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195-081
STATE OF ALASKA ALIIIL OIL AND GAS CONSERVATION CO , SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: ESP Change-out ❑., 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska LLC Development ❑✓ Exploratory ❑ 195-081 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic Service ❑ 6.API Number: AK 99503 50-029-22567-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028231 MILNE PT UNIT E-22 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): .10.Field/Pool(s): N/A MILNE POINT/KUPARUK RIVER OIL 11.Present Well Condition Summary: Total Depth measured 14,332 feet Plugs measured N/A RECEIVED true vertical 7,321 feet Junk measured N/A feet AA�Y 2017 Effective Depth measured 14,254 feet Packer measured 13,687 feet�v' true vertical 7,292 feet true vertical 7,056 fee ( Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 3,745' 9-5/8" 3,745' 3,044' 5,750psi 3,090psi Production 14,300' 7" 14,300' 7,312' 7,240psi 5,410psi Perforation depth Measured depth See Schematic feet « ^i°` "l��1 x SCANNED t\A :.d..�.+ e True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5/L-80/8rd,EUE 13,208' 6,857' Packers and SSSV(type,measured and true vertical depth) 7"HES VTL Packe See Above N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 980 0 Subsequent to operation: 98 126 1,234 280 194 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory Development❑✓ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil El Gas Q WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-149 Authorized Name: Bo York Contact Name: Taylor Wellman 7 / Authorized Title: Operations Manager Contact Email: twellmanc hiIcorp.com Authorized Signature: `,/'�� 1 Date 5/19/2017 Contact Phone: 777-8449 74- 5--2.4-/—/7 Form 10-404 Revised 4/2017 .000 {,c///24' ,7 RBDiiii-, Submit Original Only .3 V- WV( 2 4 26 • Milne Point Unit • Well: MP E-22 SCHEMATIC Last Completed: 5/8/2017 Mean)Alaska,LLC PTD: 95-081 Drill Rig:N 22E TREE&WELLHEAD Orig.KB Elev.:53.8'/GL Elev.:24.7' Tree 2-9/16" SM FMC Wellhead 11"5M FMC w/2-7/8"Tubing Hanger,EUE lift threads, 44 k 2.5"CIW H BPV Profile 20' OPEN HOLE/CEMENT DETAIL Pt 20" Cmt w/250 sx of Arcticset I in 24"Hole 1 t 9-5/8" Cmt w/800 sx PF"E",250 sx Class"G",250 sx PF"E"in 12-1/4"Hole k 7" Cmt w/300 sx Class"G"in 8-1/2"Hole CASING DETAIL i° Size Type Wt/Grade/Conn Drift ID Top Btm BPF 20" Conductor 91.1/H-40/N/A N/A Surface 112' 0.355 9-5/8" '4 9-5/8" Surface 40/L-80/Btc. 8.679 Surface 3,745' 0.0759 • 7" Production 26/L-80/Btc 6.151 Surface 14,300' 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.347 Surface 13,208' 0.00579 WELL INCLINATION DETAIL KOP @ 500' Max Hole Angle=67 deg.@ 4,600 to TD JEWELRY DETAIL it lti, No Depth Item 'I / 0 1 147' STA#2:Camco 2-7/8"x 1"KBMM w/DGLV wT 2 12,997' STA#1:Camco 2-7/8"x 1"KBMM w/Open Pocket ,„0 3 13,077' XN-Nipple: w/2.313" landing Profile(2.205 No-go ID) �'� 4 13,088' Discharge Head:FPDIS ,l0 5 13,089' Pump#1:SXD H6-134FLEX17.5 6 13,112' Pump#2:SXD H6-134FLEX17.5 7 13,136' Pump#3: SXD H6-134FLEX17.5 ��JJJJ 8 13,159' Intake:GSTV X H6 FER 9 13,164' Upper Seal Section:FSB3DB UT FER SB/SB PFSA 10 13,170' Lower Seal Section:FSB3DB H6 FER SSCV SB/SB PFSA H MIN ID=2.205" 11 13,176' Motor-XP-200F:200HP,2,395 volt&59 amps 2 @ 13,136' 12 13,204' WeIlLift Type E Sensor 13 13,206' Centralizer/Bottom @ 13,208' 14 13,687' 7"HES VTL Packer w/4-1/2"XN Lock/Equalizing 0.156 ID 3 t 15 13,696' 4-1/2"XN 4 PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 5,687 Kup.C Sands 13,596' 13,688' 6,963' 6,994' 92 8/4/1995 Open 1 $ Kup.B7 Sands 13,708' 13,728' 7,065' 7,074' 20 8/4/1995 Open 9&10 GENERAL WELL INFO API:50-029-22567-00-00 Drilled and Cased by Nabors 22E -6/29/1995 ;s11 Completed with ESP by Nabors 22E-8/9/1995 )w ESP RWO w/4-ES-9/7/1996 z ESP RWO w/4-ES-12/27/1996 12 Set Tubing Patch-7/20/1997 ' 13 0,t. ESP RWO w/4-ES-8/24/2000 , t.,, ESP RWO w/4-ES-6/1/2002 _ 4}KUP C Sand ESP RWO w/4-ES-11/25/2007 14 115 }KUP B7 SandESP RWO w/ASR#1-5/8/2017 041, 04 7" 13 14 TD=14,332'(MD)/TD=7,321'(TVD) PBTD=14,254'(MD)/PBTD=7,292'(TVD) Revised By:TDF 5/19/2017 • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-22 ASR 1 50-029-22567-00-00 195-081 5/3/17 5/8/17 Daily Operations " . ztt, 5/3/2017-Wednesday Continue to R/U well E-22. M/U dual manual valves on kill line, R/U choke and kill lines hoses to pit system. R/U Certek heating system, wrap fluid lines w/glycol lines. Enclose fluid lines and glycol lines in tarp containment. R/U hydraulic lines f/accumulator to BOP stack. Wrap lines in glycol and enclose in tarp containment. SIMOPS: R/D and clean up location on E- 04.Take on 8.5ppg seawater from upright tank to pits. Wellhead hand John Morrow on location to pull BPV and replace w/ TWC. Perform shell test on BOPE system.Crews continue to R/D on E-04. Clean and remove all Herculite containment. Dispose of any oily waste. Remove rig mats. (Accept Rig at 2300 hrs. On 5-3-17) Test BOPE as per Sundry, utilizing ASR BOPE test procedure.Test rams w/2-7/8" and 3-1/2" test joints to 250psi low f/5 charted mins and VBR's to 3000psi high f/5 charted mins.Test annular to 2500psi high f/5 charted mins. AOGCC rep Brian Bixby waived witness to testing @ 06:03am on 05/03/17.SIMOPS: move company rep trailer and doghouse into position on E-22, spot ESP spooler in place. Blow down all circulation lines and manifolds. P/U ESP sheave and elephant trunk and hang in place. R/U pipe racks in prep for laying down 2-7/8" completion TBG. Contact wellhead reps Greg Ruge and John Morrow on Location 5/4/2017-Thursday Rig Service Check Fluids and Grease Open IA to Flow Back Tank, Well is Bleeding Gas R/U Pressure Gauge IA Showing a Constant psi=2, R/u Pumped 50 bbl. Down the IA, Blow Down all Lines Check IA Still Constant psi=2, P/U M/U L/JT into Hanger BOLDS, Pulled Tubing Hanger to the Rig Floor unset tubing Hanger at (71k) with a Max Pull of(101k)with a Constant(95K) Break out ESP Penetrator and Tigh Cable off to the Spooler, Back out Landing Joint and Tubing Hanger and LayDown Trip out of the hole L/D 2-7/8 Completion Tubing F/13,244 ft.to 7,000 ft.) ESP Cable was Blown out 140 FT. Below Hanger, Pictures in well Folder, While Pulling Pipe at (3,780 ft.) ESP Cable stop Coming out of the hole with Tubing, R/U Strap to Cable Pulling up with Tugger and Pulling the Slack up and out of the Hole. Using Double Displacement While Tripping Continue to POOH w/ ESP completion on 2-7/8" 6.5# EUE TBG. Several bent joints found and removed from string. Bending consistently 1-2' below upset prior to collar. Fill hole w/double displacement. Continue to POOH wf ESP_ completion on 2-7/8" 6.5# EUE TBG. Several bent joints found and removed from string. Bending consistently 1-2' below upset prior to collar. Fill hole w/double displacement. L/D Baker Centrilift ESP. Clean and clear rig floor of ESP equipment. Verify pipe count. 67 bad joints found in string. 419 total joints recovered w/206 LaSalle collar clamps. 5/5/2017-Friday Rig Service Check Fluids and Grease Change over Handling Equipment f/2-7/8 to 3-1/2 Load and Tally 340 Joints 3-1/2 RTS- 8 Work String on Pipe Racks Trip in the hole w/7' 26#Casing Scraper on 371/2 RTS-8 Work string to 1,800 ft. ( Rig Crew Conducted Kick while Tripping Drill with all Hands)Trip in the hole w/7' 26#Casing Scraper on 3-1/2" RTS-8 Work string F/ 1,800 ft.to 10,015' md. POOH w/7" 26#Casing Scraper on 3-1/2" RTS-8 Work string F/10,015'md to 6250'md. Floor hand noticed pin on elevators was not correctly in place. Stop the job and investigate. Bottom of pin found to be sheared off, which removed the keeper pin that would restrained it in the elevators. Could not locate a spare. Fabricate a spare.Test fabricated replacement pin in elevators(good fit). Continue to POOH w/7" 26#Casing Scraper on 3-1/2" RTS-8 Work string F/6,250'md to"4,000'md. • ! Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-22 ASR 1 50-029-22567-00-00 195-081 5/3/17 5/8/17 Daily Operations: G , 5/6/2017-Saturday Continue to POOH w/7" 26#Casing Scraper on 3-1/2"RTS-8 Work string F/4,000' Surface, Break and Lay Down BHA 7' 26# Casing Scraper M/U Halliburton Champ PKR set up for 7"«,26#CSG,TIH on 3-1/2" RTS-8 Work String f/surface to 10,015' md. Set work string in slips, kelly up power swivel to stump, P/U 5' and lightly rotate PKR to the right.After 2 rotations, set down 20klbs to verify PKR is set. (Good Set) Fill backside w/60bbls of 8.5ppg sea water until fluid reaches surface. (Fluid �� Level at 2,281 ft.) Bleed off any residual gas migrating to surface, close pipe rams and R/U chart recorder. Perform MIT test It _on 7" 26ppf CSG to 1500psi for 30 charted mins. (Good Test). Bleed off pressure from system and blow down lines. Release Halliburton Champ PKR w/straight pull. Watch hook load to verify PKR is properly released and not showing signs of drag. POOH w/ Halliburton Champ PKR on 3-1/2" work string f/ 10,015'md to ^'3,000'md. 5/7/2017-Sunday Rig Service Check Fluid Levels Grease POOH w/ Halliburton Champ PKR on 3-1/2" work string f/3,000 ft. to Surface, Break and L/D Halliburton Champ Packer,Transfer 90 bbl. f/400 bbl.tank to Pits (JSA) load new ESP Pump Assembly and GLM'S on cat Walk, Load and Tally 416 Joints of 2-7/8 Completion Tubing on Racks, While P/U ESP Pump Assembly and Service Lower and Upper Tandem Seals TIH w/ New ESP Pump Assembly and 2-7/8 Completion Tubing to 2,000 ft. Centrilift Tec Check ESP Cable ( Good Test) R/U Circulation Nipple Attempt to Fill Tubing, Rig Shut down Lost all power to Driller Console Trouble shoot Problem with Pro Star Tec. Re-start system and check for any malfunctions. Rig functioning fine.TIH w/ New ESP Pump Assembly and 2-7/8 Completion Tubing f/2,000'md to "8,000'md.Test ESP cable and roll fluids through pump every 2,000'md. 5/8/2017- Monday Rig Service Check Fluids and Grease Centrilift REEL to Reel ESP Cable Splice at 8,000 ft.TIH w/ New ESP Pump Assembly and 2-7/8 Completion Tubing f/8,000 to 13,205 ft.Test ESP cable and flush 8.5ppg sea water through pump every 2,000' ft.. Ran Total of 417 Joints) P/U/W= 81k D/N/W=23k P/U Landing Joint Make up into Tubing hanger, Centrilift Rep Splice ESP Cable into Penetrator,Land Hanger RILDS Back out Landing Joint and Lay Down, Well Head Rep Greg Ruge and John Morrow Tee Bar and Install BPV in Hanger( Release Rig at 16:00 hrs.) Blow Down and Disconnect all Service Lines, Bleed down Accumulator Lines and Disconnect from Bop Stack, Remove Pipe Racks, Disconnect and Rig Down Certex Glycol Heating Lines and Trailer, Remove ESP Sheave and Drain Hose from Derrick, Roads and Pads Vac Truck Sucked out 100 bbl. F/Pits and 10 bbl. From Drill Cutting Box, I-Rig Welder Saltz on Rig Floor Heating up and Straitening up Base Place for Power Tongs Perform check valve swap out on carriage hydraulic lines. NES on location to being rig move from E pad to A pad. Rig crews SIMOPS, preparing A pad for stack out and prepping rig for move. Once carriage check valve swap is complete, wipe down exterior wind walls on derrick and function test hydraulic system. Carriage controls functioning much smoother. R/D and L/D derrick, move and stack out carrier unit on A pad. Roads and Pads on location w/crane. P/U rig floor, well house, and BOPE and relocate to A pad for stack out. Wellhead reps Greg Ruge and John Morrow on location to set and test production tree. Spot tree in place N/U bolts and TQ as required. NES relocate pit trailer to A pad in prep for trailer swap. Continue to R/D on E pad, N/U tree, clean and clear location. Remove mud boat, rig mats, tool push trailer and storage conex. Clean all rig equipment once relocated to A pad. 5/9/2017 -Tuesday No activity to report. • ( 195-0(3 i Regg, James B (DOA) From: Regg,James B (DOA) Sent: Monday, May 8, 2017 2:17 PM 7 JI(7 To: 'Cody Rymut - (C)' Cc: Brooks, Phoebe L (DOA) Subject: RE: MPU E-22 BOP Test Attachments: BOP Hilcorp ASR1 5-4-17 revised.xlsx Thanks for the drawings, clarifications, and discussing the low pressure test pressure with drillers and tool pushers. You are correct regarding not counting the hydraulic valve on the pump manifold. I added 5/4/17 to the Date block. Revised report attached. From: Cody Rymut- (C) [mailto:crymut@hilcorp.com] Sent: Saturday, May 6, 2017 2:58 AM To: Regg,James B (DOA) <jim.regg@alaska.gov> SCANNED ' Subject: RE: MPU E-22 BOP Test Jim, Attached is the updated report w/the number of nitrogen bottles. ' I've taken your response and had meetings with each of my drillers and tool pushes. Ultimately these are my mistakes but I wanted to make sure you know I've taken your feedback and discussed it with our team. Test#1: The initial bleed off you see on the test was due to the pressure ramping up higher than expected when the driller functioned our test pump. Driller# 1 was clear that test pressure must be bled off and re-started if the low pressure threshold is exceeded so he bled off the pressure and started over. The failed tests following test# 1 were due to a leak in our hydraulic valve#1 off of our pump manifold. I've attached two hand sketches(I'm not an artist) of our fluid system to depict how we shut in for test# 1 and #2, so you can see why✓ test#1 held, but test#2 took some trouble shooting. Once we located the leak at HV#1, we greased the valve and it held solid from that point forward. I instructed the driller not to report this as a fail/pass since hydraulic valve # 1 on our pump manifold is not part of our test envelope of well control critical equipment. Please let me know if you would like me to report these types of leaks as fails in the test procedure in the future. I have no excuses for the low pressure test's being too high. I can assure you that in the future they will be within the tolerances listed in API Standard 53, and if any are taken higher than the upper bounds (350psi), they will be bled off entirely and started over as opposed to bleeding any down. I appreciate you pointing these errors out and working with us to ensure the process is done correctly. Please let me know if you have any other questions. Cody Rymut WSM, ASR#1 Hilcorp,Alaska C: 907-230-3594 crymut@hilcorp.com 1 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, May 05, 2017 10:44 AM To: Cody Rymut - (C) Cc: DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Subject: RE: MPU E-22 BOP Test The report is missing the#of N2 bottles (Accumulator Section). Several items regarding the low pressure tests based on a review of the charts: • Test#1—Low pressure test appears to be a FP—pressured up to 450psi then bled to zero; subsequent pressure up and held at 250psi for 5 min test • What are the pressure tests shown on the chart following Test#1 (series of pressure up and bleed off records that are not labeled)? • Tests#2 and #3—low pressure tests are to be performed at 200 to 300 psi per API RP 53 Section 17.3.2.1 and Tables 1 and 2; charts show these were held at 350-400psi (for comparison, API Standard 53,Tables 2 and 3 indicates the low pressure test at 250-350psi) • Tests#4 and #5—pressures up to 500psi were applied then bled down to 300-350psi for the low pressure test. API RP 53 Section 17.3.2.1 states: "When performing the low pressure test, do not apply a higher pressure and bleed down to a low test pressure." The concern is misrepresenting the low pressure sealing capability of the tested component. Appears the remainder of the low pressure tests were performed correctly. Please address these for subsequent BOPE tests. From: Cody Rymut- (C) [mailto:crvmut@hilcorp.com] Sent: Friday, May 5, 2017 4:38 AM To: Regg,James B (DOA) <iim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L(DOA) <phoebe.brooks@alaska.gov> Subject: MPU E-22 BOP Test Attached is the BOP test from MPU E-22. Please let me know if you have any questions. Thanks! Cody Rymut WSM,ASR#1 Hilcorp,Alaska C: 907-230-3594 crymut@hilcorp.com 2 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION .1c - 451(7 BOPE Test Report *AII BOPE reports are due to the agency within 5 days of testing* Submit to:jim.reggaalaska.gov;AOGCC.Inspectorsaalaska.gov; phoebe.brooks analaska.gov Contractor: Hilcorp - Rig No.: ASR 1 DATE: 5/4/17 Rig Rep.: Bledsoe Rig Phone: 907-685-1266 Operator: Hilcorp Alaska Op. Phone: 907-230-3594 Rep.: Cody Rymut/Craig Smith E-Mail crymut@hilcorp.com Well Name: MPU E-22 PTD# 1950810 - Sundry# 317-149 - Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Test Pressure(psi): Rams: 250/3000 - Annular: 250/2500 - Valves: 250/3000 - MASP: 911 MISC.INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen. P ' Well Sign P Upper Kelly 0 NA Housekeeping P Rig P - Lower Kelly 0 NA PTD On Location P Hazard Sec. P Ball Type 1 - P - Standing Order Posted P Misc. NA Inside BOP 1 - P " FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank NA NA Annular Preventer 1 - 11" - P • Pit Level Indicators P - P - #1 Rams 1 ' 2-7/8"x 5" - P Flow Indicator NA NA #2 Rams 1 Blinds - P - Meth Gas Detector P P - #3 Rams 0 NA H2S Gas Detector P - P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln.Valves 1 " 2-1/16" P - Inside Reel valves 0 NA HCR Valves 1 - 2-1/16" P - Kill Line Valves 2 - 2-1/16" P - Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure(psi) 2850 - P - CHOKE MANIFOLD: Pressure After Closure(psi) 1300 - P " Quantity Test Result 200 psi Attained(sec) 23 - P - No.Valves 15 • P Full Pressure Attained(sec) 78 - P Manual Chokes 1 . P Blind Switch Covers: All stations Yes Hydraulic Chokes 1 - P - Nitgn. Bottles#&psi(Avg.): 4 @ 2500psi - P - CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 0 -v Test Time: 4.5 ' Hours Repair or replacement of equipment will be made within days. Notify the AOGCC of repairs with written confirmation to:AOGCC.Inspectors@alaska.gov Remarks: Tested all components as per ASR testing procedure w/2-7/8"and 3-1/2"test joints.Test witness was waived by Brian ,� Bixby @ 06:03 5/3/17. AOGCC Inspection 24 hr Notice Yes Date/Time 05/02/17 14:00 Waived By Brian Bixby Test Start Date/Time: 05/04/17 00:OOam (date) (time) - Witness Test Finish Date/Time: 05/04/17 04:30am Form 10-424(Revised 03/2017) 2017-0504_BOP_Hilcorp_ASR1_MPU_E-22 Hicorp ASR#1 BOP Test Procedure uian. u,uux: 8.0 ASR RIG 9 BOPE TEST 11"-5K STACK LOG DATE 5/4/17 WELL MPU E-22 Test Pressure 250Low/3000High Annular 250Low 2500Hich Start time Q Ol) Finish `jq Actual test time y" Shr5 TEST# Pass Fail 1 Blinds, C12,C14,C16 2 Pipe Rams, I BOP, CI, K1 3 Pipe Rams, TIW,HCR,K2 4 Pipe Rams,TIW,C5,C6,C9, K3 ✓' 5 Pipe Rams,TIW,C4,C7,CI 1,K3 6 Pipe Rams,TIW,C8, CIO,C13,C14,C15,K3 7 Annular, T1W,C8,C9,C10,K3 • 8 Choke Bleed Off • • Accumulator TcsL i r A System Pressure a�5��5 t Nl6,Ftt-'O i• = 1501, L Draw Down Pressure 1 j0,) , Anti u kti Test witnessed by 200 PSI 5 •n Test witness waived by Dr 1 u fL Full Recovery N4/S Ten Bottles 1 2 3 4 5 6 7 8 9 10 A'-1t en 3CiCIAUD 1 = '2500 ta= 25co 14. 3 : as0U y = 9,soo v Page 10 - _-=_ ,- r / / r r J /, \v` \lam 4DDo/' v / t A / i J r / , J °, °° ` f f / � - a //////// ff/ /X/ ; • r • � O •-..43; On C� ~ / / / / / / / - // � D \ r 1 I i i / >(' , -- --d0 '---,..,0 I ' / / I I 7 / / X.;,0‘) _---------- - ---F-"--,....,., - 9. ,, o i'1 // j I I // X . 10 7,......, '', 1 X . 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Ti ,-. . -1-- ........,_, • ._1,- ,ni 1---- to _ >c - 71- ',. o au. in ix r ' d ..,.. cs .:.,1 --c--• IV .....,.... .„. .— itoi. 1 0 -5 - 1 0 ...V..i. 1 0). •. : . ' ci',i1 1,., C'4 • a, '- ..o A . . \--- L.. o „ri 0 •-). . .- er cL - 0 1-- •;,,, ..). ---0 1 , .N-41 0— T-1 11111041 0 ---0 4- 1:-A (--) l's-i'k .0 •V 1 ILI 11— ?, ,..- 1/4 9 t t t..9014 3- &I CI ,es—r* 8 > . . --4 • —V") cl-- H -... H Ilk sr‘P-ii% - L. ' TO L--- U ( ) d " ;.• li WO ..,sg..- . g to -7--' *.d, c.i 7-4PF 1C-51 1--- ci -.., 1-4 a__ if k...)411/61 Ol• j ,,(1' • 1-t II J, It er)v5 • • • y ����j/j�s� THE STATE Alaska Oil and Gas � � ia� OfAT AS KA Conservation Commission tts i, L 333 West Seventh Avenue �l 41 � GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ' Main: 907.279.1433 O ','w,.. Fax: 907.276.7542 www.aogcc.alaska.gov Bo York %ANNE) APR 1 4 2u Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU E-22 Permit to Drill Number: 195-081 Sundry Number: 317-149 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, A , jas. ..„....