The URL can be used to link to this page

Home My WebLink About191-049CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Not Operable: WAG Injector MPE-07 (PTD: 1910490) Not Operable due to being shut in for its 4-year MIT- IA Date:Wednesday, December 3, 2025 10:19:41 AM From: Stephen Soroka <steve.soroka@hilcorp.com> Sent: Wednesday, December 3, 2025 10:15 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: RE: Not Operable: WAG Injector MPE-07 (PTD: 1910490) Not Operable due to being shut in for its 4-year MIT-IA Mr. Wallace WAG Injector MPE-07 (PTD: 1910490) was made Not Operable on 11/24/25 for missing its 4-year MIT-IA. The well is now classified as Operable, and a witnessed MIT-IA will be scheduled once the well is stable. Please respond with any questions. Thank You Steve From: Stephen Soroka Sent: Monday, November 24, 2025 10:24 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: Not Operable: WAG Injector MPE-07 (PTD: 1910490) Not Operable due to being shut in for its 4-year MIT-IA Mr. Wallace WAG Injector MPE-07 (PTD: 1910490) is currently shut in and will not be brought online for its scheduled 4-year MIT-IA, due in November. The well is now classified as NOT OPERABLE and will remain shut in. A witnessed MIT-IA will be scheduled once the well is returned to injection. Please respond with any questions. Thank You. Steve Soroka Hilcorp Alaska LLC Field Well Integrity Steve.Soroka@hilcorp.com P: (907) 830-8976 Alt: Chris Casey The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Not Operable: WAG Injector MPE-07 (PTD: 1910490) Not Operable due to being shut in for its 4-year MIT- IA Date:Monday, November 24, 2025 10:28:07 AM From: Stephen Soroka <steve.soroka@hilcorp.com> Sent: Monday, November 24, 2025 10:24 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: Not Operable: WAG Injector MPE-07 (PTD: 1910490) Not Operable due to being shut in for its 4-year MIT-IA Mr. Wallace WAG Injector MPE-07 (PTD: 1910490) is currently shut in and will not be brought online for its scheduled 4-year MIT-IA, due in November. The well is now classified as NOT OPERABLE and will remain shut in. A witnessed MIT-IA will be scheduled once the well is returned to injection. Please respond with any questions. Thank You. Steve Soroka Hilcorp Alaska LLC Field Well Integrity Steve.Soroka@hilcorp.com P: (907) 830-8976 Alt: Chris Casey The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM TO: Jim Regg P.I. Supervisor 1 FROM: Bob Noble Petroleum Inspector I Well Name MILNE PT UNIT E-07 Insp Num: mitRCN211115131622 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, November 24, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp Alaska, LLC E-07 MILNE PT UNIT E-07 Sre: Inspector Reviewed By: P.I. Supry Comm API Well Number 50-029-22155-00-00 Inspector Name: Bob Noble Permit Number: 191-049-0 Inspection Date: 11/14/2021 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min - Well E-07 Type Inj W 'TVD 6993 Tubing ! 2575 2577 -' 2574 2573 PTD 1910490 Type Test � SPT 'Test psi i 1748 IA 154 2015 1954 i 1940 ' BBL Pumped: 2 BBL Returned: 2 OA Interval 4YRTST P/F P — - - Notes: Wednesday, November 24, 2021 Page I of I Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 10/01/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU E-07 (191-049) Injection Profile 06/25/2020 Please include current contact information if different from above. Received by the AOGCC 10/01/2020 PTD: 1910490 E-Set: 34018 Abby Bell 10/01/2020 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday,November 08,2017 Jim Regg ,p P.I.Supervisor ) � i!I V�i SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC E-07 FROM: Bob Noble MILNE PT UNIT E-07 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT E-07 API Well Number 50-029-22155-00-00 Inspector Name: Bob Noble 191-049-0Date: 11/7/2017 ✓ Permit Number: Inspection Insp Num: mitRCN171108051409 p Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well E-07 - Type Inj W TVD 6993 ' Tubing 1553 - 1551 1550 1549 PTD 1910490 Type Test SPT Test psi 1748 IA 45 2305 " 2261 2249 BBL Pumped: 3.2 BBL Returned: 3.2 OA 0 28 • 33 - 35 Interval 4YRTST P/F P ✓' Notes: %AWED Fi,P, 2 0 Wednesday,November 08,2017 Page 1 of 1 . . Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial They are available in the original file and viewable by direct inspection. I~ DLf1 File Number of Well History File TO DELETE X Color items - Pages: I 0 o Grayscale, halftones, pictures, graphs, charts - Pages: o Poor Quality Original -.pages: o Other - Pages: DIGITAL DATA o Diskettes, No. o Other, Noffype OVERSIZED X Logs of various kinds o Other COMMENTS: Complete ¡anna Vincent Nathan Lowell Date:í~1,O)lrJ .~ o TO RE-SCAN Notes: Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: Is! U MEMORANDUM To: Jim Regg ~~~~ ~ Z~ 12 ~ ~ `l P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, December 16, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC E-07 MILNE PT UNIT KR E-07 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~~' Comm Well Name: MILNE P7' UNIT KR E-07 Insp Num: mitCS091212141239 Rel Insp Num: API Well Number: 50-029-22155-00-00 Permit Number: 191-049-0 Inspector Name: Chuck Scheve Inspection Date: 12/11/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ Type Ind. i `v ~ TVD ~ 6993 ~ ~ IA ~ ! 380 T 2100 i 2000 1980 P.T.D~' 1910490 T eTCSt SPT ~ 'j'est Sl -------~------1- yp-------~--~------ p Interval anzTST p~F P 1748 i OA ~ -~--- ' Tubing 160 380 I ---- -- - z68o z6so t i 350 320 ~ - z6so ~z6so _~_ Notes: ~~~ Wednesday, December 16, 2009 Page 1 of I • • Page 1 of 2 Regg, James B (DOA) I~' "J ~ ~ (- ~~ From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Friday, December 11, 2009 11:18 AM ~~~ ~~ ~ h'~( To: Regg, James B (DOA); NSU, ADW Well Integrity Engineer Cc: Maunder, Thomas E (DOA) Subject: RE: Missing MITs ~. Attachments: PBU 12-19 (AIO 04C.013) AA Cancellation.pdf; MIT MPU E-07 05-25-09.x1s Jim, '- MPU E-07 (PTD 1910490) was pressure tested on 05125/09, however, our records do not show who the inspector o/ was on location. I have attached th_.e MITIA form for your review. The well is currently on water injection. PBU 04-10 (PTD 1760420) was reclassified as Not Operable on 11/07/09 due to a failing MITIA. A tubing patch was set on 12/07/09 to mitigate the TxIA communication. On 12/08/09, the well was placed on water injection for a state witnessed MITIA. PBU 12-19 (PTD 1821980) Our records show that AIO 4C.013 was cancelled on 09/14/07. I have attached the canceled AA for your reference. The well was worked over on 11/20/08 and placed on a 4 year MITIA schedule. It is currently on water injection. MPU E-03 (PTD 1890170) is scheduled for a witnessed by John Crisp today. I will provide you a copy of the MITIA form at the end of the month. It is currently on gas injection. PBU S-216 (PTD 2001970) was P&A'd on 12/11/07 and hasn't been injected in since 07/20/09. There are no plans to inject in this well in the near future. I hope this helps and please let me know if you need anymore information. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 ~~`~a From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, December 11, 2009 9:51 AM To: NSU, ADW Well Integrity Engineer Cc: Maunder, Thomas E (DOA) Subject: Missing MITs Following MITs are missing or late: MPU E-07 (PTD 1910490) due 10/16/2009 PBU 04-10 (PTD 1760420) due 11/19/2009 PBU 12-19 (PTD 1821980) due 12/6/2009 (AIO 4C.013) Followng MITs are due: MPU E-03 (PTD 1890170) due 12/12/2009 PBU S-216 (PTD 2001970) due 12/13/2009 12/11/2009 • Page 2 of 2 These wells are shown in our database as currently injection as of October 31; unfortunately our production/injection data lags a month so some or all of these may currently be SI. Please provide current status and, if MITs have been performed that satisfy the Commission's regulatory requirements, forward the test results. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 12/11/2009 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov tz~ti`Il~ OPERATOR: BP Ex loration (Alaska) Inc FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: p Milne Point /MPU / E Pad 05/25/09 Andrea Hughes Packer Depth Pretest Initial 15 Min. 30 Min. Well MPE-07 Type Inj. W TVD 6,993' Tubin 2,150 2,150 2,150 2,150 Interval 4 P.T.D. 1910490 Type test P Test psi 1748.25 Casin 2,500 2,460 2,450 P/F Notes: MIT-IA for 4 year compliance OA 0 0 0 0 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P~F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubin Interval P.T.D. Type test Test psi Casing P~F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11127/07 MIT MPU E-07 05-25-09.x1s MEMORANDUM ') State of Alaska ) Alaska Oil and Gas Conservation Commission TO: Jim Regg·VJ· . 11(0.1 )') P.I. Supervisor 1"¡é11 9C DATE: Monday, October 24, 2005 FROM: Chuck Scheve Petroleum Inspector SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC E-07 MILNE PT UNIT KR E-07 Src: Inspector \,..04"° ~ Reviewed By: P.I. Suprv ..Jßrz- Comm NON-CONFIDENTIAL Well Name: MILNE PT UNIT KR E-07 Insp Num: mitCS051016150717 Rei Insp Num API Well Number 50-029-22155-00-00 Permit Number: 191-049-0 Inspector Name: Chuck Scheve Inspection Date: 10/16/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well E-07 Type Inj. w TVD 6993 IA 310 2040 2000 2000 I --,-- -š6O---, P.T. 1910490 TypeTest SPT Test psi 1748.25 OA 360 560 560 I Interval 4YRTST P/F P Tubing I 2550 2550 2550 2550 I Notes ;SÇANNEt) NOV 1 7 2005 Monday, October 24,2005 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT<OFSUNDRY WELL OPERATIONS . 1. Operations performed: WAG SWAP 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address Operation shutdown_ Pull tubing __ Stimulate Alter casing 5. Type of Well: Development _ Exploratory_ Stratigraphic_ Service_X 8'ENL, 1868' FEL, Sec. 25, T13N, R10E, UM ofproductive interval FNL, 754' FEL, Sec. 30, T13N, R11 E, UM (asp's 569276, 601632(J) " (asp's 575665,6013951) (asp's 575523, 6013804) 898' FEL, Sec. 30, T13N, R11 E, UM total depth 4124' FNL, 947' FEL, Sec. 30, T13N, R11E, UM 12. Present well condition summary (asp's 575474, 6013754) . Plugging _ Repair well _ 6. Datum elevation (OF or KB RKB 58 feet 7. Unit or Property name Milne Point Unit 8. Well number MPE-07 9. Permit number / approval number 191-049 10. API number 50-029-22155-00 11. Field / Pool Milne Point Unit / Kuparuk River Sands Total depth: measured 8787 feet Plugs (measured) true vertical 7316 feet Effective depth: measured 8682 feet Junk (measured) true vertical 7238 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 80' 13-3/8" To Surface 114' 114' Surface 5039' 9-5/8" 72 bbls Clgss 'G', 172 5073' 4656' bbls PF 'E' Production 8770' 7" 81.9 bbls Class'G' 11961 ' 7329' Perforation depth: measured Open Perfs 8382'-8420',8452'-8484' true vertical Open Perfs 7019'-7046',7069'-7092'. Tubing (size, grade. and measured depth) 2-7/8",6.5#, L-80 EUE TBG @ 8334' MD. Packers & SSSV (type & measured depth) Otis TRSV SCSSV @ 567' MD, Otis HVT Packer @ 8344' MD. Otis BWD Packer @ 8427' Md. