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185-185
Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. ~(~'~- ~ (~ Well History File Identifier Organization (done) ~'Two-Sided RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: .. [] Logs of various kinds TOTAL PAGES: NOTES: ORGANIZED BY; BEVERLY BREN VINCENT SHERY~ LOWELL Project Proofing Other [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /si Scanned (done) SCANNED BY; ~ BREN VINCENT SHERYL MARIA LOWELL Is~ ReScanned (done) RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ General Notes or Comments about this file: PAGES: /-7~'~ Quality Checked (done) RevlNOTScanned.wpd ~ ~ STATE OF ALASKA ~ ~ ~ ~S~ 'Fe AL~ OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPE~~-~I~I'~~ ~;2°°t ~`4s° {~ + - p''r~r~ :"` _ ' „ Water SOUI'Ce Well • • 1. Operations Performed: , ..,;, ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate '" ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown Change Out ESP ' ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 185-185 ' 3. Address: ®Senrice ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20873-01-00 7. KB Elevation (ft): 56, 9. Well Name and Number: MPA-02A 8. Property Designation: 10. Field /Pool(s): ADL 047437 ~ Milne Point Unit / Kuparuk River Sands - 11. Present well condition summary Total depth: measured 3725 • feet true vertical 3167 - feet Plugs (measured) None Effective depth: measured 3603 feet Junk (measured) None true vertical 3082 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 20" 115' 115' Surface 2897' 13-3/8" 2897' 2584' 4930 2670 Intermediate Production 3686' 9-5/8" 3686' 3140' 3520 2020 Liner s~~i~ ~Ul.. ~ 2~~~ Perforation Depth MD (ft): 3282' - 3521' Perforation Depth TVD (ft): 2859' - 3025' 4-1/2", 12.6# L-80 2786' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): Gravel Pack Screen Assembly with 9-5/8" Baker SC-1 A 3124' - 3547' Packe r and a 9-5/8' Baker Model 'D' Sump Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ^ Development ®Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ^ Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Howard West, 564-5471 N/A Printed Name Sondra Stewman Title Drilling Technologist ~ Prepared By Name/Number: ~ Sig ature - Phone 564- t~1 '~ -(~ Sondra Stewman, 564-4750 Form 10-404 Revised 04!2006 ~ ~ 0 ~ '~ ~° s'~~~- ~ ~ Z~~~ Submi~inal Only A 7. g ~o Tree: Cameron 4 1/16" Wellhead: FMC 13 5/81" 5M, w/ FMC 11" x 4.5" NSCT (top and bottom) G-6 Tbg. Hnr. and 20" 91.1 ppf, H-40 11 MPU A-2a WSW Orig. K~v. = 56.0' (N 27E) Orig. v. = 21.0" KOP @ 650' Max. hole angle = 50 deg. @PBTD Hole angle thru' perfs = 47 deg. No DLS > 4°/100' 13 3/8", 72 ppf, L-80 Btrc, surface csg. 9 5/8" 36 ppf, K-55, Btrc. prod. casing (drift ID = 8.765", cap. = 0.0773 bpf ) 4.5", 12.6 ppf, L-80, IMP Btrs. tbg. (cap. = 0.01522 bpf, drift ID = 2897' Gravel Pack Summary 9/19/85 - 88 cu. ft. 20/40 Ottowa sand Perforation Summary Ref log: 08/16/85 -DILL Size SPF Interval (TVD) 5" 12 3282' - 3294' (2856'-2864') 5" 12 3308' - 3362' (2875'-2912') 5" 12 3396' - 3460' (2934'-2977') 5" 12 3464' - 3521' (2980'-3018') DATE I REV. BY I COMMENTS Centrilift ESP 2743' 16-HC12500 HPLT pump. Centrilift Seal Sections 2752' GS63DBUT SB/SB PFSA GS63DLT SB/SB PFSA CL5 Centrilift KMH 2766' Centralizer 2782' 190 hp motor, 2415 v. / 48 amps. ?) 9 5/8" x 8.7' Lynes 3016' ] external casing packer. 9 5/8" Baker SC-1A pkr. 3124' 5.5", 17 ppf, blank pipe 5.5", 17 ppf, 12" ga. screen 3525' (ID =4.892"} 'O' ring sub (ID = 2.375") 3268' 5.5" 12" ga. tell tail screen (ID = 4.892") Baker Model 'D' sump pkr. 3547' 9 5/8" float collar (PBTD) 3603' 9 5/8" float shoe 3686' 11/23/96 JBF Latest ESP Completion by Nabors 4ES 04/12/98 M.Linder RWO Nabors 5-S 6/5/08 REH ESP RWO -Nabors 3S MLLNE POLNT UNIT WELL A-2a WSW API NO: 50-029-20873-0'1 BP EXPLORATION (AK) BP EXPLORATION Operations Summary Report Page 1 of 3 Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: From - To MPA-02 MPA-02 WORKO NABOB NABOB Hours VER S ALASK S 3S Task DRI ~, Code' LING NPT ', Start I Rig Rig Phase Spud Date: 12/18/1982 : 6/2/2008 End: 6/6/2008 Release: 6/6/2008 Number: Description of Operations 6/3/2008 00:00 - 02:00 2.00 MOB P PRE Rig down and prepare to move off of Z-pad. 02:00 - 07:00 5.00 MOB P PRE Move Carrier, Pits and Pipe Shed from GPB Z-pad to MPU A-pad. 07:00 - 09:30 2.50 MOB P PRE Stage equipment on A-pad and lay mats around A-02. 09:30 - 11:30 2.00 MOB P PRE Lay herculite and spot carrier over A-02, spot Pit Complex and Pipe Shed. 11:30 - 13:00 1.50 MOB P PRE Raise and scope derrick. Pin windwall and secure guy lines for derrick 13:00 - 14:00 1.00 MOB P PRE Berm rig, secure walkways and stairs, hook up flowline, mudline, electrical lines, steam lines, waterlines and rig up floor. Rig accepted at 14:00 hours. 14:00 - 19:00 5.00 KILL P DECOMP R/U lines to tree for well kill and test line to 3,500 psi. 19:00 - 00:00 5.00 KILL P DECOMP Wait on seawater trucks and tiger tank to be delivered and set up. Seawater trucks arrived at 20:30 hours. Tiger tank and rig up crew arrived at 00:00 hours. 6/4/2008 00:00 - 01:00 1.00 KILL P DECOMP Lay herculite and set tiger tank. Rig up hardline from choke to tiger tank and test to 500 psi. 01:00 - 02:00 1.00 KILL P DECOMP R/U lubricator and test to 500 psi with diesel. Pull BPV. 100 psi on the tubing and 170 psi on the IA. R/D lubricator. 02:00 - 05:00 3.00 KILL P DECOMP Pump 45 bbls of 120 degree seawater down tubing taking returns out the IA through the choke out to the tiger tank. 2-1/2 bpm at 80 psi. Gas and diesel returns. Line up and bullhead 40 bbls of 120 degree seawater down the tubing at 2-1/2 bpm with 100 psi. Shut down, tubing pressure 10 psi and 80 psi on the IA. Line up and pump 215 bbls of 120 degree seawater down the tubing taking returns through the choke to the tiger tank. 3 bpm at 130 psi. Diesel and water returns. 8.4 ppg in and out. Pumped 260 bbls around and had 175 bbls of returns. 05:00 - 08:30 3.50 KILL P DECOMP Monitor well, 10 psi on the tubing and 30 psi on the IA. Call out MI mud engineer to assist with weighting up of fluid with salt to 8.7 Pp9• 08:30 - 10:00 1.50 KILL P DECOMP Break circulation with 8.7 ppg brine down the Tubing taking returns up the IA back into the Pits. Pumping at a rate of 3 bpm / 100 psi with returns after approximately 10 bbls away. Pumped a total of 250 bbls with 124 bbls of losses. Final MW in = 8.7 ppg ,final MW out = 8.5 ppg. 10:00 - 10:30 0.50 KILL P DECOMP Shut in and monitor well due to no more salt on location to wei h u the seawater. SITP = 0 psi ,SICP = 0 psi. 10:30 - 12:00 1.50 KILL P DECOMP Wait on more salt to arrive. Discuss with Anchorage Engineering and decision made to circulate another wellbore volume and see if we can achieve 8.7 ppg returns. 12:00 - 12:30 0.50 KILL P DECOMP Salt arrives on location, weight up the Pits to 8.7 ppg. 12:30 - 13:30 1.00 KILL P DECOMP Break circulation at a rate of 3 bpm / 100 psi with 8.7 ppg brine. Get returns on surface after 15 bbls away. Slow down to 2 bpm / 50 psi to lessen the loss rate into the formation. Pum ed a total of 12 Is with 50% losses. Final MW in = 8.7 ppg ,final MW out = 8.4 ppg. 13:30 - 15:30 2.00 KILL P DECOMP Shut in and monitor the well. SITP = 0 psi ,SICP = 0 psi. Fill up the Pits and weight up to 8.7 ppg. 15:30 - 16:00 0.50 KILL P DECOMP Break circulation at a rate of 2 bpm / 40 psi and get returns after 2 bbls pumped away. Very small amount of returns. Observe returns fall off to-about 1/3 bpm. Pumped 73 bbls and shut down. Printed: 6/30/2008 9:28:25 AM • BP EXPLORATION Page 2 of 3 Operations Summary Report Legal Well Name: MPA-02 Common Well Name: MPA-02 Spud Date: 12/18/1982 Event Name: WORKOVER Start: 6/2/2008 End: 6/6/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/6/2008 Rig Name: NABORS 3S Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 6/4/2008 16:00 - 17:00 1.00 KILL P DECOMP Line up down the IA and bullhead an annulus volume of 150 bbls down the IA at a rate of 2 bpm / 50 psi. 17:00 - 18:00 1.00 KILL P DECOMP Shut down and monitor the well. Fill up the Pits with seawater and weight up to 8.6 ppg per discussion with Anchorage Engineering. 18:00 - 18:30 0.50 WHSUR P DECOMP Install Cameron 4" Type H TWC and test from above to 3 500 si for 10 charted minutes. Good test. 18:30 - 19:30 1.00 WHSUR P DECOMP R/D lines from tree and remove from cellar. 