„4„..., Cathy '. Foerster Chair DATED this /Ay of April, 2017. RBDMS APR 1 7 2017 RECEIVED STATE OF ALASKA APR 0 7 2017 09,L- 441 7 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS `^`°' 20 MC 25.280 1.Type of Request: Abandon 0 Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change-out ❑✓ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development 0 195-081 ' 3.Address: 3800 Centerpoint Dr,Suite 1400 Ei 6.API Number: Stratigraphic ❑ Service Anchorage Alaska 99503 50-029-22567-00-00 ' 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432D Will planned perforations require a spacing exception? Yes ❑ No 0 MILNE PT UNIT E-22 ' 9.Property Designation(Lease Number): ,)5 10.Field/Po (s): 911 0 C. a8 21 I ini iii& l'oiht, Ac.J(„` Riitd Oi") 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 14,332' 7,321' 14,254' 7,292' 911 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 3,745' 9-5/8" 3,745' 3,044' 5,750psi 3,090psi Production 14,300' 7" 14,300' 7,312' 7,240psi p 5,410psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5/L-80/8rd,EUE 13,246 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 7"HES VTL Packer w/4-1/2"XN Lock and N/A 13,687 MD/7,056 TVD and N/A 12.Attachments: Proposal Summary ❑ Wellbore schematic ❑✓ 13.Well Class after proposed work: (0) Detailed Operations Program ❑ BOP Sketch p Exploratory ❑ Stratigraphic Development[IJ Service 0 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 4/22/2017 OIL Q WINJ El WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS , WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York Contact Name: Taylor Wellman "r'r,4 Authorized Title: Operations Manager Contact Email: twellman(c�hilcorp.com V Authorized Signature: 'L, Zv Yorks Date: 4/7/2017 COMMISSION USE ONLY Contact Phone: 777-8449 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: �,/� 17- kLi L! Plug Integrity ❑ BOP Test 7 Mechanical Integrity Test ❑ Location Clearance ❑ / r Other: * 3006 ,ASS eke /�sf lIn / z5- ' ps " rut.c..-(4-v 5F— Ca.S;r►. .� .14_1; 42, I S00 ,;,. Post Initial Injection MIT Req'd? Yes ❑ No El (t Z Spacing Exception Required? Yes ❑ No 4 Subsequent Form Required: /o-'LI L7 N RBDMS APR 1 7 201 09 APPROVED BY Approved by: /Y COMMISSIONER THE COMMISSION Date:¢/ 3—17 �jS� y�ll f lt /a7�I /2. _/7 ORIGiNAL 44 7 y Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Submit and pp pp Attachments in Duplicate • • RWO—ESP Swap Well: MPU E-22 Hilcorp Alaska,LI) Date:03/22/2017 Well Name: MPU E-22 API Number: 50-029-22567-00 Current Status: SI -Oil Well [ESP] Pad: E-Pad Estimated Start Date: April 22, 2017 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 195-081 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907)947-9533 Second Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228 (M) AFE Number: WeIIEZ Input Required: Yes Current Bottom Hole Pressure: 1,611 psi @ 7,000' TVD (BHP Survey 03/18/17; EMW=4.43 ppg) Maximum Expected BHP: 1,611 psi @ 7,000' TVD (No new perfs being added, but possible C/O) Current Shut-In Tbg Pressure: 380 psi Max. Predicted Surf Pressure: 911 psi (Based on 0.10 psi/ft gas gradient) Brief Well Summary: MPU E-22 was originally completed as a Kuparuk B and C Sand ESP producer in August 1995. The well has been worked over and replaced the ESP 4 times. The failure mechanisms have ranged from scale buildup to mechanical wear on the pump. Early ESP swaps were attributed to physical damage conveying the ESP down through excessive doglegs. The current ESP was installed in November of 2007 and has seen an unusually long run life. The current ESP has experienced downhole electrical failure. Objective: The objective is to utilize the ASR#1 to pull the existing completion, diagnose the failure mechanism and run a new ESP. .1 c�ws;n� p. Brief Procedure: Pre-Rig Procedure: 1. Clear and level pad area in front of well.Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services Pump.Setup reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Forward circulate at least one wellbore(annular)volume with 8.5 ppg sea water down the tubing (thru open GLM pocket @ 13,057' md),taking returns up the annulus to the 500 bbl returns tank. a. Annular volume from GLM @ 13,057'= 395bb1s 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 7. RD Little Red Services Pump and reverse out skid. • 8. RU crane.Set BPV. ND Tree. NU 11" BOPE. RD crane. • 9. NU BOPE house.Spot mud boat. WO Rig Procedure: 10. MIRU Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 11. Pull BPV. Bleed any pressure off tubing and casing. 12. Kill well w/8.5 ppg seawater as needed. Set TWC. • RWO—ESP Swap Well: MPU E-22 Hilcarp Alaska,LI) 0500 Date:03/22/2017 13. Test BOPE to 250 psi Low/3,000 psi High, annular to 250 psi Low/2 006 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hrs in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR rams on 2-7/8"test joint. 14. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr.Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. b. With stack out of the test path,test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking vivo anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 15. Pull TWC. Bleed any pressure off tubing and casing to 500 bbl returns tank. Kill well w/8.5 ppg seawater as needed. 16. MU 2-7/8" landing joint(EUE)and BOLDS. 17. Pull over string weight(landing PU wt=81k during 2007 RWO) on tubing hanger to confirm free. LD tubing hanger. a. Contingency: (If a rolling test was conducted.) i. MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 18. POOH with the ESP completion. a. Note: Carefully inspect the 2 GLM's in this well and confirm that all dummy valves are properly seated. b. Note: Observe for any possible holes in the tubing string. c. Note depth and take samples of any scale or solids deposits found. d. Report any abnormalities to Ops Engineer. + Ick vd 19. MU 7" casing scraper assembly and RIH. Reciprocate w/scraper in 7" 26#casing around -14--4,00A=- MD. 20. POOH with casing scraper. L/D scraper assembly. r 21. MU test packer and RIH on workstring to+/- O0 m !c'� , tA 1' 22. Set test packer and pressure test 7" casing to 1500psi for 30 min (charted). -' �� 23. Unseat test packer and POOH while laying down the workstring. Ca) • 24. RU spoolers, PU RIH with new ESP completion on 2-7/8"tubing. a. Set base of ESP at+/-13,240' (Pump intake around+/-13,190'). b. Lower GLM at+/-13,050' md. c. Upper GLM at+/-150' md. d. Land Tubing. Note PU (Pick Up)and SO (Slack Off)weights on tally. 25. RU Pump Truck. Freeze Protect down back side(+/-58 bbls.to 2,000'). 26. Land tubing in hanger. RILDS. Lay down landing joint. • • RWO—ESP Swap Well: MPU E-22 Ililcorp Alaska,LL) Date:03/22/2017 27. Set BPV.Test tubing hanger to 250/5,000 psi thru test port. 28. RD Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. Post-Rig Procedure: 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. Pull BPV. Set TWC. ND BOPE. 3. NU existing 2-9/16" 5,000#tree.Test tree to 250/5,000 psi. Pull TWC. RD crane. 4. Move 500 bbl returns tank and rig mats to next well location. 5. Replace IA pressure gauge if removed (7"). 6. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Existing Tree/Wellhead 5. FWD Circ to Kill Tank Flow Diagram 6. REV Circ to Kill Tank Flow Diagram 7. Bleed to Pits Flow Diagram 8. Blank RWO Changes Form • • Mime PointMPE-22 Unit We SCHEMATIC Last Completed: 11/25/2007 Hilcom Alaska,LLC PTD: 195-081 Drill Rig:N 22E TREE&WELLHEAD Orig.KB Elev.:53.8'/GL Elev.:24.7' Tree 2-9/16"-SM FMC 11"5M FMC w/2-7/8"Tubing Hanger,EUE lift threads, id i,,-, Wellhead 2 5"CIW H BPV Profile P 20 OPEN HOLE/CEMENT DETAIL ;w 20" Cmt w/250 sx of Arcticset I in 24"Hole 1 s 9-5/8" Cmt w/800 sx PF"E",250 sx Class"G",250 sx PF"E"in 12-1/4"Hole is,*" i 7" Cmt w/300 sx Class"G"in 8-1/2"Hole ris !, CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm BPF it 20" Conductor 91.1/H-40/N/A N/A Surface 112' 0.355 " 9-5/8" Surface 40/L-80/Btc. 8.679 Surface 3,745' 0.0759 9-5/8" .5 7I 7" Production 26/L-80/Btc 6.151 Surface 14,300' 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.347 Surface 13,246' 0.00579 WELL INCLINATION DETAIL KOP @ 500' Max Hole Angle=67 deg.@ 4,600 to TD JEWELRY DETAIL No Depth Item 1 163' STA#2:Camco 2-7/8"x 1"KBMM w/DGLV 2 13,057' STA#1:Camco 2-7/8"x 1"KBMM w/Open Pocket 3 13,136' XN-Nipple: w/2.313" landing Profile(2.205 No-go ID) 4 13,149.6' Discharge Head:FPDIS 5 13,150' Pump#1:PMSXD 1.4(COATED STAGES) 6 13,163' Pump#2:PMSXD 1.4(COATED STAGES) fey 7 13,178' Pump#3: PMSXD 1.4(COATED STAGES) !1" ' 8 13,195' Intake:FPINTAR ee>� 9 13,196' Upper Seal Section:FST3DBHLUT PFS AB HSN ti 1`�2 10 13,203' Lower Seal Section:FST3DBHLLT PFS AB HSN MIN ID=2.205" 11 13,210' Motor-FMH-G:185HP,2,340 volt&53 amps 2 @ 13,136' 12 13,242' Phoenix XT-0 Sensor 13_ 13,244' Centralizer/Bottom @ 13,246' 14 13,687' 7"HES VTL Packer w/4-1/2"XN Lock/Equalizing 0.156 ID 3j 15 13,696' 4-1/2"XN PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 5,6&7 a. Kup.C Sands 13,596' 13,688' 6,963' 6,994' 92 8/4/1995 Open I Kup.B7 Sands 13,708' 13,728' 7,065' 7,074' 20 8/4/1995 Open so e`8 �9&10 GENERAL WELL INFO API:50-029-22567-00-00 isi as a Ilk Drilled and Cased by Nabors 22E -6/29/1995 11 Completed with ESP by Nabors 22E-8/9/1995 p ESP RWO w/4-ES-9/7/1996 ,� ESP RWO w/4-ES-12/27/1996 M. u 12 Set Tubing Patch-7/20/1997 F 13 sx ESP RWO w/4-ES-8/24/2000 i 1 ESP RWO w/4-ES-6/1/2002 V }KUP C Said ESP RWO w/4-ES-11/25/2007 4' 15 }KUP B7 Sand 7„1,4i k 13 14 TD=14,332'(MD)/TD=7,321'(TVD) PBTD=14,254'(MD)/PBTD=7,292'(TVD) Revised By:TDF 3/28/2017 •II Milne Point Unit Well: MP E-22 ' PROPOSED Last Completed: 11/25/2007 Hilcorp Alaska,LLC PTD: 195-081 Drill Rig:N22E TREE&WELLHEAD Orig.KB Elev.:53.8'/GL Elev.:24.7' Tree 2-9/16"-5M FMC 11"5M FMC w/2-7/8"Tubing Hanger,EUE lift threads, k, k Wellhead �, 2.5"CIW H BPV Profile 2D' /(,..« r OPEN HOLE/CEMENT DETAIL i, E 20" Cmt w/250 sx of Arcticset I in 24"Hole t 1 tt 9-5/8" Cmt w/800 sx PF"E",250 sx Class"G",250 sx PF"E"in 12-1/4"Hole +. #,' 7" Cmt w/300 sx Class"G"in 8-1/2"Hole V 4' 1, , CASING DETAIL 74. Size Type Wt/Grade/Conn Drift ID Top Btm BPF i s 20" Conductor 91.1/H-40/N/A N/A Surface 112' 0.355 9-5/8,lalil 9-5/8" Surface 40/L-80/Btc. 8.679 Surface 3,745' 0.0759 7" Production 26/L-80/Btc 6.151 Surface 14,300' 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.347 Surface 13,246' 0.00579 WELL INCLINATION DETAIL KOP @ 500' Max Hole Angle=67 deg.@ 4,600 to TD JEWELRY DETAIL No Depth Item 1 163' STA#2:Camco 2-7/8"x 1"KBMM w/DGLV 2 13,057' STA#1:Camco 2-7/8"x 1"KBMM w/Open Pocket 3 13,136' XN-Nipple: w/2.313" landing Profile(2.205 No-go ID) 4 13,149.6' Discharge Head:FPDIS 5 13,150' Pump#1:SXD H6 6 13,173' Pump#2:SXD H6 7 13,197' Pump#3:SXD H6 8 13,220' Intake:GSTHVV X H6 FER 9 13,225' Upper Seal Section:FSB3DB UT FER SB/SB PFSA 10 13,231' Lower Seal Section:FSB3DB UT FER SB/SB PFSA HL MIN ID 2.205" 11 13,237' Motor-XP-200F:200HP,2,395 volt&59 amps 2 @ 13,136' 12 13,265' WeIILift Type E Sensor 13 13,267' Centralizer/Bottom @ 13,269' t' 14 13,687' 7"HES VTL Packer w/4-1/2"XN Lock/Equalizing 0.156 ID 3*44 II 15 13,696' 4-1/2"XN `"° PERFORATION DETAIL ' • 'v 4 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status ul S5,6&7 a: Kup.C Sands 13,596' 13,688' 6,963' 6,994' 92 8/4/1995 Open 5 Kup.B7 Sands 13,708' 13,728' 7,065' 7,074' 20 8/4/1995 Open 9&10 GENERAL WELL INFO API:50-029-22567-00-00 WeAl d Drilled and Cased by Nabors 22E -6/29/1995 1 t I1111 Completed with ESP by Nabors 22E-8/9/1995 '' ESP RWO w/4-ES-9/7/1996 ESP RWO w/4-ES-12/27/1996 12 Set Tubing Patch-7/20/1997 V 13 i ESP RWO w/4-ES-8/24/2000 %i ESP RWO w/4-ES-6/1/2002 $4 q} KUPCSand ESP RWO w/4-ES-11/25/2007 r ' 'r . gym' ^.14 1;" Ili i 4, 15 }KUP B7 Sand t, +4, 7"All k 13 14 TD=14,332'(MD)/TD=7,321'(TVD) PBTD=14,254'(MD)/PBTD=7,292'(1VD) Revised By:TDF 3/28/2017 • • Milne Point 2016 ASR Rig 1 Knight Oil'Tools 130P llileorp Alaska.EU: Stripping Head ini I Shaffer .i11" - '5000 -.,. tit III III lii tit III Ill t III I I _ ... 2 7/8" -5" VBR *Amp_lip _ '''r.Nao` 11" 000 r - Blind i , *..... _, - 2" I<i I I Line lik_ 2" Choke Line ffe"iik''' ' ills III ill'Iii t_ -- IF'ii - ii''' ) �I ii _ i : E \ ) i ao $?11FilL: �� ) T 1 i _ is t 1111< 1111a.kiRi -� Manual Manual Manual HCR Updated 2/29/16 2 9/16 Otis tree cap 0 11 X 2 7/8 FMC tubing . MPE-22 hanger 2 'A" BPV profile III lir ... 441111IM I II I 111.0 FA& 2 9/16 CM 5M swab g 40 - ,t4 SO valve ; . ill lei 4Z\ \PIP 1I 0 4 ' \ a - „. ) 2 9/16 CIW SM SSV ,, with Baker actuator '..:-;----------:-.--": wompinirm INI PP .,:, ' 2 9/16 CIW 5M 61 ? C, '-: HWO master valve I MI I. ... (0. SI - IIIII ,___ 7E: Iill ..i.-,,„„,......4 • Fit...- ..= ii. . .........„... 13 5/8 3M X 115M FMC Gen mr— 1 4,.), „„. ma —Mil I 4740 ,,,./. ) .4 . 2 1/16 3M HWO 5 tubing spool IL -- --);) • . E 1 ii C--), ; ,...-t valve ,I . Hu - g 1 II I 0 i 13 5/8 3M casing spool leg ima .II: ''',. i • ., , -irNit-- - 11. ) . -- , . -c321 am. 1,,,,.,„\,), .„ 2 1/16 3M HWO . , LE :f i valve ...,. , ir 0., • ...' E t F2 gab S'J -a o a a; c4 Ci 41 I X DIV 0 co ',2' 0 — 0 •13. .?. .2 0P I DID 91) o r• 41 '• F. c., ',, > 0 0 114 4 .. O 0 Lel E 0 2 4: (5` u. .. 'iLL'4 41 P fl; O ..e. .•40:1--HOD4 < 2 co .-3 t.T. > CD 1-- LI z tu 1) ; 6)IT) 17I) 0 C.1.7en 6 0 § CO 04 0 CO 0 C en In 0 8) o a ;A N R .-.a t...) 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W 1- n Q S h 4 K gl6 I • • tt E GL 4' 11 i 1 o A*g vo > U 5."d CA a <I 1 X Z"U m ',2a.' o OIC 9TJ m E u > m a. .. �► , Des--y0� a ' w > m.rd ' 4 a xmZ7 uz 6D In VTD 1 aFL c:11 A m a v �( ( mCO O a m o a SDLA N )11CI C - v k ! C • �p y a -x 0 t u d � y w 1 m u- � c 7-7. -- , 6 444 •h, E. Y .11 11 i...; I- .,",..41g: :"' 1.4 0y J c m IJ 14 CII 401 Q-E -r ‘J ceW � 1- 2 0 � Y z • r$9N Y }j -f J- r Q F, -H- I- U) i-.}- -{.::.}- -14- ---i F- J-— N 6 ar c o � u L = u 0`L • ! STANDARD WELL PROCEDURE Mem")Alaska,1,ii. NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets(formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/02 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 0 0 • I 7/ ID / \ � xx � \ E . . /%' ` ` . . } / \ / /ƒ / m 3 \ / } j)/ \\\ \\\ \ ) Jam § § 2 § e — - : x / Z @ § 5 \ , ) \ / / \ 2 \ \ 1OP} } > ( 3 . a. y /, .. \< / ` \ ) ; x [ ` ^ £ \ ! ® \ _/=( . ..04 «: : 7 ` - NO. .,�4 i Y � .c � p\ i ©. 7;2§£ }' — •:.: Jj .- /ƒ }' :ft #k ƒ ` aaj :. Ili ƒ 0 w ■ p_ . \ O&� , � = a & § c. / \ / 0 § - \ § V I § • • o, a L_ >' .0 0 0 0 c a> eu o .0 Q a) c V yS Ce _ o Uioc U a) 02 0 co a as EL E a _. 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File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS' Scanned by' Bevedy Diann~athan Lowell Is~ [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is/ • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 t ©G l Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPE -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPE -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 mv.._ .t;k • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10.404) MPE -Pad 10/10/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal MPE -02 1851910 50029214170000 3.8 NA 3.8 NA 5.95 8/23/2011 MPE -03 1890170 50029219160000 Tanko conductor NA NA NA NA NA MPE -04 1900050 50029219970000 Tanko conductor NA NA NA NA NA MPE -05 1900810 50029220580000 Sealed conductor NA NA NA NA NA MPE -06 1910480 50029221540000 0.2 NA 0.2 NA 6.8 9/6/2011 MPE -07 1910490 50029221550000 Sealed conductor NA NA NA NA NA MPE -08 1910500 50029221560000 Sealed conductor NA NA NA NA NA MPE-09 1941320 50029225130000 14.0 NA Need top job MPE -10 1941430 50029225210000 0.9 NA 0.9 NA 7.65 8/23/2011 MPE -11 1950010 50029225410000 11.0 NA Need top job MPE -12 2050670 50029232620000 1.0 NA 1.0 NA 4.25 8/23/2011 MPE -1313 2020440 50029225360200 Dust Cover NA NA NA 57.8 9/6/2011 MPE -14 1970050 50029227340000 0.0 NA 0.0 NA 7.65 10/10/2011 MPE -15 1941530 50029225280000 0.8 NA 0.8 NA 8.5 8/26/2011 MPE -16 1961140 50029226860000 0.6 NA 0.6 NA 5.95 8/26/2011 MPE -17 1961150 50029226870000 12.8 NA Need top job MPE -18 1970420 50029227480000 2.3 NA 2.3 NA 17 8/23/2011 MPE -19 1970370 50029227460000 0.1 NA 0.1 NA 7.65 10/10/2011 MPE -20A 2040540 50029225610100 1.0 NA 1.0 NA 6.8 8/23/2011 MPE -21 1981150 50029228940000 3.0 NA 3.0 NA 10.2 8/23/2011 " MPE -22 1950810 50029225670000 0.8 NA 0.8 NA 3.4 8/23/2011 MPE -23 1950940 50029225700000 1.6 NA 1.6 NA 15.3 9/6/2011 MPE -24A 2001860 50029228670100 0.2 NA 0.2 NA 5.1 9/6/2011 MPE -25A 2040450 50029229800100 2.0 NA 2.0 NA 15.3 8/23/2011 MPE -26 2002060 50029229940000 Dust Cover NA NA NA 5.1 9/6/2011 MPE -28 2050550 50029232590000 1.8 NA 1.8 NA 15.3 8/23/2011 MPE -29 2010370 50029230040000 Dust Cover NA NA NA 3.4 9/6/2011 MPE -30A 2010110 50029229030100 0.3 NA 0.3 NA 2.55 8/26/2011 MPE -31 2050720 50029232630000 2.0 NA 2.0 NA 13.6 8/23/2011 MPE -32 2050650 50029232610000 1.5 NA 1.5 NA 13.6 8/23/2011 MPE -33 1981280 50029228980000 4.1 NA 4.1 NA 7.65 8/23/2011 STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSION" REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate isi Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development IO Exploratory ❑ ° 195 -0810 3. Address: P.O. Box 196612 Stratigraphic Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22567 -00 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028231 MPE -22 10. Field /Pool(s): r MILNE POINT FIELD / KUPARUK RIVER OIL POOL 11. Present Well Condition Summary: Total Depth measured 14332 feet Plugs (measured) None feet true vertical 7325.02 feet Junk (measured) None feet Effective Depth measured 14254 feet Packer (measured) 13687 feet true vertical 7292.43 feet (true vertical) 7056 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.1# H-40 32 - 112 32 - 112 Surface 3714' 9- 5/8 "40# L -80 31 - 3745 31 - 3044 5750 3090 Production 14271' 7" 26# L -80 29 - 14300 29 - 7312 7240 5410 Production tt Liner k �sA t � SE r' 2 3 2511: Liner Perforation depth: Measured depth: 0 13596 - 13668 0 13708 - 13728 _ - - True Vertical depth: O 7017.47 - 7047.56 0 7064.27 - 7072.63 - - - Tubing: (size, grade, measured and true vertical depth) 2 -7/8" 6.5# L -80 28 - 13246 28 - 6872 Packers and SSSV (type, measured and true vertical depth) 7" HES VTL PACKER 13687 7056 RECEIVED 12. Stimulation or cement squeeze summary: EP a 2011 Intervals treated (measured): Alaska Oil & Gas Cons. Commission Treatment descriptions including volumes used and final pressure: AnctC1r gQ 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 68 15 1322 210 Subsequent to operation: 62 12 1461 176 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development El ' Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil — 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGO GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: I NA Contact Joe Lastufka Printed Nam oe Last <a Title Petrotechnical Data Technologist Signatu a Phone 564 -4091 Date 9/6/2011 Form 10-404 Revised 10/2010 RBDM$ SEP 13 201 lZ' !I e/ Submit Original Only • MPE-22 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY TIYMTATA 8/7/2011!T/1/0 = 270/240/260. Acid Treatment. Pumped 10bbls diesel, 3bbls 60/40, 22bbls 1 10% DAD acid, 60bbls 'crude down tubing. FWHP's = 270/320/260. Wells support in control of well. FLUIDS PUMPED BBLS 10 DIESEL 22 10% DAD ACID 3 60/40 METH 60 CRUDE 95 TOTAL • • • TREE: 2 9/16" - 5M FMC M P U E 22 ORIG. KB. ELEV = 53.8' (N 22E) WELLHEAD: 11" 5M FMC ORIG. GL. ELEV = 24.7' (N 22E) w/ 2 7/8" FMC Tubing Hanger , EUE RT To Tbg. Spool = 26.3' lift threads, 2.5" CIW H BPV profile /s F� 20" 91.1 ppf, H- 115' 40 Camco 2 -7/8" x 1" 163' sidepocket KBMM GLM KOP @ 500' MAX HOLE Angle 67 Deg. @ 4600' - TD 9 5/8 ", 40 # /ft, , 3745' , L -80 Btrc. 2 7/8" 6.5 ppf, L -80, 8 rd EUE tbg.. ( drift ID = 2.347 ", cap. = 0.00592 bpf) Camco 2 -7/8" x 1" 13,057 13,500'of #1 CEBERSSCable sidepocket KBMM GLM w/ LaSalle cable clamps 2 -7/8" XN nipple 13,136' (ID 2.205 ") 1 OP Triple Pump - PMSXD 1:4 83P22, 91P22, 91P22 13,150' Bolt on Intake, FPINTAR 13,195' Tandem Seal Section ._ Model FST3 DB HLUT /HLLT PFS AB HSN 13,196' Motor, 185 HP, 2340 volt, 13,210' 53 amp, Model FMH -G wi Phoenix XTO w/6 fin Centralizer 13,242' 7" Marker joint (22' long) 13,435' Perforation Summary Ref log: 08/02/95 GR / CCL Note: A Centrilift slim line pump was installed 08/24/00 and 05/29/02 due to SIZE SPF INTERVAL (TVD) severe dog legs at 4365` and 4415' M D " 3.375" 6 13,596'- 13,668 6,963'- 6,994' 3.375" 6 13,708'- 13,728' 7065-7074' 7" HES VTL packer w/ 4 1 /2 "XN Lock/Equalizing 0.156" ID 13,687' 1 s" Choke. Total length is 10.22' Alpha Jet charges @ 60 deg. phasing 4 1(2" XN 13,696' Junk in Hole: 3 cable bands di and 3 flat guards 8/09/95 ORIG. PBTD 14,254' 7" 26ppf, L -80, BTRS 14,300' DATE REV. BY COMMENTS 06/29/95 JBF Drilled and cased MILNE POINT UNIT 12/27/96 M. Linder RWO 4 -ES ESP Change out WELL E - 09/07/96 M. Linder RWO 4 -ES Installed slim line pump API NO: 50 - 029 - 22567 07/20/97 M. Linder Set tubing patch. 08/24/00 JWS RWO 4ES install new pump and choke 06/01/02 B. Hasebe RWO 4 -ES w/ slimline ESP BP EXPLORATION (AK) 11/25/07 REH RWO 4ES ESP Change out STATE OF ALASKA ~ ~' ALASKA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS ~~~ ~ ~~~ ~~~~ 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 195-081 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22567-00-00 ' 7. KB Elevation (ft): 54, 9. Well Name and Number: MPE-22 " 8. Property Designation: 10. Field /Pool(s): ~,; ~ ~~ / ADL 028231 ' Milne Point Unit / Kuparuk River ;~ r~.~ 11. Present well condition summary Total depth: measured 14332 ~ feet true vertical 7325 'feet Plugs (measured) None Effective depth: measured 14254 feet Junk (measured) None true vertical 7292 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 112' 112' 1490 470 Surface 3714' 9-5/8" 3745' 3044' 5750 3090 Intermediate Production 14271' 7" 14300' 7312' 7240 5410 Liner ~~~~~~~E~ JAIL ~ ~ 2008 Perforation Depth MD (ft): 13596' - 13728' Perforation Depth TVD (ft): 7017' - 7073' 2-7/8", 6.5# L-80 13246' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" HES VTL Packer with 4-1/2" XN Lock/Equalizing 13687' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: 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: 0 0 0 840 0 Subsequent to operation: 161 ' 9 1094 250 184 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 "tune Phone 564-4750 Date ~a -0 Sondra Stewman, 564-4750 ,~~~~~ Form 1A-404 Revised 04/2006 Submit Original Only • ~ TREE: 29/16" - 5M FMC WELLHEAD: 11" 5M FMC w/ 2 7/8" FMC Tubing Hanger ,EUE lift threads, 2.5" CIW H BPV profile P ORIG. KB. ELEV = 53.8' (N 22E) ORIG. GL. ELEV = 24.7' (N 22E) RT To Tbg. Spool =26.3' 20" 91.1 ppf, H- 115' 40 ~~ 6 Deg• @ 46 g~ TD 19 5/8", 40#/ft, 3745' L-80 Btrc. 