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Home My WebLink About196-031STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Plugged Back for Sidetrack 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned I-I Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 196-031 301-137 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20707-01 4. Location of well at surface 9. Unit or Lease Name 1880' SNL, 1692' WEL, SEC. 23, T11 N, R13E, UM Prudhoe Bay Unit At top of productive interval N/A 10. Well Number At total depth D-19A 2984' SNL, 3436' WEL, SEC. 23, T11N, R13E, UM 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Prudhoe Bay Pool KBE = 78.70' ADL 028285 12. Date Spudded 03/02/1996 113' Date T'D' Reached 114' Date COmp'' Susp'' or Aband'03/16/1996 9/7/2001 115' Water depth' if offshore N/A M SL 116' NO' of Completions Zero 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 120. Depth where SSSV set1 21. Thickness of Permafrost 10565 9008 FTI 6834 6647 FTI []Yes [] NoI N/A MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP Be'I-rOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" X 30" Insulated Conductor Surface 110' 36" B cu },ds Concrete 13-3/8" 72# L-80 Surface 2702' 17-1/2" 3549 cu ft Permafrost II 9-5/8" 47# L-80 Surface 8758' 12-1/4" 1177 cu ft Class 'G', 130 cu ft PF 'C' 7" 26# IJ4S 8281' 8941' 8-1/2" ¢24 cu ft Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) None 5-1/2", 17#, L-80 6305'- 8221' 8221' MD TVD MD -I-VD 4-1/2" 8357' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6315' Oement Plug when Suspended (05/96) 6257' Set Bridge Plug (09/07/01) 6254 Set Whipstock (09/08/01) 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Not on Production N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing C, asing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Sabra, core chRF_C E iVF__ HOV 0 5 ZOO! Alaska Oil & Gas Cons, Commission Anchorage ~ J'_ I Form 10-407 Rev. 07-01-80 ORIGINAL Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Sag River 8801' 8490' Shublik 8838' 8525' Ivishak 8916' 8600' .Alas~,a Oil & GaS Cons. 31. List of ARachments: Summa~ of Daily Drilling Repoas 32. I hereby ce~i~ that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble~ ~ Title TechnicalAssistant Date ~J' D-19A 196-031 301-137 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No./Approval No. 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 attach merits. 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. FormlO-407 Rev. 07-01-80 0RIGI[qAL Well: D-19B Rig Accept: 09/04/01 Field: Prudhoe Bay Rig Spud: 09/09/01 APl: 50-029-20707-02 Rig Release: 09/20/01 Permit: 201-112 Drilling Rig: Doyon 14 PRE-RIG WORK 05/17/01 Drift run with 4.50" centralizer and sample bailer to top of cement at 6315' sim. 07/08/01 MITOA passed, bleed tubing, bleed IA. 07/18/01 MIT-T passed, CMIT T x IA passed. 07/19/01 Ran gyro survey from surface to TD at 6338'. Run in hole with jet cutter and stuck at GLM at 4864'. Pulled off after working, slickline to fish. 07/20/01 Run in hole with overshot to latch 19' of e-line tools with jet cutter at 6294' sim. Pulled out of hole with all e-line tools. Drift and tag cement top at 6311' sim. 07/21/01 Cut 5-1/2" tubing at 6310' with 4-7/16" jet cutter. Circulate well with 2% KCL. Freeze protect tubing. XPLORATi i , :, : BP E ON Page ii Operati°ns Summary Report Legal Well Name: D-19 Common Well Name: D-19B Spud Date: 4/24/1982 Event Name: REENTER+COMPLETE Start: 9/2/2001 End: 9/20/2001 Contractor Name: DOYON Rig Release: 9/20/2001 Rig Name: DOYON 14 Rig Number: :: ::~Date~i~;: From ~;:To: HOURS ACtiVi~ LCode ;~NPT ~Phase: : Description of Operations 9/N2001 00:00 - 00:00 24.00 MOB P PRE Rig down floor. Skid floor. Move rig off of S-110i. Install booster wheels. RD windwalls. PJSM. Prepare derrick bridle. LD derrick. Moved ~mp, utili~ module, and shop to D-Pad and ~mplete rig up of same. Pull inside cuEings ~nveyor. Complete installation of Super G Derrick shakers. Clean Io~tion. PJSM Move rig off S-Pad. 19/3/2001 00:00 - 15:30 15.50 MOB PRE Move rig from S-Pad to D-Pad. 15:30 - 22:00 6.50 RIGU PRE Spot rig near D-19. Raise A legs. Raise derrick and windwalls. Set windwall "C" Se~ion. Unhook bridle lines and tie ba~. Hang bra~s for rails. Hang lights. 22:00 - 23:00 1.00 RIGU PRE Lay down old drilling line spool. Set new spool in pla~. 23:00 - 00:00 1.00 RIGU PRE Pick up top drive & rig up. Set new cu~ings ~nveyor in pla~. Rigging up floor. 9/4/2001 00:00 - 10:00 10.00 RIGU P PRE RU top drive and rig floor. Install conveyor. Install BOP in sub-base. Spot rig over well. Skid floor. 10:00 - 16:00 6.00 RIGU P PRE A~pt rig at 10:00. Continue to RU floor. Take on sea water. Che~ well pressure. RU lines to tree and annulus and test to 3,500 psi. 16:00 - 17:00 1.00: RIGU = ;PRE RU DSM lubri~tor and pull BPV. 17:00 - 20:00 3.00 RIGU ~ :PRE RU circulating lines. Displa~ diesel freeze protection by pumping ~ bbls of sea water down IA and obtain clean returns. Switch and pump 188 bbls of sea water down tubing and obtain clean returns. Flow check. Well static. 20:00 - 20:30 0.50 RIGU P PRE Set ~C and test to 1000 psi. 20:30 - 21:30 1.00 RIGU P PRE ND tree. LD tree. Make dummy run with XO for tubing hanger. 21:30 - 22:30 1.00 RIGU P PRE Wo~ on well head. Grind off tip of one lock dOwn screw. 22:30 - 00:00 1.50 RIGU P PRE NU BOPE. 9/5/2001 00:00 - 04:00 4.00 RIGU P PRE Continue to NU BOPE. Install se~nda~ annulus valve. )~:00 - ~:30 0.50 RIGU P PRE Body test BOP to 2000 psi. Can't test higher due to leaking tubing hanger seals. 04:30 - 05:30 1.00 RIGU P PRE RU DSM and pull ~C with lubri~tor. 05:30- 07:00 1.50 RIGU P PRE RU and pull tubing to rig floor. P/U 155K. S/O 145K. 07:00 - 07:30 0.50 RIGU P PRE Circulate one hole volume at 10 bpm at 210 psi. 07:30 - 08:30 1.00 RIGU P PRE Crimp ~ntrol lines and cut. LD tubing hanger. MU test plug and land tubing and test plug. 08:30 - 09:00 0.50 RIGU P PRE RU to test BOP. 09:~ - 14:30 5.50 RIGU P PRE Test BOPE to 250 psi Iow, 3,500 psi high as per AOGCC regs and BP policy. Test annular to 2,500 psi. BOP test witness waived by John Crisp of AOGCC. 14:30 - 15:30 1.00 RIGU 3 PRE RD test equipment and P/U Hallibu~on spooling unit. MU 5" DP to pull plug and tubing. 15:30 - 16:30 1.00 PULL = DECOMP Pull tubing to floor. LD landing equipment. 16:30- 17:30 1.00 PULL ~ DECOMP RU to LD tubing. 17:30 - 18:00 0.50 PULL P DECOMP : Fluid out of balan~. Pump d~ job. 18:00 - 22:00 4.00 PULL P DECOMP Pull 5 1/2" tubing and spool en~psulated control lines. Connections tight and threads hanging up. Retrieved 25 control line protectors and 5 SS bands. 22:00- 22:30 0.50 PULL P DECOMP RD ~ntrol line equipment. 22:30 - 00:00 1.50 PULL P DECOMP POOH LD 5 1/2" tubing. 9/6/2001 00:00 - 03:30 3,50 PULL P DECOMP Continue to UD 5 1/2" tubing. Recovered 150 joints and 25.80' cut joint, 3 GLMs, SSSV landing nipple, 25 control line >rote~ors, 5 SS bands, and ~ntrol line, Good jet cut. 03:30 - 04:30 1.00 PULL P DECOMP Clear rig floor of tubing handling equipment. Printed: 9/24/2001 4:59:15PM ,:: ; i BP:EXPLORATION Page 2 ~ i operati°nsSummary Report Legal Well Name: D-19 Common Well Name: D-19B Spud Date: 4/24/1982 Event Name: REENTER+COMPLETE Start: 9/2/2001 End: 9/20/2001 Contractor Name: DOYEN Rig Release: 9/20/2001 Rig Name: DOYEN 14 Rig Number: :~:~:: Date~- ~From ? TO HoUrsi ActiVity code ~NpT ::phaSe Description of Operations 9/6/2001 04:30 - 05:30 1.00 BOPSUF:P DECOMP Change top pipe rams to 2 7/8" x 5" variable rams. 05:30- 06:00 0.50 BOPSUF:P DECOMP Service rig. 06:00 - 06:30 0.50 BOPSUF.P DECOMP RU and test top pipe rams to 250 psi / 3,500 psi. 06:30 - 07:00 0.50 WHSUR P DECOMP Install wear ring. 07:00 - 10:00 3.00 CLEAN P DECOMP P/U milling tools and MU milling assembly with mule shoe and water melon mill. 10:00- 17:00 7.00 CLEAN P DECOMP RIH P/U drill pipe from shed. 17:00 - 17:30 0.50 CLEAN P DECOMP I Tag top of tubing stub at 6,305'. Prepare pits for mud displacement. 17:30 - 18:30 1.00 CLEAN P DECOMP Displace sea water in hole with 9.6 ppg LSND drilling fluid at 12 bpm and 1250 psi. Obtain base line torqe: 4,000 ft*lb at 50 RPM. : 18:30- 22:00 3.50 CLEAN P DECOMP Slip drilling line, 1,780'. Change to new spool of line. 22:00- 22:30 0.50 CLEAN P DECOMP Service top drive. 22:30 - 00:00 1.50 CLEAN P DECOMP POH standing back drill pipe to 2,400'. 9/7/2001 00:00- 01:00 1.00 CLEAN P DECOMP Continue to POH to 2,420'. 01:00- 03:00 2.00 CLEAN N RREP DECOMP Drilling line back lashed. Slip and cut damaged line. 03:00- 03:30 0.50 CLEAN P DECOMP POH to BHA. 03:30 - 04:30 1.00 CLEAN 3 DECOMP Stand back drill collars and I_JD milling assembly. 04:30- 05:00 0.50 CLEAN ~ DECOMP PJSM RU eline. 05:00- 07:30 2.50 CLEAN ~ DECOMP RIH and set bridge plug at 6,257' wireline depth. POH and RD eline. 07:30- 08:00 0.50 CLEAN = DECOMP Pull wear ring. 08:00 - 09:30 1.50 WHSUR ~ DECOMP RU to pull 9 5/8" pack off. Bleed pressure off of eA. 09:30 - 14:00 4.50 WHSUR P DECOMP Attempt to pull pack off. Unable to unseat pack off using heat and fluid movement through seal area. Also used heat on outside of spool. Pull max weight on J lug pulling tool. 14:00- 16:30 2.50 WHSUR P DECOMP ND BOP and tubing spool. 16:30 - 17:00 0.50 WHSUR P DECOMP Install 9 5/8" pack off. 17:00 - 19:30 2.50!WHSUR P DECOMP NU BOP and condition B tubing spool. 19:30 - 20:00 0.50 WHSUR P ~DECOMP Install wear ring and test pack off to 5000 psi for 15 minutes. 20:00 - 21:00 1.00 CASE P DECOMP Pressure test 9 5/8" casing and BOP flanges to 300 psi for 5 minutes and 3500 psi for 30 minutes. 21:00 - 23:00 2.00 STVVHIP 3 WEXIT MU whipstock assembly and orient MWD. 23:00 - 00:00 1.00 STWHIP 3 WEXIT Upload MWD. 9/8/2001 00:00 - 01:30 1.50 STWHIP 3 WEXIT RIH w/BHA. Surface test MWD. 01:30 - 04:00 2.50 STWHIP = WEXIT !RIH to 6,200' 04:00 - 04:30 0.50 STWHIP = WEXIT Orient whipstock to 86? right of high side and set BP at 6,254'. 04:30 - 14:30 10.00 S'I'WHIP P WEXIT Mill window from 6,231' to 6,247' and drill formation to 6,270'. 14:30- 15:00 0.50 STWHIP P WEXIT Perform FIT test to 12.0 ppg EMW. 15:00 - 19:30 4.50 S'I'WHIP P WEXIT Flow check. Well static. POOH and log for geology tie in from 6,004' to 5,624'. Continue POOH. 19:30 - 21:30 2.00 S'I-WHIP P WEXIT LD BHA. Down load MWD. Upper string mill in gage. 21:30 - 22:30 1.00 S'I-WHIP P WEXIT Flush stack and clear rig floor of milling tools. 22:30 - 00:00 1.50 DRILL P INT1 MU 8 1/2" drilling BHA. :9/9/2001 00:00 - 01:30 1.50 DRILL P INT1 Continue to MU BHA. Surface test MWD. 01:30 - 04:30 3.00 DRILL = INT1 TIH picking up 72 singles. RIH to 6,135'. Orient through window. 04:30 - 05:00 0.50 DRILL = INT1 Wash from 6,255' to 6,270'. 05:00 - 00:00 19.00 DRILL ~ INT1 Drill from 6,270' to 7,096'. Flow rate 550 gpm. AST=9.79. ART=4.3. 9/10/2001 00:00 - 00:00 24.00 DRILL P INT1 Drill from 7,090' to 8,570'. ART=10.21. AST=6.68. Hole in good shape. Printed: 9/24/2001 4:59:15 PM Si'ATE OF ALASKA ALASKa-, OIL AND GAS CONSERVATION COMi~,,,SSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 Location of well at surface 1880' SNL, 1692' WEL, SEC. 23, T11N, R13E, UM At top of productive interval N/A At effective depth 2007' SNL, 2664' WEL, SEC. 23, T11N, R13E, UM At total depth 2984' SNL, 3436' WEL, SEC. 23, T11N, R13E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE = 78.70' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number D-19A 9. Permit Number 196-031 10. APl Number 50- 029-20707-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10565 feet Plugs (measured) 9008 feet 6834 feet Junk (measured) 6647 feet See Diagram. Top of Fish at 6834' (03/96) See Diagram. Casing Length Size Cemented M D TVD Structural Conductor 110' 20" 8 cu yds Concrete 110' 110' Surface 2702' 13-3/8" 3549 cuft Permafrost II 2702' 2702' Intermediate 8758' 9-5/8" 1177 cu ft Class 'G', 130 cu fl PF 'C' 8758' Production Liner 1337' 7" 424 cu ft Class 'G' 8281' - 8941' 7999' - 8552' Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 to 8221' with 4-1/2" tailpipe to 8357' 4r~C/~orage' Packers and SSSV (type and measured depth) 9-5/8" BeT packer at 8221" Otis SSSV Landing Nipple at 2104' 13. Attachments [] Description Summary of Proposal [] Detailed Operations Program [] BOP Sketch 14. Estimated date for commencing operation June 5, 2001 16. If proposal was verbally approved Name of approver 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Date Approved Contact Engineer Name/Number: Walter Quay, 564-4178 Bill Isaacson, 564-5521 Prepared By Name/Number: Terrie Hubble, 564-4628 .17. I hereby certify that the foregoing is true and correct to the best of my knowledge , Signed w,,,iam s. ,saacson '~_L. ~. ~......___ Title Senior Drilling Engineer [Conditions of Approval: Notify Commission so representative may witness !~ Plug integrity __ BOP Test ~'~., Location c~earance i Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commission Form 10-403 Rev. 06/15/88 Date ~/t.'t' Z H ~ ZOdi I Approval No. Commissioner Date ~-2.,/t/~/ Submit In Triplicate '~*' STATE OF ALASKA ' ALASKA ,..,,L AND GAS CONSERVATION CO,,,MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown []Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Ann-Comm 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1880 SNL, 1692' WEL, SEC. 23, T11N, R13E, UPM At top of productive interval (n/a) At effective depth 2007' SNL, 2652' WEL, SEC 23, T11N, R13E At total depth 3019' SNL, 3411' WEL, SEC. 23[T11N, R13E 5. Type I~ well: Development [] Exploratory [] Stratigraphic I--I Service 6. Datum Elevation (DF or KB) KBE = 78.65' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number D-19A 9. Permit Number / Approval No. 96-123 10. APl Number 50-029-20707-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 10564 feet true vertical 8929 feet Effective depth: measured 6834 feet true vertical 6647 feet Casing Length Plugs(measured) Junk(measured) KOP (window) 8941' - 8947'. 7" Liner abandoned from 8941' to 9618'. 2-3/8" CT, Top @ 6834'. 5/8" umbillical inside coil, top @ 6844'. 