19:30 - 21:00 1.50 WHSUR P DECOMP N/D 4-1/16" tree. Clean and inspect hanger threads, inspect lock down screws. Test 4-1/2" NSCT XO in hanger, 9.75 turns to make up. Gravity feed IA with 8.6 ppg fluid, taking 16 bph. 21:00 - 00:00 3.00 BOPSU P DECOMP N/U 11" x 13-5/8" 5M DSA, N/U 13-5/8" 5M BOP stack. Gravity feed IA with 8.6 ppg fluid, taking 16 bph. 6/5/2008 00:00 - 01:30 1.50 BOPSU DECOMP N/U 13-5/8" 5M BOP stack, install choke line, kill line and koomey lines. Install flow riser. Gravity feed 8.6 ppg fluid into IA while nippling up, taking 16 bph 01:30 - 02:00 0.50 BOPSU DECOMP Function test BOP stack. 02:00 - 06:00 4.00 BOPSU DECOMP Fill BOP stack and choke manifold with water. Test Blind rams, VBR's, Annular Preventer, Choke Manifold Valves, Hyd Kill and Choke Valves, Manual Kill and Choke Valves, TIW and Dart Floor Valves to 250 psi low pressure and 3,500 psi high pressure, Hold each test for 5 minutes on the chart. Used 4-1/2" test joint. Perform Koomey draw down test. AOGCC witness of test was waived by Chuck Scheve, test was witnessed by the BP WSL and Nabors Toolpusher. No failures. Gravity feed IA with 8.6 ppg fluid, taking 15 bph. 06:00 - 08:00 2.00 WHSUR DECOMP Pick up and make up Opso Lopso and Lubricator with Polished Rod with Well Support Techs. Pressure test to 500 psi with diesel -good. Pull 4" Type "H" TWC. The Tubing is on a vac. Break out and lay down Lubricator and Opso Lopso. 08:00 - 10:00 2.00 WHSUR DECOMP Pick up Landing Joint with 4-1/2" NSCT XO for the Hanger. BOLDS with FMC rep. Pull the Hanger to the Floor with a PUW = 48K. Observe the fluid on top of the Hanger fall out of the Stack. Fill the well with 10 bbls of 8.6 ppg brine. Bring Centrilift tools to the Rig Floor. Break out and lay down Tubing Hanger and Landing Joint. 10:00 - 13:00 3.00 PULL DECOMP Pick up and make up TIW Valve and Headpin. Break circulation with 8.6 ppg brine down the Tubing taking returns up the IA at a rate of 2 bpm / 50 psi. Hang ESP Sheave and Elephant Trunk while circulating. Circulate surface to surface until returns cleaned up. Small amount of crude in returns. Final MW in = 8.6 ppg ,final MW out = 8.6 ppg. Pumped a total of 220 bbls. Blow down and rig down lines. 13:00 - 18:00 5.00 PULL DECOMP POOH with existing 4-1/2", 12.6#, L-80 IBT ESP Completion. Laid down the first 14 oints o Range 3 Pipe he Pipe Shed. POOH standing back the remaining 37 stands (74 Joints) in the Derrick. Maintaining 20-30 bph fill rate with 8.6 ppg brine while POOH. The ESP Cable is covered in crude. Recovered 188 bands. 18:00 - 21:00 3.00 PULL DECOMP Break out and UD ESP assembly. 21:00 - 22:30 1.50 PULL DECOMP Clear and clean rig floor, box up old ESP and remove from pipeshed. Put new ESP in pipeshed and remove from boxes. Remove containment trunk. Printed: 6/30/2008 9:28:25 AM BP EXPLORATION Operations Summary Report Legal Well Name: MPA-02 Common Well Name: MPA-02 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 3S Date From - To Hours ', Task ~ Code NPT 6/5/2008 22:30 - 00:00 1.50~UNC01~1 6/6/2008 00:00 - 02:30 2.50 RUNCO 02:30 - 08:00 I 5.501 RU 08:00 - 09:00 I 1.001 RU 09:00 - 10:30 1.50 RU 10:30 - 11:30 1.00 RU 11:30 - 13:00 I 1.501 WHSUR I P Start: 6/2/2008 Rig Release: 6/6/2008 Rig Number: Page 3 of 3 Spud Date: 12/18/1982 End: 6/6/2008 Phase ~~, Description of Operations RUNCMP M/U ESP assembly. Keeo hole full, taking 5 bph. RUNCMP M/U ESP assembly. Fill ESP with oil and check as per Centralift Procedures. Unable to clamp flat cable below motor as clamp would pinch cable. Clamp cable above motor as per Centralift. Hole taking 5 bph. RUNCMP RIH with 4-1/2" 12.6# - bin .Torque tubing to mark, average make up torque 2,800 Wlbs. Use Best-O-Life 2000 pipe dope on all connections. Ran a total of 88 Joints of Tubing, 1 Flat Guard, 2 Protectolizers, 3 Bands and 48 Cannon Clamps. RUNCMP PU Tubing Hanger and Landing Joint with FMC rep. Orient per FMC rep. Install Penetrator with Centrilift rep. RUNCMP Perform Penetrator splice with Centrilift rep. RUNCMP Obtain final PUW = 47K and SOW = 42K. Land Tubing Han er and RILDS with FMC re LD Landin Joint. RUNCMP Dry rod TWC with FMC re .. Test from above to 3,500 si for 10 c arte mins - aood. Unable to test from below due to injection into reservoir. 13:00 - 17:30 4.50 BOPSU P RUNCMP Drain the BOP Stack and ND BOPE. Lay down in the Cradle. 17:30 - 20:30 3.00 WHSUR P RUNCMP NU Adapter Flange and 4-1/16" Tree with FMC rep. Perform final ESP checks.l.6 ohm phase to phase, 5 gigaohms phase to ground. Test hanger void to 5,000 psi for 30 minutes and test tree to 5,000 psi with diesel. Good tests 20:30 - 21:30 1.00 WHSUR P RUNCMP R/U lubricator and test to 500 psi. Pull 4" CIW Type H TWC and install 4" CIW Type H BPV. R/D lubricator. 21:30 - 22:00 0.50 WHSUR P RUNCMP N/D secondary annulus valve and secure tree and cellar. "Release rig at 22:00 hours". Printed: 6/30/2008 9:28:25 AM STATE OF ALASKA 11/14/07 OIL AND GAS CONSERVATION COMMISSION BOPS lest Report Submit ta: Contractor: Nabors Rig No.: 3S Rig Rep.: J.Greco/J.Fr~tts Rig Phone: 659-4487 Operator: BP Op. Phone: 659- 4485 Rep.: W.HoffmanB.Burson Field/Unit & Well No.: MP A-02A PTD ~ 85-185 Operation: Drlg: Workover: X Test: Initial: X Weekly: Test Pressure: Rams: 250/3500 Annular: 250/3500 TEST DATA MISC. INSPECTIONS: Test Result Test Result Location Gen.: P WeN Sign P Housekeeping: P Drl. Rig P PTD On Location P Hazard Sec. P Standing Order Posted P BOP STACK: Quantity Size Test Result Annular Preventer 1 13 5/8 5000 P Pipe Rams 1 2 7/8" x 5" P Lower Pipe Rams Blind Rams 1 Blind P Choke Ln. Valves 1 3 1/8" 5000 P HCR Valves 2 3 1/8" 5000 P Kill Line Valves 1 2 1/16" 5000 P Check Valve 0 NA MUD SYSTEM: Usual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P Test Results DATE: 6/5/2008 Rig Fax: 659- 4486 Op. Fax: 659-4628 Explor.: Bi-Weekly Valves: 250/3500 FLOOR SAFETY VALVES: Quantify Test Result Upper Kelly Lower KeNy BaN Type 1 P fr~side BOP 1 P CHOKE MANIFOLD: Quantity Test Result No. Valves 13 P Manual Chokes 1 P Hydraulic Chokes 1 P AGCUMUlATOR SYSTEM: Ttme/Pressure Test Result System Pressure 3000 P Pressure After Clos~ue 1700 P 200 psi Attained 29 sec P FuN Pressure Attained 2 min 5 sec P Bid Switch Covers: All stations P Nitgn. Bottles (avg}: 4@ 2000 Number of Failures: 0 Test Time: 4.0 Hours Components tested ALL Repair or replacement of equipment wiN be made within days. Notify the North Slope Inspector 659-3607, follow with written confmnation to Se~erviser at: Remarks: Tested all comaonerrts,tested new tiansaes that replaced unibott connection on rist move as well as new kill line hose. 24 HOUR NOTICE GIVEN YES X NO Date 06/04/08 Time 0500 hrs Test start 0200 txs Finish BOP Test (for rigs) BFL 11 /14/07 ~~ANI11E~ JUN ~ ~ 2008 By Chuck Sheve Witness J. Fritts/ B.Burson Nabors 3S BOP Test MP A-02A 6-5-08.x1s RE: MPU Water Supply Wells • • Subject: RE: MPU Water Supply Wells From: "MPU, Well Operations Supervisor" <welloperationssupervisor @BP.com> Date: Fri, 02 Mar 2007 13:49:38 -0900 To: Thomas Maunder <torn maunder@admin.state.ak.us> Tom, I from what I know, they have always been ESPs. If . you - would _. like, I can dig back through the well files. Please let me know. Thanks, John R. Cubbon WjONED AP 1 • 201 MPU Well Operations Supervisor 1- 907 - 670 -3330 Original Message From: Thomas Maunder [mailto•tam; maunder Sent: Friday, March 02, 2007 1:28 PM To: MPU, Well Operations Supervisor Subject: Re: MPU Water Supply Wells Thanks John. For the ESP wells, they have always been ESPs correct? Tom MPU, Well Operations Supervisor wrote, On 3/2/2007 1:17 PM: Hi Tom, t,k \ O � V ��� \S(4°-\(°Q1 The information for these wells is as follows: F -02 ESP Completion Active Water Supply Well tC1(o- (] A2A ESP Completion Active Water Supply Well S- 13- 01 ESP Completion Non - Active Water Supply Well (has not been utilized since at least 2004, and likely much longer) k %0 O� F -21 ESP Completion Active Water Supply Well F -58 ESP Completion Active Water Supply Well F -77 ESP Completion Active Water Supply Well \ S -22 Jet Pump Com letion in the UGNU. Has been SI since 2005 due to _ \L\ excessiv san production. S as a hot Ivishak water supply well in 2006. We are evaluating completion options and trying to overcome potential a Q S - \ � corrosion challenges due to the high CO2 content of the water. Tentative plan to put into service later in 2007. I hope this helps Tom. If you have any questions, or need any further details, please don't hesisitate to let me know. Thanks John R. Cubbon MPU Well Operations Supervisor 1- 907 - 670 -3330 1 of 2 3/2/2007 1:58 PM RE: MPU Water Supply Wells Original Message From: Thomas Maunder [mailt V tom m..