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Home My WebLink About194-126MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, October 17, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC J-13 MILNE PT UNIT J-13 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/17/2023 J-13 50-029-22508-00-00 194-126-0 W SPT 6705 1941260 1676 1927 1930 1925 1929 25 167 162 157 4YRTST P Kam StJohn 9/12/2023 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:MILNE PT UNIT J-13 Inspection Date: Tubing OA Packer Depth 183 2695 2645 2633IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS230913084931 BBL Pumped:1.9 BBL Returned:1.9 Tuesday, October 17, 2023 Page 1 of 1           MEMORANDUM TO: Jim Regg !j P.I. Supervisor '-'Red. FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, September 11, 2019 SUBJECT: Mechanical Integrity Tests Hilcorp Alaska LLC 1-13 MILNE PT UNIT J-13 Sre: Inspector Reviewed By: P.I. Supry Comm Well Name MILNE PT UNIT J-13 API Well Number 50-029-22505-00-00 Inspector Name: Bob Noble Permit Number: 194-126-0 Inspection Date: 9/10/2019 Insp Num: mi[RCNI90910161447 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well J-13 TypelnJ w TVD 6705 Tubing 1579 1W i;w i, s PTD 1941260 Type Test SPT (Test psi 1676 IA 594 2513 2464 - j v)- —f� BBL Pumped: 1.5 BBL Returned: 1.5 OA 71 256 259_ 263 Interval 4YRTST PIF P Notes: Wednesday, September 11, 2019 Page I of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg - Ii/C j1� DATE: Friday,October 09,2015 P.I.Supervisor l ( SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC J-13 FROM: Jeff Jones MILNE PT UNIT KR J-13 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry T- NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT KR J-13 API Well Number 50-029-22508-00-00 Inspector Name: Jeff Jones Permit Number: 194-126-0 Inspection Date: 9/29/2015 Insp Num: mitJJ151005105521 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min — ----- ---- Well J l3 Type Inj j W" TVD 6705 Tubing 1674 1675 • 1676 -11676 - PTD1941260 Type Test SPT Test psi 1676 IA 42 2515 - 2480 2463 - Interval 14YRTST P/F P OA 39 303 - 298 290 . Notes: 1 well inspected,no exceptions noted. Sat4tii Friday,October 09,2015 Page 1 of 1 .. .. ,.:.'.m i .. :'x: m^awrwp.a+Yt'Y.. w v2 n' •. rn ^siq•,rM'2"C.5a � ': wMk4Y ac ro . x rw x ..... ...r. w e—rv. .... ... ., • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 NEDFEB 2, 1 ZCla Mr. Tom Maunder , i Alaska Oil and Gas Conservation Commission r �') -T_ 13 333 West 7 Avenue �.I Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPJ -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPJ -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) MPJ -Pad 9/5/2011 Corrosion Vol. of cement Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped Final top of cement date inhibitor sealant date ft bbls ft gal MPJ - 01A 1991110 50029220700100 Sealed Conductor NA NA NA NA NA MPJ -02 1900960 50029220710000 Sealed Conductor NA NA NA NA NA MPJ -03 1900970 50029220720000 Sealed Conductor NA NA NA NA NA MPJ-04 1900980 50029220730000 Sealed Conductor NA NA NA NA NA MPJ -05 1910950 50029221960000 Dust Cover NA NA NA 3.4 9/5/2011 MPJ-06 1940950 50029224930000 4 NA 4 NA 8.5 8/21/2011 MPJ -07 1910970 50029221980000 3.8 NA 3.8 NA 3.4 8/21/2011 MPJ -08A 1991170 50029224970100 18 NA Need top job MPJ -09A 1990114 50029224950100 Sealed Conductor NA NA NA NA NA MPJ -10 1941100 50029225000000 Sealed Conductor NA NA NA NA NA MPJ -11 1941140 50029225020000 Sealed Conductor NA NA NA NA NA MPJ -12 1941180 50029225060000 Sealed Conductor NA NA NA NA NA - MPJ -13 1941260 50029225080000 1 NA 1 NA 3.4 8/21/2011 MPJ -15 1991070 50029229520000 Dust Cover NA NA NA 5.1 9/5/2011 MPJ -16 1951690 50029226150000 1.8 NA 1.8 NA 11.1 8/20/2011 MPJ -17 1972080 50029228280000 0.8 NA 0.8 NA 8.5 9/5/2011 MPJ -18 1972200 50029228340000 1.3 NA 1.3 NA 17.0 9/5/2011 MPJ -19A 1951700 50029226070100 2.2 NA 2.2 NA 15.3 8/20/2011 MPJ -20A 2001850 50029228320100 5.8 NA 5.8 NA 65.5 9/5/2011 MPJ -21 1972000 50029228250000 3.5 NA 3.5 NA 28.1 8/20/2011 MPJ -23 2001200 50029229700000 0.8 NA 0.8 NA 10.2 11/1/2009 MPJ -24 2001490 50029229780000 Open Flutes - Treated MPJ -25 2040730 50029232070000 1 NA 1 NA 8.5 8/21/2011 MPJ -26 2040640 50029232050000 1.2 NA 1.2 NA 11.9 8/20/2011 . • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, October 04, 2011 TO: Jim Re , ( P.I. Supervisor Sel SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC J -13 FROM: Bob Noble MILNE PT UNIT KR J -13 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry )- NON- CONFIDENTIAL Comm Well Name: MILNE PT UNIT KR J -13 API Well Number: 50- 029 - 22508 -00 -00 Inspector Name: Bob Noble Insp Num: mitRCN111003062106 Permit Number: 194 - 126 - Inspection Date: 10/1/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well J -13 'Type Inj. W ' TVD 6705 • IA 310 2105 - 2090 2090 - P.T.D 1941260 ' TypeTest SPT Test psi 1676 - OA 40 230 220 225 — Interval P/F P ' Tubing 1600 1600 1600 1600 Notes: i Tuesday, October 04, 2011 Page 1 of 1 MPJ-13 (PTD #1941260) Classifie~Under Evaluation ~ Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Inte ri En ineer NSUADWWelllnte rit En ineer BP.com ~ t9 ~0~ 9 ty 9 [ 9 Y 9 @ I ,~ t~ Sent: Tuesday, October 16, 2007 9:05 PM Kc~~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); MPU, Well Operations Supervisor; MPU, Wells Ops Coord; NSU, ADW Well Operations Supervisor; MPU, Field Lead Tech; Rossberg, R Steven; Engel, Harry R Cc: NSU, ADW Well Integrity Engineer Subject: MPJ-13 (PTD #1941260) Classified as Under Evaluation AI I, MPJ-13 is a produced water injector that was secured and reclassified as Not Operable when diesel was reported leaking from the starting head on 10/09/07. The well passed an MITOA w/N2 on 10/16/07 proving the surface casing competent. In addition, the well passed an MITIA on 10/05/07. After further diagnostic work, it appears that the diesel spilled over the conductor due to therms( expansion. DHD has removed approximately 2" of gravel and fluid from the conductor by surface casing annulus to allow for thermal expansion. In addition, the temporary cellar liner has been left in place as a precaution for when the well is returned to service. The plan forward is as follows: 1. S: Pull TTP 2. PE: Put well on injection classified as Under Evaluation 3. D: Monitor to ensure diesel is not leaking from conductor into cellar liner .... •.--...~•~~•-z~~ 4. WIC: Reclassify as Operable if no indication of leakage Please call with any questions or concerns. Thank you, ~ ~~~~ ~t ~ ~~~~ Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 f ..~.__.-~..___._.__.~......_ 10/19/2007 MPJ-13i possible surface casing lea . Page 1 of 1 Regg, James B (DOA) From: MPU, Wells Ops Coord [MPUWeIIsOpsCoord@BP.com] ~ t_i (~~0.~ Sent: Tuesday, October 09, 2007 5:47 PM ~~ ~l~ To: NSU, ADW Well Integrity Engineer; MPU, Well Operations Supervisor; Regg, James B (DOA) Subject: MPJ-13i possible surface casing leak ~~ ,4 Anna and Andrea, Well MPJ-13i Produced Water Injection Well- Possible surface casing leak. On 10/9/07 the pad operator found that the cellar was contaminated with diesel and upon further investigation he noticed that the diesel appeared to be coming from the Braden head. He shut the we{I in and notified me that there was a problem. Current status is: The well is shut in and freeze protected and slickline is moving over to set a plug in the XN nipple to secure the well. It looks like the diesel is coming out the cement circ ports on the conductor and not the Braden head. The flow rates are eratic on this well which correlates to the fluctuation of the annulus pressures. I would like to request that the DHD crew come over and trouble shoot this well to verify if we have an integrity problem. Thank you, Rob Handy MPU Well Operations Coordinator (907) 670-3387 (907) 670-3390 Fax MPUWeIIsOpsCoord@bp.com 10/ 16/2007 MEMORANDUM TO: ~ Jim Regg l / P.I. Supervisor 1 Z '~ ~ ~t f "t L~ ~C FRO,NI: Lou Grimaldi Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, October 08, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC J-13 MILNE PT UNIT KR J-13 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~ j~.~- Comm Well Name: MILNE PT UNIT KR J-13 Insp Num: mitLG07t005I22200 Rel Insp Num: API Well Number: 50-029-22508-00-00 Permit Number: 194-126-0 Inspector Name: Lou Grimaldi Inspection Date: to/5%2007 Packer Depth ~ Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ J-13 ~TYPe lnj. ~ W ~ TVD 6705 ~ IA 780 ~~ 2020 _ ~ 2000 ~ 1990 , ~ ~ P.T. ~ 1941260 '~TypeTest I SPT ~~ 'l'est pSl ~i ~ 2020 -~ QA f _ 270 0 400 ~~ AOO T ~~ P , i~ Interval 4YRTST P~F Tuhing ~ 1950 ~~ 1950 1950 j 1950 NOteS• Oberved pretest conditions for 15 minutes "OK". 1.1 bbl's pumped. Monday, October 08, 2007 Page l of 1 . STATE OF ALASKA . AL . OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS D D D 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Opera!. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 65 KB 8. Property Designation: ADL-315848 11. Present Well Condition Summary: Total Depth measured 9750 true vertical 7486.15 Effective Depth measured 9647 true vertical 7396.03 Casing Conductor Surface Production Length 80 2804 9704 Size 13-3/8" 48# H-40 9-5/8" 36# L-80 7" 26# L-80 Perforation depth: Measured depth: 9206 - 9222 True Vertical depth: 7011.51 - 7025.42 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations x Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development Stratigraphic D feet feet Stimulate 0 Other 0 chem cut tubing WaiverD Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: :> iii" en Exploratory Service 194-1260 M 6. API Number: 50-029-22508-00-00 Plugs (measured) Junk (measured) None 9108 2 <- > C) :z = I» n c.e t-:I :::r ... e I» co CD 9. Well Name and Number: MPJ-13 10. Field/Pool(s): Milne Point Field/ Kuparuk River Oil Pool ¿.; ~¡r I ;'~ Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 869 620 1380 700 15. Well Class after proposed work: Exploratory Development 16. Well Status after proposed work: Oil D Gas D WAG feet feet MD 33 - 113 31 - 2835 28 - 9732 9230 - 9238 7032.38 - 7039.34 3-1/2" 9.2# 4-1/2" Baker SABL-3 Packer 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal Signatu Form 10-404 Revised 04/2004 TVD 33 - 113 31 - 2477.09 28 - 7470.4 Burst 1740 5120 7240 Collapse 750 2370 5410 9314 - 9334 9346 - 9382 7133.28 - 7164.62 7105.43 - 7122.83 L-80 27 - 8900 8851 RBDMS 8Ft ./UN 2 1 2006 Tubing pressure 2161 1704 Service p WINJ M WDSPL Sundry Number or N/A if C.O. Exempt: 306-142 Title Data Mgmt Engr Phone 564-4424 nR\G\i\JAL Date 6/14/2006 Submit Original Only -- . MPJ·13 I ~ESCRIPTION OF WORK COMPLET NRWO OPERATIONS EVENT SUMMARY FLUIDS PUMPED BBLS 5 Flopro 125.5 Meth 507 1 % KCL 13.8 Acid 247 Crude 170 Diesel 1068.3 TOTAL I ACTIVITYDATE I SUMMARY I 4/20/2006 *** MIRU CTU # 9 *** RIH with 2.375" Underreamer ( blades to 5.75") Tag and stall motor at 9342' ctmd. Underream down to 9634' ctmd. at 7 fpm taking returns to tanks. Tag at 9634' and stall. PU off bottom and unable to free stalled motor. PUH 76' to 9558' and unable to move pipe or pump down coil. Pressure up coil to 6800 psi and unable to rupture burst disc after several attempts. Able to inject down backside at 3.1 bpm at 2900 psi WHP. Spot 15% DAD acid across perfs down the backside letting acid soak while trying to work the coil up and down. *** Continued on WSR 04/21/06 *** 4/21/2006 ***Continued from WSR 04/20/06*** Continue attempting to work pipe up and down.Displaced backside with HOT crude to perfs, unloaded well to well # 7 flowline and attempt to surge WHP while working coil up and down. Wait for 80' manlift. Wrap injector and gooseneck and apply heat, pump hot diesel down backside. Continue to work pipe while flowing to well # 7 flowline. Unloaded the well to return tanks to nearly 0 PSI while applying pressure to coil attempting to rupture burst disk. Shut in and load the backside with hot diesel.*** Continued on WSR 04/22/06 *** 4/22/2006 *** Continued from 04/21/06 WSR *** Allow time for possible ice to thaw while applying more heat to injector and lubricator. Attempt to circulate down the coil. No luck. Inject down 1 % X-SLK the backside. Able to get 4.9 bpm at 2770 psi WHP. SD and dump WHP while coil in tension. No movement. Pump with 2 pumps - get 5.4 bpm. No movement. Change out blown O-ring on lubricator, PT lubricator, PT good. Re-wrap exposed lubricator and apply heat then attempt to surge a 3/4" disconnect ball around coil and over gooseneck. *** Continued on 04/23/06 WSR *** 4/23/2006 *** Continued from 04/22/06 WSR *** Drop 3/4" disconnect ball, surge around coil and over gooseneck. Ball confirmed over gooseneck, continue surging coil to seat ball on disconnect. Took coil up 7500 psi. Unable to disconnect. Displace backside to perfs with N2 at 1500 scf/ min. Flowback to tanks and attempt to disconnect and pull pipe free. Appeared to have disconnected but unable to pull free. Prep to cut pipe. *** Continued on 04/24/06 WSR *** 4/24/2006 *** Continued from 04/23/06 WSR *** Kill well with 11.6# brine w/safe lube, monitor well for losses. Fluid level appears to be stable at -526'. Cut coil on surface. RU E-line and RIH with 1.25" OD chem cutter. Cut coil at -9100' MD. Good indication of cut, POOH with E-line while LRS displaced coil with kill weight fluid. *** Continued on 04/25/06 WSR *** 4/25/2006 *** Continued from 04/24/06 WSR *** Rig down E-line, reconnect to cut coil at surface to CTU, POOH with coil. Close swab with 454' showing on coil depth counter. Blow down coil with N2. RDMO. Notified Pad Op of well status. MPU operations instructed Pad Op to POI. Job complete. Road unit to shop to weld coil. *** Continued on 04/26/06 WSR *** Estimated top of coil fish = 9108' ctm. Re: J-13i Sundry Approval e e Danielle, I will see that the sundry is sent when finalized. Unfortunately, it may not be signed today. Sorry about that. You may proceed with your plans to cleanout and acidize the well. Tom Maunder, PE AOGCC \~L-\_\~ Ohms, Danielle H wrote, On 4/1812006 3:03 PM: Tom, Fax # is 564-4440. Appreciate your expediting this approval through for us. Thanks. Danielle From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us]........ ~. âJ~. of, Sent: Tuesday, April 18, 2006 2:43 PM b)'..,AN~~Et»n{ t....l~ ). To: Ohms, Danielle H Subject: Re: J-13i Sundry Approval Danielle, What is your fax. I would expect the sundry to be signed within the hour and we can send it to you. I do not see any problem with proceeding to plan the job to take advantage of the coil availability. Tom Maunder, PE AOGCC Ohms, Danielle H wrote, On 4/1812006 2:32 PM: Tom, Per our phone conversation, would like to get a verballe-mail approval to go ahead with the acid stim on Injector J-13i, for which a Sundry was just sent to you. Want to keep the Coiled Tubing Unit busy on MPU J Pad while waiting to go back to H Pad for some jobs. The CT unit would be ready to move to J-13i for the fill clean out part of the job today/tonight and likely be wanting to finish up with the acid stirn tomorrow. Thanks! Danielle 1 of 1 4/19/2006 2:48 PM @ 1f"'MlJ rç ® ¡fryj, l6 e (mrrr rr ¡...., ~Lr e AI~ASIiA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR Timothy Lee Petroleum Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 St(" 1£ h. "!!.'. . t;.~ k:', H . ~V~f)n~~::.r).1 {\ \qL\- ~~ Re: Milne Point Field, Kuparuk River Sands Oil Pool, MPJ-13 Sundry Number: 306-142 Dear Mr. Lee: Enclosed is the approved Application for Sundry Approval relating to the above referenced welL Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may me with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this/9 day of April, 2006 EncL a r STATE OF ALASKA (5J:r ~/I~ ;,t::.t;t::IVI:::U A~ Ol~ AND GAS CONSERVATION COMM_ON #L\h~ IJ.¡""r< 1 8 t'006 APPLlcAtnoN FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon Alter casing 0 Change approved program 0 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): Suspend Repair well 0 Pull Tubing 0 Operational shutdown Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Development 0 Stratigraphic 0 Perforate Stimulate 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to ~umber: Exploratory 0 194-1260 . Service ~ 6. API Number: 50-029-22508-00-00 -/ 9. Well Name and Number: 65 KB MPJ-13 - 8. Property Designation: ADL -315848 11. 10. Field/Pools(s): Milne Point Field / Kuparuk River Sands Pool PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9750 7486.15 ' 9648 7396.9 None None Casing Length Size TVD Burst Collapse Conductor 80 13-3/8" 48# K-55 33 113 33 113 2730 1130 Surface 2804 9-5/8" 36# L -80 31 2835 31 2477 5120 2370 Production 9704 7" 26# L -80 28 9732 28 7470 7240 5410 Perforation Depth MD (ft): 9206 - 9222 9230 - 9238 9314 - 9334 9346 - 9382 Packers and SSSV Type: Perforation Depth TVD (ft): 7011.51 - 7025.42 7032.38 - 7039.34 7105.43 - 7122.83 7133.28 - 7164.62 4-1/2" Baker SABL-3 Packer Tubing Size: 3-1/2" 9.2# Tubing Grade: L-80 Tubing MD (ft): 27 - 8899 Packers and SSSV MD (ft): 8851 12. Attachments: Descriptive Summary of Proposal ~ Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Date: 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 Plugged 0 WAG 0 GINJ 0 WINJ ~ Service ~ Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name ~ Title Petroleum Engineer Signature Phone 564-4038 Date COMMISSION USE ONLY 4/27/2006 Abandoned 0 WDSPL 0 Prepared by Sharmaine Vestal 564-4424 Timothy Lee 4/13/2006 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Othe r: ":2 r-r"'\~ '\'> '" ........... '"' ..)C)'-J'-J ~ '5" , -'" '4"-.