044.90 E 0.315 4049.97 6216.08 67,350 316.480 3692.00 3764.40 3056.85 N 2791.19 W 6003003.14 N 562983.25 E 0.803 4139.34 6311.75 65,740 316,220 3730.08 3802.48 3120.35 N 2851.77 W 6003066.10 N 562922.11 E 1.701 4227.10 6407.35 62.980 317.510 3771.44 3843.84 3183.23 N 2910.69 W 6003128.46 N 562862.63 E 3.133 4313.27 6503.38 59.580 314.300 3817.59 3889.99 3243.72 N 2969.25 W 6003188.43 N 562803.55 E 4.596 4397.44 6599.28 57.030 315.930 3867.98 3940.38 3301.51 N 3026.83 W 6003245.72 N 562745.46 E 3.027 4478.97 -. 6696.00 53.420 316.440 3923.13 3995.53 3358.82 N 3081.83 W 6003302.54 N 562689.96 E 3,757 4558.39 6792.05 50.030 317.120 3982.62 4055.02 3413.75 N 3133.47 W 6003357.02 N 562637.84 E 3.573 4633.78 6889.28 45.310 317,000 4048.08 4120.48 3466.36 N 3182.42 W 6003409.19 N 562588.42 E 4.855 4705.64 6984.88 41 .440 313.700 4117.56 4189.96 3513.10 N 3228.49 W 6003455.52 N 562541.94 E 4.690 4771.23 7080.83 41.210 313.120 4189.62 4262.02 3556.64 N 3274.52 W 6003498.65 N 562495.54 E 0.466 4834.45 7133.59 41.020 313.430 4229.37 4301.77 3580.42 N 3299.78 W 6003522.21 N 562470.07 E 0.528 4869.06 7190.00 41 .020 313.430 4271.93 4344.33 3605.87 N 3326.66 W 6003547.42 N 562442.96 E 0.000 4906.01 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 317.190° (True). Magnetic Declination at Surface is 25.599°(09-Feb-03) Based upon Minimum Curvature type calculations, at a Measµred Depth of 7190.00ft., The Bottom Hole Displacement is 4906.02f1., in the Direction of 317.306° (True). .~ 25 March, 2003 - 11:15 Page 4 of 5 Dri/lQuest 3.03.02.002 .-õ- .. Sperry-Sun Drilling Services Survey Report for MPS·20 MWD Your Ref: 500292313200 Job No. AKMW2277345, Surveyed: 14 February, 2003 BP EXPLORA TION (ALASKA) INC. Milne Point Unit BPXA Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 7190.00 4344.33 3605.87 N 3326.66 W Projected Survey .~ Survey tool prOflram for MPS-20 MWD Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 359.00 0.00 358.98 359.00 7190.00 358.98 Tolerable Gyro(MPS-20 Gyro) 4344.33 MWD Magnetic(MPS-20 MWD) ~ 25 March, 2003 - 11: 15 Page 5 of 5 DrillQuest 3.03.02.002 ') I MEMORANDUM ) State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich ~ Commissioner 111o'.P (}.ttj~' \ THRU: Jim Regg ~tl P.I. Supervisor DATE: April 28, 2003 SUBJECT: Mechanical Integrity Test BPX MPU S Pad FROM: Chuck Scheve Petroleum Inspector NON· CONFIDENTIAL Type Inj. Type test Well 5-20 P.T.D. 202-241 Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.TD. Notes: Well P.TD. Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Inj. Type test Type Inj. Type test Type Inj. Type test Typelnj. Type test 5 P Packer T.V.D. Test psi 15 Min. 30 Min. 1300 1300 1920 1900 Interval P/F I f Depth 4124 1031 Pretest 1300 1000 Initial 1300 1980 Tubing Casing T.V.D. Tubing Test psi Casi ng T.V.D. Tubing Test psi Casing T.V.D. Tubing Test psi Casing T.V.D. Tubing Test psi Casing Interval P/F Interval P/F Interval P/F Interval P/F Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover 0= Other (describe in notes) Test's Details I traveled to BPXs MPU 8 Pad and witnessed the initial MIT on well 8-20. The pretest tubing and casing pressures were observed and found to be stable. The pressure test was then performed for 30 minutes with the well demonstrating good mechanical integrity. M.I.T.'s performed: 1 Attachments: MIT report form 5/12/00 L.G. Number of Failures: º Total Time during tests: 1 hour cc: MIT MPU S Pad 4-28-03 CS.xls 5/7/2003 ~ G ,J /6\ c';"E Ö2) ~.. If \.\ _~ .~_.:J (::.-;--< ) c' fi1\ ,_. IA\ ~ '// [ß\ ,J tn1 ,_7:J I.fÙ ,_~ '.' \\ IJlJ ) ~ ,~ FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 333 W. ]TH AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276·7542 Pat Archey Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Milne Point Unit MPS-20i BP Exploration (Alaska), Inc. Permit No: 202-241 Surface Location: 3303' NSL, 208' WEL, Sec. 12, TI2N, RI0E, UM Bottomhole Location: 3697' NSL, 3506' WEL, Sec. 01, TI2N, RI0E, UM Dear Mr. Archey: Enclosed is the approved application for permit to drill the above referenced service well. This 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~¿;t~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED this Â,f.?day of January, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section ,\ " ~~,¡\.. ¡/i7/0rs 12. Distance to nearest property line 13. Distance to nearest well ADL 380110, 3506' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 6001 MD Maximum Hole Angle 18. Casin~ Program Specifications $Ize Casina Weight Grade CouDlina 20" 92# H-40 Welded 9-5/8" 40# L-80 BTC 7" 26# L-80 BTC Hole 42" 12-1/4" 8-112" , STATE OF ALASKA '\ ALASKA C._~ND GAS CONSERVATION COMMI~,-ÖN PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well [J Exploratory [J Stratigraphic Test [J Development Oil II Service [J Development Gas [J Single Zone [J Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Planned KBE = 72' Milne Point Unit / Schrader 6. Property Designation Bluff / ADL 380109 7. Unit or Property Name Milne Point Unit 8. Well Number / MPS-20i 9. Approximate spud date. 02/02/03?' Amount $200,000.00 / 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 7120' MD / 4298' TVD o 17. Anticipated pressure {s~20 AAC 25.035 (e) (2)} 67 Maximum surface 145s/psig, At total depth (TVD) 4162'/1872 psig Setting Depth Top Botom MD TVD MD TVD Surface Surface 1121 112' Surface Surface 29051 2500' Surface Surface 71201 4298' 11. Type Bond (See 20 AAC 25.025) 1 a. Type of work II Drill [J Redrill [J Re-Entry [J 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 33031 NSL, 208' WEL, SEC. 12, T12N, R10E, (As Staked) At top of productive interval 14921 NSL, 34221 WEL, SEC. 01, T12N, R10E, UM At total depth 3697' NSL, 35061 WEL, SEC. 01, T12N, R10E, UM Number 2S100302630-277 Lenath 112' 29051 71201 Quantity of Cement (include stage data) 260 sx Arctic Set (Approx.) 