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Subsequent to operation 02/20/2003 15. Attachments classification as: Copies of Lpgs and Surveys run _ Daily Report of Well Operations _ Suspended - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. .A~~ J~ Title: Technical Assistant DeWa ne R. Schnorr Oil-Bbl Prior to well operation 02/14/2003 Water-Bbl 2517 Casinç¡ Pressure Tubinç¡ Pressure 2137 3295 Service WAG Iniector Date March 14.2003 Prepared by DeWa ne R. Schnorr 564-5174 BOMSBFl SUBMIT IN DUPLICATE Form 10-404 Rev 06/15/88 . . . MPE-07 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 02/17/2003 WAG SWAP: SWAPPED FROM WATER TO GAS INJECTION. EVENT SUMMARY 02/17/03 PJSM. SUPPORT ROLLED BLINDS TO LINE UP FOR GAS INJECTION AND TORQUED FLANGES TO SPEC. SERVICED TREE AND FLUSHED SENSING LINES. MIRU FESCO. PRESSURE TESTED TO 4100 PSI. PUMPED 20 BBLS METHANOL DOWN THE TUBING AT 2950 TO 2600 PSI @ 1.0 BPM, AND 2 BBLS METHANOL DOWN THE FLOW LINE FOR FREEZE PROTECT. RDMO. TURNED WELL OVER TO THE OPERATOR TO BE PUT ON INJECTION. WELL WAS CONVERTED TO GAS AND PUT ON INJECTION AT 3000 MCFPD. Fluids Pumped BBLS 22 METHANOL 22 TOTAL . State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy 0 Taylor cß DATE: December 10, 2001 Chairman ~ ~ SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder ~\ BPX P.I. Superviso c..~~' MPU-E Pad "Q((.; E-03 & E-Oi Lf- q FROM: Chuck Scheve MPU t ,1 I' 0 Petroleum Inspector Milne Point ~ -I NON- CONFIDENTIAL . MEMORANDUM 4 P 4 P Type Test M= Annulus Monitoring P= Standard Pressure Test R= Intèmal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover 0= Other (describe in notes) Test's Details I traveled to BPXs E Pad in the MPU and witnessed the 4 year MIT on wells E-03 and E-07. The pretest tubing and casing pressures were observed and found to be stable. The casing was then pressured up and observed for 30 minutes with both wells demonstrating good mechanical integrity. M.I.To's performed: ~ Attachments: Number of Failures:i Total Time during tests: 3 hours ~ F!: 6 :2. l..lJtfðb M IT report form 5/12/00 L.G. MIT MPU E-03 & E-07 12-10-01 CS.xls 12/13/01 ql\..-lft . . ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION ~ GR/COLLAR FINAL BL Ã SBT/GR/CCL FINAL BL 1 GR/COLLAR RF SEPIA 1 SBT/GR/CCL RF SEPIA / MPL-14 \ MPL-14 1 COLLAR/PERF FINAL BL ../1 SBT!GR/CCL FINAL BL /1 COLLAR/~~RF RF SEPIA 1 SBT/GR/CCL RF SEPIA ~PFC/CCL FINAL BL /l PRESSURE FINAL BL 1 PFC/CCLRF SEPIA 1 PRESSUERF SEPIA 0\- L¥-\ MPE-7 C1l-"5Ü MPE-08 ./Í COLLARI.OG FINAL BL 1 COLLAR LOG RF SEPIA Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: Please sign and re1iurn to: Petrotechnical Da1ia Center BP Exploration (Alaska) Ino 900 East Benson Boulevard Anchorage, Alaska 99508 Received by Date Date: 25 May 1994 RE: Transmittal of Sent by: U.S. MAIL ECC No. Run .Jl 1 tr Run # 1 Run .Jl 1 tr Run .Jl 1 tr Run .Jl 1 tr Run .Jl 1 tr Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 6205.00 6205.01 6199.00 ~~~): ;k000 I ~f~ 1'" ç(" Â" \. '" I Vl:#'\ ~ , I, (.J "" ..;....I 1. ...../// .. ~., ,:i! Date: tJ /" '..,~~~ ·.JO" ~·'Í'r",··.s: /"I 'qr. "0 ·1'0 ¿~?7 . '- !.s>,," eN!..,,, q{~~{ on: . SCHLUMBERGER WELL SERVIC. A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPoRATION HOUSTON. TEXAS 77251-2175 SEP 2 8 1993 Conaco, Inc. ~O['J~r Street, Suite 305 Anchorage, AK 99503 Attention: Dorothy Bourbeau Gentlemen: Enclosed are~I._prints of the Company_Conocº-, Inc. Well Field_ MjJ,mLf_QJ.nt Additional prints are being sent to: _L1Ll.p r ints _ ConQco.!. Inc. ---ºOO Nor tlLQª-.!ry Ashford Houston. TX 77079 -.Att~_~9I:gJ;L1.amÞ~OF 20 llLE_fL- Injection Survey, Run 1, 9/22/93 I tv -s; 1i?£J7l:V /1:BrvfI ¡ foR.I eel- MPU E-7 I I ~ \ ~()..'i':)- 8'''D~ County North Slope State Alaska :5 I' 1 BL prints, 1 RF Sepia Chevron Production Co~~nY 1301 McKinney Houston. TX 77010 ~n: Gary Forsthoff 713/754-5618 ~-prints, 1 RF Sepia ~ U.S.A.. Inc. 6 Desta Drive, Sllit~_02 Midland. TX 79705 Attn: John Carrol -915j1iR5-:05.BO '\ ----..----.- _LIL4:>rints ~ll.J)co. Inc. -.lQ.O.Q...S.o.ut.h Pine ~.Q.nJ;:.a.~j,~ty~-ºlL-1.4f¡.o2.::l2 67 ~.At.tllL......J.ane~L.w..ehb..-llJ9JB~ -----------.-- ~-,------------- -.l....BlpßA~, 1 RF Sepia .-AJ.aš--'ka OiL..&Jìas Conservat.· ~ommission _200Lf.Qrcu,ILine Drive _ A~~horag~~ AK 99501 Larry Grant prints pri t .prints RECEIVED SEP 3. 19 .. 9j Alaska 01/ & Gas Cons C Anc/¡orag~ ommission ~ - The film is returned to ConocQ, Dorothy Bourbeau Rece;ï~ ;þ cv G4-5 Da e: We appreciate the privilege of Very truly yours, SCHLUMBERGER WELL SERVICES Raymond N. Dickes DISTRICT MANAGER 5WS- 327·F CH (7 BL/3 RF) ALASKA OIL AND GAS CONSERVATION COMMISSION July 26, 1993 William L Brister Div Mgr Explor Prod NA Conocolnc 3201 C St Ste 200 Anchorage, AK 99503 Re: WAG project" MPU E"7 Dear Mr Brister: ~LTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501·3192 PHONE: (907) 279·1433 TELECOPY: (907) 276-7542 cn ,+, This is in response to your correspondence of pilot Water Alternating Gas (yVAG) project a procedural modification in the injection in Milne Point Unit by Area Injection Order NO.1 (MPU E-7) is in compliance with all Commission Accordingly, under the authority of AIO No. 10, t WAG project for the Milne Point Unit. esting approval to initiate a ur proposal involves ced recovery operations ell you intend to use for this project ents for Class II injection wells. mission approves Conoco's pilot In order to maintain the integrity of our well reco Operations, Form 10"104, upon completion ofth lease submit a Report of Sundry Well version. We appreciate Conoeo's efforts to improve oil recovery at Milne Point, and will be interested in your evaluation of the project's effectiveness. rpc/jo 1'1 · William L. Brister Division Manager Exploration Production, North America July 14, 1993 Mr. David W. Johnston Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Mr. Johnston, Conoco Inc. 3201 C Street, Suite 200 Anchorage. AI< 99503 v..1 '7 / ~ (. / , 3 ~~ Attached is our request for initiating a pilot project for Water Alternating Gas 0NAG) injection at project involves converting Milne Point Unit water injection well E-7 to WAG injection. Please direct any questions or comments regarding this matter to Mr. Jim Hand at 564-7645. Your prompt attention and approval is appreciated. Sincerely, William L. Brister Manager cc: JRH, TJY · Interoffice Communication TO: FROM: DATE: SUBJECT: Tom Yeager Jim Hand July 13, 1993 Request to AOGCC to WAG [-7 submit the following [-7 WAG justification to the AOGCC: Conoco requests approval to implement an immiscible water alternating gas (WAG) injection project on the MPU [-7 well. The purpose for this work is to enhance oil recovery from the offset producers and better manage gas production. [-7 was converted to water injection in January 1993 to provide pressure support for the B-21 and [-6 offset producers. These three wells are fault separated from the rest of MPU'sproducers and injectors (figure 1). [-7 is completed as a single selectiveiiin/ithe MK-l and MK-2 sands to allow zone isolation. Both the offset weHsQjlproduction have increased as a result of water injection in [-7. pnMay 22nd after 3 1/2 months of water injection, a injection profileis(u;rveywas run in [-7 (attachment 1). At the stabilized injection rate.of3()~()iaWPD, the survey indicates 61% of the water is entering a 6' intervaln~ªrthetop of the MK-2. The remaining water is entering a 10' interval attheþ¡¡se of the MK-l via the injection mandrel. As of yet, the high perm strea.kirtthe MK - 2 has not adversely impacted the offset producers. Gas injecliQnirato the base of the MK-l should improve vertical sweep efficiency. Arco Kuparuk has publisheda~øchhica.T paper (JPT May 1989) which confirms the vi abil ity of the immi scibleW~G.process. The Kuparuk sands extend from Arco Kuparuk up through Milne PQi~~.log and core descriptions indicate the sands are very similar. Thereii§iinoiireason why a WAG project at Milne Point would not see the same success¡¡s~rç.oKuparuk. Arco's study indicates the gas improves the vertical sweep effi.çiency, repressurizes the reservoir more qui ckly, and reduces the water-oiT<rª~jiQ .as a function of recovery. Thi s may result in a 2-5% increase inuTtimat~/recovery of the original oil in place. Conoco has reviewed three of<~rçoTsiiP1miscible WAG drill sites (2B, 2X, and lR). Our analysis indicates that Qnly 40% of the 36 BCF injected has been produced back vi a offset producers.. Thi s means 60% of the gas is bei ng stored in the reservoir. The aver~~eGas-Liquid Ratio (GLR) after gas breakthrough was 674 SCF/STB. The m~><iP14nlGLR for an individual well was 4200 SCF /STB. The cyc 1 i c GLR' s.º~X~~i~eemed to hinder Arco' s abil ity to the wells. In the m¡¡jQri~y()fthe wells the cycled gas acts as a lift source. proposes to start the immiscible WAG process fairly conservatively a 2: 1 WAG ratio. Due to the high perm streak it will Gons~ Anchorage · 2 limit the amount of gas entering the MK-2. Arco Kuparuk's "rule of thumb" in their C-3/C-4 Sand high perm streak is to inject 2.5% of the total sands movable pore volume. For the other sands, Arco typically injects 5% of the movable pore volume on the gas cycle. Initially Conoco plans to follow the same guidelines. E-7 is currently injecting 2700 BWPD at 2860 psi wellhead pressure into the MK-l sand. On June 20th a plug was set to isolate the MK-2 in order to increase the water injected pore volume in the MK-l sand. Based on the injection profile survey, about 266 MBW has been injected into the MK-2 or 7.7% of the movable pore volume. As of July 12th about 228 MBW or 10% of the pore volume had been injected into the MK-l. Prior to start-up of first gas injection cycle, Conoco plans to reopen the MK-2 and re- establish water injection into both sands. When the WAG facility hook-up is completed in late July both the reservoirs will have had sufficient amounts of water injected to satisfy the 2:rWAG ratio criteria. At this point, we would plan to switch E-7 to gas andtnject about 5.6 MMCFPD for one month, run a plug to isolate the MK-2 and cpntinue to inject gas into the MK-l for another 1/2 month at the same rate. Thi s equates to about 2.5% of the movable pore volume (86 MRB) in the.MK-2 and 5% of the movable pore volume in the MK-l (114 MRB). We would then switch back to water injection