\, ~_\...) ~ RBDMS BFt APR 1 9 2006 Subsequent Form Required: ~ Approved by: APPROVED BY THE COMMISSION Date: 4- -( B .,()6 /;7 , Su~t in D~licate A:::~ ~~ ¥-/B·DÞ e e To: John Cubbon/Clint Spence Wells Ops Supervisor Date: April 11th, 2006 From: Tim Lee (x4038) lOR: 50 bopd Subject: MPJ-13i FCO COST CODE: MKJPDWL13 ESTIMATED COST: $40,000 I 1 Ic I Wash tbg/ FCO/Perf Acid Wash OBJECTIVES MPJ-13i needs a FCO to re-establish injection into the A2 sands. The bottom perf is at 9382' MD and ideally the FCO should cleanout to TD at 9648' MD, leaving 266' of . rathole. At least 50' of rat hole should be established so that warmback passes can be performed during future IPROF's, but a FCO to TD would be desired. After the cleanout is complete, jet 10 bbls of7.5% DAD acid across the A2 Sand perfs only (9346' MD- 9382' MD) while squeezing away. Try to avoid stimulating the A3 sand (9314' MD- 9334' MD) with acid, as it already takes 63% of the current injection. ~ BACKGROUND Injector MPJ-13i has fill covering the A2 Sands which needs to be cleaned out. A tag on 4/10/06 indicated fill at 9324' MD, showing all of the A2 sands are covered. The current injection rate is approximately 1100 bwpd, with a target of 1200 bwpd. The A2 Sand accounts for 30% of OOIP in this HD. " The last SBHP was performed on 2/7/95, registering a pressure of3420 psi. This cleanout will prep the well for an IPROF as well as improve injectivity into the A2 Sands. Getting this IPROF will help meet MPU's state reporting requirements for 2006, in addition to the value of the surveillance data. A separate request will be sent out for the IPROF. Please allow for approximately 2 weeks of injection post-c1eanout before the IPROF is performed. Note: *The tbg size is 3-1/2" *Min ID = 2.75" @ 8888'MD (XN Nipple) *Max angle 50 deg @ 3202' MD *Max DLS 5.1 deg at 3677' MD e e SCOPE 1. RU CT. 2. Jet possible schmoo build-up offtbg. 3. FCa to TD @ 9648' MD (clean out to at least 9432'MD). 4. After ensuring fill returns have been sufficiently circulated out, jet 10 bb1s of 7.5% DAD acid across A2 Sand perforations only (9346' MD-9382' MD) and squeeze away (avoid getting acid above 9330' MD, as much as possible, to keep out of the A3 Sands; increased injectivity there is not necessary). 5. POOH while taking returns to surface (ensure some loss). 6. RD CT. 7. Immediately return well to injection at an initial target rate of 1200 bwpd. Tree: 3 1/8" - 5M Ca Wellhead: 133/8" 5M FMC Universal Slimhole system w/ 13 5/8" FMC Tubing Hanger, 3.5" NSCT lift threads, 3" CIW "H" BPV profile 13 3/8", 48 ppf, K-55, BTRC. MPU J - 13i ORI . KB. ELEV = 63.7' (N 22E) ORIG. GL. ELEV = 34' RT To Tbg. Spool = 27.1' (N 22E) ~J .. KOP @ 500' Max. hole angle = 46 to 49 deg. f/ 2250' to 8150' Hole angle through perfs = 29 deg, 9 5/8", 36 ppf, L-80 Btrc. I 2835' md I~ ~ 7" 26 ppf, L-80 NSCC casing (ID = 6.276", cap .= 0.0383 bpf) 4 ~ 7" Howco ES Cementer I 5584' md I 3.5", 9.2 ppf, L-80, EUE and NSCT (10 = 2.867", cap. = 0.0087 bpf) Min. tbg. ID = 2.75" in 'XN' npl. at 8,888' md Stimulation Summary None performed ~ t--- ~ t--- Baker 7" x 4.5" K Anchor I 8850' md I Baker 7" x 4.5" 'SABL-3' I 8851' md I pkr. HES 3.5" 'X' npl. (2.813 PB) I 8877' md I HES 3.5" 'XN' npl. (2.75" no-go) Wireline Re-entry guide I 8888' md I I 8899' md I Perforation Summary Ref loa:SBL/GR/CCL 10/15/94 t--- '----- SIZE SPF NTERVAL TVD) 4" 4 9206' - 9222' (7012'-7026') 4" 4 9230' - 9238' (7033'-7040') 4" 4 9314' - 9334' (7106'-7123') 4" 4 9346' - 9382' (7133'-7165') Two 7"x 21' marker joints @ 8935' to 8977' 4" hollow carriers loaded w/ 32 gm. Alpha Jet charges (EHD=0.5", TTP=32.0")@ 90 deg. phasing /' IORIG. PBTD 7" 26#, L-80, BTRS I 1 9648' md I 19732' md I DATE REV. BY 1 0/09/94 02/19/95 1/12/04 DH / JBF JBF Lee Hulme COMMENTS Drilled & Cased by N 22E Completion String run by N 4ES Correct drawing to show lower perfs MILNE POINT UNIT WELL J-13i API NO: 50-029-22508 BP EXPLORATION (AK) J-13i Sundry Approval e e Tom, Per our phone conversation, would like to get a verbal/e-mail approval to go ahead with the acid stirn on Injector J-13i, for which a Sundry was just sent to you. Want to keep the Coiled Tubing Unit busy on MPU J Pad while waiting to go back to H Pad for some jobs. The CT unit would be ready to move to J-13i for the fill clean out part of the job today/tonight and likely be wanting to finish up with the acid stirn tomorrow. Thanks! Danielle 1 of 1 4/18/2006 2:41 PM r( WELL LOG TRANSMITTAL { j9Jj-/dtp C!I2S11. ProActive Diagnostic Services, 'nc. To: State of Alaska AOGCC 333 W. 7th Street Suite 700 3001 Porcupine St. Anchorage, Alaska 99501 RE: Distribution - Final Print[s] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1389 Stafford, TX 77497 BP Exploration(Alaska), Inc. Petro-Technical Data Center LR2-1 900 East Benson Blvd. Anchorage, Alaska 99508 ." LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT(S) OR CD-ROM FILM BLUELINE Open Hole 1 1 1 MP J-13i 2-5-2004 Res. Eva!. CH 1 1 1 1.)!J '-1' I Lv '-' Mech. CH 1 Caliper Survey Signed: ""'.-."'. -.. ~ ~ .~ O\---~ ^0<\~J~s.-~~A"- PRoAcTivE DiAGNOSTic SERviCES, INC., Date: --REeEtVED F EB 1 :.) 2004 ..Þdaska Oil &; Gas Cons. Commision Anmorag8 PO Box 1 ~69 STAffoRd TX 77477 Print Name: Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com ~ ~fY\~ i§(ÇA~NEn n:B 2 @ 2004 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich DATE: October 14, 2002 Commissioner , , ~ SUBJECT: Mechanical Integrity Test THRU: Jim Regg ':~f~,. ib/¢-/~~'~ BPX P.I. Supervisor MPU J Pad FROM: Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. WellI J-13 ITypelnj.I S I T.V.D. 16704I ~ooo I~ooo I~ooo I=ooo 4 P.T.D.I 194-126ITypetestl P ITestpsil 1676 I Casingl 0 I 2500 I 2440 I 2420I P/F [ P Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: Type test IType Inj. Type test IType Inj. Type test Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to BPXs MPU J Pad and witnessed the routine 4 year MIT on well J-13. The pretest tubing and casing pressures were observed and found to be stable. The pressure test was then performed with the well demonstrating good mechanical integrity. M.I.T.'s performed: 1_ Number of Failures: O Attachments: Total Time during tests: 1 hour cc: MIT report form 5/12/00 L.G. 2003-1014_M IT_M P U_J- 13_cs.x Is 10/23/2003 ANNULAR INJECTION DATA ENTRY SCREEN Asset MilD.e. .......................................... Rig Name ~.{tb.Ql'.~..22E,, ............................. Inj Well Name [V.I..P..,J.:.I.:~ ...................................... Legal Desc 2,3..I..9.'.bI~.L.:3J.7.9.'.~.E,L,..~;.e.~.21].,.'['.;I.;].[q,.BJ.0E .................................. Research ....................................................................................................................... C.~.r.e.~l,~.d..~.(~py..~.e.~LtQ. AO.q.C.C.. ~.o. 2:;~:.~Z ..................... Permit Start .......... [,/.1/9..4; ......... Permit End .......].~.:3J].9..4. ....... Sur Csg Dep 2.8.:3.5. ....... : ........ Cumulative Data 'Rig Well Total Mud/Ctg Wash ........ 1.4.,.127- ................ .1.~,2~2 ................... .6..4.5. ......................................................................... :...,:....{~.Q.: ..................... 1.3.0 ...... ::... *Permit Expires in 30 Days or Less* Completion Formation Intermittant Final Fluids Fluids Freeze Freeze Dai y Data Well Injedion ~ I I I '": Fbi:b ~' Total Rate PreSsure .Status Cx3'lZna'ls~ · · I~ii53'"'~"~ ....................... :['b70'~7~ .................... ~?(J ........................................... ~'~'~ .......................................................................................................................................................................................................................................... :['i~'~'~ ......................... Open 1994 YEAR END SUMMARY MPJ-13 10/09/94 60 60 MPJ-19 10/17/95 160 160 1995 SUMMARY ~ pj.-~.~ .................. {.67.~.§?~ ............. ~-.;~. ............... -1-~.~ ................................................................................................. 1,110 .......................................................................................................................... MPJ-19 10/19/95 185 185 MPJ-19 10/20/95 320 320 MPJ-19 10/21/95 475 475 N19...... .!.,..0.,(...2....2.../....9.,.5.. ..................... ...7..,,0...,..0.. ................................................................................................................................................................................................................................................................ ..7,..,.0.....0... ................................. ,,~eJ-19 10/24/95 280 280 ~i5,]:: 'J9 ~ 0/25/95 52~J ..... 520 MPJ-19 10/26/95 600 600 MPJ- 19 ~ 0/27/95 420 420 __ -- MPJ-19 10/28/95 410 410 MPJ-19 10/29/95 900 900 MPJ-19 10/30/95 325 60 385 MPJ-16 ......................................................................................................................................................................... 11/02/95 1,400 ~ .......................................................................................................................................................................................................................... ~";';~'~J~J ................................................................................................................................................................................................................... .................................................... ~ .......................................................................................................................................................................................................................................................................... ; MPJ-16 11/04/95 110 110 ......................................................... -- ................................................................................................................................................................................... MPJ-16 11/05/95 617 617 MPJ-16 11/06/95 480 480 MPJ-16 11/07/95 508 508 iVi'i~'J:~"~ .......................... ~'"~"/6~ ...................... ~'~ ......................................................................................................................................................................... : ............................................................................................................ ' ............ '~'?~' .................................................................................................................................................................................................................................... ~'lS'~J :'¥~ ............................................................................................................................................................................................................................................................................................................................................................................................... 11/09/95 170 ~'~ ...................................................................................................................................................................................................................................... ,MPJ-16 1 III 'l/gb I~/ ' MPJ-16 11/15/95 810 810 MPJ-16 '1-~']~'~/9'--~ .......... 310 310 ~l~j.,-.i.,~ .......................... ii 'imi '~' ' ~i~ ~ ..................... ~'66 ..................................................................................................................................................................................................................................... ~66 ............................................................................................................................................................................................................... ~ ................................................................................................................................................................................................................................................ ,,~ , ........................................................................................................................................................... , ............................................................................................................................................................................................. ~ ................................................................................................. ...... ....................................... . ................................................................................................................................................. .......................................................................................................................................................................................... ; ........................................................................................................................................................................................................................................... ~ ...................................................................................................................................................................................................................... .............................................................................................................................................................. ................................................................................................. , .......................................................................................................................................................................... , ........... ""~'~":'~7 .......................................................................................................................................................................................................... ~, ,.'. , ....... . __ .. ~ ". ,o. [:"L.. ....... i~'2 __ , ............................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................. ..... .................................................................................................................. j ........................................................................ ................................................................................................................................................................................................... ................................................................................................................................................................................................................................................................................................................................................................................................................................................................................. . ........................................................................................................................................................................................ are.d rvlces rilling 900 East Benson Boulevard, MB 8'1 · Anchorage, Alaska 99508 (907) 561-5111 Fax: (907) 564-5193 December 14, 1998 Wendy Mahan Natural Resource Manager Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501-3192 RECEIVED Re: Annular Disposal Information Request Dear Ms. Mahan: DEC 14 1998 Naska Oil & Gas Cons. Oommi~ion Anchorage On October 28, 1998 you requested an update from Shared Service Drilling regarding Annular DispoSal Records from July 25, 1995 through present time. We compared your list with our records and are able to provide yOu with the following data: · Individual Annular Disposal Logs from the ssD database which coincide with the approved wells on your attached AOGCC Annular Log. The.SSD records are provided to you in the same order as listed on your log. There were some wells'on your list which were not injected into. These wells are identified as follows: · Endicott wells 1-03/P-16, 1,65/7q-25, 1-59/0-24 · EXploration well Pete's Wicked #1 · Milne Point wells E-22, E-23, F-O1, L-16, J-19, L-25, F-30, L-21, K-38, NMP #1 & tV2, K-05, K-02, H-07, K-25, K-37, E-17, F-21, K-30, K-34, K-21i, F-66, K-06, K-54, K-33, F-49i, K-18 · PBU Wells E-38, 18-34, 15-42, S-29A, 15-46, B-36, 15-43, 11-38 · The reason many of these annuli were not used is because the waste materials generated from these wells were injected into other approved annuli. Hopefully the injection logs submitted with this letter will clarify this: In addition, please note that our records show: · The wells listed above in italics were permitted but not used for annular disposal. · The wells listed above in BOLD were not Permitted for annular disposal. Wells drilled after June 6, 1996 were required by SSD procedure to be permitted with a Sundry Approval (10-403) form. Our records show that no Sundry Approval for Annular Disposal was filed for these wells. Wells drilled between July 25, 1995 and June 6, 1996 were automatically approved for annular disposal with the Permit to Drill. We also provide you with a cumulative report from our database of records from July 25, 1995 through the present. FrOm those records, we show. the following wells not listed on your report were used for annular disposal:- ,.Annular Disposal Letter 12/14/98 ! · Endicott wells 1-23/O-15, 1-61/Q-20, 2-40/S-22 · Exploration well Sourdough #3 -_ ~=oo ~4 ,~ - · ~vnme yoint wells F-06, H-05, H-06, J: 13, L-24 ' ~ s* o? o · PBUwells-18-30, 18-31, 14~4,.~-4_3, E-34, E-36, G-04A, andS-33-~'~z- · Individual logs are provided to you fo~ thes~ ~'ogs ~s we~l. · Finally, our records show that the B-24 outer annulus was left open (see attached correspondence) Thank you for the opportunity to provide clarity to these records. If I can be of any further assistance please do not hesitate to contact me at 564-5183, or Karen Thomas, Environmental Advisor at 564-4305. Sincerely, Fritz P. Gunkel Shared Service Drilling Manager FPG/KMT cc: Dave Wallace - HSE Manager (w/out attachments) RECEIVED oEc !4 ,~aska Oil & Gas Cons. (;ommissioB Anchorage f, ~arc..d SerVice Dlilling lnd~ar Injection Volumes ~ly 25, 1995 until December 1998 ~mulative Report Surface Casing Inj Well Depth ficott Cum Mud Legal Desc Cum Total & Ctgs 'on 15 1-19/I-18 5000 Sec. 36, T12N, R16E 8,960 7,848 'On 15 1-23/O-.15 4246 2020'FNL, 2087'FEW, SEC.36,T12N,R16E 32,084 30,604 on 15 1-33/M-23' 5013 3217'NSL, 2114'WEL, Sec 36,T12N, R16E 9,879 9,729 Cum Rig Cum Compl Cum Form Cumlnterm Cum Final Disposal Period Annulus Wash Fluids Fluids E[eeze . . Freeze Start End . StatUs. 