�under' �admin.state.ak.�_s] Sent: Monday, February 26, 2007 3:13 PM To: Cubbon, John R Subject: MPU Water Supply Wells John, I see that MPF -02 was just worked over. In the course of checking a few things, I noticed in our production report that this well was reported to be a flowing completion and it appears to have been since completion in August 1996. I have checked our reports on your other wells and found the following: MPA -02A -- submersible, SI or no information to August 1995, then flowing or no information since. MPB- 01 - - -- submersible, SI or no information to January 1998, then flowing to September 2001 and SI since MPF- 21 - - -- flowing since completion June 1997 MPF- 58 - - -- flowing since completion November 1996 MPF- 77 - - -- flowing since completion April 1996 MPK- 34 - - -- flowing since completion December 1997 MPS- 22 - - -- hydraulic pump or flowing since completion in October 2003, SI mostly MPS- 90 - - - -no water production reported I think the production method for all the wells is ESP. Am I correct? I am not sure where the error might be coming from. When you confirm the production method, I will get with our stat techs here and see how we are receiving the information. Then I will get back to you and we can see what changes may be needed. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC 2 of 2 3/2/2007 1:58 PM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO' David John,~n, Chairman,("" THRU' Blair Wondzell, P. I. Supervisor FROM' Larry Wade,~~~p_ Petroleum Irfspect<Jr DATE: April 11,1998 FILE NO: .DOC SUBJECT: BOP Test Nabors 5s MPU A-02A PTD 85-185 April 11,1998: I traveled to Milne Pt to witness a BOP test on Nabors 5s. The first test encompassed the shock hose between the stack and choke manifold which had a leak. We were able to test the stack, kelly and floor valves. ! went back to the office while they changed out the shock hose. After replacing it I went back and we tested the choke manifold valves and accumulator. SUMMARY: I witnessed a BOP test on Nabors 5s. 1 failure 16 hours Attachments: ak9gdkfe.xls cc; NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Workover: X DATE' 11-Apr-98 Drlg Contractor: Nabors Rig No. 5s PTD # 85-185 Rig Ph.# 659-4456 Operator: BPX Rep.: Lee Hinkle Well Name: MPUA-O2A Rig Rep.: Mike Downey Casing Size: 7" Set @ 3,686 Location: Sec. 23 T. 13N R. IOE Meridian Umiat Test: Initial X Weekly Other Test MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok (Gen) PTD On Location X Standing Order Posted X Well Sign X Drl. Rig X Hazard Sec. X FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. Pressure P/F 1 250/5,000 P 250/5,000 P 250/5,000 P 25O/5,000 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. I 250/250O 250/5,000 1 250/5,000 f 250/5,000 I 250/5,000 I 250/5,000 f 250/5,000 250/5,000 P/F P P P P P P MUD SYSTEM: Visual Alarm Trip Tank X X Pit Level Indicators X X Flow Indicator X X Meth Gas Detector X X H2S Gas Detector X X CHOKE MANIFOLD: No. Valves 12 No. Flanges Manual Chokes 1 Hydraulic Chokes 1 Test Pressure P/F 250/5,000 P 32 250/5,000 P Functioned P Functioned P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 4@2250 3000 1700 minutes lg sec. minutes 5 sec. X Remote: X Psig. Number of Failures: 1 ,Test Time: 5.0 Hours. Number of valves tested 18 Repair or Replacement of Failec Equipment will be made within days. Notify the Inspector and follow with Wdtten or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector ~;TATE WITNESS REQUIRED? YES NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Larry Wade F1-021L (Rev.12/94) akggdkfe.xls STATE OF ALASKA ALASKA'OIL AND GAS CONSERVATION CO~MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown []Stimulate []Plugging []Perforate [~Pull Tubing [-] Alter Casing C~ Repair Well [~Other ESP changeout & upgrade wellhead 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2031' SNL, 1584' WEL, Sec. 23, T13N, R10E, UM At top of productive interval 855' SNL, 1051' WEL, Sec. 23, T13N, R10E, UM At effective depth 579' SNL, 962' WEL, Sec. 23, T13N, R10E, UM At total depth 579' SNL, 962' WEL, Sec. 23, T13N, R10E, UM 5. Type of well: [] Development [-] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KBE) KBE = 56' 7. Unit or Property Name Milne Point Unit 8. Well Number MPA-02a 9. Permit Number / AppmvalNo. 85-185 10. APl Number 50-029-20873-01 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 3686' feet true vertical 3084' feet Effective depth: measured 3686' feet true vertical 3084' feet Casing Length Structural Co nd ucto r Surface Intermediate Production Liner Plugs (measured) Junk (measured) Size Cemented 80' 20" To surface 2860' 13 3/8" 1600 sxs Arc° Fondu 1100 sxs Permafrost 'C' 3650' 9 5/8" 38 Bbls Class 'G' MD 'TVD 116' 116' 2897' 2583' 3686' 3122' Perforation depth: measured true vertical 3282'-3294',3308'-3362',3396'-3460',3464'-3521' 2856'-2864',2875'-2912',2934'-2977',2980'-3018' Tubing (size, grade, and measured depth) Packers and SSV (type and measured depth) 4 1/2" 12.6# L-80 to 2757' Anch0rage 9 5/8" Baker SC-!A pkr @ 3124' & Baker Model 'G' Sump pkr @ 3547' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service Water Source Well 17. I hereby certify that the foregoing is true and correct to. the best of my knowledge Signed .... J, eanne L, Haas ~'~/~/L,,CcZ -._.~/i /~//'~-¢----1:itle Staff Technical Assistant Date ~_'~-/'~/,~(/~¢z- Prepared By Name/Number: Jeanne L. Haas, 564-5225 Form 10-404 Rev. 06/15/88 Submit In Duplicate,~ Progress Report Facility M Pt A Pad Well MPA-02A Page 1 Rig Nabors 5S Date 13 April 98 Date/Time 10Apr 98 06:00-18:00 18:00-21:30 21:30-00:30 11 Apr 98 00:30-03:30 03:30-04:00 04:00-05:00 05:00-06:00 06:00-08:00 08:00-10:30 10:30-15:30 15:30-18:00 18:00-19:30 19:30-21:30 21:30-23:00 23:00-05:00 12 Apr 98 05:00-06:00 06:00-09:00 09:00-10:00 10:00-13:00 13:00-17:30 17:30-18:00 18:00-20:30 20:30-21:30 21:30-22:30 22:30-23:30 23:30-01:00 13 Apr 98 01:00-02:00 02:00-06:00 Duration 12hr 3-1/2 hr 3 hr 3 hr 1/2 hr 1 hr 1 hr 2 hr 2-1/2 hr 5 hr 2-1/2 hr 1-1/2 hr 2 hr 1-1/2 hr 6 hr 1 hr 3hr 1 hr 3 hr 4-1/2 hr 1/2 hr 2-1/2 hr 1 hr 1 hr 1 hr 1-1/2 hr 1 hr 4 hr Activity Rig moved 100.00 % Rig moved 100.00 % Removed Hanger plug Circulated at 2793.0 fl Rigged up Hanger plug Removed Xmas tree Rigged up All rams Rigged up All rams Tested All rams Repaired High pressure lines Circulated at 2793.0 fl Repaired High pressure lines Tested All rams Rigged down Tubing hanger Pulled Tubing in stands to 2793.0 ft Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Tool run Ran Tubing to 0.0 ft (4-1/2in OD) Ran Tubing to 0.0 ft (4-1/2in OD) Ran Tubing to 2802.0 ft (4-1/2in OD) Rigged up Tubing hanger Serviced Other sub-surface equipment Installed Tubing hanger Removed BOP stack Installed Xmas tree Freeze protect well - 170.000 bbl of Diesel Installed Hanger plug Rig moved 0.00 % STATE OF ALASKA ALASK~OIL AND GAS CONSERVATION C-OMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown []Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other ESP changeout & upgrade wellhead 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2031' SNL, 1584' WEL, Sec. 23, T13N, R10E, UM At top of productive interval 855' SNL, 1051' WEL, Sec. 23, T13N, R10E, UM At effective depth 579' SNL, 962' WEL, Sec. 23, T13N, R10E, UM At total depth 579' SNL, 962' WEL, Sec. 23, T13N, R10E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KBE) KBE = 56' 7. Unit or Property Name Milne Point Unit 8. Well Number MPA-02a 9. Permit Number / Approval No. 85-185 10. APl Number 50- 029-20873-01 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 3686' feet true vertical 3084' feet Effective depth: measured 3686' feet true vertical 3084' feet Casing Length Structural Conductor Surface Intermediate Production Liner Plugs (measured) Junk (measured) ORIGINAL Size Cemented MD TVD 80' 20" To surface 116' 116' 2860' 13 3/8" 1600 sxs Arco Fondu 1100 sxs 2897' 2583' Permafrost 'C' 3650' 9 5/8" 38 Bbls Class 'G' 3686' 3122' Perforation depth: measured true vertical 3282'-3294',3308'-3362',3396'-3460',3464'-3521' 2856'-2864',2875'-2912',2934'-2977',2980'-3018' Tubing (size, grade, and measured depth) Packers and SSV (type and measured depth) 4 1/2" 12.6# L-80 to 2795' AJaska Oil ~ L~S ¢ ' -, u0ns. Coml]]issior) 9 5/8" Baker SO-lA pkr @ 3124' & Baker Model 'G~~ ~ 3547' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service Water Source Well 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /~, ~' ~ Title ~r,'(I.;',.,~ ~,,~,. ~~r Date ~[IZ. {.tt~ / - 'JPre~)ared"By Name/Number: ~~ [¥0~/?