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg.. ( drift ID = 2.347", cap. = 0.00592 bpf ) 113,500' of #1 CEBER SS Cable w/ LaSalle cable clamps Perforation Summary Ref loa: 08/02/95 GR / CCL SIZE SPF INTERVAL (TVD) 3.375" 6 13,596'-13,668 6,963'-6,994' 3.375" 6 13,708'-13,728' 7065'-7074' `Alpha Jet charges @ 60 deg. phasing Junk in Hole: 3 cable bands and 3 flat guards 8/09/95 Camco 2-7/8" x 1" 163' sidepocket KBMM GLM Camco 2-7/8" x 1" 13 057 sidepocket KBMM GLM , 2-7/8° XN nipple 13 136` (ID 2.205") , Triple Pump- PMSXD 1:4 150` 13 83P22, 91 P22, 91 P22 , Bolt on Intake, FPINTAR 13,195' Tandem Seal Section ` Model FST3 DB HLUT/RELY PFS AB HSN 13,196 Motor, 185 HP, 2340 volt, 13 210` 53 amp, Model FMH-G , Phoenix XTO w/6 fin Centralizer 13,242` ' 7" Marker joint (22' long) 13,435` Note: A Centrilift slim line pump was installed 08124/00 and 05129/02 due to severe dog legs at 4365` and 4415' MD. 7" HES VTL packer w14 112"XN Lock/Equalizing 0.156" ID 13,687' Choke. Total length is 10.22' 4 1 /2" XN 13, 696' ORIG. PBTD 14,254' 7" 26ppf, L-80, BTRSI n inn, un/~aiaa uesr unllea ana cases MILNE POINT UNIT 12/27/96 M. Linder RWO 4-ES ESP Change out WELL E-22 09/07/96 M. Linder RWO 4-ES Installed slim line pump API NO: 5- 0-029-22567 07/20/97 M. Linder Set tubing patch. 08/24/00 JWS RWO 4ES install new pump and choke 06/01/02 B. Hasebe RWO 4-ES w/ slimline ESP BP EXPLORATION (AK) 11/25/07 REH RWO 4ES ESP Chan a out • • BP EXPLORATION Page 1 of 3 Operations Summary .Report Legal Weli Name: MPE-22 Common Well Name: MPE-22 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 4ES Date f=rom - To Hours TasK Code NPT 11/20/2007 09:00 - 12:30 3.50 MOB P 12:30 - 16:30 4.00 MOB P 16:30 - 17:00 0.50 MOB P 17:00 - 18:00 1.00 RIGU N WAIT 20:30 - 22:00 I 1.50 RIGU I P 22:00 - 23:00 1.00 RIGU P 23:00 - 00:00 1.00 PULL P 11/21/2007 00:00 - 00:30 0.50 PULL P 00:30 - 02:30 2.00 PULL N WAIT 02:30 - 06:30 I 4.001 PULL I N I WAIT 06:30 - 10:30 I 4.00! KILL I P 10:30 - 11:00 I 0.501 KILL I P 11:00 - 12:00 I 1.001 WHSUR I P 12:00 - 14:30 I 2.501 WHSUR I P 14:30 - 18:00 I 3.501 BOPSUr{P 18:30 - 2$:00 2.501 BOPSU~P Spud Date: Start: 11 /19/2007 End: 11 /25/2007 I Rig Release: 11/25/2007 Rig Number: Phase Description of Operations PRE PJSM Scope & lay down derrick. Rig down rig components. PRE PJSM. Move Rig & all rig components from MPH-08B to MPE-22. MPH pad operator witnessed moving sub off well. PRE MIRU on MP-E-22. Spot sub, pipe shed and pits. PRE Wait on electrician to remove light from adjacent wellhouse. Set up power cord to camp. Unload support equip. PRE Con't to spot in rig sub, pits, & pipe shed. Begin R/U rig. PRE Raise & scope up derrick. R/U 2nd annular valve. R/U lines to pits & rig. ACCEPTED RIG @ 2200 hrs. DECOMP R/U lines to kill well. Spot in tiger tank & R/U lines. DECOMP P/U lubricator. Pressure test to 500 psi, Ok. Pull BPV. DECOMP L/D BPV & lubricator. DECOMP Wait on Vac trucks w/ seawater kill fluid due to trucks being lined up at hot water plant which are hauling water to a cement job on another rig. DECOMP 1st truck arrived @ 02:30 hrs. Take on hot seawater kill fluid. Wait on 2nd truck to 04:30 hrs.Take on additional seawater. Wait on 3rd truck for reason listed above. DECOMP Record wellhead pressures -SITP = 540-psi, SICP = 840-psi, OAP = 250-psi. Bleed tubing pressure off to 240-psi to blow down tank. Start circulating @ 2.0-bpm @ 350-psi. down tubing taking returns to blow down tank through Super Choke and holding 350-psi backpressure on IA. Pumped tubing volume and shut-in IA and bu{Iheaded 75-Bbls. into formation @ 2.0-bpm @ 2100-psi. Shut down pumping. SITP = 100-psi., SICP = 300-psi after 15 minutes. Open Super Choke and start pumping at 2.0-bpm @ 100-psi on tubing. Increased pump rate to 3.5-bpm with tubing pressure at 1080-psi and increasing to 1310-psi while holding 350-psi backpressure on IA through Super Choke. Circulated 490-Bbls. seawater surface to surface and an additional 112-Bbls. until returns were clean seawater. Shut down circulating. ISIP - 90-psi on Tubing, 90-psi on IA and 250-psi on OA. OAP max. psi was 280-psi. Did not bleed OA. Recovered -370-bbls. oil to GC-2 for processing and shipping down the pipeline. DECOMP Monitor well. SITP and SICP fell to 0-psi after 30-minutes. Opened tubing and IA and both on vacuum. DECOMP PJSM. FMC wellhead technician set TWC w/dry rod. Counted 5-1 /2 turns and masured downstroke at 1" to ensure proper thread makeup depth on TWC. Test from above & below w/ 1000 psi. DECOMP ND 2-9/16" 5M production tree. Both the AWV actuator and the SSV actuator are defective. Tree will be replaced. Inspection of tubing hanger lift threads shows that there are bad threads with gaps in some of the threads. A 2-7/8" EUE 8rd. pin XO was screwed in 8 turns by hand and then made up an addtional turn with chain tongs. DECOMP PJSM. Nipple up 13-5/8" 5M BOP stack w/blind-shea rams and 2-7/8" x 5" VBR's. Double valved inner annulus. Torqued all studs to required torque with Sweeney wrench. DECOMP Crew change. Check PVT alarms. Inspect derrick. DECOMP Air out stack & choke manifold. Begin testing ROPE. Looking Printed: 12/4/2007 8:40:30 AM • • BP EXPLORATION`.. Page 2 of 3 Operations Summary Report Legal Well Name: MPE-22 Common Well Name: MPE-22 Spud Date: Event Name: WORKOVER Start: 11/19/2007 End: 11/25/2007 Contractor Name: NABORS ALASKA DRILLING { Rig Release: 11/25/2007 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase 11/21/2007 18:30 - 21:00 2.50 BOPSU P DECOMP 21:00 - 22:00 1.00 BOPSU P DECOMP 22:00 - 00:00 2.00 BOPSU P DECOMP 11/22/2007 00:00 - 01:00 1.00 BOPSU P DECOMP 01:00 - 02:00 1.00 PULL P DECOMP 02:00 - 03:30 1.50 PULL P DECOMP 03:30 - 06:00 2.50 PULL P DECOMP 06:00 - 11:00 5.00 PULL P DECOMP 11:00 - 12:00 1.00 PULL P DECOMP 12:00 - 19:30 7.50 PULL P DECOMP 19:30 - 21:30 2.00 PULL P DECOMP 21:30 - 22:30 1.00 PULL P DECOMP 22:30 - 23:00 0.50 RUNCO RUNCMP 23:00 - 00:00 1.00 RUNCO RUNCMP 11/23/2007 00:00 - 02:00 2.00 RUNCO RUNCMP 02:00 - 05:00 3.00 RUNCO RUNCMP 05:00 - 22:00 17.00 RUNCO WAIT RUNCMP 22:00 - 00:00 2.00 RUNCO RUNCMP 11/24/2007 00:00 - 05:00 5.00 RUNCO RUNCMP 05:00 - 09:15 4.25 RUNCO RUNCMP Description of Operations for leak. TWC appared to be leaking slightly. P/U lubricator & pressure test to 500 psi. Change out TWC w! new TWC. UD lubricator. Pressure test BOPE as per BP/AOGCC requirements. LP 250 psi, HP 3500 psi. Used 2 7/8" test jt. No failures. John Crisp waived witness test. Finsh testing BOPE as per BP/AOGCC requirements. LP 250 psi, HP 3500 psi. Used 2 7/8" test jt. BOP test witnessing waived by John Crisp. P/U lubricator & test same to 500 psi. Pull & UD TWC & lubricator. R1D test equip. P/U & M/U 2-7/8" spear. RIH & spear tubing hanger. BOLDS. P/U & pull free w/ 100K, Wt dropped off to 90K. Pull hanger to floor. Disconnect ESP cable &meg same. Cable bad. Break out spear & L/D same. L/D hanger & R/U circulating head. Break circulation long way, 4 BPM @ 1340 psi. tosses running 18 bbls /hr. Circulated out very small amount to frac sand. Took 28 bbls to fill hole & break circulation. Lost 65-Bbls. during circulation. Pumped total of 450 bbls. POH w/1st stand tubing. String ESP cable over sheave to ESP cable spooler. Cont. POH w/2-7/8" tubing standing in derrick and spooling ESP cable. Recovering Lasalle cable clamps. Maintaining well control w/double steel displacement. Changeout ESP cable spools in spooler. Cont. POH w/2-7/8" tubing standing in derrick and spooling ESP cable. Recovering Lasalle cable clamps. Maintaining well control w/double steel displacement. Crew change. Check PVT alarms. Inspect derrick.Drain, break out & UD ESP. Inspection showed burned motor, intake shaft came apart & was inside of pump. Pump were gritty but free. cable was good. R/D elephant trunk. Clear & clean rig floor. R/U tongs. Check & change spools. Load new ESP, unpact & inspect same. PIU, M/U & service new ESP. M/U & service ESP. Plug in & check connection. ESP BHA: Centralizer, 185-HP Motor, Tandem Seal Section, 91 stg. P22 Pump, 91 stg. P22 Pump, 83 stg. P22 Pump, Discharge Head. Ttl length = 100.49'. Fill hole w/ 26 bbls of seawater. RIH w/ ESP on stands of 2 7/8" tubing. RIH w/ 14 stands. Suspended operations for high winds in derrick. Rig maintenance. Housekeeping. Cleaning and painting. Winds throughout the day steady at >20-mph with gusts to +50-mph. Phase 1 weather conditions with driving conditions at Level 2 on wellpads. Con't to RIH w/ ESP completion. Meg cable & Pump thru pump every 2000' 1.5 BPM @ 1920 psi. changed out 3 Its of tubbing w/ galled & damaged threads. RIH w/ 22 stands. Con't to RIH w/ ESP. Pump thru pump &meg cable every 2000'. 1.5 BPM @ 1920 psi. RIH w/ 81 stands + 1 single. Changed out total of 6 jts. Centrilift technician make reel to reel splice in ESP cable. Printed: 12!4(2007 8:40:30 AM • • BP EXPLORATION` Page 3 of 3 Opera#ions Summary Report Legal Well Name: MPE-22 Common Well Name: MPE-22 Spud Dater Event Name: WORKOVER Start: 11/19/2007 End: 11/25/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/25/2007 Rig Name: NABOBS 4ES Rig Number: Date From - To Hours Task Code NPT Phase I Description of Operations 11/24/2007 09:15 - 09:30 0.25 BUNCO RUNCMP 09:30 - 12:15 2.75 BUNCO WAIT RUNCMP 12:15 - 16:30 4.25 BUNCO RUNCMP 16:30 - 17:00 0.50 BUNCO RUNCMP 17:00 - 18:00 1.00 BUNCO RUNCMP 18:00 - 18:30 0.50 BUNCO RUNCMP 18:30 - 19:30 1.00 BUNCO RUNCMP 19:30 - 20:00 0.50 BUNCO RUNCMP 20:00 - 22:30 2.50 BUNCO RUNCMP 22:30 - 00:00 1.50 BOPSU P RUNCMP 11/25/2007 00:00 - 00:30 0.50 BOPSU P RUNCMP 00:30 - 01:30 1.00 WHSUR P RUNCMP 01:30 - 03:00 1.50 WHSUR P RUNCMP 03:00 - 04:30 1.50 WHSUR P RUNCMP 04:30 - 07:30 3.00 WHSUR P RUNCMP 07:30 - 08:00 0.50 WHSUR P RUNCMP Attempted to continue RIH w/ESP completion. Wind blowing steady at 28-mph with gusts to +43-mph. Unable to move traveling block through derrick safely. Suspended operations until wind speed drops to safe levels. Wind speed currently at 21-30 MPH. Continue RIH w/ESP completion. Pumped 10-Bbls. through pump and megged cable every 2000' while RIH. Used 212 LaSalle Clamps, 2 Flat Guards, 6 Protectolizers. Changed out total of 6 jts. MU 2-7/8" 8rd. landing joint w/TIW valve to tubing hanger. Centrilift technican splice field attachable penetrator connector to ESP cable. Crew change. Check PVT alarms. Inspect derrick. Had dropped object from derrick. A conduit clamp fell -30' from A-leg. Removed 2 additional unused clamps. See IR 2473315 for details. Finished final field splice in ESP cable. Test same. Plug into penetrator in hanger. Land hanger. P!U Wt = 81 K, S/O Wt = 37K. RILDS. Install TWC as per FMC. Attempt to pressure test, no success. Drain stack. Call for lubricator. P/U lubricator & pull TWC. Rubber was rolled. Install new TWC. L/D lubricator. Pressure test plug from above to 1000 psi. Test from below buy pumping down annulus, 3 BPM @ 800 psi. Drain BOP stack N!D choke & kill lines. N/D BOP stack &DSA. Finish N/D BOPE &DSA. N/U Adapter flange & test to 5K as per FMC. Tested, Good. N/U X-mas tree. Fill & test to 5K for 15 min as per FMC. Tested Good. Pad operator Ok'd wellhead orientation and accepted tree and wellhead configuration. P!U lubricator. Test to 500 psi. Pull TWC. Install BPV & test by injection. Pump 3 BPM @ 900 psi for 10 min. L/D lubricator. PJSM. R/U LRS & pressure test lines to 3500 psi.. Freeze protect well by pumping 15 bbls of dead crude down tubing & pumping 65 bbls down annulus. RDMO LRS. Secure cellar. RELEASED RIG AT 0800-HRS. Printed: 12/4/2007 8:40:30 AM 1. Operations performed: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation shutdown r-! Stimulate I"1 Plugging r'l Perforate Pull Tubing r-! Alter Casing I~1 Repair Well I~! Other 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Locat'ion of well at surface 3825' NSL, 2103' WEL, Sec. 25, T13N, R10E, UM At top of productive interval 2456' SNL, 1343' EWL, Sec. 32, T13N, R11E, UM At effective depth 2743' SNL, 1740' EWL, Sec. 32, T13N, R11E, UM At total depth 2784' SNL, 1798' EWL, Sec. 32, T13N, R11 E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Size 14332 feet 7325 feet 14254 feet 7292 feet Length Structural Conductor Surface Intermediate Production Liner Casing 80' 20" 3714' 9 5/8" 14271' 7" 5. Type of well: I~ Development r-I Exploratory r-I Stratigraphic r"l Service Plugs (measured) Junk (measured) Change Out ESP 6. Datum Elevati°'n (DF or KB)' KBE = 54' 7. Unit or Property Name Milne Point Unit 8. Well N~mber MPE-22 9. Permit Number / Approval No. 195-081 .... 10. APl Number 50- 029-22567-00 ..... 11. Field and Pool Milne Point Unit / Kuparuk River Sands Three cable bands and three flat guards (08/95) Cemented MD TVD 250 sx Arcticset (approx) 800 sx PF 'E', 250 sx 'G', 250 sx PF 'E' 300 sx Class 'G' 112' 112' 3745' 3044' 14300' 7312' Perforation depth: measured 13596' - 13668', 13708' - 13728' true vertical 7017' - 7048', 7064' - 7073' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 13241' Packers and SSSV (type and measured depth) 7" HES 'VTL' packer at 13687' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED JUN 0 6,2002 Naska 0il & Gas O0,~s, Anchorage OR 14. OiI-Bbl Prior to well operation: Subsequent to operation: ':! 5'." Attachments I'"1 Copies of Logs and Surveys run I~ Daily Report of Well Operations !~ Oil I"! Gas D Suspended 17. I hereby certify that the foreg.~ing is true and correct to the best of my knowledge Signed Sondra ~ .... ~,,.._ Ti_tie Technical Assistant Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl 16. Status of well classifications as: Form 10-404 Rev. 06/15/88 Casing Pressure Tubing Pressure Service Prepared By Name/Number: $ondra Stewrnan, 564-4750 Submit..in DuPlicate.. .... Legal Well Name' MPE-22 Common Well Name' MPE-22 Spud Date: Event Name: WORKOVER Start: 5/27f2002 End: 5/30/2002 Contractor Name: NABORS Rig Release' 5/30/2002 Rig Name: NABORS 4ES Rig Number: 4ES :D!~b ;i ~d!'~;~6; H~'~ i~~ ~bS~ i~p~ Ph~§b ::-:; :: :i::-: Description of Operations 5/27/2002 - 0.00 5/28/2002 00:00- 02:00 2.00 RIGU P PRE MI/RU & SAFE OUT EQUIPMENT/RIG ACCEPT @ 0200 HRS. 5/28/2002 02:00 - 06:00 4.00 KILL P DECOMP RIG TIGER TANK/TAKE ON SEAWATER/PULL BPV 06:00 - 16:30 10.50 KILL P DECOMP CIRC WELL BORE CLN- OF INFLUX & MONITOR WELL & WELL CONTINUE TO FLOW RE-CIRCULATE WELLBORE & MONITOR WELL CONTINUE TO FLOW CIRCULATE & RAISE WT TO 8.8 PPG. & MONITOR WELL DEAD. 16:30- 17:00 0.50 WHSUR P DECOMP SET TWC. & TEST 17:00- 18:00 1.00 WHSUR P DECOMP NIPPLE DN TREE 18:00 - 19:30 1.50 BOPSUiq P DECOMP NIPPLE UP BOP 19:30 - 20:30 1.00 BOPSUR P DECOMP BODY TEST BOP TO 3500 PSI. & CHOKE MANIFOLD & FUNCTION RAMS & ANNULAR..& KOOMEY TEST. 20'30 - 21:30 1.00 BOPSUR P DECOMP RIG LUBRICATOR & PULL TWC 21'30 - 23:00 1.50 PULL P DECOMP RIG LANDING JT. BOLDS & PULL HANGER TO FLOOR & TEST & LAY DN SAME. 23:00 - 00:00 1.00 PULL P DECOMP POOH WITH ESP COMPLETION 5/29/2002 00:00- 07:30 7.50 PULL P DECOMP CONTINUE TO POOH WITH ESP COMP.. 07:30- 09:30 2.00 PULL P DECOMP LAY DN ESP 09:30- 12:30 3.00 RUNCOI~ ~ COMP MU ESP ASSY. 12:30- 23:30 11.00 RUNCOI~/P COMP RIH WITH ESP COMPLETION. 23:30- 00:00 0.50 RUNCOI~ COMP MAKE UP HANGER @ ESP SETTING DEPTH @13240' 5/30/2002 00:00- 02:30 2.50 RUNCOI~P COMP MAKE EFT CONNECTOR & LAND HANGER & RILDS & TEST SAME 02:30 - 04:00 1.50 BOPSUF; ~ COMP SET TWC & TEST & NIPPLE DN BOP 04:00 - 05:00 1.00 WHSUR ~ COMP NIPPLE UP TREE & TEST TO 5000 PSI. (NOTE: TREE WAS CHANGED OUT WITH A RE-CONDITIONED ) 05:00 - 06'00 1.00 WHSUR ~ COMP PULL TWC & SET BPV & SECURE TREE AREA (RIG RELEASED @ 0600 HRS. 5/30/2002) JUN 0 6 2002. :AJaska Oil & Gas Co~s. Coramissio[~ Anchorage , , , Printed: 6/3f2002 1:01:02 PM 1 c:LO~mld.D°c STATE OF ALASKA " .... ALASKA ~IL AND GAS CONSERVATION COMM,,sSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Ty~_j)e of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. ,]~Development KBE = 54' -Iq'Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 3825' NSL, 2103' WEL, Sec. 25, T13N, R10E, UM MPE-22 At top of productive interval 9. Permit Number / Approval No. 195-081 At 2455' SNL, 1342' EWL, Sec. 32, T13N, R11E, UMeffective depth 0RIGI~IAL 10. APl Number50.029-22567 2742' SNL, 1740' EWL, Sec. 32, T13N, R11E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 2783' SNL, 1797' EWL, Sec. 32, T13N, R11E, UM Sands 12. Present well condition summary Total depth: measured 14332 feet Plugs (measured) true vertical 7325 feet Effective depth: measured 14254 feet Junk (measured) Three cable bands and three flat guards (08/95) true vertical 7292 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 250 sx Arcticset (approx) 112' 112' Surface 3714' 9 5/8" 800 sx PF 'E', 250 sx 'G' 3745' 3044' Intermediate 250 sx PF 'E' Production 14271' 7" 300 sx Class 'G' 14300' 7312' Liner Perforation depth: measured 13596' - 13668', 13708' - 13728' true vertical 7017' - 7048', 7064' - 7073' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 13225' : Packers and SSSV (type and measured depth) 7" HES 'VTL' packer at 13687' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Daily Report of Well Operations [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ,~'~/f~¢ ~/~ Title TechnicalAssistant Date Prepared By Name/Number: Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Duplicate summary Report Legal Well Name: MPE-22 Common Well Name: MPE-22 Spud Date: 6/28/1995 Event Name: WORKOVER Start: 8/21/2000 End' 8/25/2000 Contractor Name: NABORS Rig Release: 8/25/2000 Group: RIG Rig Name: NABORS 4ES Rig Number: 4ES i~I~ Date I' i'~'r°m~'To i~ ~rs-' :ACtivi~ C°de '.i.Ph~ ~ :~: DeScription of Operations 8/21/2000 03:00 - 06:00 3.00 MOB PRE RIG DOWN & PREPARE TO MOVE. 06:00 - 10:00 4.00 MOB PRE MOVE FROM MP PAD F TO MP PAD E. 10:00 - 12:00 2.00 MOB PRE SPOT IN SUBS & HOOK UP SAME. 12:00 - 14:00 2.001RIGU PRE RIG UP ON MPE-22 WELL. ACCEPT RIG @ 1400 HRS 8-21-00. 14:00 - 15:30 1.50 RIGU PRE SPOT IN & HOOK UP TIGER TANK. 15:30 - 18:30 1.00 WHSUR DECOMP P/U LUBRICATOR & PULL BPV. 16:30 - 18:00 1.50 WHSUR DECOMP MAKE UP LINES TO X-MAS TREE. PREPARE TO KILL WELL 18:00 - 19:00 1.00 KILL DECOMP LOAD PITS W/8.4 PPG SEAWATER. 19:00 - 19:30 0.50 KILL DECOMP TEST LINES TO 3500 PSI.. OPEN WELL. SITP 800 PSI. SlOP 870 PSI. 19:30 - 00:00 4.50 KILL DECOMP BLOW DOWN TBG. CIRCULATE WELL 3.5 BPM @ 1500 PSI. W/ SEAWATER M& KILL WELL. 8/22/2000 00:00 - 00:30 0.50 KILL DECOMP OBSERVE WELL. WELL DEAD. HOLE STAYED FULL. 00:30 - 01:00 0.50 BOPSUR DECOMP INSTALL & TEST TVVC. 01:00 - 02:00 1.00 WHSUR DECOMP N/D X-MAS TREE. 02:00 - 04:30 2.50 BOPSUR DECOMP N/U BOPE. 04:30 - 08:00 3.50 BOPSUR DECOMP TEST BOPE. LP 300 PSI, HP 3500 PSI, OK. John Crisp waived : witness of BOP Test 08:00 - 09:00 1.00' BOPSUR DECOMP Rig Lubricator & pull two. 09:00 - 11:00 2.001WHSUR i DECOMP Rig up landing Jt. & Pull Hanger to floor & lay dn same. 11:00 - 00:00 13.00 PULL !DECOMP Pooh Laying dn tbg. 2-7~8" 8~23~2000 00:00 - 01:30 1.50 PULL DECOMP Continue to lay dn esp completion. 01:30 - 13:00 11.50 CLEAN COMP i Rig SWS & run 6.06" OR/JB to 13719' & pulled tight @ 40' on toh & work free. Run # 2 found tight spot @ 1000' pooh & found nothing. Run # 3 tag @ 13718' & pooh & Rec. Rubber & Metal bands. & run No. 4 to I 13718' & pooh & found clean basket. 13:00 - 18:30 5.501RUNCO~ COMP Rig HES Packer on SWS & Baker 20 setting tool & Icg into position & I set @ 13687' pooh & rig dn same. 18:30 - 23:59 5.48 RUNCO~I COMP Mu esp Assy & rih with same on 2-7/8" tbg. picking singles from shed. for a total fo 60 its/@ midnight. Printed: 8/29/2000 2:58:11 PM tiOn; Summa : Re.port Legal Well Name: MPE-22 Common Well Name: MPE-22 Spud Date: 6/28/1995 Event Name: WORKOVER Start: 8/21/2000 End: 8/25/2000 Contractor Name: NABORS Rig Release: 8/25/2000 Group: Rig Name: NABORS 4ES Rig Number: 4ES ~e.~ PhaSe~::~i~ .~, !.- : Description of Operations 8/24/2000 00:00 - 06:00 6.00 RUNCOI~ COMP cont. to rih with esp completion for a total of 194 jts. @ 0600 hrs. and making esp cable splice. 06:00 - 07:30 1.50 RUNCOI~ COMP Splice ESP cable 07:30 - 14:00 6.50 RUNCOr i COMP Continue to RIH with ESP Completion to 12,200' 14:00 - 16:30 2.50 RUNCOr COMP ISplice ESP cable 16:30 - 17:30 1.00 RUNCO~ COMP Continue to TIH with ESP Completion with a total of 418 joints of 2 7~8" 1-80 6.4 ppf tubing 17:30 - 18:00 0.50 RUNCO~4 COMP Make up Tubing hanger 18:00 - 21:30 3.50 RUNCOi~ COMP Make up penetrators, Splice BIW connectoron cable and Test 21:30 - 22:30 1.00 RUNCOI~ COMP Land Hanger and run in Lock Down Screws. Laid down Landing joint. 