in the MK-l for 2 month period at 2700 BWPD. Tþe plug would then be pulled and water injected into both sands for another} 1/2 months. If no adverse effect is seen at the offset producer$, tÞ~...next cycle would be at a 1:1 WAG ratio. Ultimately, our goal is to g~ttQiaO.5 WAG ratio. In summary, Conoco feels theWAGprQcess will aid significantly in handling produced gas at Milne Point while at the same time potentially improving performance and ultimate recovery from the offset producers. We are pursuing the pilot WAG project with caution and will take the appropriate action to minimize the risk to existtnqproduction. Conoco will monitor the performance and make modificatiQosto the WAG ratio as necessary. Conoco's plans are consistent with accept.edpractices which are being applied by Arco in their WAG process. If successful, the WAG process holds future potential for other areas of Milne Point. /--"- James R. Hand Senior Reservoir Engineer cc: Gas Handling Team, Team, fil e I ~ 2880.80 FTIIN E 7 RRER KUPRRUK STRUCTURE - ANCHORAGE M~ 13-JUl-B3 (conoco) .noco Inc. Anchorage Division To Larry Grant Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 (907)279-1433 o Under Separate Cover Iii!' Enclosed Subject Quantity Contents .cord of Shipment of Confidential Information From Date June 10 1993 Steve Davies Conoco Inc. 3201 C Street, Suite 200 Anchora e, Alaska 99503 (907) 564-7640 Via Petroleum Couriers -7 Final Drilling & Completion Report -7 Core Analysis Report -7 Sidewall Descriptions -2 Final Drilling Report -3 Final Drilling Report -4 Final Drilling Report 1-1 Final Drilling Report 1-2 Final Drilling Report -3 Final Drilling Report 1-3 No Whole Core or Sidewall Cores taken as noted on completion report. 1-4 Final Drilling Report -4A Core Analysis Report tJ-1 Final Drilling Report d-1 Core Analysis Report -1 Core Description Report -2 Final Drilling Report -2 Completion History - Final Drilling Report -4 Final Drilling Report - Final Drilling & Completion Report -8 Final Drilling & Completion Report -9 Final Drilling & Completion Report - Core Description Report -9 Core Analysis Report RECEIVED JUN 1 1 1993 Alaska Oil & Gas Cons. Commission Anchorage Received By Signed By Date mptly by signing and returning second copy. Date Remarks Transmittal Copy Only To (' MAY 2 6 1993 PLEASE REPLY TO SCHLUM8ERGER WELL SERVICES Pouch 340069 Prudhoe Bay. AI< i . . SCHlUMBERGER WEll SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 77251-2175 Conoco. Inc. 3201 "C" Street. Suite 200 Anchorage. AK 99503 Attention: Linda Starr Gentlemen: Enclosed ore 3 BLprintsofthe Water Flow Log/Production Log, Run 1, 5/22/93on: Compony Conoco Inc. Well Milne Point Unit E-7 Field Milne Point Additional prints ore being sent to: 1 BL prints Conoco. Inc. 600 North Dairy Ashford Houston, TX 77079 Attn: Geor~e Lamb. OF 2018 PI orth Slope Stote Alaska 1 BL prints . 1 RF Sepia Chevron U.S.A. 11111 South Wilcrest Houston. TX 77099 Attn: Larry Sydora 713/561-3674 1 BL prints Conoco. Inc. 1000 South Pine Ponca City. OK 74603 Attn: Glenn Welch. 7391 RW 1 BL prints . 1 RF Sepia OXY U.S.A., Inc. 6 D~~ta Driv~, ~lIitp 600' Midland. TX 79705 Attn: John Carrol 915/685-5898 prints prints 4l~ <~[;f/VË/) Oil ~ /9g Gci'$ c. 'J -itJcho/: Oils. ~ We.- ~. z"S; . u. ~IJ The film is returned to Conoco. Linda Starr Received bY'~~ Date: We appreciate the privilege of servingy()l,J. Very truly yours, SCHLUMBERGER WELL SERVICES ~a~ol1.d:..N. Dic.~es OISTRICT M.NAOI_ sws- 132" OH/CH (11 BL/3RF) Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503-3999 (907) 564-7600 . January 22, 1993 Mr. Blair Wondzell Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: REPORT OF SUNDRY WELL OPERATIONS Dear Mr. Wondzell, Attached is the Report of Sundry Well Operations, Form 10-404, for converting Milne Point Unit Well E-7 from an oil producer to a water injector. Water injection into E-7 was commenced on January 19, 1993. Please direct any questions or concerns regarding this form to me at 564-7660. ~IY~ Tom Yeager SHEAR Specialist Att: cc: CVL, JLA, T JY Chevron Occidental E-7 Well File ~ · STATE OF ALASKA ...' ALA~OIL AND GAS CONSERVATION COMMI«>~ REPORT OF SUNDRY WELL OP Type of Request: Operation shutdown _ Pull Tubing Stimulate Alter casing Name of Operator Conoco Inc. 3. Address 3201 C Street, Suite 200 Anchorage, AK 99503 4. Location of well at surface 1493'FNL, 1877'FEL, Sec. 25, T13N, R10E, U.M. At top of productive interval 3929' FNL, 754' FEL, Sec.30, T13N, R11E, U.M. ~t~ffective depth ~'f'~I>\~~t..,S9a'FEL, Sec.30, T13N, R11E, U.M. Attot$1 depth 4124' FNL, 947' FEL, Sec.30, T13N, R11E, U.M. 12. Present well condition summary Total depth: measured true vertical 8787' feet 7316' feet Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: Length Size 80' 5039' 13-3/8" 9-5/8" 8770' 7" Alter casing _ Repair well Other X 5. Type of Well: Development ..L Exploratory _ Stratigraphic _ Service 6. Datum elevation (DF or KB) 58' KDB 7. Unit or Property name Milne Point Unit feet 8. Well number E-7 9. Permit number/approval number 91-49/92-221 10. API number 50-029-22155 11. Field/Pool Kuparuk River Field Plugs (measured) Measured depth True vertical depth To Surface 72 bbl Class G 172 bbl Permf E 81.9 bbl Class G 114' 5073' 114' 4656' 8804' 7329' measured 8382'-8420'; 8452'-8284' true vertical 7019'-7046'; 7069'-7092' Tubing (size, grade, and measured depth) 2-1/8" 6.5# /ft, L-80, fUE, 8rd, 8334'MD Packers and SSSV (type and measured depth) Otis TRSV SCSS\I@5ß7'MD, Otis HVT Paker @ 8344'MD, 13. Stimulation or cement squeeze summary Intervals treated (measured) None Treatment description including volumes used and final Prior to well operation (Prod.) $Qb~quent to operation (Inj.) 15. Attachments Oil-Bbl 227 Representative Dailv Avera9~>Pl'oductio~or Iniection Data Gas-Met Water-Bblc.sir¡9Prlitssure Tubing Pressure 70 227 280 275 2,000 150 1,290 Copies of Logs and Surveys run Daily Re ort of Well Operations X Suspended 17. I here certify that ~g is true and correct to the best of my knowledge. Title SHEAR SPECIALIST 14. 16. classification as: Service Water Injector Date 01-22-93 . Milne Point unit E-07 API No.: 50-029-22073 Location: Milne Point Field - E-07 Convert Producer To Water Injector 11-12-92: 11-13-92: 11-14-92: MOBILIZING RIG TO I-4A . . Finish Rig Up. Replace Pump Hoses and valve on choke manifold. Nipple up BOP. Screw into hanger wjlanding joint. Tighten up landing joint and pressure up on pipe rams due to gas leakage. Repair check valve going to main pump. Pressure up again, BPV apparently leaking. Bleed off gas below BPV and retrei ve landing joint. Close blind rams and pump 61 BBLS down tubing. Pull BPV and replace with two way check. Note: A piece of rubber caught in BPV. Test BOP's and related equipment to 250/5000 psi. Pull two way check valve. Fill Backside, release hanger, pressure up to 200psi and release packer with 120k. Note pressure increased to 300psi. Bleed gas off backside and circulate 25 gel BBL pill plus 497 BBLS of source water returns of 247BBL5.. Monitor well. Pull Hanger to Rig Floor. Pull to SSSV, LD sssv ,j?'k-)::'., >~ GLM. Change cable spools and POOH 1 / down tubing. Ljd.ÔW:n<ESP. Empty pipeshed and load tubing and packer in shed. Rig up loggers and RIH with Gauge Ring set down at 8250' wo)::''k-ed down to 8450'. POOH and recover 6 bands. RIH wjgauge )::'it).9<t08450' and recover 1 band. RIH with packer and set same~rt8424'. Rig down loggers. Hold safety meeting and>ireview tubing running procedure. RIH with seal assembly, 2-1/16" GLM and packer. Center derrick over hole. RIH with 248 joints tubing, SSSV and total of 249 joints of tubing. Set down on joints #130 and #218. continue to pick up tubing on joint #265 stabbed in. Review tally SSV 4' to high. POOH and lower sssv 1 joint RIH. Tie in control line & test. Rig up sliçkline and set plug in x-nipple below packer, POOH wjslick lin~..pump packer fluid 195 BBLS. Pump 60 BBLS diesel did not .exceed 700psi. Pressure up to set packer. NOTE; at 0800 hc)'u.:r's packer did not set suspect x- nipple set above.pé.\çlç~J;'. R/U slickline and<:ret:r'i(åve(iplµ.g. Redress plug and RIH - stacked out at SCSSV. POOH, left plug in SCSSV. RIH and latch plug and POOH and redres$plug. RIH and set plug at 8355' (2nd attempt). Test tubing to30QO psi and backside to 2300 psi for 30 minutes - MIT Test. Ret:r'ieve plug, close SCSSV, and set BPV. N/D BOP's and N/Ut:r'eeand test. Pull BPV and set 2-way check valve. Tree would:nottest (control line feed through stripped on wellhead $P901)i. NjD tree, pull control line out of spool, tap threadst>.~:ndN/utree. Test tree to 5000 psi - OK. 11-15-92: Preparing to move :r'igitp«<::r-4A well. clearance. Waiting on location · STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well ¡,.u.. OIL ~ GAS [J SUSPENDED D ABANDONED D 7. Permit Number 2. Name of Operator Conoco, Inc. 91-49 3. Address 3201 C Street, Suite 200, Anchorage, AK 8 API Number 50- 029-22155 1493' FNL, 1877' FEL, SEC-25, T13N, R10E, V.M., At Top Producing Interval 9. Unit or Lease Name Milne Point Vnit 4. Location of well at surface 10. Well Number 3929' FNL, 754' FWL, SEC-30, T13N, RIlE, V.M., At Total Depth 4124' FNL, 947' FWL, SEL-30, T13N, RIlE, V.M., AK E-7 11. Field and Pool 5. Elevation in feet (indicate KB, OF, etc.1 KB 35" AGL 6. Lease Designation and Serial No. ADL 28231 Kuparuk 13. Date T.D. Reached 07/11/91 14. Date Comp., Susp. or Aband. 07/16/91 16. No. of Completions 1 18. Plug Back Depth (MO+TVD) 19. Directional Survey 8682'MD/7238'TVD YESKJ NoD Type Electric or Other Logs Run - LDT - CNL - MSFL - NGT - AMS - GR - RFT - GCT CASING, LlNERAND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13 3 8 54.4 K-55 Surface 80' 30" 600sx Permafrost "c" 9 5/8" 36 K-55 Surface 5039' 12 1/4" 480sx "E" 350sx "G" 7" 26 L-80 Surface 8770' 8 L2" 400sx "G" 8382' - 8420' MD 12 SPF, 21gm, 609 7019' - 7046' TVD 8" TUBING RECORD DEPTH SET (MD) PACKER SET (MD) 832 ' + 24. Perforations open to Production (MD+TVD of Top and interval, size and number) 8452' - 8484' MD 12 SPF, 21 gm, 609 phsq 7069' - 7092' TVD ACID. FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED None 27. I Date First Production 10/03/91 PRODUCTION Method of Operation (F lowing, gas lift,etc.) ESP Date of Test Hours Tested PRODUCTION FOR OIL·BBL TEST PERIOD. CALCULATED OIL-BBL 24-HOUR RATE. GAS-MCF WATER-BBL CHOKE SIZE GAS·OIL RATIO Flow Tubing Press. Casing Pressure GAS-MCF WATER·BBL OIL GRAVITY·API (cord 28. CORE DATA of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. reservoir quality rock containing hydrocarbons in Submit in duplicate Rev. CONTINUED ON REVERSE SIDE MAR 8089' 6704 (-s.s. Middle Kuporuk 8368' 6899 (-s.s. Laminated Zone 8488' 6983 (-s.s. , I 4 "". .. . . MILNE POINT UNIT E-7 FINAL DRILLING & COMPLETION REPORT CONOCO, INC. AJ:':!1t'lw~ " ·£:""I'£IIOJ/IIt", , 1M ¡¿"'.S' ""Ii' G. ~~. ~Orll ,¡ AJU;/¡Or¡ilg~ . ,m,ss/em , PTD: 8565' WELL: MPU E-7 '1/ / 0 t.