992 120 12/5/95 12/5/96 Open 1,160 200 120 9/30/95 12/31/95 Open 150 8/31/95 12/31/95 Broached or~ 1..5 ... !-61/Q-20 4236 .3075'NSL,' 220-~iWEL, sec .1"3t~1"2N,. R!6E .... 2.~,.228.. 21",.3.79 .. 2,.~.!;~ .............. 1,!7~ ....................................................................................... 60..1.2!~./9.5 ........... !~.5..!96 ......................... .°.@e.n .......... on 15 2-4o/s-22 4531 2020'FNL,.2289'FEL, Sec 36,T12N, R16E 31,195 29,952 1,063 120 60' 7/25/95 12/31/95 Open ?.7! !..5;~7 ............................ ¥. 1.5 ........................... .3.~..4.0?.S.L..L..4...9..5.6. '.W.E..I~.,... ~.e..c..2.~?~.!.!...N....R..! .4..~ .............................. .3...,.~.0-2. .................................... .9..0.:~ ............................... ..2..,.._o.79 .............................................................................................................................................................................................. .9...0.. ................ 1...1..!~/?..~ ....................... !..~3..!.!.95 .............. ..._,.....0.p.e .n ................ on 14 DS 15-45 3829 4749' NSL, 5180' WEL, Sec. 22, T11N, 1,882 1,697 134 51 4/4/96 4/4/97 Broached on 14 DS 15-48 . 3548 Sec. 22, T11N, R14E 3,385. 216 820 2,283 66 12/21/95 12/21/96 Open 9n 14 DS 15-49 3667 4676' NSL, 5165' WEL, Sec. 22, T11N, 4,669 1,559 1,141 1,904 65 2/21/96 2/21/97 Open 3rt 9 · 18-30 3930 1499'SNL, 26'WEL, Sec 24,T11N, R14E 2,266 936 380 800 150 7/25/95 12/31/95 Open 3n 9 18-31 3680 3719'NSL, 64'WEL, Sec 24,T11N, R14E 6,086 2,250 1,100 2,565 171 7/26/95 12/31/95 Open 3n 9 18-32 3830 3632'NSL, 41'WEL, Sec 24,T11N, R14E 3,311 1,861 200 1,i00 150 8/24/95 12/31/95 Open ~n 9 18-33 4140 3690'NSL, 56'WEL, Sec 24,T11N, R14E 5,215 2,050 3,035 10 120 9/28/95 12/31/95 Open :)rs 18E 12-35 . 3543 348'NSL, 705'WEL, Sec 18,T10N, R14E 3,723 3,436 137 150 9/1/95 12/31/95 Open ~rs 18E 12-36 3452 63'FSL, 899'FEL, Sec 18,T10N, R15E 4,002 1,961 50 1,871 120 10/13/95 12/31/95 Open ~rs 18E 13-36 3431 1585'NSL, 5187'WEL, Sec 13,T10N, R14E 4,137 3,523 464 150 10/26/95 12/31/95 Open )rs 18E 14-44 3288 2829'NSL, 1617'WEL, Sec 9,T10N, R14E 3,974 2,319 1,535 120 8/17/95 12/31/95 Open roration 4 Sourdough #3 4236 2245'FSL, 5067' FEL, Sec. 29, T9N, R24E 5,786 4,630 1,156 1/26/96 1/26/97 Closed e -' MPK-17 3508 3648'NSL,2100'WEL, Sec.03,T12NR 11E 19,608 18,538 285 685 !00 4/18/96 4/18/97 Open !?_.2..2..~ ................... . .M.p_.c_.-..2_3" ................. ..4..9..~.! ........................ 1. 0_.3_8_ _N_ ..S_LL 2_4_0_4__W_E_ L_,......s e_c._..!_ 0.2, T 1__~3N~, ................. 2,__~06_0_ .............. __1_,_80__0. ............... 130 .................................................. .1_30___._1/2~!9_6__ ........ 1_/_2_5_/9__7_ ......... _O_p? n ..... ~rs 22E MPC-25 8595 1143'FNL, 2436'FWL, Sec lO,T13N, R10E 1,905 1,465 300 140 1/5/96 1/5/97 Open ~rs 22E MPC-26 4704 1086 NSL, 2419 WEL, Sec 10,T13N, 5,228 4,483 555 190 12/19/95 12/19/96 Open ~rs 22E MPC-28 5405 Sec 10,T13N, RIOE 425 350 75 2/15/96 2/15/97 Open Page 1 .DEC 1 1998 Cons. ;ha~'.~d oervice Drilling Inn[fl'ar Injection Volumes uly 25, 199~ until December 1998 :umulative Report Surface Casing ig Inj Well Depth abors 22E MPF-06 8766 abors 22E MPF-14 6690 ~bors 22E MPF-70 7919 ~bors.22E MPH-05 5335 Cum Mud Cum Rig Cum Compl Cum Form Cum Interm Cum Final Disposal Period Annulus Legal Desc Cum Total & Ctgs Wash Fluids Fluids Freeze Freeze Start End. S!atus . Sec 06,T 13N, R 10E 1,927 1,731 196 1/25/96 1/25/97 Open Sec 06,T13N, R10E UM 18,717 17,107 1,270 340 6/3/96 6/3/97 Open 2189'NSL, 2591'WEL, Sec 6,T13N, R10E 19,775 18,794 735 190 56 6/17/96 6/17/97 Open 2882'NSL. 4028'WEL, Sec 34,T13N, R10E 8,283 7,711 382 190 8/19/95 12/31/95 Open tbors 22E Mp.!?-06 . 7304 2824'NSL, 4044'WEL, Sec 34,T13N, R10E 8,515 8,335 180 8/5/95 12/31/95 Open ~bors 22E Mp.!.-07 2680 2339'NSL 3906'WEL, Sec 33,T13N, R10E 1,680 1,280 250 80 70 9/21/95 12/31/95 .Open !b0rs .22E~ ....... ,M..P...J.-! ,3. .............. ~.e,.3.,5 .......................... ~.~,?.'?.,,S.L.,,..3, !,, .7,.9. ?~,,L.',,. S~....2~7,!,,~,.,,,.R.!,~.,E. ...................... !.~.,.?..,7, .......................... ! 3,~ .27,2. ................ .~_4.,.5, .................................................................................................................................. 60 ..................................... !.3..0. ............. !.,0. !,!.,.7,~9.,,5, .................. 1,~!.3,.,! !.9,,.5. ..................... (~,.p.? ............. lbors 22E MPJ-16 3112 2317'NSL, 3336'WEL, Sec 28,T13N R10E 985 915 70 11/12/95 12/31/95 Open lbors 27E B-24 4080 Sec 18,T13N, R11E UM 1,468 1,396 72 1/25/96 1/25/97 Open Ibors 27E . MPF-22 8841 Sec 06,T13N, R10E UM 6,536 6,466 70 12/12/95 12/12/96 Open tbors 27E MPF-25 3405 1857'NSL 2696'WEL Sec 6 T13N R10E 9 897 9 357 250 225 65 12/26/95 12/26/96 Open Lbors 27E MPF-37 6621 1931'NSL 2643'WEL Sec 6 T13N R10E 7 032 6 887 70 75 7/25/95 12/31/95 Open ~bors 27E MPF-38 8561 1994'NSL 2731'WEL Sec 6 T13N R10E 9 232 9 157 75 12/6/95 12/31/95 Open ~bors 27E MPF-45 6678 1979'NSL, 2608'WEL, Sec 6,T13N, R10E 17,562 17,381 181 7/31/95 12/31/95 ' Open ~bors 27E MPF-62 6059 2141'NSL 2627'WEL Sec 6 T13N R10E 386 316 70 10/13/95 12/31/95 Open ~..,,b.,..o..,?.,,2....7.....E,. ........................ ..M..._p.....F...:?,. .............................. .~.,7......7.,.,.2. .................................. ..2....?-5.~.?~-L~.~.....2.~5~..2..L.w.....E-.L..~......s....e...c~.~..T...?.....N..~......R....!..~.~..~E..~ ................................... ...9....,.,,.7.?.,, .............................. ,,,9,.~.~,.5,' ............... : ................................................................................................................................................................................................................... ..7..?. ............. ?. ?, ,9.. , ,s,. , ....................... !,.~?.,~/.~..s.. .................. ,,o_p.~..,,, ............... .bors 27E MPF-78 7085 2237'NSL, 2555'WEL, Sec 6,T13N, R10E 8,476 7,456 40 775 65 140 9/12/95 12/31/95 Open bors 27E MPL-24 6515 3654'NSL 5180'WEL Sec 8 T13N R10E 6 790 4 900 1 320 165 335 70 11/27/95 12/31/95 Open 3A ~ ................................................... ,.F.:.~.3,, ...................................... _3.,¥.o. ............................... ~.3,.3._27_S_L.:,..2.?_.7.~.L.w..E.L_,.._s,,e..c...?,_T.?.,!.?.,.,,,.~.,I_.3..,E' ............................ ~.,.;.?~ ................................ !..8,.3. ........................ _~60 ......... 4__6..5. ............................................................................................................. ,~.?.. .............. ~.2.!?,6. .................... ~!.2..!_/??_ ................... ..O_p_~.n_ E F.36 3691 2642'NSL, 2878'WEL, Sec 2,T11N, R13E 6,963 1 998 1,359 3,471 135 12/18/95 12/18/96 Open yon 9 D-30 3456' 3625' NSL, 1066' WEL, SEC. 23, T11N, 5,261 2,811 1,275 1,035 140 1/31/96 1/31/97 Open yon 9 D-31 3215 SEC. 26, T11N0 R13E 150 ' 150 4/20/96 4/10/97 Open yon 9 D-33 3222 2965' NSL, 1067' WEL, SEC. 23, T11N, 4,661 2,425 2,106 130 2/21/96 2/21/97 Open bors 18E S-43 3121' 4211'NSL,4503'WEL,SEC35,T12N,R12E 5,943 2,636 1,716 1,511 80 5/7/97 5/7/98 OPEN Page 2 Shared ~e'i~ice Dr, illing Ann~i~l'r injeCtion Volumes July 25, 1995, until December 1998 Cumulative Report Sudace Casing {ig Inj Well Depth ~abors 28E B-33 3504' ..... Jabors 28E E-34 3664 . , Cum Mud Cum Rig Legal Desc Cum Total & Ctgs Wash 969'SNL, 1898'EWL, Sec 31, T11N, R14E 3,974 2,842 857' 168'SNL, 500'WEL, Sec 6, T11N, R14E 9,656 7,228 1,420 Cum Compl Cum Form Cum Interm Cum Final Fluids Fluids Freeze Freeze 195 80 858 40 110 Disposal Period Annulus Start End Status 5/1/96 12/31/96 Broached 8/23/95 12/31/95 0 :)en, labors 28E E-36 3648 1706'SNL, 822'WEL, Sec 6,'T11N. R14E 9,271 4,417 1,293 3,096 365 100 7/25/95 12/31/95 O)en labors28E E-37 3810 3391'N~L 881:WEL Sec'6Ti1N R14E ......... ~,'"~" .... ~'~i ;3-~ 8~ 9/16/g5 ' 12/3i75 "Open labors 28E E-39 3638 3358'NSL, 501'WEL, Sec 6,T11N, R14E 2,250 928 220 1,022 80 8/28/95 12/31/95 O )en labors 28E G-O4A 3509 2917'NSL, 1974'WEL, Sec 12.T11N, R13E 5,937 1,798 1,824 2,315 10/20/95 12/31/95 O )en labors 28E G-21 3509 2911'NSL 2368'WEL Sec 12 T11N R14E 11 430 3 956 3 072 4 270 70 '62 9/8/95 12/31/95 O ................................................................................................................................................... ~ ....................................... ~ ............................ ~. ..................... ~ .......................................................... ~ ............................................... :..L~ ......................................... ~ ................................................. .'. ......................................................................................................................................................................................................................................................................... labors 28E S-24 2750 1633'8NL 4228'WEL Sec 35 T12N R12E 20 261 11 773 2 177 5 751 275 285 12/9/95 12/9/96 O )en rabors 28E S-33 2958 1639'SNL, 1487'WEL, Sec 35,T12N, R12E 18,014 6,613 2,431 8,392 270 308 12/1/95 12/1/96 Open abors 28E S-41 3331 4152' NSL, 4504' WEL, Sec 35,T12N, 8,062 4 159 2 034 1 754 115 2/8/96 2/8/97 Open abors 28E S-42 3077 Sec 35, T12N, R12E 168 100 68 3/13/96 3/13/97 Open abors 2E$ H-35 3157 ' 4535'NSL 1266'WEL sec 21 T11N R13E 4 860 3 725 555 480 20 ' 80 10/26/95 ' 12/31/95 Open abors2ES H-36 3550 4478'NSL, 1265'WEL, Sec21,T11N, R13E 1,452 857 100 410 85 10/26/95 12/31/95 Open Page 3 h sred r'ij..I I]j n TO: Blair Wondzell FROM: Chris West DATE: October 27, 1995 SUBJECT: MPB-24 Well Suspension APl # 50-029-22642 Blair; Please find attached a copy of the Form 10-403 to temporarily suspend this well as per AOGCC 20- AAC 25.110. As discussed this morning we propose'setting three plugs in this well as detailed in the attached form. This will allow us to retain the wellbore for potential future sidetrack or service well use. We would like to keep the well's 9-5/8" x 7" annulus available for the injection of liquid 'wastes. There are no other well annulii on this pad for injection. The annulus for MPB-24 was approved for injection as Part of the permit dated 25 January 1996. The annulus will be freeze protected before moving the rig. Thank you for your help in this matter. Please call me if I may be of any assistance. Chris West Drilling Operations Engineer Nabors 27E (907)-564-5089 1 i/' 20/' 9 ~i:. 13, A T E .... E: t!{ C ",./D 9h--'i26 6306 ..-;f~3599---96'a.'i CH/,SR/C,SL "9h ('.) /" '1/' ,. 9,~.~~'' i~'~6 63~ 9 ~- '- '126 C D i',!/D C 9 a- '" i._ '~ 6 '~....D N / D C T V D 9a. .... i 26 CDR C OIl'lp C: C) I'1'1 d; 0 rn I/" i8/'9a. '1 i/' i~'I' 9 ~.~ i2,,.," 9/9a. I 'l/'l~/9a. oz., ...... i26 CDR/'D,~ TVD ~a-50 ..... 7t~O0 9~+--~ 126 F ~.~/' G R ~aS- 529~ ('rr:,) (? 0 I1'1 Ii,' 'i i 2/' 'i Si/' 9a '1 0 / 1 o q fl ga.--' 1~-.'~6 G R / r' r' L....... ---1°6 ,3 "~ 9a----126 ~LE//Zi".!,..I PROFZLE g4--" 126 Pl. S/STATIC ...... i 26 SBT//GR/CCL Ar"e dr'y d'i tch samp'i es Was 'l;he v,/eii cored? rece'i'ved? Ar'e we'l'J tests r'equi'r'ed?~]v~.es ~,"/e i 'J "i' 8 '}' fq COiTIp 'J 'i' ar'~ce __~~ ,3 0 i~ ivi E N T S ~ c e '¥ v e d ? f- LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Reference: MILNE POINT NORTH SLOPE, AK Enclosed, please find the data as described below: Date: RE: Prints/Films: 1 GR/CCL FINAL BL+RF Run # 1 1 PLS FINAL BL+RF Run # 1 25 September 1995 Transmittal of Data ECC #: 6280.05 Sent by: HAND CARRY Data: GR/CCL 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 ~~ - Date Received by:I/~~'/%-//~g~ '~ Please sign and return to; Petrotechnical Data Cente~ BP Exploration (Alaska) Ino 900 East Benson Boulevard Anchorage, Alaska 99508 ~eeeived by STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSlO~ ?"'~/ WELL COMPLETION OR RECOMP LETION FIEP/I:)FIT 1. Status of Well Clas of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE E~ Water I 7. Permit Num~r~ 2. Name of Operator BP Exploration (Alaska) Inc. 94-126 3. Address 8. APl Number P. 0. Box 196612, Anchora~le, Alaska 99519-6612 ....... 5o- 029-22508 4. Location of well at surface ! ~'!-ili,'"'~.~:?!~ .! ~'~?.i~,,~,Fj¢_,~.'_-..~£ 9. Unit or Lease Name 2319'NSL, 3179' WEL, SEC. 28, T13N, RIoE _ ~,.',,i';i.~ ~ ~- '~~,:':,,:,,~., ~. Milne Point Unit At Top Producing Interval ~ ~!:';;!:'!~ ' ? MPJ-13 N/A .! ,~'." "! :~..~. ~'..~~r 11. Field and Pool At Total Depth Milne Point - Kuparuk River Sands 2425' NSL, 1281' WEL, SEC. 21, T13N, RIOE 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 65' ADL 315848 19/27/942. Date Spudded 13.10/5/94Date T.D. Reached 14.~Date Comp.,~_____Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions ~-,,///¢//~,¢ NIA feet MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD', 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 9750' MD/7486' TVD 9647' MD/7396' TVD YES [] NO [] None feet MD 1800' (Approx.) 22. Type Electric or Other Logs Run GR/RES/NEU 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'f-rOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 32' 112' 24" 250 sx Arcticset (Approx.) 9-5/8" 36# L-80 30' 2835' 12-1/4" 560 sx PF "E'F250 sx "G" 7" 26# L-80 27' 9731' 8-1/2" 356 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 4" 4spf 3-1/2", L-80 8900' 8851' MD TVD 9346'-9382' 7133'-7165' 9314'-9334' 7105'-7123' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9230'-9238' 7029'-7036' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9206'-9222' 7006'- 7021' 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 3/17/95 Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SlZE IGAS-OIL RATIO TEST PERIOD ~' I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. RECEIVED MAR 2~ 1995 Alaska Oil & Gas Cons. Commission Anchora ~' Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ..~ GEOLOGIC MARKERS 30. ;'1 FORMATION TESTS NAME MEAS. DEPTH TRUE VERT. DEPTH Subsea Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Kuparuk C Kuparuk B 9131' 9141' 6881' 6890' Kuparuk A3 Kuparuk A2 9307' 9342' 7034' 7065' R £C£\\J£D M~R 2. 3 1995 1I\aS\Ia Oil & Gas Cons. CommisSiII , .AAchora'" n 31. LIST OF ATIACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge J!f¿ of} J Signed .íIt.rV( Title Drillin9 En9ineer SupervisaL Date :, ~ 1\( ( INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24 : If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage 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". Form 10-407 MP J-13 09/27/94 110' MOVE RIG FROM J-12 TO J-13. HOOK UP WATER, STEAM, ELECTRICAL LINES. NU 20" DIVERTER SYSTEM. ACCEPT RIG @0300 HR'S ON 09/27/94. 09/28/94 2,034' MODIFY BELL NIPPLE. MIX SPUD MUD AND LOAD BHA IN PIPE SHED. P/U STAND DC AND FUNCTION TEST DIVERTER. FINISH P/U BHA. SPUD AND DRILL 12 1/4" HOLE F/110-2034'. CIRC BOTTOMS UP. SHORT TRIP TO KOP @ 5oo'. 09/29/94 2,860' FINISH SHORT TRIP. NO PROBLEMS. DRILL 12 1/4" HOLE FROM 2034- 2860'. CIRC BOTTOMS UP. SHORT TRIP TO 500' KOP. TIGHT SPOT @ 2030-2080', CIRC AND COND MUD. POH. LD BHA. R/U TO RUN CASING. RUN 9 5/8" 36# L-80 BTC CASING, SHOE @ 2835'. M/U CEMENTING HEAD AND CIRC. NO LOSSES. R/U HOWCO. TEST LINES. DROP PLUG. MIS AND PUMP 560 SXS PERMAFROST "E". TAIL WITH 250 SXS "G". DROP PLUG AND DISPLACE WITH RIG PUMP. BUMP PLUG. FLOATS HELD. L/D CEMENT HEAD AND BACK OUT LANDING JT. N/D DIVERTER SYSTEM. R/U HOWCO AND PUMP 100 SX PERMAFROST "E" TOP JOB. R/D CASING TOOLS AND N/U FMC SPEEDHEAD. 09/30/94 4,160' N/U SPEED HEAD AND 13 5/8" BOPE. R/U AND TEST BOPE. ALL RAMS AND VALVES. TESTED ANNULAR. M/U BHA #2. ORIENT AND TEST MWD. RIH TO F/C @ 2751' TEST CASING, OK. DRILL F/C, CEMENT, F/S AND 10' NEW FORMATION. DRILL 8 1/2" HOLE F/2870-4160'. 10/01/94 5,650' DRILL FROM 4160-4328'. CIRC BO'I-I-OMS UP. SHORT TRIP TO CASING SHOE @2835'. WASH AND REAM F/3300-3900'. RIH. DRILL FROM 4328- 5650'. CIRC BO'I-I-OMS UP. SHORT TRIP TO CASING SHOE. HIT TIGHT SPOT @5087', RIH. CIRC HI-VIS SWEEP AROUND. DROP EMS AND POH. L/D MWD AND MOTOR. R/U ATLAS TO RUN RFT LOG. RUNNING RFT ACROSS SCHRADER BLUFF SANDS. RECEIVED MAR 2. i995 .~s~ 0il & Gas Cons. Commission Anchora ~ 10/02/94 5,876' FINISH RUNNING RFT. 14 PRESSURES TAKEN WITH HYDROSTATIC PRESSURES RANGING FROM 1983-2095'. SERVICE WEAR RING AND TOP DRIVE. M/U BHA #3. BIT, TURBINE, LWD/MWD, ORIENT AND TEST SAME. RIH TO CASING SHOE. CUT AND SLIP DRILLING LINE. FINISH RIH TO 4695'. LOG FROM 4695-5545' WITH LWD. DRILL 8 1/2" HOLE WITH TURBINE F/5650-5876'. 10/03/94 8,204' DRILL 8 1/2" HOLE FROM 5876-8204'. 10/04/94 8,900' DRILL 8 1/2" HOLE FROM 8204-8900'. DRILLED WITH ONE PUMP UNTIL 2300 HR'S. PR INCREASED F/35-100 FPH WITH 2 PUMPS. CIRC LOW/HI VIS SWEEP. SHORT TRIP TO 5600'. 10/05/94 9,685' FINISH RIH. NO PROBLEMS. DRILL FROM 8900-9047'. CHECK SURFACE EQUIPMENT, OK. LINE PUMPS UP ON HOLE. POH, WET. FOUND HOLE IN SLIP AREA 35 STANDS AND A DOUBLE OFF BOTTOM. CHECK PUMP, OK. RIH, NO PROBLEMS. DRILL FROM 9047-9685'. 10/06/94 9,750' DRLG F/9685-9750'. CBU. POH TO SHOE. TIGHT AT 4135'. WORKED THROUGH OK. RIH. PIN KEEPER ON ELEVATORS BROKE AND FELL IN DP. REPLACED ELEVATORS. CIRC AND CONDITION MUD. PUMP LO/HI VIS SWEEPS. SPOT PILL. PUMP SLUG. POH LD DP. SPOTTED LCM PILL ACROSS SHRADER BLUFF. LD BHA. REMOVE SOURCE AND DOWNLOAD MWD. CHANGE RAMS TO 7". PULL WEAR BUSHING. TEST DOORS. RU CSG EQUIPMENT. RIH W/7" CSG. 10/07/94 9,750' RIH W/7" CSG. CBU @ SHOE. LOST FILL TABS. CONT'D RIH SLOW. LOST 20 BBL'S MUD TO FORMATION. LAND CSG. CIRC. CEMENT 1ST STAGE. OPENED ES CEMENTER. CIRC 2 ANNULAR VOLUMES. PERFORM 2ND STAGE CEMENT. CLOSE ES CEMENTER. RD CSG EQUIP AND LANDING JT. INSTALL 7" PACKOFF AND TEST. CHANGE RAMS AND TOP DRIVE TO 3 1/2". TEST 3 1/2" RAMS. INSTALL WEAR BUSHING. PU BHA AND 3 1/2" DP. DRILL ES CEMENTER. RECEIVED MAR 2~ 1995 Oil & Gas Cons. Commission Ant. ri. r'.