22:30 - 23:00 0.50 RUNCOI~t COMP Install TWC and test to 2500 psi. 23:00 - 00:00 1.00 RUNCOI~I COMP Service Bridge Crane 8/25/2000 00:00 - 00:30 0.50 RUNCOI~ COMP Service Bridge crane 00:30 - 02:30 2.00 RUNCOI~I COMP Nipple Down BOP and Double Studded adapter flange 02:30 - 04:00 1.50 RUNCOI~I COMP Nipple up tree .Test hanger and tree to 5000 psi. Final Test on Penetrator 04:00 - 06:00 2.00 RUNCOA COMP Pulled TWC and Set BPV. Secured tree and cellar area. Rig released at 06:00 hrs 08-25-00. -: ,,.: . ~ [.' · Printed: 8/29/2000 2:58:11 PM STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown []Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other ESP Exchange 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3825' NSL, 2103' WEL, Sec. 25, T13N, R10E, UM At top of productive interval 2293' SNL, 1288' EWL, Sec. 32, T13N, R11E, UM At effective depth 2652' SNL, 1873' EWL, Sec. 32, T13N, R11E, UM At total depth 2676' SNL, 1912' EWL, Sec. 32, T13N, R11E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 5. Type of well: [] Development [] Exploratory [] Stratigraphic I~ Service 6. Datum Elevation (DF or KBE) KBE = 53' 7. Unit or Property Name Milne Point Unit 8. Well Number MPE-22 9. Permit Number / Approval No. 95-81 10. APl Number 50- 029-22567 11. Field and Pool Milne Point Unit / Kuparuk River Sands 14300' feet 7311' feet 14254' feet 7291' feet Length Size 80' 20" 3714' 9 5/8" Plugs (measured) Junk (measured) Cemented 250 sx Arcticset (approx) 800 sx PF 'E', 250 sx 'G' 14271' 7" 250 sx PF 'E' 300 sx Class 'G' 13596'-13668',13708'-13728' 7017'-7048',7065'-7074' Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80 to 13525' Packers and SSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure MD TVD 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl 112' 112' 3745' 3799' 14300' 7311' 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended ORISlN4L 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Chip Alvord ~ ~__~_ Title Engineering Supervisor Date / Prepared By Name/Number: Mary Youngers 564-5242 Form 10-404 Rev. 06/15/88 Submit In Duplicate (~" Service Tubing Pressure Casing Pressure SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX/ARCO Well Name: MPE-22 Rig Name: N-4ES AFE# 339032 Accept Date: 12/25/96 Spud Date: . Release Date: 12/27/96 DECEMBER 26, 1996 RIG ACCEPTED @ 0730 HRS ON 12/25/96. CONT RU & BERM RIG SCOPE DERRICK. TAKE ON 9.5 PPG NACL, SET, BERM TT, RU LUB & PULL BPV & NU HARD LINES TO TREE (TEST LINES TO 2000 PSI) TUBING 470 PSI ANN 420 PSI CIRC INFLUX OUT W/9.5 PPG NAC THRU CHOKE PUMP 592 BBL DETERMINE WELL TAKING FLUID MIX & PUMP XANVIS PILL. MONITOR TUBING & ANNULUS CONT TO BLOW GAS NO FLUID CONT TO CIRC W/9.5 & CUT TO 9.4 PPG. ND TREE & NU BOP'S & TEST SAME TO 250 LOW & 5000 HIGH TEST WAIVED BY BOBBY FOSTER W/AOGCC RIG LANDING JT & PULL HANGER TO FLOOR & MONITOR WELL TAKING APP 12 BPH POOH W/ESP COMPLETION. DECEMBER 27, 1996 CONT POOH W/ESP COMP & EVALUATE SAME FOUND PUMP LOCKED & INTAKE SHOT (REC HES TOOL STRING). RIG HES SLICK LINE & RIH 5.875" GPJJB TO 13784' (REC RUBBER) & RIG DOWN SAME. MU ESP ASSY & RIH W/SAME. DECEMBER 28, 1996 MAKE SPLICE IN ESP CABLE. CONT TO RIH W/ESP ASSY & MU HANGER & LANDING JT. MU SPLICE IN ESP @ HANGER, LAND TUBING & RILDS. SET TWC & ND BOP, NU BOP, NU TREE, TEST TO 5000 PSI SET BPV. FREEZE PROTECT WELL TO 2000' W/DIESEL BLOW DN LINES & SECURE TREE. RIG RELEASED @ 2400 HRS 12/27/97. Page 1 of 1 F' E R M I T AOGCC Yi'~d'¥v'¥ctua'J We.l J (3 e o i o g 'i c ,:~ '1 I,'i a "~ e r" i a 1 s I n v e n t-. o r' y 0 A T A T D "' F' 95 -'- 08 i 6 ? 59 ~'~ ~ 5 .-- i ~. 338 C D R /,3 D i".,! 'J 0 8/3 I)/" 8 ~:: 9 S - 0 8 I CDR DEF'TI'4 SHIFT · i, .-, o~:.. f) 8 /3 0 / 9 !:ii, 95 .... O.,.~°'i CI.)R DEPTi.-I SHiF'T c.-~<'3000 .... 7300 TVD /~'i2693 '-- i/-~ '163 '1 (I. 8 / 'i 'i/' 9 5 r' e q u "¥ r' e d ? y e s ~ A n d r" e c e 'i '.,/,a d i? y e. s ~C~-- A n a ] y s 'i s &. d e ::', c r" 'i p '! i' o ri r'-~:,, c :; i' ',/~:i: d ".1' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND I,OG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 95-81 3. Address 9. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 5 o- 029-22567 4. Location of well at surface ~1~ ~ 9. Unit or Lease Name 3825' NSL, 2104' WEL, SEC. 25, T13N, RIOE .................~IZA::I~=A'I'~i [~ Milne Point Unit At Top Producing Interval i ¢:~%?, !!'!';'~i'i'I.~-~' ~ ~Z~t-~r~ {!-'1 ~10. Well Number 2373' SNL, 1236' EWL, SEC. 32, T13N, R11E .~ ~ .:~ !! 11. Field and Pool At Total Depth~-~'.5~ ~ .......... .r' i · -~' ~Milne Point/Kuparuk RiverSands ~ ~2772' SNL, ~E,~ EWL, SEC. 32, T13N, R11E 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 53.35' I ADL 028231 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, If offshore 116. No. of Completions 06/10/95 06/24/95 08/04/95I N/A feet MSL ] One 17. TotaIDepth(MD+TVD) 18. PiugBackDepth(MD+TVD 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 14332' MDFF323' TVD 14254' MD/7291' TVD YES [] NO [] N/A feet MD 1800' (Approx.) 22. Type Electric or Other Logs Run GR/RES/NEU/DEN 23. CASING, LINER AND CEMENTING RECORD SEI-I'ING DEPTH MD CASING SIZE VVT. PER FT. GRADE TOP BO'FI'OM HOLE SIZE CEMENTING RECORD AMOUNT PUl LED 20" 91.1# H-40 32' 112' 24" 250 sx Arcticset (Approx.) 9-5/8" 40# L-80 31' 3745' 12-1/4" 8oo sx PF 'E', 250 sx 'G', 250 sx PF 'E' 7" 26# L-80 29' 14300' 8' 1/2" 300 SX Class 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom and ;~5. TUBING RECORD interval, size and number) SIZE DEPTH SET(MD) PACKER SET(MD) 3-3~8"'Gun Diameter, 6 spf 2-7/8", L-80 13554' N/A MD TVD ~_6. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 13596'-13668' 7017'-7048' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 13708'- 13728' 7065'-7074 Freeze protected w/72 bbls diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 08/14/95 ES P Date_of Test Hours Tested I-EST~RODUCTIONPERIOD FORj~ OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Casing Pressure 3ALCULATED ]1~ OiL-BBL GAS-MCF WATER-BBL OIL GRAViTY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Bdef description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. Ot iGINAL.RECEIVED MAY 0 7) 1996 Alaska 0il & Gas Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. (Subsea) Top Kuparuk 13112' 6764' Top C Sand 13568' 6952' Top B Sand 13714' 7013' 31. MST OF A'CI'ACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed -~'~~ Title SeniorDril/ing Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng 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 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: MP E-22 BOROUGH: NORTH SLOPE UNIT: UNKNOWN FIELD: UNKNOWN LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 06/11/95 08:00 SPUD: RELEASE: 08/10/95 09:00 OPERATION: DRLG RIG: NABORS 22E WO/C RIG: NABORS 22E 06/12/95 ( 1) TD: 1432' ( 0) 06/13/95 (2) TD: 2774' (1342) 06/14/95 (3) TD: 2872' ( 98) DRILLING MW: 0.0 VIS: 0 SET FUEL TNKS, FINISH BERMS, HOOK UP WATER, ELECTRICAL AND STEAM LINES. CLEAR LOCATION. TAKE ON WATER AND START MIXING MUD. RU DIVERTER AND INSTALL FLOW LINE. ACCEPT RIG @ 0800 HRS ON 06/11/95. FUNCTION TEST DIVERTER. MU BHA #1. DRILL ICE AND CEMENT FROM 62 - 112'. ORIENT AND TEST MWD. DRILL 12 1/4" HOLE FROM 112 - 1432'. CIRC AND COND MUD MW: 0.0 VIS: 0 DRILL 12 1/4" HOLE FROM 1432 - 2018'. CIRC SWEEP AROUND. SHORT TRIP 15 STANDS. HIT TIGHT SPOT @ 1470 - 1410'. BACK REAM FROM 1400 - 870'. RIH. HIT TIGHT SPOT @ 1468'. WASH AND REAM SLOW 6 STANDS TO BOTTOM. CIRC BOTTOMS UP. INCREASE MUD WT. DRILL 12 1/4" HOLE FROM 2018 - 2396'. MUD BUBBLING OVER ROTARY TABLE. CIRC AND COND MUD. BRING MUD WT UP QP 10.4 IN AND OUT. MONITOR WELL. DRILL F/ 2396 - 2541'. CIRC AND INCREASE WT. MONITOR WELL. DRILL FROM 2541 - 2682'. CIRC AND INCREASE MUD. DRILL FROM 2682 - 2774' MUD CUT TO 9.7 PPG. CIRC AND COND MUD. DRILLING MW: 0.0 VIS: 0 CIRC AND COND MUD. MONITOR WELL. PULL 2 STANDS. TRYING TO PACK OFF. WASH TO BOTTOM. CIRC AND COND MUD. MONITOR WELL. BACK REAM OUT OF HOLE TO 2180' PACKED OFF AND COULD NOT CIRC OR ROTATE. COULD NOT PICK UP OR SLACK OFF. JAR AND WORK PIPE FREE. ROTATE SLOWLY AND BRING PUMP UP SLOW. CIRC AND COND MUD. BACK REAM 15 STANDS OUT OF HOLE TO 800' PULLED LAST TWO STANDS WITHOUT PUMPS OR ROTATING. RIH. HIT TIGHT SPOT @ 2190'. WASH AND REAM 2190 - 2238'. HOLE NOT BEING CLEANED AT THIS RATE. DRILL AND SLIDE FROM 2238 - 2301'. CIRC OUT GAS CUT MUD. VERIFY SIDETRACK @ 2190'. DRILL FROM 2301 - 2872'. CIRC OUT GAS CUT MUD EACH STAND WELL : MP E-22 OPERATION: RIG : NABORS 22E PAGE: 2 06/15/95 ( 4) TD: 3760' ( 888) 06/16/95 (5) TD: 3760' ( 0) 06/17/95 (6) TD: 3760'( 0) SHORT TRIP TO HWT DP MW: 0.0 VIS: 0 CIRCULATE AND CONDTION MUD AT 2874' SHORT TRIP TO HWT DRILL PIPE AT 1060'_ TIGHT HOLE F.'2380 - 1800'. PUMP AND BACK REAM OUT OF HOLE. TAG BRIDGE @ 2400' ON TRIP IN HOLE. COULD NOT GET THROUGH. ORIENT MOTOR AND WASH THROUGH BRIDGE F/ 2450 - 2492'_ CONTINUE WASH TO BOTTOM AT 2872'. CIRCULATE AND CONDITION MUD. GAS CUT MUD. INCREASE MUD WT. DIREDCTIONAL DRILL F. 2872 - 3016' POH FOR WASH OUT. TIGHT HOLE F. 2770 - 2~75'. BACK REAM OUT OF HOLE. NO PROBLEMS ABOVE 2575'. FOUND BIT NOZZLE WASHED OUT AND ALL BUTTON ON INTER ROW OF BIT GONE DUE TO EROSION. MU NEW BIT, RIH. TIGHT HOLE F/ 2650 - 2700'. WORK THROUGH WITH OUT PUMPING. CONTINUE TRIP IN HOLE WITHOUT PROBLEMS. CIRCULATE BOTTOMS UP, NO GAS. DIRECTIONAL DRILL F/ 3016 TO 9 5/8" CASING POINT @ 3760'_ CIRCULATE HOLE CLEAN, CLAY AND SHALE AT SHAKER. MONITOR WELL. SHORT TRIP TO HWT DRILL PIPE. NU CASING SPOOL MW: 0.0 VIS: 0 FINISH SHORT TRIP TO HWT DRILL PIPE. 25 OVER DRAG F/ 2830 - 2770'. CIRCULATE HOLE CLEAN. POH FOR 9 5/8" CASING. SLM. NO CORRECTION. NO HOLE PROBLEMS. LAY DOWN 8" BHA. CLEAR RIG FLOOR. CHANGE BAILS. RIG UP CASING TOOLS. RUN 92 JOINTS 9 5/8" 40# NT-80 BTC CASING, SET @ 3745' -- CIRCULATE AND RECIPROCATE CASING. NO PROBLEMS. TEST LINES. PUMP 75 BBL OF NSCI SPACER MIXED AT 11.5 PPG, CEMENT W/ 800 SX TYPE 'E' MIXED @ 12.0 PPG 309 BBL SLURRY FOLLOWED BY 250 SX CLASS 'G' CEMENT MIXED AT 15.8 PPG 51 BBLS SLURRY, DISPLACED WITH RIG, BUMP PLUG. FLOATS OK, FULL RETURNS. RIG DOWN CEMENT HEAD, CASING TOOLS AND LAY DOWN LANDING JOINT. NIPPLE DOWN DIVERTER SYSTEM. TOP CEMENT JOB WITH 39 BBL TYPE 'E' CEMENT FROM CELLAR WITH GUZZLER. PREPARE TO INSTALL FMC 11" 5000# GEN 5 CASING SPOOL. PU NEW 'G' DRILL PIPE MW: 0.0 VIS: 0 INSTALL 11" 5000# CASING SPOOL AND 11" 5000 X 11" 5000 TUBING SPOOL FMC SEN V SYSTEM. TEST CASING SPOOL SEAL, OK. NU 13 5/8" 5000# BOP STACK. TEST BOPE, TEST ALL RAMS, LINES AND VALVES. TEST HYDRIL. TEST TIW VALVE, IBOP AND TOP DRIVE. RIG DOWN TEST EQUIPMENT, INSTALL LONG WEAR BUSHING. INSTALL BELL NIPPLE AND FLOW LINE. TIGHTEN TURN BUCKLES. SERVICE TOP DRIVE. CONTINUE CLEAN MUD PITS WITH GUZZLER. PICK UP NEW STRING OF 'G' DRILL PIPE. MAKE UP EACH JT, BREAK OUT AND REDOPE, MAKE UP AND STAND BACK IN DERRICK, 140 OUT OF 242 JTS PICKED UP. WILL PICK UP ALL OF NEW DRILL PIPE. WELL : MP E-22 OPERATION: RIG : NABORS 22E PAGE: 3 06/18/95 (7) TD: 4568'( 808) 06/19/95 (8) TD: 6666' (2098) 06/20/95 (9) TD: 7710' (1044) 06/21/95 (10) TD: 9881' (2171) 06/22/95 (11) TD:l1971' (2090) DRILLING MW: 0.0 VIS: 0 CONTINUE PICK UP NEW 'G' DRILL PIPE. MAKE UP AND TORQUE PIPE, BREAK OUT RE-DOPE, MAKE UP AND TORQUE, STAND BACK IN DERRICK. REPAIR IRON ROUGHNECK. FINISH PICKING UP 'G' DRILL PIPE. PICK UP BHA #3, SHALLOW TEST MOTOR AND MWD, OK. RIH WITH BIT %3, TAG FLOAT COLLAR @ 3663'. CIRCULATE BOTTOMS UP @ 3663'. TEST CASING, OK. DRILL FLOAT EQUIP, CEMENT AND 10' NEW FORMATION TO 3770'. CIRCULATE BOTTOMS UP. CASING SHOE @ 37~5'. TEST FORMATION TO LEAK OFF. DIRECTIONAL DRILL F/ '3770 - 4568'. DRILLING MW: 0.0 VIS: 0 DIRECTIONAL DRILL F~ 4568 - 5332' CIRCULATE BOTTOMS UP. SHORT TRIP TO 9 5/8 CASING SHOE ~ 3745'. WELL SWABBING DUE TO BALLED UP STABILIZERS, NOT TIGHT, BACK REAM EVERY OTHER STAND. CIRCULATE AND CONDITION MUD. RIG UP ATLAS WIRELINE. RIH WITH GYRO SURVEY TO 5000', SURVEY @ 30' STATIONS 5000' TO 4100', 100' STATIONS 4100' TO SURFACE. RIG DOWN ATLAS. BREAK CIRCULATION. PRECAUTIONARY REAM 5242' TO BTN @ 5331'. DIRECTIONAL DRILL 5332 - 6666'. RIH WITH TURBINE MW: 0.0 VIS: 0 DIRECTIONAL DRILL 6666 - 6910'. CIRCUALTE WHILE CHANGE SWAB ON PUMP #2. DIRECTIONAL DRILL 6910 - 7710'. CIRCULATE BOTTOMS UP. CONTINUE CIRCULATE WHILE DRECO SERVICE HAND INSPECTS DERRICK. MONITOR WELL, OK. PUMP SLUG, POH. WELL SWABBING 6848 - 4900'. BACK REAM EVERY OTHER STAND. CIRCULATE IN 9 5/8" CASING. MIX SLUG. MONITOR WELL, OK. CONTINUE POH, LAY DOWN BHA, DOWN LOAD LWD TOOL. CHANGE OUT IRON ROUGHNECK SPINNERS. SERVICE WEAR BUSHING. PU BHA #4, LOAD CDN SOURCE, SHALLOW TEST, RIH. DRILLING MW: 0.0 VIS: 0 CONTINUE RIH TO 9 5/8" CASING SHOE @ 3745'. BREAK CIRCULATION. SERVICE TOP DRIVE. REPLACE AIR HOSE, SLIP AND CUT DRILLING LINE. CONTINUE RIH. MWD CHECK SHOT @ 4760' TAG BRIDGE @ 5318'. WASH THRU BRIDGE F/ 5318 - 5340' TIGHT HOLE F/ 6570 - 7200'. PRECAUTIONARY REAM 90' TO BTM. DIRECTIONAL DRILL WITH 2-STAGE TURBINE F/ 7710 TO 9881'. DRILLING DIRECTIONAL DRILL F/ 9881 - 11971' MW: 0.0 VIS: 0 06/23/95 (12) TD:13293' (1322) DRILLING MW% 0.0 VIS: 0 DIRECTIONAL DRILL F/ 11971 - 12950'. CIRCULATE BOTTOMS UP. 15 STAND SHORT F/ 12950 - 11600'. TIGHT HOLE F/ 12100 - 11900'. WORK THRU TIGHT SPOT. NO PROBLEMS AFTER WORKING PIPE. DIRECTIONAL DRILL F/ 12950 - 13293' WELL : MP E-22 OPERATION: RIG : NABORS 22E PAGE: 4 06/24/95 (13) TD:13883' ( 590) 06/25/95 (14) TD:14332' ( 449) 06/26/95 (15) TD:14332' ( 0) 06/27/95 (16) TD:14332' ( 0) 06/28/95 (17) TD:14332' ( 0) DRILLING MW: 0.0 VIS: 0 DIRECTIONAL DRILL F/ 13293 - 13620' CIRCULATE WHILE CHANGE LINER AND SWAB IN PUMP #1. DRILL F/ 13620 - 13883'. SHORT TRIP TO CASING SHOE MW: 0.0 VIS: 0 CIRCULATE WHILE CHANGE LINER AND SWAB PUMP #1. DRILL F/ 13883 - 13941' CIRCULATE WHILE CHANGE LINER AND SWAB PUMP #1. DRILL F. ~3941 -.~4144'. WEAR PLATE ON #1 PUMP WASHED OUT. CIRCULATE BOTTOMS UP AND SHORT TRIP F/ 14144 - 14332'. CIRCULATE HOLE CLEAN. MONITOR WELL, PUMP SLUG. SHORT TRIP TO 9 5/8" CASING SHOE. TIGHT F/ 9520 - 8183'. BACK REAM CLAY SECTION F/ 5600 - 5400'. POH MW: 0.0 VIS: 0 CONTINUE BACK REAM CLAY SECTION. POH TO CASING SHOE @ 3745'. CIRCULATE BOTTOMS UP. MONITOR WELL, OK. SLIP AND CUT DRLG LINE. CHANGE OUT TOP DRIVE SAVER SUB AND SERVICE RIG. 2ND SHORT TRIP TO 5800' THROUGH CLAY SECTION. POH TO CASING SHOE. MONITOR WELL, OK. NO PROBLEMS. RIH TO 14241'. FILL PIPE EVERY 25 STANDS. NO PROBLEMS. BREAK CIRCULATION. PRECAUTIONARY REAM LAST STAND TO BTM @ 14332'. FULL RETURNS. RETURNS STARTED DECREASING. SLOWED PUMP RATE, RETURNS CONTINUE TO DECREASE. MONITOR WELL. ANNULUS FULL AND NOT FALLING. POH. FLOW UP DRILL PIPE, FLOAT LEAKING, WELL SWABBING. PUMP AND BACK REAM OUT OF HOLE. PUMP OUT OF HOLE 25 STANDS WITH NO RETURNS. REAM W/ HOLE OPENER MW: 0.0 VIS: 0 CONTINUE PUMP OUT OF HOLE WITH NO RETURNS. REGAIN CIRCULATION @ 3800'. PULL INTO CASING @ 3745' CIRCULATE AND CONDITION MUD. MONITOR WELL, OK. POH. DOWN LOAD LWD TOOLS. L/D LWD AND TURBINE. M/U BHA #5 AND 8.5" HOLE OPENER. RIH TO CASING SHOE @ 3745' CIRCULATE AND CONDITION MUD. STAGE IN HOLE. CIRCULATE AND CONDITION MUD AFTER EACH 15 STAND STAGE. CIRCULATE THICK MUD OUT OF HOLE. REAM 13181' TO BTM. REAMING @ 13466'. MW: 0.0 VIS: 0 REAM T/BTTM. CIRC & COND MUD. MONITOR WELL -OK. POOH. LD DC'S. PULL WEAR BUSHING TEST BONNET SEAL T/1500. RU CASG TOOLS. REPAIR STABBING BOARD ELEC. CABLE. RIH W/7" 26# L-80 BTC CASG. WELL : MP E-22 OPERATION: RIG : NABORS 22E PAGE: 5 06/29/95 (18) TD:14332' ( 0) 06/30/95 ( 19') TD:14332 PB: 7368 07/30/95 (20) TD:14332 PB: 7368 07/31/95 (21) TD:14332 PB: 7368 08/01/95 (22) TD:14300 PB:14254 08/02/95 (23) TD:14300 PB:14254 ND BOPE MW: 0.0 VIS: 0 RAN CASG T/14300. CBU. PUMPED 350 BBLS & LOST 200. TEST LINES T/3500. PUMP 300 SX OF CL G. FOLLOW W/300 BBLS H20 W/HOWCO. & 243 BBS W/RIG PUMPS. BUMP PLUG T/1800. FLOATS HEALD. LOST 280 BBLS. OPEN ES CMTER. W/3300 PSI & CIRC CASG VOL 810 BPM W/750 PSI. NO LOSSES. PUMP 2ND STAGE. 70 BBLS SPACER. 310 SX CL. G 815.8 PPG. DISPLACE W/80 BBLSDIESEL & 291 BBLS H20. BUMP PLL~G T/3500. FLTS HELD. NO LOSSES.RD CMT HEAD. INSTALL PACKOFF' -- TEST T/300. INSTALL 2-WAY. RIH W/HNGR. TEST T/5000. CHANGE TOP RAMS T/5" & ND BOPE. RELEASE RIG MW: 0.0 FINISH N/D BOPE. N/U ADAPTOR FLANGE AND 2 - 9/16" 5M TREE. TEST TREE, OK. TWO WAY CHECK LEFT IN TUBING HANGER. CUT AND SLIP DRILL LINE. REPAIR DEAD MAN BACK NUTS. L/D 5" DP AND CLEAN MUD PITS. FREEZE PROTECT MP E-22 WITH 75 BBLS DIESEL. ALSO FREEZE PROTECT MP E-13 WITH 120 BBLS DIESEL. BLOW DOWN LINES AND PREPARE TO MOVE RIG. RELEASE RIG 8 2300 HRS ON 06/29/95. MIRU MW: 0.0 SCOPE DOWN DERRICK. MOVE RIG FROM E-13 TO E-22. ND TREE & ADAPTER FLANGE. NU BOPE. SET TEST PLUG. ACCEPT RIG 8 0001 HRS. 7/30/95. WASH & ROTATE CMT. F/7625-89' MW: 0.0 FINISH RU & TEST BOPE TO 250/5000 PSI. ANNULAR TO 250/3000 PSI. WITNESSING WAIVED BY JERRY SPAULDING -AOGCC FIELD INSPECTOR. D4 DRILL. LOAD PIPE SHED W/BHA. SLM & DRIFT. MU BHA #1 RIH ON 3.5" DP TO 2000'. CONTINUE PU DP & RIH TO 7580'. TAG CEMENT. MILL CEMENT F/7580'-7622'. MILL ES CEMENTER F/7622'-25'. WASH & ROTATE CEMENT F/7625'-89'. PREP TO PUMP BREAKER MW: 0.0 CLEAN OUT CEMENT AND STRINGERS F/7689-8095'_ CBU. CONTINUE PU DP & RIH TO 14150. CBU 8 4BPM W/1350 PSI. REV. CIRC. SHUT DOWN & CLEAN PIT #1. DISPLACE WELL W/FILTERED 9.7# BRINE. PREP TO PUMP BREAKER SWEEP. CIRC, FILTER, & COND. BRINE MW: 0.0 CONT TO CIRC. 8 6 BPM. TEST CASG. TO 3500 PSI. PULL STDS TO CK EXTENT OF POLYMER COATING ON PIPE.STILL COVERED. RIH. POH TO 12275'. CBU. POH, LD & CLEAN BOOT BASKETS. MU BHA #2. START RIH. FINISH RIH TO 14150. REVERSE CIRC. FILTER PIT TO PIT. WELL : MP E-22 OPERATION: RIG : NABORS 22E PAGE: 6 08/03/95 (24) TD:14300 PB:14254 08/04/95 (25) TD:14300 PB:14254 08/05/95 (26) TD:14300 PB:14254 08/06/95 (27) TD:14300 PB:14254 RIH W/GUNS. MW: 0.0 REV. CIRC. @ 5BPM W/2100 PSI WHILE HEATING & FILTERING FLUID. START POOH. REPAIR AIRLINE ON HI-DRUM CLUTCH. POOH. RU ATLAS. RIH W/GR/CCL T/14164. LOG F/14163 T/12893. RD ATLAS. MU TCP GUNS & RIH W/GUNS & TEST STRING ON 3.5" DP. POOH W/TEST STRING MW: 0.0 DRIFT 3.5" DP T/il200'. CHECK FAS FILL VALVE. FILL DP. FINISH RIH T/13725. RU WL RIH W/GR/CCL. CORRELATE & POOH. PU DP PUP & SPACE OUT GUNS. SET PACKER @ 13462. RU T/TEST MANIFOLD. ATTEMPT T/SHOOT FLUID LEVEL IN DP. SONOLOG SOUNDER NOT WORKING PROPERLY. TEST ALL SURF. LINES & VALVES T/3500PSI. OK. PRESS ANNUL. T/2100 PSI. T/FIRE GUNS. PERF'D W/ATLAS 3-3/8" ALPHA JET @ 6 SPF F/13596 T/13668 & 13708 T/13728. FLOW WELL T/TEST SEPARATOR ON 1/4" CHK. SHUT WELL IN & MONITOR SURF PRESS F/1.5 HRS. PRESS F/0 T/225PSI. OPEN UP & BLED OFF. BULLHEAD 42 BBLS OF BRINE DOWN THE TBG @ 1 BPM W/2300PSI. MONITOR THE WELL -STATIC. PRESS UP ANNUL T/3200PSI T/OPEN CIRC VALVE. BLED OFF PRESS. CIRC DOWN DP W/RETURNS THRU CHK & GAS BUSTER @ 2BPM W/450PSI. MONITOR WELL -STATIC. RELEASE PKR W/200K. BULLHEAD 50 BBLS OF BRINE DOWN ANNULUS @ 1.5 BPM W/2100PSI. MONITOR WELL F/30 MIN & ALLOW RUBBERS T/RELAX. FLUID LOSS @ 2 BPH. START POOH W/TEST STING. LD DP MW: 0.0 CONTINUE POH W/TEST STRING. FINISH POH W/TEST STRING. STRAP & MU BHA, RIH TO 14,150'. D1 DRILL; REVERSE CIRC. START LD DP. RUNNING 2 7/8" ESP COMP. MW: 0.0 SERVICE RIG. FINISH LD DP & BHA. RU TO RUN ESP COMPLETION. PU & TEST ESP. RUNNING 2 7/8" COMPLETION. 08/07/95 (28) TD:14300 PB:14254 08/08/95 (29) TD:14300 PB:14254 RIH W/6" GR/JB ON SLICKLINE MW: 0.0 SERVICE RIG. CONTINUE RIH W/ 2 7/8" COMPLETION. TESTING CABLE. POH W/ 2 7/8" COMPLETION. ND FLOWLINE & RISER. NU PERFORATING FLANGE. WO CAMCO UNIT & 7" LUBRICATOR. RU LUBRICATOR. RERUN TO 4222'. POH RECOVERED 4 BANDS. RERUN TO 5844'. POH. RECOVERED 5 BANDS. RERUN TOOLS. RU ATLAS WIRELINE MW: 0.0 POH W/6" GR/JB FROM 6330'_ RERUN #5 TO 7107'. RERUN #6 TO 13638'_ RERUN #7 TO 13600'. RERUN #8 TO 13600'. RERUN #9 TO 13600'. RU ATLAS WIRELINE. RECEIVED MAY 0 ~ 1996 Alaska Oil & Gas Cons. Commission Anchorage WELL : MP E-22 OPERATION: RIG : NABORS 22E PAGE: 7 08/09/95 (30) TD:14300 PB:14254 08/10/95 (31) TD:14300 PB:14254 08/11/95 (32) TD:14300 PB:14254 RUN COMPLETION MW: 0.0 RIH W/GYRO T/13500. LOG OUT. RD ATLAS. ND PER FLANGE. NU RISER & FLOWLINE. INSTALL TEST PLUG. TEST BOPE T/250/5000 PSI. ANNUL T/250/3000PSI. OK. WITNESSING WAIVED BY JERRY HERRING W/AOGCC. PULL TEST PLUG. RU T/RUN 2-7/8 ESP COMPLETION. PU & TEST EST. RUNNING COMPLETION F/3000 T/6000. FREEZE PROTECT ~ MW: 0.0 RIH W/ESP COMPLETION. T/13554. MU HAGR & SPLICE ESP. LAND TBG & LD LNDG JT. NU T/TEST ADPT. FLNG & TREE T/5000. PULL 2 WAY CHK. REPAIR ELECTRICAL MUD PUMP & FREEZE PROTECT THE WELL W/DIESEL. RIG RELEASED MW: 0.0 FREEZE PROTECT WELL W/62 BBLS DIESEL IN ANNUL & 10 BBLS DOWN TBG. SECURE TREE & RELEASE RIG @09:00 ON 8/10/95. SIGNATURE: ( rilling srrintendent) DATE: CO~PA~:" BF' WELL NAME MF'E-22 : qr"~;nu i MnMt. POINT LOCATION 2 AL~XA MAGNETIC D~L!NATiON 28.?? ~RID CONVERGENCE ANGLE 0.00 9ATE: 11-dqJt-?5 WELL NUMBER 0 APi~ 50-029-2~67-00 AZIMUTH FROM "'~^~'~u~,~ 'TABLE To_ TawG~T,,,,. ~. IS ;.,~ IN POINT(TIP) TRUE ~RT DEF'~ i12,00 iNCLiNATION ~nu~n 0,00 ~XqT ITUDE (N/-S) O, 126.32 ...... c:.'-.L. ~ tut! f~ f~ ft' ii',2~00 ,,,vt' r, i!2~00 ~00200 ~8~0 '..200,00 -O~Ol 300~00 i00,0 300,00 -r~ 400~00 i00~.0 400+00 -02S2 5:30,00 iO0,0 500, O0 -0740 700~00 lOO,O 699~96 2~% i100,00 '^~ ^ ~^o~ M ~ 1~r~.O0 1~.n 1i77,56 ~L o~ ~^~ ~'~' i00,0 i393,t5 ~ ~.=v 00,56 ~=r,A n^ ...... m', a7 1!3,92 !600,00 i00~0 lSA~.')~ ~ =' !700~00 !00,0 '~,.,,~,~ ~ t80,78 ~O0.Afi ~ ..... ~ -,~, -~.