\ q FIELD: KUPARUK CASING: 133/8" @ 111' 7" @ 8770' 9 5/8" @ 5039' CURRENT TD: 8787' DATE: 06/29/91 : 06/30/91 : 07/01/91 : 07/02/91 : 07/03/91 : 07/04/91 : Description of Operations: Move rig from well E-6 to E-7, nipple up diverter, mix spud mud, caliper and strap BHA. Program MWD and MPT, function test diverter and knife valve. Drill from 105' to 135'. POOH lay down motor and change from 2 cone bit to three cone bit and packed rotary assembly. Re-program MWD/MPT and RIH. Drilled from 135' to 1475'. Short tripped to collars with no problems. Controlled drill from 1475' to 2296' to handle cuttings. Circulated thick clays and clay balls at 1700'. Added soap to prevent balling. Gas cut mud at surface 7.3 ppg. Shut -in and checked for flow. No flow. Circulate and conditioned mud until MW in equalled MW out (9.3 ppg). Drilling ahead. Drilled from 2296' to 2452'. CBU. POOH for directional BHA. P/U stab., motor and two cone bit. TIH to 2452'. Drilled from 2452' to 2585'. Ream build section. Drilled from 2585' to 3340'. Sperry Sun MWD unable to decode logging and directional data due to amplitude problems created downhole. Dropped SS survey to confirm MWD data - OK. POOH. Change orifice in MPT tool from 8/32" to 16/32" and reprogram MPT tool. TIH. Finish TIH to 3340' - no fill. Drilled from 3340' to 4316'. Short trip. Drilled from 4316' to 4970' - 9-5/8" casing point. Circulate and condition mud. POOH for conditioning trip. Finish short trip - no fill. C & C. POOH. R/U Schlumberger and RIH with 4 arm caliper from 4970' to 13-3/8" shoe at 115'. Pulled caliper tool out of rope socket while entering shoe. RIH with overshot and latch fish at 106'. POOH with fish (caliper tool) and LID same. RIH with sidewall cores (SWC's) to 138' - tagged up. Attempt tpget below 138' several times with SWC's - unsuccessful. M/U 12-1/4" bit, stabili~era...d 1 stand of DC's and TIH to 138'. Wprked bit past 138' with 8,000# WOB and RIH to 1150'. Circulate Borke Coal chunks out of wellbore. Circulate until clean and POOH. R/U Schlumberger and RIH with SWC's. Shot 45 SWC's and recovered 27 - left 18 core barrels in the hole. M/U bit and TIH to 4910'. Ream hole from 4910' to 4970'. Drill from 4970' to 5057' attempting to move junk out of hole. C & C. POOH and LID 12-1/4" BHA. Run 117 joints of 9-5/8", 36 ppf, K-55,BTTS casing to 5039' (FS), FC at 4952' . R/U Halliburton and pump 70 bblsvvater, 480 sx (172 bbls) of class "E" at 12.3 PPG + ."". ... . . MILNE POINT UNIT E-7 FINAL DRILLING REPORT OPERATOR: CONOCO, INC. MPU E-7 FIELD: KUPARUK PTD: 8565' CASING: 133/8" @ 111' 9 5/8" @ 5039' 7" @ 8770' CURRENT TD: 8787' DATE: 06/29/91 : 06/30/91 : 07/01/91 : 07/02/91 : 07/03/91 : 07/04/91 : PROGRESS 0 Description of Operations: Move rig from well E-6 to E-7, nipple up diverter, mix spud mud, caliper and strap BHA. Program MWD and MPT, function test diverter and knife valve. Drill from 105' to 135'. POOH lay down motor and change from 2 cone bit to three cone bit and packed rotary assembly. Re-program MWD/MPT and RIH. Drilled from 135' to 1475'. Short tripped to collars with no problems. Controlled drill from 1475' to 2296' to handle cuttings. Circulated thick clays and clay balls at 1700'. Added soap to prevent balling. .Gas cut mud at surface 7.3 ppg. Shut -in and checked for flow. No flow. Circulate êll1dconditioned mud until MW in equalled MW out (9.3 ppg). Drilling ahead. Drilled from 2296' to 2452'. CBU. POOH for directional BHA. P/U stab., motor and two cone bit. TIH to 2452' . Drilled from 2452' to 2585'. Ream build section. Drilled from 2585' to 3340'. Sperry Sun MWD unable to decode logging and directional data due to amplitude problems created downhole. Dropped SS survey to confirm MWD data - OK. POOH. Change orifice in MPT tool from 8/32" to 16/32" and reprogram MPT tool. TIH. Finish TIH to 3340' - no fill. Drilled from 3340' to 4316'. Short trip. Drilled from 4316' to 4970' - 9-5/8" casing point. Circulate and condition mud. POOH for conditioning trip. Finish short trip - no fill. C & C. POOH. R/U Schlumberger and RIH with 4 arm caliper from 4970' to 13-3/8" shoe at 115'. Pulled caliper tool out of rope socket while entering shoe. RIH with overshot and latch fish at 106'. POOH with fish (caliper tool) and LID same. RIH with sidewall cores (SWC's) to 138' - tagged up. Attempt to get below 138' several times with SWC's - unsuccessful. M/U 12-1/4" bit, stabilizer and 1 stand of DC's and TIH to 138'. Worked bit past 138' with 8,000# WOB and RIH to 1150'. Circulate Borke Coal chunks out of wellbore. Circulate until clean and POOH. R/U Schlumberger and RIH with SWC's. Shot 45 SWC's and recovered 27 - left 18 core barrels in the hole. M/U bit and TIH to 4910'. Ream hole from 4910' to 4970'. Drill from 4970' to 5057' attempting to move junk out of hole. C & C. POOH and LID 12-1/4" BHA. Run 117 joints of 9-5/8", 36 ppf, K-55, BITS casing to 5039' (FS), FC at 4952'. R/U Halliburton and pump 70 bbls water, 480 sx (172 bbls) of class "E" at 12.3 PPG + .., tJ... 07/05/91 : 07/06/91 : 07/07/91 : 07/08/91 : 07/09/91 : 07/10/91: 07/11/91: 07/12/91: 07/13/91 : 07/14/91: 07/15/91 : 07/16/91 : . . 350 sx (72 bbls) of class "G" cement at 15.8 PPG for first stage. Open HOS tool with 21 00 psi and circ. Pump 100 bbls water, 963 sx (346 bbls) of class "E" at 12.3 PPG + 50 sx (6 bbls) class "G" cement at 15.8 ppg for second stage. Displaced and bumped plug. N/D diverter and N/U BOP's. Test BOP's and choke manifold to 500/5000 psi. M/U 8-1/2" BHA and TIH to TOC at 1950'. Drill cement, HOS tool and cement to 2036'. TOC at 4903'. Drill cement to 4952'. Drill FC and cement to 5038'. Test 1500 psi for 30 min. - OK. Drill FS and 10' of new formation from 5057' to Perform LOT to 12.1 PPGe. Drill from 5067' to 5224'. POOH and P/U motor and PDC bit. TIH. Drill from 5224' to 5925'. POOH for bit change. TIH. Drill from 5925' to 6743'. Short trip. Drill from 6743' to 6996'. Lost 700 psi standpipe pressure - POOH for washout (1 joint of DP washed out). Replace joint and TIH. Drill from 6996' to 7023'. Drill from 7023' to 7883'. Drill from 7883' to 7893'. Short trip - no fill. Drill from 7893' to 8Q55'. POOH and L/D motor, MWD, and PDC bit. P/U insert bit and TIH to 8055' - nolv't::9rtl~J~om 8055' to 8089'. .,'0 I,. t ¡ý .,.% 'W Drill from 8089' to 8353'. Short trip - no fill. Drill from 8~R3' to ä41Ó' Ppqt;t,for new bit. 4~ii§i:l$Ji1;~:;y' ' /\~'i,::,ø¡J' Drill from 8374' to 8477'. Short trip - no fill. Drill from 8477' toBSø ife~~:,~nd condition. Short trip to shoe and condition hole for logs. Rig up loggers an(1JJGn DIL,LDT,CNL,MSFL, NGT,AMS. Run AMF, GR, RFT FROM 8190' TO 8464'. Drilled from 8598' to 8787'. Circulate and condition, short tripped 10 stands. Circulate and condition. Rig up casing crew and start RIH with 7" casing. Rig up and run 205 joints of 7", 26 ppf, L-80 casing to 8770' (FS), FC at 8683'. Pumped 50 bbls. 11 ppg setpiolite, 40 bbls. water, 81.9 bbls class "G" cement with additives and displaced with 337 bbls. produced water. Bumped plug, checked floats and pressure tested casing to 1,5()0 psig for 30 minutes. Rig down casing crew, install packoff and test to 5,000 ps.ig. Change rams to 3.5" and cleaned pits. Test BOP to 500 psig/5000 psig. Pickup .nd strap BHA and 3.5" drill pipe. Finish P/U 3.5" Dp and TIH to 8682' (FC). Reverse circulate brine until clean. POOH. R/U and run CCL-GR-GCT from PI¡TD to surface. P/U perforating guns and TIH. Finish TIH with perforating guns. FUH with GR-CCL correlating log. Displace DP with 61 bbls of diesel, set packer, and test packer to 500 psi. Perforate from 8382'-8420' and 8452'-8484' with an ISIP of70ipsi. Flowed 15 bbls for 1 hour then well stopped flowing. Reverse out diesel andoil.POPH and LID DP, packer, and perf. guns. Change rams to 2-7/8" and test bonnet set.ls to 2000 psi - OK. P/U electric submersible pump and RIH with 2-7/8" tubing. Run 242 joints of 2-7/8" 6.5 #/ft L-80 tubing. M/U packer, make splice in reda cable, M/U SCSSV and control line and RIH on 17 joints of 2-7/8" tubing to 8320' MD .... . . (bottom of ESP). M/U hanger, splice reda cable and freeze protect tubing and annulus with diesel. R/U slickline and set plug, set packer, test SCSSV, pull plug and test packer to 500 psi - OK. Install BPV. Circulate diesel out of tubing and annulus. 07/17/91: Sheared packer, POOH to packer. Rebuild packer, cut and splice ESP cable. and test control line. RIH with tubing and land at 8320' (bottom of ESP). Test hanger. Displace annulus with 60 bbls of 8.5 PPG brine with 12% Methanol and 5 bbls diesel. Set plug in X-nipple. Set and test packer - OK. Displace tubing with 12 bbls diesel. NID BOP's and N/U tree. Test wellhead and tree to 5000 psi - OK. Set BPV. Released rig at 2030 hrs on 07/16/91. RIG RECEIVED: SPUD DATE: 06/28/91 RIG: NABORS 27E " . -:c Sidewall Description~~ lC:%J/\f5:'::Ai'·'-, Conoco, Inc. """""/\1;* E-7 Well Milne Point Field ql-O'-{~ . II'Il' 4450 WEST 50TH AVENUE ANCHORAGE, ALASKA 99502 s Conoco, Inc. E-7 Well consol fluorescence. ; 1 sorted; ceous; carbonaceous fluorescence. poorly good odor; even s fluorescence. 4541.5 . , 4565.0 calcareous; streaks light-medium ; sl good odor; 4571. 0 lar; ; 1 brown; f f well sorted; poorly consol odor; even medium stain; carbonaceous fluorescence. 4572.0 ately sta gray; consol moder- odor; even medium 4572.5 well sorted; gold fluorescence. brown; fine ined; subrounded; moderately consolidated; good odor; even med stain; 4574.0 odor; ; ish tan; si; y consol medium sta gold fluorescence. fair 4599.5 consol fluorescence. g ish tan; silty; slightly sandy; poorly burrows; good odor; streaks medium stain; gold 4601.0 grayish brown; very fine lar; moderate well sorted; consol medium stain; gold fluorescence. odor; even 4618.0 ; brown; fine-f grained; subangu- lar-subrounded; well sorted; poorly consol ; good odor; even medium stain; gold fluorescence. 4620.0 As above. ..;/I ;,j¡i þ . '.~ E-7 Sidewall Descriptions, continued 4628.0 As above. 4629.0 As above. 4630.0 As above. 4734.0 Sandstone; brownish gray; very fine-fine grained; sub- rounded; moderately well sorted; poorly consolidated; trace glauconite; fair odor; even medium stain; gold fluorescence. 4734.5 Sandstone; grayish brown; very fine-fine grained; subangu- lar-subrounded; moderately well sorted; poorly consolidated; good odor; even medium stain; gold fluorescence. 4736.0 Sandstone; grayhish brown, fine grained; subrounded; well sorted; poorly consolidated; good odor; even medium stain; gold fluorescence. 