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189-034
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, May 19, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 2-22 DUCK IS UNIT MPI 2-22 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/19/2023 2-22 50-029-21931-00-00 189-034-0 W SPT 9765 1890340 2441 2235 2255 2247 2257 118 98 114 120 4YRTST P Guy Cook 4/4/2023 Testing was completed with a Thunderbird pump truck and calibrated gauges. The OOA annulus read a consistent 140 psi throughout the testing process. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:DUCK IS UNIT MPI 2-22 Inspection Date: Tubing OA Packer Depth 976 2755 2723 2714IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC230403174916 BBL Pumped:1.9 BBL Returned:1.9 Friday, May 19, 2023 Page 1 of 1 DATE 07/18/2019 Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Abby Bell Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 JENDICOTT MPI 2-22 (PTD 189-034) CD 1: Hilcorp_NIP12-22_IPRDF 20Jun14_FINAL 3 1 0 2 3 CD 2: kilcorp__MP12-22_Processed-IPRDF 20)un13 3 1 0 2 4 109034 RECEIVE® JUL 19 2019 AOGCC Please acknowledge r^eipt by sigAng and retVrniy g one copy of this transmittal or FAX to 907 777.8337 Received By/ /'///I /n / / / / T Date: PT MEMORANDUM TO: Jim Regg P.I. Supervisor 4 I FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 8, 2019 SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC 2.22 DUCK IS UNIT MPI 2-22 Sre: Inspector Reviewed By: p � P.I. Supry —MC NON -CONFIDENTIAL Comm Well Name DUCK IS UNIT MPI 2-22 API Well Number 50-029-21931-00-00 Inspector Name: Jeff Jones Permit Number: 189-034-0 Inspection Date: 4/222019-1 Insp Num: mi[JJ]90503130519 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 2-zz 'TypeInj j W'TVD 97es -Tubing zzsl i zzl9 - zzse � zzss 1890340 Type Testi SPT Test psi ff 2441 IA 848 3033 _ 2991 - 2982ped: 2.3 BBL Returned: 2.1 OA loo - loo zo lao = Interval — 4YRTST IP/F P Notes: I well inspected, no exceptions noted. Wednesday, May 8, 2019 Page I of I STATE OF ALASKA ALLCA OIL AND GAS CONSERVATION CO11 SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Lf Plug Perforations LJ Fracture Stimulate U Pull Tubing Li Operations shutdown LJ Performed: Suspend ❑ Perforate Q Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill Cl erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska LLC Development ❑ Exploratory ❑ 189-034 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic❑ Service ❑ 6.API Number: AK 99503 50-029-21931-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0034633 DUCK IS UNIT MPI 2-22 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A ENDICOTT/ENDICOTT OIL 11.Present Well Condition Summary: Total Depth measured 12,323 feet Plugs measured N/A RECEIVED true vertical 10,594 feet Junk measured 11,944'&12,029' feetJUN �t 2 Effective Depth measured 12,029 feet Packer measured 11,330 feet v 2017 true vertical 10,344 feet true vertical 9,765 fee ,P4`C Casing Length Size MD TVD Burst Collapse Conductor 110' 30" 110' 110' N/A N/A Surface 2,498' 13-3/8" 2,498' 2,489' 5,020psi 2,260psi Intermediate 9,403' 9-5/8" 9,403' 8,314' 6,870psi 4,760psi Intermediate 1,839' 9-5/8" 11,242' 9,692' 8,150psi P 5,090psi Tieback Liner 10,992' 7" 10,992' 9,491' 7,240psi 5,410P si Production Liner 1,324' 7" 12,322' 10,593' 11,220psi 8,530psi Perforation depth Measured depth See Schematic feet t4 4E® True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6/L-80/TC-II 11,408' 9,829' 1,508(MD) Packers and SSSV(type,measured and true vertical depth) Baker S-3 HXO SVLN See Above 1,508(TVD) 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 12,500 700 2,357 Subsequent to operation: 0 0 15,238 850 2,356 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory Development El Service Q Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAGIN Q GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: - Authorized Name: Bo York Contact Name: Taylor Wellmarfrra Authorized Title: Operations Manager Contact Email: twellman(cr�hllc p.com Authorized Signature: Data 6/1/2017 Contact Phone: 777-8449 Form 10-404 Revi 4/2017 /2�� RBDMS �� JUN - 5 2017 Submit Original Only ' • li • • Endicott Unit Well: 2-22 SCHEMATIC Last Completed: 3/21/2006 Ililcora Alaska,LLC PTD: 189-034 TREE&WELLHEAD WELL INCLINATION DETAIL SAFETY NOTE KB Elev.:55.5'/BF Elev.:17.14 Tree 4-1/16CIW KOP=3,400' H2S Readings Average 230-260 PPM 4 ;, t, Wellhead FMC A � � 1Max Angle is 45 deg.@ 10,171' on A/L&Gas Injectors/Well Requires A30' a SSSV when on ML. 6," "� r. w OPEN HOLE/CEMENT DETAIL .. 30" 260sx Arctis Set 1 13-3/8" 3,423 cu/ft Permafrost in a 17-1/4"Hole 3 ; eS' 9-5/8" 575 cu/ft Class"G"in a 12-1/4"Hole 13-3/8" 4 S 7" 428 cu/ft Class"G"in a 8-1/2"Hole/Tie Back Lnr CMT @ 10,987' CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 2 ` 30" Conductor N/A N/A Surface 110' N/A :` 13-3/8" Surface 68/NT-80/Butt 12.415" Surface 2,489' 0.150 9-5/8" Intermediate 47/NT8OS 8.681" Surface 9,403' 0.0732 47/NT95HS 8.681" 9,403' 11,242' 0.0732 r • ;" Tie Back 26/L-80/TC-II 6.276" Surface 10,987' 0.0383 Production 29/NT95HS/SM-110 6.184" 10,998' 12,322' 0.0371 3 TUBING DETAIL ti 0 I `' 4-1/2" Tubing 12.6/L-80/TC-II 3.958" Surf 11,408' 0.0152 , l+, JEWELRY DETAIL r ti No Depth Item 1 1,508' 4-1/2"HES HXO SVLN X-Profile(3.813"ID) 2 3,728' ST 2:Type=MMG,Latch=KGB2,Port=0,Dev.=13,TVD=3,724',VIv=DMY,3/6/2006 h' 3 6,507' ST 1:Type=MMG,Latch=KGB2,Port=0,Dev.=36,TVD=6,004',VIv=DMY,3/6/2006 d' 4 10,987' 7"TIW Ported Tie Back Liner,ID=6.30" a r 5 11,299' X-Nipple,ID-3.813" ( 6 11,330' Baker S-3 7"x 4-1/2"Packer 1 .; 7 11,364' X-Nipple,ID-3.813" - 8 11,394' XN-Nipple,ID-3.725" 9 11,407 4-1/2"Fluted WLEG-Bottom @ 11,408' 10 11,944' FISH:Interwell 350-700 HEX Choke Pkr,3-1/2"FN,ME-, 4/4/2014 _ ENDICOTT PERFORATION DETAIL Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Size 11,452' 11,482' 9,865' 9,890' 30 5/23/17 Open 2-7/8" t. i 4 11,530' 11,553' 9,930' 9,949' 33 7/4/2002 Open 2" 9-5/8" 5 11,593' 11,643' 9,982' 9,988' 50 7/4/2002 Open 2" II11,643' 11,680' 10,023' 10,054' 37 7/4/2002 Open 2" k 6 11,758' 11,778' 10,118' 10,135' 20 4/19/1989 Open 5" 11,783' 11,790' 10,139' 10,145' 7 4/19/1989 Open 5" 11,801' 11,805' 10,154' 10,157' 4 4/19/1989 Open 5" 7 4' 11,809' 11,828' 10,160' 10,176' 9 4/19/1989 Open 5" II: i 11,836' 11,905' 10,183' 10,240' 69 4/19/1989 Open 5" 1r11,908' 11,929' 10,243' 10,260' 21 4/19/1989 Open 5" 8 tt % 11,933' 11,986' 10,264' 10,308 53 4/19/1989 Open 5" k; 9 11,991' 11,994' 10,312' 10,315' 3 4/19/1989 Open 5" 1 12,000' 12,016' 10,320' 10,333' 16 4/19/1989 Open 5" NOTE:Angle @ Top Perforation=34°@ 11,530'/Ref:SLB MD Log on 3/29/2009 GENERAL WELL INFO Endicott Sa ids API:50-029-21931-00-00 e`; Drilled,Cased&Completed by Doyon 15 -4/19/1989 Fish Pushed to lA I 21 3 RWO- 12,029-3/16/2006 / /2006 w 10 Set Hex Choke-7/19/2013 may► 11° Move Hex Choke-4/4/2014 1 yy t' Perf Add-5/23/2017 7 +k'At At=i . TD=12,323(MD)/TD=10,594'(TVD) PBTD=12,029'(MD)/PBTD=10,344'(TVD) Revised By:TDF 6/1/2017 • • 441 Hilcorp Alaska, LLC 1v Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 2-22 Slickline 50-029-21931-00-00 189-034 4/17/17 5/26/17 Daily Operations: 4/12/2017 -Wednesday No activity to report. 4/13/2017 -Thursday No activity to report. 4/14/2017 - Friday No activity to report. 4/15/2017-Saturday No activity to report. 4/16/2017-Sunday No activity to report. 4/17/2017- Monday **WELL S/I ON ARRIVAL, NOTIFY PAD-OP, PT PCE 250L/3,500H**. WORK THROUGH TIGHT SPOT FROM SURFACE TO 22' SLM, DRIFT&TAG 4-1/2" MCX VLV W/3.80" GAUGE RING @ 1,490' SLM/,1508' MD. PULL 4-1/2" MCV VLV @ 1,492' SLM / 1,508' MD. DRIFT TBG FOR SBHPS W/2.50" CENT, 3' x 1-1/2" STEM, 1.75" SAMPLE BAILER &S/D @ 11,700' SLM, RECOVER SAMPLE OF SCHMOO. 4/18/2017-Tuesday **WELL S/I ON ARRIVAL, NOTIFY PAD-OP, PT PCE 250L/3,500H**. COMPLETE SBHPS PER PROCEDURE. DRIFTED 3.25" BARBELL ASSEM.TO 11,538' MD (PERF TARGET= 11,481') (OAL= 19.5"), DIDN'T TAG TD. SET 4-1/2" MCX @ 1,490' SLM (1,508' MD). ***PERFORMED SUCCESSFUL DRAWDOWN TEST, WELL LEFT SHUT IN ON DEPARTURE, DSO NOTIFIED***. ***RETURNED WELL TO OPS FOR INJECTION - NOTIFIED PAD OP OF DEPATURE*** • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 2-22 Slickline 50-029-21931-00-00 189-034 4/17/17 5/26/17 Daily Operations: 5/10/2017 -Wednesday ***WELL ON INJECTION UPON ARRIVAL*** (pull sssv/drift). PT PCE 250#-LOW/2,300#-HIGH. PULLED INTACT 4-1/2" MCX SSSV (ser#M-40B) FROM X-NIP AT 1,508' MD. DRIFT TBG W/21' x 2-7/8" DMY GUNS TO 11,900' SLM (no obstructions) (targe btm perf depth = 11,481'). ***WELL LEFT SHUT-IN ON DEPARTURE, DSO NOTIFIED***. 5/11/2017 -Thursday No activity to report. 5/12/2017 - Friday No activity to report. 5/13/2017 -Saturday No activity to report. 5/14/2017 -Sunday No activity to report. 5/15/2017 - Monday No activity to report. 5/16/2017 -Tuesday No activity to report. • . ` � Hilcorp Alaska, LLC tk-LLWeekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 2-22 Slickline 50-029-21931-00-00 189-034 4/17/17 5/26/17 Daily Operations: 5/17/2017 -Wednesday No activity to report. 5/18/2017 -Thursday No activity to report. 5/19/2017 - Friday No activity to report. 5/20/2017 -Saturday No activity to report. 5/21/2017 -Sunday No activity to report. 5/22/2017 - Monday No activity to report. 5/23/2017 -Tuesday PT 250 LOW/2600 HIGH. RUN IN W/30' x 2-7/8" RAZOR DP GUNS & PERFORATE INTERVAL @ 11452'- 11482'. SLICKLINE TO COME IN TO SET SSSV AT LATER DATE. WELL LEFT SHUT IN - NOTIFIED PAD OP OF WELL STATUS. • Hilcorp Alaska, LLC � Ma q Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 2-22 Slickline 50-029-21931-00-00 189-034 4/17/17 5/26/17 Daily Operations: 5/24/2017 -Wednesday No activity to report. 5/25/2017 -Thursday No activity to report. 5/26/2017 Friday WELL S/I ON ARRIVAL, (SET 4.5" Al-VALVE, SER# HABS-0468/2.00" CHOKE), PT 250/2,200. 5/27/2017 -Saturday No activity to report. 5/28/2017 -Sunday No activity to report. 5/29/2017 - Monday No activity to report. 5/30/2017-Tuesday No activity to report. • • of , gwP���i%/y� THE STATE Alaska Oil and Gas .4? 'VA n Conservation Commission 174%.0114 .... 111%.17.0.•,....70,411 UfALA S KA. .yam_ '•f t Pt__-- - 333 West Seventh Avenue �,.> GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 �' Main: 907.279.1433 OF ALAS,' Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager Hilcorp Alaska, LLCsaws) AP ! �l t., 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Endicott Field, Endicott Oil Pool, DIU MPI 2-22 Permit to Drill Number: 189-034 Sundry Number: 317-147 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this/ day of April, 2017. RBDMS Lt_ 171 7 2017 • • RECEIVED STATE OF ALASKA APR 0 7 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION Q - 41/3//7 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑✓ ' Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change-out ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑ 189-034 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service 0 6.API Number: Anchorage Alaska 99503 50-029-21931-00-00 ' 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 462 Fa.J7 Will planned perforations require a spacing exception? Yes ❑ No ❑✓ /45?.. t0.`7 DUCK IS UNIT MPI 2-22 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0034633' I ENDICOTT/ENDICOTT OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): , Plugs(MD): Junk(MD): 12,323' ' 10,594' 12,029' 10,344' 1,100 N/A 11,944'&12,029' Casing Length Size MD TVD Burst Collapse Structural 110' 30" 110' 110' N/A NH/A Surface 2,498' 13-3/8" 2,498' 2,489' 5,020psi 2,260psi Intermediate 9,403' 9-5/8" 9,403' 8,314' 6,870psi 4,760psi Intermediate 1,839' 9-5/8" 11,242' 9,692' 8,150psi 5,090psi Tieback Liner 10,992' 7" 10,992' 9,491' 7,240psi 5,410psi Production Liner 1,324' 7" 12,322' 10,593' 11,220psi 8530 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 4-1/2" 12.6/L-80/TC-II 11,408 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker S-3 and HES HXO SVLN 11,330 MD/9,765 TVD and 1,508 MD/1,508 ZTVD 12.Attachments: Proposal Summary Q Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service ❑✓ 14.Estimated Date for 15.Well Status after proposed work: — 4/21/2017 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAGIN Q ° GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York Contact Name: Taylor Wellman i r A Authorized Title: Operations Manager Contact Email: twellmanCa hilcorp.com v� Contact Phone: 777-8449 Authorized Signature: fes, -4 '� i � Date: 4/7/2017 TTTT"'' COMMISSION USE ONLY Conditions of appro . Notify Commission so that a representative may witness Sundry Number: 3 11- 047 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ NoRDDIVIS t t_ , ---) 1 7 2017 Spacing Exception Required? Yes ❑ No Subsequent Form Required: /0 Ve.,9`f /p APPROVED BY Approved by:07 ✓ 91244.,(4,....., COMMISSIONER THE COMMISSION Date: q_.../3 _ 0 Submit Form 10-403 Revised 4/2017 RiGa it' lid for 2 months from the date of approval. n Duplicate AForm and Attachments 4.(!(., ri./0. • • Perf FV Well: END 2-22 PTD: 189-034 Hilcorp Alaska, API:50-029-21931-00 Well Name: END 2-22 API Number: 50-029-22125-02 Current Status: On Injection Rig: SL/EL Estimated Start Date: April 21, 2017 Estimated Duration: 3 days Reg.Approval Req'std? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 189-034 First Call Engineer: Taylor Wellman (907)777-8449 (0) (907)947-9533 (M) Second Call Engineer: Wyatt Rivard (907) 777-8547 (0) (509) 670-8001 (M) AFE: WeIIEZ Entry Required: Yes Maximum Expected BHP: 1150psi @ 10,000' TVD(Based on 2-20 SBHPS on 05/21/14) Max.Anticipated Surface Pressure: 1100psi (Based on last SI pressure) Last SI WHP: 1100psi Well SI and taken on 04/05/14 Min ID: 3.725"4-1/2"XN Nipple @ 11,407' and Brief Well Summary: END 2-22 is a water injector located on MPI. The well currently injects into the FI, FIII, FIV and K3A sands. The END 2-26 well is located in proximity to this well and is currently lacking support in the FV sand. The aim is to change the distribution of injection support and not to just increase injection capacity. Objective:Add perforations to the following zones as prescribed in the table below. . Gun Run# Perf Top Perf Bottom Perf Length Formation 1 +/-11,451' +/-11,481' 30' FV Total 30' - Table 1: END 2-22 Proposed Perf Gun Runs Note: Final depths to be confirmed in "Final Approved Perf Sheet" Non Sundried Operations Slickline 1. MIRU SL unit. 2. Pressure test to 300psi low and at least 2,000psi high. 3. RIH & pull 4-1/2" MCX SSSV from 1508' and (set on 04/05/14). 4. Drift well w/20'x2-7/8" dummy gun and tag. a. Target depth to reach is 11,520' md. b. Last tag was on 04/04/14 at 11,944'slmd. i. SL was attempting to pull a HEX plug choke and could not make it into the tubing tail. It was pushed to bottom.See 04/04/14 WSR for full details. 5. RDMO SL unit. Sundried Operations(Approved Sundry required prior to proceeding) E-Line 6. RU EL unit and pressure test to 250psi low 2,000psi high. 7. MU perforating tool string with 30'of 2-1/2"—3-1/8", 6spf,guns. 8. RIH and correlate gun run to Tie-In Log. Contact OE Taylor Wellman or OE Wyatt Rivard (contact info above) prior to perforating for final approval of tie in. 9. Perforate as per Table 1: END 2-22 Proposed Perf Gun Runs. POOH. a. Correlation Log: HES Dual Latero Log dated 12-Apr-1989 • • Perf FV Well: END 2-22 PTD: 189-034 Ililcoro Alaska,Lb API: 50-029-21931-00 b. Note any tubing pressure change in WSR. 10. RD Eline. Slickline 11. RU SL unit and pressure test to 250psi low/2,000psi. 12. RIH and set 4-1/2" MCX SSSV at 1508' md. a. Description of last SSSV set on 04/05/14: 4-1/2" MCX (ser# M-40B w/ r lock,1.25" bean & sec lock down). See WSR for full details. 13. RD SL unit. • H . • Endicott Unit Well: 2-22 SCHEMATIC Last Completed: 3/21/2006 Hileorp Alaska,LLC PTD: 189-034 TREE&WELLHEAD KB Elev.:55.5'/BF Elev.:17.14 Tree 4-1/16CIW J C Wellhead FMC 30 I* OPEN HOLE/CEMENT DETAIL 30" 260sx Arctis Set °y 13-3/8" 3,423 cu/ft Permafrost in a 17-1/4"Hole 0, 17, 7, 9-5/8" 575 cu/ft Class"G"in a 12-1/4"Hole 1 r a, 7" 428 cu/ft Class"G"in a 8-1/2"Hole/Tie Back Lnr CMT @ 10,987' ° t$ I: r h. i, it Y 0 CASING DETAIL 13-3/8"4 ;, Size Type Wt/Grade/Conn ID Top Btm BPF F 30" Conductor N/A N/A Surface 110' N/A 2 b' 13-3/8" Surface _ 68/NT-80/Butt 12.415" Surface 2,489' 0.150 r . 47/NT8OS 8.681" Surface 9,403' 0.0732 144 1 9-5/8" Intermediate 47/NT95HS 8.681" 9,403' 11,242' 0.0732 7„ Tie Back 26/L-80/TC-II 6.276" Surface 10,987 0.0383 0- Production 29/NT95HS/SM-110 6.184" 10,998' 12,322' 0.0371 '` TUBING DETAIL ‘t.,. ' 4-1/2" Tubing 12.6/L-80/TC II 3.958" Surf11,408' 0.0152 ' 3 WELL INCLINATION DETAIL KOP=3,400' f Max Angle is 45 deg.@ 10,171' JEWELRY DETAIL sv r; No Depth Item r. 1 1,508' 4-1/2"HES HXO SVLN X-Profile(3.813"ID) 2 3,728' ST 2:Type=MMG,Latch=KGB2,Port=0,Dev.=13,TVD=3,724',VIv=DMY,3/6/2006 3 6,507' ST 1:Type=MMG,Latch=KGB2,Port=0,Dev.=36,TVD=6,004',VIv=DMY,3/6/2006 4 10,987' 7"TIW Ported Tie Back Liner,ID=6.30" 5 11,299' X-Nipple,ID-3.813" 6 11,330' Baker S-3 7"x 4-1/2"Packer 7 11,364' X-Nipple,ID-3.813" 00 t 8 11,394' XN-Nipple,ID-3.725" P. �` 9 11,407' 4-1/2"Fluted WLEG-Bottom @ 11,408' 8 10 11,944' FISH:Interwell 350-700 HEX Choke Pkr,3-1/2"FN,ME-, 4/4/2014 1„ ,+ k ENDICOTT PERFORATION DETAIL 4 Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Size 9-5/8"a _ 5 11,530' 11,553' 9,930' 9,949' 33 7/4/2002 Open 2" f- 11,593' 11,643' 9,982' 9,988' 50 7/4/2002 Open 2" 11,643' 11,680' 10,023' 10,054' 37 7/4/2002 Open 2" '' 6 11,758' 11,778' 10,118' 10,135' 20 4/19/1989 Open 5" Nttk V 11,783' 11,790' 10,139' 10,145' 7 4/19/1989 Open 5" R 7 °At, 11,801' 11,805' 10,154' 10,157 4 4/19/1989 Open 5" 11,809' 11,828' 10,160' 10,176' 9 4/19/1989 Open 5" 1 8 ' 11,836' 11,905' 10,183' 10,240' 69 4/19/1989 Open 5" t. 11,908' 11,929' 10,243' 10,260' 21 4/19/1989 Open 5" #i, g p; 11,933' _ 11,986' 10,264' 10,308 53 4/19/1989 Open 5" %t .,,, 11,991' 11,994' 10,312' 10,315' 3 4/19/1989 Open 5" ' OE 12,000' 12,016' 10,320' 10,333' 16 4/19/1989 Open 5" tItt . NOTE:Angle @ Top Perforation=34°@ 11,530'/Ref:SLB MD Log on 3/29/2009 toV. SAFETY NOTE Endicott sands / H2S Readings Average 230-260 PPM Fish Pushed to 11on A/L 84 Gas Injectors/Well Requires 12,029-3/16/2006 ty a SSSV when on ML. °••••,,,," 10 '�� 1t® x' GENERAL WELL INFO �, 7';* ,rkar1 API:50-029-21931-00-00 Drilled,Cased&Completed by Doyon 15 -4/19/1989 TD=12,323(MD)/TD=10,594'(TVD) RWO 3/21/2006 PBTD=12,029'(MD)/PBTD=10,344'(TVD) --- Set Hex Choke-7/19/2013 Move Hex Choke-4/4/2014 Reviseded By:TDF 3/29/2017 n 0 Endicott Unit Well: 2-22 SCHEMATIC PROPOSEDIII Last Last Completed: Hileorp Alaska,LLC PTD: 189-034 KB Elev.:55.5'/BF Elev.:17.14 SAFETY NOTE t. ii. _, $, y TREE&WELLHEAD H2S Readings Average 230-260 PPM 4 ti Tree 4-1/16CIW on A/L&Gas Injectors/Well Requires 30"Ni 0 p 4 to Wellhead FMC a SSSV when on ML. 1 4 OPEN HOLE/CEMENT DETAIL el 1 7 30" 260sx Arctis Set iiI193_-3/8" 3,423 cu/ftPermafrost in a 17-1/4"Hole 3/g 5/8" 575 cu/ft Class"G"in a 12-1/4"Hole 14 V 7" 428 cu/ft Class"G"in a 8-1/2"Hole/Tie Back Lnr CMT @ 10,987' CASING DETAIL 2, Size Type Wt/Grade/Conn ID Top Btm BPF 30" Conductor N/A N/A Surface 110' N/A 13-3/8" Surface 68/NT-80/Butt 12.415" Surface 2,489' 0.150 9-5/8" Intermediate 47/NT805 8.681" Surface 9,403' 0.0732 a 47/NT95HS 8.681" 9,403' 11,242' 0.0732 7„ lie Back 264/7 6/L-80/TC-II 6.276" Surface 10,987' 0.0383 Production 29/NT95HS/SM-110 6.184" 10,998' 12,322' 0.0371 3 TUBING DETAIL 4-1/2" Tubing 12.6/L-80/TC-II 3.958" Surf 11,408' 0.0152 WELL INCLINATION DETAIL KOP=3,400' Max Angle is 45 deg.@ 10,171' JEWELRY DETAIL o No Depth Item 1 1,508' 4-1/2"HES HXO SVLN X-Profile(3.813"ID) li 2 3,728' ST 2:Type=MMG,Latch=KGB2,Port=0,Dev.=13,TVD=3,724',VIv=DMY,3/6/2006 3 6,507' ST 1:Type=MMG,Latch=KGB2,Port=0,Dev.=36,TVD=6,004',VIv=DMY,3/6/2006 4 10,987' 7"TIW Ported Tie Back Liner,ID=6.30" 5 11,299' X-Nipple,ID-3.813" 6 11,330' Baker S-3 7"x 4-1/2"Packer ; 7 11,364' X-Nipple,ID-3.813" 8 11,394' XN-Nipple,ID-3.725" 9 11,407' 4-1/2"Fluted WLEG-Bottom @ 11,408' 10 11,944' FISH:Interwell 350-700 HEX Choke Pkr,3-1/2"FN,ME-, 4/4/2014 4 ENDICOTT PERFORATION DETAIL 9-5/8" :15 6 iji Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Size g 11,451' 11,481' + 9,865' 9,890' 30 Future Future ✓' 11,530' 11,553' 9,930' 9,949' 33 7/4/2002 Open 2" 11,593' 11,643' 9,982' 9,988' 50 7/4/2002 Open 2" 7 , 11,643' 11,680' 10,023' 10,054' 37 7/4/2002 Open 2" " 11,758' 11,778' 10,118' 10,135' 20 4/19/1989 Open 5" r8 11,783' 11,790' 10,139' 10,145' 7 4/19/1989 Open 5" lie 11,801' 11,805' 10,154' 10,157' 4 4/19/1989 Open 5" 9 11,809' 11,828' 10,160' 10,176' 9 4/19/1989 Open 5" 11,836' 11,905' 10,183' 10,240' 69 4/19/1989 Open 5" 11,908' 11,929' 10,243' 10,260' 21 4/19/1989 Open 5" 11,933' 11,986' 10,264' 10,308 53 4/19/1989 Open 5" Endicott Sands 11,991' 11,994' 10,312' 10,315' 3 4/19/1989 Open 5" 12,000' 12,016' 10,320' 10,333' 16 4/19/1989 Open 5" Fish Pushed to NOTE:Angle @ Top Perforation=34°@ 11,530'/Ref:SLB MD Log on 3/29/2009 12,020-3/102006 10 seGENERAL WELL INFO to 7'F' a API:50-029-21931-00-00 TD 12,323(MD)/TD=10,594'(TVD) Drilled,Cased&Completed by Doyon 15 -4/19/1989 PBTD=12,029'(MD)/PBTD=10,344'(TVD) RWO-3/21/2006 Set Hex Choke-7/19/2013 Move Hex Choke-4/4/2014 Reviseded By:TDF 3/29/2017 • • Post Office Box 244027 Anchorage,AK 99524-4027 Hilcorp Alaska,LLC ,JUL 3 0 2015 3800 Centerpoint Drive Suite 100 AOGCAnchorage,AK 99503 [`*+� Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 Commissioner Cathy Foerster _ O�� Alaska Oil & Gas Conservation Commission CJ g 333 West 7th Avenue, Suite 100 `a_ 9- a.., Anchorage, AK 99501 Re: Duck Island Unit Well Renaming Request 'CANNEL (. 410 n 9016 Dear Commissioner Foerster, Hilcorp Alaska, LLC (HAK) requests a change to the naming convention of Duck Island Unit wells to remove the unused suffixes at the end of each well name. Well names currently include a forward slash "I" followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/L21" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD# 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/T34" (PTD # 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp Orig New API_WeIINo PermitNumber WellName WellNumber WeIlNumber 50029218010000 1880370 DUCK IS UNIT MPI 1-01/J19 1-01 50029226010000 1951500 DUCK IS UNIT MPI 1-03/P16 1-03 50029216050000 1861060 DUCK IS UNIT MPI 1-05/020 1-05 50029217430000 1870810 DUCK IS UNIT MPI 1-09/J18 1-09 50029217430100 1970290 DUCK IS UNIT MPI 1-09A/L21 1-09A 50029221070000 1901570 DUCK IS UNIT MPI 1-11/SN4 1-11 50029223610000 1930560 DUCK IS UNIT MPI 1-15/P25 1-15 50029221000000 1901500 DUCK IS UNIT MPI 1-17/SN2 1-17 50029221000100 1961990 DUCK IS UNIT MPI 1-17A/117 1-17A 50029225690000 1950930 DUCK IS UNIT MPI 1-19/118 1-19 50029220050000 1900020 DUCK IS UNIT MPI 1-21/K25 1-21 50029225100000 1941280 DUCK IS UNIT MPI 1-23/015 1-23 50029217220000 1870420 DUCK IS UNIT MPI 1-25/N22 1-25 50029217220100 1970750 DUCK IS UNIT MPI 1-25A/K22 1-25A 50029216930000 1870090 DUCK IS UNIT MPI 1-27/P20 1-27 50029216690000 1861810 DUCK IS UNIT MPI 1-29/M25 1-29 50029225620000 1950720 DUCK IS UNIT MPI 1-31/M21 1-31 50029225770000 1951070 DUCK IS UNIT MPI 1-33/M23 1-33 50029225770100 1980870 DUCK IS UNIT MPI 1-33A/L24 1-33A 50029225770200 1982550 DUCK IS UNIT MPI 1-33B/L24 1-33B 50029225770300 2050040 DUCK IS UNIT MPI 1-33C/M24XX 1-33CXX 50029216720000 1861840 DUCK IS UNIT MPI 1-35/025 1-35 50029217480000 1870900 DUCK IS UNIT MPI 1-37/P24 1-37 50029218270000 1880630 DUCK IS UNIT MPI 1-39/P17 1-39 50029218270100 2061870 DUCK IS UNIT MPI 1-39A/N-16 1-39A 50029217130000 1870320 DUCK IS UNIT MPI 1-41/023 1-41 50029218640000 1881050 DUCK IS UNIT MPI 1-43/P26 1-43 50029219910000 1891240 DUCK IS UNIT MPI 1-45/Q26 1-45 50029216250000 1861310 DUCK IS UNIT MPI 1-47/Q21 1-47 50029216250100 1972030 DUCK IS UNIT MPI 1-47A/M20 1-47A 50029218410000 1880780 DUCK IS UNIT MPI 1-49/P21 1-49 50029223040000 1921190 DUCK IS UNIT MPI 1-51/V20 1-51 50029225010000 1941120 DUCK IS UNIT MPI 1-53/Q20 1-53 50029217880000 1880210 DUCK IS UNIT MPI 1-55/R25 1-55 50029218730000 1881140 DUCK IS UNIT MPI 1-57/R23 1-57 50029226440000 1960220 DUCK IS UNIT MPI 1-59/024 1-59 50029225200000 1941420 DUCK IS UNIT MPI 1-61/Q20 1-61 50029219050000 1890060 DUCK IS UNIT MPI 1-63/T22 1-63 50029226270000 1951880 DUCK IS UNIT MPI 1-65/N25 1-65 50029226270100 2032120 DUCK IS UNIT MPI 1-65A/N27 1-65A 50029219850000 1891140 DUCK IS UNIT MPI 1-67/T20 1-67 50029220200000 1900290 DUCK IS UNIT MPI 1-69/V19 1-69 50029215680000 1860630 DUCK IS UNIT MPI 2-02/P18 2-02 50029215850000 1860820 DUCK IS UNIT MPI 2-04/M19 2-04 50029216990000 1870180 DUCK IS UNIT MPI 2-06/J22 2-06 50029217710000 1880040 DUCK IS UNIT MPI 2-08/K16 2-08 50029223020000 1921170 DUCK IS UNIT MPI 2-12/Q16 2-12 50029216390000 1861490 DUCK IS UNIT MPI 2-14/016 2-14 50029218850000 1881340 DUCK IS UNIT MPI 2-16/M16 2-16 50029220320000 1900430 DUCK IS UNIT MPI 2-18/L16 2-18 50029220480000 1900600 DUCK IS UNIT MPI 2-20/L15 2-20 50029219310000 1890340 DUCK IS UNIT MPI 2-22/114 2-22 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �� S DATE: Thursday,May 07,2015 P.I.Supervisor 1// SI SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC 2-22/L14 FROM: Johnnie Hill DUCK IS UNIT MPI 2-22/L14 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv NON-CONFIDENTIAL Comm Well Name DUCK IS UNIT MPI 2-22/L14 API Well Number 50-029-21931-00-00 Inspector Name: Johnnie Hill Permit Number: 189-034-0 Inspection Date: 4/28/2015 Insp Num: mttJWH150505111241 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2-22/L14 Type Inj ®TVD 9765 Tubing 2400 2400 " 2400- 2400- , 2400. PTD 1890340 Type Test SPT Test psi 2441 - IA 1198 ' 3040 2995 " 2986 - 2986 ' Interval 4YRTST _ IP/F I P `' OA 100 - 100 ' 100 100 100 Notes: %AHMED MAY 2 2 2015 Thursday,May 07,2015 Page 1 of 1 Irr["' ~e Project Well History File Cove,~ Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Organizing RESCAN Color items: [] Grayscale items: Poor Quality Originals: Other: [] [] NOTES: DIGITAL DATA [] Diskettes, No. [] Other, No/Type BY: BEVERLY ROBIN VINCENT SHERYL~'~WINDY OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [;r/ Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL (~NINDY Scanning Preparation BY: BEVERLY ROBIN VINCENT SHERY~WINDY Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: K-'~'-~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ YES BY: ~ SHERYL WINDY DATE ://-/~'~S! BEVER O~!~.N~INC ENT MARIA Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ~ YES (SCANNING I$ COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) I I I I NO NO RESCANNEDB?': BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: ISI Quality Checked 12110102Rev3NOTScanned.wpd UNSCANNED, OVERSIZED MATERIALS AVAILABLE: 1 ~~ 63~ FILE # ,~ To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission ; 333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 Voice (907) 279-1433 Fax (907) 276-7542 w,,y OF%%i�s9 THE STATE Alaska Oil and Gas ��'" �� ° 1 lS� Conservation flt _ = _ Illitw� GOVERNOR SEAN PARNELL 333 West Seventh Avenue .°iALY'AS" p. Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Josiah Igwe saws) 110'j 1 3 20)3 Engineering Team Leader BP Exploration (Alaska), Inc. 3� P.O. Box 196612 l ! Anchorage, AK 99519-6612 Re: Endicott Field, Endicott Oil Pool, EPA 2-22/L-14 Sundry Number: 313-524 Dear Mr. Igwe: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P �.-- Cathy aç erst Vicray Chair, Commissioner DATED this of October, 2013. Encl. 1 6, STATE OF ALASKA 10 wrl - ', ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS t 20 AAC 25.280 """'' (`"f 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program Suspend❑ Plug Perforations❑ Perforate Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ 189-034-0 • 3.Address: Stratigraphic ❑ Service 6.API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-21931-00-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 462 EPA 2-22/L-14 , Will planned perforations require a spacing exception? Yes ❑ No 0 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0034633 • ENDICOTT, ENDICOTT OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 12322 • 10593 • 12029 10344 None 12029 Casing Length Size MD TVD Burst Collapse Structural Conductor None None None None Surface 2461 13-3/8"68#NT-80 37-2498 37-2497.99 5020 2260 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#L-80 L-80 36-11424 Packers and SSSV Type: 4-1/2"Baker S-3 Hydro Set Packer Packers and SSSV MD(ft)and ND(ft): 11346 9722.44 4-1/2"HES MCX SSSV 1508',1507.99' 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development ❑ Service el • 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG S • Abandoned ❑ Commission Representative: GSTOR ❑ BPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Josiah Igwe Email Josiah.Igwe @BP.Com Printed Name Josiah Igwe Title Petroleum Engineer Signature Phone 564-4753 Date Prepared by Garry Catron 564-4424 A.—.,--" \O •3-to VS COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: S V2)—" S 24( Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No © Subsequent Form Required: / 0 " 4 0 4 APPROVED BY Approved by: % COMMISSIONER THE COMMISSION Date: 16 _/` Form 10-403 Revised 10/2012 A Cp p apt i tarps alp f}r 12 months from the date of approval. Su i Form and Attachments in Duplis t vt F /o/! /)3 V I V 1 I V H L RBDMS OCT 16 2 `v ..01 � '.�.` Casing Summary ADL0034633 Casing Length Size - MD Top MD Base ND Top TVD Base Burst Collapse Grade LINER 23 2-7/8"6.16# L-80 11700 11723 10070 10089 13450 13890 L-80 LINER 1324 7"29# NT95HS 10998 12322 9495 10593 9690 7820 NT-95HS PRODUCTION 9367 9-5/8"47#NT8OS 36 9403 36 8314 6870 4760 NT8OS PRODUCTION 1839 9-5/8"47#NT95HS 9403 11242 8314 9692 8150 5080 NT95HS SURFACE 2461 13-3/8"68# NT-80 37 2498 37 2498 5020 2260 NT-80 TUBING 11388 4-1/2" 12.6#L-80 36 11424 36 9842 8430 7500 L-80 • • • Perforation Attachment ADL0034633 Well Date Perf Code MD Top MD Base TVD Top TVD Base 2-22/L-14 7/4/02 APF 11530 11553 9930 9949 2-22/L-14 7/4/02 APF 11593 11600 9982 9988 2-22/L-14 7/4/02 APF 11600 11601 9988 9989 2-22/L-14 7/4/02 APF 11601 11643 9989 10023 2-22/L-14 7/4/02 APF 11663 11680 10040 10054 2-22/L-14 4/17/89 PER 11758 11778 10118 10135 2-22/L-14 4/17/89 PER 11783 11790 10139 10145 2-22/L-14 4/17/89 PER 11801 11805 10154 10157 2-22/L-14 4/17/89 PER 11809 11828 10160 10176 2-22/L-14 4/17/89 PER 11836 11905 10183 10240 2-22/L-14 4/17/89 PER 11908 11929 10243 10260 2-22/L-14 4/17/89 PER 11933 11986 10264 10308 2-22/L-14 4/17/89 PER 11991 11994 10312 10315 2-22/L-14 4/17/89 PER 12000 12016 10320 10333 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF End2-22 AFE# AENINJEC bp boy;= Memorandum To: J. Middendorf/R.Liddlow: WireLine TL Date: Sept. 23, 2013 L. Seymour/T. Norene Well Ops Team Leaders From: Josiah lgwe PE AFE: AENINJEC Est. Cost: $200,000 Subject End2-22:Reperf/ Down Hole Choke/IPROF: IOR: 100 Summary: 1 S Pull 4.5" MCX SSSV, Pull and Re-dress HEX choke / Drift and Tag TD with dummy gun. 2 E Reperf / Run and set 3.50" Re-dressed HEX Choke with 1/2" orifice at 11830' and 3 S Run IPROF and Set 4.5" MCX SSSV at 1508' MD. Well data: 2-22/L-14 well data Current Status: PWI online Last Well Injection: 09/22/2013 Injection volume 5112bpd, WHIP 2215 psi Max Deviation: 45 degrees @ 10,171'MD Minimum ID: 3.725" @ 11,394' 4-1/2" HES XN Nipple Last Downhole Op: 07/29/13 Slick Line ran memory (PROF Last Drift & TD Tag: 05/17/13 S-Line tagged TD at 11,972' slm SBHP/T: 01/26/2006: 4189 psi / 176 deg F Latest H2S Value: not measured on water injectors Endicott is an elevated risk area. Please ensure that SOP: Wellwork at Elevated 1 Risk Areas is followed. 1 End2-22 • • AFE# AENINJEC Objective r Re-perforate Fi, Fii, Fiv, and S3A4 zones and re-install HEX choke deep down hole to get a ✓ better flooding to the USZ producers, 2-20, 2-18, and 2-26. Background Information: 2-22 is a Niakuk injector which is open to both the S3A zones and the Upper Subzones injecting 10,000 bpd. Almost all the water is going into the S3A. It probably supports 1-17A, 2-08 and 2-18 in the S3A. And probably would support 2-20, 2,16 and 2-26 (and maybe a bit 2-18) in the USZ. Injector 2-22/L-14 was a 3A/Fi MI WAG injector until it developed tubing by inner annulus communication in 2001 preventing it from being placed back on MI injection. A rig workover in 2006 rectified the tubing leak. Since then the well has been injecting at 10 mbpd of water. IPROF ran in 2003 indicate that 80% of the fluid is been injected into the LSZ. HEX choke was set at 11725' to isolate the lower sub zone and IPROF 2 weeks after showed injection rate reduced to 4500 bwpd with 76% flooding into the lower zone. 1. Slickline 1. SI Well. 2. MIRU Slick Line. 3. RIH and pull 4 1/2" MCX SSSV from 1508' MD. 4. Retrieve HEX choke from 11,725' and 5. D&T TD with dummy gun and TEL. 6. RDMO 2. E-Line procedure: 1. MIRU E-Line. • Ensure to have lnterwell Engineer onsite to redress the previously pulled HEX choke. 2. MU tool string with Perforating Gun/GR/CCL 3. RIH w/BHA, SLB 30' gun 3106 PowerJet Nova HMX, 6 SPF 60 deg phasing. o Note Max. diameter of gun in liquid/gas after shot is 3.57"/. ( Make sure there is enough fluid at the shooting depth) 4. Log up hole to correlate depths. 5. Perforate interval (11,785' — 11,755'), POOH 2 End2-22 • • AFE# AENINJEC 6. At surface MU and RIH SLB 20' Gun, 3106 PJ Nova HMX, 6 SPF 60 deg phasing. 7. Log up hole and perforate the interval (11,685' — 11,665'), POOH • 8. At surface MU and RIH SLB 25' Gun, 3106 PJ Nova HMX, 6 SPF 60 deg phasing. 9. Log up hole and perforate the interval (11,530 — 11,555' ), POOH 10.At surface, MU tool string with 3.5" Interwell HEX choke, for 7" casing(23 — 32 #/ft, HEX350-700 model) with 1/2" orifice and Omega Hydrostatic Setting Tool/GR/CCL. 11.Check connection between Omega Hydrostatic Setting Tool and CCL or other connections to wireline running string. Apply voltage from logging unit through cable, cable head (tractor) and CCL. Record voltage from power panel when 12VDC is reached below CCL. 12. Perform a shortcut test in steps 20V/ 50V/ 100V and 150V below CCL and record the current (amp. on the power panel) at each step. 13.Connect the omega motor to the CCL and test that the motor is running and record the current (amp. on the power panel) before running in hole. 14.Make up adapter kit to the HEX Bridge Choke and Omega Hydrostatic Setting Tool. Ensure that all the connections are secured with lock rings or set screws. Do not lift the setting tool and choke from horizontal to vertical with setting sleeve made up against the HEX choke. • Remove clamps on element 15.Make up connections from setting tool to CCL/GR. 16.Install assembly in Lubricator and commence pressure test. 17.RIH with tool string; care to be taken when passing restrictions and profiles such as sub- sea safety valve, gas lift mandrels and nipples. Do not at any point exceed 114 ft/min (35 meter/minute). 18.After reaching setting depth power up to activate setting tool. Two "kicks" on the weight indicator may be observed during the setting. One will be the shear pins and the other the shear stud. Watch the current (amp) while sending power down to setting tool. The current should be between 20 and 100 mAmp. 19.Correlate setting depth using CCL and reach setting depth in upward direction. Set 3.50" OD HEX plug mid-element at 11,830' MD, placing the slips at 11,831.5' MD. • Tie in to SLB Cement Bond Log dated 17 APR-1989 20.Observe weight loss on weight indicator. 21.Run back in hole and lay down weight to assure the plug is set. 22.Pull out of hole. 3 End2-22 • • AFE# AENINJEC 23.RDMO E- Line. Put well on injection for 3 weeks before proceeding with the (PROF. 3.Slick Line. IPROF: 1. MIRU Slick Line unit. 2. MU Memory (PROF tool string including FB spinner/inline spinner/pressure/temp/GR/CCL. 3. RIH and make a down pass with the well injecting at a constant rate as close to the well's normal injection rate after the DH choke install. 4. Make spinner up and down passes at 40, 80, and 120 FPM from 11,500' MD to TD • Tie in to SLB Cement Bond Log dated 17 APR-1989 5. Perform stop counts at the following depths: • 11500' MD • 11570' MD • 11650' MD • 11720' MD • 11783' MD • TD 6. POOH and check for good data. 7. Reset 4.5" MCX SSSV at 1508' and and return well to injection. 8. RDMO IPROF Log Presentation: 1. Job comments: • Operating steps in sequence • Rate control valve setting, percent opening, and injection rate • Wellhead injection pressure and temperature • Logging passes executed • Field data interpretation 2. In a header for each pass, include a summary of the injection conditions 4 End 7-)7 • • AFE# AENINJEC PERFORATING PROCEDURE HOW VIUSn MMIMS&wits Well: End2-22 API#: Date: 09/23/2013 Prod Engr:Josiah lgwe Office Ph: 564-4753 H2S Level: Home Ph: 590-0610 Cont Fax: n/a CC or AFE: AENINJEC WBL Entries IOR Type Work Desciption 100 S Drift to TD with Dummy gun 100 E REPERFS(75')/Set HEX Choke Well Objectives and Perforating Notes: ADPERFS 11530-11555, 11685-11665 and 11785-11755'MD Attachment: Reference log with proposed peril annotated,5"/100'scale. Reference Log Tie in Log - feet Log: DLUML CBL tie-in log to be on Date: 4/12/1989 4/17/19:' depth with the reference log. Company: ' SLB Depths(from-to) Depths(from-to) Feet SPF Orient. Phasing Zone Ad/Re/Iperf 11,530' - 11,555' 11,530' 11,555' ra;Odom 60° Fiv Reperf 11,665' - 11,685' 11,665' - 11,685' r random 60° Fii Reperf 11,755' - 11,785' 11,755' - 11,785' 30' random 60° Fi Reperf Requested Gun Size: 3-1/8" Charge: 3106 PJ Nova Syystem Is Drawdown Necessary/Desired/Unnecessary During Perforating Unnecessary Preferred Amount of Drawdown/Suggestions to Achieve Drawdown N/A Last Tag: 9,303 ft MD on 7/16/2009 Est Res. Pres.@ 8800' MD is 3,200 psi Perforation Summary Summary Dist Well: End2-22 Town: Date: API#: 50-029-21931-00 Prod Engr: Anch Prod Engr P.D. Center PBTD General Comments: Depths Balance Referenced to BHCS Gun Dia. Orient. SPF Phasing Zone Adperf/Reperf 0/B/U 3-1/8" random 6° 60° Fiv Reperf 0/B/U 3-1/8" random 6° 60° Fii Reperf 0/B/U 0/B/U 0/B/U 0/B/U 0/B/U 0/B/U 0/B/U 6 End2-22 • • AFE# AENINJEC 11500 x i 1 Illitti ,.. ,,,....i h . • 1 J I oil _ - C.. _.1—..t I ... ______ SLB CBL, Dated 17-Apr-1989 , ; ii 1 • 11530'-11555' ({ • __ + 'e II tI4' 1. j i I .___.f st 1 f{ t h..-"- r: * + C - t is .. ti� 1 j a it #� ' 1 11600 t+ '1 ' i } . 5 a-4 I i , i - i , v „ ; _ . _ _ , ____ • . . ,. . , ,_ . ..,,,,, .. i .i i . %. 9 ti, E 1`¢ I ■ . N ' ' 4 1.-...1),i,11 r a . e t Itlif ''' a. I SLB CBL, Dated 17-Apr-1989 icill,z4 11685'-11665' i 1 1f .4 • � C , 1 t x . i I t • 1700 , I f ,; '. ,Ar I ' • ' . ft, b, -.4 7 r End2-22 • S AFE# AENINJEC i x . .. . t liF * li,. ; . ..„.. , ; a, ,,,,., l 1 ,, {, 1. ; . < . 1(I ,t . , . . 7.----t, 1. if t-,:.41. 1 I ate ; r 1 t S i 7!):, r J SLB CBL, Dated 17-Apr-1989 J _. 11755'—11785' p {x i 1 J0 i Y1 ♦ f A,. -1 K ,. •. r ,� J �_..._._... _..._...._...� _.. . �. .y-.3 IMF lb,mi.11807 { `. = f sil- f i t-t: , 1 1 i i - 01, -..._. r., _ . . :. , . f y.e.;....,_ i e . 1) e. .. ;i Set HEX Choke @ 11830' ' t';' -.-1 t*- . . . 1 f i -_ i 1 ' 7L--- t .• . .04 r t FT, .!:.}, I .', I ' 8 • End2-22 • • AFE# AENINJEC HEX350.7CU Bring++Plug rn ,yam 5 ileh a 115inrn 45,43inch MIN gin 1228 to 1909mrn HF)C1F{i-?Ilf.+iirciti iI Fi:4 N Ek 75.16inch ll 0416,611m 'il 1 t '— A63ench _I. r I • 0n ,... II. O?.819 iris 2325mm =ilia& L • I , ,s i in I r 9 II • ' End2-22 • AFE# AENINJEC 'ME 4-1: 6'CYr SAFETY NOTES:1425 READINGS AVERAGE 23.11-299 t i111 I-E.0 FLT.: END2-22 PPM O.4.aJL&;AS!WC-PUS.WEL 1.REQU+{RE3 a ......., �,....__.� ,..�.. v7=-„Y WHEN CPN MO. Tl ITOR � KB FiEV 55.5 % *+ '4 01fU,Fd' 17.'4 s '� * 1569' 141eIC'55g1,D-7.019' 1l,ucl'r,l- 4S=P '0171'. *} a •DetunNU- .15! #+ + EMMIRIIIMEMIN a* 44 • 13-3A--5«EiP.g I-5.1 RTFf. --f 2468' �4 • 17=17.415' s ;a Ell 1728 5.721 M 113 lN' KC;i7 rim: 1hVCii sa • d!-I) Ii!3;I4 L4',ki 'W IKG32 C)dit31.0 CSC. + -5.'3' 47i.N X1;3 RC N 9:1-i 3403' � J 4 *4 4 *4 • Minimum ID=3.725”@ 11394' 4* 4-112'HES XN NIPPLE +4 4' !e w. 44 • #4• : R ±4 4 117'LNR.2011,,LdC,7C-1 .C' 8 WI'.ID-6.2T6'I low A. • ICYUFr LltH ...10998' --"e.... °.' 1CI 6r 7'Th7 P c N T F 7 T F-u l c t 4 AF5FR1r r 61 I.WI!'t:.-Ei,Sr'.4.NI jM1I.ti U-!LEVI" H 11.. r, fEFORATCP.SLR:AlAnY f 11234' 1-14-1:71-Fr:Ff :t x.1'.17-3.81 rI MT LOG FM L..ON 141-2;88 0V:,L=111-701.'1-Gf:24 0 11S:.4.1 - - I 11930' H'':<1-12 DKR0-9F1CR,1O 8.959' I kid.Rea•.a f1UJud'xi CB f:i I'elo.i.d1 adlf dr..H ITl2E Pm IPTFF7vP1. 13p0.x Oh IS - f 11354'J(4-1:2,FE5X1I'.D-3.6131 2 Li .16',0-'1.s69 CI 07.D44.< 2 8 '156'3-'16.)2 0 67C4I7.2 7 6 `1;1 4 3-'.1 6 5 6 0 (7 r4•'7% 11364' 4.1:,I-ES I i NF L.-:i.2w'l • 4 ''Intl•"Ir,II 0 LX'1Ai°e 5 4 '179'3--173C 0 &-9199 11406' I-14-1.:- I-c4.I1=:4..T;IT I ri .1 `ix:i-`'VAS t] 1'L•!MN a 4 '14::!3-".1,211 U LK''RIPE I 5 .1 '1d16-"93E 0 C{''9'99: i S 4 11075-..¢7S I� ca„SA!: ■■ 4 11J!3-1''L6ii U C4'•LL' I 5 4 1193'-1-991 0 C4:' Ce19 I • 4 1.10:6-1:016 0 64'3.uls. I I i', T F i r 17 F.# I r,1,1-IL �--{ 11408' 111i�31I] 1 I * 7?? F3h-c rt51»T067TAI]9+1$rc6; I. • GIB 12029' _ 12 11. -ITO'o'Fl I ;PM'73N rx... .7T1 1}*i0 w1 tt 4}•*4414414 I Lii 71C,Lir.Ll`,1, !J 3.1 SFr.13=E;.18 12322' MATE FaF'J RY ' CC6'k1iy 14TF Fi1•u HY COMA- IS EMJY.:S-7 L.NR 05429,119 JLI4 INTI LL COMPLETION •III:.1i^ DI:WILT AUJE I Ls ynl-i V %L:E 'W'1L 2-22;_-11 03:2?;041 G19 RI CI 11.4.41 Mt 1.!NLU=1: 1`.` .7...07 .II H WO PP.'i7'<,477 PP"-Z=S AP Au 5I-329-2'U1-39 1 k.'I1&UY ,ties F.cu ruN- 5.7.026T-24.11.16=,1916'51,11..8,7774''An NM a7 Wire'L 'ClLc o rT CUF J B O 1S :1::17,11 uR,'..IA1 ,JS rim ss.iv SkFFI v hail- 9P etplaratIOn(Alaska") 10 • • bp BP Exploration (Alaska) Inc. 0 Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 KMINED May 22, 2012 Mr. Jim Regg g9 — °3 y Alaska Oil and Gas Conservation Commission Y v 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of Endicott Row 2 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from Endicott Row 2 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Endicott Row 2 Date: 03/28/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal END2 -02 / P -18 1860630 50029215680000 15.0 3.0 0.5 8/28/2010 1.70 9/29/2010 END2 -04 / M -19 1860820 50029215850000 4.0 1.0 0.5 8/28/2010 1.70 9/29/2010 END2 -06 / J -22 1870180 50029216990000 2.0 1.0 0.5 8/28/2010 1.70 9/29/2010 END2 -08 / K -16 1880040 50029217710000 1.5 0.1 0.5 9/2/2010 3.40 9/29/2010 END2 -12 / 0-16 1921170 50029223020000 0.5 1.0 0.0 9/2/2010 NA 3/28/2012 END2 -14 / 0 -16 1861490 50029216390000 2.5 3.0 0.5 9/2/2010 1.70 9/28/2010 END2 -16 / M -16 1881340 50029218850000 2.0 0.5 0.5 9/2/2010 1.70 9/28/2010 END2 -18 / L -16 1900430 50029220320000 2.0 0.3 0.5 9/2/2010 2.60 9/28/2010 END2 -20 / L -15 1900600 50029220480000 5.0 3.0 0.5 8/28/2010 3.40 9/28/2010 7 END2 -22 / L -14 1890340 50029219310000 5.0 5.0 0.5 8/28/2010 6.80 9/28/2010 END2 -24 / M -12 1931730 50029224180000 0.5 NA 0.5 NA 1.70 9/28/2010 END2 -26 / N -14 1880550 50029218150000 2.0 1.8 0.5 9/2/2010 1.70 9/28/2010 END2 -28B / 0 -19 2030060 50029218470200 0.5 NA 0.5 NA 1.70 9/28/2010 END2 -30B / ME -01 2081870 50029222280200 3.0 3.0 0.5 8/28/2010 2.60 9/28/2010 END2 -32 / SN -03 1901190 50029220840000 3.0 2.0 0.5 8/28/2010 2.60 9/28/2010 END2 -34 / P -14 1861720 50029216620000 1.0 NA 1.0 NA 12.80 9/25/2010 END2 -36 / 0 -14 1900240 50029220140000 5.0 3.0 0.5 8/28/2010 2.55 9/25/2010 END2 -38 / SN -01 1901290 50029220900000 3.0 4.0 0.5 8/28/2010 1.70 9/25/2010 END2 -40 / S -22 1941520 50029225270000 15.0 13.0 0.5 9/2/2010 4.00 9/25/2010 END2 -42 / P -13 1881450 50029218920000 5.0 4.0 0.5 8/28/2010 2.55 9/25/2010 END2 -44A / 0-11 1970710 50029217670100 0.5 NA 0.5 NA 22.10 10/5/2010 END2 -468 / S -13 1971370 50029219210200 4.0 1.0 0.5 9/2/2010 3.40 9/25/2010 END2 -48 / 0 -13 1951660 50029226120000 2.0 2.0 0.5 8/28/2010 1.70 9/25/2010 END2 -50 / U -08 1930670 50029223670000 2.0 1.0 0.5 8/28/2010 1.70 9/25/2010 END2 -52 / S -14 1870920 50029217500000 1.0 0.3 0.5 9/2/2010 0.85 9/25/2010 END2 -54 / Q -12 1911220 50029222180000 4.0 3.0 0.5 8/28/2010 1.70 9/25/2010 END2 -56A / E101 1980580 50029228630100 0.5 NA 0.5 NA 25.50 9/25/2010 END2 -58 / S -09 1900520 50029220410000 7.0 5.0 0.5 8/28/2010 3.40 9/25/2010 END2 -62 / Q -17 1861580 50029216480000 10.0 7.0 0.5 8/28/2010 8.50 9/25/2010 END2 -64 / U -10 1900770 50029220550000 2.0 1.0 0.5 8/28/2010 2.55 9/25/2010 END2 -66 / SD -12 1930790 50029223740000 0.3 NA 0.3 NA 1.70 9/24/2010 END2 -68 / S -17 1880970 50029218580000 2.0 3.0 0.5 8/28/2010 1.70 9/24/2010 END2 -70 / U -15 1881530 50029218990000 0.7 NA 0.7 NA 3.40 9/24/2010 MEMORANDUM • State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Monday, May 09, 2011 TO: Jim Regg P.I. Supervisor ' � '- (-111 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 2- 22/L14 FROM: Lou Grimaldi DUCK IS UNIT MPI 2- 22/L14 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv„: -- 4 _-- NON - CONFIDENTIAL Comm Well Name: DUCK IS UNIT MPI2- 22/L14 API Well Number: 50- 029 - 21931 -00 -00 Inspector Name: Lou Grimaldi Insp Num: mitLGl10507112301 Permit Number: 189 -034 -0 Inspection Date: 5/7/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 7 2- 22 /i14' Type Inj. 1 w ' TVD T Well 9765 _1 IA 400 2770 - I 2730 I 2720 - 1 P.T.D 18903401 TypeTest SPT Test psi 2750 ' OA ' 65 65 65 65 Interval 4YRTST p/F P Tubing 185o 1 1850 1 1850 1845 1 Notes: 000A cemented to surf w/ 120psi on it. 2.6 Bbl's Meoh pumped. Good test. , 1I\ ' 1 4 5. - 0 t Ps, Monday, May 09, 2011 Page 1 of 1 MEMORANDUM To: Jim Regg r'7 P.I. Supervisor ~~'`l~ ~~Z, ~~ FROM: Lou Grimaldi Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Monday, December 29, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC Z-22/Ll4 DUCK IS UNIT MPI 2-22/L14 Src: Inspector Well Name: DUCK IS UNIT MPI 2-22/L14 Insp Num: mi[LG081220135056 Rel Insp Num: NON-CONFIDENTIAL API Well Number: so-o29-2 t 93 t -oo-oo Permit Number: 1 s9-034-0 Reviewed By: P.I. Suprv J~ Kr'-- Comm Inspector Name: Lou Grimaldi Inspection Date: 12/zo/2oos Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ..Well ~ z-zzn.la ;Type InJ• ~ w ~ TVD _ 9~es ~! IA ao _ s9eo %, s9so 39so :' - _ _. _ P.T. 1890340 .'I'YPOTCSt 1 SPT 'l'est pSl ..3990 ~ OA 140 160 . .. _ __ . _ _ _ 160 160 .Interval 4YRTST _ _ ._ _. _ __ _ P/F P Tubing'. zsoo zszs zszs zszs _ __ _ NOtes: 3.9 bbl's pumped. Good test. _ _ . _ _ '~~~' ti~i'v .