551 sx PF 'L., 190 sx Class 'GI 98 sx PF 'E', 149 sx Class IG' / ./ 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production Liner true vertical RECEIVED DEC 11 2002 Alasl<a Oil & Gas Gons. Commission Anchorage Perforation depth: measured 20. Attachments II Filing Fee [J Property Plat [J BOP Sketch [J Diverter Sketch II Drilling Program II Drilling Fluid Program [J Time vs Depth Plot [J Refraction Analysis [J Seabed Report [J 20 AAC 25.050 Requirements Contact Engineer NamelNumber: Steve Campbell, 564-4401 Prepared By Name/Number: Sondra Stewman, 564-4750 21. ~~:~:; C:a~::::t thep3oit::¡; correct tO~:::;i,En~~;er'::::;f{<;'/ Date i ~ /1 O/O;;¿ Permit Number API Number .., ") I 3 r) APpr9~al '!Ã'~~ '^ See cover letter 2- ß z.. - 2. '?II 50- 0 2. 9 - <-, => ...L--, '\ ;;0 - I U·) for other reQuirements Conditions of Approval: Samples Required 0 Yes )XI No Mud Log Re uire 0 Yes r8I No Hydrogen Sulfide Measures 0 Yes 181 No Directional Survey Required J8I 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 oRfð\'AÄiTs~~ fe ?;S'lJO psi. JIll: T, c"lotl~!td;1 101 Y'l't<tti'-CJ, ~)r2 Approved By M L. Ball Commissioner . the commission Date \ ~ ~ 'ú '2 Form 10-401 Rev. 12-01-85 ,~ ,. S mit I Triplicate ) Schrader Bluff r ~d Program MPS-20i Permit IWell Name: I MPS-20i Drill and Complete Program Summary I Type of Well (service I producer I injector): Injector / Surface Location: 1975' FNL, (33031 FSL), 2081 FEL, (50701 FWL), SEC. 12, T12N, R10E X=565801.52 Y=5999971.19 Target Start Location: 37871 FNL, (14921. FSL), 34221 FEL, (18561 FWL), SEC. 1, T12N, R10E "OB" X=562557.0 Y=6003412.00 2=4162 TVDss Bottom Hole Location: 3697' FNL, (1582' FSL), 35061 FEL, (17731 FWL), SEC. 1, T12N, R10E X=562472.71' Y=6003501.40 'z = 4298 TVDss I AFE Number: I TBD I RiQ: I Doyon 14 /' I Estimated Start Date: I 02 Feb 2003 I OperatinQ days to complete: 19.8 I MD: 17,120 I I TVD: 14,298 I I Max Inc: 167 I I KOP: 1600 I I KBE: 172.0 I Well DesiQn (conventional, slim hole, etc.): I Conventional Grass Roots Water Injector I Objective: I Schrader "OA", "DB" Mud Program 12.25-in Surface Hole Mud Properties: Density (ppa)~ Funnel visc YP 8.8-9.2/ 75-150 25-60 HTHP N/A Spud - LSND Freshwater Mud pH API Filtrate LG Solids 8.5 - 9.5 < 8 < 6.5 8.S-in Intermediate Hole Mud Properties: Density (pPQ) PV YP HTHP 8.9-9.2 / 10-20 20-28 N/A LCM Restrictions: None Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to D8-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1 R. LSND Freshwater Mud pH API Filtrate LG Solids 8.5 - 9.0 < 8 < 6.5 1 , ) Schrader Bluff S-p rro~:¡ram MPS-20i Permit Cement Program Casing 9.625-in 40-lb/ft L-80 BTC surface casing Size Basis 2500/0 excess over gauge hole in permafrost interval. 400/0 excess over gauge hole below permafrost. Top of tail cement 750-ft MD above casing shoe. Total Cement Wash 20-bbl Water Spacer Vol: 461-bbl Spacer Lead Tail Temp 50-bbI10)4tþ/gal un-viscosified Alpha spa~ 407-bbl¡b~;r~sx 10.7-lb/gal Permafrost L -MS/fe/sx (Ceme;~1 surface) ",....,"''''') 40-bbl, 9... -sx 15.8-lb/gal Premium G - V'~1t;j/sx to 0 n at 2,400-ft MD BHST == 55°F from SOR, BHCT 60°F estimated by Halliburton Casing 7.0-in 26-lb/ft L-80 BTC intermediate casing Size Basis Top of tail cement 500-ft MD above top of Ugnu. 40% excess over gauge. Total Cement Wash 20-bbl Water Vol: 70-bbl Spacer Lead Tail Temp 30-bbI10Âlb/gal un-viscosified Alpha Sp~er, 38-bbl, ~x 12.0-lb/gal Permafrost E - t.1 ~Ae/sx (top of~I'ê,øpt 4,947-ft MD, 500' abov~ìriflU) 30-bbl,¡(4.:~x 15.8-lb/gal Premium G -(.!.1 t' /sx to ofli11 at 6,153-ft MD, 500' above BHST == 80°F from SOR, BHCT 70°F estimated by Halliburton Evaluation Program 12.25-in Hole Section: Open Hole: MWD/GR Gyro if required Cased Hole: None 8.S-in Hole Section: Open Hole: MWD/GRlRES Cased Hole: SCMT 2 ) Schrader Bluff S-Pr 1ro~uam MPS-20i Permit "" Formation Markers Formation Tops MOrkb TVDrkb Pore Pressure Estimated EMW (ft) (ft) (psi) (Ib/gal)* Base Permafrost 1884 1822 TUZC 5447 3472 NA 6653 3972 1786 8.65 NB 6686 3992 1795 8.65 NC 6726 4017 1806 8.65 ~ . "l.. NF 6824 4082 1836 8.65 Top OA 6867 4112 1849 8.65 Base OA 6902 4137 1860 8.65 Top 08 6936 4162 1872 8.65 Base OB 6970 4187 * Based on 55 depths Casin~rrubing Program Hole Size Csg/ WtlFt Gr5'e Conn Length Top Bottom Tbg O.D. / MD / TVDrkb MD / TVDrkb 42-in 20-in* 92# H-40 Welded 80' 0' t 12' / 112' 12.25 9.625 40# L-80 8TC 2,905' 0' 2,905' / 2,500' 8.5-in 7.0-in 26# L-80 BTC 7,120' 0' 7,120' / 4,298' * The 20-in conductors are insulated! Recommended Bit Program BHA Hole Size Depth (MD) Bit Type 1 2 12.25-in 0' - 2,905' 8.5-in 2,905' - TO Smith FGXI Smith FGS+ Nozzle/Flow rate 3-15 & 1-1 0 3-15 & 1-1 0 3 ') Schrader Bluff s-pr\1rO~:lram MPS-20i Permit Well Control: Surface hole will be drilled with a diverter. / Intermediate hole: · Maximum anticipated BHP: 1,872-psi @ 4, 162-ft TVprkb - Top of "DB" · Maximum surface pressure: 1,455-psi @ surface / (Based on BHP and a full column of gas from TO @ O.1-psi/ft) ._ . /.... ,~ . ,Planned BOP test pressure: ~,~()O~P's!. "._.. ,". ,... . . .._ . ';. _,..:~. . ....,.. ..... ., :.... <integrity test: . An: FI.T)o.11 ,,5-lb/gal will· þe .rn.