4749.0 Sandstone; grayish brown; very fine-fine grained; subangu- lar-subrounded; moderately well sorted; poorly consolidated; trace glauconite; good odor; even medium stain; gold fluores- cence. 4750.0 As above. 4755.0 Sandstone; grayish brown; very fine grained; subangular- subrounded; moderately well sorted; poorly consolidated; trace glauconite; good odor; even medium stain; gold fluorescence. 4762.0 As above. 4808.0 Sandstone; grayish brown; very fine grained; subangular- subrounded; moderately we!.l sorted; poorly consolidated; fair odor; even medium stain; go1.di:fluorescence. 4821.5 Sandstone; grayish brown; fine grained; subangular; moder- ately well sorted; poorly cónSolidated; fair odor; even medium stain; gold fluorescence. 4823.0 Sandstone; grayish brown; very fine-fine grained; subangu- lar-subrounded; moderately well sorted; poorly consolidated; good odor; even medium stain; goldfluoréscence. 4824.0 Sandstone; grayish Þrown;.very fine-fine grained; moder- ately sorted; poorly consolidated; trace glauconite; good odor; even medium stain; gold fluores¢endce. 4825.0 Sandstone; grayish brow11.; very fine grained; subangular- suÞrounded; well sorted; p00:J;"ly êonsolidated; good odor; even medium stain; gold fluorescence. ... . . CORE ANALYSIS REPORT FOR CON~:~ AK q // 17 MILNE POINT (; August 1991 FILE 70092 s of materials and information supplied by the expressed represent our best judgement; however, warranty regarding profits or performance resulting reports. by Petroleum Testing Service cannot be guaranteed. These Testing Service assumes no responsibili from 4450 W. 50TH AVENUE II> ALASKA TELEPHONE 243-2822 8,1991 P.M. Conoco, Inc. 200 3201 C , Alaska 99503 Re: Core Analysis File No. 70092 Enclosed is on North Slope core analysis from Milne Point reference, tests E-7 , of have or comments Manager, at (907)243-2822. Should you Don Graika, Alaska We data iate the 11 prove to be of service and trust is the development of this reservoir. S PETROLEUM TESTING SERVICE, INC. Peter T. Schuyler Pres PTS:rf Encl. . . ;¡J1Jj~!JJ.)Jl} 13~1~lIl1 ðJlIi'1J~ij Ç) ~lICS~ ® 4450 W. 50TH AVENUE · ANCHORAGE, ALASKA 99502 TELEPHONE (907) 243-2822 File No: Date: 70092 August 8,1991 Well: Field: state: Milne North S Alaska Client: Conoco, Inc. CORE ANALYSIS PROCEDURES 1. Trim samples to right cylinders and stabilize with aluminum wrap and 200 mesh end screens. 2. Determine oil and water saturations by Dean Stark extraction. Drying temperature 180 degrees F 3. Determine porosity and grain density by Boyles Law at ambient pressure. 4. Remove screen and aluminum wrap, where appropriate, and determine permeability at :lpO psi confining pressure. ICE INC · · 1 · · · · 1 · · · ' . A 1 1 · · · · · · SID E W ALL COR E A N A l Y S I S RES U L T S - I I ,- - I SATURATION I I I I I I I GRAHl I INCHES I I I SAMPLE PERMEA8ILITYI POROSITY I 0/\.1 OIL \.lATER TOTAL DENSITY RECOVERED COMMENTS I THOLOGICAL DESCRIPTION I rrd % RATIO (PERCENT PORE VOLUME) I glee I I L~ - - - - -L. 51 4755.00 49 29.0 0.5 30.4 63.6 94.0 2.60 1.00 5st, gry, vfsd, mod emt, good odr, ev It sta1n, dl yel-gld fluor 52 4762.00 40 29.8 0.2 17.7 75.2 92.9 2.58 0.50 5st, gry, vfsd, mod cmt, good odr, ev It stain, dl yel-gld fluor 53 4825.00 04 31.2 0.3 20.7 74.5 95.2 2.60 .00 5st, gry, vfsd, mod cmt, good odr. ev It sta n, dl yel-gld uor PETROLEUM TESTING SERVICE, INC. COMPANY : CONOCO AK WEll : E-7 PAGE 2 CORE TYPE: N/A FIELD : MILNE POINT FILE NO.: 70092 MUD TYPE : WATER BASE COUNTY: NORTH SLOPE DATE : AUGUST 08. 1991 FORMATION: N/A STATE : ALASKA SID E W All COR E A N A l Y S I S RES U l T S These results must be used with caution. Sidewall samples are obtained by impact coring. This method can fracture hard formations, thereby possibly increasing the porosity and permeability. In soft formations, impact coring can compact the samples, resulting In decreased porosity and permeability. .. Dr ng fractures and soft formations, thereby affecting the porosity, permeab ty, on, grain density and cation exchange capacity results. . . Milne Point E No. 7 DRILLING 06/29/91: 06/30/91: 07/01/91: 07/02/91: 07/03/91: 07/04/91: 07/05/91: 07/06/91: . API No.: 50-029-22155 Move rig from well E-6 to E-7, nipple up diverter, mix spud mud, caliper and strap BHA. Program MWD and MPT, function test diverter and knife valve. Drill from 105' to 135'. POOH lay down motor and change from 2 cone bit to three cone bit and packed rotary assembly. Re-program MWD/MPT and RIH. Drilled from 135' to 1475'. Short tripped to collars with no problems. Controlled drill from 1475' to 2296' to handle cuttings. circulated thick clays and clay balls at 1700'. Added soap to prevent balling. Gas cut mud at surface 7.3 ppg. Shut -in and checked for flow. No flow. Circulate and conditioned mud until MW in equalled MW out (9.3 ppg). Drilling ahead. Drilled from 2296' to 2452'. CBU. POOH for directional BHA. P/U stab., motor and two cone bit. TIH to 2452'. Drilled from 2452' to 2585'. Ream build section. Drilled from 2585' to 3340'. Sperry Sun MWD unable to decode logging and directional data due to amplitude problems created downhole. Dropped SS survey to confirm MWD data - OK. POOH. Change orifice in MPT tool from 8/32" to 16/32" and reprogram MPT tool. TIH. Finish TIH to 3340' - no fill. Drilled from 3340' to 4316'. Short trip. Drilled from 4316' to 4970' - 9-5/8" casing point. circulate and condition mud. POOH for conditioning trip. Finish short trip - no fill. C & C. POOH. R/U Schlumberger and RIH with 4 arm caliper from 4970' to 13-3/8" shoe at 115'. Pulled caliper tool out of rope socket while entering shoe. RIH with overshot and latch fish at 106'. POOH with fish (caliper tool) and L/D same. RIH with sidewall cores (SWC's) to 138' - tagged up. Attempt to get below 138' several times with SWC's - unsuccessful. M/U 12-1/4" bit, stabilizer and 1 stand of DC's and TIH to 138'. Worked bit past 138' with 8,000# WOB and RIH to 1150'. circulate Borke Coal chunks out of wellbore. Circulate until clean and POOH. R/U Schlumberger and RIH with SWC's. Shot 45 SWC's and recovered 27 - left 18 core barrels in the hole. M/U bit and TIH to 4910'. Ream hole from 4910' to 4970'. Drill from 4970' to 5057' attempting to move junk out of hole. C & C. POOH and L/D 12-1/4" BHA. Run 117 joints of 9-5/8", 36 ppf, K- 55, BTTS casing to 5039' (FS), FC at 4952'. R/U Halliburton and pump 70 bbls water, 480 sx (172 bbls) of class "E" at 12.3 PPG + 350 sx (72 bbls) of cla.s "G" cement at 15.8 PPG for first stage. Open HOS tool with 2100 psi and circ. Pump 100 bbls water, 963 sx (346 bbls) of class "E" at 12.3 PPG + 50 sx (6 bbls) class "G" cement at 15.8 ppg for second stage. Displaced and bumped plug. N/D diverter and N/U BOP's. Test BOP's and choke manifold to 500/5000 psi. M/U 8-1/2" BHA and TIH to TOC at 1950'. Drill cement, HOS tool and cement to 2036'. RIH to TOC at 4903' .... Drill cement to 4952'. Drill FC and cement to 5038'. Test ca§ipg to 1500 psi for 30 min. - OK. Drill FS and 10' of new formation from 5057' to 5067'. Perform LOT to 12.1 PPGe. Drill from 5067' to 5224'...J?OQH and P /U motoDd:t@ Drill from 5224' to 5925' .<POOH for bit chan~;F.- TIH. TIH. Drill tIlm 5925' to 6743'. Short~. Drill from 6743' to 6996'. Lost 700 psi standpipe pressure - POOH for washout (1 joint of DP washed out). Replace joint and TIH. Drill from 6996' to 7023'. 07/08/91: Drill from 7023' to 7883'. 07/09/91: Drill from 7883' to 7893'. Short trip - no fill. Drill from 7893' to 8055'. POOH and L/D motor, MWD, and PDC bit. P/U insert bit and TIH to 8055' - no fill. Drill from 8055' to 8089' . 07/10/91: Drill from 8089' to 8353'. Short trip - no fill. Drill from 8353' to 8477'. POOH for new bit. 07/11/91: Drill from 8374' to 8477'. Short trip - no fill. Drill from 8477' to 8598'. Circulate and condition. Short trip to shoe and condition hole for logs. Rig up loggers and run DIL,LDT,CNL, MSFL, NGT,AMS. 07/12/91: Run AMF, GR, RFT FROM 8190' TO 8464'. Drilled from 8598' to 8787' . Circulate and condition, short tripped 10 stands. Circulate and condition. Rig up casing crew and start RIH with 7" casing. 07/13/91: Rig up and run 205 joints of 7", 26 ppf, L-80 casing to 8770' (FS), FC at 8683'. Pumped 50 bbls. 11 ppg sepiolite, 40 bbls. water, 81.9 bbls class "G" cement with additives and displaced with 337 bbls. produced water. Bumped plug, checked floats and pressure tested casing to 1,500 psig for 30 minutes. Rig down casing crew, install packoff and test to 5,000 psig. Change rams to 3.5" and cleaned pits. Test BOP to 500 psig/5000 psig. Pickup and strap BHA and 3.5" drill pipe. NOTE: Rig released to AFE No. 1397 at 2400 hrs on 07/12/91. Total cost on AFE No. 1396 is $1,394,605. 07/14/91: Finish P/U 3.5" Dp and TIH to 8682' (FC). Reverse circulate brine until clean. POOH. R/U and run CCL-GR-GCT from PBTD to surface. P/U perforating guns and TIH. 07/15/91: Finish TIH with perforating guns. RIH with GR-CCL correlating log. Displace DP with 61 bbls of diesel, set packer, and test packer to 500 psi. Perforate from 8382'-8420' and 8452'-8484' with an ISIP of 70 psi. Flowed 15 bbls for 1 hour then well stopped flowing. Reverse out diesel and oil. POOH and L/D DP, packer, and perf. guns. Change rams to 2-7/8" and test bonnet seals to 2000 psi - OK. P/U electric submersible pump and RIH with 2-7/8" tubing. 07/16/91: Run 242 joints of 2-7/8" 6.5 lIft L-80 tubing. M/U packer, make splice in reda cable, M/U SCSSV and control line and RIH on 17 joints of 2-7/8" tubing to 8320' MD (bottom of ESP). M/U hanger, splice reda cable and freeze protect tubing and annulus with diesel. R/U slickline and set plug, set packer, test SCSSV, pull plug and te$t packer to 500 psi - OK. Install BPV. Circulate diesel out of tubing and annulus. 07/17/91: Sheared packer, POOH topa-çker. Rebuild packer, cut and splice ESP cable. Hookup and test control line. RIH with tubing and land at 8320' (bottom Q~ESP). Test hanger. Displace annulus with 60 bbls of 8.5 PPGbrine with 12% Methanol and 5 bbls diesel. Set plug in X...nipple. Set and test packer - OK. Displace tubing with 12 bbls diesel. N/D BOP's and N/U tree. Test wellhead and tree to 5000 psi - OK. Set BPV. Released rig at 2030 hrs on 07/16/91. '. MAY 29, 1992 BOB SOPTEI CONOCO INC. 3201 C STREET SUITE 200 ANCHORAGE, ALASKA 99503 RE: 91-0050 .' MILNE PT. E-8 DEAR MR. SOPTEI, A REVIEW OF OUR FILES INDICATE THAT CONOCO INC. IS THE OPERATOR OF THE SUBJECT WELLS. OUR MONTHLY PRODUCTION REPORTS SHOW THAT THESE TWO WELLS HAVE BEEN PRODUCING SINCE JANUARY AND MARCH OF THIS YEAR. WE HAVE NOT RECEIVED THE COMPLETION REPORTS (407) FOR THESE WELLS AS OF THIS DATE. A FORM 407 FOR THE COMPLETION WITH THE DAILY WELL OPERATION ATTACHED SHOULD OF BEEN FILED WITHIN THIRTY DAYS AFTER THESE WELLS WERE COMPLETED. PLEASE LET ME KNOW IF THERE IS ANY PROBLEM WITH SUBMITTING THESE FORMS AS REQUIRED IN A TIMELY MANNER. SINCERELY, ~:hYU STEVE MC MAINS STATISTICAL TECHNICIAN C: ROBERT CRANDALL SR PETR GEOLOGIST . . AOGCC GEOLOGICAL MATERIAlS INVENTORY UST ~ \ lß l&-7 (. . ) 1-"\ ("'i ~ ( - ~'f WEll NAME COMPLETION DATE Î ," 10, ( CO. CONTACT PERMIT II VY\ lOG TYPE RUN INTERVALS NO. to the nearest foot 1) \ 2) C-~t- LbL ~ 3) C-'lß ~ 4) C~L. ~ .J.