~ ~ VDU Monday, December 29, 2008 Page I of I MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor .--; I 'K,t/¡I'c; 5 i9{/ù0 ) V¡ l DA TE: Wednesday, May 17,2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 2·22/Ll4 DUCK IS UNIT MPI 2·22/L14 \ ttC~./ 0 'b'-\'....~ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: 'Y"?- P.I. Suprv"-..,t::F'- Comm NON-CONFIDENTIAL Well Name: DUCK IS UNIT MPI 2-22/L14 API Well Number 50-029·21931-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060513200730 Permit Number: 189-034-0 Inspection Date: 5/13/2006 ReI Insp N urn Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. i 2·22/L14 IType Inj. i W : TVD I I . - ! i I I m~ Well I 9773 I IA 2220 2750 2740 2740 i I , I 1890340 !TypeTest I SPT ! Test psi I ì I ! - P.T. 2443.25 I OA 80 80 I 80 80 I I I I Interval WRKOVR P/F P Tubing: 2080 2080 I 2080 2080 i Notes After the 3D-minute pressure test the IA was bled down to 550 psi and observed for 1 + hour with no pressure increase noted. This verifies tubing x IA integrity. SCANNED JUN "f 3200G Wednesday, May 17, 2006 Page 1 of 1 Re: 01-08A (#2051950), 17-13A (#2050200),12-19 (#1821980), N... e e 4' I reviewed the MITs and compared to test reports from Commission Inspector Chuck Scheve. I see where he was concerned about high IA pressure - he required pressure to be bled off and monitored for at least 1 hr in each ofthe following wells: END 1-23/020 (PTD 1941280) and END 2-22/L14 .-:;::¡ ((PTD 18903~Y our reports do not acknowledge the additional evaluation of the IA pressure. Question - what is the reason for high pre-test IA pressure in these 2 wells? ~ Inspector's reports indicated there was no pressure build up during the monitoring timeframe; it may be premature to conclude there is no pressure communication. We will probably want to recheck pressures periodically during the next month to verify there is no communication. Jim Regg AOGCC ,.. NSU, ADW Well Integrity Engineer wrote: Jim, Winton, and Bob, Please see the attached MIT forms for 01-18A (#2051950), 17-13A (#2050200), 12-19 (#1821980), NGI-07 (#1760380), Endicott 1-05/0-20 (1861060), 1-23/0-15 (#1941280), and 2-22/L-14 (#1890340) MITs. The AOGCC representative witnessed the majority of the tests. 01-08A Post initial injection - Witnessed by Chuck Scheve 17-13A UIC Compliance - Witnessed by Chuck Scheve 12-19 CMIT-TxIA AA 4C.000 Compliance - not witnessed NGI-07 MIT-T for Sundry #303-132 - not witnessed NGI-07 MIT-OA for Sundry #303-132 - not witnessed Endicott 1-05/0-20 UIC Compliance - Witnessed by Chuck Scheve Endicott 1-23/0-15 MITIA post initial injection - Witnessed by Chuck Scheve Endicott 2-22/L-14 UIC Compliance - Witnessed by Chuck Scheve «MIT PBU 01-08A 05-15-06.xls» «MIT PBU 17-13A 05-15-06.xls» «MIT PBU 12-19 05-12-06.xls» «MIT PBU NGI-07 05-11-06.xls» «MIT PBU NGI-07 05-12-06.xls» «MIT END 1-05, 1-23,2-22 05-13-06.xls» Please let me know if you have any questions or if there are any errors in the forms. Thank you, }Inna (j)u6e 10f2 5/17/20061:35 PM Re: 01-08A (#2051950), 17-13A (#2050200),12-19 (#1821980), N... e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 e 20f2 5/17/20061:35 PM ~ ,~,.,' \"" ~.- ~ STATE OF ALASKA 0 r/3)ac:) , ALASK4 þIL AND GAS CONSERVATION MISSION t .J REPORT OF SUNDRY WELL OPERATI.QNS?~ 1. Operations Performed: Run r tieback liner o Abandon o Suspend o Operation Shutdown o Perforate II Other o Alter Casing 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program 181 Pull Tubing o Perforate New Pool o Waiver o Time Extension 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. o Development 0 Exploratory 189-034 13. Address: o Stratigraphic 181 Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21931-00-00 7. KB Elevation (ft): 55.5 9. Well Name and Number: END 2-22/L-14 8. Property Designation: 10. Field / Pool(s): ADL 034633 Endicott Field / Endicott Pool 11. Present well condition summary Total depth: measured 12322 feet true vertical 10593 feet Plugs (measured) None Effective depth: measured 12236 feet Junk (measured) None true vertical 10520 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 30" 110' 110' Surface 2498' 13-3/8" 2498' 2498' 5020 2270 Intermediate 9403' 9-5/8" 9403' 8314' 6870 4760 Production 1839' 9-5/8" 9403' - 11242' 8314' - 9692' 8150 5080 Liner 1324' 7" 10998' - 12322' 9495' - 10593' 11220 8510 Tieback Liner 1 0969' 7" 22' - 10992' 22' - 9491' 7240 5410 , 'C ~\\\\\'E,r; r'·~ Xlj' ì ..... 2 f\ fil') '. {f,..¡" Perforation Depth MD (ft): ~.~'". ,., '. '> ',~, ,~J'" "~.. ~ 11530' - 12016' Perforation Depth TVD (ft): 9930' - 10333' 4-1/2' 12.6# L-80 11407' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): r x 4-1/2" Baker S-3 Packer 11330' 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS BFL MAYO 4 2006 Treatment description including volumes used and final pressure: 13. Representative Daily Averaç¡e Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casinç¡ Pressure Tubina Pressure Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: 181 Daily Report of Well Operations o Exploratory o Development 181 Service 181 Well Schematic Diagram 16. Well Status after proposed work: o Oil o Gas 181 WAG oGINJ oWINJ o WDSPL 17. f hereby certify that the foregoing IS true ana correct to the t est of my knowledge. I Sundry Number or N/A if C.O. Exempt Contact John McMullen, 564-4711 306-033 Printed Name Sondra Stewman Title Technical Assistant ~~ ~. )t:ý _ _ ('Ii Prepared By Name/Number: Signa re .~ ~rr:. --"""''if \)~:::u'Yì",", Phone 564-4750 Date o - () 7 - ' ,&ondra Stewman, 564-4750 . . Form 10-404 Revised 04/2004 Submit anginal Only Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-22/L-14 2-22/L-14 REENTER+COMPLETE DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 3/5/2006 3/19/2006 Spud Date: 3/25/1989 End: 3/19/2006 1 3/412006 119:30 - 20:00 0.50 MOB P PRE RID MIa Secure Well. 120:00 - 20:30 0.50 MOB P PRE Remove Stack Secure on Pedistal. i 20:30 - 21 :00 0.50 MOB P PRE Rig Up Booster Wheels. '121 :00 - 22:00 1.00 MOB P PRE Move Rig to UD Derrick. [22:00 - 22:30 0.50 MOB P PRE Remove Derrick pins UD Derrick. 22:30 - 00:00 1.50 MOB P PRE Begin Mobization to Endicott Well 2-221 L-14. 3/5/2006 100:00 - 11 :00 11.00 MOB P PRE Moving Rig From Drill Site 9-41 to Endicott Island Well 2-22 I L-14. Stage Rig on Island for ATP Meeting. 11 :00 - 14:00 3.00 MOB P PRE ATP Meeting with END and Rig Crews. 14:00 - 15:00 1.00 MOB P PRE PJSM, Raise Derrick. 15:00 - 16:00 1.00 MOB P PRE Remove Rear Boosters. 16:00 - 17:00 1.00 MOB P PRE Install BOP Stack on Pedestal. 17:00 - 17:30 0.50 MOB P PRE Rig Up Floor and Ready Rig to Move over Well. 17:30 - 19:00 1.50 MOB P PRE Wait on Ice Pad in front of well to set up. 19:00 - 20:30 1.50 MOB P PRE Layout Herculite and Rig Mats. 20:30 - 22:30 2.00 MOB P PRE Spot Rig Over Well END-2-22. 22:30 - 00:00 1.50 MOB P PRE Close up Cellar and Spot Slop Tank. Rig was Ready to work at Midnight, had 3 hours of Safety Meeting and 3 hours waiting on Ice for Pad. Accept Rig at 1800 hours. 3/6/2006 00:00 - 01 :00 1.00 RIGU P PRE Install Secondary Annulus Valve. Spot Cuttings Tank, Take on Sea Water. 01 :00 - 02:00 1.00 RIGU P PRE Rigging Up to and Pulling BPV. 02:00 - 02:30 0.50 WHSUR P WHDTRE PJSM. Pressure Test Lines to 2,500 psi. 02:30 - 03:00 0.50 CLEAN P DECOMP Circulate Out Freeze Protection From Tubing. At 7 BPM with 1500 psi 03:00 - 05:30 2.50 CLEAN P DECOMP Circulate Out 4.5" x 9 5/8" Annulus. Pumped Hi-Vis, Safe Clean Sweep 40 bbls at 8 bpm with 1470 psi. 05:30 - 06:30 1.00 WHSUR P DECOMP Rig up, Set Two Way Check and Test to 1000 psi. 06:30 - 09:30 3.00 WHSUR P DECOMP PJSM. Nipple Down Tree. Bleed Down Control line to bleed tank. Terminate and Plug Control Lines. 09:30 - 10:00 0.50 WHSUR P DECOMP Safety Meeting in Dog House. Topic Stepping It Up to the Next Level. No More Accidents, Incidents or Spills. Discuss working together in pairs and working as a team, look out for your buddy. Stopping the Job. Secondary Containment, Spill Containment is mandatory. 10:00 - 15:00 5.00 BOPSU P DECOMP PJSM. N 1 U BOPE 15:00 - 18:30 3.50 BOPSU P DECOMP Attempt to Test BOPE. 5 min tests. 250 psi Low 13500 psi High for Annular. 250 psi Low /4000 psi High for Pipe Rams, Blind Rams, HCR Choke 1 Kill, Manual Choke 1 Kill, Upper and Lower IBOP, Floor Valves. Witness to BOPE Test Waived by Jeff Jones with AOGCC. Were able to complete three test. Fluid Leaking by Tubing Hanger. 18:30 - 19:00 0.50 BOPSU P DECOMP Rig Down Back Out Test Equipment. Rig Up Power Tongs, Rig Up xo Assembly to Pull Hanger To Rig Floor. 19:00 - 19:30 0.50 BOPSU P DECOMP RlU DSM Pull Two Way Check. 19:30 - 20:00 0.50 BOPSU P DECOMP RID DSM. 20:00 - 21 :30 1.50 WHSUR P DECOMP Back out Lock Down Screws, Pull Hanger to Rig Floor Maximum Pulled 170,000# Sroke Over, 150,000# Up Weight. 21 :30 - 22:30 1.00 PULL P DECOMP Ciculate Hole 180 spm with 1340 psi. 22:30 - 23:30 1.00 PULL P DECOMP Back Out and Lay Down Running Tool, and Hanger. RlU 4"Tubing Elevators. 23:30 - 00:00 0.50 PULL P DECOMP Lay Down Two Joints of 4.5" Tubing. 31712006 00:00 - 01 :00 1.00 BOPSU P DECOMP MI U Test Plug and XO to TDS Tubing Landed Test Plug Ran Printed: 3/20/2006 12:09:46 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-22/L-14 2-22/L-14 REENTER+COMPLETE DOYON DRILLING INC. DOYON 16 Start: 3/5/2006 Rig Release: 3/19/2006 Rig Number: Spud Date: 3/25/1989 End: 3/19/2006 10:00 - 11 :00 1.00 FISH 11 :00 - 15:30 4.50 FISH 15:30 - 17:00 1.50 FISH 17:00 - 17:30 0.50 FISH DECOMP '¡In Lock Down Screws. DECOMP II R I U BOP Test Equipment. DECOMP ,Tested BOPE. 250 psi Low 13500 psi High for Annular. 250 I psi Low I 4000 psi High for Pipe Rams, Blind Rams, HCR Choke / Kill, Manual Choke I Kill, Upper and Lower IBOP, Floor Valves. All Tests Held fl5 Minutes wI No Leaks or Pressure Loss. Witness to BOPE Test Waived by AOGCC Rep Jeff Jones. DECOMP Blew Down and Rigged Down All BOP Test Equipment. DECOMP P / U Landing Joint and Retrieved Test Plug. LID Landing Joint and Test Plug. DECOMP R I U Floor to LID 4.5" Tubing. R I U Camco Spooling Unit. DECOMP POOH wI 4.5" Tubing, Spooled Up Control Lines. 21 Rubber Clamps, 3 Steel Bands and 1 SSSV Recovered. DECOMP RID Camco Spooling Unit, Cleared and Cleaned Rig Floor. DECOMP POOH wI 4.5" Tubing. LID Total of 271 Joints 4.5" Tubing, 6 GLM Assy, 1 Sliding Sleeve Assy, 16' Cut Joint. DECOMP Cleared and Cleaned Rig Floor. DECOMP Ran and Set Wear Bushing. DECOMP Loaded and Tallied 21 Joints of HWDP, R I U 4" DP Handling Equipment. DECOMP M I U BHA #1: 8-3/8" Oversized Guide w/ Hollow Mill, OS Bowl wI 4-1/2" Grapple, Bushing, OS Bowl w/ 4-1/2" Grapple, OS Ext, Top Sub, Pump Out Sub, Lub Bumper Sub, Oil Jar, XO, 9 x 6-1/4" DCs, XO, Accelerator Jar, XO, 21 Jts HWDP. Total BHA Length = 970.23'. DECOMP Serviced Rig. DECOMP RIH wI BHA on 4" DP. PI U DP 1 x 1 from Pipe Shed. DECOMP RIH wI BHA on 4" DP to 10,880'. PI U DP 1 x 1 from Pipe Shed. DECOMP M I U Top Drive, Engaged Pump, 5.0 bpm, 590 psi. String Weight Up 202,000#, String Weight Down 178,000#, Rotary String Weight 193,000#, 60 rpm Torque 5,500 ftIlbs, wI 0 Pumps, String Weight Up 202,000#, String Weight Down 180,000#, Washed Down to 10,890', Pump Rate 5.0 bpm, 600 psi, Tagged Top of Stub at 10,890'. Dressed Off Top of Tubing Stub 60 rpm, Torque 5,500 ft Ilbs, Overshot Fell Over Tubing Stub, Swallowed Tubing Stub to 10,900', Pump Pressure Increased to 1,200 psi, Shut Down Pump and Bled Off Pressure, Stacked 15,000# On Stub. P I U w/ 15,000# Overpull, Bled Off Jars to Ensure Grapples were Engaged. S I o to Neutral Weight, PI U wI 10,000# Overpull, Rotated 17 Tums to Right. With 10 Turns into the String, Torque Increased to 10,000 ft Ilbs, Continued to Rotate, With 15 Turns into the String Torque Dropped to 3,500 ft Ilbs, Lost 10,000# of Overpull. PI U 20' Drill String Free. Engaged Pump, 5 bpm, 600 psi. DECOMP Pumped and Circulated Around 20 bbl Hi-Vis Sweep, 15.5 bpm, 3,995 psi. DECOMP POOH wI 4" DP. DECOMP POOH wI BHA, HWDP and DC's. B I 0 and LID 0 I S BHA and Fish. Recovered, Cut Joint, Pup Joint, SBR and K Anchor. DECOMP Clear and Clean Rig Floor. 05:00 - 05:30 0.50 PULL P 05:30 - 06:00 0.50 PULL P 06:00 - 06:30 0.50 PULL P 06:30 - 08:00 1.50 PULL P 08:00 - 08:30 0.50 PULL P 08:30 - 16:00 7.50 PULL P 16:00 - 17:00 1.00 PULL P 17:00 - 17:30 0.50 PULL P 17:30 - 18:00 0.50 PULL P 18:00 - 21 :30 3.50 FISH P 21 :30 - 22:00 0.50 FISH P 22:00 - 00:00 2.00 FISH P 3/8/2006 00:00 - 09:30 9.50 FISH 09:30 - 10:00 0.50 FISH Printed: 3/20/2006 12:09:46 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-22/L-14 2-22/L -14 REENTER+COMPLETE DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 3/5/2006 3/19/2006 Spud Date: 3/25/1989 End: 3/19/2006 3/812006 17:30 - 19:00 1.50 FISH DECOMP M I U Packer Milling BHA: 8-1/2" Packer Mill, 3 x Boot Baskets, Bit Sub, Bumper Sub, Oil Jar, XO, 9 x 6-1/4" Drill Collars, XO, Accelerator Jars, XO, 21 Jts HWDP. BHA Total Length = 974.96'. 19:00 - 22:00 3.00 FISH DECOMP RIH wI Packer Milling BHA on 4" DP to 10,900'. - 22:30 0.50 FISH DECOMP M I U Top Drive, Engaged Pump, String Weight Up 208,000#, String Weight Down 195,000#, Rotating String Weight 195,000#,70 rpm Torque 6,000 ftllbs. SPR #1 at 30 SPM, 250 psi, SPR #2 at 30 SPM, 400 psi. 22:30 - 00:00 1.50 FISH DECOMP Milled Packer From 10,930 to 10,931'. WOM 6,000#, 70 rpiTI, Torque on Bottom 10,000 ft Ilbs, Pump Rate 4 bpm, 1,080 psi. 3/9/2006 00:00 - 03:00 3.00 FISH P DECOMP Milled Packer From 10,931 to 10,935'. WOM 10,000#,70 rpm, Torque on Bottom 10,000 ft Ilbs, Pump Rate 4 bpm, 750 psi. 03:00 - 03:30 0.50 FISH P DECOMP Circulated Bottoms up,1 08 spm, 10 bpm, at 4,020 psi. 03:30 - 04:30 1.00 FISH P DECOMP At 550 bbls Pumped, Driller Observed 8% Gain in Flow and 4 bbl Pit Gain. Driller Shut Down Pumps and Closed Annular Preventer. DPP 0 psi, CP 40 psi. Notified Endicott Control Room, North Slope AOGCC and BP Drilling Superintendent Mike Miller. 04:30 - 05:30 1.00 FISH P DECOMP Held PJSM, Brought Pump on Line and Opened Choke, Pump Rate 30 spm, 240 psi. CP Dropped to 0 psi. Increased Pump Rate to 50 spm, 750 psi, Circulated 200 bbls, Shut Down Pump, and Observed Well Through Choke and Gas Buster, No Flow from Wellbore. Opened Annular Preventer, Wellbore Fluid 10' Below Flowline, Observed Well, Well Static. 05:30 - 06:30 1.00 FISH P DECOMP Circulated Bottoms Up, 11 bpm, 4,000 psi. No Gas on Bottoms Up. 06:30 - 07:00 0.50 FISH P DECOMP RIH and Chased, Pushed 9-5/8" x 4-1/2" Packer to 10,984'. Stacked 20,000# on Packer to Engage Grapple on PRT. P I U 20' Observed 5,000# Overpull. 07:00 - 10:00 3.00 FISH P DECOMP Pumped and Circulated Around 40 bbl Hi-Vis Sweep, 11 bpm, 4,020 psi. Circulated Extra 1 hour to Allow Endicott Ops Access to Well house Under Geronimo Line. Shut Down Pumps, Observed Well, Well Static. B I 0 and BID Top Drive. 10:00 - 14:00 4.00 FISH P DECOMP POOH wI 4" DP. 14:00 - 15:30 1.50 FISH P DECOMP POOH wI BHA, Racked Back 4" HWDP and 6-1/4" DC. B I 0 and LID Milling BHA. No Recovery. 4" Grapple on PRT Sheared Off and Left in Hole. 15:30 - 16:00 0.50 FISH P DECOMP Cleared and Cleaned Rig Floor. Cleaned Out Junk Baskets. 16:00 - 16:30 0.50 FISH P DECOMP Brought Packer Spear BHA Components to Rig Floor and Tallied Same. 16:30 - 17:30 1.00 FISH P DECOMP M I U Packer Spearing BHA: Spear wI 4" Grapples, Stop Sub, XO, Pump Out Sub, Bumper Sub, Oil Jar, XO, 9 x 6-1/4" Drill Collars, XO, Accelerator Jars, XO, 21 Jts HWDP. BHA Total Length = 966.22'. 17:30 - 18:00 0.50 FISH P DECOMP RIH to 2210'. 18:00 - 18:30 0.50 FISH P DECOMP Service Rig. 18:30 - 21 :30 3.00 FISH P DECOMP RIH to 10976'. 21 :30 - 22:00 0.50 FISH P DECOMP Establish Parameters Up Weight 212,000# Down Weight 177,000#,Slacked Off and Latched Onto Fish at 10986'. 40 psi Increase On Pumps. Swallowed 2' Set Down 20k, Held 40 psi Increase in Pump Pressure. 3-5 Thousand Over Pull. 22:00 - 23:30 1.50 FISH P DECOMP Dropped The Dart Attempt to Open Pump Out Sub, Monitor Printed: 3/20/2006 12:09:46 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-22/L -14 2-221L-14 REENTER+COMPLETE DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 3/5/2006 3/19/2006 Spud Date: 3/25/1989 End: 3/19/2006 3/9/2006 22:00 - 23:30 1.50 I FISH P DECOMP Well. 23:30 - 00:00 0.50 FISH P DECOMP POOH From 10,986. 3/10/2006 00:00 - 09:30 9.50 FISH P DECaMP POOH w/4" DP. DP Pulled Wet. 09:30 - 11 :00 1.50 FISH 'p DECOMP POOH wI BHA, Racked 4" HWDP and 6-1/4" DCs. 11 :00 - 13:30 2.50 FISH Ip DECOMP B I 0 and LID Fish. Recovered, Packer wI Mill Out Ext, 5-1/2" x 3-1/2" XO, 3-1/2" Pup Joints, 3 Joints 3-1/2" Tubing, 3-1/2" X Nipple, 3-1/2" XN Nipple wI PX Plug Installed, 3-1/2" Pup Joint 113:30 - 14:00 wI WLEG. Total Length of Fish: 112.62'. Punched Holes in Tubing to Allow Fluid to Drain, Due to PX Plug in Tubing Tail. 0.50 FISH P DECOMP Cleared and Cleaned Rig Floor. 14:00 - 16:00 2.00 FISH P DECOMP RIH w/3 Stands 6-1/4" DCs, B I 0 and LID Same. 16:00 - 19:00 3.00 CLEAN P DECOMP M I U RCJB Clean Out BHA: 6" RCJB, XO, 7" Casing Scraper, 3 x 6" Junk Baskets, Bit Sub, Bumper Sub, Oil Jar, XO, 18 x 4-3/4" Drill Collars, 21 Jts 4" HWDP. BHA Total Length = 1,241.73'. 19:00 - 20:00 1.00 CLEAN P DECOMP Slip and Cut Drilling Line. 20:00 - 23:00 3.00 CLEAN P DECOMP RIH With BHA on 4" DP To 11,430'. 23:00 - 00:00 1.00 CLEAN P DECOMP Establish Parameters: Up Weight 210,000#, Down Weight I 180,000#, Rotating Weight 96,000# at 50 rpm, Torque 6,000 ftllbs. Sand Cap and IBP Not at Anticipated Depth. PIU DP Ip From Pipe Shed and RIH to 11,636'. 3/11/2006 00:00 - 01 :00 1.00 CLEAN DECOMP Washed Down Tagged Up At 11,671. String Weight Up Weight 210,000#, String Weight Down 182,000#, Pump Rate 4.8 bpm, 1,075 psi. Increased Pump Rate, 9.0 bpm, 3,700 psi. P I U x 5, Tagged Up at 11,671' Each Time, Unable to Wash Down Below 11,671'. 01 :00 - 02:30 1.50 CLEAN P DECOMP Pumped and Circulated Around 40 bbl Hi-Vis Sweep, 9.0 bpm, 3,700 psi. 02:30 - 08:00 5.50 CLEAN P DECOMP POOH wI 4" DP. 08:00 - 09:00 1.00 CLEAN P DECOMP POOH wI BHA, Racked Back 4" HWDP and 4-3/4" DCs. 09:00 - 09:30 0.50 CLEAN P DECOMP POOH, B / 0 and LID RCJB BHA and Fish. Recovered IBP Inside RCJB. 09:30 - 10:00 0.50 CLEAN P DECOMP Cleared and Cleaned Rig Floor. 10:00 - 12:30 2.50 FISH P DECOMP Held PJSM. M I U Packer Milling BHA: 6" Packer Mill, 3 x Junk Baskets, Bit Sub, Pump Out Sub, Bumper Jars, Oil Jars, XO, 18 x 4-3/4" DC's, 21 Joints 4' HWDP. BHA Total Length = 1,231.84'. 12:30 - 15:00 2.50 FISH P DECOMP RIH wI BHA on 4" DP to 11,595'. 15:00 - 17:30 2.50 FISH P DECOMP M I U Top Drive, Engaged Pump, 5.0 bpm, 980 psi. String Weight Up 215,000#, String Weight Down 182,000#, Rotating String Weight 202,000#,70 rpm Torque 8,000 ftllbs, Washed Down to 11,674', Tagged Up on Packer at 11,674'. Milled Packer 11,674' to 11,677', WOM 5,000# - 10,000#,70 rpm, Torque 10,000 ft Ilbs, Pump Rate 5.0 bpm, 960 psi. 17:30 - 19:00 1.50 FISH P DECOMP Circulate Bottoms Up at 10 bpm With 3850 Psi. 19:00 - 21 :30 2.50 FISH P DECOMP Push Packer From 11,691' To 11,830'. Washed and Ream To 12,029' at 100 rpm with 6,000 to 8,000 ftllbs Torque, 5,000# to 30,000# WOM, 7.5 With 1800 psi. 21 :30 - 00:00 2.50 FISH P DECOMP Pump 40 bbl Hi-Vis Sweep, Displace Well to Clean Sea Water at 7.5 bpm With 1860 psi. 3/12/2006 00:00 - 01 :30 1.50 FISH DECOMP Displaced Well bore wI Clean 8.5 ppg Sea Water, 7 bpm, 1,780 psi. Monitored Well, Well Static, B I 0 and BID Top Drive. 01 :30 - 09:30 8.00 FISH DECOMP POOH wI 4" DP, Bottom 39 Stands Coated wI Paraffin. Crews Printed: 3/20/2006 12:09:46 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-22/L -14 2-22/L-14 REENTER+COMPLETE DOYON DRILLING INC. DOYON 16 Start: 3/5/2006 Rig Release: 3/19/2006 Rig Number: Spud Date: 3/25/1989 End: 3/19/2006 3/12/2006 01 :30 - 09:30 8.00 FISH DECOMP Utilized Power Washer and Absorbent to Clean DP. 09:30 - 11 :00 1.50 FISH DECOMP POOH wI 4" BHA, BHA Coated wI Paraffin. Crews Utilized Power Washer and Absorbent to Clean BHA, Racked 4" HWDP and 4-3/4" DCs. B I 0 and LID Milling BHA. 11 :00 - 12:00 1.00 FISH DECOMP Cleared and Cleaned Rig Floor. 12:00 - 13:30 1.50 DHB TIEB1 Held PJSM wI Rig Crew, Schlumberger Crew, Halliburton Rep, Tool Pusher and Drilling Supervisor. R I U Schlumberger Equipment. M I U 5-3/4" Gauge Ring I Junk Basket Assy wI GR-CCL Tool To E-Line. 13:30 - 16:30 3.00 DHB TIEB1 RIH wi GR I JB-GR-CCL on E-Line to 10,500'. Stacked Out wI Tools at 10,500'. Attempted to Work Tools Past 10,500' wI 0 Success. POOH, E-Line and Tools Covered wI Paraffin. Recovered 2 Gallons Paraffin from Junk Basket. 16:30 - 19:00 2.50 DHB TIEB1 Cleaned Up Tools, RIH wI GR I JB-GR-CCL on E-Line to 10,400'. Stacked Out wI Tools at 10,400'. Attempted to Work Tools Past 10,440' wI 0 Success. POOH, E-Line and Tools Covered wI Paraffin. Recovered 3 Gallons Paraffin from Junk Basket. Discussed Situation wI Anchorage Team, Decision Made to Run and Set CIBP on DP. 19:00 - 20:30 1.50 DHB TIEB1 Cleaned Up E-Line Tools, RID Schlumberger E-Line Equipment. 20:30 - 22:30 2.00 DHB TIEB1 M I U CIBP Assembly and RIH wI BHA. BHA Consists of: CIBP, Running Tool, Ported Sub, Pump Out Sub, XO, 18 x 4 3/4" Drill Collars, 21Jts HWDP. BHA Total Length = 1,204.63'. 22:30 - 00:00 1.50 DHB TIEB1 RIH wI BHA on 4" DP to 4082'. 3/13/2006 00:00 - 03:30 3.50 DHB TIEB1 RIH wI CIBP to 11,440'. 03:30 - 04:30 1.00 DHB TIEB1 M I U Top Drive, Established Parameters, String Weight Up 207,000#, String Weight Down 190,000#, Broke Circulation, 8 bpm, 1,800 psi, Rotated Drill String to the Right wI 35 Rounds, Set CIBP, Pulled to 260,000# to Shear MST and Set CIBP. 04:30 - 05:00 0.50 DHB TIEB1 Held PJSM, R I U Head Pin and Lines. Closed Pipe Rams, Pressure Tested 9-5/8" Casing and CIBP to 4,000 psi f/15 Minutes, OK. Bled Down Pressure, Opened Pipe Rams. R I U Little Red Equipment. 05:00 - 06:30 1.50 CLEAN CLEAN PJSM wI Rig Crew, Little Red, Mud Engineer, Tool Pusher and Drilling Supervisor. Tested Lines to 1,000 psi, Pumped 100 bbls 180 Degree Diesel. Pump Rate 1.5 bpm, 500 psi. 06:30 - 07:00 0.50 CLEAN CLEAN Spotted 100 bbl180 deg Diesel in Annulus wI 40 bbl Hi-Vis Safe Clean Sweep and 80 bbls 160 deg Clean Seawater. 07:00 - 08:00 1.00 CLEAN CLEAN Allowed 180 deg Diesel to Soak in Annulus. 08:00 - 10:00 2.00 CLEAN CLEAN Displaced Well bore to Clean 160 deg Seawater. Pump Rate 12 bpm, 3,950 psi. Overboarded Diesel, Sweep, 300 bbls Seawater. 10:00 - 10:30 0.50 CLEAN CLEAN BID and RID Lines. 10:30 - 14:00 3.50 CLEAN CLEAN POOH wI 4" DP. 14:00 - 15:00 1.00 CLEAN CLEAN POOH wI BHA, Racked Back 4" HWDP and 4-3/4" DCs. B I 0 and LID CIBP Setting Tool. 15:00 - 16:00 1.00 CLEAN CLEAN Cleared and Cleaned Rig Floor. 16:00 - 17:00 1.00 CASE TIEB1 Serviced Rig. 17:00 - 18:00 1.00 CASE TIEB1 Held PJSM. M I U polish Mill BHA: 7.34" x 8.20" Tandem polish Mill, Pin x Pin XO, 2 x Junk Baskets, 9-5/8" Casing Scraper, Bit Sub, XO, Bumper Jars, Oil Jars, XO, 18 x 4-3/4" DC's, 21 Joints 4" HWDP. BHA Total Length = 1,237.58'. Printed: 3/20/2006 12:09:46 PM Legal Well Name: 2-22/L -14 Common Well Name: 2-22/L -14 Spud Date: 3/25/1989 Event Name: REENTER+COMPLETE Start: 3/5/2006 End: 3/19/2006 Contractor Name: DOYON DRILLING INC. Rig Release: 3/19/2006 Rig Name: DOYON 16 Rig Number: Date 3/13/2006 118:00 - 21 :30 3.50 CASE TIEB1 RIH wI BHA on 4" DP to 10,928'. 21 :30 - 22:00 0.50 CASE TIEB1 M I U Top Drive, Engaged Pump, 5.0 bpm, 580 psi. String Weight Up 215,000#, String Weight Down 172,000#, Rotating String Weight 195,000#, 60 rpm Torque 7,000 ftllbs, Washed Down to 10,992', Tagged Up on Tie Back Sleeve at 10,986'. 122:00 - 23:00 Dressed Off Inside of PBR 10,986' to 10,992', Dressed Off Top of PBR at 10,986'. 1.00 CASE TIEB1 Pumped and Circulated Around 40 bbl Hi-Vis Sweep, 13 bpm, 3,900 psi. B I 0 and BID Top Drive. 23:00 - 00:00 1.00 CASE TIEB1 POOH w/4" DP. 3/14/2006 00:00 - 03:00 3.00 CASE P TIEB1 POOH wI 4" DP. 03:00 - 04:30 1.50 CASE P TIEB1 Held PJSM. Slipped and Cut Drilling Line. 04:30 - 06:00 1.50 CASE f TIEB1 POOH wI BHA. Racked 4" HWDP, 4-3/4" DCs. B I 0 and LID polish Mill BHA. 06:00 - 07:30 1.50 BOPSU P TIEB1 Held PJSM. Cleared and Cleaned Rig Floor. M I U Test Joint, RIH, Latched and Retrieved Wear Bushing. M I U Test Plug, Ran and Set Test Plug in Welhead. C/O 3-1/2" x 6" Variable I Rams fl 7" Solid Pipe Rams. 07:30 - 08:30 1.00 BOPSU1 P TIEB1 R I U Test Equipment, Performed Body Test on BOP Stack, 250 psi 14,000 psi Held Each Test fl5 Minutes wI No Leaks or Pressure Loss. Test Witnessed By Doyon Tool Pusher and BP Drilling Supervisor. 08:30 - 09:30 1.00 BOPSU P TIEB1 Pulled Test Plug, RID Test Equipment, BID Lines. 09:30 - 10:00 0.50 CASE P TIEB1 R I U 7" Casing Handling Equipment. 10:00 - 10:30 0.50 CASE P TIEB1 Held PJSM w/ Rig Crew on Running Casing. 10:30 - 11 :00 0.50 CASE P TIEB1 M I U Seal Assy: Seal Section wI No Go Fluted Collar and 10' 7" BTC Pup Joint, 2 Joints 7" 26# L-80 BTC Casing. Seal Assy Fluted Collar has Ported Insert Float. Joint #2 has Baker Insert Type II Landing Collar. Bakerlocked All Connections, M I U Torque 9,000 ft Ilbs. Filled Casing and Checked Floats, OK. 11 :00 - 21 :00 10.00 CASE P TIEB1 RIH wI 203 Joints 7" 26# L-80 BTC Casing, Average M I U Torque 9,000 ft Ilbs. Utilized Best-O-Life 2000 NM Pipe Dope on All Connections. Filled Casing Every 5 Joints. 21 :00 - 22:00 1.00 CASE P TIEB1 R I U Torque Turn Equipment and Double Stack Casing Tongs. 22:00 - 00:00 2.00 CASE P TIEB1 RIH wI 31 Joints 7" 26# L-80 TC-II Casing. Torque Turned All Connections, M I U Torque 10,100 ft Ilbs. Utilized Jet Lube Seal Guard Pipe Dope on Connections. 3/15/2006 00:00 - 01 :30 1.50 CASE P TIEB1 RIH wI 34 Joints 7" 26# L-80 TC-II Casing to 10,985'. Torque Turned All Connections, M I U Torque 10,100 ft Ilbs. Utilized Jet Lube Seal Guard Pipe Dope on Connections. 01 :30 - 02:30 1.00 CASE P TIEB1 C I 0 to Long Bails, M I U Circulation Head and Lines. 02:30 - 03:30 1.00 CASE P TIEB1 Broke Circulation, 3 bpm, 200 psi, RIH and Stung Into Tie-Back at 10,991', Observed Pressure Increase to 400 psi, Tested Seals to 500 psi. PI U on Casing String, Observed Total Pressure Loss. 03:30 - 04:00 0.50 CASE P TIEB1 Broke Out Circulating Head, Dropped Type II Land Collar Pressure Seat Ball, M I U Cementing Head wI Wiper Plugs Installed. 04:00 - 05:00 1.00 CASE P TIEB1 Engaged Pump and Circulated Ball on Seat, Tested Casing to 2,500 psi f/15 Minutes, Increased Test Pressure to 3,000 psi fl 15 Minutes. Increased Pressure and Sheared Ball and Seat at 3,650 psi. Regained Circulation. 05:00 - 07:00 2.00 CASE P TIEB1 Circulated to Condition Hole, 10 bpm at 1,250 psi. Held PJSM Printed: 3/20/2006 12:09:46 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-22/L-14 2-22/L -14 REENTER+COMPLETE DOYON DRILLING INC. DOYON 16 Start: 3/5/2006 Rig Release: 3/19/2006 Rig Number: Spud Date: 3/25/1989 End: 3/19/2006 3/15/2006 TIEB1 05:00 - 07:00 2.00 CASE P 07:00 - 10:30 3.50 CEMT P TlEB1 wI Rig Crew, Schlumberger Crew, Truck Drivers, Mud Engineer, Tool Pusher and Drilling Supervisor. Continued to Circulate While Schlumberger Batch Mixed Cement. Switched to Schlumberger, Pumped 5 bbls Water, 2 bpm, 100 psi. Shut in Cement Manifold, Tested Lines to 4,500 psi, OK, Bled Down Pressure. Switched to Little Red, Pumped 50 bbls Diesel, 4.8 bpm, 700 psi, Pumped 5 bbls Glycol, 4.5 bpm, 1,100 psi. Dropped Bottom Plug, Pumped 107 bbls (215 sks) 11.5 ppg Lite Crete Cement wI 0.400 %bwoc Dispersant, 0.130 %bwoc Retarder, 0.600 %bwoc Antifoam, 1.50 gall sk GASBLOK, 46.00 %bwoc Extender, 24.00 %bwoc Silica; Followed by 206.5 bbls (974 sxs) 15.8 ppg Premium Class G Cement wI 0.300 %bwoc Dispersant, 0.070 %bwoc Retarder, 0.200 %bwoc Antifoam, 0.350 %bwoc Fluid Loss. Pumped Cement at the Following Rates: Lead Cement Pumped 5.00 bbls 25.00 bbls 50.00 bbls 75.00 bbls 100.00 bbls 107.00 bbls Tail Cement Pumped Rate Pressure Flow 25.00 bbls 3.50 bpm 425 psi 16% 50.00 bbls 4.00 bpm 640 psi 16% 75.00 bbls 4.50 bpm 670 psi 16% 100.00 bbls 4.50 bpm 675 psi 16% 125.00 bbls 4.00 bpm 650 psi 16% 150.00 bbls 4.50 bpm 700 psi 16% 175.00 bbls 4.50 bpm 700 psi 16% 200.00 bbls 3.50 bpm 530 psi 16% 206.50 bbls 2.00 bpm 150 psi 16% Dropped Top Wiper Plug, Pumped 5.0 bbls Water 4.50 bpm, 200 psi. Switched to Rig Pumps and Displaced Cement with 413 bbls of Clean Seawater at the Following Rates: Pumped Rate Pressure Flow 25.00 bbls 8.00 bpm 480 psi 16% 50.00 bbls 8.00 bpm 480 psi 16% 100.00 bbls 10.00 bpm 740 psi 17% 150.00 bbls 10.00 bpm 740 psi 18% 200.00 bbls 10.00 bpm 750 psi 18% Caught Cement wI 215.0 bbls Pumped 250.00 bbls 7.00 bpm 1,800 psi 18% 300.00 bbls 6.75 bpm 2,780 psi 18% 350.00 bbls 5.00 bpm 3,650 psi 14% 400.00 bbls 2.00 bpm 3,940 psi 10% 405.00 bbls 1.00 bpm 3,650 psi 0% 412.00 bbls 1.00 bpm 3,900 psi 0% Bumped Plug wI 418.00 bbls Total Displacement Pumped. Pressured up to 4,300 psi to Bump Plug, Held fl 5 Minutes. RIH and Landed Out Seal Assy on Top of Tie Back PBR. Bled Rate 3.00 bpm 5.00 bpm 5.00 bpm 5.00 bpm 5.00 bpm 4.00 bpm Pressure 550 psi 750 psi 700 psi 655 psi 645 psi 350 psi Printed: 3/20/2006 12:09:46 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-22/L-14 2-22/L-14 REENTER+COMPLETE DOYON DRILLING INC. DOYON 16 Start: 3/5/2006 Rig Release: 3/19/2006 Rig Number: Spud Date: 3/25/1989 End: 3/19/2006 3/15/2006 07:00 - 10:30 3.50 CEMT P TIEB1 Down Pressure and Checked Seals, Seals Held. Cement In Place at 1030 hrs. 10:30 - 11 :00 0.50 CEMT P TIEB1 Flushed BOP Stack wI Water - Retarder - Citric Acid Sweep. Pumped Down BOP Stack. 11 :00 - 12:00 1.00 WHSUR P TIEB1 N I D and Split Stack. Set Emergency 7" Slips in Place and Energized wI 150,000# Set Down Weight of 7" Casing. 12:00 - 13:00 1.00 CASE P TIEB1 R I U Wachs Cutter and Cut 7" Casing, Left 6-1/4" Stub. POOH, L / D Cut Joint and Cementing XO. 13:00 - 15:00 2.00 WHSUR P TIEB1 Installed 7" Packoff, N I U New 13-5/8" 5M Tubing Spool. Tested Void to 4,300 psi f/15 Minutes. Torqued LDS to 450 ft I Ibs. 15:00 - 17:00 2.00 BOPSU P TIEB1 N I U BOP Stack, C I 07" Solid Rams f/3-1/2" x 6" Variable Rams. 17:00 - 17:30 0.50 BOPSU P TIEB1 Make BOP Test Assembly. 17:30 - 20:30 3.00 CEMT P TIEB1 Slight Seawater Returns Noted in BOP Stack. Close Blind Rams and Pressure Up on 7" Casing to 1,500 psi and Wait on Cement. 20:30 - 21 :00 0.50 BOPSU P TIEB1 Install BOP Test Assembly. 21 :00 - 00:00 3.00 BOPSU P TIEB1 Test BOPE to 250 psi Low and 3,500 psi High Pressure for Annular, 250 psi Low and 4,000 psi High Pressure for Rams, Valves and Choke Manifold. AOGCC Witness of BOP Test Waived By Lou Grimaldi. Test Witnessed by WSL and Doyon Toolpusher. Test #1 - Annular. Test #2 - Blinds, Choke Valves 1,12,13,14, Kill HCR and Upper IBOP. Test #3 - Blinds, Choke Valves 9, 11, Manual Kill, Lower IBOP. Test #4 - Blinds, Choke Valves 5,8, 10, Dart Valve. Test #5 - Blinds, Choke Valves 4, 6, 7, Floor Valve. Test #6 - Blinds, Choke Valve 2 3/16/2006 00:00 - 01 :30 1.50 BOPSU P TIEB1 Continue Pressure Tesing BOPE Equipment to 250 psi Low and 4,000 psi High. Test #7 - Blinds, Choke Valves 3, 1. Test #8 - Blinds, Choke HCR. Test #9 - Blinds, Manual Choke Valve. Test #10 - Pipe Rams, Choke HCR, Kill HCR. Accumulator Test- Starting Pressure 2,950 psi, 1,750 psi After Functioning BOPE, First 200 psi in 17 Seconds, Full Pressure in 1 minute and 18 Seconds, 5 Nitrogen Bottles at 2,150 psi. 01 :30 - 02:00 0.50 BOPSU P TIEB1 Pulled Test Plug and Installed Wear Bushing. 02:00 - 03:00 1.00 CLEAN P CLEAN R I U Bails and Elevators 03:00 - 04:00 1.00 CLEAN P CLEAN M I U BHA #7, 6" Bladed Junk Mill, 3 x Junk Baskets, Bit Sub, Pump Out Sub, Lubricated Bumper Sub, Oil Jar, XO, 18 x Drill Collars, 21 x HWDP. Total BHA = 1231.77' 04:00 - 09:00 5.00 CLEAN P CLEAN RIH with BHA #7 on 4" DP to 10,800' 09:00 - 09:30 0.50 CLEAN P CLEAN M I U Top Drive, Established Parameters: String Weight Up 225,000#, String Weight Down 155,000#, Rotating String Weight 182,000#, 60 rpm, Torque 10,000 ft fibs, 8 bpm, 1,000 psi. Washed Down and Tagged Up at 10,888'. 09:30 - 10:00 0.50 CLEAN P CLEAN Circulated Bottoms Up 11.75 bpm, 4,050 psi. 10:00 - 10:30 0.50 CLEAN P CLEAN Closed Pipe Rams, Pressure Tested Casing to 4,000 psi f/15 Printed: 3/20/2006 12:09:46 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-22/L-14 2-22/L-14 REENTER+COMPLETE DOYON DRILLING INC. DOYON 16 Start: 3/5/2006 Rig Release: 3/19/2006 Rig Number: Spud Date: 3/25/1989 End: 3/19/2006 3/16/2006 10:00 - 10:30 0.50 CLEAN P CLEAN Minutes, OK. Bled Down, Opened Pipe Rams. 10:30 - 12:30 2.00 CLEAN P CLEAN Drilled Cement and Float Equipment 10,888' to 10,995', WOM 5,000# - 15,000#, 80 rpm, Torque On Bottom 11,500 ft Ilbs, 7 bpm, 1,500 psi. Washed Down to 11,019'. 12:30 - 13:00 0.50 CLEAN P CLEAN Pumped and Circulated Around 40 bbl Hi-Vis Sweep, 12 bpm, 3,850 psi. Circulated Until Returns Over Shakers Were Clean. 13:00 - 14:30 I 1.50 CLEAN P CLEAN Washed Down to 11,402', 9 bpm, 2,145 psi, 60 rpm. 14:30 - 15:00 0.50 I CLEAN P CLEAN Pumped and Circulated Around 20 bbl Hi-Vis Sweep, 12 bpm, 3,900 psi. Circulated Until Retums Over Shakers Were Clean. 15:00 - 16:00 1.00 I CLEAN P CLEAN B I 0 and BID Top Drive. M I U Circulating Head and Lines, Closed Pipe Rams, Pressure Tested Casing to 4,000 psi f/30 Minutes, OK. Bled Down, Opened Pipe Rams. 16:00 - 16:30 0.50 CLEAN P CLEAN Washed Down and Tagged Up on CIBP at 11,440'. String Weight Up 250,000#, String Weight Down 163,000#, Rotating String Weight 193,000#, 85 rpm, Torque 11,000 ft Ilbs, 9 bpm, 2,125 psi. 16:30 - 17:30 1.00 CLEAN P CLEAN Milled CIBP 11,440' - 11,443', WOM 5,000# - 20,000#, 80 rpm, Torque On Bottom 15,000 ft Ilbs, 9 bpm, 2,050 psi. 17:30 - 18:30 1.00 CLEAN P CLEAN Push CIBP to 12,029' 18:30 - 20:30 2.00 CLEAN P CLEAN Circulate 10.5 bpm at 3,700 psi. R / U Little Red and Pressure test lines to 3,500 psi. 20:30 - 21 :30 1.00 CLEAN P CLEAN Pump 50 bbl of 180 Degree Diesel with Little Red, 2 bpm at 450 psi, 124 bbls of Seawater10 bpm at 3,160 psi 21 :30 - 22:00 0.50 CLEAN P CLEAN POOH to 11 ,467' and Let Diesel Soak 22:00 - 22:30 0.50 CLEAN P CLEAN RIH to 12,029, 22:30 - 00:00 1.50 CLEAN P CLEAN Pump Open Circ Sub, Pump 40 bbl Safe Clean Hi-Vis Sweep Displace Well with Heated Clean Seawater. 7 bpm at 1,320 psi. 3/17/2006 00:00 - 01 :00 1.00 CLEAN P CLEAN Displaced Wellbore to Clean 8.5 ppg Seawater. 7 bpm, 1,340 psi. 01 :00 - 10:00 9.00 CLEAN P CLEAN Observed Well, Well Static, B I 0 and BID Top Drive. POOH LID 4" DP. 10:00 - 11 :30 1.50 CLEAN P CLEAN POOH, LID 4" HWDP, 4-3/4" DC, Clean Out BHA. Cleaned Out Junk Baskets. 11 :30 - 12:30 1.00 CLEAN P CLEAN Cleared and Cleaned Rig Floor. 12:30 - 15:30 3.00 EV AL P TIEB1 Schlumberger Slickline Alerted to be on Location at 1030 hrs, Unit Arrived on Location at 1200 hrs. The Rig was Ready to R I U Slickline at 1230 hrs, Waited on Schlumberger Slickline Crew to Gather Needed Equipment and to Sort Out Problem with Pressure Hose to Weight Indicator and Sheave Block. 15:30 - 16:00 0.50 EVAL P TIEB1 Held PJSM, R I U Schlumberger Equipment. 16:00 - 21 :00 5.00 EVAL P TIEB1 RIH wI 5.83" Gauge Ring I Junk Basket on Slickline to 11,400'. Empty Junk Basket, Recovered 1/2 Gallon of Metal Pieces and Rubber Chunks. Re-run Junk Basket to 11,400' POOH, Junk Basket Empty. RID Schlumberger Slickline Equipment. 21 :00 - 22:00 1.00 RUNCMP Hold PJSM, Rig Up Tubing Handling Equipment. 22:00 - 00:00 2.00 RUNCMP Run 4.5", 12.6#, L-80, TC- Tubing to 625'. Average Make Up Torque 3,860 ftllbs. 3/18/2006 00:00 - 12:30 12.50 RUNCMP Run 4.5", 12.6#. L-80, TC- Tubing from 625' to 9,887'. Average Make Up Torque 3,860 ft Ilbs. Torqued Turned Every Connection. Used Jet Lube Seal Guard Pipe Dope. Pressure Test Tubing to 4,000 psi for 15 Minutes Every 3,000'. 12:30 - 14:00 RUNCMP Make Up SSSV, Rig Up Control Lines. Test Control Lines to 5,000 psi. Printed: 3/20/2006 12:09:46 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-22/L-14 2-22/L -14 REENTER+COMPLETE DOYON DRILLING INC. DOYON 16 17:00 - 18:00 1.00 18:00 - 18:30 0.50 18:30 - 19:00 0.50 19:00 - 20:00 1.00 20:00 - 22:00 2.00 22:00 - 23:00 1.00 23:00 - 00:00 1.00 3/19/2006 00:00 - 01 :30 1.50 01 :30 - 03:30 2.00 03:30 - 05:00 1.50 05:00 - 06:00 06:00 - 08:30 08:30 - 09:00 09:00 - 10:00 10:00 - 12:00 12:00 - 18:00 18:00 - 19:00 19:00 - 22:00 22:00 - 00:00 1.00 BOPSU P 3.00 WHSUR P 2.00 WHSUR P os Start: Rig Release: Rig Number: 3/5/2006 3/19/2006 Spud Date: 3/25/1989 End: 3/19/2006 , NPT I P _------L I RUNCMP ¡ I RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP WHDTRE WHDTRE WHDTRE WHDTRE WHDTRE WHDTRE Run 4.5",12.6#. L-80, TC-II Tubing with SSSV Control Lines from 9,887' to 11,384'. Average Make Up Torque 3,860 ft Ilbs. Torque Turned Every Connection. Used Jet Lube Seal Guard Pipe Dope. Make Up Hanger Assembly, Terminate and Make Up Control Lines to Hanger. Test Lines to 5,000 psi. Land Hanger and Run In Lock Down Screws. Tubing Set at 11,408', Up Weight 165,000#, Down Weight 133,000#. Rig Up and Pressure Test Tubing to 4,000 psi for 15 Minutes. Rig Down Test Equipment, Casing Equipment and Control Line Equipment. Clear Rig Floor. Hold PJSM, Rig Up Schlumberger Slick Line Unit. RIH to Retrieve SSSV Dummy Valve & POOH. RIH to Retrieve D-16 Plug. POOH wI D-16 Plug on Slickline. RIH wI SSSV Dummy Valve on Slickeline and Set in SSSV. Tested Control Lines. RID SWS. Held PJSM, R I U Vac Truck to Pump. Displaced 7" x 4-1/2" Annulus wI Corrosion Inhibited 8.5 ppg 140 deg Seawater, 3 bpm, 200 psi. R I U Little Red to Circulating Manifold. Pumped 60 bbls Diesel Down 7" x 4-1/2" Annulus, Shut In Annulus Valve, Lined Up on Tubing, Pumped 5 bbls Diesel Down Tubing. Dropped BallI Rod Assy and Allowed to Fall on Seat on RHC Sleeve in XN Nipple at 11,394'. Pressured up to 2,500 psi to Set Baker S-3 Packer, Increased Pressure to 4,000 psi and Tested Tubing f/30 Minutes, OK. Bled Down Tubing Pressure to 2,000 psi and Shut In. Pressure Tested 7" x 4-1/2" Annulus to 4,000 psi fl 30 Minutes, OK. Bled Down All Pressures, Blew Down All Lines and RID Same. RID Little Red. B I 0 and LID Landing Joint. Ran and Set TWC. N I D BOP Stack and Related Equipment. C I 03-1/2" x 6" Variable Rams fIT' Solid Rams, cIa Choke and Kill on BOP Stack. Waited on Endicott Production to Bleed Down 2-20 Prior to Lifting Stack. Set BOP Stack back on Pedestal. Nipple Up and Test Adaptor Flange to 5,000 psi. Terminate Control Lines. Nipple Up Tree and Test to 5,000 psi. Install BPV and Secure Well. Rig Released at 24:00 hrs. Printed: 3/20/2006 12:09:46 PM TREE: 9-518", NSCC Ref. Log: 2" 5" 4 Open Open Open Open Open Open Open Open _ STATE OF ALASKA _ ALA" OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 55.5 KB 8. Property Designation: ADLO-034633 11. Present Well Condition Summary: Total Depth measured 12322 true vertical 10593.2 Effective Depth measured 12236 true vertical 10519.81 Casing Conductor Surface Intermediate Production Liner Liner Size 30" Drive Pipe 13-3/8" 68# L-80 9-5/8" 47# NT80S 9-5/8" 47# NT95HS 2-7/8" 6.16# L-80 7" 29# SM-110 Length 80 2469 9375 1839 23 1324 Perforation depth: Measured depth: 11530 - 11553 Closed 11809 - 11828 12000 - 12016 True Vertical depth: 9930.14 - 9949.1 Closed 10160.39 -10176.17 10319.96 - 10333.42 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl o o x Plug Perforations 0 Perforate New Pool D Perforate D 4. Current Well Class: Development Stratigraphic D Stimulate D Other D waiverD Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 189-0340 6. API Number: 50-029-21931-00-00 Exploratory Service p 9. Well Name and Number: » G") ::::s n I» "" Q n .... Q I» :::! cc "" n ~ 3 t;¡. "" õ' :::! 2-22/L-14 10. Field/Pool(s): Endicott Field/ Endicott Pool feet feet 11430 None Plugs (measured) Junk (measured) feet feet » i» "" I» 52 MD TVD Burst Collapse 30 - 110 30 - 110 29 - 2498 29 - 2497.99 4930 2270 28 - 9403 28 - 8313.53 6870 4760 9403 - 11242 8313.53 - 9692.09 8150 5080 11700 - 11723 10070.22 - 10089.21 13450 13890 10998 - 12322 9495.24 - 10593.2 11220 8510 11593 - 11680 11758 - 11778 11783 - 11790 11801 -11805 11836 - 11905 11908 - 11929 11933 - 11986 11991 -11994 9982.06 - 10053.72 10118.14 -10134.69 10138.83 - 10144.63 10153.75 - 10157.07 10182.83 - 10240.37 10242.88 - 10260.44 10263.79 - 10308.2 10312.4 - 10314.92 4-1/2" 12.6# L-80 28 - 10957 3-1/2" 9.2# L-80 10957 - 11067 4-1/2" TIW HBBP Packer 10952 2-7/8" Otis WD Packer 11700 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 0 0 o 0 0 15. Well Class after proposed work: Exploratory Development 16. Well Status after proposed work: Oil D Gas D: WAG Service P WINJ P WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Printed Name Sharmaine Vestal / .~?/ .- ~./ . . Signa~~ Form 10-404 Revised 04/2004 0 RIG I N A (' Contact Sharmaine Vestal Title Data Mgmt Engr Phone 564-4424 Date 3/14/2006 200~ Submit Original Only ') Tubing pressure o o e e 2-22/L-14 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMllltbiRY 2/15/2006 CTU #5, Drift/Tag/lBP; MIRU DS CTU #5. Hold PJSM and SIMOPS with Nordic 2. RIH with 3.625" TS drift for upcoming chem cut. Tagged at 9 5/8" production packer @ 10,944' ctmd (est. 10,962' mdBKB). POOH. RIH with 2.00" JSN unrestricted to 12,060' ctmd and pushed to 12,070' ctmd with 2000# down weight. Discussed results w/ town engineer and decided depth reached was sufficient, no further clean out necessary. POOH. RIH with Baker 2.50" IBP. Set IBP at 11430'. Cant' on WSR 2/16/06... NOTE: 21/2" BAKER IBP HAS 1 3/8" FISHING NECK - 1840# DOWN TO EQUALIZE - 5500# UP TO PULL RELEASE 2/16/2006 CTU #5, IBP/Sand Dump; PT IBP - good. RIH with 2.25" SDN. Tag and verify depth of IBP (11425' ctmd). Lay in 700# of 20/40 river sand on top of IBP. Top of sand tagged at 11396' ctmd (29'). POOH. FP tubing to 1500' with 60/40 methanol. Well to remain shut in for further rig prep work. Pad operator notified of well status. *** Job Complete *** 2/20/2006 ***WELL SI ON ARRIVAL*** RIH W/ 3.6" SWEDGE W/ BLB W/ 2.5" GAUGE RING BRUSH SWN NIPPLE 11,001' SLM ***CONTINUED ON 02-21-2006*** 2/21/2006 *** CONTINUED FROM -02-20-2006 *** SET 3.5 PX-PLUG @ 11,001' SLM *** TURN WELL OVER TO DSO *** FLUIDS PUMPED BBLS 181 Meth 58 2% KCL 10 Gel 5.4 Sand slurry 254.4 TOTAL Re: VARIANCE REQUEST - SUNDRY #306_ / END 2-22/L-1... r"'~·~' Subject: Re: VARIANCE REQUEST - SUNDRY #306-033/ END 2-22/L-14 RWO From: Winton Aubert <winton_aubert@admin.state.ak.us> Date: Mon, 27 Feb 2006 09:54:07 -0900 To: "Seward, Michael (FAIRWEATHERt <MichaeI.Seward@bp.com> Mike, Per 20 AAC 25.285 (h), AOGCC hereby approves alternate BOPE, as described below, for your proposed workover (App. No. 306-033) of well End 2-22/L 14 (PTD 189-034). All other stipulations apply. Winton Aubert AOGCC 793-1231 \:'".. ,t' Seward, Michael (FAIRWEATHER) wrote: Winton, Following up on our earlier phone conversation, Doyon 16 will be moving to the Endicott 2-22/L-14 workover later this week. The scope of this workover has been detailed in the Application For Sundry Approval (Form 10-403) recently submitted to your office dated 1/24/06 (Sundry # 306-033). The rig currently has in place a 13-5/8" 5000 psi BOP stack with 3 preventors (annular, variable pipe rams, blind rams). The maximum anticipated surface pressure for this well is 3200 psi and the BOP test pressure specified in the well program is 4000 psi. Considering the maximum anticipated surface pressure and the inability to add a fourth preventer due to height restrictions in the substructure, BPXA requests a variance from 20 AAC 25.285 (c)(2)(B) for this workover. The current BOP stack configuration provides adequate well control protection and does not compromise the overall safety of the workover. Please call me if you have any questions. Regards, Mike Seward Mike Seward Ops. Drlg. Engr. / Endicott - Badami ACT Drilling / BPXA +1.907.564.5916/0 +1.907.632.4728 /m 1 of 1 2/27/20069:55 AM ~(i(ù?',I' ,ð ~, I ,Œ, I " l'I',rq f ii' i , I' , , "! I I ,¡ I I " U!J lJ i_ ) (,~fnl ~I' ¡' /;,i~r \, fl: ,@/8,/" (ñ) r~'7 ,'8t \\ I 'I' 1 I" I' , I " ,~'" ¡'! 