~a ,~,5 l~ov,~z 263 ~900,00 !00,0 ..... ~ 2100,00 I00,0 2033~16 363,76 ~2~ ~n ~a-, ~ 21!6,ch 419~7~ 2300,00 !00,0 2i96,73 478,68 2700,00 200~0 2494,93 744,02 2900,00 i00,0 26~2,43 896,02 3000,00 !00,0 2684,i0 976,74 3100/o0 I00~0 2742,77 1057,69 3200,00 3500,00 3600,00 iO0,O 2797,23 1!41,54 100,0 2~94,08 !3!6,% ~..~,. ~ ~_ ~.....~ tOO,O 3064,~i !677~97 ~+v 3i06,59 !768,/~ 0170+0'4 .... ,O0 3700&0 4000,00 4100,00 I'~'" H/-S deo d. eo ft 0,00 0,00 0,00 O,ii 20+73 0,08 0,21 i5~06 0~57 0,30 34~30 0,?7 =,=F~.r,:JE-~ '::_:ISF%ACEMEHT ;.',.t AZIMU?H -Y ~+ ft d. eq O: O0 :".: ~ 00 O, Or..... 0,03 0/,':8 lO A. :-'...--' r., ".,o · .. ~ .a ;.. '.d.; :-' ~ - 0,01 0,57 0,22 '--,~"' o.-.,, 12,79 DLS lOOft 0,00 0~13 0,12 0,12 i,96 !06,52 O,'c'.., , .z, .....: _':c. :-::,63 77,03 1,i2 _ _ q. -:.'r--: 1to =.,~ -0+75 7,91 -, ................. '+:-' 95,48 1,235 a.a. ~ t ~.-.~ -._':.OY - . +'.-'-' £ ~+/-: "' · 5,F:~ i!3265 -6274 22,27 ~3,4.2, 107,23. 0,62 6,8i , ,_-,, ,_,:i'~- .=c, -ii ,26 32,03 ..... :.:..._ :_-.."= 107..-37 !,48 · ,r, .-- !1,:..,,37 17,.-'?::., ~ A?.. 9 C, ,~; . . : -7_, i '--'-" · -' ;u,v/ .... - 26,51 [ll,7A ._,,._,4 !?,?; 127247 082i26 61~i3 ..-.. == ,~=. ?r., 2,7'2 ~-Q' ,l~ ,.v.,, -.- -~2'-- -.-Q O7- ,_-72'-','~/4.7 .... :-. ,',~ :'.-,'.5 , .z~ , ...,._., i18,!7 1,16 I =, ,'.:..-'3 ~¢7,14 =: =:, : ...... ..... -_.,, :_,..- '.'.-.".'.-', 1 i 1 i A .?'.-., -i ?h.. lO .- t9,78 ~ ........ --",¢ I;'-'.,79 i i=-. ,'.:7: i,':-'!,58 4,,05 _ .. -'.."' C': O"f -/C, ~ v..w .......... o.'", or; ~'?¢.,.77-: -9S:17 i9'?~'.---".: '~';'~ *'~ !22,52 2,4? 23 ~'.'.-.'2i2g..,54 -!22,67 ia.2, ,.-,':'-'" ........... ." ,'L.', ..-'., ,.,.o"s'~, ,..._,':':: 1,62 c,7 ",., .~.-_,o .--.:, -14':,',':" .,,, ,,.,-.. ..... , ,., ,../ +/L zl.'-_:,i: ,..-., -" i,., ,:..,'-' .'"',~,O ~..'"-"..C i.' 8.,.,7,~ .... ...... ir-.', ;,~ 2, Ut) .-..'u,v..-':ca ..:...:: -160,10 '--= .... Eli.Ar'. ~-q ~.r~ -' 36,99 !25,87 -zss,z~ ..... 355,!5 478,68 '~ *" .. ~Q~V i£.~,i£ ..... ~ ...... ''' -- ~r, ~ !28,~o _~o~ ~ 652,*?. "'"'.. .~,,a'>6.4~:, .~ !27,26 2~46 99,71 .... i27,'qn -592,0g .... ///,~,:~ o7~,...,,~a 127,3i. 1,57 ~9,4~ i27~04 %4i,00 ~a~,53 ~r,~= a~ t27,30 2,73 ~ =7 !27 ~" -671,7~ 6i.46 ~" ~ -7~.~o 62,63 i25.48 -796,20 .... " 124,29 -g47,18 00,£7 ........ A~. ?s 74,71 -gqg .~ ~ ~ ..... ?08,26 1i4t~70 ~,~, 977 ....... ~ 1046,60 ...... ~ !Z7, 1121,58 i405,58 '"~.,, 07 ~175,74 1475,54 126,91 ._.-,, 16 I i,i2 '1,08 ..,_:- ,,..,., 125,03 -!003,06 A4,7i !24,42 z~' == '": '"'" -i107,15 ,.,O,.J 2 iLO,/ ~ . -- :'"' :'=' i28205 ~o~s ~, 1678,0t 126,71 ~ ~ 14i9,~7 1768,80 126,61 1,30 1~,.,,~o 2,3? 1564,63 1948,85 126,60 !,?1 ME~SUR'~ iNTerVAL VERTICAL DEPTH g£P?H 4130.00 30.0 3206.12 4160.00 30.0 32!8.41 4!90.00 30.0 3230.65 4220.00 30.0 3242.?6 4250.00 30.0 3255.30 43i0.00 4340.00 4370.00 4400.00 446:0.00 4485.00 4640.00 4670.00 4862.0i 495~.12 5053.68 5149.26 5242.63 5338,76 5626.24 5816,63 59i2,72 6198~04 A~7g,73 6453,20 30.0 3267,77 3~,0 3280.41 30.0 '3'29'3,2! 30.0 3306.il SURVEY CALCULATIONS ~,~***~ CIRCULAR ARC METF~D****~*** TARGET STAT!CkN AZI~]TH LATITUDE .... .. -.-~ .." . .... c,~ 12,46 -1177.60 wcp ~ 65,95 124.05 -1192.61 2030,78 .~s ~. 126.62 -~n~ ,~ -_-~ ~O! m~w~ 2085,48 65,73 !~,78 -!240.63 2ii2.77 65.16 !24,93 -1256,42 zzo.°,96 o>'".00 123,75 -t271.77 2!94,17 -~ ~ 126,20 .or~ .o ~21 ~31 65.04 ~o-~-' 30,0 30~0 3343,70 2Z75/K) 65~82 ~J*v JoJO~ 7J 30,0 3380,71 ~a:~.~:~j,.,_ AS,54._ 30~0 3434~?0 24!2,8! 66.92 30,0 34i6.6! 2440,43 67~15 95.8 3466.38 ~=~:.84 '~ o~ ......... .......... ~,¢,,0~ ,..~,~ 3582,61 2819.0~ AA,30 o~i i4 ?;.ng,~n M,05 ~'= 96,i o~07,nn 3079.~." M.37 95,7 3772.71 3255,27 66,8! =o,v 38t0.61 ~a~ ~= .... MPE-22 Dm, ~',TUR~. DISPD~EMDIT at ft ft I~ ~ !976,09 1609,76 2003.41 1632,1! 2030.79 1654.17 2058,15 1676.34 2085.50 AZIMUTH 12~. 126 126.50 ~L O 1698,^0. 2112 ..x° .o lz..,.4, 1721,06 2139.96 126.46 1743.15 2167&? 126.45 t764.87 2!94,17 126,45 1787,05 2221,31 126.44 l~..Jo -1oo4,.o !809,54 2248.~. l~ ~? -i350.30 1832,06 2275.90 124,07 -~o.~.17 1850.88 2298,69 125,45 - i331.37 1877,09 ~n,59~ !~,75 -1397.27 1299,31 ~57,92 , 125.50 -.4~,~2 192!,57 2365.~?'"" ~-.= =. iac~ ~ !,4~,97 2412,81 -!4~.~6 !966.45 125,48 ~= o 2440,43 l~.,~, -14~h.92 1989,20 2468,04 123,40 -1509,47 2~52,48 2555,84 i22,98 -1557,74 2136,27 2643,90 123,19 ',~...,*~0~ ~ 22(Y?,93 273!,69. 122,56 -1653,24 ~83,42 2819.08 123,~n i700.56 1~,17 -!746.67 2428,74 25.°91,59 i23,66 -1794,56 2502,73 3079,63 125,42 -1844,42 2575,16 3167,54 124,!4 -!894.62 2647,44 3255,53 124,14 -!90l,C~? ~20,40 2~43,66 I25,21 -19~.30 279i,54 3430,15 · o9~ 74 ,17 65,91 i25.33 -?0°5-~ 95,9 3966~31 3692,53 65.35 !26,05 -2!46,25 4.0 4044.42 3665,08 66,35 aSA,A9 ~-,a, ~ t26,41 126,37 126 '= 126,34 126.33 ~L qq 126.31 126,29 !26.20 128,10 12~,Of) 125.91 125.81 125.72 94.2 408i,59 3951,67 c,,'-",,,;° i'Z7,16 -'.;S0i,26 p.,q,q i~.,= ,r, m.'~3!,% 67,i9 IS'7,16 -?.q49,40 i04,5 .,.,=, ,, ,.~.~,=.-., ,':.,r,: 66,!7 -.:. ,,,-,., .,- A= ~,.~ ~.-'~ o',. -2460,76 r,:' .", · .... ~.,".;,1 ~;.-','v'£'t""*"' '-':'- .~,~,,L,,-'_'.. '; '5-" Q'%,--" ~lo"'r .-, ,..~._.,,t.", .."...' ~. O4~,Ja}. -~ ~ -2'-"' -- .... · -' ' '-"P-': 125,64 125,61 1Z5,59 125,55 125,53 2863,01 3517,97 125,53 2934.20 3.505,52 i25,53 3005.15 3692,87 125.53 3074,66 3779.20 125.55 3143,70 3865.40 125,58 o~li,=~° 3951,97 125.61 o27~.R4 ~31,64 125,64 3421.78 4_14,/a 125.72 3490,86 %01,56 1:0./, DLS lOOft !7.05 4,97 7.33 0,29 3,20 3,61 10.51 2.99 6.05 2.35 0,54 2.19 3.60 1.07 2.33 2.40 0.79 0,62 O.q3 0.71 0.77 0.56 1,08 1.44 1,76 1 0,i4 ! ,05 1,36 0.72 0,90 0.65 0,98 0,93 0.03 1,00 0,60 0¢?6 r.~u~ NO. 7340,~¢v 7435,33 75i4,18 7690+44 7786,05 7881,0.3 7976,31 807i ~ 8157 *~ .... 8452.78 8644~29 8738,85 883!+7~ 9023+i! 9595,~9 9690,52 97~5,51 9880,?8 9976,36 !0072+&4 i0356,5'i 10453,44 o= ; 4497,o? 96,O 4572,40 95,6 4673,43 95,0 47ii~i3 o~.~o 4749,41 95,2 4788,13 '~,9 4827,i0 94,7 4865+39 94,9 4942,06 96,2 4980,89 95,3 50!8,82 94,6 5056,04 96+6 5i30,67 94,7 5i67,50 95,3 5204,63 95~0 5354,83 95,0 5470,24 95,4 5548,0i 96~5 ==~ =~ 9~,6 94,7 ...... 93,4 s7o~+0! TARGET STATION AZIMUTH :a,:,::u='~TiT'Z~ SECTION :[~Z~ ~m,, ~: N/-S ft de~. : deg ., 4387,Y& 66,2i 125.'78 -2~A4,71 4473,61 67,08 ~",!8~: -2615,99 ~oou~=" oo 67,i7 ,~, =~ _~ ~o 4737,TM 66.~~ Ion.oo -9774 =~ 4825,34 67+35 i28,53 -282~.!6 49t3+39 AT,lO 129,23 -2~I ~ 5000,60 67+i! 130,12 -2940,26 5088+71 &6,78 130+3i =~'~o~,~+~v =~ 66,64 i30+35 -3052.48 5234,44 66,54 130,57 5322,00 hA+AS '"" == ~'~ 40 5409,04 ¢5,57 129,42 -3203,84 5496,!8 66,05 129,23 -3259+i4 ssg2 + ~ o~__~ .. A~,97._ i28 ,~:=" -3313,77 5844,79 66+29 i2A+34 -3476,76 5'93i,64 66,18 127.8! -3530,35 6019,63 ~A 99 ~c? ~ -3564,29 6i07,04 66,87 !27,83 -3~7,88 6193,94 66,76 IL7,66 6Z79,~? 66,70 i26,73 -3742,70 6368.18 67+i0 i26+54 -3795+74 '~=~,42 " i26,3! 6543, i7 AT,00 i~ .~62 =3699:2i ..... ~,.,,~_,,_ 126+29 ._.,.,v ,,.,v I.'g + 6/!8,5/ 66.6! '= ~-'' ...... l~o,~__, -4002,09 4406.43 66.73 i24,79 -4052 6693,70 66,67 125+ 00 - 4! 02+ 47 7066,26. ,_:,.~ - ":.,o 114+07 -4200+87 ....7154, ~,~ 65+70 !24,19 -~4~,~ "' 5! 724!+87 AS.gA '123+75 -4298+i5 72~9.03 AA *^ I74.4A . . ,~v .... -4347,0A 74i7,32 o~+~> £~+6/ ......... =~' =~ i24 - ._. . /~9~,/0 66,25 +Z8 -444s.44 HF'E-22 OJO~+~O ....... ~,..=Y+o! 4474,¢! 0077,£~ 3770,40 4645',~1 3840~06 4737,50 AZIMIJTH deq ~o=-,77 !25 -'~ ~/,.~ 125 ~r~ 125 3977.7r, 49i3,49 ~= o~ 4044,94 5000~67 126.01 4!12 ~o SOSg.7~ ,ol ^o ~'==,4t 5173.82 12A.LA ~i// _ . . 4290,~3. . =::<~,0~.~= -~ i26.27 4358, i! ~r)o~ ,,,+~ i26 ..... o£ 5496+18 126,~, 4493,32 558,3+ti i26,41 J/.:'/ + ~2 i ,., aA~P,+20 .... 4836,26 DL'S deo/ 1,."J<';f t !.00 !+50 0,82 1,52 0,93 0,73 0,86 0,40 0,15 0,34 0,98 0,15 V.OL 0,20 0,27 0+52 0,05 "7%:J +.-,-~ ~:z'.z/ +v; ~,., + ~,., .- 4974,08 6!94,00 ~ ¢A.~.q~,.., .,~ 0,20 %a42+08 A279 +36 ~-,t =,:, - ' - =~'"" ,44~5 "'" ~ ~ 0,2~ - . ,.,~ ,.~ . , ~ ~j,,) gion.ao !26,57 =~" =~' A71R,62 125,J6 Ju¥6,J7 .. _ r,;r, ri AQA.A.~o ioL ~ j~OO~J,.: .~.~..=~,~ -~,.,+~ 5540.18 6893,74 126,52 56i3,23 6981,!5 !26,49 ~. ~,+Z~ /~Jq,70 !~ .... 44 ~:~'~,44 1141.~ 126,41 5973+86 .74i7,22 126,35 6046,40 .7~04_. ,,~° ! i,.,~z, o~ ,.,~1~ + .. .,_/z+,~ 6i88~ $16i+56 ,.,~,20 i26,26 0,50 1,0! 0.21 0,29 0,37 0,45 0,88 0,76 0,58 0,1! 0,06 0,49 P~ NO: MEASURED iNT~.~5)AL VERTICAl, D~r :H ft ft ft r~,~' ,4~-: 10645,72 96,0 5~20,21 i0741,17 ~,5 5;559 ~o~F:~.';'z 94,8 5~,98,32 0932 c,~ '~,3 5937 ~ 11026 ox 11122 o~ !13t4.12 11409 ~ 11501 ~ ',~ !1970.72 12066~ 12!60.8! 12255.32 1244!,52 12629.~9 12821,09 13008,71 13195,73 !o~Q~,47 13387,82 13481.56 13577.41 13671 ~ t07£7 47 i3957~4! 14239,45 96,1 5977,45 '~.9 60~5.73 9A.i 6054,37 95.7 6093,02 92.3 6169.03 93,6 6206,57 95.6 6244,60 92,4 628i.31 92~4 6318.54 6395,69 94,5 6470,~ 91,2 6506.43 95+0 6544,06 94,6 '~.6 6619.60 95,7 6698.28_' 'k3,9 6/'-7,5.42 94.1 6813,52 O0~O,~Y 95.7 6889~90 93.7 6968,92 93,9 7049,13 96.2 7090,59 y.,~ 7!32,02 94~2 7!72,66 94,3 7254,5! ****.**~*.**** ANA~R!LL ****~**w***** SbT<VS¥ CALCULATIONS ******~**~* CIRCULAR ARC M~TI.qOD*:****~* TARGET STATION AZIM&ITH LATITUDE SEC3ION INCu4, N/-S ft deq deg. ft 7852,95 65,34 124,8! -.4642.43 7940.16 65,47 124.57 -~,92,09 g ~ A= ~o .... 4741.4~ ~0~,,t2 i~4.ol m ~ ~ ........ 8ilo.u4 Ag.Yg 124,41 -4790,47 ~on~ ~ 65,72 i~4.7n ~,~1 65,62 124,8^ -4890,20 ~7' ~ 66,28 124.90 -~39.26 8462,58 ~,,33 i25,04 -4'789,71 8550.12 66.03 124.86 -5039,87 ~c,~ ~ &5,01 125,07 8721,4! ~A '-'=. 126,04 -Si ~,,7^ · -... %~J .~.~ . ~-/ ,~ .. . ~o/,~1 ~,,49 126,41 -51~9,46 8894,97 AA,;A .... .=,~,50 -524i,61 8979,74 ~,,52 126,10 -5291 9064,25 A5..,~"'" 126.~ -5341 ,~¢8, .y ~.~..:¢~ t26.23 -5445,49 ~5,34 A~,98. ,.,126,2~ 9496.06 66.67 i25,91 -s~o~¢., ...-~ 9583.29. 66,66 ..~,,~c= =~ -5649,03 9670,24 6~,,39 !25,69 -5699,62 9755,83 65.98 1~.43 -5749.59 9~ ~? i~ =' 12S,23 -5799,94 9930.04 -AK.62.._ 126.40 -~.~.,~ I~015,44 65,79 126,92 -5901,94 !010!,I0 65,&2 I£7,!6 -5953.55 !0187,10 A6.40. 127 .~,~° -6005,57 10272,25 66,~3 ,~, =7 10359,64 ...~z~. ~,¢~z 126,24 -6105,60 10447, ~a'~ ,.,.'~,42 iz..,J* -6t~.~),59 1(~?,i,53 l~,43 i26,54 -621! iO~.l, =' !26,3! ~ fl~ ' ~ . ~. zu/o4.44 64,54 126.32 ~0791,24 64,~ !~.76 -6364 ~*'77.60 64.35 ~o8,, 125,63 -64!4.76 10962.52 64,5! ~= ~' ~ .....89 11047.~°6 64.30 1t132,01 63,79 125.33 -656i,94 !12!6,!7 ~ '-'* .~,~u !24,51 -64,10,i4 MF%-22 DEPA~TL~E DlorLaCnMF~T at ft ft ,53q3.7A ~ ~ ,-~ 6¢25,52 7940,17 ,.4477,13 8027,13 65~,39 8113,57 6620,66 8201,29 AZIMUTH d. ea 126,24 t26,22 126,21 126,17 126 ,'~./'~ 6692,60 8288,84 126.16 6762,98 c~74,AI 126.14 6835,12 8462.63 126,13 6906,89 6550,17 126,12 6978,12 8637,08 126,11 7046,79 8721,47 126,10 7116,00 8B07.27 126.10 7186,59 8895,03 126,11 7254,91 8979,~0 126,11 73~,97 9~:64,3! 126,11 , 7392,75 9151.20 126,11 /46~,0~ 9238,55 126,12 ~2~.40 126,12 753¢3.10 ~R ~ 7A03,07. 9412 ,~ ~ 126,12 7670,68 7496,12 126,12 77,41,39 95_,83,35 126,12 78!1,97 9670,30 126,12 7881,61 9755,90 126,11 7~2+.~, 9~42.94 126,10 8023,32 '~30,12 126,10 817~1.82 10015,51 126,11 6160,20 10101,17 126,11 8Z~8.69 10187,16 126.12 8296,76 10272,31 126,13 8367,t0 10359,70 126.13 8437~64 10447 ~ 8536.i4 10532,58 8_/.,i6 16519,59 ~'~4,56 10704,49 87~4.75 10791,29 8784,89 10577.66 ~4 '- tOgA~ ~ ~¥z~,31 11047,27 8992,44 11132,08 9061.48 11216.25 !26.14 126.14 126~14 126,14 126.i4 I26,13 126,12 126,12 126,11 DLS ,.i~/ IOOf~c 0.66 0,26 0,44 0,22 0,28 0,18 0.70 0.i5 0.2! 0,99 0.44 0,20 0,43 0,8! 0,09 0,47 0,69 0,26 0,64 0.12 0,30 0,50 0.50 0 0,23 0.63 0.71 0.96 0.29 0.00 0,51 0,48 0,54 0.13 0,58 0.47 0,57 0,79 PAGE NO, 6 MF'B-22 PROJECTED TO TD 142~2~A4 93.4 AZIMUTH LATITUDE DEPARTU~ DISPLACEMENT ar AZI~DTH DLS N/-S E/-W deg/ f~ f~ f~ deg lCK~fr 11300,00 ~ "' . 6~,~x; 124,5! -66~,A5 9t30,58 11300,09 126,10 0,03 gyro/data RECEIVED MAY 0 ~ 1996 Nask~ 0it & Gas Cons. Commission Anchorage B.P. EXPLORATION E PAD WELL NUMBER MPE-22 MILNE POINT FIELD, ALASKA 7 5/8"Gyro Survey Survey date' @ August 1995 Job number · AK0895G283 SR283.DOC Gyrodata Incorporated P.O. Box 79389 Houston. Texas 77279 713/461-3146 Fax: 713/461-0920 August 21, 1995 Ms. Terrie Hubble B.P. Exploration Prudhoe Bay Drilling Department 900 E. Benson Blvd. Anchorage, AK 99508 MB 12-1 Re: E Pad Well MPE-22 Milne Point field, Alaska Dear Ms. Hubble, Enclosed please find one (1) original and three copies (3) of the completed survey of Well #MPE-22 We would like to take this opportunity to thank you for using Gyrodata and we look forward to serving you in the future. Robert J. S~u~p~ Operations Manager RS/gr Serving the Worldwide Energy Industry with Precision Survey Instrumentation gyro/data CONTENTS JOB NUMBER: AK0895G283 · DISCUSSION , SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT gyro/data t. DISCUSSION, SURVEY CERTIFICATION SHEET gyro/data, DISCUSSION JOB NUMBER · AK0895G283 Tool 080 was run in MPE 22 on ATLAS 5/16" Wireline inside 7 5/8" casing to a depth of 13515 feet. The survey was run without problems. gyro/data SURVEY CERTIFICATION SHEET JOB NUMBER: AK0895G283 The data for this survey and the calculations for this survey were obtained and performed by me according to the standards and procedures as set forth by Gyrodata Incorporated, and are true and correct to the best of my knowledge. TOM STODDARD SURVEY ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Incorporated. This report represents a true and correct directional survey of this well based on the original data obtained at the wellsite. Checked by: TIM ANDERSON- TOM STODDARD OPERATIONS ENGINEER gyro/data 2. SURVEY DETAILS gyro/data' SURVEY DETAILS JOB NUMBER: AK0895G283 CLIENT: B.P. EXPLORATION RIG: ATLAS LOCATION: MPE UNIT WELL: MPE-22 LATITUDE: 70.455° N LONGITUDE: 149.5° W SURVEY DATE: 8 AUGUST 1995 SURVEY TYPE : 2 1/2" GYRO MULTISHOT DEPTH REFERENCE: NABORS 4ES RKB MAX. SURVEY DEPTH: 13515 FEET SURVEY TIED ONTO: N/A SURVEYINTERVAL: 100 FEET UTM CO-ORDINATES: Y = 6,016,361.44 X = 569,040.31 TARGET DIRECTION: 126.32° GRID CORRECTION: N/A CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: STODDARD gyro/data 3. OUTRUN SURVEY LISTING A Gyro da t a D i re c t i ona i Survey for B.P. EXPLORATION WELL: MILNE POINT WELL NUMBER MPE-22, 7 5/8" CASING Location: E PAD, MILNE POINT FIELD, ALASKA Job Number: AK0895G283 Run Date: 8-Aug-95 06:15:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.455000 deg. N Sub-sea Correction from Vertical Reference: 53.9 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 126.320 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyro da t a D i r e c t i ona i Survey B.P. EXPLORATION WELL: MILNE POINT WELL NUMBER MPE-22, Location: E PAD, MILNE POINT FIELD, Job Number: AK0895G283 7 5/8" CASING ALASKA MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SUBSEA SECTION DEPTH feet feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg. / feet deg. 100 ft. 0.0 0.00 0.00 0.0 0.0 -53.9 0.00 0.0 0.0 MEASURED DEPTHS REFERENCED TO NABORS 4 ES R.K.B. 0.0 - 13515.0 FEET; GYRODATA GYRO SURVEY RUN IN 7 INCH CASING. Page HORIZONTAL COORDINATES feet 0.00 N 0.00 E 115.0 .24 139.64 115.0 .2 61.1 .21 215.0 .41 338.64 215.0 .1 161.1 .64 315.0 .47 352.83 315.0 -.4 261.1 .13 415.0 .30 334.40 415.0 -1.0 361.1 .21 515.0 .52 41.31 515.0 -1.1 461.1 .49 615.0 1.12 90.02 615.0 -.3 561.1 .87 715.0 2.19 106.86 714.9 2.3 661.0 1.16 815.0 3.58 112.02 814.8 7.1 760.9 1.41 915.0 4.86 114.97 914.5 14.3 860.6 1.29 1015.0. 5.53 115.23 1014.1 23.2 960.2 .67 1115.0 7.28 115.74 1113.5 34.1 1059.6 1.75 1215.0 10.52 121.35 1212.3 49.4 1158.4 3.35 1315.0 12.58 126.89 1310.3 69.4 1256.4 2.33 1415.0 13.91 128.10 1407.6 92.3 1353.7 1.36 1515.0 16.61 127.58 1504.1 118.6 1450.2 2.70 1615.0 20.74 127.78 1598.8 150.6 1544.9 4.14 1715.0 22.47 128.10 1691.7 187.4 1637.8 1.73 1815.0 24.04 128.52 1783.6 226.9 1729.7 1.58 1915.0 27.77 128.15 1873.6 270.6 1819.7 3.73 2015.0 30.16 128.50 1961.0 318.9 1907.1 2.40 .2 139.6 .18 S .16 E .2 94.9 .01 S .16 E .7 358.6 .72 N .02 W 1.4 352.4 1.37 N .18 W 1.9 .2 1.94 N .01 E 2.6 4.4 8.8 15.8 24.7 35.7 51.0 70.7 93.2 119.3 151.1 187.7 227.1 270.7 319.0 29.3 67.1 90.0 100.7 106.0 108.9 112.0 115.5 118.4 120.5 122.0 123.2 124.1 124.7 125.3 2.29 N 1.29 E 1.73 N 4.09 E .01 N 8.82 E 2.95 S 15.55 E 6.79 S 23.75 E 11.60 S 33.81 19.10 S 47.32 30.39 S 63.83 E 44.34 S 82.00 E 60.48 S 102.78 80.05 S 128.12 E 102.69 S 157.15 E 127.17 S 188.13 E 154.26 S 222.40 E 184.29 S 260.38 E A Gyro d a t a D i r e c t i on a i Survey B.P. EXPLORATION WELL: MILNE POINT WELL NUMBER MPE-22, Location: E PAD, MILNE POINT FIELD, Job Number: AK0895G283 7 5/8" CASING ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SUBSEA SECTION DEPTH feet feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 2115.0 33.17 128.81 2046.1 2215.0 35.41 128.37 2128.8 2315.0 36.91 127.84 2209.5 2415.0 38.58 127.64 2288.6 2515.0 40.70 130.56 2365.6 371.4 1992.2 3.01 371.4 125.8 427.7 2074.9 2.26 427.7 126.1 486.7 2155.6 1.53 486.7 126.4 547.9 2234.7 1.67 547.9 126.5 611.6 2311.7 2.82 611.6 126.8 217.08 S 252.22 S 288.63 S 326.10 S 366.35 S 301.36 E 345.40 E 391.84 440 25 489.72 E 2615.0 44.59 129.82 2439.1 2715.0 48.88 128.00 2507.6 2815.0 51.31 127.11 2571.8 2915.0 51.46 127.69 2634.2 3015.0 53.19 127.51 2695.3 679.1 2385.2 3.92 679.2 127.1 751.9 2453.7 4.49 752.0 127.3 828.6 2517.9 2.52 828.7 127.3 906.7 2580.3 .48 906.8 127.3 985.8 2641.4 1.74 986.0 127.4 410.05 S 455.75 S 502.49 S 549.94 S 598.22 S 541.47 E 598.14 E 658.96 E 721.03 E 783.74 E 3115.0 55.64 127.22 2753.5 3215.0 58.90 127.50 2807.6 3315.0 62.12 127.13 2856.8 3415.0 62.70 127.02 2903.1 3515.0 63.84 126.78 2948.1 1067.1 2699.6 1151.2 2753.7 1238.2 2802.9 1326.8 2849.2 1416.1 2894.2 2.46 1067.3 127.4 3.27 1151.4 127.4 3.23 1238.4 127.4 .59 1327.0 127.3 1.16 1416.4 127.3 647.57 S 698.61 S 751.36 S 804.79 S 858.42 S 848.37 E 915.23 E 984.45 E 1055.16 E 1126.58 E 3615.0 65.70 126.52 2990.7 3715.0 66.11 125.32 3031.5 3815.0 65.69 126.40 3072.4 3915.0 64.83 126.33 3114.2 4015.0 64.04 125.71 3157.4 4115.0 65.72 127.27 3199.8 4165.0 65.83 127.23 3220.3 4215.0 66.21 127.89 3240.7 4315.0 65.11 125.06 3281.9 4365.0 64.56 128.34 3303.1 1506.6 2936.8 1597.9 2977.6 1689.2 3018.5 1780.0 3060.3 1870.2 3103.5 1960.7 3145.9 2006.3 3166.4 2052.0 3186.8 2143.1 3228.0 2188.3 3249.2 1.87 1506.8 127.3 1.17 1598.1 127.2 1.07 1689.3 127.1 .86 1780.1 127.1 .97 1870.3 127.0 2.19 1960.9 127.0 .23 2006.5 127.0 1 . 43 2052 . 1 127 . 0 2.80 2143 . 2 127.0 6 . 04 2188 . 5 127 . 0 912.42 S 965.97 S 1019.45 S 1073.30 S 1126.36 S 1180.20 S 1207.80 S 1235.65 S 1289.81 S 1316.85 S 1199.15 ~ 1273.0~ ~ 1347.05 E 1420.18 E 1493.14 E 1565.92 E 1602.21 E 1638.43 E 1711.67 E 1747.95 E A Gyro da t a D i r e c t i o n a i Survey B.P. EXPLORATION WELL: MILNE POINT WELL NUMBER MPE-22, Location: E PAD, MILNE POINT FIELD, Job Number: AK0895G283 7 5/8" CASING ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SUBSEA SECTION DEPTH feet feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 4415.0 65.40 126.69 3324.3 4515.0 65.83 125.36 3365.6 4615.0 67.03 124.47 3405.6 '4715.0 67.04 123.89 3444.6 4815.0 66.23 124.45 3484.2 2233.6 3270.4 2324.7 3311.7 2416.3 3351.7 2508.3 3390.7 2600.1 3430.3 3.44 2233.8 127.0 1.28 2324.8 127.0 1.45 2416.4 126.9 .54 2508.4 126.8 .96 2600.1 126.7 1344.44 S 1398.01 S 1450.46 S 1502.19 S 1553.74 S 1783.89 1857.55 1932.7] 2008 88 2084.83 4915.0 66.19 124.42 3524.6 5015.0 65.90 124.33 3565.2 5115.0 66.42 123.07 3605.6 5215.0 65.97 123.48 3646.0 5315.0 66.89 123.32 3685.9 2691.5 3470.7 2782.9 3511.3 2874.2 3551.7 2965.6 3592.1 3057.1 3632.0 . 05 2691 . 6 126 . 6 .30 2782.9 126.5 1.27 2874.2 126.5 .59 2965.6 126.4 .93 3057.1 126.3 1605.49 S 1657.09 S 1707.84 S 1758.03 S 1808.48 S 2160.30 E 2235.73 E 2311.82 E 2388.32 E 2464.84 E 5415.0 66.39 122.91 3725.6 5515.0 67.07 124.59 3765.1 5615.0 66.90 123.95 3804.2 5715.0 66.57 124.20 3843.7 5815.0 65.53 125.04 3884.3 3148.8 3671.7 3240.6 3711.2 3332.5 3750.3 3424.3 3789.8 3515.7 3830.4 .62 3148.8 126.2 1.68 3240.6 126.1 .61 3332.6 126.1 .40 3424.4 126.0 1.30 3515.8 126.0 1858.64 S 1909.68 S 1961.50 S 2012.98 S 2064.90 S 2541.73 E 2618.11 E 2694.17 E 2770.27 E 2845.47 E 5915.0 65.50 125.32 3925.7 6015.0 65.39 127.26 3967.3 6115.0 65.43 125.97 4008.9 6215.0 66.44 126.39 4049.7 6315.0 67.47 126.44 4088.8 3606.7 3871.8 3697.6 3913.4 3788.6 3955.0 3879.9 3995.8 3971.9 4034.9 .25 3606.7 125.9 1.77 3697.7 126.0 1.17 3788.6 126.0 1.08 3879.9 126.0 1 . 03 3971.9 126 . 0 2117.33 S 2171.16 S 2225.40 S 2279.30 S 2333.93 S 2919.85 m 2993 1~ ~ 3066.14 E 3139.84 E 3213.89 E 6415.0 66.62 127.24 4127.8 6515.0 66.33 128.57 4167.8 6615.0 65.91 128.80 4208.2 6715.0 66.19 127.36 4248.8 6815.0 66.59 127.86 4288.9 4063.9 4073.9 4155.6 4113.9 4247.0 4154.3 4338.3 4194.9 4429.9 4235.0 1.12 4064.0 126.0 1.25 4155.6 126.0 .47 4247.0 126.1 1.34 4338.3 126.1 .60 4429.9 126.2 2389.13 S 2445.45 S 2502.60 S 2558.96 S 2614.88 S 3287.59 E 3359.93 E 3431.31 E 3503.25 E 3575.84 E A Gyro da t a D i r e c t i o na i Survey B.P. EXPLORATION WELL: MILNE POINT WELL NUMBER MPE-22, Location: E PAD, MILNE POINT FIELD, Job Number: AK0895G283 7 5/8" ALASKA CASING Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet SUBSEA DEPTH feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg. / feet deg. 100 ft. HORIZONTAL COORDINATES feet 6915.0 67.40 127.52 4328.0 7015.0 66.83 127.17 4366.8 7115.0 66.18 128.53 4406.7 7215.0 66.69 129.09 4446.7 7315.0 67.96 128.71 4485.3 4521.9 4614.0 4705.7 4797.3 4889.5 4274.1 4312.9 4352.8 4392.8 4431.4 .86 4521.9 126.2 .65 4614.0 126.2 1.40 4705.7 126.3 .72 4797.3 126.3 1.31 4889.5 126.4 2671.16 S 3648.68 E 2727.04 S 3721.92 E 2783.31 S 3794.33 ~ / 2840.76 S 3865.76 ..' 