~d~!·PtIthØ }·.O~in ,ç~sjng; .. . . ,. ,-- . :-:.' . ., .....~ ,", . ~ ,., ", r · .;:~> :,~:.'.:.:_. ::,':,.~...... .._~_,,~,_~,. ...,.,._;~.shoe.' :..·:··'~ick toleran..ce: 77~9"bbtwithfL2~lb/gal ~{Ú:få!î~.~f.ìÎ~-~fJ1:~$~lb/ga:1 @> :>" :,; .,...>_.. ,.... ..:: _ _,_.~:.~ .. .>:::.,_~~~-'-9_~~2;;~lo :þ~sirjg.·shQ~~ · Planned completion fluid: 9.8-lb/gal brine I 7.0-lb/gal Diesel (1 ,800-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- 1 ,800-ft TVDss) but maybe present in shallower SV sands and also as deep as 3,OOO-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 wi 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. 4 ~) Schrader Bluff S-Pr . JrOQram MPS-20i Permit · 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. · 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. /' · 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 present on the planned well path. Hydrogen Sulfide · Milne Point S-Pad is not designated as an H2S Pad. /" Anti-collision Issues · None, except for consideration of planned wells. 5 ') Schrader Bluff s-p¡, 'rroÇlram MPS-20i Permit DRILL & COMPLETION PROCEDURE Drillinq 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. /'" MIRU Doyon 14, NU diverter. /' Drill 12.25-in hole to 2,905-ft as per directional plan. ,,/ Rig up and run 9.625-in 40-lb/ft, L-80, BT&C casing and cement in place. ND diverter. NU BOPE. / Drill 8.5-in hole to TD as per directional plan. Rig up and run 7.0-in 26-lb/ft, L-80, BT&C casing and cement in place. /' Run SCMT log. /' Test casing to 3500-psi Perforate well in OA and OB sands. ,/,. Run 2.375-in dual completion. /' Test packer to 3500-psi Install tubing head and Christmas tree. RD Doyon 14. Spinner survey to be done after rig moves off of location. 6 L Proposed MPS-20 ,Jal string completion 20" 92# H-40 WELDED CONDUCTOR @ 112' MD/TVD I II··· 2-3/8" 'X' nipples (set at - 2200' MD) .~ ~ r~ f. ~ ~r· ,~ !IL" 0 " § '~ i!~ '.~ !í'íi IE ¥ ! i: [ ;~ ~. IIò: ~ :f I ~ J. 1 ì; II' ~ ,¡ ì ~ :} 'h 2-3/8" 4.7# L80 1ST tubing strings ~1 I :~ ~ :i .~ 9-5/8" 40# 1-80 BT&C ~MD/2500' TVD J :~ ~ ~ ~ ~ Ii 1:, ß ~ ~ '~ l\:.; t! f¡ ¡~ .' ,j ~ t ã, l: " .~ , ;¡ ~ ~ ~ ; !r:' ~ '. tl t IJ :j n ~ w 4 'I: ~, :1 ~ 1 P ,. i ~I! i ~ ~ j I I~ ~ ':~; . ] 'i , ~ ~ ~ ~ ~ ,) ~ ,~ i ~ t ~ ~ '{ ¥ ,~ ~ 'j ~ '¥. ~I 7" x 2-3/8" Saker GT dual packer (set at - 6767' MD) /' 2-3/8" 4.7# L80 1ST pup jt (-10') 2-3/8" 'X' nipple with 1.875" no-go OA Perfs 2-3/8" 4.7# L80 1ST pup jt (-10') 6867 - Re-entry guide 6902' MD OS Perfs 6936- 6970' MD / 7" x 2-3/8" Saker FH packer (set at -6910' MD) 2-3/8" 4.7# L80 1ST pup jt (-10') 2-3/8" 'X' nipple with 1.875" no-go 2-3/8" 4.7# L80 1ST pup jt (-10') Re-entry guide -- . ..~ 7" 26# L-80 BT&C ~D/4298' TVD 2-3/8" Dual Strings with dedicated OA and OB injection. Plan: MPS·20 wp06 (Plan MPS-20iPlan MPS-20) C",,"ed By: Ken AUen Date: 1214/2002 Checked: Date: Reviewed: Date: Tool CB-GYRO-SS M\\1}oIFR~MS SURVEY PROGRA!'o' o.pth Fm D<pth To SurwY'Plao 33.00 1200.00 Planned: MPS-20 "-1'06 VI1 1200.00 1120.12 PIamed: MPS-20 "-1'06 VI1 REFERENCE !!\'FORMA TION Co-onJi...", (N'E) R"r.reuœ, W.II Centr" Plan MPS·20. 1m: Nc'<1h Vcrtícal (n'D) R"r"""""" S·Pad 0",. 72.00 S«,ion (VS) R.r"""",,,, Slot - (O.OON.O.OOE) M<3SUr«l Deptb R"r.r"",:e; S·Pad 0",. 12.00 Calcula'ion M<Ihod Minimum CIID~ture COMI'ANYIJHAI BPAn....X'o C"a,:ulatioo Mo:tb.x1: MininMUn CUl\'3lure Em·r Sysr...'11': ISCWSA Scan Method: Tra\'CyhD.krNonh Error Surr<KO:: Ellirtil;al - Casin)?: Wamín~ M~lh(1d: Rub ß.1scd d Slot N'A Loogitud< 149"'21'5I.1mW latitud< 10'24-:J1309N WELL DETAILS Northing Ea5ÛD¡! 5999911.19 565&0152 TARGET DETAILS +EI·W Northing ·3493.82 6004159.00 ·321439 fœ34I2.oo ~-w ·543.51 -N'-S ·1.98 Name Pian MPS-20 Size 9.625 7.000 CASING DETAILS MD Name 95/8' 7" 2905.22 7120.11 TVD 2501.46 4298.46 No. All TVD depths are ssTVD plus 72'for RKBE. Target Xatu (OB) VSec 0.00 0.00 2.33 167.81 318.40 370.74 1076.70 4212.10 4729.73 4752.24 4852.61 Sbap< Polygon Cittle ,REdius: (50) DLeg TFace 0.00 0.00 0.00 0.00 1.50 317.19 2.50 0.00 2.00 0.00 0.00 0.00 -.r:Q0 -0.01 0.00 0.00 4.00 179.99 0.00 0.00 0.00 0.00 Easting 562211.00 562551.00 +E/-W 0.00 0.00 -1.58 - 114.04 -216.37 -251.95 -731. 