~ ". 10/08/94 9,750' DRILL PLUG AND ES CEMENTER. FINISH RIH W/3 1/2" DP. TEST CSG. DRILL 13' CEMENT TO LANDING COLLAR AT 9647'. DISPLACE WELL W/ FILTERED SOURCE WATER. FILTER WATER AND ADD 25 GAL/100 BBL'S CORROSION INHIBITOR. BLOW DOWN LINES AND POH LD DP. REPAIR IRON ROUGHNECK. CONT LD DP TO 2000'. DISPLACE 2000' W/DIESEL. FINISH LD DP AND BHA. PULL WEAR BUSHING AND BLOW DOWN LINES. INSTALL FMC FALSE BOWL AND CHANGE RAMS TO 2 7/8". ND BOPE. INSTALL HOLD FLANGE AND TEST. INSTALL CAP. CLEAN PITS. 10/09/94 9,750' FREEZE PROTECT ANNULUS W/60 BBL'S DIESEL. FINISH CLEAN PITS. RELEASE RIG @0800 HR'S 10/08/94. ~xF~ 2. ~ 1995 Alaska. 0ii & 6as Cons. Commission Anchoru BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: MP J-13 BOROUGH: NORTH SLOPE UNIT: UNKNOWN FIELD: UNKNOWN LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 02/15/95 03:00 SPUD: RELEASE: 02/18/95 10:30 OPERATION: DRLG RIG: WO/C RIG: NABORS 4ES 02/16/95 ( 1) TD: 9750 PB: 9647 02/17/95 ( 2) TD: 9750 PB: 9647 02/18/95 ( 3) TD: 9750 PB: 9647 NU BOP STACK MW: 0.0 MOVE PITS, PIPE SHED & SUB OFF MP J-09I. SET MATS & LAY HERCULITE. SET SUB, PIPE SHED & PITS. RU SAFETY EQUIPMENT. SET FUEL TANK. RU MUD & FLOW LINES. BERM EQUIPMETN. ACCEPT THE RIG @1500 HRS ON 2/15. ND DRY HOLE TREE. NU ADPTR FLNG. & BOPE. PULL BPV BOLDS. PULL DUMMY HANGER. ATTEMPT T/TEST BOPE. LEAK @ LOWER GRAY LOC CLAMP. TIGHTEN CLAMP. STILL LEAKING. ND BOP STACK. INSTALL NEW RING /DIFFERENT GRAY LOC CLAMP. NU BOP STACK. RIH W/RBP RETRIEVING TOOL MW: 0.0 REDRESS STUDS ON GRAY LOC CLAMP. INSTALL & TIGHTEN. TEST BOPE TO 250/3500 PSI; ANNULAR TO 250/3000 PSI. WITNESSING WAIVED BY DOUG AMOS - AOGCC FIELD INSPECTOR. RD TEST EQUIPMENT. SET WEAR RING. RU TO RUN TBG. FINISH DRIFT & SLM TBG. MU BAKER RETRIEVING TOOL. RIH ON 3.5" TBG TO 1200'. CIRC DIESEL CAP OUT TO FLOW TANK W/10.3# BRINE. RIH W/3.5" F/PIPE SHED TO +-3950'. WOLL STARTED FLOWING F/TBG (OUT OF BALANCE). DISPLACE 11.5# BRINE W/10.3#. WTS RUNNING F/9.7# TO 11.5#. CIRC TILL CONSISTENT. D5 DRILL--OS: 29 SEC. CONTINUE RIH W/TBG. RIH W/3.5" COMPLETION MW: 0.0 SERVICE RIG. FINISH PU & RIH W/3.5" TBG TO 9010' CIRC & EQUALIZE BRINE WT. RIH. LATCH RBP @ 9071' OPEN BYPASS & MONITOR WELL - OK. RELEASE RBP. CIRC THRU GAS BUSTER. CIRC GAS F/UNDER PLUG. MONITOR WELL - OK. POH W/3.5" TBG. LD 8 JTS EUE 8RD. CUT 102' & SLIP 42' DRLG LINE. FINISH POH W/TBG. LD RBP & RUNNING TOOL. PULL WEAR RING. MU TAILPIPE & PACKER ASSY. RIH ON 3.5" TBG. RECEIVED ~AR 2.~ 1995 A~s~/_iii & Gas Cons. Commlssio[~ Anchor~ WELL : MP J-13 OPERATION: RIG : NABORS 4ES PAGE: 2 02/19/95 ( 4) TD: 9750 PB: 9647 RIG RELEASED MW: 0.0 SERVICE RIG. FINISH RIH W/3.5" COMPLETION. MU HANGER & LANDING JT. CBU. CONTINUE CIRC & ADD 25 GAL/100 BBLS COREXIT 7726 CORROSION INHIBITOR. DRAIN STACK. LAND HANGER, RILDS. FREEZE PROTECT TO 1100' W/40 BBLS DIESEL DOWN ANNULUS. U-TUBE TO TBG. DROP PKR SETTING BALL. PRESSURE TO 4000 PSI F/30 MIN - OK. BLEED TBG TO 1500 AND PRESSURE ANNULUS TO 3500 PSI F/30 MIN - OK. TEST WITNESSED BY DOUG AMOS - AOGCC FIELD INSPECTOR. BACK OUT & LD LANDING JT. SET BPV. ND BOPE, FLOWLINE, & RISER. NU ADAPTER FLANGE. TEST TO 5000 PSI - OK. NU TREE. PULL BPV. SET TWC. TEST TREE TO 5000 PSI - OK. PULL TWC. SET BPV. RELEASED RIG @ 2230 2/18/95. SIGNATURE: (drilling superintendent) DATE: RECEIVED MAR 2 b 1995 Ai~$k~ Oil & Gas Cons. Commission ^nchora - MILNE POINT, ALASKA TO: Hendrix/Stevens FROM: Ketchum Well Name:I MPUJ-13i Main Category: IE-line Sub Category:I Initial Perforation Operation Date: IJanuar~ 19,1995 Date: I January 19, 1995 Atlas WL - - $5,000.00 AFE # 330078 II OBJECTIVE: Perform initial perforations through 7" casing and obtain a SBHP as per program. IIWHSIP= psig I IAP=0psig I OAP= 0 psig I II i ~ i · 1it i . 11 i l. ITIMEI OPERATION 0900 MIRU Atlas Wire Line, tailgate. RU slow due to wind and coordination w/ 4ES rig on J-06 1050 Establish and announce radio silence for the arming of the 4" Alpha Jet (32gm) guns 1 13 0 RIH w/ GR CCL and first set of guns 1 145 SD hard @ 1576'ELM. PU and attempt to RIH w/o results. Tag is solid and hard. 1200 At the request of the Wells supervisor, RDMO Atlas and schedule a CTU wash. RESULTS: SD on a hard ice plug in 7" casing at 1576'ELM; unable to get DH. Well file indicated a total of 65 BBLs diesel used for freeze protection which should reach a depth of +/- 1600'. RDMO Atlas and schedule a CTU wash job for tomorrow. No mishaps. Gas Cons. 6ommissi0n gnchora -' Milne Point Unit, Alaska TO: FROM: Well Name: Main Category: Sub Category: Operation Date: Steve Rossberg Date: I Jan. 26, 1995 J Jim Fox IMP J-13i PERF Initial Jan. 26 - 27, 1995 OBJECTIVE: Make the initial casing perforations in preparation for completion as WIW. Wellbore is open - i.e. no tubing - open casing to PBTD. Perform a static bottomhole pressure survey to determine initial reservoir pressure. 1/26/95 1000 - MIRU Atlas E-Line unit. SICP = 0 Psig. RIH w/4"x 30' hollow carrier perforating gun and PFC Gamma Ray / CCL tool. Correlate depth - Correct by adding 9'. Mark line. Log up to 9350' RKB. Detonate gun. Log up and POOH. All shots fired and centered. Well on vacuum. RIH w/tandem 4" hollow carrier casing guns. Tie in depth. Log up to 9323' RKB. Detonate bottom gun perforating casing from 9346' to 9352' RKB. SITP = 0 psig. Log up. RIH. Log up to 9312' RKB. Detonate top gun. Log up and POOH. All shots fired and centered. Well still on vacuum. RIH w/tandem 4" hollow carrier casing guns. Tie in depth. Log up to 9205' RKB. Pulled approx. 700 lbs. over line weight at 9314' RKB (top of last set of perforations shot ) and pulled free. Detonate bottom gun perforating casing from 9230' to 9238' RKB. SITP -0 psig. Log up. RIH. Log up to 9200' RKB. Attempt to detonate top gun. Lost all power on logging unit. Re-establish power- Guardian filter box appears to have electrical malfunction. Attempt to shoot w/o filter - open circuit. POOH. Top gun did not fire. Bottom gun - all shots fired and centered. Fluid to surface but pressure too Iow to measure. RIH W/single 16'x 4" hollow carrier perforating gun. CPU Panel power supply not functioning. Hot shot out and install new CPU. Continue RIH. Tie in depth. Log up to 9200' RKB. SlCP =0 psig. Detonate gun perforating casing from 9206' to 9222' RKB. SlCP = 0 psig. Log up and POOH. All shots fired and centered. MU HP pressure / temperature tool. Take 5 min. reading in lubricator. RIH. Correlate depth. POOH to top perforation at 9206' RKB. Record SBHP for 20 min. POOH to 9006' and monitor pressure for 10 min. POOH. Record pressures in the lubricator for 10 min. 1/27/95 - 0500 RDMO Atlas E-Line Unit. Secure wellhead. Results: Casing perforated as per program (see listing below). Wellbore fluids appear to at least initially be overbalanced relative to reservoir pressure. Upper zones may be slightly higher pressured. Gas Cons. Commission Pressure survey results: Depth Pressure ( psia ) Temperature ( deg. F ) Lubricator (initial) 66.2 42.9 (final) 47.0 56.4 9206' RKB (initial) 3107.6 171.2 (final) 3109.7 171.1 9006' RKB (initial) 3032.0 164.6 (final) 3036.1 164.6 Lubricator (initial) 142.4 60.9 (final) 144.8 69.9 While it appears that the SBHP is still building at a slow rate ( approx. 1 psi/10 min.) the reservoir pressure at the top perf is 3110 psia (3095 psig) which equates to an EMW = 8.49 ppg. Tie in log/date 10/15/94 Charges: 32 gm. Alpha Jet, EHD = 0.50", TTP = 32.0" .......... Interval Measured Depth ......... Top Ft. Base Ft. Gun Diameter Shot Density Orientation 9346' 9314' 9230' 9206' 9382' 9334' 9238' 9222' ,1 4" 4" 4" n/a n/a n/a n/a Phasing RECEIV£ ) MAR 25 1995 Uil & Gas Cons. Commission Anchors. ANNULAR INJECTION DATA ENTRY SCREEN Asset .MiJJ~P-, ........................................ Legal Desc 2.3.1.9.'.blS/,..3.1zg.:~E,L.S.ec..28.,.T,,1.3,bt,...B.1.0.E ..................... Research Rig Name .[~ab.er.s..22E ........................... · ....................................................................................................................... C~3r-rp-,ctad..c~pY.-s.eJ3L.t¢...&O.G.C.C-.Q~-2.-=25.~9.7. ......... Inj Well Name '.M.E,J,~.;I..3...'ii. ........................... Permit Start.....t. DJ..:l..ZJ..9.5... Permit End.....1..2J..3..l.J..9.5.... ' ......................................................................................................... Sur Csg Dep 2..&3.5 .............. · .............................. Cumulative Data Rig Corn pletion Formation Well Total Mud/Ctcj Wash Fluids Fluids ....... :t,.4.,..1.2Z ............ ;t.3...29.2 .......: ...... ;.6.,4.5,.~ .................................................................. I ntermittant Final Freeze Freeze ..~..,..,,..~.0.....:;:;: ............. :t.3.Q ......... I i Mud, Ctgs, Cmi I Source ! Date of i Contaminated Rig Wash [ Well I Injection i Drlg Mud Fluids Daily Data Completion' Intermiltant ' Final , Formatiol Freeze Freeze Daily Fluids ~ Fluids | Protection Protection Total Rate AnnulUs PressUre status c°rC~entS comPlications MPJ-13 870 MPJ-13 MPJ-19 MPJ-19 MPJ-19 !10/28/95 .M_..P.~_J.:...1._~. ...... !10/30/95 __M_rP J__.2-__16 !11/02/95 160 _!..,.~.~..0. ............... 32O 475 7OO 585 280 520 600 ~-;,-.~--~- 410 900 325 t i60 ) 10 ) ) ) ) ) ) , _M..._P_J_.:..1. 6 _i11/04/95 11/05/95 11/06/95 11/07/95 1/08/95 PJ-16 !11/09/95 MPJ-16 !11/11/95 MPJ-16 111/15/95 MPJ-16 11/16/95 i'1/17/95 MPJ-16 ~'1/18/95 480 508 275 170 110 617 __ I i ! 508 i 797 ~ ! ! 797 810 ! I ! ._810 ~ I 310 ! I ~310 -- ................. -- ..... --7 ............. 1 1994 YEAR END SUMMARY 1995 SUMMARY COMF'A~' BP WE. LL NAM~ MPJ-13 LOCATION 1 MILNE POI~ LOCATION 2 A~AS~ ~GHETIC D~CLINATION 28,94 GRID C~_m~' ~ERGE~E ANGLE 0,00 DATE~ ZT-SEP-94 WELL kq]MB~ 0 WELL HEAD LOCATION: LAT(~L/-S) 0.00 · DEF'(E/-W) 0.00 AZI~JTH FR~]M ROTARY TABLE TO TA~ET IS 17,10 TIE IN POINT(TIP) : MEASURED D~TH 112,00 TRUE V~RT DEPTH 112,00 INCLINATION 0,00 AZIMUTH 0,00 LATITUDE(N/-S) 0,00 DEPAE~L~:E (E/-W) 0,00 RECEIVED tvlAR 2,5 1995 A~_~ska Oil & Gas Cons. Commission Anchor~ ************* ~N~BRILL ************** **********~* CIRCULAR A~C METHOD****.**** M£ASI_IRE£, I~E~tAL ~ICAL DEF'~ DEF.~rH ft ft ft 180,47 ~.5 180,47 358,62 ~.2 358,62 TARG~.T ~ATION AZIMb~H LATITLCJ£ S~TION INCLN, N/-S ft deq deg ft -0,03 0.12 260,42 -0,01 -0,12 0,34 276,69 0,00 -0,01 0,~ 0,41 312.26 0,72 D~PAE~UR~ M.~'LACE~NT at AZIMUTH £/-W it ft de9 O,{Q 0,® 0,~ -0,07 0,07 260,42 -0,43 0,43 270,5~Y -0,85 0,~. 286,52 -1,27 1,47 2?9,62 DLS de~/ 100f~ 0,00 0,18 0,25 0,31 0,10 546,38 ~7,~ 729,69 821,89 913,89 ~,3 ~6,37 91,2 637,54 92,1 729,50 ~,2 621,41 92,0 912,~ 1,45 1,£<~ 29,94 !,83 -1.ryJ 2.08 331,24 1,41 4,13 2,27 39,85 4,11 0,67 4.17 9,28 1,12 8,47 3,.J 42,07 7,69 ~,cl 8,58 26,34 1,50 15,17 5,55 42,[~ 13,17 ~,78 15,83 33,69 2,06 24,~ 7,56 36,12 21,~ 15,34 26,29 35,70 2,31 l(Q7,13 1103,19 1198,53 1293 96,1 1096,96 95,3 1191,21 95,1 1281,74 95,0 1370,25 7~,51 10,25 37,23 ~,91 23,98 40,72 36,0~. 2,B? 56,72 13,t4 38,28 48,29 ~,92 60,18 36,64 3,01 79,3i 16,11 35,29 67,60 50,28 84,2__, 36,~ 3,22 107,27 19,3~4 30,0~ 91,~? 65,79 113.10 35.57 3.78 ~ 14/,~J 34,12 4,27 141.09 23,37 28,76 1~,16 8~,76 ' ~ 1483,38 1_578,52 1671,99 1765,63 1860,18 94,7 14~,60 95,1 1542,02 93,5 1624,40 93,8 1705,19 94,4 1784.26 179,.39 25,17 26,55 156,67 2'20,6? 27,07 27,16 194,05 263,8? 29,~ 30.64 232.~ 310,33 31.80 30.13 273.~ 360,~ 34,~ 27,22 319,01 100,82 186.31 32,76 2,15 119,75;_ 228,03 31,~. 1,~ 141,13 272,13 3!,24 2,9? 165,26 319.85 31,11 2,65 189,?1 371,26 30,77 3,16 2051,30 2148,26 2243,91 2336,62 91,2 1856,07 100,0 1936,59 97,0 2010,57 95,7 2080.25 92,7 2144,59 413,40 37,52 2.7,22 3~,,57 473,93 38,95 30,b-7 420,69 534,56 41,58 32,75 474,(X) 597,96 44,?1 ~),70 529,75 ~2,74 47,18 31,28 56E.',,96 214,37 424,65 ~.32 3,51 244,28 466,46 30,14 2.52 277,20 549.11 30,32 311,62 614,61 30,47 3,77 ~5,98 681,34 30,52 2,50 2431,27 2522 2619,05 2718,00 2761 94,7 2208,30 91,7 2269,29 96,1 2333,15 98,9 2399,01 63,2 2441,17 730,56 46,20 31,62 646,67 796,79 48,~ 31,69 704,93 .886,21 48,36 32,3~ 765,63 937,63 48,20 2S'.97 829,00 ?63,42 48,06 52,51 869,20 362,50 751,33 30,./,0 1,11 416,41 819,75 30,69 0,20 456,52 891,57 30,~ 0,55 494.74 %5.4~ 30.83 1,83 519,13 1012,43 30,85 3,01 2914,18 3010,42 3106,~7 3202,43 3298,37 1~,0 2529,71 96,2 25?3.30 96,4 2656,53 95,6 2718,49 95,9 2781,06 1079,43 48,49 31,20 953,53 1149,18 48,81 33.i1 1014,~ 1219,07 49,27 ~,7~ 1075,45 1288,16 49,90 36,84 1134,81 1357,14 46,6? 34,23 11~,97 571,51 1111,69 30,94 609,% 1183,91 3!,01 6S0,11 1256,~ 31,15 692,16 13'Z?,24 31,36 734,43 1401,77 31,~ 0,80 1,53 0,71 2,53 2,42 3394.59 3469.44 3%0,06 3677,05 3770.69 96.2 2845,02 94.9 2909,09 90.6 2970,96 97,0 3037,31 93,6 3101,27 1426,46 46,00 30,57 1254,65 1494,77 47,02 28.3~ 1315,53 1~0,10 46,86 24.30 1374,65 1630.65 ~,,?0 17,5~ 14~J,89 1699,02 46,96 13,73 1506,74 772,96 1473.63 31,64 ~7,~ 1543,52 31,~ 836.71 1609.44 31,32 ~1,98 1679,04 30,89 &B0,43 1745,12 30,30 2,01 3,27 5,06 3.® PAGE NO, .3-13 *****~****** ANA~ILL ************** SURVEY CALCULATIONS ************* CIE~UL~ AEC; M~THOD******** ME~SL.~ED INI~VAL VB~ICAL DEPTH ~,66,26 ~,6 3167,67 4~5,09 ~,6 ~03,76 4147,76 92,7 ~70,91 4243.40 ~,6 ~40~12 TARGET STATION AZIMLK~ ~TITUDE SECTION INCLN, K/-S ft deg dM ft 1767.60 45.02 13.17 1573.~ 1832,26 43,49 10.48 1637,13 1897,84 43,~ 11,35 1701.'~ 1961,42 43,54 12,17 1764,42 2027,09 43.76 10,~ 1629,16 D£PARI~_K<E DISF'LAC~PNT at AZI~r~H E/-W ft ft deo 896,42 1811.00 29.67 909,75 1872.92 922,25 1935,72 26,45 ~5.26 1996.97 27.93 948.08 2060.28 27.40 lOOft 2,07 2.60 0.63 0,61 1,42 4435,02 452"k,89 4624.79 4717,61 95,3 96,4 3578,34 94,9 3646.77 94.9 37t5,27 92,8 3782,EE:. 20?2,56 43,8~ IO.SQ 1894,07 21~.85 43.82 9,99 1'~9,79 2'224,10 43,55 10,70 2024~42 2289,47 43,76 12,36 2088,78 2353,42 43.65 13.07 2!51.34 959,85 2123.40 26.67 0.15 971,63 2187,43 26.37 0.25 965.43 2250,65 25,91 0,52 99'6,57 ~14.34 25,51 1.23 1010.69 ~76.~2 25.16 0,53 4613.79 4909,f~' ~03.16 5097.26 5192.38 96,2 38-~,81 94.1 39~,98 94,1 4045.49 ~.1 4111,33 2420,85 45,60 I3,97 2217,03 2469,54 46,82 14.17 22~.75 2558,20 47.07 14.47 2350,35 2626.64 46.~. 14.37 2416.71 2695.24 46.00 16,50 2482,67 1026,50 2443,14 24.64 2,13 1043,22 2510,74 24.55 1,28 106'0,22 2578.42 24.28 0,36 1077.~ 2645,95 24.03 0,74 10~.56 2713.63 23.81 1,67 5287,27 5380,87 5474,00 5-567,90 5595,60 94,9 4177,19 93,6 4242,20 .~.,1 4307,02 93,9 4372,37 27,7 4~1.63 27E~,55 46,11 1%44 2546_,55 2630.67 45,90 15.78 2613,41 2897,73 45,89 16.49 2677,64 29E5,15 45,91 16,76 2742,25 ~85,06 45,98 17,28 2761,28 1114.~5 2781.53 23.62 0.81 1132,46 2648.23 23,43 0,35 1151,~. 2914,57 23.26 0,55 1170,5,5_ 2981,55 23,11 0,21 1176,18 [.¢Q1,35 23,07 1,37 5689,33 5763,21 S~78,06 5973,30 6066,48 93,7 4456,70 93,9 4521.73 94,6 4587,35 ~,2 4653,20 93,2 4717,56 3052,52 46,09 16,09 2625,91 3120,20 46,21 15,25 2~91,10 31Eq).67 46.24 16,42 29%,98 2257,48 46,29 16.49 3022,98 3324,79 46.~ 12.67 3088.15 11~,54 3066.40 ~.93 0.92 1213,62 3135,5-7 22.78 0,./,6. 1232,51 3203,56 22,~ 0,89 1252.00 3271.99 22.~ 0.07 1269,07 3336,74 22.34 2.61 6161,72 6256,37 6351,69 ./.445,62 65,40,27 95,2 4763,26 94,7 ~48.60 ~.3 4914.46 93,9 4979,37 94.6 5044,72 ~c.:,~ ~ 46,42 14,73 3155,11 3462.08 46.26 16.14 3221.13 ~,98 ~,,30 16.87 3287,19 3598,86 46,29 19,01 5<351,78 3667,30 ~,,37 16,34 3416,64 1285,52 3406.94 22,17 1,41 1303.74 3474,97 22.04 1.09 1323,.~ 3543,55 21,93 0,56 1[-(44,23 3611,28 21,e5 1,65 126'6,15 3679,64 21,7~ 0,52 .~3.02 6727,79 ~,22,73 6917,27 7011,99 92,8 5108,72 94,6 5174,13 94.9 523~,65 94,5 53O5,05 94.7 5070 3734.43 46.37 16,i5 3480.61 3603,00 ~..34 16.26 3545.97 3871.69 ~5,37 18,20 3611.22 ~'39,96 46,09' 17,59 3676,19 4008.14 46.01 17,~ 3741,14 1~56.51 37~6.60 21,72 1.08 1407.25_ 3815.00 21.65 1.00 1428.75 3863.56 21,59 0.05 144~.73 3'~1.72 21.52 0,55 1470.50 4019,77 21.46 0.24 7109.25 7199,69 7293.88 7386.78 7482.86 97,3 5436,33 90,4 5501,06 94,2 5_.%6,35 94,9 56.31,97 94,1 56.96,89 4078,12 46.,03 15.79 38FJ6,12 4143,24 46,09 18,~ 3670.42 4211,15 ~,,19 17,37 2~35,12 4279.72 46.33 17.2_7 4~,~ 4347.61 46..39 17.26 1490.77 4089,52 21.36 1.55 1509.72 4154.45 21.31 1,BO 1530,38 4222.23 21,25 0,52 1550,80 4290,64 21,19 0,17 1571.00 4358.57 21.13 0.~. PAGE NO. ; *********~-*** ANADRILL ************** .c_t~.'.V[¥ CALCLB. ATIONS ***~********* CIRCULAF~ ARC M~D*~****** MEA-g_~[D INTEE4JAL ~RTICAL DEPTH DB'TH ft ft ft 7577,03 94,2 5761,80 7670,85 93,6 ~26,44 77E6,47 95,6 58_~,34 7860,96 94,5 5957,38 7955,96 95,0 6022,67 Tee:GET STATION AZI)~LrfH LATITL~DE SECTIDN INC..LN, hL/-S ft de.~ deg it 4416,02 46,46_ 16,37 41.30,90 4484,Q1 46,45 18,50 41~,77 4553,~ 46.,42 16,85 4261,78 4621,83 46,60 14,61 4327,77 46.90,78 ~.,55 16,05 4394 DEPARTURE DISPLACEMENT at AZIMUTH DLS E/-W dee/ ft it dea lOOft 1590,73 4426,59 21,06 0,68 1611,10 4494,45 21,01 1,64 1.~,14 45E~.62 20,96 1,25 1650,72 4631,90 20,60 1,73 166~,76 47(E).56 20,60 1,11 6~0,63 8146,14 8241,41 94,7 6O67,70 95,5 6153,50 95,3 6220,63 92,4 6287,85 94,7 6~9,07 4759,55 46,70 13,&3 4460,79 ~28.62 46,21 12,75 4526,16 4896,09 44,18 14,65 4593,83 4959,40 42,45 13,95 4655,25 5021,76 40,(~ 14,17 4715,63 1666,69 4769,02 20,71 1,72 1702,61 4&37.66 20.61 0,97 1718,59 49~.76 20,51 1,55 1734.25. 4967,80 20,43 1,94 1749,43 502¢~,87 20.35 2,54 8521,57 ~517,07 6712,41 88_05,64 93,0 6431,40 95,5 6508.18 95,3 6~7,21 93,4 6666,39 95,1 6747,82 5080,12 37,~ 12,27 4772,77 51~,73 35,09 12,94 4628,18 5189.96 32,93 14.76 ¢S79,96 5239.'~49 31,17 13,94 4927,99 5268,54 31.06. 13,12 4975,78 1762,83 5087,92 20,27 2,66 1775,21 5144,19 20,19 2,95 1787,95 5197,19 20,12 2,50 1800,25 5246,52 20.07 1,94 1Bll,75 52~5,36 20,01 0,46 6994.~ 9088,37 9162.32 9280,94 9376,5i 94,0 6909.34 94.0 6990.89 98,6 7076.64 95.6 7159.eYJ 5336,18 30,45 12,91 5022,31 5429,~ 29,59 11,51 5114,17 5478,2I 29,5? 