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Home My WebLink About194-116 Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 06/01/2023 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 6/1/2023. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through 6/1/2023. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. 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 have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Supervisor Hilcorp North Slope, LLC Hilcorp North Slope LLC.Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor Top-offReport of Sundry Operations (10-404)06/01/2023Well NamePTD #API #Initial top of cement (ft)Vol. of cement pumped (gal)Final top of cement (ft)Cement top off date Corrosion inhibitor (gal)Corrosion inhibitor/ sealant dateL-2072210815002923702003.371.31/23/2023123/1/2023L-2312230105002923746003.003.0-393/27/2023M-111810575002920589002.602.6-105/29/2023M-311920325002922256001.501.5-165/29/2023M-331941165002922504001.301.3-145/29/2023N-171830095002920898001.201.2-115/30/2023N-18A2081755002920906010.500.5-65/30/2023N-21A1961965002921342011.001.0-85/30/2023N-272071045002923365000.500.5-45/30/2023N-292141105002923521002.302.3-245/30/2023N-31215175500292356000-0--205/30/2023V-2342220045002923707006.3210.91/23/2023243/1/2023W-2412221545002923741002.502.5-263/1/2023Z-121891025002921977000.700.7-45/23/2023Z-34212061500292346900-0--155/27/2023Z-402111735002923462000.700.7-65/27/2023Z-46A2052035002923280010.500.5-35/23/2023Z-502120015002923463000.500.5-35/27/2023Z-662121955002923482000.700.7-85/27/2023Z-116211124500292345500-0--175/27/2023Z-210204181500292322600-0--125/27/2023Z-2292221045002923726003.8361.23/5/2023363/27/20231.301.3-5/29/2023M-3319411650029225040014 • • Wallace, Chris D (DOA) From: Regg,James B (DOA) Sent: Friday, October 13, 2017 9:50 AM To: Wallace, Chris D (DOA) Subject: FW:OPERABLE: Producer M-33 (PTD#1941160) OA Over NOL Jim Regg Supervisor, Inspections AOGCC SCANNED rr,L2 . ." `'fi 333 W.70 Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or iim.regg@alaska.gov. From:AK, GWO Well Integrity Engineer[mailto:AKGWOWellSiteEnginee@bp.com] Sent:Thursday, October 12, 2017 4:29 PM To: Regg,James B (DOA)<jim.regg@alaska.gov> Cc:AK, GWO SUPT Well Integrity<AKDCWelllntegrityCoordinator@bp.com> Subject:OPERABLE: Producer M-33 (PTD#1941160)OA Over NOL Jim, Artificial lift producer M-33 (PTD# 1941160)was reported to have sustained outer annulus casing pressure over NOL on 10/10/17. The pressures were confirmed to be T/I/0=360/1425/1800. The well was shut in recently for plant maintenance. The OA pressure spike on 10/10/17 is related to thermal effects of a temperature swing of placing the well on production(-20 degree F to 156 Degree F) with a fluid packed annuli and not to a change in the wells mechanical condition. The well has no known integrity related issues. This well is still OPERABLE, subject to maintaining NOL's. Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering Office 907-659-8110 Cell 907-980-0552 Harmony 4530 1 STATE OF ALASKA OLASKA OIL AND GAS CONSERVATION COMMIS • REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate ® Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 194-116 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22504-00-00 7. Property Designation(Lease Number): ADL 0028282 8. Well Name and Number: PBU M-33 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 9995 feet Plugs measured feet true vertical 9237 feet Junk measured feet .TIN 2 7 2017 Effective Depth: measured 9900 feet Packer measured 9158 feet true vertical 9143 feet Packer true vertical 8411 feet AO GCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 28-108 28-108 1490 470 Surface 3146 10-3/4"45.5#NT-8 28-3174 28-3062 4560 1730 Intermediate Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner Perforation Depth: Measured depth: 9316-9344 feet feet 9434-9458 feet 9458-9459 feet 9459-9479 feet True vertical depth: 8566-8594 feet feet 8682-8706 feet 8706-8707 feet 8707-8727 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 24-9222 24-8474 Packers and SSSV(type,measured and 4-1/2"Baker SABL-3 Packer 9158 8411 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED JUL 2 12017, Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 335 9085 3252 1635 255 Subsequent to operation: 392 12345 3397 1502 278 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development m Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil B Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 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: N/A Authorized Name: Shriver,Tyson Contact Name: Shriver,Tyson Authorized Title: Well Intervention Engineer r Contact Email: Tyson.Shriver@bp.com 7 Authorized Signature: ,dh Date:(,/?/ /7 Contact Phone: +1 9075644133 Form 10-404 Revised 04/2017 1/17-1-- rl �/ 7 f j7-,41(7 ,/7 7---�J�///7 RB D'RS I JUN 2 8 2017 Submit Original Only • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RECEIVED JUN 272017 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary ,ACC June 22, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Adding of Perforations for Well M-33, PTD # 194-116. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • • Q o 0 0 0 0 0 C") N 6) N O N- c- N LC) O r- Ln V L) t` U y 0 0 0 0 0 0 i O) C9 co 0) co C) • LU c- CO m co Co co co co N CO CO CO O 0 CA d N C") CO 0) Cr) CO I I I I I I- 00 00 CO CO CO 0) V N N N N CO CA 4.0CD C CbC`7 O CO N O x- C) CA O (NI co co O) O a) • 0 CU i Q M r— CO CO CO CY) O d- C 07 N N N a) a) N = G • CO a c) cocp co Lc) co co , 0-) L H F 0 H 0 = Z Z co Z Cl) N_ N N N U O m aO Ln L 9 O M CO 0) • 00 — 0 O CO c- o co co O 0) -J Z Z Z ,0 000 C H 'y 00000 U• D u_ D D D Z Z ctO O O m 00) dddH . 0 • / _1 . 3 0 Eo 7 in 0) 7 - 1 1 II < \ F- / H a � \ � \ O E 0 a- < 2 � / < / / 2 t 2 u \ .1< \ 0 7 C I-< co H G CD / I— \ / $ a 11 - < 1 I m < 1 i II / \ LL • ® / ® / ƒ CO I + a / / . / / » o > r W � $ � / � < Q E cU < < / \ E < 0 -1 0 , 2 E e L I g E O R < R % 2 z % O / / / � \ • k � / � � / ._ gel(7 < I- / / / E / E / \ / ƒ ¥ a < 2 Z H- E \ E / / O / O / R 2 ¥ g # -I (-0 -Ir 0. :,=• / t / / : ƒ \ / -) (3) \ < up m2_ _\ i \ O < / E f < / / / _CDLi G ƒ ..„(/) / i $ \ � - \ a cc < ± > \ 5 O 2 < c 0 2 < m < L = CU / O w & / 5 a \ / / w ƒ \ ix : < / / \ ® � Z \ / / ƒ I / ZI / 2 / _ / / / -1Ez OH » \ \ OGZeC)- T0z » H \ � / Rk / O ± _ / / ƒ - f » < 7 < g ' O -IW Et & Et (9O W- OO •NIIWW< � ? � ? 9 / � - 5 / 2 / / < \ / * - 5 g ƒ I ƒ \ / / a) : c : : 7- : : k c » & E E c < t \ L < N- N. w >- - / m 5 \ \ N Ca 0 a 3 a < 4111 TREE= 41116"CNV SA NOTES: CHROME CSGS TBG*** V�ELLFEAD= 10-3/4"-5MFMC I111-33 r ACTUATOR= S H CAMERON O B.ELEV= 54.8' BF.ELEV= 25.6' KOP= 1763' 2075' -4-1/2'SSSV OTIS LAND MP,D=3.813" Max Angle= 31"@ 5987' I Q Datum MD= 9609' Datum TVD= 8800 SS GAS LFT MANDRELS IL ST MD TVD DEV TYPE VLV LATCH PORT DATE 10-3/4'CSG,45.5#,NT-80,D=9.953" —{ 3176' 5 3078 2978 29 KBMG-M DOME BK 16 01/10/15 4 5614 5190 31 KBMG M DOME BK 16 01/10/15 3 7629 6969 25 KBMG-M DMY BK 0 08/02/09 Minimum ID = 2.31" 91 sit' 2 8324 7605 21 KBMG-M DMY BK 0 08/02/09 OTIS X NIP INSIDE STRDL PATCH 1 9014 8269 11 KBMGM DMY BK 0 08/02/09 9080' —14-1/2"OTIS X NP,D=3.813" g e (9115'-9172 H4-1/2"BKR STRDL PATCH, D=2.31"(01/09/15) Jr 9140' 1—7-5/8"X 6-1/2'BKR PSR,D=3.875" 9162n—17-5/8"X 4-1/2"BKR SABL-3 PKR,ID=3.88" I i1 9166' —OTIS X NP,D=2.313(01/09/15) ' 9196' —14-1/2"OTIS X NP,D=3.813" • 9213' --{4-1/2"OTIS XN NP,D=3.725" 9213' —{2-7/8"NP REDUCER,D=2.313'(12/04/09) 4-1/2'TBG, 12.6#,13CR-80 NSCT, — 9225' / .0152 bpf,ID=3.958" 9226' —14-1/2 WLEG,D=4.00" 9219' --I EIMD TT LOGGED 12/29/94 PERFORATION SUMMARY REF LOG:ATLAS BHCS ON 10/13/94 ANGLE AT TOP PERF: 10"@ 9316' Note:Refer to Production DB for historical perf data SIZE SPF t T IAL Opn/Sqz SHOT SQZ 3-3/8'r 6 9316-9344 0 05/22/17 3-3/8"r 6 9434-9458 0 90/21/96 3-3/8"r 6 9459-9479 0 01/17/95 PBTD —I 9900' 14.4.4414. 7-5/8"CSG,29.7#,13CR-80, 9986' %N11111111 61.1.1.1.v 1.1.1,1.1.1 .0459 bpf,D=6.875" DATE REV BY COMMENTS DATE REV BY COMMENTS PRJDHOE BAY UNIT 10/22/94 ORIGINAL COMPLETION 07/07/16 JG/JMD SET PX PLUG w/PRONG(07/03/16) VVB-L: M-33 03/19/10 JLW/SV CSG CORRECTION 07/12/16 JG/JMD PULL®PX PLUG/TREE C/O PNMT No:'1941160 10/07/14 R1K/JMD SET XX RUG/GLV GO(09/25/14) 05/23/17 BTNJMD ADPERFS(05/22/17) API No: 50-029-22504-00 01/20/15 JMFXJMD PATCH 8 GLV GO(01/09-10/15) SEC 6,T11 N,R13E, 1864'FTL&195'FWL 01/20/15 JMANJMD RILL RUG(1/12/15) 03/08/15 PJC PATCH CORRECTION/REFORMAT BP Exploration(Alaska) • STATE OF ALASKA A.. KA OIL AND GAS CONSERVATION COMM. ,ON REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon❑ Repair Well El Plug Perforations ❑ Perforate Other /t/I- q p?dG/� Performed Alter Casing❑ Pull Tubing ❑ Stimulate-Frac El Waiver❑ Time Extension❑ J Change Approved Program❑ Operat Shutdown❑ Stimulate-Other ❑ Re-enter Suspended W❑ 2 Operator 4 Well Class Before Work: 5 Permit to Drill Number BP Exploration(Alaska),Inc Name Development CI Exploratory 194-116-0 3 Address P O Box 196612 Stratigraphic ❑ Service 6.API Number Anchorage,AK 99519-6612 50-029-22504-00-00 7 Property Designation(Lease Number) 8 Well Name and Number ADL0028282 PBU M-33 9 Logs(List logs and submit electronic and printed data per 20AAC25 071) 10 Field/Pool(s) PRUDHOE BAY,PROD e'E I V E D 11 Present Well Condition Summary Ft1 Total Depth measured 9995 feet Plugs measured None feet JAN 3 0 2015 true vertical 9237 12 feet Junk measured None feet AOGCC Effective Depth measured 9900 feet Packer measured 9160 18 feet true vertical 9142 95 feet true vertical 8412 72 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"91 5#H-40 30 21-110 21 30 21 -110 21 1490 470 Surface None None None None None None Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner None None None None None None Perforation depth Measured depth 9434-9458 feet 9458-9459 feet 9459-9479 feet True Vertical depth 8682.35-8706 01 feet 8706.01 -8707 feet 8707-8726.72 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) 4-1/2"Baker SABL-3 Packer 9160.18 8412 72 Packer None None None SSSV 12.Stimulation or cement squeeze summary 1 Intervals treated(measured). 0 ZJ1� VV Treatment descriptions including volumes used and final pressure JC�NN�,y v1-16 2 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation. 341 6078 3338 760 199 Subsequent to operation: 633 25480 4220 460 397 14 Attachments 15.Well Class after work Copies of Logs and Surveys Run Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16 Well Status after work Oil 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C.O Exempt ' N/A Contact Garry Catron Email Garry.Catron(�BP.Com Pnnted Name Garry Catron Title PDC PE Signature jialtAAT Lam— Phone 564-4424 Date L 1/30/2015 i/7-/-i/7-/- z i/ 4. / i RBDMS,dJAM 3 0 2015 Form 10-404 Revised 10/2012 WC Submit Original Only Y m =0• 000000 co co 0 NJ- 8 ) O 00 O) 00 M M 3 LC) r 00 m r co 00 CO 00 00 00 N N M▪ O CO r- N O) N O) N co co co co co) 00 co N U) 0 R 141 co N O M O I- N- co v- U) co M C N CO N CO 4.+ N CO N 00 NI- O N- M o 00 M N O) O N 0) co O) O) O) O) i i i i I I i CU c4 V 00 O '- N.. M O L) M_ Q NCe) 0) N00000) Nso) 0)co C O s El O 7 co o 9 arncrnco H 00 7 ~ 0 ~ M Cr) _ 0 Z Z 2 Ni O VD (D •� N • N_ U - N N m i i N 4 c)O un - u) d 000 O cp 00 O 00 J Z Z Z c0 000 c H H H H H 0 000 0 0 0 0 0 0 Z Z 0 < a o cD ° m U 0- a d 11 H • Q .c O Q a) o -§ 60E8 L• c 1.1 _1115 , (0 =O N �C > C N Q (� a) O E . 0. _ N p N O O O - C Z O N II -p ( .-.b C ' S? 7,- c N 3 i °o O o vires < 4--,O c EN- a) a M C > (3 04= E4, 00 < a) -p O 06- > .--. 2u � O C > E � p) O p a ° L (0 OL N • o o C * (13 a) w O > O Q)+-' a 2 c J D N O 4) 6) C M o o �o m -0 o .CO cn < c N o Q C E o a) 0 CD a)x plo N- C * -0o C Co � C - C- c rn N- � °� JQ • 4- E C .