72 -2862.60 -3214.39 -3229.68 -3297.89 -N'·S 4219.15 346959 SECTION DETAILS +N/-S 0.00 0.00 1.71 123.11 233.58 271.98 789.86 3089.87 3469.59 3486.10 3559.74 1VD 4107.00 4162.00 TVD 33.00 550.00 683.31 1461.86 1777.57 1872.00 2501.46 3796.56 4162.00 4187.00 4298.47 Name XaIU Hardliœ Xa1u (OB) Azi 0.00 0.00 317.19 317.19 317.19 317.19 317.19 317.19 317.19 317.19 317.19 MD Ine 33.00 0.00 550.00 0.00 683.33 2.00 1483.33 22.00 1833.33 29.00 1941.30 29.00 2905.22 67.56 6297.56 67.56 6936.48 42.00 6970.12 42.00 7120.12 42.00 Sec 1 2 3 4 5 6 7 8 9 10 11 MDPath Fonnation 1884.14 BPRF 5447.42 TUZC 6653.98 SBF2-NA'- 6686.94 SBF1-NB 6726.83 SBE4-NC 6750.12 SBE2-NE 6824.80 SBEI-NF 6867.68 TSBD-OA 6902.47 TSBC 6936.48 TSBB-OB 6970.12 TSBA5 (base OB) FOR.,\-tAT10N TOP DETAILS TVDPath 1822,00 3472.00 3972.00 3992,00 4017.00 4032.00 4082,00 4112.00 4137.00 4162,00 4187,00 No. 1 2 3 4 5 6 7 8 9 10 11 550' MD, 550'TVD 683.33' MD, 683.31'TVD A Start Dir 1.5/100' / Start Dir 2.5/100' /" 0- -..' ~ " ,~ ~ .Jtq, . ~ Ñ /~~ ..J'I ;'~ /' ~ \6° -go ¡ 002. 800 / MD,1461.86'TVD End Dir : 1833.33' MD, 1777.57' TVD Start Dir 4/100' : 1941.3' MD, 1872'TVD 2905.22' MD, 2501.46' TVD End Di 1483.33' 600 E 2: o ~ ..c ë- CJ '" () '€ >- 2400 2 E- ,~ .............. 3200 Xatu Hardline SBF2-NA 6207,56' t.,ID, 37'J6.5bT .'D ~¡g SBE4-NC SBF NB /? TSBD-OA SBP-~ TSBB-OB ~RF l-NF ! / I Xatu (OB) I~HC/7Ì~ TSBA5(baseOB) ~O( Die : 6936J18' ~l ,_ / MPS-20 wp06 , 7" ..., D< ~f , : 1m2' n"A" 'r 4800 IOJ SInn Di 4000 I ' 5600 4000 2400 3200 Vertical Section at 317.19° [800ft/in] 1600 800 Plan: MPS-20 wp06 (Plan MPS-20!Plan MPS-20 C r""led By: Ken Allen I>ate: Checked: Date: Date: SURVEY PROGR<\M o"pth Frn D<pth To Suryey.Plan Tool 33.00 1200.00 Planned: MPS-20 "p06 VI CB-G YRO-SS 1200.00 7120.12 Planoot MPS·20 "p06 V I MWD--'-IFR~MS REFERENCE INFORMATION \Vell Centr~: Plan MPS...20. Trœ North S-Pad o,,\, 72.00 Slot - (O.ooN.O.OOEI S-Pad 0",. 72.00 Minimum Cllr..atur~ Co-ordiD.3t~ (N:E) R¿f¿rçn,:è: Vert;.;al (f'.D) R.ofcr=: SoctiOD (\'5) R.::fer-~DCè: r.kasul\.'d D<pth Refe"'o«: C8ku1at~m Mçtbod: ò WELL DETAIlS No<1hing Easling 5999971.19 56580152 Milllmu!11 CUlva!1 ¡SeWSA lr.ì\·C\'III}(~rN\lftl Flit,,;.:31 . Casing Rul..:slb~....1 l"al..1J13Ik.'oßM':-II'Il1l; Em... Sys!.:m Scan M~th.'I(1 Erwr SurÚ1:': W3nli~M.."f.hc...t Slot N'A longituœ 149'27·51.103W lati~ 70"24'37309N TARGET DETAILS -;.-Ð-'V Northing -3493.82 600U59.OO -321439 6003412.00 cF.J-W -5435 -N'-S -1.98 Name Plan MPS-2 Size 9.625 7.000 CASING DETAILS Name 95/8' 7" MD 2905.22 7120.11 TVD 2501.46 4298.46 No. I 2 7120.12' MD, 4298.47' TVD Total Depth MPS·20 wp06 ]' - Eæ;1ing Shape 562271.00 Pol)"ßOD 562557.00 Cude (Radius: ....-N'-S 4219. 3469. TVD 4107.00 416200 Narœ XaIu Hard!iœ XaIu (OB) Target VSee 0.00 0.00 2.33 167.81 318.40 370.74 1076,70 4212.10 4729.73 4752.24 4852.61 150) TFaee 0.00 0.00 317. I 9 0,00 0,00 0.00 -0.01 0.00 179.99 0.00 0.00 DLeg 0.00 0,00 L50 2.50 2.00 0.00 4.00 0.00 4.00 0.00 0.00 SECTION DETAILS +EIcW 0.00 0.00 -1.58 114.04 216.37 -251.95 -731.72 -2862.60 -321439 -3229.68 -3297.89 +N/-S 0.00 0.00 1.71 123.11 233.58 271.98 789.86 3089.87 3469.59 3486.10 3559.74 TVD 33,00 550.00 68331 1461.86 1777.57 1872.00 2501.46 3796.56 4162,00 4187.00 4298.47 Azi 0.00 0.00 317.19 317.19 317.19 317.19 317.19 317.19 317.19 317.19 317.19 Ine 0.00 0.00 2.00 22.00 29.00 29.00 67.56 67.56 42.00 42.00 42.00 MD 33.00 550.00 683.33 1483.33 1833.33 1941.30 2905.22 6297.56 6936.48 6970.12 7120.12 See 1 2 3 4 5 6 7 8 9 10 II TVD 6297,56' MD, 3796.56'TVD 6936.48' MD, 4162' i i I Xlitlf Hall'lilll: I I ~r.dD 250 518" ~tnrt Dir 4/100' : 1941.3' MD, 1872'TVD End Dir : 1833.33' MD, 1777.57' TVD '\...... S~artDir2I1oo': 1483.33'MD, 1461.86'TVD 1500~ Start Dir 2.5/100' : 68333' MD, 68331 'TVD ~O('O - Start Dir 1.51100' : 550' MD, 550'TVD -1200 -600 W est( - )Æast( +) [ 600ft/in] ........, Xatu (OB) FORMATION TOP DETAILS TVDPath MDPath Fonnation BPRF TUZC SBF2-NA SBFI-NB SBE4-NC SBE2-NE SBEI-I\'F TSBD-OA TSBC TSBB-OB TSBA5 (base OB) 1884.14 5447.42 6653.98 6686.94 6726.83 6750.12 6824.80 6867.68 6902.4 7 6936.48 6970.12 1822.00 3472.00 3972.00 3992.00 4017.00 4032.00 4082.00 4112.00 4137,00 4162.00 4187.00 No. I 2 3 4 5 6 7 8 9 10 1 I -- --- All TVD depths are == ssTVD plus 72'for RKBE. ~ 3600 3000 2400 200 800 c ~ o o :£. +' :;:: t: o ~ ~ o VJ " ~~ I 200 I 600 TVD 2501.46' o MD, 2905.22' i 1800 -2400 -3000 -- -3600 600 o ~) ) BP KW A Planning Report MAP Company: Field: Site: Well: Wellpath: ßpAmoco Milne Point M·PtSPad Plan MPS-40 Plan MPS-20 Da~: <12/4/2002> Time: 07:14:2p ... ... .. Page: Ç«~~r4~J1at~(N~)~ef~rence: Well: .Plarl MPS.,20, True North V~r1cal(TYD)~ef~r~~ce: S-~~d. qev72.0 Seeti~I){YS) R~f~ren~e: Well (0.00N,Q.00E,317.19Azi) SurveyCalcûla~~n.Method: ... Minimum Curvature Db: Oracle Field: 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 BGGM2002 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-20 Slot Name: Well Position: +N/-S -1.98 ft Northing: 5999971.19 ft Latitude: 70 24 37.309 N +E/-W -543.57 ft Easting : 565801.52 ft Longitude: 149 27 51.103 W Position Uncertainty: 0.00 ft Wellpath: Plan MPS-20 Plan: MPS-20 wp06 Date Composed: Version: Tied-to: Well Ref. Point 0.00 ft Mean Sea Level 26.21 deg 80.79 deg Direction deg 317.19 11/20/2002 17 From Well Ref. Point +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Current Datum: Magnetic Data: Field Strength: Vertical Section: S-Pad Dev 6/29/2001 57481 nT Depth From (TVD) ft 0.00 Height 72.00 ft Principal: Yes Casing Points