10,~6 5161,94 5525,04 29,46 11,08 5208,19 1822,50 5~2,76 19,94 0,67 1832,70 5381,66 19,68 0,72 1~2,20 5435,_A,4 19,81 0,46 1851,64 5484.® 19,73 0,32 1860,60 5530,56 19,66 0,17 9465,43 9560,37 94.9 9655,18 94.8 F~OJI~CT[g TO TD 9750+00 94,8 7237 7~0 7403.15 7486, il 5568,46 29,27 12o70 5250,85 5614,51 29,02 11,17 5296,09 5660,25 28,96 12,09.' 5341,09 5705.98 28,96 12.~ 5385,,98 1869,58 557.3,76 19,60 1879,15 5619,58 19.54 1888.,41 56~...5.10 19,47 0 0,83 0,48 1898,03 5710,63 19.41 0,02 LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 14 February 1995 RE: Transmittal of Data Sent by: ANCH.EXPRESS Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 1 CCL FINAL BL+RF FSJ~ MPB-11 1 CCL FINAL BL+RF ECC No. Run # 1 6280.04 Run # 1 6334.01 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 si~n s~d return to$ Pet~o ........ c~_ Data Cente~ BP Ezr~lors, t. icn (Alaska) In~ 900 '-:' - = Bouieva;?d ...... CEIVED " ' "~--~ ~ ? Alaska Oil & Gas Cons. Commission Anchorage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 31 January 1995 RE: Transmittal of Data Sent by: MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION MPJ-13 1 PFC/PERF FINAL BL+RF Run # MPJ-13 i PLS/STATIC FNL BL+RF Run # ECC No. 6280.03 6280.02 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: RECEIVED FEB 08 1995 Alaska Oil & GasCons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIuN APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program x Pull tubing Variance__ Perforate __ Other__ 2. Name of Operator BP Exporation (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2319' NSL, 3179' WEL, SEC. 28, T13N, RIOE 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service x At top of productive interval 9. N/~At effective depth ORIGINAL 10. 2376' NSL, 1291' WEL, SEC. 21, T13N, RIOE At total depth 11. 2425' NSL, 1281' WEL, SEC. 21, T13N, RIOE Datum elevation (DF or KB) KBE = 65' feet Unit or Property name MIIne Point Unit Well number MPJ- 13 Permit number 94-126 APl number 50- 029-22508 Field/Pool Milne Point - Kuparuk River 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 9750' feet 7486' feet 9647' feet 7396' feet Length Size Plugs (measured) 7" wireline retrievable bridge plug @ 4500' MD Junk (measured) Cemented Measured depth True vertical depth 80' 20" 250 sx Arcticset 112' 112' 2805' 9-5/8" 560 sx PF "E"/250 sx "G" 2835' 74 69' 9704' 7" 356 SX Class "G" 9731' measured 9206'-9222', 9230'-9238', 9314'-9334', 9346'-9382' (proposed intervals - work in progress) true vertical Tubing (size, grade, and measured depth) None RECEIVED Packers and SSSV (type and measured depth) None JAN 2 4 1995 Oil & Gas Cons. Commission /~nchora ~, 13. Attachments Description summary of proposal x Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 2/2/95 16. If proposal was verbally approved Oil__ Gas __ Name of approver Date approved Service Water Injector 17. I hereby certify th¢/~.f.)or~,.~)ol/~g is true/,~nd correct to the best of my knowledge. Signed /~1/ ~ "-"'""~'~?- "' ~ Title Workover Superintendent FOR COMMISSION USE ONLY 15. Status of well classification as: Suspended __ Date //~o/~,. Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Te,,.st Location clearance Mechanical Integrity Test ¢,/ Subseq~ent.forrp uire ur,g,nal ~lne~ i~' Ko:7__ David W. Johnston Approved by order of the Commission J Approval No. ¢,_~,--'~ ~/7 J Approved Copy Returned --C~)mmi-ssloner Date //~/~'~ I Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Milne Point J-13i RWO/Completion Q_b!ective: The objective of workover is to complete the well as a water injector in the Kuparuk sands with 3-1/2" 9.3# L-80 EUE tubing and a permanent latched packer. The water injection from MP C-13i will support producing wells J-10 and J-12. if an acceptable injection rate is not obtained the well will be hydraulically fractured down the 3.5" tubing after release the rig. Background: The well was drilled with Nabors 22E and 7" casing run and cemented in September 94. Both CBT and wireline conveyed perforation were recently performed. Currently, the well has diesel freeze protection to 2,000' MD, 10.3ppg NaCIBr brine to TD below the diesel, and a 7" wireline retrivable bridge plug was set at +/-4500'MD. Work Scope: 1. MIRU Nabors 4ES. ND tree and NU BOPs. 2. Retrieve 7" retrievable bridge plug @+/-4500'MD. 3. Run 6" gauge ring and junk basket to +/-9,100'MD 4. Run 3.5" 9.3# L-80 EUE tubing with a 7" latched permanent packer. Freeze protect well down to 2,000'TVD with diesel. Set packer @ +/- 9,000'MD and test tubing and annulus to 4,500 psi. 5. RDMO Nabors 4ES. 6. Place well in water injection service. If an acceptable injection rate is not obtained the well will be hydraulically fractured down the 3.5" tubing w/o rig. Timing_;.." Rig Nabors 4ES is expected to move on this well 2/2/95. The workover is expected to take 3 days. RECEIVED JAN 2 4 1995 A~ska, 0J~ & Gas Cons. Commission Anchora ~' D H January 16, 1995 MPU J-13i 20" 94# K-55 Btrc ~ Conductor Casing Surface Casing KOP @ 500' Max Hole Angle: 50° @ 32O0' MD 3 1/2" Threaded ~-~o-ru~i,~ [ ~ooo'+/-so' J (Ali. tubing/packer depths and perforation E ¢ E IV E D data are PROPOSED) " JAN 2 4 1995 ' A!~$~ .0il .& Gas Co~s. C0mmi,, Anchora ~, PERFORATION SUMMARY Atlas 4' Alpha Jet 4spf. 7.0" X 3.5" Baker Packerl 9000' +/-] X~ X 90° phasing, 32gm charge ID)~--'-L"-'"I I ~ ! REF LOG: SBL/GR/CCL 10/15/94 3 1/2" "X" Nipple (2.813" I I SIZE SPF INTERVAL OPEN/SQZ'D 3 1/2" L-80 NSCT Tailpipe/'"~/ ~ 4" 4 9206' to 9222' Open 3 1/2" "XN" Nipple (2.75" ID)~-,,. ; 4' 4 9230' to 9238' Open ,~' I------'l 4" 4 9314' to 9334' Open 3 1/2" WLEG 4" 4 9346' to 9382' Open · , I 7.0" 26#, L-80 Butt. Csg [ 9725' , DATE REV. BY COMMENTS MILNE POINT UNIT 12-29-1994 RBF Proposed Tubing Completion WELL J-13i APl NO' ,50-029-22508 . BP EXPLORATION (AK) I I I 500 W. International Airport Road Anchorage, Alaska 99518-1199 (907) 562-7669 December 19, 1994 TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the LWD DEPTH CORRECTED CDR & CDN TVD for well MPJ-13, Job # 94387 was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 State of ,Z~a~ Alaska C~I~& Gas Conservation Comm. Attn: LariSL.?rant 3001 Porcupf'rm-D~ Anchorage, Alaska 3 Bluelines 1 Film 1 RFolded Sepia % 1 OXY USA, Inc Attn: Erma Galindo P.O. Box 50250 Midland, Texas 79710 1 Blueline 1 RFolded Sepia Sent Certified Mail P 676 541 382 RECEIPT BY SIGNING AND RETURNING ONE COPY E/~H TO: PLEASE ACKNOI BP EXPLORATION (ALASKA)INC. PETROTECHNICAL DATA CENTER, MB3-3 900 EAST BENSON BLVD. ANCHORAGE, ALASKA 99519-6612 SCHLUMBERGER GEOQUEST 500 WEST INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518-1199 Schlumberger Courier: Date Delivered: Received By: 500 W. International Airport Road Anchorage, Alaska 99518-1199 (907) 562-7669 TO: November 17, 1994 BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the LWD DEPTH CORRECTED CDR & CDN for well was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 MPJ-13, Job # 94340 1 OH LIS Tape 1 Depth Shift Monitor Plot 3 Bluelines 1 Film Returning CDR, CDN, CDR & CDN- TVD Field Film Alaska Oil & Gas Conservation Comm. Attn: Larry Grant 3001 Porcupine Drive Anchorage, Alaska 99501 1 OH LIS Tape -''' "-~--.. 1 Blueline 1 RFolded Sepia OXY USA, Inc Attn: Erma Galindo P.O. Box 50250 Midland, Texas 79710 1 OH LIS Tape 1 Blueline 1 RFolded Sepia Sent Certified Mail P 676 541 369 BP EXPLORATION (ALASKA)INC. PE'FROTECHNICAL DATA CENTER, MB3-3 900 EAST BENSON BLVD. ANCHORAGE, ALASKA 99519-6612 SCHLUMBERGER GEOQUEST 500 WEST INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518-1199 Schlumberger Courier: Date Delivered: Received By: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 20 October 1994 Transmittal of Data ECC #: 6280.01 Sent by: U.S. MAIL Data: LDWG Dear Sir/Madam, Reference: MILNE POINT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 SBT/GR/CCL RF SEPIA Run # 1 1 SBT/GR/CCL FINAL BL Run # 1 1 GR/CCL RF SEPIA Run # 1 1 GR/CCL FINAL BL Run # 1 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Or F)~to (907) 563-7803 LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 28 October 1994 Transmittal of Data Sent by: ANCHORAGE EXPRS Dear Sir/Madam, EnClosed, please find the data as described below: WELL ~ ~ DESCRIPTION .k/~.~J-11' (08-11-13) 1 PDK/GR LDWG TAPE+LST 1 GR/CCL LDWG TAPE+LST 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 ~ECE/VED Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson OCr ~ 7 ~994 J or FAX ~o (907) 563-7803 LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 4 October 1994 Transmittal of Data Sent by: U.S. MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION MPJ-13 1 PFC/PERF FINAL BL 1 GR/COLLAR FINAL BL 1 PFC/PERF RF SEPIA 1 GR/COLLAR RF SEPIA 1 FMT/GR FINAL BL 1 FMT/GR FINL.RF SEPIA Run # 1 Run # 1 Run # 1 Run # 1 ECC No. 6279.00 Run # 1 6280.00 Run # 1 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 ~chorage, AK 99518 ~ Att~ Rodney D. Paulson Received ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 September 30, 1994 Terry Jordan BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Well # Company Permit # Surf Loc Btmhole Loc Milne Point Unit MPJ-13 Revised BP Exploration (Alaska) Inc. 94-126 2319NSL, 3179'WEL, Sec 28, T13N, R10E, SM 2412'NSL, 1123'WEL, Sec 21, T13N, R10E, SM Dear Mr Jordan: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the original approved permit dated September 23, 1994 are in effect for this David W Johnston \ Chairman ~ BY ORDER OF THE COMMISSION c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl BP EXPLORATION ARCO Alaska, Inc. TO' Date' September 26, 1994 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention' David Johnston Subject: MPJ-13 Revised Permit (#94-126) Enclosed is a new permit for well MPJ-13. The proposed well is targeting a different bottom hole location. Yours Sincerely, Drilling Engineer Supervisor MS RECEIVED S EP 2_ 6 199~ Gas Cons. Commission STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION coMMIsSION PERMIT TO DRILL 2O AAC 25.O05 la. Type of work Drill [] RedrillDllb. Type of well. Exploratoryl-] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen191 Service [] Development Gas [] Single Zone [] Multiple Zone[] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (AlaskaJ /nc. KBE = 65' feet Mi/ne Point - Kuparuk River 3. Address 6. Property Designation Sands P. O. Box 196612. Anchoraoe. Alaska 99519-6612 ADL 315~4~ 4. Location of well at surface 7. Unit or property Name 11. Type Bond(se,, 20 AAC 25.025) 2319'NSL, 3179' WEL, SEC. 28, T13N, RIOE MIIne Point Unit At top of productive interval 8. Well number Number 2209' NSL, 1200' WEL, SEC. 21, T13N, RIOE MPJ-13 2S100302630-277 At total depth 9. Approximate spud date Amount 2412' NSL, 1123' WEL, SEC. 21, T13N, RIOE ~ $200,000.00 12. Distance to nearest 13. Distance to nearest well 4.~ber of acres in property15. Proposed depth(uDandTVD) property line ADL 25516-1123' feet No close approach feet 2560 9703' MD/7459' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 ^^c 25.035 (e)(2)) Kickoff depth soo feet Maximum hole angle ~, o Maximum surface 2850 psig At total depth (TVD) 7459'/3~50 psl~l 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) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset i (Approx.) 12-1/4" 9-5/8" 36# K-55 BTRC 2767' 31' 31' 2798' 2465' 560 sx PF "E"/250 sx "G"/250 sx PF "E" 8-1/2" 7" 26# L-80 NSCC 9673' 30' 30' 9703' 7459' 356 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 $ F_.P 2 Co 199'~ Perforation depth: measured true vertical Ai&~<& 0it & Gas Cons. C0mmission ' Anchorafie 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling programFfl Drilling fluid program [] Time vs depth pict [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] 21.1 hereby certif/~, that the/f .~goin, g is true and correct to the best of my knowledge Signed~//~/~~' ~'~' f)//~/VL.dC~/t~~ Title Drilling Engineer Supervisor Date / Commission Use Only Permit Number APl number IAppro. xal date See cover letter 'C'~i~tio,'/- /0.?_. ~' 50-C~2_. ~- ~_ ~.-._.4-~ ~ J ~.-qC~u~e"~d -- ~',~ for other requirements Con ns of approval Samples requ, ired [] Yes [] No M d Icg []Yes [] No Hydrogen sulfide measures [] Yes ~ No Directional survey requ~reo ~ Yes [] No Required working pressure for BOPE I--12M; 1-13M; ~,M; FI10M; F']15M; Other: Original Signed By by order of Approved by 0avid W. Johnston Commissioner me commission Date Form 10-401 Rev. 12-1-85 Submit in tri[ I Well Name: I MPJ-13 Well Plan Summary I Type of Well (producer or injector): [ Kuparuk Producer [ Surface Location: "Target Location: Bottom Hole Location: 2319 NSL 3179 WEL Sec 28 T13N R10E UM., AK. 2209 NSL 1200 WEL Sec 21 T13N R10E UM., AK. 2412 NSL 1123 WEL Sec 21 T13N R10E UM., AK. [AFE Number: I 330078 I Estimated Start Date: I 9/26/94 IMD: 19703' I ITVD: I Well Design (conventional, slimhole, etc.): I Rig: I Nabors 22-E I Operating days to complete: I 9 1 7459' bkb I IKBE: I Milne Point Ultra Slimhole 7LS 165' Formation Markers: Formation Tops MD TVD (bkb) base permafrost 1900 1814 NA 4938 3944 Top of Schrader Bluff (West Sak) Sands OA 5169 4104 Seabee Shale 5531 4354 Base of the Schrader Bluff (West Sak) Sands HRZ 8707 6599 High Resistivity Streak Top Kup 8895 6759 Kuparuk Cap Rock Top C Sand 9109 6944 Target 9270 7084 Kuparuk A Sand Total Depth 9703 7459 Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 24" 13 3/8" 54.5# K-55 Weld 80 32/32 112/112 12 1/4" 9 5/8" 36# K-55 btrc 2767 31/31 2798/2465 8 1/2" 7" 26# L-80 NSCC 9673 30/30 9703/745~ Internal yield pressure of the 7" 26g casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 7100 TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3550 psi is 2850 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: Open Hole Logs: Surface Intermediate Final Cased Hole Logs: MWD Directional Only N/A 1. Insert Bit to Seabee Top w/MWD GR/RES (CDR). 2. Run RFF (14 Pressures/7 Sands/1 Sample) acorss Schrader Bluff. 2. PDC Bit f/Seabee to TD w/MWD Dir/GR/CDR/CDN. GR/CCL will be run in 7" casing to coincide with Wireline Perforating Operations without a Rig on the well. CBL run only if necessary. A GR/CCL Log will be obtained in the 7" casing in conjunction with WL Perforating. Mud Logging is not required. Mud Program: I Special design considerations I None- SPUD MUD Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 50 15 8 10 9 8 to to to to to to to 9.6 90 35 15 30 10 15 Intermediate Mud Properties: N/A I Density Marsh Yield 10 sec 10 rain pH Fluid (PPG) Viscosity Point gel gel Loss Production Mud Properties: I None- LSND freshwater mud Density Marsh Yield 10 sec 10 rain pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 10 3 7 8.5 6-8 to to to to to to to 10.2 50 15 10 20 9.5 4-6 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. Directional: Ig°P: 15°°' I I Maximum Hole Angle: 12, degrees Close Approach Well: (No Shut Ins) Disposal: Cuttings Handling: CC2A Fluid Handling: All ddlling and completion fluids can be annular injected. Otherwise, Haul to CC2A. Annular Injection: The MPJ-13 annulus is permitted for drilling & completion fluid injection. DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. AREA WELL PREV VOL PERMITTED PERMITTED DATES INJECYED VOL (aBES) (aBES) Milne Point MPJ-13 0 35,000 6/1/94 to 12/11/94 Milne Point MPJ-12 0 35,000 6/1/94 to 12/11/94 FREEZE PROTECTION: Pay close attention to annulii being used for disposal so to avoid freezing. Sometimes the annulii are ke open by ensudng that an adequate volume (+60 bbls) is injected every 6-12 hours. This practice is mon economical than pumping 60 bbls of diesel freeze protection every time the pumps are shut down; howe if this practice is used, it is important that the injection frequency into the annulus be adequate to preven freeze ups -- the drillers must communicate to each other the last time the annulus was injected into to avoid freezing. MPJ-13 WELL 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 9-5/8" CIRC. TEMP 50 deg F at 2500' TVDSS. SPACER' 75 bbls fresh water. LEAD CEMENT TYPE: ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX #SACKS' 560 Type E Permafrost YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE' ADDITIVES: 2.0% CaCl2 WEIGHT: 15.8 ppg APPROX #SACKS: 250 FLUID LOSS: 100-150 cc Premium G YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. FREE WATER: 0 TOP JOB CEMENT TYPE: Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx APPROX NO SACKS: 250 E MIX WATER' 11.63 gal/sk CENTRALIZER PLACEMENT: 1. I Bowspdng centralizer per joint of 9-5/8" casing on bottom 10 joints of casing (10 required). 2. Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Pedorm lab tests on mixed cement/spacer/mud program an, ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to purr job requirement. Displace at 12 bpm. Mix slurry on the fly -- batch mixing is not necessar~ CEMENT VOLUME: 1. The Tail Slurry volume is calculated to cover 500' md above the 9-5/8" Casing Shoe with 30% excess. 2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry to 1500' md with: excess and from 1500' md to surface with 100% excess. 4. 80'md 9~5/8", 36~ capacity for float joints. 5. Top Job Cement Volume is 250 sacks. MPJ-13 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON STAGE I CEMENT JOB ACROSS THE KUPARUK INTERVAL: CIRC. TEMP: 140° F BHST 170 deg F at 7040' TVDSS. SPACER: 20 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1 above current mud weight. CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 WEIGHT: 15.Sppg YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk APPROX # SACKS: 193 THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F FLUID LOSS: < 50cc/30 min @ 140° F FREE WATER: 0cc @ 45 degree angle. STAGE II CEMENT JOB ACROSS THE SCHRADER BLUFF SANDS CIRC. TEMP: 60°F BHST 80 deg F at 7040' TVDSS. SPACER: 75 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1 above current mud weight. LEAD CEMENT TYPE: ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX #SACKS: NONE Type E Permafrost YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.2% Halad 344, 2.0% CaCl2 WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk APPROX # SACKS: 163 THICKENING TIME: 4 hours @ 50 FLUID LOSS: 100-150 cc FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 7" x 8-1/4" Straight Blade Rigid Centralizers-- two per joint on the bottom 22 joints of 7" Cas total). This will cover 300' above the C Sand. 2. 