- o E 6i Q � � � O � JZ E W Q 6i - U co Z .a QN cLn a) rn� <co fri U no �� Q C >, o .Wo C (6 -0a) 'CU) Z � To p � * a) °) * •cn (n * (7.) (NI O 0„ ... . .07, „„) 03 cn W W m N W m c) W W co 11 O V' O 6) J Q a O o W U) U) O U) . Y U) J O O I I a) a. —LL 70 > I > o ' o 6) CO Q o > > > Q AWN � 0 = Q CQoda) O o> aa)) C� �C- U � Ln �ZIn cV O J N o Q O E O 2 x ° Z = C Q A- C �\ C = W = N o C� < a) Ci. C@ (Lo cm t D � � C9U : ° W � -3W -- -3 = -- -51— w � cV W o O OW wml- O > p `n 5 p ami C O in OIL V) E c 0 Z Qm Z QQ- Z m m w Z c = N II ~ > J w m II ° • H O O . Q< O *- O *W O *W W O • J . NN0 C00 .1- 2.2 :9, A u _ � Oa v oo c�i � DW � DLYDWmmD U) (/) a) pO C U) ao O oZU) V Z (/) mZU) z < Z Qa I I Q I I ��O m (n •- LO O C O Q 1I <- (t- -° Q o_ 1 J 1 J O Q � d C > C V M .U7 U) O J Q • C o O> O . * c\') Z J Z J Z ,0 O W Z � aEi a00 aE) cn � � o � Q c0 aEi ) E inC , J > OU �- WOU - n- UO -. ›+ ~ ° > ~ J oN- O0On > H 2 > � � C0a) > U) � OU) - OU) � W U) p 6 22 oaD o E �'� o � � � 2o � gm W � w (nw2 (nwcn � w �- • rn O W Q O O r O CD �c20U o a�"i 0 < Q) o rn n 7.:.-1 -.. Q u N C > Q Z W Li Li � 2 Li U Z (9 0 d' .g. > CO < — _0 (7, > .4. O > � in — m W W W W W > .c (n > (U . .0 O ac) ° U) > _ . (1) > "_ °o m z i_ p_ i_ m z = o m U 0U) U) C@E a a CU � 7 � U) U U a - J . ZH � ZHZH Wco _ II a) > 11 a) Jc-- m o EJ > II J II ~ ( C W . mZ W mz 'W mzu_ ~ m > - N Q L (n •in ° Q > O Q > O d cm io * Q O O Q O O Q O O Q J O I .CU) HZOit m 0_ EOU) HO oc) � W Wim * I- * * 2 * * 2 * * -, W * v 7t v ,n U) in U) N 0 N N N O O O O N N N N :, \ co 6) co l\ co ;', OO 6 N • O a) c (nO � � d N N O Q c F._ > -0 a) 2 I .a) p C o > O Q3 n o a CoE _ x o 0 co o Q cs) G (13 n cu 0 in O Ln O V D '-- v a) Ln D O IIin W - o a) 0N o a) � IT) 0 C * C (n — D D 0 F- o cn C a) O a3 N * 'a3 _ co 2 g F- _Q F- Q ca ° co C- O u) (6 a0 J Q C �a' � cm C > n (NIID croro20 a ND - `Y) EJ L' J > o CI � �� 2 a) 0 0 LL 2inco � a) � � L (n p N C1 �- 0 C O '- r-- O `t Li � Oin � G�▪ OA - Vao •L � Q Ov UN _1_i0 2 m x � - U _J U FCO- -P-, 3Q cN = -- Qa; � u) u) 2z ,n � O II � � c) NC CL ° 0 oU _1 aQooao _1D � 2u) 0 0 o CD- V) CI r) D c CD LO J _ Ln EaZ o0 J *• mD * wO CK DD �cnC °oY (n (nao0 HON- 1) * Coai y 2 § •± C G j / � 2 O % 2 0. 2 7 R CD a k \ \ v R ® v.- o < O CU CO / / / o < a- ¢ 0 ¢ / o < R 6 J / CI- L \ k ± LEr E • / / \ — 0_ & x < 2 7 2 r \ ± -O 1.11ƒ % ? - (9 # o L / / /CO\ \ / 0 ® Z D U)Q 3 x \ ® f < a) 2bxf 0co I / ) D* } E R o < CC I@ r / TREE= 4-1/16"CTW S. Y NOTES: 13-CR TUBING AND LINER. yV.LI-EAD= 10-3/4"-5M FMC M 33 CHROME CSG AND TBG ACTUATOR= BAKER OKB.B_EV= 54.8 F.B_EV= 25.6' •KOP= 1763' 2075' H4-1/2"SSSV OTIS LAND NIP,D=3.813" Max Angle= 31°@ 5987• O Datum MD= 9609' Datum1VD= 8800'SS GAS LFT MANDRELS L 10-3/4"CSG,45.5#,NT-80,D=9.953" H 3176' HA ST MD 'VD DEV TY FE VLV LATCH FORT DATE_ 5 3078 2978 29 KBMG-M DOME BK 16 01/10/15 4 5614 5190 31 KBMG-M DOME BK 16 01/10/15 Minimum ID =2.31" 9142' 3 7629 6969 25 KBMG-M DMY BK 0 08/02709 4-1/2" BKR STRADDLE PATCH 2 8324 7605 21 KBMGM DMY BK 0 08/02/09 1 9014 8269 11 KBMGM, DMY BK 0 08/02/09 9080' 4-1/2-OTRS X NP.D=3.813" 4-1/2"BKR STRADDLE PATCH, —�911T-9172 D=2.31"(01/09/15) X X 9140' —BAKER PBR 9162' —17-5/8"X 4-1/2"BAKER SABL-3 R(R,D=3.88" i ; 9196' —14-1/2"OTIS X NP,D=3.813" 9213' H4-1/2'OTIS XN NP.ID=3.725" 9213' J-1_2:-7/8"NP REDUCER,D=2.313"(12/04/09) 4-1/2"TBG,12.6#,13CR80,.0152 bpf,ID=3.958"--j 9225' / 9226' j—{4-1/2 TBG TAL,IA/LEG 9219' _H ELMD TT LOGG®12/29/94 PERFORATION SLL*.IARY REF LOG:ATLAS BI-KS ON 10/13/94 ANGLE AT TOP Imo. 10°@ 9434' Note:Refer to Roduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SOZ 3-3/8"' 6 9434-9458 0 10/21/96 3-3/8"r 6 9459-9479 0 01/17/95 PBTD H 9900• •••••••••• 1.i•i•i•i•i•i•i•i•i J 7-5/8"CSG,29.7#,13CR80,D=6.875"- I 9986' DATE REV BY COMMENTS DATE REV BY COMMENTS FRUDHOE BAY UNIT 10/22/94 ORIGINAL COMPLETION 03/19/10 JLW/SV CSG CORRECTION WELL M-33 10/03/01 RWTP 10/07/14 RJK/JMD SET XX PLUG/GLV GO(09/25/14) PERIvTT No:'1941160 09/28/09 SVVC/SV GLV GO(08/02/09) 01/20/15 JMM'JMD RESET PATCH&GLV C/O(01/09-10/15) API No: 50-029-22504-00 12/15/09 ACB/SV RJLL TTPISET NIP RED(12/04/09)01/20/15 JMIWJMD RLL PLUG(1/12/15) SEC 6,T11 N,R13E 1864'FTI.&195'FW_ 12/15/09 MV/SV SET LWR PATCH 12/19/09 GJF/SV SET UPPER PATCH BP Exploration(Alaska) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 18, 2012 ff oi 4 - l l 6 Mr. Jim Regg f 33 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue S ANNF AUG ) 2012 Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB M -Pad Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad M that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) M -pad Date: 04/14/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal M -01 1690780 50029200420000 Sealed NA NA NA NA NA M -03A 2011470 50029201020100 0.25 NA 0.25 NA 0.85 6/3/2009 M -04 1710230 50029201050000 0 NA 0 NA NA 4/14/2012 M -05A 1970810 50029201940100 0.5 NA 0.5 NA 2.6 6/3/2009 M -06A 1930930 50029203670100 0.25 NA 0.25 NA 0.85 6/3/2009 M -07 1790370 50029203730000 0.25 NA 0.25 NA 0.85 6/3/2009 M -08 1800860 50029204990000 1.75 NA 1.75 NA 10.2 6/24/2009 M -09B 2022200 50029205630200 6.25 NA 6.25 NA 44.2 6/3/2009 M -10 1810290 50029205670000 0.25 NA 0.25 NA 2.6 6/4/2009 M -11 1810570 50029205890000 0.25 NA 0.25 _ NA 1.7 6/4/2009 M -12A 2001510 50029205930100 0.25 NA 0.25 NA 1.7 6/4/2009 M -13A 2011650 50029205220100 2.75 NA 2.75 NA 17 6/4/2009 M -14 1801090 50029205120000 1 NA 1 NA 5.1 6/4/2009 M -15 1810850 50029206120000 6.75 NA 6.75 NA 55.3 6/4/2009 M -16 1810860 50029206130000 0.25 NA 0.25 NA 1.7 6/4/2009 M -17A 2000320 50029206280100 0.5 NA 0.5 NA 2.6 6/3/2009 M -18B 1930540 50029208550200 10 NA 10 NA 73.1 6/24/2009 M -19B 2081980 50029208970200 Sealed NA NA NA NA 4/13/2012 M -20A 1971990 50029209120100 8 NA 8 NA 52.7 6/24/2009 M -21A 1930750 50029209230100 0.5 NA 0.5 NA 3.4 6/24/2009 M -22 1830540 50029209360000 16 NA 16 NA 117.3 6/23/2009 M -23 1830550 50029209370000 0.25 NA 0.25 NA 1.7 6/4/2009 M -24A 2011260 50029209390100 0.25 NA 0.25 NA 0.85 6/24/2009 M -25 1860650 50029215700000 8 NA 8 NA 55.3 6/3/2009 M -26A 1920280 50029220040100 2.75 NA 2.75 NA 18.7 6/3/2009 M -27A 1930860 50029219920100 0.25 NA 0.25 NA 2.6 6/24/2009 M -28 1860740 50029215780000 1 NA 1 NA 4.3 6/3/2009 M -29A 2000990 50029219040100 1 NA 1 NA 4.3 6/3/2009 M -30 1920300 50029222550000 0.5 NA 0.5 NA 3.4 6/3/2009 M -31 1920320 50029222560000 0.5 NA 0.5 NA 3.4 6/4/2009 M -32 1920330 50029222570000 0.25 NA 0.25 NA 0.85 6/4/2009 7 M -33 1941160 50029225040000 20 NA 20 NA 133.45 6/24/2009 M -34 1941330 50029225140000 6.25 NA 6.25 NA 25.5 6/3/2009 M -38A 2011320 50029225190100 21.3 NA 21.3 NA 210.8 11/26/2009 STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS ~'~°'_ 1. Operations Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate^ #))~( A Performed: Alter Casing ^ Pull Tubing^ Pertorate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-e er Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: Permit to Drill Number: Name: Development ^~ Eacploratory 194-1160 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ API Number: Anchorage, AK 99519-6612 50-029-22504-00-00 8. Property Designation (Lease tuber) : Well Name and Number: ADLO-028282 PBU M-33 10. Field/Pool(s): P PRUDHOE BAY FIELD / PRUDHOE OIL OOL 11. Present Well Condition Summary: Total Depth measured` 9995 feet Plugs (measured) None feet true vertical 9237.12 feet Junk (measured) None feet Effective Depth measured 9900 feet Packer (measured) 9162 true vertical 9142.95 feet (true vertical) 8415 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 91.5# H-40 30 - 110 30 - 110 1490 470 Surface 3121 10-3/4" 45.5# NT80LHE SURFACE - 3176 SURFACE - 3064 5210 2480 Intermediate Production 9931 7-5/8" 29.7# NT95/13CI SURFACE - 9986 SURFACE - 9228 Liner Liner Pertoration depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr80 27 - 9225 27 -8477 Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker SABL-3 Packer 9162 8415 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~~ ~r ~~.~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 425 3187 3983 245 Subsequent to operation: 408 2240 4124 204 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ~ Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ 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: N/A Contact Gary Preble Printed Name Gary Pre,{ Title Data Management Engineer Signature Phone 564-4944 Date 1/12/2010 Form 10-404 f~evised 7/2009 RBDMS ~N 1 ~ 2010 ~~ Submit Original ly ~- ~ /9!0 ~~lQla M-33 194-116 DFDF ATTA(_NMFNT Sw Name Operation Date Perf Operation Code - ---- --- Meas Depth Top ------------- Meas Depth Base Tvd Depth Top Tvd Depth Base M-33 12/29/94 PER 9,434. 9,459. 8,682.35 8,707. M-33 1/17/95 APF 9,459. 9,479. 8,707. 8,726.72 M-33 10/21/96 RPF 9,434. 9,458. 8,682.35 8,706.01 M-33 5/10/09 BPS 9,213. 9,479. 8,454.87 8,726.72 M-33 12/4/09 BPP 9,213. 9,479. 8,454.87 8,726.72 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE ~~ • M-33 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 12/3/2009 ***W ELL S/I ON ARRIVAL*** (pre patch) ;PULLED P-PRONG FROM 9.179' SLM ***CONT WSR ON 11-4-09*** _ 12/4/2009 ***CONT WSR FROM 12-3-09*** (pre patch) ~~~~~~~~~ ~ ~~~~~ ~~~~~ ' :PULLED 4-1/2" PXN-PLUG BODY FROM 9,182' SLM (9,213' MD) DRIFTED TO 9,210' SLM W/ 20' x 3.70" DMY WHIPSTOCK (no obstructions) ESET 2-7/8" X-NIP REDUCER IN XN-NIP @ 9,186' SLM (9,213' MD) SET 2.313 XX PLUG IN NIP REDUCER @ 9,186' SLM (9,213' MD) EQUALIZE 2.313 XX PLUG @ 9186' SLM (9213' MD) PULL 2.313" XX PLUG FROM 9186' SLM (9213' MD) ***WELL LEFT S/I, TURN OVER TO PAD OP*** 12/8/2009T/I/0=280/140/210. Temp=S1. T & IA FL's. (for E-Line). ALP @ 210 psi & SI @ IA casing valve. TBG FL @ 564' (9 bbl). IA FL @ 312' (9 bbl). OA FL @ ;Surface. SV & WV =CLOSED. MV &SSV =OPEN. IA & OA = OTG. NOVP. 12/9/2009*** WELL SHUT IN UPON ARRIVAL *** (ELINE: PATCH) INITIAL T/I/0= 450 / 160 / 180 . ;SET BOTTOM PORTION OF A 2-PART BAKER STRADDLE COMPLETION AT X9172' TO PATCH LEAK IN PACKER. FINAL T/I/O = 300 / 160 / 180. 3VALVES ON DEPARTURE: SSV OPEN, SWAB CLOSED. ***JOB COMPLETE*** 12/9/2009T/I/0=220/150/180 Temp=S1 CMIT TxIA 1000 psi. (Mitigate TxIA comm) SB for EL to set plug. MI, start RU. **Cont. on WSR 12-10-09** _ 12/10/2009 **Cont. from WSR 10 09-09** ;220/140/180 Temp=S1 CMIT-TxIA 1000 psi**PASS** (Mitigate TxIA comm) Pumped 3 bbls 60/40 and 15 bbls diesel down TBG to reach test pressure. 1st 15 min T/IA lost 20/20, 2nd 15 min T/IA lost 0/10, for a total T/IA loss of 20/30 in a 30 min test. Bled TxIA press down (-6 bbls). Tags hung on WV,IA. Valve ;positions upon departure:SV,WV=closed;SSV,MV,lA,OA=open, operator notified. FW HP's=220/240/180 ~ s _~ _ ~ _ _ __~ ~ ~___~~ e_ ___ __ _ ___ ___~~~__~ ~~~_ ~___~ 12/12/2009°T/I/O = 200/200/80 MIT IA PASSED to 2500 psi. (Mitigate TxfA Comm) Pumped 8.5 bbls of crude into the IA to reach test pressure. IA lost 80 psi in the 1st 15 min and 20 psi in the 2nd 15 min for a total loss of 100 psi in the 30 min hest. Bled IAP back down. Final WHP's = 220/0/180 Slickline on the well at the time of departure. 12/12/2009'""*W ELL S/I ON ARRIVAL*"" SET UPPER BKR STRADDLE PKR AT 9107' SLM/9,117' MD (MIN ID:2.31, MAX OD: 3.70", OAL:26', 4-1/2" G-F.NECK) LRS MIT-IA TO 2500 PSI **PASS*" (see Irs log) SET 4-1/2" WHIDDON CATCHER SUB ON TOP OF PATCH AT 9107' SLM PULLED STA.#1 BK-DGLV, SET STA.#1 BK-DGLV AT 8993' SLM/9,014' MD PULLED STA.#4 BK-DGLV FROM 5,590' SLM/5,614'MD PULLED STA.#5 BK-DGLV FROM 3,059' SLM/3,078'MD SET STA.#5 BK-LGLV (1500 TR0,16/64") AT 3,059' SLM/3,078'MD ""*CONT WSR ON 12-13-09"** 12/13/2009:***CONT WSR FROM 12-12-09*** `SET BK-S/O GLV IN STA.