1 i I I ,,' I ! \ '" ,: ,\ \ \\" ' f i ... I i ¡ \ ¡" ~ j ¡ , \ .., "\ !I \ (~U j I I II in ~ ,~ /,n '.\ n 1u' ~, ... I! 'II '_ il.JJ \W 1...::::3 L.1 U \..::::;."" ' , I, ) AI/A~KA OIL AND GAS CONSERVATION COMMISSION / FRANK H. MURKOWSKI. GOVERNOR / J 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 John McMullen Senior Production Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 ! ~-OOG Re: Endicott, END 2-22jL-14 Sundry Number: 306-033 ~t;/~N~:[J) ~JÞ~N ~) 1 2.00b Dear Mr. McMullen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, rJ4¡J~ Cathy P. Foerster Commissioner DATED this3~y of January, 2006 Encl. ~ 'lso/z,ooto ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 RECEIVED JAN 2 6 2006 Alaska Oil & Gas Cons. Commission AnLi'~raUð 1. Type of Request: 0 Abandon 0 Suspend 0 Operation Shutdown 0 Perforate 0 Other o Alter Casing / II Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well o Change Approved Program II Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: 11. Total Depth MD (ft): 12322 Casing , S~ructl)ral Conductor Surface Intermediate Production Liner 99519-6612 55.5 ADL 034633 -- 4. Current Well Class: / o Development 0 Exploratory o Stratigraphic ~service 5. Permit To Drill Number 189-034 / 6. API Number: //' 50- 029-21931-00-00 9. Well Name and Number: END 2-221L-14./ 10. Field / Pool(s): Endicott Field / Endicott Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 10593 12236 10520 None Length Size MD / TVD Burst Junk (measured): None Collapse 110' 30" 110' 110' 24981 13-3/8" 2498' 2498' 5020 2270 9403' 9-5/8" 9403' 8314' 6870 4760 1839' 9-5/8" 94031 - 11242' 8314' - 9692' 8150 5080 1324' 7" 10998' - 12322' 9495' - 10593' 11220 8510 23' 2-7/8" 11700' - 11723' 10070' - 10089' 13450 13890 Perforation Depth MD (ft): Perforation Depth TVD (ft): 11530' - 12016' 7 9930' - 10333' Packers and SSSV Type: 9-5/8", HBBP , 7", Otis WD SSSV Landing Nipple 12. Attachments: D.a Description Summary of Proposal o Detailed Operations Program 14. Estimated Date for Commencing Operations: o BOP Sketch February 15, 2006 Date: 16. Verbal Approval: Commission Representative: 17. I hereby certify that t forego' Printed Name Jo .~Iè Signature !/ Tubing Size: 4-1/2' x 3-1/2", 12.6# x 9.2# Tubing Grade: Tubing MD (ft): L-80 11067' Packers and SSSV MD (ft): 10952',11700' 1553' /' / 13. Well Class after proposed work: o Exploratory 0 Development D.a Service 15. Well Status after proposed work: DOil / o Gas D.a WAG 0 GINJ o Plugged . DWINJ o Abandoned o WDSPL rue and correct to the best of my knowledge. Contact John McMullen, 564-4711 Title Senior Production Engineer , .~' ,~ Prepared By Name/Number: Phone Date ( 2'-( '()-6 Sondra Stewman, 564-4750 Commission Use Only Sundry Number: ( '2¡)(p '-'oó3 Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity œ13'OP Test ~chanicallntegrity Test 0 Location Clearance Other: T -e <) t [30 1) E fa 4000 f ~ , M IT (~~~.d. Subsequent Form Required: lO - 4 0 4 . Approved By: (1ftu ~~ Form 10-403 ReV¡;; 0;/f05 ., ", I' ': A L ORIGiN MDMS 8Ft JAN :3 ] 2006 COMMISSIONER APPROVED BY THE COMMISSION Date I-~-Oþ Submit In Duplicate ) ) bp Endicott Well 2-22/ L-14 (WAG Injector) Rig Workover Sundry Notice 1. Well History END 2-22 / L-14 was originally drilled & completed in 1Q 1989 and operated as a fulltime WAG injector ./' until early 2001. A tubing leak developed in 2001and the well was waive red for water injection only (TxIA communication) and carried this status until late '2004. Required compliance pressure tests in late 2004 failed (CMIT-TxIA failed on pressure stabilization), and the well has been shut-in since. 2. Current Well Status Shut-in. Well secured with a tubing tail plug. 3. Workover Objective The proposed 2-22 / L-14 rig workover is necessary to replace corroded tubing, isolate a slow production casing/packer leak and return the well to fulltime WAG injection service. This RWO will restore well integrity by means of the following: 1. Pulling the existing completion (tubing, SBR assembly, production packer and tailpipe assembly; 2. Running a 7" Tieback string from the existing 7" Liner top (10998' MD) to surface and cementing 9- 5/8" x 7" annulus to surface; 3. Installing a new 4-1/2" completion string. The planned workover will include the following tasks: Pre-Rig Operations 1. PPPOT-T and IC. Function LDS. No-Flow. MIT-OA. 2. Pull XX plug & SV; / 3. Run SBHPS; 4. RIH and drift 4-1/2" tubing and 3-1/2" tailpipe; 5. RIH w/ jetting assembly; clean-out to PBTD; 6. RIH w/ BOT 2-1/2" IBP, set at 11430' MD; spot sand on top of IBP; 7. Shoot circulation holes / string shot tubing at the cut point; 8. Chemical cut 4-1/2" tubing above SBR; /' 9. Circulate well to kill weight brine; freeze protect to -200'; 10. Install BPV. Rig Operations 1. MIRU Doyon Rig 16; 2. Circulate well to clean KWF via ~,.u i~g cut; 3. ND/NU BOPE. Test BOP E to ~PSi; 4. Pull existing 4- Y2" completion; Endicott 2-22 / L-14 RWO Sundry Notice Page 1 of 4 Rig Operations - Continu)d . 5. RIH wi GR I JB, as re4uired; clean out to tubing stub; 6. RIH wi latch assembly and pull tubing stub and SBR; 7. RIH and mill I retrieve packer; /" 8. RIH wi TIW Tandem Polishing I Dressing Mill Assembly; dress off liner top; ) 9. Set RBP -100' below 7" liner top at 10998'; 10. RIH wi 7" 26# tieback string and ported tieback seal assembly; 11. Cement 9-5/8" x 7" annulus back to surface; test 7"; / 12. Install new packoffs, casing slips and tubing head; test; 13. RIH and clean out to I retrieve RBP 14. RIH and clean out to I retrieve IBP; / 15. RIH and clean out to top of isolation packer assembly (-11700'); 16. RIH wi new 4-1/2" 112.6# I L80 tubing and packer; 17. Land tubing, set packer, test tubing/lA. Set TWC; 18. NO BOPE; NU tree and test. RDMO. / Endicott 2-22 / L-14 RWO Sundry Notice Page 2 of 4 Attachment 1 - END 2-22 Existing Completion ) RT. ELEV= 55.5' B.F, ELEV = 17.14' MAX. DE\!. = 44:26 10200' MD ) TREE: 4-1/16" .15000 psi ¡ Ca'neron 1 Axelson Actuator \NELLHEAD: 13-518"! 5000 psll FMC (CCL) O --E SSSV LANDING NIPPLE I OTIS (3.813"I.D.) 1553' 13-318", 68#tTt" L-80, Btrs Cgg WfSSSV IN MIN. 1.0 2" 2400' I ,....  ~ -< 4·112", 12.6#lft, l-80, TOO 9-5/8",47#m NTSOS XO to NT95HS / I 9403' >- TOP OF 1" UNER I 10998' t ~ )¡. 9-5/8", 47#1ft, NT95HS, NSCC I 11242' I >- A I PERFORATING SUMMARY Ref-log: DlL..(3R (4-12-89) SIZ.E SPF INTERVAL STATUS 2" 6 11530' - 11553' Open 11593' -11643' Open ~ 11643'-11680' Open 5" 4 11758' - 11778' Open 11783' - 11700' Open 11801' " 11805' Open 1180g - 11828' Open 11836' - 11905' Open 11908' - 11929' Open 11933' - 11986' Open 11991' - 11994' Open 12000' -12016' Open GlMs (Cameo), (1-1/2" RK Latch) No. TVDSS MD-BKB #6 4082' 4169' #5 6216' 6914' -E-- #4 77Ut R710' #3 8645' 9918' tI2 9193' 10674' #1 929g 10815' - SLIDING SLEEVE OTIS "XA" (3..813" I.D.) I 10881' I II -E-- ] .o ~ TIW SBR (12' Icng) (5.4.38" 0.0.) 9-518' PACKER TIW (HBBP) (4.00" 1.0.) 3-1IZ', 9.2#Ift L-8O, TAILPIPE 3-112' '&PIS' NIPPLE PARKER (2.750" 1.0.) 3-1/2" 'SNN' NIPPlE PARKER (2635" 3-112" 10938' 10952' 1 mç¡ç¡' I 11030' I 11067' 1 ~ MARKER I 11352' I ~ ~r OtiS "WD~ Pkr w/2-17J8" "SWS Nipples 111,700' (2.313" 1.0.) ,......- 2-7/8" WLEG 111,723 PBTD 12,236' »^^^ . TOP OF FILL @12070 7", 29#!t'!, SM-110. 12322' >XXX Btrs-TKC . Date By Comments ENDICOTT WELL: 2-22/ L-14 03l0gS9 FH FRCFOS8) PERMIT NO, 1890340 API NO. 50-029-2193100 05'25189 JLH INITIAL COMPLET ION SEe 36, T12N, R16E, 1919' FNL & 2224' FEL 1Q2Æ12 JLH New PBTD & Aõ:I Perf 12111.()2 JWS Add Perfs BP EXPLORATION (ALASKA), INC Endicott 2-22 / L-14 RWO Page 3 of 4 Sundry Notice Attachment 2 - END 2-22 sed Completion R1. ElEV 121.1'. ElEV DEV. 44:26 MD Eilts ') TOP OF liNER ) NT95HS. I ""' ,... PERFORATING SUMMARY R.,! lúfJ Dll-GR T SP!' INTERVAL 6 !1S3Q' - H 553' . 11643' 116&0' 4 0~!1 PElTO ,291//ft. Btr¡¡,TKC Cornmenls !"Ii PROPOSED JlH p,,¡fs ~ND 2-22 FMC (CCl) Otis 'WD" Pkr 'III U1fff, "SWS Nipples (2.313" 1.0,) 2·1fS" WLEG I ^^1~ x x>! OF Fill ENDICOTT WELL: 2·22 I L-14 PERIIIIIT NO. 1890340 API NO. 50-029-2193100 SEC 36, Ti2N, R1GE, 1919' FNl 8. 2224' FEL p",f BP EXPLORATION (ALASKA), INC Endicott 2-22/ L-14 RWO Sundry Notice 40f4 e e ò BP Exploration (Alaska) Inc. Attn: Well Integrity Engineer, PRB-24 Post Office Box 196612 Anchorage. Alaska 99519-6612 November 13, 2005 RECEIVED NOV 1 6 2005 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. ih Ave. Anchorage, Alaska 99501 Alaska Oil & Gas Cons. Convnission Anchorage Subject: END2-221tíi'14 (PTD #1890340) Application for Canceftation of Sundry #302-166 Dear Mr. Aubert: Attached is Application for Sundry Cancellation form 10-404 to cancel sundry number 302-166. The sundry was for continued water injection with slow TxlA communication. The well will remain shut-in in preparation for a rig work over. With the cancellation of the sundry, the well will be removed from the Monthly Injection Report. An AOGCC witnessed MIT -IA will be scheduled post initial injection into the well after the work over is complete. If you require any additional information, please contact Anna Dube or Joe Anders at (907) 659-5102. Sincerely, J~~ Joe Anders, P.E. Well Integrity Coordinator ~^NNED DEe 1 ô 2005 Attachments Application for Sundry Cancellation form 10-404 ~ ^ /" 1. Operations Abandon D Repair Well D Plug Perforations D Stimulate D Othe Amk_t "'".."'. . w Performed: Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D AnCnorage Change Approved Program D Opera!. Shutdown D Perforate D Re-enter Suspended Well D 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 1Ð9<Ø340 ;!), 3. Address: P.O. Box 196612 Stratigraphic Service ¡;;¡ 6. API Number: Anchorage, AK 99519-6612 50-029-21931-00-00 7. KB Elevation (ft): 9. Well Name and Number: 55.5 KB 2-22/L-14 8. Property Designation: 10. Field/Pool(s): ADLO-034633 Endicott Field/ Endicott Pool 11. Present Well Condition Summary: Total Depth measured 12322 feet Plugs (measured) None true vertical 10593.2 feet Junk (measured) None Effective Depth measured 12236 feet true vertical 10519.81 feet Casing Length Size MD TVD Burst Collapse Conductor 80 30" Drive Pipe 30 - 110 30 - 110 Surface 2469 13-3/8" 68# L -80 29 - 2498 29 - 2497.99 4930 2270 Intermediate 9375 9-5/8" 47# NT80S 28 - 9403 28 - 8313.53 6870 4760 Production 1839 9-5/8" 47# NT95HS 9403 - 11242 8313.53 - 9692.09 8150 5080 Liner 23 2-7/8" 6.16# L-80 11700 - 11723 10070.22 - 10089.21 13450 13890 Liner 1324 7" 29# SM-11 0 10998 - 12322 9495.24 - 10593.2 11220 8510 Perforation depth: Measured depth: 11530 - 11553 11593 - 11680 11758 - 11778 11783 - 11790 11801 - 11805 11809 -11828 11836 - 11905 11908 - 11929 11933 - 11986 11991 - 11994 12000 -12016 True Vertical depth: 9930.14 - 9949.1 9982.06 -10053.72 10118.14 -10134.69 10138.83 -10144.63 10153.75 -10157.07 10160.39 - 10176.17 10182.83 - 10240.37 10242.88 - 10260.44 10263.79 -10308.2 10312.4 -10314.92 10319.96 - 10333.42 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 28 - 10957 3-1/2" 9.2# L-80 10957 -11067 Packers and SSSV (type and measured depth) 4-1/2" TIW HBBP Packer 10952 2-7/8" Otis WD Packer 11700 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8FL NOV 16 2005 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory 0 Development 0 Service ¡;;¡ Daily Report of Well Operations 16. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 WINJ ¡;;¡ WDSPl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: 301-287 Contact Joe Anders / Anna Dube Printed Name Joe Anders, P.E. Title Well Integrity Coordinator Signature r) ~ rL...A '.v7 Phone 907-659-5102 Date 11/13/2005 ~ e STATE OF ALASKA e ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED NOV 1 6 2005 mmiss Form 10-404 Revised 04/2004 Submit Original Only RE: END2-22 Cancel Waiver & Sundry pïb-:l:\- 1<Ó~-034 e e Q/JR. III \6tôš' Suh,jcct: RE: END2-22 Cancel Waiver & Sundry \ ¡q From: "~SU, ADW Wclllntcgrity Engineer" <NSUADWWcllIntegrityEnginccr@ßP.com> Date: Sun, 13 Nov 2005 19: 15:05 -0900 To: "Rossberg, R Stcven" <RossbeRS@RP.com>, "Engel, Harry R" <EngclHR@BP.com>, winton ßubcrt@admin.statc.ak.us, jim..rcgg@admin.statc.ak.us, END/BAD Arca Manager <ENDBADAreaManager@BP.com>, "END, Operations Lead Tcch" <ENDOpcrationsLcadTech@BP.com>, "McMullen, John C" <McMuIIJC@BP.com>, NSUAD WW ellOperationsSupervisor@?.BP.com CC: "Reeves, Donald F" <RcevesDf(~BP.com>, "Holt, Ryan P (VECO)" <Ryan.Holt@BP.com>, "Frazier, l\iicholas B" <fraznb@BP.com.>, "Hughes, Andrea (VECO)" <hugha4@BP.com>, "NSU, ADW Wel1 Intcgrity Engineer" <NSUADWWelllntegrityEngillccr(t:l}BP.com> Helloal!. Well END2-22 has been reclassified from Waiver to Trouble. A RWO is planned to fix the tubing leak. Lead Tech, would you please ensure any waiver related signage is removed from the wellhouse. Ryan, would you please mail a 10-404 to the AOGCC to cancel the Sundry. Please call with any questions. Joe 1-907-659-5102 WA-GI¡\¡ From: Reeves, Donald F Sent: Saturday, October 29,20057:52 PM To: NSU, ADW Well Integrity Engineer Cc: Winslow, Jack L.; Luckett, Ely Z. (VECO) Subject: END2-22 Cancel waiver & sundry 8{;ANNED DEC 1 @ 2005 Anna, Since END2-22 is planned for a RWO, I recommend we cancel the waiver and the sundry. The well is currently secured with a TIP & a SV. Thanks, Donald Reeves Well Integrity Engineer (907) 659-5525 (907) 659-5100 #1923 Pgr 1 of 1 11/15/20059:57 AM RECEIVED , STATE OF ALASKA \ ALA...Á OIL AND GAS CONSERVATION COMI'v.. j~ION OCT 1 0 Z005 REPORT OF SUNDRY WELL OPERATI0tj§ska Oil & Gas Cons. Commission 1. Operations Abandon D Repair Well D Plug Perforations D Stimulate D OtheÁticl,oftitfêcel Waiver Performed: Alter Casing D Pull Tubing D Perforate New Pool D WaiverD Time Extension O· , Change Approved Program D Operat. Shutdown D Perforate D Re-enter Suspended Well D 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 189-0340 3. Address: P.O. Box 196612 Stratigraphic Service M' 6. API Number: Anchorage, AK 99519-6612 50-029-21931-00-00 7. KB Elevation (ft): 9. Well Name and Number: 55.5 KB 8. Property Designation: ADLO-034633 11. Present Well Condition Summary: Total Depth measured 12322 true vertical 10593.2 Effective Depth measured 12236 true vertical 10519.81 Casing Conductor Surface Intermediate Production Liner Liner Length 80 2469 9375 1839 23 1324 Size 30" Drive Pipe 13-3/8" 68# L-80 9-5/8" 47# NT80S 9-5/8" 47# NT95HS 2-7/8" 6.16# L-80 7" 29# SM-11 0 Perforation depth: Measured depth: 11530 - 11553 11809 - 11828 12000 -12016 True Vertical depth: 9930.14 - 9949.1 10160.39 - 10176.17 10319.96 - 10333.42 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl o o x feet feet feet feet MD 30 - 110 29 - 2498 28 - 9403 9403 - 11242 11700 - 11723 10998 - 12322 11593 - 11680 11836 - 11905 9982.06 - 10053.72 10182.83 - 10240.37 4-1/2" 12.6# 3-1/2" 9.2# 4-1/2" TIW HBBP Packer 2-7/8" Otis WD Packer 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal Printed Name Sharmaine Vestal I Signat~ ~J Form 10-404 Revised 04/2004 10. Field/Pool(s): Endicott Field/ Endicott Pool Plugs (measured) Junk (measured) 2-22/L-14 None None ~ANNED NO\; () 8 2005 TVD 30 - 110 29 - 2497.99 28 - 8313.53 8313.53 - 9692.09 10070.22 - 10089.21 9495.24 - 10593.2 11758 - 11778 11908 - 11929 10118.14 -10134.69 10242.88 - 10260.44 L-80 L-80 Burst Collapse 4930 6870 8150 13450 11220 2270 4760 ""'"5080 13890 8510 11783 - 11790 11933 - 11986 11801 - 11805 11991 -11994 10138.83 -10144.63 10263.79 - 10308.2 10153.75 -10157.07 10312.4 - 10314.92 28 - 10957 10957 - 11067 10952 11700 RBDMS BFl 0 CT ] ]. 2005 Title Data Mgmt Engr Phone 564-4424 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 000 000 15. Well Class after croposed work: Exploratory C Development r 16. Well Status after proposed work: Oil r Gas r WAGL OR\G\~~AL Tubing pressure o o Service R GINJ r WINJ R WDSPL r Sundry Number or N/A if C.O. Exempt: 301-287 Date 9/30/2005 Submit Original Only MEMORANDUM ) ) State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg.~ ( , P.I. supervisorK¿f1 Z Z/J¡ ði; DATE: Tuesday, February 22, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 2-22/L14 DUCK IS UNIT MPI 2-22/L14 l~- 03Lf- FROM: Lou Grimaldi Petroleum Inspector Src: Inspector Reviewed By: _.~] P.I. Supr~l--- Comm Well Name: DUCK IS UNIT MPI 2-22/Ll4 Insp Num: mitLG050211073938 Rei Insp Num: NON-CONFIDENTIAL API Well Number: 50-029-21931-00-00 Permit Number: 189-034-0 Inspector Name: Lou Grimaldi Inspection Date: 2/10/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2-22/L14 Type Inj. N TVD 9459 IA 240 3380 3360 3330 3300 3270 P.T. 1890340 TypeTest SPT I Test psi 2364.75 OA 100 100 100 100 100 100 Interval REQVAR P/F I Tubing 420 3520 3490 3460 3430 3400 Notes: Combo Tubing/IA MIT. WIL plug set in tubing tail. Consistant 25-30 psi decline. Results to be determined by AOGCC engineers. UAF' "'i 1, l) r¡ jY~, SCJ\NNEC m -{.l LUWv Tuesday, February 22,2005 Page I of I MEMORANDUM ) State of Alaska ) Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ~11 Z(VI/OS DATE: Monday, February 14,2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 2-221L14 DUCK IS UNIT MPI 2-22/L14 \0<1- o7JCf FROM: Lou Grimaldi Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ,TEt--- Comm Well Name: DUCK IS UNIT MPI 2-22/Ll4 Insp Num: mitLG050212113051 Rei Insp Num: NON-CONFIDENTIAL API Well Number: 50-029-21931-00-00 Permit Number: 189-034-0 Inspector Name: Lou Grimaldi Inspection Date: 2/10/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2-22/L14 Type Inj. N TVD 9459 IA 240 3380 3360 I 3330 3300 3270 P.T. 1890340 TypeTest SPI Test psi 2364.75 OA 100 100 100 100 100 100 Interval REQVAR PIF F Tubing 420 3520 3490 3460 3430 3400 Notes: Combo MIT, .W/L plug set in tubing tail @ 11,030. IA pressire showed steady decline which never stabilized. SCANNED MAH 1 4 2005 Monday, February 14,2005 Page 1 of I MEMORANDUM ., State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ~. ZIZ4~6 DATE: Monday, February 14,2005 SUBJECT: Mechanical Integrity Tests BP EXPLORA TrON (ALASKA) INC 2-22/L14 FROM: Lou Grimaldi Petroleum Inspector DUCK IS UNIT MPI 2-22/L14 l<69 -' o3£f Src: Inspector Reviewed By: P.I. Suprv $¡'- Comm NON-CONFIDENTIAL Well Name: DUCK IS UNIT MPI 2-22/L14 Insp Num: mitLG050212125332 Rei Insp Num: API Well Number: 50-029-21931-00-00 Permit Number: 189-034-0 Inspector Name: Lou Grimaldi Inspection Date: 2/10/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I 2-22/114 Type Inj. N TVD 9459 IA 2760 3370 3350 3335 3315 3295 P.T. 11890340 TypeTest SPT Test psi 2364.75 OA 100 100 100 100 100 100 Interval REQVAR PIF F Tubing I 2870 3480 3460 3440 3405 3390 Notes: 2nd test on this well today (see mitLG050212113051). Combo MIT, W/L plug set in TT @ 11,030. IA pressure exhibits staedy decline. Bled well with no gas present prior to test. SCANNED MAR 1 4 2005 Monday, February 14, 2005 Page I of I MEMORANDUM ) State of Alaska ) Alaska Oil and Gas Conservation Commission TO: Jim Regg 'K¿d!.' [.f 2410s- P.I. Supervisor '1 ( DATE: Monday, February 14, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 2-22/L14 DUCK IS UNIT MPI 2-22/L14 o./o3l{' \CfJ - \ FROM: Lou Grimaldi Petroleum Inspector Src: Inspector Reviewed By: , -¡"fPv' P.I. Suprv './'P, Comm Well Name: DUCK IS UNIT MPI 2-22/L14 Insp Num: mitLG050212132857 ReI Insp Num: NON-CONFIDENTIAL API Well Number: 50-029-21931-00-00 Permit Number: 189-034-0 Inspector Name: Lou Grimaldi Inspection Date: 2/10/2005 Packer Well 2-22/114 Type Inj. N TVD P.T. 1890340 TypeTest SPT Test psi Depth 9459 2364.75 IA OA Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 3320 I 3270 190 3390 3240 100 100 100 100 100 Interval REQVAR PIF F Tubing 240 3460 3400 3360 3320 Notes: 3rd test today on this well (see mitLG050212113051 & mitLG050212125332), Verified wing valve integrity by depressuring flowline (OK). IA pressure bled off steadily. -NI.\.'Er"':; Ml\n 1;¡ 2DG5 SCA. ~~ .U . Mf\. .. Monday, February 14,2005 Page I of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich Commissioner THRU: FROM: Jim Regg P.I. Supervisor Lou Grimaldi Petroleum Inspector NON- CONFIDENTIAL DATE: September 13, 2003 SUBJECT: Mechanical Integrity Tests BPX Endicott, MPI 2-22, 1-69, 1-67 Duck Island Unit Endicott Field Packer Depth We,,I 2-22/L-14 I Type Inj. P.T.D.I 189-034 I Type test Notes: Combo nMIT, plug set inT.T. 10,999' 1-69N-19 I Type Inj. 190-029IType test Notes: Observed pretest conditions for 30 minutes "OK". 1-67/T-20 I Type Inj. 189-114 Type test Notes: Observed pretest conditions for 30 minutes Type INJ. Fluid Codes Type Test F = FRESH WATER INJ. M= Annulus Monitoring G = GAS INJ. P= Standard Pressure Test S = SALT WATER INJ. N = NOT INJECTING R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Pretest Initial 15 Min. 30 Min. 2-22/L-14 passed its combo MIT. 1-69/V-19 passed its 4-year MIT. Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) 1-67/T-20 IA was not topped offprior to its MIT. Filled with 41 bbl's MEOH, pressured up three times with excessive bleed-off. Decline seemed to be getting less each time. Above reults were from last attempt. DHD will invetigate and report. Number of Failures: One M.I.T.'s performed: Three Attachments: Total Time during tests' 7 hours cc: Bill Rochine (BPX Endicott) Tom Maunder (A.O.G.C.C.) MIT report form 5/12/00 L.G. , OAf NED OCT ¢. 2003 2003-0913_MIT_DIU_2-22_Ig.xls 9/15/2003 BP EXPLORATION 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 October 1,2002 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 Daily Annulus Pressure Report for 2-22/L-14 Dear Mr. Maunder: Attached in duplicate is the daily inner and outer annular pressure data for the month of September 2002 from 2-22/L-14 in the Endicott Reservoir. The enclosed data is to be forwarded to the State on a monthly basis until the leak path is eliminated. If there are any questions regarding this data, please contact me at 564-5234. Sincerely, Madelyn AJMillholland Data Manager MAM Enclosure cc: File' 76.13 RECEIVED oct o 3 2O02 Alaska Oil & Gas Oons. Anchorage ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL 2-22 Note: The DATE 9/1/2002 9/2/20O2 9/3/2002 9/4/2002 9/5/2002 9/6/2002 9/7/2002 9/8/2002 9/9/2002 9/10/2002 9/11/2002 9/12/2002 9/13/2002 9/14/2002 9/15/2002 9/16/2002 9/17/2002 9/18/2002 9/19/2002 9/20/2002 9/21/2002 9/22/2002 9/23/2002 9/24/2002 9/25/2002 9/26/2002 9/27/2002 9/28/2002 9/29/2002 9/30/2002 REPORT PER AOGCC VARIANCE Well has confirmed leak. Well can remain on injection under variance. data below must be recorded daily and sent to the AOGCC on a monthly basis. (9-5/8) psi pA (13-3/8) psI WHP (psi) Inject Rate (MBD) 2250 150 1902 15528 2250 150 1888 14868 2250 150 1906 15016 2250 150 1907 15110 2250 150 1879 14313 2250 150 1859 13962 2250 150 1939 15242 2250 150 1906 14853 2250 150 1919 15305 2250 150 1901 14759 2250 150 1877 14305 2250 150 1888 14684 2300 100 1890 14581 2300 150 1898 15003 2300 150 1910 15099 2300 150 1888 14577 2050 150 1775 12693 2200 150 1765 12810 2050 150 1682 11476 2100 150 1730 12556 2250 150 1871 14788 2250 150 1870 14656 2200 100 1840 13775 2250 200 1854 14565 2250 200 1854 14446 2250 200 1870 14768 2250 200 1838 14012 2250 200 1855 14474 2250 200 1824 13830 2250 200 1812 13659 WriT 169 170 166 167 168 165 168 168 167 164 171 162 172 168 166 158 162 175 168 150 163 174 172 173 171 167 170 170 173 173 Note ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL 2-22 Note: REPORT PER AOGCC VARIANCE Well has confirmed leak. Well can remain on injection under variance. The data below must be recorded daily and sent to the AOGCC on a monthly basis. DATE l IA (9-5/8) 9/1/2002 2250 9/2/2002 2250 9/3/2002 2250 9/4/2002 2250 9/5/2002 2250 9/6/2002 2250 9/7/2002 2250 9/8/2002 2250 9/9/2002 2250 9/10/2002 2250 9/11/2002 2250 9/12/2002 2250 9/13/2002 2300 9/14/2002 2300 9/15/2002 2300 9/16/2002 2300 9/17/2002 2050 9/18/2002 2200 9/19/2002 2050 9/20/2002 2100 9/21/2002 2250 9/22/2002 2250 9/23/2002 2200 9/24/2002 2250 9/25/2002 2250 9/26/2002 2250 9/27/2002 2250 9/28/2002 2250 9/29/2002 2250 9/30/2002 2250 psi pA (13-3/8) p~ WHP (psi) Inject Rate (MBD) WHT 150 1902 15528 169 150 1888 14868 170 150 1906 15016 166 150 1907 15110 167 150 1879 14313 168 150 1859 13962 165 150 1939 15242 168 150 1906 14853 168 150 1919 15305 167 150 1901 14759 164 150 1877 14305 171 150 1888 14684 162 100 1890 14581 172 150 1898 15003 168 150 1910 15099 166 150 1888 14577 158 150 1775 12693 162 150 1765 12810 175 150 1682 11476 168 150 1730 12556 150 150 1871 14788 163 150 1870 14656 174 100 1840 13775 172 200 1854 14565 173 200 1854 14446 171 200 1870 14768 167 200 1838 14012 170 200 1855 14474 170 200 1824 13830 173 200 1812 13659 173 Note BP EXPLORATION 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 September1,2002 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 Daily Annulus Pressure Report for 2-22/L-14 Dear Mr. Maunder: Attached in duplicate is the daily inner and outer annular pressure data for the month of August 2002 from 2-22/L-14 in the Endicott Reservoir. The enclosed data is to be forwarded to the State on a monthly basis until the leak path is eliminated. If there are any questions regarding this data, please contact me at 564-5234. Sincerely, Madelyn A. Millholland Data Manager MAM Enclosure cc: File: 76.13 ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL 2-22 Note: DATE 8/1/2002 8/2/2OO2 8/3/2002 8/4/2OO2 8/5/2002 8/6/2002 8/7/2002 8/8/2002 8/9/2002 8/10/2002 8/11/2002 8/12/2002 8/13/2002 8/14/2002 8/15/2002 8/16/2002 8/17/2002 8/18/2002 8/19/2002 8/20/2002 8/21/2002 8/22/2002 8/23/2002 8/24/2002 8/25/2002 8/26/2002 8/27/2002 8/28/2002 8/29/2002 8/30/2002 8/31/2002 REPORT PER AOGCC VARIANCE Well has confirmed leak. Well can remain on injection under variance. The data below must be recorded daily and sent to the AOGCC on a monthly basis. (9-5/8) 1750 2200 2200 2100 2200 2200 2100 2300 2300 2300 2300 2300 2300 2250 2250 2300 2300 2350 2300 2300 2300 2300 2300 2300 2300 2250 2250 2250 2250 2250 2250 psi pA (13-3/8) psI WHP (psi) Iniect Rate (MBD) WriT (F) 200 1750 13832 149 150 1839 15152 151 150 1837 15031 159 150 1825 14487 156 150 1860 15141 150 150 1855 15110 154 150 1839 14727 156 150 1884 15708 167 150 1889 15516 166 150 1891 15463 171 150 1890 15618 168 150 1902 15596 166 200 1912 15853 169 150 1880 14823 167 150 1885 14357 166 150 1894 14650 166 150 1908 14690 169 150 1917 15408 169 150 1914 15617 169 150 1910 15401 170 150 1908 15612 168 150 1910 15318 169 150 1912 15299 174 150 1900 15158 173 150 1881 14865 170 100 1874 14735 171 150 1878 15024 172 150 1876 10608 170 150 1875 7438 169 150 1864 15044 165 150 1904 15387 165 Note ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL 2-22 Note: The DATE 8/1/2002 8/2/2002 8~3/2002 8/4/2002 8~5/2002 8~6/2O02 8/7/2002 8/8/2002 8/9/2002 8/10/2002 8/11/2002 8/12/2002 8/13/2002 8/14/2002 8/15/2002 8/16/2002 8/17/2002 8/18/2002 8/19/2002 8/20/2002 8/21/2002 8/22/2002 8/23/2002 8/24/20O2 8/25/2002 8/26/2002 8/27/2002 8/28/2002 8/29/2002 8/30/2002 8/31/2002 REPORT PER AOGCC VARIANCE Well has confirmed leak. Well can remain on injection under variance. data below must be recorded daily and sent to the AOGCC on a monthly basis. (9-5/8) psi pA (13-3/8) p~ WHP (psi) Iniect Rate (MBD) 1750 200 1750 13832 2200 150 1839 15152 2200 150 1837 15031 2100 150 1825 14487 2200 150 1860 15141 2200 150 1855 15110 2100 150 1839 14727 2300 150 1884 15708 2300 150 1889 15516 2300 150 1891 15463 2300 150 1890 15618 2300 150 1902 15596 2300 200 1912 15853 2250 150 1880 14823 2250 150 1885 14357 2300 150 1894 14650 2300 150 1908 14690 2350 150 1917 15408 2300 150 1914 15617 2300 150 1910 15401 2300 150 1908 15612 2300 150 1910 15318 2300 150 1912 15299 2300 150 1900 15158 2300 150 1881 14865 2250 100 1874 14735 2250 150 1878 15024 2250 150 1876 10608 2250 150 1875 7438 2250 150 1864 15044 2250 150 1904 15387 WHT 149 151 159 156 150 154 156 167 166 171 168 166 169 167 166 166 169 169 169 170 168 169 174 173 170 171 172 170 169 165 165 Note SCANNED OCT 0,'4 2'002 BP EXPLORATION 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 August 1,2002 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 Daily Annulus Pressure Report for 2-22/L-14 Dear Mr. Maunder: Attached in duplicate is the daily inner and outer annular pressure data for the month of July 2002 from 2-22/L-14 in the Endicott Reservoir. The enclosed data is to be forwarded to the State on a monthly basis until the leak path is eliminated. If there are any questions regarding this data, please contact me at 564-5234. Sincerely, Madelyn A. rglillholland Data Manager MAM Enclosure cc: File: 76.13 SCANNED AUG ~ _1 2D0~, ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL 2-22 Note: DATE 7/1/2002 7/2/20O2 7/3/2OO2 7/4/2002 7/5/2O02 7/6/2002 7/7/2002 7/8/2002 7/9/2002 7/10/2002 7/11/2002 7/12/2002 7/13/2002 7/14/2O02 7/15/2002 7/16/2002 7/17/2002 7/18/2002 7/19/2002 7/20/2002 7/21/2002 7/22/2002 7/23/2002 7/24/2002 7/25/2002 7/26/2002 7/27/2002 7/28/2002 7/29/2002 7/30/2OO2 7/31/2002 REPORT PER AOGCC VARIANCE Well has confirmed leak. Well can remain on injection under variance. The data below must be recorded daily and sent to the AOGCC on a monthly basis. I la (9-5/8) 2250 1350 1600 1200 1200 2800 2200 2300 2300 230O 2300 2300 2300 2300 2300 2200 2300 2300 2200 2250 2250 2200 2200 2200 2150 2250 550 1700 1750 1750 psi pA (13-3/8) psI WHP (psi) Inject Rate (MBD) WHT (F) 150 1900 12537 170 150 1917 14566 173 150 1931 15952 170 150 1920 8088 171 150 1908 16320 170 150 1902 15974 171 150 1915 16251 169 150 1918 16181 171 150 1875 15040 170 150 1924 16263 173 150 1914 16058 170 150 1899 15832 173 150 1895 15741 175 150 1884 15712 172 150 1890 15855 171 150 1854 13787 172 150 1847 15051 175 150 1833 14713 168 150 1811 14267 176 150 1832 14589 168 150 1807 14148 165 150 1811 14074 165 150 1839 14699 160 150 1821 14183 166 150 1825 13686 168 150 1847 14656 167 100 1133 1419 122 100 1137 3275 130 200 1339' 4950 157 200 1560 9860 150 Note Was shut in a short period. WAS S/I FOR WELL WORK Plant S/D Plant S/D SCANNED [ ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL 2-22 Note: The DATE I IA (9-5/8) 7/1/2002 2250 7/2/2002 135O 7/3/2002 1600 7/4/2002 1200 7/5/2002 1200 7/6/2002 2800 7/7/2002 2200 7/8/2002 2300 7/9/2002 2300 7/10/2002 2300 7/11/2002 2300 7/12/2002 2300 7/13/2002 2300 7/14/2002 2300 7/15/2002 2300 7/16/2002 2200 7/17/2002 2300 7/18/2002 2300 7/19/2002 2200 7/20/2002 2250 7/21/2002 2250 7/22/2002 2200 7/23/2002 2200 7/24/2002 2200 7/25/2002 2150 7/26/2002 2250 7/27/2002 550 7/28/2002 7/29/2002 1700 7/30/2002 1750 7/31/2002 1750 REPORT PER AOGCC VARIANCE Well has confirmed leak. Well can remain on injection under variance. data below must be recorded daily and sent to the AOGCC on a monthly basis. psi pA (13-3/8) ps~ WHP (psi) Inject Rate (MBD) WHT (F) 150 1900 12537 170 150 1917 14566 173 150 1931 15952 170 150 1920 8088 171 150 1908 16320 170 150 1902 15974 171 150 1915 16251 169 150 1918 16181 171 150 1875 15040 170 150 1924 16263 173 150 1914 16058 170 150 1899 15832 173 150 1895 15741 175 150 1884 15712 172 150 1890 15855 171 150 1854 13787 172 150 1847 15051 175 150 1833 14713 168 150 1811 14267 176 150 1832 14589 168 150 1807 14148 165 150 1811 14074 165 150 1839 14699 160 150 1821 14183 166 150 1825 13686 168 150 1847 14656 167 100 1133 1419 122 100 1137 3275 130 200 1339 4950 157 200 1560 9860 150 Note Was shut in a short period. WAS S/I FOR WELL WORK Plant S/D Plant S/D STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X ADD PERFS Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 1919' FNL, 2223' FEL, Sec. 36, T12N, R16E, UM At top of productive interval 2615' FNL, 3381' FEL, Sec. 25, T12N, R16E At effective depth 2557' FNL, 3384' FEL, Sec. 25, T12N, R16E, UM At total depth 2222' FNL, 3386' FEL, Sec. 25, T12N, R16E, UM 5. Type of Well: Development _ Exploratory_ Stratigraphic__ Service__X (asp's 258984, 5982498) (asp's 257973, 5987116) (asp's 257972, 5987175) (asp's 257980, 5987509) 6. Datum elevation (DF or KB feet) RKB 56 feet 7. Unit or Property name Duck Island Unit / Endicott 8. Well number .,, 02-22 / L-14 9. Permit number / approval number 189-034 / 302-166 10. APl number 50-029-21931 11. Field / Pool Endicott Field / Endicott Pool 12. Present well condition summary Total depth: measured true vertical 12322 feet Plugs (measured) 10593 feet Tagged TD @ 11704' (07/01/2002) Effective depth: measured true vertical 11704 feet Junk (measured) 10074 feet Casing Length Conductor 72' Surface 2460' Intermediate 11204' Liner 1324' Size Cemented Measured Depth True Vertical Depth 30" Driven 110' 110' 13-3/8" 3423 c.f. Permafrost 2498' 2498' 9-5/8" 575 c.f. Class 'G' 11242' 9692' 7" 428 c.f. Class 'G' 10998' - 12322' 9495' - 10593' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) Open Perf 11530'-11553', 11593'-11643', 11663'-11680', Covered with Fill 11758'-11778', 11783'-11790', 11801'-11805', 11809'-11828', 11836'-11905', 11908'-11929', 11933'-11986', 11991 '-11994', 12000'-12016' Open Perfs 9930'-9949', 9982'-10023', 10040'-10054', Covered with Fill 10118'-10134', 10138'-10144', 10154'-10158', 10161'-10176', 10182'-10240', 10242'-10260', 10263'-10308', 10312'-10314', 10319'-10334'. 4-1/2", 12.6#, L-80 TBG @ 10952' w/3-1/2", 9.2 ppf, L-80 Tubing tail to 11067'. 9-5/8" x 4-1/2" TIW HBBP PKR @ 10952'. 4-1/2" SSSVLN ~.,~p~,.;.. ,: ...... , ,,; , 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 07/03/2002 Subsequent to operation 07/06/2002 OiI-Bbl Representative Daily Averaqe Production or Iniection Data Gas-Mcr Water-Bbl Casing Pressure 15249 15770 Tubing Pressure 1931 1902 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations _ 16. Status of well classification as: Oil _ Gas _ Suspended _ Service WATER INJECTOR 17. I hereby certify that the foregoing is_.tru~and correct to the best of my knowledge. ,~~~~.~ ~~~ Title: Techical Assistant DeWayne R. Schnorr ~ Date Julv 17, 2002 Prepared by DeWar/ne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · 8CANNEP JUL 3 ;[ 2002 SUBMIT IN DUPLICATE 2-22 / L-14 Description of Work Completed NRWO OPERATIONS 06/23/2002 ANN-COMM (WAIVER COMPLIANCE)' MIT-IA 07/01/2002 PERFOI:~,TING: DRIFT/TAG; SSSV C/O OR STROKE 07/04/2002 PERFORATING: INJECTION PROFILE SUMMARY 06/23/02 ANNUAL LEAK RATE TEST FROM IA TO TUBING AS PER AOGCC VARIANCE. IA LEAKS TO TUBING AT A RATE OF 1 BPM @ 400 PSI OVERPRESSURE. AOGCC INSPECTOR JOHN CRISP WITNESSED THE TEST. 07/01/02 PULL MCX ISSSV (SER # NM-19) @ 1519' SLM. DRIFT TBG W/2.5" DG(13' LONG BAILER) & TEL.. LOCATE TTL @ 10,043' SLM + 24' = 10,067' CORR MD. TAG BOTTOM @ 11,680' SLM + 24' = 11,704' CORR MD. NO SAMPLE. RDMO. GIVE O7/O4/O2 PERF 11530-11553' 11593-11643 11663-11680' WITH 4 GUN RUNS. FIRST GUNS FIRED WHILE INJECTING 5000 BWPD. Fluids Pumped 1 PRESSURE TEST LUBRICATOR TO 3000 PSI W/1 BBL OF DIESEL. 10 60/40 METHANOL WATER 11 TOTAL Page 1 $C;/; NED JUL 2002 BP EXPLORATION 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 July 1,2002 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 Daily Annulus Pressure Report for 2-22/L-14 Dear Mr. Maunder: Attached in duplicate is the daily inner and outer annular pressure data for the month of June 2002 from 2-22/L-14 in the Endicott Reservoir. The enclosed data is to be forwarded to the State on a monthly basis until the leak path is eliminated. If there are any questions regarding this data, please contact me at 564-5234. Sincerely, Madelyn A. Millholland Data Manager MAM Enclosure cc: File: 76.13 RECEIVED JUL 2 2002 Anchorage BCANNED JUL 1 0 2007 i" ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL 2-22 Note: DATE 6/1/2002 6/2/2OO2 6/3/20O2 6/4/2OO2 6/5/2O02 6/6/2O02 6/7/2002 6/8/2002 6/9/2002 6/10/2002 6/11/2002 6/12/2002 6/13/2002 6/14/2002 6/15/2002 6/16/2002 6/17/2002 6/18/2002 6/19/2002 6/20/2002 6/21/2002 6/22/2002 6/23/2002 6/24/2002 6/25/2002 6/26/2002 6/27/2002 6/28/2002 6/29/2002 6/30/2002 REPORT PER AOGCC VARIANCE Well has confirmed leak. Well can remain on injection under variance. The data below must be recorded daily and sent to the AOGCC on a monthly basis. (9-5/8) psi ~A (13-3/8) p~ WHP (psi) I Inject Rate (MBD) I WHT (F) I 2300 150 1916 15522 171 2400 150 1928 15927 172 2400 150 1918 15801 170 2400 150 . 1912 15800 171 2400 150 1918 15838 172 2400 150 1905 13519 173 2400 150 1880 14974 177 2400 150 1896 15571 175 2400 150 1888 15456 177 2350 150 1909 15831 175 2350 150 1908 15556 174 2350 150 1888 15299 175 2350 150 1886 15024 176 2400 200 1927 15687 174 2350 150 1936 15642 177 2350 150 1897 15138 175 2350 150 1794 12237 164 2400 150 1934 15816 175 2100 150 1897 15108 172 2350 150 1915 15187 174 2350 150 1917 15291 174 2350 150 1911 15183 170 2350 150 1925 15549 170 2350 150 1933 15739 173 2250 0 1885 14728 174 2350 150 1895 15185 172 2250 150 1933 15831 167 2350 150 1933 15873 167 2350 150 1937 15930 169 2250 150 1887 14911 172 Note ~ -.--~..~.,--.. SCANNED JUL :[ 0 201 2 ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL 2-22 Note: DATE 6/1/2002 6/2/2OO2 6/3/2002 6/4/2002 6/5/2OO2 6/6/2002 6/7/2O02 6/8/2002 6/9/2002 6/10/2002 6/11/2002 6/12/2002 6/13/2O02 6/14/2002 6/15/2002 6/16/2002 6/17/2002 6/18/20O2 6/19/2002 6/20/2002 6/21/2002 6/22/20O2 6/23/20O2 6/24/2002 6/25/2002 6/26/20O2 6/27/2002 6/28/2002 6/29/2O02 6/30/20O2 REPORT PER AOGCC VARIANCE Well has confirmed leak. Well can remain on injection under variance. The data below must be recorded daily and sent to the AOGCC on a monthly basis. l IA (9-5/8) psi ~A (13-3/8) p~ WHP (psi) I Inject Rate (MBD) I WHT (F) I 2300 150 1916 15522 171 2400 150 1928 15927 172 2400 150 1918 15801 170 2400 150 . 1912 15800 171 2400 150 1918 15838 172 2400 150 1905 13519 173 2400 150 1880 14974 177 2400 150 1896 15571 175 2400 150 1888 15456 177 2350 150 1909 15831 175 2350 150 1908 15556 174 2350 150 1888 15299 175 2350 150 1886 15024 176 2400 200 1927 15687 174 2350 150 1936 15642 177 2350 150 1897 15138 175 2350 150 1794 12237 164 2400 150 1934 15816 175 2100 150 1897 15108 172 2350 150 1915 15187 174 2350 150 1917 15291 174 2350 150 1911 15183 170 2350 150 1925 15549 170 2350 150 1933 15739 173 2250 0 1885 14728 174 2350 150 1895 15185 172 2250 150 1933 15831 167 2350 150 1933 15873 167 2350 150 1937 15930 169 2250 150 1887 14911 172 Note ,SCANNED JUL BP EXPLORATION 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 June 3, 2002 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 Daily Annulus Pressure Report for 2-22/L-14 Dear Mr. Maunder: Attached in duplicate is the daily inner and outer annular pressure data for the month of May 2002 from 2-22/L-14 in the Endicott Reservoir. The enclosed data is to be forwarded to the State on a monthly basis until the leak path is eliminated. If there are any questions regarding this data, please contact me at 564-5234. Sincerely, Madelyn A. Milt~olland Data Manager MAM Enclosure cc: File: 76.13 RECEIVED JUH 0 4 £002 Nask~ 0il & Gas Cons. Comm~SS~O~ Anchorage SCANNED JUN 2,,¢,,,2002 . ANNULUS PRESSURE REPORT FOR ENDICO'I-r WATER INJECTION WELL 2-22 Note: REPORT PER AOGCC VARIANCE Well has confirmed leak. Well can remain on injection under variance. The data below must be recorded daily and sent to the AOGCC on a monthly basis. DATE 5/1/2002 5/2/2002 5/3/20O2 5/4/2002 5/5/2002 5/6/2002 5/7/2002 5/8/2002 5/9/2002 5/10/2002 5/11/2002 5/12/2002 5/13/2002 5/14/2002 5/15/2002 5/16/2002 5/17/2002 5/18/2002 5/19/2002 5/20/2002 5/21/2002 5/22/2002 5/23/2002 5/24/2002 5/25/2002 5/26/2002 5/27/2002 5/28/2002 5/29/2002 5/30/2002 5/31/2002 IA (9-5/8) psi OA {13-3/8) psi WHP (psi) Inject Rate (MBD) WHT (F) Note 2400 150 1968 15948 168 2350 150 1970 15789 166 2400 150 1989 16263 165 2400 150 1984 16280 168 2400 150 1976 16295 167 2400 200 1947 15647 170 2350 150 1926 15120 172 2350 150 1921 15019 172 2350 150 1922 15173 170 2350 150 1949 15390 172 2350 150 1940 15207 173 2400 150 1920 14894 173 2350 150 1920 14892 174 2400 150 1945 15426 172 2400 150 1954 16004 172 2400 150 1941 15542 170 2400 150 1919 15030 170 2400 150 1923 15423 170 2400 150 1924 15442 169 2400 150 1938 15581 168 2400 150 1931 15880 171 2400 150 1931 15859 171 2400 150 1929 15811 175 2400 150 1918 15002 176 2400 150 1937 15468 171 2400 150 1947 15726 166 2400 150 1936 15679 167 2400 150 1946 15986 170 2400 150 1926 15665 172 2350 150 1935 15895 172 2350 150 1931 15734 173 SCANNED JUN Note: ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL 2-22/ REPORT PER AOGCC VARIANCE Well has confirmed leak. Well can remain on injection under variance. The data below must be recorded daily and sent to the AOGCC on a monthly basis. DATE 4/1/2002 4/2/2002 4/3/2002 4/4/2OO2 4/5/2OO2 4/6/2002 4/7/2002 4/8/2002 4/9/2002 4/10/2002 4/11/2002 4/12/2002 4/13/2002 4/14/2002 4/15/2002 4/16/2002 4/17/2002 4/18/2002 4/19/2002 4/20/2002 4/21/2002 4/22/2002 4/23/2002 4/24/2002 4/25/2002 4/26/2002 4/27/2002 4/28/2002 4/29/2002 4/30/2002 IA (9-5/8) psi OA (13-3/8) psi WHP (psi) Inject Rate (MBD) WHT 2450 150 2013 16619 169 2450 150 2020 16516 170 2400 150 2022 16642 168 2450 150 2025 16806 165 2400 150 2023 16458 169 2400 150 2055 16200 164 2450 150 2024 16231 167 2400 150 2017 16531 167 2450 150 2028 16466 165 2450 150 2012 16561 164 2400 150 2038 16932 162 2400 150 2011 16515 163 1700 150 1404 6201 173 1900 150 1377 6254 177 2000 150 1543 9719 169 2000 150 1699 12368 161 2400 150 1993 17007 161 2400 150 1970 16322 163 2400 150 1989 16839 162 2400 150 1994 17129 162 2400 150 1983 16935 164 2400 150 1982 16838 162 2400 150 1995 16990 162 2400 150 1981 16526 166 2400 150 1968 16040 170 2400 150 1917 14903 173 2400 150 1923 14332 173 2400 150 1967 15750 168 2400 150 1972 16181 167 2400 150 1965 15828 170 Note SCANNED 2 8 2002_ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: ADD PEFIFS Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Vadan~:e _ Perforate _X Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 4. Location of well at surface 1919' FNL, 2223' FEL, Sec. 36, T12N, R16E, UM At top of productive interval 2615' FNL, 3381' FEL, SEC 25, T12N, R16E, UM At effective depth 2355' FNL, 3387' FEL, Sec. 25, T12N, R16E, UM At total depth 2222' FNL, 3386' FEL, Sec 25 T12N, R16E, UM 5. Type of Well: Development _ Exploratory __ Stratigraphic _ Service__X (asp's 258984,5982498) (asp's 257973, 5987116) (asp's 257975, 5987376) (asp's 257980, 5987509) 6. Datum elevation (DF or KB feet) RKB 56.0 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-22 / L-14 9. Permit number / approval number 189-034 10. APl number 50-029-21931-00 11. Field / Pool Endicott Field / Endicott Pool 12. Present well condition summary Total depth: measured true vertical 12322 feet Plugs (measured) 10593 feet Effective depth: measured true vertical Casing Length Conductor 72' Surface 2460' Intermediate 11204' Liner 1324' Perforation depth: Tubing (size, grade, and measured depth 12070 feet Junk (measured) 10379 feet Size Cemented Measured Depth True vertical Depth 30" Driven 110' 110' 13-3/8" 3423 cf Permafrost 2498' 2498' 9-5/8" 575 cf Class 'G' 11242' 9692' 7" 428 cf Class 'G' 10998' - 12322' 9495' - 10593' measured Open Perfs 11600'-11601 ', 11758'-11778', 11783'-11790', 11801 '-11805', 11809'-11828', 11836'-11905', 11908'-11929', 11933'-11986', 11991 '-11994', 12000'-12016' true vertical Open Perfs 9988'-9989', 10118'-10134', 10138'-10144', 10154'-10158', 10161'-10176', 10182'-10240', 10242'-10260', 10263'-10308', 10312'-10314', 10319'-10334'. 4-1/2", 12.6 ppf, L-80 TBG to 10952' w/3-1/2", 9.2 ppf, L-80 Tubing tail to 11067'. Packers & SSSV (type & measured depth) 9-5/8" x 4-1/2" TIW HBBP Packer @ 10952'. 4-1/2" SSSVLN @ 1553' 13. Attachments Description summary of proposal _X Detailed operations program _ BOP sketch _ 15. Status of well classification as: 14. Estimated date for commencing operation June 3, 2002 16. If proposal was verbally approved Name of approver Date approved Oil _ Gas _ Service WATER INJECTOR Suspended __ 17. I hereby ce,~t~that the foregoing is true and correct to the best of my knowledge. SignedDan R Title: Endicott Sr. Petroleum Engineer FOR COMMISSION USE ONLY Questions? Call Dan Robertson @ 564-5546. Date ~'//")/~ Z- Prepared by DeWayne R, Schnorr 564-5174 Conditions of approval: Notify Commission so representative may witness I Approval n~.~,~ Plug integrity_ BOP Test_ Location clearance_ ~--" Mechanical Integrity Test_ Subsequent form required 10- Approved by order of the Commission Cat1111~ Oec~i '~[,ayl~ ~''" ;i ,..~, Commissioner Date ~,~,,~/~.~---- ORIGINAL Form 10-403 Rev 06/15/88 · SCANNED MAY 2, 8 2002 SUBMIT IN TRIPLICATE BP Exploration (Alaska) Inc. Post Office Box 196612 900 East Benson Blvd Anchorage, Alaska 99519-6612 bp May 17, 2002 Mr. Tom Maunder, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: Endicott Well 2-22/L-14 Application for Sundry Approval Dear Mr. Maunder: Attached is an Application for Sundry Approval form 10-403 for Endicott water injec,.q, tion well 2-22/L-14. This request is for approval to add perforations in additional zones to provide pressure support to an offset producer which is currently receiving inadequate pressure support. Background information, a summary procedure, and wellbore schematic are attached. If you require any additional information or clarification, please contact Dan Robertson at 564-5546 or Jim Ambrose at 564-4375. Sincerely, Dan Robertson, P.E. Sr. Petroleum Engineer Attachments SCANNED' MAY ?