2 Kinley cutters inside coil. Size Cemented MD TVD Structural Conductor 110' 20"x 30" 72 c.f. 146' Surface 2666' 13-3/8" 3549 c.f. 2702' Intermediate 8722' 9-5/8" 1307 c.f. 8758' Production Liner 1338' 7" 424 c.f. 8282' - 8951' 146' 2702' 8449' 8000'-8632' Perforation depth: measured true vertical All perfs in well D-19 sqzd off. Fish in D-19A OH from 8941' to 10360'. D-19A TD @ 10564' All perfs in well D-19 sqzed off. Tubing (size, grade, and measured depth) 5-1/2" 17#, L-80 tubing to 8221' with 4-1/2" tailpipe @ 8357'. Packers and SSSV (type and measured depth) 9-5/8" PKR (BET) @ 8221', 5-1/2" Otis SSSVLN @ 2104'. 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge s~ott L~Voi~ Title Technical Assistant -- Prepared By Name/Number: :~ ~ ~ ? ~ ! , .. Date ¢/~"~ / PeW~y,e ~noCrr E~4:5 ~ 74 Form 10-404 Rev. 06/15/88 Submit In Duplicate D-19A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 04/30/2001 ANN-COMM: PT TBG & CSG HANGERS FOR RWO PREP INFO SUMMARY 04/30/01 ATTEMPT TO PRESSURE TEST TUBING AND CASING HANGERS FOR POSSIBLE RWO INFORMATION. TUBING HANGER SEALS ARE BAD. CASING HANGER SEALS ARE BAD. FAILED TESTS. Fluids Pumped BBLS. 0 0 TOTAL Description No Fluids Pumped DP~ nAilItHG ,, w~J.s BP Exploration Alaska To: From: Subject: Reference: Tom Maunder - AOGCC Date: May 24, 2001 Walter Quay DS D-19 Application for Sundry Approval - Reenter for Sidetrack Operations APl # 50-029-20707-2 Approval is requested for the propose of sidetracking D-19A to a new bottom hole location as a conventional producer targeting Ivishak Zone 2 reserves. Well D-19B was suspended per Sundry Approval "96-123" and has been shut-in since May of 1996. This suspension occurred after and unsuccessful attempted coiled tubing sidetrack. During the sidetrack operation with a coiled tubing unit, the coil became stuck when drilling had reached a depth of 10,564' ctmd. Efforts to free the BHA were unsuccessful, complicated by the umbilical cable housed inside the coil. The coil/cable was eventually severed at 6834' elmd and recovered above this point. A bullhead squeeze cement plug was placed with the top(calculated at 6730'). A wireline gauge ring run on 5/17/01, tagged up at 6315' MD. The proposed path forward is to cut the 5-1/2" tubing above the production packer at -6300' MD. The rig would then move on, pull the tubing above the cut, and set a bridge plug on wireline at -6274' MD. The well will then be sidetracked and a 7" liner cemented back into the 9-5/8" casing. See attached schematics for details. The sidetrack is currently scheduled for Nabors 9ES beginning around July 10th, after the completion of the D18A sidetrack. The pre-rig work for this sidetrack is planned to begin as soon as the attached Application for Sundry is approved. Scope Pre-Riq Work: * Notify the field AOGCC representative with intent to re-enter the well * 1. Liquid pack the well. Pressure test the tubing and cement P&A plug to 3000 psi for 30 minutes. Pressure test the annulus to 3500 psi for 30 minutes. 2. Rig up E-line. Run gyro. Cut the 5Y2" L-80 tubing at 6300' MD. This cut will not be fished, so the use of a jet or chemical cutter is at the discretion of the Wells Group Representative. 3. Displace the well to clean seawater by circulating down tubing through the tubing cut. Continue to circulate until clean seawater returns to surface. Freeze protect top 2200' MD with diesel by circulating diesel in down tubing. 4. Test the McEvoy 9-5/8" mandrel packoff and tubing hanger seals to 5000 psi for 30 minutes. 5. Set a BPV in the tubing hanger. Secure well. 6. Remove the well house and flowlines. If necessary, level the pad. Please provide total well preparation cost on the handover form. D-19B Application for Sundry Ri.q 1. 2. 14. 16. 17. Operations: MIRU Nabors 9ES. Circulate out freeze protection and displace well to kill weight brine (adequate to maintain Cretaceous pressure behind 9-5/8" casing). Set TWC. 3. Nipple down tree. Nipple up and test BOP[:. 4. Pull and lay down 5-1/2" tubing from E-line cut and above. 5. MU 9-5/8" whipstock window milling assembly and RIH to top of tubing stub. POOH. 6. RIH with 9-5/8" Baker bottom-trip anchor whipstock assembly. Orient whipstock as desired and set on BP. Mill window in 9-5/8" casing at -6250' MD. POOH. 7. RIH with 8-1/2" drilling assembly (with MWD/GR/RES) to whipstock. Kick-off and drill the 8-1/2" intermediate section to Top Sag @ +_8670 MD (8488' TVD). 8. Run and cement 7", 26# intermediate drilling liner to -150' back into window. POH. 9. Make up and RIH with a 6-1/8" directional assembly (with MWD/GR/RES/DEN/NEU) to the liner landing collar. Test 7" liner from the landing collar to surface to 3000 psi for 30 minutes. 10. Drill 6-1/8" production section as per directional plan to an estimated TD of 10,225' MD (9033' TVD). 11. Run and cement a 4 ~", 12.6# 13Cr-80 solid production liner throughout the 6-1/8" wellbore. Displace well to clean seawater above liner top. POQH SB DP. 12. Test the 4-1/2", 7", and 9-5/8" casing from the 4-1/2" landing collar to surface to 3000 psi for 30 min. 13. Pick up perf guns on 2-3/8" X 4-1/2" DP and RIH to perforate - 400' of selective intervals. Perforate well with -200 psi underbalance to the reservoir. POOH LD DP. Run 4-1/2" 12.6# 12Cr-80 New Vam completion tying into the 4-1/2" liner top. Set packer and test the tubing to 3500 psi and annulus to 3000 psi for 30 minutes. Freeze protect the well to -2200' and secure the well. Rig down and move off. Post-Ric~ Work: MIRU slickline. Pull the ball and rod / RHC plug from 'X' nipple below the new production packer. Install gas lift valves. Post-Rio Work: 1. MIRU slickline. Pull the ball and rod / RHC plug from 'X' nipple below the new production packer. Install gas lift valves. Estimated Pre-rig Start Date: 06/05/01 Estimated Spud Date: 07/10/01 Walter Quay Operations Drilling Engineer 564-4178 D-19B Application for Sundry TREE: 6" ClW WELLHEAD: McEVOY ACTUATOR: OTIS 133/8"'72~ I L-80, BTRS 2702' IKOP: 4000' 24° @ 530ff 17o @ 8900' 66° @ 9382' 89° @ 9594' 94° ~ 10534' 5 1/2", 17~ft, L-80, AB BTRS TUBING '(IPC) CAPACITY: .0232 BBL/FT 7" LINER 8281' 95/8", 47#~, I 8758' L-80, BTR8 PERFORATION SUMMARY REF. LOG: SWS-BHCS- 5-7-82 TIE-IN LOG: SWS - CBL 5-10-82 SIZE SPF INTERVAL C,PEN/SQZ'D 2 7/8"1 4 9240- 9250' SQZD/4-30-88 3 1/8" 4 9300 - 9310' SQZD/4-30-88 2 7/8" 4 9327 - 9353' SQZD/8-30-91 2 7/8" 4 9366 - 9368' SQZD/8-30-91 3 3/8" 4 9368 - 9388' SQZD/2/10/94 ~-3/8" 6 9366' - 9406' S()ZD 2/25/96 D KB. ELEV =78.65' BF. ELEV = 42.95' SSSV LANDING NIPPLE ( OTIS ) (4.562" ~D) I 21 04' N°I MD(BKB)I '2 I 3000' I ~° I 5966'I 916121' I 8166°6' I 716763' I 617125' I 517279' I 417602' I 3I 7756' I 217902' I 118o63' I 5 1/2" SLIDING SLEEVE (OTIS "XA") (4.562"1D) GAS LIFT MANDRELS ' (OTIS LBD W/RA LATCH) TVDss 2921' 4751' 5759' 5903' 6355' 6502' 6838' 6983' 728T 7432' 7568' 7718' 8135' BOT SBR 8201' 5/8" PACKER [ 8221' I BOT ) (4.750"1D) 1/2", 12.6#ift, L-80 TAILPIPE 4 1/2" "X" NIPPLE (OTIS) (3.813" ID) 4 1/2" "XN" NIPPLE (OTIS) (3.725" ID) 4 1/2" TBG TAIL ( BOT )(SOS) (ELMD- REF BHCS 5-7-82) 8284' 8315' 8357' 8348' BAKER WHIPSTOCK I 8936' WINDOW FROM 8941'- 8947' 3.75" HOLE TO 10564' BIT STUCK AT 10360' FISH IN HOLE: 2-3/8" coiled tubing, top at 6834'. 5/8" umbilical inside coil, top at 6844'. 2 Kinley cutters inside coil. Camco BHA #3, 3.375" OD, 25.08' Radius UBHO, monel, 3.125" OD, 16.8' Ddlex tandem 2.875" motor, 12.88' Hycalog, HS-38HG bit, 3.75" OD, .42' ~ Cement plug set 2/25/96 Top @ 9166'. PBTD [ 9580' I ~ 7", 26#/ft, L-80,1J4S [ 9618'I DATE REV. BY COMMENTS 5-12-82 INITIAL COMPLETION 1-21-92 A. TEEL REVISED 2-10-94 MELVAN CTU CMT SQZ 2-14-94 HUGHES REPERFORATE 3-31-96 . . _ PAB CT SIDETRACK, FISH · FISH: LOST4-22-86- BOWSPRING CENTRALIZER ARM, 2' L x 1/2" W x 1/8" T. FISH IS AT OR BELOW 9460' WLM. PRUDHOE BAY UNIT WELL: D-19 (22-23-11-13) APl NO: 50-029-20707-- SEC 23; TN 11N; RGE 13E BP Exploration (Alaska) -~¢ELLHEA'D= MCEVOY ACTUATOR= OTIS KB. REV = 78.65 BF. ELEV = 42.95 KOP = 4000 ~ ~'~i~"'~ ......~ @'"~"6'~'6~ Datum MD = 9206 Datum TVDss= 8800' D. '"9A Planned Prs ,ig 13-3/8" CSG, 72#, LB0, ID=12.347 Id 2702' 5-1/2" Tubing Cut @ +-6300' 8135' 1-15-1/2" OTIS 'XA' SLIDING SLV, ID:4.562 I 5-1/2" TBG, 17#, L80, .0232 bpf, ID=4.892 Id 8222' ITOP OF 7" LNR Id 8281' 4-1/2" TAILPtPE, 12.6#,L80, .0152 bpf,ID=3.958 Id 8357' 8758' % IN HOLE coiled tubing, top at 6834' 5/8" umbilical inside coil, top at 6844' Kinley cutters inside coil. 8201' Id 5-1/2" BOT SBR I 8221' 1-195/8"x 5-1/2"BOTPKR, ID=4.75 8222' 1-15-1/2"x 4-1/2" XOI 8284' 8315' 8357' Id4-1/2" OTIS 'X' NIP, ID=3.813 I Id4-1/2" OTIS 'XN' NIP, ID=3.725" I Id4-1/2" TBG TAIL, ID=3.958 I 8348' I-I I PERFORATION SUMMARY REF LOG: SWS-BHCS, 5/7/82 ANGLEATTOPPERF: 143 @ 9240 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2 7/8' 4 9240-9250 S 04/30/88 3 1/8' 4 9300-9310 S 04/30/88 2 7/8' 4 9327-9353 S 08/30/91 2 7/8' 4 9366-9368 S 08/30/91 3 3/8' 4 9368-9388 S 02/10/94 3 3/8' 6 9366-9406 S 02/25/96 MILLOUTWINDOW 8941'-8947' I 10360' ! FISH - CAMCO BHA #3, RADIUS I I UBHO MONFI, DRILEX TANDEM 2.875" MOTOR. HYCALOG HS-38HG BIT 10360' J I 8936' I--[ BKR WHIPSTOCK I Id I 7" LNR, 26#, L80, .0383 bpf, ID=6.276 I--~ 9618' DATE REV BY COMMENTS 05/12/82 ORIGINAL COMPLETION 06/11/96 PAB SIDETRACK COMPLETION 02/20/01 SlS-SLT CONVERTED TO CANVAS 03/08/01 SlS-LG FINAL 05/24/01 WDQ Pre-Rig PRUDHOE BAY UNIT WELL: D-19B PERMIT No: APl No: 50-029-20707-02 Sec. 23, T11 N, R13E BP Exploration (Alaska) CANVAS UPDATE: 03/08/01 TREE = 6" CIW 13-3/8", 72 #/ft, LB0, I 2702' BTC Top of 7" Liner at +/-6100' MD Window Milled from Whipstock Top of Window at +~-6250' D-19B Proposed Completion 4-1/2" 'X' Landing Nipple with 3.813" seal bore. Cellar Elevation = 43.50' Base Flange = 44.68' Nabors 9ES RKB = 73.5' 4-1/2" 12.6# 13Cr-80 Vam Ace Tubing with GLM's BAKER 7" x 9-5~8" Tie Back Sleeve ZXP Liner Top Packer 'Flex Lock' Hydraulic Liner Hanger GAS LIFT MANDRELS TVD TBD TBD TBD TBD TBD Size 1-1/2" 1-1/2" 1" 1" 1" Valve Type RP Shear Dummy Dummy Dummy Dummy Bridge Plug set at +/-6274' MD Cut and Pul Tubing@ +-6300' Tag TOC with WL @ 6315' MD 5/17/01 FISH IN HOLE 2-3/8" coiled tubing, top at 6834' 5/8" umbilical inside coil, top at 6844' 2 Kinley cutters inside coil. 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 7" x 4~1/2" Baker 'S-3' Production Packer 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 4-1/2" 'XN' Landing Nipple with 3.813" seal bore and 3.725" No-Go ID. 4-1/2" WireLine Entry Guide spaced-out into 4-1/2" liner tie-back sleeve. +/-8,518' I BAKER5"x7" Tie Back Sleeve ZXP Liner Top Packer 'HMC' Hydraulic Liner Hanger 9-5/8", 47 #/ft, L-80, BTC I +/-8668' 7", 26 #/ft, L-80, BTC-Mod 4-1/2" 12.6 #fi-t, L-80, BTC-Mod I +/-10,225' Zone 2A Sands 7", 29 #Iff, L-80, ~ BTC Date 05/18/01 Rev By Comments WDQ Proposed Completion PRUDHOE BAY UNIT WELL: D-19B APl NO: 50-029-20707-02 Shared Services Drilling THE MATERIAL UNDER THIS COVER HAS BEEN MICROF'ILMED · ON BEFORE M PL A T E E IA L U N D W E R T H IS M A R K E R C:LOI~MFrLM.DOC PERMIT DATA ................ 96-031 7055 96 - 031 CN/GR 96-031 IND ELECTRO 96-031 SSVD AOGCC Individual Well Geological Materials Inventory Page: 1 Date: 10/22/98 T DATA PLUS ~IIEL/CN/GR ~/SEPIA ~L~SEPIA ~L~SEPIA 10-407 R COMPLETION DATE ~//~/ ~ DAILY WELL OPS ~ ~1~/~1 TO ~//?/~ RUN RECVD 04116/96 1 04109/96 1 04109/96 1 04109/96 Are dry ditch samples required? yes ~o~3%nd received? y~s--4~ Was the well cored? yes no Analysis & description received? yes no Are well tests required?~s ~_-Received? ~as---~- Well is in compliance Initial COMMENTS STATE OF ALASKA ALASKA ,6'''~- AND GAS CONSERVATION CC'?'MISSION 'WELL COMPLETION ,jR RECOMP LETION hEPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator '7. Permit Number BP Exploration 96-31 3. Address P. O. Box 196612, Anchoraqe, Alaska 99519-6612 4. Location of well at su rface 1880' SNL, 1692' WEL, Sec.23, T11N, R13E At Top Producing Interval 1798'SNL, 1932' EWL, Sec. 23, T11N, R13E At Total Depth 3019 SNL, 3411' WEL, Sec 23, T11N, R13E 5. Elevation in feet (ind i~te KB, DF, etc.) 6. Lease Designation and 78.65' KB 028285 12. Date Spudded 3/~96 17. Total Depth (MD+TVD) 10565', 8930' Serial No. 8. APl Number 5o- 029-20707-01 9. Unit or Lease Name Prudhoe Ba Y Unit 10. Well Number D-19A 11. Field and Pool Prudhoe Bay Field/Prudhoe Bay Pool 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offsh ore 16. No. of Completions 3/16/96 9/17/96 n/a feet MSL zero 18. Plug Back Depth (MD+T VD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafro st 5900, 5698' YES ,~ NO r; I 2104' feet MD 2008' 22. Type Electric or Othe r Logs Run 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH ME: CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORE AMOUNT PULLED 20x30 Insula ted Conductor Surface 110 36" 8 cu. yds concrete 13 3/8" 72# L-80 Surface 2702 17 1/2" 3549 cu. ft. Permafrost II 9 5/8" 47# L-80 Surface 8758 12 1/4" 1177 cu. ft Class G 130 cu. ft. Permafrost C 7" 26# IJ4S 8281 9618 8 1/2" 424 cu. ft. Class G Production (MD+TVD of Top and Bottom and 25. TUBING RECORD 24. Perforations open to interval, size and number None SIZE DEPTH SET (MD) PACKER SET (MD) 5 1/2" I 8221' 8221" W/4 1/2" taill~ipe I to 8357' 26. ACID, FRACTURE, CEMENT S(tJEEZE, ETD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6834-5900' 387 c.f. Class G cement 27. PRODUCTION TEST Date First Production Not on Production IMethod of Operation (Flow ing, gas lift, etc.) N/A r"l ! ¢', ! Date of Test Hours Tested PRODUCTION FOR lOlL-DEL GAS-MCF TEST PERIOD I~ Casing Pressure GAS-MCF Flow Tubing Press. CALCULATED OIL-DEL 24-HOUR RATE ]1~ WATER-DEL WATER-DEL CHOKE SIZE GAS-OIL RATIO OIL GRAVITY-APl (corr) 28. CORE DATA I Brief description of lith ology, porosity, fracture s, apparent dips, and pre sence of oil, gas or wate r. Submit core chips. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. Sag River Shublik Ivishak NAME GEOLOGIC MARKERS MEAS. DEPTF BKB 8803' 8835' 8913' TRUE VERT. DEPTF SS 8413' 8443' 8518' 30. F'_O..RMATIO N TESTS Include interval tested, pressure data, all fluids GOR, and time of each pha se. recovered and gravity, 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and co rrect to the best of my k nowledge Title ¢-rl-) Tc_c. hni¢.~l ~.~.¢i.