MD TVD Diameter Hole. SIZe ft ft in in 2905.22 2501.46 9.625 12.250 95/8" 7120.11 4298.46 7.000 8.500 7" Formations MD TVD Formations Lithology Dip Angle Dip DIrection ft ft deg deg 1884.14 1822.00 BPRF 0.00 0.00 5447.42 3472.00 TUZC 0.00 0.00 6653.98 3972.00 SBF2-NA 0.00 0.00 6686.94 3992.00 SBF1-NB 0.00 0.00 6726.83 4017.00 SBE4-NC 0.00 0.00 6750.12 4032.00 SBE2-NE 0.00 0.00 6824.80 4082.00 SBE1-NF 0.00 0.00 6867.68 4112.00 TSBD-OA 0.00 0.00 6902.47 4137.00 TSBC 0.00 0.00 6936.48 4162.00 TSBB-OB 0.00 0.00 6970.12 4187.00 TSBA5 (base OB) 0.00 0.00 Targets Map Map <- Latitude --> <-- Longitude -> Name Description TVD +N/-S +E/-W Northing Easting Deg Min See Deg Min Sec Dip. Dir. ft ft ft ft ft Xatu Hardline 4107.00 3114.48 -3434.54 6003055.00 562340.00 70 25 7.932 N 149 29 31.814 W -Polygon 1 4107.00 4219.15 -3493.82 6004159.00 562271.00 70 25 18.795 N 149 29 33.567 W -Polygon 2 4107.00 3114.48 -3434.54 6003055.00 562340.00 70 25 7.932 N 149 29 31.814 W -Plan out by 407.08 at 4107.00 3431.28 -3178.90 6003374.00 562592.82 70 25 11.048 N 149 29 24.321 W Xatu (OB) 4162.00 3469.59 -3214.39 6003412.00 562557.00 70 25 11.425 N 149 29 25.363 W ) BP ) KW A Planning Report MAP Company: BPAmoco Date: .·..12/4/20Q2 Tilne: .. 07:11:25.'. . .. . ....... .. .Pa~e: Field: Mill1e Point Ço,.Qrdi~.t~(~,æ)lt~fere~ce: Well:PI~nMP$2(),.True North Site: M PtSPad Vel't~eal(1'Yº~ltef~re~ee: S~Padpev72,0 ... .. Well: Plan MPS-20 S~tiol1("S).·ª~fe..el1e~: VVell{Q.QON,O.00E,317.19Azi) WelIpath: Plarl MpS~2() ,Survey' Çalcula~i9nMeth~d: MinimumCul'Vature Db: Oracle Targets Måp M:~lt) <:'·.i.;/Låtitûde _..~ <~_... Longitude· ..;--> µe$eriptioJj Northing Easting DegMin·.··. .·Sec Deg Min See Dip. Dir. ft ft -Circle (Radius: 150) -Plan hit target Plan Section Information MD lncl Azim TVD +N/-S +E/-W pLS ..... ........ ·BlIild.·· ... .·..·.Turn TJ;?O Target ft deg deg it ft' ft .. deg/10Qftd~g/100ftdeg/1()Qft cI¢g 33.00 0.00 0.00 33.00 0.00 0.00 0.00 0.00 0.00 0.00 550.00 0.00 0.00 550.00 0.00 0.00 0.00 0,00 0.00 0,00 683.33 2.00 317.19 683.31 1.71 -1.58 1.50 1.50 0.00 317.19 1483.33 22.00 317.19 1461.86 123.11 -114.04 2.50 2.50 0.00 0.00 1833.33 29.00 317.19 1777.57 233.58 -216.37 2.00 2.00 0.00 0.00 1941.30 29.00 317.19 1872.00 271.98 -251.95 0.00 0.00 0.00 0.00 2905.22 67.56 317.19 2501.46 789.86 -731.72 4.00 4.00 0.00 -0.01 6297.56 67.56 317.19 3796.56 3089.87 -2862.60 0.00 0.00 0.00 0.00 6936.48 42.00 317.19 4162.00 3469.59 -3214.39 4.00 -4.00 0.00 179.99 Xatu (OB) 6970.12 42.00 317.19 4187.00 3486.10 -3229.68 0.00 0.00 0.00 0.00 7120.12 42.00 317.19 4298.47 3559.74 -3297.89 0.00 0.00 0.00 0.00 Survey MD Incl Azi.m TVD SysTVD MåpN . Map~ VS DLS. .. TFO Tool/Comment ft deg deg ft ft ft ft ft d~g/10Oft deg 33,00 0.00 0.00 33,00 -39.00 5999971.19 565801.52 0.00 0.00 0.00 CB-GYRO-SS 100.00 0.00 0.00 100.00 28.00 5999971.19 565801.52 0.00 0.00 0.00 CB-GYRO-SS 200.00 0.00 0.00 200.00 128.00 5999971.19 565801.52 0.00 0.00 0.00 CB-GYRO-SS 300.00 0.00 0.00 300.00 228.00 5999971.19 565801.52 0.00 0.00 0.00 CB-GYRO-SS 400.00 0,00 0.00 400.00 328.00 5999971.19 565801.52 0.00 0.00 0.00 CB-GYRO-SS 500.00 0.00 0.00 500.00 428.00 5999971.19 565801.52 0.00 0.00 0.00 CB-GYRO-SS 550.00 0.00 0.00 550.00 478.00 5999971.19 565801.52 0.00 0.00 0.00 CB-GYRO-SS 600,00 0.75 317.19 600.00 528.00 5999971.43 565801.30 0.33 1.50 0.00 CB-GYRO-SS 683,33 2.00 317.19 683.31 611.31 5999972.88 565799.92 2.33 1.50 0.00 CB-GYRO-SS 700.00 2.42 317.19 699.96 627.96 5999973.35 565799.48 2.97 2.50 0.00 CB-GYRO-SS 800,00 4.92 317.19 799.75 727.75 5999978.00 565795.10 9.36 2.50 0.00 CB-GYRO-SS 900.00 7.42 317.19 899.16 827.16 5999985.82 565787.73 20.10 2.50 0.00 CB-GYRO-SS 1000.00 9.92 317.19 998.01 926.01 5999996.78 565777.39 35.17 2.50 0.00 CB-GYRO-SS 1100.00 12.42 317,19 1096.11 1024.11 6000010.87 565764.11 54.54 2.50 0.00 CB-GYRO-SS 1200.00 14.92 317,19 1193.27 1121.27 6000028.06 565747.91 78.16 2.50 0.00 MWD+IFR+MS 1300,00 17.42 317,19 1289.31 1217.31 6000048.31 565728.81 106.00 2.50 0.00 MWD+IFR+MS 1400,00 19.92 317.19 1384.04 1312.04 6000071.59 565706.86 138.01 2.50 0.00 MWD+IFR+MS 1483,33 22,00 317.19 1461.86 1389.86 6000093.28 565686.41 167.81 2.50 0.00 MWD+IFR+MS 1500,00 22.33 317.19 1477.29 1405.29 6000097.85 565682.10 174.10 2.00 0.00 MWD+IFR+MS 1600,00 24.33 317.19 1569.11 1497.11 6000126.67 565654.93 213.71 2.00 0.00 MWD+IFR+MS 1700,00 26.33 317,19 1659.49 1587.49 6000157.80 565625.58 256.49 2.00 0.00 MWD+IFR+MS 1800.00 28.33 317.19 1748.32 1676.32 6000191.20 565594.09 302.41 2.00 0.00 MWD+IFR+MS 1833.33 29.00 317,19 1777.57 1705.57 6000202.83 565583.12 318.40 2.00 0.00 MWD+IFR+MS 1884.14 29.00 317,19 1822.00 1750.00 6000220.75 565566.22 343.03 0.00 180.00 BPRF 1900.00 29.00 317.19 1835.87 1763.87 6000226.35 565560.95 350.72 0.00 180.00 MWD+IFR+MS 1941,30 29.00 317.19 1872.00 1800.00 6000240.92 565547.21 370.74 0.00 180.00 MWD+JFR+MS 2000,00 31.35 317.19 1922.74 1850.74 6000262.38 565526.98 400.24 4.00 359.99 MWD+IFR+MS 2100.00 35.35 317.19 2006.26 1934.26 6000302.36 565489.28 455.20 4.00 359,99 MWD+JFR+MS 2200.00 39.35 317.19 2085.74 2013.74 6000346.49 565447.67 515.86 4.00 359.99 MWD+IFR+MS 2300,00 43.35 317.19 2160.79 2088.79 6000394.54 565402.36 581.91 4.00 360.00 MWD+IFR+MS 2400.00 47.35 317.19 2231.06 2159.06 6000446.28 565353.57 653.03 4.00 360.00 MWD+IFR+MS 2500,00 51.35 317.19 2296.19 2224.19 6000501.46 565301.54 728.88 4.00 360.00 MWD+IFR+MS 2600,00 55.35 317.19 2355.88 2283.88 6000559.82 565246.52 809.09 4.00 360.00 MWD+IFR+MS 2700,00 59.35 317.19 2409.82 2337.82 6000621.06 565188.77 893.27 4.00 360.00 MWD+IFR+MS '. ) ) BP KW A Planning Report MAP Company: BP Amoco Date: .