~ 8 ~.O0~. 2-22/L-14 Additional Perforation Pro.qram Synopsis Objective The proposed add perforations in water injector 2-22/L-14 are intended to support the Fiv, Fiii, and Fii subzones in the offset producer well 2-20/L-15 in the Niakuk fault block. Pressure data indicates that the 2-20/L-15 bottomhole location is currently not receiving adequate injection support. Waterflood support from 2-22/L-14 should increase recovery from the upper subzone intervals. Background Information As part of the Niakuk fault block development, injector 2-24/M-12 was added in 1995. It was perforated in conformance with producers 2-20/L-15 and 2-26/N-14 with the intention of providing waterflood support. Unfortunately there is, at best, only limited pressure communication between the 2-24/M-12 and 2-20/L-15 locations. Fault isolation of the upper subzone sands between 2-24/M-12 and 2-20/L-15 wells is likely responsible for the pressure isolation. The seismic data indicates a N-S trending fault between the 2-26/N-14 and 2-20/L-15. This fault also separates 2-20/L-15 from the injector 2-24/M-12. Reservoir pressure data also supports the fault isolation theory. The most recent reservoir pressure in 2-20/L-15 was 2076 psia at datum measured on January 11, 2002. Reservoir pressure at the 2-24/M-12 injection well location, extrapolated from its shut in wellhead pressure, indicates a reservoir pressure on the order of 5500-6000 psi, significantly higher than observed at the 2-20/L-15 producer bottomhole location. Fii, Fiii, and Fir sand development in injection well 2-22/L-14 affords the best option for providing injection support to the 2-20/L-15 location. The other existing injection well in the Niakuk fault block, 2-16/M-16, has poor sand development in the Fii, Fiii, and Fir subzones and likely would not provide adequate injection support to the 2-20/L-15 location. Injector 2-22/L-14 was a 3A/Fi MI WAG injector until it developed tubing by inner annulus communication in 2001 preventing it from being placed back on MI injection. A rig workover to replace the tubing is necessary to return the well to MI injection as several unsuccessful attempts were made to install a tubing patch. Efforts are ongoing to determine the incremental EOR benefits associated with a rig workover to return 2- 22/L-14 to a 3A/Fi MI injector (relative to other potential locations for MI injection). If a rig workover is justified on well 2-22/L-14to enable MI injection, there is the option to isolate the proposed additional perforations from the current 3A/Fi perforation, either mechanically or with a cement squeeze. Well 2-20/L-15 was last tested 5/7/02 at 188 bopd, 65% watercut, 5520 GOR. Reservoir Risks SCANNED MAY 2 8 2002 Interwell sand connectivity is always a concern in the upper subzone. There is a small risk that all the Fii, Fiii, Fiv sands present in the 2-22/L-14 well are not connected with the sands in 2-20/L-15. This would reduce the benefits associated with the add perforations. There is a significant permeability contrast between the 3A and the proposed add perforations in the Fii, Fiii, and Fiv subzones. The existing 27 ft of Fi perforations take 7% of the total injection based on the last injection profile run on 10/11/99. Low injection rates into the add perforation intervals would reduce the magnitude and timing of the benefits observed in 2-20/L-14. Summary Procedure 1. RIH with slickline, pull SSSV, and drift with 2" dummy gun. 2. RIH w/GR/CCL/perf gun. 3. Perforate the following interval (ref. Halliburton DLL 4/12/89): Zone Top Bottom Lenqth Gun Type Shot Density Fiv 11530' 11553' 23' 2" PowerJet 6 s.p.f. Fiii 11593' 11643' 50' 2" PowerJet 6 s.p.f. Fii 11663' 11680' 17' 2" PowerJet 6 s.p.f. Phasinq Orientation 60° random 60° random 60-0 random 4. Place well back on injection and monitor for injection performance change. 5. Re-run SSSV. SCANNED MAY ~ TREE: 4-1/16" / 5000 psi/~' ron / Axelson Actuator R.T. ELEV 55.5' WELLHEAD: 13-5/8" / 5000, / FMC (CCL) B.F. ELEV = 17.14' ~ ...... MAX. DEV. = 44:26 10200' MD OTIS (3.813" I.D.) 13-3/8", 68#/ft, L-80, Btrs Csg ~I W/SSSV IN MIN. I.D. 2" I 2498' I r ~ ~ 4-1/2", 12.6#/ft, L-80, TDS GLM's (Camco), (1-1/2" RK Latch) . No. TVDSS MD-BKB #6 4082' 4169' 9-5/8", 47#/ft ,.----..-- #5 6276' .6914' ... NT80S XO to NT95HS ] ~- -- #4 771.ci' 9,71{3, I J+ct R~I_~~ QQI~~ 9403' f -- - '--'--'--' ! #2: 9193' 10674' #1 9299' 10815' SLIDING SLEEVE .......- (3.813" I.D.) (5,438" O.D.) i 9-5/8" PACKER ~ ~ 3-1/2", 9.2#/ft L-80, TAILPIPE f - -- PARKER (2.750" I.D.) 10999' 9-5/8", 47#/ft, NT95HS, NSCC rI '~.--3-1/2" 'SWN' NIPPLEI 1067' I PERFORATING SUMMARY Ref. Log: DLL-GR (4-12-89) SIZE SPF INTERVAL STATUS ~ MARKER I 11352' 2 1/8' 2 11600'~ 11601' Open 5" 4 11758' - 11778' Open 11700' 11783' - 11790' Qpen 11801'- 11805' Open 11809' - 11828' Open 11836' - 11905' Open 11723' 11908' - 11929' Open 11933' - 11986' Open 11991' - 11994' Open 12000' - 12016' Open I .... 7", 29#/ft, SM-110, I ~ Btrs-TKCI 12322' ~ IIII II IIIII IIIIIIII :Date By Comments ENDICOTT WELL: 2-22 / L-14 03/09/89 FH PROPOSED APl NO, 50'029'2193100 05/25/89 JLH INITIAL COMPLETION COMPLETION :DIAGRAM 1/22/92 JLH New PBTD & Add Perf 3/22/96 JTP CTU FCC BP EXPLORATION '------"' '(ALASKA), INC #6 4082' 4169' #5 6276' .6914' ... #4 771R' R71h' ~q R~~ QQI~~ #2: 9193' 10674' #1 9299' 10815' N N Z BP EXPLORATION 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 March 4, 2002 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 Daily Annulus Pressure Report for 2-22/L-14 Dear Mr. Maunder: Attached in duplicate is the daily inner and outer annular pressure data for the month of February 2002 from 2-22/L-14 in the Endicott Reservoir. The enclosed data is to be forwarded to the State on a monthly basis until the leak path is eliminated. If there are any questions regarding this data, please contact me at 564-5234. Sincerely, ~J Madelyn/~. Millholland Data Manager MAM Enclosure cc: File: 76.13 Alasl~a 0il & Gas Cons. C0mmissio~ ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL 2-22 Note: REPORT PER AOGCC VARIANCE Well has confirmed leak. Well can remain on injection under variance. The data below must be recorded daily and sent to the AOGCC on a monthly basis. DATE 2/1/2002 2/2/2OO2 2/3/2002 2/4/2O02 2/5/2002 2/6/20O2 2/7/2002 2/8/2002 2/9/2002 2/10/2002 2/11/2002 2/12/2002 2/13/2002 2/14/2002 2/15/2002 2/16/2002 2/17/2002 2/18/2002 2/19/2002 2/20/2002 2/21/2002 2/22/2002 2/23/2002 2/24/2002 2/25/2002 2/26/2002 2/27/2002 2/28/2002 IA (9-5/8) psi OA (13-3/8) psi WHP (psi) Inject Rate (MBD) WHT 2400 250 1982 16965 162 2400 250 1926 16366 164 2400 250 1984 16894 162 2400 250 1852 14689 165 2400 250 1871 15666 154 2350 150 1949 16865 156 2350 150 1967 17161 157 2350 150 1983 13344 157 2400 0 1993 17504 162 2350 150 1994 17352 161 2350 150 1994 17352 161 2400 150 1985 17137 163 2300 150 1998 17253 164 2300 150 2022 17559 166 2300 150 2000 17076 169 2300 150 1985 16867 168 2300 150 1996 17251 167 2400 150 1983 16727 161 2400 100 1999 17191 167 2400 200 2059 18142 168 2400 200 2045 17884 166 2100 200 1699 12621 168 2500 200 2036 17686 163 2500 200 2050 17636 164 2500 200 2060 17628 163 2500 150 2049 17314 167 2500 150 2042 17345 168 2500 150 2053 17736 166 Note BP EXPLORATION 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 May 1, 2002 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 Daily Annulus Pressure Report for 2-22/L-14 Dear Mr. Maunder: Attached in duplicate is the daily inner and outer annular pressure data for the month of April 2002 from 2-22/L-14 in the Endicott Reservoir. The enclosed data is to be forwarded to the State on a monthly basis until the leak path is eliminated. If there are any questions regarding this data, please contact me at 564-5234. Sincerely, Data Manager MAM Enclosure cc: File: 76.13 R E C i:E I'V E D ,SCANNED JUL 1 9 2002 ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL 2-22 Note: REPORT PER AOGCC VARIANCE Well has confirmed leak. Well can remain on injection under variance. The data below must be recorded daily and sent to the AOGCC on a monthly basis. DATE 4/1/2002 4/2/2002 4/3/2002 4/4/2OO2 4/5/2002 4/6/2002 4/7/2002 4/8/2002 4/9/2002 4/10/2002 4/11/2002 4/12/2002 4/13/2002 4/14/2002 4/15/2002 4/16/2002 4/17/2002 4/18/2002 4/19/2002 4/20/2002 4/21/2002 4/22/2002 4/23/2002 4/24/2002 4/25/2002 4/26/2002 4/27/2002 4/28/2002 4/29/2002 4/30/2002 IA (9-5/8) psi OA (13-3/8) psi WHP (psi) Inject Rate (MBD) WriT 2450 150 2013 16619 169 2450 150 2020 16516 170 2400 150 2022 16642 168 2450 150 2025 16806 165 2400 150 2023 16458 169 2400 150 2055 16200 164 2450 150 2024 16231 167 2400 150 2017 16531 167 2450 150 2028 16466 165 2450 150 2012 16561 164 2400 150 2038 16932 162 2400 150 2011 16515 163 1700 150 1404 6201 173 1900 150 1377 6254 177 2000 150 1543 9719 169 2000 150 1699 12368 161 2400 150 1993 17007 161 2400 150 1970 16322 163 2400 150 1989 16839 162 2400 150 1994 17129 162 2400 150 1983 16935 164 2400 150 1982 16838 162 2400 150 1995 16990 162 2400 150 1981 16526 166 2400 150 1968 16040 170 2400 150 1917 14903 173 2400 150 1923 14332 173 2400 150 1967 15750 168 2400 150 1972 16181 167 2400 150 1965 15828 170 Note SCANNED JUL 3. 9 2t)02 BP EXPLORATION 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 February 4, 2002 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 Daily Annulus Pressure Report for 2-22/L-14 Dear Mr. Maunder: Attached in duplicate is the daily inner and outer annular pressure data for the month of January 2002 from 2-22/L-14 in the Endicott Reservoir. The enclosed data is to be forwarded to the State on a monthly basis until the leak path is eliminated. If there are any questions regarding this data, please contact me at 564-5234. Sincerely, Madelyn A. Millholland Data Manager MAM Enclosure cc: File: 76.13 RECEIVED FEB O 8 ?0(];~ Alaska Oil & Gas Coos. Cormissio~ Anchorage ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL 2-22 Note: REPORT PER AOGCC VARIANCE Well has confirmed leak. Well can remain on injection under variance. The data below must be recorded daily and sent to the AOGCC on a monthly basis. DATE 1/1/2002 1/2/2002 1/3/2002 1/4/2002 1/5/2002 1/6/2002 1/7/2002 1/8/2002 1/9/2002 1/10/2002 1/11/2002 1/12/2002 1/13/2002 1/14/2002 1/15/2002 1/16/2002 1/17/2002 1/18/2002 1/19/2002 1/20/2002 1/21/2002 1/22/2002 1/23/2002 1/24/2002 1/25/2002 1/26/2002 1/27/2002 1/28/2002 1/29/2002 1/30/2002 1/31/2002 IA (9-5/8) psi OA (13-3/8) psi WHP (psi) Inject Rate (MBD) WHT (F) 2400 200 1988 17265 157 2300 150 1991 17375 156 1987 17458 156 2300 150 1984 17389 155 2400 200 2017 18007 159 2300 200 1864 15766 157 2400 200 2026 18115 162 2400 200 2030 17770 163 2400 200 1998 17350 156 2400 200 2002 17257 166 2400 200 2007 17570 163 2500 200 2021 17476 164 2400 150 1899 15068 149 2500 200 1998 17052 162 2350 200 1996 17011 161 2350 150 1963 16628 160 2340 260 1920 16077 158 2350 200 1921 16374 155 2350 150 1931 16802 155 2350 150 1937 17228 156 2350 150 1312 5864 141 2350 150 1868 16208 161 2350 150 1952 17346 163 2300 150 1934 17010 161 2300 150 1955 17257 158 1900 150 1891 16211 158 1900 150 1899 16126 158 2200 150 1897 16202 157 2200 150 1915 16543 160 2200 150 1974 17045 160 2200 150 1975 16697 164 Note BP EXPLORATION 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 December 3, 2001 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 Daily Annulus Pressure Report for 2-22/L-14 Dear Mr. Maunder: Attached in duplicate is the daily inner and outer annular pressure data for the month of November 2001 from 2-22/L-14 in the Endicott Reservoir. The enclosed data is to be forwarded to the State on a monthly basis until the leak path is eliminated. If there are any questions regarding this data, please contact me at 564-5234. Sincerely, Madelyn A. Millholland Data Manager MAM Enclosure cc: File: 76.13 RECEIVED E}EC O 6 200t Alaska Oil & Gas Cons. Commissio~ A~chor~ e Note: ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL 2-22 REPORT PER AOGCC VARIANCE Well has confirmed leak. Well can remain on injection under variance. The data below must be recorded daily and sent to the AOGCC on a monthly basis. DATE 11/1/2001 11/2/2001 11/3/2001 11/4/2001 11/5/2001 11/6/2001 11/7/2001 11/8/2001 11/9/2001 11/10/2001 11/11/2001 11/12/2001 11/13/2001 11/14/2001 11/15/2001 11/16/2001 11/17/2001 11/18/2001 11/19/2001 11/20/2001 11/21/2001 11/22/2001 11/23/2001 11/24/2001 11/25/2001 11/26/2001 11/27/2001 11/28/2001 11/29/2001 11/30/2001 IA (9-5/8) psi OA (13-3/8) psi WHP (psi) Inject Rate (MBD) WHT (F) 2350 175 1938 17712 155 1000 150 1917 6420 156 2250 150 1869 17072 160 2200 200 1826 16888 162 2100 200 1855 17275 161 2200 200 1909 17698 155 2250 150 1922 17813 154 2300 150 1951 18425 156 2300 150 1961 18488 159 2300 100 1951 18425 156 2300 100 1922 17117 164 2300 200 1956 17449 160 2350 200 1968 17526 165 2350 200 1958 17143 164 2350 200 1965 17491 160 2350 100 1966 17515 156 2350 100 1963 17402 153 2350 100 1955 17314 153 2350 100 1951 17453 154 2350 100 1949 17004 158 2350 200 1970 17065 162 2350 200 1965 17392 154 2350 150 1959 17384 153 2350 150 1933 16988 159 2350 150 1934 16781 164 2300 200 1941 16712 164 2300 150 1931 16761 153 2300 150 1952 16986 156 2350 150 1956 16954 158 2300 150 1690 12355 152 Note 2-22/L-14 Annulus Pressure Report 20000 , 2500 18000 16000 2000 14000 12000 10000 15oo F-i _.~_ OA (13_3/8) psi ~ i--'~~- IA (9-5/8) psi 8000 i 1000 E WHP (psi) , '~WHT (F) 6000 , 4000 ~ 500 2000, i 12/3/2001 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WI=LL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ CONVERSION H20 to MI INJECT Pull tubing _ Alter casing _ Repair well _ Other_X CONVERSION 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 4. Location of well at surface 1919' FNL, 2223' FEL, Sec. 36, T12N, R16E, UM At top of productive interval 2615' FNL, 3381' FEL, Sec. 25, T12N, R16E At effective depth 2355' FNL, 3387' FEL, Sec. 25, T12N, R16E, UM At total depth 2222' FNL, 3386' FEL, Sec. 25, T12N, R16E, UM 12. Present well condition summary 5. Type of Well: Development _ Exploratory__ Stratigraphic__ Service__X (asp's 258984, 5982498) (asp's 257973, 5987116) (asp's 257975, 5987376) (asp's 257980, 5987509) 6. Datum elevation (DF or KB feet) RKB 56 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 02-22 / L-14 9. Permit number / approval number 189-034 10. APl number 50-029-21931 11. Field / Pool Endicott Field / Endicatt.P_oQL I Total depth: measured 12322 feet Plugs (measured) true vertical 10593 feet Effective depth: measured 12070 feet Junk (measured) true vertical 10379 feet Casing Length Size Cemented Measured Depth Conductor 72' 30" Driven 110' Surface 2460' 13-3/8" 3423 c.f. Permafrost 2498' Intermediate 11204' 9-5/8" 575 c.f. Class 'G' 11242' Liner 1324' 7" 428 c.f. Class 'G' 10998' - 12322' A~al~ 011 & (~es C0~s. Commissi0~, Anchorage True Vertical Depth 110' 2498' 9692' 9495' - 10593' Perforation depth: measured Open Perf 11600'-11601 ', 11758'-11778', 11783'-11790', 11801 '-11805', 11809'-11828', 11836'-11905', 11908'-11929', 11933'-11986', 11991 '-11994', 12000'-12016' true vertical Open Perfs 9988'-9989', 10118'-10134', 10138'-10144', 10154'-10158', 10161'-10176' 10182'-10240', 10242'-10260', 10263'-10308', 10312'-10314', 10319'-10334'. Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 TBG @ 10952' w/3-1/2", 9.2 ppf, L-80 Tubing tail to 11067'. Packers & SSSV (type & measured depth) 9-5/8" x 4-1/2" TIW HBBP PKR @ 10952'. 4-1/2" SSSVLN @ 1553'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 02/28/1999 Subsequent to operation 03/01/1999 Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Well Shut-in. 1450 Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations _ 16. Status of well classification as: Oil __ Gas _ Suspended _ Converted 3/1/1999 Service Conversion H20 to MI 17. I hereby certify that the fo~ect to the best of my knowledge. Title: Endicott Reservoir Engineer Form 10-404 Rev 06/15/88 Date March 05, 1999 Prepared by De~Yayne R. $chnorr 564-5174 SUBMIT IN DUPLICATE 2-22 / L-14 Description of Work Completed NRWO OPERATIONS 02/02/1999 STATIC PRESSURE SURVEY 03/01/1999 WELL CONVERSION FROM WATER TO MI 06/18/1999 TEST IA SUMMARY 02/02/99 PULLED 4 Y2" MCX # M-02, PREFORMED STATIC SURVEY W/DUAL HALLIBURTON SPARTEK GAUGES,SET 4 Y2" MCX # NM12,CLOSURE TEST GOOD. WELLHEAD PRESSURE INCREASED FROM 2473 PSI TO 2481 PSI OVER 5 HOURS. GAUGES SET @ 11637' MDBKB ( 9932 TVDSS), BHSIP = 4163 PSI, BHSIT = 164 DEGREES F, DELTA P = 3.7 PSI/HR. SHUT-IN DATE: WATER INJECTION WAS STOPPED 09/98 IN PREPARATION FOR MI INJECTION. SINCE THEN, THERE HAVE BEEN 2 PERIODS OF GAS INJECTION OF APPROXIMATELY ONE HOUR EACH. THE MOST RECENT ONE HOUR PERIOD OF INJECTION (PRESSURE DISTURBANCE) WAS ON THE MORNING OF 01/29/1999. 03/01/99 WELL CONVERTED FROM WATER INJECTION TO MI INJECTION. 06/18/99 PUMPED A TOTAL OF 5 BBLS OF DIESEL AND 3 BBLS OF 60/40 METHANOL. Fluids Pumped 5 DIESEL 3 60/40 METHANOL WATER 8 TOTAL Page I bp BP Exploration (Alaska) Inc. 900 East Benson Blvd PO Box 196612 Anchorage, AK 99519-6612 (907) 561-5111 October 5, 2001 Tom Maunder Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage Alaska, 99501 Re: Endicott Well 2-22/L-14 Variance Request Dear Mr. Maunder, Please find attached an Application for Sundry Approval for Endicott water injection well 2-22/L-14. This application is for a variance to continue water injection onlY in this well. Tubing to inner annulus communication was discovered in this well 5/2001 during routine mechanical integrity testing of the inner annulus. Subsequent leak detection logging confirmed a tubing leak at 4602 MD with a leak rate of 1 bpm at 1700 psi differential pressure. Three attempts have been made to restore tubing integrity via installation of a tubing patch across the leak. None of the patch attempts have been successful for more than 48 hours. It has not been possible to determine the tubing patch failure mechanism for all the attempts and the probability of success with further attempts is questionable. A successful combined tubing/casing mechanical integrity test with a plug in the tubing tailpipe was performed 8/17/01. This test was witnessed by an AOGCC inspector. This well provides essential waterflood support to maximize rate and reserves for the Niakuk fault block Zone 3A as it is the only injector into this zone. It is proposed to return the well to water injection only with the following provisions: 1. The injection rate, tubing and annuli pressures will be recorded daily and reported to the AOGCC on a monthly basis. 2. A pres. a test of the inner annulus to m~,,~itor the leak rate will be performed annually. 3. A uesL'P.~ mechanical integrity test will be performed every 2 years unless daily monitoring indicates more frequent testing is warranted. 4. The well will be visually inspected daily. Miscible gas injection will not be attempted until mechanical integrity is restored and AOGCC approval obtained. Please contact me at 564-5546 if you have any questions or require additional information. Sincerely, Dan Robertson, PE Endicott Production Engineer Attachments: Form 10-403 Application for Sundry Approval Well 2-22/L-14 Well service reports Well 2-22/L-14 Completion diagram CC: Jim Ambrose Endicott Production and Wells Coordinator Bill Blosser Mark Weggeland Madelyn Millholland STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Vadance _X Perforate _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface ,/ ,/ 1919' FNL, 2223' FEL, Sec. 36, T12N, R16E, UM At top of productive interval 2616' FNL, 1898' FWL, SEC 25, T12N, R16E, UM At effective depth 2355' FNL, 1892' FWL, Sec. 25, T12N, R16E, UM At total depth 2223' FNL, 1893' FWL, Sec 25 T12N, R16E, UM 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service__X (asp's 258984,5982498) (asp's 257973, 5987116) (asp's 257975,5987376) (asp's 257980,5987509) 12. Present well condition summary v/' Total depth: measured 12322 feet Plugs (measured) true vertical 10593 feet v/' Effective depth: measured 12070 feet Junk (measured) true vertical 10379 feet Casing Length 'Size Cemented Conductor 72' 30" Driven Surface 2460' 13-3/8" 3423 c.f. Permafrost Intermediate 11204' 9-5/8" 575 c.f. Class 'G' 6. Datum elevation (DF or KB feet) RKB 55.5 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 02-22 / L-14 9. Permit number / approval number 189-034 v" --.. ..~ 10. APl number L~ 50-029-21931v''' I I I ~ 11. Field / Pool c,,,J Endicott Field / Endicott Pool Measured Depth True vertical Depth 110' 110' 2498' 2498' 11242' 9692' Liner 1324' 7" 428 c.f. Class 'G' 10998' - 12322' 9495' - 10593' Perforation depth: measured Open Perfs 11600'-11601 ', 11758'-11778', 11783'-11790', 11801 '-11805', 11809'- 11828', 11836'-11905', 11908'-11929', 11933'-11986', 11991 '-11994', 12000'-12016' true vertical Open Perfs 9988'-9989', 10118'-10134', 10138'-10144', 10154'-10158', 10161 '-10176' 10182'-10240', 10242'-10260', 10263'-10308', 10312'-10314', 10319'-10334' Tubing (size, grade, and measured depth 4-1/2", 12.6 ppf, L-80 TDS to 10952' w/3-1/2", 9.2 ppf, L-80 Tubing tail to 11067'. Packers & SSSV (type & measured depth) 9-5/8" x 4-1/2" TIW HBBR Packer @ 10952'. 4-1/2" SSSVLN @ 1553' 13. Attachments Description summary of proposal _X Detailed operations program __ BOP sketch __ 15. Status of well classification as: 14. Estimated date for commencing operation October 14, 2001 16. If proposal was verbally approved Name of approver Date approved Oil __ Gas __ Service WAG INJECTION. Suspended __ 17. I hereby ~,ify that the foregoing is true and correct to the best of my knowledge. Signed ~ l~ Title: Endicott Sr. Petroleum Engineer Dan Robertson FOR COMMISSION USE ONLY Questions? Call Dan Robertson @ 564-5546. Date 10/08/2001 Prepared by DeWayne R. Schnorr 564-5174 Conditions of approval: Notify Commission so representative may witness I Approval no. Plug integrity__ BOP Test__ Location clearance __ -, ~1 ~'~ Mechanical Integrity Test _~ Subsequent form required 10-t,r,.c~ ~',.~',,~,~. ~c.~~,~'c.~c,~[ ~.~,.~ / Approved by order of the Commission 0ri[Ii. al Signed By commissioner Date / Canm¥ O~.i~!i / ' ORIGIIx rA Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLI CATE BP Alaska, Inc. Prudhoe Bay Unit WELL SERVICE REPORT P1(END2-22(W4-6)) WELL JOB SCOPE JOB NUMBER EN D2-22 AN N-COM M 0610010630.4 DATE DAILY WORK UNIT NUMBER 08/17/01 CMIT IA X TBG LITL-RED DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 12 NO NO LRS-NICKLES SAUVE FIELD AFE/CC Detail Code DAILY COST ACCUM COST Signed ESTIMATE N13222 CMIT LLRT $0.00 $62,385.00 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann Final Outer Ann 1100 PSI 3000 PSI 1100 PSI 3000 PSI 100 PSI 110 PSI DALLY SUMMARY PLUG CURRENTLY IN TAILPIPE. MIT IA X TBG TO 3000 PSI. TEST OF TUBING/CASING SYSTEM WAS SUCCESSFUL. TEST WITNESSED BY AOGCC INSPECTOR JOHN CRISP. TIME LOG ENTRY 08:00 ARRIVE LOCATION, GET PERMIT. 08:20 BLEED TUBING FROM 2500 PSI TO 1000 PSI AND MONITOR. 08:30 MIRU, PJSM, PT SURFACE LINE 08:40 TUBING & IA PRESSURES NOT BUILDING. BLEED OFF TEST IS SUCCESSFUL. 09:01 START PUMPING 50/50 METH/WATER DOWN IA TO PRESSURE UP IA X TBG. 09:09 SHUTDOWN PUMP 5.3 BBLS PUMPED DOWN IA TO BRING IA X TBG TO 3000 PSI. START MIT TEST. 09:16 RIG DOWN CO MAN WILL MONITOR TEST. MOVE TO NEXT LOCATION: 09:40 TUBING & IA ARE HOLDING 3000 PRESSURE. POSITIVE PRESSURE TEST IS SUCCESSFUL. ~. FLUID SUMMARY 5 BBLS OF 50/50 METH/WATER SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $634.00 DOWE LL $0.00 $16,810.00 HALLIBURTON $0.00 $21,957.00 HBR $0.00 $3,500.00 HOT WATER PLANT $0.00 $1,133.00 LITTLE RED $0.00 $770.00 PEAK $0.00 $250.00 SCHLUMBERGER $0.00 $8,635.00 VECO $0.00 .$3,420.00 WAREHOUSE $0.00 $1,125.00 ~ TREE: 4-1/16" / 5000 psi / Cc` 'on / Axelson Actuator R.T. ELEV = 55.5' WELLHEAD: 13-5/8" / 5000 ~t "MC (CCL) B.F. ELEV = 17.14' MAX. DEV. = 44:26 10200' MD i O OTIS (3.813" I.D.) 1553' 13-3/8", 68#/ft, L-80, Btrs Csg W/SSSV IN MIN. I.D. 2" I 2498' I ~- -- 4-1/2", 12.6#/ft, L-80, TDS GLM's (Camco), (1-1/2" RK Latch) No. TVDSS MD-BKB #6 4082' 4169' 9-5/8", 47#/ft '-""'-" i#5 6276' 6914' NT80S XO to NT95HS I ~- ~ ~4 771 .q' R71f~' i ~ _ _ #3 8645' 99 ! 8' I 9403' f "---'--- #2 9193' 10674' #1 9299' 10815' SLIDING SLEEVE ,-.,....--. (3.813" I.D.) ~ (5.438" O.D.) 9-5/8" PACKER I TOP OF 7" LINER ~ ~ TIW (,BBP)(4.00" I.D.) , ~ ._--.--- 3-1/2", 9.2#/ft L-80, TAILPIPE ~ -- PARKER (2.750" I.D.) 10999' 9-5/8", 47#/ft, NT95HS, NSCC FI ' '~ -- 3-1/2" 'SWN' NIPPLE I ..... I r ~ ,~ ~k PARKER (2.635" 11030' PERFORATING SUMMARY Ref. Log: DLL-GR (4-12-89) SIZE SPF INTERVAL STATUS ~ MARKER I11352' I 2 1/8' 2 11600' - 11601' Open 5" 4 11758' - 11778' Open 11700' 11783' - 11790' Open 11801'- 11805' Open 11809' - 11828' Open 11836' - 11905' Open 11723' 11908' - 11929' Open 11933' ~ 11986' Open 11991'- 11994' Open 12000'- 12016' Open PBTD I 12'236:1 ..... ~ ^ ^ ~ TOP OF FILL @12070 Btrs-TKC 12322' IIIIIIIII III I iiiiiiiiiiiiii ii iiiiiiiiiiiiii i iiiiiiiii ii iiiiiiiiiii iiii ii Date By Comments ENDICOTT WELL: 2-22~ L-14 03/09/89 FH PRoPosED :APl:NO. 50-029~21:93100 05/25/89 JLH INITIAL COMPLETION COMPLETION DIAGRAM 3~22/96 JTP CTU FCO BP EXPLORATION (:ALASKA), INC I I #6 4082' 4169' #5 6276' 6914' #4 7719' R71~' #3 8645' 99!8' #2 9193' 10674' #1 9299' 10815' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor,~ DATE: September 4, 2001 Chair SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder ~'('~¢/W~_ .,~\,~,.,.., BPX P I Supervisor /;t / J-(O-,-,--- _ ;... ·. ~.~, ~ "~ t~r,.5,, Endicott ~z.~r'~ ~ ~ ~-- MPI 2-22 / L-14 FROM: John Crisp MPI Petroleum Inspector Duck Island Unit NON- CONFIDENTIAL P..T.D~I Notes: ,, w~,I P.T.D-I I Wall , , , '~:' , Packer, Depth Pretest Initial 15 Min. 30. Min. , We"l'-~-""l'"~'"~'l. ". I''''v'''' I''"° I'"u"'"~'l ~ ,i ,,,oo I,,oo I"Oo I,,,,e,'v.,I 0 .P.T.D.I 1890340 IType. testl P ITestpsil 2500 I CasingI 450 I 2500. I 2500 I 250O ! P/F .I ~ Notes: Initial MIT after tubincj patch installed. . . . w~,l I TYpe'"i:l I ~.v.o. I ITubingI I I I I'"terva'l P.T.D.I IT~petestlITestpsil ' I Casing l I ' I ' I ,,I P~F I I T~,,.~.I I ~.v.o. I' ' I 'u~n~ I I I I" I'"~e'va'l ' TY'petestl ITestPsilI casin91 I" I' '1 ,,I 'P,/F I' I Type'ni'I ' I'.v-°'l Imu~'Ol .I.. I 'I"'I'n~va'l Type,testl , ,,ITest psi l I Casing I I I, I , I e/F I, I ~y,e',,~.l '.. I T.V.0. I I Tu~,,, I . I . I I , I'"te"a'l Typetestl ITestpsiI , I ,casi.~ I I I I I P/F, I Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to BP's Duck Island Unit to witness an initial:MIT on well MPI 2-22 / L-14 after tubing patch was installed. No failures witnessed M.I.T.'s performed: 1_ Attachments: Number of Failures: 0 Total Time during tests: 3hrs. cc: MIT report form 5/12/00 L.G. MIT DIU 9-4-01jc.xls 9/5/01 MEMORANDUM TO: Julie Heusser ',~\~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: August 17, 2001 Commissioner ~_o.~,~- .'~""¢)~-''~ SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder BPX Supervisor ~,,~.'~t~'~ t. Endicott 2-22 / L-14 P.I. PTD 1890340 FROM: John Crisp Duck Island Unit Petroleum Inspector Endicott MPI .NON- ,.,CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. wad 2-22' ITyPelnj.'l' N IT-v:D-I 9457 IT%i~gt 94O, I' .30~0 I 3o001 2~ 'l~"te,vaq 'V .'P.TJD. I 1890340 ITYpetestl '_P" 'l Test PSi i, , 3000, I.c~inol .~75 I 2940 I' 2,.3o I 2~ I P/F !--P Notes: Tubing tail plug set f/MIT. Known tubin~l leak. I w'N IType~nj.I .... IT-V'D-i' "1TubinglI I I '" I~"~1" I ,P.T.D.i IT, yr~testl, ITestPSil I...casingl.'. ' '1 .... I.'.' '" I .' I' P/F' I. ' I Notes: ' w'~.'l ... I T'~"ni-I ' . .... I ~.V~D..'I '., I Tu,",¢'l' '. '1 ...... I.. "'1' I.,;,te,v.=q . P.T.D.I ..... I,'rymtestl ,,, ITest, psil I Casing l . I, .I I I P/F I ,, Notes: Wa~l ' IYype,.j.l"' I T.~/'.D: I "1 TUbingI '" I ..... I' I' ' ' 'l,.t~,;~i ' 'P.T.D'I T ' test ' Test psi ' ' CaSin ........ P/F I~pe . ! ... I I .... I. .g.i... I . I .I ..... I I Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details This welt has approved variance to continue inection w/a tubing leak. Tubing tail plug set & tested tubing & IA. Passed the pressure test. M.I.T.'s performed: .1_ Attachments: Number of Failures: Total Time during tests: 2bm ,c,c: MIT report form 5/12/00 LG. MIT DIU 2-22 L-14 8-17-01jc.xis 8/20/01 RE: MIT BPX DIU MPI 6-18-01 JJ.xls Subject: RE: MIT BPX DIU MPI 6-18-01 JJ.xls Date: Thu, 26 Jul 2001 12:12:42 -0500 From: "Robertson, Daniel B" <RobertDB@BP.com> To: '"tom_maunder@admin.state.ak. us'" <tom_maunder@admin.state.ak.us> CC: "Ambrose, Jim G" <AmbrosJG@BP.com>, "Spearman, Jim W" <SpearmJ@BP.com> Tom, When the injection waiver request for well 2-22/L-14 was submitted both Jim Ambrose and I believed that we had obtained a successful combined tubing and casing pressure test. Further review of all the pressure test information seems to indicate that we have not obtained or documented a completely successful MIT of the tubing and casing. In the absence of a successful MIT, we would like to withdraw the waiver request until we can further confirm well integrity. Sorry for the confusion on this. Dan ..... Original Message ..... From: tom_maunder@admin.state.ak.us [mailto :tom_ma u nder~ad min. state.ak, us] Sent: Wednesday, July 25, 2001 12:45 PM To: Dan Robertson Subject: MIT BPX DIU MPI 6-18-01 JJ.xls Dan, Enclosed is that MIT we talked about. Sorry I was delayed in getting it to you. Lets discuss. Tom Maunder SCANNED JUL 3 1_ 200?_ 1 of 1 7/26/01 12:38 PM facsimile BP Exploration (Alaska) Inc 900 East Benson BIvd Anchorage, AK Date: 28 June 2001 To: Jane Williamson Fax Number: 907-276-7542 Pages to follow: 2 Subject: Sundry form 403 for 2-22/L-14 Waiver From: James Ambrose Dept: BP/Endicott Telephone: 907 564-4375 Fax: 907 546-4441 ambrosjg@bp.com Message: Jane, Attached is a Sundry form 403 requesting a waiver to return Endicott well 2-22/L-14 to water injection. Original documents are being courier to your office. I will be on vacation for 2 weeks starting tomorrow. If you have questions or require additional information please contact Dan Robertson, Endicott Lead PE, at 564-5546. Regards Jim Ambrose SCANNED JUL :3 1 2002: STATE OF ALASKA ALAS/F' ' OIL AND GAS CONSERVATION COMMISSI~' APPLICAT,JN FOR SUNDRY APP. ,OVALS 1. Type of Request: Abandon __ Suspend ..... Operation Shutdown __ Re-enter suspended well __ Alter casing _ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing __ Variance x Perforate __ Other__ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) BP Exploration (Alaska) Inc. Development . KBE = 55.5 feet Exploratory .__ 3. Address Stratigraphic .__ 7. Unit or Property name P. 0. Box 196612, Anchoracle, Alaska 99519-6612 Service ~__ Duck Islan Unit/Endicott 4. Location of well at surface 8. Well number 1919' SNL, 2224' WEL, Sec. 36, T12N, R16E 2-22/L-1 MPI At top of productive interval 9. Perm/j~'number 2720' SNL, 3374' WEL, Sec. 25, T12N, R16E 89-y At effective deplh 110. A/PI number 2268 SNL. 3389 WEL. Sec. 35. T12N. R16E I ,/50-029-21931 "~ .'-'-:,, At total depth 11,~/'. Field/Pool 2221' SNL, 3389' EEL, Sec. 35, T12N. R16E yEndicott Oil Pool _L~J~' c~ 12. Present well condition summary / Total depth: measured 12322' feet Plugs (measured) ~ LM true vertical 10593', feet BKB / Effective depth: measured 11914 feet Junk (measu~red) /, true vertical 10248' feet BKB Casing Length Size Cemented r,J~J/ Measured ~e,p,t,h True__vertical depth Structural _ ~ ~ y ul~u BKB - Conductor 72' 30 D,~ve~n ~ 110' 1101 Surface 2460' 13-3/8 3423 c.f. ~, ~ a~rost 2498' 2498' Intermediate 11204' 9-5/8 575 c.f.~C~s G 11242' 9692' Production Liner 1324' 7 428 lass G 109,98:12322' 9495'- 10593' Perforation depth: measured 11600'-11601'; 11758'-11778 11783'-11790'; 11801-11805'; 11809'-11828'; 11836'-11905'; 11908'-11929~ 11933~1 true vertical ~ubsea)9932~9933~ 1~ 10127~10185~ Tubing(size, grade, and measured depth)4-1/2"12.~ 11991~11994~ 12000~12016' 10079~ 10083'-10089~ 10098~10102~ 10105~10121'; )205? 10208~10253~ 10257~10259~ 10264~10278' tub~g with 3-1/2"~ilp~e ~ 11067' Packers and SSSV (type and measured de packer at 10952'; 7" WD packer at 11700'; 4-1/2" SSS V at 1553' 13. Attachments Description summary of xx Detailed operations program BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: June 30,2001 16. If proposal was verbally approved Name of approver 17' I he?/~ce!ifY Signed ~~.,~. Oil ~ Gas Suspended Date approved Service MI Injector true and correct to the best of my knowledge. 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- I Approval No. <..'~_~:'~t-' {'7 7 Approved by order of the Commission SUBMIT I I~'I'fR~I~LLICATE Form 10-403 Rev 06/15/88 ORIGINAL SUNDRY APPLICATION FOR VARIANCE ENDICOTT POOL WELL 2-22/L-14 June 28, 2001 Background Well 2-22/L-14 was originally drilled and completed in April, 1989 from the Endicott Main Production Island (MPI), as a water injection well. In March 1999, the well became a water alternating MI injector. Cumulative water and MI injection through the end of May 2001 is 36.7 mmb and 3.3 bcf, respectively The well is a critical injection point, providing the all water injection support for offtake in the Niakuk 3A Subzone. Continued water injection will also help maintain reservoir pressure in this EOR pattern above minimum miscibility pressure. The mechanical integrity of well 2-22/L14 was tested on May 26, 2001 prior to the AOGCC witnessed MIT. Tubing by inner annulus communication was observed at which point the AOGCC was notified and the well shut in. No inner to outer annulus communication was noted during this testing. On May 27, 2001 a plug was set in the tubing tail in preparation for a combined MIT. On May 28, 2001 2-22/L-14 failed a combined tubing and inner annulus mechanical integrity test when inner by outer annulus communication was observed. On June 3, 2001 the test port on the 9 5/8"packoff was opened and bleed down from 560 psi to 540 psi. Inner annulus fluid level was at the surface and outer annulus pressure was at measured at 70 ft. No inner to outer annulus communication has been observed since this operation. On June 18, 2001 a combined MIT on the tubing and inner annulus was witnessed by the AOGCC. During this test the pressure decreased 30 psi from 2500 psi in 30 minutes and no inner by outer annulus communication was observed. A leak detection Icg was run on June 25, 2001 that located a single tubing leak 4602 ft MD. BP intends to run a mechanical patch across this leak as soon as obtaining the necessary equipment. Recommendation BP requests that 2-22/L-14 be allowed to return to water injection only, until such time as a tubing patch can be run across the identified tubing leak to repair the tubing to inner annulus communication problem. BP would supply daily injection data, incorporating water rate plus wellhead and annulus pressures, to the AOGCC on a monthly basis. BP believes the well may be utilized in this manner, pending remedial action, without compromising safety or the environment. Your concurrence is requested. SCANNED JUt... 3 ] 2002 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser Commissioner THRU: Tom Maunder P.I. Supervisor FROM: Jeff Jones Petroleum Inspector DATE: June 18, 2001 SUBJECT: Mechanical Integrity Tests BPX MPI Duck Island Unit Endicott Field ,, ..................... Packer ' [:~P~ ' prete~t ...... Initial ;1'5 Min. "30'Min. IT,,e,nj.'! 0'1 P~'T.D.I' 187~18, .ITy~t~l ~,p', ,, I,T~tpsi' 2~ I, Ca=nol 1~,,,I 2575 I, 25751 2575 I' P~ IE ~ prmf~ nmee,,r= mnnifnr~ far ~n min ~. w~.d. 2-~1.4 .... ITyp~.~,]..I.., .'~Y~.~'~" ~ I TuU"oI' O'~ "'1".~o I'~_~1 2~20 li"t~N~ PTDI ~~ TY~t~t~ P IT~tPsiI 2~ I CaS~ngl 0 ,-,,- -, ........... I ............. %, N~: W~I has kn~ ~mmuni~tion~ ~A. , ~.T.o:l.,,, .. ITy~et~l ..... IT~tpql N~: , ,wal ...... ',' .... ......... ,"1 P.T.~.,I .......... IT~t~tl IT~'I I Casing. I !' I I I N~: ............ ! ......... I ...... I I ........ I ..... Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details M.o~day, J_~ne ~ ~ I traveled to BPX's Duck Island Unit Main Production Island to witness MIT's on wells 2-06 and 2-22. Mark Sauve was the BPX representative in charge of testing and he performed the tests in a safe and proficient manner. The pre-test pressures were monitored for 30 minutes and observed to be stable and then the MIT's were performed with one failure witnessed. Well 2-22 has a known communication between the tubing and the inner annulus and a tubing tail plug had been installed for the test. I noted that over the 30 minute test on well 2-22 the tubing and IA pressures equalized and tracked closely and did not stabilize. I monitored the pressures for an additional 30 minutes and the pressures continued decreasing, failing the MIT. Well 2-06 passed its MIT and is suitable for continued injection. Su~.marv: I witnessed a successful MIT on well 2-06 and well 2-22 failed its MIT at BPX's DIU MPI Endicott. M,I.T.'s performed: ~ Number of Failures: ~_ Total Time during tests: 2 hrs Attachments: O_ C~: SCANNED JUL 3 1 2002 MIT BPX DIU MPI 6-18-01 JJ.xls 7/26/01 MEMORANDUM TO: Julie Heusser g,.1271g-~, I Commissioner , _.~)7SUBJECT: THRU: Tom Maunder P.I. Superior ? ~'--' ' ~~ - FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 18, 2001 Mechanical Integrity Tests BPX MPI Duck Island Unit Endicott Field i Packer Dep'd~ Pretest initial' 15 Min.' 30 Min.. ',' . '" / "wdll 2-O6/J22I T~ Inj. I ' e I T~V.'D'. I '"3"~ I Tu~,.,.,I ',~o I","-~o I ~ I' .C~o,',l..~a.I W I I P'T'D'I ' 187-018 IType testI P ITest psiI 2348 I,Casi .r~l I ,1600 I 257,5. I.. 2575 .I, 2575 I P/F ! P I I' ,~,.:. ,,P,. ,re-t ,est pressures monitored 'for 30 min. & ob~rved t~ be stable. ' ' ' Wm~l 2.22~u4 '1 Type ~,j.I , I' Y.vli~. I "~"~ I Tuba,g I 0 . I. 2~ 't 2~ '1' 2S20 'l~"te~'~l' 4 I · p.T..D.I .... 1&9~034..I.Typet~l. P' I'T~t%!l "2~ ..I.c,s~"gl "0 '1 '.2p75. I 2~ I 2~0 I P~F Notes: Well has known communication between casing & IA. I wa~'l'IT~P~,J.I I Y.v:0./'" I'T"~"g'l .... I "' I ' '1 ..... I~"~e,,,,~l ' I.'. P-T*D.*I '. ,"' ,',,', ITy"e.t.~l .. ITe,tPs~I' '.' .'. I C,:",;l '" I'' I' I". '1 .P": I i' 'Wetil ' ' I Type Inj'.I' ' I T.V.D. I" I T~bing I "I ' ' I I "Ilnten,all ' P.T.D,.I, ITy,pete,tl ' :' . I,T'~,t ,psil , , I c%,,~g I ..... I' '. ' I".'. ,"' I ' ! "~F I : Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details Monday, J..une .[8, 2001: I traveled to BPX's Duck Island Unit Main Production Island to witness MIT's on wells 2-06 and 2-22. Mark Sauve was the BPX representative in charge of testing and he performed the tests in a safe and proficient manner. The pre-test pressures were monitored for 30 minutes and observed to be stable and then the MIT's were performed with one failure witnessed. Well 2-22 has a known communication .betw~n the tubing and the inner annulus and a tubing tail plug had been installed for the test. I noted that over the 30 minute test on Well 2,22 the tubing and IA pressures equalized and tracked closely and did not stabilize. I monitored the pressures for an additional 30.minutes and the pressures continued decreasing, failing the MIT. Well 2-06 passed its MIT and is suitable for continued injection. Summa~: I witnessed a successful MIT on well 2-06 and well 2-22 failed its MIT at BPX's DIU MP! Endicott. M.I.T.'s Performed: _2 Number of Failures: ~_ Total Time during tests: 2_hm Attachments: _0 C~: MIT BPX DIU MPI 6-18-01 JJ.xis 7/25/01 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser ~' ~,,~ DATE: May 28, 2001 Commissioner /~o~UBJECT: Mechanical IntegrityTests THRU: Tom Maunder BPX P.I. Supervisor MPI ~l~-O\ Duck Island Unit FROM: Jeff Jones Endicott Field Petroleum Inspector Packer Depth Pretest Initial 15 Min. 30 Min. WellI 2-70 s I ~.V.D. I,~00 I Tubing I 2600 I 2600 I 2700 I 2700 I'lntervall 4 P.T.D.I 188-153 ITypetestl P ITestpsil 2300 ICasingI 1675I 2550I 2540I 2540I P/Fi_PI Notes: Pre-test pressures monitored for 30 min. & observed to be stable. I WellI 2-22 I T . ,nj.I N i T.V.D. I,,~0 I Tubing I 1400 12750 I 2550 12525 I lntervall 4 P.T.D.I 189-034 ITypetestl P ITestpsiI 2365 ]CasingI 1240I 2630I 2450 I 2390 I" P/F IF. Notes: Well has known communication between casing & IA. Ob, pressure increased 660 psi during MIT. WellI 1-51 I Typelnj. I S I T.V.[). I 8785 I Tubingl 2650 I 2675 I 2650 I 2650 I lntervall 4 P,T.D.I 192-119 ITypetestl P ITestl,siI 2196 ICasingI 1120I 2550I 2540I 2535I P/F Notes: Pre-test pressures monitored for 30 min. & observed to be stable. we,,I ~-43 I Typ~,nj.I S I T.V.D. I 9540 ITub, ng12500 12400 [2480 12450 I,nterva,[ P.T.D.I 188-105 ITypetestl P ITestpsil' 2385 ICasingI 600 I 25251 24401 23751 P/F Notes: Pre-test pressures mc;nitored for 30 min. & observed to be stable.. I I I I I I I I I I Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus MonitOring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details Monday, May 28. 2001: I traveled to BPX's Duck Island Unit Main Production Island to Witness 4 year MIT's on wells 2- 70, 2-22, 1-51 and 1-43. Mark Sauve was the BPX representative in charge of testing and he performed the tests in a safe and proficient manner. The pre-test pressures were monitored for 30 minutes and observed to be stable and then 4 MIT's were performed with one failure witnessed. Well 2-22 has a known communication between the tubing and the inner annulus and a tubing tail plug had been installed for the test. I noted that over the 30 minute test on well 2-22 the tubing and IA pressures equalized and tracked closely and the OA pressure increased fi.om 0 psi to 660 psi and did not stabilize. Summary: I witnessed 3 Successful MIT's and well 2-22 failed it's MIT at BPX's DIU MPI Endicott Field. M.I.T.'s performed: 4 Number of Failures: 1_ Total Time during tests: 3 hfs. Attachments: cc: MIT BPX DIU MPI 5-28-01 JJ 6/9/01 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser ~'-'- DATE: Commissioner Tom Maunder, ~~~ P. I. Supervisor ~.~. t c~, THRU: December 14, 2000 FROM: Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Test Duck Island Unit MPI Thursday~ December 14~ 2000: I traveled to BPX's MPI in the Endicott Field and witnessed the safety valve system testing on WAG well 2-22. Well 2-22 is a WAG injector that was recently switched to gas injection. The well was shut in at the time of this test due to ongoing problems with Endicotts MI skid. All. components tested functioned properly and held the pressure tests. Robed Larson performed the testing.today, he demonstrated good test procedures and was a pleasure to work with, Summary: I witnessed SVS testing at BPX's DIU Well 2-22. DIU MPI 1 wells 3 components 0 failures Attachment: SVS DIU MPI 12-14-00 CS X Unclassified Confidential (Unclassified if doc. removed ) Confidential Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report Operator: BPX Operator Rep: Robert Larson AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Field/Unit/Pad: Endicott / DIU / MPI Separator psi: LPS Date: 12/14/00 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 2-40/S22 1941520 2-42/P13 1881450 2-44AJQ1 1970710 2-46B/S1 1971370 2-48/013 1951660 2-50FL108 1930670 2-52/S14 1870920 2-56A/EI 1980580 , . 2-58/S09 1900520 , 2-60/U13 1930830 " 2-62/Q17' 1861580, 2-68/S 17 1880970 5-01/SD7 1801200 2-22/L14 , 1890340 3700 2000 2050 P P P WAG Wells: 1 Components: 3 Failures: 0 Failure Rate: [] 9o var Remarks: WAG Well on gas 12/19/00 Page 1 of I SVS DIU MPI 12-14-00 CS.xls STATE OF ALASKA ALAS~" OIL AND GAS CONSERVATION COMMIS~' i REPORT O¢' SUNDRY WELL OPEHATIONS 1. Operations performed: Operation shutdown __ Stimulate__ Plugging__ Pull tubing__ Alter casing Repair well ..... Perforate. Other x 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora.cle, Alaska 99519-6612 4. Location of well at surface 1919' SNL, 2224' WEL, Sec. 36, T12N, R16E At top of productive interval 2720' SNL, 3374' WEL, Sec. 25, T12N, R16E At effective depth 2268' SNL, 3389' WEL, Sec. 35, T12N, R16E At total depth 2221' SNL, 3389' WEL, Sec. 35, T12N, R16E 5. Type of Well: Development Exploratory ~ Stratigraphic . Service .. 