¢t~nt Date General: This form is des igned for submitting a co all types of lands and le ases in Alaska. Item 1' Classification of Service Wells: Gas injec water disposal, water sup ply for injection, observ Item 5: Indicate which el evation is used as refere given in other spaces on this form and in any atta Item 16 and 24: If this completion), so state in in item 27. Submit a sep data pertinent to such in well is completed for sep item 16, and in item 24 s arate form for each addit terval. Item 21' Indicate whether from ground level (GL) o Item 23: Attached supplem ental records for this we ing and the location of t he cementing tool. Item 27: Method of Operat ion: Flowing, Gas Lift, R jection, Gas Injection, S hut-in, Other-explain. Item 28: If no cores take n, indicate "none". INSTRUCTIONS mplete and correct well c tion, water injection, st ation, injection for in-s nce (where not otherwise chments. arate production from mor how the producing interva ional interval to be sepa r other elevation (DF, KB II should show the detail od Pump, Hydraulic Pump, ompletion report and log on eam injection, air inject ion, salt itu combustion. shown) for depth measurem ents e than one interval (mult iple Is for only the interval reported rately produced, showing the , etc.). s of any multiple stage c ement- Submersible, Water In- Form 10-407 TREE: 6" CIW WELLHEAD: McEVOY ACTUATOR: OTIS ,--3-19A Status at Shutdow,. ~' KB. ELEV =78.65' BF. ELEV = 42.95' SSSV LANDING NIPPLE I 21 04' ( OTIS )(4.562" ID) I 13 3/8", 72#/ft, L-80, BTRS 12702' I KOP: 4000' MAX ANGLE: 24° @ 5300' Top of Coiled Tubing @ 6834' BKB Top of Umbilical @ 6844' BKB 5 1/2", 17#/ft, L-80, AB BTRS TUBING (IPC) TUBING ID: 4.892" !CAPACITY: .0232 BBL/FT -G/~S LIFT MANDRELS lC)TIC; I RI') W/I:'A I AT~I-I~ · N~ MD(BKB) TVDss 12 3000' 2921' 11 4864' 4751' 10 5966' 5759' 9 6121' 5903' 8 6606' 6355' 7 6763' 6502' 6 7125' 6838' 5 7279' 6983' 4 7602' 7287' 3 7756' 7432' 2 7902' 7568' 1 8063' 7718' 5 1/2" SLIDING SLEEVE I I 81 35' (OTIS "XA")(4.562"1D) I I TOPOF I 7" LINER 8281' 9 5/8", 47#/ft, L-80, BTRS I 8758'1~ BOT SBR 8201' I 9 5/8" PACKER I I ( BOT ) (4.750"1D) 8221' 4 1/2", 12.6#/ft, L-80 TAILPIPE 41/2 X"NIPPLE .... (OTIS) (3.813" ID) 8284' 4 1/2 .... XN" NIPPLE 5' (OTIS) (3.725" ID) I 831 41/2"TBGTAIL ! 8357'1 ( BOT )(SOS) (ELMD-REF BHCS 5-7-82) I 8348'1 MARKER JOINT 9158' I Hole and Coiled Tubing are filled with 8.9 ppg drilling fluid. Whipstock PERFORATION SUMMARY REF. LOG: SWS-BHCS- 5-7-82 TIE-IN LOG: SWS - CBL 5-10-82 I SIZE I SPF I INTERVAL 27/8'1 4 I 31/8'1 4 I 27/8'1 4 I 2 7/8'~ 4 I 33/8'] 4 J 3-3/8"/6 ! 9240- 9250' 9300- 9310' 9327- 9353' 9366-9368' 9368-9388' 9366'-9406' OPEN/SQZ'D; SQZD/4-30-88 SQZD/4-30-88 SQZD/8-30-91 SQZD/8-30-91 SQZD/2/10/94 OPEN/2/13/94 PBTD [ 9580'1 7", 26#/f1:, L-80, IJ4S ] 9618'J %%%%% '%/%/%/%/%/ '%/%/%/%/%/% %/%/%/%/%/%' '%/%/%/%/%/%' '%/%/%/%/%/%' '/%/%/%/%/%' '%/%/%/%/%/%/ 2 3/8" Coiled Tubing Hydraulic / Electric Umbilical TD 10,564' 3.5" open hole FISH: LOST 4-22-86- BOWSPRING CENTRALIZER ARM, 2' L x 1/2" W x 1/8" T. FISH IS AT OR BELOW 9460' WLM. Well: D-19A Accept: 3/1/96 Field: Prudhoe Bay Spud: 3~2~96 APl: 50-029-20707-01 Release: 3/30/96 Permit: 96-31 CTD Unit: 9485 Prep Work 2/26/96 Top of whipstock set at 8936 ft bkb, top of tray is facing 18 deg left of high side. Liner deviation - 15 deg. at whipstock depth. 2/27/96 BHA #1: Milled XN nipple at 8322' CTMD (9 stalls, 50 min). Tagged whipstock at 8951+'. Milled to 8955' (5 stalls, 1.5 hr.). Mill worn to 3.72". BHA #2: Reamed into window 8951 - 8954 ft. Milled a further 5 ft from 8954 to 8959 ft. (Milled a total of 3.5 hr., 2 stalls). Mill worn to 3.72". BHA #3: Drilled additional 12 ft of formation from 8958 ft to 8970 ft (4'/hr). Reamed window with dual string mills to clean it (1 hour). Formation mill worn heavily on shoulder. Gauge was 3.73". Gauge on upper reamer was 3.75"+. The 7' by 3.8" string mill assembly passed through the window easily. Camco dummy BHA not run. No biozan pumped. Tubing freeze protected to 500'. FIowline freeze protected. SideTrack Date Day Depth 3/1/96 1 8956 N/u flowcross and 4 1/16" bops, remove hand rails on wellhouse, position substructure over wellhouse with crane, spot CTU #4985, release crane due to high winds, position EWS fluids skid and equipment. Call out crane [wind at 10 mph]. Pick tower sections and set injector head on tower. 3/2/96 2 8977 R/d peak crane, r/u work floor, m/u lubricator, m/u Camco BHA #3, perform bop function and press test, m/u Radius directional equipment, test expansion joint, circ hot seawater to warm CT and test HB&R fluids skid, m/u Drilex 1.20 deg bent motor with 3 3/4" used bit. RIH circ at min rate, check orientor at 5000 ft, worked well, cont. RIH. Tagged whipstock, corrected depth to 8936 ft, RIH and tagged td at 9854 ft, drilled directional hole to 8977 ft bkb. 3/3/96 3 9132 Drill build section from 8977 - 9044 ft with 1.2 deg bent motor, take surveys every 30 ft. Drill to 9044'. Suction screen plugging problems. Blew main hydraulic pump on ACS unit. Unable to pump. RU HB&R (slow due to phase 2 driving conditions). Attempt to pump. Surface lines froze. POOH. Break out and thaw surface lines. Tarp and heat reel, r/u lines, pump 15 bbl MeOH, circ mud, RIH to td. Drill from 9044 - 9132 ft. Lost circ press and ROP, log gr up through window. Add 8 ft to CTD to tie-in. Correct depth = 9132 ft bkb. POOH to check BHA. 3/4/96 4 9146 POOH. Found washed out valve in manifold. By-passed reversing valves. RIH w/single cone bit. Ream to btm, EWS pump engine/hydraulics overheating, r/u BJ's pump truck, bit stalling frequently, RBI bit had 3.5" long gauge protection on sides, bit cone did not rotate on btm, POOH, change out monel, motor and run bit #1 rr. RIH, drill build section from 9133 - 9146 ft. 3/5/96 5 9164 POOH. Bit face worn. RIH w/bit #3. Drill from 9146' - 9161' Drilling boulders. Camco BHA #3 shorted. POOH. Bit face 60% worn, 1/16" under gauge. M/u Camco BHA #2, m/u monel, circ. FIo-pro, m/u Drilex 1.9 deg bent motor and diamond bit. RIH. Ream last 6 ft to td, drill from 9161 - 9164 ft. 3/6/96 6 9206 Drilling in zone 3 with diamond bit. Drill from 9164 - 9201' Slow drilling, 3-4'/hr. Ran gr. Add 5 ft to depth [TD = 9201 ft bkb]. Lost BJ's pump, POOH while repair BJ's pump for bit change. Bit was 1/16" under gauge, RIH, BJ's pump repaired, ream from 9152 - 9180 ft bkb. Slow reaming. Difficult reaming due to several stalls. 3/7/96 7 933O Ream from 9180 - 9206 ft with new TSP. bit. Slow, 4'/hr. Only drilled at 1'/hr in new hole. Drilled to 9207'. POOH for bit change. Bit worn but in gauge. RIH w/ BHA #7. Slow drilling then broke into normal sand, 10-20 FPH. Short trip 300 ft @ 9304, no tight spots. Cont drilling to 9330 3/8/96 8 9507 Drill to 9333'. Run gr, +5' correction. Drill to 9507'. Build angle and turn. ROP increased below 9380'. Slower and stalls from 9440' - 9470'. Stacking wt and not drilling on bottom. Attempt to run gr. Tool shorted. POOH. Bit worn 50%, in gauge. Radius tool OK. Camco BHA shorted. Swap to BHA #3. PU new tandem motor and bit and RIH. Check injector head while RIH. Prep to swap system to new mud. 3/9/96 9 9611 Tag btm. Try to run gr strip-went to dead short. Tool tested fine @ 4500 while RIH. POOH. Radius shorted. Camco BHA #3 OK. RIH w/BHA #9. Oriented at 4500', OK. Tagged and ran gr tie-in. Td @ 9511'. Swapped over to new mud. Reamed tight spots at 9475' and 9490' (2 hr. to clean up). Lost steering signal when oriented to hs. POOH. Found Radius tool bad. Switch tools & test. RIH. No problem washing to btm. Cont. drilling from 9512 to 9611. Penetration from 20 to 50 FPH. Good sand 3/10/96 10 9900 Drill from 9611 to 9670. Ran gr. Some cuttings build-up between 9300' - 9400'. Wiped clean. Drilled ahead. Stacking problems. Weight 6k# heavier after mud swap. Added Lubetex. Improved some. ROP improved below 9745'. Drilled to 9800', stringers with ROPs as high as 100'/hr. Ran gr. Cont. drilling to 9888 where we had trouble drilling. Acted like bit bailing in 21n clay. Lost Radius signal while trying to drill through it. Broke through clay and drilled to 9900 ft. Pulled out. Stopped in 7 inch liner to change 2 injector arm roller bearings. Freeze protected coil on the way out. 3/11/96 11 10021 Pull out to check tools. Kemlon pin broken. Camco BHA OK. Change out monels. RIH w/BHA #10. Reamed tight spots from 9870' - 9890'. Drilled from 9900' - 9950', 35' ROP. Trying to drop angle, but bouncing off hard streaks. Losing approx. 1-2 bbl/hr returns. Ran gr. Drill ahead. Turned toolface to 135 right @ 9956. Drilled down to 9986 then had difficulty getting wt to btm. Had to ream hole above to continue. Drilled to 10010 and surveyed. Re-oriented to 45 right to begin building again so that hole would level out at +/- 8953 tvd. Drilled to 10015 and began to stack out again. Worked pipe without success. Reamed hole from 9900 to td at several tool faces. Finally got wt to btm but then would stall very easily. Cont. drilling @ 5-6 FPH. Frequent stalls. High drilling torque. Bit finally quit drilling. Ran gr strip and check shot. Pulled out. 3/12/96 12 10155 Pull out to check tools. Bit completely cored out (looks like an ash tray). RIH w/ BHA #11. Sat down at 9936' while washing down. Drilled off. Drill ahead. 55'/hr ROP w/25'/hr alternating hard streaks. Drilled down to 10155 when bit quit. Ran gr strip and caught sample at 10140 ft. Pulled out. Bit cored out. Changed Radius tool, motor, and bit. Check Camco BHA. Ran in w/bit #10. 3/13/96 13 10248 Ran in w/bit #10. Drill 25 ft. Orienter quit. POOH. Swap out BHA's. RIH. Drill 70 ft. Drilling. 3/14/96 14 10366 Drilled w/bit #10 to 10360. Could not make any more hole. Pulled out and changed bit and motor. Drilled from 10360 to 10366. Had great difficulty getting through hard spot @ 10360. Once through the hard spot the bit drilled w/high torque with frequent stalls. Pulled out to change bit and motor. 3/15/96 15 10400 Pulled out of hole, change out bit and motor, TIH. Drill to 10400', lost Radius tools. POOH. Bit starting to core out. Decision made to run logs. Lay down BHA. Prepare upper connector. MIRU/atlas. PU deep ind, short normal,cnl,gr, sp. Retrieve MeOH and RIH. Trouble w/atlas counter wheel on way in. Fixed same. Correct depth in liner. Run into open hole 3/16/96 16 10500 Ran logs. No problem getting to bottom. Decided to drill ahead. At report time: Total Depth 10500. Angle 96 deg. 3/17/95 17 Stuck tools at 10384 following short trip. Motor stalled when pipe got stuck indicating that bit is stuck. After working pipe for 12 hours decided to disconnect. Unable to disconnect. 3/18/95 18 Reverse circulated and pumped acid in attempt to free pipe. No success. Displaced coil to N2 in attempt to increase buoyancy. No success. Plan to pump larger acid job today. 3/19/96 19 10564 Circ N200H through choke. Pipe did not come free with N2 in the coil. Pumped 10 bbl of gelled 15% HCl/6% HF acid with water spacers and spotted across BHA in stages. Worked pipe. Did not pull free. Bullheaded live acid away then circulated bottoms up. Mixed and pumped 14 bbl bleach spear and 24 bbl of Ml's SFT spotting fluid in open hole section. Let soak in an effort to reduce drag in open hole from that might be preventing maximum pull on stuck BHA. 3/20/96 20 10564 Soak Ml's SFT across open hole. Work pipe beginning after 8 hr soak. No success. Worked fresh SFT around BHA every few hours and soak again. Work pipe- no success. Pressured up wellhead to 1950 psi and pulled 80% of yield at that collapse condition in an effort to increase buoyancy and pull downhole. Worked pipe without success. Pumped last 3 bbl of SFT across BHA and soaked. Worked pipe-no success. Circulated out bleach spear and SFT to surface under choke. Condition mud and prepare for 3rd high strength mud acid treatment. 3/21/96 21 10564 Changed-out brass in pack-off to larger ID, pump 25 bbl bleach, pump 44 bbl 15%/6% gelled HCl/HF acid in stages. Let acid soak, lost returns when acid left bit, work CT to 82,000 lb., pumped 57 bbls FIo-pro down CT ann. to bullhead acid to formation. Pump 5 bbls seawater and 5 bbls MeOH to frz protect CT ann. Had a pin hole leak in CT at measuring wheel near reel 3/22/96 22 10564 Pull CT to 80K, still stuck, hold 72 K on CT. Freeze protect 5.5" tubing to 1500 ft. Release BJ's pump truck and 2 heaters. All equipment off location except Camco CTD unit and EWS fluids skid. Well is dead. 3/28-30/96 Well on vacuum. Cut coil at surface. Drop Kinley cutter and cut umbilical at 6844' (2 attempts). Recovered umbilical. Cut and recovered coil from 6834'. Freeze protect tubing. Final siwhp = 800 psi. (gas cap in the well). RDMO. Note: injectivity when fluid packed is approx..5 bpm/1000 psi. 9/17/96 Well was SI w/2500 SIWHP, killed well with 200 bbls sea water. Pumped 5 bbl fresh water lead, 69 bbl cmt, 5 bbl fresh water tail and 132 bbl diesel displacement. The last 5 bbls were squeezed in wNVHP approaching frac pressures. Estimate TOC @ 5900' Cement used: 15.8 ppg, Class G 4 hr thickening time, 70 mL fluid loss DRILE BP EXPLORATION (ALASKA)INC. END OF WELL MAP D-19 A SIDETRACK PRUDHOE BAY ALASKA True (-1.1 7) NORTH REF. TO GRID NORTH Mag (+28.37) EXPLORATION (ALASKA)INC. ST-00G : Planned Sidetrack D19A-00 : D-19 Actual Sidetrack D-19ORG : Original Wellbore 8400~ 8600 8800-- 9000 · 9200 I ~.-..._ Original Wellbore Planned Sidetrack ii i Actual Wellbore E/W Scale I Inch: 400 It O Original Wellt .... Planned 400 _ ,. -- (33 -- 0 -- -- - -400' -- -- -- -- __.- -- -- -- -- -800 -- -- -- -- -- · -1200 -- -- -- -- -- -- --1600 Vertical Section Scale 1 inch: 200 It P.LANE oF VERTICAL SECTION 188.55° Referenced to True North III I File Name : c:~bp~d-19~d-19eow, plo Drawn By : Bimo Hadiputro Date : April 8, 1996 Sheet1 D-19A SIDETRACK END OF WELL SURVEYS PREPARED FOR TED STAGG (BP) i MDI inc. Dirl SS TVD VS] N/(-S)I ......... ~-~) .... -Build _Turn.l ._D_o_g_.le_~ ASP Y ASP X}'~:-~'~-~{~ ................................... ft deg deg ft ft ft ft deg/100' deg/100'/deg/100 ft ft 8900.0 17.1 302.2 8505.5 203.2 76.3 -':1648.8 0.0 0.0/ -'0.0 ---5959151.0 651819.0 1. TIE IN POINT 8946.6 17.1 302.2 8550.0 197.9 83.6 -1660.4 0.0 0.0~ 0.0 5959158.0 651807.3 8968.0 20.1 300.2 8570.3 195.4 87.1 -1666.2 14.0 -9.5 14.3 5959161.5 651801.3 2. KoP 'R998.0 21.3 296.2 8598.4 192.1 92.1 -1675.6 4.0 -13.3 6.2 5959166.5 651791.9 , ~ '" 28.0 22.4 291.2 8626.2 189.4 96.6 -1685.8 3.7 -16.7 7.2 5959171.0 651781.6 [ 9058.0 23.4 288.2 8653.9 187.4' 100.5 -1696.8 3.3 -10.0i 5.1-- 5959174.5 651770'.5 9073.0 23.8 284.7 8667.6 186.7 102.2 -1702.6 ...... 