~f_¢ ~¢~D:~6F~ ~, Form 10-404 Rev. 06/15/88 v/ S~bmit In Duplicate, ~,~,) SUMMARY OF DAILY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPUA-02a Rig Name: N-4ES AFE# 339028 Accept Date: 11/18/96 Spud Date: . Release Date: 11/23/96 NOVEMBER 19, 1996 ACCEPT RIG @ 2400 HRS ON 11/18/96. RIG UP HARDLINES TO TREE & TIGER TANK. RIG UP LUBRICATOR, PULL BPV - SITP 30 PSI SICP 100 PSI. ATTEMPT TO KILL WELL W/8.4 PPG SOURCE WATER, CIRCULATE TUBING VOLUME BULLHEAD INTO PERF @ 4 ½" BPM 210 PSI CIRCULATE OUT BACKSIDE TO TIGER TANK, DIESEL & 8.7 PPG VISCOSIFIED BRINE IN RETURNS SHUT DOWN MONITOR WELL SITP 20 PSI SICP 20 PSI CIRCULATE INCREASE BRINE WT 8.4 TO 8.5 PPG CIRCULATE AROUND W/70% RETURNS. NOVEMBER 20, 1996 CONTINUE CIRCULATE INCREASE BRINE WT. 8.4 TO 8.5 PPG REVERSE CIRC THROUGH HEATER STRING MONITOR WELL, WELL DEAD, BLOW DOWN LINES. SET 4" TWC IN 4 Y2" TUBING, ND MASTER VALVE & ADAPTER DIFFICULT TO REMOVE ADAPTER FLANGE FROM TUBING SPOOL - HAD TO USE PORT, A POWER JACK INSTALL TWC IN HEATER STRING SIDE. NU 11" 3000 X 13 5/8" 5000# DSA NU BOP STACK INSTALL 4 W' RAMS TEST BOP TEST ALL RAMS, LINES & VALVES TO 250 & 3000 PSI. WITNESS OF TEST WAIVED BY CHUCK SCHEVE OF AOGCC. RIG UP FLOOR SM WITH CREW ON PULLING TWC W/O LUBRICATOR - PULL TWC W/ROD POOH LD 65 JTS 2 3/8 4.7# CS HYDRILL TUBING TUBING IN GOOD CONDITION PULL TWC FROM 4 ½" TUBING MAKE 4 Y2" TUBING LANDING JT BACK OUT LOCK DOWN SCREWS ATTEMPT TO PULL TUBING HANGER TO RIG FLOOR WORK TUBING TO 175K - 125K OVER STRING WT CANNOT PULL BROWN OIL TOOL PACKER @ 2774' FREE PACKER MOVE UP HOLE APPROX. 1 FT. WELL FLOWING SHUT WELL IN CIRC OUT GAS FROM UNDER PACKER ON CHOKE ATTEMPT TO PULL PACKER FREE WORK TUBING TO 175K 80% OF APl NON UPSET TUBING YIELD 125K OVER STRING WT NO SUCCESS. NOVEMBER 21, 1996 CIRCULATE SLOW, WORK STUCK PACKER TO 150K - NO MOVEMENT. CHANGE OUT ELEVATOR TO 200 TON WORK TUBING STRING TO 250K-200K OVER STRING WT. NO MOVEMENT WORK TUBING TO 85% OF YIELD OF 4 ½" L-80 IMP BUTT TUBING RIG UP SLICKLINE UNIT RIH & SET PLUG IN DB NIPPLE @ 2827' WLM TWO RUNS TO SET PLUG RIG DOWN SLICKLINE UNIT ATTEMPT TO TEST PLUG & PKR TO 200 PSI -INJECT INTO FORMATION 2 BPM 80 PSI. CIRCULATE & BALANCE BRINE WT @ 8.5 PPG MONITOR WELL FLUID LOSS 6 BPH STATIC. ND BOP PICK UP ON TUBING HANGER ABOUT 2.5' 140K ON VVT INDICATOR, INSTALL 4 'Y~" BOWL & SLIPS WITH COLLAR CLAMP REMOVE TUBING HANGER, MU LANDING JT & REMOVE BOWL, SLIP & CLAMP SLACK OFF & SET WT. OF STRING ON PKR BACKOFF OF LANDING JT NU BOP STACK SCREW INTO Page 1 of 2 SUMMARY OF DALLY OPERATIONS TUBING STRING WITH LANDING JT. WORK TUBING PKR WAS FREE ONLY NEEDED TO SLACK OFF & SET WT OF STRING ON PACKER BACKOFF OF LANDING JT. WORK TUBING PKR WAS FREE ONLY NEEDED TO SLACK OF TO 0 WT & PU TO MOVE PKR UP HOLE PU WT 47K, S/O WT 37K CIRCULATE & WORK TUBING. RIG UP SLICKLINE UNIT-RIH & PULL PLUG FROM DB NIPPLE @ 2827' WLM TWO RUNS TO PULL PRONG & PLUG. RIG DOWN SLICKLINE UNIT POOH PKR & ESP LD TUBING 15 JTS OUT OF HOLE @ 0600 HRS. NOVEMBER 22, 1996 SERVICE RIG FINISH POOH W/4 Y2" TUBING LD 75 JTS 4 ~ 12.6# L-80 R-2 IMP BUTT TUBING & 20 JTS 4 ~ 12.75# L-80 EUE 8RD TUBING. LD PKR, GLM & ESP PUMP & MOTOR LOCKED UP CLEAR FLOOR TIH W/66 JTS 4 ½" BUTT TUBING FOR WT BELOW PKR PU 9 5/8" R'I-I-S & STORM VALVE RIH SET TOP OF STORM VALVE @ 26' TEST RTTS TO 500 PSI OK. DN BOP STACK. ND 13 5/8 5000# Xl1" 3000# TUBING SPOOL NU 13 5/8" 5000 X 11" 3000# TUBING SPOOL. NU 13 5/8" 5000 X 11" 5000# TUBING SPOOL TEST PACK OFF TO 1600 PSI OK NU BOP STACK. INSTALL TEST PLUG TEST BOP STACK TEST ALL RAMS, LINES & VALVES TO 250 & 5000 PSI TEST HYDRILL TO 250 & 3000 PSI. PULL TEST PLUG. RETRIEVE RTTS & STORM VALVE POOH LD TUBING. RIG UP HES SLICKLINE UNIT - RIH W/8.5" GR/JB SET DOWN @ 2797'. POOH RECOVERED 2 BAND & RUBBER OFF OF TUBING HANGER. RIH W/6.0" GR'JB TO 3000' TO CHECK FOR FILL -DID NOT SET DOWN. RIH W/8.5" GR/JB TO 2808' BEAT DOWN TO 2810' POOH NO JUNK. RIH W/8.5' GR/JB TO 2810' POOH NO JUNK WAIT ON 8.3" GR FROM DEADHORSE. NOVEMBER 23, 1996 CONTINUE RUN 8.5" GR/JB SET DOWN SOLID @ 2810' POOH NO JUNK IN BASKET. RIH W/8.3" GR/JB SET DOWN @ 2810' STICKY PICKING UP POOH NO JUNK. RIH W/6.70" GR/JB SET DOWN @ 3117' (TOP OF GRAVEL PACK SCREEN) POOH RECOVERED TWO BANDS - RIG DOWN SLICK LINE, SUSPECT BAD SPOT IN CASING @ 2810' MU & SERVICE ESP 6.75" HC 12000 PUMP. RIH W/ESP ON 88 JTS 4 Y2" 12.6# L-80 IRT TUBING MU 10 X 4 Y2" TUBING HANGER MAKE SPLICE ON ESP CABLE @ TUBING HANGER. LANDING TUBING STRING W/BOTTOM OF ESP @ 2795' SET TWC TEST 500 PSI ND BOP STACK. NU FMC 11" 5000 X 4 1/16 5000 PSI ADAPTER SPOOL, NU CIW 4 1/16 5000# TREE CHANGE OUT MANUAL WING VALVE TO HDY GATE VALVE, HYD GATE VALVE WILL NOT CLOSE ALL THE WAY - CHNAGE BACK TO MANUAL VALVE. TEST TREE & PACK OFF TO 5000 PSI PK PULL TWC VALVE,INSTALL 4" BPV, FREEZE PROTECT WELL W/DIESEL BULLHEAD 115 BBLS DIESEL DOWN ANNULUS @ 3,4 BPM 190 PSI. BULLHEAD 30 BBLS DOWN TUBING @ ½ BPM. NOVEMBER 24, 1996 FINISH FREEZE PROTECTING TUBING W/30 BBLS OF DIESEL BUL ~L.~I~D~D~..~. BPM SITP 100 PSI. SICP 100 PSI. SECURE WELL, RIG DOWN LINE~(~~~i~} RIG RELEASED @ 0800 HRS ON 11/23/96. Page 2 of 2 Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Point A No. 2A - CONFIDENTIAL (3,434'-Kuparuk River) AFE 10-61-1131 API No. 50-029-20873-01. Ak. Permit No. 85-185. Elevation: 56' KB. Location: 2031' FNL, 1585' FEL, Sec. 23, T13N, R10E, U.M. 8-15-85: Raise derrick & spot sub base over well. Spot pits,motor complex & pipe sheds. Mix 500 bbl mud. Remove blind flange & begin ND BOPs. 8-16: NU stack & choke & kill lines. RD to test BOPs, install test plug. Cha~nge 3 1/2" rams to 5". Test upper & lower pipe rams, shear rams, choke & kill manual valves, HCR valves, choke manifold, upper & lower Kelly lock & floor valve to 3000 psi. Test Hydril to 2500 psi. Test witnessed & approved by Bobby Foster. Retrieve test plug,.run wear bushing, strap & PU BHA. Replace electronics & battery packages in MWD. Test MWD. Strap HWDP & PU HWDP. Strap & PU 5" DP, tag plug @ 2764'. Displace diesel & 10.4 ppg mud w/9.4 ppg mud. Test csg to 1500 psi & drlg cmt. Tag EZSV @ 2862'. 8-17: Drlg on EZ-SV. Drlg from 2897' to 3722'. Make 8 std. short trip 3722' to 2997'. Circ & POOH. LD MWD, strap DP. Run GO's DIL, SFL, CNL, LDT, GR from 3725' to 2897'. RIH to 3725'. Circ & cond mud. POOH, LD DP. RU to run csg. Begin running 94 its of 9 5/8", 36 #/ft, K-55 csg w/buttr threads. 8-18: Finish running 9 5/8" csg. ECP @ 3006'. Float collar @ 3602'. Float shoe @ 3683'. Circ I csg volume & pump 40 bbl Desco sweep @ 11 ppg. Pump 58 bbl of 15.8 ppg Class G cmt w/1% CFR-2 & 3% NaCI. Displace w/279 bbl 9.3 ppg KCL brine. Bump plug & press, up to 1800 psi to inflate ECP. Bleed off, floats held, full returns. CIP @ 1220. Circ mud from pits & from 13 3/8" wellbore into well. Pump 53 bbl 15.3 ppg Permafrost cmt. Pump 116 bbl Arctic Pack. CIP @ 2030. WOC. ND stack, insert slips - set 150,000 lbs onto slips, cut csg. 8-19: ND stack & set slips on 9 5/8" csg. Cut csg & dress chamber. ND tree & tbg spool. RIG RELEASED. Conoco Inc, 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-76O0 October 23, 1987 Ms. Fran Jones Alaska Oil and Gas Conservation Commission 3001 Porcupine drive Anchorage, Alaska 99501 Dear Ms. Jones: Enclosed please find the drilling "well histories" from Conoco's Milne Point Unit Wells No. B-17 and A-2A. If you require additional information concerning these well histories, please contact Mike Zotzky at 564-7623. Yours very truly, YV B-17, A-2A OC'[ 2 6 Alaska 0il & Gas Cons. Commissiou Anchorage Torn Painter Division Manager Conoco inc. 3201 C Street Suite 200 Anchorage, AK 99503 December 23, 1986 Mr. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99503 Dear Mr. Chatterton: Temporary Shut-in of Production and injection Wells Within the Milne Point Unit As you are aware, Conoco et al. has filed an application with the Department of Natural Resources to temporarily discontinue production operations at Miine Point. The attached sundry notices are intended to serve as notice of the pending temporary shut-in of all wells located within ~he Milne Point Unit. 'There are 19 active and 5 inactive production wells at Miine Point. All active or~:'c'ion~_ . wells will be freeze pr.~.tec~ed~ ~ by, disc!acing, the too 3000' of .~he tubin~ ~-',h a 1:3 diesel:oil mixture. The annular fluid levels will be moninored for leaking gas lift valves, if necessary the production casing annulus will be displaced with a diesel:oil mixture to at least 3000'. Once the shut-down operation is como!eted, pre~sure survey= wil~ be run -'- ~i~ production wells After the surveys are run BPVs will be installed and all SCSSVs and _:,_neat. valves wi~ ~ be closed The inactive production wells have been adequately freeze protected with diesel across the permafrost. There are current~ =y ten active and six inacuive water injection wells in the Mi!ne Poin~ Unit. ACTIVE: B-8, B-12, B-14, B-17, B-18 C-8, C-ii, C-12, C-15 C¥P-2 STATIC: B-5A, B-7, B-19 C-6, C-10, C-19 Active water injection wells will be freeze protected by displacing the tubing to at least 2000' with a 50:50 water:methanol mix. The SCSSV and wellhead valves will remain open for two to three weeks after the well is shut-in to monitor wellhead pressure. When adequate wellhead data has been obtained the BPVs will be set and the SCSSVs and all wellhead valves will be closed. The static injection wells are currently freeze protected and no additional work will be required. Injection water is supplied by three water source wells. Thoug.h_ only one well is active at any given time, all wells are capable of produc- ing. A-2A; B-i; CFP-1 Water source wells will be freeze protected by displacing the tubing to at least 2000' with a 2:1 propylene glycol:water mixture. After the wells have been displaced with the glycol:water the BPVs will be set and all wellhead valves will be closed. The E-2 gas storage well has been shut-in since July 1986 due to a tubing leak. The wellbore is filled with natural gas so that freezing is not a concern, but to prevent potential corrosion an inhibitor will be displaced into the well. A 50:50 methanol:water mix will be used to carry the inhibitor. If you have any questions on the shutdo~ procedure please contact Don Girdler at 564-7637. Yours very truly, ~-~v ~ ~T../~.'. ?ainter ~~!s ion >tanager STATE OF ALASKA ALASK .... OIL AND GAS CONSERVATION COMM~81ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown Re-enter suspended well FI Alter casing ~ Time extension [] Change approved program ?1 Plugging [] Stimulate ~ Pull tubing ~ Amend order [] Perforate ~ Other 2. Name of Operator Conoco Inc. 3. Address 3201 C Street, Std. 200, Anchorage, Alaska 99503 4. Location of well at surface 2031' FNL, 1585' FEL, Sec. At top of productive interval 3171' FNL, 2186' FEL, Sec. At effective depth At total depth 3434' FNL, 2366' FEL, Sec. 23, T13N, R10E, U.M. 23, T13N, R10E, U.M. 23, T13N, R10E, U.M. 5. Datum elevation (DF or KB) 56' KB feet 6. Unit or Property na_m_e Milne Point Unit 7. Well number A-2A 8. Permit number 85-185 9. APl number 50-- 029-20873-01 10. Pool Kuparuk River 11. Present well condition summary Total depth: measured 3725 true vertical 3164 feet feet Plugs (measured) Effective depth: measured true vertical feet feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 20" 2860' 13 3/8" 3650 ' 9 5/8" measured Cemented Measured depth True Vertical depth To Surface 116' 1600 Sxs Arco Fondu 2897' 1100 Sxs Permafrost "C" 38 bbls. Class "G" 3686' 3282'-3294'; 3308'-3362'; 3396'-3460'; 3464'-3521' 116' 2583' 3122' true vertical 2856'-2865'; 2874'-2912'; 2935'-2980'; 2983'-3022' Tubing (size, grade and measured depth) 4~", 12.75 PPF, L-80, BTRS Packers and SSSV (type and measured depth) Submersible Pump Packer @ 2774' 12.Attachments Description summary of proposal ~ Detailed operations program [~'% ~(~P ~k~t~ ~ 13. Estimated date for commencing operation January 1987 14. If proposal was verbally approved Name of approver Ar~ch0rage. Date approved 15. I hereb, y__c.e. Etify that t~e foregoing is true and correct to the best of my knowledge Signed %~A~._.~" tA_~.-~ Title ~-'~.-o~'-¢. ~h' Commission Use Only Date Conditions of approval [] Plug integrity [] BQP.Test ,/'-i..' !.:i ~ "-~ ~-':". ~' ~.. ~ ,~,¢.;",-'_~.~ ~ · -' ~.~ · f Approved by Notify commission so representative may witness [] Location clearance I Approva, No. by order of the commission Date i ',' I-* ' ~' '-'~ Submi~ in tr~plicate Form 10-403 Rev 12-1-85 Commissioner , STATE OF ALASKA ,: ALASKA C_..?AND GAS CONSERVATION CO,~,_~_.IISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE E~ Water Source Well 2. Name of Operator 7. Permit Number Conoco Inc 85-185 3. Address 8. APl Number 3201 "C" Street, Ste. 200, Anchorage, AK 99503 50- 029-20873-01 4. Location of well at surface 9. Unit or Lease Name 2031' FNL, 1585' FEL, Sec. 23, T13N, R10E, U.M. Milne Point Unit At Top Producing Interval 10. Well Number 3171' FNL, 2186' FEL, Sec. 23, T13N, R10E, U.M. A-2A At Total Depth 11. Field and Pool 3434' FNL, 2366' FEL, Sec. 23, T13N, R10E, U.M. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 56'I ADL 47437 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore 116. ND. of Completions 8-15-85 8-16-85 9-20-85J N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 3725'MD(3164'TVD) 3578'-XfD(3062'TVD) YES ~ NO [] I~/A feetMDI +1800' 22. Type Electric or Other Logs Run D IL- SFL- CNL-LDT-GR- SP 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13 3/8' 72# L-80 0 2897' 17~" 2 1600 sks Arco Fondu and 1100 ~ks Perm. frost "C" cmt. 9 5/8" 36# K-55 0 3686' 12¼" 38bbls Class G, 53 h bls Permafrost 116 bbls Arctic Pac 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) Tertiary water sands: SIZE DEPTH SET (MD) PACKER SET (MD) 3282'-3294' (2856'-2865' TVD) 4~" 12.75# 2909' 2774' 3308'-3362' (2874'-2912' TVD) 2 3/8" CS Hy([ril 2052' 3396'-3460' (2935'-2980' TV]:)) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 3464'-3521' (2983'-3022' TV]:)) DEPTH INTERVAL (MD) AMOUNT& KINDOF MATERIAL USED 12 SPF, 120° phasing, 5" guns 27. PRODUCTION TEST Date First Production J Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr) Press. 24-HOUR RATE ~ .... 28. CDR E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Submit in duplicate Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ' ,::' G'EoL:C)(~I'C' NI~ARI~EI~S' '~':'/~/~"! ~""~:-:"' ~'.!'-~ ":~ ~ FeRM~'FtON T'EST~; ' '- --- .';i: i:~::,'' ' NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. "A" 3014 ' 2667 ' "B" 2274' 2851' "C" 3396' 2935' "D" 3569' 3056' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ.combustion. Item 5' Indicate which elevation is used as reference (where not otherWise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24-show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Atta(~hed supl~lemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. '",, ~?~.; .. Item 27:.'. Me,th. od 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 survey SU~R¥ SHEE? ~/~ DATe Tlrm SUR~ DRILL SUREX DR1FT AZI .CORR . TOpL FACE CO~U~NTS _M/D/Y $ DEPTH ,DEPTH ..... DIR. H.S. ~G. TRU5 ,. .... . , , ., --. . , .. - _. . , ....... ~ ~ - .. ._ ....... .... . .... ........ ,, ~ , · - i ,_ , . . ~ .... . _ _ · _ , .... .... , ..... . L .. -- ~ .... * ' . ., , . ...... .... , . ,, .... ,, &laska Oil & Gas Cons, ,,,¢_ ~. .., · Porto t029 A?.,::~er~:~ , Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. OPERATOR, WELL NAME AND'NUMBER Reports and Materials to be reCeived by: ~ ~'~-~ ~ ~.~ ~ Date Required t Date Received Remarks Completion Report ? ~ ~ Core Chips ....... Core Description ~ ~:'; i~' Registered Survey Plat h/~( ~%~ ~'" ~ ~ '- ~'{:' -'"?/: Inclination Survey ~/? .... ;;:~,j;~:~ Directional Survey . ,.~?~.~:~¥ :::: -.:"~. ~:.,' :,.,;: :::. ' '~ Drill Stem Test Reports .':: ~ Production Test Reports ~Tr"t"~';~...~[?