7" x 8-1/4"Straight Blade Rigid Centralizers-- one per joint from 5600' - 4850' to cover the Sc Bluffs Sands (18Total). 3. Run one 7"x 8-1/4"Straight Blade Rigid Centralizer inside the 9-5/8" casing shoe. 4. Total 7" x 8-1/4"Straight Blade Rigid Centralizers needed is 63. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud progra ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to p~ job requirement. Displace at 8-10 bpm. Batch mixing is not necessary. CEMENT VOLUME: 1. Stage I cement volume is calculated to cover 750' md above the C Sand with 30% excess. 2. Stage 2 cement volume is calculated to cover from the OG base to the to 500' above the NA Top with 30% excess. MPJ-13 Proposed Summary of Operations o , o o o . o , 10. 11. 12. 13. 14. 15. 16. Drill and Set 20" Conductor. Weld a starting head on conductor. Prepare location for rig move. MIRU Nabors 22E drilling rig. NU and test 20" Diverter system. Build Spud Mud. Drill a 12-1/4" surface hole and run and cement 9-5/8" casing. Run only Dir MWD (No LWD Required). ND 20" Diverter, NU and Test 13-5/8" BOPE. RIH w/ Insert bit on Low Speed/High Torque Motor, and Directional MWD and LWD CDR (GR/RES). Test 9-5/8" casing to 2800 psig, Drill out float equipment and 10 feet of new formation, Perform a LOT (Do not exceed 12.5 ppg). Drill ahead to the base of the Schrader Bluff (West Sack) into the Seabee Shale, CBU, Wiper Trip to the BHA, Circulate & Condition for Logging, POOH. LD the Insert Bit and Motor. Send Schrader Bluff Logs to town -- ASAP. RU Atlas W/L Unit and RIH w/ 9n~ RFT (7 Sands/2 Pressures per Sand/1 Sample). MU a Hughes R417G PDC bit on a turbine, with Directional/Gamma Ray, Resistivity/Neutron/Density (Triple Combo) MWD/LWD tools. RIH. Mad Pass the O Sand Interval as outlined by the Geological review of the Schrader Bluff GR/RES Logs. Drill 8.5" hole to TD and Run and Cement 7" casing (2 Stage Cement Job to cover the Schrader Bluff). This hole section will be logged LWD with Triple Combo (GR/Res/Neu/Dens). RIH while PU 3-1/2" drill pipe with 7" 26# bit and .scraper. Drill out ES Cementer, RIH to PBTD, displace the drilling mud out of the hole with source water, while performing a casing wash, filter source water to 2 micron absolute. POOH L/D 3-1/2" drill pipe. Freeze protect the well. ND BOPE, NU the False Bowl and Dry Hole Tree to Prepare Well for Perforation and Frac Work. RDMO Nabors 22E drilling rig to drill MPJ-14. Well will be stimulated in absence of rig and completed with Coil Tubing deployed ESP. MPJ-13 Well Plan PAGE 8 Approved Copy JDP 9/16/94 8OO0 PRUDHOEBAYDRI_LZNG 'GROUP i ~PJ-~3 (PO6) VERTICAL SECTION VIEW Section at: 20.81 TVD Scale.' 1 inch = ~000 feet Dep Scale ' ~ knch = 1000 feet ~ , , AnaErill SchJumberger )_._ ! , ! Manken ]2entlfication MO BKB SECTN .:NCLN ....... j Al KB 0 0 0 O. O0 ,~ B) KOP BUILD 2,5/100 500 500 0 0.00 C) END OF a.5/iO0 BUILD ~351 ~156 708 46.87 ) D) 9-5/8' CASING PT 2798 2465 103~ 46.27 E) S~ART 2/100 DROP 9057 6~00 ~83~ a6.27 ...... : ...... ~s¢a.mr,:sr-~9 F) END OF 2/100 DROP 8670 67S8 533~ ~0.00 G) .... TARGET .... 9~?0 70B4 553 ~ 30. O0 )' '- j H) TD 9703 7459 5748 30.00 I , . - .................. ~ ... .... ' ........ , ,,~,-,~ .... ~- '; .... ~?:ih:r~<': :',~::: X:TL~:-:'-'- O' 500 lO00 1500 2000 8500,,vOv~^ ^ 3300 4000 4500 5060 5500 5,300 6500 ~ ~ Sect ion Departure m · _ : - · ., : .i i ... , - ,i : : ' .. .:. , :- . .' . . .. :. . ; PRUDHOE BAY DRI · ill Marker ~Oent ~ f ~cat ]sn MD N/S E/~ B) KOP BUILO 2.5,/~00 500 0 c) END OF 2.~/,00 9UZLO 235~ 66~ aS1 D) 9-5/8" C~SIN6 PT 2798 SO3 368 E) ~5TART 2/~00 DROP 8052 45~6 1716 F) ,END OF 2Y tO0 OROF 8870 4984 ,894 G)' TARGET .... 9270 517, ,965 TD : 9703 5373 2042 _LING "GROUP MPJ-13 (PO6) PLAN VIEW CLOSURE ..... : 5748 feet at Azimuth 20.81 DECLINATION.: 28.93~ E SCALE ....... : ~ inch = 1000 feet DRAWN ....... : 09/26/94 /Inad£~ ]] $£h]umberger 55( 3500 TAR ET 200 FT RADIUS , , , I . ).~ ......................... , _ i ; ~ _.../ ~ I · . ....,,, ......, ,.. 00~ 2500 2000 ]500 ~000 500 0 500 ~_000 ~.500 2200 2500 3000 3500 <- WEST · EAST -> Ill .... I II .... III -_ II[I , Illl ., . ',. TOTAL P. 05 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 September 23, 1994 Adrian Clark Drilling Engineer Supervisor BP Exploration P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPJ-13 BP Exploration Permit No: 94-126 Sur. Loc. 2319'NSL, 3179'WEL, Sec. 28, T13N, R10E, UM Btmhole Loc. 2286'NSL, 59'WEL, Sec. 21, T13N, R10E, UM Dear Mr. Clark: 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. Sin~ermlv ._. urlg~nal' S~gned By David W. Johnston David W. Johnston Chairman BY ORDER OF THE COMMISSION 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 2O AAC 25.005 la. Type of work Drill [] Redrill I"111b. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI'-]I Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 65' feet Milne Point - Kuparuk River 3. Address 6. Property Designation Sands P. 0. Box 196612. AnchoracTe. Alaska 99519-6612 ADL 315848 4. Location of well at surface 7. Unit or property Name 11. Type Bond(s~e 2o AAC 25.o25) 2319'NSL, 3179' WEL, SEC. 28, T13N, RIOE MIIne Point Unit At top of productive interval 8. Well number Number 2100' NSL, 170' WEL, SEC. 21, T13N, RIOE MPJ-13 2S100302630-277 At' total depth 9. Approximate spud date Amount 2286' NSI., 59' WEL, SEC. 21, T13N, RIOE 9/27/94 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth(uDa~dTVD) property line ADL 25516-59' feet No close approach feet 2560 9947' MD/7439' TVD feet 16. TO be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 5oo feet Maximum hole angle 37 o Maximum surlace 2850 psig ,At total depth (TVD) 7439'/3550 p~ 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M D TVD MD TVD (include stage data) 24" 20~ 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset ! (Approx.) 12-1/4" 9-5/8" 36# K-55 B TRC 2785' 31' 31' 2816' 2465' 560 sx PF "E"/250 sx "G"/25O sx PF "E' 8-172" 7" 26# L-80 NSCC 9917' 30' 30' 9947' 7439' 353 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 RECEIVED Surface Intermediate Production S EP 20 1994 Liner Alaska Oil & Gas Cons. Commission Perforation depth' measured Anch0r[,,,~ trUe vertical ' 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverler Sketch [] Drilling program[] Drilling fluid progra~ [] Time vs depth pict [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] 21.1 hereby cert.~/h/~)t.h.e f.oregoing/Js true and correct to the best of my knowledge Signed . (~..k~~( Title Drilling En~lineer Supervisor Date - - Commission Use Only / / Permit Number IAPI number IApprova(~,. d..a.~ ~ ISee cover letter ~ ¢¢'-//.Z ~'~ 150- o ~ ? - 2_ z_.5'o 2', ¢ ¢"-" -/"/ Ifor other requirements Conditions of approval Samples required [] Yes ~ No Mud Icg required []Yes '~ No Hydrogen sulfide measures [] Yes ~ No Directional survey required ~1~ Yes [] No Required working pressure for BOPE l-]2M; F'I3M; j~5M; F'IIOM; I-'115M; Other: J;'~g~nal Signed By by order of Approved by O.a, vid W. Johnston Commissioner tne commission_.Date Form 10-401 Rev. 12-1-85 Submit in triplicate i Well Name: IMPJ-13 Well Plan Summary TyPe of Well (producer or injector): ] Kuparuk Producer [Surfafie Location: Target Location: Bottom Hole Location: 2319 NSL 3179 WEL Sec 28 T13N R10E UM., AK. 2100 NSL 0170 WEL Sec 21 T13N R10E UM., AK. 2286 NSL 0059 WEL Sec 21 T13N R10E UM., AK. [ AFE Number: [ 330078 [ [ E~Hmated Start Date: [ 9/2'7/94 [ [MD: [ 9947' [ [TVD: [ Well Design (conventional, slimhole, etc.)- [ Rig: [Nabors 22-E [ Operating days to complete' [9 [7439' bkb ] ['KBE- {65' Milne Point Ultra Slimhole 7LS Formation Markers: Formation Tops . MD TVD (bkb) base permafrost 1900 18'] 5 NA 5047 3935 Top of Schrader Bl~i=f (West Sak) Sands oA 5366 4145 ,, Sealxie Shale 5541 4260 Base of the Schrader Bluff (West Sak) Sands HRZ 8952 6580 High Resistivity Streak To..p Kup 9139 6740 Kuparuk Cap Rock Top C Sand 9353 6925 Target 9515 7065 Khparuk A Sand Total Depth 9947 7439 Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 24" 20" 91.1# H-40 Weld 80 32/32 112/112 12 1/4" 9 5/8" 36# K-55 btrc 2785 31/31 2816/2465 8 1/2" 7" 26# L-80 NSCC 9917 30/30 9947/7439 Internal yield pressure of the 7" 26~ casing is 7240 psi. Worst case surface pressure would occur wi full column of gas to the reservoir at 7100 TVDSS. Maximum anticipated surface pressure in this c assuming a reservoir pressure of 3550 psi is 2850 psi, well below the internal yield pressure rating o 7" casing. Logging Program: Open Hole Logs: Surface Intermediate Final Cased Hole Logs: MWD Directional Only N/A 1. Insert Bit to Seabee Top w/MWD GR/RES (CDR). 2. Run RFT (14 Pressures/7 Sands/1 Sample) acorss Schrader Bluff. 2. PDC Bit f/Seabee to TD w/MWD Dir/GR/CDR/CDN. GR/CCL will be run in 7" casing to coincide with Wireline Perforating Opera without a Rig on the well. CBL run only if necessary. S EP 20 1994 Alaska Oil & Gas Cons. Commission Anchor~:,~; A GR/CCL Log will be obtained in the 7" casing in conjunction with WL Perforating. Mud Loggin not required. Mud Program: Special design considerations None- SPUD MUD Surface Mud Properties: ] Density' Marsh 'Yield 10 sec 10 min pH Fluid (PPG) Vi~osity Point gel gel Loss 8.6 50 15 8 10 9 8 to to to to to to ~o 9.6 90 35 15 30 10 15 intermedia'te Mud Pr,'operties: N/A ] Density Marsh Yield 10 sec 10 rain pH Fluid (PPG) Viscosity Point gel gel Loss Production Mud Properties: [ Nbne- LSND freshwater mud Density Marsh Yield 10 sec 10 rain pH FlUid (PPG) Viscosity Point gel gel Loss 9.0 40 10 3 7 8.5 6-8 , tO tO tO tO tO tO tO 10.2 50 15' 10 20 9.5 4-6 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer wi' installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: }KOP: 1500' Maximum Hole Angle: Close Approach Well- 31 degrees (No Shut Ins) Disposal: Cuttings Handling: CC2A Fluid Handling: All drilling and completion fluids can be annular injected. Otherwise, Haul to CC2A. Annular Injection: The MPJ-13 annulus is permitted for drilling & completion fluid injection. DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. AREA WELL PREV VOL INJECT i~5'RMITTED VO .'PERMITTED I (BBLS) (BBLS) ~ilne Point ~PJ-13 0' 35,000 c~/1/94 to 12. Milne Point MPJ-12 0 35,000 6/1/94 to 12, Milne Point MPJ-09 3900 35,000 !6/1/94 to 12, FREEZE PROTECTION: Pay close attention to annulii being used for disposal so to avoid freezing. Sometimes the annulii are ke open by ensudng that an adequate volume (+60 bbls) is injected every 6-12 hours. This practice is mor~ economical than pumping 60 bbls of diesel freeze protection every time the pumps are shut down; how{ this practice is used, it is important that the injection frequency into the annulus be adequate to prevent ups-- the drillers must communicate 'o each other the last ,il~i'el~_ l~m. ,[-,,ltl~,ll~l',l~'as inject into to avoid freezing. I EL, El V I2 tJ S EP 20 1994 ^iaska 0il & 6as Cons. Commission Anchor~.~,~: MPJ-13 Proposed Summary of Operations I . 2. 3. 4. 5. . . o 11. 12. 13. 14. 15. 16. Ddll and Set 20" Conductor. Weld a starting head on conductor. Prepare location for rig move. MIRU Nabors 22E drilling dg. NU and test 20" Diverter system. Build Spud Mud. Drill a 12-1/4" sudace hole and run and cement 9-5/8" casing. Run only Dir MWD (No LWD Required). ND 20" Diverter, NU and Test 13-5/8" BOPE. RIH w/Insert bit on Low Speed/High Torque Motor, and Directional MWD and LWD CDR (GR/RES). Test 9-5/8" casing to 2800 psig, Drill out float equipment and 10 feet of new formation, Pedorm a LOT (Do not exceed 12.5 ppg). Drill ahead to the base of the Schrader Bluff (West Sack) into the Seabee Shale, CBU, Wiper Tdp to th'e BHA, Circulate & Condition for Logging, POOH. LD the Insert Bit and Motor. Send Schrader Bluff Logs to town -- ASAP. RU Atlas W/L Unit and RIH w/one RFT (7 Sands/2 Pressures per Sand/1 Sample). MU a Hughes R417G PDC bit on a turbine, with Directional/Gamma Ray, Resistivity/Neutron/Density (Tdple Combo) MWD/LWD tools. RIH. Mad Pass the O Sand Interval as outlined by the Geological review of the Schrader Bluff GR/RES Logs. Drill 8.5" hole to TD and Run and Cement 7" casing (2 Stage Cement Job to cover the Schrader Bluff). This hole section will be logged LWD with Triple Combo (GR/Res/Neu/Dens). RIH while PU 3-1/2" ddll pipe with 7" 26/1 bit and scraper. Drill out ES Cementer, RIH to PBTD, displace the drilling mud out of the hole with source water, while pedorming a casing wash, filter source water to 2 micron absolute. POOH L/D 3-1/2" drill pipe. Freeze protect the well. ND BOPE, NU the False Bowl and Dry Hole Tree to Prepare Well for Pedoration and Frac Work. RDMO Nabors 22E drilling dg to drill MPJ-14. Well will be stimulated in absence of dg and completed with Coil Tubing deployed ESP. RECEIVED S EP 20 ]994 p,i~sk~ Oil & Gas Cons. Commission Anchor~: ,~ MPJ-13 WELL 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 9-5/8" CIRC. TEMP 50 deg F at 2500' TVDSS. SPACER: 75 bbls fresh water. LEAD CEMENT TYPE: ADDITIVES: Retarder WEIGHT: 12.0 ppg gal/sk APPROX #SACKS: 560 Type E Permafrost YIELD:2.17 ft3/sx MIX WATER: 11.63 THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE: ADDITIVES: 2.0% CaCI2 WEIGHT: 15.8 ppg gal/sk APPROX #SACKS: 250 FLUID LOSS: 100-150 cc Premium G YIELD:1.15 ft3/sx MIX WATER: 5.0 THICKENING TIME: Greater than 4 hrs at 50° F. FREE WATER: 0 TOP JOB CEMENT TYPE: Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx gal/sk APPROX NO SACKS: 250 E MIX WATER: 11.63 CENTRALIZER PLACEMENT: 1. 1 Bowspring centralizer per joint of 9-5/8" casing on bottom 10 joints of casing (10 required). 2. Place ali centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Pedorm 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 slurry on the fly -- batch mixing is not necessary. CEMENT VOLUME: 1. The Tail Slurry volume is calculated to cover 500' md above the 9-5/8" Casing Shoe with 30% excess. 2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry to 1500' md with 30% excess and from 1500' md to sudace with 100% excess. 3. 80'md 9-5/8", 36~ capacity for float joints. 4. Top Job Cement Volume is 250 sacks. R E C E IV E D S EP 20 1994- Aiaska Oil & Gas Cons. Commission Anchorh,~ CEMENT MPJ-13 PRODUCTION CASING PROGRAM- HALLIBURTON STAGE I CEMENT JOB ACROSS THE KUPARUK INTERVAL: CIRC. TEMP: 140° F BHST 170 deg Fat 7040'TVDSS. SPACER' 20 bbls fresh water. 70 bbis Alpha Spacer mixed as per Halliburton specifications weighted to 1. above current mud weight. CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 WEIGHT: 15.Sppg YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk APPROX # SACKS: 205 THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F FLUID LOSS: < 50cc/30 min @ 140° F FREE WATER: 0cc @ 45 degree angle. STAGE !1 CEMENT JOB ACROSS THE SCHRADER BLUFF SANDS CIRC. TEMP' 60° F BHST 80 deg F at 7040'TVDSS. SPACER: 75 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1. above current mud weight. LEAD CEMENT TYPE; ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX #SACKS: NONE Type E Permafrost YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.2% Halad 344, 2.0% CaCI2 WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk APPROX # SACKS: 148 THICKENING TIME: 4 hours @ 50 FLUID LOSS: 100-150 cc FREE WATER' 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 7"x 8-1/4" Straight Blade Rigid Centralizers-- two per joint on the bottom 22 joints of 7" Casi total). This will cover 300' above the C Sand. 2. 7" x 8-1/4"Straight Blade Rigid Centralizers-- one per joint from 5600' - 4800' to cover the Sc Bluffs Sands (20 Total). 3. Run one 7"x 8-1/4"Straight Blade Rigid Centralizer inside the 9-5/8" casing shoe. 4. Total 7"x 8-1/4"Straight Blade Rigid Centralizers needed is 65. OTHER CONSIDERATIONS: Pedorm lab tests on mixed cement/spacer/mud prograr enSure compatibility prior to pumping job. Ensure thickening times are adequate relative to pu job requirement. Displace at 8-10 bpm. Batch mixing is not, necessary. CEMENT VOLUME: 1. Stage 1 cement volume is calculated to cover 750' md above the C Sand with 30% excess. 2. Stage 2 cement volume is calculated to cover from the OG base to the to 500' above the NJ with 30% excess. RECEIVED S EP 20 1994 Gas Cons. Commission Anch0rh,~ PRUDHOE BAY DRI Marker IdentifiCation MD N/S Al KB 0 0 B) KOP BUILD 2.5/100 500 0 C) END OF 2.5/~00 BUILD 245~ 673 O) ~-5/§" CASING ?~ 28!6 909 E} $~A~ E/lO0 DROP 9J75 4378 FI END OF 2/100 DROP 9~15 488§ 2894 ~] .... TARGET .... 9525 5051 8996 HI iD gg~7 52~7 3106 398 538 2592 _LING GROUP MPJ-'I 3 (PO4) PLAN VIEW. CLOSURE ' 6097 feet at Azimuth 30..62 DECLINATION.: 28.934 E SCALE ....... : ~ ~nch = ~000 feet DRAWN ....... : 09/~3/94 I II , III ~4nadf'J 2] $ch]umt~er'ger' 5500- 5000- 4500 4000 ~500- 3000. 85O0 2000-' ~500- ~000- 500- 500 500 0 500 1000 . 1500 2000 ZS.00 3000 3500 4000 4500 5000 5500 6000 $500 <- ~,~EST ' EAST -> I I ._ ill ,.. ; , : .: -. ~ -, . . . ,;'. ::'.- ..' .... - ... ~ .: / , PRUDHOE BAY DR ILL I NG GROUP 8 , i VERTICAL SECTION VIE~. I m Section at' 30.62 ~ TVO Scale.: ~ inch = ~000 feet ~' ~ /Oep Scale.: 1 inch = t000 feet o .... ! /DRawn ..... : og/]3/g~ o ......... m m 0 , ,, K~ 0 0 0 . 0.00 ' ~,I , 8, KO, BUZLD ~.5/,00 500 500 0 0.00 0' B) 9-5/8' CASING P? 28,6 2465 ,056 48.78 E) S,,nT 2/,O0 O,O, 8,75. 5,,5 50B8 48.7, F) E.O OF 2/,00 DROP 9, ,5 6725 56B, 30.00 6) .... ~A~GET 95J5 7065 58B~ 30.00 O~- ~. H) TB 9947. 7439 6097 30.00 : } ',;'~r~ ~ - ' - ~ ..... ~ ...... '- ~ - - ~ ..... ~ ..... . ....... I · I ~- ~ ....... %-,- ...... !- ' ....... ~ __~ ...... ...._ . ;, ~ Aiask~Oil & 6a; Cons. ccrmmission ' , A~C ~or~ 2500- 3000, ~500- 4000 . 4500= 5000 5500- B000- 5500- 7000 7~OO- 8OOO 8500- 9000 0 5OO tO00 ~500 3500 4000 200~ 2500 3000 Section Departure i _, 4500 5000 5500 B000~ 6500 · II I._ I -,,W',~'J¢i,t~ ~c~g~ .