-t 5) C-t-.JL.. ~ .:l.+- 6) =< :< 1) .:l :;; OJ ;l 9) ~ 10) t-'& 11) t - "!> 12} ~ 13) 14) - 15) .:Jt-S 16) 11) - 18) - " . '! A" J ; 1 <. . . ÂûGCC GEûlûGiCÂl MÂTERiÂlS ih"VENTûRY üST PERMIT It q l - 4:q mtu ~ lOG TYPE RUN INTERVALS SCALE NO. (to the nearest foot) [inch/l001 19) C. \ À \(1 ~ \ 4 S ~,&-,,'48;} S S 20) 4- OJ[ f"í'\ [01 I ~-- :)1 5 I ,-,:::JIJ ,- l \ J 21) p~ \ 7~D-ßld5O S 22) C ý~-¡-c 23) 0ß~ 24) 25] 26) 27) 28) 29) 30) 31) ]?) - "J 33) 1.d1 - 'J 35) 36] 37) 38) 39) 40) , ill) 42) 'I e November 2, 1992 Mr. Blair E. Wondzell Petroleum Inspector Supervisor Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 RE: MPU E-7 CEMENTING INFORMATION Dear Mr. Wondzell, Cl5 Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503-3999 (907) 564-7600 The attached cementing information is offered pursuant to our conversation regarding the conversion of our MPU E-7 well from production to injection. A cement bond log was not run on this well when originally completed because the requirement did not exist and because there were no indications during the primary cement job of inadequate cement coverage. The M PU E-7 well has been on production since late 1991. Because there have been no indications during this time of any cement integrity problems and because the cementing report indicates good cement placement with full returns throughout the job, Conoco is confident there is adequate cement coverage behind pipe to contain injection. Please direct any concerns or questions regarding this matter to me at 564-7660. Sincerely, ~(~ Yo^, l~ff' Tom Yeager SHEAR Specialist att: cc: CVL, JHA ( 1~ 10\ \~ I v 1)/ HIU¡r: rOINT UNIT e CASING AND CEMENTING REP. Well: £-7 Ground Elevation: .:2.'/ (ft) Drillers T .D.: Ç{5'9&> ( ft) $7 t7 ~ ~:7//7 RKB - Grd. E 1 ev . : Jtj (ft) Loggers 1. D.: ft'?f' (ft) Top of Hanger-RKB: 3'/ (ft) Spacing 5'4e ~~ >0 BBLS of /1 PPG ~p;../ì.Je I/o .i .i/r ~ J. " BBLS of /S; g' PPG C-J...~~ l:' ¿vI ð. 2. "'70 0, 'I"?" //~/~. ~ ~'/) ø· t'? s"""-?o .L wL- BBLS of PPG Haximum Recorded Temperature from Logging Runs l!I..2-..oF Centralizers and Preflush: Cement (Stage I) Cement (Stage II) .41..0 ¿::F£- 3 ) Disp. Fluid: '3 "53 BBLS of g'~~ @ OF PPG_ /r-øLu-c J ¿¿/~ Time Started Time Completed Rate (BPM) PSI (max. ) / ~: )0 /!' : ð ç 7 795 . /s ~ " r /ç: 2,.¡-- ~ 700 / r: '3ð /5':' ç:l.. ~r ./ 00 () Circulation Pre-Flush Stage I Stage II Displacement Recip. Pipe /~; t"$" / ~: /ô . /7 ; " 5"" I..,.; " () ~ ,;:2. {"o - /¿ {)D (Why Stopped) ,L¿j.Åt./ -?'/:t Top Plug:~ No) (bbls) Bumped Top Plug: ~, No) Floats Held: ~ No) Cement Returns to Surface: (Yes,~ Final Landing Weight ;7~ Performance: (Good, Fair, Poor) Supervisor: ~o_~c?j¥ / þor¿-d,k-r Bottom Plug:~, No) Total Pumped Disp. '3~7 Full Returns: ~ No) Initial String Weight: />'0 Service Co/: d4t!a.-.,;--'¿;.... Date: 7//;¿JclL (lbs) ~'tPo psi BBLS (lbs) ·i. nd ¡iLI' ¡-Dm (J :: 0Ø-'Ø3: 31jj : 30·-1?i·¿+:: 30 it: 30···1?i;5 : øø ;':¡: 00····:1..3:: 00 3: (10,-,:1. ~5: 00 :ØØ···lß:ŒJ(.:j ß: Ø0--i:~0: 0Ø (ìJ:00-22:ØØ ;;~: 00·-í.?'+: øø HT';;;' . ;jø 1.Ø0 ø. ;50 ß.øø i.?. ø ø 3.ØØ Ø.0(1 ø.øø 0.(1(1 ;:: . (1 ø ø.øø i.~. Ø0 i.?. [11:-) Ø.Ø0 ø.øø -.".....A_-t-··, '.-- t.::::<L.,J ,.',1. ¡I Cel" 1 1'1 . _ii' Date 07/L2/91 Well rein D ß irHj hl1 1:;; 11:):1. :L u q all p(:~T-at:Lun LD "P ." ¡:;Hn CHANGE OP RAMS ND PULL WEAR ING rEST DOOR SEALS 0 I:: U n I-j D I;: lJ 1'-1 ;~ Ø ~.::) CIF~C PUMP 0 BBLS :1.:1. PPG BBLS, CLASS G CEMENT PRODUCED WATER" BUMP F () I( .3 [] 1'1 I II I~D C ~;G CF~EW, I I'-1S TriLL l!f::¡CI~,(JFF '. E (; T TO TO J";5,, CLEAI'~ P I T~; TEST BOP TO 500/5000, SET WEAR RING" STRAP BHA, PU BHn AND ,,~ Ø600 NOW PUMPING CSG WASH HELD 2 -MIN PRE TOUR ,- -::J Ø0 <:;1 ¡; ¡¡ L .. . ø ("0(''> -.:)'.3" vJí':¡SH B¡:~ I DGE (,)) o BOT E 1:' I D L T i~ , I:) B L. ~; LJ I:) T E" 0 T P L 1.1 G " :I. " WI nDDITIVES" DISPLACED WI 337 BBL.S 1:'1.. U f3. CHEcr, I~L on T:3 "fE~; T C ~)f3 0 1 ;':¡1?i1?if* ;.50¡;:'Øf* , Hf:)11GE 1~í-iIYS I..USH 11UD 1... I HE::; . ~-(((-.(;;:. :,;"" ; ',^,: \,' ¡ ,-- ;: .. .. . SCHLUMBERGER WELL SERVICES 500 W. INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518 __ COMPUTING CENTER LOCATION ATTENTION __ PRINT CENTER SERVICES WELL NAME WELL NAME SERVICES NO. OF BOXES:: ;1 NO. OF BOXES: JOB NO. JOB NO. ADD'L TAPES ADD'L TAPES WELL NAME WELL NAME SERVICES SERVICES NO. OF BOXES: NO. OF BOXES: JOB NO. JOB NO. ADD'L TAPES ADD'L TAPES WELL NAME WELL NAME SERVICES SERVICES MBERGER COURIER: DATE DELIVERED: RECEIVED BY: NO. OF BOXES: NO. OF BOXES: JOB NO. JOB NO. ADD'L TAPES ADD'L TAPES FROM CITY ADDRESS CITY ATTENTION PHONE ONE HOUR . . SCHlUMBERGER WEll SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 77251-2175 ,.ûUl ! 5 199; PlEASE AEPl Y TO SCHLUM8ERGER WELL SERVICES Pouch 340069 Prudho~ Bay, AK 99734-0069 ATTN: B~rni~/Sh~ll~y Conoco, Inc :[2oi-'tC"St r~~ t, Sui t e 200______ ~nchora~AK 99503 _.______ Attention: ~1 nc!a St an ___ Gentlemen: Enclosed are~~rints ofthe_ GCLíÇorr~ct_~d CopY..L-Run 1. 7 /13/91 __on: Company_~OC~~c ."'~--- Well___ Milne PoinLJlll.H_E.-7 It\ \" ~ . \ ------ Field~_tl.!le POi nt __County~rth Sl.Q.1l~_State_.....Ala!';ka Additional prints ore being sent to: LBL--prints G.Q!!OCO, Inc _____ º--Q..o North DaiJ'y_Ashford HoustoTh-I2C_] 7079 ._- Attn: Geor-K~~mb. OF 201.8.....J'E..Ec_ ---' 1 BL-prints, 1 RF Sepia ~h~vron.JL S . A. ...illlL.S:ou t h W 1lu Ii! s t JJ ou_s t 01lJJLJ 7 099 M'IN~i.c.ha.e.L Qu j n n _*( 713/561-3673) ~L-prints Çon()~llLç__ LO-ºQ..-S-ºJ.!.LhJjy~ £onco Ci tL_-ºK 74603 --- ~t tll-'.......-G.1gn n..1l~.1c h , 7 J6..Q.lU)L__ 1 BL ..prints, 1 RF Septa Jì.X.Y.JL...s..A~nc -~- _6.__..D£.S.t_iL.nr.i.~_Slli t p f. 00 'l _____ Jüdl.and--IX-.-1..9.1~---~----- Attn: J.oluLC;¡rrol ---- *(<41 ')/.685-5RQ8) ~~=~-~---""-~--~ ~~, / '~ 1 m:://prints , 1 RF Sepi a '\ ¡AÍaska Oi~ &.Gas~~IYat]on ) ~. CQ~ssJon ' .~~ / .3illìL..P.o.r..c.ujUn.e Dr] Vp / :~~n_AK_~:S/ // prints ----- --- prints The film is_r~turn~d ~. Conoco, Linda Starr We appreciate the privilege of Very truly yours, SCHLUMBERGER WELL SERVICES RaymQ1dN'm Di cjt~ê_ DISTRICT M...N....GER sws 1327V 5pe'"'l'"'l~-5J1t CAILLING ~ SEAVIC:ES . ,=~=,---.=-"---~~~= TO: Alaska Oil & Gas Conservation Commission Attn: Mr. John Boyle 3001 Porcupine Drive Anchorage, AK 99501 DATE: June 17, 1991 TRANS #: AK-MM-910615 RE: Conoco Point E - 7 The following technical data is being submitted herewith. Please acknowledge receipt by signing and returning a copy of this letter to the address printed below, attention E.A. Opstad. ENCLOSED INFORMATION SUMJ\.fARY Well E - 7 MD: 1 Blueline Print 1 Folded Sepia TVD: 1 Blueline Print 1 Folded Sepia \Jk 1 LIS Tape Received By: Alaska Oil & Gas Conservation Commission - Date ~V\ jJwYrYW^ 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Baroid Company J · SCHLUMBERGER WELL SERVI(~ES 500 W. INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518 COMPANY __ COMPUTING CENTER LOCATION ATTENTION __ PRINT CENTER WELL NAME SERVICES WELL NAME SERVICES NO. OF BOXES: NO. OF BOXES: JOB NO. JOB NO. ADD'L TAPES ADD'L TAPES WELL NAME WELL NAME I SERVICES SERVICES NO. OF BOXES: NO. OF BOXES: JOB NO. JOB NO. ADD'L TAPES ADD'L TAPES WELL NAME WELL NAME SERVICES SERVICES NO. OF BOXES: JOB NO. JOB NO. ADD'L TAPES ADD'L TAPES SCHLUMBERGER COURIER: DATE DELIVERED: } RECEIVED BY: FROM CITY ADDRESS CITY ATTENTION 24 HOUR PHONE . . SCHLUMBERGER WELL SERVICES, A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 77251-2175 JUL 1 7 '00' "-EASE RE"- Y TO SCHLUMBERGER WELL SERVICES Pouch 340069 Prudhoe Bay, AK 99734-0069 ATTN: Bernie/Shelley Conoco, I nc 3201 nçn ~tr''''Pt ,_ Suite 200 Anchora~AI<-_99503 Attention: __ Lj nda St arr GCT, Run 1, 7/13/91 Gentlemen: TCP Gun Correlation Rec, Run 1, 7/13/91 Enclosed are 3 BLprintsofthe__~erf~ePth Control, Run 1, 7/12/91 Company Conoco, Inc Well Milne poinLllni t F>-7 Field Mi lne POi nL Additional prints are being sent to: 1 BL --+>rints CQ noc ~_!!~_ 600 North Datil Ashford lLouston, TX 17079 Attn: George LÆ~F 2018 PER_____ on: -' County -----Bart h Slope State Ala!'\ka 1 BL prints, 1 RF Sepia Chevron U.S.A. 11111 South Wilcrest Houston. TX 77099 ..ATTN: Mtchael Qui nn *(713/561-3673) Uk--prints Conoco , Inc lltQº-__5.QJ\tJLP in~ . Ponca Cit y. 0.K_B,603 Attn: .--Gl_~ª-Y~ch, 7360 RDW 1 BL prints, 1 RF Sepia OXY U .£..A. Inc .6,-D.e..s.t_a..lh:iYe.......5w-t.e.-6 00 ? Midland, TX 79705 .At.tn: John f.;¡rrol *( Ql 5/MI5=5898) --- 1 B~ _pr¡;:'ts , 1 RFSèp·i-a.~ A}áska Oil & Gas Conserva:t:.i on / \ / Commission l :'HìQLJ>.Qr_c..Uþin~ Dr i Vp (Anchoragp, AK 99501 \Attn: John Boylp .// prints "^^~^-'" .,,,.... ~,è."'·· ·~----~príñts --~. The film is_returned to Conoco, Linda Starr We appreciate the privilege of serving you. Very truly yours, SCHLUMBERGER WELL SERVICES R.ªYIJlºI1(iJ'.¡._)t<;'~,L__--,-- DISTRiCT MANAGER ~.._._-~-.-----.--.,-.------- r·_/'¡Ifi--".' . . SCHLUMBERGER WELL SERVICE~> A DiVISION OF SCHLUMBERGER TECHNOLOGY CIORPORATION HOUSTON. TEXAS 772'51-217'5 Jut 1 5 199' PlEASE REPlY TO SCHlUMBERGER Well SERViCES Pouch 340069 Prudho~ Bay, AK 99734-0069 ATTN: Bernie/Shelley Conoco ,_lnc~__~~-----__-_-__-_- 3201 ltC"~ St_£pet, S~{>_~~Qº-___ Anc ho rage L~_9 9 5J>1__________ Attention: ~_ktl1da Starr______ j ,~ ,¡ J DIT-E( 5:;), DITE( 2 ') ,CNLCP9RO), CNL(l}AW), NGT, J Gentlemen: . CNL(TVD~PORO),5" TVD Phasor, 2" ~D Phasor,RFT, Enclosed are_Ul~nntsof the__Gy-b-e-r~n~-10/91 an: Company _º_onoco , ~-----z;n-:-'. i ' Well____tl:i,1n~_Eºi1!LUnH~-=1- I>¡I f..tø1 ct Field.--11i 1 ne POtIl1. èO\..ldty! . North Slope Additional prints are being sent to: 1 B~--prints Cono.~~_l1.Ç__ 6 OQ_N 0 r tllJ2a i rY_fis hf 0 rsL-__ Houston, TX 77079 Attn: Geor~mb. OF 2018 PER State Alask;¡ 1 BL prints, 1 RF Sepi a Chevron U.S.A. 11111 Soutþ Wilcrf>st Houston, TX 77099 MTIiLl1i chap} QUi nn ~3/561-3673) L~rints Conocº~__ Hl.Qº--~JjjJL..£~------· Po nc 0 _C iJy--,-_QK.~~O 3 ~il~Jgnn....1l..B~LiQ.Q..-.Rl2101-- --~-_..__._.._.._- 1.. ~L prints, 1 RF Septa _Q}{Y U. S . A. he lLIle.sta..J)ri Vp , . ~u:it-f"---6D02- .l1i.dland, TX 79705__ ~~John C;¡rrol *(91'1/685-58Q8) 1 BL~~if'1Js..1RFSept§i ~Ci Oil & Gas Consprv:a,ti.on ~C.o.mmis.sion / 3illti__P.Q rCJ,Uu.