~ ....... :.~j , Digitized Data ~'tc~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL[] COMPLETED WELL;E~X OTHER [] 2. Name of Operator Conoco Inc. 3. Address 3201C Street, Suite 200, Anchorage, Alaska 4. Location of Well 2000'FNL, 1585' FEL, Sec. 23, T13N, RiOE, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 56' KB 6. Lease Designation and Serial No. 47434 7. Permit No. ~-.~ ..~ ' I ~, ~ 8. APl Number 50- 0~9_20873_01 9. Unit or ~ease ~ame ' Milne Poi~ Unit 10. ~ell NumbeF A-2A 11. Field and Pool Kuparuk River 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). This well was brought on as a water producing well on 12-31-85, and its status should be changed from suspended to service and classified as a water source well. 14. I hereby certify that the foregoing is true and correc~ to the best of my knowledge. The space be ommission use Conditions of ~OOroval, if ang: Date By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate GEARHART INDUSTRIES, INC. CUSTOMER c~oco, INC. FIELD ~q~mARt~< Well Name N~IzN-g PO]]~ ~IT A-~ County NO~ S~PE State Type of Logs Distributed ~L/~S ~ D~A, DIL, ~L/~S Date Date Job Ran 8-16-85 9--.30-85 Blue Line i Sepia Pre-Fold j Rolled Logs mai led to: COMPANY PERSON ADDRESS CRRR~ PRINTS HAILED FROM DISTRIBUTED BY C~E ARHART INDUSTRIES TESSIE HORN-BECK 2"/100' TYPE . ~ DIL -. CDL/CNS !P~q DATA ~'"- CDL/ClqS ~OP DEPTH 2875 2875 2875 BOTTOM DEPTH 3721 3721 3721 5"/100' TYPE ~' CDL/ClqS RA~ff DATA '"' CDL/ClqS 2875 372] 2875 3721 2875 3721 Please date and sign and return in the enclosed self-addressed add return to o.o o. // NO. OF LIS TAPES 1 SIGNED ~ - 0(.] ? ~' ]~ ~ ,..~ ~_ ~ ,~ ~ DATED ~msk~ Oi~ ~ r~ r~,.. Commission 139 East 51st St., Suite 102 RO. Box 102436 Anchorage, AK 99510 Telephone (907) 562-2538 Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 September 12, 1985 State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen: Monthly Report of Drilling and Workover Operations Attached for your information and file are the original and one copy of each of the required Monthly Reports of Drilling and Workover Operations conducted during August 1985. If you should have any questions, please call Lynn Alexander at 564-7609. Very truly yours, Everett D. Wilson Administrative Manager LA/vv Att. STATE OF ALASKA ALASKAr . AND GAS CONSERVATION CC /IISSION MONTHLY REPORT DRILL. lNG AND WORKOVER OPERATIONS il. Drilling well 'S Workoveroperation ~J 2. Name of operator 7. Permit No. Conoco inc. 85-185 3. Address 8. APl Number 3201 C Street, Suite 200, Anchorage, Alaska 99503 50_029-20873-01 9. Unit or Lease Name Milne Point Unit 4. Location of Well at surface 2031 ' FNL, 1585' FEL, Sec. 23, T13N, R10E, U.M. 6. Lease Designation and Serial No. ADL 47437 5. Elevation in feet (indicate KB, DF, etc.) 59' KB 10. Well No. A No. 2A 11. Field and Pool Kuparuk River Field Kuparuk River For the Month of August ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Tagged cmt. plug @ 2764'. Drilled cmt. to 2862'. Drill 2897' to 3725' to log.- 13. Casing or liner run and quantities of cement, results of pressure tests Run 94 jts. of 9 5/8", 36#, K-55, Btrc csg. Pump 38 bbl. of 15.8 ppg. Class G w/l% CFR 2 & 3% NaC1. Pump 53 bbls of 15.3 ppg. Permafrost cmt., 116 bbls Arctic Pack down 3 3/8" X 9 5/8" annulus. 14. Coring resume and brief description NONE 15. Logs run and depth where run DIL-SFL-CNL-LDT-GR f/3725' to 2897' 16. DST data, perforating data, shows of H2S, miscellaneous data NONE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED TITLE DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Ala$1~a Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10404 Submit in duplicate Rev. 7-1-80 MEMORANDUM State' of Alaska ~fLASFJt:DIL A~D GAS CO~SERVATION CO~R~%ISSIOM C.V. ~tt rton Cha z,.'~an THRU: Lonnie C. Smith Commissioner FROM: Bobby D. Fosterf'~ Petroleum Inspector DATE: August 19, 1985 FILE NO: D. BDF. 67 TELEPHONE NO: SUBJECT: Conoco Milne Point Kuparuk River U~it A-2A BOPE Test Permit #_85-1 85 · ? Thursday, August 15, 1985: The BOPE test began at 2:00 PM and was concluded at 4:00 PM. As the attached BOPE test reports shows, there were no failures. In summary, I witnessed the BOPE test on Conoco's A-2A. Attachment 02-O01AfRev. 10/Z9) O&G //4 5184 STATE OF ALASKA ALASKA 0IL & GAS CONSERVATION COMMISSION B,O.P,E, Inspection .Report Inspector / ~~,f Operator Location: Casing Set @ ~~,~%> ft. Drilling Contractor /~J~~"~ . Location, General ~ Well Sign~~ General Hcusekeeping~fP~' Rig ~ Reserve Mud Svstems Visual Trip Tank Pit Gauge Flow Monitor ~" Gas Detectors Audio BOPE Stack Test Pressure Annular Preventer 7 . =~~~ Blind Rams r/ !! ~~5~P Choke Line Valves H,C,R, Valve Kill Line Valves Check Valve Ri~ #~:~ ?~Reoresentative ACCUMULATOR sYSTEM Full Charge Pressure ~/~ ~,O psig. Pressure After' Closure' /~'~ psig, Pump incr. clos. pres. 200 psig ~- min~ lsec. Full Charge Pressure Attained: ~ min ~sec. No ~ ~ ~~ ~ psig Controls: Master ~~ Remote~'~_~ Blinds switch cover'~~ Kell? and Floor Safety Valves Upper Kelly / Test Pressure ~OD ~ Lower Kelly. / Test Pressure ~7~c~ Ball Type / Test Pressure ~-o~ Inside BOP / Test Pressure ~~ Choke Manifold ~~ Test Pressure ~ ~ No. Valves ! ~' Adjustable Chokes ~ Test Results: Failures ~ Repair or Replacement of failed equipment to be made within Hvdrauically operated choke Test Time~ hrs. days and Inspector/ Com~nission office notified. Remarks: Distribution orig. - AO&GCC cc - Opera~or . cc - Supervisor I nsp e c't~ ~. ~~~~ August 5, 1985 Mr. James R. Hand Engineer Conoco Inc. 2525 C Street, Suite 100 Anchorage, Alaska 99503 Re: ~{ilne Point Unit No. A-2A Conoco Inc. Permit No. 85-185 Sur. Loc. 2031'FNL, 1585'FEL, Sec. 23, T13N, R!0E, L%~. Btmhole Loc. 3362'FNL, 23!7'FEL, Sec. 23, T13N, R10E, U~. Dear Mr. Hand: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, .Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conse?vation. Mr. Jam_e s Hand Milne Point Unit A-2A -2- August 5, 1985 To aid us in scheduling ~ield work, please no~i~v this office 2A hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the ComMission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, ~ -, , ~ '~'~. __ , Chairman o f Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COI'~ISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental. Conse~-ation w/o encl. Mr. Doug L. Lowery John FI, Kemp Manager of Alaskan Operations Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-76O0 August 2, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed are the original and two copies of the Permit to Drill application for Milne Point A-2A. A $100 check is being submitted with the permit application to fulfill the permitting fee requirement. If you have any questions, please call Jim Hand at 564-7640. Very truly yours, John R.~emp ~'./ Manager of Alaskan Operations JRH/vv cc: MP A-2A Correpondence File STATE OF ALASKA ALASKA fOrL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL la. Type of work. DRILL [] 20 AAC 25.005 EXPLORATORY [] SERVICE [] STRATI~. RAPHIC I-] '~_~'~ SINGLE ZONE [] ': "~ ~ MULTIPLE ZONE [] :, ~ REDR, ILL [~ lb. Type of well DEVELOPMENT OILxI~] DEEPEN [] DEVELOPMENT GAS [] 2. Name of operator Conoco Inc. 3. Address 3201 "C" Street, Suite 200, Anchorage, AK. 99503 4. Location of well at surface 2031' FNL, 1585' FEL, Sec 23, T13N, RIOE, U.M. At top of proposed producing interval 3125' FNL, 2160'FEL, Sec 23, T13N,R10E, U.M. At total depth 3362' FNL, 2317' FEL, Sec 23, TL3N, R10E, U.M. 5. Elevation in feet (indicate KB, DF etc.) II 6. Lease designation and serial no. ~ 59' to Ms~, A~L ~ ~7 ~37 ',I'7~1¢'. ~, . _ D 12. Bond information (see 20 AAC 25.025) Type Blanket Surety and/or number 8086-15-54 9. Unit or lease name Milne Point Unit 10. Well number A No. 2A 11. Field and pool Kuparuk River Amount $200 ~ 000.00 15. Distance to nearest drilling or completed well A-3 120 feet 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 33 mi SE of Deadhorse miles 1800' at target feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease *3670' MD (3170')TVD feet 2,560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures o I KICK OFF POINT 3000 feet. MAXIMUM HOLE ANGLE 44.5 (see 20 AAC 25.035 (c) (2) 21 18. Approximate spud date 8105185 psig@__ Surface 1500 psig@3170 ft. TD (TVD) Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) Hole Casing 30" 20" 17~" 13 3/8" 12~ , 9 5/8" 94 72 36 22. Describe proposed program: PELP L-80 L-80 BTRS BTRS 80' _ 2920' 3635' 0' . 