6. Datum elevation (DF or KB) KBE = 55.5 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-22/L- 14 MPI 9. Permit number/approval number 89-34 10. APl number 50- 029-21931 11. Field/Pool Endicott Off Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 12322' feet Plugs (measured) 10593' feet BKB 11914' feet Junk (measured) 10248' feet BKB Length Size Cemented 72' 30 Driven 110' 110' 2460' 13-3/8 3423 c.f, Permafrost 2498' 2498' 11204' 9-5/8 575 c.f. Class G 11242' 9692' 1324' 7 428 c.f. Class G 10998'- 12322' 9495'- 10593' measured 11600'-11601'; 11758'-11778'; 11783'-11790'; 11801'-11805'; 11809'-11828'; 11836'-11905'; 11908'-11929'; 11933'-11986'; 11991'-11994'; 12000'-12016' true vertical (subsea) 9932'-9933'; 10063'-10079'; 10083'-10089'; 10098'-10102'; 10105'-10121'; 10127'-10185'; 10187'-10205'; 10208'-10253'; 10257'-10259'; 10264'-10278' Tubing (size, grade, and measured depth) 4-1/2" 12.6# TDS tubing with 3-1/2" tailpipe to 11067' Packers and SSSV (type and measured depth) 9-5/8" packer at 10952'; 7" WDpackerat 11700'; 4-1/2" SSSVat 1553' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure MITIA (6/18/99) ORIGINAL 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 0 0 0 0 0 17892 0 0 Tubing Pressure 0 2482 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil., Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. -FOrm 10-404 Rev 06J'~88 Service MI Ini. p. ntnr Date 7/21/99 SUBMIT IN DUF~IOATE BPX Endicott Production Engineering Department Test IA DATE: 6/18/99 WELL N°: 2-22/L-14 BP EXPLORATION REP: Merle Jones, D. Williams SERVICE COMPANY: APC DATE/TIME OPERATIONS SUMMARY 1330 MIRU to IA. PT hose to 3500 psi. 1345 Start pumping diesel. 5 bbls away switch to 60/40 Meth. Pumped 3 bbls of 60/40 meth. Pressure up to 2500 psi. Good test. Held 2500 psi. SUMMARY: * Pumped a total of 5 bbls of diesel & 3 bbls of 60/40 Meth. STATE OF ALASKA ALASKa'" "'L AND GAS CONSERVATION COMMISSIOI~¢' REPORT Oil SUNDRY WELL OPEF ...,TIONS 1. Operations performed: Operation shutdown__ Stimulate Plugging Pull tubing Alter casing __ Repair well Perforate .. Other x 2. Name of Operator 5. Type of Well: 6. BP Exploration (Alaska} Inc. Development Exploratory 3. Address Stratigraphic 7. P. 0. Box 196612, Anchora.cle, Alaska 99519-6612 Service x 4. Location of well at surface 8. 1919' SNL, 2224' WEL, Sec. 36, T12N, R16E At top of productive interval 2720' SNL, 3374' WEL, Sec. 25, T12N, R16E At effective depth 2268' SNL, 3389' WEL, Sec. 35, T12N, R16E At total depth 2221' SNL, 3389' WEL, Sec. 35, T12N. R16E Datum elevation (DF or KB) KBE = 55.5 feet Unit or Property name Duck Island Unit/Endicott Well number 2-22/L- 14 MPI 9. Permit number/approval number 89-34/91-296 10. APl number 50- O29-21931 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical measured true vertical Length 12322' feet Plugs (measured) 10593' feet BZ4B 11914' feet Junk (measured) 10248' feet Size Cemented Measured depth True vertical depth BKB BKB 72' 30 Driven 110' 110' 2460' 13-3/8 3423 c.f. Permafrost 2498' 2498' 11204' 9-5/8 575 c.f. Class G 11242' 9692' 1324' 7 428 c.~ Class G 10998~12322' 9495~10593' measured 11600'-11601'; 11758'-11778~ 11783~117907 11801~118057 11809'-11828? 11836~119057 11908~119297 11933~119867 11991~119947 12000~12016' true vertical ~ubsea)9932~99337 10063~10079~ 10083~10089~ 10098~10102~ 10105~101217 10127'-101857 10187'-10205~ 10208'-10253? 10257~102597 10264'-10278' Tubing (size, grade, and measured depth) 4-1/2" 12.6# TDS tUbing with 3-1/2" tailpipe to 11067' Packers and SSSV (type and measured depth) 9-5/8" packer at 10952? 7" WD packer at 11700'; 4-1/2" SSS V at 1553' or cement squeeze summary ~ 13. Stimulation ------".-IfiL. Intervals treated (measured) 26 1997 Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data An'ch0rage OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 14476 0 2097 Subsequent to operation 0 0 14267 0 2069 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service w_~t~r/ni, ector 17. I hereby certify that,~J:Le foregoipg~is true and correct to the best of my knowledge. Signed'~"~ ' "~ ~'~C~~'3 Title 5;,ni~r T,~hni~,l ,tt.e~i.et, nt ,V Form 10-4/~ Rev 06/15/88 Date 6/24/97 SUBMIT IN DUPLICATE BPX Endicott Production Engineering Department MIT DATE: 5/3/97 WELL N°: 2-22/L-14 BP EXPLORATION REP: R. Clump SERVICE COMPANY: HB & R I I. DATE/TIME OPERATIONS SUMMARY 1010 Miru HB& R to IA. IWHP= 2050 psi, lAP= 600 psi, OAP= 100 psi. 1021 PT hard line to 3000 psi. Pump 9 bbls to [let lAP= 2650 psi. 1127 Start test. 1142 lAP= 2620 psi after 15 mins. 1157 lAP= 2620 psi after 30 mins. Passes MIT. Bleed back lAP to 375 psi. 1210 HB & R RDMO. IWHP= 2010 psi, lAP= 375 psi, OAP= 100 psi. Summary: Passed 4-year MIT w/J. Spaulding as AOGCC witness, RECEIVED Alaska Oil & Gas Cons. Commissior~ Anchorage ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 16 March 1994 RE: Transmittal of Data ECC #: 6145.00 Data: PDK-PORO Dear Sir/Madam, Reference: BP 2-22/L-14 ~.. 501 ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 1 Sent by U.S. MAIL PDK/GR/CCL FINAL BL PDK/GR/CCL RF SEPIA Run # 1 Run # 1 Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: j Date: ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 8 April 1994 Transmittal of Data Sent by: U.S. MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION /PLS INJ. FINAL BL PLS INJ. RF SEPIA ~ PLS ~NJ. FINAL BL 1 PLS INJ. RF SEPIA /U-8 MPI 2-50/U-8 MPI '3-17/J-30 vl PLS INJ. FINAL BL 1 PLS'INJ. RF SEPIA /~CCL CEMENT FINAL BL a~"CCL CIRC. FINAL BL 1 CCL CEMENT RF SEPIA 1 CCL CIRC. RF SEPIA '~/1 GR/CCL FINAL HA 1 GR/CCL RF SEPIA SBT/GR FINAL BL i SB /SR SEPIa /CCL TUB. FINAL BL 1 CCL TUB. RF SEPIA ~ CCL TUB. FINAL BL 1 CCL TUB. RF SEPIA ,/1 PLS STP FINAL BL 1 PLS STP RF SEPIA Cont/ ECC No. Run # 1 Run ~ 1 5669.03 Run # 1 Run ~ 1 6145.01 Run # 1 Run # 1 6148.00 Run ~ 1 Run ~ 1 Run ~ 1 Run ~ 1 6001.06 Run # 1 Run ~ 1 6001.08 Run ~ 1 Run $ 1 6001.07 Run # 1 Run g 1 6005.01 Run # 1 Run # 1 6005.02 Run # 1 Run # 1 6153.00 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: Date: Please sign and return to: BP Exploration (Alaska) Inc. Petrotechnical Data Center Mailstop MB 3-3 900 East Benson Boulevard Anchorage, Alaska 99519-6612 Received by: Date: RECEIVED ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 24 February 1994 RE: Transmittal of Data ECC #: 6145.00 Data: PDK-PORO Dear Sir/Madam, Reference: BP 2-22/L-14 ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: Sent by U.S. MAIL · PDK! LDWG TAPE+LISTER Run # 1 Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson ~,,~. ' Date: . BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 March 6, 1992 Lonnie Smith, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Cancellation of Sundry Intents Dear Mr. Smith: The following is a list of approved Applications for Sundry Approvals for jobs that have been cancelled. If there is need for any additional information, please contact Jeanne Haas at 564-5225. z~.z' ~ ,~ 2-22/L- 14 90-773 10/9/90 1-43/P-26 90-896 12/24/90 3-39/J-39 91-082 3/14/91 1-69/V- 19 91-333 11/6/91 Sincerely, . ,~An n e Haas Technical Assistant II jlh cc: Working Interest Owners Drilling Well File RECEIVED MAR ~1 1992 Alaska Oil & Gas Cons. Commission Anchorage~ 1. Type of Request: AL~'I,~. ~, OIL AND GAS CONSERVATION COMMISSiuN APPLICATION FOR SUNDRY APPROVALS Abandon __ Suspend Alter casing ~ Repair well Change approved program ~ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1919'SNL, 2224' WEL, Sec. 36, T12N, R16E At top of productive interval 2720' SNL, 3374' WEL, Sec. 25, T12N, R16E At effective depth 2268' SNL, 3389' WEL, Sec. 35, T12N, R16E At total depth 2221' SNL, 3389' WEL, Sec. 35, T12N, R16E 12. Present well condition summary Total depth: measured Operation Shutdown ~ Plugging Pull tubing ~ Variance. 5. Type of Well: Development Exploratory Stratigraphic Service x Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 12322' feet Plugs (measured) 10593' feet BKB Re-enter suspended well ~ Time extension ~ Stimulate X Perforate Other 6. Datum elevation (DF or KB) KBE -- 55.5 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-22/L- 14 MPI 9. Permit number 89-34 10. APl number 50-029-21931 11. Field/Pool Endicott Oil Pool RECEIVED J 11914' feet Junk (measured) 10248' feet BKB Size Cemented DEC 20 1991 Alaska Oil & Gas Cons. Commisslo~ Measured de~h0rage TrueBv/~ical depth true vertical measured true vertical Length 72' 30 Driven 110' 110' 2460' 13-3/8 3423 c.f. Permafrost 2498' 2498' 11204' 9-5/8 575 c.f. Class G 11242' 9692' feet 1324' 7 428~ C~ss G 10998~12322' 9495'-10593' measured 11600'-11601'; 11758'-11778~ 11783~11790~ 11801~11805~ 11809'-11828~ 11836~11905~ 11908~11929~ 11933~11986~ 11991~11994~ 12000~12016° true vertical (subsea) 9932'-9933'; 10063'-10079'; 10083'-10089'; 10098'-10102'; 10105'-10121'; 10127'-10185'; 10187'-10205'; 10208'-10253'; 10257'-10259'; 10264'-10278' Tubing (size, grade, and measured depth) 4-1/2" 12.6t/TDS tubing with 3-1/2"tailpipe to 11067' Packers and SSSV (type and measured depth) 9-5~8"packer at 10952'; 7" WD packer at 11700'; 4-1/2" SSS V at 1553' 13. Attachments Description summary of proposal ~ Detailed operations program x BOP sketch .... 14. Estimated date for commencing operation January 5, 1992 1 ~. If proposal was Verbally approved Name of approver Date approved 15. Status of well classification as: Oil Gas Service Water Injector Suspended~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed "'~'" //~ .~~'~.-'--"--'-.-....,, Title EnclicottOperations&ProductionLeadEngr. FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test Mechanical Integrity Test~ Approved by order of the Commission Form 10-403 Rev 06/15/88 Location clearance Subsequent form required 10- ~'~'~ ORIGINAL SIGNED BY ~n .... '" C. *.~.".~TH SUBMIT IN TRIPLICATE R. Allan/J. Golding (' 2-22/L-14 OTU Mud Ac~d Stimulation Pre-Stimulation Preparation 1) RU slickline unit. and pull SSSV. RDMO slickline unit. 2) Block SSV with fusible cap and shut-in well at choke and wing valve. Note wellhead and annulus pressures. 3) Obtain wellhead crude sample from 2-18/L-16 and submit them to Dowell/Schlumberger's lab for emulsion/sludge testing. The test should be conducted for the specific acid system to be pumped with both live and spent acid (with associated additives) heated to a reservoir temperature of ~ 210 °F. Ensure the acid system is "doped" with 5000 ppm ferric ions as this will ensure sufficient iron reducing/sequestering agents are added to the acid system. Finally, ensure the service company adjusts the type and volume of additives as dictated by the emulsion test results. 4) Inspect the weilhouse and surrounding areas for cleanliness, spills, etc. 5) Have the following on site to be pumped: Pre-Stimulation - 200 bbls filtered seawater (kill well, cool weilbore) - 20 bbls filtered seawater (buffer cement, test pumps) - 0.5 bbls acid resistant cement (lay cement cap above scale fill at PBTD ) - 32 bbls filtered seawater (displace coil) 3 Staae Stimulation -- - 420 gallons (10 bbis) deisei preflush with 10% mutal solvent. - 3125 gallons (78 bbls) 15% HCL - 12,500 gallons (157 bbls) 12-3 HCL-HF mud acid - 1680 gallons (40 bbls) filtered seawater w/1%F78 Surfactant (Doweil)" - 26,733 scf Nitrogen w/513 gallons (12 bbls) filtered seawater = 65% Foam - 12,500 gallons (167 bbls) fresh water overflush with 2% NH4Cl. Fluid Treatmentfqal/ft) V01ume(qal) Addltive8 15% HCL 25 (125 feet) 12-3 Mud Acid 100 (125 feet) NH4CL: 100 (125 feet) FOAM 14 (125 feet) 3125 12,500 12,500 1,680 AS LISTED BELOW AS TO AP! RP 42 TESTING AS LISTED BELOW AS TO APl RP 42 TESTING 2% NH4CL: OVERFLUSH 1% F-78 Surfactant Acid Additives: Inhibitor': Surfactant Anti-sludge: Non-emulsifier: Iron Reducer: Mutual Solvent Notes- A-270 @ 4g/regal 0.2% F-75N W-35 @ 0-10g/regal as per sludge test W-54 @ 0-10g/mgaJ as per emulsion test i.58 @ 25#/mgal or as needed per sludge testing 10% U-66 RECEIVED DEC ~0 19~tl Tubing Capacity - 168 bbls. Capacity of liner to top of perfs ~ 26~1~~ Capacity of liner from PBTD to top of perfs - 8.5 bbls (356 gals) ....... 0il & Gas Cons, CommtS¢oa 7- 29#/ft liner= 0.0371 bblslff Anchora.3e Avg Angle ~ 35 Deg. Kickoff ~ 3000' 15% HCL = 8.962 PPG = 0.4654 psi/ft 12% HCL-3%HF= 8.871 PPG = 0.4605 psi/ft R. Allan / J. Goldir~' 2-22/L-14 CTU Mu'u. ,cid Stimulation Rever.~e OUt fill and Lay Cement Plu~ An acid resistant cement plug is being laid to protect the CaCO3 fill, at the bottom of the hole, from coming into contact with the HF acid. Contact with the HF would result in precipitate formation which could further damage the formation. 1) MIRU stimulation company, pump unit, filtering unit, and CTU with 2.25" OPEN NOZZLE. Install a pump-in sub and ensure a check valve is installed between the CTU and pump van. Note wellhead and annulus pressures and monitor dudng the job. Pressure test lines and CTU to 4500 psi. Note: Filter all fluids that are to enter formation through a 3 micron nominal filtering unit. Replace connection dependent O-dng seals on injector head. Ensure weight indicator is reading dead injector weight. Secure injector with chains if felt to be required (depending on weather and lubricator length). Weight checks should be done every 3000' and after each ID restriction. Slow running speed to _-20 ft/min through ID restrictions. 2) Prepare class G acid resistant cement for a 120 cc/30 mtn fluid loss and 2-3 hour thickening time for a design temperature of 200 °F. Perform fluid loss test on cement. If fluid loss is satisfactory, proceed with stimulation program. 3) Pump 200 bbis filtered seawater down the production tubing to kill and liquid pack the well if SIWHP is substantially greater than 400 psi. With a hyrdrostatic head of 4460 psi and 3A reservoir pressure at 4800 psi, 400 psi head pressure will be required to maintain kill conditions. ., 4) Once kill volume is away, continue in hole with coil. Begin pumping the 20 bbis filtered seawater stage through coil at approximately 1 BPM as the coil reaches PBTD (11914' MD-BKB). Tie in to PBTD (9/9/91 profile modification 11914' MD BKB) and flag coiled tubing. 5) Switch to reverse circulation, taking CaCO3 scale up the coil ensudng that WHP remains below 2000 0~i to prevent CT collapse. Continue reverse out until 21' of scale has been removed (new PBTD 11935' +__5' MD-BKB). Wait 30 minutes for disturbed CaCO3 solids to settle. 6) Pump the following at surface at 1BPM down the CT with surface choke closed. -0.5 bbls acid resistant cement -approximately 32 bbis filtered seawater to displace CTU. RECEIVED 7) DEC 20 t991 a OiJ & 6as Cons. [,un.niss~o,, Anchorage Locate CTN at the new PBTD (-11935') as cement hits CT nozzle. Pull CTN up 13' (barrel for barrel) until nozzle is at 11922' MD-BKB as trailing edge of cement hits CT nozzle. POH with CT and wait 8 hours for cement plug to set. 8) RIH with 2.25" SWAGE and TEL. Locate 2-7/8" tubing tail @ 11718' MD-BKB. RIH and tag PBTD. POH and RDMO. R. Allan / J. Goldint~ 2-22/L-14 CTU Muu Acid Stimulation 3 Staq. e ~timulal;ion 9) RIH with CTU with 2.25" OPEN NOZZLE, tie in to new PBTD and flag coiled tubing. Sample acids to ensure acceptable concentration and that iron count is less that 350 ppm. Also perform the following quality control checks: · Ensure sample bottles are on location prior to pumping the job in order to catch acid samples. · Make sure service company circulates all acid tanks pdor to pumping job to ensure a uniform acid mixture. Catch acid samples after circulating tanks. Check acid strength on location with a calibrated hydrometer. · Check service company ticket to ensure all additives have been added. · Ensure surface pressure and flowrate instrumentation is propedy registering and calibrated. Strapping the tanks dudng the job is useful in verifying volumes pumped. 10)Acidize 125' of Zone 3A perforations with a 3 stage treatment with foam diversion. Pump as follows: Pull CT nozzle up to 11800' MD-BKB and pump the 1st of 3 stages. Pump the acid at approximately 1-2 BPM (i.e. maximum rate to stay below bottomhole fmc pressure). Record wellhead tubing and annulus pressures in a timely manner and compare to the CTU readings throughout the job. Hook up an ERAD chart recorder and ensure the entire scale will be utilized. Mark events such as pre-flush, acid, diversion or post-flush at the perfs to note stimulation progression. ., If maximum permissable non-fmc wellhead pressure is achieved with minimal rate, allow acid to soak on the perforation to break them down instead of aborting the job. Do not exceed a 0.56 psi/ft (5685 psi @10150' ss) bottom hole treating pressure while acid is entedng the formation. This equates to a surface wellhead pressure of -1200 psi (0.44 psi/ft; all water in tubing) assuming the tubing is completely liquid packed. -Pump 420 gallons diesel Preflush with 10% mutual solvent. -Pump 1041 gallons 15% HCL + Additives: 1st stage. -Pump 4170 gallons 12-3 Mud Acid + Additives -Pump 420 gallons filtered seawater + 1%F78 -Pump 601 gallons 65 quality foam with 1% F-78 @ 2BPM. -Pump 420 gallons filtered seawater + 1% F78 -Shut down for 15 minutes 11)-Pump 1041 gallons 15% HCL + Additives: 2nd stage @ 1.5 BPM.' -Pump 4170 gallons 12-3 Mud Acid + Additives ,..~C [' -Pump 420 gallons filtered seawater +1°/oF78 R/.; I VE ~ -Pump 880 gallons 65 quality foam with 1% F-78 @ 2BPM -Pump 420 gallons filtered seawater + 1% F78 DEC ~0 ~99_1 -Shut down for 15 minutes 41a,~ka Oil & 8as Cons. (~ommissto, Anchorage R. Allan / J. Goldir~' 2-22/L-14 CTU MTSO3 ,~cid Stimulation 12)-Pump 1041 gallons 15% HCL + Additives: 3rd stage @ 1.5 BPM. -Pump 4170 gallons 12-3 Mud Acid + Additives 13)Move CTN to 11700' and pump 12,500 gallons of NH4Cl:overflush at maximum permissable matdx rate. Monitor wellhead pressure bleed off. POH with CT and RDMO field equipment. 14)Place well immediately on allocated injection rate with full header pressure of seawater from plant. Use pure seawater; or commingled if seawater is not available. RU slickline unit and set SSSV after 3 to 4 days injection. 15)Production logs will be requested separately. The cement plug will be left in place unless it is determined later that injection cannot be re-established into the 3A4 and 3A3. RECEIVED DEC ~0 1991' Alaska 0il & Gas Cons. Commission Anchorage BP EXPLORATION BP Explorabo~: ~A,a$~.al 900 East Benson Boulevard Ancr',orage..;.as..& 995; 9-66~ 2 (907) 561-5111 November 12, 1991 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sirs: Enclosed please find one sepia and one blueline print for the well logs run on the following Endicott wells: Well 1-27/P-20 4/12/91 9800' ~ 10700' '-------'- '" Run One Pedorating Record Halliburton Logging Services Well 1-69/V-19 "- ........ 120' - 2020' ,-2.. d~ Temperature Survey Camco Well 2-06/J-22 12140' - 12205' Tubing Puncher Record Schlumberger 2-22tL-14 11284' - 11700' Perforating Record Schlumberger 9/20/91 Run One 10/26/91 Run One 9/23/'91 Run One 2063/JLH/ctt Alaska Oil and Gas Conservation Commission November 12, 1991 Page Two Well Well 2-22/L-14 (cont'd) 11 283' - 11689' Perforating Record Schlumberger 2-36/O-i 4 ¢' 10800' - 11520' Production Profile Survey Camco Well Well 2-44/R-12 200' - 1200' Injection Profile Survey Camco 2-70/U-15 11 300' - 11700' Perforating Record Schlumberger 3-17/J-30 13200' - 1401 3' Production Profile Survey Camco ' ~ ,,. Well 3-29/J-32 12195'- 12704' ., Dual 'Burst TDT Log (TDT-P) ~i Schlumberger 12180' - 12710' ~ Dual Burst TDT-P Borax Pump-In Schlumberger Well 3-39/J-39 13800' - 1 4426' ., 'i",";' Production Logging Services Atlas Wireline 9/30/91 Run One 8/9/91 Run One 9120191 Run One 10/19/91 Run Three 8/12/91 Run One 8/20/91 Run One 10/27/91 Run Two 8/26/91 Run One 2063/JLH/clt STATE OF ALASKA ALAbKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIOI Perforate Other 1. Operations performed: Operation shutdown Stimulate Plugging . Pull tubing Alter casing Repair well 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1919' SNL, 2224' WEL, Sec. 36, T12N, R16E At top of productive interval 2720' SNL, 3374' WEL, Sec. 25, T12N, R16E At effective depth 2268' SNL, 3389' WEL, Sec. 35, T12N, R16E At total depth 2221' SNL, 3389' WEL, Sec. 35, T12N, R16E 12. Present well condition summary Total depth: measured true vertical 5. Type of Well: Development Exploratory Stratigraphic, Service RECEIVED NOV - 6 1991 Alaska 0il & 6as Cons. 6omm'tssiOn Anchorage 12322'feet Plugs (measured) 10593'feet BKB 11914'feet Junk (measured) 10248'feet BKB 6. Datum elevation (DF or KB) KBE = 55.5 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-22/L-14 MPI 9. Permit number/approval number 89-34/91-296 10. APl number 50- 029-21931 11. Field/Pool Endicott Oil Pool Effective depth: measured true vertical Length Size Cemented Measured depth True ve~.¢~ depth BKB 72' 30 Driven 110' 110' 2460' 13-3/8 3423 c.f. Permafrost 2498' 2498' 11204' 9-5/8 575 c.f. Class G 11242' 9692' measured 1324' 7 428 c.~ Class G 10998'-12322' 9495'-10593' 11600; 11758'-11778? 11783'-11790? 11801'-118057 11809'-11828? 11836'-11905~ 11908'-11929? 11933'-11986? 11991'-11994? 12000'-12016' true vertical (subsea) 9932', 10063'-10079? 10083'-100897 10098'-10102? 10105'-10121? 10127'-10185? 10187'- 10205? 10208'- 10253? 10257'- 10259? 10264'- 10278' Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Tubing (size, grade, and measured depth) 4-1/2" 12.6# TDS tubing with 3-1/2"tailpipe to 11067' Packers and SSSV (type and measured depth) 9-5/8"packer at 10952? 7" WD packer at 117007 4-1/2" SSS V at 1553' 13. Stimulation or cement squeeze summary 14. Intervals treated (measured) Treatment description including volumes used and final pressure ,Representative Daily Average Production or Injectiorl Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Currently shut- in Tubing Pressure Prior to well operation Subsequent to operation 16. Status of well classification as: Oil . Gas . Suspended .... Service Water In/ector 15. Attachments Copies of Logs and Surveys run ..... Daily Report of Well Operations w 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ...Sign.ed ~ /'~ ~ -~-'-~..~ Title Endicott Oper. and Production Lead En,qineer Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Endicott Production Engineering Department ADD PERFORATIONS DATE: 9/30/91 WELL Na: 2-22/L-14 TYPE OF OPERATION: BP EXPLORATION REP: SERVICE COMPANY: PERFORATE M.D. MARTIN SCHLUMBERGER IDATE TIME ] OPERATIONS SUMMARY 9/28/91 1330 RIG UP SCHLUMBERGER 1500 RUN IN HOLE WITH 2-1/8" HYPER DOME GUNS (25A - ULTRAJET) LOADED WITH (1) ONE SHOT EACH. TIE IN TO CBL-GR DATED 4/17/89. POSITION FIRST GUN AT 11,596' (CBL DEPTH) (11,600' DLL DEPTH). WHP = 80 PSI. FIRE GUN. NO CHANGE IN WHP. POSITION SECOND GUN AT 11,596" (CBL). FIRE GUN. WHP = 80PSI. NO SURFACE INDICATION OF COMMUNICATION TO THE FORMATION. POH AND RD SCHLUMBERGER 1730 RIG UP HB&R. ATTEMPT TO PUMP METHANOL DOWN TUBING. WHP = 2700 PSI. FORMATION WILL NOT TAKE FLUID. BLEED OFF TUBING PRESSURE TO 1150 PSI. SECURE WELL. 9/29/30 0730 I WHP = 1150 PSI. NO CHANGE. 1200 I BLEED OFF WHP TO 0 PSI 9/30/91 1000 RIG UP SCHLUMBERGER. RUN IN HOLE WITH 2-1/8" HYPER DOME GUNS (25A ULTRAJET) LOADED WITH '(2) TWO SHOTS EACH. TIE IN TO CBL-GR DATED 4/17/89. POSITION FIRST GUN AT 11,596' (CBL DEPTH) (11,600' DLL DEPTH). WHP = 0 PSI. 1100 FIRE GUN. WHP UP TO 390 PSI. MONITOR WELLHEAD PRESSURE ,, ,, 1200 WHP = 390 PSI.. BLEED OFF TO APPROX. 100 PSI THRU 1/2" HOSE. WHP BUILDS UP TO 390 PSI IN 3 TO 5 MINUTES. REPEAT BLEED OFF (3) THREE TIMES. CONFIRM COMMUNICATION TO FORMATION. POH AND RD SCHLUMBERGER. RECEIVED Alaska Oil 8, ~as Cons. Com~'tss'to~ At .... ~A OIL AND GAS CONSERVATION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown ~ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program__ Pull tubing ~ Variance~ Perforate x Other~ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1919' SNL, 2224' WEL, Sec. 36, T12N, R16E At top of productive interval 2720' SNL, 3374' WEL, Sec. 25, T12N, R16E At effective depth 2268' SNL, 3389' WEL, Sec. 35, T12N, R16E At total depth 2221' SNL, 3389' WEL, Sec. 35, T12N, R16E 12. Present well condition summary Total depth: 5. Type of Well: Development Exploratory ., StratJgraphic Service x RECEIVED SE P 2 ? 1991 Alaska 0il & Gas Cons. CommlSsle[ 6. Datum elevation (DF or KB) KBE = 55.5 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-22/L- 14 MPI 9. Permit number 89-34 10. APl number 50-029-21931 11. Field/Pool Endicott Oil Pool measured true vertical 12322' feet Plugs (measured) 10593' feet BKB Effective depth: measured true vertical 12236' feet Junk (measured) 10520' feet BKB Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured de~ TrueBv/~ical depth 72' 30" Driven 110' 110' 2460' 13-3/8" 3423 c.f. Permafrost 2498' 2498' 11204' 9-5/8" 575 c.f. Class G 11242' 9692' 1324' 7" 428 c.f. Class G 10998'-12322' 9495'-10593' measured 11758'-11778'; 11783'-11790'; 11801'-11805'; 11809'-11828'; 11836'-11905'; 11908'-11929'; 11933'-11986'; 11991'-11994'; 12000'-12016' true vertical (subsea) 10063'-10079'; 10083'-10089'; 10098'-10102'; 10105'-10121'; 10127'-10185'; 10187'-10205'; 10208'-10253'; 10257'-10259'; 10264'-10278' Tubing (size, grade, and measured depth) 4-1/2" 12.6# TDS tubing with 3-1/2"tailpipe to 11067' Packers and SSSV (type and measured depth) 9-5/8"packer at 10952'; 7" WD packer at 11700'; 4-1/2" SSS V at 1553' feet 13. Attachments Description summary of proposal x Detailed operations program x BOP sketch 14. Estimated date for commencing operation September 27, 1991 16. If proposal was verbally approved Name of approver Mike Minder 9/27/91 Date approved 15. Status of well classification as: Oil Gas Service Water Injector Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~- ~ ~---.._...___ Title Endicott Operations & Production Lead Engr. FOR COMMISSION USE ONLY Date 9/27/91 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 0RIGINAt SIGNED BY LON~]!F, P, RIVIITH Commissioner Approved Copy Returned I Appr°val N°'/~/- ~'/?~ Date /~~ ~J SUBMIT IN TRIPLICATE ENDICOTt FIEI~D Well 2-22/L- 14 In order to determine the current 3C reservoir pressure in L-14, we plan to set a plug in the WD packer at 11700' MD and then add one perforation' 11600' BKB (Ref. DLL, 4/12/89) This hole will be perforated using a 2 1/8" gun at 1 shot. A lubricator will be installed and tested to 3000 psi for all well work. The SSSV will be reinstalled and tested after the perforation is added. RECEIVED SEP 2 ? 1991 Alaska .Oil & Gas Cons. Commiss%e~ Anchorage il IBASIC SYSTEM MAKEUP ' BOWEN PACKOFF' ~, o ~, , ~ l~- HAND .PUMP /.~ ~SE SEAL . oWrU E. F'LOWLINE ~ FLOWLINE ~ VALVE :,,." , GREASE LINE GREASE. IS GREASE RESERVO. BOP RECEIVED S E P ~ ? t991 Alaska Oil & Gas Cons. Commission ;Anchorage 1. Type of Request: (' STATE OF ALASKA ~ ~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Ab~don ~ Sus~nd ~ O~rafion Shutdown R~enmr sus~nded well Alter ~ng ~ Repar well ~ Plugging x ~me extension ~ Sdmulate ~ Ch~ge appro~d pr~ram ~ Pull ~bing ~ Vad~ ~ Pedorate ~ ~er~ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) BP Exploration (Alaska)/nc. Development~ KBE = 55.5 feet Exploratory 3. Address Stratigraphic 7. Unit or Property name P. 0. Box 196612, Anchorage, Alaska 99519-6612 service x Duck/s/and Unit/Endicott 4. Location of well at surface 8. Well number 1919' SNL, 2224' WEL, Sec. 36, T12N, R16E At top of productive interval 2720' SNL, 3374' WEL, Sec. 25, T12N, R16E At effective depth 2268' SNL, 3389' WEL, Sec. 35, T12N, R16E At total depth 11. 2-22/L- 14 MPI 9. Permit number 89-34 10. APl number 50- 029-21931 Field/Pool 2221' SNL, 3389' WEL, Sec. 35, T12N, R16E 12. Present well condition summary Total depth: measured true vertical Effective depth: · Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Endicott Oil Pool 12322' feet Plugs(measured)?~, ~, ,,, .- .---. -~ ~ ~.[ I'- IV~ I~l 10593' feet BKB 12236' feet Junk (measured) OCT 0 4 3.990 10520' feet BKB Length Size Cemented Ueasureq~-Rt'{'fa['~~-"~/ffB True ve,ical deCh BKB 72' 30" Driven 110' 110' 2460' 13-3/8" 3423 c.f. Permafrost 2498' 2498' 11204' 9-5/8" 575 c.f. Class G 11242' 9692' 1324' 7" 428 c.f. C/ass G 10998'- 12322' 9495'- 10593' measured 11758'-11778'; 11783'-11790'; 11801'-11805'; 11809'-11828';11836'-11905'; 11908'-11929'; 11933'-11986'; 11991'-11994'; 12000'-12016 true vertical (subsea) 10063'-10079'; 10083'-10089? 10098'-10102'; 10105'-10121'; 10127'-10185'; 10187'-10205'; 10208'-10253'; 10257'-10259'; 10264'-10278' Tubing (size, grade, and measured depth) 4-1/2" 12.6tt TDS tubing with 3-1/2" tailpipe to 11067' Packers and SSSV (type and measured depth) 9-5/8" packer at 10952'; 7" WD packer at 11700'; 4-1/2" SSSV at 1553' 13. Attachments Description summary of proposal ~ Detailed operations program x BOP sketch 14. Estimated date for commencing operation October 1990 16. if proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil Gas Service Water 'Injector Suspended 17. I hereby certify that the foregoing~s true and correct to the best of my knowledge. Signed ,/'~/--¢_.,~n4~y~ ¢ /,~~g4,-x. Title ReservoirDevelopmentCoordinator 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 J Approval No. Commissioner Date lO/d:~ Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY Approved Copy Returned LONNIE C. SMITH JO/j(-.~/OiC',L SUBMIT IN TRIPLICATE 2-22/L-14 In!ection TREATMENT PROCEDURE: . . . . . , Day 8. Day 9. 10. 1655TLR Profile Modificetion W/CTU RIH with slick line to pull SSSV, run a ddft on tubing to ensure no obstruction exists in the wellbore, and to tag PBTD. Last PBTD at 12220' MDBKB on 5/9/90. Block the SSV with a fusible cap and SI the well at the choke, wing valve, and pipe rack. Note wellhead and annulus pressures on telex and prepare to monitor dudng the job. MIRU CTU w/TEL, pump unit, and other required field equipment. Pressure test treating lines, valves, and coiled tubing unit to the swab valve to 4500 psig. Notes' Replace connection dependent O-ring seals on injector head. Ensure weight indicator is reading dead injector weight. Secure injector with chains. Weight checks should be done every 3000' and after each ID restriction. Slow running speed to + 20 FPM through ID restrictions. RIH with 2.25" open nozzle on CT and tie into tubing tail at 11723' for depth control. Tag TD with CT at -12220' MDBKB (5/9/90 tag). Spot 7100 gals (169 BBLS) of seawater containg 7100 lbs of CaCO3 flakes from TD to 12020' MDBKB. Notes: A 20#/1000gal Linear Gel system has been recommended to provide an approximate 1.0 ft/min settling velocity, but the ultimate carrier fluid selected should be tested and optimally recommended by the service company. Ensure the CT is POOH at an equivalent spotting rate. [i.e. CT rate (BPM) / 0.0371 Bbl/ft = POOH rate (FPM) ] 2 BPM = 54 FPM 1 BPM = 27 FPM 7100 lbs of CaCO3 (22.7 ppg-bulk density) in 7"-29#/ft Liner (1.5603 gal/ft) equates to -220' of fill once all particles have settled out of carrier medium. Displace CaCO3 from CT with seawater (CT volume ~23 'BBLS) and Shut down pumps. POOH wi CT and RDMO CTU and service company. Leave well Shut-In until plugback operations are completed in order to facilitate PBTD tags. RIH with slickline w/TEL to verify top of CaCO3 plug. Top of plug should approximate 12020' MDBKB, Notify Anchorage office if results substantially indicate otherwise as the remainder of program computations assume this depth. RDMO and leave well SION. Block the SSV with a fusible cap. Note wellhead and annulus pressures on telex and prepare to monitor during the job. MIRU CTU w/TEL, pump unit, and other required field equipment. Pressure test treating lines, valves, and coiled tubing unit to the swab valve to 4500 psig. Notes' Replace connection dependent O-ring seals on injector head. Ensure weight indicator is reading dead injector weight. Secure injector with c~i~.c E IV E D 2-22/L- 14 Injection · ,ofile Modification w/CTU Weight checks should be done every 3000' and after each ID restriction. Slow running speed to + 20 FPM through ID restrictions. 11. R IH with 2.25" open nozzle on CT and tie into tubing tail at 11723' for depth control. Tag top of CaCO3 plug with CT at -12020' MDBKB and compare to slickline tag. 12. Spot 2000 gals (~48 aBES) of seawater containg 2000 lbs of 20/40 mesh sand from 12020'- 11930' MDBKB. Notes: A 40#/1000gal Linear Gel system has been recommended to provide an approximate 0.5 ft/min settling velocity, but the ultimate carder fluid selected should be tested and optimally recommended by the service company. Ensure the CT is POOH at an equivalent spotting rate. [i.e. CT rate (BPM) / 0.0371 Bbl/ft = POOH rate (FPM) ] 2 BPM -- 54 FPM I BPM = 27 FPM 2000 lbs of 20/40 mesh sand (14.3 ppg-bulk density) in 7"-29#/ft Liner (1.5603 gal/ft) equates to -90' of fill once particles settle from carder medium. 13. Displace sand from CT with seawater (CT volume ~23 aBES) and Shut down pumps. 14. POOH w/CT and RDMO CTU and service company. Leave well SION. Day 4 15. RIH with slickline w/TEL to verify top of sand plug. Top of plug should approximate the target depth of 11930' MDBKB. Notify Anchorage office if results substantially indicate otherwise as the pedorations below 11930' MDBKB (11933-11986, 11991-11994, and 12000-12016 MDBKB) should be completely covered with sand. 16. Place well on a temporary maximum injection rate of 15000 BWPD for a period of 72 hours. POST TREATMENT WQRK: 1. RU slickline unit w/TEL and tag' PBTD once the well stabilizes at a 15000 BWPD injection rate. If PBTD is acceptable, set the SSSV. Return well to allocated rate injection ASAP.~ 2-22/L-14 SUMMARY OF TREATMENT FLUIDS Fluid Volume Additives gal Seawater 7100 (169 aBES) Seawater 2000 (48 aBES) 7100 lbs CaCO3 with 20 #/1000 gal HEC gel (200' of 7"-29#/ft fill from 12220'-12020' MD) 2000 lbs 20/40 Sand with 40 #/1000 gal HEC gel (90' of 7"-29#/ft fill from 12020'-11930' MD) Seawater ~ 2100 (~50 aBES) CT displacement 1655/TLR WELL 1-69N-19 *PRODUCTION PROFILE 12080' - 12850' Camco 6/2/90 Run No. 1 WELL 2-04/M-19 6/16/90 *DUAL BURST TDT LOG (TDT-P) 9798'- 10682' Run No. 1 Schlumberger WELL 2-20/L-15 6/29/90 *DGR/EWR/CNO/SFD 9491'- 10595' Run No. 1-3 Sperry-Sun *DGR/EWR 10347' - 11635' Sperry-Sun Run No. 1-3 *DGR/CNO/SFD 10347' - 11635' Sperry-Sun Run No. 1-3 *FORMATION MULTI-TESTER 10704' - 11198' Run No. 1 Western Atlas *GAMMA RAY (CASED HOLE) 10100' - 10520' Run No. 1 Western Atlas *CEMENT EVALUATION LOG 9515' - 11552' Run No. 1 Schlumberger *CEMENT BOND LOG 9515'- 11528' Schlumberger Run No. 1 *GAMMA RAY- POSTION GUNS 10276' - 10802' Run No. 1 Schlumberger WELL 2-22/L-14 *INJECTION PROFILE 11080' - 12220' Camco 519190 Run No. 1 7/2/90 7/2/90 7/3/90 *DGR/CNO/SFD 10557' - 11463' Sperry Sun Run No. 1 *FORMATION MULTI-TESTER 10636' - 11182' Run No. 1 Atlas *CBT 10160 - 11348 Schlumberger Run No. 1 *CET 10160' - 11370 Schlumberger Run No. 1 WELL 2-22/L-14 *TEMPERATURE LOG 11080' - 12235'" Camco Run No. 2 WELL 2-36/O-14 *COLLAR LOG 10160' - 11260' Atlas Run No. 1 WELL3-01/N-2~ STATIC TEMPERATURE SURVEY 12250' - 12953' Run No. 1 Camco .,.WELL 3-07/N-28. *TEMPERATURE LOG 13000' - 13400' Camco Run No. 1.' WELL 3-39/J-39 *TDT-P 14120' - 14636' Schlumberger Run No 1 ,.WELL 3-49/Jr40 *DUAL STATIC SURVEY 14922' - 14934' Schlumberger Run No. 1 WELL 4-04/T-26 *INJECTION PROFILE LOG 13575' - 13975' Run No. 1 Camco *TEMPERATURE LOG 13100' - 14037' Camco Run No. 1 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 December 19, 1989 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Endicott Field - Bottom-Hole Pressure Reports Dear Sirs: Enclosed are Bottom Hole Pressure Reports for the following wells. Well Name Date ~-22/L-14 2-52/S-14 3-05/O-29 3-1 l/M-30 3-35/L-36 4-14/R-34 5-03/SAG 9. 5-03/SAG 9 10/23/89 11/24/89 11/27/89 10/28/89 11/11/89 10/22/89 11/24/89 11/25/89 If there are any questions regarding this data, please, contact Dave MacDonald at 564-4697. R'ECEIVED DEC2 1989/ ' &l~tSka OJJ & Gas Cons. C0mmiSsi0.~ Anchorage Sincerely, ~itanne L. Haas JLH Enclosures cc: File: 76.13 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 November 7, 1989 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Boyle: Enclosed please find one sepia and one blueline print for the well logs run in the following Endicott wells: WELL 2-22/L-14 *TEMPERATURE LOG 11500'-12100' CAMCO Run No. 1 WELL 4-14/R-34 *INJECTION PROFILE TEMPERATURE SURVEY 10000'-10640' Run No. 2 CAMCO WELL 3-21/L-34 *PRODUCTION PROFILE 12300'-12857' CAMCO Sincerely, Lyn~la M. Stamper '\ .... Run No. 1 Anchorage LMS BP EXPLORATION August 16,1989 BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re' Endicott Well Log Information Dear Mr. Boyle: Enclosed please find one L.I.S. (data format) tape and computer read-out sheet for the open hole run in the following Endicott wells: 3-17/J-30 50 029 21946 00 2-22/L-14 50 029 21931 00 4-46/N-39 5O O29 21957 00 Sincerely, GND/Ims cc: File 06.10 1O94/GND BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 July 24, 1989 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Boyle' Enclosed please find one sepia and one blueline print for the well logs run in the following Endicott wells: '~'~ELL 1-63/T-22 APl No 50 029.21905 Run No. 2 *PRODUCTION PROFILE 12000'-12660' 5 inch log scale _ logged by Camco WELL 3-41/K-39 6/7/89 cased hole well APl No 50 029 21878 Run No.1 *COLLAR LOG 13300'-13638' 6/12/89 5 inch log scale cased hole well logged by Atlas Wireline Services ~"-~WELL 3-01/N-29 APl '50 029 21678 Run No.1 *SPINNER HP PRESSURE TEMPERATURE LOG 12280'- 12730' 4/23/89 5 inch log scale cased hole well logged by Halliburton WELL 2-70/U-15 APl 50 029 21899 Run No.2 *PERFORATING RECORD 11190'-12050' 6/19/89 5 inch log scale cased hole well logged by Schlumberger '~'~ WELL 2-68/S-17 APl 50 029 21858 Run No.1 '"---,_~*PRESSURE BUILD UP SURVEY 10023'-11200' 3/24/89 no log scale cased hole well "~ PRODUCTION LOG 10600' -11000' 6/11/89 5 inch log scale cased hole well logged by Schlumberger WELL 1-27/P-20 APl 50 029 21693 Run No.1 '~"~*PRODUCTION PROFILE LOG 990o'-10850' 6/27/89 5 inch log scale cased hole well logged by Camco W, ELL 2-22/L-14 APl 50 029 21931 "'"-~*INJECTION PROFILE LOG 11748'-12100' 6/14/89 5 inch log scale cased hole well logged by Camco Run No. 1 W~ 2-04/M-19 APl 50 029 21586 Run No.1 TEMPERATURE LOG 10100'-10660' 6/13/89 5 inch log sCale cased hole well · logged by Camco 1-08/K-16 APl 50 029 21676 Run No.1 RODUCTION PROFILE LOG 11700'-12200' 6/9/89 5 inch log scale cased hole well logged by Camco WELL 3-17/J-30 ""--'*CEMENT APl 50 029 21946 Run No.1 EVALUATION LOG 13040'-14004' 7/3/89 5 inch log scale cased hole well CEMENT BOND LOG 103040' - 14004' 7/3/89 5 inch log scale cased hole well GAMMA RAY- CCL 13100' - 13700' 7/5/89 5 inch log scale cased hole well logged by Schlumberger '"-"" Alaska 0il & Bas Cons. C0rnmissi0~ Anch0ra,~e WELL 4-50/K-41 APl 50 029 21940 Run No.1 & 2 ""'J'PERFORATING RECORD 13553'-13564' 6/22/89 Run 1 ~,.<5 inch log scale cased hole well *PERFORATING RECORD 13260' - 13820' 7/8/89 Run 2 5 inch log scale cased hole well logged by Schlumberger WELL 2-46/Q-15 APl 50 029 21921 Run No.1 ~*PRODUCTION PROFILE 10600'- 11000' 6/21/89 2 & 5 inch log scale cased hole well '""*TEMPERATURE SURVEY 10600' - 11100' 6/24 & 25/89 2 inch log scale logged by Otis WELL 3-17/J-30 APl 50 029 21946 Run No.1 ~ *DUAL LATEROLOG MICROSPHERICALLY FOCUSED LOG 13382'- 14102' 3/8/89 --,...~. 2 & 5 inch log scale open hole well *COMPENSATED SONIC LOG 13382' - 14080' 6/29/89 2 & 5 inch log scale open h01e well ~*DUAL INDUC.T!ON LATEROLOG 13382' - 14105' 6/29/89 .. 2 & 5 inch log scale open hole well ~ *SPECTRAL DENSITY DUAL SPACED NEUTRON LOG 13382' - 14103' 6/29/89 2 & 5 inch log scale open hole well *FORMATION TEST LOG no depths 6/29/89 no log scale open hole well logged by Halliburton Sincerely, GD/Ims File 06.10 ~' A~.as~ Oil & Gas C~ons. CommissWl~ WELL 2-44/R-12 ~'*INJECTION PROFILE 12000'- 12710' CAMCO Run 1 WELL 3-27/M-33 ~*TEMPERATURE LOG 11500' - 12084' HALLIBURTON Run 1 ,WELL 4-20/M-35 *PRODUCTION PROFILE 11550' - 11850' CAMCO Run 1 WELL 2-44/R-1:2 *COLLAR LOG 12240' - 12660' Run 1 ATLAS WIRELINE sERVICES WELL 1-43/P-~0 *DUAL BURST TDT LOG (TDT-P) 12995' - 14270' SCHLUMBERGER WELL 3-05/0-29 *DUAL BURST TDT LOG (TDT-P) 11650' - 12567' HALLIBURTON ,WELL 2-2;2/L-14 *COMPLETION RECORD 11027' - 11715' *CEMENT EVALUATION LOG (ET) 9578' - 12240' *CEMENT BOND 'LOG (CBT) 9578' - 12216' SCHLUMBERGER WELL 1-49/P-21 *PRODUCTION PROFILE LOG 10700' - 11200' CAMCO 1027/GD ,WELL 4-2~)/N-37 *LEAK DETECTION LOG 10320' - 11710' CAMCO WELL 4-26/O-34 *TEMPERATURE LOG 10900' - 11730' CAMCO Enclosed please find one sepia and one blueline print for the open hole well logs run on the following Endicott Wells' WELL 2-70/U-15 ~ *REPEAT FORMATION TESTER 11555'-12220' Run 1 *COMPENSATED NEUTRON - LITHO-DENSITY 0900' 12212' ~ *D1UAL Ir~DUCTION- SFL 10900' - 12254' ~*SUBSEA TVD LOG 10900' - 12250' "~*DUAL LATEROLOG MICRO- SFL ~-~, ~,,.. 10500' - 12250' *BOREHOLE COMPENSATED SONIC LOG 10900' - 1220' SCHLUMBERGER WELL 2-46/Q-15 *GAMMA LOG 8800' - 11344' HALLIBURTON Run 1 ,WELL 2-.~2/L-14 ~ *DDL- I SELECTIVE FORMATION TESTER ,~,, No Log Depth Run 1 *SPECTRAL LITHO DENSITY COMPENSATED NEUTRON LOG ~ , 11242' - 12330' DUAL LATEROLOG MICROLOG ~ 10800'- 12338' *DUAL INDUCTION GUARD LOG 11228'- 12330' "~ *MICRO LOG 1027/GD 11228' - 12330' HALLIBURTON PERIOD OF CONFIDENTIALITY DATE OF COMPLETION, SUSPENSION OR ABANDONMENT 30-DAY FILING DATE RELEASE DATE COMMENTS BY fp~ DATE · B.RPC. 02 (05/89) BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5'111 June 2, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Attn' Mr. C. V. Chatterton Well 2-22/L-14 MPI (Endicott) Enclosed, in duplicate, is form 10-407, our Report of Well Recompletion for the above named well. This information reflects the current condition and status of the well. Also enclosed are two copies each of daily drilling reports, directional and gyroscopic surveys The open hole logs were sent under separate cover by the BP Endicott department. Yours very truly, Drilling Engineering Supervisor JGV/KTH Enclosures (4) J. OIdenburg (MB 7-1) Endicott WlO's w/4 Well File RECEIVED Alaska.Oil & Gas Cons. Commission ' ~,~.~: ~nchorage ., STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLF_.TION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] Water Iniector 2. Name of Operator 7. Permit Number BP Exploration 89-34 3. Address 3. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 5o- 029-21931 4. Location of well at surface 9. Unit or Lease Name Duck Island Unit/Endicott 1919' SNL, 2224' WEL, SEC. 36, T12N, R16E ' i~~N~ 10. Well Number At Top Producing Interval V~RIFI'ED 2-22/L-14 MPI 2720' SNL, 3374' WEL, SEC. 25, T12N, R16E Su~'f._~ 11. Field and Pool At Total Depth ~,. H...~"~ Endicott Field/Endicott Pool 2221'SNL, 3389' WEL, SEC. 25, T12N, R16E~' 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 55.5' I ADL 34633 12. Dale Spudded 13. Date T.D. Reached 14. Date Comp., Susp."~)r Aband." 115. Water Depth, if ottshore 116. No. of CompJelions 03/26/89 04/11/89 04/19/89I 6 - 12 feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 12322'MD/10593'TVD 12236'MD/10520'TVD YEs [] NO []I 1555feet MD 11466' 22. Type Electric or Other Logs Run DLL/MG/GR, GR/CNS/.F.L T/DI.L, RFT, SLD/GR/CNT .. 23. CASING, LINER AND CEMENTING RECORD ...... SETTING DEPTH MD CASING SIZE VVT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" ' ..... Structural Drive Pipe .... Surface 110' 13-3/8" 68# NT80 Surface 2498' 17-1/2" 3423 cu ft permafrost ........... 9-5/8" 47# NT80S Surface 9403' 12-1/4" 9-5/8" 47# NT95HS 9403' 11242' 12-1/4" 575'cu ft Class G 7" 29// NT95H S 10998' 12322' 8-1/2" 428 cufl Class G , ,, 24. Perforations open to Production (MD+TVD of Top and'Bottom and 25. ~'UBING RECORD interval, size and number) SIZE "'DEPTH SET (~ID) PACKER S~'I' (MD)" SchlumbergerS"@4spf MD rVDss .... 4'1'/2" 12.6# 11067' 10952' 11758'- 11778' 10063'- 10079' . .......... 11783'. 11790' 10083'- 10089' W/3-1/2" tailpipe .... 11801'- 11805, 10098'- 10102' ;)6. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11809'- 11828' 10105,- 10121' DEF;~'H INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11836'- 11905' 10127'- 10185' ......... 11908'- 11929' 10187'. 10205' 13-3/8"x 9-5/8" Down Squeezed Annulus w/160 BBLS 11933'- 11986' 10208'- 10253' . . Dry Cru,d..e.. ..... 11991'- 11994' 10257'- 10259' 12000'-12016' 10264'. 10278' ' ' ....... 