·1.2/4/200? Tlrne:07:14:25 Page: 3 Field: Milne Point Co~rdin.te(NE)Reference: VVell:·.Plàn MPS"20,·True.North Site: MptS'Pad V ert~cal (TVq) ~~ference: S"Pad Dev 72.0 .... .... Well: Plan MPS~20 Section(VS)....Refe~el1ce: ... VVeIL(O.OON ,0.OOE,317 .t9Azi) Wellpatb: Plan· MPS-20 Survey (;alcul,tion M~thod: Minimum Curvature I>b: Oracle Survey MD lncl Azim TVI> SysTVD MapN VS DLS TFO Tool/Comment ·ft deg deg ft ft ft it deg/tOOft ····.·d~9 2800,00 63.35 317.19 2457.76 2385.76 6000684.88 981.01 4.00 360.00 MWD+IFR+MS 2905,22 67.56 317.19 2501.46 2429.46 6000754.49 565062.94 1076.70 4.00 360.00 MWD+IFR+MS 3000,00 67.56 317.19 2537.65 2465.65 6000818.22 565002.85 1164.30 0.00 0.00 MWD+IFR+MS 3100,00 67.56 317.19 2575.82 2503.82 6000885.46 564939.45 1256.73 0.00 0.00 MWD+IFR+MS 3200,00 67.56 317.19 2614.00 2542.00 6000952.70 564876.04 1349.15 0.00 0.00 MWD+IFR+MS 3300,00 67.56 317.19 2652.18 2580.18 6001019.93 564812.64 1441.58 0.00 0.00 MWD+IFR+MS 3400,00 67.56 317.19 2690.35 2618.35 6001087.17 564749.24 1534.00 0.00 0.00 MWD+IFR+MS 3500,00 67.56 317.19 2728.53 2656.53 6001154.41 564685.83 1626.43 0.00 0.00 MWD+IFR+MS 3600,00 67.56 317.19 2766.71 2694.71 6001221.65 564622.43 1718.85 0.00 0.00 MWD+IFR+MS 3700,00 67.56 317.19 2804.89 2732.89 6001288.88 564559.03 1811.28 0.00 0.00 MWD+IFR+MS 3800,00 67.56 317.19 2843.06 2771.06 6001356.12 564495.62 1903.71 0.00 0.00 MWD+IFR+MS 3900.00 67.56 317,19 2881.24 2809.24 6001423.36 564432.22 1996.13 0.00 0.00 MWD+IFR+MS 4000,00 67.56 317,19 2919.42 2847.42 6001490.60 564368.82 2088.56 0.00 0.00 MWD+IFR+MS 4100.00 67.56 317,19 2957.59 2885.59 6001557.83 564305.41 2180.98 0.00 0.00 MWD+IFR+MS 4200.00 67.56 317,19 2995.77 2923.77 6001625.07 564242.01 2273.41 0.00 0.00 MWD+IFR+MS 4300.00 67.56 317.19 3033.95 2961.95 6001692.31 564178.60 2365.83 0.00 0.00 MWD+IFR+MS 4400.00 67.56 317.19 3072.12 3000.12 6001759.55 564115.20 2458.26 0.00 0.00 MWD+IFR+MS 4500.00 67.56 317.19 3110.30 3038.30 6001826.78 564051.80 2550.69 0.00 0.00 MWD+IFR+MS 4600.00 67.56 317.19 3148.48 3076.48 6001894.02 563988.39 2643.11 0.00 0.00 MWD+IFR+MS 4700,00 67.56 317.19 3186.66 3114.66 6001961.26 563924.99 2735.54 0.00 0.00 MWD+IFR+MS 4800,00 67.56 317.19 3224.83 3152.83 6002028.50 563861.59 2827.96 0.00 0.00 MWD+IFR+MS 4900,00 67.56 317.19 3263.01 3191.01 6002095.73 563798.18 2920.39 0.00 0.00 MWD+IFR+MS 5000,00 67.56 317,19 3301.19 3229.19 6002162.97 563734.78 3012.81 0.00 0.00 MWD+IFR+MS 5100.00 67.56 317.19 3339.36 3267.36 6002230.21 563671.38 3105.24 0.00 0.00 MWD+IFR+MS 5200.00 67.56 317.19 3377.54 3305.54 6002297.45 563607.97 3197.67 0.00 0.00 MWD+IFR+MS 5300.00 67.56 317.19 3415.72 3343.72 6002364.69 563544.57 3290.09 0.00 0.00 MWD+IFR+MS 5400.00 67.56 317.19 3453.89 3381.89 6002431.92 563481.17 3382.52 0.00 0.00 MWD+IFR+MS 5447.42 67.56 317.19 3472.00 3400.00 6002463.81 563451.10 3426.35 0.00 0.00 TUZC 5500,00 67.56 317.19 3492.07 3420.07 6002499.16 563417.76 3474.94 0.00 0.00 MWD+IFR+MS 5600,00 67.56 317,19 3530.25 3458.25 6002566.40 563354.36 3567.37 0.00 0.00 MWD+IFR+MS 5700,00 67.56 317,19 3568.43 3496.43 6002633.64 563290.96 3659.79 0.00 0.00 MWD+IFR+MS 5800.00 67.56 317.19 3606.60 3534.60 6002700.87 563227.55 3752.22 0.00 0.00 MWD+IFR+MS 5900.00 67.56 317.19 3644.78 3572.78 6002768.11 563164.15 3844.65 0.00 0.00 MWD+IFR+MS 6000.00 67.56 317.19 3682.96 3610.96 6002835.35 563100.75 3937.07 0.00 0.00 MWD+IFR+MS 6100,00 67.56 317.19 3721.13 3649.13 6002902.59 563037.34 4029.50 0.00 0.00 MWD+IFR+MS 6200,00 67.56 317.19 3759.31 3687.31 6002969.82 562973.94 4121.92 0.00 0.00 MWD+IFR+MS 6297,56 67.56 317.19 3796.56 3724.56 6003035.42 562912.08 4212.10 0.00 0.00 MWD+IFR+MS 6300.00 67.46 317.19 3797.49 3725.49 6003037.06 562910.54 4214.35 4.00 179.99 MWD+IFR+MS 6400.00 63.46 317.19 3839.02 3767.02 6003103.22 562848.15 4305.30 4.00 179.99 MWD+IFR+MS 6500,00 59.46 317.19 3886.78 3814.78 6003167.12 562787.90 4393.13 4.00 179.99 MWD+IFR+MS 6600,00 55.46 317.19 3940.56 3868.56 6003228.43 562730.08 4477.41 4.00 179.99 MWD+IFR+MS 6653,98 53.30 317.19 3972.00 3900.00 6003260.35 562699.98 4521.29 4.00 179.99 SBF2-NA 6686.94 51.98 317.19 3992.00 3920.00 6003279.41 562682.01 4547.48 4.00 179.99 SBF1-NB 6700.00 51 .46 317,19 4000.09 3928.09 6003286.87 562674.98 4557.74 4.00 179.99 MWD+IFR+MS 6726,83 50.39 317,19 4017.00 3945.00 6003302.02 562660.69 4578.56 4.00 179.99 SBE4-NC 6750,12 49.45 317.19 4032.00 3960.00 6003314.99 562648.47 4596.39 4.00 179.99 SBE2-NE 6800,00 47.46 317.19 4065.08 3993.08 6003342.15 562622.86 4633.72 4.00 179.99 MWD+IFR+MS 6824.80 46.47 317.19 4082.00 4010.00 6003355.33 562610.43 4651.84 4.00 179.99 SBE1-NF 6860.63 45.03 317.19 4107.00 4035.00 6003374.00 562592.82 4677 .50 4.00 179.99 Xatu Hardline 6867,68 44.75 317.19 4112.00 