¢.J!X~04 .ul,5~ ~0;.,~2 ~ ~ , "- : . -' ' ' - : ' " i ' ' '' ' ' ' ' ' ' 'J ;' '~'' :, ::.,'-' .... ' -:' '.~':- '~,": :."-U,:'""' : ' ~-;- ~.~ ..... ~ .,::. ~. ....:1 ..... .._..- WELL PERMIT CHECKLIST WELL NAME /~p~ ~7~_ /'~ PROGRAM: exp [] dev~ redrll [] serv [] GEOL AREA {?~ UNIT~ //~ ~.~ ON/OFF SHORE O~ ADMINISTRATION 1. Permit fee attached ................... Y N~ 2. Lease number appropriate ................ Y N 3. Unique well name and number ............... Y N 4. Well located in a defined pool .............. Y N 5. Well located proper distance from drlg unit boundary...Y N 6. Well located proper distance from other wells ...... Y N 7. Sufficient acreage available in drilling unit ...... Y N 8. If deviated, is wellbore plat included ......... Y N 9. Operator only affected party ............... Y N 10. Operator has appropriate bond in force .......... Y N 11. Permit can be issued without conservation order ..... Y N 12. Permit can be issued without administrative approval...Y N 13. Can permit be approved before 15-day wait ........ Y N 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 ...... N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 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 .~ N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to ~(~ psig.~/ N 27. Choke manifold complies w/API RP-53 (May 84) ....... ~----~ 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............. Y GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N 31. Data presented on potential overpressure zones ..... Y N 32. Seismic analysis 9f shallow gas zones .......... Y 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: TAB C~mments/Instructtons: HOW/jo - A:~FORMSlcheklist rev 03/94 WELL PERMIT CHECKLIST UNIT# PROGRAM: exp [] dev~ redrll [] serv ~ ON/OFF SHORE d;~J ADMINISTRATION 1. Permit fee attached ................... 2. Lease number appropriate ................ 3. Unique well name and number ............... 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary.. 6. Well located proper distance from other wells ...... '7. Sufficient acreage available in drilling unit ...... 8. If deviated, is wellbore plat included ......... 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order ..... 12. Permit can be issued without administrative approval.. 13. Can permit be approved before 15-day wait ........ ENGINEERING N N N N N N N N N N N N N APPR 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 . . . Y ~ 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. N 21. If a re-drill, has a 10-403 for abndnmnt been approved. ~¥ N- 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to ~~ psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ....... ~~]/~ 28. Work will occur without operation shutdown ....... ~,~N 29. Is presence of H2S gas probable ............. Y GEOLOGY APPR 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/_ 31. Data presented on potential overpressure zones ..... Y/~/~j 32. Seismic analysis of shallow gas zones .......... y N ,~../..7~ 33. Seabed condition survey (if off-shore) ........ .~ N ' - 34. Contact name/phone for weekly progress reports . . . /. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: BEW DWJ~~-- Comments/Instructions: HOW/lo - A:XFORMS~cheklist rev 03/94 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. MILNE POINT Run 1: 15- OCT - 1994 GR/CCL Cased Hole ATLAS Atlas Wireline Services Tape Subfile ~ is lype: LIS TAPE HEADER MILNE POINT UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: 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 MPJ - 13 500292250800 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 21-0CT-94 6280.01 L. KOENN J. FOX 28 13N 10E 2319 3179 65.00 65.00 34.00 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 3RD STRING 9.625 2835.0 PRODUCTION STRING 7.000 9731.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: ATLAS WIRELINE SERVICES EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ REMARKS: GR/CCL Cased Hole. 40.00 26.00 *** THIS IS THE DEPTH REFERENCE FOR THIS WELL *** PASS 1 (UPPER MAIN) & PASS 2 (LOWER MAIN) WERE NOT DEPTH SHIFTED SINCE THE MAIN PASS IS THE DEPTH REFERENCE FOR THIS WELL. LOG TIED TO MAGNETIC MARKS. FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY MPU TOOL CODE START DEPTH STOP DEPTH GRCH 3613.0 5616.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS MPU CURVE CODE GRCH PASS NUMBER: 1 BASELINE DEPTH $ REMARKS: EQUIVALENT UNSHIFTED DEPTH PASS 1 (UPPER MAIN PASS). NO DEPTH SHIFTS WERE DONE SINCE THIS IS THE DEPTH REFERENCE. CN : BP EXPLORATION WN : MPJ - 13 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv size Length Typ Typ Cls Mod 1 GRCH SBT 68 1 GAPI 4 2 TENS SBT 68 1 LB 4 4 21 532 20 0 4 32 943 39 5 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 48 Tape File Start Depth = 5616.000000 Tape File End Depth = 3613.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 12022 datums Tape Subfile: 2 138 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE S~RY MPU TOOL CODE START DEPTH STOP DEPTH GRCH 8259.0 9596.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS MPU CURVE CODE GRCH PASS NUMBER: 2 BASELINE DEPTH $ EQUIVALENT UNSHIFTED DEPTH REMARKS: PASS 2 (LOWER MAIN PASS) . NO DEPTH SHIFTS WERE DONE SINCE THIS IS THE DEPTH REFERENCE. CN : BP EXPLORATION WN : MPJ - 13 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH SBT 68 1 GAPI 2 TENS SBT 68 1 LB 4 4 21 532 20 0 4 4 32 943 39 5 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 32 Tape File Start Depth = Tape File End Depth = 9596.000000 8259.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 8026 datums Tape Subfile: 3 63 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY MPU TOOL CODE START DEPTH STOP DEPTH GRCH 9364.0 9596.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS MPU CURVE CODE GRCH PASS NUMBER: 2 BASELINE DEPTH GRCH 9369.0 9369.5 9382.5 9383.0 9383.5 9383.5 9385.0 9385.0 9399.0 9399.5 9400.0 9400.5 9434.5 9434.5 9442.0 9442.0 9466.0 9466.5 9516.0 9516.5 9544.5 9544.5 9590.0 9590.0 9590.5 9591.0 9629.0 9629.5 9629.5 9630.0 REMARKS: EQUIVALENT UNSHIFTED DEPTH PASS 3 (REPEAT PASS). TENS WAS SHIFTED WITH GRCH. /??MATCH1.OUT CN : BP EXPLORATION WN : MPJ - 13 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GRCH SBT 68 1 GAPI 2 TENS SBT 68 1 LB API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 85 180 13 1 4 85 180 13 1 * DATA RECORD (TYPE~ 0) Total Data Records: 1014 BYTES * Tape File Start Depth = 9596.000000 Tape File End Depth = 9364.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 13418 datums Tape Subfile: 4 53 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 3612.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 5616.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL GR ACC SBT VDL CENT $ CASING COLLAR LOC. GAMMA RAY ACOUSTIC COMMON SEGMENTED BOND TOOL VDL SUB CENTROLLER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS / OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 15-OCT-94 FSYS REV. J001 VER. 1.1 1927 15-OCT-94 9647.0 9633.0 3612.0 9602.0 1500.0 YES TOOL NUMBER 2317XA 1309XA 1633EA 1424XA 1424PA .00O 9731.0 .0 BRINE .00 .0 .0 0 .0 .000 .000 .000 .0 .00 .000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN) : .0 REMARKS: PASS 1 (UPPER MAIN PASS). .0 .0 CN : BP EXPLORATION WN : MPJ - 13 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR SBT 68 1 GAPI 4 2 TTEN SBT 68 1 LB 4 3 TEN SBT 68 1 LB 4 4 SPD SBT 68 1 F/MN 4 5 CCL SBT 68 1 4 4 21 532 20 0 4 32 943 39 5 4 32 943 39 5 4 67 407 39 5 4 77 609 68 6 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 196 Tape File Start Depth = 5655.000000 Tape File End Depth = 3599.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 57377 datums Tape Subfile: 5 273 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8259.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 9602.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL GR ACC SBT VDL CENT $ CASING COLLAR LOC. GAMMA RAY ACOUSTIC COMMON SEGMENTED BOND TOOL VDL SUB CENTROLLER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 15-0CT-94 FSYS REV. J001 VER. 1.1 1810 15-OCT-94 9647.0 9633.0 3612.0 9602.0 1500.0 YES TOOL NUMBER 2317XA 1309XA 1633EA 1424XA 1424PA .0OO 9731.0 .0 BRINE .00 .0 .0 0 .0 .000 .000 .000 .0 .00 .000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS) : 0 TOOL STANDOFF (IN): .0 REMARKS: PASS 2 (LOWER MAIN PASS). CN : BP EXPLORATION WN : MPJ - 13 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA .0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR SBT 68 1 GAPI 4 2 TTEN SBT 68 1 LB 4 3 TEN SBT 68 1 LB 4 4 SPD SBT 68 1 F/MN 4 5 CCL SBT 68 1 4 4 21 532 20 0 4 32 943 39 5 4 32 943 39 5 4 67 407 39 5 4 77 609 68 6 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 133 Tape File Start Depth = 9641.000000 Tape File End Depth = 8249.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 46833 datums Tape Subfile: 6 209 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9363.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 9602.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL GR ACC SBT VDL CENT $ CASING COLLAR LOC. GAMMA RAY ACOUSTIC COMMON SEGMENTED BOND TOOL VDL SUB CENTROLLER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : 15-OCT-94 FSYS REV. J001 VER. 1.1 1751 15-OCT-94 9647.0 9633.0 3612.0 9602.0 1500.0 YES TOOL NUMBER 2317XA 1309XA 1633EA 1424XA 1424PA .0O0 9731.0 .0 BRINE .00 .0 .0 0 .0 .000 .000 .000 .0 .00 .000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT) : .0 .0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN) : .0 REMARKS: PASS 3 (REPEAT PASS). CN : BP EXPLORATION WN : MPJ - 13 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR SBT 68 1 GAPI 4 2 TTEN SBT 68 1 LB 4 3 TEN SBT 68 1 LB 4 4 SPD SBT 68 1 F/MN 4 5 CCL SBT 68 1 4 4 21 532 20 0 4 32 943 39 5 4 32 943 39 5 4 67 407 39 5 4 77 609 68 6 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 28 Tape File Start Depth = 9641.000000 Tape File End Depth = 9353.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 64296 datums Tape Subfile: 7 104 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 8 is type: LIS 94/10/21 01 **** REEL TRAILER **** 94/10/20 01 Tape Subfile: 8 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 20 OCT 94 4:32p Elapsed execution time = 15.32 seconds. SYSTEM RETURN CODE = 0 ****************************** * * * ALASKA COMPUTING CENTER * * * ****************************** *--.-.-------------------.---* *------- SCHLUM8ERGER -------. *---.-.----------------------* ****************************** COMPANY NAME , t' E' L L ',Î. 11.11,< F' ¡" ~, \"1 ,., 1'1 ",,' FIELD NAME BOROUGH STATE API NUMBF:R P,' [;" 1:', ,t:;' 'R, E' N C'F, N C" , $;J I':' 1"'...., ,..,,' J : BP EXPLORATI(}N : 1!{PJ-13 : MII1f\¡E POIN'~ : NORTH SLOPE : ALASKA : 50-029-22508-00 : 94340 ~D~ 0 rvl9 (\ - ' RECEIVED NOV 1 6 J994 AlaSka 0/1 a G ~= Dtmmlotlon ,3C , Im!r l r .--- . - CD 11ft ì , ~ f1 - Z ftI CD , " lIS Tace Verification LlstinQ IChlumberger Alaska Co~put1nq Center 15-NOV-'99415:35 PAGE: t * * * * Q F' f.' l, 5 F R " IrE )~ Â ~ ~ DATF Of:.'I(".IN REEL NAME C C\ N 1'1 n u ~ T I [) 1\1 # pREVIOUS PEFt! C("lMMEN1 H~ADER **** ~ EDIT : q4/11/15 ! F'LTC : C}4340 . . . . : BP EXPLORATION, ~ILNE POINT, MPJ-13, API 50-029-22508-00 **** 5FRVICE DATF' QPICIN 1'ApF NAHE C(iN1'INUATION # pREVIOUS TAPE COMMF~NT TI'PF HEADER MILNE pnINl' M';O/MAD LOGS # WELt, NA~1}£: API NU¡\>H~ER: OPERATOR: LnGGlf..JG C(1MPANY: TApE CREATION DATE: # JOB DATA TAPE HEADER **** N1\ N E : E j) I '1' : q4/11/15 : FLTC : 94340 : 1 . .. : QP EXPLORATION, MILNE POINT, MPJ.t3, API 50.029.22508.00 MPJ-13 , 500292250800 BPEXPLORATION SCHLUMBERGERWF;t.,I,I SERVICES 15-NOV.94 ~JOBNUJ"'.BER!. ' LOGGINGEN~INE~R1 OPERATOR WITNESS: BIT RUN 1 -..-----. 94.340 STAMOUR J PYRON BIT RUN 2 w-.-..w... 9' i. ;3 ~"" 0,.,,' "" '.,' '" ," 5... AMOUR J PYRON aIT RUN] -....-...-.. .# SURFACE LOCATION SECTION: ¡rOWNSH IP; RANG£'; : FNL: FSL: F'EL: FWL: ELEVA~ION(FT FROM KElJLY BUSHING: DERRICK F~tOOR: GROUND LEVELl: 28 13N 10E 2319 3179 MSL 0) 65,00 65.00 34.00 # wFLt CASING RECORO 1ST STRING ?,,~'f) S"I.~~,'"I'N".'G'! <, 1\1 .." ["(,. OPEN HOLE CASING DRILLERS BIT SIZ! (IN) SIZE (!N) DEPTH (FT) .------.----- .-....-.- ---..--... 8.500 9.625 2833.0 "","":""~""'C"-'"~"'."""'r'"""""""""""""'.'":."~'"..'......,.,...'...,~.....'. IS Tape verification Listino chlumberqer Alaska Computinó Ce~t~r ~RD STRING PRODHCTION S"rRII-vG # RF'MßRKS: $ # LIS FORMAT nATA LIS FOR~'~AT DATA 15-NOV-199415:35 PAGE: 2 **** FTI,E FILl=': NAME SERVICE VERSION D 11. Tf" MÞ-X REC SIZE FTLF TYPE LAST J;'II,E HEADER **** : EDIT .001 : FLIC : 0O1CO1 : 94/11/15 : 1024 : T..O . . FJLF HEADeR F I I, F. N U M B F. R: EDITED MERGED MWD Depth shifted and DFP'f'H INCREMENT: # FILl" SUMMARY tD\fJG tIDaL CODE --..,....-..---..-- C",t'" 'ð, , ,)n C D 1\' ,.i "~. I ¡ $. 1 " e11poed eUTV~S' all bit runs merged. 0.5000 STARTOEPTH ...--.....--- 2838.0 5647.0 STOP DEPTH .""".""".."'" 9692.0 9629.0 # BASFLIN! CURVE FOR SHIFTS: GRCH CURVE SHIrT DATA (MEASURED DEPTH) # ...........F,QUIVALENT UNSHIFTEf) DEPTH........... MWD 'RASEl,INE DEPTH .--..-.......-.... ~. En~B8 . 0 9587.5 9550.5 9431.0 9415.0 9374.5 9324.0 9242.5 9216.0 9182.0 9149.0 9125.0 9110.0 9084.0 9013,0 0892.5 ........... 88886.5 9586.0 9547.5 9422.5 9407.5 9369.0 9317.5 9235.0 9208.5 9177.5 9143.5 9120.5 9105.0 907a.5 9001..5 8B86,0 ~,;=;'. """"'."-';"",, ",.. ';-,' '" ,-,,"~'-"r-e-"-.---e---'~--'--~'--'-'-'~-"-'--".-"'-;--,...."... -"'-'""-";'_."-"""".".' '~"~""-"._".;',=." ~"".,...;."~,,. "'.'=.'._-'=""~""~'" ;r.~ .,.,= "".=,~ .=, ~=, ;~"."'='=;.""'=""'._'."-,,.,,"""', ;""'.""""'='-"""-";;""""""""-~='='=";-""'-'."""-,,, """"""",,,"",,,,",.., """""",'.,=,"'" "","""", = """,="",."",",'" ~,"',,-.""."'" ."',,,e,',", IS 'T'ar".e Ver1t1catlon LlstinQ ,chlumberger Alaska Computlna Center 8R75.0 8Q27,O 8720.0 86b3,5 859~.O 8522.0 8413,0 8391.5 8326.0 5558,5 5427,5 5293.5 5teR.O 5t36,O 5012,0 4886,0 4748,0 4660.5 4607,5 4497,0 4408,0 4357,5 4301.0 4213.0 4099.5 4033,5 3817.0 3707.5 3680.5 3638.0 100,0 $: ß~£{r;ED DATASOtlÞêt t,D1~lG TOOl1 conE ..""............. COR CrH~ S # RE~1ARKS : 8968.0 8821..0 8714.(') 8656.5 8589.5 8515.0 &406.0 8383.5 8319.0 5557.0 5425.0 5291.0 518S.5 5132.5 5069.5 4983.5 4745.5 4n58.0 4604.5 4494.0 4404.5 4354.5 4298.0 4212.0 4096.5 4030,0 3813.5 3703.5 3679.5 3636.5 98,5 BIT RUN NO. MERGE TOP .......-... .....-... 1 2838.() 2 5647.0 15-NOV-199415:35 MERGE SASE ........,.. 5647.. (} 9692.0 PAGE: 3 THE B~S! CURVE W~S THE GRCH OVER ~H! !N'E~VAbS 9595 TO 8260A.ND FROM 5616 TO 3614. A BLOCK SHIFT OF -1.5 F1 WAS APPLIED ABOVE 3614 FT. $ # LIS F'ORMAl' DATA ,,_.."""~"'~"'~- -"~...._"..,-".,,..," '0'" .... " .. 15 Tace verificatIon ListlnQ chlumberger Alaska Computlnq Center 15-NQV-199415:35 PAGE: 4 ** ~ATA FORMAT SP~CTFICATIO~ RErORD ** ** SET TYPE - 64EB ** ----------.--------.-------.-- TYPE REPR COnE VALUE -------.--.-----.----.-.-----. 1 66 0 2 66 0 3 73 68 4 66 1 5 66 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 0.5 FT 15 0 F1 68 1 0 .--------.----.---.--.-.-.-.-. ** SET TYPE-CHAW *. ' -----.--.---------------------.-.__.._~-.-----_._..-.--.-----.---.-.-.-.---.----.-.-..- NAMF S!RV UNIT SERVICE API API API API rILE NUMB NUMB SIZE REPR PROCESS 10 ORDER # LOG TYPE CLASS MOD NUMS lAMP ELEM CODE (HEX) ....._---_._-_.__._--------...-.--~..._.~..__._-_.._.-..-.-.._..-....-....-.-~....._~.. DEPT FT 00 000 00 0 1 1 1 4 68 0000000000 GR ~WD GAP! 00 OO~ 00 0 1 1 1 4 68 ooo~OOOOOO Rap MWD FPHR no 000 00 0 1 1 1 4 68 0000000000 F~T MWDtU5, Q()()QQ aQ Ql1 1 4 ~8 QOQQOQQOQO FfA 'MWD OHMM 00 000 00 01 11 4 68 0000000000 RP MWD OHMM 00 000 00 0 1 1 1 4 68 oo~ooooooo DER MWD OHMM 00 000 00 0 1 1 1 4 68 OOQCfOOOOOO yRA MWÐ OHMM 00 000 00 0 1 1 1 4 68 0000000000 VAP ~WD OHMM 00 000 00 0 1 1 1 4 68 0000000000 RHOA MWD GtC] 00 000 00 0 1 1 1 4 68 0000000000 DRHC MWD G/C] 00 000 00 0 1 t 1 4 68 0000000000 PEr' MWDaN/E 00 000 00 0 1 11 4 68 OOtlOOOOOOO CALN MWD IN 00 000 00 0 1 1 1 4 68 0000000000 NPHI MlrJD PU-S 00 000 00 01 1 1 4 68 OQOOOOOOOO NCNT MWD cpa 00 000 o~ 0 1 1 1 4 68 0000000000 rCNT MWD CPS 00 000 00 0 1 1 1 4 68 0000000000 GRCH eSG GAP! 00 000 "00 0 1 t " 1 "",,4 6QOOOOOQOOOO -_._..-_._.__.---_.-..------------...._--._-_....-.~.--.._...~._.~._..--_.._...~-._.... ** DATA DEPT. RA.MiAÎD \fRP .M\'~D CALN. Nh\O ** 974e."sOO -999.250 -999.250 "999.250 GR.ftìWD R p.ÎI !VI W D RHO8.MWD NP HI.¡V¡~¡ D ..999.250 -999.250 -999.250 -999.250 ROP:,.MWD DERi"""MW'D'"' ", '. ' DRHQ...MWD NCN'r.MWD -999.250 .999.250 -99 g.~2 SO -999.,250 FE~.MWD VRA.MWO PEF.MWD FCNT.MWD .. 9 99","', '..2",5°," -999,.250 -999.210 '.999.250 """","~"~,.~-,).,.,~,)",",.~"",..",-,=),-""""""","",",,,..,.,".'oc'.",:-", ~..' ")",. " "'.""""""','")';",-,- "~' ~':' ~"""")""!:...,".,,,,......,.,..':.)., ,_.",~""".- .,,' """"."""".""""~""",""".",.,.,,, '-': ~,..'.:' !,:""""""""""",-:"""-,.""".~")-"",,,-,.:.,, ,,"',,-,"',!,:"""".,,""")""""""""""". ""',",""""',""",'."'" "')'.,"',"":'.""".."""",""")"""""""-"""',""'~"'" """:"'""".'-"""""".;"",:.,.'~",)",-.'"""."..."."..,..."",,,.,..." "",1""." IS Tape verification Listinq !chlumherqer AlasKa Computinq Center 15-NOV-199415:35 GRC~.CSG DFp'T' . R.I'. . ~,! W D VRP.f,i¡ID C ß LN. ~.~¡J D GRCp.('Sr; ** E 1\: D 0 F" 1) A. T A **** FILF'. FJLF NAtl.1E; SERVICE VERSION DATE' MAX REC STZF" FILE TYPE LAST FItJE **** F~ILE FILE NA~4E SERVICE VER.SION DA'!'F MAX REC SIZE FILE' TYPE!.: LAST FILE -999.250 2773.50() -999.250 -999.250 -999.250 -999.250 ** r.R' t,', !"O' ,:t, . '"\ W RP.MWD RHOa. ~lWD NPHI.. H~O 41.061 -999.250 -999.250 -999.250 ROP;,- ~1WD DER. N'tjD DRHO.MWD NCNT.MWD '1'RAIT,ER **** : FDIl' .001. : FLIC : OOtCOl : 94;/11/15 : 1024 : t,D . .. HEADER **** : EDIT .()O2 : FLIC : OO'COl : 94/11./15 : 1024 : [dJ . .. f'ILF HEAD!.£< ,"1 LE NUMBER: EDtTED MERGED MAD Depth_hifted aod DEpTH INCREME:~J'r: # FIL¡E SUMMARY T.,D\~!G TOGII CODE~ ..........""".-......... 2 clipped burvesJ all bit runs merged, 0.5000 START DEPTH ....--..-.... 4635.0 4564.0 STOP DEPTH .