2.7 -23.31 9.7...... 5959176.0 651764.7 9088.0 23.6 280.7 8681.3 186.4; 103.~ -1708.4 -1.3 -26.7 ...... -1-~-~- ............ 5-~9177.0651758.8 ............................... 9108.0 24.6 278.5-- 8699.6 186.4 104.9 -1716.5 5.0 -11.0 6.7 59591'78.0 651750.8 9138.0 26.7 274.5 8726.6 187.2- 106.3_ ...... _--_1_72_9_:4 ........... .7..__.0..i-_._'.~ii.-_"_':'13;~"_-..'i_-.'ii~i~-%'i!'~.' ............... ~-~--~'~'-'~-9.0 ............. 6'~'~,~'~':-8- ................................................ 9168.0 31.5 269.7 8752.9 189.2 106.~' -1744.0 ........ ~'~'~' F ....... - 1--'~.-0- ............ '{'~'7~- 5959179.0 .......... -~ 5-'-~-~, ...................................................... 9198.0 38.3 261.4 8777.5 193.6 105.2 -1761.0 22.7 -25.7 27.0 5959177.0 651706.3 9228.0 42.9 254.0 8800.2 201.0 101.0 -1780.0 --- 15.3 - .2417 ...... 2-~-~-~- ............ 5959172.5 651687.3 ............................... 9258.0 48.1 246.2 8821.3 211.6 93.6 -1800.1 17.3 -26.0 25.4 5959165.0 651667.4 9288.0 '53.5 239.6 8840.3 225.6 83.0 -1820.7 18.0 22.0 24.8 5959154.0 651647.0 9318.0 57.1 232.3 8857.3 242.7- 69.2 -1841.1 12.0 -24.3 23.3 5959140.0 651626.9 .................................... ..P~52.0 61 .~' 223.7 8874.8 265.6 49.6 .......... L'{'~-~.~'~ ........... 1-~'~' ........... :~_5.--,~ .......... -~',~:'~' ............. 75'~-~-9~"~ ~'.~- .......... ~Z~'~'i~-.'~ ( .;2.065.8 217.5 8888.1 288.6 29.2 -1880.2 15.0 -20.7 23.8--- 5959099.0 651588.-6- I t12.0 70.2 211.6 8899.4 313.9 6.3 -1895.9 14.7 -19.7 23.4 5959076.0 651573.4 Z~. .... .......... 97_1_i ............. iii.'. - 9472.0 75.0 196.0 8917.5 369.2 -45.9 -1918.7 9.3 -25.3 , ...... ~2-~-i-~)- 5959023.0 651551,6 ....................................................... 9504.0 78.9 187.8 8924.8 400.3 -76.4 --_1925.1 12.2 -25.6 27.8 5958992,5 65154518 ....................................... 9534.0 82.6 186.~- 8929.6 429.9 ............ :'1-0-5~-8- .......... '"~';9~:~' ................ ;i'"~':"~ ................. :'~-,"~ ........ ~'~'i'~ ......... ~';~-~-~'~'~'1'5 -- 9564.0 87.5 188~- 8932.2 459.7 -135.4 ...... ':{ ~-~-:~-~- .............. i-'~7~- .................. ~7~' ................. ~-~"i'~ ................ ~-6~'~-~-~'i'~ ............... 9594.0 89.0 185.7 ---8933.1 - 489.7 -165.1 -1936.3 .... 5.0 _8.0 ........... ~-~ ........ -5-~58903.5 651536.4 ................................... , Page 1 Sheet1 9654.0 91.2 180.1~ 8933.2 549.~ -225 OI -1939 2f. 50l I~ ......... '--~ ........ -'- ..........[ " -8 7 10 O i 5958843 5 651534 81 9694.0 88.4i 178.0i 8933.4 588.~1 -265.01 -1938.5 -7.0 -5.2' 8.71 5958803.5! 651536.3 - 9724.0 85.2 175.-'~___.~ 8935.0 61---~-~I ...... --2--~--~'t- -1936~'t' -1'~"~' '-8'~' 13 5!' -S&j~:~:7~ 5i 651,~3~-6 .... ..... '_ .............. '._..~ ........ · ........... ~ : _ : .. J ..................... ~ .................. '. ............. 9754.0 85.2! 172.6] 8937.5 646.5! -324.7] -1933.7 0.01 -9.7. 9.6 5958744.0 651542.3 / -! -354.~ --;i'~J-.b-i ........... -376- ....... :;.;._~.L,,-o ......... ;i'-'i':~ ....... -6--5-~-~7~. :~'t/ 9784.0 86.1 169.21 8939.8 -674.8~ 5958714.5 --' 9815.___~.. 87.1 165.8 8941.~- 703.4 _ -384.4 -1922.2 .... --3.--2 ........ -.1_..~I.0 .......... !.1__._4. 5958684.5 651555.0]' ...... 9__8_4_4_...0..] 86.2 161.7 8943.3 729.4 -412.2 -1914.1 -3.1 -14.1 14.5 5958657.0 651563.7 9874.0 ..... §~i~- .............. ~'-,~'~'i-~) ..... ~',~,~ .............. ~-~-~-~ ........ _~'1~.~ -i'90~.6 ~.0 _i'5:7-' 15.8 "~-~2~i~ ' 6'~'i~-2,.'8 .... _ ___ _(,'~ ¢.0 88.5. 157.3 8946.4 780.5 -467.8 -1891.9 5.7 1.0 5.8 5958601.5 651587.0 , i~ 34.091.0 155.8 8946.5 805.6 -495.3 -1879.9 8.3 -5.0 9.7 5958574.0 651599.5 9964.0 90.3 154.1 8946.2 830.2 -522.5 ~1867.2 -2.3 ~5.7 6.1 5958547.0 651612.8 9994.0 85.9 155.0 8947.2 854.7 -549.5 -1854.3 -14.7 3.0 15.0 5958520.0 651626.2 -- 10008.0 84.9 155.8 8948.3 866.2 -562.2 -1848.5 -7.1 5.7 9.1 5958507.5 651632.3 10044.0 86.9 159.8 8950.9 896.7 -595.5 -1834.9 5.6 11.1 12.4 5958474.5 651646.5 10074.0 90.6 163.0 8951.5 923.1 ~623.9 -1825.4 12.3 10.7 16.3 5958446.5 651656.6 10104.0 90.1 164.5 8951.4 950.1 -652.7 ....... --:1"8-~'~ .--~ ........... ;~. 7-- ............. ,~'~ .............. ~'i',~ ............... ~'~-~'2,-1-'~"i'~- ................ ~',~"i"~-,~-~- 10124.0 88.7 166.6 8951.6 968.3 -672.0 -1812.0 -7.0. 10.5 12.6 5958398.5 651671.0 10164.0 86.0 164.4 8953.4 1004.7 -710.7 ..... '::~-§'8~-;~- ......... ;6%~--; ............... :,~'~- .................... ~-';':7- ............... ~§:~'--~-~0- ........... (~-6--~-.-~ ................................................. 10204.0 86.4 165.6 8956.1 1041.0 -749.2 -17~1 6 --- 1.0 -3.0 3.2 5958321.5 651692.9 ........................ .__ 10244.0 88.1 166.8 8958.0 1077.6 -788.0 -1782.0 4.3 3.0 5.2 5958283.0 651703.3 __ 10284.0 91.3 168.0 8958.2 1114.6 -827.1 -1773.3 8.0 3.0 8.5 5958244.0 651712.8 , 'f t.0 94.8 168.3 8956.1 1151.7 -866.2 ~1765.1 8.8 0.7 8.8 5958205.0 651721.8 ;'.-,1.0_ 95.2 169.6 8954.6 1167.6 -882.8 -1761.8 2.4 ___7.6 .......... __8._0_ .............. ___5.958188.5 651725.4 -~' ,4.0 98.6 171.6 8947.0 1226.6 -944.5 -1751.6 5.4 3.2 6.2 5958127,0 651736.9 10441.0 98.5 174.3 8941.5 1261.6 -980.8 -1747.1 -0.3 7.3 7.2 5958091.0 651742.1 10484.0 95.8 177.3 8936.2 1303.0 -1023.3 -1743.9 -6.3 7.0 9.3 5958048.5' 651746.1 -- 10534.0 94.4 181.0 8931.7 1352.0 -1073.1 -1743.1 -2.8 7.4 7.9 5957998.5 651747.9 10565.0 93.5 183.2 8929.6 1382.6 -1104.0 -1744.3 -2.8 7.2 7.7 5957967.5 651747.4 3. TD Notes: 1. The Relative N/S and E/W values above is-~lative off of surface Ioc~ation referenced to True North ............................ 2. Grid convergence is 1.17° East and Magnetic Declination to True is 29.54° ' ......................................................................................................... Page 2 Sheet1 I RKB DEPTH · '78.7' ,,, CUSTOMER' BP EXPLORATION INC. 'WELL NAME: D-19 LOCATION: PRUDHOE BAY, ALASKA bRLG. ENGINEERS TED STAGG, BROCK WILLIAMS (BP) DATE' I I 3/3/96 TO 3/15/96 " 3TIONAL DRILLERS Phillip Marwood ((DRILEX)) . ,, I'ICAL SECTION' USE 188.55° to Grid ~_ ;LINATION TO TRUE 29.54° GRID CONVERGENCE 1.17° ~NTERPOLATED POINT 8900 MD -KOP POINT 8968 MD -. THESE SURVEYS ARE TRUE AND CORRECT TO THE BEST OF MY KNOWLEDGE. BIMO HADIPUTRO - DRILEX SERVICES INC. =. Page 3 ANNULAR INJECTION DATA ENTRY SCREEN A s s e t .~0~,. ......................................... 'Rig Name .blab~3r.s..?_SE ........................... Inj Well Name ..Y..~'3.6.1 ....................................... Permit Start ....... 5./..5./.,9.5 ...... Sur Csg Dap .3.5.0.9. .............. · .............................. Cumulative Data Legal Desc .5.0Q:$EL..6.7.,3:E.~L..$ec...3..4,...T..1.1N,..B..!.,3E .......................... R e s e a r c h ........................................................................................................................ C.o.r,[ec t ..c Qp.y..s~ ~L..to..AQ.G C.C...Q Q..2.;26.; 9.7. .............. Rig Completion Formation Well Total Mud/Ct.g Wash Fluids Fluids ..,.....4o2,9.7....~ ......... :.. 3 . .A .4.1 .................. 5.89 .................................................................... Permit E n d ....:I..2.L3..1.J..9.5... Intermittant Final Freeze Freeze F Source Date o[ We I Injection Y-36 Daily Data iMud, Ctgs, Cm'~ I I 'lntermittant ~ ~----' : t !Contaminatedj RigWash Completion Formation Freeze I Freeze ~ DailY: Drlg Mud / Fluids Fluids FlUids· ] Protection I Protection Total; :: 235 Y-38 Y-38 Y-38 05/07/95 655 Y-38 '0'5'/08/9'5''"'-"'"----"' 105 Y-38 142 Y-38 05/1 0/95 337 I Y- 38 '~"~'Ti-'i")-'~-~- 321 !Y-38 05/12/95 .~29 ~Y-38 05/1 3/95 ~':'~'~ .... 05/14/95 05/15/95 05/16/95 05/1 7/95 162 45 I --[-- l---- [Annulus ' Pressure Status I Comments Complications . 1993 Year End 1995 YEAR END SUMMARY 05/1 8/95 ~_~.2.55 ...... STATE OF ALASKA ALA; .... OIL AND GAS CONSERVATION COMMISS APPLICA', .ON FOR SUNDRY APi--FIOVALS 1. Type of Request: Abandon __ Suspend X Operation Shutdown__ Re-enter suspended well Alter casing __ Repair well __ Plugging __ Time extension Stimulate __ Change approved program __ Pull tubing __ Variance __ Pedorate __ Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development X Exploratory __ Stratigraphic __ Service 6. Datum elevation (DF or KB) KBE= 78.65 AMSL 7. Unit or Property name Prudhoe Bay Unit 4. Location of well at surface 8. 1880' SNL, 1692' WEL, SEC. 23, T11N, R13E, UPM At top of productive interval 9. N/A At effective depth 10. 2007' SNL, 2652' WEL, SEC. 23, T11N, R13E At total depth 11. 3019' SNL, 3411' WEL, SEC. 23, T11N, R 13E 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Well number D-19A Permit number 96-31 APl number 50- 029-20707-01 Field/Pool Prudhoe Oil Pool 10564 feet Plugs (measured) 8929 feet 6834 feet Junk (measured) 6647 feet ORI61NAL Casing :: Length Size Structural -- Conductor 110' 20x30 Su trace 2666' 13 3/8 Intermediate 8722' 9 5/8 Production -- Liner 1338' 7 Perforation depth: measured Cemented 8c.y. 3549 c. f 1307c. f 424 Measured depth 146' 2702' 8758' 8282-8951' true vertical subsea feet True vertical depth BKB 146' 2702' 8449' 8000c8632' RECEIVED Tubing (size, grade, and measured depth) 5 1/2" L-80 to 8221' with 4 1/2" tailpipe to 8357' Packers and SSSV (type and measured depth) Packers @ 8221' SSSV @ 2104' JUN 1 0 1996 Alaska 011 & Gas Cons. Commission Anchorage 13. Attachments Description summary of proposal X Detailed operations program __ BOP sketch X 14. Estimated date for commencing operation 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Suspended~ Service 17. I hereb~L~ertify that th_e f~regoing is true and correct to the best of my knowledge. Signe"~,~/-F~...-.~7~ 6.~'~~ _ Title Supervisor Gravity Drainage f/ FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOPTest ~ Location clearance~ Mechanical Integrity Test ~ Approved by order of the Commission Form 10-403 Rev 06/15/88 Subsequent form required 10- /'~O'~" Original Signed By David W. Johnston I Approval No.% __ ~O~ Approved Copy Commissioner Returned _ BP EXPLORATION To: A0(~ Anchorage Date: May 14, 1996 From: Subject: Mark Stanley ~ BPX - MB 10-2 Well D-19a Sundry - Suspension of Well Notify AOGCC prior to commencing with plug-back operations. During a sidetrack operation of this well with a coil tubing unit, the coil became stuck when drilling had reached a ._depth of 10564'M.D. Efforts to free the BHA were unsuccessful, complicated by the umbilical cable housed insTde the coil. The coil/cable was eventually severed at 6834'MD and recovered above this point (see attached diagram-[. =oc,'&¢p,,.f-o~ <:~ Et~.~'.' The objective of the planned operation is to suspend the well such a manner that the option exists to conduct a future conventional sidetrack operation from above the coil fish, or, if no suitable reservoir target can be found, to P&A the well completely in the future without the requirement for downhole intervention. . R/U cement unit & attempt to establish an injection rate into open hole. (*See below). Bullhead a volume of cement equivalent to total volume between TD of open hole and 6730'MD inside tubing (less close-ended displacement of coil). Displace to leave the top of cement inside of 5.5 tubing at 6730' MD. Pressure test as per AOGCC requirements. Guideline to the total volume of cement is as follows: ~ya?r~ 1. 3.75" open hole from TD up to liner whipstock = 1628' ( 13 bbls slurry ) 2. 7" liner volume from whipstock at 8936' up to tubing tail at 8357' MD =579' (18bbls slurry) 3. 5-1/2" tubing from tbg. tail to top of C.T. fish at 6830' = 1 527' (27 bbls slurry) 4. 5-1/2" tubing from top of CT fish to 500' above at 6330' = 500' (11 bbls slurry) Total Slurry Volume= 69 bbls 2. R/U S-line, tag cmt plug, verify at least 100' above CT fish at 6730' MD. Pull GLV to allow tbg./IA communication. 3. Freeze protect the top 2200' MD of inner annulus and tubing with diesel. Bleed off any pressure from tubing and inner / outer annuli. 4. Secure well. * 1 a. If it proves impossible to establish an injection rate into the open hole, then the alternative plan will be to rig up coil tubing and lay a balanced cement plug above the C.T. fish at least 500' in height (11 bbls slurry). Revert to original plan once cement in place. If there are any issues that may need clarification please contact me at 564-5938. Thanks. RECEIVED JUN 1 0 t99 Ala~ Oit ~ B~.~ Cons. Commistlion WELLHEAD: McEVOY BF. ELEV = 42.95' ACTUATOR: OTIS 13 3/8"' 72#/ft' I L-80, BTRS 2702' KOP: 4000' 24° @ 5300' 17° @ 8900' 66° @ 9382' 89° @ 9594' 94° @ 10534' 5 1/2", 17#/ft, L-80, AB BTRS TUBING (IPC) TUBING ID: 4.892" CAPACITY: .0232 BBL/FT SSSV LANDING NIPPLE I 21 04' ( OTIS ) (4.562" ID) I GAS LIFT MANDRELS ((3TIC; I RD W/F'A I AT~H~ ,, N° MD(BKB) TVDss 12 3000' 2921' 11 4864' 4751' 10 5966' 5759' 9 6121' 5903' 8 6606' 6355' 7 6763' 6502' 6 7125' 6838' 5 7279' 6983' 4 7602' 7287' 3 7756' 7432' 2 7902' 7568' 1 8063' 7718' 5 1/2" SLIDING SLEEVE I (OTIS "XA") (4.562"1D) 8135' TOPOF [ 7" LINER 8281' 9 5/8", 47#/ft, L-80, BTRS [ 8758'[ BOT SBR I 8201' 9 5/8" PACKER [ ( BOT ) (4.750"1D) 8221' 4 1/2", 12.6#/ft, L-80 TAILPIPE 4 1/2 .... X" NIPPLE (OTIS) (3.813" ID) 4 1/2 .... XN" NIPPLE (OTIS) (3.725" ID) 4 1/2" TBG TAIL ( BOT )(SOS) (ELMD- REF BHCS 5-7-82) 8284' 8315' 8357' 8348' PERFORATION SUMMARY REF. LOG: SWS- BHCS- 5-7-82 TIE-IN LOG: SWS - CBL 5-10-82 SIZE I SPF[ INTERVAL OPEN/SQZ'D 27/8"I 4 I 9240- 9250' SQZD/4-30-88 31/8"I 4I 9300-9310' SQZD/4-30-88 27/8"I 4I 9327-9353' SQZD/8-30-91 27/8"I 4I 9366-9368' SQZD/8-30-91 33;~88,' ~ 9368 9388' SQZD/2/10/94 - 9366' - 9406' SQZD 2/25/96 BAKER WHIPSTOCK [ 8936' WINDOW FROM 8941'- 8947' 3.75" HOLE TO 10564' BIT STUCK AT 10360' FISH IN HOLE: 2-3/8" coiled tubing, top at 6834'. 5/8" umbilical inside coil, top at 6844'. 2 Kinley cutters inside coil. Camco BHA #3, 3.375" OD, 25.08' Radius UBHO, monel, 3.125" OD, 16.8' Drilex tandem 2.875" motor, 12.88' Hycalog, HS-38HG bit, 3.75" OD, .42' Cement plug set 2/25/96 Top @ 9166'. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown x Stimulate Plugging Perforate Pull tubing Alter casing Repair well 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 1880' SNL, 1692' WEL, SEC. 23, T11N, R13E, UPM At top of productive interval N/A At effective depth 2007' SNL, 2652' WEL, Sec. 23, T11N, R13E At total depth 3019' SNL, 3411' WEL, Sec.23, T11N, R13E 5. Type of Well: Development X Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 78. 65 AMSL 7. Unit or Property name Prudhoe Bay Unit 8. Well number D-19A 9. Permit number/approval number 96-31 / 10. APl number 50- 029-20707-01 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured 10564 feet Plugs (measured) true vertical BKB 8929 feet Effective depth: measured 6834 feet Junk (measured) true vertical BKB6647 feet Casing Length Size Cemented Structural -- Conductor 110 20X30 8 c.y. Surface 2666 13 3/8 3549 c.f. Intermediate 8722 9 5/8 1307 c.f. Production -- Liner 1338 7 424 c.f. Perforation depth: measured ORIGINAL Measured depth 146 2702 8758 8282-8951 True vertical depth BKB 146 27O2 8449 8OO0-8632 true vertical Tubing (size, grade, and measured depth) 5 1/2" L-80 to 8221' with 4 1/2" tailpipe to 8357' Packers and SSSV (type and measured depth) 9 5/8" BOT packer at 8221'; 5 1/2" SSSV at 2104' RECEIVED MAY 1 7 1996 feet 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Almmka Qil & ~1~; Cona..Commi~ion Anchoraoe 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1145 18516 94 0 Tubing Pressure 808 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended x Service 17. I hereby_.~rt~oing Si~lned ~/'J,/~ Form 10-404 R~'v 06/1~/-88 is true and correct to the best of my knowledge. Title Coiled Tubing Drilling Engineer Date 05/15/96 SUBMIT IN DUPLICATE TREE: 6" ClW WELLHEAD: McEVOY ACTUATOR: OTIS D ,9A Status at Shutdown KB. ELEV =78.65' BF. ELEV = 42.95' sssv LANDING NIPPLE I 2104' J ( OTIS )(4.562" ID) 13 3/8", 72#/ft, L-80, BTRS 12702' I KOP: 4000' MAX ANGLE: 24° @ 5300' Top of Coiled Tubing @ 6834' BKB Top of Umbilical @ 6844' BKB 5 1/2", 17#/ft, L-80, AB BTRS TUBING (IPC) TUBING ID: 4.892" CAPACITY: .0232 BBL/FT GAS LIFT MANDRELS (~TI~I R~ W/~A IAT~H~ N~ MD(BKB) TVDss 12 3000' 2921' 11 4864' 4751' 10 5966' 5759' 9 6121' 5903' 8 6606' 6355' 7 6763' 6502' 6 7125' 6838' 5 7279' 6983' 4 7602' 7287' 3 7756' 7432' 2 7902' 7568' 1 8063' 7718' 5 1/2" SLIDING SLEEVE I (OTIS "XA") (4.562"1D) 8135' TOP OF 7" LINER 8281' 9 5/8", 47#fit, L-80, BTRS I 8758'J BOT SBR 8201' 9 5/8" PACKER ( BOT ) (4.750"1D) 8221' 4 1/2", 12.6#/ft, L-80 TAILPIPE 41/2 X"NIPPLE .... I I (OTIS) (3.813" ID) 8284' 4 1/2 .... XN" NIPPLE I 5'l (OTIS) (3.725" ID) 831 41/2"TBGTAILI 8357'1 ( BOT )(SOS) (ELMD-REFBHCS5-7-82) I8348'1 MARKER JOINT I 9158' I Whipstock PERFORATION SUMMARY REF. LOG: SWS-BHCS- 5-7-82 TIE-IN LOG: SWS - CBL 5-10-82 INTERVAL OPEN/SQZ'D 9240- 9250' 9300- 9310' 9327- 9353' 9366- 9368' 9368- 9388' 9366'-9406' SQZD/4-30-88 SQZD/4-30-88 SQZD/8-30-91 SQZD/8-30-91 SQZD/2/10/94 OPEN/2/13/94 , /%/%/%/ %%%% '%/%/%/%/% '%/%/%/%/% % PBTD 7", 26#/ft, L-80, IJ4S I 958o' J I 9618' I Hole and Coiled Tubing are filled with 8.9 ppg drilling fluid. 2 3/8" Coiled Tubing Hydraulic / Electric Umbilical TD 10,564' 3.5" open hole FISH: LOST 4-22-86- BOWSPRING CENTRALIZER ARM, 2' L x 1/2" W x 1/8" T. FISH IS AT OR BELOW 9460' WLM. Well: D- 19A Accept: 3/1/96 Field: Prudhoe Bay Spud: 3/2/96 APl: 50-029-20707-01 Release: 3/30/96 Permit: 96-31 CTD Unit: 9485 Prep Work 2/26/9'6 Top of whipstock set at 8936 ft bkb, top of tray is facing 18 deg left of high side. Liner deviation = 15 deg. at whipstock depth. 2/27/96 BHA #1: Milled XN nipple at 8322' CTMD (9 stalls, 50 min). Tagged whipstock at 8951+'. Milled to 8955' (5 stalls, 1.5 hr.). Mill worn to 3.72". BHA #2: Reamed into window 8951 - 8954 ft. Milled a further 5 ft from 8954 to 8959 ft. (Milled a total of 3.5 hr., 2 stalls). Mill worn to 3.72". BHA #3: Drilled additional 12 ft of formation from 8958 ft to 8970 ft (4'/hr). Reamed window with dual string mills to clean it (1 hour). Formation mill worn heavily on shoulder. Gauge was 3.73". Gauge on upper reamer was 3.75"+. The 7' by 3.8" string mill assembly passed through the window easily. Camco dummy BHA not run. No biozan pumped. Tubing freeze protected to 500'. Flowline freeze protected. SideTrack Date Day Depth 3/1/96 1 8956 N/u flowcross and 4 1/16" bops, remove hand rails on wellhouse, position substructure over wellhouse with crane, spot CTU #4985, release crane due to high winds, position EWS fluids skid and equipment. Call out crane [wind at 10 mph]. Pick tower sections and set injector head on tower. 3/2/96 2 8977 R/d peak crane, r/u work floor, m/u lubricator, m/u Camco BHA #3, perform bop function and press test, m/u Radius directional equipment, test expansion joint, circ hot seawater to warm CT and test HB&R fluids skid, m/u Drilex 1.20 dog bent motor with 3 3/4" used bit. RIH circ at min rate, check orientor at 5000 ft, worked well, cont. RIH. Tagged whipstock, corrected depth to 8936_ft~d~ tagged td at 9854 ft, drilled directional hole to 8977 ft bkb.[[;~ ~ {,., ~ ~ ¥ EL D MAY 1 7 1996 Alaska 0il & Gas Cons. commission Anchor,~ge 3/3/96 3 9132 Drill build section from 8977 -. 9044 ft with 1.2 deg bent motor, take surveys every 30 ft. Drill to 9044'. Suction screen plugging problems. Blew main hydraulic pump on ACS unit. Unable to pump. RU HB&R (slow due to phase 2 driving conditions). Attempt to pump. Surface lines froze. POOH. Break out and thaw surface lines. Tarp and heat reel, r/u lines, pump 15 bbl MeOH, circ mud, RIH to td. Drill from 9044 - 9132 ft. Lost circ press and ROP, log gr up through window. Add 8 ft to CTD to tie-in. Correct depth - 9132 ft bkb. POOH to check BHA. 3/4/96 4 9146 POOH. Found washed out valve in manifold. By-passed reversing valves. RIH w/single cone bit. Ream to btm, EWS pump engine/hydraulics overheating, r/u BJ's pump truck, bit stalling frequently, RBI bit had 3.5" long gauge protection on sides, bit cone did not rotate on btm, POOH, change out monel, motor and run bit #1rr. RIH, drill build section from 9133- 9146 ft. 3/5/96 5 9164 POOH. Bit face worn. RIH w/bit #3. Drill from 9146'- 9161' Drilling boulders. Camco BHA #3 shorted. POOH. Bit face 60% worn, 1/16" under gauge. M/u Camco BHA #2, m/u monel, circ. FIo-pro, m/u Drilex 1.9 deg bent motor and diamond bit. RIH. Ream last 6 ft to td, drill from 9161 - 9164 ft. 3/6/96 6 92O6 Drilling in zone 3 with diamond bit. Drill from 9164 - 9201'. Slow drilling, 3- 4'/hr. Ran gr. Add 5 ft to depth [TD = 9201 ft bkb]. Lost BJ's pump, POOH while repair BJ's pump for bit change. Bit was 1/16" under gauge, RIH, BJ's pump repaired, ream from 9152 - 9180 ft bkb. Slow reaming. Difficult reaming due to several stalls. 3/7/96 7 933O Ream from 9180 - 9206 ft with new TSP. bit. Slow, 4'/hr. Only drilled at 1'/hr in new hole. Drilled to 9207'. POOH for bit change. Bit worn but in gauge. RIH w/ BHA #7. Slow drilling then broke into normal sand, 10-20 FPH. Short trip 300 ft @ 9304, no tight spots. Cont drilling to 9330 3/8/96 8 95O7 Drill to 9333'. Run gr, +5' correction. Drill to 9507'. Build angle and turn. ROP increased below 9380'. Slower and stalls from 9440'- 9470'. Stacking wt and not drilling on bottom. Attempt to run gr. Tool shorted. POOH. Bit worn 50%, in gauge. Radius tool OK. Camco BHA shorted. Swap to BHA #3. PU new tandem motor and bit and RIH. Check injector head while RIH. Prep to swap system to new mud. RECEIVED MAY 1 7 199t~ Alaska 011 & G;~ Cons, Commission Anol~or~ge 3/9/96 9 9611 Tag btm. Try to run gr strip-went to dead short. Tool tested fine @ 4500 while RIH. POOH. Radius shorted. Camco BHA #3 OK. RIH w/BHA #9. Oriented at 4500', OK. Tagged and ran gr tie-in. Td @ 9511'. Swapped over to new mud. Reamed tight spots at 9475' and 9490' (2 hr. to clean up). Lost steering signal when oriented to hs. POOH. Found Radius tool bad. Switch tools & test. RIH. No problem washing to btm. Cont. drilling from 9512 to 9611. Penetration from 20 to 50 FPH. Good sand 3/10/96 10 9900 Drill from 9611 to 9670. Ran gr. Some cuttings build-up between 9300' - 9400'. Wiped clean. Drilled ahead. Stacking problems. Weight 6k# heavier after mud swap. Added Lubetex. Improved-some. ROP improved below 9745'. Drilled to 9800', stringers with ROPs as high as 100'/hr. Ran gr. Cont. drilling to 9888 where we had trouble drilling. Acted like bit bailing in 21n clay. Lost Radius signal while trying to drill through it. Broke through clay and drilled to 9900 ft. Pulled out. Stopped in 7 inch liner to change 2 injector arm roller bearings. Freeze protected coil on the way out. 3/11/96 1 1 10021 Pull out to check tools. Kemlon pin broken. Camco BHA OK. Change out monels. RIH w/BHA #10. Reamed tight spots from 9870'- 9890'. Drilled from 9900'- 9950', 35' ROP. Trying to drop angle, but bouncing off hard streaks. Losing approx. 1-2 bbl/hr returns. Ran gr. Drill ahead. Turned toolface to 135 right @ 9956. Drilled down to 9986 then had difficulty getting wt to btm. Had to ream hole above to continue. Drilled to 10010 and surveyed. Re-oriented to 45 right to begin building again so that hole would level out at +/- 8953 tvd. Drilled to 10015 and began to stack out again. Worked pipe without success. Reamed hole from 9900 to td at several tool faces. Finally got wt to btm but then would stall very easily. Cont. drilling @ 5-6 FPH. Frequent stalls. High drilling torque. Bit finally quit drilling. Ran gr strip and check shot. Pulled out. 3/12/96 12 10155 Pull out to check tools. Bit completely cored out (looks like an ash tray). RIH w/ BHA #11. Sat down at 9936' while washing down. Drilled off. Drill ahead. 55'/hr ROP w/25'/hr alternating hard streaks. Drilled down to 10155 when bit quit. Ran gr strip and caught sample at 10140 ft. Pulled out. Bit cored out. Changed Radius tool, motor, and bit. Check Camco BHA. Ran in w/bit #10. 3/13/96 13 102 48 Ran in w/bit #10. Drill 25 ft. Orienter quit. POOH. Swap out BHA's. RIH. Drill 70 ft. Drilling. RECEIVED MAY 1 7 1996 Oil & (~ Con~. Commission Anchorage 3/14/96 1 4 10366 Drilled w/bit #10 to 10360. Could not make any more hole. Pulled out and changed bit and motor. Drilled from 10360 to 10366. Had great difficulty getting through hard spot @ 10360. Once through the hard spot the bit drilled w/high torque with frequent stalls. Pulled out to change bit and motor. 3/15/96 15 10400 Pulled out of hole, change out bit and motor, TIH. Drill to 10400', lost Radius tools. POOH. Bit starting to core out. Decision made to run logs. Lay down BHA. Prepare upper connector. MIRU/atlas. PU deep ind, short normal,cnl,gr, sp. Retrieve MeOH and RIH. Trouble w/atlas counter wheel on way in. Fixed same. Correct depth in liner. Run into open hole 3/16/96 1 6 10500 Ran logs. No problem getting to bottom. Decided to drill ahead. At report time: Total Depth 10500. Angle 96 deg. 3/17/95 17 Stuck tools at 10384 following short trip. Motor stalled when pipe got stuck indicating that bit is stuck. After working pipe for 12 hours decided to disconnect. Unable to disconnect. 3/18/95 18 Reverse circulated and pumped acid in attempt to free pipe. No success. Displaced coil to N2 in attempt to increase buoyancy. No success. Plan to pump larger acid job today. 3/19/96 19 10564 Circ N200H through choke. Pipe did not come free with N2 in the coil. Pumped 10 bbl of gelled 15% HCI/6% HF acid with water spacers and spotted across BHA in stages. Worked pipe. Did not pull free. Bullheaded live acid away then circulated bottoms up. Mixed and pumped 14 bbl bleach spear and 24 bbl of Ml's SFT spotting fluid in open hole section. Let soak in an effort to reduce drag in open hole from that might be preventing maximum pull on stuck BHA. 3/20/96 2O 1 O564 Soak Ml's SFT across open hole. Work pipe beginning after 8 hr soak. No success. Worked fresh SFT around BHA every few hours and soak again. Work pipe- no success. Pressured up wellhead to 1950 psi and pulled 80% of yield at that collapse condition in an effort to increase buoyancy and pull downhole. Worked pipe without success. Pumped last 3 bbl of SFT across BHA and soaked. Worked pipe-no success. Circulated out bleach spear and SFT to surface under choke. Condition mud and prepare for 3rd high strength mud acid treatment. 3/21/96 21 10564 Changed-out brass in pack-off to larger ID, pump 25 bbl bleach, pump 44 bbl 15%/6% gelled HCI/HF acid in stages. Let acid soak, lost returns when acid left bit, work CT to 82,000 lb., pumped 57 bbls FIo-pro down CT ann. to bullhead acid to formation. Pump 5 bbls seawater and 5 bbls MeOH to frz protect CT ann. Had a pin hole leak in CT at measuring wheel near reel 3/22/96 22 10564 Pull CT to 80K, still stuck, hold 72 K on CT. Freeze protect 5.5" tubing to 1500 ft. Release BJ's pump truck and 2 heaters. All equipment off location except Camco CTD unit and EWS fluids skid. Well is dead. 3/28-3O/96 Well on vacuum. Cut coil at surface. Drop Kinley cutter and cut umbilical at 6844' (2 attempts), Recovered umbilical. Cut and recovered coil from 6834', Freeze protect tubing, Final siwhp = 800 psi. (gas cap in the well), RDMO, Note: injectivity when fluid packed is approx..5 bpm/1000 psi. DRILE C__ BP EXPLORATION (ALASKA)INC. END OF WELL MAP D-19 A SIDETRACK PRUDHOE BAY ALASKA True (-1.17) NORTH REF. TO GRID NORTH Mag (+28.37) BP EXPLORATION (ALASKA)INC. 8400-- -- -- -- -- 8600 8800 9000 ~00 ST-00G : Planned Sidetrack D19A-00 : D-19 Actual Sidetrack D-19ORG : Original Wellbore Original Wellbore Planned Sidetrack Actual Wellbore E/W Scale I Inch: 400 It 0 0 0 0 0 0 0 0 0 0 0 0 0 Original Well_~ I I1[ I III II ~ 4O0 _ ,. -- -- 0 -- -- -4OO ,_8oo -1200 -- - ~---1600 Vertical Section Scale 1 Inch: 200 ff PLANE oF VERTICAL SECTION 188.55° Referenced to True North II I File Name : c:tbpld-191d-19eow, plo Drawn By : Bimo Hadiputro Date : April 8, t 996 Sheet1 I [ I I 'D-19A SIDETRACK END OF WELL SURVEYS PREPARED FOR TED STAGG (BP) j / r.~ MD Inc. Dir/ SS TVD VSi N/(-S)- E/(-W) Build Turn Dogleg ASP Y ASP X Comments ~ --' ft deg degl fi: ..... fi: ~' fi:deg/100' deg/100' deg/100' ft ft ~ 8900.0 17.1 302.2 8505.5 203.2 76.3 -:1648.8 0.0 0.0 0.0 5959151.0 651819.0 1. TIE IN POINT ,,.,.., -- 8946.6 17.1 302.2 8550.0 197.9 83.6 -1660.4 0.0 0.0 0.0 5959158.0 651807.3 "---- -- 8968.0 20.1 300.2 8570.3 195.4 87.1 -1666.2 14.0 -9.5 14.3 5959161.5 651801.3 2. KOP -- ! 