4040.00 6003377.63 562589.41 4682.49 4.00 179.99 TSBD-OA 6900,00 43.46 317.19 4135.20 4063.20 6003393.99 562573.98 4704.98 4.00 179.99 MWD+IFR+MS 6902.4 7 43.36 317.19 4137.00 4065.00 6003395.23 562572.81 4706.68 4.00 179.99 TSBC Company: BP Amoco Field: Milne Point Site: M PtSPad Well: Plan MPS-20 Wellpatb: Plan.MPS-20 ) ) BP KW A Planning Report MAP Date: 12/4/2002 Time: 07:14:25. . ... .... Pa~e: Çø..ordináte(NE)Reference:WèlhPlanMP$-20, True Npl'th Vert~cal (TVI»:R~fereµce: S-Pé:1dD~v7?:O Seçtión(YS) Ref~rence: WeIL(q.00N,Q;OOE,317, 19Azi) :~urvey C~I~ubJ.tiQnM~tIiod: Minimum Curvature I)b: Survey MO InCl Aziln ft deg d~g 6936.48 42.00 317.19 6970.12 42.00 317.19 7000.00 42.00 317.19 7100.00 42.00 317.19 7120.12 42.00 317.19 4 TV» SysTVD MapN M~pE VS DLS TFO ft ft ft ft ft dag/tOOft ··.çteg 4162.00 4090.00 6003412.00 562557.00 4729.73 4.00 179.99 Xatu (OB) 4187.00 4115.00 6003428.38 562541.56 4752.24 0.00 180.00 TSBA5 (base OB) 4209.20 4137.20 6003442.92 562527.84 4772.23 0.00 180.00 MWD+IFR+MS 4283.52 4211.52 6003491.60 562481.95 4839.14 0.00 180.00 MWD+IFR+MS 4298.47 4226.4 7 6003501.40 562472.71 4852.61 0.00 180.00 MWD+IFR+MS P054966 DATE CHECK NO. DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS 11/18/02 VENDOR DISCOUNT P054966 NET 11/18/02 INV# CKll1402G PERMIT TO DRILL FEE H -V-Y·l'-;>-,\ - . 'j ,"'" ; r ,-/ f.--..l_) i RECEtv ED DEC 11 2)02 AlàS\<a Oil & Gas Gons. Commission - Anchorage ~ THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK 99519-6612 NATIONAL CITY BANK Ashland, Ohio 56-389 41"2" No. P 054966 CONSOLIDATED COMMERCIAL ACCOUNT PAY TO THE ORDER OF ALAKSA OIL & GAS CONSERVATION 333 W. 7th AVE, STE.100 ANCHORAGE, AK 99501 , DATE NOV. 1a¡2002 AMOUNT , , , 8"...:.','p' r;~ ..~.. ~1Ut. ,'m','''''·.·'':I··':f.',.''t.:''.''',,', ,. I.'.,f,.,i,..,',',.',. "-'f.. J I 'I.., nUt' I .. . "'~..l 1111I" 1U1". 'lit III _.~t11ll- oj"; *****$,100.00***** N~1i:r~f:~~~:::~\~~b~~~@t~Q;~~ . ··:·:A~~:;r""- ...... ...... \..... .".. é!]~~~;f++{*~~1~:~:){~:;;~~~~;;i~ -- II' 0 5 L, 9 b b II' I: 0 L. ~ 2 0 ~ a 9 51: 0 ~ 2 7 a., b II' ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) "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. HOLE 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). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates 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) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the ·permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST COMPANY . AfJ;¿ WELL NAME¡I;1~ ¡t1/JS:-:?ð;' PROGRAM: Exp _ Dev _ Redrll_ Re-Enter _ Serv 2L- Wellbore seg_ FIELD & POOL S"2-.J'>Ic.¡Ó INIT CLASS 1- OJ..1¡T GEOL AREA 2'9ð UNIT# /1 ~':?.2... ~ ON/OFF SHORE....9..a.? ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . Y\ 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. W ell located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is wellbore 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 12. Permit can be issued without administrative approval.. . . . . Y N ý'" (Service Well Only) 13. Welllocatedwlin area & strata authorized byinjectionorder#Ld..ß. Y N U>l-~Qlt/ z-v1..~Z./~ z.DZ..'l.~Ge ~2... 0°9 (Service Well Only) 14. All wells wlin X mile area of review identified. . . . . . . . .. ~ N /11, s 3IÍ¡ I'1fJS .?3/~ ft1fS ~O/~ rf/.f-.2.) / ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . N 16. Surface casing protects all known USDWs. . . . . . . N 17. CMT vol adequate to circulate on conductor & surf csg. . . . ~- 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . Y ~) 19. CMT will cover all known productive horizons. . . ... . . .. . ~N 20. Casing designs adequate for C, T, B & permafrost. . . . . . . N 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . . N D 11-1()4,- I '-I. 22. If a re-drill, has a 10-403 for abandonment been approved. . . -¥-N- Ai/If: 23. Adequate wellbore separation proposed.. ..... . . . . . . . . IN 24. If diverter required, does It meet regulations. .. . . . . ... . N , / 25. Drilling fluid program schematic & equip list adequate. . . . . N ;11 Pt'Jt- M 11../ ~. 2 P f1 · 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N P' J , ~7: BOPE press rating appropriate; test to . ŠS"OD psig. ~ N fYL Ç. / '155' p! { . 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N \/JGA- '1'1/03 29. Work will occur without operation shutdown. . . . . . . . . . . )~) 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y ~~ I I. It ~ A.... J L 31. Mechanical condition of wells within AOR verified. . . . . . . . ø N Ail ~t~<:. jA,A.,( ~ ~ rt'(..' f, {)f pN . CL.~ [;~ ~~L 'tOyÇ. , J{¡Ud9 , RESERVOIR ENGINEERING APPR DATE I&:- ~'- APPR DATE . (Service Well Only) GEOLOGY APPR DATE ~/- /~~~ '(Éxploratory Only) Rev: 10/15/02 .r ........- ----- l ~ 32. Permit can be issued wlo hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (if off-shore). . . . . .. ...... 36. Contact namelphone for weekly progress reports. ...... ( GEOLOGY: RP<1tc:: PETROLEUM ENGINEERING: UIC ENGINEER COMMISSIONER: Commentsllnstructions: TEM JDH JBR COT t DTS ò¡' 2J/a3 MLB 6Y'L?