#4 AT 5,590' SLM/ 5614'MD PULLED 4-1/2" WHIDDON C-SUB FROM 9,102' SLM (empty) EQUILIZED 2-7/8" XX-PLUG AT 9,156' SLM PULLED 2-7/8" XX-PLUG FROM 9,156' SLM ""*LEFT WELL S/I, NOTIFY PAD OP ON DEPARTURE*"* FLUIDS PUMPED BBLS 30 DIESEL 5 60/40 METH 33 Total TREE = 4-1116" CfJV WELLHEAD'- 10-314" - 5M FMC 'ACTUATOR= BAKER KB. EV = 55.6' ', BF. ELEV = 25.6' KOP = 1763" Max Angle = 31 @ 598T Datum MD = 9609' Datum TV D = $$QO' SS 10-3/4" CSC, 45.5#, NT-80, ID = 9.953" 3176' Minimum iD = 2.31" @ 9142' 4-1/2" BKR STRADDLE PATCH 4-112" BKR STRADDLE PATCH, 9117'- 91 ID = 2.31" (12/12109) SAFELY ES: 13-CR TUBING AND LINER. M -3 3 CHROME SG AND TBG 2075' 4-1/2" SSSV OTIS LAND NIP, ID = 3.813" GAS LIFT MA NDRFI_S ST MD ND DEV TYPE VLV LATCH PORT DATE 5 3078 2978 29 KBMG-M DOME BK 16 12/13!09 4 5614 5190 31 KBMG-M SO BK 20 12!13109 3 7629 6969 25 KBMG-M DMY BK 0 08/02/09 2 8324 7605 21 KBMG-M DMY BK 0 08/02/09 1 9014 8269 11 KBMG-M DMY BK 0 08(02/09 9080' -~ 4-1/2" OTIS X NIP, ID = 3.813" 9140' BAKER PBR , 9j 162' I--j 7-5/8" X 4-1/2" BAKER SABL-3 PKR, ID = 3.88" 4-1/2" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" ~--~ 9225' 9196' --~ 4-112" OTIS X NIP, ID = 3.813" 9213" 4-112" OTIS XN NIP, ID = 3.725" 9213' 2-7/8" NIP REDUCER, ID = 2.313" (12/04!09} 9225' 4-1i2 TBG TAIL, WLEG 9219' ELMD TT LOGGED 12/29/94 PERFORATION SUMMARY REF LOG: ATLAS BRCS ON 10/13/94 ANGLE AT TOP PERF: 10 @ 9434' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 3-3/8" 6 9434 - 9458 O 10121(96 3-3/8" 6 9459 - 9479 O 01117195 PBTD 9900' 7-518" CSC, 29.7#, 13-C R, ID = 6.875" 9986' DATE REV BY COMMENTS DATE REV 8Y COMMENTS 10/22/94 ORIGINAL COMPLETION 10/03!01 RN/TP 09!28/09 SWCiSV GLV C/O (08/02/09} 12/15/09 ACB/SV PULL TTP/SET NIP RED (12/04/09) 12/15/09 MV/SV SET LWR PATCH 12/19!09 GJF/SV SEf UPPER PATCH PRUDHOE BAY UNfI' WELL: M-33 PERMIT No: 1941160 API No: 50-029-22504-00 SEC 6, T11 N, R13E, 1864' SNL & 195' EWL BP Exploration (Alaska) • ~ , ~~~`~ ~~v PROAcrive DinyNVSric SEavicES, Inc_ V /fGLL L~C7 T'R~4/1/~~/1/T7",4L To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hale/Open Hole/Mechanical Logs and/orTubing Inspection(Caliper/ MTT) The technica! data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : BP Exploration (Alaskaj, Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Be~son Blvd. Anchorage, Alaska 99508 and , ~ `~ ~~k ..~~; ~ ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West international Airport Road Suite C Anchorage, AK 99518 Fax: (907~ 245-8952 1] Leak Detection - WLO 23-Aug-09 M-33 2) Signed Print Name: ~Qj~-~<~ t ~Co~~o BL / ED~ 50-029-2250400 Date : . PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. (NTERNATIONAI AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907~245-8951 Fax: (907~245-88952 E-MAIL : '" ~ , _ ~ ~,:'.i ~ '.~ WEBSITE v _..... _ ~''? C'\Documents and SettingslOwnet\Desktop'~Transmit_BP.douc From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~~Q ~I ~~d~ Sent: Monday, May 11, 2009 9:17 AM ~ To: Regg, James B(DOA); Maunder, Thomas E(DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Weiipad Lead; GPB, Well Pad MN; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, Prod Controllers; Brown, Don L. Cc: Holt, Ryan P(ASRC); Quy, Tiffany; Brown, Don L.; NSU, ADW Well Integrity Engineer Subject: NOT OPERABLE: M-33 (PTD #1941160) TxIA Communication ~-}~-.,~vCS ' ~-t7.~ All, Well M-33 (PTD #1941160) has been confirmed to have TxIA communication. The gas lift valves were changed out and the weil failed a TIFL on 05/07/09. On 05/10/09 a downhole piug was set in the well and the well passed an CMIT-Tx1A to 3000 psi. The well has been reclassified as Not Operabie and will remain shut in until casing and tubing integrity can be restored. Please contact me wifh any questions. Thank you, Taylor Weliman filling in for Anna Dube/Andrea Hughes Office: 659-5102 Pager: 659-5100 x 1154 •~ 1~..i:`~~ ~ ,. .= , ~ ~~ _ ._ ~~~i~~ From: NSU, ADW Well Integrity Engineer Sent: Tuesday, April 28, 2009 5:25 PM To: 'Regg, James B(DOA)'; 'Maunder, Thomas E(DOA)'; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Welipad Lead; GPB, Well Pad MN; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, Prod Controllers; Brown, Don L Cc: NSU, ADW Well Integrity Engineer; Roschinger, Torin T.; Quy, Tiffany Subject: UNDER EVALUATION: M-33 (PTD #1941160) TxIA Communication All, Well M-33 (PTD #1941160) has been found to have sustained casinq pressure on the IA. The TIOs were 2340/2330/180 psi on 04/16/09. However, a TIFL was not performed until today due to the GC turnaround and tank issues. The TIFL did fail when the IA inflowed 5530 ft durin the bleed. The well has been reclassified as Under Evaluation and has been placed on a 28-day clock with a start date of 04/16/09. The plan forward for the well is as follows: 1. D: TIFL - FAILED 2. S: Change out OGLV 3. D: Re-TIFL A wellbore schematic and TIO plot have been included for reference. Please call with any questions or concerns. Thank you, 8/6/2009 NOT OPERABLE: M-33 (PTD~941160) TxIA Communication • Page 2 of 2 Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 8/6/2009 PBU M-33 PTD 194ll60 4/28/2009 TIO Plot d,000 3,000 2,000 i ,oor # Tbg -~- IA ~ OA OOA ~-- OOOA ~ On . ~ • 01/31J09 U2/07109 02/14/09 02/21/09 02/28109 03J07/09 03J14109 03/21I09 03128/09 04/04109 04/11/09 04/15/09 04/25/03 TREE= 4-1/16" CNV I WELLHEP.D = 10-3/4" - 5M FMC ACTUATOR = BAKER KB ELEV = 55.6' BF. ELEV = 25.6' KOP = 1763' Max Angle = 31 @ 5987' Datum MD = 9809' ' Datum N D=~4 8800' SS 10-3/4" CSG, 45.5#, NT-8Q, 1~ = 9.953" . SA TES: 13-CR TUBING AND LINER. M~3 3 CHROME CSG AND TBG 2075~ 4-1/2" SSSV OTIS ~AND NIP, ID = 3.813" GAS LIFf MANDRELS Minimum ID = 3.725" @ 9213' 4-1/2" OTIS XN NIPPLE ~ 4-1/2" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" ~-i J225' PERFORRTION SUMMARY REF LOG: ATLAS BHCS ON 10/13/94 ANGLE AT TOP PEFF: 10 @ 9434' Note: Refer to Production DB for historical perf data SlZE SPF INTERVAL Opn/Sqz DATE 3-3l8" 6 9434 - 9458 O 10/21/96 3-3/8" 6 9459 - 9479 O 01/17/95 PBTD -j 990U~ 7-5l8" CSG, 29.7#, 13-CR, ID = 6.875° 9986' ST MD TV D DEV l"Y PE V LV LATCH PORT ~ATE 5 3078 2978 29 KBMG-M DOME BK 16 12104/08 4 5614 519Q 31 KBMG-M DOME BK 16 12/04/08 3 7629 6969 25 KBMG-M dOME BK 16 12l04/08 2 8324 7605 21 KBMG-M DdME BK 16 12l04/08 1 9014 8269 11 KBMG-M SO BK 24 12/04I08 90$0~ 4-1l2" OTIS X NIP, ID = 3.813" 9140~ ~ BAKERPBR~ 9162' --~7-5(8" X 4-112" BAKER SABL-3 PKR, ID = 3.8$" ~ 9196~ 4-112" OTIS X NIP, ID = 3.813" 9213~ 4-1/2" OTIS XN NIP, ID = 3.725" 9225~ 4-1/2 TBG TAIL, WLEG 9219~ -~ELMD TI" LOGGED 12(29/94 DATE REV BY COMMEMfS DATE REV BY COMMENTS 10/22/94 ORIGINAL COMPLEfION 02/27/01 SIS-Is( COMJERTEB TO CAM/AS 03/16/01 SIS-CS FINAL 10/03/01 R~UTP 12112/08 MBM/SV GLV C/O (12/04/08) PRUDHQE BAY UNfI" WF1L: M-33 PERMIT No: ~1941160 API No: 50-d29-22504-00 SEC 6, T11 N, R13E, 1864' SNL & 195' EWL BP F~cploration {Alaska} M-33 (PTD #1941160) Classified as Problem Well . All, Well M-33 (PTD #1941160) has been found to have sustained casing pressure on the IA. The TIO pressures were 2240/2180/220 psi on 04/27/07. A subsequent TIFL failed on 04/29/07. The plan forward for this well is as follows: 1. D: TIFL - FAILED 2. S: Set DGL Vs 3. F: MITIA A wellbore schematic has been included for reference. «M-33.pdf» The well has been classified as a Problem well. Please call if you have any questions. Thank you, Andrea Hughes sr:.AftNED MAY 0; 7 2007 Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 Content-Description: M-33.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 5/1/2007 10:57 AM TREE = 4-1/16" CNV WB..LI-EAD = 10-3/4" - 5M FMC A C1UA TOR = BA KER KB. ELBI = 556' BF. ELBI = 25.6' KOP= 1763' Max Angle = 31 @ 5987' Datum MD = 9609' Datum TVD = 8600' SS 10-3/4" CSG, 45.5#, NT-80, ID = 9.953" Minimum ID = 3.725" @ 92 4-1/2" OTIS XN NIPPLE I 4-1/2" TBG, 12.6#, 13-CR, .0152 bpf, Ð = 3.958" PERFORA llON SLMMð.RY REF LOG: ATLAS SHCS ON 10/13/ ANGLEATTOPPERF: 10@9434 Note: Refer b A'oduction œ for historical SIZE SPF INTERVAL Opn/Sqz 3-318" 6 9434 - 9458 0 3-318" 6 9459 - 94 79 0 I PBTD I 7-5/8" CSG, 29.7#, 13-CR, ID = 6.875" DUE 1 0/22~4 02/27'{) 1 03/16'{) 1 1 0,{)3,{) 1 RBI BY COM\llENTS ORlGINA L COMPLETON CONV ERTED 1D CA t-N AS FINAL 8IS-lsl SIS-CS RNITP . . M-33 SAFETY NOTES: 13-CR TUBING Alii) UNER. CHROME CSGANDTBG 2075' H 4-1/Z' SSSV OTIS LAND NIP, ID = 3.813" I . GAS LIFT Mð.NDRELS I 3176' "}--J ~ ST lit{) TVD lEV TYÆ VLV LATCH roRT DATE 5 3078 2923 30 KBMG-M BK ~ 4 5614 5135 31 KBMG-M BK 3 7629 6914 25 KBMG-M BK 2 8324 7550 22 KBMG-M BK 1 9014 8214 12 KBMG-M BK 13' I . 9080' H 4-lIZ' OTIS X IIIP, ID = 3.813" I l ~ 9140' H BAKER PBR I 8: ~ 9162' 1-17-518" X4-1/Z' BAKER SABL-3 PKR, ID= 3.88" I . 9196' H 4-lIZ' OTIS X IIIP, ID - 3.813" I . . 9213' H 4-1/Z' OTIS XN NIp, ID = 3.725' I I 9225' - --1 9225' H 4-1/2 TOO TAIL, VlA..EG I I 9219' H B..1It{) TT LOGGED 12/29/94 I 94 perf data DUE 10/21/96 01/17/95 9900' I 9986' ~8 DA1E PRLÐHOE BAY UNIT \llÆLL: M-33 PERMrr No: 1941160 AA No: 50-029-22504-00 SEC6, T11N, R13E, 1864' SNL & 195' BNL REV BY COMMENTS BP Exploration (Alas ka) 01'4 OR BEFORE C,.LO~mM.~°c GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10570 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) 11/13/96 Well Job # Log Description Date BL RF Sepia LIS Tape B-23 ~ -~ ~.~ ,~"~ 96326 CNTD 961029 1 1 1 A-34A LEAK DETECTION LOG 961025 1 1 D-18 LEAK DETECTION LOG 961027 1 1 M-12 INJECTION PROFILE 96101 7 I 1 M-18B INJECTION PROFILE 961020 1 1 M-18B PUMP IN TEMP LOG 961 020 1 1 M- 33 PERFORATING RECORD 961 021 I 1 M-19A PACK OFF GAS LIFT MANDREL 961021 I 1 N-08 INJECTION PROFILE 961021 1 1 N-19 PRODUCTION PROFILE W/DEFT 961023 1 1 P-08 GAS LIFT SURVEY 961022 1 1 S- 15 INJECTION PROFILE 961030 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 p m R H 17 .;.. o,~i:cai Hater"i'ais Inventor': D A T A 94 .-- i 16 i 9 a.--- 1 i 6 '1 8302 B !-'I C ./A C ./G R C C L CN L/6 R DiFL/:,3R/SP F H '1- F'FC/F'E RF SSTVD Z D L / C N L/' G R /(.t A L. f_.~ I 70--' 995~ /9000 .... 9. 70 7300-"'9953 _~'"~'? 300 9953 s oo .... 995 s ~9270~9500 ~300---9953 ~7 S 00--, 99S3 9 4---- i 'l 6 'i 9 4 -'- 1 'i 6 '1 ar, e dr'y di:,..,,h sarnp'ies r'equi'r'ed ''~ '-~d r"ecei'ved'2 Was %h8 we i j cor'ed'? yes ~lo_~ ~'la d Ar'e we'i'i tests r'equir"ed" . ,. yes H \,,!ei'i i's i'n compiiar, ce ...... I n i' t i' a i C C, H H E i"..! T S STATE OF ALASKA ALA~IL AND GAS CONSERVATION COMMISF"-~-" '. REPORT ,_. SUNDRY WELL OP .,ATIONS 1. Operations performed: Operation shutdown Stimulate__ Plugging__ Pull tubing__ Alter casing Repair well 2. Name of Operator BP E~ploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development Exploratory Stratigraphic Service Perforate ,.~.] L...//,, Other X / j / /..,~ , ,.,, 6. Datum elevati6~i~(p,F~r 7. Unit or Property name '- Prudhoe Bay Unit feet 4. Location of well at surface 1864' SNL, 195' EWL, SEC. 6, T11N, R 13E At top of productive interval 3286' SNL, 3144' EWL, SEC. 6, T11N, R13E At effective depth 3280' SNL, 1700' EWL, SEC. 6, T11N, R13E At total depth 3286' SNL, 3214' EWL, SEC. 6, T11N, R13E 8. Well number M-33(33-6-11-13) 9. Permit number/approval number 94-116 / 10. APl number 50- 029-22504 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length .. 9995 feet 9237 feet 9900 feet 9134 feet Size Plugs (measured) Junk (measured) Cemented 110' 20" 3121' 10 3/4" 9931' 7 5/8" .. 260sx Arcticset I 1050 sx CSIII/375 sx "G" 1100 sx Class "G" measured 9434'-9459~9459'-9479' true vertical subsea 8627~8654~8654'-8676' Tubing (size, grade, and measured depth) 4 1/2", 13CR80 @9225' Packers and SSSV (type and measured depth) Packer @9162'and SSSV@2075' Measured depth 165 3176 9986 True vertical depth BKB 165 3O64 9228 FEB 1996 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure Oil & Gas Cons, Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure -1293 6337 47 2029 1606/' 8772 48 0 Tubing Pressure 242 247 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil X Gas Suspended Service 17. I her¢:~y ce, j;tif~' th, at the.,f~c~going is true¢,-Tnd correct to the best of my knowledge. /'?., .//.//.-,-////~ Form :10-4d4 Rev 06~-1,~/88 SUBMIT IN DUPLICATE 1/17/95 WELL M-33 (33-6-11-13) Addperf The following additional interval were perforated using 3 guns, 6 SPF, random orientation and 60° phasing. 7/8/95 [NJ TEST: DATA FRAC: FRAC: 250 760 9459- 9479 MD' _ Hydraulic Fracture Performed a Hydraulic Fracture using the following fluids: _. Fluid Summary & 510 Bbls Bbls TOTAL FLUIDS PUMPED DOWN HOLE LOAD VOLUME 0 Total Diesel FLUID ADDITIVES BJ SPECTRA FRAC G4000 FLUID SYSTEM with 15 PPT silica flour and 40 PPG adomite regain in pad. No ESL. 3/8" LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 24 January 1995 RE: Transmittal of Data Sent by: MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION 1 PFC/PERF FINAL BL+RF 1 PFC/PERF FINAL BL+RF ECC No. Run # 1 6285.04 Run # 1 6300.03 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: Please siEn and return Petrotec~ical Data Cente~ BP E~x?!cration (~!a..,a) In~ 900 East ~=~~=~.