8998.0 21.3 296.2 8598.4 192.1 92.1 -1675.6 4.0 -13.3 6.2 5959166.5 651791.9 9028.0 22.4 291.2 8626.2 189.4 96.6 -1685.8 3.7 -16.7 7.2 5959171.0 651781.6 -- 9058.0 23.4 288.2 8653.9 187.4 100.5 -1696.8 3.3 -10.0 ,~.1 5959174.5 651770.5 - 9073.0 23.8 284.7 8667.6 186.7 102.2 -1702.6 2.7 -23.3 9.7 5959176.0 651764.7 9088.0 23.6 280.7 8681.3 186.4 103.5 -1708.4 ~1.3~ -26.7 10.8 5959177.0 651758.81 9108.0 24.6 278.5 8699.6 186.4 104.9 -1716.5 5.0 -11.0 6.7 5959178.0 651750.8 9138.0 26.7 274.5 8726.6 187.2 106.3 -1729.4 7.0 -13.3 9.1 5959179.0 651737.8 9168.0 31.5! 269.1 8752.9 189.2 106.7 -1744.0 --~6.0 -18.0 18.2 5959179.0 651723.3 '9198.0 ' 38.3 '"261 .~: 8777.5 193.6 105.2 -1761.0 - 22.7 -25.7 27.0 595917710 ..... 651706.3 9228.0 42.9 254.0 8800.2 201.0 101.0 -1780.0 15.3 -24.7 22.2 5959172.5 651687.3 9258.0 48.1 2~--~.2- 8821.3 211.6 ...... 93.6 -1800.1 17.3 -26.0 25.4 5959165.0--- 651667.4: 9288.0 53.5 239.6 8840.3 225.6 83.0 -1820.7 18.0 -22.0 24.8 5959154.0 651647.0 -- , r' 3318.0 57.1 232.3 8857.3 242.7~ 69.2 -1841.1 12.~- -24.3 23.~ 5959140.0 651626.9 9352.0 61.3 223.7 8874.8 265.6 ............... 49--~ ........... ~-1-'§8~7~ ......... 1-~.-~- ...... 225.37 ........ -2-~'0-' 5959120:0 651605.6: 9382.0 65.8 217.5- 8888.1 288.6 29.3 -1880.2 i5.0--- -20.7 23.8 5959099.0 651588.6 9412.0 70.2 211.6 8899.4----313.9 6.3 -1895.9 14.7 :19.7 23.4 5959076.0 651573.4 9442.0 72.2 203.6 8909.1 -' 340.9 -18.8 -1909.0 ..... 6.7- '-26.7 ....... -2-~ ....... --~959050.5 651560.8 9472.0 75.0 196.0 8917.5 369.2 -45.¢ '1918.7 9.3 :25.3 26.0 5959023.0 651551.6 9504.0 78.9 187.8 8924.8 400.3 '-76.4 -1925.1 12.2 "-25.6 27.8 5958992.5 651545,8 9534.0 "82.6 186.8 8929.6 429.9 -105.8 -1928.9 1-2.3 -3.3 12.8 5958963.0 651542.7 - 9564.0 87.5 188.1 .... 8932.2 459.7 -135.4 -1932.7 16.:~I 4.3 16.9 ...... -,5958933.5 651539.,~ 9594.0 89.0 185.7' 8933.1 489.7 -165.1 -1936.3. 5.0.L__ -8.0 9.4 5958903.5 651536.4 ................................ / Page 1 Sheet1 "9'624.0 89.7 182.7 8933.4 519.5 -195.1i -1938.5t 2.3/ -10.01 10.31 5958873.51 651534.9f - 9654.0' 91.2 180.1' 8933.2 549.21 -225.0t -1939.2' 5.01 -8.7i 10.01 5958843.51 651534.81 _- 9694.0 88.4 178.0~ 8933.4 588.5t -265.0' -1938.5_ -7.0j -5.2 8.71_ 5958803.5 651536.3 ........... 9724.0 85.2 175.5! 8935.0 617.7 -294.9 -1936.8 -10.7 -8.3 13.5~ 5958773.5 651538.6 --9754.0 85.2 172.6i 8937.5 646.5! -324.7 -1933.7 0.0 -9.7 9.6 5958744.0 651542.-~ -- 9784.0 86.1 169.2 8939.8 674.8 -354.2 -1929.0 3.0 -11.3 11.7 5958714.5 651547.7 9815.0 87.1 165.8 8941.7! 703.4 -384.4 -1922.2 3.2 -11.0 11.4 5958684.5 651555.0 9844.0 86.2 161.7 8943.3 729.4 -412.2 -1914.1 -3.1 -14.1 14.5 5958657.0 651563.7 -- ,./ '~74.0 86.8 157.0 8945.2' 755.3 -440.2 -1903.6 2.0 -15.7 15.8 5958629.0 651574.8 ~904.0 88.5 157.3 -8946.4 780.5 -467.8 -1891.9 5.7 1.0 5.8 5958601.5 651587.0 -- -- -- 9934.0 91.0 155.8 8946.5 805.6 -495.3 -1-879.9 8.3 -5.0 9.7 5958574.0 651599.5 9964.0 90.3 154.1 8946.2 830.2 -522.5 -1867.2 -2.3 -5.7 6.1 5958547.0 651612.8 ~'9994.0 85.9 155.0 8947.2 --- 854.7 -549.5 -1854.3 -14.7 3.0 .... 15.0 5958520.0! 651626.2 __ 10008.0 84.9 155.8 8948.3 866.2 -562.2 -1848.5 -7.1 5.7 9.1 5958507.5 651632.3 10044.0 86.9 159.8 8950.9 896.7 -595.5 -183~,.9 5.6 11.1 12.4 5958474.5 651646.5 ' 10074.0 90.6 163.0 - 8951.5 923.1 -623.9 -1825.4 12.3 10.7 16.3 5958446.5 651656.(~' 10104.0 90.1 164.5 8951.4 950.1 -652.7 -1817.0 -1.71 5.0 5.3 5958418.0 651665.6 -- -- 10124.0 88.7 166.6 8951.6 968.3 -672.0 -1812.0 -7.0 10.5 12.6 5958398.5 651671.0 10164.0 86.0 164.4~ 8953.4 1004.7 -710.7 ..... .~.;~-~.~-i-~- ..... _-~.-§ ............. -~5.--5 .......... ~-~- 5958360.0 651681.8 10204.0 86.4 165.6 -8956.1 1041.0 -749.2 -17~.6 1.0 -3.0 3.2 5958321.5 651692.9 1'0244.0 88.1 166.8 8958.0 1077.6 -788.0 -1782.0 4.3 -- 3.0 --5.2 --- 5958283.0 651703.3 -(. !84.0 91.3 168.0 8958.2 1114.6 -827.1 -1773.3 8.0' 3.0 8.5 5958244.0 651712.8 _ 10324.0 94.8 168.3 8956.1 1151.7 -866.2 -1765.1 8.8 0.7 8.8 5958205.0 651721.8 10341.0 95.2 169.6 -~ 8954.6 1167.6 -882.8 -1761.8 2.4 7.6 8.0 5958188.5 651725.4 10404.0 98.6 171.6 8947.0 1226.6 -944.5 -1751.6 5.4 3.2 6.2 5958127.0 651736.9 10441.0 98.5 174.3 8941.5 1261.6 -980.8 -1747.1 -0.3 7.3 7.2 5958091.0 651742.1 10484.0 95.8 177'.3-- 8936.2 130-3.0 -1023.3 -1743.9 -6.3 7.0 9.3 5958048.5 651746.1 --i"0534.0 " 94.4 181.0 8931.7 1352.0 -1073.1 -1743.1 -2.8 7.4 7.95957998.5 651747.9 10565.0 93.5 183.2 8929.6 1382.6 -1104.0 -~-744.3 -2.8 7.2 7.7- 5957967.5 651747.4 3. TD Notes: 1' The Relative N/S and E/W values abov--~ is relative off of surface.. location referenced to True North '" 2. Grid convergence is 1.17° East, and Magnetic Declination to True is 29.54,° ,,1 ...... , .... Page 2 Sheet1 RKB DEPTH' 78.7' CUSTOMER' BP EXPLORATION INC. _ WELL NAME: D-19 LOCATION' PRUDHOE BAY, ALASKA, ELi DRLG. ENGINEERS TED STAGG, BROCK WILLIAMS (BP) ; ' TE ' 3/3/96 To 3/15/96 ~.,.tECTIONAL DRILLERS Phillip Marwood ((DRILEX)) VERTICAL SECTION USE 188.55° to Grid DECLINATION TO TRUE 29.54° GRID CONVERGENCE 1.17° INTERPOLATED POINT 8900 MD KOP POINT 8968 MD THESE SURVEYS ARE TRUE AND CORRECT TO THE BEST OF MY KNOWLEDGE. I BIMO HADIPUTRO - DRILEX SERVICES INC. Page 3 Logging Services To: Pmdhoe Bay LDWG Recipients Date: 18 April 1996 From.: Rodney D. Paulson Subject: Re-release~°f D- 19A LDWG Ta~e The LDWG tape for D-19A accidentally had the data for D-16 copied to it. Enclosed is a corrected tape with the D-19A data on it. Please replace the previous D-19A tape with this one marked ** REVISED ** I apologize for any inconvenience this may cause. Western Atlas International, Inc. 5600 B Street, Suite 201 Anchorage, Alaska 99518-1686 Tel (907)563-3233 Fax (907)563-7803 Thank you, Geoscience Center Manager I:~/X¥ 0 3 1996 Alaska Oi! & Gas Cons. ~mmi~iou ~n~omge LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 18 April 1996 Transmittal of Data ECC #: 6627.00 Sent by: HAND CARRY Data: OH-LDWG Dear Sir/Madam, Reference: D-19A PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 CORRECTED LDWG TAPE Run # 1 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 _/~/ Or FAX~t.o (~07) 563-7803 Received by: ~~~___~ ~~//~ ~/ //~ · ,.. --~ Date: ,,~Y 0 3 1996 Oil & Gas Cons, Commis~ior~ APR Alaska 0il & Gas Cons. Commission Anchorage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Reference: BP D-19A PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 LDWG TAPE+LIS Date: RE: 10 April 1996 Transmittal of Data ECC #: 6627.00 Sent by: HAND CARRY Data: OH-LDWG Run # 1 Please Sign and return to: Attn. Rodney D. paUlson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 ......... ~ / (j~r FAX %o ~907) 563-7803 ~,~,,~,~,,]Vm,,,-",'"' Received by: ~ .~~~..~ _~~ Date~9~' ~ 6 '996 LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Reference: BP D-19A PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Date: RE: Prints/Films: 1 IEL FINAL BL+RF Run # 1 1 CN FINAL BL+RF Run # 1 1 SSVD FINAL BL+RF Run # 1 21 March 1996 Transmittal of Data ECC #: 6627.00 Sent by: HAND CARRY Data: OH-LDWG Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Received by: RECEIVED Anchorage, AK 99518 90?) 563-?803 APR 09 1995 Date: ~l~.b.~;~ 0 ~pA_. ~_ · . ~ch~e 2e of Request: .. Name of Operator BP Exploration (Alaska) Inc. STATE OF ALASKA ALASKA '-" AND GAS CONSERVATION COMMISSION '~ Suspend Operation Shutdo~,. _z__/ Re-enter suspended well__ Alter casing__ Repair well Plugging ~ Time extension Stimulate Change approved program __ Pull tubing __ Variance __ Perforate __ Other__ 6. Datum elevation (DF or KB) KBE = 78.65 AMSL 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development X Exploratory __ Stratigraphic __ Service ORIGINAL 4. Location of well at surface 1880' SNL, 1692' WEL, SEC. 23, T11N, R13E, UPM At top of productive interval N/A At effective depth 2007' SNL, 2652' WEL, Sec. 23, T11N, R13E At total depth 3019' SNL, 3411' WEL, Sec.23, T11N, R13E 7. Unit or Property name Prudhoe Bay Unit 8. Well number D-19A 9. Permit number 96-31 10. APl number ,.~"" 50- 029-20707--~1 11. Field/Pool Prudhoe Oil Pool feet 12. Present well condition summary Total depth: measured 10564 true vertical BKB 8929 Effective depth: measured 6834 true vertical BKB 6647 Casing Length Size Structural -- Conductor 110 20X30 Surface 2666 13 3/8 Intermediate 8722 9 5/8 Production -- Liner 1338 7 Perforation depth: measured feet Plugs (measured) feet feet Junk (measured) feet Cemented 8 c.y. 3549 c.f. 1307c. f. 424 c.f. true vertical Tubing (size, grade, and measured depth) 5 1/2" L-80 to 8221' with 4 1/2" tailpipe to 8357' Measured depth 146 2702 8758 True vertical depth BKB 146 2702 8449 8282-8951 8000-8632 RECEIVED Alsska 0il & 6as Como. commission Packers and SSSV (type and measured depth) 9 5/8" BOT packer at 8221'; 5 1/2" SSSV at 2104' Anchorsge 13. Attachments Description summary of proposal Detailed operations program__ BOP sketch 14. Estimated date for commencing operation 16. If proposal was verbally approved Oil Name of approver Date approved Service 17. I hereby certify th. at the foregoing is true and correct to the best of my knowledge. .Signed ~~ TitleCoiledTubingDrillingEngineer ( ' ~"~// FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance Mechanical Integrity Test S.urqsequCn, t,.formfe~luired 10- Ong na. b gne(] uy David W. Johnston Approved by order of the Commission 15. Status of well classification as: Suspended~ Date 04/10/96 I Approval No.? Approved Copy .l:~..t, J~ed --Commissioner --Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE FREE: 6" C1W WELLHE/~D: McEVOY ACTUATOR: OTIS E ,9A Status at Shutdown KB. ELEV =78.65' BF. ELEV = 42.95' SSSV LANDING NIPPLE J 2104' J ( OTIS )(4.562" ID) 13 3/8", 72#/ft, ..o. .T,S I zo ' I KOP: 4000' MAX ANGLE: 24° @ 5300' Top of Coiled Tubing @ 6834' BKB Top of Umbilical @ 6844' BKB 5 1/2", 17#/ft, L-80, AB BTRS TUBING (IPC) TUBING ID: 4.892" CAPACITY: .0232 BBL/FT GAS LIFT MANDRELS (~TIC::; I RI-) W/PA I ATC. H~ N° MD(BKB) TVDss 12 3000' 2921' 11 4864' 4751' 10 5966' 5759' 9 6121' 5903' 8 6606' 6355' 7 6763' 6502' 6 7125' 6838' 5 7279' 6983' 4 7602' 7287' 3 7756' 7432' 2 7902' 7568' 1 8063' 7718' 51/2" SLIDING SLEEVE I I (OTIS "XA") (4.562"1D) 8135' TOPOF I 7" LINER 8281' 9 5/8", 47#/ft, L-80, BTRS I 8758'1~ BOT SBR 8201' 9 5/8" PACKER (BOT) (4.750"1D) 8221' 4 1/2", 12.6#/ft, L-80 TAILPIPE 4 1/2 .... X" NIPPLE I (OTIS) (3.813" ID) 8284' 4 112 .... XN"NIPPLE I 5' (OTIS) (3.725" ID) 831 4 1/2" TBG TAIL I 8357' (BOT)(SOS) (ELMD- REF BHCS 5-7-82)I 8348' MARKER JOINT 9158' J Whipstock _PERFORATION SUMMARY REF. LOG: SWS-BHCS- 5-7-82 TIE-INLOG: SWS- CBL 5-10-82 27/8"I 4 I 9240-9250' SQZD/4-30-88 3 1/8"I 4 I 9300- 9310' SQZD/4-30-88 2 7/8"I 4I 2 7/8"I 4I 3 3/8"J 4 J I 9327- 9353' 9366-9368' 9368-9388' 9366'-9406' SQZD/8-30-91 SQZD/8-30-91 SQZD/2/10/94 OPEN/2/13/94 PBTD J 9580' J 7", 26#/ft, L-80, IJ4S [ 9618'J .%/%/%/%/ %%%% '%/%/%/%~% '%/%/%/%/% %' · %,,,' ,% Hole and Coiled Tubing are filled with 8.9 ppg drilling fluid. 2 3/8" Coiled Tubing Hydraulic / Electric Umbilical TD 10,564' 3.5" open hole FISH: LOST 4-22-86- BOWSPRING CENTRALIZER ARM, 2' L x 1/2" W x 1/8" T. FISH IS AT OR BELOW 946O' WLM. !~ EXlIL01~AI10N BP Exploration (Alaska) 900 E. Benson Blvd POB 196612 Anchorage, AK, 99519 907 561 5111 Date' April 10, 1996 To: Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention' Re: Blair Wondzell Senior Petroleum Engineer Well D-19A Shutdown of Well Operations Well D-19A is a coiled tubing sidetrack of well D-19. The sidetracking operation began on March 1, 1996 and drilling had progressed to a depth of 10564' BKB when the bit became stuck at 10357' BKB on March 16, 1996. Attempts to free the bit were unsuccessful. On March 30, 1966, the coiled tubing was cut and recovered at a depth of 6834' BKB. Coiled tubing drilling equipment has been rigged down and the well is secured with kill weight mud to surface. A diagram of the current well condition is attached along with Form 10-403. Further recovery of coiled tubing is complicated by an electric/hydraulic umbilical that is inside the 2 3/8" coiled tubing. We are requesting approval to shutdown operations on D-19A pending investigation of fishing or abandonment options. The well will remain shut in. Sincerely, Ted Stagg CT Drilling Engineer cc: Well File Petrotechnical Data Center RECEIVED STATE OF ALASKA ALASrv-~ OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS · Type of Request: Abandon __ Suspend .__ Operation Shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program x Pull tubing__ Variance__ Perforate __ Other__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1880' SNL, 1692' WEL, SEC. 23, T11N, R13E, UPM At top of productive interval 1802' SNL, 1937' EWL, SEC. 23, T11N, R13E, UPM At effective depth 1706' SNL, 1810' EWL, SEC. 23, T11N, R13E, UPM At total depth 1689' SNL, 1791' EWL, SEC. 23, T11N, R13E, UPM 5. Type of Well: Development X Exploratory __ Stratigraphic __ Service ORIGINAL 6. Datum elevation (DF or KB) KBE = 78.65 AMSL 7. Unit or Property name Prudhoe Bay Unit 8. Well number D-19A 9. Permit number 10. APl number 50- 029-20707- 11. Field/Pool Prudhoe Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 9620 feet Plugs (measured) BKB 9279 feet Effective depth: measured true vertical 9511 feet Junk (measured) fill at 9511' MD (05/88) BKB 9173 feet Casing Length Size Structural -- Conductor 110 20X30 Surface 2666 13 3/8 Intermediate 8722 9 5/8 Production -- Liner 1338 7 Perforation depth: Cemented 8 c.y. 3549 C.f. 1307 c.f. Measured d[4~l~ ~ ~ t-~r~ .