/~'3 SFD WGA y/' MJW G:\geology\permits\checklist.doc ) ) Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to sim.plify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ì) Sperry-Sun Dring Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Jun 12 09:42:45 2003 ) d-ó~ ~d~1 II ~33 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/06/12 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date.................... .03/06/12 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPS-20 500292313200 BP Exploration (Alaska) I Inc. Sperry-Sun Drilling Services 12-JUN-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002277345 B. ZIEMKE D. FERGUSON MWD RUN 2 MW0002277345 T. MCGUIRE C. DIXON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 12 12N 10E 3304 209 MSL 0) 72.40 38.40 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 20.000 112.0 8.500 9.625 2987.0 # REMARKS: ) .) 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS v~dERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) , UTILIZING GEIGER-MUELLER TUBE DETECTORS. 4. MWD RUN 2 COMPRISED DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. SCHNORR, BP ALASKA, INC., DATED 6/10/03. MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1 AND 2 REPRESENT WELL MPS-20 WITH API#: 50-029-23132-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7190'MD/4344'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP RESISTIVITY) . SLIDE = NON-ROTATED INTERVALS, REFLECTING BIT DEPTHS $ File Header Service name............ .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/12 Maximum Physical Record. .65535 File Type.. . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP RPD RPM RPS RPX FET $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 42.0 113.0 2970.5 2970.5 2970.5 2970.5 2970.5 STOP DEPTH 7158.5 7189.5 7151.0 7151.0 7151.0 7151.0 7151.0 # .. . BASELINE CURVE FOR SHIFTS: ) ) CURVE SHIFT DATA (MEASURED DEPTH) , --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ BIT RUN NO 1 2 MERGE TOP 42.0 3000.0 MERGE BASE 3000.0 7189.5 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 42 7189.5 3615.75 14296 42 7189.5 ROP MWD FT/H 2.64 2619.91 435.697 14154 113 7189.5 GR MWD API 6.95 135.05 68.4534 14234 42 7158.5 RPX MWD OHMM 0.06 309.1 16.8485 8362 2970.5 7151 RPS MWD OHMM 0.39 248.53 16.6858 8362 2970.5 7151 RPM MWD OHMM 1.84 2000 21.8796 8362 2970.5 7151 RPD MWD OHMM 2.04 2000 25.0431 8362 2970.5 7151 FET MWD HOUR 0.03 46.39 0.636968 8362 2970.5 7151 First Reading For Entire File......... .42 Last Reading For Entire File.......... .7189.5 File Trailer Service name............ .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/12 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...... .03/06/12 Maximum Physical Record. .65535 F i 1 e Typ e. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 ) header data for each bit run in separate files. 1 .5000 START DEPTH 42.0 113.0 STOP DEPTH 2928.5 3000.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # 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: 11-FEB-03 Insite 66.37 Memory 3000.0 112.0 3000.0 .5 66.1 TOOL NUMBER 83562 12.250 112.0 LSND 9.20 170.0 8.5 200 7.6 .000 .000 .000 .000 .0 71.6 .0 .0 $ ') ) # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWDOI0 GR MWDOI0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 42 3000 1521 5917 42 3000 ROP MWDOI0 FT/H 2.64 944.66 187.301 5775 113 3000 GR MWDOI0 API 13.4 135.05 66.7725 5774 42 2928.5 First Reading For Entire File......... .42 Last Reading For Entire File.......... .3000 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/12 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...... .03/06/12 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS 3 header data for each bit run in separate files. 2 .5000 START DEPTH 2929.0 2970.5 2970.5 2970.5 STOP DEPTH 7158.5 7151.0 7151.0 7151.0 RPX FET ROP $ 2970. 2970.5 3000.5 ') 7151.0 7151.0 7189.5 # 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 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value.. . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 14-FEB-03 Insite 66.37 Memory 7190.0 3000.0 7190.0 41.0 70.1 TOOL NUMBER 136692 145654 8.500 2987.0 LSND 9.00 43.0 8.0 200 8.2 2.700 1.620 5.900 3.900 65.0 113.0 68.0 68.0 Name Service Order DEPT ROP MWD020 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 GR MWD020 API ') 1 68 8 3 ) RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2929 7189.5 5059.25 8522 2929 7189.5 ROP MWD020 FT/H 11.53 2619.91 606.897 8379 3000.5 7189.5 GR MWD020 API 6.95 131.83 69.6005 8460 2929 7158.5 RPX MWD020 OHMM 0.06 309.1 16.8485 8362 2970.5 7151 RPS MWD020 OHMM 0.39 248.53 16.6858 8362 2970.5 7151 RPM MWD020 OHMM 1.84 2000 21.8796 8362 2970.5 7151 RPD MWD020 OHMM 2.04 2000 25.0431 8362 2970.5 7151 FET MWD020 HOUR 0.03 46.39 0.636968 8362 2970.5 7151 First Reading For Entire File......... .2929 Last Reading For Entire File.......... .7189.5 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/12 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.004 Physical EOF Tape Trailer Service name..... . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/06/12 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 Date. . .. .. .. . . . . . . . . . . . . .03/06/12 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File