~.. Boulevard Received by Da~e FEB 1 7 1995 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR REC:OMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration 94-116 3. Address 8. APl Number P. O. Box 196612, Anchora~le, Alaska 99519-6612 50-029-22504 4. Location of well at surface ~ .; : ._. :; ~ 9. Unit or Lease Name 1864' SNL, 195' EWL, SEC. 6, T11N, R13E i '' i i.. ' ';'~ i Prudhoe Bay Unit !,/~._j'~.~lf*~_____ ~i '' ~ " 10. Well Number At Top Producing Interval 3286' SNL, 3144'EWL, SEC. 6, T11N, R13E ,! ~..~i;:;?2I,i ¥~-~d~:J~'~J-,. ~.~ , ll.M'33 (33'6-11-13)PrudhoeField and Pool At Total Depth Bay Field/Prudhoe Bay Pool 3286'SNL, 3214'EWL, SEC. 6, T11N, R13E 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 54.8' ADL 28282 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 10/3/94 10/12/94 12/29/94I N/A feet MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 121. Thickness of Permafrost 9995' MD/9237' TVD 9900' MD~9134' TVD YES [] NO [] 2075' feet MDt 1900' (Approx.) 22. Type Electric or Other Logs Run Run 111 DIFL/CNI_/ZDI_/AC/GR/CAL Run 112 RFT 23. CASING, LINER AND CEMENTING RECORD SE'FIqNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.511 H-40 30' 11 O' 30" 260 sx Arcticset I (Approx.) 10-3/4" 45.511 NT8OLHE 30' 3176' 13-1/2" 1050 sx CS 111/375 sx "G" 7-5/8" 29.711 NT95/13CRSO 27' 9986' 9-7/8" 1100 SX Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET(MD) PACKER SET (MD) Gun Diameter 3-3/8" 6 spf 4-1/2", 13CR80 9225' 9162' MD TVD 9434 '-9459' 8627'-8654' 9459'-9479' 8654'-8676' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 12/29/94 Gas Lift Date of Test Hours Tested TEST:~RODUC-rlON FORpERiOD ~ OIL-BBL GAS-MCF WATER-BBL CHOKESlZE GAS-OIL RATIO Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. RECEIVED jA~4 241995 Al~.~,~ ()ii & Gas Cons. Commission Anchor: Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOL~ MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Subsea Sag River 9309' 8504' Shublik 9346' 8540' Top Sadlerochit 9434' 8627' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /~/ ~~ TitleDri#in~_Erl~ineer$~.oorvis(~r Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". R E C ElY E D Form 10-407 d tAi'~ ? Aiaska 0i! & Gas Cons. Commission Anchor: ' ~P/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: M-33 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 10/02/94 12:01 SPUD: RELEASE: 10/22/94 09:00 OPERATION: DRLG RIG: NABORS 18E WO/C RIG: NABORS 18E 10/02/94 ( 1) TD: 110'( 0) 10/03/94 (2) TD: 110'( 0) 10/04/94 ( 3) TD: 1838' (1728) 10/05/94 (4) TD: 3185'(1347) 10/06/94 ( 5) TD: 3185' ( 0) MIRU MW: 0.0 VIS: 0 RD FROM S-02A. RD FLOOR, SECURE CELLAR, PREP DERRICK FOR MOVE. MOVE COMPLEXES TO M-33. MOVE DERRICK AND SUB TO M-33 PIN DERRICK AND BRIDLE UP. DRILLING MW: 0.0 VIS: 0 MOVE RIG MODULES TO M-PAD PIN AND RIG UP DERRICK, SPOT SUB OVER WELL, SPOT MUD PITS, MOTORS, BOILER AND PIPE SHEDS. TAKE ON WATER AND NIPPLE UP DIVERTER SYSTEM AND HYDRIL. MIX SPUD MUD AND RIG UP RIG FLOOR. TEST DIVERTER SUSTEM WITH STATE MAN. DRILLING MW: 9.2 VIS:280 RIH TAG ICE @ 75', DRILL ICE TO 100'_ ORIENT MOTOR AND MWD. SPUD M-33 WELL AT 0700 HRS, 10/03/94. DRILL FROM 110-1101'. SHORT TRIP LITTLE TIGHT AT 990' DRILL FROM 1101-1838'. RUN 10 3/4" CSG MW: 9.6 VIS: 86 DRILL FROM 1838 TO 3023. SHORT TRIP 10 STANDS NO TROUBLE. DRILL FROM 2023 TO 3185 TD. CIRC BOTTOM UPS. SHORT TRIP TO HWDP SLM NO CORRECTION AND NO TROUBLE. CIRC BOTTOM UPS. DROP SURVEY. POH (WET) LD BHA AND RETRIEVE SVY. CLEAR FLOOR. RU TO RUN CSG HAVE SAFETY MEETING AND RUN 10 3/4" CSG. TESTING BOPS MW: 9.2 VIS: 38 RAN 76 JTS 10 3/4" 45.5# NT80 BT&C CASING. MAKE UP CMT HEAD. CIR AND COND MUD AND HOLE FOR CEMENT JOB. RECIPICATE PIPE. TEST LINES. BJ CMT'D 10 3/4" SURFACE CSG W/ SHOE @ 3.175' PUMPING 75 BBLS WATER, 359 BBLS COLD SET 3 LEAD, 77 BBLS CL "G" TAIL. DISPLACED @ 12 BPM. RECIPICATED PIPE BUMPED~PLUG W/ CALCULATED DISPLACEMENT TO 2000 PSI. FLOATS HELD CIP. RD CMT'D HEAD, RAN 1' TP 80' AND RU TO DO TO JOB. BJ DID TOP JOB PUMPING 150 SX COLD SET 2. CIRC GOOD 14.7 PPG CMT TO SURFACE. BACK OUT LANDING JT AND CLEAR FLOOR OF ALL CSG EQUIP. ND 20" DIVERTER. MU 13 5/8" - 5M SPLIT UNI-HEAD. NU BOPS. REMOVE HYDRIL CAP. REPLACE SEALS ON PISTON. FINISH NU BOPS. SET TEST PLUG AND RU TO TEST BOPS. TEST PIPE RAMS. CHOKE LINE, CHOKE MANIFOLD, KILL LINE. STABBING VALVES. UPPER PIPE RAMS, VALVE IN CHOKE MANIFOLD AND TEST PLUG. REDRESS TEST PLUG. RECEIVED ~-~ ?. 4 1995 Anohur: ~ELL : M-33 OPERATION: RIG : NABORS 18E PAGE: 2 10/07/94 (6) TD: 4700' (1515) 10/08/94 (7) TD: 6700'(2000) 10/09/94 ( 8) TD: 7775' (1075) 10/10/94 ( 9) TD: 8650' ( 875) 10/11/94 (10) TD: 9340'( 690) 10/12/94 (11) TD: 9750' ( 410) DRILLING MW: 9.3 VIS: 40 FINISHED TESTING BOPS. TEST HYDRIL, BLINDS AND KELLY COCKS. VOLUME TEST. PULLED TEST PLUG AND SET WEAR BUSHING. PU 8 7/8" BIT AND BHA, ORIENT AND SURFACE CHECK. RIH TO 3067' WASH F/ 3067-3093'. TEST 10 3/4" CSG. DRLG PLUG AND FC ~3093', GOOD CMT, FS @ 3175' AND 10' NEW HOLE TO 3195'. CIRC BOTTOMS UP. PERFORM LEAK OFF TEST. DRLG 9 7/8" HOLE F/ 3195-4218'. MADE 11 STAND SHORT TRIP TO SHOE. HOLE IN GOOD SHAPE. CLEAN OUT SUCTIONS SCREENS. DRLG 9 7/8" HOLE F/ 4218-4700'. DRILLING MW: 9.7 VIS: 50 DRLG 9 7/8" HOLE F/ 4700-5513'. CIRC. CHECK FOR FLOW. MADE 14 STD SHORT TRIP. HOLE IN GOOD SHAPE. DRLG 9 7/8" HOLE F/ 5513-5593'. REPAIR PUMP. WELD UP WASHED OUT TEE BELOW PULSATION DAMPENER. DRLG 9 7/8" HOLE F/ 5593-6700' NO PROBLEMS. DRILLING MW: 9.7 VIS: 43 DRLG 9 7/8" HOLE F/ 6700-6818'. CIRC. CHECK FOR FLOW. STABLE. MADE 20 STAND SHORT TRIP TO 4250' HOLE IN GOOD SHAPE. REPAIR CHAIN GUARD ON #2 PUMP. DR~G 9 7/8" HOLE F/ 6818-7384'. WASH OUT IN UNIBOLT. REPLACED BRASS RING. DRLG 9 7/8" HOLE F/ 7384-7571'. WELD UP WASH OUT ON #1 PUMP. 90 DEGREE TEE BELOW PULSATION DAMPENER. DRLG 9 7/8" HOLE F/ 7571-7775' DRILLING MW: 9.7 VIS: 44 DRLG 9 7/8" HOLE F/ 7775-8292' CIRC. CHECK FOR FLOW. BLOW DOWN KELLY. MADE 16 STAND SHORT TRIP. BRIDGE @ 8240', LD 2 JTS. WASH AND REAM F/ 8240-8292'. DRLG 9 7/8" HOLE F/ 8292-8650'. DRILLING MW: 9.8 VIS: 39 DRLG 9 7/8" HOLE F/ 8650-9239' ROP DECREASED TO 18 FPH W/ 20K WOB F/ 9147-9235'. INCREASED WOB TO 30K. KELLY HOSE LEAKING. CHECK FOR FLOW. POH W/ 30 STANDS DP. HOLE IN GOOD SHAPE. CHANGE OUT KELLY HOSE AND TEST SAME. RIH. WASH AND REAM F/ 9180-9239' DRLG 9 7/8" HOLE F/ 9239-9340' TOP OF SAG RIVER @ 9316' ROP INCREASED FROM 17 FPH IN KINGAK TO 60 FPH IN SAG RIVER. DRILLING MW: 9.8 VIS: 0 DRILLING 9 7/8" HOLE F/ 9340-9391' MWD SURVEY, CK FOR FLOW, DROP SURVEY, SLUG DP, BLOW DOWN KELLY, CK FOR FLOW. POH FOR BIT. LD MWD, MOTOR, AND JARS. SLM. NO CORRECTION. HOLE IN GOOD SHAPE. SERVICE WEAR RING. PU NEW BIT, BHA, JARS AND RIH TO 10 3/4" SHOE. STRING UP NEW DRILLING LINE. FILL PIPE @3100' RIH, FILL PIPE @ 7000'. FINISH RIH TO 9340'. NO PROBLEMS. WASH AND REAM F/ 9340-9391' DRLG 9 7/8" HOLE F/ 9391-9750' NO PROBLEMS. Anchor: ~ELL : M-33 OPERATION: RIG : NABORS 18E PAGE: 3 10/13/94 (12) TD: 9995' ( 245) 10/14/94 (13) TD: 9995' ( 0) 10/15/94 (14) TD: 9995' ( 0) 10/16/94 (15) TD: 9995' ( 0) LOG W/ ATLAS MW: 9.8 VIS: 0 DRILLING F/ 9750-9995'. CIRC. OBSERVE WELL, STABLE. SHORT TRIP 10 STDS. HOLE GOOD. CIRCULATE BOTTOMS UP W/ LO/HI SWEEP AROUND. DROP EMS SURVEY, PUMP DRY JOB, BLOW DOWN KELLY. HOLE STABLE. POH F/ LOGS. RETRIEVE EMS TOOL. R/U ATLAS AND RIH W/ DIFL, CNL, ZDL, AC, GR, CAL. LOGGER TD 9961'. LOG RUN #1. POH LOG #1 AND PREP F/ RETURN RUN. POH LD DP MW: 9.8 VIS: 0 RUN ATLAS LOG #2, RFT. POH ATLAS RFT FIRST RUN, PACKER FAILED. XO TOOLS, RIH, MAKE ADDITIONAL 6 SETS FOR PRESSURES/SAMPLES. POH RD ATLAS. P/U BIT #4, RIH SLM. FILL PIPE AT SHOE AND 7000'. RIH T/ 9890' WASH AND REAM F/ 9890-9995'. NO PROBLEMS. NO CORRECTION ON PIPE STRAP. CIRC LO/HI VIE SWEEP, HOLE CLEAN ON BOTTOMS UP. OBSERVE WELL. POH LD DP TO RUN CSG. CIRC 7-5/8" CSG F/CEMENT MW: 9.8 VIS: 0 POH, L/D 5" DP. REPAIR PIPE SKATE. POH, L/D 5" DP AND BHAo INSTALL TEST PLUG, XO RAMS TO CSG RAMS, BONNET TEST TO 3500 PSI, PULL TEST PLUG. RU AND RUN 7-5/8" CSG, TOTAL OF 24 JTS 29.7# 13 CR NSCC, 217 JTS 29.7# NT95. 2 PUP JTS NT95. RUN 50 TURB AND 63 ST. BLADE CEN. RU CMT HEAD AND WASH DOWN 15', TO 9986', TAKING LIGHT WEIGHT CIRC/COND MUD. #2 PUMP CHAIN BROKE: CIRC W/#1 AT 100 SPM, 7.1 BPM WHILE REPAIRING #2. COMPLETE REPQIRS ON PUMP #2 AND CONTINUE CIRC AND COND F/CMT. BJ START BATCH. MIX TAIL. NO NOTICEABLE MUD LOSSES TO HOLE. RUN 4.5" 13 CR TBG ASSY MW: 9.8 VIS: 0 R/U BJ AND BATCH MIX TAIL W/ CIRC/COND W/ RIG PUMP. TEST LINES. DROP BOTTOM PLUG. WASH UP DROP TOP PLUG DISPLACE WITH CALCULATED STROKES. LOST RETURNS W/ 9 BBL DISPLACEMENT TO GO. THEN REGAINED RETURNS W/ 4 BBLS LEFT. BUMPED PLUG. TEST CSG. DRAIN STACK, CHECK FLOATS, OK. L/D LANDING JT, FLUSH PACKOFF LANDING BOWL, INSTALL AND TEST PACKOFF, OK. CLEAR FLOOR OF EQUIPMENT. XO RAMS TO 4.5". INJECT 190 BBL DOWN ANNULUS TO CLEAR. TEST BOPE. RUN 13 CR COMPLETION ASSY ON BAKER SABL-3 PACKER. P/U BALL VALVE, CONNECT AND TEST CONTROL LINES. RUN 4.5" 12.6# 13 CR NSCT TBG COMPLETION ASSEMBLY. REC£1VED Anchor: ~ELL : M-33 OPERATION: RIG : NABORS 18E PAGE: 4 10/17/94 (16) TD: 9995 PB: 9237 10/18/94 (17) TD: 9995 PB: 9237 10/19/94 (18) TD: 9995'( o) P/U TBG BRIDGE PLUG MW: 0.0 Seawater RIH W/ 4.5" 12.6# 13 CR NSCT TBG ASSY. P/U TBG HANGER, ATTACH AND TEST CONTROL LINES. REVERSE CIRC SEAWATER TREATED WITH CORROSION INHIBITOR. LAND TBG, BACK OUT LANDING JT., RUN IN LOCKDOWNS, TORQUE TO SPECS. INSTALL 2 WAY CHECK. D ETACH CONTROL LINES. L/D ALL VENDOR EQUIP FROM FLOOR. XO TOP RAMS IN STACK TO 5". N/D BOPE. HOOK UP CONTROL LINES, TEST. INSTALL ADAPTER FLANGE, TEST. N/U TREE AND TEST. R/U TO SET PACKER: DROP BALL. SET PACKER. OBSERVED PRESSURE LOSS ON TBG. CHECK SURFACE EQUIPMENT AND ATTEMPT TEST ON TBG. OBSERVED PRESSURE LOSS. MONITOR ANNULUS AND OBSERVE CONTINUOUS WEAK FLOW ON TBG ANNULUS. REPEAT TBG TEST WITH ALL SURFACE EQUIPMENT ISOLATED WITH SAME PRESSURE LOSS. R/U ON ANNULUS AND TEST. OPEN AND OBSERVE, CONTINUE RETURN ON TBG. R/U SAME AND RIH, PULL DUMMY AT HXO BALL VALVE NIPPLE AT 2096'. RIH SET PLUG IN BALL VALVE NIPPLW. PRESSURE TEST TBG W/ ANNULUS OPEN, OBSERVE PRESSURE LOSS. LEAK IN TBG ABOVE SSSV @ 2096'. RIH W/ SLICKLINE AND RETRIEVE SSSV PLUG. RETRIEVE PACKER SETTING BALL AND SEAT XN NIPPLE AT 9213'. POH AND L/D SLICKLINE UNIT. ORDER OUT TBG BRIDGE PLUGS. ALERT E-LINE UNIT FOR PROBABLE CHEM CUTTINGS OPS. BAKER PACKERS ON LOC. W/ MODEL G LOCKSET RETRIEVABLE BRIDGE PLUG. WAIT ON TBG/HANDLING EQUIP. PULL 2 WAY CHECK MW: 0.0 Seawater P/U MODEL G LOCKSET RBP, SET @ 52' TEST TBG/HANGER CONNECTIONS. NO LEAKS. POH L/D RBP. W/O CAMCO WL UNIT. R/U CAMCO, RIH W/ SLICKLINE SET PLUG IN X NIPPLE @ 9101'. POH. RIH RETRIEVE RP SHEAR @ 3099' TOOK 2 RUNS. RIH. SET DUMMY IN TOP GLM @ 3099'_ POH. PRESSURE TEST TBG. PRESSURE TEST ANNULUS. RIH W/ SLICKLINE AND RETRIEVE PLUG F/ X NIPPLE, REDRESS TOOLS AND RIH SET PLUG IN SSSV @ 2096' POH W/ WL. PRESSURE TEST TBG. THIS RETEST CONFIRMS LEAK 2096 - 52' IN TBG. RIH W/ WL AND RETRIEVE PLUG AT SSSV, R/D CAMCO. INSTALL 2 WAY CHECK. N/D TREE. N/U BOPE. TEST BOPE. P/U LUBRICATOR, PULL 2 WAY CHECK. POH L/D TBG MW: 0.0 VIS: 0 P/U RTTS, DC'S AND 2 7/8 DP, RIH SET RTTS AT 1004' TEST 4 1/2 OBSERVE PRESS LOSS, ATTEMPT TEST BELOW RTTS PKR LEAK. RESET RETEST W/ LIMITED SUCCESS. PKR HYD UNSETTING. POH TO 850'. RESET AND TEST W/ GOOD TEST ON 4.5". ISOLATED LEAK BETWEEN 1004 - 850' PACKER DEVELOPED LEAK BY ELEMENTS. POH L/D DP, PKR. R/U ATLAS AND RIH. CUT TBG AT 9132' MIDDLE OF FIRST JT ABOVE SABL-3 PKR. POH, RD ATLAS. INSTALL 4.5" TEST. POH LD TBG COMPLETION ASSEMBLY. FOUND IMPROPER MAKEUP AND GALLED THREAD AT JT 205-206. DEPTH 950'. CONTINUE POH. INSPECT EACH JT FOR DAMAGE AND IMPROPER MAKEUP. RECEIVED dFi' 2 4 1995 i4~.sk~ Oil a Gas Cons. Commission ,Anchor: - ~ELL : M-33 OPERATION: RIG : NABORS 18E PAGE: 5 10/20/94 (19) TD: 9995' ( 0) 10/21/94 (20) TD: 9995' ( 0) 10/22/94 (21) TD: 9995 PB: 9237 10/23/94 (22) TD: 9995 PB: 9237 RIH W/ PBR ON 3 1/2" DP MW: 0.0 VIS: 0 FINISH POH LD 4 1/2" COMPLETION ASSEMBLY. RECOVERED CUT OFF JT 4 1/2" TBG AND ALL STAINLESS STEEL BANDS. INSTALLED TEST PLUG. CHANGED UPPER RAMS TO 3 1/2" TEST RAMS TO 5000 PSI. PULLED TEST PLUG AND SET WEAR RING. PU 6 3/8" OD OVERSHOT, TWO BOWLS W/ 4 1/2" GRAPPLES, EXTENSION, BUMPER SUB. JARS 6 - 4 3/4" DC'S. RIH PU 3 1/2" DP TO 9095'. CIRC BTTMS UP. WORKED OVERSHOT OVER FISH @ 9132' PULLED 75K OVER STRING WT. RELEASED ANCHOR SEAL ASSY. CHAINED OUT OF HOLE. LD ANCHOR SEAL ASSY, PUP, AND PIECE OF 4.5" TBG AND FISHING TOOLS. PU BAKER ANCHOR SEAL ASSY AND PBR. RIH W/ PBR ON 3 1/2" DP. RUN 4 1/2" TBG MW: 0.0 VIS: 0 FINISH RIH W/ BAKER ANCHOR SEAL ASSY AND PBR ON 3 1/2" DP LATCHED INTO PKR @9132'. RU AND TEST PKR AND ANCHOR SEALS. SHEARED OUT OF PBR. LD 2 JTS DP. CHANGE SWIVEL PACKING. CUT DRLG LINE. POH LD 3 1/2" DP, DC'S AND PBR SEAL NIPPLE. PULLED WEAR RING AND SET TEST PLUG. CHANGED UPPER RAMS TO 4 1/2", TEST. PULLED TEST PLUG. RU CASER. RIH W/ PBR SEAL NIPPLE, X-NIPPLE, GLM'S AND 4 1/2" CHROME TBG. TEST 7 5/8" CSG MW: 0.0 Seawater RAN 176 JTS 4 1/2" CR TBG, PBR SEAL NIPPLE, AND 5 GLM'S. PU OTIS BVN. HOOKED UP CONTROL LINES AND TESTED. FINISH RIH W/ 4.5" CR TBG STUNG INTO PBR RECEPTICAL FOR SPACEOUT. PU AND DISPLACED HOLE W/ 375 BBLS TREATED SEAWATER. PU PUPS FOR SPACE OUT. PU TBG HANGER. RAN CONTROL LINES THRU TBG HGR AND TEST. LANDED TBG ON HANGER, RILDS. RU AND TEST TBG AND PKR. HELD. BACK OUT LANDING JT, SET TWC, AND CUT CONTROL LINES. CHANGE UPPER RAMS TO 5" AND ND BOPS. NU TBG HEAD ADAPTER AND TREE. TEST. RU LUBRICATOR AND PULLED TWC. RU TO CIRC AND TEST. PRESSURE TBG. TEST 7 5/8" CSG, HELD. RELEASE RIG MW: 0.0 Seawater FINISHED TESTING 7 5/8" CSG, HELD. SHEARED RP. FREEVE PROTECT TBG 7 5/8" CSG W/ 128 BBLS DIESEL. SET BPV. RD HOSES AND PUMP IN SUB. EMPTY PITS AND CELLAR. RELEASE RIG @ 0900 HRS 10/22/94. SIGNATURE: (drilling superintendent) DATE: RECEIVED ,i ,,,,,. ~ ' ~ 1 ,./,.1 A'~s~ 0il & Gas Cons. Commission Anchor: M-33 Well MWD Surveys 0.00' - 9331' BP EXPLORATION (Alaska) Inc. Pad M 33 slot #33 Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : PMSS <0 - 9311'> Our ref : svy4504 License : Date printed : 25-0ct-94 Date created : 25-0ct-94 Last revised : 25-0ct-94 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on n70 20 37.100,w148 57 17.056 Slot location is n70 20 18.766,w148 57 11.365 Slot Grid coordinates are N 5974505.418, E 629009.786 Slot local coordinates are 1864.17 S 194.84 E Reference North is True North RECEIVED dAi~ 2 z,,. 1!)95 Oil & Gas Cons. [;ommission BP EXPLORATION (Alaska) Inc. Pad M,33 Prudhoe Bay,North Slope, Alaska Measured Inclin. Azimuth True Vert. Depth Degrees Degrees Depth 0.00 0.00 0.00 0.00 196.00 0.30 51.50 196.00 289.00 0.40 151.70 289.00 381.00 0.40 129.50 381.00 473.00 0.50 98.20 472.99 565.00 0.40 101.00 564.99 657.00 0.60 87.70 656.99 747.00 0.70 87.30 746.98 839.00 1.10 62.70 838.97 934.00 1.10 56.80 933.95 1026.00 1.50 69.40 1025.93 1117.00 1.80 65.50 1116.89 1209.00 2.00 70.50 1208.84 1301.00 2.10 69.10 1300.78 1394.00 2.10 75.00 1393.72 1487.00 3.00 94.40 1486.63 1578.00 4.60 106.30 1577.42 1671.00 7.60 118.30 1669.89 1763.00 11.20 121.80 1760.64 1856.00 13.40 120.00 1851.50 SURVEY LISTING Page 1 Your ref : PMSS <0 - 9311'> Last revised : 25-0ct-94 R E C T A N G U L A R Dogleg Vert C 0 0 R D I N A T E S Deg/lOOFt Sect 0.00 N 0.00 E 0.00 0.00 0.32 N 0.40 E 0.15 0.23 0.18 N 0.75 E 0.58 0.60 0.30 S 1.15 E 0.17 1.16 0.56 S 1.79 E 0.28 1.86 0.68 S 2.50 E 0.11 2.56 0.72 S 3.30 E 0.25 3.30 0.68 S 4.32 E 0.11 4.20 0.25 S 5.67 E 0.60 5.23 0.67 N 7.24 E 0.12 6.27 1.58 N 9.10 E 0.53 7.57 2.59 N 11.52 E 0.35 9.33 3.72 N 14.35 E 0.28 11.41 4.86 N 17.44 E 0.12 13.72 5.91 N 20.68 E 0.23 16.20 6.16 N 24.75 E 1.33 19.78 4.96 N 30.62 E 1.95 25.61 0.99 N 39.62 E 3.49 35.44 6.60 S 52.58 E 3.96 50.40 16.75 S 69.59 E 2.40 70.11 1948.00 14.70 119.30 1940.75 2040.00 18.00 122.10 2029.02 2132.00 20.00 122.10 2116.00 2224.00 21.10 119.70 2202.15 2316.00 22.10 114.10 2287.69 27.79 S 89.00 E 1.42 92.37 41.06 S 111.23 E 3.69 118.13 56.98 S 136.60 E 2.17 147.86 73.54 S 164.31 E 1.50 179.99 88.82 S 194.50 E 2.49 213.81 2410.00 23.40 111.60 2374.38 2503.00 23.30 112.30 2459.76 2595.00 23.60 113.00 2544.17 2688.00 24.30 115.80 2629.16 2781.00 25.60 115.80 2713.48 102.91 S 228.00 E 1.72 250.12 116.69 S 262.18 E 0.32 286.92 130.79 S 295.97 E 0.44 323.50 146.39 S 330.34 E 1.44 361.24 163.46 S 365.66 E 1.40 400.46 2873.00 26.70 116.50 2796.06 2965.00 27.30 114.80 2878.04 3059.00 28.40 114.80 2961.15 3110.00 28.70 115.10 3005.94 3215.00 28.90 113.70 3097.96 181.34 S 402.05 E 1.24 441.00 199.41 S 439.70 E 1.06 482.76 217.83 S 479.56 E 1.17 526.67 228.11 S 501.66 E 0.65 551.05 249.00 S 547.72 E 0.67 601.62 3306.00 28.70 113.40 3177.70 3398.00 28.70 114.40 3258.40 3490.00 28.70 115.10 3339.10 3584.00 28.10 114.80 3421.78 3676.00 27.80 114.80 3503.05 266.52 S 587.91 E 0.27 645.45 284.42 S 628.30 E 0.52 689.62 302.92 S 668.42 E 0.36 733.79 321.78 S 708.96 E 0.66 778.50 339.86 S 748.10 E 0.33 821.62 3769.00 27.80 114.10 3585.32 3862.00 27.30 114.40 3667.77 3953.00 27.60 116.20 3748.53 4047.00 29.70 115.80 3831.02 4138.00 29.50 117.90 3910.14 357.82 S 787.59 E 0.35 864.99 375.48 S 826.81 E 0.56 908.00 393.41 s 864.73 E 0.97 949.94 413.16 S 905.24 E 2.24 995.01 433.46 S 945.33 E 1.16 1039.93 4230.00 29.50 116.20 3990.22 4324.00 29.00 116.20 4072.23 4416.00 28.90 117.20 4152.74 4509.00 29.00 117.20 4234.11 4599.00 29.30 117.60 4312.72 454.06 S 985.68 E 0.91 1085.20 474.34 S 1026.89 E 0.53 1131.12 494.34 S 1066.67 E 0.54 1175.64 514.92 S 1106.71 E 0.11 1220.63 535.10 S 1145.63 E 0.40 1264.43 RECEIVED d;:.,i,i 2 4 1995 ;, ~, .?-,,- Oi~ & Gas Con~. Commissio~ Anchor[ All data is in feet unless otherwise stated Coordinates from slot #33 and TVD from wellhead (54.80 Ft above mean sea level). Vertical section is from N 0.00 E 0.00 on azimuth 115.15 degrees. Declination is 0.00 degrees, Convergence is 0.98 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ BP EXPLORATION (Alaska) Inc. SURVEY LISTING Page 2 Pad M,33 Your ref : PMSS <0 - 9311'> Prudhoe Bay,North Slope, Alaska Last revised : 25-0ct-94 Measured Depth 4692.00 4785.00 4875.00 4968.00 5062.00 5154.00 5247.00 5340.00 5433.00 5524.00 5617.00 5710.00 5802.00 5897.00 5987.00 6079.00 6172.00 6266.00 6361.00 6454.00 6550.00 6643.00 6738.00 6833.00 6927.00 7022.00 7115.00 7209.00 7304.00 7399.00 7491.00 7585.00 7681.00 7775.00 7869.00 7963.00 8058.00 8151.00 8244.00 8337.00 8432.00 8526.00 8620.00 8714.00 8809.00 8904.00 8998.00 9091.00 9186.00 9280.00 Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Degrees Degrees Depth C 0 0 R D ! N A T E S Deg/lOOFt Sect 28.70 119.30 4394.06 556.57 S 1185.27 E 1.10 1309.44 30.10 115.10 4475.09 577.39 S 1225.87 E 2.68 1355.04 30.30 117.20 4552.87 597.34 S 1266.50 E 1.19 1400.30 30.50 115.50 4633.09 618.23 S 1308.67 E 0.95 1447.34 30.40 115.10 4714.12 638.59 S 1351.74 E 0.24 1494.98 30.80 115.10 4793.31 658.45 S 1394.15 E 0.43 1541.81 30.40 115.10 4873.36 678.53 S 1437.02 E 0.43 1589.16 30.10 116.20 4953.70 698.81 S 1479.25 E 0.68 1636.00 30.30 115.10 5034.08 719.06 S 1521.42 E 0.63 1682.78 30.40 115.80 5112.60 738.82 S 1562.94 E 0.40 1728.76 30.70 114.80 5192.70 759.02 S 1605.67 E 0.63 1776.03 30.20 113.00 5272.87 778.12 S 1648.76 E 1.12 1823.14 30.10 113.40 5352.42 796.32 S 1691.23 E 0.24 1869.32 30.70 113.00 5434.36 815.26 S 1735.41 E 0.67 1917.37 31.20 110.90 5511.55 832.55 S 1778.34 E 1.32 1963.58 29.70 112.70 5590.86 849.85 S 1821.63 E 1.91 2010.11 28.00 114.10 5672.31 867.65 S 1862.82 E 1.97 2054.96 27.90 114.80 5755.35 885.89 S 1902.92 E 0.36 2099.02 27.80 113.70 5839.35 904.12 S 1943.38 E 0.55 2143.39 27.90 113.70 5921.58 921.58 S 1983.17 E 0.11 2186.82 28.00 113.00 6006.38 939.41 S 2024.48 E 0.36 2231.79 27.90 114.10 6088.53 956.83 S 2064.43 E 0.56 2275.36 27.70 113.40 6172.57 974.67 S 2104.99 E 0.40 2319.66 27.90 113.00 6256.60 992.12 S 2145.71 E 0.29 2363.94 27.80 113.00 6339.71 1009.28 S 2186.13 E 0.11 2407.82 27.70 114.10 6423.79 1026.96 S 2226.68 E 0.55 2452.03 27.50 113.40 6506.20 1044.31 S 2266.12 E 0.41 2495.11 27.20 112.30 6589.70 1061.08 S 2305.91 E 0.62 2538.26 26.20 113.00 6674.57 1077.51 S 2345.31 E 1.10 2580.90 25.60 112.70 6760.02 1093.63 S 2383.54 E 0.65 2622.36 25.10 112.70 6843.16 1108.83 $ 2419.88 E 0.54 2661.72 24.70 113.70 6928.43 1124.42 S 2456.26 E 0.62 2701.27 24.30 115.50 7015.78 1140.98 S 2492.46 E 0.88 2741.07 24.30 114.80 7101.46 1157.42 S 2527.47 E 0.31 2779.75 24.30 116.50 7187.13 1174.16 S 2562.34 E 0.74 2818.43 24.40 118.60 7272.77 1192.09 S 2596.69 E 0.93 2857.15 24.00 119.30 7359.42 1210.94 S 2630.77 E 0.52 2896.00 23.10 118.60 7444.68 1228.93 S 2663.28 E 1.01 2933.08 22.90 121.10 7530.28 1247.01 S 2694.79 E 1.07 2969.29 20.30 118.60 7616.75 1264.08 S 2724.46 E 2.96 3003.40 19.20 116.50 7706.16 1278.94 S 2752.91 E 1.38 3035.46 17.80 117.60 7795.30 1292.49 S 2779.47 E 1.53 3065.27 16.10 116.20 7885.21 1304.90 S 2803.90 E 1.86 3092.66 14.80 116.20 7975.81 1315.96 S 2826.37 E 1.38 3117.70 12.80 116.90 8068.07 1326.08 S 2846.64 E 2.11 3140.35 11.10 113.70 8161.01 1334.52 $ 2864.40 E 1.92 3160.01 10.90 112.70 8253.28 1341.58 S 2880.89 E 0.29 3177.94 10.50 114.40 8344.66 1348.48 S 2896.72 E 0.55 3195.19 10.10 116.90 8438.13 1355.82 S 2912.03 E 0.63 3212.18 9.90 120.00 8530.70 1363.59 S 2926.38 E 0.61 3228.47 I ECEiVED ,~::.~..~ ,~ii & Gas Cons. Anchor: All data is in feet unless otherwise stated Coordinates from slot #33 and TVD from wellhead (54.80 Ft above mean sea level). Vertical section is from N 0.00 E 0.00 on azimuth 115.15 degrees. Declination is 0.00 degrees, Convergence is 0.98 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ BP EXPLORATION (Alaska) Inc. Pad M,33 Prudhoe Bay, North Slope, Alaska SURVEY LISTING Page 3 Your ref : PMSS <0 - 9311'> Last revised : 25-0ct-94 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 9311.00 10.10 120.70 8561.23 1366.31 S 2931.02 E 0.75 3233.83 RECEIVED d~-'~i,~ 2 ~- Anohor,, All data is in feet unless otherwise stated Coordinates from slot #33 and TVD from wellhead (54.80 Ft above mean sea level). Vertical section is from N 0.00 E 0.00 on azimuth 115.15 degrees. Declination is 0.00 degrees, Convergence is 0.98 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ M-33 Well EMS Surveys 9339'- 9995' Note: 9995' - Projected Data-No Survey RECE]VED d;:;.] :;' ,r,,. ,..,.~,,.~ Oil & 6;~s Cor~s. Oornrnissio~ ~nchor~ BP EXPLORATION (Alaska) [nc. Pad M 33 slot #33 Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : EMS <9339' - 9995'> Our ref : svy4508 License : Date printed : 27-0ct-94 Date created : 25-0ct-94 Last revised : 25-0ct-94 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on n70 20 37.100,w148 57 17.056 Slot location is nTO 20 18.766,w148 57 11.365 Slot Grid coordinates are N 5974505.418, E 629009.786 Slot local coordinates are 1864.17 S 194.84 E Reference North is True North RECEIVED J~,~ ~. 'iS ~]~1,~ .O[i.& Gas Cons. ~mchor~ BP EXPLORATION (Alaska) Inc. Pad M,33 Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 1 Your ref : EMS <9339' - 9995'> Last revised : 25-0ct-94 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 9339.00 10.29 119.92 8588.79 1368.81 S 2935.30 E 0.84 3238.76 9432.00 9.71 121.02 8680.38 1377.00 S 2949.22 E 0.66 3254.84 9527.00 9.20 121.39 8774.09 1385.08 S 2962.57 E 0.54 3270.36 9621.00 8.98 122.07 8866.91 1392.89 S 2975.20 E 0.26 3285.11 9716.00 8.39 122.56 8960.82 1400.56 S 2987.33 E 0.62 3299.35 9810.00 8.13 121.86 9053.84 1407.76 S 2998.75 9904.00 8.01 123.64 9146.91 1414.89 S 3009.85 9934.00 7.46 127.09 9176.64 1417.23 S 3013.14 9995.00 7.46 127.09 9237.12 1422.00 S 3019.46 E 0.30 3312.75 E 0.29 3325.83 E 2.40 3329.80 E 0.00 3337.55 Projected Data - No Survey RECEIVED J,a,[,! 