~.-D.r:i vp ( AIKh.oI~ AK 99501 \ .-ð,t t n: John Boyl4>- / " . ~,. _N"" -- "",~ prints -- ",".",~ ---~'"f>r:ints., plrints The film iL.....!:.eturned to Conoco, Linda Starr Received by: -~~_._~~--- We appreciate the privilege of Very truly yours, SCHLUMBERGER WELL SERVICES ß? YJIlg I1clJL,f)ic..ì",_~_________________ O¡STRJCT MANAGER sws-- 1327 F . ) ,.. SCHlUMBERGER WEll SERVIC A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 772'51-217'5 'JUL 1 0 1991 "-USE RE"- Y TO SCHLUMBERGER WELL SERVICES Pouch 340069 Prudhoe Bay, AK 99734-0069 ATTN: Bernie/Shelley Conoeo, Ine 3201 "c"-st-rf>¡>t, Suite 200 Anehor~e, AK 99503 Attention:~cla Starr Gentlemen: Enclosed are~~rints of the Company Canoe 0 , Ine Well Milne Point Unit E-7 Field Mi 1 ne POi nt /Kuparl1k R; vp.r Additional prints are being sent to: 1 BL prints Conoeo, Ine 600 North Dairy Ashford Houston, TX 77079 Attn: George Lamb. OF 2018 P~R Four Arm Caliper, Run I, 7/02/91 Sidewall Core Ree, Run 1. 7/02/91 on: County North Slope State A]a!';ka 1 BL prints, 1 RF Sepia Chevron U.S.A. 11111 South Wilerest Houston. TX 77099 ATTN: Mj ehael Q\li nn *( 7l3/561-3673) 1 BL prints Conoeo. Ine IOOO-.So.u.tlL_£.:iM- Poneo Ci~OK 74603 -ð,J t n:_--.Gl e nJ1 We 1 ffi..-TI.61L1U2W ...L..RL.-prints, 1 RF Sepi.a J)XY U. S .A. Ine £} Df>!';ta Drivf>, ~11itf> £\002 Midland, IX 79705 Attn: John Carrol *(Ql,)/68558Q8) 1 Bþ" prints , 1 RF Sepia f Aliska Oil & Gas ConsH~~Üon ! ' ' , Commission \ 3.QQl_h.rÇJ1!ll.M...JlriY..e. ~.r.ag~ AK 99501 . / At\tn: John Boylf> // prints _-prinE prints J/ // // --~--- The film is returned to Conoeo, Linda Starr . We appreciate the privilege of serving you. Very truly yours, SCHLUMBERGER WELL SERVICES ßaYD10nd~N.Dj cl\.,:_s___~__________~ DISTRICT MANAGER sws 1327F I«)~~~.~...~.~ WALTER J. HICKEL, ALASKA OIL AND GAS CONSERVATION COMltlISSION April 16, 1991 3001 R. S. Rossberg Sr. Drilling Engineer Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503 Re: Milne Point Unit E-7 Conoco Inc. Permit No. 91-49 Sur. Loc. 1493'FNL, Btmhole Loc. 1249'FSL, 25, T13N, R10E, UM Sec. 30, T13N, RlIE,UM Dear Mr. Rossberg: Enclosed is the approved above referenced well. permit to drill the The permit to drill does additional permits required agencies, and does not operations until all determinations are made. you from obtaining law from otner governmental authorize conducting drilling other required permitt.ing The Commission will advise wished to witness. those BOPE tests that it ion dlf/enclosures cc: Department of Fish Department of Section w/o encl. w/o encl. . STATE OF ALASKA A ALASKA AND GAS CONSERVATION C~ISSION PERMIT TO DRill 20 AAC 25.005 1a. Type of work Drill:X Re-Entry 2. Name of Operator Redrill Deepen 1b. Type of well. Exploratory:= Stratigraphic Test := Service Developement Gas = Single Zone :x: 5. Datum Elevation (DF or KB) KB 35' AGL feet Kuparuk River Field 6. Property Designation o 4. Location of well at surface Alaska 99503 1877' FEL, 7. Unit or property Name 11. Type Bond (see 20 MC 25025) SEC. 25, T13N, R10E. U.M., N.S.B., AK At top of productive Interval 1500' FSL, 450' FWL, Blanket 8. Well number Number SEC. 30, T13N, R11E At total depth 1249' FSL, 705' FWL, SEC. 30, T13N, R11E 12. Distance to nearest 13. Distance to nearest well property line 6529 feet 45 feet 16. To be completed for deviated wells Kickoff depth 2500 feet Maximum hole angle 420 18. Casing program size Casing -7 8086-15-54 9. Approximate spud date Amount 22 1 991 14. Number of acres in propert 2555 8565'MD/7190' 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maxímum surface 3480 psíg At totaí depth (TVD) De th Bottom MD TVD 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Downsqueeze: ± Frost "C" ± 60 bbl diesel Effective depth: measured true vertical feet feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True Vertical measured true vertical 20. Attachments Filing fee 00 Property plat 10 BOP Sketch K' Diverter Sketch :xi Drilling fluid program [J Time vs depth plot iZJ Refraction analysis 0 Seabed report 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Drilling program KJ 20 AAC 25.050 requirements ~C Signed Date Steve Rossberg Title Commission Use Only Per@f Number Approval date - 7' Cj 50- 02 ? - .z :4., - ~ r / Conditions of approval Samples required 0 Yes)t'NQ Mud log required 0 Yes Hydrogen sulfide measures 0 Yes ~ No Direction~urvey required l21 Yes 0 No Required working pressure for BOPE 02M; 0 3M;pq5M; 0 10M; D15M Other: by order of the commission See cover letter for other requirements No Approve Form 10-401 Rev. 12-1-85 Commissioner Date ,Æ,. I Submit in triplicate ~' . . SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL Conoco Inc. 3201 C street, suite 200 Anchorage, Ak 99503-3992 CONOCO MILNE POINT UNIT E-7 I. Casing and Cementing Program CASING PROGRAM Hole Size Casing Size Depth Weight Grade Conn ( Inches) (Inches) (ft) (ppf) 30" 13-3/8" 115' 54.5 ppf K-55 WELD 12-1/4" 9-5/8" 4,915' 36 ppf K-55 BTTS 8-1/2" 7" 8,565' 26 ppf L-80 BTTS A. The 13-3/8" conductor will be set at 80' below ground level then cemented to the surface with ±600 sacks Permafrost type "C". B. The 9-5/8" surface casing will be set approximately 50' below the base of the Schrader Bluff "OB" sand and cemented to surface. The cement job will be performed in two stages utilizing a hydraulically operated stage tool located at approximately 1,800' M. D. Stage I cement will consist of approximately 850 sacks permafrost type "E" followed by a 350 sack class "G" tail. Stage II cement will consist of approximately 550 sacks permafrost type "E" followed by a 50 sack class "G" tail. If cement is not circulated to surface, a top job will be performed using permafrost type "c" cement. C. The 7" production casing will be set at 8,565' MD/7,190' TVD or approximately 300' below the base of the Lower Kuparuk sands. Class "G" cement (approximately 350 sacks) will be circulated from the 7" shoe to 1,000' above the top of the Kuparuk interval. After the 7" casing is set, the drilling rig will move off and the well will be completed using a work over rig. II. Drilling Fluid Program A. 0 - 500' 9.0 ppg freshwater spud mud. B. 500'- 4,915' 9.0 ppg - 9.4 ppg freshwater spud mud. C. 4,915' - 8,565' 9.4>ppg - 10.4 ppg dispersed. - ·; . Conoco Inc. Supplemental Data Sheet Well E-7 March 25, 1991 Page 2 III. Drilling Program Conoco Inc. proposes to drill MPU well E-7 to continue development of the Kuparuk River Pool at Milne Point. The mud system will consist of a fresh water spud mud (9.0 - 9.4 ppg) from the surface to the 9-5/8" casing point at approximately 4,915'. A low solids, non-dispersed system (9.4 - 10.4 ppg) will be used from 4,915' to the 7" casing point at 8,565' T D. Single shot surveys will be taken at the 9-5/8" and 7" casing points. MWD surveys will be taken every 30' in the build interval and every 100' in the vertical and slant sections. A gyro survey will be run from T D to surface at the completion of the well. All surveys will be referenced to the section Grid System and corrected for magnetic declination. A complete set of open hole logs will be run from T D through the top of the Kuparuk River·interval. A 20", 2,000 psig diverter will be installed on the 13-3/8" conductor for drilling surface hole. A 13-3/8", 5,000 psi RSRRA BOPE stack will be nippled up to the surface casing for drilling the production hole. Pressure tests and function tests will be performed on the pressure control equipment as per State Regulations. Maximum downhole pressure is estimated at approximately 3,500 psig and is based on initial reservoir pressure. Maximum surface pressure is estimated at 3,400 psig, based on an unexpanded gas bubble with temperature effects not taken into account. The closest wellbore is MPU well E-6 with 45' of closure at 880 'TVD. Well E-6 will be shut-in and wellbore pressure monitored while drilling thil? interval. Approximately 400 sacks of Permafrost Type C cement displaced with dead crude and/or diesel will be pumed. down the 7" x 9-5/8" annulus for final arctic pack and freeze protection after disposing of excess drilling fluids. . . Conoco Inc. Supplemental Data Sheet Well E-7 March 25, 1991 Page 3 WELL PROGNOSIS AND DRILLING PROGRAM TVD MD FORM BIT TYPE WT YP PV VISC FL 500 500 GRAVEL 5-1-5 SPUD 9.0 100 20 100 15 900 900 SAND/SHALE 5-1-5 SPUD 9.0 100 20 100 15 3895 4059 L TOP 5-1-5 SPUD 9.2 25 15 60 15 4415 4764 OB TOP 5-1-5 SPUD 9.2 25 15 60 12 4450 4812 OB BASE 5-1-5 SPUD 9.4 25 12 60 10 6700 7865 CAP ROCK B10M LSND 9.6 25 8 60 8 6800 8001 MK-1 TOP B10M LSND 10.4 12 8 35 6 6890 8123 LZ TOP B10M LSND 10.4 12 8 35 6 7190 8565 T.D. B10M LSND 10.4 12 8 35 6 True vertical depths are based on a sub-surface datum. · MILNE POINT UNIT 1. STATE PLANE COORDINATES ARE ZONE 4. 38'44'40' NOTES: ! I ! I / /, ¿/ /, r~/, E PAD /, r~ ;/;/ 11 ~~ ;/;// Þ '\;; -<? 4~ ,;;> Q? /'J \.:@ PT. VICINITY MAP --- 2. ALL GEODEllC POSI1l0NS ARE BASED ON N.A.D. 1927. 3. OFFSETS TO SEC1l0N LINES ARE COMPUTED BASED ON PROTRACTED VALUES OF THE SEC1l0N CORNER POSITIONS. r-j--., MILES -<?l LOCATION IN SECTION 25, T. 13 N., R. 10 E., U.M., ALASKA WELL FROM NORTH LINE FROM EAST LINE E-6 E-7 E-8 1446' 1493' 11 94' 1914' 1877' 2107' STATE PLANE COORDINATES-ZONE 4 E PAD WELL NORTH EAST (X) E-6 6,016,371.44 569,230.07 E-7 6,016,324.64 569,267.62 E-8 6,016,621.42 569,034.43 LEGEND ~.._____.______~m,____.___m__'_- GEODETIC POSITIONS NAD 1927 ~----~--~~--- ~--"'-~--'--- @ EXIST1i\jG \,VELL WELL NORTH LATITUDE WEST LONGITUDE o PROPOSED WELL E-6 E-7 E-8 70' 27' 18.306" 70' 27' 17.842" 70' 27' 20.782" 149' 26' 06.1.39" 149' 26' 05.048" 149' 26' 11.818" SURVEYED FOR: PROPOSED WELL LOCATIONS ~. E-6, E-7 & E-8 S0.'\! O'or ~ S -/:( : 9 T 0.. -/:( é) ~oo: 000000 0 00000000"0006. ~ .. '" .. '" <> "" 0," '" .. '" .. .. .. .. <> <> .. .. .. '" .. .. <> " '" .. ~ 000 ~TI1:. µ o;Ð-I <::.,0 L-L;' ['}y' : S. .0 X 0 "-. ~V',<.o W'2.WL-S /ic';j~ (/)~çl'(' 000 00' [~).[Z:;J[ li 1'/000000'00': "",,,, .z,~' DrESSlOt'!;\.· '--:<$-r) .tx:x:Dn~~,>j F. CNGtlitIRS Af'O lAND SI.JR~S ATE: 3-1-9: DRAWN STOLL CHECKED: VAIL JOB NO.: 90-059 (c 0010 C Q) SC.:...l._E: 1 ø = 30Cj' .3.335 Þ>.RC1\C BlVD su.n: 2m AJ-IŒtORAGE.. AJ.._AS)<~A HSû3 T13NR9E T 13 N R 10 E T 13 N R 11 E MILNE P;(;iINT UNIT CKEVROH ® COHOCO ET AL ® cONoéo CD CONOCO ET AL 9 o Denot.. tr.et numbe,. Tot.1 Ar.. In Unit :15.744 Acr.. . ~ .. 3 IS S 2 o.n,ot.. tkctSon NurnMt r ~~ - Unit Bound." -t AOL-31971 1265 AC ADL Le...~ . CONOC" ET 'L e ......... 1 ~ ð/U 11 12 7 8 ,.-/ A.Ot.-255~ 2533.AC ADL-4 7 4 3.. 2560 AC AOL-47433 2 60 AC, ~D~7432 68 AC "'- ~ROH (ß) CO N4<..t> IT AL@ ~ ø CON" ® CONOCO Ef A ® ëONOCO ET AL ~ CHEVRO CHEVRON .. ~ ~ .. 