2898.70 S 3937.56 E 7415.0 66.78 129.45 4523.7 7515.0 66.80 129.29 4563.1 7615.0 66.59 130.36 4602.7 7715.0 66.56 130.29 4642.5 7815.0 66.23 130.21 4682.5 4981 5073 5165 5256 5348 .7 .4 .1 .6 .0 4469.8 4509.2 4548.8 4588.6 4628.6 1.36 4981.7 126.4 .15 5073.4 126.5 1.00 5165.1 126.5 .07 5256.7 126.6 .34 5348.1 126.7 2956.88 S 3015.17 S 3073.99 S 3133.36 S 3192.57 S 4009.21 E 4080.26 E 4150.80 E 4220.76 E 4290.69 E 7915.0 66.79 129.00 4722.4 8015.0 65.96 128.49 4762.4 8115.0 65.93 127.45 4803.2 8215.0 66.33 127.21 4843.7 8315.0 66.27 126.93 4883.9 5439 5531 5622 5713 5805 .6 .1 .4 .8 .4 4668.5 4708.5 4749.3 4789.8 4830.0 1.25 5439.7 126.7 .96 5531.3 126.7 .95 5622.6 126.8 .45 5714.0 126.8 .27 5805.6 126.8 3251.04 S 3308.38 S 3364.56 S 3420.01 S 3475.21 S 4361.35 E 4432.81 E 4504.79 E 4577.51 E 4650.56 E 8415.0 66.25 127.59 4924.1 8515.0 66.01 126.85 4964.6 8615.0 66.78 126.73 5004.6 8715.0 66.78 127.14 5044.1 8815.0 66.58 125.73 5083.7 5896 5988 6080 6171 6263 .9 .4 .0 .9 .7 4870.2 4910.7 4950.7 4990.2 5029.8 .61 5897.1 126.8 .72 5988.6 126.8 .79 6080.2 126.8 .38 6172.1 126.8 1.31 6263.9 126.8 3530.63 S 3585.94 S 3640.82 S 3696.04 S 3750.58 S 4723.42 4796.24 4869.62 4943.08 5016.95 8915.0 67.12 125.25 5123.0 9015.0 67.09 125.68 5161.9 9115.0 66.77 123.55 5201.1 9215.0 66.87 123.99 5240.4 9315.0 66.66 124.33 5279.9 6355.7 6447.8 6539.7 6631.6 6723.4 5069.1 5108.0 5147.2 5186.5 5226.0 .70 6355.8 126.8 .40 6447.9 126.7 1.99 6539.9 126.7 .42 6631.7 126.7 .38 6723.5 126.6 3803.96 S 3857.41 S 3909.66 S 3960.76 S 4012.35 S 5091.82 E 5166.85 E 5242.56 E 5318.98 E 5395.02 E A Gyro da t a D i r e c t i o na i Survey B.P. EXPLORATION WELL: MILNE POINT WELL NUMBER MPE-22, Location: E PAD, MILNE POINT FIELD, Job Number: AK0895G283 7 5/8" CASING ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SUBSEA DOGLEG CLOSURE SECTION DEPTH SEVERITY DIST. AZIMUTH feet feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 9415.0 66.67 123.36 5319.5 9515.0 66.59 123.65 5359.2 9615.0 66.31 122.26 5399.1 9715.0 65.94 123.44 5439.6 9815.0 65.53 123.49 5480.7 6815.1 5265.6 6906.8 5305.3 6998.3 5345.2 7089.6 5385.7 7180.6 5426.8 .89 6815.2 126.6 .28 6906.9 126.6 1.30 6998.3 126.5 1.13 7089.6 126.5 .41 7180.6 126.4 4063.49 S 5471.28 4114.17 S 5547.82 4164.04 S 5624.73 4213.64 S 5701.55 4263.91 S 5777.61 9915.0 66.09 123.65 5521.7 10015.0 66.11 123.62 5562.2 10115.0 66.20 124.03 5602.6 10215.0 66.12 124.64 5643.0 10315.0 66.15 123.37 5683.5 7271.7 5467.8 7363.1 5508.3 7454.4 5548.7 7545.9 5589.1 7637.2 5629.6 .57 7271.8 126.4 .04 7363.1 126.4 .38 7454.4 126.3 .56 7545.9 126.3 1.16 7637.2 126.3 4314.35 S 5853.61 E 4364.99 S 5929.73 E 4415.91 S 6005.70 E 4467.51 S 6081.23 E 4518.'66 S 6157.04 E 10415.0 66.07 124.02 5724.0 10515.0 65.44 123.65 5765.0 10615.0 65.34 124.19 5806.7 10715.0 65.81 123.62 5848.0 10815.0 65.70 123.61 5889.1 7728.6 5670.1 7819.7 5711.1 7910.5 5752.8 8001.5 5794.1 8092.5 5835.2 .60 7728.6 126.2 .72 7819.7 126.2 .51 7910.5 126.2 .71 8001.5 126.2 .11 8092.6 126.1 4569.38 S 6233.11 E 4620.15 S 6308.85 E 4670.88 S 6384.29 E 4721.67 S 6459.86 E 4772.15 S 6535.79 E 10915.0 65.47 123.33 5930.4 11015.0 65.55 124.23 5971.9 11115.0 66.20 123.42 6012.8 11215.0 66.25 123.48 6053.1 11315.0 66.18 122.95 6093.4 8183.5 5876.5 8274.4 5918.0 8365.6 5958.9 8457.0 5999.2 8548.3 6039.5 .34 8183.5 126.1 .82 8274.5 126.1 .98 8365.7 126.1 .07 8457.1 126.0 .49 8548.5 126.0 4822.36 S 6611.75 4872.96 S 6687.39 4923.76 S 6763.21 4974.20 S 6839.56 5024.33 S 6916.12 11415.0 65.99 123.95 6134.0 11515.0 66.12 123.96 6174.5 11615.0 66.50 125.20 6214.7 11715.0 66.55 125.68 6254.5 11815.0 66.45 124.70 6294.4 8639.6 6080.1 8731.0 6120.6 8822.5 6160.8 8914.2 6200.6 9005.9 6240.5 .93 8639.8 126.0 .14 8731.1 125.9 1.19 8822.7 125.9 .45 8914.4 125.9 .91 9006.1 125.9 5074.72 S 6992.39 E 5125.77 S 7068.20 E 5177.74 S 7143.59 E 5230.93 S 7218.32 E 5283.78 S 7293.27 E A Gyro d a t a D i r e c t i on a i Survey B.P. EXPLORATION WELL: MILNE POINT WELL NUMBER MPE-22, Location: E PAD, MILNE POINT FIELD, Job Number: AK0895G283 7 5/8" CASING ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SUBSEA DOGLEG CLOSURE SECTION DEPTH SEVERITY DIST. AZIMUTH feet feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 11915.0 65.98 125.13 6334.8 12015 . 0 65 . 94 125 . 33 6375 . 5 12115 . 0 66 . 72 126 . 05 6415 . 6 12215 . 0 66 . 79 125.43 6455 . 1 12315 . 0 66 . 76 124 . 17 6494 . 5 9097 . 4 6280 . 9 . 62 9097 . 6 125 . 9 9188 . 7 6321 . 6 . 19 9188 . 9 125 . 9 9280 . 3 6361 . 7 1 . 02 9280 . 5 125 . 9 9372 . 1 6401 . 2 . 57 9372 . 4 125 . 9 9464 . 0 6440 . 6 1 . 16 9464 . 3 125 . 9 5336.15 S 5388.84 S 5442.27 S 5495.94 S 5548.39 S 7368.30 E 7442.89 E 7517.22 ) 7591.86 ~' 7667.32 E 12415.0 66.58 124.36 6534.1 12515.0 66.41 123.98 6574.0 12615.0 66.29 124.29 6614.1 12715.0 65.57 123.15 6654.9 12815.0 65.46 124.54 6696.4 9555.8 6480.2 .26 9556.1 125.9 9647.4 6520.1 .39 9647.7 125.9 9738.9 6560.2 .31 9739.3 125.8 9830.1 6601.0 1.26 9830.5 125.8 9921.1 6642.5 1.27 9921.5 125.8 5600.09 S 5651.60 S 5702.99 S 5753.68 S 5804.36 S 7743.20 E 7819.07 E 7894.89 E 7970.84 E 8046.42 E 12915.0 65.81 125.60 6737.6 13015.0 65.69 124.79 6778.7 13115.0 66.32 124.76 6819.4 13215.0 66.34 125.55 6859.5 13315.0 65.32 124.54 6900.4 10012.1 6683.7 1.02 10012.6 125.8 10103.3 6724.8 .74 10103.7 125.8 10194.6 6765.5 .63 10195.1 125.8 10286.2 6805.6 .72 10286.7 125.8 10377.4 6846.5 1.38 10377.9 125.8 5856.70 S 5909.25 S 5961.36 S 6014.10 S 6066.49 S 8120.97 E 8195.49 E 8270.53 E 8345.41 E 8420.10 E 13415.0 65.54 124 .49 6942.0 13515 . 0 65 . 30 125 . 66 6983 . 6 10468 . 3 6888 . 1 . 23 10468 . 8 125 . 8 10559 . 2 6929 · 7 1 . 09 10559 · 7 125 . 8 6118.02 S 6170.27 S 8495.03 TM 8569.46 .... Final Station Closure: Distance: 10559.73 ft Az: 125.76 deg. A Gyro da t a D i r e c t i o na i Survey for B.P. EXPLORATION WELL: MILNE POINT WELL NUMBER MPE-22, 7 5/8" CASING Location: E PAD, MILNE POINT FIELD, ALASKA Job Number: AK0895G283SS Run Date: 8-Aug-95 06:15:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.455000 deg. N Sub-sea Correction from Vertical Reference: 53.9 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 126.320 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyro da t a D i r e c t i on a i B.P. EXPLORATION WELL: MILNE POINT WELL NUMBER MPE-22, Location: E PAD, MILNE POINT FIELD, Job Number: AK0895G283SS 7 5/8" CASING ALASKA SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG DEPTH DEPTH SECTION SEVERITY feet deg. deg. feet feet deg./ 100 ft. CLOSURE DIST. AZIMUTH feet deg. -53.9 0.00 0.00 0.0 0.0 0.00 0.0 0.0 MEASURED DEPTHS REFERENCED TO NABORS 4 ES R.K.B. 0.0 - 13515.0 FEET; GYRODATA GYRO SURVEY RUN IN 7 INCH CASING. Survey Page HORIZONTAL COORDINATES feet 0.00 N 0.00 E 100.0 .30 217.05 153.9 .2 .38 200.0 .43 344.16 253.9 -.1 .44 300.0 .40 345.66 353.9 -.6 .16 400.0 .39 220.37 453.9 -1.0 .32 500.0 .76 60.26 553.9 -.8 .64 600.0 1.54 96.58 653.9 .7 .98 700.0 2.73 108.87 753.9 4.2 1.26 800.0 4.08 113.18 853.9 9.9 1.37 900.0 5.12 115.07 953.9 17.8 1.05 1000.0 6.23 115.43 1053.9 27.5 1.11 1100.0 8.61 118.04 1153.9 40.4 2.41 1200.0 11.40 123.71 1253.9 57.9 2.92 1300.0 13.17 127.43 1353.9 79.7 1.90 1400.0 15.20 127.85 1453.9 105.0 2.00 1500.0 18.78 127.69 1553.9 ' 135.5 3.46 1600.0 21.77 127.97 1653.9 172.5 2.71 1700.0 23.53 128.39 1753.9 214.1 1.63 1800.0 26.95 128.23 1853.9 261.0 3.26 1900.0 29.96 128.47 1953.9 315.0 2.51 2000.0 33.38 128.77 2053.9 376.7 2.94 .2 122.2 .7 197.5 1.4 356.2 1.9 355.4 2.6 11.5 4.4 44.0 8.8 76.0 15.8 94.2 24.7 102.8 35.7 107.1 51.0 110.2 70.7 113.5 93.2 116.8 119.3 119.4 151.1 121.3 187.7 122.7 227.1 123.8 270.7 124.6 319.0 125.2 427.7 125.8 .12 S .16 E .29 N .11 W .97 N .08 W 1.59 N .11 E 2.08 N .50 E 2.07 N 2.38 E 1.06 N 5.94 E 1.16 S 11.46 E 4.47 S 18.79 E 8.71 S 27.78 E 14.67 S 39.34 E 23.90 S 54.34 E 36.65 S 71.98 E 52.09 S 91.98 E 70.78 S 116.12 E 93.48 S 145.33 E 119.25 S 178.11 E 148.34 S 214.91 E 181.84 S 257.28 E 220.38 S 305.50 E A Gyr oda t a D i r e c t i ona i Survey B.P. EXPLORATION WELL: MILNE POINT WELL NUMBER MPE-22, Location: E PAD, MILNE POINT FIELD, Job Number: AK0895G283SS 7 5/8" CASING ALASKA Page SUBSEA I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet DOGLEG SEVERITY deg./ 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 2100.0 35.88 128.21 2153.9 2200.0 37.85 127.73 2253.9 2300.0 40.38 130.12 2353.9 2400.0 45.52 129.43 2453.9 2500.0 50.63 127.35 2553.9 446.1 521.0 601.9 694.9 807.2 2.03 1.61 2.65 4.05 3.07 486.7 126.2 547.9 126.5 611.6 126.8 752.0 127.2 828.7 127.3 263.56 S 359.86 E 309.68 S 419.03 E 360.26 S 482.23 F 419.92 S 553.71 E 489.46 S 642.02 E 2600.0 52.01 127.63 2653.9 2700.0 55.66 127.22 2753.9 2800.0 61.93 127.16 2853.9 2900.0 64.10 126.75 2953.9 3000.0 65.88 125.91 3053.9 932 1067 1233 1428 1647 .2 .7 .1 .5 .9 .88 2.47 3.23 1.26 1.12 986.0 127.3 1151.4 127.4 1238.4 127.4 1506.8 127.3 1689.3 127.2 565.51 S 741.26 E 647.96 S 848.87 E 748.28 S 980.40 E 865.79 S 1136.49 E 995.27 S 1313.60 E 3100.0 64.10 125.76 3153.9 3200.0 65.86 126.98 3253.9 3300.0 65.71 125.74 3353.9 3400.0 66.85 124.02 3453.9 3500.0 65.98 124.36 3553.9 1862 2081 2298 2529 2757 .9 .2 .9 .9 .5 .96 1.87 1.89 .63 .23 1870.3 127.0 2143.2 127.0 2324.8 127.0 2600.1 126.8 2782.9 126.6 1122.10 S 1253.05 S 1382.85 S 1514.30 S 1642.75 S 1487.28 E 1661.96 E 1836.71 E 2026.72 E 2214.77 E 3600.0 66.15 123.44 3653.9 3700.0 66.88 124.11 3753.9 3800.0 66.31 124.42 3853.9 3900.0 65.43 126.63 3953.9 4000.0 66.55 126.40 4053.9 2983 3214 3447 3668 3889 .8 .6 .3 .3 .8 .65 1.38 .63 1.28 1.07 3057.1 126.3 3240.6 126.1 3515.8 126.0 3697.7 126.0 3971.9 126.0 1768.05 S 1895.22 S 2026.04 S 2153.81 S 2285.19 S 2403.52 E 2596.47 E 2789.18 E 2969.53 E 3147.82 E 4100.0 66.43 128.11 4153.9 4200.0 66.24 127.43 4253.9 4300.0 67.02 127.29 4353.9 4400.0 66.93 129..02 4453.9 4500.0 66.79 129.32 4553.9 4123.8 4349.9 4583.4 4814.5 5051.9 1.21 1.25 .72 .83 .43 4155.6 126.0 4429.9 126.2 4614.0 126.2 4889.5 126.3 5073.4 126.5 2425.91 S 2566.04 S 2708.44 S 2851.58 S 3001.50 S 3334.83 E 3512.44 E 3697.53 E 3879.17 E 4063.60 E A Gyrodata B.P. EXPLORATION WELL: MILNE POINT WELL NUMBER MPE-22, Location: E PAD, MILNE POINT FIELD, Job Number: AK0895G283SS 7 5/8" ALASKA Direct CASING i ona 1 Survey Page SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG DEPTH DEPTH SECTION SEVERITY feet deg. deg. feet feet deg./ 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 4600.0 66.46 130.27 4653.9 4700.0 66.13 128.60 4753.9 4800.0 66.31 127.14 4853.9 4900.0 66.07 127.05 4953.9 5000.0 66.73 126.79 5053.9 5282.7 5511.6 5737.1 5964.2 6194.7 .15 1.02 .41 .69 .61 5348.1 126.6 5531.3 126.7 5805.6 126.8 5988.6 126.8 6263.9 126.8 3150.28 S 4240.74 E 3296.17 S 4417.59 E 3434.05 S 4596.09 E 3571.32 S 4776.99 E 3709.59 S 4961.43 E 5100.0 67.10 125.59 5153.9 5200.0 66.80 124.10 5253.9 5300.0 66.60 123.61 5353.9 5400.0 65.80 123.45 5453.9 5500.0 66.11 123.63 5553.9 6428.9 6662.9 6894.6 7121.3 7344.4 .46 .41 .36 .88 .15 6447.9 126.7 6723.5 126.7 6906.9 126.6 7180.6 126.5 7363.1 126.4 3846.44 S 5151.45 E 3978.37 S 5344.93 E 4107.45 S 5537.68 E 4231.14 S 5728.03 E 4354.65 S 5914.17 E 5600.0 66.13 124.30 5653.9 5700.0 65.61 123.75 5753.9 5800.0 65.80 123.62 5853.9 5900.0 65.51 123.84 5953.9 6000.0 66.25 123.47 6053.9 7570.4 7794.9 8014.5 8234.9 8458.8 .73 .69 .62 .61 .08 7637.2 126.3 7819.7 126.2 8092.6 126.2 8274.5 126.1 8548.5 126.0 4481.26 S 6101.60 E 4606.37 S 6288.29 E 4728.87 S 6470.68 E 4850.99 S 6654.55 E 4975.21 S' 6841.11 E 6100.0 66.06 123.96 6153.9 6200.0 66.55 125.68 6253.9 6300.0 65.96 125.23 6353.9 6400.0 66.79 125.45 6453.9 6500.0 66.49 124.17 6553.9 8684.5 8912.7 9140.3 9369.3 9601.2 .54 .46 .42 .59 .32 8731.1 126.0 8914.4 125.9 9188.9 125.9 9372.4 125.9 9647.7 125.9 5099.81 S 7029.65 E 5230.06 S 7217.10 E 5360.91 S 7403.35 E 5494.30 S 7589.57 E 5625.61 S 7780.79 E 6600.0 65.59 123.18 6653.9 6700.0 65.76 125.28 6753.9 6800.0 66.34 125.44 6853.9 6900.0 65.47 124.82 6953.9 6929.7 '65.30 125.66 6983.6 9827.8 10048.3 10273.4 10494.2 10559.2 1.23 .91 .71 .47 1.09 9830.5 125.8 10103.7 125.8 10286.7 125.8 10559.7 125.8 10559.7 125.8 5752.40 S 7968.92 E 5877.53 S 8150.50 E 6006.75 S 8334.97 E 6132.93 S 8516.27 E 6170.27 S 8569.46 E A Gyro da t a D i r e c t i on a i Survey B.P. EXPLORATION WELL: MILNE POINT WELL NUMBER MPE-22, 7 5/8" CASING Location: E PAD, MILNE POINT FIELD, ALASKA Job Number: AK0895G283SS Page SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DEPTH DEPTH SECTION feet deg. deg. feet feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet Final Station Closure: Distance- 10559.73 ft Az: 125.76 deg. Quality Control Comparisons B.P. EXPLORATION WELL: MILNE POINT WELL NUMBER MPE-22, Location: E PAD, MILNE POINT FIELD, 7 I! ALASKA Job Number : AK0895G283 / AK0895G283 INRUN/OUTRUN Comparison INRUN OUTRUN Depth Inc Inc Delta 1015.0 5.45 5.53 -.075 2015.0 29.91 30.16 -.249 2815.0 51.16 51.31 -.150 3015.0 52.55 53.19 -.636 4165.0 65.68 65.83 -.150 4215.0 66.07 66.21 -.144 13515.0 65.12 65.30 -.175 INRUN Az 115.96 128.31 127.23 127.90 127.80 127.37 125.52 For Inclinations Greater than 1 degrees: Average Inclination Difference = -.2257 deg. Average Azimuth Difference = .13982 deg. OUTRUN Az 115.23 128.50 127.11 127.51 127.23 127.89 125.66 Delta .737 -.193 .129 .390 .569 -.515 -.138 gyro/data 4. QUALITY CONTROL Quality Control Comparisons B.P. EXPLORATION WELL: MILNE POINT WELL NUMBER MPE-22, Location: E PAD, MILNE POINT FIELD, 7 5/8" CASING ALASKA Job Number : AK0895G283 / AK0895G283 inrun/outrun Comparison inrun outrun Depth Inc Inc Delta 1015.0 5.45 5.53 -.075 2015.0 29.91 30.16 -.249 2815.0 51.16 51.31 -.150 3015.0 52.55 53.19 -.636 4165.0 65.68 65.83 -.150 4215.0 66.07 66.21 -.144 13515.0 65.12 65.30 -.175 inrun Az 115.96 128.31 127.23 127.90 127.80 127.37 125.52 For Inclinations Greater than 1 degrees: Average Inclination Difference = -.2257 deg. Average Azimuth Difference = .13982 deg. outrun Az 115.23 128.50 127.11 127.51 127.23 127.89 125.66 Delta .737 -.193 .129 .390 .569 -.515 -.138 gyro/data QUALITY CONTROL REPORT JOB NUMBER · AK0895G283 TOOL NUMBER MAXIMUM GYRO TEMPERATURE 080 78.89°C MAXIMUM AMBIENT TEMPERATURE ' 75.10°C MAXIMUM INCLINATION 67.10° AVERAGE AZIMUTH 124.657° WIRELINE REZERO VALUE NO CORRECTION REZERO ERROR / K N/A CALIBRATION USED FOR FIELD SURVEY · 23-JUNE-1995 CALIBRATION USED FOR FINAL SURVEY ' 23-JUNE-1995 PRE JOB MASS BALANCE OFFSET CHECK: 0.0 POST JOB MASS BALANCE OFFSET CHECK: .05 CONDITION OF SHOCK WATCHES UPON ARRIVAL AT RIG OK UPON COMPLETION OF SURVEY OK UPON RETURN TO ATLAS OK BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH TVD FIELD SURVEY 13515 65.30 125.66 6983.40 FINAL SURVEY 13515 65.30 125.66 6983.60 NORTHING 6170.40 S 6170.27 S EASTING 8569.60 E 8569.46 E gyro/data 5. EQUIPMENT AND CHRONOLOGICAL REPORT gyro/data EQUIPMENT REPORT JOB NUMBER: AK0895G283 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL NO. 080 COMPUTER A0153 GYRO SECTION A0094 POWER SUPPLY A0085 DATA SECTION A0032 PRINTER A0029 POWER SECTION A0027 INTERFACE A0035 BACKUP TOOL NO. 713 COMPUTER A0122 GYRO SECTION A0073 POWER SUPPLY A0055 DATA SECTION A0025 PRINTER A0079 POWER SECTION A0052 INTERFACE A0071 WIRELINE COMPANY ATLAS WIRELINE CABLE SIZE 5/16" RUNNING GEAR 2 1/2" SYSTEM WITH 3" HEATSHIELD, 3.5" WEAR BUSHINGS AND ECCENTRIC BAR. TOTAL LENGTH OF TOOL 25.5 FEET MAXIMUM O.D. : 3 1/2 INCHES TOTAL WEIGHT OF TOOL 350 POUNDS gyro/data CHRONOLOGICAL REPORT JOB NUMBER: AK0895G283 12 August 1995 04:30 Leave Endicott. 06:00 Arrive E Pad. 07:00 Assemble tool. 07:30 Pick-up tool. 09:45 Depth 13,500 feet. 12:00 Depth 5100 feet. 13:15 Lay down tool. 14:00 Process survey. 15:30 Return to Western Atlas. 22:30 Check tools, O.K. August 1995 Standby for Milne Point H Pad Well number 05. gyro/data FUNCTION TEST JOB NUMBER: AK0895G283 5 Survey stations were collected at the depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft 1 2 3 4 5 2800 51.16 51.16 51.16 51.16 51.16 AZIMUTH M.D. ff 1 2 3 4 5 2800 127.71 127.23 127.33 127.56 127.40 gyro/data B.P. EXPLORATION E PAD, WELL NO. MPE-22 MILNE POINT FIELD, ALASKA Gyro Multishot Survey in 5.5" drill pipe Survey date: 18 June, 1995 Job number · AK0695G272 RECEIVED MAY 0 3 1996 Alaska 0ti & Gas Cons. Co~i~ SR272.DOC Gyrodata Incorporated P.O. Box 79389 Houston, Texas 77279 713t461-3146 Fax: 713/461-0920 July 25, 1995 Ms. Terrie Hubble B.P. Exploration Prudhoe Bay Drilling Department 900 E. Benson Blvd. Anchorage, AK 99508 MB 12-1 Re: E Pad Well No. MPE-22, Milne Point Field,Alaska Dear Ms. Hubble, Enclosed please find one (1) original and three copies (3) of the completed survey of Well #MPE-22 We would like to take this opportunity to thank you for using Gyrodata and we look forward to serving you in the future. 'Sincerely n Robert J. Shoup. Operations Manager RS/gr Serving the Worldwide Energy Industry with Precision Survey Instrumentation gyro/data CONTENTS JOB NUMBER · AK0695G272 1. DISCUSSION, SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR272.DOC gyro/data 1. DISCUSSION, SURVEY CERTIFICATION SHEET SR272.DOC gyro/data DISCUSSION JOB NUMBER' AK0695G272 Tool 136 was run in MPE-22 on ATLAS 5/16" Wireline inside 5.5" drill pipe. The survey was run without problems. SR272.DOC gyro/data SURVEY CERTIFICATION SHEET JOB NUMBER: AK0695G272 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the wellsite. Checked by :- TIM ANDERSON OPERATIONS ENGINEER SR272.DOC gyro/data 2. SURVEY DETAILS SR272.DOC gyro/data SURVEY DETAILS JOB NUMBER: AK0695G272 CLIENT: B.P. EXPLORATION RIG: NABORS 22E LOCATION: MILNE POINT WELL: MPE-22 LATITUDE: 70.455 N LONGITUDE: 149.5 W SURVEY DATE: 18-June, 1995 SURVEY TYPE: MULTISHOT IN 5.5" drill pipe DEPTH REFERENCE: MAX. SURVEY DEPTH: ROTARY TABLE EVELATION 53.9 asl 5000' SURVEY TIED ONTO: N/A SURVEYINTERVAL: 100' 30' (5000-4100') UTM CO-ORDINATES: TARGET DIRECTION: 126.32 GRID CORRECTION: CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: STODDARD SR272.DOC gyro/data 3. OUTRUN SURVEY LISTING SR272.DOC A Gy r o a a ~ a $ z r e c ~ m o n a I S u r v e y for B.P. EXPLORATION WELL: E-PAD ~MPE-22 Location: MILNE POINT FIELD, ALASKA Job Number: AK0595G272 Run Date: 18-Jun-95 17:00:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.455000 deg. N Sub-sea Correction from Vertical Reference: 53.9 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction- 126.320 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gy r o da t a D i r e c t i on a I S u rve y B.P. EXPLORATION WELL: E-PAD #MPE-22 Location: MILNE POINT FIELD, Job Number: AK0595G272 ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet SUBSEA DEPTH feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg. / feet deg. 100 ft. H O R I Z O N T A L COORDINATES feet 2100.0 32.73 128.60 2033.2 2200.0 35.36 128.25 2116.0 2300.0 36.99 128.87 2196.7 2400.0 38.79 128.91 2275.6 2500.0 40.64 128.42 2352.6 363.6 419.5 478.5 539.9 603.7 1979.3 2062.1 2142.8 2221.7 2298.7 2.71 363.6 125.8 2.64 419.5 126.1 1.67 478.5 126.4 1.79 539.9 126.7 1.88 603.7 126.9 212.59 S 294.98 E 247.37 S 338.84 E 284.17 S 384.99 322.72 S 432.79 ~ 362.64 S 482.68 E 2700.0 48.50 128.t2 2494.9 2800.0 50.96 128.12 2559.6 2900.0 51.14 127.45 2622.4 3000.0 52.71 127.30 2684.1 3100.0 55.43 127.04 2742.8 743.9 820.1 897.9 976.6 1057.5 2441.0 2505.7 2568.5 2630.2 2688.9 3.93 743.9 127.2 2.46 820.2 127.3 .56 898.0 127.3 1.57 976.7 127.3 2.73 1057.7 127.3 449.49 S 592.80 E 496.59 S 652.81 E 544.24 S 714.28 E 592.02 S 776.83 E 640.93 S 841.35 E 3200.0 58.57 127.49 2797.2 3300.0 61.46 126.84 2847.2 3400.0 62.63 125.48 2894.1 3500.0 63.19 124.39 2939.6 3600.0 65.25 124.71 2983.1 1141.4 1228.0 1316.3 1405.3 1495.3 2743 . 