2 4 I'!)95 Anchor:. All data is in feet unless otherwise stated Coordinates from slot ~33 and TVD from wellhead (54.80 Ft above mean sea level). Vertical section is from wellhead on azimuth 115.15 degrees. Declination is 0.00 degrees, Convergence is 0.98 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 28 October 1994 RE: Transmittal of Data Sent by: ANCHORAGE EXPRS Dear Sir/Madam, Enclosed, please find the data as described below: ?LL I # DESCRIPTION [~ - f~ ~ k Ge/COL LDWG TAPE+mST ECC No. Run # 1 954.04 Run # 1 3043.04 Run # 1 6279.00 Run # 1 6280.01 Run ~ 1 6285.00 Run # 1 6286.00 Run # 1 6288.00 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson OCr $ J or FAX ~o (907) LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 26 October 1994 RE: Transmittal of Data Sent by: U.S. MAIL Dear Sir/Madam, Enclosed, please find the data as described below: DESCRIPTION 1 POL/CCL FINAL BL 1 POL/CCL RF SEPIA 1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA 1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA 1 CCL/CHEMCUT FINAL BL 1 CCL/CHEMCUT RF SEPIA ECC No. Run # 1 3060.04 Run # 1 Run # 1 4123.03 Run # 1 Run # 1 4473.02 Run # 1 Run # 1 6042.07 Run # 1 Run # 1 6285.01 Run # 1 ~Pl~.acc si~n =~d reuurn to: Atlas ~l= ...... ~rviccs 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson - , Or FAX.to (907) 563-7803 LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 17 October 1994 RE: Transmittal of Data Sent by: U.S. MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION M-33 ~~ ~/~%HC/AC/GR FINAL BL ~i-~F~T/GR FINAL BL /.tDZiL/CN/GR FINAL BL FL/GR/SP FINAL BL ~~VD/MWD FINAL BL HC/AC/GR RF SEPIA DL/CN/S~ RF SEPIA IFL/GR/S? RF SEPIA Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 FCC No. 6285.00 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn..Rodney D. Paulson Received by: RECEIVED "'~ ~ 1994 Alaska 0il & Gas Cons. Commission Anchorage MEMORANDUM TO: THRU: State of Alaska David Jo~, Chai rma'n//Y Blair Wondzell, P. I. Supervisor FROM: Lou G ri maldi,~'-,~-- SUBJECT: Petroleum Inspector Alaska Oil and Gas Conservation Commission DATE: October 6, 1994 FILE NO: AWNJJFBD.doc BOP Test Nabors rig #18-E BPX well# M-33 Prudhoe Bay field PTD # 94-116 Thursdav, October 6, 1994: I traveled to Nabors rig # 18-E to witness the initial BOP test on their rig which is presently drilling BPX well # M-33 in the Prudhoe Bay Field. The rig was ready when I arrived. The test went slowly with 3 components failing, these being the upper pipe rams, the manual choke valve and the outside blooey line valve on the choke manifold. All failed components were repaired and retested "OK". The test lasted 5 hours and I found Don Dubois (Nabors toolpusher) test procedure to insure a good test of the BOPE. Mike Whitely (Drilling foreman) was in attendence for the test. I found the overall condition of the rig to be in good shape. Summary: I witnessed the initial BOP test on Nabors rig # 18-E. Test time 5 hours. 3 failures. Attachment: AWNJJFBD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: 10 3/4 Test: Initial X Workover: DATE: Nabors Rig No. 18E PTD# 94-116 Rig Ph.# BP Explora§on Rep.: Mike Whitely PBU M-33 Rig Rep.: DON DUBOIS Set @ 3526' Location: Sec. 6 T. 11N R. 13E Meridian UM Weekly Other 10/6/94 659-4608 Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) Reserve Pit N/A Well Sign OK Drl. Rig OK BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Pressure P/F 250/3500 P 250/5000 F 250/5000 P 250/5000 P 250/5000 F 250/5000 P 250/5000 P N/A N/A MUD SYSTEM: Visual Alarm Trip Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Gas Detectors OK OK FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. Pressure P/F 1 250/5000 P I 250/5000 P I 250/5000 P I 250/5000 P CHOKE MANIFOLD: No. Valves 16 No. Flanges Manual Chokes 2 Hydraulic Chokes I Test Pressure P/F 250 / 5000 F 36 250/5000 P P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 2 Blind Switch Covers: Master: Nitgn. Btl's: 8 Bottles 2200 (Ave.) 3,000 ! OK 1,400 OK minutes 32 sec. minutes 14 sec. OK Remote: OK Psig. Number of Failures: 3 ,Test Time: 5.0 Hours. Number of valves tested 27 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Upper pipe rams failed, replace and retest "OK", Outside Blooey vlv failed notify inspector when repaired Manual choke valve failed, Grease-function and retest "OK" 10-7-94: Mike Whitely called and informed me the blooey line valve had been repaired and retested "OK" Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Louis R Griraaldi FI-02t L (Rev. 7/93) AWNJJFBD.XLS MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johns~:~¥--~',j DATE: Chair~m~~ THRU: Blair Wondzell, ~~ FILE NO: P. i. Supervisor ~op"/'~,t FROM: John Spaulding,~r SUBJECT: Petroleum Insp. October 3, 1994 EHNLJABD.doc Diverter Function Test BPX PBU Nabors 18E Prudhoe Oil Pool PTD 94-116 Monday October 3, 1994: I witnessed the Diverter Function Test on Nabors 18E BPX / PBU. As noted on the AOGCC Diverter Function Test Report no failures were observed. The rig was well layed out with good wind direction and all emergency access areas open. Summary: failures. I witnessed the Diverter Function Test on Nabors 18E with no Attachment: EHNLJABD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report operation: Development XXX Exploratory: Drig Contractor: Nabors Rig No. 18E PTD # 94-116 Rig Ph. # Operator: BPX Oper. Rep.: Don Dubois Well Name: /~1~33 Rig Rep.: Terry Hanna Location: Sec. 6 T. 11N R. 13E Merdian Umiat 659-4608 MISC. INSPECTIONS: Location Gen.: ok Well Sign: ok Housekeeping: ok (Gen.) Drlg. Rig: ok Reserve Pit: na Flare Pit: na DIVERTER SYSTEM INSPECTION: Diverter Size: 20 in. Divert Valve(s) Full Opening: yes Valve(s) Auto & Simultaneous: yes Vent Line(s) Size: 10 in. Vent Line(s) Length: 100 ft. Line(s) Bifurcated: yes Line(s) Down Wind: yes Line(s) Anchored: yes Turns Targeted I Long Radius: yes ACCUMULATOR SYSTEM: Systems Pressure: Pressure After Closure: 200 psi Attained After Closure: Systems Pressure Attained: Nitrogen Bottles: 3050 psig 1450 psig min. 41 sec. 2 min. 20 sec. 8 ~ 2000 avg. psig MUD SYSTEM INSPECTION: Light Alarm Trip Tank: ok ok Mud Pits: ok ok Flow Monitor: ok ok GAS DETECTORS: Light Alarm Methane ok ok Hydrogen Sulfide: ok ok ~ Valve~~ Nabom 18E ~ ~)~Diverter Prevailing Wind North South Distribution odg. - Well File c - OpedRep c - Database c - Tdp Rpt File c - Inspector FI-022 AOGCC REP.: OPERATOR REP.: EHNLJABD.XLS John H. Spaulding ALASKA OIL AND GAS CONSERVATION COMMISSION September 8, 1994 WALTER J. HICKEL, GOVERNOR ... 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Terry Jordan Drilling Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit M-33 BP Exploration (Alaska), Inc. Permit No: 94-116 Sur. Loc. 1864'SNL, 195'EWL, Sec. 6, TllN, R13E, UM Btmhole Loc. 2017'NSL, 1726'WEL. Sec 6, TllN, R13E, UM Dear Mr. Jordan: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention eqUipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. -~nston ~~a~r~~~ oF T~~~C ~SION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 fla. Type of work Drill [] Redrill Dllb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []1 Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration KBE = 54.8 feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchoraae. Alaska 99519-6612 ADL 28282 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25,025) 1864' SNL, 195' EWL, SEC. 6, T11N, R13E Prudhoe Bay Unit At top of productive interval 8. Well number Number 2059' NSL, 1815' WEL, SEC. 6, T11N, R13E M-33 (33-6-11-13) 2S100302630-277 At total depth 9. Approximate spud date Amount 2017' NS/_, 1726' WEL, SEC. 6, T11N, R13E 9/17/94 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (aD and TVO) property line ADL 28279-1864' feet No close approach feet 2560 9992' MD/9228' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (~e 20 AAC 25.o35 (e)(2)) Kickoff depth ~5oo feet Maximum hole an~lle~9.3~ o Maximum surface 3330 psig At total depth (TVD) ~800'/4390 psi~ 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M D TVD MD TVD (include stage data) 30" 20" 91.5# H-40 Weld 80' 30' 30' 110' 110' 260 sx Arcticset I (Approx.) 13-1/2" 10-3/4" 45.5# NT8OLHE Butt 3140' 29' 29' 3169' 3055' 1050 sx CS III/375 sx "G"/250 sx CS II 9-7/8" 7-5/8" 29. 7# NT95HS NSCC 9031' 28' 28' 9059' 8309' 9-7/8" 7-5/8" 29. 7# 13CR80 NSCC 933' 9059' 8309' 9992' 9228' 825 sx Class "G" conting ency 6-3/4" 5-1/2" 17# 13CR80 NSCC 883' 9109' 8358' 9992' 9228' 135 sx Class "G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface ~ ~ ~,~ ! Intermediate Production ~-:~ ~.-? ~ ~ Liner Perforation depth' measured i~.i~..,_~,~.~ O',i &. ~.s~ C01'~:~, 60 true vertical A~c['~'~' '-:~~; 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program l'~l Drilling fluid program [] Time vs depth plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby c~ify t?t~?he foregoing is true and correct to the best of my knowledge ~-)t4 Signed '?;(!~'~ ~.-/'.~ ~ 1;' Title Drilling Engineer Supervisor Date':-:/ ' '/ ~ ( ) Commission Use Only ' Permit Number ' 'J IAPlnumber IAppr~.~ldate ~s .Seecoverletter ?~'-/'/'~ 150-~:~- ~~ ~ J~ ~- Ifor other requirements Conditions of approval Samples required [] Yes ~ No Mud log required ~] No Hydrogen sulfide measures [] Yes 1~ No Directional survey requ~rea J~ Yes [] No Required working pressure for BOPE 1-12M; 1-13M; ~I5M; I-I10M; I-I15M; Other: Orfgina! S[{]lle by order of Approved byno,,~,~ ,~ ,~,-__,_ ~y Commissioner tne commission Date~--,,-- Form 10-401 Rev.~"l'2'-'t-8~J Submit in ti'iplicate Well Plan Summary ]WellName: IM-33 PBU I Type of Well (producer or injector): I Producer I Surface Location: ] 3415' FSL 4696' FEL Sec 06 T11N R13E UM Target Location: ! 2059' FSL 1815' FEL Sec 06 T1 IN R13E UM Bottom Hole Location: 2017' FSL 1726' FEL Sec 06 T1 IN R13E UM I AFE Number: 14P0579 I I Estimated Start Date: I Sept. 17, 1994 I IuD: 19992' I [TVD: I Well Design (conventional, slimhole, etc.): I Rig: I Nabors 18-E I Operating days to complete: I 15 19228, I IRT'GL 129.5' I KBE:I 54.8' I Slimhole producer Formation Markers: Formation Tops MD TVD (BKB) Base Permafrost 1856' 1855' Ugnu Zone 4A 3943' 3730' Top Seabee (CM3) 5864' 5405' Kuparuk/Put River Absent Absent IKRU/LCU 7526' 6855' Top Sag River 9259' 8506' Top Shublik 9297' 8543' Top Sadlerochit 9380' 8625' Target 9428' 8672' Total Depth 9992' 9228' Casing/Tubin Program: Wt/Ft Hole Size Csg/ Wt/l~t Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 30" 20" 91.5# H-40 Weld 80' 30'/30' 1107110' 13-1/2" 10-3/4" 45.5# NT80LHE Butt 3140' 29'/29' 3169"/3055' 9-7/8" 7-5/8" 29.7# NT95HS NSCC 9031' 28'/28' 9059'/8309' 9-7/8" 7-5/8" 29.7# 13Cr-80 NSCC 933' 9059'/8309' 9992'/9228' Contingency 6-3/4" 5 1/2" 17# 13Cr-80 NSCC 883' 9109'/8358' 9992'/9228' Tubing 4 1/2" 12.6 13Cr-80 · NSCT 9132' 27'/27' 9159'/8407' Well Plan Summary Logging Program: ] Open Hole Logs: 13 1/2" Hole 9 7/8" Hole 6 3/4" Hole I Cased Hole Logs: 7 5/8" Casing 5 1/2" Liner None None GR/DIL/BHCS/CNL/SP None Optional SBT and Gyro Mud Program: I Special design considerations I None Surface Mud Properties: ] SPUD Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.5 100 20 15 20 9 15 tO tO tO tO tO tO tO 9.5 300 60 60 80 10 25 Intermediate Mud Properties: I LSND Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 35 10 5 10 9.5 5 tO tO tO tO tO tO tO 10.0 50 15 10 20 10 10 Production Mud Properties: I LSND Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.8 30 8 3 7 8 6 tO tO tO tO tO tO tO 9.2 45 13 10 15 9 8 NOTE: Keep annular velocities around drill pipe at or above 220 ft/min wherever possible Directional'. I KOP: I ~500' I Maximum Hole Angle: I 29.31 degrees Close Approach Well: None The above listed wells will be secured during the close approach. Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Well Plan Summary PROPOSED DRILLING AND COMPLETION PROGRAM WELL M-33 [ 06-11-13 ] PBU 1. MIRU. NU diverter and function test same. 2. Drill 13-1/2" hole. Run and cement 10-3/4", 45.5#, NT-80 Buttress casing to surface. . Install blowout prevention equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer. Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based on original reservoir pressure. Maximum possible surface pressure is 3330 psi based on a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. Function test BOPE to 5000/250 psi. e Test 10-3/4" casing to 3000 psi for 30 minutes. A formation leak-off test will be performed 10' below the 10-3/4" shoe. . Longstring Option: Directionally drill 9-7/8" hole to TD. Run a 7-5/8", 29.7#, NT-95 NSCC by 7-5/8", 29.7#, 13Cr-80 NSCC casing string and cement with Class G cement around the 7-5/8" shoe. The annulus will be freeze protected with dry crude. Bump the plug with filtered seawater. Test casing to 3500 psi. Sa. Non-longstring Option: Directionally drill 9-7/8" hole to the 7-5/8" casing point above the top of Sag River. Run a 7-5/8", 29.7#, NT-95 NSCC casing string to within 10' of 9- 7/8" TD and cement with Class G cement around the 7-5/8" shoe. The annulus will be freeze protected with dry crude. 6b. Directionally drill the 6-3/4" hole to TD. Run 5~1/2", 17#, 13 Cr-80 NSCC liner from TD to 150' inside 7-5/8" casing shoe and cement using Class G cement. 6C. Clean out to 5-1/2" float equipment. Change over to filtered seawater completion fluid. Test casing and lap to 3500 psi. . Run 7-5/8" production packer on the 4-1/2", 12.6g, 13 Cr-80 NSCT tubing. A subsurface safety valve with dual control lines will be placed 100' below base of permafrost. Install and test Xmas tree. Freeze protect the tubing and annulus with diesel from surface to 2100' TVDBKB. Set and test packer. 8. The well will be perforated after the rig has been released. Fluids incidental to the drilling of a well will be injected down CC-2A. Tubing Size: 4-1/2", 12.6 # NT 13CR-80 tubing with 5 GLM's. Well Plan Summary 10-3/4" SURFACE CASING CEMENT PROGRAM - BJ SERVICES CASING SIZE: 10-3/4" CIRC. TEMP: 38°F PREFLUSH: 75 bbls fresh water ahead of lead slurry. LEAD CEMENT TYPE' COLD SET III ADDITIVES: retarder WEIGHT: 12.2ppg YIELD: 1.92ft3/sx MIX WATER: 10.53 gps APPROX. # SACKS: 1050 THICKENING TIME: Greater than 4 hrs. @ 50°F TAIL CEMENT TYPE: CLASS G ADDITIVES' 2% A-7 +1 ghs FP-6L WEIGHT: 15.8 ppg YIELD: 1.15 ft3/sx APPROX. # SACKS: 375 MIX WATER: 4.95 gps THICKENING TIME: Greater than 3-1/2 hrs @ 50°F TOP JOB CEMENT TYPE: COLD SET II ADDITIVES: WEIGHT: 14.5 ppg APPROX. # SACKS' 250 YIELD' 0.96 ft3/sx MIX WATER: 3.89 gps THICKENING TIME: Greater than 2 hrs @ 50°F CENTRALIZER PLACEMENT: 1. Run 1 bow type centralizer per joint for the first 15 joints. 2. Place the centralizers in the middle of each joint with a stop collar. CEMENT VOLUME: 1. Lead slurry from TD to surface w/100% excess (less the tail slurry volume). 2. Tail slurry volume 375 sx (to cover 500' of casing shoe w/100% excess). 3. Top job volume 250 sx. Well Plan Summary 7-5/8" LONGSTRING CASING CEMENT PROGRAM - BJ SERVICES CASING SIZE: 7-5/8" CIRC. TEMP: 140°F PREFLUSH: 20 bbls fresh water SPACER: 70 bbls BJ MCS-4 Spacer weighted 1.0 ppg above mud weight. LEAD CEMENT TYPE: CLASS G ADDITIVES: 3% A-2 + 0.4% FL-52 + 0.5% CD-32 + 1 ghs FP-6L WEIGHT: 11.0 ppg YIELD: 3.31 ft3/sx APPROX. # SACKS: 390 THICKENING TIME: 5 hrs FLUID LOSS: 150-250 cc/30 minutes TAIL CEMENT TYPE: CLASS G MIX WATER: 20.92 gps ADDITIVES: 150 ghs BA-86L + 0.6% CD-32 + 0.2% FL-33 + 0.2% A-2 + ,;-~I-,,~:!',~'; ? 0.5% gel + 2 ghs FP-10L + S-400 WEIGHT: 15.7 ppg YIELD: 1.17 ft3/sx MIX WATER: 4.85 gps APPROX. # SACKS: 435 THICKENING TIME: 2-1/2 to 3 hrs FLUID LOSS: < 50 cc/30 minutes FREE WATER: 0 cc CENTRALIZER PLACEMENT: 1. Run 2 Turbulator per joint to 300' MD above top of Sadlerochit. 2. Run 1 straight blade rigid centralizer every joint 300' above and below the Cretaceous interval. (only where lead cement is being pumped to the Cretaceous) from 3643' to 6164'. 3. Run 1 solid body 7-3/4" x 9-1/4" centralizer or turbolator on first 2 joints inside 10-3/4" surface casing shoe. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 bpm. Mix lead slurry on the fly, batch mix the tail slurry. CEMENT VOLUME: 1. Lead slurry to 300' MD above top of Ugnu (top of Ugnu at 3943' MD) 2. Tail slurry to 1000' MD above top of Sag River with 30% excess. 3. 80' MD 7-5/8", 29.7# capacity for float joints. Note: Hydrocarbon bearing zones are identified in the Ugnu and Sag River intervals. Well Plan Summary 7-5/8" CASING (CONTINGENCY) CEMENT PROGRAM - BJ SERVICES CASING SIZE: 7-5/8" CIRC. TEMP: 140°F PREFLUSH: 20 bbls fresh water SPACER: 70 bbls BJ MCS-4 Spacer weighted at mud weight. LEAD CEMENT TYPE: CLASS G ADDITIVES: 3% A-2 + 0.4% FL-52 + 0.5% CD-32 + 1 ghs FP-6L WEIGHT: ll.0ppg YIELD: 3.31 ft3/sx APPROX. # SACKS: 390 THICKENING TIME: 5 hrs FLUID LOSS: 150-250 cc/30 minutes WEIGHT: 15.8 ppg APPROX. # SACKS: 260 FLUID LOSS: 100-150 cc/30 minutes MIX WATER: 20.92 gps TAIL CEMENT TYPE: CLASS G ADDITIVES: 0.3% FL-52 + 0.5% CD-32 + 0.1% A-2 + 1 ghs FP-6L YIELD: 1.14 ft3/sx MIX WATER: 4.85 gps THICKENING TIME: 3-1/2 to 4-1/2 hrs FREE WATER: 0 cc CENTRALIZER PLACEMENT: 1. Run 2 Turbulator per joint to 300' MD above top of Sadlerochit. 2. Run 1 straight blade rigid centralizer every joint 300' above and below the Cretaceous interval. (only where lead cement is being pumped to the Cretaceous) from 3643' to 6164'. 3. Run 1 solid body 7-3/4" x 9-1/4" centralizer or turbolator on first 2 joints inside 10-3/4" surface casing shoe. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 bpm. Mix lead slurry on the fly, batch mix the tail slurry. CEMENT VOLUME: 1. Lead slurry to 300' MD above top of Ugnu (top of Ugnu at 3943' MD) 2. Tail slurry to 1000' MD above top of Sag River with 30% excess. 3. 80' MD 7-5/8", 29.7# capacity for float joints. Note: Hydrocarbon bearing zones are identified in the Ugnu and Sag River intervals. Well Plan Summary 5-1/2" PRODUCTION LINER (CONTINGENCY) CEMENT PROGRAM- BJ SERVICES CIRC. TEMP: 140° F BHST: 220° F at 8800' TVDSS. PREFLUSH: 20 bbls fresh water SPACER: 70 bbls BJ MCS-4 Spacer weighted 1.0 ppg above mud weight. CEMENT TYPE: CLASS G ADDITIVES: 150 ghs BA-86L + 0.6% CD-32 + 0.2% FL-33 + 0.2% A-2 + 0.5% gel + 2 ghs FP-10L WEIGHT: 15.7 ppg YIELD: 1.17 ft3/sx MIX WATER: 3.58 gps APPROX. # SACKS: 135 THICKENING TIME: 45 min. @ Surface + 3-4 hrs @ 140°F FLUID LOSS: less than 50 cc/30 minutes @ 140°F FREE WATER: 0 cc at 45° angle. NOTE: Ensure that a thickening time test is performed that simulates the shut down time incurred while rotating off of the liner. Note gellation tendencies ( if any ) of slurry when consistometer is re-started after shutdown period - additional retarder may be required - consult w/cementer. CENTRALIZER PLACEMENT: 1. Run 2 right hand turbolators per joint in open hole, 2. Run 1 right hand turbulator per joint in lap, and none opposite intermediate casing shoe.. OTHER CONSIDERATIONS: Batch mix the cement slurry. Perform fluid loss test on the batch mixed slurry. Fluid loss should be 50 cc/30 min. or less. Report actual fluid loss on morning report. Displace @ 6-8 bpm. LINER CEMENT VOLUME: 1. Open hole (6-3/4" X 5-1/2") + 30% excess (adjust if a caliper log is run and it indicates severe washouts). 2. 5-1/2", 17# casing capacity below landing collar (80'). 3. 150' liner lap (6.875" x 5-1/2") 4. 200' of cement on top of the liner in the 7-5/8" casing. Well Plan Summary D60o PRUDHoE BAY DRILLING GROUP mnlnl i · ....... M-33 (PC) VERTICAL SECTION Section TVD Scale.' J inch = 2200 feet Dep Sca]e' J inch = 2200 fee[ VIEW 0 600 1200 ~800 2400 3000 3600 42d00 4800 5400 6000 8600 7200 7800 Sec[Jori Departuce Il . .iii , o A [ iI Drawn ..... : 06/22/94 ! ~ ~arKen Identif~cat~en 14fl BED gECfN 0 i j i .... A) KB 0 0 0 O. O0 [ ] B) KOPBUILD 2.50/,00 ,500 ,500 0 0.00 B-- C, ENOOF 2.50 BUILO 2672 2~P2 293 29.3, 0 ' ' O) 10-3/4" CASING POINT 3169 3055 · 536 29.31 ' ' .... ' .... '-' '~;~T~r T~ E) KOP DROP J 50/~00 6807 29 ' I . 7472 2643 r I] F} END OF ].50 DROP 8759 80]3 '3074 ~O.O0 ~ ' ' . G) 7-5/8" CASING POINT 9259 8506 3!6~ lO.O0 I) REFERENCE TD DEPTH 9842 g080 3262 10.00 J) TO 9992 9228 3288 ]0,00 ' I ~ ;~J }~¢~ ' ~2~' ' ~- ~s~~, -~ ........... . - -~ ............ r .......... I -~--~_~---~ .......... ~ : ~ i~ ....... ~.~.~. ........ ' i ' .... ; ' 1 . ~- -~ ~.~ ~__ ~ . .,~ .... , ' -- I , ~=~ ........ ..... ' --~ ................ ¢ ..... I J t PRUDI-tOE BAY DRILLING GROUP - _ I) ~00 .', -ss z~ PLAN VlEX CLOSURE 3288 feet at Azimuth !15 ~5 ~ , ~ SCALE ....... : 1 inch = 400 [eet t ~ I ..... ] DRAXN. ' 061P2/94 ......................... , ,~ ...................................... i MarkerA) X8 Identification [~DO ~/SO E/~O i B) [~ BUltO 2.50/100 1500 0 0 : C) ENO OF 2.50 BUILD ?678 t25 266 - .. ~.- ~ ....... gl lO-g/4" CASING POINT Si6g ~ ~ El KOP DROP 1.~/100 7~72 It~3 F] ENO OF 1.50 8flOP 8759 1306 2782 O] 7-5/8" C~Stt';G POINI 9259 1343 ~ Il REFERENCE TO DEPI~; gO12 1~86 , ' J) ~0 999~ I397 2976 I ~ . ....... ' ~ .... ~ ~ ~ . ,.. , f': .... I 400 600 800 1000 1200 1400 lfiOO 1800 2000 2~00 2400 2E, OD 21]OD 3000 3800 3400 .r 'l i [Cn,.~dr~]] (c).q,3 Kl~r,5 ,31 f:,? ? ?6 PF I) WELL PERMIT CHECKLIST INIT CLASS WELL NAME GEOL AREA UNIT# PROGRAM: exp [] //~ dev~ redrll [] ON/OFF SHORE serv [] ADMINISTRATION .~PPR A , lo 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. Permit fee attached ................... Lease number appropriate ............... Unique well name and number .............. Well located in a defined pool ............. Well located proper distance from drlg unit boundary. Well located proper distance from other wells ..... Sufficient acreage available in drilling unit ..... If deviated, is wellbore plat included ........ Operator only affected party .............. Operator has appropriate bond in force ......... Permit can be issued without conservation order .... Permit can be issued without administrative approval. Can permit be approved before 15-day wait ....... ENGINEERING 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg..~ N 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............. ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid program schematic & equip list adequate · 25. BOPEs adequate .................. ~ i i~ N 26. BOPE press rating adequate; test to ~d>6~ s g N 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... .~~ 29. Is presence of N2S gas probable ............ · Y (3w GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y/N 31. Data presented on potential overpressure zones ..... 32. Seismic analysis 9f shallow gas zones ......... ~ N 33. Seabed condition survey (if off-shore) ....... /. Y N 34. Contact name/phone for weekly progress reports . . ./.. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: o , · CD Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. MICROFILMED Run 1' 13 - October - 1994 DIFLIACIZDLIC NIGR 7170 9953 WESTERN ATLAS Atlas Wireline Services Tape Subfile 2 is type: '~S TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD RUN 1 6285.00 K. RICHARDS SEE REMARKS M - 33 500292250400 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 21-OCT-94 RUN 2 RUN 3 6 liN 13E 1864 195 55.60 25.60 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 9.875 IREMARKS: DIFL/AC/ZDL/CN/GR. LOGS WITNESSED BY: 10.750 3175.0 9995.0 H. HAYWOOD & D. BUMGARTNER. CIRCULATION STOPPED AT 1900, 12-OCT-94. SP RETURN GROUNDED TO THIS WELL. MAXIMUM BOREHOLE DEVIATION IS 31.2 DEG AT 5987'. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, CALIPER CORRECTED, CHISM FILTERING IS ACTIVE, CASING CORRECTIONS OFF, SALINITY = 0.00 PPM. PER CLIENT'S REQUEST, BOREHOLE & TORNADO CHART CORREC- TIONS WERE APPLIED TO THE DIL DATA. THE DIL DATA WAS CALIPER CORRECTED. THE CORRECTED DATA WAS THEN USED IN THE ATLAS TORNADO CHART TO GET "RT" & "DI" CURVES. RT = TRUE FORMATION RESISTIVITY. DI = DEPTH OF INVASION. DUE TO A COMPUTER MALFUNCTION, THE DATA FROM THE REPEAT PASS WA& ,OT RECORDED & IS THEREFOR. 3NAVAILBLE. FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; depth shifted and clipped curves; hole data. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 7170.0 9870.0 BCS 7224.0 9924.0 DIL 7252.0 9953.0 SDN 7195.0 9894.0 2435 7258.0 9876.