27. PRODUCTION TEST Dale First Producti°n IMethod of Operation (Flowing, gas lift, etc.) ' ' April 17, 1989 . I Flowing Date of Test Hours Tested PI:~ODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE iGAS-OIL RATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA ......... Brief deScriPtion of litl~ology, porosity,' fractures, apparent dips, and presence of oil. gas or water. Submit core chips. · .... RECEIVED JUN o 5 t989 Alaska.Oil ,& Gas Cons. Commission Submit in duplicate Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. " GEOLOGIC MARKERS FORMATION TESTS NAME Include interval lested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOP HRZ 10917' 9432' ITKIL YARIAK 11249' 9697' KEKIKTUK 11416' 9835' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to lhe best of my knowledge Signed ~~~/~~ TitleDrillin.qEn.qineerin.qSupe~isor Date ~-"'/~///~"' INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shoWn) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If. no cores taken, indicate "none". Form 10-407 BP EXPLORATION Daily Drilling Report -- ENDICOTT March 27, 1989 at 0600 hrs ,ig: DOYON 15 (ell: 2-22/L- 14 (M. PI) AFE # 717567 APl: 50-029-21931 AFE Amount: Current Amount: 0600 Depth: 2510' Day: 2 48 - Hour Ftg: 2510' '.urrent Operation: Waiting on cement. Accept rig on well 2-22/L-14 @ 0900 hrs. on 3-25-89. Spud well @ 1200 hrs. on 3-25-89. Drill and survey 17-1/2" hole to 2510'. Circulate and condition hole for casing. POH. Run 13-3/8" casing and cement with Permafrost cement. ~Iud Type: FW/GEL SURVEY ~ WT: 9.5 VIS: 65 PV: 15 YP: 15 FL: 20 Solids: 8 Temp: °F ANGLE D ,I~... ECTION TVD SE(TI'ION COORDINATES. DLS. BP EX~ORATK)N '.ig: DOYON 15 ~rell: 2-22/L- 14 (MPI) Daily Drilling Report-- ENDICOTT March 28, 1989 at 0600 hrs AFE # 717567 API: 50-029-21931 AFE Amount: Current Amount: .'urrent Operation: 0600 Depth: 3353' Day: 3 24- HourFtg: 843' Tripping for motor. NU wellhead. Drill cement from 13-3/8" casing. Drill and survey 12-1/4" hole to 3353'. vlud Type: FW/GEL SURVEY MD,. WT: 9.2 VIS: 38 PV: 7 YP: 8 FL: 22 Solids: 4 Temp: 54 °F ANGLE. DIRE~'T.,!ON. TVD ~.ECTION COORDINATES DLS BP EXPLOR~'~ON Daily Drilling Report -- ENDICOTT March 29, 1989 at 0600 hrs ',ig: DOYON 15 Veil: 2-22/L- 14 (MPI) AFE # 717567 A.PI: 50-029-21931 AFE Amount: Current Amount: 0600 Depth: 4684' Day: 4 24- HourFtg: 1331' ;urrent Operation: Tripping for bit and BHA change. Drill and survey 12-1/4" hole to 4684'. /Iud Type: LIGNO ,~I,)'RVEY MD WT:9.3 VIS:37 PV:7 ANGLE DIRECTION TVD YP: 11 FL: 17.2 SECTION Solids: 7 Temp: COORDINATES DL$. i BP EXPLOR~N Daily Drilling Report-- ENDICOTT March 30, 1989 at 0600 hrs Rig: DOYON 15 Well: 2-22/L-14 (MPI) AFE # 717567 APl: 50-029-21931 AFE Amount: Current Amount: 0600 Depth: 6275' Day: 5 24- Hour Ftg: 1591' Current Operation: Drilling 12-1/4" hole. Drill and survey to 6275'. Mud Type: LIGNO WT: 9.5 VIS: 38 PV: 10 YP: 10 FL: 12.8 SURVEY ~ ANQLE 19 5207 38.4 23 5969 37.6 DIRECTION N20W N20W TVD 4912 5574 ECT ON 786 1252 Solids: 7 Temp: 62 °F COORDINATES. N753 W246 N1195 W407 DL~ 0.3 0.2 Daily Drilling Report-- ENDICOTT March 31, 1989 at 0600 hfs ,{ig: DOYON 15 ;Veil: 2-22/L-14 (MPI) AFE # 717567 APl: 50-029-21931 AFE Amount: Current Amount: 0600 Depth: 7125' Day: 6 24- Hour Ftg: 900' 2urrent Operation: Drilling 12-1/4" hole. Drill and survey to 7125'. Mud Type: LIGNO WT: 9.6 SURVEY MD ANGLE 28 7048 36.9 VIS: 39 PV: 13 DIRECTION N12W TVD 6439 YP: 9 FL: 8.9 SECTION 1890 Solids: 8 Temp: 81 °F COORDINATES. DLS N1802 W625 1.7 BP EXPLOR,~;T}CN Daily Drilling Report -- ENDICOTT April 3, 1989 at 0600 hrs ig: DOYON 15 ~ell: 2-22/L-14 (MPI) AFE # 717567 APL 50-029-21931 AFE Amount: Current Amount: 0600 Depth: 9410' Day: 9 72- Hour Ftg: 2285' lurrent Operation: Drilling 12-1/4" hole Drill and survey to 9410'. iud Type: LIGNO WT: 9.8 VIS: 38 PV: 14 ;URVEY MD,. ANGLE 33 7949 36.1 36 8533 36.7 40 9292 39.8 DIRECTION NllW NllW N02W TVD 7161 7632 8227 YP: 9FL: 5.4 SECTION 2428 2774 3244 Solids: 9 Temp: COORDINATES N2328 W739 N2667 W805 N3133 W875 82°F DL$. 0.3 0.2 1.7 8P Daily Drilling Report-- ENDICOTT April 4, 1989 at 0600 hrs ig: DOYON 15 Tell: 2-22/L-14 (MPI) AFE # 717567 APl: 50-029-21931 AFE Amount: Current Amount: 0600 Depth: 967 6' Day: 10 24- Hour Ftg: 266' ',urrent Operation: Drilling 12-1/4" hole. Drill and survey 12-1/4" hole to 9676'. lud Type: LIGNO iURVEY 41 9572 WT: 10.0 VIS:38 PV:10 ANGLE DIRECTION 40.4 N08W TVD 8441 YP: 10 FL: 5.6 SECTION 3423 Solids: 10 Temp: 90 ~F COORDINATES DLS N3312 W890 1.5 ~P E~..OR~N Daily Drilling Report-- ENDICOTT April 5, 1989 at 0600 hrs Jig: DOYON 15 Veil: 2-22/L- 14 (MPI) AFE # 717567 API: 50-029-21931 AFE Amount: Current Amount: 0600 Depth: 10122' Day: 11 24- Hour Ftg: 446' .'urrent Operation: Trip for bit. Drill and survey 12-1/4" hole to 10122'. elud Type: FW/LIG WT: 10.0 SURVEY MD. ANGLE 44 10042 43.7 VIS: 40 PV: 15 DIRECTION N08W TVD 8790 YP: 12 FL: 5.6 SECtiON 3737 Solids: 10 Temp: 92 °F COORDINATES_ DL$. N3622 W942 1.0 Daily Drilling Report-- ENDICOTT April 6, 1989 at 0600 hrs ,~: DOYON 15 ;11: 2-22/L- 14 (MPI) AFE # 717567 API: 50-029-21931 AFE Amount: Current Amount: 0600 Depth: 10485' Day: 12 24- Hour Ftg: 363' rrent Operation: Drilling 12-1/4" hole. Drill and survey to 10485'. ~d Type: FW/LIG IRVEY, MD 45 10212 WT: 10.2 VIS:37 PV: 14 ANGLE DIRE~FION 44.2 N07W 8913 YP: 10 FL: 5.2 SECTION 3855 Solids: 12 Temp: 94 °F COORDINATES_ DL$ N3739 W958 0.5 8P E~iPLORA]'~CN Daily Drilling Report -- ENDICOTT April 7, 1989 at 0600 hrs [g: DOYON 15 'ell: 2-22/L-14 (MPI) AFE # 717567 APl: 50-029-21931 AFE Amount: Current Amount: 0600 Depth: 10865' Day: 13 24- Hour Ftg: 380' arrent Operation: Drilling 12-1/4" hole. Drill and survey to 10865'. Iud Type: FW/LIG WT: 10.2 URVEY MD ANGLE 47 10595 42.8 VIS: 40 PV: 15 DIRECTIQN N07W 9190 YP: 10 FL: 5.4 SECTION 4118 Solids: 12 Temp: 96 °F COORDINATES. DLS N4001 W992 0.6 BP EXP~OR,~'ICN Daily Drilling Report-- ENDICOTT April 10, 1989 at 0600 hrs Rig: DOYON 15 Well: 2-22/L- 14 (MPI) AFE # 717567 API: 50-029-21931 AFE Amount: Current Amount: 0600 Depth: 11495' Day: 16 72- Hour Ftg: 630' Current Operation: Drilling 8-1/2" hole. Drill to 12-1/4" hole TD @ 11252'. Run and cement 9-5/8': casing; shoe @ 11242'. Test casing and drill out cement. Mud Type: F'W/LIG WT: 10.2 VIS:37 PV: 10 YP: 10 FL: 4.8 Solids: 11 Temp: 114 °F SURVEY MD. ANQLE. DIRECTION TVD. SECTION COORDINATES. DLS 51 11252 34 N05W 9702 4527 N4409 W1037 1.5 BP E~]~I. OR~N Daily Drilling Report -- ENDICOTT April 11, 1989 at 0600 hrs ~ig: DOYON 15 ~Vell: 2-22/L- 14 (MPI) AFE # 717567 API: 50-029-21931 AFE Amount: Current Amount: 0600 Depth: 11899' Day: 17 24- Hour Ftg: 404' 2urrent Operation: Tripping for bit. Drill 8-1/2" hole to 11899'. .~iud Type: FW/LIG SURVEY, MD WT: 9.7 VIS: 37 PV: 11 ANGLE DIRECTION TVD, YP: 10 FL: 5.8 SECTION Solids: 8 Temp: 102 ~F COORDINATES DLS BP EXPLOR~ION Daily Drilling Report -- ENDICOTT April 12, 1989 ~t 0600 hrs Rig: DOYON 15 Well: 2-22/L- 14 (MPI) AFE # 717567 APl: 50-029-21931 AFE Amount: Current Amount: 0600 Depth: 12323' Day: 18 24- Hour Ftg: 424' Current Operation: POH to mn logs. Drill 8-1/2" hole to TD @ 12323'. Circulate and condition hole. Mud Type: LIGNO SURVEy MD WT: 9.7 VIS: 38 PV: 10 YP: 9 FL: 5.6 ANGLE DIRECTION TVD SECTION Solids: 9 Temp: 102 °F COORDINATES DLS BP EXPLORAT~CN Daily Drilling Report -- ENDICOTT April 13, 1989 at 0600 hrs Rig: DOYON 15 ~Vell: 2-22/L- 14 (MPI) AFE # 717567 API: 50-029-21931 AFE Amount: Current Amount: 0600 Depth: 12322' Day: 19 24- Hour Ftg: 0 Current Operation: Making wiper trip. Run open hole logs: DLL/MG/GR, CNS/FLT/DIL/GR, RFr. Mud Type: LIGNO SURVEY MD. WT: 9.9 VIS: 39 PV: 11 YP: 9 FL: 5.6 ANGLE DIREQI'IQN TVD SECTION Solids: 10 Temp: 102 °F COORDINATES DLS. ?L Daily Drilling Report -- ENDICOTT April 14, 1989 at 0600 hrs Rig: DOYON 15 Well: 2-22/L- 14 (MPI) AFE # 717567 APl: 50-029-21931 AFE Amount: Current Amount: 0600 Depth: 12322' Day: 20 24- Hour Ftg: 0 Current Operation: POH to mn 7" liner. Run open hole logs: SLD/CNT/GR, RFr. Make wiper trip. Mud Type: LIGNO WT: 9.9 VIS: 39 PV: 11 YP: 9 FL: 5.6 SURVEY MD ANGLE DIRECTION TVD SECTION Solids: 10 Temp: COORDINATES, DL$. BP KXi~I. ORJ~ION Daily Drilling Report -- ENDICOTT April 17, 1989 at 0600 hrs Rig: DOYON 15 Well: 2-22/L- 14 (MPI) AFE # 717567 API: 50-029-21931 AFE Amount: Current Amount: 0600 Depth: 12236' PBTD Day: 23 72- Hour Ftg: 0 Current Operation: Flowing well. Run and cement 7" liner; shoe @ 12322'. Drill cement and test liner and lap to 3000 psi - OK. Displace well to filtered 9.0 ppg brine. Run CET/CBT logs. Perforate well with drillpipe conveyed guns. Mud Type: BRINE ,~UR,VEy MD WT: 9.0 VIS: PV: YP: FL: Solids: Temp: °F ANGLE DIRECTION TVD SECTION COORDINATES DL$. BP EXPLOR.ZQ'~N Daily Drilling Report -- ENDICOTT April 18, 1989 at 0600 hrs Jig: DOYON 15 Veil: 2-22/L-14 (MPI) AFE # 717567 API: 50-029-21931 AFE Amount: Current Amount: 0600 Depth: 12236' PBTD Day: 24 24- Hour Ftg: 0 ;urrent Operation: Running Gyro survey. Fire guns and flow well. Reverse out and spot pill. gyro. POH and LD guns. RU and running /Iud Type: BRINE ;URVEy MD WT: 9.0 VIS: PV: YP: ANGLE DIRECTION TVD SECTION Solids: Temp: °F COORDINATES DL$ BP EXIt. ORaN Daily Drilling Report -- ENDICOTT April 19, 1989 at 0600 hrs Rig: DOYON 15 Well: 2-22/L- 14 (MPI) AFE # 717567 APl: 50-029-21931 AFE Amount: Current Amount: 0600 Depth: 12236' PBTD Day: 25 24- Hour Ftg: 0 Current Operation: Testing packer. RIH with 7" WD packer and tailpipe and set at 11700'. RU and mn 4-1/2" robing. NU and test tree. Set plug in tailpipe and set packer. Testing packer. Mud Type: NaCL SURVEY MD WT: 9.0 VIS: PV: YP: FL: Solids: Temp: ANGLE DIRECTIq)N, TVD SECTION COORDINATES DLS, BP EX]q. OR~ION Daily Drilling Report .- ENDICOTT April 20, 1989 at 0600 hrs .tig: DOYON 15 ~rell: 2-22/L- 14 (MPI) AFE # 717567 APl: 50-029-21931 AFE Amount: Current Amount: 0600 Depth: 12236' PBTD Day: 26 24- Hour Ftg: 0 2urrent Operation: Rig released. Displaced robing annulus to 9.6 ppg. brine and freeze protect. Install BPV and release rig 1600 hrs. 4-19-89. .Vlud Type: NaCL SURVEY MD WT: 9.6 VIS: PV: YP: FL: Solids: Temp: °F ANGLE DIRECTION TVI> SECTION COORDINATES DL$. ~OMP~NY BP ID(PLO~TION WELL ~ MPI 2-2Z/L-14 LOC~TI~ 1 NORTH SLOPE BO~I]UDH LOC~TION 2 M~&'I~'~'IC DI~CLIN~TION 91.0~ D~T£: 0~-~-87 W~L NU~ 22 W~L ~ LOC~TION: L~T(N/-S} 0,00 AZIHUTH ~OM ROTARY TAB~ TO TARGET IS TI£ IN POINT(TIP): ME~SUR£1) DEPTH 0,00 TRtE VI~RT I)£PTH 0,00 INCLINATION AZIMUTH 0.00 LATITUI)£{N/-S) 0.00 D~'ARTUR]~(~-W) 0,00 D~(£/-W) 0.00 348,48 P1EASURED INH~RVAL VERTICAL DEPTH DEPTH ft ft ft 0,00 0.0 0.00 479.00 477,0 479,00 985.00 506.0 985,00 1479,00 4?4,0 1478,98 1930,00 451.~ 1929.96 ~Rb~ CALCULA?IDNS RADIUS OF CURVAllJRE -t~THOI)~,w~ T~£T STATION ~I~ITH $£CTI~ I~LN, N/-$ ft d~ d~ ft 0.00 0.00 0.¢0 0.00 0.08 0.25 190.00 -0,85 0,00 210.00 -1,09 -2.72 0,~ 236,00 -3.44 -4.65 0.25 222.~) -6.02 i MI 2-22/L-14 DEPARlUR£ I)ISPLACI~£NT at E/-W ft ft 0.00 0.00 -0,70 0,70 -1.07 1.53 -3.26 4.74 -6.23 8.66 AZIIII. ITH deg 0.00 265,00 224,51 223.49 deq/ lOOf: 0.00 0,05 0.05 0.15 0,11 2478.00 2718.00 3(X)4.00 3263,00 3394.00 548.0 2477.94 240.0 2717.93 2~6.0 3003,93 259,0 3262.90 131,0 33~.84 '8,91 0,75 130.00 -10.30 -10.42 0.10 144.00 -11,60 -11.57 0,40 148,00 -12,63 -11.85 1.25 45.00 -12.26 -8.81 2.10 3,00 -8,84 -5.93 11,88 209,92 0.15 -4.72 12.52 202,13 0,27 -4,02 13,25 I97,~ 0,10 -0,79 12.27 1~o70 0,54 0,73 8.87 175,29 1.I0 3584.00 3773,00 3963.00 4150,00 4350,00 190,0 3583.04 1~9.0 3768.51 190,0 3949,55 187,0 4120,17 200,0 4295.24 7.55 7.90 350.00 7.65 -0.28 7.65 357,91 3,09 43.43 14,00 348,00 42.87 -7.13 43.46 350.56 3,23 !00,67 21.10 347.00 98,77 -19,52 100.68 348,82 3.74 176,89 27,I0 344,00 172,65 -38,63 176,92 347,39 3.27 272.89 30,70 340,00 264.54 -68,48 273,26 345.49 2.04 4539,00 4633,00 4822,00 5012.00 5207.00 I89,0 4452.59 94,0 4527,11 189,0 4&74,20 190.0 4821,75 I95.0 4974,04 376,15 36,50 339,00 362,47 432.74 38.60 340.¢0 416,13 549,80 39,20 ::L~,O0 526,92 667.86 38,90 340.~0 638.67 788.31 38,40 340.00 7'53.11 -105.10 377,40 343.83 3.08 -125,16 434.54 34~.26 2.33 -167,69 552,96 342.35 0.74 -210,58 672.49 341.75 0.68 -252.24 794,23 341,48 0,26 5397,00 5774,00 6157,00 190,0 5122.95 191,0 5272,73 186,0 5419,00 195.0 5573.08 168,0 5722.73 905,04 38,40 340.00 864,01 1022.10 38.30 33%00 975,01 1135,59 38.00 340,Q0 1082.64 1253,80 37,60 340,00 1194,95 1366.20 36,90 339.00 1301,53 -292.60 912.21 341.~ 0.00 -334,I0 I030,67 341.09 0,33 -374,34 1145,53 340.~3 0.37 -415.22 1265.03 340,84 0,20 -455,07 1378.79 340.73 0,49 6341,00 6529,00 6725,00 7048,00 7193.00 7381,00 7572.00 7696,00 7949.00 814~,00 1~4,0 5870,54 188,0 6022,15 196,0 6179,71 ~3,0 6439.18 145,0 6555,37 188,0 6705.51 l?I.O 6858.35 124,0 6957,90 253,0 7161,92 197,0 7321,00 1474.28 36,20 93%00 1403,83 1589,77 ~.30 338,00 1507.27 1698,58 36,70 337.00 1615,74 18~,02 36.40 348.00 1799.98 1976,74 37,10 346.00 1884.51 2089,81 36,90 347,00 1994,52 2204,33 '36.80 348,00 2106,35 2278,26 36,40 348.00 2178,66 2427.86 36,10 348.00 2325,00 2544,06 36,20 349.¢0 2438,87 -494.34 1488,32 340,60 -535,08 1599.43 340.46 -577,81 1715.95 340,32 -632,38 1907,84 340.64 -651,?0 1994,08 340,92 · 0.38 0.32 0.37 1,66 0,96 -678.31 2106,71 341,22 0,34 -703,10 2220,60 341,54 0,32 -718.47 22?4,08 341.75 0,32 -749,58 2442,84 342,13 0,12 -772,75 2558,36 342,42 0.30 8339,00 8533,00 8713.00 8902,00 9096.00 1'73.0 7476,64 194,0 7632,59 1.50.0 7775,96 18%0 7924.79 194,0 8076,20 2658.18 . 36.30 ~ 347,00 2530,50 2773,57 36,70 349,¢0 2663,37 2882,37 37,70 350,00 2770.37 2998,84 38,40 349, O0 2884,90 3120,00 3%00 353,00 3004,68 -796.47 2671,97 342.66 -820,47 278~,88 342,88 -840,30 2895.00 343,I3 -861,53 3010,80 343,37 -880,50 3131.04 343,67 0,61 0,65 0,65 0,49 1,33 ' F'AGE NO, :3 i' MPI 2-22/L-I4 MEASURED !N?I~UAL UERTICAL I)~TH DEPTH ft ft 9292.00 176,0 0227.65 9572,00 280,0 8441.83 975'5, O0 183.0 8580,04 ~940.00 185,0 8717.09 10042.00 102.0 8791.32 10212.00 10405.00 10595,00 10783.00 10970,00 11178,00 11252.00 170,0 8913.71 1~.0 9052.&6 170,0 9191,04 188,0 9330.77 187.0 9475,04 2~,0 9642.01 74,0 9702.99 ************* ANADRILL ~******~ SU~EY CALCULATIONS ~* RADIUS OF Ct~VATURE M£~O0~**~** TARG~ STATION AZI~TH SELTION INCI, N. N/-S ft deq deq ft 3243.43 39,80 358,00 3128,67 3422,38 40.40 353.03 3308.41 3542,18 41,50 349,00 3426,84 3~.3~ 42,90 351 .¢0 3549.21 3736,25 43,70 352.00 3618.40 I~TITUD£ DEP~TU~E DISPL~I~ENT ~t ~/-}~ ft ft -890.25 3252,86 -v~04.40 342~,80 · -923.16 3549,01 -944.74 3672,80 -~5,08 3742,32 3853,94 44.20 353.03 3735,37 3987,55 43,70 352.00 38&8.17 4117.41 42,80 353.03 .3997,24 4242.48 41.00 3~4.00 4121,98 4361,20 38.20 353.C0 4240,40 ~ZIMUTH 344.12 344.Yl 344.92 345,09 345.21 4484,62 35,00 355,® 4363,71 4526,26 34,00 355.~0 4405,46 deg/ lOOft 1,67 1,17 1,55 1.05 1.03 -970,48 385?,38 345,44 0,50 -987.76 3992,34 345,67 0.44 -1004,95 4121,63 345,8? 0,60 -1019,16 4246,10 346,11 1,02 -1032,65 4364+32 3~,31 1.54 -1045.61 4487,23 346,53 -1049.27 4528.69 34~.60 1,64 1.35 COMPANY BP EXPLORATION WELL HAi~ PPI 2-22/L-14 LOCATION 1 HO~t:H SLOPE BOROUGH LOCATION 2 ALASI(A I~TE: 08-APR-89 MA~N£T]C DECLINATION 31,0~ ~L NUMBB~ 22 ~AG~ NO. 2 ,::::xx:***** ANAl)RILL ************** SURV~ AIqALYSIS ***** RADIUS OF CUR~ATL~ !'" ~PI 2-22/L-14 ft ~ INC_CHG CUMIFtC_CHG I_RATE AZM_CH(; CLMA2?I_CHG TURH_RATE CLOSURE TOOL_FACE DLS DLSRT ft deg deg deg/tOOft deg deg. deg/lOOft ft deg deg/lOOft deg/lOOft**2 0.0 0,00 0.00 0.00 479.0 479.0{:) 0.25 0.25 985.0 985,00 -0.25 0.00 1479,0 1478,98 0,75 0,75 19~.0 1~9,96 -0.50 0.25 0,00 0.00 0,00 0,00 0,05 190,00 190,00 39,67 -0,05. 20,00 210,00 3,95 0,I5 26,00 236.00 5,26 -0.I1 -14.00 222,00 -3,10 0.08 0.00 0.00 0.00 0.69 0.00 0.05 0.01 1.27 174.09 0.C5 0.00 3.8~ 0,00 0.15 0,02 0.00 0.00 0.11 0,01 2478,0 2477,94 0,50 0,75 2718,0 2717,93 -0,65 0,10 3004,0 3003.93 0.30 0,40 ~,0 3262,90 0,85 1,25 3394,0 3:393,~I 0,85 2.10 0.09 -92,00 130.00 -16.79 -0,27 14.00 1~4o00 5.83 0.10 4.00 148.00 1.40 0,~ -103.00 ~5,00 -39.~ 0,65 -42,00 3,00 -32,06 7,86 109.84 0,15 0,01 6,94 178,15 0.27 0,05 6,46 0,00 0,I0 0,06 3,23 119.12 0.5~ 0.17 7,30 173,69 1.10 0,43 3584.0 3583.04 5,80 7.90 3773.0 3768,51 6,10 14.00 3963,0 3949,55 7,10 21.10 4150.0 4120.17 6.00 27,10 4350.0 42~5,24 3.60 30.70 3.05 -13.00 -tO.O0 -6,84 3.23 -2,00 -12.00 -1.06 3,74 -t.O0 -13,00 -0.53 3.21 -3.00 -16.00 -1.60 1,80 -4.00 -20.00 -2.00 -1,25 17,58 3.~9 -1.58 4,54 3,23 0,08 -0,60 2,89 3.74 0,27 3.37 I2.91 3.27 0.25 1,05 77,50 2.C4 0.62 4539,0 4452,59 5,80 36,50 4633,0 4527, tl 2,10 38,60 4822.0 4674.20 0.~ 39.20 5012,0 4821,75 -0,30 5207.0 4974.04 -0.50 38,40 3.07 -1,00 -21,00 -0,53 2.23 1,00 -20,00 1.06 0,32 -2.00 -22.00 -1.06 -0.16 2.00 -20,00 1,05 -0.26 0,00 -20.00 0,00 30,59 5,86 3,08 0,55 39,53 16,57 2,33 0,80 59.08 65,24 0+74 0,84 78,79 104,17 0.~8 0,03 14.7.7 30.00 0.26 0.22 5397.0 5122,95 0.00 38.40 5-'-J88.0 5272,73 -0,10 38.30 5774.0 5419,00 -0,30 38,00 5969.0 5b-73.08 -0,40 37.60 6157,0 5722,73 -0,70 0.00 0,00 -20,00 0,00 -0.05 -1,00 -21.00 -0.52 -0,16 1,00 -20.00 0,54 -0.21 0.00 -20.00 0.00 -0,37 -1.00 -21.00 -0.53 114,15 90,00 0.¢0 0.13 132.65 99.56 0.33 0,17 150,59 116,32 0.27 0.02 168.21 0.® 0,20 0.08 96,75 0,00 0.49 0~15 6341,0 5870,54 -0,70 36,20 6529,0 6022,t5 O,lO 36,30 6725,0 6179,71 0.40 36,70 7048.0 643~,L8 -0,30 36,40 7193.0 6~"5.37 0.70 37.10 -0.38 0,00 -21'00 0.00 0,05 -1,00 -22,00 -0,53 0.20 1.00 -21,00 0.51 -0.09 9.00 -12,00 2,79 0.48 -2,00 -14.00 -1.38 204.02 0.00 0.38 0.06 223,29 80,79 0.32 0.03 243.49 56.47 0.37 0.02 260,17 96,81 1.~6 0,40 185.97 1~.59 0,96 0.49 7381.0 6705,51 -0.20 36,90 7572,0 6858.35 -0,10 36,80 7696,0 6957,90 -0,40 36,40 7949.0 7161,92 -0,30 36,I0 8146.0 732!,00 0.10 36.20 8339,0 7476.64 0,10 36.30 8533,0 7632,59 0.40 36,70 8713,0 7775,96 1,00 37.70 8902,0 7924,79 0.70 38.40 9096.0 ~76.20 0.60 39,00 -0.11 ' 1.00 -13.00 0.53 -0.05 1,00 -12.00 0.52 -0.32 0.00 -12,00 0.00 -0,12 0,00 -I2,00 0,00 0,05 1,00 -11.00 0,51 0,05 -2,00 -13,00 -1,04 0,21 2,00 -11,00 1.03 0,56 1,00 -10,00 0,56 0,37 -1.00 -11,00 -0,53 0,31 4°00 -7.00 2,06 266,32 108,79 0.~4 0,33 268.2S ~,~ 0,32 0.0I 268,90 178,83 0.~2 ' 0,00 7.70,15 0o00 0,12 0,08 262,41 60.47 0.~0 0.09 271,07 85,97 0,61 0,16 272,04 72,22 0.65 0,02 270.10 31,51 0,65 0.00' 268,02 41,71 0.49 0.08 270.11 80,76 1.33 0.43 *****xxx~xxx AHADRIL], ***k-x-********* SURVEY ANALYSIS ***** RADIUS OF CLIRVATLIR~ 1~/3-10D~**~ Ii 1PI 2-22/I.-14 MD TVD IHC_CHG CUMINC_CHG I_RAI'~ AZM_CHG CLMA~_CHG TURN_RA~ CLOSURB TOOL_~AC£ DLS DLSRT ft f~ deg deg deg/lOOft deg deg deg/lOOf~ f~ deg fleg/lOOft deg/lOOf~**2 9292.0 822_.7,65 0.80 39.80 9b-72.0 8441.03 0.60 40.40 9755.0 8580,04 1.10 41.50 9940.0 8717.0~ 1.40 42,90 10042.0 8791,:32 0.80 43.70 0.41 5.00 -2,00 2.55 0.21 -5.00 -7.00 -1.79 0.60 -4.00 -tl.O0 -2.19 0.76 2.00 -9.00 1.08 0.78 1o00 -8.00 0.98 247,49 77.79 1.67 0.18 225.4~ 81.37 1.17 0.18 220.19 68.76 1.55 0.21 216.89 44.~ 1.05 0.27 262,69 78,07 1,63 0.02 10212.0 8913.71 0.50 44.20 0.~ 1,00 -7.00 0.59 10405,0 ?052,66 -0.50 43.70 -0.26 -1o00 -8,00 -0.52 10595.0 9191,04 -0.~ 42.80 -0.47 1,00 -7.00 0.53 10783.0 9330,97 -1.80 41.00 -0.96 1.00 -6.00 0.53 10970.0 9475,04 -2.80 38.20 -1.50 -1,00 -7.00 -0.53 204.93 54.57 0.)0 0,31 195,54 126,14 0.44 0.03 18,5,42 143.10 0.60 0,08 I75.43 160.02 1.02 0.23 213.21 40.96 1.54 0.28 11178.0 9642,01 -3.20 '35.00 -1,54 2.00 -5.00 0.96 153,07 160,37 1.~ 0.05 11252.0 9702.99 -I.00 34,00 -1.35 0.00 -5.00 0.00 148.31 0.00 1.35 0.39 GREAT LAND DIRECTIONAL DRILLING INC. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY mmm mm BP EXPLORATION COMPANY MPI # 2-22/L'14 WELL NAME ENDICOTT LOCATION AL389-D12. SINGLE SHOT & MWD 4/17/89 JOB NUMBER BRIAN WEST NAME TYPE SURVEY DATE DIRECTIONAL .~r-' SUPERVISOR TITLE SIGNATURE 479 FT 11252 FT mmmmmmmmmmmmmmmmmmmmmmmm~mmmmmmmmmmmmmmmmmmmmmmmmmmmmm DEPTH INTERVAL FROM TO DATE SURVEY TAKEN 3/24/89 4/07/89 FROM TO THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL WE HAVE RETAINED A COPY OF YOUR SURVEY REPORT IN OUR FILES FOR YOUR CONVENIENCE; HOWEVER, SHOULD YOU SO DESIRE, ALL COPIES OF THE SURVEY REPORT WILL BE FORWARDED TO YOU ON WRITTEN REQUEST. ALL SURVEYS ARE KEPT IN A LOCKED FILE AND ARE HELD IN STRICTEST I_AND DIF~,ECTIONAI.. DRII..I..ING, ]'NC -q717/89 C.']Jent - BP EXPI. ORATJON ........... t. '- /-~:-/L .- Vez:-tjr-ol Sc, error; at.- N 1'i.G3 W Moqnet :1 c Dec 1:1 not J or,- 3:) decl. 0 rf, J n E I}¢ita fJ]e narf~e - II-MI 'J-qD_DAT ( Wel] RECORD OF SURVEY clssumed vet'-t J ca1 to HD of ComputatJor~: Survey dote: Method ..... : RKB t!eJght.: 0_01 HL-AG DR I F: T .I)EP~H DG MN 0 0 0 h79 0 15 985 0 0 :1 h 79 0 45 :1930 0 JS -r RUV[-: R T SUBSEA SECI' ] ON DEPTft DEPTH DIST O. O0 --55. O0 O_ O0 479. O0 42-5. O0 -0_97 985. O0 930. O0 -- J .9I lh78.98 1h23.98 - 3. ih 'J 929.96 187h. 96 -6.32 DIRECTION RELATIVE COORDINATES ANGLE FROM WELL.-- HEAD N 0.00 E 0_00 N 0.00 [:-' S JO O0 W 2] n~ "-' ..... o 0.18 W S 30 O0 W o n6 '-' 0 56 W ....t- -23 . S 56..00 W ._,"~87 o ~' 3.2Yt W s 20 no E 7 3h ~ h 37 W CLOSURE D I S T ANCE 0 _ O0 1%_ . 5.0:"5 8. DG MN S N 0 0 0 F- ._'~ 10 0 0 W S 15 7 29 W S 39 S5 ]b W c,_30 hh 6 W DOG LEG d,_-'~ q / ] 00 0_000 O. 052 O.Oh9 O. 1~2 O. 11i 2...',q, '/8 0 h 5 2718 0 300.h 0 2h. 3263 J 15 339h ,_.° 0 2h77 oh oz,~m 9h --:10 3h . -- ~ 1[_¢_ . 27J7.93 2662.93 .-:I~_72 3003_93 29h8.93 --12.88 32~2 oO 3207 90 --.1~ 88 3393.85 3338.85 64.00 E 36 On E 33. O0 45. O0 E 3.00 E '. 10_81 S 1.2h W 11 9h '-' . .~ 0 11'- 12.98 S 0.80 E 13.35 S h.03 E 10.03 S 5_51 E 11. 13.00 13.9h · J I_. -q h S 6 3h h W ¢, 22 o 0 30 E o_ .'4 ..... ,,_ 29 E S 28 q6 23 E 0.092.. 0.271 O. 105 0. 329 0 [Z'71, ,:, c.',', 7 54 3773 ~ --4 0 3963 21 6 - (T h 1,> 0 27 6 -q350 30 42 3583_ 06 3528_ 06 B. 27 3768.53 37] 3.53 -ql. 15 3949.57 3894 _ 57 98.39 hJ20. 19 hO':r:,_.,: . 1917h .6o_ 4295.25 h2-qO_2S 270.61 N JO.O0 W 6.29 N q_GJ E N 212.00 W h1.52 N 2.3h W N .... :t3 O0 W 9'7 -gl N 1h.'7~'o W N 16_00 W 171.30 N 33.8h W N 20.00 W 263.19 N 63.70 W 7_7h N 35 36 h9 E h i_ ._,~_,L-r-' N 3 ]3 ~.:~.--~F W 98. .52 N 8 .__,.,'~t'-' 56 W 17h.~1 N :IJ _10 27 W 270_77 N 13 36 17 W 3.108 3.737 "'~ "D '~ ,7_- ~ . t_~-__L_' J _ 87,, 539 36 30 h633 3[3 36 [50 :l'~,_38 ,.Sh !5207 38 2h hhS2.6:l h397.61 373.88 lifo ~,.7.13 hh72.13 h30. h6 4674 2,°_ h619 '~'~ 547 85 h821.77 h766.77 666_ 24 h97h. 06 h919.06 786.72] N 21.00 W 361.I'J N 100.3'J W N 20.00 W 41h.77 N 120_37 W N 20.00 W B26.30 N J. 60.96 W N 20.00 W 638.7fi N 201.90 W N 20.00 W 753.22 N 2h3.56 W 374.79 N JG 32] 26 W 431.88 N 16 10 59 W 5S0_36 N I7 0 20 W 86~.93 N 17 32 2~ W 79:1.62 N 2]7 SS 7 W 3.07h 2 27° 0_317 O. 0. 256 539'7 38 24 5588 38 lfl 577h 38 0 [5969 3'7 36 6157 36 Sh SJ22.96 5067.96 903.4~4 S272.75 5217.75 :!020.65 5419.02 536h. 02 2].J3h. 30 5573.10 5518.10 1252.51 ~,-z,-o-~ 75 5667 75 136-4 91 ~-ll I' £_f. o . . = N 20.00 W 86~. 12 N 283.92 W N 20.00 W 975.h9 N 32h.hS W N 20.00 W '1083.45 N 363.75 W N 20.00 W 1195.76 N 40h_63 W N 2J.O0 W 1302.35 N hh4.h8 W 909_S7 J028.03 11h2.88 1262.37 1376.1I N 18 ]J i9 W N 1.8 23 51 W N 18 33 3J W N 2]8 hl h2 W 'N 2]8 50 39 W 0.000 O. 052 O. 0.205 O. RECORD OF SURVEY MEAS DRIFT TF.'.UVFNT EUP, SEA =EL_.T]ON DIRECTION ,,ELA, IVE DEP'FH DG MN DEPTtt DFP'FH_ DIST AN~LE._ FROM WELL--',-iEAE 63-4.1. 36 :I2 5870.,5(i 58. .15. . 5(5 Jq72_99 N 2.1. O0 W 'J40;~.6F,. N ,483.75 ,,:,, :: 36 12 60,-:,-:. 27 5'.'?,5',7 _ 27 ."c~`2.,,_,= ..... 35 N 22 O0 W 1507 o::. ~_, N 521t . (;725 :3d ] o " 79 o'-~ ......... - 567. ~,_ ~'l ..... ~:;12q ~2 1697_0q N 2:1 On W I,:;.16_30 N 12 '/0;~,":~ 3~ 5h 6438 56 ,__,~_,,_'"'~q:q.. 56 ,'~n'~o~_,~,.: ~.-.o N :12 .... riO W i80:1 62 N ,522 01 ,/:1om 37 0 ,.'7,55h.;~;~ (.4. h99 4q .197,:5 7h N 1~,.00 W 1tZ:io_'12 N 6-40.88 7301 36 5q 670q.6fl dCShg_6fi 2__089_72 N .13_00 W 1996.83 N F572 ~6 12 c~B~L,.12 6808.~2 22OS_qb N ~2_00 W 2~07.88 N '/696 36 2q 6958 05 6903 05 ~c7o_E$5 N 12.00 W 2179_68 N '/949 36 6 7J6P.Ofl 7107.08 2q26_qt3 N 12.00 W 2~,76.02 N ~:[/T(; 36 ''~ t J,_l 16 726d .16 25;}2 6~ N 11 O0 W ~;,~o 666.30 W 690 _ 92 W 70`6.18 W 737.29 W 7,'30. ,45 W 8339 36 18 7q76.80 7h2:1_80 2c-;'56_77 N 11.00 W 255'1.92 N 8,:~:3.., 36 ~t2 7632 ..... 75 7577 75 ~77,_ 16 N 11 O0 W <oo=."~'"c 19N R713. 37 ~2 7776.12 7723 . 12 ~.,~aaO ..... ~7 -N 10 Off W ~, ,~_20~q~ N 8902 3fl 2h 792h.95 7869.95 2997.qq N 13.00 W 2fi86.73 N 9096 39 0 8076.36 802J.36 ~118_S9 N 7.00 W 3006.~1 N 782_. 23 W 80q .25 W 82q. 08 W 8-45 _ 3'J W 86q .28 W 9292 39 q8 822'1.81 8172.8'1. 32q2.03 N 2_00 W 3130.q9 N c:~c,-;,c.,: ,_,.,_ qO 2h 8h;{'1 . 9°.~ 838d . oo: .-- 3q2J . 1`2,_, N 8 . O0 W 3310 . 08 N '~-~ 9755 h.1 30 8580 20 ,-,,:o~_ ~- 97 .... - . ~:.,,_,~.,.O 3S,qO_ N 1.1 O0 W 3828 38 N ..- 9940 q2 5q 87:1.7.25 8¢.~o,-~ .,_,_,`2~: 3e1`65 ....... 19 N 90~ W 3550 73 N .100q2 q3 q2.. 8791. qB 8736_/{8 3735. O,q N 8. O0 W 3'6'.19.9'1 N 87]4. Oq W ,q-~o 75 W 909.5!~ W 931. J2 W 10212 ;~q 12 8913.87 8858.87 3852_'73 N 7.00 W 3736.89 N 956.86 W JOqO5 h3 q2 9052.82 8997.82 3986.35 N 8.00 W 3869.69 N 97q.3q W 30595 q2 h8 9:19.1.2:i 913C-;.2:1 q:lld.2J N 7.00 W 3998.75 N 991.33 W .107~3 q_l 0 93911.13 9274.13 ;{2q.1..27 N `6.00 W q123.q? N :1005_55 W .10970 38 .12 9q75.21 9~20.21 q360.00 N 7.00 W q2ql..-°-1 N :I019.0q W 1J.17fl 35 0 96~{2.17 9587_'17 ]4q83_;~i N 5.00 W q365.23 N J032_00 W .,_:,c: 3q 0 9703.15 96;t8. :15 ;t525.05 N 5. O0 W ;.t-"t0`6.98 N I035.65 W CLOSURE DOG LEE; DISTANCE DF;,_ MN ~'-' de:q/10 f)_ J885 61 N J9 0 1,_ W 0.38.0 ].5o.:: t;~ N ~o I0 36 W 0.18&, . ~ ~s . ~ .~ - .190S .... 9~ N :1~ ,_~ [50 W 1.006 2105.06 N 18 27 10 W 2218 `2`2 N 1::38 2;"_-91.22 N 1'1 L~.,'-~ 5 W 2q~-+0.07 N 17 35 lq W -.'D F_ .~ L~ ,o- ~'- ...... ,.o~ N I7 ~8 ~3°= W O. 053 0. q 09 O_ 161 0 _ 117 O_ 18-4 2669. 121 N .17 2 30 W 2'783.89 N J6 q7 30 W · oc~o.~ Om N, 'lC-; 33 20 W ct--J.." t.~ _ _- ! ~ - 3007_95 N J6 19 17 W ~1,___ 27 N 16 H_ 18 W 0 _206 0 0.87'-2, 3250 22 N :lc:'-"- - .., o-~ 59 W 3;{27.58 N 15 2 hq W 35h6.96 N .1. q 51 30 W 3670_78 N .1.:{ q:] 38 W or~0.3-4 N .1. q 3;.~ q2 W i . 0. 925 O. 938 0.908 0 91'" . 3857_~t5 N Jq 21 ]45 W 3990.47 N 114 7 57 W q119.flO N '13 55 25 W q2qq.33 N '13 ;{2 16 W q3(-;2.`60 N '1.3 30 30 W 0.1{10 0. 358 0. 532 0. 984 J .511 q;~85_5`6 N '13 J8 5 W z~527.03 N '13 '13 29 W 1.5'/J 1. 351 [.)A T A INTERF"OLATF_D FOR EVEN 300 FFET 01" SUB,SEA DEPTH 4 / 3 ?/8? SUB ,:SEA MD--TVD VERTICAL DEPTtt D I FF. CORRECT 0 0 0 100 0 0 ~00 0 0 £- 300 0 0 400 0 0 RELATIVE COORD]NATFS FROM WELl. --tiEAD 0_:[2 S 0_02 W 0 _,_,3 S 0_06 W 0.55 o~ O_:lO W 0 76 '-' o :i3 W 0.98 S 0.1'/' W 655 d;55 600 0 0 I .:37 cS 0_3'1 W 755 755 700 0 0 '1..59 S 0.39 W ,J° t:~, ~,~ 8 F=~ ~-~.~ 800 0 0 i. 80 S O_ 4 6 W or:r:...,., 955 -900. 0 O_ -'= . O0 o¢' 0 . R'n= ~_, W 105[_-; 1055 ¢ 155 1.155 ~P55 1255 .1. 355 3355 1555 1SSS _1 dSS 1655 1755 1755 1855 1855 1955 1955 :I. 000 0 0 1:100 0 0 1700 0 0 1300 0 0 1400 0 0 1500 0 0 1600 0 0 :1700 0 0 1800 0 0 1900 0 0 20OO 0 0 2300 0 0 2200 0 0 2300 0 0 2400 0 0 2500 0 0 2600 0 0 2700 0 0 28OO 0 0 2900 0 0 2055 2055 2155 2].55 2255 2255 2'355 2355 2~55 2455 2555 2555 2455 2655 2755 ,:755 2855 2855 2955 2955 4_45 S 3.43 W -q 23 o 3 "-'~ W ~ . ..._t . ut.-~ 6.00 S 3.93 W 6.7'7 .:e 4.18 W 7 SO S 4 u~ 8.33 S 3_65 W 8_77 S 3.08 W ~0 S o 5I W - t-- . 10.03 S 1_95 W 10.67 S 1.38 W 3:t_17 S 0.81 W il.65 S 0.25 W '12.08. S 0.20 E :12.44 o"' O..hfl E 12.80 S 0.68 E MP] ~ 2--P2/l..--]~t DATA IN-[[:RPOI. ATED FOR EVEN 100 FEET OI: SUkISEA DEPTH 36S7 37S9 3969 079 190 :30 4 · ., £_ 4669 4 797 4926 50SS S]83 53] 0 54 38 .'.5S6S S69:3 .5820 S946 6072 6197 03,': ,_ 6446 'FRII_ VERT SUB SEA MD-TVD 'F-R-'-~F_...ICAL DE P T tt DEP'F tt D I FF. CORRECT 30S5 3000 0 0 3]55 3;100 0 0 325S 3200 0 0 R'°~:S 3300 0 0 34 SS 34 00 0 0 3.~o~:, 3[500 365S 3600 37SS 3700 ;~, o 38,.~.~ 3800 9 S 3:~ ;_',..~ .'qo 00 14 0 ,~.., ;4000 :4;I 10 155 4 100 3S 1 1 2 S 5 4 o_ 00 49 J 4 q3SS 4300 67 i8 ;t SS 4 4 00 87 20 :-~--',,_ 4,500 114 27 465S ~600 142 28 z~ 7SS 4700 171 ~9 4riSS 4 riO 0 aO 0 2° 49SS 4900 SOSS SO00 aSS 27 S 3 SS S :! 00 ,_°83 28 [7. '3 [.2 IL [Z- _~ .=c:O 0 310 27 S3SS [-}300 338 28 54 S S S400 38S ~7 SSSS SSO0 391 26 S655 S600 417 26 S7SS S700 442 25 SSSS S800 467 2S S9S5 S900 491 P4 REI. AT]VE COORD]NA'FES FROM WELL.-ttEAD 13.0S .S !_;t4 f-- 13. 19 c,"'_ ,_.°-. ~:17_. E . .-..., 13.3~, o"' 3_93. _ E 1:1 Ol '-' t.5 07 IT 4.7[-5 S S.18 E ]h3.07 N 26.S4 W 189.S7 N 39.78 W 242.06 N S6.83 W 300.37 N 77.6'0 id 362_ 84 N 'I00.9S id 4~'- 90 N 511.73 N 587 ~ N 6.6.3.7S N 738.90 N :128_06 W 3 SS. 66 W 183.38 W o10 c~o W 238.3;+ W 813.S1N 887.94 N 962 2° N ~036.20 N ij09_68 N 26S_S0 W 292.S9 W 319.6S W 346.5S W 373.30 W 1182. S7 N 1,:~4.10 N 1324.6.7 N 1393.88 N :14~2. :i S N 39.9.82 W 426.44 W 4qo OS W 479.63 W 506.40 W MP .I DATA IN-fERPOI_ATED [:OR EVEN 100 FEElr OF SURSEA DEP-ft4 4/17/89 . -- MEAS I'RII VERT OLI~_, SEA MD--TVD Dr-'_ I:' T H DE P T H DE-_- P T It D I FF. 5570 dOB5 6000 S1~ 6694 6155 63 O0 539 6819 oc. .-' ~FF ~ 6200 564 694q ~355 6300 589 ~,.~ 6400 S :14 7194 6555 6500 639 73 :] 9 6655 6600 664 Y444 6755 6'700 689 7568 68155 6800 71 Lq. '7 .-' r.9'.9 ."C)17 [- ~' ~,7 ,o:-, cz o:: ,.'~.~ 6900 78:16 7940 8064 8188 831.2 '! 05 [3 71 S S 725[:. 73[.i. 5 7000 76:1. 7 :I 00 785 Z,_O0 ~' 809 7300 833 7400 857 8436 7555 7500 881 85(51 765[3 7600 906 8686 .~**~, ~,~, 7700 931. 1t813 7855 7800 958 8940 7955 7900 985 9089 80c-~ - oo 8000 1014 91~8. ¢ filES 8108_ 105TMo 9328 8255 8200 1073 9458 8355 8300 11.03 9589 8455 8400 1134 9722 8SSS 8S00 1167 7856 8655 8600 1201 9992 8755 8700 1237 10130 8855 8800 1275 VURTICAI_ RELATIVE COORDINATES CORI~EC-F FROM WELI_-IiEAD -- 24 1530.45 N 533_30 W 24 1599.17 N 560.37 W 25 1670.09 N I383.05 W 25 1741.75 N 604.28 W o~ 1813 69 N 624 69 W 24 24 24 24 24 24 24 25 25 27 27 30 30 31 33 31t 36 38 39 1887.13 N 640_97 W 1960.42 N 657.89 W 2033.25 N 674.37 W 2:!05.62 N 690.42 W 2:t77.49 N 705.72 W ;~49_2-:! N 720_94 W ,_.ch__O. :.3 N 736.2:1 W 2392.B3 N 750_82 W 2464.25 N 765.I9 W 2 U"-' '. . 3o 23 N 779 18 W 2608.72 N 793.27 W P68J.80 N 807.33 W =7;~o.43 N =cl 16 W oooo 9fi N 835 33 W 2910.S0 N 8~9.07 W 2989.62 N 861.60 W 3070_89 N 869.35 W 31S3.29 N 876.03 W 3237_J4 N 883.37 W 332].22 N 891.61 W 3406.79 N 905.93 W 3495.15 N 921.32 W 358S.91N 936.38 W 3680.62 N 949.45 W 3776.20 N 9d2.03 W f)ATA INT[:RPOI_ATED FOR EVEN 100 FEET O[-- SUf3SEA DEPTH M,~£AS_ TRU VERT SUB SEA MD-TVD VERTICAl. I')FP'['It DEPTH DI:Pl-lt DI FF_ CORRECT 'J 0408 9055 9000 ~353 3~ ] 0545 9155 9100 1390 37 10 (;.q 1 ~2S5 920 o 1426 o ,:: 10814 9~-~ 9;qO 0 1459 ~:~ 109q4 94 5[5 9q 00 :14 89 30 1 :l 1.94 96;55 9600 _[~c,9 2S 2S RELATIVE COORDINATES FROM WELL-ItEAD 3871.72 N 97~.6:1. W 396~.98 N 986.89 W 4055.62 N 997.81W 4:1~3.1] N ]007_78 W ~225.30 N :1017.15 W 4300_85 N ~37~.0I N ] 0~_._~.23 W ]032.77 W 2-22/L.-~4 DATA ]N-FERF'OI_ATED t:OR EVEN 1000 FEET OF MEASURED DEPTH MEAG. TRU VERT SUB SEA F)FP'F tt DEP T tt DEP T H ~000 ~000 9~5 2000 2000 1945 ~000 3000 2945 ~000 3983 3928 5000 4812 4757 6000 5598 cc,.o 7000 ¢5400 6345 8000 7203 7148 9000 8001 7946 10000 87dl 8706 I :1000 9499 9444 RELATIVE COORDINATES FROM WEL L-ItEAD 1213.34 N 1774.08 N 2355.50 N 2947.24 N 3591.43 N 413.20 W 613_86 W 743 Da W 854_ 89 W 937_ 20 W 42S9.70 N 1020.91 W ~ke~ Ident~f~catton ND TVD DEPRT B) TD ~25E 97O3 4525 6500 6000 5500 5000 4500 4000 3500 3000 2500 2000 tSO0 t000 500 500 5500 5000 4500 4000 3500 3000 2500 2000 HORIZONTAL VIEW BP EXPLORATION M?I ~ 2-22/L-14 CLOSURE: 4527 ft N 13.2 H DECLINATION: 31.00 ~eg E SCALE: ! inch = 1000 feet DRAWN: 4/17/89 1.~00 lO00 500 0 500 600 1~00 lBO0 5400 VERTICAL SECTION BPEXPLORATION MPI ~ 2-22/L-i4 SECTION AT N li.53 W TVD SCALE: t inch : t200 feet DEP SCALE: I inch = t200 feet DRAWN : 4/17/89 ~4arker IOenttftcatton ~ ~ DEPRT ~I(B 0 0 0 'I'D tt2h'2 97O3 455 3000 3600 4200 T 4800 5400 6000 6600 7PO0 78O0 8400 9000 9600 tO2.00 ----~-- iOBO0 -600 6OO t200 tBO0 2400 30OO 3600 Oepartupe 4200 4BOO 5400 6000 6600 $UB.$URFACE DIRECTIONAL ~URVEY F'~l UIDANCE F~ONTINUOUS ~']OOL comp .!ny Well Nam® BP EXPLORATION 2-22/L-14 MPI (191~' SNL,2224' WEL,SEC i~6,T12N.R16E) Field/Location ENDICOTT, N0gTH SLOPE. ALASKA Job Reference No. 73296 MCBRIDE/COX Date 17-APR-89 Computed By: KOHRING SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR BP EXPLORATION 2-ZZ/L-I~ MPI ENDICOTT NORTH SLOPE9 ALASKA SURVEY DATE: 17-~,PR-89 ENGINEER: MCBRIDE /COX METHODS O~ COMPUTATION IO'JL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPULRTION: LINEAR VERTICAL SECT IUN: HORIZ. DIST. PRUJECTED ONTO A TARGET AZIMUTH OF NORTH lZ, DEG 99 MIN WEST UP EXPLORAI[UN Z-2Z/L-I~ MP1 ENDICUTI NUR[H SLOPEr ALASKA COMPUTATION DATE: 25--APR-89 PAGE 1 DATE DF SURVEY: 17-APR-89 KELLY BUSHING ELEVATION: 55.50 PT ENGINEER: MCBRIDE /COX INTERPOLATED VALUES FUR EVEN 100 FEET OF MEASURED DEPTH tRUE SUB-SEA ,. COURSE MDASURED VERTICAL VERTIC.~E: O:~-.~'~:t~_TION AZIMUTH DEPTH DEP:M DEPTH !. ~'MIN DEG MIN o. u o o o 9 - 55.5 o J~i%:"O:';} o N 0 0 100.00 100.UU 44.50 0 -'0 N 19 5 E 200.00 ZOO.U0 144.50 0 0 N 22 47 E 500.00 300.00 24~.50 : 0 ! S 2 26 W 400.00 400.00 344.50 0 4 S 45 4 E 500.00 500.00 444.50 0 5 S 18 41 W 500.00 600.00 5~4.50 0 8 S I 35 W lO0.UO 700.00 6~*.50 0 0 N 21 5 E BUO.UU 800.00 Tqm.50 0 5 S 60 9 W 900.00 gO0.O0 8~4.50 0 7 S 7 55 W 1000.00 1000.00 944.50 1100.00 1100.00 1044.50 1200.00 1ZOU.UO 1144.50 1300,00 1300.00 1244.50 1400.00 1400.00 1344.50 l~OO.UO 14~9.99 14.44.49 1600.00 1599.99 1544.49 1700.00 1699.99 1544.49 1UOO.UO 17~9.99 1744.49 l~OO.OO 1~9~.~ 1844.49 0 2 S 30 Z5 E 0 7 S 28 35 W 0 10 S 7 44 W 0 15 S 16 49 W 0 25 S 43 14 W 0 20 S 45 11W 0 12 S 73 I W 0 9 S 50 32 W 0 6 S 54 16 w 0 3 S 29 4 W ZOUO.OU lcj99.99 1944.49 2100.00 Z099.99 204~.~'9 ZZO0.UO Z199.99 214~.4.9 Z3OO.UU 2Z~9.99 2244.49 2400.'00 2399.99 2344.49 Z~O0.UO 2499.99 2444. ~+9 Z6OO.UU 2599.9~ 2544.%9 ZTUO.OU 2699.~9 25~4.49 2800.00 2799.9~ 2/'44.48 ~ ZgO0.UO Z899.98 2844.~8 0 1 N 1! 39 E 0 2 S 0 39 W 0 6 N 66 19 E 0 1Z S 70 34 E 0 23 S 95 43 E 0 2~ S 77 Z E 0 19 S 71 48 E 0 21 S 62 44 E 0 1l S ~1 54 E 0 21 S q. 2 43 E 3000.00 2999.93 2944.4~ 0 21 ~lO0.OO 3099.'98 3044.48- 0 11 3ZOO.U0 3199.9ti 3144.48 0 20 3500.UU 52¥9.97 5Z44.47 0 46 ~4OO.OO 3399.95 3344.45 1 51 3500.00 3499.76 3444.26 5 3 3600.U0 3599.05 3543.55 8 22 3BUO.OU ~Tgq.u% 3739.34 14 52 3900.u0 3890.57 3835.07 18 35 S 3853 E S 10 35 E N 39 51 E N 30 51 f N 16 0 E N 9 35 W N 11 39 W N 11 26 W N 14 17 W N 15 29 w VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTI3N SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.90 0.00 0.00 N 0.00 0.00 0.00 0.00 S 0.00 0.01 0.00 0.01 N 0.00 0.00 0.09 0.00 N 0.00 -0.11 0.08 0.~0 S 0.05 -0.19 O.1R 0.17 S 0.0~ -0.40 0.10 0.41 S 0.03 -0.52 0.03 0.52 S 0.06 -0.54 0.11 0.55 S 0.01 -0.67 0.03 0.72 $ 0.11 -0.79 0.00 0.84 S 0.09 W -0.88 0.14. 0.94 S 0.11 W -1.13 0.00 1.22 S 0.19 W -1.45 0.13 1.56 S 0.25 W -I.B3 0.19 2.04 S 0.56 W -Z.18 0.24 2.53 S 1.06 W -2.37 0.29 2.81 S 1.40 W -2.41 0.08 2.94 $ 1.71 W -Z.51 0.08 3.07 S 1.85 W -l.57 0.19 3.17 S 1.98 W -2.58 0.09 3.18 S 1.96 W -2.56 0.20 3.16 S 1.98 W -Z.$O O.1Z 3.16 S 1.83 W -2.65 0.38 3.17 S 1.65 W -2.87 0.25 3.25 S 1.11 W -3.15 0.18 3.35 S 0.36 W -3.45 O.1B 3.49 S 0.26 E -3.83 0.11 3.75 S 0.80 E -4.23 0.29 4.02 $ 1.38 E -k.66 0.31 4.3~ S 1.81 E -5.30 -5,75 -5.81 -5.11 -3.57 2.19 13.91 31.14 54.12 82.95 0.38 0.28 0.67 0.33 3.06 3.26 .3.08 3~ 3,86 4.90 S 2.22 b 5.31 S 2.45 E 5.32 S 2.66 E 4.44 S 3.22 E 2.63 S 4.05 E 3.28 N 3.87 E 14.76 N 1.47 E 31.68 N 1.96 w 54.17 N 6.74 W 81.96 N 14,44 W 0.00 N O 0 E 0.00 S 78 55 W 0.01 N 3 58 E O. O0 N 27 21 0.11 S 25 41 0.19 5 25 5 c 0.41 5 4 30 E O. 53 S 6 40 E 0.55 S 1 0 E O. 73 5 8 51 W 0.84 5 5 56 W 0.95 S 6 4.6 W 1.23 S 8 45 W 1.58 5 B 56 W Z.11 S 15 16 W Z.74. S 2Z ~4 W 3.14 5 26 26 W 3.40 5 30 1Z W 3.59 S 31 I W 3.74 5 32 2 W 3.74 5 31 40 W 3.73 S 32 6 W 3.65 S 30 3 W 3.58 S 27 30 W~-. 3.43 5 18 46 3.37 5 6 11 3.50 S 4 13 ~ 3.84 S 12 1 E 4.24 S 18 54 E 4.71 5 ZZ 34 E 5.38 S 24 Z5 E 5.U4 5 Z4 46 E 5.94 S 26 34 E 5.49 S 35 57 E 4.03 5 57 1 E 5.07 N 49 44 E 14.83 N 5 40 E 31.14 N 3 32 W 5~.59 N 7 5 W 83.22 N 9 59 W BP ~XPLURATLON Z-ZZ/L-lq ENDICOTT NORT~ SLOPb~ ALASKA COMPUTATION D.~TE: 25-AP~.-89 PAGE 2 OATE DF SURVEY: 17-APR-89 KELLY BUSHING ELEVATION: 55.50 FT ENGINEER: MCBRIDE /COX INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED OEPTH TRUE 5U6-SEA :. COURSE M~-ASURkD VERIICAL VERTICAL'-i~;¥-ZA;TIDN AZIMUTH DEPTH DEPTH OEPTM ~::~:'."~MIN DEG MIN ¢100.U0 ¢075.62 4020.12 . 25 37 ~ZOO.UO ~16a.dO 4109.30 27 53 ~3UO.OU 4252.56 4197.06 29 29 ~400.00 ~338.40 ~282.90 32 18 4~00. U0 ~421.43 4365.93 35 26 ~bOO.OO 4581.51 4446.07 ~7 52 ~TUO.OU 457~.59 4524.09 39 ZO 4~00.U0 ¢656.9B 4501.¢8 39 13 ~900.00 47J~.53 4679.03 39 ~ VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DIG/lO0 FEET FEET FEET DIG MIN bOUO.UO 4812.29 4756.79 38 53 5100.00 4890.25 4834.75 38 ~6 5200.00 4968.5~ 4913.04 38 26 ~SOU.OU 5046.~0 4~91.30 ~8 26 5¢00.00 5125.11 5069.61 38 27 5300.00 5203.43 5147.93 38 b60O.UO 5281.B1 5Z26.31 38 5700.00 5360.50 5305.00 37 59 5800.00 543~.J0 5383.80 37 57 5900.U0 5518.36 5~62.86 37 N 13 17 W 117.90 N 15 39 W 158.46 N 20 4 W 203.59 N Z1 36 W 251.23 N 21 34 W 302.12 M Z1 36 W ~57.~3 N 21 Zl W 416.79 N 20 56 W 478.95 N 20 57 W 541.89 N 20 54 W 604.64 6UUO.UU 55'J7.71 5542.Z1 37 24 6100.00 5671.~2 56Z!..qZ 37 6 6200.00 5757.23 5701.73 36 44 6300.U0 5837.59 5'T82.09 156 1R 6400.UU 591B.17 596Z.67 36 1~ 65U0.00 5998.92 5943.4Z 36 11 6600.00 60~9.60 6024.10 36 1~ 6100.00 6160.14 6104.64 36 30 ~BUO.OO 6Z40.~5 61~q.~5 36 50 6900.00 63ZU.50 6264.80 36 48 N 20 57 W 667.15 N 21 3 W 7Z9.39 N 21 lq W 791.20 N Z1 3Z W 853.02 N 21 40 W 914.75 N 21 47 W 976.~6 N 21 57 W 1038.07 N 22 lO W 1099.26 N 22 9 W 1160.28 N 22 15 W 1220.99 7UOU.UO 6400.52 6345.02 36 31 7100.00 6¢50.75 6425.25 36 51 IZUO.O0 6550.52 6505.0Z 37 4 1300.00 6640.33 6554.~3 36 58 7400.00 67Z0.27 6664.77 37 7500.UU 6800.11 674½.61 36 55 1600.00 6880.06 6824.56 36 48 7700.00 b9~0.36 6904.~6 36 22 7~O0.OO I0~1.16 6~85.56 35 5 1900.00 1122.05 7066.55 36 1 N 22 3~ W 1281.29 N 22 41 W 1341.22 N 22 47 W 1400.74 N !2 49 W 1~59.65 N 23 3 W 1518.Z5 N 23 8 W 1576.59 N !3 3 W 1635.04 N 22 5M W 1693.68 N 22 37 W 1752.79 N 19 44 W 1812.43 N 16 Z W 1~72.03 N 14 1 W 1931.71 N 13 5Z W 1992.01 N 13 39 W 2052.27 N 13 29 W 2112.33 N 13 11 W 2172.53 N 12 55 W 2332.57 N 12 50 W 2292.14 N 12 54 W 2351.03 N 12 51 W 2409.80 3.27 3.58 1.79 2.09 2.85 2.86 1.83 0.32 0.15 0.26 115.83 N 23.06 W 118.10 N 11 15 W 155.15 N 33.01 W 158.62 N 1Z 0 W 198.18 N ¢6.89 W 203.65 N 13 18 W 242.90 N 64.13 W 251.23 N 14 47 W~- 290.58 N 82.98 W 302.19 N 15 56 $- 342.89 N 103.47 W 357.68 N 16 48 W 398.02 N 125.39 W 417.30 N 1;' 29 W 456.37 N 147.95 W 479.75 N 1]' 57 W 515.52 N 170.56 W 543.00 N 18 18 W 574.48 N 193.12 W 606.07 N lB 34 W 0.08 0.24 1.0Z 0.11 0.00 0.24 0.33 0.40 0.30 0.29 633.21 H 215.58 W 668.90 N lB 48 W 691.67 N 238.05 W 731.49 N 18 59 W 749.70 N 260.47 W 793.66 N 19 9 W 807.64 N 283.24 W 855.87 N 19 19 W 865.46 N 306.14 W 918.01 N 19 28 W 923.22 N 329.16 W 980.15 N 19 37 W 980.85 N 352.30 W 1042.20 N 19 45 W 1038.0¢ N 315.50 W 1103.86 N 19 53 W 1095.04 N 398.73 W 1165.37 N 20 0 W 1151.74 N 421.86 W 1226.57 N 20 7 W 0.38 0.13 0.49 0.27 0.48 0.50 0.50 0.37 0.83 Z.67 1207.99 N 445.10 W 1287.39 N 20 13 W 1263.85 N 468.38 W 1347.85 N ZO ZO W 1319.29 N 491.6Z W 1407.91 N ZO 26 W 1374.15 N 514.69 W 1467.38 N ZO 3Z W~-.~. 1~28.68 N 537.78 W 1526.55 N 20 37 ) 1482.94 N 560.94 W 1585.48 N ZO 43 k 1537.28 N 584.12 W 1644.52 N ZO 48 W 1591.84 N 607.30 W 1703.75 N 20 52 W 1646.87 N 6~0.50 W 176~.44 N 20 56 W 170Z.79 N 652.41W 1823.49 N ZO 57 W 1.97 1759.62 N 670.67 W 1883.09 N ZO 51 W 1.30 1817.32 N 685.89 W 194Z.45 N 20 40 W 0.76 1875.B5 N 700.44 W 200Z.35 N ZO Z8 W 0.93 1934.37 N 714.80 W Z06Z.ZZ N ZO 16 W 0.63 1992.78 N 728.87 W Z1Zl.89 N ZO 5 W 0.3~' 2051.35 N 7¢2.85 W Z181.71 N 19 54 W 0.60 2109.84 N 756.46 W 2241.35 N 19 43 W 0.4~ 2167.95 N 769.7~ W 2300.53 N 19 32 W -0.37 2225.38 N 782.85 W 2359.06 N 19 22 Y 0-,..23 2282.70 N 795.97 W 2417.¢9 N 19 13 W bP EXHLURATIUN Z-ZZ/L-14 MP! ENDICUT! NO~TH SLOPEm ALASKA CL3MPUT~TIi3N DATE: 25-~PR-89 PAGE 3 DATE OP $URVEY: 17-APR-89 KELLY BUSHING ELEVATIUN: 55.50 PT ENGINEER: MCSRIDE /COX INTERPOLATED VALUES FOR EVEN IO0 FEET OF MEASURED DEPTH IRUE SUB-SEA . ~=~ .L=~COURSE VERTICAL DUGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE M~A~UREU VERTICAL vERT SE ICAL :DJ~ION A ZIMUTH CTION SEVERITY NORTH/SOUTH EAST/WEST D/ST. AZIMUTH DEPTH DEPTH DEPTH :B~-~N DEG MIN FEET OEG/IO0 FEET FEET FEET OEG MIN 8UO0.UO /203.06 7147.56 '35 .5'5 8100.00 1Z85.U5 7228.33 36 5 UZUO.O0 7364.56 7309.06 '36 ZO 8300.00 14~5.13 7389.63 36 21 8~00.~0 75Z5.71 7470.Z! 36 26 USUO.OU /606.22 7550.72 36 31 B6UO.O0 7686.~8 7630.88 36 43 8700.UO f766.I~ 771~.&8 37 3I 8~OU.UO ~8~5.Z1 7789. T1 37 59 8900.00 7923.?8 7868.Z8 38 23 N 12 34 W 2468.39 N 12 20 W 2527.31 N 12 19 W 2586.28 N 12 50 W 2645.47 N 13 16 W 2704.66 N 12 57 W Z763.96 N 12 50 W 2823.72 N 12 34 W 2883.94 N 1! 4~ W 2945.16 N 10 47 W 3006.92 9000.00 8002.04 7946.54 38 37 9100.U0 U019.93 8024.43 39 1 9ZUO.UO 8157.46 8101.96 39 19 9300.00 8Z34.60 8179.10 39 43 9~00.00 8311.24 8255.74 40 9bOO.U0 ~3~6.81 0331.37 41 14 ~600.00 8~62.55 8407.05 40 21 9700.00 8538.46 8482.96 40 56 9000.00 8613.54 855~.04 41 46 ~00.00 U6~?.69 8632.19 42 N 9 24 W 3068.98 N 7 47 W 3131.34 N 5 52 W 3193,91 N 3 55 W 3256.62 N 3 5 W 3319.59 N 6 38 i 3384.03 N 9 45 W 3448.97 N 11 49 W 3513.94 N 1! 13 W 3579.90 N 10 19 W 3646.83 1UOUO.00 8761.02' 0705.57 43 9 10100.00 0833.3T 8i'77.87 44 13 IOZOU.UO U904.76 8849. ;'6 44 25 103UO.UU 8916.45 8920. ~}5 4'~ 5~ IU4UO.UU 9040,67 8993.17 43 41 10500.00 9121.11 9065.~1 43 30 10600.00 9193.U'=3 9!3~. 39 42 56 10100.00 9267, 11 9212,!1 41 52 lO~O0 00 ~34Z.75 9287.25 40 54 10~00:00 ~419.01 9J63.52 59 26 N 9 33 W 3714.54 N 9 9 W 3783.32 N 9 14 W 3853.03 N 9 29 W 3922.45 N 9 2! W 399].33 N 8 59 d 4059.96 N 8 54 W 4128.19 H 8 32 W 4195.29 q 9 1~ W 4261.00 N 7 55 W 4325.25 IIUUU.UO 94'~6.05 9441.35 38 T N 6 5! W 4387.54 11100.00 9516.41 9520.91 36 31 N 5 46 W 4447.45 11Z00.00 9657.62 9.502.12 34 5~ N 5 16 W 4505.06 11300.00 9739,9~ 9684.48 34 2Z N 4 35 W 4560.96 11400.00 9~2Z.64 9767.14 34 7 N 3 37 W 4616.30 11500.00 9905.40 9349.90 34 15. N 3 17 W 4671.36 11600.00 9987.85 993g..36 34 30 N 2 35 W 4726.77 11~00.~0 100~0.~5 10014.75 34 21 N 2 4 W 4782.12 118~0.0~ 10152.96 10097.&6 33 56 N 1 ~9 W 4836.91 11~00.00 10236.23 10180.73 33 21 N 0 59 ~ 4890.75 1.01 0.90 0.82 0.81 0.54 1.0Z 0.38 0..85 0.66 0.81 1.00 1.13 1.30 1.37 1.43 2.47 2.44 0.80 1.03 0.92 1.06 1.00 0.43 0.76 0.34 0.04 1.08 1.11 1.10 2.51 2339.88 N 808.91 W 2475.76 N 19 4 W 2397.46 N 8Z1.59 W 2534.33 N 18 54 W 2455.12 N 834.18 W 2592.97 N 18 45 W 2512.94 N 847.05 W 2651.86 N 18 37 W~-~=, 2570.61 N 860.48 W 2710.81 N 18 30 W 2628.38 N 873.9~ W Z769.87 N 18 Z3 W 2686.66 N 887.28 W 2829.38 N 18 16 W 2745.43 N 900.59 W 2889.36 N 18 9 W Z~05.32 N 913.54 W Z950.32 N 18 2 W 2865.97 N 925.70 W 3011.76 N 17 54 W 2927.26 N 936.63 W 3073.~6 N 17 44 W 2989.26 N 946.03 W 3135.39 N 17 33 W 3051.96 N 953.57 W 3197.46 N 17 Z1 W 3115.36 N 959.01 W 3259.63 N 17 6 W 3179.49 N 962.67 W 3322.03 N 16 50 W 3244.66 N 968.17 W 3386.02 N 16 36 W 3309.36 N 977.41 W 5450.68 N 16 27 W 3373.23 N 989.98 W 3515.50 N 16 Z1 W 3437.94 N 1003.24 W 3581.32 N 16 16 W 3503.84 N 1015.78 W 3648.11 N 16 IO W 3570.76 N 1027.49 W 3715.65 N 16 3 W 3638.93 N 1038.69 W 3784.27 N 15 55 W 3708.06 N 1049.83 W 3853.81 N 15 ~8 W 3776.84 N 1061.22 W 3923.10 N 15 41 W~= 3845.08 N 107Z.56 W 3991.87 N 15 35 W 3913.13 N 1083.54 W 4060.38 N 15 28 W 3980.86 N 1094.25 W 4128.52 N 15 Z2 W 4047.55 N 1104.47 W 4195.5] N 15 15 W 4112.93 N 1114,18 W 4261.17 N 15 9 W 4176.94 N 11Z3.35 W 4325.36 N 15 3 W 1.56 4239.21 N 1131.43 W 4387.60 N 1% 56 W 2,45 4299.44 N 1137.89 W 4447.47 N 14 49 W 1.29 4357.51 N 1143.57 W 4505.07 N 14 42 W 0.50 4414.00 N 1148.47 W 4560.96 N 14 35 W 0.58 4470.14 N 1152.53 W 4616.3~ N 14 27 W 0.23 4526.18 N 1155.86 W 4671.43 N 14 19 W 0.74 4582.66 N 1158.90 W 4726.92 N 14 11 W 0.~',,: 4639.29 N 1161.13 W 4782.39 N 1~ 3 W 0291 4695.46 N 1162.87 W 4837.32 N 13 54 ..~:~:~S 4750.82 N 1163.96 W 4891.33 N 13 45 W "C":'::~ BP EXPLORAT[UN Z-II/L-l_4 ENDICOTT NURTH :~LUPE ~gMPUT~TION D&TE: IS-APR-89. PAGE 4 DATE OF SURVEY: Il-APR-89 KELLY BUSHING ELEVATION: 55.50 FT ENGINEER: MCSRIDE /COX INTERPOLATED VALUES FOR EVEN 100 FEET DF MEASURED DEPTH TRUE SDS-SEA ~.. /:/:~?'COURSE VERTICAL DOGLEG RECTANGULAR CODC~DINATES HDRIZ. DEPARTURE MEASUR~-D VtRIICAL VERTICAL :~-~..~ION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTU D~PIH DEPTH .~~'N DEG M[N FEET DEG/IO0 FEET PEET FEET DEG MIN ~:: ¢-. ~. IZOOO.OO iO~ZO.O0 t026~.50 ~Z 50 N 0 55 W ~9~].90 1.04 ~805.4~ ;~ 1164.8I W 49~.60 N ~] ~7 W -tZZOO.Og ZO~O~.~t ZO3,8.gt 32 9 N 0 4 W ~95.7~ 0.39 4859.05 N II65.ZZ W ~96.8t N ~3 Zg W IZZOO.UO IO4Bg.]J 10~]~.~3 3~ 3Z N 0 2~ E 50~7.17 1.27 4912.17 N 1165.21 W 50~8.48 N 13 ZO W IZJUU.UU 105~.~6 10518.~6 31 2~ N 0 Z9 F 5097.q0 0.00 4964.31 N 1164.77 W 5099.13 N 1~ 12 W ~ 1Z3ZZ.OU I059].Z4 I05~7.T~ -:~1 24 N 0 Z9 E 5108.57 O.OO' 4975.T~ N 116~.67 W 5110.Z~ N 15 lO W ~P EXPLORATIUN 2-Z2/L-14 MP1 ENDICUT! NURTH 5LOPE, ALRSRA COMPUTATION DATE: 25-APR-89 DATE OF 5URYE¥: 17-APR-89 KELLY BUSHING ELEVATIUN: 55.50 FT ENGINEER: MCSRIOE /COX INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH IRUE SUB-SEA MEASUREU VERTICAL VERTICAL DEPTH DEPTH DEPTH O.UO O.OU -55.50 ZUUU.UO IOUU.UO 944.50 0 Z. ZO00.OU 1999.~9 19~4.~9 :='0 1 3UOU.UO Z999.98 2944.~8 0 21 4UO'O.UU 3984.14 3928.T4 Z2 16 50UO.OU ~B1Z.Z9 4756.79 38 53 6000.00 5597.71 5542.21 37 24 7UOU.O0 64~0.52 6~4~.02 36 37 8UUO.UU ?ZO$.06 7147.56 35 55 90UO.O0 8002.04 7946.54 3B 37 VERTICAL DOGLEG RECTANGULAR COORDINATES HURIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET DEG 10000.00 8761.07 8705.57 43 9 11000.00 9496.85 9441.35 38 -f 1ZOO0.OU 10~Z0.00 10264.50 32 50 12322.00 10593.24 10537.74 31 24 0.00 -0.79 -2.58 -5.30 117.90 667.15 N 22 34 W 1281.29 N 16 Z W 1~72.03 N 12 34 W 2468.39 N 9 24 W 3068.98 N 9 33 W 3714.54 N 6 51 W 4387.54 N 0 55 W 4943.80 N 0 29 E 5109.57 0.00 0.00 0.09 0.38 3.27 0.08 0.38 1.97 1.01 1.00 1.06 1.56 1.04 0.00 0.00 N 0.00 E 0.00 N 0 0 E 0.84 S 0.09 W 0.84 S 5 56 W 3.18- S 1.96 W 3.74 5 31 40 W 4.90 S 2.22 E 5.38 S 24 25 E '~-'~ 115.R3 N 23.06 W 118.10 N 11 15 W 633.21 N 215.58 W 668.90 N 18 48 W 1207.99 N 445.10 W 1287.39 N go 13 W 1759.62 N 670.67 W 1883.09 N 20 51 W 2339.88 N 808.91 W 2475.76 N 19 4 W 2927.26 N 936.63 W 3073.46 N 17 44 W 3570.76 N 1027.49 W 3715.65 N 16 3 W 4239.21 N 1131.43 W 4387.60 N 14 56 W 4805.44 N 1164.81 W 4944.60 N 13 37 W 4975.78 N 1164.67 W 5110.