0' 0' ! 0' 35' ~ 35' I I 80' 2920' 3670' 80' 2500' 3170' Previously set Prev~ous]v s~ 425 sks Class G cmt 116 bbls Arctic Pak cmt. 316 sks Permafrost "C" Conoco Inc. proposes re-entering A-2 and converting it to a water source well for the Milne Point Unit. Mud will system will be non-dispersed, low solids with a mud weight of 9.4 ppg. A 13 3/8" 5000 psig RSRRA BOPE stack · be used on production hole. Pressure tests will be performed as per State Regulations. Casing will be pressure tested to 1500 psig. A-2A will be drilled out from 2744' to 2864' (cmt abandonment plug) with 12 ~" bit. The well will drop angle and move to the southwest away from any previously drilled wells. Arctic Pak will be placed in the 13 3/8" X 9 5/8 annulus following primary cementing. The perforating and gravel packing will be performed after the rig has been released. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGN ED /~,,.,__--- ~-~:~-/~ TITLE E~gi~eer The spa~ow for Commission use CONDITIONS OF APPROVAL DATE Au~.~t 1~ 1OR~, Samples required ! Mud log required I Directional Survey required I-lYES ~[~. O '1 []lYES ~O I ~[~YES I--iNO Permit number f Approval date Form 10-401 APl number 50-o ~ ,-lo ~j 7~~ o t Rev. 7-1-80 SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE August 5, 1985 by order of the Commission Submit in triplicate SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL Conoco et al - Milne Point No. A-2A Conoco Inc. 3201 "C" Street, Suite 200 Anchorage, Alaska 99503 I. CEMENTING PROGRAM The primary cement job for the 9 5/8" production casing will be cemented in two stages. The first stage will consist of ±425 sacks of Class "G" cement pumped around the casing shoe (estimated ±650' of annular cement, actual volumes will be based on four arm caliper). The secondary cement job will consist of ±316 sacks of permafrost type "C" cement followed by ±116 barrels of arctic pack pumped down the 9 5/8" X 13 3/8" annulus. II. ANTICIPATED GEOLOGY 2897'-3670' Surface conglomerates, clay, silt and sand sequences. III. FORMATION EVALUATION A. Wireline logs for the 12~" hole (from T.D. to surface casing) will include: Dual Induction log; Spherically Focused log; Litho Density log; Compensated Neutron log - Gamma Ray; four arm caliper. B. Cased hole logs will include Gyro and GR/CCL. ~o. High viscosity fresh water gel(non-dispersed) mud system. DIRECTIONAL PROGRAM The A-2A well will be drilled out from 2744' to 286/4' (cement abandonment plug) with I2¼" bit. After the shoe has been tested, the well will be drilled to 3000' with 12¼" bit, at which depth the angle will be dropped from the wells existing angle of 44.5° to 39.1°. The well will be drilled to a total depth of 3670' M.D. (3170' T.V.D.). IV. DRILLING FLUIDS V. VI. COMPLETION PROGRAM The water bearing Tertiary Sands will be perforated, gravel packed and/used for water injection purposes for the Milne Point Unit. ~/''> ' ,'/ / ' : J. R. Hand Engineer L,O¢&TION I~1 SECI*IO~ IT,litE PI, AN, CO,ORDI. FROM N. LINd ~ ~. LINE NOR?HIN~i$ EASTINGI ~ il 3' ~067' 6,020 ~ ~0, 81 56 3 ,71~3.0~ I ;47 ' f,, ~ Oz./, I'~'".'/? I'~U. D,~ SI M PSON' "'L:':, · · ! · · NOTIPI ! ./ Ill I~ CO 0¢0 Mil. NE P ,IN? UNIT I. iTATE Pi,,KNE ¢O,ORDIi ARE ZONe. 4, .~_ ...., N.A, D. ItZ~, ~, OFFSE~ TO gg~TlON I~[S ARE COMPUTED tA~[D ON PROTRACT! VALUE~ OF TH~ SECTION CORNER I~ODETI~ t, ATITuDE ?0Q28' O~l',6?l* Il, ?c~ z~ o4. 47 ?" Ii. POIITION t,CINGI'I' UDE ~ CI.IECKED [,O lOOK i4tlG ~6' ~,117' W. L.K. 07. ~Z 14t°~l* 3J.&99'* W, L.K, · C£RTIFICATE OF SURVEYOR · I HERE~Y CERTIFY THAT I AM PROPI~RI.Y LAND SU~V(YING IN THE STATE OF ALASKA AND THAT TH?5 PLAT LOCATION SURVEY MA0[ 8Y ~E OR UNOER AND OTHER ~TAIL~ ARE CORRECT, ~ .~_. ~. .. .'~ 'A' PAD PAD A. WELL NO, 2A PROPOSED "' MILNE PT., NORTH SLOPE, ALASKA .... EASTHAN WHIPSTOCK. INC. ........ 2400 _ ........ 2500_ ! · ....... F_L~600._ .... ~__ _Z ~ -.~ ~. ........ ' .... 2700 ....... · . · ..... ' ..... __2800 ........ TRUE VERTICAL DEPTH ....... 2900 _ .... ' .......... :3000 _ .... 3100. 3200 _ NOTE"PLOTTING PLANE: S 55 DEG 51 MIN W ',,' 13 3/8" CSG PT TVD=2583 TtlD=289T DEP=IO11 ..... .. KOP -. TVD=2656 TMD=3000 DEP=1084 44 DEG ;34, MIN S 3;3 BEG ;30 MIN W 42 4' DROP 2 1/2 DEG PER loo FT 39 4' TARGET TD TVD:3170 TMD=3670 DEP=1514 TVD=2820 TMD=3220 DEP=I 250 1 000 11 O0 1 200 1:300 [ I I I 1 4OO ! 1500 I 1 600 I VERTICAL SECTION PAD A, WELL NOt 2A PROPOSED MILNE PT.. NORTH SLOPE. ALASKA EASTMAN WHIPSTOOK. INC. ' NORTH ._ 8OO ..... 90O .__ .... · .............. 1000 _ .... 1100_ 1200_ ...... 1JO0_ __ 1400 _ 900 800 700 -- 600 500 _ ! ! I ! --~-: ]-~'-~i~' '~OP TVD-2656 T~D-3000 ...................... DEP= 1084 · . SOUTH 972 WEST 495 ............. 2909 2974 3038 TO 2640 2??? 2805 2844 400 516 25?9 TARGET TVD=2820 TMD=3220 DEP=1230 SOUTH 1094 WEST 575 PLANE OF PROPOSAL S :3:3 DEG 30 MI N W 1230' (TO TAROET) (FROM SURFACE) 3OO RECEIVED Alaska Oil & Gas Cons. ,, , lnornm'ss"on :,,chorage M1LNE POINT UNIT A. NO. 2 CASING DIAGRAM OPERATOR: CONOCO, INC. SURFACE LOCATION' £031' FNL, 1585' FEL, S23, TI3N, RIOF, U.M. BOTTOMHOLE LOCATION' 4841 FNL, 3133 FEL, S23, TI3N, RIOE, U. hL SPUD DATE: 12/17/82 GROUND LEVEL EL: 23' KELLY BUSHING EL.: DEPTH {RKB)I _ Lto'. g4 & Il.., ..,~,1 '- L-~, ITR~ CS6. A ZT44' /~BAN~MENT 2164~ - · * . , ~4165' 4~4' ' ~ ·~- . '... ~.~ {~ o.~ ~,/m.z m,I .... 6.t PPi ~ Jg~i~ SI~' ~ ~0~ PP~ WVO 5518'54~ , . ~ . 4 ,STSO' i~t IZTi' IG{ P~ M~ ~ CASIN ~ ~.1 ~ EWw ORIGINAL: JBF, 5/83 REVISIONS: ii -- m ii i Casin~: 20", 94 lb/fl, H-40, Pelp, O'-!tlS' 13-3/8", 72 lb/fl, L-80, BTRS., 0'-2897' Cement: Primary 1-~-3/8" - 1600 sks. (3085 ft3) A~CO Fondu cement followed by 1100 sks. (1045 fl-) Permafrost type C cement. Abandonment and ~tdecrack plugs A sidetrack was plugged back from 5051' to 4700' .using 275 sks. of class G w/2% Cat12, I% CFR-2. The plug was dressed off to the kick-off point at 4774'. The 8~" open hole was plugged back and abandoned with five plugs. The 13-3/8" casing was also plugged back by placing a cement plug on top of a brideplug. Plug No. 1 (8272'-±8002') - 125 sks. class G w/l% CFR-2. Plug No. 2 (5750'-5518') - 150 sks. class G w/l% Cat12, 5 lbs/sk Gilsonite. Plug No. 3 (5499'-±5150') - 225 sks. class 6 CFR-2. Plug No. 4 (5022'-±4622'~ - 175 sks. class G CFR-2. Plug No. 5 (4545'-4155') - 125 sks. class G w/l% CFR-2, 2% Cat12. Plug No. 6 (2864'-±2744') - tO0 sk$. of Permafrost type C cement was spotted on top of the EZSV bridgeplug aC 2864'. Perforations: -None- Directions] Htehlights: The extrapolated hole angle and direction at total depth is 4°, S 11.5° E.- The maximum measured hole angle is 54' at 3931'. The hole angle and directiom at the 13-3/8" casing shoe is 45", S 32.5° W. /~,ge % //a)/ee/~ · ' CONOCO INC. MILNE POINT UNIT BOP STACK conductor '::'(1)- B.O.P.-stack size rating meets API RP 53 & spec 6A for class 5M with clamp & hub connectors all hydraulically operated. "(2) BOPE to be operated on each trip - '& pressure tested weekly. "(3) Hydraulic control system for BOPE -' to include (5) station control manifold located remote with 160 gallon accumulator and reservoir :-..unit and auxiliary energy source ' ' for 'System activation. '-- :~(4) Ram type BOP to include a:minimum -.o of one set of blind rams and two sets of appropriate pipe rams. -(5) Choke and kill manifolds shown seperately to meet AP1 RP 53 class 5M requirements. evente~ f-- z~ ~ i~ ~/~" - ~ooo* ~" - ~ooo de Ouclecs~)CS6 ~ - Si ~ ~ 00' ,i,~i - . . . ~'s~ ~2 zo-_~ooo~ 3" - 5000 Side Outlets conn=c~io~i .! zo [I '.'-' ..;~.' .'. '.j~.'.... · , , m ' ~ F'RO~ ~UD PUfF KILL MANIFOLD FROM REhtOTE HIGH R~OTE PRESSURE GAGE SERS~ PRESSURE PU~P NOTE' ~ HYGRAULIC CONTROLLED REMOTE OPERATED L H~RXUL)C ~.NT~L S~STE~ FOR B~ ~C~ 8 CHO~ W~N)FOLD TO INCLUDE (~) ST~TI~ CC~FROL W~NIFO~ ~ED REVOT~Y ~TN 3~0 PSI ACCUUUL~TOR 8 160 G~. RESE~R 8 ~UX. E~ERGY SOURCE. ~. ~ROL W~FO~ PLUS V~R)~8~ CHOKE ~NT~ YO BE ~ED ON R~G FLOOR. DRILLING Z K[~ a CHC~ U4N~FOLDS ~ ~EET ~ RP53 ~. ). ~ ~NIF~O ~IZ[- RATING Z'- ' ~REMOTE PRESSURE GAGE · , ~~ ~ ~- CHOKE TO PiT MUD/GAS SEPARATOR ...