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) B~ASELINE DEPTH LL8 7256.0 7268.5 7269.0 7280.5 7281.0 7281.0 7289.5 7290.0 7290.5 7297.5 7298.5 7303.0 7310.0 7311.0 7311.5 7314.5 7322.0 7325.5 7328.5 7330.0 7331.0 7331.5 7337.5 7342.5 7343.0 7352.0 7355.0 7358.0 7359.5 7360.0 7361.5 7364.5 7365.0 7369.0 7381.5 7386.5 7386.5 7387.0 7397.5 7398.0 7401.0 EQUIVALENT UNSHIFTED DEPTH ILD DT RHOB 7256.0 7268.5 7298.0 7299.0 7311.0 7312.0 7315.0 7330.5 7380.5 7281.0 7281.5 7289.5 7290.0 7325.5 7325.0 7332.0 7331.0 7342.5 7351.0 7342.5 7354.5 7357.0 7357.5 7359.5 7359.0 7362.0 7364.5 7397.0 7397.5 7401.0 7387.0 7386.0 all runs merged; NPHI 7269.0 7280.5 7290.5 7303.0 7310.0 7322.0 7328.5 7331.5 7338.0 7343.0 7359.5 7365.5 7369.0 no case 7410.0 7410.5 7424.0 7424.5 7439.0 7440.5 7444.5 7447.5 7451.5 7452.0 7452.5 7455.5 7456.5 7457.0 7467.0 7473.5 7490.5 7491.0 7500.0 7501.5 7507.5 7508.0 7516.5 7518.5 7522.0 7524.5 7528.5 7529.0 7538.0 7547.0 7557.0 7559.5 7563.0 7563.5 7597.5 7598.0 7604.5 7605.0 7627.5 7649.0 7673.5 7703.0 7704.0 7705.0 7717.0 7719.5 7765.5 7766.5 7803.0 7810.0 7810.5 7811.0 7811.5 7815.0 7815.5 7816.0 7816.5 7839.0 7840.0 7842.0 7424.5 7456.5 7501.5 7507.5 7556.5 7411.5 7424.5 7450.0 7450.5 7451.5 7465.0 7490.0 7491.0 7524.5 7538.0 7563.0 7563.5 7702.5 7703.0 7717.0 7803.0 7808.5 7809.5 7810.0 7811.0 7814.5 7815.5 7816.0 7817.0 7839.5 7840.0 7842.0 7409.5 7424.0 7455.5 7473.5 7501.5 7508.0 7516.5 7521.5 7528.5 7557.0 7597.5 7605.0 7673.5 7719.5 408.5 7423.5 7437.5 7447.0 7455.5 7500.5 7518.5 7529.0 7547.5 7556.5 7598.5 7605.0 7649.0 7766.5 7424.5 7440.5 7444.0 7447.5 7455.5 7473.5 7500.0 7508.0 7516.0 7528.5 7547.0 7556.5 7559.0 7597.5 7605.0 7627.5 7704.5 7765.5 7842.5 7845.0 7846.0 7852.0 7859.0 7871.0 7874.5 7875.5 7877.0 7893.5 7894.5 7911.5 7925.5 7926.0 7932.5 7933.5 7934.0 7953.5 7954.5 7955.0 7968.0 7971.0 7975.0 7981.5 7987.0 8004.0 8004.5 8008.5 8009.0 8019.5 8020.0 8021.0 8037.0 8039.5 8049.0 8060.5 8077.0 8081.5 8086.0 8087.0 8088.0 8095.0 8106.0 8106.5 8114.0 8116.0 8127.5 8128.0 8132.5 8133.0 8144.5 8145.5 8149.0 8153.0 8178.5 8179.0 8216.0 8224.5 8231.0 8240.0 7894.5 8048.5 8106.0 8133.0 8179.5 8216.0 8224.5 7843.0 7845.5 7846.0 7854.0 7859.5 7870.5 7874.0 7911.5 7925.5 7926.5 7933.0 7933.5 7934.5 7954.0 7954.5 7955.0 7967.5 7970.5 7975.0 7987.0 8020.0 8020.5 8060.0 8077.0 8082.0 8086.5 8087.0 8087.5 8114.0 8116.0 8125.5 8126.5 8144.0 8145.0 8231.5 8241.0 7876.0 7893.5 7981.0 8003.5 8008.5 8019.0 8049.0 8106.5 8133.5 8179.0 8224.5 7877.0 8005.0 8008.5 8019.0 8037.0 8039.5 8047.5 8094.5 8106.0 8132.0 8152.0 8178.5 8225.0 7894.0 7981.5 8004.0 8009.0 8019.0 8048.5 8106.5 8133.5 8149.5 8178.5 8224.5 8241.0 8242.0 8242.5 8250.5 8251.0 8257.5 8258.0 8264.5 8265.0 8274.0 8288.0 8305.5 8328.0 8345.0 8354.0 8361.5 8362.0 8364.5 8365.5 8366.5 8368.5 8369.0 8371.0 8372.5 8373.0 8373.5 8375.0 8378.0 8384.5 8385.5 8439.5 8456.0 8457.5 8467.0 8469.0 8469.5 8496.0 8496.5 8528.0 8535.5 8566.0 8566.5 8573.0 8573.5 8582.0 8587.0 8596.5 8599.0 8599.5 8601.5 8602.0 8610.5 8611.0 8651.5 8658.5 8692.0 8695.5 8696.0 8705.0 8706.0 8264.0 8305.0 8373.0 8439.5 8469.0 8566.0 8586.5 8596.5 8611.0 8242.0 8242.5 8243.0 8305.0 8364.0 8368.0 8369.0 8371.0 8384.0 8385.O 8457.5 8459.0 8566.5 8573.5 8610.0 8705.5 8250.5 8258.0 8264.5 8288.0 8305.5 8354.5 8361.0 8364.5 8372.5 8375.0 8439.5 8466.5 8566.5 8573.0 8587.0 8596.0 8599.0 8601.5 8611.0 8658.0 8691.5 8695.0 8250.0 8257.5 8265.0 8305.5 8354.0 8361.0 8373.0 8439.0 8468.0 8495.5 8565.5 8581.5 8586.5 8595.5 8601.5 8610.5 8651.0 8695.5 8706.0 8251.0 8264.5 8274.0 8305.5 8328.0 8345.5 8362.5 8366.5 8373.0 8378.0 8438.5 8469.5 8496.0 8528.5 8535.5 8566.0 8573.5 8598.0 8601.5 8611.0 8692.0 8696.5 8706.5 8707.0 8707.5 8709.5 8711.5 8714.0 8722.0 8722.5 8732.5 8735.5 8737.0 8739.0 8739.5 8740.0 8742.5 8743.0 8745.5 8746.5 8750.5 8751.0 8751.5 8754.5 8755.0 8765.5 8770.0 8793.0 8797.0 8801.0 8802.5 8804.0 88O5.5 8808.0 8808.5 8811.0 8811.5 8815.0 8821.0 8824.0 8824.5 8827.5 8830.5 8833.0 8835.5 8836.0 8858.5 8863.5 8869.0 8871.5 8872.0 8881.0 8881.5 8885.0 889O.0 8892.5 8896.5 8901.0 8911.0 8912.0 8912.5 8916.0 8711.5 8735.0 8739.5 8770.0 8805.0 8823.5 8830.5 8836.0 8863.5 8871.5 888O.5 8897.0 8706.0 8706.5 8707.5 8732.0 8746.0 8747.0 8750.0 8754.0 8755.0 8765.0 8796.5 8800.0 8803.0 8820.0 8824.0 8836.5 8857.5 8911.0 8912.0 8735.0 8739.0 8742.0 8750.5 8754.5 8770.0 8802.0 8805.0 8808.0 8811.0 8823.5 8830.5 8835.5 8863.5 8869.5 8872.0 8881.5 8912.0 8916.0 8712.0 8714.5 8721.5 8737.0 8792.5 8814.5 8826.5 8869.5 8881.0 8885.0 8890.5 8893.0 8901.5 8913.0 8709.5 8714.0 8723.5 8735.0 8737.0 8740.0 8742.5 8751.0 8808.0 8812.0 8826.5 8830.5 8833.5 8836.0 8864.0 8872.5 8881.0 8912.5 8916.5 8916.5 8922.0 8923.5 8927.5 8934.5 8935.0 8947.0 8947.5 8951.5 8954.0 8954.5 8957.0 8958.0 8961.5 8962.0 8963.0 8971.0 8977.5 8979.5 8993.5 8998.0 8998.5 9007.0 9012.5 9015.0 9017.5 9027.0 9045.5 9059.5 9066.5 9078.0 9078.5 9081.5 9098.5 9101.0 9101.5 9102.0 9103.5 9117.5 9118.0 9125.0 9125.5 9130.5 9134.0 9135.5 9138.0 9138.5 9141.5 9142.5 9143.0 9146.0 9147.5 9154.0 9154.5 9164.0 9164.5 9165.0 9166.0 9166.5 9167.0 8927.0 9118.0 9143.0 8920.5 8922.0 8956.5 8957.5 8961.5 8964.0 8965.0 9014.5 9017.0 9101.5 9102.0 9103.0 9104.5 9130.5 9138.0 9139.0 9142.0 9147.0 9148.5 9154.5 9155.0 9164.0 9165.5 9166.5 9167.5 8926.5 8935.0 8947.5 8954.5 8971.0 8977.0 8998.0 9007.0 9012.0 9077.5 9101.5 9118.0 9125.0 9143.0 516.5 8934.0 8954.5 8979.0 8997.5 9027.0 9059.5 9066.0 9078.0 9101.0 9133.5 9142.5 9163.5 8928.0 8935.0 8947.0 8951.0 8953.5 8980.0 8993.5 8998.5 9045.5 9060.0 9078.0 9082.0 9098.0 9117.0 9125.5 9135.5 9143.0 9165.5 9167.5 9169.0 9169.5 9176.0 9176.5 9180.0 9185.5 9186.0 9190.5 9192.5 9193.0 9200.5 9207.5 9208.0 9216.0 9218.0 9228.0 9230.5 9235.0 9251.0 9264.0 9264.5 9278.0 9282.0 9292.0 9298.0 9300.0 9301.0 9302.5 9304.5 9305.0 9311.0 9314.0 9330.0 9344.0 9346.0 9346.5 9348.5 9353.0 9360.0 9361.0 9361.5 9363.0 9366.0 9367.5 9369.5 9372.0 9374.5 9376.5 9377.0 9382.0 9384.5 9386.5 9389.0 9397.5 9398.0 9402.5 9403.0 9410.0 9416.0 9186.0 9311.5 9345.5 9348.5 9352.5 9369.5 9386.5 9388.5 9402.5 9415.5 9168.0 9264.0 9264.5 9298.5 9300.5 9301.0 9303.5 9311.5 9330.5 9348.5 9360.5 9361.0 9362.0 9363.5 9396.5 9397.5 9169.0 9186.0 9193.0 9207.5 9218.5 9229.0 9291.5 9301.5 9310.5 9346.0 9353.5 9367.5 9371.5 9375.5 9382.5 9384.0 9386.5 9389.0 9402.5 9410.0 9416.0 9170.0 9176.5 9180.0 9185.0 9192.5 9217.5 9228.5 9235.0 9250.5 9264.0 9291.0 9304.0 9310.5 9344.0 9353.0 9367.0 9376.5 9176.5 9186.0 9191.0 9193.5 9201.0 9208.0 9215.5 9228.0 9230.5 9278.0 9281.5 9292.5 9304.5 9311.5 9313.5 9346.0 9366.0 9375.0 9382.5 9384.5 9386.5 9403.5 9416.5 9430.0 9431.5 9433.0 9434.0 9442.5 9443.0 9445.5 9452.5 9453.0 9458.5 9460.5 9480.0 9481.5 9482.0 9482.5 9492.0 9495.5 9496.0 9497.5 9498.5 9503.5 9504.0 9511.0 9513.0 9524.0 9530.0 9535.0 9541.0 9547.5 9563.5 9570.0 9573.0 9581.0 9583.0 9596.5 9598.5 9603.0 9604.5 9605.0 9611.0 9615.0 9622.0 9624.5 9634.5 9639.0 9639.5 9642.5 9653.0 9659.5 9668.5 9676.0 9681.0 9691.0 9693.5 9713.5 9735.0 9755.0 9764.0 9769.0 9807.5 9433.0 9442.0 9458.0 9460.0 9495.0 9510.5 9563.0 9598.5 9615.0 9622.0 9681.5 9429.0 9430.5 9433.5 9442.0 9482.5 9483.0 9484.0 9498.5 9512.5 9596.5 9598.0 9602.5 9605.0 9639.0 9640.0 9668.0 9676.0 9692.0 9694.5 9764.0 9769.0 9434.0 9442.0 9452.5 9460.0 9495.5 9503.5 9530.5 9598.5 9625.0 9681.5 9714.0 9441.5 9444.0 9452.0 9458.0 9460.0 9479.0 9491.5 9495.5 9503.5 9510.5 9529.5 9534.5 9547.5 9569.5 9580.5 9583.0 9598.0 9604.5 9633.5 9642.5 9653.0 9660.0 9681.5 9691.0 9713.5 9734.5 9755.0 9443.5 9453.0 9499.0 9510.5 9523.5 9541.5 9573.5 9598.5 9611.0 9807.5 9810.0 98 ,0 9813.5 9814.0 9814.5 9815.0 9817.0 9818.5 9819.0 9823.5 9824.0 9824.0 9827.5 9827.0 9828.0 9828.5 9831.0 9838.0 9847.0 9856.0 9862.0 9863.0 9863.5 9867.0 9867.5 9868.0 9868.5 9869.5 9876.5 9877.0 9877.5 9878.0 9879.0 9887.0 9895.0 9910.5 $ MERGED DATA SOURCE PBU TOOL CODE GR BCS DIL SDN 2435 $ REMARKS: 9817.5 9819.0 9827.0 9827.5 9862.0 9863.5 9867.5 9868.0 9868.5 9869.0 9876.0 9877.0 9877.5 9878.5 9879.5 9894.5 9909.5 9824.5 9838.5 9813.0 9819.0 9824.0 9847.0 9856.0 9862.0 9868.5 9887.5 RUN NO. PASS NO. MERGE TOP 1 5 7170.0 1 5 7224.0 1 5 7252.0 1 5 7195.0 1 5 7258.0 MAIN PASS. MTEM, SP, TEND, & TENS WERE SHIFTED WITH LL8. ILM, RT, & DI WERE SHIFTED WITH ILD. CALl, DRHO, & PEF WERE SHIFTED WITH RHOB. FUCT & NUCT WERE SHIFTED WITH NPHI. 9813.5 9827.0 9830.5 9838.0 9863.0 MERGE BASE 9870.0 9924.0 9953.0 9894.0 9876.0 CN /??MATCH1.OUT /??MATCH2.OUT /??MATCH3.OUT /??MATCH4.OUT /??MATCH5.OUT $ : BP EXPLORATION : M - 33 : PRUDHOE BAY (ALASKA) COUN : NORT. SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 18 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR BCS 68 1 GAPI 4 2 DT BCS 68 1 US/F 4 3 TEND BCS 68 1 LB 4 4 TENS BCS 68 1 LB 4 5 LL8 DIL 68 1 OHMM 4 6 ILM DIL 68 1 OHMM 4 7 ILD DIL 68 1 OHMM 4 8 RT DIL 68 1 OHMM 4 9 DI DIL 68 1 IN 4 10 MTEM DIL 68 1 DEGF 4 11 SP DIL 68 1 MV 4 12 RHOB SDN 68 1 G/C3 4 13 DRHO SDN 68 1 G/C3 4 14 PEF SDN 68 1 BN/E 4 15 CALl SDN 68 1 IN 4 16 NPHI 2435 68 1 PU-S 4 17 FUCT 2435 68 1 CPS 4 18 NUCT 2435 68 1 CPS 4 4 67 465 06 6 4 84 653 71 5 4 20 789 90 0 4 20 789 90 0 4 50 746 76 1 4 50 746 76 1 4 50 746 76 1 4 50 746 76 1 4 50 746 76 1 4 50 746 76 1 4 50 746 76 1 4 22 779 91 0 4 22 779 91 0 4 22 779 91 0 4 22 779 91 0 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 72 * DATA RECORD (TYPE# 0) 994 BYTES * Total Data Records: 433 Tape File Start Depth = 9974.000000 Tape File End Depth = 7166.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 106724 datums TaPe Subfile: 2 1035 records... Minimum record length: 62 bytes Maximum record length: 994 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. ,RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 5 .2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7169.5 9880.5 AC 7224.0 9935.0 DIFL 7247.0 9964.0 ZDL 7194.0 9904.0 2435 7257.0 9887.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MODL GR CN ZDL TEMP KNJT KNJT PCM AC DIFL $ CABLEHEAD TENSION MODAL SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY TEMPERATURE KNUCKLE JOINT KNUCKLE JOINT PULSE CODE MODULATOR BHC ACOUSTILOG DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: 13-OCT-94 FSYS REV. J001 VER. 1.1 0 245 13-OCT-94 9995.0 9957.0 7300.0 9953.0 1800.0 TOOL NUMBER 3974XA 3517XA 1309XA 2435XA 2222MA/2222EA 2806XA 3921NA' 3921NA 3506XA 1603MA/1609EA 1503XA 9.875 3175.0 .0 LSND 9.80 36.0 9.1 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS. NO REPEAT PASS DATA AVAILABLE. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : M- 33 : PRUDHOE BAY : NORTH SLOPE : ALASKA 4 180.0 1.880 .632 1.560 .000 1.480 .000 THERMAL SANDSTONE 2.65 .000 1.5 56.0 180.0 56.0 .0 56.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 22 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 GR AC 68 1 GAPI AC AC 68 1 US/F CHT AC 68 1 LB TTEN AC 68 1 LB SPD AC 68 1 F/MN RFOC DIFL 68 1 OHMM RILM DIFL 68 1 OHMM RILD DIFL 68 1 OHMM VILD DIFL 68 1 MV RT DIFL 68 1 OHMM DI DIFL 68 1 IN TEMP DIFL 68 1 DEGF SP DIFL 68 1 MV ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 PE ZDL 68 1 BN/E CAL ZDL 68 1 IN CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S CN 2435 68 1 PU-L 4 4 06 969 49 6 4 4 48 852 89 1 4 4 95 558 30 1 4 4 95 558 30 1 4 4 61 094 30 1 4 4 27 515 24 6 4 4 06 213 78 0 4 4 04 903 06 0 4 4 04 522 10 6 4 4 04 903 06 0 4 4 06 213 78 0 4 4 40 467 34 0 4 4 53 419 67 0 4 4 52 443 33 1 4 4 09 884 61 1 4 4 76 731 33 1 4 4 24 115 90 6 4 4 98 211 23 1 4 4 98 211 23 1 4 4 52 326 75 5 21 LSN 2435 68 1 CPS 4 22 SSN 2435 68 1 CPS 4 * DATA RECORD (TYPE# 0) Total Data Records: 1022 1018 BYTES * , 84 023 70 4 83 368 34 88 Tape File Start Depth = 9974.000000 Tape File End Depth = 7166.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIs representation code decoding summary: Rep Code: 68 258360 datums Tape Subfile: 3 1106 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes Tape Subfile 4 is type: LIS 94/10/20 01 **** REEL TRAILER **** 94/10/21 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Fri 21 OCT 94 8:45a Elapsed execution time = 19.22 seconds. SYSTEM RETURN CODE = 0