18 17 16 15 14 1:1 + + - - +~ ~ ~ 23 24 U 2.0 ..21 22 23 24 19 2 21 22 AOl-25516 ADL-4743" ADL-3158<4e L A.Ot.-255 1<C 25110 AC AOL-25515 2s.44 AC ~~~~' :~.u 1280 AC AOL-47437 2560 AC ADL-"7438 2544 C 1280 AC1280 AC CHEVRON @ .CONO<-o..ET AL <.8> ® CHEVRON . "' . '"T. 30 2" 28 27 2& 25 30 2g EXHIBIT A + + -r + MILNE POINT UNIT AREA 31 33 34 Bu.d on Uml.t ...."ål.n.Aluk. 35 :Ie 31 3Z 0 1 2 Acx.-2ðð17 ...11.. -= 2235 AC ADl-25518 2!i60 AC AOL-28231 2555 AC Sc.l. . CHEV. Î "'RCO .~ .OHIO . CONOCO. INC. UllN[ 'OINT UNIT . DIVERTER STACK FOR 13 3/8· CONDUCTOR ~........ !'Yr ~-;""r .1:7' 'F~ I~ (~~.. ~. eN; 'IlL U' llN[ IEl\. III"\.( 'lOw LINt ro- #.1'1 1000 'I' AhNVUI 'R[V(IIHII /II"'!!7T~ UM¡- .c>'st'~ 40 1>1'£ ~F~ OlvUTU OUIC. COH"[ct A$S(wn, S A V [' sva .. B [ "h. Y STAIITIO ~[AO '/)'~'/~'.. .e. ~.....~.,,:~, . . . '. .... ", : ~ ."... þ' . . . '" '. . ,.. " 3/t' c.a S I "'Ci - - 1-' . . . . :.:':. .~.: 1. The hydraulic control systetlwill be in accordance with API specifications and AOGCC requir~ments. 2. The HCR valve will open when the preventer closes. A single 10" relief line will run off of the drilling spool HCR valvQ and wi 11 have a tal-geted downstream tee for downwind diversion. Valves on both 5idesof the tee will be full opening and linKed together to ~nabla one to always be open and the other to b2 closed. E58S~# BOP SYSTEM 13-5/81 RIG 27E INC,--t~ABORS CONOCO Line Flow ine L Fill Annu at' PrevErltor 13- 5/8" ::l1 AfI Ram . Valve Gate 3" 5000# Manual Gate & 3" HCR VALVE Two 3" 500Ø# Manual Val yes Line Line: Choke Kill Ram Ram Tubing Spool wi 211-5000# 13- 5/8" ::l1 AfI 13-518' ::l1 ~A+rn.Ä~rrll ~/~--74J '-' '-,-- A fI 13-::i/B" ::l1 13- 5/B" ::l1 11' x AfI API Side Outlets Casing Spool wi 311-5000# Side Outlets 9-5/8" Sur-face Casing 13-3/8" Conductor- Casing 11' Tt'i'eooed Correction API . BOP STACK SIZE RATING MEETS API RP53 & SPEC 6A FOR CLASS BOPE TO BE OPERATED EACH TRIP AND TESTED \w'EEKL Y. BOP HYDRAULIC CONTROL SYSTEM TO INCLUDE (5) STATION CONTROL tvlANIFOLD LOCATED REtvl0TE ",nTH 160 GALLON ACCUMULA TORI RESERVOIR UNITI 8. AUXILIARY ENERGY SOURCE FOR SYSTEM ACTIVATION, MINIMUM ONE SET BLIND RAMS 8. Tv.JO SETS APPR.OPRIA TE PIPE RAMS. CHOKE 8. KILL MANIF:OLDS SHOWN SEPARA TEL Y TO MEET API RP 53 CLASS 5M REQUIREMENTS. 5M L 2 3 4-, 5, . ~ fRC),I MU P .~ KILL MANIFOLD fROM RnIOTE: HIGH PRESSURE PUMP G:'GE SENSæ NOTE : ( HT'JI¡AUlIC CC~TROL STST(II fOR BOP SHCK a CHOKl . 11A~:fOLD TO "CLUD( (5) STATi~ CCNT ROL IlAIIlfOLD l0C~T £0 R[ "'GTfLY 'f¡TH 3000 PSI ACCC\lULATOR 8 160 GAL R[5[1<,<;)IR a AUX. (/;(RGY SOURC£. (5! S TA WNT ROL 1/ A~lrOlO PUIS V!.R IABLE ChOKE c.c~Ti1OL TO BE IDCATEO ON RIG fLOOR. Z. till a CHCKl IIANlrOLDS TO ,f(ET API RPS3 ct. SII STOS. 3 KILL IItNlr<X.D SIZ( - RATING 4. CHOl( I/LNlrOLD SIZE- HYDR~UUC CONTROLLED REMOTE OPERATED DRIlliNG SPOOL HYDRAULIC CONTROLLED REMOTE OPERATED PRESSURE GAGE SENSOR ADJUSTABLE C110KE TO ATMOSPHERIC MUD/GAS SEPARATOR CHOKE B KILL MANIFOLDS FOR 95/81' a 7" 00 CASItJG BOP STACK BOP MANIFOLD LAYOUT - CONoea, INC. CHOKE MANIFOLD TO SHALE SHAKER ~ hD:Ý ~~~' ùHI )Y1 1¥ HSSOG. .--.-.,.. - ..- ~-- Q ._. __. H(,~ o -M- ~ L-i~'--L HMVO~ L~'~ Lï=-~~ I' G··, -, (",-'1M! : ""'.''''-0 , r .. ""'--' 0- - ~ ....,¡(- ..1\;0 ~/\ H'" ...... FLOW SH££ T ( AXHS£HIHOIJ$TlllUlTo. 1.- f~"'()IIoI,M...a(A'" - ,"'O..t......U2U trM.."n.i.V ~<IIO '4n (Ce,.) ..........--..---- - --- .. .___t. _..__ ,,(..... "fA ........---..--.. -.........---- þ..~... ..--- .._-~ IAIt.. ¡uti D· 1477 -02 ,¡.)I"\ ~.. - P~V OA AO" s.uChON ....Al....!. sucnc", CA Ol~è... (...ç.VA\,.V( .. . LMT£C .1..8(",4 , t ".~.t ...u....t'..) 6..~~,.V...£ 1fÂI.YI. o $2' 6' 's~vtv 'GA '''S' '-OV'l _ ..... ~ ...... NABOAS D>¡ILLNG "$II" .....c' ktf. H ( ~(- ~- 0-' o c.- -- . . '~-r ~ ,... It , , ... , I _.:J 'f 'II.l , ~ ~ ~ ~ ~ ~ ~ ,....) HOU , ..... ::'~$'l''''..c('IS ,_ _u . -.-.. - Q) f-1 ,. '- "-"': ~ ~~) . . , n Y .~. ~ ~ .' T t.. ~ ¢r-;r'i": . § r' 0 1" t--i _____3-__ --J.... L J I ... ,¿ti~."4,,I.i . I k wuo rAOVGH, r. ø :. . ","" ..,.ll' . J k:::: . .. -.~ ,.,..,.." ~if"~ ! . ..i.. ....~...., I' ) ~ ~. " ..,(11I .., I . T..... ": ~ r' _1' ~""(A I ~. UIC)(U ( ¡ ~ ¡.~~' ,: I :¡ f . I ~ ~ ... :' I ~ ~ I 'it'··, ,~ ~. ~ ~ _.~ I' ' ,.~ . "..." .".j..... .,~ ~..u,. ." L..,~ T..... _ ...~ _ .._1._ _~ g ~ ..__ __ ,__ :ffi: _ ~._ I ,. J. n. ...{.... .n, g>- t.,..". ~....~ 1 ¡ t "",0 I ~ t ~ U) , , CL( ,,(~ '.. I \ : t I~: U .. I :w:: I. ,., U) ~ I ~i.~" , I ~ Q ~ ,:1:\ t ~ ~ x ~ I :(/)~ ~ ."" "" ..,..,+"., .,): ùS rl.'.,# ,.._ ~#....,,,,,""'_') I· I !....- -- -.- -Jr- __:___L._ - :_-~ [1 $$ IYI $ AA~ ¡ : T I LJ ø --..- (J) ~ -)0- H~Ø 1·-11 A . J. wAfl~ _ HG4.( "Ll "'--$ ""'''''':,( N(,~ ¡¡¡" ...........Ll '':.1- . IÞvW P".... ....,¡( .,. I CM""'( Pv....¡ '"..~"( 11\':''-' ".. ~a _$ CU.M(A "\JO · Inc@ CONOCO, Structure : Pad E Field : Milne Point Unit Well: 7 North Slope, Alaska Location Scale 1 East --> 100.00 200 1600 2000 I 2400 2600 1200 1400 1800 2200 o 600 800 1000 200 <O<J SURFACE LOCATION. 1493' FNL. 1877' FEL SEC. 25. TUN, R10E reated by jones For: S ROSSBERG Dote plotted 21 -Mar-9 1 Plot Reference Îs 7 Version 12. Coordinates ore in feet reference slot 17. rue Vertical Depths ore reference wellhead. ~nEASTMAN LmlUCHRISTENSEN .._~C............., S 45 DEG 30 MIN E 3263' (TO TARGET) 0 0 0 0 N 400 ~ 800 0 u (j) 1200 1600 ....c -+- 2000 CL Q) 0 2400 0 2800 Ü 3200 -+- L Q) 3600 > Q) 4000 :J L '400 f- '800 I I 52C'\O V 5600 6000 RKB ELEVATION: 35' TARGET LOCATION: 1500' FSL. 450' FWL SEC. 30, T13N, R11 E KOP TVD~2500 TMO~2500 OEP~O TARGD 1VD~68OC TMD=8001 DEP-3263 SOUTH 2287 EAST 2327 300 900 15.00 BUILD 3 DEG/ 1 00 FT 27.00 33.00 39.00 EOB TVD~3791 TMD~3918 DEP~502 T/ L TVD~3895 TMO~4059 OEP~598 ~/ OB TVD~4415 TMO~4764 OEP~1075 '" 8/ 08 1YD~4450 TMO~4812 DEP~1107 , "~" ~-"OO '"O-,"~ ~,-'''' AVERAGE ANGLE 42 DEG 32 MIN 2800 200 (j) () o ro 200 0 0 0 0 400 600 800 (j) 0 1000 C -t- 1200 ~ 1400 I 1600 I V 1800 -2000 2200 ·2400 2600 1/ cap DEP=5171 TARGET / MK1 TVD~6800 TMD~8001 DEP~3263 TO / 7"UNER TVD""ì190 TMD=8530 OEP=3620 T/ LZ TVD~6890 TMD~8123 DEP~3345 \'" r- -r-¡ 400 I ----¡---M---r-~^T--~--! 1200 1600 2000 2400 3600 4000 Scale 1 200.00 Vertical S~çj¡on on 134.50 az.imuth .....ith reference 0.00 N. 0.00 [ from slo! #7 800 100 1150 1200 1250 1300 1350 1400 1450 1500 2150 2100 . ~ - - -9ÕO ;,00 . 2050 . 2000 1950 1900 1850 1800 1750 1100 _ - -- nõ -- 1150 _ - - --1 300 1200 1250 1300 ....(1) o Q) \) \) 1350 500 Ù;;~I 1400 1450 . 5tH¡- - _____1 1500 ------------ 2150 2100 2050 .2000 950 1900 1850 1800 1750 .. ..-.. I- W W lL. .........." I I- CL . lVIILNE POINT UNIT 'VELL E=7 DEPTH vs. TI11E 0 - - - - " - 2CCO - - - - \ -4OCO - - '" - - -6CCO - - ~ - -8ŒO - - - ~ -1CCOJ T T I- T ¡- 0 2 4 6 8 10 TllvE (DAYS) 12 14 " ~ () :3: <....!> () VJ 10 () ...J u " u " (/) I- - & W Q.. ...J ...J W 3 0:: o LL l- (/) - ...J If) :::,¿ 0::, ~ W 0:: . DO NOT WRITE IN ~. THIS SPACE . o z I IIIIIII I~~ II I I I I I I o · 0 · 0. . -0 () ..c u 10 +-' +-' 10 () () ~ +-' · VJ () ..--0 .c ...c() VJ+-'-O ~ :J c~ >- () .- U +-'~ C L ().- () L ~ .o.()..o+-, ·0..c101O L+-,~~ ·10 80.0'«;0. .~ 0. § § ~ E -oLL 0 ()~~()..o C OJ~ .- () () 10 ~ ~ U U () () ()CCL~-o() -0 10 IOU ()L +-,+-,IOVJ+-' 0 10 VJ VJ .- u ~ .- .- -0 () () C-o-o()<....!>~..o +-' ~ LLIO-oIO-o -0 () () U () () () 0. 0.'- +-' >- > +-'OO-oIO~O 10 L L () .- C L uo.o.-o>oo. o C () 0. -O-O:J-O()IO ()() ..c ()+-'+-'+-'()+-'() ..oIOIOC..o ..0 u u () L o 0 0 .- 0 0 +-' +-' ~ ~ U +-' +-' .- ~;¡::~EE ~~~~()() ()()():J()o.o. ~ ~ ~ VJ ~ 0 C VJ VJ VJ VJ VJ VJ 10 .......t--I........~l--4l--4u ~ II IIIII~ ~~~~~~ II~ ~I ~I~~I~~ II~ ~I~I~I'I~ I .>- >-10 +-'-0 L I IOLrI 0....... E () 0. VJ - +-' () U .-0 L . () o .-0 ~ -0 () . <....!> () () c-oc () æ ~ 3 ~ -oCIOIOC C > o L 0 L () ..o()Lo.:J -oo.ocr 10 L 0. L .- OlOo.C () 0.:J > C () 10 10 0 > 10 ..c .- .- L +-' +-' () () LIOIO§> o > L 10 +-,L+-' ..c 10 () VJ C L VJ·- ()CC()~ 0. 0'- VJ () o u E 10 ~ -0 () VJIOIO~VJ () () o VJ VJ VJ 0 0---0 .+-, VJ . L . :J . ...0 VJ . ·OJ .-0 C C 10 L () ...0 : § . C . L .+-, " .-0 ()VJ·C ().u O·tr\· +-' .IOC ·0 U ·~O·VJ·.:t . () . L·- C· 1 0..:J+-, ()·O XLVJU +-'....... () () :J. () +-'<....!>-O "L C ·>-10 0 ()OO .~~LLVJVJ..o ...0 0 o.c o.~-o IOOJ+-' 01O~() ·CCULN~()-o O·-:J o·-~ ~:J VJ.¥-O L 0 ~ ·IOCC()OUOJU· .()·-o+-,..c cc-o L L U 10 C .-.- () -0 .- () .- +-' VJ VJ c-o> VJ()O ·()~O()·->-·-Lo. .co ~+-,+-,><:JO o ()!:U()()-oL .N()+-,():J~ ()o. UIO+-'-oIOCU L~COVJIOOC :J :J .- L L 0 10 0 U 0. () E 0..- -0 VJL<....!> +-'0 +-' ()+-' ÇIOL+-'1O -oU-oU().s::J~CL ()C uocr ()IO >+-':JOIOC()~Eo. ooo+-'~.¥-o~c:() L L L L 10 0 0 VJ 0. 0. OJ-O :J~ -0 L () lI).... () -0 C () OJOJ()VJ IO>()IOL cC-O:JC ·-.¥..oo ,-,-c LOJUIO..o LVJ:J+-, () .- +-'10 C(»OJ.¥()~ VJ U C () .- 0 C L () 10 E +-' U .- () 0 ~ L() ID VJ..o..o OUVJu+-,+-,1O ~() +-'1010 ccuo....+-' gt()~~~~+-'~~ -o:J>:J()ID........ cr CVJLOUUro.....-o() o ()C ()~-o u~VJ()~~.......~OIO --.,.- VJ·- 0 VJ·-·-·- VJ VJ VJ -3+-'-333............... . ...... N tr\ .:t LrI \.D r--. co (JI 0 ...... N tr\ .:t LrI r-t r-f ~......... r-I r--f ~ ~5~~ tr\ ...... C ~ ~ r"\ r"\ tr\ .:t '-J '-J .-0 () () 01 . . · +-' ..c .- 10 U VJ : &~~o.. . · () +-' · -0 10 · 10 <J · W () · +-' Q.. · CO · () OJ · ~ 0 · o.<....!> +-' · :J L ·cr() · () +-' L · ~ () · 0 > +-' VJ () r"\ . +-,.:t co 1 1>- · +-' -0 10 · VJ 01~ ··-~C'-J . 0·- +-' tr\ . ·<....!>VJIOLrI . C L I ·UO Q.. ()o:: · +-' +-' L :~.~~ëL() . ()L VJ« -o..cU(),..o () U VJ L ~ 10 LVJ()o. ..0 -0 >-0 :JE +-,~L crèõ<....!> C 0.0. () L () E LOJ~.-OVJ o U U 10 E L .- OJ () o.L~-o +-' OJ ~ ~ (/) VJ-oIO:JO N<....!> >-.-.- VJ ~ I VJ :J -0 .- ~ () C ~ L~>->mO () L 10 E +-' OJ 10 ..c () L C VJ () U ().- VJW.¥ C >~()Q..O() UO..cVJ -0.- ()OJ U () L C L 10 -0 VJ VJ 0. () () () VJ VJ L 0 0 VJ -......«00...... \.D r--. CO (JI 0 ...... N tr\.:t LrI \.D r--. CO ........................NNN NNNNNN :J ~~ ~I r"\ LrI '-J I I I I I I I .-0 () +-' · C · () VJ · () L .0. VJ VJ () C C 0 0'- N+-' VJVJ-o () 10 C C OJ 0 2 ~ U 0-0 ()~ () L~..o :J 10 10 VJ..c () VJ VJ VJ () LC~ (/)0.00 ...J L ...J()-OVJ w>()+-' 30+-'~ C :J U~()VJ ...... 10 VJ () I'- () L Cl.+-,L «Co.>- æ () () 0+-'10> .....g+-'L I- IO:J ~C-oVJ I-OVJ() (/) .- L -0 VJ 10 () >- +-' ~ " ~fßêg OVJIO~ I- () « L U () æ 0..- L o EO ...JIOVJ..c Q.. +-,.- VJ XIO()~ W-OVJ~ o O::()() -0 OLL~ «-0 LL««...... (JIO...... N N tr\ tr\ tr\ ~ ~ L () ..c +-' o r"\ \.D '-J VJ .¥ L ~ L 10 C o +-' -0 ~ VJ +-' C () ~ L LLW LLO:: ~ 00 'I () Z(/) 0 l- t>'\> -~ f\) Z f\.) ::) :::::-; õi1í ~ WO:: 0« l\. (/) ::) ..... ...JI- «« 0 ......1- I I-(/) ........... ...... Z(/) ...... (/) ~ ::5 u ...J {} 0 I;) 0 " Q.. V) 0\ :J cr () L 10 C o +-' ...... (JI , (JI N...... ,...... tr\0 c- \.D >, () 0 L·..., ~I r"\ \.D '-J ....·~~·~u~ ()3Cl. 00::