-......... 5647.0 ' 5647.0 CDR CDN $ # BASFLINE CURVE FOR SHIFTS: GRCH CURVE SHIrT DATA CMFA5UREÐ DEPTH) # A ôt) t'\ ð 0 " a e 0 t" .' RA5f~r,.Ir-.'!E DEPTH .-........-.............. -999.250 -999.250 -999.250 -999.250 .- - .. -.. ...... E QUI V ALE N'1~ UN S H I F 1~ ED, DE P T Ii"".. - -- .... BaeS6.5 FET.MWD VRA.MWD PEF.MWO FCNT.MWD PAGE: 5 .999.250 -999.250 -999.250 -999.250 IS Ta~e verifIcation Listinq ,chlumberqer Alaska ComputlnQ Center 15-NOV-199415:35 s 5583.0 5426.5 5273.0 5226.5 5191.0 5141.("1 5068.5 5035.5 489~.O 4795.5 4752.0 4678.5 4657.0 100.° 5579.5 5422.5 526B.5 5219.0 5183.5 5136.0 5064.0 5032.5 4895.5 4789.'5 4746.0 4672.5 4653.0 96.0 # MFRGED DATA SOURCE I D\I,íG TOOT.J CODE BIT ~UN NO. MERGE TOP --~----.--- --------- MERGE BASE l1li------."'- .-...-.-------... $' I RFMl\RKS: THE BASE CURVE WAS THE GRCH OVER THE INTERVALS 9595 TO 8260 AND FROM 5616 TO 3614. S " LIS FORMAT DATA ** DATA FORMAT SPECIfICATION RECORD** ** SET, 'TlP£-64EB *. ~-~---~~-~--~-_.-~...__.-.~~-- TYPE REPR CODE VALUE .____M-___..-"-------...-.-.-. 1 66 0 2 66 0 3 73 60 4 66 1 5 66 6 73 1 65 8 68 9 65 11 66 12 68 1,3 66 14 65 15 66 16 66 0 66 °.e.,5 '",1- 11 0 FT 68 :1 1 ---..---..-.---------.-.-...-- PAGE: 6 IS Ta~e verification L1stlna chlumberger Alaska ~omputlng Center ** SET TYPE - CHAN ** 15-NQV-199415:35 PAGE: 7 -_w_--------.---------------.--.---.----.----------.-----------------------.-.-.------- NAMF SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS TO ORD£R # LOG TYPE CLASS MOO NUMB SAMP ELEM CODE (HEX) --------------------.------.---------------------------------------.----.-----------.-. DfpT FT 00 000 00 0 2 1 1 4 68 0000000000 GÞ MAD GAPI 00 000 00 0 2 1 1 4 68 0000000000 Rap MAO FPHR 00 000 00 0 2 1 1 4 68 0000000000 RA ~AO QBMM 00 000 00 0 2 1 1 4 68 0000000000 RP ~AO OHMM 00 000 00 0 2 1 1 4 68 0000000000 DER ~AD OHMM 00 000 00 0 2 1 1 4 68 0000000000 yRA MAD OHMM 00 000 00 0 2 1 1 4 68 0000000000 yAp ~An QHMM 00 000 00 0 2 1 1 4 68 0000000000 RHOP ~AD G/C3 00 000 00 0 2 1 1 4 68 0000000000 DRHO MAD G/C3 00 000 00 0 2 1 1 4 68 0000000000 PEr MAD BN/E 00 000 00 0 2 1 1 4 68 0000000000 CAL~ MAD IN 00 000 00 0 2 1 1 4 68 0000000000 NPHT MAP PUNS 00 000 00 0 2 1 1 4 68 0000000000 NCNT MAD CPS 00 000 00 0 2 1 1 4 68 0000000000 rCNT MAD CPS 00 000 00 0 2 1 1 4 68 0000000000 -----.....----..--.---.-.-----------.-.-.-...-.---.....--.--...-...--.-.-----.....-..-- ** DA'rA DFP'T'. RP.MAO RHOB.MAD NPHT.MAD DEPT. RP.MAD RHoa,MAD Nt'H! .M'AD ** ** 5647000 2:736 2.071 41.200 4564.QOO -999.250 .9 Q a, ,") '5' t', '"""""",.",;z",..!".".",,",'",,/IIo"",' ",,\I,'" -9., ~r:'25 0 END OF OATA ** **** FIL~ FILE': NAME SERVICE VERSION DA 1'ft' MAX R~C SIZE FILE TYPE. Ll\ S'T' F I tIE GR.- MAD DER¡MAD DRHCh.MAD NCNT.MA,D GR. MAD DER;.MAD PB.HO,¡¡.MAD NC1\l1'~: MAD TRAILER **** : EDIT. 002 ;FLIC : f'tO1COl ; 94:/11./15 : 1024 : tIC) . . 73.882 2.786 0.055 265.750 -999.250 -9 9 9.,~"; 0 . 9 9 9... "0, ,'1""""""",;. ,,' ." ...999; , ',,"'0 ROP.MAD V'RA.,MAD PEFi,MAJ) rCNT;.MA,D ROP~MAD V RA¡,¡; MAI) p E'~.M AD FCNT;MAD 745.930 -999.,250 2.501 5,.590 -999.250 -999.250 - 9 9i~,2iO "6;0 '37 RA.MAD VRP,. MAD CALN.MAD 2.886 -999.250 9<.815 RA,.MAD VRP..MAD CAx",N>.MAP .. .999.~50 -999.25<> -999'j.¡SO ""~"""""'":'."'",:,_~..~": ",',"'"," """.','.,'.-'" ""1 "..~".. '!'" """-,, ".., ,..""", .."." ""'."'" ,.'" '!""'" 'I.' ".""""'-,""""""':!C:' _....,~-..".., -,"""""""""'" "-""-"" """~""'" "',""'~"'" -,.""""""""":""",~:,~""""",-~"",:-",,,,"""',""""'-'":~":"",""~"'~""~'C:' '"":C":"":"'"-":""~"""":'.'-'.~"-"':"."""""'""""",:-"",....."",,""~::::""":'-"'""""~~'r,"',-"',""":"-':'~:',"..,M"""""""""""2""""""""""""""'-". "":,::,-"~.",,,,,=,,~.....,. ':'."""'" IS Ta~e verification L1stino chlUmberger Alaska Computing Center 15-NOV-199415:35 **** fTLE FTLF' NAME SFRVICE VERSIOi\ OATf M~X HEC SIZJ:'. FILF TYPE LAS 'T' F I TJ E HEADRR **** . c::"DT'f "3 " ", !.' . 0,. : FLIC : 0O1COl : 94/11/15 : 1024 : LO . .. rTLF HEADER FTLF ~TUMBf1'R R~W M¡~D ('urves and loq BIT RUN NUltfBER; DFP'T'H 1 NC~EMEf\TT: # FTLF SUMIV¡~HY {.[)WG TOOl" COnE 3 header data for each bit run in separate 1 0.5000 START DEPTH stoP DEPTH ."".-..-.............. -.-------.- --.-.-.... 5650,5 CDR $ 2775.0 # LOG HEADER DATA DATE LOGGED: SOFTiiJARE: SURFACE SOFTWARE VERSION: DOWNHOL! SOFTWARE VERSION: DATA TYPE (MEMORY or REAL.TIME): TO DRILLER eFT): . TQ?LCJG. INTE:RV.t\Lt (F:rJ: ~aT'rOMLnG INT!RVAl rFTl = 8IT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: M AX.IMUM ANGLe: I TOOL STRING (TOP TO V~NÐOR TOOLCOOE -..-..-.-........-.-.. COR $ BOREHOLE AND CÄSING DATA, OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (L8/G): MUD VISCOSITY (8): ¡vHJD PH: MUD CHLORIDES (PPM): # BOTTOM) TOOT) TYPE .............. PHASE & AMP RESISTIVITY # ((í'T) : # OS-OCt-94 LOGOS 20.S FAST 2.5 MEMORY 9750.0 ~"l,.~".~.,.,':"8. 80 43.5 49.9 TOOL NUMBER ....".--..'" RGSO22 8 50,0 2533.0 10,50 42.00 ~' tiles. PAGE: 8 ¡IS Tare verif1cation Listinq 'ChlUmberqer Alaska Computing Center 15-NUV-199415:35 TOOL STANDOFF (IN): ~WR 'R~QUENCY (HZ): ************ RUN 1 ************* RGS READOUT PORT TO B1T:52.04 FT~ ð~jLr~DRI~ia3Af72~lo ~~,g;¡¡f5~f29 ~T ************ RUN 2 ************* RGS R~ADOUT PORT TO BIT:59.51 FT. §~~ ~~A~~~15~ð~~ ~Z B¥~:IY7:j~;~'~76 FT DEN TO 8IT:119.28FT NEUT TOBITt126.26 FT DRILLED INTERVAL 5651 FT TO 9750 FT CON ~ASHDOWN DATA 4570 F1 TO 5651 FT WELL TO AT 6:50 ON 10-5-94 HOLE INCLINATION AT TDt29.0 DEG, $ # LIS fORMAT DATA # F'LUTD Lnss (C3): ~nXTMUM RFCORnEP TEMPFRATURE (OEGF): RESTSTIVITY (OHMM) AT TEMPERATURE (OEGf): ~UD AT ~EASUPEr TEMPERATURE eMT): ~UD AT MAX CIRCULATI~G TEMPERATUR~ : ~UD FILTRATE AT (MT): MUD CAKE A~ (MT): f,TEtTTPON TonL MA1.'RIX: ¡,,\ATRIX DENSIrry: HOLE CORRECTION (IN): # # RFMßRKS: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** ~--.----_...._---------..-...- TYPE RftPR CODE. VALUE ----------------------..-.---- 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 a 68 9 65 11 66 12 68 13 66 1.4 65 0,5 FT 36 0 FT 140.0 2.390 2.080 0.000 SANDSTONE 2.65 8.500 1.000 PAGE: 9 79.0 71.0 0.0 IS Tape verlfjcation Listing ,chlumberaer AlasKa Computing Center 15-NOV-199415:35 PAGE: 10 -------------.-----------.-.-- TYPE RFPP CODE VALUE ---------------------------.s- 15 66 68 16 66 1 0 66 1 .------------.---------------- ** SET TYPE - CHAM ** -----.----.---.-----------------------.----..---.-..-------------------....------.----- N~M~ SERV UNIT SERVICE API API API API FILE NUM8 NUMB SIZE REPR PROCESS to ORnER # LOG TYP~ CLASS MOD NUMB SAMP ELEM CODE (HEX) -------------._----------_._--~-----------_..__._._.--._----_.-._----_._---_..-_._.-.~. DEPT FT 00 000 00 0 3 1 1 4 68 0000000000 GP Lwt GAPI 00 000 00 0 3 1 t 4 68 0000000000 ROPF Lw1 F/HF 00 000 00 0 3 1 1 4 68 0000000000 TAB {¡WI HR 00 000 00 0 3 , 1 4 68 0000000000 ATR Lwt QHMM 00 000 00 0 3 1 1 4 68 0000000000 PSI< LW1 OHM!\.' 00 000 00 0 3 ,. 1 4 68 0000000000 PER LWl QHMM 00 000 00 0 ) 1 1 4 68 0000000000 ._.....------_._--.-.---.----_._---_.._..~....._............-.-..-.-..-.....-....-..... ** DATA DEpT. ATR .l;W 1 DEPT. ATP..tJWl ** END OF, DAT.A **** fILE FILE NAME SERVICE VERSION DATE MAX f(FC SIZE FILE' TYPE LAS" rIllE **** FILE FILF NAM~: SERVICE v, " E' R, ~ I' f"I ",:' , ~,,' \,) ¡~ DArE MAX REC SIZE F' t,' I . f;( T, Y P,E"" . '"J',. , LAST FIlIE ** 5,6~O.,500,. -9'19.250 27'5.000 -999.25Q GR.LWl PSR.LWl GR.LW 1 PSR. LW 1 -999.250 -999.250 41.061 -999.250 " 98.904 -999.250 -999,.250 -999.250 TAB.IJW1 '.999;.~:250 TAB.LW1 -999.250 RQPE.LWl DER~LWl ROPE~LWl DER¡LW 1 ** TRAILER **** : EDIT .003 : F LIC : DOiCD! :9411 t /1 5 : 1,024 : fJO . . HEADER **** : €Drr .004 : ~~LIC : 0O1CO1, : 94/11/1 5 : 1024 : co . Of IS 'T'aoe verification List1r¡q Chlumberger Alaska Co~putlnq Center 15~NOV-1994 15:35 F T Lf.'" HE: ADER FILE' NOMBJO'fi; R a. ~'. f.. W D rurves and loa BIT RHN N!JiAAEP: OF?,. H I NCR EMEt,; 1': # FILE SUM,MARY J..I[)wG TC'OTJ cnrnt 4 header data for each bit run In seoarate 2 0.5000 S'J.'ART f'EPTH stop DEPTH .-.------- 9750 9750 ---.--M_-_-__- ---------... COR r.D~,! $ 5651.0 5651.0 # LOG HE'.Aoe:R T)A'TA DATE LOGGED: SOFTWARE: SflRF'ACE SOF"'ltJl1RE VERSION: DOWNHO~E SOFTWARE VERSION: ' DATA TYPE (MEMORY or REAL.TIME): Tn DRILLER (FT): TOP LOG INTERV1\L (F'r): ROTTOM LOG INTERVAL CFT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DIG) MINIjII¡U~\ ANGlJE;: N¡AX!fIIUr~1 ANGrJE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE .......-..--.-----.. --------- COR PHASE 'AMP RESISTIVITY CON DENS..' Nt;lJTRON POROS1':t'1 S BOREHOLE AND CASING DATA OPEN HOhEBIT SIZE (IN>. DRILLERS CASING OEPTH CrT>: # # AQREHOLE CONDITIONS MUD TYPE: Þ~UDDF.NSITY (ld3/G): MUD VISCOSITY (S)~ NUJD PH: ~H.TD CHLORIO8S (ÞPM): FI,lJID LOSS CC3): ^XINUMRECORD~:D TE:r~PERATURE COEGF): RES IST ¡VI TY' (OHMfliD A'X TEMPER ATURE ,"EOr): MUD AT M€ASURED Tr;MPERA1~URE eM'!'): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT (M!),: MUD CAKE AT (NT): !'fEUTRON TOOL ~!¡A'tRIX: # 05-QCr-g4 LOGOS 20,S FAST 2.5 MEMORY 977S0~' .°0' 28. 969.0 80 46.7 29.0 ," TOOL NUMBER ......,....... RGSO22 NO~O22 8 ii" Q, 0".,' .", 2ø33.0 1 0,'50 42,00 140.0 2.390 2.080 0.0.00 SJHJDS1\()NE PAGE: 11 - files. 79.0 71.0 0.0 IS Ta~e Verification Listinq chlumterger Alaska Co~putlnq Center 15-NOV-199415:35 # ~/, A T R I X DE r-.; S T '1: v : hOLE CORREcrlON (IN): TOOL STANDOFF (IN): EwR FREQUENCY (HZ): 2.65 8.500 1.000 FORMAT SPECIFICATION RECORD ** ** SET T¥PE - 64EB ** ----.---.----.--.--.--.--.-..- TYPE REPR CODE VALUE ---....-.---..-----..-.-..-.-- 66 0 66 0 73 64 66 1 66 73 65 68 65 66 68 66 65 66 66 66 # RFM~RKS: # LrS FORMAT DATA ** OATA ."-'------- ************ RUN 1 ************* RGS RFADOUT PORT TO BIT:52,O4 FT RFS TO,~," BIT,.,:48.S7 FT G,R TO,,' B,,11:, S§£,,29 F1 DPILLFD INERVAL 2860 FT Tn 5651 FT ************ RUN 2 ************* RGS READOUT PORT TO BIT:59.51 FT. RES TO RIT:56.34 Ft GR TO ~IT:66.76 FT DEN READOUT PORT TO 81T:117 97 FT D~~ TO 811:119.28 FT NFUT to BIT:126.26 DRILLED INTERVAL 5651 FT TO 9750 FT CON WASHDOWN DATA 4570 FT TO 5651 FT wFLL TO AT 6:50 ON 10-5-94 HOLE I~CLINATrON AT 10129.0 DEG, $ ~ 3 4 5 '6 7 a 9 11 12 1.3 14 1.5 j,6 () ~~5 16 0 F'T 68 1 1 -.._....._.~--._-----~._-.._-. FT PAGE: 12 IS ,. ape Ve r i f 1 cat j, 0 n Lis t 1 n q chlumberger Alaska Co~putlng Center lS-NOV-199415:35 ** SET TYPE - CHAN ** -.-.--------___.__8______.-----------.---------.---------------------.-.--------------- NAMF SERV UNIT SERVICE API API API API FILE NOMB NUMB SIZE REPR PROCESS 10 ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) -------------------------------------.--.--.--.--.----.---..-.-----------.---.-.--.---. DFpT FT 00 000 00 0 4 1 1 4 68 0000000000 GR T,w2 GAP! 00 000 00 0 4 1 1 4 68 0000000000 ROPF LW? F/HR 00 000 00 0 4 , 1 4 68 0000000000 T A E~ I, w ? H ROO 0 0 0 0 0 0 4 1 1 4 6 8 0 0 0 0 00 0 0 0 0 TAB~ Lw2 HQ 00 000 00 0 4 1 1 4 68 0000000000 ATR Lw2 OHM~ 00 000 00 0 4 1 1 4 68 0000000000 PSR LW2 QHMM 00 000 00 0 4 1 1 4 68 0000000000 DER Lw2 OHM~ 00 000 00 0 4 1 1 4 68 0000000000 RHOP LW? G/C3 00 000 00 0 4 1 1 4 68 0000000000 DPHT I,W2 PO 00 000 00 0 4 1 1 4 68 0000000000 DPHO LW2 G/C3 00 000 00 0 4 1 1 4 68 0000000000 PFF [,W2 8N/F 00 000 00 0 " 1 1 4 68 0000000000 DCA' TJw2 IN 00 000 00 0 4 1 1 4 68 0000000000 TNpB LW2 PU 00 000 00 0 4 1 1 4 68 0000000000 HENA LW2 CP5 00 000 00 0 4 1 1 4 68 0000000000 HFF~ LW2 CPS 00 000 00 0 4 1 1 4 68 0000000000 ..~...--.--_._-_._.._----_..__..--_...--~....--...._.--.--..-..--.-.....-.-......-..-.- ** DATA ** DEpT. TABD.LW2 RHQB.t,ìÞJ2 DCAL.LW2 DEpT. TA at). t"W2 RHOP.IJW2 PCAL.tJW2 -999.250 -999.250 -999.250 -999.250 76.4.14 2,..$~ 9 36;3vO 42.700 TAB.LW2 DER.LW2 PEF.LW2 HEFA.LW2 TAB.LW2 DER.JJ,.W2 PEr.LW2 HEFA.LW2 74.694- -999.250 -999.,250 -999.250 732.611 2.741 O~O5' ' 266.769 9750.000 -999.250 -999.250 -999.250 5651..000 - 9 99.,250 2;052 1.333 GR.LW2 ATR~LW.2 npHI.LW2 TNPH.LW2 GR.LW 2 A TR,'LW.2 . DPHI!'LW2 TNPH.LW2 R()PE.LW2 paR~.J:..W2 DPHQ.'LW2 RENA~.LW2 R g,I,'.~,,¡t~i , '~kN'A!~E:~ ** END OF DATA ** **** FILE FILE N¡PH1~ SFRVICE -ViF'R,~ 10'1 ""', 1..,., , ,\,. D A'l'F MAXREC 5IZF'. FILF TYPE LAST FIT,e: THAIt,ER **** : EDIT, 004 : FLIC : 00 tC 0 1 : 94/11/15 : 1024 . TO'" It ,j.. II " PAGE: 13 -999.250 -999.210 -999.250 -999.250 ~:;~3i ~:¡lå IS Tape Verification ListinG chlumberQer Alaska Computing Center 15-MOV-t99415:35 **** fILE FTL~ NAME SERVICE VERSIOì'-t UATF" fvlAX RF'.C SJZ'" FII.JF TYPE; LAS'" FILE HEADF'R **** . r".,' ¡, T", :[' ("u' () 5 .. ,...:, " . : FLYC : ovlCOl : 94/11/15 : 1024 : Lei . ,. rT LE HE:ADER F'YLF t,IUMBER RAW MAD Curves and loq BIT RUN NUMRER: . DFpT H 1 NCR E~H1:~' T: .. F'YLE SUMMARY r,D~¡G TOQIJ CODE: 5 hpader data for each bit run in seDarate 2 0.5000 STÞ.RT DEPTH STOP DEPTH ------.--- 5650.5 5650.5 ---..---------. ----------- COR CON $ 4568.0 4568.0 tF LOG HFADER DA,tA DATE LOGGED: SOFT\!\fARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): '1'1) DR¡LL~R{.FiI':l:l .> ,', '. TOP I,~OG INTER'VA).., (Ftf: BOTTOM LOG INT!RVAL(FT): PIT ROTArl~G SPEEOCRPM)t HOLE INCLINATION (DEG) i~ I ~ i ~ S~ ~ ~~ gt~ ¡ TOOT.! STRING (TOP TO VENDOR TOOL COpg .....--..-....-.......-- Cf)R CDN $ ROREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH CFT): # BOTTO~t) TOOL TYPf; "'-...-..-- PHASE & AMP REStSTIVITY DENS & NEUTRON POROSITY # # RQREHOtE CONDITIONS '\!'it1D T,y' P,E 11 I, .." ' "", ",,'.. MUD DENSITY (La/G): MUD VISCOSITY (8): OS-OCT-94 LOGOS20.S FAST 2.5 MEMORY ~~; ii:: g 9692.0 80 :~:i TOOL NUMBER --.....-..... RGSO22 NDSO22 8.500 2833.0 to.50 42,00 . files. PAGE: 14 í.. ) "'r~"~"'-'c=-'-:"'~""'"'"'"'-"~""""""""-'."'--'-'.'--"'""--""""i'""'~",""i'....""...,..."",.....",..,....,..,. ,..",~",...,..c...~",."",.."".".",..", """, ""c",."" "'Z""""""="~""!"~"""~.".'!F~'"="'="'="""".'"'0'""",."",="",=, "",, ".,""'",",", """""""",="""""".,."",""".",.-"".""",,,,, """","""",-,,',,=,,'" ""',,",,, -"'""~"""""~'".""','"""":""""",:o""",,,-,, ~-"""""e,,,,"-::~",-,:""""':' ,"c",,"'-" ' IS Tape Verification Llst1nrJ chlumberqer Alaska Computinq Center 15-NOV.199415:35 ., ;\dJl) PH: r-,¡ t1 D C H L 0 HT D F S (P P 'Î!) ~ FCUTD LOSS (C3): MAXIMU~ RECORnED TEMPERATURE (DEGF): RE5TSTIVITY (OHMM) AT TEMPERATURE (DEGF>: MUD AT MFASURED TEMPERATURE eM!): MUD AT MAX CIRCULATING TEMPERATURE: MUD ~ILTRATE AT (~T): MUD CAKE AT (MT): ~I EIJTRON TOOL MATRIX: Ml\TRIXDENSTTY; HOLE CQRRFCTION (IN): TOOL STANDOfF (IN): EWR FREQUENCY (HZ): SANDSTONE 2.65 8 ..500 1.000 140.0 2.390 2.080 0.000 # # REMARKS: ************ RUN 1 ************* RGS READOUT PORT TO BIT:52.04 FT RES 1,°,.,81',.148187 FT, G, R TO""A,.I,TI,SJ£29 FT DRILLED INERV L 2860 FT TO 5651 FT ************ RUN 2 ************* RGS READOUT PORT TO 8IT:59.51 FTs RE.".S 11.-:',0811'561.34 F! . G"R,'1'OBI".TI6e.76 P'T DEN READOUT PoRT TO BIT:117£97 FT DEN TO BIT:119.28 FT NEUT TO 6ITt126.26 FT DRILLED INTERVAL 5651 FT 109750 FT CON WASHDOWN DATA 4570 rT TO 5651 FT WELAL, TO AT 6: 50 ON 10-5-94 HOLE INCLINATION AT TD129.0 DEG. $ DATA # LIS FORMAT ** DATA FORMAT SPECIFICATION RECORO** ** SET TYPE - 64Eß ** - -- -. -....... - .."'. ..1IIIt .... ........ -.--. TYPE R!PR CODE, VALUE ....-........-.-.......-.-..-...-- 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 a 68 9 65 11 66 12 68 0.5 FT 1.& 79.0 71.0 0.0 PAGE: 15 IS Tape Verification ListlnQ chlumherqer Alaska Computlna Center 15-NOV-199415:35 ---_w-...-----."-------.-.-.-- TYPE REPR CODe VALUE ------------.----------------. 1~ 66 0 14 65 FT 15 66 68 16 66 1 0 6& 1 ---------------..------------- PAGE: 16 ** SET TYPE - CHAN ** ----..---------------...-.-----------------------------------------.-------.----.-.---- NAMF SERV UMIT SERVICE API APT API API FILE NUMB NUMB SIZE REPR PROCESS TO nRrER # LnG TYPE CLASS MOD NUMB SAMp ELEM CODE (HEX) -.---------.-------------------------------------------------------.------.----.--.--.- DFpT FT 00 000 00 0 5 1 1 4 68 0000000000 GR MO1 GAP! 00 000 00 0 5 1 1 4 68 0000000000 RnpE MD1 F/HR 00 000 00 0 5 1 1 4 68 0000000000 TA8 MDt HR 00 000 00 0 5 1 1 4 68 0000000000 TAB~ MD1 HR 00 000 00 0 5 1 1 4 68 0000000000 ATR MDt OHMM 00 000 00 0 5 1 1 4 68 0000000000 PSR MDt OHMM 00 000 00 0 5 1 1 4 68 0000000000 DER ~D1 QHMM 00 000 00 0 5 1 1 4 68 0000000000 RHQB MOt GIC3 00 000 00 0 5 1 1 4 68 0000000000 DPHT MDt PO 00 000 00 0 5 1 1 4 68 0000000000 DRHO MOl GtC) 00 000 00 0 5 1 1 4 68 0000000000 PEF t~D1 aN/E 00 000 00 i 0 5 1 1 4 68 0000.000000 DCAL MDt IN 00 000 00 0 5 1 1 4 68 0000000000 TNPH NO1 PU 00 000 00 0 5 1 1 4 68 0000000000 HEN. MDl CPS 00 000 00 0 5 1 1 4 68 0000000000 -HEFA MDt cPS 00 000 00 0 5 1 1 4 68 0000000000 ._.....-..-.-.----.~.-_.__...-.-_...__.._-_..-...-.......-...._.-.--~--_..__..._.__.__. ** D,A1'A DePT. TA B D it MDt, RHOR.MDI DCAl-. MÞ1 DEPT. TABO.MD1 RJ40B. f<1D1. DCAL.MDl ** ** 5650.500 .999.250 2.071 1.315 4568.000 -999.250 -999.25C1 -999.250 ~:ND OF DATA ** ,""'".,,...,.-- "'-11""" """"-,r"""""'«""'" r'" 'I'"~ .'" '" '>",,',""f'" "~, I'" !""f""~'" "'1'" GR~f1,'O 1 ATR~MO 1 OPHI~MO1 TNPH.MDl GR.MD 1 ATR.MPl DPHI.l'-1Dl TNPH. MDl 13.882 2.886 35.100 41 .200 -999.250 "999.250 -999.250 -999.250 Rap E',~M D 1 PSftlilMD1 DRHO~MD1 HENA¡MOl ROPEc:.MDl P$Ri,MDl DRHO,t"MDl HENAiMDl "7 4S~;930 2.':16 0.Q55 265.750 -999.250 -999.,,250 -999.v250 -999.250 TAB.MD! DER.MD1 PEF.MDt HEFA,MDl TAB.MDl OER.MD1 PEF.MD1 HErA.MOl 0.442 2,:,',.,..'",'.78,', ,,' 2.501 5.590 ., 9,,99,..,".....,.,,2, 5' Q -999.250 -999.250 6.037 IS Tape Veriflcatio~ L1stlnQ chlumberger AlasKa ~omputinó Center **** fILE FJLF: t\!AME; ~FRVIcr," 0 t:'.. VER~Ic)N DATE MAX R~C SIZr. FIL1:' TYPE L~S" f:'IT..JE TKAlfJE;P **** : EDIT .úOS : FLre : 0O1COl : Q4/1l/1.5 : 1024 : LO . . **** 5FRVICE DATF. O~IGIM TÞPF NAME CC'N'T'INUATIQM # PPE"IOUS TAPE CO í\>\ t"f E"r T TAPE TRAILER **** NA¡\1~ : EDTT . : 94/11/15 : FLIC : 94340 : 1. . .. : RP EXPLORATION, lS.NOV-199415:35 PAGE: 17 MIT.JNF. POINT, ~1PJ"1l, API 50-029..22508.00 **** REf;f", SFRVICì~: NAÌ'ii~~ pATF. ORIGIN REEl;, NAME CONTINUATION # PREVIOUS REEL CCMME;NT TRAIliER **** : EDI~.(' : 94/11/15 : FLIC : 94340 . .. '" '" : RP EXPLORATION, MILNE POINT, MPJ-13, API 50-029-22508-00