3 2793 .3 2840.2 2885.7 2929.2 3.16 1141.5 127.3 2.95 1228.1 127.3 1.68 1316.4 127.2 1.12 1405.4 127.1 2.08 1495.4 126.9 691.71 S 908.08 E 744.02 S 977.10 E 796.13 S 1048.42 E 847.11 S 1121.41 E 898.17 S 1195.56 E 3700.0 66.21 125.21 3024.2 3800.0 65.89 125.03 3064.8 3900.0 64.71 124.42 3106.6 4000.0 63.55 126.74 3150.3 4100.0 65.05 126.94 3193.6 1586.4 1677.8 1768.6 1858.6 1948.7 2970.3 3010.9 3052.7 3096.4 3139.7 1.07 1586.5 126.8 .36 1677.8 126.7 1.30 1768.6 126.6 2.39 1858.6 126.6 1.51 1948.7 126.6 950.42 S 1270.27 1002.99 S 1345.02 1054.75 S 1419.69 1107.09 S 1492.86 1161.11 S 1564.97 4130.0 65.64 123.00 3206.1 4160.0 65.98 124.05 3218.4 4190.0 65.87 126.62 3230.7 4220.0 65.69 125.87 3243.0 4250.0 65.73 125.78 3255.3 1975.9 2003.2 2030.6 2058.0 2085.3 3152.2 3164.5 3176.8 3189.1 3201.4 12.08 1975.9 126.6 3.39 2003.2 126.5 7.83 2030.6 126.5 2.36 2058.0 126.5 .32 2085.3 126.5 1176.74 S 1587.31 E 1191.85 S 1610.12 E 1207.69 S 1632.46 E 1223.87 S 1654.53 E 1239.88 S 1676.70 E A Gyro d a t a D i r e c t i o n a i S u r v e y B.P. EXPLORATION WELL: E-PAD #MPE-22 Location: MILNE POINT FIELD, Job Number: AK0595G272 ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet SUBSEA DEPTH feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg. / feet deg. 100 ft. HORIZONTAL COORDINATES feet 4280.0 65.16 124.93 3267.8 4310.0 65.00 123.75 3280.4 4340.0 64.49 126.49 3293.2 4370.0 64.58 126.20 3306.1 4400.0 65.04 124.26 3318.9 2112.6 2139.8 2166.9 2194.0 2221.1 3213.9 3226.5 3239.3 3252.2 3265.0 3.21 2112.6 126.5 3.61 2139.8 126.4 8.43 2166.9 126.4 .91 2194.0 126.4 6.05 2221.1 126.4 1255.67 S 1271.01 S 1286.62 S 1302.67 S 1318.33 S 1698.95 E 1721.42 E 1743.61 1765.42 ~ 1787.59 E 4430.0 65.69 124.56 3331.4 4460.0 65.82 124.67 3343.7 4485.0 65.79 124.07 3354.0 4520.0 65.71 125.45 3368.4 4550.0 65.54 125.75 3380.7 2248 2275 2298 2330 2357 .4 .7 .5 .4 .8 3277.5 3289.8 3300.1 3314.5 3326.8 2.36 2248.4 126.4 .54 2275.7 126.4 2.19 2298.5 126.3 3.59 2330.4 126.3 1.06 2357.8 126.3 1333.74 S 1349.28 S 1362.16 S 1380.35 S 1396.26 S 1810.09 E 1832.60 E 18'51.42 E 1877.64 E 1899.86 E 4580.0 66.20 125.50 3393.0 4610.0 66.92 125.54 3404.9 4640.0 67.15 125.48 3416.6 4670.0 66.87 123.64 3428.4 4700.0 66.80 124.01 3440.2 2385 2412 2440 2467 2495 .1 .6 .3 .9 .4 3339.1 3351.0 3362.7 3374.5 3386.3 2.31 2385.1 126.3 2.40 2412.6 126.3 .79 2440.3 126.3 5.73 2467.9 126.3 1.15 2495.4 126.2 1412.21 S 1428.20 S 1444.24 S 1459.91 S 1475.26 S 1922.11 E 1944.51 E 1967.00 E 1989.74 E 2012.65 E 4730.0 66.65 124.15 3452.0 4760.0 66.41 124.14 3464.0 4790.0 66.20 124.51 3476.0 4820.0 65.96 124.62 3488.2 4850.0 66.26 123.78 3500.3 2523 2550 2577 2605 2632 .0 .5 .9 .3 .7 3398.1 3410.1 3422.1 3434.3 3446.4 .67 2523.0 126.2 · 80 2550.5 126.2 1.34 2577.9 126.2 · 87 2605.3 126.2 2.75 2632.7 126.1 1490.70 S 1506.15 S 1521.64 S 1537.19 S 1552.61 S 2035.48 ~ 2058.25 ~1 2080.94 E 2103.52 E 2126.21 E 4880.0 66.40 124.16 3512.4 4910.0 66.41 124.24 3524.4 4940.0 66.24 124.02 3536.4 4970.0 65.85 124.86 3548.6 5000.0 65.72 123.12 3560.9 2660.2 2687.7 2715.1 2742.5 2769.9 3458.5 3470.5 3482.5 3494.7 3507.0 1.26 2660.2 126.1 .26 2687.7 126.1 .89 2715.1 126.1 2.84 2742.5 126.1 5.31 2769.9 126.0 1567.96 S 1583.42 S 1598.83 S 1614.34 S 1629.63 S 2149.00 E 2171.73 E 2194.47 E 2217.08 E 2239.77 E A Gyro da t a D i r e c t i ona i Survey B.P. EXPLORATION WELL: E-PAD #MPE-22 Location: MILNE POINT FIELD, ALASKA Job Number: AK0595G272 Page MEASURED I N C L AZIMUTH VERTICAL VERTICAL SUBSEA DEPTH DEPTH SECTION DEPTH feet. deg. deg. feet feet feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100ft. HORIZONTAL COORDINATES feet Final Station Closure: Distance: 2769.89 ft Az: 126.04 deg. A Gyro d a t a D i r e c t i o na i Survey for B.P. EXPLORATION WELL: E-PAD #MPE-22 Location: MILNE POINT FIELD, ALASKA Job Number: AK0795G272SS Run Date: 18-Jun-95 17:00:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.455000 deg. N Sub-sea Correction from Vertical Reference: 53.9 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 126.320 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyro d a t a D i r e c t i on a i Survey B.P. EXPLORATION WELL: E-PAD #MPE-22 Location: MILNE POINT FIELD, Job Number: AK0795G272SS ALASKA Page SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG CLOSURE DEPTH DEPTH SECTION SEVERITY DIST. AZIMUTH feet deg. deg. feet feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet -53.9 0.00 0.00 0.0 0.0 0.00 0.0 0.0 0.00 N 0.00 E 0 - 5000 PT. GYRO SURVEY RUN IN 5 1/2" DRILLPIPE. MEASURED DEPTHS ARE REFERENCED TO AN R.K.B. HEIGHT OF 53.9 PT. ABOVE SEA LEVEL. 100.0 .10 146.05 153.9 -.1 .12 .2 308.2 200.0 .12 358.30 253.9 -.2 .11 .4 331.6 300.0 .18 358.41 353.9 -.4 .11 .6 345.0 400.0 .26 25.43 453.9 -.5 .13 1.0 357.3 500.0 .62 64.46 553.9 -.2 .47 1.6 22.8 600.0 1.46 99.02 653.9 1.3 .96 3.5 59.6 700.0 2.68 108.15 753.9 4.7 1.25 7.8 87.0 800.0 4.06 111.96 853.9 10.3 1.40 14.6 99.5 900.0 5.05 113.92 953.9 18.1 1.00 23.3 105.4 1000.0 6.14 114.09 1053.9 27.7 1.09 33.8 108.4 1100.0 8.63 117.12 1153.9 40.4 2.52 48.3 110.7 1200.0 11.35 124.03 1253.9 57.9 2.99 67.4 113.7 1300.0 12.99 127.17 1353.9 79.4 1.79 89.3 117.0 1400.0 15.01 127.07 1453.9 104.3 1.99 114.4 119.4 1500.0 18.65 126.94 1553.9 134.5 3.54 145.1 121.1 1600.0 21.70 128.24 1653.9 171.2 2.85 180.9 122.5 1700.0 23.63 128.57 1753.9 212.9 1.76 220.0 123.7 1800.0 27.45 128.71 1853.9 260.3 3.64 263.5 124.6 1900.0 30.22 128.81 1953.9 315.3 2.34 363.6 125.3 2000.0 33.39 128.51 2053.9 377.6 2.69 419.5 125.9 .09 N .10 W .25 N .12 W .50 N .12 W .85 N .10 E 1.15 N .57 E .98 N 2.30 E .72 S 5.76 E 2.12 S 11.26 E 5.26 S 18.58 E 9.25 S 27.53 E 14.95 S 39.15 E 24.11 S 54.13 E 36.74 S 71.58 E 51.76 S 91.43 E 69.92 S 115.53 E 92.32 S 144.62 E 118.26 S 177.27 E 147.88 S 214.34 E 182.36 S 257.27 E 221.30 S 305.96 E A Gyro da t a D i r e c t i ona i Survey B.P. EXPLORATION WELL: E-PAD ~MPE-22 Location: MILNE POINT FIELD, Job Number: AK0795G272SS ALASKA Page SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG DEPTH DEPTH SECTION SEVERITY feet deg. deg. feet feet deg./ 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 2100.0 36.13 128.54 2200.0 38.29 128.90 2300.0 40.71 128.42 2400.0 46.23 128.21 2500.0 50.74 128.12 2153.9 2253.9 2353.9 2453.9 2553.9 447.2 523.0 605.0 703.5 813.4 2.19 1.76 1.90 3.34 2.59 478.5 126.3 539.9 126.6 743 . 9 126.9 743.9 127.1 820.2 127.3 264.65 S 360.51 E 312.10 S 419.62 E 363.45 S 483.71 P 424.45 S 561.05 E 492.46 S 647.55 E 2600.0 51.94 127.37 2700.0 56.07 127.13 2800.0 61.63 126.65 2900.0 63.86 124.49 3000.0 65.98 125.08 2653 2753 2853 2953 3053 .9 .9 .9 .9 .9 938.0 1074.6 1240.5 1434..8 1653.2 1.07 2.82 2.77 1.44 .55 976.7 127.3 1141.5 127.3 1316.4 127.3 1495.4 127.0 1677.8 126.7 568.62 S 746.19 E 651.30 S 854.97 E 751.44 S 987.26 E 863.85 S 1145.71 E 988.83 S 1324.88 E 3100.0 63.67 126.76 3200.0 65.73 125.79 3300.0 65.79 124.08 3400.0 66.61 124.15 350'0.0 65.80 124.11 3153.9 3253.9 3353.9 3453.9 3553.9 1866.1 2082.2 2298.4 2527.3 2754.3 2.31 .55 2.18 .69 3.90 1948.7 126.6 2085.3 126.5 2298.5 126.3 2550.5 126.2 2769.9 126.1 1111.63 S 1498.92 E 1238.03 S 1674.14 E 1362.06 S 1851.29 E 1493.14 S 2039.07 E 1620.91 S 2226.82 E 3507.0 65.72 123.12 3560.9 2769.9 5.31 2769.9 126.0 1629.63 S 2239.77 E Final Station Closure: Distance: 2769.89 ft Az: 126.04 deg. gyro/data 4. QUALITY CONTROL SR272.DOC Quality Control Comparisons B.P. EXPLORATION WELL: E-PAD #MPR-22 Location: MILNE POINT FIELD, Job Number : AK0595G272 / Comparison ALASKA / AK0595G272 Depth Inc Inc Delta 200.0 .27 .11 .167 500.0 .70 .30 .400 1000.0 5.44 5.33 .109 1500.0 15.98 15.93 .053 2000.0 30.11 30.02 .085 2500.0 40.45 40.64 -.190 3000.0 52.72 52.71 .011 3500.0 63.48 63.19 .293 5000.0 65.69 65.72 -.037 Az 34.84 53.76 113.86 126.65 128.04 127.91 126.55 125.20 123.11 For Inclinations Greater than 10 degrees: Average Inclination Difference = .03579 deg. Average Azimuth Difference = -.2914 deg. Az 20.93 34.30 113.85 127.14 128.83 128.42 127.30 124.39 123.12 Delta 13.916 19.461 .013 -.490 -.793 -.516 -.747 .808 -.011 gyro/data QUALITY CONTROL REPORT JOB NUMBER: AK0695G272 TOOL NUMBER: 136 MAXIMUM GYRO TEMPERATURE: 75.0c MAXIMUM AMBIENT TEMPERATURE: 38.0 c MAXIMUM INCLINATION: 60.8 AVERAGE AZIMUTH: 126.32 WIRELINE REZERO VALUE: O' correction REZERO ERROR / K: n/a CALIBRATION USED FOR FIELD SURVEY: 6/29/95 CALIBRATION USED FOR FINAL SURVEY: 6/29/95 PRE JOB MASS BALANCE OFFSET CHECK: -.66 POST JOB MASS BALANCE OFFSET CHECK: -.80/120 TF,-.3/40 TF USED CONDITION OF SHOCK WATCHES .UPON ARRIVAL AT RIG: OK UPON COMPLETION OF SURVEY: OK UPON RETURN TO ATLAS OK BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH TVD NORTHING EASTING FIELD SURVEY FINAL SURVEY 5000 65.72 123.12 3560.4 1630.3S 2238.65E 5000 65.72 123.12 3560.9 1629.63S 2239.77E SR272.DOC gyro/data FUNCTION TEST JOB NUMBER: AK0695G272 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft 1 2 3 4 5 2600 44.13 44.13 44.13 44.13 44.13 AZIMUTH M.D.~ 1 2 3 4 5 2600 128 128 128 128 128 SR272.DOC gyro/data 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR272.DOC gyro/data EQUIPMENT REPORT JOB NUMBER: AK0695G272 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 136 GYRO SECTION A0099 DATA SECTION A0025 POWER SECTION A0052 BACKUP TOOL No. 080 GYRO SECTION A0094 DATA SECTION A0029 POWER SECTION A0027 COMPUTER POWER SUPPLY PRINTER INTERFACE COMPUTER POWER SUPPLY PRINTER INTERFACE A0153 A0055 A0079 A0071 A0122 A0032 A0082 A0035 WIRELINE COMPANY: CABLE SIZE: ATLAS WIRELINE 5/16" RUNNING GEAR 2 1/4" System TOTAL LENGTH OF TOOL: MAXIMUM O.D.: 31.5 feet 2.25 INCHES TOTAL WEIGHT OF TOOL: 240Lbs SR272.DOC gyro/data CHRONOLOGICAL REPORT JOB NUMBER: AK0695G272 6/16/95 0900 6/17/95 6/18/95 1300 1400 1640 1700 1800 1920 1945 2030 2145 2345 6/19/95 0145 0400 FINISH MPL-16, STAND BY STAND BY, C PAD NOT READY, ATLAS STANDING BY FOR FRAC MU TOOL. 136 STANDBY TOOL RUNNING. PU TOOL ,ZERO TOOL. MU PACK OFF. START INRUN. PUMP TOOL DOWN 5000'. 1800' LD TOOL. RD ATLAS AND BD TOOL. RETURN ATLAS, CHECK TOOL, POST RUN CAL CHECK. PROCESS SURVEY. FAX TO RIG. RETURN RIG. DETERMINE REFERENCE POINT. MILNE POINT CAMP FOR JOB 8 A.M. TOMORROW. SR272.DOC TO: Schlumberger - GeoQuest A Division of Schlumberger Technologies Corporation 500 W. International Airport Road Anchorage, Alaska 99518 - 1199 (907) 562-7669 (Bus.) (907) 563-3309 (Fax) August 29, 1995 . BP Exploration (Alaska)Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. ", Anchorage, Alaska 99519-6612 The following data of the I.,WD DEPTH CORRECTED CDR/CDN & CDR/CDN TVD for well IVIP~-22, Job # 952~2 was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612. 1 OH LIS Tape 3 Bluelines each 1 Film each Returning CDR/CDN, CDR/CDN TVD field film State of Alaska Alaska Oil & Gas Conservation Comm. Attn: Larry Grant 3001 Porcupine Drive . Anchorage, Alaska 99501 ---" . 1 OH LIS 'Fape 1 Blueline.each 1 RF Sepia each OXY USA, Inc Attn: Darlene Fairly P.O. Box 50250 Midland, Texas 79710 1 OH LIS Tape 1 Blueline each 1 RF Sepia each Sent Certified Mail P 905 127 893 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP EXPLORATION (ALASKA)Il,lC. SCHLUMBERGER PETROTECHNICAL DATA CENTER, MB3-3 500 WEST INTERNATIONAL AIRPOR~'f' F~OAD 900 EAST BENSON BLVD. ANCHORAGE, ALA~9~I~-I:'J'~ 41asko 0il & Schlumberge Date Received By: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 15 August 1995 Transmittal of Data ECC #: 6468.00 Sent by: ANCH.EXPRESS Data: GR/CCL Dear Sir/Madam, Reference: BP MPE-22 MILNE POINT / KUPARUK NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 LDWG TAPE + LIS Received by: Please sign and return to: Attn. Rodney D. Paulson '-- ~inesu£t~ 201 Services .~~ ~FCF/~FD // 5600 B_~treet AX/~(907) 563-7803 ' ..~~8-'' TM ~ -~ .... ,#88/00 LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Reference: BP MPE-22 MILNE POINT / KUPARUK NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 1 GR/CCL FINAL BL+RF GR/CCL(TCP)FNL BL+RF Date: RE: 8 August 1995 Transmittal of Data ECC #: 6468.00 Sent by: ANCH.EXPRESS Data: GR/CCL Run # 1//~ Run # 1 Please sign and return to: ~tn. Rodney D. Paulson At~s Wireline Servi~---~ 5600~~__Street Suite . Anchorage,/~99518 563-?803 Received b~/ ~ ~/~-'"~/ Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation Shutdown X Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing __ Variance __ Perforate __ Other __ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3825' NSL, 2104' WEL, SEC. 25, T13N, RIOE 5. Type of Well: Development x Exploratory __ Stratigraphic __ Service At top of productive interval 9. Datum elevation (DF or KB) KBE=54 Unit or Properly name Milne Point Unit Well number MPE-22 Permit number At effective depth At total depth 2810' SNL, 1756' EWL, SEC. 32, T13N, R11E 95-81 10. APl number 50- 029-22567 11. Field/Pool Milne Point / Kuparuk River Sands feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 80' Surface 3713' Intermediate 14271' Production Liner Perforation depth: measured None 14332 7336 Size 20" 9-5/8" 7" true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None feet feet feet feet Plugs (measured) Junk (measured) ORIGINAL Cemented 160 sx AS (Approx) 800 sx PF 'E', 250 sx 'G' 310 sx 'G' Measured depth 112' 3~5' 143O0' True vertical depth 112' 3039' 7322' RECEIVED JUL 0 5 1995 Alas~ 0il & Gas Cons. C0mr~/ssi0n ;,, 13. Attachments Description summary of proposal X Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 07/O4/95 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas__ Suspended__ Service 17. I hereby certi.fy that the fortegoing i~ t, rue and correct to the best of my knowledge. Signed ~ ~'J~~FOR COMMISSIoNTitle Drilling EngineeringSuperviSOruSE ONLY Date Conditions of approval: Notify~ommission so representative may witness \_ ~ . r-, I Approval No.,o, z.~,_.. /...)/~ I Plug integrity BOP Test Location clearance ~ ~'' 7..~ ,~..~-(.., I Mechanical Integrity Test Subsequent form required 10- ~0 _'~'/" ,~lSi"~ved Copy Returned _~ Original Signed By ,-, Y_~_/~Z~~ Date 7/ /¢~ J Approved by order of the Commission I')avid W, Johnston --..'o,.~o~r,~r,, o Form 10-403 Rev 06/15/88 , SUBMIT IN TRIPLICATE BP EXPLORA]'ION Memorandum To: Terri Hubble Date: 7/3/95 From: Ding Hsu Subject: MP E-22 Operation Shutdown Request Please prepare an "Application for Sundry Approvals" from AOGCC for Nabors 22E operation shutdown on well MP E-22. Due to well spacing and rig move constraints on E-pad, it is recommended to shut-down 22E's operation after cementing the 7" casing across reservoir and leave the well for rig 4ES to complete. Nabors 22E will move to well E-23 after E-22 shut down and Nabors 4ES will move to E-22 after C-09 RWO. If you have any question please let me know X-5061. Gas Cons. Commission Anch0ra;.;r' ALASKA OIL AND GAS / CONSERVATION COMI~SSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 June 7, 1995 Adrian.Clark Drilling Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPE-22 BP Exploration (Alaska), Inc. Permit No. 95-81 Sur. Loc. 3825'NSL, 2104'WEL, Sec. 25, T13N, R10E, UM Btmnhole Loc. 2355'NSL, 3395'WEL, Sec. 32, T13N, RILE, 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 er at 659-3607. David W. (JohnstOn ~~ BY ORDER OF 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 20 AAC 25.005 la. Type of work Drill [] Redrill I-Illb. Type of well. Exploratoryl-1 Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenFII 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= 54 feet Milne Point / Kuparuk River 3. Address 6. Property Designation Sands P. O. Box 196612, Anchorage, Alaska 99519-6612 028231 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 2o AAC 25.025) 3825' NSL, 2104' WEL, SEC. 25, T13N, RIOE Milne Point Unit At top of productive interval 8. Well number Number 2835' NSL, 4045' WEL, SEC. 32, T13N, R11E MPE-22 2S100302630-277 At total depth 9. Approximate spud date Amount 2355' NSL, 3395' WEL, SEC. 32, T13N, R11E 06/09/95 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and TVD) property line 375133/2355 feet No close approach feet 2560 14498'/7370' feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth 500 feet Maximum hole angle sz o Maximum surface 2810 psig At total depth (TVD) 7000'/3510 psig 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80 32 32 112 112 12-1/4" 9-5/8" 40# L-80 Btrc 3569 31 31 3600 2984 711 sx PF 'E', 250 sx 'G', 250 sx PF 'E' 8-1/2" 7" 26# L-80 Btrc 14468 30 30 ¢5ECJ~ 7370 596 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 de ~.~)True Vertical depth Structural Conductor Surface Intermediate ,~iO~,~ -' 5 Production .& G~S 60f~S. Liner Perforation depth: measured '- ...... L '~rt, g~Of;, true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed reportE] 20 AAC 25.050 requirements[] 21. I hereby c(~jtify that the foregoing is true and correct to the best of my knowledge Signed ~/~/,tr/,,.~ ~~ ~ Title Drillin~l Enceerin~t Supervisor Date "' -- ~ v ' ~i / ' -- Commission Use Only Permit Number IAPI number Approval date See cover letter ~,.¢-- ~/ 150-~c,2_7-- ~.-~---.5'~' ,~ ~--- 7----~_~~-- for other requirements Conditions of approval Samples required [] Yes J;~ No Mud Icg required []Yes [] No Hydrogen sulfide measures [] Yes J2~ No Directional survey required ~ Yes [] No Required working pressure for BOPE [] 2M; i-13M; ~iii[,5M; []10M; F-I15M; Other: ~jrigina! Signed By by order of~/7/? Approved by David W. Johnston Commissioner [ne commission Date Form 10-401 Rev. 12-1-85 Submit ,_,ate I Well Name: I MPE-22 Well Plan Summary Type of Well (producer or injector): I Kuparuk Producer Surface Location: Target Location: Bottom Hole Location: 3825 NSL 2104 WEL Sec 25 T13N R10E UM., AK. 2835 NSL 4045 WEL Sec 32 T13N R11E UM., AK. 2355 NSL 3395 WEL Sec 32 T13N R11E UM., AK. I AFE Number: 1330130 I Estimated Start Date:I 6/9/95 I Rig: I Nabors22-E I Operating days to complete: I 20 IMD: I 14498' I I TVD: 17370' bkb I IKBE: I54' Well Design (conventional, slimhole, etc.):I Milne Point Ultra Slimhole 7LS Formation Markers: Formation Tops M D TVD (bkb) base permafrost 1846 1814 NA 6941 4329 Top of Schrader Bluff Sands (8.3 ppg) O B 7426 4524 (8.3 ppg) Seabee Shale 7513 4559 Base of Schrader Bluff Sands (8.3 ppg) HRZ 12073 6394 High Resistivity Streak Top Kup 13017 6774 Kuparuk Cap Rock Top C1 Sand-- 13614 7014 Target Sand 1 (9.7 ppg) Target Top B7 Sand 13768 7076 Target Sand 1 (9.7 ppg) Total Depth 14498 7370 Casing/Tubing Program: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVD 24" 20" 91.1 # H-40 Weld 80 32/32 11 2/112 12 1/4" 9 5/8" 40# L-80 btrc 3569 31/31 3600/2984 8 1/2" 7" 26# L-80 btrc 14468 30/30 14498/7370 Internal yield pressure of the 7" 26# casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 7000 TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3510 psi is 2810 psi, well below the internal yield pressure rating of the 7" casing. Gas Con.~. Comm. issio~ Anchor: 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. PDC Bit f/Seabee to TD w/MWD Dir and LWD (GR/CDR/CDN). GR/CCL will be run in 7" casing to locate the TCP Guns. CBL run only if necessary. Mud Logging is not required. Mud Program: ISpecial design considerations INone- 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 min pH Fluid (PPG) Viscosity Point gel gel Loss Production Mud Properties: I None- LSND freshwater mud Density Marsh Yield 10 sec 10 min 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 10.4 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: I KOP: 1500' IMaximum Hole Angle: Close Approach Well: 67 degrees (No Shut Ins) Disposal: Cuttings Handling: Central Reserve Pit while the Kuparuk Bridge is out; otherwise CC2A. Fluid Handling: All drilling and completion fluids can be annular injected. Annular Injection: The MPE-22 annulus is permitted for drilling & completion fluid injection. DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. AREA WELL PREV VOL !PERMITTED PERMITTED INJECTED VOL DATES (BBLS) (BBLS) Milne Point M PE-22 0 35,000 1/1/95-12/31/95 Milne Point MPE-10 5000 35,000 1/1/95-12/31/95 Milne Point M PE-09 5000 35,000 1/1/95-12/31/95 FREEZE PROTECTION' Pay close attention to annulii being used for disposal so to avoid freezing. Sometimes the annulii are kept open by ensuring that an adequate volume (+60 bbls) is injected every 6-12 hours. This practice is more economical than pumping 60 bbls of diesel freeze protection every time the pumps are shut down; however, if this practice is used, it is important that the injection frequency into the annulus be adequate to prevent freeze ups -- the drillers must communicate to each other the last time the annulus was injected into to avoid freezing. 1. 2. 3. 4. 5. MPE-22 Proposed Summary of Operations Drill and Set 20" Conductor. Weld a starting head and top job nipple 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). 6. ND 20" Diverter, NU and Test 13-5/8" BOPE. 7. RIH w/Insert bit on Low Speed/High Torque Motor, and Directional MWD and LWD CDR (GR/RES). Test 9-5/8" casing to 3000 psig, Drill out float equipment and 10 feet of new formation, Perform a LOT (Do not exceed 12.5 ppg). 8. 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. 9. MU a Hughes R417G PDC bit on a turbine, with Directional/Gamma Ray, Resistivity/Neutron/Density (Triple Combo) MWD/LWD tools. RIH. 10. 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 (G R/Res/Neu/Dens). 11. 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. 12. POOH & PU Drill Pipe Conveyed Perforating Guns. RIH and Set Packer. Perforate the well underbalance. Kill well while circulating 10.2 ppg kill weight brine. 1 3. POOH laying down 3-1/2" Drill Pipe. 14. Change Rams and run the ESP on 2-7/8" Threaded Tubing with the Nabors 22-E Rig. 15. ND BOPE, NU and Test Tree. RDMO Nabors 22E drilling rig to drill next well. 16. Install Surface Lines and Wellhouse and put the well on production. Drilling Hazards and Risks: 1. There was evidence of shallow gas/hydrates in the E-Pad area (E-7,8, 9, 10, and 11); therefore, the MW schedule requires 9.5ppg by 2000' tvd. This practice was applied on the MPE-9 and E-20 wells and there was no evidence of hydrate problems while drilling the surface hole. MPE-IO and MPE-11 required 10.0 and 10.5 ppg respectively; therefore, the well plan will advise crews to be prepared to weight up accordingly. . The MPE-09 encountered pore pressure in this Kuparuk fault block that was 1.7 ppg above what was expected (11.6 ppg vs 10.1). This resulted trouble time and costs associated with the well kill incident being complicated with the Schrader Bluff sand exposed. As a result, the MPE-IO and MPE-11 well designs were modified to top set the Kuparuk with a 7" casing and drill the Kuparuk reservoir with 6" hole and set a 5" liner. However, the production from the MPE-09 and MPE-11 wells has effectively relieved the overpressure in this fault block to 9.7 ppg EMW. This was determined via bottom hole static gauges run in the MPE-05 injector in April 1995. The MPE-05 well was returned to water injection shortly after that with strict instructions that the daily MPE-05 injection is not to exceed the daily production from the MPE-09 and MPE-11 wells. Bryce Cunningham is tracking this data on a weekly basis. 