~7 N 13 10 W BP EXPLORATION 2-ZZ/L-14 NORTH 5LUPE~ ALASKA COMPUTATION D6Tr-: ZS-~PR-89 KELLY DATE OF SURVEY: BUSHING ELEVATION: ENGINEER: PAGE 6 17-APR-B9 55.50 FT MCBRIDE /COX IRUE MEASURED V~-R!ICAL DEPTH DEPTH SUB-SE VERT IC L)EPT O.OO o.o0 -55. '55.50 5).DO O. 155.50 155.50 100. Z55.50 255.50 ZOO. 355.5U 355.50 300. ~55.5U 455.50 400. 5~5.50 555.5U 50.0. 655.50 655.b0 600. 855.50 855-50 800. 955.50 9~5.50 ~OU. 1055.50 1055.50 1000. 1155.50 1155.50 1100. 1255.50 1255.50 1ZOO. 1355.V0 13V5.50 1300. 1455.50 1455.50 1400. 1555.51 1555.50 1500. 1675.51 1657.50 1~00. 1155.51 1755.~0 1~00. 1855.51 1855.50 1800. 1955.51 1955.50 1900. ZU55.51 Z055.50 ZOO0. Z155.51 Z155.50 2100. 2255.51 2255.50 2200. 2~55.51 Z355.50 2300. Z455.51 Z~55.50 2400. Z555.51 2555.~0 2500. 2655.51 Z6~5.50 2500. Z155o52 Z155.~0 2100. Z855.52 285~.50 2800. Z955.52 2~55.50 ZOOO. 3055.52 J055.50 3000. 3155.5M 3155-50 3100. 32~5o52 3255.50 3200. 3355.~4 3355.50 3300. 3455.62 3455.50 3400. 3556.05 3555.50 3500. ~657.20 3655..50 3600. 3759.~2 3755.50 3700. 3~63.14 3~55.50 3~00. NTERPULATEO VALUES FOR A .COURSE ~L :~~ION AZIMUTH H =~-D.'~~N DEG MIN 50 O0 O0 O0 O0 O0 UO O0 OO O0 0 '0' N 0 0 E 0 0 N 32 3 W 0 O N 34 9 E 0 0 S 68 ~ w .0 4 S 21 57 E 0 I S 25 13 E 0 9 S 12 16 W 0 3 S 34 1S E 0 1 S 62 26 W 0 8 S 36 20 W 90 O0 O0 O0 O0 O0 O0 O0 O0 O0 0 3 S 26 59 E 0 3 S 15 23 W 0 I0 S 13 43 W 0 11 S 7 21 W 0 19 S 34 34 W 0 24 S 46 53 W 0 14 S 48 32 W 0 1Z S 57 38 w 0 5 S 37 36 w 0 5 S 57 29 W O0 O0 OO O0 o0 o0 O0 O0 O0 O0 0 1 N 71 47 E 0 1 N 55 17 w 0 6 N 88 0 E 0 5 S 86 17 E O 19 S ~.4 11 E 0 ZT S 82 2~ E 0 21 S 78 53 E 0 20 S 6~ 15 E 0 23 S 68 ~ E 0 19 S 52 ZO E O0 o0 O0 O0 O0 O0 OD OD O0 o0 0 0 0 0 1 3 6 lO 13 17 25 S 35 17 E 16 S 26 10 E 9 S 79 41 E 38 N 32 Z1 E 5 N 27 32 E 36 N 2 7 W 54 N 12 34 w 7 N t! 27 w 34 N 11 34 W 13 N 15 49 ~ EVEN 100 VERTICAL SECTION FEET 0.00 0.00 0.00 0.01 -0.05 -0.15 -0.29 -0.50 -0.52 -0.59 FkET OF SUB-SE~ DEPTH 90GLEG RECTANGULAR CO SEVERITY NORTH/SOUTH EA DEG/IO0 FEET O.OO 0.00 N 0.00 0.00 S 0.00 0.00 S 0.00 0.01 N 0.10 0.05 S 0.17 0.14 S 0.00 0.29 S O.1Z 0.50 S 0.00 0.53 S 0.1~3 0.63 S ORDINATES ST/WEST EET 0.00 E O.OO W 0.00 W 0.00 E 0.01 E 0.09 E 0.05 E 0.05 E 0.05 E 0.08 W -0.15 0.03 0.80 S 0.11 W -0.83 0.04 0.88 S 0.08 W -1.00 0.07 1.08 S 0.16 W -1.29 0.16 1.39 S 0.21 W -1.66 0.28 1.81 S 0.37 W -2.04 0.17 2.33 S 0.85 W -2.32 0.19 2.73 S 1.26 W -2.37 0.15 2.87 S 1.59 W -2.47 O.OZ 3.02 S 1.79 W -2.54 0.06 3.13 S 1.94 W -2.59 O.1Z 3.19 S 1.97 W -Z.55 0.13 3.15 S 1.98 W -2.59 O.lZ 3.18 S 1.92 W -2.60 0.24 3.14 S 1.75 W -Z.77 0.18 3.23 S 1.38 W -3.02 0.07 3.30 S 0.69 W -3.32 0.16 3.43 S 0.01 W -3.65 0.01 3.63 S 0.56 E -4.07 0.10 3.91 S 1.13 E -4.44 0.10 4.17 S 1.61 E -5.01 0.01 4.65 S Z.04 E -5.58 0.24 5.14 S 2.39 E -5.87 0.60 5.41 S 2.52 E -5.49 0.36 4.91 S 2.93 E -4.47 0.80 3.67 S 3.66 E -1.08 3.57 0.01 S 4.23 E 8.00 3.53 8.98 N Z.70 E 23.08 3~50.. 23.77 N 0.35 W 44.15 3"19'~ 44.46 N 4.50 W 71.60 3.~'66 71.03 N 11.38 W i ~_, DIST. FEET DEPARTURE AZIMUTH DEG MI N 0.00 N 0 0 E O.O0 5 79 0 W 0.00 $ 82 28 W 0.01 N 10 35 E 0.05 5 15 0 E 0.16 S 31 57 E 0.30 S 9 15 E 0.51 5 5 14 E 0.53 S 5 35 E 0.63 S 6 53 w 0.81 1.09 1.40 1 3.00 3.28 3.51 3.68 S 7 33 W 5 5 17 W S 8 30 W S 8 28 W S 11 25 W S ZO Z W S 24 46 W S 29 0 W 5 30 40 W S 31 44 W 3.75 S 31 42 W 3.7Z S 3Z 6 W 3.71 S 31 4 W 3.60 S 29 7 W,,~_.~ 3.51 S 23 9 W 3.37 S 11 ~+8 W 3.43 s 0 5 W 3.67 S 8 45 E 4.07 S 16 11 E 4.47 S Z1 7 E 5.08 5.67 5.96 5.1 Z 5.18 4.23 9.38 23.77 44.69 71.93 5 23 39 E 5 24 58 E 525 0 E S 30 51 E S 44 55 E S 89 53 E N 16 45 E N 0 50 W N 5 46 W N 9 5 W BP EXPLURA%IUN Z-ZZ/L-I~ MPI ENDICOTT NURTH SLOPEm ALRSRA COMPUTATION DATE: 25-a. PR-89 PAGE 7 DAT~ OF SURVEY: 17-APR-89 KELLY BUSHING ELEVATIUN: 55.50 FT ENGINbER: MCBRIDE /COX INTERPOLATED VALUES .~OR EV'EN 100 PEET OF SUB-SEA DEPTH TRUE SUB-S~A MbASUREU VERT[CAL VERTICAL DEPTH DEPTH DEPTH 3969.06 3955.50 3900.00 4077.73 4055.50 4000.00 26 -53 4189o49 4155.50 4100.00 27 43 ~OJ.J8 ~2~5.50 4200.00 29 33 4½gU.J3 ~355.50 4~00.00 32 55 4542.15 4455.50 4400.00 36 33 4668.92 4555.50 4500.00 39 4 4%98.U9 ~655.50 4600.00 ~9 13 49Z7.00 47~5.50 4100.00 39 0 ~055.49 4855.50 4~00.00 38 47 COURSE D~~%ON AZIMUTH N 13 4~ W N 14 5~ W N 19 42 W N 21 35 W N 21 33 W N 21 32 W N 21 ~ W N 20 57 W N 20 54 W N 21 2 W VERTICAL DOGLEG RECTANGULAR CUORD'INATES HURIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 106.44 3.84 104.69 N 20.37 W 106.66 N 11 0 W 148.90 3.55 145.94 N 30.47 W 149.08 N 11 47 W 19R.72 2.43 193.57 N 45.23 W 198.79 N 13 9 W ~52.86 2.15 244.44 N 64.74 W 252.87 N 14 49 W ~13.04 3.12 300.81 N 87.03 W 313.14 N 16 8 W 382.06 2.51 365.46 N 112.60 W 352.42 N 17 7 W 459.42 1.43 438.02 N 140.91 W 460.13 N 17 49 W 540.70 0.14 514.39 N 170.13 W 541.79 N 18 18 W 621.55 0.25 590.37 N 199.19 W 623.06 N 18 38 W 701.74 0.52 665.70 N 228.06 W 703.68 N 18 54 W 0.57 740.07 N 256.72 W 78~.33 N 19 7 W 0.09 814.07 N 285.77 W 862.77 N 19 ZO W 0.07 887.88 N 315.06 W 942.13 N 19 32 W 0.34 961.57 N 344.53 W 1021.43 N 19 42 W 0.35 1034.42 N 374.02 W 1099.96 N 19 52 W 0.30 1106.74 N 403.49 W 1177.99 N 20 1 W 0.24 1178.12 N 432.71 W 1255.07 N ZO 10 W O.ZO 1248.60 N 462.01W 1331.34 N ZO 18 W 0.51 1318.10 N 491.12 W 1406.62 N 20 26 W 0.22 1386.29 N 519.81 W 1480.54 N 20 33 W 0.17 1453.78 N 548.48 W 1553.81 N 20 40 W 0.60 1521.03 N 577.19 W 1626.87 N ZO 46 W 0.40 1588.69 N 605.96 W 1700.33 N 20 52 W 1.36 1657.38 N 634.84 W 1774.81 N ZO 57 2.21 1727.62 N 660.91 W 1849.72 N ZO 56 W 0.72 1799.04 N 681.30 W 1923.72 N ZO 44 W 0.83 1872.17 N 699.53 W 1998.59 N ZO 29 W 0.76 1945.45 N 717.48 W 2073.54 N go 14 W 0.29 2018.65 N 735.07 W 2148.32 N ZO 0 W 0.56 2091.90 N 752.3Z W 2223.07 N 19 46 W 0.43 Z164.45 N 768.92 W 2296.97 N 19 33 W 0.46 2235.52 N 785.18 W 236~.40 N 19 0.63 2306.35 N 801.36 W 2441.60 N 19 9 W 0.66 2377.23 N 817.16 W 2513.76 N 18 58 W 0.92 2448.62 N 832.76 W 2586.36 N lB 46 W 0.94 2520.38 N 84B.74 W 2659.45 N 18 36 W 1.10 2591.99 N 865.51 W 2732.67 N lB 27 W '0:~:30 2664 17 N 882.14 W 2806.41 N 18 19 W :'1: * ]2 '~?~ 2737:45 N 898.80 W Z881.23 N 0.86 2813.20 N 915.18 W 2958.31 N 18 I W 5183.36 4955.50 4900.00 38 21 5~11.11 5055.50 5000.00 38 26 5438o81 5155.50 5100.00 3~ 25 5566.4~ 5255.50 5200.00 38 21 569~o66 53)5.50 5300.00 38 0 5~Z0o54 5455.50 5~00.00 37 5~ 5946.83 5555.50 5500.00 37 30 60~2.63 5655.50 5600.00 37 9 6197.~4 5755.5U 5700.00 36 45 6322.23 5855.50 5800.00 36 18 N 21 13 W 780.93 N 21 33 W 859.88 N 21 42 W 938.70 N 21 54 W 1017.45 N 22 9 W 1095.38 N Z2 9 W 1172.80 N 22 25 W ]249.Z6 N 22 39 W 1324.86 N 22 47- W 1399.46 N 22 52 W 1472.69 64~6.24 5955.50 5900.00 36 5 6510.12 6055.50 6000.00 36 13 6694.23 6155.50 6100.00 3~ 23 6818.95 6Z55.50 6200.00 36 55 69~3.91 6355.50 6300.00 36 37 7U68.49 6455.50 6400.00 36 35 ~193.11 5555.50 6500.00 37 5 1318.98 6655.50 6600.00 36 53 ~444o15 6755.50 6700.00 37 3 7569.~0 6855.5~ 6~00.00 ~6 55 N ~3 6 ~ 1545.24 N 23 5 W 1617.56 N 22 58 W 1590.29 N 22 1~ W 1764.06 N. !7 57 W 1838.61 N !4 9 W 1912.86 N lB 52 W 1988.22 N 13 35 N Z06~.67 N 13 Z$ W 2138.94 N 13 1 W ZZ14.17 '1693.96 6995.50 6900.00 36 25 1817.11 7055.90 i'O00.00 35 59 7941.32 %155.50 7100.00 35 52 8064.91 1255.50 7200.00 36 14 8188.76 1355.50 ]'300.00 3~ 18 [;312.88 7455.50 ~400..00 36 19 8~37.01 7555.50 7500.00 36 8561.~6 1655.50 7500.00 36 48 B6U6.55 ~755.5~ TTO0.O0 37 23 H813.06 7855.50 7800.00 38 3 N 12 50 W 2288.55 N 12 54 W 2361.42 N 12 43 W 2434.04 N 12 21 W 2506.61 N 12 18 W 2579.63 N 12 56 W 2653.10 N I3 IO W 2726.62 N 12 51 W 2800.66 N 12 39 W 2875.77 N 11 42 W 2953.20 BP EXPLORATION Z-II/L-14 ENDICUTT NORTH 5LOPE9 ALASKA COMPUTATION DATE: IS-APR-89 PAGE 8 DATE OF SURVEY: 17-APR-S9 KELLY BUSHING ELEVATION: 55.50 FT ENGINEER: MCBRIDE /COX INTERPOLATED VALU7-$ FOR EVEN 100 FEET OF SUB-SE~, DEPTH . hS TRUE SUB-SEa - >~-~ COURSe VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURtD VtRrICAL VERTICAL B~E, ION AZIMUTH SECTION SEVERITY NORTH/SOUTH E~ST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH~- -:~J~N~ DEG MIN FEET OEG/IO0 FEET FEET FEET DEG MIN U~40.50 795b.bO 7900.00 38<28 N 10 15 W 303Z.03 ~068.57 805b.50 8000.00 38 55' N 8 19 W 3111.70 9197.~7 8155.50 8100.00 39 18 9JZ~.ZO BZ55.SO 8ZO0.O0 39 50 9458.35 8355.50 8300.00 41 1 9590°?3 8465.50 8400.00 40 25 912Z.~6 055-5.50 8500.00 41 b 9856o46 8655.50 8600.00 42 Il 99~2.31 875b.bO 8700.00 43 6 10130.93 8855.50 8800.00 ~4 30 N 5 55 W 3192.33 N 3 24 W 3273.71 N 5 4 W 3356.96 N 9 27 W 3442.97 N 11 47 W 3528.71 N 10 44 W 3617.60 N 9 36 W 3709.35 N 9 5 W 380~.83 IOZIU.U? ~95b.50 8900.00 44 5 1U~U9.4b ~055.50 9000.00 43 39 1U547.36 9155.50 9100.00 ~3 21 10685.~6 ~Z55.50 9200.00 42 Z 10816.~B 9355.50 9300.00 40 43 I8947.01 9455.50 9400.00 39 2 1107~.93 9565.50 9500.00 36 53 11191.~2 ~655.b0 9500.00 35 0 11318.80 9755.50 9100.00 34 2Z 114~9.6~ 9855.50 9900.00 34 6 11560.~3 9965.59 9900.00 Ia 31 l168Z.lZ 1005~.50 lO000.O0 34 27 11803.06 10155.50 10100.00 33 55 11~Z3.05 10255.50 10200.00 33 14 1204Z.16 10365.50 10300.00 32 26 IZ16U.~U 104~5.50 10400.00 32 13 IZ3ZZ.OO 10593.Z4 10537.74 31 24 N 9 28 W 390Z.29 N 9 19 W 3997.93 N 9 1 W 4092.36 N 8 35 W 4184.35 N 8 15 W 4272.00 N 7 23 W 4354.78 N 5 45 W 4432.06 N 5 17 W 4503.60 N 4 25 W 4571.40 N 3 Z= W 4638.15 N 3 4 W 4705.00 N 2 6 W 477Z.26 N I 19 W 483~.58 N 0 56 W 4903.04 N 0 Z9 W 4965.86 N 0 4 W 5026.95 N 0 Z9 E 5108.57 0.88 1.08 1.31 I .30 3.03 2.41 I .03 0.81 0.97 0.TB 0 0.38 0.58 1.11 1.30 1.12 1.03 1.32. 0.56 0.20 0.77 0.86 0.gz 0.61 1.40 0.83 0.00 Z890.7Z N 930.30 W 3036.73 N 1~ 50 W 2969.68 N 943.2.8 W 311b.89 N 1T 37 W 3050.37 N 9~3.41 W 3195.89 N 17 Zl W 3132.73 N 960.12 W 3276.56 N 17 2 W 3217.40 N 965.37 W 3359.11 N 16 42 W 3303.41 N 976.45 W 3444.?0 N 16 28 W 3387.70 N 993.01 W 3530.24 N 16 ZO W 3475.02 N 1010.42. W 3618.94 N 16 12 W 3565.63 N 1026.61 W 3110.48 N 16 3 W 3660.26 N .1042.12 W 3805.72 N 15 53 W 3756.88 N 1057.89 W 3902.98 N 15 43 W 3851.51 N 1073.63 W 3998.35 N 15 34 W 3945.30 N 1088.64 W 409Z.74 N 15 25 W 4036.66 N 1102.83 W 4184.60 N 15 16 W 4123.88 N 1115.78 W 4272.15 N 15 8 W 4206.42 N 1127.33 W 4354.87 N 15 0 W 4283.95 N 1136.33 W 4432.09 N 14 51 W 4356.03 N 1143.43 W 4503.61 N 14 42 W 4424.58 N 1149.30 ",4 4571.41 N 1~ 33 W 4492.36 N 1153.89 W 4638.19 N 14 24 W 4560.44 N 1157.80 W 4705.11 N 14 14 W 4629.19 N 1160.76 W /,772.50 N 14 4 W 4697.18 N 1162.91 W 4838.99 N 13 54 W 4763.47 N 1164.17 W 4903.66 N 13 44 W ~ 4828.16 N 1165.09 W 4966.75 N 13 34 W 4891.26 N 1165.27 W 5028.15 N 13 Z4 W 4975.78 N 1164.67 W 5110.Z7 N 13 10 W BP ~XPLURATION Z-Z2/L-14 MPI ENDICOTT NURTH SLUPE~ ALASKA GCT LAST 'READING P~TIJ URILL~-R' S DEPTH COMPUTAfIgN DATE: 25-APR-S9- PAGE 9 DATE UF SURVEY: 17-APR-89 KELLY BUSHING ELEVATION: 55.50 FT ENGINEER: MCBRIDE /COX INTERPOLATED VALUES FOR CHOSEN HORIZONS ~!~..!.i~.~.~ SURFACE LOCATIDN = 1919' SNL E 222~' WEL, SEC36, T12N, R16E :~.. ~'ASURED UE~TH TVO RECTANGULAR COORDINATES ;-~ :.i!~:'.,~.BELDW KB PROM KB SUB-SEA NORTH/SUUIH EAST/WEST 12207.39 10~95.~5 10439.85 ~915.99 N 1165.18 W 12236.00 10519.84 10~64.3~ 4930°95 N 1165.05 12312.00 1059~.a~ 10537.71 ~975.78 N 116~.67 Z-ZZ/L-14 ENDICOTT MARK[R PBTD DRILLER'S D~PTH CONPUTATIgN DATE: Z5-~PR-89 KELLY · · :~.,~ ,~ SURFACE LOCATION = 1919m SNL E i:i;-~?~ASURED DEPTH TVD -= ': :~ :-'~ BELOW KB FROM K~ SUB-SEA 12236.00 10519.8~ 10464.54 12322.00 10593.24 10537.7~ PINAL MEASURED DEPTH lZ3Z2.O0 WELL LgCATION IRU~. YERT[CAL DEPTH 10~93.Z4 AT TD: SUS-SE~ HORIZONTAL DEPARTURE VERTICAL DISTANCE AZIMUTH DEPTH FEET OEG MIN 105~7.7~ 5110.27 N l~ 10 DATE OF SURVEY: BUSHING ELEVATION: ENGINEER: PAGE 10 1T-APR-B9 55.50 FT MCBRIDE /COX 2ZZ~' WEL, SEC36, TIZN, R16E RECTANGULAR COORDINATES NORTH/SOUIH EAST/WEST 4930.95 N 1165.05 W 4975.78 N 1164.67 W SCHLUMBERGER O I RE C T I ONIAL SURVE Y COMPANY BP EXPLORATION WELL. 2-22/L- i 4 MP I FIELD END I COTT COUNTRY USA RUN ONE DATE LOOOED 17 - APR - 89 REFERENCE 73296 WELL' (1919' L 2 24' WEL ', ~EC 36, T12N, R16E) HORIZONTAL PROJECTION 6000 SCALE = 1/1000 IN/FT ~.~...`...`...`.~f-~..~...~.~.~....?T.....:.].?Z.?].Z~.Z~ZT.~Z~....+.-;...;-*iIZ.~]Z7T~;~ "'?'-~":"'r]~"'~'"?7.'"?'7'"'7"rZT!'].~E?Z~L'i.:'Z?Z.~.ZC'rT?T?"~";'? i'i-i ':'"i"':"": ....... .'. ¢ ".~"?'"~' ?' '! 'f' ?' -'. ' ?'~ '? ~ ! ~"'? ..... t"'~'"W"'? .... ~'""t"T'"~ ..... ?"'?"'!"!' ? ~ : ? 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Full Cherse Pressure Accained~....~ Conc=o~,~ ~ocer ~~ ..... .-. - ~emoce_~ Bl~udo ev~Cch cover~~ , t .... ReZXy a~ FXoor Safe~_Ve!ves. Lo~e~ E~lly_./ Tone F~nanutn ...... ~, , Xne~m BOP, ~Tmat. Pramaucl.,. ~ _. No, Valves , /~ ' ,.- _. .-, No, flantes , , ._. - .... AdJu. ta~le Chokes ~'- -- i ~esulCsz Failures ~- ,Tmo~ TJ3ne__.'~ hrs. ....... - , off Eoplaaeme~c o~ faS]ed Pq,,tpmanc tfl ~a made within days and Zn~peccor! ' ! Conn.~sion office ~o~tfied,. / / / / , .~ ~' . - -- , em _ lB ....... I I I I m . -- m i i "~,-' I i -. I _. ii -- - Discrtb~cicn cc - Supervisor Standc~.d Alaska Production Company WELL ~ ---~-' ~'~ /1~ ~-'- TEST FLUID //~ ('? ACCUMULATOR VOLUME /~ ~~ TEST TYPE: DWEEKLY ~FLANGE UP ~CASI~G SET LAST CASING: '/~'} "AT~~ .. PRESSURE & PERFORMANCE TESTS: BOP EQUIPMENT TEST REPORT BOP STACK--LIST ALL ITEMS TOP TO BOTTOM, MANUFACTURER AND TYPE, SIZE OF RAMS, ETC. , %.."'.' ,,¢.,'? t " / ~ ," ~ ' ' ' q ~ ~ ' , ~'. ~ ..~ '," .~ ~ / ACCUMULATOR ACCUMULATOR ONLY TEST TEST & PUMPS UNIT PRESSURE TIME CLOSING CLOSING RECHARGE TIME TIME TIME ANNULAR ~,~. ~'C)~'~ 3~ / ~ BLIND RAM ~~ PIPE RAM ~ PIPE RAM ~ CHOKE MANIF. ~ ~ TEST TOOL: ~ PLUG, ~CUP, ~PACKER ~. KELLY COCK gl ~ ~ CASING TESTED: FT. TO .PSI. ACCUMULATOR RECHARGE: ~ PSI BEFORE TEST, KELLY VALVE g2 ~ ~ ~~ PSI AFTER CLOSING ALL BOP'S ~ INSIDE BOP ~ ~ ~' 7~. MIN. RECHARGE TIME. , sop DroLL SEC. KELLY HOSE ~~ ~ TR~P DR~LL SEC. STAND PIPE t~ ~ NITROGEN PRECHARGE: 1. 2 CHOKEUNE ~~ ,, 4. S.~ S.~ 7. ~ _8.~ 9. 10. ~11. ~12. ~13. KILL LINE " ~ 14. 1 5. 16. EQUIPMENT CHECKLIST YES NO CIRCULATING HEAD ON FLOOR V INSIDE BOP ON FLOOR & SUBS KELLY VALVES ON FLOOR & SUBS "~PARE KELLY VALVE v/ "~VT SYSTEM OPERATING t,/ FLOW SENSOR OPERATING ,-~/' STROKE COUNTER OPERATING TRIP TANK v/' LOCKING SCREWS ON BOP & ALL VALVES OPERATE EASILY. /, GAS SNIFFER OPERATING BARITE ON HAND /O GEL ON HAND Z~'Z,~ WATER ON HAND SURFACE MUD VOLUME HYDRAULIC OIL ON HAND NITROGEN BACKUP SYS. ~ .NO. OF BOTTLES HOOKED UP, AT~~;~ PSI NITROGEN PRESSURE. SACKS SACKS BBL BBL DRUMS MALFUNCTIONS & COMMENTS (ITEMIZE ALL LEAKS, MALFUNCTIONS~QI~.I~I~{elo~R, MEN3;_ET.C~ AND ACTION TAKEN.) / /' ,/ 4 SUPERVISOR: TO BE COMPLETED AND PUT ON FILE FOR EACH BOP TEST. AK 2283-2 (3-88) March 21, 1989 Telecopy: (907)276-7542 J. G. Vidrine Endicott Drilling Engineering Supervisor BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Duck Island Unit/Endicott 2-22/L-14 BP ExplOratiOn (Alaska) Inc. Permit No. 89-34 Sur. Loc. 1919'SNL, 2224'WEL, Sec. 36, T12N, R16E, UM. Btmhole Loc. 2032'SNL, 3276'WEL, Sec. 25, T12N, R16E, UM. Dear Mr. Vidrine: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. To aid us in~scheduling field work, please notify this .office 24 hours prior to commencing installation of 'the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is.required, please also notify this office 24hours prior t° commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Vet , / Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 March 15, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Attn' Mr. C. V. Chatterton Well 2-22/L-14 MPI (Endicott) Enclosed, in triplicate, is form 10-401, our Application for Permit to drill the above-named well. Also included are the , attachments noted on the permit form and our check in the ... amount of $100.00 to cover the permit filing fee. Yours v,ery, truly, ,Ii G. Vidrine Endicott Drilling Engineering Supervisor JGV/KTH cc' Richard Loveland Well File STATE OF ALASKA { ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrilll-Illb. Type of well. Exploratoryl'-I Stratigraphic Testr-I Development OiliZ] Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration BKB=56 feet Endicott Field/Endicott Pool 3. Address 6. Property Designation P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 34633 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 ^^c 25.025) 1919' SNL, 2224' WEL, SEC. 36, T12N, R16E Duck Island Unit/Endicott At top of productive interval 8. Well number Number 2350' SNL, 3210' WEL, SEC. 25, T12N, R16E 2-22/L-14 MPI 2S100302630-277 At total depth 9. Approximate spud date Amount 2O32' SNL, 3276' WEL, SEC. 25, T12N, R16E March 26, 1989 $2OO, OOO. OO 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth (MD and TVD) property line ADL 34634 2004 feet 2-26/N-14 20 feet 2560 12498'MD 10656'TVDfeet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickott depth 3500 feet Maximum hole an~lle 39.80 Maximum surface 3900 pslg At total depth (TVD)9855'/4840 pslg 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" Struct. Drive Pipe 75 Surface 131' 131' 17-1/2" 13-3/8" 68# NT80 Butt 2444 Surface 2500' 2500' 2700 cu fl Permafrost 12-1/4" 9-5/8" 47# ' NT80S NSCC 9635 Surface 9691' 8500' 12-1/4" 9-5/8" 47# NT95HS NSCC 1635 9691~ 8500' 11326' 9756' 575 cu fl Class G 8-1/2" 7" 29# NT95HS Butt 1422 11076' 9564' 12498' 10656 457 cu ft Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical ..... 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. I hereby ce_rtify,.,,t~,th~ f. or~)goir~ is t~rue and correct to the best of my knowledge Signed/~,~ ~X~.~~J,~/~/.~v,..~, Title EndicottDrillin.~ En.qineering Supervisor Date._~//~,d~'~,. , Only Commission Ui~pprov~ Permit Number IAPI number ISoe cover letter ~-,.~7~ 150- O..z?-' ~./'¢,_?? /89 Ifor other requirements ConditiOns of approval Samples required [] Yes J~No Mud log required [] Yes ~"NO Hydrogen sulfide me_.~asures .[] Yes~,~ No D. ir, ection'a,~l survey requ~recl ~'Yes [] Required workin(,~t~uCr~::~13~,~[]10U; []15M; Other: ' by order of Approved by ~ ~ ' ' ~ ~t ~/(~v~ Commissioner ~ne commission Da.t Form 10-401 Rev. 12-1-85 Lte .PROPOSED DRILLING AND COMPLETION PROGRAM ,WELL 2-22/L-14 (MPD Obiective ;' , Well 2-22/L-14 will be drilled as a water injection Well. Zone 3A is the primary objective. The completion will be mn at the time of drilling and will consist of a packer-tailpipe assembly. Operation Execute a rig move to slot 2-22 and rig-up. Vertically drill 17-1/2" hole to 2500 ft. and cement 13-3/8" 68#/ft., NT-80CYHE Buttress casing to surface. Pressure test casing. Install BOPE. Maximum BHP is 4840 psi at 9855 ft. TVDss. Maximum possible surface pressure is 3900 psi based on a full gas column. Drill out casing and 5 ft. of new hole and conduct a formation leak-off test. Vertically drill 12-1/4" hole to 3500 ft., then directionally drill to the intermediate casing point above the Kekiktuk formation. Run and cement 9-5/8" 47#/ft., NT80S and NT95HS, NSCC casing. No abnormal pressures are expected in the 12-1/4" hole section. Pressure test casing. Drill out casing shoe. Drill 8-1/2" hole to TD. Run open hole logs. Run and cement 7" 29#/ft, NT95HS buttress (TKC) liner to TD with approximately 250 ft. of lap in the 9- 5/8" casing. Clean out to float collar. Test casing and lap to 3000 psi. Change over to NaC1 packer fluid. Run CET/CBT/VDL/GR/CCL in 7" liner and in the 9- 5/8" casing to the top of cement behind the 9-5/8" casing. Run gyroscopic survey from PBTD to surface. Perforate well under balance utilizing drill pipe conveyed guns. Flow well for simple clean-up. Kill well and complete with a packer-tailpipe completion. Perform MIT on completion. A sub surface safety valve will be installed below base of permafrost. Nipple down BOPE. Install tree on wellhead and release rig. The 13-3/8" x 9-5/8" annulus will be freeze protected with a non-freezing fluid down to 3000 feet with the rig on location. Note: Notify Alaska Oil and Gas Conservation Commission prior to pressure testing casing, production liner, liner lap, and performing MIT. KRL/3-11-89 L~g6P~I ±~99901 U3NI] IIQ§ SH§6±N I~/=6~..Z Gl NDV~ 9Rqd ~13~lDVd ..Z 3DSN SHS61N la/~Z~..9/S-6 1=1 9/01 I lJ 1~996 Izl 9~,:) I I 13 g~g6 dOl H3NIq .,/ U3NDYd ,.9/c~-6 qA33q§ 9NI(]I'IS ..gl 1 -t7 696 IJ 00S9 9g~6 (d31Vl,411c53) DDC;:jN cjOglN IJl~Llz ..9/cj-6 IN3LA3D ..9/g-6 JO dOl 3dld31Vl ..g/l-£ //~ 9Nl~ilqi Sell 09--I l_-1/=9'g l '..g/I -t7 /.J O0 _c,£ ( 93(:]g'6£ :319NV '~ ,L'I I N:}:Jla)dON J.J 0OO£ (CI31¥Kt11S3) NOIID3IOHd 3Z33U_-I -lO klOllO~ IJClO~g lJ OOgg Dig 3HADOg-IN IJ/=99..9/£-£1 I..-~ OS.c,.` I LJ ogcj I ASSS .i.:l 9917 I IJ 99171 I§OHJV~dHRd 3SV§ ~ J.:l l £ I iH 1 £ 1 3did 3AI~CI ,,0£ riAL O I n-I_-I 9NIZ33~J-NON NVHgVlQ Ci3SOdO~d ilODIGN3 B.O.P. STACK CONFIGURATION 13-5/8 IN. TRIPLE RAM STACK SO00 PSI WP DRILLING ANNULAR PREVENTER I ! PIPE RAMS I i I BL IND....RAMS . I ! ! 2_ IN. KILL LINE ' !,,, j 4 I.. cHOKE LI.E ' DRILLINGSPOOL ~ GATE GATE 6ATE i ] GATE I I PIPE RAMS i I ENDICOTT DEVELOPMENT WELL 2-22/L-14 (MPI) DEPARTURE TO BHL: 5272 FT 12498 FT M D 10656 FT TVD BKB DEPARTURE TO TARGET: 4947 FT 11990 FT MD 10266 FT TVD BKB N 11° 40' W TRUE NORTH GRID SLOT 2-22 SURFACE LOCATION X = 258,984 FT; Y = 5,982,498 FT 1919 FT SNL; 2224 FT WEL SEC 36, T12N , R16E NOTE: THE NEAREST WELL TO 2-22/L-14 IS 2-26/N-14 LOCATED 20 FT SOUTHEAST AT SLOT 2-26. KRL/3-11-89 ., ,i __ · IIIIII1~ ldain ProductiM Island (ldPI) ....... T. IZ N. I S 4 T. IIN. \ :~~~,,12 ,. "% ~~, , ~~:'~ ~":.~.77~., .... ..' ~,/:';r"; ~ hi( nd ~Satellite4,, Dr l. inI Islnnd (SDI) · .f - ... ~,.. ~~' ' 'q ~ :::,7~ :-', DickI Island · ~,-.- ~¢.~/T,, k ' "~"' ::''-'~7' ' DRW NO. IIG- 85 ,1 SHEET I of I0 , REV'. 0 PLAT OF PROPOSED WELL LOCATIONS ldPI Vlblll Llceted IA Si¢.;S&.T.I~N-~R. ISE.,Umi4t M. .SDI Wells LM:Mtd IA Ss-I:. I,T.IIN.,R.I?E.,UNITIt IL PREPARED FOR SOIIIO ALASKA PETROI. EUId CO. PREPAR E~ IY F.R. BELL & ASSOC. PRUOHOE BAY OFFICE PRUOHOE BAY, ALASKA BATE: NOV. 13, It85 SCALE: I"81 MILE WN BY: RG.T. CXECXED BY' I.E. $4 36 ~ 20 IIII ....... i IJ~ .. o I ~$o 7'0 ii ~)0 I~ 0 17 I~) 0 ~ 0 ~1 0 ~$ 0 z?~© .?o ° 6 ~.~0 6 e(~7050 NO TEE' 36 CERTIFICATE OF SURVEYOR o I Iloarbycertifythatl em properly registered and licensed to proctica land aarvaying ia the State ~ Aiaskae~that this plat represents aa propoaed I~atioa for fha'Well num~ra Ihown above. All e~rveyiag ~as do~e by me o~ under ~y supervis~n~ and t~t ell di~naions a~d details ara correct. Indicates well Indicates Calc[Hated Section Corner Polition Indicate~ Parpendicaler Offset Oisfan~l Indicate~ ~~iculer Offer Distance ~en~icular ~istanc~ ' PLAT OF ~PI P~OPOSED ~ELL LOCATIONS L~GATE~ IN ~EC.~,T.I~.,R.I~ E. U.IAT ~. PREPARED FOR SOHIO ALASKA PETROLEUM CO. DRW. 116-85 SHEET 2 of I0 u REV. 0 PREPARED BY F.R. BELL S ASSOC. ' PRUDHOE BAY OFFICE PRUDI, IOE BAY, AL, ASKA DATE' NOV. 115, 19t5 SCA LE' I W# IY: R.~.T. CHECKED BY' I,E. " " ,, I I II .r' I I II I.,'"'~ I I I I IIELL AlP ZOl~ I UT), ( .. 6 LATXTUBE L~ ~ ( lilt ,. ! Y- S912412.37 N- 7105524.5! 70G2t'ZO.O&70' 14~S7'2e.4~' X. 259119,70 E- 464t37,~6 2 Y- ~982~79.88 N- 780~3~3.~2 70~2X'20.98X4· 247~57'24.6237· ~83S,43 2~6B,94 X- 23904~,49 E- 464094.4~ 3 Y- 5982474.18 'N- 7805321,98 70c21'09.9846' 147=57'20,6258" 1936.77~ 2032.11 ~X- 259175.01 ! E. 464135.65 5 Y. 5982465.99 N- 7805319.46 70c21'09.9023" 147c57'20.7857" 1945.15' 20~7.58- X- 259169.27 E- 464133.95 & Y- 598256~.50 N- 7B05~48.47 70o21'10.816B· 147~57'24.9454' 1852.17~ 2179.~8 ~- 2590~0.02 E- 4&4091.04 7 Y- 5982457.B0 N- 7B05~16.94 70c21'09.B200· 147o57'20.9455" 1~53.52 2043.06 X" 2~916~.54 'E' 464132,24 8 Y' ~9825~,30 N' 780~34~.94 70~21'10.7344' 147°~7'25,10~3' 1860.~4 21B~.3~ X' 259024.29 E' 464089.33 , 9 Y- 5982449.61 N- 780~314.41 70~21'09.7376· 147057'2~,1054· 1961.B9 204B,53 X- 2~9157,B0 E- 464130.53 10 Y- 5982~47.1~ N- 7B0~343.42 70o21'10.6521· 147~7'25,2651· ZB68,91 2190,83 X- 2~9018,~5 E~ 464.087,62 11 Y- 59B2441.42 N- 780~311.B9 70~2~'09,6~3· 147o57'21.2653· 1970.26 2054,00 X- 2~9~52,07 E- 464128,B3 12 Y- 59B2~38.92 N- 7B05340.90 70~ 21'10, 5697· 147o57'25,42~0· 1B77.2B 2~96.30 X- 259012.82 E- 46408~.92 I - t~ Y- 59824~3.23 N- 780~09.36 70~21'09.57~0' t47o~7'21.4251' 't978.63~ 20~9.47 X- 259t46.33 E- 464127. t2 t4 Y- 5982530.73 N- 7805338.37 70~ 21'10. 4874' 147°57'25.5B49' tBGS.&6 2201.77 X- ~9007.08 E- 464084,2t t5 Y- 5982425.03 N- 7805306.84 70c21'09.4906' 147c57'21.5850' 1~87.00 2064.94 X- 259140.60 E- 464125.42 16 Y" 5982522.~4 N" 7805335.85 70°21'10.4051' t47°57'2~,7447' 1194.03 2207.24 X' 25900t.35 E' 4640B2.50 t7 Y~ 5982416.a4 N' 7805304.31 70°2t'09.40B3' t47~57'21.7449' t995.3B 2070.41 X~ 259t34.16 E~ 464t23.71 Ii Y' 59825t4.3~ N' 7B05333.32 70°21'10.3227' t47°S7'25.9046' t902.40 22t2.Tt X~ 258995.61 E' 464080.B0 19 Y- 5982408.65 N- 7B05301.79 70c21'09.3260' ~ t47°57'21.9047' 2003.75 2075.B9 ~- 259129. t3 E' 464122.00 20 Y' 5982506. t6 N' 7B05330.B0 70c21'10.2404' 147°57'26.0644' 1910.77 2218.1~ X~ 2~8989.B7 E· 464079.09 21 Y' 59B2400.46 N' 7805299.27 70°21'09.24~6' t47°57'22.0646' 2012.12 20~1.36 X' 2~9123.39 E' 464120.30 ~ , -, ~, ,r MPI PRO~SED WELL L~ATION LIST ~¢ ~ A~;~t "'~F' 1 ~':~ '~:::"~'::'~ LOCATED IN SEC. S6,T. IZN., R.ISE. UHIAT ~~..~~.,.'~"," :, SOHIO ALASKA PETROLEUM CO. ~,~ g~ ~9~ .'~ ~ DRW. NO. 116-e5 PREPARED BY DATE'NOV. I~, tk ~ ........ ~ SHE ET 3 of IO F.R. BELL & ASSOC ~k~c~i~~ ~ ~ ' SCALE: N/A -~%~~~ PRUDHOE BAY OFFICE ~RAWN BY: RG.T RgV. O PRUDHOE BAY, CHECKED BY, l.[ kl I III I I - I I J I I II I I II I IIIII I I II I I r I__ ~J. 22 Y- S912497.97 i- 710S321,27 7FZt't0. L~L' 14~7'26.2241' 19~9.:~ Z223.6~ X~ ~1914,24 E- 464077,31 23 Y-'~982392.27 N- 7B0~296.74 70°21'09.1613' 147~ 57 ' 22. 2244' 2020.49 2086.83 x- 259~7.65 E- 4641~'8,59 24 ~Y- 5962469.77 H- 7605~25.75 70~21'10.0757' ~47c57'26.3842' 1927.5~ X= 258978.40 ' E= 464075.68 . 21'09.07~0' ~ i47~57 22 3843 2028 86. 2092 30 ='X- 25~1{1.~2 [ E· 4441i4.B8 ~ ' ' ·] ' " { i~35.~0 2234 60 ~ N- 7805323 23 70: 2i O{ ~34 147:~7 26.5440 i · 24 'Y- 5982481.~8 , . . ,X= 258972.67 i E= 444073.97 ' , . i _ 27 ~Y" ~982375.89 ' N" 78052~1 49 ~70:21'08.9944" %47c~7'22.~442" ' 2037.24 ' 20~7.77 X- 259i06.18 Et 464115}19{ 28 Y- 5982473.39 N- 7805320 70 70021'09,9111' 147057'26.7039" 1}44,27 2240,07 X- 256964.93 E' 464072 27 29 Y- 5982367.70 N- 7805269.17 ~70c21'08.9143" 147c57'22.7040" 2045.&I 2103.24 X- 259100.45 E- 4441~3.47 30 Y- 5982465.20 N- 7BO5316.Zg ~70c2~'09.B287' 147057'24.8437, ~952.~4 {2245.54 X- 258941.20 E- 464070.36 { 31 Y- 5962359.50 N- 7805266 &5 {70c22'08.6320" t47CST'22.B&39' 2053.96 ] 2106.72 32 Y- 5982457. O1 Nm 7805315.65 ; 70c21'09, .7464" 147'57'27. 0236" 1941.01 i;2251 · 01 X' 258955.46 E' 464066.85 { 33 Y- 5982351.31 N- 7805264.12 {70c21'08.7496" ~ 470 57 ' 23 , 0237 " 2062.35 ~21~4,19 34 ym 5962448,82 N' 7605313.13 70c21'09.&641" 147057'27.1834" 1969.36 2256.49 X' 259066.03 E' 444~03.23 ~ ~{ 36 Y' 5982416.05 N' 7805303.03~ 70~21'09.3347" 147c57'27.B229" 2002.87 2276.37 X' 258926.76 E' 464060.32 ; 37 Y' 5962310,36 N' 7605271.50 i70°21'06.3379' 147e 57 ' 23, 8230' 2104.21 2141.55 X' 259060.30 E' 464101'53 . 38 Y- ~962407.B6 N- 7805300.51 ,70o21'09 2524' 147e57'27.gi27· 2011.24 2263.84 X- 25892[.05 E- 464058.61 39 Y- 5962302.17 N- 7805266.98 7~21'08,2556" 147c57'23.9129· 2112.58 2147.02 X- 259054.56 E- 464099.62 , 40 Y- 5962399.67 N- 7805297.98 i70°21'09.1700" 147~ 57 ' 28.1426" 2019.62 2269.31 Xi 258915.31 E- 464056'91,, 41 Y- 5962293.97 N- 7605266.45 70o21'08.~733· ~47G57'24.1427· 2120.~5 2152,49 X- 259046.83 Es 464098.t~ 42 Y- 5962391.48 N- 7805295.46 70021*09.0877· 147o57'28.3024· 2027.99 2294.79 X- 256909.56 Es 464055.20 , i i ~.;.%,:, ~, T,~r', , ,,:, , ~. ,,.., ~~.. ?, ...... ,. ~ ' . MP! PR~SED WELL L~ATION LIST ~ : · ,., , ~ ~ ~,e, ~ ~ ~.~ .... ,.... LOC4TED IN SEC. ~6 T. 12N. R. 16 E. UMIAT M. ~~~~~L,~:~~~ ~~' ' SOHIO ALASKA PETROLEUMCO. J~[~' ~' ER. BELL & ASSOC. &k~s~ SHEET 4 of ,0 SCALE: ./A '~~V PRUDHOE BAY OmCE -' REV O PRUDHOE BAY, ~ASKA DRAWN · ' ' CHECKED BY: B.E. i i i ii ~ELL AlP ZO~ 3 UTh ,, .~ & L&TZTU~E LO~ .. ! l! T IZlT 43 Y- ~9122fl"71 N-""TiOS2&3,93 70~21'01,0t09' 1'4~57'2'4,302&b' 21~,11" X- '~904~.09 E- 464096,4~ 44 Y- 5962~6~,29 N- 7605292,93 70'~21'09',0054' 147~57'28,4423' 20~&.3& 230~;2b X- 258903.B4 E- 46405~.50 . ~+ ..... --45 ~Y= 5~7~.59~N-, 7~6~2~-t".i6--?O'2~'O8.O~-B~*' 247~57'24.4~25' .' 2~3~;-~0'2-2'~. .~X, 259037.36 ; E= 464094.70 44 Y= 5982375. tO N= 7B05290.4~ 70;'21'OB.V230' { t47=57'2B.~22t" ~ 2044.73 2305.73 X= 25aaga.tt E= 46405t.79~ 47 Y= '59~2249.40 N= 7BO525B,aa . 70=2{ '07.9263" = ~47c57'2'4.~223" ] 2~46.07 '48 Y" 5982366,9~ N"' 7B0~287,89 170°2l '08.8407* 147°57'28,7i20~ 2053, lO j X" 258892,37 E" 464050,08 49 Y' 596226~.22 N" 7805256.35 7'0~22:07,84~9" ~47°57'24,'"71'~2~ 2254.44~ 2~74.~8 X= 259025,89 E' 46409~,29 50 Y' 5982358.7~ N" 7B05285,36 70°2~'08,7584' ~47~57'~i,94~B" 206~,47~ 23~&,67 X' 258886.&3 E" 464048.~8 5~ Y' 598225~,02 N' 7805253,8~ 7002~'07,7626" 147°57'24,'9420" 2~&2,B~ ~ 2~79,86 X" 259020,15 E' 464089,~8 I 52 Y' ~982350,52 N' 7805282,84 70c2~'08.6760" 147°57'29,~0~7" 2069,65 2322,~4 X' 2~8880,90 E' 464046,&7 , 5~ Y= 5982244.B~ N= 780~252.]2 70°22'07,679~" ~47o57'25.~029" 2~72,29 2~85.33 X- 2590t4.4~ E- 464087,88 54 Y- 5982342,33 N- 7805280,3~ 70°22'08,~9~7" ~47°57'29,2&~5" 2078,221 2327,&2 X- 2~8875,16 E- 464044.96 55 Y= 5982236.64 N= 7BO524B.78 70c21'07.5969" 147°57'~5.2627" 2179.56 2190';'80 X= 259008.68 E= 464086. t7 56 Y= 5982334.14 N= 7805277.79 70~2~-'08.511'3' ~47°57'29.4214' 2086.59~ 2333.09 X= 258869.43 E= 464043.26 57 Y= 5982228.44 N= 7805246.26 70~21'07.5146' 147°57'25.42t~' 2t87.93'2196.27 X' 259002.94 E= 464084.46 5e ~= 5982325.95 H= 7805275.27 70o2t'08.4290*'' ~47~57;'29'.5~t'2, 2094.96 X- 2~aa63,&e E- 46404t,55 59 Y" 5962220.2~ N" 7805243.73 70021'07,43i3" 147°57'25.5114" 219&.30 2201.74 X" 2~8997.21 E" 464062.76 6'"0 y. 982317.76 N- 'a0 272. 4 70 2i,0a.34 7. 147o 7,"29.7 iI. 2103.332344:03 X" 258857.96 E" 464039.85 - 61 Y" 5982212.06 N" 7805241.21 70~2~'07.~499" 1470 57 ' 25". 741~"' 2204.&7 2207.21 X" 2~8991.47 E- 4640~1.05 62 Y" 5982~09.57. N' 760~270.22 70c 2'1' 08. 2643~ .... 147°57"29.90~" 2111.71 2~49.50 X" 258852.22 E' 46403~.14 ~3'" Y" 598220~.87 N" 7~0523~.69 70021'07."2676" 147°57'25.9011" 2213;05 2212.&9 X" 258985.74 E' 464079.34 B II I I I II I I II · ~: ~ : , . , ,,~~.__~ .~ MPI PRO~SED WELL L~TION LIST .~ ~ 4C'-~1, ~?~'"'~ I ~:; '~'~;~?';~.} LOCATED IN ~C. 36 T.I~N. R. 16E. UMIAT M. , , , ,, t49~ · ~~~~2~ SOHIO ALASKA ~TROLEUM CO. ............. ,~OFEgS~~ SHEET Sol :O ER. BELL & ASSOC. SCALE' -~%~~ _ PRUDHOE BAY OFFICE .... DRAWN BY : REV. O PRUDHOE ~Y, ALAS~ cHEcKEoBY: I I i i ii i ii ii i II I II I III I II &4 Y- Stl2$0t,31 II- 7105267,&9 70'°2t'01, il20' t47°S7'$O,04J01' Ii20,H X- 25114&,41 E" 46405&,43 6~ Y" S98219~,68 N" 780~2:S6,16 70°22'07,18~2" 247°~57'26,0620" 2222,43 X- 2S8980,00 E- 464077,&4 66 :Y' 598229~,1B N' 7805265.17 70'21'08,0997" t47 57 30,2206 2~2~.45 2360.45 X= 258840.75 E' 4640~4.75 e7 Y= 5~-a'2teT.4~ N= 78052~3;-6~-~'21'0~-['~-9;'- 147-57'2b,2208' ' 2229,80 . X= 258974,26:' E- 464075,93 ~ ~ , , 68 Y- ~982284,99 N- 780~262,64 ~ 70: 22 '08,0~7~" 247~7'~0,~80~' 2~6,82 X- 25ae35.0t , E- 46403~.02 2 ~9 Y- ~982~79 30 N- 7B0~232 1~ 70~21'07.0206" ~ ~47c~7'26.3807" 2218. t7 ~2229,t0 X- 2~8968:~3~ E- 464074:23 70 Y- 5982276.B0. N- 7805260,Z2 70~2~'07,9350" ~ 247~57'30,5403" 2~45,~9 2372,39 X- 2~8829,28 E- 46403~,3~ ~ , ~: , . :'r , , ', . , ? ~ ? ~-~ ~ .,,,, ~ ,.'~ ,; ,~ · .., .... , I I ii MPI PRO~SED WE~ L~ATION MST ~-~ ~ 4~ ~l LOCATED IN SEC. 36,T. IZ N.,R. 16 [. UMIAT ~"~---~--~ SOHIO ALASKA PETROLEUM CO. . - . Ii'~-,-~~ s~T 6 o~ ~o F.~. BELL ~ &S$OC. scsi: NI~ ~;"~ss~ ~ P~ U DHOE B~Y OF FICE %~%~~ D~WN IY: ~.65. ~. o F~UDHOE CHECKED BY; B.E ii iiii I i i II Date: 6-FEB-89 Search Radius= 200 7 DEGREE LEAD LINE For proposed well: 2-22/L-14 [22-25-12-16] Location = W-E S-N TVD(SBS) Top 258984.00 5982498.00 -56.00 Bottom 257476.38 5987532.78 10580.00 Note~ Ail depths in feet Below Kelly Bushing (BKB) Time: 15:34:50 WELL IDENT Closest Approach /PROPOSED\ /NEARB¥N CLOSEST TVD DEPART TVD DEPART DISTANCE A000-0000051 HI-1 NO COORDINATE A000--0000083 MI-33 NO COORDINATE A000-0000086 MI-36 NO COORDINATE A029-2051800 MI-SD7 5044.1 595.3 A029-2063900 ~I-SD9 1707.5 0.0 A029-2064000 ~ISD10 4847.2 438.4 A029--2156800 ~I-P18 4013.5 58.6 A029--2158500 MI-M19 1.1 0.0 A029-2160500 MI-O20 3500.0 0.0 A029--2163900 HI-O16 1400.9 0.0 A029--2164800 ~I-Q17 .100.9 0.0 A029-2166200 MI-P14 3600.0 2.2 A029-2166900 ~I-M25 0.9 0.0 A029--2167200 MI--O25 1.0 0.0 A029--2169300 MI--P20 200.5 0.0 A029--2169800 MI-J22 0.8 0.0 A029--2172200 MI-N22 1000.7 0.0 A029-2174300 MI-J18 1100.5 0.0 A029--2174800 ~I--P24 2999.8 0.0 A029-2175000 HI-S14 3500.0 0.0 A029-2176700 ~I--R12 400.9 0.0 A029-2177100 MI--K16 100.9 0.0 A029-2180100 ~I-J19 379.4 0.0 A029--2181500 POINTS WITHIN SPECIFIED SEARCH WINDOW POINTS WITHIN SPECIFIED SEARCH WINDOW POINTS WITHIN SPECIFIED SEARCH WINDOW 4383.0 707.9 1441.9 1700.0 3.3 1579.0 4634.7 897.0 983.8 4011.2 14.1 92.2 0.0 0.0 90.4 3499.9 18.1 174.6 1400.0 4.7 35.2 100.0 0.2 230.4 3600.9 37.8 30.9 0.0 0.0 175.0 0.0 0.0 197.8 200.0 0.2 173.1 0.0 0.0 79.6 1000.0 1.8 170.1 1099.5 25.2 174.5 2999.3 33.3 174.3 3501.0 10.5 170.7 400.0 0.7 139.8 100.0 0.2 69.5 400.0 1.1 197.2 Vertical /PROPOSED\ TVD DEPART Intersection /NEARBYN TVD DEPART 3968.2 48.8 6156.4 39.8 2189.0 4632.8 299.9 8286.5 277.6 3654.6 4342.7 161.1 ? J · . ~ . 6438.7 203.6 2096.0 VERTICAL DISTANCE l_ MI-P17 3500.0 0.0 3499.6 A029-2184700 MI-P19 1544.1 0.0 1543.1 A029-2188500 ~I-M16 0.9 0.0 0.0 A029-2189200 ~I-P13 3500.0 0.0 3500.5 S UHI~IAR~ - . - 77.7 15.8 0.0 21.3 161.7 20.9 29.4 111.4 The well which comes closest to the proposed well is: A029-2181500 ffI-N14 Closest approach distance = KICK OFF for this run = 16.5 feet 3500.0 feet Date: Search Radius= 200 COURSE LINE For proposed well: 2-22/L-14 [22-25-12-16] Location = W-E S-N TVD(SBS) Top 258984.00 5982498.00 -56.00 Bottom 258101.20 5987678.98 10580.00 Note~ Ail depths in feet Below Kelly Bushing (BKB) 6-FEB-89 Time: 15:30:16 Closest Approach WELL IDENT /PROPOSED~ /NEARBY~ CLOSEST TVD DEPART TVD DEPART DISTANCE A000-0000051 MI-1 NO A000--0000083 MI--33 NO A000--0000086 MI-36 NO A029-2051800 MI-SD7 5197.7 A029-2063900 MI-SD9 1707.5 A029--2064000 MISD10 4919.1 A029-2156800 MI-P18 4058.6 A029-2158500 MI-M19 1.1 A029-2160500 MI-O20 3500.0 A029-2163900 MI-O16 1400.9 A029-2164800 MI-Q17 .100.9 A029-2166200 MI-P14 3600.0 A029--2166900 MI-M25 0.9 A029-2167200 MI-O25 1.0 A029--2169300 MI--P20 200.5 A029-2169800 MI-J22 0.8 A029-2172200 MI-N22 1000.7 A029-2174300 MI-J18 1100.5 A029-2174800 MI-P24 2999.8 A029-2175000 MI-S14 3500.0 A029-2176700 MI--R12 400.9 A0Zg--2177100 MI--K16 100.9 A029--2180100 MI-J19 379.4 A029--2181500 COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW 723.3 4483.8 796.6 1397.7 0.0 1700.0 3.3 1579.0 492.7 4664.6 926.0 931.7 69.6 4056.4 14.8 84.3 0.0 0.0 0.0 90.4 0.0 3499.9 18.1 174.6 0.0 1400.0 4.7 35.2 0.0 100.0 0.2 230.4 2.2 3600.9 37.8 30.9 0.0 0.0 0.0 175.0 0.0 0.0 0.0 197.8 0.0 200.0 0.2 173.1 0.0 0.0 0.0 79.6 0.0 1000.0 1.8 170.1 0.0 1099.5 25.2 174.5 0.0 2999.3 33 .3 174.3 0.0 3501.0 10.5 170.7 0.0 400.0 0.7 139.8 0.0 100.0 0.2 69.5 0.0 400.0 1.1 197.2 Vertical /PROPOSED\ TVD DEPART Intersection /NEARBY\ TVD DEPART 3945.1 44.2 6073.9 12.5 2129.7 4720.8 352.5 8468.2 326.0 3748.4 4271.6 134.0 6352.8 181.6 2081.2 VERTICAL DISTANCE A029-2182700 Mi--P17 3500.0 0.0 3499.6 A029-2184700 MI--P19 1544.1 0.0 1543.1 A029--2188500 MI-M16 0.9 0.0 0.0 A029-2189200 MI-P13 3500.0 0.0 3500.5 SUMMAIIY 77.7 15.8 0.0 21.3 161.7 20.9 29.4 111.4 The well which comes closest to the proposed well is: A029-2181500 Mi-N14 Closest approach distance = 16.5 feet KICK OFF for this run = 3500.0 feet Interval Mud Weight~ ENDICOTT MUD PROGRAM MAIN PRODUCTION ISLAND WELL 2-22/L-14 Viscosity Fluid Loss , (sec/qt) (ml/30min) pH 0-2500 8.8-9.8 100-200 20-15 9.0-9.5 Set 13-3/8" casing 9.2-10.2 40-45 15 - 16 9.0-10.5 2,500- 11,326 11,326- 12,498 9.6-10.2 Set 9-5/8" casing 40-45 6-8 9.0-11.0 Hang 7" Liner Mud Type/ Components Generic Mud #5 Seawater Fresh water Gel Soda Ash Generic Mud #7 Seawater Fresh water Gel Caustic Soda Soda Ash Barite Lignosulfonate Drispac Lignite Newdrill Generic Mud #7 Seawater Fresh water Gel Caustic Soda Soda Ash Barite Lignosulfonate Drispac Lignite Newdrill DOYON DRILLING, INC. RI 6 NO. MUD AND SOLIDS CONTROL EQUIPMENT Equipment Manufacturer Nominal Model Capaci tM Shaker Desander Mudcleaners Centrifuge Brandt Dual Double Demco 2-12" cones Tri Flow 1000 9pm 700 9pm ( e ach ) Double 400 9pm 8 each - 4" (each) cones Pioneer Mark II, i50 9pm Decantin9 Degasser Drilco Agitators Brandt Hoppers Geosource Vacuum I000 9pm 8 each - 25 h.p. Dual Sidewinders lO00 9Pm The trip tank and mud tank sections have one vertical pit level float indicator which are connected to the drillin9 recorder system that contains visual and audio warnin9 devices located in the driller's console. ~ Ii It~' DOUBT. . - ASK:II -- _ I I , I r ~ ! I O: ' j J /z :o' ,z · I , i · ! ! t I I 1 -,~ ! I i ~L ~O ~ ~-0 ~1 ' o 6Lo .~'~ '-0 I --'° 13-5/8" API-5000~ 13-5/8" API-3000~ CONTROL LINE i WELLHEAD ASSEMBLY,ENDICOTT 5KSI 13-3/8"x 9-5/B"× 4-1/Z" SOHIO ALASKA PETROLEUM COMPANY F ICURE i (3) 13-3/8" 9-5/8" CONTROL LINE] i-" '.: : ,'~ ~'' ~ '"" 4 - 1/2:' ~: II. 3. 9-5/8~ CASING AND WELLttEAD EQUIPHENT 3.1 TESTING B.O.P. STACK I. After B.O.P.'s arc nippled up to split speedhead, make up 13" x 6-1/2 Internal Flush B.O.I'. test plug, Accessories Item 7, Part No. 538116. 2. Lower plug into head (it will land on lower step). Tighten /4 lockscrews 90° apart. 3. After B.O.P. test, back out lockscrews and retrieve test plt, K. CAUTION: It [s very important not to have the lockscrews protruding into the bore of the head while either running or pulling the B.O.P. test plug. Always check them If in doubt. (29) SPL I T SPEEOHE^O TEST PLUG THO . II _ ._~ II II II II II II II Ii ACC'lESSOR[ES ITEM 6 21,0 I P,,"IP TFC, T PlIIC; F,']C~ ~Pof:.PRCIW! (S'1F11171 ~'. <~6 DIA I ! .. t.-~/? IF FEHALE THO v II II II II II II _/ ACCESSORIES rTEN 7 L8 210 I · .-.. 2cDL~ · .-..J · '"- "E i' ;-L.,'3 cC~ LIDgEREOw'L '5~'~:6} E,. .: . II. 4. 4-1/2 TUBING AND WELLllEAD EqUIPHENT TESTING B.O.P.'s 1. After 9-5/8" has been set and tested, run in B.O.P. test pl-~, Accessory Item 6, Part Number 538117, which lands in t, pper bowl of the split speedhead. Run in 4 lockscrews lightly, 90° apart to keep plug from movlng. 2. After test, retract lockscrews and pull plug. 3. Run in short bowl protector, Accessory Item 8, Part Number 538114, using the same running tool, Accessory Item 5, Part Number 538115, that was used for the long protector. 4. After bowl protector is in place, run in 6 lockscrews liMhtly to hold protector in place. CAUTION: Upper lockscrews must be retracted when the bowl protector or B.O.P. test plug is either run or pulled. -- TEST PLUG --PACKING PORT TEST P. ORT --LOCKSCREW CASING HANGER SPLIT SPEEDHEAD 13-3/8 9-5/8 .ffif CHECK LIST FOR NEW WELL PERMITS Company ITEM A~PROVE DATE /- ' YES (1) Fee ~PC, i~47/,~F 1. Is the permit fee attached .......................................... / (2) Loc ~2'; thru 8) (8) (3) Admin .~. ~.~.7./~. 9. '(9 ~hru 13) 10. 11. (10 and 13) 12. 13. (4) Cas~ ,~.'.~.~. o ~-/y-~? (14 thru 22) 14. 15. 16. 17. 18. 19. 20. 21. 22. Lease & Well No. NO 2. Is well to be located in a defined pool ............................. 4 .... 3. Is we~.l located proper distance from property line .................. 4. Is we~ located proper distance from other wells ................ ' ... ' 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... Is administrative approval needed ................................... ~ Is the lease number appropriate ..................................... .~ Does the well have a unique name and number ......................... ~ Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... ~ Is enough cement used to circulate on conductor and surface ......... .~ Will cement tie in surface and intermediate or production strings ... ~ Will cement cover ali known productive horizons ..................... ~ Will all casing give adequate safety in collapse, tension and burst.. .x~ Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate~ Are necessary diagrams and descriptions of~'~~r-a~BOPE attached. Does BOPE have sufficient pressure rating - Test to psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (5) BOPE (23 thru 28) 23. 24. 25. 26. 27. 28. (6) OTHER · (2~ thr (6) Add: Geology: DWJ Engin_e,erin~: ,,cs rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. REMARKS INITIAL ceo. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ~ Z ~ RD 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 APPENDIXi No special'.effort has been made to chronologically organize this category of information. .o .,""-. . .'" · ,.?"-, .. .~,. · ?% . ' "" o e" "., .-'"' · ~q'".. %.-,. ..d'-:'? ...~.,.Ch. ~,'1 · "~ ./,,. ~... ,. '\.. ..:"% /.. .., ,.. ...-',% i , f}Jl:.,,alll ,i 1'1.9..1... ' i..." · I~L .i "', 1'~' /% ?%., ,,"°. .,.'-, .... ,i ,. -'1 lit-, ,' · , i,m,. , i · ' al ,.,'..-.l ..=,,, r ..,l~'l'.:~ "...h '".'" ,"', "'~ k.,..:....~.. ~..,; r~,.~: . ..::.,..~.~., "~ ' .,~%...,".., ., "-. ..~,., ..~ .~. ... ."%. .. ~?',. e""% ./',, ., ;'.. :: ..~'. ~.'. ,- . . ~-.. ,,.... .,'-...,,. /'"~i:1 ~r'"". ,"" .. ,',*' ,. r..~'rl-',,r .... ~' -.' 7!%. ,.~" ..~'. T, :-:~, '" · .,'!~.,,.;.? ........ .,,_.,.:..,,.-,,, .. ! ., ., I · · ., I ......................................... ,i330 I &$Sl %-- I VVI VI · Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 2 - 22/L - 14 500292193100 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 23-FEB-94 6145.00 D. BARBA M. MARTIN 36 12N 16E 1919 2224 55.50 14.50 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 9.625 11242.0 47.00 7.000 12322.0 29.00 4.500 10952.0 12.60 3.500 11067.0 9.20 EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GRCH 11310.0 11310.0 11399.0 11399.5 11403.5 11403,0 11407.5 11407.5 11414.5 11414.5 11419.0 11417.0 11426.5 11424.5 11452.5 11451.5 11461.0 11459.5 11470.5 11470.5 11482.5 11482.0 11487.5 11486.5 11493.0 11492.0 PBU TOOL CODE: DLL PBU CURVE CODE: GR RUN NUMBER: 2 PASS NUMBER: 1 DATE LOGGED: 12-APR-89 LOGGING COMPANY: '11519.5 11526.5 11538.0 11543.5 11559.0 11564.0 11612.0 11618.5 11620.0 11622.5 11639.5 11642.0 11650.0 11656.0 11664.5 11669.0 11676.0 11678.5 11683.0 11870.0 $ REMARKS: 11519.0 11526.0 11536.5 11543.5 11558.5 11563.5 11610.0 11617.0 11619.0 11622.0 11638.5 11641.5 11649.5 11655.5 11664.0 11669.0 11677.0 11679.0 11683.0 11870.0 PDK-100/GR. LOG TIED TO DUAL LATERLOG MICROLOG DATED 12-APR-89. WELL SHUT-IN AT 14:00, 06-FEB-94. A DIFFUSION CORRECTED SGMA CURVE IS INCLUDED FOR EACH PASS. THE CURVE IS NAMED SGNT & WAS CORRECTED WITH THE FOLLOWING PARAMETERS: BOREHOLE SIZE = 8" CASING SIZE = 7" SALINITY = 25000 ppm. OPEN HOLE GAMMA RAY DOWNLOADED FROM THE BP EXPLORATION UPS/CSS SYSTEM 22-FEB-94. SHIFT PROCEDURE AS FOLLOWS: 1) FIRST PASS GAMMA RAY DEPTH MATCHED TO OPEN HOLE GAMMA RAY. 2) FIRST PASS SGMA DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 3) ALL SUBSEQUENT GAMMA RAY PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 4) ALL SUBSEQUENT SGMA (PDK) PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS SGMA. / ? ?MATCH1. OUT $ FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 11383.0 11684.0 11395.0 11696.0 (MEASURED DEPTH) files. BASELINE DEPTH SGMA 11310.0 11310.0 11399.0 11399.5 11403.0 11402.5 11408.0 11407.5 11419.0 11417.0 11426.0 11425.0 11460.0 11459.5 11470.5 11470.5 11473.0 11473.0 11482.5 11482.0 11487.5 11486.5 11490.0 11489.5 11493.0 11493.0 11519.5 11519.0 11526.5 11526.0 11538.0 11537.0 11541.0 11540.5 11544.5 11544.0 11550.0 11550.0 11559.0 11558.5 11564.0 11563.5 11567.0 11566.5 11575.0 11574.0 11610.0 11608.5 11620.0 11618.5 11622.0 11621.0 11639.5 11638.5 11642.0 11641.5 11647.5 11646.5 11656.0 11655.5 11664.5 11664.0 11669.0 11669.0 11676.0 11676.5 11678.5 11679.0 11682.0 11682.5 11870.0 11870.0 $ REMARKS: PASS 1. - EQUIVALENT UNSHIFTED DEPTH ALL PDK CURVES WERE SHIFTED WITH SGMA. GRCH WAS DEPTH MATCHED TO OPEN HOLE GAMMA RAY. / ? ?MATCH2. OUT $ CN : BP EXPLORATION WN : 2 - 22/L - 14 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PDK 68 1 GAPI 4 2 BKL PDK 68 1 CPS 4 3 BKS PDK 68 1 CPS 4 4 BIF PDK 68 1 4 5 CSLS PDK 68 1 CU 4 6 LS PDK 68 1 CPS 4 7 SS PDK 68 1 CPS 4 8 MSD PDK 68 1 CU 4 9 PHI PDK 68 1 PU-S 4 10 RATO PDK 68 1 4 11 RBOR PDK 68 1 4 12 RICS PDK 68 1 4 13 RIN PDK 68 1 4 14 SGMA PDK 68 1 CU 4 15 SGMB PDK 68 1 CU 4 16 SGNT PDK 68 1 CU 4 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 64 * DATA RECORD (TYPE# 0) 958 BYTES * Total Data Records: 81 Tape File Start Depth = 11870.000000 Tape File End Depth = 11310.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 19058 datums Tape Subfile: 2 Minimum record length: Maximum record length: 257 records... 