~,ve~al depth --' "~' '"'" BKB 146 146 2702 MAR 0 1 ]996 2702 Al~i~i¢0il & Gas Cons. Commi~¢.o'~149 Anchor~e 8282-9620 8000-9279 424 c.f. measured 9327'-9353', 9366'-9388', 9240'-9250', 9300'-9310', sqzd 9366'-9406' open true vertical subsea 8914'- 8975' (four intervals) Tubing (size, grade, and measured depth) 5 1/2" L-80 to 8221' with 4 1/2" tailpipe to 8357' Packers and SSSV (type and measured depth) 9 5/8" BOTpacker at 8221'; 5 1/2" SSSV at 2104' Anchorage 13. Attachments Description summary of proposal__ Detailed operations program BOP sketch X 14. Estimated date for commencing operation March 7,1996 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 certify that the foregoing is true and correct to the best of my knowledge. Signed ~_~'/'~ Title Coiled Tubing Drilling Engineer Date 03/01/96 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative maywitneSSplug integrity BOP Test ¢'" Location clearance IAppr°val No' 4::::~(¢ ' ~¢¢ Mechanical Integrity Test Subsequent form required 10- ~ c~ ~' Approved Copy Returngd 0riginalw.Signed Johnston By _~_ David Approved by order of the Commission Commissioner Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE Blind/Shear Slip Rams Slip Ram Pipe Ram I CT Sidetrack BOP for 27/8" ~'~AR 0 1 19~6 .A~a~k~ Oil & G~$ Co,q~. Commi~sio,q A~chor~9~ 23/8" 27/8" 3/8" BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 995t9-6612 (907) 561-5111 To' Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Date: February 27, 1996 Attention: Blair Wondzell Subject: D-19A Application For Sundry Approvals Form 403 Enclosed is a Form 403 for well D-19A to change the BOP system to be used for liner running. A copy of this BOP system is enclosed. If there are any questions please contact me at 564-5894. Thank you. Sincerely, Theresa Mills Coiled Tubing Technical Assistant 3 ~'~AR 0 ] ]996 Alaska Oil & Gas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska)Inc. ~O Box 198612 Anchorage, Alaske g9519-6612 TELECOPY COMMUNICATIONS CENTER Date: P.1 TO: Name: Company: Location: Fax # ~ Confirm # FROM: Name & Ext,; Department: PBU Resource.Mgmt. . Mail Stop: , _ NOTES: PAGES TO FOLLOW (Does Not Include Cover Sheet) SEOURI'I'~ OL^@$1FICATION PRIVATE SECRET CONFIDENTIAL · , , Tele¢opy # 564-5500 Confirm # 564-4225 For Communications Center Use Only Time In Time Sent Time Confirmed Confirmed By Operator BPX D-19A Sidetrack Ravised 2/27/96 _S_ummarv of O=e_[ations: Well D-19 is currently shut-in due to high TGOR. The well is being sidetracked.to achieve lower GOR production. This sidetrack will be conducted in two phases. Phase 1: Cut Window: Planned for Feb, 27-27, 1996. · The existing Ivishak perforations will be cement squeezed. · A whipstock will be set on ELine at approximately 8936' MD. Utilizing a conventional coil tubing unit, a window will be cut in the 7" liner anct 10 ft of formation will be drilled. Phase 2: Drill Directional Hole: Planned for Feb. 29 · March 10, . Directional drilling coil tubing equipment will be rigged up and utilized to drill the directional hole as per attached plan to planned TD of 10548' MD [8931' TVDss). Mud Program: - Please 1: Seawater · Phase 2: FIo-Pro (8.8 - 8.9 ppg) Casing Program: - 2 7/~", 6,16~, L-80, FL.4S liner will be run from TD to approx. 8300' MD and cemented with approx. 70 cu. ft, cement. The well will then be perforated with coil tubing conveyed guns, Well Control: - See attachments. - Phase 1, win~ow milling,, will utilize "Type B" BOP Syste.rn sho, wn..in th.e a. ttac. h..ed diagram. Drilling operat;ons will utilize the fully lubricated system Shown ~n [ne at-~acnea (~iagram, The production liner will be run using the 4.~c[~.~ and annular prey_enter,.system shown in the attached diagram, o~ _(.o.~,~,~./,~';~,.~'+~-~' ~, - Pipe rams, blind rams and the CT PaCk-off will be pressure tested to 400 psi and to 4000 psi. The annular preventer will be tested to 400 psi and 2000 ~i. Directional · See attachements, Kl~k Off: 8936' MD (8540' ,,T~, .D SS) ~ TD: 10,548' MD (8,931 'rVD ss) - Magnetic and incllnatlon suweys will be taken evenj 25 ft, No gyro will be run, Logging . A (~amma Ray Icg will be run over all of the open hol.e section. - A Gamma ~ay /Indu~ion Icg is tentatively scheduled. FEB 2. 7 lg96 Oil & Cms Cons. Commission _ I~o,ooo I i CT Sidetrack BOP for 2 7/8" Liner Running Operations _ 4 111S" lO,GOO psi Annular Blind/Shear ~ 2 3/8" Slip Rams ~ .... 2 718" Blip Ram ~ ~ ~ $/8" Pipe Ram FEB 2 7 1996 Alaska Oil & Gas Cons. Commission Anchorage 2 3/8" CT 10,o00 Ps, k-Off II _. CT Sidetrack BOP for Fully Lubricated Drilling Operations Lubrioator l Bli! Sllp Ram Slip Ram Pipe Ram 23/8" FEB 2 7 19~6 oil & Gas Cons. Commission Anchorag~ ~KA OIL AND GAS CONSERVATION COM~IISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 February 21, 1996 Ted Stagg, Coiled Tubing Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit D- 19A BP Exploration (Alaska), Inc. Permit No. 96-31 Sur. Loc. 1880'SNL, 1692'WEL, Sec. 23, TllN, R13E, UM Btmnhole Loc. 3037'SNL, 3665'WEL, Sec. 23, T1 iN, R13E, UM Dear Mr. Stagg: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill 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) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. Jolm. ston ~ Chairman ~ BY ORDER OF THE COMMISSION dlf/Enclosures Department of Fish & Game, Habitat Section w/o encl. Department of Em4ronmental 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 [] RedrillFlllb. Type of well. Exploratory[] Stratigraphic Test [] Development Oil[] Re-Entry [] Deepen []1 Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration 78.65 feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. 0. Box 196612. Anchoraqe, Alaska 99519-6612 028285 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 1880' SNL, 1692' WEL, SEC 23, T11N, R13E Prudhoe Bay Unit At top of productive interval 8. Well number Number 1798' SNL, 1932' EWL, SEC. 23, T11N, R13E D-19A 2S100302630-277 At total depth 9. Approximate spud date Amount 3037' SNL, 3665' WEL, SEC 23, T11N, R13E, 2/26/96 $200,000.00 :12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and 'rVO) property line ADL028284 @ 1613 feet No close approach feet 2560 10548'MD, 8931'TVDss feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth ~936'MO feet Maximum hole angle 93 o Maximum surface 2500 psig At total depth (TVD) ~00'¢/~430 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M D TVD M D TVD (include stage data) SS 3.75" 2 7/8" 6.16 L-80 FL4S 2250' 8300 7938 10548 8931 70 cu.ft. 19. To be completed for Redrill, Re-entry, and Deepen Operations. FEB 0 9 '1 6 Present well condition summary Total depth: measured 9629 feet Plugs (measured) Alaska Oil & Gas Cons. Commission true vertical BKB9279 feet /~chorage Effective depth: measured 9511 feet Junk (measured) fillat 9511'MD (05/88) true vertical BKB9173 feet Casing Length Size Cemented Measured depth True Vertical depth Structural BKB Conductor 110 20x30 8 cu. yd. 146 146 S u rfac e 2666 13 3/8 3549 cu. ft. 2702 2702 I ntermed iate 8722 9 5/8 1307 cu. ft. 8758 8449 Production --- Lin er 1338 7 424 cu. ft 8282-9620 8000-9279 Perforation depth' measured 9366;9406' Sqzd:9327'-9353', 9366;9388', 9240;9250', 9300;9310' true vertical 8914'-8975'ss(four intervals) 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21.1 hereby certi_fy,,~a~J, he foregoing is true and correct to the best of my knowledge Signed ~¢i///'"~'"~/" .,,r../~ Title CoiledTubin~IDrillin~IEn~lineer Date .z/?/? Commission Use Only Perm[ Number IAPI number IApprov. al dat~_ See cover letter ,~""-~,/' 15 0'':::~''2'' ~-"'~' ~ ~::~ ~ -~:~ '/I ,~:~/'~//~'~:~_ for other requirements Conditions of approval Samples required [] Yes 1~ No Mud log required l~Yes 'J~ No Hydrogen sulfide measures [] Yes [] No Directional survey requ~rea ~ Yes [] No Required working pressure for BOPE 1-12M; 1-13M; 1-15M; I-IIOM; I-!15M; 'l~ Other: .~tg~nal Signed By by order of Approved by 0avid W. Johnston Commissioner zne commission Date-,, - ,w Form 10-401 Rev. 12-1-85 Submit in tripicate BPX D-19A Sidetrack Summary of Operations: Well D-19 is currently shut-in due to high TGOR. The well is being sidetracked to achieve lower GOR production. This sidetrack will be conducted in two phases. Phase 1: Cut Window: Planned for Feb. 14 - 21, 1996. - The existing Ivishak perforations will be cement squeezed. - A whipstock will be set on ELine at approximately 8936' MD. - Utilizing a conventional coil tubing unit, a window will be cut in the 7" liner and 10 ft of formation will be ddlled. Phase 2: Drill Directional Hole: Planned for Feb. 26 - March 10. - Directional drilling coil tubing equipment will be dgged up and utilized to ddll the directional hole as per attached plan to planned TD of 10548' MD (8931' TVDss). Mud Program: - Phase 1' Seawater - Phase 2: FIo-Pro (8.8 - 8.9 ppg) Casing Program: - 2 7/8", 6.16#, L-80, FL-4S liner will be run from TD to approx. 8300' MD and cemented with approx. 70 cu. ft. cement. The well will then be perforated with coil tubing conveyed guns. Well Control: - See attachments. Phase 1, window milling, will utilize "Type B" BOP arrangement. - Drilling and completion operations will utilize the 6-ram and annular BOP arrangement shown in the attached diagram. - Both BOP arrangements allow for tree to remain in place and for the BHA to be fully lubricated above the swab valve. - Lubricator/pack off is pressure tested on each trip. Directional - See attachements. - Kick Off: 8936' MD (8540' TVD ss) - TD: 10,548' MD (8,931' TVD ss) - Magnetic and inclination surveys will be taken every 25 ft. No gyro will be run. LoAgging - Gamma Ray Icg will be run over all of the open hole section. - A Gamma Ray / Induction Icg is tentatively scheduled. FEB 09 Alaska Oil & Gas Cons. Commission /~chorage TREE: 6" CIW WELLHEAD: McEVOY ACTUATOR: OTIS 13 3/8"' 72#/ft' I L-80, BTRS 2702' KOP: 4000' MAX ANGLE: 24° @ 5300' 5 1/2", 17#/ft, L-80, AB BTRS TUBING (IPC) TUBING ID: 4.892" CAPACITY: .0232 BBL/FT 7" LINER 8281' 9 5/8", 47#/ft, I L-80, BTRS 8758' ----- J -19A Proposed Sidetrack KB. ELEV =78.65' BF. ELEV = 42.95' SSSV LANDING NIPPLE i 2104' I ( OTIS )(4.562" ID) GAS LIFT MANDRELS N° MD(BKB) TVDss 12 3000' 2921' 11 4864' 4751' 10 5966' 5759' 9 6121' 5903' 8 6606' 6355' 7 6763' 6502' 6 7125' 6838' 5 7279' 6983' 4 7602' 7287' 3 7756' 7432' 2 7902' 7568' 1 8063' 7718' 5 1/2" SLIDING SLEEVE I I 8 1 35' (OTIS "XA")(4.562"1D) I I BOT SBR I 8201' ( BOT ) (4.750"1D) 8221' 4 1/2", 12.6#/ft, L-80 TAILPIPE 41/2 X"NIPPLE .... I (OTIS) (3.813" ID) 8284' 4 1/2 .... XN" NIPPLE 5'1 (OTIS) (3.725" ID) 831 I 8357' I 4 1/2" TBG TAIL ( BOT )(SOS) (ELMD-REF BHOS 5-7-82) I 8348'1 MARKER JOINT I 9158'1 Whipstock PERFORATION SUMMARY REF. LOG: SWS- BHCS- 5-7-82 TIE-INLOG: SWS - CBL 5-10-82 2 7/8"I 4 I 9240- 9250' SQZD/4-30-88 31/8"I 4 I 9300-9310' SQZD/4-30-88 27/8"I 4 I 2 7/8"I 4I 3 3/8"] 4I 3'3/8"16I 9327-9353' 9366-9368' 9368-9388' 9366'-9406' SQZD/8-30-91 SQZD/8-30-91 SQZD/2/1 O/94 OPEN/2/13/94 PBTD I 9580'1 7", 26#/ft, L-80, IJ4S [ 9618' J %%%%%%' '%/%/%/%/% 3.5" open hole FISH: LOST 4-22-86 - BOWSPRING CENTRALIZER ARM, 2' L x 1/2" W x 1/8" T. FISH IS AT OR BELOW 946O' WLM. TREE: 6" ClW WELLHEAD: McEVOY ACTUATOR: OTIS 13 3/8", 72#/ft, L-80, BTRS 12702' I KOP: 4000' MAX ANGLE: 24° @ 5300' 5 1/2", 17#/ft, L-80, AB BTRS TUBING (IPC) TUBING ID: 4.892" CAPACITY: .0232 BBL/FT -19A Proposed Completion KB. ELEV =78.65' BF. ELEV = 42.95' SSSV LANDING NIPPLE 12104'1 ( OTIS )(4.562" ID) GAS LIFT MANDRELS I~TI~ I RD W/PA I ATOll) Nm MD(BKB) TVDss 12 3000' 2921' 11 4864' 4751' 10 5966' 5759' 9 6121' 5903' 8 6606' 6355' 7 6763' 6502' 6 7125' 6838' 5 7279' 6983' 4 7602' 7287' 3 7756' 7432' 2 7902' 7568' 1 8063' 7718' 51/2" SLIDING SLEEVE i (OTIS "XA")(4.562"19) 8135' TOPOF [ J 7" LINER 8281' 9 5/8", 47#/ft, L-80, aTRS [ 8758'J~ 2 7/8" FL4S cemented line BOT SaR I 8201' ( BOT ) (4.750"1D) 8221' 4 1/2", 12.6#/ft, L-80 TAILPIPE . (OTIS) (3.813" ID), 8284' 4 1/2 .... XN" NIPPLE (OTIS) (3.725" ID) 8315' 4 1/2" TBG TAIL I 8357'J (ELMD - REF BHCS 5-7-82) 8348' MARKER JOINT [9158'1 Whipstock PERFORATION SUMMARY REF. LOG: SWS- BHCS- 5-7-82 TIE-IN LOG: SWS - CBL 5-10-82 4 I 31/8"I 4I 27/8"I 4I 27/8"I 4 I 33/8] 4 I 3-3/8"/ 6I INTERVAL OPEN/SQZ'D 9240-9250' 9300-9310' 9327-9353' 9366-9368' 9368-9388' 9366'-9406' SQZD/4-30-88 SQZD/4-30-88 SQZD/8-30-91 SQZD/8-30-91 SQZD/2/1 O/94 OPEN/2/13/94 PBTD , 26#/ft, L-80, IJ4S I 958o' I 9618' J ,%/%/%/%/%/%/' %/%/%/%/ %/%/%/%/ %%%%%% "%/%/%/%/% %' '%/%/%/%/%/%' '%/%/%/%/%/% '%/%/%/%/%/%/, FISH: LOST 4-22-86 - BOWSPRING CENTRALIZER ARM, 2' L x 1/2" W x 1/8" T. FISH IS AT OR BELOW 946O' WLM. CTF_, .3.2B ICoil Tubing BOPEI Blind/Shear Blind/Shear Pipe Rams Slip Rams I I Pump-In SubI BCP Stack Type B To be used when no mud will be circulated I Spacer Spools I(as needed for Height) I Manual Swab Valve I Hydraulic Act uat ed Valve Manual Mast er Valve · --~.J Exist ing Flowline I Manual Winc Lift Cas In (if applicable) 23,~, CT-~ I 10,000 psi Pack-Off Lubricator D-19A CT Sidetrack BOP for Drilling and Completion Operations Blind/Shear Shear Ram Slip Ram Pipe Ram I I Slip Ram Pipe Ram ]mmTll ~ 2 7/8" BP Exploration (Alaska) Coiled Tubing Drilling & Liner Running Proposed Wellhead/BOPE Confi~Turation -3,500 -3,250 -3,000 -2,750 D-19 Plan View -2,500 250 -2,000 X distance from Sfc Loc 2OO -2OO -400 -600 - -800 - -1,000 -1,200 -1,400 - IWellName D-19 I CLOSURE IDistance 2,288 ft Az 2 38 de~l NEW HOLE E/W (X) N/S (Y) Kick Off -1,657 48 TD -1~950 -1~197 State Plane 651,518 5,957,911 Surface Loc 653,467 5,959,108 I Az Chq MD (ft) Curve I -50.~ 1401 Curve 2 -20.0 130 Curve 3 -5.0 259 Curve 4 -5.0 350 Inverted 733 Total Ddd 1,612 Drawn: 2/7/96 16:01 Plan Name: Case I 8510 8530 8550 8570 8590 8610 8630 8650 8670 8690 8710 8730 8750 8770 8790 8810 8830 8850 8870 8890 8910 8930 8950 D-19 0 200 400 Vertical Section Path Distance (Feet) 600 800 1,000 1,200 1,400 I ITSAD- I I I Angle @ K.O.= 17 deg MD:8936 DL 1= 14 deg/lO0 17 deg DL 2= 9 deg/100 ....... TopZ3 23 deg Top Z2 ........................................................ DL 3= 25 deg/100 8 ~- 21N~'"'"~'"-""~-~-- ........................... 8,950 ........................................ 10548 TD Tot Drld:879 ft Marker Depths @Oriel Wellbore TSAD I 8,5181ft TVD TopZ3 J 8,7191ft TVD Top Z~, I 8,7751ft TVD I 8,94olft TVD 8,95o I 8,9501ft TVD Kick Off I 8,5401ft TVD I 8~9361ft MD Deprtr @KO 1 ~673 f t 8,936I 1,612I 10,548I 8~931~ MD KO Pt MD New Hole Total MD TVD TD Build Rt deg/1 O0 MD (ft) Curve I 0.0 1 4 0 Curve 2 5.0 I 3 0 Curve 3 25.0 259 Curve 4 O. 0 350 Inverted 733 Total Drld 1,612 Drawn: 2/7/9 6 16:01 Plan Name: Case I BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (9O7) 561-5111 Date: Feb. 7, 1995 To: Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Blair Wondzell Senior Petroleum Engineer Re: Well D-19A Prep for CT Sidetrack Well D-19A is scheduled for a through tubing sidetrack to be drilled with coiled tubing. The following summarizes the procedure required to prepare D-19A for sidetracking and is submitted as an attachment to Form 10-403. 