3. No other drilling hazzards or risks have been identified for this well. MPE-22 WELL 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 9-5/8" SPACER: 75 bbls fresh water. LEAD CEMENT TYPE: ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX #SACKS: 711 TAIL CEMENT TYPE: ADDITIVES: 2.0% CaCI2 WEIGHT: 15.8 ppg APPROX #SACKS: 250 CIRC. TEMP 50 deg F at 2500' TVDSS. Type E Permafrost YI ELD:2.17 ft3/sx M IX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. Premium G YIELD:I ,15 ft3/sx MIX WATER: 5.0 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. FLUID LOSS: 100-150 cc FREE WATER: 0 TOP JOB CEMENT TYPE: Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg gal/sk APPROX NO SACKS: 250 YIELD:2.17 ft3/sx E MIX WATER: 11.63 CENTRALIZER PLACEMENT: 1. I Bowspring 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: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 bpm. Mix 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 surface with 100% excess. 4. 80'md 9-5/8", 40# capacity for float joints. 5. Top Job Cement Volume is 250 sacks. RECEIVED - 5 ~!~ 0ii .& Gas Cons. Commission 11 CEMENT MPE-22 PRODUCTION CASING PROGRAM- HALLIBURTON STAGE I CEMENT JOB ACROSS THE KUPARUK INTERVAL: CIRC. TEMP: SPACER: 140° F BHST 170 deg F at 7040' TVDSS. 20 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk APPROX # SACKS: 286 FLUID LOSS: < 50cc/30 min @ 140° F STAGE II CEMENT JOB ACROSS THE SCHRADER MIX WATER: 5.0 gal/sk THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F FREE WATER: 0cc @ 45 degree angle. BLUFF SANDS: CIRC. TEMP: SPACER: LEAD CEMENT TYPE: 60° F BHST 80 deg F at 7040' TVDSS. 20bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. Type E Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX #SACKS: NONE TAIL CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.2% Halad 344 WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk APPROX # SACKS: 31 0 FLUID LOSS: 100-150 cc YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. MIX WATER: 5.0 gal/sk THICKENING TIME: 4 hours @ 50 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" Casing (52 total). This will cover 200' above the C Sand. 2. 7" x 8-1/4"Straight Blade Rigid Centralizers-- one per joint from 5600' - 4850' to cover the Schrader Bluffs Sands (21Total). 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 74. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is not necessary. CEMENT VOLUME: 1. Stage I cement volume is calculated to cover 1000' md above the C Sand with 30% excess. 2. Stage 2 cement volume is calculated to cover from the OG base to the to 1000' above the NA Top with 30% excess. --- £i iiii i · SHAR'I '''D SERV [CES 14~rker ~.d.-n(i'ti~tied I~D BKB SECTlt ' INCLI~ A) KB 0 0 0 0.00 i))BUILO l/lO0 500 500 0 0.00 C) BUILD i,5/~00 800 800 7 3.00 D) CURVE 2,19/100 IlO0 i099 34 7,50 E) BUILD ~,5/I00 1400 i393 B? i3.50 Fi CURVE 3/100 3000 2701 952 53.50 ${ END 3/100 CURVE- 3429' 29i5 i322 65:27 HJ 9-5/8" CASING POIN] 3500 2984 1479 65.27 lJ '- ...... IARGEI ....... 13614 7014 10646 66.27 d] 7' CASII~G.POIffT 14498 7370 ii456 55.27 K) 'lO 14498 7370 i i456 66.27 DR_TL EZNG · ii iiii i lllJ ii i ! i ii · i i I IL ANADRILI. AKA-DPC APPROVED JUN d 5 1995 m , iii i iii i ii il , ~lnadrY. l ] Sch]umbe~ge~ .... NPE-,22 (P8) VERT I CAL SECT I ON Section at: '$26.32 Tvo-Scale ' I inch = 1600 feet Dep'Scale.:' '! 'int'h ~ 1600 'feet" i I_ I i 11111 illin,i ii I Il VIEN _ i 11 ill 11 ,,,_ iNII'JAL . 0 900 1600 2400 3200 44]00 4800 5600 6400 7200 8000 8800 9§00 t0400 I i200 12000 12800 13600 ........... Sec[ ion Oep'~rtude I~na~r)lL [d93 ~'.PF...2ZPi{ 81.52 { 51 ~ il C Z I I SHARED SERV C '$. DRILLING' ........................ [tPE-22 P~ VI[~ . , ..... CLOSURE ' · OB --- - ......... i~u~un~ ...... J lq~O I~l ~ ~ZIIIIU[II 1~1 ~ (~ ....... ~Di[I[[ ............ -p:K~-B¢(~ .......... ISClZ'[~..'.'.': 2' 'i'"fneh'"= i~6~' ~e~ ............ ~ ......... .. f !NI:~AL ~ ~- C] BUILD ].5/]00 800 3 Anchor: ~ ....... ' .... ,, ,, , ~" . . .............. : .... ~ ' : "-;. ............. '1 ~°°~~~~~~' - .....'" L. m : i ii ii i -- -~ ~ I- .................... ~ .. 700 0 700 ~400 ;~ 100 2800 3500 ~0() 4900 5600 6300 7000 7700 8400 9 tOQ 9~0 t050.O ! !200.._119.00 . ~'"'i~51" EAST -:'~ ......................................... lc)g3 ~E~8 I)1.52 IO:OO ,AK I) ¢- Z I (J'l I (:3 WELL PERMIT CHECKLIST F, .LD PO L GEOL AREA ~cT~ UNIT# PROGRAM: exp [] dev~ redrll [] ///3-2-~ ON/OFF SHORE ADMINISTRATION ENGINEERING 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. Permit fee attached .................. Lease number appropriate ............... Unique well name and number .............. Well located in a defined pool .............. Well located proper distance from drlg unit boundary. Well located proper distance from other wells ..... Sufficient acreage available in drilling unit ..... If deviated, is wellbore plat included ........ Operator only affected party ............... Operator has appropriate bond in force .......... Permit can be issued without conservation order .... Permit can be issued without administrative approval. Can permit be approved before 15-day wait ....... N N N N N N N N N N N N 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 ~P-53 (May 84) ....... 28. Work will occur without operation shutdown ...... i~_~ N 29. Is presence of N2S gas probable ........... N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones .. .... Y/N 32. Seismic analysis 9f shallow gas zones .......... 7 N 33. Seabed condition survey (if off-shore) ........ /Y N 34. Contact name/phone for weekly progress reports .... /. Y N [exploratory only] GEOLgGY: ENGIEERING: COMMI SS ION: C~mments/Instructions: TAB serv [] HOW/jo - A:%FORMS%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. ALASKA COMPUTING CENTER * ....... SCHLUMBERGER COMPANY NAME : BP EXPLORATION WELL NAME : MPE-22 FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA AP1 NUMBER : 50-029-22567-ee REFERENCE NO : 95272 LIS Tape Veri~i'¢ation'Listing Schlumberger Alaska Computing Center 28-AUG-1995 15:25 **** REEL HEADER SERVICE NAME : EDIT DATE : 95/08/28 ORIGIN : FLIC REEL NAME : 95272 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., MILNE POINT MPE-22, API #50-029-22567-00 *=** TAPE HEADER **** SERVICE NAME : EDIT DATE : 95/88/28 ORIGIN : FLIC TAPE NAME : 95272 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC.~ MILNE POINT MPE-22, API #5e-~29-22567-00 TAPE HEADER MILNE POINT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MPE-22 5ee2922567ee BP EXPLORATION SCHLUMBERGER WELL SERVICES 28-AUG-95 BIT RUN 1 BIT RUN 2 BlT RUN 3 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL e) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 95272 ST.AMOUR DIXON 95272 ST.AMOUR DIXON 25 '13N leE 3825 2104 53.83 53.83 24.7e OPEN HOLE CASING DRILLERS BlT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 9.625 3745.e PAGE: LIS Tape Veri~i'cation'Listing Schlumberger Alaska Computing Center 28-AUG-1995 15:25 3RD STRING PRODUCTION STRING REMARKS: Well drilled 17-JUN through 26-JUN-95 with CDR and CDN. All data was collected in two bit runs, $ $ *=** FILE HEADER FILE NAME : EDIT .eel SERVICE : FLIC VERSION : 001C01 DATE : 95/08/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : PAGE: FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged, DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH CDR 3645.0 14338.0 CDN 7589.0 14338.0 $ BASELINE CURVE FOR SHIFTS: GRCH CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GR.CDR 88888 14146 14081 14039 13970 13785 13769 13747 13642 13603 13570 13538 13484 13438 13351 13328 13289 13248 .0 88893 .0 14151 .5 14088 .5 14046 .0 13975 .5 13792 .5 13776 .0 13752 .0 13648 .5 13610 5 13575 5 13543 5 13488 5 13443 0 13355 0 13334 0 13293 5 13253 .5 .5 .0 .0 .0 .5 .0 .5 .0 .0 .5 0 5 0 5 5 5 0 LIS Tape Verifi, cation, Listing Schlumberger Alaska Computing Center 28-AUG-~g95 ~S:25 13215.5 13219.5 13192.5 13193.5 13142.5 13146.0 1304~.5 13045.0 12962.5 12965.0 12852.0 12855.0 12802.5 12806.0 12798.5 12801.0 12769.0 12772.0 12736.0 12738.5 100.0 102.5 $ MERGED DATA SOURCE LDWG TOOL CODE BIT RUN NO. MERGE TOP MERGE BASE CDR 1 3645.0 7710.0 CDR 2 7710.0 14338.0 CDN 2 7589.~ 14338.0 $ REMARKS: The depth adjustments shown above reflect the MWD GR ~o the GR logged by Atlas, All other MWD curves were carried wi~h the GR, This file also contains the Very Enhanced QRO resisitivi~¥ with 2' average that was r~processed at GeoQuest, $ LIS FORMAT DATA PAGE: ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 60 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 17 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 0 LIS Tape Verifi'cation"Listin9 Schlumberger Alaska Computing Center 28-AUG-~995 15:25 PAGE: SET TYPE - CHAN *~ NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 52259 00 000 00 0 1 ! 1 4 68 0000000000 RA MWD OHMM 52259 00 000 90 0 1 1 1 4 68 9009999999 RP MWD OHMM 52259 09 999 99 0 1 1 1 4 68 0000009099 VRA MWD OHMM 52259 90 999 90 0 1 1 1 4 68 9099999999 VRP MWD OHMM 52259 90 990 99 0 ~ 1 ~ 4 68 9099999999 DER MWD OHMM 52259 99 099 99 0 ! ~ ~ 4 68 00~0~00000 ROP MWD FPHR 52259 99 999 99 0 ! 1 ~ 4 68 0000009999 FET MWD HR 52259 09 099 99 0 ~ Z ~ 4 68 000000~0~0 GR MWD GAPI 52259 99 990 99 0 1 ~ ! 4 68 00~0e000~0 RHOB MWD G/C3 52259 99 990 99 ~ ~ ~ 1 4 68 9999999999 DRHO MWD G/C3 52259 99 999 99 0 ~ 1 1 4 68 9999999999 PEF MWD BN/E 52259 Oe oee ee 0 ~ ~ ~ 4 68 oeeeeoeeee CALN MWD IN 52259 Oe oee oe e 1 ~ ~ 4 68 oee~eeeeee NPHI MWD PU-S 52259 ee 00e ee e ~ 1 ~ 4 68 00eeeeeeee GRCH ATL GAPI 52259 ee ~ee oe e 1 1 ~ 4 68 eeeoeeeoee DATA ** DEPT. 14337.5ee RA.MWD -999.25e RP.MWD -999.250 VRA.MWD VRP.MWD -999.25e DER,MWD -999.25e ROP,MWD 77,252 FET.MWD GR.MWD -999.25e RHOB.MWD -999.25e DRHO.MWD -999.25e PEF.MWD CALN.MWD -999,25e NPHI,MWD -999.25e GRCH.ATL -999.25e DEPT. 3645.eee RA.MWD -999.25e RP.MWD -999.25e VRA.MWD VRP.MWD -999.25e DER.MWD -999.25e ROP.MWD -999.25e FET.MWD GR.MWD 2.39[ RHOB.MWD -999.25e DRHO.MWD -999.25e PEF.MWD CALN.MWD -999.25e NPHI.MWD -999.25e GRCH.ATL -999.25e END OF DATA ** -999.25e -999.25e -999.25e -999.25e -999.25e -999.25e **** FILE TRAILER **** FILE NAME : EDIT .eel SERVICE : FLIC VERSION : eelCel DATE : 95/e8/28 MAX REC SIZE : le24 FILE TYPE : LO LAST FILE : LIS Tape Verification. Listing Schlumberger Alaska Computing Center **** FILE HEADER FILE NAME : EDIT .~02 SERVICE : FLIC VERSION : OO1CO1 DATE : 95/08/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 28-AUG-1995 15:25 PAGE: FILE HEADER FILE NUMBER 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CDR $ LOG HEADER DATA' 3643.e 7710.0 DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 26-JUN-95 FAST2.SB005 V4.0C MEMORY 7710.0 3745.0 7710.0 TOOL NUMBER CDR $ RESISTIVITY/GAMMA RAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): RGS055 8.500 3745.0 10.40 LIS Tape Verification,Listing Schlumberger Alaska Computing Center 28-AUG-1995 15:25 FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): ~.470 1.3~0 69.0 69.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: ************ RUN 1 ************* RES TO BIT: 47.54; GR TO BIT: 58.el; CDR READOUT PORT TO B DRILLED INTERVAL 3760' - 771e' $ # LIS FORMAT DATA PAGE: ** DATA FORMAT ~PECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE ~ 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 I LIS Tape Verifi-ca%ion. Listing Schlumberger Alaska Computing Cen~er SET TYPE - CHAN -* 28-AUG-1995 15:25 PAGE: NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 52259 00 000 00 0 2 1 1 4 68 0000000000 ATR MWD OHMM 52259 00 000 00 0 2 1 [ 4 68 0000000000 PSR MWD OHMM 52259 00 000 00 0 2 1 ~ 4 68 0000000000 DER MWD OHMM 52259 00 000 00 0 2 1 1 4 68 0000000000 ROPE MWD F/HR 52259 00 000 00 0 2 1 1 4 68 0000000000 TABR MWD 52259 00 000 00 0 2 ~ 1 4 68 0000000000 GR MWD GAPI 52259 00 000 00 0 2 1 1 4 68 000~000000 ** DATA DEPT. 7710.5~0 ATR.MWD -999.250 PSR.MWD -999.250 DER.MWD ROPE.MWD 146.883 TABR.MWD -999.250 GR.MWD -999.250 END OF DATA -999.250 **** FILE TRAILER FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 95/08/28 MAX REC SIZE : [024 FILE TYPE : LO LAST FILE : **** FILE HEADER FILE NAME : EDIT .003 SERVICE : FLIC VERSION : e~iCel DATE : 95/08/28 MAX REC SIZE : [024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW MWD Curves and log header data for each bit run in separate giles. BIT RUN NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY LIS Tape Verifi~a%ion. Lis%lng Schlumberger Alaska Computing Cen~er 28-AUG-1995 15:25 PAGE: VENDOR TOOL CODE START DEPTH CDR 7647.0 CDN 7589.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE STOP DEPTH 14332.0 14332.0 26-JUN-95 FAST2.SBO~5 V40.C MEMORY 14333.~ 7589.0 14333.0 TOOL NUMBER CDR CDN RESISTIVITY/GAMMA RAY NEUTRON/DENSITY RGS055 NDS022 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): 8. 500 3745.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): 10.4~ 60~ 1.470 1.31e 69 .o 69.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): SANDSTONE 2.65 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: ************ RUN 2 RES TO BIT: 54.82; GR TO BIT: 65.24; CDR READOUT PORT TO BIT: 57.99~ LIS Tape Verification~Listing Schlumberger Alaska Computing Cen~er 28-AUG-1995 15:25 DEN TO BlT: 120.71; NEUT TO BlT: 127.69 CDN READOUT PORT TO BlT: 119.40'; DRILLED INTERVAL 7710' 14333~ WELL TD'D 24-JUN-95 822:30; VISCOSITY 42; FLUID LOSS 4,3 CHLORIDES 600 PPM; DATA FROM DOWNHOLE MEMORY; DOWNHOLE SOFTWARE V4.0C $ LIS FORMAT DATA PAQE: DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 64 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 52259 00 000 00 0 3 1 1 4 68 0000000000 ATR LW2 OHMM 52259 00 000 00 0 3 1 1 4 68 0000000000 PSR LW2 OHMM 52259 00 000 00 0 3 1 1 4 68 0000000000 DER LW2 OHMM 52259 00 000 00 0 3 1 1 4 68 0000000000 ROPE LW2 F/HR 52259 00 000 00 0 3 1 1 4 68 0000000000 TABR LW2 52259 00 000 00 0 3 1 1 4 68 00~0000000 GR LW2 GAPI 52259 ~0 000 00 0 3 1 I 4 68 000000~000 RHOB LW2 G/C3 52259 00 0~0 00 0 3 1 1 4 68 0~000~0000 DRHO LW2 G/C3 52259 00 000 00 0 3 1 1 4 68 0~00000000 DPHI LW2 PU 52259 00 000 00 0 3 1 1 4 68 0000000000 PEF LW2 BN/E 52259 00 000 00 0 3 1 1 4 68 0000000000 NSI LW2 52259 00 00~ 00 0 3 1 1 4 68 0000000000 TNPH LW2 PU 52259 00 000 00 0 3 1 1 4 68 0000000000 LIS Tape Verifi~ation~Listing Schlumberger Alaska Computing Center 28-AUG-1995 15:25 PAGE: NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TABD LW2 52259 99 999 09 9 3 1 1 4 68 9009909909 DCAL LW2 IN 52259 99 999 99 9 3 I 1 4 68 0000000000 CALN LW2 IN 52259 99 009 00 9 3 1 ~ 4 68 9000909000 DATA DEPT. 14332.009 ATR.LW2 -999.259 PSR.LW2 ROPE.LW2 77.252 TABR.LW2 -999.250 GR.LW2 DRHO.LW2 -999.250 DPHI.LW2 -999.250 PEF.LW2 TNPH.LW2 -999.250 TABD.LW2 -999.259 DCAL.LW2 DEPT. 7585.000 ATR.LW2 -999.250 PSR.LW2 ROPE.LW2 -999.250 TABR.LW2 -999.259 GR.LW2 DRHO.LW2 -999.250 DPHI.LW2 -999.259 PEF.LW2 TNPH.LW2 41.499 TABD.LW2 -999.250 DCAL.LW2 -999.250 DER.LW2 -999.259 RHOB.LW2 -999.259 NSI.LW2 -999.259 CALN.LW2 -999.259 DER.LW2 -999.259 RHOB.LW2 -999.250 NSI.LW2 -999.259 CALN.LW2 -999.259 -999.259 -999.259 -999.259 -999.250 -999.259 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .093 SERVICE : FLIC VERSION : 001C01 DATE : 95/08/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 95/08/28 ORIGIN : FLIC TAPE NAME : 95272 CONTINUATION # : ~ PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., MILNE POINT MPE-22, API #59-029-22567-00 LIS Tape ~erifica~ion Listing Schlumberger Alaska Computing Center 28-AUG-J995 [5:25 PAGE: 3.3. **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 95/08/28 ORIGIN : FLIC REEL NAME : 95272 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., MILNE POINT MPE-22, AP1 #50-029-22567-00 Tape Subfile' 2 i~ type: ~S 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 MPE - 22 500292256700 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 14-AUG-95 6468.00 B. ESARY SEE REMARKS 25 13N 10E 3825 2104 53.80 24.70 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 3RD STRING 9.625 3745.0 PRODUCTION STRING 7.000 14300.0 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: EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ GR/CCL Cased Hole. REMARKS: 40.00 26.00 LOGS WITNESSED BY: T. ANGLEN / B. CUNNINGHAM *** THIS IS THE DEPTH REFERENCE FOR THIS WELL *** ******************** NOTICE ************************ THIS LOG, PER THE FIELD BLUELINE REMARKS, WAS ADJUSTED FOR KB ZERO (RIG 4ES) TO 7.16' BELOW ORIGINAL KB. ORIGINAL KB RIG 22E = 53.83' kIG 4ES ~ ~ = 46.67 LOG (RIG 4ES) KB ZERO 7.16' ADJUSTMENT ******************** NOTICE ************************ PASS 1 WAS NOT DEPTH SHIFTED SINCE PASS 1 IS THE DEPTH REFERENCE FOR THIS WELL. FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 10700.0 14163.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE PASS NUMBER: BASELINE DEPTH $ REMARKS: EQUIVALENT UNSHIFTED DEPTH PASS 1 (MAIN PASS) . NO DEPTH SHIFTS WERE DONE SINCE THIS IS THE DEPTH REFERENCE. CN : BP EXPLORATION WN : MPE - 22 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 GR 68 1 GAPI 2 TENS GR 68 1 LB API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 30 995 99 1 4 4 30 995 99 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 35 Tape File Start Depth = 14163.000000 Tape File End Depth = 12700.000000 Tape File Level Spacing = 0.500000 Tape F~le D~pth Uni__, = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 8782 datums Tape Subfile: 2 136 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 run in separate files. PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 13905.0 14163.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 BASELINE DEPTH GRCH 13969.5 13970.0 13978.5 13979.0 13979.5 13979.5 13981.5 13981.5 14020.0 14020.5 14042.5 14041.5 14046.5 14045.5 14072.0 14071.5 14072.5 14072.5 14084.0 14083.5 14092.5 14090.5 14093.0 14091.0 14106.5 14106.5 14128.5 14128.5 14129.0 14129.5 14132.5 14133.5 14133.5 14134.5 14152.5 14153.0 14154.5 14155.0 14155.0 14155.5 $ REMARKS: EQUIVALENT UNSHIFTED DEPTH PASS 2 (REPEAT PASS). TENS SHIFTED WITH GRCH / ? ?MATCH2A. OUT $ CN : BP EXPLORATION WN : MPE - 22 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GRCH GR 68 1 GAPI 2 TENS GR 68 1 LB API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 30 995 99 1 4 4 30 995 99 1 * DATA RECORD (TYPE# 0) Total Data Records: 1014 BYTES * Tape File Start Depth = 14163.000000 Tape File End Depth = 13955.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 1252 datums Tape Subfile: 3 58 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12696.0 $ LOG HEADER DATA STOP DEPTH 14190.5 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): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EBAR SBAR EBAR CCL GR $ ECCENTRIC SINKER BAR SINKER BAR ECCENTRIC SINKER BAR CASING COLLAR LOC. GAMMA RAY 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): 02 -AUG- 95 FSYS REV. J001 VER. 1.1 2051 02-AUG-95 14150.0 14164.0 12693.0 14163.0 1800.0 YES TOOL NUMBER 2324XA 1311XA .000 14300.0 .0 BRINE 9.70 .0 .0 0 .0 .000 .000 .000 .0 .00 .000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NOR~ALIZIN~ ~INDOW (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 (MAIN PASS). $ CN : BP EXPLORATION WN : MPE - 22 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 GR 68 2 CCL GR 68 3 SPD GR 68 4 TTEN GR 68 5 TEN GR 68 1 GAPI 1 1 F/MN 1 LB 1 LB 4 4 30 310 01 1 4 4 30 150 01 1 4 4 30 636 99 1 4 4 30 635 99 1 4 4 30 635 99 1 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 143 Tape File Start Depth = 14190.500000 Tape File End Depth = 12696.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 44657 datums Tape Subfile: 4 218 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 13904.0 $ LOG HEADER DATA STOP DEPTH 14190.5 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): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EBAR SBAR EBAR CCL GR $ ECCENTRIC SINKER BAR SINKER BAR ECCENTRIC SINKER BAR CASING COLLAR LOC. GAMMA RAY 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): 02-AUG-95 FSYS REV. J001 VER. 1.1 2038 02-AUG-95 14150.0 14164.0 12693.0 14163.0 1800.0 YES TOOL NUMBER 2324XA 1311XA .0O0 14300.0 .0 BRINE 9.70 .0 .0 0 .0 .000 .000 .000 .0 .00 .000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALI ZIN~ ~INDOW (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 (REPEAT PASS). $ CN : BP EXPLORATION WN : MPE - 22 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 GR 68 2 CCL GR 68 3 SPD GR 68 4 TTEN GR 68 5 TEN GR 68 1 GAPI 4 1 4 1 F/MN 4 1 LB 4 1 LB 4 4 30 310 01 1 4 30 150 01 1 4 30 636 99 1 4 30 635 99 1 4 30 635 99 1 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 23 Tape File Start Depth = 14190.500000 Tape File End Depth = 13954.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 6935 datums Tape Subfile: 5 98 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 6 is type: LIS 95/ 8/11 01 **** REEL TRAILER **** 95/ 8/11 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Fri 11 AUG 95 1:39p Elapsed execution time = 10.05 seconds. SYSTEM RETURN CODE = 0