~,__ ~' "~,~ :°' CHOKE 8 KILL MANIFOLDS FOR ~/8'~ 8 7" OD CASING BOP STACK ~ ~OP ~IANIFOLD LAYOUT - CONOCO, INC. ~~~, , , , , · , , , CHECK LIST FOR NEW WELL PERMITS · /'~' ~,!~ ." :,.~,,.,~,, Company u_..~,,:..t~ Lease & Well No i"" ITEM APPROVE DATE YES NO REMARKS (1) Fee i' ;~' '- ' :;" 1 (2) Loc t.'-)c.~,. ¢'"' '~ ',~i"! 2. (2 thru ~) 3. 4. 5. 6. 7. ' 8, (8) (9 thru 12) ~~'l-l?"' .?'/' .,. · '(10 and 12) (4) Casg .'; ~ '~' (13 thru 21)" (5) BOPE (22 thr'u '26) e 10. 11. 12. 13. 14. 15. 1,6· 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. Is the permit fee attached ........................................... -- Is well to be located in a defined pool ........................ ..~...~ Is well located proper distance from property lineI i'' ' ' [!' '~/' ~ " '? Is well located proper distance from other wells . [ ...'~ " · · · Is sufficient undedicated acreage available in this pool Is well to be deviated and is wellbore plat included ................ ~..'~., . Is operator the only affected party .............................. Can permit be approved before ten-day wait .......................... ..,?':/... Does operato have bond in force r a ............................. ..... ~;,.~, ~ Is a conservation order needed ...................................... " Is administrative approval needed ................................... -L~,. Is the lease number appropriate ........................... Is conductor tring provided ' S eeleeeleeeeeeeeeeeeeeleeeee~eeeeee~eeee· "~" ''~ '" Is enough cement used to circulate on conductor and surface ...... .... .. Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. ?~.,..~., 'Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ /!,7',t.7., ~ ./[/:~-'/":) ..z,~"//. ~ . . ,~:~'~'/'..'~" Is' div sys req ired /:'~'" / a erter tem u . ....................... . .... . ....... .. · "? ~" 9 !~' :', ': :' ' Are necessary diagrams of diverter and BOP equipment attached ....... /;',:'~,,'7" ..... ~" Does BOPE have sufficient pressure rating - Test to ~,,/~,~,~ psig .. .,,,, Does the choke manifold comply w/API RP-53 (Feb.78) ....... ........... , ,, Is the presence of H2S gas probable ................................. ":~., ~' Additional requirements '"",.!," eleeel~eleeee·..e.eel.eeeeeleeeeeeeeeeeeeeeee '""', 0 ~Z H 0 ~ ~-] Geology: HWK LCS WVA 'MTM JAL ~/'~...... rev: 03/13/85 6.01l .E.ngineerin~: BEW. /' INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE , , Well Histo.ry 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 APPENDIXi No special 'effort has been made to chronologically organize this category of information. DIRECT DIGITAL LOGGING COMPU TER PROCESSED ANALYSI..S L;omp.an!~.. CONOCO, INC, W~:ll MILNE POINT UNIT A-2A Field KUPARUK DATE OF JOB: 08'-16~$5 Countp NORTH SLOPE State ALASKA Co. untr,~, USA CL lENT FORMAT DATA TAPE LO G I NFORMA T I ON STANDARD FORMAT ( L , I , S , ) ~.~tell No, ~ CONOCO {~2A Depths: 2~,.' e.. O O '~' '~ 37,40, O0 Fie:id: KUF'AF..:LiK [~AI'E OF dOE,': 08-1 Time.; P~ga: ia SEP!,:_~,~Jg~,5 9:02 ~M THU. 1 I, 'S, TAPE RECORDS REEL HEAl)ER :~*:~-* Ser. vic~ ,name: &~]5FOI Previou~ r'e~l: :.l'~ · .~: :~ TAPE HEADER ~:~ Pr~viou~ .tape: Date: 85/09/12 Commentz: Date: ,:,..,,- Ud,. 1 2 £ommentz: HEADER Origin: Or'igin: RECORD""' P a g e Reel name: 'S0486~ Continuation tS: Oi Continuation :~: Oi -:~:'~ EOF *** FiLE HEADER File name: ~L~..,FOi. OOi HEADER RECORD© Mmximum le. ngth: 1~024 Film t..vpm: LO Prms~iou. s .Pilm: Date: P~g~ MNEM CN WN FN COUN STAT CTRY .SECT 'TOWN RANG EK8 EDP EGL PD LMF DMF ,RUN LCC .SON LUN FL LUL ENGI WITH DD bL TLi 8LI TCS TL~B ~T HT MV ~S RM HFST MFSS RMC MCST 1 NFORMAT I ON RECORDS CONTENTS UN I T CONOCO., INC. MILNE POINT UNIT R-2A KUPA RUK DA'TE NORTH SLOPE , ALASKA . US A , i ~Iq ..... IOE 55., 000 O, OOO, , MS', K~ 76! i NORTM SLOPE NORTN SLOPE W~ITE BENOA ~7i 9,000 .......... 3725 000 28 75. O O 0 .......... 3721 , 000 .......... i 6,00:0 ............ 1 ~. 270 7~. 000 7S. 0'00 NON-DISF' FLOWL i NE 93. '000 .............. i,lO0 ............... m m m i i I ~ m m m ,9 O0 .......................... 64,3'00 ........................ ME" ~URE[ ~'0 :' , , , , , , ~ , , . , , , , ~ , : ! , s'O0 .............. 68,000 ........................ MEASURED ............................................ TYPE C A T G SIZE CODE 0 0 40 65 0 0 40 -6,5 0 0 4.0 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 2 65 0 0 3 65 0 0 3 65 F'T 0 ~ 4. 68 FT O 3 4 68 FT O 3 4. 68 0 3 '2 65 0 3 2 65 0 3 2 65 0 0 2 79 0 O 2 79 0 0 10 ~".~ 0 0 iO 65 0 0 20 0 0 2 0 65 0 0 2 0 65 0 O 20 65 FT 0 3 ,4 68 FT o 3 4 6'8 FT 0 ~ 4. 68 FT O 3 4 68 HR 0 2 4 68 H.R 0 4 4 68 DEGF' 0 1 4 68 DEGF 0 i 4. 0 2 20 6= -" 2 0 65 C P 0 2. 4 68 OHMH O 2 4 68 0 H bi M O '2 4 6 E; D E G F 0 2 4. :S .~ O 2 12 65 OHMM 0 2 4 68 DEGF O 2 4 68 0 2 i2 65 F'ag .¢.; COMMENT RECORDS Thi~ LiS 'tape was written bp Gmarhart Indu~trie~ Wirelin~ Services, Ail curve and tool rune:monies used ere tho~m which most clos~:l~,~ match Gearhart curve end too,1 mnemonics. ~EARHART TO SCHLUMBERGER MNEM SERVICE UNIT MNEM SERVICE UNIT D~.,F TH FEET DEPT FT TEN MERGE MV TENS MERGE MV RAT COMPU.TEO RAT COMF'UT ~]R MERGE GAPI GR MERGE GAP! XCAL MERGE iNCH CAI... I MERGE IN ILD MERGE OHMM ILD MERGE OHMM ILM MERGE OHMM ILM MERGE OHMM LLS MERGE OHMM LLS MERGE OHMM FFDC MERGE CPS FFDC MERGE CPS NFDC MERGE CPS NFDC MERGE CPS RHO8 MERGE G/C~ RH08 MERGE G/C~ DRHO MERGE G/C:3 DRHO MERGE G/CS FCNL MERGE CPS FCNL MER~E CPS NCNL MERGE CPS NCNL MERGE CPS CILD COMPUTED MMHO CILD COMPUT MMHO CDL COMF'UTED PU DPHI COMPUT PU NPHS .COMPUTED SSPU NPH! COMPUT PU Pmge ~ATA ~': :~. :~ :~ ENTRY BLOCKS EN TRY FORMA "F Y P E T SPEC ~ F i CAT IONS SiZE CODE O ~ GG Page: :+::-~.:+:.:.~,: ,ENTRY BLOCK LEGEND TYPE DESCRIPTION ;0 Tmrmir, ator ( no mor. e. mntr. im~_-. ) DATA F.ORMAT SERVICE SERVICE iD ORDER # AP1 AP! APl APl .UNIT LOG TYPE CLASS HOC, D E P T 3 04863 F T 0 0 O 0 "~ MU TEN.. MERGE J04863 ., 0 0 0 .~ RAT :COHPLiT 304863 ,0 O O 0 ~R ~ER~E 3 0486:.~ ~AP t :0 54 i O CALI MERGE S0486~ iN 0 24 i ~ 0 i i_D MERGE 3 04863 OHMM O i 20 46 0 i LM ME'"~' K.E 304863 OHHM 0 i 20 44 0 L,L,3 MERGE 304863 OHblH 0 220 6 0 FF'DO MERGE 3048~3 .CPS 0 98 2 0 NFDC MERGE 3'04863 .CPS 0 98 I O kHuB MERGE 304863 ~3,YC3 0 94 i 0 DRHO MERGE 304863 G/C.3 .0 i ,,00 i O F:C:NL MERGE 3,04863 ,CPS 0 78 3 i '0 NCNL ~ERGE 30486~ CPS 0 78 30 .0 CZLD ,CO~iPU'I' 304863 M~HO 0 69 46 0 DPN[ COMPUT ' "-' 3 06 ~ ~ 3 P U 0 0 O 0 N P H i C 0 M P U T 30486:3 P U 0 i ¢' ~ ~z 2 ',O oPEC I F I _.AT 10N¥ FILE P RC: ~ SIZE L. Vi_ SMF'L RC 4 0 i 68 4 O i 68 4 0 i 68 4 O i 68 4 0 i 68 4 O i 68 4 0 i 68 4 0 1 68 4 0 i 68 4 0 i 68 4. O i 68 4 0 i 68 4 O i 68 4 O i 4 0 i 68 4. 0 i 68 4 O i 68 PRL L:~=S~ iNDICATORS 000000 0'00000 000000 O000OO 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 '000000 000000 000000 000000 000000 000000 000000 000000 000000 O00UUU O001jO0 000000 000000 O000tjO 000000 0,00000 000000 000000 000000 000000 P~ge D E.P T F~DC NPHI 3740.000 O, 9.72i 3640.00:0 7 J 5.80,0 4O, · '..~ 54 0., 000 694,200 50,6~-'0 ~440,000 44,600 334:0,:000 717,200 ..u 324 0, .000 91 ~, 1.00 ~4 76,0 3140, '0 O0 7'56.400 44,400 3040.000 775,000 40,590 2940. 000 6.44.700 44,65O TENS NFDC O73,000 O, 0.00 2:025,00~0 6~33,100 23:08, O00 7'03,60 0 2044,0 O0 686,800 199i , 0:00 717,700 2034, :0,'00 7:05, O0 0 1947.0'00 734.300 22'00, 000 682,500 1849,0'00 727, i O0 RAT RHO8 -999,250 O,OOO 2. 750 2, lO0 2. 175 ., 965 2,085 :032 2,112 3,182 1.881 2,868 2.i30 2,773 2,059 3, 01.4 2.262 DATA GR DRHO .0,000 0,.000 54.6O0 -,007 80, .7:00 ,075 43.2:0.0 ,014 44.1,00 .024 31 .500 -, 022 56.700 .042 39.800 -,008 ~,9. 400 ,09i RECORDS CALl FCNL ILO NCNL 0,000 1.,000 0,000 13..070 62.700 11.350 i94,600 13,670 55.700 11. 066 17.0,500 15,300 50,000 15 t62.500 IJ,420 53.60'0 13.243 173,900 15.470 ~,100 27,990 167,300 14,810 58.300 12,023 164,900 15.250 75,700 15.346 '203. I O0 16,000 55.200 t2.853 167.700 I LH CILD 12.503 1 000,00.0 9,572 88. i 05 9.840 90,765 9.886 65.615 10.8i4 75.509 14,355 35.727 1 0.2..73 83, i '76 13.552 65.i63 17. 179 77.804 LL3 DF'H i I ,000 i 60,606 7,015 7,534 28,788 5.970 .74 .~,. o 6,442 9,247 46,606 6. 194 3i .5i5 5, 70.-' ''~ 23 5i= P~g~ DEP T FFDC NPH I TE NS NFDC RAT RHOB OATA GR DRHO RE CORD'''o CALl FONt.. lED N C N L. ILM C ii..D LL~ DPWi Fii~ name: &GSFO1 ,'00! Maximum length: 'i TRAILER RECORDS File type: LO Version Nmxt .~ile: Date: i 0 EOF EOF ~:~-~