1. Perform tubing integrity test. 2. Drift tubing and liner with a 3.7" OD, 20 ft long drift. 3. Run Kinley caliper over the proposed whipstock interval to confirm liner condition. 4. Rig up CTU and drift well with dummy bent housing motor. 5. Squeeze existing perforations by laying cement from PBTD to cover all perforations. Apply squeeze pressure. Reverse out cement to below whipstock depth. Underream whipstock interval to insure clean conditions for setting whipstock. 6. Rig up e-line unit and set whipstock. 7. RU CT service unit and mill window in liner. Ted Stagg CT Drilling Engineer cc: Well File Petrotechnicai Data Center FF..8 0 9 ' 996 Alaska (::)it & Gas Cons. ,-~, STATE OF ALASKA AI. ~, OILAND GAS CONSERVATION COMMISS. , APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown ~ Re-enter suspended well .__ Alter casing ~ Repair well ~ Plugging ~ Time extension ~ Stimulate X Change approved program ~ Pull tubing ~ Variance ~ Perforate × Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development X Exploratory __ Stratigraphic ~ Service 4. Location of well at surface 1880'SNL, 1692' WEL, SEC. 23, T11N, R13E, UPM At top of productive interval 1802' SNL, 1937' EWL, SEC. 23, T11N, R13E, UPM At effective depth 1706'SNL, 1810'EWL, SEC. 23, T11N, R13E, UPM At total depth 1689'SNL, 1791' EWL, SEC. 23, T11N, R13E, UPM 6. Datum elevation (DF or KB) KBE = 78.65 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number D-19 (22-23-11-13) PBU 9. Permit number 82-11 10. APl number 50- 029-20707 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural -- Conductor 110 Surface 2666 Intermediate 8722 Production -- Liner 1338 Perforation depth: 9620 feet Plugs (measured) BKB 9279 feet 9511 feet Junk (measured) BKB 9173 feet fill at 9511' MD (05/88) Size Cemented Measured depth True vertical depth BKB 20X30 8 ¢.y. 146 146 13 3/8 3549 c.f. 2 702 2 702 9 5/8 1307 c.f. 8758 8449 424 c.f. 7 measured 9327'- 9353', 9366'- 9388' true vertical subsea Tubing (size, grade, and measured depth) 5 1/2" L-80 to 8221' with 4 1/2" tai~ipe to 8357' 8282-9620 8000-9279 Sqzd: 9240'-9250', 9300'-9310', FEB 0 9 Packers and SSSV (type and measured depth) 9 5/8" BOT paCker at 8221'; 5 1/2" SSSV at 2104z~aska (~1 & Gas Cons. Commission Anchorage 13. Attachments Description summary of proposal X Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation February/March 1989 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 certify that the foregoing is true and correct to the best of my knowledge. Signed T'r[le Senior Technical Assistant I FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test ~ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commission Form 10-403 Rev 06/15/88 Approval No.~.,. O~! Commissioner SUBMIT IN TRIPLICATE TREE: 6" ClW WELLHEAD: McEVOY ACTUATOR: OTIS 13 3/8"' 72#/ft' I L-80, BTRS 27'02' KOP: 4000' MAX ANGLE: 24° @ 5300' 5 1/2", 17#/ft, L-80, AB BTRS TUBING (IPC) TUBING ID: 4.892" CAPACITY: .0232 BBL/FT ~-,O-19 Proposed Squeeze KB. ELEV =78.65' BF. ELEV = 42.95' sssv LANDING NIPPLE ( OTIS )(4.562" GAS LIFT MANDRELS /QTI~I RD W/FA IATCN~ 'N~ MD(BKB) TVDss 12 3000' 2921' 11 4864' 4751' 10 5966' 5759' 9 6121' 5903' 8 6606' 6355' 7 6763' 6502' 6 7125' 6838' 5 7279' 6983' 4 7602' 7287' 3 7756' 7432' 2 7902' 7568' 1 8063' 7718' 5 1/2" SLIDING SLEEVE J (OTIS "XA") (4.562"1D) 8135' i TOP OF 7" LINER 8281' 9 5/8", 47#/ft, L-80, STRS I 8758'!~ PERFORATION SUMMARY REF. LOG: SWS- BHCS- 5-7-82 TIE-IN LOG: SWS - CBL 5-10-82 SIZE SPF INTERVAL OPEN/SQZ'D 2 7/8'~ 4 9240 - 9250' SQZD/4-30-88 3 1/8'~ 4 9300 - 9310' SQZD/4-30-88 2 7/8"i 4 9327 - 9353' SQZD/8-30-91 27/8'~ 4 9366- 9368' SQZD/8-30-91 3 3/8'; 4 9368 - 9388' SQZD/2/10/94 3-3/8"I 6 9366'- 9406' OPEN/2/13/94 PBTD [ 9580' J 7", 26#/ft, L-80, IJ4S 19618"1 %%% [ , , ,r,,%, ,I r,'.'.-.'.'.'] I BOT SBR 8201' J 9 5,8" PACKER I I I (BOT) (4.750"1D) 8221 4 1/2", 12.6#/ft, L-80 TAILPIPE 4 1/2" "X" NIPPLE (OTIS) (3.813" ID) 4 1/2 .... XN"NIPPLE (OTIS) (3.725" ID) 4 1/2" TBG TAIL (BOT)(SOS) (ELMD o REF BHCS 5-7-82) 8284' J 8315'] 8357'1 8348' J MARKER JOINT 9158' J Top of squeeze cemem = 9190' MD · FEB 0 9 0i1 & Gas Cons. commissio~ ~chorage FISH: LOST 4-22-86- BOWSPRING CENTRALIZER ARM, 2' L x 1/2" W x 1/8" T. FISH IS AT OR BELOW 9460' WLM. ST PROGRAM: exp [] dev [] redrll ~ serv [] / · ~ttached .................. N appropriate ............... N name and n~mber .............. N in a defined pool ............. N proper distance from drlg unit boundary. . N i proper distance from other wells ..... N ~creage available in drilling unit ..... N is wellbore plat included ........ N .y affected par~y .............. N . appropriate bond in force ......... N 3e issued without conservation order .... N ,e issued without administrative approval. . N ~e approved before 15-day wait ....... N :ring provided ................ Y N( lng protects all known USDWs ......... Y ~uate to circulate on conductor & surf csg.. Y ~uate to tie-in long string to surf csg . . . Y .,er all known productive horizons ...... ~ N ~ns adequate for C, T, B & permafrost .... ~kage or reserve pit ............ il, has a 10-403 for abndnmnt been approved. £1bore separation proposed ......... required, is it adequate .......... lid program schematic & equip list adequate .~L~ N ate ..................... ~ N rating adequate; test to ~3~ psig.~Y~ N ~ld complies w/API RP-53 (May 84) ....... ~f----N-A~-- :cur without operation shutdown.. ...... ~ N of H2S gas probable ~ N ~e issued w/o hydrogen sulfide measures .... Y ted on potential overpressure zones ..... Y lysis of shallow gas zones .......... ~/ N ition survey (if off-shore) ........ ./~ N ' ~/phone for weekly progress reports . . . /. Y N [exploratory only] ENGINEERING: COMMI SS ION: JDH ~ JDN Comments/Instructions: wellbore seg [] z 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. D- 19A E BAY ~'~' ~ ~ Alaska Oil & ,..,~., Cons. Commission Anchorage 1/ / ~ .-..,-. . .. .- _':.~.~....': J ~ ~.~-.~..¢ .-_ ..... .., :;.:,: .... .. ..... . ../ ~ ./ --.- .'-:.. ...:;: ,. -_-. --. st-. ! · ~'~" ";' ""~:" B ..... I-. '~ '" ~...--- ............................... ::Tk.t? :. ~ ;-..:'..YT~ :.: :. .... · ---, - ~- - -a; .;-~ ~' '---' ............................ 14 - March - 1996 . ....... ,. ..... i£L/CN/GR -""'".. ;..'::--" :. .... -. Tubing Conveyed ' -->; - -U ' -,'. -- :_.~_r~., 2--~: . · .... i ....... . .... r! .. WESTEI?J~i ATLAS, 8950 10390 Logging Services Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING RUN 1 6627.00 BRAD ESARY SEE REMARKS REMARKS: D - 19A 500292070701 BP EXPLORATION (ALAS~) INC. WESTERN ATLAS LOGGING SERVICES 09-APR-96 OPEN HOLE RUN 2 RUN 3 23 lin 13E 1881 1692 78.65 .00 42.95 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7.000 8947.0 3~750 10400.0 IEL/CN/GR. LOG TIED INTO CASED HOLE CNL (03-DEC-95/WALS) WHICH WAS REFERENCED TO BHCS DATED 07-MAY-82. LOGS WITNESSED BY: J. MELVAN, C. PARKER, D. BOYER. COILED TUBING CONVEYED, CAMCO UNIT 985. MAXIMUM DOG LEG 27.8 DEG/100' AT 9504' MD, ANGLE = 78.9 DEG. CHLORIDES = 40000 MG/L. CIRCULATED 1/2 BBL/MIN ON BOTTOM THEN 1/4 BBL/MIN WHILE LOGGING MAIN PASS. CIRCULATED 1/4 BBL/MIN WHILE LOGGING REPEAT PASS. IEL VERIFICATIONS NOT WITHIN WESTERN ATLAS SPECIFICATIONS. GAMMA RAY NOT WORKING AT SURFACE, AFTER LOG VERIFICATIONS NOT PERFORMED. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, BOREHOLE CORRECTION = 3.750", CHISM FILTERING OFF, CAS ING CORRE IONS OFF, SALINITY = 0.00 PPM. FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR SN 2418 $ depth shifted and clipped curves; .5000 START DEPTH STOP DEPTH 8950.0 10363.0 8950.0 10390.0 8950 . 0 10374 . 0 BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH RT 8966.5 8971.5 8971.5 8975.0 8975.0 8981.0 8981.5 8988.5 8989.0 8995.0 8995.0 8999.5 8999.0 9003.5 9003.5 9024.5 9024.0 9025.0 9024.5 9034.5 9034.0 9044.5 9043.5 9053.5 9053.0 9055.5 9055.0 9055.0 9057.5 9057.5 9069.0 9069.0 9084.0 9084.0 9090.5 9091.0 9107.5 9107.5 9109.5 9109.0 9126.5 9126.5 9130.5 9130.5 9142.5 9142.0 9156.5 9156.5 9163.5 9164.0 9165.5 9166.0 9175.0 9175.0 9178.0 9178.0 9180.5 9181.0 9185.0 9185.5 9189.0 9190.0 9198.0 9197.5 9210.5 9210.5 9212.5 9213.0 9214.5 9215.5 9243.0 9243.0 9246.5 9247.5 9253.5 9254.0 9260.5 9261.0 9261.5 9261.5 9276.5 9277.0 9277.5 all runs merged; EQUIVALENT UNSHIFTED DEPTH NPHI 8966.0 no case (79 #~c1:_LT,) G~0D,~%{ .T,~O& ~ k~H S k~llf : .TAfJ. S .~dO~IS H.T.%{ON : NIIOD i%f~ ZOHO/1Hd : N~ lf6I-(I : NM NOIL~f~O~dXZ d~ : ND JJlO' ~HD.T.1fW66 / J ao' HDg¥ a / 0'9L£0I 0'06COI 0' £9£0I .~S%f~ Z~HZN 'IHdN HLIM QZI~IHS ZHZM LDflN ~ LDQ~ 0'0S68 P 0'0S68 P 0'0~68 P dO& ZOHZM 'ON SS~fd I I I · OM N/IH S'L9IOI 0'9~L6 ~'9IL6 S'£996 S'0996 0'PI~6 S'L8~6 S'6P~6 O' ~76£6 0'9~6 ~'OE~6 0'~ ,6 ~'0tEOI ~'6~0I ~'I6IOI 0'£8IOI 0'0tIOI 0'89IOI ~'S966 0'££66 ~'~066 O'[LL6 ~'9IL6 0'LL96 ~'6996 O'LLS6 9' 66~6 0 ' 8c3~'6 S'06£6 0'99£6 S'95£6 90£6 : 8I~E NS ~'0£EOI 0'6~EOI 0'I6IOI S'£8IOI S'0£IOI 0'89IOI S'L9IOI S'S966 S'£566 0'9066 O'Ett6 O'~L6 ~'9IL6 S'gL96 ~'6996 0'~996 ~'I996 O'ALN6 ~'£I~6 S'66~6 0'8~6 0'6~6 O'ERS6 0'~6£6 0'06£6 ~'99£6 ~'9~£6 0'0E£6 0'90£6 S'£0£6 O'S6E6 Tape depth:ID: 'F 9 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR SN 68 1 GAPI 4 2 RT SN 68 1 OHMM 4 3 SN SN 68 1 OHMM 4 4 SP SN 68 1 MV 4 5 TEND SN 68 1 LB 4 6 TENS SN 68 1 LB 4 7 NPHI 2418 68 1 PU-S 4 8 FUCT 2418 68 1 CPS 4 9 NUCT 2418 68 1 CPS 4 4 23 310 01 1 4 23 995 99 1 4 23 995 99 1 4 23 995 99 1 4 23 995 99 1 4 23 995 99 1 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 36 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 117 Tape File Start Depth = 10400.000000 Tape File End Depth = 8950.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 29011 datums Tape Subfile: 2 293 records... Minimum record length: Maximum record length: 46 bytes 1006 bytes Tape Subfile 3 is type: LIS TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 2 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String %1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 1 4 .2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8910 . 0 10363 . 0 IEL 8910 . 0 10390 . 0 2418 8910 . 0 10374 . 0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): 14-MAR- 96 FSYS REV. J001 VER. 1.1 1102 10400.0 10400.0 8950.0 10390.0 1500.0 15-MAR-96 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT CORR GR KNJT CN KNJT IEL $ CABLEHEAD TENSION CORRELATION SUB GAMMA RAY DOUBLE KNUCKLE JOINT COMPENSATED NEUTRON DOUBLE KNUCKLE JOINT INDUCTION ELECTROLOG TOOL NUMBER 3977XB 3965XA 1310XA 9999ZZ 2418XA 9999ZZ 811XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT) : LOGGER'S CASING DEPTH (FT): 3.750 8947.0 8950.0 BOREHOLE CONDITIONS MLPD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3) : MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OHMM) AT TEMPERATI/RE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: FLOPRO 8.80 .0 9.5 5.0 .0 .200 .000 .130 76.0 .0 76.0 MUD FIoLTRATE A~ MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : REMARKS: MAIN PASS. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : D-19A : PRUDHOE BAY : NORTH SLOPE 00 .120 .000 THERMAL SANDSTONE .00 3.750 .0 .0 76.0 .0 * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units 1 GR IEL 68 1 GAPI 2 RT IEL 68 1 OHMM 3 SN IEL 68 1 OHMM 4 COND IEL 68 1 MMHO 5 SP IEL 68 1 MV 6 CHT IEL 68 1 LB 7 'TTEN IEL 68 1 LB 8 TEN IEL 68 1 LB 9 SPD IEL 68 1 F/MN 10 CNC 2418 68 1 PU-S 11 CN 2418 68 1 PU-L 12 LSN 2418 68 1 CPS 13 SSN 2418 68 1 CPS API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 05 310 01 1 4 4 05 120 46 1 4 4 05 995 99 1 4 4 05 110 46 1 4 4 05 010 01 1 4 4 05 635 99 1 4 4 05 635 99 1 4 4 05 635 99 1 4 4 05 636 99 1 4 4 42 995 99 1 4 4 42 890 01 1 4 4 42 334 31 1 4 4 42 334 30 1 52 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 333 Tape File Start Depth = 10400.000000 Tape File End Depth = 8904.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 83791 datums Tape Subfile: 3 409 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes 0'9/. 0' 0'9/. 0' 0'9/. 0EI ' 000 ' 0£I' 000 ' 00E' O. 0'S S'6 0' 08'8 O~dO~ 0 '0S68 0 'L968 OSL'C ZZ6666 krXSI 9E ZZ6666 k~XOI £I 1fXS96 E H.q~I~-lM 0'00SI 0'06£0I 0'0968 0'00~0I 0'00~0I 96-MRfI4-SI 9£8 I'I 'H~ I00D 'A~H SAS~ 96-H%f~-gI : (i~) Hid~G ONIS~D : (NI)~ZIS £I~ ~OH ~i~Q ~NIS~fD GASf ~OH~O~ ~O~IOH3,D.~I.q NOI,LDflCLMI J~IIO£ .~q)IDl/MM Hq~flOQ ,LNIO£ .Wq)tDflNM .~ISflOQ 5flS NO I J,k~I.~HHOD bIOI SN23. CSfMH,~IM%fD J.DN~I ND 2L£N>I H~ %IHOD .LHD .~dX.L ~IO0,L ,~OD ~IO0,1. HOGNMA (NO,LLO~ OJ, dOi) ~NIHJ, S ~IO0.L : (HHd,4) G.q.qdS ONI~DO~I : (3,,g) ~itfAH~,LbII DO~I P~O3,.LO~t : (3.4) ~RfAH.~JlqI OO~I dO.L : (m.~) H.~990~I Gm : (.L~) H.qq~IIH(/ GiL : C[.'~C[N:.~ NOIIICTQDHID Z~I.L : NOISHMA HH%fM~L.~OS : GZ~DO~I .~i~fG 0' S/.£0I 0'gE68 8IPE 0' 00P0I 0' gE68 ~I.qI 0' P9g0I 0 ' ~E68 HO H.LaMa a0,LS H.Ld.q(I .LM%fJ, S .~(IOD ~IOOi HOGRHA OOSE' £ I I A~S ZqI~ :J~NM~HDNI HI~G :~M~WflN SS~fd :HM~W/1N~NIHIS ~00~ 'saI!~ ~~das u! un~ pu~ 'Builds IOO~ 'ss~d qo~ ~o~ ~p x~p~q BoI pu~ s~AlnO S~SS%f~ i~aZH MqOH NMdO M~ £ :HZ~flM HqlM H~(Ik~H ZqIm SIT :aclK~ s! ~ ai%~qns ad~ MIID CAKE AT BH NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: REPEAT PASS. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : D-19A : PRUDHOE BAY : NORTH SLOPE THERMAL SANDSTONE .00 3.750 .0 .0 * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR IEL 68 1 GAPI 4 2 RT IEL 68 1 OHMM 4 3 SN IEL 68 1 OHMM 4 4 COND IEL 68 1 MMHO 4 5 SP IEL 68 1 MV 4 6 CHT IEL 68 1 LB 4 7 TTEN IEL 68 1 LB 4 8 TEN IEL 68 1 LB 4 9 SPD IEL 68 1 F/MN 4 10 CNC 2418 68 1 PU-S 4 11 CN 2418 68 1 PU-L 4 12 LSN 2418 68 1 CPS 4 13 SSN 2418 68 1 CPS 4 4 05 310 01 1 4 05 120 46 1 4 05 995 99 1 4 05 110 46 1 4 05 010 01 1 4 05 635 99 1 4 05 635 99 1 4 05 635 99 1 4 05 636 99 1 4 42 995 99 1 4 42 890 01 1 4 42 334 31 1 4 42 334 30 1 * DATA RECORD (TYPE# 0) 1014 BYTES * 52 Total Data Records: 329 Tape File Start Depth = 10400.000000 Tape File End Depth = 8920.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 Tape Subfile: 4 Minimum record length: Maximum record length: 111906 datums 403 records... 62 bytes 1014 bytes Tape Subfile 5 is type: LIS 96;1 4/ 9 O1 **** REEL TRAILER **** 96/ 4/10 O1 Tape subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 10 APR 96 7:36a Elapsed execution time = 3.02 seconds. SYSTEM RETURN CODE = 0