62 bytes 958 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 11372.0 11684.0 11384.0 11696.0 BASELINE DEPTH GRCH 11310.0 11310.0 11402.5 11401.5 11403.0 11407.5 11407.0 11410.5 11412.0 11414.5 11415.0 11414.0 11415.5 11419.5 11417.5 11423.5 11426.0 11426.5 11425.0 11429.0 11427.5 11432.0 11441.5 11439.5 11442.5 11445.0 11443.0 11445.5 11444.0 11451.5 11450.0 11452.0 11451.0 11455.0 11463.0 11461.5 11465.5 11467.0 11469.0 11468.5 11469.5 11473.0 11473.0 11476.0 11477.0 11479.5 11480.5 11482.5 11481.5 11485.5 11487.5 11488.0 11487.0 11490.0 11489.5 files. (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH SGMA 11310.0 11402.0 11409.5 11410.5 11413.0 11413.5 11421.5 11424.5 11430.5 11441.5 11454.0 11465.0 11466.5 11469.5 11476.0 11476.5 11479.0 11479.5 11484.5 11487.0 · 11492.5 11519.0 11524.0 11525.0 11527.0 11534.0 11538.0 11543.0 11547.0 11547.5 11548.5 11549.5 11559.5 11560.5 11566.5 11570.0 11571.0 11571.5 11572.5 11574.0 11575.0 11580.0 11594.5 11595.5 11596.0 11605.0 11606.0 11608.0 11614.5 11616.5 11618.0 11620.0 11622.0 11626.0 11626.5 11628.0 11633.0 11634.0 11634.5 11639.5 11647.5 11655.5 11656.0 11656.5 11659.5 11664.0 11664.5 11666.0 11668.0 11669.0 11673.0 11676.0 11677.5 11682.5 11688.0 11689.0 11689.5 11690.0 11870.0 $ 11492.0 11518.5 11526.0 11533.5 11536.5 11542.0 11547.5 11549.0 11559.0 11559.5 11565.5 11570.5 11571.0 11578.5 11594.0 11603.0 11603.5 11605.5 11615.5 11618.0 11621.0 11625.0 11638.0 11646.0 11654.5 11663.0 11664.0 11665.5 11678.0 11683.0 11870.0 11523.5 11524.0 11546.0 11547.0 11569.5 11570.0 11573.0 11573.5 11593.0 11593.5 11612.5 11615.0 11624.5 11625.5 11627.0 11631.5 11632.5 11633.5 11655.0 11655.5 11659.0 11667.5 11669.0 11673.0 11676.5 11688.5 11689.0 11689.5 11690.5 11870.0 REMARKS: PASS 2. ALL PDK CURVES WERE SHIFTED WITH SGMA. CN WN FN COUN STAT / ? ?MATCH3. OUT /??MATCH4. OUT $ : BP EXPLORATION : 2 - 22/L- 14 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PDK 68 2 BKL PDK 68 3 BKS PDK 68 4 BIF PDK 68 5 CSLS PDK 68 6 LS PDK 68 7 SS PDK 68 8 MSD PDK 68 9 PHI PDK 68 10 RATO PDK 68 11 RBOR PDK 68 12 RICS PDK 68 13 RIN PDK 68 14 SGMA PDK 68 15 SGMB PDK 68 16 SGNT PDK 68 1 GAPI 1 CPS 1 CPS 1 1 CU 1 CPS 1 CPS 1 CU 1 PU-S 1 1 1 1 1 CU 1 CU 1 CU 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 64 * DATA RECORD (TYPE# 0) 958 BYTES * Total Data Records: 81 Tape File Start Depth = 11870.000000 Tape File End Depth = 11310.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 19058 datums Tape Subfile: 3 211 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 11383.0 11684.0 11395.0 11696.0 BASELINE DEPTH 11310.0 11387.5 11399.5 11402.0 11402.5 11408.5 11410.0 11412.0 11414.0 11415.0 11419.5 11423.5 11426.0 11426.5 11430.0 11430.5 11440.5 11443.5 11447.5 11448.5 11449.0 11452.5 11460.0 11462.5 11463.0 11466.5 11469.5 11472.5 11478.5 11479.5 11482.5 11487.0 11490.5 11491.5 11492.0 11504.5 11511.5 GRCH 11310.0 11387.5 11400.0 11406.5 11408.0 11416.0 11419.0 11423.0 11426.5 11427.0 11438.0 11440.5 11444.5 11452.0 11458.5 11461.0 11467.5 11471.5 11480.5 11484.5 11488.0 (MEASURED DEPTH) - EQUIVALENT UNSHIFTED DEPTH SGMA 11310.0 11399.5 11400.0 11408.0 11409.5 11411.5 11412.0 11423.0 11424.0 11446.0 11447.0 11460.5 11465.0 11477.0 11477.5 11489.5 11490.5 11503.0 11509.5 11514.0 11515.5 11521.5 11523.0 11523.5 11531.0 11532.0 11532.5 11535.5 11536.5 11537.0 11540.0 11547.0 11547.5 11553.5 11554.5 11557.0 11559.0 11574.0 11574.5 11575.0 11592.5 11596.0 11604.5 11605.5 11610.0 11618.0 11618.5 11620.0 11622.5 11633.5 11639.5 11640.0 11640.5 11642.0 11642.5 11657.5 11659.0 11659.5 11660.0 11666.0 11667.5 11669.0 11673.0 11675.5 11677.5 11678.0 11689.5 11690.0 11870.0 $ REMARKS: 11512.0 11514.0 11520.0 11521.0 11521.5 11529.0 11529.5 11530.0 11533.5 11534.0 11535.0 11538.0 11545.0 11545.0 11546.0 11546.0 11552.0 11552.5 11555.5 11557.0 11572.0 11572.5 11572.5 11589.5 11593.5 11601.5 11602.5 11607.0 11615.0 11616.0 11617.0 11620.5 11631.5 11637.0 11637.5 11638.0 11639.5 11640.5 11655.5 11657.5 11657.5 11658.5 11664.5 11666.0 11668.0 11672.0 11675.0 11677.0 11678.5 11689.0 11690.5 '11870.0 11870.0 PASS 3. ALL PDK CURVES WERE SHIFTED WITH SGMA. / ? ?MATCH5. OUT /??MATCH6. OUT $ CN WN FN COUN STAT : BP EXPLORATION : 2 - 22/L- 14 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units 1 GRCH PDK 68 2 BKL PDK 68 3 BKS PDK 68 4 BIF PDK 68 5 CSLS PDK 68 6 LS PDK 68 7 SS PDK 68 8 MSD PDK 68 9 PHI PDK 68 10 RATO PDK 68 11 RBOR PDK 68 12 RICS PDK 68 13 RIN PDK 68 14 SGMA PDK 68 15 SGMB PDK 68 16 SGNT PDK 68 1 GAPI 1 CPS 1 CPS 1 1 CU 1 CPS 1 CPS 1 CU 1 PU-S 1 1 1 1 1 CU 1 CU 1 CU * DATA RECORD (TYPE# 0) Total Data Records: 81 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 00 201 24 1 4 00 201 24 4 00 201 24 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 64 958 BYTES * Tape File Start Depth = 11870.000000 Tape File End Depth = 11310.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 38116 datums Tape Subfile: 4 202 records... Minimum record length: Maximum record length: 62 bytes 958 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass 1 gamma ray and background counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT: 0.5000 PASSES INCLUDED IN AVERAGE PBU TOOL CODE PASS NUMBERS GRCH PDK $ REMARKS: 1 1, 2, 3 AVERAGED PASS. $ CN : BP EXPLORATION WN : 2 - 22/L - 14 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units 1 GRCH PNAV 68 1 GAPI 2 BKL PNAV 68 1 CPS 3 BKS PNAV 68 1 CPS 4 BIF PNAV 68 1 5 CSLS PNAV 68 1 CU 6 LS PNAV 68 1 CPS 7 SS PNAV 68 1 CPS $ MSD PNAV 68 1 CU 9 PHI PNAV 68 1 PU-S 10 RATO PNAV 68 1 11 RBOR PNAV 68 1 12 RICS PNAV 68 1 13 RIN PNAV 68 1 14 SGMA PNAV 68 1 CU 15 SGMB PNAV 68 1 CU 16 SGNT PNAV 68 1 CU API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 71 784 90 5 4 4 71 784 90 5 4 4 71 784 90 5 4 4 71 784 90 5 4 4 71 784 90 5 4 4 71 784 90 5 4 4 71 784 90 5 4 4 71 784 90 5 4 4 71 784 90 5 4 4 71 784 90 5 4 4 71 784 90 5 4 4 71 784 90 5 4 4 71 784 90 5 4 4 71 784 90 5 4 4 71 784 90 5 4 4 71 784 90 5 64 * DATA RECORD (TYPE# 0) Total Data Records: 81 958 BYTES * Tape File Start Depth = 11870.000000 Tape File End Depth = 11310.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 38116 datums Tape Subfile: 5 102 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 EDITED BACKGROUND PASS Pulsed Neutron only: (neutron generator off). PASS NUMBER: 0 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 Depth shifted and clipped curves for background pass START DEPTH STOP DEPTH 11327.0 11845.0 11339.0 11857.0 BASELINE DEPTH GRCH 11310.0 11310.0 11332.0 11330.5 11339.5 11338.0 11343.5 11342.5 11364.0 11363.5 11370.0 11369.0 11403.0 11401.5 11408.0 11406.5 11415.0 11414.5 11419.5 11417.0 11426.5 11424.0 11441.5 11440.0 11461.0 11458.5 11463.0 11461.0 11473.0 11472.5 11488.0 11487.0 11490.5 11489.0 11527.0 11525.0 11538.0 11536.0 11543.5 11542.5 11559.0 11557.5 11564.0 11562.0 11567.5 11565.5 11589.5 11588.0 11610.0 11607.0 11622.5 11621.0 11639.5 11638.0 11642.0 11641.0 11647.0 11646.0 11664.5 11663.5 11669.0 11668.5 11672.5 11671.5 11675.5 11675.5 11678.5 11678.0 11683.5 " 11682.5 11690.0 11690.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH 11698.5 11712.5 11718.0 11722.0 11725.5 11736.5 11745.0 11793.5 11803.5 11807.5 11832.0 11870.0 $ REMARKS: 11698.5 11713.5 11719.5 11723.5 11725.5 11736.5 11746.5 11792.5 11801.5 11806.0 11831.5 11870.0 BASELINE PASS (SOURCE OFF). BKL & BKS WERE SHIFTED WITH GRCH. / ? ?MATCH7. OUT $ CN : BP EXPLORATION WN : 2 - 22/L - 14 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 3 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PDK 68 1 GAPI 4 2 BKL PDK 68 1 CPS 4 3 BKS PDK 68 1 CPS 4 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 12 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 18 Tape File Start Depth = 11870.000000 Tape File End Depth = 11310.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 42601 datums Tape Subfile: 6 Minimum record length: Maximum record length: 100 records... 62 bytes 1014 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11382.5 PDK 11394.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PDK PDK-100 SB SINKER BAR $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): STOP DEPTH 11685.0 11697.0 07-FEB-94 FSYS REV. J001 VER. 1.1 1142 07-FEB-94 11847.0 11870.0 11330.0 11845.0 900.0 YES TOOL NUMBER 2725XA 0.000 12322.0 0.0 SEAWATER 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 0.00 '0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): -100 FAR COUNT RATE HIGH SCALE (CPS): 3900 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS) : 60000 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 1. $ CN : BP EXPLORATION WN : 2 - 22/L - 14 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 24 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 2 BKL PDK 68 3 BKS PDK 68 4 BIF PDK 68 5 CCL PDK 68 6 CSLS PDK 68 7 CSS PDK 68 8 G1 PDK 68 9 G2 PDK 68 10 ISS PDK 68 11 LS PDK 68 12 SS PDK 68 13 MON PDK 68 14 MSD PDK 68 15 PHI PDK 68 16 RATO PDK 68 17 RBOR PDK 68 18 RICS PDK 68 19 RIN PDK 68 20 SGMA PDK 68 21 SGMB PDK 68 22 SGNT PDK 68 23 SPD PDK 68 24 TEN PDK 68 GAPI CPS CPS CU CPS CPS CPS CPS CPS CPS CPS CU PU-S CU CU CU F/MN LB 4 4 06 511 09 0 4 4 39 705 61 6 4 4 74 169 61 6 4 4 00 201 24 1 4 4 92 630 79 6 4 4 00 201 24 1 4 4 00 201 24 1 4 4 35 975 96 1 4 4 36 631 32 1 4 4 00 201 24 1 4 4 71 162 89 6 4 4 05 626 89 6 4 4 32 125 68 0 4 4 00 201 24 1 4 4 00 201 24 1 4 4 23 260 40 0 4 4 23 260 40 0 4 4 23 260 40 0 4 4 23 260 40 0 4 4 96 761 61 6 4 4 00 201 24 1 4 4 00 201 24 1 4 4 52 386 28 5 4 4 17 922 28 5 96 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 132 Tape File Start Depth = 11700.000000 Tape File End Depth = 11372.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 70942 datums Tape Subfile: 7 206 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 FILE SUMMARY ' VENDOR TOOL CODE START DEPTH GR 11372.0 PDK 11384.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PDK PDK-100 SB SINKER BAR $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): STOP DEPTH 11686.0 11698.0 07-FEB-94 FSYS REV. J001 VER. 1.1 1217 07-FEB-94 11847.0 11870.0 11330.0 11845.0 900.0 YES TOOL NUMBER 2725XA 0.000 12322.0 0.0 SEAWATER 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): -100 FAR COUNT RATE HIGH SCALE (CPS): 3900 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 2. $ CN : BP EXPLORATION WN : 2 - 22/L - 14 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FOR~T RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 24 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 2 BKL PDK 68 1 CPS 3 BKS PDK 68 1 CPS 4 BIF PDK 68 1 5 CCL PDK 68 1 6 CSLS PDK 68 1 CU 7 CSS PDK 68 1 CPS 8 G1 PDK 68 1 CPS 9 G2 PDK 68 1 CPS 10 ISS PDK 68 1 CPS 11 LS PDK 68 1 CPS 12 SS PDK 68 1 CPS 13 MON PDK 68 1 CPS 14 MSD PDK 68 1 CU 15 PHI PDK 68 1 PU-S 16 RATO PDK 68 1 17 RBOR PDK 68 1 18 RICS PDK 68 1 19 RIN PDK 68 1 20 SGMA PDK 68 1 CU 21 SGMB PDK 68 1 CU 22 SGNT PDK 68 1 CU 23 SPD PDK 68 1 F/MN 24 TEN PDK 68 1 LB 4 4 06 511 09 0 4 4 39 705 61 6 4 4 74 169 61 6 4 4 00 201 24 1 4 4 92 630 79 6 4 4 00 201 24 1 4 4 00 201 24 1 4 4 35 975 96 1 4 4 36 631 32 1 4 4 00 201 24 1 4 4 71 162 89 6 4 4 05 626 89 6 4 4 32 125 68 0 4 4 00 201 24 1 4 4 00 201 24 1 4 4 23 260 40 0 4 4 23 260 40 0 4 4 23 260 40 0 4 4 23 260 40 0 4 4 96 761 61 6 4 4 00 201 24 1 4 4 00 201 24 1 4 4 52 386 28 5 4 4 17 922 28 5 96 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 138 Tape File Start Depth = 11701.000000 Tape File End Depth = 11357.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 77027 datums Tape Subfile: 8 212 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 9 is type: LIS FILE HEADER FILE NUMBER: 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11382.5 PDK 11394.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PDK PDK-100 SB SINKER BAR $ STOP DEPTH 11685.0 11697.0 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 07-FEB-94 FSYS REV. J001 VER. 1.1 1250 07-FEB-94 11847.0 11870.0 11330.0 11845.0 900.0 YES TOOL NUMBER 2725XA 0.000 12322.0 0.0 SEAWATER 0.00 0.0 0.0 0 0.0 0~. 000 0.000 0.000 0.0 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): -100 FAR COUNT RATE HIGH SCALE (CPS): 3900 NEAR COUNT RATE LOW SCALE (CPS): 0 NEA~R COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 3. $ CN : BP EXPLORATION WN : 2 - 22/L - 14 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 24 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BKL PDK 68 1 CPS 4 3 BKS PDK 68 1 CPS 4 4 BIF PDK 68 1 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 G1 PDK 68 1 CPS 4 9 G2 PDK 68 1 CPS 4 10 ISS PDK 68 1 CPS 4 11 LS PDK 68 1 CPS 4 12 SS PDK 68 1 CPS 4 13 MON PDK 68 1 CPS 4 14 MSD PDK 68 1 CU 4 15 PHI PDK 68 1 PU-S 4 16 RATO PDK 68 1 4 17 RBOR PDK 68 1 4 18 RICS PDK 68 1 4 19 RIN PDK 68 1 4 20 SGMA PDK 68 1 CU 4 21 SGMB PDK 68 1 CU 4 22 SGNT PDK 68 1 CU 4 23 SPD PDK 68 1 F/MN 4 24 TEN PDK 68 1 LB 4 4 06 511 09 0 4 39 705 61 6 4 74 169 61 6 4 00 201 24 1 4 92 630 79 6 4 00 201 24 1 4 00 201 24 1 4 35 975 96 1 4 36 631 32 1 4 00 201 24 1 4 71 162 89 6 4 05 626 89 6 4 32 125 68 0 4 00 201 24 1 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 4 00 201 24 1 4 52 386 28 5 4 17 922 28 5 96 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 132 Tape File Start Depth = 11700.000000 Tape File End Depth = 11372.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 103768 datums Tape Subfile: 9 206 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 10 is type: LIS FILE HEADER FILE NUMBER: 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 0 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11327.0 PDK 11339.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PDK PDK-100 SB SINKER BAR $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS / OIL RATIO: CHOKE (DEG): NEUTRON TOOL STOP DEPTH 11854.5 11867.0 TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 07-FEB-94 FSYS REV. J001 VER. 1.1 1055 07-FEB-94 11847.0 11870.0 11330.0 11845.0 1800.0 YES TOOL NUMBER 2725XA 0.000 12322.0 0.0 SEAWATER 0.00 0.0 0.0 0 0.0 0.000 0.O0O 0.000 0.0 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): -100 FAR COUNT RATE HIGH SCALE (CPS) : 3900 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): 0.0 REMARKS: BASELINE PASS (SOURCE OFF). $ CN WN FN COUN STAT : BP EXPLORATION : 2 - 22/L- 14 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BKL PDK 68 1 CPS 4 3 BKS PDK 68 1 CPS 4 4 CCL PDK 68 1 4 5 SPD PDK 68 1 F/MN 4 6 TEN PDK 68 1 LB 4 4 06 511 09 0 4 39 705 61 6 4 74 169 61 6 4 92 630 79 6 4 52 386 28 5 4 17 922 28 5 24 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 63 Tape File Start Depth = 11870.000000 Tape File End Depth = 11310.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units =Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 92715 datums Tape Subfile: 10 136 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 11 is type: LIS 94/ 2/23 O1 **** REEL TRAILER **** 94/ 2/24 01 Tape Subfile: 11 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes · End of execution: Thu 24 FEB 94 10:34a Elapsed execution time = 43.66 seconds. SYSTEM RETURN CODE = 0 LLLLLLLLLL. L' _ : LLLL. LLLL I i I i I :[. I I I i SSSSSSSS i i ~: :i: i i i I I i ~: ::; ~'.~ S S $ S S S I I ~5 5t5 ii SS Ii Ii SS SS i I ! I i i I I I I SSSSSSSSSS iiiiiiliii ~i,o~'S'-"--"-' .... D [.:' [:~ ~.:~ i.'.':. [:: [:, £.'. [:, id L' D [:, [:, [:, [:~ [:, D [.~ [:, [:, U i...i D D C, D i.l U D D [;, ['.,U U D D [:, C, Li U D D D D U U D D D D U U DD D D U U DD DD UU D D D D U U DDDDDDDDDD D DD E:,D DD Di':, U L~ i',! i','! l'! t"i LI U H. H bi H i',i ~-i U U Pi Pt Pt i'l M Pi t':i t:i U U ~'i H i,I H i',i H bi hi U Li bi i'ibi bi hi ~,i i,i i',i U Li hi i'ibi i'i i~i ~'i U U hi hi i,i Pi U U H i'i i'i hi U i..ibi i'i bi i',i U U H b'i i'i bi H bi i'i H LI LI U LI U U U LI U U U U U U U U U U U LI U LI 22 2 2 O0 O0 O0 O0 O0 O0 O0 00 ii iii iiii ii ii ii ii ii ii ii iiiiiiiiii iiililiiii 00000000 00000000 O0 O0 00 O0 O0 O0 O0 O0 00 000000 0000 00000000 AA AAAA AA AA AA AA AA AA AA AA AAAAAAAAAAAA AAAAAAAAAAAA AA AA AA AA AA AA AA AA 00000000 O0 O00000 O0 O0 O0 O0 O0 O0 O0 00 00 O0 O0 O0 O0 O0 O0 O0 O0 0000000000 00000000 RRI~F.'.RRRRR RR RRRRRRRRRRRR RR RR RR RR RR RR RRRRRRRRRRRR RRRRRRRRRRR RR RR RR RR RR RR RR RR RR RR PPPPPF'PPPPP P PP PP F'F'F'P F'F'F' PP PP PP PP PP PP PPPPPPPPPF'PP PPPPPPPPPPPP PP PP PP PP PP 88889:,,7::88:B8 888888:'3:='.:888:~ 88 88 88888888 888888:~:8 88 88 ,., 0 ,) 0 ,Ti C, 0 ,, ,-' 0 bi bi bi i',i H i'i Pl Pl M Pl I'i I"l i'i H M ~i M I't M f'i M i~i MM t,1 H HH bii"i 9999999999 99 99 '~L-~ 99999 '.-'~ 999 ,~,~ 999 'i) 99999 S Service~ n~me: &G5F01 Pr.~vious r. mel: Date: 89:"04/20 Comments: HEADER Origin: RECORD~~ Reel name: 264264 Continuation ~ Oi S:rvice name: &G5F01 Previous tape: Date: 89/04/20 Commmnts: Origin: Tape name: 264264 Continuation File: name: .001 Ser-vica name: Version Date: Na>..:imum length: 1024 File type: LO Previous ?ile: ., M H E H CN WN COUN S T A T CTRY APiN LATi LOHG SECT T 0 bJ N RAHG EK~ E DF EGL PD LMF DMF RUH TiHE DATE LCC SOH. LUN FL LUL ENG]' W l T N DD DL C8Dt C:8L ] TLi BL I TCS TLA8 8HT MR T HT hiSS DFD MViS DFPH DFL RM RMF bIFST HFSS RMC I NFORMAT I ON F:ONTENTS 2-22/'L-i 4 MPI EhlD I COTT NORTH SLOPE ALASKA i..iS A '2 i 9~ i 36,,, ~6E,, 5.5., i4,500 HS .... KB .... K B .... i 2/ 4/'89 30 ...... 264264 NORTH SLOP E E ZARNDT i ~, .00 i 1 ~4~.000, i i ~42, i i ~8,000 ic. 3~O. 9.~5i .... 9, ~50 .... O, '000 2.07, OOO, , 2 O 7,0 O i.. Z GNO FLOWL Z NE 9,800, i 0,500 5,600, i , ~70, , 78, O00 HE~S, ~ , 83.0 EXPLORATION 'UUU ..... 0 Hin 0 Min IIIIIlIIII AP1NLIM: 50-029-2193i .......... DATE LOGGED 04-1~-~ 89 .......... I I I I ! I I I I i IIlllll Il I IIIIII, ii I I i I I i N 0 Sec W II II II II tiII I II II II I II II II II II II I II I II II II I II II I I II II II I II II i Ii JI II I II U i i i,~II I· i £ii ii ii ·i ii iI II II I I I I I I I I ADD I SOH A D D i S 0 N RECORDS LIN I T TYPE CATG SIZE CODE 0 0 40 65 0 0 40 65 0 0 40 65 0 0 20 65 0 0 '-20 65 0 0 20 65 0 0 4. 6,9 0 0 ~4 65 0 0 34 65 0 0 2 65 O 0 .'g 65 0 0 ~ 65 FT 0 ~ 4 68 FT 0 3. 4 68 FT O 3. 4 68 0 3. 2 65 0 3' ;2 65 O 3. 2 65 0 0 2 79 0 0 4 68 0 0 8 65 O 0 2 79 O 0 10 65 0 0 10 65 0 0 20 65 O 0 20 65 0 0 20 65 O O 20 65 FT 0 ,3 4 68 FT 0 3 4 68 FT 0 3 ,4 68 FT 0 ~ 4 68 FT O :3 4 68 FT 0 3. 4 68 HR 0 2 4 '" HR 0 4 4. 6,9 DEGF O i 4 68 DEGF 0 I 4 68 0 2 20 65 0 2 20 65 LB/G 0 2 .'t 68 CP 0 2 4 68 O 2 4 68 O '2 4 68 OHMM 0 2 4 68 OHMbl 0 2 4 68 DEGF O '2 4 68 O 2 i2 65 Oi-tH H 0 '2 4. 68 ERROR M H E M MCST MCSS L: '._-; I NFORMAT I ON RECORDS CONTENTS UNIT 76,000 .................................................. DEGF i'iEAS ............................................. 9,625 ................................................... 8,500 ................................................... TYPE C A T ii SIZE 4 i2 4 4 CODE 68 Page ERROR COMMENT RECORDS ;.~lmll Location Comment Wall Location Comment Wmll Location Comment Wmll Location Comment Wmll Film Comment I: t.,;mll File Comment 2: Well File Comment 3: l.,.Imll Fite Comment 4: SURFACE: 1919' FNL & 2224' FEL B.P. EXPLORATION: 2-22/L-14 MPI CHLORIDES = 14'00 PPM. ANNULAR HOLE VOLUME CALCULATED FOR LINER. DIGL/SDL?DSN TOOL STRING RUN IN COMBINATION, PLS SYSTEM USED. .m:~ LIS tapm written b~7: ANCHORAGE COMPUTING CENTER · :~ All curve an.d tool mnemonics u~ed are those which most closely match ~,:m Gearhart curve and tool mnmmonicz, ~E:ARH~RT TO SCHLUMBERGER TOP ~OTTOM MNEM SERVICE UNIT MNEM SERVICE UNIT DEPTH Fl' DEPT FT ~R GAMMA GAPI GR GAMMA GAPI GRCO GAMMA GAPI GRCO 'GAMMA GAPI LLD DLLT OHMM LLD DLLT OHMM CLLD DLLT MMHO CLLD DLLT MMHO LLS DLLT OHMM LLS DLLT OHMM MGRD MCGRD O'HMM M~RD MCGRD OHMM GRCOI GAMMA GAPI GRCO GAMMA GAPI C:AL.I CAL. I_2 IN CALl CALI_2 IN TEHS DITSHD LBS TENS DITSHD LBS DEPTH 10796.00 11227 75 I1227 75 I1227 75 11227 75 '11227 75 "11227 75 11227,75 11227,75 11227,75 DEPTH 12366 .00 12365 O0 12365 O0 12365 O0 12365 O0 12365 '00 12365 O0 12365 O0 12365 O0 12365 O0 DITSHD 8RID GAMMA DSN_I I DSN I I DSN_I I DSN_I I SDL SDL SDL SDL. SDL SDL. SDL SDL SDL 8DL SDL SDL C A L, I_1 M I CLOG FLAG MY GAPI CPS CPS DECP C?C DECP CPS CPS IN IN OHMM Pi I M K SP GR FDSN NDSN NPHI NRAT DPE DPHI DRHO FSDL NSDL PE PELC QLS QSS QPE RHOB SDSO CALl MINV D I TSHD BRID GAMMA DSN_I I DSN I I DSN_I I DSN_I I SDL SDL SDL SDL SDL SDL SDL SDL SDL SDL SDL SDL C~LI_I MICLOG FLAG MV GAPI CPS CPS DECP C?C DECP CPS CPS ~N OHMM 11227' 75 I 1227 75 11227 75 11 227 75 11 227 75 11 227 75 I 1 227 75 11227 75 11227 75 11227 75 11227 75 11227 75 I 1 227 ?'5 I 1 227 75 11227 75 11227,75 11227,75 ! 1227,75 11227.7,5 11227,75 11227,75 12365 O0 12365 O0 12365 O0 12365 O0 12365 O0 12365 O0 12365 O0 12365 O0 12365 00 12365 O0 12365 O0 12365,00 12365.00 12365,80 12365,08 12365,00 t2365..00 12365,00 12365,00 12365,00 12365,OO MNORI ILH t ILD1 CILD1 SGRD SP1 TENS t'ilMK1 CTEN MICLOG D IND DIND DIND SGRD DIND DITSHD DITSHO DSTU OHMM OHMM OHMM MMHO OHMM MY LBS FLAG LBS COMMENT RECORD MNOR MtCLOG OHMM ILM DIND OHMM ILD DIND OHMM ClLD DIND HMHO SGRD SGRD OHMM SP DIND MV TENS DITSHD LBS MIMK DITSHD FLAG CTEN DSTU LBS 11227 75 11227 75 11227 75 I1227 75 11227 75 11227 75' 11227 75 112'27 7S 11227 75 12365 12365 12365 12365 i2365 12365 12365 12365 12365 O0 O0 O0 O0 O0 O0 0 0 O0 0 0 BATA FORMA ENTRY TYPE DESCRIPTION 16 Datu.m zpeci¢ic~tion block zub-type 0 Tecmlr, a~o~~ ( no mop~_ entpi ez ) TYPE T SPEC I F I CA SIZE CODE 16 1 Gg 0 I 66 TIONS Pa ge DATA FORMAT SPECIFICATIONS SERVICE SERVICE AP1 MNEM ID ORDER ~ UNIT LOG AP1 AP1 APl FILE TYPE CLASS MOD ~ PRC # SiZE LVL SMPL RC PROCESS iNDiCATORS DEPT 264264 FT 0 GR GAMMA 264264 QAPi GRCO GAMMA 264264 GAPi LLD DLLT 264264 OHMM 12 CLLD DLLT 264264 MMHO ii LLS DLLT 264264 OHMM i2 MGRD MCGRD 264264 OHMM 52 GRCO GAMMA 264264 GAPI CALl CALl 2 264264 IN 2 TENS DITS~D 264264 LBS MIMK DiTSHD 264264 FLAG '0 SP BRID 264264 MV 0 GR GAMMA 264264 GAPI 3 FDSN DSN Ii 264264 CPS 23 NDSN DSN-II 264264 CPS 23 NPHI DSN'-II 264264 DECP 28 NRAT DSN-'II 264264 C/C 24 DPE SDL- 264264 53 DPHi SQL. 264264 DECP 58 DRHO SDL 264264 G?CJ :FSDL SDL 2642.64 CPS NSDL SDL 264264 CPS 53 PE SDL 264264 PELC SDL 264264 QL.S SDL 264264 54, QSS SDL 264264 54 ~PE SD,L 264264 53 RHOB SQL. 264264 G/C3 53 S'DSO SDL. 264264 IN 52 CALl CALl 1 264264 IN 2 MINV MICLOG 264264 OHMM 52 MNOR MICLOG 264264 OHMM 52 IL.M DIND 264264 OHMM 71 ILO biND 264264 OHMM 7i CiLD bIND 264264 MMHO SGRD SGRD 264264 OHMM 72 !SP bIND 264264 NV 0 TEHS DiTSHD 264264 LBS MIMK DiTSHD 264264 ,FLAG 0 CTEN DSTU 264264 ,LBS .0 0 0 0 1 lO.O i O 1 0 i00 i 0 1 0 200 60 1 0 i 04 60 1 0 200 40 1 0 700 10 i 0 1.OO 1 0 i 0 800 i 0 I 0 350 0 1 0 0 0 i 0 :0 0 i 0 1,O.O i 0 i 0 343 I 0 i 0 343 0 I O 9,00 4 O 1 0 20.O 1.0 1 0 590 1 0 1 0 901 30 1 O 560 i 0 I 0 540 20 I 0 54.0 i 0 i 0 58.0 1 0 1 0 58'0 20 i 0 3:':00 G 0 1 0 3O O 7 O 1 O 5.9 :O 2 :O 1 0 50 O 1,O i O ,82 O 3 'O i 0 8,00 i 0 1 0 50'O 10 1 0 52,0 20 1 0 204 40 1 O 204 60 1 0 I 04 60 1 0 20'0 60 I 0 ::0 :0 i 0 350 0 I O 0 0 i 0 0 0 I 0 4 O i 68 4 O i 68 4 0 i 68 4 0 $ 68 4 0 t 68 4 0 1 68 4. 0 i 68 4 0 1 68 4 O i 68, 4 0 1 68 4 O i 68 4 O 1 68 4 O ,i 68 4 O 1 68 4 0 1 68 4 O 1 68 4 O 1 6,8 4 O 1 68 4 O i 68 4 0 i 68 4 O i 68 4 0 i 68 4 0 J 68 4 O 1 68 4 0 i 68 4 0 1 68 4 O I 68 4 O '1 68 4 0 J 68 4 O I 68 4 O '1 68 4 0 i 68 4 .0 1 68 4 0 i 68 4 .0 .1 68 4 0 I 68 4 O I 68 4 0 1 68 4 O i 68 :4 0 i 6.8 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 00000.0 000000 000000 000000 000000 000000 000000 000000 000000 000000 OOOO00 O'O0000 000000 000000 000000 O0000'O 000000 O0000-O 000000 00000.0 000000 '000000 000000 O0000O 000000 000000 000000 000000 000000 '000000 000000 OOO000 000000 000000 000000 00000'0 000000 '000000 OOOO00 000000 · 000000 :000000 000000 000000 000000 000000 000000 000000 0,00000 000000 O00000 000000 000000 000000 OOOO00 000000 000000 000000 000000 0:00000 000000 'O0000O 000000 000000 000000 .000000 000000 0'0000.0 000000.0'O0000 000000 :OOO000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 O00OOO 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 DEPT CALl NRAT QLS i LH GR TENS DPE QSS ILD GRCO MiHK DPHI QPE CiLD DA LLD SP DRHO RH08 TR RECORD CLLD ~R FSDL SDSO SP LLS FDSN NSDL CALI TENS NDSN i-' b M l N V M i H K GRCO NPHi PELC MNOR CTEN Page 12365,008 5.046 -vv¥.250 -999.250 -999,250 12300,000 8,347 5,I78 -.040 20,366 12200,000 8,320 5.18:3 -.010 1i0,609 1 21 00,000 8,5:74 4.986 -,010 241.730 12000.000 8.687 6,377 ,O3i 23,0~ 1900,000 8,3:30 5. 347 ,001 t:05,085 6 2200 -999 -999 -999 23 5:387 19 14 5460 0 -- 17 5227 0 20000 87 5241 0 26 5140 20000 .016 ,80i ,250 .250 ,250 ,596 .4i6 · 046 · 039 · 886 .772 ,169 , .000 ,009 ,636 .713 · :357 .000 ,015 ,00'0 .898 ,908 ,000 ,013 ,059 983 053 ,00,0 '005 000 7 0 -999 -999 -999 29 0 50 18 0 6 21 0 1 09 0 :3'8 23 .472 · 000 ,250 .250 ,250 ,305 · 000 ,131 .11i ,286 · 347 ,000 ,265 .031 ,773 .999 ,000 ,266 .051 · 050 ,167 ,000 .094 .191 .374 ,577 · 000 ,267 ,045 ,050 ,200 4732,220 -999,25 0 -999.250 -999,250 20,8:37 4458.220 ,063 2. 429 28,:360 153,596 3970,500 .015 2,209 125;066 2t2,351 5135, OOO ,016 2,208 25,0· 114 24.741 4732. 220 , O19 2.49 0 29,52i 197,614 5019,920 ,026 2,2,05 149,554 O,OOO -999.250 -999,250 -999.250 -999,250 0,000 31 ,603 6930.994 ,056 58,837 0,000 19,744 9281.217 0,000 -7.749 0,000 19,943 9:312,217 O.OOO -12.679 0,000 75.862 5737.884 0,000 59.769 O.OOO 20,14i 9508.438 ,000 -11.:375 -999 -999 -999 -999 26 4400 16021 7 5591 1:38 4522 16265 8 5809 228 479:3 1'6285 9 5983 28 3214 1491 0 9 5532 130 4:3372 1651:3 8 54:31 .200 .250 .250 .250 ,250 .038 .332 . i54 ,945 .126 .264 .584 .791 .732 .388 ,065 ,11i .518 . :352 ,996 ,223 .985 · 246 .i23 .923 .798 .246 .:336 .749 , 067 ,939 -999.250 -999.250 - V'.V .~ , ~.r.., 0 -999.250 22,989 21182.848 2,755 2.677 0.000 61 .593 21 792. 488 2.320 3,907 0,000 50,843 22218,922 i .842 1 0. 925 O, 000 27.112 19060.789 2·447 1:3,465 O, 000 20,159 21737.574 2,106 2.674 0.000 -999,250 -999,258 -999.250 -999,250 -999.250 :32.297 .230 2.977 3.130 i114.238 19.476 .220 2.381 4.650 1:34 1 , 020 19, 129 1,945 1 0. 275 148@,9i8 7.3.522 ,268 2.829 9,789 1202.979 19.85.'3 ,228 2, i96 3,560 I i 7:3, :398 D E P T CAL i H R A T QLS iLM GR TENS DPE QSS ILD GRCO biiHK DPHi QPE CILD DA LLD SP DRHO RH08 SGRD TA RECORDS CLLD GR FSDL SDSO SP LLS FDSN NSDL CALl TENS MGRD NDSN bi i N V Pi i M K GRCO NPHi PELC MNOR CTEN P~LDe ilSO0,O00 8.64i 5.825 .OiO i3.508 li700,000 i0.249 t0,599 -.022 4.I72 11600,000 8.4.57 4.785 -,018 2`33,793 11500.000 9,568 5,049 ,006 9,896 li400,OOO 9,568 4,777 ,046 8,402 11300,000 9,802 2,`324 -,009 i76,796 102,002 5256,459 ,000 -,019 2:3.87i 99,128 5096.400 ,204 ,027 4. 295 17,51:3 48 05. `386 0,000 -. 0`34 1 092,567 73,26 0 4863,589 . O00 ,.02i 1'.0,715 74,664 53i4,662 ,008 · 0`32 .9. 704 28,876 5067,299 O, OOO . Oi 0 29 O, 07`3 126,68.3 O, 000 · 05..7,, -, 228 41 ,89i 123, 114 O, 000 ,1i`3 .i:31 2:32,806 21. 750 0,000 ,212 -, 068 ,915 90,986 O, 000 ,007 -, 288 93, :32'9 92.7`30 0..000 ,Oii -,066 103,055 35,86.3 '0, O00 , ,002 .-,18i ,3,447 14, 120 5i 51,440 .0i6 2,558 i 4. 09`3 4,564 5091 , i 60 , 2,460 7,296 492.1 80 4i70,52i 2,296 ,382,`3`30 i O, 826 3789,668 ,005 2,633 i2.112 7,860 ,002 2,626 9. 003 320,4,01 45,34,940 -,016 2,642 .35 O, 248 0,000 i 0`3, `357 5i,39,217 ,000 116. 864 0,000 90,239 6828 'i 05 .i40 94.6i:3 0,000 1 8,949 8047.4:38 0,000 -5,244 0.000 78,114 4415,994 O,OOO 122,699 O, 000 67,911 4501 ,550 ,000 8:3,812 0,000 29.152 4229,994 O,OOO 5,940 12,660 `3465,926 14569.246 9,3i2 5416,5i7 3,898 i487,543 i6239,699 ii,600 5358.3i4 `340,543 4957.880 15781.609 8,72`3 5401,967 9,398 4i15,i10 14001,97,3 i0,'078 5445,618 7,280 4447,419 140,39,.79i i0,087 5722,08`3 280,07:3 11924,721 1,3566,336 10,451 547,4,720 7.289 i877i.727 2.`326 8.i70 0,000 2,30:3 i4658,94i 4.469 i,980 0.000 11,,309 22058.652 2.295 3.277 0,000 9,246 19319,,3'16 2,897 8,197 O,O0.O i9754,984 3.5`38 6.776 0.000 271,851 2576`3,293 4,742 28.573 O,O00 99,321 .244 2.782 6.790 i,32i.299 78.694 .463 4.207 i,99,3 ii53.680 18,699 .20i 2.432 3,695 1212.8,38 72,556 ,i98 `3,47`3 6,,313 i,360,7,38 6.3,052 3,669 `3,902 15._-48,219 26,645 ,052 5.i05 33,271 1380,459 DEPT [:AL i NRAT QLS i LM GR TENS DPE QSS iLD GRCO MIMK DPHi CiLD OATA LLD SP DRHO RH08 SGRD RECORD CLLD FSDL SDSO LLS FDSN NSDL CALl TENS MF;RD N D S N PE M i NV M i~iK GRCO NPHi PELC OTEN F'ag~ l0 ~,: .~ * :~: FILE TRAILER **** Fi. la name: &GSF01 . 001 Maximum length: 1024 TRA I LER RECORD'~ Version File type: LO Next ~ile: Date: Pmg~ 1t **m. FiLE HEADER .m~ Film name: .002 Servica nama: Version #: Date: Mmximum length: 1'024 File type: LO Previous ~ile: INFORMATION RECORDS Page 1 2 M tq E M CONTENTS UNIT T'fPE CATG SIZE CODE ERROR CN WN FN COUN STAT CTRY APIN LATi LONG SECT TOWN RANG EK8 EDF EGL PD LMF DMF RUN TIF1E [)ATE LCC SON LUN FI. LUL ENG I WITN DD DL CBD~ CBL 1 TLi ,BL i TCS TLAB BHT MAT blSS DF.D MViS DFPH .DFL Rt'i RMF MFST blFSS Ri'it 8,P. '"-22/L-~ i 4 MPI ENDICOTT NORTH SLOPE ALASKA LiSA 2i 9~1 'OOO ..... ~ I ~ m O [)ag 0 Min 0 0 D~g 0 Min 0 36 ....... 12N ...... 16E ...... SS.S00 , . O. ~000, . . ~4,500 . , MS KB KB ...... ~7~4,000 . , 30 264264 ,., NORTH SLOP . , E ADDISOA E ADDISON ZARNDT l~..O.O i2~35.:000 ...... 11242.0.00 ....... 11242,000 '11228. '000 ..... 12~3'0. 000 ..... 9.~51 ......... 9, ~50 ........ O, O00 ......... 207. :000 ....... 207, :000 ....... LI6NO FLOWL ~ NE 9,8'00 ..... ~8., 0'00 .... t0 , 500 .... 5,600 ..... i . 37:0 ..... I , i ~0 ..... Z8.00.0 .... ME~S. ~ . 8~.0 ............... EXPLORATION APi NLIM: DATE LOP, GED I I i · I I I I I I I I I I I I I I · I 0 Sat . N FT FT FT FT FT FT FT FT FT HR HR DEGF . DEGF L8/G , CP ,' Oi4HM , OHMM . DE6F , OHMH 0 0 40 65 0 O 40 65 0 0 40 65 0 0 20 85 0 0 --':' 0 65 0 0 20 65 O 0 4 68 0 0 34 6~ 0 0 34 65 0 0 2 65 0 0 3 65 0 0 3 65 0 3 4 68 0 3 4 68 0 3 4 68 0 3 2 65 0 :3 2 65 O 3 2 65 0 0 2 79 O 0 4 68 0 0 8 65 0 0 2 79 O 0 10 65 0 0 10 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 20 65 0 3 4 68 0 ~ 4 68 0 ~ 4 68 0 3 4 68 0 3 4 68 0 .3 4 68 0 2 4 68 0 4 4 68 0 1 4 68 0 I 4 68 0 2 20 65 0 2 20 65 0 2 4 68 0 2 4 68 · 0 2 4 68 O 2 4 68 0 2 4 68 0 2 4 68 0 2 4 68 O 2 12 65 0 2 4 68 I NFORMAT I ON RECORDS Pagm MNEM CONTENTS UNIT TYPE CATG SIZE CODE ERROR MCST M C S S CS ?G, 000 .................................................. ME~S ............................................. 9. 625 ................................................... 8,500 ................................................... DEGF 0 2 4 GE; 0 2 i2 6.5 COMMENT RECORDS Hmll Location Comment 1: SURFACE: 1919' FNL & 2224' FEL Well Location Comment 2: tdmll Location Comment 3: 8.P. EXPLORATION: 2-227L-14 MPI Well Location Comment 4: Wmll Film Comment 1: CHLORIDES = 1400 PPM. ANNULAR HOLE VOLUME CALCULATED Wmll File Commmnt 2: LINER, DIGL/SDL/DSN TOOL STRING RUN IN COMBINATION, Well Film Comment J: SYSTEM USED. Well Film Commmnt 4: FOR PLS II [.IS tapm writtmn bp: ANCHORAGE COMPUTING CENTER ~ All curvm and tool mnmmonics used are thosm which most closel:~ match ** Gear. hart curve and tool mnemonics. ~m GEARHART TO SCHLUMBERGER TOP 80TTOM MNEM SERVICE UNIT MNEM SERVICE UNIT DEPTH DEPTH FT DEPT FT '10796,00 GE2 GAMHA G'API GE GAM~A GAPI 11334~00 GECO2 GAMMA GAPI GECO GAMHA GAPI '11~34,00 LLD2 DLL'T OHMM .LLD DLLT OHMM 11334,00 CLLD2 DLLT MMHO CLLD DLLT MigHO 1'1334,00 LLS2 DLLT OHMM LL$ DLLT OHMM 11~34,00 MGRD2 MCGRD OHMM MGRD MCGRD OHMM 11334,00 CALI2 CALI_2 IN CALl CALI_2 IN 11334,00 TENS2 DITSHD LBS TENS DITSHD LBS 113~4,00 MIMK2 DITSHD FLAG MIMK DITSHD FLAG "113~4.00' DEPTH 12:366 O0 12!002 O0 12.002 00 12.002 O0 12062 O0 120 02 00 1 2 0 0 2,0 0 12002 O0 12002 OO 12002 O0 Page 14 SP2 GR3 GRC03 FDSN3 NDSN3 NPHI3 NRAT3 DPE3 DPHI3 DRH03 FSDL. 3 NSDL3 PE3 PELC3 QLS3 QPE3 RHO83 SDS03 CALI3 MINV~ 8RID GAMMA GAMblA DSN II DSN II DSN II I DSN I! SDL SDL SDL SDL SDL SDL SDL SDL SDL SDL SDL CALI_I MICLOG NV GAPI GAPI CPS CPS DECP C?C DECP G/C3 CPS CPS G/C3 IN IN OHMM SP GR GRCO FDSN NDSN NPHI NRAT DPE DPHI DRHO FSDL NSDL PE PELC QL$ QSS QPE RHOB SDSO CALl MINV 8RID GAMHA GAMMA DSN_I I DSN_I I DSN_I I DSN_I I SDL SDL SDL SDL SDL SDL SDL SDL SDL, SDL. SQL SOL CALI_I MiCLOG MM GAPI GAPI CPS CPS DECP C/C DECP G/C3 CPS CPS G/C3 IN OHMM 11334 11334 11334 11334 11334 11334 11334 11334 '11334 11334 11334 11334 11334 li334 i1334 i1334 11334 i1334 i1334 i1334 li334 .00 ,00 ,00 ,00 .00 ,00 ,00 .00 O0 O0 O0 O0 O0 O0 O0 O0 O0 '00 '00 O0 12002 O0 12002 O0 ~.002 O0 12002 O0 12002 O0 12002 O0 12002 O0 1 2002 00 12002 O0 12002 O0 12002 O0 12002 O0 1 2002 O0 12002 O0 120 02.00 12002, O 0 12:002,00 1 2002..00 12002. O0 12002,00 12002. O0 MNORS iLMS I LD3 C ILDS SGRDB TENSS M I MK~ CTENS SP~ MICLOG D I ND DIND DIND SGRD DII'SHD DITSHD DSTU D I ND OHMM OHMM OHMH MMHO OHMM LBS FLAG LBS MV COMMEN MNOR MICLOG ILM DIND ILD DIND CILD DIND SGRD SGRD TENS DITSHD MIMK DITSHD CTEN DSTU SP DIND T RECORDS OHMM 10796,00 OHMM 11334.00 OHMM 11334.00 MMHO 11334,00 OHMM 11334.00 LBS 11334,00 FLAG 11334.00 LBS 11334,00 MV 11334.00 11290 12002 12002 12002 12002 12002 12002 '12002 12002 50 O0 O0 O0 0 0 O0 O0 O0 O0 Pag~ 15 ~ATA FORMA .~: :*: ~ :s ENTRY 8LOCKS :~:~ ~ EN TRY ~-':~. ENTRY BLOCK LEGEND .~'~ TYPE DESCRIPTION i6 Datum spmci~ication block sub.-tppm 0 Terminator ( no mor. m mntrims ) T SPEC. I F I CA TYPE SIZE CODE 0 i GG T IONS Page t6 DATA FORMAT ~*.** DATUH SPECIFICATION BLOCKS ,I.: :+: :4 :f: :+: -'+: ~: :~ :~: :+: · :+:, :.~ ,'+: ,'~ .'+: ."N :4 :+: :+:..'+: :~ ~ .'+: :~ :+: :~ :+: :~ :4-:. :+: ~: SPECIFICATIONS 17 SER¥ICE SERVICE AP1 MNEM ID ORDER # UNiT LOG AP1 TYPE AP1 APl FILE CLASS MOD PRC ~ SIZE LVL SMPL RC PROCES9 INDICATORS DEPT 264264 FT 0 GR GAMMA 264264 GAPI 3 GRCO GAMMA 264264 GAPi 3 LLD DLLT 264264 OHMM 12 CLLD DLLT 264264 MMHO LL~ DLLT 264264 OHMM 12 MGRD MCGRD 264264 OHMM 52 CALI CALI 2 264264 IN 2 TENS DITS~D 264264 LBS 16 MIMK DITSHD 264264 FLAG 0 SP BRiD 264264 NV 0 GR GAMHA 264264 GAPI 3 GRCO GAMMA 264264 GAPI FDSN DSN II 264264 CPS 23 NDSN DSN--II 264264 CPS 23 NPHI DSM--II 264264 DECP 28 NRAT DSN--II 264264 C?C 24 OPE SDL- 264264 5~ DPHI SDL 264264 DECP 58 DRHO SDL 264264 G/C3 53 FSDL SD,L 264264 CPS 53 ,NSDL SDL 264264 CPS PE SDL 264264 53 PELC SDL 2~4264 QLS SDL 264264 54 QSS Sbt.. 264264 54 QPE SDL, 2642,64 53 RHOB SDL 264264 G/C3 53 SOSO SDL 264264 IN 52 CAL! C~L! I 264264 IN 2 MINV MICL~G 2'64264 OHMM 52 MNOR MiCLOG 264264 OHMM 52 I, LH BIND 264264 OHMM 71 ILD ,DIND 264264 OHMM CILD BIND 264264 MMHO SGRD SGRD 26426,4 OHMM 72 TENS DITSND 264264 LBS 16 MtMK DITSHD 264264 FLAG :0 CTEN DSTU 264264 LBS ,O SP DIND 264264 MY 0 0 0 0 2 lO0 i0 3 1 i00 10 3 i 200 60 3 i i 04 60 3 1 2O0 40 3 i 70'0 10 3 i 800 10 3 1 ~50 0 3 1 :0 0 3 1 0 0 3 1 1.00 10 3 i 1 O0 i 0 3 1 343 10 .7 1 343 0 3 1 9 O0 40 3 1 20.O 10 3 1 59:0 1 0 3 1 901 30 3 1 56'0 i 0 3 1 54 '0 20 3 1 540 i 0 3 i 58'0 580 20 3 i ,3:00 60 3 1 3.00 70 ,3 1 590 20 3 1 5 O0 1 0 3 t 82,0 30 3 1 800 1 0 3 1 5,0.0 1 0 3 1 520 2.0 `3 1 20 4 40 3 i 204 60 3 104 60 3 20'0 60 3 1 35 '0 0 3 i 0 0 3 1 0 0 0 :0 3 1 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 6'8 68 68 68 68 68 68 68 68 68 68 68 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 O00OO0 000000 000000 000000 000000 000000 000000 000000 .000000 000000 000000 .000000 000000 000000 000000 000000 000000 O0000O 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 iOOO000 000000 000000 00000~0 000000 000000 0,00000 000000 000000 .000000 000000 000000 000000 000000 000000 OOO000 000000 000000 000000 000000 000000:000000 000000 000000 000000 000000 000000 000000 000000 '000000 000000 000000 00,0000 000000 000000 000000 000000 000000 000000 00000:0 000000 00:0000 00000.0 000000 OOOO00 OOO00O 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 '000000 000000 000000 00000'0 000000 000000 '00000.0 000000 000000 0,00000 000000 DEPT TENS NRAT QL$ iLM GR HiMK DPE Q$S iLD GRCO SP DPHi QPE CiLD DA LLD GR DRHO RHO8 S6RD TA RECORDS CLLD 6RCO FSDL SDSO TENS LLS FDSN NSDL CALl MiMK MGRD NDSN PE MiNV CTEN CALl NPHi PELC HNOR SP Pa g ¢ 15 12002.000 -999.250 5.409 ,075 29.085 12000.000 -999,250 6,602 -,004 24.339 i19.00,000 -999,250 5.253 , 'Oi 6 142,286 I1800,000 .--999.,250 6,055 .0i7 i1700,000 ..-999,250 -999.250 -99'9,250 -999,250 11600,000 495.0,894 -999,250 -999,250 .-999.250 -999.250 -999,250 .000 .003 49,135 -999,250 -999.25 0 .000 ,002 46,02 0 -999.250 -999,250 2000,0,000 -999,250 -999,250 ,016 ,'007 -999.250 -99'9.250 -999,250 -999,250 -999,250 135,357 O,OO'O -999,250 -999,250 -999.250 -999,250 -999,250 ,i97 20,352 -999,250 -999,250 ,069 -,235 21.730 -999.250 -999.250 .2.73 ,050 ,050 -999,250 -999,250 . i.08 · -, 494 29,733 -999,250 -999.250 -999.250 -999.250 -99'9,250 168,109 4880,i80 -999,250 -999,250 -999.250 -999.250 35.778 .024 2,32i 51.077 -999.250 35.778 .020 2..53i 48.377 -999.250 43.33i ,026 2,196 141.297 -999,250 94.545 ,054 2,4:67 20,758 -999,25 0 -999,250 -999.250 -999. 250 -999.280 ,2:00 -99'9. 250 -999,250 -999,250 -999,250 -999.250 34,603 7726,2i7 ,000 5372,865 -999,250 34,72j 5364,1 05 .000 5736. 634 -999.250 42,723 9692.885 ,000 53i4,662 -999,250 92,336 6265,550 .027 5620,22'8 -999,250 -999.250 -999,250 -999,250 -999.250 0,000 -999,250 -999,250 -999.250 -999.250 -999.250 3975,402 i5844,154 9,i68 0,000 -999.250 3005.737 14742,154 9.092 0.000 -999,250 4397."048 i656i.i56 8,742 0.000 -999,250 3335.i77 15642,083 8,953 0.000 -999,250 -999.250 -999,250 -999.250 -999.250 ,200 -999,250 -999,250 -999,250 -999.250 -999,250 i999i .832 2,042 i 0,037 1 i 04. 379 -999.250 i 8449. 074 2.501 12,704 i 32i, 299 -999,250 21474,305 2.156 2,968 li24.i00 -999,250 i8777,5i2 2,28i 6,5i8 i281 ,859 -999,250 -999,250 -999,250 -999.250 -999,250 12.946 -999,250 -999.250 -999.250 -999.250 -999.250 ,226 2,309 i0,696 -29,i78 -999,250 .~/~ 2.971 9,897 -28.696 -999,250 .223 2.056 3.795 -82.132 -999,250 ,258 3,269 4,43i 116,346 -999,250 -999.250 -999,250 -999,250 -999,258 8,279 -999,250 -999,250 -999,258 -999,250 RECORDS DEPT GR GRCO LL.D CLLD LLS TENS HiHK SP GR GRCO FDSN NR~T DPE DPHi DRNO FSDL NSDL QLS QSS QPE AH08 SDSO CALl ILH ILD CILD SGRD TENS MiMK 11500,000 4976.343 -999,250 -~,250 -999,250 11400,000 5~29,2i3 -999.250 -999,250 -999.250 11300,0'00 -999.250 -999,250 .-999.250 -999,250 1120.0 000 -999.250 -999,250 -999,250 -999,250 11100,000 -999,250 --999,250 -999.250 -999.250 77.738 96,548 10 0,000 4743,i80 -999 -999.250 -999,250 -999 -~,250 -999,250 -999 -999.250 -999.250 -999 75.599 93.892 7 0.000 5132,260 -999 -999.250 -999,250 -999 -999,250 -999.250 -999 -999.250 -999,250 -999 -999.250 -999.250 -999 -999.250 -999,250 -999 -999.250 -999.250 .-999 -999.250 -999.250 -999 -999,250 -999,25'0 -999 -999,250 -999 -99.9,250 -999 -999,250 -999 25.0 258 .250 -999 -999 -99'9 .739 .250 .250 ,250 .250 ,250 ,250 ,250 ,250 ,250 .250 250 ,250 .250 .250 250 250 0.000 -999.250 -999.250 -999,250 -999.250 0,000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999,250 -999,250 -99'9,250 -999,250 -999,250 -999,250 -999,250 -99'9,250 -999 -999,250 -999.250 -999 -999.250 -999,250 -999 -999,250 -999,250 -999 -999.250 -999,25.0 -999 -999,250 -999,250 -999 -999,250 -999,250 -999 -999,250 -999,250 -999 -999,250 .'999,250 -99'9 -999,250 -999,250 -999 -999,250 -999,250 -999 -999,25.8 -999,250 -999 .250 ,250 ,250 ,250 ,250 ,250 °250 ,250 .250 ,250 ,250 ,250 -999.250 -999,250 -999.250 -999.250 -999,250 -999,250 -999,250' -999,250 -999,250 -999,250 11000,0,00 -999,250 -999,250 -999,250 -999,250 9.420 -999,250 -999,250 -999,250 -999.250 MGRD NDSN PE biiNV CTEN 8 -999 -999 -999 -999 CALl NPHi PELC HNOR SP ,803 9.664 .250 -999,250 .250 -999.250 ,250 -999,250 .250 -999,250 7,341 5,590 9.695 -999.250 -999,250 -999.250 -999.250 -999,250 -999.250 -999,250 -999.250 -999,250 -999,250 -999.250 -999.250 -999,250 -999,250 -999,250 -999,250 -999.250 -999,250 -999,250 -999,250 -999,250 -999,250 -999.250 -999.250 -999,250 -999,250 -999,250 -999,250 -999.250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999.250 -999,250 -999.250 -999.250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999.250 -999.250 -999,250 -999.250 -999,250 -999,250 -999,250 -999.,250 -999.25'0 -999.250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,25.0 -999,258 -999.250 -99'9,250 -999,250 -999,250 Pagm 19 DEPT TENS NRAT QLS iL.H GR NiMK DPE QSS ILD GRCO SP DPHI QPE CiLD DATA LLD GR DRHO RHOB S~RD RECORDS CLLD GRCO FSDL SDSO TENS LLS FDSN NSDL CALl MiMK MGRD NDSN PE MINV CTEN CALI NPNi PELC MNOR SP P~ge 20 10900,000 -999,250 -999.250 -999.250 -999,250 0800, 000 -999.250 -999,250 -999,250 -999,250 -999,250 -999.250 -999,250 -999,250 -999.250 -999.250 -999,250 -999,250 -'999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999.250 -999,250 -999,250 -999. 250 -999,250 -999,250 -999.250 -999.2S 0 -999,250 -99'9. 250 -99'9,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999.250 -999.250 -999.250 -999.250 -999,250 -999,250 -999.250 -999.250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -99~,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999.250 -999,250 -999,250 -999,250 ~:*** FiLE TRAILER *~*~ File name: ~GSFO1 ,00-o Ma×irr~um length: 1024 TRAILER RECORDS .. Vmrsion #: File type: LO Next ~ile: Date: Pa gm ~.*** FiLE HEADER **** File name: ,003 SaPvic~ name: Vmrzion #: Maximum length: 1024 File type: LO Previou_~ ?ile: MHEM CN WN FN COUN STAT CTRY AP iN LATI LONG SECT TOWN RANG EK8 EDF EGL PD LMF DMF RUN T-I ME DATE LCC SON LUN FL LUL ENGI W I 'tN DD DL CSD 1 CSLi TLi 8Li TCS TLA8 8H T MRT hiT MSS DFD MVI S DFPH DFL RM Ri,IF blFST MFSS CONTENTS B,P, EXPLORATION 2-222L-14 MPi ENDICOTT NORTH SLOPE ALASKA USA 21931 °o 16E 55,500 · O.'O00 ..... 14,500 .... MS K8 K8 i7i4,000 i27 4/89,,, . 30 .......... 264264 , , NOR3'H SLOP, , E ADDISON E ADDISON ZARNDT i2322,0:0 i23~5.0'0~,. ii228,000,, 9,35i 9,35~ O, O0 0 ...... 20?, 0:0~ 207,000 L,iQNO FLOWL.INE 9,80:0 ~8,. 00,0 i,'O. 500 5,,6 00 i , ~ ......... 78,000 MEAS ..... i,830 0'00 .......... 0 Min 0 0 Min 0 m m m m im , a IIIItmI 1IImIml ImlIlII m m I i m . i i d ~ . I I NFORMA AP1 DATE LOGGED: ...... 0 Smc W I i i i i i I I I ; I · · m m m i · , ! Ii * ! JI . m m m . . . ,I m ~ ~ m a m I I * m , m ~ m NUM: 50-029-2193i 04-12- 89 TION imll. mmlml i I · m I l ! m I I m I I l , RECORDS UNIT tllIlI ,IlII I I S · I I m · m m I m m m I m i , 1 , · ~T ! . FI . FT , DEGF DEaF L8/~ . . OHMM . DEaF i , OHMH TYPE CATG SIZE CODE 0 0 40 65 0 0 40 65 0 0 40 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 4 68 0 0 ~4 65 0 0 34 65 0 0 2 65 '0 0 3 65 0 0 ~ 65 · 0 :3 4 68 0 3 4 68 0 3 4 68 0 3 2 65 0 ~ 2 65 0 ~ 2 65 0 0 2 79 0 0 4 68 0 0 8 66 0 0 2 79 0 0 10 65 0 0 10 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 20 65 0 :3 4 68 0 ~ 4 68 0 :3 4 68 0 3 4 68 0 3 4 68 0 3 4 68 0 2 4 68 0 4 4 68 0 t 4 68 0 1 4 68 0 2 20 65 0 2 2 0 65 ,0 2 4 68 0 2 4 68 0 2 4 68 0 2 4 68 0 2 4 68 0 2 4 68 0 2 4 68 '0 2 i 2 65 '0 2 4 68 Page ERROR 22 MCST biCSS C: S I NFORMAT I ON RECORDS CONTENTS i~Ii E A S ............................................. 9,6~5 ................................................... 8,5 0'0 ................................................... UNIT DEGF TYPE CATG SIZE 4 i2 CODE 68 Page ERROR 2~ COMMENT RECORDS Wmll Location Comment 1: SURFACE: 1919' FNL & 2224' FEL Well Location Comment 2: Well Location Comment 3: B.P, EXPLORATION: 2-22/L-14 Well Location Comment 4: Well Film Comment 1: CHLORIDES = 1400 PPM, Wmll File Comment 2: Wmli File Comment 3: SYSTEM USED. ANNULAR HOLE VOLUME CALCULATED FOR ?" LINER, DIGL/SDL?DSN TOOL STRING RUN IN COMBINATION. PLS Wmll File Comment 4: LIS tape written by: ANCHORAGE COMPUTING CENTER All curve and tool mnemonics used are those which most clo~¢lp match · =+~ Gearhart curve and :tool mnmmonicz. GEARHART TO SCHLUMBERGER TOP BOTTOM MHEM SERVICE UNIT MNEM SERVICE UNIT DEPTH DEPTH DEPTH FT DEPT FT 10796.00 12366,:00 GE4 GAMMA GAPI GR GAMMA GAPI 1:0796,00 11290,50 GRC04 GAMMA GAPI GRCO GAMMA GAPI 10796,00 '1'1290,50 TENS4 DITSHD LBS TENS DITSHD LBS 18796,.00 11290,50 Page 24 ~ATA ENTRY 0LOCKS ENTRY FORMA T SPEC I ~ I CA TYPE SIZE CODE 16 1 66 0 1 66 TIONS Pagm ~*~ ENTRY 8LOCK LEGEND TYPE DESCRIPTION '16 Datum $~mci¢ication block sub-t~pm 0 Tmrmina~or ( no morm mn'trims ) C, ATA FORMAT SPEC I F I CAT IONS Page 26 DATUM SPECIFICATION 8LOCKS **** SERVICE SERVICE MNEM iD ORDER # APl API AP1 AP1 FILE UNIT LOG TYPE CLASS MOD SIZE PRC # LVL SMPL RC PROCESS iNDiCATORS DEPT 264264 GR GAMMA 264264 GECO GAMMA 264264 TENS DITSHD 264264 FT 0 0 0 0 3 GAPI 3 100 10 2 2 GAPi 3 i00 iO 2 2 LBS 16 35-0 0 2 2 68 68 68 68 000000 0'00000 000000 000000 000000 000000 000000 000000 000000- 000000 000000 000000 DEPT ~R DATA TENS RECORDS P~g~ 27 11290,500 11200,000 lliO0.O00 11000,000 10900,000 10800,000 39.'705 99, 061 149.260 151 ,600 7' 1 , 388 77,G05 49,312 123.031 185,376 188,282 88,662 96,382 4921,792 4790,835 4732,632 4688,979 4645,327 4616,226 FiLE TRAILER File name: &G5FO~ ,003 Maximum lengt, h: 1024 TRAILER RECORD SePvice name: File type: LO Version #: Next ? i 1 e: Date: Page 28 Smr. vice name: &G5FO1 Next rmml: Date: 89,..04/2'8 Comments: Origin: Reel name: 264264 Contir, uation #: O1 :~.:.~m* TAPE TRAILER mmmm .Service name: Next tape: Date: 89/04/.20 Origin: Comment z: Tape nmme: 264264 Continuation #: O1
